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Home My WebLink About20132940.tiffEXHIBIT INVENTORY CONTROL SHEET Case USR13-0042 — AKA ENERGY GROUP, LLC Exhibit Submitted By Description A. Planning Commission Resolution of Recommendation B. Planning Commission Summary of Hearing (Minutes dated 09/17/2013) C. Planning Services PowerPoint Presentation Don Evans — Hill Land D. Services, Inc. Emissions Application for Additional Equipment Don Evans — Hill Land E. Services, Inc. Sign, Noise Abatement and Lighting Plan Don Evans — Hill Land F. Services, Inc. Corrected Sign Plan G. H. J. K. L. M. N. O. P. O. R. S. T. U. V. W. 2013-2940 �una'''b.�Ir'✓� '.a%:3if.; `�/.,H Z a I. • • ♦ tf zis g. t • l r. -- _ • 1: • 1 1 r 4404. • .t • •r:c.6 --- '! ,• 1-- — 4'r 't • as. it .4 „ i F- 0 0 LLB d} L.U. C z 0 z Q CL Iii Karla Ford From: Chris Gathman Sent: Wednesday, September 25, 2013 4:06 PM To: Karla Ford Subject: FW: Air Permit Application / Aka Energy Group - USR 13-0042 Attachments: Aka Air Emissions Submittal Scans.zip Karla, This is a zip file so I am not sure if you need another version or not. Sincerely, Chris Gathman Planner Ill Weld County Department of Planning Services 1555 N. 17th Avenue, Greeley CO. 80631 Ph: (970)353-6100 ext. 3537 Fax: (970)304-6498 Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. From: Don Evans [mailto:devans.pfs@gmail.com] Sent: Wednesday, September 18, 2013 2:32 PM To: Chris Gathman Subject: Air Permit Application / Aka Energy Group - USR 13-0042 Chris, Attached is the emissions application for the additional equipment to be added to the site. Please let me know if you have any questions. Thanks, Don Evans Contract Agent Hill Land Services, Inc. 700 Automation Drive, Unit H 1 Windsor, CO 80550 devans.pfs@gmail.com 970-227-9682 970-674-9120 Fax No virus found in this message. Checked by AVG - www.avg.com Version: 2013.0.3408 / Virus Database: 3222/6677 - Release Date: 09/18/13 A kA energy group.11c August 15, 2012 Attn: Carissa Money Air Pollution Control Division Colorado Department of Public Health and Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246 Re: Facility -wide Permit Modification (Permit #07WE0081) Gilcrest Gas Plant (AIRS ID: 123/0098) Dear Ms. Money: Aka Energy Group, LLC (Aka) is proposing to expand the Gilcrest Gas Plant by adding a 20 MMSCF/day processing train to provide additional capacity far the extraction of natural gas liquids (NGL) and compression of natural gas. A 40 MMSCF/day amine unit is also being proposed to provide carbon dioxide (CO2) removal capabilities for the facility. Permit applications were originally filed for this effort during September 2010 (package number 247766)..A few design changes have occurred for the expansion since these application materials were filed, and Aka is therefore resubmitting a complete application for the project. Aka is also requesting that the APEN fees already paid for package number 247766 ($1,223.20 for eight APEN) be applied to this submittal. Proposed modifications to the facility include the addition of the following emission - related equipment:' • One (1) 40 MMSCF/day amine unit (with associated reboiler and thermal oxidizer); • One (1) Caterpillar G3520B compressor engine: • Two (2) Caterpillar G3306TA propane compressor engines; • One (1) regeneration gas heater; • One (1) 210 bbl condensate tank and associated load -out; • One (1) 210 bbl produced water tank; • One (1) 210 bbl slop tank; and • Additional valves, flanges, and other equipment associated with equipment leaks of VOC. ' A new molecular sieve will be used to remove water from the natural gas stream and an existing hot oil heater (H-770) will be used to provide process heat to the new process train. 65 Mercado Street, Suite 250 Durango, CO 81301 (970) 375-6405 - (970) 375-2216 (fax) energy group. Ilc Emissions from the proposed regeneration gas heater, produced water tank, and slop tank are expected to be below APEN-reportable levels, and the facility will become a major source of air pollution with respect to Title V thresholds after these modifications. Aka is also submitting APEN for the existing C-1, C-2, C-3, C-4 and C-5 compressor engines at the facility to revise the VOC limits and to apply a 50% control efficiency for VOC and HAP. (Each of these engines is equipped with a catalyst which controls VOC and HAP emissions, but no VOC/HAP control efficiency has been applied to these sources to date_) The facility will remain a synthetic minor source of air pollution with respect to HAP after these modifications Attached, please find the following in support of this effort: • Form APCD-100: "Construction Permit Application Completeness Checklist"; • Attachment A: A $1,070.30 check for the APEN filing fees;2 • Attachment B: APEN & Application(s) for Construction Permit(s): 3 o Form APCD-200 (General APEN): ■ Amine reboiler (new); • Natural gas burner (new - for thermal oxidizer); ■ Midstream condensate tank load -out (new); and • V-50 - Plant blowdown vent (123/0098/010); o Form APCD-201 (Reciprocating Internal Combustion Engines): • C-1 - Caterpillar G3516LE (123/0098/001); • C-2 - Waukesha 7044G51 (123/0098/011); • C-3 — White -Superior 8G825 (123/0098/005); • C-4 - Waukesha L5790GSI (123/0098/007); • C-5 - Waukesha L5790GSI (123/0098/016); ■ C-8 - Caterpillar G3306TA (new); • C-9 - Caterpillar G3306TA (new); and • C-10 - Caterpillar G3520B (new); o Form APCD-203 (Fugitive Component Leak Estimates): • LEAKS —Fugitive emissions from equipment leaks (123/0098/014); o Form APCD-204 (Midstream Condensate Tank Battery - new); and o Form APCD-206 (Amine Sweetening Unit APEN - new); • Attachment C: Emissions Calculations and Supporting Documentation; • Attachment D: Form APCD-101: "Company Contact Information"; • Attachment F: Form APCD-102: "Facility Wide Emission Inventory"; • Attachment G: Process description, flow diagram, and plot plan; • Attachment H: Operating and Maintenance Plans: o Form APCD-301 (Reciprocating Internal Combustion Engines); and o Form APCD-306 (Amine Sweetening Systems); 2 Fifteen (15) APEN are included in this submittal; Aka is requesting that the APEN fees previously submitted with package number 247766 (51,223.20 for eight (8) APEN, check #016858) be applied to this submittal. Additional APEN filing fees for this submittal are therefore seven (7) APEN x 5152.90/APEN = $1,070.30 in additional fees. Aka has requested an increase in the emission limits for equipment leaks of VOC (LEAKS -AIRS Point 014) due to an increase in the number of components associated with the expansion. Emissions from the plant vent (V-50, AIRS Point 010) have also been revised based on a review of historical throughputs and future projections. 65 Mercado Street, Suite 250 Durango, CO 81301 (970) 375-6405 - (970) 375-2216 (fax) AkA energy group, lic • Attachment I: Regulatory Analysis. (Attachment E is not required, as the net emission increase associated with the project is below levels which trigger air quality impact analysis requirements_) Please let me know if you have any questions regarding this submittal. Sincerely, r Virgil Frazier, EHS Area Manager 65 Mercado Street, Suite 250 Durango, CO 81301 (970) 375-6405 - (970) 375-2216 (fax) Company Name: Aka Energy Group, LLC Source Name: Gilcrest Gas Plant Date: August 15, 2012 Form APCD-104T1 Colorado Department of Public Health and Environment Air Pollution Control Division Oil & Gas Industry Construction Permit Application Completeness Checklist Ver, September 28, 2009 C:olorado Department of Pi hi IcHealth and bvirottment Are you requesting a facility wide permit for multiple emissions points? In order to have a complete application, the following attachments must be provided, unless stated otherwise. If a licatian is incomplete it will be returned to sender and filing fees will not be refit` Yes No 0 ❑ Attachment Application Element Applicant APCD A ADEN Filing Fees 0 ■ B Air Pollutant Emission Notice(s) (APENs) & ❑ ra C Emissions Calculations and Supporting Documentation ❑ ,, D Company Contact Information - Form APCD-101 ❑' ❑ E Ambient Air Impact Analysis NA, Attachment E not required ❑ Check here if source emits only VOC (Attachment E not required) d ❑ F Facility Emissions Inventory — Form APCD-102 ❑ Check here if single emissions point source (Attachment F not required) n ❑ G Process descriptions flow diagram and plot plan of emissions unit and/or facility ❑ Check here if single emissions point source (Attachment G not required) 1"_71 r H Operating & Maintenance (O&M) Plan — APCD Form Series 300 ❑ Check here if true minor emissions source or application is for a general permit (Attachment H not required) ✓ MI I Regulatory Analysis ❑ Check here to request APCD to complete regulatory analysis (Attachment I not required) ❑ J Colorado Oil and Gas Conservation Commission (COGCC) 805 Series Rule Requirements Form APCD-105 ❑ ❑ Check here if source is not subject to COGCC 805 Series requirements (Attachment J not required) Send Comulete A licatio t o. pp n Colorado Department of Publlc Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Check box if facility is an existing Title V source: n Send an additional application copy Check box if refined modeling analysis included: IT Send an additional application copy Page 1 of I FoneAPCD-100-AppCompleteCheckiirt-Ver.9-28-2009,doc Attachment A APEN Filing Fees Check Date: Ma I25/2012 Check No. 019660 Invoice Number Invoice Date Voucher ID Gross Amount Discount Available Paid Amount 052312 May/23/2012 00015226 917.40 0.00 917.40 Vendor Number - Name Total Discounts 0000000834 State of Colorado SO 00 Cheek Number Date Total Amount Discounts Taken Total Paid Amount 1119660 Mayr25/2012 S917.40 $0.00 $917.40 A �4A . M1• Do not cast? It the word "V010' appears aryva,;,:rt• t;.. AKA ENERGY GROUP LLC 65 Mercado Street, Suite 250 Durango, CO 81301 Phone (970)764-6650 General Disbursement aouidJEsappea,w1en,ur Comerica Bank Houston. .1X Date Mayi25/2012 Pay Amount $9 I 7.40k Pay ****NINE HUNDRED SEVENTEEN AND 40/ 100 DOLLAR**** t o The Order Of 019660 32-75/1110 STATE OF COLORADO Dept of Public Health & Environment Air Pollution Control - APCD-SS-H I 4300 Cherry Creek Drive South Denver, CO 80246-1530 Two signatures required for amounts overS25,000 OOL966OO 1: L L TQQD 7 5 31: L88 TOL18 7 L 2ii' Check Date: May/04/2012 Check No. 019555 Invoice Number Invoice Date Voucher ID Gross Amount_ Discount Available Paid Amount 07WE0881 Ma /02/2012 00015082 152.90 0.00 152.90 Vendor Number Name Total Discounts 0000000834 State of Colorado S0.00 Check Number Date Total Amount Discounts Taken Total Paid Amount 019555 May/04/2012 $152.90 $0.00 4152.90 On lint rash ii the w rl "VOID" appears anywhere an the check. The led Star at lower loll shouloi disappear when robbed. AKA ENERGY GROUP LLC 65 Mercado Street, Suite 250 Durango, CO 81301 Phone (9711)7M-6650 General Disbursement Comerica Bank Houston. TX Date May/04/2012 Pay Amount 51S2.90"'* Pay ****ONE HUNDRED FIFTY-TWO AND 90 100 DOLLAR**** To The Order Of STATE GF COLORADO Dept of Public Health & Environment Air Polluxion Control - APCI]-SS-131 4300 Cherry Creek Drive South Denver. CO 80240-1530 019555 32-75/1110 PIP Two signatures required for amounts over525.000. Hip E 5 511' t: L L L0C:1d 7 5 3i: 168 to L.Ei L 2H. Attachment B APENs & Application(s) for Construction Permit(s) Emission Source AIRS ID: 123 Permit Number: ire W -J 0 m Facility Equipment ID: Section 02 — Re Section 01 — Administrative Information a❑o r 13472 Weld County Road 40 Source Location v Lt n 00 ZIP Code: 61301 65 Mercado St., Suite 250 2 O O 0 970-764-6661 Phone Numbe 970-375-2216 z add amine reboiler to facility -wide permit - Section 03 — General Information O CO :J C .} .C ,,. a . , 4-Y, > _ 0 • C 4.. te a E w E 7, V ^ - C C —❑� i C ., C C v o, F. E- '+ ea E '7 ,-• -,.:. ........—z •Tal. en .- a- Es a a g OOc. �a R V1 _E .C < .7 u +4 0 ,a te, - e J. ^ en C VI L .J - ` re,'- 6 rn O S h r�a E c 'e •0 =-_a, y 7 : o, L 'l V, y C .= ^ f t J W a v J a r 4W c 3li r y � `�, i r r. V L J a :1 U t� T 3 R t C' C C L �I APEN forms: Into://wv, r tl a C C C, C. C. fi O O ment Information & Material; Use Manufactnrin Section 04 — Processin ci Manufacturer: e I75 2 C y-' 2 y L a. U g u SCi C. .c 'C n. 9 O a. C C :i U• ti er tr L L G G X O 0 .O o u U ADEN - Ver v-1 Q-2U08.doc Form APCI)-200 - Gene FORM APCD-200 0 a a a Emission Source AIRS ID: 123 F 0 a e 0 e. a 113- 2 in as U 1. 0 a U r3 c 71.3 .y N eG td _ U g I 0 LW e, O a is _ { co fI� v a` cv W 4016'31"N 10448'15"W vn 2 a OG O 44 T. -'' _ O � E M1 nit Wiz°o w O CO w ez Direction of outlet (cheek one): merit & Fuel Consumption Information Section 06 — Combustion E 0 z U 0 H 5 2 Identification No,: Amine reboller 0. E 0 C.≥ 0 w 0 2 co) 0 lL to e6 CA .0 rw 0 0 0 O 3 7 .� 1040 Btu/SCF U v N L�. crI O m 2 r a (7) L Ct O a I A E E o - ! a c 7- r.• 0 a — V - 0 `. 4 N 0 Rl A a u W O g °ate Br C •r.. ._ W _1. 0 �. y aAim o.n t 71 .... t� E a 8 a n 0. O 9 0 E O t1 of -5C L to 0 cl y. y C 3 0 u J E' . g a a J o I u Sectil i N .5 .. ¢ AP 42 AP42 Q < '7 4 V Q Requested Permitted Emissions'° Uncontrolled Controlled Tons/Year) (Tnncli.arl I { O o p p to o u') 0.5 u) uo S r-- ' ti O G O tt0 D ui e T wnuve tc.a. c,niil: I Actual Calendar Year Emissions' Uncontrolled Controlled (Tons/Year) (fonsl'Yearl i I. .... ....., .nnln a ,usuuKut,u, Emission Factor Uncontrolled Basis Units U co IblMMSCF lb/MMSCF IblMMSCF IblMMSCF 0 ,rn c G 2 Q `a • 84►Ib/ Please use the APCD Non -Criteria Reportable Air Pollutant 'Annual emission fees will be based on actual emasions rcnoned here If left blank annual rmissenn ID to CO (0 0 t() t: N N O O t!) U - L w Y w v° — ld OO . U V J v Control Device Description 3 CAA 2I a i '2' f. a EC u U L d 0. 0 v VI 0 5 j4 .0 .0 E VI S 0 E w W U U 4 b a S U v 4 U m .0 r C Section 08 —Applicant Certification EHS Area Manager 0 a I ci Z w ci w L I- O z z O -. — E C w .2 I Z E O J � J v • rn a `O • v w J > CO O CI w w U /+�1y V Z AIRS ID Number: 00 as 0 LLI Permit Number: Aka Energy Group, LLC N z a C's 0. E O Zip Code: 81301 13472 Weld County Road 40 Plant Location: 970-764-6661 Phone Number: LL 5 Person to Contact: vfrazier@akaenergy.com E-mail Address: Uncontrolled Actual Controlled Actual Emissions (Ibsfyear) Emissions (lbs/year) 103 103 In © co T I L) C CO ri 1 GRI-HAPCalc lG a' r C7 Emission Factor (Include Units) 7.38E-04 Ib/MMBtu co 2 2 .6 0 LLJ c0 Q N. 8.44E-04 lb/MMBtu Control Equipment I Reduction (%) c N I A Chemical Name acetaldehyde benzene formaldehyde Chemical Abstract Service (CAS) Number 75-07-0 N N- 9 O C to Calendar Year for which Actual Data Applies Reporting Scenario (1, 2 or 3): EHS Area Manager o Supply Data Co N 0 Title of Person Legally Authorized to Supply Data O_ Co Co A (5 0 T d a O V N O 3 l5 rn Co J 0 ✓ Co (5 • LL Co CO > z December 4, 2006 Form Revision D CO to O � TOBURNER C, 3 O. Ch A .Q N W a a J c a. t d e a A a c _$ s r EJ 44' o ,� a a .a E w a v" u a g 2. d O 0. C. 7. .8 a L. w Q A S ' 4 s a 'Y 0 .= e v 2 E a a 3 a J e ° s. Z a = a a T.: € 2 O £ a o C E �, ;r4 e a a aq c!d boy g a• a 0.f y d fir. 3 V = O a>. E so LA F -.IA d 0C O z Ci, W p o r Li 0 P a a a. 7_ s 3 Q$ n u e�1 d .04 7u`. ... aC N C+ a a �' Q C0 X . ae ❑ ❑ = rx ❑ ❑ ❑00 O til Section 01 — Administrative information Q 13472 Weld County Road 40 �i.. a 0 LLI a LIP tide: 81301 Mailing Address: Q vfrazier@akaenergy.com E-mail Addre a. a a m O N 0 a E H a a a a aW O a d C Z Section 03 — General Information U N a 7 ti t. a I N c, O a -a a U 2 oo O c N LQ- CY b .Q 0 N 72. E- E a U - � � E A. a L J , H " - or a 1774 a E. Z a v '4 r co .2 E a _ 8. n .0' cc r 3A A AC 17 u>, E h ^J MMn G .7 L.a •a ¢ MK O F R• - C a+ L- a L GO r in �..'.] rL. R V isl O .3 crsZ 4 @ u v' G U L. . = a ! y? :J +° a v as r ^ Y : a t v - -, ,- - a on g J 6G W g.e _ v _ rs e 2Gc-+ v 7" a -2 b 7 0 V O G 0L G :17 - K c, '� 0 6, r�,.y y a a y7.u�l-rO L. n < C r „ O merit Information & Material Use /Manufarturin Section 04 — Processin a a z a C U". •1arnilac3urci- T y a .v 0�4 L tl 8 P C p 53 . j O O C. c. d . aa a a 3 3 << a� E 0 Cr ' 6 c .O ,p7 u u U U ❑ FORM APCD-200 0 0} O L M O 9 G Flu a 4 V In C C 'TJ 64 z C' C64 .st a r do A LJ z 104 48' 15" W O h7 z Z A d E E C G C rtl ro fas v E w �, v TOBURNER A U 72. O ti U C .C t O Direction of outlet (check one): Lion Information nient & Fuel Consum Section 06 — Combustion E in F M;uiufacture Company equipment Identification No.: eJ r3 ,17 a 0 cc 6L , 1040 Btu/SCF E g i 2 c0 CO 43 s CLI 6.05 MMBtuihr rn C 4: L 7 a Y 1.11 c O Li t C n O 7, E 4 E ° a k r o Y CU C 4 E e Q C II (f C C C U E O U 0.3 0.3 AP42 AP 42 AP42 AP 42 a < v < . . Requested Permitted Emissions'' Uncontrolled Controlled (Tons/Year) (Tonc/Year) 6 O 0 4"7 o N min G O O a V rri N q Cr, N u ,+ z x fa �c.�....v,r- I Actual Calendar Year Emissions Uncontrolled Controlled (Tons/Year) (Tons/Year) Emission Factor Uncontrolled Units Basis U. ILL k.' U.. U. 22 a 2r .O 2 .0 2 .0 2 a c0 40 4.0 tp o n i` C. C' I 'U :Von -Criteria Reportak nn.vi h... ti'i r. Lin..t ...,...... Control Effciene (% Reduction) • o u IU :t oO.. U ':J LU Control Device Description F, v 417 E k Pollutant a. s -C. E; aa z r. di I- a a z Section OS —A G. Form APCD-200 - General ADEN - Ver 9-10-2008 doc 2 W O O W! I- a z z a - CO (0 W • .P H °} ZE E 8 o • c J J -a a= CZ 43 Ja, CO 73 liD VL O O. W I- 1 z O z CO 0 C N AIRS ID Number: co co a W N- r< Permit Number: Aka Energy Group, LLC Zip Code: 81301 'O } C O 13472 Weld County Road 40 Plant Location: CD CO co CO ti ti CA c Q E z v O Person to Contact: Virgil Frazier CO N UI h C) Q ti C Fax Number: erazier@akaenergy.com E-mail Address: I 1 CJ co Emission Uncontrolled Actual Factor Source I Emissions (lbs/year) GR!-HAPCalc 52 o i ca U a a U' I Emission Factor (Include Units) 7.38E-04 Ib/MMBtu 7.48E-04 lb/MM8fu 15.44E-04 Ib/MMBtu Control Equipment / Reduction (%) I Reporting BIN A Q Q Chemical Name acetaldehyde CD CD N c cli formaldehyde Chemical Abstract Service (CAS) Number 75-07-0 N cam) 'To N- O O CO Calendar Year for which Actual Data Appli O CV Reporting Scenario EHS Area Manager 113 N C, U- 7723 Title of Person Legally Authorized to Supply Data all N Ui Co Cl Q Q. {I) O Q- ) N O i 0) a) — J C O O z Form Revision Date: December 4, 2006 co O O C7 N u 0 COI W ckt A 4 on � X r. a m LucD2C Permit Number: Facility Equipment ID: Y H Q C. C. 11 O co j L a O. i '''. sf 0 d ?•S Gr 0. yil 0 ca O. C .5 7 u G , Cr 41, ria 441 .r Z L`. 4 C AO LI .g F t F .a 4 04 t u Com 0. w o w a c s 8 Di 3 i r W d 6 u 1'.. Y - C !� L' C C I. .� .. �' m y L�7 C C U V G `o9 PI .N w o< o ot wa Fii Q. y t . a '� n I. d C C • is 9 Qi 4. 9. . .C .C. < ari 0. C. A V D L C+ Cr I • 41 41 u a a =el Cr Di © a Cr a ❑ ❑ a oc ❑ 71 ❑ c et c al ri❑0 ❑❑ <°z Section 01 -Administrative Information 2. O +u UJ Z in a oc J 0 ZIP Code: 81301 0 U N 0 CA C O rn s 9 z z z L Person To Conlac 970-375-2216 Section 03 — General Information N C 4} g - v = C ! v G 1. j r F. .r C a C .C C. E '7 M. J 4 ,ci - L C Q L. ` a C R ,.F,.C C o -.- ee 8 u r.j LL1 W:7 E'c-n mo br°i ≥ = :�., v, e ... y '- L J 1. .S Y . e L. E e u r y - �' C D_ L .� a C ti/ _ = u .G S e E a = h v }'c C E �v a r- a E a_'- a u a� �p?1 C^ a 0 a' o a ..+ 4 •" o t. M v u 2. '.d ti m — _ Nen CO ch - aC CA . v } r ^ 1 - ,A 7 - J h z >. C3 ment Information & Material Use 1.4 Manufacturin Section 04 — Processin 6 C J c a • C Z Menutacturcr: .0 a C> M 37,906 bblryr condensate C 174 3 " .7. C Er c5 - C C 2 V :J L200 - General APEN - Ver9- I b-2608.doc c L2 N a 0.1 FORM APCD-200 ,30 O 4 Emission Source AIRS ID: 123 Permit Number: 07WE0881 O aD dpi •o ozo 0. �rr C r 0 N m 'v 9.3 1131 10. 3.3 3,5 _ d 2 sea ✓ Ce Gv o 4 e I f W 0 p. I (D 631 "4- J y. g D Q �y v O. v 1-" C e 2 rn A o O O J 0 4 c ❑ 0 O 0. C C 3C c A 0 ❑ Direction of outlet (check one): 1 0 C tion Information meta &r Fuel Consum 0 Section 06 — Combustion E C w J Manufacturer: Company equipment Identification No.: 5 .0 ea Q zc, .L C v 0 0 17. A a A 8 ✓ AP -42 Senior 5.2.2.1.1 M U f0 v 8a w a U j E. T l c O _a O wd c E . 1.1 HI 1O C C D 4 C 0 D. 0 y ; v .14 d a 1 ^. o w a o Ctt '7 to O _ • . 9 {e C CL — 3 '} E C C 0 O E a J C orA - = N G = d Sr 5 O 0 .s3 4 Lt: j I co cc ▪ g Er FC 6 .F., Y rn Emission Factor Documentation attac • E y g C C 3.3 g C. c U m C N O C o G e o C L u Li Ce ;tee O v L. y.J O 6 Control Device Description C vU'.+ C d _ 0 ▪ � 3 � • Cp R s � s S1 Y 4 ▪ C SP L 31. L C -E To a EHS Area Manager F= romi APCD-200 -General ADEN - Ver 9-1tf-2008 doc z w 0 w 0 in E z O ti) E w"' I— ZE U J c J a a. `o c } cdl O 0 w CC t w I rFE V a z CO 0 AIRS ID Number: CO b C O Permit Number: Aka Energy Group, LLC Zip Code: 81301 m C 0 U 134721 Weld County Road 40 Plant Location: 970-764-6661 Phone Number: N LL Person to Contact: ofrazier@akaenergy.com E-mail Address: Uncontrolled Actual Controlled Actual Emissions (Ibslyear) Emissions (lbs/year) 1021 1na1 Emission Factor (Include Units) 2.69E-02 lb/bbl .e M 0 U',.) NI M Control Equipment I Reduction (%) Reporting BIN C Chemical Name hexane a) C a) N C L Chemical Abstract Service (CAS) Number 110-54-3 N R Calendar Year for which Actual Data Applies: Reporting Scenario (1, 2 or a) a6 horized to Supply Data EHS Area Manager Title of Person Legally Authorized to Supply Data C Q m fn aa cL CU Q Q 0) V) 0 4-I W N I O t 445 Ta Oy a) J C O a) 0 Z Form Revision Date: December 4. 2006 o a. L 01 aea C �I o o V0 > V •A e 3 a N V C 2 Q C E 7 _•L F W t-', C a_ Wo E ti " 0 � H y ria S lr PA a 14 O 44 r Z COS Il 0 LE 6 Q G • O' Lu cE I.L., [Leave Permit Number: G a T 9 A D ts o a O. y_Ta * c 4Y Oc. us g G 0, u . ?� u a '- G .a s a _ a , I- 2 v E w •E 9° =€ o a a 9 w la LP 1.7 .. d 4. g E �. a °' v �, 'g+ 440 •e o 5 10 d € y' `..: x t a * e ', G ,M. W .. a ❑ ElR $ -5 fJ L •y0 .0 LI L r' O O s _ 'U •E a O o IC V1 Y ' — 1 03 n 4 L .. g ZZ. G o o., tf. ..c.y -., v c a. me Zv 7 r'l Cr Cr Cr Cr C a ce x❑ ❑ fx a❑ ❑ ❑❑❑ El El col Section 01 —Administrative Information c ©• GC 0 Z Col CO 0 GJ 0 65 Mercado St., Suite 250 Mailing Address 0 c) O C 7 970-764-6661 Phone Number: 970-375-2216 0 7 Q P C N re • 5 '5 J W R G - Ste"0 .m C 2 0.. Section 03 —General Information •0 0 E APEN firms: II ❑ 7 El c G t •rZ (F C LEI O Q E 6 G C E v 0 m O O. L f 73 6 7 4 L z A C L G , L � Q g •C •J • ' j 5 : 0Y1 E-6. CI Li z ment Information & Material Ilse /Manufacturin Section 04 — Proccssin `U U Manufacturer: o 5 3,500 MSCF/yr G R A Vl CO U U) QI C _C FORM AFCD-200 L rV E s7 U v r�r V 5 C+' O V1 L D4 o r% 7 E ao a. 0 co Emission Source AIRS ID: 123 E- 0 0.11 C v 0 U a 0 0.1 705 a Vs t5S V E . W pC O `a C C O o to `a a 104 48" 15"W oc E z - z e X P;. F C U, Ll 0 r.. O Direction of outlet (check one): Width (inches) = 0. !u u ate. y L • C O a 0 sme .O tin N, u u) ment & Fuel Consumption Information 0 Section 06 -- Combustion E u 0 0 Manufacturer: Company equipment identification No.: 0 4 g 2 Y .O Q U a a. r U 0. N, :J p 8 O s 0 J C L W C y L C C n a t y: E o C C p fI� c .7 .g .2 0 E -13 g C C Emission Factor C v_ a M C 0 0 0 1 o ij Control Device Description S r • z 5 3 C 0 v V Section OS —A EHS Area Manager L•7 a. 0. C C C C elf Form APCD-200 - General APEN - Ver.9-10-200$.doc N ,F+ O N U C�0 G. 4.4 a Internal Combustion En Permit O CO CO O 07 N Section 02 — Re Section 01 — Administrative Information v Y_ G w a ,„ aVI r L a a V 7 5 O G E d o a `c 0 a U o E _a - a � 10 co 4. .C c 4 C -E- .... in 0a .. G c r-4 .� e ti a g yy f O' 4 e C W 0 toE IA L le ", °' ? E.. a i c O C. J ' t -1.e 0. C. ,. a E E a 04 to at 4 ' ❑ ❑ E cu. 'D Z 6 ` r I. .= u k: Co co .`a C (� a C Y c ` o_ U 4,.. C ..j. C O c a A, E b e ,�, _a. _ O c - Z V. E 3 c o L y O ? 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U .F; U t. i :J 'J C co before 7/1/2010 U W 2 V c a U U • C U E A C r, c c z ine Information Section 04 — En 00 l9 EL tO C) Manufacturer: 00 U C G O i- O O c0 n ti N 0 O U U r C C 00 J i3 O U � ,U v1 - C- 0 I. �. . •c o. ai bb 0 0 000 ca r Q a a c .C 1 1 U :J C EJE c s e C I e < T U E C C � 1 % c a 3 U ;r 5 C a U ❑� ❑ . C O 7. N c, 'c s 0 CI 57 E U FORM APCD-201 Form APCD-20I-RICEAPEN-Ver7-27-2oI I doe fl Internal Combustion En AIR POLLUTANT EMISSION NOTICE Emission Source AIRS ID: Permit Number: 07WE0881 0 8 u CCGD g y a 0 .0 ca w m 0 C7 104 48' 15" W 4 O N CO CO r- ti 6 Width (inches) = I II 4 73 8 U CJ Direction of stack outlet (check one): Section 06 — Fuel Consumption Information ut7 N 4,1 g d 1.0 (NI :41±___F_L 0 N 4.1 0 1000 Btu/SCF Requested Permit Limit 86,4 MMSCF/yr El 'uel ratio controller? 7.1 G 0 N a V N a manufacturer d a al UI E manufacturer manufacturer N a GRI-HAPCale g (4. UI— O a 0) M 0 O CO CO 0) r` N CO .0 m M T a .0 tri SJ O C,) O o? 0 M O CO CO U-) R• - Ca N r U) Et CNA ,k .0 Emission Factor 4. 9 m DI .g 8 CO3 a 'Y go C C 7 s Li V g W a I 9 it --- d O C U.1 W cal 10I C0 0 a C .0 rl m m n L L 00) L .0 .0 L & c0 2 co n U) Uncontrolled Basis J O RU 0) 0) M Q W O) 0) 0 W 0) 0) Ci7 0 W U) U) U) 4 ' 0. 4 N a c CO U:1 CO C+7 Co CO 0 U] C w 0 ah C) 0 R a 0 U, E • oxidation catalyst Y) 2 0 m 0 u) 2 •0 oxidation catalyst 0 U1 U) CL L J C J C U U N C E ta , a. g C _v at EHS Area Manager C •a 2 N GJ E LL on o 4 O to n z j J J C r c r v) _c E ,n C C s = V Q C e Section 05 —A C C C .) C) U _ t0tl 0. O. co FormAPCD-20I-ItICEAPEN-Verb-27-20 I I doc Internal Combustion En O 40 171 nE v 4 Ism w i+ 4 7.7 +III W F V~'1 1 M [V Emission Source AIRS ID, CO lil Permit Number: O. cr as o C.7 A 0. a x z o © t, C a. _ NI Ct• i C 3. w x 3 w a w C9 y° Ea n J c co .O 0 V .0 C e •37e C .c en a E Y 0 c m n. A O _or 3 = .X C _ a Y. 6J •y C y ,.- yj E. c9 L., C E v O `-- c al.et 'd:.'E s' b ri s. C6 x ° r 0i. ea. 4D 4 .E 9 qua :r `u 3 .E +V d W 4.0 S. L C < - w C v V a a L. Z E e 4. C c •r. ° ro a� c c Z U R Cd E a g `:� O d v L. < v _ :4 a. > f 4 O. OD C L L v ° E m Q. 3 e 0 t�J. a p a 3. F.F z• o I /� yJ yJ L Y 6i it f �J V E U O L N =O. OO. OO. N d 411 41 !We IL ❑❑❑ ❑o El -. ° Section 01 — Administrative Information Gilcrest Gas Plant cu C O C) 0 2 c E x a. ZIP lode: 81301 O O Cn a 970-764-6661 Phone Number: 970-375-2216 J ..O z !ier@akaenergy.com Information Section 03 — Genera N -4 v C) - J0 d O. O o cJ Gel eel 4, ° v>(D [9 v N 19 V C S.r.6 "O ® E C N c� z w ea 7 U gt.O 0 e E ,Ni .3: tri .. •C .Q C C .° — 1 `� c (al O C. � O w - v u.. v a 3 , a = . v - 4E.V I. : . :J r L - c C. .. T $ = 4� i eC�ryi J C C tug v A •E Wi _ _ ah c •' a e a i w. a H_! pp 'r. v .'' 4.' y °P J t' O ro4� .g. -$r,,'g "'�_� ?C .C .R C y E ?..r .�C✓4-eC - <r APEN forms: h L U N t .OI 7 0 •n C before 6/12/2006 L z C before 7/1/2007 3 g C . va ea ti rp, 5 a i El 7 ea e. � 9 C v ine Information Section 0+4— En 7. to co a a a N 0) r- J before 7/1/2007 au dale of manilla M anu iacturer: DO ❑E C ^.1 C UI C :x7 0 LNI P- 6 GA N N E 0 O O tN Manulacturtr'n MA\ititian 0 0 u G s .� � F HE CO is' 3z ❑ ❑ C) a ° ° C c a E N c. s J J n L. E S C a O O .0 .O .x U ea LJ J U G O e 0 O. E E a C - < L C h ti G a1. E a U1.1 LEN Q .L D E cci G G FORM APCD-201 RICFAPEN-Vcr7-27-201 I doe Internal Combustion En AIR POLLC 0 ao 0) (04 C,? Co N Emission Source AIRS ID: Permit Number: I- L an ..-7 1- V C7 O O 42 • V i Lin 45 C1; Y g ma B L W 01 b O 0 z c) o 23 E Co I. 0 r C.) e- C,) CO z 9 �L LL. N U) Z o 1.1 A a C. C C v !! C U O O g 3 UCI >o a d � o 3 O L V eC g e. Q O a u ea 3 Section 06 — Fuel Consumption Information a I G N f cD C U) CV N ti U) N - 0 1000 Btu/SCF Requested Permit Limit 0 Nut L 12,850 SCF/hr 7.2 r.._ . [71 m 7 'a 3 3 a V C 3 a w Y. Information & Em Section 07 - Emissions Invent° Estimation Method M v d manufacturer E manufacturer GRI FIELD DATA a a N Q d N d n LU 0 E P 1 ii O O N Cg .v CO 0) a0 G "— N N CO cc! h a) - so Cl a. a a v}05 CD CO N h CO Emission Factor Documentation attached D Actual Calendar Year Emissions 3 m 2 S 2 S 3 03 2 3 S L e1 s co) L e1 0) 3 3 L L m m a a 2 L JD _ S rn rn.a a P-- 06 3 co S S a Uncontrolled Basis N O 9 LU N C3 w O L3 23 23 U() O CO co {Q CN CU M 9 a) a 3 'U . aV V' or) u) 1.0 c e v 01 en in c G :5 Li a S�1 I C LPL. C, C!) z cc U Ch Z CC CC Cf CC C.) o V LI CA CO CO CO ZZ Z Z S cc Z EHS Area Manager FnnmAPCD-20I -RICEA PEN-Ver7-27-2Q l I .doc .71 t4 U _3 I- n 2 a u., C 0 a 'O .4 0 G V ei u u c. d N = 1 a E a C � 3 (c 3 OJ c • that this source is E - Person (Please print) Internal Combustion En Emission Source AIRS ID: a. a a N a ,d7 O ti a a -a U a C a Cd a a a i C -a a V C. w u• Ct v a O .0 L. Cd .a a O. C. u w Loa V a a C Le) Section 01 — Administrative Information to J a. a as 'Q y a; e. a a a a II a 4 •b a a .0a .c c Y a . a E r oa a Y a V - .a J a kf Ca. 'E a a a. e • CO 7 Ole: 03 - -a lC. a - .0 E a C. vI u 1 x r L .... V 3, a is 'r 2 a t W v v W = D a a' a' Cr re cc x ❑ O ❑ ❑ ("7 D a vs o UL .z L!7 J ti O 0. 4 CJ Change permit limit a a a D a M. Y L iI Q C • a . a C To a14 .a .0 ar = 3 a u Ib! TOQ a v hi, a a 6.. u U ha. ZIP ['ode: 81301 tfS 44 3 UJ 0 U a 2 (0 sal CO -a r' D CJ E < i x ._ O C.3 D C a 970-764-6661 Phone Numbe a U- C, - R a a 3 a -a V m CA c. •E a c L , < 1.-.. C1 C 1 u 1° U1.1 E o 9 C Vi Q C V C., L. O 4 oE a a Q aL L } V t44 M C ti ❑ r, �'= 970-375-2216 Fax Number: vfrazier@akeenergy.com x 7 a Section 03 — General Information a T N I Cd U A a N - a a N 1- a L - c E 0.t � oz�n �ntrrs L. < r•. r+ r� r t o r`J rV Pd 1.. t Q' •"�. -a i U 0 j 0. C. 2 L^ ;a At a = it i V = E .. = a ben.`..1 v L . b a o In r•: rs F cd u_�? r •L y ,C U C a z "" r :O A L s= a v - C r • ., a - L .. - ea D - r u �p �;q v u _ 4 .c ..1 VI rn j .. a-, Col Ch. C '44 Z4.4E -a 4-. } C x 7i .r co -, -} j j $ w L r '. c t v E i e ,3 - a A 7 �— 3 .C a L Q C G- c L o c a.. aI a co to ?. L O J „ I L ,to a D G .-. G L v F o _ .0' 'a . ` -d a W c � r -` ..... 4 c G: � u a— Z `ro' ' y 3 w; 4 a C `I G L a, before 611212006 a E a C ^� V E ta 0 a V5 a4-4 :! J L J R } a 0. u C. E o " CaT S (p R a a ,2 c J C ❑ ine Information Section 04 — En V CO IC C C•• a CI 7L NI 0. i/: a D ❑ a - a 11 C L aLO a a CO J O w - V 00 before 7/1/2007 2 White Superior ❑ ❑ OO O O 0 -14 C. 0.r O O ca co Q O O w FORM APCD-201 FormAPCD-20 -RICEAPEN-Vor7-27-20I I doe fV a 4.3 C. Internal Combustion En AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Red U) O O Cn 0 C'7 N Emission Source AIRS ID: oc a W Permit Number: W O) O z Co a 1044815"W r C") co Z a v h C 8 G El r N V C9 U Width (inches) II is ❑ Circular: Inner Diameter (inches) a C C Con U. cot ea) 7.5 c G:: C CC E C Section 06 — Fuel Consumption F C) Seasonal Fuel Use (% of Annual Use) C z U. N t C CC) N 2 1. N C) C U.) N O 1000 Btu/SCF Requested Pemtit Limit 50 MMSCF/yr 5660 SCF/hr LC C) CO c z Section 07 — Emissions Inventory Information & Emission Control Information 0 Estimation Method or Emission Factor Source AP42 AP 42 N a AP 42 manufacturer ` U Es G c. manufacturer I GRI FIELD DATA I AP 42 I AP 42 AP42 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. • VI y G a.•a • u aF Q' C c CC J ��. • 0.48 O O- r NiC) 684 lb/yr T 65 lb/yr , C) "a r e c ci p. C i. .J z d o V O Q o O m R N • C\I ti T co C'} '0 a p} .,- r I` W U i) 0 O g C.} I.- •' g C C E '-- d . 