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HomeMy WebLinkAbout1.1 ApplicationDecember 8, 2006 CY'4w-Wr� .\CS_ 2oot012..073 Willem Colorado Department of Public Health & Environment Construction Permit Section, APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Re: Construction Permit Application Crawford Trail Compressor Station Garfield County, Colorado Dear Mr. Roland Hea: EXPLORATION & PRODUCTION Tower 3, Suite 1000 1515 Arapahoe Street Denver, CO 80202 303/572-3900 303/629-8282 fax Williams Production RMT Company (Williams) is submitting the attached Facility -Wide Construction Permit Application for a proposed natural gas compression facility, the Crawford Trail Compressor Station. The Crawford Trail Compressor Station (Crawford Trail) will be located in the SW '/a of the SE % of Section 23, Township 6S, Range 97W in Garfield County, situated at an elevation of approximately 8450 ft above sea level. This facility is designed with a capacity to gather and compress up to 180 MMscf/day of incoming natural gas at a typical field pressure of 200-245 psig. Inlet field natural gas will be routed through an inlet separator to remove entrained liquids from the inlet gas stream. The gas will be compressed by several reciprocating, internal combustion engine -driven compressors to a pressure of approximately 900-950 psig, and routed through two parallel triethylene glycol (TEG) dehydration units to remove moisture from the gas stream. The dehydrated natural gas stream will then leave the facility via pipeline. Williams plans to install four internal combustion engine driven compressors, two internal combustion engine driven generators, one process heater, two 90 MMscf/day TEG dehydration units, one vapor recovery unit (VRU), and six 400 -bbl condensate storage tanks at the facility. A site location map, facility plot plan, and process flow diagrams are provided in Attachment I. A completed Permit Application form and completed APENs for emissions sources are provided in Attachment 2. Facility -Wide Sources and Emissions Internal Combustion Engines There will be six (6) natural gas fired reciprocating internal combustion engines at the Crawford Trail Compressor Station. There will be four Caterpillar 3612LE TA -130 4 - cycle lean burn engines each site -rated at 3,550 hp and equipped with selective catalytic oxidation (SCO) emission control systems that will operate in inlet natural gas compression service (ID: ENG -01 through ENG -04). Site -rated horsepower ratings are based on non -derated manufacturer specifications. The NOn/CO/VOC emission factors Roland Hea - CDPHE December 8, 2006 Page 2 for the 3612LE TA -130 engines will be 1.0 g/hphr NOx, 0.18 g/hp-hr CO, and 0.1 g/hp-hr VOC based on manufacturer's emission factors and emission testing results obtained for like -kind engines operating at the Williams Parachute Creek Gas Plant. The annual potential emissions of NO., CO, and VOC from each Caterpillar 3612LE TA -130 engine will be 34.3 tpy, 6.0 tpy, and 3.4 tpy. Due to the high demand and low supply of compressor/engine packages, Williams is proposing an Alternate Operating Scenario (AOS) for two of the proposed engines (IDs: ENG -03 and ENG -04). Williams intends to install and operate two Caterpillar G3516 TALE -130 engines initially until the 3612LE TA -130 units can be brought in for full- time operation for the ENG -03 and ENG -04 emission points. Williams anticipates that the smaller, G3516 TALE units may run for up to 12 months before allocation of the larger 3612LE units will occur. Thus, Williams is requesting the option of installing either the 3,550 hp Caterpillar 3612LE TA -130 units or the 1,340 hp Caterpillar G3516 TALE -130 engines for ENG -03 and ENG -04. Under either scenario, each engine would be equipped with an SCO emission control system. The worst case emissions from these engines for both criteria pollutants and formaldehyde would be the Caterpillar 36I2LE TA- 130. Appendix B lists the emission information for each type of engine and the APEN attached for these proposed sources (ENG -03 and ENG -04) in Appendix A reflects the worst case scenario emissions assuming that the 36I2LE TA -130 units are installed. The fifth and sixth proposed engines (lDs: ENG -05 and ENG -06) will be Caterpillar G3516 TA -130 rich burn generator engines site -rated at 1,053 hp (1,200 rpm), each equipped with a 3 -way catalyst emission control system that will provide electrical power to the site. In operation, only one of these generators should be running at any given time, with the second unit intended to serve solely as a backup unit. However, Williams would like to permit these two engines at the maximum operational capacity of 8,760 hrs/yr per engine, in the event that both units are needed to maintain full operation of the facility. Given that uncontrolled potential emissions of NO„ from each unit is well above 100 tpy, both of these units will be subject to 40 CFR Part 64 Compliance Assurance Monitoring (CAM). A proposed CAM plan has been attached in Attachment 4. The proposed controlled NO„/CONOC emission factors for these generator engines will be 2.0/2.0/0.25 g/hp-hr with maximum annual NO., CO, and VOC emissions of 20.3 tpy, 20.3 tpy, and 2.5 tpy, respectively. Triethylene Glycol Dehydration Units There will be two TEG dehydration units (Source ID: DEHY-1 and DEHY-2), plumbed in parallel, and each designed to remove water from the natural gas after it has been compressed to 900-950 psig by the booster compression units. Each TEG dehy is designed to process up to 90 MMscf/day of field natural gas and both will operate with a flash tank and a regenerator still vent condenser emission control. Under normal operating conditions, the flash tank overhead vapor streams and the regenerator still vent condenser overhead streams from both TEG dehydration units will Roland Hea - CDPHE December 8, 2006 Page 3 be routed to the VRU. The dehydration units therefore are designed to operate as closed- loop systems with no emissions to atmosphere. Consistent with Division recommendations, Williams is classifying the VRU as a control device rather than a permitted process unit, and is listing the VRU as such on the completed APEN forms for the two dehydration units. HYBON Engineering, the proposed VRU manufacturer, guarantees a minimum 95% run-time, which corresponds to a maximum of 18 days of down-time per year for routine repair and maintenance. The control efficiency of each dehy, as listed on the APENs, was determined based on the VRU vendor run-time guarantee, a copy of which is provided in Attachment 3. Controlled emissions listed on the dehydration unit APENs were calculated based on the assumption that each dehydration unit operates with condenser controls at all times and a VRU downtime of 5%. When the VRU is not operating, VOC and HAPs are emitted from the flash tank and the regenerator still vent condenser outlet of each dehydration unit. The estimated annual permitted VOC emissions from each dehydration unit are 3.6 tpy from each flash tank and 4.8 tpy from each regenerator still vent condenser outlet, for a total of 8.4 tpy from each dehydration unit. Condensate Storage Tanks Williams plans to install six 400 -bbl aboveground atmospheric condensate storage tanks at Crawford Trail. The six stock tanks (ID: TANK -01) will be manifolded together and will be designated as one emission point. Condensate at a maximum inlet pressure of approximately 245 psig will be routed from the inlet gas separator to a pressurized condensate flash tank process vessel which will operate at approximately 20 psig. Condensate flash vapors produced as the condensate pressure is reduced from the inlet separator pressure to 20 psig are routed to the VRU where they are recompressed and routed back into the facility inlet gas stream with zero emissions to atmosphere. Additional flash gas is produced as the 20 psig condensate leaves the flash tank process vessel and is routed to the stock tanks operating at atmospheric pressure. This flash gas will be emitted through the TANK -01 vent to atmosphere. A process flow diagram of the VRU is presented is Attachment 1. Permitted VOC emissions from the TANK -01 emission source are calculated as the combined total of estimated flash and working/breathing emissions from the tanks during normal operating conditions with the VRU operating (flash from 20 psig to atmosphere, 8,322 hr/yr), plus estimated flash and working/breathing emissions during VRU down- time (flash from 245 psig to atmosphere, 438 hr/yr). An average daily condensate production rate of 40 bbl/day is assumed. Annual VOC emissions from the TANK -01 emission source during normal operating conditions, estimated using the API E&P TANKS 2.0 computer model and including flash and working/breathing losses, are 15.0 tpy. Annual VOC emissions from the TANK -01 emission source during upset conditions when the VRU is not operating are estimated at 2.5 tpy. Total requested VOC emissions from the TANK -0I emission source are 17.5 tpy. Roland Hea - CDPHE December 8, 2006 Page 4 Consistent with Division recommendations, Williams is classifying the VRU as a control device rather than a permitted process unit, and is listing the VRU as such on the completed APEN for the TANK -01 emission source. Due to the inherent seasonal variability of condensate production in the Piceance Basin, Williams requests that APCD lists only an annual condensate throughput limit in the permit. Vapor Recovery Unit As described above, Williams will use one VRU as a VOC and HAP emission control device for both dehydration units and the condensate tank emission unit. The permitted emissions from the dehydration units and the condensate storage tanks are estimated based on the vendor guarantee of a 95% control efficiency for the vapor streams being controlled by the VRU, based on a 100% control efficiency while operational, and assuming a maximum down-time of 5% (18 days per year) when the VRU is non- operational. A process flow diagram of the proposed VRU is provided in Attachment 1. Process Heater Williams will install a heat medium system that will be used to support various process unit operations including TEG regeneration, building heat, storage tank heating and other miscellaneous heat loads. This natural gas fired process heater (ID: HTR -01) has a maximum heat rating of 15.0 MMBtu/hr. Emissions of NO,,, CO, and VOC are estimated at 6.32 tpy, 5.31 tpy and 0.35 tpy, based on AP -42 natural gas combustion emission factors. Loadout Periodically, condensate will be loaded from the condensate storage tanks at Crawford Trail into tracks for transport off site (ID: LOAD -01). The estimated total condensate production rate of 40 bbls/day and molecular weight data from the E&P TANKS 2.0 model were used in conjunction with the USEPA loadout equation to estimate VOC emissions from this source. Emissions of VOC from this source are estimated to be below the threshold limit of 2 tpy for APEN reporting. Therefore, the LOAD -01 condensate loadout source is an insignificant emission source that will not be included in the facility -wide permit. A condensate loadout calculation sheet is provided in Attachment3. Fugitive VOC from Leaking Equipment Potential fugitive VOC emissions from leaking equipment (ID: FUG -01) are estimated at 7.9 tpy VOC, using estimated equipment component counts, a representative inlet gas analysis from a compressor station in the same field, and US EPA Oil and Gas Roland Hca - CDPHE December 8, 2006 Page 5 Production Operations emission factors. A fugitive VOC emissions calculation sheet is provided in Attachment 3. Total Facility -Wide Potential Emissions Total facility -wide potential emissions for all sources included in the facility -wide permit and all sources that are exempt from permitting are 184.1 tpy NO„, 70.0 tpy CO, and 61.1 tpy VOC at Crawford Trail. Potential emissions of regulated non -criteria reportable pollutants (HAP) from the facility are estimated at 15.0 tpy aggregate, with formaldehyde being the highest single HAP emission at 6.3 tpy. An emissions spreadsheet is provided in Attachment 3. Compliance with National Ambient Air Quality Standards (NAAOS) Williams used the US EPA SCREEN3 model to demonstrate that the NO„ emissions from the six internal combustion engines at Crawford Trail will not result in a violation of the annual NAAQS for NO2 of 100 1.1g/m3. For this analysis, Williams conservatively assumed that both electrical generators run simultaneously, though in operation only one of the generators will run at any given time. The combined maximum annual ambient air NO2 concentration is estimated at 73.3 µg/m3 at the nearest property boundary approximately 150 feet from the primary compressor engine building. Adding an accepted background NO2 concentration of 7.5 µg/m3, provided by Doris Jung of the APCD, results in a total combined maximum ambient air concentration of 80.8 µg/m3. This value is below the annual NAAQS for NO2 of 100 µg/m3 and the proposed facility will not cause an off-site violation of the NAAQS. Copies of the NAAQS calculation sheet and SCREEN3 input and output report are provided in Attachment 5. We request that the Division invoice Williams for the APEN fees associated with this application. Williams has also attached a proposed Draft Permit for CDPHE review based on the emissions and conditions outlined in this application. If you have any questions related to this submittal, or if you require additional information please call me at the Williams Denver office at (303) 606-4366. Sincerely, Williams Production RMT Company Rick Matar Air Quality Practice Leader attachments ATTACHMENTS Attachment 1: Area Map, Facility Plot Plan, Process Flow and VRU Diagrams Attachment 2: Permit Application and Completed APENs Attachment 3: Emissions Inventory Spreadsheet and Supporting Calculation Sheets Attachment 4: Proposed CAM Plan for ENG-5/ENG-6 Attachment 5: SCREEN3 Modeling Summary Attachment 6: Sample Draft Permit for Crawford Trail Attachment 1 Area Map, Facility Plot Plan, Process Flow and VRU Diagrams TOp03 map pnnted 00 11/30/06 from 'COLORADO.1p0' and'Undded.tp9' 108116.000' W 10894.000' W 10892.000' W 10090.000' W 100°08.000' W WG584 108105.000' W 3Y31.000' N 39033:000' N 3r35.000' N ' &Ii\c. e` - 4ne-�_CryY1 Vr s ,�1 _' N.. -33 ��`''' -Gil — i - .C]I. fel tom/ ). 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R1` f r11�i r.„,,,,, �r b f 1 . / 1' r. � (r / ' ,l ,h} I fff Ir r a,.. .r ; , 49.. tits ''' 1 . .11 • I, ii I•Ti C} .'i" u. 1 10596 000' W 10094.000' W 108412.000' W 0990.000' W 108108.000' W WG584 108°05.000' W Ins GO 63 1t 13 0 33 34 3JWn \4pui,d 't with TOPOC `0a n: Nmend GemFli Iwavau vh,anphesom type. n CRAWFORD TRAIL COMPRESSOR STATION SITE LOCATION MAP 1i 18 7t,® eW S WILLIAMS PRODUCTION RMT COMPANY SW' '4 SE' '4 Section 23 T6S R97W November 2006 Garfield County, Colorado Facility-Wide Permit Application ;1 hems II I _-titYA.Min I Mo -a 'ILS ®IXf9-l� \ :try, 7,131 :tr.O'nnI mai Mir 1 4 • E 1 1; a Oo' oz a i kcos y N W FW ^404 Vezmoi tl a 1- z r d rc 0 1- ~m O jNVI 41-2m ,S0.8--10=,-. 1 -JN pm Qdk 0 QJKNS O Vf rip-- d 2 UWNN LIL1- V) N u W o > 4 a> Y • N N 0.4 N6 0 F isaReogezow s W 0 W • 8 0 d • z 52 2N 0 0 EC N 0}M W y W<ye K▪ gfU>-5OZJJd 0 G 6 eg 3:N c° 3$¢ is e 6 II 1 1 1 1 i !i 1 F r 1 1 1 mikev..4 T.6 C�LUMN 4 °3 le :1; 220 rfr?-0i41 Attachment 2 Completed Application for Construction Permit Completed APENs Air Pollution Control Division Construction Permit Application PLEASE READ INSTRUCTIONS ON REVERSE SIDE. 1. Permit to be issued to: 2. Mailing Address: 3. General Nature of Business: SIC code (if known) 4. Air Pollution Source Description: (List permit numbers if existing source, attach additional pages if needed) Williams Production RMT Company 1515 Arapahoe St., Tower 3, Suite 1000 Denver, Colorado 80202 Exploration and Production of Natural Gas 1311 Natural Gas Gathering and Compression N/A Is this a Portable Unit? No 5. Source Location Address (Include Location Map) If portable, include the initial location and home base location Crawford Trail Compressor Station SW ''4 of the SE'''4 of Section 23, Township 6 South, Range 97 West Garfield County, Colorado 6. Reason for Application: (Check all that apply) New or Previously Unreported Source Modification of Existing Source Request for Synthetic Minor Permit Other: Administrative Permit Amendments ❑ Transfer of Ownership (Complete Section 9 & 10 below) O Company Name Change (Complete Section 9 below) ❑ Other: 7. Projected Startup Date: July 2007 (Construction); October 2007 startup Y Signature of Legally Authorized Person of Company listed in Section I Rick Mater — Air Quality Practice Leader Type or Print Name and Official Title of Person Signing Above 8. Check appropriate box if you want: ❑ Copy of preliminary analysis conducted by Division ❑ To review a draft of the permit prior to issuance /2/a Slob Date Signed Phone: (303) 606-4366 Fax: (303) 629-8285 These sections are to be completed only if a company name change or transfer of ownership has occurred. 9. Permit previously issued to: 10. Transfer of Ownership Information Effective Date of Permit Transfer: As responsible party for the emission source(s) listed above, l certify that the business associated with this source has been sold, and agree to transfer the permit to said party. Signature of Legally Authorized Person of Company listed in Section 9 Type or Print Name and Official Title of Person Signing Above Date Signed Phone: Fax: Mail completed application, APENs, and filing fee to: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 http://www.cdphe.state.co.us/ap/stationaryase Phone: (303) 692-3150 Revised August 2004 O 0 N ., E 0 so E w ti a+ a 0 b 0 0 v L W 0. d w 9 0 z z 0 W 2: 1-4 1-1 a d u 0 0 O 0 0 0 Veel E NL- O • :$ Y Y 7> W E 0. w 0 O C a dz a•0 z'Y w Y E W d' w uested Action (Check Applicable Request Boxes) Section 02 — R Section 01 — Administrative Information 0. 0. 0 E 00 .0 s.0 y ▪ Y E N d • O a E a u to m E T u O. h m t •e m e 0 Y D K • u a W E E0 O 0, y > a° Y ID u a. O a "<"t" U O 00 U • 5 0 0 EL f a a ❑❑ 33 ❑ 0000 ❑ war Company Name: ' Williams Production RMT Company U TLC U 0 L3. Jr) 0 et taY 1T p a. ZIP Code: 80202 Mailing Address: 1515 Arapahoe Street, Tower 3, Suite 1000 Denver, Colorado 0 Z 303-629-8285 rick.matar®will lams.com Section 03 — General Information 3 0 8 0. Y E O F O 0 0 G ° S o O O L O °v O. 0 O e e E . t 6 d Q 9 0- O U M O t . 00 O Q N M - c n N rn • • N O\NL U b '0 m W H• et, M O n N. Y 000 o 3 >, J O U L O O 0 Z z z 00❑ N g bientairquality.pdf) O. 0 0 3 E a. e. Y o Y Y y e 0 E 00 o c p y O � • 9 w E ▪ u 0 O .O Z v• Y a ine Information Section 04 — En 0 z c N z° 8 0 0. 8 a a. 2 i g 0 'O vii n r r 'd N y pa (.§533 8 O O O a p o E .s C c o u Engine Function: F 6 .YY gm ✓ • a U f 0 O 000 A V3 z 0 Check box to left to request copy of draft permit prior to issu 0 O 0. tte: August 2006 tit CF 0 z 0 N r yre0 II 8 Yi 0 z. -.• t 0 0 .Ni °r •E" rr1 ei 00 VI 00 OD N Section 07 — Emission Control Information 0 04L E 0 action 06 — Fue OL° h eita isUr u, a r 0 0 `. L°u , •S 8 'L E Y '^ -18et L 8 .) e• .V u _e• 0. C 5.z $ E y � Z 3 a:« tit all x0----'- T., .c.,. 1040 Btu/SCF Seasonal %Fuel Use: 125 I Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov Annual:Fuel Consumption >I (gallons7norMMSCF/yr) ��, Acniai Reportedfors f A Requested Permit`,;: r..'.Caleadar Year• 5• ... ..Limit ...-:- x+:, I 202.1 MMSCF/yr I N4Tuel Use Rate n Pt. •Type, of Fuel 1(SCF/k 1fhr) i Burned r 23075 scf/hr Natural Gas n factor documentation to this t u N 0 m c 8 O dile Poilutant.Emfss'ioni lnventoiy '1; ' a': Actual, Cal itliii ear Emissions �Uncontro0ed`" .� Uncontmlled� =`Controlled" Em,ssion•Factor. .(Pounds/Year) � (Pounds/Year)` �i (yncvlud1 ti"")br 7 a 7 a 7 as 't r N 46 2775 Uz v1 n VI IA 0 00 co N P 0 N N goy C f... ;OA .... yep... G Z,' r Q Q Q Q 7.7 .9 1.r ° U 9O0 O o H t'1 n 4 g n r .. ,. E(C -.0Z.i: 'lam IAcetaldehyde o€ ii Q V 4./ Qi 0 .9 4. s. U �x. E 1- ° k� 0° lel Uz �. 7.7 1 ±g, •y .. -$Gp 'cc a V0 '4V' l:C r', f!- ' 6:: e,.e 'le. . ,.1, d° r.. 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R> z 5 a< U a a E o D o> o 8 m e°o >> E 8 ea e 0. a L L a •U 6 U O v v ffi a 5a w a a a0 a 0 I h h e Yf ®❑❑❑ ❑ z W 0 0 d rn u o g° E V E w u J ti E 0 Z z S a 0 o N ° U 0 SW 1/4 SE 1/4 of Sec. 23, T6S, R97W U a N Denver, Colorado 0 M Phone Number. 303-629-8285 1 z w Person To Contact: E-mail Address: The projected startup date is: 10 a S o N ° p 11 mpc•C n t� •o � a Vel M in tabu y 4,- wac cnr4en o -g v cuo 0 ii 5 'te em0 E C ° e o co 0 yyN OD ae' 0 U moon U 3 y [[ 9 0 p•^ b 0 p •• W ry L T "0 a a A z 3 e e U a 9 o ° °�a .tea y 5 u jt�� e� • sv m 0 T.y AU € „� N E L Q O ,� 0O N w v n> ti > —elm W �� cat E e a n U 3 tO co N 0 > d E w a `° 0 i0 g 'o °i.j 0 e E X4.3° b'H V g '-ig � r � SI o U N a 0 ,_ *¢ e p qya V�, O ° V m ,n u�•a w° °ttthc4 Y V 3 0 0 3 , °e d. • ti .526u 5a W tQ z • E i 5 V Q tg' is 0.¢ in FL Pd he.state.co.usi .0 3 r 0 0 0 Z z z ❑❑ 53 ®® ❑ v c'To 8 g « U 1- e� 3 yyU W 0 0 o. d Tr a — 0 4 fl s° 0 eco g 66 6 o .0 i F.S3 e � 1 ° W U et 0; r I) N o a ° 0 a oti e38u� • o�u ee� ° u.2 0 8' 0 b e. R o N c 3 0 r.5 s..4. a a g o 0 20 C 0 U c 'fi E • 2 0 o° C 0 0 0 T i 5 .0 w :: R W g 1 a a.a 6 0 e p a E E w z v E Section 04 — Eneine Information we 8 0 en ey 51- S3 a .. ° o z a ❑ - Q3 8 ®❑❑® to CV Q p.c o G' x •t E •5 ° e lg. yre 0 '�Sa 8 2 a F/3e° N ti z; 0. 0❑® V EE EE ❑®®❑g N N y o 6 5 N N co T a y Sm N 0 0 0 0 0 A 9 V g g g g '8) u E u i E w >... U �0 G 0 4 Engine Function: ctt 0 a Form Revision Date: August 2006 n for Construction Permit - Internal Combustion En IR POLLUTANT EMISSION NOTICE (APEN) & Applit Section 05 — Stack Information ig • a Q • .° i z z O in 3 W) e. g U 8 0 Width (inches) = ,Y: c s� •u N e 00 00 x N mz z Direction of Section 07 — Emission Control Information Section 06 — Fuel Co N 1 ff. T P 0 z. • U 0 1/1 E W i• Da Ea.: .t -6,123y s gm T4 vco w • • 11 1040 Btu/SCF 1 Seasonal %Fuel Use: 125 I Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov . w U5 a w,� a_ o as A. . S. 202.1 MMSCF/yr Actual Reported.for Calendar. Year Actual Calendar Year Emissions Type of Fuel:. It Barbed Natural Gas Fuer Use Rate '- (SCF/hr, gaUhr) 8 h N Or. M . •_.. ' Non -Criteria Reportable PoilutantEmissions Inventory • .' • %Uncontrolled Emtuion-Factor'' (Inclirde•UnNs) , N < N a N a N a Actual Calendar Year Emissions yY oc U o 8 . ::-.. }a gel t - 540 I a: 2775 I 9} p �y l C•q 3a R 0 1757.5 p O .+ P O n .~.: ;G! -5. a a a .. 't a,• . cl. 9 r-- 107-02-8 N V a` 9 b8 ar Chemical Name, - 0 ars 'O WI Q • C .2 Q a c 0 N wu I Formaldehyde I • • Ciiteita Pollutant Emissions -Inventory, "' • :_ - k Requested Perm-itted Eiaissioas I p y C 0:i Va0t a M •e b v, M 8 . ::-.. }a gel t - a: O ,N a 0 8 N 1 0 ch1 o so L ,o` �. : Y I ,Actual Calendar Year:Emisilotis ' Controlled :I (Tons/Year) J ...?..i g14 5 Uncontrolled Emission'Factor (Include ` h -a o :•-I L .0 d Y, N I- d e .•• ar Z VO ,O O a G N no s 0 •oo 7.1 N C 0 ' N 0 Y V of N q °m A gfski O C 6 ? ta.:a e a°'"g Y e 0 •4 C •' o 9 aq FI Form Revision Date: August 2006 FA 1 0 1.g w '. 1.41 T O U °� E. 0 EJ H 0 0 i;j ct L. i N R" 0 « O 'm 0 Co) •'^d w° W a 0 0 0 O u 0 t ad z 3 4, n W U z z O cncn 0, z a 4 0 o ° > ^d C4iee 1 uested Action (Check Applicable Request Boxes) Section 02 — Re trative Information '0 -4 0 8 O 6 O 1- a ll 3 a b O i v .0 T 1 a O 7 0 K S R 'y .. O 0 0) .0 a C F o u o O a W a n V V W C 4p YO E u mg e m W O .o IC M N n Bi a U U [-- S: U V 0 IX 0 O a 0 m 6 v E- a U c L y rN K E O U F' o L L. o .o 0 n a °0 a to O 0 $ -11 a oa u D O A a a Z Y dLi $ m uM W 0 U U Y 0 0O 0 " •Q"a" z ❑ ❑ a z ❑ ❑ 41 ®❑®❑ ❑ z SIC Code: 1311 E 8 o w U E as E 0 0 0 o M` co atv 0 z z " o a o G E O U In SW 1/4 SE 1/4 of Sec. 23, T6S, ZIP Code: 80202 Mailing Address: Denver, Colorado 303-606-4366 303-629-8285 a E 0 z u IS 0 a Section 03 — General Information 0 N ro I •O o. 0 For New or Reconstructed Sources: C 3 a 0 Sg M Y 3 ,L n 0t oo< -5A„Um V 0 �O VC o O w O U CR O a o 0. a�, L = c 0. a0 v 0 0 0 z z z ❑ El 0 a r ® ® ❑ c 0. .0 0- N O. 6. oa ( I II in a 6 ei 8e 2" 'd U L ^I w g SIn U ,,, 8 La G Y O C o e r 0'a t 2a 0err es o 1 0 0 K 0 .". L o d o s ° ao° u a,3 a •• e a pp Op C" N a a O 0 g A L lC D .. a“ E 0 n 8 e L 1 U U a Y 8 X0 A. 0 O o 0 y g W L 9 g Y e E t U o C 0 o 0 0 0`L 0 a o 4) o v C .L e . 0 L V Vp - pp? 0 4r O .'C V e V u 0 g E re m 0 E y a w W 8 c ,o ^a " E is. zCS 0 0 t E Section 04 — EnEine Int - 4, C C W • O u w Engine Function: 8 -4 04 8 rl .c m b sor ❑® $ z U 0 a V t 3 u 0 A 6 0 O x 0 0. o° 1 0 0 O .100 O g E 5 0 0 w° .5 0 00 it 0 cte 4.4 E O V L b 0 W 0 IR POLLUTANT EMISSION NOTICE (APEN) & Applie Section 05 — Stack Information in et. W Z .� ea n n .art •r • r. • z>,.Y. 3 N 0<'i 00— co 00 N o11 os.-, u A t 6 3 tl ❑I O E O '8 u 0 pctl LJ E U ❑C E o c -a -.5.. W o 0 I N O N S ❑ = o ❑ a Ii7 N coc 13. U ▪ II O z L G u �a > Q ID ® O v N 1 y A 06 M9 c 6 O ,E. .2o m Q UJ tlet (check Section 06 — F 0 0 Q h k n a 0 z 8c L to c U. 0 00 0 1040 Btu/SCF 1 Seasonal % Fuel Use: 125 I Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov a0:6a zb oi C.. N v Annual Fuel -Consumption ` ?I • (gallons/yr °r MMSCF4i-). I 202.1 MMSCF/yr Y t3 a m Actual' Reported for • • • Calender Year. 4 O r .Actual Calendar Year :Emissions 4 U µ0. •g. o Ep la m le m ,. a s5 . 23075 scf/hr 8 �,. LL �YA O 73 E O 0 W 0 .112 O 0 ea E 0 lations and e g c 0 U ' ^ Non+Criteria Reportable Pollutant Emitsions Inventory. e W C .'e4_=, .; O cV >8 .h c,.. - N v N v N v N q O �• m V a V 9 V t,pp.9 e; Y Coht 6llcd- a m I 540 I 4 2775 I .Actual Calendar Year :Emissions •. 751 Q'- .0 7 .0 . V w O P 11100 I e} - .rc v cm: a a < < 1.0 g/hp-hr .# • ," ,,,. , V o r- 4 °I? k.-4 o N en n 0 .o. d •iq u Y, .E z'' U I IAcetaldehyde ° 4 a € m I Formaldehyde I Criteria Pollutant Emissions Inventory ' ' ' " Litoquested Permitted Emissions. ' • Controlled: I • (Tons/Year) a 6.0 3.4 IThe Calendar Year foF which?Actual: Fuel Consin iption anctEmis'siomData Applies=i5:. 9 0 CN u O 5 M I 85.7 O O .Actual Calendar Year :Emissions f2 1 go U a - e} - .rc • :Uncontrolled _ Emission Factor'. (Include Volts) 1.0 g/hp-hr 2.5 g/hp-hr at a et .4 ."q. x x rtifica of • •I Section 0 N 0. Form Revision Date: August 2006 ou 0 u vo d° ^ O . y U .d L E > wWw 17 g u N a 0. o oe >. N a 5 • •(12 F z y co t w 0 0 'z E - z'ce A.4ra o 9 0 a 1 noa 1 .•q o O x 1 uested Action (Check Applicable Request Boxes) tion 02—Re for New Permit or Newly Reported Emission Source Request Alternative Operating Scenario (AOS) Request Modification to Existing Permit (Check each box below applies) 0000 13 z pc U SW 1/4 SE 1/4 of Sec. 23, T6S, R97W W T a 5 F o ,e uen Oa 0 0a a5 l U L z c 0 o. a N E o ri w a. @ .] g L u at b w 2 F m Tito O '" b U F e .� d 8 E ❑ ❑ r o a U } 3 v U 10 T v F = OU 6 . up O °' 2 .4 ya 1 O }ul a [zd 0 u $ O Y 0. m $ o a W it aa ❑ ❑ co ❑ ❑ = ❑ z' Change Fuel or Equipment Change Permit Limit 8 co o to E L a 0ea ai 0 a N Denver, Colorado 3 3034294285 Person To Contact: E-mail Address: Section 03 — General Information 0 N .r 0 v f 1 a CP u E G 0- o c .N l �o 5 e a ° =U • C -5 _ 8a ea. a.0 co .=u3 b- is Lo CC c c0 •tt in u2 "d, u M i o M ^C. € pe .05- 5 N M 5 N 0 H N 9 t0.1 d O vs.,- 00 _O k c E c M MM G C co'5g a5 € 3 c01 a c .8 a s �i co 3 c cu; n� v 1 ' 4.5 0 .0 o ° b 5 E o 0 w 6� z y "3 O W 0 p a d .,5"j}+ 0 m' y E S o w?°'z'� 3O G'° E 6SCC s s 79 z 6 u ' E Yy i o p H p w q O t O .L o a w .0 » g e 0 0• p4 V 00 ° 0 II •en ° A ° 4. y� c v u . O V O 0 0_ :p y -1,, E E 15 a, 4.. RCAi � a 8o W � ;�cal �f z z z 0 0 } } C w 01 _ 8 8 et 5 i g B 64C o. o 0 0 X m .0 0 o $; e m b 1 E'E $ 0 F 5 cu 0 T 8 5 O 0 2 _ 2 0 0 I ..4. 5 'J' om C _ a 5 ,°c igw E 0 0 ❑ F E s g g u o E sp C 'L 5 m 0 c < W w 0 Form Revis' -late: August 2006 d E 0 y' Pert oa a a 0 110•� IR POLLUTANT EMISSION NOTICE (APEN) & Applii r N 3 fel (4 4 r N 00 (1 3 W Section 07 — Emission Control Information 0 co) 4� "LC • • O • •.U, SEC ✓6• „s. wk 0 In r af�1 fi fit jQls", :5. 0 N 0 O •0 2 0 O is 0 V 44 O os N w 0 V O A .i•_If �f . 0 2. ' ,2:m;C) 'a'c. EwC"(p G:F1.07 'c w 1040 Btu/SCF Seasonal %Fuel Use: 125 I Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov kms-` ?ti• • 4,CArinua1•Eue1;Consumibn;S pt- 1".":.'; ,.,f. ....(gallbn's/ycu[SIMSCFlyfT •a: `-'•,.,_' ggg _I 202.1 MMSCF/yr A k• V 9 a L. 1't r< • 9 • u; ,L. r m 23075 sc(/hr Natural Gas Vi y [r i riti 1p. 2 1 p it..W 4,16'43 0 ,.e Iii O Brr 2 m.d.7a ,'i m IC W. ,o 'Z -' a a a a ,ix#.iq Ft A. o C,V 7,,,p BjYa x$ 43 0'8 1.y 879 R C 2775 yqqy $_. -o- ") t-1 = O H T "" °°z's au,5i.m d Q Q Q ' t' :1 + IQ,:,:.N •'i1 4744 421'1.,-U'i I' 107-02-8 V r o irl ir:5,t tq Y, 0 � F U t S u C Fi 0 g F •Op 41; fps ,O• "7 n 0 a ri v•^ y _OA-- a;C A 000 e d W .n Q W' :0' al o: 'O 4.0 *9: 6 'U ..4. Q '.310 z (. .0 W U 1 .4 • O v .5 O W 0 a ot i T ao o U a Ts o E `I§ :. C O 1as N e1 w 0 o p uvC o.0 N d .w O y 0 U E v p > L 00 L. W P. O Oi . CO 0 a < 0 0 z 0 w 0 42 2 en rW' .- I)) 1 Fi vo 0 az zz 7) 0 C W g 1 az F g a Z 0 a a d uested Action (Check Applicable Request Boxes) Section 02 — Re Section 01— Administrative Information ' 0? a O 0. 0. 3 E 0. > 9 d o o s °-- •8 o6 .0 >. g a o :7 . O O • •F - a 4 u ° e.O - lu 0 u V o Ch •( . g v w30 in u Cg o N aO t H 1 < u 1-°^6a t '� & 'C E El ❑ o °' o ' p( 0 u x u :5 .C, to .44 6E m G C v 9 O p 6 y, W O W z t� O i6 y • E O.. - n, O. C e _ 4.0 A> c m Y rg o zL ae. f., p„ z 0 v. 7 to ` .°. 8 00 W 0. G 0 C 0 ... 0.. o f a 'ET)o m a 'S da 0 0 0 0 U V V a D K F l a z a ❑ 0 z 0❑ V 0000 0 z° SIC Code: 1311 in 6 0 e Oa 0 5V vi.. 0a: a o` E 0 U a F o FE 0 ki d z z g s 6 0 8 ON 0 U .n SW 114 SE 1/4 of Sec. 23, T6S, R97W m°S 0 0. ZIP Code: 80202 Denver, Colorado 303-606-4366 303-629-8285 Z0 z 0 LL a Section 03 — General Information 0 42 9 43 t a d z Iz Y E O o el .0 •S a v C 6, e5 a e5 0.. o F ie Ea 0. 0 0 U 2 0 0 O epa '6O oo cd L uC R h a r F Y R M C .g• 5 pp M N M 0 la $ w 8 to.: n Y a1 8 0 000 ❑ .y E e 0 n "n C a . C .0 co 0 gn o> -. 0 W Xia 38 a* 14 z Q c 7 c dl cca =2B 0 §•u.g o w0S 5 0 o— '- .% 0 a 2 ,p t > ua oa y g •s u 3 ,, to 18 t .5 `0 > 0 q a o 4 .,? 8.5 '�a G� 0'e 3 9 C U C E 4.3 O C n 0 n �2o €gravc0i8Sc 3€o W 4 C p Ij N v `� N-1 gO L.o 'L g� a L Ti. •y .a u .m .a. O u a 0. e .5 2 u a & z. 4 O, F a a 0 0 0 Z z z ❑❑ 0 ®® ❑ E 0 Y i 0. 8 3 c i N O O 0 O ^y N CC O . 4 Im I,.0 1 U & g c N C• V 8- b 0o .._ M >• — S $ b o i o y' Yi.x $13 �p .e • on O .L... O .? 0 1 G C s e Ti 8 2s E ti .. r ` °Y48 p% e 0 o; O 0 x 0 9 13 0 ta po e 0. es c 11 G E. D .... ; ... V O$ a o E° E '. 0 C .°- O y. . $ y 4. a ie =, E U .Ei y 7 pg * o 0 0 0= 5 0r t- 'ita 00 0 W in : 9 L. inn in in E O 4 Eeg u tJ .t• OR O ,. . a e a - E 1=°.zcia33<m ❑ ❑ ti t E a z aoa .0.5.❑ -8 ,a C A fr C . E E = a 0 0❑ u C en 1L a z° Engine Function: CN 0. s 0 kee Q8 §. 0 c E o = a ' U U E E co Y Y N 0 Y o n 2 2 w t 5 ❑ AC U 6. m U C m R L .0 E CO 43 4 C U F 0 ®0 ❑ 0 n o 5 g0 m aV W.C .00 WWp N J z 5 E'. E DDD. E ki o ' 2 �E u g ' 7 'O U N O .D 0 E 55 N U Li p. u U a 1 C8 0 O a 6 a 0 8 0 6 0 0 w -mate: August 2006 IR POLLUTANT EMISSION NOTICE (APEN) & Applin Section 05 — Stack Information 0 t- h 3 t --' 4j 'N N' yuy L. 55 • • • v I t O 0 G L O e ❑ I 0 C E u '� s O I all 0 L O CO ❑ O 0 n y W O • O 0 ❑ 0 ❑ u h 7 "1 •It • 00 N ion Information Section 06 — Fuel Consum ,rte o. '•• I in h z r ❑e u aW r0 } '0 «1- u 0 a 0 'O 0 V 0 0 C 4 0 0 0 0 0 0 0 n n Fuel Heating Value .(indicate amts, ;r Bti✓Ib, Btu!gal;... Btu/SCF 1040 BtuJSCF Seasonal % Fuel Use: 125 I Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov Annual. Fuel Commit' peon (gallons/yrorMMSCF/yr) . • Requested'Permit , lumit '' 66.65 MMSCF/yr Actual ftepurted for' • Calendar Year I;=Aetudl'Clleadai Yeas Embsions •I Type:qf: Fuel' Bumed' • V 2 z Fad Use•Raie- @ 100% toad (SCF/hr, gaVhr)' t i O 00 O 0 0 0 O E ro co 0 to 0 y ib E n n E trl W 145 O a Y c_ .o0•i al Z :-8-g G krgC 0 Y •.pC'•.0 Fe V •. .' � N as N a H a N a s I;=Aetudl'Clleadai Yeas Embsions •I . O S T ' N r Uncontrolled (Pounds/Year) 193.4 V m ,-• V $ e - am, 6 a a 6 V ' .V' • a I 75-07-0 107-02-8 71-43-2 1 vi Is r h a O O. Y ' ,.4z V Acetaldehyde C Y 1 QQ n QCO I Formaldehyde I C j 4 • • pp 4 ea '0 —O_•S P- 9 V... C p- ,n IG W "E. 6 t � v 0. s 65 g o. o V't 19 20.34 1 T., 'g70 r 91.5 5.08 y .9 O' lin 4Y. >!:'... 0 V0' w p U -.a 0. .<' U• 3 o: J- r...11 Ft. E. ... • .74.Uncontrolled ;`Emission Factor L'Onelude Units) 19.9 g/hp-hr Is r h a O O. I 0.5 g/hp-br , Z OV > z a0 2 X O 0 0 E W a. F 0 C O 0 0 4 £ . 0 U o O o � U a 2 2 a0 U O z .12Y '0 0 CA a O 1 9 A W c ° O b 8. 7 r 12_ E 0 a V d y N 00 0 'y 1 a 'e C. G 0 o u w u . 0 N C H O U :'d 2- E> 10 W a`. 0 a S 0. o - 4 ¢ 04 T d W 0 0, m d 'O W 0 °z A o Q vJ F m W N d b z .gg z as a a v Section 02 — Requested Action (Check Applicable Request Boxes) Section 01 — Administrative Information 4) 0 N E 612 '2 ay u Z y e t a co 3 11 y a 1.1z st F d P O' CAy a0 ®❑❑❑ r) 8 0 z z 0 AGO 0 is V e o. O e = EO � 3ci z z TCp c 6. OC O 0 0 0 t V 0 a Ir) Change Fuel or Equipment Change Permit Limit g 0 COu 5 0 00 0 U N Denver, Colorado 2 a e Phone Number: E-mail Address: Section 03 — General Information r0 N The projected startup date is: 10 For New or Reconstructed Sources: 42 wo Oa 00 OC 2. y U 00 T VS 9 S U ry aenn 0 6« O 0 'g - � a� =3 c° ea ? C V P y o o • d a, r., E e°5 v0—� JL y s a r I? iJ CO yy°a oa iii E q2. °� et 2 0 y C .- y LP. a« .5 a to E pQ g 9 Ch u c E • 4 o a 41 .0 G t y e O V N V m o G € V 'w T N G E O ib!! 4 y O G U LO 4) 0u]=U 'O a9 a9 c '�'X .i0. C V d '- oaa eca rn „445. py 0 — O V g p V �T N 0 0 0 0. V E V d.QO a. Qv) A .c 0 g O 2 L O t E .. 00 Wa o E o —0, z . 0 0. 0. gaga 0 z Z Z ❑❑ r >- 0 0 00 0 'O 6 2 :n I. is i e y U u O. - C• V u el O • O 0 $ r. O at8 E a 0a $ Q mDo o 2 8 e i-3. � .. o° --A0 C a o ° ° 0 u e0 w ti « 0 W4 O C 01 o `G $ 0 O .c W° E 3 8 U u 50i'i V E L G 3 O $ a ° E SGj 0 '8 u ti g0 y L G E G 'G .0 .0 0 0.o hNC 410 lab ea O O t O G G T s_n y y�E e 0 N p� If E G M �! co ch w E y E h.0 0 0.- as E c- Z 0 0 3 ? e Information Section 04 — En z C rn Engine Function: 0 0 CSIA. 0. 01 CO 4 N 3 'g ® ® ❑ ® n E i 0 z• y n 0 0 _ E CC H m Y @ to E u ❑❑®❑. b f0 5 P u F 8 y 1 o C - C7 P. m (.- O c cn ° cR O 0 U ..0 .2 s E n '60 u E S 2 w 0 0 —a < w a o. ue: August 2006 zZ O Imt 3 a .N. N 4 d 00 ,:;it;;;„1. .420. oi �b0 N 0 w Section 07 — Emission Control Information tion Informati Section 06 - Fuel Consum 0 .AU• F Ip fv \ }FE• i `�H �U S 'd.& jt 0a; 1/4 501 N e h ,F0% 'U)) a:• IY. n L) z h 1. • x O 0 a t 5p00 0 0.= u O .. <Q u u 5 s E 0 3 g O a T o 3 _ kutil RFuel co.ti npnon Fuel Heatutg Value',; y (gations/yrorMMSCF/yr),. :-.(Indicateumts^- " Actual Roported for RegiiestediPeaiti a' 'Blu/Ib, Btu/gal .._Caleadar.Yeir' _..,..-... Limit -1 7;1.71:: Btii/SCF) r .. 66.65 MMSCF/yr I 1040 Btu/SCF I Seasonal % Fuel Use: 125 I Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 0 ' „• o u20 L Cm ,-..'t k': -g 0 Z 2 hi 0 ICs. N a 0 0 E 0 s and emission factor d r 0 0 0 4 kN� 4 qN Q qN 4 N �Actual;Glendar Year Eridsvons?; r Uncontrolled, ;?:Controlladt ;; li,(PairidsOrith301 a(Pounds/Ywr)n rp N a coO. Idfr I 710.5 v a v CNO '0 $v .. N d ¢ ¢ d Vair.,4 } Z ,r. 4 n c 9 ? N q r 4 io n App S . (4-0 Ai '.3 ; ' Lt.ff. 0 a t = i. k Formaldehyde I ?.r o,, 'p. 0 0 ' I 40 C d. o:5 3030 k. a z e. 0 Y .0 0 9.. Y0 y P4 FC ;1 Bi '0l a3 Ai Form Revision Date: August 2006 0 O 00 NN 0 0 U N b b M e 0 0 Practice Leader U 0 0 z 0 0136 �00 z 2 1 2 Z N N 0 N t.' IT N 0 z° g Z �z 4 VJ `-' O z N 6 �n N N 0 0 W 1 3TT ro Dehydrated Field Gas 68! ♦ +» 2 csig IE 13 1 2 4. g z 0 z g 0 1 o a W Fq 9 0 d V1 14. z z a z z m 1 A U 1 A A 1 1 o. p� a 6 0 x 8 0 0 y �S 1 A. 0 95 o'0 o° C U ° O pppo U6a0 0 7 8 V ww 5 00 O .az T 4My Ia. wu al w 8 wo E z U 0 z �O//�� z r/J e cel 0-1 1-42 Act, Pr4 t A a a ; d . AtC E �3 W z W � O op N co eAb 0 M w 0. N -01 303-606-4366 0 N zQ 0 0 U S 6 0 a a w Requested Emissions (lbs/yr) 1723 1872 442 GRI GLYCaIc GRI GLYCaIc GRI GLYCa1c i u .8 5 01 M { N C) i - Control Equipment/ Efficiency et e in T ON AAA ro < U U Chemical Name cn H k Chemical Abstract Service Number 71-43-2 108883 1330207 AIRSID.: N/A PERMIT No.: Pending CO 0 0 k 0 « rn \rn0 Practice Leader $ § Cnuao2 � H = . 020o 2 \\°§0z 4.1 e�\§§[ H ¥aa, /)tE®\\\ §ƒH ( C4 0 4- *1f-\ 0§E- 2O\ -2k§ P-4 <§©2°@ z0 ,P.2 — //#fl §)2 k m 2 0. 0 ADDITIONAL INFORMATION OR REMARKS: 90MMscf/day TEG with condenser; Still Vent and Flash Tank Emissions captured by Vapor Recovery Unit with 5% downtime of VRU B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Plant ID No. For Slack II DERV -2 0 l.: i� CHECK ALL BOXES THAT APPLY x New or previously unreported source` Requesting modification of existing permit t Change in emissions, throughputs or equipment t Tranifer of ownership (Liu previous owner in REMARKS section of box A.) t Previous APEN is expiring I Request for Emission Reduction Credit t t (Specify) ° Complete all applicable portions of APEN 1 Complete `Requested Level' values for permit limits • t Complete all information above box A, and those remaining portion which reflect changes IIDATE YEAR FOR WHICH THE ACTUAL DATA APPLIESJH Typed Name and Title: Rick Maur, Air Quality Practice Leader 'Date source began or will begin operation: _ Apri1200R Colorado Dept of Public Health & Environment APEN # 2 of 2 Aur Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 For Information, Call Denver, Colorado 50246-1530 '93) 692-3150 $� a. % 7 T- 4 ) ƒ 9 tri 0� #! Percent by Weight 1 Season 111 el' Finished Product Description Dehydrated Field Gas z CHECK HERE IF YOU WISH TIIE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. Design Process Rate (Specify Units/Hour) 90 MMscf/day 00) p' \ Process Seasonal Throughput (% of Annual) . ° | Fuel Heatb (BTU/Ib. IT BTU/ tgnature of Person Legally Authorized to Supply Data � IAnnual Fuel Consumption _T Q. <! Y. Raw Materials -Annual Consumption \ /!! SOA ƒ 1 / !" ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE UNCONTROLLED NA NA I VN I - . - 4,z «7! ! 8`0 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be Bled prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Pan A, • ILC.1. Flow Rate N/A ACFM _ }k CONTROLLED NA NA NA J # )\ Dacri,tan Field Gas ;1 z Normal Operation of This Source I. Hours/Day Days/Week Weeks/Year 24 7 52 Design Input Rate (106 BTU/to 2k A PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. a Diameter I Temperature N/A ft N/A °F Serial No. D. PROCESS INFORMATION Description of Processing Unit 90 MMscf/day TEC Dehydration Unit ) » C. FUEL INFORMATION Description of Combustion Unit 11 Make/Model: 6E. POLLUTION CONTROL EQUIPMENT Type of Control Equipment ¥ A. GENERAL INFORMATION \ Vapor Recovery Unit '6 § / ! 5ƒ!/)/ U F 0 z O C4 El „ c r 0.4 O e g WC Eno a W E-4 E U O AIRS Number N/A h ooN CO b O d U v' a N 0 303-606-4366 D 0 o n a williams.com .a •t F. g MNeI r- N Emission Factor Source GRI GLYCaIc GRI GLYCa]c GRI GLYCakc az M N en 0) N M V O 5 0.6.o 1 g W g V e e ONcnth A A A to • /m ce < U U 6 Benzene Toluene Xylenes 8 a 1Nl VgZ a r W DD v O n 1330207 § ) 2 f ADDITIONAL INFORMATION OR REMARKS: Plant ID No. for Stack HTR -1 Finished Product -Annual Output f\ CHECK ALL BOXES THAT APPLY x New or previously unreported source" Requesting modification of existing permit t t Change in emissions, throughputs or equipment i Transfer of ownership (List previous owner in REMARKS section of box A.) t Previous APEN is expiring L Request for Emission Reduction Credit t t (Specify) * Complete all applicable portions of APEN t Complete 'Requested Level' values for permit limits I Complete all information above box A, and those remaining portions which reflect changes YEAR FOR WHICH THE ACTUAL DATA APPLIES: I Date source began or will begin operation: October 2007 rol Division k Drive South, APCD-SS-B1 For Information, Call 80246-1530 (303) 692-31 } we. ; �\ _ } }in 2, \ \& / }I& | ƒ % n ,« }!.41 A ti ai ypcd Name and Title: • Rick Malar, Air Quality Practice leader - CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. Jh ` 2 # ?*9 �� Fuel Heating Value: (BTU/Ib, BTU/gal, BTU/scf) 1040 Btu/scf ch) ® If /} A SI19.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more, refer to attached sketch of plant layout) Height Diameter Temperature Flow Rate Velocity Moisture 20.0 f 2.0 R 500 °F • 3,770 ACFM 1,200 ft/min NA % Signature of Person Legally Authorized to Supply Data L IC— v. , Actual level (Data year level) ' ire7 \)$ u- 7 E `©£ Q - ESTIMATED . .. ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE _ UNCONTROLLED 0,48 Negl 5.31 . Requested level 126.3 MMscf/yr 7< ƒ) ! § f .6 __ IS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be tiled prior to this :Oration date, whenever s permit limitation must be modified, whenever control equipment is anged, and annually whenever a significant emission change occurs For specific details see egutation 3, Part A, • H.C.I. CONTROLLED NA NA NA I NA NA \� Z' C2i Raw Materials Used ! ) a) ) % - z Hours/Day Days/Week 24 7 Overall Collection Efficiency PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. i-. D. PROCESS INFORMATION Description of Processing Unit z ) 6 ! C. FUEL INFORMATION Description ofComMsstiori Unit Natural Gas -Fined Process Heater 15.0 MMBtu/hr Make/Model: NA k. POLLUTION CONTROL EQUIPMENT Type of Control Equipment 1 ! I A. GENERAL INFORMATION | 2 .2§® 4166\ |/#()e H E U 0 a 303 629-8285 k v W O. N T 303-606-4366 rick.matar@williams.com T Emission Factor fl Requested Emissions T Actual Emissions from the 0 Source R A s a Emission Factor (include units) Control Equipment/ Efficiency "al Chemical Name ALL BELOW DE MINIMIS 11 Chemical Ab.,hst Service Number 0 V O 0 PERMIT No.: Pending 0 00 u » F-• (3031-606-4366 0 a. ADDITIONAL INFORMATION OR REMARKS: Space Htg (% Ann.) uct I Finished Product -Annual Output II > §; CHECK ALL BOXES THAT APPLY X New or previously tmrcported source" Requesting modification of existing permit t * Change in emissions, throughputs or equipment Transfer of ownership (List previous owner in REMARKS section of box A.) t Previous APEN is expiring I Request for Emission Reduction Credit t t (Specify) • Complete all applicable portions of APEN t Complete `Requested Level' values for permit limits t Complete all inforrnation above box A, and those remaining portions which reflect changes YEAR FOR WHICH THE ACTUAL DATA APPLIES: Date source began or will begin operation: October 2007 rat Division c Drive South, APCD-SS-B1 For Information Call 80246-1530 (303)692-315 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Plant ID No. for Stack FUC-01 12 Seasonal Fuel Use (% of Annual Use) > \ ® `0 1 Requested level Finished Prod Description 60 \® \; } 0 \! ® |$ ! yped Name and Title: ---- Rick Matar, Air Quality Practice Leader f ) CHECK HERE W YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. 