The URL can be used to link to this page

Home My WebLink About205-1061a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Cannery Loop Unit GL: 19.8' BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20" K-55 123' 13-3/8" L-80 1866' 9-5/8" L-80 3721' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate N/A SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface 4120'(TOW) Surface ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 417 sx12-1/4" 16" N/A Surface 606 sx Surface 1953' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 272452 2388727 20-133-20553-00-00July 22, 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 9/25/2022 205-106 / 322-391 N/A CLU-10August 3, 2005281' FSL, 531' FEL, Sec 7, T5N, R11W, SM, AK 37.8' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORDSETTING DEPTH TVD 2388335 TOP HOLE SIZE N/A Sterling Undef GP ADL 02397 Date of Test: Oil-Bbl: N/A Gas-Oil Ratio: AMOUNT PULLED N/A 274233 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. PACKER SET (MD/TVD) Driven N/A 4,120' MD / 3,721' TVD N/A 8,450' MD / 8,002' TVD 4,120' MD / 3,721' TVD N/A 77' FNL, 1255' FWL, Sec 17, T5N, R11W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 40# Surface 133# 68# 123' Water-Bbl: PRODUCTION TEST N/A Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl:Flow Tubing WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 4:19 pm, Feb 01, 2023 xNoJSB Abandoned 9/25/2022 JSB RBDMS JSB 021323 xGBJM 10/26/23 DSR-2/15/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval N/A N/A 8,450' 8,002' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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. TPI (Top of Producing Interval). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. INSTRUCTIONS Tyonek Wellbore Schematic, P&A Reports Authorized Title: Drilling Manager No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 2.1.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.02.01 15:44:47 -09'00' Monty M Myers Excape System Details - 12 Excape modules placed -Green control line fired module 1 -Yellow control line fired modules 2 thru 8 -Red contol line fired modules 9 thru 12 - Ceramic flapper valves below each module except for module 1 Plugged Beluga Perfs: (RKB) Module 12 - 5,674' - 5,684' Squeezed 12/11/07 Module 11 - 5,713' - 5,723' Squeezed 12/11/07 Module 10 - 5,880' - 5,890' Module 9 - 6,956' - 6,966' Module 8 - 7,030' - 7,040' Module 7 - 7,083' - 7,093' Module 6 - 7,174' - 7,184' Module 5 - 7,716' - 7,726' Module 4 - 7,965' - 7,975' Module 3 - 8,098' - 8,108' Module 2 - 8,219' - 8,229' Module 1 - 8,265' - 8,275' Top of Cement (cbl) @ 4,260' MD 1150' above 9-5/8" shoe Excape System Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 12 - 5,690' Module 11 -5,729' Module 10 -5,897' Module 9 -6,976' Module 8 -7,049' Module 7 - 7,106' Module 6 -7,196' Module 5 -7,736' Module 4 -7,985' Module 3 - 8,118' Module 2 -8,240' Module 1 -NA Permit #:205-106 API #:50-133-20553-00-S02 Prop. Des:ADL 02397 KB elevation:41' (21' AGL) WBS #: Latitude:60°31' 56.84" N Longitude: 151°15' 48.37" W Spud:7/22/2005 TD:8/3/2005 Rig Released:12:00hrs 8/10/2005 CLU-10 Pad 1 Drive Pipe 20" K-55 133 ppf Top Bottom MD 0' 123' TVD 0' 123' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,953' TVD 0' 1,866' 16" hole Cmt w/ 606 sks (246 bbl) of 12.0 ppg, Type 1 Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd w/ 6.25" OD control line protectors Top Bottom MD 0' 8,419' TVD 0' 7,971' 8.5" hole Cmt w/ 1,324 sks (274 bbls) of 15.8 ppg, class G PBTD 5,374' MD 4,926' TVD Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 4,120' TVD 0' 4,962' 12.25" hole Cmt w/ 417 sks of class G, (75 bbls) of 12.5 ppg, Lead & (45 bbls) of 15.8 ppg, Tail TD 8,450' MD 8,002' TVD Junk Plug Remains @ 8,292' CTM SandC 1 C1 C2 Date 10/17/09 10/10/09 10/6/09 Gun Type 2" 6 spf 60º 2-3/8" 4 spf 60º 2-3/8" 4 spf 60º TVD 4,977'-4,992' 4,977'-4,992' 5,087'-5,107' Ft 15 15 20 MD 5,425'-5,440' 5,425'-5,440' 5,535'-5,555' Sterling Perfs: 3.5" Owen Cast Iron Bridge Plugs set: @ 5,649' KB w/ 65' cmt (10/02/09) top of cmt tagged @ 5,583' MD (10/6/09) @ 5,830' KB w/ 58' cmt (10/01/09) @ 6,906' KB w/ 35' cmt (09/29/09) 3.5" Owen Cast Iron Bridge Plug set: @ 5,532' KB w/ 15' cmt (10/14/09) 10' of fill above Bridge Plug top of cmt @ 5,507' MD Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Cannery Loop Unit # 10 Kenai Peninsula Borough 5,419' - 5,555' ~ 3º / 100 ft @ 750' MD 8/31/2005 CJD Lease: State: Perf (TVD): Cannery Loop Unit Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 4,971' - 5,107' ~3º RKB:41' (above MSL)21' (AGL) 2-1-23 Top of Cement (est.) @ 3,260' MD 100% fill Sterling C1 Interval: 5,372,-,5,614 ft MD 3.5" Owen Cast Iron Bridge Plug set: @ 5,410' KB w/ 36' cmt (2/9/12) ~top of cmt @ 5,374' MD Sterling C2 Interval: P&A'd 9-5/8" Cast Iron Bridge Plug @ ~4,130' TOW @ 4,120' MD Activity Date Ops Summary 7/16/2022 Held PJSM and approved PTW,MIRU Cruz 35 Ton Boom Truck. Disconnected prep and remove wellhouse. RDMO Boom Truck.,Spotted rain for rent supply and return tanks, R/u pump and circulating eq. Filled supply tank with source water.,MIRU YJ EL Unit, PT lubricator 250-2500psi-good test. RIH w/Wt Bars, CCL and 1-9/16" RTG Tbg Punch, correlated on depth, pressure up on tbg t/600psi. Punched holes 4,230'-32'. Observed pressure drop t/100psi. POOH. L/d tools,Attempted to circulate dn tbg up IA pressure up t/2500psi w/no leak off. Lined up to pump dn IA returns up tbg same results. Continued attempting to rock both direction and could not break circulation. Pressure up on tbg to 2,500psi and SI well over night. 7/17/2022 PJSM and approved PTW.,SITP fell f/2500psi t/300psi over night. Lined up to pump dn Tbg returns IA. Pressure up on tbg to 3000psi monitored slow leak-off. cont working pressure up and t/ 4000psi and surging well, after several attempts final broke circulation at 2bpm.,Continued circulating @ 2bpm/1200psi, worked rate up @ 4bpm/850psi, returns 1/1 of 9-10ppg mud. After BU (270bbls) circulating pressure decreased 4bpm/400psi. Cont circulating at 350bbls returns were 8.4ppg. SD pump and well static.,Vac truck on location to start hauling return tank to G&I. Once return tank is emptied plan to rev circ STS or until returns are clean. 7/18/2022 PJSM and approved PTW,Lined up circulating eq. Reversed circulated well w/ 8.4ppg Source water @ 4bpm/400psi, B/u returns of drilling mud. At 300bbls away (STS) returns were clean 8.4ppg SW. Continued rev circulating pumped a total of 350bbls and S/d pump. Monitored well Tbg/IA was static.,R/d pump and circulating eq. Secured well. Pre Rig work complete 7/21/2022 PJSM, MIRU YJ EL Unit, RIH w/CCL Wt. bar and 2" RCT. Correlated and cut tbg at 4225', POOH, confirm cutter fired, L/d tools. M/u tools and RIH w/CCL wt bar and 3-1/2" jet cutter, correlated and cut tbg in same place @ 4,225'. POOH L/d tools. RDMO EL. 8/1/2022 PJSM - Lay out felt and liner, spot rig equipment and carrier, Brum around rig, hook up hoses to pits and pump, run Electrical/ prep to raise derrick, raise and scope up derrick, check well (TBG static), (IA static),Install BPV, and terminate Control lines, Nipple down 3-1/16 10m x 13-5/8 5m studded, x 3-1/16 10m studded top prepped for 6-1/2 extended neck,Nipple up 13-5/8 5m spool, 13-5/8 Double rams & 13-5/8 5m annular, hook up Koomey hoses, charge Accumulator and function test BOP's install Choke and kill lines,Rig up rig floor, stairs, and railings M/up 2-7/8 & 3-1/2 test joints, top of pill pit with 8.4 well water 8/2/2022 Held PJSM, M/U 3.5 & 2-7/8 test joints, pick up handing tools, run in with 2-7/8 test joint, fluid pack, lines and BOPE, Choke manifold & shell test to 3000 psi good test,Test 13-5/8 5m BOPE's & related surface equipment with 2-7/8 & 3-1/2 test joints to 250 low and 3000 psi HI, held each test 5 minutes on chart test made with water, preform Koomey draw down one fail pass on draw down (failed to reach 3000 psi on full pressure build up) adjust regulator preform draw down, (Good test) test witnessed by Bob Noble and Sean Sullivan with AOGCC, Quadco test gas detectors alarms PVT,PJSM with crews on Pulling EXCAPE tbg from well,Break down test joints, rig up spooler, rig up floor to pull pipe,Spear into 3-1/2 tbg, calculated weight of string 39k, pick up unseat hanger at 70k pick up wt. working up to 70k in 10k intervals, picked up to 80k, weight fell off to 70k wt., pic up to 80k, slack off pipe to land pack off in tbg,head, pack not seating in head to lock down, tap pack off down in head, unable to seat same, pick up to 80k to work pipe, pipe set in csg slips, work pipe again unable to get pipe back down to set pack off in head, pack off 4 ft high, lay out spear make up BPV and landing joint in hanger and secure well for night,Line up spear pack off for in the morning. 8/3/2022 Held PJSM with crew,Check well, well static, mixed lube pill & pick up spear, install back off, speared 3-1/2 pipe circulated at 1 bpm at 230 psi establishing pressure and rate, pack off leaking, increase rate to 2.3 bpm at 1300 psi, pack off seated getting returns from IA, pumped 20 bbl. of lube pill followed with 40 bbls of 8.4 ppg fluid, pack off started leaking,Shut down pump, release spear, changed out rubber on pack off & install spear in 3-1/2 pipe.,Circulate at 2.3 bpm at 1300 psi while holding 60k wt. pick up to 80k wt. weight dropped off to 76k, circulate for 5 minutes picked up to 80k weight dropped off to 64k, let circulate for 5 minutes, picked up to 72k weight dropped off to 44k continue to pick up while circulate at 2.3 bpm at 1300 psi getting pack off and slips out of BOPS, finish circulating 20 bbl. lube pill out of tbg into annulus pump total of 143 bbls.,Remove csg slips break out spear & cut piece of 3.5 pipe, with csg pack off and lay out same,Make up head pin, reverse circulate a hole volume at 4 bpm getting back slugs of mud in returns. pump total of 270 bbls shut down pump well static,Pooh removing 6-1/4 rigid centralizers, and (3) 3/8 Escape control line with SS bands and 1/2 cable from 4225 ELM to 3008 ft DPM recovered 38 6-1/4 rigid centralizer, 390 set screws, 115 SS bands total jts laid down 38 and 20 ft cut piece. secure well for night 8/4/2022 Held PJSM AND JSA,Pooh laying down 3-1/2 9.3#, EUE L-80 pipe remove 6-1/4 centralizers and SS bands and spooling up (3) 3/8 SS Escape control lines, and 1/2 " cable on spools recovered 133 jts of pipe & top and Bottom cut joints, recovered 390 SS Bands, (missing 9 SS Bands) recovered (134) 6-1/4 centralizers, on last 10 jts had strip on mud on tube in spots 1/2" thick x 3" wide, in spots. in all pipe look good, had some slight pitting on,tube on several joints,fluid pack well, MIT the 9-5/8 csg and Escape module control lines to 1500 psi for 30 minutes good test had 20 psi bleed off, OA had 65 psi during test AOGCC Sean Sullivan witnessed test.,Rigging down pipe skate and secure well for night. 8/5/2022 Held PJSM with crews,Rig up yellow jacket E-line,E-line RIH with 7.80-gauge ring and junk basket, CCL, tagging at 3992 ft. ELM had 200 # over pull pulling off bottom pooh check junk basket, had small amount of mud in junk basket,Rig down W-line,unload & lay out 2-7/8 work string, strap and tally, rig up pipe skate, rigging up handling equipment,Pick up 8-5/8 bit (No jets) & a 9-5/8 40# csg scrapper & Trip in hole picking up 2-7/8 ph. 6 work string to 3200 ft. reversed circulate at 1839 ft. at 1.5 bpm at 85 psi broke circulation at 3200 ft. secure well for night. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: CLU 010 Cannery Loop Hilcorp Energy Company Composite Report , AK Contractor AFE #: AFE $: Job Name:222-00912 CLU-10 Decomplete for Sidetrack Spud Date: jp p pppg g MIT the 9-5/8 csg and Escape module control lines to 1500 psi for 30 minutes good test had 20 psi bleed off, cut tbg in same place @ 4,225'. Punched holes 4,230'-32'. Pooh laying down 3-1/2 9.3#, EUE L-80 pipe 8/6/2022 PJSM check well (well static),Reverse circulate at 1.7 bpm at 170 psi total of 9 bbls,Trip in hole picking up off rack, f/ 3,202 ft. to 3,777 ft. dpm,Rig up circulating hoses to wash down,Wash from 3,777 ' to 3,849 tagging hard fill at 3,849 ft. unable to wash down,Rig up power swivel & stripper head & spool center stack,Wash and ream f/ 3849 ft. to 4212 ft. Reverse circulating, pumping at 2.25 bpm at 375 psi, with 60/80 rpm with 1000 to 1800 ft/ lbs., with 0/6 WOB, had hard spots at 3848 ft. 4010 to 4015 ft., 4115 to 4,141 ft. and 4190 to 4112 ft. pick up wt 30 k so wt 24k Rt wt. 26k,Reverse circulate 2 tbg volumes at 2.25 bpm at 400 psi,Laid down 2 joints work string ft 4212 ft to 4167 ft. secure well for night 8/7/2022 PJSM & JSA,Rig down power swivel and secure on skid, roll up service loop, Rig down haws head, & adapter spool, change elevators and prep handling equipment for POOH,Pooh Laying down. 2-7/8" work string f/ 4,150 ft. to surface, P/up wt. 30k S/o wt. 24k. & lay out BHA,Rig down pipe skate, cleared rig floor and rig up yellow jacket E-line,RIH with Legacy BIg Boy CIBP Part number 000-7710-002, 7.710 OD Suitable for 9-5/8 29.3-53.5 PPF csg rated for 8000 psi at 325 deg F LOT # 83738, setting CIBP at 4148 ELM pick off plug and tagged to verify plug at 4,148,Pick up 2-3/4 with 3 centralizers for 9.5/8 40# csg RIH set up tools at 1158 ft., continue in hole tagging CIBP at 4,148 ft. ELM Log with CBL f/ 4,148 ft. to surface at 50 fpm EST top of cmt at 3425 ft.,Rig down E-line and secure well 8/8/2022 Held prejob meeting and JSA, rig down rig floor,Rig up and MIT the 9-5/8 csg and CIBP set at 4148 ft. to 3000 psi for 30 minutes, (GOOD TEST) Jim Regg with AOGCC waived witness of test,Rig down pits, vac out pits, bleed down koomey and roll up hoses, Nipple down 13-5/8 BOP's, install tbg spool and dry hole tree, Scope down and lay down derrick, move carrier & support equipment off liner, roll up liner, pick up location. 8/22/2022 Ops team RU triplex pump to CLU-10. Test lines and pump to 3,500 psi. Pressure up well to 3593 psi, hold for 30 min. Final test pressure 3571 psi. Bleed fluid back to tank. RD pump and hoses. gyg y setting CIBP at 4148 ELM pick off plug and tagged to verify plug at 4,148 ELM Log with CBL f/ 4,148 ft. to surface pg gg ypg Activity Date Ops Summary 9/22/2022 Continue R/D Complexes, Scope down derrick, Prep and Lay over derrick, rig movers on location @ 0930 started splitting apart back yard, pulled boiler house and pump skids, catwalk and HPU building, pull jig and spot in crane pull choke house and lay over wind wall, pull iron roughneck.;Lower dog house into water tank, pull out water tank and generator skid, pull out gas buster, give state notification for upcoming BOP test.;Spot in cranes and hoist derrick off sub, hoist draw works and sub off and onto trailers, move pony subs over new well and spot cranes in, set sub on pony subs, set draw works on sub, set derrick on sub and pin, spot in water tank and raise dog house, spot in gen skid, raise wind wall.;Spot in HPU and pit module #1.;Raise derrick. R/U electrical lines, mud pumps, pit equipment, drive shaft, and brake linkage. R/U pop-off lines and jumper hoses. lower walkways install handrails, and lights on roof tops. Power up get-set raise and R/U vacuum degasser, Cont to R/U lower kelly hose,;and service loop and drill line. Install cable clamp and anchor line on DW drum. Prep to spool up drill line.;Install Derrick raise cylinder controls to derrick, Continue R/U electrical/utility lines, Install turnbuckles on TQ tube, prep to scope up derrick. Lay felt and liner for catwalk. remove shipping pins from Iron roughneck. R/U standpipe, TD hydraulics, drillers gauge and instrument lines. 9/23/2022 Scope up derrick and pin, install T bar and tur buckles on torque tube, rig movers on location 0700hrs spot in catwalk and water tank, crane in cement silo and centrifuge, set gas buster and raise, P/U top drive and secure to blocks, M/U torque bushing, hook up service loop and kelly hose.;Continue rigging up, change liners on Mud pumps t/ 5.5'', check top drive function take on water to rig tank and pits, check pit function, work on rig acceptance check list, N/D tree flange and dress top drive, bails saver sub link tilt cylinders, continue rigging up floor.;N/U BOP Stack, choke and kill lines, flow box and riser, hook up flow line, check pre- charge on all bottles, function test rams, handi berm around rig.;Energize Koomey, P/U test jt. and install test plug, flood stack with water and shell test BOP's to 3500 psi.;Function test mud pumps, flood mud lines with water and perform visual inspection, rack and tally drill pipe.;Pressure test BOPE w 4 1/2" test jt. to 250 low/3500 high for 5 min each. Perform Koomey Drawdown test. test manual and hydraulic chokes to 2000psi. Test gas alarms and PVT system. Test witnessed by AOGCC (Guy Cook).;Blind rams Fail/Pass ( functioned and bled air out of system). Well sign Fail/Pass (retrieved well sign from well house).;R/D test equipment and prep to P/U BHA and DP. 9/24/2022 Blow down lines, set wear ring 9'' ID, clear floor.;Service rig and top drive check break linkage and driveshaft.;Load pipe on racks and P/U BHA components to floor, Adjust service loop cover.;M/U Clean Out BHA, Bit, Bit Sub, Stab, XO, RIH t/ 4148' tag CIBP.;Displace well t/ 9.1 ppg 6% KCL Polymer 370 gpm 320 psi.;POOH f/ 4148' t/ surface, L/D BHA.;P/U 18 jts of HWDP and rack back in derrick.;R/U test equipment, test casing to 3500psi for 30min. 175 gal pumped, 175 gal returned. R/D test equipment, Blow down lines. Prep Whipstock BHA to PU.;M/U whip stock assembly as per rep. Shallow test MWD tools, M/U whip stock and scribe MWD.. TIH F/ 82' T4130' Orientate whip stock to 30 deg LOH. Tag bridge plug @ 4148' and trip anchor w 4K set down. P/U 5' placing top of whipstock @ 4120'. Set down 30k and shear off of whipstock.;Orientate whip stock to 30 deg LOH. Tag bridge plug @ 4148' and trip anchor w 4K set down. P/U 5' placing top of whipstock @ 4120'. Set down 30k and shear off of whipstock. 9/25/2022 Mill Window f/ 4120' TOW t/ 4134' BOW 5k WOB 400 gpm 1015 psi 80 rpm Drill t/ 4164', Drift window multiple time no issues, turn off rotary and dry drift clean no drag. 398lb of metal recovered total.;Circulate bottoms up 500 gpm 1385 psi MW 9.1ppg in and out.;R/U and perform FIT t/ 515 psi 12.16 ppg EMW27.6 gal pumped 25 gals returned , R/D test equipment and blow down lines.;POOH w/ Milling Assembly f/ 4078' t/ Surface, L/D Milling Assembly Window mill 1/4" under, follow mill 1/8" under, Gage mill 1/16" under.;Clean and clear rig floor, prep drilling BHA to P/U.;P/U 8 1/2" directional drilling BHA, and TIH f/ 692' to 4086' Calc = 67.4bbls, Act= 66.8 bbls.;Service rig and check fluids;R/U test equipment and perform Fit @ 3720' TVD. 9.1 ppg mud. pressure up 655psi. 12.48ppg EMW. 47 gal pumped, 45.5 gal returned.;Orientate to 30 deg LOH and slide thru window ( no set down) and continue to drill F/ 4164 ' T/ 4273' 53 RPM @ 5.5K tq. 470 GPM, 1285 psi. 2-6K WOB.;Circulate bottoms up 470 gpm, 1290psi. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: CLU 010RD Cannery Loop Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00102 CLU-10RD Drilling Spud Date: CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Cody Dinger To:Brooks, James S (OGC) Subject:RE: [EXTERNAL] RE: CLU-10 and CLU-10RD 10-407s Date:Friday, February 3, 2023 10:04:03 AM Should definitely be P&A, my mistake. From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Friday, February 3, 2023 10:02 AM To: Cody Dinger <cdinger@hilcorp.com>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Chad Helgeson <chelgeson@hilcorp.com>; Monty Myers <mmyers@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com> Subject: [EXTERNAL] RE: CLU-10 and CLU-10RD 10-407s Hi Cody, The form that you submitted for CLU-10 P&A is filled out as Gas/Dev. Can you verify if this should be P&A ? thanx From: Cody Dinger <cdinger@hilcorp.com> Sent: Friday, February 3, 2023 9:43 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Brooks, James S (OGC) <james.brooks@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Chad Helgeson <chelgeson@hilcorp.com>; Monty Myers <mmyers@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com> Subject: RE: CLU-10 and CLU-10RD 10-407s Hello AOGCC team, Hilcorp would like to retract the 10-407 for CLU-10RD as we have additional perforations to conduct under sundry 322-589(CLU-10RD Initial Completion). The 10-407 for CLU-10 will be unchanged by this work so can remain submitted. Let me know if you have any questions or need anything from me to make this request possible. Thank you! Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 From: Cody Dinger Sent: Wednesday, February 1, 2023 3:54 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: CLU-10 and CLU-10RD 10-407s Hello, Attached are the 10-407s for CLU-10 and CLU-10RD. Thank you! Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221215 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14A 50133205390100 213196 9/22/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 10/24/2022 YELLOW JACKET PERF-GPT CLU 05RD 50133204740100 215160 7/15/2022 YELLOW JACKET PLUG-PERF CLU 10 50133205530000 205106 7/16/2022 YELLOW JACKET PERF KALOTSA 4 50133206650000 217063 8/24/2022 YELLOW JACKET PERF MPU K-09 50029232470000 205014 12/11/2022 READ CaliperSurvey Please include current contact information if different from above. T37376 T37377 T37378 T37379 T37380 T37381 By Meredith Guhl at 10:10 am, Dec 16, 2022 CLU 10 50133205530000 205106 7/16/2022 YELLOW JACKET PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.16 10:11:16 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SRU 213-15 50133206520000 215100 6/24/2022 Yellowjacket PERF KBU 33-06X 50133205290000 203183 6/26/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 6/28/2022 Yellowjacket GPT-PERF END 3-17F 50029219460600 203216 7/2/2022 Yellowjacket PERF-RETAINER KBU 32-08 50133206240000 214014 7/12/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 7/15/2022 Yellowjacket GPT-PERF SRU 213-15 50133206520000 215100 7/19/2022 Yellowjacket GPT-PLUG MPU I-17 50029232120000 204098 7/19/2022 Yellowjacket TUBING CUT CLU 05RD 50133204740100 215160 7/21/2022 Yellowjacket PLUG CLU 10 50133205530000 205106 7/21/2022 Yellowjacket RCT-JET CUT SRU 213-15 50133206520000 215100 7/22/2022 Yellowjacket PERF Please include current contact information if different from above. By Meredith Guhl at 8:52 am, Nov 23, 2022 T37295 T37295 T37295 T37296 T37297 T37297 T37298 T37299 T37300 T37301 T37302CLU 10 50133205530000 205106 7/21/2022 Yellowjacket RCT-JET CUT Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.23 09:08:15 -09'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTALT#20221117-1 Log Print Files and Log Data Files: Well API #PTD #Log Date Log Company Log Type AOGCC Eset# CLU 05RD2 50133204740200 222092 9/27/2022 Yellowjacket CBL CLU 10 50133205530000 205106 8/7/2022 Yellowjacket CBL-PLUG CLU 10RD 50133205530100 222113 9/30/2022 Yellowjacket CBL CLU 10RD 50133205530100 222113 10/16/2022 Halliburton RCBL CLU 13 50133206460000 214171 10/2/2022 Yellowjacket CBL Please include current contact information if different from above. T37265 T37266 T37267 T37267 T37268 By Meredith Guhl at 1:32 pm, Nov 17, 2022 CL U 1 0 501 33205530000 205106 8 /7 /2022 Ye llowjac ke t CBL-PLUG Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.17 13:32:28 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________CANNERY LOOP UNIT 10 JBR 10/26/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 4.5" test joint used for testing. Well sign not posted. After looking for the well sign for a few hours they found it on the well house and posted it on the rig. Blinds failed initial low. Troubleshoot, cycle blinds and purge air from the system and retest for a pass. Test Results TEST DATA Rig Rep:Sonny ClarkOperator:Hilcorp Alaska, LLC Operator Rep:Sam Menapace Rig Owner/Rig No.:Hilcorp 169 PTD#:2051060 DATE:9/24/2022 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopGDC220923175358 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 1219 Sundry No: 322-391 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign FP Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11" 5000 P #1 Rams 1 2 7/8"x5" VB P #2 Rams 1 Blinds FP #3 Rams 1 4.5" Solid P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8"x2 1/16 P Kill Line Valves 1 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3025 Pressure After Closure P1200 200 PSI Attained P23 Full Pressure Attained P88 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2425 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P29 #1 Rams P4 #2 Rams P4 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P1 9 9 9 9999 9 9 9 9 9 FP FP Well sign not posted. Blinds failed initial low. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 10 CANNERY LOOP UNIT 10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 10 50-133-20553-00-00 205-106-0 W SPT 4130 2051060 1500 65 65 65 65 OTHER P Sully Sullivan 8/4/2022 MIT on CLU 10 casing to 1500 psi per the sundry #322-391.Tubing was pulled so there are only production csg and casing-casing annulus pressures. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:CANNERY LOOP UNIT 10 Inspection Date: Tubing OA Packer Depth 0 1800 1795 1795IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS220801130253 BBL Pumped:0.5 BBL Returned:0.5 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 0,7WRYHULI\SOXJLQWHJULW\IRUUHGULOOZHOOLVD VXVSHQGHGJDVSURGXFHU-5HJJ 1 9 sundry #322-391. James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 14:06:28 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________CANNERY LOOP UNIT 10 JBR 08/29/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Closure time for ann. 25sec., 8 sec. vbr, blinds 7sec., HCR 2sec. Accumulator failed initial test would only reach 2975psi, adjust regulator up to 3k, retest and pass. 24 acc. Bottles with avg, 1025psi each. Inspection witnessed by Bob Noble and Sully Sullivan. Test Results TEST DATA Rig Rep:Chris HannevoldOperator:Hilcorp Alaska, LLC Operator Rep:Ed Hooter Rig Owner/Rig No.:Hilcorp 401 PTD#:2051060 DATE:8/2/2022 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopRCN220802155726 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 2.5 MASP: 1219 Sundry No: 322-391 CLOSURE TIME (sec) Time/Pressure P/F Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 2 5/8x5 P #2 Rams 1 blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8 P HCR Valves 1 3-1/8 P Kill Line Valves 3 3-1/8&2-1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1900 200 PSI Attained P21 Full Pressure Attained P112 Blind Switch Covers:Pall stations Nitgn Btls# &psi (avg)P6@2200 ACC Misc FP1 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 9 9 9 99 999 9 9 FP Closure time for ann. 25sec., 8 sec. vbr, blinds 7sec., HCR 2sec.Accumulator failed initial test witnessed by Bob Noble and Sully Sullivan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aSVL 6HH6FKHPDWLF 3 W B V )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Meredith Guhl at 8:56 am, Jul 01, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH %23 WHVW WR SVL $QQXODU WHVW WR SVL )((:&3& '/% ; '/% ; ; '65%-0 3UHVVXUH WHVW FDVLQJ WR SVL DIWHU SXOOLQJ WXELQJ EHIRUH VHWWLQJ &,%3 WR YHULI\ LQWHJULW\ RI ([FDSH OLQHV 3URYLGH KUV QRWLFH IRU $2*&& ZLWQHVV RI WHVW $GGLWLRQDO 3 $ SOXJ ZLOO EH UHTXLUHG LI WHVW IDLOV GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.07.11 15:40:28 -08'00' RBDMS JSB 071222 tĞůůWƌŽŐŶŽƐŝƐ ϬϮͬϬϭͬϮϬϮϮ tĞůůEĂŵĞ͗>hͲϭϬW/EƵŵďĞƌ͗ϱϬͲϭϯϯͲϮϬϱϱϯͲϬϬͲ^ϬϮ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ƵƐƉĞŶĚĞĚǁĞůů>ĞŐ͗E ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌϴϯϬϱWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϱͲϭϬϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ;ϵϬϳͿϳϳϳͲϴϱϬϯ;KͿ;ϵϬϳͿϯϬϭͲϭϳϯϲ;DͿ DĂǆ͘ǆƉĞĐƚĞĚ,W͗Εϭ͕ϱϴϴƉƐŝΛϯ͕ϲϵϰ͛ds Ϭ͘ϰϯƉƐŝͬĨƚŚǇĚƌŽƐƚĂƚŝĐĐŽůƵŵŶƚŽ ƐƵƌĨĂĐĞ DĂǆ͘WŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞΕϭ͕ϮϭϵƉƐŝ ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚƚŽƐƵƌĨĂĐĞ tĞůů^ƚĂƚƵƐ͗ tĞůůǁĂƐƐƵƐƉĞŶĚĞĚŝŶϮϬϭϮ͘>ĂƐƚǁĞůůƐƵƐƉĞŶƐŝŽŶƌĞƉŽƌƚĐŽŵƉůĞƚĞĚŝŶ^ĞƉƚĞŵďĞƌŽĨϮϬϮϬ͘ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ >hͲϭϬǁĂƐĚƌŝůůĞĚŝŶϮϬϬϱĂŶĚĐŽŵƉůĞƚĞĚĂƐĂŶyWǁĞůůĂŶĚĨƌĂĐ͛Ě͘dŚĞǁĞůůĐĂŵĞŽŶůŝŶĞĨůŽǁŝŶŐϲ͘ϵŵŵƐĐĨĚ ΛϭϬϴϱƉƐŝĂŶĚϮϵϬďǁĚ͘ŶĂƚƚĞŵƉƚǁĂƐŵĂĚĞƚŽŝƐŽůĂƚĞƚŚĞǁĂƚĞƌƉƌŽĚƵĐƚŝŽŶǁŝƚŚƉĂƚĐŚĞƐŝŶϮϬϬϲĂŶĚǁĂƐ ƵŶƐƵĐĐĞƐƐĨƵůŝƐŽůĂƚŝŶŐǁĂƚĞƌĂŶĚƐĂŶĚ͘/ŶϮϬϬϳĐŽŝůƉůƵŐŐĞĚďĂĐŬƚŚĞĞƐĐĂƉĞŵŽĚƵůĞƐĂŶĚŵŝůůĞĚŽƵƚƚŚĞĐĞŵĞŶƚ͘ dŚĞŽƌŝŐŝŶĂůĐŽŵƉůĞƚŝŽŶǁĂƐƉůƵŐŐĞĚďĂĐŬŝŶϮϬϬϵĂŶĚƌĞĐŽŵƉůĞƚĞĚƚŽƚŚĞ^ƚĞƌůŝŶŐWŽŽů͘/ŶϮϬϭϮƚŚĞǁĞůůǁĂƐ ƉůƵŐŐĞĚďĂĐŬĂŶĚƚŚĞǁĞůůƐƵƐƉĞŶĚĞĚ͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐǁŽƌŬŝƐƚŽƉƌĞƉĂƌĞƚŚĞǁĞůůĨŽƌƌĞĚƌŝůů͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ͗ ͲWůƵŐǁŝƚŚϯϲ͛ŽĨĐĞŵĞŶƚƐĞƚĂƚϱ͕ϯϳϰ͛ Ͳ^>ZĂŶϮ͘ϳϱ͟ŐĂƵŐĞƌŝŶŐƚŽϱ͕ϯϲϴ͛;ϲͬϯͬϮϮͿ WƌŽĐĞĚƵƌĞ͗ ϭ͘ZhͲůŝŶĞΘWƵŵƉƵŶŝƚ͕WdůƵďƌŝĐĂƚŽƌĂŶĚŚŽƐĞƐƚŽϮ͕ϱϬϬƉƐŝ Ϯ͘,ŽůĚŝŶŐĂƚůĞĂƐƚϰϬϬƉƐŝŽŶƚŚĞƚƵďŝŶŐƉƵŶĐŚƚƵďŝŶŐĂƚΕϰ͕ϮϯϬ͛ Ă͘ϯͲϭͬϮ͟ǆϵͲϱͬϴ͟ĂŶŶƵůƵƐŚĂƐϰϬďďůϭϭƉƉŐŵƵĚƉƵƐŚƐƉĂĐĞƌ ď͘ZĞŵĂŝŶĚĞƌŝƐϭϬƉƉŐĚƌŝůůŝŶŐŵƵĚ ϯ͘ƐƚĂďůŝƐŚĐŝƌĐƵůĂƚŝŽŶĨƌŽŵƚƵďŝŶŐƚŽ/͘ ŽŶƚŝŶŐĞŶĐǇ͗ŝĨĐŝƌĐƵůĂƚŝŽŶĐĂŶ͛ƚďĞĞƐƚĂďůŝƐŚĞĚĂƚůĞĂƐƚϮďƉŵĐŽŶƚĂĐƚK͘DĂǇŚĂǀĞƚŽĐŽŵĞƵƉŚŽůĞ ĂŶĚƉƵŶĐŚͬĐƵƚĂŐĂŝŶ͘ĂĐŬƵƉĐƵƚͬƉƵŶĐŚĚĞƉƚŚсцϰ͕ϭϳϬ͛D ϰ͘KŶĐĞĐŝƌĐƵůĂƚŝŽŶŝƐĞƐƚĂďůŝƐŚĞĚďŽƚŚĚŝƌĞĐƚŝŽŶƐ͕ƐǁĂƉǁĞůůŽǀĞƌƚŽĂůůƐŽƵƌĐĞͬůĞĂƐĞǁĂƚĞƌĂƚŵĂǆƌĂƚĞ ĂŶĚĐůĞĂŶǁĂƚĞƌƌĞƚƵƌŶƐ ϱ͘ZDK>ĂŶĚƉƵŵƉƚƌƵĐŬ ϲ͘D/ZhϰϬϭǁŽƌŬŽǀĞƌƌŝŐ ϳ͘/ŶƐƚĂůůdt͕EƚƌĞĞ͕EhKW ϴ͘dĞƐƚKW ¾dĞƐƚKWƚŽϮϱϬͬϯϬϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘;EŽƚŝĨǇ K'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚͿ͘ ¾/ĨƚŚĞKWŝƐƵƐĞĚƚŽƐŚƵƚŝŶŽŶƚŚĞǁĞůůŝŶĂǁĞůůĐŽŶƚƌŽůƐŝƚƵĂƚŝŽŶŽƌŝĨKWĞƋƵŝƉŵĞŶƚĐŽƵůĚďĞ ĐŽŵƉƌŽŵŝƐĞĚ͕>>KWĐŽŵƉŽŶĞŶƚƐƵƚŝůŝǌĞĚĨŽƌǁĞůůĐŽŶƚƌŽůŽƌĐŽŵƉƌŽŵŝƐĞĚŵƵƐƚďĞƚĞƐƚĞĚ ƉƌŝŽƌƚŽƚŚĞŶĞǆƚƚƌŝƉŝŶƚŽƚŚĞǁĞůůďŽƌĞ͘ ¾KWƐǁŝůůďĞĐůŽƐĞĚĂƐŶĞĞĚĞĚƚŽĐŝƌĐƵůĂƚĞƚŚĞǁĞůůĚƵƌŝŶŐƚŚŝƐǁŽƌŬŽǀĞƌ͘ ϵ͘WƵůůdt ϭϬ͘WŝĐŬƵƉŽŶŚĂŶŐĞƌǁŝƚŚƐŚŽƌƚũŽŝŶƚ '/% tĞůůWƌŽŐŶŽƐŝƐ ϬϮͬϬϭͬϮϬϮϮ ϭϭ͘ZhͲůŝŶĞ ϭϮ͘WƵůůƚƵďŝŶŐŝŶƚĞŶƐŝŽŶ͕;ŶŽŵŽƌĞƚŚĂŶϱϬϬϬηͿ ϭϯ͘Z/,ĂŶĚĐƵƚƚƵďŝŶŐĂƚΕϰ͕ϮϮϱ͛ǁŝƚŚũĞƚĐƵƚƚĞƌ EŽƚĞ͗ ŽŶŽƚŵŽǀĞƚƵďŝŶŐďĞƚǁĞĞŶůŝŶĞƌƵŶƐ ϭϰ͘Z/,ĂŶĚĐƵƚƚƵďŝŶŐĂŐĂŝŶĂƚĐƵƚǁŝƚŚũĞƚĐƵƚƚĞƌĂƚƚƵďŝŶŐĐƵƚ;ĐƵƚĐĂďůĞ͕ƐƚĂŝŶůĞƐƐƚƵďŝŶŐ͕ĞƚĐͿ ϭϱ͘ZůŝŶĞ ϭϲ͘WƵůůĂŶĚůĂǇĚŽǁŶƚƵďŝŶŐ EŽƚĞ͗ƌĞĐŽƌĚŶƵŵďĞƌĐůĂŵƉƐͬďĂŶĚƐĨŽƌĐŽŶƚƌŽůůŝŶĞƐĂŶĚĐĂďůĞ͕ƐĂǀĞĐĞŶƚƌĂůŝǌĞƌƐ;ĚŽŶŽƚĚƌŽƉƐĞƚ ƐĐƌĞǁƐĚŽǁŶŚŽůĞͿ ŽŶƚŝŶŐĞŶĐǇ͗/ĨĞƋƵŝƉŵĞŶƚ͕ĐĂďůĞ͕ŽƌĐŽŶƚƌŽůůŝŶĞĂƌĞůĞĨƚĚŽǁŶŚŽůĞ͕ĂĐĂƐŝŶŐƐĐƌĂƉĞƌƌƵŶǁŝůůďĞ ŵĂĚĞƚŽƉƵƐŚŝƚƚŽďŽƚƚŽŵ͘ ϭϳ͘ZhůŝŶĞ ϭϴ͘>ŽŐ>ĨƌŽŵ/WƚŽƐƵƌĨĂĐĞ ϭϵ͘^ĞƚϵͲϱͬϴ͟/WĂƚΕϰ͕ϭϯϬ͛;ƐĞƚϱ͛ĂďŽǀĞĐŽůůĂƌͿ ϮϬ͘D/d/WƚŽϯϬϬϬƉƐŝ Ϯϭ͘EKW͕EhĚƌǇŚŽůĞƚƌĞĞ ϮϮ͘ZDKZŝŐϰϬϭ ƚƚĂĐŚŵĞŶƚƐ͗ ϭͿĐƚƵĂů^ĐŚĞŵĂƚŝĐ͘ ϮͿWƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯͿtĞůůŚĞĂĚŝĂŐƌĂŵʹƵƌƌĞŶƚ ϰͿtĞůůŚĞĂĚŝĂŐƌĂŵʹWƌŽƉŽƐĞĚ ϱͿZŝŐϰϬϭKWŝĂŐƌĂŵϭϯͲϱͬϴ͟ ϲͿZŝŐϰϬϭʹ&ůƵŝĚ&ůŽǁŝĂŐƌĂŵ ϳͿK'ZtKŚĂŶŐĞ&Žƌŵ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aIW# 0' 'RQQD$PEUX] /HDVH 6WDWH 3HUI79' &DQQHU\/RRS8QLW &RXQWU\ $QJOH#3HUIV *URXQG/HYHO 5HYLVLRQ'DWH $ODVND 86$ a 5.% DERYH06/ $*/ 7RSRI&HPHQWHVW # 0' ILOO 6WHUOLQJ&,QWHUYDO IW0' 2ZHQ&DVW,URQ%ULGJH3OXJVHW # .%Z FPW a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aIW# 0' &KDG+HOJHVRQ /HDVH 6WDWH 3HUI79' &DQQHU\/RRS8QLW &RXQWU\ $QJOH#3HUIV *URXQG/HYHO 5HYLVLRQ'DWH $ODVND 86$ a 5.% DERYH06/ $*/ 7RSRI&HPHQWHVW # 0' ILOO 6WHUOLQJ&,QWHUYDO IW0' 2ZHQ&DVW,URQ%ULGJH3OXJVHW # .%Z FPW aWRSRIFPW# 0' 6WHUOLQJ&,QWHUYDO WZKWK^ &DVW,URQ%ULGJH 3OXJ#a &DQQHU\/RRS &/8&XUUHQW sĂůǀĞ͕hƉƉĞƌDĂƐƚĞƌ͕ s'ϯϬϬ͕ϯϭͬϭϲϭϬD&͕ ,tK͕ƚƌŝŵ sĂůǀĞ͕^ǁĂď͕s'ͲϯϬϬ͕ ϯϭͬϭϲϭϬD&͕,tK͕ ƚƌŝŵ dƌĞĞĐĂƉ͕KƚŝƐ͕ϯϭͬϭϲϭϬD& yϲЪKƚŝƐYƵŝĐŬhŶŝŽŶ ϮϬΖ͛ ϭϯϯͬϴΖ͛ ϵ͘ϲϮϱΖ͛ ϯ͘ϱΖ͛ ^ƚĂƌƚŝŶŐŚĞĂĚ͕ sĞƚĐŽDͲϭϵϲ͕ ϭϯϱͬϴϱDyϭϯϯͬϴs'Ͳ>ŽĐ ďŽƚƚŽŵ͕ǁͬϮͲϮΖ͛>WK DƵůƚŝďŽǁů͕sĞƚĐŽDͲϭϵϲ͕ ϭϯϱͬϴϱDƐƚĚĚďŽƚƚŽŵy ϭϯϱͬϴϱD&ƚŽƉ͕ǁͬ ϮͲϮϭͬϭϲϱD^^K ĚĂƉƚĞƌ͕sĞƚĐŽ͕ϭϯϱͬϴϱD ƐƚĚĚyϯϭͬϭϲϭϬDƐƚĚĚƚŽƉ͕ ƉƌĞƉƉĞĚĨͬϲЪ͛͛ĞǆƚĞŶĚĞĚ ŶĞĐŬ sĂůǀĞ͕s'ͲϮϬϬ͕ϮϭͬϭϲϱD&͕ ,tK͕ƚƌŝŵ sĂůǀĞ͕DĂƐƚĞƌ͕s'ͲϯϬϬ͕ ϯϭͬϭϲϭϬD&͕,tK͕ ƚƌŝŵ ĂŶŶĞƌǇ>ŽŽƉ >hηϭϬ ϮϬyϭϯϯͬϴyϵϱͬϴyϯЪ &ĂůƐĞŚĂŶŐĞƌŶĞĐŬ͕sĞƚĐŽ 'ƌĂǇDͲϭϵϲ͕ϭϯϱͬϴϱDǆϯΖ͛ /tdǇƉĞ,WsƉƌŽĨŝůĞ͕ EŽ>ŝĨƚdŚƌĞĂĚƐ ǆĐĂƉĞůŝŶĞƐǆϯ &DQQHU\/RRS &/87HPSDEDQGRQPHQW ϮϬΖ͛ ϭϯϯͬϴΖ͛ ϵ͘ϲϮϱΖ͛ ^ƚĂƌƚŝŶŐŚĞĂĚ͕ sĞƚĐŽDͲϭϵϲ͕ ϭϯϱͬϴϱDyϭϯϯͬϴs'Ͳ>ŽĐ ďŽƚƚŽŵ͕ǁͬϮͲϮΖ͛>WK DƵůƚŝďŽǁů͕sĞƚĐŽDͲϭϵϲ͕ ϭϯϱͬϴϱDƐƚĚĚďŽƚƚŽŵy ϭϯϱͬϴϱD&ƚŽƉ͕ǁͬ ϮͲϮϭͬϭϲϱD^^K sĂůǀĞ͕s'ͲϮϬϬ͕ϮϭͬϭϲϱD&͕ ,tK͕ƚƌŝŵ ĂŶŶĞƌǇ>ŽŽƉ >hηϭϬ ϮϬyϭϯϯͬϴyϵϱͬϴ 7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG ϭϯͲϱͬϴΗ^ƉŚĞƌŝĐĂůŶŶƵůĂƌ ,ĞŝŐŚƚ͗ϰϲΗ tĞŝŐŚƚ͗ϭϮ͕ϴϬϲ ϭϯͲϱͬϴΗ>t^ŽƵďůĞKW ,ĞŝŐŚƚ͗ϯϳΗ tŝĚƚŚ͗ϵϯΗ tĞŝŐŚƚϵ͕ϵϬϬůďƐ͘ dKWZD^ ϮͲϳͬϴΗdKϱͲϭͬϮΗDh>d/Ͳ ZD^ KddKDZD^ >/EZD^ ϭϯͲϱͬϴΗDƵĚƌŽƐƐtͬϰͲ ϭͬϭϲΗŽƵƚůĞƚƐ ,ĞŝŐŚƚ͗Ϯϴ͘ϱΗ tŝĚƚŚϯϭΗ ƵĂůϰͲϭͬϭϲΗDĂŶƵĂů'ĂƚĞ ǀĂůǀĞƐtͬ^ƚŽϮͲϭͬϭϲΗ ϰͲϭͬϭϲΗDĂŶƵĂů'ĂƚĞ ǀĂůǀĞΘϰͲϭͬϭϲΗ,Ztͬ ^ƚŽϮͲϭͬϭϲΗ &Ƶůů DƵĚƌŽƐƐƐƐǇ͘ǁŝĚƚŚ ǁͬǀĂůǀĞƐŝŶƐƚĂůůĞĚ tŝĚƚŚ͗ϵϴ͘ϱΗ tĞŝŐŚƚ͗ ϮϮϬϬůďƐ͘ <ŝůůƐŝĚĞ ŚŽŬĞƐŝĚĞ ,ĞŝŐŚƚĚĚŝƚŝŽŶĨŽƌZŝŶŐ'ĂƐŬĞƚƐ͗ϬΗ KWdŽƚĂů ,ĞŝŐŚƚ͗ϭϭϭ͘ϱΗ KW dŽƚĂůǁĞŝŐŚƚ͗Ϯϰ͕ϵϬϲůďƐ͘ ϭϯͲϱͬϴΗϱŵKW WĂĐŬĂŐĞ tͬϰͲϭͬϭϲΗsĂůǀĞƐ +LOFRUS$ODVND//&+LOFRUS$ODVND//&Changes to Approved Rig Work Over Sundry Procedure6XEMHFW &KDQJHVWR$SSURYHG6XQGU\3URFHGXUHIRU:HOO&/837'6XQGU\;;;;;;$Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHULJZRUNRYHU5:2³ILUVWFDOO´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y Samantha Carlisle at 12:34 pm, Dec 07, 2021 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH 8450 DLB 12/07/2021 DSR-12/7/21 8002 X SFD 1/1/2022 Superseded by Sundry 322-391. P&A effective 9/25/2022 ^ƵƐƉĞŶĚĞĚtĞůů/ŶƐƉĞĐƚŝŽŶĂƚĂ tĞůů͗ĂŶŶĞƌǇ>ŽŽƉhŶŝƚϭϬ ^ƵƌĨĂĐĞ>ŽĐĂƚŝŽŶ͗Ϯϳϯ͛&^>͕ϱϮϬ͛&>͕^ĞĐ͘ϳ͕dϱE͕Zϭϭt͕^͘D͘ WĞƌŵŝƚƚŽƌŝůů͗ϮϬϱͲϭϬϲ W/͗ϱϬͲϭϯϯͲϮϬϱϱϯͲϬϬͲϬϬ K'/ŶƐƉĞĐƚŝŽŶĂƚĞ͗ϬϵͲϬϳͲϮϬ K'/ŶƐƉĞĐƚŽƌ͗ŽďEŽďůĞ ,ŝůĐŽƌƉZĞƉƌĞƐĞŶƚĂƚŝǀĞ͗<ĞǀŝŶĂƐƐŝĚǇ ^ŝǌĞWƌĞƐƐƵƌĞ;ƉƐŝͿ dƵďŝŶŐϯͲϭͬϮ͟Ϭ ĂƐŝŶŐϵͲϱͬϴ͟Ϭ ΎEŽƚĞ͗tĞůůŚĞĂĚƉƌĞƐƐƵƌĞƐƚŽďĞƌĞĐŽƌĚĞĚŵŽŶƚŚůǇĂƚŵŝŶŝŵƵŵ͘ ,ŝůĐŽƌƉůĂƐŬĂ͕>>ƐƵďŵŝƚƐƚŚŝƐƐƵƐƉĞŶĚĞĚǁĞůůƌĞŶĞǁĂůƌĞƋƵĞƐƚƉĞƌϮϬϮϱ͘ϭϭϬ͘ĂŶŶĞƌǇ >ŽŽƉhŶŝƚϭϬǁĂƐŝŶƐƉĞĐƚĞĚŽŶ^ĞƉƚĞŵďĞƌϳ͕ϮϬϮϬďǇŝŶƐƉĞĐƚŽƌŽďEŽďůĞĂŶĚĂϭϬͲϰϬϰǁĂƐ ƐƵďŵŝƚƚĞĚĂŶĚĂƉƉƌŽǀĞĚ͘ :ƵƐƚŝĨŝĐĂƚŝŽŶĨŽƌ^ƵƐƉĞŶƐŝŽŶZĞŶĞǁĂů͗ x>hϭϬŝƐǁĞůůƉŽƐŝƚŝŽŶĞĚĨŽƌĨƵƚƵƌĞƐŝĚĞƚƌĂĐŬŽƉƉŽƌƚƵŶŝƚŝĞƐ͕ƚŚŝƐĐŽƵƉůĞĚǁŝƚŚƚŚĞ ǁĞůůďŽƌĞďĞŝŶŐŝŶŐŽŽĚŚĞĂůƚŚ͕ŵĂŬĞƐŝƚĂƉƌŝŵĞĐĂŶĚŝĚĂƚĞĨŽƌĨƵƚƵƌĞŝŶǀĞƐƚŵĞŶƚ͘ KƚŚĞƌEŽƚĞƐ͗ xŽŶĚŝƚŝŽŶŽĨtĞůůŚĞĂĚ͗tĞůůŚĞĂĚǁĂƐŝŶŐŽŽĚĐŽŶĚŝƚŝŽŶǁŝƚŚůŝŶ ĞƐďůŝŶĚĞĚ͘EŽůĞĂŬƐŽƌ ĚƌŝƉƐ͘ xŽŶĚŝƚŝŽŶŽĨ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞ>ŽĐĂƚŝŽŶ͗tĞůůŚĞĂĚǁĂƐƉƌŽƚĞĐƚĞĚǁŝƚŚǁĞůůŚŽƵƐĞ͘ x&ŽůůŽǁhƉĐƚŝŽŶƐŶĞĞĚĞĚ͗EŽŶĞ ƚƚĂĐŚŵĞŶƚƐ͗ xƵƌƌĞŶƚtĞůů^ĐŚĞŵĂƚŝĐ xWŝĐƚƵƌĞ;ƐͿ xWůĂƚͲϭͬϰŵŝůĞƌĂĚŝƵƐŽĨǁĞůůďŽƌĞ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aIW# 0' 'RQQD$PEUX] /HDVH 6WDWH 3HUI79' &DQQHU\/RRS8QLW &RXQWU\ $QJOH#3HUIV *URXQG/HYHO 5HYLVLRQ'DWH $ODVND 86$ a 5.% DERYH06/ $*/ 7RSRI&HPHQWHVW # 0' ILOO 6WHUOLQJ&,QWHUYDO IW0' 2ZHQ&DVW,URQ%ULGJH3OXJVHW # .%Z FPW aWRSRIFPW# 0' 6WHUOLQJ&,QWHUYDO Y * Y Q ' ' !!! ! !!! ! ! ! !! !Q*Y**,*Y Q Q ***YY&/8 61: &$11(5< /223 81,7 .(1$,81,7 &/8 &/8 &/8 .8 &/86 &/86 CLU S-4 CLU S - 5 CLU 10 CLU 14 CLU 09 CLU 0 5 CLU 13 CLU 08 CLU 0 5 R D CLU 0 7 CLU 0 1 CLU 0 1 R D CLU 0 1 R D P B 1 CLU 0 6 &/81R3DG 6HF 6HF 6HF6HF )HHW $ODVND6WDWH3ODQH=RQH1$'¯ /HJHQG 4XDUWHU0LOH5DGLXVDURXQG:HOO%RUH 2LODQG*DV8QLW%RXQGDU\ 0DS'DWH &$11(5</22381,7 &/86XVSHQGHG:HOO ! ! ! !! ! /RFDWLRQ0DS 2YHUYLHZ Coo k I n l e t .HQDL +RPHU 7\RQHN 6HZDUG1LQLOFKLN $QFKRUDJH +$.3HWUD:HOO6\PERO**DV,6,*DV Q 3 $ Y 6XVSHQGHG 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Suspended Well Inspection Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 5,410; 5,532; 5,649; Total Depth measured 8,450 feet 5,830; 6,906 feet true vertical 8,002 feet 8,292 feet Effective Depth measured 5,374 feet N/A feet true vertical 4,926 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 8,419' MD 7,971' TVD Packers and SSSV (type, measured and true vertical depth)N/A; N/A N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi 10,160psi 123' 1,866' 5,750psi 3,450psi Collapse 1,500psi 1,950psi 3,090psi 10,530psi Casing Structural 20' 13-3/8" 9-5/8" Length 123' 1,953' 5,410' 8,419' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-106 50-133-20553-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Cannery Loop Unit 10 N/A ADL0002397|FEE-WCPC 5,410' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai C.L.U. / Beluga Gas, Sterling Undefined GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 3-1/2"8,419' 4,962' 7,971' WINJ WAG 0 Water-Bbl MD 123' 1,953' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:28 am, Sep 28, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.25 16:56:56 -08'00' Taylor Wellman SUSP SFD 9/29/2020 RBDMS HEW 10/26/2020 DSR-9/28/2020 Suspended Well Inspection gls 10/8/20 KEN June 2020 Suspended Well Inspection Data Well: Cannery Loop Unit 10 Surface Location: 273’ FSL, 520’ FEL, Sec. 7, T5N, R11W, S.M. Permit to Drill: 205-106 API: 50-133-20553-00-00 AOGCC Inspection Date: 09-07-20 AOGCC Inspector: Bob Noble Hilcorp Representative: Kevin Cassidy Size Pressure (psi) Tubing 3-1/2” 0 Casing 9-5/8” 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x Condition of Wellhead: Wellhead was in good condition with lines blinded. No leaks or drips. x Condition of Surrounding Surface Location: Well head was protected with well house. x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore Tree cxn = 4-3/4" Otis Excape System Details - 12 Excape modules placed -Green control line fired module 1 -Yellow control line fired modules 2 thru 8 -Red contol line fired modules 9 thru 12 - Ceramic flapper valves below each module except for module 1 Plugged Beluga Perfs: (RKB) Module 12 - 5,674' - 5,684' Squeezed 12/11/07 Module 11 - 5,713' - 5,723' Squeezed 12/11/07 Module 10 - 5,880' - 5,890' Module 9 - 6,956' - 6,966' Module 8 - 7,030' - 7,040' Module 7 - 7,083' - 7,093' Module 6 - 7,174' - 7,184' Module 5 - 7,716' - 7,726' Module 4 - 7,965' - 7,975' Module 3 - 8,098' - 8,108' Module 2 - 8,219' - 8,229' Module 1 - 8,265' - 8,275' Top of Cement (cbl) @ 4,260' MD 1150' above 9-5/8" shoe Excape System Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 12 -5,690' Module 11 -5,729' Module 10 -5,897' Module 9 - 6,976' Module 8 -7,049' Module 7 - 7,106' Module 6 -7,196' Module 5 -7,736' Module 4 -7,985' Module 3 -8,118' Module 2 -8,240' Module 1 -NA Permit #:205-106 API #:50-133-20553-00-S02 Prop. Des:ADL 02397 KB elevation:41' (21' AGL) WBS #: Latitude:60°31' 56.84" N Longitude: 151°15' 48.37" W Spud:7/22/2005 TD:8/3/2005 Rig Released:12:00hrs 8/10/2005 CLU-10 Pad 1 273' FSL, 520' FEL, Sec. 7, T5N, R11W, S.M. Drive Pipe 20" K-55 133 ppf Top Bottom MD 0' 123' TVD 0' 123' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,953' TVD 0' 1,866' 16" hole Cmt w/ 606 sks (246 bbl) of 12.0 ppg, Type 1 Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd w/ 6.25" OD control line protectors Top Bottom MD 0' 8,419' TVD 0' 7,971' 8.5" hole Cmt w/ 1,324 sks (274 bbls) of 15.8 ppg, class G PBTD 5,374' MD 4,926' TVD Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,410' TVD 0' 4,962' 12.25" hole Cmt w/ 417 sks of class G, (75 bbls) of 12.5 ppg, Lead & (45 bbls) of 15.8 ppg, Tail TD 8,450' MD 8,002' TVD Junk Plug Remains @ 8,292' CTM SandC 1 C1 C2 Date 10/17/09 10/10/09 10/6/09 Gun Type 2" 6 spf 60º 2-3/8" 4 spf 60º 2-3/8" 4 spf 60º TVD 4,977'-4,992' 4,977'-4,992' 5,087'-5,107' Ft 15 15 20 MD 5,425'-5,440' 5,425'-5,440' 5,535'-5,555' Sterling Perfs: 3.5" Owen Cast Iron Bridge Plugs set: @ 5,649' KB w/ 65' cmt (10/02/09) top of cmt tagged @ 5,583' MD (10/6/09) @ 5,830' KB w/ 58' cmt (10/01/09) @ 6,906' KB w/ 35' cmt (09/29/09) 3.5" Owen Cast Iron Bridge Plug set: @ 5,532' KB w/ 15' cmt (10/14/09) 10' of fill above Bridge Plug top of cmt @ 5,507' MD Well Name & Number: Municipality: Perforations (MD): Angle @ KOP & Depth: Date Completed: Revised by: Cannery Loop Unit # 10 Kenai Peninsula Borough 5,419' - 5,555' ~ 3º / 100 ft @ 750' MD 8/31/2005 Donna Ambruz Lease: State: Perf (TVD): Cannery Loop Unit Country: Angle @ Perfs: Ground Level: Revision Date: Alaska USA 4,971' - 5,107' ~3º RKB:41' (above MSL)21' (AGL) 09-18-2020 Top of Cement (est.) @ 3,260' MD 100% fill Sterling C1 Interval: 5,372,-,5,614 ft MD 3.5" Owen Cast Iron Bridge Plug set: @ 5,410' KB w/ 36' cmt (2/9/12) ~top of cmt @ 5,374' MD Sterling C2 Interval: Y * Y Q ' ' !!! ! !!! ! ! ! !! !Q*Y**,*Y Q Q ***YYCLU 10 S005N011W CANNERY LOOP UNIT KENAI UNIT CLU 05 CLU 09 CLU 10 KU 13-08 CLU S-4 CLU S-5 CLU S-4 CLU S-5CLU 10 CLU 14 CLU 09CLU 05CLU 13 CLU 08CLU 05RDCLU 07CLU 01CLU 01RDCLU 01RDPB1CLU 06CLU No. 1 Pad Sec. 8 Sec. 7 Sec. 17Sec. 18 0 380 760 Feet Alaska State Plane Zone 4, NAD27 ¯ Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 6/22/2020 CANNERY LOOP UNIT CLU 10 Suspended Well ! ! ! !! ! Location Map Overview Coo k I nl et Kenai Homer Tyonek SewardNinilchik Anchorage HAK Petra Well Symbol*Gas,SI Gas Q P&A Y Suspended ` Suspended WellInspection R'ew Report |nspectNo: susKCN200908173300 Date Inspected: 9/7/2020 ' Inspector: Bob Noble TypeofInspection: Subsequent Well Name: CANNERY LOOP UNIT lO Date AO6CCNotified: 9/4/2020 Permit Number: 2051060' Operatoc Hi|co/pA|aska, LL[ � Suspension Approval: Sundry _ A 312-040 ' Operator Rep: Kevin[aszey Suspension Date: 2/9/2012 ' Wellbore Diagram Avail? Location Verified? E/1 Photos Taken? � <fVerified, How? Other (specify incomments) - Offshore? 7 Well Pressures (psi): Tubing: O Fluid in Cellar? W ' � !A: 0 8PV|nsta!!e67 El OA: O VRP|ug(s)Installed? E] Wellhead Condition Wellhead is in good condition with all lines blinded. No sign of leaks or drips. - Condition ofCellar � The cellar was good clean dry gravel. ' Su/nmund|n�Su�ace[ondkiun Wellhead protected with awell house. Pad was good clean gravel. ^ Comments � Location was verified with a pad map. Supervisor Comments Photos (2) attached.� m��c- / "J[�`- UI/��/ Monday, September 21, 2020 0 0 C)tic T- co O C) p Z N O m Q 0 L F" cV O Z a U aUi o� N JitU U �U I �O =U�o QU o 0 (� N 0-- U) -- t% OQ0-0 STATE OF ALASKA ALA" OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Suspended Well Inspection❑ 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Exploratory ❑ ` 205-106 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 e 50-133-20553-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-02397• Cannery Loop Unit 10 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A 0" Cannery Loop/Sterling Undefined Gas Pool 11.Present Well Condition Summary: 5,410;5,532;5,649; Total Depth measured • 8,450 feet Plugs measured 5,830;6,906 feet �r , '`�rE hi Ell true vertical . 8,002 feet Junk measured 8,292 feet EP 112015 Effective Depth measured 5,374 feet Packer measured N/A feet true vertical 4,926 feet true vertical N/A feet AOGC Casing Length Size MD TVD Burst Collapse Structural Conductor 123' 20" 123' 3,060 psi 1,500 psi Surface 1,953' 13-3/8" 1,953' 1,866' 3,450 psi 1,950 psi Intermediate 5,410' 9-5/8" 5,410' 4,962' 5,750 psi 3,090 psi Production 8,419' 3-1/2" 8,419' 7,971' 10,160 psi 10,530 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic CANNED DEC 1 4 2015 Tubing(size,grade, measured and true vertical depth) 3-1/2" 9.3#/L-80L- 8,419'MD 7,971'TVD Packers and SSSV(type,measured and true vertical depth) N/A;N/A N/A; N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory Development * Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Li WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ • SUSP 2 SPLUG❑ 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: N/A Contact Taylor Nasse Email tnasse@hilcorp.com Printed Name Taylor Nasse Title Operations Engineer Signature On12/ Phone 907-777-8354 Date ? 4(/' Form 10-404 Revised 5/2015 41.i 7/3 , RBDMS EP 15 2015 Submit Original Only • • Suspended Well Inspection Data Well: Cannery Loop Unit 10 Surface Location: 273' FSL, 520' FEL, Sec. 7,T5N, R11W, S.M. Permit to Drill: 205-106 API: 50-133-20553-00-00 AOGCC Inspection Date: 08-17-2015 AOGCC Inspector: Johnnie Hill Operator Rep: Mike Chivers Size Pressure (psi) Tubing 3-1/2" 0 Casing- IA 9-5/8" 0 Casing-OA 13-3/8" 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Condition of Wellhead: Good • Condition of Surrounding Surface Location: Good • Follow Up Actions Needed: None Attachments: • Current Well Schematic • Pictures (3) • Plat—1/4 mile radius of wellbore (KEN July 2015) • • Permit#: 205-106 CLU-10 API#: 50-133-20553-00-S02 II Prop.Des: ADL 02397 KB elevation: 41' (21'AGL) Pad 1 Ililrarp %Iaska.LI.c WBS#: 273' FSL, 520' FEL, Drive Pipe Latitude: 60°31'56.84"N 20" K-55 133 ppf Sec. 7, TSN, R11W, S.M. Longitude: 151°15'48.37"W Top Bottom Spud: 7/22/2005 MD 0' 123' TVD 0' 123' 8/3/2005 Rig Released:12:OOhrs 8/10/2005 Surface Casing 13-3/8" L-80 68 ppf BTC , , VI , 4IN:La4 Top Bottom MD 0' 1,953' ND 0' 1,866' Tree cxn=4-3/4"Otis 16"hole Cmt w/606 sks(246 bbl)of 12.0 ppg,Type 1 Top of Cement(est.) Intermediate Casing @ 3,260'MD ._ 9-5/8" L-80 40 ppf BTC 100%fill Top Bottom ! MD 0' 5,410' e TVD 0' 4,962' Top of Cement(cbl) ---------------1.1: 12.25"hole Cmt w/417 sks of class G,(75 bbls) @ 4,260'MD of 12.5 ppg,Lead&(45 bbls)of 15.8 ppg,Tail 1150'above 9-5/8"shoe Production Tubing 3.5"Owen Cast Iron Bridge Plug set: '' 3d w/ L-80O9.3 ppf EUE w/6.25"OD control line protectors @ 5,410'KB w/36'cmt (2/9/12) °' / - - Sterling C1 Interval: Top Bottom -top of cmt @ 5,374'MD ` 5,372,-,5,614 ft MD MD 0' 8,419' I ND 0' 7,971' 8.5"hole Cmt w/1,324 sks(274 bbls)of 15.8 ppg,class G 3.5"Owen Cast Iron Bridge Plug set: @ 5,532'KB w/15'cmt (10/14/09) Sterling C2 Interval: 10'of fill above Bridge Plug ' I. top of cmt @ 5,507'MD y • . i 3.5"Owen Cast Iron Bridge Plugs set: @ 5,649'KB w/65'cmt (10/02/09) Sterling Perfs: top of cmt tagged @ 5,583'MD(10/6/09) SandC MD Ft ND Gun Type Date 4 - @ 5,830'KB w/58'cmt (10/01/09) 1 5,425-5,440' 15 4,977-4,992' 2" 6 spf 60° 10/17/09 @ 6,906'KB w/35'cmt (09/29/09) Cl 5,425-5,440' 15 4,977'-4,992' 2-3/8"4 spf 60° 10/10/09 C2 5,535-5,555' 20 5,087'-5,107' 2-3/8"4 spf 600 10/6/09 - i Excape System Details -Ceramic flapper valves below each module as follows: Excape System Details Flappers MD(RKB): ` -12 Excape modules placed Green control line fired module 1 Module 12-5,690' ! - control line fired modules 2 thru 8 Module 11-5,729' III .7.„ -Red contol line fired modules 9 thru 12 Module 10-5,897' - -Ceramic flapper valves below each module V, fel except for module 1 Module 9-6,976' V Module 8-7,049' s Plugged Beluga Perfs:(RKB) Module 7-7,106' V. Module 12 5,674' 5,684' Squeezed 12/11/07 Module 6-7,196' `!4lC.- - -, -' -, ' Squeezed 12/11/07 Module 5-7,736' i litI Module 10 5,880' 5,890' Module 4-7,985' r- Module 9 6,956' 6,966' Module 3-8,118' 'r Bit ,.'r Module 8 7,030' 7,040' Module 2-8,240' CV Module 7 7,083' 7,003' Module 1- NA *top Module Module 6 7,174' 7,184' Module 5 7,716' 7,726' eiI Module 3 8,098' 8,108' Module 2 8,219' 8,229' Junk TD PBTD Plug Remains©8,292'CTM 8,450'MD 5,532'MD 8,002'ND 5,084'TVD Well Name&Number: Cannery Loop Unit#10 Lease: Cannery Loop Unit Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations(MD): 5,419'-5,555' Perf(TVD): 4,971'-5,107' Angle @ KOP&Depth: --3°/100 ft @ 750'MD Angle @ Perfs: -30 Date Completed: 8/31/2005 Ground Level: 41'(above MSL) RKB: 21'(AGL) Revised by: Kevin Skiba Revision Date: 2/22/2012 0 0 Y. .... ,.. , . . . = . .. ...1 a. 0 cn. ix ...,......... . . ,.. . . ........ .. „,..... . ' .. 4-) cr) z 4e.e., 1::: cr) cm e- . i LC) 0 P..7 C' - C-) . . . .... .. -'.• a_ C) C- 11` 0 d) ' ' ' 0 - Pawl ta __I r- - - U) 0 ui ' ... c\,1 0 (..) w Lc) ,..,.. cf) I 1, LT-43:17:-..:f." -P z. a , .. ..... . . . .. , . - . 0 < o_ u.. (r) cn .., .. . . ,, .. . ...... . , ... . u _ - ...... .,. ... , , ,... ,.....„.