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Home My WebLink About20163268.tiffConstruction Air Permit Application Discovery Fort Lupton Plant Weld County, Colorado Submitted for: Discovery DJ Services LLC Dallas, TX Submitted by: Cr, mphutee artnersiscr. Fort Collins, CO June 2016 Construction Air Permit Application Discovery Fort Lupton Plant Contents Attachment A► Project Description Project Description Figure I —General Location Map Figure 2 —Simplified Process Flow Diagram Figure 3 -Overall Site Layout Attachment Form Form Form Form Form Form Form Form Form Form Form Form B—CAPCD Application Forms APCD-101 Company Contact Information APCD-102 Facility Wide Emission Inventory APCD-201 E 1, Compressor Engine APCD-201 E2, Compressor Engine APCD-20 1 E3, Compressor Engine APCD-20I E4, Compressor Engine APCD-301 Engine O&M Plan APCD-200 CB, Compressor Blowdown APCD-200 RP, Compressor Rod Packing Vents APCD-202 D I , EG Dehydration Unit A.PCD-202 D2, EG Dehydration Unit APCD-302 Dehydrator O&M Plan Form APCD-203-Fug, Fugitive Equipment Leaks Form APCD-303 Fugitive O&M Plan Form APCD-205—CT, Condensate Storage Tank Form APCD-304 -Condensate Storage Tank O&M Plan Attachment C Emissions Estimates Reciprocating Engines Compressor B l ovwdown Compressor Rod Packing Vents Condensate Storage Tanks TEG Dehydration Unit Produced Water Storage Tanks Fugitive Equipment Leaks Dehydrator Enclosed Flare Plant -Wide Enclosed Flare Reboiler Burners Facility Potential to Emit Summary Attachment D Regulatory Analysis Attachment E ----Supporting Documentation Gas Analysis ProMax Simulation Flow Sheet Attachment A Project Description Project Description Discovery Di Services, LLC is proposing the installation of the Discovery Fort Lupton Plant. This facility will process produced gas recovered from oil wells to extract natural gas liquids (NGL). It will be located in Section 11, Township 1 North, Range 66 West in Weld County, Colorado (see Figure 1). Produced gas will feed to an inlet separator where liquids will be separated from the inlet gas. Overhead gas will be fed to four inlet compressors driven by gas -fired reciprocating engines equipped with oxidation catalyst, and then to one of two 20 MMscfd mechanical refrigeration unit (MRU). Ethylene glycol (EG) will be injected into the gas fed to the MRU and then to a chiller. Propane used as a refrigerant and recycled via electrically driven compression. The chilled gas will feed to a three-phase separator, where residue, NGL and water/EG streams will discharge. Residue gas from these units will discharge to a natural gas sales pipeline, and recovered NGL will be staged out of pressurized bullet tanks to a sales NGL, pipeline. Still vent vapors from the glycol regeneration unit will be will be sent to a BTEX unit and from the BTEX unit will be sent to an enclosed flare. The inlet gas will flow through an inlet separator where the gas/liquid will be separated. The water/condensate collected at the separator will be stored in atmospheric API 12F tanks that will be manifolded together. Vapors off of these tanks will be collected and compressed with an electrically -driven vapor recovery unit (VRU) and injected back into the inlet gas stream. A simplified process flow diagram is presented in Figure 2, and a preliminary facility plot plan is presented in Figure 3. Emission sources associated with this project include: • Natural gas fired reciprocating engines • Compressor rod packing vents and blowdown • Condensate storage and thermodynamic flash • Produced water storage tanks • Mechanical Refrigeration Units with EG dehydration unit flash tank and regeneration still vent • Combustion emissions from natural gas fired burners (EG regeneration, NEIL stabilization) • Combustion emissions from enclosed flares • Fugitive Equipment Leaks t I leJI 4 Fe I --- N C 3 a J 0' ((fX Lis1 2 $08 •••• r �▪ ,,. S ! r %___ I `� ,39r'Cy S-5;71\441 Eltrelti)5fr J 5164 I 11/4 c QynCIS,, f • 5o' y� y ie7 .4. N. j; om "r:71 ■ . ■ r,•. /503 7 • • • -‘+" I 4 ? 1 • ' T • • W ■ too - r C w. i • • 4n. • •; dfir • • • 7d (i:. General Vicinity Weld County, Co C2-mpliance Wirer,..... Ft. Collins, CO (970) 420-0001 WWw.conitlaIiance-partners.com Discovery DJ Services LLC Discovery Ft. Lupton Plant PROJECT NAME Discovery Ft. Lupton Plant FILENAME Loc.srf General Location Map Sec. i , TIN, R66W Weld County, Co LE 1 in = 700 rn REVISED 6/8/2016 FIGURE NUMBER 1 1 L. 0 n c a ID a E 0 0 0 C a) hij E' Electric VRU Condensate Storage J G) Z Q ❑- A fro nW � A X so wco co 2 le w csii >ct a) N EG Regenerator Y I C I 0 F- 45 C O a) v .C CL M�1VIDI Col6IN" E IT 04E' 03 tt O CL C 2 cq LL . e % J .001.1_ 41- > 00 'Ea O _! t' Tin cb O.to 15o z J a 6 as V 6 it g 2 LL — a z LU W 2 I S I r a a < '4 a L, a Jit r- 4....4 Ji rI 27 DOUBLE DRIVE GATE . — - a§ w re I PAO M r _ - =a a - -nL. a a raw am a a we. a a g )- $S r I i t- • as = >4 12 N 52,I(,Ir_�T "T .. pi I — 1 w 7 I(I ®. a a III 8 00 r- O1)d6 lie MK cnn E)] arm And C7 —J .i b438d1Ienee) F -� av3HII3MO I ass Ear d3100'V `J3 it3SN3aNO3 L x'' , J t I L I g 8 IL U, it eg IN Ii II ii 4=. 1 ti PARTNERS, LLC. U ai aJ a' 2 uj stilt W O tt� r. 0 2 2 I ? Tccfi= . . , £* 'II _ NHL '0;4:74\''.3.374.3.3 ]i4:4;-04 6tS S..'8 `lily3l'•,'cJIw4S Asa. l;d Attachment B CAPCD Application Forms Form APCD-101 Colorado Department of Public Health and Environment Air Pollution. Control Division Company Contact Information Form Ver. September 10, 2008 Company Name: Discovery DJ Services LLC Colorado Department of Public Health and Environment Source Name: Discovery Fort Lupton Plant Permit Contact': Cory Jordan Address: 7859 Walnut Hill Lane, Suite 335 Sheet h Dallas TX 75230 City State Zip Phone Number: (214) 414-1980 Fax Number: Same E-mail: cory@discoverymidstreann.com Billing Contact: (Permit Fees f Same Address: Street City State Zip Phone Number: Fax Number: E-mail: Compliance Contact2: Same Address: I Street City State Zip Phone Number: Fax Number: E-mail: Billing Contact: (Annum' Fees) 4 Same Address: Street City State Zip Phone Number: Fax Number: E-mail: Check how would you like to receive your permit fee invoice? Flail: LI E-mail: Fax: O Footnotes: ' The permit contact should be the point of contact for technical information contained in the permit application. This may be a company representative or a consultant. 2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted facility. 3 The billing contact (Permit fees) should be the point of contact that should receive the invoice for fees associated with processing the permit application & issuing the permit. (Reg. 3, Part A, Section VI.B) The billing contact (Annual fees) should be the point of contact that should receive the invoices issued on an annual basis for fees associated with actual emissions reported on APENs for the facility. (Reg. 3, Part A, Section VI.C) Page 1of1 APCD-1 O 1 _Contact Form APCD-IO2 Company Name: I)ucniers 1)4 Srnkcr, 1.1.17 Source Name, I)i+cr ery Furl I,vptnn Plant Source AIRS II): Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form leer. September 10. 2008 Colura:do Depa.naslelu of Public I'catch and Environnle11[ r --- ('nrornrolkd PnIeRSWI to Eml(4PTE) - — — ( ■ntrelkd Potential le Erna (1'7 ) -- - CM: mtcrkyru ( F F. (Error hI Criteria {Tl'i) 1 I LU', (Ilnh r) PNI _Ct +' Intl (TPY)1( :G[)y NM CO I t"iY[' I ti7 Tel F:T1 0 X 0 ILSI �, I[6'110 ,1071 { nr,f}rl tIk8III Equtpmrii lk'.cription TM' P%I • 1'411, S[I r.- tii}x CO{'S1 5'{;ht' I Ir1 Tnl FR I \rl 11{'IIt} Aortal Acre rrllr. Meth 224-T!tTP TSP to ,.� rktis .{erlal .1vv n-7ire AIr1h X21-Ttn' CO. 1Y1� `i,S} Cf}Ir New F,1-prriprantlrylEngine 0.0 0.a 0-0 0 I 6.7 32.4 9,03 I 39 36 0 0 46.11 731 454 a 0 0 0.A 0.0 00 67 6.7 6.4 1 39 36 New _ '4w Y,.+-krc(ra Cl E P rqt Emile IJ-Hrciprnnting �}.0 0.0 4.0 0.0 �(i7 3� J $ n4 I 39 36 0 0 4,648 73R 454 0 0 0 O.a 6.p 00 0,0 734 454 0 0 0 SI6 2 162 0.0 6.7 6.7 6.4 39 .16 0 0 lr4..1 73R �{-1 0 n • Engine 00 0.0 0.a 4.0 0.0 D.0 67 G.7 I CO J2.J + 5_.-1 0.4 904 1 9.RJ l.13 39 _16 36 0 0 4,641 y 611 731 7311 4S.[ JSJ a 0 ; - 0 0 0 - 0 0.4 O.a 0.0 d.0 0.0 0,0 0.0 0.0 6.7 6.7 6.7 ►-.7 6.4 39 39 36 36 0 0 0 9 ! 021 3s021 731 731 44 154 0 0 0 0 0 • 0 P 5,162 + R 161 5,162. 'd 0 0 0� !C162 tires IA -Reciprocating F: O.n n.0 34 0 0 5,16'. 5,162 6.7 ---n,0 6.4 New New CII-S-umnrn,cr Il(rnrr onn PI'-k&11'rcklhgSral`t'enu 0.0 0.0 4A 0,0 6 2. 17 4 12_ 0 0 0 68 0 0 0.0 0,0 0.0 0.0 0,0 5.2 25 17 12 0 4 a 6n 0 p New _--. (Tama lera.tiTanks Cr. 0.0 0.0 0.0 0.0 0,11 00 0.0 CO, 4.0 0.0 13-7 1 109 74 19 50 n 0 0 296 0 _ 0 0.0 0.0 a.0 n.0 0.0 _ 0.0 0.7 1 109 74 19 50 0 0 296 a 0 a 2 6 26 000 0.40 151 wit 0.0 135.7 , II5:.7 4743.9 59.2 II!! 0 a 0 Jn5 0 0 0.4 Co0.0 an 0.4 0.0 0J 1 2 1 0 0 0 ----e 0 I 0 R 0 "Zen tiro III-T)rindraler 113-IArindeatgr 00 0.4 0.0 4.a. 4a 0.0 I3.1 1 R,1U ,ills lE1 I,-LJR 0 i 0 0 S P 0 0.0 0.0 A0 A0 P.4 0.0 n! 163 5d 7 - -9 0 0 II 9 It 0 0 0 a 36 0 nn . J 0.0 0.0 0.0 0.0 n,a 0,0 13.1 I 8.153 4RJ !2R Lai R —_ -- 0 0 5 0 0 0.0 0.0 0.0 0..0 O,0 0.0 0.3 163 i 5 7 29 0 0 0 _ 0 0 0.9 2 tL_9 p0.rypa � 0 Nix F F ttte E l I.raka wRr rNI'nxT+ 0.0 0,0 0.0 d,4 0.0 0.0 !.3 1 120 17R b7 tS4 4 0 0 327 d 0 0.0 0.0 n.0 O.0 O,A 0.P S.E 115 270 1711. 4 0' 0 113 0 n 1.6.3 0.00 62 ...- 0.10 i :HIE" OS, _ Perm& Permitted Sources 5uhlalat Etemp4 Soren 0.0 00 0:0 0.1 26.7 129.-1 221.,1 17,167 .Lull IAEA 0.24 005 0.16 3,26-3 0.72 11,+90 0.00 2,45t con I$I1 O.aa J,Rtt 0.011 n a.4n h 0.00 - 0.0 O.0 0.0 0.1 26.7 + _l47 46.:t 732 0 61 517 0-d3 101 0.00 291 o.at 12,024 O.On 2,951 0.na I,Rtt 0 AA 6Ri 0.00 0 0.110 ar 0 15 fO,T.! On 21.607 0 n0 I - - I I .. I I Ir I I 1 .\TI,pi cotmp(I 1(1tf1tR(lirrnt atFV4Orgy Suhinlal w ie(tr(e+ a s 0.1 11.0 00 0:o 0.0 O n I Aloe 1 0 a n 0 0 0 0.n 0.0 to ' 0.0 k 0.0' 0.0 01 1 0 C 0 n 0 0 0 n 0 n 0 0 0 o 0 p� r Mr l'rodurrd 1i't(t.r Ster.re Ta9Jtr a-0 a 0 1 n n 4.a I nine 0.00 Q.1 F o9 3-1 I J I 11 I 0 I ( T 0 0 a r a ��..rak.o.'I,.,1, e n o I ti4'1e I'lalt•S►-Ide EAe%snl Flare IEa11)^16alarlReteeteraler 11444,44 0 . 0 • A n 4 A in 0.0 0.0 0.9 4.4 0.05 1.-1 0.11 1 2 0.00 I n.l a,d :wr rw'r■e 0,0 h■ krinrd _..... a.a Vi K- and HIP r a0 maw, set a.0 (Veera k O.0 ttirrkw..lr 0 ma rak dNbat 0 0.0 0.0 0 0 a s 0 0 014 n.3R 1! :V,nr --- o.0 i 't we...tr. PASS34 % .r Fur r..h.r,,., es . t Pr,snt,■,1 {-.pt,arrd ti T.t+lr ['alulalk [ 0.0 4.4 0 a 0.0 O.a , LJ 1.� 0.1 4-0 O.0 n,d A,0 0.0 0.4 a0 0.0 a.d OA New 3taltllurMunn - r 0.0 • 4.0 0.0 0.0 11 1.2 o t n,0 a.0 0-0 0.0 n.0 0.a 0,0_ _ 0.0 .. 0.4 to a.0 1,793 n 0 ),793 0.0 O:0 Q8 -a 1.4 1.2 0.1 1 0.0 0.0 0,0 0.0 0.0 a.0 00 0.4 0.0 0.0 1,793 1. 0 0 1.79.4 1 IinigrdM.nl :SuhmMal - 0,4 O.0 0:0 0..0 + R e 1 0.1 Ia9 34 4 ; 1 4 0 0 0 0 - 0 0.0 4.0 _-. ! 0.0 04 1 ..4 I r • 2.6 0.! 104 S1 i I1 A 6 0 o -- o o 3 &R7 _ _ q 0 !,5419 Ttl..1. All Sewtrt, - 0.I 9.0 1 .0.i I 0.1 1 24.5 1 t31.9 I Uncontrolled ILtPIStmnr_rg(TP1-)s UncantrolkdTotal,.t01L1Fs(TPt'1-i 221.. ! 17.474: 1 1?r94 T 104 1 3,274 I 71l 540 I 2 951 I I nli J,wl3 I -- 0 1 P I 0 I o -n I 0.o T 0.1 T 29.6 {'oetralkd)L1,i1/2Sia,.n.eY['rw}')-, Controlled Total. 1 29.3 AlIIA1kOn} 46.7 ■ 111 512 Ins ( Se9 -+ t 1 T «014(' _4 1 1175 615 0 0- 1 2.1.314 j t1 0 -Al I 2,t,19!� � 9.0 I 0.9 � 0.4 I 1.6 I 9,1 ( 1.$ 1 0,9 1 2.4 1 a.4 r OA I 0 1 0.3 I 0.1 I a. j 6.0 I 1.5 1 09 1 n.3 I 0,0 I p.a I 26.1 ' 0.7 Company Marnt 6/8/2016 Page 1ofI AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit You will be charged an additional APEN fee if AI'E.N is filled out incorrectly or missing information and requires re -submittal. Permit Number: Reciprocating Intertial Combustion E n i n e l [Leave blank unless APCD has already assigned a pennit # & AIRS ID] Emission Source AIRS ID: Facility Equipment ID: El [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 Administrative Information Company Name: Discovery DJ Services LLC Source Name: Discovery Fort Lupton Plant Source Location: Section 11, T1 N, R66W Portable Source Home Base: ova Mailing Address: 7859 Walnut Hill Larne, Suite 335 Dallas, TX Person To Contact: Cory G. Jordan E-mail Address: Cory@discoverymidstream.com Section 03 — General Information For existing sources, operation began on: Normal hours of source operation: 24 hours/day General description of equipment purpose: Gas Compression Date the engine was ordered: 2016 Date the engine was relocated into Colorado: nia NAICS, or SIC Code: 213112 County: Weld Elevation: 5,135 Feet ZIP Code: 75230 Phone Number: (214) 414-1980 Fax Number: (2 14) 414-1989 7 days/week 52 weeks/year Section 02 — Requested Action (check applicable request boxes) Request for NEW permit or newly reported emission source Request for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) Request MODIFICATION to existing permit (check each box below that applies) El Change fuelor equipment ID Change company name ■ ■ • (� Change permit limit LI Transfer of ownership 1I Other Request PORTABLE source permit Request ADEN Update Emissions data nzust be completed. Blank A PENs will not be accepted. II Notification of AOS permanent replacement A+ ail, Info. Notes: For new or reconstructed sources., the projected startupdate is: n/a / Will this equipment be operated in arty NAAQS nonattainment area? (h.ttp:/fvv nv.colorado.gov/cdphe/attainment) Section 04 — Entwine Information Engine date of manufacture: 2015/2016 Date engine construction commenced: Date of any reconstruction/modification: nla Manufacturer: Caterpillar Engine function: U Primary and/or peaking power p Model: G3516B Compression Pump jack Manufacturer's maximum rated horsepower a sea level: Manufacturer's maximum site rating: Engine Brake Specific Fuel Consumption @ 100% Load: Cycle Type: Ignition Source: ■ a 2 -Stroke Spark ■ 4 -Stroke Compression 1,380 Yes ■ No Engine displacement: 69.3 7,301 Serial No.: Emergency back-up power Water pump U. Other: BHP @ 1,400 RPM BHP @ RPM Btu/HP-hr Combustion: Aspiration: What is the maximum number of hours this engine is used for emergency back—up power? FORM APCD-201 Lean Burn. Natural I Don't know E/cyl kW Rich Burn Turbocharged n/a Hours/year Page 1 of 2 Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of live -year term., or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to Colorado Department ofPubliic Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this ADEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 AP EN forms: http://www.colorado.gov/cdphe/APEN1bnns Application status: http://www.colorado.govicdpheipermitstatus 0 Check box to request copy of draft permit prior to issuance. Check box to request copy of draft permit prior to public notice. Form APCD-201-RICEAPE-Ver.02.10.2014.docx • ;s111 ;mu Las • z C c C mo •cid *A* C z z 0 cot TT� V 1 II Fu 4 Foo au ittt Emission Source AIRS ID: •• L z O I 4) •rq Fir 7:4 •rt O ■ sw -45 I t r-� W C) L. CD ce G�5 PC cc E u et T. Vim+ tn sid ' If U•. 1'M North Latitud (meters or 6 iL-H ca Q . n..n /O ,..... 2 Flow Rate Velocity (ACFM) (it/sec) I CsJ 1 '4' G) oo CD Temp. (IT) O Stack Discharge Height Above Ground Level cfeet) in CO I Stack Base Elevation (feet) in CO Operator Stack ID No. El ' C 0 a ,• 0 • O A ■ czt I..r C U 0 Other: Length (inches) = Ii O Exhaust Opening Shape & Size (check one): tion information Section 06 -- Fuel Consum (N Le tv C4 , Sul fur Fuel Heating Value Content (t-uu./1b, Btu/gal, Btu/SCF) (1% wt_) r C di V 1,100 Btuiscf , 88.2 MMscfy c3 c I Fuel Use Rate @ 100"x, load (SCF/hr, gal hr) rE O 0 aLt - e Natural Gas f Csi C P : U Is i1 6 se 915 tin cie Iwl1 'ne ma�yy. FINS 0 ,46d U r,.