6.g rc a . C Ib/MMBtu Ib/MMBtu Ib/MMBtu O CO .3 t Q a .C a m _ L a o) g/bhp-hr 1 lb/MMBtu _3 CO 2 a 2 CO 2 = •c S C 7, o ku Q) Q 1 W Co Q LU cra o UJ CA UJ Q - v, O C) — T O Cc) W i4 a UA N CO a W Control Efficiency (% Reduction) `'• C7 CO o CC) _ 72.7% CI in ` Cu, Q U3 °J°()5 Control Device Description c ✓1 Primary L NSCR rf Z cc Z NSCR ix Z i:C Z cc Z Pollutant 2 7 0 CC C•:-'• a 'a t ;,.. v v C c v ','-, "pi _C CC _ C-) U. r O . ot 1'4 J ▪ C • j ,• J C 'C C • Ci 3 C G - C.) C • J ii _ 'lu :J • 74 J CO y r C r vi r. C7 ; 'J 0_ C C CC a+ d 4 C 06 0 C 0 b €HS Area Manager N LL C) O C�� L. C tol y C it .. CA 0 C CU J ..1 CC z FormAPCD-201 -RICEAPEN..Vcr7-27-20 I I .doc C N o. Internal Combustion En Emission Source MRS ID: 8. a Po a 0• Permit Number: tia 0 ea 61 u 7 4) a N U 5 I- c = o aa. C W 0 3. Z e O a E N = 4 O s. U E n �>^ qn I.3 = d 0. 5 1 =' O ® d o r C C. e 3 otz c 511 ea 0 r Y 3 3"5p ai FIrwi u.C. L ' L L �.r U Y .4.. ��" o 6 z E12 = � -3 a a c� V Pr 0 G 1. it d 4� Si m = Q y. C C D. go.— 4... C M g 0.. - '5 C E 41i 4 d a I 5 14 7 3 = 14 0 ci 91 CO aax❑❑aa❑❑ ❑❑❑ DO M T roLy 0 , V U CA 0 Gi!crest Gas Plant 7 U .c ZIP Code: 81301 65 Mercado St„ Suite 250 970-764-6661 Phone Number 970-375-2216 .0 E z ea LL Section 03 — General Information Ta O a 0 8 0 U) 0 N A Y N In U Y A C G o • E C y a = E cc. L y• - i c u i. e 7 C P — Y 0 'J o C <. U .90 tie to a c m o v`, v I-, Z u 4 — en M y o N N 0, 7 r G ..ti .. ^ ?+ a a cco a --u 0% C 4 A - > g o L G = a ; Vi L u e r ai e © - z a, f o r �� < �.— f c cei _v — CC el.v v v O 0. eC - - L.! Ili a CI 1 d E 4 _ 7 W L �' >' ^ 8 C J 7. Y o C u e c' � oot!' t,.' t,.. � r p 0 v y+r. �f i - ? . ,C wi 0 •� �p a L e m y ' i. v N = `„ .h L > pQ > C.0 ` — Li X.' A WI. " am.5 Cii. a. before 6/12/2006 C J E a C U i — co 0 N CO before 7/1/2007 inc Information Section 04 —En II aft before 7/1/2007 Manufacturer: 2 2 0 0 N r 0 0 CO 0 N N s a 0 ID E •J' co az ❑ ❑ Combust ion CS E. U C 2n .0 e, 0 0 0 0 0. m. C 4.0 a4 L C.- — 1 _6 ❑ 2) 0 L m v J 0 t `a I {3 G Internal Combustion En LC 0 t C O 3 L. � m r y 6 E CC 4z a 't co d N. Q L UJ U E7 z ZD O 104 48' 15" W o 5.1 co co Z o2 o< M U) O. U F O T E 9 Q U) N M1 N 0 VS C w C • _ r� 8 a cn N C N ILO N {7r N ci co o 1000 Btu/SCF n (gal/yr or MMSCF/yrl a E C u C 85.2 MMSCFI C O C L g rtl Pr ee v C U. 9720 SCF/hr I 2: or 2 .C.. c ❑ C O CI 2. 7. C O CG a74, c i C c C C rn 71 e. O C Lid U I na a) z Estimation Method (V 0. N O. manufacturer manufacturer manufacturer GRI FIELD DATA q 'V O < < d 0 e CO c C .c J U) 00 0 a? co 0 C) 0 N 0 N. d 1• .b M ✓ co 0 M co O d O cri N N d ca) 61 C') a) co M N on attached Emiesion Factor Document Actual Calendar Year En issionsi C} C a m 1-1 C m L fl s Cr) 4 L d a C) cc O L L L � a a D co 0) O r QC 0 r 7 CC LCI 2 .o r` cd _J m Uncontrolled Basis O v 0 N 0 W W m co O O ti CO fV iV c) O Ui 03 CC 2 e 0 10. rs:'yf e e aC. Control Device Description a C) 0 C) z cc U to z C Cal rt U rn z U <n z U U) z re U N z C a. ,N - u tea. U J U C G U C Y • 'm L ers � ▪ L fj C 7 c sC $ C 4r r ^J C C U c •. aq c J CO b r Q 6. a+ �_ Cin v EHS Area. Manager .13 N LL FormAPCD-201-RICEAPEN- Ver7-27_20I I doc N 0 N n, 2 C. Internal Combustion En C7 Emission Source AIRS ID: cat OO LU S0 O Permit Number: C 9 a aQ s "3,„ 0 J y 53 E 0 r a J a c 0 U LL a Section 02 — Re Section 01 Administrative Information N G CO a = Y v o d V £ y L 6 :".a Q '� = = v a 0 c o e. EE °' 5 G °° 7"'-, 4' O C a �C P Ti E 'ii aVi +'L+ J C L.. = E- s u 'L. 3 L. T e `" c z C W .SP1 L. a qi- t 0_ E a SP, C. 0 0. 5 :,c o i C g C G % . L u i. 3' a v ;.4 r V C V N E V e b Z E 0? a 4A 12 '� 'O 0 G = o .0 .E C 7 �,. C O.z 7s c. v 4, o; 0 - i4 CO 7< .0 cy CAcc -�, €0S C M b y r `-. 0. F Z = c s, i O cs A. C A. ? u Y C E u v u 0 Ca 0 0 7 Aka Energy Group, LLC 4° c c v, Z C o O � G' r t1 ❑ ❑ ❑ ❑ y J ZIP Code: 81301 0 C C I, 0 970-764-6661 Phone Number: L 0I U- 3 C e V 4 C. CCi C E N C0 O CC 'd , 'C C J ❑ < 4 Z 970-375-2216 Fax Number Section 03 — General Information 0 Q 2 U J O C 8 O u) O 03 v 3 R Q rn >-. E C C C C C u :,. Ei 0 C 7 C a. C E C 4 Y o " c G — c 0vtrt h vi N N N E CN C' b o C C M M f r 0 U L cC v- APEN forms: htt u n C C v C Cl r Y C0 C3 N O C .0 C C C C 2 1.7 before 7/1/2007 O z •J CC C Z .G 77, E.3 a G. 7 J' 3 7 � Inc Information Section 04 — En :J T c� U E Z 2J a a La A s a d C —c V, 1.0 O before 7/1/2007 2 Manufacturer: ❑O ❑ 0 I.0 A. O O N Ct> N O O CA m 00 .� tV a OO Combustion: C. C C > C . •� L O t 0 C N C a C E C C C u C, FORM APCD-201 Internal Combustion En Co co O 7 J L O d 'q CI Cy N .C y r • E r ' .-% E t > 4+ L C~.. a 0 Q O O CI 0 h cot ▪ 44 0 O E L J A o 4 .. C i G G E q w a r ry V L o 1- ..F., iB j :3 • N EL ✓ � p VI C ri C3 W VI ▪ 0. y a 4 cc i:r V: O vs cs co cm V z kV, e o to LL m 01 /On V 4 00 4 Z w E z O d' I[i O 5ry C7 Co O z w4 Ce. C M 0 [J tV N U) U Direction of stack outlet (cheek one): Width (inches) = Section 06 — Fuel Consum a z C. U) CV 06 C In U) N 1000 Btu/SCF g a s Q a e 0 0 7 9720 SCF/hr Z Z D 0 0 ci i^ L C a C a E ..r7 C C E w 6,▪ 1 C C C C is: N • 0 a U Estimation Method or Emission Factor Source 1 V ,d AP 42 +d' < AP 42 I m G> c E manufacturer I IS M c E GRI FIELD DATA I 4 < ry e. a. <C AP42 • Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants nut listed above. I Requested Permitted Fmissions UncontroIled Controlled (Tons/Year) (Tons/Year) M CO 0 M CO, 0 C} c0 o 4.03 N m' n• r--- • N T .0 T1 .Q N A i. coM 0 aMi 0 ado 46 ai N a7 °} �' N co N 224 lb/yr in Actual Calendar Year Emissions' Uncontrolled Controlled (Tons/Year) (Tons/Year) I Emission Factor Uncontrolled Basis Units c0 2 A 2 35 2 2 2 1] L .e h ao .e a a, g/bhp-hr a Y 2 lb/MMBtu lb/MMBtu N 0 0• r iV 4 m .- N 0 Q r 5.88E-04 O r 0O c] 0 aq ,- d M 0 rN- N C.) Q CO w. N CO O co r Control Efficiency (% Reduction) 60 O.0 c IO 0 In On0 o e 2, o s 0 s Control Device Description 0 U I g.. • C y NSCR NSCR NSCR NSCR NSCR ¢ U coo Z NSCR Pollutant r r .4.--;,�+,•,, ly -a T E LE J j J ' < C .J C CA C = EMS Area Manager C N Ll 0) 5 7.0 Ca g c rl N PI i • c E Internal Combustion En L Cq 0 0 C7 N Emission Source MRS ID: co co 0 LLJ Permit Number: C U C v Section 02 — Re Section 0I —Administrative Information .-. _ p C. G O 6. I v W 7 - cEl , r O b z c c- c W1 C L c f.- 711 o u V o .c. G' 5 •r 0) a .0 L. u_= s G , .E CD 4 '�" a V T C L' 0 — CC L d us y E. L C` r - L f L '�} o W y6 8 a E o0 ..l _ _ 2) M1 a' E x ---- id u , © > a i �5, e. t .�� a o ta (r 'E L a o= .§ a G.t 4 V -- 7.4 "'� ep C4 fV c C. X: c . . sC a C ❑ ❑ •" ' C 4 y !a iCp, _ ri7 Z" W u L _ CO .... C3 a e c �+ c c a 6. cs o *- p is m E j�'vi 7 ' �' c '.s L y C.. E o L, z c a E . y CJ L '.�". Li: o v �°' 1.i° v O 0~0 5 i e ^a V i V L Zti '.^JIY .6:.(J.Y. C.3_ C? 4jO C C F 4; WI 'L. '> .9 .4 O F U 2C g: O' S S a 0 L N Z L. O' me Y ❑ ❑ a ❑ ❑ z° 4 f S O .t'. ❑CO ❑❑ ❑�Z 0 Y .t Y v U .�. V Lry CAL o < Ca' { T i� zc 13472 Weld County Road 40 Source Location ZIP Code: 81301 O U 0 C, 0 970-764-6661 Phone Numher: 970-3752216 .C z 0 U T 41) 45 m Section 03 — General Information N co 1 For new or reconstructed t C U C c z e c o O �i a 66 • W Y � C i Z a a a I. c f= re -•r. o c = - c %n u` �. O .C2 .1 t V ti u,',,-11 a= L f"' -W '�-C c c '° ...1 0 0, u J tv,vCTC c Lc N N IN O O STen en en o0 In end... C G0 ii C LC . s1:', J .. CI P :] G o O E 'y a _ TX .. Sr f � G C :LR. - U 0. 'r f < :) after 6/12/2006 Co O .4 R C after 1/1/2011 2 v 3 4- C) C J U J }t 4f El z • CU Cd C y C g { Z E c 13 c. 13 f O L J L • c. 7 ine Information Section 04 — En U b 0 ,^L after 7/1/2008 CO 2- b U Manufacturer: r V F V E. ❑ 0. C 42 v s a U 5 U C. fs`fi ti LLI x 0 0 ec 0 a CO O) m a C S c a. n C G Q L.. E I v ,f f C) U L , G C j c 3 W 3. 7 5_ U c C U .1, C 0 L L a O G Jf s, O 3 v v v v ce C' d 0 o O s 2 .1 1 EJ U IJ I C Ea - 7 C 7 on 19 U C CJ .C v s C C CE 6 S S5 FORM APCD-201 FonnAPCD-20I-RICEAPEN-Ver7-27-20 I I doe Internal Combustion En a L o U b ga A c0 CO 4 Permit Number: 0 o g co C7 o N 8 C7 z 10 4 104 48' 15" W M co z ti 0 e•fi ap C.) U C ea U c IP C L > b i a s Y R � y 1 7 .T o z v W g O v g Seasonal Fuel I> O z U) N rt LO 04 U 07 3 0 a Requested Permit Limit 13.4 MMSCF/yr v C U 1T 7J ce cC 7.4 — CJ U U fh 0 3 LI C C z U C C 7 C.. trs Information & Emission Control Information Section 07 — Emissions Invento Estimation Method or Emission Factor Source AP d7 4 O1 h VN < V N d < RI YZ manufacturer rnmend IS ' L 7 ? 7 Q 2 ml ; g tU m cc c I13 E N *4- ] O. c< E 4 PL R4' a. Q Q . J J u- G c C :J v O a \:',-; o O o a)� .- O 00 tei ?� .- v � cn .- B oo l r � r r ' F I C7 -.:4- O v •o 4 T •n e7 .- M Z. N 4 a 9 ac.um ca,enuar yr, emissions below & fuel ntie above (e.g. nom: f Emission Factor Actual Calendar Year Emissions' Uncontrolled Basis Units Uncontrolled r Controlled Irons/Year) I (Tons/Yeart I ii S, i f 4 L i L. 9 ti i os Y 'a 9 1 41 W 3 c2 •_ - r . 'a 73 a c_ C .r w v tl' p r 2 Er +i+N a N 1 2 U a C F 2 Z ` c E M 7 s� z 2 a z 2 `a g/bhp-hr gib hp- h r cL as d. 2 2 a J 2 . lb/MMBtu N Q uj d rn r. N C' W Ck — NN CI' aJ Ch .-= w CO CO to 14 t- CO C O Cri r N O o7 9 LAW N c9 O 404 NT.- C) Q W C i _ c›_;,.8 : •G 3 7 ,y C LT e I2 e o Qn m cn 64: o \ i?, \e moo. Control Device Description lSecondary ri co C) cet 2' NSUH unnr-, a [C n a Z 0 z 0 z C ..1.,�z>I- €ism ENS Area Manager Internal Combustion En (NJ Emission Source AIRS ID: c 0 7 T C Cd C c 4 z X._ A `T E 5 N A C7 CC E L J C �. L2 a co co uJ t•-•i Permit Number: V G L nested Action (check applicable request boxes) Section 02 — Re Section UI — Administrative Information S"--. C -c C CJ a c J E R N C C F Q it 11 y V C.; n o - J_ fli1 9 q C 4].' O 0 u o .0 �- CC — 9+ O =1 G E v C a J H 0 % O c :r u 4 E E i • ❑ ❑ g a 3 I -y CC - a'� Y G i ''L c '. g CC d .. -c E c p- e c u 4. L '�, 5 CC �. y u V s W < p, of 5 v L C € m = 9 7.V u a : = r, L L V CC CZ a. = U C o a C . n = = 7 9 9 a x x ❑❑Y a' ❑ ❑ v z 7 0 0 3 to E JA L!. 0 M CO C 0.: ti Mailing Address: 65 Mercado Si, Suite 250 970-764-6661 Phone Number: O Z 0 Ce U', 0 E a ny v E w u CC U) o. d Q ? dJ B) C O y' ,C1 E 0V _ 0 En 9 _C �© Z c 970-375-2216 Fax Number: -mail Address: vfrazier@akasnergy.com Section 03 — General Infor N_ O CO 1!) v • = O r R 4• Lr . " 0.5 ...I p � C9 ;Call Mf gM�L `ti.6:a19= ;Vt.:. 0. O. Cr. 0 4 Ltiv C C Edo A VI G v -°- o .a O. .4 ; 71 G t , V Y R -: :3 fw C T C• • A a ' L C. Cd €o t , - 79 e , C O w u R. •r, E E^ E 9 r O ." C V ≥'V GR,y G4 h a °v S 1 `i c• "E-, 3 E r s � c a V C C. L V. = L•`, y V G _ SW -o '1: i v -.r :r j a LAv' 'E O .f a. j Ti 44 V a, V L1. Ca ,C r, .5 O a,,.•1 u .-E r —v 7 Vr-rL1 _ Q;ii APEN forms: Application status after 6/12/2006 after 1/1/2011 v G = G C 3 $ C C y u. C) L G J v V . , Cw r7 el C ₹ C 3 LI C z inc Information Section 04 — En v C ., J V Cl .c V J Fre -• G. ❑ -0 C. 0 C S I- u E c. C C. - = after 711/2008 _7 5 Cd les 7 ❑❑ J co co C9) 1.0 O) m i R r C. IE N E E w .r L L C C Cd ,11 L. Combustion: oa g- 2, G a w L .0 C — C r 'n <1- Uo c CIE Y V Le N un ❑ O V ^� v f .5 f- 17.) h, FORM APCD-20I ForrnAPCD-20I-R10EAPEN-Ver7-27-20 I I dne .Q Internal Combustion En co 0) e to 0. ai Ix P � � 4r ,:. 40. Tot W LL 0 L m C C ci 0 w F too 4 y 5 jj z (") a) 0 o Oil ao 0 M O z o iL ti 0) Y.� a 6 en r 0) C? er n -0 ro C Y.0 g s 0 L. ❑ i3 U' > L _I ❑ C L. C .0 0 u a u ' J C. "c' ;sf c c±l rE ,E ©Q O A A LLI Section 06 — Fuel Consumption Information a 0 z k J w c ,c cn , N N' in 0 1040 Btu/SCF Requested Permit Limit 1529 SCF/hr C z 0 7 7 t.i- ': O C . j C 60 u C Q Q• ., c.,.) a 7 C1 b << q d = T. 2 manufacturerfAP 42 C E N [[`�� L Q E �i N N i V <C Q..9 3 4. ea x _1 N e`d b eg vu 6 r d r O C 00 Q 47 r Q 0 CQ P') >_ _ .- Jan 6) W it I kJ _ Q i. G co 7 0.14 I 0.14 Q O 31.1 M1 o r ... — _A .O ? A 22 lb/yr 4�. a. �a.cuWar $r. nemow.55 luel use uhov'e (eg_ 1007): l Emission Factor Actual Calendar Year Emissions) Controlled (Tons/Year) IICIWVne I wa'tc I ] 50% f 1.58E-031Ib/MMBtt1 Please use the APCD Non -Criteria Renortahle Air P..IL.ro..l 5 C1 C i? .- v, .c. .i 7 C , n 7 .n 7 ` o, g/bhp-hr g/bhp-hr g/bhp-hr J a 7 a N (N O 9 w w d= v Cr? rn r .- N 0 w v O, r '' 0� w CC W ul (0 CO (,,ci in in N o C? 9 w 0, N- N Cry 9 w CO CD N Control ° Efficiency (°Jo Reduction) e Tr 0) i o 0 in if co co e C) in e .0 Li-)in u 0 Control Device Description C. 5' a U, I . (F) Z NSCR 1 NSCR l) CO 7 -Cl) Z c Z. i C7 .z v s ^ 'y EHS Area Manager r ` cJ 7 C. J I- L U tr.) tl C C C C V ';i as C 0 ^ V e � 6 C. C C! C L r. 'r c 5 _ zrl 17; .0 c 15 G p— d 3 C v, _ E 3 N s C V6(n .71 Ti C c) a c _ ' �, y 0 8 2 El O E 4.47 - c C a Internal Combustion En u AA� l�l R, 0 164 dw �C$C Q a N a '. Ny W F O z y0 VJ oa w O U a a E Z I" E avj 0 O C Emission Source II1 V rea o ° ❑ e' a O o V cz C g C Y C .C L L L 'v � _ . � L C n 0 L Y ;n u S C C E d = 3 at J y 6YCr oil, E Co v J y $ t M S413 T.I f A 'o �. C 44 4 pt Y C = CC e g q L C 6 di V ,Y y c..• �. .../ G ` a U .C C Y C .r V �Z.y L T GTzi Z a y .� ..' C U Eli •d 4o .0 U .- q a Q ila L L O41.1 CCI1 C.0 ,..�� Orr � `Rp 1` t CC - r, I 4+ U v -, v Ii Y N 7 7 7 7 o 0 41 4I 34 ell ❑ ❑ 0 lin Section 01 — Administrative Information Elevation: 4,771 gob a a add engine to facility -wide permit ❑ ❑ ❑ mos Q z ZIP Code: 81301 Mailing .Addres! 970-764-6661 Phone Numbe d Ito Z.; pC Ct 970-375-2216 Fax Number: of raz ier@akaenergy.com re Section 03 — General Information N CO C. c. L V C Z O :i V C o 4 b C G 4: µ E . C -!a J y C C. ' T.; P 0 "7 C Q P1 a = . are :.: i O ^ :J to O ;_ y j .fl p o '�j` 5 ` '� 1. ..:670s. � L i J L 22 0 C — 5 E O .` 4 G L :, = C EE Y U L. :..= ec yE u n c. _ _ L iV a .F C a ^3 L 4 Q� m R z V 4 Y m t+ p a iJ a L '4 . L �..� v C° } • y. � g L V I.: X v �.. .7 Cr S Y JM. AV 4`t '•k this APEN form: •b 1. trcrr i rf rn M } rY t".4 •r! Cr, a' \D .0 45 el M C. CO C V U APEN forms: ht U 0 u J after 6/12/2006 ion carnmeuc(d: Cale engine cons 0 CN CD C R1 C C C after 1/1/2011 me Information Section 04 — En after 7/1/2007 Engine date of manufacture: d m Manufacturer: •, G u. gar 0 O N ti G C o c r , .y EC c n '2 b C b C 7 C t� n a g g ❑ 0 C �' b O c c L L C 3 y O , G o C 4 U 4: 4 0 o x U fO. y rV A/) ❑ID J G J :r } O u c zn W 1. C C cl C 74 r� , a. C 8 C C Jg AI c g L. h C C. C r- r C. •C B Y 30 T I O I'l D-201 I I .dnc C a. Internal Combustion En ...... 1-• 0 on C ol Cl.in 04 T co E ' rmi TT b 6 5 d LQ A U Q V f a. u 6 C Ti. Ir CA W 0 O �Z° v o F o y z IEd C) 0 0 H C) ,r U 1T1 E Z o w Lc 6 16 0 0.4 Ou , QI a" 1 in 8 a 0 u a 00 0. w 2 CO U) Ea oD a Q z t0 t0 0 m Q) ti ti .142 U c4 C u li Q C L LJ E v � 0 ta o m •a G A C7 y Section 06 — Fuel Consumnt on Information } Seasonal Fuel Use (% of Annual Feb 1Vlar-May I Jun -Aug ar CV U) N O 1040 Btu/SCF Requested Permit Limit 102.2 MMSCF/yr 11,663 SCF/hr z OjuaAul SWOISSrt113 -!0 UOIpas a D AP 42 AP 42 aa d ..U"°.. c O S manufacturer manufacturer so d7 o i `r ¢ a Requested Permitted Emissions Uncontrolled Controlled (Tons/Year) (Tons/Year) in cn 03 L0 'LC 6 in in o cn O O ^ cfl d 4 coo I L A 1 o N t • in 'r*7 uIryr I 273 Iblyr .O a) co 0.53 0.53 Mtn C) ri-O i- r Q L m,08 ei cQ M- c0 3 co - 4,1.1.1.1.111 Ea,cuuilr yr. crun Ions neios eir fuel a!e aboY(` (t.g. 2007): I Emission Factor Actual Calendar Year Emissions Et I .tool.; III oxiaauon catalyst 50% 5.14E-03 lb/MMBtu Benzene oxidation catalyst 50% 1.30E-03 lb/MMBtu Please use the APCD Non -Criteria 13enenuhtn Ai,- Pnu.,tw..t Add -..d..._ r__— ._ ___ .— .. . . .. Uncontrolled Basis Units Uncontrolled (Tons/Year) 9.99E-03 Ib/MMBIu 0 m 7 m 0 a I g/bhp-hr 9/bhp-hr g/bhp-hr m acc w rn rn Q w a) a) a) 0 o 1.11 '— ca CO u') a O u, cs In cV 0 m O Iii' co "l m Control Efficiency (% Reduction) O L O U a) r,..0 p 4i Control Device Description Secondan E a oxraauon catalyst oxidation catalyst oxidation catalyst u) 2 c E K 0 Y. [ r.„, I onent Leak Emissions (APEN) & Application for Construction Permit— Fu AIR POLLUTANT EMISSION NOTICE 0) O O 0 Emission Source AIRS ID: 123 ar O w 3 O Permit Number: lProvidc Facility Nquipmcnt it) to identify how this equipment is refercneed within your organization I Facility Equipment ID: LEAKS Section 02— Requested Action (Check applicable request boxes) Section 01 — Administrative Information Request for NEW permit or newly reported emission source Request MODIFICATION to existing permit (check each box below that applies) ❑ U ❑ Change company name ❑ ❑ Change process or equipment Change permit limit 0 El w C N. ti C • C nCj Request to limit HAPs with a Federally enforceable limit on PTE •I. U' 2 G = L '.) d ...Vc .C C a. y o I C C r .E c Y J V 1 E :J Q Jr 'I. r n o C N e. c >.E C •+} < J c. C S z ❑ ❑ ❑ ❑ C ers Co 0 65 Mercado SI., Suite 250 970-764-6661 C) N U - J Person Ire Contac 970-375-2216 Fax Number: m a C d (13 N C add components due to expansion < Z Section 03 — General Information C C U U .y G C U U C C U L N sources, ope x U U CJ 'a 0. C) O 0 C C m C Y C 7 U C) E YEn Y C 0 cc cp rn C) Y 0.1 tt O U `J 7 N. °� ors of Source t1 C E z C C C. E C C 3 U C. 76- -c C. J ... z 3 < = J C. C C C U c. C ❑ co C U E C C 7 :J < Z` - C ;F.1. G J Information C Section 04 — Re Y t .G - f..1:4 C. J C tr e = Z z C U Li 'J. k C C c. r U f. 9 f — 40 CFR Part 60, Subpart OOOO Section 05 — Stream Constituents (% 'tom) ausxait-u a T 0 N. C"? N. r..- Xylene (wt. %) i... o O 0 Ethylbenzene (wt. %) C 0 • O 00 O r r r Y V a T O O O e 3 do xi L.ri La �L v 44 o o e — 0q0 0 o 3 ie o o cv .N C..4 e O O c .r y ry T Ca O O T T Stream Leavy Oil (or Heavy Liquid) I Light Oil (or Light Liquid) L T sz V ILI Q xm U Eh 9 ._ G L L C6 G. � C 7 7 a � U 0 J C t. C C X ❑' 0 C C C C u U c d c a C C C C >. C U C A C C C. ❑ - Vcr N-10-21105 doe Form APCl -203 - Fugitive{ornponentt.caks A FORM APCD-203 onent Leak Emissions O U r:. 71. 00 C Cr) Emission Source AIRS ID: Permit Number: 07WE0081 Section 07 —Leak Detection & Repair (LDAR) & Control Information Section 06 — Location Information (Provide Datum and either LatiLong or UTM) ra CO a 2 ad VT . 0. z 4,3 C Q C No LIDAR program O C w - N C C z c) C4 0 10448'15"W C*) co c. E. T U 1 eta 'C a N 0 a 0 C E •3 Section 08 —Emission Factor Information a C i 74 4 C D u-i i Count` lc N 0 0 0 0 C or J Light Oil (or Light' fa7 V C W co O 1720 C Heavy Oil (or Heavy Liquid) E :+ V d c0 cc o O O O C .4y . GL. wJ © 3850 C~0 Q O N O g. IOpen -Ended Lines 1 I— d G ) E S G a O a g O aa 0. g u > W ` u JI C Section 09— Emissions Inventory information & Emission Control Information C_ E a t. a C O a L C L La C Estimation Method or Emission Factor Source FPA-O5318-95-017. Table i-4 EPA 453A-95.017, Table 2.4 EPA -053!8-95O17. Table 2-4 EPA-A5.3tR-95-b17. Tabs 2-4 EPA -45318-95-017. Table 2-4 m a C q, a W Please use the APCD Non -Criteria Reportable Air Pollutant :Addendum, form to report pollutants not listed above. I Requested Permitted Emissions l. {{ 39.0 2110 lb/yr 4378 lb/yr W V J 3. 3+ 7+ Ch h CC U ? o N T 'n Uncontrolled (Tons/Year) h cci co 2304 lb/yr 5426 lb/yr 1063 lb/yr `>' Lo CO d CD C a) Actual Calendar Year Emissions= Controlled (Tons/Year) I Uncontrolled (Tons/Year) 6 G ra C O C Uncontrolled Basis co) 4 u G p 41 1Z I• Control Efficiency (% Reduction) C. CI a Z. r1 Control Device (Description 11 A 4. p oc 11 E C will be based on into in Sec 03 - OQ nilsslons is left blank, e C c � C L 'CO VI L Y E 4.1 VS 6.1 Y L a L iw 9 I- Qa is Cl C U 0 at .45 Y r0 C 0 Cd u w i.i u Section 10 —A EHS Area Manager m N m LL 0C 5 a IV co 0 N Emission Source AIRS II): ci W V 9' A J C . 9 C 0 LU O Permit Number: Co ci c c ra au U C G E ci .c a. 2. C a. ci u Cd ci V nested Action (Check applicable request boxes) Section 02 — Re Section OIL — Administrative Information w d :, X, 3. O. T. R n a ❑ r v L .72 { �+ O. —, O a s v a 'O4, C Q. 7.--1, G ri ,,.r+ L h J v L G E L O E i V Q. _ .b v ci. ,° E ;v .y u J . Ea- C G . v O. IL J • t L e 4 e :10L W a> -`r '� c c. r O y a..'4 ts` C C u 'O t j — `E a J G.7 •'� per. O E 0 y a< 0 L.0 e Vao tit 15 •gea C .. :r4 =C. C 7 •p yr Q a *� V J a U CyV a 0 v O Cr Cr to LID DE Aka Energy Group, LLC ci E A 3 Sr ci C C ci J ZIP Code: 813 65 Mercado St., Suite 250 1 O U a ca ci ci 970-764-6661 Phone Number LI. QY Person To Contact: Fax Number: 970.375.2216 vfrazier@akaenergy.com E-mail Adldres C ci C coo CO 0 O .C U m co a 0 C O C 8 m c 0 G a ci Section 03 — Ceneral Information N O 4,2 L C O C ;.s 2 y U G 9 r~ 24 hours/day 210 bbl condensate tank ki L o ci c __C •C C ❑ ❑ o z' z z z 0 CI El LI e c J J a J ❑ ❑ ❑ ❑ • r. C tl c u) N z G c C C ci • A .5 I Z i 0 Al o R a v l [d E u 3 `a o :1 C C C G — - -.T V L • ( J 9 1 a. •`a % s r a y 5.0 n sF. Al so L' Y ca ci L CS E LI z cb C G { 7 :j 7. U :l 9 'V C!1 z :J c •J 72. ci ' J 3 . C:21 V - A F G r- j N C C 0. ci E L. z C P C `.1 4: O R a a 4COO ^ -O V v ^ C c E et ✓. e� a = E - • r. L N tit 51 D ' L V+ t. w 2 L D i 0.S 4O[! E c7 pN r`i [ N C. siD -c 0 M M O C G ) M ` a. a 9 2 E G D - a U 3 U 3 Q e c G 5 •C, c 4! iC V. he.statc.co.us!a U AI'EN forms: htt J ae V .r G z C N G C td •J, d ,c n z ro v7. u C A x :e > c x C GL § y? on co h A Z 7 Cco E E � v } z Y oC 4 U ^ c J n r o t L n y C Y L `c 3 N c 7, 11:1 o 3 'r A Section 04 —Tank Battery Information' D LAC Number of tanks: .C .C L 6 G G z z El Ii r } E qL O Yl m Al ci. ta Ca . S G ≥ p J C G 6 ti C Y C c u 0 it t E N O r- tO t O Reid Vapor Pressure: a co SJ 4 ci 'S 'l. ci a c C n • ea C n +p -7 J — G CV 3 C. R G w 'y G 3 r � C C E a V o a C O V _ U -o ro 4 G u � E ; C LV ; r J 4 ci O 0 C. C. C Ly o C O T. h o V c 0 0 13 L ❑ ❑ IO 4 .c ti 6 o a ,E 41 i G ca 'r p� is C 3C � g E O O_.. 'v1 d C > ci cd o o U f e011 .s .J •00J 7 C a -O in V • a nv y} .O G '�h L• ^ C: 4 — p j a Cn ail 0�.. ^ t L CZ 4 [[0 C Q Q N C c. FORM APCD-204 li CIO n) O 0 Emission Source AIRS ID: 123 Permit Number: 07WE©081 L 8 QC I. u 4d 0 a ci V C b U, .0 E C V C ti u L f1.0) V i 0 0 U Section 45 — Stack Information (Combustion stacks must be listed here) E V n o 2 r I.LI W 0 a z ;)- e, 104 48'15'W cns oo u" 8 } F 4. a� N F " I— V J i C LI C- 1-4 C I I m' :n r 0 J U v U H u It U v C c. Y q v c i f II VJ CJ U E 42 V U U Section 07 — Coast 7 U 0 C C 0) .G C O 2 ,c 0 ci C V .ci L G }, C U O of the tank batter! 0 ;C C U 'fl CI C 'v a CL F C E ci F C- C F" :y C ci MakelModel: 'J 8 a U C u C c c L. E a del � C a ation & Emission Control Information I- Z Z F TANKS 4 0 9d TANICC A !1 O,a Z I- Requested. Permitted Fn�iccinnc§ . I er a .15 O a Ja [t . a L,... -O ' a..r. �a_p. Fwarri, t Actual Calendar Year Emissions' "u C ' . . II io . H.. . Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not Hsi Annual emission fees will he based on eetual emissions re eeried here If Fell [dank annuril rnuccinn il+..c u•411 h.. L,.c...r .... ...... .......i .SJ C , Emission Factor J C I llncontrolled Basis Control Efficiency (% Reduction) Identify in Section 07 ce Description c U V: E .C 4 C g 7 a .c - - 'al N 4 u C .• J C le; C . L:.d n v. f. c S .O '= = -C N 'U u 7:1C t- C rn ^ n t E L C _ U J ci � C L c—•3 ENS Area Manager C h C v n O C ci cJ H C 8 A z N C. Ii7 N Emission Source AIRS ID: W W O Permit Number: Facility Equipment ID: AMINE Section 02 — Re Section 01. —Administrative Information ca a. iZZ d E CC C _G ;.1.1N LJ f C EI.1 C "�� Q .1"3 CD 7 C G C • n m .L - to S i41)0- 047 • c e4 El O ce L. N•. c a c i • V pl y u _ •5 • C - L A 'C `Y ti a C E G 41 E c E E m C .4 r " d r q C 0 " mco 2 Cr' T O = •a 011 0 5 5 L 2. .J C.:. 64 C Lo a❑ o 1T C VU Z Aka Energy Group, LLC •O C=. E- Tr - 970-764-6661 Phone Number: Person To C'ontaci 970-375-2216 • 0 LL vlrazier@akaenergy.com n C Section 03 — General Information .E) CO II9 N 1 3 3- o ❑ ❑ z z ❑ ❑ Vl f CIS n c C L w C ri •5 c A C a f'•1 I L z C C. 5 3 .C ' • c ti G J L 8, E. • ▪ 5 2 > C1 - (7 v ✓ e - G .c a C -C of, a aim C Lot C J T C) Ir V4 a 1. N E u _tiJ . I'O ;::1, C 6 L V V a O O Unit Equipment Information Section 04 — Amine Sweetenin 03 I - a m 0 it 5 G m F ❑ 2 O (o 7 • U J L ▪ U. 0 y C CJ m as J 2 C U, Fes. C- • C E .E Us C!a CNti IOC) 119 C C. C C SA O 13 U ,7 .7 C C. O C7 Rich Amine Feed: Cr) U, rn_ c_ M "-2 O mt co m O 119 ei O 8 O el Al en c PI PI `: CI O G 3 C. C C Ji 7.7 lb. G C. S u C 14 U APEN fonts: -C v •f. n a ti Application slate z Q E U C 71 O. C. U) 7 �n 2 n, co •7 7 n 1J. a C LI Ci U u 0 u • [Z O 0 C C E. E. G G 0 0.. C U r7.1 C C Y. O 00 U U as 7) V zt 71. C •Hr • 1g -r AI L 1 L Q .a C� C C. C C a .2 c U. 4 .4 a U C DO C) 0 �a 1U LLl C 4) C) C C) a EL 41 0 IJ co FORM APCD-206 Cd a) 0 O M cN Emission Source AIRS ID: Permit Location (Datum & either Lat/Long or UTM) Source, if no combustion Section 06 —Stack Section 0S —Stack Information (Combustion stacks must be listed here) o QCq 00 „ 3 W 0 0 3 C E z ZO U) M co z 33g v ti 111 z 2 } 0 3 e ,o L O Section 07 — Control Device Information ( Indicate if a control device contr w 0 CO C C O a2 O Make/Model/Serial #: U) N 0 0 00 ads I- H x n X c i C) CI) 0 O r- r v.) O O 0 O E v N N 'O m a U a) a C U C C O E C Y e w V.) c V O O c E E iJ C C) C' C) C e� e e a Requested VOC' & HAP Control IJ'lici Annual time that VRU is bypassed Information & Emission Control Information Section 0$ — Emissions Invento C C) O CC z N 0 z .) E E E a 0 0 .0 .00 a E E E simulation model simulation model a) c.6 .O co N Q) 0) b t d T a) 0.1 LSI T a a fi CV CD a) g C., tea`, O N ti 0 5▪ ; 4 5 .may E 4r O E Is 00 9 a a 7 u _ 2 sa Emission Factor Documentation attached "C Emission Factor 3 .0 E w E E A E� a w Ni /A EE E E 0 Ih E N E E .e U E E a strolled Basis O O P) O M O O G) Cd W (V O C7 Cr) C e- O a Control Device Description Identify in. Section 07 9 z � o E p E E 00 E 6 ' 5 9 .o . L m 3 0° o ▪ � E c otLe t .O • - ire G o =. a g_ • 1.3 E .C E Q z-83 r- a $� G Y C y < .'G. . 51) E Y �q G Y , A G t 0 .G a -E W 0'. E J LA L 6 L C CO 41 N a. E W 4 4 u a a R `m a▪ a • U- E a > C 0 a G 0 C C R C a L Y .0 u Q sc E .0 C 04 u Y r.. ▪ v C e to 1.O L C 41 a 0 EHS Area Manager Form AFCD-206- AmineUnit ADEN - Ver.9-10-200S.doc Attachment C Emission Calculations and Supporting Documentation Caterpillar G3516LE Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC Caterpillar G3516LE - Reciprocating Internal Combustion Engine (4SLB) w/AFRC 8 Oxidation Catalyst Site Specific Unit Rating a: 1297 hp Operating Schedule: 8760 hr/yr BSFC: 7600 Btu/hp-hr Maximum Fuel Use b: 9.860 MSCF/hr 86.4 MMSCF/yr Maximum Heat Input: 9.86 MMBtu/hr ' Maximum design engine output (1340 hp) @ 4800' msl site elevation and 100 F inlet air temperature. b Based on LHV of: 1000 Btu/SCF Criteria Pollutant Emission Calculations Pollutant Uncontrolled Emissions ` Controlled Emissions d Emission Factors i Data Source i (lb/hr) (tpy) % Control ? (lb/hr) (tpy) NOx 1.50 g/bhp-hr manufacturer 4.29 18.79 0% 4.29 18.79 CO 1.90 g/bhp-hr 1 manufacturer 5.43 23.80 93% 0.38 1.67 VOC 0.60 g/bhp-hr i manufacturer/AP42; 1.72 7.51 75% 1 0.43 I 1.88 SO2 5.88E-04 lb/MMBtu AP 42 0.01 0.03 0% i 0.01 i 0.03 TSP/PM 10/PM2.5 9.99E-03 lb/MMBtu ' AP 42 0.10 0.43 0% 0.10 i 0.43 Hazardous Air Pollutant (HAP) Emission Calculations Pollutant Uncontrolled Emissions C Controlled Emissions ° Emission Factors . Data Source 1 (lb/yr) i (tpy) % Control . (Ib/yr) I (tpy) 1.1.2.2-Tetrachloroethane < 4.00E-05 lb/MMBtu AP 42 < 3 < 1.73E-03 50% 1 < 2 1 < 8.64E-04 1.1,2-Trichloroethane < 3.18E-05 lb/MMBtu AP 42 1 < 3 < 1.37E-03 50% : < 1 ! < 6.87E-04 1.1-Dichloroethane < 2.36E-05 lb/MMBtu AP 42 < 2 < 1.02E-03 50% < 1 < 5.10E-04 1,3 -Butadiene 2.67E-04 lb/MMBtu AP 42 23 0.01 50% 12 0.01 1.3-Dichloropropene < 2.64E-05 lb/MMBtu AP 42 < 2 < 1.14E-03 50% < 1 I < 5.70E-04 2,2,4-Trimethylpentane 2.50E-04 lb/MMBtu AP 42 21.6 0.01 50% 1 10.8 0.01 2-Methylnaphthalene 3.32E-05 lb/MMBtu '•. AP 42 = 3 i 1.43E-03 50% i 1 i 7.17E-04 Acenaphthene 1.25E-06 lb/MMBtu AP 42 0.1 5.40E-05 50% 0.1 1 2.70E-05 Acenaphthylene 5.53E-06 lb/MMBtu AP 42 1 0.5 I 2.39E-04 50% i 0.2 1.19E-04 Acetaldehyde 8.36E-03 lb/MMBtu AP 42 722 0.36 50% 1 361 0.18 Acrolein 5.14E-03 lb/MMBtu AP 42 444 0.22 50% 222 0.11 Benzene 1.30E-03 lb/MMBtu GRI LITERATURE 1 112 0.06 50% 56 0.03 Benzo(b)fluoranthene 1.66E-07 lb/MMBtu AP 42 0.01 7.17E-06 50% 0.01 € 3.58E-06 Benzo(e)pyrene 4.15E-07 lb/MMBtu AP 42 0.04 1.79E-05 50% 0.02 8.96E-06 Benzo(g,h,i)perylene 4.14E-07 lb/MMBtu AP 42 0.04 1.79E-05 50% i 0.02 8.94E-06 Biphenyl 2.38E-04 lb/MMBtu GRI FIELD TEST i 21 0.01 50% 10 0.01 Carbon Tetrachloride < 3.67E-05 lb/MMBtu AP 42 < 3 < 1.58E-03 50% < 2 ? < 7.92E-04 Chtorobenzene < 3.04E-05 lb/MMBtu AP 42 < 3 < 1.31E-03 50% < 1 i < 6.56E-04 Chloroform < 2.85E-05 lb/MMBtu AP 42 < 2 < 1.23E-03 50% 1 < 1 1 < 6.15E-04 Chrysene 6.93E-07 lb/MMBtu AP 42 0.06 2.99E-05 50% 0.03 ' 1.50E-05 Ethylbenzene 3.97E-05 lb/MMBtu AP42 _ 3.4 1.71E-03 50% i 1.7 ! 8.57E-04 Ethylene Dibromide < 4.43E-05 lb/MMBtu AP 42 < 4 < 1_91E-03 50% <2 < 9.57E-04 Fluoranthene 1.11E-06 lb/MMBtu AP42 0.10 i 4.79E-05 50% I 0.05 I, 2.40E-05 Fluorene 1.11E-05 lb/MMBtu GRI FIELD TEST € 1.0 4.79E-04 50% i 0.5 i 2.40E-04 Formaldehyde 0.26 g/bhp-hr manufacturer 6513 3.26 75% 1628 0.81 Methanol 2.50E-03 lb/MMBtu AP 42 - 216 0.11 50% 108 0.05 Methylene Chloride 2.00E-05 lb/MMBtu AP 42 _ 2 8.64E-04 50% I 1 ': 4.32E-04 Naphthalene 7.44E-05 lb/MMBtu AP42 6 i 3.21E-03 50% 3 I 1.61E-03 n -Hexane 1.11E-03 lb/MMBtu AP42 96 0.05 50% i 48 i 0.02 PAH 2.69E-05 lb/MMBtu AP 42 2 1.16E-03 50% 1 5.81E-04 Phenanthrene 1.04E-05 lb/MMBtu AP 42 _ 0.9 i 4.49E-04 50% i 0.4 € 2.25E-04 Phenol 2.68E-05 lb/MMBtu GRI FIELD TEST 1 2.3 1.16E-03 50% ' 1.2 € 5.79E-04 Pyrene 1.36E-06 lb/MMBtu AP 42 0.1 ' 5.87E-05 50% 0.1 ! 2.94E-05 Styrene < 2.36E-05 lb/MMBtu AP 42 . < 2 < 1.02E-03 50% i < 1 € < 5.10E-04 Tetrachloroethane 2.48E-06 lb/MMBtu AP 42 0.2 1.07E-04 50% 0.1 5.36E-05 Toluene 8.15E-03 lb/MMBtu GRI LITERATURE 704 0.35 50% i 352 0.18 Vinyl Chloride 1.49E-05 lb/MMBtu . AP 42 1 6.43E-04 50% 1 1 3.22E-04 Xylenes(m.p,o) 2.73E-04 lb/MMBtu = GRI LITERATURE 1 23.6 0.01 50% 1 11.8 1 0.01 HAP Totals < 3.57E-01 g/bhp-hr 1 (calculated) i < 8944 < 4.47 68% < 2844 , < 1.42 Manufacturer's uncontrolled emission factors (EF) for NOX, CO, and formaldehyde. VOC EF is sum of manufacturer's uncontrolled NMNEHC and formaldehyde EF plus AP 42 EF for acetaldehyde and butryaldehyde (NMNEHC EF does not include aldehydes). PM10 and SO2 EF are from AP 42, Table 3.2-2 (PM10 EF is sum of condensable and filterable EF and is equivalent to PM2.5 and total PM EF for 4 -stroke, lean -bum (4SLB) engines). Uncontrolled HAP EF for 4SLB engines (Ib/MMBtu) from EPA's AP 42 and GRI-HAPCalc 3.01; the highest EF between the data sets is used here (GRI field test and literature EF (g/hp-hr) were converted to (lb/MMBtu) using 7,276 Btu/hp- hr, per GRI-HAPCalc guidance). d Controlled emissions are based on uncontrolled EF and the indicated catalyst control efficiencies. 