11 § ` Design Process Rate S • i Units/Hour) P P M< t $ 41 rIKIS NOTICE 15 VALID FOR FIVE YEARS. A revised notice shall be filed prior to this iA 5119.96 FILING FEE 15 REQUIRED expiration date, whenever a permit limitation must be modified, whenever control equipment Is OR EACH NOTICE FILED. changed, and annually whenever a significant emission change eeeors. For specific details see Regulation 3, Part A, • II.C.I. Send compla*ed forms with fees to: ' f r. 1 E7; , e. h) ! Fuel Heati (BTU BTU Irsignatore of Person Legally Authorized to Supply Data t - Annual Fuel Consumption _ |�\ Raw Materials -Annual Consumption ii~jp )� ® /z®` « ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE UNCONTROLLED NA NA NA Requested level ± {o ) ,z Flow Rate f NA ACFM l Kind of Fuel Burned CONTROLLED NA NA NA Raw Materials Used § 0 zzz } \ Hours/Day Days/Week Weeks/Year 24 7 52 C. FUEL INFORMATION - ,,,.Design Design htpm Rate (106 BTU/Ir) Description of Combustion Unit a } (PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. Diameter Temperable ft Ambient °F D. PROCESS INFORMATION Description of Processing Unit I Fugitive VOC from Equipment Leaks §§ k\ Z/l23(5)§a.,z E. POLLUTION CONTROL EQUIPMENT k/ } 1 A. GENERAL INFORMATION 1 0 0 0 _$` � 1 calW U H zz rA O `.r W z" Hi e as Ott av E-0 O b 5 44 g rri z E 8 e 0f -4 o 0 C 5 E z 0 o, 303-629-8285 303-606-4366 a 1' z 0 F 5 $ 30 0 my Is N C N W C V w V s 1 d 1 ALL BELOW DE MINIMIS II Chemical Abstract Service Number 1' z 0 F AIRS ID.: N/A a O z H 31-606-4366 E N 11 3 a 1/40 U 0 N 0 • C7 • 9 zs° 0 8 0 1 k g U b 0 Uv ogo • =x 0 . 4- U O z0 � h o O 14. z Y et E :114 0 Ge nY 8 1 8 S y d L CONDEN et N3 vi a° y O zO 8s.'22 4' IL s! a=_ v,• • b 0 °ie.-% k'a$U able Goat thrgig l�06� (oft m: Fma "ru1e •0 A z qA w U 0 z 0 w e a� a1. ag itc w as FHM 0 .5 a = U z0 AIRS Number N/A Permit Number 303-606-4366 0 � o y 0 g g�. d V b O 0 z° • gs a. o 0 a - -- 108 108 Lima rRpovyd Control Equipmrn✓ Efficiency e 0 •m z Q 1 V E az y Attachment 3 Emissions inventory Spreadsheet Supporting Calculation Sheets NOVEMBER 2006 - CRAWFORD TRAIL COMPRESSOR STATION CRAWFORD TRAIL COMPRESSOR STATION INLET GAS COMPOSITION Date of analysis: 8/24/06 Analysis ID 200608124 (from Clough Compressor Station) Pollutant Molecular Volume Gas Weight Corrected' Weight Percent Weight Fraction Wt. Fraction (lb/lb-mol) (%) (Ib/lbmol) (%) (%) Methane 16.01 86.64% 13.8715 72.49% 77.90% Ethane 30.02 6.71% 2.0131 10.52% 11.31% Total HC (Non-VOC) 93.35% 83.01% 89.21% Propane 44.03 2.04% 0.8995 4.70% 5.05% i -Butane 58.04 0.44% 0.2577 1.35% 1.45% n -Butane 58.04 0.42% 0.2449 1.28% 1.38% i -Pentane 72.05 0.18% 0.1311 0.69% 0.74% n -Pentane 72.05 0.13% 0.0908 0.47% 0.51% n -Hexane 86.06 0.08% 0.0654 0.34% 0.37% Other Hexanes 86.06 0.11% 0.0921 0.48% 0.52% Heptanes 100.07 0.06% 0.0580 0.30% 0.33% Octanes + 114.08 0.04% 0.0445 0.23% 0.25% Benzene 78.1 0.01% 0.0102 0.05% 0.06% Toluene 92.1 0.02% 0.0184 0.10% 0.10% Ethylbenzene 106.2 0.00% 0.0011 0.01% 0.01% Xylenes 106.2 0.01% 0.0085 0.04% 0.05% Total NMNE VOC 3.54% 10.04% 10.79% Carbon Dioxide 43.99 2.96% 1.3012 6.80% NA Nitrogen 28.02 0.I0% 0.0283 0.15% NA Hydrogen Sulfide 34.06 0.00% 0.0000 0.00% NA Water 18 0.00% 0.0000 0.00% NA Helium 4.00 0.01% 0.0002 0.00% NA Totals 100.0% 19.1366 100.00% 100.00% ' Weight Fraction corrected to remove Carbon Dioxide,Nitrogen, H2S, and Helium content. 11/24/2006 Crawford Trail Emissions Attachment 4 SCREEN3 Dispersion Modeling Summary Attachment 4 Proposed CAM Plan ENG-5/ENG-6 Williams Production RMT Company, Crawford Trail Compressor Station ENG-S/ENG-6 CAM Plan Submitted December 8, 2006 Compliance Assurance Monitoring Crawford Trail Compressor Station Williams Production RMT Company Emission Unit a) Facility: Crawford Trail Compressor Station b) Location: SW 'A SE'''A of Sec. 23, T6S, R97W in Garfield County c) Description: Two G3516 TA -l30 rich -bum engines w/NSCR and AFR d) Const. Permit Number: Pending Background The proposed Crawford Trail Compressor Station generator engines (IDs: ENG-5/ENG-6) meet the applicability requirements as described in 40 CFR 64 Compliance Assurance Monitoring (CAM). • Both units will be located at a proposed major source; • Both units are subject to emission limitations or standards for an applicable regulated air pollutant; • Both emission units will use an add-on control device to achieve compliance with an emission limit; and • Both emission units have a potential to emit without the control device of greater than 100 tons per year of NOx. The CAM regulation requires the following of an affected source: • Proposed indicators of performance relevant to compliance; • Indicator ranges or conditions, or the process by which such indicators will be established; • Performance criteria that satisfy 40 CFR 64.3(b); • Indicator ranges and perfomiance criteria. The regulation requires affected sources to monitor at least one indicator of performance for the control device. For these sources a minimum of one observation per 24 hours of the chosen parameter must be performed and recorded. Rationale of Selection of Performance Indicators The pressure drop across the catalyst will be monitored weekly. A AP exceeding limits in indicator range may indicate that the catalyst is becoming fouled. Temperature into the unit is measured because temperature excursions can indicate problems with engine operation and can retard the chemical reduction taking place in the catalyst bed. Williams Production RMT Company, Crawford Trail Compressor Station ENG-5/ENG-6 CAM Plan Submitted December 8, 2006 Monitoring Approach The key elements of the monitoring approach for NOx emissions, including the indicators to be monitored, indicator ranges and performance criteria are presented in Table 1 below. TABLE 1. Crawford Trail Rich -bunt Engine CAM Indicator No.1 Indicator No.2 Indicator No.3 I. Indicator Pressure drop across the catalyst Temperature of exhaust gas into catalyst Temperature of exhaust gas out of catalyst. Measurement Approach Differential pressure transmitter Thermal device Thermal device II. Indicator Range AP < 2" H2O from baseline. Excursions trigger corrective action. 750 °F < T < 1350 °F. Excursions trigger corrective action. INLET °F < T < 1350 °F. Excursions trigger corrective action. III. Performance Criteria A. Data Representativeness Standard accuracy to ±2% FS. Standard accuracy to 12% FS. Standard accuracy to +2% FS. B. Verification of Operational Status AP reading within indicated range. Temperature reading within indicated range. Temperature reading within indicated range. C. QA/QC Practice and And criteria. Calibration annually Calibration annually Calibration annually 11 Monitoring Frequency Weekly Daily Daily E. Data Collection Procedures Spot AP noted on Site Log Weekly. Spot Temperature noted on Site Log Daily Spot Temperature noted on Site Log Daily F. Averaging Period None None None Attachment 5 SCREEN3 Dispersion Modeling Summary DECEMBER 2006 - CRAWFORD TRAIL COMPRESSOR STATION Crawford Trail Compressor Station Modeled Source Inputs to Determine Compliance with the NO2 Annual National Ambient Air Quality Standard Emission Rate Engines 1-4 = NO2 Emissions from Engines ENG -0I -ENG -04 (w/SCO) 34.3 tpy NO, 1.0 g/bhp-hr 0.75 Per Section 4.1.1.3 Colorado Modeling Guidelines Colorado Default NO2/NO, _ Calculation of NO, Emission = tpy NO, * 2000 Ib/ton * 453.6 g/Ib * 1 yr/8760 hr * 1 hr/60 min * 1 min/60 sec * 0.75 NO2/NO, 0.99 g NO,/sec * 0.75 = 0.74 g NO2/sec Engine Stack Parameters stack height (11) = 28.0 = 8.53 meters stack diam(ft) = 1.50 = 0.46 meters velocity (ft/sec) = 221.3 = 67.44 meter/sec Temp. (deg F) = 858.0 458.9 deg. C = 732,0 deg K Building Dimensions height (ft) = 24.00 = 7.32 meters length (ft) = 220.00 = 67.06 meters width (ft) = 60.00 = 18.29 meters Distance to Nearest Property Boundary approximate distance (ft) = 150.0 = 46 meters Modeling Inputs no complex or simple terrain building downwash rural environment full meteorology automatic distance array of 10 to 1,000 meters zero terrain height above stack base Modeling Results max. 1 -hr concentration/engine is 119.2 ug/m3 NO2 at 65 meters max. 1 -hr fenceline conc./engine is 119.0 ug/m3 NO2 at 46 meters - conversion of 1 -hr concentration to annual concentration 119.2 * conversion factor 0.08 (see pg. 4-16 of SCREEN2 Users Guide, Oct. 1992 version, EPA -454/R-92-019) - 119.2 * 0.08 = 9.54 ug/m3 NO2 annual average 12/4/2006 Crawford Trail Emissions.xls DECEMBER 2006 - CRAWFORD TRAIL COMPRESSOR STATION Crawford Trail Compressor Station Modeled Source Inputs to Determine Compliance with the NO2 Annual National Ambient Air Quality Standard NO2 Emissions from Engines ENG -05 and ENG -06 (w/SCO) Emission Rate CAT 3516TALE; ENG-5/ENG-6 = 15.3 tpy NO, ® 1.5 g/bhp-hr Colorado Default NO2/NO, = Calculation of NO, Emission 0.75 Per Section 4.1.1.3 Colorado Modeling Guidelines = tpy NO, * 2000 Ib/ton * 453.6 g/lb * 1 yr/8760 hr * 1 hr/60 min *1 min/60 sec * 0.75 NO2/NO, 0.44 g NO,/sec * 0.75 = 0.33 g NO2/sec Engine Stack Parameters stack height (ft) = stack diam(ft) = velocity (fUsec) _ Temp. (deg F) = Building Dimensions height (ft) _ length (ft) = width (ft) _ 20.00 60.00 30.00 Distance to Nearest Property Boundary approximate distance (ft) = 150.0 24.0 = 7.32 meters 1.00 = 0.30 meters 89.9 = 27.39 meter/sec 864.0 462.2 deg. C = Modeling Inputs no complex or simple terrain building downwash rural environment full meteorology automatic distance array of 10 to 1,000 meters zero terrain height above stack base 6.10 meters 18.29 meters 9.14 meters 46 meters 735.4 deg K Modeling Results max. l -hr concentration/engine is 168.5 ug/m3 NO2 at 37 meters max. 1 -hr fenceline concJengine is 165.0 ug/m3 NO2 at 46 meters - conversion of 1 -hr concentration to annual concentration 165.0 * conversion factor 0.08 (see pg. 4-16 of SCREEN2 Users Guide, Oct. 1992 version, EPA -454/R-92-019) 165.0 * 0.08 = 13.20 ug/m3 NO2 annual average 12/4/2006 Crawford Trail Endsslons.xls DECEMBER 2006 - CRAWFORD TRAIL COMPRESSOR STATION Crawford Trail Compressor Station Modeled Source Impacts to Verify Compliance with NO2•NAAQS Summary of Maximum Combined NOp Ambient Air Quality Impacts at the Property Boundary Emission Max. 1-Ilr Annual Ave. Source (ug/m3 NO2:(ug/m3 NO,) ENG -01 1)9.2 9.54 ENG -02 119.2 9.54 ENG -03 119.2 9.54 ENG -04 119.2 9.54 ENG -05 165.0 13.20 ENG -06 165.0 13.20 TOTAL 806.80 64.54 Background NA 7.50 Tot.+Bkgnd NA 72.04 Standard NA 100.00 12/4/2006 Crawford Trail Emisslons.xls 12/04/06 09:03:54 *** SCREEN3 MODEL RUN *** *** VERSION DATED 96043 *** Crawford Trail Compressor Station - ENG1-ENG4 SIMPLE TERRAIN INPUTS: SOURCE TYPE = POINT EMISSION RATE (G/S) _ .740000 STACK HEIGHT (M) = 8.5300 STK INSIDE DIAM (M) _ .4600 STK EXIT VELOCITY (M/S)= 67.4000 STK GAS EXIT TEMP (K) = 732.0000 AMBIENT AIR TEMP (K) = 293.0000 RECEPTOR HEIGHT (M) _ .0000 URBAN/RURAL OPTION = RURAL BUILDING HEIGHT (M) = 7.3200 MIN HORIZ BLDG DIM (M) = 18.3000 MAX HORIZ BLDG DIM (M) = 67.0600 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 20.969 M**4/S**3; MOM. FLUX = 96.190 M**4/S**2. *** FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA (M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH 10. .3177E-15 6 1.0 1.0 10000.0 76.54 8.18 8.17 NO 100. 99.97 4 15.0 15.0 4800.0 9.74 8.20 6.74 SS 200. 48.90 4 15.0 15.0 4800.0 12.18 15.56 10.43 SS 300. 28.21 4 15.0 15.0 4800.0 14.81 22.61 13.56 SS 400. 20.72 4 15.0 15.0 4800.0 15.54 29.45 16.66 58 500. 16.18 4 15.0 15.0 4800.0 15.54 36.15 19.63 SS 600. 14.19 4 10.0 10.0 3200.0 23.43 42.72 21.76 SS 700. 12.37 4 10.0 10.0 3200.0 23.43 49.19 24.57 SS 800. 10.75 4 8.0 8.0 2560.0 29.58 55.57 26.84 SS 900. 9.756 4 8.0 8.0 2560.0 29.58 61.88 29.52. SS 1000. 8.806 4 8.0 8.0 2560.0 29.58 68.13 32.09 SS MAXIMUM 1 -HR CONCENTRATION AT OR BEYOND 10. M: 65. 119.2 4 15.0 15.0 4800.0 9.10 5.58 5.24 SS DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB ********************************* *** SCREEN DISCRETE DISTANCES *** ********************************* *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST (M) CONC (UG/M**3) U10M USTK MIX HT PLUME SIGMA SIGMA STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH 46. 119.0 4 20.0 20.0 6400.0 8.71 3.99 4.80 SS DWASH= MEANS DWASH=NO MEANS DWASH=HS MEANS DWASH=SS MEANS DWASH=NA MEANS NO CALC MADE (CONC = 0.0) NO BUILDING DOWNWASH USED HUBER-SNYDER DOWNWASH USED SCHULMAN-SCIRE DOWNWASH USED DOWNWASH NOT APPLICABLE, X<3*LB **************************************** *** REGULATORY (Default) *** PERFORMING CAVITY CALCULATIONS WITH ORIGINAL SCREEN CAVITY MODEL (ERODE, 1988) **************************************** *** CAVITY CALCULATION CONC (UG/M**3) _ CRIT WS 3108 (M/S) CRIT WS 0 HS (M/S) DILUTION WS (M/S) CAVITY HT (M) CAVITY LENGTH (M) ALONGWIND DIM (M) - 1 .0000 99.99 99.99 99.99 7.77 35.67 18.30 * * * *** CAVITY CALCULATION CONC (UG/M**3) CRIT WS 0108 (M/S) CRIT WS 0 HS (M/S) DILUTION WS (M/S) CAVITY HT (M) CAVITY LENGTH (M) ALONGWIND DIM (M) - 2 *** .0000 99.99 99.99 99.99 7.32 19.71 67.06 CAVITY CONC NOT CALCULATED FOR CRIT WS > 20.0 M/S. CONC SET = 0.0 **************************************** END OF CAVITY CALCULATIONS **************************************** *************************************** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE MAX CONC DIST TO TERRAIN (UG/M**3) MAX (8) HT (M) SIMPLE TERRAIN 119.2 65. 0. *************************************************** ** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS ** *************************************************** 12/05/06 15:08:05 *** SCREENS MODEL RUN *** *** VERSION DATED 96043 *** Crawford Trail Generator Engines - ENG5/ENG6 SIMPLE TERRAIN INPUTS: SOURCE TYPE = POINT EMISSION RATE (G/S) _ .440000 STACK HEIGHT (M) = 7.3200 STK INSIDE DIAM (M) _ .3000 STK EXIT VELOCITY (M/S)= 27.3900 STK GAS EXIT TEMP (K) = 735.0000 AMBIENT AIR TEMP (K) = 293.0000 RECEPTOR HEIGHT (M) _ .0000 URBAN/RURAL OPTION = RURAL BUILDING HEIGHT (M) = 6.1000 MIN HORIZ BLDG DIM (M) = 9.1400 MAX HORIZ BLDG DIM (M) = 18.2900 THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED. BUOY. FLUX = 3.634 M**4/S**3; MOM. FLUX = 6.729 M**4/S**2. ***FULL METEOROLOGY *** ********************************** *** SCREEN AUTOMATED DISTANCES *** ********************************** *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA (M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH 10. .0000 1 1.0 1.0 320.0 63.71 4.68 3.63 NO 100. 135.2 4 8.0 8.0 2560.0 8.84 8.20 6.82 SS 200. 76.88 4 5.0 5.0 1600.0 12.97 15.56 9.87 SS 300. 57.93 4 5.0 5.0 1600.0 12.97 22.61 13.06 SS 400. 44.79 4 4.0 4.0 1280.0 16.09 29.45 15.86 SS 500. 36.46 4 3.5 3.5 1120.0 18.41 36.15 18.66 SS 600. 30.76 4 3.0 3.0 960.0 21.55 42.72 21.31 SS 700. 26.44 4 2.5 2.5 800.0 25.96 49.19 24.03 SS 800. 23.53 4 2.5 2.5 800.0 25.96 55.57 26.78 SS 900. 20.85 4 2.0 2.0 640.0 32.57 61.88 29.47 SS 1000. 19.14 4 2.0 2.0 640.0 32.57 68.13 32.09 SS MAXIMUM 1 -HR CONCENTRATION AT OR BEYOND 10. M: 37. 224.7 4 8.0 8.0 2560.0 7.58 3.34 4.05 SS DWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB ********************************* *** SCREEN DISCRETE DISTANCES *** ********************************* *** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES *** DIST CONC U1OM USTK MIX HT (M) (UG/M**3) STAB (M/S) (M/S) (M) 46. 220.0 4 8.0 8.0 2560.0 AWASH= MEANS NO CALC MADE (CONC = 0.0) DWASH=NO MEANS NO BUILDING DOWNWASH USED DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB **************************************** *** REGULATORY (Default) *** PERFORMING CAVITY CALCULATIONS WITH ORIGINAL SCREEN CAVITY MODEL (ERODE, 1988) **************************************** *** CAVITY CALCULATION CONC (UG/M**3) CRIT WS @l0M (M/S) CRIT WS @ HS (M/S) DILUTION WS (M/S) CAVITY HT (M) CAVITY LENGTH (M) ALONGWIND DIM (M) PLUME SIGMA SIGMA HT (M) Y (M) 2 (M) DWASH 7.69 3.99 4.44 SS 1 *** *** CAVITY CALCULATION - 2 *** .0000 CONC (UG/M**3) = .0000 99.99 CRIT WS @10M (M/S) = 99.99 99.99 CRIT WS @ HS (M/S) = 99.99 99.99 DILUTION WS (M/S) = 99.99 7.49 CAVITY HT (M) = 6.30 16.72 CAVITY LENGTH (M) = 11.64 9.14 ALONGWIND DIM (M) = 18.29 CAVITY CONC NOT CALCULATED FOR CRIT WS > 20.0 M/S. CONC SET = 0.0 **************************************** END OF CAVITY CALCULATIONS *************************************** **********************************x**** *** SUMMARY OF SCREEN MODEL RESULTS *** *************************************** CALCULATION PROCEDURE MAX CONC DIST TO TERRAIN (UG/M**3) MAX (M) HT (M) SIMPLE TERRAIN 224.7 37. 0. *************************************************** ** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS ** ************************************************.*** Attachment 6 Proposed Draft Permit Summary (electronic copy will be provided) Williams Production RMT Company Permit No: To Be Issued INITIAL APPROVAL PERMIT NO: DATE ISSUED: To be issued Colorado Department of Public Health and Environment Air Po' _ . _. . DRAFT PERMIT INITIAL APPROVAL ISSUED TO: Williams Production RMT Company THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural Gas pipeline booster compression and gas dehydration facility, known as the Crawford Trail Compressor Station, to be located in the SW % of the SE '4 of Section 23, Township 6 South, Range 97 West, approximately 6 miles northwest of Parachute in Garfield County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: This is a facility -wide permit covering all equipment and activities at this facility. Details of equipment and activities are given in Attachment A. THIS PERMIT 15 GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. EPA Method 9 shall measure opacity. (Reference: Regulation 1, Section II.A.1.8 4.) 2. This source is subject to the odor requirements of Regulation No. 2 (State only enforceable). 3. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Reg. 3, Part B, TILE.) (State only enforceable) 4. This source shall be limited to maximum consumption, processing and/or operational rates as listed in Attachment A and all other activities, operational rates and numbers of equipment as stated in the application. Monthly records of the actual operational rates and activities shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B,II.A.4) During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly limitation shall be required. Compliance with the yearly consumption and operational limns shall be determined on a rolling twelve (12) month total. By the end of each month a new Twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly consumption and operational rates and keep a compliance record on site or at a local field office with site responsibility, for Division review. 5. Facility -wide emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis): (Reference: Regulation 3, Part B, II.A.4). Point Sources Nitrogen Oxides. 184.1 tons per year, and Volatile Organic Compounds' 61.1 tons per year, and Carbon Monoxide. 70.0 tons per year, and Formaldehyde: 6.3 tons per year, and Fugitive Emissions Volatile Organic Compounds. 7.9 tons per year, and Monthly limits are based on a 31 -day month. Emissions from individual equipment and activities shall not exceed the limits specified in Attachment A. Records of actual emissions shall be maintained and made available for Division review upon request. 15.6 tons per month 5.2 tons per month 5.9 tons per month 1063 pounds per month 1343.5 pounds per month AIRS ID: To Be Issued 1 Williams Production RMT Company Permit No: To Be Issued INITIAL APPROVAL Colorado Department of Public Health and Environment DRAFT PERMIT During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly limitation shall be required. Compliance with the annual limits shall be determined on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site for Division review. 6. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Reg.3, Part A,II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non-criterla reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative - operating scenario and is Installing a permanent replacement engine. 7. Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. 8. This permit shall expire if the owner or operator of the source for which the permit was Issued: (1) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this initial approval permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen' months or more; (iii) does not complete construction within a reasonable time of the estimated completion date (See General Condition No. 6, Item 1). The Division may grant extensions of the deadline per Regulation No. 3, Part'B, III.F.4.b. (Reference: Regulation No. 3, Part 13.111.F.4) Natural Gas Internal Combustion Engines 9. Points 001, 002, 003, 004, 005 and 006: the serial numbers of the subject equipment shall be provided to the Division prior to Final Approval. (Reference: Regulation No. 3, Part B, III.E.) 10. The engines listed in Attachment A (AIRS ID: 001, 002, 003, 004, 005 and 006) may be replaced with other engines in accordance with the temporary engine replacement provision or with other engines of the same make and model In accordance with the permanent replacement provision of the Altemate Operating Scenario (AOS), Included in this permit as Attachment B. 11. Source compliance tests shall be conducted on compressor engines to measure the emission rate(s) for the pollutants listed below in order to show compliance with emission limits and to demonstrate the performance of the emission control devices. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. The protocol shall include manufacturer's analysis of emissions at engine maximum and minimum loads, at site-specific conditions. Engine operating parameters will be included in the analysis with emissions reported in parts per dry volume and grams per actual horsepower -hour (g/bhp-hr) or pounds per million BTU (Ib/MMBtu). No compliance test shall be conducted without prior approval from the Division. Any stack test conducted to show compliance with a monthly or annual emission limitation shall have AIRS ID: To Be Issued 2 Williams Production RMT Company Colorado Department of Public Health and Environment Permit No: To Be Issued INITIAL APPROVAL DRAFT the results projected up to the monthly or annual averaging time by multiplying the test regtdts�v,)t�ylowable number of operating hours for that averaging. lime (Ref: Regulation No. 3, Part B, Secti 1 I Nitrogen Oxides, Formaldehyde, Carbon Monoxide and Oxygen using EPA approved methods. If the engines operating as points 001, 002, 003, 004, 005 and 006 are of the same make and model, a compliance test shall be required for one of these units, and a thirty -minute test run may be performed for the other identical units. If the emissions from the shortened test on the second and subsequent units show that emissions are not more than 10% above the emissions of the unit that had a full test series performed on it, then the Division will consider the emissions from the second and subsequent units to be identical to the emissions from the first unit. A full set of three test runs must be completed on any unit whose shortened test shows that emissions are more than 10% of the unit undergoing the full test series. 12. Points 001, 002, 003 and 004: these engines shall be equipped with oxidizing catalysts capable of reducing uncontrolled emissions of volatile organic compounds by at least 93%, carbon monoxide by at least 93% and formaldehyde by at least 75%. Operating parameters of the control equipment shall be identified prior to final approval of this permit. The Identified operating parameters will replace the control efficiency requirement on the final permit. (Reference: Regulation No. 3, Part B, IV.E.) 13. Points 005 and 006: each generator engine shall be equipped with a 3 -way catalyst capable of reducing uncontrolled emissions of nitrogen oxides and carbon monoxide by at least 75%, volatile organic compounds by at least 50% and formaldehyde by at least 50%. Operating parameters of the control equipment shall be identified prior to final approval of this permit. The identified operating parameters will replace the control efficiency requirement on the final permit. (Reference: Regulation No. 3, Part B, IV.E.) By: By: Roland C. Hea, P.E. Unit Leader Blue Parish, P.E. Permit Engineer Permit History: Action Date Description Initial Approval This Issuance Installation of four natural gas compressor engines (AIRS ID: 001, 002, 003 and), one generator engine (ID: 005), one backup generator engine (ID: 006), two TEG dehys (AIRS ID: 007 and 008) and associated equipment. AIRS ID: To Be Issued 3 Williams Production RMT Company Colorado Department of Public Health and Environment Permit No: To Be Issued INITIAL APPROVAL DRAFT maximum and minimum loads, at site-specific conditions. Engine operating parameters i{LZJQrJy4ed In the analysis with emissions reported in parts per dry volume and grams per actual horsepo bhp -11r) or pounds per million BTU (Ib/MMBIu). No compliance test shall be conducted without prior approval from the Division. Any stack test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Ref: Regulation No. 3, Part 8, Section 111.0.3) Nitrogen Oxides, Formaldehyde, Carbon Monoxide and Oxygen using EPA approved methods. If the engines operating as points 001, 002, 003, 004, 005 and 006 are of the same make and model, a compliance test shall be required for one of these units, and a thirty -minute test run may be performed for the other Identical units. If the emissions from the shortened test on the second and subsequent units show that emissions are not more than 10% above the emissions of the unit that had a full test series performed on it, then the Division will consider the emissions from the second and subsequent units to be identical to the emissions from the first unit. A hill set of three test runs must be completed on any unit whose shortened test shows That emissions are more than 10% of the unit undergoing the full test series. 13. Points 001, 002, 003 and 004: these engines shall be equipped with oxidizing catalysts capable of reducing uncontrolled emissions of volatile organic compounds by at least 93%, carbon monoxide by at least 93% and formaldehyde by at least 75%. Operating parameters of the control equipment shall be identified prior to final approval of this permit. The identified operating parameters will replace the control efficiency requirement on the final permit. (Reference: Regulation No. 3, Part 8, IV.E.) 14. Points 005 and 006: each generator engine shall be equipped with a 3 -way catalyst capable of reducing uncontrolled emissions of nitrogen oxides by 90%, carbon monoxide by at least 75%, volatile organic compounds by at least 50% and formaldehyde by at least 50%. Operating parameters of the control equipment shall be identified prior to final approval of this permit. The Identified operating parameters will replace the control efficiency requirement on the final permit. (Reference: Regulation No. 3, Part B, IV.E.) 15. Points 005 and 006: each of these engines represents a potential major source, if left uncontrolled. As such, these units are subject to the requirements described in 40 CFR Part 64 Compliance Assurance Monitoring (CAM). These units must operate in compliance with a CAM plan submitted to the state for final approval, originally submitted with the construction permit application. By: By: Blue Parish, P.E. Permit Engineer • Roland C. Hea, P.E. Unit Leader Action Date Description Initial Approval This Issuance Installation of four natural gas compressor engines (AIRS ID: 001, 002, 003 and), one generator engine (ID: 005), one backup generator engine (ID: 006), two TEG dehys (AIRS ID: 007 and 008) and associated equipment. AIRS ID: To Be Issued 3 Williams Production RMT Company Permit No: To Be Issued INITIAL APPROVAL Notes to Permit Holder: Colorado Department of Public Health and Environment Air Po" _ . _ .. DRAFT PERMIT 1) The production or raw material processing limits and emission limits contained in this permit are based on the production/processing rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedence of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns. The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits slated in this permit as soon as possible, but no later than two (2) hours after the start of the next working day, followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission In the future. 3) The following facility -wide emissions of non -criteria reportable air pollutants are estimated based upon equipment and activity specifications as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds. This Information is listed on the Division's emission Inventory system. C.A.S. # SUBSTANCE EMISSIONS ILB/YR] 50-00-0 Formaldehyde 12,520.8 71-43-2 Benzene 3,904.7 75-07-0 Acetaldehyde 3,708.3 107-02-8 Acrolein 2,343.4 108-88-3 Toluene 4,214.2 1330-20-7 Xylenes 1,071.8 110-54-3 n -Hexane 2,094.9 4) The emission levels contained in this permit are based on the following emission factors: Compressor Engines (AIRS ID: 001, 002, 003 and 004): 63612LE TA -130 Lean Bum Units Pollutant Emis. Factor Emis. Controls Control Eff.% Nitrogen Oxides 1.0 g/hp-hr SCO N/A Carbon Monoxide 0.18 g/hp-hr SCO -93 Volatile Organic Compounds 0.10 g/hp-hr SCO -93 Acetaldehyde AP -42 SCO 50 Acrolein AP -42 SCO 50 Benzene AP -42 SCO 50 Formaldehyde AP -42 SCO 75 Potential AOS Engines (AIRS ID: 003 and 004): G3516LE TA -130 Lean Burn Units Pollutant Emis. Factor Emis. Controls Control Eff.% Nitrogen Oxides 1.5 g/hp-hr SCO N/A Carbon Monoxide 0.10 g/hp-hr SCO >=90 Volatile Organic Compounds 0.16 g/hp-hr SCO 50 Acetaldehyde AP -42 SCO 50 Acrolein AP -42 SCO 50 Benzene AP -42 SCO 50 Formaldehyde AP -42 SCO 75 AIRS ID: To Be Issued 4 Williams Production RMT Company Permit No: To Be Issued INITIAL APPROVAL Colorado Department of Public Health and Environment DRAFT PERMIT Generator Engines (AIRS ID: 005 and 006): 03516 TA -130 Rich Burn Units Pollutant Emis. Factor Emis. Controls Control Eft.% Nitrogen Oxides 2.0 g/hp-hr NSCR/AFR 00 Carbon Monoxide 2.0 g/hp-hr NSCR/AFR 78 Volatile Organic Compounds 0.25 g/hp-hr NSCR/AFR 50 Acetaldehyde AP -42 NSCR/AFR 50 Acrolein AP -42 NSCR/AFR 50 Benzene AP -42 NSCR/AFR 50 Formaldehyde AP -42 NSCR/AFR 50 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on April 15, 2012. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) Proposed engines, IDs: 005 and 006, are subject to 40 CFR Part 64 Compliance Assurance Monitoring (CAM) and must comply with an approved CAM plan to monitor the control equipment on each unit. 7) This facility will be classified as follows upon issuance of this permit: Major Source Operating Permit ' Synthetic Minor: Carbon Monoxide, Formaldehyde Major: Nitrogen Oxides MACT ZZZZ Synthetic Minor: Formaldehyde MACT HH Synthetic Minor: HAPs AIRS ID: To Be Issued 5 Williams Production RMT Company Permit No: To Be Issued INITIAL APPROVAL Colorado Department of Public Health and Environment DRAFT PERMIT GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5.6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 3. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of, a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initIo. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division(APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions Imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for inspection upon request at the location set forth herein. With respect to a portable source which is moved to a new location, a copy of the Relocation Notice (required by law to be submitted to the APCD whenever a portable source is relocated) should be attached to this permit. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section 111.6. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 5. Issuance (initial approval) of an emission permit does not provide "final" authority for this activity or operation of this source. Final approval of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section IV.H. Final approval cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. If the APCD so determines, it will provide written documentation of such final approval, which does constitute "final" authority to operate. Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you (1) do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activitywas scheduled to commence as set forth in the permit, whichever is later; (2) discontinue construction for a period of 18 months or more; or (3) do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the permittee prior to the expiration date.• 7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) prior to commencement of the permitted operation or activity. Failure to do so is a violation of Section 25-7-114.5(12Xa),C.R.S. and AQCC Regulation No. 3, Part B, Section IV.H.1., and can result in the revocation of the permit. You must demonstrate.compliance with the permit conditions within 180 days after commencement of operation as stated in condition 5. 8. Section 25.7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of Inspections and administration. If a source or activity Is to be discontinued, the owner must notify the Division In writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and'Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. AIRS ID: To Be Issued 6 ATTACHMENT A - CRAWFORD TRAIL COMPRESSOR STATION Details of equipmeat/activities covered under this facility -wide permit AIRS ID g Description Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors Specific Provisions 001 One (1) Caterpillar, Model: G3612LE TA -130, S/N: N/A, natural gas fired, 4 -stroke, lean -burn, low emissions design, reciprocating internal combustion engine, site heat input rated al 24,000,000 BTU/hr, site rated output at 3,550 HP, powering a natural gas compressor. This engine is equipped with an automatic air -to -fuel ratio controller and an Oxidation Catalyst for the control of emissions of Carbon Monoxide, Volatile Organic Compounds and Hazardous Air Pollutants. This is identified as ENG -01. Operational Limits: Consumption of natural gas as a fuel shall not exceed 202.1 MMscf/yr and 18.6 MMscfmonds. This is based on a typical gas heat value of 1,040 BTU/SCF (HHV) Emission Limits: Compliance plan. Initial compliance test and subsequent portable testing. Pollutant Annual Limit Monthly Limit Nitrogen Oxides 34.3 tons per year 5,822 lbs/month Carbon Monoxide 6.0 tons per year 1019 lbs/month Volatile Organic Compounds 3.4 tons per year 570.6 Ibs/momh Formaldehyde 1-39 tons per year 235.7 'ha/month Emission Factors: Pollutant Controlled Emission Factors (r/bbp-br) Ib/MMbtu Nitrogen Oxides 1.0 - Carbon Monoxide 0.18 - Volatile Organic Compounds 0.10 - Fonnnklebyde - 0.0132 Acetaldehyde • 0.00418 Acrokin • 0.00257 002 One (1) Caterpillar, Model: G3612LE TA -130, S/N: N/A, natura low emissions design, reciprocating internal combustion engine, 24,000,000 BTU/hr, site rated output at 3,550 HP, powering a engine is equipped with an automatic air -to -fuel ratio controller and control of emissions of Carbon Monoxide, Volatile Organic Compounds Pollutants. This is identified as ENG Operational Limits: Consumption of natural gas as a fuel shall not exceed 202.1 MMScUyr and based on a typical gas heat value of 1,040 BTU/SCF (HHV) Emission Limits: gas fired, 4 -stroke, site heat natural gas compressor. an Oxidation and -02. 18.6 MMsefhnonth. lean -bum, input rated al This Catalyst for the Hazardous Air This is Compliance plan. Initial compliance test and subsequent portable testing. Pollutant Annual Limit Monthly Limit Nitrogen Oxides 34.3 tons pa year 5,822 lbs/month Carbon Monoxide 6.0 tons per year 1019 lbs/month Volatile Organic Compounds 3.4 tons per year 570.6 Ibs/month Formaldehyde 1.39 tom per year 235.7 lbs/month Emission Factors: Pollutant Controlled Emission Factor, (g/bbp-hr) ib/MMbtu Nitrogen Oxides 1.0 Carbon Monoxide 0.18 - Volatile Organic Compounds 0.10 - Formaldehydc - 0.0132 Acetaldehyde - 0.00418 Acrolein - 0.00257 AIRS ID 0 Description Make, Model, Serial Number, Design Rate, Capacity, Controls, Emisslon Factors Specific Provisions 003 One (I) Caterpillar, Model: G3612LE TA -130, SIN: N/A, natural gas fired, 4 -stroke, lean -burn, low emissions design, reciprocating internal combustion engine, site heat input rated at 24,000,000 BTU/hr, site rated output at 3,550 HP, powering a natural gas compressor. This engine is equipped with an automatic air -to -fuel ratio controller and en Oxidation Catalyst for the control of emissions of Carbon Monoxide, Volatile Organic Compounds and Hazardous Air Pollutants. This is identified as ENG -03. Operational Limits: Consumption of natural gas as a fuel shall not exceed 202.1 MMscUyr and 18.6 MMscf/month. This is based on a typical gas heat value of 1,040 BTU/SCF (HHV) Emission Limits: Compliance plan. Initial compliance test and subsequent portable testing. Pollutant Annual Limit Monthly Limit Nitrogen Oxides 34.3 tons per year 5,822 lbs/month Carbon Monoxide 6.0 tons per year 1019 Das/month Volatile Organic Compounds 3A tons per year 570.6 lbs/month Formaldehyde 1.39 tons per year 235.7 lbs/month Emission Factors: Controlled Emission Factors Pollutant (g/bhp-hr) 1b/MMhtu Nitrogen Oxides 1.0 - Carbon Monoxide 0.18 - Volatile Organic Compounds.. 0.10 - Fonnaldehyde - 0.0132 Acetaldehyde - 0.00418 Acrolein 0.00257 004 One (I) Caterpillar, Model: G3612LE TA -130, S/N: N/A, nature low emissions design, eciprocating internal combustion eng 24,000,000 BTU/hr, site rated output at 3,550 HP, powering a engine is equipped with an automatic air -to -fuel ratio controller and control of emissions of Carbon Monoxide, Volatile Organic Compounds Pollutants. This is identified as ENG -04. Operational Limits: Consumption of natural gas as a fuel shall not exceed 202.1 MMscUyr and based on a typical gas heat value of 1,040 BTU/SCF (HHV) Emission Limits: gas fired, 4 -stroke, lean -bum, ne, site heal input rated al natural gas compressor. This an Oxidation Catalyst for the and Hazardous Air 18.6 MMscimonth. This is Compliance plan. Initial compliance lest and subsequent portable testing. Pollutant Annual Limb Monthly Limit Nitrogen Oxides 34.3 tons per year 5,822 lbs/month Carbon Monoxide 6.0 tons per year 10191bs/montb Volatile Organic Compounds 3.4 tons per year 570.6 lbs/month Formaldehyde 1.39 tons per year 235.7 lbs/month Emission Factors: Controlled Emission Factors Pollutant (g/bhp-hr) Ib/MMbtu Nitrogen Oxides 1.0 Carbon Monoxide 0.18 - Volatile Organic Compounds 0.10 - Formaldehyde - 0.0132 Acetaldehyde - 0.00418 Acrolein - 0.00257 AIRS ID 4 Description Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors Specific Provisions 005 One (I) Caterpillar, Model: G3516TA-130, S/N: N/A, natural gas fired, 4 -stroke, rich -bum, low emissions design, reciprocating internal combustion engine, site heat input rated at 9,130,000 BTU/hr, site rated output at 1,053 HP, powering a natural gas compressor. This engine is equipped with an automatic air -to -fuel ratio controller and a 3 -way Catalyst for the control of emissions of Nitrogen Oxides, Carbon Monoxide, Volatile Organic Compounds and Hazardous Air Pollutants. This unit is identified as ENG -05. Operational Limits: Consumption of natural gas as a fuel shall not exceed 66.6 MMscUyr and 5.7 MMsctmonth. This is based on a typical gas heat value of 1,040 BTU/SCF (HHV) Emission Limits: Compliance plan. Initial compliance test and subsequent portable testing. 40 CFR Pan 64 Compliance Assurance Monitoring Pollutant Annual Limit Monthly Limit Nitrogen Oxides 20.3 tons per year 3,454 Ibs/montb Carbon Monoxide 203 tons per year 3,454 Ibs/month Volatile Organic Compounds 2.5 tons per year 432 Ibs/nwnth Formaldehyde 0,35 tons per year 60.3 Ibs/month Emission Factors: Pollutant Controlled Emission Factors (f,/bhp-hr) Ib/MMbta Nitrogen Oxides 2.0 - Carbon Monoxide 2.0 - Volatile Organic Compounds 0.25 - Fomraldehyde - 0.01025 Acetaldehyde - 0.00140 Acrolein • 0.00132 006 One (1) Caterpillar, Model: G3516TA-130, SM: N/A, natural ga fired, 4 -stroke, emissions design, reciprocating internal combustion engine, site heal input rated BTU/hr, site rated output at 1,053 HP, powering a natural gas compressor. equipped with an automatic air -to -fuel ratio controller and a 3 -way Catalyst for emissions of Nitrogen Oxides, Carbon Monoxide, Volatile Organic Compounds Air Pollutants. This unit is identified as ENG -06. Operational Limits: Consumption of natural gas as a fuel shall not exceed 66.6 MMscf/yr and 5.7 MMscUmonth. based on a typical gas heat value of 1,040 BTU/SCF (HIiV) Emission Limits: rich -bum, low at 9,130,000 This engine is the control of and Hazardous This is Compliance plan. Initial compliance lest and subsequent portable resting. 40 CFR Pad 64 Compliance Assurance Monitoring Pollutant Annual Limit Monthly Limit Nitrogen Oxides 20.3 tons pct year 3,454 lbs/month Carbon Monoxide 20.3 tons per year 3,454 lbs/month Volatile Organic Compounds 2.5 tom per year 432 lbs/month Formaldehyde 0.35 tons per year 60.3 lbs/month Emission Factors: Pollutant Controlled Emission Factors (g/bbp•br) Ib/MMbtu Nitrogen Oxides 2.0 Carbon Monoxide 2.0 - Volatile Organic Compounds 0.25 - Fornnldehyde 0.01025 Acetaldehyde • 0.00140 Acrolein - 0.00132 AIRS ID tt Description Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors Specific Provisions 007 One triethylene glycol (TEG) natural gas dehydration system, S/N: N/A, feed gas design rated at 90,000,000 SCF per day, lean TEG circulation rate at 24 gallons per minute. This system consists of: gas/glycol contactor, flash tank and gas driven glycol pump. All emissions will be captured by a Vapor Recover Unit. 