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204-035
e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ O!t- 035 Well History File Identifier Organizing (done) D Two-sided ""1111111 ""1111 D Rescan Needed 11111111111" 111111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: BY: ~ Date ~ f¡ 101 ó¿' D Other:: Project Proofing 11I1111111111111111 tlfP 151 BY: ~ 151 mp Scanning Preparation + I = TOTAL PAGES I () I (Count does not include cover sheet) V\J1p 151 L! ~ BY: Date: Production Scanning Stage 1 Page Count from Scanned File: I 0 d- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: f?/ / fo/ CJ Co Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO 151 t41 P NO BY: Maria Date: 151 11I111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned 11I11111111111 1111I BY: Maria Date: 151 Comments about this file: Quality Checked 11I1111111111111111 10/6/2005 Well History File Cover Page.doc • Marathon Alaska Production LLC Alaska Asset Team Aik Marathon P.O. Box 1949 MARATHON Alaska Production LLC Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 July 12, 2011 Guy Schwartz Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 -- Field: Kenai Gas Field Dear Mr. Schwartz, Submitted for your records is the Wellview cementing and frac information for KBU 11 -8x well. Also included are Cement Bond Logs for: z.04-035 • KBU 11 -7 • KBU 11 -8x • KBU 11 -8Y • KBU 22 -6 • KBU 24 -7x Please contact me at (907)283 -1371 if you have any questions or need additional information. Sincerely, ° h Il aitrtfiLl - \ k; Kevin J. Skiba Regulatory Compliance Representative Enclosures: Wellview Reports cc: Houston Well File 5 CBL logs Kenai Well File (2) KJS /A \ Sperations Summary Report by Ali Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation. Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6006004N011W01 I KENAI ALASKA USA Casing Flange Elevation (ft) [Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date Rig Release Date 0.001 66.00 87.00 21.00 3/28/2004 Daily Operations Report Date: 6/1/2004 Job Category: COMPLETION 24 Hr Summary Truck in frac tanks for frac job. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:00 16:00 8.00 RURD STIM AF RU /RD Equipment. Truck in fracd tanks. Report Date: 6/2/2004 Job Category: COMPLETION 24 Hr Summary R/U frac equipment and lines Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 06:00 06:00 24.00 RURD STIM AF RU /RD Equipment. Continue to spot frac tanks and equipment. Run lines. Report Date: 6/3/2004 Job Category: COMPLETION 24 Hr Summary Continue to rig up frac equipment. Start hauling water to location. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com . 06:00 06:00 24.00 RURD STIM AF Continue R/U frac tanks equiment and lines. Begin hauling water to loacation. Report Date: 6/4/2004 Job Category: COMPLETION 24 Hr Summary Hauled water to location. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 06:00 06:00 24.00 RURD STIM AF Continue hauling water to location. Report Date: 6/5/2004 Job Category: COMPLETION 24 Hr Summary RU wireline and tag PBTD © 7534' KB. Ran a bond log from 7513' WLM. Hauled water to location O ps Trouble ' Start Time End Time Dur (hr) , Ops Code Activity Code Status Code Com 07:00 07:30 0.50 RURD SLIK 'AF Pollard arrive on location, meet with operator to discuss procedure, fill out permit. 07:30 08:00 0.50 SAFETY MTG AF Safety Meeting 08:00 08:30 0.50 RURD SLIK AF Rig up to tree. Well unperforated. 08:30 09:30 1.00 TAG BOTM AF RIH w/ 2.70 "" GR to 7513' WLM (7534' KB). POOH. RD and move to CLU 6. 09:30 09:45 0.25 RURD ELEC AF 'Expro arrive on location. Meet with operator and obtain work permit. 09:45 10:05 0.33 SAFETY MTG AF Travel to location, hold PJSM 10:05 10:45 0.67 RURD ELEC AF Spot trucks and RU bond tools and surface eqp 10:45 12:00 1.25 TRIP TOOL AF RIH w/ bond tool to PBTD © 7513' WLM. 12:00 12:15 0.25 LOG CSG AF Start repeat pass, retum to bottom 12:15 13:45 1.50 LOG CSG AF 'Logging main pass to TOC. POOH. 13:45 14:30 0.75 RURD ELEC 'AF Tools at surface. RD truck and return to gas field office to turn in permit. Report Date: 6/6/2004 Job Category: COMPLETION 24 Hr Summary Completed hauling water to location. Ops Trouble Start Time . End Time Dur (hr) . Ops Code . x Activity Code . Status . Code Com 06:00 06:00 24.00 RURD STIM AF Completed hauling water to location. Report Date: 6/8/2004 Job Category: COMPLETION 24 Hr Summary Stared R/U frac trucks and flowback equipment. Ops ' , ' Trouble _ Start Time 'End Time Our Or) -- .- . Ops Code . Activity Code Status: - Code Com 06:00 06:00 24.00 RURD STIM AF Start moving in frac trucks and flowback equipment Report Date: 6/9/2004 Job Category: COMPLETION 24 Hr Summary Continued to R/U frac trucks, lines, frac head, and flowback equipment Ops Trouble' .. Start Time • End Time ' Our (hr) Ops Code . Activity Code Status Code 06:00 06:00 24.00 RURD STIM AF Continued to R/U frac trucks, lines, coi81 tubing and flowback equipment. Test frac lines to 8500 psi. Test coil tubing and flowback lines to 4500 psi. www.peloton.com Page 1/3 Report Printed: 7/11/2011 (My •perations Summary Report by Jill Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation. Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6006004N011W01 KENAI ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date Rig Release Date 0.00 66.00 87.00 21.00 3/28/2004 Daily Operations Report Date: 6/10/2004 Job Category: COMPLETION 24 Hr Summary Lab tests indicated bad kcl in 4 frac tanks. Transfer bad fluid out of tanks. Rinse out tanks and load fresh water. Mix 4 tanks of good kcl. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code - Com 06:00 06:00 24.00 RURD STIM TA MSSM Lab tests indicated 4 tanks had bad kcl pertaining to hardness levels. Transfer bad fluid to temporary holding tanks. Rinse out frac tanks and load fresh water in same. Mix new kcl. Verify ok with additional lab testing. Report Date: 6/11/2004 Job Category: COMPLETION 24 Hr Summary Fracture stimulated 10 excape module intervals. RIH with CT and cleaned well out to 7540'. Jetted well in and put to well test equipment. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 06:00 07:00 1.00 RURD STIM AF Prep frac trucks and chemical pumps and fluids 07:00 07:30 0.50 SAFETY MTG AF Hold pre job safety meeting 07:30 08:15 0.75 PUMP FRAC AF Make final chemical and equip checks. Open well. Had 190 psi on well. Perform module 1 injectivity test. ISIP = 5196 psi. Calculated Frac gradient = 0.73 psi /ft. 08:15 09:00 0.75 PUMP FRAC AF Pert and Frac mod 1 Derfs (7370 - 7380' MD) w/ BJ Lightning_V_1800 wtr based system at 15 BPM at max TP = 4551 psi. Ramp 2.0 - 6.0 ppa. Place 26,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 250 bbl. Tagged w/ ProTechnics CFT 1100 chemical tracer and Sc -46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 09:00 09:15 0.25 PUMP FRAC AF Pert and breakdown mod 2 oerfs_(7232 - 7242' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 4100 psi. Tot Load = 27 bbl. Tagged w/ ProTechnics CFT 2200 chemical tracer and Sc-46 RA marker. 09:15 09:45 0.50 PUMP FRAC AF Pert and Frac mod 3 perfs (7189 - 7199' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3800 psi. Ramp 2.0 - 8.0 ppa. Place 55,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 366 bbl. Tagged w/ ProTechnics CFT 1200 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. (Saw no positive indications of fracture growing into module 2 perfs) 09:45 10:15 0.50 PUMP FRAC AF Pert and Frac mod 4 perfs (7102 - 7112' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 4100 psi. Ramp 2.0 - 8.0 ppa. Place 28,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 212 bbl. Tagged w/ ProTechnics CFT 1400 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 10:15 10:45 0.50 PUMP FRAC AF Pert and Frac mod 5 perfs (6970 - 6980' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 4500 psi. Ramp 2.0 - 8.0 ppa. Place 37,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 259 bbl. Tagged w/ ProTechnics CFT 1500 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 10:45 11:30 0.75 PUMP FRAC AF Pert and Frac mod 6 perfs (6818 - 6828' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3700 psi. Ramp 2.0 - 8.0 ppa. Place 28,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 211 bbl. Tagged w/ ProTechnics CFT 1600 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 11:30 12:00 0.50 PUMP FRAC AF Perf and Frac mod 7 perfs (6722 - 6732' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3760 psi. Ramp 2.0 - 8.0 ppa. Place 28,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 215 bbl. Tagged w/ ProTechnics CFT 1700 chemical tracer and Sc -46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 12:00 12:30 0.50 PUMP FRAC AF Pert and Frac mod 8 perfs (6605 - 6615' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3800 psi. Ramp 2.0 - 8.0 ppa. Place 28,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 207 bbl. Tagged w/ ProTechnics CFT 1900 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. 12:30 13:00 0.50 PUMP FRAC AF ,Perf and Frac mod 9 perfs (6443 - 6453' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3220 psi. Ramp 2.0 - 8.0 ppa. Place 28,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 204 bbl. Tagged w/ ProTechnics CFT 2000 chemical tracer and Sc-46 and Ir- 192 RA markers in pad and slurry volumes, respectively. www.peloton.com Page 2/3 Report Printed: 7/11/2011 (A\# Sperations Summary Report by JO Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation. Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6006004N011W01 KENAI ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB- Casing Flange Distance (ft) KB- Ground Distance (ft) Spud Date Rig Release Date 0.00 66.00 87.00 21.00 3/28/2004 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 13:00 13:30 0.50 PUMP FRAC AF Perf and Frac mod 10 perfs (6373 - 6383' MD) w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 4800 psi. Ramp 2.0 - 8.0 ppa. Place 32,000 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 222 bbl. Tagged w/ ProTechnics CFT 2100 chemical tracer and Sc -46 and Ir- 192 RA markers in pad and slurry volumes, respectively. (Increased breaker loading to 4 gpt versus 2 gpt on all other stages) Total frac job load = 2173 bbls. 13:30 14:30 1.00 RURD STIM AF Shut down frac trucks. Clean up equipment and lines. Secure frac equipment for the night 14:30 16:00 1.50 RURD COIL AF RU /RD Coiled Tubing Equipment 16:00 17:00 1.00 TRIP TOOL AF Run in Hole with Coiled Tubing to 6350. Check pick up weight prior to cleaning out excape flappers. 17:00 18:30 1.50 TRIP TOOL AF Run in Hole with Coiled Tubing from 6350 7540'. Had positive weight indication of breaking excape flappers at 6375, 6447, 6607, 6722, 6819, 6972, and 7237' RKB (Modules 10, 9, 8, 7, 6, 5, 2). Had indications of possible ;flapper break at 7105 and 7193' RKB (Modules 3 & 4). Unable to wash to PBTD of 7565. CBU at 7540' RKB. 18:30 23:00 4.50 JET N2 AF POOH to 5000' and jet well in with 750 scfm N2. Well slow in and sporadic in unloading and flowing on its own. Well started to flow at stable FTP of 300 psig. 23:00 '00:00 1.00 JET N2 AF RIH with CT at 350 scfm to ensure all intervals open. Tagged up firm at module 4 flapper depth of 7105' RKB. Unable to work CT past flapper. 00:00 01:00 1.00 TRIP TOOL AF Pull out of Hole with Coiled Tubing. Shut in well with FTP = 800 psi. 01:00 01:30 0.50 RURD COIL AF RD Coiled Tubing Injector head and clean out lines. Secure CT equipment for the night. 01:30 03:30 2.00 RURD EQIP AF Work with production operators to trouble shoot SSV ESD hook up and operation. 03:30 06:00 2.50 FLOW BACK AF Flow Well to test equipment. Well unloading and flowing at 1210 psig FTP, 1.4 MMCFD, 281 BWPD, on a 21/64th choke. Test separator at 285 psig. Cumulative water recovered = 187 bbls or 8.6% of 2173 total frac job load. Report Date: 6/12/2004 Job Category: COMPLETION 24 Hr Summary Flow test well. Shut in well to clean out plugged off sand buster. Opened up well and continued to flow test and clean up well. - - Ops Trouble - . - Start Time End Time 'Oath* ,Ops Code , ' - Activitt Code Status Code • Coin, - _ 06:00 01:00 19.00 FLOW TEST AF Flow well to test equipment. Sand buster plugged off. Shut in well. 01:00 03:00 2.00 FLOW TEST AF Clean out frac sand from sand buster and open up well. 03:00 06:00 3.00 FLOW TEST AF Flow well to test separator. Well flowing with 1250 flowline pressure, 4.8 MMCFD, 42 BWPD on a 26/64th choke. BHP line reading 1745 psi. Cumm water recovered = 444 bbls or 20.4% of 2173 total frac job load. Final DIMS report. Flow data to be communicated via testers report through Ken Walsh /Production Operators. www.peloton.com Page 3/3 Report Printed: 7/11/2011 • 11 ‘11 • Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation. For String: PRODUCTION CASING #1 Casing Detail: Casing Description Prop Run? Run Date Set Depth (ftKB) Set Tension (1000Ibf) Wellbore Centralizers Scratchers PRODUCTION CASING #1 No 4/14/2004 00:00 7,602.0 0.0 KENAI BELUGA UNIT 11 -8X Comment Casing Components Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 CUT JOINT Casing 3 1/2 2.992 3.40 L -80 8RD 31.46 12.2 43.7 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 19 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 6,242.52 43.7 6,286.2 9 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE TANK Casing 3 1/2 2.992 8RD 35.60 6,286.2 6,321.8 MODULE (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade ' Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 EXCAPE PUP Casing 3 1/2 2.992 8RD 19.74 6,321.8 6,341.5 ASSEMBLY (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 38.80 6,341.5 6,380.3 MODULES (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 8RD 2.05 6,380.3 6,382.4 ASSEMBLY (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 31.33 6,382.4 6,413.7 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 38.86 6,413.7 6,452.6 MODULES (black) EUEMO 0 Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 4 EXCAPE PUP Casing 3 1/2 2.992 8RD 26.77 6,452.6 6,479.3 ASSEMBLY (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 94.24 6,479.3 6,573.6 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 38.88 6,573.6 6,612.5 MODULES (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) ' Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 EXCAPE PUP Casing 3 1/2 2.992 8RD 13.22 6,612.5 6,625.7 ASSEMBLY (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 62.77 6,625.7 6,688.4 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 39.10 6,688.4 6,727.5 MODULES (black) EUEMO D Jts Item Description Icon OD (in) ID (in) ' Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 4 EXCAPE PUP Casing 3 1/2 2.992 8RD 26.56 6,727.5 6,754.1 ASSEMBLY (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 31.36 6,754.1 6,785.5 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 38.95 6,785.5 6,824.4 MODULES (black) EUEMO D www.peloton.com Page 1/3 Report Printed: 7/11/2011 • . fl %.0 • Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation. For String: PRODUCTION CASING #1 Casing Components Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 EXCAPE PUP Casing 3 1/2 2.992 8RD 19.72 6,824.4 6,844.1 ASSEMBLY (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 94.15 6,844.1 6,938.3 (black) EUEMO D Jts Item Descnption Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 39.15 6,938.3 6,977.4 MODULES (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 94.00 6,977.4 7,071.4 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) ' Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 39.02 7,071.4 7,110.5 MODULES (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 EXCAPE PUP Casing 3 1/2 2.992 8RD 17.59 7,110.5 7,128.0 ASSEMBLY (black) EUEMO D Jts Item Description Icon ' OD (in) ' ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 31.43 7,128.0 7,159.5 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread ' Length (ft) ' Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 39.08 7,159.5 7,198.6 MODULES (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt ( Ib/rt) Grade Top Thread Length (ft) '' Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 8RD 4.92 7,198.6 7,203.5 ASSEMBLY (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 38.75 7,203.5 7,242.2 MODULES (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE PUP Casing 3 1/2 2.992 8RD 4.91 7,242.2 7,247.1 ASSEMBLY (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 3 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 94.23 7,247.1 7,341.4 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 EXCAPE Casing 31/2 2.992 8RD 35.52 7,341.4 7,376.9 MODULES (black) EUEMO D Jts Item Description 'Icon ' OD (in) ID (in) Wt ( Ib/ft) ' Grade Top Thread Length (ft) 'Top (ftKB) Btm (ftKB) Comment 6 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 188.39 7,376.9 7,565.3 (black) EUEMO D Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 3 1/2 8RD 0.65 7,565.3 7,565.9 COLLAR (black) EUEMO --Wt D Jts Item Description 'Icon OD (in) ID (in) ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 3 1/2 2.992 9.30 L -80 8RD 31.43 7,565.9 7,597.4 (black) EUEMO D Jts Item Descnption Icon OD (in) ID (in) Wt ( Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 3 1/2 8RD 4.65 7,597.4 7,602.0 SHOE shoe EUEMO D www.peloton.com Page 2/3 Report Printed: 7/11/2011 it V/ • Casing & Cement • Marathon Oii Well Name: KENAI BELUGA UNIT 11 -8X Corporation. For String: PRODUCTION CASING #1 Cementing Job Details: Cementing Start Date Cementing End Date Cementing Company 4/14/2004 00:00 B.J. SERVICES Comment Bumped plug w /500psi over displacement pressure. Coil tubing unit indicator: N Tool company: Weatherford Wait on cement (hrs): 9 Description Type Stnng Wellbore PRODUCTION CASING Casing PRODUCTION CASING #1, KENAI BELUGA UNIT 11 -8X 7,602.0ftKB Cement Stage #1 Description: Float Failed? Plug Failed? Full Retum? Pipe Reciprocated? Pipe Rotated? Pressure Held (psi) No No Yes Yes No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Return (bbl) 1 5,250.0 7,602.0 Top Plug? Bottom Plug? Final Pump Rate (bbl /min) Pump Start Time Pump End Time No Yes 'Initial Pump Rate (bbl /min) 6 Avg Pump Rate (bbl /min) Drill Out Dia (in) Plug Bump Pressure (psi) Pressure Release Date 4 !Final Pump Pressure (psi) 15,000.0 2,000.0 Comment PIPE MOVEMENT NOTES: Drag down 65000 Drag up 92000 Pipe movement: RECIPROCATING Time stopped reciprocating: 13:30 Time started reciprocating: 12:00 Annular flow after cement job (Y /N): N Hours circulated between stages: 4 Pressure before cementing: 1700 Excess volume measured from: Caliper Returns: Full Time cementing mixing started: 12:15 Cement Fluids • LEAD Class I Density (lb/gal) Yield (fN /sack) Volume Pumped (bbl) CLASS G 15.80 1.171 181.0 Comment Displacement fluid used: BRINE Time displacement started: : Wait on Cement Time: 9 Compressive strength temp #2: 130 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 120 Free water test temperature: 120 Total water used: 103 Fluid loss test pressure: 4000 Thickening test pressure: 4000 Fluid Type Amount (sacks) Mix H2O Ratio (gal/sack) Percent Excess Pumped ( %) LEAD 872 4.981 30.0 Cement Fluid Additives Add Amount Amount Units . - Conc Unit: : Conc • : -Type' BA -56 1.2 % BWOC EC -1 0.5 % BWOC FP -6L 1.0 gphs KCL 3.0 % BWOC R -3 0.1 % BWOC Wellheads Install Date 'Type Job 'Removed Date 'Comment www.peloton.com Page 313 Report Printed: 7/11/2011 • itv, a Casing & Cement • Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation., For String: INTERMEDIATE CASING Casing Detail: Casing Description Prop Run? Run Date Set Depth (ftKB) Set Tension (10001b1) Wellbore Centralizers ' Scratchers INTERMEDIATE CASING No 4/4/2004 00:00 5,589.6 0.0 KENAI BELUGA UNIT 11 -8X Comment Casing Components Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING HANGER Casing 9 5/8 8.835 40.00 L -80 BTC 1.37 23.0 24.4 (black) Jts Item Descnption Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 PUP JOINT Casing 9 5/8 8.835 40.00 L -80 BTC 3.11 24.4 27.5 (black) Jts Item Descnption Icon OD (in) ID (in) Wt (lb/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 13 CASING JOINT(S) Casing 9 5/8 8.835 40.00 L -80 BTC 5,473.70 27.5 5,501.2 2 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 9 5/8 8.835 40.00 L -80 BTC 1.50 5,501.2 5,502.7 ThreadLock Y /N: Y COLLAR (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 2 CASING JOINT(S) Casing 9 5/8 8.835 40.00 L -80 BTC 85.18 5,502.7 5,587.9 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 9 5/8 8.835 40.00 L -80 BTC 1.70 5,587.9 5,589.6 ThreadLock Y /N: Y SHOE shoe Cementing Job Details: • Cementing Start Date Cementing End Date Cementing Company 4/8/2004 00:00 I B.J. 1 . SERVICES Comment BHT logged (Y /N): N Cement Found on Between Chow and Collar (Y /N): N Cement found on liner tool (Y /N): N Coil tubing unit indicator: N Wait on cement (hrs): 8 Description Type String Wellbore INTERMEDIATE CASING ' Casing INTERMEDIATE CASING, 5,589.6ftKB KENAI BELUGA UNIT 11 -8X Cement Stage #1 Description: . . Float Failed? ? Full Return? Pipe Reciprocated? Pipe Rotated? Pressure Held (psi) No 'Plug Failed No No No I No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Return (bbl) 1 3,015.0 5,590.0 Top Plug? Bottom Plug? Final Pump Rate (bbl /min) Pump Start Time Pump End Time Yes I Yes 'Initial Pump Rate (bbl/min) 7 1 Avg Pump Rate (bbl /min) (Drill Out Dia (in) 'Final Pump Pressure (psi) 'Plug Bump Pressure (psi) 'Pressure Release Date 7 650.0 1,150.0 Comment Annular flow after cement job (Y /N): N Hours circulated between stages: 1.5 Excess volume measured from: gauge hole Time cementing mixing started: 05:00 Cement Fluids TAIL Class Density (lb/gal) Yield (ft /sack) Volume Pumped (bbl) CLASS G 13.50 1.851 662.0 Comment Displacement fluid used: MUD Time displacement started: : Wait on Cement Time: 8 Compressive strength temp #2: 106 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 96 Free water test temperature: 96 Total water used: 145 Fluid loss test pressure: 3250 Thickening test pressure: 3250 Fluid Type Amount (sacks) Mix H2O Ratio (gal /sack) Percent Excess Pumped (%) TAIL _ 654 9.31 50.0 Cement Fluid Additives Add Amount - - Amount Units Conc Unit - - Conc - - - - Type ASA -301 0.1 % BWOC BA -56 2.5 % BWOC BA -90 10.0 % BWOC www.peloton.com Page 1/2 Report Printed: 7/11/2011 11%.# • Casing & Cement Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation. For String: INTERMEDIATE CASING Cement Fluid Additives Add Amount Amount Units Conc Unit Conc _ Type CaCI 2.0 % BWOC EC -1 0.5 % BWOC FP -6L 1.0 gphs SMS 0.5 % BWOC Wellheads Install Date Type Job Removed Date Comment www.peloton.com Page 2/2 Report Printed: 7/11/2011 . eA \/J • Casing & Cement S Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation. For String: SURFACE CASING Casing Detail: Casing Description Prop Run" Run Date Set Depth (ftKB) Set Tension (1000lbf) Wellbore Centralizers Scratchers SURFACE CASING No 3/29/2004 00:00 1,517.0 0.0 KENAI BELUGA UNIT 11 -8X Comment Casing Components Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 Csg Hd Upper Casing 13 5/8 13.625 4340 1.73 21.0 22.7 (black) Jts Item Description Icon OD (in) ID (in) Wt (lb/ft) Grade ' Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 Csg Hd Lower Casing 13 5/8 13.625 4340 1.92 22.7 24.7 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 PARTIAL JT Casing 13 3/8 12.415 K -55 BTC 12.85 24.7 37.5 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade — Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 35 CASING JOINT(S) Casing 13 3/8 12.415 68.00 K -55 BTC 1,437.51 37.5 1,475.0 ThreadLock Y /N: Y (black) Jts Item Description Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 13 3/8 12.415 K -55 BTC 1.70 1,475.0 1,476.7 ThreadLock Y /N: Y COLLAR (black) Jts Item Descnption Icon OD (in) ID (in) Wt (Ib/ft) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING JOINT(S) Casing 13 3/8 12.415 68.00 K -55 BTC 38.60 1,476.7 1,515.3 (black) Jts Item Description Icon OD (in) ID (in) Wt (Ibf) Grade Top Thread Length (ft) Top (ftKB) Btm (ftKB) Comment 1 CASING FLOAT Casing 13 3/8 12.415 K -55 BTC 1.73 1,515.3 1,517.0 SHOE shoe - Cementing Job Details: Cementing Start Date Cementing End Date Cementing Company 3/29/2004 00:00 Date ' Cementing SERVICES Comment Coil tubing unit indicator: N Tool company: Ball Check Wait on cement (hrs): 8 Description Type String Wellbore INTERMEDIATE CASING ' Casi n g [ SURFACE CASING, 1,517.0ftKB KENAI BELUGA UNIT 11 -8X Cement Stage #1 Description: Float Failed? Plug Failed? Full Retum? Pipe Reciprocated? Pipe Rotated? Pressure Held (psi) No [ No No No No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Retum (bbl) 1 21.0 1,517.0 9.0 Top Plug? Bottom Plug? [Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) 'Pump Start Time [Pump End Time Yes No Avg Pump Rate (bbl /min) ' Drill Out Dia (in) Final Pump Pressure (psi) Plug Bump Pressure (psi) 'Pressure Release Date 400.0 550.0 Comment Annular flow after cement job (Y /N): N Hours circulated between stages: 4 Pressure before cementing: 450 . Cement Fluids SPACER Class Density (Ib /gal) Yield (ft /sack) Volume Pumped (bbl) CLASS G 12.00 2.51 186.0 Comment Displacement fluid used: MUD Time displacement started: : Wait on Cement Time: 8 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 112 Fluid Type Amount (sacks) Mix H2O Ratio (gal /sack) Percent Excess Pumped ( %) SPACER 417 11.28 Cement Fluid Additives Add Amount - Amount Units ' Conc. Unit - • ' - Conc -. Type -" . CD -32 0.3 % BWOC FP -6L 1.0 % BWOW LW6 18.0 % BWOC MPA -1 20.0 % BWOC SMS 1.0 % BWOC www.peloton.com Page 1/3 Report Printed: 7/11/2011 '(' \"11 • Casing & Cement III Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation. For String: SURFACE CASING Cement Stage #2 Description: Float Failed? Plug Failed? Full Retum? Pipe Reciprocated? Pipe Rotated? Pressure Held (psi) Yes Yes No No No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Retum (bbl) 2 0.0 0.0 Top Plug? Bottom Plug? Initial Pump Rate (bbl /min) Final Pump Rate (bbl /min) Pump Start Time Pump End Time No No Avg Pump Rate (bbl/min) Drill Out Dia (in) Final Pump Pressure (psi) Plug Bump Pressure (psi) Pressure Release Date 0.0 Comment Annular flow after cement job (Y /N): N Cement Fluids (Foam job (YIN): N) Class Density (lb/gal) Yield (ft' /sack) Volume Pumped (bbl) Comment Time displacement started: : Wait on Cement Time: 8 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Fluid Type 'Amount (sacks) Mix H2O Ratio (gal /sack) Percent Excess Pumped ( %) (Foam job (Y /N): N) Cement Fluid Additives Add - - Amount - _ - Amount Units ,I Cone Unit - - Conc ' . Type Cement Stage #3 Description: Float Failed? Plug Failed? Full Retum? Pipe Reciprocated? Pipe Rotated? Pressure Held (psi) No I No No No 1 No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Retum (bbl) 3 21.0 1,518.0 Top Plug? NO 'Bottom Plug? No 'Initial Pump Rate (bbl/min) Final Pump Rate (bbl /min) 'Pump Start Time 'Pump End Time Avg Pump Rate (bbl /min) Dull Out Dia (in) 'Final Pump Pressure (psi) 1Plug Bump Pressure (psi) 'Pressure Release Date 0.01 Comment Cement Fluids SPACER Class Yield (ft /sack) Volume Pumped (bbl) CLASS G 'Density (lb /gal) 12.001 2.511 186.0 Comment Time displacement started: : Wait on Cement Time: 8 Pressure slurry density was measured at: 0 Temperature used in fluid loss test: 0 Total water used: 112 Fluid Type Mix 1(20 Ratio (gal/sack) Percent Excess Pumped ( %) SPACER 'Amount (sacks) 4171 11.28 Cement Fluid Additives - Add . - Amount - '- Amount Units . . .. - , •Conc Unit ' CD -32 0.3 % BWOC FP -6L 1.0 % BWOW LW6 18.0 % BWOC 1 MPA -1 20.0 % BWOC SMS 1.0 % BWOC Cement Stage#4 Description: Float Failed? ? Full Retum'? Pipe Reciprocated? Pipe Rotated? Pressure Held (psi) Yes 'Plug Failed Yes No No , No Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Retum (bbl) 4 0.0 Top Plug? Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) 'Pump Start Time 'Pump End Time No !Bottom Plug? No 1 Avg Pump Rate (bbl /min) 'Drill Out Dia (in) 'Final Pump Pressure (psi) 'Plug Bump Pressure (psi) 'Pressure Release Date 0.0 Comment Annular flow after cement job (Y /N): N Cement Fluids <typ> Class 'Density (lb/gal) 'Yield (ft /sack) 'Volume Pumped (bbl) Comment Fluid Type 'Amount (sacks) 'Mix H2O Ratio (gal /sack) 'Percent Excess Pumped ( %) www.peloton.com Page 2/3 Report Printed: 7/11/2011 K m" Casing & Cement Marathon Oil Well Name: KENAI BELUGA UNIT 11 -8X Corporation, For String: SURFACE CASING Cement Fluid Additives Add - Amount Amount Units Conc Unit Conc Type - Wellheads Install Date Type Job Removed Date Comment www.peloton.com Page 3/3 Report Printed: 7/11/2011 • ~ Marathon MARATHON Alaska Productian LLC ~ MaT~fthon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~G~ Y ~1.~' October 13, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations ~CT ~ ~ 2Q09 ~~eska Oit ~ Gas Cans. Corturrussinn Anchoraps (~ 3~ ~, d ~I'' Field: Kenai Gas Field Well: Kenai Beluga Unit 11-8x ~:~~ ~~~ ~ _ ~~_, Dear Mr. Aubert: Attached for your records is the10-404 Report of Sundry Well Operations for KBU 11-8x well. The AOGCC provided approval for the addition of 24' of perforations under Sundry # 308-375. Marathon no longer intends to perform this activity and is closing out this sundry as a Non-Work activity. Other wells in this program experienced reduced production when perforated, which was caused by additional water infiltrating the wellbore. This decision is intended to minimize the risk of loosing crucial production while entering the high demand season. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, _ ~ .,~2~ Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~E~EIV~C} 0 C T 1 ~0~00~7-~'p~ ~#las~C~ Oil & Gas Cons. Commission 1. Operations Abandon Repair Well Plug PerForations Stimulate Other ~ ~C Q~'~ration Performed: Alter Casing ~ Pull Tubin~ Perforate New Pool ~ Waiver^ Time Extension ^ Non-Work Change Approved Program ~ Operat. Shutdowr{~ Perforate ^ Re-enter Suspended Well ~ 2. Operator Marathon Oil Company N 4. Well Class Before Work: ' . Permit to Drill Number: ame: Development ^~ Exploratory0 ~ 204-0350 3. Address: p0 BoX 7 949 Stratigraphic ~ Service ^ PI Number: Kenai Alaska, 99611-1949 50-133-20536-00-00 7. KB Elevation (ft): ~ Well Name and Number: $7' 21' AGL Kenai Belu a Unit 11-8x 8. Property Designation: '~ 0. Field/Pool(s): A-028142 Kenai Gas Field / Beluga 8~ Tyonek Formations 11. Present Well Condition Summary: Total Depth measured ~ 7,659' feet Plugs (measured) N/A true vertical ''~ 7,401' feet Junk (measured) N/A Effective Depth measured 7,565' feet true vertical 7,3p7' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 134' 134' 3,060 psi 1,500 psi Surface 1,496' 13-3/8" 1,517' 1,507' 3,450 psi 1,950 psi Intermediate 5,569' 9-5/8" 5,590' S,340' 6,870 psi 4,750 psi Production 7,581' 3-1/2" 7,602' 7,344' 10,160 psi 10,540 psi Liner PerForation depth: Measured depth: 6,373' - 7,380' True Vertical depth: 6,118' - 7,122' Excape Tubing 3-1/2' L-80 7,602' Tubing: (size, grade, and MD) Capillary String Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): The approved perforation additions were not added because of the additional water infiltration issues experience with some of the other Treatment descriptions including volumes used and final pressure: wells, in this program, after they were perforated. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments . Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations . Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-375 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician ~ Signature :~ Phone (907) 283-1371 Date October 13, 2009 V Form 10-404 Revised 04/2006 Submit Original Only • ~. ~~ OIL ~`~ ~a7 COI~TSERQA7`I011T COl-II~IISSI011T Kyle Miranda Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kenai Gas Field, Upper Tyonek/Beluga Gas Pool, 11-9x ~~~ Sundry Number: 308-375 cc~~ ~ ~' d~~ Dear Mr. Miranda: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~9~~ Daniel T. Seamount, Jr. Chair DATED this- ~ day of October, 2008 Encl. M Marathon MARATHON Oil Company October 17, 2008 ~~~,~ Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Application of Sundry Approvals Field: Kenai Gas Field Well: Kenai Beluga Unit 11-8x Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ors ~~~ ~ ~ L:i Alaska Oi! & Gas Cons. ~,~ ;; Anchorage ~.. 3~ ~~ Attached for your records is the10-403 Application of Sundry Approvals for KBU 11-8x well. Marathon requests permission to enhance gas production by adding 24' of perforations at 7,530' - 7,554' MD. The target interval is located in the Beluga formation, below the #1 Excape Module. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ..Q~i17/w Kevin J. Skiba Engineering Technician Enclosures: 10-403 Application of Sundry Approvals cc: Well Schematic Perforation Procedure 1 ~~ ~ a5 ! Houston Well File Kenai Well File KJS KM STATE OF ALASKA `9.Z~"~ ALA OIL AND GAS CONSERVATION COM ON ~- APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 i~ •, 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate ~ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Mat'athOn OII Cot7t an p y 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 204-0350 3. Address: PO BOX 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20536-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ ~ Kenai Beluga Unit 11-8x Spacing Exception Required? Yes No 9. Property Designation: /~q~ ~ 10. KB Elevation (ft): 11. Field/Pool(s): F~ A 028142 ~s 87'~ (21' AGL) Kenai Gas Field /Beluga & Tyonek Formations 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,659' - 7,401' - 7,565' - 7,307' - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 134' 134' 3,060 psi 1,500 psi Surface 1,496' 13-3/8" 1,517' 1,507' 3,450 psi 1,950 psi Intermediate 5,569' 9-5/8" 5,590' 5,340' 6,870 psi 4,750 psi Production 7,581' 3-1/2" 7,602' 7,344' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,373' - 7,380' 6,118' - 7,122' 3-1 /2" L-80 7,602' Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 31, 2008 Oil ^ Gas ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Kyle Miranda Title Production Engineer Signature ~,.~~ ~ , ~ Phone (907) 283-1370 Date October 17, 2008 ~ ~ ~' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .,.30 ~'- 3 ~J Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~fC.~~ Cp~~cj\ CG~`Y\ ~ C'~~~1:~' ..~~ Cs~CCf:t~ ~ ^^ ~ ~. `~~~ ~Q1~~~ Subsequent Form Required: ~®~ APPROVED BY / A roved b : COMMISSIONER THE COMMISSION Date: [ ~ ~ / pp y Form 10-403 Revised 06/2006 Submit in Duplicate 4 • INARATHON Marathon Oil Corporation Field: Kenai Beluga Unit WBS: Not requested yet Pad: 14-6 KBU 11-8x September 16, 2008 Well Status: 3.104 MMcf/d @ 421 psi (SCADA 9-17-08) and 3 bwpd (TOW 9-17-08). Objective: Perforate the following Beluga sands. Depths and surface pressure to fire guns: 7530' - 7554' (24' net, 14' & 10' tandem guns, single run) - 1520 psi Guns to be used: 2-3/8" RTG (Retrievable Tubing Gun) guns loaded 4 SPF 60 degree-phased with TAG-2375-402NTX charges and PX-1 firing head. API tar~berformance: 0.27" entrance hole and 19.21" penetration. Max gun swell in air: 2.575" OD. Procedure a) Remove well house. b) MI diesel man-lift. c) MIRU Expro E-line service with full lubricator, pump-in sub, flow tubes, and pressure control equipment. d) Hold PJSM. e) PT lubricator to 2000 psi (MPSP+) with KCL H2O or methanol, weather dependent. fj RIH with dummy guns to minimum depth needed for CCL correlation. POOH GR. 2. a) RIH w/ 24' of guns (type shown above, 14' & 10' tandem single run). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain 1520 psi WHP (underbalanced at 40% DD). d) Pull up into position and shoot 7530' - 7554' (OH). Leave well shut in for 15 minutes while POOH. Observe and note pressure build rate over 15 minutes. Open well to flow while continuing to POOH. e) LD spent perf gun and lubricator. RD Expro. Return well to production. Flow test. 3. Produce well to sales. CONTACTS Ken Walsh: 907-283-1311 (w) Jennifer Enos: 713-296-3319 (w) 907-394-3060 (c) 713- 408-3583 (c) Lyndon Ibele: 907-565-3042 (w) Clyde Scott: 713-296-2336 (w) 907-748-2819 (c) KGF Operators: 907-283-1305 • • MD Formation Bottom tvd Pressure* 7554 7296 3000 40% dd WA~,1~, temp 1800 1515 130 Tyonek 72-8, most likely partially depleted, Silty and tight *Most recent MTF in general area: KBU 34-6, two tests at 3720 & 2600 psi. KBU 11-8x Add perfs - MD Dammeyer 10/16/2008 2:28:57 PM -c 50-133-20536-00-00 A - 028142 87' (21' AGL) I: 66' above MSL 60° 27' 34.707" N 151 ° 14' 44.257" W 275,155.87 2,362,053.64 ~: 3/28/2004 4/9/2004 sed: 4/15/2004 06:OOhrs Tree crossing =4-314" Otis TOC (approx.) @ 5,150' MD ~ KBU 11-8x Pad 41-7 43' FSL, 755' FEL, Sec. 6, T4N, R11W, S.M. 1= 1' i~ t ~. ,~ '~` :- ~,1 b+ 't+ Excaoe Svstem Details: - BHP monitoring line volume tank located from 6,286' - 6,322' RKB. Ceramic flapper valves below each module as follows: Module 10 - 6,375' Module 9 - 6,447' Module 8 - 6,607' Module 7 - 6,722' Module 6 - 6,819' Module 5 - 6,972' Module 4 - 7,105' Module 3 - 7,193' Module 2 - 7,237' Module 1 - NA ,, :~ r yn TD PBTD 7,659' MD 7,565' MD 7,401' TVD 7,307' TVD i MARATNOM Conductor 20" K-55 133 ppf Top Bottom M D 0' 134' TVD 0' 134' 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 1,517' TVD 0' 1,507' 16" hole Cmt w/ 417 sks of 12.0 ppg, Type 1 cmt, 100% returns, (9 bbl) cmt to surface Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,590' TVD 0' 5,340' 12-1/4" hole cmt w/ 654 sks (215 bbls) of 13.5 ppg, Class G cmt Production Tubing 3-1/2" L-80 9.3 ppf Mod EUE Top Bottom 8rd MD 0' 7,602' TVD 0' 7,344' 8-1 /2" hole cmt w/ 871 sks of 15.8 ppg, Class G cmt - 10 Excape modules placed - Red control line fires top 8 modules - Gretan control line fires bottom 2 modules - Ceramic flapper valves below each module Module 10 - 6,373'-6,383' Module 9 - 6,443'-6,453' Module 8 - 6,605'-6,615' Module 7 - 6,722'-6,732' Module 6 - 6,818'-6,828' Module 5 - 6,970'-6,980' Module 4- 7,102'-7,112' Module 3 - 7,189'-7,199' Module 2 - 7,232'-7,242' Module 1 - 7,370'-7,380' Well Name & Number: Kenai Beluga Unit 11-8x Lease: Kenai Gas Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD:) 6,373' - 7,380' (TVD): 6,118' - 7,122' Angle @ KOP and Depth: -2° / 100 tt @ 800' to 1,900' Angle/Perfs: - 4 degrees Dated Completed: 4/15/2004 Completion Fluid: 6% KCL Prepared By: Kevin Skiba Last Revision Date: 10/17/2008 Alaska lion Domestic Production M Marathon P.O. Box 196168 Company Anchorage, AK 99519 -6168 Oil C MARATHON Telephone 907/561 -5311 Fax 907/564 -6489 June 21, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7 Ave, Suite 100 Anchorage, AK 99501 °' t1 Reference: Completion Report 10 -407 for permit 204 -035 Field: Kenai Gas Field / Beluga Well: KBU 11 -8X Dear Mr. Aubert, Enclosed please find an updated Well Completion Report for Kenai Gas Field well KBU 11 -8X and associated well operations summary. As previously communicated, this well has been completed cased hole with a 3.5" Excape monobore production string to surface. The well was fracture stimulated on June 10, 2004. This revised 10 -407 is being submitted to include final complefion and production test information. Should you require further information, I can be reached at 907 - 529 -0524 / 713 -296- 2730, or by e-mail at JRThompson@MarathonOil.com. Sincerely, James R. Thompson Sr. Completions Engineer Enclosures: Completion Report Operations Summary ST. OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: OilIJ Gas © Plugged ❑Abandoned EI Suspended E WAGE 1b. Well Class: 2OAAC 25.105 20AAC 25.110 Development Exploratory Es GINJ ❑ WINJE WDSPLE No. of Completions 1 Other Service Stratigraphic Test E 2. Operator: 5. Date Comp., Susp., Permit to Drill Number: Name: Marathon Oil Company or Aban � / / / � o 204 -035 4 3 Address: 6. Date Spudded: � . API Number: P.O. Box 196168, Anchorage, AK 99519 - 6168 3/28/2004 50- 133 - 20536 -00 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number 4/10/2004 Kenai Beluga Unit 11 -8X Surface: 43' FSL, 755' FEL, Sec. 6, T4N, R11W, S.M. 8. KB Elevation (ft.): 15. Field/Pool(s): 87 Top of Productive 23.19' FSL, 789.84' FWL, Sec. 5, T4N, R11W, S.M. 9. Plug Back Depth (MD + Beluga Horizon: TVD): 7565' MD / 7307' TVD Total Depth: 76.38' FSL, 881.92' FWL, Sec. 5, T4N, R11W, S.M. 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD +TVD): 16. Property Designation: 7659' MD / 7400' TVD A- 028142 Surface: x- 275,155.870 y- 2,362,053.640 Zone- 4 11. Depth where SSSV Set: 17. Land Use Permit: NA TPI x- 276,700.810 y- 2,362,047.050 Zone- 4 NA feet MD 19. Water Depth, if Offshore: 20. Thickness of Permafrost: Total Depth x- 276,793.060 y- 2,362,055.470 Zone- 4 NA feet MSL ` . .. ; - CIA 18. Directional Survey: Yes © NoE 21. Logs Run: +.1 t y '.N SP /GR -IEL- Density/Neutron - Sonic - Single Arm Caliper ... '-` '" 4�f?/`` 1 xR'7 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD A(OUNT SIZE FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 133.0 K -55 0 134 0 134 Driven NA NA 13 -3/8" 68.0 K -55 0 1517 0 1506 16" 417 sx NA 9 -5/8" 47.0 L -80 0 5590 0 5340 12 -1/4" 654 sx NA 3 -1/2" 9.3 L -80 0 7602 0 7344 8 -1/2" 871 sx 105,000 23. Perforations Open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size, and Number; if none, state "none "): SIZE DEPTH SET (MD) PACKER SET (MD) MD: 6373 - 6383', 6443- 6453', 6605- 6615', 6722- 6732', 6818 - 6828', 6970 - 6980', 3 -1/2" 7602 NA 7102 - 7112', 7189- 7199', 7232 - 7242', 7370 -7380' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED TVD: 6118- 6128', 6188 - 6198', 6349- 6359', 6466- 6476', 6561- 6571', 6713- 6723', See No. 23 26,000 to 55,000 Ibs 20/40 Ottawa 6845- 6854', 6931- 6941', 6974 - 6984', 7112 -7122' 26 PRODUCTION TEST Date of First Production: 6/11/2004 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas- MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 6/16/2004 24 Test Period —' NA 6400 42 26/64 NA Flow. Tubing Casing Pressure Calculated Oil-Bbl: Gas- MCF: Water -Bbl: oil Gravity - API (corr): Press: 1240 0 24 -Hour Rat —0• NA 6400 42 NA 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, 11 nessary). Sub 1 ∎,., , •ne, state "none ". None 1 1" I Form 10 -407 Revised 4/2003 CONTINUED ON REVERSE SIDE • • 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None ". None None 30. List of Attachments: Directional Survey, Operations summary, Wellbore Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name James R. Thomsspon Title Sr. Completions Engineer Signature K - Phone 907 - 529 -0524 / 713- 296 -2730 Date 5/12/2004 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex.50- 029 - 20123- 00 -00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 27: If no cores taken, indicate "none. ". Item 28: List all test information. If none, state "None ". Form 10 -407 Revised 4/2003 • • Marathon Oil Company Page 1 of 1 Final Well / Event Summary Legal Well Name: KENAI BELUGA UNIT 11 -8X Common Well Name: KENAI BELUGA UNIT 11 -8X Event Name: ORIGINAL DRILLING Start Date: 3/24/2004 End Date: 4/11/2004 DATE TMD 24 HOUR SUMMARY 3/27/2004 134 (ft) Load out / move in rig up on KBU 11 -8X 3/28/2004 134 (ft) Rig up, NU diverter, test, prepare for spud 3/29/2004 1,173 (ft) Test diverter, PU 5" DP, MU BHA, spud well, dril ahead 16" hole 3/30/2004 1,517 (ft) TD csg pt at 1517 ft, circ, wiper trip, circ, POH, RU / run 13 3/8 csg, RIH inner string, space out, stab in, C/C mud. 3/31/2004 1,517 (ft) Cont C /C, cmt 13 3/6 csg, N/D diverter, N/U BOPE 4/1/2004 1,537 (ft) Test BOPE, M/U BHA #2, P/U 5" DP, test csg, displace, circ for LOT 4/2/2004 2,800 (ft) Repair Epoch, LOT, drill ahead 12 1/4 hole drctnl 4/3/2004 4,080 (ft) DrIg To 3008',Cbu,Wiper trip,Service Rig,Rih Wiper Trip,Drlg. To 4080' 4/4/2004 4,920 (ft) Drlg. 12 1/4" Hole Directionally to 4920' 4/5/2004 5,500 (ft) DrIg. 12 1/4" Hole Drcntl to 5500' 4/6/2004 5,611 (ft) DrLg 12 1/4" drcntl. to 5611' /circ,/wiper trip, /circ/pooh for 9 -5/8" csg. 4/7/2004 5,611 (ft) Rig Up To Run Csg. /Run Csg. /Prepare To Cmt. 4/8/2004 5,611 (ft) Cement 9 5/8" CSG. Intall packoff. Test BOPE. P/U 8.5" bit and BHA. P/U DP while RIH. Mix new flopro mud. RIH and TAG © 5501'. Drill float collar. 4/9/2004 6,646 (ft) Drill out shoe tract and shoe. Clean old hole and Drill F/5611' to 5631'. C/O mud. Perform LOT. Drill F/5631' to 6646'. Circ. shakers clean. 4/10/2004 7,659 (ft) POOH to shoe. Service rig. Repair rig. RIH. Drill F/6646' to 7659'. Circ. clean. Wait on Geologist decision. 4/11/2004 7,659 (ft) Circ. clean. POOH to CSG shoe. RIH. Circ. Clean. POOH(SLM). P/U Reeves DP conveyed tools. RIH. Circ. Deploy tools. POOH logging. 4/12/2004 7,659 (ft) Logging w /Reeves. UD logging tools. Printed: 6/21/2004 2:03:55 PM • • Marathon Oil Company Page 1 of 1 Final Well / Event Summary Legal Well Name: KENAI BELUGA UNIT 11 -8X Common Well Name: KENAI BELUGA UNIT 11 -8X Event Name: ORIGINAL COMPLETION Start Date: 4/11/2004 End Date: DATE TMD 24 HOUR SUMMARY 4/12/2004 7,659 (ft) P/U 8.5" BHA. RIH w /5" DP to CSG shoe. Slip and cut drlg. line. Cont. RIH to 7659'. Circ. and cond mud. POOH and UD DP. 4/13/2004 7,659 (ft) UD DP. Pull wear bushing. Clear rig floor of DRLG tools. Run 3 1/2" Prod CSG. CBU. R/U and run GR correlation log. 4/14/2004 7,659 (ft) Correlate Excape completion. R/U BJ and cement 3 1/2" production CSG. WOC and empty and clean pits. N/D BOPE. Set slips. Cut and dress CSG stub. Install pack off and test. Install tree and test. R/D rig. 4/15/2004 7,659 (ft) R/D rig. R/D camp and move. Release rig to KU31 -7X WO @ 06:00hrs 04/15/2004. II I -- —_— -- — - Printed: 6/21 /2004 2:04:35 PM • • Marathon OH Company Page 1 of 1 Final Well / Event Summary Legal Well Name: KENAI BELUGA UNIT 11 -8X Common Well Name: KENAI BELUGA UNIT 11 -8X Event Name: ORIGINAL COMPLETION Start Date: 6/1/2004 End Date: DATE TMD 24 HOUR SUMMARY 6/1/2004 (ft) Truck in frac tanks for frac job. 6/2/2004 (ft) R/U frac equipment and lines 6/3/2004 (ft) Continue to rig up frac equipment. Start hauling water to location. 6/4/2004 (ft) Hauled water to location. 6/5/2004 (ft) Hauled water to location 6/6/2004 (ft) Completed hauling water to location. 6/8/2004 (ft) Stared R/U frac trucks and flowback equipment. 6/9/2004 (ft) Continued to R/U frac trucks, lines, frac head, and flowback equipment 6/10/2004 (ft) Lab tests indicated bad kcl in 4 frac tanks. Transfer bad fluid out of tanks. Rinse out tanks and Toad fresh water. Mix 4 tanks of good kcl. 6/11/2004 (ft) Fracture stimulated 10 excape module intervals. RIH with CT and cleaned well out to 7540'. Jetted well in and put to well test equipment. 6/12/2004 (ft) Flow test well. Shut in well to clean out plugged off sand buster. Opened up well and continued to flow test and clean up well. Printed: 6/21 /2004 2:04:50 PM • ~. '~-~- '• ~ 03/01 /2008 DO NOT PLACE ~~ V R.~ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc '-' .~ Alaska Asset Team Northern Business Unit , , M MARATHON ~ ~ Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-296-3397 August 22, 2006 Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 HAND DELIVERED RE: Marathon Oil Company KED 11-8X CONFIDENTIAL Dear Mr. Okland: Confidential digital data for the above referenced well is enclosed. The CD contents are listed below: Name Adobe Acrobat: 7.0 Docun-aent: LAS File ~ ~ '~ () V, :L ~ KBU l1-aX_Mudlog_MD. pdf DA T File ~ kbu_ll-ax_dir. dat ~ kbu_11-8x_dir .Ias ~ kbu_11-8X_field .Ias ~ kbu_11-8x_mudlog .Ias ~ kbu_11-8x_neut-den .Ias SCANNED f1IUG 2 :1 20GB Precision Dat:a Package 'm' kbu_11-8X_field. dpk To confirm receipt of this data, please sign and fax a copy of this transmittal to me at 713-499-8504. Thank you, ~~/tNr- Kaynell Zeman Engineering Technician Enclosure RECEIVED AUG 2 2 2006 Recei'r 1JY.' : Alaska OjJ & Gas Cons. Commis$ion Date: l'f \'. Anchorage -L 0 li-.~ ;} ð<-f- D >,[ Kenai Beluga Unit 11-8X . . Kayne", Started to cool down in Houston yet? In the 50's and 60's here. I need some help getting OH data for KBU 11-8X ( API 50-133-20536-00 ). We need: Open Hole bJuelines OpenhoJe reproduce abies (digital graphics files, pdf, pds ) Open hole logging digits (LIS, DLlS, or LAS ). Directional survey ( ascii text, xis ) TNX Howard 1 of 1 8/16/20069:40 AM \1 J~~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040350 Well NamelNo. KENAI BELUGA UNIT 11-8X Operator MARATHON OIL CO S{J...1.- At ¡vi,.., ~ y API No. 50-133-20536-00-00 MD 7659 r' TVD 7400 / Completion Date 6/11/2004-- Completion Status 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: SP/GR-IEL-Density/Neutron-Sonic-Single Arm caliper Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type [ Electr Digital Dataset Med/Frmt Number Name . Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments -i Sample Interval Set Start Stop Sent Received Number Comments Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? 'l"ï"M- Daily History Received? lÎ>N ~n::i" Formation Tops Analysis Received? ~ . Comments: iL-~ t) B J'~~~ , Compliance Reviewed By: ~ Date: L~~ ¥' I ~~ 4\7 ~ . ~ Ù ~t..Jt{\7 '-llr~-/ ~ ~ )//).../ ~ '1 . . Alaska Business Unit Domestic Production Marathon Oil Company P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 August 11, 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED AUG 1 5 2006 Alaska Oil & Gas Cons. Commission Anchorage Reference: Completion Report 10-407 for Permit 204-035 Field: Kenai Gas Field I Beluga Well: KBU 11-8X Dear Mr. Aubert: As requested by Mr. Steve McMains, please find enclosed a copy of all previous communications with the AOGCC regarding the Well Completion Report and associated attachments for Kenai Beluga Unit Well No. 11-8X. Should you require further information, I can be reached at 713-232-9347 or 713-296-2730 or by email atJRThompson@MarathonOil.com. Sincerely, Ò::::::T~P~ Sr. Completions Engineer Enclosures: KBU 11-8X AOGCC Form 10-407 Directional Survey Wellbore Diagram Operations Summary . . Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519·6168 Telephone 907/561-5311 Fax 907/564·6489 Marathon Oil Company June 21, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Completion Report 10-407 for permit 204-035 Field: Kenai Gas Field / Beluga Well: KBU 11-8X Dear Mr. Aubert, Enclosed please find an updated Well Completion Report for Kenai Gas Field well KBU 11-8X and associated well operations summary. As previously communicated, this well has been completed cased hole with a 3.5" Excape monobore production string to surface. The well was fracture stimulated on June 10, 2004. This revised 10-407 is being submitted to include final completion and production test information. Should you require further information, I can be reached at 907-529-0524/713-296- 2730, or bye-mail atJRThompson@MarathonOil.com. Sincerely, ræ~ James R. Thompson Sr. Completions Engineer Enclosures: Completion Report Operations Summary KI::t.,I::IVt:U . STATE OF ALASKA . AUG 152006 ALASKA~L AND GAS CONSERVATION COMM ION WELL COMPLETION OR RECOMPLETION REPORT ANIIOLU8Cons.Commission 1a. Well Status: oilD Gas[] PluggedDAbandOned D Suspended D WAGD 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory [] GINJ D WINJD WDSPLD No. of Completions 1 Other Service Stratigraphic Test D 2. Operator. 