„.., , . ... If 4411k .44 . '%.....t" r, ..,, ' i. . ,.... ',Pr.: • • tf ,, ;_, { • S CLU 03 CLU 04 CLU S-1 CLU 12 G CLU 11 IIIIIV CLU 07 CLU 01 1 O CLU 06 CLU 01RD CLU 05 CLU 13 CLU 08 • CLU S-3 ,�-G CLU 09 Hilcorp Alaska j Cannery Loop Suspended Wells CLIL.7-4 -- ----- - Quarter Mile Radius Map CLU 10 ? loou 290 FEET POSTED WELL DATA • GCLU S-5 WWI Label • WELL SYMBOLS Onlled Gas-Input Well Gas Well Election Well Shul-in Well Shut-in Gas Well 1 September 2,2015 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/17/15 Inspector: Johnnie Hill Operator: Hilcorp Well Name: Cannery Loop Unit 10 ' Oper. Rep: Mike Chivers PTD No.: 205-106 Oper. Phone: 283-1345 Location Verified? Yes Oper. Email: If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 02/09/12 Date AOGCC Notified: 08/14/15 Sundry No.: 312-040 Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 • Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: good Condition of Surrounding Surface - Location: good gravel Follow Up Actions Needed: none • Comments: well was verified by pad well location map Attachments: Photos(2) REVIEWED BY: Insp.SupryJ /742- Comm "i22Comm SCANNED SEP 1 5 2016 PLB 06/2014 2015-0817_Suspend_CLU-10Jh.xlsx • • • • 4 N !ii Se.) J • U O ., O O O � Z u7el, L0 O �N. s l4 N D U� r ` a. CoQ 01U 0J v W. w „yoQU) 4 10 Z. 4t. <CLL. Z O w rCw a aw7w • O -�. 0 .. 4 -d a x _ .- .. o 0 OU •II . 'mo�ii,I V � 4cD a $ ' U U a U -0 ) 0 El. 'V o A r4CD 00 o Cu y p N vi a.) D H ,. r-" on ) aao0 oa : • 0 S FST a 4 ilikAt 410 ill 4 , i R I 4 111111 „, , =”‘ i r tt? ' . C c • \ 2015-0817_Suspend_CLU-10_photos_j h.docx Page 2 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Monday, March 12, 2012 P.I. Supervisor � Z SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 10 FROM: Matt Herrera CANNERY LOOP UNIT 10 Petroleum Inspector Src: Inspector Reviewed By;,,, P.I. Supry 3 8(1— NON - CONFIDENTIAL Comm Well Name: CANNERY LOOP UNIT 10 API Well Number: 50 - 133 - 20553 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH120307102025 Permit Number: 205 - 106 - 0 Inspection Date: 3/1/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 10 ' Type Inj. N � I TVD IA 10 545 - 545 545 545 - PTDI 2051060 ' TypeTest SPT Test psi 500 OA Interva °TAR PIF P Tubing ° 0 _1 ° 0 0 Notes: Monobore completion NO OA. MIT performed for CINGSA order no. 9,Sundry 312 -031. SLA WNED JUN 12 2012 Monday, March 12, 2012 Page 1 of 1 Marathon Alaska Production LLC 1 ,\ Alaska Asset Team r thon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 February 23, 2012 RECEIVED Mr. Daniel Seamount FEB 2 7 20 Alaska Oil & Gas Conservation Commission 333 W 7 Ave Alaska Oil & Gas Cons. Commission Anchorage, Alaska 99501 _ anchorage Reference: 10 -407 Well Completion Report and Log ao 10 :;:) Field: Cannery Loop Unit Well: Cannery Loop Unit #10 Dear Mr. Seamount, Submitted for your records is the Well Completion Report and Log for CLU -10 well. In conjunction with the development of the CINGSA gas storage project, plugs were placed in the CLU -10 production tubing to isolate the Sterling C1 and C2 sands. Please contact me at (907) 283 -1371 if you have any questions or require additional information. Sincerely, FEB z1u12, / c j 9 .-- " --5 Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -407 Well Completion Report & Log cc: Houston Well File Well Schematic Kenai Well File Operations Summary (2) KJS STATE OF ALASKA ALASKOPIL AND GAS CONSERVATION COMMIS N WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: al ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill #: 205 - 106 Marathon Alaska Production LLC Aband.: 2/9/2012 Sundry #: 312 - 040 3. Address: PO Box 1949 6. Date Spudded: 13. API Number: Kenai Alaska, 99611 -1949 7/22/2005 50- 133 - 20553 -00 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 273' FSL, 520' FEL, Sec. 7, T5N, R11W, S.M. 8/3/2005 Cannery Loop Unit #10 Top of Productive Horizon: 8. KB (ft above MSL): 41' 15. Field /Pool(s): 80' FNL, 1,255 FWL, Sec. 17, T5N, R11W, S.M. GL (ft above MSL): 20' Cannery Loop Unit /Sterling Total Depth: 9. Plug Back Depth(MD +TVD): 84' FNL, 1,269' FWL, Sec. 17, T5N, R11W, S.M. 5,374' 4,926' Undefined Gas Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 272,452.10 y- 2,388,727.00 Zone- 4 8,450' 8,002' ADL - 02397 TPI: x- 274,220.41 y- 2,388,339.78 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 274,233.56 y- 2,388,335.72 Zone- 4 NA NA 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re- drill /Lateral Top Window MD/TVD: NA 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 133 K -55 0' 123' 0' 123' Driven NA NA 13 -3/8" 68 L -80 0' 1,953' 0' 1,866' 16" 606 sks 0 9 -5/8" 40 L -80 0' 5,410' 0' 4,962' 12 -1/4" 417 sks 0 3 -1/2" 9.3 L -80 0' 8,419' 0' 7,971' 8 -1/2" 1,324 sks 0 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) MD TVD Perf Size Number 3 -1/2" 8,419' NA C ACID, FRACTURE, CEMENT SQUEEZE, ETC. 1 RECEIVED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED FEB 2 7 2012 I 27. ` tlaskR Oil & Gas Cons. tlamto $BtAtN TEST Date First Production: A *pod of Operation Flowing, gas lift, etc.): 9/1/2005 _.._ Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: NA - Test Period - - - - 100% gas Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: - Oil Gravity - API (corr): Press. - 0 24 -Hour Rate — - - 0 NA 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. RBDMS FEB 2 8 201 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE74/ - 24- 446kJWrlgj;t,� 6 29. GEOLOGIC MARKERS (List all formations and marker ountered): 30. FORMATI STS NAME MD TVD Well tested? Yes Li No U If ye , t intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top and submit detailed test information per 20 AAC 25.071. Permafrost - Base Sterling 5,026' 4,579' Beluga 5,614' 5,166' Tyonek 8,278' 7,830' Formation at total depth: Tyonek 8,450' 8,002' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283 -1371 Printed Name: Kevin J. Skiba �� , Title: Regulatory Compliance Representative ,� Signature: Sdun, , , S$ * Phone: (907) 283-1371 Date: February 23, 2012 V 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 Item lb: 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 prod Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 in Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Ag rations Summary Report by Jobe . Marathon Oil ell Name: CANNERY LOOP UNIT 10 Qtr /Qtr, Block, Sec, Town, Range • Field Name License # State /Province Country 6007005N011W01 CANNERY LOOP UNIT 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 20.00 41.00 21.00 7/23/2005 8/6/2005 Daily Operations Report Date: 2/9/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard E line to set CIBP and dump bail cement. Did not have nor could they get the correnct XO in a timely manner. Shut down for the night. NO charges for today. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:00 09:00 1.00 SAFETY MTG Hold PJSM. Obtain SWP. Discuss JSEA. Discuss emergency procedures, alarms, and muster area. Make job assignment and talk about specific hazards. Notified Mr Jim Regg with AOGCC the 9:00 am that we would need a �;' witness for the tagging of the CIBP's and the dump bailing of cement on top. 09:00 11:06 2.10 RURD ELEC Spot equipment. MU lubricator. MU tool string- gamma /CCL. Carry QTS /BOP's /8' lubricator to Wellhead. Brought XO for 3 -1/16 5M wellhead. Need XO for 4-1/8 10 M tree. 11:06 14:06 3.00 WAITON EQIP Wait on wellhead XO. 14:06 16:06 2.00 RURD ELEC Pollard bringing a threaded flange that they can RU to. Knock out tree cap flange. Waiting for proper flange. Flange shows up and is wrong 4- 1/16" 5M. Wrong flange. Reinstall tree cap flange and PTest. Nearest correct flange is 2 -1/2 hours away at Susan Dionne pad. Send crew and boom truck to retrieve flange. Shut down job for the night. 16:06 16:21 0.25 SECURE WELL Secure wellhead and location for the night. Turn in permit and sign out. Report Date: 2/10/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard E line. Tagged CIBP @ 5521.5'. Original retainer set © 5532'. in October of 2009. Must have had some fill. Dump bailed approx 14 gals of cement(36') on CIBP. Set second CIBP a 5410' and dump bailed approx 14 gals of cement (36') on top. Cement samples taken of each batch of cement set hard by Saturday morning. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:00 08:45 0.75 SAFETY MTG Hold PJSM. Obtain SWP. Discuss JSEA. Discuss emergency procedures, alarms, and muster area. Make job assignment and talk about specific hazards. Notified Mr Jim Regg with AOGCC the 9:00 am that we would need a witness for the tagging of the CIBP's and the dump bailing of cement on top. 08:45 09:45 1.00 RURD ELEC Start equipment. MU lubricator. MU tool string- gamma /CCL with 2.90" GR.. Carry QTS /BOP's /8' lubricator to Wellhead. 09:45 09:57 0.20 TEST EQIP PTest lubricator to 1500 psi. Test good. 09:57 11:57 2.00 RUNPUL ELEC RIH w/ 2.90" GR to tag top of CIBP. Logged two passes with the gamma ray /CCL to get on depth. Tagged © 5521.5'. Tag witnessed by Mr. Lew Gramaldi AOGCC. Approximately 10' of fill on top of CIBP. Called and discussed this issure with Mr. Jim Regg. He discussed with Guy Shwartz. It was decided that we could go forward. 11:57 13:33 1.60 BAIL FLD PU 30' of 2 -1/2" dump bailer. Fill with approx 7 gals of cement. RIH to 5521'. Log to get on depth. RIH to 5487' plus 34' of tool length. Dumped cement @ 5521'. PU 5'. Wait. PU 5'. wait. PU to 5507'. Wait. loose approx 100 Ibs on weight indicator. TOC is 5507'. POOH. 13:33 14:33 1.00 BAIL FLD Load bailer with approx 7 gals of cement. RIH to 5478'. Log uphole to get on depth. RUn back in Report Date: 2/15/2012 Job Category: R &M MAINTENANCE 24 Hr Summary MIRI Baker to load well with fresh water and PTest to 1500 psi. Witnessed by the AOGCC inspector. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG Hold PJSM. Obtain SWP. Discuss JSEA. Discuss emergency procedures, alarms, and muster area. Make job assignment and talk about specific hazards. Notified Mr Jim Regg with AOGCC the 9:00 am that we would need a witness for the tagging of the CIBP's and the dump bailing of cement �C on top. 08:00 09:00 1.00 RURD EQIP MIRU Baker pump truck to pressure test 3 -1/2" casing. RU 2" hard lilne. 09:00 09:00 TEST EQIP Presssure test lines to 2350 psi. Test good. 09:00 09:00 PUMP WTR Pump 41 bbls of fresh water to load casing. 09:00 09:00 TEST CSG RU calibrated gauge and chart recordrer. Pressure test casing to 1650 psi. Hold pressure for 35 minutes. No change in presssure. Test was witnessed by Mr. Bob Noble with the AOGCC. www.peloton.com Page 1/2 Report Printed: 2/21/2012 1(\ // *rations Summary Report by Job, .Marathon Oil Well Name: CANNERY LOOP UNIT 10 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6007005N011W01 CANNERY LOOP UNIT 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 20.00 41.00 21.00 7/23/2005 8/6/2005 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 09:00 09:00 RURD EQIP Rig down equipment and move over to CLU 6. Re- install tree cap. Well dead. 09:00 09:00 SECURE WELL Close valves and secure well. Movoe to CLU 6. www.peloton.com Page 2/2 Report Printed: 2/21/2012 • • Permit #: 205 -106 WW1 API #: 50- 133 - 20553- 00 -S02 C L U -1 0 Marathon O i l Prop. Des: ADL 02397 Alaska Production LLC KB elevation: 41' (21' AGL) Pad WBS #: 273' FSL, 520' FEL, Drive Pipe Latitude: 60 31' 56.84" N 20" K - 55 133 ppf Longitude: 151 15' 48.37" W Sec. 7, T5N, R11W, S.M. Top Bottom MD 0' 123' Spud: 7/22/2005 TVD 0' 123' [ I TD: 8/3/2005 Rig Released: 12:O0hrs 8/10/2005 I _J Surface Casing 13 -3/8" 0' 68 ppf BTC ��. Top Bottom MD 0' 1,953' 6 1,866' Tree cxn = 4 - 3/4" Otis 16" " h 0' hole Cmt wl 606 sks (22 46 bbl) of 12.0 ppg, Type 1 Top of Cement (est.) fs �� K Intermediate Casing @ 3,260' MD . I / 9 -5/8" L -80 40 ppf BTC 100% fill ^/( U Top Bottom ,.. MD 0' 5,410' • I TVD 0' 4,962' Top of Cement (cbl) �,�. 12.25" hole Cmt w/ 417 sks of class G, @ 4,260' MD of 12.5 ppg, Lead d & (45 bbls) of 15.8 ppgg, , Tail 1150' above 9 - 5/8" shoe 24 1(12_.--- Production Tubing 3.5" Owen Cast Iron Bridge Plug 3 - 1/2" L - 80 9.3 ppf EUE q q set: V 8rd wl 6.25" OD control line protectors @ 5,410' KB w/ 36' cmt (2/9/12) _ I---- Sterling C1 Interval: Top Bottom -top of cmt @ 5,374' MD - 5,372, - ,5,614 ft MD MD 0' 8,419' I 1 TVD 0' 7,971' . 1 8.5" hole Cmt w/ 1,324 sks (274 bbls) of • ' ... / 15.8 ppg, class G 3.5" Owen Cast Iron Bridge Plug set: ✓ • @ 5,532' KB w/ 15' cmt (10/14/09) Sterling C2 Interval: 10' of fill above Bridge Plug top of cmt @ 5,507' MD .'J ji i 3.5" Owen Cast Iron Bridge Plugs set: . n ? @ 5,649' KB w/ 65' cmt (10/02/09) Sterling Perfs: I L� top of cmt tagged @ 5,583' MD (10/6/09) SandC MD Ft TVD Gun Type Date 4 - @ 5,830' KB w/ 58' cmt (10/01/09) 1 5,425' - 5,440' 15 4,977'- 4,992' 2" 6 spf 60° 10/17/09 el 1 @ 6,906' KB w/ 35' cmt (09/29/09) C1 5,425' - 5,440' 15 4,977- 4,992' 2 -3/8" 4 spf 60° 10/10/09 Ti 4■! C2 5,535' - 5,555' 20 5,087'- 5,107' 2 -3/8" 4 spf 60° 10/6/09 Di Excape System Details t - Ceramic flapper valves below Di each module as follows: Excape System Details �( 7 - 12 Excape modules placed Flappers MD (RKB): - Greer. control line fired module 1 Module 12 - 5,690' DI - control line fired modules 2 thru 8 Module 11 - 5,729' ) - Red contol line fired modules 9 thru 12 Module 10 - 5,897' IA) t - Ceramic flapper valves below each module Module 9 - 6,976' ? except for module 1 Plugged Beluga Perfs: (RKB) Module 8 - 7,049' DI f Modulo 12 5,671' 5,684' Squeezed 12/11/07 Module 7 - 7,106' ) Modulo 11 5,713' 5,723' Squeezed 12/11/07 Module 6 - 7,196' T' � Module 5 - 7,736' t Modulo 10 5,880' 5,800' Module 4 - 7,985' ? Modulo 0 6,056' 6,966' Module 3 - 8,118' DI C Modulo 8 7,030' 7,040' Module 2 - 8,240' ) Module 1 - NA DI � Modulo 5 7,716' 7,726' 3 . ' Modulo 4 7,965' 7,975' Ic - Mc4ule-3 8,008' 8,108' It 31i Module 2 8,219' 8,229' Modulo 1 8,265' 8,275' Junk TD PBTD Plug Remains @ 8,292' CTM 8,450' MD 5,532' MD 8,002' TVD 5,084' TVD Well Name & Number: Cannery Loop Unit # 10 Lease: Cannery Loop Unit Municipality: Kenai Peninsula Borough _ State: Alaska Country: USA Perforations (MD): 5,419' - 5,555' Perf (TVD): 4,971' - 5,107' Angle @ KOP & Depth: - 3° / 100 ft @ 750' MD Angle @ Perfs: -3° Date Completed: 8/31/2005 Ground Level: 41' (above MSL) 1 RKB: 21' (AGL) Revised by: Kevin Skiba Revision Date: 2/22/2012 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg tq 2't4 ( DATE: 2/14/2012 P. I. Supervisor FROM: Bob Noble SUBJECT: Plug Test Petroleum Inspector Marathon Oil Co. CLU #10 PTD 205 -106 • 2/14/12 I arrived on location at Marathon Oil Company's Cannery Loop Unit #10 to witness a pressure test on a plug. I met with Marathon's Rep Mike Sulley and we went over the Sundry for the well (Sundry #312 -040). The approved Sundry called for a 1500 psi test on this plug. Mike told me that the well had a bridge plug set at 5532' back in October 2009. He said that 14 gallons or approximately 30 feet of cement was placed on top of the bridge plug (witnessed by AOGCC Inspector Lou Grimaldi 2/9/2012). Second bridge plug was set at 5410 feet with 25 feet of cement placed on top of that (also witnessed by AOGCC Inspector Lou Grimaldi 2/9/2012). It was this cement plug that I was there to witness the pressure test on. The test went as following; Pre T /I /O =0/0/0 Ade& F sEB ` `' `', Initial T /I /0= 1650/0/0 15 min T /I /0= 1650/0/0 30 min T /I /0= 1650/0/0 Attachments: none Non - Confidential 2012 -0214 P1ugTest_CLU -10_bn • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg IL �. Iv DATE: February 10, 2012 P. I. Supervisor 1 I FROM: Lou Grimaldi SUBJECT: Wellbore Plug Petroleum Inspector Cannery Loop Unit #10 Marathon Oil Co. PTD #205 -106 Thursday, February 9, 2012; I witnessed the tag of a previously set Cast Iron Bridge Plug (CIBP), spotting of cement on top of said plug then the setting of an additional CIBP farther uphole. arrived at the location to find the Pollard wireline Electric Line (E -line) unit ready to re- tag the plug. It was explained to me that this plug had been set by ExPro (a different E- line company) on October 14, 2009. There was an E -line log available showing the plug location. As this is a "EXCAPE" completed well, there were not any landing nipples or other identifying "landmarks" to correlate to other than resistivity. Ed Hawker (Pollard E -line operator) tagged the fill on top of the plug at 5521 feet and logged upward while doing so. This correlated to the previous log from the original plug setting showing approximately 11 feet of fill above the CIBP which was set at 5532 feet (RKB). I suggested that approval to dump cement on top of the fill be obtained from the AOGCC office. Mike SuIley (Marathon) obtained this approval and I witnessed approximately 12 gallons of Class H cement at 16.4 ppg dumped by E -line bailer method. This should place approximately 33 lineal feet of cement in the 3 'A2 -inch tubing of which a 25 -foot plug was required. Samples were caught and had started thickening by the end of the job. After the cement was dumped an "Alpha" 3 %2 -inch CIBP was picked up and ran in the hole. This plug was placed on depth by correlation at 5410 feet (RKB), set and retagged with the E -line setting tool and approximately 250 pounds was placed upon it. The crew then proceeded to mix and dump bail a cement plug on top similar to the lower plug. left prior to completion of this operation. All operations I witnessed seemed in accordance with the stipulations set out in the well plan and sundry requirements Attachments: Wellbore Plug CLU 10 02 -09 -12 LG file.pdf Non - Confidential 201 2- 0209_P lug_C LU -10_lg 1 of 1 • • r '._ ° °c 0 � �n -1—I m��— Ip- aC7�I �p , & o c @ a m m 3 x = . 0 cc? cU t z m C ompany MARATHON OIL COMPANY , n rn ° g o o ' » „ z �$ r Well CANNERY LOOP #10 u 8 3 c m CI' m x cg a u 5- CO g Cr Field CANNERY LOOP I -- u0 a m -c K z-, ¢1 CD R' 2 a' 0- �,.< = m .- Cou nty KPS m o Sta ALASKA Country USA m o 3 - m {/ 1 s m r Cn n TI * C) m m O m 3 ' s � � n a) 0 (D (p 0 � r r CD �' m CD 2 z T a) c� T D N N G Q N M m o C> 0 4 ''' CD cncnoo c) l'' -.I z z -.4 CA 1,0 co ` (AZ � o n m m --1 j m7 om � a' _awrvo m ry , X X = m %Z1 T, > OD b3 :t1 Z -< -< 0 'W ICI T O O c cy, fto 7) �, O O z 0 xxz z O CO I.) N.) C7 O O rr - r m m Q � � o -0 Nm co _ n T 8 o -< ' la N Z XI ♦n /] 0 �� T 8 — Vi 0 X~ a s1 3 > —1 // 0, 0 G7 0 2) R 0 r-T nI 0 iv l� p { -i N lD O O R. CD 41 «< Fold Here »> All interpretations are opinions based on inferences from electrical or other measurements and we cannot and do not guarantee the accuracy or correctness of any interpretation, and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages, or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These interpretations are also subject to our general terms and conditions set out in our current Price Schedule. Comments CIBP SET @ 5532' (10- 14 -09). TAGGED FILL @ 5521' AND DUMP BAILED 30' OF CEMENT ON FILL /PLUG. SET CIBP @ 5410', TAG PLUG AND DUMP BAIL 30' OF CEMENT ON PLUG. POLLARD • E LINE CI BP TAG 552 SERVICES, INC. Database File: mocclut0.db Dataset Pathname: pass3 Presentation Format: gr -ccl Dataset Creation: Thu Feb 09 09:28:54 2012 by Log SCH 110630 Charted by: Depth in Feet scaled 1:240 36 CCL -4 250 Reverse Gamma Ray (GAPI) 0 0 Gamma Ray (GAPI) 150 0 Line Tension (Ib) 1000 ■■� HI i 5300 11 , �.. i■a r♦--- t Une Tension ∎m ∎�� Bever. �� ∎� �11i►�i1 4-- CCL 5350 11 111111■ ■ 1_111[1■ ■■■C1I -■ ��Ili ■■■ ■■■� ■■!�■■■ ■ ■■■■�■■ ■era■■■ ■ ■ ■� 111_1■ / 5400 • �■ ■■ ^=CIBP ∎1�� sii`iii r. � M11 11ri111 ■■■■■ iir■■■ ■■■s ■ ■ ■ ■i■■■ _ �� ■1fi ■11 ■=M �o6_ =__ ' - ■ ■� — ifil� -- , r ki '► 5450 ■■ ■ii■_■_■_ ■ ■� ■�E ■_r ■ line Tension �' — ■� Reverse Gamma Gamma Ray ..11111 111 �k 1 �-- CCL ' _pp�+ ■■■— ■— ■1107 ■ ■ ■■ ■_ ■_ ■_�_ ■_- _ ■��_ ■ ■■ 5500 ■ ■ ■��- ■�F� ■ ■■ = ■ ■ = ■- 1 � _� — I 7 — ►7 - -- NEI■ ■ ■■ 4�� CCL TO GAUGE RING 6.5' _— pm��ai■■■ 5521 T.T.' 7� :lEiiTi� F ■ ■ ■�■ 1111 ■11 36 CCL -4 ^ ^^ 250 Reverse Gamma Ray (GAPI) 0 0 Gamma Ray (GAPI) 150 0 Line Tension (Ib) 1000 . 0 POLLARD ,..._ E -LINE PLUG POSITION PASS SERVICES, INC. Database File: mocclul0.db Dataset Pathname: passl3 Presentation Format: gr -ccl Dataset Creation: Thu Feb 09 15:57:42 2012 by Log SCH 110630 Charted by: Depth in Feet scaled 1:240 36 CCL -4 250 Reverse Gamma Ray (GAPI) 0 0 Gamma Ray (GAPI) 150 0 Line Tension (lb) 2000 0 ti i i 1 1 f ; ID- { —.- _ 5350 - �� lit -- Line Tension - Reverse Gamma Rav CCL i ' �. I r + C WC O 1 - - 4-- CCL TO TOP OF PLUG =12.5' 4' :111 i -% 5400 z C =CI B ' / Eimmtlimonom Z , - - ' . 36 CCL -4 250 Reverse Gamma Ray (GAPI) 0 0 Gamma Ray (GAPI) 150 0 Line Tension (lb) 2000 r • • POLLARD ..,.. Rv � s POST TAG CIBP - 5410' s INC. Database File: mocclul0.db Dataset Pathname: passl5 Presentation Format: gr -cci Dataset Creation: Thu Feb 09 16:11:45 2012 by Log SCH 110630 Charted by: Depth in Feet scaled 1:240 36 CCL -4 250 Reverse Gamma Ray (GAPI) 0 0 Gamma Ray (GAPI) 150 0 Line Tension (lb) 2000 ■ ■I ■ CCL ■ III Line Tension ■■■ PA _I - ■ ■■ ■■ hlrIIIIIIII■M MINI 1111 I 4 / 5300 CI ■_I_ 1111 . _� _ NI IM CA ■I ■I■ 1 111 RI MI E1 MI r� �l� 11■1 h s 1111 _,_ i .1 11 -I 5350 � 1111 r.. _I rig _�_ A - y Line Tension C' CCL C1 ■■ III EIIIIIIMIIMMIIIIMIMIII MUM C Iti �� ■� �_ .J �` I CL TO PLUG = 14'�■ _ ` __ � PI ! __ 5400 111 _ 1111 ff Ins 1 _ CIBP _ = — a.' om 36 CCL -4 250 Reverse Gamma Ray (GAPI) 0 0 Gamma Ray (GAPI) 150 0 Line Tension (lb) 2000 • • t SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative Marathon Alaska Production, LLC P.O. Box 1949 Kenai, AK 99611 -1949 Re: Cannery Loop Field, Sterling Undefined Gas Pool, Cannery Loop Unit #10 Sundry Number: 312 -040 Dear Mr. Skiba: NED JAN 3 ??U1Z 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. 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 reconsideration. A request for reconsideration 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. Si erely, i 1 A, • an Com ssion: DATED this3(day of January, 2012. Encl. Marathon Alaska Production LLC • Alaska Asset Team M Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 RECEIVED January 24, 2012 JAN 21( 2012 Mr. Daniel Seamount Alaska OiI & Gas Cons. Commission Alaska OiI & Gas Conservation Commission Anchorage 333 W 7 Ave Anchorage, Alaska 99501 Reference: 10 -403 Application for Sundry Approvals Field: Cannery Loop Field Well: Cannery Loop Unit #10 Dear Mr. Seamount, Submitted for your approval is the10 -403 Application for Sundry Approvals for CLU -10 well. Marathon proposes to isolate the Sterling C1 and C2 intervals in the CLU -10 well to comply with Storage Injection Order No. 9, for the purpose of developing the CINGSA ✓ gas storage project, as discussed in the Injection Order in Finding #14. The plugging procedure complies with 20 AAC 25.112, (c), (1), (E), using a mechanical bridge plug and cement placed with a dump bailer. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, 44...12A.TIAA-d 0 3- , )&0-eLi Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Proposed Well Schematic Kenai Well File Detailed Operations Program (2) KJS (.20- ' ' jEIVED qq • STATE OF ALASKA I - ALASKOL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS JAN nn 20 AAC 25.280 2 U�L 1. Type of Request: Abandon Ell reolug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ !.:,: ; - €I1ap a�nv_ ((ter ed,program �] a <:. TT''rrPPff Suspend ug Perforations A • Perforate ❑ Pull Tubing Ill ' Spe y �� EII Ilto Operational shutdown III Re-enter Susp. Well ❑ Stimulate El Alter casing ❑ - Other: ..__.._, „ __. . ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development 0 • Exploratory ❑ 205 -106 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20553 -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: Spacing Exception Required? Yes El No D Cannery Loop Unit #10 9. Property Designation (Lease Number): 10. Field / Pool(s): L4 1jrl"t`ttur6C OC' ADL - 02397 • Cannery Loop Unit / Sterling 11. PRESENT WELL CONDITION SUMMARY ' Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,450' 8,002' • 8,339' 7,891' NA 8,292' Casing Length Size MD TVD Burst Collapse Structural Conductor 102' 20" 123' 123' 3,060 psi 1,500 psi Surface 1,932' 13 -3/8" 1,953' 1,866' 3,450 psi 1,950 psi Intermediate 5,368' 9 -5 /8" 5,410' 4,962' 5,750 psi 3,090 psi Production 8,377' 3 -1/2" 8,419' 7,971' 10,160 psi 10,530 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,880' - 8,275' 5,432' - 7,827' Excape 3 -1/2" L -80 8,419' Capillary Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): SSSV: NA Packers: NA Packers: NA 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: - 1 • so. /2 - Commencing Operations: February 8 , 2012 Oil ❑ Gas ,J WDSPL ❑ Suspended R 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature Phone Date i < .sityl..). („ (907) 283 - 1371 January 24, 2012 v� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 z-0(4 Plug Integrity / BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: i tI of- .5 1. srec ,i i r °'( :4 Subsequent Form Required: ` 0—y0-7— i APPROVED BY Approved by: / (3a°,i OMMISSIONER THE COMMISSION Date: /•3 /-a •' / AtI • RBI NS J,41��' " �o ORIGINAL � �� p 1/4- ,;2 Form 10 - 403 Revised 1/2010 Submit in Duplicate itsk l.. Marathon Oil CLU 10 Cannery Loop 1 Pad CINGSA Sterling Abandonment Procedure WBS: BL.11.25566.EXP.002 APPROVALS: Mike Sulley 01/20/2012 Program Writer Mike Ellis 01/24/2012 Mike Ellis No deviation from this procedure to occur without prior approval from supervisor. Well Status: Per the CINGSA agreement, and as specified in the AOGCC issued SIO 9 order, the CLU 10 Sterling C sands are to be isolated prior to the commencement of the injection project. Marathon is to perform the work to comply with the SIO 9 at CINGSA's cost per the CINGSA agreement. Objective: ,Methodology is to isolate Sterling C1 and C2 sands using E -line and Slickline to dump bail cement, set another bride e .1u. and dum • bail cement then to pressure test the plugs. This procedure performs the isolation work. It is intended to perform the full wellbore abandonment in the summer of 2012. Resources: MIRU E -Line, lubricator, light plants, heater, bridge plugs, setting tool, cement, dump bailer Paperwork: Sundry Approval, Procedure, WBD, Work Permit, Well Ops transfer sheet. CINGSA notification and approval are required: Notifying CINGSA of well work at Cannery Loop, and gaining CINGSA's approval, is required per the CINGSA agreement prior to commencing well work. Coordinate CINGSA notification with Chick Underwood. ✓ Procedure: Pre -work: 1. Have GE Vetco inspect and perform wellhead maintenance. Test 9 -5/8" pack -off void on casing head X tubing head to 1500 psi. Work lockdown pins on tubing head. Check for trapped pressure. Open valves on annuli and check for trapped pressure. Grease valves. Verify pressure isolation between all annuli. 2. Hold PJSM prior to rigging up equipment. 1 NOTE: Previous well work on this well conducted 10 -14 -2009 set a CIBP at 5532' kb, effectively isolating the Sterling C2 sand from the C1 sand. Dump bailing 25' of cement on top of this CIBP should complete the Sterling C2 abandonment. A second CIBP is to be set above the Sterling C1 sand with 25' of cement to be dump bailed on top of it. This should complete the Sterling C sand abandonment. NOTE: Discussion with the AOGCC's Mr. Jim Regg indicated that the AOGCC is more interested in witnessing the tagging and setting of the CIBP's than the tagging of the TOC's. They are also interested in witnessing the casing pressure test upon completion of the abandonment. Work discussion overview Mr. Regg: Wireline work: Run 2.80" gauge ring. Tag CIBP at 5532' kb. (AOGCC and CINGSA to witness CIBP tag). Dump bail 25' of cement. WOC. E -line Work: Tag TOC cement. Set CIBP above Sterling C1 at 5410 ft MD. Set back down and tag CIBP. AOGCC (and CINGSA) would like to witness tag of CIBP rather than TOC tag. Wireline work: Continue to dump bail 25' of cement on top of CIBP. 3. MIRU wireline. RU lubricator. Pressure test lubricator to 250/2000 psi. Make a gauge ring run using a 2.80" gauge ring to PBTD @ 5532'. Notify AOGCC and CINGSA to witness CIBP tag. PU dump bailer. Dump bail 25' of cement on top of 3 -1/2" CIBP @ 5532' (Tagged 10/24/2009). 4. MIRU E —line. PU GR/CCL, setting tool and 3 -1/2" CIBP. Notify AOGCC and CINGSA to witness CIB_ P ta_g_ Ensure setting tool has been rebuilt and o -rings replaced prior to running. RIH with 3 -1/2" CIBP. Get on depth using previous CIBP and perforations 5419' to 5434' MD. Confirm depths, correct to MD per Expro Dual Radial Cement Bond log dated 8/17/2005. 5. Pull cement retainer up to set depth of 5410' MD (pulling tool up hole will pull E -line tight, given deviation). Caution: Do not set in a collar (The nearest collar is 5403'). Confirm with Marathon wellwork supervisor that set depth is accurate. With confirmation, set CIBP 5410 ft MD (top pert is 5419 ft MD). Set back down and confirm that the CIBP did indeed set. AOGCC to witness this tag. POOH. 6. MIRU wireline. PU dump bailer. Dump bail 25' of cement on top of 3 -1/2" CIBP @ 5410 ft MD. Typically three runs. 7. WOC overnight. 8. MIRU Pollard hot oil unit. Pump approximately 50 bbls fresh water to load hole. Test 3 -1/2" plug /tubing to 1500 psi. RD Pollard. AOGCC to witness casing pressure test. 2 • 4 • History: CLU 10: 11/04/11: Trial MIT. Pump '132 gals MEOH. No pressure. 10/24/09: PT tag 5532'. BHP 453 psig, fluid 5483'. 10/17/09: Reperforate 5425 -5440' ( -6' correction to CBL). No response. See well history for balance of history. Considerations Instructions and Planning: 3 Permit #: 205-106 C L U - 10 S " rritiM Marathon oil API PI # #: 50-133-20553-00-S02 Prop. Des: ADL 02397 Alaska Production t f C KB elevation: 41' (21' AGL) Pad 1 WBS #: 2 73' FSL, 520' FEL, Drive Pipe Latitude: 60° 31' 56.84" N Sec. 7, T5N, R11 W, S.M. 20" K -55 133 ppf Longitude: 151° 15' 48.37" W Top Bottom Spud: 7/22/2005 MD 0' 123' _ TVD 0' 123' TD: 8/3/2005 I - I Rig Released: 12:O0hrs 8/10/2005 Surface Casing 113 -3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,953' TVD 0' 1,866' Tree cxn = 4 - 3/4" Otis 16" hole Cmt wl 606 sks (246 bbl) of 12.0 ppg, Type 1 Top of Cement (est.) Intermediate Casing @ 3,260' MD I•. 9 -5/8" L -80 40 ppf BTC 100% fill Top Bottom , MD 0' 5,410' TVD 0' 4,962' ' 12,25" hole Cmt wl 417 sks of class G, (75 bbls) KOP Ca? 750' MD /TVD of 12.5 ppg, Lead & (45 bbls) of 15.8 ppg, Tail Build - 3 °/100 from 750' - 1,750' ' , E 4E Production Tubing Sterling C1 3 -1/2" L -80 9.3 ppf EUE Top of Cement (cbl) Interval: 8rd w/ 6.25" OD control line protectors @ 4,260' MD 5372 -5614 ft MD Top Bottom MD 0' 8,419' 1150' above 9 -5/8" shoe TVD 0' 7,971' 1 8.5" hole Cmt w/ 1,324 sks (274 bbls) of 15.8 ppg, class G 2.75" Owen Cast Iron Bridge Plug set: @ 5,532' KB (10/14/09) y '" Tagged cement plug @ 5,583' RKB 2.5" Owen Cast Iron Bridge Plugs set: tw I t ` (10/06/09) @ 5,649' KB w/ 65' cmt (10/02/09) @ 5,830' KB w/ 58' cmt (10/01/09) ∎ 7 @ 6,906' KB w/ 35' cmt (09/29/09) I Sterling Perfs: 1 . . SandC MD Ft TVD Gun Type Date t 1 5,419'-5,434' 15 4971' -4986' 2 3/8" 4 spf 60° 10/10/09 , . , C1 5,419' - 5,434' 15 4971' -4986' 2" 6spf 60 10/17/09 Excape System Details 42 5,535' 5,555' 28 5087' 5107' 2 3/8" 1 spf 60° 10/6/04 - Ceramic flapper valves below each module as follows: k 11 Flappers MD (RKB): D` Module 12 - 5,690' Module 11 - 5,729' Excape System Details Module 10 - 5,897' - 12 Excape modules placed Module 9 - 6,976' "i' 'l[ - Green control line fired module 1 Module 8 - 7,049' ') - control line fired modules 2 thru 8 Module 7 - 7,106' - Red contol line fired modules 9 thru 12 Module 6 7,196' - Ceramic flapper valves below each module Module 5 - 7,736' 7 �C except for module 1 Module 4 - 7,985' 1.11 Plugged Beluga Perfs: (RKB) Module 3 - 8,118' ? AAodulo 12 5,671' 5,681' Squeezed 12/11/07 Module 2 - 8,240' T1 Modulc 11 5,713' 5,723' Squeezed 12/11/07 Module 1 - NA Modulo 10 5,880' 5,800' Modulc 0 6,956' 6,066' DI Modulc 8 7,030' 7,040' ? Modulo 7 7,083' 7,093' Modulc 6 7,171' 7,184' k' rill Modulo 5 7,716' 7,726' [ -1 Modulc 1 7,065' 7,075' * , Modulo 2 8,210' 8,225 Module 1 8,265' 8,275' TD PBTD Junk 8,450' MD 5,532' MD I Plug Remains @ 8,292' CTM 8,002' TVD 5,084' TVD Well Name & Number: Cannery Loop Unit # 10 Lease: Cannery Loop Unit Municipality: Kenai Peninsula Borough State: Alaska 1 Country: 11 USA Perforations (MD): 5,419' - 5,555' Perf (TVD): 4,971' - 5,107' Angle @ KOP & Depth: - 3° / 100 ft @ 750' MD Angle @ Perfs: -3° Date Completed: 8/31/2005 Ground Level: 41' (above MSL) 1 RKB:I 21' (AGL) Rpvicpri hv• Mike Siillav Rpvicirn natp• 7/19/9011 p • Permit #: 205 -106 HAWN L U" 1 0 API #: 50- 133- 20553- 00 -S02 Marathon O i l Prop. Des: ADL 02397 PROPOSED Alaska Production LLC KB elevation: 41' (21' AGL) Pad 1 WBS #: Drive Pipe Latitude: 60° 31' 56.84" N 273' FSL 520' FEL 20" K - 55 133 ppf Longitude: 151° 15' 48.37" W Sec. 7, T5N, R11W, S.M. Top Bottom Spud: 7/22/2005 MD 0' 123' TVD 0' 123' TD: 8/3/2005 Rig Released: 12:00hrs 8/10/2005 I . Surface Casing 13 -3/8" L -80 68 ppf BTC Top Bottom MD 0' 1,953' TVD 0' 1,866' Tree cxn = 4 -3/4" Otis 16" hole Cmt w/ 606 sks (246 bbl) of 12.0 ppg, Type 1 Top of Cement (est.) Intermediate Casing @ 3,260' MD k 9 -518" L -80 40 ppf BTC 100% fill Top Bottom MD 0' 5,410' TVD 0' 4,962' Top of Cement (cbl) r- 1 12.25" hole Cmt w/ 417 sks of class G, (75 bbls) of 12.5 ppg, Lead & (45 bbls) of 15.8 ppg, Tail @ 4,260' MD 1150' above 9 -5/8" shoe Production Tubing Sterling C1 3 -112" L -80 9.3 ppf EUE Owen CIBP to be set @ 5410' f 1 Interval: 8rd w16.25" OD control line protectors + 25' cement (dumpbailed) 5372 - 5614 ft MD Top Bottom TOC 5385 ft MD MD 0' 8,419' TVD 0' 7,971' 8.5" hole Cmt w/ 1,324 sks (274 bbls) of [k ) 15.8 ppg, class G 2.75" Owen Cast Iron Bridge Plug set: @ 5,532' KB (10/14/09) 11, _ Tagged cement plug T @ 5,583' RKB 2.5" Owen Cast Iron Bridge Plugs set: • t (10/06109) @ 5,649' KB w/ 65' cmt (10/02/09) Tn1 @ 5,830' KB w/ 58' cmt (10/01/09) • 11 t - @ 6,906' KB w/ 35' cmt (09/29/09) .) I Sterling Perfs: f SandC MD Ft TVD Gun Type Date �� 1 5,419'- 5,434' 15 4971'-4986' 2 3/8" 4 spf 60° 10/10/09 Excape System Details "t,_, C1 5,419' - 5,434' 15 4971' -4986' 2" 6spf 60° 10/17/09 1e= I ) • G2 5535'- 5,555' 29 5087' 5107' 2 3/8" 4 spf 60° 10/6/00 - Ceramic flapper valves below , I i each module as follows: 1 �3 Flappers MD (RKB): ti'('- BI ' Module 12 - 5,690' �� x Module 11 - 5,729' Excape System Details Module 10 - 5,897' - 12 Excape modules placed Module 9 - 6,976' fi _ Green control line fired module 1 Module 8 - 7,049' f +� 3 : control line fired modules 2 thru 8 Module 7 - 7,106' f - Red contol line fired modules 9 thru 12 Module 6 - 7,196' 1 D - Ceramic flapper valves below each module Module 5 - 7,736' n except for module 1 Module 4 - 7,985' i Ll Plugged Beluga Perfs: (RKB) Module 3 - 8,118' 1 f� Modulo 12 5,674' 5,684' Squeezed 12/11/07 Module 2 - 8,240' Modulo 11 5,713' 5,723' Squeezed 12/11/07 Module 1 - NA a [ L Modulo 10 5,880' 5,800' -Modulo 0 6,056' 6,966' I DI ' - Modulo 8 7,030' 7,040' h 7 Modulo 7 7,083' 7,093' Modulc 6 7,174' 7,184' 1 ) t Mo 5 7,716' 7,726' ' Modulo 4 7,065' 7,075' Modulo 3 8,098' 8,108' ,. 01 4Medule -2 8,210' 8,220' Modulo 1 8,265' 8,275' TD PBTD Junk 8,450' MD 5,532' MD Plug Remains @ 8,292' CTM 8,002' TVD 5,084' TVD Well Name & Number: Cannery Loop Unit# 10 Lease: Cannery Loop Unit Municipality: Kenai Peninsula Borough State: Alaska 1 Country: 11 USA Perforations (MD): 5,419' - 5,555' Perf (TVD): 4,971' - 5,107' Angle @ KOP & Depth: - 3° / 100 ft @ 750' MD Angle @ Perfs: -3° Date Completed: 8/31/2005 Ground Level: 41' (above MSL) RKB: I 21' (AGL) Rpvicpri hv• Mika Sullpu Rpvicinn Bate.- 7/51/9011 Marathon Alaska Production LLC Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 January 19, 2012 Mr. Daniel Seamount JAN 2 3 2012 Alaska Oil & Gas Conservation Commission 333 W 7 Ave } , : Li g LEttiC i;ortiniSS1011 Anchorage, Alaska 99501 Reference: 10 -403 Application for Sundry Approvals Field: Cannery Loop Field Well: Cannery Loop Unit #10 Dear Mr. Seamount, N FEB j 4 Z01. Submitted for your approval is the10 -403 Application for Sundry Approvals for CLU -10 well. Marathon proposes to perform a Mechanical Integrity Test of the wellbore to comply with the Storage Injection Order No. 9, Rule 5: Demonstration of Mechanical Integrity. Please find attached the Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Mechanical Test Plan which provides a summary and background for the test, the details that relate to the subject well, and a current wellbore schematic, depicting the Sterling C1 interval depths. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, 6 k t f),,, e , yA j Y W _ Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC CINGSA SIO 9 Mechanical Integrity Test Plan Houston Well File Current Well Schematic Kenai Well File (2) KJS STATE OF ALASKA ALAS411,IL AND GAS CONSERVATION COMMIS", APPLICATION FOR SUNDRY APPROVALS A s 2012 20 AAC 25.280 , 4xto'< t�gth t;fjill6..01113t11$$l 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Ch ,; �p 4Wd program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Perform MIT Test , El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development Exploratory ❑ 205 -106 • 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 -20553 I 0 -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: Spacing Exception Required? Yes El No D Cannery Loop U #10 9. Property Designation (Lease Number): 10. Field / Pool(s): i f „....' 1 ADL - 02397 Cannery Loop Unit / Sterlin • 11/4 . ool /P / .2,:; r — 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measu d): Junk (measured): 8,450' . 8,002' . 8,339' 7,891' NA 8,292' Casing Length Size MD TVD Burst Collapse Structural Conductor 102' 20" 123' , 1 3,060 psi 1,500 psi Surface 1,932' 13 -3/8" 1,953' ., ,866' 3,450 psi 1,950 psi Intermediate 5,368' 9 -5/8" 5,41 r. 4,962' 5,750 psi 3,090 psi Production 8,377' 3 -1/2" 8,419 7 10,160 psi 10,530 psi Liner I 1 1 /� 1 I Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubi Size: , u , )(lin g ade: Tubing MD (ft): 5,880' - 8,275' 5,432' - 7,827' xc p - 3 /2" L -80 8,419' pill Packers and SSSV Type: SSSV: NA l and WV D (ft) and TVD (ft): SSSV: NA Packers: NA Packers: NA 12. Attachments: Description Summary of Proposal it Class after proposed work: Detailed Operations Program ❑ BOP Sketch D ory ❑ Development El Service ❑ 14. Estimated Date for x 15 o . Well Status after proposed work: February 1, 201 Commencing Operations: Oil ❑ Gas El WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and corr t to the best of my knowledge. Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature Phone (907) 283 -1371 Date January 19, 2012 (9... COMMISSION USE ONLY Conditions of approval: Notify Co ission so that a representative may witness Sundry Number: 61 t b' (53 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent F' m Required: APPROVED BY Appr• ed by: COMMISSIONER THE COMMISSION Date: RSDMS FEB 14 2012 0 R 1 G l N A Form 10 -403 Revised 1/2010 Submit in Duplicate • • Cook Inlet Natural Gas Storage Alaska, LLC Proposed Mechanical Integrity Test Plan Cannery Loop Sterling C Gas Storage Pool Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) requested by application dated July 27, 2010, a storage injection order from the Alaska Oil and Gas Conservation Commission (AOGCC) authorizing injection for the underground storage of natural gas in the Sterling C Gas Storage Pool of the Cannery Loop Unit. The AOGCC held a public hearing on October 19 -20, 2010 during which CINGSA presented oral and written testimony concerning the project. By Order, the AOGCC issued Storage Injection Order No. 9 (SIO 9) dated November 19, 2010, granting CINGSA the authority to commence the injection of gas for underground storage subject to certain Conclusions and Rules, all as more fully outlined in SIO 9. Two of the key requirements imposed on CINGSA as a condition of SIO 9 are that CINGSA 1) demonstrate the mechanical integrity of all storage injection wells and existing pool wells before injection commences (Rule 5 Demonstration of Mechanical Integrity), and 2) maintain surveillance of operating parameters for storage and offset wells to provide continued assurance that gas remains confined to the Sterling C Gas Storage Pool (Conclusion 8). Following, is the methodology CINGSA proposes to employ to demonstrate the mechanical integrity of all existing pool wells and maintain continued surveillance of the Pool to assure that gas remains confined to the Sterling C Pool. All new gas storage wells will be tested in accordance with 20 AAC 25.412 (c)(d). CINGSA proposes to satisfy the requirements of Conclusion 8 and Rule 5 of SIO 9 through routine monitoring of the annulus pressure of existing wells, and via pressure testing the annulus of certain wells to demonstrate their mechanical integrity, plus the tubing string of certain other wells. Table 1 provides a summary of the scope of CINGSA's proposed measures to satisfy the requirements of Conclusion 8 and Rule 5. The rationale for monitoring pressure of certain annuli and performing a mechanical integrity test is more fully summarized for each individual well below. Table 2 provides a depth reference to the Sterling C1 interval, from Sterling C1 Top to U. Beluga Top, by well. Routine monitoring and recording of annulus pressure will help identify whether any gas may be leaking from the Sterling C Pool or other formations. CINGSA proposes a monthly monitoring and reporting frequency to satisfy the requirements of Conclusion 8. CINGSA proposes to conduct a mechanical integrity pressure tests on the annulus of the wells listed in Table 1 to satisfy the requirements of Rule 5. CINGSA proposes a maximum test pressure of 500 psi for 30 minutes since most of the wells are not completed with tubing set on a packer, and thus, are not in the same configuration contemplated in 20 AAC 252. Y • • Table 1 Proposed Routine Monitoring and Mechanical Integrity Test Plan Cook Inlet Natural Gas Storage Alaska, LLC Well Name Current Status Annulus for MIT Routine Monitor Annulus CLU 1RD Producing 4 1/2 x 7 4 1/2 x 7 and 7 x 9 5/8 CLU 3 Inactive 3 1/2 x 9 5/8 3 1/2 x 9 5/8 CLU 4 Inactive 3 1/2 x 13 5/8 3 1/2 Tbg, 3 1/2 x 13 5/8, and 13 5/8 x 20 CLU 5 Inactive 3 1/2 Tbg x 9 5/8 3 1/2 Tbg, 3 1/2 x 9 5/8, and 9 5/8 x 13 3/8 CLU 6 P & A Sterling C 4 1/2 Tbg 4 1/2 tbg and 4 1/2 x 7 CLU 7 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 8 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 9 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 10 ✓ Planned P & A 3 1/2 Tbg and 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 11 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 12 P & A'd Sterling C None 9 5/8 Csg Table 2 Cannery Loop Wells, Sterling C interval, Sterling C1 Top to U. Beluga Top Well Name Sterling C depth interval, MD Sterling C depth interval, TVDSS CLU 1RD 5815 -6155 -4927 to -5155 CLU 3 5313 -5574 -4963 to -5205 CLU 4 5171 -5409 -4971 to -5198 CLU 5 6063 -6300 -4856 to -5081 CLU 6 7782 -8114 -4876 to -5099 CLU 7 7700 -7965 -4858 to -5095 CLU 8 6690 -6945 -4871 to -5101 CLU 9 5942 -6195 -4860 to -5102 CLU 10 5372 -5614 -4883 to -5125 CLU 11 6281 -6537 -4876 to -5113 CLU 12 7264 -7522 -4920 to -5158 I ` • • CLU 10 CLU 10 is currently completed to the Sterling via a 3 -1/2" Excape type completion, with the 3 -1/2" monobore having been cemented in place, in the open hole with cement being brought up above the 9- 5/8 shoe. The Sterling C interval is to be isolated /squeezed prior to commencement of gas storage operations. The Sterling interval extends from 5372 -5614 ft MD. Intermediate casing is set at 5410 ft MD, and thus, extends approximately 38 ft below the top of the Sterling C. Proposed Annuli to configure for routine pressure monitoring: • 3- 1/2 "x9 -5/8" tubing head • 9 -5/8 "x13 -3/8" casing head Proposed Mechanical Integrity Test Procedure: • Perform a 500 psi pressure test of the 3 1/2" tubing after squeezing /isolating the Sterling C interval. CINGSA proposes a 30 minute test duration with no more than a 10 percent change in pressure during that time interval being required for a valid test. • The proposed pressure test will apply an approximate differential of 2149 psi at 5410 ft MD/4962 ft TVD, per the following assumptions: an approximate 500 psi formation pressure at TVD; a fresh water hydrostatic gradient in the tubing, and the 500 psi of applied surface pressure. (Assumed anticipated top of cement of Sterling plug depth for differential calculation.) • Perform a 500 psi pressure test of the 3 -1/2" x 9 -5/8" annulus being mindful of the low pressure on the inside of the tubing and of collapse. CINGSA proposes a 30 minute test duration with no more than a 10 percent change in pressure during that time interval being required for a valid test. • The proposed pressure test will apply an approximate differential of 2149 psi at 5410 ft MD/4962 ft TVD, per the following assumptions: an approximate 500 psi internal tubing pressure at TVD; a fresh water hydrostatic gradient in the annulus, and the 500 psi of applied surface pressure. (Assumed intermediate casing shoe depth for differential calculation.) • A test of the 9 5/8" x 13 3/8" annulus is not recommended since it would most likely serve as a leak off test of surface shoe at 1953 ft MD. A successful leak off test of the surface casing shoe was performed at the time of drilling (1300 psi @ 1953 ft MD). • �'' �� Permit #: 205 -106 r � API #: 50- 133 - 20553- 00 -S02 V L U 1 O Marathon Oil Prop. Des: ADL 02397 Alaska Production LLC . KB elevation: 41' (21' AGL) Pad 1 WBS #: 273' FSL, 520' FEL, Drive Pipe Latitude: 60 31' 56.84" N Sec. 7, T5N, R11 W, S.M. 20" K -55 133 ppf Longitude: 151 15' 48.37" W Top Bottom MD 0' 123' Spud: 7/22/2005 TVD 0' 123' TD: 8/3/2005 Rig Released: 12:00hrs 8/10/2005 i Li Surface Casing 13 -3/8" L -80 68 ppf BTC �,,r1 Top Bottom MD 0' 1,953' TVD 0' 1,866' Tree cxn = 4 - 3/4" Otis 16" hole Cmt wl 606 sks (246 bbl) of 12.0 ppg, Type 1 Top of Cement (est.) Intermediate Casing @ 3,260' MD 9 -5/8" L -80 40 ppf BTC 100% fill Top Bottom ., MD 0' 5,410' TVD 0' 4,962' I 12.25" hole Cmt w/ 417 sks of class G, (75 bbls) KOP p 750' MD /TVD of 12.5 ppg, Lead & (45 bbls) of 15.8 ppg, Tail Build - 3 ° /100 from 750' - 1,750' •,. 