� Cot rum 1•i.1 ita rte+ rt ��•�yy •w iE no esi no (in w PPS 64. z ;j t • a t mic PSI S a .i..1 W V V tit I Si FZI N O_ N fir' a. (N Cl. N a. Manufacturer Manufacturer Manufacturer Manufacturer (N ck (N iq CL N 1- a. Please use the APC) Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed atu► e. n. Requested Permitted Emissions en O a in a di O O o CD a N 6 'Vs tt1 N s is c t (NO r 0 c 0 d n 0 d in 0 a 0 a - co "zr Co co � Ni o (N Q 0 a I b/M M Btu Ib/MM'VMBtu g/hp-hr lb/MMBtu CO g/hp`hr g/hp-hr g/hp-hr Ib/MMBtu lb/MMBtu m 2 a Emission 'O _W f LO LU r-- A. f- O a L{7 03 'r co r Lo r acoo O O Lc a 0 0 O O 0 0 0 0 0 in O) co o co 0 c it � l o V x Oxid. Cat Oxid. Cat m /� �} ! x 1OOS CO Formaldehyde Acetaldehyde { Acrolein Benzene C/3 .� • g ciP itri :ft ig V 4:$14 CI3 Gil -O • B•W 03 • -4 O cis I— ) y�y f) 4I V r .rr r • • cin • ee ..T, \IVY C C r.• ei Ga L 0 a) c CDrat CL a a wN 4 4Y 4 G CC a a o t J rc aOa(1414 IC F-1 aw f 73 r� cti • ti PC 5- 0 roi t hti c c ▪ to 0 o,0 o ISC rcs +� Qd) ✓ Po. +IS tin ▪ ss1 0 I 5 r!�I pa C! .10 . rr• o • a IS 'IC Cd Cd t O 0 as L I C •a tot :et U sp. ars tin 5 O r r•c Ca O visa • • • 15 O d as 0 C-) V O €s d C`1 L Con Q) 110 44) 0 A�l pma C- MID Ct O , 0. 1 C4-1 N • T C e•� wJ :mot 0ten V0.4 I rpmilwas 0 T 0 t Coal • no Ni w H C 4 coo coo 11 C H z ^r� l 1 ii al!C '^I 9•.• Cu S▪ F 5 L C S. id C7 6.0 4.4 r. v p! ag Emission Source AIRS ID: fH 1 00 . Cid Cab 1) i.r 11. ran 03 I J u in V Lir JZ cso cif )7r a i7r iPow .... I1 0 i Cab i E.. tu S^^r.▪ f11 rAn Fa O '1" • C) 0-1 ILJ 01 la ••y Yj 40 lag <14 %Cre Pak as opid ima t. rei Ce ttl C Section 01 -- Administrative Information O ICal ce — sit Oa To T • at ��1 #1 co 4 C N ai o it: 7 Inc 9.) C p i at E CD IA • mall . IC �, ,iy Ca o. 61 J Os aeat Q -. W =MI• 4•— o a.n wa Pa Lir 0 cat 74 w al Q O ft Cr Git 2 V V mo 1'J{�.rCI sm i S V 134 V iii Discovery DJ Services LLC Company Name: ■ i CO NJ CO Car LI W C a Source Name: Section 11, TI N, R66W Source Location: Change company name +.r C Transfer of ownership E ti Change fuel or equipment essi ass sass esic '4/ Portable Source Request PORTABLE source permit I c Request APEN Update ED 0 CO N- N Lane, Suite 335 7859 Walnut Hil Emissions data must be completed. Blank A PETVs will not he accepted. 0 (214) 414-1980 Phone Number: Cony G. Jordan 5../cd cid O Cco rim S Coe a INS C) r rar C • 1i.1 seia •r+1 ■ (214) 414-1980 Fax Number: Cony@discoverymidstream.com E-mail Address: Cl eN tn sa a 0 0 • ■ ✓ �..i �,,. `la Po ed 0 mzt c1/44 U, C a z Gas Compression pmcnt purpose: Ce .INN fCIS Pt Ut r.+ �c � a Cis *4 E cc miz a U fral Q CIO %7M •, M art Cs) so ice. 4 z 1.5 Art �# 4? r* p .�..i0 Tei 0 Cri cz con to lob ti '.*, o a, Sms1 two Cis) a C • la pot •,� ▪ o �. 0 CO 0+-i , c 0.4 met C' • fi E V I • • ED, • 44 la 5a1 Q 11/41 •- is to 44 maw wLs • cy� o ttj ct +� Ca c Elf E E n 4° a on 0 icolo i • i 11,4 18"4 C rain a? ` 10141 teeri eke '1 LLI Et ces alb w 0 en gzt ry el CS en en Coen k✓ tires I z 0.0 ♦~ "0a C ro C be aoi 4.1 Ct 2 a • T Application ca Ct .0 0on 42 O 0 .�i .^ mo •r+ . co co 7-4 O Lks 0 Co U 0 am 0) 0 Lo 0 0 O 0 0 Date engine construction commenced: (0 cs L V Date the engine was ordered: c1J C Date of any reconstructienlmodifcation: C Date the engine was relocated into Colorado: U C 7 a I Ci 044 CO T6 let cot a .5 0 0. Engine date ofmanufacture: 7 CO CD I y3 0 ‘65 .j..1 0 Manufacturer: z CJ c# .T7 6K • T cd 0 cd 074 • 0 CD OD CO • • r U En 001 6.4 • can E 64 2 a— ' r CeD • ray T• i 4 a1 1 ice' t. i2• ct C 0.4 z N - Engine Brake Specific Fuel Consumption @ 100% Load: a 00 C U Combustion: ■ U ■ 4V z ■ as g H a I C ua uolortqutop ituaai.ul CI Ct4,4 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Red Emission Source AIRS ID: Q E z TN. 01) a Is)7 La E 0 con tam T1 Ita ient ire Ct r" r �w� t~ .Z' I a) 4.0 ar/ yy��, C) els 0.0 et — tai Co C E I. C) I- / LL 03 0 4.4 0 N i P' W MN M Northing or Latitude (meters or de` roes) 4434719 U t TIM Easting or Longitude (meters or degrees) 521844 rr I o Horizontal NAD83 bstructing raincap Velocity (ft/sec) NI a Flow Rate (ACFM) NI - co 0 CD Vertical Temp. CF) CD CO MI Direction of stack outlet (check one): - Operator Stack Base Stack Elevation ID No. { i pct) E2 5,135 II 0 CZ" isa C El (N r 4 tie CAI Ca Co C▪ r) 4V rim IN e'7 . e1 V Cas W CN N Natural Gas 10,070 scfh n/a 88.2 MMscfy 1,100 Btulscf < 0,01 25 Actual Reported for Requested I emiit Limit Calendar Year l Ty] S C) 0 mos haL i ea0Va . i st g I ••r r-' st •im tj Can I AP -42 N a cC N i'l 0., c( AP -42 Manufacturer Manufacturer Manufacturer Manufacturer AP -42 N iii Cl. < CV le ai Q ed Permitted fissions 0 0 0 0 rte- 1` N.- En NO co O O 6 co o 0 d co c> O 6 CO O 6 6 C+ I i co N CO N w CO 6 N c a o 6 c c r4 issi � c Actual Calendar Year Emissions2 Controlled CI-oils/Year) kcrolein 1 nla 0 0.00 51 ibll tMBtu Benzene nla 0 0.0004 Ib/MMBtu 3 Please use the A PCD Non -Criteria Reportable Air Pollutant Addendum form to re-ortpollutants not: lis u will be charged an additional APEN fee if AMEN is filled out incorrectly or missing information and requires re -submittal. tual emission fees vvill be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions_ ttaroiled /Year) Emission Factor Documentation attached Data year for actual calendar yr. emissions below & fuel use above (e.g. 2007); Emission Factor Cr.; - fir * = Ib1MMBtu ti 2 2 2 zi co L � ca CI ch -C CO 2 in Lit j 7.71 E-5 7.71E-5 0.0008 0.5 0.48 0.5 0.113 0.0084 tJncontrol :ontro l Fficiency eduction) o to c C C O r- an CO 0 Control Device Description l 3 . A C OA C) � �! r�4/•� i yy�� (V C• //�•� 41J C Ca 0 al 0 03 0 .mil w C I� ct C (•5 L t ' R O t (•�fR V ;'W C Pollutant V�� MI a) o E a aw 0 InC sr; V1j •mil Cn • YYI wit 0 + ` T�1 Yf•� sic n o E i ry �•A tdd rfr � 5I] •" Fri o i� fi) ray c �F d rs t2, tit C) c) CC3 v cis •r �fti L Y 0 .0 o •T-1 1-4 I — cu crni wimi Y di CY ) yer oo i0 ►ao S•e C O 1 Nat O 0 Kin S -• VI U C C C 0 tur z ws iC U r -s 0 • 1o1 r wso wrZ Nod .- Ct 6'3 • ke Lr Q 0 .w U z 0 F• C tit 4 Piet Ir•al let Eml W L C z z C ri C ri g stilt � 1 I SHIV a3.11110uoisst tua C� slat 5 ret +C L 4J . � C) ad a • � rte. •Q 0 J+, �+NI ci V O tec• t 0 U 42) • I 0 MC Cd re o • W iz it i.. E 4.4 Cse cam? lii 491 lye Ca L Ce •a E clip 0. CS C? 4-4 a — 4- Coe • >~ C1? r04` +•e Cor = Vfonii �. esi I YJ t Cal COO Section 01 — Administrative Information r. C C u Request for coverage under GENERAL PERMIT number GP02 (Natura U CN C` Ls p� y./ a .. L) z con Discovery DJ Services LLC Company Name: C 0 0 U, a Source Name: • 0 Change company name 0 • L J • • H czt Section 11, TIN, R66W Source Location: Change permit limit Request PORTABLE source permit co C Ci en 0 0 0 Request APEN Update Ei 0 CNI 0 U a N Lane, Suite 335 2 V Emissions data must be completed. Blank APES will not be accepted. ca ca (214) 414-1980 Phone Number: Cory G. Jordan TA 0 ;••1 t replacement rmi Cid emlia w ,•. 636 ' Mt .t (214) 414-1980 2 z Cory►@discoverymidstream,com E-mail Addre • pea Vaal Information Section 03 — Genera ct • 465 D4 wati +04 eat Cry G3' 4 C3 U r — tin 0 C 1 C 1 d I) C C7 7.711 ~ C Cw" Ct w 45 WM. C tab E t ea cui C? ,L eta C 0 •a .� 2 5 ..� .n :3 .0 E U 44:4 a ism i..l `t FF>1� . la CL) 0 • 0 0 • 0 (451 f."' �Y CA • ••• tax L C! g SE • Y•1 to 64 cr pia .fie. U 'd T C a Ch Qs tom 41 Cal wive o E a s•. les +CA NI ire 45 r Ut 0 Clo cm Ci•.,4 jy %% U- cit taa 0 IS (64 elti :61 SI 30 d 2 7 L t r a "cup z oft p co,) i of C? Ca 0 Oft E 8 tie M ON 1/4O En, cr1 M m 0 r‘ r4C42 0 C5 v "es,+.r Cs r 0 0 02 73 0 r 0 di ezi C U z . cal L. CO II o 0 C MI 010 0 0 C 4a) 40 Con 09) 1) 0 Cr al St•• 2 of 0 en en o o 0 Gas Compression 76 0 at Cala 0 Cal cc �•r • y co C : S- 0 i 0 0 06) 0 '04 Can 13.0 I. t W� 19 7 .S 4i31 Nall -0 LI 1 0 C U ' • U U rc C et Ciorn s. a VJ Y~-1 1 C 0 Cj Engine displacement: CD r N gal C,' l k • 0 Ca 2 L Ri 0 C) 2 \0 D DI L'J Ps 1Y tat W C, `Tri.Q U E 0. • Engine function: 0 .D T z Cl :I] .v t. C) Ott 2 ca • i7) ft - Eta come mer r r. %.c e n.J} p: 0 •1 1.� 166664 0 U U P0 — 0 • tam CD as z C) ca C) Combustion: El ett 6.0 co .24 web trtl— $ Cad N 6 0 ti C 5:f ca cu ED E V CA ..•l cbs 4 „In ra is _tea ca Form APCD-201-R_ICEAPEN-'Ver.02.10.2014.docx FORM APCD-201 Internal Combustion r: mine t .= et .,..6 irr Se Fti iet z 44 , ao FI Cr z C co, Eas 1 �I ri Permit Number: 4 ,y TS lEn tima [ Fasting or UTM Northing or Method of Collection for Location )ngitude Latitude Data (e.g. map, OrPS, s or degrees) (meters or degrees) CoogleEarth) Digitize Plot Plan (Preliminary) 4434724 13 521844 E3 5,135 35 1 300 6089.4 129.2 Flow Rate (ACFM) Stack Discharge Height Above Ground Level (feet) Stack Base Elevation (feet) Operator Stack ID No. win C O 'ass C rzi Ii II •mg be O 0 •N U Lr 0 ■ (NJ r Inner Diameter (inches) 0 i • ag tie Ise \gr▪ r rC) C ! cfn CZ cio W Section 06 — Fuel Consumption Information w 0 tn 0,2 Las 4 7 L? C LC) r C V t .rat i z a) w > U a 00-40 O U CZ I f retz cz 71,1 10,070 sefh 2- H 1 C7 L z z • C) Gs-• N r, eT CIA .ON a' 0 C Le) Information & Emission Contro 4.1 Imo ▪ ria LITJ C � en•1 0 C cC�,, V1' N Ct. < O CL < Cpl CL. d NI Ll. C Manufacturer Manufacturer Manufacturer Manufacturer e'J t < . Cw CI_ < C O. Q I Requested Permitted Emissions 0 0 0 0 0 Q 0 O N Co it co N co fit? t`-` c) 0' NO 6 C3 co d Q 6 co 0 0 6 co © 0 6 COT CD 6 N- cad Wit- cc t c,,i co N CO N N en fJ ce} ( p C 1 4 c; Cl 0 irst el 415 cc Actual Calendar Year Emissions` 4.4 la 77 tio• ,w b t . Factor Documentation attached Data year for actual calendar yr, emissions below &. fuel use above (e.g. 2007): F uncontrolled (Tons/Year) Ce 40•0 E Pm ix a 4) Ib/MM Btu lb/MMBtu CO CO 2 g/hp-hr gfhp-hr L. a L a .= Ca I b/M M Btu 03 ctly or missing information and requ11 blank, annual emission fees will be based nission. J U ncontrolled Basis U,) P-- N 7.71 E-5 7.71E-5 0 or C Co LO Ci cc 6 U7 O co r r 6 co O O 6 In O C7 Octt o 0 0 ea t C) clz •r tifil 7 _ J Phi v ,_., U ; k r..•0 { ,._, .5its O O O O Q O N- Co 0 C0 C0 •� L cai = C. At NMI Control Device Description Secondary Primary ica C al C CD C CU Cl3 C Oxid. Cat Oxid. Cat a -I Co C) rci O C a c Pollutant l ormaldehyde Acetaldehyde re o T_ is# Su" 4-0 CL C.) ran 0 •'i-a Pa la .64 � \R n+4)C4-s .2 03 act col C � ...w cE C .a en 0 0 C u ." O somml O ta • a •1 'a Qa 41.) it 64 V J ` 0 tea •l.. is tit esti 124 >1O rip 4.s '- Loa - 1 — a as €? CD 013 Eat 152 p z o 1.4 E 0 a a- 4) ,r 4-4 ect O Of) Ci, Cv O y O I atal fats la O U) r C jr 0 1 O Oa 1 44 Cl)'- CO Can Cise P ism Pal 3••"i C a — id 101cod S iJ• 7 Cul I JINNI lap • iril tai Esti JD C z z C ID r� L ma ri C 1 oat di 'O EC 4 5 040 C iI 14 NW 14.0 147. bles muZ cis �l.y1 a r•! Emission Source AIRS ID: C Ly 0 di n •� tu tES Ce s5 CE3 CCS Mims( ice+ C] fd E ▪ O ten LL, ' ›- Ct 4-21 r • a 7 • L. ity Equipment ID: nested Action (check applicable request boxes) Section 02 — Re •� IIYt yi v z E O alma ci rvo L z 11 Discovery DJ Services LLC Company Name: ran et r r� '•411 L E C f POSE 614 co mic ,1..1 ��yy//� T- 470 T T C" cts C a Q. 1) Source Name: no▪ s .mat -fima las T co cis Ne▪ e tat cid 4101 Cr I El on 11. TIN, R66W Source Location: Change company name El Change fuel or equipment 5 cis iss Change permit limit El El Lo co - Request PORTABLE source permit El Request APEN Update N N O 1�1 N Lane, Suite 335 Blank A PENs will not be accepted. Emissions data must be completed. C X co N - no 1" 7 0 0 CO O) a 4 Ncir Cam! Phone Number: Cory G. Jordan Q .rr ci U Is E M rjrai let C z (214) 414-1980 z Cory@discoverymidstream.com E-mail Address: (71 Is z Section 03 — General Information C V d •Ti rt V /L.��I '1�+1 0 1.1 Lbw FM O DO O ct • • r. U 0 0 1-4 to 'U O Normal hours of source operation: Gas Compression General description of equipment purpose: E A ma ill e a— ,0)- che1- F- wC so 4.E - h cis de Lai Is t4 r 04 CO) i•• is) tap 2 ...,,}} tier GV n Yi•� bot a5 cr; W.' (i) ?i G C tn r. z At �y V �..J um O S.+ et C PrEi Qs) • al es OS O O iLf= 52 o a Is 6 Ow CI -44 Is ett • Ce Va = SW i Is • rr CLD am CIS r..l CI: IS W \Mat pat Ca tai I 5 AI tag I= wig yawy aal Q.O Ata ;F. 0 co) 4in a I .IF 1 hi NI ligS ii O f•�•l 0 0 0 O in CrS fti en C V t- en rn L 1 Cs Cs en en Lies CD Qrn L -a ITS ' C 4 Ct a9 4 ter.., L ://www.colorado. Rat Date engine construction commenced: Csil Date the engine was ordered: Date of any reconstruction/modification: c Date the engine was relocated into Colorado: a r•fl ■ I) n 0 E -,a4) 4 0 0 O b XI C.)) ', "a ;r 11. •.1 pI Csi al Ceti T� UOi mulojui our 0 co a> Engine displacement: Engine date of manufacture: co co co CD • it C) "0 Manufacturer: II II • 0 4 hied+ peC T rao F...Isra C} • Manufacturer's maximum site fl 0 .0 swoN O 0 pa • 1 a 4, Ito O cia 7.0 ct Lin �. f0 U ://www.colorad E ce 5 • ritt - Combustion: 0 • U ata • urn w..1 C con C • ,— . ^� ci 0 • C • o Faff .l rel 4-c Uit O O .I a1 a to a rT IRO wci 4.s talma40 0 C �? 44.0 4 hJ as Cr J 0 e la= To C O tiV d3 a tin • • CD C ...y 71. r•*.1 V er. 02 .10.2014.docx. -RICEAPEN , Q FORM AP I 2 t11 CID ua uopsflquuo3 inuaa;ui Pa Ctt C fV l 1 14 its tint At W;' I1 0 4 4 4 Emus apg 01) 0 cg ta as Pre at • a cat pr � r... r ct'•.!1 fri c •>1 o 0 Om CO) int es am riz ►w• 0 4.1 riC • I 0 .�i tt es tin • • r•n Coe rte., ice i tion Information Section 06 - Fuel Consum C z it .74 1 r -n —S 1 dr) mg 2 CA } •o C C 400 g4 0 gel O o SD. tt 0 0 cgo ca rrV F�+�I Ci N co Ct CD C i i • Ala { ovium O C ftt fa C C c con c z ,a •^ ri 130 ■• 4I C O a O isa 4.0 0 r•r to VI i,i Cr oda- a 0 NNNN CL CL. < < < C co co ct, O �0 O co O O 0 ci ci 0 �L+ 2 cc; Manufacturer Manufacturer N - Manufacturer t LU C•4 (N (N C fin ct < < N co co (NI of (N 0 d O © O Cr) 0 O O /O O O 6 6 CD (N h • N- O V O Ir- l`k1 CC 4.4 r.�.' . a•e too r. 4t _ U fia eel c-0 as ems cot raj C 4- F r 1 0 a zsuoiss m "BOA Jepuogo lwn .pv OM 1 io 0 Emission Factor o3 W O CO fi n iD a a 0) Pa r 03 ncontrolled Basis LJJ X1.1 0 O R o cfa Pct Q d CO CO it) 0 d 6 ci 0 0f O O O O O • C) :td •treM C ro C) • Co C C co C tt co • to 7 7 7 Ct �R3 C (13 C r; L U 0 -a C P� U act O O C r C 6. 4.1 a Ce 411. CIO C ■- Sd C z ci Cii Cie cal C 6 0 Mo ct EID •C . ; O vi C VS iv* mt V5 fit, Cap o it o cri col ►..., Ut 4-, cs7 at 0 0.4 its! Cpb) 3-4 0 sit tj Y Tzi �11 itj tp el) cif4 �1I E 0 t— 4." 