'This is identified as DEHY-01. Operational Limits: Potential Natural Gas processed in the dehydration system. 90 000 000 SCF/DAY Ilan TEG circulation rate: 24 ga0ons/minute Emission Limits: Equipped with condenser and all emissions captured by VRU; assumed up to 5% VRU downtime. VOCAIAP DRE: >95% Overall Compliance Plan Pollutant Annual Limit Volatile Organic Compounds 8.4 tons per year Toluene 1,871 lbs per year Xylenes 442 lbs per year Benzene 1,722 lbs per year 008 One triethylene glycol (TEG) natural gas dehydration system, SM: N/A, feed gas design rated at 90,000,000 SCF per day, lean TEG circulation rate at 24 gallons per minute. This system consists of: gas/glycol contactor, flash lank and gas driven glycol pump. All emissions will be captured by a Vapor Recover Unit. This is identified as DEHY-02. Operational Limits: Potential Natural Gas processed in the dehydration system: 90,000,000 SCF/DAY Lean TEG circulation rate: 24 allonslmtaule Emission Limits: Equipped with condenser and all emissions captured by VRU; assumed up to 5% VRU downtime. VOC/HAP DRE: >95% Overall Compliance Plan Pollutant Annual Limit Volatile Organic Compounds 8.4 tons per year Toluene 1,871 lbs per year Xylenes 442 lbs per year Benzene 1,722 lbs per year 009 Three (3) custom, vertical fixed roof tanks, each wi h a capacity of 400 barrels and manifolded together. Flash emissions captured in the flash t nk are routed to a Vapor Recovery Unit. Additional flashing from the flash tank down to atmospheric pressure are vented to atmosphere. The tanks are identified as TK-01. Operational Limits: Condensate throughput limit: 14,600 barrels per year Emission Limits: Compliance Plan Pollutant Annual Limit Volatile Organic Compounds 17.5 tons per year Benzene 1321bs/yr AIRS ID N Description Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors Specific Provisions 010 One natural gas fired process heater with a maximum heal rating be used to for TEC regeneration, storage tank heating, building loads. This heat medium system will be identified Operational Limits: The maximum heal input rating of this heater is: 15.0 MMbtu/hr. Fuel Consumption: 126,346,000 SCF/YR Fuel consumption based on 1040 Btu/scf heating value Emission Limits: of 15 MMbtu/hr. This unit will heat and miscellaneous heat as HTR -01. Compliance Plan. Subject to NSPS De Pollutant Annual Limit Nitrogen Oxides 6.32 toes per year Carbon Monoxide 5.31 tons per year Volatile Organic Compounds . 0.35 tons per year PM -I 0 0,48 tons per year 011 Description Fugitive emissions from equipment leaks. The facility ID Operational Limits: The source shall be limited to a maximum equipment configuration for this unit is, as listed below. 0. hatches. dump FUG -1. amu and inn.umenr 1, Table 7-4 Component Non -Residue Get Service NGL Service Valves 416 94 Connectors 1045 476 Mangos 258 146 Seals - 14 Other* 54 - VOC Content (wta%v) 10.79% 100% • Other equipment includes compressors. PRVs. relief valves, diaphragms. drains, ve Emission Limits: Pollutant Annual limit Monthly Limit Volatile Organic Compounds 7.9 tons per 1343 lbs/month Emission Factors (Ib/hr-component): Source: EPA.453/RA3-0I Component Non -Residue Gas Service NGL Service Valves 0.00992 0.00551 Connectors 0.00044 0.00046 Flanges 0.00086 0.00024 Seals 0.00529 0.02866 Other 0.0194 0.01653 C 0 0 d k u u 8 N ---- Feel Gas Heating Valoe- 1040 Bnose7 Serial Maximum Horsepower Item Hot Fuel Feel Volumetric Exhaust Exhaust Suck Suck F.shamt Number Open0o8 SlteRatiog Input Hate Use Use Flow Velocity Velocity Diameter Height Temp Houn/Yr Hp MMB0Ner BeWHp-hr sever AUbe0yr actin ft/min ft/me («t rm. E F NA 8760 3550 24.0 6760 23075 202.14 23461 13276 221.3 1.50 211.00 858 NA 8760 3550 24.0 6760 23075 202./4 23461 13276 2213 1.50 28.00 858 NA 8760 3550 24.0 6760 23075 202.14 23461 13276 2213 130 28.00 858 NA 8760 3550 24.0 6760 23075 202.14 23461 13276 2213 1.50 28,00 858 NA 8760 1053 7.91 7515 7609 66.65 4235 5392 89.9 1.00 24.00 864 NA 8760 1053 7.91 7515 7609 66.65 4235 5392 899 100 7400 ace NA 8760 NA NA NA NA NA NA NA NA 127 20.00 800 NA 8760 NA NA NA NA NA NA NA NA I n conn em c I, 8 _ Y z _ 2 S z NA 8760 NA NA NA NA NA NA NA NA n 17 U' s..w.... . 2 z 2 Z z z z z 6 z Z2 5s $ & FF LL o Ig I $$gg A R R ill F f ^W< 4 y.,dC RM9 111111 lulrt muo F2ea_°e cgqqq qqgg 3oc1U00ci » 2 o '^'^ di /5 �� V� S n u5o lis 'neaten HTR -I Process/Regen Hemet Hot Oil Hester i d .g 2 c Z'90 o ui to ea i I F. iE °i 1 1 ei 1 I4$464 6a` 6' I.;.;,;(7, 0 55555! ,QR qR Q„ Y Q p 0 Mill 0 S a 5 0 .. ..sa f5 ' o z 5 z z � 2 8 a z 2 a 2 z 2 z `z z z z Z _ z zg z a 2 z z 2 Z2 5s $ -0555 0 0 0 0 0 5 00_ d d d d 5 0000 s a1 li ao 21 1,4 _ Sz 0.10 0.77 3.4 0.10 0.77 3.4 0.10 0.77 3.4 0.10 0.77 3.4 0.25 0.58 2.5 025 0.58 23 1.91 8.4 1.91 8.4 F5 f < Nzz „ 0 a Ii Z al2 g u �c •o nnN�n Li;:;;;” w m w 0N 2:2:2201, .Th ' ;1;17e1 ;1'22 .4,4r4�.s 555520 ..82 io =i i£ tg y c 1.14_ F".5666661 recany engines ENG -01 Inlet Compression (itvpilla 36121E TA -130 15CD ENG -02 Inlet Compression Caterpillar 3612 IS TA -130 w/SCO ENG -03 Inlet Compression Caterpillar 3612 LE TA -130 wISCO ENG -04 Inlet Compression Caterpillar 3612 LE TA -130 w/SCO ENG -05 F.lec ical Generator Caterpillar 035161A-130 MNSCR ENG -06 Electrical Generator Caterpillar 63516 TA-130w/NSCR TEG Units DENY.1 TEG Gas Dehydration Glycol Regen. Still Vent DEHY.2 TEG Gas Dehydration Glycol Regee. 51111 Vent Homers Hlit-1 Process/Reg= Heater Hot OO Heater Tants TANK -01 Condensate Stone Su 400 -bbl Coad Tanks > g 1 @ $ : u a < Jo . ' Y _ C 6 ii E a, gi 13 Ai 11I;a WS e4 2 It L 8 It f gP Y P `� ik <8 a s .wa. ...err 47r 0.4 878.7 0.3 540.3 0.0 46.2 1.39 27743 0.0 4.2 0.1 116.7 0.0 42.9 0.0 193 04 878.7 CO 540.3 0.0 46.2 139 2774.9 0.0 4.2 0.1 116.7 0.0 42.9 0.0 19.3 04 878.7 0.3 540.3 0.0 46.2 139 2774.9 0.0 42 0.1 116.7 0.0 42.9 0.0 19.3 0.4 878.7 0.3 5403 0.0 46.2 139 2774.9 0.0 42 0.1 116.7 0.0 42.9 0.0 19.3 OA 96.7 0.0 912 0.0 54.8 036 710.5 0.0 0.9 0.0 38.5 0.0 19.3 0.0 6.8 0.0 96.7 0.0 912 0.0 54.8 036 7103 0.0 0S nn Its nn 'a, ,... ,. o %F 0 -- , e e , ei >o o cid2 22 z z ^4p oo g z2 zz 22 0 , 2 2 z z z z z < 2 3 z 2 0. I NA NA NA NA 0.07 132.3 NA NA 0.00 9.6 0 0 06 5260 0 in 201 5 03 692 NA NA NA NA 0.0 32.7 NA_ NA 0.0 3.4 0.1 51415 nn ens , fl' > .J d 4 e e 20, :iia oS gA zj aE is s a1 li ao 21 1,4 01*CQx ItNfS* RARRRR FFia-h<< ,!..Inch XR°Rou 111111 IJ�i it q» 04 11 z ° g a $ s I p 2v. y 1 i 1 7 8 1 Crawford Trail Emissions.sts FEATURES 14 FULI IRANGE OF)ATTACHMENTS . WIdget' ar nge`of bolt on system'expansion , esachwanwi a orydet edfiandtested, UNMATCHED1PRODUCTa'SUPPORTF tOF2FERE0I14ROUGHiWORLDWIDt CATERRPIULyA-'R,, DE%1'LER kNETWORK n More,than1r500 dealer outlets ylt�r .164B.Saw 0,: atmet. e.' 1 Caterputar#factorq:train d,dealer -.techmcians service every aspect of your; ▪ petroleum engine - - u 99L7%of{p its bders hllediwtt iri 24, t!houts�'` w`o ,law l f s ) W ii'' a'9f 14ailt a%' sl ▪ Cateerpilll parts and labor warranty �M, Preventive maintenance agreements, availablSeffor irepain,before failure" i•iptry sg 1gl ' 5'v tr ScheduledlSampling (S O+SA'") ]1e MY. t'�2{RLKJbfPp4 r'2 :, ' piroorra,�m"imatches�your orl sam le •against Caterpolarrset standards to determinat' �a " iritrernal.engineFcomporient sonditio_ n presence+of un'wantedifluids presences of£comti stton by-protlucts ktx.;, +�."a'L- 3H seth$ at', . a_ SINGLE,SOURCE SUPPLIER' ' =Caterpl)lar' 'j ' '•si`r za d'. casts engine blocks heads, •' cylinde Miners eand alcwireel housings yr'r .=machinesfcritical om onents _- assembles complete engine OwnershIp'of thesetm nufacfuri,ng processes enabi.vEi t*tpAla -- produce h igh gluailty sdependablelproduct. Factory ci sig ed sy to ms built at CaterpillarlScrhed al.G1np4/7t' ,aaj.faciltes mo t tatiF .3 P.emrca,�,w:20: Shown with Optional Equipment Cr-IGt -Ef,1Gti Gas G3612 Petroleum 3195-3550 bhp Engine 2383-2647 bkW 900-1000 rpm CATERPILLAR* ENGINE SPECIFICATIONS V-12, 4 -Stroke -Cycle Bore — in (mm) 11.8 (300) Stroke — in (mm) 11.8 (300) Displacement — cu in (L) 15,528 (254.4) Aspiration Turbocharged and Aftercooled Capacity for Liquids — U.S. gal (L) Jacket Water Circuit' 177 (669) Aftercooler Circuit' 17 (64) Lube Oil System (refill) 272 (1030) Package Shipping Weight (Dry) — Ib (kg) 'Engine only 55,300 (25 084) k,Okik Low emissions Broad operating{{spipclirrang and t"3rr !i' "urns nFa .a r p tilt. ability to+burn e,wide s ectrrurr1 of , x gaseous fuels }p;` P ;, yg( ilCate ppiillar AdvencedaktalkEtwin -44 Man gement (eADEM'111) nttrolrsystem' • Witth detonahonrse�nsitrve'timing&control fonndiv) ▪ eye hcyllnders • Robust `d eselstrengtlikdesign'provides •'N prolonged1hfe and lower,owmng and iY rA Y ost JI 1 4 r -i< Y f operatinglcosts 0: • S TESTING' Prototype)testing on'every mode) proves computer design k• °')) Yi • F:/13 Eng£ ,N3A ,. rMi;" •Ili - 1 yenfies systemytoir.rsionaljstabdny cwt H t < 4rt+1'r^ " 9b :4F ry; sX 1S''I. functlonalitystests everytmodelr • Every&Caterpillar. engi z jdyna nometert 'testedunderrfiu�llloadltoaertsureyproper . k) engine performance 4' 'a, , ■ WEB SITE I • a :For addrtionaltinformahon on ally .'- petroleum`s' owerre uiremerits; visa. s:,a a po- a v g 9-,r z s„ wwwcat oilandgas corns a t s qq L..-.:.t..ea .kl j .r:4:r&.',aio�'1-i Jd".?LaY.-s CE LEHW0614-01 CATERPILLAR' G3612 GAS PETROLEUM ENGINE FACTORY INSTALLED STANDARD & OPTIONAL EQUIPMENT SYSTEM STANDARD OPTIONAL • Air Inlet . Air cleaner — standard -duty Heavy `duty. ao cleaner with precleane s Inlet air adapter Heavy-duty air cleaner JIth ram_ protection_ Charging System Charging alternators Control System , Caterpillar ADEM III control system provides electronic governing integrated with air/fuel ratio control and individual cylinder ignition timing control Cooling System Jacket water pump Jacket water thermostats and housing Aftercooler pump Aftercooler water thermostats and housing Single -stage aftercooler Exhaust System FiywheelIlousing, Fuel System • IgnitionSystem Dry wrapped exhaust manifolds Vertical outlet adapter SAE No. 00 flywheel SAE No. 00 flywheel housing SAE standard rotation • Gas admission valves with electronically controlled fuel supply pressure ADEM III control system senses individual cylinder detonation and controls individual cylinder timing Cushier) doniroceysterri eohware'.is'evailatile for non standard rahn`gs Software -,s geld programmable using flesfime'mo'ry: Expanslon.tank Flexible connections Jacket:water. Heater • .Flexible -bellows adapters.: .Exhausi'expander •Welii-flanges. `Fuel fitter Gas' pressure regulator Flexible' connection Low energyfuel, system CorrosiVe.gaiRref system CSAcertification ••Instrumentetloh LCD display panel monitors engine parameters and displays diagnostic codes Remote data mbnitoring' and speedcontrol:.• Competlble'With Cat Eleatronio Technician'IETj .-and•Data View fel stomer'Corie unibation'Mbdule (CCM): b. ,'Display panel deletion�is optional �; ,' .. Lube System Crankcase breathers (top mounted) Oil cooler Oil filter Oil pan drain valve Alr•orelectric motor -driven prelutie Duplex oil filter 01 or RH service tube oil makeup .system. MountingSystem Engine mounting feet (six total) .Mounting plates (set ofstx) Power Take=offs Front stub 'shafts Protection Electronic shutoff system with purge cycle Crankcase explosion relief valves Gas shutoff valve Starting System Air starting system Alr pressure reducing valve Natural gas starting system General Paint, Caterpillar yellow Vibration dampers Engine barring device Damper guard LEHWO814-01 G3612.GAs 0?Tfip4,0vIooirsiE TECHNICAL DATA CATERPILLAR' G3612 Gas Petroleum Engine — 900.1000 rpm C"' gPshi.e.,•trizr,.• 6-A4.141ad bhp (bkW) Alx.i.iAd • • • • • • bhp (bkW) , e EngGie Speed rpm • • -navivi:t +.%;- 319542383):: -2397;(1787)-;'' Ate; .: • • .7 tr. . t..4:,;WiaNt' c•ir \Ts .. • ... ; DM5310-00 3550 (2647) 2662 (1985) 1000 SCACTeiniseritUise ; °F (°C) • .;;;• . • CompresslonlRatio • !:130 (54)l" 130 (54) 9.0:1 •, •• NOX"''" g/bhp-hr g/bhp-hr . ydrO.Cajbo...ag, • • g/bhp-hr , --vn"U•11/;$!.. Fuel ConsuMplian @ 100% Loath', 6..70.1(salco: • • " J.°, • .•••'•.(?....9:14-1. • . 15136?; 0.70 250 6.15 .2 • Btu/bhp-hr (MJ/bkW-hr) Btu/bhp-hr (MJ/bkW-hr) A741g1g4i64 • • : ,; frovu:P.--).• • b... fr. .1‘ IceiMIMPT AVIV itair HeatiFiejeallod to;Aftaie•bal8i • 6566%168d • • ;f8.)7§%`...Coad ; • ilRisjettlen;la 8dittuat .4.1100%.Load ' @75% -Load • Btu/mn (bkW) .• Btu/mn (bkW) Btu/mn (bkW) Btu/mn (bkW) Btu/mn (bkW) Btu/mn (bkW) 9,333A184)"• • - . 134,72'1(2369) 107,0910883)' ;:. rir .• 6,760 (9.57) 7,050(9.98) 36,195 (636) 31,271 (550) 26,509 (466) 14,525 (255) 154,673 (2720) 123,759 (2176) Eithaust;S• ystem ExhaustGas Flov;;;Rate @AGO% Load 0.764'.8:Old •;) Ekhe'llatilkcktiirepetatuie '61199!..;.:1-§4.i• . 075%1166d cfm (mf/min) cfm (m'/min) °F (°C) °F (°C) 20,834:15.9:1H' 1608116)• , 6,4 (fi.0! • 8671484r 23,461 (664) 18,554 (525) 858 (459) 878 (470) tinalielSestem: • • • ' fur Inlet -.Avg Rote • ..@.;1110Vjkoad : • 'tri.in) Gas Pressure . 'at 100% load and speed cfm (m'imin) cfm (m3/min) 8,521. (241) • 6142.(186) • 9,598 (272) 7,477 (212) psi (kPa) 43-(95) 43 (295) LEKW0814-07 CATERPILLAR' 63.612 GqS PETROLEUM ENGINE GAS PETROLEUM ENGINE DIMENSIONS Length - _ `;'* In(inml ' (4735;;11-°; 4414.414141): Width in Imm) 93.68 (2379.5) Height - : , , jn'(mm) - -,,,128 77 (3219'9)7;: Shipping Weight Ib (kg) 55,300 (25 084) RATING DEFINITIONS AND CONDITIONS Note: General configuration not to be used for installation. See general dimension drawings for detail. Engine performance is obtained in accordance with SAE J1995, IS03046/1, BS5514/1, and DIN6271/1 standards. Transient response data is acquired from an engine/generator combination at normal operating temperature and in accordance with 1S03046/1 standard ambient conditions. Also in accordance with SAE J1995, BS5514/1, and DIN6271/1 standard reference conditions. Conditions: Power for gas engines is based on fuel having an LHV of 905 Btu/cu ft (33.74 kJ/L) at 29.91 in. Hg (101 kPa) and 59° F (15° C). Fuel rate is based on a cubic meter at 29.61 in. Hg (100 kPa) and 60.7° F (15.6° C). Air flow is based on a cubic foot at 29.61 in. Hg (100 kPa) and 77° F (25° C). Exhaust flow is based on a cubic foot at 29.61 in. Hg (100 kPa) and stack temperature. TMI Reference No.: DM5312-00, DM5310-00 Materials and specifications are subject to change without notice. The International System of Units (SII is used in this publication. LEHW0914.01 (9-011 Primed in U.S.A. 02001 Caterpillar All rights reserved. G35161TA as;Getierator:Set Engine Performance Engine Speed (rpm) Compression Ratio Aftercooler Inlet Temperature (°F) Jacket Water Outlet Temperature (°F) Ignition System Exhaust Manifold Combustion System Type 1200 9.0:1 130 210 EIS WATER COOLED STANDARD rczk at& &J&-5 \G-1 i6 -( Ge,. Fuel LHV of Fuel (Btu/SCF) Fuel System CATERPILLAR° Minimum Fuel Pressure (psig) Methane Number at Conditions Shown Rated Altitude (ft) at 77°F Design Temperature NAT GAS 920 HPG IMPCO 35 80 5000 LEngine)RatingjDatan+'jaki°1 sr 'kt`y+uifElatrAzwy`:'itratifLoedlmcaigd4 (tr3:100^/14 Fl75%r1uk.,:t.40.0 s, Engine Power (w/o fan) bhp 1053 790 528 Generator Set Power (w/o fan) kW 740 555 370 (Engine Date ONEMOW WO Specific Fuel Consumption (BSFC) (1) Air Flow (Wet, @ 77°F, 28.8 In Hg) Air Mass Flow (Wet) Compressor Out Pressure Compressor Out Temperature Inlet Manifold Pressure Inlet Manifold Temperature (10) Timing (11) Exhaust Stack Temperature Exhaust Gas Flow (Wet, 0 stack temperature, 29.7 In Hg) Exhaust Gas Mass Flow (Wet) VMS dr WOREVAlleitial IMNIMItrai Blu/bhp-hr SCFM Ib/hr in. HG (abs) °F in. HG (abs) °F °BTDC °F CFM Ib/hr Nitrous Oxides (NOx as NO2) (9) I g/bhp-hr (Corr. 15% 02) Carbon Monoxide (CO) (9) Total Hydrocarbons (THC) (9) Non -Methane Hydrocarbons (NMHC) (9) Exhaust Oxygen (9) Lambda (Corr. 15% 02) (Corr. 15% 02) (Corr. 15% 02) ne •v+xi•a, as.f+� ^^::...., trr Engine HeAi Balence,Date° " ,�„ as s k N 11 Input Energy LHV (1) Work Output Heat Rejection to Jacket (2) (6) Heat Rejection to Atmosphere (Radiated) (4) Heat Rejection to Lube 011(5) Total Heal Rejection to Exhaust (to 77°F) (2) Heal Rejection to Exhaust (LHV to 3507) (2) Heal Rejection to Aftercooler - stage 1 (3) (7) (8) 26 PPm 7515 7909 86776 1554 1244 963 6892 5514 4271 61.3 59 52.2 268 240 202 58.7 49.5 39.9 134 133 133 22.5 22.5 22.5 864 840 793 4235 3329 2487 7273 5820 4510 Ile atRlrl^Ijn+>`91f�j(j(LS�n 1 -� 19.9 17.5 17.5 1476 1190 798 �1 1 hei2 g/bhp-hr ppm 1.2 1.3 1.4 EFS ost. 139 138 122 g bhp -hr ppm 1.5 1.5 2.0 301 300 338 g/bhp-hr ppm 0.23 0.23 0.31 15 14 16 2.0 1.12 1.6 1.3 1.11 1.10 '1,41n.l,rra.d t,+Y 1;: Vilitr,,•$n.211M,�n1'4`.ir Btu/min 131838 104070 76107 Btu/min Btu/min Blu/min Btu/min Btu/min Btu/min Btu/min 44663 51811 4554 0 26862 17156 3941 33498 43406 3795 0 20819 13089 2549 22332 34134 3037 0 15237 9156 1365 -ENGLISH- page 1 of 2 DM5144-00 iEn9( QLNoisepata at 1O0%°jioed Noise • Mechanical ® 1 m Noise • Exhaust ® 1.5 m 100 dBA 111 dBA Tug Usage Qui n R';,, ,.`.j .51144. berate Factor/ Engine Timing vs Methane Number <30 30 35 40 45 50 55 80 80 to 65 70 75 100 0 0.59/14 0.59/15 0.59/16 0.59/17 0.90/14 0.90/15 0.90/18 1.0/16 1.0/18 1.0/20 1.0/23 1 e 4f� Y JFV� -•Nisi 111 titude, Deraitate Otors"lthik 13 • 120 W 110 ~ 100 90 • 80 70 ▪ 60 (°F) 50 WAWO r ,3xifhWWW'r, 'r tl" n�:` `-ar<fii0 0 1.00 1.00 1.00 0.98 0.94 0.91 0.88 0.84 0.81 0.78 0.75 0.72 0.70 1.00 1.00 1.00 1.00 0.96 0.93 0.89 0.86 0.83 0.80 0.77 0.74 0.71 1.00 1.00 1.00 1.00 0.98 0.94 0.91 0.87 0.84 0.81 0.78 0.75 0.72 1.00 1.00 1.00 1.00 1.00 0.96 0.92 0.89 0.86 0.82 0.79 0.76 0.73 1.00 1.00 1.00 1.00 1.00 0.98 0.94 0.91 0.87 0.84 0.81 0.78 0.75 1.00 1.00 1.00 1.00 1.00 0.99 0.96 0.92 0.89 0.85 0.82 0.79 0.76 1.00 1.00 1.00 1.00 1.00 1.00 0.98 0.94 0,90 0.87 0.84 0.81 0.77 1.00 1.00 1.00 1.00 1.00 1.00 0.99 0.96 0.92 0.89 0.85 0.82 0.79 1.00 1.00 1.00 1.00 1.00 1.00 1.00 0.98 0.94 0.90 0.87 0.84 0.80 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 ALTITUDE (FEET ABOVE SEA LEVEL) After"co0ler,FieatnBJectlona:FactorsWar s..;*,` >vE' exRrr:iit I Ana ; x e ,? w°: ;',9? M.-. Lt3;Gi hm GN4 130 1.36 1.46 1.53 1.61 1.69 1.77 1,77 1.77 1.77 1.77 1.77 1.77 1.77 11 120 1.29 1.36 1.44 1.52. 1.59 1.67 1.67 1.67 1.87 1.67 1.67 1.67 1.67 110 1.19 1.27 1.34 1.42 1.50 1.57 1.57 1.57 1.57 1.57 1.57 1.57 1.57 100 1.10 1.17 1.25 1.32 1.40 1.48 1.48 1.48 1.48 1.48 1.48 1.48 1.48 90 1.01 1.08 1.15 1.22 1.30 1.38 1.38 1.38 1.38 1.38 1.38 1.38 1.38 80 1.00 1.00 1.08 1.13 1.20 1.28 1.28 1.28 1.28 1.28 1.28 1.28 1.28 70 1.00 1.00 1.00 1.03 1.10 1.18 1.18 1.18 1.18 1.18 1.18 1.18 1.18 ▪ 60 1.00 1.00 1.00 1.00 1.00 1.08 1.08 1.08 1.08 1.08 1.08 1.08 1.08 (°F) 50 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 . 1.00 1.00 0 1000 2000. 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 ALTITUDE (FEET ABOVE SEA LEVEL) i..DM5144• io'Data!iYontende:oi be Osed,with a4e,onglne Petformance BookPeramoo?t4. DM5Q00-00 on page.N;;, DM5144-00 •ENGLISH- page 2 of 2 27 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 ALTITUDE (FEET ABOVE SEA LEVEL) After"co0ler,FieatnBJectlona:FactorsWar s..;*,` >vE' exRrr:iit I Ana ; x e ,? w°: ;',9? M.-. Lt3;Gi hm GN4 130 1.36 1.46 1.53 1.61 1.69 1.77 1,77 1.77 1.77 1.77 1.77 1.77 1.77 11 120 1.29 1.36 1.44 1.52. 1.59 1.67 1.67 1.67 1.87 1.67 1.67 1.67 1.67 110 1.19 1.27 1.34 1.42 1.50 1.57 1.57 1.57 1.57 1.57 1.57 1.57 1.57 100 1.10 1.17 1.25 1.32 1.40 1.48 1.48 1.48 1.48 1.48 1.48 1.48 1.48 90 1.01 1.08 1.15 1.22 1.30 1.38 1.38 1.38 1.38 1.38 1.38 1.38 1.38 80 1.00 1.00 1.08 1.13 1.20 1.28 1.28 1.28 1.28 1.28 1.28 1.28 1.28 70 1.00 1.00 1.00 1.03 1.10 1.18 1.18 1.18 1.18 1.18 1.18 1.18 1.18 ▪ 60 1.00 1.00 1.00 1.00 1.00 1.08 1.08 1.08 1.08 1.08 1.08 1.08 1.08 (°F) 50 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 . 1.00 1.00 0 1000 2000. 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 ALTITUDE (FEET ABOVE SEA LEVEL) i..DM5144• io'Data!iYontende:oi be Osed,with a4e,onglne Petformance BookPeramoo?t4. DM5Q00-00 on page.N;;, DM5144-00 •ENGLISH- page 2 of 2 27 CATALYTIC SILENCER SIZING PROGRAM GT EXHAUST SYSTEMS, INC. 4121 NW 37 SVeel Lncaln. NE 68524 402.323-7272 Fax 402-3217270 CUSTOMER: HANOVER COMPRESSION PROJECT: WILLIAMS co. DATE: 2/21/2006 QUOTATION I.D.: DESCRIPTION: CAT 3516TALE, 1400RPM, 134I/HP, 856TEMP OXIDATION REDUCTION PRESSURE DROP CALCULATED WITH A 12 INCH OUTLET PERFORMANCEDATAINPUT AND CALCULATION$ INPUT DATA CALCULATED (FLOW: ACFM or SCFM 70114.7 or NCuMIM1n32114.7 or LBIMIN or LB/HR 13305 S.G. or M.W. 28.7 TOAST PGAS PSIG PATM PSIA OUTLET SIZE, IN FUEL, (GAS,or DIESEL) BODY STYLE (201 OR 501) MAX BODY CAPACITYor R 3 -WAY OR OXIDATION SERIES (2100 - 5100) NUMBER OF ELEMENTS o "' 656 14.7 12 GAS 201 2 OXIDATION 4160 2 ACFM SCFM ruu.7 NC 311/141932114.7 LB/MIN LB/HR 7408.58 2987.44 221.75 13305.00 0.99102 • SEE M.W. 28.700 NOTE TOAST 1314 POAS P$IA 14.700 OUTLET, SOFT. 0.765 OUTLET VEL, FT/MIN 9430.4 VEL HEAD; IN H2O 2.22 SCFH amu/ 166394 (FOR CAT CONV SPACE VELCALCI ' NOTE 27.5 MW TYP FOR RICH BURN EXHAUST GAS: 19.7 MW TVP. FOR LEAN BURN GAS OR DIESEL " MAX. BODY CAPACITY - For modul r enter number of elements and half elements as 1. 2.4.8. elc. For the small round (6",8".10".12',14",or 181 ENTER R IN C -3D AND THE DIAMETER SELECTED IN C-31. '-' NUMBER ELEMENTS For modular enter the number of full and hart elements as 1.1.5.2.2.5.3.3.5,.... u0 to entered Max. Body Capacity. Fa small round (6',8",10",17.14".or 16") ENTER "1" ANO ENTER THE DIAMETER OF IN C-31 GT CATALYTIC CONVERTER MODEL NUMBER 201 V 0 - 2 - 200 . 4112 CALCULATED PRESSURE DROP "0 6.71 INCHES H20, CALCULATED SPACE VELOCITY = 123355 WITH LEAN BURN GAS ENGINE, MIN. OXIDATION RATES ARE: 95 % & HCHO. AND 50 % NMNEHC BASED ON STATED EXH. FLOW & THE FOLLOWING EMISSIONS OUT OF ENGINE: WE WARRANT EMISSIONS OUT OF CONVERTER NOT EXCEED: UNITS: Nola 1: FRANC. NMNEHC Nota 2: OXtdatlon Catalyst on Mosel or Lars Gas Cannot Reduce NOx NOX CQ HCHO NMHC an,t NMNEHC ae" 1.50 1.89 0.25 0.46 0.31 1.50 0.09 0.01 0.23 0.16 Pm1BHP-11 gm/BHP-hr gm/BHP-hr gm/BHP-hr gm/9HP-Iv PERFORMANCE WARRANTY CONTINGENT UPON CONVERTER INSTA LATION ON A PROPERLY MAINTAINED ENGINE EXCESSNE OIL CONSUMPTION ANDIOR FUEL CONSUMPTION MAY MASK OR POISON THE CATALYST AND REDUCE DESTRUCTION ENGINE LUBE OIL MUST BE OF A TYPE RECOMMENDED FOR CATALYTIC CONVERTER SERVICE. ELEMENTIS) WILL REQUIRE PERIODIC CLEANING. FREQUENCY WILL DEPEND ON LEVEL OF CONTAMINANT$ IN THE EXHAUST GAS CERTAIN CONTAMINANTS SUCH AS HEAVY METAL IN FUEL AND LUSE OIL WILL POSION THE CATALYST AND VOID THE WARANTY HANOVER BILL DARNOFALL WILLIAMS 3516TALE 1340HP 201VO-2-14112-1, SELECT SIZE 2/2172008.4:15 PM K • 0. O O *, O a n V' b O M l'D, N la Ch CO N T h O1 OO Q\ N -; p& r, h W Ol v°pco i b V N M O t. '� n b r40 l0 _ o ,. O v' .a 00 M N O) t M 00 Vl n r N 1-, 0 ii O c O it li a .a > o l0 N M h N 0O vi N N 0O V r- el rp U 40 a? M O\ N n N co n N h cr C co rn 0 N N O O D\ N 00 00 00 N V 72 N N N N N N N N N CO 00 v.� N 3 ,C :...'^. T. '> e O Y p 0 C 2 3 5L) O O CZ 0aXS c"� Uu n.gx.. 2 • > Vu._ V u V y v h co o . .)a ,OxVLPLO Nx407TV.OtP.. 0.O 10 O M1. .4 N N O L T 00 O O H S W 4 c.`^. c ax[gF WXVF^..1' > eh. P. N O0 ^O N O 00 h 00 M H n -+ -- v) lO m T CO Or 00 O. N --. O N 04 11, DEHY-1 Still Vent Condenser Overhead To VRU Assume 95To`Dow i tme of VRU for GRI GLYCatc Model Crawford Trail Compressor Station Uncontrolled Emissions if VRU down Component (Ib/hr) tons/yr Q, rry N 00 Q C d: O N ret V rn V T O` O N O O 1� rel N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 'Total Emissions 89.646 19.6 Total NMNE VOC Emissions 8.4 Total scf/hr to VRU from condenser vent: 368 Total acfm to VRU: 6.84 Methane 36.293 Ethane 15.104 Propane 10.069 i -Butane 3.625 n -Butane 4.301 i -Pentane 1.983 n -Pentane 1.649 Cyclopentane 0.222 n -Hexane 0.930 Cyclohexane 1.331 Other Hexanes 1.717 Heptanes 1.178 Methylcyclohexane 1.648 Benzene 3.933 Toluene 4.273 Ethylbenzene 0.108 Xylenes 1.010 2,2,4-Trimethylpentan 0.062 C8+ Heavies 0.210 Crawford Trail Emissions )\)§)]§§)\($m7=la,am •:§§\,aq;�}:0g!(;!._ I-00r,$-m_R§§;§--- a e\ oo r'ne l - V'l 0 0 0 g ///\}je2;\[/))32 » 0'00 0CN0 N§R0mzN B§2/„ 200§!000 11 S' _k 40 co 4.e Im a2] IfJ ul■ . g_ $, t°§,0 0CCO 01 CO =)a§)k;2,G02o°ƒ-*■ \/\/)§/\kƒ\)\//k)} Note: Flash Tank Vapor Composition from GLYCaIc DEITY -I Flash Tank Overhead To VRU Volumetric Flow From GLYCaIc Stream Data Crawford Trail Compressor Station ]000- F/_66,`6_ ki§§))\/§§\§}\ »47;38;8888880) „ =:,aa,==,® Flash to HTR -1 Fuel Gas 1290 scf/hr ' VD Ul 1/40 666666en )/;n,a;;mmeea00-00 \\$,-§®;/k1g-gx\§;§\§) §& uoya#;/.14. eV & 0 ® 0 to „ $)°;m®`J!&K4/t!f cOX �Fg�*ce Crawford Trait Emissions \#%Pm¥*�m �}()§}(nv!t-nggA• 20/) 0 N ;in00t▪ . 0 o e rn §/\§§\j\\\j(\\\\ uo / /7 } /k)\ *a § %\! t;©V0229§!» #°® !2! $2J-«; 7k�r z¥^ a�zzz/ *$,! §O/a;Z4A40TI»u�M1& DEHY-2 Still Vent Condenser Overhead To VRU Assume 95%'I?$ ntime of VRU for CRI GLYCaIc Model Crawford Trail Compressor Station Uncontrolled Emissions if VRU down I Component (Ib/hr) tons/yr N en t-4 6O6o666c0o0660600 Total Emissions 89.646 19.6 Total NMNE VOC Emissions 8.4 Total scf/hr to VRU from condenser vent: 368 Total acfm to VRU: 6.84 Methane 36.293 Ethane 15.104 Propane 10.069 i -Butane 3.625 n -Butane 4.301 i -Pentane 1.983 n -Pentane 1.649 Cyclopentane 0.222 n -Hexane 0.930 Cyclohexane 1.331 Other Hexanes 1.717 Heptanes 1.178 Methyleyclohexane 1.648 Benzene 3.933 Toluene 4273 Ethylbenzene 0.108 Xylenes 1.010 2,2,4-Trimethylpentan 0.062 C8+ Heavies 0.210 Crawford Trail Emissions k rd W N h., 00 0 N_ pi O O N N O c M ri 0o N a V 7 N .� N N n "� V .y , `L b oo g N 7 v r- 0 vl O b Mea�� 0 r 0.0 V N- N en P. 0o V n- b o 0 Q g' M- t� N N O .: O O O O O O 8. 0 N M vl N CO vl N N 00 N lD - 10 mr V O N h N 00 ^ N wl 7 C CO M 0 N N O O a N V rD 0 1. 0 N N N N N N N ON NCO -. ^ DO N 3 I' d• Y Y as ea 313 O x 111! w 0 to O �L Fii0y 0 C u ad • U 0 m(pw00LO0 G O OH L T 00 O W O U W W .". a4'.1 c iv'x C1 F W X U F 'S Note: Flash Tank Vapor Composition from GLYCaIc DEHY-2 Flash Tank Overhead To VRU Volumetric Flow From GLYCaIc Stream Data Crawford Trail Compressor Station µ. ly My. o -. g g 8 N- V= 8$ o o, 8' 8 8 8 8 8 80, N C C O O O O O O O O O G C G O O O N IFlash to HTR -1 Fuel Gas 1290 scf/hr I O O O O O O en in b 00 M^ 0 N M O 0o r N N O rn O a. 0 a- -. - O 0 a. _ 0 0 0 0 0 0 63.712 0 CN. 0 E �i�'z"3 CO 00 V 0 7 o o 0 o p N N a. O V In CO N N 0000 00 C) 06 r. " 0 a 4.0 n 0 s o roe ° u u 0 6 G° D c x T .2 w tee. c c0xm€- >Ct'.oH A Crawford Trail Emis craword_90MM GRI-GLYCa1C VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Crawford Trail - using Clough Inlet Analysis File Name: C:\williams\New Sites\crawford Trail\Crawford_90MMDEHY.ddf Date: November 20, 2006 DESCRIPTION: Description: 90 MMscf/day TEG Flash to Condenser; 120 deg F condenser at 950 psi contactor pressure 40 psi Flash Tk @ 100E w/all emissions to VRU; Assumed 5% downtime (438 hr/yr) for VRU, otherwise all vapors are captured Annual Hours of Operation: 438.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 1.6398 39.355 0.3591 Ethane 2.2995 55.188 0.5036 Propane 2.9590 71.016 0.6480 Isobutane 1.4177 34.024 0.3105 n -Butane 1.9666 47.198 0.4307 Isopentane 0.9084 21.802 0.1989 n -Pentane 0.8366 20.078 0.1832 cyclopentane 0.1731 4.155 0.0379 n -Hexane 0.5444 13.067 0.1192 Cyclohexane 1.0905 26.172 0.2388 Other Hexanes 0.9421 22.609 0.2063 He tapes 0.7341 17.619 0.1608 Methylcyclohexane 1.3061 31.346 0.2860 2,2,4-Trimethylpentane 0.0277 0.665 0.0061 Benzene 3.8178 91.627 0.8361 Toluene Ethyl benzene Xylenes C8+ Heavies 4.1068 0.1015 0.9652 0.0132 98.564 2.437 23.166 0.316 0.8994 0.0222 0.2114 0.0029 Total Emissions 25.8502 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEx Emissions UNCONTROLLED REGENERATOR EMISSIONS 25.8502 21.9109 9.5635 8.9914 620.404 5.6612 620.404 525.861 229.525 215.794 5.6612 4.7985 2.0944 1.9691 Component lbs/hr lbs/day tons/yr Page 1 c rawo rd_90MM Methane 1.6432 39.436 0.3599 Ethane 2.3228 55.748 0.5087 Propane 3.1090 74.615 0.6809 Isobutane 1.5603 37.446 0.3417 n -Butane 2.2385 53.724 0.4902 Isopentane 1.2498 29.995 0.2737 n -Pentane 1.2046 28.910 0.2638 Cyclopentane 0.2816 6.758 0.0617 n -Hexane 1.1141 26.738 0.2440 Cyclohexane 2.7231 65.353 0.5963 other Hexanes 1.6517 39.642 0.3617 Heptanes 2.8233 67.758 0.6183 Methylcyclohexane 5.2727 126.546 1.1547 2,2,4-Trimethylpentane 0.1066 2.559 0.0234 Benzene 11.0735 265.764 2.4251 Toluene Ethyl benzene Xylenes C8+ Heavies 26.8005 1.8720 19.9723 13.5530 643.211 44.927 479.336 325.271 5.8693 0.4100 4.3739 2.9681 Total Emissions 100.5724 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions FLASH TANK OFF GAS 100.5724 96.6064 60.9390 59.7183 2413.738 22.0254 2413.738 2318.554 1462.536 1433.239 22.0254 21.1568 13.3456 13.0783 Component lbs/hr lbs/day tons/yr Methane 34.6533 831.679 7.5891 Ethane 12.8050 307.319 2.8043 Propane 7.1099 170.637 1.5571 Isobutane 2.2071 52.971 0.4834 n -Butane 2.3344 56.026 0.5112 Isopentane 1.0741 25.779 0.2352 n -Pentane 0.8122 19.493 0.1779 Cyclopentane 0.0492 1.181 0.0108 n -Hexane 0.3857 9.257 0.0845 cyclohexane 0.2409 5.782 0.0528 Other Hexanes 0.7747 18.593 0.1697 Heptanes 0.4439 10.653 0.0972 Methylcyclohexane 0.3421 8.210 0.0749 2,2,4-Trimethylpentane 0.0347 0.834 0.0076 Benzene 0.1151 2.762 0.0252 Toluene Ethyl benzene Xylenes c8+ Heavies 0.1663 0.0062 0.0443 0.1970 3.990 0.150 1.064 4.728 0.0364 0.0014 0.0097 0.0431 Total Emissions 63.7962 1531.108 13.9714 Total Hydrocarbon Emissions 63.7962 1531.108 13.9714 Page 2 Total VOC Emissions Total HAP Emissions Total BTEX Emissions craword_90MM 16.3379 392.110 0.7524 18.057 0.3319 7.967 COMBINED REGENERATOR VENT/FLASH GAS EMISSIONS 3.5780 0.1648 0.0727 Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene xylenes C8+ Heavies 36.2931 15.1044 10.0689 3.6248 4.3010 1.9825 1.6488 0.2224 0.9301 1.3314 1.7167 1.1780 1.6482 0.0624 3.9329 4.2731 0.1078 1.0096 0.2102 871.034 362.507 241.653 86.995 103.224 47.581 39.571 5.337 22.323 31.954 41.202 28.271 39.556 1.499 94.389 102.554 2.586 24.230 5.044 7.9482 3.3079 2.2051 0.7938 0.9419 0.4342 0.3611 0.0487 0.2037 0.2916 0.3760 0.2580 0.3609 0.0137 0.8613 0.9358 0.0236 0.2211 0.0460 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions 89.6463 89.6463 38.2488 10.3159 9.3233 2151.512 19.6325 2151.512 917.971 247.582 223.760 COMBINED REGENERATOR VENT/FLASH GAS EMISSION CONTROL REPORT: 19.6325 8.3765 2.2592 2.0418 Component Uncontrolled tons/yr Controlled % Reduction tons/yr Methane Ethane Propane Isobutane n -Butane isopentane n -Pentane Cyclopentane n -Hexane cyclohexane other Hexanes Heptanes 7.9489 3.3130 2.2379 0.8251 1.0015 0.5089 0.4417 0.0724 0.3284 0.6491 0.5314 0.7155 Page 3 7.9482 3.3079 2.2051 0.7938 0.9419 0.4342 0.3611 0.0487 0.2037 0.2916 0.01 0.15 1.47 3.78 5.95 14.69 18.25 32.78 37.98 55.08 0.3760 29.25 0.2580 63.94 Methyl cyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethyl benzene Xylenes C8+ Heavies craword_90MM 1.2296 0.0310 2.4503 5.9057 0.4113 4.3837 3.0112 0.3609 0.0137 0.8613 0.9358 0.0236 0.2211 0.0460 70.65 55.83 64.85 84.15 94.26 94.96 98.47 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 35.9967 19.6325 35.9967 24.7348 13.5104 13.1510 19.6325 8.3765 2.2592 2.0418 45.46 45.46 66.13 83.28 84.47 CONDENSER condenser Outlet Temperature: Condenser Pressure: Condenser Duty: Hydrocarbon Recovery: Produced water: VOC Control Efficiency: HAP Control Efficiency: BTEX Control Efficiency: Dissolved Hydrocarbons in water: Component 120.00 deg. F 12.50 psia 2.88e-001 MM BTU/hr 6.01 bbls/day 25.31 bbls/day 77.32 % 84.31 % 84.94 % 620.41 mg/L Emitted condensed Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethyl benzene Xylenes 0.64% 98.83% 99.68% 99.79% 99.00% 95.18% 90.86% 87.85% 72.68% 69.45% 61.48% 48.87% 40.05% 57.03% 26.00% 24.77% 25.97% 34.48% 15.32% 5.42% 99.36% 1.17% 0.32% 0.21% 1.00% 4.82% 9.14% 12.15% 27.32% 30.55% 38.52% 51.13% 59.95% 42.97% 74.00% 75.23% 74.03% 65.52% 84.68% 94.58% 4.83% 95.17% Page 4 craword_90MM C8+ Heavies 0.10% ABSORBER 99.90% NOTE: Because the calculated Absorber Stages was below the minimum allowed, GRI-GLVCalc has set the number of Absorber stages to 1.25 and has calculated a revised Dry Gas Dew Point. Calculated Absorber stages: 1.25 calculated Dry Gas Dew Point: Temperature: Pressure: Dry Gas Flow Rate: Glycol Losses with Dry Gas: wet Gas Water Content: calculated Wet Gas water Content: specified Lean Glycol Recirc. Ratio: Component 7.17 lbs. H20/MMSCF 120.0 deg. F 950.0 psig 90.0000 MMSCF/day 3.1841 lb/hr Saturated 105.96 lbs. H2O/MMSCF 3.80 gal/lb H2O Remaining Absorbed in Dry Gas in Glycol water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n=Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4 -Tri methyl pentane Benzene Toluene Ethyl benzene xylenes C8+ Heavies FLASH TANK 6.75% 93.25% 99.70% 0.30% 99.97% 0.03% 99.97% 0.03% 99.92% 0.08% 99.89% 0.11% 99.85% 0.15% 99.81% 0.19% 99.82% 0.18% 99.78% 0.22% 99.05% 0.95% 99.66% 0.34% 98.52% 1.48% 99.73% 0.27% 99.43% 0.57% 98.48% 1.52% 99.75% 0.25% 88.86% 11.14% 85.20% 14.80% 82.11% 17.89% 76.16% 23.84% 97.91% 2.09% Flash Control: vented to atmosphere Flash Temperature: 100.0 deg. F Flash Pressure: 40.0 psig Left in Page 5 Removed in craword_90MM Component Glycol Flash Gas Water carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane cyclohexane other Hexanes Heptanes Methylc clohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene xylenes C8+ Heavies REGENERATOR 99.98% 41.06% 4.33% 4.53% 15.35% 30.42% 41.41% 48.95% 54.01% 59.93% 85.19% 74.41% 92.13% 68.39% 86.48% 94.15% 75.79% 99.02% 99.43% 99.70% 99.81% 98.74% 0.02% 58.94% 95.67% 95.47% 84.65% 69.58% 58.59% 51.05% 45.99% 40.07% 14.81% 25.59% 7.87% 31.61% 13.52% 5.85% 24.21% 0.98% 0.57% 0.30% 0.19% 1.26% No Stripping Gas used in regenerator. Remaining component in Glycol Distilled overhead water carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4 -Tri methyl pentane Benzene Toluene Ethylbenzene 34.12% 0.00% 0.00% 0.00% 0.00% 0.00%. 0.00% 0.00% 0.93% 0.83% 0.59% 0.67% 3.47% 1.46% 0.58% 4.25% 1.98% 5.05% 7.95% 10.44% Page 6 65.88% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 99.07% 99.17% 99.41% 99.33% 96.53% 98.54% 99.42% 95.75% 98.02% 94.95% 92.05% 89.56% craword_90MM Xylenes 12.95% c8+ Heavies 12.17% STREAM REPORTS: 87.05% 87.83% WET GAS STREAM Temperature: Pressure: Flow Rate: 120.00 deg. F 964.70 psia 3.76e+006 scfh Component conc. Loading (vol%) (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethyl benzene 2.23e-001 3.98e+002 2.95e+000 1.29e+004 1.O1e-001 2.80e+002 8.65e+001 1.37e+005 6.69e+000 1.99e+004 2.04e+000 4.43e-001 4.21e-001 1.82e-001 1.26e-001 4.99e-003 5.19e-002 2.39e-002 1.07e-001 5.79e-002 8.91e+003 2.55e+003 2.43e+003 1.30e+003 8.99e+002 3.47e+001 4.43e+002 2.00e+002 9.12e+002 5.75e+002 3.79e-002 3.69e+002 4.99e-003 5.65e+001 1.30e-002 1.00e+002 2.00e-002 1.82e+002 9.98e-004 1.05e+001 xylenes 7.98e-003 8.40e+001 C8+ Heavies 3.89e-002 6.57e+002 Total Components 100.00 1.91e+005 DRY GAS STREAM Temperature: Pressure: F10w Rate: 120.00 deg. F 964.70 psia 3.75e+006 scfh Component Conc. Loading (vol%) (lb/hr water 1.S1e-002 2.69e+001 Carbon Dioxide 2.95e+000 1.28e+004 Nitrogen 1.01e-001 2.80e+002 Page 7 craword_9oMM Methane 8.67e+001 1.37e+005 Ethane 6.70e+000 1.99e+004 Propane 2.04e+000 8.90e+003 Isobutane 4.44e-001 2.55e+003 n -Butane 4.21e-001 2.42e+003 isopentane 1.82e-001 1.30e+003 n -Pentane 1.26e-001 8.97e+002 cyclopentane 4.95e-003 3.43e+001 n -Hexane 5.18e-002 4.42e+002 Cyclohexane 2.37e-002 1.97e+002 other Hexanes 1.07e-001 9.09e+002 Heptanes 5.77e-002 5.71e+002 Methylc clohexane 3.74e-002 3.63e+002 2,2,4-Trimethylpentane 4.99e-003 5.63e+001 Benzene 1.16e-002 8.92e+001 Toluene 1.70e-002 1.55e+002 Ethylbenzene 8.21e-004 8.62e+000 Xylenes 6.10e-003 6.40e+001 C8+ Heavies 3.82e-002 6.43e+002 Total Components 100.00 1.90e+005 LEAN GLYCOL STREAM Temperature: 120.00 deg. F Flow Rate: 2.28e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.84e+001 1.26e+004 water 1.50e+000 1.92e+002 carbon Dioxide 2.98e-011 3.82e-009 Nitrogen 6.46e-014 8.28e-012 Methane 9.51e-018 1.22e-015 Ethane 5.57e-008 7.14e-006 Propane 3.24e-009 4.16e-007 Isobutane 8.81e-010 1.13e-007 n -Butane 8.85e-010 1.13e-007 isopentane 9.11e-005 1.17e-002 n -Pentane 7.90e-005 1.O1e-002 Cyclopentane 1.30e-005 1.66e-003 n -Hexane 5.88e-005 7.54e-003 Cyclohexane 7.64e-004 9.80e-002 other Hexanes 1.91e-004 2.45e-002 Heptanes 1.28e-004 1.64e-002 Methylcyclohexane 1.82e-003 2.34e-001 2,2,4-Trimethylpentane 1.68e-005 2.15e-003 Benzene 4.59e-003 5.89e-001 Toluene 1.80e-002 2.31e+000 Ethylbenzene 1.70e-003 2.18e-001 xylenes 2.32e-002 2.97e+000 C8+ Heavies 1.46e-002 1.88e+000 Page 8 craword_90MM Total Components 100.00 1.28e+004 RICH GLYCOL STREAM Temperature: 120.00 deg. F Pressure: 964.70 psia Flow Rate: 2..39e+001 qpm NOTE: Stream has more than one phase. Component Conc. Loading (wt%) (lb/hr) TEG 9.42e+001 1.26e+004 water 4.21e+000 5.64e+002 carbon Dioxide 2.85e-001 3.82e+001 Nitrogen 6.19e-004 8.28e-002 Methane 2.71e-001 3.63e+001 Ethane 1.13e-001 1.51e+001 Propane 7.63e-002 1.02e+001 Isobutane 2.81e-002 3.77e+000 n -Butane 3.42e-002 4.57e+000 Isopentane 1.74e-002 2.34e+000 n -Pentane 1.51e-002 2.03e+000 cyclopentane 2.48e-003 3.32e-001 n -Hexane 1.13e-002 1.51e+000 cyclohexane 2.29e-002 3.06e+000 Other Hexanes 1.83e-002 2.45e+000 Heptanes 2.45e-002 3.28e+000 Methylcyclohexane 4.37e-002 5.85e+000 2,2,4-Trimethylpentane 1.07e-003 1.44e-001 Benzene 8.80e-002 1.18e+001 Toluene 2.19e-001 2.93e+001 Ethylbenzene 1.57e-002 2.10e+000 xylenes 1.72e-001 2.30e+001 C8+ Heavies 1.17e-001 1.56e+001 Total Components 100.00 1.34e+004 FLASH TANK OFF GAS STREAM Temperature: 100.00 deg. F Pressure: 54.70 psia Flow Rate: 1.29e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.73e-001 1.06e-001 Carbon Dioxide 1.50e+001 2.25e+001 Nitrogen 8.31e-002 7.92e-002 Methane 6.35e+001 3.47e+001 Ethane 1.25e+001 1.28e+001 Propane 4.74e+000 7.11e+000 Page 9 craword_90MM Isobutane 1.12e+000 2.21e+000 n -Butane 1.18e+000 2.33e+000 Isopentane 4.38e-001 1.07e+000 n -Pentane 3.31e-001 8.12e-001 Cyclopentane 2.06e-002 4.92e-002 n -Hexane 1.32e-001 3.86e-001 cyclohexane 8.41e-002 2.41e-001 Other Hexanes 2.64e-001 7.75e-001 Heptanes 1.30e-001 4.44e-001 Methylcyclohexane 1.02e-001 3.42e-001 2,2,4-Trimethylpentane 8.94e-003 3.47e-002 Benzene 4.33e-002 1.15e-001 Toluene 5.30e-002 1.66e-001 Ethylbenzene 1.73e-003 6.24e-003 Xylenes 1.23e-002 4.43e-002 C8+ Heavies 3.40e-002 1.97e-001 Total Components 100.00 8.65e+001 FLASH TANK GLYCOL STREAM Temperature: 100.00 deg. F Flow Rate: 2.38e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.48e+001 1.26e+004 water 4.24e+000 5.64e+002 Carbon Dioxide 1.18e-001 1.57e+001 Nitrogen 2.70e-005 3.59e-003 Methane 1.24e-002 1.64e+000 Ethane 1.75e-002 2.32e+000 Propane 2.34e-002 3.11e+000 Isobutane 1.17e-002 1.56e+000 n -Butane 1.68e-002 2.24e+000 Isopentane 9.48e-003 1.26e+000 n -Pentane 9.13e-003 1.21e+000 cyclopentane 2.13e-003 2.83e-001 n -Hexane 8.43e-003 1.12e+000 Cyclohexane 2.12e-002 2.82e+000 other Hexanes 1.26e-002 1.68e+000 Heptanes 2.13e-002 2.84e+000 Methylcyclohexane '4..14e-002 5.51e+000 2,2,4-Trimethylpentane 8.18e-004 1.09e-001 Benzene 8.77e-002 1.17e+001 Toluene 2.19e-001 2.91e+001 Ethylbenzene 1.57e-002 2.09e+000 xylenes 1.72e-001 2.29e+001 C8+ Heavies 1.16e-001 1.54e+001 Total Components 100.00 1.33e+004 Page 10 craword_90MM REGENERATOR OVERHEADS STREAM Temperature: 212.00 deg. F Pressure: 14.70 psia Flow Rate: 8.42e+003 scfh Component Conc. Loading (vol%) (lb/hr) water 9.29e+001 3.71e+002 carbon Dioxide 1.61e+000 1.57e+001 Nitrogen 5.77e-004 3.59e-003 Methane 4.61e-001 1.64e+000 Ethane 3.48e-001 2.32e+000 Propane 3.18e-001 3.11e+000 Isobutane 1.21e-001 1.56e+000 n -Butane 1.73e-001 2.24e+000 Isopentane 7.80e-002 1.25e+000 n -Pentane 7.52e-002 1.20e+000 Cyclopentane 1.81e-002 2.82e-001 n -Hexane 5.82e-002 1.11e+000 Cyclohexane 1.46e-001 2.72e+000 Other Hexanes 8.63e-002 1.65e+000 Heptanes 1.27e-001 2.82e+000 Methylcyclohexane 2.42e-001 5.27e+000 2,2,4-Trimethylpentane 4.20e-003 1.07e-001 Benzene 6.39e-001 1.11e+001 Toluene 1.31e+000 2.68e+001 Ethylbenzene 7.94e-002 1.87e+000 xylenes 8.47e-001 2.00e+001 C8+ Heavies 3.58e-001 1.36e+001 Total components 100.00 4.88e+002 CONDENSER VENT GAS STREAM Temperature: 120.00 deg. F Pressure: 12.50 psia Flow Rate: 3.68e+002 scfh Component Conc. Loading (vol%) (lb/hr) water 1.37e+001 2.39e+000 carbon Dioxide 3.63e+001 1.55e+001 Nitrogen 1.32e-002 3.57e-003 Methane 1.05e+001 1.64e+000 Ethane 7.88e+000 2.30e+000 Propane 6.92e+000 2.96e+000 Isobutane 2.51e+000 1.42e+000 n -Butane 3.49e+000 1.97e+000 Isopentane 1.30e+000 9.08e-001 n -Pentane 1.20e+000 8.37e-001 Cyclopentane 2.54e-001 1.73e-001 Page 11 craword_90MM n -Hexane 6.51e-001 5.44e-001 Cyclohexane 1.34e+000 1.09e+000 other Hexanes 1.13e+000 9.42e-001 Heptanes 7.55e-001 7.34e-001 Methylcyclohexane 1.37e+000 1.31e+000 2,2,4-Trimethylpentane 2.50e-002 2.77e-002 Benzene 5.04e+000 3.82e+000 Toluene 4.59e+000 4.11e+000 Ethylbenzene 9.86e-002 1.02e-001 xylenes 9.37e-001 9.65e-001 C8+ Heavies 7.98e-003 1.32e-002 Total Components 100.00 4.37e+001 CONDENSER PRODUCED WATER STREAM Temperature: 120.00 deg. F Flow Rate: 7.38e-001 gpm Component Conc. Loading (wt%) (1b/hr) (ppm) water 9.99e+001 3.69e+002 999109. Carbon Dioxide 2.71e-002 9.99e-002 271. Nitrogen 1.63e-007 6.00e-007 0. Methane 1.44e-004 5.31e-004 1. Ethane 2.30e-004 8.49e-004 2. Propane 3.06e-004 1.13e-003 3. Isobutane 7.99e-005 2.95e-004 1. n -Butane 1.47e-004 5.43e-004 1. Isopentane 4.80e-005 1.77e-004 0. n -Pentane 4.74e-005 1.75e-004 0. Cyclopentane 6.90e-005 2.55e-004 1. n -Hexane 2.56e-005 9.46e-005 0. cyclohexane 2.89e-004 1.07e=003 3. other Hexanes 3.57e-005 1.32e-004 0. Heptanes 1.92e-005 7.08e-005 0. Methylcyclohexane 1.65e-004 6.11e-004 2. 2,2,4-Trimethylpentane 4.83e-007 1.78e-006 0. Benzene 2.