4• Production Tubing Sterling C1 3 -1/2" L -80 9.3 ppf EUE Top of Cement (cbl) Interval: 8rd wl 6.25" OD control line protectors @ 4,260' MD ( 5372 -5614 ft MD Top Bottom 1150' above 9 -5/8" shoe MD 0' 8,419' ND 0' 7,971' n 8.5" hole Cmt w/ 1,324 sks (274 bbls) of 15.8 ppg, class G 2.75" Owen Cast Iron Bridge Plug set: @ 5,532' KB (10/14/09) -� c Tagged cement plug @ 5,583' RKB 2.5" Owen Cast Iron Bridge Plugs set: (10/06/09) @ 5,649' KB w/ 65' cmt (10/02/09) @ 5,830' KB w/ 58' cmt (10/01/09) • @ 6,906' KB w/ 35' cmt (09/29/09) ( Sterling Perfs: , V . SandC MD Ft TVD Gun Type Date 1 5,419' - 5,434' 15 4971' -4986' 2 3/8" 4 spf 60° 10/10/09 Excape System Details C1 5,419'- 5,434' 15 4971' -4986' 2" 6spf 60 10/17/09 Ceramic flapper valves below • b - G2 5,535' 5,555' 29 5087' 5107' 2- 4 -spf&& 10/6/09 each module as follows: j�I Flappers MD (RKB): Module 12 - 5,690' �■ Module 11 - 5,729' jjI Excape System Details Module 10 - 5,897' '' - 12 Excape modules placed Module 9 - 6,976' - Green control line fired module 1 Module 8 - 7,049' control line fired modules 2 thru 8 Module 7 - 7,106' l4' Di - Red contol line fired modules 9 thru 12 Module 6 - 7,196' Stt - Ceramic flapper valves below each module ` ? except for module 1 Module 5 - 7,736'' ig Module 4 - 7,985' t Plugged Beluga Perfs: (RKB) Module 3 - 8,118' t, ? Modulo 12 5,674' 5,684' Squeezed 12/11/07 Module 2 - 8,240' VA. Tit Modulo 11 5,713' 5,723' Squeezed 12/11/07 Module 1 - NA ? Modulo 10 5,880' 5,890' Modulo 0 6,956' 6,966' �t Module 8 7,030' 7,040' ? Modulo 7 7,083' 7,093' Dt Module 6 7,174' 7,184' 3 Modulo 5 7,716' 7,726' 101 Modulo 4 7,965' 7,975' ICJ . - Module -2 8,219' 8,229' Module 1 8,265' 8,275' TD PBTD Junk 8,450' MD 5,532' MD Plug Remains @ 8,292' CTM 8,002' TVD 5,084' TVD Well Name & Number: Cannery Loop Unit # 10 Lease: Cannery Loop Unit Municipality: Kenai Peninsula Borough State: Alaska ( Country: II USA Perforations (MD): 5,419' - 5,555' Pert (TVD): 4,971' - 5,107' Angle @ KOP & Depth: - 3° / 100 ft @ 750' MD Angle @ Perfs: -3 Date Completed: 8/31/2005 Ground Level: 41' (above MSL) 1 RKB:/ 21' (AGL) Rpvisprl hv• Mikp S.,Ilev Rpvisinn f)atp• 7/19/9011 + Page 1 of 3 • • r . Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) prig z' — Sent: Friday, February 10, 2012 4:11 PM ( r' z oS -f oL To: 'Skiba, Kevin J. (MRO)' rrD Z cG — 1Z I Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: RE: CLU MITs for CINGSA Kevin, reviewed all the sundry applications for the MIT 's on CLU wells. Three wells: CLU 6, CLU 10 and CLU 12 MIT will not need to be retested following the P & A work that is ongoing (these sundries will be returned as not needed) . I believe CLU 12 is already done and has been tested to 1500 psi. . The other wells are approved as written with the 500 psi MIT as proposed. This is adequate pressure to ensure we have a monitor -able annulus. The Commission will want to witness each and every one of the MIT's on the list. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Maunder, Thomas E (DOA) Sent: Friday, January 27, 2012 7:18 AM To: Skiba, Kevin J. (MRO) Cc: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: CLU MITs for CINGSA Kevin, Were the work plans submitted designed by Marathon or was it a collaborative effort between yourselves and CINGSA? Why is the proposed applied pressure for testing only 500 psi? Even assuming that the inside BHP at the liner tops or packers is 500 psi, the tubulars all have published burst pressures well in excess of the hydrostatic plus greater applied pressure. Thanks in advance. Please "reply all" with the response. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, January 26, 2012 2:37 PM To: 'Skiba, Kevin J. (MRO)' Subject: RE: CLU MITs for CINGSA Thanks Kevin. That answers the question I had. Tom From: Skiba, Kevin J. (MRO) [mailto:kskiba ©marathonoil.com] Sent: Thursday, January 26, 2012 2:01 PM To: Maunder, Thomas E (DOA) Cc: Ellis, Michael (MRO); Skiba, Kevin J. (MRO) 2/10/2012 A Page2of3 • Subject: RE: CLU MITs for CINGSA Tom, It was discussed during a CINGSA / Marathon meeting that Marathon would provide Cannery Loop casing pressures to CINGSA on a monthly basis. Any anomalies would be provided immediately. Both parties have plans to further discuss the data collection and sharing issue. I hope that helps. Sorry it took so long to get back with you. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC kskiba(c marathonoil.com Office (907) 283 -1 371 Cell (907) 394 -3674 Fax (907) 283 -1350 Safe, Clean, & Responsible From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 24, 2012 2:05 PM To: Skiba, Kevin J. (MRO) Subject: RE: CLU MITs for CINGSA Thanks. Regarding the pressure monitoring when CINGSA is operating, will the IA and OA values be shared with them or will they be obtaining pressure readings themselves. Working with two parties here is a little confusing. Tom From: Skiba, Kevin J. (MRO) [mailto:kskiba @marathonoil.com] Sent: Tuesday, January 24, 2012 12:39 PM To: Maunder, Thomas E (DOA) Subject: RE: CLU MITs for CINGSA Tom, The tubing pressures are collected daily, from the SCADA system, and entered on to round sheets and into our TOW database. The O.A. and I.A. pressures are gathered weekly and entered on to region wide round sheets and into TOW. Let me know if you have any other questions. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC 2/10/2012 Page 3 of 3 • . kskiba @marathonoil.com Office (907) 283 -1371 Cell (907) 394 -3674 Fax (907) 283 -1350 x Safe, Clean, & Responsible From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 24, 2012 9:48 AM To: Skiba, Kevin J. (MRO) Subject: CLU M1Ts for CINGSA Kevin, I am looking at the 403s for the proposed MITs. What sort of pressure monitoring does Marathon presently do on the wells? I presume there is a daily check by the operator of the tubing pressures and maybe the tubing x casing annulus pressure. Is that correct? Thanks in advance, Tom Maunder, PE AOGCC 2/10/2012 • Marathon JKARATHON Alaska Production LLB Mara~FTOn Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~G~ December 30, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-407 Well Completion Report and Log Field: Cannery Loop Field Well: Cannery Loop Unit #10 Dear Mr. Aubert: ~~~sico ~i1 ~ Ga:~ Coles. Commissio~- An~^6~s~r~0~' ~~~ ~~~ ~~:~~ ~~~~ ~ ~ 20iC~ Submitted for your records is the Well Completion Report and Log for CLU-10 well. The Beluga formation was abandoned and CLU-10 was recompleted into the C-1 and C-2 sands of the Sterling Pool. The C-2 sands produced water and were isolated with a bridge plug. Efforts to produce the Sterling C-1 sands, in commercial volumes, were also unsuccessful. CLU-10 is presently shut-in awaiting further evaluation of the utility of the / Sterling Pool in the Cannery Loop Unit. Please contact me at (907) 283-1371 if you have any questions or require additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-407 Well Completion Report & Log cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALAS LAND GAS CONSERVATION COMMIS ,~~;::~Ii`~ ~~~~~~~ WELL COMPLETION OR RECOMPLETION REPOR~I~~~~-Commissi0f~ 1a. Well Status: Oil^ GasO Plugged ^ Abandoned ^ Suspended ^ 2oaac 2s.1 os 20AAC 25.110 GINJ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 1 1b. Well Class: ~.., ; ~hn Development ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: Marathon Oil Company 5. Date Comp., Susp., or Aband.: 10/6/2009 12. Permit to Drill #: 205-106 Sundry#: 309-325 ~ 3. Address: PO BOX 1949 Kenai Alaska, 99611-1949 6. Date Spudded: 7/22/2005 13. API Number: 50-133-20553-00-00 ~ 4a. Location of Well (Governmental Section): Surface: 273' FSL, 520' FEL, Sec. 7, TSN, R11W, S.M. 7. Date TD Reached: 8/3/2005 14. Well Name and Number: Cannery Loop Unit #10 Top of Productive Horizon: 80' FNL, 1,255 FWL, Sec. 17, TSN, R11W, S.M. 8. KB (ft above MSL): 41' Ground (ft MSL): 20' 15. Field/Pool(s): Total Depth: 84' FNL, 1,269' FWL, Sec. 17, TSN, R11W, S.M. 9. Plug Back Depth(MD+TVD): 5,532' 5,084' Cannery LOOP Unit /Sterling POOI 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 272,452.10 y- 2,388,727.00 Zone- 4 10. Total Depth (MD +TVD): 8,450' 8,002' 16. Property Designation: ADL - 02397 TPI: x- 274,220.41 y- 2,388,339.78 Zone- 4 Total Depth: x- 274,233.56 y- 2,388,335.72 Zone- 4 11. SSSV Depth (MD +TVD): NA 17. Land Use Permit: NA 18. Directional Survey: Yes ^ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: NA (ft MSL) 20. Thickness of Permafrost (TVD): NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 20" 133 K-55 0' 123' 0' 123' Driven NA NA 13-3/8" 68 L-80 0' 1,953' 0' 1,866' 16" 606 sks 0 9-5/8" 40 L-80 0' 5,410' 0' 4,962' 12-1/4" 417 sks 0 3-1/2" 9.3 L-80 0' 8,419' 0' 7,971' 8-1/2" 1,324 sks 0 23. Open to production or injection? Yes ^ No ^ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8,419' NA MD TVD Hole Size s~f 5,419'-5,434' 4,971'-4,986' 0.27 4 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: 9/1/2005 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: NA Hours Tested: - Production for Test Period Oil-Bbl: 0 Gas-MCF: - Water-Bbl: - Choke Size: - Gas-Oil Ratio: 100% gas Flow Tubing Press. - Casing Press: 0 Calculated 24-Hour Rate ~ Oil-Bbl: 0 Gas-MCF: - Water-Bbl: - Oil Gravity -API (corr): NA 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No 0 Sidewall Cores Acquired? Yes ^ No ^~ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~DMS Jl~t - 2 20'~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE 28. GEOLO IC MARKERS (List all formations and marker untered): 29. ORMATION TESTS NAME MD TVD Well tested? Yes ~ No ,list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost -Top detailed test information per 20 AAC 25.071. Permafrost -Base Sterling 5,026' 4,579' Beluga 5,614' 5,166' Tyonek 8,278' 7,830' Formation at total depth: Tyonek 8,450' 8,002' 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283-1371 Printed Name: Kevin J. Skiba Title: Regulatory Compliance Tecnician Signature: , ~ Phone: (907) 283-1371 Date: October 30, 2009 U 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 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for 1 njection, 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 and Ground Level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ,~~, Ma~r+a,,th~o,,n~ Fations Summary Report by Job• II Name: CANNERY LOOP UNIT 10 Qtr/Qtr, Block, Sec, Town, Range 6007005N011W01 Field Name CANNERY LOOP UNIT License No. State/Province ALASKA Country USA Daily Operations Report Date: 9119/2009 Job Cate o R&M MAINTENANCE 24 Hr Summary Pump 105,000 SCF N2. Pressure well to 3100 psi. Pressure broke over to 2650 psi. -- - - -~ Ops Trouble ~~Starl Time ~~ End Time Dur (hrs) Ops Code Activity Code Status Code Comment 09:00 09:30 0.50 SAFETY MTG AF Discuss BJ and ASRC JSA's. Assign tasks, discuss BJ safety checklist. Issue permit. 09:30 11:15 1.75 RURD OTHR AF Spot and RU n2 pump. P = 1700 psi. 11:15 11:30 0.25 TEST EOIP AF Test lines to 4500 psi. 11:30 13:00 1.50 PUMP N2 AF Pump 105,000 SCF N2. Pressure peaked at 3100 psi and broke back to 2650 psi. 13:00 13:30 0.50 RURD OTHR AF RD N2 pump. P = 2650 psi. Release equipment. Report Date: 9/30/2009 Job Category: R&M MAINTENANCE 24 Hr Summary Set CIBP at 6906' MD RKB (50' above module 9) and dump bail 35' cement on top. - -- Start Time End Time Dur (hrs) - - ~ Ops Code ~ Activity Code Ops Status Trouble Code Comment 07:30 09:00 1.50 SAFETY MTG AF Hoid PJSM. Discuss Expro JSA, assign tasks, and issue permit. 09:00 11:00 2.00 RURD ELEC AF Spot and rigup eline unit. 11:00 11:15 0.25 TEST EQIP AF Test lubricator to 500 / 1870 psi. 11:15 11:30 0.25 SAFETY MTG AF Hold explosives safety meeting. SD Scada and all communications. Arm setting tool and stab on well. 11:30 13:00 1.50 RUNPUL ELEC AF RIH 2.5" owen CIBP. Correlate to module 9, pull into position and set plug at 6906' MD RKB. 13:00 14:00 1.00 RUNPUL ELEC AF POH. 14:00 14:30 0.50 DUMPBL CMT AF Mix 6 gal cement and load 45' bailer. Stab on and test OT sub. 14:30 15:15 0.75 RUNPUL ELEC AF RIH dump bailer #1. Tag CIBP at 6906' and dump bailer. /' 15:15 16:00 0.75 RUNPUL ELEC AF POH empty bailer. 16:00 16:30 0.50 DUMPBL CMT AF Mix second batch of cement and fill bailer. Stab on and test QT sub. 16:30 17:00 0.50 RUNPUL ELEC AF RIH Bailer #2. Dump cement at 6890' .Total cement 35'. 17:00 18:00 1.00 RUNPUL ELEC AF POH bailer 2. 18:00 18:30 0.50 SECURE WELL AF _ Secure well for night. Close permit and leave location. Report Date: 10/2/2009 Job Cate o R&M MAINTENANCE 24 Hr Summary Set CIBP at 5830' MD RKB (50' above module 10) and dump bail 35' cement on top.10/1/09 Received verbal permission from AOGCC to test CIBP at 1500 psi . Start Time ~ End Time Dur (hrs) '~.. Ops Code Activi Code Ops Status Trouble Code Comment 07:30 08:30 1.00 SAFETY MTG AF Hold PJSM. Discuss Expro JSA, assign tasks, and issue permit. Hold environmental standdown and discuss 2009 environmental stats and ideas for improvement. 08:30 09:30 1.00 RURD ELEC AF Spot and rigup eline unit. 09:30 09:45 0.25 TEST EQIP AF Test lubricator to 500 / 1870 psi. 09:45 10:00 0.25 SAFETY MTG AF Hold explosives safety meeting. SD Scada and all communications. Arm setting tool and stab on well. 10:00 11:00 1.00 RUNPUL ELEC AF RIH 2.5" owen CIBP. Correlate to module 10, pull into position and het plug at 5830' MD RKB. 11:00 12:00 1.00 RUNPUL ELEC AF POH. Bleed well from 1850 psi to 0 psi to negative test plug while POH. 12:00 12:15 0.25 DUMPBL CMT AF Mix 6 gal cement and load 40' bailer. Stab on and test OT sub. 12:15 13:15 1.00 RUNPUL ELEC AF Dump 15' cement on CIBP and POH. WHP = 0 psi 13:15 13:30 0.25 DUMPBL CMT AF Mix 6 gal cement and load 40' bailer. Stab on and test OT sub. 13:30 14:30 1.00 RUNPUL ELEC AF Dump 2nd 15' cement on CIBP and POH. WHP = 0 psi. 14:30 15:00 0.50 DUMPBL CMT AF Mix 6 gal cement and load 40' bailer. Stab on and test QT sub. 15:00 16:00 1.00 RUNPUL ELEC AF Dump 3rd 15' cement on CIBP and POH. WHP = 0 psi. 16:00 16:30 0.50 SECURE WELL AF Secure well for night. Close permit and leave location. Report Date: 10/3/2009 Job Category:. R&M MAINTENANCE _ 24 Hr Summary Set CIBP at 5649' MD RKB (25' above module 12) and dump bail 35' cement on top. Pressure well to 1850 psi with N2. 10/2/09 received written a-mail verification of 1500 psi CIBP test and verbal permission from BLM to set the CIBP lower than the 50' above perforation typically required by BLM. Ops Trouble Start Time End Time Dur (hrs) OpS Gode Activity Code '~ Status Code ' Comment _ 07:30 08:15 0.75 SAFETY MTG AF Hold PJSM. Discuss Expro JSA, assign tasks, and issue permit. Hold ', environmental standdown and discuss 2009 environmental stats and ideas for improvement. www.peloton.com Page 1/2 Report Printed: 12/28/2009 M~ iwnanreon ®OilCompany rations Summary Report by Job• Weii Name: CANNERY LOOP UNIT 10 Casing Flange Elevation (ft) 0.00 Ground Elevation (ft) 20.00 KB-Casing Fl ange Distance (ft) 41.00 KB-Ground Distance (ft) 21.00 Spud Date 7/23/2005 Rig Release Date 10/3/2009 Start Time. End Time Dur (hrs) ~ Ops Code Activity Code Status Code Comment ~ 08:15 08:45 0.50 RURD ELEC AF Spot and rigup eline unit. 08:45 09:00 0.25 TEST EOIP AF Test lubricator to 500 / 1870 psi. 09:00 10:15 1.25 RUNPUL ELEC AF RIH with weight bars and tag cement top at 5771' with AOGCC witness. POH 10:15 12:15 2.00 RUNPUL ELEC AF RIH P!T log. Tag fluid level at 5567' (7' below bottom) 12:15 12:30 0.25 SAFETY MTG AF Hold explosives safety meeting. SD Scada and all communications. Arm setting tool and stab on well. 12:30 13:15 0.75 RUNPUL ELEC AF RIH 2.5" owen CIBP. Correlate to module 10, pull into position and set plug at 5649' MD RKB. 13:15 13:45 0.50 RUNPUL ELEC AF POH. Bleed well from 1850 psi to 0 psi to negative test plug while POH. 13:45 14:00 0.25 DUMPBL CMT AF Mix 6 gal cement and load 40' bailer. Stab on and test OT sub. 14:00 15:00 1.00 RUNPUL ELEC AF Dump 15' cement on CIBP and POH. WHP = 0 psi 15:00 15:15 0.25 DUMPBL CMT AF Mix 6 gal cement and load 40' bailer. Stab on and test OT sub. 15:15 16:00 0.75 RUNPUL ELEC AF Dump 2nd 15' cement on CIBP and POH. WHP = 0 psi. 16:00 16:15 0.25 DUMPBL CMT AF Mix 6 gal cement and load 40' bailer. Stab on and test OT sub. 16:15 17:00 0.75 RUNPUL ELEC AF Dump 3rd 15' cement on CIBP and POH. WHP = 0 psi. 17:00 18:30 1.50 SECURE WELL AF Secure well for night. Close permit and leave location. www.peloton.com Page 2/2 Report Printed: 12/28/2009 Marathon Orations Summary Report by Jobs Nultarnor ~QilCpntpany Well Name: CANNERY LOOP UNIT 10 Qtr/Qtr, Block, Sec, Town, Range Field Name License No. State/Province Country 6007005N011W01 CANNERY LOOP UNIT ALASKA USA Daily Operations Re ort Date: 10/7/2009 Job Cate o RECOMPLETION 24 Hr Summary MIRU Expro wireline. RIH w/ 2.60" GR and tag cement top @ 5,583' MD RKB. Tag was witnessed by Lou Grimaldi, AOGCC. RIH w/ 20' of 2 3/8" pert guns and perforate 5,535' - 5,555' (correlated from OH logs) while holding 1200 psi at surface. RD Expro. Leave well shut in and monitor for night- no change. Ops Trouble Start Time. End Time Dur (hrs) Ops Code Activity Code Status Code Comment 07:30 08:30 1.00 SAFETY MTG AF Attended montly KGF safety meeting. 08:30 09:30 1.00 SAFETY MTG AF Traveled to location and held PJSM with Expro and operator. Discussed sim ops, working short handed, handling explosives, and emergency procedures. Obtained safe work permit. 09:30 11:00 .1.50 RURD ELEC AF RU wireline equipment and PU lubricator. 11:00 11:30 0.50 TEST EQIP AF PU tools and PT lubricator to 2000 psi. Good test. 11:30 14:00 2.50 RUNPUL ELEC AF RIH w/ RS, CCL, 1.68" x 14' weight bars, OJ, LSS, and 2.6" GR. Tag cement (new PBTD @ 5583' MD RKB. Tag witnessed by Lou Grimaldi wit - AOGCC. POOH logging collars. 14:00 14:30 0.50 SAFETY MTG AF OOH. Held explosives safety meeting. Prep truck and site for explosives operation and arm gun. 14:30 14:45 0.25 TEST EQIP AF PT lubricator to 2000 psi. Good test. Bleed well down to 1200 psi for perforating. 14:45 17:45 3.00 PERF TBG AF RIH w/ 20' of 2 3/8" 4 spf 60 deg phasing pert guns. Correlate depth to OH logs and perforate 5535'-5555' (C2 interval). Positive indication of firing, no change in pressure. POOH. 17:45 18:45 1.00 RURD ELEC AF LD lubricator and RD wireline equipment. Sign out, leave location, and turn in work permit. Secured well and will monitor over night. Re ort Date: 10/8/2009 Job Cate o RECOMPLETION 24 Hr Summary RU Expro wireline. RIH w/ PT tools to determine fluid level and look for perforations. Fluid level @ 5480' MD RKB. No other useful information. RD Expro. Ops Trouble Start Time End?ime Dur (hrs) ;Ops Code Activity Code Status. Code Commeht 11:00 11:45 0.75 SAFETY MTG AF Hetd PJSM with Expro. Discussed working in wet conditions, working with the crane/manlift, and emergency procedures. Obtained safe work permit. 11:45 12:30 0.75 RURD ELEC AF PU lubricator and RU wireline equipment. PT lubricator with well pressure (1200 psi). Good test. 12:30 15:45 3.25 LOG PROD AF RIH w/ PT tools as follows: Surface: 1199psia & 47deg F End down pass @ 5583' (tag) Fluid level @ 5480' POOH t/ 5300' (1425psia) Blow wellhead pressure down to 1100 psi (1305psia @ 5300') Log interval f/ 5300'-5583' after 15 and 45 minutes from shut in No change in fluid level or significant change in temperature. Perforations were not picked up by CCL. POOH. 15:45 46:45 1.00 RURD ELEC AF RD Expro for night. Sign out, turn in permit, and leave location. Report Date:. 10/11/2009. Job Cate o RECOMPLETION 24 Hr Summary RU Expro wireline. RIH w/ 15' of 2 3/8" pert guns and perforate C1 (5,419'-5,434' MD RKB) correlated off OH logs. Shot w/ 1100 psi on wellhead, pressure dropped to 950 psi in 1 hour. RD Expro. Turn well to production for flow test. Ops Trouble Start Time. End Time Dur (hr's) Ops Code Activity Code Status Cotle Commeht 07:30 08:30 1.00 SAFETY MTG AF Held PJSM w/ Expro and operator. Discussed crane/manlift ops, emergency procedures, and sim ops. Obtained safe work permit. 08:30 09:30 1.00 RURD ELEC AF RU wireline equipment and PU lubricator. 09:30 09:45 0.25 SAFETY MTG AF Held explosives safety meeting. 09:45 10:15 0.50 TEST EOIP AF Arm pert gun, PU, and PT lubricator to 2000 psi. Good test. 10:15 11:45 1.50 PERF TBG AF RIH w/ 2 3/8" x 15' RTG pert gun loaded 4 SPF and 60 deg phasing. Tag PBTD @ 5581' and correlate. Perforate 5419'-5434' (correlated 5425'-5440' from OH logs). Wellhead pressure dropped from 1100 psi to 950 psi in 1 hour. POOH. 11:45 12:45 1.00 RURD ELEC AF LD lubricator and RD wireline equipment. Turned in safe work permit, signed out, and left location. www.peloton.com Page 1/3 Report Printed: 12/17/2009 ' ~ Marathon rations Summary Report by Jot ruaaleor Oil Cor»pany Well Name: CANNERY LOOP UNIT 10 Casing Flange Elevation (ft) Ground Elevation (ft) KB-Casing Flange Distance (ft) KB-Ground Distance (ft) Spud Date Rig Release Date Daily Operations Re ort Date: 10/15/2009 Job Cate o RECOMPLETION 24 Hr Summary Ran PT log. Determined water zone and set plug at 5532' ELMD. Stag Time End Time Dur{hrs), Ops Code Activity Code Ops Status Trduble Code Comment 07:15 08:15 1.00 SAFETY MTG AF Hold PJSM. Discuss Ezpro JSA, assign tasks, and issue permit. 08:15 08:45 0.50 RURD ELEC AF RU eline unit. PU PT tools and stab on well 08:45 09:00 0:25 TEST EOIP AF Test lubricator to 1000 psi. 09:00 11:00 2.00 LOG PROD AF RIH PT string. Log PT to tag at 5558'. SIWHP = 446 psi. BHP at 5550' _ 1190 psi. Fluid level - 3925'. Log indicates slight crossflow from c2 to c1 sand. POH. 11:00 14:30 3.50 WAITON ORDR AF Wait on decision to set plug. 14:30 14:45 0.25 SAFETY MTG AF Hold explosives safety meeting. Go on radio silence. 14:45 15:30 0.75 RURD ELEC AF PU 2.75" CIBP. Stab on and test OT sub. 15:30 17:30 2.00 RUNPUL ELEC AF RIH 2.75" Owen CIBP. Tie in to CBL and set at 5532', between top c2 perf and collar at 5528'. POH. 17:30 18:00 0.50 SECURE WELL AF Secure well and move equipment to make room for slickline. Re ort Date: 10/16/2009 Job Cate o RECOMPLETION 24 Hr Summary Swabbed 19 Bbls water from 3900' to final depth of 5470'. Well bled off aftyer final run. Start Time End Time Dur (hrs) Ops Code.. Activity Cotle - OPS Status. Trouble Code Comment 07:30 08:00 0.50 SAFETY MTG AF Hold PJSM. Discuss Pollard JSA and safety checklist. Issue permit. 08:00 10:00 2.00 RURD SLIK AF Spot and RU slickline unit. PU 2.90" swab cups and stab on. 10:00 10:15 0.25 TEST EOIP AF Test lubricator to 2000 psi. 10:15 15:00 4.75 SWAB TBG AF Make 7 swabbing runs. Original fluid level @ 3900'. Final fluid level 5470'. Total returns 19 Bbls. Small blow after each run but no noticable flow after final run with WHP = 0 psi. 15:00 15:30 0.50 SECURE WELL AF Secure well for night. Close permit, sign out and leave location, Re ort Date: 10/17/2009 Job Cate o RECOMPLETION 24 Hr Summary Swabbed 2 runs and found fluid at 5420' then 5440'. Changed to 17' 2-1/2" bailer and bailed 45 gal water. Final fluid level below 5500'. Start Time End Time Dur(ftrs) Ops Code Activity Code Ops Status ' Trouble Code Commeht 07:30 08:00 0.50 SAFETY MTG AF Hold PJSM. Discuss Pollard JSA and safety checklist. Issue permit. 08:00 08:30 0.50 RURD SLIK AF Spot and RU slickline unit. SIWHP = 30 psia after 17 hours shutin. PU 2.90" swab cups and stab on. 08:30 08:45 0.25 TEST EOIP AF test lubricator to 2000 psi. 08:45 10:15 1.50 SWAB CSG AF Make 2 swabbing runs. Original fluid level @ 5420' (up 50' in 17 hours). Final fluid level 5440'. Total returns 7 gals. No flow after final run with WHP = 0 psi. 10:15 15:15 5.00 BAIL FLD AF Make 12 runs with 1T X 2-1/2" bailer. Full bailer is about 4.5 gal. Total fluid returns is 45 gal. No returns on last run. final fluid level is below 5500'. 15:15 16:00 0.75 RURD SLIK AF Rig down and release slickline unit. Close permit, sign out and leave location. Re ort Date: 10/18/2009 Job Cate o RECOMPLETION 24 Hr Summary - RIH and reperforate 5425 - 5440 OH (-6` correction to CBL. No response. Start Tlme End Time Dur{hrs) Ops Code Activity Code Ops Status Trouble. Code Comment 07:30 08:30 1.00 SAFETY MTG AF Hold PJSM. Discuss Expro JSA and assign tasks. Issue permit 08:30 09`00 0.50 RURD ELEC AF Rig up eline unit. 09:00 09:15 0.25 SAFETY MTG AF Hold explosives safety meeting. Using safe system so leave scada on and SD celphones. 09:15 09:30 0.25. RURD ELEC AF Arm 2" X 15', 6 spf 60 deg phased pert gun and stab on well. 09:30 09:45 0.25 TEST EQIP AF test lubricator to 2000 psi. 09:45 10:30 0.75 RUNPUL ELEC AF RIH. Tie into CBL (6' off of openhole logs. 10:30 11:00 0.50 PERF CSG AF Position gun to shoot 5425' - 5440' OH (5419' - 5434 cased hole). Shoot gun and log off.No response from well. POH. 11:00 12:00 1.00 RURD ELEC AF OOH. RD and release unit to KBU 23-7. Secure well, sign out, close permit and leave location. www.peloton.com Page 2/3 Report Printed: 12/17/2009 ,~ Marathon Orations Summary Report by Job ~~' ~f}tCampany Well Name: CANNERY LOOP UNIT 10 Daily Operations Re ort Date: 10/25/2009 Job Cate o RECOMPLETION 24 Hr Summary MIRU Expro wireline. RIH w/ PT tools to ge t bottom hole pressure and fluid level. BHP @perfs: 453psig, FL: 5,483' MD RKB (49 feet below perfs). Tag PBTD @ 5,532. RD Expro. Start Time End Time Dur (hrs) Ops Code Activity Code Ops Status Trouble Code Comment 08:00 08:45 0.75 SAFETY MTG AF Held PJSM w/ Expro and operator. Discussed job procedures, emergency operations, and hand safety. Obtained safe work permit. 08:45 09:30 0.75 RURD ELEC AF RU wireline equipment and PU lubricator. 09:30 10:00 0.50 TEST EQIP AF PU PT tool string and PT lubricator to well pressure (400 psi). Good test. 10:00 11:45 1.75 LOG PROD AF Perform PT survey as follows: Air test: 11.7 psia & 34.0 degF 5 min bench test at tubing hanger Start: 409.8 psia & 37.8 degF End: 409.6 psia & 38.0 degF RIH @ 120 fpm and log well. Fluid level @ 5483'. Tag CIBP @ 5532' POOH to perfs (5425').. Perform 5 min bench. Start: 464.6 psia & 105.2 degF End: 464.6 psia & 105.2 degF POOH @ 120 fpm logging well. 11:45 12:45 1.00 RURD EOIP AF LD lubricator and RD wireline equipment. Sign out, turn in work permit, and leave location. www.peloton.com Page 3/3 Report Printed: 12/17/2009 • 205-106 50-133-20553-00-00 ADL 02397 ~: 41' (21' AGL) 60° 31' 56.84" N e: 151 ° 15' 48.37" W 7/22/2005 8/3/2005 used: 12:OOhrs 8/10/2005 Tree cxn = 4-3/4" Otis Top of Cement (est.) 4,889' MD 500' above 9-5/8"shoe 2.75" Owen Cast Iron Bridge Plug set: @ 5,532' KB (10/14/09) 2.5" Owen Cast Iron Bridge Plugs set: @ 5,649' KB w/ 65' cmt (10/02/09) ' @ 5,830' KB w/ 58' cmt (10/01/09) - @ 6,906' KB w/ 35' cmt (09/29/09) - Ceramic flapper valves below each module as follows: Module 12 - 5,690' Module 11 - 5,729' Module 10 - 5,897' Module 9 - 6,976' Module 8 - 7,049' Module 7 - 7,106' Module 6 - 7,196' Module 5 - 7,736' Module 4 - 7,985' Module 3 - 8,118' Module 2 - 8,240' Module 1 - NA Junk Plug Remains @ 8,292' CTM CLU-10 Pad 1 273' FSL, 520' FEL, Sec. 7, TSN, R11W, S.M. M M~w-rnoM / Drive Pipe 20" K-55 133 ppf Top Bottom MD 0' 123' TVD 0' 123' Surface Casing 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,953' TVD 0' 1,866' 16" hole Cmt w/ 606 sks (246 bbl) of 12.0 PP9~ TYPe 1 Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,410' TVD 0' 4,962' 12.25" hole Cmt w/ 417 sks of class G, (75 bbls) of 12.5 ppg, Lead & (45 bbls)of 15.8 ppg, Tail Tagged cement plug 5,583' RKB ~ (10/06/09) ,~; Production Tubing 3-1/2" L-80 9.3 ppf EUE 8rd w/ 6.25" OD control line protectors Top Bottom MD 0' 8,419' TVD 0' 7,971' 8.5" hole Cmt w/ 1,324 sks (274 bbls) of 15.8 ppg, class G Sterling Perfs: SandC MD Ft TVD Gun Tvpe Date 1 5,419'-5,434' 15 4971'-4986' 2 3/8" 4 spf 60° 10/10/09 5~' ,555' ~ ~ 7 Z/4~~ A FCII° ~T°Pr°°- ~0/~/Bg a e ~ ~. ' [ w y ~ ~ _. ~~ Fa .~ ~ .`. ~ +*{ ~, ~' TD PBTD 8,450' MD 5,532' MD 8,002' TVD 5,084' TVD ~n control line fired module 1 control line fired modules 2 thru 8 contol line fired modules 9 thru 12 mic flapper valves below each module t for module 1 ' 'Squeezed 12/11/07 nn..a io n ~ a ~~'z~ _ c ~o~~ Squeezed 12/11/07 Well Name & Number: Cannery Loop Unit #10 Lease: Cannery Loop Unit County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,419'-5,555' (TVD): 4,971'-5,107' Angle @ KOP and Depth: - 3° / 100 ft @ 750' MD Angle/Perfs: -3° Dated Completed: August 31, 2005 Completion Fluid: 6% KCL Revised by: Kevin Skiba Last Revison Date: 12/21/2009 CLU #10 PTD #205-106 and Su~ry #309-325 • Page 1 of 1 ZoS- toC~ Aubert, Winton G (DOA) From: Walsh, Ken [kdwalsh@marathonoii.com] Sent: Wednesday, Odober 14, 20Q9 2:35 PM To: Aubert, Wintan G (DOA} Cc: Walsh, Ken; Skiba, Kevin J.; Ibele, Lyndon; Dammeyer, llllfichael D.; Multin, Mickey Subject: CLU #10 PTD #205-106 and Sundry #309-325 ~C~~C3t~, r ~~d~ C}. ~~~~~t ~~~a~~r ~rc~€~€~~~i~r~ ~r~~ine~r ~tl~rafihon ~il~~k~ F~roduct3c~~ ~~~ 9t~7-283-13'~ 9 ~~~fi~e~ 9~7-39~-3060 ~~~9~~ ~ ~~ ~` ,~ ; ~~,~~~~~~ ' ` + ~ ` ~ ~0~ 10/15/2009 . • ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~~ P.I. Supervisor "~, r i`,~~ ~I~~~ ~l THRU: FROM: Lou Grimaldi Petroleum Inspector Section: 7 Township: 5N Drilling Rig: GD-1 Rig Elevation: 41' Operator Rep.: Rang/Mullins/Ostroot DATE: October 7, 2009 SUBJECT: Well Bore Plug & Abandonment Cannery Loop Unit #10 , Marathon Alaska Production LLC Cannery loop Unit/Beluga Pool PTD #205-106 ~ Sundry #309-325 ~ Range: 11 W _ Meridian: Seward Total Depth: 8450' ~ Lease No.: ADL0002397 Casina/Tubinq Data: Casinq Removal: Conductor: 20" O.D. Shoe@ 123' ~ Casing Cut@ N/A Feet Surface: 13 3/8" O.D. Shoe@ 1953' ~ Casing Cut@ N/A Feet Intermediate: 9 5/8" O.D. Shoe@ 5389' ~ Casing Cut@ N/A Feet Production: None O.D. Shoe@ N/A ~ Casing Cut@ N/A Feet Liner: None O.D. Shoe@ N/A ~ Casing Cut@ N/A Feet Tubing: 3 1/2" O.D. Tail@ 8398' ~ Casing Cut@ N/A Feet Pluqqinq Data: Tvpe Pluq Bottom of T.O.C. Mud Weight Pressure /bottom unl Founded on Cement T.O.C. Denth Verified? above pluq Test Perforation Brid e lu 5831' i 5771' Wireline ta N2 ~Ne . test failed Perforation Brid e lu 5649' 5583' Wireline ta , N2 2000 si Pass i Type Pluq Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag ~ s~` Annulus Balanced C.T. Tag ~~j~~~~~'~ 1~~~ ~` ~~~~~ Casing Stub Retainer No Surface 10/02/09 witnessed tag of TOC above "Excape" module #10. Good tag but negative pressure test had failed as well had approximately 400 psi on tubing (had been bled to zero). Suspected squeeze of "Excape" modules #11 &#12 (12/11/07) had failed. Approval to set bridge plug above module #12 obtained. Set same at 5649' and dump bail approx 40' cement on top. Pump N2 to 2000 psi on top and leave for weekend with electronic data recorder on tubing. 10/06/09 Returned to CLU #10, data from tubing pressure recorder showed good pressure test. RIH w/2.6 gauge ring to 5583' tagged up firm but hi her than ex ected a rox 26' hi h could not et dee er. Acce ted ta E-line will be erforatin above lu s. '~ 9 P ~ PP 9) 9 p P 9~ p 9 p 9 cc; Attachments: Plug tag record; pressure test ,i Distribution: -Wefl File (original) -Read File -DNR/DOG Rev.:01/26/09 by L.R.G. P& A CLU 10 10-06-09 LG.xls 10/15/2009 Pressure Temp (deg Date & Time (psia) F) 10/2/200917:25 18.814 49.91 10/2/200917:25 562.794 49.92 10/2/200917:30 790.382 49.73 10/2/2009 17:45 1553.361 49.01 10/2/200917:53 2002.842 48.59 10/2/200918:00 2025.039 48.25 1 0/2/2009 1 8:30 2014.273 46.48 10/2/200919:00 2010.116 44.95 10/2/200919:30 2007.716 43.92 10/2/2009 20:00 2006.138 43.1 10/2/2009 20:30 2005.023 42.59 10/2/2009 21:00 2004.184 42.21 10/2/2009 21:30 2003.548 41.79 10/2/2009 22:00 2003.036 41.37 10/2/2009 22:30 2002.634 41.34 10/2/2009 23:00 2002.303 41.12 10/2/2009 23:30 2002.033 41.51 10/3/2009 0:00 2001.783 41.43 10/3/2009 0:30 2001.573 41.19 10/3/20091:00 2001.389 40.84 10/3/20091:30 2001.229 40.73 10/3/2009 2:00 2001.094 40.87 10/3/2009 2:30 2000.978 41.03 10/3/2009 3:00 2000.869 41.03 10/3/2009 3:30 2000.769 41.07 10/3/2009 4:00 2000.675 40.83 10/3/2009 4:30 2000.59 40.65 10/3/2009 5:00 2000.516 40.77 10/3/2009 5:30 2000.454 40.89 10/3/2009 6:00 2000.395 40.85 10/3/2009 6:30 2000.327 40.63 10/3/2009 7:00 2000.275 40.47 10/3/2009 7:30 2000.224 40.37 10/3/2009 8:00 2000.173 40.32 10/3/2009 8:30 2000.119 40.3 10/3/2009 9:00 2000.074 40.5 10/3/2009 9:30 2000.037 40.97 10/3/200910:00 2000.014 41.57 10/3/200910:30 1999.972 42.18 10/3/200911:00 1999.96 44.31 10/3/200911:30 2000.009 46.65 10/3/200912:00 1999.976 46.75 10/3/200912:30 1999.969 47.75 10/3/200912:50 1999.969 48.79 ~ ~L) ~ - I ~~ CLU #10 PT plug @ 5583' 2000 1500 eo ~ a d L y ~~0~ N d ~ a 500 0 ~ u 10/2/2009 10/2/2009 10/2/2009 10/3/2009 10/3/2009 10/3/2009 10/3/2009 10/3/2009 10/3/2009 16:48 19:12 21:36 0:00 2:24 4:48 7:12 9:36 12:00 Date 8 Time Cement PI ug Tag Database: CLU 10.sc6 Drate CXeation: Project: CLU 10 `~ ~~~ `~ -( C~ ~ Depth Unit: Well: CLU 10 Vertical Scale: Log Pass: Douui Preserrtation: PLT (SF~) Default Prese~~tation PI 100 Depth (ft) Casing Gc-1Q 10cator (n 5050 00 f ~~~-2-C. ~~ ~ati2oos io:ss:is Ann ft 1:240 90 Davunhde T ature 110 ~0 Car~aatance l%Waterl 100 ~ 408 Pressure Lower (psi) 508 ~,~„ J I~ 5200 5.'i00 • 5400 5,500 5550 FLUI D \J 5600 56.50 #1 #11 5750 ~Top of C',err~errt 5771 5soo -- _ _________ _______ __ --- --______- - ---_____ ---__ ~ ~ EXPRO C L U# 10 C e m e n t ta 1 WIRELINE iNTERYENTIQN g 0-6-09 ', Database File: cIu10.db , Dataset Pathname: HG2/pass5 ' Presentation Format: ccl Dataset Creation: Tue Oct 06 11:44:37 2009 by Log Std Casedhole 07122 ', Charted by: Depth in Feet scaled 1:240 I ~ ' 'J ~Cl ~ ` L~~ ~% I 0 LTEN (Ib) 3000' ----------------------------------------------------------• ' r ~ ~ ( --r- , -i ~ -~ ~ , ~ i - ~ ! ; i i ! i 1 ~ ~ i I i i i ,_ _ i ~ I +~ I i i i { _ ~ ~- i 1 i T ~r _ ~ ~- I' i ! ~-J ~ ~~ ~ ' ~ I _ L I_ _ `~ - ~ - ~ i - --~ -- ~ ~ - ~ - . i I ~ i ' i~ ~ I ~ ~ ~ I~ _ I I ~ ~ I ~ _ ~ +- I ~ , i '~ ~ '----~---~-- _ -' - ; . ~ ~ : ~, I _ ~ _~ i ~ i i ~ _ - ~_ i . ~ _ _ 4200 ,_; ' i i -I__ -- -- ---- _i__ - ~ -1 -- -- i I I I ~ -I ~ ~ i . - ,~-~- ~~ ~ __~~ ~ j ! _r _ ! ~ I ; _ I -~ I- _ - -. ~~ ~ ~ ~ ~ - ~ ~ i ~ I_ -~ ---} ~ ~ ~ -- -1--- ~- - - --- --- --- - __.. -- - - _ ~.. --- - ' ~ i i i _ ( I ; ' _ ~ _ I i ; -:~-. -~ ~--j=- - ~ ~ - , -- - ~- - ~ - ; , - ---i ~ ~ ; ' , , ' _ i I , , ~, _~ ~i i i I ' ~ i ~ ~I i ~ ;~ i i ~ 1 '_ _ ! i- ~ ~ I _ _ ~ I ~ : r - - - - ~ , -- - -- ~ ; __ - ~-~ ' ----~- -~- {-- I ~?- , I ~ I ~ iT ~ i j ~ i i ~ J ~ ~ 1 ._ I ' . _ i ? ~ ! ~ __I L ! ' . I ' _ i ; , ~ ; _ , _ ~ i -T ~ ; _ , , -~-- , { ~~i _ ~ ; i ; ~ , , 4250 ; ~ _ ! ~ ! h ROUGH JT. i ~ _ ; ~ _ i _ . -~ ~,- ----I- ', ' ---~+ --L -`~ -~~ _ ~ . i i j I , ,. I I ` ~ -i-- ~ , ~ ~ ~_ I ---i-- - - ~ --t - -~ ~- I -7 ~-- ~ - ~ - ~ ~ -- - ~ ~ I ; I ~ _.. .. , .. . i . .. _ , ~. . .. .-~ _ . ~ . _~__ ' I _I ' -~-- --1- --~ - ,-- '- - ~ - -~ ~ --~ ~- ~ ~ ~ `+ ! i ~ _;~ i , : ~ ~ ~ i i i ; I ~ __ I a __ i ~ , ~ . I ~ ~ i I I I . . ~- I- ~ 1-_- - ~~ L_ ~ ~ ~ ~ , - ----j- i i i ~ i I i ~ i i ~ i _~ _ , ~ , __ , ~ I _ i _ i ! _ _ , . ~ I ~ ~_L _ _ i- . - - -- - ' 4300 i-~ ~- ~ ~ i ~ ~ -~ ~ - ~ _ ~ _ I -~ i- -- I _ - .--- i-- -1 -~ ~ _ ; ~ i i ~ I ~ ~ _ ~ ! ~ , J ! i ,_ i ~ i ; ~- i _ ' _l_ ' i ~ ' ' ~ ~ ~- ;- _I j - - ' ~': i-I I -~-- _ _i i !~ i ~' ~- ; ~ ' L ! . ~ . i ! _! ! i i _i. _ , . ~ ~ I 1 ~ l ~ ~_ ~- _ _ _ , ~~_ , --~ -~- ~_~-__.-. ---~-- -,'- --~- ~ -~-_ ~ ----,-, -, :- ' - i + ~ ; i - ; -- ~ -- , - ; --- - ~ ~ ~ - -~- ~ f ~ ~ ~ , I _ i _ _ i _ _ . _ ~ , i_+_ _ __ ~ i -~ ' ~ ' !-~-, _ ~ ~ i ~ ~ i I i i ii i I~,, _ ~ - ~ j - _ , I - i --' ~. I I ~~_. 1 ! j i i- I- -}--- - -~-- I ._ I i i _ j ~ 1 ~ ' i ~ i ,_ i - - ----..~ ' - ' -!- , --~- - ~ --~ - - ~ 4• T- - , - - ~_ ~ _ -- ~- - ; -~- - - -~-- -~j---F _-~---~ i i -- - _-_ _ ' ~ _-t-_ --- --- - 1--- - ' ; - - - , - -j- --'-- - r- -.~- - _ -- ~ ~ - - - ; -- , _ _ . , i , , ~ , ; ~ . _ ; -, ' ~ - , - _- G- ~~. ~: ; ~ ~~ _ - , - - -- __-_ -a- _ ; -- ~ _I , -~ ~ i - ~ -- , ; , i , , , i i i ; ~ - L ~. -- - i - i j 1- - , --~- __ { - i ;- ~ ~ ~ , i ~ ~ ~ -~ --i- - - i - I - - -- ----_~ !,_ - ~ _ ~ --- - --~--i i - -- i -- ------ ~~~ ` ~ --- ~ ~~ ~ ~ ~ - ---- ~ T --~- ~ - -- - - - - i ~ - , ---- - ` ~ '_ ~ - , ~ ~ - -- ~ --- ~ - - ! ~ i , _ -{ -- i - _ -- ~ , ~ ~ _ ~ ~ i ~ ~ ~ - ~ , ! ~ ~ - , - ., ! ' ~ ' --I - - ,--~ - i _ - ; - ~ ~ ~ - - - ! ~ . _ i_ ; , i_ i , i i _ ~ ~ i ,; ;_ ; i { ~ , _ 1 , ~ i , i , 4400 ~ ~ i ~ ~ ~ ~ _` _ - !- , !- - ~ --', -- - ~ , ~ -- + {- --r---~-- - , ,-- ---' -! ~--- ~ - ! i --- ,__ _ , ~ , ~ , _ ; , ! i i i - ~ -- -- u u ~ ~ ' --~ - --- - -- ~ ~-- ; T - ~- - - - _i -,- - T~ -, ` i ~ ' = i i ~ ~ ~ ~ : ~ -~ -- r ~ ~-i- _ _ ---;--- ; i . - ; ---i ~ --- ~ ~ , ---~ -- _ - ~ -- 1 ' ...~ -- - ~ - I --- I ~ ---~ -- - I , -- I I _- , I -- -----*-~ i __ i I I _ _,- I - - - . -- ~ ~ ! -- , i ~ -- ~ ` i i I ~ i i I i I i i _ I ! ! I , i y ; I , , I I ~ ! I _ 1 I I - ' _ _ I _ -~--- ~ _ ; . I - - ' ; '--'- _~ ~- i_ - _ r- , - i ! I i . ~, i ~ _ _ 1 _ i i ' _ _~ i I ~ i ~ I I I ~ ~- - ! ~ ~ ---~---;- - _~ --*-- - ~ ---~ _ -- - - : ,-- , , -- - --I- + , - ~- --- - 4450 T - - ~~ ~ --r ~ -- i -- -~- --! i~ - ~ i i i I I I ~ i i I i ~ i _ I ~ ' ~ J - - ~ -. __ ,~ i ' ~ ' I ; '- i- __ - , ~ _--~ ' _ -- , - ~ ~ - i-- -- ---1-- ~ ~ -- -~ i ~ ~-t ~__~- ~ ~ -- -~- -- - ~ - ~--- -, - - ~ ---+- ~ i , -±--, - ~ - -- ~-- . --- -=- ~ L~_ , ~ - ----!.~ I I -i --- 1 ~ i -T-- - ~ i _ _ i -~-_ . ~ -1- - ~._- ; ~ - --t--- __ -~- _ -_~ _ T , ., , ~ _ ` ~ ~ ~ j I _ ;. ) _ . i i ~ i , I ~ I - ~ ' I ' ~ ; - -- -- - - - --~- -- _ _ , I ~ ' ~ J , ~ ~ ~ ~ ~ ; ~ ~ I_ -- ~- ----~- -~~ - -- -- ( - ---~- ~ ~ -I - - I ~ - ~ - -- ~ i , _ 4500 ; ~ , ~ i ~ i ~ ~ - - i i , , i - , i , ' ~ i . i ;; i i i ~ , - - i , , - - ;~ - ~ ~ `- ~ ! . i ! ' , ~ I . I ' i I , ' I ,~ ~ ~ I _ ~~ ~ ~, ! ~ i _ ~ , ~--~- ~~ --~ - , ~ - -- ~ _ - ,---r- - I ~~--- ~ --}-- -- ~ -~- _ -- , -r- , ~ -- ~ -- -~ ~ -- i ~ _ _ ~ __~ -~--I_ - _. ~ , , _' _-1 t I _ ~ i " -t- ~ - ~ L I ; I _ , , i ~ -; ~ , _ i -- - , ~ , ~ i- ~-- , ~ , - i , _ I -_ i ; ; , - - , - - - , ; , i ~ ~ , _ ~- , . ; _ ~ i ~ ; - T- ~ ~-- ,_ _ - , _ __~ - ,_ ' ~ ~ ,_: _ ~ i-, , _ _ ~ ~ ~-+--- - -- ~ _ ----~ -- _ -!. - "~ -,- ~ ;-- ;-+ ~- _ _ --_ -- I- ~ '_._ _ . ._~.'- , !,_~ I j . 4550 __~i -, -T . "..~.._''_' _-' T _ , ~ T - - ' -_. , _ _ i i _ _ , ~ ~ ~ ~ ~ ~ : ~ : , i ~ ; ~ ~ i _ ~ ~ , ~ ~ _~ ~ ' = ~ ~ --- - ~ - - - - ~ - ~- ~--; ,- ~ ~ ~ ' ~~i t ~_ ~ ~ i,_ ~ I I i ~ ~ ~, j . ~ ~ ! ' I ~ _ ~ . , ~ ~ ! ~~ ~ T ._ ! . _ I I ~ ~ --- - - - ~ -- ~--- rt- _- - ~ • .. ! ~ ,_ ~ _ i- _ , . ~ - 1 ~ ~ I - -I ~ 4600 , ~ . ~_ ~ ; - i i _ ; _~ -_~__ ~- '.-~_,~ i i _ 4700 ; j ~ ~ i --~---- ~-- , ~,--~---- - ~ ~ ---}-- ; _ i ~ ~ ~ _~ _ - ;-----~---~ ~ _ ~ _ i ~~ 4750 ._ , _ !-- - i-- - -}--- - - _ _ . ~ --__ r - -- ; - - - --- ---- -- -- ~ _i _~ _ -- - i ; ; --- __ --- --- ~ ~ . - -1 - ~ i I ~ - - - -- -- ~ i - --- _ ~ !_ ~ ~ _ i _ ~ ! __ i _ i i ' ~ ~ i ~ i ~ I i _. ~ ~ i i - ~ , i _ i ~; _ _ i ~ I j i ~ i , _- - ' - - -- - r - ~.- - -- i I --~-- ~ i -- ~--~ i i , , ~ ~ -~._ - - _ i _ ! ~ ~ i --+--- -- j - I - . __ . r-. , ' -.. -_ ~ _ ~~. _I ;~ I ~ _ ~ i I ~ _ I ~ ---- - ~ -- ~ - I ---~ -- -~ ' ~ -~- - - / ~ - ' - - ~-- i ~- I I ~ - . ... .... i. . .. I ... ~...... .,. I .... _ .~. ~ ' . ,. . . i ._ i I .. . ~ .~ ~ ..~ _.. •~~~ . ... I i ._~ . . . . j.. _ I __ _. ~ ~- _ ~ ~.. ..... . . . - j i ~ I ~ i.. ~- ~----~ -- ~ ~-~- - - --~ -i-1-- -- ~ I ~, ~-~ ~ ---- ~ I ! ~ - , 1 - ; - I ~ - i_ - - -- - -- ~- _ ~ ~ ; ' _- - -- ~Lf --~ - I i . ~. ~ _ i ' i - 1 } ~ i I_ i ~ j - ~_~ ~_ -----~ - ~ i ~ - - j -- I _ I ---~-- ~- ~ I __- Ti -- 1 i _ - ~ ~ _ ~ i I - -r-- - i _ . I i _ -- - -~- --- ; T~ - ; i --,- - -- i - ----C-- - , I -, - - -- -t--` L _ ~_: -- +; - - _ i __~ - ;- -- - , - - -----~ {-; -- ~ ~~___~~~~~ ~~_~~~~_ I ~ -- -- _ ' _ 4850 a i _ _ ; , ; i ; ~ , , , i ; i - ~ ~ , , , , ~~ , - - ' - ~ -~ i i - - - - - , - - -- ~_ 1-~ - ~ ~ , ~ i ; ~ , i ~ i _ ~ _ i --- ~- _ , ;_ . _ ~_ ~ -- ~ ~ ~ _ _i -~~-- _ ;_ ~ ~i ~ ~ ~--- ~' ~ ~ ~ ~ ~ ' ~ - ~ ~---~- ~ -i -- ! - ! i ~ _ i i ~ ; i ~ ~ ~ , ~- ; -r---~- ; , , , ~ 'i . I -I ~ ~ ~ ~ ~; I -~ ~ ~ , ; i ~ , _ . -i-i ~ ~ ~ {_ - '' , , - ; ~ , ; , ' - + - ~ ~ i ~-' _ - - - -- i I - ~ ~-- -- - , , ~ , - ~ ~ ~ ~ ~ i , -~ - : ~ , ~; ~ ~, ~;- - i , i ~ ; i i - -- i-- -- -~~ ~ - - ~ ; • ;- ~ --,- , ----- -~ -' ---- ~ , , i ~- i , , ~ _, , ~ ,: ~. i_ _ ~ - , - _ L ; ~ , -~ _ _ _. _ ~- ~ -- ~ ~- a_~ .- ~ i ~- -- ~ 4900 , ~ ; ~ ~ ~ i , I , J i ~ : ~ : _ ^ i I - - ~ - ; ! ~ ! - -~-- ~ - , ; -}---r ! i . , ~, _ __ _ , . - ~ , : , ----~- ; ~ , ---; -i--~ ~ _ ~ ~ -- - ; - i __ ' ~ -~- , -- ~- ~ - --' _T ~ , - ----a- -- ---- ; ~ ---;~- ,~ -, ----1----~--~---- - , i . , ': ~ ~ ~ ; ~ ~ ~ ~ ~, ~ ; ~ _ , _ , i ~ , ~ ~ _ , __ ~ ~ - ! ' - --~- - - - -- - - - - ~ i - - ~ ~ ~ ' , ' -- -~- ~ _ i I~ , - ~ - i - ; ~ ~_~ - -~ i ~ ~~ ~ ~ _ < < , ~ ~ ~_ _ ~ _ ~ ~ , ; -- - ~ ~ __ ,_ ~ ~ - i - ' ' i ~ - - -- i ~ ~ -~---~--1- -- - -!- -- i_ ~ - ; - - ~-- ~- - ~ _ r _ i i . ' ' 4950 , ~ _ ' i ; I , ~ , ~ ~ ~ , ~ _ - - ~ ~' i - , i- ~ ; -- -- ~__-_-- -- ~ - ~ - , ; ; j i -i- i ~ , _ ~ i ; , ; , ~, ~ i ~ , ~ _ ~ ~ : . ! ,-~- - - -- ~ - -±-- ~ ~ _ , ; ~ ' - -' - ! i - ~.- - - ~ ` i , - -- - ~ ~ i_ i_ . ~ - - - K ~ ~ - --- ~- i ~ __ ~- T~ ~- - I ~_ ; _ _ ~ ~ ~ -~ _ -'-~ I ~ i '-G----~ N y_ i- _ _ I i i. i- i i . j I --~---}-- -{-- i i_ - - i - ~ ~ ~-~ - ~ I -{ -- _ -- ~ --- - - - , -- -- ~ ~ i - ~ -- i ~ ~ _ - ~ ~ _ _ I . i _ i j _ i _ i ~ ~ i _ i ~ ~ 1 i i i _ ~ ~_ ~ , ~ ' i i i I_ i , i _! _ ! ~ . _ ~ i i_ ~ ' --~- ~- ! ~ -~---~{- ~ _ j ~ ~ ~ - _ i --r--r-~- ' _ .. ~ -- - - --- ~ ._ ~ ~ _ i - - , i. i - ~ - - =--~- i _ -~- ~ ~ _- , -- ~ -- -~-- - ~- - -- --~ i _ ' i i ' ~ 5 0 ~ ~+~ ~ ~ ~ ' ~ i ~ ~ ~ ~ i ~ 00 ; ~ , ~ ~ ' ~ ~ ~- ~ ~ -~ ----~,~. I ~ ~ -~- ~-~- i -- ~ ~ _ - ; , ~ ~ _ ~ ~ ; ~ 1 , j _ ~ : - = _~~ : ~ __. - _ !-- ~ , - , _ -- ---- ---- -!- -- ~ , , -- --~- -~--- - - , _ ~-- _ , ~----'~-_ _ , , -- - -- -- -{--,-_- ~ -~ --- -- , ,- - ; , ; ~ , ~ ~ ~ ~, : , ~, , ~ , ~ , ~ ~ ~ ~ ~---------------------------------------------------------- 000£ ~GI) N31~ 0 i i i i ~ • i ~_ ! i i ~ ~ E '~ ~, ~I I i !~ d011~W3~ ~ --rt-~~ ~_ __ - '-~ ; -C-- ~---,--{------ £8SS ~ ~ __ -- ---- --- -- - -~-- - -- ;---r -r- ~ , f- ; , I ~ i i ' ~ i ~t ; j , ' - , ~ . , l I ~ ~~ , , i _ i ~ ~ _ i _i i i _ ~ ~ i • - - -i-- -1-- ~--}--~ - - - !_- ';- ,- _t _-~- i~ , , , ~ I i, i i i OSSS ~ _, ~ ~ ; ~ ; ^ ~ ~ . i _ ' ~ ~ ~~ ~ _ ~ ~ i ~ _; , ~ , ~i ~ ~ ~~ ~ ~ -__ -._ ~~I ~_ __ _ !~ _ ~-- ~-~--- _ ~ - --I---- ~ ~~ ~ ~- -- --- G-- ~ -- --- "~ ' - - -- ~---- -~-' - i -+ -- --, --~~ -i- ~-i ~ .. ~~- I ~-~"~ OOSS ~ S- l~~ S I ~ ~ _ ~- -- -, -- ----, -- - ~ ~ ~ i ; , i l _ i _ . i ~ , i- - --~--.. ; ~ ~ ~ ~_ ~ i -.-'- - --~-- ~-_ -I---_ i _~_ _ _ ' _ - - - --- - _ ~, _ _ . -, --,--; -- - --- - - -~-- _ _ , _ c:ontirmation of changes to CLU I O recompl~on procedure (Sund.~, # 3U9-263) Pa e 1 of 1 8 2oS - t o(p Aubert, ~nton G (DOA) To: Dammeyer, MichaeF D. Cc: DOA AOGCC Prudhoe Bay Subject: RE: Confirmation of changes to CLU i 0 rec~omplehon prooedure Mr. Dammeyer. a O~GC~ hBi ~bY ?r~P~ ~~°S Ci~a!'y°S i~ ~L':^u~~ '~i~. 3~:Jy-32~ ~~^0? ~;1.~.^'_."~. J~i -vi :~`J.~.'i ,. _~ 1 - ( ~~; J ?!~ 1 ' z .: ~ . ~- ~6 j, s~ri~pc oeiovv. ~; ot"~; su~:~r~ a~prova~ ~tip;.r?atic;;s app;y. . U'1ln.<~t~ :aauert ,~OGCC ?93-1231 - ___ __ _ _ _ _ _ _. From: Damme~r, Mkhael D. [mailto:n~ddammeyer~mara#~onai.com] _ Sen~ FridaY, Otbober 02, 2009 9:00 AM Ta Auber~ Win6on G (DOA) Cc: Wal,sh, Ken; Sldba, Ke~rin J.; Rang. Uai9 L ~ Subject: Cor~firmation ~ chat~ges tio CLU 10 necompl~ion Prvicedure (Sundry # 309-263) Mr. Aubert, This is a request for confim~ation of changes to the CLU 10 rec~mpletion procedure (Sundry # 309-263) as Ken Walsh and I discussed with you yesterday (pctober 1, 200g)- We i-~ter~ to proceed as per the original approved proc~edure with an additionai ste~: after the second plug is set, we wip bleed the wen d~m to atm~p~~, ~ the thirc! CIBP at 5624' and slickline tag the plug to v~erify i~.s location, and finaNy pressur~e ~est the ~ug w~ an addidonal 1500 psi of nitrogen at surtace. We wia then co~rtinue on with the procedure as planned (dump bailing of cement, etc). If you would please indicate your approvai of this change by ~+eplying to this ema7, we wiN have written approval to show the on-s~e w~nes.s later today. Thank you, Michael Dammeyer Produc~ion Engineer II Marathon Alaska Production LLC ~~~~~~~~~ ~ ~~? ~J ~~ ~ 20~~ 10/2f2009 ~ • ~.~~~ ~~ _~ ~~ ~~ _ ~ ~ ~~~ ~ ~ ~ ~~ ~ ~~~ ~ SEAN PARNELL, GOVERNOR Mr. Michael D. Dammeyer Production Engineer Marathon Alaska Production LLC ~ P.O. Box 1949 ~ ~ " ~- ~ Anchorage, AK 99611-1949 ~ Re: Cannery Loop Unit, Beluga Pool, Cannery Loop Unit # 10 Sundry Number: 309-325 r., ~, .~~,;,, Dear Mr. Dammeyer: 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, Daniel T. Seamount, Jr. l Chair n DATED this ~Zday of September 2009 Encl. ~ ~ ~ IVlarathon JMARQTHON Alaska Productian LL~ ~ September 11, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Cannery Loop Unit Well: Cannery Loop Unit #10 Dear Mr. Aubert: Ma•hon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~ ~~~ ., Attached for your approval is the10-403 Application for Sundry Approvals for CL-10 well. Marathon proposes to plug the Beluga formation perForations and recomplete CL-10 into ~' the Sterling C1 and C2 sands. We hope to commence with work operations during the last week of September 2009. Please contact me at (907) 283-1371 if you have any questions or need additional information. Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-403 Application for Sundry Approvals Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File KJS MDD STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N . '~i~l,$t A- 9~/~~too q ~r:~acfl , il +.~~, ,~ i ~isi.. APPLICATION FOR SUNDRY APPROVALS ,, , . „ 20 AAC 25.280 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: Marathon Alaska Production LLC 4. Current Well Class: 5. Permit to Drill Number: Development ~~ Exploratory ~ 205-106 • 3. Address: p0 BOX 1949 Stratigraphic ~ Service ~ 6. API Number: Kenai Alaska, 99611-1949 50-133-20553-00-00 • 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: ~j~~ ~J~ i E i R S ~ ~°l'~y ^ Ca nnery Loop Unit #10 . ng xcept on pac equired? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL - 02397 • 41~ •(21~ AGL) Cannery Loop Unit / Beluga Poo! ' 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): 8,450' - 8,002' . 8,339' 7,891' NA 8,292' Casing Length Size MD TVD Burst Collapse Structural Conductor 102' 20" 123' 123' 3,060 psi 1,500 psi Surface 1,932' 13-3/8" 1,953' 1,866' 3,450 psi 1,950 psi Intermediate 5,368' 9-5/8" 5,389' 4,962' 5,750 psi 3,090 psi Production g,377~ 3-1/2" 8,398' 7,971' 10,160 psi 10,530 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,880' - 8,275' ~ 5,432' - 7,827' Excape 3-1/2" ~' L-80 8,398' Capillary Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ~• Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: September 28, 2009 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 Michael D. Dammeyer Title Production Engineer Signature Phone (g07) 283-1333 ~ate ~ September 11, 2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~- ,3~~ r' Plug Integrity BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~/:~ " L~(~ ~ . ~ ~~+~~~~ ~~"~... J`~" ~ ?O~~ APPROVED BY 5 Approved by: COMMISSIONER THE COMMISSION Date: ZZ Form 10-403 Revised 06/2006 ~~~~, ~~ L '~a~,,~4~~,,~~~1~+~ pSubmit in Du icate ~` ~~~ ~ ~~ ~ ° Modification to CLU 10 Recom~tion Procedure ~ Page 1 of 1 Aubert, Winton G (DOA} From: Dammeyer, Michael D. [~dammeyerr@)marathonoii.com] Sent: Friday, September 18, 2Q09 3:00 PM Ta: Au~rt, Winton G (DOA) Cc: Scott, Ctyde M_; Loughnane, Katie M.; McElmoyl, Courtney; Dammeyer, Michaei; Henry, Nancy; Ibele, Lyndon; Miranda, Kyle; Mullin, Midcey; Ostroot, James G.; Rang, Craig L.; Skiba, Kevin J.; Walsh, Ken Subject: Madfication to CLU 10 Recompletion Procedure Winton, This email is a follow up to our discuss~n today (Se~ember 18, 2009} regarding Marathon's desire to add a step to our recompletion procedure on well Cannery Loop Unit #10. We would like add one more cast iron bridge plug at 5624' (50' above the top squeezed perforation interval at 5674'-5684~ and dump bail 35'+ of cement on top of the plug in the usual manner. The purpose is to ensure both squeezed perforation irrtervals stay isolated. If you have any questions, or desine further documentation, please da not hesitate to email or phone. Thank you, Mu:hae,L Michael Dammeyer Production Engineer II Marathon Oil Company-Alaska Asset Team 907-283-1333 (office} 907-394-8270 (cell) 9/21/2009 • M MARATHON APPROVALS • MARATHON ALASKA PRODUCTION LLC ALASKA ASSET TEAM Well CLU 10 Cannery Loop Unit Pad 1 Recompletion Procedure WBS # Not Yst Submitted Michael Dammeyer 9~~09 Michael Dammeyer ~e~ ?