0 • Cale I SAO \\ VV et g"s CO at -o eims • mm Ct3 C4. • amsm cl•��F Ct E g I al F— 4) Q ,0 ce 4Tet a cal Q a, C) s N al tsa — • �i4 0 CO, •emi 541 ` _»..4 Ca(41 • St t..1 NC: E., en atsr. Tr, pc 0) F"•� C. Cie CLeal a 78— r w • o .a ;70 al torn C' v C 0 • R I z LU con CLI I) N 3.4 1< cu .adel L t Bally Authorized to Supply Data Eri cc j— CA al 0 0 4) COI 5Ir —C- 0 U • C 00 Ea • — Form APCD-301 Colorado Department of Public Health and Environment Air Pollution Control Division Operating and Maintenance Nan Template for Reciprocating Internal Combustion Engines Ver. September 19, 2013 -4c; -Ants *Lk{ yr rn& V Cobrada Department of Public Heaith and Eiwironmenr The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) template for reciprocating internal combustion engines that are permitted at synthetic minor facilities in the State of Colorado. The O&M Plan shall be submitted with the permit application. A single O&M Plan can be used for all engines at the facility. If the O&M Plan template is completed correctly, the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly, the Division will work with the facility to make corrections. Once a construction permit is issued, the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators are not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval with the permit application. However, the Division encourages the use of this template to expedite the permit application approval process. Submittal Date: June 2016 Section 1 - Source Identification For new permits some of this information (i.e. Facility AIRS ID, Facility Equipment ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill out those fields that are known and leave the others blank. Company Name: Discovery DJ Services LLC Facility Location: Weld County, CO Facility Name: Discovery Fort Lupton Plant Facility AIRS ID (for existing facilities) Units Covered by this O&M form Facility Equipment 1D - El E2 E3 E4 AIRS Point III Permit Number Rich Burn (RB) or Lean Burn (LB) LB LB L LB Air Fuel Ratio Controller (YIN) Catal st T .e $ SCE SCC SCE a Non -selective Catalytic Reduction (NSCR) or Selective Oxidation Catalyst (SCO) Section 2 Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the Division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Page 1 of 4 APCD-301_RICE-O&M Colorado Department of Public Health and Environment Air Pollution Control Division Section 3 - Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. ei The operator will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division, as reflected in the construction permit. Please see the operation and maintenance plan guidance document for further details and examples of emission calculations. Section 4 - General Monitoring Requirements Table 1 below details the schedule by which fuel consumption and hours of operation must be tracked by the source. The hours of operation must be tracked only if emissions, fuel consumption or maintenance activities are based on hours of operation. Table 1 Parameter Monitoring Frequency Fuel Consumption Monthly Hours of Operation Monthly Table 2 outlines fuel use monitoring methods. The source must choose one primary monitoring method and, optionally, may choose up to two backup methods. Check each box that applies. Table 2 Primary Back-up Fuel Consumption Monitoring Method Individual engine fuel meter ❑ ❑ Facility -wide fuel meter attributed to fuel consumption rating and hours of operation in Manufacturer -provided fuel consumption Other (to be approved by the division) - attach explanation and sample calculations ❑ ❑ Table 3 details the portable testing frequency for engines at the facility based on the requested permitted emission totals for the entire facility. Check the appropriate box based on facility -wide NOx and CO permitted emissions. Consecutive portable analyzer tests must be separated by at least a calendar month. AIi portable analyzer tests must be performed per Division protocol, which can be found at http://www.colorado.govlcs/Satellite/CDPHE-AP/CBON/1 51596520270. Table 3 Control Status _ Portable Testing Frequency ❑ Permitted Facility Emissions ❑ Permitted Facility Emissions Permitted Facility Emissions ≥ 100 - t pY NO. or CO < 100 t > 80 t Py — Py NOx or CO < 80 t py NO. or CO SCR or NSCO Quarterly; remain number quarterly the of consecutive frequency regardless tests. shall passing of the Quarterly; consecutive any the then quarterly of the semi-annual source shall tests. semi-annual return passing tests to after tests. fail quarterly then 4 If Semi-annual; consecutive tests. If then the semi-annual any then passing of source the annual shall annual testing. semi-annual return after tests 2 fail to No catalyst Annual Annual Annual Note: The schedule for portable analyzer testing begins upon engine startup, in other words if an engine is to be tested quarterly then the engine should be tested twice within the first 180 days of operation. A reference method test performed on an engine may substitute for a portable analyzer test. Section 5 - Emission Control Equipment Monitoring Requirements sill out applicable sections only Table 4 details control equipment monitoring frequency for rich burn engines. Check the appropriate box based on facility - wide NOx and CO permitted emissions. See the footnotes following Tables 4 and 5 for details on proper control equipment operating parameter monitoring and compliance requirements. Page 2 of 4 APCD-301_RICE-O&M Colorado Department of Public Health and Environment Air Pollution Control Division Table 4 Rich Burn Engine Monitoring Frequency Emissions Control Device Monitoria Re g q uirement Monitorin& Frequencyill _ Permitted Facility ❑ Permitted Facility Emissions ?8otpy NO. orCO c8otpy Emissions NO. or CO Non -selective reduction (NSCR) catalytic Pre -catalyst Temperature b Daily Weekly Catalyst Differential Pressure e Monthly Monthly Air Controller -Fuel Ratio (AFRC) AFRC Dy sensor mV reading C Weekly Weekly b Pre -catalyst temperature shall stay within the range of 750° F to 1250° F. If the temperature is outside of this range then appropriate maintenance activities shall be performed. ° AFRC O2 Sensor Monitoring and Maintenance Requirements • If the engine uses an oxygen sensor then it will be replaced per manufacturer's recommended schedule. If the replacement is determined by hours of operation then the source will track the hours of operation. • In addition to the weekly AFRC 02 Sensor mV reading, this parameter must be recorded during each portable analyzer test. Table 5 details control equipment monitoring frequency for lean burn engines. Check appropriate box based on facility -wide NOx and CO permitted emissions. See the footnotes following Table 5 for details on proper control equipment operating parameter monitoring and compliance requirements. Table 5 Lean Burn Engine Monitoring Frequency Emissions Control Device e__.__..... Monitoring Frequency ❑ Permitted Facility L Permitted Facility Monitoring g Rc q uirement ? 80 tpy Emissions NO. or CO c 80 tpy Emissions NOx or CO Selective Oxidation (SCO) Catalyst Pre -catalyst Temperature a Daily Weekly Catalyst Differential Pressure e Monthly Monthly ci Pre -catalyst temperature shall stay within the range of 450° F to 1350° F. If the temperature is outside of this range then appropriate maintenance activities shall be performed. Catalyst Differential Pressure Baseline Establishment and Monitoring Requirements • The pressure drop shall not exceed 2 inches of water column from the baseline value established by the source when the engine is operating at maximum achievable load. This baseline pressure drop shall be established by the source during each initial compliance and portable analyzer test, and as noted below. • If the pressure is outside this range then the appropriate maintenance shall be performed to bring the pressure back into range. In lieu of maintenance the source may choose to perform a portable analyzer test of the engine to establish a new pressure drop value. If the test demonstrates that the engine is in compliance with its emission limits, the pressure drop value at which the engine is tested shall become the new baseline, • The catalyst will be cleaned, reconditioned and replaced per the manufacturer's recommended schedule and a copy of maintenance reports shall be kept. If the catalyst cleaning, reconditioning and replacement depends on hours of operation then the source shall track the hours of operation for the engine. • For new, cleaned or reconditioned catalyst on an existing engine: the new pressure drop baseline must be established by the operator within the first 7 days of engine/catalyst operation and re-established during the next regularly scheduled emission test. • For new cleaned or reconditioned catalyst on a new engine: the new pressure drop baseline must be established within the first 180 days of engine operation. Page 3 of 4 APCD-301 10E -O&M Colorado Department of Public Health and Environment Air Pollution Control Division Section 6 — Rccordkeeping Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records for the requirements listed in sections 2, 3, 4 and 5 for a period of 5 years. If an applicable Federal NSPS, NESHAP or MALT requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities. When establishing baseline catalyst pressure drops under Section 5 requirements of this plan, Divide Creek will conduct tests and establish a pressure drop for high, low, and normal operating loads, if appropriate for anticipated operating conditions. At least one baseline pressure drop at high load will always be established during performance tests. Pressure drop readings will be compared to the baseline pressure drop established at the conditions nearest those at the time of the recording. Note: These templates are intended to address operation and maintenance requirements of the State of Colorado for equipment operated at synthetic minor facilities. If the facility or equipment is subject to other state or federal regulations with duplicative requirements, the source shall follow the most stringent regulatory requirement Page 4 of 4 APCD-301 _RICE -O&M \tlI U {' F „se, Can Cit I C z uCu 1 C Permit Number: Cr ..r uested Action (check applicable request boxes) Section 02 — Re uollEttuojuI avtils!utitupy C a Y_ r) zit 49) pa . w re tie C< p a is Ca tot ..r Ci freve tir nos. a r T CN ist O �l) M �•L O V Zr Discovery DJ Services LLC Company Name: C- 0 a t O O 2 2 O pmj tri C C Cie U COI CIO ine1 L31 cat 1p o O et co 44 cr C4 . i U Section 11, T 1 N , R66W Source Location: Change company name ■ Change fuel or equipment C LU C C) C Transfer of ownership ■ • U • - ch • cz Ocn o • st 0-4 wIEWO eml L U Y.a rails WI, • Ito E • -11 selog Request APEN Update IDID CO N - Li 0 U n R C co Mailing Address: Blank APENs will not be accepted. Emissions data must be completed. (214) 414-1980 Phone Number: CD O Person To Contact: it "4♦i PPall Q 1Yll zPIZ gin FaxNumber: Cory@discoverymidstream.com E-mail Address: Section 03 — General Information 4.� C.) 0 C C3 sources, operation began on: i . Ls ran l> pot scs N- C N Compressor Blowdown ral C Eim z -a o '6 CDLI ' B 0 O C C 'C1 el 7 C E crai iza .C d�. J 7 6. .- ,Ca .O ta�.� C. 06e in SS L Lk.) Ut oT1 czt 05•- r+ •Ian r 3,' O «I, • .-; talZ Ali 7.1 r> W CS it G A U rd 'r C) C Ce •• F. CP. in 44 rl 69) ••▪ �•iwee Ca Gq 20 C/1 ma .QomCe MI en adiS 044 414 ci co . I cie g ,-+ w CU Cel O It ate � e asV Ifs cs) 44 = C c c 0 Ci J Q�3 7]. ens 0 Ts: 0 -r-b4 e +.+ I) 0 z t e L • 4,O �f en ass en en en 0 0 0 M en en .. ta) 44 > 0 g mtt 705 Cin ass • cd 1) f•. 0 E 11 E.' .r- ♦�iwVy�T.��yi1 reic.t Vet rs C) 0 0 in. 0 sea ECr r. %• Y meat information & Material Use 1Ea /Ma nu factu rin Section 04 — Processin Description of equipment': z C Manufacturer: 7( Design Process Rate Specify Units/Hour) 4.2 Mscffeventlunit Events/yr Actual. Level Annual Requested Permitted Level (For Data Year) (Specify Units) 302.4 Mscfy I Description Natural Gas •L 1� 7 VJ tha Leai •Cry L tat d•1 p. U 4) Lis cpo 'Ps Y) ....� a a •15..1 • 1O 0, R. ifrrmr ' •� 13-1 et V V tau eiha a 0 � ra a Cr cr •W ,S i SIP° it C Upsp s — r ro MN 1 �•I 914 i.r .14 a. CytL a .can reat a :i4 .1114 a lar tea E L tob O C f^ Owl f,l1 Q csi 013 mier S m ,>') 41 41) . • Cfp 0 CA L Lei "CI Cti girt V 4 9 la CI) • CD CJ i ra cn Cr H c▪ l tt tM }1 � .4' A Cla n 0 L.. ,^ en usi o• 'a cr rhal tef GeneralAPEN — Ver.02.1O.20141docx Form C-200 FORM APCD-200 Ct Po laj Emission Source AIRS ID: Permit Number: f1* ..r gra C) C 3.$ a4 c17 Cat _1) 2J C) --4 PE r r —rl CCS ssC +k.f ( cid ct MCI Cg Ci 5 C ►, Digitize Plot Plan (Preliminary) CB 5.135 35 NA NA NA NAD83 13 521844 4434730 Velocity Moisture 1-tonzonta1 Datum urm UTM Easting or sec) (%)(N :I 27, NAD83. Zone Longitude WGS84) (12 or 13) (meters or degrees) Flow Rate (ACFM) lit en• d o H Discharge Height Above Ground Level (Feet) C Col] A4 riaLl I. Operator Stack ID No. r - r 0 II r N on .C 11 ■ Width (inches) = ■ •• O tsi 4 • •N tin cki Ct JD • .;~ • ar• n a..4 U ••ry fir r�c��t;rii.rouY uoit went & Fuel Consum •- Section 06 — Combustion E C) C Manufacturer: C O z detitification No.: Company equipment I I .... :l Q > 7 V r-' 1) �,0 p 2 h. 0 en .rr 0 I ..;.�.u... 1.2 Fuel Heating Value find l3tullb, Btu/gal, Bt 'SC v cp U i V ea C4 irt .2" r g in Co, Orar P4 D e s i gn Input Rate (106 Btu/hr) I 4-.1 I Ty] C E inwr *pi rim rat I tit C E Section 07 — Emissions Invent° a UD g 0 O cis 0 2 a O ..W U] z r�r •-- b" czt Mass Balance 'You will be charged an additional ADEN fee if APEN is filled out incorrectly or information is missing anti requires re -submittal. 'Annual emission fees will be based on actual emissions reported here. Requested Permitted Emissions Uncontrolled Controlled (Tons/Year) (TonslYear rbi en r Dr C ic ts Actual Calendar Year L missions4 Controlled (Tons/Year) Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not lis I Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput above (e.g. 2007): —4 :U t L �.r ,,r. I 0 i i-+ r i t'' a) .O r—�+.� ' i CO CO u w V . . aO in J O 0 Li ontrol [11ciency Eteduct on) i i Lt ;n, V O 1'' rotes r" > — 0 Q .-� (....) Control Device Description ct O . c ,, 2 Pollutant 0 III C.i 0 C..; PCI CC 4' C' �.i •.a E C co o pal . s Coe . — mom • P unt Igo Isr1 a tea rim row t INS VV 0 f • rue▪ d }s) • a a v qJ1 V yr a Qrbau row . p Pam ✓ pm rop 4.1 Pim Ct Form A PCD-200 — GeneratAPEN -- Ver .0 ' .10. '014.docx AIR POLLUTANT EMISSION NOTICE (A.PEN) & Application for Construction Permit — Genera11 Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit # 8 AIRS ID] Permit Number: 0 0 0 6.4 t — E .fit 4} (.60. , teat �Y a) w Action (check applicable request boxes) [Provide Faci O z .a c. co +i co Ce a' L c V 4 el WI Q _ .A .a z Go z = . ELi mtl 4.1 els Cs ....C eik PI to 0. • r- •- tisal iismrim 'Pa 12I il wet CD 76 rams Ca gum 2V) et tit 1.01 "Imil SS 9r} C) Ca N CT= Cr O Ii V p x l ato• l :4 .— { a r C Co r t�! Lai Q) "2 0 Z Discovery DJ Services LLC Company Name: 0 O -J 0 LL 0 O a, a Source Name: Section 11, T1 N, R65W Source Location: Change company name U Change fuel or equipment r i G Q O C a er of ownership H Change permit limit U Co {„Y Ct 0 aC o p tta J H 4 clai Imo Col cis rai INS cet d.F .r. tilt C r Request AFEN Update • O U) 0 U N CO CO Qa J FPS 7859 Walnut H i Mailing Address: Emissions data must be completal Blank AFENs will not be accepted. cu (214) 414-1980 Phone Number: Cory G. Jordan Person To Contact: — C ci Piz O Z (214) 414-1980 Fax Number: Cori@discoverymidstrearn.com E-mail Address: C •Q 4-4 tI� V 44 0 C LO CO a. 0 CO at F- 0) Ct -n � L ro to a, I- a E 0 a iy r'e 0 zaa r 04 •Tti CLs 1 {� ,rte rL,G.? ino , - el e4 ‘Idu ;4:4 a CU r cr F 9 0 co .A •t 0 , liMa sten Ca 1 lie GO Doss 3'1 04) Mr row S. G Cs a Vt glom eti rue E d ,SS 124 a Com = W.. F r V a a t Mg "NO edie Cte Ct Ls c z en 0 oC C C O 44-1 en a' C Li QC en a' wD r.r en en 0 0 kan en I C r a o Ct 8 0.4 ran 44) gra :.//www.colorad r" ..--1 C./ 0 O Pik S own • •-- T- .Owa ,a gas 4-1 r-� d) tut Q ez wc▪ i a a 0 0 ta) tin • 9 V 0 n O I- Q 0 i CO .- .I' olma -c cl Q ct o L 'Z' U • T1 • to t Mill PSI y� i Os CrCaludal . II z d .1)Crt cti C Manufacturer: 50 sof per compressor I I � 1.3 MMscty Total for 3 Compressors I 1 Actu��.l Lc\ ci Annual Requested Permitted i (For Data Year) (Specify Units) _t � C fl CLK ea 0 (J7 V o Natural Gas e i Ct ty., l'•J 2 cid L� 0 0 tit • ..Y. a .Y sol Lit a Ca Ca A V Y 11 Tit cit Cs tic s C? 60 C 'R ^Gil - YYYYY� Fa a 0 di tg ?C' C) C 1� }• V st7 at 0 rce 4"O- 4.4 0 C U C 0 v 0 .0 cri w C rd CCS • C? 0, Cts VCr PC) in avi eg 'd 4-a Form APCD- 00 — GeneralAPEN — Ver.02..10.2014.docx FORM APCD-200 • YI.•Y los Liu Cid imo A • MI amle Won NI C z z Iii 7 Emission Source AIRS ID: Permit Number: T•, a .° I a. 4' r aaall Cd E sty V.*.a -a •aj 0 1) Can CIS H•• N . rl 4-4 r•1 E 4 P', r�l . 0 4-4 C •may ,i..i t est CD Lirj tit • md ima aa�N O YL fI, 'Mr a i a E.i a a Width (inches) = MEI a C a— i..i 2 Section 06 — Combustion E 6 C) O Company equipment Identification No.: I) ras I 0 O 0 al U r 0 E-1 0 O r C) Lb W C) 0) Section 07 — Emissions Inventory Information & Emission Control Information cn C . ,-.tai f ect rip S.r a a rn a 0 ✓ a •..1 r irl a 41 0 Et `W+ nation hod or You will be charged an additional APEN fee if APEN is filled out incorrectly or information is missing and requires re -submittal. 