001 Page 1 of 20 8/18/2012 Waukesha F1197G Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC Waukesha F1197G w/ NSCR Unit ID (s): C-6, C-7 Site Rating a: 166 hp BSFC: 9000 btu/hp-hr Maximum Heat Input: 1.50 mmbtu/hr Maximum Fuel Use°: 13.1 mmscf/yr Controls: NSCR catalyst 1498.23 a Site -rated bhp; Maximum 186 bhp derated 3% per each 1000 ft above 1500 ft mean sea level (msl; nominal site elevation is 5000 ft msl). n Based on FHV of: 1000 btu/scf Criteria Pollutant Emission Calculations Pollutant Emission Factors ` Potential Emissions (ton/yr) Control Efficiency (%) Uncontrolled Controlled Uncontrolled Controlled NOx 11.5 g/bhp-hr 3 g/bhp-hr 18.49 4.82 74% CO 15 g/bhp-hr 1 g/bhp-hr 24.11 1.61 93% NMHC 0.3 g/bhp-hr 0.25 g/bhp-hr 0.48 0.40 17% PM10 0.01941 lb/mmbtu 0.01941 lb/mmbtu 0.13 0.13 0% SO2 5.88E-04 lb/mmbtu 5.88E-04 lb/mmbtu 0.004 0.004 0% Manufacturer's uncontrolled and controlled emission factors. Uncontrolled factors are for expected pre -control emissions (i.e., with air/fuel ratio set slightly rich of stoichiometric point to maximize control efficiency of catalyst) PM10 (the sum of condensable and filterable emission factors) and SO2 factors are from AP -42 Table 3.2-3. Non -Criteria Reportable Pollutant Calculations Pollutant HAP Emission factors (4 -stroke, rich burn engines) Potential Emissions (Ib/yr) De Minimis ° Bin (lb/yr) 1.1-Dichloroethane < 1.13E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 B 500 1,1,2,2-Tetrachloroethane 2.53E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 A 50 1,1,2-Trichloroethane < 1.53E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 A 50 1,3 -Butadiene 6.63E-04 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 9 A 50 1.3-Dichloropropene < 1.27E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 A 50 Acetaldehyde 2.79E-03 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 37 A 50 Acrolein 2.63E-03 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 35 A 50 Benzene 1.58E-03 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 21 A 50 Carbon Tetrachloride < 1.77E-05 lb/mmBtu, AP -42 Table 3.2.3 (July 2000 revision) 0 A 50 Chlorobenzene < 1.29E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 A 50 Chloroform < 1.37E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 A 50 Ethylbenzene < 2.48E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 C 1000 Ethylene Dibromide < 2.13E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 A 50 Formaldehyde 0.10 g/bhp-hr, GRI FIELD TEST DATA 321 A 50 Methanol 0.02 g/bhp-hr, GRI FIELD TEST DATA 64 C 1000 Methylene Chloride 4.12E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 1 A 50 Naphthalene < 9.71E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 1 B 500 PAH 1.41E-04 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 2 A 50 Styrene < 1.19E-05 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 C 1000 Toluene 5.58E-04 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 7 C 1000 Vinyl Chloride _ < 7.18E-06 lb/mmBtu, AP -42 Table 3.2-3 (July 2000 revision) 0 A 50 Xylene 0.0014 g/bhp-hr, GRI LITERATURE DATA 5 C 1000 total < 504 — -- ° Deminimis levels for reportable non -criteria pollutants, per Colorado Regulation No. 3. FormAPCD-102-Gilcrest Gas Plant 2012Ju1y 002,003 Page 2 of 20 8/16/2012 White Superior 8G825 Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC White Superior 8G825 w/ NSCR Site Specific Unit Rating a: 708 hp Operating Schedule: 8760 hr/yr BSFC: 8000 Btu/hp-hr Maximum Fuel Use °: 5.660 MSCF/hr 50 MMSCF/yr Maximum Heat Input: 5.66 MMBtu/hr a Site -rated bhp; 800 bhp derated 3.5% per each 1000 ft above 1500 ft elevation site elevation is 4770 ft MSI). ° Based on LHV of: 1000 Btu/SCF Criteria Pollutant Emission Calculations Pollutant Uncontrolled Emissions C Controlled Emissions d Emission Factors Data Source (lb/hr) (tpy) % Control (lb/hr) (tpy) NOx 12.00 g/bhp-hr manufacturer ' 18.73 I 82.04 83.3% 3.12 i. 13.67 CO 11.00 g/bhp-hr manufacturer 17.17 75.20 72.7% 4.68 20.51 VOC 0.40 g/bhp-hr I manufacturer/AP-42 0.62 1 2.73 50% I 0.31 1.37 SO2 5.88E-04 Ib/MMBtu '': AP -42 0.003 0.015 0% 0.003 : 0.015 TSP/PM10/PM2.5 1.94E-02 lb/MMBtu 1 AP -42 0.11 0.48 _ 0% 0.11 0.48 Hazardous Air Pollutant (HAP) Emission Calculations Pollutant Uncontrolled Emissions C Controlled Emissions d Emission Factors Data Source (Ib/yr) (tpy) % Control (Ib/yr) (tpy) 1,1,2,2-Tetrachloroethane < 2.53E-05 lb/MMBtu . EPA < 1 < 6.27E-04 50% < 1 < 3.14E-04 1,1,2-Trichloroethane < 1.53E-05 lb/MMBtu EPA < 1 ' < 3.79E-04 50% < 0 < 1.90E-04 1,3 -Butadiene < 6.63E-04 Ib/MMBtu I EPA < 33 < 1.64E-02 50% < 16 < 8.22E-03 1,3 Dichloropropene 1.27E-05 lb/MMBtu EPA 1 I 0.00 50% 0 0.00 Acetaldehyde < 2.79E-03 Ib/MMBtu I EPA < 138 i < 6.92E-02 50% < 69 I < 3.46E-02 Acrolein 2.63E-03 lb/MMBtu I EPA 130 0.07 50% I 65 0.03 Benzene 1.58E-03 lb/MMBtu I EPA . 78 3.92E-02 50% 39 i 1.96E-02 Carbon Tetrachloride 1.77E-05 Ib/MMBtu I EPA 0.9 4.39E-04 50% 0.4 2.19E-04 Chlorobenzene 1.29E-05 lb/MMBtu I EPA 0.6 3.20E-04 50% 0.3 ° 1.60E-04 Chloroform 1.37E-05 lb/MMBtu EPA 1 0.00 50% 0 • 0.00 Ethylbenzene 2.48E-05 lb/MMBtu € EPA 1 0.00 50% 1 0.00 Ethylene Dibromide 2.13E-05 lb/MMBtu I EPA 1.1 5.28E-04 50% 0.5 I 2.64E-04 Formaldehyde 0.10 g/bhp-hr I GRI FIELD TEST DATA ! 1367 I 0.68 50% 684 = 0.34 Methanol 0.02 g/bhp-hr I GRI FIELD TEST DATA _ 273 I 1.37E-01 50% 137 € 6.84E-02 Methylene Chloride 4.12E-05 lb/MMBtu . EPA 1 2.0 I 1.02E-03 50% 1.0 I 5.11E-04 Naphthalene 9.71E-05 lb/MMBtu EPA 4.8 I 2.41E-03 50% 2.4 1.20E-03 PAH < 1.41E-04 lb/MMBtu I EPA < 7 ? < 3.50E-03 50% < 3 < 1.75E-03 Styrene 1.19E-05 lb/MMBtu I EPA 0.6 2.95E-04 50% 0.3 I 1.48E-04 Toluene 5.58E-04 Ib/MMBtu I EPA 28 0.01 50% I 14 0.01 Vinyl Chloride 7.18E-06 Ib/MMBtu , EPA 0 1.78E-04 50% 0 I 8.90E-05 Xylenes(m,p,o) 0.0014 g/bhp-hr GRI LITERATURE DATA: 19 0.01 50% 10 0.00 HAP Totals < 1.53E-01 g/bhp-hr I I < 2089 I < 1.04 50% I < 1045 ! < 0.52 c Manufacturer's pre -catalyst uncontrolled emission factors (EF) for NOX and CO. Uncontrolled VOC EF is manufacturer's controlled NMNEHC EF backcalculated assuming 50% control efficiency. PM10 and SO2 EF are from AP -42, Table 3.2-3 (PM10 EF is sum of condensable and filterable EF and is equivalent to PM2.5 and total PM EF for 4 -stroke, rich -bum (4SRB) engines). Uncontrolled HAP EF for 4SRB engines from EPA's AP 42 and GRI-HAPCalc 3.01 (the highest EF between the data sets is used here). d Controlled emissions are based on uncontrolled EF and the indicated catalyst control efficiencies. Control efficiencies for NOX and CO are calculated based on indicated pre -catalyst EF and manufacturer's post -catalyst EF (2.0 g/hp-hr NOX and 3.0 g/hp-hr CO). 005 Page 3 of 20 8116/2012 Caterpillar L5790GSI Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC Waukesha L5790GS1 - Reciprocating internal Combustion Engine (4SRB) w/AFRC & NSCR Site Specific Unit Rating a: 1215 hp Operating Schedule: 8760 hr/yr BSFC: 8000 Btu/hp-hr Maximum Fuel Use °: 9.720 MSCF/hr 85.2 MMSCF/yr Maximum Heat Input: 9.72 MMBtu/hr a Maximum design engine output. ° Based on LHV of: 1000 Btu/SCF Criteria Pollutant Emission Calculations Pollutant Uncontrolled Emissions C Controlled Emissions d Emission Factors Data Source (lb/hr) (tpy) % Control (lb/hr) (tpy) NOx 11.00 g/bhp-hr manufacturer 29.46 129.06 93.6% 1.88 8.21 CO 8.00 g/bhp-hr manufacturer 21.43 93.86 87.5% 2.68 11.73 VOC 0.80 g/bhp-hr I manufacturer/AP-42 2.14 I 9.39 50% I 1.07 4.69 SO2 5.88E-04 lb/MMBtu '', AP -42 0.006 0.025 0% 0.006 : 0.025 TSP/PM10/PM2.5 1.94E-02 lb/MMBtu I AP -42 0.19 0.83 _ 0% 0.19 0.83 Hazardous Air Pollutant (HAP) Emission Calculations Pollutant Uncontrolled Emissions ` Controlled Emissions d Emission Factors Data Source (Ib/yr) (tpy) % Control (lb/yr) (tpy) 1,1,2,2-Tetrachloroethane < 2.53E-05 lb/MMBtu . EPA < 2 € < 1.08E-03 50% < 1 < 5.39E-04 1,1,2-Trichloroethane < 1.53E-05 lb/MMBtu EPA < 1 ' <6.51E-04 50% < 1 <3.26E-04 1,3 -Butadiene < 6.63E-04 lb/MMBtu I EPA < 56 I < 2.82E-02 50% < 28 < 1.41E-02 1,3-Dichloropropene 1.27E-05 lb/MMBtu EPA 1 I 0.00 50% 1 0.00 Acetaldehyde < 2.79E-03 lb/MMBtu 1 EPA < 238 I < 1.19E-01 50% < 119 < 5.94E-02 Acrolein 2.63E-03 lb/MMBtu I EPA 224 0.11 50% 1 112 0.06 Benzene 1.58E-03 Ib/MMBtu I EPA 135 I 6.73E-02 50% 67 s 3.36E-02 Carbon Tetrachloride 1.77E-05 Ib/MMBtu I EPA 1.5 7.54E-04 50% 0.8 3.77E-04 Chlorobenzene 1.29E-05 lb/MMBtu I EPA 1.1 1 5.49E-04 50% 0.5 ° 2.75E-04 Chloroform 1.37E-05 lb/MMBtu EPA 1 0.00 50% 1 • 0.00 Ethylbenzene 2.48E-05 lb/MMBtu € EPA 2 0.00 50% 1 0.00 Ethylene Dibromide 2.13E-05 Ib/MMBtu I EPA 1.8 9.07E-04 50% 0.9 I 4.53E-04 Formaldehyde 0.10 g/bhp-hr 1 GRI FIELD TEST DATA ! 2346 I 1.17 50% 1173 = 0.59 Methanol 0.02 g/bhp-hr I GRI FIELD TEST DATA _ 469 ; 2.35E-01 50% 235 € 1.17E-01 Methylene Chloride 4.12E-05 lb/MMBtu . EPA 1 3.5 I 1.75E-03 50% 1.8 1 8.77E-04 Naphthalene 9.71E-05 lb/MMBtu EPA 8.3 `:. 4.13E-03 50% 4.1 2.07E-03 PAH < 1.41E-04 lb/MMBtu 1 EPA < 12 ? < 6.00E-03 50% < 6 < 3.00E-03 Styrene 1.19E-05 lb/MMBtu I EPA 1.0 5.07E-04 50% i 0.5 i 2.53E-04 Toluene 5.58E-04 lb/MMBtu i EPA 48 0.02 50% 24 0.01 Vinyl Chloride 7.18E-06 lb/MMBtu i EPA 1 I 3.06E 04 50% 0 i 1.53E-04 Xylenes(m,p,o) 0.0014 g/bhp-hr GRI LITERATURE DATA` 33 0.02 50% 16 0.01 HAP Totals < 1.53E-01 g/bhp-hr -- < 3586 . < 1.79 50% _• < 1793 = < 0.90 c Manufacturer's pre -catalyst uncontrolled emission factors (EF) for NOX and CO. Uncontrolled VOC EF is manufacturer's controlled NMNEHC EF backcalculated assuming 50% control efficiency. PM10 and SO2 EF are from AP -42, Table 3.2-3 (PM10 EF is sum of condensable and filterable EF and is equivalent to PM2.5 and total PM EF for 4 -stroke, rich -bum (4SRB) engines). Uncontrolled HAP EF for 4SRB engines from EPA's AP 42 and GRI-HAPCalc 3.01 (the highest EF between the data sets is used here). d Controlled emissions are based on uncontrolled EF and the indicated catalyst control efficiencies. Control efficiencies for NOX and CO are calculated based on indicated pre -catalyst EF and manufacturer's post -catalyst EF (0.7 g/hp-hr NOX and 1.0 g/hp-hr CO). 007,016 Page 4 of 20 8/16/2012 ] / ) § a) k ) /� o 6.k U, §0 22\ \ ) = S o ] e.,••c 2 f@ /a a co -� ;e G o$ $\ j CO 1:30 CO k o 2 2 / ; > e m & -O f b \ Q j\ m q O! EL LL 7, O co \ % c / ? k c O 2 2_ 8 !.E- 0 E 2 EEgq/ Bo. \\ $6�rQ»% ek Q. {) §) �i 7Ja 2� \f o— /\ \\ \c \> %Vi %{ a) a) a2 E co co E �fi )§ «\& >- co co \j kW C«_ C§ o > § ) O Total VOC vented: FormAPCD-102-Gilcrest Gas Plant_2012JuIy 010 Caterpillar L7044GSI Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC Waukesha L7044GS1 - Reciprocating internal Combustion Engine (4SRB) w/AFRC & NSCR Site Specific Unit Rating a: 1680 hp Operating Schedule: 8760 hr/yr BSFC: 7650 Btu/hp-hr Maximum Fuel Use °: 12.850 MSCF/hr 112.6 MMSCF/yr Maximum Heat Input: 12.85 MMBtu/hr a Maximum design engine output. ° Based on LHV of: 1000 Btu/SCF Criteria Pollutant Emission Calculations Pollutant Uncontrolled Emissions C Controlled Emissions d Emission Factors Data Source (lb/hr) (tpy) % Control (lb/hr) (tpy) NOx 13.1 g/bhp-hr manufacturer 1 48.52 1 212.5 92.4% 3.70 16.2 CO 11.7 g/bhp-hr manufacturer 43.33 189.8 91.5% 3.70 16.2 VOC 0.5 g/bhp-hr I manufacturer 1.85 I 8.1 50% I 0.93 4.1 SO2 5.88E-04 lb/MMBtu AP -42 0.008 0.03 0% 0.008 _ 0.03 TSP/PM10/PM2.5 1.94E-02 lb/MMBtu AP -42 0.25 1.1 0% 0.25 1.1 Hazardous Air Pollutant (HAP) Emission Calculations Pollutant Uncontrolled Emissions ` Controlled Emissions d Emission Factors Data Source (lb/yr) (tpy) % Control (lb/yr) (tpy) 1,1,2,2-Tetrachloroethane < 2.53E-05 lb/MMBtu . EPA < 3 i < 1.42E-03 50% < 1 I < 7.12E-04 1,1,2-Trichloroethane < 1.53E-05 lb/MMBtu EPA <2 i <8.61E-04 50% < 1 <4.31E-04 1,3 -Butadiene < 6.63E-04 lb/MMBtu I EPA < 75 I < 3.73E-02 50% < 37 < 1.87E-02 1,3-Dichloropropene 1.27E-05 lb/MMBtu EPA 1 I 0.00 50% 1 0.00 Acetaldehyde < 2.79E-03 lb/MMBtu I EPA < 314 I < 1.57E-01 50% < 157 < 7.85E-02 Acrolein 2.63E-03 lb/MMBtu I EPA 296 I 0.15 50% I 148 0.07 Benzene 1.58E-03 Ib/MMBtu I EPA . 178 I 8.89E-02 50% 89 i 4.45E-02 Carbon Tetrachloride 1.77E-05 Ib/MMBtu 1 EPA 2.0 9.96E-04 50% 1.0 4.98E-04 Chlorobenzene 1.29E-05 lb/MMBtu I EPA 1.5 7.26E-04 50% 0.7 ° 3.63E-04 Chloroform 1.37E-05 lb/MMBtu EPA 2 0.00 50% 1 • 0.00 Ethylbenzene 2.48E-05 lb/MMBtu € EPA 3 0.00 50% 1 0.00 Ethylene Dibromide 2.13E-05 Ib/MMBtu I EPA 2.4 1.20E-03 50% 1.2 I 5.99E-04 Formaldehyde 0.10 g/bhp-hr 1 GRI FIELD TEST DATA I 3245 I 1.62 50% 1622 = 0.81 Methanol 0.02 g/bhp-hr I GRI FIELD TEST DATA I 649 I 3.24E-01 50% 324 € 1.62E-01 Methylene Chloride 4.12E-05 lb/MMBtu . EPA I 4.6 I 2.32E-03 50% 2.3 1 1.16E-03 Naphthalene 9.71E-05 lb/MMBtu EPA 10.9 I 5.47E-03 50% 5.5 2.73E-03 PAH < 1.41E-04 lb/MMBtu 1 EPA < 16 < 7.94E-03 50% < 8 < 3.97E-03 Styrene 1.19E-05 lb/MMBtu I EPA 1.3 6.70E-04 50% 0.7 i 3.35E-04 Toluene 5.58E-04 lb/MMBtu i EPA 63 0.03 50% I 31 0.02 Vinyl Chloride 7.18E-06 lb/MMBtu , EPA 1 I 4.04E-04 50% 0 i 2.02E-04 Xylenes(m,p,o) 0.0014 g/bhp-hr GRI LITERATURE DATA` 45 0.02 50% 23 0.01 HAP Totals < 1.51E-01 g/bhp-hr -- < 4914 . < 2.46 50% _• < 2457 = < 1.23 c Manufacturer's pre -catalyst uncontrolled emission factors (EF) for NOX and CO. Uncontrolled VOC EF is manufacturer's controlled NMNEHC EF backcalculated assuming 50% contol efficiency. PM10 and SO2 EF are from AP -42, Table 3.2-3 (PM10 EF is sum of condensable and filterable EF and is equivalent to PM2.5 and total PM EF for 4 -stroke, rich -bum (4SRB) engines). Uncontrolled HAP EF for 4SRB engines from EPA's AP 42 and GRI-HAPCalc 3.01 (the highest EF between the data sets is used here). d Controlled emissions are based on uncontrolled EF and the indicated catalyst control efficiencies. Control efficiencies for NOX and CO are calculated based on indicated pre -catalyst EF and manufacturer's post -catalyst EF (0.1 g/hp-hr NOX and 1.0 g/hp-hr CO). 011 Page 6 of 20 6/16/2012 Uncontrolled Emissions f 1 n -Hexane v cn O co O U) CV uD O O O r Ch CV V f� CD co O O O O CV O I NV O,- 0 0 0 9509 2,2,4 TMP O N O ;754D O O 41 O O c— N OD O O O co Ci O: O 0 co 0 0 0 l'7 g •=- CO CD Xylene Er Jo cn N O O M O c) N. 0 2) O Ul T? E N N 0 0 O O a I V O• N 0 co 0 4385 EB N O M O co p O In O • c... CV Ul 0 0 0 0 0 I g O 0 0 0 O 1063 '=-' Toluene ^ 5426 d O) O N O f+ c) g2 O t.e. 4n g N 0 0 0 0 0 I s O N O 0 0 Benzene v 15 O) O as, O 1� O N O Ul N CO N.- 0 0 0 0 0 : N O N O O O 0 N VOC 88.7 772 . O) to _ C cl M O O Nr O O O N O (O 0 0 0 0 0 0 1 fM O O O 0 0 (ton/yr) N M O � O) O • O 6) ' O M O I• O• M co O- • f� O (O O 0 0 0 0 0' 0• 0 ' C7 O CO O O O O t"') r Control Efficiency (%) LDAR Program e r.9.' ' c 0(�000000000000Q c e c n c c c o 3 3� o 0 0% 0% 45% 0% 0 0 o I O O O ip U) Equipment Modification ° o I 13542 Total: -- O O O O O O O O O O O O O O O O o O O O O O - I 0 0 0 o O 0 0 0 0 0 0 0 0 0 0 0 o O O o 0 0 0 Factor b kg/hr/comp onent 4.5E-03 8.4E-06 2.5E-03 9.8E-05 3.9E-04 3.9E-07 1.1E-04 2.9E-06 2.0E-04 7.5E-06 2.1E-04 1.1E-04 c))__)CO N CO M O M N O O O O w w w w 9 0 9 w-13 w w 0 0 9 0 w w w w O V Tr O CV c- CV V' el. <! C4 1- Oi O N U1 R OD ci % l- Service Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Quantity a N O n 0 CD 0 00 0 u) 0 0 0 0 0 0 N O C' O 0 0 N OD (O CO CO N Equipment Type Valves co d co C ta Connectors Open-ended lines Pump Seals Other Components IL d Control efficiency (CE) for equipment modifications per Table 5-1 of EPA 45318.95.017: 100% CE for open-ended lines with blinds, caps, or plugs (as required by NSPS KKK). • Control efficiency for quarterly LDAR monitoring per FORM APCD-203: monthly control efficiencies may be used in tracking actual emissions if monitoring is performed monthly (88% gas valve. 76% It oil valves, 68% It oil pumps). Volatile Organic Compound (VOC) and Hazardous Air Pollutant (HAP) emissions based on controlled TOC emissions and conservative estimate of mass % of individual constituents as follows: •00 O C C Ti • e o C G v 0 • d w C w cs C U 0 0 O 0 0 N 0 fV 3 3 g 0 CD O N O CD a FormAPCD-102-Gilcrest Gas Plant_2012July: 014 GILCREST GAS PLANT en w J H Z w n. 5 a 0 2 N 4b LL O (7 I✓/ w U 0 Emissions f 1 n -Hexane Ja CA O N O N CD 0 0 0 et Is CD Ce 0 0 0 0 0 I N O rs 0 0 0 4378 2,2,4 TMP la 4- O CV 0 0 0,_ O O 4- N to O O O O O , t+j 0 M 0 0 0 0 CD Xylene =.• 53 O N O ,- i- O 33 O Ul Tr N 0 0 0 0 0 I M O,_ O O O O N EB 4 O O N O N- O O. 4- co to O O O O O I M O N. o 0 0 0 515 Controlled Toluene j) O C OCS' O h 0^ O to co N p 0 0 0 �p 0 I tD O N p 0 0 2617 Benzene 12- 23„ :7-, 00 O V' O CD 1s O N O CO ,_ N to N 0 0 0 0 0 : E O N 0 0 0 is. 0 ,- VOC CO • W O O e- O • O O N O (O 0 0 0 0 0 0 0 i r 0•00000) 01 TOC (ton/yr) ) Csj O cli O N 0 M O • n O M a • V O V• M 1- O (O O O O O O O; n O e- 0 OD O O O 0 02 ca CO Control Efficiency (%) LDAR Program e 70% 0% 61% 0% e o 0 0 D D o o 0 0 0 0 O 0 O 0 D D D D 0 0 0 0 0 o a o o o D D 0 0 0 0 0% 0% 45% 0% 0 0 o D D D 0 0 0 1 ae a O 0 Equipment Modification d 0000eo D D D D O O O O O D 0 0 O O O O ovooeeee D D D D O O O O O O O O O O o 0 00000 D D D D 0 0 0 0 D D D I 0 0 0 0 ~ N M Factor b kg/hr/comp onent 4.5E-03 8.4E-06 2.5E-03 9.8E-05 3.9E-04 3.9E-07 1.1E-04 2.9E-06 g o q Q O t[) r W_ N h N r 2.0E-03 1.4E-04 1.4E-03 2.5E-04 O Q O Tr C M. N . N 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Service Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil Gas Heavy Oil Light Oil Water/Oil A C CO 7 a M O N O QO cn O OD O O CO co CDM N 0 0 0 0 O O N O C) 0 0 0 Equipment Type Valves Flanges Connectors Open-ended lines Pump Seals Other Components d Control efficiency (CE) for equipment modifications per Table 5-1 of EPA 45318-95.017: 100%CE for open-ended lines with blinds, caps, or plugs (as required by NSPS KKK). • Control efficiency for quarterly LDAR monitoring per FORM APCD-203: monthly control efficiencies may be used in tracking actual emissions if monitoring is performed monthly (88% gas valve, 76% It oil valves, 68% It oil pumps r Volatile Organic Compound (VOC) and Hazardous Air Pollutant (HAP) emissions based on controlled TOC emissions and conservative estimate of mass % of individual constituents as follows: .21 0 0 0 0 0 0 M N r t0 CO 6 S O N O CO CO a FormAPCD-102-Gilcrest Gas Plant_2012July. 014 Aka Energy Group, LLC Gilcrest Gas Plant Heater Emission Calculations Eclipse Series FDS Hot Oil Heater (H-760) Unit Rating: 5.588 mmBTU/hr Fuel usage a: 0.00559 mmSCF/hr 48.97 mmSCF/yr Operating hours: 8760 hours a Based on fuel heat content of: 1000 BTU/SCF Criteria Pollutant Emission Calcuations Criteria Pollutant Emission Factor Data Source Emissions (tpy) NOx 100 lb/mmSCF AP -42 Section 1.4, Table 1.4-1 (July 1998 revision) 2.45 CO 84 lb/mmSCF AP -42 Section 1.4. Table 1.4-1 (July 1998 revision) 2.06 PM10 7.6 lb/mmSCF AP -42 Section 1.4. Table 1.4-2 (July 1998 revision) 0.19 SO2 0.6 lb/mmscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.015 VOC 5.5 lb/mmSCF AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.13 Non -reportable Criteria Pollutant Emission Calculations Hazardous Air Pollutant (HAP) Emission Factor b Data Source Emissions (lb/yr) Deminimus ` (lblyr) 1,3 -Butadiene 3.42E-04 lb/mmBTU GRI FIELD TEST DATA 16.8 50 2,2,4-Trimethylpentane 2.84E-03 lb/mmBTU GRI FIELD TEST DATA 139.1 1000 Acetaldehyde 7.38E-04 Ib/mmBTU GRI FIELD TEST DATA 36.1 50 Benzene 7.48E-04 Ib/mmBTU GRI FIELD TEST DATA 36.6 50 Biphenyl 4.73E-07 lb/mmBTU GRI FIELD TEST DATA 2.32E-02 1000 Dichlorobenzene 1.18E-06 Ib/mmBTU EPA 0.1 — Ethylbenzene 2.11E-03 Ib/mmBTU GRI FIELD TEST DATA 103.4 1000 Fluorene 8.00E-08 Ib/mmBTU GRI FIELD TEST DATA 3.92E-03 1000 Formaldehyde 8.44E-04 lb/mmBTU GRI FIELD TEST DATA 41.3 50 Methanol 9.64E-04 Ib/mmBTU GRI FIELD TEST DATA 47.2 1000 Naphthalene 5.98E-07 lb/mmBTU EPA 2.93E-02 500 n -Hexane 1.76E-03 lb/mmBTU EPA 86.4 1000 Phenol 1.07E-07 Ib/mmBTU GRI FIELD TEST DATA 5.24E-03 1000 Polycyclic Organic Matter (POM): 2-Methylnaphthalene 1.47E-07 Ib/mmBTU GRI FIELD TEST DATA 7.20E-03 — 3-Methylchloranthrene 1.80E-09 lb/mmBTU EPA 8.81E-05 -- 7.12-Dimethylbenz(a)anthracene 1.57E-08 Ib/mmBTU EPA 7.69E-04 -- Acenaphthene 9.00E-08 Ib/mmBTU GRI FIELD TEST DATA 4.41E-03 -- Acenaphthylene 6.70E-08 Ib/mmBTU GRI FIELD TEST DATA 3.28E-03 -- Anthracene 8.70E-08 Ib/mmBTU GRI FIELD TEST DATA 4.26E-03 -- Benz(a)anthracene 8.70E-08 lb/mmBTU GRI FIELD TEST DATA 4.26E-03 -- Benzo(a)pyrene 7.00E-08 lb/mmBTU GRI FIELD TEST DATA 3.43E-03 -- Benzo(b)fluoranthene 1.50E-07 Ib/mmBTU GRI FIELD TEST DATA 7.34E-03 -- Benzo(g,h,i)perylene 2.60E-07 lb/mmBTU GRI FIELD TEST DATA 1.27E-02 -- Benzo(k)fluoranthene 7.60E-07 Ib/mmBTU GRI FIELD TEST DATA 3.72E-02 -- Chrysene 1.17E-07 Ib/mmBTU GRI FIELD TEST DATA 5.73E-03 -- Dibenz(a,h)anthracene 1.03E-07 Ib/mmBTU GRI FIELD TEST DATA 5.04E-03 -- Fluoranthene 9.00E-08 Ib/mmBTU GRI FIELD TEST DATA 4.41E-03 — Indeno(1,2,3-c,d)pyrene 1.20E-07 lb/mmBTU GRI FIELD TEST DATA 5.87E-03 -- Phenanthrene 6.00E-08 Ib/mmBTU GRI FIELD TEST DATA 2.94E-03 — Pyrene 8.30E-08 Ib/mmBTU GRI FIELD TEST DATA 4.06E-03 -- TOTAL POM 0.1 50 Styrene 2.08E-03 Ib/mmBTU GRI FIELD TEST DATA 101.8 1000 Toluene 1.02E-03 Ib/mmBTU GRI FIELD TEST DATA 49.8 1000 Xylenes(m,p,o) 1.32E-03 lb/mmBTU GRI FIELD TEST DATA 64.6 1000 TOTAL 723.3 -- b Uncontrolled emission factors for HAP from heaters g 5 mmBTUlhr from GRI-HAPCaIc 3.01, based on a composite of EPA's AP -42, GRI field data and GRI literature data. The highest emission factor between the data sets is listed here in order to provide a conservative estimate of HAP emissions from heaters. ° Deminimis levels for reportable non -criteria pollutants, per Colorado Regulation No. 3. FormAPCD-102-Gilcrest Gas Plant 2012Ju1y:015 Page 9 of 20 8/16/2012 Aka Energy Group, LLC Gilcrest Gas Plant APEN-exempt Heater Emission Calculations Unit 11-750 - Regen Gas heater 11-770 - }lot Oil Heater Unit Rating: 3.08 mmhnt hr 4 nunbnrhr Fuel usage'' 0.00308 mmscfhr 0.00400 mmscf''hr 26.98 mmscf VT 35.04 mmscf yr Operating hours. 87(6(1 hours 8760 hours ' Based on fuel heat content of: Emission Calculations: 1000 but scf Criteria Pollutant Emission Factor Data Source Emissions (tons/yr) H-750 11-770 i\Ox 100 lb nunscf AP -42 Section 1.4, '1 -able L4-1 (July 1998 recision) 1.35 1.75 CO 84 lb, rnn,scf AP -42 Section 1.4. Table 1.4-I (July 1998 revision) 1.13 1.47 P1)4107.G lb, moue( AP -42 Section 1.4. Table 1.4-2 (July 1998 revision) 0.10 0.13 5O'_ 0.6 Iblmmscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.008 0.01 VOC 5.5 Ib nunscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.07 0.10 hazardous Air Pollutant (HAP) Emission Factor' Data Source Emissions (Ib/vr) H-750 11-770 1,3 -Butadiene 3.42E-04 Ib/mmBTU GRI FIELD TEST DATA 9 12 2,2,4-Trimethylpentane 2.84E-03 Ib/mmBTU GRI FIELD TEST DATA 77 100 Acetaldehyde 7.38E-04 Ib/mmBTU GRI FIELD TEST DATA 20 26 Benzene 7.48E-04 Ib/mmBTU GRI FIELD TEST DATA 20 26 Biphenyl 4.73E-07 Ib/mmBTU GRI FIELD TEST DATA 0.01 0.02 Dichlorobenzene 1.18E-06 Ib/mmBTU EPA 0.03 0.04 Ethylbenzene 2.11E-03 Ib/mmBTU GRI FIELD TEST DATA 57 74 Fluorene 8.00E-08 Ib/mmBTU GRI FIELD TEST DATA 0.002 0.003 Formaldehyde 8.44E-04 Ib/mmBTU GRI FIELD TEST DATA 23 30 Methanol 9.64E-04 Ib/mmBTU GRI FIELD TEST DATA 26 34 Naphthalene 5.98E-07 Ib/mmBTU EPA 0.02 0.02 n -Hexane 1.76E-03 Ib/mmBTU EPA 48 62 Phenol 1.07E-07 Ib/mmBTU GRI FIELD TEST DATA 0.003 0.004 Polycyclic Organic Matter (POMP: 2-Methylnaphthalene 1.47E-07 Ib/mmBTU GRI FIELD TEST DATA 0004 0005 3-Methylchloranthrene 1.80E-09 Ib/mmBTU EPA 0.0000 0.0001 7,12-Dimethylbenz(a)anthracel 1.57E-08 Ib/mmBTU EPA 0.0004 0.0006 Acenaphthene 9.00E-08 Ib/mmBTU GRI FIELD TEST DATA 0-002 0-003 Acenaphthylene 6.70E-08 Ib/mmBTU GRI FIELD TEST DATA 0.002 0.002 Anthracene 8.70E-08 Ib/mmBTU GRI FIELD TEST DATA 0.002 0.003 Benz(a)anthracene 8.70E-08 Ib/mmBTU GRI FIELD TEST DATA 0.002 0.003 Benzo(a)pyrene 7.00E-08 Ib/mmBTU GRI FIELD TEST DATA 0.002 0.002 Benzo(b)fluoranthene 1.50E-07 Ib/mmBTU GRI FIELD TEST DATA 0.004 0.005 Benzo(g,h,i)perylene 2.60E-07 Ib/mmBTU GRI FIELD TEST DATA 0007 0.009 Benzo(k)fluoranthene 7.60E-07 Ib/mmBTU GRI FIELD TEST DATA 0.021 0.027 Chrysene 1.17E-07 Ib/mmBTU GRI FIELD TEST DATA 0-003 0.004 Dibenz(a.h)anthracene 1.03E-07 Ib/mmBTU GRI FIELD TEST DATA 0.003 0.004 Fluoranthene 9.00E-08 Ib/mmBTU GRI FIELD TEST DATA 0.002 0-003 Indeno(J,2,3-c,d)pyrene 1.20E-07 Ib/mmBTU GRI FIELD TEST DATA 0.003 0-004 Phenanthrene 6.00E-08 Ib/mmBTU GRI FIELD TEST DATA 0.002 0.002 Pyrene 8.30E-08 Ib/mmBTU GRI FIELD TEST DATA 0.002 0.003 TOTAL POM 2.31E-06 Ib/mmBTU 0.1 0.1 Styrene 2.08E-03 Ib/mmBTU GRI FIELD TEST DATA 56 73 Toluene 1.02E-03 Ib/mmBTU GRI FIELD TEST DATA 27 36 Xylenes(m,p,o) 1.32E-03 Ib/mmBTU GRI FIELD TEST DATA 36 46 TOTAL 1.48E-02 Ib/mmBTU 398.7 517.7 t !rnnntrulled eons sron factors for HAP from heaters 5', 5' mbhrlu from GRI-HAPCatc 3.01. based on a composite of EPA's AP --12, GRI field t) io and GRI Inerahmc dais The highest eruusron fact n between the data sets is listed bat m eider to provides conservative estimate of HAP emissions from healers. b Dendnlmts levels for reportable non -criteria pollutants, per Colorado Regulation No. 3. ForrnAPCD-102-Gilcrest Gas Plant 2012July: APEN-exempt heaters Page 10 0) 20 8/1612012 Caterpillar G3520B Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC C10 Caterpillar G3520B - Reciprocating Internal Combustion Engine (4SLB) w/AFRC 8 Oxidation Catalyst Site Specific Unit Rating a: 1725 hp Operating Schedule: 8760 hr/yr BSFC: 7029 Btu/hp-hr Maximum Fuel Use b: 11.663 MSCF/hr 102.2 MMSCF/yr Maximum Heat Input: 12.13 MMBtu/hr ' Maximum design engine output @ 4771' msl site elevation and reduced inlet air temperature. b Based on LHV of: 1040 Btu/SCF Criteria Pollutant Emission Calculations Pollutant Uncontrolled Emissions ` Controlled Emissions d Emission Factors Data Source I (lb/hr) (tpy) % Control ? (lb/hr) (tpy) NOx 1.00 g/bhp-hr manufacturer 3.80 16.66 0% 3.80 16.66 CO 2.55 g/bhp-hr manufacturer 9.70 42.48 93% 0.68 _ 2.97 VOC 0.84 9/bhp-hr i manufacturer/AP 42 I 3.19 13.99 50% 1.60 i 7.00 SO2 5.88E-04 lb/MMBtu AP 42 0.01 0.03 0% 0.01 i 0.03 TSP/PM10/PM2.5 9.99E-03 lb/MMBtu ' AP42 0.12 0.53 0% 0.12 ! 0.53 Hazardous Air Pollutant (HAP) Emission Calculations Pollutant Uncontrolled Emissions ` Controlled Emissions ° Emission Factors . Data Source 1 (lb/yr) (tpy) % Control 1 (Ib/yr) I (tpy) 1,1,2,2-Tetrachloroethane < 4.00E-05 lb/MMBtu AP 42 < 4 < 2.13E-03 50% < 2 < 1.06E-03 1.1,2-Trichloroethane < 3.18E-05 lb/MMBtu . AP 42 < 3 < 1.69E-03 50% : < 2 ; < 8.45E-04 1.1-Dichloroethane < 2.36E-05 lb/MMBtu AP 42 < 3 < 1.25E-03 50% < 1 < 6.27E-04 1,3 -Butadiene 2.67E-04 lb/MMBtu AP 42 28 0.01 50% 14 r 0.01 1.3-Dichloropropene < 2.64E-05 lb/MMBtu AP 42 < 3 < 1.40E-03 50% < 1 I < 7.01E-04 2,2,4-Trimethylpentane 2.50E-04 lb/MMBtu AP 42 26.6 0.01 50% I 13.3 0.01 2-Methylnaphthalene 3.32E-05 lb/MMBtu '•. AP 42 1 4 i 1.76E-03 50% I 2 8.82E-04 Acenaphthene 1.25E-06 lb/MMBtu AP 42 0.1 6.64E-05 50% 0.1 I 3.32E-05 Acenaphthylene 5.53E-06 lb/MMBtu AP 42 _ 0.6 I 2.94E-04 50% i 0.3 1.47E-04 Acetaldehyde 8.36E-03 lb/MMBtu AP 42 888 0.44 50% i 0.22 Acrolein 5.14E-03 lb/MMBtu AP 42 546 0.27 50% 273 0.14 Benzene 1.30E-03 lb/MMBtu GRI LITERATURE I 138 0.07 50% i 69 0.03 Benzo(b)fluoranthene 1.66E-07 lb/MMBtu AP42 0.02 8.82E-06 50% 0.01 € 4.41E-06 Benzo(e)pyrene 4.15E-07 lb/MMBtu AP 42 0.04 i 2.20E-05 50% 0.02 ' 1.10E-05 Benzo(g,h,i)perylene 4.14E-07 lb/MMBtu AP 42 0.04 2.20E-05 50% I 0.02 1.10E-05 Biphenyl 2.38E-04 lb/MMBtu GRI FIELD TEST I 25 0.01 50% 13 0.01 Carbon Tetrachloride < 3.67E-05 lb/MMBtu AP 42 < 4 < 1.95E-03 50% <2 I. < 9.75E-04 Chtorobenzene < 3.04E-05 lb/MMBtu AP 42 < 3 9 < 1.62E-03 50% i < 2 I < 8.08E-04 Chloroform < 2.85E-05 lb/MMBtu AP 42 < 3 < 1.51E-03 50% I < 2 € < 7.57E-04 Chrysene 6.93E-07 lb/MMBtu AP 42 0.07 3.68E-05 50% 0.04 ' 1.84E-05 Ethylbenzene 3.97E-05 lb/MMBtu AP42 i 4.2 2.11E-03 50% i 2.1 I 1.05E-03 Ethylene Dibromide < 4.43E-05 lb/MMBtu AP 42 < 5 < 2.35E-03 50% < 2 € < 1.18E-03 Fluoranthene 1.11E-06 lb/MMBtu AP42 0.12 . 5.90E-05 50% I 0.06 € 2.95E-05 Fluorene 1.11E-05 lb/MMBtu GRI FIELD TEST € 1.2 i 5.90E-04 50% i 0.6 I 2.95E-04 Formaldehyde 0.43 g/bhp-hr manufacturer 14325 7.16 75% 3581 1.79 Methanol 2.50E-03 lb/MMBtu AP 42 1 266 0.13 50% 133 0.07 Methylene Chloride 2.00E-05 lb/MMBtu AP 42 _ 2 1.06E-03 50% 1 I 5.31E-04 Naphthalene 7.44E-05 lb/MMBtu AP 42 8 s 3.95E-03 50% 4 I 1.98E-03 n -Hexane 1.11E-03 lb/MMBtu AP42 118 0.06 50% i 59 i 0.03 PAH 2.69E-05 lb/MMBtu AP 42 3 1.43E-03 50% 1 7.15E-04 Phenanthrene 1.04E-05 lb/MMBtu AP 42 _ 1.1 1 5.53E-04 50% i 0.6 2.76E-04 Phenol 2.68E-05 lb/MMBtu GRI FIELD TEST 1 2.8 1.42E-03 50% 1.4 € 7.12E-04 Pyrene 1.36E-06 lb/MMBtu AP 42 0.1 ' 7.23E-05 50% 0.1 3.61E-05 Styrene < 2.36E-05 lb/MMBtu AP 42 . < 3 < 1.25E-03 50% i < 1 € < 6.27E-04 Tetrachloroethane 2.48E-06 lb/MMBtu AP 42 0.3 1.32E-04 50% 0.1 6.59E-05 Toluene 8.15E-03 lb/MMBtu GRI LITERATURE 866 0.43 50% 433 0.22 Vinyl Chloride 1.49E-05 lb/MMBtu . AP 42 2 7.92E-04 50% 1 € 3.96E-04 Xylenes(m.p,o) 2.73E-04 lb/MMBtu = GRI LITERATURE i 29.0 0.01 50% 14.5 I 0.01 HAP Totals < 5.20E-01 g/bhp-hr (calculated) < 17316 < 8.66 71% < 5077 , < 2.54 Manufacturer's uncontrolled emission factors (EF) for NOX, CO, and formaldehyde. VOC EF is sum of manufacturer's uncontrolled NMNEHC and formaldehyde EF plus AP 42 EF for acetaldehyde and butryaldehyde (NMNEHC EF does not include aldehydes). PM10 and SO2 EF are from AP 42, Table 3.2-2 (PM10 EF is sum of condensable and filterable EF and is equivalent to PM2.5 and total PM EF for 4 -stroke, lean -bum (4SLB) engines). Uncontrolled HAP EF for 4SLB engines (Ib/MMBtu) from EPA's AP 42 and GRI-HAPCalc 3.01; the highest EF between the data sets is used here (GRI field test and literature EF (g/hp-hr) were converted to (lb/MMBtu) using 7,276 Btu/hp- hr, per GRI-HAPCalc guidance). d Controlled emissions are based on uncontrolled EF and the indicated catalyst control efficiencies. G3520B Page 11 of 20 8/16/2012 Caterpillar G3306 Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC C8, C9 Caterpillar G3306 - Reciprocating internal Combustion Engine (4SRB) w/AFRC & NSCR Site Specific Unit Rating a: 195 hp Operating Schedule: 8760 hr/yr BSFC: 8149 Btu/hp-hr Maximum Fuel Use °: 1.529 MSCF/hr 13.4 MMSCF/yr Maximum Heat Input: 1.59 MMBtu/hr a Maximum design engine output @ 4771' msl site elevation and reduced inlet air temperature. ° Based on LHV of: 1040 Btu/SCF Criteria Pollutant Emission Calculations Pollutant Uncontrolled Emissions C Controlled Emissions d Emission Factors Data Source (lb/hr) (tpy) % Control (lb/hr) (tpy) NOx 16.50 g/bhp-hr manufacturer 7.09 I 31.07 94% 0.43 1.88 CO 16.50 g/bhp-hr manufacturer 7.09 31.07 88% 0.86 3.77 VOC 0.38 g/bhp-hr manufacturer/AP-42 0.16 1 0.72 50% I 0.08 0.36 SO2 5.88E-04 lb/MMBtu '': AP -42 0.001 0.004 0% 0.001 - 0.004 TSP/PM10/PM2.5 1.94E-02 lb/MMBtu AP -42 0.03 0.14 _ 0% 0.03 0.14 Hazardous Air Pollutant (HAP) Emission Calculations Pollutant Uncontrolled Emissions ` Controlled Emissions d Emission Factors Data Source (Ib/yr) (tpy) % Control (Ib/yr) (tpy) 1,1,2,2-Tetrachloroethane < 2.53E-05 lb/MMBtu . EPA < 0 i < 1.76E-04 50% < 0 I < 8.81E-05 1,1,2-Trichloroethane < 1.53E-05 lb/MMBtu EPA < 0 1 < 1.07E-04 50% < 0 < 5.33E-05 1,3 -Butadiene < 6.63E-04 Ib/MMBtu I EPA < 9 ' < 4.62E-03 50% < 5 < 2.31E-03 1,3 Dichloropropene 1.27E-05 lb/MMBtu EPA 0 I 0.00 50% 0 0.00 Acetaldehyde < 2.79E-03 lb/MMBtu 1 EPA < 39 I < 1.94E-02 50% < 19 I < 9.72E-03 Acrolein 2.63E-03 Ib/MMBtu I EPA 37 0.02 50% I 18 0.01 Benzene 1.58E-03 lb/MMBtu 1 EPA . 