~. ZUa~ ~/~/200~i Ken Walsh L. C. /6~ 09-~9-09 Lyndon Ibele Author: Michael Dammeyer Latest Version Date: 9/3/09 (Slight revision KDW on 9/8/2009) Well Status: Dead well. Wellhouse is off. Fluid level via Echometer at 2335' from surface on 8/28/09. SIWHP was 900 psi on the same date. Make sure pressure is held on well for entire procedure; this pressure will be used to verifv the pluqs are sealed and to provide the desired qressure to fire the quns. H istory: • Aug 2009: 8/31: Waiting for pressure to push water below perforation target. 8/28: Echometer shows fluid at 2335' (after trying to flow well days before). 8/25: DD Bailer 2.5", samples recovered from 8094'. 8/25: Gage ring 2.63" tagged 8017' (metal piece/cement shards came out with the gage ring, the ring bobbled at 5725'). • Mar 2008: Swab well, does not flow. • Dec 2007: cement squeeze the top two modules (95% of production) due to solids/water from these mods. Squeeze was drilled out with a 2.70" mill, and plug pushed to bottom 8300'. N2 lift; well does not flow. • 2005 to 2007: Lots of problems with sand, fishing, etc. • Sep 2005: Well completed (7 MMcfpd @ 1085 psi FWHP and 290 bwpd) Obiective: Plug and abandon Beluga Excape, and then recomplete to Sterling C1 and C2. ~ Well Recomplete Procedure MDD Page 1 08/26/2009 • Procedure: Three parts... • Part 1: Verify fluid level is below 5600' and SIWHP is above 2000 psi. a. MI man-lift (wellhouse is already off). b. Get work permit. c. 7:30 PJSM on location. Review JSA and SimOps. d. MIRU Slickline and tag fluid level. If fluid level is below 5600', and SIWHP is at least 2000 psi, then skip to part two. If not, calculate the needed N2 to displace the water and raise the SWHP above 2000 psi. e. MIRU BJ nitrogen pumping unit with needed scf of N2 and 2" 1502 iron connection. f. Pressure well to displace water and leave SIWHP above 2000 psi. *** Note: if nitroqen is needed, the pressure needed to shoot _quns will chan_qe and will needed to be recalculated, dependinp on the volume of nitro_qen used ~"~` Part 2: Plug Beluga Excape ~`'` Note #1: Notifv AOGCC 24+ hrs before plup_qin_q operation (20 AAC 25.112 (h)) *'~ ~ Note #2: AOGCC re_qulations require onlv a sin_qle plu_q. However, upon verbal recommendation from the AOGCC, we will set two plu_qs to ensure the proper isolation of a lonq production interval. *"* *** Note #3: BLM and AOGCC re_qulations are different reqardin_q plu_q depth requirements. In summarv, we will need 35' of cement above the plu_q (as per BLM) and must set the plu_q exactlv 50' above the Qerforated interval (AOGCC re_qs require 50' or /ess, and BLM require 50-100', leavin_q 50' exactlv as the onlv settin_q location). *** Note #4: AOGCC re_qulations require testin_q the plu_q with a surface pressure of 0.25 psi/ft tvd or 1500 psi (whatever is _qreater). With a casin_q shoe at 8002' tvd, this requires 2000+ psi testin_q pressure at surface. a. MI man-lift (wellhouse is already off). b. Get work permit. c. MIRU Expro E-line with full lubricator, pump-in sub, flow tubes, and pressure control equipment. Have cement (BJ), two Owen (Expro to provide) 2.5" CIBP, and a 2" bailer to dump cement. d. 7:30 PJSM on location. Review JSA and SimOps. e. PT lubricator to 2000 psi (MASP+) with KCL H20 or MeOH, weather de ndent. f. RIH with 2.5" CIBP via setting tool with casing collar locator and set a 690 '(depth must ~ be exactly 50' above perforation at 6956' to conform to both BLM and CC • regulations). Confirm CIBP is set. POOH with setting tool. g. RIH with 2" bailer filled with cement for enough times to place a minimum of 35' of cement on top of bridge pfug. h. Let cement dry for 24 hours. Do not bleed down well. ~ Te4 ~ ~ ~; ~o ~ 1 ~c~r~ ? Well Recomplete Procedure MDD Page 2 08/26/2009 ~ ~ RIH with the second 2.5" CIBP setting tool with casing collar locator and set at 5830' (depth must be exactly 50' above perforation at 5880' to conform to both BLM and AOGCC regulations). Confirm CICM is set. POOH with setting tool. Verify CIBP is set at correct depth. RIH with 2" OD bailer filled with cement enough times to place a minimum of 35' of cement on top of bridge plug. RIH with 2.5" GR to verify depth of cement. Ensure well head pressure holds 2000+ psi on surface. ! Part 3: Perforate three Sterling sands. ** Note: The reservoir is connected to well CLU 6, which has an estimated current reservoir aressure of 450 psi. The oriqinal reservoir pressure was 2230 psi: at 40% DD, our needed BHP to be safe is ~1340 psi, which calculates to a surface pressure of about ~ 1190 psi ~ Depths to fire guns: C 1 5425-544Q' M D(15' net) C1 5499-5524' MD (25' net - caution; Sw calculates high) C2 5540-5560' MD (20' net) 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 tarqet performance: 0.27" entrance hole and 19.21" penetration. Max qun swell in air: 2.575" OD. a) MI man-lift. b) Get work permit and have open hole logs. c) MIRU Expro E-line service with full lubricator, pump-in sub, flow tubes, and pressure control equipment. e) 7:30 PJSM on location. Review JSA and SimOps. f) PT lubricator to 2000 psi (MASP+) with KCL H20 or MeOH, weather dependent. g) RIH with dummy gun to minimum depth needed for CCL correlation, and tag cement to verify depth. POOH. 2. a) RIH w/ 20' of guns (type shown above). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) Bleed down well to obtain ~1190 psi SWHP ~ d) Pull up into position and shoot 5540' - 5560' (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. f) Flow test overnight to monitor for water. Well Recomplete Procedure MDD Page 3 08/26/2009 .' ` ~ ~ 3. a) Repeat Step 1, a-g. b) RIH w/ 15' of guns (type shown above). c) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain ~1190 psi SWHP. - d) Pull up into position and shoot 5425' - 5440' (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. f) Flow test overnight. ~ Note: Reconsider shootinq the remainin_q potential "wet" inferval based upon qas rate and water production from prior intervals "`~`~ 4. a) RIH w/ 25' gun (type shown above). b) Correlate Expro CBL/GR/CCL log depth to open-hole logs. c) SI well long enough to obtain ~1190 psi SIWHP. d) Pull up into position and shoot 5499' - 5524' (OH). '~eave 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. f) RD Expro, flow test. 5. Produce well to sales. C_onsiderations Instructions and Planninq: See above. Well Recomplete Procedure Page 4 MDD 08/26/2009 205-106 50-133-20553-00-00 ADL 02397 i: 41' (21' AGL) 60° 31' 56.84" N le: 151 ° 15' 48.37" W 7/22/2005 8/3/2005 ased: 12:OOhrs 8/10/2005 Tree cxn = 4-3/4" Otis Top of Cement (est.) @ 4,889' MD 500' above 9-5/8" shoe KOP (a~ 750' MD/TVD Build -3°/100 from 750' - 1,750' Ceramic flapper valves below ach module as follows: Module 12 - 5,690' Module 11 - 5,729' Module 10 - 5,897' Module 9 - 6,976' Module 8 - 7,049' Module 7 - 7,106' Module 6 - 7,196' Module 5 - 7,736' Module 4 - 7,985' Module 3 - 8,118' Module 2 - 8,240' Module 1 - NA Taqqed on (8/25/09) 2.63" GR @ 8,017' 2.5" DD bailer @ 8,094' Junk Piug Remains @ 8,292' CTM Cannery Loop 10 Pad 1 273' FSL, 520' FEL, Sec. 7, T5N, R11 W, S.M. ~~ I -~ . i, I ~ ~~ i 4' A' ~ ;. r~ "~ k~ = ~ ,~. ~ w..y ;:~ , S lo2c~ ~ t~. ` ~ 4~: ~ .~ ~ ~~y ;~ ,-'~ ~ ~ ;~ S43o' ;~! t ~d . ~~ a~ q:G~o~' e~ ^~ ~ ~; Ya J ~ • ~r ~ ~ ~ ~: ~~ . y~ ~~ ~ '~ ~ ' ~ ~~ ~. ~; ~ . '~ ~ .~ ~~ . ~ 1~ . a ~ ~ ~ ~~ ' ~; ~ . ~? ~ , • ~ ~ 4 ~;. TD PBTD 8,450' MD 8,339' MD 8,002' TVD 7,891' TVD ~ M MARATNON Drive Pipe 20" K-55 133 ppf Top Bottom M D 0' 123' ND 0' 123' 13-3/8" L-80 68 ppf BTC Top Bottom MD 0' 1,953' ND 0' 1,866' 16" hole Cmt w/ 606 sks (246 bbl) of 12.0 ppg, Type 1 Intermediate Casinq 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' S,389' ND 0' 4,962' 12.25" hole Cmt w/ 75 bbls of 12.5 ppg, class G Lead & 45 bbls of 15.8 ppg, class G tail 3-1/2" L-80 9.3 ppf EUE 8rd w/ 6.25" OD control line protectors Top Bottom MD 0' 8,398' ND 0' 7,971' 8.5" hole Cmt w/ 1,324 sks of 15.8 ppg, class G - 12 Excape modules placed - Green control line fired module 1 - control line fired modules 2 thru 8 - Red contol line fired modules 9 thru 12 - Ceramic flapper valves below each module except for module 1 Perfs MD (RKB)(All Beluaa Zonesl: , , ' Squeezed 12/11/07 ' ' Squeezed 12/11/07 Module 10 - 5,880' - 5,890' ~ Module 9 - 6,956' - 6,966' ~ ~~ ~ ? Module 8 - 7,030' - 7,040' Module 7 - 7,083' - 7,093' Module 6 - 7,174' - 7,184' ~ZZ ~ Module 5- 7,716' - 7,726' J Module 4 - 7,965' - 7,975' Module 3 - 8,098' - 8,108' Module 2 - 8,219' - 8,229' Module 1 - 8,265' - 8,275' Well Name & Number: Cannery Loop Unit #10 Lease: Cannery Loop Unit County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,880' - 8,275' (TVD): 5,432' - 7,827' Angle @ KOP and Depth: - 3° / 100 ft@ 750' MD Angle/Perfs: - 0.5° Dated Completed: Revised by: August 31, 2005 Kevin Skiba Completion Fluid: Last Revison Date: 6% KCL 9/10/2009 6 #. MICROFILMED 03/~ 1 /2008 DC~ NOT PLACE ANY NEW MATERLAL UNDER THiS PAGE F:\LaserFiche\CvrPgs_InsertsiMicrofilm Mazker.doc • M Marathon MARATHON Oil Company January 11, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Cannery Loop Field Well: Cannery Loop Unit #10 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~ ~~'-~~~ ~~C~ ~ ~ ?' ~~~~~~ ail ~ ~~ C~t~~4 ~~~T1~i1rR1A~1 ~~~~~~~~ ~'~ JA1~ ~ 2QE~fi Attached for your records is the Sundry Report 10-404 for well CLU-10. Work was performed on this well under Sundry # 205-106 which commenced in July of 2005 and concluded on December 28, 2007. Marathon cement squeezed the top two perforation intervals to isolated wellbore water infiltration. If you have any questions or need further information please call me at (907) 398-9954. Sincerely, C~~'/ , - ~.J f ~~i~~ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS DMD STATE OF ALASKA ~ ~~ X ~'t~ ~f ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS JAN 1 ~ 24~1~ Alaska (lil R [gas f'nna~_ ~~~~ri~:inn 1. Operations Abandon Repair Well Plug Perforations ~ Stimulate Oth ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ n 8 Waiver^ Time ExtenHHsion Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development ~ Exploratory^ 205-106 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20553-00-00 7. KB Elevation (ft): 9. Well Name and Number: 41' ' Canne Loo Unit #10 8. Property Designation: 10. Field/Pool(s): ADL 02397 Cannery Loop Unit / Beluga Pool 11. Present Well Condition Summary: Total Depth measured 8,450' ~ feet Plugs (measured) 0 true vertical $,Op2' , feet Junk (measured) 8,292' Effective Depth measured 8,339' feet true vertical 7,gg1' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 103' 20" 123' 123' 3060 psi 1,500 psi Surface 1,932' 13-3/8" 1,953' 1,866' 3,450 psi 1,950 psi Intermediate 5,368' 9-5/8" 5,389' 4,962' 5,750 psi 3,090 psi Production 0 0 0 0 0 0 Liner 8,377' 3-1/2" 8,398' 7,971' 10,160 psi 10,530 psi Perforation depth: Measured depth: 5,880' - 8,275' True Vertical depth: 5,432' - 7,827' Tubing: (size, grade, and measured depth) NA NA NA Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured); 5,713' - 5,723' 5,674' - 5,684' Treatment descriptions including volumes used and final pressure: Cement squeezed top two perforation intervals with 6 bbls of 15.8 ppg cement 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 415 40 0 Subsequent to operation: 0 0 0 40 288 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development 0 Service ^ Daily Report of Well Operations X 16. 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: 305-356 Contact Kevin Skiba (907) 283-1371 Printed Name Dennis M. Donovan Title Production Engineer Signature Phone (907) 283-1333 Date January 11, 2008 Form 10-404 Revised 04/2006 ~ ~~ ~°` ~~~~ ~' ~ 'Z~~~ ~\'a~ Submit Original Only 50-133-20553-00-00 ADL 02397 n: 41' (21' AGL) 60° 31' 56.84" N e: 151 ° 15' 48.37" W Drive Pipe 20" K-55 133 ppf Top Bottom M D 0' 123' TVD 0' 123' 13-318" L-80 68 ppf BTC Top Bottom MD 0' 1,953' TVD 0' 1,866' 18" hole Cmt w/ 608 sks (246 bbl) of 12.0 ppg, Type 1 Canne Loo 10 • Pad 1 273' FSL, 520' FEL, Sec. 7, T5N, R11W, S.M. TD - 8,450' MD 8,002' TVD 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,389' TVD 0' 4,962' 12.25" hole Cmt w/ 75 bbls of 12.5 ppg, class G Lead 8 45 bbls of 15.8 ppg, class G tail 3-1/2" L-80 9.3 ppf EUE 8rd wl 8.25" OD control line protectors Top Bottom MD 0' 8,398' TVD 0' 7,971' 8.5" hole Cmt wl 1,324 sks of 15.8 ppg, class G • 12 Excape modules placed • Green control line fired module 1 • control line fired modules 2 thru 8 • Red contol line fired modules 9 thru 12 • Ceramic flapper valves below each module except for module 1 'Squeezed 12/11/07 'Squeezed 12/11/07 Module 10 - 5,880' - 5,890' Module 9 - 6,956' - 6,966' Module 8 - 7,030' - 7,040' Module 7 - 7,083' - 7,093' Module 6 - 7,174' - 7,184' Module 5 - 7,716' - 7,726' Module 4 - 7,965' - 7,975' Module 3 - 8,098' - 8,108' Module 2 - 8,219' - 8,229' Module 1 - 8,265' - 8,275' Well Name & Number: CLU - 10 Lease: Cannery Loop Unit County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 5,880' - 8,275' (TVD): 5,432' - 7,827' Angle @ KOP and Depth: - 3° / 100 ft @ 750' MD Angle/Perfs: BHP: BHT: Completion Fluid: 6% KCL Dated Completed: 8131/2005 Prepared by: Kevin Skiba Last Revison Date: 1/11/2008 • { Marathon Oil Company Page 4 of 27 Operations Summary. Report Legal Well Name: CANNERY LOOP UNIT 10 . Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: t3/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: Date From - To Hours Code Code Phase Description of Operations 9/23/2005 07:30 - 07:45 0.25 SAFETY MTG_ PRDTST Sign in at office, discuss work, issue work permit 07:45 - 08:00 0.25 SAFETY MTG_ PRDTST Hold location safety meeting, fill out JSA. 08:00 - 09:00 1.00 RURD_ SLIK PRDTST RU Stickline. 09:00 - 10:00 1.00 TAG_ BOTM PRDTST PU 20' 1-11/16" dummy gun. Run to 8346' KB. 10:00 - 11:00 1.00 WAITON EOIP PRDTST Stand by for Protechnics equipment. 11:00 - 15:30 4.50 LOG_ CSG_ PRDTST RIH w/ corelab logging tool to 5500' KB. Log to 8300'KB making three passes at 60fpm, 90fpm, and 120fpm. 15:30 - RURD_ SLIK PRDTST RD slickline and spot equipment on CLU 9. 10/24/2005 08:00 - 08:30 0.50 SAFETY MTG_ PLUGAB Arrive at gas field, hold safety meeting, issue work permit. 11 perforations and water flow. Wellbore must be able to drive 2.82". Printed: 1/10/2008 5:08:47 PM • Page 5 of 27 Operations Summary Report Legal We11 Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code i Code Phase Description of Operations 10/24/2005 08:30 - 10:30 2.00 RURD_ ELEC PLUGAB 10:30 - 11:15 0.75 PULD_ BHA_ PLUGAB 11:15 - 13:30 2.25 TAG_ BOTM PLUGAB Marathon Oil Company 13:30 - 15:00 1.50 TAG_ BOTM PLUGAB 15:00 - 16:30 1.50 TAG_ BOTM PLUGAB 16:30 - 17:45 1.25 TAG BOTM PLUGAB 17:45 - 19:00 1.25 RURD_ ELEC PLUGAB 10!25!2005 08:00 - 08:20 0.33 SAFETY MTG_ PLUGAB 08:20 - 09:45 1.42 RURD_ SLIK PLUGAB 09:45 - 11:15 1.50 BROAC TBG_ PLUGAB 11:15 - 13:30 2.25 BROAC TBG PLUGAB 13:30 - 13:45 0.25 PULD_ BHA_ PLUGAB 13:45 - 17:00 3.25 BROAC CSG_ PLUGAB 17:00 - 18:00 1.00 RURD_ SLIK PLUGAB 10/26/2005 08:00 - 09:00 1.00 SAFETY MTG_ PLUGAB 09:00 - 11:30 2.50 RURD_ ELEC PLUGAB 11:30 - 11:45 0.25 PULD PKR PLUGAB 11:45 - 13:30 I 1.751 RUNPULI ELEC I PLUGAB 13:30 - 14:00 0.50 PULD_ BHA_ PLUGAB 14:00 - 15:00 1.00 RURD_ ELEC PLUGAB 11/4/2005 07:00 - 10:00 3.00 RURD SLIK PLUGAB 10:00 - 11:00 1.00 PULD BHA_ PLUGAB 11:00 - 11:20 0.33 RUNPU SLIK PLUGAB 11:20 - 12:00 0.67 BROAC CSG PLUGAB 12:00 - 13:40 1.67 BROAC CSG_ PLUGAB 13:40 - 15:00 1.33 BROAC CSG_ PLUGAB 15:00 - 15:30 0.50 BROAC CSG_ PLUGAB 15:30 - 17:00 1.50 BROAC CSG PLUGAB 17:00 - 17:50 0.83 RURD_ SLIK PLUGAB 17:50 - 18:45 0.92 RURD_ SLIK PLUGAB 11/12/2005 08:00 - 08:15 0.25 SAFETY MTG_ PLUGAB 08:15 - 08:30 0.25 SAFETY MTG_ PLUGAB 08:30 - 10:30 2.00 RURD_ SLIK PLUGAB 10:30 - 11:30 1.00 TEST_ BOPE PLUGAB 11:30 - 12:15 0.75 DRIFT_ TBG_ PLUGAB 12:15 - 14:00 1.75 WAITON EOIP PLUGAB RU eline unit through wellhouse dbl doors w/ BOPs above house. PU a-line string including CCL and 2.87" gauge cutter Tag at top module w/ occasional sticking. Work tools, but unable to pass. Correlate depth to top pert in top module at 5674'. POOH w/ large indentation in side of gauge cutter. PU 2.80" GC. Run and work, unable to get through top pert. POOH. PU 2.74" GC. Work cutter, unable to work through top pert. POOH. PU 2.65" GC. Able to work throuah too oerf at 5674'. Did not hang up through remainder of top module perfs. Taq at 5712', top pert of next module. nable to work through. POOH w/damage GC. Have production bring well back on. RD E-line unit. Call out slickline to run broach. Arrive at gas field, sign in and obtain work permit. RU slickline unit RIH w/ 2.77" swage to 5674' KB. Work tools for 1 hour w/ no luck. Run 2.72" swage to 5674' KB, work 40 min. Fall through to 5713' KB and work tools 30 min. Tighten tool string. RIH w/ 2.72" swage to 5713' KB. Work for 35 min. Fall to 5880'. Work for 45 minutes, fall to 7174' KB. Work for 40 min. Fall to 7716' KB. Work 45 min. unable to pass. RD slickline unit. Arrive at gas field. Hold safety meeting. Issue work permit. RU electric line. MU 20' special clearance patch. Hold safety meeting and arm firing head. RIH w/ patch. Set down in top module. Pick up and retry w/ no success. POOH w/o attempting to set. Hold safety meeting and lay down patch, disarm firing head. RD E-line unit. MI RU wire line unit. Held PJSM and discussed procedure. Shut in well prior to running in well. MU 1 3/4" tool string with 15' stem, KJ, 1 3/4" oil jars, 1 3/4" long spangs, 2.78" swedge. PT lub with WHP = 1800 psig. RIH tagged up at 5683' KBD. Tried to work through, POOH with tools MU 2.735" spiral swedge (ribbed), RIH swedge down to 5731' KBD. Worked down to 5820' KBD. Some resistance through module #11, POOH MU 2.785" spiral wound tappered swedge, RIH to 6=5683' KBD. Work tools for 25 minutes, made 2', POOH MU 2.835" pineapple broach, RIH to 5683' KBD, worked 1', POOH OOH checked broach, add 5' stem and 2.785" swedge RIH to 5687' work tools for 45 minutes, Broke through to 5692' KBD, continue to work tools down to 5689' KBD, POOH OOH with tools, RD unit. Production put well back on line. Wireline left lease. Sign in at gas field, hold safety meeting, issue work permit. Hold location safety meeting, fill out JSA. RU slickline unit and crane through wellhouse. Shut in well, pressure test lubricator. RIH w/ 2.74" broach to drift tubing to 5740'. PU 3" F-collar stop. Unable to get through tree, break springs. Wait on replacement springs. Printed: 1/10/2008 5:08:47 PM • e Marathon Oil Company Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: ORIG-NAL COMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours ~ Code Code Phase Start: 8/17/2005 Rig Release: Rig Number: 1 Page 6 of 27 Spud Date: 7/23/2005 End: 1 /22/2006 Group: Description of Operations 11/12/2005 14:00 - 15:00 1.00 RUNPU SLIK PLUGAB RIH w/ 3" F-collar sto .Locate and set in to collar of 3' u at 5723'. Shear off and POOH. 15:00 - 16:00 1.00 RUNPU SLIK PLUGAB RIH w/ 3.5" GS and first half of patch (13' tool string) to 5714'. Set and shear off. POOH. 16:00 - 17:00 1.00 RUNPUL SLIK PLUGAB RIH half of catch (12.54') to 5702'. Install 17:00 - 17:45 ~ 0.75 ~ SETREL ~ TOOL ~ PLUGAB ~ RIH w/ 3.5" GS and G-stop. Set at 5701' and POOH. 17:45 - 18:30 0.75 RURD_ SLIK PLUGAB RD wireline truck and return well to production. 12/9/2005 08:00 - 09:00 1.00 SAFETY MTG_ PLUGAB MIRU PWS. Held PJSM and discussed procedure on well. Discussed potential safety issues around the well head. 09:00 - 09:15 0.25 PULD_ LOG_ PLUGAB MU 1.25" tool string with quick temp/ pressure gauges. WHP= 900 psig, 8.080 MCFPD and 336 BPD H2O. 09:15 - 10:40 1.42 TEST_ BOPE PLUGAB PU lubricator, PT lubricator with WHP of 900 psig. RIH with tool string at 60 FPM.. 10:40 - 12:00 1.33 LOG_ CSG_ PLUGAB Gauges at 5500' (above module 12) hold 3 minutes, RIH at 30 FPM to 5700', stop for 3 minutes top of patch. 12:00 - 12:30 0.50 LOG_ CSG_ PLUGAB RIH through patch to 5750' stop for 3 minutes, continue down hole to 5850' hold for 3 minutes, sat down at 5887' work gauges up and down. PUH at 30 FPM to 5500' 12:30 - 13:05 0.58 LOG_ CSG_ PLUGAB Stop for 3 minutes, POOH at 60 FPM. No problems dropping through and pulling through patch with tool strings. 13:05 - 14:30 1.42 PULD_ LOG_ PLUGAB OOH with gauges, check to verify data, good pressure data. 14:30 - 16:00 1.50 REPAIR EOIP PLUGAB MU 1.32" swedge to tag fill. Lay down the lubricator to fix the packoff. Had to wait for pack off from town. 16:00 - 16:45 0.75 REPAIR EOIP PLUGAB Pack off repaired PU tool 1.25" tool string, with spangs jars, oils and swedge. 16:45 - 17:30 0.75 TAG_ BOTM PLUGAB RIH tagged up at top of the #10 module at 5795' KBD, POOH with tools. 17:30 - 18:30 1.00 SECUR WELL PLUGAB Lay down lubricator and secured well. PWS left lease. 12/11/2005 07:30 - 09:00 1.50 SAFETY MTG_ PLUGAB MIRU PWS. Held PJSM and discussed procedure on well. Discussed potential safety issues around the well head. 09:00 - 09:15 0.25 PULD_ EOIP PLUGAB MU 1.75" tool string with 3.5" GS pulling tool. WHP= 900 psig, 7, 999 MCFPD and 380 BPD H2O. Sht well in. 09:15 - 09:45 0.50 TEST_ BOPE PLUGAB PU lubricator, PT lubricator with WHP of 1350 psig. RIH with GS 09:45 - 10:00 0.25 RUNPU EOIP PLUGAB Locate top of "G" stop, work tool. POOH 10:00 - 10:40 0.67 RUNPU EOIP PLUGAB OOH with GS, blow down lubricator, retrieved the "G" stop, Re-pin the GS. PU tool string, open up well. 10:40 - 12:00 1.33 RUNPU EOIP PLUGAB RIH with 3.5" GS to pull top spacer pipe at 5709' KB. Work tools POOH. 12:00 - 14:00 2.00 PUMP_ TRET PLUGAB When wire ine at 3200' wire frozen off at packoff. Start injecting methanol after closing the wire line valve. Wire came free. Continue POOH 14:00 - 14:30 0.50 RUNPU EOIP PLUGAB OOH with upper spacer pipe. Redress the GS pulling tool. 14:30 - 16:30 2.00 RUNPU EOIP PLUGAB RIH to 5717' KBm latch lower spacer pipe. Work tools string for 1 hr before lower pack off released. POOH 16:30 - 16:45 0.25 RUNPU EOIP PLUGAB OOH with the lower spacer pipe and packoff. The lower packoff seal was missing. There was sand in the tools and around the seal profile. 16:45 - 17:15 0.50 RUNPU EOIP PLUGAB MU 2.75" GR, PU tools, RIH to 5707' KB, POOH 17:15 - 18:00 0.75 BROAC CSG_ PLUGAB RIH with 2.35" swedge tag up at 5729' KB. Top of "F" stop. POOH 18:00 - 19:00 1.00 SECUR WELL PLUGAB OOH secured well, lay down wireline equipment for night. PWS left lease Printed: 1/10/2008 5:08:47 PM • Marathon Oil Company Page 7 of 27 Operations Summary: Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase I Description of Operations 12/11/2005 18:00 - 19:00 1.00 SECUR WELL PLUGAB Requested the well flow over night to clean up the well bore. 12/12/2005 07:30 - 09:00 1.50 PLUGAB MIRU PWS. Held PJSM and discussed procedure on well. Discussed potential safety issues around the well head. 09:00 - 09:15 0.25 PLUGAB MU 1.75" tool string with 2.73" swedge. Open well up to lubricator. 09:15 - 09:30 0.25 PLUGAB PT lubricator with WHP of 1350 psig. RIH with swedge down to 5711' KB setting down at perforations. Work swedge through several times. clear perf debris POOH. 09:30 - 10:00 0.50 PLUGAB OOH, MU spacer pipe with bottom "F" stop, RIH slowly. Sat down at the same spot as swedge at 5711' KB, work spacer easy, unable to get down with spacer, POOH 10:00 - 10:40 0.67 PLUGAB OOH with spacer and "F" stop, MU 2.74" pineapple broach, Open well. 11:45 - 12:30 0.75 PLUGAB RIH with 2.74" broach. Sat down at 5685' KB, work tool string several times accross tight spots. POOH 12:30 - 13:00 0.50 PLUGAB OOH with broach, MU GS with lower packoff with spacer. 13:00 - 14:00 1.00 PLUGAB RIH to 5728' KB, Work pack off several time to set stop, Set POOH 14:00 - 14:30 0.50 PLUGAB OOH with GS, Re pin GS, MU middle spacer, RIH to 5714' KB, Work tool string, sheared pin, POOH 15:00 - 15:20 0.33 PLUGAB OOH with GS, MU top pack off with 11' spacer pipe. 15:20 - 15:30 0.17 PLUGAB RIH to top of middle spacer at 5702' KB, work tool string, sheared GS, POOH 15:30 - 15:45 0.25 PLUGAB OOH with GS, Re pin GS, MU upper pack off 15:45 - 16:30 0.75 PLUGAB RIH to top of spacer pipe with upper "G" stop @ 5690' KB, work tool string set packoff, POOH 16:30 - 16:45 0.25 PLUGAB OOH with tool string, verified "G" stop set. Rig down wire line unit. Open well up to production. WHP= 1420 psig 16:45 - 17:30 0.75 PLUGAB PWS rigged down well secured. 1/9/2006 112:00 - 13:00 I 1.00 13:00 - 13:45 0.75 13:45 - 13:50 0.08 13:50 - 14:20 0.50 14:20 - 15:40 1.33 15:40 - 17:00 1.33 17:00 - 18:00 1.00 1/10/2006 12:00 - 13:00 1.00 13:00 - 13:45 I 0.75 13:45 - 14:00 I 0.25 14:30 - 14:40 I 0.17 14:40 - 15:40 1.00 15:40 - 16:00 0.33 16:00 - 16:30 0.50 Patch set at 5712' - 5,_ 6 1~IIFtU w eTine unit. Held PJSM and discussed wireline operation with wire line crew and operations. Well head flowing pressure @ 815 psig, 7140 MCF. PT with WHP, no leadks shut well in Prior to opening up well for running plug. MU 2.83" Daniels packoff with cone bottom on 1 3/4" tool string with 10' stem, oil and spang jars. Shut in well open swab valve. RIH set plug at 5692' KBD above "F" stop. Work tool string, sheared GS, POOH. OOH with GS, MU "A" stop. RIH sat down at 5692' KBD. Work "A" stop sheared pin, POOH. OOH with GS, RD wire line unit. PWS left lease. MIRU wireline unit. Held PJSM and discussed wireline operation with wire line crew and operations. SIWHP= 1050 psig PT with WHP, no leaks shut well in Prior to opening up well for pulling plug. MU 2.5" GS, RIH to pull "A" stop. Sat down 12" high, @ 5680' ELM, work GS could not latch "A" stop, POOH Re-pin GS with steel pin, RIH sat down @ 5680' WLKB. POOH with GS. OOH with GS, MU 1 3/4" drive down bailer, RIH Sat down at 5680' WKB, work tool sting, POOH OOH with DD bailer, sample had water cup of beach sand. RIH with DD bailer. Printed: 1/10/2008 5:08:47 PM • C Marathon Oil Company Page 8 of 27 Operations .Summary Report Legal WeN Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase j Description of Operations 1/10/2006 16:30 - 17:00 0.50 Lost 3' of depth, sat down at 5683' WKB, work DD, POOH, Made 3 more runs working DD in and out of hole. 17:00 - 17:30 0.50 OOH with bailer, sand with water. MU 2.5" hydrostatic bailer, RIH to top of fill. Work tool string, Made 3' hole, down to 5681' WKB. POOH 17:30 - 17:45 0.25 Setup light plant, light plant through belt, called for new one. OOH with DD bailer 17:45 - 17:50 0.08 Blew down lubricator, layed down equipment for night. 17:50 - 18:30 0.67 Secured well, PWS left lease. Note: Sand top at 5681' WKB, well shut in over night. 1/11/2006 05:30 - 06:30 1.00 MIRU wireline unit. Held PJSM and discussed wireline operation with wire line crew and operations. SIWHP= 1150 psig 06:30 - 07:10 0.67 PT with WHP, no leaks shut well in Prior to opening up well. 07:10 - 08:00 0.83 MU 2.5" DD bailer, RIH to top of fill. 08:00 - 08:30 0.50 Sat down @ 5680' WKB, Work tool sting, POOH with DD bailer. 08:30 - 09:00 0.50 MU 1 3/4" drive down bailer, 09:00 - 10:00 1.00 Sat down at 5680' WKB, work tool sting, POOH 10:00 - 14:30 4.50 OOH, MU 2.5" pump bailers, made total of 14 runs working bailers down to 5686' WKB. Had three runs with no sand. 14:30 - 15:10 0.67 MU GS, RIH tagged at 5686' WKB, tired to latch "A" stop, could not latch POOH 15:10 - 15:30 0.33 OOH with GS, MU 2" DD bailer, RIH sat down at 5686' WKB, work bailer, POOH 15:30 - 16:30 1.00 OOH with DD bailer, 2 cups sand with water. Continue to RIH with bailer working at same spot. Made 3 more runs with 2" DD bailer. 18:30 - 18:45 0.25 OOH with bailer, Blew down lubricator, layed equipment down for night. 18:45 - 19:30 0.75 Secured well, PWS left {ease. Note: Sand top at 5686' WKB, well shut in over night. 1/12/2006 06:30 - 06:45 0.25 Held PJSM and discussed procedure with wire line crew. 06:45 - 08:00 1.25 RU 1 3/4" tool string with 2 1/4" DD bailer. PTwith WHP, WHP= 1040 psig. 08:00 - 08:40 0.67 RIH to 5687' WKB work tool sting to 5689' WLM, POOH with 1/2 cup sand. 08:40 - 09:15 0.58 RIH with 2 1/4" hydrostatic bailer to 5689' WKM. work tools, POOH, OOH with 2 cups sand. 09:15 - 10:00 0.75 MU DD bailer, RIH to with 2 1/4" DD bailer to 5689' WKB, POOH with 1/2 cup sand metal marks on bottom of bailer. 10:00 - 11:00 1.00 MU GS, RIH to 5689' WKB, latched up on "A" stop, POOH 11:00 - 12:00 1.00 OOH with "A" stop, RIH with GS to pull plug, sat down at 5690' WKB, could not latch up on plug, POOH 12:00 - 12:40 0.67 00)H with GS, MU 2 1/4" Hydrostaitc bailer, RIH to to 5690' WKB, work bailer, POOH 12:40 - 13:30 0.83 OOH with bailer, full of sand, MU GS, RIH to 5691' WKB, tired to latch up on plug, could not locate, POOH with GS 13:30 - 16:30 3.00 MU 2 1/4" Hydrostatic bailer to 5691' WKB, work tool string, Bailer stuck, work tool sting, set jars off several times, work spangs try to spang out HYD. bailer. Brought wrire cutters out from shop. 16:30 - 17:30 1.00 Bled off well head pressure by 400 psig, hydrostatic bailer released, POOH with bailer. MU GS RiH to 5692' WKB to latch plug, no luck, POOH 17:30 - 18:00 0.50 Lay down wire line unit for night. 18:00 - 18:30 0.50 Secured well, PWS left lease Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 9 of 27 Qperations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Sub ~ D t ~ Fro T I H I a a e m - o ours .Code Ph se Description of Operations Code 1/13/2006 07:00 - 08:00 1.00 Held PJSM and discussed procedure with wire line crew. 08:00 - 08:30 0.50 RU 1 3/4" tool string with 2 1/4" DD bailer. PTwith WHP, WHP= 660 psig. 08:00 - 09:20 1.33 RIH to 5690' WKB work tool sting to 5692' WKB, POOH with 1/2 cup sand and water. 09:20 - 10:00 0.67 RIH with 2 1!4" hydrostatic bailer to 5692' WKM. work tools, POOH, OOH with 2 cups sand. Metal marks on bottom of bailer. 10:00 - 10:45 0.75 MU GS, RIH to 5692' WKB, work GS would not latch plug. POOH 10:45 - 11:30 0.75 MU 2 1/4" hydrostatic bailer to 5692' WKB, work tool string, pooh, OOH with bailer some sand and water. 11:30 - 12:15 0.75 Re-pim tool, RIH to 5692' WKB, work bailer, POOH, OOH no sand or water 12:15 - 13:00 0.75 MU 1 1/4" DD bailer, RIH to to 5693' WKB, work bailer, POOH, full of sand and metal marks on bottom of bailer. 13:00 - 13:40 0.67 MU GS, RIH to 5692' WKB, tired to latch up on plug, could not locate, POOH with GS 13:40 - 14:30 0.83 MU 2 1/4" DD bailer to 5691' WKB, work tool string, POOH, OOH some sand and water. 14:30 - 15:15 0.75 RIH with 2 1/4" DD bailer to 5691' WKB, work tool string, POOH, OOH bailer empty. latch broke. 15:15 - 16:00 0.75 MU 2 1/4" hydrostatic bailer, RIH to 5692' WKB, work tool string, pooh, OOH empty bailer. 16:00 - 17:00 1.00 RIH with GS to 5692' WKB, work could not latch plug, POOH 17:00 - 17:50 0.83 MU 2 1/2" pump down bailer, RIH to 5692' WKB, work tools, POOH, OOH small piece of metal held open flapper, no liquids or sand. 17:50 - 18:45 0.92 MU gs with K-joint above GS, RIH to 5692' WKB, work tools, could not latch up on plug. POOH 18:45 - 20:00 1.25 OOH, secured well, lay down equipment for night. Note: no progess retrieving the DK plug 1/14/2006 07:00 - 07:30 0.50 Held PJSM and discussed procedure with wire line crew. 07:30 - 09:00 1.50 Work on starting unit and boom truck 09:00 - 09:20 0.33 MU 2.25" DD bailer, PT with WHP, RIH to 5692' WKB work tool sting, POOH with 112 cup sand and water. 09:20 - 11:00 1.67 RIH with same bailer to 5692' WKM. work tools, POOH, OOH with 2 cups sand. Metal marks on bottom of bailer. 11:00 - 11:40 0.67 MU 2 1/4" hydrostatic bailer to 5692' WKB, work tool string, pooh, OOH with bailer 2 cups of sand and water. 11:40 - 12:15 0.58 MU 2 1/4" hydrostatic bailer to 5692' WKB, work tool string, pooh, OOH with bailer some sand and water. 11:30 - 12:15 0.75 MU GS, RIH to 5692' WKB, tired to latch up on plug, could not locate, POOH with GS 12:15 - 12:50 0.58 MU 2 1/4" hydrostatic bailer to 5692' WKB, work tool string, pooh, OOH with bailer 2 cups of sand and water. 12:50 - 13:20 0.50 RIH with same bailer to 5692' WKM. work tools, POOH, OOH with 2 cups sand. 13:20 - 14:10 0.83 RIH with same bailer to 5692' WKM. work tools, POOH, OOH, no sand. Metal marks on bottom of bailer. 14:10 - 16:30 2.33 MU GS, Pressured up on lubricator with High pressure gas, RIH to 5692' WKB, tired to latch up on plug, latched plug. Worked tool sting for several hours. Attempt to jar out a pfTi ` uTg: ~- 16:30 - 17:50 1.33 Not much movement on plug. Bled off 250- 300 psig, well down to 320 psig to try and free up plug, did not move plug. Lost Spang jars, still Printed: 1/10/2008 5:08:47 PM • • Marathon Oif Company Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Page 10 of 27 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Cod Phase Description of Operations 1/14/2006 16:30 - 17:50 1.33 had oil jars. Tried to work the tool string out of bind. Lost oil jars. Well dropping sand in on tool string. Pull 1700 Ibs on wire. 17:50 - 18:30 0.67 Put pressure back on well, pressure back up to 590 psig, after hour was able to gel the oil jars back no spangs and plug would not move. Cannot shear off of the plug with out Spang jars. 18:30 - 23:59 5.48 Decided to hold bind on wire over night before dropping cutter bar. PWS crew left for night one person monitored the well till midnight. No change on well. 1/15/2006 00:01 - 07:00 6.98 PWS night personnel held tension on wire during the night. No change in well status. WHP= 580 psig. Held PJSM and discussed procedure with wire line crew. 07:00 - 08:45 1.75 Tried to move tool sting, no luck, good oil jars but have lost spangs, cannot shear down to get off GS. Decide to drop cutter bar. 08:45 - 09:10 0.42 Shut in the wire line Valve against the .125" wire. Blew down the lubricator, MU cutter bar to line. Stab on lubricator. PJSM before dropping cutter. 09:10 - 09:20 0.17 Opened up the wireline valve, dropped cutter, wire cut. POOH with wire. 09:20 - 09:45 0.42 with wire, secured well, lay down the lubricator to pull 100' wire off of unit, retie rope socket, MU tool stiringwith a 2.5" SB. RIH to 5668' WKB 09:45 - 10:40 0.92 Latch cutter bar, POOH, OOH with cutter bar, lay down unit, RD 10:40 - 12:00 1.33 PWS RD unit and left lease. Mark on bottom of the cutter bar indicates good fishing neck on tool string rope socket. Tool stting is 27.5' long with a 1.5" fishing neck looking up. 1/17/2006 01:00 - 08:00 7.00 MI spot BJ coil unit, spot crane, lay out flow back iron and lay out liners. 1/18/2006 06:00 - 12:00 6.00 Secured work permit, held PJSM and discussed safey issues around the wellhead. Continued to rig up the coil unit, finish laying out lines, pull well house. MU BOP to tree. 12:00 - 12:30 0.50 Load coil with 50/50 Methanol, 29 BBLS. Shell test, low 300 psig, high 4300 psig. No leaks, open up line to bled down pressure to tank. 12:30 - 15:00 2.50 BOP test, low 300 psig, high 4000 psig. Blinds rams, tubing rams at same pressure. Blew down pressure on coil. PU 8 ea., 6" lubracator sections and make up below injector head. 15:00 - 17:00 2.00 Total 61' Lubricator, lowered the 1 3/4" coil, cut coil to MU coil tubing connection. Made pull test to 15, 000 Ibs, drained, MU the baker fishing tool string to end of coil. 17:00 - 17:45 0.75 Baker tool string consist of CT connection, dual back pressure valve, XO, Bowen accelerator jar, XO, 2 ea. weight bars, UP/down jars, Hyd disconnect, Hyd 3" GS, total length =33.35' 17:45 - 19:30 1.75 Take tool string to well head, cool down N2 to displace the coil to the Methanol tank, problem with N2 hydrolic pump on N2 pumping unit. tired to fix, no luck. 19:30 - 20:30 1.00 BJ arrainged to bring a N2 unit out from shop, should arrive around 2200 hr. 20:30 - 23:59 3.48 Discussed late hour and remaining job procedure. Decided to monitor equipment through night and continue with opening up the well and do the rest of fishing job in AM. Most of crew left lease. 1/19/2006 06:00 - 07:00 1.00 Secured work permit, held PJSM and discussed safey issues around the wellhead. Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Operations Summary Report Page 11 of 27 Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To ~ Hours Code I Code Phase Description of Operations 1/19/2006 07:00 - 07:30 0.50 Cooled down the N2 unit, open flow line to methanol tank, Displaced the 50/50 Methanol in coil to tank. 07:30 - 07:45 0.25 Held 800 psig on coil, open well to coil. RIH with 1 3/4" coil, with Baker tool string consisting of CT connection, dual back pressure valve, XO, Bowen accelerator jar, XO, 2 ea. weight bars, UP/down jars, Hyd disconnect, Hyd 3" GS, total length =33.35' 07:45 - 08:00 0.25 Coil sat down a the companion flange above swab valve. Work coil to try and clear the flange upset. No luck, Blew down the lubracator, open Bowen connection. 08:00 - 08:10 0.17 Baker tool string consist of CT connection, dual back pressure valve, XO, Bowen accelerator jar, XO, 2 ea. weight bars, UP/down jars, Hyd disconnect, Hyd 3" GS, total length =33.35' 08:10 - 08:20 0.17 Take tool string to well head, reconnect Bowen connection. Drop coil below the flange connection. Pressure test lubracator up to 1000 psig. Good test. Open well. 08:20 - 11:10 2.83 RIH with coil to 5665' CTM, sat down could not latch with the JDC. Work coil down to try and latch up on wire line fish. Pull up hole, 2000 Ibs over, tool slipped off. 11:10 - 11:30 0.33 POOH with Coil, OOH. Blow down real, break Bowen connection no fish. Marks on the JDC, indications are from marks that the rope socket may be kocked in tubing. 11:30 - 12:00 0.50 Mu tool string with wash pipe. PU and take coil to well head. PT Bowen connection to 1100 psig, no leaks open well. 12:00 - 13:40 1.67 RIH pumping minimum rate,.5 BPM, increase PIR to 1.5 BPM when coil at 5580', hold coil till returns to tank, returns to tank after 68 bbls pumped. 13:40 - 13:50 0.17 Continue running in hole down to 5693' CTM. Made three up and down passes washing accross tool string. POOH 13:50 - 14:00 0.17 Shut down pump, continue pulling out of hole. 14:00 - 14:30 0.50 OOH with wash pipe. Cool down N2, displace coil to flow back tank. Blow down the lubricator and coil to 0 psig. Break out Bowen connection. 14:30 - 15:35 1.08 Layed down the wash pipe. MU a skirted JDC, to exsisting tool string. PU tool string and connect to well head. 15:35 - 17:00 1.42 Reconnect Bowen, PT lubracator to 1000 psig, no leaks. RiH with Skirted JDC. 17:00 - 17:55 0.92 Continue down to 5673' CTM, Sat down latch up on rope socket. PU 18000 Ibs, set jars off, PU 20000 Ibs set jars, work tools down to -3000 Ibs, re cock jars, PU to 23, 0000 Ibs, set jars. Continue working jars, set off 15 times up. Plug would not move. Tried to shear off by faring down, jars would not work in the down stroke. 17:55 - 18:10 0.25 Start pump, pumping down back side of well, 31 bbls pumped, pull bind on tool string and fish plug would not move. 18:10 - 18:40 0.50 Decide to pump off of the JDC, unable to shear the GS on wireline fish. Pumped 32 bbls to release JDC, tool released, POOH with coil. 18:40 - 19:50 1.17 When coil at at 800', start N2 cool down to displace fluid out of the coil, start pumping N2 down coil. 19:50 - 20:40 0.83 coil at surface, N2 down, blow down N2 to flow back tank, break Bowen connection. 20:40 - 21:40 1.00 PU tool string, drop tools down to change jars pulled excelarator and stem, shorter tool string. PU and move to tree, tools setting down in lubricator. Start laying down lubricator, found lip in top of lubricator section that Printed: 1/10/2008 5:08:47 PM • • Marathon OII Company Page 12 of 27 Operations Summary Report Legal Well Name: CANNER Y LOO P UNIT 10 Common W ell Name: CANNER Y LOO P UNIT 10 Spud Date: 7/23/2005 Event Nam e: ORIGINA L COM PLETI ON Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIE R DRILL ING Rig Release: Group: Rig Name: GLACIE R DRILL ING Rig Number: 1 I' Date From - To Hours Code Code .Phase Description of Operations 1/19/2006 20:40 - 21:40 1.00 tool setting down on preventing tools from dropping out of the lubricator. 21:40 - 22:30 0.83 PU lubricator, stab on to tree. Decided to send everyone home except to people to monitor equipment through the night. Get start in morning. WHP= 0 psig 1/20/2006 07:45 - 08:15 0.50 Secured work permit, held PJSM and discussed safey issues around the wellhead. 08:15 - 08:20 0.08 Disconnect the Bowen tree connection and dropped down the tool string to change out the Baker oil up/down jars. Dropped the accelarator off of the tool string. 08:20 - 09:00 0.67 MU Bowen tree connection. Open back side to lubricator to PT lubricator. Pressure up to 1000 psig, leak at the 5 connection up on lubricator. Tried to adjust postition on the bubricator would not test. 09:00 - 12:05 3.08 Layed down part of the the lubricator, dropped the leaking piece of the lubricator and shortened the lubricator length. PU and reconnect lubricator on well. Pressured up on lubricator to 1000 psig, no leaks. 12:05 - 12:06 0.02 Baker tool string consist of CT connection, dual back pressure valve, XO, XO, Up/down jars, Hyd disconnect, Hyd 3" GS 12:06 - 13:15 1.15 RIH with coil down to 5600 CTM, PU weight = 7500 lbs. 13:15 - 13:50 0.58 Sat down at 5671' CTM, PU coil pulled up to 12000 Ibs to 5673' CTM. PU to 12, 000 Ibs, jar up. RIH stacked up to -2000 Ibs, PU fired jars in the up strock, continued to jar up stacking up to -4000 Ibs to re cock the jars, fired up 10 times with no movement on tool string fish. 13:50 - 15:10 1.33 Continue to work jars, fared down 5 times with no movement on fish, PU to 180001bs, fire jars and stack coil weight at 0 Ibs between jars. Jarred up 20 times. Down 3 more times with no movement on fish. 15:10 - 15:30 0.33 Pipe nearing max pipe stress, Start fluid pumps to release the JDC. 15:30 - 15:35 0.08 Released the tool string, shut down pumps, freeze protect the lines, start N2 down coil @ 500 SCFM, increase to 750 SCFM. 15:35 - 16:00 0.42 Pump N2 with coil at 5651' for 30 minutes, PUH with coil to 4200' CTM. Returns to surface. WHP= 350 psig. Continue up hole with coil. 16:00 - 16:30 0.50 N2 rate at 500 SCFM. Coil at 3600 psig, water rate declined, RIH with coil. 16:30 - 16:50 0.33 Coil down to 4300', WHP= 250 PSIG, 27 BBLS to FB tank, PIP= 1450 psig. 16:50 - 17:00 0.17 Coil at 5650', N2 rate at 750 SCFM, 31 bbls to flow back tank. 17:00 - 17:20 0.33 WHP=370 psig, 50 BBLS to flow back tank. Cut N2 to 500 SCFM. 17:20 - 17:40 0.33 PU hole with coil jetting well while pulling up hole. WHP= 330 psig 17:40 - 17:50 0.17 Coil at 5000', total fluid to tank = 68 BBLs. WHP= 327 psig, N2 at 500 SCFM 17:50 - 18:00 0.17 N2 rate at 500 SCFM, coil at 4000', 80.1 BBLS to flow back tank, WHP still dropping, PIP= 939 psig. Shut down N2. 18:00 - 18:40 0.67 OOH with coil continue to monitor well. WHP= 0 PSIG, total fluid to tank= 84 BBLS to tank. 18:40 - 20:00 1.33 Lay down lubricator and break out Baker fishing tools. Decide to lay down for night let well fill back up with fluid. Secured well. BJ left lease. 1/21/2006 08:00 - 09:00 1.00 Held PJSM, discussed work and secured a work permit. 09:00 - 09:30 0.50 Strapped tanks, 84.1 BBLS in flow back tank. Pressure tested the lubricator to 1000 psig. 09:30 - 10:00 0.50 Open well to RIH with coil, WHP= 0 psig 10:00 - 10:30 0.50 Coil at 2000', started N2 at 500 SCFM. No returns to flow back tank. Printed: 1/10/2008 5:08:47 PM • Marathon Oil Company Page 13 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: ORIGINAL COMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date ~I"From - To ~I Hours Code Sub I phase Code ~l 1 /21 /2006 110:30 - 10:40 I 0.17 10:40 - 11:40 1.00 11:40 - 12:10 0.50 12:10 - 12:30 0.33 12:30 - 13:00 0.50 13:00 - 14:00 1.00 14:00 - 15:00 1.00 15:00 - 16:00 1.00 16:00 - 17:00 1.00 17:00 - 17:30 17:30 - 18:00 18:00 - 18:30 1/22/2006 08:00 - 08:35 i 08:35 - 09:00 09:00 - 10:00 10:00 - 10:16 10:16 - 10:28 10:28 - 11:40 11:40 - 12:10 12:10 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 15:00 0.50 0.50 0.50 0.58 0.42 1.00 0.27 0.20 1.20 0.50 0.83 0.50 0.50 1.00 15:00 - 15:55 15:55 - 16:28 16:28 - 17:15 17:15 - 17:30 17:30 - 18:15 0.92 0.55 0.78 0.25 0.75 Spud Date: 7/23/2005 Start: 8/17/2005 End: 1/22/2006 Rig Release: Group: Rig Number: 1 Description of Operations Coil at 5660' CTM, N2 at 1000 SCFM, cut rate back to 500 SCFM. Good returns to flow back tank. WHP= 4 psig. PU coil 500', RIH to 5660' CTM, continue to Jet well in. FB tank at 109 BBLS. FB tank at 150 bbls, called out vac truck to move fluid to G& I, move coil up 40' and back down while jetting well. Vac truck pulled 70 bbls out of flow back tank, 97 BBLS left in tank. Well making 1.0 bbl minute, 1440 BPD, N2 at 500 SCFM, WHP= 225 psig. Continue jetting in well @ 5610' CTM, N2 rate at 500 SCFM, WHP= 226 psig. PU coil 40 feet while jetting, RIH 40'. Not much change in flow at surface good water returns to flow back tank. N2 at 500 SCFM. Worked coil up to 5500' CT, WHP= 215 psig, Water rate down to 380 BPD. Coil at 5460' CTM, POOH with coil, 88.3 bbls in flow back tank. WHP= 125 psig. Coif at surface, WHP falling down to 0 psig, flow well to flow back tank, no water to tank. Decide to shut down for night. Secure well, shut down equipment. Total water made to flow back = 214 bbls since 1030 am. BJ left lease, will need to move more N2 down from Anchorage. No gas noted in flow back tank. Held PJSM, discussed work and secured a work permit. Strapped tanks, 101 BBLs in flow back tank. Pressure tested the lubricator to 1000 psig. Open well to RIH with coil, WHP= 250 psig, when coil at 1500', start pumping N2 at minium rate of 500 SCFM. PIP increase when coil at 2900' fluid level. Continue in well to 5600' CTM. Coil at 5630' CTM, returns to surface. 