$Se-002 1.05e-001 285. Toluene 2.53e-002 9.33e-002 253. Ethylbenzene 4.71e-004 1.74e-003 5. xylenes 6.21e-003 2.29e-002 62. C8+ Heavies 2.18e-007 8.07e-007 0. Total Components 100.00 3.69e+002 1000000. CONDENSER RECOVERED OIL STREAM Temperature: 120.00 deg. F Flow Rate: 1.75e-001 gpm component Conc. Loading Page 12 craword_90MM (wt%) (lb/hr) water 4.70e-002 3.51e-002 Carbon Dioxide 1.13e-001 8.43e-002 Nitrogen 1.45e-005 1.08e-005 Methane 3.84e-003 2.86e-003 Ethane 3.O1e-002 2.25e-002 Propane 1.99e-001 1.49e-001 Isobutane 1.91e-001 1.42e-001 n -Butane 3.64e-001 2.71e-001 Isopentane'4.57e-001 3.41e-001 n -Pentane 4.93e-001 3.68e-001 cyclopentane 1.45e-001 1.O8e-001 n -Hexane 7.63e-001 5.70e-001 Cyclohexane 2.19e+000 1.63e+000 Other Hexanes 9.51e-001 7.10e-001 Heptanes 2.80e+000 2.09e+000 Methylcyclohexane 5.32e+000 3.97e+000 2,2,4-Trimethylpentane 1.06e-001 7.89e-002 Benzene 9.58e+000 7.15e+000 Toluene 3.03e+001 2.26e+001 Ethylbenzene 2.37e+000 1.77e+000 xylenes 2.54e+001 1.90e+001 C8+ Heavies 1.81e+001 1.35e+001 Total Components 100.00 7.46e+001 Page 13 ON Engineering Company, Inc. (432) 697-2292 (432) 520-2292 Fax (432) 697.2310 R. 0. BOX 4185 MIDLAND, TEXAS 79704 2404 COMMERCE MIDLAND, TEXAS 79703 www.hybon.com Date: October 11, 2006 Mr. Gerard G. Alberts Williams Company Principal Environmental Specialist 1515 Arapahoe St., Tower 3, Suite 1000 Denver, CO 80202 Mr. Alberts, Per our conversation yesterday, electric drive vapor recovery units have very minimal down time. As a packager of vapor recovery units for over 50 years, as well as a company that maintains over 100 similar size units in a rental fleet that are often on "run time" contracts, we estimate average run time on Hy -Bon electric drive vapor recovery units to average 95%. This down time percentage assumes that the unit is properly installed and properly maintained. This percentage coincides with the "over 95%" quoted in an article we had published in the American Oil and Gas Reporter (attached — see last sentence in the article). It also matches the figures used by the Natural Gas STAR program. The STAR presentation on vapor recovery states "vapor recovery can capture up to 95% of the gas from the tanks". We can make no assertions as to the run time viability of other manufacturer's equipment — especially in vapor recovery service. Vapor recovery is a very specialized application that requires a great deal of experience in working with wet gas at very low pressures. Many companies represent that they sell "vapor recovery units" but actually have little or no experience in this niche application — resulting in projects with extremely poor run times capturing gas. However, we are confident in the run time estimates we provide for Hy -Bon equipment, and it's my sincere hope we have an opportunity to work with Williams Company on this project. Best Regards. .earT S R�cIiRf"Gff' Larry S. Richards President 1/24/2006 NOVEMBER 2006 • CRAWFORD TRAIL COMPRESSOR STATION CRAWFORD TRAIL COMPRESSOR STATION NORMAL OPERATION WITH VRU RUNNING 8,322 HOURS PER YEAR CONDENSATE FLASII TO VRU, TANK WORKING/BREATHING LOSSES VENTED TO ATMOSPHERE TANK -0I E&P TANK2.0 CONDENSATE TANK WORKING/BREATHING LOSSES Annual Hrs ofOpemtion Number of Tanks Condensate Flow Rate Operating Hours/Year Inlet Separator Temperature Inlet Separator Pressure Site Atmospheric Pressure Stable Oil API Gravity Stable Oil Reid Vapor Press. E&PTANK2.0 Output VOC, C3+ Benzene Toluene Ethylbenzene Xylenes n -Hexane Methane Ethane Aggregate HAP 8322 (<= 8760 hr/yr) 3 40.0 bbl/day total 365 hours/yr 74 degF 245 psig 12.5 psis 58.5 deg. API 5 psis Uncontrolled Perm/Bed/Controlled It& Ea &IL (BT 11.512 47.9 3.609 15.02 0.055 0.2 0.013 0.05 0.080 0.3 0.020 0.08 0.003 0.0 0.001 0.00 0.025 0.1 0.007 0.03 0.213 0.9 0.052 0.22 5.648 23,5 0.173 0.72 9,581 19,1 0.836 3.48 0.376 1.6 0.093 0.39 Pressurized Nash Oil Composition From SAP TANK Model Run Liquid Component l% Vol.) Hydrogen Sulfide 0.000 Oxygen 0.000 Carbon Dioxide 0.332 Nitrogen 0.000 Methane 0.851 Ethane 1.598 Propane Isobutane n -Butane Isopenlane Pentanes Hexanes Heptanes Octanes Nonanes Decanes+ Benzene Toluene Ethylbenzene Xylenes n -Hexane 2,2,4-Trimethylpentanl Total An Consdluenls 2.644 1.611 2.333 2.464 2.570 8.093 18.839 14.037 12.157 16.019 1.094 5.403 0.660 5.811 3.466 0.021 100.000 CRAWFORD TRAIL COMPRESSOR STATION ALTERNATIVE/MAINTENANCE OPERATION WITH VRU DOWN-TIME OF 438 HOURS PER YEAH CONDENSATE FLASH AND TANK WORKING/BREATHING LOSSES VENTED TO ATMOSPHERE TANK -0I E&P TANK2.0 CONDENSATE INPUT Annual Hss of Operation 438 (<= 8760 hr/yr) Number of Tanks 3 Condensale Flow Ram 40.0 bbl/day total Operating Hours/Year 365 hours/yr Bulk Condensate Temperatur 60 deg F Flash Tank Pressure 20 prig Site Atmospheric Pressure 12.5 psis Stable Oil API Gravity Stable Oil Reid Vapor Press. E&P TANK2.0 Outop( VOC, C3+ Benzene Toluene Ethylbenzene Xylenes n -Hexene Methane Ethane Aggregate HAP 58.5 deg. API 5 psis Permlted/Uncontroiled 11.512 5042 2.52 0.055 24 0.01 0.080 35 0.02 0.003 1 0.00 0.025 11 0.01 0.213 93 0.05 5.648 2474 1.24 4.581 2006 1.00 0.376 165 0.08 Pressurized Condensate Analysis Augur 20. 2003 Liquid Component IN Vol) Hydrogen Sulfide 0.000 Oxygen 0.000 Carbon Dioxide 1.175 Nitrogen 0.000 Methane 7.799 Ethane 3.360 Propane Isobutane n -Butane lsopcntane Pentanes hexanes Heptanes Octanes Nonanes Oceans+ Benzene Toluene Ethylbenzene Xylenes n -Hexane 2,2,4-Trimeihylpentam Total All Constituents 3.149 1.604 2.239 2151 2.328 7.231 16.755 12.466 10.792 14.219 0.975 4.801 0.586 5.159 3.092 0.019 100.000 Cnwdord Tra8 Eminlnm 11n4n4a6 NOVEMBER 2006 - CRAWFORD TRAIL COMPRESSOR STATION CRAWFORD TRAIL COMPRESSOR STATION TOTAL PERMITTED TANK FLASH AND WORKING/BREATHING EMISSIONS TO ATMOSPHERE TOTAL OPERATING HOURS 8,760 HOURS PER YEAR Normal Permitted/Maintenance Total Permitted Operation Operations Tank Operations Maximum Hours/Yr 8322 438 8760 Permitted Emissions 15.0 2.5 17.5 VOC Emission (tpy) Benzene Emission (Ib/yr) 108 24.1 132 Benzene Emission (tpy) 0.1 0.0 0.1 Toluene Emission (lb/yr) 166 35.0 201 Toluene Emission (tpy) 0.1 0.0 0.1 Ethylbenzene Emission (Ib/yr', 8 1,3 10 Ethylbenzene Emissions (tpy) 0.0 0.0 0.0 Xylenes Emission (Ib/yr) 58 11.0 69 Xylenes Emission (Ipy) 0.0 0.0 0.0 n -Hexane Emission (1b/yr) 433 93.3 526 n -Hexane Emission (tpy) 0.2 0.0 0.3 A8g. HAP Emission (tpy) 0.4 0.1 0.5 PFF/Uatontrolled Emissions 47.9 2.5 50.4 VOC Emission (tpy) Benzene Emission (Ib/yr) 458 24.1 482 Beaune Emission (Ipy) 0.2 0.0 0.2 Toluene Emission (Iblyr) 666 35.0 701 Toluene Emission (tpy) 0.3 0.0 0.4 Ethylbenzene Emission (Ib/yr; 25 1.3 26 Ethylbenzene Emissions (Ipy) 0.0 0.0 0.0 Xylenes Emission (1b/yr) 208 11.0 219 Xylenes Emission (tpy) 0.1 0.0 0.1 n -Hexane Emission (Ib/yr) 1773 93.3 1866 n -Hexane Emission (tpy) 0.9 0.0 0.9 Agg. HAP Emission (tpy) 1.6 0.1 1.6 Overall Control Efficiency: 65% Crawford Trail Emission' RAP TANK V2.0 Calculation Report--- Developed by DB Robinson 4 Associates Ltd. 2006.11.24 • Project Setup Information Project File Plowsheet Selection Calculation Method Control Efficiency Known Separator Stream Entering Air Composition Piled Name Well Name Well ID Date C:\Williame\New Sites\Crawford Trail\Crawford245_32psi.ept : Oil Tank with Separator RVP Distillation 0.0% : High Pressure Oil : No Crawford Trail C.S. Sherrard Park Compressor Station AUG. 2003 Pressurized Condensate Sample Prom 245 psig Separator to Plash Tank • 20 psig to Atmospheric Uncontrolled 438 Hr/1 2006.11.24 • Data Input Separator Pressure Separator Temperature Ambient Pressure Ambient Temperature ClOe 50 C10+ MW -- Nigh Pressure oil No. Component 1 H25 2 02 3 CO2 4 N2 5 Cl 6 C2 7 C3 8 i -C4 9 n -C4 10 i-05 11 n-05 12 C6 13 C7 14 C8 15 C9 16 C10+ 17 Benzene 18 Toluene 19 8 -Benzene 20 Xylene 21 n -C6 22 224Trimetbylp -- Sales 011 245.001peig] t 74.001P1 t 12.50(psia) 50.00(71 : 0.7440 s 153.89 mol % 0.0000 0.0000 1.1750 0.0000 7.7990 3.3600 3.1490 1.6040 2.2390 2.2510 2.3280 7.2310 16.7550 12.4660 10.7920 14.2190 0.9750 4.8010 0.5860 5.1590 3.0920 0.0190 Production Rate Days of Annual Operation API Gravity Reid Vapor Preoeure s 40(bb1/day] t 365 (days/year] s 58.5 5.00(peia) Calculation Results • -- Emission Summary Item Uncontrolled (ton/yr] Uncontrolled (lb/hr] page 1 Controlled (ton/yr) Controlled (lb/hr] ESP TAN( V2.0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2006.11.24 Total HAPS Total HC voce, 02. VOCs, C3♦ 1.650 95.223 70.485 50.423 0.377 21.740 16.092 11.512 Uncontrolled Recovery Info. Vapor 7.0100 [MSCPD] HC Vapor 6.5200 [MSCPD) 00R 175.25 [SCP/bbl] Emission Composition 1.650 95.223 70.485 50.423 0.377 21.740 16.092 11.512 No Component Uncontrolled Uncontrolled Controlled Controlled [ton/yrl [lb/hrl [ton/yr] [1b/hr] 1 028 0.000 0.000 0.000 0.000 2 02 0.000 0.000 0.000 0.000 3 CO2 10.264 2.343 10.264 2.343 4 N2 0.000 0.000 0.000 0.000 5 Cl 24.737 5.648 24.737 5.648 6 02 20.063 4.581 20.063 4.581 7 C3 23.776 5.428 23.776 5.428 8 1-C4 6.921 1.580 6.921 1.580 9 n -C4 6.670 1.523 6.670 1.523 10 1-05 3.194 0.729 3.194 0.729 11 n-05 2.373 0.542 2.373 0.542 12 C6 2.822 0.644 2.822 0.644 13 07 2.265 0.517 2.265 0.517 14 C8 0.542 0.124 0.542 0.124 15 C9 0.163 0.037 0.163 0.037 16 C10♦ 0.045 0.010 0.045 0.010 17 Benzene 0.242 0.055 0.242 0.055 18 Toluene 0.349 0.080 0.349 0.080 19 H -Benzene 0.014 0.003 0.014 0.003 20 Xylene. 0.109 0.025 0.109 0.025 21 n-06 0.935 0.213 0.935 0.213 22 224Trimetbylp 0.002 0.000 0.002 0.000 Total 105.486 24.084 105.486 24.084 -- Stream Data No. Component 1 H25 2 02 3 CO2 4 N2 5 Cl 6 C2 7 C3 8 1-C4 9 n -C4 10 1-05 11 n-05 12 C6 13 C7 14 C8 15 C9 16 C10♦ 17 Benzene 18 Toluene 19 B -Benzene 20 Xylenes 21 n -C6 22 224Trimethylp MW LP O11 Plash 011 Sale Oil Plash Gas W&9 0a8 Total 701i861one mol % mol % mol % mol % mol % mol a 34.80 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 44.01 1.1728 0.1266 0.0000 7.3420 4.3776 6.9102 28.01 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 16.04 7.7545 0.2772 0.0000 51.8437 9.5870 45.6889 30.07 3.3579 0.7185 0.0030 18.9207 24.7502 19.7698 44.10 3.1497 1.7691 0.5277 11.2899 43.4612 15.9758 58.12 1.6047 1.3644 1.2115 3.0212 6.5029 3.5283 58.12 2.2401 2.0967 2.0029 3.0851 5.2488 3.4002 72.15 2.2522 2.4222 2.4445 1.2500 1.6731 1.3116 72.15 2.3293 2.5665 2.6062 0.9306 1.2326 0.9746 86.16 7.2351 8.3011 8.5106 0.9497 1.2632 0.9953 100.20 16.7646 19.4967 20.0502 0.6556 0.9054 0.6920 114.23 12.4732 14.5656 14.9934 0.1359 0.1969 0.1448 128.28 10.7982 12.6235 12.9976 0.0360 0.0584 0.0392 153.89 14.2272 16.6388 17.1338 0.0078 0.0133 0.0086 78.11 0.9756 1.1262 1.1562 0.0874 0.1183 0.0919 92.13 4.8038 5.6005 5.7628 0.1058 0.1504 0.1123 106.17 0.5863 0.6851 0.7054 0.0038 0.0056 0.0040 106.17 5.1620 6.0326 6.2110 0.0283 0.0425 0.0304 86.18 3.0938 3.5666 3.6605 0.3059 0.4117 0.3213 114.24 0.0190 0.0221 0.0228 0.0006 0.0008 0.0006 MM 95.05 106.18 108.10 29.44 41.89 31.26 Stream Mole Ratio 1.0000 0.855D 0.8303 0.145D 0.0247 0.1697 Heating Value [BTU/SCP] 1543.47 2285.56 1651.56 Gas Gravity [0as/Air] 1.02 1.45 1.08 Bubble Pt. a 1009 [pais] 287.30 21.58 5.30 page 2 86P TAMC V2.0 Calculation Report--- Developed by DH Robinson & Assoeiatea Ltd. 2006.11.24 RVP 0 100F 4,el0 67.91 Spec. Gravity O 100F 0.670 10.89 4.91 0.685 0.687 page 3 S&P TALAR V2.0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2006.11.24 • Project Setup Information • Project Pile : C:\Williams\New Sites\Crawford Trail\Crawford32_atmoe.ept Plowsheet Selection : Oil Tank with Separator Calculation Method RVP Distillation Control Efficiency t 0.0% Known Separator Stream : Low Pressure Oil Entering Air Composition : No Piled Name : Crawford Trail C.S. Well Name : Sherrard Park Compressor tation AUG. 2003 Pressurized Condensate Sample Well ID : Plash Tank • 20 peig to Atmosphere Uncontrolled Data : 2006.10.23 • Data Input Separator Preeeure Separator Temperature Ambient Pressure Ambient Temperature C10+ Su C10+ MW -- Low Pressure Oil : 20.00(peig] 74.00IF1 : 12.50Ipsial 50.00IF1 t 0.7800 : 153.89 No. Component mol % 1 823 0.0000 2 02 0.0000 3 CO2 0.1266 4 N2 0.0009 5 C1 0.2772 6 C2 0.7185 7 C3 1.7691 8 i -C4 1.3644 9 n -C4 2.0967 10 1-05 2.4222 11 n-05 2.5665 12 C6 8.3011 13 C7 19.4967 14 C8 14.5656 15 C9 12-6235 16 C10+ 16.6388 17 Benzene 1.1262 18 Toluene 5.6005 19 2 -Sansone 0.6851 20 Xylenes 6.0326 21 n -C6 3.5666 22 224Trimethylp 0.0221 Sales Oil Production Rate : 401bbl/day] Days of Annual Operation : 365 Maya/year] API Gravity : 58.5 Reid Vapor Pressure : 5.00(peia] • Calculation Results • -- Emission Summary Item Uncontrolled Uncontrolled Controlled Controlled (ton/yr] (lb/br] (ton/yr] page 1 e&P TANK 72.0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2006.11.24 Total RAPS 0.410 Total HC 20.226 VOCs, C2+ 19.468 VOCs, C3♦ 15.807 0.094 4.618 4.445 3.609 Uncontrolled Recovery Info. Vapor 1.0300 (MSCPDI HC Vapor 0.9800 (MSCPD) GOR 25.75 (BCP/bbl] Emission Composition 0.410 20.226 19.468 15.807 0.094 4.618 4.445 3.609 No Component Uncontrolled Uncontrolled Controlled Controlled Ron/yr1 (1b/hr1 (ton/yrl flb/hr1 1 1128 0.000 0.000 0.000 0.000 2 02 0.000 0.000 0.000 0.000 3 CO2 0.949 0.217 0.949 0.217 4 82 0.000 0.000 0.000 0.000 5 Cl 0.758 0.173 0.758 0.173 6 C2 3.662 0.836 3.662 0.836 7 C3 9.009 2.057 9.009 2.057 8 1-04 1.958 0.447 1.958 0.447 9 n-04 1.682 0.384 1.682 0.384 10 1-05 0.731 0.167 0.731 0.167 11 n-05 0.547 0.125 0.547 0.125 12 C6 0.676 0.154 0.676 0.154 13 C7 0.580 0.132 0.580 0.132 14 08 0.150 0.034 0.150 0.034 15 C9 0.051 0.012 0.051 0.012 16 010. 0.011 0.003 0.011 0.003 17 Benzene 0.057 0.013 0.057 0.013 18 Toluene 0.089 0.020 0.089 0.020 19 8 -Benzene 0.004 0.001 0.004 0.001 20 Xylenes 0.030 0.007 0.030 0.007 21 n-06 0.228 0.052 0.228 0.052 22 224Trimethylp 0.001 0.000 0.001 0.000 Total 21.173 4.834 21.173 4.834 -- Stream Data NO. Component 1 H29 2 02 3 002 4 N2 5 C1 6 C2 7 C3 8 i -C4 9 n -C4 10 i-05 11 n-05 12 C6 13 C7 14 CO 15 C9 16 C10♦ 17 Benzene 18 Toluene 19 8 -Benzene 20 Xylene 21 n -C6 22 224Trimethylp MN LP Oil Plash Oil Sale Oil Plash Gas W&8 Gas Total Emissions mol % mol 6 mol % mol % mol % mol % 34.80 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 44.01 0.1266 0.1164 0.0000 7.6185 4.1893 4.3490 28.01 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 16.04 0.2772 0.2178 0.0000 44.0132 7.8399 9.5249 30.07 0.7185 0.6911 0.0038 20.9270 24.7401 24.5625 44.10 1.7691 1.7532 0.5868 13.5131 42.5639 41.2107 58.12 1.3644 1.3611 1.2016 3.7866 6.9428 6.7958 58.12 2.0967 2.0942 1.9846 2.9172 5.9311 5.8373 72.15 2.4222 2.4232 2.4335 1.6522 2.0638 2.0447 72.15 2.5665 2.5683 2.5976 1.2473 1.5421 1.5284 86.16 8.3011 8.3106 8.5012 1.3281 1.6389 1.6244 100.20 19.4967 19.5219 20.0449 0.9626 1.2190 1.2070 114.23 14.5656 14.5851 14.9940 0.2101 0.2755 0.2724 128.28 12.6235 12.6406 12.9994 0.0584 0.0845 0.0833 153.89 16.6388 16.6614 17.1371 0.0100 0.0149 0.0147 78.11 1.1262 1.1276 1.1555 0.1196 0.1498 0.1484 92.13 5.6005 5.6079 5.7625 0.1527 0.1980 0.1959 106.17 0.6851 0.6860 0.7054 0.0057 0.0077 0.0076 106.17 6.0326 6.0407 6.2117 0.0431 0.0582 0.0575 86.18 3.5666 3.5709 3.6575 0.4336 0.5394 0.5345 114.24 0.0221 0.0221 0.0227 0.0009 0.0031 0.0011 MW 106.18 106.28 108.08 32.27 43.22 42.71 Stream Mole Ratio 1.0000 0.9986 0.9709 0.0014 0.0277 0.0291 Heating Value IBTU/SCP) 1686.61 2360.34 2328.96 Gas Gravity (Gas/Air] 1.11 1.49 1.47 Bubble Pt. • 100P (petal 21.90 19.77 5.42 page 2 86P TANK V2.0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2006.11.24 RVP 0 100P Ipaial 11.02 10.47 5.00 Spec. Gravity 0 100P 0.698 0.698 0.700 page 3 Williams Production RMT Crawford Trail Compressor Station Proposed Process Heater Detail Sheet Source ID Number Equipment ID Source Description Equipment Usage Equipment Make Equipment Model Date in Service Emission Controls Fuel Heating Value Heat Input • Assume 80% efcent Permit Status Potential Emissions HTR -1 HTR -1 Medium Heater Process Heater Estimated October 2007 None 1040 Btu/scf 15.00 MMBlulhr Source Location Zone: 12 UTME(m): 742100 UTMN(m): 4376450 Potential operation 8760 hr/yr Potential fuel usage 126.35 MMscf/yr Stack ID Stack Height Stack Diameter Exit Velodty Exit Temperature Volume Flow Rate HTR -1 20 fi 2N 20 Ws 500 deg F 3,770 ft'/min Pollutant Emission Factor (Ib/MMscf) (Ib/MMBtu) Nominal Hrs of Estimaled Emissions Rating Operation (MMBtulhr) (hrs/yr) (Ib/hr) NOx CO VOC SOx PM10 100.00 15.00 8760 1.44 84.00 15.00 8760 1.21 5.50 15.00 8760 0.08 0.60 15.00 8760 0.01 7.60 - 15.00 8760 0.11 (tpy) 6.32 5.31 0.35 0.04 0.48 Source of Emission Factor AP42 AP42 AP42 AP42 AP42 Crawford Trail Emissions.xls Printed on 12/4/2006 NOVEMBER 2006 - CRAWFORD TRAIL COMPRESSOR STATION CRAWFORD TRAIL COMPRESSOR STATION LOAD -1 CONDENSATE LOADOUT VOC EMISSIONS USEPA Loadout Equation L=12.46*S*P*MW/(T*(1-eft)) from AP -42 Section 4.4 Molecular Weight of Vapors, MW 50.81 Ib/Ib-mol E&P TANK2.0 True Vapor Pressure, Pva @ T 5 psia Estimated Temperature of Bulk Liquid Loaded, T 80 F Estimated 540 R Saturation Factor 0.6 Dedicated service Efficiency of controlled loading (%) 0.0% Annual throughput, v 613 1000 gallons Loading losses, L @ tank L=12.46SPMW/T(I-eff) Annual losses @ tank, L*v Loading Frequency Truck Volume Loading Rate Loading Duration Annual ars of Operation Hourly VOC During Loading 3.52 Ib/1000 gallons 2,156.74 lb/yr 1.1 82 trucks/yr 7500 gal/truck 75 gal/min 100.0 min/truck 136.67 hr/yr 15.78 lb/hr (while loading) tpy 11/24/2006 Cranford Trail Emissions Crawford Trail Compressor Station FUG -1 Fugitive VOC Detail Sheer Component Counts Based on Typical Process Unit Counts 8760 Hours Per Year Valves Valves Relief Compressor Pump Flanges Flanges Connectors Connectors Process Unit GasNapor Liquid Valves Seals Seals Gas/Vapor Liquid Gas/Vapor Liquid Compressor Skid (6) 240 30 12 24 0 180 12 720 48 Separator (1) 6 4 2 0 0 8 2 120 30 Storage Tank (3) 12 18 6 0 6 15 30 45 90 Dehydration Unit (2) 150 40 8 0 8 40 100 100 300 Flare (I)* 8 2 2 0 0 15 2 60 8 b CO N O M b 6 a 0 'Equipment Emission Source Percent Hours of Control Total HC Total HC Total VOC Type Factor' Count VOC Operation Factor Emission Emission Emission (Ib/hr/source) (Percent) Rate (Ib/1w) Rate (ipy) Rate (tpy) Valves-GasNapor 0.009920 416 10.79"/. 8760 0.00% 4.13 18.1 2.0 Valves -Light Liquids 0.005510 94 100.00% 8760 0.00% 0.52 2.3 2.3 Relief Valves 0.019401 30 10.79% 8760 0.00% 0.58 2.5 0.3 Compressor Seals 0.019401 24 l0.79°% 8760 0.00% 0.47 2.0 0.2 Pump Seals -Light Liquids 0.028660 14 100.00% 8760 0.00% 0.40 1.8 1.8 Flanges-Gas/Vapor 0.000860 258 10.79% 8760 0.00% 0.22 1.0 0.1 Flanges-Lighl Liquids 0.000243 146 100.00% 8760 0.00% 0.04 0.2 0.2 Connectors - GasNapor 0.000440 1045 10.79% 8760 0.00% 0.46 2.0 0.2 Connectors - Li:ht Li.uids 0.000460 476 100.00% 8760 0.0034 0.22 1.0 1.0 P n CO o M M C ri 0 r Oil and Gas Production Operations equipment leak emission factors (from OAQPS TTN BBS). EPA453/R-95-017. Table 2-4 Hazardous Air Pollutant Fugitive Emissions Component Wt% lb/yr ton/yr Benzene 0.05% 32.67 0.02 Toluene 0.10% 59.27 0.03 Ethylbenzene 0.01% 3.42 0.00 Xylenes 0.04% 27.34 0.01 n-Hexanc 0.34% 210.47 0.11 Williams Production RMT Company Colorado Department of Public Health and Environment Permit No: To Be Issued Air Po" INITIAL APPROVAL DRAFT PERMIT ATTACHMENT B 1. Altemative Operating Scenarios The following Alternative Operating Scenario (AOS) for temporary and permanent engine replacement has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility- Altemative Operating Scenarios, and Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part 0, and has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a construction permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 1.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for90 operating days or less in any 12 month period. Permanent" is defined as in the same service for more than 90 days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day counts towards the 90 day total. Note that the compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by the permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). Results of all tests and the associated calculations pursuant required by this AOS shall be submitted to the Division within 30 calendar days of the test. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on-site, or at a local field office with site responsibility, to contemporaneously record the start and stop date of any engine replacement, the manufacturer, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. 1.1.1 The permittee may temporarily replace the existing compressor engine that Is subject to the emission limits set forth In this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the emissions from the temporary replacement engine comply with the emission limitations for the existing permitted engine as determined in section 1.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 1.2. 1.1.2 The permittee may permanently replace the existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower without modifying this permit, so long as the emissions from the permanent replacement engine comply with the emission limitations for the existing permitted engine as determined in section 1.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 1.2. An Air Pollution Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative operating scenario and Is installing a permanent replacement engine. This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. If 40 CFR Pari 63, Subpart ZZZZ is newly triggered by a permanent replacement engine, the permittee must apply for a revision to their operating permit within 90 days of installation. AIRS ID: To Be Issued 7 Williams Production RMT Company Colorado Department of Public Health and Environment Permit No: To Be Issued INITIAL APPROVAL DRAFT PERMIT 1.2 Portable Analyzer Testing The permittee shall measure nitrogen oxide (NO,) and carbon monoxide (CO) emissions In the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the temporary replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol as found on the Division's website at: htto://www.cdphe.state.co.us/ao/down/oortanalvzeproto.Dd( Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual or short term emission limit, the results of the tests shall be covered to a Ib/hr basis and multiplied by the allowable operating hours In the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. If the portable analyzer results indicate compliance with both the NOx and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time,period. Subject to the provisions of C.R.S. 25-7.123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOx or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOx and CO emission limitations or until the engine is taken offline. 1.3 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine That Is being Installed as an entirely new emission point and not as part of an AOS -approved replacement of an existing onslte engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: To Be Issued 8 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: DATE ISSUED: 07GA0178L April 16, 2007 FINAL APPROVAL ISSUED TO: WILLIAMS PRODUCTION RMT, CO THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Land development project known as Crawford Trail 20" Pipeline, located in Section 33, 6S, 96W, Garfield County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Overiot grading and associated construction activities. THIS PERMIT 15 GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. The fugitive particulate emission control measures listed on the attached page (as proposed in the Fugitive Dust Control Plan submitted to the Division) shall be applied to the fugitive particulate emission producing sources as required by Regulation No. 1. 2. This permit shall expire on 12/1/2007. By: aw-- Michael Harris, F1.E. R K Hancock III, P.E. Unit Leader Permit Engineer AIRS ID: 046/0029/001 Page 1 of 3 WILLIAMS PRODUCTION RMT, CO Permit No. 07GA0178L Final Approval Colorado Department of Public Health and Environment Air Pollution Control Division PARTICULATE EMISSIONS CONTROL PLAN THE FOLLOWING PARTICULATE EMISSIONS CONTROL MEASURES SHALL BE USED FOR ENFORCEMENT PURPOSES ON THE SOURCES COVERED BY THIS PERMIT, AS REQUIRED BY THE AIR QUALITY CONTROL COMMISSION REGULATION NO 1. THIS SOURCE IS SUBJECT TO THE FOLLOWING EMISSION GUIDELINES: a. All Activities - Visible emissions not to exceed 20%, no off -property transport of visible emissions. b. Haul Roads - No off -property transport of visible emissions shall apply to on-site haul roads, the nuisance guidelines shall apply to off-site haul roads. c. Haul Trucks - There shall be no off -property transport of visible emissions from haul trucks when operating on the property of the owner or operator. There shall be no off -vehicle transport of visible emissions from the material in the haul trucks when operating off of the property of the owner or operator. Control Measures 1. All unpaved roads and other disturbed surface areas on site shall be watered as necessary to prevent off -property transport of visible fugitive particulate emissions. 2. Vehicle speed on all unpaved roads and disturbed areas shall not exceed a maximum of 30 mph. Speed limit signs shall be posted. 3. All disturbed surface areas shall be revegetated according to the information submitted by the applicant with the permit application. 4. Surface area disturbed shall be minimized as described in the information submitted by the applicant with the permit application. 5. Gravel entryways shall be utilized to prevent mud and dirt carryout onto paved surfaces. Any mud and dirt carryout onto paved surfaces shall be cleaned up daily. 6. No earth work activities shall be performed when the wind speed exceeds 30 miles per hour. AIRS ID: 046/0029/001 Page 2 of 3 WILLIAMS PRODUCTION RMT, CO Permit No. 07GA0178L Final Approval Colorado Department of Public Health and Environment Air Pollution Control Division GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 3. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of, a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit,conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for inspection upon request at the location set forth herein. With respect to a portable source that is moved to a new location, a copy of the Relocation Notice (requiredby law to be submitted to the APCD whenever a portable source is relocated) should be attached to this permit. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part8, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 5. Issuance (initial approval) of an emission permit does not provide "final" authority for this activity or operation of this source. Final approval of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part 8, Section III.G. Final approval cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. If the APCD so determines, it will provide written documentation of such final approval, which does constitute "final" authority to operate. Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you (1) do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activity was scheduled to commence as set forth in the permit, whichever is later; (2) discontinue construction for a period of 18 months or more; or (3) do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the permittee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) prior to commencement of the permitted operation or activity. Failure to do so is a violation of Section 25-7- 114.5(12)(a), C.R.S. and AQCC Regulation No. 3, Part 8, Section III.G.1., and can result in the revocation of the permit. You must demonstrate compliance with the permit conditions within 180 days after commencement of operation as stated in condition 5. 8. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. AIRS ID: 046/0029/001 Page 3 of 3 Colorado Department of Public Health and Environment Page 1. of 3 Air Pollution Control Division - LAND DEVELOPMENT - Air Pollutant Emission Notice (APEN) — and — Application for Construction Permit Q New Facility 0 Transfer of Ownership * 0 Change in Production 0 No Change (ADEN Update Only) All sections of this APEN and application must be completed prior to submittal to the Division for both new and existing facilities. An application with missing information may be determined incomplete and may result in longer engineer processing times. * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. Permit Number AIRS Number Company Name: Billing Address: Person to Contact: Email Address: Williams Production RMT Company 1515 Arapahoe Street, Tower 3 Zip Code: 80202 Suite 1000 Denver, CO Rick Matar Phone Number: 303.606.4366 rickmatarnwilliams.cotn Fax Number: 303.629.8285 Please provide description of the activity: (Also, please provide a site map) Construction activities to prepare area for pipeline installation. The project will consist of two pipeline segments being constructed within near proximity to each other. See attached map for site details. Project Name & Location: Crawford Trail 20" Pipeline (Begin) County: Garfield Section: 33 (End) County: Garfield Section: 16 Township: 6S Range: 96W Township: 58 Range: 97W Total area of land in project: 167.0 Acres Date earthmoving will - Commence: - 06/18/2007 Total area subject to earthmoving: 167.0 Total disturbed area at any one time: 167.0 Area to be paved (roads, parking lots): 0 Date paving will be completed: Estimated time to complete entire project (includes buildings) List any known or suspected contaminates in the soil: NA Acres Acres Acres - 5 months Stop: - 10/29/2007 Brief description of how the project development will occur (attach an additional page if necessary): Construction equipment will prepare the pipeline route prior to the installation of the pipeline. The pipeline will be installed and the disturbed area will be reclaimed as necessary. Revised September 2004 http://www.cdphe.state.co.us/ap/stationary.html Colorado Department of Public Health and Environment Page 2 of 3 Air Pollution Control Division - LAND DEVELOPMENT - FUGITIVE DUST CONTROL PLAN FOR LAND DEVELOPMENT (This must be submitted with the Air Pollutant Emission Notice -and -Application for Emission Permit) Regulation No. 1 requires that a fugitive dust control plan be submitted by applicants whose source / activity results in fugitive dust emissions. The control plan must enable the source to minimize emissions of fugitive dust to a level that is technologically feasible and economically reasonable. If the control plan is not adequate in minimizing emissions a revised control plan maybe required. The control plan (if acceptable to the Division) will be used for enforcement purposes on the sources. Please check the dust control measures which you propose for your activity. The Division will enforce the control measures checked. Use separate sheets if more space is needed. Also note items with an asterisk (*). This indicates those measures which will probably be required. I. Control of Unpaved Roads on Site O Watering ❑ Frequent (Watering Frequency of 2 or More Times Per Day) O As Needed ❑ Application of Chemical Stabilizer O Vehicle Speed Control Speeds limited to 25 mph maximum. Speed limit signs must be posted. (Generally 30 mph is maximum approvable speed on site.) O Gravelling H. Control of Disturbed Surface Areas on Site O Watering O Frequent (Watering Frequency of 2 or More Times Per Day) O As Needed ❑ Application of Chemical Stabilizer ❑ Vehicle Speed Control Speeds Limited To MPH Maximum. Speed Limit Signs Must Be Posted. O Revegetation Revegetation Must Occur Within One Year Of Soil Disturbance O Seeding with mulch ❑ Seeding without mulch ❑ Furrows at right angle to prevailing wind Depth of furrows Inches (must be greater than 6") ❑ Compaction Of Disturbed Soil On A Daily Basis To Within 90 % Of Maximum Compaction (As determined by a Proctor Test). ❑ Foundation areas only; or ❑ MI disturbed soil. ❑ Wind Breaks Type: (Example: Snow Fence, Silt Fence, etc.) ❑ Synthetic Or Natural Cover For Steep Slopes. Type: (Netting, Mulching, etc.) Revised September 2004 http://www.cdphe.state.co.us/ap/stationary.html Colorado Department of Public Health and Environment Air Pollution Control Division - LAND DEVELOPMENT - III. Prevention Of Mud And Dirt Carried Out Onto Paved Surfaces. • Prevention ❑ Gravel Entry Ways ❑ Washing Vehicle Wheels ❑ Other: ❑ Cleanup of Paved Areas Frequency: Times Per Day ❑ Street Sweeper ❑ Hose With Water ❑ Other: Additional Sources of Emissions List any other sources of emissions or control methods Non -road mobile sources as well as support vehicles. Dust emissions will mainly be controlled through speed control and watering as needed for these sources. Signature of Legally Authorized Person (not a vendor or consultant) Date Rick Matar Air Quality Practice Leader Name (please print) - - Title • Check the appropriate box if you want: Z Copy of the Preliminary Analysis conducted by the Division ® To review a draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $119.96 to: Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3148 Small Business Ombudsman (303) 692-2135 Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Revised September 2004 http://www.cdphe.state.co.us/ap/stationary.html 05/29/2007 13:50 9709472629 BLM GSM DJ Beaupeurt Bureau of Land Management 2425 S. Grand Ave., Suite 101 Glenwood Springs, CO 81601 Dar DJ Beaupeurt, PAGE 01/01 MIECIEIEVW1 Williams. tor AL APR 20f7 BY; EXPLORATION & PRODUCTION Tmvcr 3, Suite 1000 151$ Arapahoe stmt tknrer, CO 80202 3031572.3900 303/629-8292 fax April 24, 2007 This letter is to cbnfinn the appointment of Sandy Hotard to execute documents as an agent for Bargath Inc. and Tom. Fiore as representative of Bargath Inc. in documents furnished to the Bureau Of Land Management. Sincerely, Alan Harrison Vice President Bargalth., Inc. OPTIONAL FORM et 07401 FAX TRANSMITTAL Mot pegee 1. I ra Dept/ FaiF 704;6- 151 3 From Phone Fax e N6$ n40.01-917.7358 5099.101 GENERAL SERVICES ADMINIStRATION STANDARD FORM 299 (120)6) Prescribed by DOWSDA/DOT P.L 96487 and Federal Register Notice 5-22-95 APPLICATION FOR TRANSPORTATION AND UTILITY SYSTEMS AND FACILITIES ON FEDERAL LANDS FORM APPROVED OMB NO. 1004-0189 Expires: November 30, 2008 NOTE Before completing and filing the application, the applicant should completely review this package and schedule a preapplication meeting with representatives of the agency responsible for processing the application. Each agency may have specific and unique requirements to be met in preparing and processing the application. Many times, with the help of the agency representative, the application can be completed at the preapplication meeting. FORAGENCY USE ONLY Application Number Date filed Name and address of applicant (include zip code) Bargath Inc. c/o Williams Production RMT, 1058 County Road 215, Parachute, CO 81635 Attn: Sandy Hotard 2. Name, title, and address of authorized agent if different from Item 1 (include zip code) Bargath Inc. c/o Williams Prod. RMT, 4289 C.R. 215, Parachute, CO 81635 Attn: Tom Fiore 3. TELEPHONE (area code) Applicant S. Hotard 970-683-2288 Authorized Agent T. Fiore 970-263-2743 4. As applicant are you? (check ane) a. ❑ Individual b. Corporation* c. Partnership/Association. d. State Government/State Agency e. ❑ Local Government f. ❑.Federal Agency * If checked, complete supplemental page 5. Specify what application is for: (check one) a El New authorization b. ❑ Renewing existing authorization No. c. ❑ Amend existing authorization No. d. ❑ Assign existing authorization No. e. ❑ Existing use for which no authorization has been received* f. ❑ Other* *lfchecked provide details under Item 7 6. If an individual, or partnership are you a citizen(s) of th United States? ❑ Yes ❑ No 7 Project description [describe in detail): (a) Type of s stem or facility, (e.g., canal, pipeline, road); (b) related structures and facilities; (c) physical specifications (length, width, grading, etc.); (d) term of years need d; (e) time of year of use or operation; (1) Volume or amount of product to be transported; (g) duration and timing of construction; and (h) temporary work areas needed for construction (Attach additional sheets, if additional space is needed,) a) Project Description: See attached Plan of D velopment (POD) Sections 1, 2, 3 and 4 for complete description. Project will be a 20" diameter natural gas gathering buried pipeline system; b) no related facilities; c) Physical specifications: 0.72 miles of 20.000" 01) buried pipeline on Federal lands. Permanent and temporary construction ROW at 50.0' and 150.0', respectively; d) Term of years needed: 30 years; e) Time of year use or operation: year round operation; fj Volume or amount of product to be transported: will vary through life of project from 250 mmcfd to 500 mmefd; g) Duration and timing of construction: Construction to begin about July 15, 2007 and take 90 calendar days to complete; h) Temporary work areas for construction: specified in d) above. 8. Anach a map covering area and show location of project proposal 9. State or local government approval: ❑AOached ElApplied for ❑ Not required 10. Nonreturnable application fee. ❑AOached ❑Not required 11. Does project cross international boundary or affect international waterways? ❑ Yes LIN. (If "yes," indicate on map) 12. Give statement of your technical and financial capability to construct, operate, maintain, and terminate system for which authorization is being requested. Bargath, Inc. (Bargath)is a wholly owned subsidiary of Williams Production RMT., and is a major natural gas and other energy producing, gathering, processing and transportation entity on both regional and national areas of operations. Sufficient technical resources and financial assets are held by Bargath to successfully construct, operate and terminate the project. Only trained, certified, experienced, skilled and technically competent firms and individuals will be employed in the design, construction, operation and other aspects of the project throughout its life. (Continued on page 2) This form is authorized for local reproduction. 13a cscnbe other rensonoblc alternative routes and modes considered. A pipeline Is the only practical method of transporting natural gas. Routes from Um Trail mdgo area being utilized by Northwest Pipeline and n current Winloms Production pipeline route nee not practical. b Why were these alternatives not selected? See above. a Give explanation as to why itis necessary la cross Federal Lands All other routes are token far existing uses or have dlfp,Wt and prohibitive terrain character, 14. List authorizations and pending applications filed for similar projects which may provide tnfemndon to the authorizing agency. (Spee(( number. dote, code, or name) None 15. provide statement of need far project, including me economic feasibility and hems such as: (o) cost of proposal (mrmrneffon, operadog and maintenance); (b) estimated cost of next best alternative; and (c) expected public benefits. a)Cost of construction nt $14 million, annual operation and maintenance at 5250,000 per year; b) No alternate has been considered or ddvtope0; c) This project will move field production natural gas to points of processing and connection hubs with the national gas transmission systems. This will provide for continued and Increased supply of mater& gas tor public use and benefit. 16 Describe probable crams on the population in the oren indudmg the social cad economic aspects, and the niml lifestyles. A. detailed assessment and report of probable cads on population, social and economic factors ppm rural lifestyle will be presented m an Envhaumenml Assessment report (by Weatwater Engineering) prepared in conjunction with Ibis project application. 17. Describe likely environmental effects [hot the proposedprojcct will have one (o)airquN(ty; (b) visual impact; (e) surface end ground Wei quality end quantity; (rr) the control or shuctural change an any stream or other body of water, (e) existing noise levellrs and (1) the surface of the land, including vegetation, petmahost, mil, and soil stability. A detailed assessment and report of probable effects on air quality, vtsupt Impact, surface and ground water, streams and water bodies, noise levels, surface Impacts will be presented in an Environmental Assessment report prepared In conjunction with this protect application. 18. Describethe probahlo effects that the proposed project will have on (a) peyote ens of fah, pinn0ife, wildlife, and marine life, including threatened and endangered species; and (b) marine mammals, including hunting, capturing, collecting, arkilling these animals, A detailed assessment and report of probable effects on fish, plants, wildlife, marine life, T & E specks and marine mammals will be presented in an Environment& Assessment report prepared In conjunction With this project nppllention. 19. Stam whether any hazardous material as defined In thispamgmph, will beosed,produccd, transported or stored on orwvithin the right-of-way orany ofthe right -of -wry facilities, or used in the conslnmtion, operation, nmintennnea or (emanation of the rigid -of -my or any of its facilities liamtdons material" mumu any substance, pollutant or contaminant that is listed as bwordous under the Comprehensive Environmental Response, Compenso0on, and Lability Act of 1980,ns amended,42U.S.C. 9601 el seq., and its regulations. The definition of hazardous substances under CERCLA includes any "bazmdous waste" as defined in the Resource Conservation and Recovery Act of 1976 (RCRA), as amended, 42 U.S.C. 9601 el seq., and its regulations. The tens hazardous motel -Ws also includes any Irate., or byproduct mmledal as oro any the eeAtomiic Energy ne yAct or 11954,asagnated as a emended, 42s U.S.C.substa201111 elsder Tkelerm does not include ho including crude oil or any fraction thereof that No toxic substances ore proposed for use In correction with construction and opeCLA erratioon 0ns 1 S 42Indus�Waslne and Toxic Substances 104), nor dots the tarn include (mol discussion In POD Section 6 for more information. 