4 Annual emission fees will be based on actual emissions reported here. f'em fitted Emissions Controlled (Ton s/Year) i 13.7 Controlled Uncontrolled (' I `onR/Year) (Fons/Year) el ii (toot aAoga tndgfruo.rtlt stopq suoussitua .nipualu3 iuniau aoi a Emission Factor Actual Cal E nis P i .1 I Uncontrolled Units. Basis i e Control Efficiency 1% Reduction) i lion attached Data yea Overall Collection F Ii i ciency I :e Description Primary Secondary - 1 I E 4 TO . 0 i • C C.� E 0 •MI •OS con Q a • p— siC T' 4' �d g •— et V E La li• !{ • a'� L O al O glo rc..•c s�� % cse yy� E C — awl tug S PSI t 1-4 tat ktAl Authorized to Supply Data Ver.02.10.20 14.docx Form APCD-200 — Generals PEN dration e cio .py trz ILI wbs cwo .44 .=1 CLI 1I akt C z z I.�.I z Ii Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit # & AIRS ID] Permit Number: 4.4 N C S C U3 U Cr 5 cal Y• •+ C "b • ,.., A C E ▪ C - W rr•� t T� LTJ . zit O 42) C" e4 Cis et C!; Section 02 — Re S a Request for NEW permit or newly reported emission source a N • o was � a U Z Discovery DJ Services LLC Company Name: Source Name: Change company name ■ Change process or equipment ■ Section 11, TIN, R66W Source Location: C) Trans fer of ownership ■ Change permit limit • In r Request to limit HMIs with a Federally enforceable limit on PIE a M N If; N . Irer Ct C}J Dom et In t -- Mailing Address: •is S pC S W S V C S .3 Imo+ C/3 Old Fi! ■ 0 t a 0 •- a) C a) C C a 0 a . a • fl} a) ■ (214) 414-1980 a z Person To Contact: O GO 73 0 0% .— C 64 7 Q. •C 11''•Q��II v • - o g s s.J C. L 0 o 41-i b al V.! r t rrry imm isi LE PRI i Q CJ -as -4- Cal 'T Q Q. PI CJ L - (214) 414-1980 Fax Number: E-mail Address: 6 b ZIA cse Section 03 - General Information 0 0 • ceC ig Q Q Q • • 0 0 Q 4 • En 1) a 4 C -d a) 14 • Con FA r_ri 0 U r. i-y Rd ;"--'III Y1k :..) ct) et CZ 11) '1) L r a C 0 gm C) w L Caiso .. CU a C iirj L CCI NI.* ... --,1/4.. NEC 0 i.-4 0 ell 6 ••1 4 U) s el 6 el a AI cic cis +-+ Qa ca IPz ' 0 a N 614 o 1) ik x O 614 El Z tan w 0 C.)1 Q t O orL . 0J C 5.4 r 5., . c con a U c CJ c •—' cdd ran Qen �► essCU • s 4 O c t) tin A • N ://www.colorado. vled IC Will this equipment be operated in any NAAQS nonattainment area? • S U cfr d • T1 Pz s r- H . E t C► S 41) 0 •IH p I~ a Ca • b.0 tie 0 al 0 I) o • E •- bD•bVVV ct Cca) t 101 E t cri tit: it <I) •- tl 'l ...y 0E. ao all O, ficcj Pr X C -•C o 1•••I C�1 L CZ et C 2i as a '6 en it P C °' — a Ter etai i.. C 6 4 ,--� ze tsiQ do eica'rn C 3 'it:* ;14=1 C Ian O CO (NI eN1 _ p rn en I en en rn 1-40111) Q. .51 cot 8 3M I 8 C 4 5 g I C �Q1 act Q53 1 o • ri4 ;=.1 co itg rid en ry 0 co lorado. govicd t z as tEi i ://www.colorado. Application status: htt C`. DP) C •Lei C!] WI • Can 0 a a 0 o 0 E 4 '6Fr U? co 11 — c i r en O CS 4-4 ,,... ro CI im "O Ce S I.11 cat C:3 C En A A iat Serial No.: TIU • 1-1 a era C Manufacturer: a 2 tri C • • a tau eig CO 0 C • C. Lean glycol water content: v a N C/) kroi r- aai 0.4 C . . Cr Design Capacity: Dehy. Gas Throughput: . -. V et .10 Ct Few U CC/] 0 0 1) U yQ Cr' z z O I_ sv 1:14 Cs H H PM Efl 0-1 CD C a) bn • adi `s Cia ca Water Content: • En C. En F+N Cold Separator: ■ z ED • • es En p CJ) •.r 4.4 7.r G U eD En FN EC bO n {CS � 0 '� —t 7 F 4-1 o � a `O O Z ,.Q 03 ..r o YJ 5 • C o CC ■ C) .0 a. 3 .rN •Cit rid 0 Q .I- a S 4 cu 0 0 C.) S C 0 GI 0 in .0 0 ■ MCI rol P S ao s, ar o a.� cu V 1 tan ickat: Q It ri • En "0 9.2 um v -r "fl tit L C Cr tmi APCD-202 Dehy-APDN cis C Ca Ji FORM APCD-202 •1� tow PM Att t /ia-N cit r C z z C I�T}I 14 Emi z Ii H' QgLi Emission Source AIR ID: Permit Number: L C .rte eke a Am if no combustion Qin Section 06 —Stack t - 1.0 ram E C.? ct L✓] u csei U E ..{r CG IFS Ctmi Temp. Flow Rate Velocity Moisture © (ACFM) (f 1d sec) (%) C ri CIC " Y CD ON N al CeN Stack Discharge Height Above Ground Level (feet) en Stack Base Elevation (feet) in en it Other (Describe): S Width (inches) — Il oat O rl •Ty bra) fJ tal O • Irs • c tin ere rf Sibs •+• 1 leZt . tog O T . C z G7 cu Circular: Inner Diameter (inches) a© z r y Y Cre r.. fin 0 V LIS tC Section 07 — Control Device Information i Combustion Device used for control of: Make/Model/Serial #: Enclosed Flare Manufacturer Guaranteed: co 4-u eel - oc Nit Waste gas heat content: 0 O r 0 41P. Is) \.f (4-4 �wC o u ►�� Trani c.) 0 6, C O • ■ Constant pilot li E CD ct tan a Pit a) C Tai U W cc a 0 Qo • pc rr� r r • Condenser used for control of O Q. Temperature (°F): 0 ontrol E. Fri del Requested VOC & Make/Model: •••O 1.0 (44 WILf t1/24 ca . E Requested V O C &. CHAP Contro ti. tit Con CL c YJ Cu C Information & Emission Control Information Section 08 — Emissions Invento 0 In Cyr ct 0 CProMax - 1 0 ProMax 1 0.00 0.00 ProMax steal above. itrolled Is/Year) 0.26 p O C) +ice Ile Gil esir -el � 's" �r c �' I I '.ice T • Emissions )ntrolled ins/Year) Ib/MMscf Gas l ortable Air Pollutant Addendum form to re ort pollutants not li [nation and requires re -submittal. r yr. emissions below & gas throughput above (e.g. 2007 Emission Factor Actual Calend a to r k ) i-. r,... on AAO Hd� ` I V lb/MINIscf Gas IbfMMscf Gas IbIMMscf Gas 1l)fiMscf Gas lblllriMscf Fuel lb/M1Siscf Gas it; -.--� • TP=PI ri a i U 44I I •.,� ' " n T- :o r1/41i d ' 1_' I I co trol It T• L L "G .. L. mg ,- cc Q C. C. 0 ci •— 11PIE1 a) Qto Y..-1 C TO tei CO O O T T a) tD CD a)' C) 0 4) Cat 4U Please use the AP O rn .1y C) cn Cr v Ca ai Cd 2 a.} a C' U, atC Limo eel cis tip i rY C CA cn E �-. C) tu a) CO C ••... Vf JD .-y to a) Cmj CJ Ir Ckee �n��n{�Cmmi .gat CO, P- _f 4.d C�5 4.0 ea CC '.V c,L T li trml Del 4'til Phi Section Cet C MTh Col C • O tua cis a tamit Cr1 L • goo cs �•r 04 Att r1 L C z 0 1r� l z Fl C Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit # & AIRS ID] Permit Number: C ct • 4.4 c >� I C) Ca L V] . 0 tip C) ELJ •G C C.)) p. as I 2 Facility Equipment ID: Section 02 — Re nforu tion 1.8 CD • • fie cso I Cs Cl cr T n C Company Name: a N p Y1 tat II rot Ge k!�.I ■ Source Name: • Change process or equipment ■ Psz 0 Source Location: r C Transfer of ownership ■ Change permit limit ■ 4) isa Request to limit HAPs with a Federally enforceable limit on PTE • Lfl N hei N 7859 Walnut Hill Lane, Suite 335 Mailing Address: . r�A1 V J C ••••4 Li 2 0 04 Ga.) O en cM C 1 ..r •°' _,E .° Q., r..) •— 1 . on C (A 0I• o. .:2 . • - 03 Ch Ts' cd CD E 43 C ca � C 0 O el a) , "- .a) C Ln e a• 0 te c cia 0.2 H r • (214) 414-1980 Phone Number: Person To Contact: ■ (214) 414-1980 C ea ion E te u C E-mail Address: T. cd • Esoz ad Cctl 4 74) Addl. Info. Cd 03 — General Information • a Cal In a EN- -Le 1-4 t ger CNA eha rr � 00 C 0 0 4/1 1•� z ins C golml 6 et C E Ca -a1 C �; U 4 Z Z ■ G tin rF o I:4 al 0 Al 0 RS 4_7 U ii O w Z •: cc C e of c as 0 0 -O,n1 • #E • •i c }F •rn U Cr ra C ://www.colorado. C CY z C SO L 0 •l,.F •rte A A C CO cts ,a g a tin z 2 PC c • r' • Cd E C i -- C= N C4 Vx e •to) Itimr awl C' ._ C9 L e, a g 01art e imeTtL t1 CSeSe cal tar 1.4 cc too gat et °at cog) la y C{ U 4"e itt a oo en 6. Lao CD Cs 0 a In Ctn a Ll.; v 0 a -0 0 z) A.PEN forms: httn:1/ C ▪ dry • (a C) ,+, 0 I z 0 O o 4.4 itg cE r ' A. O • R^ 9 r 4-1 O C' C fn 0 cV •p. C VJ ea 0 ea T1 •• ,- t u A cin cd H C H Manufacturer: I) C Li I GC • • Q C `^ ■ Nrs ÷i ch r E yJ 0 EA E 4 Pump Make & Model:. tan ri U U IV) Cent 1.74 eD © a - n. U N Design Capacity: Dehy. Gas Throughput: Ct a Ct 0 C ll�'J Q U) C Er: O 0 --� C v M�1 —a a ^f Water Content: U'] os cat f15 CLI Cold Separator: z tic L'J.1 tal In U, Ctt i C On 00 Os .C1 rin 8 0 ,Oa" V] E fu 0 a) C 'ens SU tl�f C i•�1 ri II no• to -- co cis JD .." {.3 O.1 0 cu 0 .�J g i •2 • ' �. 0.i 0 6 Sy 0.4 sue, a 0 G cr o 0 4 .L ..O v C) U 0 • Ea erns 7) tJ] 2 •E de C/1 L ea et Cr Q IC � w te bo Cd c a 6 ac c CCC 0 ctl o C e Ue.f Ts a C rs tsd att Attach the extended • . V • 0 rJl • O 51.1 Ct FORM APCD-202 Emission Source AIRS ID: Permit Number: Location (Datum & either Lot/Long or UTM) if no combustion 5 Section 06 —Stack Section 05 — Stack information (Combustion stacks must be listed here) - Velocity Moisture , (ftlsec) (17,i)) O G Ira 39. en Temp. Flow Rate (°F) (ACFM) C INII Stack Discharge Height Above Ground Level (Feel) txPd Slack Base Elevation. (feet) 1 in la kj Operator Stack ID No, U 0 estol rn II O ■ Ct 6 • • t v i • • Co Ca 4 ti rhn 4-i �F 2 N n Q C See C) T I col V1J t -d >ri .2 fad L L CAI b L L L C et dpi tin Ct (1.) rn iat r✓ C /) 0 G 0 O U .ti, Cy 4 0 N *0 414 Regenerator Vent + Flash Gas (secondary Combustion Device used for control of: E Make/Model/Serial #: Enclosed Flare Manufacturer Guaranteed: CCI cc Waste gas heat cow NO NO Lt. o' o 0C \ a 0 O U 0 1.1 • a n S Make/Model: rlE • 13/43 Temperature (°F): O \Tt4LJ used for control ■ Make/Model: Requested VOC & I IAP Control Efficiency: C C) I' Information & Emission Control Information r C a I f relgoisd -- c-4ill- .0 , 41) rn a> 5 0 4A 0- I en f-1 Per. V C.) b u t lc Z C-i e v a W Phi 71 sa lea MI Cil Cid CD le Cd M C) on . - . C C ' stirnation l or Emission 1 o1ci I .I O it a 1-4 A4 r•-• 'PM ,1 A- Actual Calendar Year Emissions Requested !emuitthd Emissions Control (Tons/V 14O 4 7 i a of COO= )ntrolled is/Year) 461 as 'io a GC Cflo Cal CM . ri Controlled ( Tons/Year) Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not lis I Emission Factor Documentation attached Data year for actual calendar yr. emissions below & gas throughput above (e.g. 2007): I Uncontrolled (Tons/Year) Ib/MMscf Gas lblMlsitsc_f. Fuel IbflVMMscf Gas 113/1VIJNilsef Gas IbAIMscf Gas Ib1MMscf Gas IbfNI scf Gas Emission Factor v3 .,--, - r Ib/MMscf ^ re; ziloC /-- '. ' ! IIN1 O Uncontrolled Control Efficiency (% Reduction) Identify in Section 07 Control Device Description Secondary LaiPrimary. r a -4.s J -4 1 ID YJ .r�w I Cd F C ar co . t Qq O C o Prz cts 4C] _si ta} T O 6.4 61 ter aeZ• a S C G/} 'a a /MI LI a et r Co I a f f us a Cia NMI V1 f 2 L ts> tie lot C Ca 4 Ct Ct COMO cc cc 4• sic ICI A ciii cc C ,C c fi a C i C,) ACG+I tam 1a t l ink 490 'y T P} C E 7 egally Authorized to Supply Data twat ran .631 Form APCD-302 Colorado Department of Public Health and Environment Air Pollution Control Division Operating and Maintenance Plan Template for Glycol Dehydration Systems Ver. September 19, 2013 Colorado Department of Public Heath and Environment The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) for glycol dehydration systems that are permitted at synthetic minor facilities in the State of Colorado. An O&M Plan for each type of glycol dehydration system configuration, as described in Section 1, shall be submitted with the permit application. One O&M Plan may be used for multiple glycol dehydration systems at one facility if each are controlled and monitored in the same manner. If the O&M Plan template is completed correctly, the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly, the Division will work with the facility to make corrections. Once aconstruction permit is issued, the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators are not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval with the permit application. However, the Division encourages the use of this template to expedite the permit application approval process. Submittal Date: June 2016 Section 1 - Source Identification For new permits some of this information (i.e. Facility AIRS ID, Facility Equipment ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill out those fields that are known and leave the others blank. Company Name: Discovery DJ Services LLC Facility Location: Weld County, CO Facility Name: Discovery Fort Lupton Plant Facility AIRS ID (for existing facilities) Units Covered by this O&M form Facility Equipment ID DI. D Permit Number tbd . tbd AIRS Point ID Glycol Type Used a EG EC a Glycol types include Ethylene Glycol (EC), Di -Ethylene Glycol (DEG), and Tri-Ethylene Glycol (TEG) Emission Points and Control Status: Check the appropriate boxes indicating whether the dehydration system(s) are equipped with a,fash tank and whether or not the flash tankpr..esent and still vent emissions are controlled or recycled or vented to atmosphere. Flash Tank Controlled/Recycled Vented to atmosphere Section 2 - Maintenance Schedules Check one of the following: Still Vent El Controlled/Recycled Vented to atmosphere Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the Division upon request. Page 1 of 4 APCD-302_Dehy-O&M Colorado Department of Public Health and Environment Air Pollution Control Division u Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Section 3 - Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. The source will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division, as reflected in the construction permit. Please see the operation and maintenance plan guidance document for further details and examples of emission calculations. Section 4 — General Monitoring Requirements Table I below details the schedule on which the source must monitor each of the listed operating parameters depending on the requested permitted emissions at the facility. Check the appropriate box based on facility wide permitted VOC emissions. Table 1 Parameter Monitoring Frequency - -- . Permitted Facility Z Permitted Facility Emissions ≥ 80 tpy VOC Emissions < 80 tpy VOC Lean Glycol Circulation Rate Daily Weekly Wet Gas Inlet Temperature Weekly Monthly Wet Gas Inlet Pressure Weekly Monthly Volume of Gas Processed Monthly Monthly Chiller (Cold Separator) Pressure (EG units only) Weekly Monthly Chiller (Cold Separator) Temperature (EG units only) Weekly Monthly Tables 2 and 3 outline the methods by which the source may monitor the lean glycol recirculation rate and the volume of gas processed, respectively. In Tables 2 and 3 the source must chose one primary monitoring method and, optionally, up to two backup monitoring methods. Check each box that applies. Table 2 Primary Back-up Lean Glycol Recirculation Rate Monitoring Method + l col flow meter s) — includin flow from all injection oints or um s Record strokes minute and convert to circulation rate — make/model and stokes a ❑ minute/ circulation per rate relationship must be made available to the pump division upon request per Assume must maximum be made available design to the pump division rate b u — )on pump rec make/model uest and circulation rate specifications ❑ �� b Note: if you are requesting to permit at a rate lower than the maximum design pump rate then this option should not be used as it will create de facto non-compliance. Table 3 Primary Back-up Volume of Gas Processed Monitoring Method a Metered ❑ Inlet s Outlet D Fuel Gas ❑ Compressor Discharge Ill Other: • • Metered ❑ Inlet Outlet Fuel Gas Compressor Discharge ❑ ❑ ❑ ❑ether. ❑ Assume maximum design rate' specifications shall be made available to the division upon request ❑ Other (to be approved by the division): attach method explanation and sample calculations ❑ C Note: if you are requesting to permit at a rate lower than the maximum contactor design rate then this option should not be used as it will create de facto non-compliance. Page 2 of 4 APCD-30 _Deny -0&M E Colorado Department of Public Health and Environment Air Pollution Control Division Section 5 - Emission Control or Recycling Equipment Monitoring Requirements Table 4 below details the monitoring frequency for control equipment depending on the type of control equipment used and the requested permitted emissions at the facility. Check the appropriate box