28" in tank, 109 BBLS, continue to pump N2 at 500 SCFM. PIP= 1700 psig FB tank at 164 bbls, called out vac truck to move fluid to G& I, 105 bbls H2O in tank after transfer. Continue to pump N2 to unload well, PIP= 1130 psig, WHP= 207 psig, 1400 BPD rate. Well making 1.0 bbl minute, 1440 BPD, N2 at 500 SCFM, CT @ 5600' CTM, WHP= 196 psig, go returns to flow back tank. Continue jetting in well @ 5600' CTM, N2 rate at 500 SCFM, WHP= 189 psig. Water rate down to 864 BPD. PU coil to 5595' CTM, Not much change in flow at surface good water returns to flow back tank. N2 at 500 SCFM. No gas from well. Water rate at 625 BPD. Vac truck hauled 4 loads of water to gas field (280 BBLS). WHP= 204 psig, PIP= 1095 psig, N2 pumped 200, 000 SCF. Continue to pump N2 at 500 SCFM, WHP= 190 psig, Water at 547 BPD rate. CT @ 5595' CTM. WHP= 185 psig, BWPD based on strap is 795 BPD rate. Shut down the N2 to monitor the well with out N2. WHP= 41 psig, PIP= 880 psig, still water to flow back tank, no help from formation. Decide to pull coil out of well and rig down coil. Coil at surface, WHP falling down to 0 psig, flow well to flow back tank, Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 14 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 1/22/2006 17:30 - 18:15 0.75 18:15 - 20:00 1.75 20:00 - 22:30 2.50 2/4/2006 08:00 - 08:30 0.50 SAFETY MTG_ PLUGAB 08:30 - 09:00 0.50 RURD_ SLIK PLUGAB 09:00 - 11:30 2.50 RURD_ OTHR PLUGAB 11:30 - 13:15 1.75 RURD_ SLIK PLUGAB 13:15 - 14:45 1.50 RUNPU SLIK PLUGAB 14:45 - 16:00 1.25 RURD_ SLIK PLUGAB 2/7/2006 08:00 - 08:35 0.58 08:35 - 18:00 9.42 18:00 - 18:30 I 0.50 18:30 - 19:30 1.00 2/8/2006 08:00 - 08:35 0.58 08:35 - 09:30 0.92 09:30 - 11:00 1.50 11:00 - 17:00 6.00 17:00 - 20:00 3.00 20:00 - 20:45 I 0.75 20:45 - 21:45 I 1.00 21:45 - 23:00 1.25 23:00 - 23:59 0.98 00:10 - 00:24 0.23 00:24 - 00:45 I 0.35 00:45 - 01:30 I 0.75 01:30 - 05:30 I 4.00 05:30 - 06:00 I 0.50 12/9/2006 106:00 - 08:00 I 2.00 08:00 - 09:00 I 1.00 no water to tank. Secure well, shut down equipment. Total water made to flow back = 300 bbls since 930 am. 240, 000 N2 pumped. No gas to flow back tank during entire job. BJ left lease. Held PJSM, discussed work and secured a work permit. Spot slickline equipment. Start and RU big crane. RU slickline equipment RIH 2"JDC pulling tool. Hit down 3 times to latch flash. Worked and could not move spang jars on fish. Shear off and POH RD slickline and leave location. Held PJSM, discussed work and secured a work permit. Moved in equipment, ran hard line, set tanks, crane and hung BOP's on well head. Moved 350 BBLs 6% KCL to supply tank, 50/50% Methanol for freeze protecting coil and pressure testing. BJ left lease. Held PJSM, discussed work and secured a work permit. Load back side to PT BOP'S. PT low shell to 400 psig. High side to 4600 psig. Bled off pressure, closed blinds, PT blinds, Blinds would not test. Work on blinds, PT blinds, would not test. Closed rams, PT rams to 450 psig, 4500 psig. Tested Pulled BOPS off of well head. Rebuild Blinds. Take BOP's to well head. Closed blinds, PT low to 600 psig, High to 4500 psig, Test good. Bled down pressure. open blinds, break lubricator, wait on Baker Tool. Tools arrived, MU coil connector to 1 3/4" coil, BHA consist of 2.25 CT connector, 2.125" DCPV, 2.0" XO, 2.0" jar, 2.0" XO, 2ea. 2.125" Wght bar, XO, XO, 2.125" up/down jars, XO, Hyd disc, 2.125" hyd JDC, 2" bell guide. PT coil connector to 3500 psig, test good. PU lubricator and reconnect to well. Pressue up on WHA to low 380 psig, high to 1966 psig. Tested good. Displaced coil with 6% KCL. RIH with coil. Coil at 5000' ctm, pu weight at 14000 lbs. 24 hour coverage Continue running in hole with coil, coil at 5600', PIR= .35 BPM. WHP= 0 psig, PIP= 120 psig. Increased PIR= 1.2 BPM, to load hole and break circulation to surface. Well on vacumn. Circulate bottoms up. H2O to surface, tag top of fish. PU hole 10', shut down pumps, RIH latched fish. PU 10', repeat working jars down 7 times. Start pump at 0.3 BPM. Stop pump, Jar down 25 times. PU hole 10' jared up, RIH to reset jars, PU hole 10' jared up came loose. POOH OOH with tools, block in tree, break out lubricator. No fish. JDC in catch position. Freeze protect coil, nipple up injector. Pump lost prime, lack of 50/50 Methanol tank empty..cool down N2. Displaced coil. Open up well, RIH with coil 1 3/4" coil, BHA consist of 2.25 CT connector, 2.125" DCPV, 2.0" XO, 2.0"jar, 2.0" XO, 2ea. 2.125" Wght bar, XO, XO, 2.125" up/down jars, XO, Hyd disc, 2.125" hyd JDC, 2" Printed: 1/10/2008 5:08:47 PM • ~ Marathon Oil Company Page 15 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23!2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours ~ Code I Phase Description of Operations Code 2/9/2006 08:00 - 09:00 1.00 bell guide. 09:00 - 11:30 2.50 Coil at 5650' CTM, PU weight = 11000 Ibs, tagged fish with JDC. Set down weight -8000 lbs. PU 10' to try and latch fish. Repeat 5 times with no indication that fish would latch, possible broken fish neck. POOH 11:30 - 12:30 1.00 OOH with coil, no fish. Lay aside coil tubing lubricator and secured to crane. Shut blinds on BOP's. 12:30 - 13:00 0.50 RU wire line on well. PWS on location discussed wire line operation with operators. MU LIB to RIH tag flash. On well with lubricator and 1.5" tool string. 2.6" LIB. 13:00 - 13:10 0.17 Weight indicator on wire line unit broke, wait for one from shop. Weight indicator arrived. Repaired, Open well to RIH with wire line. WHP= 0 psig. 13:10 - 13:30 0.33 Wire line tagged up at 5673' KBD. POOH with LIB. OOH with LIB, LIB indicates a good rope socked looking up. 13:30 - 15:30 2.00 MU JDC, RIH to latch up on fish at 5672' KBD. PU gained wait but lost wait, repeat to latch up on fish. POOH with tools string. OOH with JDC retrieved a K-joint and rope so~IsQt. Ball socket on bottom. Should be good fishing neck on tool string. 15:30 - 19:00 3.50 Repin tool string, RIH with JDC, attempted to latch fishing neck on tool string. Good latch, POOH with wire line. RD PWS 19:00 - 19:20 0.33 RD crossover above BOP's to rewnnect the coil lubricator. 19:20 - 22:00 2.67 MU BHA to 1 3/4" coil, BHA consist of 2.25 CT connector, 2.125" DCPV, 2.181" Hyd disconnect, HT accelartor jar, 2.125" Impact drill, 2.181" XO, 2.75" XO, 2.375" X 5.9" Hydrill pup, 18' joint X 2.375" flat bottom wash pipe. 22:00 - 23:00 1.00 PT the WHA to 1050 psig, good. 23:00 - 23:43 0.72 RIH with coil to 5687' CTM, PU weight= 12000 Ibs. Tagged up PU 1', load coil with 6% KCL. Continue after midnight 00:10 - 00:30 0.33 Tag top of fish with wash over pipe & Hydralic jack. PU 4' flag coil. Start pumping water down coil at 1.25 BPM. 00:30 - 00:45 0.25 Work hip tripper for about an hour. Worked down 3', stalled motor. PU hole with coil 10', RIH tagged fish moved fish down hole 3.7' indicated by distance coil traveled. 00:45 - 02:40 1.92 Stopped pumping down coil, POOH with coil. 02:40 - 04:40 2.00 OOH with tools, block in tree, break out lubricator. Freeze protect coil, lay down hip tripper BHA. Cut off coil connector & 60' of coil. MU coil connector. Test connector. PT shell at low 200 psig, 11100 psig. 04:40 - 06:00 1.33 Open up well, RIH with coil 1 3/4" coil, BHA consist of 2.25 CT connector, 2.125" DCPV, 2.0" XO, 2.0" jar, 2.0" XO, 2ea. 2.125" Wght bar, XO, XO, 2.125" up/down jars, XO, Hyd disc, JDC 2/10/2006 06:00 - 06:50 0.83 RIH coil, coil at 5699. Coil tagged up, put -1000 Ibs down. PU coil, Pulled 200 Ibs over. Sat down again. PU pulled Ibs over pull. POOH with coil 06:50 - 07:45 0.92 OOH with coil, shut in bottom master tree. WHP= 0 psig. Break Bowen to check for fish on tool string. ,Fish on tool string. PWS tool string, all of the wire line tools string down to e 07:45 - 09:15 1.50 Crew change held PJSM. Continue with same BHA to retrieve wire line retrievable plug. PT back side of lubricator with 50/50 methanol. Bled down pressure to Methanol tank. Open well head. 09:15 - 10:00 0.75 RIH coil, coil at 5694' CTM. Coil tagged up, put -4000 Ibs down. PU coil, Pulled 1000 Ibs over. Sat down again. PU pulled 1000 Ibs over pull. POOH with coil Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 16 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: ORIGINAL COMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date I From - To I Hours ~ Code Code. Phase 2/10/2006 10:00 - 11:10 I 1.17 11:10 - 12:30 1.33 2/18/2006 09:00 - 10:00 1.00 SAFETY MTG PR1EVL 10:00 - 17:30 7.50 RURD COIL PR1 EVL 17:30 - 18:30 1.00 RURD_ COIL PR1 EVL 2/19/2006 09:00 - 10:00 1.00 SAFETY MTG PR1 EVL 10:00 - 17:30 7.50 RURD COIL PR1 EVL 17:30 - 18:30 1.00 RURD_ COIL PR1 EVL 2/22/2006 09:00 - 10:00 1.00 SAFETY MTG PR1 EVL 10:00 - 12:00 2.00 RURD_ EOIP PR1 EVL 12:00 - 12:30 0.50 RURD_ EOIP PR1 EVL 3/8/2006 08:00 - 10:30 2.50 10:30 - 11:00 0.50 SAFETY MTG_ PR1EVL 13:00 - 15:30 2.50 SAFETY MTG PR1EVL 3/9/2006 08:00 - 09:30 1.50 SAFETY MTG_ PR1EVL 09:30 - 11:00 1.50 RURD_ COIL PR1EVL 11:00 - 12:45 1.75 RURD_ COIL PR1EVL 12:45 - 14:00 1.25 RURD_ COIL PR1EVL 14:00 - 14:30 0.50 RURD_ COIL PR1EVL 3!10/2006 07:00 - 07:45 0.75 SAFETY MTG_ PR1 EVL 07:45 - 10:30 2.75 RURD_ COIL PR1EVL 10:30 - 13:50 3.33 CLEAN LOC PR1 EVL 13:50 - 16:20 2.50 RURD_ COIL PR1EVL 16:20 - 17:15 0.92 TEST_ BOPE PR1 EVL 17:15 - 17:30 0.25 RURD_ COIL PR1 EVL 17:30 - 18:00 0.50 RURD_ COIL PR1 EVL 3/11/2006 07:00 - 07:45 0.75 SAFETY MTG_ PR1 EVL 07:45 - 11:05 3.33 RURD_ COIL PR1 EVL 11:05 - 11:45 0.67 RURD_ COIL PR1 EVL 11:45 - 14:10 2.42 PUMP N2 PR1 EVL 14:10 - 19:00 4.83 PUMP_ N2_ PR1 EVL 19:00 - 19:43 0.72 RUNPU COIL PR1 EVL 19:43 - 20:00 0.28 RURD_ COIL PR1 EVL 20:00 - 20:30 0.50 RURD_ COIL PR1 EVL 3/12/2006 08:00 - 08:45 0.75 SAFETY MTG_ PR1 EVL 08:45 - 10:38 1.88 RURD_ COIL PR1EVL 10:38 - 10:51 0.22 RURD_ COIL PR1EVL 10:51 - 12:12 1.35 PUMP_ N2_ PR1EVL 12:12 - 15:12 3.00 PRIEVL 15:12 - 15:42 0.50 PUMP_ N2_ PR1EVL 15:42 - 16:12 0.50 PUMP N2 PR1EVL Spud Date: 7/23/2005 Start: 8/17/2005 End: 1/22/2006 Rig Release: Group: Rig Number: 1 Description of Operations OOH with coil, Shut well in, break out lubricator to check tool string for plug. Dropped down tool string. Recovered Plug. RD Baker fishing tools out of the lubricator. RD lubricator to get less lubricator hanging below the CT injector. Crane lowered lubricator. Crane boom collapsed, landing between the coil unit and the pump truck. All equipment shut down. Prepare permit and hold safety meeting. Discuss safely rigging down broken crane mast and CT equipment Grease tree and set BPV. Bleed tree to 0 psi. Lay down lubricator onto blocks. Remove choke, iron basket, and manlift from under crane boom. Lay down crane boom on to blocks. Secure location for night and leave. Prepare permit and hold safety meeting. Discuss final rig down of broken crane mast and CT equipment Detached crane boom from crane. Rigged down and moved equipment from location Secure location for night and leave. Prepare permit and hold safety meeting. Discuss possible hazards of pulling BPV Spot Expro crane. Rig up vetco lubricator and pull BPV. RD Crane. Secure location and leave. Deliver equipment to cannery loop. Prepare permit and hold safety meeting. Meet at KGF office and discuss new JSA. Agree on forward safety plan. Prepare permit and hold safety meeting. Spot containment and move well house. RU pump and flowback iron. Vent tree and RU BOP. Secure location and leave. Prepare permit and hold safety meeting. Finish spotting equipment and start RU. Ran displacement tak on pump over. Spilled and cleaned up 10 gal 50/50 McOH. Continue rigging up CTU, pump, and N2 unit. Test Blinds and Pipes 200 / 4000 psi. Stes stripper 200. / 2000 psi. Remove injector head from tree. Secure location and leave. Prepare permit and hold safety meeting. Start equipment and stab injector on wellhead. Start N2 cooldown. Shell test BOP to 2000 psi. Displace McOH back to tank with N2. RIH jetting with N2 to 5650' (just above patch). Recovered 30 Bbls while RIH. Well open to tank. Jet well at 5650'. 175 Bbls returns. POH CT with well open to tank. Well died. Total returns 200 Bbls. Secure location and leave. Prepare permit and hold safety meeting. Start equipment and stab injector on wellhead. Start N2 cooldown. Shell test BOP to 2000 psi. RIH jetting with N2 to 5650' Qust above patch). Well open to tank. Jet well at 5650'. 163 Bbls returns. Water rate is 1200 BWPD Jet well at 5650'. 22 Bbls returns in 30 min. Water rate is 1060 BWPD Jet well at 5650'. 19 Bbls returns in 30 min. Water rate is 910 BWPD Printed: 1/10/2008 5:08:47 PM • • `Marathon Oil Company Operiatolns Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Page 17 of 27 CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 GLACIER DRILLING Rig Release: Group: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code ~ Code I~'~ Phase 3/12/2006 16:12 - 16:42 0.50 PUMP_ N2_ PR1 EVL 16:42 - 17:45 1.05 PR1 EVL 17:45 - 18:13 0.47 RUNPU COIL PR1EVL 18:13 - 18:23 0.17 RURD_ COIL PR1EVL 18:23 - 18:45 0.37 RURD_ COIL PR1EVL 3/15/2006 05:30 - 06:15 0.75 SAFETY MTG_ PR1 EVL 06:15 - 07:45 1.50 RURD_ COIL PR1EVL 07:45 - 08:45 1.00 RURD_ COIL PR1EVL 08:45 - 10:24 1.65 PUMP N2 PRIEVL 10:24 - 12:04 1.67 PR1 EVL 12:04 - 13:08 1.07 PUMP N2 PR1 EVL 13:08 - 14:12 1.07 PUMP_ N2_ PR1 EVL 14:12 - 15:11 0.98 PUMP_ N2_ PR1 EVL 15:11 - 19:29 4.30 PUMP_ N2_ PR1 EVL 19:29 - 19:40 0.18 RUNPU COIL PR1 EVL 19:40 - 05:00 9.33 RURD_ COIL PR1EVL 05:00 - 06:00 1.00 RURD_ COIL PR1 EVL 3/16/2006 06:00 - 06:30 0.50 SAFETY MTG_ PR1EVL 06:30 - 16:00 9.50 REPAIR EOIP PR1EVL 16:00 - 18:00 2.00 RUNPU COIL PRIEVL 18:00 - 20:00 2.00 RURD_ COIL PR1EVL 3/18/2006 09:00 - 10:30 1.50 10:30 - 10:50 0.33 SAFETY MTG_ PR1EVL 10:50 - 11:30 0.67 RURD_ SLIK PRIEVL 11:30 - 13:00 1.50 RUNPU SLIK PR1EVL 13:00 - 14:00 I 1.001 RUNPUIJ SLIK I PR1 EVL 14:00 - 15:00 1.00 RUNPU SLIK PR1 EVL 15:00 - 15:45 0.75 RUNPU SLIK PR1 EVL 15:45 - 16:30 0.75 RURD_ SLIK PR1 EVL 4/12/2006 07:30 - 08:00 0.50 SAFETY MTG_ PR1 EVL 08:00 - 09:00 1.00 RURD_ SLIK PR1 EVL 09:00 - 10:50 1.83 RUNPU SLIK PR1 EVL 10:50 - 11:30 0.67 RUNPU SLIK PR1 EVL 11:30 - 12:05 0.58 RUNPU SLIK PR1 EVL 12:05 - 12:35 0.50 RUNPU SLIK PR1EVL 12:35 - 13:50 1.25 RUNPU SLIK PR1EVL 13:50 - 15:00 I 1.171 RUNPULJ SLIK I PRIEVL 15:00 - 16:10 I 1.171 RUNPULJ SLIK I PRIEVL 16:10 - 17:30 1.33 RURD_ SLIK PR1 EVL 4/13/2006 08:00 - 08:45 0.75 SAFETY MTG_ PR1 EVL 08:45 - 09:30 0.75 RURD_ SLIK PR1 EVL 09:30 - 10:30 1.00 RUNPU SLIK PR1 EVL 10:50 - 11:15 0.42 RUNPU SLIK PR1 EVL 11:15 - 12:00 0.75 RUNPU SLIK PR1 EVL Description of Operations Jet well at 5650'. 17 Bbls returns in 30 min. Water rate is 810 BWPD Jet well at 5650'. Pull vac truck load from tank. No precise numbers to determine rate. POH CT with well open to tank. Well died. Total returns 280 Bbis. Secure location and leave. Prepare permit and hold safety meeting. Start equipment and stab injector on wellhead. Start N2 cooldown. Blow down well from 1050 psi. Shell test BOP to 1000 psi. RIH jetting with N2 to 5650' (just above patch). Well open to tank. 24 Bbls returns whi-e RIH Jet well at 5650'. 90 Bbls returns. Jet well at 5650'. 175 Bbls returns. Water rate is 2000 BWPD Pull vac truck load. Jet well at 5650'. 31 Bbls returns in 30 min. Water rate is 1490 BWPD Jet well at 5650'. 19 Bbls returns in 30 min. Water rate is 910 BWPD Jet well at 5650'. Rate fairly steady at 800 BWPD. Out of N2 POH CT with well open to tank. Injector head stopped at 5500'. Unable to POH. Well continued flowing water /foam. Total returns is 450 Bbls. Well flowed 40 bbls through the night and died at 5 AM. Continue repairing injector head. Prepare permit and hold safety meeting. Repair CT injector head. POH CT. RD CT and leave location. Move equipment from pad 41-7 to Cannery Loop. Prepare permit and hold safety meeting. RU pollard wireline. RIH 2.75" gauge cutter. Tag top of old patch at 5694' RKB. Fluid level is at 4140'. RIH packoff and lower 10' section of patch. Set from 5694' to 5682'. POH RIH r~,oPr 10' cection of R~trh Set from .56R~' to .FFRQ' POH RIH "G" Stop. Set at 5668'. POH RD SL and leave location. Prepare permit and hold safety meeting. RU Expro wireline. RIH 1.25" swage. Tag fill above upper patch at 5601' RKB. POH RIH 2.125" bailer. Work at 5601' down to 5602'. POH RIH 2.65" LIB to tag fluid level. Tag fluid at 4110'. POH RIH 2.25" pump bailer. Made 2'. POH. Dumped 1 Ot sand. RIH 2.125" drive down bailer. Worked from 5609' SL to 5614' SL. POH. Dumped 1 gal sand. RIH 2.125" drive down bailer. Worked from 5610' SL to 5619' SL. POH. Dumped 1/2 gal sand. RIH 2.125" drive down bailer. Worked from 5610' SL to 5621' SL. POH. Dumped 2 gal sand. Rig back SL for night and leave location. Prepare permit and hold safety meeting. RU Expro wireline. RIH 2.25" drive down bailer. Work from 5612' down to 5614'. POH RIH 2.25" bailer. Work from 5612' down to 5615'. POH RIH 2.75 "Gauge ring to sluff in fill. Tag fill at 5612'. POH Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 18 ~f 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 4/13/2006 12:00 - 13:00 1.00 RUNPU SLIK PR1EVL RIH 2.25" bailer. Worked from 5614' SL to 5619'. POH. Dumped 1 gal sand. 13:00 - 13:50 0.83 RUNPU SLIK PR1EVL RIH 2.125" pump bailer. Worked from 5615' SL to 5621'. POH. Dumped 1.5 gal sand. 13:50 - 14:35 0.75 RUNPU SLIK PR1 EVL RIH 2.125" drive down bailer. Worked from 5619' SL to 5624'. POH. Dumped 2 gal sand. 14:35 - 15:25 0.83 RUNPU SLIK PR1 EVL RIH 2.125" drive down bailer. Worked from 5620' SL to 5624'. POH. Dumped 1 gal sand. 15:25 - 16:00 0.58 RUNPU SLIK PR1 EVL RIH 2.125" drive down bailer. Worked from 5621' SL to 5625'. POH. Dumped 1 gal sand. 16:00 - 16:35 0.58 RUNPU SLIK PR1 EVL RIH 2.125" drive down bailer. Worked from 5621' SL to 5627'. POH. Dumped 2 gal sand. 16:35 - 17:30 0.92 RUNPU SLIK PR1EVL RIH 2.125" drive down bailer. Worked from 5627' SL to 5633'. POH. Dumped 2 gal sand. 17:30 - 17:50 0.33 RURD_ SLIK PR1 EVL Rig back SL for night and leave location. 4/14/2006 07:00 - 07:20 0.33 SAFETY MTG_ PR1 EVL Prepare permit and hold safety meeting. 07:20 - 08:10 0.83 RURD_ SLIK PR1 EVL RU Expro wireline. 08:10 - 09:25 1.25 BAIL_ FILL PR1 EVL RIH 2.125" drive down bailer. Work from 5627' down to 5629'. POH. Recovered 1/2 gal flex sand. 09:25 - 10:20 0.92 BAIL_ FILL PR1 EVL RIH 2.125" drive down bailer. Work from 5627' down to 5629'. POH. Recovered 3/4 gal flex sand. 10:20 - 11:05 0.75 BAIL_ FILL PR1 EVL RIH 1.5" drive down bailer. Work from 5627' down to 5629'. POH. Recovered 2 cups flex sand. 11:05 - 12:05 1.00 BAIL_ FILL PR1EVL RIH 2.125" drive down bailer. Work from 5627' down to 5631'. POH. Recovered 3/4 gal sand. 12:05 - 12:45 0.67 BAIL_ FILL PR1 EVL RIH 2.125" drive down bailer. Work from 5631' down to 5635'. POH. Recovered 3/4 gal sand. 12:45 - 13:30 0.75 BAIL_ FILL PR1 EVL RIH 2.125" drive down bailer. Work from 5635' down to 5640'. POH. Recovered 3/4 gal sand. 13:30 - 14:10 0.67 BAIL_ FILL PR1EVL RIH 2.125" drive down bailer. Work from 5636' down to 5640'. POH. Recovered 3/4 gal sand. 14:10 - 15:00 0.83 BAIL_ FILL PR1EVL RIH 2.125" drive down bailer. Work from 5636' down to 5644'. POH. Recovered 3/4 gal sand. 15:00 - 15:40 0.67 BAIL_ FILL PR1EVL RIH 2.125" drive down bailer. Work from 5638' down to 5644'. POH. Recovered 3/4 gal sand. 15:40 - 16:15 0.58 BAIL_ FILL PR1EVL RIH 2.125" drive down bailer. Work from 5639' down to 5635'. POH. Recovered 3/4 gal sand. 17:30 - 17:50 0.33 RURD_ SLIK PR1EVL Rig down SL and leave location. 4/19/2006 07:00 - 07:20 0.33 SAFETY MTG_ PR1 EVL Prepare permit and hold safety meeting. 07:20 - 10:15 2.92 RURD_ SLIK PR1EVL RU WL. MU 1.5" RS, ks, 10' stem, KJ, OJ, & DD bailer. Ice in tree, round up Methanol to address ice. 10:15 - 11:00 0.75 BAIL_ FILL PR1EVL RIH 1 314" drive down bailer. Work from 5624' down to 5626'. POH. Recovered 0.5 gal mud/ beach sand. 11:00 - 12:00 1.00 BAIL_ FILL PR1EVL MU 2.5" DD bailer, RIH 2.5" drive down bailer. Work from 5625' down to 5627'. POH. Flapper broken. MU ball bottom. 12:00 - 12:45 0.75 BAIL_ FILL PR1 EVL RIH 2.5" drive down bailer. Work from 5625' down to 5627'. POH. Recovered 2 cups mud/sand. 12:45 - 13:30 0.75 BAIL_ FILL PR1 EVL MU 2.0" drive down bailer. Work from 5628' down to 5630'. POH. flapper sheared. No sand or mud. Printed: 1/10/2008 5:08:47 PM • ~ Marathon Oil Company Page 19 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Phase Description of Operations Code 4/19/2006 13:30 - 14:15 0.75 BAIL_ FILL PR1 EVL RIH 2.125" drive down bailer with ball bottom. Work from 5629' down to 5632'. POH. Recovered 31/2 gal sand. 14:15 - 15:00 0.75 BAIL_ FILL PR1EVL RIH 2.125" drive down bailer. Work from 5632' down to 5635'. POH. Recovered 0.5 gal sand. 15:00 - 15:45 0.75 BAIL_ FILL PR1 EVL RIH 2.125" drive down bailer. Work from 5632' down to 5635'. POH. Recovered 0.5 gal sand. 15:45 - 16:30 0.75 RURD_ SLIK PR1 EVL RD for night problem with boom truck starting. PWS moving into shop to replace boom truck for tomorrow. Secured well for night. WHP= 750 psig 4/20/2006 07:00 - 08:20 1.33 SAFETY DRIL SLICK Uptain work permit, held PJSM and spot up boom truck. Boom truck would not start work on truck. 08:20 - 08:30 0.17 RURD_ SLIK SLICK RU WL MU 1 3/4" DD with a ball bottom. Tool string consist of 1 3/4" RS, ks, 10' stem, KJ, OJ, & 1 3/4" DD bailer. 08:30 - 09:30 ~ 1.00 ~ BAIL_ ~ FILL ~ SLICK 09:30 - 10:30 1.00 BAIL_ FILL SLICK 10:30 - 12:00 1.50 BAIL FILL SLICK 12:00 - 13:00 ~ 1.00 ~ BAIL_ ~ FILL ~ SLICK 13:00 - 13:45 0.75 BAIL FILL SLICK 13:45 - 14:30 0.75 BAIL FILL SLICK 14:30 - 16:10 1.67 BAIL FILL SLICK 16:10 - 16:40 0.50 SLICK 15:45 - 16:30 4/21 /2006 08:30 - 09:15 09:15 - 09:30 0.751 RURD I OTHR SLICK 0.75SAFETYDRIL (SLICK 0.251 RURD SLIK SLICK RIH TO 5633' down to 5635'. POH. Recovered 0.25 gal mud/ beach sand. RIH to 5635' down to 5637'. POH. 0.5 gal sand mud. RIH 1 3/4" drive down bailer. Work from 5637' down to 5640'. POH. Recovered 6 cups mud/sand. RIH with drive down bailer. Work from 5639' down to 5641'. 4 cups of sand or mud. RIH w/drive down bailer with ball bottom. Work from 5641' down to 5642'. POH. Recovered 1/2 gal sand. RIH same drive down bailer. Work from 5642' down to 5644'. POH. Rewvered 0.5 gal sand. RIH with same drive down bailer. Work from 5645' down to 5645'. POH. Recovered 0.25 gal sand. MU pump bailer, RIH tagged up on fill at 5648' KBD. work bailer. POOH with bailer. Recovered 2 cups. RD for night problem with pack off leaking. Lay down the lubricator to repack prior to leaving the pad. Secured well for night. WHP= 750 psi Problem with boom truck caused late start on rigging up on well. Uptain work permit, held PJSM and spot up boom truck. RU WL MU 1 3/4" DD with a ball bottom. Tool string consist of 1 3/4" RS, ks, 10' stem, KJ, OJ, & 1 3/4" DD bailer. 09:30 - 10:30 1.00 BAIL_ FILL SLICK RIH TO 5647' down to 5649'. POH. Recovered 0.75 gal mud/ beach sand. 10:30 - 11:15 0.75 BAIL_ FILL SLICK RIH to 5647' down to 5650'. POH. 0.5 gal sand mud. 11:15 - 12:00 0.75 BAIL_ FILL SLICK RIH 1 3/4" drive down bailer. Work from 5648' down to 5650'. POH. Recovered 1 gal mud/sand. 12:00 - 12:45 0.75 BAIL_ FILL SLICK RIH with drive down bailer. Work from 5650' down to 5652'. 4 cups of sand or mud. 12:45 - 13:30 0.75 BAIL_ FILL SLICK Boom problem, lay down lubricator and replace boom truck. 13:30 - 14:00 0.50 BAIL_ FILL SLICK RIH same drive down bailer. Work from 5651' down to 5654'. POH. Recovered 0.5 gal sand. 14:00 - 14:45 0.75 BAIL_ FILL SLICK RIH with same drive down bailer. Work from 5653 'down to 5655'. POH. Recovered 0.5 gal sand. 14:45 - 15:45 1.00 BAIL_ FILL SLICK RIH tagged up on fill at 5655' KBD. Work bailer down to 5657' KBD. Printed: 111012008 5:08:47 PM • • Marathon Oil Company Page 20 of 27' Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: ORIGINAL COMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code Code .:Phase 4/21/2006 14:45 - 15:45 1.00 BAIL_ FILL SLICK 15:45 - 16:30 0.75 BAIL FILL SLICK 16:30 - 17:15 0.75 BAIL FILL SLICK 17:15 - 20:30 3.25 WAITON EQIP SLICK 20:30 - 23:59 3.48 WAITON EQIP SLICK 23:59 - 02:00 2.02 RURD OTHR SLICK ..4/22/2006 10:00 - 10:30 0.501 SAFETY DRIL SLICK 10:30 - 11:00 0.501 RURD SLIK SLICK Spud Date: 7/23/2005 Start: 8/17/2005 End: 1/22/2006 Rig Release: Group: Rig Number: 1 Description of Operations POOH with baiter. Recovered .25 gal mud sand. RIH tagged up on fill at 5656' KBD. Work bailer down to 5657' KBD. POOH with bailer. Recovered .25 gal mud sand. Open well to open top tank, blew down 200 Ibs off of well. RIH tagged up on fill at 5655' KBD. Work bailer down to 5661' KBD. POOH with bailer. Recovered 2 gallons of mud sand. Tried to start the boom truck. Truck would not start. Called out machanic to wrok on truck, Secured well. Worked on truck with no luck. Contiue to work on truck. Truck started, lay down the lubricator. Secured well for night. WHP= 600 psi Uptain work permit, held PJSM. Discussed safe work practices around the well. RU WL MU 1 3/4" DD with a ball bottom. Tool string consist of 1 3/4" RS, ks, 10' stem, KJ, OJ, & 1 3/4" DD bailer. 11:00 - 11:30 0.50 BAIL FILL SLICK 11:30 - 12:30 1.00 BAIL FILL SLICK 12:30 - 13:15 0.75 BAIL FILL SLICK 13:15 - 13:45 0.50 BAIL FILL SLICK 13:45 - 15:30 1.75 BAIL FILL SLICK 15:30 - 16:00 ~ 0.50 ~ BAIL_ ~ FILL ~ SLICK 16:00 - 17:00 I 1.001 BAIL I FILL I SLICK 17:00 - 18:30 1.50 RURD_ SLIK SLICK 18:30 - 19:00 0.50 RURD_ SLIK RDMO 7/6/2006 07:00 - 07:30 0.50 SAFETY MTG SLICK 07:30 - 09:00 1.50 RURD SLIK SLICK 09:00 - 09:40 0.67 RUNPU TBG_ SLICK 09:40 - 10:50 1.17 RUNPU TBG SLICK 10:50 - 12:30 1.67 RUNPU TBG SLICK 12:30 - 13:30 1.00 RUNPU TBG_ SLICK 13:30 - 15:30 2.00 RUNPU TBG_ SLICK 15:30 - 18:00 2.50 RUNPU TBG SLICK 18:00 - 18:30 0.50 RUNPUL~ TBG_ SLICK 18:30 - 19:00 0.50 RURD SLIK SLICK RIH TO 5655' down to 5658'. POH. Recovered 0.5 gal mud/ beach sand. Hard packed, opened up well to flow back tank blew down 100 psig. RIH to 5658' down to 5663'. POH. 0.75 gal sand mud. RIH 1 3/4" drive down bailer. Work from 5665' down to 5670'. PUH tool string hung up in the top of patch. OOH with tool string, couple of marks on bottom of the tool string. MU 2.75" GR RIH to top of patch at 5668' KBD, POOH Lay down 1 3/4" tools, MU 1.25" tools string, with 1.25" DD bailer. RIH tagged up at 5731' KBD. Tools hanging up pull up and set off jars. Work tool string a couple of times. POOH. OOH with 1.25" tool string. metal marks along side of the bailer. Called shop to get a 1"tools string brought out from shop. RD 1.25" tools. MU 1.0 "tools string. RIH throgh patch tagged fill at 7320' KBD. Between #5 and #6 excape module. WHP= 620 psig. POOH OOH with tool string, secured well. Rig down wire line unit. Pollard left lease. Uptain work permit, held PJSM. Discussed safe work practices around the well. RU WL. Consists of RS,KJ,Stem,Stem,KJ,OJ,SJ. PR lubricator. Have leak fixed, test good. RIH w/ 3" GS to 5668' KB, Latch and Pull G Stop, POOH RIH w/ Same to 5669' KB latch and pull top packo ,POOH, Hang up in various spots rom to u er gone on packoff RIH with Same to 5682' KB, latch lower pack off, Beat on for 1 hr couldn't pull, Shear GS, POOH Change tool String to 1-3/4" and Pull of 50' of Wire RIH w/ 3" GS to 5682' KB, Latch and Pull packoff, POOH RIH w/ same to 5694' KB, Latch G stop, beat on for 1-1/2 Hrs, Couldn't pull, POOH RIH w/ same to 5694' KB. latch and~ull G POOH OOH with tool string, secured well. Rig down wire line unit. ~ 7/7/2006 ~ 07:00 - 07:20 ~ 0.331 SAFETY MTG_ ~ SLICK ~ Uptain work permit, held PJSM. Discussed safe work practices around Printed: 1/10/2008 5:08:47 PM L~ • Marathon Oil Company Page 21 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 D ti ti ~ H C h D i n f O F rom - To pera ons ate ours ase p o o ode P escr d Co e 7/7/2006 07:00 - 07:20 0.33 SAFETY MTG_ SLICK the well. 07:20 - 07:50 0.50 RURD_ SLIK SLICK RU WL. Consists of RS,KJ,Stem,Stem,KJ,OJ,SJ. PR lubricator, BOP test good 07:50 - 08:30 0.67 RUNPU TBG_ SLICK RIH w! 3" GS to 5694' KB, Latch and Pull top packoff, POOH 08:30 - 09:30 1.00 RUNPU TBG_ SLICK RIH w/ Same to 5714' KB latch and pull middle spacer, POOH 09:30 - 13:40 4.17 RUNPU TBG_ SLICK RIH w/ Same to 5724' KB latch packoff, beat on for 1 Hr., try to shear off, beat down for 3 Hrs., Come free, POOH (had sand packed in GS tool) 13:40 - 14:10 0.50 RUNPU TBG_ SLICK Change Oil Jars and Pull of 50' of Wire and Cut 14:10 - 16:00 1.83 RUNPU TBG_ SLICK RIH w/ 3" GS to 5724' KB, Latch packoff, beat on at 1800# force for 1 Hr., Couldn't pull, sheared off, POOH 16:00 - 16:40 0.67 RUNPU TBG_ SLICK Rig down and Clean up 16:40 - 17:00 0.33 RURD_ SLIK SLICK Stand by for decision to rig back up, decision is no, Leave site 7/8/2006 07:00 - 07:45 0.75 SAFETY MTG_ CMPFLW Uptain work permit, held PJSM. Discussed safe work practices around the well. 07:45 - 10:20 2.58 RURD_ COIL CMPFLW RU BJ CTU. 10:20 - 11:30 1.17 RURD_ COIL CMPFLW Fill CT. 11:30 - 12:10 0.67 TEST_ BOPE CMPFLW Perform full BOP test 250 / 4500 psi. Good test 12:10 - 13:45 1.58 RURD_ COIL CMPFLW PU 15' lubricator and fishing tools. Connector, dbl checks, 2-1/$" hyd jars, hyd disconnect, hydraulic release 3" GS. Total tool length 13' 1-1/2". 13:45 - 14:05 0.33 TEST_ BOPE CMPFLW Shell test lub /BOP to 1500 psi. 14:05 - 15:30 1.42 RUNPU COIL CMPFLW RIH w/ 3" GS to 5722' KB, Latch packoff. 15:30 - 17:15 1.75 RUNPU COIL CMPFLW Jar up 11 times at 32000# (17000 overpull) and down 3 times at 6000 down wt. Unable to move packoff. POH to cut CT. 17:15 - 19:15 2.00 RURD_ COIL CMPFLW Cut 50' CT. Replace CT connector and rerig tools with accelergator jar added to string. Tool length = 19'6-1/2". Stab injector. 19:15 - 19:45 0.50 RURD_ COIL CMPFLW Stab injector and shell test BOP to 1500 psi. 19:45 - 20:35 0.83 RUNPU COIL CMPFLW RIH. Latch patch at 5719' CTMD. Jar up 25 times at 16 - 19K# overpull. Unable to move patch. Pump release GS. 20:35 - 21:15 0.67 RUNPU COIL CMPFLW POH 21:15 - 21:45 0.50 RURD_ COIL CMPFLW Rig back Ct for weekend. 7/20/2006 10:00 - 10:40 0.67 SAFETY MTG_ CMPFLW Uptain work permit, held PJSM. Discussed safe work practices around the well. 10:40 - 11:50 1.17 RURD_ ELEC CMPFLW RU BJ Expro Eline. PU dummy string with CCL on bottom 11:50 - 13:15 1.42 RUNPU ELEC CMPFLW RIH. Log patch to ensure we can get tools inside. POH. 13:15 - 14:00 0.75 RURD_ ELEC CMPFLW Prepare 1-3/8" explosive jet cutter. 14:00 - 14:15 0.25 SAFETY MTG_ CMPFLW SD all toms. Complete perforating checklist. 14:15 - 15:15 1.00 RUNPU ELEC CMPFLW RIH 1-3/8"jet cutter. Tie into CCL. 15:15 - 15:35 0.33 CUT_ TBG_ CMPFLW Attempt to cut patch. Jet cutter did not fire. 15:35 - 16:15 0.67 RUNPU ELEC CMPFLW POH. 16:15 - 17:00 0.75 RURD_ ELEC CMPFLW Disarm jet cutter and investigate firing problem. 17:00 - 17:30 0.50 RURD_ ELEC CMPFLW Rerig jet cutter 17:30 - 18:20 0.83 RUNPU ELEC CMPFLW RIH 1-3/8"jet cutter and position. 18:20 - 18:30 0.17 CUT_ TBG_ CMPFLW Attempt to cut patch. Jet cutter will not fire. 18:30 - 19:15 0.75 RUNPU ELEC CMPFLW POH. 19:15 - 19:45 0.50 RURD_ ELEC CMPFLW Rig back for night. Leave location. 7/21/2006 07:30 - 08:00 0.50 SAFETY MTG_ CMPFLW Uptain work permit, held PJSM. Discussed safe work practices around the well. 08:00 - 09:00 1.00 RURD_ ELEC CMPFLW RU BJ Expro Eline. PU dummy string with CCL on bottom 09:00 - 09:30 0.50 RURD_ ELEC CMPFLW Prepare 1-3/8" explosive jet cutter. 09:30 - 09:45 0.25 SAFETY MTG_ CMPFLW SD all toms. Complete perforating checklist. 09:45 - 10:15 0.50 RUNPU ELEC CMPFLW RIH 1-3/8"jet cutter. Tie into CCL. Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 22 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 ti D i F T H ~ C d io f I D ons pt Opera ate rom - ours o escr n o o e Code Phase 7/21/2006 10:15 - 10:25 0.17 CUT_ TBG_ CMPFLW Attempt to cut patch. Jet cutter did not fire. Cut patch at 5727', 10' into 1.5" ID. 10:25 - 11:00 0.58 RUNPU ELEC CMPFLW POH. 11:00 - 12:15 1.25 RURD_ ELEC CMPFLW Rig back for night. Leave location. 7/22/2006 07:30 - 08:00 0.50 SAFETY MTG_ SLICK Uptain work permit, held PJSM.. Discussed safe work practices around the well. 08:00 - 09:30 1.50 RURD_ SLIK SLICK RU with PWS. WHP= 1500 psig. MU 1 314" tool string with RS, KJ,10' stem, KJ, Oil jars, Long strock spangs, KJ and 3.5" GS. 09:30 - 11:30 2.00 RURD_ SLIK SLICK RIH tool string falling in well slow. Tool string at 5640' with tools falling slow, decide to POOH before latching up on fish. No way to shear off of the fish. 11:30 - 11:50 0.33 WORK SLIK SLICK Pull tool string up in lubricator. MU pump and air compressor to tree cap. Start pumping diesel to help break up E-line grease in well bore. 11:50 - 13:25 1.58 WORK SLIK SLICK RIH working the tool string when tools at 2000', tools falling good. RIH picking up tools to work diesel in grease in well bore. 13:25 - 14:15 0.83 WORK SLIK SLICK Latched up on seal assy, work PU set off jars with 450 Ibs PU. Found fish at 5695' KBD. Continue working tool string work oil jars. 14:15 - 15:30 1.25 WORK SLIK SLICK Work tool string up and down. PU to 1600 Ibs set off oil drop down and reset oils and work spangs to move fish down. Tool moving down 1' after spanging down. 15:30 - 16:30 1.00 WORK SLIK SLICK POOH with tool string to cut wire and lay down for night. Fjsh_moved a total of 6' un from start to 568Q' KRn 16:30 - 17:30 1.00 WORK SLIK SLICK OOH with tool string, secure well, break down tool string, cut off 200' wire and re-tie the rope socket for monday. 17:30 - 18:30 1.00 RURD_ SLIK SLICK Cleaned up around well head, secured unit, pump additional diesel down well while pump on location. PWS left lease. 7/25/2006 07:30 - 09:30 2.00 PU lubricator. Held PJSM and discussed safety and environmental concerns around the well head. Uptained Safe work permit and discussed JSA. 09:30 - 10:00 0.50 Added 5' lubricator, 5' 1 3/4" stem on tool string. PU lubricator and go to well with lubricator. WHP = 1510 psig. Open well. 10:00 - 12:15 2.25 RIH to 5726' KBD, latch on fish with 3' GS. Work tool string up and down to move fish. Fish still moving up and down. shear off after 2 hours working tools. POOH 12:15 - 13:20 1.08 OOH with tools, Re pin the GS, sand and grease on tool string. RIH with same tools. Work oil and spangs, fish tight across module. Moved the fish 10' to 5716' KBD Bottom of seal assy at 5727' KBD. 13:20 - 14:10 0.83 Shear off of tool string POOH to re pin GS. Repin 3" GS. RIH with same tools 14:10 - 15:25 1.25 Work tool string several times sheared off, POOH with tool string. 15:25 - 16:30 1.08 OOH Repin GS. RIH with same tool string. Work the spangs and oil jars. Shear off tool string, POOH. 16:30 - 17:00 0.50 OOH with tool string, lay down lubricator, cut off 200' wire and re tie the rope socket to get ready for tomorrow. Moved the seal assy total of 11' today 5715' KBD. 17:00 - 17:45 0.75 Secured well, lay down lubricator and secured site. PWS left lease. 7/26/2006 07:30 - 09:30 2.00 RURD_ SLIK SLICK PU lubricator. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. 09:30 - 10:00 0.50 WORK SLIK SLICK PU lubricator and go to well with 1 3/4" too string. WHP = 1500 psig. Open well. 10:00 - 12:15 2.25 WORK SLIK SLICK RIH to 5719' KBD, latch on fish with 3' GS. Work tool string up and down to move fish. Fish still moving up more than down. Work oil jars several times. Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 23 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To I Hours. Code. Code Phase Description of Operations 7/26/2006 112:15 - 12:30 I 0.25 I WORK I SLIK I SLICK I Tool string pulled off of fish or fish came loose. Gained 35 Ibs 12:30 - 13:40 1.17 WORK SLIK SLICK 13:40 - 16:00 2.33 WORK SLIK SLICK 16:00 - 16:30 0.50 WORK SLIK SLICK 16:30 - 17:00 0.50 RURD SLIK SLICK 7/27/2006 07:30 - 08:00 0.50 RURD SLIK SLICK 08:00 - 09:30 1.50 WORK SLIK SLICK 09:30 - 10:00 0.50 WORK SLIK SLICK 10:00 - 10:15 0.25 WORK SLIK SLICK 10:15 - 15:00 4.75 WORK SLIK SLICK 15:00 - 17:00 2.00 WORK SLIK SLICK 17:00 - 17:15 0.25 WORK SLIK SLICK 17:15 - 17:50 0.58 RURD SLIK SLICK 7/28/2006 07:30 - 08:00 0.50 RURD SLIK SLICK 08:00 - 08:10 0.17 WORK SLIK SLICK 08:10 - 08:40 0.50 WORK SLIK SLICK 08:40 - 09:00 0.33 WORK SLIK SLICK 09:00 - 09:40 0.67 WORK SLIK SLICK 09:40 - 12:15 2.58 WORK SLIK SLICK 12:15 - 13:00 0.75 WORK SLIK SLICK 13:00 - 13:15 0.25 WORK SLIK SLICK 14:00 - 17:50 3.83 RURD SLIK SLICK additional tool weight. POOH with tools. Open lubricator recovered 9.6' of the bottom of seal assn. MU 2.60" LIB to RIH tag top of fish. OOH with LIB found cut off element on the LIB. MU 2.7" bull dog spear with a 2.5" OK shear up tool. RIH found fish at 5727' KBD drive down spear to make sure good and set in packoff. PUH to shear pin. Sheared pin, POOH. OOH with RB, MU 3" SB. RIH to 5732" KB, Work tool string. Sheared off prong. POOH OOH with tool string, lay down lubricator, cut off 150' wire and re tie the rope socket & repack the pack off to get ready for tomorrow. Secured well, lay down lubricator and secured site. PWS left lease. Note: recovered 9.6' seal assy. PU lubricator. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. PU lubricator and go to well with 1 3/4" too string. WHP = 1500 psig. Open well. RIH to 5712' KBD, attempt to latch on fish with 3' SB. Work tool string up and down to latch fish. Could not latch fish. POOH. Tool was not sheared. MU LIB to RIH tagged up on fish. POOH found sand marks on LIB. MU pump down bailer. RIH with same. Work bailer, POOH with bailer, sand and water in bailer. RIH with bailer, POOH with bailer. Water level at 5030' in tubing coming up in tubing. Gray formation sand on each return to surface with bailer. WHP= 1400 psig. OOH with tool string, lay down lubricator, cut off 150' wire and re tie the rope socket & repack the pack off to get ready for tomorrow. Secured well, lay down lubricator and secured site. PWS left lease. Note: made 11 bailer runs in well. PU lubricator. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. PU lubricator and go to well with 1 3/4" too string. WHP = 1500 psig. Open well. RIH to 5732' KBD, Work pump bailer, POOH with bailer. Found fluid level at 4930'. POOH OOH with bailer, sand and water in bailer. RIH second run with bailer. Work tool string form 5731' KBD. Started pumping H2O and Methanol water at surface to try and reduce amount of sand entering the well bore. OOH with bailer some sand and water in balier, changed out the ball from rubber to steel. RIH with same. Tools sat down at 301' KBD, Work tool string with no success. PUH pump higher concentration of Methanol) water with no success. Worked tool string down to 332' KBD. MU star bit to try and clear the hydrate in the tubing. RIH to 332' no luck. Let the well set for an hour. RIH sat down at same place. POOH with tool string lay, down the lubricator and rig down equipment. Secured well, RD wire line unit, PWS left lease. Note: made 13 pump bailer runs in well. Total sand recovered 2 gallons, bull nose spear is still) landed in the remaining 6" piece of the Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 24 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: ORIGINAL COMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING f F D T ate rom - o Hours Code Gode Phase 7/28/2006 14:00 - 17:50 3.83 RURD_ SLIK SLICK 8/1/2006 1 07:00 - 08:00 1.00 RURD SLIK SLICK 08:00 - 14:00 I 6.001 WORK I SLIK I SLICK 14:00 - 14:15 0.25 WORK SLIK SLICK 14:15 - 14:30 0.25 WORK SLIK SLICK 14:00 - 17:00 3.00 RURD SLIK SLICK 8/4/2006 07:30 - 09:00 1.50 RURD SLIK SLICK 09:00 - 11:10 2.17 WORK SLIK SLICK 11:10 - 13:00 1.83 WORK SLIK SLICK 13:00 - SLICK 13:00 - 13:30 I 0.501 WORK I SLIK I SLICK 13:30 - 14:30 1.00 WORK SLIK SLICK 14:30 - 16:00 1.50 SLICK 16:00 - 17:30 1.50 RURD SLIK SLICK 8/23/2006 08:00 - 10:00 2.00 RURD SLIK SLICK 10:00 - 11:45 1.75 WORK SLIK SLICK 11:45 - 13:10 1.42 WORK SLIK SLICK 13:10 - 13:20 0.17 WORK SLIK SLICK 13:20 - 13:40 0.33 WORK SLIK SLICK 13:40 - 15:30 1.83 WORK SLIK SLICK 15:30 - 19:00 3.50 WORK SLIK SLICK 19:00 - 20:00 I 1.001 WORK I SLIK I SLICK 20:00 - 21:15 1.251 WORK SLIK SLICK Spud Date: 7/23/2005 Start: 8/17/2005 End: 1/22/2006 Rig Release: Group: Rig Number: 1 Description of Operations seal assy and the packoff. PU lubricator. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. MU star bit to try and clear the hydrate in the tubing. RIH to 332' KBD. RIH sat down at same place. Work tool string while pumping Methanol. Maintain 1550 psig on top of plug. POOH check tool sting, RIH with same tools to try and chip at hydrates in tubing. POOH with tool string lay, down the lubricator and rig down equipment. Secured well, RD wire line unit, PWS left lease. PU lubricator. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. MU 2.25" hydrostatic bailer. Use WHP to PT lubricator. WHP = 1400 psig. RIH sat down @ 5732' KB. Work tool string, POOH with bailer. OOH with bailer, check bailer for sand by pulling the bottom ball section off of the bailer. Bottom of bailer blew off. Cause a pipe wrench to hit one of the wireline crew helpers in the jaw breaking his tooth and cutting his lip. Stopped job for medical attention. Held second PJS meeting after crew member changed out. MU 2.5" DD bailer. Problem with O-ring leaking on lubricator. Break out connection, replace oring and lubricated, PT lubricattor, OK. RIH with 2.5" DD bailer to 5632' KBD. Work tool string, POOH with bailer. Small amount of sand in bailer. Decided to MU 3" KB, RIH to 5732' KBC, work tools could not latch the bull nose spear and pack off. POOH OOH with SB, lay down and make up the pump bailer. RIH with pump bailer to 5632' KBD. Work pump bailer, POOH. OOH with bailer, B/D lubricator, check bailer for sand. Recovered 1 quart sand. MU 3.0" SB. RIH to latch fish, could not latch, POOH Secured well, RD wire line unit, PWS left lease. MIRU Equipment. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. MU 2.25" hydrostatic bailer. Use WHP to PT lubricator. WHP = 1400 psig. RIH sat down @ 5732' KB. Work tool string, POOH with bailer. OOH with bailer, check bailer for sand by pulling the bottom ball section off of the bailer. Approx. 1 cup of sand water. Marks on bottom of bailer shaped like fishing neck. Lay down bailer, MU 3.0 JDC with 4' stem. RIH to 5732' KBC, work tools, sat down 2' high. PU hole, sat down, POOH OOH with SB, no fish, check bottom of the SB. No Marks, RIH with SB to 5732' KBD. work tool string, POOH. OOH with SB, No marks on SB. RIH to latch fish, latch fish, POOH. Work tool string accross each collar, fish hung up at 41.91' KBD. Sheared tool, POOH with TS. Replace sheared pin in SB, RIH with SB to latch fish, fish found at at 5732' KBD, Work tool string, POOH with tool string, OOH checked pin. MU tool string, RIH to 5732' KBD, worked tool string, no indication that fish latched. POOH with tools. OOH no fish. Lay down equipment. Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 25 of 27 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ORIGINAL COMPLETION Start: 8/17/2005 End: 1/22/2006 Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From- To Hours Code Cade Phase 8/23/2006 21:15 - 22:00 0.75 RURD SLIK SLICK 8/24/2006 07:00 - 09:00 2.00 RURD SLIK SLICK 09:00 - 09:45 0.75 WORK SLIK SLICK 09:45 - 10:50 1.08 WORK SLIK SLICK 10:50 - 11:00 0.17 WORK SLIK SLICK 11:00 - 11:10 0.17 WORK SLIK SLICK 11:10 - 11:20 0.17 WORK SLIK SLICK 11:20 - 11:40 0.33 WORK SLIK SLICK 11:40 - 13:30 1.83 WORK SLIK SLICK 13:30 - 14:10 0.67 WORK SLIK SLICK 14:10 - 17:00 2.83 WORK SLIK SLICK 17:00 - 18:40 1.67 RURD_ SLIK SLICK 8!29/2006 09:00 - 11:30 2.50 RURD SLIK SLICK 11:30 - 12:15 0.75 WORK SLIK SLICK 12:15 - 13:15 1.00 WORK SLIK SLICK 13:15 - 14:35 1.33 WORK SLIK SLICK 14:35 - 14:40 0.08 WORK SLIK SLICK 14:40 - 16:30 1.83 WORK SLIK SLICK 16:30 - 17:40 1.17 WORK SLIK SLICK 17:40 - 18:00 0.33 WORK SLIK SLICK 18:00 - 18:45 0.75 WORK SLIK SLICK 8/30/2006 09:00 - 11:30 2.50 RURD SLIK SLICK 11:30 - 12:15 0.75 WORK SLIK SLICK 12:15 - 13:15 1.00 WORK SLIK SLICK 13:15 - 14:35 1.33 WORK SLIK SLICK 14:35 - 14:40 0.08 WORK SLIK SLICK 14:40 - 16:30 1.83 WORK SLIK SLICK Description of Operations PWS and Expro left lease. Indications on tools that fish may have sand around the fishing neck decreasing potential to latch upon fish. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. MU 2.25" pump bailer. Use WHP to PT lubricator. WHP = 1430 psig. RIH sat down @ 5732' KB. Work tool string, POOH with bailer. OOH with bailer, check bailer for sand by pulling the bottom ball section off of the bailer. Approx. 1.5 cup of sand water. Lay down bailer, MU 3.0 SB with 4' stem. RIH to 5732' KBC, work tools, could not latch fish, POOH OOH with SB. MU 2.5" Pump bailer, RIH to 5732' KBD. Work tool string, POOH. OOH with pump bailer, some sand, RIH with Pump bailer, Work tools, POOH. OOH with bailer, some water and sand. MU RB (Shear up tool) RIH to latch fish. Latch fish, work tool string, sheared off fish, POOH MU 2.5" pump bailer, RIH to 5732' KBD, work bailer, POOH. some sand in bailer, MU 3.5" JDC, RIH latch fish, work tool sting, Shear off fish, POOH with tool sting. Decide to rig down unit. PWS left lease. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. MU 2.25" pump bailer. Use WHP to PT lubricator. WHP = 1500 psig. RIH sat down @ 5732' KB. Work tool string, POOH with bailer. OOH with bailer, check bailer for sand Approx. 1.0 cup of sand water, soft with water. Pull bailer, MU 3.0" jc w/15' stem. Open well. RIH with JDC to 5732' KBD. Latch up on fish, work oil jars, set off 6 times, sheared off of fish. POOH OOH with JDC no fish, re-pin JDC, take to well. Open well to tool string. RIH with JDC. RIH with JDC to 5732' KBD. Latch up on fish, work oil jars, set off 3 times, sheared off of fish. POOH. JDC bottom skirt had a 1" piece broken off of it. MU JC shear up tool to pull the bull nose spear on next run. RIH with 3" RS to latch bull nose spear. Latch spear, hit oil jars 7 times, sheared off POOH OOH with RS, tool not sheared, did not have spear. Lay down tool string for night, PWS left lease. Held PJSM and discussed safety and environmental issues. Uptained Safe work permit and discussed JSA. MU 2.25" pump bailer. Use WHP to PT lubricator. WHP = 1500 psig. RIH sat down @ 5732' KB. Work tool string, POOH with bailer. OOH with bailer, check bailer for sand Approx. 1.0 cup of sand water, soft with water. Pull bailer, MU 3.0" jc w/15' stem. Open well. RIH with JDC to 5732' KBD. Latch up on fish, work oil jars, set off 6 times, sheared off of fish. POOH OOH with JDC no fish, re-pin JDC, take to well. Open well to tool string. RIH with JDC. RIH with JDC to 5732' KBD. Latch up on fish, work oil jars, set off 3 times, sheared off of fish. POOH. JDC bottom skirt had a 1" piece broken off of it. MU JC shear up tool to pull the bull nose spear on next Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 ORIGINAL COMPLETION GLACIER DRILLING GLACIER DRILLING Hours .Code Code Phase Start: 8/17/2005 Rig Release: Rig Number: 1 Page 26 of 27 ~ Spud Date: 7/23/2005 End: 1 /22/2006 Group: Date From - To Description of Operations 8/30/2006 14:40 - 16:30 1.83 WORK SLIK SLICK run. 16:30 - 17:40 1.17 WORK SLIK SLICK RIH with 3" RS to latch bull nose spear. Latch spear, hit oil jars 7 times, sheared off POOH 17:40 - 18:00 0.33 WORK SLIK SLICK OOH with RS, tool not sheared, did not have spear. 18:00 - 18:45 0.75 WORK SLIK SLICK Lay down tool string for night, PWS left lease. 9/3/2006 07:00 - 15:00 8.00 RURD_ ELEC MIRU MIRU braded line to fish seal assy. Had problems with crane extension, leaks in lubricator had to lay down the lubricator and breaK the tools string down to fix to different leaks at connections in the lubricator. Decided to shut down until Tuesday due do late start. 9/6/2006 07:00 - 09:00 2.00 RURD_ ELEC WRLN Held PJSM, discussed procedure and safey issues with personnel. Uptained a work permit. 09:00 - 09:30 0.50 WORK ELEC WRLN RU 0.25" braded line unit with 10' 2.125' stem, oil jars, 1.75" spangs with 3.0" JDC. PU tool sting and go to well. PT lubricator with N2 prior to opening up well. PT good, open well. RIH to 5711' KIBD. 09:30 - 10:00 0.50 WORK ELEC WRLN Try to latch up on fish. Work tool sting with no success latching fish. POOH with tools. Tools at 1760' KBD counter on unit quit working. 10:00 - 12:35 2.58 WORK ELEC WRLN Trouble shoot counter issue, found metal pin on the counter gear sheared. Shut down unit while repair parts brought out from shop. Repair counter, continue OOH with tools. OOH MU pump bailer. Aprox. 1 .5 cups sand with dents on bailer bottom. 