22 1.10E-02 50% 11 i 5.50E-03 Carbon Tetrachloride 1.77E-05 lb/MMBtu I EPA 0.2 1.23E-04 50% 0.1 6.16E-05 Chlorobenzene 1.29E-05 lb/MMBtu I EPA 0.2 8.98E-05 50% 0.1 ° 4.49E-05 Chloroform 1.37E-05 lb/MMBtu EPA 0 0.00 50% 0 • 0.00 Ethylbenzene 2.48E-05 Ib/MMBtu € EPA 0 0.00 50% 0 0.00 Ethylene Dibromide 2.13E-05 lb/MMBtu EPA 0.3 1.48E-04 50% 0.1 I 7.42E-05 Formaldehyde 0.25 g/bhp-hr 1 manufacturer 941 I 0.47 50% 471 = 0.24 Methanol 6.06E-03 Ib/MMBtu I GRI FIELD TEST DATA _ 84.4 4.22E-02 50% 42.2 € 2.11E-02 Methylene Chloride 4.12E-05 lb/MMBtu . EPA 1 0.6 1 2.87E-04 50% 0.3 1 1.43E-04 Naphthalene 9.71E-05 lb/MMBtu EPA 1.4 1 6.76E-04 50% 0.7 3.38E-04 PAH < 1.41E-04 lb/MMBtu 1 EPA < 2 ? < 9.82E-04 50% < 1 < 4.91E-04 Styrene 1.19E-05 lb/MMBtu I EPA 0.2 8.29E-05 50% i 0.1 I 4.14E-05 Toluene 5.58E-04 lb/MMBtu i EPA 8 0.00 50% i 4 0.00 Vinyl Chloride 7.18E-06 Ib/MMBtu , EPA 0 5.00E-05 50% 0 I 2.50E-05 Xylenes(m,p,o) 4.24E-04 lb/MMBtu GRI LITERATURE DATA` 5.9 0.00 50% 3.0 0.00 HAP Totals < 3.06E-01 g/bhp-hr -- < 1152 < 0.58 50% < 576 < 0.29 c Manufacturer's uncontrolled emission factors (EF) for NOX, CO, and formaldehyde. VOC EF is sum of manufacturer's uncontrolled NMNEHC and formaldehyde EF plus AP42 EF for acetaldehyde and butryaldehyde (NMNEHC EF does not include aldehydes). PM10 and SO2 EF are from AP -42, Table 3.2-3 (PM10 EF is sum of condensable and filterable EF and is equivalent to PM2.5 and total PM EF for 4 -stroke, rich -bum (4SRB) engines). Uncontrolled HAP EF for 4SRB engines (lb/MMBtu) from EPA's AP 42 and GRI-HAPCalc 3.01 (the highest EF between the data sets is used here). d Controlled emissions are based on uncontrolled EF and the indicated catalyst control efficiencies. Control efficiencies for NOX, CO and VOC are calculated based on indicated pre -catalyst EF and emission levels required by 40 CFR 60, subpart JJJJ (1.0 g/hp-hr NOX, 2 g/hp-hr CO, and 0.7 g/hp-hr VOC). G3306 Page 12 of 20 6/16/2012 C O c C E O co a) ti N N a C L N O > U) cn C 2 C o E O C° 0 U L E j E O z N O N U). E E N .C (a co E O E a N O O 0) CA N !A N CO C X a) f° O L m E N O w O� a) o y > D_O O E o U>• A C O a).m E U E 5 a) O O N ..L. C � C E _ O 03 U a c co L () U c C o •E � m � � O o E co "U— m CO U > a) � 2C 'E O N N w a) E O o Qw w o 0) Cl) .U)E E Y 7 V) Q Z a) N a) U) m a) 0. N N W Ca O. a) U) W C a) •0 > 0 a c a aL) N a x O ≤a E a) CD Y a) ≤a 0 U) U) ca O U) C O O U) E W O ^ O O °CNN- O N r Cfl O Uncontrolled C 000 o N. r L E O — o N 00 co o L O O MMSCF/day@STP .c E S 2a) E E�`a`° 3 z' z ° a o 0 E ELL79Eil- co ea o ca to _ L L O' O O to LL W 2 C N N. O O CO O _O U) N 01 LC) Cr) o^ O U) N ti O O O M 0 0 O CO O Cfl U) N U) CO ti U) r CO U) U) r CO N N O N N 0 Cr) O N O O r o r 0 0 N r U) U) CO Cr) r 0 M t!) Cf r 0 0 0 0 O O C) O 0 U) U) O 0 r O O 0 0 0 0 0 0 M O O O CO O O O O O O O O O O O r 0 0 0 0 0 C) Cl N CO 0 Tr 0 0 U) M O N N. N CO O CO Li) ON 000000 h O N 00 O CO O O 0 0 0 0 0 0 0 N O r et 0 0000000000 Cr) NOOr0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N C') U) r F— O d' co N 0 COP.CO CO 0) M CO CO 0 0 a) 0 0 O N- O N N N. co O O O O CO r" CO CO co O1.0U) 0000 0 . . - CO 00 N 0 0 0 0 0 0 0 CO 4 0 N M CO I- _O O d F- r 0 0) 0) r Tr d' CO CO CO M O N 0 0 N' CO MOM O r O O O 0 O O N M O CO t7 O O r 0 0 0 O O O O O O O• N.• O • 6.594762017 6.35773E-05 92.79882308 w x 0 a) wa Z E ce o < ! < U z 0.007212287 HYDROGEN SULFIDE 0.028497721 0.007459733 0.002114378 2.25597E-05 CNI LC) O O M U) O N O v oMM r r CO N CO (.6 0 M ' ' O O O 0.000370257 W W z W z Zilj Q Z a M I- < F=-0mma2 2waSzazz 0.000224014 N-HEPTANE 0.246183262 0.183463438 0.000550977 U) a) O N LLI O M CO CD c0 O N O 0 T- d w z w N z w w w W w zzmzz z-I=>X0< m�wOzo O N CO O Cr) 27122.9698 U) N N U) O CO LO cr COCO a)) CO Cfl Co ' O N O M 0 co to r O Amine Vent Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC 0 C Co . J U (1) E 3 Co N 0 w E O co 0 (/) c 2 m co • a) Q c Q , O 2 7) 0 .n O EE oU C CO c -0 .o11_) m ▪ E U) a C O N O to E 7 O L N o o m U) Co +-a 0 C O O N • U E N a) Co MI 0- 0 • C • C a N o 72 n. o ,O N iv Co 7 m U N in • 0 7, _ C) 0 .- o E o E co 7/1 a) N w O C « O 'C N L C • E 0 .O • O a) • CO• o) E vTo (6 7 • a 0 Ta - O c (simulation run vent stream flow @ 40 MMSCFD capacity) co co C) U (6 O C a) C U Co N L a C (6 0 0 C C O a a) m L a) U (6 a) N X 0 0 (I) (6 0 O N 0 0 CO o_ 0) O a) 2 CL W 'Cr) 0. O. C C a) 2 a) co CO L x a) a) U N O ((0 O Thermal Oxidizer o E 0 2 0 CO LOU) CO 0Co 0 in L U- 0 co N. N CO 0 CO 0 L O co w Amine vent flow to oxidizer: a) CO co L x W O L 0) c C U) 0. 0 14 Btu/SCF Emission Calculations: Emissions (lb/hr) I (tons/yr) (D M o WV' Co D1 ,- CO (D M 0o 0 0 () V 0 v V' 0 v CO 0 Data Source TNRCC RG-109 (Draft - October 2000) TNRCC RG-109 (Draft - October 2000) a AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) a Simulation run Emission Factor 0.1 lb/MMBtu 0.53 lb/MMBtu 7.6 I b/mmscf 1.03 lb/MMBtu Criteria Pollutant O O _o 2 O Z 0 a_ (.1) C) U)) O t6 0E N) 0 U C • _O Z Co E c O U C C U O • J C6 O .C O N U > 0 p_ E a O N � C • O LL v W _o co . 2 CO d c N O U Q E N 00 O 0 O aj c o x a) 0 a C 0 E o a • E c (6 0 Lk N a) O N o0 -01 (6 (6 R) • U O ▪ E E • 0 12 O U o ea U U N - a) C D) c CO M b 3 U' N L E a) 17)--- 0 -U o U N N a C +. N X E m o a) X z4 a) O O A (O 0 CD (D 0 C 2 •C 0 Co C U) 0 U U) N a) N 0 a a) U) > C O U a) cO .Q U) O 1 CO C O U .E a) V) N a) a) C .E co 0 O O_ C) c .E 7 a U) C U (6 U (n O CO N E U) 0 a FormAPCD-102-Gilcrest Gas Plant_2012JuIy: amine2 Amine Reboiler Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC Unit Amine Reboiler Unit Rating: 16 mmbtu/hr Fuel usage a: 0.01538 mmscf/hr 134.8 mmscf/yr Operating hours: 8760 hours a Based on fuel heat content of: Emission Calculations: 1040 btu/scf (maximum expected rating) Criteria Pollutant Emission Factor Data Source Emissions (tons/yr) NOX 100 lb/mmscf AP -42 Section 1.4, Table 1.4-1 (July 1998 revision) 6.74 CO 84 lb/mmscf AP -42 Section 1.4, Table 1.4-1 (July 1998 revision) 5.66 PM10 7.6 lb/mmscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.51 SO2 0.6 lb/mmscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.04 VOC 5.5 lb/mmscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.37 Hazardous Air Pollutant (HAP) Emission Factor a Data Source Emissions (tons/yr) 1,3 -Butadiene 3.42E-04 lb/MMBtu GRI FIELD TEST DATA 2.40E-02 2,2,4-Trimethylpentane 2.84E-03 lb/MMBtu GRI FIELD TEST DATA 1.99E-01 2-Methylnaphthalene 1.47E-07 lb/MMBtu GRI FIELD TEST DATA 1.03E-05 3-Methylcholanthrene 1.80E-09 lb/MMBtu EPA 1.26E-07 7,12-Dimethylbenz(a)anthracene 1.57E-08 lb/MMBtu EPA 1.10E-06 Acenaphthene 9.00E-08 lb/MMBtu GRI FIELD TEST DATA 6.31E-06 Acenaphthylene 6.70E-08 lb/MMBtu GRI FIELD TEST DATA 4.70E-06 Acetaldehyde 7.38E-04 lb/MMBtu GRI FIELD TEST DATA 5.17E-02 Anthracene 8.70E-08 lb/MMBtu GRI FIELD TEST DATA 6.10E-06 Benz(a)anthracene 8.70E-08 lb/MMBtu GRI FIELD TEST DATA 6.10E-06 Benzene 7.48E-04 lb/MMBtu GRI FIELD TEST DATA 5.24E-02 Benzo(a)pyrene 7.00E-08 lb/MMBtu GRI FIELD TEST DATA 4.91E-06 Benzo(b)fluoranthene 1.50E-07 lb/MMBtu GRI FIELD TEST DATA 1.05E-05 Benzo(g,h,i)perylene 2.60E-07 lb/MMBtu GRI FIELD TEST DATA 1.82E-05 Benzo(k)fluoranthene 7.60E-07 lb/MMBtu GRI FIELD TEST DATA 5.33E-05 Biphenyl 4.73E-07 lb/MMBtu GRI FIELD TEST DATA 3.31E-05 Chrysene 1.17E-07 lb/MMBtu GRI FIELD TEST DATA 8.20E-06 Dibenz(a,h)anthracene 1.03E-07 lb/MMBtu GRI FIELD TEST DATA 7.22E-06 Ethylbenzene 2.11E-03 lb/MMBtu GRI FIELD TEST DATA 1.48E-01 Fluoranthene 9.00E-08 lb/MMBtu GRI FIELD TEST DATA 6.31E-06 Fluorene 8.00E-08 lb/MMBtu GRI FIELD TEST DATA 5.61E-06 Formaldehyde 8.44E-04 lb/MMBtu GRI FIELD TEST DATA 5.91E-02 Indeno(1,2,3-c,d)pyrene 1.20E-07 lb/MMBtu GRI FIELD TEST DATA 8.41E-06 Lead 4.90E-07 lb/MMBtu EPA 3.44E-05 Methanol 9.64E-04 lb/MMBtu GRI FIELD TEST DATA 6.75E-02 Naphthalene 5.98E-07 lb/MMBtu EPA 4.19E-05 n -Hexane 1.76E-03 lb/MMBtu EPA 1.24E-01 Phenanthrene 6.00E-08 lb/MMBtu GRI FIELD TEST DATA 4.20E-06 Phenol 1.07E-07 lb/MMBtu GRI FIELD TEST DATA 7.50E-06 Pyrene 8.30E-08 lb/MMBtu GRI FIELD TEST DATA 5.82E-06 Styrene 2.08E-03 lb/MMBtu GRI FIELD TEST DATA 1.46E-01 Toluene 1.02E-03 lb/MMBtu GRI FIELD TEST DATA 7.12E-02 Xylenes(m,p,o) 1.32E-03 lb/MMBtu GRI FIELD TEST DATA 9.25E-02 TOTAL 1.48E-02 lb/MMBtu 1.035 a Uncontrolled emission factors for HAP from heaters @ 5 mmbtu/hr from GRI-HAPCalc 3.01. based on a composite of EPA's AP -42, GRI field data and GRI literature data. The highest emission factor between the data sets is listed here in order to provide a conservative estimate of HAP emissions from heaters. FormAPCD-102-Gilcrest Gas Plant_2012July: reboiler Page 15 of 20 8116/2012 Thermal Oxidizer Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC The thermal oxidizer servicing the amine vent waste gas stream will be fired by an 8 MMBtu/hr natural gas bumer with a continuous 0.05 MMBtu/hr pilot light. Combustion emissions from the natural gas -fired burner are presented below. Unit Natural Gas Burner Unit Rating: 8.05 MMBtu/hr Fuel usage a: 0.00774 MMSCF/hr 67.81 MMSCF/yr Operating hours: 8760 hours Based on fuel heat content of: Emission Calculations: 1040 Btu/SCF (maximum expected rating; includes pilot light) Criteria Pollutant Emission Factor Data Source Emissions (tons/yr) NOx 100 lb/MMSCF AP -42 Section 1.4, Table 1.4-1 (July 1998 revision) 3.39 CO 84 Ib/MMSCF AP -42 Section 1.4, Table 1.4-1 (July 1998 revision) 2.85 PM10 7.6 lb/MMSCF AP -42 Section 1.4. Table 1.4-2 (July 1998 revision) 0.26 SO2 0.6 lb/MMSCF AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.02 VOC 5.5 lb/MMSCF AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.19 Hazardous Air Pollutant (HAP) Emission Factor a Data Source Emissions (tons/yr) 1.21E-02 1,3 -Butadiene 3.42E-04 lb/MMBtu GRI FIELD TEST DATA 2,2,4-Trimethylpentane 2.84E-03 lb/MMBtu GRI FIELD TEST DATA 1.00E-01 2-Methylnaphthalene 1.47E-07 lb/MMBtu GRI FIELD TEST DATA 5.18E-06 3-Methylcholanthrene 1.80E-09 lb/MMBtu EPA 6.35E-08 7,12-Dimethylbenz(a)anthracene 1.57E-08 lb/MMBtu EPA 5.54E-07 Acenaphthene 9.00E-08 lb/MMBtu GRI FIELD TEST DATA 3.17E-06 Acenaphthylene 6.70E-08 lb/MMBtu GRI FIELD TEST DATA 2.36E-06 Acetaldehyde 7.38E-04 lb/MMBtu GRI FIELD TEST DATA 2.60E-02 Anthracene 8.70E-08 lb/MMBtu GRI FIELD TEST DATA 3.07E-06 Benz(a)anthracene 8.70E-08 lb/MMBtu GRI FIELD TEST DATA 3.07E-06 Benzene 7.48E-04 lb/MMBtu GRI FIELD TEST DATA 2.64E-02 Benzo(a)pyrene 7.00E-08 lb/MMBtu GRI FIELD TEST DATA 2.47E-06 Benzo(b)fluoranthene 1.50E-07 lb/MMBtu GRI FIELD TEST DATA 5.29E-06 Benzo(q,h,i)perylene 2.60E-07 lb/MMBtu GRI FIELD TEST DATA 9.17E-06 Benzo(k)fluoranthene 7.60E-07 lb/MMBtu GRI FIELD TEST DATA 2.68E-05 Biphenyl 4.73E-07 lb/MMBtu GRI FIELD TEST DATA 1.67E-05 Chrysene 1.17E-07 lb/MMBtu GRI FIELD TEST DATA 4.13E-06 Dibenz(a,h)anthracene 1.03E-07 lb/MMBtu GRI FIELD TEST DATA 3.63E-06 Ethylbenzene 2.11E-03 lb/MMBtu GRI FIELD TEST DATA 7.45E-02 Fluoranthene 9.00E-08 lb/MMBtu GRI FIELD TEST DATA 3.17E-06 Fluorene 8.00E-08 lb/MMBtu GRI FIELD TEST DATA 2.82E-06 Formaldehyde 8.44E-04 lb/MMBtu GRI FIELD TEST DATA 2.98E-02 Indeno(1,2,3-c,d)pyrene 1.20E-07 lb/MMBtu GRI FIELD TEST DATA 4.23E-06 Lead 4.90E-07 lb/MMBtu EPA 1.73E-05 Methanol 9.64E-04 lb/MMBtu GRI FIELD TEST DATA 3.40E-02 Naphthalene 5.98E-07 lb/MMBtu EPA 2.11E-05 n -Hexane 1.76E-03 lb/MMBtu EPA 6.22E-02 Phenanthrene 6.00E-08 lb/MMBtu GRI FIELD TEST DATA 2.12E-06 Phenol 1.07E-07 lb/MMBtu GRI FIELD TEST DATA 3.77E-06 Pyrene 8.30E-08 lb/MMBtu GRI FIELD TEST DATA 2.93E-06 Styrene 2.08E-03 lb/MMBtu GRI FIELD TEST DATA 7.33E-02 Toluene 1.02E-03 lb/MMBtu GRI FIELD TEST DATA 3.58E-02 Xylenes(m,p,o) 1.32E-03 lb/MMBtu GRI FIELD TEST DATA 4.66E-02 TOTAL 1.48E-02 Ib/MMBtu 0.521 a Uncontrolled emission factors for HAP from heaters @ 5 mmbtu/hr from GRI-HAPCalc 3O1, based on a composite of EPA's AP -42, GRI field data and GRI literature data. Th' highest emission factor between the data sets is listed here in order to provide a conservative estimate of HAP emissions from heaters. FormAPCD-102-Gilcrest Gas Plant_2012July: TO burner Page 16 of 20 8/16/2012 15 ft (nominal) O • ° :17.@ c a a) 2 E^ C.) a § C.)C73 06 � k / 2 c 76 O ▪ 4 § 2 O) _ �� 03 C - / 2 g -_▪ _■ C nfl x co C' ° • 00%k § e 0 • r .E CO CU 1 2 a)°/ O CO O_C //�f \ k/ E In 0 I— < k§ti kC et C gSn �$ — ' CU . l CO �kf § C oa)e0 C) E a CO O E V �Z1 0 E�fLi- C 4- o r_. � � • �0 « O 2 § \ k c. » § §7 0c �� W CO $ ' 2 U C .g q $ Z § 2 m co i P. \ k < % L. .c o 4 R▪ s CO 0 • k .C / C C kf/2 16 mi Aka Condensate production: 103.9 bbl/d 1592052 gal/yr 37906 bbl/yr VOC emissions: Benzene emissions: Toluene emissions Ethylbenzene emissions: Xylene emissions: n -Hexane emissions: §$ Page 17 of 20 N O N iro CO U) C O C.) V C O .N liJ co C co 0 tris G) N C a) C 0 • C co N co N a) U ti C W a) C � a) U 0_ C N ._ a)� 0) r• O N 06 N o O • c E o a) a) c O N � c a) p 0 a) � E • W ca CD 0 0- . a) J C Q) 'p 2 O 4 - • 0 coo n Zf N m U CO O) N �a c 3 -5 co .2- V- 2 E N co N • O 0 y a) L0. C 0_ Et? n3 w ~ o EO N J 0 vi C O O O U O N O C E W V LL = 12.46 SPM/T a) a) ca @U U N .p a) O j .o - "E) O Co a E 0 d • v COO • CO CONCO Cr) O O 0 N 0 ct U) ca a) N d p) O O O a) a) y E m m a 03 0) p .a -d U Ca 3 I o- O Q — 0. 3 O w a1 cr m p > — 0) ca N 0 Y h 3 O O CO • 48 .0 U ._12)� " • O co C 8 L 3 p o f9 • (a C) > U o c N N 0. 0 2 E 0 v> .. E II II II II II CI) Q • ♦- J 1592052 gal/yr 37,906 bbl/yr Tank throughput e Total VOC Emissions f .0.0.0.0 .0 .0 .0 .0.0 .0 N C -) 0 N C• N CO O) .- O) ( � V- 1- (O 0 0 O N 00 O O O O O O C Y O co CC 0 • O Nits_a) m N N • co i • E N O O -p C >. a ? ? a N Or N CO \ \ \ "?.s. \ \ CZCZZCZ O 0 0 0 0 0 0 0 v> o Lo ^00N•- O cs N N 0 0 0 0 r 2 o O 4 0 0 0 0 O a c a Q 3 co E N LL 'O O a) OO)(o 0 E to N .v (a O y 0 w O O-0 ku E 0 Y v 0 t9 cj Z 0 C i H Y 0 0 >`` � L. � � � ', o a E Q (' .043 -0.0.Q -Q D > o ~ o 0) -.cc --to (a a -'v to cot -. V' N0 on v 0 p a) U) CO .- m �Ovas C 0 % «�+ O) a) v) a) - C C O > 0 0 co0 0 a) w 3 Q O 0 100 0 O C Z 0 O m 3 cm N_c a ... 0 Cl) c w rnQ d O iL6 O = CO• n3aw3 `O 45 ET) v a O a) a) > O > N C co7 O C 4- .... 3 C a) O O a) Cu' a) V C V a)a)a)v,a) co CO N 3 N 0 X X ). C a) o E E 0 X a) ( N cn22<2w m a v 41 simulation run. O N O CO a) m a FormAPCD-102-Gilcrest Gas Plant_2012JuIy: loadout Regen Gas Heater Emission Calculations Gilcrest Gas Plant Aka Energy Group, LLC Unit Regen Gas Heater Unit Rating: 1.5 mmbtu/hr Fuel usage a: 0.00144 mmscf/hr 12.63 mmscf/yr Operating hours: 8760 hours a Based on fuel heat content of: Emission Calculations: 1040 btu/scf (maximum expected rating) Criteria Pollutant Emission Factor Data Source Emissions (tons/yr) NOX 100 lb/mmscf AP -42 Section 1.4, Table 1.4-1 (July 1998 revision) 0.63 CO 84 lb/mmscf AP -42 Section 1.4, Table 1.4-1 (July 1998 revision) 0.53 PM10 7.6 lb/mmscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.05 SO2 0.6 lb/mmscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.004 VOC 5.5 lb/mmscf AP -42 Section 1.4, Table 1.4-2 (July 1998 revision) 0.03 Hazardous Air Pollutant (HAP) Emission Factor a Data Source Emissions (tons/yr) 1,3 -Butadiene 3.42E-04 lb/MMBtu GRI FIELD TEST DATA 2.25E-03 2,2,4-Trimethylpentane 2.84E-03 lb/MMBtu GRI FIELD TEST DATA 1.87E-02 2-Methylnaphthalene 1.47E-07 lb/MMBtu GRI FIELD TEST DATA 9.66E-07 3-Methylcholanthrene 1.80E-09 lb/MMBtu EPA 1.18E-08 7,12-Dimethylbenz(a)anthracene 1.57E-08 lb/MMBtu EPA 1.03E-07 Acenaphthene 9.00E-08 lb/MMBtu GRI FIELD TEST DATA 5.91E-07 Acenaphthylene 6.70E-08 lb/MMBtu GRI FIELD TEST DATA 4.40E-07 Acetaldehyde 7.38E-04 lb/MMBtu GRI FIELD TEST DATA 4.85E-03 Anthracene 8.70E-08 lb/MMBtu GRI FIELD TEST DATA 5.72E-07 Benz(a)anthracene 8.70E-08 lb/MMBtu GRI FIELD TEST DATA 5.72E-07 Benzene 7.48E-04 lb/MMBtu GRI FIELD TEST DATA 4.91E-03 Benzo(a)pyrene 7.00E-08 lb/MMBtu GRI FIELD TEST DATA 4.60E-07 Benzo(b)fluoranthene 1.50E-07 lb/MMBtu GRI FIELD TEST DATA 9.86E-07 Benzo(g,h,i)perylene 2.60E-07 lb/MMBtu GRI FIELD TEST DATA 1.71E-06 Benzo(k)fluoranthene 7.60E-07 lb/MMBtu GRI FIELD TEST DATA 4.99E-06 Biphenyl 4.73E-07 lb/MMBtu GRI FIELD TEST DATA 3.11E-06 Chrysene 1.17E-07 lb/MMBtu GRI FIELD TEST DATA 7.69E-07 Dibenz(a,h)anthracene 1.03E-07 lb/MMBtu GRI FIELD TEST DATA 6.77E-07 Ethylbenzene 2.11E-03 lb/MMBtu GRI FIELD TEST DATA 1.39E-02 Fluoranthene 9.00E-08 lb/MMBtu GRI FIELD TEST DATA 5.91E-07 Fluorene 8.00E-08 lb/MMBtu GRI FIELD TEST DATA 5.26E-07 Formaldehyde 8.44E-04 lb/MMBtu GRI FIELD TEST DATA 5.55E-03 Indeno(1,2,3-c,d)pyrene 1.20E-07 lb/MMBtu GRI FIELD TEST DATA 7.88E-07 Lead 4.90E-07 lb/MMBtu EPA 3.22E-06 Methanol 9.64E-04 lb/MMBtu GRI FIELD TEST DATA 6.33E-03 Naphthalene 5.98E-07 lb/MMBtu EPA 3.93E-06 n -Hexane 1.76E-03 lb/MMBtu EPA 1.16E-02 Phenanthrene 6.00E-08 lb/MMBtu GRI FIELD TEST DATA 3.94E-07 Phenol 1.07E-07 lb/MMBtu GRI FIELD TEST DATA 7.03E-07 Pyrene 8.30E-08 lb/MMBtu GRI FIELD TEST DATA 5.45E-07 Styrene 2.08E-03 lb/MMBtu GRI FIELD TEST DATA 1.37E-02 Toluene 1.02E-03 lb/MMBtu GRI FIELD TEST DATA 6.68E-03 Xylenes(m,p,o) 1.32E-03 lb/MMBtu GRI FIELD TEST DATA 8.68E-03 TOTAL 1.48E-02 lb/MMBtu 0.097 a Uncontrolled emission factors for HAP from heaters @ 5 mmbtu/hr from GRI-HAPCalc 3.01. based on a composite of EPA's AP -42, GRI field data and GRI literature data. The highest emission factor between the data sets is listed here in order to provide a conservative estimate of HAP emissions from heaters. FormAPCD-102-Gilcrest Gas Plant_2012July: regen gas heater Page 19 of 20 8/16/2012 N_ N 0 Produced Water Tank Calculations Gilcrest Gas Plant Aka Energy Group, LLC C) 0C W C H w Q O N L a m d Cu W cc N O C .(/); 'U N N N f0 O CO y 3 E C CO OP C 2 0 E 2 -y a ID w to O O N V a o O o O C a CL cu N W E c o 3 V) U O C U d p O In N O a) 1D X) CD W 3 (13 ...� to CD o E O O` co Z CO O ,O m O O .E a a) Tank Height (nominal): (from simulation run) to I - (v to M C) C0) CO CD CI O M CV O O N O to 'D O SD la M ID .O co co CO d co co 0 C O w2 O az a ° E xa Q O c ti N� Total annual water (total projected) 0.01 % (conservative estimate) Mass % Oil: ? O O C + + $ W O O O j.O O O N 0 0 0 0 0 d CA C to O co, E .0 + + W W CD CD O O C O y h W R C O "2. o0 c — as Di O CI) rn U O V 0 U O co OO ' b � tD CO W b o m w O O a O z o 3 O W W_ UJ N U0 C O O U) O O 00 0 W W OO O O O O CD r CO to r Vs CO Vs to Ul )41 O O O (D O W W COO O V N O O O to to (D O O O W W W r r r CA (D CO Vs O O O 0 W W W M CD r O to r r N NNN T- R to V to (D M CD CD C) C') ON (0a CA1� • co O C) O) co N CO O EQO N co ozi a) O METHANE w z w w CD O W CD cc; 0.0 0.00E+00 0 0.00E+00 O OD C) O OD C) wt C) C) wt O C) O O O O O O N O O N r O j W W j W W W W W W W W O M ' O CO U) to to N to Cl) U) O r O O C) r N r O V 6 06 Ps 6 N N r C) N r e- r OOOOOOOU)CDrI� CO C;OO O O a a O O N O W O W W W W to wt C) CD r OD wt N r O) MANN N O O CO a) o a) o to Q) O CA r O O O O O O N- CV O r N r r W W W W W W W W W W W W O CD O O CI) wt N r r N N. N 0 0 0 Vs. O Vs Vs CD r N CO Nr M O p r c{ CO (V CV (0 (V O O 03 O O W O CO v o t.- (') N- [7 co O CO N.. N N Or(DCD Cr,N r r r N r r N r r W W W W W W W W O) (A O CD M O r (0 (Aw'MCOCOMr in co M N N. C') Ch N C") CO C)) N Nr N r O N O 00 N O O O N O O O C') O .- '- O 0 0 0 0 0 0 O O O O O O 0 0 0 0 0 0 a O O O O 0 0 0 0 0 O O O O O O O to V- C) OD M C) N wt (V r O N r O r C') NC)NOOOONOO OC') O 'a'(DrOOOOOOO OO OO 0 0 0 0 0 0 0 0 0 0 O O O O OCDC7000OOCO 00 00 1 -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE 2-METHYLPENTANE N-HEPTANE METHYLCYCLOHEXAN 2,2,4-TRIMETHYLP O OO LLI W W W OF ETHYL BENZENE O-XYLENE N -OCTANE COws '- O CD CD CD CD O O O vs' c4 C) O C c0 Q3 W co(O0) C")(V 2 (1) O O 25 � � W es 1O > CO C'') ? '1 C') < C1 W (0 O in • o - O 00 d O L m CD E N C') N) C N ON. 2 C C+) ('7 o E 'a E Cn O O) CO O C C a) o o C%) 0 N Cn E c rn m m o i Doo m'6 a 3 w C > O y .2 C Yo °) m 46 C) C C >U(i FormAPCD-102-Gilcrest Gas Plant_2012JuIy: water tank E TERRAN G3516 LE GAS COMPRESSION APPL1CATi0N ENGINE SPEED (rpm) COMPRESSION RATIO. AFTERCOOLER WATER INLET (°F). JACKET WATER OUTLET (°F): COOLING SYSTEM IGNITION SYSTEM EXHAUST MANIFOLD. COMBUSTION NOx EMISSION LEVEL (g/bhp-hr NOx): SET POINT TIMING GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka Energy, LLC Gilcrest Plant 1400 8:1 130 210 JW+OC,AC ADEM3 ASWC Low Emission 1.5 33.0 FUEL SYSTEM: WITH SITE CONDITIONS: FUEL: FUEL PRESSURE RANGE(psg): FUEL METHANE NUMBER: FUEL LHV (Btu/sd): ALTITUDE(ft)• MAXIMUM INLET AIR TEMPERATURE(°F): NAMEPLATE RATING: Aka Energy Group, LLC Proposal Number; 82332 Date: 5-1-08 Page 12 CATERPILIAW HPG IMPCO AIR FUEL RATIO CONTROL Nat Gas 35.0-40.0 84.8 905 5300 100 1340 bhp@1400rpm MAXMIUM SITE RATING AT MAXIMUM INLET AIR RATING TEMPERATURE RATING NOTES LOAD 100% 100% 76% 63% ENGINE POWER (1) bhp 1340 1265 949 670 INLET AIR TEMPERATURE °F 69 100 100 100 ENGINE DATA FUEL CONSUMPTION (LHV) (2) Bturbhp•hr 7545 7603 7888 8286 FUEL CONSUMPTION (HIV) (2) Btufbhp-hr 8369 8434 8750 9191 AIR FLOW (3) Ib/hr 12795 12144 9290 6263 AIR FLOW WET (77°F, 14 7 psis) (3) scfm 2886 2739 2095 1413 INLET MANIFOLD PRESSURE (4) in Hg(abs) 69.9 66.6 52.4 39.1 EXHAUST STACK TEMPERATURE (5) °F 854 851 840 842 EXHAUST GAS FLOW (@ stack temp, 14.5 psia) (6) MI/rein 7651 7244 5501 3738 EXHAUST GAS MASS FLOW (6) Ibhr 13305 12629 9667 6543 EMISSIONS DATA NOx (as NO2) (7) g'bhp-hi 1.50 1.50 1.50 1.50 CO (7) gbhp-hr 1.89 1.90 1.96 1.90 THC (molecular wt. of 1584) (7) gbhp-hr 3.07 3.14 3.45 3.60 NMHC (molecular wt of 15.84) (7) gbhp-hr 0.46 0.47 0.52 0.54 NMNEHC (molecular wt. of 15.84) (7) grbhhp-hr 0.31 0.31 0.35 0.36 HCHO (Fanmeldehyde) (7) gbhp hr 0.25 0.26 0.28 0.30 CO2 (7) gbhp.hr 491 494 515 539 EXHAUST OXYGEN (8) % DRY 8.3 8.2 8.0 7.8 HEAT REJECTION HEAT REJ TO JACKET WATER (9) Btu/min 41538 40296 34369 29885 HEAT REJ. TO ATMOSPHERE (9) BtWmn 5313 5115 4279 3543 HEAT REJ. TO LUBE OIL (9) Btu/mn 6195 6010 5126 4457 HEAT REJ TO AFTERCOOLER (9)(10) Btufmn 12308 14851 10038 3557 HEAT EXCHANGER SIZING CRITERIA HEAT REJ TO JACKET WATERILUBE OIL CIRCUIT HEAT REJ TO AFTERCOOLER A cooling system safety factor of 0°a has been added to the heat exchanger song criteria (10) (10x1I) Btu.rmn Blu/mn 53126 15593 Engine rating obtained and pr.sa..d r accordance well SO 304611, adivat.d for fuel. ate altitude and site inlet alt temperature. 100% rating at ma4 nun inlet air temperature a the marmun engine capability for the specified fuel at site albtaie and madmen site feet ar empnrabse Mao ratng is the maomum canaditty for the emoted fuel at site arotude and reduced Mel air temperature. Lowest bad meg is me lowest conunud6 duly operating bad mowed. No o erload remitted at rating storm. For notes hdonnadm ccnsrrf page geee. PREPARED BY JOHN SOSTMANN, Exterran Data generated by Gas Engne Rating Pro Version 3.01 00 Ref Data Set DM8542-01-003, Printed 29Apr2008 Page 1 of 4 TERRAN G3516 LE COMPRESSION APPLICA110N 1400 n 1350 31303 a ^53 '.03 " 53 37 GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka Energy, LLC Gilcrest Plant Engine Power vs. Inlet Air Temperature Aka Energy Group, LLC Proposal Number; 82332 Date: 5-1-08 Page 13 CATERPILLAR° 1 1400 1200 11000 a. a P W 800 600 400 200 0 950 43 53 63 73 83 93 100 Air Temperature. `F Engine Power vs. Engine Speed 1'0 ----------------- -------------_� ----- -�� -- �� -- ��i -- -- -- -- -- 1150 1200 1250 Engine Speed (rpm) 1300 1350 1400 1450 5000 4500 n 4000 d 3500 a3000 r 2500 c 2000 g 1500 1000 500 0 1000 1050 1103 Engine Torque vs. Engine Speed -M —i— ita — MEI MEN =MI �i- -i IIMM mMi 1450 950 1000 1050 1100 1150 1200 1250 Engine Speed (rpm) PREPARED BY JOHN SOSTMANN, Exterran Data generated by Gas Engine Rating Pro Version 3 01 00 Ref Data Set DM8542-01-003, Pnnted 29Apr2008 1300 1350 1400 120 130 140 Max Power vs. Speed Capability for Site Conditions Full Continuous Operating Range at Standard Conditions .Low Load Intermittent Operating Range Max Torque vs. Speed Capability for Site Conditions Full Continuous Operating Range at Standard Conditions .Low Load Intermittent Operating Range Page 2 of 4 TERRAN G3516 LE GAS COMPRESSION APPLICATION GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka Energy, LLC Gllcrest Plant NOTES 1 Engine rating is with two engine dnven water pumps Tolerance is ± 3% of full load 2 Fuel consumption tolerance is ± 3 0% of full load data 3 Undried air Flow is a nominal value with a tolerance of ± 5 %. 4 Inlet manifold pressure is a nominal value with a tolerance of ± 5 %. 5 Exhaust stack temperature is a nominal value with a tolerance of (-)63°F, (-)54°F 6. Exhaust flow value is on a' wet" basis Flow is a nominal value with a tolerance of ± 6 %. Aka Energy Group, LLC Proposal Number; 82332 Date: 5-1-08 Page 14 CATERPILLAR' 7 Emission levels are at engine exhaust flange prior to any after treatment Values are based on engine operating at steady state conditions, adjusted to the specified NOx level at 100% load Fuel methane number cannot vary mare than ± 3 NOx tolerances are +111%, -96% of specified value All other emission values listed are higher than nominal levels to allow for instrumentation, measurement. and engine -to -engine variations They indicate not to exceed" values 8 Exhaust Oxygen level is the result of adjusting the engine to operate at the specified NOx level Tolerance is ± 0 5 9. Heat rejection values are nominal Tolerances, based on treated water are ± 10% for jacket water circuit. ± 50% for radiation, ± 20% for lube oil circuit, and ± 5°0 for aftercooler circuit 10 Aftercooler heat rejection includes an aftercooler heat rejection factor for the site elevation and inlet air temperature specified Aftercooler heat rejection values at part bad are for reference only Do not use part load data for heat exchanger sizing 11 Heat exchanger sizing criteria are maximum heat rejection for the site. with applied tolerances PREPARED BY JOHN SOSTMANN, Exterran Data generated by Gas Engine Rating Pro Version 3 01.00 Ref Data Set DM8542-01-003. Pnnted 29Apr2008 Page 3 of 4 C56AT3-0002 TERRAN G3516 LE GAS COMPRESSION APPLICATION Constituent Water Vapor Methane Ethane Propane Isobutane Norbutane Isopentane Norpentane Hexane Heptane Nitrogen Carbon Dioxide Hydrogen Sulfide Carbon Monoxide Hydrogen Oxygen Helium Neopentane Octane Nonane Ethylene Propylene TOTAL (Volume °nil GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka Energy, LLC Gilcrest Plant Mole 0/0 Norm H2O 0 0000 0 0000 CH4 92 2700 92 2700 C2H6 2 5000 2 5000 C3H8 0 5000 0 5000 iso-C4H1 O 0 0000 0 0000 nor-C4H 1O 0 2000 0 2000 iso-05H12 0 0000 0 0000 nor-05H I2 0 1000 0 1000 C6H14 0 0500 0 0500 C7H16 0 0000 0.0000 N2 3 4800 3.4800 CO2 0 9000 0 9000 H2S 0 0000 0.0000 CO 0 0000 0 0000 H2 0 0000 0 0000 O2 0 0000 0 0000 HE 00000 00000 neo-05H12 0 0000 0 0000 C8H18 0 0000 0 0000 C9H20 0 0000 0 0000 C2H4 0 0000 0 0000 C3H6 0 0000 0 0000 Abbrev I00 0000 100 0000 Fuel Makeup: Unit of Measure: Aka Energy Group, LLC Proposal Number; 82332 Date; 5-1-08 Page 15 CATERPILLAR' Nat Gas English Calculated Fuel Properties Caterpillar Methane Number: 84.8 Lower Heating Value (Btu/scf): Higher Heating Value (Btuiscf): WOBBE Index (Btuiscf): 905 1004 1168 RPC (%) (To 905 Btulscf Fuel): 100% Compressibility Factor: Stoich AT Ratio (VokVol): Stoich AT Ratio (Mass'Mass) Specific Gravity (Relative to Air) Specific Heat Constant (K). 0 998 9.45 15.75 0.600 1.313 CONDITIONS AND DEFINITIONS Calerplar Methane N.,mber represents the Snack insistence of a gaseous lust. A should be used web the Carerpdar Fuel Usage Glade for the engine and ramp to Oetenniire the raanig for the luel specified. A Fuel Usage Guide for each rating is included on page 2 erns standard technical data sheer. RPC always apples to naturally aspirated (NA) engines. and turbocharged (TA or LEI engines only when they are dueled for Narude and ambient sire conditions Project specific technical data sheets generated by the Caterpillar Gas Engine Rating Pro program tale the Caterpillar Methane Number and RPC into account when generating a sire rating. Fuel properties for Blatant calculations are at 60F and 14.096 psia. Calenhdlan shag have no lability in taw or equity. for damages. corisergueniry or otherwise. awn; horn use of program and related maienai or any pan thereof FUEL LIQUIDS I 'cid gases, well head gases, and associated gases tynicaly contain hared water and heavy hydrocarbons entrained in the gas. To prevent de•Anatlon and severe damage to the engine. hydrocarbon Bawds must not be allowed to enter the engine luel system To remove hgdlds. a lewd separator and coalescing fitter are ieco.emerxfed, with an automatic them and collection lark to prevent contamination of the ground in accordance with local codes and standards. to avoid water condensation in the engine or heel lines. Ban the relative humidity of water in the fuel to 80% a: the minimum fuel operabeg temperature. PREPARED BY JOHN SOSTMANN. Exterran Data generated by Gas Engine Rating Pro Version 3 01 00 Ref. Data Set DM8542-01-003, Printed 29Apr2008 Page 4 of 4 GILCREST REPLACEMENT UNIT 1 HP Unit 1 Cat 3516LE Incremental Tons/year Prior Tons/year New Tons/year Engine rating Derate Altitude Derate Temp Derating New rating NOx gm/hp-hr Tons/year CO gm/hp-hr Tons/year 708 2 13.7 3 20.5 1297 1.5 18.8 1.9 23.8 5.1 69.8 3.3 84.2 74.9 87.5 1340 4800 4000 5000 0.8 100 1 0.96 0.04 3.20% 0.032 1,297 HELIUM Mole °/0: 0 %: 0 %: 0.39 CO2 Mole %: 3,2, OXYGEN Mole %: r 0.06 METHANE Mole %: 63.7 ETHANE Mole %: 30.59 PROPANE Mole %: 2.02 %: 0.02 NBUTANE Mole ()/0: 0.02 0/0: 0 0/0: 0 cyo: 0 BTU Wet: 1,216.02 BTU Dry: 1,237.66 Compress Factor:_ 0.9962, Edit New Methane number 100 6370 44 1345.96 34 68.68 10 0.2 10 0.2 96.35 7785.04 80.8 FEB-03-2004 TUE 04:29 PM SOUTHERN UTE GROWTH FUND FAX NO. 970 375 2216 02/02/2004 15:31 4326870810 MECHANICAL EQUIPMENT P. 03/06 PAGE 02 February 2, 2004 AKA Energy 2577 Main Ave. Durango, CO 81301 Attention: Mr. Mike Boland MECHANICAL ECIUIPMENT INC. Reference: MEI Quote 404-02-2775 Catalytic Converter Application Gentlemen: In response to our telephone conversation earlier today, Mechanical Equipment, Inc., is pleased to offer the following emission control equipment for your referenced project: Two (2) Mechanical Equipment, Inc. Arlen ualor Model PXL-10-BMB catalytic exhaust silencer constructed with ten (10) inch, 125# ANSI flanges, end intend out, and a hinged catalyst servicing door. The catalyst system shall be MEI CAM-LOK°° PHOENIX type construction and shall be supplied with NO-NOx proprietary NSCR catalyst. The catalyst chamber is designed to accept a second catalyst element at a later date should emission requirements so dictate. The silencer section of the system is reactive in design eliminating sound rather than muffling it; a true quality product The sound attenuation will be 35-00 dBA. This unit shall be for installation on a Superior Model 8G825 natural gas spark ignited ongine to operate at 725 BHP/900 RPM with an exhaust flow of 1000 SCFM/1200 °F. Sample ports will be located in the inlet and outlet neck of the vessel. Three (3) 3/4" NPT high catalyst temperature ports will be provided in the vessel to accept thermocouples for determining Pre and Post catalyst temperatures. Lifting eyes will be installed at both ends of the unit for positioning the vessel in any orientation. Base price to include shop primer coat. Approximate dimensions - shell diameter - 26"; overall length - 131 ". Net Price Each FOB Midland, Texas -----------------------'-- S 9,165.00 Approximate Shipping Weight ------ ------ 831 lbs. P.O. BOX 1800 - (432) 687-0601 • PAX $ (432) 687-0810 • MIDLAND, TEXAS 79?02 FEB-03-2004 TUE 04:29 PM SOUTHERN UTE GROWTH FUND FAX NO. 970 375 2216 02/02/2904 15:31 4326870910 MECHANICAL_ EQUIPMENT P. 04/06 PAGE 83 AKA Energy Page Two MEI Quote 404-02-2775 CONVERTER PERFORMANCE EMI ITAN"1' POST CONVERTER. PERFORMANCE NOx CO VOC 2.0 grn/BHP-HR 3.0 gun/BHP-HR 0.2 gm/BHP-HR Maximum Attenuator Pressure Drop - (Flange to Flange) = 6.0 in. H2O Shipment: Approximately four to five (4-5) weeks, after receipt of order, subject to prior salt. To protect the catalyst against possible damage by excessive operating temperature, we offer the following high temperature shutdown. Further, to limit back pressure on the engine as well as to protect the catalyst from possible exhaust "backfire" damage we quote on the following exhaust explosion relief valve: >41GHJXHAUST TEMPERATURE slW[IITDOWIi Two (2) Model ALT -1301-F ignition powered. solid state, single set point, NEMA Class 1, Group D, Division 1 and 2, adjustable high temperature shutdown with digital display. Unit supplied for control panel mounting and with one (1) TEM-ME1* thermocouple assembly (C.S.A. certified). Net Price Each FOB Midland, Texas ------ ---- $ 569.00 *TEM-ME' thermocouple assembly includes a 14" long spring loaded, stainless steal sheathed, type K, stainless steel thermocouple installed in a six inch x 1/2" 304 stainless steel thermowell with nipple -union -nipple adapter assembled to a terminal block mounted in a cast aluminum housing. Assembly includes 50 feet of 20 AWG stainless steel armored type K thermocouple wire. P.O. BOX 1800 • (432) 687-0601 - FAX 4d (432) 687-0810 • MIDLAND, TEXAS 79702 CVO FEH-03-2004 TUE 04:29 PM SOUTHERN UTE GROWTH FUND FAX NO. 970 375 2216 02/02/2804 15:31 4326670810 MECHANICAL EQUIPMENT P. 05/06 PAGE 04 AKA Energy Page Three MEI Quote #04-02-2775 FMANST EXPLOSION RELIEF V,A,LVF,5 AND SADDLES Two (2) MEI-10H-000, 10 inch diameter, exhaust explosion relief valve with high temperature trim. Includes stainless steel support rods, Inconel tension spring and special high temperature gasket. Net Price Each FOB Midland, Texas ---------- ...... $ 949.00 Two (2) MEI-010-000, 10" x 10" pre -fabricated flanged ANSI 125# flat face exhaust explosion relief valve saddle to mate with valve. Net Price Each FOB Midland, Texas - -- •- ---- - - -- $ 175.00 Shipment: Approximately three (3) weeks, after receipt of order, subject to prior sale. AIR/FUEL R.