20. Nome Willie Deparlmem(syAgency(ics) wham this application is being filed. US DOI, DLM, Glenwood Springs Field Office 1 HEREBY CERTIFY, Thal lam °Flegel age and a horiud to do bpdoess in the Sime and that Ihave personally cumin d the information contained in the application and believe drat the i , othiii mbmit •y • correct 4 Il e est of m tat ledg:1111e. Signature of A. 4icnntt . �� Title 18, U.S.C. Section 1001 and Title 4 SC. Section 1212, make it o mime foray personknowiegly rand willfully to moire to any deportment or agency of the United Suites any false, fictitious, or fraudulent smlcmcnm or representations as to any matter Indite fbjurisdiction. (Continued on page 1) - (SP -299, page2) APPLICATION FOR TRANSPORTATION AND UTILITY SYSTEMS AND FACILITIES ON FEDERAL LANDS GENERAL INFORMATION ALASKA NATIONAL INTEREST LANDS This application will be used when applying for a right-of-way, permit, license, lease, or certificate for the use of Federal lands which lie within conservation system units and National Recreation or Conservation Areas as defined in the Alaska National Interest Lands Conservation Act. Conservation system units include the National Park System, National Wildlife Refuge System, National Wild and Scenic Rivers System, National Trails System, National Wilderness Preservation System, and National Forest Monuments. Transportation and utility systems and facility uses for which the application may be used are: 1. Canals, ditches, flumes, laterals, pipes, pipelines, tunnels, and other systems for the transportation of water. 2. Pipelines and other systems for the transportation of liquids other than water, including oil, natural gas, synthetic liquid and gaseous fuels, and any refined product produced therefrom. 3. Pipelines, slurry and emulsion systems, and conveyor belts for transportation of solid materials. 4. Systems for the transmission and distribution of electric energy. 5. Systems for transmission or reception of radio, television, telephone, telegraph, and other electronic signals, and other means of communications. 6. Improved rights-of-way for snow machines, air cushion vehicles, and all -terrain vehicles. 7. Roads, highways, railroads, tunnels, tramways, airports, landing strips, docks, and other systems of general transportation. This application must be filed simultaneously with each Federal department or agency requiring authorization to establish and operate your proposal. In Alaska, the following agencies will help the applicant file an application and identify the other agencies the applicant should contact and possibly file with: Department of Agriculture Regional Forester, Forest Service (USFS) Federal Office Building, P.O. Box 21628 Juneau, Alaska 99802-1628 Telephone: (907) 586-7847 (ora local Forest Service Office) Department of the Interior Bureau of Indian Affairs (BIA) Juneau Area Office 9109 Mendenhall Mall Road, Suite 5, Federal Building Annex Juneau, Alaska 99802 Telephone: (907) 586-7177 Bureau of Land Management (BLM) 222 West 7th Ave., Box 13 Anchorage, Alaska 99513-7599 Telephone: (907) 271-5477 (ora local BLM Office) National Park Service (NPS) Alaska Regional Office, 2525 Gambell St., Rm. 107 Anchorage, Alaska 99503-2892 Telephone: (907) 257-2585 U.S. Fish &Wildlife Service (FWS) Office of the Regional Director 1011 East Tudor Road Anchorage, Alaska 99503 Telephone: (907)786-3440 Note -Filings with any Interior agency may be filed with any office noted above or with the: Office of the Secretary of the Interior, Regional Environmental Officer, Box 120, 1675 C Street, Anchorage, Alaska 99513. Department of Transportation Federal Aviation Administration Alaska Region AAL- 4,222 West 7th Ave., Box 14 Anchorage, Alaska 99513-7587 Telephone: (907) 271-5285 NOTE- The Department of Transportation has established the above central filing point for agencies within that Department. Affected agencies are: Federal Aviation Administration (FAA), Coast Guard (USCG), Federal Highway Administration (FHWA), Federal Railroad Administration (FRA). OTHER THAN ALASKA NATIONAL INTEREST LANDS Use of this form is not limited to National Interest Conservation Lands of Alaska. Individual departments/agencies may authorize the use of this form by applicants for transportation and utility systems and facilities on other Federal lands outside those areas described above. For proposals located outside of Alaska, applications will be filed at the local agency office or at a location specified by the responsible Federal agency. SPECIFIC INSTRUCTIONS (Items not listed are self-explanatory) Item 7 Attach preliminary site and facility construction plans. The responsible agency will provide instructions whenever specific plans are required. 8 Generally, the map must show the section(s), township(s), and ranges within which the project is to be located. Show the proposed location of the project on the map as accurately as possible. Some agencies require detailed survey maps. The responsible agency will provide additional instructions. 9, 10, and 12 - The responsible agency will provide additional instructions. 13 Providing information on altemate routes and modes in as much detail as possible, discussing why certain routes or modes were rejected and why it is necessary to cross Federal lands will assist the agency(ies) in processing your application and reaching a foal decision. Include only reasonable alternate routes and modes as related to current technology and economics. 14 The responsible agency will provide instructions. 15 Generally, a simple statement of the purpose of the proposal will be sufficient. However, major proposals located m critical or sensitive areas may require a full analysis with additional specific information. The responsible agency will provide additional instructions. 16 through 19 - Providing this information in as much detail as possible will assist the Federal agency(ies) in processing the application and reaching a decision. When completing these items, you should use a sound judgment in furnishing relevant information. For example, if the project is not near a stream or other body of water, do not address this subject. The responsible agency will provide additional instructions. Application must be signed by the applicant or applicant's authorized representative. If additional space is needed to complete any item, please put the information on a separate sheet of paper and identify it as "Continuation of Item". (For supplemental, see page 4 ) (SF -299, page 3) SUPPLEMENTAL NOTE: The responsible agency(ies) will provide additional instructions CHECK APPROPRIATE BLOCK I - PRIVATE CORPORATIONS ATTACHED FILED' a. Articles of Incorporation ❑ ❑ b. Corporation Bylaws _ ❑ ❑ c. A certification from the State showing the corporation is in good standing and is entitled to operate within the State. ❑ ❑ d. Copy of resolution authorizing filing ❑ ❑ e. The name and address of each shareholder owning 3 percent or more of the shares, together with the number and percentage of any class of voting shares of the entity which such shareholder is authorized to vote and the name and address of each affiliate of the entity together with, in the case of an affiliate controlled by the entity, the number of shares and the percentage of any class of voting stock of that affiliate owned, directly or indirectly, by that entity, and in the case of an affiliate which controls that entity, the number of shares and the percentage of any class of voting stock of that entity owned, directly or indirectly, by the affiliate. ❑ ❑ f. If application is for an oil or gas pipeline, describe any related right-of-way or temporary use permit applications, and identify previous applications ❑ ❑ g If application is for an oil and gas pipeline, identify all Federal lands by agency impacted by proposal. ❑ ❑ II - PUBLIC CORPORATIONS a Copy of law forming corporation ❑ ❑ b. Proof of organization ❑ ❑ c. Copy of Bylaws ❑ ❑ d. Copy of resolution authorizing filing ❑ ❑ e. If application is for an oil or gas pipeline, provide information required by Item "14' and "I -g" above. ❑ ❑ III - PARTNERS[ -IIP OR OTHER UNINCORPORATED ENTITY a. Articles of association, if any ❑ ❑ b. If one partner is authorized to sign, resolution authorizing action is ❑ ❑ c. Name and address of each participant, partner, association, or other ❑ d. If application is for an oil or gas pipeline, provide information required by Item "I -f' and "I -g" above. ❑ ❑ * If the required information is already filed with the agency processing this application and is current, check block entitled "Filed.' Provide the file identification information (e.g., number, date, code, name). If not on file or current, attach the requested information. (Continued on page 5) (SF -299, page 4) NOTICES NOTE: This applies to the Department of the Interior/Bureau of Land Management (BLM). The Privacy Act of 1974 provides that you be furnished with the following information in connection with the information provided by this application for an authorization. AUTHORITY: 16 U.S.C. 310 and 5 U.S.C. 301. PRINCIPAL PURPOSE: The primary uses of the records applications; (2) recordation of adjudicative actions; and (3) administrative actions. ROUTINE USES: BLM and the Department of the Interior (DOI) may disclose your information on this form: (1) to appropriate Federal agencies when concurrence or supporting information is required prior to granting or acquiring a right or interest in lands or resources; (2) to members or the public who have a need for the information that is maintained by BLM for public record; (3) to the U.S. Department of Justice, court, or other adjudicative body when DOI determines the information is necessary and relevant to litigation; (4) to appropriate Federal, State, local, or foreign agencies responsible for investigating, prosecuting violation, enforcing, or implementing this statute, regulation, or order; and (5) to a congressional office when you request the assistance of the Member of Congress in writing. EFFECT OF NOT PROVIDING THE INFORMATION: Disclosing this information is necessary to receive or maintain a benefit. Not disclosing it may result in rejecting the application. are to facilitate the (1) processing of claims or indexing of documentation in case files supporting The Paperwork Reduction Act of 1995 requires us to inform you that: The Federal agencies collect this information from applicants requesting right-of-way, permit, license, lease, or certifications for the use of Federal Lands. Federal agencies use this information to evaluate your proposal. No Federal agency may request or sponsor and you are not required to respond to a request for information which does not contain a currently valid OMB Control Number. BURDEN HOURS STATEMENT: The public burden for this form is estimated at 25 hours per response including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to: U.S. Department of the Interior, Bureau of Land Management (1004-0189), Bureau Information Collection Clearance Officer (WO -630) 1849 C Street, N.W., Mail Stop 401 LS, Washington, D.C. 20240. A reproducible copy of this form may be obtained from the Bureau of Land Management, Land and Realty Group, 1620 L Street, N.W., Rm. 1000 LS, Washington, D.C. 20036. (SF — 299, page 5) Last Revised 3/8/07 PLAN OF DEVELOPMENT SUPPLEMENT To SF -299 APPLICATION FOR TRANSPORTATION AND UTILITY SYSTEMS AND FACILITIES ON FEDERAL LANDS FOR 20" CRAWFORD TRAIL GATHERING PIPELINE SYSTEM GARFIELD COUNTY, COLORADO Submitted By Bargath Inc. Parachute, Colorado Prepared By D. R. Griffin & Associates, Inc. Professional Engineers & Land Surveyors Rock Springs, Wyoming March 8, 2007 Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 1 of25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 TABLE OF CONTENTS Section Topic Page 1. Purpose and Need 2 2. Right -of -Way Location 4 3. Facility Design Factors 7 4. Government Agencies Involved 8 5. Construction of the Facilities 9 6. Resource Values and Environmental Concerns 23 7. Stabilization and Reclamation 24 8. Operation and Maintenance 24 9. Termination and Restoration 25 10. Appendices A. POD Location Maps B. Table Preliminary Ownership List & Surface Impact Summary C. Table of Access Roads on Federal Lands D. Typical Drawings 1.0 PURPOSE AND NEED Introduction - This Plan of Development (POD) was prepared in support of Bargath, Inc.'s (Bargath) SF -299 Application for Transportation and Utility Systems and Facilities on Federal Lands submittal to the Bureau of Land Management (BLM) to obtain right-of-way grants and to construct a natural gas pipeline gathering system consisting of about 3,830 feet of new 20 -inch -diameter pipeline and ancillary facilities in Garfield County, Colorado. Bargath is a gathering pipeline operating company, a wholly-owned subsidiary of Williams Production RMT Company (WPRMT). The format, outline and content of this POD follow the guidelines established by the BLM as presented in the pamphlet Obtaining A Right -Of -Way On Public Lands, Bureau of Land Management, Land & Realty, April 3, 2006 (http:// www.blm.gov/ nhp/ what/ lands/ realty/ ObtainingaROWPamphlet.pdf). Project Description - The proposed gathering system will connect the outlet of one new field compressor stations to a recently constructed 30 -inch diameter gathering pipeline (30" Bargath Gathering Pipeline). The trunk of the gathering system will be a 20 -inch diameter pipe. The existing 30" pipeline will carry gathered natural gas about 2 miles to Bargath's Parachute Creek Gas Plant for processing and eventual transportation on other pipeline systems for customer use. Ancillary facilities to be installed at the ends and along the pipelines include future pig launcher and receiver assemblies, tie-in piping and valve assemblies four pipeline and compressor station connections, side valve tee and blow off Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 2 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 assemblies for connection of jumper lines to the trunk line and line drip assemblies for periodic removal of accumulated water and condensate liquids. Other miscellaneous items to be installed include line markers, cathodic protection wire leads and cathodic protection current rectifier stations or sacrificial anodes. Pipeline construction will primarily consist of typical trench and bury installation methods. At special road, irrigation ditch and other crossings, alternate installation methods including directional drilling, horizontal boring, flumed ditch and other methods will likely be used. Pipeline Right-of-wav Length and Widths - About 3,830 lineal feet (0.72 miles) of 20 -inch pipeline will be on Federal lands. The requested permanent right-of-way width for the pipeline is 50 feet being situated 25 feet left and 25 feet right on either side of the pipeline centerline. A temporary right-of-way width of 75 feet total (25 feet additional over the permanent right-of-way width) is requested for construction purposes. The construction right-of-way will be situated 25 feet on one side (spoil side) and 50 feet on the other side (working side) of the pipeline centerline. The orientation of the spoil side and working side will vary left to right and right to left depending upon the pipelines proximity to existing parallel pipelines, other encroachments and terrain factors encountered along the pipeline route. Additional temporary extra workspace and staging areas beyond the 75 foot temporary construction work space will be needed at select locations along the pipeline routes. These areas are needed for road and drainage crossings, vehicle maneuvering area for sharp bends, top and bottom of steep terrain ascent sections, side hill bi-level construction segments, fabricated facility installation sites, equipment and material storage locations, begin and end pipeline staging areas and staging areas at major points of project access. These extra workspace and staging areas have not been currently identified. Prior to construction, such areas will be identified, mapped and summarized. This information will be submitted to the BLM in a temporary use permit application (TUP) for consideration and approval. Typically, the project area utilized for extra workspace and staging areas amounts to about 9% of the total disturbed acreage on a pipeline project. A 9% amount for extra workspace and staging areas has been included in the surface impact summary presented in Appendix B of this POD. Project Need - The product carried by the pipeline system will be field grade semi -wet natural gas. The pipeline system will be a non -jurisdictional, non- regulated high pressure gathering system moving gathered natural gas from field compressors towards a centralized gas processing plant. Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 3 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 In recent time, gas well drilling, development and production has expanded significantly in the Parachute and Rifle regions of Colorado. Existing Bargath pipeline and other gathering facilities are unable to adequately gather and transport the quantities of natural gas demanded both presently and in the future. This project will provide added pipeline system size and operating pressure to efficiently move larger quantities of natural gas from field to market for public use and benefit. 2.0 RIGHT-OF-WAY LOCATION 20 -inch Trunk Line - The 20 -inch pipeline first enters Federal lands (BLM) at the west line of NW % SE '% Section 19 T6S R96W. The 20 -inch pipeline exits Federal lands (BLM) at the east line of NW'/ SW 1/4 Section 20 T6S R96W. The total length of Federal lands crossed is about 3,830 lineal feet or 0.72 miles. Maps — A detail map at 1" = 2000' with USGS topographic map base is provided in Appendix A. Land Status — The following tables depict "Federal Ownership List and Surface Impact Summary" and "Staging and Extra Workspace Areas, Federal Lands" for the project. This tables present the following information: • ROW # - Sequential list of ownership parcels crossed by the pipelines. • Legal Location of each crossed parcel by township, range, section and sectional part. • Apparent owner name for each federal parcel. • Length of parcel crossing. • Permanent ROW acreage per parcel at 50 foot ROW width. • Total construction ROW acreage for each parcel at 75 foot total width. • Extra workspace estimate acreage for each parcel at 50% of total due to the steep terrain on federal surface. • Total surface impact acreage for each parcel • Subtotals and totals of the above for federal ownership, 20 -in trunk line. A summary of the Appendix B table is shown below: Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 4 of 25 DRG Job N 14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 N CD FEDERAL OWNERSHIP LIST & SURFACE IMPACT SUMMARY 20" CRAWFORD TRAIL GATHERING PIPELINE PROJECT BARGATH, INC. March 8, 2007 Total Surface Area Acres cO 4.75 M V' Extra Workspace at 50% Total Acres N V 2.38 N t0 Construction ROW 75' ACRES 4.22 2.38 C) N to Permanent ROW 50' Acres 0o N to uo 0 v d' Length LF 9ath Gathering Pipeline o '4) V N 1,380 O M at co Owner 2 -J m BLM TOTALS -20" CRAWFORD TRAIL PIPELINE To 0) J V w (1) CAZ NWSW Section 0) 20 0) c K to 0) (0 K Cfa O=(° F- to co I- -p* T6S 0 * cC 24" Bar 2 b b 'r) V N oat h ea cd g 0 Last Revised 3/8/07 STAGING AND EXTRA WORKSPACE AREAS FEDERAL LANDS 20" CRAWFORD TRAIL GATHERING PIPELINE BARGATH, INC. March 8, 2007 Offset & Work Area Description 2 -level development & topsoil, spoil storage area. 25' extra width spoil side, 50' extra width working side, full length of ROW 2 -level development & topsoil, spoil storage area. 25' extra width spoil side, 50' extra width working side, full length of ROW Disturbed Area (Acres) cv cg co el CL / CL a ®/ / \» a QTR § k z z Description Steep Side Hill Steep Side Hill Surface Owner ] ] 4 IrD $ O CI- CO CO CO, ROW Last Revised 3/8/07 3.0 FACILITY DESIGN FACTORS The design and construction of the pipeline system will be in accordance with applicable regulations, recognized industry codes and the normal and customary practice for this type of facility. These regulations and codes include the latest accepted editions of 49 CFR 192 Transportation of Natural and Other Gas by Pipeline: Minimum Federal Safety Standards and ASME 831.8 Gas Transmission and Distribution Piping Systems. Maximum operating pressure, pipe material specifications, basic construction requirements and other such design factors for the project are listed below: Design maximum operating pressure: 1,200 psig Project line pipe, F = 0.72 20.000" OD x 0.281" WT x API -5L X-70 (or) 20.000" OD x 0.312" WT x API -5L X-65 (or) 20.000" OD x 0.312" WT x API -5L X-56 (or) 20.000" OD x 0.344" WT x API -5L X-52 Project line pipe, F = 0.60 road crossings: 20.000" OD x 0.312" WT x API -5L X-70 Project line pipe, F = 0.60 fabricated assemblies: 20.000 " OD x 0.312" WT x API -5L X-70 (or) 20.000 " OD x 0.344" WT x API -5L X-65 (or) 20.000" OD x 0.375" WT x API -5L X-52 Valve and flange rating: ANSI Class 600 Pipe coating, typical installation: Nominal 15 mil thin film -fusion bonded epoxy factory applied (TF-FBE). Pipe coating, road bore rough handling installation: Abrasion resistant overlay (ARO) nominal 45 mil over nominal 8 mil TF-FBE. Pipe coating, fabricated assembly installation:. Bare metal pipe provided for fabrication. Below grade installation primer coated and tape wrapped. Above grade installation spray painted with epoxy based paint. Minimum pipe cover in trench: 1'-6" for rock areas 2'-6" for general areas 4'-0" for cultivated and industrial activity areas 5'-0" for road crossings 7'-0" for drainage and canal crossings Trench dimensions: Width: Pipe OD + 1'-2" minimum Pipe OD + 3'-0" Maximum Depth: Min Cover + Pipe OD + 0'-6" NOTE: for trenches greater than 5'-0" total depth, conditions shall be inspected by a qualified person and appropriate slope stability measures implemented as required for safety. This may include sloping, shoring and bracing trench walls as directed by the qualified person. Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 7 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 Pipeline product: Field grade semi -wet natural gas, flammable, non-toxic. Operating temperature: Nominal 60° F, Typical range 40°F to 90°F, Maximum design temperature coatings 120°F Maximum design temperature pipe, valves & fittings 250°F Size and width of permanent and construction rights-of-way, extra workspace, staging sites and other temporary areas are discussed in Section 2 above. Locations not included in the permanent right-of-way (50 foot width) and temporary construction total width (75 foot width) will be identified, mapped and tabulated prior to construction. Locations on Federal Lands will be listed and applied for in a temporary use permit application. The TUP application will be submitted and approved prior to construction. 4.0 GOVERNMENT AGENCIES INVOLVED The proposed project will be constructed and operated as an intrastate upstream gathering pipeline for the sole transport of WPRMT products. The project is located in a Class 1 area (as defined by 49 CFR 192.5) and upstream of any gas processing plant. Accordingly, the project will be non -jurisdictional and not under the rule of the Federal Energy Regulatory Commission. Likewise, the project is non -regulatory (as defined by 49 CFR 192.1) and not under the authority of the U.S. Department of Transportation Office of Pipeline Safety or the Gas Pipeline Safety Division of the Colorado Public Utilities Commission. Although being non - jurisdictional and non-regulated, the pipeline will be designed, constructed and operated in accordance with the USDOT regulations and ASME codes previously cited. Construction and operation of the project will, however, comply with Colorado Revised Statutes CRS 9-1.5-105 pertaining to gas pipeline operator participation and compliance with the Utilities Notification Center of Colorado Notification Association. The project crosses properties listed in the Garfield County Recorder and Assessor Offices as being owned by the Bureau of Land Management. Unless otherwise informed, it is understood that all right-of-way grants and temporary use permits for Federal lands (BLM) will be under mandate of the Bureau of Land Management. The project is situated entirely within Garfield County, Colorado, and will accordingly require permits and approvals from appropriate departments of that county. These include: Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 8 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 • Pipeline Development Plan Permit, Garfield County Building & Planning Department. All drainages crossed by the project are intermittent streams or ephemeral "dry - washes" and are not considered "Waters of the United States." Applications for utility stream crossing permits to the U.S. Army Corps of Engineers under 33 CFR 325 will not be required for the project. Permits from the State of Colorado may be needed for acquisition of water for project use and for the disposal of hydrostatic test water and accumulated storm water discharge. The permits and Colorado agencies involved include: • Surface water or well water appropriation, Colorado Department of Natural Resources, Division of Water Resources. • Construction Activity Storm Water Discharge with Storm Water Management Plan, Colorado Department of Health, Water Quality Control Division. • Construction Dewatering Wastewater Discharge, Colorado Department of Health, Water Quality Control Division. 5.0 CONSTRUCTION OF THE FACILITIES Prosect Survey And Pre -construction Staking - Prior to the construction of the proposed project, numerous pre -construction activities will be completed. These activities include, but are not necessarily limited to, land surveying, selection of final pipeline alignment and facility locations, coordination with land owners and other affected interests, coordination with users of existing utility corridors, procurement of ROW, acquisition of permits, finalization of engineering design, procurement of materials, and selection of construction contractors. Additional surveys will be conducted for construction staking purposes. Permission will be obtained, as necessary, prior to entering a property to conduct a survey. Pre -construction staking designates the centerline and outside ROW boundaries. These and the extra construction widths will be staked and flagged at 200 -foot nominal intervals or at other appropriate spacing required by conditions. Known existing utility locations will be flagged where the pipeline parallels or crosses existing utility corridors to avoid damage and disturbance. Additional staking will be provided as needed at meter stations, pigging facilities, side valves and other appurtenant facilities. The limits for all construction staging areas and the location of access road entry points will be suitably staked and flagged. Plan of Development 20" Crawford Trail Gathering P/L, Williams Production RMT Co. Page 9 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 Project Drawings, Engineering Specifications And Standards Project drawings to be prepared for the work will include the following: • Pipeline alignment sheets • Mechanical flow diagram • Fabrication drawings • Crossing and permit drawings • Construction and environmental detail sheets • Other special detail drawings as needed. Documents to describe and detail the work will include the following: • Pipeline Construction Contract • Information and Notice To Bidders • Attachment A — Specification for Pipeline Construction • Attachment B — Supplemental Specification for Pipeline Construction including Project Description, Scope Of Work And Special Provisions. • Attachment C — Materials Provided by Owner • Attachment D — Contract Price Schedule • Attachment 0-1 Contract Price Schedule Description including payment item description and exclusions, basis of payment and method of measurement. The controlling standards for the design and construction of the work will be the U.S. Department of Transportation Pipeline Safety Regulations 49 CFR 192 Transportation of Natural Gas and Other Gas by Pipeline: Minimum Federal Safety Standards. Where 49 CFR 192 does not address particular design, construction or operation requirements necessary for the work, the provisions of American Society of Mechanical Engineers ASME Code B31.8 Gas Transmission and Distribution System Piping System will be incorporated into the work. Other applicable codes, regulations and standards will be applied to the work when referenced by the controlling 49 CFR 192 regulation and ASME B31.8 Code and as otherwise determined by the normal and customary standard of practice for this type and nature of work. The provisions of any permit or license issued by controlling agencies providing a required approval for the project will also be considered a controlling standard for the project. Construction Schedule, Manpower and Equipment - Construction will begin upon the receipt of the necessary agency approvals and permits, acquisition of ROW grants from affected landowners, delivery of sufficient quantities of line pipe and other materials to start the work and retention of a qualified, available and economically viable contractor to perform the work. The estimated duration Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 10 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 of construction for this project is sixty (60) calendar days. The BLM will be provided required notice in advance of construction start up. Authorized representatives of Bargath, Bargath's construction inspectors, project managers, construction engineers and surveyors and the contractor's supervisor staff shall attend any BLM required pre -construction meeting. The number and types or personnel, vehicles and equipment employed for project construction will increase from a minimum at the beginning of the work, to a maximum about three weeks after start, stay more or less at this peak level until about three weeks from the end of the work and then decrease to a minimum. At the peak level of personnel staffing and equipment deployment, the following types and approximate numbers can be expected: Description Quantity (Each) Personnel Surveyors 4 Construction Manager 1 Construction Engineer 1 Chief Inspector 1 Inspector/Management Clerical 1 Inspectors 9 X-ray Technicians 4 Construction Supervisor 1 Assistant supervisor 1 Contractor clerical 1 Foremen 2 Equipment Operators 6 Welders 6 Welder Assistants 6 Laborers 15 Truck Drivers 6 TOTAL 65 Vehicles & Equipment 4x4 Pickup & personal cars 40 Dozers 2 Patrol Graders 2 Brush Hog 1 Side Booms 4 Welder Trucks 6 Trucks & Flat Bed Trailer 4 Stringing Trucks 4 Flatbed Trucks 4 Trenching Machine 1 Track Backhoes 2 Wheel Backhoes 2 Horizontal Boring Machine 1 Directional Drill Machine 1 Pipe Bending Machine 1 Dump Truck 1 X-ray Van 2 Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 11 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 Desch ation Quantic (Each) Air Compressors 2 Water Pumps Dewatering 4 Water Pumps Pressure Test 2 Side Cast Seeder 1 Drill Seeder 1 Office Trailer 2 Equipment Trailer 2 Portable Toilets 4 Personnel and equipment required for a project of this size, type and nature exist in adequate quantities in the regional area. The equipment and personnel will be staged and lodged in nearby locations to include but not limited to Parachute, Rifle, Meeker, Craig, Glenwood Springs, De Beque, Grand Junction and points in between. Pipe storage yards, equipment and materials warehousing, contractor yards and other project use areas will be a pre-existing locations owned by Bargath or other industrial or commercial concerns. Clearing And Grading - Vegetation will be cleared and the construction ROW graded to provide for safe and efficient operation of construction equipment and to provide space for temporary storage of spoil material and salvaged topsoil. In general, the width of the ROW clearings will be kept to a practical minimum to avoid undue disturbance. Brush clearing will be limited to trimming and/or crushing to avoid disturbance of root systems. All brush and other materials that are cleared will be windrowed along the ROW. Where necessary, all brush and other debris cleared will be disposed of in accordance with instructions from the jurisdictional agency or landowner and all applicable laws and regulations. Topsoil removed during the clearing and grading operations will be segregated from subsoils. At a minimum, the first 6 -inches of surface soil would typically be separated. These topsoils will be preserved for subsequent restoration activities on the ROW. Three approaches to topsoil removal are provided in this POD. These include: 1) full ROW width topsoil removal; 2) trench and spoil area only topsoil removal and 3) blade width only topsoil removal. ROW section details of these topsoil removal methods are provided in Appendix D Typical Drawings. The method of topsoil removal to be utilized on the project may vary from location to location. This will depend upon landowner desires, government agency stipulations, conditions encountered on the ground during construction, advisement of any soil & reclamation specialist employed or involved on the work, and the preferences and requirements of the contractor in regard to his adopted plan for successful clearing, grading, restoration, reseeding and reclamation of the project. Grading of the construction area will be performed in order to create a suitable work surface for construction vehicles and heavy equipment. On flat to mildly or moderately sloping terrain, a uniform work surface will be graded across the Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 12 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 entire ROW. A bi-level work surface may be necessary in more sloped areas. ROW section details for side hill bi-level construction are shown in Appendix D Typical Drawings. Side hill cuts will be kept to a minimum to ensure resource protection and a safe, stable surface for heavy equipment use. When required by controlling agency or the landowner, construction activities will not be conducted during conditions when the soil on the ROW or access roads are too wet to adequately support construction equipment. In such instances and where construction equipment creates excessively deep ruts, construction activities will be discontinued until soil conditions improve. All survey monuments located within the ROW will be protected during construction activities. Survey monuments include, but are not limited to, General Land Office and BLM Cadastral survey corners, reference corners, witness points, U.S. Coastal and Geodetic Survey benchmarks and triangulation stations, military control monuments, and recognizable civil survey monuments. In the event of obliteration or disturbance of any of the above, the incident will be duly reported. Where such monuments are obliterated during construction, the services of a registered land surveyor will be employed to restore the monuments in accordance with established procedures. Each such survey would be duly recorded with the appropriate county and other jurisdictional agencies. Trenching - Typical pipe cover, ditch width, depth and similar dimensions are detailed in Section 3.0 Facility Design Factors above. In all instances, pipeline burial depths will be in conformance with the requirements of 49 CFR 192 Pipeline Safety Regulations. Occasionally, the ditch will be excavated to depths greater than the general values specified. Such instances include where the ditch will be excavated to pass beneath railroads, roads, streams, drainages and other obstructions. As a minimum, the ditch will be excavated to a depth to allow a clearance of 24 inches between the project pipeline and other pipelines or underground facilities. Machine excavation will not be performed closer than 5 feet from any existing pipeline, communications cable or other such buried facility encountered in the ROW. Existing pipeline locations will be marked in the field and 48-hour prior notification given to the pipeline or other underground utility operator. Construction methods employed to excavate a trench will vary depending on soils, terrain, and related factors. Self-propelled trenching machines will be used where possible. Conventional mechanical backhoes will be used on steep slope areas, unstable soils, high water table, and where deep or wide trenches are required. Where rock or rock formations are encountered, tractor -mounted mechanical rippers or rock trenching equipment may be used to facilitate excavation. In areas where rippers or trenchers are not practical or sufficient, Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 13 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 blasting may be employed. Strict safety precautions will be taken when blasting. Backhoes will then be used to clean the ditch after ripping or blasting. Unless otherwise required and agreed upon, pipeline crossings of non -surfaced, gravel, lightly traveled, and rural roads will be made using open trench "cut and cover" methods with mechanical ditching machine or backhoe. Installation at these locations, including cleanup and restoration of road surfaces, will usually be completed within one day. Provisions will be made to detour or control passage of traffic during the construction. Boring & Drilling - Pipeline crossings at more heavily traveled roads, hard - surface roads, railroads, highways and similar crossings will be made by boring. Boring methods may include horizontal slip or slick boring, horizontal directional drilling or both. The horizontal slip or slick boring method requires the excavation of boring pits at both the entry and exit points of the pipe installation. The depth of the bore pits is foot or more lower than the pipe installation. Pipe is installed on a straight horizontal and vertical grade line between the bore pit faces. The installation is accomplished by auger drilling a circular hole slightly larger than the pipe being installed. The boring proceeds through a pilot pipe which is advanced by mechanical jacking behind the auger head. Excavated material is discharged through the rear of the pilot pipe. After the pilot pipe has been advanced to the end, the carrier pipe is welded to its far end. The pilot pipe and carrier pipe pair is then drawn back through the drill excavated hole. When the carrier pipe is in place, the pilot pipe is cut off to be used again for the next bore crossing. Slip boring refers to "dry" drilling. Slick boring refers to the use of drilling fluid or mud to lubricate the process and provide circulation of bore cuttings from behind the auger and out the back of the pilot pipe. Horizontal directional drilling is typically performed with the entry point at the ground surface. The exit point for this method may or may not have a bore pit but typically does not. Directional drilling does require that small or moderate size mud pits be established at both ends of the drill span. Directional drilling uses a small diameter pilot drill and drill string to establish an initial hole along the bore path. Drilling mud is circulated through the head of the pilot drill and back through the drilled hole. Drilling mud lubricates and cools the drilling head, circulates cuttings out of the hole and provides hydraulic support of the hole until the carrier pipe is installed. After the pilot hole has been established, reaming heads are attached to the pilot string and passed through the hole to open it up to a diameter of about 1.5 times, or less, of the carrier pipe diameter. The hole may need to be reamed several times depending upon the size of pipe to be installed and earth conditions present. When the hole has been expanded to the required size, one end of a pull block is hooked to the pilot string and the other end is welded to the carrier pipe. The carrier pipe is then pulled back through the hole to complete the drill span. Within the limits of the carrier pipe material to be installed, the bore path is typically curved in vertical alignment and some times in Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 14 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 horizontal alignment as well. For steel pipe, the rate of installed curvature is about 100 foot of radius for each inch of pipe size (i.e. R = 3,000 feet for 30 -inch carrier pipe, R = 800 feet for 8 -inch carrier pipe). Drilling installation methods typically minimize and often avoid the disruption of traffic at road, highway and railroad crossings. Drilling methods used at crossings of excluded and restricted areas, irrigation ditches, flowing streams, wetland areas and similar cultural and environmental sensitive locations can often thoroughly avoid occupation of land crossed by the pipe, the disruption of flowing water, surface disturbance and other like problems. Drilled pipe installations are significantly expensive to install and are accordingly used selectively. Drilling methods using pressurized muds are always subject to "frac-outs" and "blow -outs" (sudden, accidental escape of drilling fluids) which present a minor but typically acceptable construction risk and environmental hazard. Pipe installed by drilled methods is typically of larger wall thickness and strength than the other project line pipe. This is required to address the additional external forces present as result of the installation method and the crossing itself. The carrier pipe in a drilled installation is almost always treated with a sacrificial coating or abrasion resistant overlay. This is present to absorb the wear and tear of the drilling work and to guard the under -laying corrosion protection coating on the pipe itself. Pipe installation - Pipe will be shipped directly from a manufacturer or supplier by rail and truck to offsite storage sites and then be hauled by truck to the pipeline ROW. Each individual joint of pipe will be unloaded by cranes or tractors equipped with side booms and slings, and strung parallel to the ditch. Sufficient pipe for road crossings will be stockpiled at staging areas near the crossing. Stringing operations will be coordinated with trenching and installation activities in order to properly manage the construction time at a particular tract of land. Gaps will be left at access points across the ditch to allow crossing of the ROW. As construction proceeds, some of the