12:35 - 15:00 2.42 WORK ELEC WRLN RD bailer MU 3.0"JDC. Braded line cable twisted below upper sheave. Lay down lubricator and crane blocks to staighten out the twisted wire. 15:00 - 15:45 0.75 WORK ELEC WRLN PU lubricator, MU JDC with modified skirt to try and latch up on fish. PT lubricator. 15:45 - 17:00 1.25 WORK ELEC WRLN RIH with 3.0" JDC to latch fish. Could not latch up on fish. POOH with braded line. 17:00 - 18:30 1.50 WRLN OOH with tools lay down lubricator, RD braded line & crane. Clean up around well head. PWS left lease. 9/7/2006 07:00 - 09:00 2.00 RURD_ ELEC WRLN Held PJSM, discussed procedure and safey issues with personnel. Uptained a work permit. 09:00 - 09:30 0.50 WORK SLIK WRLN RU 0.125" slick line unit with 1 3/4" JS, KJ, 10' 2.125' stem, KJ, oil jars, 1.75" spangs 2.5" pump bailer. PU tool sting and go to well. 09:30 - 11:00 1.50 WORK SLIK WRLN RIH to 5731' KBD, slow falling in well due to the braded line grease. On bottom with bailer, work tool string POOH with bailer. OOH dump 1.5 cups sand, pour diesel down tubing to loosen up the grease. 11:00 - 12:35 1.58 WORK SLIK WRLN MU 3.0"JDC, RIH to latch up on fish, not able to latch fish. POOH with JDC. MU balier. RIH to bail sand. 12:35 - 13:55 1.33 WORK SLIK WRLN Work tool string at 5721' KBD, POOH, 2 cups of sand. MU JDC 13:55 - 15:15 1.33 WORK SLIK WRLN RIH latch fish, work spangs up, POOH. No fish, dogs slightly rolled on JDC. 15:15 - 16:00 0.75 WORK SLIK WRLN RIH with 3.0" RS to try and pull spear. Latched fish at 5733' KBD. Beat up, POOH 16:00 - 16:20 0.33 WORK SLIK WRLN No fish, MU 3.0"JDC. RIH to latch fish. 16:20 - 18:00 1.67 WORK SLIK WRLN RIH to 5733' KBD, latched up on fish, work spang jars for over an hour, sheared off fish. POOH 18:00 - 19:00 1.00 RURD_ SLIK WRLN Lay down equipment, RD slick line. PWS left lease. 9/8/2006 07:00 - 08:00 1.00 Issue Permik. 08:00 - 08:30 0.50 SAFETY MTG_ CMPFLW Held PJSM. Discussed safe work practices around the well. 08:30 - 09:00 0.50 RURD_ OTHR CMPFLW Spot crane and RU vetco. 09:00 - 09:30 0.50 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and concurrent operations. 09:30 - 11:55 2.42 RURD OTHR CMPFLW Set BBV. Remove old tree below lower master. Pull BPV. Set 2 way Printed: 1/10/2008 5:08:47 PM • Marathon Oil Company Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 'i From - To 9/8/2006 09:30 - 11:55 11:55 - 12:30 12:30 - 14:00 14:00 - 17:30 9/12/2006 07:00 - 07:30 07:30 - 08:30 08:30 - 08:50 08:50 - 10:00 10:00 - 12:00 12:00 - 14:00 9/13/2006 19/14/2006 19/16/2006 CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 ORIGINAL COMPLETION Start: 8/17/2005 GLACIER DRILLING Rig Release: GLACIER DRILLING Rig Number: 1 Page 27 of 27 ~ Spud Date: 7/23/2005 End: 1 /22/2006 Group: Hours Code Code Phase Description of Operations 2.42 RURD_ OTHR CMPFLW check. 0.58 TEST_ TREE CMPFLW PT tree to 5000 psi. Good test. 1.50 RURD_ OTHR CMPFLW Pull 2 way check. Continue BJ rigup 3.50 RURD_ COIL CMPFLW Finish BJ rigup ready to PT. SDFN. 0.50 SAFETY MTG_ CMPFLW Held PJSM. Discussed complete check list. Issue Permit. 1.00 RURD_ COIL CMPFLW Start equipment and continue RU. 0.33 SAFETY MTG_ CMPFLW Changed supervisors. Hold safety meeting with new supervisor and full crew.. Discuss complete checklist and tripping hazards. 1.17 RURD_ COIL CMPFLW Continue RU. Pull test connector. 2.00 TEST_ BOPE CMPFLW Perform full BOP test at 250 psi / 3500 psi. Good test. 2.00 RURD_ COIL CMPFLW Attempt to PT coil connector. Change coil connector and PT. PU DCV, accel, jar, disconnect, hyd JDC to catch 2.31" FN. Stab on well and shell test to 250 / 3500 psi. 2.00 RUNPU COIL CMPFLW RIH with fishing tools. 0.17 RUNPU COIL CMPFLW Tag fish at 5718' CTMD. Push downhole to 5722'. Drag up hole at 2-4K overpull to 5710'. Jars hit and lost all drag. 0.83 RUNPU COIL CMPFLW POH to check for fish. 1.00 RURD_ COIL CMPFLW very.. Mark on skirt and inside overshot. Appears that fish did not latch into dogs. Only a friction bite. Rig back for night. 0.50 SAFETY MTG_ CMPFLW Held PJSM. Discussed complete check list. Issue Permit. 1.58 RURD_ COIL CMPFLW Start equipment and continue RU. PU same fishing string and stab on well. 0.17 SAFETY MTG_ CMPFLW Perform shell test to 1300 psi. 1.50 RUNPU COIL CMPFLW RIH 3" JDC. 0.33 RUNPU COIL CMPFLW Tag and work down from 5719' to 5726'. PU with 6K overpull and 2-6K for 15'. 0.92 RUNPU COIL CMPFLW POH. 0.75 RURD COIL CMPFLW , o fish_and no indications of being over fish. Check tools, Shell 14:00 - 16:00 16:00 - 16:10 16:10 - 17:00 17:00 - 18:00 07:00 - 07:30 07:30 - 09:05 09:05 - 09:15 09:15 - 10:45 10:45 - 11:05 11:05 - 12:00 12:00 - 12:45 test to 1000 psi. 1.50 RUNPU COIL CMPFLW RIH 3" JDC. 2.75 RUNPU COIL CMPFLW Tag. Work up and down. No catch Jet down to bottom. No catch. Jar down 6 times. no catch. Jet down to bottom. Keep hole full by circulating 6% KCI across tree. 1.00 RUNPU COIL CMPFLW POH 1.00 RURD_ COIL CMPFLW OOH. Rig back for night 0.50 SAFETY MTG_ CMPFLW Held PJSM. Discussed complete check list. Issue Permit. 5.50 RURD_ COIL CMPFLW Complete coiled tubing rig down and leave location 0.33 SAFETY MTG_ CMPFLW Held PJSM. Discussed complete check list. Issue Permit. 0.42 RURD_ ELEC CMPFLW RU Expro eline and downhole video camera. 1.58 RUNPU ELEC CMPFLW RIH DHV camera 1.22 LOG CSG_ CMPFLW Record video from 5650' Fishing neck is at 5729' (cPal accv is ;" 12:45 - 14:15 14:15 - 17:00 17:00 - 18:00 18:00 - 19:00 09:00 - 09:30 09:30 - 15:00 11:15 - 11:35 11:35 - 12:00 12:00 - 13:35 13:35 - 14:48 14:48 - 15:30 0.70 RUNPUL~ ELEC CMPFLW POH 15:30 - 16:00 0.50 RURD ELEC CMPFLW RD Expro and leave location. Printed: 1/10/2008 5:08:47 PM • • Marathon Oil Company Page 1 of 17 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: MAINTENANCE/REPAIR Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING - Date From - To Hours Code Code Phase 1/11/2007 07:00 - 08:15 1.25 SAFETY MTG_ MIRU 08:15 - 10:40 2.42 RURD_ SLIK SLICK 10:40 - 11:00 0.33 WORK SLIK SLICK 11:00 - 13:00 2.00 WORK SLIK SLICK 13:00 - 13:25 0.42 WORK SLIK SLICK 13:25 - 14:45 1.331 WORK SLIK SLICK 14:45 - 17:00 I 2.251 WORK I SLIK I SLICK 17:00 - 19:00 2.00 RURD_ SLIK SLICK 1/12/2007 07:30 - 08:30 1.00 SAFETY MTG_ MIRU 08:30 - 09:05 0.58 RURD_ SLIK SLICK 09:05 - 09:15 0.17 TEST_ BOPE SLICK 09:15 - 10:15 1.00 WORK SLIK SLICK 10:15 - 11:30 1.25 WORK SLIK SLICK 11:30 - 13:10 1.67 WORK SLIK SLICK 13:10 - 14:30 1.33 WORK SLIK SLICK 14:30 - 15:45 1.25 WORK SLIK SLICK 15:45 - 17:00 1.25 WORK SLIK SLICK 17:00 - 18:15 1.25 WORK SLIK SLICK 18:15 - 19:00 0.75 RURD_ SLIK SLICK 1/1312007 07:30 - 09:00 1.50 SAFETY MTG_ MIRU 09:00 - 09:20 0.33 RURD SLIK SLICK 09:20 - 09:30 0.17 TEST_ BOPE SLICK 09:30 - 10:40 1.17 WORK SLIK SLICK 10:40 - 11:55 1.25 WORK SLIK SLICK 11:55 - 12:55 1.00 WORK SLIK SLICK 12:55 - 14:05 1.17 WORK SLIK SLICK 14:05 - 15:00 0.92 WORK SLIK SLICK 15:00 - 16:15 1.25 WORK SLIK SLICK 16:15 - 17:20 1.08 SLICK Spud Date: 7/23/2005 Start: 1/11/2007 End: Rig Release: Group: Rig Number: 1 Description of Operations Held PJSM. Discussed complete check list. Issue Permit. RU slick line unit, mu lubricator and tool string. MU 2.5" Pump bailer, 2.70" flapper bottom. PU and go to well with tool string. PT lubricator with Methanol to 1500 psig. RIH with tool string to 5726' KBD. Work bailer, POOH with bailer. 1/2 cup of sand. PU go to well with bailer, PT lubricator with Methanol, good test, RIH with tool string to 5727' KBD. Work bailer, POOH with bailer. Chunck of rubber in flapper. Flapper pin broke replace pin. PU go to well with bailer, PT lubricator with Methanol, good test, RIH with tool string to 5729' KBD. Work bailer, POOH with bailer. OOH with bailer, 2 qts sand. PU go to well with bailer, PT lubricator with Methanol, good test, RIH with tool string to 5732' KBD. Work bailer, POOH with bailer. OOH with bailer, 2 qts sand. Lay down lubricator for night. Secured well, left lease. Held PJSM. Discussed complete check list. Issue Permit. RU slick line unit, mu lubricator and tool string with 2-1/2" pump bailer. Stab on well. PT lubricator with Methanol to 1500 psig. RIH with tool string to 5712' KBD. Work bailer, POOH with bailer. No sand recovered. RIH with tool string to 5712' KBD. Work bailer, POOH with bailer. 2 Qts sand recovered. RIH with tool string to 5712' KBD. Work bailer, POOH with bailer. 2 Ots sand recovered. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 2 Qts sand recovered. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 1.5 Ots sand recovered. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 1.5 Ots sand recovered. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 1 Qt sand recovered. Lay down lubricator for night. Secured well, left lease. Held PJSM. Discussed complete check list. Issue Permit. RU slick line unit, mu lubricator and tool string with 2-1/2" pump bailer. Stab on well. PT lubricator with Methanol to 1500 psig. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 1 Ot sand recovered. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 2 Qts sand recovered. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 2 Ots sand recovered. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 1.5 Ots sand recovered. RIH with 2.70" LIB to 5713' KBD. Hit down and POH. Impression only shows sand. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 1.5 Ots sand recovered. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 1.5 Ots sand recovered. Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Page 2 of 17 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: MAINTENANCE/REPAIR Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date 'From - To Hours Code Phase Code 1/13/2007 17:20 - 18:30 1.17 RURD_ SLIK SLICK 1/16/2007 07:30 - 09:00 1.50 SAFETY MTG_ MIRU 09:00 - 09:20 0.33 RURD SLIK SLICK 09:20 - 09:30 0.17 TEST_ BOPE SLICK 09:30 - 10:50 1.33 WORK SLIK SLICK 1 /17/2007 1 /18/2007 1 /19/2007 10:50 - 13:30 2.671 WORK~SLIK SLICK 13:30 - 15:50 I 2.331 WORK I SLIK I SLICK 15:50 - 16:45 0.92 WORK SLIK SLICK 16:45 - 18:15 1.50 WORK SLIK SLICK 18:15 - 19:00 0.75 RURD_ SLIK SLICK 07:30 - 09:15 1.75 SAFETY MTG_ MIRU 09:15 - 09:35 0.33 RURD SLIK SLICK 09:35 - 09:45 0.17 TEST_ BOPE SLICK 09:45 - 10:30 0.75 WORK SLIK SLICK 10:30 - 11:35 I 1.081 WORK I SLIK I SLICK 11:35 - 12:10 0.58 WORK SLIK SLICK 12:10 - 12:45 0.58 WORK SLIK SLICK 12:45 - 13:20 0.58 WORK SLIK SLICK 13:20 - 14:30 1.17 WORK SLIK SLICK 14:30 - 15:45 1.25 WORK SLIK SLICK 15:45 - 16:40 0.92 WORK SLIK SLICK 16:40 - 19:30 2.831 RURD_ SLIK SLICK 08:00 - 08:20 0.33 SAFETY MTG_ MIRU 08:20 - 09:20 1.00 RURD SLIK SLICK 09:20 - 09:30 0.17 TEST_ BOPE SLICK 09:30 - 12:10 2.67 WORK SLIK SLICK 12:10 - 12:45 0.581 WORK_ SLIK SLICK 12:45 - 14:20 1.581 WORK_ SLIK SLICK 14:20 - 15:00 I 0.671 WORK I SLIK I SLICK 15:00 - 16:00 I 1.001 RURD I SLIK I SLICK 08:00 - 08:30 0.50 SAFETY MTG_ MIRU 08:30 - 10:40 2.17 RURD SLIK SLICK 10:40 - 10:55 0.25 TEST_ BOPE SLICK 10:55 - 17:15 6.33 WORK SLIK SLICK Spud Date: 7/23/2005 Start: 1/11/2007 End: Rig Release: Group: Rig Number: 1 Description of Operations Lay down lubricator for night. Secured well, left lease. Held PJSM. Discussed complete check list. Issue Permit. RU slick line unit, mu lubricator and tool string with 2-1/2" pump bailer. Stab on well PT lubricator with Methanol to 1500 psig. RIH with tool string to 5713' KBD. Work bailer, POOH with bailer. 1 Ot sand recovered. RIH with tool string to 5713' KBD. Work bailer, Start OOH with bailer. RIH with wire finder to 450'. No sign of wire. POH. Pin sheared in wire finder and left wire finder in hole. Wait on tools. RU wire cutter to chase wire finder and cut wire. Chase wire finder to 5682'. Jar down to cut wire and release cutter. POH. Lay down lubricator for night. Secured well, left lease. Held PJSM. Discussed complete check list. Issue Permit. RU slick line unit, mu lubricator and tool string with 2-1/2" pump bailer. Stab on well. PT lubricator with Methanol to 1500 psig. RIH with blind box to 5682' KB. Beat down on sidewall cutter to cut wire. POH RIH with braided line brush. Tag wire at 200'. Beat down to 220' to ball up wire. POH. RIH with 2 prong wire grab. Unable to find wire. POH. RIH 3" wire finder to 80'. Work tool and POH with 2' piece of wire. RIH 3" wire finder to 280'. No sign of wire. RIH Braided line brush to 400'. No wire. POH and adjust brush. RIH Braided line brush to 1200'. No wire. POH. RIH 3" wire finder and braided line brush. Work down to 320' POG with drag to 257'. Tool stuck. Shear off and POH. Lay down lubricator for night. Rerig tools for heavy fishing. Secured well, left lease. Held PJSM. Discussed complete check list. Issue Permit. RU slick line unit, mu lubricator and tool string with 1.75" blind box. Stab on well. PT lubricator with Methanol to 1500 psig. RIH with 2-1/2" JDC pulling tool and latch baited wire at 258'. Work tools and came off. POH. JDC was sheared. Slip and cut 100' wire. Redress tool and PT lubricator to 1500 psi. RIH with same string and tag baited wire at 258'. Unable to latch. POH. PU 2.70" LIB. Pressure test lubricator to 1500 psi with McOH. RIH 2.70" LIB. Jar down and POH. Recovered impression of wire. PU wire spear. Pressure test lubricator to 1500 psi. RIH baited center spear to 258' and latch wire. Pull wire up hole 13'. Unable to break wire. Release spear and POH. RD unit and preparee to RU braided line unit to pull wire. Call for ASRC crane. Secured well, left lease. Held PJSM. Discussed complete check list. Issue Permit. RU Braided line unit, mu lubricator and tool string with 2.5" JDC pulling tool. Stab on well. PT lubricator with Methanol to 1500 psig. RIH with 2-1/2"JDC pulling tool and latch baited wire at 243'. Jar fish back up hole and into lubricator. Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Page 3 of 17 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAI R Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 I Date From - To Hours Code Code Phase Description of Operations 1/19/2007 17:15 - 18:30 1.25 WORK SLIK SLICK LD lar a ball of wire and center spear. 18:30 - 19:00 0.50 RURD_ SLIK SLICK Rig back unit or night. Secured well, left lease. 1/20/2007 07:30 - 08:30 1.00 SAFETY MTG_ MIRU Held PJSM. Discussed complete check list. Issue Permit. 08:30 - 10:00 1.50 RURD_ SLIK SLICK RU Braided line unit, mu lubricator and tool string with 2.5" JDC pulling tool. Stab on well. 10:00 - 10:15 0.25 TEST_ BOPE SLICK PT lubricator with Methanol to 1500 psig. 10:15 - 10:45 0.50 WORK SLIK SLICK RIH with 2.70" LIB to 295'. Impression of fishing neck and wire. 10:45 - 14:35 3.83 WORK. SLIK SLICK Fish wire for 7 trips from 270' to 335'. Recovered 6 pieces of wire for a total recovery of 12' 14:35 - 15:10 0.58 SLICK RIH~,S" .IDC pulling tnnl I atrh and reCnyer Wirefinder and hraidarl ling 15:10 - 16:50 1.67 SLICK RIH wire grab 3 trips and recover 57' of wire in 3 peices. 16:50 - 18:30 1.67 RURD_ SLIK SLICK Rig back unit for night. Secured well, left lease. 1/21/2007 08:30 - 09:00 0.50 SAFETY MTG_ MIRU Held PJSM. Discussed complete check list. Issue Permit. 09:00 - 09:25 0.42 RURD_ SLIK SLICK RU Braided line unit, mu lubricator and tool string with 4 prong wire grab. Stab on well. 09:25 - 09:30 0.08 TEST_ BOPE SLICK PT lubricator with Methanol to 1500 psig. 09:30 - 12:30 3.00 WORK SLIK SLICK RIH 4 prong wire grab 5 trips.Recover 38' wire in 4 pieces. 12:30 - 17:15 4.75 WORK SLIK SLICK RIH wire grab and wire finder 10 trips. Recover 161' in 10 pieces ranging from 6' to 20' recovered wire on all trips. 17:15 - 20:30 3.25 RURD_ SLIK SLICK Rig back unit for night. Secured well, left lease. 1/22/2007 08:00 - 08:45 0.75 SAFETY MTG_ MIRU Held PJSM. Discussed complete check list. Issue Permit. 08:45 - 10:00 1.25 RURD_ SLIK SLICK RU Slickline line unit, mu lubricator and tool string with 2" Wirefinder. Stab on well. Pressure test to 1500 psig, Pressure Test Good 10:00 - 10:50 0.83 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 542 BLM W/T, POOH - 10' wire (PT and RIH) 10:50 - 11:25 0.58 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 556' BLM W/T, POOH - 15' wire (PT and RIH) 11:25 - 12:00 0.58 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 572' BLM W/T, POOH - 8' wire (PT and RIH) 12:00 - 12:35 0.58 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 575' BLM W/T, POOH - 20' wire (PT and RIH) 12:35 - 12:55 0.33 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 602' BLM W/T, POOH - 15' wire (PT and RIH) 12:55 - 14:00 1.08 RUNPU BRDL SLICK Refill meth for pump, safety walk around 14:00 - 14:15 0.25 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 618' BLM W/T, POOH - 12' wire (PT and RIH) 14:15 - 14:45 0.50 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 630' BLM Wlr, POOH - 20' wire (PT and RIH) 14:45 - 15:15 0.50 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 647' BLM W/T, POOH - 25' wire (PT and RIH) 15:15 - 15:35 0.33 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 669' BLM W/T, POOH - 2' wire (PT and RIH) 15:35 - 16:00 0.42 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 675' BLM W/T, POOH - 15' wire (PT and RIH) 16:00 - 16:25 0.42 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 694' BLM W/T, POOH - 12' wire (PT and RIH) 16:25 - 17:15 0.83 RUNPU BRDL SLICK RIH w/ 2" Wirefinder and Grab to 703' BLM W/T, POOH - 12' wire (PT and RIH) 17:15 - 18:00 0.75 RURD_ SLIK SLICK Lay Lub and secure area for the night 18:00 - 18:30 0.50 RURD_ SLIK SLICK Sign out and return PWL shop 1/23/2007 08:00 - 08:45 0.75 SAFETY MTG_ MIRU Held PJSM. Discussed complete check list. Issue Permit. 08:45 - 09:55 1.17 RURD_ SLIK SLICK RU Braided line unit, mu lubricator and tool string with 4 prong wire Printed: 1/7/2008 4:30:42 PM • Marathon Oif Company Page 4 of 17 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Phase Description of Operations Date From - To ' Hours Code Code 1/23/2007 08:45 - 09:55 1.17 RURD_ SLIK SLICK grab. Stab on well. 09:55 - 10:05 0.17 TEST_ BOPS SLICK PT lubricator with Methanol to 1500 psig. 10:05 - 17:15 7.17 WORK SLIK SLICK RIH wire grab and wire finder 12 trips. Recover 166' in 12 pieces ranging from 2' to 25' recovered wire on all trips. First trip latched at 542'. Last trip latched at 703'. SD job for 20 minutes and did safety audit with full crew. 17:15 - 18:30 1.25 RURD_ SLIK SLICK Rig back unit for night. Secured well, left lease. 1/24/2007 08:00 - 09:30 1.50 SAFETY MTG_ MIRU Held PJSM. Discussed complete check list. Issue Permit. 09:30 - 09:45 0.25 RURD_ SLIK SLICK RU Braided line unit, mu lubricator and tool string with 4 prong wire grab. Stab on well. 09:45 - 09:55 0.17 TEST_ BOPE SLICK PT lubricator with Methanol to 1500 psig. 09:55 - 18:00 8.08 WORK SLIK SLICK RIH wire grab and wire finder 13 trips. Recover 224' in 12 pieces ranging from 15' to 30' recovered wire on all trips except 1. First trip latched at 717'. Last trip latched at 953'. 18:00 - 19:00 1.00 RURD_ SLIK SLICK Rig back unit for night. Secured well, left lease. 1/25/2007 07:30 - 08:45 1.25 SAFETY MTG_ MIRU Held PJSM. Discussed complete check list. Issue Permit. 08:45 - 10:45 2.00 RURD_ SLIK SLICK RU Braided line unit, mu lubricator and tool string with 4 prong wire grab. Stab on well. 10:45 - 10:55 0.17 TEST_ BOPE SLICK PT lubricator with Methanol to 1500 psig. 10:55 - 16:45 5.83 WORK SLIK SLICK RIH wire grab and wire finder 12 trips. Recover 164' in 11 pieces ranging from 8' to 20' recovered wire on all trips except 1. First trip latched at 975'. Last trip latched at 1148'. 16:45 - 17:30 0.75 RURD_ SLIK SLICK Rig back unit for night. Secured well, left lease. 1/27/2007 08:00 - 08:45 0.75 SAFETY MTG_ MIRU Held PJSM. Discussed complete check list. Issue Permit. 08:45 - 10:00 1.25 RURD_ SLIK SLICK RU Braided line unit, mu lubricator and tool string with sidewall wire cutter. Stab on well. 10:00 - 10:15 0.25 TEST_ BOPE SLICK PT lubricator with Methanol to 1500 psig. 10:15 - 12:05 1.83 RUNPU SLIK SLICK RIH sidewall cutter to 1615. Set down and cut wire. Shear off and POH 12:05 - 13:20 1.25 RUNPU SLIK SLICK Latch wire at 1150. POH 468' wire. 13:20 - 14:20 1.00 RUNPU SLIK SLICK RIH and retrieve cutter at 1637'. POH 14:20 - 16:15 1.92 RUNPU SLIK SLICK RIH sidewall cutter to 3911' and cut wire. Shear off and POH. 16:15 - 19:00 2.75 RUNPU SLIK SLICK Latch ware at 1620' and recover 2296' wire. 19:00 - 20:00 1.00 RUNPU SLIK SLICK Latch and recover cutter at 3911' 20:00 - 22:00 2.00 RURD_ SLIK SLICK Rig down unit and release from well. Move uNIT TO kbu 42-6 FOR TAG RUN. 6/13/2007 08:00 - 08:30 0.50 SAFETY MTG_ SLICK Arrive on location. Hold PJSM and obtain permit. 08:30 - 09:45 1.25 RURD_ SLIK SLICK Rig up equipment. Lick up lubricator and fishing tool string. 09:45 - 10:00 0.25 RURD_ SLIK SLICK Ptest lubricator and w/I BOP's. Test good. 10:00 - 11:00 1.00 RUNPU SLIK SLICK RIH with 2-1 /2" magnet to 4200' KB. POOH with 3" piece of wire. 11:00 - 12:30 1.50 RUNPU SLIK SLICK RIH with 3-1/2" Side Wall cutter tp 4232'. Cut wire. POOH. 12:30 - 14:00 1.50 RUNPU SLIK SLICK RIH with 3-1/2" wire finderw/ wire spear. to 3911' KB. Latch and pull wire OOH. Recover 321' of wire 14:00 - 15:10 1.17 RUNPU SLIK SLICK RIH with 3-1/2" JDC to 4232'. Latch and pull SW cutter. 15:10 - 16:20 1.17 RUNPU SLIK SLICK RIH with 2-1/2" magnet to 5704 KB. POOH. Recover 6" finger off of wire finder. 16:20 - 18:00 1.67 RUNPU SLIK SLICK RIH with 3-1/2" SW cutter to 5674' KB. Couldn't pass module. Pull up to 5661' KB. Cut wire. POOH. 18:00 - 18:30 0.50 RURD_ SLIK SLICK RIG down. Safe out well for the night. Leave location. 6/14/2007 07:00 - 07:30 0.50 SAFETY MTG_ SLICK Arrive on location. Hold PJSM and obtain permit. 07:30 - 08:00 0.50 RURD_ SLIK SLICK Rig Up Slickline Unit 08:00 - 09:08 1.13 WAITON EOIP SLICK Standby to fill up Hot Oil Truck w/ water to PT lub's and BOP's 09:08 - 09:15 0.12 TEST_ BOPE SLICK PT Lub and BOP, test good 09:15 - 11:00 1.75 RUNPU SLIK SLICK RIH w/ 3-1/2" Bowan Wirefinder w/ wire spear to 4232' KB, latch and Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Page 5 of 17 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Sub I , phase Description of Operations Date From - To Hours Code Code 6/14/2007 09:15 - 11:00 1.75 RUNPU SLIK SLICK pull wire, POOH 1,409' of wire on spear 11:00 - 11:45 0.75 RUNPU SLIK SLICK Spool wire on spooling device, 1409' of wire 11:45 - 12:35 0.83 RUNPU SLIK SLICK RIH w/ 3" JDC to 5661' KB, latch and pull side wall cutter, POOH 12:35 - 13:10 0.58 RUNPU SLIK SLICK RIH w/ 2-1/2" Magnet to 5704' KB, Tag POOH w/ nothing 13:10 - 14:00 0.83 RUNPU SLIK SLICK RIH w/ 2-1/2" JDC to 5704' KB, latch and pull Sidewall Cutter, POOH 14:00 - 14:35 0.58 RUNPU SLIK SLICK RIH w/ same to 5706' KB, latch and pull wirefinder, POOH 14:35 - 15:00 0.42 RUNPU SLIK SLICK RIH w/ 2.35" Blindbox to 5707' KB, beat down several times, POOH, Shows fishing neck on BBox 15:00 - 15:45 0.75 RUNPU SLIK SLICK RIH w/ 3-1/2" Bowan wire finder w/ wire spear to 5661' KB, Latch and pull wire, POOH 40' of wire. 15:45 - 16:15 0.50 RURD_ SLIK SLICK Rig Down for night 6/15/2007 07:00 - 07:20 0.33 SAFETY MTG_ SLICK Arrive on location. Hold PJSM and obtain permit. 07:20 - 08:15 0.92 RURD_ SLIK SLICK Rig Up Slickline 08:15 - 08:30 0.25 TEST_ BOPE SLICK PT Lubricator and BOP's, test good 08:30 - 09:40 1.17 RUNPU SLIK SLICK RIH w/ 2.50" JDC to 5707' KB, latch and Pull Fish, POOH. Have tool string 09:40 - 10:15 0.58 RURD_ SLIK SLICK Rehead and take off extra lubricator 10:15 - 10:30 0.25 TEST_ BOPE SLICK PT Lubricator and BOP's, test good 10:30 - 11:30 1.00 RUNPU SLIK SLICK RIH w/ 2.50" Pump Bailer to 5736' KB, work bailer, POOH, Bailer empty 11:30 - 12:30 1.00 RUNPU SLIK SLICK RIH w/ 2.50" Pump Bailer to 5736' KB, work bailer, POOH, 1/2 Full of sand 12:30 - 14:00 1.50 RUNPU SLIK SLICK RIH w/ 2.50" Pump Bailer to 5736' KB, work bailer, POOH, 1/2 Full of sand 14:00 - 15:00 1.00 RUNPU SLIK SLICK RIH w/ 2.50" Pump Bailer to 5738' KB, work bailer, POOH, 1/2 Full of sand 15:00 - 16:00 1.00 RUNPU SLIK SLICK RIH w/ 1.75" hydrostatic Bailer, work bailer, POOH. Full Bailer of sand and metal marks on mule shoe 16:00 - 16:40 0.67 RUNPU SLIK SLICK RIH w/ 3" RS to 5738' KB Couldn't Latch, POOH (NOTE: could be piece's of wire, wire finder fingers, and sand could be on fishing neck of Bulldog Spear) 16:40 - 17:30 0.83 RURD_ SLIK SLICK Rig down and clean up 11/7/2007 07:30 - 08:15 0.75 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and concurrent operations. 08:15 - 17:00 8.75 RURD_ COIL CMPFLW Spot and RU BJ coil unit. RU tanks, Buster, Supply tank, McOH, choke skid. Put 50 Bbls McOH in tank. 17:00 - 17:30 0.50 RURb_ COIL CMPFLW Finish BJ rigup ready to PT. SDFN. 11/8/2007 07:00 - 07:45 0.75 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and snow conditions. Issue permit. Jim Regg waived BOP test witness at 2:00 PM Nov 5. 07:45 - 15:15 7.50 RURD_ COIL CMPFLW Cut 50' of coiled tubing. RU Baker fishing tools, Connector, dbl cks, disconnect, bi-directional hipp tripper, JDC overshot. L = 17'. Fish consists of daniels packoff, cut off extension tube all baited with a bulldog spear with a 2.31" fishing neck looking up. L = 4'. Test Hipp Tripper and JDC. 0.5 BPM at 1300 psi and 0.75 BPM at 1700 psi. all works fine. 15:15 - 15:30 0.25 CMPFLW SD to avoid all night fishing. 15:30 - 16:30 1.00 CMPFLW Hipp Tripper is 2.875". Decide to trim OD to 2.80". Safe out well for night and leave location. 11/9/2007 07:00 - 07:45 0.75 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. 07:45 - 09:35 1.83 RURD_ COIL CMPFLW PU 20' of lubricator and Baker tools, Connector, dbl cks, disconnect, Hipp tripper, JDC pulling tool, L=17'. Stab on well. 09:35 - 09:45 0.17 TEST EOIP CMPFLW Test Bowen connection to 1000 psi. Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Page 6 of 17 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date ~ From - To Hours Code Cod I Phase Description of Operations e I 11/9/2007 09:45 - 10:45 1.00 RUNPU COIL CMPFLW Attempt to RIH. Difficult passing DSA above tree. 10:45 - 13:00 2.25 RUNPU COIL CMPFLW RIH. 13:00 - 13:30 0.50 WORK COIL CMPFLW Work Hipp Tripper to pass 2.80" JDC through top pert interval. Tagged at 5681'. Work down to 5683.5'. Unable to make progress. 13:30 - 14:10 0.67 RUNPU COIL CMPFLW POH CT to check tool and ensure we are not damaging tools or casing. 14:10 - 14:30 0.33 RURD_ COIL CMPFLW OOH. Check tools. Tool is marked for full length on one side from perfs. No indication we are damaging anything. Will run 2.80" Swage in AM. 14:30 - 16:00 1.50 RURD_ COIL CMPFLW Secure well for noght. Take crew to monthly safety meeting at KGF. 11!10/2007 07:00 - 08:00 1.00 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. 08:00 - 08:45 0.75 RURD_ COIL CMPFLW Warm up equipment 08:45 - 09:10 0.42 RURD_ COIL CMPFLW M/U lubricator to injector. 09:10 - 09:35 0.42 PULD_ BHA_ CMPFLW P/U Hipp-Tripper and 2.80" swedge 09:35 - 09:45 0.17 RURD_ COIL CMPFLW Go to well with injector. 09:45 - 10:00 0.25 TEST_ EQIP CMPFLW PT Bowen connection to 1000 psi. 10:00 - 11:15 1.25 RUNPU COIL CMPFLW Open well, RIH /WHP=Opsi. 11:15 - 11:30 0.25 PUMP_ WTR_ CMPFLW At 5500' with BHA, start pumping at .5bpm to establish circulation. 11:30 - 11:55 0.42 CLNOU TBG_ CMPFLW See differential pressure increase at 5683'. WHP=O, Coil=1200psi @ .5 bpm, RIW=7K, up wt.=14k 11:55 - 12:30 0.58 RUNPU COIL CMPFLW Beat down 1.5', PUH to check wt.No overpull, RBIH to 5684.3' and cont. swedging 12:30 - 12:40 0.17 RUNPU COIL CMPFLW Swedge at 5689.3' CTM, not seeing anything, PUH to 5679' and ease back in hole to 5717.2'. 12:40 - 14:15 1.58 CLNOU TBG_ CMPFLW Work swedge down to 5724' CTM. Unable to make any more progress. 14:15 - 14:35 0.33 CLNOU TBG_ CMPFLW Still at 5724', seeing sand in returns. 14:35 - 15:00 0.42 RUNPU COIL CMPFLW PUH to 5675', WHP=O, Coil=1200, Up wt=15k 15:00 - 15:15 0.25 RUNPU COIL CMPFLW RBIH to 5724', see little work with HT. 15:15 - 15:45 0.50 RUNPU COIL CMPFLW PUH again to 5675', shut down pump and RBIH for dry tag. 15:45 - 15:55 0.17 RUNPU COIL CMPFLW Dry tag at 5724' CTM. POOH pumping. 15:55 - 16:45 0.83 PULD_ BHA_ CMPFLW At surface, pop off well, lay down BHA, lubricator. 16:45 - 17:10 0.42 PUMP_ TRET CMPFLW Go to well with injector and displace kcl from coil with meth/water. 17:10 - 17:30 0.33 SECUR WELL CMPFLW Set down injector, place Hite cap on well, secure well and location for night. Turn in permit. 11/11/2007 08:00 - 08:45 0.75 SAFETY MTG_ SLICK Arrive on location. Hold PJSM and obtain permit. 08:45 - 10:20 1.58 RURD_ SLIK SLICK Move manlift. Spot equipment. Rig Up Slickline. PU 2.5" DD bailer. Stab on well. 10:20 - 10:30 0.17 TEST_ EOIP SLICK Test lubricator. 10:30 - 11:25 0.92 BAIL_ FILL SLICK RIH bailer. Tag at 5724' RKB. Bail down to 5730'. POH Recovered 2 cups sand. 11:25 - 11:30 0.08 TEST_ EQIP SLICK Test lubricator. 11:30 - 12:10 0.67 BAIL_ FILL SLICK RIH bailer. Tag at 5732' RKB. Bail down to 5732' RKB. POH Recovered 2 cups sand and bottom of bailed is damaged from fish. 12:10 - 12:15 0.08 TEST_ EQIP SLICK Test lubricator. 12:15 - 13:15 1.00 RUNPU SLIK SLICK Run 2.73" LIB. Tagged 5732'. POH. No impression. Side damage from perfs. 13:15 - 13:20 0.08 TEST_ EQIP SLICK Test lubricator. 13:20 - 14:45 1.42 BROAC CSG_ SLICK RUN 2.80" swage. Jar down through upper modulefrom 5686' to 5694' RKB. Pull back through upper module and stuck. Jar free and POH. 14:45 - 15:15 0.50 RURD_ SLIK SLICK Cut wire and rehead. 15:15 - 15:20 0.08 TEST_ EQIP SLICK Test lubricator. 15:20 - 17:55 2.58 BROAC CSG_ SLICK RUN 2.76" swage. Tag and drop through at 5704' Jar down and stick repeatedly at 5716". POH to cut wire. 17:55 - 18:00 0.08 TEST EQIP SLICK Test lubricator. Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Operations Summary Report Page 7 of 17 Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours j Code ~ Sub .phase Description of Operations ,Codes 11/11/2007 18:00 - 19:00 19:00 - 20:00 11/12/2007 07:00 - 08:00 08:00 - 08:45 08:45 - 09:15 09:15 - 10:00 10:00 - 10:45 10:45 - 12:15 12:15 - 14:30 14:30 - 15:15 15:15 - 16:45 16:45 - 17:00 17:00 - 17:15 17:15 - 18:30 11 /13/2007 07:00 - 08:00 08:00 - 08:45 08:45 - 10:00 10:00 - 10:45 10:45 - 12:25 11/14/2007 07:00 - 08:00 08:00 - 08:05 08:05 - 09:45 09:45 - 10:00 09:35 - 09:45 09:45 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 14:45 14:45 - 15:05 15:05 - 15:20 1.00 BROAC CSG_ SLICK RUN 2.76" swage. Tag and jar down at 5720'. Jar out for 30 min to get free. POH. 1.00 RURD_ SLIK SLICK Rig back for night. Sdecure well and leave location. 1.00 SAFETY MTG_ SLICK Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. 0.75 WORK SLIK SLICK Warm up equipment. MU tool string with 2.5" DD bailer. PT lubricator to 2000 psig. Good test. 0.50 WORK SLIK SLICK Open well, RIH to 5727' KBD. Work baiter to 5728', POOH. 0.75 WORK SLIK SLICK OOH with full bailer of sand. RIH with 2.5" DD. Tagged fo;; at 5729' KBD.- Work to 5730' KBD. POOH 0.75 WORK SLIK SLICK OOH with 1/4" full of sand. MU tool string RIH with sameDD too 5730' KBD. POOH with bailer. Metal marks on bottom of bailer. 1.50 WORK SLIK SLICK MU 2.76" swedge, RIH to 5718' KB. Beat down swedge, not making hole. Jar up for 30 minutes POOH with swedge. 2.25 WORK SLIK SLICK Cut 100' wire, RIH with 2.75" swedge to 5720' KBD. Beat down not making hole. Jar up 30 minutes. POOH 0.75 WORK SLIK SLICK MU 2.70" swedge, RIH to 5726' KB. Beat down swedge, not making hole. POOH with swedge. 1.50 WORK SLIK SLICK MU 2.75" swedge, RIH to 5718' KB. Beat down swedge, not making hole. Jar up for 30 minutes POOH with swedge. 0.25 WORK SLIK SLICK MU 2.5" DD bailer, RIH to 5724' KBD beat down to 2728' POOH 0.25 WORK SLIK SLICK OOH with bailer, 2 cups of sand. Marks on bottom. RD wire line. 1.25 RURD_ SLIK SLICK PWS left lease after riggind down and cleaning up around well. 1.00 SAFETY MTG_ PR1 EVL Hold PJSM and discussed todays operaations. 0.75 RURD_ COIL PR1EVL Warm up equipment. PU injector and take to well. Displace Methanol with KCL. 1.25 RURD_ COIL PR1EVL Break Bowen and bring injector to ground. Wind picking up and swinging injector. Decide to take back to well and displace the KCL with Methanol to keep coil from freezing. 0.75 RURD_ COIL PR1 EVL Break Bowen, take injector to cradle. Secured well. 1.67 RURD_ COIL PR1 EVL All personnel left location. 1.00 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. Warm up equipment during PJSM. 0.08 RURD_ COIL CMPFLW James Regg with the AOGCC waved the BOP test witness at 1630 hour on 11-13-2007. 1.67 TEST_ BOPE CMPFLW Performed BOP test. 300 psi low/4300 psi on high. good test. PU injector. Go to well with injector. Displace Methanol to Methanol tank with 28 bbls of 6% KCL. 0.25 RURD_ COIL CMPFLW Bled down coil, break Bowen connection. Take injector to ground, PU 2 ea. 8' sections of lubricator. P/U Hipp-Tripper and 2.80" swedge 0.17 RURD_ COIL CMPFLW Go to well with injector. 3.25 TEST_ EOIP CMPFLW PT Bowen connection to 1000 psi. 1.00 WORK COIL CMPFLW Open well, WHP=O psi. RIH with coil, dry tag down to 5718.5' CTM. Sat down, PU hole to 5711' CTM. Start pump at 0.75 BPM, RIH with hipp- tripper with 2.8" swedge. 0.50 PUMP_ WTR CMPFLW PIP= 1600 psig, work swedge down to 5719.3. Stalled hipp-tripper, PUH to 5715' CTM. RIH with swedge down to 5720.5'. Stalled 0.25 PUMP_ WTR_ CMPFLW PUH with coil, RIH with swedge working past tight spots. Total fluid pumped 67 BBL. Returns to flow back tank. 0.33 PUMP_ WTR_ CMPFLW Work tool down hole slowly, swedging working at 1300 psig to 2500 psig. Work down to 5722.5' pressure decreased. Work swedge to 5725.7' CTM. 0.25 PUMP_ WTR_ CMPFLW Stalled, PUH to 5712' CTM. RIH with swedge down to 5727.6' CTM. Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: MAINTENANCE/REPAIR Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours Code Code Phase Start: 1 /11 /2007 Rig Release: Rig Number: 1 Page 8 of 17 ~ Spud Date: 7/23/2005 End: Group: Description of Operations 11/14/2007 15:05 - 15:20 0.25 PUMP_ WTR CMPFLW Pressure increased PUH with coil. 15:20 - 15:30 0.17 PUMP_ WTR CMPFLW RIH with coil to 5723.0' CTM. PUH to 5659' CTM. 15:30 - 15:40 0.17 PUMP_ WTR CMPFLW Shut down pump to make dry run and tag top of fish. Ran in hole slow with 2.8" swedge to top of fish at 5729.4' CTM. 15:40 - 16:00 0.33 WORK COIL CMPFLW POOH with coil, keep pumping down back side while pulling out of hole with coil to keep the hole from producing fluid to the well. 16:00 - 17:00 1.00 TEST EOIP CMPFLW OOH with swedge. MU 2.8" X 2.31" overshot with hipp-tripper. Take to 17:00 - 17:30 0.50 WORk 17:30 - 18:15 0.75 WORN 18:15 - 19:20 1.08 WORN 19:20 - 19:30 0.17 RURD 19:30 - 20:30 1.00 RURD 11/15/2007 08:00 - 09:00 09:00 - 10:15 10:15 - 11:00 11:00 - 11:15 11:15 - 11:25 11:25 - 12:40 12:40 - 12:47 12:47 - 12:50 12:50 - 13:15 13:15 - 13:20 13:20 - 14:00 14:00 - 14:30 14:30 - 14:40 14:40 - 15:30 15:30 - 15:42 15:42 - 15:52 15:52 - 16:04 well. PT Bowen to 1000 psig. Open well RIH with coil. COIL CMPFLW Coil at 5579' CTM, Continue down hole tag top of fish at 5729.5' CTM. PUH with coil. No indication of fish. PU to 5718'. Start pump at 1.0 BPM, PIP= 1000 psig, RIH to top of fish. COIL CMPFLW Tag top of fish at 5730', put + 5000 Ibs down on fish while pumping. Shut down pump let pressure fall off to 0 psig. PU coil, no change in PU weight, PUW = 14, 000 psig. COIL CMPFLW POOH with coil. COIL CMPFLW OOH, close swab valve. Bled off coil, break out Bowen connection. PU injector and break out tool string. PU injector. go back to well head to displace coil with Methanol. COIL CMPFLW Finish rig back on coil. Secured well. Shut down all equipment. BJ left lease. 1.00 ~ SAFETY MTG_ ~ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. Warm up equipment during PJSM. 1.25 RURD_ COIL CMPFLW Startup equipment. PU lubricator. Go to well with injector. 0.75 RURD_ COIL CMPFLW Displace methanol out of coil to methano{ tank. Replace packing in lubricator. Continue displacing Methanol. 0.25 RURD_ COIL CMPFLW Disconnect lubricator. PU tool string-MHA, Hydraulic disconnect, Hipp-tripper, 2.80" JDC overshot.Re-install lubricator on WH. 0.17 TEST_ EOIP CMPFLW PT Bowen connection to 1000 psi. 1.25 RUNPU COIL CMPFLW Open well, WHP=O psi. Check Hipp-Tripper performance at various pump rates. RIH with with hipp- tripper with 2.8" JDC overshot. At 5600' check up weight-14K. Dry tag down to 5725' CTM. PU hole to 5710' CTM. No over-pull. Sat down again at 5725' Pu. No over-pull. 0.12 PUMP_ WTR_ CMPFLW Start pump at 0.5 BPM. RIH 5723'. Stall out. PUH. 0.05 PUMP_ WTR_ CMPFLW Increase rate to 1bpm @1800 psi. RIH to 5723'. Stall out-release pressure. PUH. 0.42 PUMP_ WTR_ CMPFLW Reduce rate to 3/4 bpm @ 1400 psi. Trip action not as good. Reduce rate to 1/2 bpm, better trip acton-hold @ 5723'. Try to work tool down hole. Very touchy-Hipp-tripper wants to stall out. Loosing tripper action. 0.08 RUNPU COIL CMPFLW Shut down pump. Let pressure bleed off. Set down. Stack out one last time in an attempt to latch into fish. POOH to change out Hipp-tripper. No over-pull. 0.67 RURD_ COIL CMPFLW Bump up in lubricator. OOH. Close swab valve. 0.50 RURD_ COIL CMPFLW Close swab. Break down lubricator. PU new Hipp-Tripper. Carry lubricator to the WH. 0.17 TEST_ EOIP CMPFLW Test shell to 1000 psi. Test good. 0.83 RUNPU COIL CMPFLW RIH with new Hipp-tripper and 2.80" OD overshot. 0.20 RUNPU COIL CMPFLW IH @ 5600'. Pull test 14K. Establish pump rate @ 3/4 bpm. 0.17 RUNPU COIL CMPFLW RIH Tag 5726'. Stall Hipp-Tripper. PUH. 0.20 PUMP_ WTR_ CMPFLW Reduce rate to 1/2 bpm 1300 psi. Run back in hole to 5726'. Hammer tripping good. Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Operations Summary Report Page 9 of 17 Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: ~ MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code ~ Sub phase Description of Operations Code 11/15/2007 16:04 - 16:08 0.07 RUNPU COIL CMPFLW 16:08 - 16:12 0.07 PUMP_ WTR CMPFLW 16:12 - 16:37 0.42 PUMP WTR CMPFLW 16:37 - 16:45 0.13 RUNPU COIL CMPFLW 16:45 - 16:55 0.17 RUNPU COIL CMPFLW 16:55 - 17:55 1.00 RUNPU COIL CMPFLW 17:55 - 18:15 0.33 RURD_ COIL CMPFLW 18:15 - 18:40 0.42 RURD_ COIL CMPFLW 18:40 - 19:15 0.58 RURD_ COIL CMPFLW 19:15 - 19:30 0.25 RURD_ COIL CMPFLW 11/16/2007 07:00 - 07:45 0.75 SAFETY MTG_ CMPFLW 07:45 - 08:10 0.42 RURD_ COIL CMPFLW 08:10 - 09:30 1.33 RURD_ COIL CMPFLW 09:30 - 10:00 0.50 TEST_ EOIP CMPFLW 10:00 - 10:50 0.83 RUNPU COIL CMPFLW 10:50 - 11:15 0.42 WORK COIL CMPFLW 11:15 - 11:40 0.42 WORK COIL CMPFLW 11:40 - 12:20 0.67 WORK COIL CMPFLW 12:20 - 12:40 0.33 WORK COIL CMPFLW RIH to 5726.2'. Pumping 1/2 bpm @ 1200 psi. RIH in bites-good hammer action. Increase rate to 1 bpm @ 1800 psi. Loose hammer action. Decrease rate to .85 bpm. Poor trip action. Decrease rate to .65 bpm. As Hipp-Tripper stalls out, we pickup to regain pressure and are slowly loosing hole. Acts like we are "hydraulicing" the toolstring up hole--off the fish. PUH to 5710'. Reduce rate to 1/3 bpm. RIH to 5736.9' Tag up. Our deepest penitration today. Shut down pump. Stack weight on fish. Bleed annulus pressure to 0. PU. No over-pull. POOH. OOH. Close swab. Break out lubricator. Lay down tool string. Displace coil w/ methanol. 28 BBLS. Bleed pressure off wellhead. Stand back lubricator. Tie off to tree. Disconnect injector assemblyand set down. Install night cap and secure well for the night. Turn in permit. Sign out. Leave location and lock gate. Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. Warm up equipment during PJSM. Startup equipment. PU lubricator. Go to well with injector. MU tool string with 2 1/8" up/down jars with a 2.8" overshot. Go to well with BHA. Displace methanol out of coil to methanol tank. Continue displacing Methanol. PT Bowen connection to 1000 psi. Open well, WHP=O psi. RIH with 2 1/8" jars with 2.8" JDC overshot. At 5600' check up weight-14K. Dry tag down to 5720' CTM. PUH to 5713', start pumping fluid at 0.3 BPM. RIH washing down to top of fish, sat down 5000 lbs. Set off jars. PIP - 450 psig. Increased PIR to 0.75 BPM. Shut off pump. PUH with coil, to 5699' CTM. PU weight + 3000 lbs. RIH with coil to 5720.9' CTM, PIR= 0.75 BPM. PIP= 1000 psig. Shut down pump. Sat down +4000 Ibs set jars off, PUH with coil. RIH washing down to top of fish. Shut off pump. Sat down 8000 Ibs. Set off jars. PUH with coil. PU weight + 3000 Ibs. POOH with coil. OOH with coil, Break off the Oil jars and overshot. MU BI hipp-tripper with 2.65" OD JDC. Go to well with tool string, injector, take to tree. note:Found small pieces of metal behind dogs in overshot. 12:40 - 13:00 0.33 WORK COIL CMPFLW PT shell to 1000 psig, Open well. RIH with coil. 13:00 - 14:00 1.00 WORK COIL CMPFLW Dry tag at 5733.5' CTM. Start pump @ 0.75 BPM. Fill coil, work hip tripper, shut down pump. PU coil +3000 Ibs PUW. RIH start pump, work hip tripper with 2.65" OD JDC on bottom. 14:00 - 14:35 0.58 WORK COIL CMPFLW Shut down pump, PIP down to 200 psig, PUH with coil +3000 Ibs pick up weight. POOH with coil. 14:35 - 15:40 1.08 WORK COIL CMPFLW OOH with coil, Shut in swab, break Bowen check tool string for fish~Nc __ n JDC. No visual marks. Take back to well. 15:40 - 16:00 0.33 WORK COIL CMPFLW RIH with Hipp-tripper and 2.65" OD wire line JDC. 16:00 - 16:30 0.50 WORK COIL CMPFLW Coil at 2000' CTM, 16:30 - 16:45 0.25 WORK COIL CMPFLW Coil at 5715' CTM, Dry tag top of fish, tag at 5725.5' CTM. PUH to 5724' Start pump at 0.5 BPM, hipp tripper working. RIH tagged fill at 5725.3' CTM. Stalled hip-tripper, PUH. Shut down pump. 16:45 - 17:00 0.25 WORK COIL CMPFLW Coil at 5722' CTM. Start pump at 0.75 BPM, hipp tripper working. RIH tagged fill at 5725.3' CTM. Stalled hipp-tripper, Pick up coil to 5655'. 17:00 - 17:30 0.50 WORK COIL CMPFLW RIH tag at 5725.5' CTM. Tagged up same place could not get any Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Operations .Summary Report Page 10 of 17 ~ Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 11/16/2007 17:00 - 17:30 0.50 WORK COIL 17:30 - 18:15 0.75 WORK COIL 18:15 - 18:40 0.42 RURD_ COIL 18:40 - 19:15 0.58 RURD COIL 19:15 - 19:30 0.25 RURD_ COIL 11/17/2007 08:00 - 09:00 1.00 SAFETY MTG 09:00 - 11:30 2.50 RURD COIL 11:30 - 12:00 I 0.501 RURD I COIL 12:00 - 13:00 I 1.001 RUNPULI COIL 13:00 - 13:20 I 0.331 WASH I FILL 13:20 - 14:00 0.67 WASH FILL 14:00 - 14:10 0.17 WASH FILL 14:10 - 14:20 I 0.171 WASH I FILL 14:20 - 14:40 I 0.331 WASH I FILL 14:40 - 15:20 0.67 SAFETY MTG_ 15:20 - 15:50 0.50 WORK COIL 15:50 - 16:10 0.33 RURD_ COIL 16:10 - 17:20 1.17 RURD COIL 17:20 - 17:30 ~ 0.17 ~ SAFETY ~ MTG_ 17:30 - 17:50 0.33 RURD_ SLIK 18:00 - 19:00 1.00 WORK SLIK 19:00 - 19:15 I 0.251 WORK 1 SLIK 19:15 - 19:30 19:30 - 19:45 11/18/2007 07:00 - 07:40 0.25 WORK~SLIK 0.25 RURD_ COIL 0.67 SAFETY MTG_ 07:40 - 09:15 09:15 - 10:00 1.58 RURD-COIL 0.75 RUNPUJCOIL 10:00 - 11:00 I 1.001 WASH I FILL CMPFLW deeper. POOH with coil. CMPFLW OOH. Close swab. Break out lubricator. Checked tool string no marks on JDC, trace of sand inside fishing neck. Lay down tool string. CMPFLW Displace coil w/ methanol. 28 BBLS. Bleed pressure off wellhead. CMPFLW Stand back lubricator. Tie off to tree. Disconnect injector assembly and set down. Install night cap and secure well for the night. CMPFLW Tum in permit. Sign out. Leave location and lock gate. CMPFLW Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. Warm up equipment during PJSM. CMPFLW Replace reel vavle on coil reel. Replace the level winder on coil unit, PU injector cut 250' 1 3/4" coil off of real. MU roll on coil connector on end of coil. CMPFLW MU tool string with CC, double check and 2 1/8" wash nozzle. Go to well with BHA. Displace methanol out of coil to methanol tank. CMPFLW Open well, WHP=O psi. RIH with 1 3/4" coil with wash nozzle down to 5500' CTM. Start pump at 0.5 BPM. CMPFLW RIH washing down to top of fish, tag top of fish at 5721' CTM. Set down 4000 Ibs would not wash off fish. PUH CMPFLW PUH to 5712' CTM. Increased pump rate to 1.5 BPM. RIH with coil to 5720.5' CTM. Sat on top of fish, would not wash off. PUH with fish. CMPFLW PUH to 5710' CTM. Increased pump rate to 2.0 BPM, RIH with coil to 5720.5' CTM. Sat on top of fish, would not wash off. CMPFLW PUH to 5699' CTM. Pump rate @ 2.0 BPM, RIH with coil to 5720.5' CTM. Sat on top of fish, would not wash off. CMPFLW PUH to 5710' CTM, Shut off pump, RIH to top of fish at 5720.3' CTM. No progress. POOH with coil. CMPFLW CLU pad had an ESD, shut down all pumping and wait till all clear to start back up on coil unit. CMPFLW OOH. Close swab. Break out lubricator. Checked tool string no marks on 2.8" JDC, trace of sand inside fishing neck. Lay down tool string. CMPFLW Displace coil w/methanol. 28 BBLS. Bleed pressure off wellhead. CMPFLW Stand back lubricator. Tie off to tree. Disconnect injector assembly and lay down. Ready well for wire line unit. BJ personnel left lease. CMPFLW Held PJSM with Pollard personnel and ASRC crane operator. Discussed procedure with wireline unit. PU lubricator go to Weill. CMPFLW MU 1.75" RS, KJ, 10' stem, KJ, Oil jars, spang jars with 2.80" LIB. CMPFLW Open well, RIH to top of fish @ 5675' KBD. Sat down high. Hit down twice. POOH with LIB. CMPFLW OOH with LIB, no marks. MU 2.5" LIB same tool string. Open well, RIH to 5733' KBD. POOH with LIB. OOH, found metal impressions on face of LIB. Wire line retrievable Spear fishing neck on LIB. CMPFLW RD wire line unit. Crew left lease. CMPFLW Tum in permit. Sign out. Leave location and lock gate. CMPFLW Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. Warm up equipment during PJSM. CMPFLW MU tool string with CC, double check and 2 1/8" Baker venturi basket. Go to well with BHA. Displace methanol out of coil to methanol tank. CMPFLW Open well, WHP=O psi. RIH with 1 3/4" coil with 2.13" venturi basket on end of coil. Sat down at 5704.5' CTM. Start pump at 1.5 BPM. CMPFLW RIH with coil while pumping. Sat down same spot. PU coil 10' to 5795' KBD. RIH at 10 FPM while pumping. PUH 100', RIH with out pumping. Tag up high. Changed pump rate while setting down. PUH 300', RIH with coil sat down at 5704' KBD. Printed: 1/7/2008 4:30:42 PM C: • Marathon Oil Company Page ~ 1 of 17 Operations Summary Report Legal Well Name: C ANNER Y LOO P UNIT 10 Common W ell Name: C ANNER Y LOO P UNIT 10 Spud Date: 7/23/2005 Event Nam e: MAINTE NANCE/ REPAI R Start: 1/11/2007 End: Contractor Name: G LACIE R DRILL ING Rig Release: Group: Rig Name: G LACIE R DRILL ING Rig Number: 1 ~ Date From - To j Hours Code Code Phase Description of Operations 11/18/2007 11:00 - 12:00 1.00 WORK COIL CMPFLW No progress, POOH with coil. CT at surface. Closed swab valve. 12:00 - 12:35 0.58 RURD_ COIL CMPFLW Take off walking dogs. Take injector to ground. MU BHA with 2.6" centralizer, 2 1/8" jar, x-over, 2.13" venturi basket with mule shoe on bottom. 12:35 - 12:40 0.08 RURD_ COIL CMPFLW Open swab valve. WHP = 0 psig. 12:40 - 13:00 0.33 WORK COIL CMPFLW RIH with coil. Sat down at 5725.0' CTM. PUH 2', RIH sat down same depth. Start pump at 1.5 BPM. 13:00 - 13:30 0.50 WORK COIL CMPFLW RIH with coil. Sat down at 5725.0' CTM. Work venturi basket, PU coil and RIH with coil. Pump pressure at 2600 psig. Coil stacking out at same depth. Flagged pipe. 13:30 - 14:14 0.73 WORK COIL CMPFLW POOH with coil. 14:14 - 15:00 0.77 RURD_ COIL CMPFLW OOH with coil. Shut swab valve 15:00 - 15:20 0.33 RURD_ COIL CMPFLW Take off walking dogs. Take injector to ground. Break out tool string found pieces of metal. Lay down Venturi basket and MU Baker 2.65" JDC on bottom. 