for "Monitoring Frequency" based on the facility - wide permitted VOC emissions. In addition, indicate still vent and flash tank emissions controls by checking the appropriate boxes. Table 4 Emissions Recycling Control Method or Still Vent Flash Tank Parameter Monitoring Frequency ❑ Permitted Facility Permitted Facility Emissions ?80tpyVOC <80tpyVOC Emissions Condenser Temperature Outlet Weekly Monthly LCondenser Thermal Oxidizer Combustion Chamber Daily Weekly ❑ ❑ Temperature Combustor or Flare Pilot Light Monitoring r Daily Weekly ♦� ►�I Method 22 Readings Daily Weekly Recycled System Vapor (Including Recovery or Closed Units) Loop To be determined by the source and approved by the division g ❑ ❑ Re-routed Reboiler to Burner To be determined by the source and approved pp by the division h ❑ d Maximum Condenser Outlet Temperature If the equipment is controlled with a secondary control device and no control efficiency is being claimed for the condenser then the condenser outlet temperature does not need to be monitored and there will be no maximum condenser outlet temperature. For all other equipment the maximum condenser outlet temperature shall be: Select one of the following options from Table 5: Table 5 16o°F a F (Upon limit approval is requested from the division) — attach supporting documentation if a higher e Minimum Thermal Oxidizer Combustion Chamber Temperature If the facility uses a thermal oxidizer to control emissions then the minimum combustion chamber temperature shall be: Select one of the following options from Table 6: Table 6 1400 ° F ' F the Based permit on manufacturer application specifications. and made available Specifications to the must Division upon be submitted request with W I Based on testing performed. The test data shall be submitted and attached to the O&M Plan I Page 3 of 4 APCD-302_Dehy-O&M Colorado Department of Public Health and Environment Air Pollution Control Division Pilot Light Monitoring Options If the facility uses a Combustor or Flare then the source must indicate the method by which the presence of a pilot light will be monitored in Table 7. One primary method for Pilot Light Monitoring must be checked and, optionally, up to two backup methods can be checked. Table 7 Primary Back-up Monitoring Method Visual Inspection ❑ Optical Sensor ❑ ❑ Signal _-_ ElAuto-�Igniter ❑ Thermocouple ❑ g Recycled or Closed Loop System Monitoring Plan In the space provided below please provide a brief description of the emission control or recycling system, including an explanation of how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Direction of waste gas to the enclosed flare will be inherent to the process design h Reboiler Burner Control Monitoring Plan In the space provided below please provide a brief description of the emission control system, including an explanation of how the system design ensures that emissions are being held or rerouted when the reboiler is not firing. Direction of waste gas to the enclosed flare during times not required by the burner will be inherent to the process logic Section 6 -- Recordkeeping Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records for the requirements listed in sections 2, 3, 4 and 5 for a period of 5 years. If an applicable Federal NSPS, NESHAP or MACT requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities. Note: These templates are intended to address operation and maintenance requirements of the State of Colorado for equipment operated at synthetic minor facilities. If the facility or equipment is subject to other state or federal regulations with duplicative requirements, the source shall follow the most stringent regulatory requirement. Page 4 of 4 APCD-302_Dehy-O&M U 114 •• a AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Fu Emission Source AIRS ID: em unless APCD has already assigned a permit # & A Q Permit Number: C 1i 0 Q 2 5 C • CA 4 ti a J LL Facility Equipment ID: uestcd Action (Check applicable request boxes) 4.4 C 1 0; aI Li G a -Tripi 110 a . MU Wag 4.Y C l a rid CPI N Pen I■d Cie a 4tr wzg co sit 6E rs' Z a p sti N f CN L U CA 9 O Le Discovery DJ Services LLC Company Name: Source Name: Change company name Change process or equipment 71.3 C Section 11, T1 Ni R66VV Source Location: ism C Change permit limit r 0 1-0 Co r L LL Request to limit HAPs with a Federally enforceable limit on PTE APEN Submittal for update only (Please note blank APENs will not be accepted) CID 0 Y 0 N Lane, Suite 335 due 5 Ual OD Mailing Address: (214) 414-1980 U z e1 C Person To Contact: Cory G. Jordan (214) 414-1980 U Address: Cory@discoverymidstrearn.com LIJ y...i tat Pio CLI to) Lac :.r sources, operation began on: ci) N Other (Describe): Natural Gas Processing Plant 0 .- co 4-5 C- 2 o U O t icr 2 r I^1 J cd 0cis y Q C 0 Es i-4-5 f '0 .r. o co asi 0. F3 . .IA itt r`\ I els 1 1� ./R ICP' Rs —i aJ 1j o 0 • P o Eat too F TH ss Q iha tie :4 i 14Cio cs La c • c E Ui � Q esi O v r l.W U 4 N ♦ A o s•.Li" its Li•t • Cil coo to C) a, a U re is il, ?, a • o Y 0 O CA .C1) C) ., 'st L el 04 !Mrze L E Is li 4o ,tia tit Ca 0 - t� � a. 1 Cit rdo Clt ash IMO 4C C can tup rit �rimi co tie %sr .= o = "in sicia en elan% r1/4E. ICe i.•, .4 .> cz o cr o .= 75 rz mze •� a Don't know n tt thiAl r 0 ■ Don't know ■ Cans 0 ID 7 i) O +i! t) • 1c L J CC C4 wit Ch O V tD CIA E ... A� Y • .mil rJ TI Ili9Y Is this equipment subject to LISPS 40 CFR Part. 60, subpart 0000? Section 05 — Stream Constituents y,J C) 0 1) •1•J U ". Cw 5.2 sirs S C .J� l �8.y cc 0 a . ? C an 1- .0 Pm cat U c o s t� d o d o aa tido Ds Pr V r r r Ge _a C. = ? :$ is �I.l C —F a ci a in ri O c5 Submit a representative gas and liquid extended analysis (including] Toll (wi Benzene (-wt. %) co t id a Ni a 1 0 CD iN r r rem Stream Light Oil (or Light Liquid) rt _. '4 rate•/Oil El Forme PC D-203-.PugitiveComponentLeaksAPE N-Ver.11-13-2014 C i FORM APCD-203 )orient Leak E+ tnissionsi Coi Ni sso rim emit 1.4 cut Diwo Ems z z �V 11 V 1 4 H n Cis tov ).• Emission Source AIRS ID: Permit Number: 1109B11 1.10.1111 [04tuoD x S Section 07 —Leak Detection & Re Section 0 . Location Information (Provide Datum and either Lat/Lon or UTM) C) U9 115 U es �T+fi co p eCt WAR Per Reg. 7, Section X'r11.17 C LDAR per NSPS O E Ci. _Q~ i.J r4� � t 'C S n c tvi o }'a..``o o `_ Y • [h' 2 Y 1— o I •� b o 0 c . 6 41n"r.10. — a..1 _ all, Lung or Method ofCollection for de . Location Data (e.g. map, GPS, legrees) Goo eEarth) 520961 4432473 Digitized Plot Plan UTM Easting or. Longitude (meters or degrees') UTM Zone (12 or 1 ) E6F E84b'N Horizontal Datum (NAD27, NAD83. WGSS4) Cif •0 et 5 mum rum et gas C p.q salt rift I: 0 cis sts ttz E C coo C r • En I ici % eu 1.0 .y 44 mil kin cgs es tit c-44. ■s tes L oe itz cc 4t • rFd C) 173 03 a) C 1) a E 0 0 c .}r 03 U Co O cooln co uJ a) C) H a) 7^� rt• faol Ommi t F! .tosi a.e b r4 - al) r r U Q 0 rat • w U -0 V 0 O U d W (11 '.0a izt cow m. Ct 0 a � E 42 Q it C] E oi tpr Fiji ra f..l samr et, ow cao O Coin tic Ewald in CCS tom. a � O K 4 0 CC4 • Gin a1 .may, Q_S 5 ..et 46- ft V Fab 1Ler .rte P 8 0 1Y S .666 V Cl L el fs cc II �•4 a _Y oak L a .WF Lei • ry w 1) C) CY.) a I 4 C U • 0 • ••••• U a • r. ti ttg 0" . 0 4-1 •-s C) 0 r0 h Ira 00 Y H co co co ori N W' CO H co 0 C 6 '? CL) W C H 0 ci C d 0) CD 6 tants not ii 00 rat r•� Car • -. 4• r • : amot f•• *ma utaut =" side C, C IF Please use the C N C) 0 a r �. Sol V emAtA a •� C . mei a •Ca S 6=I • — T• S PIC leme 6i.., • P,tat CI▪ MO E c i~ Q 91 tin a till! fl) ra Ca to 71 Q CI•i-5 T�� 4'y = r-, La '&1 r- ct a - t - .p.• , L rat C4 eu - VI 0 •— tui L welEi W• t 0 w rei Ct — 0 .I is En In • -...! . ,— ..- i 'r CCf Ca GEE•' 0) ,Co 0• . 0.0 Li ri -al ccS ass LA .Sr .0 4) 0 C11 Z I O 2 O ”i• C *al ow Cal Coe ;is siE U 4.0 CI CI CU 12 0 C9 0 O t'4 0 0 CIPt U a V ct Ct C Yfil n •r•r 75. 7131 tgl C,} 0.0 Cf.) Form A PCD-2O3-Fugitiv'eCotnponentLeaksAPEN-'der,11-13.2014 FORM APCD-203 Form APCD-303 Colorado Department of Public Health and Environment Air Pollution Control Division Operating and Maintenance Plan Template for Fugitive Component Leak Emission Sources Ver. September 19, 2013 Cobra& Deparunent of Public Health and Eiwironrnent The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) for fugitive component leak emission sources that are permitted at synthetic minor facilities in the State of Colorado and do not have any applicable NSPS or MACT requirements. If the facility has NSPS or MACT requirements, e.g. NSPS KKK, then the source shall follow the federal requirements and a separate O&M Plan need not be submitted. If required, the O&M Plan shall be submitted with the permit application. If the O&M Plan template is completed correctly, the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly, the Division will work with the facility to make corrections. Once a construction permit is issued, the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators are not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval with the permit application. However, the Division encourages the use of this template to expedite the permit application approval process. Submittal Date: June 2016 Section 1 - Source Identification For new permits some of this information (i.e. Facility AIRS ID, Facility Equipment ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only. fill out those fields that are known and leave the others blank. Company Name: Discovery DJ Services LLC Facility Location: Weld County, CO Facility Name: Discovery Fort Lupton Plant Facility AIRS ID (for existing facilities) Units Covered by this O&M form Facile E ui ment ID FUG1 Permit Number AIRS Point ID Section 2 - Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the Division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Page 1 of 2 APCD-303_FUG-O&M Colorado Department of Public Health and Environment Air Pollution Control Division Section 3 - Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. The source will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division, as reflected in the construction permit. Please see the operation and maintenance plan guidance document for further details and examples of emission calculations. Section 4 — General Monitoring Requirements General Leak Detection Program - all sources must conduct a recorded walk-through by plant or company personnel with visual, auditory and olfactory leak detection according to the schedule in Table 1. The operator must make a reasonable attempt to fix any leaks found during these inspections. Check which box applies based on facility -wide permitted VOC emissions. Table 1 Permitted Facility VOC Emissions Inspection Frequency ❑ a 80 tpy Monthly < 80 tpy Quarterly Section 5 - Emission Control Monitoring Requirements Non -KKK LDAR Program Using Method 21 — (If federally enforceable emission reductions are being requested) • Attach an explanation of the monitoring program and recordkeeping format • The master component list and monitoring records shall be made available to the division upon request • Maintain a log of equipment and component additions and deletions Section 6 - Recnrdkeeping Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records for the requirements listed in sections 2, 3, 4 and 5 for a period of 5 years. If an applicable Federal NSPS, NESHAP or MALT requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities. This facility will be subject to the monitoring requirements set forth by 40 CFR 60, Subpart OOOO Page 2 of 2 APCD-303_FUG-O&M Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit # & AIRS ID] Permit Number: a I4-6 • 0 :r T . N '0 (1.) L • 1�1 ▪ T. cr • JJ CD eel 0 r• � a, co ric iw PC MOM INNS Pc— .E.,i cid mil+ Section 02 — Re Section 01 -- Administrative Information ion 64 cat tort Ct �I tie O Discovery DJ Services LLC rzi 4'V a} r a 0 oo O D 0 0 0 LL C CO Source Name: C IC Pet ate tae wor Ope Cr tit 115 0 Section 11, T1 N, R66W Source Location: Change company name Change process or equipment ■ tin r C Transfer of ownership • CID N- Lane, Suite 335 i S co %PEN Submittal for Permit Excrnpt/Grranditthered source F— a (93 Cte G a C imt "ribs' tow 5 PO Cat z ■ (214) 414-1980 Phone Number: Cow G. Jordan Person To Contact: V . CZ 2.0 Fax Number: scoverymidstrear.com E-mail Address: C E 0 13 0 CU "O Co o i-1 6.0 �- 0 ny C) W to a. rr."LLLL c `• I a 11 sof .- E • tar Section 03 - Genera .0 .tits 0 .(if' co) tal et.,7; ..4 . Ct (i) U Las E-1 1.0 el* Pi a C usC 'Q N Normal Hours of Source Operation: • z 1. C) C) s T O as col v rig st ;del w I .eaLw rT � atip ci; if: r ELI' kin a ;;56 c --a tan Ca a 0 rel . . IL VI VI 44) . Ad ``+n . ee+s G C� *Vs 0 ca C14 tit .O "t C; IAm l 'd a calai I) sC �f n ct ct Q co "a es 0 co it ers '••i • c) cos V) • te AA co Lel Lop i..i V C) Q N a a Ct DE C Al to .cr •i.J gas separation [NOT liquids extractio cu CU V C 2 tid^ a a C 92 cis 1-6 U •,ice Ci , I.q GS ca Pit LA ligml ear O CZ -- • S es Pop — it o ICI 1 C is C E 40 L C Cam. C Imo Tur i.e 0 LTJ•encC9 it LC 94 in CIO r::• fie Ce Ca\ • d in Cie rs 603 I' el La e ct 4tan Li �r r a Ci kt Ci wig r°4 Cr e' II C 11). L a Cal E tin Irse Li r Ca Ala a C = t ;r in,' co) td ° c i.+ F 1°F L r=1 cif 4 V en EX I ea no y a '1 ..... S ten tn I N I st1/40 a en N Et 't W enrnrn<0 0C: 0 rn tin en en t3 ••.-e•� coo u 5 414 Can t• ti C ��ro• lyy E e.a C tt 0 as ror tat aim ;.0-1 F�••1 a :1h nvw.coloracko U 0 C) Os Information Ct co 0 0 tb Os RVP of Sales Oil co) an .• fau I a CC3 5 External Floating Ro Internal Floating Roof: • a u Tank Design: s Date Of First Production (Month/Year) L Installation Date of most recent storage vessel in storage tank (Month/Year) 2 i I '1 al Volume of Storage Tank (IMO o o act # of Liquid Manifold Storage Vessels in Storage Tank r Storage Tank 11) Wells Sergi iced by this Storage Tank or Tank Battery (E&P Sites Onl) ) a Newly Reported Well 1 EDON. Name of Well t. go eo E Pa A 1 1 I E a I 1 1 1 1 0 FORM APCD-205 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit Emission. Source AIRS ID: Permit Number: I` t rW sting or tude degrees ) Midstream sites only) VelocityN1oI stare I (.ft/Sec) (2/10) _„I Flow Rate (ACFM) 3 rP it o ' L/ i Stacy Discharge Height Above Ground Level (feet) • Stack Base Elevation (feet) • C Z Operator Stack. ID No. H O O • L C a .I ■ a Ca V C ,J flo ect cin O O • II 4-4 .2 41 C El II a .`� .. V tan C taE C radipoo .C • wr yr J T▪ � - Cr, OD le‘) 0-4 .C I C r I Manufactu Waste gas hea Pilot burne I I 7 n HAP Control E urn temp. to achib rrt pilot light? Describe Any Other: ll 10 d for control of the Make/Model: fi iciercy: l (emissions vented C Cli 4.- Carp CL•I Information aration Technolo i CoD eve V J ..� b q 48J rem sel 71. O 0 Pte TaS ▪ 0,1 04 n3 0 CL to O 4.1 o I {rr O 1-4 d r r1 on .}' 1"1 O UOl UWJOJul 10.131103 110910 u IOJUI E CO CO co co as 2 2, 2 2 2 D_ a CL 0_ 0_ I 0: incs 2 0r itu 2 CL, co 2 [L Actual Calendar Year Emission2 Requested Permitted Emissions Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) I h r r---� t Y ` r 6 o O O o 6 o o C C0 'cam ' c o 135.72 0.58 0.24 '-; �O V co O . - - eco O c .... 0.47 I 7 in 1 ION •fir Ltd t incontrol.led Basis I CN N.-- " , tI Ili © F en Q UJ N Z0 -3L-8 €0-35 ,T E Pollutant oc Ethylbenzene LI ri al Z--frii. 174 N is • 4. itha C .C2 rat . - E Gs r.� ▪ cis; taw ce eq N cep C C WI a • ft #r� MV r DPMII SO PW a.� rr� rxisal .m AS rrAs foa C . et ra CS C C son 4s E C E C . • Ir•1 ete lme MW �C t C E CD Ctai D a wele 'S 4.1 • a 9 Q P 011 0 LIE SSD rrww erg I C us . ♦Ar1 1 f i ina 4 T^ ici Q die pew CC ai r: Ps U iW cat L ei • V am cu S O 4 eu 0.0 sic a) . PENNI 1;1 0 o v tin tan , }^1 .) - 4- U O — /M erg W 0 cu evarj Att la I 14 COD CAt ti? • ..C � < size i' _ 0 z O rri Ct I- ran VJ • 0 0 CO .O ....1 a. o O r tt C O CM a O O C} 0 1.0 k C U O O arc ;r4 irth Ca c# O LS a V N a ro ccs S 0J ; O ' cri Q �y .'