pipe and stringing equipment will be temporarily stored at approved staging and extra workspace areas along the ROW. After the joints of pipe are strung along the ditch but before the joints are welded together, individual joints of the pipe will be bent to accommodate horizontal or vertical changes in direction. Such bends will be made utilizing an approved cold, smooth bending machine having a hydraulically operated shoe that makes the bend. Where the deflection of a bend exceeds the allowable design limits for field -bent pipe, shop fabricated pieces (induction or "hot bends") or trimmed segmentable forged fittings will be installed. After the pipe joints are bent, the pipe is lined up end-to-end and clamped into position. The pipeline will then be welded in conformance with 49 CFR Part 192, Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 15 of25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 Subpart E, "Welding of Steel in Pipelines" and API 1104, "Standard for Welding Pipelines and Related Facilities," latest edition. Welds will be visually inspected by a qualified inspector and will be subject to radiographic inspection in conformance with DOT requirements. A specialized contractor certified to perform radiographic inspection will be employed to perform this work. Any defects will be repaired or removed as required under the specified regulations and standards. Project specifications will require that the pipe be externally coated with fusion bonded epoxy coating prior to delivery. After welding, field joints will be coated with either a tape wrap or shrinkable sleeve wrap. Before the pipe is lowered into the ditch, the pipeline coating will be visually and electronically inspected and any detected faults or scratches will be repaired. Backfillinq - Once the pipe coating operation has been completed, the pipeline will be lowered into the ditch. Side -boom tractors will be used to simultaneously lift the pipe, position it over the ditch, and lower it in place. Inspection will be conducted to verify that minimum cover is provided, the trench bottom is free of rocks/debris/etc., external pipe coating is not damaged, and the pipe is properly fitted and installed into the ditch. In rocky areas, padding material or a rock shield will be used to protect the pipe. Backfilling will begin after the pipeline has been successfully placed in the ditch and final inspection has been completed. Backfilling will be conducted using a bulldozer, rotary auger backfiller, or other suitable equipment. Backfill will generally consist of the material originally excavated. In some cases, backfill material from other areas (borrow material) may be needed. Backfill would be graded and compacted, where necessary for ground stability, by being tamped or walked in with a wheeled or track vehicle. The soils will be replaced in a sequence and density similar to pre -construction conditions. Subsoils will be backfilled first, followed by replacement of stockpiled topsoil. Once the excavation has been filled and compacted, the topsoil would typically be crowned in a berm, 12 -inches -high or less, and tapered outward from the center and/or spread uniformly over the disturbed ROW. The material in the berm is intended to compensate for normal settling of backfilled materials. Any excess excavated materials or materials unfit for backfill will be properly disposed of in conformance with applicable laws or regulations, and landowner or jurisdictional agency requirements. Where possible, these surplus materials will be spread out over the ROW to avoid off-site disposal. Where required by controlling agencies, landowners, other situations and good cause, controlled compacted backfill will be placed at road crossings and other such locations. Backfill material to be placed shall be inspected and determined suitable for use by a qualified person. The backfill shall be placed at a controlled water content range in level uniform layers not exceeding 8 -inches compacted Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 16 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 thickness. The resulting backfill density shall not be less than 90% maximum density (or higher if prescribed by permit, agency or landowner) as determined by an established AASHTO or ASTM procedure. Pressure Testing - The entire pipeline will be tested in compliance with 49 CFR Part 192 Pipeline Safety Regulations. This will be accomplished through hydrostatic (water) or pneumatic testing, or both. Some portions of the pipeline may require pneumatic testing due to the steepness of the terrain. Prior to filling the pipeline for a pressure test, each section of the pipeline will be cleaned by passing reinforced poly pigs through the interior of the line. Incremental segments of the pipeline will then be filled with test media, pressurized, and held for the duration of the test. The length of each segment tested will depend on local topography. Typically, the tests of individual segments will be conducted in sequence and the test media will be transferred from one segment to another. Hydrostatic test water intake and discharge will be done in conformance with all applicable local, state, and federal requirements. Performance of these operations shall avoid adverse impacts to aquatic, wildlife, and visual resources. The test water will be obtained from a surface water, an existing well (pending water appropriation permits), a municipal water source and a commercial provider. At discharge points, the release of water will be controlled to prevent erosion. Energy dissipating devices will be employed where needed. When required, discharged waters will be sampled, tested and filtered in accordance with applicable discharge permit requirements. Upon completion of pressure testing, the pipeline segment will be dried using compressed dry air, pigs, spheres, or other accepted means. Once dried and fully ready for service, including tie-ins to terminal and online facilities, the pipeline will be purged of air and charged with natural gas. Upon obtaining sufficient gas volume and pressure, the line is typically ready for gas transmission and gathering service. The event is typically called the moment of "Substantial Completion." Cleanup and Restoration - Upon completion of backfilling, construction work will commence to clean up, restore, and re -vegetate the ROW. Efforts will have be taken during the prior work to minimize erosion, restore the natural ground contour, account for trench settling, re-establish plant growth, and allow natural surface drainage. As agreed with the landowner or controlling agencies, all completed construction areas and temporary access roads will be returned as nearly as possible to their original condition and service. All restoration and re - vegetation will be completed to the satisfaction of the landowners, controlling agencies and other recognized parties. First, any trash, brush, surplus material, or other debris will be cleared from construction areas and disposed of in an appropriate manner. The ROW will Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 17 of25 DRG Job #I4466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 then be graded and restored to nearly pre -construction grades. Final restoration of disturbed areas will be accomplished by whatever means are most suited for the particular soils, terrain, vegetation and climate at a specific site. In general, waterbars will be constructed to prevent erosion of unconsolidated soils and provide drainage away from the disturbed area and into existing washes or drainages. Where deemed appropriate, slash will be used to control erosion. Where necessary, terracing or other erosion control techniques may be employed. Reseeding will be accomplished using seed mix or plant species approved by the landowners or controlling agencies. Seedbed preparation and seeding operations will be conducted in accordance with accepted techniques for the particular area and task. In areas with difficult reclamation problems, restoration and re -vegetation will be considered a special management problem and will be resolved in coordination with the landowner and the respective authorities involved. Advice may be sought from specialty agencies or environmental consultants to fully determine the appropriate mitigation and reclamation measures needed. Residential Areas And Private Property - The construction ROW will not be located within 50 feet of a place of residence or similar use. Where residential and private property is encountered, the following practices where reasonable, prudent and beneficial will be implemented: • If the trench is left open overnight within 250 feet of a residence, place of business or similar activity, it will be fenced or barricaded to mitigate safety concerns. • Owners of private roads along the route will be notified 24 hours in advance of planned road crossings. • Private road crossings will be completed within three hours and roads will be restored to pre -construction conditions or better. • Access to and from residences, place of business and similar areas will be maintained at all times unless express authorization to the contrary is obtained for the landowner, lessee or other authorized entity. • Construction activities, except for pressure testing, will only occur between 7 AM and 6 PM, six days a week (Monday through Saturday). • No trench within 250 feet of a residence, place of business or similar area will be left open for more than three days. • If blasting activities are required, matting will be used to prevent damage from flying debris. Landowners, lessees and others will be notified in advance to ensure that all persons, livestock and equipment are out of the danger zone. Where it is determined by a qualified person that there are still identifiable risks in proximity of the work area, blasting will not be used. Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 18 of 25 DRG Job 1114466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 • In residential and similar areas, topsoil replacement (topsoil import) may be used as alternate to topsoil segregation. Livestock Issues - Prior to construction, concerns and issues of landowners, lessees and controlling agencies in regard to pipeline construction and livestock will be solicited and considered. Stipulations, requirements and reasonable requests developed from such inquires will be incorporated in the work. As a minimum, the following will be established for the work: • Fences crossing the ROW will be braced, cut, and temporarily fitted with gates to permit passage. • During construction, the openings will be controlled as necessary to prevent the escape of livestock. • Existing fences will be replaced and braces left in place upon completion of construction activities. • During construction, no gates or cattle guards on established roads over public or private lands will be obstructed or damaged by construction activities. • Adequate precautions will be taken to ensure that livestock and wildlife will not be prevented from reaching water sources because of open ditches or pipe strung along the ditch. Such precautions will include contacting livestock operators, providing adequate crossing facilities, or other measures as needed. • All damaged livestock facilities will be repaired or replaced to a condition as good as or better than the pre -construction condition. The final facilities shall be acceptable to the landowner, lessee or other authorized person. Temporary fences shall be installed if original fences affected by the work do not provide adequate livestock control. • Temporary fences or other barriers shall be installed if pipeline construction destroys or eliminates natural barriers. Replacement of the natural barrier is desired upon the completion of construction if practical. Permanent fencing or artificial_barriers shall be used if the natural barrier cannot be reasonably restored. Health and Safety - The following health and safety measures shall be made a requirement of the pipeline construction work: • Special precautions shall be taken when working on pipeline segments parallel to, crossing or near high voltage overhead electric power transmission lines. These precautions shall include: o Measuring the pipe -to -ground voltages on pipe sections each day at the commencement of work, prior to work involving pipe contact and when directed by a qualified person. Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 19 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 o Rubber tired vehicles operating on a common pipeline and powerline ROW area shall be strap grounded to mitigate capacitive coupling. Grounding shall be made using a metal chain or conductive strap connected to the vehicle frame and contacting the ground. o Vehicles shall not be refueled on or near an electric powerline ROW. o The pipeline contractor shall coordinate with affected utilities to avoid utility disruptions. • A fire prevention and suppression plan shall be developed and implemented for the work. • When required, a job specific blasting plan shall be developed and implemented for the work. • Excluding hydrostatic testing, nighttime construction will not be permitted. Work shall not commence prior to sunrise and work shall cease at sunset. Work in residential, business and similar areas shall be limited to 7 AM to 6 PM, Monday through Saturday. • No camping will be allowed on the pipeline ROW. • When required, watering and other means of dust control will be provided. Dust control within 500 feet of residences, public roads and other gathering places will be diligently implemented and maintained. Standards and regulations pertaining to air quality emissions including particles other than dust will be made requirements of the project work. • Trenches left open overnight and within 250 feet of a residence, office building, commercial or industrial business site or similar area shall be fenced or barricaded to mitigate safety concerns. • Should a well, spring or water supply facilities be adversely affected by construction, an emergency source of potable water will be provided until mitigation can be completed. Repairs and replacement of affected facilities shall be undertaken upon completion of pipeline work in the immediate area of the damage. • Dredge or fill material of any amount will not be discharged in or near the proximity of a public water supply intakes or municipal watersheds. • All equipment used in the work shall be properly equipped and maintained to ensure compliance with applicable health, safety and environmental regulations. Waste Disposal and Sanitation - The following measures will be implemented and enforced in the performance of the project work: • Littering of any kind will not be allowed on the ROW. A daily litter -policing program will be employed in the work. Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 20 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 • Construction and operating sites will be maintained in a clean and sanitary condition at all times. Collected wastes will be disposed of promptly at an approved site. • "Waste" means all discarded matter, including but not limited to, human waste, trash, garbage, refuse, oil and fuel drums, petroleum products, blasting boxes, worn out parts, abandoned equipment, leftover materials, etc. • Excess or unsuitable materials will be returned to the supplier, sold to a commercial salvage yard, turned in at commercial recycling center or delivered to public or private disposal site approved for project use. • Special implementation plans prepared for and made part of the work will be maintained and followed for the duration of the work. Such plans may include Hazardous Materials Management Plan, Spill Prevention and Countermeasure Plan and others. • Portable chemical toilets will be provided and dispersed within the project area. Their number and location will vary with the length of the project, the number of workers present and the work phase of the project. Generally, a portable toilet will be provided at each contractor yard, pipe yard or permanent staging area. A portable toilet will be available for worker use within 7.5 miles of any point along the ROW (i.e. 15 mile spacing). Other criteria not withstanding, a portable toilet will be provided for each 40 people or fraction thereof employed on the work. • Human wastes stored in portable toilets will be removed from the ROW on a regular periodic basis according to the capacity of the units and their monitored usage. Such human waste will be disposed of at an approved location in accordance with applicable laws and regulations. Construction Access - Access for construction equipment and personnel will be entirely from existing public roads, existing field access roads and along the pipeline right-of-way. Public roads involved include Interstate 70 and its associated frontage roads, Highway #6 and County Road #246. Bargath has already or will enter into operating agreements with the landowners or operators for existing field access roads to be used for construction and operations. Where needed, Bargath will apply for and acquire temporary use permits for project field access roads located on Federal lands. Appendix A POD Location Maps shows graphically the public roads and the field access roads to be used for project construction. Access roads for project use located on U. S. Naval Oil Share Reserve and BLM lands are listed in Appendix C Table of Access Roads on Federal Lands. Diagrams, Drawings and Cross Sections — Appendix A POD Location Maps of this POD provides graphic information about the pipeline project vicinity and location of the pipeline routes and major facilities in addition to other information. Pipeline construction details proposed for project use including road and drainage crossings, right-of-way cross section development, topsoil clearing Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 21 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 limits and construction sequence are provided in Appendix D Typical Drawings of this POD. These drawings include the following: • DWG No. DRG -14294-7203 Typical Bored Crossing Of Road By Uncased Pipeline • DWG No. DRG -14294-7204 Typical Open Cut Crossing Of Road By Uncased Pipeline • DWG No. DRG -14294-9105 Typical Crossing Of Creek Or Drainage • DWG No. DRG -14294-9124 Typical R.O.W. Section Trench & Spoil Area Topsoil Salvage • DWG No. DRG -14294-9125 Typical R.O.W. Section With Full Width Topsoil Salvage • DWG No. DRG -14294-9135 Typical Open -Cut Crossing Non -Flowing Stream Method • DWG No. DRG -14294-9145 Typical R.O.W. Section Blade Width Topsoil Salvage • DWG No. DRG -14294-9200 Typical Side Hill R.O.W. Section With Bi - Level Grading • DWG NO. DRG -14294-9203 Natural Gas Pipeline Typical Construction Activities Sequence Contingency Planning and Contacts — The following individuals and companies currently have interest, agency or representative capacity for Bargath and WPRMT in part or all of the design, development, permitting, construction and operation aspects of the pipeline project. Additional individuals with the responsibilities of construction management, inspection, materials, construction, operations, health & safety, environmental and other will added to this list in the course of the project. BLM, county, state and local government agency contacts and representatives will be added as soon as they have been identified or assigned. Name Title Responsibility Company Contact Info Tom Fiore Staff Operations Engineer Company Sponsor/ Manager Williams Production RMT Company, Parachute, Colorado, 970-263-2743 Office Eric Miller District Facilities Engineer Company Sponsor/ Manager Williams Production RMT Company, Denver, Colorado, 303-629-8417 Office Charles Bucans, PE Principal Project Manager Star Valley Engineering, Inc. Etna, Wyoming, 307-883- 4906 Office Larry G. Bodyfelt, PELS Engineering Manager Project engineering, surveying, technical services D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Office Jim Bassett PLS (or) Dave Spurlock PLS (or) Field Survey Supervisor D. R. Griffin & Associates, Inc. Rock Springs, Wyoming Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 22 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 Name Title Responsibility Company Contact Info 307-362-5028 Office Chris Hamilton PLS Survey Manager Sandy Hotard CPL Field Land Manager ROW acquisition & permitting Williams Production RMT Company, Parachute, Colorado, 970-683-2288 Office Michael Gardner Senior Environmental Specialist Environmental Matters Williams Production RMT Company, Parachute, Colorado, 970-285-9377 Office Michael Klish Principal Environmental Scientist Environmental Matters Westwater Engineering, Grand Junction, Colorado, 970-241-7076 Office. Industrial Wastes and Toxic Substances - No toxic substances are proposed for use in connection with construction. However, if toxic substances are required, usage shall conform with the provisions of the Toxic Substances Control Act of 1976, as amended (40 CFR Part 702-799). Any release of toxic substances (leaks, spills, etc.) in excess of the reportable quantity as established by 40 CFR Part 117.3, shall be reported as required by the Comprehensive Environmental Response, Compensation, and Liability Act of 1980, Section 102 B. A copy of any requested report required by any federal or state agency of a reportable release or spill of any hazardous material shall be furnished to the authorized officer within 5 working days of the occurrence of the spill or release. All other waste, trash, or refuse will be stored in containers at all times and disposed of in an approved county or commercial landfill. 6.0 RESOURCE VALUES AND ENVIRONMENTAL CONCERNS As required, separate and specific studies of resource values and environmental concerns for part or all of the project area will be made as part of the Federal right-of-way application process in the form of an Environmental Assessment report. As agreed between Bargath and the BLM, the required resource and environmental studies and report preparation may be done by the BLM or by an approved consultant. Subject to agreement between Bargath and the BLM, a consultant if used shall be retained by Bargath, the BLM or jointly. Similar studies and report submittals will be required in part or whole for the Garfield County Building & Planning Department Pipeline Development Plan Permit submittal. Topics addressed, studied and reported in the Environmental Assessment are to include: • General Project Description • Water Use and Quality Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 23 of 25 DRG Job # 14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 • Vegetation and Wildlife • Cultural Resources • Socioeconomics • Geological Resources • Soils • Land Use, Recreation and Aesthetics • Air and Noise Quality • Alternatives • Reliability and Safety • Cumulative Impacts 7.0 STABILIZATION AND REHABILITATION Stabilization and rehabilitation for the project during the construction phase will be as described in the "Cleanup & Restoration" in Section 6.0 Construction Of The Facility above. Following construction and throughout the life of the project, the pipeline ROW will be monitored during routine ground inspections to evaluate the success of erosion control and re -vegetation. Attention during inspections will be given to locating riles, gullies, washouts and observing the condition of vegetation. The purpose of the monitoring will be to identify problem areas so that suitable corrective action can be decided and initiated. 8.0 OPERATION AND MANTENANCE The pipeline project will be operated and maintained in accordance with standard procedures that will ensure the integrity of the pipeline system. These operation and maintenance (O&M) procedures will be in accordance with safety standards applicable regulations. O&M of the pipeline will be performed by Bargath and select contract service personnel. Bargath has operations offices in the project vicinity. O&M personnel will be qualified and trained to conduct their respective duties. The pipeline will be controlled from a single gas control center located at the Bargath Parachute Creek Gas Plant near Parachute, Colorado. Initially, personnel at the gas control center and in the field will monitor and control the pipeline using manual methods. At a later time, the system will have communication and automation connections and facilities integrated with gas control, downstream processing plants, metering stations, inlet and outlet pressure regulators, upstream compressors stations, side valves and other such facilities. Ultimately, the system may be able to monitor and control all flows, pressures, flow conditions, valve open/close positions and compressor on/off states in a fully automated unattended mode. Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 24 of 25 DRG Job #14466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 Last Revised 3/8/07 The entire pipeline ROW will be clearly marked with pipeline markers and at public roads and other locations specified in applicable regulations. Such markings help reduce the possibility of damage to the pipeline as a result of construction or other activities. Upon commissioning of the project, ground patrols will be conducted periodically to inspect the ROW in order to monitor the integrity of the pipeline and the success of restorative measures. Surface travel would generally be limited to periodic valve inspections, corrosion surveys, leak surveys, ROW maintenance, and any pipeline repairs that may be needed. The frequency of patrols will conform to the requirements of DOT regulations. An "Emergency Plan" will be developed in conformance with applicable DOT requirements. The plan will establish written procedures that are intended to minimize the hazards in the event of a gas pipeline emergency. It is anticipated that the plan will address topics such as administrative issues, emergency planning, assignment of responsibilities, handling and evaluating emergency calls, responding to and controlling emergency situations, news media communications, restoration of service, obtaining and reporting emergency information, employee training, liaison with public officials, general public information program, location/inventory of pipeline repair materials and equipment, and lists of emergency telephone numbers and key personnel. 9.0 TERMINATION AND RESTORATION At the end of the pipeline's useful life, Bargath will obtain all necessary authorizations from appropriate landowners and government agencies to salvage or abandon the facilities. At that time, the pipeline will be depressurized and purged of all combustible materials. All above ground facilities would be separated and removed. All unsalvageable material would be disposed of at an approved public or private landfill. If the pipeline was to be abandoned in place, open ends of the remaining pipeline would be capped and sealed. The abandoned pipeline would then be filled with an inert media such as water, nitrogen or carbon dioxide at near zero gauge pressure. Alternatively, the decommissioned pipe would be extracted from the ground, cut in to joint lengths, hauled from the site for re -use on other projects or sold for salvage. The sites and rights-of-way from which the above ground facilities and pipe were removed would be re -graded, restored and reseeded as needed to achieve satisfactory reclamation. The abandoned rights-of-way would revert to the then present landowners or controlling agencies. Plan of Development 20" Crawford Trail Gathering P/L Williams Production RMT Co. Page 25 of 25 DRG Job 414466 D. R. Griffin & Associates, Inc. Rock Springs, Wyoming 307-362-5028 in4, E5M s M 96?J S91 M L624 $91. ElfRIFFIN & ASSOCIATES, INC. 1 CRAWFORD TRAIL GATHERING PIPELINE PROPOSED PROJECT FOR BARGATH, INC. 1414 ELK ST., SUITE 202 ROCK SPRINGS, WY 82901 (307) 362-5028 SCALE: 1 "= 2000' TOTAL FEDRAL LAND LENGTH: 3,830'± JOB No. 14466 DATE: 03/08/07 PROPOSED PIPELINE - - - - ACCESS ROADS TOPO MAP SHEET 1 1 U.S. FISH AND WILDLIFE SERVICE SPECIES ASSESSMENT AND LISTING PRIORITY ASSIGNMENT FORM SCIENTIFIC NAME: Penstemon debilis COMMON NAME: Parachute Beardtongue LEAD REGION: Region 6 INFORMATION CURRENT AS OF: March 6, 2006 STATUS/ACTION: Species assessment - determined species did not meet the definition of endangered or threatened under the Act and, therefore, was not elevated to Candidate status New candidate X Continuing candidate Non -petitioned X Petitioned - Date petition received: 03/15/2004; 05/11/2004 90 -day positive - FR date: _ 12 -month warranted but precluded - FR date: _ Did the petition request a reclassification of a listed species? FOR PETITIONED CANDIDATE SPECIES a) Is listing warranted (if yes, see summary of threats below)? YES b) To date, has publication of a proposal to list been precluded by other higher priority listing actions? YES c) If the answer to a. and b. is "yes," provide an explanation of why the action is precluded. We find that the immediate issuance of a proposed rule and timely promulgation of a final rule for this species has been, for the preceding 12 months, and continues to be, precluded by higher priority listing actions (including candidate species with lower LPNs). During the past 12 months, almost our entire national listing budget has been consumed by work on various listing actions to comply with court orders and court -approved settlement agreements, meeting statutory deadlines for petition findings or listing determinations, emergency listing evaluations and determinations, and essential litigation -related, administrative, and program management tasks. We will continue to monitor the status of this species as new information becomes available. This review will determine if a change in status is warranted, including the need to make prompt use of emergency listing procedures. For information on listing actions taken over the past 12 months, see the discussion of "Progress on Revising the Lists," in the current CNOR which can be viewed on our Internet website (http://endangered.fws.gov/). 1 Listing priority change Former LP: _ New LP: Date when the species first became a Candidate (as currently defined): 02/26/1996 Candidate removal: Former LP: _ A — Taxon is more abundant or widespread than previously believed or not subject to the degree of threats sufficient to warrant issuance of a proposed listing or continuance of candidate status. U — Taxon not subject to the degree of threats sufficient to warrant issuance of a proposed listing or continuance of candidate status due, in part or totally, to conservation efforts that remove or reduce the threats to the species. _ F — Range is no longer a U.S. territory. _ I — Insufficient information exists on biological vulnerability and threats to support listing. _ M — Taxon mistakenly included in past notice of review. _ N — Taxon does not meet the Act's definition of "species." X — Taxon believed to be extinct. ANIMAL/PLANT GROUP AND FAMILY: Flowering Plant, Scrophulariaceae HISTORICAL STATES/TERRITORIES/COUNTRIES OF OCCURRENCE: Colorado CURRENT STATES/ COUNTIES/TERRITORIES/COUNTRIES OF OCCURRENCE: Garfield County, Colorado LAND OWNERSHIP: About 69 percent of the occupied habitat and plants occur on private land owned by Occidental Oil. About 31 percent of the occupied habitat and plants occur on land managed by the Bureau of Land Management (BLM). LEAD REGION CONTACT: Pat Mehlhop, (303) 236-4215 LEAD FIELD OFFICE CONTACT: Ellen Mayo, (970)243-2778, *14 BIOLOGICAL INFORMATION Species Description Parachute penstemon is a mat -forming perennial herb with thick, succulent bluish leaves, each about 2 centimeters (0.8 inch) long and 1 centimeter (0.4 inch) wide. Flowers are funnel -shaped, white to pale lavender, blooming during June and July. Shoots are produced that run along under ground, forming new plants at short distances. Plants are able to survive on the steep, unstable shale slopes where it is found by stem elongation as leaves are buried by the shifting talus. Buried stems progressively elongate downslope from the initial point of rooting to a surface sufficiently stable to allow the development of a tuft of leaves and flowers (O'Kane and Anderson 1987). Plants produce a low number of seeds, are primarily outcrossers, and have many different pollinators that vary between populations. Taxonomy 2 Penstemon debilis was first described by O'Kane and Anderson (1987). There have been no challenges to the taxonomy as first put forward by the original authors. It is a monotypic species with an unquestioned taxonomy. Habitat The Parachute beardtongue grows on steep, oil shale outcrop slopes of white shale talus at 2,400-2,700 meters (8,000-9,000 feet) in elevation on the southern escarpment of the Roan Plateau above the Colorado River west of the town of Parachute, Colorado. It is found only on the Parachute Creek Member of the Green River Formation. Historic Range/Distribution Historic range and distribution for this species is unknown (Spackman et. al. 1997). Current Range/Distribution The parachute beardtongue is a very narrow endemic. The known occupied habitat is about 80 hectares (200 acres) in Garfield County. It is restricted to the Parachute Creek Member of the Green River Formation in the Piceance Basin. This geological stratum is the major source of oil shale in the United States and this species is one of several oil shale endemic plant species. The total area of the plant's geographic range is about 3 kilometers (2 miles) wide and 29 kilometers (8 miles) long. The Green River Formation is fairly widespread in the Piceance Basin and has been extensively searched. However, additional populations of this species have not been discovered (Spackman et al. 1997). Population Estimates/Status The Parachute beardtongue is known from six locations, two of which have only a few plants. The total estimated number of plants is currently 1,443. There are only four populations considered viable by the Colorado Rare Plant Technical Committee, three of which are owned by an energy company. The largest population on BLM land was estimated to have 300-500 plants or rosettes in 1998 when it was discovered. By 2001, only 43 plants plus numerous rosettes were known (Colorado Natural Heritage Program [CNHP] 2004); in 2005 there are again about 500 plants (Mayo, USFWS, unpubl. lit. 2005; Scheck, BLM, pers. comm., 2005). The second BLM population had 200-300 plants reported in 1994, but only 3 plants could be found in 1998 (McMullen 1998). Fewer than 10 plants were observed in 2002 (CNHP 2004). The third population, discovered in 1996 on a road cut, had 10 plants, of which 3 can still be found (Center for Native Ecosystems et al. 2004). The fourth population was previously undocumented because access was denied by an oil company. A small part of this population, about 30 plants, is now known to be on BLM land; there are unconfirmed estimates of 300 more plants on the private portion (Trappett, BLM, pers. comm. 2005). The populations on BLM land represent about 38 percent of the total plants counted and estimated. Two large populations of 300 or more plants each are on Occidental Oil property (CNHP 2004). 3 OWNER # OF PLANTS 2005 BLM 500 BLM 10 BLM 3 BLM 30 Occidental 600 (+300 estimated on land not accessed) TOTAL 1,443 THREATS A. The Present or Threatened Destruction, Modification, or Curtailment of Its Habitat or Range. This species is threatened by destruction of its habitat for natural gas production, oil shale production, other energy development and associated impacts resulting from increased access to the populations. Existing gas leases at three BLM sites have stipulations for no surface occupancy and no surface disturbance in occupied habitat and in areas necessary for the maintenance or recovery of the species (Scheck, BLM, pers. comm. 2004). The large population at Anvil Points Mine on BLM-managed land has about 35 percent of the total known and estimated plants. Locked gates limit public access to the site. Part of this occupied habitat is not currently leased. When the new Resource Management Plan (RMP) amendment for the Roan Plateau is completed, this portion of the site is expected to be leased as well (BLM 2004). Whether no surface occupancy stipulations will be applied to protect candidate species under the new plan is not known. The BLM recently approved an action under the Comprehensive Environmental Response, Compensation and Restoration Act (CERCLA) to remove health and safety hazards from the Anvil Points Mine site. Actions will include closing access to the mine adits and removing Lead from the soil on the mine bench. Actions also could include complete closure of the access road below the mine bench. The BLM plans to complete the project design during the summer of 2006 and issue a contract in the fall. An inventory of the penstemon plants on the site will be completed during planning. About 300 of the 500 plants in this population will be included in the action area (Mayo, USFWS, unpubl. lit. 2005). An Action Memorandum from the BLM State Director specifies that the project be designed to avoid impacts to the Parachute penstemon plants (Goodenow, BLM, pers. comm. 2006). Plans will have to be implemented very carefully to avoid destruction of plants. The second BLM population has diminished from "hundreds" of plants found in 1991 to fewer than 10 plants by 2002 and is no longer considered viable by the Colorado Rare Plant Technical Committee. Possible reasons for this decline include trampling and compaction by recreational users. The plants were at a roadside viewpoint and hang glider launch area. A barrier was installed to discourage gliders, but the population was not fenced. New plants grown off site from seeds were introduced but declined over several years. Monitoring failed to show a cause for the disappearance of the plants (CNHP 2004). 4 The third population, on a road cut, had 10 plants in 1996, of which 3 can still be found; it is not considered viable by the Colorado Rare Plant Technical Committee. The road is now heavily used daily by oil and gas company vehicles accessing private development sites on the Roan Plateau. A fourth population is mostly on Occidental land, perched on an unstable slope above a road that is currently used for access to an ongoing reclamation project at an old oil shale mine site. An unverified estimate of the number of plants on the Occidental part of this site is 33. Several plants on this road bank are dangling by their roots, and more would be lost here if the road right of way was widened. The BLM Grand Junction Field Office withheld the areas occupied by these two road bank populations from a new lease parcel sold in November 2005 (Trappett, BLM, pers. comm. 2006). Populations 5 and 6, including about 600 (42 percent) of the plants, occur on land owned by Occidental Oil. These populations are behind locked gates. A portion of one population was included in the Mount Callahan State Natural Area. An oil shale production facility contiguous to the Natural Area was mentioned in the designation. Occidental's current plans for research, exploration or development at or near the three sites they own are unknown (Colorado Natural Areas Program [CNAP] 1987; Scheck, BLM, pers. comm. 2004). The Piceance Basin is experiencing a "boom" in natural gas production at the present time. In 2004, Garfield County was one of two counties in Colorado issuing the greatest number of permits to drill, and it was one of the largest producers of oil and natural gas (Cappa et al. 2005). The number of new drilling permits approved in Garfield County was 1,508 in 2005, twice as many as in 2004, with another increase expected in 2006 (Macke 2005). The BLM projects that from the portion of the Roan Plateau that will be addressed in the new RMP amendment, around 3,916 billion cubic feet of natural gas will be developed over the next 20 years (Center for Native Ecosystems 2004). On June 9, 2005, BLM announced in the Federal Register its intent to initiate a program to facilitate research, development, and demonstration of oil shale recovery technologies on Federal lands (70 FR 33753). The BLM recognizes this effort as a first step toward successful development of oil shale reserves. The Energy Policy Act of 2005 provisions require the Interior Department to complete a programmatic Environmental Impact Statement by February 2007 for a commercial leasing program for oil shale and tar sands resources on public lands. On December 13, 2005, the BLM published a notice of intent to prepare the document (70 FR 73791). Public scoping meetings were held in January 2006 for the Piceance Creek Basin, which includes the entire range of the Parachute beardtongue. B. Overutilization for Commercial Recreational Scientific, or Educational Purposes. None known. C. Disease or Predation. None known. 