15:20 - 15:30 0.17 RURD_ COIL CMPFLW Take tool string to well. Open swab. RIH with coil. 15:30 - 16:00 0.50 WORK COIL CMPFLW Coil at 5730.1' CTM. Dry tag top of fish, PU did not latch fish. PUH to 5725'. RIH to top of fish to 5731.3' CTM. Sat 5000 Ibs down on fish. Set off jars. PUH slowly. Did not latch fish. 16:00 - 16:40 0.67 PUMP_ WTR CMPFLW Start pump at 1.5 BPM. 12 bbls pumped PIP @ 3200 psig. RIH to top of fish 5731.1' CTM. Set jars off 2nd time. Shut down pump. PUH with coil, did not latch fish. 16:40 - 17:30 0.83 PUMP_ WTR_ CMPFLW Repeat working jars total of 5 times. No over pull, POOH with coil. 17:30 - 18:00 0.50 RURD_ COIL CMPFLW OOH with coil. Shut swab valve 18:00 - 18:30 0.50 RURD_ COIL CMPFLW Take off walking dogs. Swing lubricator, Break down tool string. Rig back coil tubing for night. 18:30 - 19:00 0.50 RURD_ COIL CMPFLW Displace coil with methanol to freeze protect coil. 19:00 - 20:00 1.00 RURD_ COIL CMPFLW Break Bowen, take lubricator and chain to tree. RD injector and rack back coil. Clean up around lease. BJ left location. 11/21/2007 07:00 - 08:30 1.50 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and wind hazards. Issue permit. Warm up equipment during PJSM. 08:30 - 11:00 2.50 RURD_ COIL CMPFLW RU CT and cut 125' coil. Displace McOH with KCI. Rehead and pick up motor ,boot basket, and cut lip guide to clean around fishing neck. 11:00 - 12:25 1.42 RUNPU COIL CMPFLW RIH and tag top pert at 5682' CTMD. PU and start motor. 12:25 - 16:25 4.00 MILL_ JUNK CMPFLW Attempt to drill through perfs with 2.80" OD carbide faced cut lip washover shoe. Made progress from 5682' to 5689' in 4 hours. Unable to progress in final 45 minutes. 16:25 - 17:10 0.75 RUNPU COIL CMPFLW POH to inspect cut lip guide. 17:10 - 18:00 0.83 RURD_ COIL CMPFLW Rig back CT for night. Redress cut lip guide and cut OD to 2.72". 18:00 - 18:30 0.50 RURD_ COIL CMPFLW Sign out and leave location. 11/22/2007 07:00 - 08:00 1.00 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and weather hazards. Issue permit. Warm up equipment during PJSM. 08:00 - 08:45 0.75 TEST_ BOPE CMPFLW Perform full weekly BOP test 250/4500 psi. Good test 08:45 - 10:00 1.25 RURD_ COIL CMPFLW PU Lubricator. Pick up motor ,boot basket, and 2.72" cut lip guide to clean around fishing neck. 10:00 - 12:25 2.42 RUNPU COIL CMPFLW RIH and tag at 5729.8' CTMD. PU and start motor at 1 BPM. Circulate 12 bbls to fill CT. 12:25 - 13:30 1.08 WSHOV ISH CMPFLW Wash over fish from 5729.8 to 5730.7'. Work through perfs at 0.5 BPM to try and catch trash in boot basket. 13:30 - 14:10 0.67 RUNPU COIL CMPFLW POH washover shoe and check boot basket. Recovered 1/4 cup metal. 14:10 - 14:30 0.33 RURD_ COIL CMPFLW LD motor /shoe and PU Hipp Tripper and JDC pulling tool 14:30 - 15:20 0.83 RUNPU COIL CMPFLW RIH 2.80" JDC pulling tool to latch fish. 15:20 - 15:40 0.33 RUNPU COIL CMPFLW Tag bottom at 1 BPM. SD pump and pull 25K (10K overpull). Start Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Page 12 of 17 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 11/22/2007 15:20 - 15:40 0.33 RUNPU COIL CMPFLW pump at 0.5 BPM. Came loose when Hipp Tripper started to hit. 15:40 - 16:35 0.92 RUNPU COIL CMPFLW POH. 16:35 - 17:00 0.42 RURD_ COIL CMPFLW OOH. No fish. ra ole d= m_aaed and has several pieces of metal lodged inside. LD tools to send JDC for repair and to modify bottom on venturi junk basket. 17:00 - 17:30 0.50 RURD_ COIL CMPFLW Freeze protect coiled tubing and all surface lines with 50/50 McOH. 17:30 - 18:00 0.50 RURD_ COIL CMPFLW Secure location, sigh out, turn in permit, and leave locagtion. 11/28/2007 07:00 - 08:00 1.00 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and weather hazards. Issue permit. Warm up equipment during PJSM. 08:00 - 10:00 2.00 RURD_ COIL CMPFLW PU Lubricator. Pick upCoil Connector, Dual check valve, Hydraulic disconnect, and Venturi Junk basket with 2.70" overshot skirt to clean around fishing neck. BHA 12.28' long. 10:00 - 10:25 0.42 RURD_ COIL CMPFLW Displace Methanol out of coil with 26 bbls of 6% KCL water. 10:25 - 11:00 0.58 RUNPU COIL CMPFLW Open well and RIH. 11:00 - 11:05 0.08 RUNPU COIL CMPFLW Call Jim Regg AOGCC. Give notice of weekly BOP Test. Jim waived witness. Just send in report. 11:05 - 11:50 0.75 RUNPU COIL CMPFLW Continue RIH. Tag at 5729.5' CTMD. PU and start pumping at 1/2 bpm. 11:50 - 11:54 0.07 WSHOV ISH CMPFLW Increase rate to 1-1/2 bpm. Returns to surface. 6 bbls to load hole. ~ 11:54 - 12:30 0.60 WSHOV ISH CMPFLW Wash top of fish at 5729.5. PUH 10' to 571 T. Wash back down over fish w/ Venturi nozzle, trying to catch trash in junk basket. 12:30 - 13:20 0.83 RUNPU COIL CMPFLW POOH with Venturi Junk basket. 13:20 - 14:30 1.17 RURD_ COIL CMPFLW OOH. LD Venturi Junk basket. Recovered 1/8 cup of small gravel size pieces of metal. Cut 120' of pipe of coil. 14:30 - 15:00 0.50 RURD_ COIL CMPFLW Install new coil connector, Pull test to 25K. Ptest to 3500 psi. PU Hipp Tripper and JDC pulling tool 15:00 - 15:15 0.25 RURD_ COIL CMPFLW Carry Lubricator to WH. 15:15 - 16:25 1.17 RUNPU COIL CMPFLW RIH 2.80" JDC pulling tool to latch fish. 16:25.- 16:27 0.03 RUNPU COIL CMPFLW @ 5700' PU weight 10K. Tag fish @5725' Set 4K down of fish. PU to 19K----9K overpull. Latched fish 16:27 - 16:30 0.05 RUNPU COIL CMPFLW PU to 11 K---2 over pull. Start pump @ 1/2 bpm. 16:30 - 17:00 0.50 RUNPU COIL CMPFLW Pump 12.7 bbls to load the hole. Hippe-Tripper hammering. 17:00 - 17:14 0.23 RUNPU COIL CMPFLW PU to 14K. Hippe-Tripper still hammering. PU to 17K @ 5724.8'. PU to 18K @ 5724.2'. Increase rate to 3/4 bpm. 17:14 - 17:16 0.03 RUNPU COIL CMPFLW Shut down pump. Straight pull to 25.5K(15K over pull). Fish won't move. 17:16 - 17:22 0.10 RUNPU COIL CMPFLW Slack off to 10K @ 5725.6'. PU to 13K and start pump @ 1/2 bpm. 17:22 - 17:28 0.10 RUNPU COIL CMPFLW Increase rate to 3/4 bpm. No hammer action. Bleed off pressure. Straight pull to 26K(16K over pull). 5722' No movement. 17:28 - 17:34 0.10 RUNPU COIL CMPFLW Slack off to neutral point -11.5K. Start pump @ 1/2 bpm. No hammer. Increase rate to 1-1/2 bpm. Lost weight-lost fish. Pumped off JDC. Set down of fish 4K. PU to 20K (10K over pull). Latched fish. 17:34 - 18:20 0.77 RUNPU COIL CMPFLW Have fish but no hammer. Try a variety of pump rates to regain the tripe hammer. PU to 36K( 26K over) No movement. 18:20 - 19:15 0.92 RUNPU COIL CMPFLW POH. 19:15 - 19:40 0.42 RURD_ COIL CMPFLW OOH. No fish. Recovered all tools. All tools in good shape. 19:40 - 20:30 0.83 RURD_ COIL CMPFLW reeze pro ec coi e u mg an a su ace Imes with 5 50 McOH. Stand back lubricator. Shut in well. 20:30 - 21:00 0.50 RURD_ COIL CMPFLW Secure location. Sign out, turn in permit, and leave location. 11/29/2007 08:00 - 09:00 1.00 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss complete checklist and weather hazards. Issue permit. Warm up equipment during PJSM. Printed: 1/7/2008 4:30:42 PM • • Marathon OiI Company Page 13 of 17 Operations Slummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From- To 11/29/2007 109:00 - 10:00 10:00 - 10:15 10:15 - 11:30 11:30 - 12:10 12:10 - 12:30 12:30 - 13:43 13:43 - 13:48 13:48 - 14:10 14:10 - 15:00 15:00 - 15:35 15:35 - 16:40 16:40 - 17:00 11/30/2007 07:00 - 08:00 08:00 - 08:50 08:50 - 09:30 09:30 - 10:50 10:50 - 10:52 10:52 - 11:12 11:12 - 12:08 12:08 - 13:00 13:00 - 14:15 14:15 - 14:40 14:40 - 15:30 15:30 - 16:00 16:00 - 16:50 16:50 - 17:15 12/1 /2007 07:00 - 07:30 07:30 - 08:00 08:00 - 08:15 08:15 - 08:35 08:35 - 08:45 08:45 - 09:25 09:25 - 09:35 09:35 - 09:45 CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 MAINTENANCE/REPAIR GLACIER DRILLING GLACIER DRILLING Hours Code Code Phase Spud Date: 7/23/2005 Start: 1/11/2007 End: Rig Release: Group: Rig Number: 1 Description of Operations 1.00 TEST_ BOPE CMPFLW Function test BOP. Ptest Blind/shears to 250/4500 psi. Ptest Pipe/.slips rams to 250/4500 psi. Test good. 0.25 RURD_ COIL CMPFLW Cut 120' of coil. 1.25 RURD_ COIL CMPFLW PU injector. Install grapple. Pull test to 25K. PTest coil to 3500 psi. 0.67 RURD_ COIL CMPFLW PU 24' of Lubricator. Pick up Dual check valve, Hydraulic disconnect, jars, 5' of weight bar, accelerator, and 2.80" JDC. BHA 24' long. 0.33 RURD_ COIL CMPFLW Displace Methanol out of coil with 26 bbls of 6% KCL water. 1.22 RUNPU COIL CMPFLW Open well( 24 turns). RIH. 0.08 RUNPU COIL CMPFLW Continue RIH. PU @ 5700'. UP weight 14.5K. Tag top of fish @ 5729.5' 0.37 JAR_ FISH CMPFLW Hit two jar licks of 25K. No movement. Hit eight more licks 30-32K. Pulled free. 15.8K drag (1.3K overpull). 0.83 RUNPU COIL CMPFLW POOH. 0.58 RURD_ COIL CMPFLW OOH. Close swab and master( 24 turns). No fish. Recovered all tools. Overshot damaged. Skirt belled our around "dogs" or grapple. No backup overshot. Send overshot to machine shop for repair. 1.08 RURD_ COIL CMPFLW Freeze protect coiled tubing and all surface lines with 50/50 McOH. Stand back lubricator. Shut in well. 0.33 RURD_ COIL CMPFLW Secure location. Sign out, turn in permit, and leave location. 1.00 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss JSA and job scope. Issue permit. Warm up equipment during PJSM. 0.83 RURD_ COIL CMPFLW PU 24' of Lubricator. Pick up Dual check valve, Hydraulic disconnect, jars, 5' of weight bar, accelerator, and 2.82" JDC. BHA 24' long. 0.67 RURD_ COIL CMPFLW Displace Methanol out of coil with 25 bbls of 6% KCL water. 1.33 RUNPU COIL CMPFLW Open well( 24 turns). RIH. 0.03 RUNPU COIL CMPFLW Continue RIH. PU @ 5650'. UP weight 14K. 0.33 JAR_ FISH CMPFLW Tag up in perfs @ 5678'. Hit one jar lick down. Gain some weight 3.5K. PU. Pull free @ 20K. Hit twice more down. Gain 3.5 K. Pull free @ 20K. 0.93 RUNPU COIL CMPFLW POOH to replace 2.82" OD skirt w/ 2.80" on JDC. 0.87 RURD_ COIL CMPFLW OOH. Close swab and master( 24 turns). Replace skirt on JDC. 1.25 RUNPU COIL CMPFLW RIH w/ 2.80" JDC. Up weight @ 5650' 14K. 0.42 RUNPU COIL CMPFLW Tag fish @5727.3. Paint coil. Jar up three time-21 K, 25K, and 25K. No movement. Jar down twice. No movement. Jar up twice -25K. Pull off fish both times. 0.83 RUNPU COIL CMPFLW POOH. 0.50 RURD_ COIL CMPFLW OOH. Close swab and master(24 turns). Breakout tools. Lower end of JDC "belled out" again behind dogs( 2.866" OD) Send 2.82" JDC skirt to machine shop to be turned down. 0.83 RURD_ COIL CMPFLW Install lubricator on tree. Freeze protect coiled tubing and all surface lines with30 bbls 50/50 McOH. Stand back lubricator. Shut in well. 0.42 RURD_ COIL CMPFLW Secure location. Sign out, turn in permit, and leave location. 0.50 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss JSA and job scope. Issue permit. Warm up equipment during PJSM. 0.50 RURD_ COIL CMPFLW Replace stripper rubber. 0.25 RURD_ COIL CMPFLW Cut 125' of coil. Install coil connector. 0.33 RURD_ COIL CMPFLW Install external grapple. Pull test to 25K. Test good. 0.17 RURD_ COIL CMPFLW PTest coil to 3500 psi. Test good. 0.67 RURD_ COIL CMPFLW PU 24' of Lubricator.lnstall BHA-coil connector, Dual check valve, Hydraulic disconnect, Intensifier, 5' weight bar, up/down hydraulic jars, 2.8" tapered JDC. 0.17 RURD_ COIL CMPFLW Take injector to WH. 0.17 RURD_ COIL CMPFLW Displace Methanol out of coil with 25 bbls of 6% KCL water. Printed: 1/7/2008 4:30:42 PM ~ A Marathon Oil Company Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Name: MAINTENANCE/REPAIR Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To ~ Hours Code Code Phase Start: 1 /11 /2007 Rig Release: Rig Number: 1 Page 14 of 17 ~ Spud Date: 7/23/2005 End: Group: Description of Operations 12/1/2007 10:10 - 11:15 1.08 RUNPU COIL CMPFLW Open well( 24 turns). RIH. 11:15 - 11:32 0.28 RUNPU COIL CMPFLW Continue RfH. PU @ 5600'. UP weight 14K. 11:32 - 12:44 1.20 JAR_ FISH CMPFLW Run thru perfs @ 5678'. Tag up in perfs @ 5720'. PUH. RIH @ 60 fpm. Tag up @5716.4'. PUH. RIH @ 60 fpm. Tag up @ 5716.3' Jar down twice. to 5717.8'. Continue jarring down. Jar 11 times total. Get to 5720'. Out of pipe cycles. 12:44 - 13:30 0.77 RUNPU COIL CMPFLW POOH. 13:30 - 14:12 0.70 RURD_ COIL CMPFLW OOH. Close swab and master( 24 turns). LD jars, accelerator, and JDC. PU Venturi junk basket. 14:12 - 15:00 0.80 RUNPU COIL CMPFLW RIH w/ Venturi junk basket. Up weight @ 5650' 14K. 15:00 - 15:16 0.27 RUNPU COIL CMPFLW Bring pump on @ 1/2 bpm. 15:16 - 15:30 0.23 RUNPU COIL CMPFLW Fluid returns to surface. 15:30 - 15:43 0.22 RURD_ COIL CMPFLW Increase rate to 1-1/2 bpm. 15:43 - 15:54 0.18 WSHOV ISH CMPFLW Tag up @ 5730'. Wash top of spear at 1-1/2 bpm. 15:54 - 16:00 0.10 WSHOV ISH CMPFLW Reduce rate to 1/2 bpm. Wash spear. 16:00 - 16:50 0.83 RUNPU COIL CMPFLW POOH. 16:50 - 17:10 0.33 RURD_ COIL CMPFLW OOH. Close swab and master(24 turns). Breakout tools. Recover 1/4 cup of BB size metal pieces. 17:10 - 17:30 0.33 RURD_ COIL CMPFLW Install lubricator on tree. Freeze protect coiled tubing and all surface lines with 30 bbls 50/50 McOH 17:30 - 18:30 1.00 RURD_ COIL CMPFLW LD lubricator. RD crane. 18:30 - 18:45 0.25 RURD_ COIL CMPFLW Secure location. Sign out, turn in permit, and leave location. 12/2/2007 08:00 - 08:30 0.50 SAFETY MTG_ SLICK Safety meeting and JSA,Warm upmEquip. 08:30 - 10:00 1.50 RURD_ SLIK SLICK Rig up slick fine. 10:00 - 10:30 0.50 RURD_ SLIK SLICK Wireline in hole with 2.80 swedge,could not get thru swab valve,ice in valve. 10:30 - 11:45 1.25 RUNPU SLIK SLICK RIH with 2.80 swedge, Pour in 5 gals.methenal down tree.Rih to 5733'KB Tap down on spear.POOH, Fluid level at 700'. 11:45 - 12:00 0.25 RUNPU SLIK SLICK RIH with 3" SS without dogs,to 5733' Pin did not shear but had marks on brass. 12:00 - 12:40 0.67 RUNPU SLIK SLICK RIH with same SS tool with dogs to 5733'Beat down to latch, jar up pulled free.POOH 12:40 - 13:50 1.17 RUNPU SLIK SLICK RIH with SS tool with dogs, latch on to fish jar 4 times and sheared off,POOH 13:50 - 17:45 3.92 BAIL_ FILL SLICK RIH with2.50 pump bailer,with 2.78 bottom,Bail sand retrived 1 quart of sand. 17:45 - 18:15 0.50 RUNPU SLIK SLICK RIH with RS running tool.Latch up and Jar shear tool and POOH. 18:15 - 19:00 0.75 RURD_ SLIK SLICK Rig Down slick line 08:00 - 08:30 0.50 SAFETY MTG_ CMPFLW Hofd safety meeting with BJ. Discuss JSA and job scope. Issue permit. Warm up equipment during PJSM. 08:30 - 10:00 1.50 RURD_ SLIK CMPFLW MIRU slick line. 10:00 - 10:30 0.50 RUNPU SLIK CMPFLW RIH w/ 2.80" swage to -8'. Close lower master valve. POOH. Ice on swage. Dump 5 gals. Methanol. 10:30 - 11:45 1.25 RUNPU SLIK CMPFLW RIH w/ 2.80" swage to 5733' KB. Tap down for 1 hour. POOH. Stickey off bottom. 11:45 - 12:00 0.25 RUNPU SLIK CMPFLW RIH w/ 3" SS w/o dogs to 5732' KB. Tap down. POOH. Small mark on pin. 12:00 - 12:45 0.75 RUNPU SLIK CMPFLW RIH w/ 3" RS to same depth. Jar down. Pull bind-pull free. POOH to check tool. 12:45 - 13:50 1.08 RUNPU SLIK CMPFLW RIH w/ same to 5733' KB. Beat down-latch. Hit 3 lick w/ oil jars. Game free. POOH. Sheered off. Marks on inside of RS. 13:50 - 15:00 1.17 RUNPU SLIK CMPFLW RIH w/ 3' SS w/o dogs to 5733' KB. Tap down-POOH. 15:00 - 15:45 0.75 RUNPU SLIK CMPFLW RIH w/ 2.5" Pump bailer to 5708' w1.-5729' KB. Try to work by. (2.18" Printed: 1/7/2008 430:42 PM • • Marathon Oil Company Page 15 of 17 ~ Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Phase Description of Operations Date. From - To Hours Code C ode 12/2/2007 15:00 - 15:45 0.75 RUNPU SLIK CMPFLW bottom) 15:45 - 17:00 1.25 RUNPU SLIK CMPFLW RIH w/ same w/ 2.70" botttom to 5733' KB. Tap down. Hung up. Jar free. Run back down-Pump. POOH. OOH. w/ 1/3 bailer full of sand. 17:00 - 17:45 0.75 RUNPU SLIK CMPFLW RIH w/ same to 5733'. Tap down. POOH. OOH w/ 1/4 full of sand. 17:45 - 18:15 0.50 RUNPU SLIK CMPFLW RIH w/ RS to same. Latch fish. Jar up. Shear tool. POOH. 18:15 - 19:00 0.75 RURD_ SLIK CMPFLW Rig down.. LD lubricator. Clean up area. Secure well. Finish paper work. Tum in permit. Sign out. Leave loc. 12/3/2007 08:00 - 08:15 0.25 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss JSA and job scope. Issue permit. Warm up equipment during PJSM. 08:15 - 09:00 0.75 RURD_ SLIK CMPFLW RU-cut wire. 09:00 - 09:45 0.75 RUNPU SLIK CMPFLW RIH w/ 2.5" Pump bailer w! 2.7" bottom to 5733' KB. POOH. Sticky off bottom. OOH. 1/4 full of sand. 09:45 - 10:45 1.00 RUNPU SLIK CMPFLW RIH w/ same to 5733' KB. Pump. POOH. OOH-1/4 full of sand. 10:45 - 11:45 1.00 RUNPU SLIK CMPFLW RIH w/ same to same. Recover 1/4 bailer full of sand. 11:45 - 13:00 1.25 RUNPU SLIK CMPFLW RIH w/ same to same. Recover 1/4 bailer full of sand. 13:00 - 14:30 1.50 RUNPU SLIK CMPFLW RIH w! same to same. recover 1/4 bailer full of fluid. 14:30 - 15:15 0.75 RUNPU SLIK CMPFLW RIH w/ 2.62" blind box. to 5733' KB. Beat down.. POOH. 15:15 - 16:00 0.75 RUNPU SLIK CMPFLW RIH w/ 2.5" Pump bailer to same. Tap down. POOH. OOH. Recover 1/3 cup of sand. 16:00 - 17:00 1.00 RUNPU SLIK CMPFLW RIH w/ 3.0" RS. to same. Latch fish. Jar up. Shear tool. POOH 17:00 - 18:30 1.50 RUNPU SLIK CMPFLW Re-pin. RIH wl 3.0" RS to same. Latch fish. Beat up w/ oil jars for 45 minutes. Sheared tool. POOH. 18:30 - 19:30 1.00 RUNPU SLIK CMPFLW Cut 100' of wire. Re-pin. RIH w/ same to same. Latch fish. Jar up w/ oil jars. Come free(10' up). Hung up. Tap down hole. Jar up. Came free. POOH. OOH w/ Bulldog spear. Underside of upper fishing neck beginning to round off. 19:30 - 20:15 0.75 RUNPU SLIK CMPFLW RIH w/ 2.70" LIB to 5734'. Tap down. POOH-Impression of spacer i e. Clean cut. 20:15 - 20:45 0.50 RURD_ SLIK CMPFLW Rig down.. LD lubricator. Clean up area. Secure well. Finish paper work. Turn in permit. Sign out. Leave loc. 12/4/2007 08:00 - 09:00 1.00 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss JSA and job scope. Issue permit. Warm up equipment during PJSM. 09:00 - 12:00 3.00 WAITON WTHR CMPFLW Send Bulldog spear to machine shop for modifications. Prepare to Pump bail. Wait on weather. Wind gusts over Marathon limit for man-lifts and mast trucks. 12:00 - 13:00 1.00 RURD_ SLIK CMPFLW RU slick line. PU lubricator. MU tool string. PTest lubricator. 13:00 - 15:00 2.00 RUNPU SLIK CMPFLW Start in the hole, w/I unit making strange noise 3 of 4 bolts on PTL drive shaft sheared off. POOH. Wait on mechanic. 15:00 - 16:20 1.33 RUNPU SLIK CMPFLW WHP- 120 psi. RIH w/ 2.5" pump bailer w/ 2.70" x 1.5' bottom skirt. Fluid level 1130'. Tap down to 5734' KB. Work bailer. POOH. OOH bailer empty. Metal marks on inside of skirt mouth. Metal rolled in. 16:20 - 17:15 0.92 RUNPU SLIK CMPFLW Pressure up lubricator to 400 psi. RIH w/ 2.5" Pump bailer w/ 2.70" x 1.5' bottom to 5734' KB.. Work bailer. POOH. OOH. Bailer empty. Metal marks on inside of bailer mouth again. 17:15 - 18:15 1.00 RUNPU SLIK CMPFLW Pressure up lubricator to 400 psi. RIH w/ 2.5" Pump bailer w! 2.70" x 6" bottom to 5734' KB.. Work bailer. POOH. OOH. Bailer empty. Metal marks on inside of bailer mouth again. 18:15 - 18:20 0.08 RUNPU SLIK CMPFLW Discuss options with Mickey. Decide to wash-over fish with CTU in the morning. 18:20 - 19:30 1.17 RURD_ SLIK CMPFLW Rig down.. LD lubricator. Clean up area. Secure well. Finish paper work. Turn in permit. Sign out. Leave loc. 12/5/2007 08:00 - 09:30 1.50 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss JSA and job scope. Issue permit. Warm up equipment during PJSM. Printetl: 1/7/2008 4:30:42 PM • • Marathon Oil Company Page 16 of 77 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To ~ Hours Code Code Phase Description of Operations i 12/5/2007 09:30 - 12:00 2.50 WAITON WTHR CMPFLW Wait on weather. Wind gusts over Marathon limit for man-lifts and cranes. Notify Jim Regg, AOGCC, of Weekly BOP Test tomorrow. Mr. Regg waived witness. 12:00 - 13:30 1.50 WAITON WTHR CMPFLW Wind still above working limits. Call it a day at 13:30. Lower all light towers for the night. 13:30 - 14:00 0.50 RURD_ COIL CMPFLW Clean up area. Secure well. Finish paper work. Turn in permit. Sign out. Leave loc. 12/6/2007 07:00 - 08:00 1.00 SAFETY MTG_ CMPFLW Hold safety meeting with BJ. Discuss JSA and job scope. Issue permit. 08:00 - 10:00 2.00 RURD_ COIL CMPFLW Start equipment. Clear snow from work area. 10:00 - 11:30 1.50 TEST_ BOPE CMPFLW Function test BOP's. One line on pipe rams disconnected. Reconnect. Funtion rams. OK. PTest pipe rams 250/ 4200 psi. Test good. PTest blind/shear rams 250/4200 psi. Test good. 11:30 - 14:00 2.50 RURD_ COIL CMPFLW Prime up unit to displace methanol. in coil. Valve on frac tank frozen. Move heater to put heat on supply tank valve. Call Steam on Wheels. Send vac truck to KGF for load of KCL water. Call for second truck. PU first joint of lubricator and tool string-Coil connector, DFCVaIve, DF Hydraulic disconnect, Dual circ sub. 14:00 - 14:15 0.25 RURD_ COIL CMPFLW Pressure test coil, connector, and BHA to 3500 psi. 14:15 - 15:00 0.75 RURD_ COIL CMPFLW Prime up unit to displace methanol from coil. Displace coil-26 bbls. 15:00 - 16:00 1.00 RURD_ COIL CMPFLW PU remaining lubricator and tool string Extreme Motor, Venturi Junk Basket, wash-over sub (length 26.56'). Carry lubricator to WH. 16:00 - 16:10 0.17 RURD_ COIL CMPFLW Fill lubricator. Test shell to 1000 psi. Test good. 16:10 - 17:10 1.00 RUNPU COIL CMPFLW Open swab and Master valves (24 turns). WHP- 245 psi. RIH Pumping min rate. 17:10 - 17:17 0.12 RUNPU COIL CMPFLW Hold @ 4500', have pumped 10 bbls., increase rate to 1 bpm. 17:17 - 17:25 0.13 RUNPU COIL CMPFLW 19 bbls. pumped, 1300 psi. returns at a trickle. RIH. 17:25 - 17:32 0.12 RUNPU COIL CMPFLW Pumping @ 1/2 bpm, returns to surface. 17:32 - 17:45 0.22 RUNPU COIL CMPFLW Up weight @ 5500' is 12K. 17:45 - 18:15 0.50 RUNPU COIL CMPFLW Tag up @ 5725.7' CTM PU to 5720'. Electric depth counter quit as we pulled up hole. Shut down to repair depth counter. 18:15 - 18:24 0.15 RUNPU COIL CMPFLW Depth counter repaired. 44.6 bbls pumped. Bring pump on line @ 1 bpm. Catch fluid after 2 bbls. 18:24 - 18:40 0.27 MILL_ FISH CMPFLW Tag up @ 5724.3'. Paint coil at counter. PU to 5722' CTM. Reduce rate to 1/2 bpm. Begin milling down. 18:40 - 18:45 0.08 MILL_ FISH CMPFLW Parked @ 5724.5'CTM milling at 800 psi. (200 psi over motor free spin). Fish taking weight, then drilling off. 18:45 - 19:00 0.25 MILL_ FISH CMPFLW PU to 5722' CTM. Increase rate to 1 bpm. RIH milling inch by inch to 5724.5' CTM. 19:00 - 19:10 0.17 MILL_ FISH CMPFLW PUH (above perfs of modules 11 and 12) to 5665'. Milling slowly back down. 19:10 - 19:16 0.10 MILL_ FISH CMPFLW Milling @ 5721.7' CTM. PIP 1388 psi. Pumping at 1 bpm. 19:16 - 19:20 0.07 MILL_ FISH CMPFLW Milling @ 5724.8' CTM-1 bpm at 1476 psi. PUH to 5708'. 19:20 - 19:30 0.17 CIRC_ CFLD CMPFLW RIH to 5722' CTM. Park just above fish and circulate. 19:30 - 20:30 1.00 RUNPU COIL CMPFLW POOH. 20:30 - 21:00 0.50 RURD_ COIL CMPFLW OOH. Close upper master. Break off lubricator. LD tools. Less than a thimble full of metal cuttings in Venturi JB. Wear marks on bottom of washover shoe. Only a little wear on internal cutting structure-some structure missing ,but most looks new. Carry lubricator back to WH. 21:00 - 21:30 0.50 RURD_ COIL CMPFLW Displace coil with methanol-30 bbls. Pump 2 bbls into surface lines and down well. 21:30 - RURD_ COIL CMPFLW Shut all suface valves. LD lubricator. Set injector into craddle. 13:30 - 14:00 0.50 RURD_ COIL CMPFLW Clean up area. Secure well. Finish paper work. Turn in permit. Sign out. Leave foc. Printed: 1/7/2008 4:30:42 PM • Marathon Oil Company Page 17 of 17 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: MAINTENANCE/REPAIR Start: 1/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date I From - To .Hours ~ Code Code Phase I .Description of Operations 12/7/2007 07:45 - 08:15 0.50 SAFETY MTG_ CMPFLW Hold safety meeting with Pollard. Discuss JSA and job scope. Issue permit. 08:15 - 10:00 1.75 RURD_ SLIK CMPFLW RU slick line unit. PU lubricator and toolstring. MU 2.75" LIB. 10:00 - 11:30 1.50 RUNPU SLIK CMPFLW Well on vacuum. RIH w/ 2.75" LIB to 5734' KB. Tap down once. POOH. Fluid level at 810'. OOH. LIB has clear impression of 1.91" OD spacer pipe. 11:30 - 12:30 1.00 RUNPU SLIK CMPFLW RIH w/ 2.5" Pump bailer w/ 2.7' x 2" bottom to 5734' KB. Work bailer. POOH. Bailer full of water, otherwise it's clean. 12:30 - 13:45 1.25 RUNPU SLIK CMPFLW RIH w/ 2-1/2" RB w/ core extension and releasable Bulldog spear. Spear takes 3" JDC pulling tool to release.) Run to 5734' KB, tap spear down into fish. Latch fish. Hit jar licks. Fish came free.., POOH, slowly. OOH. Reoever 1.91" spacer pine and DD packoff._ 13:45 - 14:30 0.75 RUNPU SLIK CMPFLW RIH w/ 3" RS to fish "F" collar stop to 5736' KB. Tap down. Could not latch. POOH. OOH-Flat marks on RS. Skirt bend in. 14:30 - 15:45 1.25 RUNPU SLIK CMPFLW RIH w/ 2.75" LIB to 5736' KB. Tap down once. POOH. OOH. Impression of junk on top of "F" collar stop. Stand by for tools. 15:45 - 16:20 0.58 RUNPU SLIK CMPFLW RIH w/ 1.75" earth magnet to 5736'. POOH. OOH. Recover small fines, no large chunks of metal. 16:20 - 17:15 0.92 RUNPU SLIK CMPFLW RIH w/ 3-1/2" braided line brush to 5736' KB. Work brush. POOH. OOH-recover large, circular piece of metal that matches impression in LIB. 17:15 - 18:00 0.75 RUNPU SLIK CMPFLW RIH w/ 3" JUC overshot to 5736' KB. Could not latch up. POOH. OOH. No metal marks. 18:00 - 19:00 1.00 RURD_ COIL CMPFLW RD for the night. Install night cap. Close all valves on the tree. Secure location. 19:00 - 19:15 0.25 RURD_ SLIK CMPFLW Turn in permit. Sign out. Leave loc. Lock gate. 12/8/2007 07:50 - 08:15 0.42 SAFETY MTG_ CMPFLW Hold safety meeting with Pollard. Discuss JSA and job scope. Issue permit. 08:15 - 08:45 0.50 RURD_ SLIK CMPFLW RU slick line unit. PU lubricator and toolstring. MU 2.75" LIB. 08:45 - 09:20 0.58 RUNPU SLIK CMPFLW Well on vacuum. RIH w/ 2.70" LIB to 5734' KB. Tap down once. POOH. OOH. LIB has clear impression of Fishing neck of "F" collar stop. 09:20 - 10:15 0.92 RUNPU SLIK CMPFLW RIH w/ 3"JUC, XO, knuckle joint, 3' of stem, knucke joint to 5736' KB. Tap down several times. Latch fish. Hit jar licks up. Came free. POOH. OOH with "F" collar stop. Missing one of wires on leg. 10:15 - 11:15 1.00 RUNPU SLIK CMPFLW RIH w/ 2.5" DD bailer to 6980' KB. Tag up. Work bailer. Sticky cant work down. POOH. Bailer full of junk-1 /2 of Rubber seal from DD packoff, and wire from "F" collar stop. 11:15 - 12:00 0.75 RUNPU SLIK CMPFLW RIH w/ 1-314" DD bailer to 7275' KB. Work bailer down to 7278'. POOH. OOH. Recover bailer full of fine gray muck. 12:00 - 12:15 0.25 SAFETY MTG_ CMPFLW Hold pre rig down JSA. 12:15 - 13:00 0.75 RURD_ COIL CMPFLW RD w/I unit. Install night cap. Close all valves on the tree. Secure location. 13:00 - 13:15 0.25 RURD_ SLIK CMPFLW Turn in permit. Sign out. Leave loc. Lock gate. Printed: 1/7/2008 4:30:42 PM • • Marathon Oil Company Page 1 of 7 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: RECOMPLETION Start: 12/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date ;From - To Hours Code Code Phase Description of Operations 12/9/2007 ~ 07:30 - 08:10 ~ 0.67 ~ SAFETY ~ MTG_ ~ CTBG 08:10 - 10:00 1.83 RURD_ COIL CTBG 10:00 - 10:05 0.08 TEST_ EQIP CTBG 10:05 - 12:47 2.70 RUNPU COIL CTBG 12:47 - 13:09 0.37 CLNOU CSG_ CTBG 13:09 - 13:42 0.55 CLNOU CSG_ CTBG 13:42 - 14:42 1.00 CLNOU CSG CTBG 14:42 - 15:15 0.55 CIRC_ CFLD CTBG 15:15 - 16:15 1.00 RUNPU COIL CTBG 16:15 - 17:30 1.25 RURD_ COIL CTBG 12/10/2007 08:00 - 08:45 0.75 SAFETY MTG_ PATCH 08:45 - 10:00 1.25 RURD_ ELEC PATCH 10:00 - 11:10 1.17 RUNPU ELEC PATCH 11:10 - 11:30 0.33 RUNPU ELEC PATCH 11:30 - 11:45 0.25 SAFETY MTG PATCH Hold safety meeting with BJ. Discuss complete checklist and snow hazards. Issue permit. Warm up equipment during PJSM. RU CT and PU 2-1 /8"jet nozzle. Stab on injector. Test Bowen connection to 1000 psi. Good test. RIH pumping at 1BPM Jet fill from 6300' at 1.5 BPM Tag hard spot. Increase pump rate to 2 BPM Break through hard spot and jet down to 8339' CTMD at 1.5 BPM. Unable to jet deeper. Circulate 30 min at 1.5 BPM. POH RD, Secure location, and sign out. Arrive on location. Hold PJSM and obtain permit. RU Expro eline unit and PU 2.63" Magnet. RIH 2.63" magnet to drift for bridge plug. Tagged at POH Magnet SD all toms including SCADA. Hold explosives safety meeting and complete perforation checklist. 11:45 - 12:48 1.05 RUNPU ELEC PATCH RIH 3-1/2" composite bridge plug (run OD = 2.56"). 12:48 - 12:55 0.12 PATCH Set composite bridge plug at 5788' ELMD. 12:55 - 13:30 0.58 RUNPU ELEC PATCH POH 13:30 - 14:30 1.00 RURD_ ELEC PATCH RD and secure location. 12/12/2007 08:00 - 09:00 1.00 SAFETY MTG_ WBPREP Hold PJSM. Obtain work permitt. Discuss BJ JSA and job scope. Called MR. Jim Regg-AOGCG 3:OOpm, December 10, 2007. Give notice of pending Weekly BOP test. Mr. Regg waived witness. He said to proceed and submit followup report. 09:00 - 10:00 1.00 RURD_ CMT_ WBPREP RU cement pump truck and batchmixers. PU injector. Install coil connector. 10:00 - 11:00 1.00 RURD_ COIL WBPREP Cut off coil grapple. Dress coil end. Install new coil connector. Pull test to 15K. Good test. 11:00 - 11:30 0.50 RURD_ CMT_ WBPREP Carry Injector to WH. Install walking dogs. RU vac trucks. Measure water into MX. 11:30 - 13:00 1.50 RURD_ CMT_ WBPREP RU bulk cement to MX. Displace MEOH in coil w/ 6% KCL to MEOH tank. Coil displaced-26 bbls. 13:00 - 13:15 0.25 RURD_ COIL WBPREP Test Bowen's to 1000 psi. Test good. Leave 528 psi on coil. Open Masters' and swab( 23 turns.) 13:15 - 13:45 0.50 RUNPU COIL WBPREP RIH with cement nozzle. Pumping min rate. 705 psi WHP. 13:45 - 14:40 0.92 RUNPU COIL WBPREP Continue RIH. Start mixing cement. Finish at 14:00. Returns to surface @ 14:30. 14:40 - 14:55 0.25 RUNPU COIL WBPREP Tag Composite BP @ 5764' KB. Fresh water displaced to nozzle. Pump additional 20 bbls of fresh water. 14:55 - 15:15 0.33 SAFETY MTG_ WBPREP Shut down for PJSM discussing detailed job procedures. 15:15 - 15:36 0.35 PUMP_ WTR_ WBPREP Conduct pre-job injection test. Circulating @ 1/2, 1, 1-1/2 BPM. Conduct formation injection test at same rates. 15:36 - 15:44 0.13 SPOT_ CMT_ WBPREP Pum 6 bbls of 15.8 PPG cement 990 si um ressur @ 1 bpm. 15:44 - 16:04 0.33 SPOT_ CMT_ WBPREP Pump 20 bbls fresh water displacement. Cement to nozzle of coil. 16:04 - 16:12 0.13 SPOT_ CMT_ WBPREP Shut down. Open returns tank. Top of displacement tank. 16:12 - SPOT CMT WBPREP Pump 2 bbls Cil 1/2 bpm out nozzle Cc~ 5741' CTM. Beain PUH aC~ 57 15:30 - 16:30 1.00 SPOT_ _ CMT_ WBPREP Pump 3-1/2 bbls @ 1/2 bpm, while pulling up hole at 57 fpm. 16:30 - SPOT_ CMT_ WBPREP Shut down pump. PUH to 5070' CTM. Pump remaining 1/2 bbl of displacement. 16:30 - 17:15 0.75 RUNPU COIL WBPREP POOH. While circulating KCL. Printed: 1/7/2008 4:32:08 PM • • Marathon Oil Company Operations Summary Report Page 2 of 7 Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: RECOMPLETION Start: 12/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase I Description of Operations 12/12/2007 17:15 - 17:35 0.33 RUNPU COIL WBPREP OOH. Close master valves. Displace coil with Methanol. 28 bbls. 17:35 - 17:40 0.08 RURD_ COIL WBPREP Circulate 2 bbls methanol into WH. 17:40 - 18:35 0.92 TEST_ BOPE WBPREP Function test BOP's. PTest Pipes/slips 250/4500 psi. PTest Blind/shear rams 250/4500 psi.l Test good. Function test Accumulator 18:35 - 19:15 0.67 RURD_ COIL WBPREP RD injector. Secure location for the night. 19:15 - 19:30 0.25 RURD_ COIL WBPREP Tum in permit. Sign out and leave location. 12/13/2007 07:00 - 08:00 1.00 SAFETY MTG_ WBPREP Hold PJSM. Obtain work permitt. Discuss BJ JSA and job scope. Discuss motor parameters w/ Baker tool hand 08:00 - 09:00 1.00 RURD_ COIL WBPREP Carry injector to well head and install. 09:00 - 09:30 0.50 RURD_ COIL WBPREP Displace methanol from coil w/ 6% KCL water. 26 bbls. 09:30 - 10:15 0.75 RURD_ COIL WBPREP Remove inject from WH. PU 24' of lubricator to accomodate BHA. 10:15 - 10:35 0.33 RURD_ COiL WBPREP Install coil grapple. Pull test to 25K. Good test. 10:35 - 10:55 0.33 RURD_ COIL WBPREP PU DFCheck valve, Bowen Oil Jars, FAU Hydraulic disconnect. PTest coil to 3400 psi. Test good. 10:55 - 11:35 0.67 RURD_ COIL WBPREP PU Dual circulation sub, String mill/centralizer, M1 W1 Mud motor, 2.70" Tri bladed junk mill. Carry lubricator to WH. Install walking dogs. 11:35 - 12:41 1.10 RUNPU COIL WBPREP RIH w/ BHA. WHP 15 psi. Shell test 1500 psi. 12:41 - 12:50 0.15 RUNPU COIL WBPREP RIH @ 4860' CTM Pumping 1 bpm 676 psi. 12:50 - 13:00 0.17 RUNPU COIL WBPREP RIH @ 5070' CTM Pumping 1 bpm - no cement. 13:00 - 13:06 0,10 RUNPU COIL WBPREP RIH @ 5250' CTM Pumping 1 bpm -no cement. 13:06 - 13:34 0.47 RUNPU COIL WBPREP RIH @ 5300' CTM Pumping 1 bpm -no cement. Circulate bottoms up. 13:34 - 14:11 0.62 RUNPU COIL WBPREP RIH @ 5400' CTM Pumping 1 bpm -no cement. Circulate bottoms up. 14:11 - 14:40 0.48 RUNPU COIL WBPREP RIH @ 5510' CTM Pumping 1 bpm ,pressure increases-indicating soft cement. 14:40 - 14:43 0.05 RUNPU COIL WBPREP 'Watching returns. Very fine particles of cement in returns. 14:43 - 14:54 0.18 MILL_ PLUG WBPREP T Motor stalled. 14:54 - 15:05 0.18 MILL_ PLUG WBPREP Milling cement at 5 fpm, 1 K on bit , 1520 psi on motor. 15:05 - 17:05 2.00 MILL_ PLUG WBPREP Milling @ 5564'. ROP 2-1/2 to 3 fpm. 17:05 - 17:30 0.42 MILL_ PLUG WBPREP Mill to 5700' CTM. Circulate bottoms up-36 bbls. 17:30 - 17:33 0.05 TEST_ CMT_ WBPREP PUH above perfs at 5674-84' Pressure test to 1500 psi. 17:33 - 17:44 0.18 TEST_ CMT_ WBPREP WHP 1527 psi. 17:44 - 17:47 0.05 TEST_ CMT_ WBPREP WHP 1465 psi. 17:47 - 17:50 0.05 TEST_ CMT_ WBPREP WHP 1463 psi. Release pressure. 17:50 - 18:10 0.33 RURD_ COIL WBPREP Lubricator leaking slightly. Repair leak. 18:10 - 18:30 0.33 MILL_ PLUG WBPREP Run back in hole to 5700' milling. 18:30 - 19:11 0.68 MILL_ PLUG WBPREP Milling 1.5K on mill, 1843 psi on motor. 19:11 - 19:36 0.42 MILL_ PLUG WBPREP Mill to 5745' CTM. Circulate bottoms up. PUH. 19:36 - 19:38 0.03 MILL_ PLUG WBPREP PUH to 5049' CTM. 35 bbls pumped. Cuttings plugging choke. Rock choke to clear. 19:38 - 19:43 0.08 MILL_ PLUG WBPREP Pressure test both perforation intervals to 1727 psi. 19:43 - 19:48 0.08 TEST_ CMT_ WBPREP 1664 psi. 19:48 - 19:52 0.07 TEST_ CMT_ WBPREP 1546 psi. 19:52 - 19:54 0.03 TEST_ CMT_ WBPREP 1550 psi. 19:54 - 19:55 0.02 TEST_ CMT_ WBPREP 1542 psi. 19:55 - 20:35 0.67 RUNPU COIL WBPREP POOH. Circulating minimun rate. 20:35 - 21:00 0.42 RURD_ COIL WBPREP OOH. Close swab valve. Lay down tools and lubricator. 21:00 - 21:30 0.50 RURD_ COIL WBPREP Displace coil w/ methanol. 28 bbls. 21:30 - 22:15 0.75 RURD_ COIL WBPREP Stand back injector assembly. Secure well and location for the night. 22:15 - 22:30 0.25 RURD_ COIL WBPREP Turn in permit. Sign out. Leave location. Lock gate. Notify operations that we have finished for the night. 12/14/2007 08:00 - 08:30 0.50 SAFETY MTG_ WBPREP Hold PJSM. Obtain work permit. Discuss Steam on Wheels' JSA and job scope. 08:30 - 09:00 0.50 RURD OTHR WBPREP RU Steam on Wheels to heat frac tank. Printed: 1/7/2008 4:32:08 PM • • Marathon Oil Company Operations Summary Report Page3of7~ Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: RECOMPLETION Start: 12/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 12/14/2007 09:00 - 10:00 1.00 SAFETY MTG_ WBPREP Hold PJSM. Obtain work permit. Discuss BJ/ Baker JSA and job scope. Review mud motor operating perimeters. 10:00 - 10:35 0.58 RURD_ C01L WBPREP Carry injector to well head and install. 10:35 - 11:00 0.42 RURD_ COIL WBPREP Displace methanol from coil w/ 6% KCL water. 26 bbls. 11:00 - 11:20 0.33 RURD_ COIL WBPREP Remove inject from WH. Set injector in craddle to re-rig lifting sling. PU 24' of lubricator. 11:20 - 12:00 0.67 RURD_ COIL WBPREP PU DFCheck valve, Bowen Oil Jars, FAU Hydraulic disconnect. PU Dual circulation sub, String mill/centralizer, M1W1 Mud motor, 2.70" Tri bladed junk mill. 12:00 - 12:20 0.33 RURD_ COIL WBPREP Cany lubricator to WH. Install walking dogs. 12:20 - 12:30 0.17 RURD_ COIL WBPREP Shell test Bowen's to 1500 psi. Test good. Hear motor turning in the lubricator. 12:30 - 13:46 1.27 RUNPU COIL WBPREP Open Masters and Swab valve {24 turns). RIH circulating min rate. 13:46 - 13:52 0.10 MILL_ PLUG WBPREP Holding @ 5740' CTM. Increase pump rate to 1.5 bpm. 1850 psi motor free spinning. RIH to tag cement. Mill to 5776' CTM. 13:52 - 14:52 1.00 MILL_ PLUG WBPREP Tag up on Baker Composite plug at 5776' ctm. Milling at 1.5 bpm, 2200 14:52 - 15:48 0.93 MILL_ PLUG WBPREP Milling on plug @ 5777.5' CTM. 1.5 bpm 2300 psi 15:48 - 17:34 1.77 MILL_ PLUG WBPREP Still milling on plug. ,Plug breaks free. Push plug to bottom. 17:34 - 17:45 0.18 RUNPU COIL WBPREP Push plug into rathole @ 8292' CTM. Plug hangs up in Excape Modules. Sometimes neccessary to start mud motor to spin plug down thru Excape modules. 17:45 - 19:10 1.42 RUNPU COIL WBPREP POOH. Circulating bottoms up at 1.5 bpm. 19:10 - 19:35 0.42 RURD_ COIL WBPREP OOH. Close swab valve. Lay down tools and lubricator. 19:35 - 20:00 0.42 RURD_ COIL WBPREP Displace coil w/ methanol. 28 bbls. 20:00 - 20:30 0.50 RURD_ COIL WBPREP Stand back injector assembly. Secure well and location for the night. 20:30 - 21:00 0.50 RURD_ COIL WBPREP Sign vac truck manifest. Turn in permit. Sign out. Leave location. Lock gate. Notify operations that we have finished for the night. 12/15/2007 08:00 - 09:30 1.50 SAFETY MTG_ CMPFLW Held safety meeting with BJ. Issue work permit. Warmed up equipment during PJSM. 09:30 - 10:00 0.50 RURD_ COIL CMPFLW PU injector, MU coil connector to coil. Pull test to 25000 lbs. MU double checks and slick nozzle for BHA. Displace 28 bbls methanol out of coil to methanol tank with N2. 10:00 - 12:00 2.00 RUNPU COIL CMPFLW PT shell to 1500 psig. Open well, WHP=465 psi. RIH with 1 3/4" coil. 12:00 - 13:00 1.00 JET_ N2_ CMPFLW Coil at 1000' start pumping at 450 SCFM. PIP= 332 psig, WHP= 11 psig. Fluid to surface. 13:00 - 13:20 0.33 JET_ N2_ CMPFLW Coil at 3000' CTM. PIP= 585 psig, WHP= 165 psig, PIR @ 750 SCFM. Good returns to flow back tank. 13:20 - 13:35 0.25 JET_ N2_ CMPFLW Total N2 pumped = 62, 000 SCF. PIP= 620 psig, PIR= 750 SCFM. 13:35 - 15:00 1.42 JET_ N2_ CMPFLW Coil down to 4985' CTM, good returns to flow back tank. PIP= 1156 psig, PIR increased to 1000 SCFM. WHP= 40 psig. 15:00 - 16:05 1.08 JET_ N2_ CMPFLW Totafl fluid to flow back tank at 64 bbls returns. Col at 6800' CTM, PIP= 1148 psig, total pumped at 201, 700 SCF. WHP= 280 psig. 16:05 - 16:40 0.58 JET_ N2_ CMPFLW Work coil down to 8200' above module #1 @ 8265'. Still returns to flow back tank. 16:40 - 16:50 0.17 JET_ N2_ CMPFLW PUH with coil while pumping N2, reduced rate to 500 SCFM. Coil !@ 7600' ctm, WHP= 130 psig. 16:50 - 17:00 0.17 JET_ N2_ CMPFLW Good returns to flow back tank, PIP= 956 psig @ 500 SCFM. Total N2 pumped @ 230, 000 SCF. 17:00 - 17:30 0.50 JET_ N2_ CMPFLW CT at 3500' CTM, shut down N2. PIP= 550 psig. WHP= 170 psig. 17:30 - 18:00 0.50 JET_ N2_ CMPFLW Coil at surface, leave well venting into flow back tank while rigging down. WHP slowly bleeding down to o psig. No gas to surface. Shut well in a tree. Printed: 1/7/2008 4:32:08 PM • Marathon Oil Company Page 4 of 7 Operations Summary Report Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: RECOMPLETION Start: 12/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date 'From - To Hours Cade Sub I~ Phase Description of Operations Code 12/15/2007 18:00 - 19:00 1.00 RURD_ COIL CMPFLW Pull injector, RD cross over and BOP. 19:00 - 21:30 2.50 RURD_ COIL CMPFLW BJ finished rigging down and cleaned up around area. BJ left lease. 12/19/2007 07:00 - 08:00 1.00 SAFETY MTG_ WBPREP Hold PJSM. Obtain work permit. Discuss BJ JSA for installing BOP's. Discuss crane safety. 08:00 - 09:30 1.50 RURD_ COIL WBPREP Startup light towers and equipment. 09:30 - 10:45 1.25 TEST_ BOPE WBPREP CLose wing valve( 24 turns). Function test BOP rams. PTest Blind/shear rams. Test good. PTest Pipe/slips ram. Test good. 10:45 - 11:40 0.92 RURD_ COIL WBPREP PU Injector. Install jetting nozzle. Cany to WH. Install "walking dogs". 11:40 - 12:15 0.58 RURD_ COIL WBPREP Open swab valve( 24 turns). Open masters. WHP- 850 psi... Well bled down rapidly. RIH. Return tank level 5"s. (18 bbls) Recieved Methanol 12:15 - 12:30 0.25 RUNPU COIL WBPREP RIH @ 1800' CTM. Start injecting N2 at 725 scf/min. 260 psi. 12:30 - 12:55 0.42 JET_ N2, WBPREP RIH 2220' CTM. Increase N2 rate to 1000 scf/min. Fluid level may be around 1800'. 12:55 - 13:30 0.58 JET_ N2_ WBPREP RIH to 2750'. Pump pessure increasing-(lifting fluid). Retums to surface. 13:30 - 13:35 0.08 JET_ N2_ WBPREP RIH to 3150' Park- good retums to surface. Choke manifold has been freezing up. Injected 2 bbls of MEOH to clear it out. 13:35 - 13:55 0.33 JET_ N2_ WBPREP RIH good fluid returns to surface. Fluid recovery--21 bbls.(12") 13:55 - 14:05 0.17 JET_ N2_ WBPREP Returns slowing, WHP falling. RIH to 4200'. 14:05 - 14:20 0.25 JET_ N2_ WBPREP @ 4200'. Fluid recovery-- 24 bbls. (13") 14:20 - 14:40 0.33 JET_ N2_ WBPREP RIH to 5000'. Fluid recovery-28 bbls. (14") 14:40 - 14:55 0.25 JET_ N2_ WBPREP RIH to 6000'. Fluid recovery-34 bbls. (15.5") 14:55 - 15:15 0.33 JET_ N2_ WBPREP @6000'. Fluid recovery --44 bbls. (18.5") 15:15 - 15:40 0.42 JET_ N2_ WBPREP RIH to 7000'. Fluid recovery--62 bbls. (23.5") 15:40 - 16:20 0.67 JET_ N2_ WBPREP RIH to 8287' 16:20 - 16:50 0.50 JET_ N2 ~ WBPREP POOH. Fluid recovery--71 bbls. (26") N2 rate 1000 scf. 16:50 - 17:20 0.50 JET_ N2 WBPREP PUH. Fluid recovery--78 bbls. (27.5") 17:20 - 17:45 0.42 JET_ N2_ WBPREP PUH @ 2800' Out of N2. Fluid recovery--80 bbls. (28") 17:45 - 18:00 0.25 RURD_ COIL WBPREP OOH. Close master valve. Pump MEOH across tree to choke and gas buster. 18:00 - 18:15 0.25 RURD_ COIL WBPREP Stand back Injector. 18:15 - 18:30 0.25 RURD_ COIL WBPREP Secure well. 18:30 - 18:45 0.25 RURD_ COIL WBPREP Turn in permit. Sign out. Leave location. Lock gate. Notify operations that we have finished for the night. 12/20/2007 07:00 - 08:00 1.00 SAFETY MTG_ WBPREP Hold PJSM. Obtain work permit. Discuss BJ JSA for installing BOP's. Discuss crane safety. 08:00 - 09:30 1.50 RURD_ COIL WBPREP Startup light towers and equipment. Indirect heater unit thru a rod out the block. Resulting in small fire(small amount of oil on exhaust manifold), which was put out by BJ crew. Reported to Safety dept and operations. 09:30 - 10:45 1.25 RURD_ COIL WBPREP BJ did not have the neccessary equipment to rig up and N2 unit would not start. Shut the job down. 12/21/2007 07:00 - 08:00 1.00 SAFETY MTG_ WBPREP Hold PJSM. Obtain work permit. Discuss BJ JSA for installing -njector assembly. Discuss crane safety, muster areas, alarms, and cold weather safety. The wind is brutal. 08:00 - 11:00 3.00 RURD_ COIL WBPREP Start up light towers and equipment. Must use heaters and tarps to start most of the diesel engines. 11:00 - 11:30 0.50 RURD_ COIL WBPREP Function test rams on BOP's. Hydraulics slow in the cold. 11:30 - 12:15 0.75 RURD_ COIL WBPREP Check master valves-closed. Open swab valve (24 turns). Release trapped pressure in flow cross to gas buster. Well had been open to medium pressure system( 310 psi) until about 8:00 am. WHP was 1000 psi when released to gas buster at 12:40. Check stripper rubber Printed: 1/7/2008 4:32:08 PM • • Marathon. Oil Company Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 RECOMPLETION GLACIER DRILLING GLACIER DRILLING Date From - To Hours "Code Gode Phase 12/21/2007 11:30 - 12:15 0.75 RURD COIL WBPREP 12:15 - 12:45 0.50 RURD_ COIL WBPREP 12:45- 13:40 0.92 RUNPU COIL WBPREP 13:40 - 14:14 0.57 JET_ N2_ WBPREP 14:14 - 14:20 0.10 JET N2 WBPREP 14:20 - 14:39 0.32 JET_ N2_ WBPREP 14:39 - 15:00 0.35 JET_ N2 WBPREP 15:00 - 15:30 0.50 JET N2 WBPREP 15:30 - 15:55 0.42 JET_ N2_ WBPREP 15:55 - 16:15 0.33 JET_ N2_ WBPREP 16:15 - 16:34 0.32 JET_ N2_ WBPREP 16:34 - 16:48 0.23 JET_ N2 WBPREP 16:48 - 17:00 0.20 JET_ N2~ WBPREP 17:00 - 17:10 0.17 JET N2 WBPREP 17:10 - 17:20 0.17 JET_ N2_ WBPREP 17:20 - 17:30 0.17 JET_ N2_ WBPREP 17:30 - 17:45 0.25 JET_ N2_ WBPREP 17:45 -18:20 0.58 RUNPU COIL WBPREP 18:20 - 18:45 0.42 RUNPU COIL WBPREP 18:45 - 19:10 0.42 RURD COIL WBPREP 19:10 - 19:30 0.33 RURD_ COIL WBPREP 19:30 - 19:45 0.25 RURD_ COIL WBPREP 19:45 - 20:00 0.25 RURD COIL WBPREP 12/22/2007 ~ 07:00 - 08:00 ~ 1.00 ~ SAFETY MTG_ ~ WBPREP 08:00 - 09:45 1.751 RURD_ _ COIL WBPREP 09:45 - 09:55 0.17 ~ RURD_ COIL WBPREP 09:55 - 10:00 I 0.081 RURD I COIL I WBPREP 10:00 - 10:30 0.50 RURD_ COIL WBPREP 10:30 - 10:50 0.33 RUNPU COIL WBPREP 10:50 - 11:30 0.67 JET_ N2_ WBPREP 11:30 - 11:45 0.25 JET_ N2_ WBPREP 11:45 - 12:10 0.42 JET N2 WBPREP Page 5 of 7 Spud Date: 7/23/2005 Start: 12/11/2007 End: Rig Release: Group: Rig Number: 1 Description of Operations on Injector. Looks good. PU Injector. Install jetting nozzle. Carry to WH. Install "walking dogs". Open swab valve( 24 turns). Open masters. WHP- 1000 psi... Well bled down in approximately 10 minutes. RIH. Returns tank level- empty. RIH @ 1200' CTM. Start injecting N2 at 700 scf/min. 260 psi. RIH 3000' CTM. N2 rate at 700 scf/ min. Fluid level may be around 2500'. Continue RIH. Returns to surface. RIH to 3500'. Park. Pump pessure increasing-(lifting fluid). Returns to surface. RIH. Increase N2 to 980 scf/min. Good returns. Parked @ 4500 '. Good fluid returns to surface. Fluid recovery 21 bbls( 6") RIH to 5650'-park. RIH. Fluid recovery-- 34 bbls. (9.5") RIH to 7000'. Park. Fluid recovery- 39 bbls.