�.y. ♦V YJ }_ . y U Cri 0.4 piJ cn not contain work C4 Cri ir+ r Art -40 CZ Form A.PC[)-20 -CondensateTank APEN-Ver.l.2-22-2014,doe Page 2 of 2 C Ni Form APCD-304 Colorado Department of Public Health and Environment Air Pollution Control Division Operating and Maintenance Plan Template for Condensate and Mixed Liquid Storage Tanks Ver. September 19, 2013 Colorado Department of Public Health and D {ironnaent The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) for condensate and mixed liquid storage tanks permitted at synthetic minor facilities in the State of Colorado. An O&M Plan shall be submitted with the permit application. One O&M Plan may be used for multiple tanks at one facility if each are controlled and monitored in the same manner. If the O&M Plan template is completed correctly, the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly, the Division will work with the facility to make corrections. Once a construction permit is issued, the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators are not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval with the permit application. However, the Division encourages the use of this template to expedite the permit application approval process. Submittal Date: June 2016 Section 1 Source Identification For new permits some of this information (i.e. Facility AIRS ID, Facility Equipment ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill out those fields that are known and leave the others blank. Company Name: Discovery Di Services LLC Facility Name: Facility Location: Weld County, CO Discovery Fort Lupton Plant Facility AIRS ID (for existing facilities) Units Covered by this O&M form Facility Equipment ID CT Permit Number tbd .AIRS Point ID mm tbd Tank Type a C Controlled (Y/N) Yes Tank types include condensate (C) and mixed liquid (ML) Section 2 - Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the Division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Page 1 of L- APCD-304_CondTank-O&M Colorado Department of Public Health and Environment Air Pollution Control Division Section 3 - Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. The source will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division, as reflected in the construction permit. Please see the operation and maintenance plan guidance document for fierther details and examples of emission calculations_ Section 4 — General Monitoring Requirements All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. Table 1 below details the schedule on which the source must monitor each of the listed operating parameters depending on the requested permitted emissions at the facility. Check the appropriate box based on the facility wide permitted VOC emissions. Table 1 Parameter Monitoring Frequency E Permitted Facility Fl Permitted Facility Emissions ≥ 80 tpy VOC Emissions < 80 tpy VOC Condensate Throughput Monthly Month] Separator Temeerature (if present) Weekly --.---_-_-- Monthly Separator Pressure (if present) Weekly Monthly Table 2 outlines condensate and mixed liquid throughput monitoring methods. The source must chose one primary monitoring method and, optionally, may chose up to two backup methods. Check each box that applies. Table 2 Primary Back-up Condensate or Mixed Liquid Throughput Monitoring Method Inlet meter(s) ❑ Tank level measurements which take into account all additions and loadout activity ❑ III Sales or haul tickets uOther (to be approved by the division): attach method explanation and sample calculations Section 5 - Emission Control or Recycling Equipment Monitoring Requirements If a control device is used then leakage of VOCs to the atmosphere must be minimized as follows: • Thief hatch seals shall be inspected for integrity annually and replaced as necessary; • Thief hatch covers shall be weighted and properly seated; • Pressure relief valves (PRV) shall be inspected annually for proper operation and replaced as necessary; • PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses (as applicable) are routed to the control device under normal operating conditions; • Annual inspections shall be documented with an indication of status, a description of any problems found, and their resolution. Page 2 of 4 APCa-304_Condlank-O&M Colorado Department of Public Health and Environment Air Pollution Control Division Table 3 below details the monitoring frequency for control equipment depending on the type of control equipment used and the requested permitted emissions at the facility. Check the appropriate box for "Monitoring Frequency" based on the facility -wide permitted VOC emissions. In addition, indicate storage tank emissions controls by checking the appropriate boxes. Table 3 Emissions Recycling Control or Method Parameter - .... Monitoring Frequency ❑ Permitted Facility Permitted Facility > Emissions 80 tpy VOC Emissions < 80 tpy VOC___ _ .. Thermal Oxidizer Combustion Tem erature Chamber Daily ' ► eekly ❑ Combustor or Flare Pilot Light Monitoring C Daily Weekly �,. Method 22 Readings Daily Weekly Recycled System Vapor (Including Recovery or Closed Units) Loop To be determined by the source and approved by the division d } Re-routed to Reboiler Burner To be determined by the source and approved by the division C ❑ b Minimum Thermal Oxidizer Combustion Chamber Temperature If the facility uses a thermal oxidizer to control emissions then the minimum combustion chamber temperature shall be: Select one of t e. following options from Table 4: Table 4 1400 ° F s 0F the Based permit on manufacturer application specifications. and made available Specifications to the must Division upon be submitted request with 0 Based on testing performed. The test data shall be submitted and attached to the O&M Plan ❑ C Pilot Light Monitoring Options If the facility uses a Combustor or Flare then the source must indicate the method by which the presence of a pilot light will be monitored in Table 5. One primary method for Pilot Light Monitoring must be checked and, optionally, up to two backup methods may be checked. Table 5 Primary Back-up Monitoring Method ❑ -'� Visual Inspection I. ❑ -- Optical Sensor __ ❑ Auto -Igniter Signal Thermocouple ❑ ❑ d Recycled or Closed Loop System Monitoring Plan In the space provided below please provide a brief description of the emission control or recycling system, including an explanation of how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. A flow control valve automated by monitoring VRTJ operation will automatically redirect flow to the combustor in the event the VRU goes down. Page 3 of 4 APCD-304_CondTank-O&.M Colorado Department of Public Health and Environment Air Pollution Control Division e Reboiler Burner Control Monitoring Plan In the space provided below please provide a brief description of the emission control system, including an explanation of how the system design ensures that emissions are being held or rerouted when the reboiler is not firing. Section 6 — Recordkeeping Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records for the requirements listed in sections 2, 3, 4 and 5 for a period of 5 years. If an applicable Federal NSPS, NESHAP or MACI requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities. Note: These templates are intended to address operation and maintenance requirements of the State of Colorado for equipment operated at synthetic minor facilities. If the facility or equipment is subject to other state or federal regulations with duplicative requirements, the source shall follow the most stringent regulatory requirement. Page 4 of 4 APCD-304 CondTank-O&M Attachment C Emission Estimates Emission Estimates Reciprocating Engines Four, Caterpillar 3516B reciprocating engines will be utilized to drive inlet natural gas compressors. These units are 4 -stroke, lean -burn units that are inherently low-NOx emitting units, and will equipped with oxidation catalyst to further control CO and VOC/HAP emissions. Manufacturer emission factors and factors for 4 -stroke, lean -burn engines reported in the EPA AP -42 document were utilized for these estimates. Engine emission estimates are summarized Caterpillar G3516B Enginecalculation Basis Source ID Number El, F2, F.3 Source Description 4 -Cycle Lean Burn Engine Usage Compressor Engine Engine Make Caterpillar Engine Model (1361B Emission Controls Low NO ;/Oxid. Catalyst Engine Rating 1380 BHP Fuel Heating Value 1100 Btu/scf Heat Rate 10.08 MMBtu/hr Engine Heat Rate 7301 Btu/hp-hr Hours of Operation 8760 hr/yr (per engine) Potential fuel usage 80.2 MMscf/yrr (per engine) PTF. Emissions Pollutant Emission Factor Rating Estimated Emissions Source of Emission Factor lb/MMBtu lb/MMSCE g/hp-hr hp lb/hr (engine) tpy (per engine) lb/hr (all engines) tpy (all engines ) NOx CO VOC SOx PM 10 PM2.5 0.1508 0.1508 0.1448 5.88E-04 7,71E-05 7.21E-05 165.93 3319 79.65 0.647 0.085 0.085 0.5000 0.5000 0.4800 0.0019 0.0003 0.0003 1380 1380 1380 1380 1380 1380 1.52 1.52 1.46 0.01 0.00 0.00 _ 6,7 6.7 6.4 0.03 0.003 0.00 4.6 4.6 4.4 0.0 0.0 0.0 20.0 20.0 19.2 0.1 0.01 0.01 Manufacturer Manufacturer -Catalyst , 40 CFR Part 60 Subpart JJJJ AP -42, Table 3.2-2 AP -42, Table 3.2-2 AP -42, Table 3.2-2 HAP Emissions FICHO Benzene Toluene Acrolein Acetaldehyde 3.42E-02 4.40E-04 4.08E-04 5.14E-03 8.36E-03 3T650 0.034 0.031 0.396 0.644 0.1133 0.0015 0.0014 0,0170 0.0277 1380 1380 1380 1380 1380 0.34 0.001 0.004 0.051 0.084 1.51 0.02 0.02 0.73 0.3 7 1.0 0.0 0.0 0.2 0.3 4.53 0.06 0.05 0.68 1.11 40 CFR Part 63 Subpart ZZZ7 AP -42, Table 3.2-2 AP -42, Table 3.2-2 AP -42, Table 12-2 AP -42, Table 3.2-2 GI1G Combustion Emissions (Diglis h ) Pollutant Ens s ion Factor Emissions Emission Factor Source kg/MMBtu lbI MBtu tpy (per engine) tpy (all engines) CO2 CM N20 53.06 0.001 0.0001 116.977 0.0022 0.0002 5,162 0,10 0.01 15,487 0.2:9 0.03 40 CFI Part 98 Subp. C Tables C-1 & C-2 (The 5,168 15,593 Compressor Blowdown Emissions Compressors will be blowndown on occasion for maintenance and starting purposes. These events will vent to the atmosphere. Emission estimates are based on a volume derived from piping and instrumentation diagrams for an Ariel JGE4-2 compressor. A total of 24 blo down events per year per compressor is assumed, and the inlet gas composition based on a sample collected from a well that is considered typical of what will fed the facility was used for the composition basis of the material that will be blowndown. Inlet Gas Composition Constituent I Mole Percent Carbon Dioxide 1.4804 Nitrogen 0.5629 Methane 70..7311 Ethane 15.3670 Propane 7.5989 Isobutane 0.8350 Butane 2.1189 Isopentane 0.3913 Pentane 0.3926 Cyclopentane 0.0000 n -Hexane 0.0743 Cyclohexane 0.0000 2-Methylpentane 0.0000 3-Methylpentane 0.1734 Heptane 0.1560 Methylcyclohexane 0.0000 2,2,4-Trimethylpentane 0.0200 Benzene 0.0301 Toluene 0.0174 Ethylbenzene 0.0039 ortho-Xylene 0.0102 Octane 0.0231 Water 0.0000 TEG 0.0000 C9 0.0093 C10 0.0042 V0C 11.8586 CO2 1.4804 CH4 70.7311 Benzene 0.0301 Toluene 0.0174 Ethy!benzene 0.0039 Xylenes 0.0102 n -Hexane 0.0743 Slowdown Emission Summary Compressor Blowdown Fnussions Basis A.riel JGE4-2 P&IDs were used for Volume Estimate Blowdown Volume 4.2 l s cf/event/comp Number Compressors 4 Blowdowns for base Ia2 24 per year Total Vent Volume Frnis s ions Fs ti mate 403.20 M s c fly e ar Component Mole % MW Uncontrolled Controlled tpy tpy T OC CO2 CH4 Benzene Toluene [thy lbenzene Xylenes n -Hexane CO2e 11.859 1.480 70.731 0.030 0.017 0.004 0.010 0.074 50.000 44.000 16.000 78.110 92.140 106.170 106.170 86.170 3.154 0.063 0.346 0346 6.020 0.120 0.013 0.000 0.009 0.000 0.002 0.000 0.006 0.000 0.034 0.001 150.84 3.36 Compressor Rod Packing Vents Compressor rod packing seals leak a small amount of gas almost continuously at very low pressures making this type of emission source very difficult to apply any type of emission control. 40 CFR 60, Subpart OOOO will apply to these compressors, and it sets forth the requirement to periodically replace these seals, which is an effectiveemission control option. Emissions estimates for this source are based on the same composition as blowdown emissions and a leak rate of 50 scf/hr per compressor. This value is mid -range in what has been typically measured by EPA for its Gas Star program. Rod packing vent emissions are summarized below. Rod Packing Emissions Summary Basis Number Vent rate Total Gas Vented 4 Units 50 scVhr per Unit 200 seflhr Emissions Estimate Species MW Mole % Uncontrolled lb/hr tpy VOC CO2 CH4 Benzene Toluene Ethy Xylenes n -Hexane CO2e lbenzene i 106.170 106.170 50.000 44.000 3 11.859 70.731 0.017 0.004 0.010 0.074 1.480 0.030 149.644 3.13 0.34 5.97 0.01 0.01 0.00 0.01 0.03 13.70 26.16 655.44 1.51 0.05 0.04 0.01 0.03 0.15 16.000 78.110 92.140 86.170 Condensate Storage Tanks Condensate will form during inlet gas transport to the facility and during compression. The amount of condensate that may be collected was predicted using the ProMax process simulation software. A three -stage compression model was developed and executed using the inlet gas analysis utilized for the basis of the blowdown and packing vent emission estimates. Model output is provided in Attachment E. The simulation was set up assuming atmospheric storage of the condensate, with working and breathing losses, as well as thermodynamic flash emissions will be recovered by a vapor recovery (VRU) that will collect vapors off the tanks and feed them upstream of the MRU. Vapors will be directed to an enclosed flare during times when the VRU is not operational (assumed to be 10 percent annually). Condensate tank emissions are summarized below. Condensate Tank Flash Emissions Summar lblhr Constituent Uncontrolled Controlled Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane Is o p entane Pentane Cyclopentane n -Hexane Cyclohexane 2-Methy 1pentane 3-Methylpentane Heptane Methylcyclohene 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene ortho-Xylene Octane Water Ethylene Glycol C9 OO 2.1684 2.1684 0.0583 0.0583 14.0758 0.2815 31.8459 0.6369 5 8.373 1 1.1675 13.3072 0.2661 37.9793 0.7596 9.8775 0.1975 9.9934 0.1999 0.0000 0.0000 1.9941 0.0399 0.0000 0.0000 0.0000 0.0000 4.8494 0.0970 3.0823 0.0616 0.0000 0.0000 0.4677 0.0094 0.7163 0.0143 0.3079 0.0062 0.0375 0.0007 0.0821 0.0016 0.23 78 0.0048 0.0755 0.0755 0.0000 0.0000 0.0375 0.0008 0.0065 0.0001 tpy VOC CO2 CH4 Benzene Toluene Ethylbenzene Xylenes n -Hen e 2,2,4-Trimethy 1pen tan e CO2e Total Flow 61.9111 0.7599 0.9497 0.9497 6.1652 0.1233 0.3137 0.0063 0.1349 0.0027 0.0164 0.0003 0.0360 0.0007 0.8734 0.0175 0.2048 0.0000 16.4 13 scfh MMscfy 57.693 1 0.5054 Condensate Tank Working and Breathing Emissions Components (ton/yr) Working Losses Breathing Losses Total Losses Controlled Mixture 11.69 62.12 73.81 0.15 Propane 4.07 21.61 25.68 0.05 Isobutane 1.16 6.16 7.32 0.01 Butane 3.59 19.10 22.69 0.05 Isopentane 0.91 4.52 5.72 0.01 Pentane 0.93 4.93 5.56 am Cyclopentane 0.00 0.00 0.00 0.00 n -Hexane 0.19 1.00 1.18 0.00 Cyclohexane 0.00 0.00 0.00 0.00 2-Methylpentane 0.00 0.00 0.00 0.00 3-Methylpentane entane 0.46 2.42 2.88 0.01 Heptane 0.26 1.41 1.67 0.00 Methylcyclohexane 0.00 0.00 O00 0.00 2,2,4-Trirnethylpentane 0.04 0.22 0.26 0.00 Benzene 0.04 0.22 0.26 0.00 Toluene 0.02 0.09 0.11 0.00 Ethylbenzene 0.00 0.01 0.01 0.00 ortho-Xylene lell a 0.00 0.02 0.02 0.00 Octane 0.02 0.10 0.12 0.00 Ethylene Glycol 0.00 0.02 0.02 0.00 