5. Date Comp., Susp., Permit to Drill Number: Name: Marathon Oil Company or Aband: 4/15/2004 204-035 3 Address: 6. Date Spudded: API Number: P.O. Box 196168, Anchorage, AK 99519-6168 3/28/2004 50- 133-20536-00-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number 4/10/2004 Kenai Beluga Unit 11-8X Surface: 43'FSL,755'FEL,Sec. 6,T4N,R11W, S.M. 8. KB Elevation (ft.): 15. FieldlPool(s): 87 Top of Productive 23.19' FSL, 789.84' FWL, Sec. 5, T4N, R11W, S.M. 9. Plug Back Depth (MD + Beluga Horizon: TVD): 7565' MD /7307' TVD Total Depth: 76.38' FSL, 881.92' FWL, Sec. 5, T4N, R11W, S.M. 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD): 16. Property Designation: 7659' MD /7400' TVD A-028142 Surface: x- 275,156.870 y- 2,362,053.640 Zone- 4 11. Depth where SSSV Set: 17. Land Use Permit: NA TPI x- 276,700.810 y- 2,362,047.050 Zone- 4 NA feetMD 19. Water Depth, if Offshore: 20. Thickness of Permafrost: Total Depth x- 276,793.060 y- 2,362,055.470 Zone- 4 NA feet MSL NA 18. Directional Survey: ves[] NoD 21. Logs Run: SP/GR-IEL-DensitylNeutron-Sonic-Single Arm Caliper 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT SIZE FT. TOP BOTTOM TOP BOTTOM PULLED 20' 133.0 K-55 0 134 ° 134 Driven NA NA 13-3/8' 68.0 K-55 ° 1517 ° 1506 16' 417sx NA 9-5/8' 47.0 L-80 ° 5590 ° 5340 12-1/4' 654 sx NA 3-112' 9.3 L-80 0 7602 ° 7344 8-1/2' 871 sx 105,000 23. Perforations Open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size, and Number; if none, state 'none'): SIZE DEPTH SET (MD) PACKER SET (MD) MD: 6373-6383', 6443-6453', 6605-6615', 6722-6732', 6818-6828', 6970-6980', 3-112' 7602 NA 7102-7112',7189-7199',7232-7242',7370-7380' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAl (MD) AMOUNT AND KIND OF MATERIAL USED TVD: 6118-6128',6188-6198',6349-6359',6466-6476', 6561-6571', 6713-6723', See No. 23 26,000 to 55,000 Ibs 20/40 Ottawa 6845-6854',6931-6941',6974-6984',7112-7122' 26. PRODUCTION TEST Date of First Production: 6/11/2004 Method of Operation (Flowing, Gas Uft, etc.): Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas- MCF: Water-Bbl: Choke Size: GaS-Oil Ratio: 6/16/2004 24 Test Period -~ NA 6400 42 26/64 NA Flow. Tubing Casing Pressure Calculated Oil-Bbl: Gas- MCF: Water-Bbl: oil Gravity - API (CO"): Press: 1240 0 24-Hour RatE -~ NA 6400 42 NA 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, if nessary). Submit core chips; if none, state 'none'. None Form 10-407 Revised 4/2003 CONTINUED ON REVERSE SIDE OR\G\NAL . . 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach deteiled supporting data as necessary, If no tests were conducted, state 'None'. None None 30. List of Attachments: Directional Survey, Operations summary, Wellbore Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name James R. Thomspon Title Sr. Completions Engineer Signature ~(I. ~. Phone 907-529-0524/713-296-2730 Date 5/12/2004 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex.50-029-20123-OO-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 27: If no cores taken, indicate 'none.'. Item 28: List all test Information. If none, state 'None'. Form 10-407 Revised 412003 . . Marathon Oil Company Page 1 of 1 Final Weill Event Summary Legal Well Name: KENAI BELUGA UNIT 11-8X Common Well Name: KENAI BELUGA UNIT 11-8X I Event Name: ORIGINAL DRILLING Start Date: 3/24/2004 End Date: 4/11/2004 DATE TMD 24 HOUR SUMMARY 3/27/2004 134 (ft) Load out / move in rig up on KBU 11-aX 3/28/2004 134 (ft) Rig up, NU diverter, test, prepare for spud 3/29/2004 1,173(ft) Test diverter, PU 5" DP, MU BHA, spud well, dril ahead 16" hole 3/30/2004 1,517 (ft) TD csg pt at 1517 ft, circ, wiper trip, eire, POH, RU / run 13 3/S csg, RIH inner string, space out, stab in, C/C mud. 3/31/2004 1,517 (ft) Cont C/C, cmt 13 3/6 csg, N/D diverter, N/U BOPE 4/1/2004 1,537 (ft) Test BOPE, M/U BHA #2, P/U 5" DP, test csg, displace, circ for LOT 4/2/2004 2,SOO (ft) Repair Epoch, LOT, drill ahead 12 1/4 hole drctnl 4/3/2004 4,OSO (ft) Drlg To 300S',Cbu,Wiper trip,Service Rig,Rih Wiper Trip,Drlg. To 40S0' 4/4/2004 4,920 (ft) Drlg. 12 1/4" Hole Directionally to 4920' 4/512004 5.500 (ft) Drlg. 121/4" Hole DrcnU to 5500' 4/612004 5,611 (ft) DrI.g 12 1/4" drcntl. to 5611'/circ,/wiper trip,/circlpooh for 9-5Ia" csg. 4/7/2004 5,611 (ft) Rig Up To Run Csg.lRun Csg./Prepare To em!. 4/a/2004 5,611 (ft) Cement 9 5/S" CSG. Intall packoff. Test BOPE. P/U S.5" bit and BHA. P/U DP while RIH. Mix new flopro mud. RIH and TAG @ 5501'. Drill float collar. 4/9/2004 6,646 (ft) Drill out shoe tract and shoe. Clean old hole and Drill F/5611' to 5631'. C/O mud. Perform LOT. Drill F/5631 , to 6646'. Circ. shakers clean. 4/10/2004 7,659 (ft) POOH to shoe. Service rig. Repair rig. RIH. Drill F/6646' to 7659'. Circ. clean. Wait on Geologist decision. 4/11/2004 7,659 (ft) Circ. clean. POOH to CSG shoe. RIH. Circ. Clean. POOH(SLM). P/U Reeves DP conveyed tools. RIH. Circ. Deploy tools. POOH logging. 4/12/2004 7,659 (ft) Logging w/Reeves. UD logging tools. --------------- Printed: 6121/2004 2:03:55 PM . . Marathon Oil Company Page 1 of 1 Final Weill Event Summary Legal Well Name: KENAI BELUGA UNIT 11-8X Common Well Name: KENAI BELUGA UNIT 11-8X Event Name: ORIGINAL COMPLETION Start Date: 4/11/2004 End Date: DATE TMD 24 HOUR SUMMARY 4/12/2004 7,659 (ft) PIU 8.5" BHA. RIH w/5" DP to CSG shoe. Slip and cut drlg. line. Cont. RIH to 7659'. Circ. and cond mud. POOH and UD DP. 4/13/2004 7,659 (ft) UD DP. Pull wear bushing. Clear rig floor of DRLG tools. Run 3 1/2" Prod CSG. CBU. RlU and run GR correlation log. I 4/14/2004 7,659 (ft) Correlate Excape completion. RlU BJ and cement 31/2" production CSG. woe and empty and I clean pits. N/D BOPE. Set slips. Cut and dress CSG stub. Install pack off and test. Install tree and ¡ test. RID rig. 4/15/2004 7,659 (ft) RID rig. RID camp and move. Release rig to KU31-7X WO @ 06:00hrs 04/15/2004. ! -- ,--- -- Printed: 612112004 2:04:35 PM [ .--------- ---- I I I I i Legal Well Name: I Common Well Name: ! Event Name: DATE 6/1/2004 . . -"'----.,.,----...-- -- " -_._.._--------,-----~-_._- - -_...~_..._._. --""~.- 6/2/2004 6/312004 6/4/2004 6/512004 6/6/2004 6/8/2004 619/2004 6/10/2004 6/11/2004 6/12/2004 Marathon Oil Company Final Weill Event Summary Page 1 of 1 --.-- KENAI BELUGA UNIT 11-8X KENAI BELUGA UNIT 11-8X ORIGINAL COMPLETION Start Date: 6/1/2004 TMD 24 HOUR SUMMARY (ft) Truck in frac tanks for frac job. (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) End Date: RIU frac equipment and lines Continue to rig up frac equipment. Start hauling water to location. Hauled water to location. Hauled water to location Completed hauling water to location. Stared RIU frac trucks and flowback equipment. Continued to RIU frac trucks, lines, frac head, and flowback equipment Lab tests indicated bad kcl in 4 frac tanks. Transfer bad fluid out of tanks, Rinse out tanks and load fresh water. Mix 4 tanks of good kcl. Fracture stimulated 10 excape module intervals, RIH with CT and cleaned well out to 7540', Jetted well in and put to well test equipment. I Flow test well. Shut in well to clean out plugged off sand buster. Opened up well and continued to I flow test and clean up well. Printed: 6/2112004 2:04:50 PM . Marathon Oil Company . Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561·5311 Fax 907/564-6489 May 19, 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡th Ave, Suite 100 Anchorage, AK 99501 Reference: Completion Report 10-407 for permit 204-035 Field: Kenai Gas Field / Beluga Well: KBU 11-8X Dear Mr. Aubert, Enclosed please find the Well Completion Report with associated attachments for Kenai Gas Field well KBU 11-8X. This well has been completed cased hole with a 3.5" Excape monobore production string to surface. Current plans are to fracture stimulate the ten producing intervals indicated on June 9, 2004. A revised 10-407 will be submitted upon completion of this work which will include fracture stage sizes, test rates, and updated operations summary. I apologize for the delay in getting this completion notice to you. Should you require further information, I can be reached at 907-529-0524/713-296- 2730, or bye-mail atJRThompson@MarathonOil.com. Sincerely, ~;2~ James R. Thompson Sr. Completions Engineer Enclosures: Completion Report Directional Survey Operations Summary Wellbore Diagram .. STATE OF ALASKA I ALASKA ~ AND GAS CONSERVATION COMMISSI WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: OilO GasEJ PluggedOAbandoned 0 Suspended 0 W AGO 1b. Well Class: 20MC 25.105 20MC25.110 Development Exploratory EJ GINJ 0 WINJO WDSPLO No. of Completions 1 Other Service Stratigraphic Test 0 2. Operator: 5. Date Comp., Susp., Permit to Drill Number: Name: Marathon Oil Company or Aband: 4115/2004 204-035 3 Address: 6. Date Spudded: API Number: P.O. Box 196168, Anchorage, AK 99519-6168 3/28/2004 50- 133-20536-00-00 48. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number 4110/2004 Kenai Beluga Unit 11-8X Surface: 43' FSL, 755' FEL, Sec. 6, T4N, R11W, S.M. 8. KB Elevation (ft.): 15. FieIdlPool(s): 87 Top of Productive 23.19' FSL, 789.84' FWL, Sec. 5, T4N, R11W, S.M. 9. Plug Back Depth (MD .¡. Beluga Horizon: TVD): 7565' MD 1 7307' TVD Total Depth: 76.38' FSL, 881.92' FWL, Sec. 5, T4N, R11W, S.M. 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD): 16. Property Designation: 7659' MD 17400' TVD A-028142 Surface: x- 275,155.870 y- 2,382,053.640 Zone- 4 11. Depth where SSSV Set: 17. Land Use Permit: NA TPI x- 276,700.810 y- 2,382,047.050 Zone- 4 NA feetMD 19. Water Depth, if Offshore: 20. Thickness of Permafrost: Total Depth x- 276,793.060 y- 2,362,055.470 Zone- 4 NA feet MSL NA 18. Directional Survey: veslRJ NOO 21. Logs Run: SP/GR-IEL-Density/Neutron-Sonlc-Single Arm Caliper 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT SIZE FT. TOP BOTTOM TOP BOTTOM PULLED 20' 133.0 K-55 0 134 0 134 Driven NA NA 13-3/8' 68.0 K-55 0 1517 0 1506 16' 417 sx NA 9-518' 47.0 L-80 0 5590 0 5340 12-1/4' 654 sx NA 3-112' 9.3 L-80 0 7602 0 7344 8-1/2' 871 sx 105,000 23. Perforations Open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size, and Number; If none, state 'none'): SIZE DEPTH SET (MD) PACKER SET (MD) MD: 6373-6383', 6443-8453', 6605-6615', 6722-6732', 6818-6828', 6970-6980', 3-1/2' 7602 NA 7102-7112',7189-7199',7232-7242',7370-7380' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED TVD: 6118-6128',6188-6198',6349-6359',6466-8476', 6561-6571', 6713-6723', See No. 23 6845-6854',6931-6941',6974-6984',7112-7122' 26. PRODUCTION TEST Date of First Production: 2/2/2004 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas- MCF: Water-Bbl: Choke Size: GaS-Oil Ratio: 24 Test Period -~ NA NA NA NA Flow. Tubing Casing Pressure Calculated Oil-Bbl: Gas- MCF: Water-Bbl: oil Gravity - API (corr): Press: 0 24-Hour Ratl-~ NA NA 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach seperate sheet, if nessery). Submit core chips; if none, state 'none'. None Form 10-407 Revised 412003 CONTINUED ON REVERSE SIDE . . 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None". None None 30. List of Attachments: Directional Survey, Operations summary, Wellbore Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name James R. Thomspon Title Sr. Completions Engineer Signature ~ ...., DJd" Phone 907-529-0524/713-296-2730 Date 5/12/2004 ,- f . ......" INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 1 0-407 well completion report and 1 0-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex.50-029-20123-OQ-OQ). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 27: If no cores taken, indicate "none.". Item 28: List all test information. If none, state "None". Form 10-407 Revised 4/2003 . . MARATHON Oil Company Pad 41-7 KBUll-8X slott KBUll-8X Kenai Gas Field Kenai Peninsula, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-7659> svy7026 Date printed Date created Last revised 3-May-2004 29-Mar-2004 13-Apr-2004 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on 270916.030,2362063.980,999.00000,N Slot location is n60 27 34.707,w151 14 44.257 Slot Grid coordinates are N 2362053.640, E 275155.869 Slot local coordinates are 71.37 N 4239.42 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 0.00 137.00 195.00 257.00 316.00 376.00 436.00 497.00 557.00 616.00 677.00 73 9.00 802.00 865.00 929.00 992.00 1055.00 1118.00 1180.00 1242.00 6.30 7.60 8.70 9.90 10.80 1306.00 1370.00 1432.00 1462.00 1558.00 11.60 12.70 14.00 14.50 14.60 1621.00 1685.00 1748.00 1811.00 1874.00 15.30 15.60 16.70 18.30 19.60 1938.00 2002.00 2063.00 2126.00 2189.00 21.40 22.50 22.00 22.30 22.50 2252.00 2316.00 2378.00 2442.00 2505.00 22.00 21.60 21. 30 21.00 20.70 2569.00 2632.00 2695.00 2758.00 2821.00 20.90 21. 40 21.00 20.70 21.10 2884.00 2948.00 3011 .00 3074.00 3137.00 21.60 21. 50 21. 00 21. 30 22.50 Azimuth Degrees 0.00 0.10 0.70 0.50 0.30 0.00 286.00 274.40 214.30 255.10 True Vert Depth 0.00 137.00 195.00 257.00 315.99 375.99 435.99 496.99 556.98 615.97 676.96 738.95 801.94 864.90 928.75 991.44 1053.98 1116.34 1177.52 1238.51 1301.29 1363.86 1424.18 1453.26 1546.18 1607.05 1668.74 1729.25 1789.33 1848.92 1908.86 1968.22 2024.68 2083.03 2141.28 2199.59 2259.01 2316.72 2376.40 2435.28 2495.11 2553.86 2612.60 2671.47 2730.33 2789.01 2848.53 2907.25 2966.01 3024.46 R E C TAN G U L A R COO R DIN ATE 8 O.OON 0.03N 0.07N 0.128 0.378 0.668 1.178 1.578 1. 868 2.37S 2.98S 3.59S 4.44S 5.34S 6.31S 7.48S 8.55S 9.49S 10.13S 10.35S 10.628 10.62S 9.74S 9.08S 6.89S 5.69S 5.06S 4.83S 4.92S 5.45S 5.97S 6.07S 5.90S 5.49S 4.69S 3.65S 2.59S 1.67S 0.64S 0.42N 1.19N 1. 63N 1. 92N 2.24N 2.41N 2.05N 1. 43N 0.80N 0.24N 0.04N O.OOE O.l1W 0.52W 1. 05W 1. 34W 1. 59W 1.84W 2.35W 3.14W 4.08W 5.13W 5.82W 5.46W 3.51W 0.73E 6.87E 14.42E 23.30E 33.29E 44.43E 56.85E 70.32E 84.60E 91.95E 115.97E 132.18E 149.21E 166.73E 185.68E 206.13E 228.53E 252.45E 275.55E 299.30E 323.29E 347.13E 370.87E 393.52E 416.59E 438.99E 461.70E 484.43E 507.21E 529.63E 552.10E 575.03E 598.53E 621.36E 644.08E 667.58E Dogleg Deg/l00ft SURVEY LISTING Your ref Last revised 0.00 0.07 1. 04 1. 01 0.57 0.00 -0.11 -0.52 -1. 05 -1.35 . Page 1 MWD <0-7659> 13-Apr-2004 Vert Sect G RID COO R D S Easting Northing 275155.87 275155.76 275155.35 275154.82 275154.52 275154.27 275154.01 275153.49 275152.69 275151.74 275150.68 275149.98 275150.33 275152.26 275156.47 275162.60 275170.12 275178.98 275188.96 275200.09 275212.51 275225.97 275240.26 275247.63 275271. 68 275287.91 275304.95 275322.47 275341. 41 275361.85 275384.24 275408.15 275431.24 275455.00 275479.00 275502.85 275526.60 275549.27 275572.35 275594.77 275617.49 275640.22 275663.00 275685.42 275707.89 275730.81 275754.30 275777.10 275799.81 275823.30 2362053.64 2362053.68 2362053.72 2362053.54 2362053.29 2362053.01 2362052.50 2362052.11 2362051.84 2362051.35 2362050.76 2362050.17 2362049.31 2362048.37 2362047.31 2362046.03 2362044.81 2362043.70 2362042.87 2362042.43 2362041.93 2362041.67 2362042.27 2362042.79 2362044.51 2362045.40 2362045.71 2362045.60 2362045.14 2362044.22 2362043.27 2362042.71 2362042.43 2362042.38 2362042.72 2362043.30 2362043.90 2362044.39 2362044.97 2362045.60 2362045.93 2362045.93 2362045.79 2362045.67 2362045.41 2362044.61 2362043.54 2362042.46 2362041.47 2362040.82 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slott KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Bottom hole distance is 1637.26 on azimuth 88.83 degrees from wellhead. Vertical section is from wellhead on azimuth 88.88 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.50 0.60 0.70 0.90 1.20 200.60 210.60 250.50 250.00 235.10 1.10 0.70 1. 30 2.70 5.10 244.70 203.00 133.80 105.90 101.40 100.20 96.40 95.70 91.90 90.40 92.00 88.20 84.90 84.80 84.80 86.70 89.00 89.50 91.00 91.90 90.80 89.70 89.50 88.50 87.70 87.30 87.60 87.70 87.20 87.40 88.70 89.10 89.40 89.00 90.10 91. 70 91. 30 91.90 90.90 90.10 0.68 0.23 0.74 0.33 0.68 -1. 60 -1. 86 -2.38 -3.17 -4.13 0.36 1.20 1. 97 2.64 3.78 -5.19 -5.89 -5.54 -3.62 0.60 1. 91 2.19 1. 75 2.17 1. 52 6.73 14.25 23.11 33.09 44.22 1. 34 2.12 2.43 1. 67 0.10 56.64 70.10 84.39 91.76 115.82 1. 36 1.07 1. 76 2.64 2.11 132.04 149.09 166.61 185.54 205.98 2.88 1. 83 0.83 0.76 0.58 228.37 252.29 275.38 299.14 323.14 0.83 0.65 0.49 0.55 0.49 346.99 370.75 393.42 416.50 438.91 0.79 0.83 0.66 0.53 0.89 461.64 484.37 507.15 529.57 552.04 1. 22 0.28 0.87 0.74 1. 96 574.96 598.45 621. 26 643.96 667.45 . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai peninsula, Alaska Measured Inclin Depth Degrees 3200.00 3263.00 3326.00 3389.00 3451.00 22.00 21.70 21. 60 21.60 21.30 3515.00 3579.00 3642.00 3705.00 3768.00 20.90 20.80 20.70 20.20 19.90 3831. 00 3893.00 3954.00 4019.00 4082.00 19.90 20.40 22.00 21. 50 21.30 4144.00 4208.00 4272.00 4335.00 4398.00 21.20 20.70 21.00 20.90 20.60 4463.00 4525.00 4588.00 4652.00 4715.00 20.90 21.30 21.20 21. 90 21. 80 4778.00 4841.00 4905.00 4968.00 5032.00 21. 30 20.20 19.40 18.50 17.60 5095.00 5158.00 5222.00 5285.00 5347.00 16.00 14.60 12.80 11.50 11.00 5411.00 5473.00 5536.00 5645.00 5709.00 10.10 9.80 9.60 8.40 6.70 5772.00 5836.00 5899.00 5962.00 6024.00 6.30 6.40 6.00 6.00 6.00 6086.00 6148.00 6212.00 6275.00 6338.00 5.90 5.80 5.70 5.70 5.30 Azimuth Degrees 90.50 90.50 89.50 88.40 88.80 88.90 89.10 88.60 88.60 87.80 86.60 87.80 89.90 90.10 89.90 90.20 91.10 90.90 91. 40 91. 50 91.70 91. 50 91.30 89.80 89.50 89.50 87.70 87.40 85.90 84.80 85.50 87.90 86.60 86.60 85.40 84.50 84.70 84.80 83.40 83.20 84.80 85.00 84.50 83.90 85.60 86.00 85.70 84.20 85.40 86.30 True Vert Depth 3082.77 3141.24 3199.80 3258.37 3316.08 3375.79 3435.60 3494.51 3553.54 3612.72 3671.96 3730.17 3787.04 3847.41 3906.06 3963.85 4023.62 4083.43 4142.26 4201.18 4261.96 4319.80 4378.52 4438.05 4496.52 4555.12 4614.03 4674.24 4733.83 4794.68 4854.99 4915.76 4977.93 5039.52 5100.33 5163.25 5224.31 5286.41 5394.07 5457.51 5520.11 5583.71 5646.35 5709.00 5770.66 5832.33 5894.00 5957.68 6020.37 6083.08 R E C TAN G U L A R COO R DIN ATE S 0.08S 0.29S 0.29S o .14N 0.69N 1.15N 1.55N 2.00N 2.54N 3.21N 4.26N 5.30N 5.73N 5.73N 5.73N 5.71N 5.45N 5.06N 4.61N 4.04N 3.40N 2.77N 2.22N 2.00N 2.14N 2.34N 2.88N 3.80N 4.99N 6.59N 8.14N 9.11N 9.83N 10.61N 11. 45N 12.48N 13 . 49N 14.46N 16.20N 17 .18N 17.93N 18.56N 19.18N 19.85N 20.44N 20.91N 21. 37N 21. 93N 22.50N 22.94N 691.43E 714.88E 738.12E 761.31E 783.97E 807.01E 829.78E 852.10E 874.10E 895.69E 917.11E 938.44E 960.49E 984.58E 1007.57E 1030.04E 1052.92E 1075.69E 1098.21E 1120.53E 1143.55E 1165.86E 1188.68E 1212.19E 1235.64E 1258.78E 1281.09E 1302.75E 1323.17E 1342.93E 1361.08E 1377 . 67E 1392.81E 1406.04E 1418.11E 1429.78E 1440.45E 1451.02E 1467.98E 1476.33E 1483.42E 1490.47E 1497.25E 1503.80E 1510.25E 1516.66E 1522.96E 1529.35E 1535.58E 1541.60E Dogleg Deg/lOOft SURVEY LISTING Your ref Last revised 0.83 0.48 0.61 0.64 0.54 691. 30 714.74 737.97 761.17 783.84 . Vert Sect G RID Easting Page 2 MWD <0-7659> 13-Apr-2004 COO R D S Northing 2362040.23 2362039.58 2362039.13 2362039.11 2362039.22 2362039.24 2362039.20 2362039.22 2362039.33 2362039.59 2362040.23 2362040.86 2362040.86 2362040.40 2362039.95 2362039.50 2362038.80 2362037.97 2362037.08 2362036.09 2362035.00 2362033.95 2362032.95 2362032.28 2362031.97 2362031.72 2362031.83 2362032.34 2362033.13 2362034.36 2362035.55 2362036.20 2362036.63 2362037.16 2362037.77 2362038.57 2362039.37 2362040.14 2362041.55 2362042.37 2362042.98 2362043.47 2362043.96 2362044.50 2362044.97 2362045.32 2362045.65 2362046.09 2362046.54 2362046.86 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slott KBU11-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Bottom hole distance is 1637.26 on azimuth 88.83 degrees from wellhead. Vertical section is from wellhead on azimuth 88.88 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.63 0.19 0.32 0.79 0.65 806.88 829.66 851.98 873.99 895.58 0.65 1.05 2.90 0.78 0.34 917.02 938.37 960.42 984.50 1007.49 0.24 0.93 0.48 0.33 0.48 1029.95 1052.82 1075.59 1098.09 1120.39 0.47 0.66 0.20 1. 39 0.24 1143.40 1165.69 1188.50 1212.00 1235.44 0.79 2.02 1.26 1. 62 1. 50 1258.58 1280.90 1302.57 1323.01 1342.81 2.56 2.44 2.85 2.06 0.89 1360.98 1377.58 1392.73 1405.98 1418.06 1.43 0.49 0.32 1.12 2.66 1429.75 1440.43 1451.02 1468.01 1476.38 0.70 0.16 0.64 0.10 0.29 1483.49 1490.55 1497.34 1503.90 1510.36 0.17 0.17 0.28 0.19 0.65 1516.78 1523.09 1529.49 1535.73 1541. 76 275847.14 275870.58 275893.82 275917.01 275939.68 275962.72 275985.50 276007.82 276029.83 276051.42 276072.85 276094.20 276116.25 276140.34 276163.32 276185.78 276208.65 276231.42 276253.92 276276.22 276299.22 276321. 52 276344.33 276367.82 276391.27 276414.41 276436.72 276458.39 276478.84 276498.63 276516.79 276533.40 276548.55 276561.80 276573.88 276585.57 276596.25 276606.84 276623.83 276632.20 276639.30 276646.36 276653.15 276659.71 276666.17 276672 .59 276678.90 276685.30 276691.54 276697.57 . . MARATHON Oil Company SURVEY LISTING Page 3 Pad 41-7.KBUll-8X Your ref MWD <0-7659> Kena i Gas Field,Kenai Peninsula, Alas ka Last revised 13-Apr-2004 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C o 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 6402.00 5.30 84.70 6146.81 23.40N 1547.50E 0.23 1547.66 276703.47 2362047.21 6465.00 5.20 86.30 6209.54 23.85N l553.24E 0.28 1553.41 276709.22 2362047.56 6529.00 5.00 87.00 6273.29 24 . 1 9N 1558.92E 0.33 1559.10 276714.90 2362047.78 6592.00 4.80 84.20 6336.06 24.60N 1564.29E 0.49 1564.47 276720.28 2362048.09 6655.00 4.70 82.70 6398.84 25.l9N 1569.47E 0.25 1569.66 276725.47 2362048.58 6718.00 4.50 83.80 6461.64 25.78N 1574.49E 0.35 1574.69 276730.50 2362049.08 6782.00 4.50 82.00 6525.44 26.41N 1579.47E 0.22 1579.68 276735.49 2362049.60 6845.00 4.50 84.10 6588.25 27.00N 1584.37E 0.26 1584.60 276740.40 2362050.11 6909.00 4.30 85.70 6652.06 27.44N 1589.26E 0.37 1589.50 276745.30 2362050.45 6971.00 4.20 82.50 6713.89 27.91N 1593.83E 0.42 1594.07 276749.88 2362050.83 7035.00 4.20 84.50 6777.72 28.44N 1598.49E 0.23 1598.74 276754.54 2362051.27 7098.00 4.10 81.70 6840.55 28.99N 1603.01E 0.36 1603.27 276759.08 2362051.73 7161.00 3.90 80.20 6903.40 29.68N 1607.35E 0.36 1607.63 276763.43 2362052.34 7226.00 3.80 84.70 6968.25 30.25N 1611.68E 0.49 1611.96 276767.76 2362052.83 7289.00 3.60 80.90 7031.12 30.76N 1615.71E 0.50 1616.00 276771.80 2362053.26 7352.00 3.60 84.10 7094.00 31.28N 1619.63E 0.32 1619.93 276775.73 2362053.70 7415.00 3.40 84.90 7156.88 31. 64N 1623.46E 0.33 1623.76 276779.57 2362053.99 7478.00 3.10 80.50 7219.78 32.09N 1627.00E 0.62 1627.31 276783.12 2362054.37 7541.00 3.30 82.20 7282.68 32.62N 1630.47E 0.35 1630.80 276786.60 2362054.83 7604.00 3.10 83.70 7345.58 33.05N 1633.96E 0.34 1634.30 276790.10 2362055.20 7659.00 3.10 83.70 7400.50 33.38N 1636.92E 0.00 1637.26 276793.06 2362055.47 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot' KBU11-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Bottom hole distance is 1637.26 on azimuth 88.83 degrees from wellhead. Vertical section is from wellhead on azimuth 88.88 degrees. Grld is alaska - Zone 4.. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 41-7,KBUII-8X Kenai Gas Field,Kenai Peninsula, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 7659.00 7400.50 Top MD Top TVD Comments in well path -------------------- -------------------- Rectangular Coords. Comment . SURVEY LISTING Page 4 Your ref MWD <0-7659> Last revised : 13-Apr-2004 ----------------------------------------------------------------------------------------------------------- Rectangular Coords. Casing 0.00 0.00 0.00 0.00 0.00 0.00 Target name 33.38N 1636.92E Projection to TD 7.83S 15.30N 33.38N 13 3/8" Casing 9 5/8" Casing 3 1/2" Liner Casing positions in string lA' ------------------------------ ---- - -- --- - - - -- --- --- - --------- Rectangular Coords. Bot MD Bot TVD 105.69E 1459.70E 1636.92E Geographic Location T.V.D. Targets associated with this wellpath Rectangular Coordinates Revised KBUll-8X - Mid Belug 276600.000,2362054.000,999.00 KBUII-8X - TD - 2/9/ 276825.000,2362054.000,999.00 O.OON O.OON O.OON 1517.00 5590.00 7659.00 1506.50 5339.70 7400.50 O.OOE O.OOE O.OOE ------------------------------------- ------------------------------------- ----------------------------------------------------------------------------------------------------------- 28.19N 32.53N 1443.91E 1668.S8E 9-Feb-2004 9-Feb-2004 5360.00 7400.00 . . r·u -'._'--~-- -.----------.-.--.- ____·~·,_~_·__·_._..~~·_,,__.__,____·_,~_"_~_'__.n',.__._~__M~·.___._~m_._'_..__ "..-"--------.--------.------.- -".--~~----_.------,~-'-_._-_._~._---~~_.~-~-~--- ~legal Wall Nama: I Common Well Name: Event Name' Marathon Oil· Company Final Weill Event Summary Page 1 of 1 I DATE TMD 24 HOUR SUMMARY I 3/27/2004 134 (ft) Load out I move in rig up on KBU 11-8X I I 3/28/2004 134 (ft) Rig up, NU diverter, test, prepare for spud 3/29/2004 1,173 (ft) Test diverter, PU 5" DP, MU BHA, spud well, dril ahead 16" hole 3/3012004 1,517 (ft) TD csg pt at 1517 ft, eire, wiper trip, cìre, POH, RU I run 13 3/S csg, RIH inner string, space out, stab in, CIC mud. 3/31/2004 1,517 (ft) Cont CIC, cmt 13316 csg, N/D diverter, N/U BOPE 4/1/2004 1,537 (ft) Test BOPE, M/U BHA #2, P/U 5" DP, test csg, displace, circ for LOT 4/2/2004 2,SOO (ft) Repair Epoch, LOT, drill ahead 12 1/4 hole drctnl 4/3/2004 4,OSO (ft) Drlg To 300S',Cbu,Wiper trip, Service Rig,Rih Wiper Trip,Drlg. To 40S0' 4/4/2004 4,920 (ft) Dog. 12 1/4" Hole Directionally to 4920' 4/5/2004 5,500 (ft) Dog. 12 1/4" Hole DrcntJ to 5500' 4/6/2004 5,611 (ft) Do.g 12 1/4" drcntl. to 5611' lcìrc,lwiper trip,lcirclpooh for 9-518" csg. 4/7/2004 5,611 (ft) Rig Up To Run Csg.lRun Csg.lPrepare To em!. 4/S/2004 5,611 (ft) Cement 9 5/S" CSG. Inlall paekoff. Test BOPE. P/U 8.5" bit and BHA. P/U DP while RIH. Mix new flopro mud. RIH and TAG @ 5501'. Drill float collar. 4/9/2004 6,646 (ft) Drill out shoe tract and shoe. Clean old hole and Drill F/5611' to 5631'. CIO mud. Perform LOT. Drill F/5631 , to 6646'. Circ. shakers clean. 