5 D. The Inadequacv of Existing Regulatory Mechanisms. Parachute beardtongue has no Federal regulatory protection for about 62 percent of the total known and estimated plants because they are on private land. There are no State regulations that protect rare plant species in Colorado. The BLM controls access by means of a locked gate to its one viable population containing about 35 percent of all the plants. Part of this BLM site is leased for oil and gas exploration with no surface occupancy allowed. The remainder of the habitat also will be leased under the new RMP, which has not yet been released. The preferred alternative for the new RMP amendment does not include a proposed Area of Critical Environmental Concern to further protect this species. This BLM population is impacted sporadically by Garfield County road stabilization which is done to maintain access to a transmitter tower located on the plant population. The BLM told Garfield County to apply for a right-of-way when the land was transferred from Department of Energy, but continues to allow unauthorized access by the County (Scheck 2004). The BLM plans for the removal project described under Threats include a commitment to avoid adverse impacts to the plants, but decisions about the closure status of the site have not yet been made (Goodenow, BLM, pers. comm. 2006). One population, which has been reduced to 10 plants, is on BLM land at a roadside viewpoint and hang glider launch area. A barrier was installed to discourage gliders, but the population was not completely fenced. On another BLM roadside population several plants are dangling by their roots from a bank that has been undercut by heavy equipment being used to access an oil shale mine reclamation site on private land. The plants are flagged and BLM will not approve road widening. The oil and gas lease has been withheld pending plans for protection of the plants (Trappett, BLM, pers. comm. 2006). The fourth BLM site with three plants is on another roadbank a few feet from heavy truck traffic on a gravel road. There are no barriers to shield the plants. There are no travel management plans that apply to roads such as these that were built before the plants were found. A portion of one population of the larger populations was included in the Mount Callahan State Natural Area, which was designated in 1987 and is managed by CNAP (CNAP 1987). An oil shale production facility contiguous to the Natural Area was mentioned in the designation. The Natural Area agreement can be terminated at any time. E. Other Natural or Manmade Factors Affecting Its Continued Existence. Population sizes are small and vulnerable to occasional ground disturbance such as trampling by hikers and digging by fossil hunters (CNHP 2004). Climatic events, such as prolonged drought, also may adversely impact the species (CNHP 2004). CONSERVATION MEASURES PLANNED OR IMPLEMENTED: Public access to the primary BLM population has been closed to protect the population by reinstallation of a locked gate in 2005 (Scheck, BLM, pers. comm. 2005). A planned CERCLA removal project at this site may result in permanent closure of road access (Goodenow, BLM, pers. comm. 2006). The BLM has withheld an oil and gas lease for two small sites pending conservation measures for the plants (Trappett, BLM, pers. comm. 2006). SUMMARY OF THREATS 6 • The entire range of the species is small. • There are only four viable populations • Three of the four viable populations are on land owned by an oil and gas company. • Plans are under way for a CERCLA removal project on the largest BLM population. Plans will have to be implemented very carefully to avoid destruction of plants. • All populations are located in the Roan Plateau/Piceance Basin gas field development area where new privately owned wells are being drilled and new leases and applications for permits to drill are being issued in rapidly increasing numbers. • All populations are endemic to oil shale bearing strata in the Parachute Creek member of the Green River formation, which is the focus of current BLM efforts to promote oil shale research and development. LISTING PRIORITY THREAT MAGNITUDE IMMEDIACY TAXONOMY PRIORITY High Imminent Non -imminent Monotypic genus Species Subspecies/population Monotypic genus Species Subspecies/population 1 2* 3 4 5 6 Moderate to Low Imminent Non -imminent Monotypic genus Species Subspecies/population Monotypic genus Species Subspecies/population 7 8 9 10 11 12 RATIONALE FOR LISTING PRIORITY NUMBER Magnitude: High This species is an extremely rare edaphic endemic. The total estimated number of plants in 6 populations is 1,443 individuals. There are only four viable populations, three of which are owned by an energy company. The loss of any one of these four populations would represent a substantial diminution in the viability of the species. All six known populations face ongoing or potential threats including --oil and gas development; oil shale recovery; inadequacy of existing regulatory mechanisms; and potential stochastic events. Imminence: Imminent Oil and gas exploration and development continues to increase each year on and around the Roan Plateau. Five hundred sixty-six new wells were permitted in Garfield County in 2003, 796 in 2004, and 1,508 in 2005 (Macke 2005). The main access road to the Roan Plateau now has a guard at the gate to admit and log authorized vehicles. The guard recently reported that 7 300 vehicle -trips a day are made to private drilling sites on the Plateau (Mayo, USFWS, unpubl. lit. 2005). A new lease was issued in November 2005 on the habitat for two of the small BLM populations, but the plant sites were withheld at the last minute. Both sites have heavy vehicles traveling within 2-20 feet of the plants (Mayo, USFWS, unpubl. lit. 2005). About one third of the large BLM population will be leased after a new RMP amendment is completed, with stipulations not yet decided (Scheck, BLM, pers. comm. 2004). About two thirds of that same population will undergo a CERCLA removal action in 2006 or 2007. There is no information available from Occidental regarding their plans for development of the three population sites on their land. Glenwood Springs is one of the BLM field offices that is implementing a new pilot project designed to expedite energy development in 2006. Federal government policies, technological advances and economics now appear poised for development of oil shale as well as natural gas. The level of threats this poses for the Parachute beardtongue is considered high due to the direct overlap of energy resources and all known species occurrences. RATIONALE FOR CHANGE IN LISTING PRIORITY NUMBER YES Have you promptly reviewed all of the information received regarding the species for the purpose of determining whether emergency listing is needed? Is Emergency Listing Warranted? NO. The one viable BLM population will be the subject of careful planning to protect the plants prior to a removal action under CERCLA. The removal project is expected to reduce the number of visitors to the mine tunnels at the site, and may result in complete closure of the access road (Goodenow, BLM, pers. comm. 2006). The three private populations could be developed at any time, but there is no information available to indicate that development plans are under way at this time. DESCRIPTION OF MONITORING: The biologist for the BLM Glenwood Springs Field Office keeps us informed of issues affecting the species. She conducts onsite inspections several times a year, taking a U.S. Fish and Wildlife Service (USFWS) botanist along for two visits, and checks on two of the Occidental locations by permission at least once a year. We are assisting the State BLM Botanist in monitoring the trend in plant numbers on their largest population. The BLM Grand Junction and USFWS biologists together documented the location of the sixth population. The Colorado Rare Plant Technical Committee reviews the species' status at a Statewide meeting each year. COORDINATION WITH STATES: The CNAP, which is the State agency with responsibility for native plants, and CNHP at Colorado State University reviewed the species' status and provided occurrence data to the USFWS. The CNAP reported no change in the status of their Natural Area adjacent to the Occidental -owned populations. The CNHP enters new population updates and status information into their data system and provides downloads to the USFWS via a section 6 agreement. LITERATURE CITED 8 Bureau of Land Management. 2004. Roan Plateau Planning Area, Draft Resource Management Plan Amendment and Environmental Impact Statement. Glenwood Springs Field Office, Colorado. Cappa, J.A., G. Young, J.W. Keller, C.J. Carroll, and B. Widmann. 2005. Colorado Mineral and Mineral Fuel Activity, 2004. Colorado Geological Survey, Information Series 70. Center for Native Ecosystems, S.L. O'Kane, Jr., J.H. Broderick, and Colorado Native Plant Society. 2004. Petition to List Parachute penstemon (Penstemon debilis) as Threatened or Endangered, Prepare an Emergency Listing Rule, and Designate Critical Habitat Under the Endangered Species Act. 96pp. Colorado Natural Areas Program. 1987. Mount Callahan Natural Area Articles of Designation. Department of Natural Resources, Denver, Colorado. Colorado Natural Heritage Program. 2004. Biodiversity Tracking and Conservation Data System. Colorado State University, Ft. Collins. Element Occurrence Records for Penstemon debilis. Macke, B. 2005. Colorado Oil and Gas Conservation Commission monthly staff report, statistics, 8/15, 2005. McMullen, A.L. 1998. Factors Concerning the Conservation of a Rare Shale Endemic Plant: The Reproductive Ecology and Edaphic Characteristics of Penstemon debilis (Scrophulariaceae). Unpublished Master's Thesis Submitted to Utah State University, Logan. O'Kane, S.L., Jr., and J.L. Anderson. 1987. Penstemon debilis (Scrophulariaceae): a New Species from Colorado Endemic to Oil Shale. Brittonia 39(4):412-416. Scheck, C. 2004. Memorandum and maps on status of road access to Anvil Points Mine. BLM Glenwood Springs Field Office. Spackman, S., K. Fayette, K. Carsey, and R. Rondeau. 1997. Field survey and protection recommendations for the globally imperiled Parachute penstemon, Penstemon debilis O'Kane and Anderson. Colorado Natural Heritage Program, Colorado State University, Fort Collins, Colorado. Unpublished report prepared for Colorado Natural Areas Program, Denver. 9 APPROVAL/CONCURRENCE: Lead Regions must obtain written concurrence from all other Regions within the range of the species before recommending changes, including elevations or removals from candidate status and listing priority changes; the Regional Director must approve all such recommendations. The Director must concur on all resubmitted 12 -month petition findings, additions or removal of species from candidate status, and listing priority changes. Approve: /s/ Sharon Rose 11/4/2005 Acting Regional Director, Fish and Wildlife Service Date Concur: August 23, 2006 Director, Fish and Wildlife Service Date Do not concur: Director, Fish and Wildlife Service Date 10 PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@hughes.net Project: Crawford Trail Gathering Pipeline Submittal Item Tab 8- Primary Project Participants 9.07.04 (7) Listing of company representative, company and individual acting as an agent for the company and construction company contacts. There are no federal and state agency contacts. Bargath, Inc: Authorized Representative Mr. Tom Fiore P.O. Box 370 Parachute, CO 81635 Phone: 970-263-2743 Cell Phone: 970-210-1641 Email: tom.fiore@williams.com Project Manager Star Valley Engineering, Inc. Mr Charles Bucans, P.E. 107675 North U.S. Highway 89 Etna, WY 83118 Phone: 307-883-4906 Cell Phone: 307-890-8013 Email: sve@silverstar.com DR Griffin & Associates, Inc: Project Designer and Surveyor Mr. Larry Bodyfelt, PELS Engineering Manager D. R. Griffin & Associates, Inc. Professional Engineers & Land Surveyors 1414 Elk Street, Suite 202 Rock Springs, WY 82901 Phone: 307-362-5028 Fax: 307-362-1056 Cell: 307-389-0371 Email: lbodyfelt@drg-wy.com Page 1 of 2 Pipeline Construction Company The company has not been chosen. This information will be updated and submitted to Garfield County upon selection of the company. Please contact me with any questions. Sincerely, PhilipVaughan �- President- PVCMI Page 2 of 2 PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@hughes.net Project: Crawford Trail Gathering Pipeline Submittal Item Tab 9- Project Facilities 9.07.04 (8) The Crawford Trail 20 inch Gathering pipeline project facilities are noted in attached mapping prepared by DR Griffin & Associates in tab 2- Vicinity Map 9.07.04 (1). Additionally, please find attached within this tab, detailed drawings and geotechnical reports for the Crawford Trail Compressor Station. The following information is attached: A. Crawford Trail Compressor Station- Please find this information in Tab 9- Project Facilities. Harris Group, Inc. CT -CI -6401 Rev. A 2/15/07 CT -CI -6402 Rev. A 2/15/07 CT -CI -6403 Rev. A 2/15/07 CT -CI -6404 Rev. A 2/15/07 CT -CI -6405 Rev. 1 6/20/07 Crawford Trail Compressor Station- Geotechnical Engineering Group, Inc. Job 2526 Geotechnical Investigation Report dated 12/22/06. Page 1 of 6 B. Construction and Permanent rights-of-way widths are detailed below. The surface agreements are attached in Tab 5- Evidence of surface owner notification and of surface agreements 9.07.04 (4). Additionally, the working space and spoil space are noted on the DR Griffin & Associates drawings in tab 2. Summary ROW Length and Acreage Totals For Federal and Fee Lands Crawford Trail Gathering Pipeline 20" Gathering Line Crawford Trail Compressor Station Bargath Inc. c/o Williams Production RMT Company Owner Length LF Permanent ROW Acres Construction ROW ACRES Extra Workspace at 9% Total Acres Total Surface Area Acres Federal Lands 3,820 4.38 6.58 0.60 7.17 Fee Lands Chevron 37,537.80 Chevron 30 ft.= 25.85 Chevron 50 ft.= 43.09 3.88 46.97 Fee Lands- Other 48,185.30 89, 543.10 50 ft.= 55.31 85.54 75 ft.= 82.96 132.63 7.47 11.95 90.43 144.57 Total Lands for Pipelines Lands for Crawford Trail Compressor Station — All Fee 14.46 Additional details regarding these issues are noted in tab 22- Construction Management Plan. C. Technical Details: DESCRIPTION OF COMPRESSION AND DEHYDRATION FACILITIES — RABBIT BRUSH AND WEBSTER HILL Following is a description of the proposed facilities to be installed at Crawford Trail Compression & Dehydration Facilities. INLET SEPARATION This system will be designed to separate liquids from the station inlet gas (2 -phase separation) for the full build -out of 160 MMSCFD at 200 PSIG operating pressure. These liquids can be in the form of periodic pipeline slugs or inay be continuously entrained droplets in the gas stream. The maximum droplet size specification for gas leaving the scrubber is 25 microns. The maximum slug size for design purposes is 50 barrels. This event will occur no more than once every 24 hours over a 5 -minute period. Overpressure protection for a blocked outlet at the scrubber is provided at the well sites. Page 2 of 6 INLET MEASUREMENT The inlet measurement will be designed to have a capacity of 160 MMSCFD. The type of measurement element to be employed is a clamp -on ultrasonic meter. No continuous gas analysis of any kind is required in the inlet measurement system. The measurement is not for custody transfer, but the accuracy should be consistent with the commercially available measurement equipment. The output of this measurement device is both local and remote flow indication with EFM data accumulation. The EFM device must communicate to a radio that transmits the data to the Williams SCADA network. GAS COMPRESSION The gas compression system will initially consist of two (2) Caterpillar 3612/Ariel JGZ-4 compressor/engine packages. The station will be designed and laid out to expand to four compressor units at a later date. There will be two stages of compression per compressor unit. The physical layout will be similar to the existing design at the Parachute Creek facility to the extent possible. Air permits for this expansion have been applied for from the Colorado Department of Public Health and Environment. Please see these applications in Tab 7. Interstage cooling will be required between the two stages of compression. The intercooler bundles will be incorporated into a common bay of an electric -drive air- cooled heat exchanger. The gas aftercooler bundles will be incorporated into a separate bay of an electric -drive air-cooled heat exchanger. The engine coolers will be separate from the gas coolers and will also be electric motor drive. The maximum design dry bulb air temperature is 110°F. There will be one intercooler bay and one aftercooler bay installed initially with capability to expand for the third and fourth units. Space will be provided for the coolers for the third and fourth unit. Important Note: Via this application to Garfield County, we are applying for approval for the expansion of the compressor building at Crawford Trail Compressor Station to a maximum size of 75'-0" wide x 275'-0" long. This would allow for the building/compressor expansion to occur without further Garfield County land use approvals. A Garfield County building permit would, of course, need to be applied for and obtained. Page 3 of 6 GAS DEHYDRATION The gas dehydration system will be a Tri -Ethylene Glycol (TEG) system with an initial capacity of 80 MMSCFD, expandable to 160 MMSCFD with the addition of a second train as a separate expansion project. The purpose of installing the gas dehydration system is to prevent hydrate formation and/or freezing in the downstream pipelines. The moisture specification for all times of the year is 5 lbs water per MMSCFD and the design gas inlet temperature is 120°F. The inlet gas to the dehydration system must be conditioned with coalescer-type separation with 1 micron droplet size. TEG REGENERATION The TEG regeneration system will be sized for the initial load of 80 MMSCFD and will employ controls on the still overhead stream to maintain the BTEX (Benzene, Toluene, Ethyl Benzene and Xylene) at acceptable levels in the non -condensable stream. The system will be expandable to 160 MMSCFD with the addition of a second train as a separate expansion project. The still overhead condenser will be designed with air recirculation capability to prevent freezing during cold weather. Pumps and air-cooled heat exchangers will be electric motor driven. DISCHARGE GAS MEASUREMENT The discharge gas measurement system will be designed to have a capacity of 160 MMSCFD. The type of measurement element to be employed is a clamp -on ultrasonic meter. No continuous gas analysis of any kind is required in the inlet measurement system. The measurement is not for custody transfer, but the accuracy should be consistent with the commercially available measurement equipment. The output of this measurement device is both local and remote flow indication with EFM data accumulation. Continuous moisture content monitoring is also required in the discharge gas measurement system. The EFM device must communicate to a radio that transmits the data to the Williams SCADA network. VAPOR RECOVERY SYSTEM Glycol still overhead vapors, glycol flash tank vapors and condensate flash tank vapors will be compressed by a vapor recovery system and re -introduced into the main gas piping upstream of the inlet gas scrubber. The vapor recovery system will be designed for the full build -out of 160 MMSCFD. The system must be capable of operating acceptably from 35 MMSCFD to 160 MMSCFD facility throughput range. The compressor will be driven by electric motor drives and the oil cooler will be electric motor drive. CONDENSATE FLASH AND STORAGE Produced condensate will be flashed to 20 psig in the Condensate Flash Tank prior to being routed to the storage tanks. The flashed vapors will be collected in the Vapor Recovery System. The liquids from the Condensate Flash Tank will be routed to the Condensate Storage Tanks. There will be three 400 bbl Condensate Storage Tanks for storage of produced hydrocarbon liquids at 4 oz/in2 (commonly referred to as atmospheric storage). Page 4 of 6 FUEL GAS CONDITIONING The fuel gas conditioning system will be designed for the full build -out of 160 MMSCFD. The system must be capable of operating acceptably from 35 MMSCFD to 160 MMSCFD facility throughput range. The source of fuel gas will be on the inlet of the facility on the downstream side of the Inlet Separator where clean, dry gas is available to start the compressors and run the standby generator. The fuel gas will be heated above the hydrocarbon dew point by injecting a controlled stream of hot gas from the ls` stage compressor discharge. A fuel gas scrubber will be provided to filter the gas to 0.3 microns. BUILDING SYSTEMS Compressor Building: Building Type: A pre-engineered, rigid framed metal building is provided to house the engine - compressors and other related equipment. Ample space is allocated around the engine -compressors for access and maintenance. The building has one bay for work area and is designed to allow for future expansion. HVAC: Ventilation design for the compressor building shall provide for the design peak summer condition to maintain 125°F with the engine -compressors running and the outside ambient temperature of 110°F (temperature difference = 15°F). No additional heating, cooling or air conditioning is provided. Important Note: Via this application to Garfield County, we are applying for approval for the expansion of the compressor building at Crawford Trail Compressor Station to a maximum size of 75'-0" wide x 275'-0" long. This would allow for the building/compressor expansion to occur without further Garfield County land use approvals. A Garfield County building permit would, of course, need to be applied for and obtained. MCC/Control Building: Building Type: A pre-engineered, rigid frame metal building is provided to house the facility controls, MCC, air compressor system, generator and other related equipment. Ample space is allocated around the equipment for access and maintenance. HVAC: In the finished area of the MCC/control building, the cooling and heating shall be provided by a refrigeration type air conditioning and a forced air, gas furnace system. Heating for the unfinished area shall be by gas fired, unit space heaters. Cooling is not required in this area. Page 5 of 6 Important Note: Via this application to Garfield County, we are applying for approval for the expansion of the MCC/Control building at the Crawford Trail Compressor Station to a maximum size of 50'-0" wide x 125'-0" long. This would allow for the compressor station expansion to occur without further Garfield County land use approvals. A Garfield County building permit would, of course, need to be applied for and obtained. Please contact me with any questions. Sincerely, Phil` ip B. Vaughan President PVCMI Page 6 of 6 8 7 6 5 4 3 D c B A gT (SW CORNER PGM) N. 616170.44' E. 1243052.0' EL 8475.60' 81.66B -60237181913E5 N. 50+00 E 20+00 E. 12260' CPNUSER CORB CP CORE 1' EL 6473.33' PL CNP % REBARS ' A/C IE' REBAR) 619591.55' 1242173.64' .6135.00' N. 62+00 1 I 1 8 Li 00+LZ '3 E. 22+00 E. 23+00 $ g w E. 27+00 S co w E. 29+00 w N. 61+00 I I w I{Ikp, ‘C9sW. f J>q� 60+00 I (FENCE { R'NI, 3'-0' PERSONNEL a'�-7 GATE __T m /-_-_-_145__N 481).N. == 58621' N. 59+00 1 1 zr , ' ism % t I I x 57+10 SEE NOTE 14 & TANK CONTAINMENT SECTION ON CT -CI -64056405 w ��i, I w N. 58+00 .tlRl E. 23+19aN ,1 N. 5]+00 1 SEE NOTE CONfNNMENI ON CT-CF6405 T4 & TAN( SECTION• �/'• O 0.1 ' • ' \ I4i ` 3" CRUSHED US SURFACING J' TOFS (hP) ROCK fE3NCE 3 m. 0 QbyNg u •� � 81 5 / N. 56+01 "•,:"."‘ u4 % N. 56+001 QQ 8 E 22+34 ./ FUTURE MANS &DG ®a (SEE NOTE 6) S' o O \ \ \ 1ii9S N. 55+00 I �I� z RIO'.O- 1 /Aj960 , T; _ _ ni _ 1 I I-_ 1 + I /% F V n s " 0 x. u+oo 1 I 1 aI 11a SII 0 N.54+77.5 WI I .9 '• - ®. = I 9/ PERSONNEL GlE N. 53+00 � I'(I( I .�I -]'-0' MEnn , —)_ I o I �I ' IIIIII111 I I I rnL I '1 �1 3'-0' IEASONNEl GATE N. 52+00 I r 24' S DE GATE x. 1+621 I - - 4' MADE SIDEWALK 4 it MCC e4i 1/flu N. 51+00 81, 51+06 i 1 I V. 50+00 x W x I m -J 1057 21' DOUBLE I DOUBLEGTE +�'� , FENCE W /ngubdi _ i N M ce Ey,15T � fly // kw . ��a V. 49+00 ASA, _. ''1 I/ / �q , JPFROSONNEL . i GTE P.B. S 53'1703' W 153.34' '- P.B. 5 5539'10 B. 5 6641'50' W 100.00' P.B. S 5656'59 W 108.00' PIAN L P. 151' 14 22 23 v ACCESS ROAD (TYPICAL) z I P POCKETP lAND CVMPANY 22 23 F 4 CORRIDOR Vows) s 22123 NWSE I NESE N 14'0653' E 958.1' S 8876'154 E 23 27L26 263250' SWSE Y PARCEL- CRAWFORD TRAIL COMPRESSOR STATION SESE 23724 26 S 887 'Or E 2630,41' 26 25 CRAWFORD TRAIL COMPRESSOR STATION VICINITY MAP u111009 3930' LONGITUDE: 108'11' GRAPHIC SCALEto (GI>m) 180E - PO SL NOTES• 1. HORIZONTAL AND VERTICAL CONTROL I5 BASED CN SURVEY DATA PROVIDED BY DR GRIFFIN AND ASSOCIATES. BASIS OF 861P140 FOR GRID SYSTEM 5 BASED ON A IME BENIEEN BENCH MOM 131 IND B2. 2. PARCH. 600NGRY (PR.) BEARINGS SHOWN ME FROM TRUE NORTH. 3. ALL FOUNGMNN ELEVATIONS ARE BASED ON PLANT COORDINATE SYSTEM CORN TOP OF CONCRETE FOR TLE COMPRESSOR BURONO SLAB SET AT ELEVARON 100-M. PAINT 000RDINATE REVATCH 100'-0' 5 EOUAI TO ACTUAL ELEVATION 8453'-0' BASED ON SURVEY DATA 4. 33' HIGH DUAP LIFE' SECONDARY CONTAINMENT STRUCTURE WNTH LINER AND ACCESS STILE AS MANUFACTURED BY SEMI SIFT.. COMPANY. SIMM FALLS, 5D OR APPROVED EQUAL. 5. AAL NEW FENS TO BE 6-0' HON CIWH LANK. B. GRADING IND DRAINAGE SHALL BE MODIFIED FOR FUTURE COMPRESSOR BUILDING E%PASSN AT THE DME OF MAT EXPANSION. ME INURE BUGLING 511E 15 SHOWN ON PVN AS A HIDDEN UNE. DMMNG ND. CT -CI -6402 CT -01-6403 CT -G-6404 CT -G-8405 ABLE CML -GRADING AND GRAMME PLAN - 5HT 1 CML -GRADING AND DRAINAGE PLAN - 5HT 2 CML -GRADING AND ORNNAGE PUN - SW 3 CML -GRADING AND DRAINAGE PUN - MSG DEI5 REVISIONS REV GTE BY ATPD DESCRIPTION GTE 8Y APP'D DESCRIPION WILLIAMS PRODUCTION RMT COMPANY A 72/15/CF BB I5513ED FOR CUENT APPROVAL REV DATE BY PRELIMINARY ISSUE SCALE CMNN 0IK'0 APED APP'D APPROVED ts: ct4' GTE Harris Group Inc. ENERGY CIVIL SITE PLAN WILLIAMS PRODUCT/ON RMT CO. CRAWFORD THAI PROJECT 61060 DRAW, NUMBER CT -CI -6401 (REVA D C B A EE DWG CT -CI -6403 PWA! CULVERT W/FVREO EN12'O StCllONS (62 15 WCLUCNC END SECTIONS) CURVE DATA .� \vr CURVE 4 w' \ N 526@.47/, IT-� Trl 1 I / / / / / / I % i T rr-r i / / / / / / / / / / // 7- 1 -� T I 27.72' QQ11 945 ---It' /r'T 54sz / // / II // i �� /� 1 Is � �= T - __-Num..-., \�\ \ /� -- // .---- `\ E 2410.98 \ "\ \\ \ 6/ \ \ \\\ \\ \ \ \\ \ \ I \ \ I n `4, \/ I 4fj 1 1 I 1 I i I I 111 I i 1 I I 11 I I I I I I I I 1 / / I I f•I/ I I I 1 I I Y I I I 1 I I 11 I I l l I I I I 11 / / / / / / / / // / / / / / / / / 1/ / / / / / / / //j / / / / / / / //// j / / i / / i i///% / 1 / / / / / // // I I f/////�///// I I I I//////// 1 1 1 1 1//////// I 1 I 1 I I I/////// I i // r/ / r /, /. %, / r 4 1556'21' 81 239.00' 57.90' 58.04' -Y.'''. / / -I--71 42.00' ____� _- iii• - 8454 --N. 5209.00 ------ �� 30.91' 5 1749'09' LT 235.07 53.11' /- 1 -I\ � // /� /\ I. / / i 0111" 4} \y 011 20139.00,...-- /...- `` T. ,-_�I-/ / ' \ \ \ 4 1 :4595 I ; I 1 I I� I I I 1 I J 1 ' I 1 l / i / Y /// I I / / / / //x /// / // /./ / / I l 1 / / / / / / � 1 1 1 � � I. 1/ 1 I II 11I 1 111I111/I111111////Il///////// /I //iii/ A//• / / / / //IIII // // /•,,./,/./,/,/,/,/,/,//// / IIII / // / / / / // / // /// / /// /// /// / ////////////////// // / / /I./ / / / / j / / / i / / /// i,/iii /IIII/ / / / III l / / // /// / / i / / 1 N. 52+00 / /// UIQ / /IaI N. 51]9.3] N 5159.3] ` I _ END ACCESS ROAD 1 IN51ROAD A .3 / / I / /-177. 2114.30 E 2125.26 \ _____ L \1 • " \ 4 \/ \ 2077.00 / / I N. 5159.W \ 8458 \ //].84 ` M�ix BLDG \ FF=8460'-0' \ \ :59.5 \ \ /I / ) / I I/ / /j1111//,f//////////j////\ I111j1 /// / /111111'4d//////////1/// / IIII41 1 0Jll/11. q11////// IMI; IIIII////%//////\ /// //\\4I` /59.5 /\ ///////1/// / // /., \ \1 1111 EI I II 1 1 ���/ 1 I/IlI 111/11, I I LA/ / 1 /4/I 1 I 1 1 1 to I V 4l l/ 1 111 /1/// /11�� III // 1 1 1/ / / 11 l 1 / l I \/ ` N. 51+00 / i= PC CURVE 15 mow 1 1 i / I I I I I I I l I l O I I I I ti I I I I 4 \ \ \ \ 50 2 \ \\� 6 / l I M.6Ea5 I I I I i 1 / 1 11,11 l I 1 \\ \ \ l - / �� PT CURVE 161 \ E 60.8 .6 `\ ` �3 \ \ n 1 q / P., / 1 I / o `0 / / 1 l 1 ROAD 2 III I I I 1 I I I ROA x5952.00 1 I I I I 1 I I I I 1 I 1 1 1 Io \ \ I 1 1\I',\ \ \ \ III \ \ \`9,,s, 1 /WI/ PO \ -,- /// 'In 2077.00 \/ 2077.00 �IJ �-` \ 1 0. \ \ O, m I.•�I /¢ / / E 235..0 I I I 1 ill I 1 I 1 I I ; / ;11 111;11jX11Ill ! I / I \ \ \ \ \ \\ \ \ \ O4 `\1 \ / /1 1 1111=III11111 I IIII 11 I I 1 1 V\\VA AN i \ \ \ 4 \ \ / ICONE V/W//j 4 ��.2 2077.00 0'1 CLRVE i oAI •3ZB9 1 '/ / l Olr/ / 1 I I // 111I4 i�I,1/1 iiiI \\ \4 \4 \ \ \\\\\\\ / / // // /I// / / l /1 }y /II / % 1 1 ,I / l I I / / / /11 III 1I1II\ Ij 11\\\\\\ I/1\ I 1 1 I I\ \ \`\\\\\\M \ \ \\ \\ \\ \//E \\ \ \ \ \/ \\ \\ \` `\ \\ \\ \\ \\ \ \ \\. /�/ WR/8 504m \/l/ 81 8», I 1 / cults 57 /5 ♦ 22}4.01 / / / // / / / N. SO+00 _ / / / ,v// lei` E 45___,,- / / ; ; / l // 1 1 1 I / 1 If �� x i -S. / / I// / II /// II i / / 1 1\\ /1 / / \1.1 IBN60 1 I \ 1 1 1 1 FENCE 1. 1 \\ \! 1 A \1\ \\ T A /I /���% / / / / � I I \ \ 11\ \ \ \` \\ \\ \ \\ 1`\ \ \ \\ \\ 4 4 4 \\ \1 \\ \I I 1 1 i i Co / O `4 \ \ \\ 4 \\ \ \4 \\ \\\\`\\\\A \\\\\\\\\\ \ \`\\\\\\\ \\ \/ 1 \ \ 44' \ \I 4 `\ \\ \ \ \\` \ I I 1 1 ` \\ \1 a 11 \I 1\I \I 11 \\` pA -' _ \/ \/ \ \ \\ / \ ilie �i•"�� ay>4 / / / / / /; /1//1 / 1, _i��QS IMI 4 5H7.]0 N. 49+00 / / miW o R o W tea\/:NCO $ N W 1 $ BEGIN ACCESS ROAD 2 44 N 4903.43 W I 11 I\ \ W W E 232..10 PWA! CULVERT W/FVREO EN12'O StCllONS (62 15 WCLUCNC END SECTIONS) CURVE DATA CURVE / A R T L 1 38'32'17' RF 42.00' 27.72' 2825' 2 90'00'07 RT 42.00' 59.40' 65.97' 3 22'30'00' LT 88.07 34.34' 34.56' 4 1556'21' 81 239.00' 57.90' 58.04' 5 4712'52' M 42.00' 3035' 30.91' 5 1749'09' LT 235.07 53.11' 53.25' LEGEND - - - - EXISTING CONTOURS NEW CONTOURS --•.- SWALE aOWGNE GRAPRTC SCALao E 6'1' IDI 1) 1Low, -90 n NOTES: 1. FINISH GRADE ELEVATIONS AND CONTOURS ARE TOP OF FINAL SURFACING. 2. FMMI5/4 GRADE SHALL SLOPE AWAY FROM BUILDINGS AT 5S FOR A MINIMUM OF 10'-0'. 3. ALL CUT OR FILL SHALL NOT CCM 3H : IV UNLESS SHOWN OTHERWISE 4. PROVIDE SILT FENCE AND STRAW BAIT BARRIERS AS NECESSARY TO CONTROL EROSION DURIN0 CONSTRUCTION. 5. PROWDE RIP -ROP, A5 NECESSARY. AT CULVERT END 5ECRONS. LL' 6. ADITCHES WAIN 9011011 SLOPE GREATER TM 3.0/4 SHALL BE STABILIZED WTIH TYRNNOODLEANOODLE E CHANNEL LINING ERLIL. AS MANUFACTURED BY STnIntIA 9WUSTRIIS OR (/0/1158 APPROVED EGLI& 7. /LL FEL SIDE SLOPES GREATER 1NAN 3,1 ,E(CEPT ARDS COVER WM1 FUMBLE CHN4REL LINING MATERIAL. SWLL BE STABILIZED WV IANCDR C52, A5 MANUFACTURED 92' SYNTHETIC INDUSTRIES, OR ENGINEER APPROVED E0U/L CRAVING 00. CT -CI -6301 CI -CI -6401 TITLE UCN. CML-SIRRN. GENERAL NOTES CML-SITE PWM REMSN)NS REVISON5 DATE Rf APP'D DESCRIPTION DATE 91 ES DCRIPTION W� WILUAMS PRODUCTION RMT COMPANY REV 4115197 BB BY 55VED FOR CLIENT APPROVAL PRELIMINARY ISSUE SCALE DRAWN 011C0 1•.30•-0' 110 DAY YR 01/29 0] 2�7 APPS:, 9,% tbstog Harris Group Inc. ENERGY ?21'0 APPROVED CIVIL GRADING AND EDTA�NAGE PLAN SH DATE 4/797 WILLIAMS PRODUCTION KIT CO. CRAWFORD WAD PROJECT 61060 DRAAWING NUMBER CT -CI -6402 REV 8 1 7 1 6 5 4 3 2 8 + 8 + n w 24' CULVER/ W/RMED + DIO SECTIONS (46 LP iy INCWgNG END SECTIONS) 0 INV FL 8421.50 W 8 t AWCHLINE O N. SBf 15 FOR CONTINUATION SEE DWG. 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CT -CI -6402 TILE REMSIONS REVISIONS CML -GRADING AND DRAINAGE PLAN - 51! 1 DATE rff DESCPoPION REV DATE RV IPP'D DESCRIPTION wens WILLIAMS PRODUCTION RMT COMPANY A RAW BB REV DATE 8Y APD ISSUED FOR CLIENT APPROVAL PRELIMINARY ISSUE SCALE DRAWN CHt'D APP'D 1 Tn30•_0 -G! Harris Group Inc. ENERGY CIVIL GRADING AND DRAINAGE PLAN SHEET 2 YAWAMS PRODUCTION RMT CO. 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E 2392.95 IF It 84301------------------------------ li __ Irakkyrj \\ `. \ ` - -------------------------------------------- --- — �_ 8 ,.'� '\ MkTCIAINE 0 N. 58+15 FOR CONRNUAIION SEE DWO. CT -C1-6403 PLAN • N. 5834.20 E. 2398.75 DRAWING NO. CT -CI -6402 TIRE REVISIONS REVISIONS OWL -GRADING AND DRNNPGE PIAN - SNE 1 DATE By PP'D DESCRIPTION DATE RY IPP'D DESCRIPTION Willens WILL AMS PRODUCTION RMT COMPANY A 02/1581 B8 ISSUED FOR CLIENT APPROVAL REV DATE BY APP.0 PRELIMINARY ISSUE SONE DRAWN CMCD DD/98 APP'D APP'D MO DAY yRgui 01/29/D7 61 g1"/a4 PPROJED GRAPHIC SCALE (m rest ) _ - NOTES: 1. FoR GENERFL NOTES. LEGEND AND CURVE DATA SEE CRANING CT -O-6402 Harris Group Inc. ENERGY CIVIL GRADING AND DRAINAGE PLAN SHEET 3 DUE //3-40J WLLWAS PRODUCTION RMT CO. CRAWFORD TRAM_ PROJECT 01060 DRAWING NUMBLR CT -CI -6404 REV 8 D c B A 1 7 6 5 4 3 2 w000 OR METAL STAKE 0 5'-0' INIERVNS FABRIC (LAP JOINTS 5.-0') SLOPE o —FA Elf 1 =7131!;; ' To SILT FENCE DETAIL ( STRAW BALES (EMBED BALES V TO 6') STRAW BALE BARRIER DETAIL EROSION CONTROL DETAILS CONTAINMENT UNFR 4DURA LIFE' SECONDARY CONTAINMENT STRUM/RE B' TO 8' STRUCTURAL FILL STRUCTURAL ALL 1 TYPICAL TANK CONTAINMENT SECTION TYP SIDEWALK CROSS SECTION EL TRANS CONTROL JOINTS SHALL BE ATNOT AT NOT MORE THAN 4' INTERVALS. TRANSVERSE EXPANSION JOINTS SHALL BE PLACED AT NOT MORE THAN 50' INTERNALS. PROVIDE EXPANSION JON'S BETWEEN SIDEWALKS AND DOOR STOOPS, UDDER PADS, ETC. BACKFILL WITH LOW PERMEABLE MATERIAL COMPACT TO 955 MOD. PROCTOR DENSITY TYPICAL PIPE TRENCH DFTAII OF TANK LENGTH IE -7851 *VERIFY DIMS WITH TANK VENDOR 24'-0' 8' COMPACT ROAD BASE 2% SLOPE (MIN) AS REOD-SEE PLANS 25 SLOPE (MIN) AS REOO-SEE PLANS Y'0 EYE DOLTS SEE DET 1 (4 PLCS) '6 GALV DROP FORGED EYE BOLT & NUT -WORKING LOAD 52000 MIN VERIFY LOCATION WITH VENDOR DRAWINGS PRIOR TO PLACING CONCRETE i1i# a,sj�rGOGOU����O✓�9�5����j� j ly ��p� j"�<4,�`i``p1`L`�G`�p`�p0i�OiOpJi1��p 12' SCARIFIED & COMPACTED SUBGRADE .... .............. TYPICAL ROAD SECTION DRAWING NO. CT -CI -8402 CT -CI -6403 CT -CA -8404 RILE CML -GRADING AID DRAINAGE PMN -SM CML -GRADING AND DRAMA E PLAN -SID 2 CML -GRADING AND DRAINAGE PUN -SMT 3 RLYIMONS REVISIONS DATE BY APP'D DESCRIPTION REV DATE BY APP'D DEDCRIPRON Willa WTLLAMS PRODUCTION RMT COMPANY GEOTEJRILE FABRIC TX -7860 N 5636'-0' E 2334'-9' TANK OUTLINE PLAN — UNDERGROUND FRP DRAIN TANK FOUNDATION TK -7851 & 7860 SCALE NTS AS SHOWN & NOTED DE DOWN STRAPS (SUPPUED BY TANK VENDOR -TP 2 PLCS) FINISH GRADE GENERAL BACKFILL BEDDING MATERIAL SEE NOTE 2 FIELD TO TOC EL EYE BOLTS SEE DETAIL 1 UNDISTURBED OR COMPACTED SUBGRADE SECTION SCALE:1/2'.P-o' NOTES' 1. FOR CONCRETE GENERAL NOTES AND STANDARD DETAILS SEE DRAWINGS CT -CI -8301 NLD CT -CI -8303. 2. BEDDING MUST BE HOMOGENEOUS MATERIAL CONSISTING OF COMPACTED CLEAN SAND. 3. FIELD PROVIDE GUARD POSTS 0 MANWAYS, AS NEEDED. SEE TYPICAL DETNL ON DWGCT-CI-8303. 6M/87 RAW ADDED TANK FOUNDATIONS A IQNi'91 DJI JS ISSUED FOR WEAR APPROVAL 0 M/A/W BB ISSUED FOR CONSTRUCTION DATE BY APP'D PRELIMINARY ISSUE SPAJF DRAWN CKKb APPII 1".30. -0 - CUI MO DAY YR 02/14/07 02/15/07 GB JS 02/15/07 AFP'D k DA 4,/7AD7 PROJECT 61060 Harris Group Inc. ENERGY CIVIL GRADING AND DRAINAGE MISCELLANEOUS DETAILS ERAWINC NUMB WILLIAMS PRODUCTION RMT CO. CRAWFORD TRAIL CT—CI-6405 REV Geotechnical , Engineering Group, Inc. GEOTECHNICAL INVESTIGATION Crawford Trail Compressor Station Garfield County, Colorado Prepared For: Williams Production RMT Company P.O. Box 370 Parachute, CO 81635 Attention: Tom Fiore Job No. 2,526 December 22, 2006 Geotechnical, Environmental and Materials Testing Consultants Grand Junction - Montrose - Moab - Crested Butte (970) 245-4078 • fax (970) 245-7115 • geotechnicalgroup.com 2308 Interstate Avenue, Grand Junction, Colorado 81505 TABLE OF CONTENTS SCOPE 1 SUMMARY OF CONCLUSIONS 1 SITE CONDITIONS 2 PROPOSED CONSTRUCTION 2 SUBSURFACE CONDITIONS 3 SITE DEVELOPMENT 4 SEISMIC CONSIDERATIONS 5 FOUNDATIONS 6 DRILLED PIER FOUNDATIONS 7 SPREAD FOOTINGS- STRUCTURES SENSITIVE To MOVEMENT 8 SPREAD FOOTINGS- STRUCTURES WHERE MORE RISK OF MOVEMENT IS ACCEPTABLE 10 REINFORCED MAT FOUNDATIONS -WHERE MORE RISK OF MOVEMENT IS ACCEPTABLE 11 FLOOR SYSTEMS 12 BELOW -GRADE CONSTRUCTION 14 CONCRETE 14 SURFACE DRAINAGE 15 CONSTRUCTION MONITORING 16 LIMITATIONS 16 FIG. 1 - VICINITY MAP FIG. 2 - LOCATION OF EXPLORATORY BORINGS FIG. 3 - LEGEND AND NOTES OF EXPLORATORY BORINGS FIGS. 4 THROUGH 10 - LOGS OF EXPLORATORY BORINGS FIGS. 11 THROUGH 15 - SWELL CONSOLIDATION TEST RESULTS FIG. 16 - DIRECT SHEAR TEST RESULTS TABLE I - SUMMARY OF LABORATORY TEST RESULTS APPENDIX A - SAMPLE SITE GRADING SPECIFICATIONS SCOPE This report presents the results of our Geotechnical Investigation for the proposed Crawford Trail, compressor station in Garfield County, Colorado. Our investigation was conducted to explore subsurface conditions and provide foundation design recommendations for the anticipated construction. The report includes descriptions of subsoil and groundwater conditions found in seven exploratory borings made during this investigation, recommended foundation systems, allowable design soil pressures and design and construction criteria for details influenced by the subsurface conditions. The report was prepared from data developed during field exploration, laboratory testing, engineering analysis and experience with similar conditions. A brief summary of our conclusions and recommendations follows. Detailed criteria are presented within the report. SUMMARY OF CONCLUSIONS 1. Subsoils found in the exploratory borings consisted of generally of 2 to 4 feet of sandy, clay underlain by a formational claystone and sandstone material to the maximum depth explored of 8 to 25 feet. 2. Stiff to very stiff, sandy clay and medium hard to hard claystone materials were identified at foundation levels. We recommend drilled piers bedded in an underlying competent strata to reduce potential movement of structures. A competent stratum was identified at depths of 2 to 4 feet. A recommendation for shallow foundations supported by well -compacted engineered structural fill is also presented for structures where more risk of Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 7 potential movement is acceptable. A discussion of alternatives, including detailed design and construction criteria are included in the text of the report. 3. We believe slab -on -grade construction supported by the soil encountered will involve significant amount of movement. We recommend structurally supported floors in all finished areas. Detailed design and construction criteria area presented in the text of this report. 4. Surface drainage should be designed for rapid runoff of surface water away from the proposed structures. SITE CONDITIONS The subject site was located in Section 23, Township 6 South, Range 97 West in Garfield County, Colorado. A project vicinity map is shown on Fig.1. The subject site had varying slope topography to the north, south, east and west at inclinations of about 5 to 20 percent. The subject site had was covered in sage brush, oak brush and aspen type trees. A pipe line corridor was southwest of the site with vacant BLM land beyond. Vacant BLM land was north, east, south and west of the site. PROPOSED CONSTRUCTION We understand proposed construction will consist of a petroleum compressor station. The propose construction will include various compressor pads, compressor Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 2 building, pipe racks, related structures including skid mounted structures. No below grade construction is planned. If proposed construction changes or is different from what is stated, we should be contacted to review actual construction and our recommendations. SUBSURFACE CONDITIONS Subsurface conditions at the site were investigated by drilling and sampling seven exploratory borings. Locations of the exploratory borings are shown on Fig. 2. Graphic logs of the soils found in the borings and field penetration resistance tests are presented on Figs. 4 through 10. Subsurface conditions encountered in the test borings included sandy clay from the ground surface to a depth of about 2 to 4 feet underlain by formational claystone and sandstone to the maximum depth explored of 25 feet. The sandy clay was stiff to very stiff, moist, and brown to tan. The claystone was hard to very hard, moist and brown to grey. The sandstone was very hard, slightly moist to moist, and brown to tan. Refusal to auger drilling was encountered at a depth of about 8 feet in exploratory test boring TH-3 in the formational claystone. Four sandy clay samples tested had moisture content ranging from 11.9 to 24.9 percent and one of the samples had a dry density of 85 pcf. Four sandy clay samples tested had liquid limits of 33 to 42, and plasticity indexes of 2 to 17 and had 9 to 60 Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 3 percent passing the No. 200 sieve (silt and clay sized particles). Five claystone samples tested had moisture content ranging from 13.9 to 16.7 percent and dry densities ranging from 90 to 108 pcf. Five claystone samples were tested for swell consolidation characteristics using a one-dimensional oedometer apparatus. The samples exhibited 0.1 percent consolidation to 2.1 percent swell when wetted under a confining pressure of 250 to 500 psf with estimated swell pressures of greater than 4000 psf. One sandy, silty clay sample tested exhibited a cohesion of 200 psf and an internal angle of friction of 20 degrees. Three sandy clay samples tested had water soluble sulfate. Concentrations of 5 to 40 ppm. Results of laboratory testing are presented on Fig. 11 through 16 and summarized on Tables I. SITE DEVELOPMENT The surface in areas to support structures on well compacted fill, should be scarified to a depth of 10 inches, moisture conditioned to 2 to 4 percent wet of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM D 698) maximum dry density. On-site soils free of deleterious materials, organics and particles over 6 -inches diameter can be reused in non-structural areas during grading. The on site soils should not be used for well compacted fill in areas to support structures. Fill in structural areas may include special requirements as discussed later under the Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 4 "FOUNDATIONS" section of this report. Additional fill placement should be moisture conditioned to 2 to 4 percent wet of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM D698) maximum dry density in 10 -inch maximum thickness loose lifts. Subgrade soils and fill greater than 10 foot in depth should be moisture conditioned to 2 to 4 percent of optimum moisture and compacted to at least 100 percent maximum dry density standard Proctor (ASTM D698). Subgrade preparation, and placement and compaction of grading fill should be observed and tested by a representative of our firm during construction. Sample site grading specifications are included in Appendix A. SEISMIC CONSIDERATIONS Foundation and floor systems include structural support from the surficial sandy, silty clay soils. Based on 2000 UBC we believe the site is located in Seismic Zone 1. Based on our understanding of proposed construction and subsurface conditions, we suggest a "Site Class C" be used for foundation seismic design as described in 2000 IBC. Based on the field and laboratory results we suggest a shear modulus of 4 ksi. FOUNDATIONS Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 5 This investigation indicates subsurface conditions at foundation levels generally consist of sandy clay and claystone formational material with significant swell potential. Our experience indicates the formational claystone is problematic in the area and indicates the swell potential may vary across the site with swell potential higher than tested. In our opinion, a foundation to better help mitigate risk of potential movement should be anchored below the zone of probable moisture variation and concentrate the weight of the structure to resist potential swell of the sandy, silty clay. In our opinion, a straight shaft drilled pier foundation bedded in an underlying competent stratum most nearly satisfies these criteria. If the owner and builder accept the risk of significant foundation movement and associate damage the structures may be supported on spread footings or reinforced mat foundations. We present design and construction criteria for drilled pier foundations. We also provide spread footing and reinforced mat foundations for structures where significant movement is acceptable. These criteria were developed from analysis of field and laboratory data and our experience. The additional requirements (if any) of the structural engineer should also be considered. Drilled Pier Foundations Crawford Trail Compressor Station Garfield County, Colorado GEG Job leo. 2,526 6 1. Piers should be designed for a maximum allowable end bearing pressure of 25,000 psf. The piers should be designed for end bearing only. Skin friction discussed below should be used only to resist uplift. 