C9 0.00 0.00 0.00 0.00 C10 0.00 t 0.00 paw EG Dehydration Unit Emissions from the EG Dehydration units were also estimated using the ProMax process simulator. Again, simulation output is provided in Attachment E. Emissions from the associated flash tank are assumed to be utilized to the extent possible as fuel for the regenerator reboiler. Any excess flash gas will be sent to an enclosed flare. It is also assumed that either operating scenario will achieve a 98 -percent control efficiency. All of the regenerator still vent emissions will be directed to an enclosed flare. Emissions reported on application forms for this unit is the total from both the flash tank and the still vent and were adjusted up by a 100 percent safety to account for inlet gas composition variability and process simulation assumptions. Emissions from the dehydration unit are summarized below: EG Dehydrator Emissions Summary Constituent Flash Tank lb/hr I Still Vent lb/hr Total lb/hr Uncontrolled f Controlled I Uncontrolled Carbon Dioxide 2.3565 2.3565 Nitrogen 0.0163 0.0163 Methane 2.9711 0.0594 Ethane 0.6523 0.0130 Propane 0.1269 0.0025 Isobutane 0.0051 0.0001 Butane 0.0198 0.0004 Isopentane 0.0016 0.0000 Pentane 0.0018 0.0000 Cyclopentane 0.0000 0.0000 n -Hexane 0.0002 0.0000 Cyclohexane 0.0000 0.0000 2-Methylpentane 0.0000 0.0000 3-Methylpentane 1p entan e 0.0007 0.0000 Heptane 0.0003 0.0000 lei ethy Icy clohexane 0.0000 0.0000 2,2,4-Trirnethylpentane 0.0000 0.0000 Benzene 0.0022 0.0000 Toluene 0.0005 0.0000 Ethylbenzene 0.0000 0.0000 ortho-Xylene 0.0001 0.0000 Octane 0.0000 0.0000 Water 0.0040 0.0040 EG 0.0007 0.0000 C9 0.0000 0.0000 C10 0.0000 0.0000 5.8186 0.0008 0.2968 0.0876 0.0171 0.0005 0.0037 0.0003 0.0005 0.0000 0.0001 0.0000 0.0000 0.0003 0.0002 0.0000 0.0000 0.4632 0.1584 0.0187 0.0826 0.0000 55.6791 0.0000 0.0000 0.5926 Controlled 5.8186 0.0008 0.0059 0.0018 0.0003 0.0000 0.0001 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0093 0.0032 0.0004 0.0017 0.0000 55.6791 0.0000 0.0000 0.0119 Uncontrolled 8.1751 0.0171 3.2679 0.7399 0.1440 0.0056 0.0235 0.0019 0.0023 0.0000 0.0003 0.0000 0.0000 0.0010 0.0005 0.0000 0.0001 0.4654 0.1589 0.0187 0.0827 0.0001 55.6831 0.0008 0.0000 0.5926 Controlled 8.1751 0.0171 0.0654 0.0148 0.0029 0.0001 0.0005 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0093 0.0032 0.0004 0.0017 0.0000 55.6831 0.0000 0.0000 0.0119 tpy (with 100% safety factor) VOC 1.4018 0.0280 11.7228 0.2345 13.1246 I 0.2625 CO2 10.3214 10.3214 25.4856 25.4856 35.8070 35.8070 13.0134 0.2603 1.3001 0.0260 14.3135 0.2863 CH4 Benzene 0.0191 0.0004 4.0573 0.0811 4.0765 0.0815 Toluene 0.0043 0.0001 1.3875 0.0277 1.3918 0.0278 Ethylbenzene 0.0003 0.0000 0.1634 . 0.0033 0.1638 0.0033 Xylenes e s 0.0008 0. 00 0.7233 0.0145 0.7240 0.0145 n -Hexane e 0.0017 0.0000 0.0007 0.0000 0.0024 0.0000 CO2e 335.7 16.8 58.0 26.1 393.6 43.0 Total Flow scfh MMscfy scth MMscfy scfh MMscfy 57.6931 0.5054 417.0649 3.6535 2159.1465 18.9141 Produced Water Storage Tanks Liquid produced water will form during inlet gas transport to the facility and during compression. The amount of water that may be collected was predicted using the ProMax process simulation software. A three-phase compression model was developed and executed using the inlet gas analysis utilized for the basis of the blowdown and packingvent emission estimates. The simulations are executed assuming the inlet gas processed by the compression is saturated at the conditions under which the gas sample was collected. Model output is provided in Attachment E. Produced water emissions are summarized after the dehydration unit emission. Fugitive Equipment Leaks Emissions from fugitive equipment leaks are estimate using emission factors reported in Table 2-8 of Protocol for Equipment Leak Emission Estimates (EPA -453/R-95-017) and component counts from facilities of similar sizes. Emissions are summarized in the following sequence of tables. Produced Water Emissions Summary Constituent lb/hr Uncontrolled Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane Isopentane Pentane Cyclopentane n -Heine Cyclohe ne 2-Methylpentane 3-Methylpentane Heptane Methyleyelohexane 2,24-Trimet b y 1p e n to n e Benzene Toluene Ethylbenzene ortho-Xylene Octane Water TEG C9 C10 0.0427 0.0000 0.0032 0.0017 0.0016 0.0000 0.0003 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0124 0.0039 0.0004 0.0013 0.0000 325.0758 0.0000 0.0000 0.0000 tpy voC CO2 CH4 Benzene Toluene Ethylbenzene Xylenes n -Hexane CO2e 0.0875 0.1870 0.0140 0.0544 0.0171 0.0019 0.0056 0.0000 0.5358 Total Flow s cfh 6848.1531 C Cs tin C c U, E V C U 0. N n tin coMtrolled C V C 0 C vain 4 F Q v . a C W v a Uncontrolled FJ C U C F U u O Cbbei V Ie co ici UU Cl] o 0 tract) C) C D o O Ea C J U ILI I 4 c • C n 0 5 CL a Component Type ^fi C C rr. (1 mete C C. C C C C7 eel; 0 C O+ C C C C C r~; ry P1 C C CI, C C C • 7 �/. C C 'C N C sot C C fia C 0 O C Y C C C V 6 C C cb N C C. C ict C: cc vy. C rei C C Wee C C C N CV C cc C r+'I 4 C C C C C col r` -r Y r x 1 C. 4 - ti< C a C C C C• C C C d .i-. C' arr Yee- • sire 8 N If ' r. Ata N 7▪ C 4": a z r^t r-4 a re: a rr, rf, X r4 a C C N C7 In Rn tC . +C. r.•6 C C N CV C at Y'5 N M C C C'. C n C in Pei C en at N 1*s C n tfi en C C • CI T C en ?# M C C Cri C N N C C N a C C' C C C 5C 't r CC C N en C I rq n »R et: SENO r r- n ae a C G V Cl N 0 a N ry R r M C N N C C C'J 3 C lane re, r t h r at. a a C Cv C C C C 6 mit "t C C C C a a a▪ . F In rw et -r Y rt ire 7 1; Nf 71. Pr f r.� z n Cie In 0 M w "C C C VI 04 r*+ e r•4 ✓ ✓ 5 2 U O U Y1 C) C a G C C C 0 C C z C C a. C C C C C C C C C C: C C C C fine C C C. C C G C ales C a C C C C —4 C 0 C C _C C C C C C 7 C C 0 C 6 O C Y C 6 0 C C O C C z 0 C C` a C C CD 0 8 C C C? a C C? C C C7 X V 8 Ann C a a C. a C z • G C G 0C C C C O 7 t Ve• of a' X C r C 6 .`. J C •Q L • O K ce T� a YeaNt en rM 4.1 C C> C C C C C C C C C C C C C C C x n C C C 0 C C C C C C C C C C C co C C leer a - C C C C C. C 0 a e -- a 5 0 9 G 4- a 7 G r a C C C O C z Se NENE a • lar nile 0 a a rase In .21 yr ce a. gn c. O • • 8 8 a 0 MAP cry ant Cis • sale 13. tol Pri kei as 4-4 en S ON Fi -t 0 bn erl isrc Fre Lel 8 St 41) e n en ao rn rri 2 Ur re - -r SCI a re oc adr -t Pr crs C. en FA reb gll cal WEI 041) CC CC 'Et sat en on, at a al a Irt • tn ill PI a. Buffered Plant- Wide Enclosed Flare Combustion emission estimates for the plant -wide combustor are based on flare emission factors reported by the Texas Commission on Environmental Quality (TCEQ). These factors are a function of the heat content of the stream combusted.. The stream fed to this flare will be a combination of possibly condensate tank vent gas, dehydrator still vent vapors and closed vent system purge and pilot gas that is assumed to be residue gas quality. This unit is an insignificant emission source. The associated mass and energy balances and resulting emission estimates are summarized below. Plant -Wide Enclosed Flare Emission Summary Component Emission Factor Emissions Source (Ib/MM13tu) (lb/MMSCF) (lb/hr) (tpy) NOx Co VOC 0.138 0.2755 — 8.65 17.27 5.5 0.01 0.02 0.000 0.1 0.1 0.00 TCEQ TCEQ AP -42, Table 1.4-2 Composition Constituent MW LHV Mel% (lb/lb-ynol) lb/mole Btu/scf Condensate Tank I Purge/Pilot Gas I Flare Inlet (avg) Carbon Dioxide 44 0 6.0842 1.4783 5.7168 Nitrogen 28 0 0.1040 0.5630 0.1406 Methane 16 909.4 45.0608 70.7362 47.1085 Ethane 30 1618.7 23.1981 15.3637 22.5733 Propane 44 2314.9 15.5730 7.5951 14.9367 1sobutane 58 3000.4 1.5615 0.8346 1.5035 Butane 58 3010.8 4.8746 2.1172 4.6547 Is opentane 72 3699.0 0.9196 0.3908 0.8774 Pentane 72 3706.9 1.0048 0.3920 0.9559 Cyclopentane 70 3512.1 0.0000 0.0000 0.0000 n -Hexane 86 4403.8 0.1771 0.0741 0.1689 i Cyclohexane 84 4179.7 0.0000 0.0000 0.0000 1 2-Methylpentane 86 4384.0 0.0000 0.0000 0.0000 3 -Meth ylp entane 86 4384.0 0.4406 0.1729 0.4193 Heptane 100 5100.0 0.3264 0.1554 0.3128 Methylcyclohexane 98 4863.6 0.0000 0.0000 0.0000 2;2,4-Trimethy 1pentane 114 5778.8 0.0405 0.0199 0.0389 Benzene 78 3590.9 0.1143 0.0281 0.1074 Toluene 92 4273.6 0.0513 0.0157 0.0484 Ethylbenzene 106 4970.5 0.0087 0.0035 0.0082 orth o -X3, lene 106 4956.3 0.0219 0.0087 0.0208 Octane 114 5746.3 0.0398 0.0230 0.0384 Water 18 0.0 0.3822 0.0143 0.3529 TEG 150 3965.7 0.0001 0.0000 0.0001 C9 128 6435.1 0.0125 0.0092 0.0122 C10 142 7127.4 0.0042 0.0042 0.0042 Volume (set) 57.6931 5.0000 62.6931 MM Btu/hr 0.0847 0.0060 0.0907 Reboiler Burners The dehydrator reboiler and the reboiler associated with the stabilizer that will be operated within the refrigeration process unit will be rated at less than 3.5 MMBtu/hr and will be fired with residue gas. Associated emissions are estimated based on emissions reported in EPA AP - 42, Table 1.4-1. Emissions from these sources are insignificant, and the estimates are summarized below. Burner Emissions Summary Basis Burner Rating Fuel Heating Value NOX EF CO EF VOC EF 3.5 MMBtulh r 1100 Btuls cf 100 lb!Mleiscf 84 lb/MMscf 5.5 lb/MMscf Emissions Estimate (tpy) NOX CO VOC 1.39 1.17 0.08 Facility Potential to Emit Summary Emissions Unit (Iblyr) NOx CO VOC Benzene TolueneEthyl Xylenes Formaldehyde n -Hexane Benzene Total HAP El -Reciprocating Engine E2 -Reciprocating Engine E3 -Reciprocating Engine E4 -Reciprocating Engine CB -Co nipressor Blowdown RP -Rod Packing Seal Vents CT -Condensate Tanks D1 -Dehydrator D2 -Dehydrator Fug -Fugitive Equipment Leaks Produced Water Storage Tanks Plant -Wide Enclosed Flare Dehydrator Regenerator Burner Stabilizer Burner Facility Potential to Emit 6.66 6.66 6.66 6.66 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.14 1.39 1.39 6,66 6.66 6.66 6.66 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.28 1.17 1.17 6.40 38.83 5.40 38.83 6.40 38.83 6.40 38.83 3.15 25.01 13.70 108.68 0.27 2.31 0.26 163.06 0.26 163.06 3.2E 114.62 0.09 108.87 0.01 0.00 0.08 0.00 0.08 0.00 29.58 29.27 46.71 36.01 0.00 0. 36.01 0,00 0.00 36.01 0.00 0.00 36.01 0.00 0.00 17.06 4.41 11.52 74.11 19.14 50.06 0.97 0.12 0.24 5167 6.55 28.96 55.67 6.55 2$_96 169.95 64.23 178.06 34.19 3.86 11.14 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 840.95 551.66 104.86 308.94 3020.90 0.00 3095.75 3020.90 0.00 I 3095.75 3020.90 0.00 3095.75 3020.90 0.00 3095.75 OMO 68.11 126.11 0,00 295.96 547.96 0.00 8.23 11.86 0.00 0.09 254.34 0.00 0.09 254.34 0.00 312.75 839.61 0.00 0.00 158.06 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00. 0.00 12083.61 685.25 s 14575.26 Attachment D Regulatory Analysis Regulatory Analysis PREVENTION OF SIGNIFICANT DETERIORATION (PSD) 40 CFR Part 52 Section 52.21 — Prevention of Significant Deterioration of Air Quality. The requirements of this Subpart apply to the construction of new major stationary sources, the major modification of any existing major source, or any project at an existing major stationary source in an area designated as attainment or unclassified. A major stationary source is any of the 28 listed source categories that emits or has the potential to emit 100 tpy or more of any regulated pollutant or any other source type which emits or has the potential to emit any regulated pollutant in amount equal to or greater than 250 tpy. Facility potential to emit will be below PSD applicability thresholds. Therefore, the Federal PSD rule set forth in 40 CFR §52.21 as adopted by Colorado Regulation 3 does not apply to the Facility. GREENHOUSE GAS 40 CFR Part 51, 52, 70, and 71 — Greenhouse Gas Tailoring Rule. The US Supreme Court has held in Utility Air Regulatory Group v. Environmental Protection Agency No. 12-1146 that the tailoring rule exceeded EPA's authority under the Clean Air Act and applicability of these provisions to any project is likely moot. Therefore, the Tailoring Rule does not apply. 40 CFR Part 98 — Mandatory Greenhouse Gas Reporting. Subparts C and W apply to sources in certain segments of the oil and gas industry with the potential to emit Greenhouse Gases (GHG). It requires such sources above certain emissions thresholds to monitor, calculate, and report greenhouse gas emissions. This Facility meets the definition of a source category subject to both subparts. NEW SOURCE PERFORMANCE STANDARDS (NSPS) 40 CFR Part 60 General Provisions. The General Provisions of this Subpart apply to owners and operators of stationary sources that contain an affected Facility as defined under this Subpart after the publication date of a standard. The general provisions apply if there are sources subject to specific subparts of part 60. 40 CFR Part 60 Subpart KKK — Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants for Which Construction, Reconstruction, or Modification Commenced After January 20, 1984 and on or Before August 23, 2011. The facility will not be subject to this regulation based on the date of construction. 40 CFR Part 60 Subpart Kb — Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels)...Which Construction, Reconstruction, or Modification Commenced After July 23, 1984. This Subpart applies to each storage vessel with a capacity >75 m3 (-49,813 gal) used to store volatile liquids (VOL) for which construction, reconstruction, or modifications commenced after July 23, 1984. This facility will be subject to th i s subpart. 40 CFR Part 60, Subpart GO: Standards of Performance for Stationary Gas Turbines. This rule applies to stationary gas turbines, with a peak load heat input equal to or greater than 10 MMBtulhr that commenced construction, modification, or reconstruction after October 3, 1977. There are no stationary gas turbines which meet this definition located at the facility; therefore, this subpart does not apply. 40 CFR Part 60 Subpart III! — Standards of Performance for Stationary Compression Ignition Internal Combustion Engines. This Subpart applies to owners and operators of stationary Compressor Ignition (CI) Internal Combustion Engines (ICE) constructed, modified, or reconstructed after July 11, 2005. There are no CI ICE engines located at the facility; therefore, this subpart does not apply. 40 CFR Part 60 Subpart JJJJ — Standards of Performance for Stationary Spark Ignition Internal Combustion Engines. This Subpart applies to owners and operators of stationary Spark Ignition (SI) Internal Combustion Engines (ICE) manufactured after July 1, 2007 or modified or reconstructed after June 12, 2006. The driver engines will be subject to this Subpart. 40 CFR Part 60 Subpart OOOO: Crude Oil and Natural Gas Production, Transmission, and Distribution. This subpart applies to crude oil and natural gas production, transmission, and distribution facilities constructed after August 23, 2011. Affected facilities include pneumatic controllers, reciprocating compressors, equipment leaks, natural gas sweetening units and storage vessels. The Facility will be subject to this subpart 40 CFR Part 60 Subpart Db — Standards of Performance for New Fuel Burning Equipment. Subpart Db applies to steam generating unit that commences construction, modification or reconstruction after June 19, 1984 and that has a heat input capacity of greater than 100 MMBIllihr. There will not be steam generating units greater than 100 1' MBTUIhr at the Facility. Therefore, the Facility► will not be subject to the standards set forth by this Federal requirement. 40 CFR Part 60 Subpart Dc — Standards of Performance for Small Industrial -Commercial - Institutional SteamGenerating Units. Subpart Dc applies to steam generating unit that commence construction, modification or reconstruction after June 9, 1989 and that has a maximum heat input capacity less than 100 Ml' BTU/hr. The amine reboilers (AR! AR2) will be subject to this Subpart. 