4/10/2004 7,659 (ft) POOH to shoe. Service rig. Repair rig. RIH. Drill F/6646' to 7659'. Circ. clean. Wait on Geologist decision. 4/11/2004 7,659 (ft) Circ. clean. POOH to CSG shoe. RIH. Circ. Clean. POOH(SLM). P/U Reeves DP conveyed tools. RIH. Cire. Deploy tools. POOH logging. 4/12/2004 7,659 (ft) Logging w/Reeves. UD logging tools. . ...n...... KENAI BELUGA UNIT 11-8X KENAI BELUGA UNIT 11-8X ORIGINAL DRILLING Start Date' 3/24/2004 End Date· 4/11/2004 Printed: 5/1712004 2:01:35 PM ·! API: 50-133-20536-00-00 RT-GL: 21' RT-THF: 21 ' 43'FSL,755'FEL,Sec.6,T4N, R11W, S.M. Tree CXll = 4-314" Otis ITOC (est.) - ???' Excane SYStem Details - BHP monitoring line volume tank located from 6286' - 6322' RKB Excane SYStem Details - Ceramic flapper valves below each module as follows: FlanDers MD (RKB): Module 1 - NA Module 2 - 7237' Module 3 - 7193' Module 4 - 7105' Module 5 - 6972' Module 6 - 6819' Module 7 - 6722' Module 8 - 6607' Module 9 - 6447' Module 10 - 6375' KBU 11-8X TD - 7659' PBTD - 7565' . (f!!!') I Drive Pipe: 20",133 ppf, K-55 to 134' Surface Casino: 13-3/8",68 ppf, K-55, BTC @ 1517' Cmt wI 417 sks of type 1 at 12 ppg Int. Casino: 9-5/8", 47 ppf, L-80, BTC @ 5590' Cmt wI 654 sks of class G at 13.5 ppg Prod. Tubino: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" OD control line protectors to 7602' Cmt wI 871 sks of class G at 15.8 ppg Excane SYStem Details - 10 Excape modules placed - Green control line fires bottom 2 modules - Red control line fires top 8 modules - Ceramic flapper valves below each module Perfs MD (OH Loa): Module 1 - 7370-7380' Module 2 - 7232-7242' Module 3 - 7189-7199' Module 4 - 7102-7112' Module 5 - 6970-6980' Module 6 - 6818-6828' Module 7 - 6722-6732' Module 8 - 6605-6615' Module 9 - 6443-6453' Module 10 - 6373-6383' Well Name & Number: KBU 11-8X I Lease: I Kenai Gas Field I County or Parish: Kenai I StatelProv. Alaska ICountry: IUSA Perforations (MD) (TVD) Angle/Perfs I Angle @ KOP and Depth BHP: I BHT: I I Completion Fluid: 6% KCL Dated Completed: 4/15/20041 Prepared By: J. R. Thompson I Last Revison Date: 5/19/2004 . . FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Willard J. Tank Senior Drilling Engineer Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Re: Kenai KBU 11-8X Marathon Oil Company Permit No: 204-035 Surface Location: 44' FSL, 755' FEL, SEC.6, T4N, R11 W, S.M. Bottomho1e Location: 77' FSL, 914' FWL, SEC. 5, T4N, R11 W, S.M. Dear Mr. Tank: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you :trom obtaining additional permits or approvals required by law :lÌ'om other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to . ess any required test. Contact the Commission's North Slope petroleum field ins ctor at - 07 (pager). S· ce BY ORDER 0r¡THE COMMISSION DATED tbis.ß::Jday of February, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . . \¡J6A- Z./~3/u;p£/ 1a. Type of Work: DrillW RedrillD 1 b. Current Well Class: ExploratoryD Development Oil D Multiple zoneW Re-entryD Stratigraphic TestD Service D Development GasW ,/ Single zoneD 2. Operator 5. Bond: WBlanket D Single wellD 11. Well Name and Number: Name: / Marathon Oil Company Bond No. 5194234 KBU 11-8X 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196168, Anchoraqe, AK 99519-6168 MD: 7,657' TVD: 7,400' , Kenai Gas Field / Beluga / 4a. Location of Well (Governmental Section): 7. Property Designation: A-028142 Surface: 44' FSL, 755' FEL, Sec. 6, T4N, R11W, S.M. 8. Land Use Permit: 13. Approximate Spud Date: Top of Prod uctive NIA 3/23/2004 Horizon: 72' FSL, 689' FWL, Sec. 5, T4N, R11W, S.M. 9. Acres in Property: 14. Distance to Nearest Property: Total DeDth: 77' FSL, 914' FWL, Sec. 5, T4N, R11W, S.M. 2,345 4,250' 4b. Location of Well (State Base Plane Coordinates): 10. KB elevation 15. Distance to Nearest Well within Pool: Surface: x- 275,155.87' y- 2,362,053.64' Zone- 4 (Height Above GL): 87 (21' above GL) feet 1,450' (KBU 44-6) 16. Deviated Wells: 17. Anticipated Pressure (see 20 MC 25.035) Kickoff Depth: 750 It. Maximum Hole Angle: 21.24 0 Max. Downhole Pressure: 6,573 psig. Max. Surface Pressure: 2,252 psig. 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f. or sacks. Hole Casino Weight Grade CouDling Length MD TVD MD TVD (Including Staae Data) Driven 20" 129# K-55 PE +1- 100' 0' 0' 100' 100' 16" 133/8" 68# K-55 BTC 1,479' 0' 0' 1,500' 1,491' + 1- 403 sks. 121/4" 95/8" 47# L-80 BTC 5,574' 0' 0' 5,595' 5,350' + I - 685 sks. 81/2" 3 1/2" 9.3# L-80 EUE 7,636' 0' 0' 7,657' 7,400' +/-961 sks. 19. PRESENT WELL CONDITION SUMMARY (to be completed for Redrill and Re-Entry Operations) Total Depth MD (It): Total Depth TVD (It.) Plugs (measured) Effective depth MD (It) Effective Depth TVD{It): Junk (measured) Casinq Length Size Cement Volume MD TVD .. :.JI..... ,- . 'L 'I .......,t ,,..._ ~~ .,. L " J r-,... , L.. [j "I ^ ,h Perforation Depth MD (It): Perforation Depth TVD (It): ~ðJ~,.. V (VUfI 20. Attachments: Filing FeeW BOP Sketch W Drilling programW Time v. Depth PlotD ~~ Property PlatW Diverter Sketch W Seabed ReportD Drilling Fluid Program W 20 MC 25.050 ReqUirementsD 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Willard J. Tank Title Senior Drilling Engineer Signature /h/~ I J/}~ C /J/x ~ Phone 907-564-6310 Date 2/20/2004 IV Commission Use Only i Permit to Drill ~ ' 05..tJ IAPI Number: 0 I Permit Approval (j jlli I(\ÿ I See cover letter for Number: 2¿J - 50- /;3> 3 - 2.0 S" .3 Date: f~ other requirements. DYes 1:81 No . DYes E NO Conditions of approval: Samples require Mud log required rýJ)~~' ulfi asu res DYes ~NO Directional survey required ~Yes DNO O,",,'T _ a P , ~ 2.':)l?O Piô.¡'. 0.. J?j t/ ;; L/- BY ORDER OF Approved I V ~ .-" COMMISSIONER THE COMMISSION Form 1~sed 3~~L/" - I ' (SUbmitln duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 . . MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM Kenai Gas Field KBU 11-8X Original 2/20/04 Originator: W.J. Tank 11)(: ) ,t. ' ./ /'.. .. ,-L."," ,¿"/ - / Drilling Superintendent: P.K. Berqa North America Drilling Manager: B.J. Roy Page 1 of 13 . . Table of Contents General Well Data............................................................................................................................. ......................................3 Geologic Program Summary........................................................................................................................ ...........................3 Summary of Potential Drilling Hazards......................................................................................................................... ......... ..4 Formation Evaluation Summary............................. .................................................................................................................4 Drilling Program Summary......................................................................................................................... .............................5 Casing Program....................................................................................................................... ................................................6 Casing Design........................................................................................................................ .................................................6 Maximum Anticipated Surface Pressure............................................................................................ .................. ...................6 BOP E Program....................................................................................................................... .................................................8 Wellhead Equipment Summary ............................................................. ...................................... ...........................................8 Directional Program Summary..... ........................................................................................................................................ ...9 Directional Surveying Summary.................................................................................... ........................................................ 1 0 Drilling Fluid Program Summary ................................ ................................................... ........................................................ 1 0 Drilling Fluid Specifications...................................................................................................................... ..............................10 Solids Control Equipment................................................................................................................... ...................................10 Cement Program Summary.......................................................................................................................... .........................11 Regu latory Waivers and Special Procedures.................................................................................................................... ....12 Bit Summary.................................................................................................................. ....... .................................................12 Hydraulics Summary........................................................................................................................... ..................................12 Formation Integrity Test Procedure......................................................................................................................... ..............13 Page 2 of 13 . . General Well Data Well Name KBU 11-8X LeaselLicense Surface Location 44' FSL, 755' FEL, Sec. 6, T4N, R11W, S.M. / WBS Code DD.03.09596.CAP.DRL Slot/Pad Pad 41-7 Field Kenai Gas Field Spud Date 3/23/04 (est.) KB Elev. 87 County/Province Kenai Peninsula API No. Ground Level Elev. 66 State I Country Alaska Well Class Development Perm. Datum KB Total MD 7,657' Rig Contractor Glacier Drilling Water Depth NIA Total TVD 7,400' Rig Name #1 Water Protection Depth Comments: Geoloaic Proaram Summary MD - RKB TVD - RKB Pore Pressure Pore Pressure Possible Fluid Formation (ft) (ft) (psi) (ppg) Lithology Content Sterling (Not a Prod Target) 3,649 3,500 1.0 Sandstone Gas / Water Beluga (Not a Prod Target) 4,960 4,727 1.5 Sandstone Gas Middle Beluga (Primary Target) 5,605 5,360 3.80 / Sandstone Gas Tyonek (Not a Prod Target) 7,484 7,227 9.00 I Coal, Silt, Shale Gas Comments: From Lease/Block Lines Latitude Longitude Surface Location Coordinates 44' FSL, 755' FEL, Sec. 6, T4N, R11W, S.M. 600 27' 34.649" 151014' 44.100" 2,362,053.64' 275,155.87' Horizontal Døpth Di§plaçernønt (ft) MD TVD +N/-S +EbW Tolerance Directionéll l"élrget (ft) (ft) Location (Y) (X) (ft) Middle Beluga 5,605 5,360 72' FSL, 689' FWL, Sec. 5, T4N, R11W, S.M. / 28 1 ,444 Circle 250' radius TD 7,657 7,400 77' FSL, 914' FWL, Sec. 5, T4N, R11W, S.M. /" 33 1,669 Circle 250' radius Comments: Page 3 of 13 . . Summary of Potential Drilling Hazards Hazard Evént Lost Circulation in Low Pressure Sterling and Beluga sands Discussion Control losses by using sufficiently sized LCM. Comments: Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No HzS is anticipated. /. Gas sands will be encountered from +/- 3,649' MD (3,500' TVD) to total depth of the well. These sands will run from normal pressured to highly depleted and lost circulation and differential sticking are potential hazards. The Flo-Pro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. Formation Evaluation Summary Interval LWD Electric Logs Mud Logs Surface None None None 0' - 1,500' MD Intermediate None None Basic with GCA, shale density, temperature in and out, 1,500' - 5,595' MD sample collection (10' samples). Production None Quad Combo, RFT. Pull GR-Neutron to Basic with GCA, shale density, temperature in and out, 5,595' - 7,657' MD surface inside casing. sample collection (10' samples). Completion N/A GR, CCL N/A Coring Requirements: None Comments: Page 4 of 13 . . Drillina Proaram Summary CONDUCTOR: 1. 2. 3. 4. 5. Drive 20" conductor to +1-100 ft. RKB. Move in and rig up rotary drilling rig. Install starting head 20" SLC x 21 1/4", 2M flanged. /' Nipple up 21 1/4", 2M diverter, 16" diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: 1. 2. Drill a 16" hole to 1,500' MD (1,491' TVD) per the directional plan. RIH with 13 3/8" casing and hang off in the elevators. Make up stab-in sub and centralizer on 5" drill pipe. TIH with inner string and latch into stab-in float collar. Cement 13 3/8" casing. Sting out, shear out drill pipe wiper plug, and circulate drill pipe. TOOH with inner string. Cut off 13 3/8" casing. ND diverter. Install 13 3/8" slip lock connection X 13 5/8" 5M flanged multibowl wellhead./ NU 135/8" 5M BOP'S. Test BOP'S and choke manifold to 250/2,500 psi. Set wear bushing. Test surface casing to 2,000 psi. 3. 4. 5. 6. 7. INTERMEDIATE: 1. 2. 3. 4. 5. 6. 7. Drill out float equipment and 20' of new formation wI 12 1/4" bit. CBU. Test shoe to leak off. Estimated EMW is 13.0 ppg. Drill 12 1/4" directional hole to 5,595' MD (5,350' TVD) as per directional program, short tripping every 1,000' or 24 hours. At TD circulate hole clean. Make wiper trip. TOOH. Change out variable pipe rams with 9 5/8" casing rams. Run test plug and test casing rams to 2,500 psi. .../' Run and cement 9 5/8" casing. Land hanger in multibowl wellhead. / Back out landing joint. Change out 9 5/8" casing rams with variable pipe rams. Run test plug and test pipe rams to 250/2,500 psi. Set wear bushing. Test casing to 2,000 psi. 8. PRODUCTION: 1. 2. 3. 4. 5. 6. 7. Drill float equipment and 20' of new formation w/8 1/2" bit. CBU. Test shoe to leak off. Estimated EMW 14.7 ppg. Drill a 8 1/2" hole to 7,657' MD (7,400' TVD) per the directional program, short tripping every 1,000' or 24 hours. / At TD circulate hole clean. Make wiper trip. TOOH. RU logging company. Run open hole logs as per plan. RD logging company. TIH to TD for wiper trip. TOOH and laydown BHA and drill pipe. Pull wear bushing. RU and run 3 1/2" EXCAPE casing string. RU logging company to correlate EXCAPE modules to open hole logs. RD logging company. Cement 3 1/2" casing while reciprocating. Bump plug with 500 psi over displacement pressure. WOC. PU 3 1/2" casing. PU BOP stack. Run control and electric lines out tubing head outlet. Set slips. Cut 3 1/2" casing. LD BOP. Set 31/2" packoff. NU 135/8" 5M X 31/8" 5M tubing head adapter and 31/8" 5M tree. Test tree to 5,000 psi. Rig down and move out drilling rig. / 8. 9. 10. 11. Note: Drill all hole sections with 5" drillpipe. Perforating guns will be run on the outside of the 3 1/2" production casing with a flapper valve just below each perforating gun. Guns to be activated by control line to surface. COMPLETION: Completion will be done without a rig. / Page 5 of 13 . . Casing Program MD (ft) Connection API Ratings Q) r::: Casing Makeup - ~'::::- 0 (j) / ~ ëi) (\ C/) .¡¡¡ a. Size Weight / O.D. Torque Hole Size :;¡ ..9: =..9: r::: g [D 0 Q) (in) Top Bottom (Ibslft) Grade Type (in) (ft-Ibs) (in) Ü I- 13 3/8 Surface 1,500 68 K-55 BTC 14.375 N/A * 16 3,450 1,950 1,300 95/8 Surface 5,595 47 L-80 BTC 10.625 NIA * 12 1/4 6,870 4,750 1,161 3Y2 Surface 7,657 9.3 L-80 8rd 4.5 3,200 81/2 10,160 10,530 207 Comments: . The make up of the buttress connection will be to the proper mark. Casing Design Casing Shoe Safety Factors Q) r::: Casing Setting Mud Wt Frac. Form Maximum Surface C/) a. 0 - .!J! .¡¡¡ Size vveight Depth When Set Grad Press Pressure ~ 0 r::: :;¡ Q) (in) (Ibltt) Grade (TVD) (Ib/gal) (Ib/gal) (Ib/gal) (psi) [D Ü I- 13 3/8 68 K-55 1,491 9.2 13.0 8.4 898 2.21 2.13 3.51 95/8 47 L-80 5,350 9.6 14.7 3.8 2,252 1.88 1.51 3.22 31/2 9.3 L-80 7,400 11.0 15.0 10.5 2,252 1.20 2.14 1.60 Comments: Maximum Anticipated Surface Pressure Settil1g pepth CasiMgSize TVD MAWP* MASP** ..,'" mu (in) (ft) (psi) (psi) Ratio 13 3/8 1,491 2,345 898 30170 95/8 5,350 4,698 2,252 / 30170 3 112 7,400 6,573 2,252 / 30170 . MAWP = Maximum allowable working pressure *. MASP = Maximum anticipated surface pressure Comments: MASP I MAWP CALCULATIONS: Surface casinq: 133/8" (1,500' MD, 1,491' TVD) MASPfrac = ((Fracture gradient at shoe + S.F.) x .052 X TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (13.0 ppg + 0.5 ppg) x .052 x 1,491' - (.1 psi/tt x 1,491 ') MASPfrac = 1,047 psi - 149 psi MASPfrac = 898 psi. Page 6 of 13 . . MASPbhp = BHPopen hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (3.8 ppg x .052 x 5,350') - (0.3 x 9.6 ppg x .052 x 5,350') - (0.7 x 0.1 psilft x 5,350') MASPbhp = 1,057 psi - 801 psi - 375 psi MASPbhp = 0 psi MASP = MASPfrac = 898 psi (Do not use MASPbhp, use the more conservative MASPfrac.) MAWP = (0.7 x Casing Burst) - (Mud WI. - Backup Fluid WI.) x .052 x TVD MAWP = (0.7 x 3,450) - (9.2 - 8.3) x .052 x 1,491' MAWP = 2,415 psi - 70 psi = 2,345 psi Intermediate casinq: 95/8" (5.595' MD, 5,350' TVD) MASPfrac = «(Fracture gradient at shoe + S.F.) x .052 X TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (14.7 ppg + 0.5 ppg) x .052 x 5,350' - (.1 psi/ft x 5,350') MASPfrac = 4,229 psi - 535 psi MASPfrac = 3,694 psi. MASPbhp = BHPopen hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (10.5 ppg x .052 x 7,400') - (0.3 x 11.0 ppg x .052 x 7,400') - (0.7 x 0.1 psi/ft x 7,400') MASPbhp = 4,040 psi - 1,270 psi - 518 psi MASPbhp = 2,252 psi MASP = MASPbhp = 2,252 psi /' MAWP = (0.7 x Casing Burst) - (Mud WI. - Backup Fluid WI.) x .052 x TVD MAWP = (0.7 x 6,870) - (9.6 - 9.2) x .052 x 5,350' MAWP = 4,809 psi - 111 psi = 4,698 psi Production casinq: 3 1/2" (7,657' MD. 7.400' TVD) MASPfrac = «Fracture gradient at shoe + S.F.) x .052 X TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (15.0 ppg + 0.5 ppg) x .052 x 7,400' - (.1 psi/ft x 7,400') MASPfrac = 5,964 psi - 740 psi MASPfrac = 5,224 psi. MASPbhp = BHPopen hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (10.5 ppg x .052 x 7,400') - (0.3 x 11.0 ppg x .052 X 7,400') - (0.7 x 0.1 psilft x 7,400') MASPbhp = 4,040 psi - ~?O psi - 518 psi MASPbhp = 2,252 psi MASP = MASPbhp = 2,252 psi MAWP = (0.7 x Casing Burst) - (Mud WI. - Backup Fluid WI.) x .052 x TVD MAWP = (0.7 x 10,160) - (11.0 - 9.6) x .052 x 7,400' MAWP = 7,112 psi - 539 psi = 6,573 psi Page 7 of 13 . . BOPE Program Casing Test Test Casing Test Fluid Pressure Size MAWP MASP Press Density BOPS Low/High Casing (in) (psi) (psi) (psi) (Ib/gal) Size & Rating (psi) (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram Surface 13 3/8 2,345 898 2,000 9.2 (1) 135/8" 5M blind ram 250/2,500 / (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram Intermediate 95/8 4,698 2,252 2,000 9.6 (1) 135/8" 5M blind ram 250/2,500 (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets (1) 13-5/8" 5M annular (1) 13-518" 5M pipe ram / Production 31/2 6,573 2,252 2,000 10.0 (1) 135/8" 5M blind ram 250/2,500 (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets / Comments: Blowout Preventers The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top and a 13-518" x5000 psi drilling spool (mud cross) with 3-118" x 5000 psi outlets. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Casing Test Pressures Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Wellhead Equipment Summary Component Description Casing Hanger Type Casing Head 13-5/8" 3M X 13-3/8" Slip Loc W/2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL 1, 13 5/8" x 9 5/8" Fluted PR1 Mandrel Tubing Head 13-5/8" 3M Studded Bottom X 13-5/8" 5M Fig Top, W/2, 2-1116" 5M Studded Outlets, 135/8" x 31/2" Manual U,AA,PSL 1 ,PR1 Slip Adapter Flange 13-5/8" 5M X 3-118" 5M WI Seal Pocket and 3" H BPV Threads Comments: Control lines and electric cable for the EXCAPE system will be routed through the tubing head side outlet. Page 8 of 13 . Directional Proaram Summary . Build Turn Coordinates Sec. MD TVD Rate Rate Dogleg Inclination Azimuth +N/-S +E/-W VS No. Description (ft) (ft) (°/100') (°/100') ("/100') (deg) (deg) (ft) (ft) (ft) 1 Tie On 0 0 0 0 0 0 0 0 0 0 2 KOP 750 750 0 0 0 0 88.88 0 0 0 3 Build up Section 2.0 0 2.0 88.88 4 End of Build 1,811.80 1,787.66 2.0 0 2.0 21.24 88.88 3.80 194.49 194.53 5 Hold Section 0 0 0 21.24 88.88 6 End of Hold 4,609.39 4,395.28 0 0 0 21.24 88.88 23.59 1,207.62 1,207.85 7 Drop Section -1.5 0 1.5 88.88 8 End of Drop to the 5,605.46 5,360.00 -1.5 0 1.5 0 88.88 28.19 1,443.91 1,444.19 Target 9 TD 7,657.83 7,400.00 0 0 0 0 88.88 32.53 1,668.88 1,669.20 Comments: Potential Well Interference: Vertical section calculated from a reference azimuth of 88.88° taken from surface location to bottom hole location. Well KU 43-6RD KBU 44-6 KU 13-5 KTU 32-7 KU 43-6A Distance (ft) 49.8 54.8 63.3 83.2 97.7 Depth (MD) 1,175 1 ,400 1 ,488 500 1 ,488 / No serious interference exists. See attached directional plan and anticollision analysis for more details. " " ~ ~ 0 0 0 0 0 ~ '" .s +' e- o ~ ';;¡ 0 <..> ~ 'E " ~ > 2 0 E- <IJ -3000 -2000 -1000 0 1000 2000 3000 4000 5000 Vertical Section at 88.88° [3000ft/in] Page 9 of 13 West(-)lEast(+) [1500ft/in] . . Directional Survevina Summary Interval MWD Survey Magnetic Multishot Gyro Multishot Comments 0-1,500' X 1,500' - 5,595' X 5,595' - 7,657' X Comments: Drillina Fluid Proaram Summary Interval- TVD Minimum Inventory From To Density Gel (ft) (ft) (Ib/gal) Fluid Description Additives Viscosifier Barite 0 1,491 8.6 - 9.4 Gel I Gelex Spud Mud Gel, Gelex, Soda Ash, Caustic, Barite, Polypac Supreme UL Flo-Vis, PoluPac UL, KCI, SafeCarb 1,491 5,350 9.0 - 9.6 6% Flo-Pro wI Safecarb F&M, Ashphasol Supreme, Lubetex, ~ Caustic, Conqor 404, SafeScav NA 92~ Flo-Vis, DualFlo, KCI, Greencide 25G, 5,350 7,400 6% Flo-Pro wI Safecarb SafeCarb F, KlaGard, Barite, Caustic, Conqor 404, SafeScav NA Comments: See mud prognosis for details. Sized CaC03 (SafeCarb) will be used to controlleakoff into the low pressure zones. Drillina Fluid Specifications Interval - TVD LSRV From To pensity Vis 1 min PV YP Fluid Loss (ft) (ft) (Ib/gal) (seclqt) (lb.l100tf) (cP) ..0. (cc) pH ('x,) \IUf IVVIL 0 1,491 8.6 - 9.4 60 - 100 25 - 35 NC- 12 +1- 9.5 <7 1,491 5,350 9.0 - 9.6 40,000 8- 14 7 - 10 < 9.5 +1- 5 5,350 7,400 9.2 - 10.0+ / 40,000 10 - 14 <5 +1- 9.5 +1- 5 Comments: Solids Control Equipment c: .Q Q) CD CD t5 e> ~ Q) ro c: Q) 0 E .c CD ro u Q) 0) en en en CD -c ~ Ü .2 0) 0) 0 c: ï::: c: c: ..>:: ro ,jj -c ë :¡::¡ :¡::¡ 0 ro en :; :; CD .c Q) Q) :J Q) Interval C/) 0 0 :2: Ü Ü Ü N Comments 0- 7,657' MD X X X X Closed Loop System, Full Containment Page 10 of 13 . . Equipment Specifications Item (quantity, design type, brand, model, flow capacity, etc) Shaker 2 - Derrick Model 2E48-90F-3TA Desander NIA Desilter 1 - Derrick Model 0522 Mud Cleaner NIA Centrifuge 2 - MllSwaco units Cuttings Dryer NIA Cuttings Injection Marathon G&I Facility Zero Di$charge NIA Comments: The solids control equipment will consist of two flowline cleaners, a desilter, and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. Cement Program Summary Depth Gauge Top of Cement Open Casing Hole Ann Vol Slurry WOC Hole Size MD TVD Size MD TVD To TOC Vol Time Excess (in) (ft) (ft) (in) (ft) (ft) (ft3) (ft3) (hrs) (%) 13 3/8 1,500 1,491 16 0 / 0 683 1,011 8 50 95/8 5,595 5,350 12 1/4 3,1001, 2,988 781 1,206 8 50 31/2 7,657 7,400 81/2 5,300 I 5,058 / 776 1,115 NIA 50 Mix Water Comþressive Casing Slurry roc Strength Size Density Qty Yield Vol MD Qty WL FW (Psi) (in) Slurry Cement Description (lb/g~1) (sx) (fP Isx) (ft3) (ft) (gal/sx) Type (cc) (%) 8 hr 24 hr Lead 13 3/8 Tail Type I Cement 12 403 2.51 1,011 0 11.28 Fresh 526 0 196 818 Lead 95/8 685"" Tail Class "G" 13.5 1.76 1,206 3,100 8.35 Fresh 10 0 60 820 Lead /" 3 1/2 961 / Tail Class "G" 15.7 1.16 1,115 5,300 4.92 Fresh 24 0 500+ 2,632 Comments: See cement prognosis for details and spacer specifications. Page 11 of 13 . . Regulatorv Waivers and Special Procedures AOGCC Regulation 20 ACC 25.035 (e) (1) (b) Requirement for 2 pipe rams, one blind ram, and one annular for a API 5K or above BOP stack. Marathon is requesting a waiver from the above regulation for KBU 11-8X. We are requesting that the BOP stack be 'Y..- configured with one pipe ram instead of two, due to rig height restrictions in the running of the 3 1/2" production casing. f'\ The height restriction involves having rig crew members routing control line and electrical line through one of the tubing head outlets after the 3 1/2" casing is cemented and the BOP stack is picked up. This is prior to setting the casing on slips and cutting the casing sticking up. These lines control firing of the perforating guns and the monitoring of downhole pressure and temperature in our EXCAPE completion system. Similar waivers have been requested for EXCAPE completion wells in both the Kenai Gas Field and Beaver Creek Field and were granted. No problems were encountered while doing this operation on any of the wells. Also due to MASP below 2,500 psi, only a 3,000 psi BOP stack would be required for this work if it was economic to change out BOP sta~ for this well. If a 3,000 psi BOP stack was used then no waiver would be necessary. Utilizing the 13 5/8" 5M stack currently found on the Glacier Drilling #1 rig is more than sufficient for pressures to be encouf1ter.ed. ~. (!Ç..'Av1 ' , NO ~cu.