&TLO CONTROL (A1TQMA17CI Two (2) Mechanical Equipment, Inc. Series 1SG Automatic Stoichiometric AN Controller t" random logic based system for maintaining proper air/fuel ratio on rich burn engines. This system manages the engine fuel mixture adjustment to a pre -determined level of unburned oxygen as sensed in the engine exhaust, matching fuel demand with power requirements_ Oxygen concentration is measured using a Zirconium oxide probe mounted in the exhaust line. Controller electronics are housed in a NEMA 4X enclosure with transparent door. Actuator motors are enclosed in Class 1, Group D, Division l and 2, explosion proof enclosures and are connected to auxiliary power valves to be installed in the carburetor (s) fuel inlet. 1/2 AMP, 120 VAC, 60 Hz or 12 or 24v DC power is required. Net Price Each FOB Midland, Texas — ------"" $ 4,311.00 Approximate Shipping ppirlg Weigh - .••. -- _...60 lbs. Weight - Shipment: Approximately three (3) weeks, after receipt of order, subject to prior sale. P.O. BOX 1800 • (432) 687-0601 • FAX 0 (432) 687-0810 • MIDLAND, TEXAS 79702 Heceivea: L! .i/ U4 10;00i - FEB-03-2004 TUE 04:30 PM SOUTHERN UTE GROWTH FUND FAX NO. 970 375 2216 82/02/2804 15:31 4325870810 MECHANICAL EQUIPMENT P. 06/06 PAGE 85 AKA Energy Page Four MEI Quote #04-02-2775 All Prices Valid For 30 Days From Date of Proposal TERMS: EquipWe1O Net 30 Days From Date of Invoice. Thank you for your interest in our products and services. We look forward to working with you on this project. Should additional information be required, please advise. You vary truly, T.G. Smith TGS./hmh P.O BOX 1800 • (432) 687.0601 • AAX # (432) 687-0810 • MIDLAND, TEXAS 79702 % 5550 Marshall Street Arvada, Colorado 80002 Phone: (303) 237-2072 Fax: (303) 237-2659 CoRDI LLERAN RECORD OF COMMUNICATION Project Name: Gilcrest/Kersey Air Permits Project Number: ED03020 X Telephone Call Meeting Site Visit Other To: Tom Smith, Mechanical Equipment Phone: (432)-687-0601 From: Joe Miller Phone: ( ) Page 1 of 1 Date: 2/3/04 Time: RE: Pre -control emissions for S001/S003 catalyst additions I spoke with Tom regarding pre -catalyst emissions from engines S001/S003. He indicated that the engine would need to be run slightly rich of stoichiometric in order for the catalysts to operate properly. (This accounts for the pre -control estimates provided by other vendors being different from the currently permitted engine emissions). Tom suggested that we use 12 g/bhp-hr for NOx, 11 g/bhp-hr for CO, and 0.2 g/bhp-hr for VOC as uncontrolled emission factors for the engines (based on his review of manufacturer's data). Actions or Conclusions: Copies to: wi9nl'►r,i . INES MODEL. BG-R5 PAGE 211 , ENGINE OPERATING DATA AND HEAT REJECTION SUPERIOR 8G825 . _. PERCENT RATED 1Q9D 3MEP (PSI) ENGINE SPEED — RPM 900 800 700 600 atiAXE -- 110 117 880 782 684 586 HORSEPOWER 100 107 800 711 622 533 gip) 75 80 600 533 467 400 50 53 400 356 311 267 ISRA.E SPEC F I C 110 117 FUEL C0NSUifT10N 100 107 7750 7750 7800 7950 ®TUIBH?HHR) 75 80 8510 8550 8500 8500 50 S3 10150 10000 9900 9900 INTAKE AIR FLOW 110 117 1261 1 150 1009 854 {EOINREANT 100 107 1186 1055 927 791 CSCFy1) • 75 80 945 836 745 635 50 53 727 , 636 fib 482 EXHMIST FLOW 110 1;7 99 92 81 69 6.8NIN) 100 107 96 85 75 84 75 80 78' 67 59 51 50 53 59 51 46 39 EXFUU,ST TEMP. 110 117 1330 1320 1305 1270 WV) 100 75 107 80 1340 1310 1315 1280 1305 1225 1250 1140 50 53 1220 1190 1160 1110 JACIET WATER 110 117 29330 26550 23.30 21360 HEAT 1;>;•JEC TION 100 107 29100 26450 23730 21090 8TlaII3 75 80 28090 25100 22640 20000 50 53 24090 21360 18636 16360 LUKE OIL 1 10 117 3600 3600 3600 3600 HEAT REICTICN 100 107 3600 3600 3600 3500 CBII0 7S 80 3600 3510 3400 3400 30 53 3420 32`0 3240 3200 NOTES I) FUEL CONSUMPTION BASED CN PIPELINE QUALITY FUEL AND ENGINE ADJUSTMENT FOR STANDARD EXHAUST EMISSION RATES, SLBvFCT TO t3S TOLERANCE FOR FACTORY TESTS. 2) HEAT REJECTION DATA ARE BASED ON NOMINAL 180F JACKET WATER OUTLET TEM?€RATL E REFER TO GENERAL DATA SECTION. PAGE GEN-21/ -88 FOR HEAT REJECT'ADW3T14ENT FACTORS DUE TO HOT WATER SYSTEIAS OR E3ULL!ENT C00LING. HEAT REJECTION DATA ARE AVERAGE VALUES AND WILL VAR`f MTH OPERATING CONDITIONS AND AMBIENT TEMPERAT'LFE ADD RESERVE FACTOR FOR SIZING COOLING SYSTEMS. SUBTRACT IOX RESERVE FACTOR TO COMPUTE RECOVERABLE MEAT. AJAX•SUPERIOA NA 211/1-89 Cooper Industries Cooper Energy Services Aftermarket Services P.O. Box 1777 Wheat Ridge, CO 80034-1777 COOPER Cooper Energy Services June 3, 1994 Mr. Ralph Nelms Windsor Gas Processing 410 Seventeenth Street Suite 1170 Denver, CO 80202 Re: Superior 8G-825 Engine Site Rating S/N 200719 & 184789 Dear Ralph: Please find enclosed a copy of our Engine Rating report based on your site conditions of 4,767 feet elevation, 90° ambient temperature , and your gas analysis #M93NG2378 run by Marcum Gas Measurement. Our horsepower rating report is based on air capacity limitations and detonation limits (based on ambient temperatures and fuel gases). Our report shows an 11.43 percent deration based on air capacity limitations of your engines.. This would reflect a 708.56 BHP @ 900 RPM site rating (91.44 BHP deration) for your 8G-825 engines. Sincerely, Hap Schadler /jjh a:\8g825rtg.ltr cc: Tom Reynard 9850 South 1-70 Service Road Wheat Ridge, CO 80033.2267 303 425-1700 Fax 303 425-1307 Cooper•Bessemeri • A)ax& • Superior& • Enterprise" • En-Tronlc$ • Penn' engine Family Muuei ATGL' LTM VHF" Engine ararialas it drswttwu ca buresor pith Om sans /*vs ' Refer to pages 12 and 13 for VHP GL wpm equipped wan d7wtnni carDwew (low fuel pressure system) n VGF" ' These power rapt wore "moot, option Code 1100 (176 (MEP) and DSM They era avai.Ele contnuaNy a wen apowc par MO' Paw and ?inlay Curve S7070- 10 rte pemrsaraie to opal(' at las to 5% overload for fro hdw5 Pasch 24 hour goad. • Low speed ruraaMarpa required for opera- tion at 1200.1103 rpm on INne *moos and from 1200 -1600 rpm on W angina VSGT' 16V-AT27GL 16V-AT27GL 12V-AT27GL 12V-AT27GL 8L•AT27GL 8L-AT27GL P9390GSI P9390GS1 P9390GL P9390GL P9390G P9390G L7044GS1 L7042GSI' L7041GSI' L7042GL' L7042GL' L7042G L7042G L5794GSI L5790GSI L5790GSI L5794LT L5794LT L577411 L5790GL L5790GL F3524GS1 F3521 GSI F3521 GSI F3521 GL F3521GL F2895GSI F2895GSI F2895GL F2895GL P48GSUGSID P48GLJGLD P48GL'/GLD' L36GSUGSID L36GL/GLD L36GL'IGLD' H24GSUGSID H24GLJGLD H24G L H24GL'/GLEP F18GSUGSID F18GLJGLD F18GL F18GL'IGLD' F11GSUGSID F11GSUGSID F11G Continuous Duty i C. Water Temp. (Tcra) CR 800 rpm 900 rpm 1000 rpm 1200 rpm 1400 rpm 1500 rpm 1600 rpm 1800 rpm °F 'C bhp kWb bhp kwo bhp kWb bhp kWb bhp kWb bhp kWb bhp kWb bhp kWb 90° 32° 9:1 3600 2686 4050 3020 4500 3356 130° 54° 9:1 3600 2686 4050 3020 4500 3356 90° 32° 9:1 2640 1967 2970 2216 3295 2458 130° 54° 9:1 2508 1871 2820 2104 3130 2335 90° 32° 9:1 1760 1312 1980 1477 2200 1641 130° 54° 9:1 1670 1246 1880 1405 2090 1560 85° 29° 8:1 1375 1025 1547 1154 1719 1282 2063 1538 — — — — — — — — 130° 54° 8:1 1314 980 1478 1102 1642 1224 1970 1469 — — — — — — — — 85° 29° 10.5:1 1375 1025 1547 1154 1719 1282 2063 1538 — — — — — — — — 130° 54° 10.5:1 1314 980 1478 1102 1642 1224 1970 1469 — — — — — — — - - — 10:1 976 738 1090 813 1194 890 1366 1019 — — — — — — — — 8:1 900 671 998 744 1081 806 1216 907 — — — — — — — — 130° 54° 8:1 1120 836 1260 940 1400 1044 1680 1253 — — — — — — — — 85° 29° 8:1 1031 769 1160 865 1289 961 1547 1154 — — — — — — — — 130° 54° 8:1 985 735 1108 826 1232 919 1478 1102 — — — — — — — — 85° 29° 10.5:1 1031 769 1160 865 1289 961 1547 1154 — — — — — — — — 130° 54° 10.5:1 985 735 1108 826 1232 919 1478 1102 — — — — — — — - - — 10:1 732 546 818 610 896 668 1024 764 — — — — — — — — 8:1 675 503 748 558 810 604 912 680 — — — — — — — — 130° 54° 8.2:1 920 686 1035 772 1150 858 1380 1029 — — — — — — — — 85° 29° 8.2:1 848 632 954 711 1060 790 1272 949 — — — — — — — — 130° 54° 8.2:1 810 604 911 679 1013 755 1215 906 — — — — — — — — S5° 29° 10.2:1 — — — — 1265 944 1515 1130 — — — — — — — — J0° 54° 10.2:1 1205 899 1445 1078 — — — — — — — — 130° 54° 10.2:1 — — — — 1040 776 1250 933 — — — — — — — — 85° 29° 10:1 848 632 954 711 1060 790 1272 949 — — — — — — — — 130° 54° 10:1 810 604 911 679 1013 755 1215 906 — — — — — — — — 130° 54° 8:1 560 418 630 470 700 522 840 627 — — — — — — — — 85° 29° 8:1 516 385 580 433 644 480 773 577 — — — — — — — 130° 54° 8:1 492 367 554 413 615 459 738 550 — — — — — — — — 85° 29° 10.5:1 516 385 580 433 644 480 773 577 — — — — — — — — 130° 54° 10.5:1 492 367 554 413 615 459 738 550 — — — — — — — — 85° 29° 8.2:1 424 316 477 356 530 395 636 474 130° 54° 8.2:1 405 302 455 339 506 377 607 453 85° 29° 10:1 424 316 477 356 530 395 636 474 130° 54° 10:1 405 302 455 339 506 377 607 453 130° 54° 8.6:1 — — — — — — — 830 620 885 660 945 705 1065 800 130° 54° 11:1 — — — — — — 710' 530' 830' 620' 885' 660' 945' 705' 1065 800 130° 54° 11:1 — — — — — — — — 910 680' 975 730' 1040 775' 1175 880 130° 54° 8.6:1 — — — — — — — 620 460 670 500 710 530 800 600 130° 54° 11:1 — — — — — — 530' 400' 620' 460' 670' 500' 710' 530' 800 600 130° 54° 11:1 — — — — — — — 685 510' 735 550' 760 580' 880 660 130° 54° 8.6:1 — — — — — — — 415 310 445 330 475 355 530 400 130° 54° 11:1 — — — — — 355' 265' 415' 310' 445 330 475 355 530 400 130° 54° 8.7:1 — — — — — — — 415 310 445 330 475 355 530 400 130° 54° 11:1 — — — — — 455 340 490 365 520 390 585 440 130° 54° 8.6:1 — — — — — — — — 310 230 335 250 355 265 400 300 130° 54' 11:1 — — — — — — 265' 220' 310' 230' 335 250 355 265 400 300 130° 54° 8.7:1 -- -- -- -- -- -- --- 310 230 335 250 355 265 400 300 _ 30° 54° 11:1 — — — — — — 340 255 365 275 390 290 440 330 85° 29° 10:1 166 124 194 145 208 155 222 165 250 186 130° 54° 10:1 166 124 194 145 208 155 222 165 250 186 — — 10:1 — — 90 67 105 78 112 64 120 90 135 101 ISO Standvd Power (Continuous POW Rating): The highest load end speed *Itch can De Weed 24 now: P4rday. SOW Osye Mr elisk 36r days per year except b morn& menterwae rr a pearambk to aperate the engne et'4 to 10.4 o`orbed or the MaVnuM load Molted by the ntemdfenr reap, bAchevot u tow hr Mc noes in every 24 hor/ Cord 5 SEP 04 '91 04 : 9PM w7., Mr-, : `‘4 f Waukesha DRESSER PRODUCT BULLETIN July 12, 1991 PB #318 TO: WAUKESHA DISTRIBUTORS AND OEM'S SUBJECT: GAS ENGINE EXHAUST EMISSION LEVELS Waukesha Engine Division offers several methods of exhaust emission reduction. Our approach is to meet the various customer needs by offering several stages of emission control technology and to minimize the cost for the emission reduction required at a particular site. The following tables show typical levels which are attainable by an engine in good operating condition on comiercial quality natural gas fuel: gHI68ION LEVELS (ODEL CARBURETOR BETTING GR M /?.P -HR % OBSERVED MASS F.rR** VOLUME AYR" EX( A: E,^ Pox* Zo N j _ZQ_ .Q.. .30 ,GSI Lowest Manifold (Best Power) 7 28 .3 1.15 15.5:1 9.3:1 .S ,GSI Equal Nox & CO 10 10 .3 .25 .2 1.0. .45 .38 .02 .06 .30 15.9:1 9.5:1 .S ,GSI ,GSI GL Catalytic Cony. Input(3-way***) Normal (Best Economy) Normal 11 18 1.S 8 1 2:_65 .30 1.35 9.8 15.95:1'9.6:1 17:1 28:1 10.2:1 16.8:1 .S 1.0 1.7 $T25GL: ESS 7 9 6 4 GL (Normal 11.5 12.25 11.0 1.06 19.8 1 28:1 116.8:111.74 WAUKESHA ENGINE DIVISION DRESSER INDUSTRIES, INC. /111/1 .. • . . . . • M•11 tadi •••••••UNIVERSAL •.•••••• •• COMPRESSION MIRATECH Emissions Control Equipment Specification Summary Ref: Colorado Proposal Number: DD-03-317Rev00 Engine Data # of Engines: Engine Operation: Engine Make: Engine Model: Power Output: Fuel: Design Exhaust Temp: Design Exhaust Flow Rate: Lubrication Oil: 1 Gas Compression Waukesha 7044OSI 1680 bhp Natural Gas 1152 F 7524 acfm 0.6 wt% sulfated ash or less Catalytic Converter System Data Catalytic Converter Model: Inlet / Outlet Pipe Size: Overall Length: Diameter: Weight (including catalyst): Converter Pressure Loss: Sound Attenuation: Catalyst Section Internals: Shell / Body Constructions: Inlet I Outlet Connection: Instrumentation Ports: Oxygen Sensor Ports: Operation Temperature Limits; MCS-30Y3018-12-C2 .�r)nriaeS 102 inches 30 inches 1015 lbs 7.88 Inches of WC 25-30 dBA 304 SS Carbon Steel Standard 125# ANSI Bolt Pattern Flanges - FF 1 inlet / 1 outlet / 2 catalyst (1/2" NPT) 1 inlet / 1 outlet (18 mm) 750 - 1,250 degrees F (inlet); 1350 degrees F (outlet) Emission Requirements Exhaust Gases NOx CO NMHC Oxygen - Engine Outputs (g/ bhp -hr) 13.10 11.70 0.25 0.3% Reduction 4%) 92% 91% 0% Converter Area Limits Outputs (g/ bhp -hr) 1.00 1,00 0.25 1 g/bhp-hr 2 g/bhp-hr 3.5 g/bhp-hr MIRATECH guarantees the performance of the converter, as stated above, per the MIRATECH General Terms and Conditions of Sale. By: MIRATECH Catalyzer Date: 03/ 11/03 Page 26 G3520B GAS COMPRESSION APPLICATION GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka-PVTP CATERPILUIR' ENGINE SPEED (rpm): COMPRESSION RATIO: AFTERCOOLER - STAGE 2 INLET (°F): AFTERCOOLER - STAGE 1 INLET (°F): JACKET WATER OUTLET (°F): COOLING SYSTEM: IGNITION SYSTEM: EXHAUST MANIFOLD: COMBUSTION: NOx EMISSION LEVEL (g/bhp-hr NOx): SET POINT TIMING: 1400 8:1 130 201 210 JW+OC+1AC, 2AC ADEM3 DRY Ultra Lean Bum 1.0 25.0 FUEL SYSTEM: WITH SITE CONDITIONS: FUEL: FUEL PRESSURE RANGE(psig): FUEL METHANE NUMBER: FUEL LHV (Btu/scf): ALTITUDE(ft): MAXIMUM INLET AIR TEMPERATURE(°F): NAMEPLATE RATING: CAT WIDE RANGE AIR FUEL RATIO CONTROL Nat Gas 7.0-50.0 84.8 905 4771 77 1725 bhp@1400rpm MAXIMUM RATING SITE RATING AT MAXIMUM INLET AIR TEMPERATURE RATING NOTES LOAD 100% 100% 75% 50% ENGINE POWER (1) bhp 1725 1725 1293 862 INLET AIR TEMPERATURE °F 77 77 77 77 ENGINE DATA FUEL CONSUMPTION (LHV) FUEL CONSUMPTION (HHV) (2) (2) Btu/bhp-hr Btu/bhp-hr 7029 7797 7029 7797 7501 8320 8080 8963 AIR FLOW (3)(4) lb/hr 16152 16152 12349 8450 AIR FLOW WET (77°F, 14.7 psia) (3)(4) scfm 3643 3643 2785 1906 INLET MANIFOLD PRESSURE (5) in Hg(abs) 86.3 86.3 68.6 48.3 EXHAUST STACK TEMPERATURE (6) °F 996 996 1003 1053 EXHAUST GAS FLOW (@ stack temp, 14.5 psia) (7)(4) ft3/min 10661 10661 8211 5828 EXHAUST GAS MASS FLOW (7)(4) lb/hr 16766 16766 12840 8803 EMISSIONS DATA NOx (as NO2) (8) g/bhp-hr 1.00 1.00 1.00 1.00 CO (8) g/bhp-hr 2.55 2.55 2.77 3.25 THC (mol. wt. of 15.84) (8) g/bhp-hr 3.82 3.82 3.53 2.98 NMHC (mol. wt. of 15.84) (8) g/bhp-hr 0.57 0.57 0.53 0.45 NMNEHC (VOCs) (mol. wt. of 15.84) (8)(9) g/bhp-hr 0.38 0.38 0.35 0.30 HCHO (Formaldehyde) (8) g/bhp-hr 0.43 0.43 0.41 0.39 CO2 (8) g/bhp-hr 456 456 479 516 EXHAUST OXYGEN (10) % DRY 8.8 8.8 8.3 7.6 HEAT REJECTION HEAT REJ. TO JACKET WATER (JW) (11) Btu/min 27618 27618 27413 24474 HEAT REJ. TO ATMOSPHERE (11) Btu/min 7332 7332 6111 4889 HEAT REJ. TO LUBE OIL (OC) (11) Btu/min 5560 5560 4933 4153 HEAT REJ. TO A/C - STAGE 1 (1AC) (11)(12) Btu/min 11257 11257 8303 2372 HEAT REJ. TO A/C - STAGE 2 (2AC) (11)(12) Btu/min 6943 6943 5926 3809 HEAT EXCHANGER SIZING CRITERIA TOTAL JACKET WATER CIRCUIT (JW+OC+1AC) TOTAL AFTERCOOLER CIRCUIT (2AC) A cooling system safety factor of 0% has been added to the heat exchanger sizing criteria. (12)(13) (12)(13) Btu/min Btu/min 48873 7290 CONDITIONS AND DEFINITIONS Engine rating obtained and presented in accordance with ISO 3046/1, adjusted for fuel, site altitude and site inlet air temperature. 100% rating at maximum inlet air temperature is the maximum engine capability for the specified fuel at site altitude and maximum site inlet air temperature. Max rating is the maximum capability for the specified fuel at site altitude and reduced inlet air temperature. Lowest load point is the lowest continuous duty operating load allowed. No overload permitted at rating shown. For notes information consult page three. PREPARED BY: Joe Miller, MAC Data generated by Gas Engine Rating Pro Version 3.04.00 Ref. Data Set DM8770-02-001, Printed 30Aug2010 Page 1 of 4 G3520B GAS COMPRESSION APPLICATION GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka-PVTP CATERPILUIR' 2000 1500 o 1000 a. c m w 500 0 200D 2-1500 d1000 m w 500 0 30 40 50 60 70 80 90 Air Temperature, °F 100 110 120 1100 1150 1200 1250 Engine Speed (rpm) 1300 1350 1050 7000 6000 5000 ai g.4000 3000 'g2000 w 1000 0 1050 Engine Power vs. Inlet Air Temperature Data represents temperature sweep at 4771 ft and 1400 rpm 2000 1500 1000 500 0 130 Engine Power vs. Engine Speed Data represents speed sweep at 4771 ft and 77 °F 2000 1500 1000 500 0 1400 Engine Torque vs. Engine Speed Data represents speed sweep at 4771 ft and 77 °F 1100 1150 1200 1250 Engine Speed (rpm) 1300 1350 1400 7000 ■ ■ Max Continuous Power vs. Speed Capability for Site Conditions No Rating Available Range for Site Conditions Continuous Operating Range for Site Conditions Low Load Intermittent Operating Range Max Continuous Power vs. Speed Capability for Site Conditions No Rating Available Range for Site Conditions Continuous Operating Range for Site Conditions Low Load Intermittent Operating Range 6000 Max Continuous Torque vs. Speed Capability 5000 for Site Conditions 4000 . No Rating Available Range for Site Conditions 3000 2000 ElContinuous Operating Range for Site Conditions 1000 Low Load Intermittent 0 Operating Range Note: At site conditions of 4771 ft and 77°F inlet air temp., constant torque can be maintained down to 1050 rpm. The minimum speed for loading at these conditions is 1050 rpm. PREPARED BY: Joe Miller, MAC Data generated by Gas Engine Rating Pro Version 3.04.00 Ref. Data Set DM8770-02-001, Printed 30Aug2010 Page 2 of 4 G3520B GAS COMPRESSION APPLICATION GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka-PVTP CATERPILLAR` NOTES 1. Engine rating is with two engine driven water pumps. Tolerance is ± 3% of full load. 2. Fuel consumption tolerance is ± 3.0% of full load data. 3. Air flow value is on a 'wet basis. Flow is a nominal value with a tolerance of ± 5 %. 4. Inlet and Exhaust Restrictions must not exceed A&I limits based on full load flow rates from the standard technical data sheet. 5. Inlet manifold pressure is a nominal value with a tolerance of ± 5 % 6. Exhaust stack temperature is a nominal value with a tolerance of (+)63°F. (-)54`F. 7. Exhaust flow value is on a "wet" basis. Flow is a nominal value with a tolerance of ± 6 %. 8. Emission levels are at engine exhaust flange prior to any after treatment. Values are based on engine operating at steady state conditions, adjusted to the specified NOx level at 100% load. Fuel methane number cannot vary more than ± 3. Values listed are higher than nominal levels to allow for instrumentation, measurement, and engine -to -engine variations. They indicate "Not to Exceed" values. THC. NMHC, and NMNEHC do not include aldehydes. An oxidation catalyst may be required to meet Federal, State or local CO or HC requirements. 9. VOCs - Volatile organic compounds as defined in US EPA 40 CFR 60. subpart JJJJ 10. Exhaust Oxygen level is the result of adjusting the engine to operate at the specified NOx level. Tolerance is ± 0.5. 11. Heat rejection values are nominal. Tolerances. based on treated water. are ± 10% for jacket water circuit, ± 50% for radiation, ± 20% for lube oil circuit. and ± 5% for aftercooler circuit. 12. Aftercooler heat rejection includes an aftercooler heat rejection factor for the site elevation and inlet air temperature specified. Aftercooler heat rejection values at part load are for reference only. Do not use part load data for heat exchanger sizing. 13. Heat exchanger sizing criteria are maximum circuit heat rejection for the site, with applied tolerances. PREPARED BY: Joe Miller. MAC Data generated by Gas Engine Rating Pro Version 3.04.00 Ref. Data Set DM8770-02-001, Printed 30Aug2010 Page 3 of 4 Constituent Abbrev Mole % Norm Water Vapor Methane Ethane Propane Isobutane Norbutane Isopentane Norpentane Hexane Heptane Nitrogen Carbon Dioxide Hydrogen Sulfide Carbon Monoxide Hydrogen Oxygen Helium Neopentane Octane Nonane Ethylene Propylene TOTAL (Volume %) H2O 0.0000 0.0000 CH4 92.2700 92.2700 C2H6 2.5000 2.5000 C3H8 0.5000 0.5000 iso-C4H1O 0.0000 0.0000 nor-C4H1O 0.2000 0.2000 iso-05H12 0.0000 0.0000 nor-05H12 0.1000 0.1000 C6H14 0.0500 0.0500 C7H16 0.0000 0.0000 N2 3.4800 3.480D CO2 0.9000 0.9000 H2S 0.0000 0.0000 CO 0.0000 0.0000 H2 0.0000 0.0000 O2 0.0000 0.0000 HE 0.0000 0.0000 neo-05H12 0.0000 0.0000 C8H18 0.0000 0.0000 C9H20 0.0000 0.0000 C2H4 0.0000 0.0000 C3H6 0.0000 0.0000 100.0000 100.0000 Fuel Makeup: Unit of Measure: Nat Gas English Calculated Fuel Properties Caterpillar Methane Number: 84.8 Lower Heating Value (Btu/set): Higher Heating Value (Btu/scf): WOBBE Index (Btu/scf): THC: Free Inert Ratio: 905 1004 1168 0 RPC (%) (To 905 Btu/scf Fuel): 100% Compressibility Factor: Stoich A/F Ratio (VoINol): Stoich A/F Ratio (Mass/Mass): Specific Gravity (Relative to Air): Specific Heat Constant (K): 0.998 9.45 15.75 0.600 1.313 CONDITIONS AND DEFINITIONS Caterpillar Methane Number represents the knock resistance of a gaseous fuel. It should be used with the Caterpillar Fuel Usage Guide for the engine and rating to determine the rating for the fuel specified. A Fuel Usage Guide for each rating is included on page 2 of its standard technical data sheet. RPC always applies to naturally aspirated (NA) engines, and turbocharged (TA or LE) engines only when they are derated for altitude and ambient site conditions. Project specific technical data sheets generated by the Caterpillar Gas Engine Rating Pro program take the Caterpillar Methane Number and RPC into account when generating a site rating. Fuel properties for Bturscf calculations are at 60F and 14 696 psia. Caterpillar shall have no liability in law or equity. for damages. consequently or otherwise. arising from use of program and related material or any part thereof. FUEL LIQUIDS Field gases. well head gases. and associated gases typically contain liquid water and heavy hydrocarbons entrained in the gas. To prevent detonation and severe damage to the engine. hydrocarbon liquids must not be allowed to enter the engine fuel system. To remove liquids, a liquid separator and coalescing filter are recommended. with an automatic drain and collection lank to prevent contamination of the ground in accordance with local codes and standards. To avoid water condensation in the engine or fuel lines. limit the relative humidity of water in the fuel to 80% at the minimum fuel operating temperature. G3306 TA GAS COMPRESSION APPLICATION GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka-PVTP CATERPIWIR' ENGINE SPEED (rpm): COMPRESSION RATIO: AFTERCOOLER WATER INLET (°F): JACKET WATER OUTLET (CF): COOLING SYSTEM: IGNITION SYSTEM: EXHAUST MANIFOLD: COMBUSTION: EXHAUST O2 EMISSION LEVEL °/0: SET POINT TIMING: 1800 8.0:1 130 210 JW+OC, AC MAG WC Catalyst 0.5 35.0 FUEL SYSTEM: WITH CUSTOMER SUPPLIED SITE CONDITIONS: FUEL: FUEL PRESSURE RANGE(psig): FUEL METHANE NUMBER: FUEL LHV (Btu/scf): ALTITUDE(ft): MAXIMUM INLET AIR TEMPERATURE(°F): NAMEPLATE RATING: HPG IMPCO AIR FUEL RATIO CONTROL Nat Gas 12.0-24.9 84.8 905 4771 32 203 bhp@1800rpm MAXIMUM RATING SITE RATING AT MAXIMUM INLET AIR TEMPERATURE RATING NOTES LOAD 100% 100% 75% 52% ENGINE POWER (1) bhp 195 195 146 101 INLET AIR TEMPERATURE °F 32 32 32 32 ENGINE DATA FUEL CONSUMPTION (LHV) FUEL CONSUMPTION (HHV) (2) (2) Btu/bhp-hr Btu/bhp-hr 8149 9040 8149 9040 8524 9455 9195 10199 AIR FLOW (3)(4) lb/hr 1311 1311 1047 788 AIR FLOW WET (77°F, 14.7 psia) (3)(4) scfm 296 296 236 178 INLET MANIFOLD PRESSURE (5) in Hg(abs) 37.6 37.6 31.5 24.9 EXHAUST STACK TEMPERATURE (6) °F 1059 1059 1025 988 EXHAUST GAS FLOW (@ stack temp, 14.5 psia) (7)(4) ft3/min 937 937 731 536 EXHAUST GAS MASS FLOW (7)(4) lb/hr 1391 1391 1110 835 EMISSIONS DATA NOx (as NO2) (8) g/bhp-hr 16.50 16.50 15.98 13.78 CO (8) g/bhp-hr 16.50 16.50 15.98 13.78 THC (mol. wt. of 15.84) (8) g/bhp-hr 1.22 1.22 1.41 1.67 NMHC (mol. wt. of 15.84) (8) g/bhp-hr 0.18 0.18 0.21 0.25 NMNEHC (VOCs) (mol. wt. of 15.84) (8)(9) g/bhp-hr 0.12 0.12 0.14 0.17 HCHO (Formaldehyde) (8) g/bhp-hr 0.25 0.25 0.25 0.25 CO2 (8) g/bhp-hr 515 515 553 607 EXHAUST OXYGEN (10) % DRY 0.5 0.5 0.5 0.5 HEAT REJECTION HEAT REJ. TO JACKET WATER (JW) (11) Btu/min 8861 8861 7431 6039 HEAT REJ. TO ATMOSPHERE (11) Btu/min 1061 1061 832 622 HEAT REJ. TO LUBE OIL (OC) (11) Btu/min 1401 1401 1175 955 HEAT REJ. TO AFTERCOOLER (AC) (11)(12) Btu/min 515 515 185 31 HEAT EXCHANGER SIZING CRITERIA TOTAL JACKET WATER CIRCUIT (JW+OC) TOTAL AFTERCOOLER CIRCUIT (AC) A cooling system safety factor of 0% has been added to the heat exchanger sizing criteria. (12) (12)(13) Btu/min Btu/min 11428 540 CONDITIONS AND DEFINITIONS Engine rating obtained and presented in accordance with ISO 3046/1, adjusted for fuel, site altitude and site inlet air temperature. 100% rating at maximum inlet air temperature is the maximum engine capability for the specified fuel at site altitude and maximum site inlet air temperature. Max. rating is the maximum capability for the specified fuel at site altitude and reduced inlet air temperature. Lowest load point is the lowest continuous duty operating load allowed. No overload permitted at rating shown. For notes information consult page three. PREPARED BY: Joe Miller, MAC Data generated by Gas Engine Rating Pro Version 3.04.00 Ref. Data Set DM5202-04-000, Printed 30Aug2010 Page 1 of 4 G3306 TA GAS COMPRESSION APPLICATION GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka-PVTP CATERPILUIR' 250 a 200 150 a° Ca 100 c w 50 0 250 a 200 3 150 a O • 100 c w 50 0 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 Engine Speed (rpm) 600 a 500 400 lEr. 300 .. g• 200 30 40 50 60 70 80 90 Air Temperature, °F 100 110 120 Engine Power vs. Inlet Air Temperature Data represents temperature sweep at 4771 ft and 1800 rpm 250 200 150 100 50 0 130 Engine Power vs. Engine Speed Data represents speed sweep at 4771 ft and 32 °F NEB MEM u! 100 250 200 150 100 50 0 Engine Torque vs. Engine Speed Data represents speed sweep at 4771 ft and 32 °F 600 500 400 300 200 100 0 0 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 Engine Speed (rpm) El Max Continuous Power vs. Speed Capability for Site Conditions No Rating Available Range for Site Conditions Continuous Operating Range for Site Conditions Low Load Intermittent Operating Range Max Continuous Power vs. Speed Capability for Site Conditions No Rating Available Range for Site Conditions Continuous Operating Range for Site Conditions Low Load Intermittent Operating Range Max Continuous Torque vs. Speed Capability for Site Conditions No Rating Available Range for Site Conditions Continuous Operating Range for Site Conditions Low Load Intermittent Operating Range Note: At site conditions of 4771 ft and 32°F inlet air temp., constant torque can be maintained down to 1210 rpm. The minimum speed for loading at these conditions is 1200 rpm. PREPARED BY: Joe Miller, MAC Data generated by Gas Engine Rating Pro Version 3.04.00 Ref. Data Set DM5202-04-000, Printed 30Aug2010 Page 2 of 4 G3306 TA GAS COMPRESSION APPLICATION GAS ENGINE SITE SPECIFIC TECHNICAL DATA Aka-PVTP CATERPILLAR NOTES 1. Engine rating is with two engine driven water pumps. Tolerance is ± 3% of full load. 2. Fuel consumption tolerance is ± 5.0% of full load data. 3. Air flow value is on a 'vet' basis. Flow is a nominal value with a tolerance of ± 5 % 4. Inlet and Exhaust Restrictions must not exceed A&I limits based on full load flow rates from the standard technical data sheet. 5. Inlet manifold pressure is a nominal value with a tolerance of ± 5 %. 6. Exhaust stack temperature is a nominal value with a tolerance of (+)63°F. (-)54°F. 7. Exhaust flow value is on a "wet" basis. Flow is a nominal value with a tolerance of ± 6 %. 8. Emission levels are at engine exhaust flange prior to any after treatment. Values are based on engine operating at steady state conditions. Fuel methane number cannot vary more than ± 3. Values listed are higher than nominal levels to allow for instrumentation, measurement, and engine -to -engine variations. They indicate "Not to Exceed" values. THC, NMHC, and NMNEHC do not include aldehydes. Part Load data requires customer supplied air fuel ratio control. 9. VOCs - Volatile organic compounds as defined in US EPA 40 CFR 60, subpart JJJJ 10. Exhaust Oxygen tolerance is ± 0.2. 11. Heat rejection values are nominal. Tolerances, based on treated water, are ± 10% for jacket water circuit, ± 50% for radiation, ± 20% for lube oil circuit, and ± 5% for aftercooler circuit. 12. Aftercooler heat rejection includes an aftercooler heat rejection factor for the site elevation and inlet air temperature specified. Aftercooler heat rejection values at part load are for reference only. Do not use part load data for heat exchanger sizing. 