12.4 NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS (NE SHAP) 40 CFR Part 63 General Provisions. The General Provisions of this Subpart apply to owners and operators of stationary sources that contain an affected Facility as defined under this Subpart after the publication date of a standard. The general provisions apply if there are sources subject to specific subparts of part 63. 40 CFR Part 63 Subpart ZZZZ — National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. This Subpart applies to Reciprocating Internal Combustion Engines (RICE) located at major and area sources of HAP emissions. The driver engines will be subject to this Subpart. 40 CFR Part 63 Subpart HH — National Emission Standards for Hazardous Air Pollutants from Oil and Natural Gas Production Facilities. Subpart HH applies to glycol dehydration units, storage vessels with the potential for flashing, compressors, and ancillary equipment at major sources of HAP emissions, and glycol dehydration units at area sources of HAP emissions. The Facility will not be a major source with respect to HAP. The dehydration will also have a federally -enforceable emission limit for benzene of less than 1 tpy, therefore, the facility will not be subject to this subpart 40 CFR Part 63 Subpart HHH — National Emission Standards for Hazardous Air Pollutants: Organic Liquids Distribution (Non -Gasoline). This Subpart HHH applies to natural gas transmission and storage facilities that transport or store natural gas prior to entering the pipeline to a local distribution company or to a final end user, and that are a major source of HAP emissions. A compressor station that transports natural gas prior to the point of custody transfer or to a natural gas processing plant (if present) is not considered a part of the natural gas transmission and storage source category. Therefore, the Facility will be exempt from this Subpart. 12.5 STATE REGULATIONS Regulation 1: Emission Control for Particulate Matter, Smoke, Carbon Monoxide, and Sulfur Oxides, Section II — Smoke and Opacity. The visible emissions standards of Regulation Number 1 apply to all owners and operators of stationary sources in Colorado. This facility is subject to the regulation. Regulation I, Section II. Visible emissions from the equipment shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. The Facility is subject to this regulation. Regulation 2: Odor Emissions. The odor emissions standards of Regulation. Number 2 apply to all owners and operators of stationary sources in Colorado. This facility is subject to the regulation. Discovery will comply with the applicable standards of this Regulation as they apply to the Facility. Regulation 3, Part A, Section II: Air Pollutant Emission Notice Requirements. APENs are required for all stationary sources with the potential to emit greater than 2.0 tons per year criteria pollutants in an attainment area. The appropriate forms and associated fees are included with this application. Regulation 3, Part B, Section II: Construction Permit Requirements. A construction permit application is required for all sources with site -wide emissions of VOC exceeding 5.0 tpy criteria pollutants in an attainment area. Pursuant to Section II.D.3, a construction permit application is being filed for the appropriate sources. This site -wide potential to emit is calculated by totaling the emissions of all emission points required to file an APEN at the facility. Regulation 3, Part C, Section II: Operating Permit Requirements. This section addresses operating permit requirements for major sources under the definitions of Regulation Number 3. The Facility is classified as a minor source under the definitions set forth in Part A. Therefore, the Facility will not be subject to this regulation. Regulation 3, Part D, Section I: Major Stationary Source New Source Review and Prevention of Significant Deterioration. This section addresses the requirements for new source review and PSD sources in the state of Colorado. The Facility is classified as a true minor source under the definitions set forth in Part A of Regulation Number 3. Therefore, the Facility is not required to perform a PSD analysis. Regulation 6: Standards of Performance for New Stationary Sources. Regulation Number 6 addresses the federal standards adopted by the Colorado Air Quality Control Commission and incorporated into the state regulations. See the Federal Regulations applicability section above. Regulation 7, Section I: Applicability (General). Discovery intends to comply with the section of Regulation Number 7 which applies to sources in attainment and areas. Regulation 7, Section V: Disposal of Volatile Organic Compounds. This section prohibits owners and operators from disposing of VOCs by evaporation or spillage. Discovery does not intend to dispose of any VOC by evaporation or spillage, thereby demonstrating compliance with this standard. Regulation 7, Section VLB: Storage and Transfer of Petroleum Liquid. This section sets forth standards for tanks greater than 40,000 gallons which are used for the storage of petroleum liquids. There are no tanks at the Facility which meet the applicability standards, so this Section does not apply. Regulation 7, Section VII: Equipment and Storage of Crude Oil. This section sets forth standards for storage and associated equipment which handles crude oil in the State of Colorado. There is no crude oil handling at the Facility, so this Section does not apply. Regulation 7, Section II: Volatile Organic Compound Emissions from Oil and Gas Operations. This section applies to oil and gas exploration and production operations, natural gas compressor stations, and natural gas drip stations that collect store, or handle condensate in the 8 -hour Ozone Control Area that are located upstream of a natural gas plant and is required to file an APEN that emit any amount of VOCs in the State of Colorado. The Facility is located within the 8 -hour Ozone Control Area, so this Section will apply. Regulation 7, Section XVII, Statewide Controls for Oil and Gas Operations and Natural Gas Fired Reciprocating Internal Combustion Engines. This Section applies to storage tanks, equipment leaks, dehydrators, and natural gas fired reciprocating internal combustion engines located in the State of Colorado. Discovery intends to comply with all applicable standards of this Section. Attachment E Supporting Documentation PRECIS ION ANALYSIS Run File Method Operator Client: Sample Identification: Unique #: Sample Temperature: Sampled by: Component GAS MEASUREMENT EMISSIONS TESTING LABORATORY 307 856.0866 wwwprecision-lobs. tror n C:\Galaxie\data\15_01_26\15012311-O1 two1.DATA S2_BTEX User' Ward Petroleum Sharp 24-3-11 HC NI 108.8 DEG F Erik Hollaway Mole % Analysis Date Date Sampled: Purpose: Pressure: Type Sample: County: 1/26/2015 1/23/15 NI 224 PSI SPOT Adams BTU GPM Nitrogen (N2) Carbon Dioxide Methane (CH4) Ethane (C2) Propane (C3) iso-Butane (i-C4) Butane (C4) iso-Pentane (i-CS) Pentane (C5) Hexanes (C6) Heptanes (C7) Octanes (C8) Nonanes (C9) Decanes (C10+) Benzene Toluene Ethylbenzene Xylenes Totals 0.5629 1.4804 70.7311 15.3670 7.5989 0.8350 2.1189 0.3913 0.3926 0.2477 0.1560 0.0431 0.0093 0.0042 0.0301 0.0174 0.0039 0.0102 100.0000 0.0000 0.0000 714.3841 271.9498 191.1959 27.1534 69.1249 15.6555 15.7382 10.8874 8.5841 2.6933 0.6507 0.3252 1.0809 0.7436 0.1939 0.5056 1330.8664 0.0000 0.0000 0.0000 4.0992 2.0881 0.2725 0.6663 0.1428 0.1419 0.1008 0.0718 0.0220 0.0052 0.0026 0.0084 0.0058 0.0015 0.0039 7.6329 Specific Gravity from Composition Ideal BTUs @ 14.730 Saturated Ideal BTUs @ 14.730 Dry Compressibility 0.791 1311.464 1333.931 0.99569 Real BTUs @ 14.730 Saturated Real BTUs @ 14.730 Dry 1317.146 1339.711 O L U Ci LL 15 15 S th a- 1- a. cn Gas To Compression r 5 cr J VJ 1 Overhead d_ w r u Con r X LL Stage 1 Compression 0 d ID -ICL d a I CNI 1 2 - YJ 0 0 I LL a J o to O Lit O I C;+Mass F .Ci C Stage 3 Corn a. th F RI E a, G 4 a> t8 tai 0 t4 L. Cr Q) W yes Tv � N 4O LT)w T u 0 *h w to 6- t0 — 0 n o cis a in El 'C t0 • J css I- Process Streams Inlet Gas To VRU Composition Phase: Total Status: From Block: To Block: Mole Fraction Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane ,Isopentane Pentane Cyclopentane n -Hexane Cyclohexane 2-Methylpentane 3-Methylpentane Heptane Methylcyclohexane 2, 2,4-Trimethylpentane Benzene Toluene Ethylbenzene ortho-Xylene Octane Water C9 C10 Ethylene Glycol Mass Fraction Solved Solved Ambient Cooling MIX -101 Inlet 3 -phase Separator - 1.47198 0.559697 70.3287 15.2796 7.55567 0.830249 2.10684 0.389074 0.390366 0 0.0738773 0 0 0.172413 0.155112 0 0.0198862 0.0299287 0.0173010 0.00387781 0.0101420 0.0229686 0.568949 0.00924709 1.07018 0.0451957 19.0577 23.0039 28.7532 4.97293 14.1930 2.97362 3.00851 0 0.502610 0 0 1.22228 0.668141 0 0.0889308 0.199184 0.0725898 0.00766 819 0.0167978 0.0452230 0.0910291 0.00635414 0.00417610 0►.000991397 0 0 Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane Isopentane Pentane Cyclopentane n -Hexane Cyclohexane 2-Methylpentane 3-Methylpentane Heptane Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene ortho-Xylene Octane Water C9 Cl Ethylene Glycol Mass Flow 2.83211 0.685459 49.3248 20.0860 14.5657 2.10966 5.35349 1.22722 1.23130 0 0.278328 0 0 0.649556 0.679493 0 0.0993091 0.102204 0.0696906 0.0179982 0.0470723 0.114702 0.448102 0.0518492 0.02 59766 0 1.14382 0.0307480 7.42498 16.7987 30.7918 7.01954 20.0341 5.21037 5.27150 0 1.05188 0 0 2.55805 1.62592 0 0.246707 0.377855 0.162432 0.0197710 0.0433099 0.125455 0.0398268 0.0197918 0.00342571 0 lb/h Ib/h Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane 2575.99 623.470 44864.2 18269.5 13248.4 1918.88 4869.35 2.16837 0.0582901 14.0758 31.8459 58.3731 13.3072 37.9793 Isopentane Pentane Cyclopentane n -Hexane Cyclohexane 2-Methylpentane 3-Methylpentane Heptane Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene ortho-Xylene Octane Water C9 C10 Ethylene Glycol 1116.24 1119.95 0 253.157 0 0 590.814 618.044 0 90.3281 92.9612 63.3882 16.3706 42.8154 104.329 407.578 47.1602 23.6274 0 9.87748 9.99337 0 1.99409 0 0 4.84938 3.08231 0 0.467690 0.716313 0.307927 0.0374806 0.0821041 0.237830 0.0755011 0.0375200 0.00649424 0 Molar Flow lbmolih Ibmolfh Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane Isopentane Pentane Cyclopenta ne n -Hexane Cyclohexane 2-Methylpentane 3-Methylpentane Heptane Methylcyclohexane 2,2,4-Trirnethylpentane Benzene toluene Ethylbenzene ortho-Xylene Octane Water 09 C10 Ethylene Glycol 58.5326 22.2561 2796.59 607.586 300.448 33.0145 83.7778 15.4714 15.5228 0 2.93770 0 0 6.85595 6.16798 0 0.790767 1.19010 0.687967 0.154200 0.403291 0.913336 22.6240 0.367707 0.166061 0 0.0492706 0.00208079 0.877408 1.05909 1.32379 0.228952 0.653439 0.136904 0.138511 0 0.0231399 0 0 0.0562734 0.0307610 0 0.00409434 0.00917035 0.00334200 0.000353041 0.000773364 0.00208205 0.00419095 0.000292542 4.56435E-05 0 Process Streams Inlet Gas To VRU Properties Phase: Total Property Status: From Block: To Block: Units Solved Ambient Cooling Inlet 3 -phase Separator Solved MIX -101 Temperature Pressure Mole Fraction Vapor Mole Fraction Light Liquid Mole Fraction Heavy Liquid Molecular Weight Mass Density Molar Flow Mass Flow Vapor Volumetric Flow Liquid Volumetric Flow Std Vapor Volumetric Flow psia off° Ibflbmol Iblft"3 Ibmollh lb/h ftA3/h gpm MMSCFD 55* 192.106* 99.1101 0.437230 0.452707 22.8738 0.856960 3976.46 90956.6 106139 13232.9 36.2161 65 25.1063 100 0 0 41.1762 0.188469 4.60396 189.573 1005.86 125.406 0.0419311 (V CD a C O r LID L.. II O 4.4 C, m F In �1 N 0 0 E co ELL 8 S C, O O a 00/4 O CL YJ O U Lis .L a-+ I O L OO/''� N ta r-. I I 3 O Il. Ca CD V E co Sd v) C) LL O O a Ct s re U- E ro I- L ll7 O Process Streams Flash Vapors to Fuel System 17 Composition Phase: Total Status: From Block: To Block: Solved TEG Flash Tank Solved VSSL-101 Mole Fraction Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane Jsopentane Pentane Cyclopentane n -Hexane Cyclohexane 2-Methylpentane 3-Methylpentane Heptane Methylcyclohexane 2,2,4-Trimethylpentane Benzene (Toluene Ethylbenzene ortho-Xylene Octane Water C9 do Ethylene Glycol Mass Fraction 20.2316 0.220150 69.9772 8.19663 1.08742 0.0333291 0.128957 0.00835730 0.00958042 0 0.000833633 0 0 0.00286814 0.001 06408 0 0.000136784 0.0105593 0.00202361 0.000137516 0.000309989 9.45733E-05 0.0843596 1.80832E-05 3.86432E-06 0.00442199 4.05196 0.000831307 0.567038 0.0892953 0.0118801 0.000274331 0.00194029 0.000140925 0.000192541 0 2.78375E-05 0 0 0.000112316 6.80134E-05 0 7.76627E-06 0.181724 0.0526835 0.00538624 0.0238344 1.33453E-05 94.7200 7.90169E-06 5.75801 E-06 0.292608 !0 Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane Isopentane Pentane Cyclopentane n -Hexane Cyclohexane 2-Methylpentane 3-Methylpentane Heptane Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Drtho-Xylene Dctane V'later :10 Ethylene Glycol Mass Flow 38.2531 0.264957 48.2301 10.5888 2.06007 0.0832255 0.322017 0.0259051 0.0296964 0 0.00308638 0 0 0.0106188 0.00458082 0 0.000671276 0.0354359 0.00801047 0.000627229 0.00141390 0.000464124 0.0652930 9.96418E-05 2.36218E-05 0.0117917 9.20363 0.00120192 0.469494 0.138578 0.0270373 0.000822934 0.00582043 0.000524765 0.000716969 0 0.000123811 0 0 0.000499541 0.000351737 0 4.57862E-05 0.732616 0.250531 0.0295131 0.130597 7.86774E-05 88.0704 5.23049E-05 4.22833E-05 0.937347 Iblh Ibfh Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane 2.35649 5.81863 0.0163220 0.000759865 2.97110 0.296819 0.652295 0.0876108 0.126906 0.0170933 0.00512690 0.000520268 0.0198371 0.00367974 Isopentane Pentane Cyclopentane n -Hexane Cyclohexane 2-Methylpentane 3-Methylpentane Heptane Methylcyclohexane 2,2,4-Trirnethylpentane Benzene Toluene Ethylbenzene ortho-Xylene Octane Water C9 C10 Ethylene Glycol 0.00159582 0.00182938 0 0.000190129 0 0 0.000654144 0.000282190 0 4.13523E-05 0.00218294 0.000493465 3.86389E-05 8.70998E-05 2.85912E-05 0.00402221 6.13819E-06 1.45516E-06 0.000726396 0.000331762 0.000453276 0 7.82749E-05 0 0 0.000315815 0.000222372 0 2.89465E-05 0.463168 0.158389 0.0186585 0.0825647 4.97407E-05 55.6791 3.30677E-05 2.67319E-015 0.592601 Molar Flow Ibmollh lbmallh Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane Butane Isopentane Pentane Cyclopentane n -Hexane Cyclohexane 2-Methylpentane 3-Methylpentane Heptane Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene ortho-Xylene Octane Water 39 310 Ethylene Glycol 0.0535450 0.000582650 0.185202 0.0216932 0.00287797 8.82089E-05 0.000341300 2.21185E-05 2.53556E-05 0 2.20630E-06 0 0 7.59085E-06 2.81621 E-06 0 3.62014E-07 2.79464E-05 5.35569E-06 3.63951 E-07 8.20419E-07 2.50298E-07 0.000223267 4.78592E-08 1.02273E-08 1.17033E-05 0.132213 2.712501E-05 0.0185021 0.00291365 0.000387641 8.95127E-06 6.33104E-05 4.59830E-06 6.28251E-06 0 9.08321 E-07 0 0 3.66480E-06 2.21924E-06 0 2.53409E-07 0.00592954 0.00171903 0.000175750 0.000777701 4.35449 E-07 3.09066 2.57828E-07 1.87880E-07 0.00954764 Process Streams Flash Vapors to Fuel System 17 Properties Phase: Total Status: From Block: To Block: Solved TEG Flash Tank it Solved VSSL-1 41 ISM Property Units Temperature Pressure Mole Fraction Vapor Mole Fraction Light Liquid Mole Fraction Heavy Liquid Molecular Weight Mass Density Molar Flow Mass Flow Vapor Volumetric Flow Liquid Volumetric Flow Std Vapor Volumetric Flow °F psia °la Ib/Ibmol I b/ft^ 3• Ibmol/h lb/h ft^3fh gpm MMSCFD 90 72.1063* 100 0 0 23.2760 0.288553 0.264661 6.16025 21.3488 2.66167 0.00241043 210* 13 100 0 0 19.3755 0.0353071 3.26294 63.2211 1790.60 223.244 0.0297176 Hello