~t {)'r'l~~ ~ 1~OO fÇ(· Bit Summary 'ßO\>t; r Interval - MD Type Recommended Estimated From To Size WOB Rotating ROP (ft) (ft) (in) Manufacturer Model No. IADC (kips) RPM Hours (ftlhr) 0 1,500 16 Christensen MX-1 115 1 - 4 80 - 350 1,500 5,595 121/4 Christensen HCM-406 M333 Up to 50 Motor 5,595 7,657 81/2 Christensen HCM605 M323 Up to 25 Motor Comments: If a second bit is necessary for the 12 Yo" hole a MX-C3 (IADC 137) should be used to finish this section. Back up bits for the 8 W' hole section will consist of mill tooth and TCI tricone bits. See bit prognosis for additional information. Hvdraulics Summary Rig mud pumps available are shown below. Max press @ Displacement @ Liner ID Stroke 90% WP 95% eft Max Rate Hole Sections Used Qty Make Model (in) (in) (psi) (gal/stroke) (spm/gpm) On 5 8 2,597 2.04 125/255 Surface National Oil 3 A600PT 5 8 2,597 2.04 125/255 Intermediate Well 5 8 2,597 2.04 125/255 Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Page 12 of 13 . . Höle Standpipe Min Nozzle Depth-MD Size Pump Rate Pressure AV ECD Size (ft) (in) (gpm) (psi) (fpm) (Ib/gal) (32"s) Remarks o - 1,500 3 - 18's Actual Data from CLU #8 16 662 1,700 70 1 - 15 1,500 - 5,595 121/4 662 2,000 130 6 - 13's Actual Data from CLU #8 5,595 - 7,657 81/2 585 2,100 303 5 - 15's Actual Data from CLU #8 Comments: See separate hydraulics calculations. 5" drillpipe will be used for all 3 hole sections. Formation Intearitv Test Procedure / Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Page 13 of 13 121 1/4" 2M Diverter 1---. I Diverter Spool . '. Marathon Oil Well KBU 11-8X Diverter I Flow line I ~ / 116" Automatic ~I = ~ \ L- I I 116" Diverter Line I Knife Valve 1,/ / ITO Gas Buster c ~ t 2 9/16" 10M Swaco Hydraulically Operated Choke . Marathon Oil Well KBU 11-8X Choke Manifold / 13" 5M Valves I From BOP Stack . Bleed off Line to Shakers i 3 1/8" 5M Manually Adjustable Choke . . Marathon Oil Well KBU 11-8X BOP Stack I Flow Nipple I ------. I Flow Line I 13 5/8" 5M Annular Preventer ./ . 13 5/8" 5M Double Ram Preventer Pipe Ram I ./ -------. 21/16" 5M Manually Operated Valves IBlind Ram I / 3 1/8" 5M Manually Operated Valve ~~ [[[]]III0I1JOIIillJ ŒÐ 1135/8"5MCross I ~ Jt' IChoke I ITI0IIJ0IIillJ t 3 1/8" 5M Hydraulically Operated Valve 135/8" 5M x 13 5/8" 5M Drilling Spool ~ Bottom of mud cross must be 24-45" from ground level for Glacier 1 rig placement. 113 5/8" 5M Tubing Head Flange . . Surface Use Plan for Kenai Beluga Unit, well KBU 11-8X Surface location: Anticipated at 44' FSL, 755' FEL, Sec. 6, T4N, R11W, S.M. 1) Existing Roads Existing roads which will be used for access to KBU 11-8X are shown on the attached map. Kenai, Alaska is the nearest town to the site and is also shown on the map. 2) Access Roads to be Constructed or Reconstructed No new roads will be required to access KBU 11-8X. 3) Location of existing wells Well KBU 11-8X will be drilled on Kenai Gas Field (KGF) pad 41-7. A pad drawing is enclosed that shows existing wells and the proposed location of KBU 11-8X. 4) Location of existing andlor proposed facilities The locations of existing production facilities in the KGF pad 41-7 are shown on the enclosed pad drawing. A flowline will be installed from the KBU 11-8X wellhead to an existing heater and separator. 5) Location of Water Supply A water supply well exists on the pad that KBU 11-8X will be drilled from. This is shown on the pad drawing. 6) Construction Materials No construction is planned on the pad. The recent pad expansion has already been completed and is sufficient. 7) Methods of handling waste disposal; a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals . . Unused chemicals will be returned to the vendors that provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8) Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9) Plans for reclamation of the surface KBU 11-8X will be drilled from an existing pad. Reclamation of the pad will occur after the abandonment of KBU 11-8X and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from CIRI Native Corporation prior to any reclamation work beginning. 10) Surface ownership The surface owner of the land in the Kenai Beluga Unit is the CIRI Native Corporation. 11) Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. ... l. / Date: Zjzo/öd Name and Ti:le: ;1Þ~0f' ~~Je~ Willard J. Tank,t7Senior Drilling Engineer Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6319 . . KGF PAD 41-7 WELL K.B.U. 11-8X SURFACE LOCATION DIAGRAM NOTES 1. BASIS OF COORDINATES IS U.S.C & G.S. TRJ STATION AUDRY IN A.S,P. ZONE 4. (NAD 27) AVERAGE CONVERGENCE OF POINTS SHOWN; 01·05'03", 2. BASIS OF ELEVATION IS MEAN SEALEVEl. 3. MOST RECENT FIELD WORK CONDUCTED DURING DEC 2003 4. EAST BOUNDARY LINE OF SECTION 71S NOT SHOWN IN Irs TRUE POSITION. ---- ---- SETTLEMENT PIPE NO. . K.B.U. 11-8X ASP ZONE 4 NAD27 N: 2362053.64 E: 275155.87 LA T: 60"27'34.649" LONG: -151"14'44.100" FEl ; 754.7' FSl ; 43.5' ElEV ; 66.1' (MSl) SECTION 6, TOWNSHIP 04N RANGE 11 W, SM AK 43.5' FSl ---- l -- -- .B,U.24-6H 6' CIA WELL SILO . 2351975.~¡8 .275073.31 K.B.UA4-6 16' D!A. WELl SlI..O N: 2361867.24 E: 27519<\ K.8.U. 32-7 DJA. WELL. S i 0 N: E PAD 41-7 KENAI GAS FIELD K,T.U. 32-7H 16' DIA. SILO N E: 275232.75 K,ß,U,417 ì'-i: 2361808.64 E' DRAWN BY: CRM ........,"\\\\'1, .:-;..!If.'~~~" :/J," *",,&',; f~.{··~··""'·"'·:'~·§ %~~71j "'Ih\~"""''''''' Consulting <:;"roup Testing CHECKED BY: MSM HORZ. SCALE: 1 ~ "" 50' ~ SCALE 50 I FEET CONTROL POiNT 981 2" "'LCAP N 2362222.02 E ~ 275294.41 ELEV. :::0 64.26 ì \ \ \ \ \ \ I I I \ t- \ \ \ \ -(~ \ \ \ \ \ DISTANCE NOT TO SCALE 754.7' FEl SECTION LINE --- -- 100 I , I I I wi ~I ~I I I I I I t L 5 I 8 I I I I I , I I I 6 7 0M~ MARATHON OIL COMPANY KGF PAD 41-7 MARATHON ~ WELL K.B.U. 11-8X . SHEET: of ENGINEERING!M APPING /SURVEYlNG /TESTING P.O. BOX 468 SOLDOTNA, AK. 99669 VOICE; (907) 283-4218 FAX: (907) 283-3265 EMAlL: somclaneOmclonecg.com DATE: 2/12/04 rlELD BOOK NO. 03-02 VERT. SCALE: N/A JOB NO. 033095 Source Map: IJSGS, 1951 Kenai, Ala$KS 9-4, 1 :63,360 163360 Marathon Oil Company Kenai Gas Pad 4 J - 7 Area KEU 11-8X . . F I 1 r-----' I I I l..________ lu~¡ I UNIT I I I 4' X 111' I I I I I I I I , I r I I I I JIlI4f' I I t t-\ (I 1 ..." I t ,,--..., I 11,~r\ L_____.J I~ ! ,..__,1 ~-----i ~-----1~ r , L__.J " 1 I I r--' q I I r I II r : :! !! ! I III: I I I .. I t Iw I J II I I I II 1 I I I 11 I I I I I II I I !IS I I II I B I I II I r1-====d--,L-----.J I ,.,.., I I ! -\J ....,J! ! I.. ICDIJoIY 3' X 12' j 1\ t I I 75... 6X5 n" -- ~ .~ ... ,.... 75JP 6X5 11' ~ \. 75HP , X ::! U" I~I GLACIER DRILLING RIG #1 / MUD PITS AND PUMP ROOM LAYOUT .... íì. 5\1 9L 11-600 PT 15 If' 6 X :! 11" I I - !l I.::. I ---, ~ I ~ j m.~ I œ !-.~ ! 13'.... 5W 91.. 11-600 PT ,.. 8 r ..... '\ ~~ .~~ r-;-¡¡ï ~ . ... P&.L PIT 400 0 400 800 1200 1600 2000 2400 ,.-... -+- Q) Q) 2800 '+- '--" ...s::: -+- 3200 Q.. Q) 0 0 3600 Ü -+- !.... Q) 4000 > Q) :J 4400 !.... ~ I V 4800 5200 5500 6000 6400 6800 7200 7600 . . Structure: Pad 41-7 I Company I Well: KBU11-8X I Location: Kenai Peninsula, Aid / I MARATHON Oil Field : Kenai Gas Field East (feet) -> o 1000 1200 1400 1600 1800 2000 200 400 600 800 0.00 KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 ft 8.00 10.00 12.00 14.00 16.00 18.00 21.24 End of Build 88.88 AZ 200 200 o / ^,-<0 TANGENT ANGLE 21.24 DEG / 9:;+ ,,-/ :0"- +-<0 88.88 DEG A IMUTH 1669' TO TARGET/TD 21.24 18..36 16.88 15.38 13.88 12.38 10.88 9.38 7.88 End of Drop 6.29 ***Plone of Proposol*** DLS: 1.50 deg per 1 DO ft , KBU 11-8X ~ Mid Beluga - 2/9/04 TRUE TARGET ANGLE 6.29 DEG Crected by bm,ehael Date plotted: 11-Feb-2004 Plot Reference ióõ KBU 11-8X Ver .3, KBU11-8X - TO ~ 2/9/04 Coordìnotes ore În feet reference slot# KBUJ 1-8X. True VerlÎçol Depths ore reference RK8 (Glader 1). f&ii. BAKER HUG_ TNTEQ 400 o 400 800 1200 1600 2000 Vertical Section (feet) -> Azimuth 88.88 with reference 0.00 N, 0.00 E from slot# KBU11-8X . . MARATHON Oil Company Pad 41-7 KBU11-8X slot# KBU11-8X Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KBU 11-8X Ver 3 prop5612 Date printed Date created Last revised 11-Feb-2004 9-Feb-2004 11- Feb- 2 0 0 4 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on 270916.030,2362063.980,999.00000,N Slot location is n60 27 34.707,w151 14 44.257 Slot Grid coordinates are N 2362053.640, E 275155.869 Slot local coordinates are 71.37 N 4239.42 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . . MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Feb-2004 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 88.88 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 88.88 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 88.88 300.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 88.88 400.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 88.88 500.00 0.00 N 0.00 E 0.00 0.00 600.00 0.00 88.88 600.00 0.00 N 0.00 E 0.00 0.00 700.00 0.00 88.88 700.00 0.00 N 0.00 E 0.00 0.00 750.00 0.00 88.88 750.00 0.00 N 0.00 E 0.00 0.00 850.00 2.00 88.88 849.98 0.03 N 1. 74 E 2.00 1. 75 950.00 4.00 88.88 949.84 0.14 N 6.98 E 2.00 6.98 1050.00 6.00 88.88 1049.45 0.31 N 15.69 E 2.00 15.69 1150.00 8.00 88.88 1148.70 0.54 N 27.87 E 2.00 27.88 1250.00 10.00 88.88 1247.47 0.85 N 43.51 E 2.00 43.52 1350.00 12.00 88.88 1345.62 1.22 N 62.59 E 2.00 62.60 1450.00 14.00 88.88 1443.06 1. 66 N 85.08 E 2.00 85.10 1550.00 16.00 88.88 1539.64 2.17 N 110.96 E 2.00 110.98 1650.00 18.00 88.88 1635.27 2.74 N 140.19 E 2.00 140.21 1750.00 20.00 88.88 1729.82 3.37 N 172.73 E 2.00 172.77 1811.80 21.24 88.88 1787.66 3.80 N 194.49 E 2.00 194.53 2000.00 21.24 88.88 1963.08 5.13 N 262.65 E 0.00 262 .70 2500.00 21.24 88.88 2429.12 8.67 N 443.72 E 0.00 443.80 3000.00 21.24 88.88 2895.17 12.20 N 624.79 E 0.00 624.91 3500.00 21.24 88.88 3361. 22 15.74 N 805.86 E 0.00 806.01 4000.00 21.24 88.88 3827.27 19.28 N 986.93 E 0.00 987.12 4500.00 21. 24 88.88 4293.32 22.81 N 1168.00 E 0.00 1168.22 4609.39 21.24 88.88 4395.28 23.59 N 1207.62 E 0.00 1207.85 4700.00 19.88 88.88 4480.12 24.21 N 1239.43 E 1.50 1239.66 4800.00 18.38 88.88 4574.59 24.85 N 1272 .18 E 1. 50 1272.43 4900.00 16.88 88.88 4669.90 25.44 N 1302.46 E 1.50 1302.71 5000.00 15.38 88.88 4765.96 25.98 N 1330.23 E 1.50 1330.48 5100.00 13.88 88.88 4862.72 26.47 N 1355.48 E 1. 50 1355.73 5200.00 12.38 88.89 4960.10 26.91 N 1378.18 E 1.50 1378.45 5300.00 10.88 88.89 5058.04 27.31 N 1398.33 E 1.50 1398.60 5400.00 9.38 88.89 5156.48 27.65 N 1415.91 E 1.50 1416.18 5500.00 7.88 88.89 5255.35 27.94 N 1430.91 E 1.50 1431.18 5600.00 6.38 88.90 5354.57 28.18 N 1443.31 E 1.50 1443.59 5605.46 6.29 88.90 5360.00 28.19 N 1443.91 E 1. 50 1444.19 KBUl1-8X - Mid Beluga - 2/9/04 7657.83 6.29 88.90 7400.00 32.53 N 1668.88 E 0.00 1669.20 KBUll- 8X - TD - 2/9/04 All data is in feet unless otherwise stated. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Bottom hole distance is 1669.20 on azimuth 88.88 degrees from wellhead. Total Dogleg for we11path is 36.18 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company Pad 41-7,KBUII-8X Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref KBU 11-8X Ver 3 Last revised : II-Feb-2004 Comments in wellpath -------------------- -~------------------ MD TVD Rectangular Coords. Comment --------------------------------------------------------------------------------------------------------- 5605.46 7657.83 5360.00 7400.00 28.19 N 32.53 N 1443.91 E 1668.88 E KBUII-8X - Mid Beluga - 2/9/04 KBUII-8X - TD - 2/9/04 Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised --------------------------------------------------------------------------------------------------------- KBUII-8X - Mid Belug 276600.000,2362054.000,999.00 KBUl1-8X - TD - 2/9/ 276825.000,2362054.000,999.00 5360.00 7400.00 28.19N 32.53N 1443.91E 1668.88E 9-Feb-2004 9-Feb-2004 . . MARATHON Oil Company Pad 41-7 KBUll-8X slot# KBUll-8X Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KBU 11-8X Ver 3 prop5612 Date printed Date created Last revised ll-Feb-2004 9-Feb-2004 ll-Feb-2004 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on 270916.030,2362063.980,999.00000,N Slot location is n60 27 34.707,w151 14 44.257 Slot Grid coordinates are N 2362053.640, E 275155.869 Slot local coordinates are 71.37 N 4239.42 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . . MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised 11-Feb-2004 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C OORDS Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 100.00 0.00 88.88 100.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 200.00 0.00 88.88 200.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 300.00 0.00 88.88 300.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 400.00 0.00 88.88 400.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 500.00 0.00 88.88 500.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 600.00 0.00 88.88 600.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 700.00 0.00 88.88 700.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 750.00 0.00 88.88 750.00 O.OON O.OOE 0.00 0.00 275155.87 2362053.64 850.00 2.00 88.88 849.98 0.03N 1.74E 2.00 1. 75 275157.61 2362053.64 950.00 4.00 88.88 949.84 0.14N 6.98E 2.00 6.98 275162.85 2362053.64 1050.00 6.00 88.88 1049.45 0.31N 15.69E 2.00 15.69 275171.56 2362053.64 1150.00 8.00 88.88 1148.70 0.54N 27.87E 2.00 27.88 275183.75 2362053.65 1250.00 10.00 88.88 1247.47 0.85N 43.51E 2.00 43.52 275199.39 2362053.65 1350.00 12.00 88.88 1345.62 1. 22N 62.59E 2.00 62.60 275218.47 2362053.66 1450.00 14.00 88.88 1443.06 1. 66N 85.08E 2.00 85.10 275240.96 2362053.66 1550.00 16.00 88.88 1539.64 2.17N 110.96E 2.00 11 0.98 275266.84 2362053.67 1650.00 18.00 88.88 1635.27 2.74N 140.19E 2.00 140.21 275296.08 2362053.67 1750.00 20.00 88.88 1729.82 3.37N 172.73E 2.00 172.77 275328.63 2362053.68 1811.80 21.24 88.88 1787.66 3.80N 194.49E 2.00 194.53 275350.39 2362053.69 2000.00 21.24 88.88 1963.08 5.13N 262.65E 0.00 262.70 275418.56 2362053.71 2500.00 21. 24 88.88 2429.12 8.67N 443.72E 0.00 443.80 275599.65 2362053.76 3000.00 21.24 88.88 2895.17 12.20N 624.79E 0.00 624 . 91 275780.75 2362053.80 3500.00 21. 24 88.88 3361. 22 15.74N 805.86E 0.00 806.01 275961. 85 2362053.85 4000.00 21. 24 88.88 3827.27 19.28N 986.93E 0.00 987.12 276142.95 2362053.90 4500.00 21. 24 88.88 4293.32 22.81N 1168.00E 0.00 1168.22 276324.05 2362053.94 4609.39 21.24 88.88 4395.28 23.59N 1207.62E 0.00 1207.85 276363.67 2362053.95 4700.00 19.88 88.88 4480.12 24.21N 1239.43E 1.50 1239.66 276395.48 2362053.96 4800.00 18.38 88.88 4574.59 24.85N 1272.18E 1. 50 1272.43 276428.24 2362053.97 4900.00 16.88 88.88 4669.90 25.44N 1302.46E 1.50 1302.71 276458.52 2362053.98 5000.00 15.38 88.88 4765.96 25.98N 1330.23E 1.50 1330.48 276486.30 2362053.98 5100.00 13.88 88.88 4862.72 26.47N 1355.48E 1. 50 1355.73 276511.55 2362053.99 5200.00 12.38 88.89 4960.10 26.91N 1378.18E 1.50 1378.45 276534.26 2362053.99 5300.00 10.88 88.89 5058.04 27.31N 1398.33E 1. 50 1398.60 276554.41 2362053.99 5400.00 9.38 88.89 5156.48 27.65N 1415.91E 1.50 1416.18 276571.99 2362054.00 5500.00 7.88 88.89 5255.35 27.94N 1430.91E 1.50 1431.18 276586.99 2362054.00 5600.00 6.38 88.90 5354.57 28.18N 1443.31E 1. 50 1443.59 276599.40 2362054.00 5605.46 6.29 88.90 5360.00 28.19N 1443.91E 1.50 1444.19 276600.00 2362054.00 7657.83 6.29 88.90 7400.00 32.53N 1668.88E 0.00 1669.20 276825.00 2362054.00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Bottom hole distance is 1669.20 on azimuth 88.88 degrees from wellhead. Total Dogleg for wellpath is 36.18 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . . MARATHON Oil Company Pad 4l-7,KBUII-8X Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref KBU II-8X Ver 3 Last revised : II-Feb-2004 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------- 5605.46 7657.83 5360.00 7400.00 28.I9N 32.53N I443.91E I668.88E KBUII-8X - Mid Beluga - 2/9/04 KBUII-8X - TD - 2/9/04 Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------- KBUII-8X - Mid Belug 276600.000,2362054.000,999.00 KBUII-8X - TD - 2/9/ 276825.000,2362054.000,999.00 5360.00 7400.00 28.I9N 32.53N I443.91E I668.88E 9-Feb-2004 9-Feb-2004 CreGtezJ by Jll Dote plottezJ 11" Feb-2004 Plot R€fšrence ís K8U 11-8X Ver RKB (Glacíer Structure: Pod 41-7 Location; Kenai PenÎnsula, Alaska 160 200 East East (feet) 700 800 900 1000 1100 1200 1300 Field : Kenai Gas Field 40 East 200 240 -> 280 320 o 40 80 120 160 200 ,§) (fJ 150 120 1600 /\ I 80 ~ -I- (j) (j) '+- '-../ 40 J:: -I- I.... o Z 40 80 1300 120 160 200 300 400 500 600 400 300 f\ 200 I ~ -I- 100 (j) (j) '+- '-../ 0 J:: -I- I.... 0 700 Z 100 600 500 200 400 300 200 300 400 500 600 700 800 900 1000 11 East (fe -> orn a Well KBUI1-8X 360 440 520 560 400 200 160 120 80 ^ I Z o ., -¡- ::J 40 _ 0-- ~ ..._ ~ ~ ~o- -- VV ,tJ ---..0- - --Ð - - ~ 80 120 160 1400 1500 1800 1600 1700 400 300 //- ! ;",vv V -\ :U~I~8~~ ~'-_/ o f f -+- '-../ 100 200 300 1200 1300 1800 1400 1500 1600 · H H om K8U1 Structure: Pad 41-7 Well: KBU11-8X Field: Kenai Gas Field Locatìon : Kenai PenÎnsula, Alaska TRUE 0 290 350 2200 3 20 330 30 00 310 ! \ U 280 2 0 90 260 100 ~c, L,-, o 2 0 120 230 130 50 1500 Ì\J 0 rTn 0 Plo roveí I' ng íì der All show ore Measured Reference . . MARATHON Oil Company Pad 41-7 KBUll-8X slot# KBUll-8X Kenai Gas Field Kenai Peninsula, Alaska 3-D M I N I MUM D 1ST A N C E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License KBU 11-8X Ver 3 prop5612 Date printed Date created Last revised Il-Feb-2004 9-Feb-2004 Il-Feb-2004 Field is centred on 270916.030,2362063.980,999.00000,N Structure is centred on 270916.030,2362063.980,999.00000,N Slot location is n60 27 34.707,w151 14 44.257 Slot Grid coordinates are N 2362053.640, E 275155.869 Slot local coordinates are 71.37 N 4239.42 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet Object wellpath DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* MMS <0-7910'>"KBU33-7,Pad #?? GMS <0-5820'>"KU24-7,Pad #?? PGMS <778 - 5650>"KU21-6X,Pad #? MSS <0 - 5678'> Depth Shifted"KU21-6X,Pad #? MWD <3452 - 5650'>"KU21-6X,Pad #? PGMS <0-3300'>"WD-l,Pad #? MSS <0-4459'>"KUll-6,Pad #? Incl. only <0-5809'>"KU34-31,Pad #? GMS <0-10502'>"KDU5,Pad #? PGMS <0-5700'>"KU14-32,Pad #? GMS <0-11095'>"KDU6,Pad #? MSS <0-4453'>"KU21-7,Pad 14-6 PMSS <0 - ????>"KBU24-6,Pad 14-6 GMS <0-7375'>"KBU31-7,Pad 14-6 PMSS <5814 - 7575'>,,31-7Rd,Pad 14-6 WD-2 Version #1"WD-2,Pad 14-6 GMS <0-6950'>"KBU23X-6,Pad 14-6 MSS <0-5500'>"KU13-6,Pad 14-6 MSS <0-9895'>"KDU-l,Pad 14-6 MSS <0-6530'>"KU43-12,Pad 14-6 PMSS <O-???'>"KU 31-7,Pad 14-6 INCLINATION ONLY"KU14-6,Pad 14-6 GMS <0 - 9500>"KU14X-6,Pad 14-6 MSS <9776 - 10225>"KU14X-6,Pad 14-6 KU14X-6RD Version #1"KU14X-6Rd,Pad 14-6 MSS <9768 - 10217> DepthShifted"KU14X-6,Pad Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 31-May-1995 4401.9 6631.6 6631.6 31-May-1995 5872.4 1960.0 1960.0 Il-Jan-2002 5831.9 3840.0 3840.0 18-0ct-2001 5745.2 3840.0 3840.0 18-0ct-2001 5850.5 3840.0 3840.0 30-May-1995 7470.4 762.5 762.5 30-May-1995 6543.4 2700.0 2700.0 30-May-1995 7465.0 0.0 0.0 30-May-1995 5641.6 7657.8 7657.8 30-May-1995 6800.5 4060.0 4060.0 30-May-1995 7485.9 600.0 600.0 12-May-1995 3163.8 1287.5 1287.5 12-Mar-2001 2997.5 0.0 6631.6 14-Sep-1995 2896.0 1700.0 1750.0 28-Sep-1995 2896.0 1700.0 6631.6 26-Mar-1999 3373.5 750.0 750.0 12-May-1995 3055.6 0.0 0.0 12-May-1995 2979.2 300.0 300.0 12-May-1995 3345.0 750.0 7657.8 12-May-1995 3272.4 0.0 0.0 10-Jan-2001 2292.6 3680.0 3680.0 7-Nov-2003 3286.7 775.0 775.0 Il-Dec-2002 3120.9 200.0 200.0 11-Dec-2002 3120.9 200.0 200.0 11-Dec-2002 3421.5 1662.5 1662.5 11-Dec-2002 3120.9 200.0 200.0 . GMS <0 - 9492> DepthShifted 12/10/02"KUI4X-6, KBU 23-7 Version#I"KBU23-7,Pad 14-6 MWD <0 - 11857'>"KTU32-7H,Pad 41-7 PMSS <0-8864>"KTU32-7,Pad 41-7 MSS <0-10522'>"KDU#2,Pad 41-7 GMS <0-7902'>"KBU33-6,Pad 41-7 PMSS <8846 - 10960>"KTU24-6H,Pad 41-7 GMS <0-5900'>"KU24-5,Pad 41-7 GMS <0-5350'>"KUII-8,Pad 41-7 PMSS <0 - 7570>"KBU42-7,Pad 41-7 MSS <0-5707'>"KU 43-7,Pad 41-7 GMS <0-5549'>"KDU4,Pad 41-7 MSS <4320 - 10810'>"KDU4Rd,Pad 41-7 MWD <3470 - 4816>"KU24-5Rd,Pad 41-7 MWD <0-7440>"KBU 44-6,Pad 41-7 GMS <0-7290>"KBU41-7,Pad 41-7 KBU43-7X Ver 3"KBU43-7X,Pad 41-7 MWD <0-8610>"KBU43-7X,Pad 41-7 MWD <0-5300>"KBU41-7X,Pad 41-7 MSS <4305 - 5701>"KU43-6,Pad 41-7 MWD <4250 - 5740>"KU43-6RD,Pad 41-7 KTU43-6XRd Ver.7,,43-6X Rd,Pad 41-7 PGMS <0-8370'>,,43-6,Pad 41-7 PMSS <7670-9464'>,,43-6X Rd,Pad 41-7 MSS <0-5300'>,,43-6A,Pad 41-7 MWD <0-8405>"KBU33-6X,Pad 41-7 GMS <0-8120'>"KUI3-5,Pad 41-7 11-Dec-2002 18-Nov-2003 17-May-2002 31-Aug-2000 21-Jan-1994 22-Jun-2000 l-Aug-2000 21-Jan-1994 21-Jan-1994 9-Feb-2001 21-Jan-1994 5-May-1995 5-May-1995 9-Jan-2002 3-Mar-2002 13-Mar-2002 6-Jun-2003 13-Jun-2003 19-Mar-2002 31-Jan-2002 30-Jan-2002 20-Apr-1999 23-Jul-1995 16-Aug-1995 20-Jan-1994 4-Jan-2004 21-Jan-1994 3120.9 3133.2 144.3 83.2 396.0 194.3 112.9 308.5 437.1 151.3 462.7 318.5 318.5 308.5 54.8 248.8 3754.2 151. 4 305.4 49.8 49.8 2172.4 296.1 296.1 97.7 103.8 63.3 200.0 862.5 1437.5 500.0 400.0 0.0 0.0 1625.0 600.0 200.0 200.0 100.0 100.0 1625.0 1400.0 1262.5 5057.1 0.0 400.0 1175.0 1175.0 7657.8 750.0 750.0 1487.5 787.5 1487.5 . 200.0 862.5 7657.8 500.0 7657.8 0.0 0.0 1625.0 600.0 200.0 200.0 100.0 100.0 1625.0 1400.0 1262.5 5057.1 0.0 1587.5 1175.0 1175.0 7657.8 13 62.5 1362.5 1487.5 787.5 1487.5 . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 750.0 762.5 500.0 600.0 700.0 750.0 762.5 775.0 787.5 800.0 812.5 825.0 775.0 787.5 800.0 812.5 825.0 837.5 850.0 862.5 875.0 887.5 837.5 850.0 862.5 875.0 887.4 900.0 912.5 925.0 937.5 950.0 899.9 912.4 924.9 937.4 949.8 962.5 975.0 987.5 1000.0 1012.5 962.3 974.8 987.2 999.7 1012.1 1025.0 1037.5 1050.0 1062.5 1075.0 1024.6 1037.0 1049.5 1061.9 1074.3 1087.5 1100.0 1112.5 1125.0 1137.5 1086.7 1099.1 1111.5 1123.9 1136.3 1150.0 1162.5 1175.0 1187.5 1200.0 1148.7 1161.1 11 73.4 1185.8 1198.2 1212.5 1225.0 1237.5 1250.0 1262.5 1210.5 1222.8 1235.2 1247.5 1259.8 1275.0 1272 .1 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.lN O.lN O.lN O.lN O.lN O.lN O.lN 0.2N 0.2N 0.2N 0.2N 0.2N 0.3N 0.3N 0.3N 0.3N 0.4N 0.4N 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 7.9E 8.8E 9.8E 10.9E 12.0E 13.2E 14.4E 15.7E 17.0E 18.4E 19.9E 21. 3E 22.9E 24.5E 26.2E 27.9E 29.6E 31. 5E 33.3E 35.3E 37.2E 39.3E 41. 4E 43.5E 45.7E Object we11path O.OE O.OE O.OE O.OE O.OE 0.0 98.3 196.5 297.4 397.1 M.D. T.V.D. 0.0 98.3 196.5 297.3 397.0 496.3 596.8 697.3 748.2 760.7 772.7 785.2 797.7 810.3 822.8 836.2 848.6 861.1 874.7 887.1 900.9 913.3 926.4 938.9 951.3 963.8 976.3 988.9 1001. 3 1013.7 1026.4 1038.9 1051. 6 1064.0 1076.4 1089.0 1101.4 1113.4 1125.8 1138.2 1149.6 1161. 9 1174.1 1186.4 1198.8 1211. 8 1224.1 1236.3 1248.6 1260.9 1272.4 . CLEARANCE LI8TING Page 2 Your ref KBU 11-8X Ver 3 Last revised : 11-Feb-2004 MWD <0 - 11857'>"KTU32-7H,Pad 41-7 TCyl Dist Rect Coordinates Horiz Minim Bearing Dist 128.58 129.18 131. 08 133.48 135.38 137.78 139.88 141.78 142.48 142.68 142.88 142.98 143.18 143.38 143.58 143.68 143.88 143.98 144.18 144.18 144.28 144.28 144.28 144.18 144.18 144.18 144.08 144.08 144.08 143.98 143.98 143.88 143.78 143.68 143.58 143.48 143.38 143.28 143.18 143.08 143.08 143.08 143.08 143.08 143.08 143.08 143.08 142.98 142.98 142.98 142.88 87.1E 87.2E 87.3E 87.5E 87.5E 88.0E 88.7E 89.3E 89.3E 89.2E 89.2E 89.3E 89.3E 89.4E 89.4E 89.4E 89.4E 89.3E 89.2E 89.1E 89.0E 88.9E 88.8E 88.6E 88.5E 145.9 146.0 146.3 146.7 147.1 147.4 147.6 147.8 147.9 148.0 148.0 148.1 148.2 148.2 148.4 148.5 148.6 148.8 149.0 149.2 149.5 149.7 150.0 150.2 150.5 88.3E 88.1E 87.9E 87.7E 87.5E 150.9 151.2 151.6 151.9 152.3 155.3 155.8 157.4 159.6 161. 2 155.3 155.8 157.5 159.6 161.2 O.OE O.OE O.OE O.OE O.OE 496.4 596.9 697.4 748.4 760.9 87.4E 87.2E 87.1E 86.9E 86.8E 86.6E 86.4E 86.2E 86.0E 85.8E 85.6E 85.4E 85.2E 85.0E 84.8E 84.6E 84.4E 84.2E 83.9E 83.7E 83.5E 163.4 165.6 167.5 168.1 168.2 163.5 165.7 167.5 168.1 168.2 O.lE 0.2E 0.4E 0.7E 1. OE 772.8 785.3 797.8 810.5 823.0 168.3 168.4 168.5 168.6 168.6 168.3 168.4 168.5 168.6 168.6 1. 3E 1. 7E 2.2E 2.7E 3.3E 836.3 848.8 861. 3 874.8 887.3 168.5* 168.4* 168.3* 168.1* 167.8* 168.5* 168.4* 168.3* 168.1* 167.9* 3.9E 4.6E 5.3E 6.1E 7.0E 901.0 913 .5 926.6 939.1 951.5 167.5* 167.1* 166.7* 166.2* 165.7* 167.6* 167.2* 166.8* 166.3* 165.8* 964.0 976.4 989.0 1001. 5 1013.9 1026.6 1039.0 1051.7 1064.1 1076.5 1089.2 1101. 6 1113.6 1126.0 1138.4 1149.8 1162.1 1174.3 1186.6 1199.0 1212.0 1224.3 1236.5 1248.8 1261.1 48.0E 1272.6 165.1* 164.6* 164.0* 163.4* 162.7* 165.3* 164.7* 164.2* 163.6* 163.0* 152.8 153.2 153.6 154.1 154.6 162.3* 161.7* 161.0* 160.3* 159.6* 162.1* 161. 4 * 160.7* 160.0* 159.3* 155.1 155.6 156.2 156.8 157.4 158.8* 158.0* 157.3* 156.5* 155.7* 158.5* 157.7* 156.9* 156.2* 155.4* 158.1 158.8 159.5 160.2 161. 0 154.9* 154.2* 153.5* 152.9* 152.2* 154.7* 154.0* 153.3* 152.7* 152.0* 161. 8 162.6 163.4 164.3 165.2 151.6* 150.9* 150.2* 149.5* 148.9* 151.3* 150.7* 150.0* 149.3* 148.7* 166.1 148.3* 148.1* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LI8TING Page 3 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Feb-2004 Reference wellpath Object wellpath MWD <0 - 11857'>"KTU32-7H,Pad 41-7 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1287.5 1284.4 1. ON 50.3E 1284.9 1284.7 142.98 83.3E 167.1 147.6* 147.7* 1300.0 1296.6 1. ON 52.6E 1297.1 1296.9 142.98 83.1E 168.1 147.1* 147.2* 1312.5 1308.9 loIN 55.0E 1309.2 1309.0 142.98 82.9E 169.1 146.7* 146.8* 1325.0 1321.1 loIN 57.5E 1321.4 1321.2 143.08 82.7E 170.1 146.3* 146.3* 1337.5 1333.4 1. 2N 60.0E 1334.0 1333.8 143.08 82.4E 171.2 145.9* 146.0* 1350.0 1345.6 1. 2N 62.6E 1346.2 1345.9 143.08 82.2E 172.3 145.6* 145.6* 13 62 . 5 1357.8 1. 3N 65.2E 1358.3 1358.1 143.08 82.0E 173.4 145.3* 145.3* 1375.0 1370.1 1. 3N 67.9E 1370.9 1370.7 143.08 81.7E 174.5 145.0* 145.0* 1387.5 1382.3 1. 4N 70.6E 1383.1 1382.8 143.08 81. 5E 175.7 144.8* 144.8* 1400.0 1394.4 1. 4N 73.4E 13 95.7 13 95.5 142.98 81. 3E 176.9 144.6* 144.6* 1412.5 1406.6 1. 5N 76.2E 1407.8 1407.6 142.98 81. OE 178.1 144.4* 144.4* 1425.0 1418.8 1. 5N 79.1E 1419.9 1419.7 142.88 80.8E 179.4 144.3* 144.3* 1437.5 1430.9 1. 6N 82.1E 14 32.1 1431. 8 142.78 80.5E 180.6 144.3* 144.3* 1450.0 1443.1 1. 7N 85.1E 1444.1 14 43.9 142.68 80.2E 181. 