13. Heat exchanger sizing criteria are maximum circuit heat rejection for the site, with applied tolerances. PREPARED BY: Joe Miller, MAC Data generated by Gas Engine Rating Pro Version 3.04.00 Ref. Data Set DM5202-04-000, Printed 30Aug2010 Page 3 of 4 Constituent Abbrev Mole % Norm Water Vapor Methane Ethane Propane Isobutane Norbutane Isopentane Norpentane Hexane Heptane Nitrogen Carbon Dioxide Hydrogen Sulfide Carbon Monoxide Hydrogen Oxygen Helium Neopentane Octane Nonane Ethylene Propylene TOTAL (Volume %) H2O 0.0000 0.0000 CH4 92.2700 92.2700 C2H6 2.5000 2.5000 C3H8 0.5000 0.5000 iso-C4H1O 0.0000 0.0000 nor-C4H1O 0.2000 0.2000 iso-05H12 0.0000 0.0000 nor-05H12 0.1000 0.1000 C6H14 0.0500 0.0500 C7H16 0.0000 0.0000 N2 3.4800 3.480D CO2 0.9000 0.9000 H2S 0.0000 0.0000 CO 0.0000 0.0000 H2 0.0000 0.0000 O2 0.0000 0.0000 HE 0.0000 0.0000 neo-05H12 0.0000 0.0000 C8H18 0.0000 0.0000 C9H20 0.0000 0.0000 C2H4 0.0000 0.0000 C3H6 0.0000 0.0000 100.0000 100.0000 Fuel Makeup: Unit of Measure: Nat Gas English Calculated Fuel Properties Caterpillar Methane Number: 84.8 Lower Heating Value (Btu/set): Higher Heating Value (Btu/scf): WOBBE Index (Btu/scf): THC: Free Inert Ratio: RPC (%) (To 905 Btu/scf Fuel): Compressibility Factor: Stoich A/F Ratio (VoINol): Stoich A/F Ratio (Mass/Mass): Specific Gravity (Relative to Air): Specific Heat Constant (K): 905 1004 1168 21.83 100% 0.998 9.45 15.75 0.600 1.313 CONDITIONS AND DEFINITIONS Caterpillar Methane Number represents the knock resistance of a gaseous fuel. It should be used with the Caterpillar Fuel Usage Guide for the engine and rating to determine the rating for the fuel specified. A Fuel Usage Guide for each rating is included on page 2 of its standard technical data sheet. RPC always applies to naturally aspirated (NA) engines, and turbocharged (TA or LE) engines only when they are derated for altitude and ambient site conditions. Project specific technical data sheets generated by the Caterpillar Gas Engine Rating Pro program take the Caterpillar Methane Number and RPC into account when generating a site rating. Fuel properties for Bturscf calculations are at 60F and 14 696 psia. Caterpillar shall have no liability in law or equity. for damages. consequently or otherwise. arising from use of program and related material or any part thereof. FUEL LIQUIDS Field gases. well head gases. and associated gases typically contain liquid water and heavy hydrocarbons entrained in the gas. To prevent detonation and severe damage to the engine. hydrocarbon liquids must not be allowed to enter the engine fuel system. To remove liquids, a liquid separator and coalescing filter are recommended. with an automatic drain and collection lank to prevent contamination of the ground in accordance with local codes and standards. To avoid water condensation in the engine or fuel lines. limit the relative humidity of water in the fuel to 80% at the minimum fuel operating temperature. for Windows O W U Q W OC Z 0 H J 0 Simulation Result: Sour Gas treatment with Mixed Amine 0 N O. w W 2 2 2 a` a` F Q 6,192.5 lb/hr 12.2 Btu/SCF -6,213,530 Btu/hr(condenser) C •W a. m N 0 8 Amine Feed 150 gal/min at STP LL U3 a O LL O 0 N Warm L '0l LL 0 N N `0 C C, co O 40 MMSCFD a E 8°° 0 W o ao co W� co C co a x 'cc a N O O Gross Burner is 16.0 MMBTU/hr Net= 12,000,000 Btu/hr M STREAM SUMMARY Stream Number I 2 3 4 5 6 7 8 9 10 11 Stream Name SOS, Ws S'+eal GIs COW Ron Arnim Feed Makeup Water Fbl Ron Sam 7 Hot Lean Vent $tom Wean Lean Thermo Method Option GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL Vapor Fraction 0 9999636 I 0 0 0 0 0011194 0 0126303 0 1 0 0 Temperature F 100 13346286 17888358 115 85 23447199 22078488 25633894 150 25967575 18908535 Pressor. psa 893 902.696 903712= 917 30 63 30 29.696 26.196 913 913 Vapor Density 16113 4 05018 3.56372 0.3017108 0.1296892 0.1625966 L iquid l Density 16.113 6293919 6442107 63.88109 6303888 625462 62.75613 5940192 5929658 61.60096 liquid 1 Specdic Gravity 60FrO5TP 0.9975448 1.01096 1.01284 Vapor Z Factor 0799956 0.819602 0.983447 0.989348 0991746 Vapor Flowrate 4.ILISCF'deyeSTP 39 99414 38.65174 0.0267414 0 301728 140054 Llquld 1 Flowrate palimmGSTP L iquid l Flowrate gaLYMn 0.0057723 164 04841 150 0 9346572 163 54648 161 40443 148 9077 150 150 Molecular Weight 21788 210954 315621 311115 182845 31.5712 11.5712 310295 40.269 31.1115 31.1115 Molar Flowrate 1600,3410 4391.4536 4265.8603 26252799 2481.002 25.6013 2622.9955 26229955 2469.2183 1537772 2481.002 2481.002 Mass Flowreta IOW 95681 1631 899899069 82859.2464 771876575 468.1067 82811.0854 828110854 76618.6272 61924582 77187.6572 77167.6572 Note: All Liquid I Pnaae calculations exclude Free Water Molar Flowtete By Component 67: WATER 16,00610 610384 138659 210356 46 : NITROGEN 8Nra610 10 5016 10498 0.00361 49: CARBON DIOXIDE ®166510 131.27 027518 158.806 50: HYDROGEN SULFIDE 16rriolM 0.013127 0.00002239 0.013208 2 : METHANE 16011.410 334336 3341 65 1.71621 3'ETHANE 8111550 526.582 526.352 02230003 4: PROPANE 16110419 207.039 206981 0057949 5 : ISOBUTANE ronia610 34 6041 348022 0 001892 6:N -BUTANE Ibrrg6h 692625 69.252 0010549 7:1.PENTANE wrm619 217908 217893 0001596 8 : N -PENTANE Donate 21.6596 21.658 0.001534 36: CYCLOPENTANE i6noWs7 0 0 0 ID: N -HEXANE -trma1717, 14.0022 13.9985 0.003624 38: CYCLOHEXANE 100 71 0 0 0 II: N-HEPTANE 700. Fr 0932018 093133 0000688 39: METHYLCYCLOHEXAN emu r. 0 0 0 40: BENZENE omo. , 0.974462 0776661 0197601 41 :TOLUENE 0835755 0710825 0124929 45: ETHYL BENZENE Smirk m 0013127 0.012783 0000344 42:0-XYLENE Oro nr 0.179403 0 173364 0.006038 12: 9.0818NE D.7no 'I 212658 205614 0070441 4051: DEA 0 0 0 2053 : DOA tmo, nr 0 0.079944 360473 Total .5090:.01 439145 426586 262528 Molar Composition By Component 62: WATER molar 96 0 138993726 0.325043485 80.12707216 46: NITROGEN maw% 0.239137415 0246093402 0000137509 49 :CARBON DIOXIDE maim% 2.989217684 0006450751 6049107143 50: HYDROGEN SULFIDE MOW % 0.000298922 5.24865E-07 0000505108 2: METHANE =We % 76.13339558 78.33473204 0065372456 3 : ETHANE )polar % 11 99107356 12.33870779 000876/085 4:PROPANE nWar% 4.71459313 4852034525 0002207346 5: ISOBUTANE node% 0.792542327 0.815830806 7.20685E-05 6:9 -BUTANE n5aW % 1.577212538 1.623400674 0.000401824 7:I -PENTANE n191ar % 049620968 0510783289 6.07935E-05 8:N -PENTANE mill% 0493222056 0507705363 5.84319E-05 36:CYCLOPENTANE ng1O% 0 D 0 10: N -HEXANE 54006% 0318851401 0.328151885 0000138042 38:CYCLOHEXANE fl, % 0 0 0 II : N-HEPTANE B9 % 0021223468 0021832175 262067E-05 39: METHYLCYCLOHEXAN =W% 0 0 0 40: BENZENE MOW% 0022189983 0.018206434 0007534473 41 : TOLUENE Haw% 0019031368 0.016663111 0001758692 45 : ETHYL BENZENE n10Yr % 0.000298922 0.000299658 1.31034E-05 42 : 0-XYLENE n14W % 0 004085279 0.004065987 0 000444,85 12: N -OCTANE Made% 0048425463 0.048199891 0.00268318 4051: DEA mot.% 0 0 0 2053 : DOA Mar % 0 0.001874042 13.73084014 Total motto% 100 100 100 Mass Componlllon By Component 62 : WATER mess % 0.114926443 0.277585596 45.73577828 46 : NITROGEN mess % 0 307464789 0 326797785 0 000122059 49 : CARBON DIOXIDE mass % 6.037800529 0.013457399 8.434645761 1.622 80816 50: HYDROGEN SULFIDE mass% 0.000467588 847873E-07 0.000543278 4.19367E-06 2 : METHANE mass % 56.05855696 59.57335212 0 03328778 3:ETHANE mess% 16.5479739 17 5867514 0008346363 4 : PROPANE mass % 9.511257644 10.14184925 0 003083798 5 : ISOBUTANE mess% 2114114371 2247696686 0000132719 6 : N -BUTANE mass % 4.207242384 4.472635262 0 000739969 7: I -PENTANE mass% 1643081399 1.746873816 0000138961 8 : N -PENTANE mass % 1 633183948 1.736350413 0 000133528 36 : CYCLOPENTANE mass% 0 0 0 10 : N -HEXANE mass % 1 261062328 1 340461541 0 000376849 38: CYCLOHEXANE mass% 0 0 0 11: N-HEPTANE rows% 0.097601619 0.103697637 8.32291E-05 39: METHYLCYCLONEXAN mess% 0 0 0 40: BENZENE mass% 0.079548656 0.067411454 0.018615647 41: TOLUENE mass% 0.080476938 0.072776056 0.013891276 45: ETHYL BENZENE mass% 0001456462 0.001507969 440989E-05 47:0-XYLENE mass% 001990506 0020451628 0000773629 12 : N -OCTANE mass % 0.253870144 0.260964844 0 009710557 4051 : DEA mass % 0 0 0 2053 : DCA mass % 0 0.00934007 45.73964026 Total mess% 100 100 100 2088 09 25 222 0 284603 0.00009499 2103.35 210335 2080.68 22 6683 0.000141 0000141 0 0000141 158639 158639 28.062 130.577 0.013171 0.013171 0.00006705 0 013104 0 109999 0 109999 0.109999 0 015363 0 015363 0 015363 0 002969 0 002969 0 002969 0.00002404 0.00002404 000002404 0000356 0 000356 0 000356 0 00002964 0 00002964 0.00002964 0.00002841 000002841 0.00002841 O 0 0 0000266 0.000266 0 000266 O 0 0 0.000138 0 000138 0 000138 O 0 0 0 195176 0.195176 0.195176 0 123308 0 123308 0 123308 0.000321 0.000321 0 000321 0 005731 0 005731 0005731 0.06506 0 06506 0 06506 0 0 0 2088 09 2088 09 0 0 284603 28_4603 0.00008655 0.00008655 364449 0.079092 360473 360 473 360473 0.0000171 364.449 364 449 2481 25.6013 2623 2623 2469 22 153 777 2481 24 1 84 16324063 99.69103131 60 18871521 80 18871521 64.26466657 14 74102109 84 16324063 84 16324063 5 37552E-06 5 37552E-06 0 9.16912E-05 0 0 1147130189 6047998475 6.047998475 1136472246 64.91321649 1147130189 1147130189 3.826 E-06 0.000502135 0000502135 271543E-06 0.00852143 7488 1E-06 348851E-06 0.004193633 0.004196019 0.071531503 0 000585703 0 000585703 0 009990441 0.000113191 0.000113191 0.001930718 9 16508E-07 9.16508E-07 1 5633E-05 1.35722E-05 1.35722E-05 0.000231504 1.13E-06 1.13E-06 192747E-05 1.08311E-06 1.08311E-06 1.84748E-05 O 0 0 1.01411E-05 101411E -D5 0000172978 O 0 0 5 26115E-06 5 26115E-06 8.97403E-05 O 0 0 0.007440945 0.007440915 0.126921451 0.004701029 0004701029 0.080186244 1.22379E-05 1.22379E-05 0.000208744 000021849 0.00021649 0003726825 0.002480366 0002480366 0.042308017 O 0 0 14.66%0097 0308 37437 1374277545 13.74277545 14.59685869 1.112E-05 1468960097 14.68950097 100 100 100 100 100 100 100 100 Liquid 1 Volumetric Flowrate By Component 62: WATER 5340 46. NITROGEN 53010 49: CARBON DIOXIDE 53,10 50: HYDROGEN SULFIDE 5319 2: METHANE 5318 3: ETHANE 5310 4 : PROPANE 5310 5:ISOBUTANE 5340 6:N -BUTANE 53,10 0:1•PENTANE 113/30 8: N -PENTANE 53.10 36: CYCLOPENTANE 5319 10. N -HEXANE 5300 38 CYCLOHEXANE 5319 11 : N-HEPTANE 5310 39: METHYLCYCLOHEXAN 83110 40. BENZENE 53 0 41: TOLUENE 5310 45: ETHYL BENZENE 5359 42:0-XYLENE 5300 12 : N -OCTANE 5310 4051 : DEA 5310 2053 : DCA 5310 Total 5319 48 7161555 98.222348309 4964 97664 1.776431457 100 100 4575787545 45.75787545 48.92310744 6.594762017 48.7353555 48.73 3555 475119E-06 475419E-06 0 6.35773E-05 0 8.430633091 8430633091 1 611854041 92.79882308 1.622680816 1.6222680616 0.000543081 0.000542081 2.9823E-06 0.007212287 3.82185E-06 3.821 5E-06 0.002131007 0.002131007 0.028497721 0 0.000557825 0.000557825 0.007459733 0 0.000158109 0.000158109 0.002114378 0 1.68697E-06 1 68697E-06 2 25597E-05 0 2.50015E-05 250015E-05 0000334342 0 2.58178E-06 2.58178E-06 3.45259E-05 0 2.47551E-06 2 47551E-06 3.31048E-05 0 O 0 0 0 2.76871E-05 2 76871E-05 0.000070257 0 O 0 0 0 1.67514E-05 1.67514E-05 0.000224014 0 O 0 0 0 0018409126 0.018409126 0.246181262 0 0.013719655 0.013719055 0.183463438 0 4.1201E-05 4.1201E-05 0.00550977 0 0 000734677 0.000734677 0.009824755 0 0.008973954 0.008973954 0.120007719 0 O 0 0 0 45 76608691 45.76608691 4946501241 290353E-05 49.64197664 4964197664 100 100 100 100 100 100 Page 2 12 13 14 15 16 17 18 19 Strm 12 $11111 13 Smn 14 To FUN Strm 16 50,0 17 $Mn 18 Stan 19 GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL GLOBAL 0 0008702 0 1 1 0 1 I 1 174.08535 174 08535 689 17314 174 08535 25533099 650 689 17314 60 63 63 12 20377 63 29 696 12 7 12 7 13 0.197483 0.0297056 0.197483 0.0249497 0.0309134 0.0401177 64 59378 64 59378 5944269 1.01067 0.989068 1.0001 0.989068 1.0002 10001 0.997525 0 0208056 740054 0.0208056 6 7 40054 0.6 163.79838 163.79838 150 315621 315712 30.0084 210832 31.1115 27.6133 30.0084 17165 26252799 2622 9955 8125678 2 2844 2481 002 6587907 812.5678 65.8791 82859.2484 82811.0854 24383.8603 48.563 77187 6572 18191.4021 24383 8603 1130.8136 2103.56 2103 35 154 426 0 208267 000361 0.000181 461 154 0.00347 158 806 158.639 196 456 0 567673 0013208 0.013171 0.013104 0.00003675 1.71621 0.109999 0.109999 1.60621 0 230003 0.015363 0 015363 0 21464 0057949 0.002969 0002969 0.05498 0001892 000002404 000002404 0.001868 0010549 0.000356 O000356 0010193 0.001598 0.00002964 0 00002964 0.001566 0001534 0.00002841 0.00002841 0.001505 O 0 0 0 0003624 0.000266 0000266 0003358 O 0 0 0 0 000688 0.000138 0 000138 0 00055 O 0 0 0 0.197601 0.195176 0 195176 0002625 0.124929 0.123308 0 123308 0 00162 0000344 0.000321 0.000321 0.00002201 0006038 0.005731 0.005731 0 000307 0.070441 0O6506 0.06506 0 005381 0 0 0 0 360473 360 473 0.0000171 0000151 2625.28 2621 812 568 2 28443 208 09 131 755 461 153 28. 603 65 791 0.00008655 364 449 2481 658 791 154 425 461 154 196 456 0 013104 0 109999 0 015363 0 002969 0 00002404 0 000356 0 00002964 0.00002841 0 0000266 0 D 000138 0 0195176 0 123308 0 000321 0 005731 0 06506 00000171 812 568 80.12707216 80 18871521 19 00468638 9.116603754 84 16324063 19 99996964 19 00468638 0.000137509 5.37552E-06 5675266562 0.151897648 0 6999989374 56.75266562 6.049107143 6.047998475 24 17717656 7.33981781 1.147130189 I 24.17717656 0.000503108 0.000502135 0.001612665 0.001808716 3488.1E-06 0.001612665 0.065372456 0 004193633 0.013537206 70.3111536 0013537206 0.008761085 0000585703 0.001890673 9.395779253 0.001890673 0002207346 0000113191 0.000365385 240672728 0.000365385 720685E-05 916506E-07 295652E-06 0081770945 2 95652E-06 0.000401824 1 35722E-05 4 38117E-05 0.446194456 438117E-05 6.07935E-05 .1 3E-06 3 64769E-06 0.068551017 3.64769E-06 5.64319E-05 1 08311E-06 349632E-06 0.065880767 349632E-06 O 0 0 0 0000138042 101411E-05 3.27357E-05 0 146995053 O 0 0 0 2 62067E-05 5 26115E-06 169632E-05 0 024076028 O 0 0 0 0.007534473 0.007440945 0.024019651 0.114908314 0.004758692 0.004701029 0.015175099 0.070914845 1.31034E-05 1.22379E-05 3.95044E-05 0.000998499 0000229995 0.00021849 0.000705295 0.013438801 000268318 0002480366 0.008006715 0.2355511 0 0 0 0 13 73064014 13 74277545 2.10444E-06 0 006609964 100 100 100 100 1a 68960097 'Co 100 0 3.27357E-05 0 69532E-05 0 0.024019651 0.015175099 3.95044E-05 0.000705295 0.008006715 2 10464E-06 100 45 73577828 45.75757545 11.40937258 7.790212404 48.73 3555 13 04830554 11 40937258 0.000122559 4 75419E-06 52.97963 0.201814671 71 01 32545 52 97963 8 434645761 8.430633091 35 45696136 15.32105558 1.622 80816 15 93 53092 35 45696136 0.000543278 0.000542081 000183161 0002601582 3821 5E-06 0.00183161 0.033228778 0.002131007 0.007237193 53.50248116 0.007237193 0008346363 0000557825 0.001894451 13.39989203 0.001894451 0003383798 0000158109 0000536961 5033469676 0.000536961 0000132719 1 68697E-06 572919E-06 0.225428233 572919E-06 0000739969 2 50015E-05 8 49085E-05 1230050038 8 49085E-05 0.000138961 2 58178E-06 8 76808E-06 0 234628242 8 76808E-06 0000133528 247551E-06 8.40719E-06 0.22546353 840719E-06 O 0 0 0 0 0.000376849 276871E-05 9.40293E-05 0.60072047 9.40293E-05 O 0 0 0 0 832291E-05 167514E-05 5.689E-05 0.114384486 5689E-05 O 0 0 0 0 0018645847 0.018409126 0.062519941 0.425760439 0.062519941 0013891276 0.013719055 0.046591809 0.309988996 0.046591809 440989E-05 4.1201E-05 0000139924 0.00502668 0.000139924 0.000773629 0.000734677 0002495064 0.067747026 0.002495064 0 009710557 0 008973954 0 03047679 1.276199572 0 03047679 O 0 0 0 0 45 73964029 45 76608691 7 37372E-06 0033046114 49.64197664 7.37372E-06 100 100 100 100 100 100 100 0 0 0 0 61.2675 3.95274 0.658791 65 791 92.99990437 5999990892 100 66.92 23345 1051 25371 2 568840035 00 P898 3 HEAT EXCHANGERS / CONDENSERS Equipment Number Equipment Name 5 6 Rich/Lean Cooler Overall Heat Trans. Coef. Btu/hr/ft2/F 120 50 Area Per Shell ft2 1370.57 1377.47 Number Of Shells 1 1 Shell Passes Per Shell 1 1 Tube Passes Per Shell 1 1 Cooling Water gal/hr 0 26850 Delta Pressure Shellside Delta Pressure Tubeside Calculated Duty Shellside Btu/hr -3233882 -3354962 Specified Duty Shellside Refrigerant Number Refrigerant Pressure Refrigerant Temperature Mean Temperature Difference Utility Temperature In F 90 Utility Temperature Out F 105 Temperature Out Spec. F 115 Temperature Approach Spec. F 15 Delta Temperature Spec. Calculated Area/Shell Estimated Area Corrected MTD (Q/UA) F 19.66 48.71 Calculated LMTD F 19.66 48.71 LMTD Correction Factor 1 1 Curve Increment Segments Curve Increment Total Area/Shell Curve Increment Average Log Mean Temperature Difference Rating no no Page 4 PUMPS / COMPRESSORS / EXPANDERS Equipment Number 4 Equipment Name P-4 Driver Type ELECTRIC Calculation Type PUMP Stages 1 Work Capacity HP 1000000 Calculated Outlet Pressure psia 913 Specified Outlet Pressure psia 913 Specified Poly Coeficient Calculated Poly Coeficient Polytropic Head Interstage Temperature Out Efficiency (of calc type) 0.65 Water Flow Fuel Flow Electrical Usage kW 95.6306 Real Work HP -128.3599 Isentropic Head Isentropic Efficiency Inlet Temperature F 255.331 Inlet Pressure psia 29.696 Inlet Volumetric Flowrate ft3/min 21.64204 Molar Flowrate lb/hr 77187.66 Mass Flowrate lb/hr 77187.66 Discharge Temperature F 259.6757 Discharge Volumetric Flowrat ft3/min 21.69536 Calculated Cp/Cv Ratio Page 5 Amine Column 1 (Absorber) Amine Absorber Overhead Product Rate Gues Ibmol/hr 0 Bottom Product Rate Guess Ibmol/hr 0 Top Tray Pressure psia 902.7 Number of Actual Trays 10 Foaming Factor 0.8 Convergence Tolerance 0.0008 Maximum Iterations 200 Column Profiles Tray 1 2 3 4 5 6 7 8 9 10 Vapor Temperature _iquid Temperatun Liquid Rate Liquid Rate Vapor Rate Vapor Rate Comments F F Ibmol/hr lb/hr Ibmol/hr lb/hr 133.46 120.86 2504.4 77281 4266 89999 137.31 126.1 2506.8 77336 4271 90107 140.77 131.15 2509.7 77408 4273 90164 143.75 136.25 2514 77521 4276 90240 146.07 141.91 2521.2 77727 4280 90365 147.36 149.06 2534.2 78124 4287 90594 146.85 159.17 2557.2 78887 4300 91047 143.07 172.88 2591.1 80204 4323 91936 133.99 184.15 2622.6 81859 4357 93425 118.85 178.88 2625.2 82855 4389 94687 Column Properties Liquid Vapor Liquid Vapor Surface Tray Enthalpy Enthalpy Molecular Weight Molecular Weight Tension Pressure Btu/Ibmol 8tu/lbmol dyne/cm pia 1 2 3 4 5 6 7 8 9 10 -17988 335.1 30.858 21.097 50.59 902.7 -17895 384.8 30.85 21.1 50.17 902.81 -17809 429.3 30.843 21.101 49.77 902.92 -17729 467.4 30.836 21.104 49.37 903.03 -17652 496.5 30.829 21.112 48.91 903.15 -17577 511.3 30.828 21.13 48.34 903.26 -17508 500.8 30.849 21.172 47.51 903.37 -17486 445.1 30.954 21.265 46.34 903.48 -17610 319 31.213 21.441 45.27 903.6 -17981 117.3 31.561 21.575 45.48 903.71 Column Properties (Continued) Liquid Vapor Liquid Vapor Liquid Vapor Tray Density Density Viscosity Viscosity Specific Gravity Specific Gravity Ib/ft3 Ib/ft3 cP cP t,p/60F air -1 2 3 4 5 6 7 8 9 10 Tray Internal Data 63.37 3.565 2.611 0.012137 1.0162 0.8495 63.22 3.528 2.402 0.012206 1.0137 0.8482 63.07 3.495 2.219 0.012268 1.0113 0.8475 62.93 3.469 2.053 0.012323 1.009 0.8483 62.78 3.45 1.886 0.01237 1.0067 0.8517 62.62 3.444 1.701 0.012406 1.0041 0.8602 62.43 3.461 1.48 0.012425 1.001 0.8785 62.24 3.519 1.244 0.012416 0.998 0.9129 62.27 3.643 1.1 0.012354 0.9984 0.962 62.78 3.841 1.207 0.012143 1.0067 1.0056 Feed Feed Tray Diameter % Flood Passes Weir Height Weir Length Spacing Actual Area % Open or Type ft in ft 2 or 1 2 3 4 5 6 7 8 9 10 4.5 65.7 1 3 3.831 2 10.115 VALVE 4.5 66.1 1 3 3.831 2 10.115 VALVE 4.5 66.4 1 3 3.831 2 10.115 VALVE 4.5 66.7 1 3 3.831 2 10.115 VALVE 4.5 67 1 3 3.831 2 10.115 VALVE 4.5 67.3 1 3 3.831 2 10.115 VALVE 4.5 67.8 1 3 3.831 2 10.115 VALVE 4.5 68.4 1 3 3.831 2 10.115 VALVE 4.5 68.9 1 3 3.831 2 10.115 VALVE 4.5 68.7 1 3 3.831 2 10.115 VALVE Page 6 % Open Reported For Sieve Trays Only Page 7 Distillate Vapor Product Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFID METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXA BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA Total Temperature Pressure Enthalpy Molecular Weight Bottom Product Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFID METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXA BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA Total Temperature Pressure Enthalpy Molecular Weight Ibmolfir mot percent Ibfir 13.866 0.32504 249.8 10.498 0.24609 294.08 0.27518 0.00645075 12.11 2.23931E-05 5.24937E-07 0.000763199 3341.6 78.335 53610 526.35 12.339 15826 206.98 4.852 9126.6 34.802 0.81583 2022.7 69.252 1.6234 4024.9 21.789 0.51078 1572 21.658 0.50771 1562.5 0 0 0 13.999 0.32815 1206.3 0 0 0 0.93133 0.0218322 93.317 0 0 0 0.77666 0.0182064 60.663 0.71082 0.0166631 65.491 0.0127828 0.000299654 1.357 0.17336 0.00406399 18.404 2.0561 0.0481998 234.86 0 0 0 0.0799437 0.00187403 8.4051 4265.9 100 89990 F 133.46 Asia 902.7 Btu hr 1429490 21.097 Ibmol/hr mai percent Ib/hr 2103.6 80.127 37896 0.00361031 0.000137521 0.10114 158.81 6.0491 6988.9 0.013208 0.00050311 0.45016 1.7162 0.0653725 27.533 0.23 0.00876109 6.9157 0.057949 0.00220735 2.5552 0.00189212 7.20731E-05 0.10997 0.0105494 0.00040184 0.61313 0.00159596 6.07921E-05 0.11514 0.00153356 5.84149E-05 0.11064 0 0 0 0.00362361 0.000138028 0.31225 0 0 0 0.000688265 2.62168E-05 0.0689628 0 0 0 0.1978 0.00753447 15.45 0.12493 0.00475868 11.51 0.000344194 1.31107E-05 0.0365396 0.00603827 0.000230005 0.64102 0.0704413 0.00268319 8.0461 0 0 0 360.47 13.731 37899 2625.3 100 82859 F 178.88 psia 903.71 Btufir -47204700 31.561 Page 8 Tray Number 1 Total Liquid Ibmolfir 2504.4 Total Vapor Ibmolhr 4265.9 Temperature (V,L) F 133.5 120.9 Pressure Asia 902.7 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8438 0.00325 0.4926 0.002776 0.003852 NITROGEN 0.000001498 0.002461 0.00000136 0.003268 1643 CARBON DIOXIDE 0.01116 0.00006451 0.01591 0.0001346 0.005782 HYDROGEN SULFIDE 9.994E-07 5.249E-09 0.000001104 8.481E-09 0.005252 METHANE 0.0007878 0.7833 0.0004096 0.5957 994.3 ETHANE 0.0001057 0.1234 0.000103 0.1759 1167 PROPANE 0.00002501 0.04852 0.00003574 0.1014 1940 ISOBUTANE 0.000001555 0.008158 0.000002929 0.02248 5245 N -BUTANE 0.000004782 0.01623 0.000009007 0.04473 3395 I -PENTANE 6.043E-07 0.005108 0.000001413 0.01747 8453 N -PENTANE 5.732E-07 0.005077 0.00000134 0.01736 8858 CYCLOPENTANE 0 0 0 0 0 N -HEXANE 7.079E-07 0.003282 0.000001977 0.0134 4636 CYCLOHEXANE 0 0 0 0 0 N•HEPTANE 6.233E -D8 0.0002183 2.024E-07 0.001037 3503 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00008079 0.0001821 0.0002045 0.0006741 2.254 TOLUENE 0.00005017 0.0001666 0.0001498 0.0007278 3.321 ETHYL BENZENE 1.709E-07 0.000002997 5.881E-07 0.00001508 17,53 O•XYLENE 0.000003081 0.00004064 0.0000106 0.0002045 13.19 N -OCTANE 0.000001808 0.000482 0.000006691 0.00261 266.6 DEA 1E-14 0 3.407E-14 0 0 DGA 0.144 0.00001874 0.4905 0.0000934 0.0001302 Total 1 1 1 1 Tray Number 2 Total Liquid Ibmol/hr 2506.8 Total Vapor Ibmotlhr 4270.5 Temperature (V,L) F 137.3 126.1 Pressure psia 902.8 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8439 0.003686 0.4927 0.003145 0.004368 NITROGEN 0.000001472 0.002459 0.000001337 0.003263 1670 CARBON DIOXIDE 0.01124 0.00009504 0.01603 0.0001981 0.008459 HYDROGEN SULFIDE 9.988E-07 6.961E-09 0.000001103 1.124E-08 0.006969 METHANE 0.0007678 0.7829 0.0003992 0.5949 1020 ETHANE 0.0001027 0.1233 0.0001001 0.1756 1201 PROPANE 0.00002437 0.04848 0.00003483 0.1012 1989 ISOBUTANE 0.000001458 0.00815 0.000002747 0.02243 5590 N -BUTANE 0.00000464 0.01622 0.00000874 0.04464 3496 I -PENTANE 5.931E-07 0.005103 0.000001387 0.01743 8604 N -PENTANE 5.634E-07 0.005072 0.000001317 0.01733 9002 CYCLOPENTANE 0 0 0 0 0 N -HEXANE 7.604E-07 0.003278 0.000002124 0.01338 4311 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 7.227E-08 0.0002181 2.347E-07 0.001035 3018 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00009888 0.0002293 0.0002503 0.0008481 2.318 TOLUENE 0.00005736 0.0001959 0.0001713 0.0008547 3.415 ETHYL BENZENE 1.714E-07 0.000003094 5.897E-07 0.00001555 18.05 O-XYLENE 0.000003112 0.0000424 0.00001071 0.0002132 13.63 N -OCTANE 0.00000237 0.0004825 0.000008773 0.00261 203.6 DEA 0 7.016E-23 0 3.494E-22 0 DGA 0.1438 0.00002267 0.4901 0.0001129 0.0001576 Total 1 1 0.9999 0.9992 Tray Number 3 Total Liquid Ibmol/hr 2509.7 Total Vapor IbmoUhr 4273 Temperature (V,L) F 140.8 Pressure Asia 902.9 131.2 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8438 0.004195 0.4928 0.003579 0.004971 NITROGEN 0.000001452 0.002458 0.000001318 0.00326 1693 CARBON DIOXIDE 0.01148 0.0001471 0.01637 0.0003065 0.01281 HYDROGEN SULFIDE 0.000001002 7.151E-09 0.000001107 1.154E-08 0.007135 METHANE 0.0007506 0.7825 0.0003904 0.5944 1042 ETHANE 0.0001001 0.1232 0.00009757 0.1755 1231 PROPANE 0.00002386 0.04845 0.0000341 0.1012 2031 ISOBUTANE 0.00000137 0.008146 0.00000258 0.02242 5948 N -BUTANE 0.000004523 0.01621 0.000008522 0.04461 3584 I -PENTANE 5.852E-07 0.0051 0.000001369 0.01742 8714 N -PENTANE 5.567E-07 0.005069 0.000001302 0.01732 9106 CYCLOPENTANE 0 0 0 0 0 N•HEXANE 8.135E-07 0.003277 0.000002273 0.01337 4027 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 8.311E-08 0.000218 0.00000027 0.001034 2623 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.0001007 0.0002398 0.0002549 0.0008869 2.382 TOLUENE 0.00005711 0.0002 0.0001706 0.0008726 3.503 ETHYL BENZENE 1.667E-07 0.000003092 5.737E-07 0.00001554 18.55 O-XYLENE 0.000003018 0.0000424 0.00001039 0.0002131 14.05 N -OCTANE 0.000003058 0.0004826 0.00001132 0.00261 157.8 DEA 0 1E-14 0 4.979E-14 0 DGA 0.1437 0.00002602 0.4897 0.0001295 0.0001811 Total 1 1 0.9999 0.9991 Tray Number 4 Total Liquid IbmoUhr 2514 Total Vapor Ibmo&hr 4275.9 Temperature (V,L) F 143.7 136.3 Pressure Asia 903 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8435 0.004735 0.4928 0.004039 0.005613 NITROGEN 0.000001434 0.002456 0.000001303 0.003258 1713 CARBON DIOXIDE 0.01199 0.0002967 0.01711 0.0006183 0.02475 HYDROGEN SULFIDE 0.000001012 9.774E-09 0.000001119 1.577E-08 0.009657 METHANE 0.0007351 0.7819 0.0003824 0.594 1064 ETHANE 0.00009784 0.1232 0.00009539 0.1753 1259 PROPANE 0.00002342 0.04842 0.00003349 0.1011 2067 ISOBUTANE 0.000001284 0.00814 0.000002421 0.0224 6337 N -BUTANE 0.000004422 0.0162 0.000008333 0.04458 3664 I -PENTANE 5.798E-07 0.005096 0.000001356 0.01741 8790 N -PENTANE 5.522E-07 0.005065 0.000001292 0.0173 9174 CYCLOPENTANE 0 0 0 0 0 N -HEXANE 8.691E-07 0.003274 0.000002428 0.01336 3767 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 9.538E-08 0.0002179 3.099E-07 0.001034 2284 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00009832 0.0002407 0.000249 0.0008903 2.449 TOLUENE 0.00005564 0.0001998 0.0001662 0.0008714 3.59 ETHYL BENZENE 0.000000162 0.000003087 5.576E-07 0.00001552 19.06 O-XYLENE 0.000002922 0.00004232 0.00001006 0.0002127 14.48 N -OCTANE 0.000003934 0.0004826 0.00001457 0.00261 122.7 DEA 0 1.656E-22 0 8.246E-22 0 DGA 0.1434 0.00003076 0.489 0.0001531 0.0002144 Total 1 1 0.9999 0.9991 Page 10 Tray Number 5 Total Liquid IbmoUhr 2521.2 Total Vapor IbmoUhr 4280.2 Temperature (V,L) F 146.1 141.9 Pressure Asia 903.1 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8429 0.005423 0.4925 0.004625 0.006434 NITROGEN 0.000001418 0.002454 0.000001288 0.003253 1730 CARBON DIOXIDE 0.01308 0.0006093 0.01867 0.001269 0.04657 HYDROGEN SULFIDE 0.000001047 1.666E-08 0.000001157 2.688E-08 0.01591 METHANE 0.00072 0.7812 0.0003746 0.5932 1085 ETHANE 0.00009567 0.123 0.0000933 0.1751 1286 PROPANE 0.00002303 0.04837 0.00003293 0.101 2101 ISOBUTANE 0.000001195 0.008132 0.000002253 0.02237 6804 N -BUTANE 0.000004326 0.01618 0.000008155 0.04452 3740 I -PENTANE 5.763E-07 0.005091 0.000001348 0.01739 8834 N -PENTANE 5.496E-07 0.00506 0.000001286 0.01728 9207 CYCLOPENTANE 0 0 0 0 0 N•HEXANE 9.327E-07 0.003271 0.000002607 0.01334 3507 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 1.106E-07 0.0002176 3.595E-07 0.001032 1967 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00009468 0.0002392 0.0002398 0.0008845 2.527 TOLUENE 0.00005389 0.0001988 0.000161 0.0008668 3.688 ETHYL BENZENE 0.000000157 0.000003082 5.406E-07 0.00001549 19.63 O•XYLENE 0.000002822 0.00004222 0.000009715 0.0002122 14.96 N -OCTANE 0.000005167 0.0004827 0.00001914 0.00261 93.41 DEA 0 1.638E-21 0 8.153E-21 0 DGA 0.1431 0.00003652 0.4878 0.0001818 0.0002553 Total 1 1 0.9999 0.9991 Tray Number 6 Total Liquid IbmoUhr 2534.2 Total Vapor IbmoUhr 4287.4 Temperature (V,L) F 147.4 149.1 Pressure Asia 903.3 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8413 0.006428 0.4915 0.005479 0.007642 NITROGEN 0.000001403 0.002449 0.000001275 0.003246 1746 CARBON DIOXIDE 0.01543 0.001271 0.02202 0.002647 0.08239 HYDROGEN SULFIDE 0.000001174 3.888E-08 0.000001297 6.269E-08 0.03312 METHANE 0.0007035 0.7798 0.0003661 0.5919 1109 ETHANE 0.0000934 0.1228 0.00009109 0.1747 1315 PROPANE 0.00002265 0.04829 0.00003239 0.1007 2132 ISOBUTANE 0.000001089 0.008118 0.000002053 0.02232 7452 N -BUTANE 0.000004229 0.01616 0.000007973 0.04442 3820 I -PENTANE 5.755E-07 0.005083 0.000001347 0.01735 8831 N -PENTANE 5.498E-07 0.005052 0.000001287 0.01724 9189 CYCLOPENTANE 0 0 0 0 0 N -HEXANE 0.000001016 0.003266 0.00000284 0.01331 3214 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 1.327E-07 0.0002173 4.311E-07 0,00103 1638 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00008999 0.0002368 0.000228 0.0008751 2.632 TOLUENE 0.00005181 0.0001975 0.0001548 0.0008608 3.812 ETHYL BENZENE 0.000000151 0.000003074 0.00000052 0.00001544 20.35 O-XYLENE 0.000002701 0.0000421 0.000009301 0.0002114 15.58 N -OCTANE 0.000007227 0.0004826 0.00002677 0.002608 66.78 DEA 0 7.833E-22 0 3.896E-21 0 DGA 0.1423 0.00004428 0.4854 0.0002203 0.0003111 Total 1 1 0.9999 0.9991 Page 11 Tray Number 7 Total Liquid Ibmolhir 2557.2 Total Vapor IbmoVhr 4300.4 Temperature (V,L) F 146.8 159.2 Pressure Asia 903.4 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8375 0.008012 0.489 0.006819 0.009567 NITROGEN 0.00000139 0.002442 0.000001262 0.003232 1756 CARBON DIOXIDE 0.02046 0.00269 0.02919 0.005593 0.1314 HYDROGEN SULFIDE 0.000001612 1.167E-07 0.000001781 1.879E-07 0.07238 METHANE 0.0006848 0.7775 0.0003561 0.5893 1135 ETHANE 0.00009101 0.1225 0.00008869 0.1739 1346 PROPANE 0.00002233 0.04814 0.00003191 0.1003 2157 ISOBUTANE 9.532E-07 0.008093 0.000001796 0.02222 8491 N -BUTANE 0.000004133 0.01611 0.000007786 0.04422 3897 I -PENTANE 5.813E-07 0.005067 0.000001359 0.01727 8717 N -PENTANE 5.565E-07 0.005037 0.000001301 0.01717 9050 CYCLOPENTANE 0 0 0 0 0 N•HEXANE 0.000001139 0.003256 0.000003182 0.01325 2858 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 1.696E-07 0.0002166 5.509E-07 0.001026 1277 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00008388 0.0002336 0.0002123 0.0008622 2.785 TOLUENE 0.00004929 0.0001958 0.0001472 0.0008524 3.973 ETHYL BENZENE 1.433E-07 0.000003062 4.931E-07 0.00001535 21.36 O•XYLENE 0.000002547 0.00004191 0.000008763 0.0002102 16.45 N -OCTANE 0.00001142 0.0004824 0.00004227 0.002603 42.25 DEA 0 1E-14 0 4.967E-14 0 DGA 0.1411 0.00005536 0.4808 0.000275 0.0003924 Total 1 1 0.9999 0.9991 Tray Number 8 Total Liquid IbmoI1hr 2591.1 Total Vapor IbmoLlhr 4323.4 Temperature (V,L) F 143.1 172.9 Pressure psis 903.5 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8291 0.01023 0.4825 0.008684 0.01234 NITROGEN 0.000001388 0.002429 0.000001256 0.003205 1750 CARBON DIOXIDE 0.03072 0.005738 0.04367 0.0119 0.1868 HYDROGEN SULFIDE 0.000002822 3.818E-07 0.000003107 0.000000613 0.1353 METHANE 0.000667 0.7733 0.0003457 0.5844 1159 ETHANE 0.00008909 0.1218 0.00008653 0.1725 1367 PROPANE 0.00002225 0.04789 0.00003169 0.09946 2152 ISOBUTANE 7.921E-07 0.00805 0.000001487 0,02204 10160 N -BUTANE 0.000004072 0.01602 0.000007644 0.04386 3934 I -PENTANE 6.018E-07 0.00504 0.000001402 0.01713 8375 N -PENTANE 5.776E-07 0.00501 0.000001346 0.01702 8673 CYCLOPENTANE 0 0 0 0 0 N -HEXANE 0.000001316 0.003239 0.000003664 0.01314 2460 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 2.326E-07 0.0002155 7.527E-07 0.001017 926.7 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00007687 0.0002293 0.0001939 0.0008435 2.982 TOLUENE 0.00004685 0.0001936 0.0001394 0.00084 4.132 ETHYL BENZENE 1.344E-07 0.000003041 4.608E-07 0.00001521 22.64 O-XYLENE 0.000002368 0.00004161 0.00000812 0.000208 17.57 N -OCTANE 0.00002065 0.0004823 0.0000762 0.002595 23.35 DEA 0 1.562E-21 0 7.735E-21 0 DGA 0.1392 0.00006673 0.4728 0.0003305 0.0004793 Total 1 1 0.9999 0.9991 Page 12 Tray Number 9 Total Liquid Ibmol/hr 2622.6 Total Vapor IbmoUhr 4357.3 Temperature (V,L) F 134 Pressure Asia 903.6 184.1 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8151 0.01168 0.4704 0.009847 0.01433 NITROGEN 0.000001394 0.00241 0.000001251 0.00316 1728 CARBON DIOXIDE 0.04645 0.01196 0.06548 0.02463 0.2575 HYDROGEN SULFIDE 0.000004619 0.000001112 0.000005043 0.000001774 0.2408 METHANE 0.0006565 0.7673 