2. Piers should be designed for a minimum dead load pressure of 10,000 psf based on pier cross-sectional area. If this dead load cannot be achieved, pier length and bedrock penetration should be increased. The shale can be assigned a skin friction value of 1,750 psf for uplift resistance, at least 3 feet below the pier cap. 3. Piers should penetrate at least 10 feet into the formational claystone/sandstone strata and have a total length of at least 18 feet. Relatively hard drilling conditions are anticipated. Specialty drilling equipment may be necessary to advance pier holes in the formational material. We recommend a pier hole diameter of at least 12 inches. 4. Pier reinforcement should be designed by the structural engineer to resist tension in the event of swelling. Reinforcement should extend the full length of the piers and into grade beams and foundation walls. The structural engineer's design may require additional or alternative reinforcing and should be included in the foundation construction. 5. A minimum 6 -inch (or thicker) continuous void should be constructed beneath all grade beams and foundation walls, between piers, to concentrate dead load on the piers and to provide separation between the grade beams and/or foundation walls and the expansive site soils. 6. Foundation walls and grade beams should be well reinforced; the reinforcement should be designed by a qualified structural engineer. 7. Piers should be carefully cleaned prior to placement of concrete. Groundwater was not encountered at the time of this investigation to the depths investigated. Our experience indicates permeable or fractured layers that may carry or store water may exist in the formational material. We believe problems associated with pier installation can be significantly reduced by using a "drill and pour" construction procedure; that is, placing concrete immediately after pier holes are drilled, cleaned and inspected. Pumping or tremie placement may be required for proper dewatering of the pier holes if water is encountered during drilling. Concrete should not be placed in any pier hole containing more than 3 inches water. Due to recent Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 7 experience with improper installation, we recommend the use of a contractor with previous drilled pier installation experience. 8. Formation of mushrooms or enlargements at the top of piers should be avoided during pier drilling and subsequent construction operations. It may be necessary to case the top portion of the pier holes with a sono tube type casing to a depth of flaring of the pier holes to prevent mushrooms or enlargements at the top of piers. 9. Installation of drilled piers should be observed by a representative of our firm to identify the proper bearing strata and confirm proper installation technique. Our representative should be called to visit the site at the time of the first pier excavation. Spread Footings- Structures Sensitive To Movement 1. Bottom of footing should have a separation of at least 6 feet from the sandy clay and/or formational claystone. The claystone samples tested had estimated swell pressures greater than 4,000 psf. If the claystone becomes wetted it may swell with these pressures. It is very difficult to provide adequate separation from material with swell pressures in this range to completely eliminate the influences of the swell pressures. The recommended 6 feet separation between the bottom of the footings and the top of the clay and/or claystone is intended to help reduce or mask the influence of soil volume changes. 2. Existing soils should be removed to at least a depth of 6 feet below and 6. feet horizontally beyond footings in each direction and replaced with a well - compacted engineered structural fill. The resulting subgrade should be prepared by scarifying 10 -inches, moisture conditioning to 2 to 4 percent wet of optimum moisture content and compacting to at least 95 percent of standard Proctor (ASTM D698) maximum dry density. Structural fill soils should consist of non -expansive well graded sands and gravels with a maximum particle size of 1' -inches, maximum 15 percent passing the No. 200 sieve and maximum liquid limit of 30. A CDOT type Class 5 aggregate Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 8 base course would meet this criteria and is recommended. The on site soils are not suitable for use as well compacted structural fill. A sample of the proposed fill soils should be supplied to our office for acceptance testing, prior to use or import. Structural fill should be moisture conditioned to within 2 percent of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM D698) maximum dry density in 10 -inch maximum loose lifts. 3. Footings bearing on well -compacted structural fill placed as stated above should be designed for a maximum soils bearing pressure of 2,500 psf. Footing should be designed with a minimum dead load as high as possible. Loose soils should be completely removed from foundation bearing areas, prior to placing concrete. 4. We recommend a minimum width of at least 18 -inches for continuous footings. Isolated pads should be at least 36 inches by 36 inches. Foundation walls should be well -reinforced top and bottom. We recommend reinforcement sufficient to span an unsupported distance of at least 15 feet. Reinforcement should be designed by the structural engineer. 5. Based on a design soil bearing pressure of 2,500 psf, a footing width of about 18 inches and footings placed on a 6 feet thick layer of well compacted structural fill the estimated differential movement is about % to 1 inch. If wider footings are used we should be contacted to review the estimated settlement and provide additional recommendations where needed. 6. Exterior walls should be protected from freezing. Refer to local building code for details. 7. The completed foundation excavation should be observed by our representative for proof roll and to verify the foundation subgrade conditions are as anticipated from our exploratory borings. Geotechnical Engineering Group, Inc. should also be called to test compaction of subgrade and fill during placement. Spread Footings- Structures Where More Risk of Movement is Acceptable Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 9 1. The Bottom of footing should have a separation of at least 2 feet from the surface of the sandy, clay and/or formational claystone. The recommended 6 feet separation between the bottom of the footings and the top of the clay and/or claystone is intended to help mask soil volume changes. 2. Existing soils should be removed to at least a depth of 2 feet below and 2. feet horizontally beyond footings in each direction and replaced with a well - compacted structural fill. The resulting subgrade should be prepared by scarifying 10 -inches, moisture conditioning to 2 to 4 percent wet of optimum moisture content and compacting to at least 95 percent of standard Proctor (ASTM D698) maximum dry density. Structural fill soils should consist of well graded sands and gravels with a maximum particle size of 11/2 -inches, maximum 15 percent passing the No. 200 sieve and maximum liquid limit of 30. A CDOT type Class 5 aggregate base course would meet this criteria and is recommended. The on site soils are not suitable for use as well compacted structural fill. A sample of the proposed fill soils should be supplied to our office for acceptance testing, prior to use or import. Additional fill should be moisture conditioned to within 2 percent of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM D698) maximum dry density in 10 -inch maximum loose lifts. 3. Footings bearing on well -compacted structural fill placed as stated above should be designed for a maximum soils bearing pressure of 1,200 psf. Footing should be designed with a minimum dead load as high as possible. Loose soils should be completely removed from foundation bearing areas, prior to placing concrete. 4. We recommend a minimum width of at least 18 -inches for continuous footings. Isolated pads should be at least 36 inches by 36 inches. Foundation walls should be well -reinforced top and bottom. We recommend reinforcement sufficient to span an unsupported distance of at least 15 feet. Reinforcement should be designed by the structural engineer. 5. Based on a design soil bearing pressure of 1,200 psf, a footing width of about 18 inches and footings placed on a two feet thick layer of well compacted structural fill the estimated differential movement is about 2 to Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 10 4 inches. If wider footings are used we should be contacted to review the estimated settlement and provide additional recommendations where needed. 6. Exterior walls should be protected from freezing. Refer to local building code for details. 7. The completed foundation excavation should be observed by our representative for proof roll and to verify the subsurface foundation conditions are as anticipated from our exploratory borings. Geotechnical Engineering Group should also be called to test compaction of subgrade and fill during placement. Reinforced Mat Foundations —Where More Risk of Movement is Acceptable 1. Reinforced mat foundations can be designed for a maximum soil bearing pressure of 1,200 psf. When supported on a minimum 2 feet thick well compacted structural fill. Loose soils should be completely removed from foundation bearing areas, prior to placing structural fill or foundation concrete. 2. Existing soils should be removed to at least a depth of 2 feet below and 2 feet horizontally beyond the mat in each direction and replaced with a well - compacted structural fill. The resulting subgrade should be prepared by scarifying 10 -inches, moisture conditioning to 2 to 4 percent wet of optimum moisture and compacting to at least 95 percent of standard Proctor (ASTM D698) maximum dry density. Structural fill soils should consist of well graded sands and gravels with a maximum particle size of 11/2 -inches, maximum 15 percent passing the No. 200 sieve and maximum liquid limit of 30. A CDOT type Class 5 aggregate base course would meet this criteria and is recommended for structures where mitigating potential movement is a concern. The on site soils are not suitable for use as well compaced structural fill. A sample of the proposed fill soils should be supplied to our office for acceptance testing, prior to use or import. Structural fill should be moisture conditioned to within 2 percent of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM D698) maximum dry density in 10 -inch maximum loose lifts. Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 11 3. Mat foundations should be well reinforced, both top and bottom. We recommend reinforcement sufficient to span an unsupported distance of at least 12 feet and to distribute load over the entire mat foundation. Reinforcement should be designed by the structural engineer. 4. Foundations should be protected from freezing. Refer to local building code for details. 5. The completed foundation excavation should be observed by our representative to verify subsurface foundation conditions are as anticipated from our borings and to test compaction. FLOOR SYSTEMS The near -surface soils which will support slab -on -grade floors exhibited significant movement potential. Some movement must be assumed. To our knowledge, the only reliable solution to control floor movement is the construction of floors supported by the foundation system over a minimum 12 inch void. If the owner and builder accept the risk of significant movement and associated damage, the floors may be constructed as slab on grade floors. The owner is cautioned that future maintenance of any slabs on grade may include the removal and replacement of the slabs. We recommend the following precautions for construction of slabs -on -grade at this site. These precautions will not prevent movement in the event the underlying conditions become wetted; they tend to reduce damage if movement occurs. Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 12 1. Slabs should be supported by at least a 2 foot depth of well compacted, structural fill as stated above under the "FOUNDATIONS, Spread Footings" section of this report. The completed subgrade should be scarified 10 -inches depth, moisture conditioned to 2 to 4 percent wet of optimum moisture content and compacted to at least 95 percent of maximum standard Proctor (ASTM D698) dry density, prior to structural fill placement. A Geotechnical Engineering Group, Inc. representative should be called to visit the site to test compaction and observe soils in the excavation bottom and structural fill. 2. Slab -on -grade construction should be limited to unfinished areas and exterior flatwork where practical. 3. Slabs should be separated from exterior walls and interior bearing members with a slip joint which allows for free vertical movement of slabs. 4. The use of slab -bearing partitions should be minimized. Where such partitions are necessary, a slip joint allowing at least 6 inches of free vertical slab movement should be used. Doorways and stairwells should also be designed for this movement. 5. Underslab plumbing should be eliminated where feasible. Where such plumbing is unavoidable, it should be thoroughly pressure tested during construction for leaks and should be provided with flexible couplings. Plumbing extending through slab on grade floors should be separated from floor slab to allow independent movement. 6. Frequent control joints should be provided to reduce problems associated with shrinkage and curling. The American Concrete Institute (ACI) and Portland Cement Association (PCA) recommend a maximum panel size of 8 to 15 feet depending upon concrete thickness and slump, and the maximum aggregate size. We advocate additional control joints 3 feet off and parallel to grade beams and foundation walls. BELOW -GRADE CONSTRUCTION No below -grade construction is anticipated at this site. Typically, building foundation drains are not required for construction of this type. Crawl space, if any, in Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 13 building areas should be sloped so that potential moisture will not collect in these areas, but flow out of the crawl space. Crawl space areas should also be well ventilated to reduce potential humidity and musty odors. CONCRETE Three soil samples (TH- 1, TH-4 and TH-7 at 1-4 feet) were tested for water soluble sulfate concentrations. The test results indicate a water soluble sulfate concentration of 5 to 40 ppm. Concentrations in this area have been shown to have a negligible to moderate effect on concrete that comes into contact with the soils. American Concrete Institute (ACI) recommends a Type II (sulfate resistant) cement be used for concrete that comes into contact with subsoils with moderate sulfate effect. In addition, concrete should have a maximum water -cement ratio of 0.50. SURFACE DRAINAGE Performance of foundations and concrete flatwork is influenced by surface moisture conditions. The site formational claystone has significant swell potential. The swell potential typically is mobilized by wetting. Reducing the potential for moisture Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 14 migration into the site soil and formational claystone with reduce the risk of mobilization of swell potential of site materials. Risk of wetting foundation soils can be reduced by carefully planned and maintained surface drainage. Surface drainage should be designed to provide rapid runoff of surface water away from the proposed structures. We recommend the following precautions be observed during construction and maintained at all time after the construction is completed. 1. The ground surface surrounding the exterior of the structures should be sloped to drain away from the additions in all directions. We recommend a slope of at least 12 inches in the first 10 feet around the structures, where possible. In no case should the slope be less than 6 inches in the first 5 feet. The ground surface should be sloped so that water will not pond adjacent to the additions. 2. Backfill around foundation walls should be moistened and compacted. 3. Roof downspouts and drains should discharge well beyond the limits of all backfill. Splash blocks and downspout extenders should be provided at all discharge points. 4. Landscaping, if any, should be carefully designed to minimize irrigation. Plants used close to foundations should be limited to those with low moisture requirements; irrigated grass should not be located within 5 feet of the foundation. Sprinklers should not discharge within 5 feet of foundations. Irrigation should be limited to the minimum amount sufficient to maintain vegetation; application of more water will increase likelihood of slab and foundation movements. 5. Impervious plastic membranes should not be used to cover the ground surface immediately surrounding the structures. These membranes tend to trap moisture and prevent normal evaporation from occurring. Geotextile fabrics can be used to limit the weed growth and allow for evaporation. Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 15 CONSTRUCTION MONITORING Geotechnical Engineering Group, Inc. should be retained to provide general review of construction plans for compliance with our recommendations. Geotechnical Engineering Group, Inc. should be retained to provide construction -monitoring services during all earthwork and foundation construction phases of the work. This is to observe the construction with respect to the geotechnical recommendations, to enable design changes in the event that subsurface conditions differ from those anticipated prior to start of construction and to give the owner a greater degree of confidence that the additions are constructed in accordance with the geotechnical recommendations. LIMITATIONS The scope of services for this study does not include any environmental or biological (such as radon, mold, fungi, bacteria, etc.) assessment of the site or identification or prevention of pollutants or hazardous materials conditions. If the owner is concerned about the potential for such contamination or pollution, other studies should be performed. Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 16 Seven exploratory borings were drilled in the proposed structure areas. The exploratory borings are representative of conditions encountered only at the exact boring locations. Variations in the subsoil conditions not indicated by the borings are always possible. Our representative should observe open foundation excavations, observe proof roll and test compaction of subgrade and structural fill soils (as applicable) to confirm soils are as anticipated from the borings and foundations are prepared as recommended herein. The scope of work performed is specific to the proposed construction and the client identified by this report. Any other use of the data, recommendations and design parameters (as applicable) provided within this report are not appropriate applications. Other proposed construction and/or reliance by other clients will require project specific review by this firm. Changes in site conditions can occur with time. Changes in standard of practice also occur with time. This report should not be relied upon after a period of three years from the date of this report and is subject to review by this firm in light of new information which may periodically become known. We believe this investigation was conducted in a manner consistent with that level of care and skill ordinarily used by geotechnical engineers practicing in this area at this time. No other warranty, express or implied, is made. If we can be of further service in Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,626 17 discussing the contents of this report or the analysis of the influence of the subsurface conditions on the development or design of the proposed construction, please call. Sincerely, GEOTECHNICAL ENGINEERING GROUP, INC. Reviewed by: Robert W. Anderson Norman W. Johnston, P.E. Project Geologist Senior Engineer RWA:NWJ:mh (3 copies sent) Crawford Trail Compressor Station Garfield County, Colorado GEG Job No. 2,526 18 APPENDIX A SAMPLE SITE GRADING SPECIFICATIONS SAMPLE SITE GRADING SPECIFICATIONS Crawford Trail Compressor Station Garfield County, Colorado Note: Appendix A presents sample specifications. These sample specifications are not project specific. The sample specifications should be modified by the Architect, Civil engineer or Structural engineer as needed to reflect project specific requirements.) 1. DESCRIPTION This item shall consist of the excavation, transportation, placement and compaction of materials from locations indicated on the plans, or staked by the Engineer, as necessary to achieve preliminary street and overlot elevations. These specifications shall also apply to compaction of excess cut materials that may be placed outside of the subdivision and/or filing boundaries. 2. GENERAL The Soils Engineer shall be the Owner's representative. The Soils Engineer shall approve fill materials, method of placement, moisture contents and percent compaction, and shall give written approval of the completed fill. 3. CLEARING JOB SITE The Contractor shall remove all trees, brush, and rubbish before excavation or fill placement is begun. The Contractor shall dispose of the cleared material to provide the Owner with a clean, neat appearing job site. Cleared material shall not be placed in areas to receive fill or where the material will support structures of any kind. 4. SCARIFYING AREA TO BE FILLED All topsoil and vegetable matter shall be removed from the ground surface upon which fill is to be placed. The surface shall then be plowed or scarified until the surface is free from ruts, hummocks or other uneven features, which would prevent uniform compaction by the equipment to be used. 5. COMPACTING AREA TO BE FILLED Job No. 2,526 Fig. A-1 After the foundation for the fill has been cleared and scarified, it shall be disked or bladed until it is free from large clods, brought to the proper moisture content (within 2 percent above or below optimum) and compacted to not less than 95 percent of maximum density as determined in accordance with ASTM D 698. If soft/ yielding subgrade conditions are encountered, stabilization may be required. 6. FILL MATERIALS Fill soils shall be free from vegetable matter or other deleterious substances, and shall not contain rocks or lumps having a diameter greater than six (6) inches. Fill materials shall be obtained from cut areas shown on the plans or staked in the field by the Engineer. On-site materials classifying as CL, SC, SM, SW, SP, GP, GC and GM are acceptable. Concrete, asphalt, organic matter and other deleterious materials or debris shall not be used as fill. 7. MOISTURE CONTENT Fill materials shall be moisture treated to within 2 ± percent of optimum moisture content as determined from Proctor compaction tests. Sufficient laboratory compaction tests shall be made to determine the optimum moisture content for thee various soils encountered in borrow areas. The Contractor may be required to add moisture to the excavation materials in the borrow area if, in the opinion of the Soils Engineer, it is not possible to obtain uniform moisture content by adding water on the fill surface. The Contractor may be required to rake or disk the fill soils to provide uniform moisture content through the soils. The application of water to embankment materials shall be made with any type of watering equipment approved by the Soils Engineer, which will give the desired results. Water jets from the spreader shall not be directed at the embankment with such force that fill materials are washed out. Should too much water be added to any part of the rill, such that the material is too wet to permit the desired compaction from being obtained, rolling and all work on that section of the fill shall be delayed until the material has been allowed to dry to the required moisture content. The Contractor will be permitted to rework wet material in an approved manner to hasten its drying. 8. COMPACTION OF FILL AREAS Job No. 2,526 Fig. A-2 Selected fill material shall be placed and mixed in evenly spread layers. After each fill layer has been placed, it shall be uniformly compacted to not less than the specified percentage of maximum density. Expansive soils classifying as CL or SC shall be compacted to at least 95 percent of the maximum dry density as determined in accordance with ASTM D 698 (100 percent for fill deeper than 15 feet below final grade). At the option of the Soils Engineer, soils classifying as SW, SP, GP, GC or GM may be compacted to 90 percent of the maximum density as determined in accordance with ASTM D 1557 (95 percent for fill deeper than 15 feet below final grade). Fill materials shall be placed such that the thickness of loose material does not exceed 10 inches and the compacted lift thickness does not exceed 6 inches. Compaction, as specified above, shall be obtained by the use of sheepsfoot rollers, multiple -wheel pneumatic -tired rollers, or other equipment approved by the Engineer for soils classifying as CL or SC. Granular fill shall be compacted using vibratory equipment or other equipment approved by the Soils Engineer. Compaction shall be accomplished while the fill material is at the specified moisture content. Compaction of each layer shall be continuous over the entire area. Compaction equipment shall make sufficient trips to insure that the required density is obtained. 9. COMPACTION OF SLOPES Fill slopes shall be compacted by means of sheepsfoot rollers or other suitable equipment. Compaction operations shall be continued until slopes are stable, but not too dense for planting, and there is no appreciable amount of loose soil on the slopes. Compaction of slopes may be done progressively in increments of three to five feet (3' to 5') in height or after the fill is brought to its total height. Permanent fill slopes shall not exceed 3:1 (horizontal to vertical). 10. DENSITY TESTS Field density tests shall be made by the Soils Engineer at locations and depths of his choosing. Where sheepsfoot rollers are used, the soil may be disturbed to a depth of several inches. Density tests shall be taken in compacted material below the disturbed surface. When density tests indicate that the density or moisture content of any layer of fill or portion thereof is below that required, the particular layer or portion shall be reworked until the required density or moisture content has been achieved. 11. COMPLETED PRELIMINARY GRADES Job No. 2,526 Fig. A-3 All areas, both cut and fill, shall be finished to a level surface and shall meet the following limits of construction: A. Overlot cut or fill areas shall be within plus or minus 2/10 of one foot. B. Street grading shall be within plus or minus 1/10 of one foot. The civil engineer, or duly authorized representative, shall check all cut and fill areas to observe that the work is in accordance with the above limits. 12. SUPERVISION AND CONSTRUCTION STAKING Observation by the Soils Engineer shall be continuous during the placement of fill and compaction operations so that he can declare that the fill was placed in general conformance with specifications. All inspections necessary to test the placement of fill and observe compaction operations will be at the expense of the Owner. All construction staking will be provided by the Civil Engineer or his duly authorized representative. Initial and final grading staking shall be at the expense of the owner. The replacement of grade stakes through construction shall be at the expense of the contractor. 13. SEASONAL LIMITS No fill material shall be placed, spread or rolled while it is frozen, thawing, or during unfavorable weather conditions. When work is interrupted by heavy precipitation, fill operations shall not be resumed until the Soils Engineer indicates that the moisture content and density of previously placed materials are as specified. 14. NOTICE REGARDING START OF GRADING The contractor shall submit notification to the Soils Engineer and Owner advising them of the start of grading operations at least three (3) days in advance of the starting date. Notification shall also be submitted at least 3 days in advance of any resumption dates when grading operations have been stopped for any reason other than adverse weather conditions. 15. REPORTING OF FIELD DENSITY TESTS Job No. 2,526 Fig. A4 Density tests made by the Soils Engineer, as specified under "Density Tests" above, shall be submitted progressively to the Owner. Dry density, moisture content, of each test taken and percentage compaction shall be reported for each test taken. 16. DECLARATION REGARDING COMPLETED FILL The Soils Engineer shall provide a written declaration stating that the site was filled with acceptable materials, or was placed in general accordance with the specifications. 17. DECLARATION REGARDING COMPLETED GRADE ELEVATIONS A registered Civil Engineer or licensed Land Surveyor shall provide a declaration stating that the site grading has been completed and resulting elevations are in general conformance with the accepted detailed development plan. Job No. 2,526 Fig. A5 Williams Production RMT Company Crawford Trail Compressor Station Garfield County, Colorado J J Z Job No. 2,526 C# r1gMtCC)30G1, N„t1M, lns Vicinity Map Fig. 1 Note: This figure was prepared based on a map provided by Williams Production and is intended to show approximate locations of Test Borings only Legend • Indicates approximate locations of test borings Crawford Trail Job No. 2,526 Location of Exploratory Borings Fig. 2 Figure 4 PAGE 1 of 1 Grote rho lea! I lhuMiuecrn.M Group, loc. LOG OF TEST TEST BORING TH-1 PROJECT: Williams Compressor Station -Crawford Trail PROJECT NO.: 2526 CLIENT: Williams LOCATION: ELEVATION: DRILLER: Odell LOGGED BY: GM DEPTH TO WATER> INITIAL: a AFTER 24 HOURS: --Y- DATE: 11/22/2006 DEPTH TO CAVING: L a, w rn o DescriptionP. U L 7 N E T ~ co co V Notes 0 Organics noted to 1 foot depth Clay, gravelly, slight sandy, very stiff, moist, brown to tan, (CL) Bulk sample taken at 1 to 4 foot depth Q Claystone, sandy, hard, medium moist, brown to tan, (CS/SP) j �1CTr Bulk 23/12 4 6 Sandstone, clayey, medium hard to hard, medium moist, brown, to tan, (SS) Altering stiffness of drilling from 9 to 19 foot depth CT 50/10 e CT son 12 Claystone, hard, (CS) 16 CT 5ow zo Bottom of boring when terminated: 20 ft. 24 26 This information pertains only to this boring and should not be interpreted as being indicitive of the site. Figure 4 PAGE 1 of 1 Figure 5 PAGE 1 of 1 Geotechnical I Englnccilug Gronp, 1114'• LOG OF TEST BORING TH-2 PROJECT: Williams Compressor Station -Crawford Trail PROJECT NO.: 2526 CLIENT: Williams LOCATION: ELEVATION: DRILLER: Odell LOGGED BY: GM DEPTH TO WATER> INITIAL: 4 AFTER 24 DEPTH TO HOURS: T DATE: 11/22/2006 CAVING: L $ o iv Description L r� o d E ~ in 3 c m 0 Notes 0 Clay, sandy, moist, brown, (CL) Bulk sample taken at 1 to 4 foot depth j Bulk 7 Claystone, medium hard to very hard, (CS) Interlayered with sandstone Sample not recovered 4 CT 34/12 CT 19/12 8 CT 44/12 12 CT 34/12 16 20 24 s C i 50/3 Bottom of boring when terminated: 25 ft. 28 This information pertains only to this boring and should not be interpreted as being indicitive of the site. Figure 5 PAGE 1 of 1 Figure 6 PAGE 1 of 1 Gcoleclutica1 ',Engineering 4r4►uli, Inc. LOG OF TEST BORING TH-3 PROJECT: Williams Compressor Station -Crawford Trail PROJECT NO.: 2526 CLIENT: Williams LOCATION: ELEVATION: DRILLER: Odell LOGGED BY: GM DEPTH TO WATER> INITIAL: * AFTER 24 HOURS: T DATE: 11/22/2006 DEPTH TO CAVING: L L Y m w o Description 2 1 N rn F N m U Notes 0 Organics noted to 1 foot depth Drill rig refusal at 8 foot depth Clay, sandy, moist, brown/tan, (CL) j Claystone, medium hard, (CS) Bulk sample taken at 2 to 6 foot depth CT 31/12 Bulk 4 CT 34/12 8 Bottom of boring when terminated: 8 ft. r 12 16 20 24 28 This information pertains only to this boring and should not be interpreted as being indicitive of the site. Figure 6 PAGE 1 of 1 Figure 7 PAGE 1 of 1 Geotechnical I ,, 111iIJICCr Ft1 Grolup, Irae. LOG OF TEST BORING TH-4 TEST PROJECT: Williams Compressor Station -Crawford PROJECT NO.: 2526 CLIENT: Williams LOCATION: ELEVATION: DRILLER: Odell LOGGED BY: GM DEPTH TO WATER> INITIAL: * AFTER 24 DEPTH TO HOURS: -3- DATE: 11/22/2006 CAVING: C. tc 0 , Description U ° N ao E I--- N 3 c m U Notes 0 Organics noted to 1 foot depth Clay, sandy, slight silty, moist, brown, (CL) Bulk sample taken at 1 to 4 foot depth j Bulk 3 Claystone, medium hard to very hard, tan, (CS) Bulk sample taken at 4 to 6 foot depth 4 CT 37/12 Interlayered with sandstone Bulk sample taken at 18 to 22 foot depth \Bulkr- CT Sono 8 CT 5018 12 CT 50/10 16 20 24 C I 500 Bottom of boring when terminated: 25 ft. 28 This information pertains only to this boring and should not be interpreted as being indicitive of the site. Figure 7 PAGE 1 of 1 kngineering IIGeotechnical Groep, Inc' LOG OF TEST BORING TH-5 PROJECT: Williams Compressor Station -Crawford Trail PROJECT NO.: 2526 CLIENT: Williams LOCATION: ELEVATION: DRILLER: Odell LOGGED BY: GM DEPTH TO WATER> INITIAL: s AFTER 24 HOURS: DATE: 11/22/2006 DEPTH TO CAVING: 1_ 23 L . m a°ii 0vrEF Description U L a, n °' N 3 c mU Notes 0 Organics noted to 1 foot depth Clay, sandy, stiff, moist, brown, (CL) Bulk sample taken at 1 to 4 foot depth / / CT 16/12 Claystone, very hard, tan, (CS) Interlayered with sandstone 4 CT 50/3 CT 5ors 12 CT 50/9 16 20 24 50/4 Bottom of boring when terminated: 25 ft. 20 This information pertains only to this boring and should not be interpreted as being indicitive of the site. Fiqure 8 PAGE 1 of 1 Figure 9 PAGE 1 of 1 Geolevhniea1 I 11nginccring Group, Inc. LOG OF TEST BORING TH-6 PROJECT: Williams Compressor Station -Crawford Trail PROJECT NO.: 2526 CLIENT: Williams LOCATION: ELEVATION: DRILLER: Odell LOGGED BY: GM DEPTH TO WATER> INITIAL: AFTER 24 DEPTH TO HOURS: DATE: 11/22/2006 CAVING: S $^ a w Description U c N n a coE F N 3 c m o Notes 0 Organics noted to 1 toot depth Clay, sandy, moist, brown, (CL) Bulk sample taken at 1 to 4 foot depth 3 Bulk Claystone, medium hard to very hard, medium moist, tan to grey, (CS) Interlayered with sandstone Bulk sample taken at 14 to 17 foot depth 4 CT 45/12 CT 5011 e , CT 50/5 12 Bulk 16 CT 50/3 20 , Bottom of boring when terminated: 20 ft. 24 28 This information pertains only to this boring and should not be interpreted as being indicitive of the site. Figure 9 PAGE 1 of 1 G4otcvhu i40i IiEugiocpring Group, Inc. LOG OF TEST BORING TH-7 PROJECT:WWilliamslliams Compressor Station -Crawford Trail PROJECT NO.: 2526 CLIENT: i LOCATION: ELEVATION: DRILLER: Odell LOGGED BY: GM DEPTH TO WATER> INITIAL: a AFTER 24 HOURS: -T- DATE: 11/22/2006 DEPTH TO CAVING: L s « 4/w Description U L C N 2 E T re w O _ mU Notes 0 Organics noted to 1 foot depth Clay, sandy, moist, brown, (CL) Bulk sample taken at 1 to 4 foot depth Bulk 3 Claystone, very sandy, meium hard to very hard, medium moist, grey, (CS) Interlayered with sandstone 4 CT 32/12 CT 50/10 8 CT 50/6 12 CT 50'5 16 CT 50/5 20 Bottom of boring when terminated: 20 ft. 24 28 This information pertains only to this boring and should not be interpreted as being indicitive of the site. Figure 10 PAGE 1 of 1 Geotechnical I' • iiglneering Group, Iuc. KEY TO SYMBOLS Symbol Description Strata symbols clay Clays tone Sandstone Misc. Symbols TDrill rejection C Depth to caving Notes: 1. These logs are subject to the interpretation by GEG of the soils encountered and limitations, conclusions, and recommendations in this report. 2. Results of tests conducted on samples recovered are reported in the report Figure 3 SWELL / CONSOLIDATION TEST REPORT WATER ADDED Percent Strain 0 m ti m 0' 0 • • Percent Heave o c> a 0n 9 r m " 100 200 500 1000 2000 Applied Pressure - psf Natural Dry Dens. (per LL PI Sp. Gr. Overburden (psf) Pc (psf) C0Cr Swell Press. (psf) Heave % e 0 Sat. Moist. 16.7 % 90.2 405 281 MATERIAL DESCRIPTION USCS AASHTO Project No. 2526 Client: Williams Project: Williams Compressor Station -Crawford Trail Source: TH-2 Elev./Depth: 4 Remarks: Fig. 11 I Geolerhnicul I Engineeruping 4 r o . l nc. SWELL / CONSOLIDATION TEST REPORT -2 -_2 C 1 _1 0 c -o WATER ADDED Percent Strain m N a w Percent Heave v q 9 9 r ° 100 200 500 1000 2000 5000 Applied Pressure - psf Natural Dry Dens. (pcf) LL PI Sp. Gr. Overburden (psf) Pc (psf) Cc Cr Swell Press, (psf) Heave /o eo Sat. Moist. 13.7 % 100.8 923 2.1 MATERIAL DESCRIPTION USCS AASHTO Claystone, medium hard, (CS) Project No. 2526 Client: Williams Project: Williams Compressor Station -Crawford Trail Source: T11-3 Elev./Depth: 2 Remarks: Fig. 12 Geotechnical II nCrougineerp,ing Inc. SWELL / CONSOLIDATION TEST REPORT 0 -o WATER ADDED Percent Strain D CO �I 0) 01 A W N — -2 — -3 -o (D g —4 = co m N — -5 — -6 — -7 — -8 100 200 500 1000 2000 5000 Applied Pressure - psf Natural Dry Dens. (PO LL PI Sp. Gr. Overburden (psf) Pc (psf) CC ° r Swell Press. (psf Heave % e 0 Sat. Moist. 15.1 % 103.8 1069 0.6 MATERIAL DESCRIPTION USCS AASHTO Project No. 2526 Client: Williams Project: Williams Compressor Station -Crawford Trail Source: TF1 -4 Elev./Depth: 4 Remarks: Fig. 13 Gcolorlrnical I ',nginerrp,ing CrouInc- SWELL / CONSOLIDATION TEST REPORT 0 WATER ADDED Percent Strain CD CO -V 0 CT a u N — —2 — -3 n aD — 2 m -5 < N — -6 — -7 — -8 - -9 "' 100 200 500 1000 2000 Applied Pressure - psf Natural Dry Dens. (per LL PI Sp. Gr. Overburden (psf) Pc (psf) C ° C r Swell Press. (psf) Heave % e ° Sat. Moist. 13.9 % 105.2 1015 MATERIAL DESCRIPTION USCS AASHTO Project No. 2526 Client: Williams Project: Williams Compressor Station -Crawford Trail Source: TH-6 Elev./Depth: 4 Remarks: Fig. 14 Gcotcrinirul II,ngineeroup,ing CrInc. SWELL / CONSOLIDATION TEST REPORT 0 - -o "• WATER ADDED Percent Strain i m m rn a a co n> Percent Heave 7 0 9 "' 100 200 500 1000 2000 Applied Pressure psf Natural Dry Dens. (Pep LL PI Sp. Gr. Overburden (psf) Pc (psf) C c C r Swell Press. (Psi Heave % e 0 Sat. Moist. 15.0 % 107.6 1074 -0.1 MATERIAL DESCRIPTION USCS AASHTO Project No. 2526 Client: Williams Project: Williams Compressor Station-Crawford Trail Source: TH-7 Elev./Depth: 6 Remarks: Fig. 15 I Gcolcchnical I Engineerin Croup. Inc.g Vertical Deformation, in Shear Stress, psi -0.06 -0.04 -0.02 Mellon 0 Cond. 0.02 0.04 0060 35 7 10.5 Strain, % 60 50 40 30 20 10 14 0 0 5 10 Stra n, % 15 20 1 2 3 2 1 3 Fail. Stress, psi 15 10 5 C, psi 6, deg Results 1.29 19.6 0.36 0 0 5 10 Normal Stress, psi 15 Sample No. Water Content, % Dry Density, pcf Saturation, % S Void Ratio Diameter, in. Height, in. Water Content, % Dry Density, pcf FSaturation, % 2 Void Ratio Diameter, in. Height, in. Normal Stress, psi Fai. Stress, psi Strain, % Ult. Stress, psi Strain, % Strain rate, in./min. 1 2 3 11.9 11.9 11.9 101.3 101.3 101.3 49.6 49.6 49.6 0.6330 0.6330 0.6330 1.94 1.94 1.94 1.00 1.00 1.00 29.8 29.8 29.8 1013 101.3 101.3 124.8 124.8 124.8 0.6330 0.6330 0.6330 1.94 1.94 1.94 1.00 1.00 1.00 3.50 6.90 10.40 2.40 4.03 4.86 4.1 1.0 0.5 0.63 0.63 0.63 Sample Type: Description: LL= 33 PL= 31 PI= 2 Assumed Specific Gravity= 2.65 Remarks: Fig. 16 Client: Williams Project: Williams Compressor Station -Crawford Trail Source of Sample: TH-5 Depth: 2 Proj. No.: 2526 Date Sampled: 4 colcchnicrl I Enginccring Croup, Inr. Tested By: CC Checked By: TM 116 Job No. 2,526 w J CO SUMMARY OF LABORATORY TEST RESULTS co Q I- = CO Clay, Sandy, Gravelly (CL) Claystone (CLS) Claystone (CLS) Clay, Sandy, Silty (CL) Claystone (CLS) Claystone (CLS) Clay, Sandy, Gravelly (CL) Claystone (CLS) Clay, Silty (CL) Claystone (CLS) Claystone (CLS) 33ca !/1 co 0 1-1 1 5 1 1 1 r r Oo H" 0e azNV 43 1 1 0 CO 1 CA 1 M M 1 Direct Shear c O_ a w co ca o U 11 1 1 1 20 Internal Angle of Friction (Degrees) I 1 1 200 3 1 Swell I Consolidation Estimated Swell Pressure (Psf) 1 0 0 O�.L V 1 1 1 1 Confining Pressure (psf) 250 250 1 250 1 0 0 1.1, 1 500 y a 0 r N1 (0r O i 0 1 0i Atterberg Limits v x :ez ve mE a1 15 r 1 2 1 15 Liquid Limit (%) 1 40 1 1 r 1 co M 1 42 1 a C C 0 0) r O r 1 104 85 105 1 108 m _ m H e 23.1 16.7 13.7 24.9 r 1.0 r 0) r r 0) Cr) r V O r 15.0 .t m F 0" r V N r V N '1- r (0 V S H N = H M i H i H 2 H 2 H TH-7 45 r co a