9 144.4 144.4 1462.5 14 55.2 1. 7N 88.1E 14 55.8 14 55.5 142.68 79.9E 183.3 144.5 144.5 1475.0 14 67.3 1. 8N 91. 2E 14 67.7 1467.4 142.58 79.5E 184.6 144.8 144.8 1487.5 1479.4 1. 8N 94.4E 1479.7 1479.4 142.58 79.2E 186.0 145.1 145.2 1500.0 1491. 5 1. 9N 97.6E 1491.7 1491.4 142.48 78.8E 187.4 145.6 145.7 1512.5 1503.5 2.0N 100.9E 1503.6 1503.4 142.48 78.4E 188.8 146.1 146.3 1525.0 1515.6 2.0N 104.2E 1515.6 1515.3 142.48 78.1E 190.2 146.7 147.0 1537.5 1527.6 2.1N 107.5E 1527.7 1527.5 142.38 77.7E 191. 7 147.4 147.8 1550.0 1539.6 2.2N 111. OE 1539.7 1539.4 142.38 77.4E 193.1 148.3 148.7 1562.5 1551.7 2.2N 114.4E 1551.7 1551.4 142.28 77.1E 194.5 149.2 149.7 1575.0 1563.6 2.3N 118.0E 1563.6 1563.3 142.18 76.7E 195.9 150.2 150.8 1587.5 '1575.6 2.4N 121.5E 1575.5 1575.2 142.18 76.4E 197.3 151. 3 152.0 1600.0 1587.6 2.4N 125.2E 1587.5 1587.2 142.08 76.1E 198.8 152.5 153.4 1612.5 1599.5 2.5N 128.8E 1599.3 1599.0 141.98 75.8E 200.2 153.9 154.9 1625.0 1611.5 2.6N 132.6E 1611.1 1610.8 141. 98 75.5E 201. 5 155.3 156.5 1637.5 1623.4 2.7N 13 6. 4E 1623.0 1622.6 141.88 75.2E 202.9 156.9 158.3 1650.0 1635.3 2.7N 14 0 . 2E 1634.8 1634.4 141.78 75.0E 204.3 158.5 160.2 1662.5 1647.1 2.8N 14 4. IE 1646.5 1646.2 141.78 74.7E 205.7 160.3 162.2 1675.0 1659.0 2.9N 14 8. OE 1658.3 1658.0 141. 68 74.4E 207.0 162.2 164.4 1687.5 1670.9 3. ON 152.0E 1670.0 1669.7 141. 68 74.1E 208.3 164.2 166.7 1700.0 1682.7 3.0N 156.0E 1681.5 1681.2 141.58 73.8E 209.6 166.3 169.2 1712.5 1694.5 3.1N 160.1E 1693.2 1692.9 141.48 73.5E 210.9 168.6 171.8 1725.0 1706.3 3.2N 164.3E 1704.9 1704.5 141.48 73.2E 212.2 170.9 174.6 1737.5 1718.1 3.3N 168.5E 1716.3 1715.9 141.48 73.0E 213.4 173.4 177.4 1750.0 1729.8 3.4N 17 2. 7E 1727.9 1727.6 141. 48 72.8E 214.6 176.0 180.4 17 62.4 1741. 4 3.5N 177 . OE 1739.5 1739.1 141.58 72.6E 215.8 178.7 183.5 1774.7 1753.0 3.5N 181. 3E 1751. 0 1750.7 141.58 72.4E 216.9 181. 4 186.7 1787.1 17 64.6 3.6N 185.6E 1762.5 1762.2 141.68 72.2E 218.0 184.3 190.0 1799.4 1776.1 3.7N 190.0E 1774.4 1774.0 141.78 72 .1E 219.1 187.2 193.4 1811.8 1787.7 3.8N 194.5E 1785.9 1785.5 141.78 71.9E 220.1 190.3 197.0 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 750.0 762.5 500.0 600.0 700.0 750.0 762.5 775.0 787.5 800.0 812.5 825.0 775.0 787.5 800.0 812.5 825.0 837.5 850.0 862.5 875.0 887.5 837.5 850.0 862.5 875.0 887.4 900.0 912.5 925.0 937.5 950.0 899.9 912.4 924.9 937.4 949.8 962.5 975.0 987.5 1000.0 1012.5 962.3 974.8 987.2 999.7 1012.1 1025.0 1037.5 1050.0 1062.5 1075.0 1024.6 1037.0 1049.5 1061.9 1074.3 1087.5 1100.0 1112.5 1125.0 1137.5 1086.7 1099.1 1111.5 1123.9 1136.3 1150.0 1162.5 1175.0 1187.5 1200.0 1148.7 1161.1 1173.4 1185.8 1198.2 1212.5 1225.0 1237.5 1250.0 1262.5 1210.5 1222.8 1235.2 1247.5 1259.8 1275.0 1272 .1 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.lN O.lN O.lN O.lN O.lN O.lN o .1N 0.2N 0.2N 0.2N 0.2N 0.2N 0.3N 0.3N 0.3N 0.3N 0.4N 0.4N 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 7.9E 8.8E 9.8E 10.9E 12.0E 13.2E 14.4E 15.7E 17.0E 18.4E 19.9E 21.3E 22.9E 24.5E 26.2E 27.9E 29.6E 31. 5E 33.3E 35.3E 37.2E 39.3E 41.4E 43.5E 45.7E 48.0E Object we11path O.OE O.OE O.OE O.OE O.OE 0.2 100.7 201.0 301. 2 401.1 M.D. T.V.D. 0.2 100.7 201. 0 301. 2 401.1 500.4 599.0 697.3 746.1 758.5 771.0 783.3 795.7 808.1 820.5 833.1 845.5 858.4 870.8 883.2 896.8 909.2 922.0 934.4 946.9 896 .1 908.6 921.4 933.8 946.2 . CLEARANCE LISTING Page 4 Your ref KBU 11-8X Ver 3 Last revised: 11-Feb-2004 PMSS <0-8864>"KTU32-7,Pad 41-7 Rect Coordinates Horiz MinIm Bearing Dist 87.7S 87.4S 86.5S 85.2S 83.7S 82.7S 82.9S 84.3S 85.8S 86.2S 86.6S 87.0S 87.4S 87.8S 88.2S 88.6S 89.0S 89.4S 89.8S 90.1S 90.5S 90.8S 91.1S 91.4S 91.6S 91. 9S 92 .2S 92 .4S 92.7S 92.9S 93.1S 93.3S 93.5S 93.7S 93.8S 93.9S 94.0S 94.1S 94.2S 94.2S 94.2S 94.2S 94.2S 94.2S 94.1S 94.1S 94.0S 94.0S 93.9S 93.8S 93.6S 9.2W 12.0W 16.2W 18.9W 19.7W 20.4W 21.1W 21.9W 22.7W 23.4W 24.2W 24.9W 25.7W 26.4W 27. OW 27.6W 28.2W 28.8W 29.4W 29.9W 30.5W 31. OW 31.5W 32.0W 32.5W 33.1W 33.5W 34.0W 34.4W 34.9W 35.2W 35.6W 36.0W 36.3W 36.6W 36.9W 37.2W 37.4W 37.7W 37.9W 38.1W 38.3W 38.5W 38.7W 38.8W 39. OW 8.2W 8. OW 7.8W 7.6W 7.8W 199.2 199.9 200.5 201. 2 201. 9 202.6 203.3 204.1 204.8 205.6 206.3 207.1 207.9 208.7 209.5 210.3 211.1 211. 9 212.7 213.5 214.4 215.2 216.0 216.8 217.6 218.5 219.3 220.1 220.9 221.8 222.6 TCy1 Dist 185.3 185.3 185.1 185.1 185.3 88.1 87.7* 86.8* 85.5* 84.1* 88.1 87.7* 86.8* 85.5* 84.1* O.OE O.OE O.OE O.OE O.OE 500.4 599.1 697.4 746.4 758.8 958.6 971.3 983.7 996.1 1008.5 1021. 4 1033.8 1046.1 1059.3 1071.7 1084.0 1097.3 1109.6 1122.0 1135.2 1147.5 1159.8 1172.2 1184.5 1197.7 1210.0 1222.3 1234.6 1246.8 1260 . 0 1272.3 186.3 188.3 190.8 192.4 192.9 83.2* 83.7 85.9 87.9 88.5 83.2* 83.7 86.0 88.0 88.6 O.lE 0.2E 0.4E 0.7E 1. OE 771. 3 783.7 796.1 808.6 821.0 193.3 193.8 194.3 194.9 195.5 89.2 89.8 90.4 91.1 91. 8 1. 3E 1. 7E 2.2E 2.7E 3.3E 833.6 846.1 859.0 871. 4 883.8 89.1 89.7 90.3 91. 0 91. 7 196.1 196.7 197.3 197.9 198.6 92.4 93.1 93.8 94.5 95.2 92 .5 93.2 94.0 94.7 95.4 3.9E 4.6E 5.3E 6.1E 7.0E 959.3 972.0 984.4 996.8 1009.2 1022.1 1034.5 1046.9 1060.1 1072.5 1084.8 1098.1 1110.4 1122.8 1136.0 1148.3 1160.7 1173.0 1185.3 1198.5 1210.8 1223.1 1235.4 1247.7 1260.9 1273.2 96.0 96.7 97.4 98.2 99.0 96.1 96.9 97.6 98.4 99.2 99.8 100.6 101. 5 102.4 103.3 100.0 100.9 101.7 102.7 103.6 104.3 105.2 106.2 107.2 108.2 104.6 105.5 106.5 107.6 108.6 109.3 110.3 111. 4 112.5 113.6 109.7 110.7 111.8 113.0 114.1 114.8 116.0 117.2 118.5 119.8 115.3 116.5 117.8 119.1 120.4 121.1 122.5 123.9 125.4 126.9 121.8 123.3 124.8 126.3 127.9 128.5 129.5 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBU11-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LI8TING Page 5 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Feb-2004 Reference wellpath Object wellpath PM88 <0-8864>"KTU32-7,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1287.5 1284.4 1. ON 50.3E 1285.4 1284.6 93.58 39.1W 223.4 130.1 131.2 1300.0 1296.6 1. ON 52.6E 1297.7 1296.8 93.48 39.2W 224.2 131.7 132.9 1312.5 1308.9 loIN 55.0E 1309.9 1309.1 93.28 39.3W 225.0 133.4 134.7 1325.0 1321.1 loIN 57.5E 1322.7 1321.8 93.18 39.4W 225.8 135.1 136.5 1337.5 1333.4 1.2N 60.0E 1334.9 1334.0 92.98 39.5W 226.6 136.9 138.4 1350.0 1345.6 1. 2N 62.6E 1347.1 1346.3 92.78 39.6W 227.4 138.8 140.4 13 62.5 1357.8 1. 3N 65.2E 1359.3 1358.5 92.58 39.7W 228.2 140.7 142.5 1375.0 1370.1 1.3N 67.9E 1371. 5 1370.6 92.48 39.7W 229.0 142.7 144.7 1387.5 1382.3 1. 4N 70.6E 1383.7 1382.8 92.28 39.8W 229.7 144.8 146.9 1400.0 1394.4 1. 4N 73.4E 1395.8 1395.0 92 .08 39.9W 230.5 146.9 149.2 1412.5 1406.6 1.5N 76.2E 1408.0 1407.1 91.88 40.0W 231. 3 149.1 151.6 1425.0 1418.8 1. 5N 79.1E 1420.1 1419.3 91.68 40.1W 232.0 151.3 154.0 1437.5 1430.9 1. 6N 82.1E 1432.3 1431.4 91.48 40.2W 232.7 153.7 156.6 1450.0 1443.1 1. 7N 85.1E 1444.4 1443.5 91. 28 40.3W 233.5 156.1 159.2 1462.5 1455.2 1. 7N 88.1E 1456.5 1455.6 91.08 40.4W 234.2 158.5 161.9 1475.0 1467.3 1. 8N 91. 2E 1468.6 14 67.7 90.88 40.5W 234.9 161. 0 164.6 1487.5 1479.4 1. 8N 94.4E 1480.6 1479.8 90.68 40.6W 235.6 163.6 167.5 1500.0 14 91. 5 1. 9N 97.6E 1492.7 1491.8 90.48 40.7W 236.3 166.3 170.4 1512.5 1503.5 2. ON 100.9E 1504.7 1503.9 90.28 40.8W 236.9 169.0 173.5 1525.0 1515.6 2.0N 104.2E 1516.8 1515.9 90.08 40.9W 237.6 171.8 176.7 1537.5 1527.6 2.1N 107.5E 1527.9 1527.1 89.88 41. OW 238.2 174.7 180.1 1550.0 1539.6 2.2N 111. OE 1539.9 1539.0 89.78 41.1W 238.9 177.7 183.6 1562.5 1551.7 2.2N 114.4E 1551. 9 1551.0 89.58 41. 3W 239.5 180.8 187.4 1575.0 1563.6 2.3N 118.0E 1562.1 1561. 2 89.58 41.4W 240.1 183.9 191. 4 1587.5 1575.6 2.4N 121.5E 1574.0 1573.1 89.58 41.6W 240.6 187.3 195.6 1600.0 1587.6 2.4N 125.2E 1583.7 1582.8 89.58 41. 8W 241. 2 190.7 200.0 1612.5 1599.5 2.5N 128.8E 1595.6 1594.7 89.78 42.1W 241.7 194.2 204.5 1625.0 1611. 5 2.6N 132.6E 1604.8 1603.9 89.98 42.3W 242.1 198.0 209.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Total Dogleg for we11path is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LI8TING Page 6 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Feb-2004 Reference wellpath Object wellpath GM8 <0-7902'>"KBU33-6,Pad 41-7 Hori z MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 0.0 0.0 88.38 173.1W 243.0 194.3 194.3 100.0 100.0 O.ON O.OE 98.5 98.5 88.78 173.4W 242.9 194.8 194.8 200.0 200.0 O.ON O.OE 198.2 198.2 89.58 173.9W 242.8 195.6 195.6 300.0 300.0 O.ON O.OE 297.6 297.6 90.38 174.8W 242.7 196.8 196.8 400.0 400.0 O.ON O.OE 397.0 397.0 91. 28 175.8W 242.6 198.1 198.1 500.0 500.0 O.ON O.OE 496.6 496.6 92 .18 177.2W 242.5 199.7 199.8 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 4l-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 750.0 762.5 500.0 600.0 700.0 750.0 762.5 775.0 787.5 800.0 812.5 825.0 775.0 787.5 800.0 812.5 825.0 837.5 850.0 862.5 875.0 887.5 837.5 850.0 862.5 875.0 887.4 900.0 912.5 925.0 937.5 950.0 899.9 912.4 924.9 937.4 949.8 962.5 975.0 987.5 1000.0 1012.5 962.3 974.8 987.2 999.7 1012.1 1025.0 1037.5 1050.0 1062.5 1075.0 1024.6 1037.0 1049.5 1061.9 1074.3 1087.5 11 00.0 1112.5 1125.0 1137.5 1086.7 1099.1 1111.5 1123.9 1136.3 1150.0 1162.5 1175.0 1187.5 1200.0 1148.7 1161.1 1173.4 1185.8 1198.2 1212.5 1225.0 1237.5 1250.0 1262.5 1210.5 1222.8 1235.2 1247.5 1259.8 1275.0 1272 .1 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON o .1N O.lN O.lN O.lN O.lN O.lN O.lN 0.2N 0.2N 0.2N 0.2N 0.2N 0.3N 0.3N 0.3N 0.3N 0.4N 0.4N 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 7.9E 8.8E 9.8E 10.9E 12.0E 13.2E 14.4E 15.7E 17.0E 18.4E 19.9E 21. 3E 22.9E 24.5E 26.2E 27.9E 29.6E 31. 5E 33.3E 35.3E 37.2E 39.3E 41.4E 43.5E 45.7E 48.0E Object wellpath O.OE O.OE O.OE O.OE O.OE 0.0 99.8 199.7 298.9 397.0 M.D. T.V.D. 0.0 99.8 199.7 298.8 396.9 496.8 596.7 696.7 746.6 759.1 771.7 784.2 796.7 809.2 821.7 834.1 846.8 859.3 871.8 884.2 896.7 909.1 921. 6 934.5 947.0 959.4 971.9 984.3 997.5 1009.9 1022.3 1034.8 1048.0 1060.4 1072.8 1085.2 1097.9 1110.3 1122.7 1135.1 1147.5 1159.8 1172.2 1184.5 1196.8 1209.2 1221.5 1233.8 1246.1 1258.4 1270.7 . CLEARANCE LI8TING Page 7 Your ref KBU 11-8X Ver 3 Last revised : Il-Feb-2004 PM88 <8846 - 10960>"KTU24-6H,Pad 41-7 TCyl Dist Rect Coordinates Horiz Minim Bearing Dist 85.98 85.68 84.78 83.38 83.65 83.88 84.08 84.28 84.45 84.58 84.68 84.68 84.78 84.78 84.88 84.88 84.98 85.08 85.08 85.18 85.28 85.28 85.38 85.45 85.48 85.58 85.68 85.68 85.78 85.78 85.88 85.88 85.98 85.98 85.95 86.08 86.08 86.08 86.18 86.15 86.18 86.28 86.28 86.28 86.38 86.38 86.48 86.48 86.58 86.58 86.58 73.2W 73.6W 75.0W 77 .3W 80.7W 84.2W 87.9W 91. 3W 92.9W 93.3W 93.7W 94.1W 94.5W 94.9W 95.2W 95.6W 96.0W 96.4W 96.7W 97.1W 97.4W 97.7W 98.1W 98.4W 98.7W 99. Ow 99.3W 99.6W 99.8W 100.0W 100.3W 100.5W 100.6W 100.8W 100.9W 101.1W 101. 2W 101.3W 101.4W 101. 5W 101.6W 101.6W 101.7W 101.8W 101. 9W 102.0W 102.1W 102.2W 102.3W 102.4W 102.5W 220.4 220.7 221.5 222.8 224.0 225.1 226.3 227.3 227.7 227.8 228.0 228.1 228.3 228.4 228.6 228.8 229.0 229.2 229.4 229.7 229.9 230.2 230.4 230.7 231.0 231.3 231. 6 231.9 232.2 232.5 232.8 233.1 233.5 233.8 234.1 234.5 234.8 235.1 235.5 235.8 236.2 236.5 236.9 237.3 237.6 238.0 238.4 238.7 239.1 239.5 239.8 112.9 112.9 113 .2 113.7 116.2 112.9 112.9 113.2 113.7 116.2 O.OE O.OE O.OE O.OE O.OE 497.0 597.0 697.0 746.9 759.4 118.9 121. 6 124.3 125.6 126.0 118.9 121.6 124.3 125.6 126.0 O.lE 0.2E 0.4E 0.7E 1. OE 772 .1 784.6 797.1 809.5 822.0 126.3 126.8 127.2 127.8 128.3 126.4 126.9 127 .3 127.9 128.4 1. 3E 1. 7E 2.2E 2.7E 3.3E 834.5 847.2 859.7 872 .2 884.6 128.9 129.5 130.2 130.9 131.7 129.1 129.7 130.4 131.1 131. 9 3.9E 4.6E 5.3E 6.1E 7.0E 897.1 909.5 922.0 934.9 947.4 132.5 133.3 134.2 135.1 136.0 132.7 133.6 134.5 135.4 136.4 959.8 972 .3 984.7 997.9 1010.4 1022.8 1035.2 1048.4 1060.8 1073.2 1085.6 1098.4 1110.8 1123.1 1135.5 1147.9 1160.3 11 72.6 1184.9 1197.3 1209.6 1221.9 1234.2 1246.5 1258.8 1271.1 137.0 138.0 139.1 140.1 141.3 137.4 138.5 139.6 140.7 141.8 142.4 143.6 144.8 146.0 147.3 143.0 144.2 145.5 146.8 148.1 148.6 150.0 151. 3 152.8 154.2 149.5 150.9 152.3 153.8 155.4 155.8 157.4 159.0 160.7 162.4 157.0 158.7 160.4 162.2 164.1 164.2 166.1 168.0 169.9 172.0 166.0 168.0 170.1 172 .2 174.3 174.0 176.6 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LISTING Page 8 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field, Kenai Peninsula, Alaska Last revised : ll-Feb-2004 Reference wellpath Object we11path PMSS <8846 - 10960>"KTU24-6H,Pad 41-7 Horiz Min'rn TCy1 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1287.5 1284.4 1. ON 50.3E 1283.4 1282.9 86.6S 102.6W 240.2 176.2 178.8 1300.0 1296.6 1. ON 52.6E 1295.6 1295.2 86.68 102.7W 240.6 178.3 181.2 1312.5 1308.9 1. IN 55.0E 1307.7 1307.2 86.78 102.8W 240.9 180.6 183.6 1325.0 1321.1 1. IN 57.5E 1319.9 1319.4 86.88 102.8W 241. 3 182.9 186.1 1337.5 1333.4 1. 2N 60.0E 1332.1 1331.7 86.8S 102.9W 241.6 185.2 188.7 1350.0 1345.6 1.2N 62.6E 1344.3 1343.9 86.9S 103.0W 242.0 187.6 191.3 13 62.5 1357.8 1.3N 65.2E 1356.5 1356.1 86.9S 103.1W 242.3 190.1 194.0 1375.0 1370.1 1. 3N 67.9E 1368.7 13 68.3 87.08 103.2W 242.7 192.6 196.7 1387.5 1382.3 1. 4N 70.6E 1380.9 1380.4 87.08 103.3W 243.1 195.1 199.5 1400.0 1394.4 1. 4N 73.4E 1393.1 1392.6 87.18 103.4W 243.4 197.8 202.4 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LISTING Page 9 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 11-Feb-2004 Reference wellpath Object wellpath PMSS <0 - 7570>"KBU42-7,Pad 41-7 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 0.0 0.0 86.7S 124.1W 235.1 151.4 151. 4 100.0 100.0 O.ON O.OE 100.1 100.1 86.5S 124.2W 235.2 151.3* 151.3* 200.0 200.0 O.ON O.OE 199.9 199.9 85.8S 124.6W 235.4 151.3* 151. 3* 300.0 300.0 O.ON O.OE 298.6 298.6 85.6S 125.1W 235.6 151. 6 151.6 400.0 400.0 O.ON O.OE 394.5 394.5 87.7S 126.4W 235.3 154.0 154.1 500.0 500.0 O.ON O.OE 490.3 490.1 92.9S 128.7W 234.2 159.1 159.4 600.0 600.0 O.ON O.OE 584.7 584.0 101.4S 131.7W 232.4 167.0 167.7 700.0 700.0 O.ON O.OE 682.7 681.3 113.4S 13 4. 7W 229.9 177.1 178.1 750.0 750.0 O.ON O.OE 734.4 732.4 120.7S 135.5W 228.3 182.3 183.2 762.5 762.5 O.ON O.OE 746.8 744.7 122.5S 135.6W 227.9 183.6 184.5 775.0 775.0 O.ON O.lE 759.1 756.9 124.3S 135.5W 227.5 184.8 185.8 787.5 787.5 O.ON 0.2E 773.0 770.7 126.3S 135.4W 227.0 186.1 187.1 800.0 800.0 O.ON 0.4E 785.4 782.9 128.1S 135.3W 226.6 187.4 188.4 812.5 812.5 O.ON 0.7E 799.3 796.6 130.1S 135. OW 226.2 188.7 189.7 825.0 825.0 O.ON 1. OE 811. 6 808.8 132. OS 134.7W 225.8 190.0 191.0 837.5 837.5 O.ON 1. 3E 825.8 822.8 134.1S 134.3W 225.3 191. 3 192.3 850.0 850.0 O.ON 1. 7E 838.2 835.1 135.9S 133.8W 224.9 192.6 193.6 862.5 862.5 O.ON 2.2E 850.5 847.3 137.7S 133.4W 224.5 193.9 194.8 875.0 875.0 O.lN 2.7E 865.0 861.6 139.8S 132.7W 224.1 195.1 196.1 887.5 887.4 O.lN 3.3E 877.4 873.8 141.5S 132.1W 223.7 196.4 197.4 900.0 899.9 O.lN 3.9E 891.9 888.2 143.5S 131. 4W 223.3 197.7 198.6 912.5 912.4 O.lN 4.6E 904.3 900.4 145.2S 130.7W 223.0 198.9 199.9 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 750.0 762.5 500.0 600.0 700.0 750.0 762.5 775.0 787.5 800.0 812.5 825.0 775.0 787.5 800.0 812.5 825.0 837.5 850.0 862.5 875.0 887.5 837.5 850.0 862.5 875.0 887.4 900.0 912.5 925.0 937.5 950.0 899.9 912.4 924.9 937.4 949.8 962.5 975.0 987.5 1000.0 1012.5 962.3 974.8 987.2 999.7 1012.1 1025.0 1037.5 1050.0 1062.5 1075.0 1024.6 1037.0 1049.5 1061 . 9 1074.3 1087.5 1100.0 1112.5 1125.0 1137.5 1086.7 1099.1 1111.5 1123.9 1136.3 1150.0 1162.5 1175.0 1187.5 1200.0 1148.7 1161.1 1173.4 1185.8 1198.2 1212.5 1225.0 1237.5 1250.0 1262.5 121 0 . 5 1222.8 1235.2 1247.5 1259.8 1275.0 1272 .1 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.lN O.lN O.lN O.lN O.lN O.lN O.lN 0.2N 0.2N 0.2N 0.2N 0.2N 0.3N 0.3N 0.3N 0.3N 0.4N 0.4N 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 7.9E 8.8E 9.8E 10.9E 12.0E 13.2E 14.4E 15.7E 17.0E 18.4E 19.9E 21. 3E 22.9E 24.5E 26.2E 27.9E 29.6E 31.5E 33.3E 35.3E 37.2E 39.3E 41.4E 43.5E 45.7E 48.0E Object wellpath O.OE O.OE O.OE O.OE O.OE O.OE O.OE O.OE O.OE O.OE O.lE 0.2E 0.4E 0.7E 1. OE 1.3E 1. 7E 2.2E 2.7E 3.3E 3.9E 4.6E 5.3E 6.1E 7.0E 964.7 977.2 989.4 1001. 9 1014.4 1026.6 1039.1 1051. 5 1063.9 1076.4 1088.9 1101.4 1113.8 1126.3 1138.7 1151.3 1163.6 1176.0 1188.3 1200.7 1212.9 1225.2 1237.6 1249.6 1261.9 1273.8 M.D. T.V.D. 0.0 100.1 200.0 300.1 400.7 0.0 100.1 200.0 300.1 400.6 . CLEARANCE LI5TING Page 10 Your ref KBU 11-8X Ver 3 Last revised : Il-Feb-2004 MWD <0-7440>"KBU 44-6,Pad 41-7 Rect Coordinates 91. 65 91. 55 91.15 90.55 89.75 88.15 84.65 78.75 75.05 74.05 73.15 72 .25 71. 25 70.35 69.45 68.55 67.75 66.85 65.95 65.15 64.35 63.55 62.75 61.95 61. 25 60.55 59.95 59.35 58.85 58.35 57.95 57.55 57.15 56.85 56.55 56.15 55.85 55.55 55.25 54.95 54.75 54.45 54.25 53.95 53.75 53.55 53.35 53.15 52.95 52.85 52.75 69.6E 70.2E 70.7E 71.2E 71. 6E 72 .1E 72 .5E 72.9E 73.3E 73.6E 73.9E 74.2E 74.5E 74.7E 74.9E 75.1E 75.3E 75.5E 75.7E 75.8E 75.9E 76.0E 76.1E 76.1E 76.1E 76.2E 76.2E 76.3E 76.3E 76.3E 76.4E Horiz MinIm Bearing Dist 44.8E 45.0E 45.5E 46.6E 47.6E 153.9 153.8 153.4 152.8 152.0 TCyl Dist 102.0 101.9* 101.8* 101.8* 101.5* 102.0 101.9* 101.8* 101.8* 101.5* 501.2 601.8 702.3 752.4 764.8 501.2 601.6 701.8 751. 7 764.0 49.1E 52.4E 58. IE 61. 3E 62.1E 150.9 148.2 143.6 140.7 140.0 100.9* 99.6* 97.8* 96.9* 96.7* 100.9* 99.6* 97.8* 96.9* 96.7* 777.3 789.8 802.4 814.9 827.3 776.5 788.9 801.4 813.8 826.2 63.0E 63.7E 64.5E 65.3E 66.0E 139.3 138.7 138.0 137.4 136.9 96.4* 96.1* 95.9* 95.5* 95.1* 96.4* 96 .2* 95.9* 95.6* 95.2* 840.1 852.6 865.2 877.7 890.2 839.0 851.4 864.0 876.4 888.8 66.7E 67.3E 67.9E 68.5E 69.1E 136.4 135.9 135.5 135.1 134.7 94.7* 94.3* 93.7* 93.2* 92.6* 94.8* 94.3* 93.8* 93.3* 92.7* 902.7 915.1 927.5 940.0 952.4 901.3 913.7 926.1 938.5 950.9 134.4 134.1 133.9 133.6 133.5 133.4 133.3 133.4 133.4 133.6 133.8 134.0 134.3 134.7 135.2 135.6 136.2 136.8 137.4 138.2 139.0 139.9 140.8 141. 9 143.1 144.3 145.7 147.1 148.6 150.3 152.1 92 .0* 91.3* 90.6* 89.9* 89.1* 92.1* 91. 4 * 90.8* 90.0* 89.3* 963.2 975.6 987.9 1000.3 1012.8 1025.0 1037.5 1049.9 1062.3 1074.7 1087.3 1099.7 1112.1 1124.7 1137.1 1149.6 1162.0 1174.3 1186.7 1199.0 1211.2 1223.5 1235.9 1247.9 1260.2 1272 .1 88.4* 87.5* 86.7* 85.9* 85.0* 88.5* 87.7* 86.9* 86.1* 85.2* 84.1* 83.1* 82.2* 81. 2* 80.1* 84.3* 83.4* 82.4* 81.4* 80.4* 79.1* 78.0* 76.8* 75.7* 74.4* 79.4* 78.3* 77.2* 76.0* 74.8* 73.2* 71.9* 70.6* 69.3* 68.0* 73.6* 72 .3* 71. 0* 69.7* 68.4* 66.7* 65.5* 64.2* 63.0* 61.8* 67.1* 65.8* 64.5* 63.3* 62.1* 60.7* 60.9* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LI8TING Page 11 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 11-Feb-2004 Reference wellpath Object wellpath MWD <0-7440>"KBU 44-6,Pad 41-7 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1287.5 1284.4 1. ON 50.3E 1286.1 1284.4 52.78 76.3E 154.1 59.6* 59.8* 1300.0 1296.6 1. ON 52.6E 1298.4 1296.7 52.78 76.3E 156.2 58.7* 58.9* 1312.5 1308.9 1. IN 55.0E 1310.4 1308.7 52.78 76.3E 158.5 57.8* 58.0* 1325.0 1321.1 1. IN 57.5E 1322.6 1320.9 52.88 76.2E 160.9 57.1* 57.2* 1337.5 1333.4 1. 2N 60.0E 1334.9 1333.2 52.98 76.1E 163.4 56.4* 56.5* 1350.0 1345.6 1.2N 62.6E 1347.1 1345.4 52.98 76.0E 166.1 55.8* 55.9* 13 62.5 1357.8 1. 3N 65.2E 1359.3 1357.6 53.08 75.9E 168.8 55.3* 55.4* 1375.0 1370.1 1.3N 67.9E 1371. 3 1369.6 53.18 75.8E 171.7 55.0* 55.0* 1387.5 1382.3 1. 4N 70.6E 1383.5 1381.8 53.28 75.7E 174.7 54.8* 54.8* 1400.0 1394.4 1. 4N 73.4E 13 95.6 1393.9 53.38 75.6E 177.7 54.8* 54.8* 1412.5 1406.6 1.5N 76.2E 1407.5 1405.8 53.58 75.5E 180.8 55.0 55.0 1425.0 1418.8 1.5N 79.1E 1419.6 1417.9 53.68 75.4E 183.9 55.3 55.4 1437.5 1430.9 1. 6N 82.1E 1431.7 1430.0 53.88 75.3E 187.0 55.9 55.9 1450.0 1443.1 1. 7N 85.1E 1443.8 1442.1 54.08 75.2E 190.1 56.6 56.7 1462.5 1455.2 1. 7N 88.1E 1456.1 1454.4 54.28 75.0E 193.2 57.4 57.6 1475.0 1467.3 1. 8N 91. 2E 1468 . 2 1466.5 54.38 74.9E 196.2 58.4 58.7 1487.5 1479.4 1. 8N 94.4E 1480.2 1478.5 54.48 74.7E 199.2 59.6 60.0 1500.0 1491.5 1. 9N 97.6E 1492.3 1490.6 54.68 74.6E 202.2 61. 0 61. 4 1512.5 1503.5 2. ON 100.9E 1504.3 1502.6 54.78 74.4E 205.0 62.5 63.1 1525.0 1515.6 2.0N 104.2E 1516.2 1514.5 54.88 74.3E 207.7 64.3 65.0 1537.5 1527.6 2.1N 107.5E 1528.2 1526.5 55.08 74.1E 210.4 66.1 67.0 1550.0 1539.6 2.2N 111.0E 1540.2 1538.5 55.18 73.9E 212.9 68.2 69.3 1562.5 1551.7 2.2N 114.4E 1552.1 1550.4 55.28 73.8E 215.3 70.4 71. 7 1575.0 1563.6 2.3N 118.0E 1564.0 1562 . 3 55.48 73.6E 217.6 72.8 74.3 1587.5 1575.6 2.4N 121.5E 1575.9 1574.2 55.58 73.4E 219.7 75.3 77 .0 1600.0 1587.6 2.4N 125.2E 1587.8 1586.1 55.78 73.2E 221.8 77.9 79.9 1612.5 1599.5 2.5N 128.8E 1599.7 1598.0 55.88 73.0E 223.7 80.7 83.0 1625.0 1611.5 2.6N 132.6E 1611. 6 1609.9 55.98 72.8E 225.6 83.6 86.2 1637.5 1623.4 2.7N 13 6. 4E 1623.6 1621. 8 56.18 72.7E 227.3 86.6 89.5 1650.0 1635.3 2.7N 14 0 . 2E 1635.4 1633.7 56.28 72.5E 229.0 89.8 92.9 1662.5 1647.1 2.8N 144.1E 1647.2 1645.5 56.38 72.3E 230.5 93.0 96.5 1675.0 1659.0 2.9N 14 8. OE 1659.3 1657.5 56.58 72.2E 232.0 96.3 100.1 1687.5 1670.9 3.0N 152.0E 1671.1 1669.3 56.68 72.0E 233.3 99.7 103.9 1700.0 1682.7 3.0N 156.0E 1682.9 1681.1 56.78 71.9E 234.6 103.2 107.8 1712.5 1694.5 3.1N 160.1E 1694.6 1692 . 9 56.88 71.8E 235.8 106.8 111.8 1725.0 1706.3 3.2N 164.3E 1706.4 1704.6 56.9S 71.7E 237.0 110.5 115.9 1737.5 1718.1 3.3N 168.5E 1717.8 1716.0 57.08 71.5E 238.1 114.2 120.2 17 50.0 1729.8 3.4N 172 . 7E 1729.5 1727.7 57.18 71. 3E 239.2 118.1 124.5 1762.4 1741.4 3.5N 177.0E 1741. 0 1739.3 57.28 71.2E 240.2 122.0 128.9 1774.7 1753.0 3.5N 181.3E 1753.0 1751.2 57.38 70.9E 241.1 126.0 133.2 17 87.1 1764.6 3.6N 185.6E 1764.5 1762.8 57.48 70.8E 242.0 130.1 137.6 1799.4 1776.1 3.7N 190.0E 1776.0 1774.2 57.48 70.6E 242.9 134.2 142.1 1811.8 1787.7 3.8N 194.5E 1788.9 1787.1 57.48 70.5E 243.7 138.3 146.6 1900.0 1869.9 4.4N 226.4E 1872.8 1871.1 56.78 70.5E 248.6 167.5 177.4 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LISTING Page 12 Pad 41-7,KBUII-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Feb-2004 Reference wellpath Object wellpath MWD <0-8610>"KBU43-7X,Pad 41-7 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 0.0 0.0 9.6S 151.1W 266.4 151.4 151.4 100.0 100.0 O.ON O.OE 97.9 97.9 9.1S 151.6W 266.6 151.9 151.9 200.0 200.0 O.ON O.OE 197.0 197.0 7.7S 153.4W 267.1 153.6 153.6 300.0 300.0 O.ON O.OE 294.1 294.0 5.6S 156.2W 267.9 156.4 156.5 400.0 400.0 O.ON O.OE 387.9 387.7 4.1S 161. 2W 268.6 161. 8 162.3 500.0 500.0 O.ON O.OE 477.5 476.6 3.8S 171. 4W 268.7 173.0 174.7 600.0 600.0 O.ON O.OE 573.6 571. 8 4.8S 185.2W 268.5 187.4 189.6 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUII-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 750.0 762.5 775.0 787.5 800.0 750.0 762.5 775.0 787.5 800.0 812.5 825.0 837.5 850.0 862.5 812.5 825.0 837.5 850.0 862.5 875.0 887.5 900.0 912.5 925.0 875.0 887.4 899.9 912.4 924.9 937.5 950.0 962.5 975.0 987.5 937.4 949.8 962.3 974.8 987.2 1000.0 1012.5 1025.0 1037.5 1050.0 999.7 1012.1 1024.6 1037.0 1049.5 1062.5 1075.0 1087.5 1100.0 1112.5 1061. 9 1074.3 1086.7 1099.1 1111.5 1125.0 1137.5 1150.0 1162.5 1175.0 1123.9 1136.3 1148.7 1161.1 1173.4 1187.5 1200.0 1212.5 1225.0 1237.5 1185.8 1198.2 1210.5 1222.8 1235.2 1250.0 1262.5 1275.0 1287.5 1300.0 1247.5 1259.8 1272 .1 1284.4 1296.6 1312.5 1325.0 1337.5 1350.0 13 62.5 1308.9 1321.1 1333.4 1345.6 1357.8 1375.0 1370.1 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.lN O.lN O.lN O.lN O.lN O.lN O.lN 0.2N 0.2N 0.2N 0.2N 0.2N 0.3N 0.3N 0.3N 0.3N 0.4N 0.4N 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 1. ON 1. ON 1. IN 1. IN 1.2N 1.2N 1. 3N 1.3N 10.9E 12.0E 13.2E 14.4E 15.7E 17.0E 18.4E 19.9E 21. 3E 22.9E 24.5E 26.2E 27.9E 29.6E 31. 5E 33.3E 35.3E 37.2E 39.3E 41.4E 43.5E 45.7E 48.0E 50.3E 52.6E 55.0E 57.5E 60.0E 62.6E 65.2E Object wellpath O.OE O.OE O.lE 0.2E 0.4E 818.8 833.7 845.5 859.6 873.0 M.D. T.V.D. 810.4 824.5 835.5 848.7 861. 2 873.6 884.4 896.3 907.8 919.2 929.9 941.4 952.1 963.6 974.2 985.3 995.8 1006.6 1017.0 1027.7 1038.0 1048.6 1058.9 1069.2 1079.2 1088.7 1099.2 11 08.9 1119.4 1129.9 1140.6 1150.9 1160.8 11 70.7 1180.1 1189.4 1198.2 1206.8 1215.5 1224.3 1232.8 1241.4 1250.1 1258.7 1267.3 1276.3 1285.0 1294.3 1302.9 1312.4 1321.1 . CLEARANCE LISTING Page 13 Your ref KBU 11-8X Ver 3 Last revised : Il-Feb-2004 MSS <4305 - 5701>"KU43-6,Pad 41-7 TCyl Dist Rect Coordinates Horiz Minim Bearing Dist 180.45 175.55 171 .55 166.75 162.05 157.25 153.05 148.35 143.75 139.15 134.75 130.05 125.65 120.85 116.35 111.55 107.1S 102.45 97.95 93.35 88.75 84.15 79.65 75.05 70.65 66.55 62.25 58.25 53.9S 49.65 45.15 40.55 35.95 31. 25 26.55 21. 85 17.15 12.35 7.45 2.55 2.3N 7.3N 12.2N 17.1N 22.0N 27.2N 32.1N 37.3N 42.2N 47.5N 52.4N 9.0E 9.6E 10.0E 10.2E 10.2£ 10.1£ 9.7£ 9.3£ 8.8£ 8.2E 11. 3W 13.0W 14.8W 16.6W 18.5W 20.3W 22.2W 24.1W 26. OW 27.8W 29.7W 31. 5W 33.5W 35.2W 37.1W 4.4E 5.5E 6.4E 7.4E 8.3E 178.6 178.2 177.9 177.5 177.2 190.2 186.2* 182.0* 177.7* 173.4* 198.9 195.5* 191. 8 * 188.0* 183.9* 0.7E 1. OE 1.3E 1. 7E 2.2E 886.3 897.9 910.7 923.1 935.4 177.0 176.8 176.7 176.6 176.7 176.9 177 .2 177.6 178.0 178.6 7.6E 6.9E 6.2£ 5.5E 4.8£ 179.3 180.0 180.9 181. 9 183.1 168.9* 164.4* 159.8* 155.1* 150.5* 179.7* 175.4* 170.9* 166.4* 161.7* 2.7E 3.3E 3.9E 4.6E 5.3E 946.9 959.4 970.9 983.4 994.9 4.0£ 3.2£ 2.4E 1. 7E 0.9£ 184.4 186.0 187.7 189.6 191.8 145.7* 141.0* 136.2* 131. 3* 126.4* 156.9* 152.1* 147.1* 142.1* 137.0* 6.1E 7.0E 7.9E 8.8E 9.8E 1007.0 1018.4 1030.2 1041.6 1053.3 0.2E 0.6W 1. 3W 2.1W 3. OW 194.1 196.9 199.9 203.4 207.4 121.5* 116.6* 111.7* 106.8* 102.0* 131.9* 126.7* 121.4* 116.1* 110.8* 1064.6 1076.2 1087.5 1098.8 1109.7 1120.1 1131.4 1142.0 1153.3 1164.7 11 76.3 1187.7 1198.7 1209.7 1220.4 1231.0 1241.1 1251.0 1261.2 1271.4 1281. 4 1291.5 1301.7 1311.8 1321.8 1332.4 1342.5 1353.3 13 63.4 1374.5 67.9E 1384.6 4.1W 5.4W 6.7W 8.1W 9.7W 212.2 217.6 223.5 229.9 236.6 97.1* 92 .3* 87.6* 82.9* 78 .3* 105.4* 100.1* 94.8* 89.5* 84.4* 243.4 249.8 255.9 261. 