0.0003374 0.5761 1169 ETHANE 0.00008831 0.1209 0.00008506 0.1701 1368 PROPANE 0.00002243 0.04752 0.00003168 0.09805 2118 ISOBUTANE 6.768E-07 0.007988 0.00000126 0.02173 11800 N -BUTANE 0.000004065 0.0159 0.000007569 0.04324 3910 I -PENTANE 6.283E-07 0.005001 0.000001452 0.01689 7960 N -PENTANE 6.043E-07 0.004971 0.000001396 0.01678 8226 CYCLOPENTANE 0 0 0 0 0 N•HEXANE 0.000001466 0.003213 0.000004047 0.01296 2192 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 2.963E-07 0.0002139 0.000000951 0.001003 721.8 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00007231 0.000224 0.0001809 0.0008186 3.097 TOLUENE 0.00004594 0.000191 0.0001356 0.0008235 4.158 ETHYL BENZENE 1.283E-07 0.000003014 4.363E-07 0.00001497 23.49 O•XYLENE 0.000002245 0.0000412 0.000007636 0.0002047 18.35 N -OCTANE 0.00003297 0.0004841 0.0001206 0.002588 14.68 DEA 0 1E-14 0 4.92E-14 0 DGA 0.1375 0.0000578 0.4631 0.0002844 0.0004203 Total 1 1 0.9999 0.9992 Tray Number 10 Total Liquid IbmoUhr 2625.2 Total Vapor IbmoUhr 4388.8 Temperature (V,L) F 118.8 178.9 Pressure psis 903.7 Component Liquid Vapor Liquid Vapor K -Value mote frac. mole frac. mass frac. mass frac. WATER 0.8013 0.009171 0.4573 0.007652 0.01145 NITROGEN 0.000001375 0.002393 0.00000122 0.003104 1740 CARBON DIOXIDE 0.06049 0.0215 0.08434 0.04382 0.3554 HYDROGEN SULFIDE 0.000005031 0.0000022 0.000005432 0.000003473 0.4373 METHANE 0.0006537 0.7618 0.0003323 0.566 1165 ETHANE 0.00008761 0.12 0.00008345 0.1671 1369 PROPANE 0.00002207 0.04717 0.00003083 0.09634 2137 ISOBUTANE 7.207E-07 0.00793 0.000001327 0.02135 11000 N -BUTANE 0.000004018 0.01578 0.000007399 0.04248 3927 I -PENTANE 6.079E-07 0.004965 0.000001389 0.01659 8167 N -PENTANE 5.841E-07 0.004935 0.000001335 0.01649 8449 CYCLOPENTANE 0 0 0 0 0 N -HEXANE 0.00000138 0.00319 0.000003768 0.01273 2311 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 2.622E-07 0.0002124 8.322E-07 0.0009856 810.1 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.00007534 0.0002202 0.0001864 0.0007964 2.922 TOLUENE 0.00004759 0.0001894 0.0001389 0.0008082 3.98 ETHYL BENZENE 1.311E-07 0.000002989 4.409E-07 0.0000147 22.8 O-XYLENE 0.0000023 0.00004084 0.000007735 0.0002008 17.76 N -OCTANE 0.00002683 0.0004882 0.00009709 0.002583 18.19 DEA 0 1E-14 0 4.869E-14 0 DGA 0.1373 0.00002639 0.4573 0.0001285 0.0001922 Total 1 1 0.9999 0.9992 Sweetening Summary Sweet Gas H2S Residue grains/100scf 0.00033002 Acid Gas Pickup les acid gas/mole an 0.36335 Rich Amine Loading es acid gas/mole am 0.44049 Water Loss gal/min 0.49933 Amine Loss gal/min 0.015741 Page 13 Amine Still Amine Regenerator Reboiler Duty Spec Btu/hr 12000000 Overhead Product Rate Guess Ibmollhr 0 Bottom Product Rate Guess Ibmol/hr 0 Top Tray Pressure Asia 26.2 Condenser Pressure psia 26.2 Number of Actual Trays 10 Foaming Factor 0.85 Convergence Tolerance 0.001 Maximum Iterations 200 Column Profiles Tray Vapor Temperature -iquid Temperature Liquid Rate Liquid Rate Vapor Rate Vapor Rate Comments F F Ibmot/hr lb/hr Ibmol/hr lb/hr CONDENSR 150 150 322.7 5817.8 153.8 6192.6 1 237.62 223.93 345.6 6329 479.4 11882 2 242.99 234.63 2992.7 88490 483.2 10877 3 245.83 240.2 3033.1 88749 526.4 11585 4 247.65 243.34 3060.2 88895 566.8 11954 5 248.99 245.28 3079.2 88984 593.9 12187 6 250.07 246.59 3093.2 89044 612.9 12297 7 251.09 247.58 3104.2 89087 626.9 12382 8 252.12 248.32 3113.4 89121 638 12439 9 253.21 248.97 3121.6 89150 647.2 12481 10 254.41 249.59 3128.9 89319 655.4 12580 REBOILER 256.34 256.34 2469.2 76818 662.7 12750 Column Properties Tray Liquid Vapor Liquid Vapor Surface Enthalpy Enthalpy Molecular Weight Molecular Weight Tension Pressure Btullbmol Btu/lbrnol dyne/cm psia CONDENSR -17240 1015 18.031 40.27 84.95 26.196 1 -15930 1689 18.313 24.788 56.78 26.196 2 -16516 1739 29.569 23.483 42.24 28.292 3 -16271 1747 29.26 22.009 41.96 26.39 4 -16111 1753 29.049 21.091 41.83 26.487 5 -15999 1759 28.899 20.487 41.76 26.585 6 -15917 1765 28.787 20.065 41.71 26.684 7 -15853 1771 28.699 19.75 41.68 26,782 8 -15799 1779 28.625 19.498 41.66 26.88 9 -15751 1787 28.559 19.284 41.85 26.979 10 -15704 1796 28.547 19.194 41.6 27.078 REBOILER -15548 1823 31.029 19.239 39.39 29.698 Column Properties (Continued) Tray Liquid Vapor Liquid Vapor Liquid Vapor Density Density Viscosity Viscosity Specific Gravity Specific Gravity Ib/ft3 lb/f13 cP cP t,p160F air -1 Condenser 61.19 0.1626 0.4304 0.016647 0.9811 1.4023 1 59.02 0.087747 0.2687 0.016462 0.9463 0.8485 2 60.31 0.082834 0.567 0.01608 0.967 0.8106 3 59.96 0.077661 0 527 0.015448 0.9614 0.7632 4 59.74 0.074537 0.505 0.014979 0.9578 0.7331 5 59.59 0.072557 0.4915 0.014636 0.9555 0.7129 6 59.48 0.071232 0.4824 0.014382 0.9538 0.6987 7 59.4 0.070283 0.4757 0.014187 0.9525 0.8877 8 59.33 0.069552 0.4703 0.014028 0.9514 0.6788 9 59.27 0.068943 0.4658 0.013893 0.9504 0.671 10 59.22 0.068761 0.4625 0.013848 0.9498 0.6674 Reboller 59.12 0.075494 0.4779 0.013845 0.9479 0.6745 Feed Page 14 Tray Internal Data Tray Diameter % Flood Passes Weir Height Weir Length Spacing Actual Area % Open or Type It in ft 2 or 1 2 3 4 5 6 7 8 9 10 4.5 39.4 1 2 3.821 2 10.179 VALVE 4.5 51.2 1 2 3.821 2 10.179 VALVE 4.5 55.6 1 2 3.821 2 10.179 VALVE 4.5 58.3 1 2 3.821 2 10.179 VALVE 4.5 60 1 2 3.821 2 10.179 VALVE 4.5 61.2 1 2 3.821 2 10.179 VALVE 4.5 62 1 2 3.821 2 10.179 VALVE 4.5 82.6 1 2 3.821 2 10.179 VALVE 4.5 83.1 1 2 3.821 2 10.179 VALVE 4.5 63.7 1 2 3.821 2 10.179 VALVE % Open Reported For Sieve Trays Only Distillate Vapor Product Component Ibmolihr mol percent Iblhr WATER 22.668 14.741 408.38 NITROGEN 0.000140523 0.000091381 0.00393653 CARBON DIOXIDE 130.58 84.913 5748.5 HYDROGEN SULFID 0.0131042 0.00852157 0.44662 METHANE 0.11 0.0715314 1.7647 ETHANE 0.0153632 0.00999056 0.46194 PROPANE 0.00296939 0.00193097 0.13093 ISOBUTANE 2.40364E-05 1.56307E-05 0.001397 N -BUTANE 0.00035622 0.000231647 0.0207035 I -PENTANE 2.96355E-05 1.92717E-05 0.00213808 N -PENTANE 2.84088E-05 0.000018474 0.00204958 CYCLOPENTANE 0 0 0 N -HEXANE 0.000266076 0.000173027 0.0229283 CYCLOHEXANE 0 0 0 N-HEPTANE 0.000138447 9.00307E-05 0.0138721 METHYLCYCLOHEXA 0 0 0 BENZENE 0.19518 0.12692 15.245 TOLUENE 0.12331 0.0801864 11.361 ETHYL BENZENE 0.000321388 0.000208996 0.0341186 O-XYLENE 0.00573092 0.00372677 0.60839 N -OCTANE 0.0650602 0.0423081 7.4314 DEA 0 0 0 DGA 1.71005E-05 1.11203E-05 0.00179791 Total 153.78 100 6192.5 Temperature F 15D Pressure psia 28.196 Enthalpy Btu/hr 156117 Molecular Weight 40.269 Page 15 Bottom Product Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFID METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXA BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA Total Temperature Pressure Enthalpy Molecular Weight Ibmolmr mol percent Ib/hr 2080.7 84.265 37484 O 0 D 28.062 1.1365 1235 6.70517E-05 2 7155E-06 0.00228525 0 0 0 O 0 0 O 0 0 O 0 D O 0 0 0 0 0 O 0 0 O 0 0 0 0 0 O 0 0 O 0 0 O 0 0 O 0 0 O 0 0 O 0 0 O 0 0 O 0 D 0 0 0 360.47 14.599 37899 2489.2 100 76619 F 256.34 psia 29.696 Btu/hr -38391900 31.03 Column Parameters Reflux Ratio Condenser Duty Renoiler Duty Partial Condenser Vapor Product Reflux Liquid Temperature (V.L) Pressure Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFIDE METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXAN BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA Total 2.0983 Btu/hr -6213530 Btu/hr 12000000 Ibmol/hr 153.78 Ibmol/hr 322.66 F 150 150 psia 26.2 Liquid Vapor Liquid Vapor K -Value mote frac. mole frac. mass frac. mass frac. 0.9995 0.1474 0.9987 0.06595 0.1475 1.394E-11 9.138E-07 2.186E-11 8.357E-07 0 0.0004019 0.8491 0.000981 0.928 2113 1.331E-07 0.00008522 2.516E-07 0.00007212 640.3 5.284E-07 0.0007153 4.702E-07 0.000285 1354 2.947E-09 0.00009991 4.915E-09 0.0000746 33900 4.294E-10 0.00001931 1.05E-09 0.00002114 44970 1.153E-12 1.563E-07 3.716E-12 2.256E-07 0 3.503E-11 0.000002316 1.129E-10 0.000003343 0 1.485E-12 1.927E-07 5.941E-12 3.453E-07 0 1.421E-12 1.847E-07 5.887E-12 0.000000331 0 O 0 0 0 0 4.684E-11 0.00000173 2.239E-10 0.000003703 0 O 0 0 0 0 5.883E-11 9.003E-07 3.269E-10 0.00000224 0 O 0 0 0 0 0.000003295 0.001269 0.00001427 0.002482 385.2 0.000002237 0.0008019 0.00001143 0.001835 358.5 2.019E-09 0.00000209 1.189E-08 0.00000551 1035 4.85E-08 0,00003727 2.856E-07 0.00009825 768.4 8.426E-07 0.0004231 0.000005338 0.0012 502.1 O 0 0 0 0 0.00005461 1.112E-07 0.0003184 2.903E-07 0.002036 1 1 1 1 Page 16 Tray Number 1 Total Liquid Total Vapor Temperature (V,L) Pressure Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFIDE METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXAN BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA Ibmollhr 345.8 IbmoUhr 479.37 F 237.6 223.9 psia 26.2 Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. 0.9955 0.72 0.9792 0.5156 0.7233 O 2.928E-07 0 3.261E-07 0 0.001593 02729 0.003829 0.4773 171.3 4.155E-07 0.00002743 7.733E-07 0.00003715 68 1.649E-07 0.00618 1.445E-07 0.003941 37480 9.057E-10 0.00003205 1.487E-09 0.00003831 35390 1.393E-10 0.000006195 3.355E-10 0.00001088 44460 O 5.013E-08 0 1.158E-07 0 O 7.431E-07 D 0.000001717 0 O 8.179E-08 0 1.772E-07 0 O 5.923E-06 0 1.899E-07 0 O 0 0 0 D O 5.551E-07 0 0.000001901 0 O 0 0 0 0 O 2.889E-07 D 0.00000115 0 0 0 0 0 0 7.264E-07 0.0004094 0.000003098 0.001271 563.8 5.592E-07 0.0002587 0.000002813 0.0009475 462.7 0 8.718E-07 0 0.000002835 0 8.413E-09 0.00001199 4.877E-08 0.00005058 1425 0.00000335 0.0001363 0.00002089 0.0006188 40.69 1E-14 4.544E-23 5.741E-14 1.899E-22 4.544E-09 0.002944 0.00003679 0.0169 0.0001538 0.0125 Total 1 1 1 1 Tray Number 2 Total Liquid Total Vapor Temperature (V,L) Pressure Component IbmoUhr 2992.7 Ibmolfhr 483.18 F 243 234.6 psia 26.29 Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.84 0.7472 0.5118 0.5475 0.8895 NITROGEN 0 0 0 0 0 CARBON DIOXIDE 0.03897 0.244 0.05799 0.4368 6.262 HYDROGEN SULFIDE 0.000001823 0.0000235 0.000002102 0.00003258 12.89 METHANE 0.000000168 0.006159 9.116E-08 0.004019 36860 ETHANE 0 6.015E-06 0 7.356E-08 0 PROPANE 0 9.192E-09 0 1.849E-08 0 ISOBUTANE 0 0 0 0 0 N -BUTANE 0 6.617E-10 0 1.564E-09 0 I -PENTANE 0 0 0 0 0 N -PENTANE 0 0 0 0 0 CYCLOPENTANE 0 0 0 0 0 N -HEXANE 0 1.458E-09 0 5.109E-09 0 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 0 3.81E-09 0 1.553E-08 0 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0.000003154 O0O02438 0.000008331 0.0007748 77.3 TOLUENE 0.00000249 0.0001622 0.000007759 0.000608 85.14 ETHYL BENZENE 0 1.401E-07 0 8.051E-07 0 O-XYLENE 1.201E-08 0.000003048 4.31E-08 0.00001316 253.8 N -OCTANE 0.000002803 0.00008271 0.00001083 0.0003843 29.5 DEA 3.709E-21 1.529E-22 1.319E-20 8.537E-22 0.04121 DGA 0.121 0.002107 0.4302 0.009009 0.01741 Total 1 1 1 0.9992 Page 17 Tray Number 3 Total Liquid Total Vapor Temperature (V.L) Pressure Component Ibmollhr 3033.1 IbmoUhr 526.37 F 245.8 240.2 psia 26.3.9 Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8485 0.8231 0.5224 0.6543 0.97 NITROGEN 0 0 0 0 0 CARBON DIOXIDE 0.03194 0.1684 0.04804 0.3271 5.273 HYDROGEN SULFIDE 9.509E-07 0.00001024 0.000001108 0.0000154 10.77 METHANE 1.502E-07 0.00542 8.236E-08 0.003837 36090 ETHANE 0 0 0 0 D PROPANE 0 0 0 0 0 ISOBUTANE 0 0 0 0 0 N -BUTANE 0 0 0 0 0 I -PENTANE 0 0 0 0 0 N -PENTANE 0 0 0 0 0 CYCLOPENTANE 0 0 0 0 D N -HEXANE 0 0 0 0 0 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 0 0 D 0 0 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 2.154E-07 0.00001793 5.751E-07 0.00006181 83.23 TOLUENE 2.062E-07 0.00001416 6.493E-07 0.00005758 68.66 ETHYL BENZENE 0 0 0 0 0 O-XYLENE 0 6.826E-08 0 3.198E-07 0 N -OCTANE 6.367E-07 0.00001594 0.000002485 0.00008033 25.03 DEA 3.251E-21 1E-14 1.168E-20 4.64E-14 3076000 DGA 0.1195 0.003019 0.4295 0.01401 0.02525 Total 1 1 1 0.9995 Tray Number 4 Total Liquid Total Vapor Temperature (V.L) Pressure Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFIDE METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXAN BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA Total IbmoUhr 3080.2 Ibmolihr 566.78 F 247.7 243.3 psia 26.49 Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. 0.8545 0.8698 0.5299 0.7289 1.018 O 0 0 0 0 0.02688 0.1216 0.04072 0.249 4.524 5.365E-07 0.000004971 6.294E-07 0.000007882 9.266 1.411E-07 0.005034 7.79E-08 0.003757 35680 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 0 0 0 0 0 O 0 0 0 0 1.327E-08 0.000001153 3.567E-08 0.00000419 86.91 1.558E-08 0.000001104 4.942E-08 0.00000473 70.82 O 0 0 0 0 O 0 0 0 0 1.493E-07 0.000003407 5.871E-07 0.0000181 22-82 1E-14 1E-14 3.619E-14 4.892E-14 1 0.1186 0.003742 0.4293 0.0183 0.03154 1 1 1 1 Page 18 Tray Number 5 Total Liquid Total Vapor Temperature (V.L) Pressure Component Ibmollhr 3079.2 IbmoUhr 593.89 F 249 psia 26.59 245.3 Liquid Vapor Liquid Vapor mole frac. mole frac. mass frac. mass frac. K -Value WATER 0.8588 0.8995 0.5354 0.7807 1.047 NITROGEN 0 0 0 0 0 CARBON DIOXIDE 0.02318 0.09142 0.0353 0.1938 3.944 HYDROGEN SULFIDE 3.243E-07 0.000002852 3.825E-07 0.000004355 8.177 METHANE 1.358E-07 0.004804 7.537E-08 0.003713 35380 ETHANE 0 0 0 0 D PROPANE 0 0 0 0 0 ISOBUTANE 0 0 0 0 0 N -BUTANE 0 0 0 0 0 I -PENTANE 0 0 0 0 0 N -PENTANE 0 0 0 0 0 CYCLOPENTANE 0 0 0 0 D N -HEXANE 0 0 0 0 0 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 0 0 D 0 0 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0 6.835E-08 0 2.572E-07 0 TOLUENE 0 8.03E-08 0 3.564E-07 0 ETHYL BENZENE 0 0 0 0 0 O-XYLENE 0 0 0 0 0 N -OCTANE 0 7.694E-07 0 0.000004234 0 DEA 1E-14 8.357E-22 3.638E-14 4.233E-21 8.357E-08 DGA 0.118 0.004295 0.4293 0.02176 0.0384 Total Tray Number 6 Total Liquid Total Vapor Temperature (V.L) Pressure Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFIDE METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXAN BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA 1 1 IbmoUhr 3093.2 Ibmolihr 612.88 F 250.1 psia 26.88 1 1 246.6 Liquid Vapor Liquid Vapor mole frac. mole frac. mass frac. mass frac. K -Value 0.8621 0.9198 0.5395 0.818 1.067 O 0 0 0 0 0.02036 0.0708 0.03112 0.1538 3.478 2.073E-07 0.000001521 2.454E-07 0.000002559 7.339 1.325E-07 0.004655 7.384E-08 0.003886 35130 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 0 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 4.48E-21 1E-14 1.836E-20 5.19E-14 2232000 0.1176 0.004726 0.4294 0.02453 0.0402 Total 1 1 1 1 Tray Number 7 Total Liquid Total Vapor Temperature (V.L) Pressure Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFIDE METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N•PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXAN BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA Total Tray Number 8 Total Liquid Total Vapor Temperature (V.L) Pressure Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFIDE METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXAN BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA Total Ibmollhr 3104.2 IbmoUhr 626.93 F 251.1 247.6 psia 26.78 Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. 0.8647 0.9346 0.5428 0.8461 1.081 O 0 0 0 0 0.01809 0.05579 0.02774 0.1234 3.083 0.000000138 9.164E-07 1.639E-07 0.00000157 6.641 1.303E-07 0.004551 7.286E-08 0.003689 34920 O 0 0 0 D 0 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 D O 0 0 0 0 O 0 0 0 0 O 0 D 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 0 0 0 0 0 O 0 0 0 0 O 0 0 0 0 1.738E-21 1E-14 6.386E-21 5.284E-14 5755000 0.1172 0.005077 0.4295 0.02882 0.0433 1 1 1 1 IbmoUhr 3113.4 Ibmollhr 637.97 F 252.1 248.3 psia 26.88 Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. 0.8669 0.946 0.5456 0.8686 1.091 O 0 0 0 0 0.01616 0.04411 0.02484 0.09893 2.73 9.431E-08 5.669E-07 1.123E-07 9.847E-07 6.011 1.288E-07 0.004472 7.219E-08 0.003856 34720 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 0 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 1.734E-21 5.154E-22 6.369E-21 2.762E-21 0.2972 0.117 0.005376 0.4296 0.02881 0.04597 1 1 Page 20 Tray Number 9 Total Liquid Total Vapor Temperature (V.L) Pressure Component Ibmollhr 3121.6 Ibmol/hr 647.22 F 253.2 psia 26.98 249 Liquid Vapor Liquid Vapor mole frac. mole frac. mass frac. mass free. K -Value WATER 0.8689 0.9556 0.5481 0.8877 1.1 NITROGEN 0 0 0 0 0 CARBON DIOXIDE 0.01439 0.03439 0.02218 0.07804 2.389 HYDROGEN SULFIDE 6.505E-08 3.504E-07 7.784E-08 8.159E-07 5.387 METHANE 1.277E-07 0.004408 7.171E-08 0.003647 34530 ETHANE 0 0 0 0 D PROPANE 0 0 0 0 0 ISOBUTANE 0 0 0 0 0 N -BUTANE 0 0 0 0 0 I -PENTANE 0 0 0 0 0 N•PENTANE 0 0 0 0 0 CYCLOPENTANE 0 0 0 0 D N -HEXANE 0 0 0 0 0 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 0 0 D 0 0 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0 0 0 0 0 TOLUENE 0 0 0 0 D ETHYL BENZENE 0 0 0 0 0 O-XYLENE 0 0 0 0 0 N -OCTANE 0 0 0 0 0 DEA 1E-14 1E-14 3.681E-14 5.422E-14 1 DGA 0.1167 0.00585 0.4297 0.03063 0.0484 Total Tray Number 10 Total Liquid Total Vapor Temperature (V.L) Pressure Component WATER NITROGEN CARBON DIOXIDE HYDROGEN SULFIDE METHANE ETHANE PROPANE ISOBUTANE N -BUTANE I -PENTANE N -PENTANE CYCLOPENTANE N -HEXANE CYCLOHEXANE N-HEPTANE METHYLCYCLOHEXAN BENZENE TOLUENE ETHYL BENZENE O-XYLENE N -OCTANE DEA DGA 1 1 IbmoUhr 3128.9 Ibmollhr 655.42 F 254.4 psia 27.08 1 1 249.6 Liquid Vapor Liquid Vapor mole frac. mole frac. mass frac. mass free. 0.8702 0.964 0.5492 0.9048 O 0 0 0 K -Value 1.108 0 0.01269 0.02572 0.01957 0.05897 2.026 4.434E-08 2.077E-07 5.294E-08 3.688E-07 4.684 1.267E-07 0.004353 7.123E-08 0.003638 34350 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 0 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 O 0 0 0 0 1E-14 1E-14 3.883E-14 5.478E-14 1 0.1171 0.005957 0.4312 0.03263 0.05088 Total 1 1 1 1 Reboiler Reboiler Vapor IbmoIlhr 662.72 Bottom Product IbmoUhr 2469.2 Temperature (V,L) F 256.3 256.3 Pressure psia 29.7 Component Liquid Vapor Liquid Vapor K -Value mole frac. mole frac. mass frac. mass frac. WATER 0.8426 0.9693 0.4892 0.9076 1.15 NITROGEN 0 5E-18 0 7.28E-18 0 CARBON DIOXIDE 0.01136 0.01751 0.01612 0.04006 1.541 HYDROGEN SULFIDE 2.716E-08 1.081E-07 2.983E-08 1.914E-07 3.979 METHANE 0 0.004305 0 0.00359 0 ETHANE 0 5E-18 0 7.814E-18 D PROPANE 0 5E-18 0 1.146E-17 0 ISOBUTANE 0 5E-18 0 1.511E-17 0 N -BUTANE 0 5E-18 0 1.51E-17 0 I -PENTANE 0 1.031E-19 0 3.864E-19 0 N•PENTANE 0 5E-18 0 1.875E-17 0 CYCLOPENTANE 0 0 0 0 D N -HEXANE 0 2.5E-19 0 1.12E-18 0 CYCLOHEXANE 0 0 0 0 0 N-HEPTANE 0 2.5E-19 D 1.302E-18 0 METHYLCYCLOHEXAN 0 0 0 0 0 BENZENE 0 2.5E-19 0 1.015E-18 0 TOLUENE 0 2.5E-19 0 1.197E-18 0 ETHYL BENZENE 0 2.5E-19 0 1.379E-18 0 O-XYLENE 0 2.5E-19 0 1.379E-18 0 N -OCTANE 0 2.5E-19 0 1.484E-18 D DEA 0 1.024E-16 0 5.597E-16 0 DGA 0.146 0.008917 0.4947 0.04873 0.06108 Total 1 1 1 1 Sweetening Plant Stripper Summary Reboiler Duty Reboiler Duty Lean Amine Loading Water Loss Amine Loss per gal (amine soln.( 1243.7 v per Ibmol cot remc 91900 es acid gas/mole ami 0.077848 gaUmin 0,81631 gal/min 3.3671E-06 Page 22 ENERGY BALANCE Flowsheet Node Feed(s) Product(s) Difference Btu/hr Btu/hr Btu/hr STREAM 1 (Sour Gas ) -506544 0 506544 STREAM 2 (Sweet Gas ) 0 1429486 1429486 STREAM 5 (Makeup Water) -471403.6 0 471403.6 STREAM 14 (Strm 14 ) 0 4319130 4319130 STREAM 15 (To Fuel ) 0 3002.848 3002.848 STREAM 17 (Strm 17 ) 4162946 0 -4162946 STREAM 19 (Strm 19 ) 15259.94 15259.94 0 Total Streams 3200258 5766879 2566620 AMCL 1 (Absorber ) -45452362 -45775175 -322812.4 FLA 2 (F-2 ) -47204661 -47204661 0.005484141 AMCL 3 (Regenerator ) -43973782 -38235739 5738043 PUM 4 (P-4 ) -38637672 -38356975 280697.5 HEAEXC 5 (Rich/Lean ) -85564638 -85564638 -0.000111714 HEAEXC 6 (Cooler ) -41590856 -44945818 -3354962 VAL 7 (V-7 ) -43973782 -43973782 2.95714E-05 MIX 8 (M-8 ) 4319063 4319063 4.40609E-06 LIN 9 (L-9 ) 4319063 4319130 67.06388 MASBAL 10 (B-10 ) -38863259 -38637672 225587.1 VAL 15 (V-15 ) -47204661 -47204661 0.00547716 Total Equipments -423827550 -421260930 2566620 Enthalpy Difference Between Streams and Equipments 4.14439E-08 POWER BALANCE Flowsheet Node PUM 4 (P-4 ) Total Equipments Used Product(s) Difference kW kW kW 95.6306 0 -95.6306 95.6306 0 -95.6306 Page 23 Mat Bal MATERIAL BALANCE SUMMARY (MOLE) ID Component Name Feed(s) Product(s) Difference Relative Error Ibmol/hr Ibmol/hr IbmolIhr 62 WATER 163.3842 168.5006 -5.116479 -0.031315637 46 NITROGEN 471.6551 471.6551 0 0 49 CARBON DIOXIDE 197.1492 196.8987 0.2505219 0.001270722 50 IYDROGEN SULFIDI 0.013127016 0.01316338 -3.63642E-05 -0.002770177 2 METHANE 3404.631 3404.631 9.09495E-13 2.67135E-16 3 ETHANE 530.5343 530.5343 0 0 4 PROPANE 207.6981 207.6981 2.84217E-14 1.36841E-16 5 ISOBUTANE 34.8041 34.8041 0 0 6 N -BUTANE 69.26251 69.26251 1.42109E-14 2.05174E-16 7 I -PENTANE 21.79085 21.79085 -3.55271E-15 -1.63037E-16 8 N -PENTANE 21.65958 21.65958 -3.55271E-15 -1.64025E-16 36 CYCLOPENTANE 0 0 0 0 10 N -HEXANE 14.00215 14.00215 0 0 38 CYCLOHEXANE 0 0 0 0 11 N-HEPTANE 0.9320182 0.9320182 0 0 39 ETHYLCYCLOHEXA 0 0 0 0 40 BENZENE 0.9744622 0.9744622 1.11022E-16 1.13932E-16 41 TOLUENE 0.8357534 0.8357534 -1.11022E-16 -1.32841E-16 45 ETHYL BENZENE 0.013127016 0.013127016 0 0 42 O-XYLENE 0.1794026 0.1794026 0 0 12 N -OCTANE 2.126577 2.126577 -4.44089E-16 -2.08828E-16 4051 DEA 0 0 0 0 2053 DGA 0.079092245 0.08011218 -0.001019935 -0.012895508 Total 5141.725 5146.592 -4.867014 -0.000946572 MATERIAL BALANCE SUMMARY (MASS) ID Component Name Feed(s) Product(s) Difference Relative Error lb/hr lb/hr lb/hr 62 WATER 2943.421 3035.597 -92.17512 -0.031315637 46 NITROGEN 13212.66 13212.66 0 0 49 CARBON DIOXIDE 8676.301 8665.276 11.02517 0.001270722 50 IYDROGEN SULFIDI 0.4473942 0.4486335 -0.001239361 -0.002770177 2 METHANE 54620.43 54620.43 1.45519E-11 2.66419E-16 3 ETHANE 15952.1 15952.1 0 0 4 PROPANE 9158.24 9158.24 1.81899E-12 1.98618E-16 5 ISOBUTANE 2022.814 2022.814 0 0 6 N -BUTANE 4025.537 4025.537 9.09495E-13 2.25931E-16 7 I -PENTANE 1572.123 1572.123 -2.27374E-13 -1.44628E-16 8 N -PENTANE 1562.652 1562.652 -2.27374E-13 -1.45505E-16 36 CYCLOPENTANE 0 0 0 0 10 N -HEXANE 1206.593 1206.593 0 0 38 CYCLOHEXANE 0 0 0 0 11 N-HEPTANE 93.38635 93.38635 0 0 39 ETHYLCYCLOHEXA 0 0 0 0 40 BENZENE 76.11329 76.11329 0 0 41 TOLUENE 77.0013 77.0013 -1.42109E-14 -1.84553E-16 45 ETHYL BENZENE 1.393564 1.393564 0 0 42 O-XYLENE 19.04538 19.04538 0 0 12 N -OCTANE 242.9061 242.9061 -5.68434E-14 -2.34014E-16 4051 DEA 0 0 0 0 2053 DGA 8.315601 8.422834 -0.1072339 -0.012895508 Total 115471.5 115552.7 -81.25842 -0.00070371 Page 24 Mat Bal MATERIAL BALANCE BY NODE (MOLE) Flowsheet Node Feed(s) Product(s) Difference Ibmol/hr IbmoUhr Ibmol/hr STREAM 1 (Sour Gas ) 4391.454 0 4391.454 STREAM 2 (Sweet Gas ) 0 4265.86 -4265.86 STREAM 5 (Makeup Water) 25.60129 0 25.60129 STREAM 14 (Strm 14 ) 0 812.5678 -812.5678 STREAM 16 (To Fuel ) 0 2.284425 -2.284425 STREAM 17 (Strm 17 ) 658.7907 0 658.7907 STREAM 19 (Strm 19 ) 65.87907 65.87907 0 Total Streams 5141.725 5146.592 -4.867014 AMCL 1 (Absorber ) 6872.456 6891.14 -18.68461 FLA 2 (F-2 ) 2625.28 2625.28 -4.54747E-13 AMCL 3 (Regenerator ) 2622.995 2622.995 4.54747E-13 PUM 4 (P-4 ) 2481.002 2481.002 0 HEAEXC 5 (Rich/Lean ) 5103.997 5103.997 0 HEAEXC 6 (Cooler ) 2481.002 2481.002 -8.43211E-06 VAL 7 (V-7 ) 2622.995 2622.995 0 MIX 8 (M4 ) 812.5678 812.5678 0 LIN 9 (L2 ) MASBAL 10 (B-10 ) 812.5678 812.5678 0 2494.82 2481.002 13.81761 VAL 15 (V-15 ) 2625.28 2625.28 4.54747E-13 Total Equipments 31554.96 31559.83 -4.867014 Flowrate Difference Between Streams and Equipments -1.81899E-12 MATERIAL BALANCE BY NODE (MASS) Flowsheet Node Feed(s) Product(s) Difference lb/hr lb/hr lb/hr STREAM 1 (Sour Gas ) 95681.16 0 95681.16 STREAM 2 (Sweet Gas ) 0 89989.91 -89989.91 STREAM 5 (Makeup Water) 468.1067 0 468.1067 STREAM 14 (Strm 14 ) 0 24383.86 -24383.86 STREAM 15 (To Fuel ) 0 48.163 -48.163 STREAM 17 (Sean 17 ) 18191.4 0 18191.4 STREAM 19 (Strm 19 ) 1130.814 1130.814 0 Total Streams 115471.5 115552.7 -81.25842 AMCL 1 (Absorber ) 172868.8 172849.2 19.66521 FLA 2 (F-2 ) 82859.25 82859.25 0 AMCL 3 (Regenerator ) 82811.09 82811.09 1.45519E-11 PUM 4 (P-4 ) 77187.66 77187.66 0 HEAEXC 5 (Rich/Lean ) 159998.7 159998.7 -2.91038E-11 HEAEXC 6 (Cooler ) 77187.66 77187.66 -0.000287383 VAL 7 (V-7 ) 82811.09 82811.09 -1.45519E-11 MIX 8 (M-8 ) 24383.86 24383.86 -3.63798E-12 LIN 9 (L-9 ) 24383.86 24383.86 0 MASBAL 10 (B-10 ) 77086.73 77187.66 -100.9233 VAL 15 (V-15 ) 82859.25 82859.25 2.91038E-11 Total Equipments 944438 944519.3 -81.25842 Flowrate Difference Between Streams and Equipments 7.27598E-11 Page 25 TANKS 4.0 Report Page 1 of 4 TANKS 4.0.9d Emissions Report - Summary Format Tank Indentification and Physical Characteristics Identification User Identification: City: State: Company. Type of Tank: Description: Tank Dimensions Shell Height (ft): Diameter (ft): Liquid Height (ft) : Avg. Liquid Height (ft): Volume (gallons): Turnovers: Net Throughpufigal/yr): Is Tank Heated (yin): Paint Characteristics Shell Color/Shade: Shell Condition Roof Color/Shade: Roof Condition Roof Characteristics Type: Height (ft) Radius (ft) (Dome Roof) Breather Vent Settings Vacuum Settings (prig): Pressure Settings (psig) TK 1421 Vertical Fixed Roof Tank Gilcrest Train 2 condensate tank 210 bbl N Gray/Medium Good Gray/Medium Good Dome 15.00 10.00 12.00 8.00 7,050.25 225.82 1,592,052.00 050 10 00 .0.03 003 Meterological Data used in Emissions Calculations Denver. Colorado (Avg Atmospheric Pressure = 12.12 psia) file://C:\Program Files\Tanks409d\summarydisplay.htm 9/10/2010 TANKS 4.0 Report Page 2 of 4 TANKS 4.0.9d Emissions Report - Summary Format Liquid Contents of Storage Tank TK 14.21 - Vertical Fixed Roof Tank MbdunoCompornM Llqua Daly IJquk( Surf. Bulk vapor 'Avid vapor Ta pondut (dg F) Tamp vapor Pressure Paola) Mei. Maas Maas Moi gam for Vapor Omura Math Avg. Min. Man. (dog Fl Avg. 1.18. Max. Weight. Fnd. Fyot. Weight Caku4tgns Oasolat0 (RVP 13.6) Al 60.36 4787 72.66 5329 72947 6.7628 9.1474 62.0000 9260 Option 4: RVPa13.6. ASTM 8109aa3 file://C:\Program Files\Tanks409d\summarydisplay.htm 9/10/2010 TANKS 4.0 Report Page 3 of 4 TANKS 4.0.9d Emissions Report - Summary Format Individual Tank Emission Totals Emissions Report for: Annual TK 14.21 - Vertical Fixed Roof Tank Components Gasoline (RVP 13 5) Losses(Ibs) Working Loss 5.134.88 Breathing Loss] 3.695 50 Total Emissions 8.830 38 file://C:\Program Files\Tanks409d\summarydisplay.htm 9/10/2010 TANKS 4.0 Report Page 4 of 4 file://C:\Program Files\Tanks409d\summarydisplay.htm 9/10/2010 TANKS 4.0 Report Page 1 of 4 TANKS 4.0.9d Emissions Report - Summary Format Tank Indentification and Physical Characteristics Identification User Identification: City: State: Company. Type of Tank: Description: Tank Dimensions Shell Height (ft): Diameter (ft): Liquid Height (ft) : Avg. Liquid Height (ft): Volume (gallons): Turnovers: Net Throughput(gal/yr): Is Tank Heated (y/n): Paint Characteristics Shell Color/Shade: Shell Condition Roof Color/Shade: Roof Condition Roof Characteristics Type: Height (ft) Slope (ft/ft) (Cone Roof) Breather Vent Settings Vacuum Settings (psig) Pressure Settings (psig) TK-SLOP Vertical Fixed Roof Tank Gilcrest 210 bbl slop tank N Gray/Medium Good Gray/Medium Good Cone 1500 1000 1200 6.00 7,050.25 1 00 7.050.00 0.50 010 -0.03 003 Meterological Data used in Emissions Calculations Denver. Colorado (Avg Atmospheric Pressure = 12.12 psia) file://C:\Program Files\Tanks409d\summarydisplay.htm 10/1/2010 TANKS 4.0 Report Page 2 of 4 TANKS 4.0.9d Emissions Report - Summary Format Liquid Contents of Storage Tank TK-SLOP - Vertical Fixed Roof Tank labdurMComponant L6966 May Liquid Sort Buk vapor Lgim vapor Tamparaeaa laag Fl Tamp Vapor Pnaµaa (pa) MM. Map Mass MM Bass for Vapor Pons.. Month Avg, I* Max. (dig F) Avg. PAn. Mac Weight Fract. Fracl. Weight CakWatbni CltWa as (RVP B) AN 60.36 47.87 7226 6329 2.8964 22648 3.6621 604000 207.00 Option 4:RVPa6 file://CAProgram Files\Tanks409d\summarydisplay.htm 10/1/2010 TANKS 4.0 Report Page 3 of 4 TANKS 4.0.9d Emissions Report - Summary Format Individual Tank Emission Totals Emissions Report for: Annual TK-SLOP - Vertical Fixed Roof Tank Components Crude oil (RVP 5) Working Loss 16.24 Losses(lbs) Breathing Loss 692 47 Total Emissions' 710.71 file://C:\Program Files\Tanks409d\summarydisplay.htm 10/1/2010 TANKS 4.0 Report Page 4 of 4 file://C:\Program Files\Tanks409d\summarydisplay.htm 10/1/2010 sa o o tO o a cn O ,-c r1 N NO.-I0)0O[`')N,--4d'00 O H N H I zo a N I H X (7% U O O ow U) 4-) _ z 0 z O N 0 -- H E \ H U u Kt U a) U X E b) +.) 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L.0 -+ter '000c C I.0 0 CO Co co N f'') O dl C O a co a r 0 lD a co N l0 , -1 rl r L0 Ol .1 ,--I LID N ,-I N 61 ,-I l0 o N rl 1.04E-24 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000000000000000000000 000000 000000000000000 000000000000000000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00OOOOOOOOOOOOOOOOOOO 000000000000000000000 000000000000000000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 • • • • • • • • • • • • • . • • • • • 000000000000000000000 In CO CO ,-I C)crrM 6l 10 Uf) M CO N ' 1.0 U) ,--Ire) Mre) tn00 N 1/40 N 00 C) 0l M OI ,--I 0) IO N lD 01 CO In N C 0 0 Inrrn 0NC)001n61N •O •NOO 00 tO 0 CO 0 f'')r I*)O t0 v' N In 6161 v'N0 •01NOIT •:34 N 01 •f'') NIT � -I 6l . . •,. . • . • ••. . 0 CO l0 '-O O 0l O t0 •-1 CO N rl l0 61 N l0 0 0 ,-I t0 l0 •-IOON-4OON,--100.-IN Or -I Nc-10.-INN I I I I I I I I I I I I 1 1 1 1 1+ 1 1 1 W W W W W W W W W W W W W W W W W W W W W l0 W ,-1061 cr. to6%co oCO001 0 V'O01OO tO r r 1 (''1 61 (' ,-1 O ,-I f'1 N co m IU •-i C') ,-I 0 C M M . • • • • • • • • • . • . • • • • • • . N r NCO U) N N M C' I'•) N N M tO '') I'') NO CO O1 CO BENZENE •z N �I —ro N 1-I v w ro c Wza v •� C ,-I X •,I z--• w DWZ0OU N ra-1 0< E- 00v 4.1• 1.1----41 o 4.14141X w w 0 v Z W W W Z W Z Z W Z Z Z H 4.141X044111< < <>4H<XX�Ha�Zww<0i4x<w DHHW 41 41 WUWw0C4Fz> 0>+>+ WZ vnW WxxXZ00+R+HH$XZUUX s J 4.61E-06 TOTAL ALL COMPOUNDS emissions 1.45E-04 TOTAL ALL COMPOUNDS Attachment D Company Contact Information (Form APCD-101) Form APCD-I01 Company Name: Source Name: Colorado Department of Public Health and Environment Air Pollution Control Division Company Contact Information Form Ver. September 10, 2008 Aka Energy Group. LLC Colorado Department of Public I lcalth and En vronnlcnt Gitcrest Gas Plant Permit Contact': Joe Miller, Mountain Air Consulting, LLC Address: 730 17th Street. Suite 315 Street Denver CO 80202 ('it} State Zip Phone Num ber: (303)-524-9686 Fax Num ber: (303)-524-9689 E-mail: jmiller@mtn-air.com Billing Contact: (Perini( Fees? irgil Frazier Address: 65 Mercado Street, Suite 250 Street Durango CO 81301 City State _ Zip Phone Num ber: 970-764-6661 Fax Number: 970-375-2216 E-mail: vfrazier@akaenergy.com Corn pliance Contact=: Virgil Frazier Address: 65 Mercado Street. Suite 250 Street Durango CO 81301 City State Zip Phone Num ber: 970-764-6661 Fax Number: 970-375-2216 E-mail: vfrazier@akaenergy.com Billing Contact: (Annual Fees)' Virgil Frazier Address: 65 Mercado Street, Suite 250 Street Durango CO 81301 City State _ Zip Phone Num ber: 970-764-6661 Fax Number: 970-375-2216 E-mail: vfrazier@akaenergy.com Check how would you like to receive your permit fee invoice? Mail: ❑ E-mail: Fax: ❑ 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 I of I Form APC D-IOI - Company Contact Into - Ver.9-10-2008 doc Attachment F Facility Emission Inventory (Form APCD-102) L n Form APCD-I02 E E a a J Z Z x y i a ar. B _ V !. NNNNNNNN I n nnl rnllyd Potrnlul to imn IP 11 I 1 - N ' ;_!--,•Pmm 1 t � v. C _ C rrt n r M -" N x = _ _ 1 a ` vri w N 7,7 ,,%X X x -r N x- . N r _ _ '- _ - _ .p ...rr.r------_'4._r —, _ J - r N x - - . Y,! - c — n , C C f L t g C Amine X114' x - R 77. f` - rn• L. tty N O .J, C P C APf.N Oak! \uhlald - APEN Kallyl! taMtaltu.al waters ry N N 77. O O 6 C O C O O A = a X 0 C IartaiIh aat %ubt.ls1 loin!. All Seann I nconlrnl4d l oil. kit II %IN (77Y N 0 a n: N O 04 ID r 0 u C is ri C Q • 'M • .C Go 0 o 3 � z. e 0 • c E t G C C O 0 C.: Form APCD-102 Vcr September 10.2003 C gL 2 .r t t S C .• w- rr Y - .. a _ �, N - ! f - OO -H - .- N- T'r L^ Q L N - r S o x .. T ! . • • i . i n Y • r > •r• ... r9 . w '0 f m — i' r — — — ! « r N .� - , — S " e -I f, rM M ..0 2 •_ "' at ac x C O r . I I C .7{ gi .- y c' v r. N - - d r r. n a P r r 1 r.j T T n s = T w - N O O - .� _ I - r. _ = t ' N a0 O T - - rr1 7 a1 . . - O F V h r H .. N ~ .. T FC .p K vii r� P. O ... - x N I, 1 o L`.. T TI , , V. . P N '� ' r • ,r .f VO( 1 AZ I q G6 _ ..ir. C C - mi.= ; Y. - T h _ r 77.,T l __..___._. 1` _ _ = - - = .. •i r --,4.LMD«.—_ O O = = = C - . 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G .x. < r. r _ N T _. � _ „ -/+1 ' ! ^� ' -.ere 3— _ r N O 74 ca Cd a. 8 Attachment G Process Description, Flow Diagram and Plot Plan SECTION NAME: PROCESS DESCRIPTION SECTION NUMBER: 1.0 PAGE: I OF 3 ISSUE DATE: 09/02/10 ISSUED BY: DSI3 REVISED DATE: APPROVED BY: The Platte River Expander Plant is designed to process up to 20 MMscfd of inlet gas for the recovery of ethane and heavier components through natural gas liquids (NGL) recovery facilities. The NGL recovery facilities consist of a refrigerated turbo -expander plant. The Platte River Expander Plant includes: Inlet liquids (condensate) handling • DGA CO2 Removal System i CO2 thermooxidizer ➢ Molecular sieve gas dehydration ➢ Turbo -expander plant > Propane refrigeration process :► Residue gas compression • Vapor Recovery compression i Plant support utilities Field -dehydrated raw gas is delivered to the plant in a new high pressure inlet line from a central dehydration and compression facility. Inlet gas initially passed through a slug catcher where any free liquids are removed. The liquid condensate is rich in methane and therefore is stabilized prior to transfer. The field -dehydrated high pressure gas is routed to DGA (Di -Glycol Amine) contactor to remove any CO2 in the gas stream. From the DGA contactor the gas is then routed to the cryogenic expander plant at approximately 950 psig. The DGA is a partial stream from the DGA regeneration system. the remaining DGA from the stream goes to another DGA contactor to remove CO2 from an existing 20 MMSCFD stream that is processed in a similar expander plant. The DGA that has removed CO2 from the gas stream has the CO2 removed from it by the addition of heat. The heat causes the CO2 to be released from the DGA solution. The DGA also absorbs some hydrocarbons. These hydrocarbons are also released from the DGA and are mixed with the CO2. The CO2 and hydrocarbon mixed stream is then sent to a thermooxidizer that adds enough air and methane fuel before they are ignited to assure 95+% destruction of all hydrocarbons. High pressure liquids (condensate) collected in the slug catcher are routed to a stabilizer where they are heated and distilled to remove the volatile butanes and lighter components. These lighter gases are re -compressed with a vapor recovery compressor 1 (VRU) and re-routed to the plant inlet for processing. The stabilized liquids approximately 12 RVP are stored for transport on site in an atmospheric tank. The VRU is an existing system within the 20 MMSCFD plant that is already permitted at the site. The turbo -expander based cryogenic process uses a significant pressure drop between the inlet and outlet or residue streams along with an array of efficient heat exchange equipment to cool the gas mixture to around -130 degrees Fahrenheit. The process utilizes the Joule -Thompson effect for gas cooling and condensing the heavier hydrocarbons in the gas stream. Before the inlet gas can be processed in the cryogenic system, the gas's water content must be reduced to less than 1 ppm to avoid any possibility of water reaching the cold section of the plant. This is accomplished using a molecular sieve dehydration system. In this system, water is adsorbed into the molecular sieve media contained in one of two vessels. After a period of time. the inlet gas is diverted into the second vessel. The sieve media is regenerated (water cooked out) by flowing hot gas through the media to drive or literally cook the adsorbed water from the sieve in the first vessel. Dry inlet gas from the dehydration system flows to the cryogenic unit where it is cooled to sub -zero temperatures by heat exchange using internal process streams. Supplemental cooling is provided by a propane refrigeration loop. This gas cooling process condenses a significant portion of the inlet gas. The resulting liquid is removed and routed to a distillation tower (Demethanizer) to meet product specifications. The remaining cold inlet gas stream flows to the expander, which reduces the gas pressure while removing energy from the gas. This significant pressure reduction drops the temperature to cryogenic levels below -80°F. At this temperature, most of the propane and a large percent of ethane is condensed, which flow to the Demethanizer. The cold gas and liquid mixtures provide reflux for the tower. The propane refrigeration loop is a closed cycle. Propane is used as a refrigerant in a gas chiller located between the high and low temperature Gas/Gas Exchangers. Liquid propane is fed from the propane accumulator or the economizer to the gas chiller through a level control valve. Liquid propane level is maintained to keep gas tubes in the chiller covered with liquid propane. Latent heat of vaporization provides ample and efficient cooling of the rich inlet gas as the propane boils off. Propane vapor leaves the top of the chiller to the propane compressor suction scrubber. The propane compressors are Caterpillar 3306TA natural gas driven rotary screw compressors. Propane is compressed to approximately 200 psi. The vapors are filtered to remove compressor lube oil and then condensed by an aerial cooler. Propane liquid flows from the condenser to the Propane Accumulator prior to beginning the cycle again. Heat to drive the Demethanizer fractionation process is supplied by a heat medium system. The heat medium or hot oil passes through the Demethanizer Reboiler providing heat to vaporize the methane and ethane contained in the natural gas liquids stream. Gases leaving the top of the Demethanizer tower pass through a system of exchangers in the cryogenic plant in order to cool the inlet gas while warming the residue gas. The 2 residue gas then flows to the residue gas compressor. The residue compression is provided by a new Caterpillar/Ariel 3520 compressor package. The liquids leaving at the bottom of the Demethanizer tower are pumped directly from the tower to an NGL pipeline via centrifugal NGL booster pump and a pair of positive displacement NGL pipeline pumps. A portion of the residue gas is used for the molecular sieve regeneration. Regeneration gas flow to the heater is established through induced differential pressure by applying backpressure to the residue compression discharge line. During the heating cycle, the regeneration gas is heated by a gas -fired heater to over 500°F. This hot gas is used to heat the molecular sieve beds and drive off the adsorbed water. After the beds are dried, the main burner in the regeneration gas heater is shut off and the unheated gas is used to cool the regenerated molecular sieve bed back to normal operating temperatures. The hot regeneration gas is cooled in an air cooler to condense the removed water. The water is collected and sent to the water storage tank while the gas returns to the gas stream, selectable between inlet and residue. Several utility systems support the plant operations. Instrument air is provided by three air compressors. Electric power for the plant is provided by the local utility. Methanol is used to remove any freeze -ups in the turbo -expander plant during abnormal operations. Fuel gas is normally supplied from plant residue gas with a backup source from the low pressure inlet. Plant liquid waste drains are collected in a drain system and flow to the low pressure inlet separator. Waste oil is collected in an underground sump located south of the compressor building. 3 O A U) NGL's TO SAL h ial Id '3 U m Wit) Rs p Z N kj („2 emudQ c ue- h-2U w O Z N Q 8 eulw a)esuapuo3 —0 Z LL ^0 i O c O 2`' J y N Q) O. o L U rn IA y 0 J y y co 11-3 g c O - J J W y Condensate to 0 z w O w J GILCREST TRAIN I and TRAIN II PROCESS FLOW DIAGRAM Aka Energy Group, LLC Prepared By DLC Checked BY FKB Z c ce Q m E _ w Z "V"' It I I I• • V .... -\•/ N Y n .r . t 3 ':. I t I:I_ -- ..n.,s , 0 j,,, _ _ • 1-; Attachment H Operating and Maintenance (O&M) Plan(s) Form APCD-301 Colorado Department of Public Health and Environment Air Pollution Control Division Operating and Maintenance Plan Template for Reciprocating Internal Combustion Engines Vcr. February 14, 2012 .,06 Colorado Department of Publicth and Environment 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. lithe 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: August 15, 2012 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: Facility Name: Aka Energy Group. LLC Gilcrest Gas Plant Facility Location: 13472 Weld County Road 40 Facility AIRS ID (for existing facilities) 123/0098 Units Covered by this O&M form Facility Equipment ID C -7(F1197) C-8(G3306TA) C-9(G3306TA) C -10(G35206) AIRS Point ID 003 Permit Number 07WE0081 07WE0081 07WE0081 07WE0081 Rich Burn (RB) or Lean Burn (LB) RB RB RB LB Air Fuel Ratio Controller (1'/\) Y Y Y Y Catalyst Type' NSCR NSCR NSCR SCO ' Non -selective Catalytic Reduction (NSCR) or Selective Oxidation Catalyst (SCO) Section 2 - Maintenance Schedules Check one of the follow mile: Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control ID 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 E 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 I of 4 FormAPC D -30I -RIC EO&M-Vert-142012 dot 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 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 1 - 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 Flours 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 GI • Individual engine fuel meter ❑ Facility -wide fuel meter attributed to fuel consumption rating and hours of operation ❑ ., 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. All portable analyzer tests must be performed per Division protocol, which can be found at http://www.ctlphe.statc.co.usiap/down/portanalvieproto.pd( Table 3 Control Status Portable Testing Frequency ' Permitted Facility Emissions ❑ Permitted Facility Emissions < 100 tpy ≥ 80 tpy NO, or CO ❑ Permitted Facility Emissions < 80 tpy NO, or CO ≥ 100 tpy NO, or CO NSCR or SCO Quarterly: the frequency shall remain quarterly regardless of the number of consecutive passing tests. Quarterly: then semi-annual after 4 consecutive quarterly passing tests. If any of the semi-annual tests fail then the source shall return to quarterly tests. Semi-annual: then annual after 2 consecutive passing semi-annual tests. If any of the annual tests fail then the source shall return to semi-annual testing. 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 —fill 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 FormAPCD-30l-RICEOB&M-Vert-14-20t2.doc Colorado Department of Public Health and Environment Air Pollution Control Division Table 4 Rich Burn Engine Lonitoring Frequency Emissions Control Device Monitoring Requirement Monitoring Fre uency Permitted Facility Emissions < 80 tpy NO, or CO ' Permitted Facility Emissions ≥ 80 tpy NO, or CO Non -selective catalytic reduction (NSCR) Pre -catalyst Temperature b Daily Weekly Catalyst Differential Pressure ` Monthly Monthly Air -Fuel Ratio Controller (AFRO) AFRC O2 sensor mV reading ` Weekly Weekly b Pre -catalyst temperature shall stay within the range of 750° F to 1250° F. If the temperature is outside ofthis range then appropriate maintenance activities shall be performed. AFRC O2 Sensor Monitoring and Maintenance Requirements • If the engine uses an oxygen sensor then it ill be replaced per manufacturer's recommended schedule. I f 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 S Lean Burn Engine Monitoring Frequency Emissions Control Device Monitoring Requirement Monitorin Fre uency El Permitted Facility Permitted Facility Emissions < 80 tpy NO, or CO Emissions > 80 tpy NO, or CO Selective Oxidation Catalyst (SCO) Pre -catalyst Temperature ' Daily Weekly Catalyst Differential Pressure ` Monthly Monthly 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. I f 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 FormAPCD-301-RICEO&M-Vert-14-2012.doc Colorado Department of Public Health and Environment Air Pollution Control Division Section 6— Recordkeepine Reouirem cots 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 2 years. Ilan 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. ,Vote: These templates are intended to address operation and maintenance requirements of the State of Colorado for equipment operated at synthetic minor facilities. If thefaci/itr or equipment is subject to other state or federal regulations with duplicative requirements, the source shal/follow the most stringent regulatory requirement. Page 4 of 4 FormAPCD-301-R[CEO&M-Vert-1J-2012 doc Form APCD-301 Colorado Department of Public Health and Environment Air Pollution Control Division Operating and Maintenance Plan Template for Reciprocating Internal Combustion Engines Ver. February 14.2012 Colorado Department of Public 1 icalth and Environment The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) template for reciprocating internal combustion engines that arc 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 arc 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: August 15.2012 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 Namc: Facility Name: Aka Energy Group, LLC Gilcrest Gas Plant Facility Location: 13472 Weld County Road 40 Facility AIRS ID (for existing facilities) 123/0098 Units Covered by this O&M form Facility Equipment ID C -I (G3516LE) C-2 (L7044GSI) C-3 (86825) C-4 (5790GSI) C-5 (5790GSI) C-6 (F1197) AIRS Point ID 001 011 005 007 016 002 Permit Number 07WE0081 07WE0081 07WE0081 07WE0081 07WE0081 07WE0081 Rich Burn (RB) or Lean Burn (LB) LB RB RB RB RB RB Air Fuel Ratio Controller (Y/N) Y Y Y Y Y Y Catalyst Type a SCO NSCR NSCR NSCR NSCR NSCR ' Non -selective Catalytic Reduction (NSCR) or Selective Oxidation Catalyst (SCO) Section 2 - Maintenance Schedules Check one of the following: E 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 FormAPCD-30I-RICEO&M-Ver2.14.2012.doc Colorado Department of Public Health and Environment Air Pollution Control Division Section 3 - Monthly Emission Modeling or Calculations The following boa must be checked for O&M plan to be considered complete. 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 - Central muniturinC Requirements Table I 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 I 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 G ❑ Individual engine fuel meter ❑ / Facility -wide fuel meter attributed to fuel consumption rating and hours of operation • i 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. All portable analyzer tests must be performed per Division protocol, which can he found at htlp;//www.cdphe.slate.co.us/ap/down/portanalyzeproto.pdf Table 3 Control Status Portable Testing Frequency El Permitted Facility Emissions ≥ 100 tpy NO, or CO ❑ Permitted Facility Emissions < 100 tpy ≥ 80 tpy NO. or CO O Permitted Facility Emissions < 80 tpy NO, or CO NSCR or SCO Quarterly; the frequency shall remain quarterly regardless of the number of consecutive passing tests. Quarterly; then semi-annual after 4 consecutive quarterly passing tests. If any of the semi-annual tests fail then the source shall return to quarterly tests. Scmi-annual: then annual after 2 consecutive passing semi-annual tests. If any of the annual tests fail then the source shall return to semi-annual testing. 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 —fill 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 FormAPCD-301-R1C EO&At-Vcr2-I d-2012 doe Colorado Department of Public Health and Environment Air Pollution Control Division Table 4 Rich Burn Engine Monitoring Frequency Emissions Control Device Monitoring Requirement Monitoring Fre uency • Permitted Facility Permitted Facility Emissions < 80 tpy NO, or CO Emissions ≥ 80 tpy NO, or CO Non -selective catalytic reduction (NSCR) Pre -catalyst Temperature b Daily Weekly Catalyst Differential Pressure ` Monthly Monthly Air -Fuel Ratio Controller (AFRC) AFRC Oi sensor mV reading ` Weekly Weekly ° Pre -catalyst temperature shall stay within the range of 750° F to 1250° F. I f 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. l f the replacement is determined by hours of operation then the source will track the hours of operation. • In addition to the weekly AFRC O2 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 Monitoring Requirement Monitoring Fre uency •Permitted Facility a Permitted Facility Emissions ‹. 80 tpy NO, or CO Emissions > 80 tpy NO, or CO Selective Oxidation Catalyst (SCO) Pre -catalyst Temperature't Daily Weekly Catalyst Differential Pressure ` Monthly Monthly 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. l f 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. lithe 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 FormAPCD-30I-RICEOB&M-Vert-I4-2012.doc Colorado Department of Public Health and Environment Air Pollution Control Division Section 6 — Rccordkeepine Requirements The following box must be checked for O&NI 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 2 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 orfederal regulations with duplicative requirements, the source shall follow the most stringent regulatory requirement. Page 4 of 4 FormAPCD-301-RICEO&M-Vcr2-14-2012.doc Form APCD-306 Colorado Department of Public Health and Environment Air Pollution Control Division Operating and Maintenance Plan Template for Amine Sweetening Systems Ver. September 10.2008 The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) for amine sweetening systems that are permitted at a synthetic minor facility in the State of Colorado. An O&M Plan for each type of amine sweetening system configuration, as described in Section 1. shall be submitted with the permit application. One O&M Plan may be used for multiple amine sweetening 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 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: August 15. 2012 Section l - Source Identification Colorado Department of Public I Icalth and Environment 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: Facility Name: Aka Energy Group, LLC Gilcrest Gas Plant Facility Location: 13472 Weld County Road 40 Facility AIRS ID (for existing facilities) 123/0098 l nits Covered by this O&M form Facility Equipment ID Permit Number AMINE 07WE0881 AIRS Point ID Amine Type Used' DGA ° Amine types include MEA, DEA, TEA, MDEA, and DGA Emission Points and Control Status: Check the appropriate boxes indicating whether the dehydration system(s) are equipped with aflash tank and whether or not the flash tank (if present) and still vent emissions are controlled or recycled or vented to atmosphere. O Flash Tank CI Controlled/Recycled O Vented to atmosphere Section 2 - Maintenance Schedules Check one of the following: El Still Vent I Controlled/Recycled O 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 I of 4 Form APCD-306 - Aminellnit O&M - Ver 9-10-2008 doc Colorado Department of Public Health and Environment Air Pollution Control Division a 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 the facility -wide permitted VOC emissions. Table I Parameter Monitorin Frequency ❑ Permitted Facility Emissions 2 80 tpy VOC i Permitted Facility Emissions < 80 tpy VOC Lean Amine Circulation Rate Daily Weekly Gas Inlet Temperature Weekly Monthly Gas Inlet Pressure Weekly Monthly Volume of Gas or NGL Processed Monthly Monthly Tables 2 and 3 outline the methods by which the source may monitor the lean amine recirculation rate and the gas or NGL processed. respectively. In Tables 2 and 3 the source must chose one primary monitoring method and, optionally. up to two backup monitoring methods. Table 2 Primary Back-up Lean Amine Recirculation Rate Monitoring Method ❑ Amine flow meter(s) — including flow from all pumps ❑ ❑ Record strokes per minute and convert to circulation rate — pump make/model and stokes per minute/ circulation rate relationship must be made available to the division upon request ❑ Assume maximum design pump rate b — pump make/model and circulation rate specifications must be made available to the division upon request 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 or NGL Processed MonitoringMethod 0 Metered C Inlet Q Outlet Compressor Suction Compressor Discharge •Other: El(i ❑ Metered Inlet Compressor Discharge Outlet Compressor Suction 8 U • Other: 0 0 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 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 Form APC D-306 - AmmcUnn O&M - Vet 9-10-2008.doc 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 Control or Recycling Method Y g Still Vent Flash Tank Parameter Monitoring Frequency ❑ Permitted Facility Emissions ? 80 tpy VOC 0 Permitted Facility Emissions < 80 tpy VOC Thermal Oxidizer Combustion Chamber Temperature ° Daily Weekly y El • Combustor or Flare ❑ ❑ Pilot Light Monitoring ` Daily Weekly Method 22 Readings Daily Weekly Recycled or Closed Loop System (Including Vapor Recovery Units) ❑ To be determined by the source and approved by the division r ' Re-routed to Reboiler Burner O To be determined by the source and approved by the division 11 • u 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 5. Table 5 I 1400°F ❑ ° F Based on manufacturer specifications. Specifications must be submitted with the permit application and made available to the Division upon request ❑ Based on testing performed. The test data shall be submitted and attached to the O&M Plan Pilot Light Monitoring Options lithe 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 6. One primary method for Pilot Light Monitoring must be checked and, optionally. up to two backup methods can be checked. Table 6 Primary Back-up Monitoring Method • ■ Visual Inspection ❑ ❑ Optical Sensor • ❑ Auto -Igniter Signal ❑ ❑ Thermocouple r 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. Flash tank off -gas will be routed to the fuel gas system dunng normal operation. Page 3 of 4 Form APCD-306 - AmincUnit O&M - Vcr.9-10-20O8.doc Colorado Department of Public Health and Environment Air Pollution Control Division Reboller 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 — Recordkeenine 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 2 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 Form APCD-306 - AmmeUnit O&M - Ver.9-10-2008 doc Karla Ford From: Chris Gathman Sent: Wednesday, September 25, 2013 4:06 PM To: Karla Ford Subject: FW: Air Permit Application / Aka Energy Group - USR 13-0042 Attachments: Aka Air Emissions Submittal Scans.zip Karla, This is a zip file so I am not sure if you need another version or not. Sincerely, Chris Gathman Planner Ill Weld County Department of Planning Services 1555 N. 17th Avenue, Greeley CO. 80631 Ph: (970)353-6100 ext. 3537 Fax: (970)304-6498 Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. From: Don Evans [mailto:devans.pfs@aigmail.com] Sent: Wednesday, September 18, 2013 2:32 PM To: Chris Gathman Subject: Air Permit Application / Aka Energy Group - USR 13-0042 Chris, Attached is the emissions application for the additional equipment to be added to the site. Please let me know if you have any questions. Thanks, Don Evans Contract Agent Hill Land Services, Inc. 700 Automation Drive, Unit H 1 Windsor, CO 80550 devans.pfs@gmail.com 970-227-9682 970-674-9120 Fax No virus found in this message. Checked by AVG - www.avg.com Version: 2013.0.3408 / Virus Database: 3222/6677 - Release Date: 09/18/13 Karla Ford From: Chris Gathman Sent: Wednesday, September 25, 2013 2:00 PM To: Don Evans Cc: Karla Ford Subject: RE: Sign, Noise Abatement and Lighting Plans / Aka Energy Group USR 13-0042 Attachments: Signs.pdf Dear Don, The lighting plan looks fine. I forwarded your e-mail to the Health Department re: the noise plan. One correction is needed to the Sign Plan —The Use by Special Review Permit will not change the underlying zoning of the property. It still remains agricultural zoning (see freestanding signs under the attached Appendix 23-D). Per the Weld County Code — any signage would fall under the A(Agricultural) and not the Industrial category. Let me know if you have any questions. FYI: I am not sure if I will hear back from the Health Department before I leave on 9/30. If so we can confer on this when I get back before the 10/23 hearing (10/17). Sincerely, Chris Gathman Planner III Weld County Department of Planning Services 1555 N. 17th Avenue, Greeley CO. 80631 Ph: (970)353-6100 ext. 3537 Fax: (970)304-6498 Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. From: Don Evans [mailto:devans.ofs@gmail.com] Sent: Wednesday, September 18, 2013 12:27 PM To: Chris Gathman Subject: Sign, Noise Abatement and Lighting Plans / Aka Energy Group USR 13-0042 Hello Chris, 1 Attached are the plans your office has requested. Please review and let me know if the meet your approval. Thanks, Don Evans Contract Agent Hill Land Services, Inc. 700 Automation Drive, Unit H Windsor, CO 80550 devans.pfs@gmail.com 970-227-9682 970-674-9120 Fax No virus found in this message. Checked by AVG - www.avg.com Version: 2013.0.3408 / Virus Database: 3222/6674 - Release Date: 09/17/13 2 SIGN PLAN - AKA ENEERGY GROUP / USR 13-0042 Aka Energy Group will erect a sign or signs along its property facing County road 40 as required by Weld County. Sign specifications will follow guidelines delineated in Appendix 23, sections C though E of the Weld County Code for industrial zones. NOISE ABATEMENT PLAN - AKA ENEERGY GROUP / USR 13-0042 Aka Energy Group will build enclosures around the new engines and compressors. Mufflers will be installed on the engines to minimize exhaust noise. This facility shall adhere to the maximum permissible noise levels allowed in the Industrial Zone District, as delineated in Section 14-9-30 of the Weld County Code. LIGHTING PLAN - AKA ENERGY GROUP / USR 13-0042 Sources of light shall be downcast and shielded so that light rays will not shine directly onto adjacent properties where such would cause a nuisance or interfere with the use on the adjacent properties in accordance with the plan. Neither the direct nor reflected light from any light source may create a traffic hazard to operators of motor vehicles on public or private streets. No colored lights may be used which may be confused with, or construed as, traffic control devices. All lighting shall comply with Weld County and OSHA regulations. APPENDIX 23-D NUMBER AND DIMENSIONS OF INDIVIDUAL SIGNS BY ZONE DISTRICT AND TYPE SIGN TITE NUMBER ALLOWED MAXIMUM SIGN AREA MAXIMUM HEIGHT Banner 1 per zone lot 40 sq. ft. Billboard (not allowed in PUD) 1 per zone lot. No billboard shall be located less than 500 ft. from any other billboard or off -site directional sign. 300 sq. ft. 40 ft. Building No limit On a given wall, the sum of all BUILDING SIGNS which require a zoning permit shall not exceed 8% of that wales sq. ft. No higher than the top of the building Building Marker 1 per building 4 sq. I Canopy I per building face 10% of the vertical surface of the canopy or 25 sq. ft., whichever is smaller Development 1 per Planned Unit Development, Minor or Major Subdivision C & I - 150 sq. ft. all other zones - 32 sq. ft. C & I - 25 ft. all others - 8 ft. Flag 1 per zone lot A, R, & E - 15 sq. ft, total C,I&1NS-60sq,ft.total A, R, &E - 15 ft. C,1&INS -30 ft. Freestanding A, INS - 1 per zone lot. C & 1— I per ZONE LOT, I per each 500 ft, of road frontage or I per each different road frontage, whichever is greater,* A — 16 sq. ft, C& I —150 sq. ft. INS — 32 sq. ft. C & 1— 25 ft, A — 6 ft. INS — 15 ft. Identification I per tenant located within the building 2 sq. ft. 4 ft. incidental N/A N/A N/A Off -Site Directional (not allowed in PUD zoning) C, I & A - 1 per zone lot. No off -site directional sign shall be located less than 500 ft. from any other billboard or off -site directional sign. C& I - 300 sq. ft. A - 150 sq. ft. C & I - 40 ft. A - 30 ft. Political No limits No limits No limits Real Estate Promotional (On -Premises) 1 per public access single- or double-faced 48 sq. ft. each 12 ft. Real Estate Promotional (Off -Premises) 2 single- or double-faced; must have landowner permission, min. 300 ft. spacing 48 sq. ft. each 8 ft. e Residential 1 per zone lot 1 sq. ft. 6 ft. Temporary 1 per zone lot A, R, & E - 4 sq. ft. C,1&INS -8sq. ft. A, R, &E - 6 ft. C,I&INS-8ft. Wall N/A N/A Window N/A 25% of total window area KEY TO ABBREVIATIONS A Agricultural Zone District C-1 Neighborhood Commercial Zone District R -1 Low -Density Residential Zone District C-2 General Commercial Zone District Karla Ford From: Chris Gathman Sent: Thursday, September 26, 2013 8:24 AM To: Karla Ford Subject: FW: AKA CORRECTED SIGN PLAN USR 13-0042,docx Attachments: AKA SIGN PLAN USR 13-0042.docx Chris Gathman Planner Ill Weld County Department of Planning Services 1555 N. 17th Avenue, Greeley CO. 80631 Ph: (970)353-6100 ext. 3537 Fax: (970)304-6498 Confidentiality Notice: This electronic transmission and any attached documents or other writings are intended only for the person or entity to which it is addressed and may contain information that is privileged, confidential or otherwise protected from disclosure. If you have received this communication in error, please immediately notify sender by return e-mail and destroy the communication. Any disclosure, copying, distribution or the taking of any action concerning the contents of this communication or any attachments by anyone other than the named recipient is strictly prohibited. From: Don Evans [mailto:devans.pfs©agmail.com] Sent: Thursday, September 26, 2013 8:23 AM To: Chris Gathman Subject: AKA CORRECTED SIGN PLAN USR 13-0042.docx Good Morning Chris, Attached is the corrected sign plan. Thank you for the update on the other items. Our office will be in touch with you when you return to see where we stand. Have a good day! Don Evans Contract Agent Hill Land Services, Inc. 700 Automation Drive, Unit H Windsor, CO 80550 devans.pfs@gmail.com 970-227-9682 970-674-9120 Fax 1 SIGN PLAN - AKA ENEERGY GROUP / USR 13-0042 Aka Energy Group will erect a sign or signs along its property facing County road 40 as required by Weld County. Sign specifications will follow guidelines delineated in Appendix 23, sections C though E of the Weld County Code for Agricultural Zone Districts . Hello