7 266.8 271.3 275.4 278.9 282.0 284.6 287.1 289.2 291.1 292.7 294.3 38.8W 74.0* 69.9* 66.1* 62.6* 59.3* 79.2* 74.3* 69.6* 65.4* 61.5* 56.3* 53.7* 51.7* 50.3* 49.8* 58.0* 54.9* 52.3* 50.5* 49.8* 50.1 51. 4 53.8 57.0 60.9 50.3 52.3 55.8 60.5 66.2 65.5 70.6 76.2 82.0 88.2 72.7 79.8 87.3 95.1 103.2 94.5 101.0 107.6 114.3 121.1 111. 4 119.6 127.4 134.7 141.4 295.6 148.1 128.0 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LISTING Page 14 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 11-Feb-2004 Reference wellpath Object wellpath MSS <4305 - 5701>"KU43-6,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1387.5 1382.3 1. 4N 70.6E 1394.6 1329.8 57.3N 40.4W 296.7 134.9 154.8 1400.0 1394.4 1. 4N 73.4E 1407.5 1340.8 63.4N 42.4W 298.2 141. 9 161.5 1412.5 1406.6 1.5N 76.2E 1426.9 1357.9 72 .3N 44.9W 300.3 148.5 168.3 1425.0 1418.8 1.5N 79.1E 1442.3 1371.7 79.0N 46.4W 301.7 154.8 175.2 1437.5 1430.9 1. 6N 82.1E 1456.1 1384.2 84.7N 47.4W 302.7 160.8 182.3 1450.0 1443.1 1. 7N 85.1E 14 67.0 1394.2 89.1N 48.2W 303.3 166.7 189.4 1462.5 1455.2 1. 7N 88.1E 1479.0 1405.2 94.0N 49.0W 303.9 172.6 196.8 1475.0 14 67.3 1.8N 91.2E 1489.9 1415.1 98.3N 49.7W 304.4 178.6 204.3 1487.5 1479.4 1. 8N 94.4E 1501. 0 1425.3 102.7N 50.4W 304.9 184.6 211. 9 1500.0 14 91. 5 1. 9N 97.6E 1511. 9 1435.2 107.0N 51.1W 305.3 190.6 219.7 1512.5 1503.5 2.0N 100.9E 1522.7 1445.2 111. 3N 51.8W 305.6 196.7 227.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 750.0 762.5 775.0 787.5 800.0 750.0 762.5 775.0 787.5 800.0 812.5 825.0 837.5 850.0 862.5 812.5 825.0 837.5 850.0 862.5 875.0 887.5 900.0 912.5 925.0 875.0 887.4 899.9 912.4 924.9 937.5 950.0 962.5 975.0 987.5 937.4 949.8 962.3 974.8 987.2 1000.0 1012.5 1025.0 1037.5 1050.0 999.7 1012.1 1024.6 1037.0 1049.5 1062.5 1075.0 1087.5 1100.0 1112.5 1061.9 1074.3 1086.7 1099.1 1111. 5 1125.0 1137.5 1150.0 1162.5 1175.0 1123.9 1136.3 1148.7 1161.1 1173.4 1187.5 1200.0 1212.5 1225.0 1237.5 1185.8 1198.2 1210.5 1222.8 1235.2 1250.0 1262.5 127 5.0 1287.5 1300.0 1247.5 1259.8 1272 .1 1284.4 1296.6 1312.5 1325.0 1337.5 1350.0 13 62.5 1308.9 1321.1 1333.4 1345.6 1357.8 1375.0 1370.1 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.lN o .1N O.lN O.lN O.lN O.lN O.lN 0.2N 0.2N 0.2N 0.2N 0.2N 0.3N 0.3N 0.3N 0.3N 0.4N 0.4N 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 1. ON 1. ON loIN loIN 1. 2N 1. 2N 1. 3N 1.3N 10.9E 12.0E 13.2E 14.4E 15.7E 17.0E 18.4E 19.9E 21. 3E 22.9E 24.5E 26.2E 27.9E 29.6E 31.5E 33.3E 35.3E 37.2E 39.3E 41.4E 43.5E 45.7E 48.0E 50.3E 52.6E 55.0E 57.5E 60.0E 62.6E 65.2E Object wel1path O.OE O.OE O.lE 0.2E 0.4E 818.8 833.7 845.5 859.6 873.0 M.D. T.V.D. 810.4 824.5 835.5 848.7 861. 2 873.6 884.4 896.3 907.8 919.2 929.9 941.4 952.1 963.6 974.2 985.3 995.8 1006.6 1017.0 1027.7 1038.0 1048.6 1058.9 1069.2 1079.2 1088.7 1099.2 1108.9 1119.4 1129.9 1140.6 1150.9 1160.8 1170.7 1180.1 1189.4 1198.2 1206.8 1215.5 1224.3 1232.8 1241.4 1250.1 1258.7 1267.3 1276.3 1285.0 1294.3 1302.9 1312.4 1321.1 . CLEARANCE LI5TING Page 15 Your ref KBU 11-8X Ver 3 Last revised : 11-Feb-2004 MWD <4250 - 5740>"KU43-6RD,Pad 41-7 Rect Coordinates Horiz Minim Bearing Dist 180.45 175.55 171.55 166.75 162.05 157.25 153.05 148.35 143.75 139.15 134.75 130.05 125.65 120.85 116.35 111.55 107.15 102.45 97.95 93.35 88.75 84.15 79.65 75.05 70.65 66.55 62.25 58.25 53.95 49.65 45.15 40.55 35.95 31. 25 26.55 21.85 17.15 12.35 7.45 2.55 2.3N 7.3N 12.2N 17.1N 22.0N 27 .2N 32.1N 37.3N 42.2N 47.5N 52.4N 9.0E 9.6E 10.0E 10.2E 10.2E 10.lE 9.7E 9.3E 8.8E 8.2E 11. 3W 13.0W 14.8W 16.6W 18.5W 20.3W 22.2W 24.1W 26. Ow 27.8W 4.4E 5.5E 6.4E 7.4E 8.3E 178.6 178.2 177.9 177.5 177.2 TCyl Dist 190.2 186.2* 182.0* 177.7* 173.4* 198.9 195.5* 191.8* 188.0* 183.9* 0.7E 1. OE 1.3E 1. 7E 2.2E 886.3 897.9 910.7 923.1 935.4 177.0 176.8 176.7 176.6 176.7 176.9 177.2 177.6 178.0 178.6 7.6E 6.9E 6.2E 5.5E 4.8E 179.3 180.0 180.9 181. 9 183.1 168.9* 164.4* 159.8* 155.1* 150.5* 179.7* 175.4* 170.9* 166.4* 161.7* 2.7E 3.3E 3.9E 4.6E 5.3E 946.9 959.4 970.9 983.4 994.9 4.0E 3.2E 2.4E 1. 7E 0.9E 184.4 186.0 187.7 189.6 191. 8 145.7* 141.0* 136.2* 131. 3* 126.4* 156.9* 152.1* 147.1* 142.1 * 137.0* 6.1E 7.0E 7.9E 8.8E 9.8E 1007.0 1018.4 1030.2 1041. 6 1053.3 0.2E 0.6W 1. 3W 2.1W 3.0W 194.1 196.9 199.9 203.4 207.4 121. 5* 116.6* 111.7* 106.8* 102.0* 131.9* 126.7* 121.4* 116.1* 110.8* 1064.6 1076.2 1087.5 1098.8 1109.7 1120.1 1131. 4 1142.0 1153.3 1164.7 1176.3 1187.7 1198.7 1209.7 1220.4 1231.0 1241.1 1251.0 1261. 2 1271.4 1281.4 1291.5 1301.7 1311.8 1321.8 1332.4 1342.5 1353.3 13 63.4 1374.5 67.9E 1384.6 4.1W 5.4W 6.7W 8.1W 9.7W 212.2 217.6 223.5 229.9 236.6 97.1* 92 .3* 87.6* 82.9* 78.3* 105.4* 100.1* 94.8* 89.5* 84.4* 29.7W 31.5W 33.5W 35.2W 37.1W 38.8W 74.0* 69.9* 66.1* 62.6* 59.3* 79.2* 74.3* 69.6* 65.4* 61.5* 56.3* 53.7* 51.7* 50.3* 49.8* 58.0* 54.9* 52.3* 50.5* 49.8* 243.4 249.8 255.9 261.7 266.8 50.1 51. 4 53.8 57.0 60.9 50.3 52.3 55.8 60.5 66.2 271.3 275.4 278.9 282.0 284.6 72.7 79.8 87.3 95.1 103.2 65.5 70.6 76.2 82.0 88.2 287.1 289.2 291.1 292.7 294.3 111.4 119.6 127.4 134.7 141.4 94.5 101. 0 107.6 114.3 121.1 295.6 128.0 148.1 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier l) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LISTING Page 16 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 11-Feb-2004 Reference wellpath Object we11path MWD <4250 - 5740>"KU43-6RD,Pad 41-7 Horiz Minim TCy1 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1387.5 13 82 .3 1. 4N 70.6E 1394.6 1329.8 57.3N 40.4W 296.7 134.9 154.8 1400.0 1394.4 1. 4N 73.4E 1407.5 1340.8 63.4N 42.4W 298.2 141.9 161. 5 1412.5 1406.6 1. 5N 76.2E 1426.9 1357.9 72 .3N 44.9W 300.3 148.5 168.3 1425.0 1418.8 1. 5N 79.1E 1442.3 1371.7 79.0N 46.4W 301.7 154.8 175.2 1437.5 1430.9 1. 6N 82.1E 1456.1 1384.2 84.7N 47.4W 302.7 160.8 182.3 1450.0 1443.1 1. 7N 85.1E 1467.0 1394.2 89.1N 48.2W 303.3 166.7 189.4 14 62 . 5 1455.2 1. 7N 88.1E 1479.0 1405.2 94.0N 49. OW 303.9 172.6 196.8 14 75.0 1467.3 1. 8N 91. 2E 1489.9 1415.1 98.3N 49.7W 304.4 178.6 204.3 1487.5 1479.4 1. 8N 94.4E 1501.0 1425.3 102.7N 50.4W 304.9 184.6 211.9 1500.0 1491. 5 1. 9N 97.6E 1511.9 1435.2 107.0N 51.1W 305.3 190.6 219.7 1512.5 1503.5 2. ON 100.9E 1522.7 1445.2 III . 3N 51.8W 305.6 196.7 227.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 1100.0 1112.5 1125.0 1137.5 1150.0 1099.1 1111.5 1123.9 1136.3 1148.7 1162.5 1175.0 1187.5 1200.0 1212.5 1161.1 1173.4 1185.8 1198.2 1210.5 1225.0 1237.5 1250.0 1262.5 1275.0 1222.8 1235.2 1247.5 1259.8 1272 .1 1287.5 1300.0 1312.5 1325.0 1337.5 1284.4 1296.6 1308.9 1321.1 1333.4 1350.0 13 62 . 5 1375.0 1387.5 1400.0 1345.6 1357.8 1370.1 1382.3 1394.4 1412.5 1425.0 1437.5 1450.0 1462.5 1406.6 1418.8 1430.9 1443.1 1455.2 1475.0 1487.5 1500.0 1512.5 1525.0 1467.3 1479.4 1491. 5 1503.5 1515.6 1537.5 1550.0 1562.5 1575.0 1587.5 1527 . 6 1539.6 1551.7 1563.6 1575.6 1600.0 1612.5 1625.0 1637.5 1650.0 1587.6 1599.5 1611.5 1623.4 1635.3 1662.5 1675.0 1687.5 1700.0 1712.5 1647.1 1659.0 1670.9 1682.7 1694 . 5 1725.0 1706.3 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 1. ON 1. ON loIN loIN 1.2N 1.2N 1.3N 1. 3N 1. 4N 1. 4N 1. 5N 1. 5N 1. 6N 1. 7N 1. 7N 1.8N 1. 8N 1. 9N 2.0N 2.0N 2.1N 2.2N 2.2N 2.3N 2.4N 2.4N 2.5N 2.6N 2.7N 2.7N 2.8N 2.9N 3.0N 3.0N 3.1N 3.2N 76.2E 79.1E 82.1E 85.1E 88.1E 91. 2E 94.4E 97.6E 100.9E 104.2E 107.5E 111. OE 114.4E 118.0E 121.5E 125.2E 128.8E 132.6E 13 6. 4E 140.2E 144.1E 148.0E 152.0E 156.0E 160.1E 164.3E Object wel1path 21. 3E 22.9E 24.5E 26.2E 27.9E 1198.6 1209.8 1221. 0 1234.8 1245.9 M.D. T.V.D. 1159.7 1169.6 1179.6 1191.7 1201.4 1213 .1 1222.6 1232.1 1241. 8 1251.2 1260.5 1268.9 1278.3 1287.6 1296.9 1305.4 1314.7 1324.0 1332.5 1341.8 1351.2 13 60 . 4 1369.7 1379.0 1388.3 1397.6 1406.9 1416.7 1425.9 1435.1 1444.4 1453.6 1462.8 1472.2 1481.4 14 90.5 14 99.6 1508.7 1517.9 1526.9 1536.0 1545.0 1554.1 1563.1 1571.9 1580.8 1589.8 1598.7 1607.6 1616.6 1624.6 . CLEARANCE LISTING Page 17 Your ref KBU 11-8X Ver 3 Last revised : 11-Feb-2004 MSS <0-5300'>,,43-6A,Pad 41-7 Rect Coordinates 153.7S 148.8S 143.8S 137.5S 132.4S 126.0S 120.8S 115.5S 109.9S 104.5S 99.1S 94.3S 88.9S 83.6S 78.2S 73.4S 68.0S 62.7S 57.8S 52.5S 47.2S 41.9S 36.5S 31.2S 25.8S 20.5S 15.1S 9.4S 4.0S 1.4N 6.8N 12.2N 17.6N 23.2N 28.6N 34.1N 39.5N 45.0N 50.4N 55.9N 61.4N 66.8N 72 .3N 77.8N 83.2N 88.6N 94.1N 99.6N 105.2N 11 0 . 7N 115.7N 131. 2E 132.7E 134.2E 13 6. IE 13 7. 7E 139.6E 141.2E 14 2. 9E 144.6E 146.3E 148.0E 149.5E 151.3E 153.1E 154.9E 156.6E 158.5E 160.4E 162.1E 164.1E 166.1E 168.1E 17 O. IE 172 . 2E 17 4. 2E 176.2E 178 . 2E 180.3E 182.3E 184.2E 186.2E 188.1E 190.0E 192.0E 193.9E 195.7E 197.6E 199.5E 201. 3E 203.1E 205.0E 206.8E 208.6E 210.3E 212.1E 213 . 8E 215.6E 217 . 3E 219.0E 220.7E 222.2E Horiz Minim Bearing Dist 115.1 112.7 110.3 107.8 105.1 102.4 99.5 96.4 93.4 90.2 TCy1 Dist 144.5 143.7 142.7 141. 4 140.4 198.7 194.2* 189.6* 185.0* 180.3* 212.1 207.7* 203.2* 198.7* 194.1* 29.6E 31. 5E 33.3E 35.3E 37.2E 1259.3 1270.3 1281.3 1292.7 1303.6 139.0 137.9 136.7 135.3 134.0 175.6* 170.9* 166.2* 161.5* 156.9* 189.3* 184.5* 179.6* 174.7* 169.7* 39.3E 41.4E 43.5E 45.7E 48.0E 1314.5 1324.3 1335.2 1346.1 1357.0 132.6 131. 3 129.8 128.2 126.5 152.4* 147.9* 143.6* 139.4* 135.4* 164.6* 159.5* 154.4* 149.4* 144.4* 50.3E 52.6E 55.0E 57.5E 60.0E 1366.9 1377.8 1388.7 1398.7 1409.6 125.0 123.1 121.2 119.4 117.3 131.4* 127.7* 124.1* 120.6* 117.4* 139.6* 135.0* 130.5* 126.3* 122.2* 62.6E 65.2E 67.9E 70.6E 73.4E 1420.5 1431.4 1442.3 1453.2 1464.1 114.4* 111.6* 109.0* 106.7* 104.6* 118.5* 115.0* 111.8* 108.9* 106.3* 1475.0 1486.0 1497.5 1508.3 1519.2 1530.0 1540.9 1551.8 1562.9 1573.7 1584.5 1595.3 1606.1 1616.9 1627.6 1638.4 1649.1 1659.8 1670.5 1680.9 1691.6 1702.2 1712.9 1723.5 17 34.1 1743.7 102.7* 101.1* 99.8* 98.8* 98.2* 104.0* 102.0* 100.4* 99.1* 98.3* 87.0 83.7 80.4 76.9 73.5 97.8* 97.7* 98.0 98.7 99.6 97.8* 97.7* 98.1 98.9 100.2 70.1 66.7 63.3 60.0 56.7 100.9 102.5 104.4 106.6 109.1 101.8 103.8 106.3 109.1 112.3 53.6 50.5 47.5 44.6 41. 8 111.8 114.8 118.0 121.5 125.1 115.8 119.6 123.7 128.0 132.7 39.1 36.5 34.0 31.7 29.4 129.0 133.0 137.2 141.5 146.0 137.5 142.6 148.0 153.5 159.3 27.3 150.6 165.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LISTING Page 18 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field, Kenai Peninsula, Alaska Last revised : 11-Feb-2004 Reference wellpath Object we11path MSS <0-5300'>,,43-6A,Pad 41-7 Horiz Minim TCy1 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1737.5 1718.1 3.3N 168.5E 1754.3 1633.5 121. 2N 223.9E 25.2 155.3 171.5 1750.0 1729.8 3.4N 172 . 7E 17 64.8 1642.3 126.7N 22 5. 6E 23.2 160.2 177.9 1762.4 1741.4 3.5N 177 . OE 1775.2 1651. 0 132.2N 227.2E 21.3 165.2 184.4 1774.7 1753.0 3.5N 181. 3E 1784.0 1658.2 136.8N 228.6E 19.5 170.3 191.1 1787.1 1764.6 3.6N 185.6E 1794.3 1666.8 142.3N 230.2E 17.8 175.4 197.9 1799.4 1776.1 3.7N 190.0E 1804.6 1675.4 147.9N 231.7E 16.1 180.7 204.9 1811.8 1787.7 3.8N 194.5E 1814.9 1684.0 153.4N 233.3E 14 .5 186.1 212.1 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 750.0 762.5 500.0 600.0 700.0 750.0 762.5 775.0 787.5 800.0 812.5 825.0 775.0 787.5 800.0 812.5 825.0 837.5 850.0 862.5 875.0 887.5 837.5 850.0 862.5 875.0 887.4 900.0 912.5 925.0 937.5 950.0 899.9 912.4 924.9 937.4 949.8 962.5 975.0 987.5 1000.0 1012.5 962.3 974.8 987.2 999.7 1012.1 1025.0 1037.5 1050.0 1062.5 1075.0 1024.6 1037.0 1049.5 1061.9 1074.3 1087.5 1100.0 1112.5 1125.0 1137.5 1086.7 1099.1 1111.5 1123.9 1136.3 1150.0 1162.5 1175.0 1187.5 1200.0 1148.7 1161.1 1173.4 1185.8 1198.2 1212.5 1225.0 1237.5 1250.0 1262.5 1210.5 1222.8 1235.2 1247.5 1259.8 1275.0 1272.1 O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.ON O.lN O.lN O.lN O.lN O.lN O.lN O.lN 0.2N 0.2N 0.2N 0.2N 0.2N 0.3N 0.3N 0.3N 0.3N 0.4N 0.4N 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 7.9E 8.8E 9.8E 10.9E 12.0E 13.2E 14.4E 15.7E 17.0E 18.4E 19.9E 21. 3E 22.9E 24.5E 26.2E 27.9E 29.6E 31. 5E 33.3E 35.3E 37.2E 39.3E 41.4E 43.5E 45.7E 48.0E Object wellpath O.OE O.OE O.OE O.OE O.OE O.OE O.OE O.OE O.OE O.OE O.lE 0.2E 0.4E 0.7E 1. OE 1.3E 1. 7E 2.2E 2.7E 3.3E 3.9E 4.6E 5.3E 6.1E 7.0E 959.2 971.7 984.3 996.8 1009.2 1021.7 1034.1 1046.6 1059.0 1071. 5 1083.8 1096.2 1108.6 1121.0 1133.0 1145.4 1157.8 11 70.2 1182.4 1194.8 1207.1 1219.5 1232.0 1244.4 1256.7 1269.0 M.D. T.V.D. 0.0 95.4 195.5 295.5 395.3 4.6 100.0 200.1 300.1 399.9 . CLEARANCE LI8TING Page 19 Your ref KBU 11-8X Ver 3 Last revised : 11-Feb-2004 MWD <0-8405>"KBU33-6X,Pad 41-7 Rect Coordinates 5.78 5.68 5.68 5.48 5.38 5.38 5.28 4.78 4.78 4.78 4.78 4.78 4.78 4.68 4.68 4.68 4.58 4.58 4.48 4.48 4.38 4.38 4.28 4.28 4.18 4.18 4.18 4.08 4.08 4.08 4.08 4.08 4.08 3.98 3.98 3.98 3.98 3.98 3.98 3.88 3.78 3.68 3.58 3.48 3.28 3.18 2.98 2.78 2.68 2.48 2.28 105.8W 105.8W 105.7W 105.7W 105.7W 105.6W 104.9W 104.2W 103.9W 103.7W 103.6W 103.5W 103.3W 103.2W 103.0W 102.9W 102.7W 102.6W 102.4W 102.2W 102.1W 101.9W 101.7W 101. 6W 101.4W 101. 2W 101.lW 100.9W 100.7W 100.5W 100.3W 100.2W 100.0W 99.8W 99.6W 99.4W 99.2W 99.1W 98.9W 98.7W 98.6W 98.5W 98.4W 98.3W 98.2W 98.1W 98.0W 97.9W 97.7W 97.6W 97.5W Horiz Minim Bearing Dist 267.8 267.8 267.8 267.8 267.8 267.9 267.9 267.9 267.9 267.9 267.9 267.9 268.0 268.0 268.0 268.1 268.1 268.2 268.3 268.3 268.4 268.5 268.5 268.6 268.7 268.8 TCyl Dist 266.9 266.9 267.0 267.1 267.2 106.0 105.9* 105.9* 105.8* 105.8* 106.0 105.9* 105.9* 105.8* 105.8* 495.8 596.2 696.1 746.2 759.0 500.4 600.8 700.7 750.8 763.6 267.1 267.2 267.4 267.4 267.4 105.7* 105.0* 104.3* 104.0* 103.9* 105.7* 105.0* 104.3* 104.0* 103.9* 771. 5 784.0 796.7 809.2 821.7 776.1 788.6 801.3 813.8 826.3 267.4 267.4 267.4 267.4 267.5 103.8* 103.8* 103.9 104.0 104.1 103.8* 103.8* 103.9 104.0 104.1 834.2 846.7 859.2 871.7 884.2 838.8 851.3 863.8 876.3 888.8 267.5 267.5 267.5 267.6 267.6 104.3 104.6 104.9 105.2 105.6 104.3 104.6 104.9 105.3 105.7 896.8 909.3 921. 8 934.3 946.8 901.4 913.9 926.4 938.8 951. 3 267.6 267.6 267.7 267.7 267.7 106.1 106.6 107.2 107.8 108.5 106.2 106.7 107.3 107.9 108.6 963.8 976.3 988.9 1001. 3 1013.8 1026.3 1038.7 1051. 2 1063.6 1076.1 1088.3 1100.8 1113.2 1125.6 1137.6 1150.0 1162.4 1174.7 1187.0 1199.3 1211.7 1224.0 1236.6 1248.9 1261.2 1273.5 109.2 110.0 110.8 111.7 112.6 109.4 110.2 111.1 112.0 113.0 113.6 114.7 115.8 116.9 118.1 114.0 115.1 116.2 117.4 118.7 119.4 120.7 122.0 123.5 125.0 120.0 121.4 122.8 124.4 126.0 126.6 128.2 129.9 131.7 133.5 127.6 129.4 131. 2 133.1 135.0 135.4 137.3 139.3 141.3 143.4 137.0 139.0 141.1 143.2 145.4 145.5 147.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LISTING Page 20 Pad 41-7,KBUII-8x Your ref KBU 11-8X Ver 3 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Feb-2004 Reference wellpath Object wellpath MWD <0-8405>"KBU33-6X,Pad 41-7 Horiz MinIm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1287.5 1284.4 1. ON 50.3E 1281.5 1286.0 2.0S 97.4W 268.8 147.7 150.0 1300.0 1296.6 1. ON 52.6E 1293.8 1298.3 1. 9S 97.2W 268.9 149.9 152.4 1312.5 1308.9 1. IN 55.0E 1306.1 1310.6 1. 7S 97.1W 269.0 152.2 154.8 1325.0 1321.1 1. IN 57.5E 1318.4 1322.9 1.5S 96.9W 269.0 154.5 157.3 1337.5 1333.4 1. 2N 60.0E 1330.8 1335.3 1.3S 96.8W 269.1 156.9 159.8 1350.0 1345.6 1.2N 62.6E 1343.0 1347.6 1.2S 96.7W 269.1 159.3 162.4 13 62.5 1357.8 1.3N 65.2E 1355.3 1359.8 1. OS 96.5W 269.2 161. 8 165.1 1375.0 1370.1 1. 3N 67.9E 1368.0 1372.5 0.9S 96.4W 269.2 164.3 167.8 1387.5 1382.3 1. 4N 70.6E 1380.2 1384.7 0.7S 96.2W 269.3 166.9 170.5 1400.0 1394.4 1. 4N 73.4E 13 92.4 1396.9 0.6S 96. OW 269.3 169.5 173.3 1412.5 1406.6 1. 5N 76.2E 1404.6 1409.2 0.4S 95.8W 269.4 172 .1 176.1 1425.0 1418.8 1.5N 79.1E 1417.6 14 22 . 1 0.3S 95.6W 269.4 174.8 179.0 1437.5 1430.9 1. 6N 82.1E 1429.8 1434.3 O.IS 95.4W 269.4 177 .5 181.9 1450.0 1443.1 1. 7N 85.1E 1442.0 1446.5 O.ON 95.2W 269.5 180.3 184.9 1462.5 1455.2 1. 7N 88.1E 1454.1 1458.6 0.2N 95.0W 269.5 183.1 188.0 14 75.0 1467.3 1. 8N 91. 2E 1466.5 1471. 0 0.3N 94.7W 269.6 186.0 191.2 1487.5 1479.4 1. 8N 94.4E 1478.7 14 83.2 0.5N 94.5W 269.6 188.9 194.4 1500.0 1491. 5 1. 9N 97.6E 1490.4 14 94.9 0.7N 94.2W 269.6 191.9 197.7 1512.5 1503.5 2.0N 100.9E 1502.6 1507.1 0.9N 94.0W 269.7 194.9 201.1 1525.0 1515.6 2.0N 104.2E 1514.7 1519.2 1.1N 93.8W 269.7 198.0 204.5 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUII-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Pad 41-7,KBUll-8X Kenai Gas Field,Kenai Peninsula, Alaska M.D. T.V.D. Reference wellpath Rect Coordinates 825.0 837.5 850.0 862.5 875.0 825.0 837.5 850.0 862.5 875.0 887.5 900.0 912.5 925.0 937.5 887.4 899.9 912.4 924.9 937.4 950.0 962.5 975.0 987.5 1000.0 949.8 962.3 974.8 987.2 999.7 1012.5 1025.0 1037.5 1050.0 1062.5 1012.1 1024.6 1037.0 1049.5 1061. 9 1075.0 1087.5 1100.0 1112.5 1125.0 1074.3 1086.7 1099.1 1111.5 1123.9 1137.5 1150.0 1162.5 1175.0 1187.5 1136.3 1148.7 1161.1 1173.4 1185.8 1200.0 1212.5 1225.0 1237.5 1250.0 1198.2 1210.5 1222.8 1235.2 1247.5 1262.5 1275.0 1287.5 1300.0 1312.5 1259.8 1272 .1 1284.4 1296.6 1308.9 1325.0 1337.5 1350.0 13 62.5 1375.0 1321.1 1333.4 1345.6 1357.8 1370.1 1387.5 1400.0 1412.5 1425.0 1437.5 1382.3 1394.4 1406.6 1418.8 1430.9 14 50.0 1443.1 O.ON O.ON O.ON O.ON O.lN O.lN O.lN O.lN O.lN O.lN O.lN 0.2N 0.2N 0.2N 0.2N 0.2N 0.3N 0.3N 0.3N 0.3N 0.4N 0.4N 0.4N 0.4N 0.5N 0.5N 0.5N 0.6N 0.6N 0.7N 0.7N 0.7N 0.8N 0.8N 0.8N 0.9N 0.9N 1. ON 1. ON loIN loIN 1. 2N 1. 2N 1.3N 1.3N 1. 4N 1. 4N 1. 5N 1. 5N 1. 6N 1. 7N 7.0E 7.9E 8.8E 9.8E 10.9E 12.0E 13.2E 14.4E 15.7E 17.0E 18.4E 19.9E 21. 3E 22.9E 24.5E 26.2E 27.9E 29.6E 31.5E 33.3E 35.3E 37.2E 39.3E 41. 4E 43.5E 45.7E 48.0E 50.3E 52.6E 55.0E Object wellpath 1. OE 1. 3E 1. 7E 2.2E 2.7E 867.7 882.3 894.6 909.3 923.9 M.D. T.V.D. 861. 3 875.7 887.8 902.1 916.4 928.3 942.5 954.4 968.4 980.2 994.1 1005.9 1019.6 1031. 3 1044.9 1056.5 1069.9 1081.4 1094.3 1105.7 1117.2 1128.6 1140.9 1152.4 1163.8 1175.2 1186.6 1198.0 1209.4 1220.1 1231.5 1243.0 1253.8 1265.3 1276.8 1288.3 1299.8 1311.9 1323.3 1334.8 1346.8 1358.1 1370.2 1381.5 1392.8 1404.9 1416.1 1427.3 1439.1 1450.2 1461. 3 . CLEARANCE LI8TING Page 21 Your ref KBU 11-8X Ver 3 Last revised : Il-Feb-2004 GM8 <0-8120'>"KU13-5,Pad 41-7 TCyl Dist Rect Coordinates Horiz MinIm Bearing Dist 189.08 186.58 184.48 181.88 179.18 176.88 173.98 171.48 168.48 165.78 162.58 159.88 156.48 153.58 150.08 146.98 143.38 140.18 136.58 133.28 129.98 126.68 123.08 119.68 116.28 112.88 109.48 106.08 102.68 99.58 96 .28 92.98 89.88 86.58 83.38 80.18 76.88 73.38 70.08 66.78 63.28 59.88 56.18 52.78 49.28 45.48 41.88 38.28 34.38 30.58 26.88 51.6W 50.1W 48.8W 47.2W 45.6W 44.2W 42.5W 41.1W 39.3W 37.9W 36.1W 34.6W 32.8W 31. 3W 29.4W 27.8W 26. Ow 24.3W 22.5W 20.8W 19.2W 17.6W 15.8W 14.2W 12.6W 10.9W 9.3W 7.7W 6.1W 4.6W 195.5 195.4 195.3 195.2 195.1 195.0 194.9 194.9 194.9 194.9 194.8 194.9 194.9 195.0 195.0 195.1 195.3 195.4 195.6 195.8 196.1 196.4 196.8 197.2 197.6 3.1W 1. 5W O.OW 1. 6E 3.1E 4.7E 6.3E 7.9E 9.5E 11.1E 12.8E 14.5E 16.2E 17.8E 19.5E 21. 3E 23.0E 24.7E 26.5E 28.3E 30.0E 199.5 197.3* 195.0* 192.6* 190.1* 202.4 200.3* 198.1* 195.9* 193.6* 3.3E 3.9E 4.6E 5.3E 6.1E 936.2 950.8 963.0 977.4 989.6 187.6* 185.0* 182.4* 179.7* 176.9* 191.3* 188.8* 186.3* 183.8* 181.1* 1004.0 1016.1 1030.4 1042.5 1056.7 1068.8 1082.8 1094.9 1108.4 1120.4 1132.4 1144.4 1157.4 1169.4 1181.4 1193.4 1205.5 1217.5 1229.5 1240.7 1252.7 1264.8 1276.1 1288.2 1300.2 1312.3 1324.3 1337.0 1349.0 1361.0 57.5E 60.0E 62.6E 65.2E 67.9E 1373.6 1385.6 1398.4 1410.3 1422.3 174.0* 171.1* 168.1* 165.1* 162.0* 178.4* 175.6* 172.8* 169.9* 166.9* 70.6E 73.4E 76.2E 79.1E 82.1E 1435.0 1446.9 1458.8 1471.4 1483.3 158.8* 155.5* 152.2* 148.9* 145.5* 163.8* 160.7* 157.5* 154.2* 150.9* 85.1E 14 95.1 142.2* 138.8* 135.5* 132.1 * 128.8* 14 7.5* 144.0* 140.6* 137.1 * 133.6* 198.1 198.7 199.3 200.0 200.8 125.4* 122.1* 118.8* 115.6* 112.5* 130.1 * 126.6* 123.2* 119.7* 116.3* 201. 6 202.5 203.5 204.5 205.6 112.9* 109.6* 106.5* 103.4* 100.4* 109.4* 106.4* 103.5* 100.6* 97.8* 206.9 208.2 209.7 211.2 212.9 97.4* 94.6* 91.9* 89.2* 86.5* 95.1* 92.5* 89.9* 87.3* 84.8* 214.8 216.8 219.0 221. 3 223.8 82.4* 80.0* 77.8* 75.6* 73.6* 84.0* 81.4* 79.0* 76.7* 74.5* 226.5 229.4 232.4 235.8 239.1 72 .5* 70.6* 68.8* 67.2* 65.9* 71.6* 69.9* 68.2* 66.8* 65.6* 242.7 64.6* 64.8* All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . . MARATHON Oil Company CLEARANCE LISTING Page 22 Pad 41-7,KBUll-8X Your ref KBU 11-8X Ver 3 Kenai Gas Field, Kenai Peninsula, Alaska Last revised : ll-Feb-2004 Reference wellpath Object wellpath GMS <0-8120'>"KU13-5,Pad 41-7 Horiz Minim TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 1462.5 1455.2 1. 7N 88.1E 1507.4 1472.8 22.8S 31.9E 246.4 63.9* 63.9* 1475.0 1467.3 1. 8N 91. 2E 1519.2 1483.8 19.0S 33.6E 250.2 63.4* 63.4* 1487.5 1479.4 1. 8N 94.4E 1530.9 14 94.8 15.1S 35.4E 253.9 63.3* 63.3* 1500.0 1491.5 1. 9N 97.6E 1543.0 1506.0 11.2S 37.3E 257.7 63.4 63.5 1512.5 1503.5 2.0N 100.9E 1554.7 1517.0 7.38 39.0E 261. 5 63.9 64.0 1525.0 1515.6 2.0N 104.2E 1566.7 1528.1 3.38 40.9E 265.1 64.7 65.0 1537.5 1527.6 2.1N 107.5E 1578.4 1539.0 0.6N 42.7E 268.7 65.9 66.2 1550.0 1539.6 2.2N 111. OE 1590.1 1549.9 4.5N 44.5E 272.0 67.3 67.9 1562.5 1551.7 2.2N 114.4E 1602.0 1560.9 8.5N 46.3E 275.3 69.0 69.9 1575.0 1563.6 2.3N 118.0E 1613.7 1571.7 12.5N 48.2E 278.3 71.0 72 .1 1587.5 1575.6 2.4N 121.5E 1625.4 1582.6 16.5N 50.0E 281.1 73 .2 74.7 1600.0 1587.6 2.4N 125.2E 1637.0 1593.4 20.4N 51. 8E 283.8 75.7 77.6 1612.5 1599.5 2.5N 128.8E 1648.8 1604.3 24.5N 53.7E 286.3 78.4 80.7 1625.0 1611.5 2.6N 132.6E 1660.5 1615.1 28.5N 55.6E 288.6 81.3 84.0 1637.5 1623.4 2.7N 136.4E 1672.2 1625.9 32.5N 57.4E 290.7 84.4 87.5 1650.0 1635.3 2.7N 14 0 . 2E 1683.8 1636.7 36.5N 59.3E 292.6 87.7 91.2 1662.5 1647.1 2.8N 144.1E 1695.5 1647.5 40.5N 61.1E 294.4 91.1 95.1 1675.0 1659.0 2.9N 14 8. OE 1707.1 1658.2 44.5N 63.0E 296.1 94.6 99.1 1687.5 1670.9 3.0N 152.0E 1718.7 1669.0 48.5N 64.9E 297.6 98.3 103.3 1700.0 1682.7 3.0N 156.0E 1730.3 1679.7 52.5N 66.8E 299.0 102.1 107.7 1712.5 1694.5 3.1N 160.1E 1741.9 1690.4 56.6N 68.6E 300.3 106.1 112.1 1725.0 1706.3 3.2N 164.3E 1753.4 1701.1 60.6N 70.5E 301.4 110.1 116.7 17 37.5 1718.1 3.3N 168.5E 17 65.0 1711.8 64.6N 72.3E 302.5 114.2 121. 4 1750.0 1729.8 3.4N 172 . 7E 1776.6 1722.4 68.6N 74.2E 303.5 118.4 126.1 1762.4 1741. 4 3.5N 177.0E 1788.0 1733.0 72.6N 76.0E 304.4 122.6 130.9 1774.7 1753.0 3.5N 181. 3E 1799.5 1743.6 76.6N 77.9E 305.2 126.9 135.8 1787.1 1764.6 3.6N 185.6E 1810.9 17 54.1 80.5N 79.7E 306.0 131.3 140.7 1799.4 1776.1 3.7N 190.0E 1822.3 17 64.7 84.5N 81. 6E 306.7 135.7 145.7 1811.8 1787.7 3.8N 194.5E 1833.7 1775.2 88.4N 83.4E 307.3 140.2 150.8 1900.0 1869.9 4.4N 226.4E 1915.7 1851.1 116.6N 96.5E 310.8 172.7 185.8 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot# KBUll-8X and TVD from RKB (Glacier 1) (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 88.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ! VI~t ReF: HI~z Ref: N()t~th on Un : DL / , ! :. ! RlŒ (Glacíer 1) dot# KBIJ11-8}~ 'ue ll1ellheðd iDDD 3 Vel' ll-ß)< KÐU (56121 mill . Ft O.ÚO Tie 0.00 KOP/EoIH/EoRT 194.53 EoB/EoDH 1207.85 EolH/EoDH 1444.18 KOP/EoDlEoRT/Target 1669.20 EoD/EoDH/Target If - o - 179 CUt'\} . - --1---- E 0.00_ . .. E 194.4.9 _____________ .. r . .__,_.... E 1207.6L _________ .. ____ r. ; ------------ 0 00 -. - ----------- œd.[FJ Po 1 .31' [fJ E/¡'¡ [fJ ~ N 0.00 N 3.80 N 23.59 - N,lS [fJ - 750.00 17Ei7.58 4395.28 ... . . .. TIID Ü'. Em'! B8 . 882 8B.:382 88.882 ~ ~ 88.896 D Inc .. 0.00 21.24 21.24 IB 6.29 [f] -.... . . . . 1811.80 4609.39 5605.46 7657.83 t'1.D . Delete station 1¡.le 11 path? No . . B Shape frorn st.:¡t ion ---_.._- offset ~ Narfl8 : n60 27 34.97:3 lrJ151 14 15.46 frofl'l I t"tsel't North : Tgt ill · · · + field . ~., Polar : 1444.19 88.88 N 28.19 Latitude E 1443.91 Longitude IBmI] (- RQtation Thickness : Delete D PI·:m Options . . DÜrlension 1/;1 Dirrtension 1/;2 ill Marathon Oil Company Well Name: KED 11-8X Location: Kenai, Alaska. N Prepared For: MARATHON OIL COMPANY WelIKBU11..8X Kenai Peninsula, Alaska Prepared by: Tony Tykalsky Reviewed by: Hal Martins Presented to: wm Tank February 18,2004 . . ...-... SfIFE Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: Will Tank Will: Enclosed is the recommended drilling fluid program for the KBU ll-8X well to be drilled this year. The following is a brief synopsis of the program. Overview: KBU ll-8X is a development well targeting the Beluga and Tyonek formations at the Kenai Gas Field. Flo-Pro fluid will be used for the intermediate and production intervals. After logging the production interval, the well will be completed with 3 y;" excape liner cemented in place. Surface Interval: The surface interval will be drilled with the standard Gel/Gelex spud mud. Based on offset well data, no problems are anticipated during this interval. Intermediate Interval: This interval will be drilled with a Flo-Pro fluid. After drilling out the surface cement, the well will be displaced to a standard Flo-Pro KCl fluid. SafeCarb bridging material will be maintained according to the mud program to minimize losses to the formation. Fluid loss should be maintained @ 7 -9 cc' s API Production Interval: This interval will be drilled with the modified Flo-Pro fluid. After drilling out the intermediate cement and 20- 25 feet of new hole, the well will be displaced to a modified Flo-Pro KCl fluid. Fluid loss should be maintained @ < 6 cc' s API for this interval. NOTE: Mud wei2ht as hi2h as 10.6 PP2 may be required to control 2as influx at the bottom of this interval. Completion: This program assumes the well will be completed with 6% KCl brine. Tony Tykalsky Project Engineer M-I Drilling Fluids Reference Wells: KBU 33-6X, KBU 42, KBU 24-6 NOTE: This pr02ram is provided as a !wide onlv. Well conditions will alwavs dictate fluid properties required. r:zi ..FE ~ .tI!!!!/ IIIJt1 ~==¡ IFE ------ - ~ ~ lllFE '. . Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. EXECUTIVE SUMMARY Our overall goal is no M-I/Swaco HSE incidents while providing fluids and solids control services to our customer. Our goal for KBU 11-8X is to remove drill solids from the mud system at a cost of less than $0.23 per pound. This has been the average for the last three years of centrifuge van operations With the revised fluid formulation (increasing the fluid agent concentration and maintaining a lower fluid loss), we expect to minimize formation damage and hole enlargement in the production interval as demonstrated on KBU 43-7X. Use of the MI Swaco centrifuge van for the last three years has provided an estimated savings in dilution and disposal costs to Marathon Oil of over $500,000. With continued usage of our equipment, we expect to provide more savings to you during future operations. r:zj .IFE ~ . . ....... ~~IFE - Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Interval Benchmarks and Targets Drilling Intervals Depth Benchmark 1 Benchmark 2 Benchmark3 BenchmarK\i4: Interval (ft) Fluid cost per foot Volume Usage Solids Removal 0-1500' > $6.45 ft < 1519 bbls 1500 - 5595' > $34.52 ft < 3011 bbls 5595 - 7657' > $31.30 ft < 1316 bbls Total Project Avg. Max. Targets for < $28.15 < 5846 bbls < $0.23 lb ~o Spills from Centrifuge Drilling Van Operation Interval rnJ ..FE ~ Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. GellGelex Spud Mud Screens 150/180 mesh Desilter Centrifuge Van Flo- Pro w/SafeCarb Screens 180 210 mesh Desilter Centrifuge Van 3-112" 8-1/2" 7651' 7221' Flo-Pro w/SafeCarb eens 230 210 mesh Desilter Centrifuge Van 3 112" 8-112" Completion 7651' 7221' 6% KCI 2 >- Utilize all solids control equipment to minimize the build up of drill solids in the system (if possible, centrifuge the surface mud during trips to reduce drill solids). >- Condition the mud prior to running casing for all intervals. >- Cost does not include any considerations for whole mud losses. >- Cost estimate does not anticipate and need for lubricant. >- Cost does not include possible weight up requirements in the production interval. . . Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Product Usage Summary M - I Bar 0 151 197 0 348 2.05 M-I Gel 342 0 0 0 342 2.18 Ge1ex 19 0 0 0 19 0.1 Soda Ash 11 15 7 0 33 0.23 Caustic Soda 15 30 13 0 58 0.70 Con or 404 0 7 4 0 11 5.81 SafeScav NA 3 7 3 0 13 2.25 Bicarb 15 15 13 0 43 0.35 Con or 303 0 0 0 2 2 0.44 FloVis 0 271 105 3 379 34.22 Desco CF 15 0 0 0 15 0.32 Dua1F10 0 0 132 0 132 4.96 Po1ypac UL 12 120 0 0 132 9.48 Greencide 25G 0 0 2 0 2 1.51 Bioban BP Plus 0 241 105 0 346 3.49 KC1 0 1265 553 63 1881 10.85 Safecarb 0 1204 526 0 1730 13.88 SafeK1een 0 1 1 1 3 0.61 Defoam X 0 33 15 0 48 1.94 En ineer Service 5 10 7 2 24 ~ .IFE ~ . . elÆ Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Offset Well Information ud in, dr:'.!;j to casin!JjJoi~~ to Flopro fluid loss) 16.4~fc'rI!;j~~ead, encounter some coal 15.6 Short - backream - some swelling 17.6 Swelling hole - lower FL with Pac 8.4 ~iP()H~()K~ 420.0JP()~-readYÌ() ru~~sinjJ. 22 . 4.4 .1.."Jew mud - drl!;jahead !-rrip OK - d!!!;j ahead Gas - increase mud weight - increase mud weight to casing point Orlg ahead, some losses, 100% losses 4899' pump SafeCarb LCM LCM pill, lost 50 bbls during~ cementi~~ Orlg out, LOT 13.3 8 ¡Hale swellir1g, inc mud we1J~t to 10.0 PPjJ 7.8 ·Orlg ahead ~i.51Drlg;head, inc mud 10.6 I 22 6.60rlg toTO increase mud weigh (gas) 8.85 I 28 I 67 . 7.5 Spud in, drlg to casing point 8.651i2~6t11.~SW~p~h;I€Jprior to runni~g c~.~~ 7 27 I 6.20rlg out, LOT 18.4 ppg 8 20 !6:9~lD~lgah~ad ... ..~ 8 16· ~:8~rI!;j ahead 8 22 8.2 IOrlg ahead 9 22 10~¡erlg~~head 11 27 8 Orlg ahead 7 14 7.8~U~ csg~st returns 8 25 7.7 IOrlg out, LOT 14.5 ppg ~t::~ .~... ..- 27 7.5 ·Orlg ahead, inc mud ppg -- ·--·····7·-·····--······"- 25 6.2 ISpot 16.0 ppg pill on bottom, run liner r:zj ..FE ~~ . . &IÆ Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Plans & Procedures => COMMUNICATION - The Field Mud Engineer will communicate daily with the In-Town Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, possible changes to the mud program, and proposals to use products not included in the mud program. => Whole Mud Losses to the Sterlng AS Sands - Refer to fluid formulas and the Optibridge charts for maintaining proper bridging material concentration in the mud system while drilling the intermediate and production intervals. => FLUID LOSS CONTROL - In the intermediate interval the API fluid loss will be maintained in the 7 - 9 cc's range. In the production interval the API fluid will be maintained at less than 6 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum. It is particularly important to maintain a low hardness «200 ppm Ca) for effective use of DualFlo, therefore cement contamination should be completely treated as rapidly as possible prior to adding DualFlo to control or reduce fluid loss. NOTE: If additions of DualFlo do not appear to be lowering the fluid loss adequately, then switch to additions of Polypac Supreme SL after consultation with town. => LSRV - When drilling with a FloPro fluid, the low shear rate rheology should be maintained around 40,000 cps. In addition to adequate additions of Flo Vis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted high LSRV. => DRILL SOLIDS - MBT - The MBT should be kept at less than 5 ppb in the production interval through aggressive use of solids equipment and dilution as needed. => MIXING CONDITIONS - Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCl should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. => CORROSION - Conqor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of +/- 2000 PPM. => CORRISION - SafeScav NA additions should be made daily as needed with any fluid in the hole. Maintain a DO reading of less than 3 ppm => GREENCIDE 25G ADDITIONS - Greencide 25G additions should be made daily when drilling in the production interval, in the range of 5 gallons per day. => SOLIDS VAN USAGE - The Solids Van should be used whenever drill solids become un-acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the determining condition for when to use the Solids Van. => WEIGHTING UP - All increases in mud weight should be accomplished with barite additions. In the production interval, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. r:lj ..FE ~ . . &FE Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Interval Summary -16" hole o - 1500' Drilling Fluid System Gel/Gel ex Spud Mud Key Products MI Gel / Gelex / Soda Ash / Caustic Soda / MI Bar / PolyPac Supreme UL Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 150 - 180 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions OCntervarDrilllpg FluidProþèrties Depth Mud Funnel Yield API Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (sec.!qt) (lb./1OOft2) (ml/30min) (%) 0- 150' 8.6 - 9.4 60 - 100 25 - 35 NC- 12 +/- 9.5 <7% > Treat drill water with Soda Ash to reduce hardness. > Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 sec.qt funnel viscosity. > Lower funnel viscosity to +/- 75 after gravel zone has been drilled. > Add Gelex as needed to maintain sufficient viscosity for hole cleaning. > Increase funnel viscosity if fill on connections begins to occur. > Reduce fluid loss with additions ofPolypac Supreme UL prior to running surface casing. > Add 2 - 5 PPB ofM-I Seal Fine to mud system if seepage losses becomes a problem.. > Condition mud prior to cementing casing to reduce yield point and gel strengths. > Estimated volume usage for interval- 1519 barrels. > Estimated haul off volume - 2985 barrels. r:zj ".FE ~ . . ~ ~IFE Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Interval Summary - 12-1/4" hole 1500- 5595 .... Drilling Fluid System Flo-Pro Fluid Key Products Flo- Vis / PolyPac UL / KCl / SafeCarb F & M, Asphasol Supreme / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions ~nteryalDrìlling Fluid Properties Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) ( cp.) ( cps ) (m1l30min) (%) 1500 - 3500' 9.0- 9.4 8 -12 40,000 8 - 10 < 9.5 +/- 5% 3500 - 5595 9.4 - 9.6 10 - 14 40,000 7-9 < 9.5 +/- 8% }- Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. }- After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak offtest. }- Maintain DO reading of less than 3 ppm with additions of SaveScav NA. }- Maintain Conqor 404 concentration of 2000+ ppm. }- If running coals become a problem, increase Asphasol Supreme additions. }- Estimated volume usage for interval- 3011 barrels. }- Estimated haul off volume - 4775 barrels. }- Condition mud prior to running 9-5/8" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~ ".FE ~ . . ~IFE Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Intermediate Interval Fluid Formula 12-1/4" Interval from 1500 - 5595' Input Descriøtion KBU 11-8X Mud Wei~ht 9.1 - 9.2 II:: \::)el No Weiç¡ht :GcOdØl MI Bar '" ·â'Oh¢. Weiaht "'L..,leu· SG 4.2 "'I xvv iU/ò . 6 Output - 1 bbl Orderof ··· ;)¡';~,,;î¡ì'¡;f¡¡; ··0. .. Tìifiéld.lilb xliãb!&êìm iìifìøld..·lbblx .1ia.bd0&mf&c. x. ~ 1 Water 298.70 298.70 0.853 298.70 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 Flovis 2.00 2.00 0.004 1.33 Viscosity 4 POlypac Supreme UL 2.00 2.00 0.004 1.25 Fluid Loss Control 5 Caustic Soda 0.50 0.50 0.001 0.23 DH Control 6 Potassium Chloride 19.07 19.07 0.023 7.98 Inhibition 7A SafeCarb F 2.00 2.00 0.002 0.72 Bridaina Aaent 7B SafeCarb M 18.00 18.00 0.018 6.48 Bridaina Aaent If bit ballina becomes a Droblem, add the followina: 9 0-0 CWT 1.00 1.00 0.003 I 1.00 Reduce BHA Balling If torque becomes a Droblem, or slidina is difficult, add UD to 3% of the followina: 10 Lubetex 7.00 7.00 0.021 7.21 Lubricitv Total 399 399 1.000 350 MUd 9.500 -,-¡¡ 3011 Barrels TotalChlol"ide 29600 r:zi .IFE ~ Marathon Oìl Company Well Name: KBD 11-8X Location: Kenai, Alask(l. - © 1999-2001 M-II-,I-,C. - AU Rights Rèserved 1.0 0.9 0.8 c 0 :¡:;¡ 0.7 ::I .0 '¡: .... '" ¡s 0.6 ... N Ü; ... 0.5 -¡:¡ 'E ('I a.. 0.4 ... :> i :¡ 0.3 E :::! u 0.2 0.1 I f)(10"z I 1)(10° 1x10Z K8U 1 MIX Sand Brand Name S"'SlIfe-Carb 10 (F) D-Safe-Carb 40 (M) E"'Safe-Carb 250 (C) S 6.4% D 1)(103 1 )(1 (14 Calcium Avg Error 0 - Max Error 0 -100 % CPS Marathon Oil Company Well Name: KED 1l·8X Location: Kenai, Alaska. Co. Max Permeability ~ Sand COntrol DeVIce: © 1999-2001 M-I L.L.C - All Rights Re$erved 1.0 0.9 0.8 !: Q ;¡;;¡ 0.7 ::: ..0 E ill Q 0.6 ... N (i) . ... 0.5 Ü :e «I Il.. 0.4 ... =- ¡ :¡ 0.3 e ::: u 0.2 0.1 fx10.2 1x10·1 Brand Name B"'Safe-Carb 10 (F) D-Safe-Carb 40 (M) I E"'Safe-Carb 250 (C) Calcium Carbonate added: Avg Error 0 -100 % CPS Range: Max Error 0 - 100 % CPS R.ange ; 1x100 1:<101 1)(102 Parti¡::le Size (microns) 1 xi03 1)(104 . . ~ ~IFE Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Interval Summary - 8-1/2" hole 5595 - Drilling Fluid System Flo-Pro Fluid Key Products Flo-Vis / DualFlo / KCI/ Greencide 25G / SafeCarb F, KlaGard / MI Bar / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 - 230 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Interval Drilling Fluid'i(J)Î~~fes .... Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) (cp.) ( cps) (ml/30min) (%) 5595 - 7657 9.2 - 10.0+ 10 - 14 40,000 < 5 +/- 9.5 +/- 5% )0. Use one rig pit for drilling out intermediate casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. )0. If running coals become a problem, treat with a 2 PPB addition of Asphasol Supreme. )0. Periodic additions of Greencide 25G will be needed to control bacteria build-up. )0. Estimated volume usage for interval- 1316 barrels. )0. Estimated haul off volume - 2062 barrels. )0. Condition mud prior to running 3-1/2" casing. NOTE: Mud weieht as hieh as 10.6 ppe may be reauired to control eas influx at the bottom of this interval. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~ ..FE ~I . . ~ _IFE Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Production Interval Fluid Formula 8-/12" Interval from 5595 - 7657' Input I DescriPtion KBU 11-8X Mud Weiaht . 9.05 <3&1· No Weiqht MâterialCóde SafeCarb /GeICôrliíCi? Wei :¡híMaterial$G 2.8 ..... Weiaht MâteriaLPrice 0.35 ;% // 6 Sea Wâter No e.. .... 0.2516 Sea Sâlt No fä M-I Gel .a t% M~I· Gel Price a )r ce Output - 1 bbl I Order of Products š< Addition F"1å.I.d.lb Lab. am ¡F"iêld .bbl ¡It¥ib;fîîtf/ .. Sf"''''''... 1 Water 325.19 325.19 0.929 325.19 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 FloVis Plus 1.50 1.50 0.003 0.84 Viscosity 4 DualFlo 3.00 3.00 0.006 2.00 Fluid Loss Control 5 SafeCarb Fine 20.00 20.00 0.021 7.60 Bridaina Aaent 6 Potassium Chloride 20.76 20.76 0.025 8.68 Inhibition 7 Greencide 25G 0.25 0.25 0.001 0.30 Biocide 8 CONQOR 404 2.00 2.00 0.004 1.43 Corrosion Control 9 Caustic Soda 0.50 0.50 0.001 0.23 pH Control 10 SafeScav NA 0.25 0.25 0.001 0.25 Oxvqen Scavenqer If Bit ballina becomes a problem add the followina 11 D-D I 4.00 4.00 0.011 I 4.00 Reduce BHA Ballina If slidina or hiah toraue becomes a problem add 1 - 3% of the followinQ 12 Lubetex 7.00 7.00 0.021 I 7.00 Lubricitv If sloughing coals become a problem add 2 - 4 ppb of the followina 13 Asphasol Supreme I 2.00 2.00 I 0.004 I 1.33 Wellbore Stabilitv Mix fluid in the order listed above. Wait for 1 - 2 circulations before adding SafeScav NA to the system. Alternate additions of Greencide 25G and SafeScav NA as needed. Maintain 3-4 ppb concentration of DualFlo to maintain as Iowa API fluid loss as possible. Plan on daily additions of DualFlo to achieve > 6.0 cc's API Fluid Loss Reduce concentration of FloVis as needed to maintain rheology. Total 380.1 380.1 .¡¡:stifîîtâ~~dxtºl ¡,l.ìne",§ªgf! 1316 Barrels Calculated Mud Weiåht 9.050 TotalChlóride 29600 r:zj .IFE ~ Marathon Oil Company Well Name: KED ll-8X Location: Kenai, Alaska. Co. Max P,ml'leability : Sand Control Device: 100 mDarcy © 1999-2001 M-I L.L.C - All Right. R~.erv~d 11-BX Kenai Gas Field Middle Beluga Sands !:: o ~ .Q .¡: 1ii Õ ... N üi . ... <:> '€ '" II.. '" 0.4 ::- ¡ '3 E 0.3 :::¡ u 010 Target I Slend: 0.4 050 Target /Blend: 10.0 090 Target I Blend: 32.4 0.9 microns 9.2 microns; 23.5 microns Brand Name B=Safe-Carb 10 (F) O-Safe-Carb 40 (M) E=Safe-Carb 250 (Cj 0.0 0.0 0.00 0.00 0.1 0.2 8 100.0% fX10.:z 1)(10.1 1)(100 1)(101 1)(102 Particle Size (microns) 1)(103 1)(104 Calcium Carbonate added: Avg Error 0 -100 % CPS Range: Max Error 0 -100 % CPS Range: 20 Iblbbl 3.16 % 13.33 % , . . ~ ~æii IFE .- Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. HSE Issues HANDLING OF DRilLING FLUID PRODUCTS HEALTH AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENTAL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centrifuge solids van, insure all hoses and connections between the van and the rig are secure. ~ ..FE ~ Product M-I BAR M-I GEL GElEX FLOVIS DUAL-FLO POlYPAC XCD HEC Safe-Carb F,M,C lO WATE Nut Plug M-I Seal F, M, C Mix II F,M,C DESCO CF SPERSENE CF TANNATHIN VENTROl 401 SALT (Solar) BROMIDE (NaBr) & Brine Solution POTASSIUM CHLORIDE - Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Function Weighting Agent Viscosity control Bentonite Extender Viscosifier Modified Starch Fluid Loss Reducer Viscosifyer Loss Circulation Material Bridging and weighting agent Weighting agent Loss Circulation Material Loss circulation Material Loss circulation Material Dispersant Dispersant Dispersant Surfactant Densifier Densifier Shale Inhibitor I - Product AUSTIC SODA CAUSTIC POTASH BORAX SAPP SODA ASH SODIUM BICARBONATE CITRIC ACID OBANBP-PLUS EN CIDE25G - KLA-GARD LUBE TEX D-D CWT Concor 404 SAFE KLEEN sphasolD feScav NA Marathon Oil Company Well Name: KED 11-8X Location: Kenai, Alaska, Function ikalinity control pH Modifier Inorganic Borate Sodium Pyrophosphate Ikalinity control ikalinity control graphite LCM ale Control agent bricant rrosion Inhibitor . . GIÆ Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. HMIS HAZARD RATINGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 - Severe hazard 3 - Serious hazard 2 - Moderate hazard 1 - Slight hazard o - Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A - Safety Glasses B - Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D - Face Shield, Gloves, Synthetic Apron E - Safety Glasses, Gloves, Dust Respirator F - Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G - Safety Glasses, Gloves, Vapor Respirator H - Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K - Air Line Hood or Mask, Gloves, Full Suit, Boots X - Consult your supervisor for special handling directions r:!j _.FE ~ . . 8R Marathon Oil Company Well Name: KBU 11-8X Location: Kenai, Alaska. Project T earn Bob Williams Senior Engineer Locke Rooney Engineer t t Brad Billon District Manager ~ Deen Bryan Tech Service Gus Wik Warehouse Manag . MI Project Engineer and Tech Service Engineer will coordinate between the Marathon office, rig, warehouse, and the M-I field engineers. . Well progress will be monitored to look for any changes, which will improve the efficiency of the operation or avert trouble. Project Team Title Home Cellular Deen Bryan Tech Service 907 373-2713 907223-1634 Tony Tykalsky Project Engineer 907376-4613 907227-2412 Gus Wik Warehouse Manager 907776-8722 907776-8680 r:zì ..FE ~ · eaSka Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 20, 2004 John Norman Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application Field: Kenai Gas Field Well: Kenai Beluga Unit - KBU 11-8X Dear Mr. Norman Enclosed please find the PERMIT TO DRILL application, along with the associated attachments and filing fee of $100. The intent is to drill a Beluga development well in the Cannery Loop Unit. No completion is desired in either the Sterling or Tyonek pools. ~ Please note that Marathon is requesting a waiver for 20 ACC 25.035 (e) (1) (b) requiring a two pipe ram stack. The request is specified on page 12 of the attached drilling prognosis. If you require further information, I can be reached at 907-564-6310 or bye-mail at wjtank@marathon.com. Sincerely, .I j '/1 c1 vJ Î'. A 1 J. / // he\(. /' t,,; h _Þ1/~· /-~L Willard J. Tank Senior Drilling Engineer Enclosures RfCEI'VED FEB2 ~I-L.. . 0 (004 -...... Q7 & Gas ~~ -- Check No Check Date Bank Bank No Vendor No 1115246 02/20/2004 NCBAS 7780 5001123 @~¡¿~Ó~~~ Pi:@i#W\jiN 02/20/2004 1900005044 OTAl: Marathon Oil Company P. O. Box 3128 Houston, TX 77253 100.00 100.00 Hndlg Al ···@\iÄiW§~{~i@W( 100.0 100.0 111000 . . . 5 2 ~ b III I: 0 ~ . 20 :l B q 51: O. B :l ~ B ~ III . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /{tú I/~ ~ )¿ PTD# 201/-635 )( Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing wen . Permit No, API No. . (If API num ber Production.sbould continue to be reported as last two (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT BOLE In accordance witb 20 AAC 25.00S(t), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 2S.05S~ Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to tbe spacing exception tbat may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater -tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and IO' sample intervals througb target zones. Field & Pool KENAI. UPPER TYONEK BELUGA GAS - 44857 Well Name: KENAI BELUGA UNIT 11-8X PTD#:2040350 Company MARATHON OIL CO Initial ClasslType DEV 11-GAS GeoArea Unit 1 P,armitfee attache_d _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ y,as _ _ _ _ _ _ _ _ _ 2 _Leas,a _number appropriate _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ Yes _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nlque weltnam,a_anQ lJumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . y,as _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . . . . . . _ . . . . . . . . . . 4 WeIUQc¡;¡t,ad in.a. d.efine~Lpool _ . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . _ . _ 5 WellJQcat,ad prJ)perdlstance. from QriJling unitbÞundary. . _ _ . . . . . _ . . . . . . . _ . . Yes. . . . . _. ...... _ . . . . . . . . . . . . . _ . . . . . . . _ 6 WeUJQcat,ad properdlstance from ot/Jer welJs _ . . . . _ ...... _ _ Y,as . . . . . . _ . . . . . . . . _ . . . . _ . . . . . . . . . . 7 .S.uffjcientacreaQ.e.aYailable In.drillilJQ. unJL .. .... _. ...... ....... _ . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . _ _ . . . . . _ _ . . . . . . . . 8 Jf.d,aviated. .Is weJlbQre plaUncJu.ded . . . . . . _ . . . . . . . . . _ . . . . . . _ . . . . . y,as . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . 9 .Operator only affected party. . . . . . .. .... _ . . . . . . . _ . . . . . . . . y,as . . . . . . _ _ . . . . . . . _ . . . . . . _ ..... _ _ . . . . . _ . . . . . . . _ . 10 .Operator /Jas.apprJ)prlate.bond inJorce . . . _ _ . _ . . . . . . . . _ . . _ _ . . . . . _ _ _ . . . . . _Y,as. . . . _ . . . . . . . . _ _ . . . . . _ . . . . . . . _ _ _ _ . . . . . . . . . . . . . _ . . . . . . _ . . . . . . _ _ . . . . . _ . . . . _ . . . 11 p,armit can be lssued wit/JQut conservaJion order. . _ _ . . . . . . . _ ..... _ . Y,as . _ . _ . . . . . _ . . . . . . . . . . . . . . . _ _ . . . . . . _ .. ...... . . . . _ . Appr Date 12 P,armit c.an be issued wit/JQut ad.ministratÌ\le.apprJ)vaJ. . . . . . . . . . . . . . . . . . . . . . . . . y,as . . . . . . _ . . . . . _ - . . . . . _ . . . . . . . - . . . . . . . . RPC 2/23/2004 13 Can permit be approved before 15-day wait Yes 14 WelUQc¡;¡ted within area and.strata .authorized by InjectiolJ Ord,ar # (PutlO# in.cÞmm.ents) (For. NA . . . . . . . . . . . . . . . _ . . . . . . . _ _ . . . . . _ _ . . . . . . _ _ . . . . . . 15 .AlI welJs.withinJl4Jnile.area_of review id,alJllfied (FJ)r servJc.e.w.ell onlYL . . . . . _ _ . . . . . _ . .NA . . . _ _ . . . . . . _ . . . . . . . _ _ . . . . . . _ _ . . . _ _ _ _ _ _ . . . . . _ . . . . . . _ . . . _ _ _ _ . . . . . . _ . . . . _ . _ . . _ 16 Pre-produçedinjector; ~uratiQn.ofpre-pro~uctionl,ass.than3montbs.(ForservlceweIlQnJy).. NA..... _........ .... _ _ _....... _............ _............... _ _..._ 17 ACMPF:indjngof Con.sistencyhas bee.nissued.forJhis pr.oject. . . . . . . . _ _ . . . . .. . .NA _ _ _ . . . . . . . _ . _ . . . . . . . . . . . . . . . _ . . . . . . Administration Engineering Appr Date WGA 2/23/2004 Geology Appr RPC Date 2/23/2004 Program DEV On/Off Shore On Well bore seg Annular Disposal D - - - - - - - - - - - - - - - - - - - - - - - - - - - - . 18 .C.ondu.ctor s!(ingprQvided . . . . . . . _ _ . . . . . . . . . . . . _ . Y,as.. ...... ...... _ . . . . . . . . . . . . . . . _ . . . . . . . . . 19S.urfa~.casing.protects all known. USDWs . . . . . . . . . _ . . . . . . . _ _ . . . . . . . . . . . . Y,as. . . . . .. ..... _ _ . . . . . . _ . . _ . . . . . . 20CMT v.ol adeQu.ateJo circutate.onconductor_ & SUJf.C$g _ _ ...... _ _ . . . . . . . _ . . . . . Y,as. _ . . Ade.quate excess, . . . . . . . . . _ . . . . . . _ ..... _ . . 21 .CMT v_ol. adeQuateJo tie-inlQng .string to.surf cs.g. . . . . . _ . No. . . . . . . . . 22 .CMTwilJ cover_aU klJown.pro.ductiYe hQri¡!:Qns . . . . . . . . . .Y.es . . . . . . _ . . . . . . _ _ _ . . . . . . . . . . . . . . 23 .Casing designs adequate fJ)r C.T. B&perruafrost _ . . . . _ _ . . . . . . . . _ . Y,as. . . . _ . . . . . . . . . . . . . . . . _ . . . . . . _ . . . . . . . . . . . . . _ _ . 24 A~equatetan.kage_orre.serve pit . . . . . . . . y,as _ _ . . . . . GlacierRig 1.. _ . . . . . . . . . . . . . . . _ _..... _ . . . _ . . _ . 25 1f.a.re-~rilthªs.a.t0-403forabandonmentbe,anapPJQved.. ...... _..... _ _NA... _.. .t>Jewwell,. _...... _ ....... _ ..... _ ...... _. 26 AJ:Jequate.w.ellboreseparatio.n-Pfoposed...... _ . . . . . _ _ . . . . . . . . . . . . . _ _ . . . _ Y,as. . . . . _ . _ . . . . . _ _ . . . . . . _ _ . . . . . . . _ . . . . . . . _ . . . . . _ _ . . . . . . _ . . . . . . . _ . . . . . _ . . . . _ _ . . 27 Jfdiverter required, dQes iLm.eet reguJations. _ _ . . . . . _ . . . . . _ _ ...... y,as . . . . .' ........ _ _ . . . . . . _. ....... . . . . . . 28DJilIiIJg fluidprogJam schematic&eq.uiplistadequate. _ .. . . _ _ ...... ...... _ Y,as. . _ . . . . MaxMWlO,O.ppg._ _ . . . . . . . . . . . . _ . . . . . _ . . _ . . . . .. .... _ _ .... _ _ 29 .BOPEs..d.o _they meet reguJa.tion . . . . . . . . _ _ . . . . . . . . . _ . . . . . . _ . . . . _ y,as . . . . . _. ..... _ _ . . . . . _ _ _ . . . . . . . . . . . . . . . . . . . . . 30 .B.OPEpress raJilJg appropriate;testto.(put psig in.comments). . . . . . _ . _ . Yes _ _ . . . . . Test tJ)25QO. psi. .MSf> 22.52 psi. ...... 31Choke.ruanifold cQmpJies w/APt Rf>-5HMay 64)_ _ . . . . . . . . . . . . . _ . . . . . . . _ . . . . Y,as. . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . 32 WQrk will occ.ur withoutoperation.shutdown. . _ _ . . . . . . . _ . . . . . _ _ . . . . . _ . . . . . . Y,as. . . . . . . . _ . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ 33 Is presence of H2S gas probable _ ..... _ _ _ . . . . . . . . . . . . . . . . . . . . . No. _ . . . . . . _ . . . . . . . . . _ . . . . . . . . . . . .. ............ _ _ . . . . . . . 34 Meçbanlc¡;¡tC9lJdi!iono{wellswithinAORyerifiecl (fors.erviceweU onJ Y).. _ . NA ...... ..... _ ...... _ _....... _..... _...... _.............._ - - - - - - -- - - - - -- - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- . ~ - - - - - 35 Permit c.an be lssued wlo hYdrogen sulfide measures. 36 .D_ata.preselJted on pote.ntial overpressure .zones. 37 .Seismic.analysis of sbaJlow gas.zJ)nes . . . . . . _ . . . . . . . 38 .SeabedconditiolJ survey (if off-sh.ore) . . . . . . . _ . . . . . _ . 39 . Contact namelphonefor.weekly progress reports [exploratory .only] _.......... Yes. .... _ .NA... _ _... _NA _ ... . . . . . . . . . NA _.. .NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Commissioner: Date DIS Date: Engineering Commissioner: Public Commissioner Date ~¥/~