( 11") RIH. @ 7800'. Fluid recovery --50 bbls. (14") Tag TD @ 8196'. PUH and circulate N2 @ 980 scf/min. Fluid recovery 57 bbls. (16") Continue circulating N2 @ 980 scf/min. Parked @ 8180'. Fluid recovery--66 bbls. (18.5") POOH. Reduce N2 rate to 750 scf/min. Fluid recovery--71 bbls. (20") PUH @ 3600' Cut N2. Fluid recovery--73 bbls (20.5") Continue POOH. Fluid recovery--78 bbls (22") OOH. Close master valves. Pump MEOH across tree to choke and gas buster. Stand back Injector. Secure well. Turn in permit. Sign out. Leave location. Lock gate. Turn well over to production. Ask operations to bleed down pressure occationally thru night. Notify operations that we have finished for the night Hold PJSM. Obtain work permit. Discuss BJ JSA for installing Injector assembly. Discuss crane safety, muster areas, alarms, and cold weather safety. Operations was not able to bleed well down dun'ing the night, so well remained shut-in. Place a call to AK Heater Rentals to release heater. Used heater for 2 days. Start up light towers and equipment. Must use heaters and tarps to start most of the diesel engines. Check master valves-closed. Open swab valve (24 turns). Release trapped pressure in flow cross to gas buster. Received call from Mr. Jim Regg, AOGCC. Discussed our suspending operations on CLU-10 for the holidays. Jim stated that was fine and that we should conduct our weekly BOP Test on Wednesday morning when we start up operations again. Jim also waived witness on the test as he had two inspectors headed to the slope on Wednesday. Submit BOP Report to AOGCC in the normal manner. PU Injector. Install jetting nozzle. Carry to WH. Install "walking dogs". Open swab valve( 24 turns). Open masters. WHP- 750 psi...RIH. Initial level in Returns Tank (6")--21 bbls. RIH @ 1000' CTM. Start injecting N2 at 800 scf/min. RIH to 4067' CMT and park. Wait on returns. Returns to surface. RIH to 5500'. Printed: 1/7/2008 4:32:08 PM r Marathon Oil Company Page 6 of 7 Operations Summary Report 14:00 - 14:14 Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: RECOMPLETION Start: 12/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Cade Code Phase Description of Operations 12/22/2007 12:10 -12:30 12:30 -12:50 12:50 - 13:00 13:00 - 13:13 13:13 - 13:40 13:40 - 14:00 0.33 JET_ N2_ 0.33 JET_ N2_ 0.17 JET_ N2_ 0.22 JET_ N2_ 0.45 JET_ N2_ 0.33 JET N2 WBPREP Parked @ 5500' Waiting on returns. Fluid recovery---14 bbls. (10") WBPREP Returns to surface. N2 rate 800 scf/min. WBPREP Fluid revery ----27 bbls. (13.5") WBPREP RIH to 6500'. WBPREP Parked @ 6500'. Waiting on returns WBPREP Retums to surface. RIH @ 50 fpm. Increased N2 to 1200 scf/min. Fluid recovery---43 bbls (18") WBPREP RIH @ 7850' CTM. Pumping N2 @ 1200 scf/min. 1440 psi. WHP 230 psi. Fluid recovery---46 bbls. (19") WBPREP Tag TD @ 8286'. PUH 18' to 8268' and circulate N2 @ 1200 scf/min. WBPREP Reduce N2 rate to 1000 scf/min. WBPREP Fluid recovery ---59 bbls. (22.5") POOH. WBPREP PUH @ 6200'. Cut N2, out of N2. Good retums to surface. WBPREP Continue POOH. Fluid recovery--66 bbls (24.5") WBPREP OOH. Close master valves. Pump MEOH across tree to choke and gas buster. WBPREP Stand back Injector. WBPREP Secure well. WBPREP Turn in permit. Sign out. Leave location. Lock gate. Tum well over to production. Ask operations to bleed down pressure occationally thru night. Notify operations that we have finished for the night WBPREP Hold PJSM. Obtain work permit. Discuss BJ JSA for installing Injector assembly. Discuss crane safety, muster areas, alarms, and cold weather safety. WBPREP Startup light towers and equipment. WBPREP Must use heaters and tarps to start most of the diesel engines. RU N2 unit. WBPREP Check master valves-closed. Open swab valve (24 turns). Release trapped pressure in flow cross to gas buster. WBPREP Function test BOP's. Prime up pump and lines. Establish circulation to MEOH tank. PTest Blind/ shear rams, 250/ 4500 psi. Tree leaking. close masters and swab. Try again. Still leaks. WBPREP Call Vetco Gray. Leave message w/answering service. Call again at 1:20. Crew at lunch, will round them up and head them to location . WBPREP Vetco-Gray arrive. WBPREP Grease all valves on the tree. WBPREP Function test BOP's. Prime up pump and lines. Establish circulation to MEOH tank. PTest Blind/ shear rams, 250/ 4500 psi. WBPREP Tree still leaking. Mike Heath w/ Vetco trys to service valves. No replacement valves or spare parts available. WBPREP Vetco install plastic in swab valve. WBPREP PTest Blind/ shear rams, 250/4500 psi. Good test. PTest Pipe/slips, 250 psi/ 4300 psi. Test good. WBPREP Secure well. WBPREP Turn in permit. Sign out. Leave location. Lock gate. Turn well over to production. Ask operations to bleed down pressure occationally thru night. Notify operations that we have finished for the night WBPREP Hold PJSM. Obtain work permit. Discuss BJ JSA for installing Injector assembly. Discuss crane safety, muster areas, alarms, and cold weather safety. WBPREP Start up light towers and equipment. Must use heaters and tarps to start most of the diesel engines. !WBPREP Check weather with Kenai airport. They are still reporting gust over 25 • 0.23 ~ JET_ ~ N2_ 14:14 - 14:18 0.07 JET_ N2_ 14:18 -14:35 0.28 JET_ N2_ 14:35 - 15:00 0.42 JET_ N2_ 15:00 - 15:45 0.75 JET_ N2_ 15:45 - 16:05 0.33 RUNPU COIL 16:05 - 16:15 0.17 RURD COIL 16:15 - 16:30 16:30 - 16:45 16:45 - 17:00 12/27/2007 08:00 - 09:00 09:00 - 09:45 09:45 - 12:00 0.25 RURD_ COIL 0.25 SECUR WELL 0.25 RURD COIL 1.00 ~ SAFETY ~ MTG_ 0.75 RURD_ COIL 2.25 RURD COIL 12:00 - 12:10 I 0.171 RURD I COIL 12:10 - 12:55 ~ 0.75 ~ TEST_ ~ BOPE 12:55 - 13:30 0.581 WAITON EOIP 13:30 - 14:15 0.75 WAITON EOIP 14:15 - 14:45 0.50 SERVIC EOIP 14:45 - 15:30 0.75 TEST_ BOPE 15:30 - 16:30 1.00 SERVIC EOIP 16:30 - 17:00 0.50 SERVIC EOIP 17:00 - 18:15 1.25 TEST BOPE 18:15 - 18:30 0.25 SECURES WELL 18:30 - 18:45 0.25 RURD COIL ~ 12/28/2007 ~ 07:00 - 08:00 ~ 1.00 ~ SAFETY ~ MTG_ 08:00 - 09:00 1.00 RURD_ COIL 09:00 - 09:30 0.50 RURD _ COIL Printed: 1/7/2008 4:32:08 PM • f • Marathon Oil Company Operations Summary Report Page 7 of 7 ~ Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Spud Date: 7/23/2005 Event Name: RECOMPLETION Start: 12/11/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Cade Code i Phase Description of Operations 12/28/2007 09:00 - 09:30 0.50 RURD_ COIL WBPREP mph. Shut down on weather. Forecast calls for the wind to continue throughout the day. 12/29/2007 07:00 - 07:50 0.83 SAFETY MTG_ WBPREP Hold PJSM. Obtain work permit. Discuss BJ JSA for installing Injector assembly. Discuss crane safety, muster areas, alarms. 07:50 - 08:00 0.17 RURD_ COIL WBPREP Check master valves-closed. Open swab valve (24 turns). Release trapped pressure in flow cross to gas buster. 08:00 - 08:20 0.33 RURD_ COIL WBPREP PU Injector. Install jetting nozzle. Cant' to WH. Install "walking dogs". 08:20 - 08:55 0.58 RUNPU COIL WBPREP Open swab valve( 24 turns). Open masters. WHP- 440 psi...RIH. Initial level in Returns Tank (6")--21 bbls. 08:55 - 09:40 0.75 JET_ N2_ WBPREP RIH @ 1100' CTM. Start injecting N2 at 750 scf/min. Tag fluid at approximately 2000'. 09:40 - 09:48 0.13 JET_ N2_ WBPREP RIH to 3500' CMT and park. Wait on returns. 09:48 - 09:55 0.12 JET_ N2_ WBPREP Returns to surface. 09:55 - 10:10 0.25 JET_ N2_ WBPREP Parked @ 3500' Waiting on returns. Fluid recovery---21 bbls. (12") 10:10 - 10:18 0.13 JET_ N2_ WBPREP Retums to surface. N2 rate 750 scf/min. 10:18 - 10:30 0.20 JET_ N2_ WBPREP Parked @ 4500'-- bbls. Increased N2 rate to 1050 scf. 10:30 - 10:45 0.25 JET_ N2_ WBPREP RIH @ 60 fpm. Fuid recovery --28 bbls (14") 10:45 - 10:50 0.08 JET_ N2_ WBPREP RIH @ 60 fpm-6000'. Good retums to surface. Fluid recovery ---35.6 bbls (16") 10:50 - 11:00 0.17 JET_ N2_ WBPREP RIH @ 60 fpm. Increased N2 to 1200 scf/min. 11:00 - 11:45 0.75 JET_ N2_ WBPREP RIH @ 60 fpm Pumping N2 @ 1200 scf/min. 1540 psi. WHP 320 psi. Fluid recovery--43 bbls. (18") 11:45 - 12:20 0.58 JET_ N2 WBPREP Tag TD @ 8270'. PUH 8212'. 12:20 - 12:30 0.17 JET_ _ N2_ WBPREP Parked @ 8212'. Fluid retums---68 bbls. (25") 12:30 - 12:35 0.08 JET_ N2_ WBPREP Mostly N2 returns. Very little water. Fluid recovery---71 bbls. (26") 12:35 - 12:45 0.17 JET_ N2_ WBPREP Reduce N2 rate to min. rate--500 scf/min. 12:45 - 12:55 0.17 JET_ N2_ WBPREP Increase N2 rate to 1000 scf/min. POOH. 12:55 - 13:03 0.13 JET_ N2_ WBPREP PUH @ 6250'. Reduce N2 rate to 750 scf/min. No returns. 13:03 - 13:40 0.62 RUNPU COIL WBPREP Returns to surface. Continue POOH. Fluid recovery---78 bbls. (28") 13:40 - 13:50 0.17 RURD_ COIL WBPREP OOH. Let N2 blow down. Pressure has fallen from 400 psi down to 120 psi, and still falling. Fluid recovery---86 bbls. (30") 13:50 - 14:25 0.58 RURD_ COIL WBPREP Start rigging down. Leave well blowing to gas buster as long as possible. 14:25 - 17:30 3.08 RURD_ COIL WBPREP Shut well in. WHP 107 psi. Stand back Injector. Continue rigging down. 17:30 - 18:15 0.75 SECUR WELL WBPREP Secure well. 18:15 - 18:30 0.25 RURD_ COIL WBPREP Turn in permit. Sign out. Leave location. Lock gate. Turn well over to production. Ask operations to bleed down pressure occationally thru night. Notify operations that we have finished for the night Printed: 1/7/2008 4:32:08 PM Cannery Loop Unit #10: PTD ~QS-106 ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Walsh, Ken [kdwalsh@marathonoii.com] Sent: Tuesday, November 13, 2007 12:30 PM To: Maunder, Thomas E (DOA) Subject: RE: Cannery Loop Unit #10: PTD #205-106 Tom, Thanks for the quick response. Will do, on the follow-up paperwork. ~~ Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 13, 2007 12:25 PM To: Walsh, Ken Cc: Cassell, Wayne E.; Donovan Jr, Dennis M.; Grant, Patrick; Ibele, Lyndon; Mullin, Mickey; Rang, Craig L.; Skiba, Kevin J.; Sulley, Michael Subject: RE: Cannery Loop Unit #10: PTD #205-106 Ken, I confirm our discussion and that the work may proceed under 305-356. You are still attempting to isolate the water which was the original intent of 305-356. A 404 with an operations summary should be filed when the work is finished. If this latest work is not successful, please contact me so that proper documentation can be put in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Walsh, Ken [mailto:kdwalsh@marathonoiLcom] Sent: Tuesday, November 13, 2007 12:07 PM To: Maunder, Thomas E (DOA) Cc: Cassell, Wayne E.; Donovan Jr, Dennis M.; Grant, Patrick; Ibele, Lyndon; Muflan, Mickey; Rang, Craig L.; Skiba, Kevin J.; Sulley, Michael Subject: Cannery Loop Unit #10: PTD #205-106 Tom, This is a follow-up to our conversation late last week regarding handling sundry notification for work to shut off water production in the Cannery Loop Unit (CLU) #10 well. f contacted you by 11/13/2007 Cannery Loop Unit #14: PTD X45-146 • Page 2 of 2 telephone to request your guidance on how to handle the sundry filing to isolate the upper two perforated intervals, 5674'-5684' and 5713'-5723' KB, in this Excape well. Marathon applied for and was granted 10-403 approval #305-356 in 2005 to set a retrievable straddle assembly patch permanently across this interval. The patch was set in December 2005 and worked well shutting off the bulk of the produced water from these fracture stimulated intervals for about one month but the high water volume returned. Production logging confirmed that the patch was leaking. Since that time, Marathon has tried repeatedly to remove this straddle assembly patch from the wellbore. We are currently rigged up on the well with coiled tubing making, what we hope, is our last and successful attempt to remove the remainder of the patch. Once the patch is removed, Marathon proposes to 1) jet fill from the well, 2) set a composite bridge plug below the bottom perf at 5723' KB, 3) cement squeeze the two intervals with coiled tubing, 4) drill out the squeeze and composite bridge plug, and 5) jet the well in with nitrogen via coiled tubing to re-establish production. You indicated on the phone that I should provide this email to elaborate on the history and our intended work scope. You also indicated that we should be able to perform the intended work under the past Form 10-403 sundry approval #305-356. Please provide an email confirmation that you agree with this proposal. Best regards, Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) 11!13/2007 API: 50-133-20553-00 PTD 205-106 RT-GL: 21.00' RT-TH F: 21.70' CLU -10 TOC (est.) -500' above 9-5/8" shoe Ceramic flapper valves below each module as follows: Module 1 - NA Module 2 - 8240' Module 3 - 8118' Module 4 - 7985' Module 5 - 7736' Module 6 - 7196' Module 7 - 7105 Module 8 - 7049' ,Module 9 - 6975 Module 10 -5897 Module 11 -5729' Module 12 -5690' ~ `a I ~. ti . t ~~ I ~~ i ~1 l i ti* t~ ' '~ I~~` '} ,~„ _ f~ k~ :fi ~ '~. ~~ xR: yy L 4~ ~~ +$a S -~ a~ TD -8450' PBTD -8382' 1 -8265 -8275' 2 -8219 -8229' 3 -8098 - 8108' 4 - 7965 - 7975' s-n1s-7725 6-7174-7184' 7 - 7083 - 7093' 8 - 7030 - 7040' 9 -6956 -6965 10 - 5880 -5890' Patch- 5668'732' ID=1.50" Well Name 8~ Number: CLU - 10 Lease: Cannery Loop Gas Field County or Parish: Kenai StatefProv. Alaska Country: USA Pertorations ~MD) See Above gyp) BHP: BHT: Completion Fh~id: 6% KCL Dated Completed: 8131 /2005 Prepared By: J. R_ Thompson Last Revisor Date: 8/26/2005 • "~ 31iDARATNQTi Drive Pike: 20", 133 ppf, K-55 to 133' Surface Casing: 13-318", 68 ppf, L-80, BTC ~ 1953' Cmt w/ 606 sx. of Type 1 at 12.0 PP9~ frt. Casing: 9-5/8", 40 ppf, L-80, BTC ~ 5410' Cmt w/ 75 bbf of class G lead ~ 12.5 ppg and 45 bbfs Class G tail @ 15.8 Ppg Prod. Tubing: 3-1/7', 9.3 ppf, L-80, EUE 8rd with 6.25 OD coMrd line protectors to 8419' Cmt w/ 1324 sx of class G at 15.8 ppg 12 Exppe modules placed Green control fine fired module 1 Yefbw contrd line fired modules 2 thru 8 Red contol line feed modules 9 thru 12 Ceramic flapper valves below each module xceat for module 1 ~~ ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Dritl 2051060 Well NameiNo. CANNERY LOOP UNIT 10 Operator MARATHON OIL CO API No. 50-133-20553-00-00 MD 8450 TVD 8002 Completion Date 9/1/2005 Completion Status 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: SP/GR=1EL-Density/Neutron-Sonic-Single Arm Caliper Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No --_.___ `F'~D C Las 15178 eduction/Resistivity I ED C Asc Directional Survey C Las 13921 ~'Cas~ 1 ~L ---- --- - - - - Well Cores/Samples Information: Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 2000 8469 Open 3/28/2007 GR, SP, Poro, Dens, Sonic,MudLog LAS & PDF, Dir Survey 0 8450 Open 5/26/2006 Contractor UNKNOWN 200 C7 8469 ~ 5/26/2006 COL-K~(?fN~egri't57s'4=Aug- c.ryt~„r, 2005 Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMON Well Cored? Y N Daily History Received? N Chips Received? `'~4?IV"' Formation Tops ~,/ N Analysis '1`-1-fd- Received? Comments: ComNliance Reviewed By: _ __ __ __ ___ Date: __~_~._~~ ~ r M Marathon MARATHQN Oil Company March 26, 2007 Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7t'' Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon CLU #10 -API 50-133-20553-00 CONFIDENTIAL Dear Mr. Okland: Alaska Asset Team Plorthern Business Unit P.O. Box 3128 Houston, TX 77253 Telephone 713-296-3597 Fax 713-499-4469 FEDERAL EXPRESS Enclosed is one CD containing confidential digital well data for the above referenced well, as described on the attached CD Contents document. Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead address or fax to 713-499-4469. Thank you, (, I ~ ~~ Courtney McElmoyl e Received by: 0 Date: ~ ~ ~ O~J V ~ Enclosures CLU 10 API 50-133-20553-00 CD CONTENTS Confidential Operations Summary: ~,~CLU 10 Operations Summary.xls Directional Data: ~%QLi-IO INTEQ EOVJR.pdf ®cIu10_dir 5ur.dat .~--,f CLU-l0,txt Wireline Data: FINAL Marathon_CLU 10_MFT_complete.dpk FINAL_Marathon_CLU 30~lotted.dpk uCLU10_MAINDEPTH,Ias FINAL_Marathon_CLU 10 complete.dpk Mudlog Data: LICLU-lO.las .... _...__. QUID DRSLDVN MD.pdf ......... ~CLUIO_DRILDYN_TVD.pdF ~- CLU10 MUDLOG_MD.pdf '`CLU10_MUDLOG_TVD,pdF CLUIO.dbf CLUfO_SCL,DBF CLU10_tvd.dbf ®clulOr.dbF ®clu IO.hdr ~CLUlO.mdx CLU30_SCL,MDX CLU10 tvd.mdx clul0r.mdx ~,~ WeN Report CLUIO.doc ®CLUIOREMRRKS.dat As-built Plat in PDF format. i ,. * , : ~ rat MARATHOAI I ®I May 24, 2006 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7`i' Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon: Cannery Loop Unit 8 Marathon: Cannery Loop Unit 9 Marathon: Cannery Loop Unit 10 Marathon: Cannery Loop Unit 11 CONFIDENTIAL Dear Mr. Oakland: P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-499-8504 FEDERAL EXPRESS The following confidential well data is enclosed for the above referenced wells. This digital data includes directional surveys, openhole logs (LAS format) and prints (dpk format) for each well. CLU S ~• clu8 dir_aogcc.dat club vectardepth.las EMAIL_Clu-8~Iokted2. dpk CLU 9 clu9_dir_aogcc.dat clu9_reeves_field.las ~E-MAIL Marathon_CLU 9.dpk CLU 10 ~C~-~ ~~~ ~ 3 c'( ~, ~clu_10 dir_aogcc.dat L.1 CLU10_MAINDEPTH.Ias ~UZProgram Files_Reeves_WLS 7.00_Data_Marathon_CLU 10_MFT_com.dpk ~UZProgram Files_Reeves_WLS 7.00_Data_Marathon_CLU l0~lotted.dpk CLU i i a o ~ _ ~,~ v~ clu_l l_dir_aogcc.dat clu_l i~rec_las.las du_l l~rec_las tvd.las CLU11 TVD.Ias CLUl l MD.las ~Data_Marathan_CLU il~lotted.dpk • Alaska Asset Team Northern Business Unit Alaska Oil & Gas Association CLU 8, 9, 10, 11 Well Data May 24, 2006 Page 2 Please indicate your receipt of this data by signing below and returning one copy to me at the letterhead address or fax to 713-499-8504. Thank you, MARATHON OIL COMPANY Kaynell Zeman - Geological Technician Received b Y Date: ~ 6 1~ ~"l ~,~ ~ ~l1 Enclosures i 1 , ~.~ % =J ~~'' I ~. t 'sue' 4..,''s `~~ ~,~' ~/ ,~ ~ m„i ' AI.ASSA OIL A1QD G CO1~T5ER`FATI011T CODIIK155IOr1T Denise M. Titus Production Engineer Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Re: Cannery Loop No. 10 Sundry Number: 305-356 Dear Ms. Titus: X05- -~(o ~~ ~~ FRANK H. MUAKOWSKI, GOVERNOR e ," 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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. Please provide at least twenty-four (24) hours 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.. DATED this day of November, 2005 Encl. C /I--/y-0.5 ~E~~~/~ia ~g~t~~5~~. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI~N ~IOV ~, ~ ~fl~~i APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 a~k~ Qi~ ~ ~~: Cony. ~,~_,~-., ,,~:,~~n 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: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development Q Exploratory ^ 205-106 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196168 Anchorage, AK 99519-6168 50-133-20553-00-00 7. KB Elevation (ft): 9. Well Name and Number: 41' RKB Cannery Loop No. 10 / 8. Property Designation: 10. Field/Pools(s): ADL 02397 Cannery Loop Unit /Beluga 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): Casing Length Size MD TVD Burst Collapse Structural Conductor 123' 20" 123' 123' 3060 1500 Surface 1953' 13-3/8" 1953' 1866' 3450 1950 Intermediate 5410' 9-5/8" 5410' 4962' 5750 3090 Production Liner 8419' 3-1 /2" 8419' 8002' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached See attached N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft): N/A 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/14/,2005 ~ Oil ^ Gas ^ ~ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: ,.~,/ WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Denise M. Titus Printed Name ~P'vtl~ ~~. 7;"~~ Title Production Engineer Signature 1 i ~~ ~,, Phone 907-283-1333 Date 9/14/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ 5'~'~7'~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test [] Location Clearance ^ Other: Subsequent For q d: APPROVED BY / Approved by / COMMISSIONER THE COMMISSION Date: // v ~ ~ / / ~/ Form 10-403 R\evifsed 07/2005 Submit in Duplicate • M Marathon MARATHON Oil Company November 14, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave3 Anchorage, Alaska 99501 Reference: CLU #10 Dear Mr. Aubert: Alaska Asset Team Northern Business Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 Marathon Well CLU #10 was completed with multiple fracture stimulations and turned to production making 7MMcfd at 1200psi with 400bwpd production. With the high water rate, some form of isolation would be required to ease the burden to our limited water handling system. A production log was obtained and showed that most of the water was coming from the second from the top interval. On Friday, November 11, an unanticipated reduction in our production market permitted us to shut the well in long enoug o run a retrievable isolation test patch. Weekend test production shows that we have eliminated 250bwpd. ,~ Per our phone conversation this morning, we would like to request leaving the patch in the wellbore as a permanent isolation of the water production. Enclosed is the 10-403 Application for Sundry Approvals requesting permission to maintain patch isolation across perfs at 5713'-5723' in CLU 10. The current installation is fully retrievable and can be removed if necessary. A well schematic and patch description are also enclosed for your review. If you need any additional information, I can be reached at 907-283-1333 or by a-mail at dmtitus@marathonoil.com. Sincerely, ;~f. _~l i ~~~ ,. ,~ ~ s Denise M. Titus Production Engineer /" Enclosures 10-403 Sundry CLU 10 Well Schematic Isolation Patch Schematic CLU 10 PERFORATIONS/STIMULATION SUMMARY MODULE # DATE MD TVD NET FRAC DETAIL 1 8/31/2005 5674-5684 5226-5236 10 15,858 LBS 20/40 Ottawa & 12/20 Flex Sand -- 2 8/31/2005 5713-5723 5265-5275 10 21,888 LBS 20/40 Ottawa & 12/20 Flex Sand 3 8/31/2005 5880-5890 5432-5442 10 28,028 LBS 20/40 Ottawa & 12/20 Flex Sand 4 8/31 /2005 6956-6966 6508-6518 10 26,739 LBS 20/40 Ottawa & 12/20 Flex Sand 5 8/31/2005 7030-7040 6582-6592 10 25,411 LBS 20/40 Ottawa & 12/20 Flex Sand 6 8/31/2005 7083-7093 6635-6645 10 22,682 LBS 20/40 Ottawa & 12/20 Flex Sand 7 8/31/2005 7174-7184 6726-6736 10 23,178 LBS 20/40 Ottawa & 12/20 Flex Sand 8 8/31/2005 7716-7726 7268-7278 10 22,534 LBS 20/40 Ottawa & 12/20 Flex Sand 9 8/31/2005 7965-7975 7517-7527 10 24,961 LBS 20/40 Ottawa & 12/20 Flex Sand 10 8/31/2005 8098-8108 7650-7660 10 22,374 LBS 20/40 Ottawa & 12/20 Flex Sand 11 8/31/2005 8219-8229 7771-7781 10 Pump in breakdown only 12 8/31/2005 8265-8275 7817-7827 10 33,228 LBS 20/40 Ottawa & 12/20 Flex Sand *BJ Lightning_V water based frac fluid used • • CLU 10 RETRIEVABLE SLICKLINE PATCH Item Length (ft ID (in OD (in A Slip Stop 1.12 1.75 2.712 Daniels TP3 Packoff 1.39 1.53 2.72 XO 0.48 1.5 2.5 Spacer Pipe 1.5 1.91 HES Stinger 1.55 2.696 HES Recepticle 0.85 2.3 2.7 Spacer Pipe 10.2 1.5 1.91 XO 0.42 1.5 2.5 Daniels TP3 Packoff 1.39 1.53 2.72 F-Collar Stop 0.83 1.6 2.31 Total Length= +/- 25' r 1 ~~ API: 50-133-20553-00 RT-GL: 21.00' RT-THF: 21.70' 273' FSL, 520' FEL, Sec. 7, T5N, ~; R11W, S.M. Tree cxn = 4-3/4" Otis TOC (est.) - 500' above 9-5/8" shoe CLU -10 ~ M MARATNOM - 12 Excape modules placed -Green control line fired module 1 - Yellow control line fired modules 2 thru 8 - Red contol line fired modules 9 thru 12 -Ceramic flapper valves below each module except for module 1 Module 1 - 8265 - 8275' Module 2 - 8219 - 8229' Module 3 - 8098 - 8108' Module 4 - 7965 - 7975' Module 5 - 7716 - 7726' Module 6 - 7174 - 7184' Module 7 - 7083 - 7093' Module 8 - 7030 - 7040' Module 9 - 6956 - 6966' Module 10 - 5880 - 5890' Module 11 - 5713 - 5723' Module 12 - 5674 - 5684' Drive Pioe: 20", 133 ppf, K-55 to 133' Surface Casino: 13-3/8", 68 ppf, L-80, BTC @ 1953' Cmt w/ 606 sx. of Type 1 at 12.0 PPg• Int. Casing: 9-5/8", 40 ppf, L-80, BTC @ 5410' Cmt w/ 75 bbl of class G lead @ 12.5 ppg and 45 bbls Class G tail @ 15.8 ppg Prod. Tubing: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" OD control line protectors to 8419' Cmt w/ 1324 sx of class G at 15.8 ppg Well Name 8 Number: CLU - 10 Leaae: Cannery Loop Gas Field County or Parish: Kenai State/Prov. Alaska Coun USA Perforations (MD) See Above (TVD) Angle/Perfs Angle @ KOP and Depth BHP: BHT: Completi on Fluld: 6% KCL Dated Completed: 8131!2005 Prepared J. R. Thompson L.~t Revison Date: 8/26/2005 10!20/2005 7:42 AM TD -8450' PBTD - 8382' • M Marathon MARATHON Oil Company October 18, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Completion Report 10-407 for permit 205-106 Field: Cannery Loop Gas Field Unit -Beluga Well: CLU 10 Dear Mr. Aubert, • Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 ~'C%~~@ OCT ~ 1 20Q5 fllaska t~ii C ,. ~';,t < ~',i~rr~r+~r,~i,,r~ <`~... Enclosed please find the Well Completion Report with associated attachments for Cannery Loop Gas Field unit well No. 10. This well has been completed cased hole with a 3.5" Excape monobore production string to surface. I apologize for the delay in getting this completion notice to you. Should you require further information, I can be reached at 713-232-9347 / 713-296- 2730, or by a-mail at JRThompson@MarathonOil.com. Sincerely, i I James R. Thompson Sr. Completions Engineer Enclosures: Completion Report Directional Survey Operations Summary Wellbore Diagram STATE OF ALASKA ~ ~~~ ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMIS'J'rJN ~ ~~~~~~d~ W MPLETION OR RECOMPLETION REPORI~°~-~1 ~ '~~~ ~~ ~~ ia. Well Status: Oil Gas ~ Plugged Abandoned 2oAAC 2s.1os GINJ^ WINJ^ WDSPL^ No. of Completions Suspended WAG 2oAAC 2s.11 o Other 1b. Well Class: Development Q Exploratory Service ~ Stratigraphic Test[] 2. Operator Name: Marathon Oil Company 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: 205-106 3. Address: P. O. Box 3128, Houston, TX 77253 6. Date Spudded: July 23, 2005 13. API Number: 50-133-20553 4a. Location of Well (Governmental Section): Surface: 273' FSL, 520' FEL, Sec 7, T5N, R11 W, S.M. 7. Date TD Reached: August 4, 2005 14. Well Name and Number: Cannery Loop Unit No. 10 Top of Productive Horizon: 80' FNL, 1255' FWL, Sec. 17, T5N, R11W, S.M. 8. KB Elevation (ft): 41' 15. Field/Pool(s): Kenai Gas Field Total Depth: 84' FNL, 1269' FWL, Sec. 17, T5N, R11 W, S.M. 9. Plug Back Depth(MD+TVD): MD - 8382" / 7934' Beluga/Upper Tyonek Pool 4b. Location of Well (State Base Plane Coordinates}: Surface: x- 272,452.10 y- 2,388,727.00 Zone- 4 10. Total Depth (MD +TVD): MD - 8450' 18002' 16. Property Designation: Fee (private) TPI: x- 274220.41 y- 2388339.78 Zone- 4 Total Depth: x- 274233.56 y- 2388335.72 Zone- 4 11. Depth Where SSSV Set: N/A 17. Land Use Permit: NA 18. Directional Survey: Yes ~ No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: NA 21. Logs Run: SP/GR=1EL-Density/Neutron-Sonic-Single Arm Caliper 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HQLE SI ZE CEMENTING RE O AMOUNT FT TOP BOTTOM TOP BOTTOM RD C PULLED 20" 133 K-55 0 123' 0 123' Driven NA NA 13 3/8" 68 L-80 0 1953' 0 1866' 16" 606 sacks NA 9 5/8" 40 L-80 0 5410' 0 4962' 12 114" 417 sacks NA 3 1/2" 9.3 L-80 0 8419' 0 7971' 8 1/2" 1324 sacks 95000 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) 3-1/2" 8419' N/A MD (RKB): 8265-8275; 8219-8229; 8098-8108; 7965-7975; 7716-7726; 7174-7184; 7083-7093; 7030-7040; 6956-6966; 5880-5890; 5713-5723; 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5674-5684 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Module 1:8265-8275' Frac: BJ Lightning V. w/15858 Ibs prop TVD (RKB): 7817-7827; 7771-7781; 7650-7660; 7517-7527; 7268-7278 Module 2: 8219-8229' Frac: BJ Lightning V. w/21888 Ibs prop 6726-6732; 6635-6645; 6582-6892; 6508-6518; 5432-5442; 5265-5275; Module 3: 8098-8108' Frac: BJ Lightning V. w/28,028 Ibs prop 5226-5236 Module 4; 7965-7975' Frac: BJ Lightning V. w/26,739 Ibs prop Module 5: 7716-7726' Frac: BJ Lightning V. w/25,411 Ibs prop Module 6: 7174-7184' Frac: BJ Lightning V. w/22,682 Ibs prop Module 7: 7083-7093' Frac: BJ Lightning V. w/23,178 Ibs prop 26. PRODUCTION TEST Continued on back Date First Production: September 1, 2005 Method of Operation (Flowing, gas lift, etc.): FIOWIII Date of Test: 9/9/2005 Hours Tested: 1/24/1900 Production for Test Period Oil-Bbl: NA Gas-MCF: 6649 Water-Bbl: 378 Choke Size: Open Gas-Oil Ratio: NA Flow Tubing Press. 1200 Casing Press: 0 Calculated 24-Hour Rate ~ Oil-Bbl: NA Gas-MCF: 6649 Water-Bbl: 378 Oil Gravity -API (corr): NA 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ' ~ ~, ~ ~~D~ NONE .-. ~ OCR ~~~~ 1 V" CLU 10 Alaska_Cmpl_10-407.x1s CONTINUED ON REVERSE 10/18/2005 4:50 PM 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summa st results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Beluga 5614 5166 Zone Top MD Top TVD Pressure Tyonek 8278 7830 Lower Beluga 8266 7818 no data for well Lower Beluga 8220 7772 Lower Beluga 8098 7650 Lower Beluga 7967 7519 Lower Beluga 7716 7268 Lower Beluga 7175 6727 Lower Beluga 7084 6636 Middle Beluga 7030 6582 Middle Beluga 6956 6508 Upper Beluga 5877 5429 Upper Beluga 5710 5262 Upper Beluga 5670 5222 30. List of Attachments: Directional Survey, Wellbore Diagram, Operations Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: James R. Thompson Title: Senior Production Engineer Signature: Phone: 713-296-2730 Date: 10/18/2005 U 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 welt 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 29: List all test information. If none, state "None". 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Module 8: 7030-7040' Frac: BJ Lightning V. w122,534 Ibs prop (20140 Ottawa & 12/20 Flex Sand) Module 9: 6956-6966' Frac: BJ Lightning V, wl24,961 Ibs prop (20140 Ottawa & 12120 Flex Sand) Module 10: 5880-5890' Frac: BJ Lightning V. w/22,374 Ibs prop (20/40 Ottawa & 12/20 Flex Sand) Module 11:5713-5723' Frac: BJ Lightning V. Pump in Breakdown Only Module 12: 5674-5684' Frac: BJ Lightning V. w/33,228 Ibs prop (20/40 Ottawa & 12/20 Flex Sand) Form 10-407 Revised 12/2003 CLU 10 Alaska_Cmpl_10-407.x1s 10/18/2005 4:45 PM CLU 10 Directional Survey ,Report Date: 1-Sep-2005 ', - - '. L Client ~ MARATHON Oil Company - _ _. - - I -- - - 'Field _ -- -- 1 -- -- Cannery Loop Unit- ~ -- - i - ~ - ~ - 1-. - -_ - ~ - - -__ -__ 1 - - __ _ --- ---..- Structure !Slot I 10 read #1 1 CLU -- -.. - T..-_.- ~ _- ~ - . _. __ - Well CLU-10 i ~ ~_ ..~_ Borehole: _ _ _ _ _ ~ CLU-10 -... L__- I I _ ' _ ~! -- _-~-. -. - ~-- - - r I ~ I _ I ~ p -~ Well aPh Name _ ~ i - -~- - D <0-8450 > - _ MW - k ~- ~ ~ -~ ~ .__ T ~ I _ --- -. - __ -- - - Gr d Coordmate S stem y ~ ~ - AI saAl a State Plane Zone 4 i _ _ _ _ Location LaULong _ _. - ' N60 31 56.8398, W 151 15 48.3734 ~ - - - --. ~ I --- ~---- ~ - -- - - I -- _.- _-.. __ .- ___ Location Grid N/E Y/X 2388727.0000 ft 272452 1 OOOft i _ r , , ~ --- _ - ~GridConvergenceAngle: _ _ -_-- -110 deg I _ ~ -. ~, -j- -- ~ ~--- __ __. _-_ _ Grid Scale Factor j 0 999959 * ~ -- --- _ Survey / DLS Computation Method: -- ~. Minimum Curvature ~ _ _ ~ ._ _ I ~ _ _ ~ l- -- -. __ _ Vertrcal Azimuth Vertcal Section Ongm: ;101 25 deg ~ 0 OON, 0 OOE - ~- TVD Reference Datum RKB ___ ___ ~TVD Reference Elevation: :Rig (Glacier 1 41.0 ft above meansea level) - ' ---- - ~Sea Bed /Ground Level Elevation -- -----T _'I 0.00 ft to mean sea level j __ - __ - Magnetic Declination ~ 20 17 deg ~ (Total Feld Strength - ''.55383.68 ~Magnehc Dip..- _-_ 73 39 deg _ _ _... _... _. Dechnahon Date 18 Sep D3 ~ _ _ Magnetic Declination Model '~. BGS Global Geomagnetic Motlel (1945 0 2005.0] _ _. North Reference ,Total Corr Mao North to True North: _ TRUE 20.17 deo - 1 f ~ ~I i _ _ Inc _ 1AZi - ~TVD iTVD(SS) VS (deg) __ (deg) (ft) __+(ft) __~~(.ft) 0.00. _ 0.00- 0.0~_ 0.00 ~, -41.001, _ 123 0.45~~- 136.40 123.001 -~ -82.0 136 0.510 138.40 1 0 _ _ 95.00 _ 197 __ 0.10 ~ _ __330.20 197.00 156.00 258 0.30 - 33.20 258.00 217.00 318 _ 0.20 ~ _ _ 2.00 318.00 277.00 379` 0.60 97.30 379.00 338.00 439, 0.70 x- _ - - _ 121.70 _ _ 438.991 397.99 499 0 20 -- 142.90' 498.991 _ 457.99 _ 558 _ 0.60 __ 110.90 557.99 516.99 619 _ ~_ __ 121.20 618.98 __ 577.98 680 -~~ 05011 151.80 679.98 _ 638.98 ~-- - 741 _ 1.30 ___ 111.20 740.97 _ 699.97 804 __ 1.40 114.60 803.96 762.95 8~ __2.20__ 116.30 866.92 825.92 930 ___ 3.60 _ 112.60 929.84 ~ 888.84 994 _ _ _ 5.101 _ _ _ 109.30 993.65 952.65 _ 1057 6.506.50 ~ _ 111.90 1056.33 _ 1015.33 _ 1119 _ 10.10' _ 106.50 1117.67 10~76.67~. 1183' _ 12.70 104.20 1180.41 1139.401 ~- i 1246 15.7D _ 101.90 1241.47 _ 1200.47 1308 18.30 _ 100.70 1300.76 1259.76 13721__ 20.60] 99.80 1361.10 _ 1320.10 _ 1435 2323.00; 99.80 1419.59 1378.59' 1498 _ 25.20 101.80 1477.10 1436.10 t 5~ 28.301 100.70 1533.35 1492.35 1624 __ 3030 80 98.60 _ 1588.15 1547.15 1688 _ 32.60 99.50 1642.60 1601.60 _ 1748 32.10 99.50 1693.29 1652.29 1811 _ _ 31.80 99.30 1746.75 _1705.75 _- 187_4 _ 32.80 _ 97.80 1800.00 __ 1759.00 1953 33.66' 98.23 1866.08 1825.08 2003 r _ 34.20 98.50 1907.57 1866.57 - -- 2128 34.20 96.40 2010.96 1969.96 2253 33.80 _ 97.60 2114.59 2073.59 --- 2380 33.50 102.60 2220.33 2179.33 _ 2506 33.60.. 101.60 _ _ 2325.34 2284.34 - ~- 2633 33.50 __ 101.60 2431.18 2390.18 2758 ___ _33.90 100.60 2535.17 2494.17 ^_ 2884 _33.60 _ 101.20 2639.94 2598.94 301 ___ 33.70 100.20 _2745.66' 2704.66,_ 3137 _ 33.60 _ _ 100.20 2850.55 2809.55 3200 32.90 100.40 ~2903.23 2862.23 3263 __ 32.20 100.00 2956.341 2915.34 3325 _ 30.90_ 100.50 3009.17 _ 2968.17 3387 _ 29.60J'~. 99.60 3062.75 3021.75 3449 ~ 28.001 99.80 3117.11 3076.11 3515_ ~- 27.40 ~-~- 99.60 __3172.89 _ 3131.89 ~_-_ -- 3575 26.60' _ 100.30 3~ 3188.02 3637 26.10 100.50 3284.58 3243.58 --~.- 3700 _26.00 _ 102.70 3341.18 _ 3300.18 _ 3763 25.80 _ 105.30 3397.86. _ - _ 3356.86 __ 3827 25.50 105.40 _ 3455.55 3414.55 -- 3890 _25.20 _ __104.90 3512.48 ~ 3471.48 -- - -- 3951 , 25.20 104.70 3567.68 3526.68 N/-S E/-W 1DLS 'Northing- Fasting 0.0 0.00 0.00 0.00 238872_7.00 _ 272452.10_ - ~-~ 0.39 _ -0.36 0.32 _ 388726.63 272452.42 0.47 _ -0.44 _~ 0.37 2388726.55 272452.49 0.65 -0.60 ____ 0.54 ___ 0.98 2388726.39 272452.63 0.67 -0.42 0.60 0.44 2388726.57 272452.70 0.72 -0.18 _ 0.69 0.28 2388726.81 272452.79 1.02 _ 0.12 _ 1.01 _ 1 07 2388726.87 272453.11 1.68 ~ -0.35 _ _ 1.64 ___ 0.49 2386726.62 272453.73 2.10 -0.62 _ _ 2.01 0.86 2388726.34 272454.10 3.19 --10.85,--- -3.03 0.39 2388725.79 272455.10 3~- 1.61 3.52 4.61 -2.09 _ 4.29 _ 6.07 -2.67 _ 5.65 _ 7.98 3.52 _ 7.44 11.09 _ -4.82 _ 10.35 15.88 6.53 14.89 22.15 _ 8.79 ~---~~ 20.84 31~ -11.64 __ 29.31 43.64 --- _14.96 __ 41.51 59.08 18.42 56.57 -- 77.20 ~ -21.96 74.35 98.51 -25.74 ~~_ ~~ 95.32 121.90 -29.72 __ _118.37 147.61 34.56 143.63 175.97 40.08 ~-- 171.44 207.02 45.26 202.07 240.62 -50.56 _ _ 235.28 272.71 -55.86 _ 266.94 306.03 _ -61.30 ~_ 299 83 339.66 __ -66.30 - 333.12 382.88 _ -72.34 375.99 ~.. 410.75 _ __ _ -76.40 _ _ 403.60 480.85 -85.51] _ 473.26 550.55 - -94 03 ___ 542.63 620 86 -106 35 __ _ 611.86 690.48 __ -120 94 679.95 _760.67 -135.06 ,__ 746.71 830.02 _ -148.40 816.76 -- 900.02 -161.64 _885.50 970.39 ~ _--_-174 71 _ - ~ - 954.65 1040.20 -187.07 ___ 1023.36 1074. -193.24 __ 1057.35 1108.62 _ 199.25 __1090.71 1141.06 _ -205.02 1122.63 1172.24 _ -210.47 - _-_ 1153.34 1202.05 ~ -215.49 ~ 1182.73 1231.32 220.421 _ 1211.60 - 1259.91 225.36 1239.77 1287.43 -230.33 _1266.84 --- 1315.09 i _ __ -235.89 1293.93 1342.57 ~ -242.541 1320.63 0.20 2388724.22 272457.70 1.27 2388723.33 272459.47 2.24 2388721.98 272462.35 2.38 2388720.18 272466.86 2.26 12388717.81 272472.77 5.93 2388714.80 272481.18 4.12 2388711.24 272493.32 4.84 2388707.50 272508.31 4.98 2388683.64 272622.73 4.29 2388677.87 272653.25 2.91 2388671.94 272686.35 0.83 2388666.03 272717.91 0.50 2388659.95 272750.69 2.03 2388654.32 272783.87 1.13 2388647.46 272826.61 1.13 2388642.87 272854.14 0.94 2388632 42 272923.61 0.62 2388622.58 272992.80 2.19 238860_8 93 273061.78 0.45 2388593.03 ~ 273129.57 0.06 2388577.60 273198.04 0.55 2388562.95 273265.83 0.36 2388548.40 273334.30 0.44 2368534.01 273403.18 0.08 2388520.33 273471.64 1.12 2388513.50 273505.50 1.16 2388506.86 273538.74 2.14 2388500.48 _ 273570,54 2.37 2388494.44 273601.14 2.42 2388488.86 273630.43 0.96 2388483.37 273659.19 1.37 2388477.89 273687.26 0.821.40 273714.23 1.5412388466.32 273741.21 1.8312388459.16 273767.77 N60 31 56.8398 W 151 15 48.3734 N60 31 56.8362 W 151 15 48.3670 N60 31 56.8354 W 151 1548.3655 N60 31 56.8339 W 151 15 48.3625 N60 31 56.8357 W151 15 48.3613 N_60 31 56.8380 W 151 15 48.3595 N60 31 56.8387 W151 15 48.3531 N60 31 56.8364 W 151 15 48.3407 N60 31 56.8336 W 151 15 48.3332 N60 31 56.8317 W151 15 48.3262 N60 31 56.8285 W 151 15 48.3129 N60 31 56.8240 W 151 15 48.3031 N60 31 56.8192_ W151 15 48.2877 N60 31 56.8135 W 151 15 48.2604 N60 31 56.8051 W15t 15 48.2248 N60 31 56.7923 W 151 15 48.1666 N603156.7754 Wt511548.0759 N6031 56.7532 W151 1547.9569 N60 31 56.7251 W 151 15 47.7876 N60 31 56.6924 W 151 15 47.5437 N60 31 56.6584 W 151 15 47.2428 N60 31 56.6235 W 151 15 46.8875 N60 31 56.5863 W 151 15 46.4684 N60 31 56.5471 W 151 15 46.0077 N60 31 56.4994 W151 15 45.5028 N60 31 56.4451 W 151 1544.9470 N60 31 56.3940 W 151 t 5 44.3349 N60 31 56.3419 W151 15 43.6712 N60 31 56.2897 W 151 15 43.0384 N60 31 56.2360 W 151 15 42.3810 N60 31 56.1868 W 151 15 41.7157 N60 31 56.1273 W 151 15 40.8590 N60 31 56.0873 W 151 15 40.3072 N60 31 55.9976 W 151 15 38.9151 N60 31 55.9137 W151 15 37.5286 N60 31 55.7923 W151 15 36.1449 N60 31 55.6486 W 151 15 34.7842 N60 31 55.5095 W 151 15 33.4101 N6D 31 55.3780 W151 15 32.0500 N60 31 55.2477 W 151 15 30.6762 N60 31 55.1189 W 151 15 29.2943 N60 31 54.9971 W 151 15 27.9210 N60 31 54.9363 W 151 15 27.2418 N60 31 54.8771 W 151 15 26.5751 N60 31 54.8203 W 151 15 25.9371 N60 31 54.7666 W 151 15 25.3235 N60 31 54.7171 W151 15 24.7360 N60 31 54.6685 W 151 15 24.1591 N60 31 54.6198 W 151 15 23.5961 N60 31 54.5709 W 151 15 23.0552 N60 31 54.5161 W 151 15 22.5137 N60 31 54.4505 W 151 15 21.9601 N60 31 54.3783 W i 51 15 21.4462 N60 31 54.3088 W 151 15 20.9259 N60 31 542434 W151 15 20.4241 13 3/Sin Conductor CLU 10 Survey 1 of 2 10/20/2005 1:32 PM CLU 10 Directional Survey i - - Gnd Coordinates _ - ~ Geographic Coordinates _...- - -- -- - _. _ _ _ Inc Azi TVD ___ TVD (deg) I(de9~ ~n~ (n) (ft) ~ SS _ VS ~ft~ N/_S FJ W ~LS E NortMng - - ~deg/10 10~ (ft) 1 Basting Latitude Lon -- gdude ~- -- Comment _ -- 4015 4 7 25.20 ~ _ 4 50 ~ _ 105.00 3625.59 103 9 3682 75 ~ 3584.59 3641 75 14.5.023 27055 1424.83; 020 !2388429.16 -- __. J._-- -- 8 06 1476 67 27 16 50 3 273871.41 73 9 _ N 03154.1746 W151 0 15 19 15 8977 3 ~ ---~~ ~ 4140 _ 24 00 . _ 103 40 373 2 - - . - .47 1 3 _ _238 422. 7 14 __ _.~ ~ - I ! ~ 2 896. 2 _ N60 31 54 1 95 W 151 19 854 _, ~_._ _ _-_ . _ . 9. 8 3698.28 _ -283.17 , -_ 1475.21 1502 11 2388415.58 0 + 273921.54 _ N60 31 54 0503 W 151 15 18 8909 ___ 4203 23.40' 104.30 3796.97 3755.97 2388409.05 1527 41 289 23 1499 BO I 1 11 ~ 273946.00 6N 0 31 53.9906 W151 i 15 18 3995 ___ 4266 22.80 __ 103.60 ~ 3654.92 _ ---- 3813.92 ~ __ 1552.09 295.19 1523.79 1.05 2388402.63 - r - _._ _.- ~__-_-~ ' _ ~ 273969.87 _._ N60 31 53 93.19 W 151 15 17 _ 9201 __„~ ~~ -_ _ 4328 22.1D ~ 102.90! 39 .2 ~ ~ -~ _ 3929.691 - , 2388396.76 1599 191 -305.95' 1569.66$ 0.8~ 2388390.99 ~ 273992.81 274015.53 ~ -- N60 31 53 8784 W 151 N60 31 53 8258 W 151 ~~ ~ -- ~ 15 17 15 17 ~ 4596 0033 - - ~- --- _ _ 4454 ~ 451 ' f _ _ 20.60 20 - -- 103.40 -4029.47 10 0 3988.47 I _ _ _ _ 1621.85 - 311.201 - 1591.72_'_ 1 59 ~ 2388385.31 1 ~ _ _ 274037.49_ __ _ ~ N60 31 53 774_0_W 151 15 16 5624 _ I _ 8 1 ' .1_ 2.0 .4089.47 4048.47 1644 10 -316 101 1613.43 1.09 238838000 2 27405910 N60 31 53 7258_W151 15 16 1285_ ~ _ ~ _____ 4582 19.60y_. _ 100.10 4149.67 4108.6i~ 1665 831 -320 2~_ _ 1634.761 1 28 388375.42 274080.34 ; N60 31 53 6847 W 151 15 15. 7024 ' 1 4644 ~ 18.801 99.60 ~, 4208.22 ~ 4167.22. 1686.21. -323.76 ~ 1654.85 1 32 ~, 2388371.55 274100.36 N60 31 53.6503 W 151 15 15. 3009 _ _ _- _ I, 4708 ~ 17 50 100 10 4269.04 4228.04 _ 1706 14 ~. -327 17 1674.49; 2.05':2388367.76 274119.93 N60 31 53.6167 W 151 15 14. 9083 4769! _ _.---- 15 40 •.. ._ 100 60', 4327.54 . _. . . ~ - 4286.54 _ 1723.41 - -330 26 1691.48 3.45', 2388364.34 274136.86 ,, N60 31 53 5862 W 151 15 14 5688 f 4834 , 13 40 __ - . - _ - 102 60 ~ 4390.49 ~. - -- - 4349.49 - --- -__._ ._- _. ~.._ -~, - -. 1739 57 -333 50 1707.32 ~ 3.17 2388360.81 _ -.. 274152.63 --. _-._-..- - I N60 31 53.5544 W 151 -- 15 14. _- 2523 .-__.. --._-- 48971 -_ .- 11 70. - 104 60, 4451.98 ~- - 4410.98 1753.25 ~ -336 70 1720.63', 2 78'~, 2388357.35 274165.87 i N60 31 53 5228 W151 15 13 _ 9864 ___ ~ _ 4960! _ - 9.60 - 105 10: 4513,90 - 4472.90 -- ---- -._ --- - --- 1764 87 -339 68 1731 8~ 334 2388354.15 . ---- 274177.07 ___ __- _ ~N60 31 53 4935 W151 15 13 _- 7614 ~ r-__._ _.__ 5022 _. _ _ 7 50 _ 106 90 4575.20 __ +_ - _ 4534.20 .. 1774 06 -342 20 1740.74 3 41 12388351.46 . 274185, 88 N60 31 53 4686 W 151 15 13 _. _ 5843 ~ _ _ r 5086 ~ 5.401 _.. _ 108 2D - 4638.79' _ _ 4597.79; _ _ _ _.._- _~-. - ___ 1781.20: -344 36 ~ 1747.60 i 3.29' 2388349.17 _. _ 274192.69 ..__ _.. ; N60 31 53,4474 W 151 __. t5 13. 4472 ' ---- --- . 51491 _ 3 80 107 00 ~.. 4701.59 4660.59 1786 22 345 89 ~ 1752.41 ~, 2 54'x, 2388347 55 274197.48 N60 31 53 4322 W 151 15 13 3511 5213 3.30: 113.40 4765 47 ~ 4724.47 _ _ 1790 13: -347 24 1756.13 ~ 1.00.2388346.12 274201.17 ' N60 31 53.4189 W 151 15 13. 2768 ~ 5277 i 3 30 _ 108 40 4829 36 4 788.36 1793 76. -348 56 1759.57', 0.45 2388344.74 274204.58 N60 31 53.4060 W 151 15 13. 2080 _ 5402 2.80 108.30 4954 19 . 4913.19 1800.27 4 __ -349 76 i 1762.82 " 0.60 ~' 2388343.48 '~ -350 86 1765 75 0 47 2388342 33 274207 80 274210 71 N60 31 53.3941 W 151 N60 31 53 3833 W 151 15 13 15 13 1432 0845 L_. 54101 2.84 107.94 _ 4962.18 4921.18 1800 6~ -350 98~ 1766.13 0 57' 2388342 20 274211 O9 N60 31 53 3821 W t 51 15 13 0771 9 5/bin Casing 5440 5566 5693 _ 3.00 2 90 1.10 106.70 4992. t 4 102 20 ~ __5117.97 77 70 , 5244.89 4951.14 5076.97 5203.89 - - 1802.181 351.43 _ 1767.59 0.57 2388341.71 1808.65 -353 05; 1773.86 0.20 2388339.97 1812.98 -353 471 1778.19 1.54 2388339.47 274212.54 274218.78 274223.10 N60 31 53.3776 W 151 N60 31 53 3617 W151 N60 31 53 3575 W 151 15 13. 15 12. 15 12 -- 0479 9225 8359 _ __ 5819 0.60 _ 5945 0.50 ' 60198 0.50 . __ _ _ 279.40 __ 5370.88 5329.88 1613.43 -353111 F- 1778.72 1.33 2388339.83 274223.64 N6031 53.3611 W151 295.90; 5496.88 5455.88 1812.24: -352.76 1777.581 0.15 2388340.20 274222.50 N6031 53.3645 W151 - 5749.87 5708.88 1810.87 352.88 1776.86 0.24 2388340.11 274221.08 N60 31 53.3634 W 151 253.0 _ _ 1512.8253 __ 1512.8482 15 12.8766 _ _ _ _ __ 6322 0.20 _ 278.50 5873.87 58 2.87 3 .. ~ - 1810.1 -35 00 1 5.4 0. 23 340.0 8 3. ! 77 3 27 88 0 - 274220 34 60 3 53.3 22 W 151 N 1 6 - 15 12. 8912 6449 6573~ 0.30 i T 010 247.00 6000.87 313.60 6124.87 5959.87 6083.87 1809.68 -353.10 1774.90 0.13 2388339.91 _ -.. - - 1809.32 -353.15 1774.52 0.22 2388339.86 274219.82 ------ 274219.44 N60 31 53.3612 W 151 - N603153.3607 W151 15 12. 15 12 9017 ! ~ 9093 -- , 6825 _ 0 10 _ 1 _ _ 182 80 6376.87 6335.87 ~ 1809.25 -352.97 1774.48 0.016 2388340.05 274219.40 _ N60 31 53.3625 W 151 15 12 9101 ~ _ 695 0.101 119.80 6502.87 6461.87 1809.37 -353.13 1774.57 0.082388339.88 274219.49 N603153.3609 W151 1512. 9083 7075 7201 _. 0.50! 0.60 109.20 _ 6626.87, 105.30 6752 86 6585.87 6711 86 _ 1810.00 -353.371 1 8 _ 0.32j2388339.64 1811 21 353 72 1776 33 ~' 0 0812388339 26 274220.09 274221 24 N603153.3586 W151 N60 31 53 3551 W 151 15 12 15 12 8962 8731 - ~ - 7327 7452 7578 __ _ _ 0.60 D 30 0 70 ; _ . . ~-- 116.70 6878.85 6837.85 _ 111.00 7003.85 6962.85 119.50 7129.85 7088.85 . . . . . ~-- 1812.50 -354.19 1777 56 1813.45 -354.60 1778 45 _ _0.24 2388338.34 1814.51 355.10 1779 43 ~~~ - 0.09 2388338.77 ~ 0.32 2388337.82 . 274222.45 274223.34 274224.30 . N60 31 53.3505 W 151 15 12. N60 31 53.3464 W 151 15 12 N60 31 53.3415 W 151 15 12 -- 8486 I 8308 8113 _.. 7705 T 0.401 112.80 7256.84 7215.84 1815.68 -355.65 1780.51 0.24 2388337.25 274225.38 N60 31 53.3360 W151 15 12. 7896 _ 7831 7957 _ 0.60 _ _ 0.60 100.40 _ 738 83 2. 101.20 7508.83 1.8 734 3 7467.83 x- 16 - 94 1 0 2 3 4 18 .77 355. 178 .56 .18 388 36.9 1818.09 -356.19 1782.86 0.01 2388336.66 -- 42 6 43 27 2 . 274227.72 60 53 32 151 N 31 .33 W N60 31 53.3308 W151 5 12. 1 15 12. 7686 7427 8084 8210 _ 0.50' __ 0.80 _ 108.10 7635.82 105.70: 7761 81 7594.82 7720 81 _ 1819.31 -356.49 1784.04 0.09 2388336.3A 1820 90 1785 24 2388335 91 73 -356 41 0 274228.89 274230 25 N60 31 53.3278 W 151 N6031 53 3238 W151 15 12. 1512 7191 6417 _ 8337 _ 0.80; , . __87.20 7888.80 . 7847.80 . . . _ . . 1822.47 -357.10 1787.15 2388335.68 . _ 274231.99 . _ N603153.3218 W151 . 1512. _ 6570 _ _ _ _ t d D NO P t rojec e a a - 1 1 SURV EY, 8450 0.80 87.20 8001.79 7960.79 1824.00 -357.02 1788.72 0.00 2388335.72 274233.56 N60 31 53.3226 W151 15 12. 6255 3 1/tin Liner CLU 10 Survey 2 of 2 10/20/2005 1:32 PM Marathon Oil Company Operations Summary Report -Per Well Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Date ~ Event I r I 8uh I Report Date I From - To Hours I Code I ~ ,dc Phase - - - - - - - ~ 7/21/2005 Event 7/21/2005 12:00 - 06:00 18.00 RURD_ RIG_ MIRU 7/22/2005 06:00 - 06:00 24.00 RURD RIG MIRU 7123/2005 06:00 - 12:00 6.00 NUND BOPE MIRU 12:00 - 12:30 0.50 RURD_ RIG_ MIRU 12:30 - 13:00 0.50 TEST BOPE SURDRL 13:00 - 19:00 6.00 RURD_ RIG_ SURDRL 19:00 - 22:30 3.50 PULD_ DP_ SURDRL 22:30 - 00:30 2.00 PULD_ BHA_ SURDRL 00:30 - 02:00 1.50 DRILL_ ROT_ SURDRL 02:00 - 02:30 0.50 TRIP` DP_ SURDRL 02:30 - 04:30 2.00 PULD_ BHA_ SURDRL 04:30 - 06:00 1.50 DRILL_ ROT_ SURDRL i7/24l2005 06:00 - 12:00 6.00 DRILL_ ROT_ SURDRL 12:00 - 00:00 ~ 12.00 ~ DRILL_ I ROT_ I SURDRL 00:00 - 00:30 I 0.501 DRILL I ROT I SURDRL 00:30 - 01:00 0.50 CIRC_ MUD_ SURDRL 01:00 - 02:30 1.50 TRIP_ WIPR SURDRL 02:30 - 03:00 0.50 SERVIC RIG_ SURDRL 03:00 - 04:00 1.00 TRIP_ WIPR SURDRL 04:00 - 05:30 1.50 CIRC_ MUD_ SURDRL 05:30 - 06:00 0.50 TRIP_ WIPR SURDRL ,7125!2005 06:00 - 07:00 i.00 TRIP_ WIPR SURDRL 07:00 - 09:30 2.50 PULD_ BHA_ SURDRL 09:30 - 12:00 2.50 RURD_ CSG_ SURCSG 12:00 - 17:00 5.00 RUN_ CSG_ SURCSG 17:00 - 18:30 1.50 RURD_ CSG_ SURCSG 18:30 - 19:30 1.00 RURD_ CSG_ SURCSG 19:30 - 22:30 3.00 TRIP_ DP_ SURCSG 22:30 - 23:00 0.50 RUN_ CSG_ SURCSG 23:00 - 00:00 1.00 PUMP_ CMT_ SURCSG 00:00 - 01:00 1.00 PUMP_ CMT_ SURCSG Page 1 of 9 Spud Date: 7/23/2005 Event Type '--/-- Objective SideTrack-_-1- Description of Operations ORIGINAL DRILLING -/- Exploitation Gas OH --l-- PJSM, MIRU CLU-10, Set all loads, make primary connections. 85% moved / 10% rig up OH --/-- PJSM, MIRU CLU-10. Cont RU on CLU-10, all loads offloaded /spotted. Make up all connections. (plumbing / elect). 100% moved, 90% rig up OH --/-- PJSM N/U Diverter, Install Knife valve, Pitcher Nipple And R/U Diverter Line. Install Driveline on #1 Carrier Drive. PJSM; Function Test Diverter And Accumulator. Test PVT. Flow Indicator And Gas Monitors. AOGCC Rep. Witness Waived By Jim Regg. Accept. Glacier Rig #1 this date At 1230 Hrs. R/U Handling Tools, Top Drive Carrier,Bails,Elevators, Floor Spinners And Tongs. Adjust Torque Tube Turn Buckles. PJSM; Rabbit And Stand Back 66 Jts. 5" Dp. M/U Bit Handle BHA #1 Spud Well At 0030 Hrs. 39'. Drill Ahead 16" Hole Drctnl F 39' - 135. ART= 1.5 Hr. POOH For dretnl'BHA P/U And M/U Dir. BHA #2 ,Bit #2 Drill Ahead 16" Hole Drctnl F 135 To 315'. ART= 1.5 Hrs. OH --/-- PJSM: Drill/ Slide Survey F-315' To 861' ( ART= 1.15 Hr. AST= .75HR.) PJSM: Drill/ Slide, Survey F- 861' To 1931' (ART=1.8 Hr. AST= 4.7 Hr.) PTSM: Drill F-1931' To 1955' (Art=.15 Hr.) TD well at 1955 ft as per MOC GEO Dept Circ. Hi Vis Sweep Around At 646 gpm. 1600 psi. Sweep Returned 2000 Stks. Late Slight Increase in Cuttings. PJSM: Flow Check, Pooh Wiper trip, SLM. No Correction To 100' (No Drag, Gain, Loss, Torque) Service Rig: T/D, Blocks, Crown, Dwks PJSM: RIH Wiper trip To1955' Tag 2' Fill Circ. Hi-Vis Sweep At 1955' Shakers Cleaned up At 2500 Stks. After Sweep Cleared. PJSM: POOH Ta Run 13 3/8 Csg. OH --/-- POOH To Run 13 3/8 Csg. (No Drag, Gain or Losses) PJSM: POOH, L/D BHA #2 PJSM: R!U To Run 13 318 Csg. PJSM: Run A Total Of 45 Jts. 13 3/8 68# L-80 BTC. CSG. To 1953 (Wash F-1930' to 1953'). Note 15% increase in cuttings return,'cont Circ clean PJSM: R/D Weafherford Csg. Tools PJSM: C/O Bails;' Elevator R/U False Rotary To run 5" D/P Inside 13 3/8 Csg. PJSM: TIH W/ Stab in Tool on 5" D/P Inside 13 3/8 Csg. To 1867 (Top Of:Float Collar) Sting Into Float Collar At 1867, Break Ciro. PJSM: Pump 40 bbls Mud Clean 2 W/ Rig Pumps Turn Over To BJ, Pump 2 bbl Water And Test Lines to 2000 PJSM Mix And Pump 606 sxs Type 1 Cement Wf 22% LW-6, 20% MPA1, 1 °l° SMS, .3°I° CD-32, 2% CaCL, 1 ghs FP-6L, At 12 ppg, 2.48 cf/sk (246 bbl Slurry) Cement Returned To Shaker Mud Weight 10 ppg. Cement In Place At 0046 hr. Stop Pumping Ck. Floats, Floats Holding. Bleed Pressure Off. Max Pressure During Pumping 727 psi. Pump 2 bbl Water and 27 • • Printed: 10!20/2005 11:28:23 AM Marathon Oil Company Operations Summary Report -Per Well Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Date ~ Event ~ Sub ' ~ Report Date ~ from - To Hours ( Code i i Phase i Code ~ 00:00 - 01:00 ~ 1.OO ~UMP_ CMT_~ SURCSG 01:00 - 02:00 1.00 PUMP_ CMT_ SURCSG 02:00 - 03:30 i.50 TRIP_ CMT_ SURCSG 03:30 - 06:00 2.50 NUND ROPE SURCSG 7/26/2005 06:00 - 08:00 2.00 NUND BOPE SURCSG 08:00 - 12:00 4.00 NUND BOPE SURCSG 12:00 - 13:00 1.00 NUND BOPE SURCSG 13:00 - 17:30 4.50 NUND BOPE SURCSG 17:30 - 18:30 1.00 TEST_ BOPE SURCSG 18:30 - 00:30 6.00 PULD_ DP_ SURCSG 00:30 - 05:00 4.50 TEST BOPE SURCSG 05:00 - 05:30 0.50 TEST_ BOPE SURCSG 05:30 - 06:00 0.50 PULD_ DP~ SURCSG 7/27/2005 06:00 - 08:30 2.50 TRIP_ BHA SURCSG 08:30 - 09:30 1.00 TEST_ CSG_ SURCSG 09:30 - 10:30 1.00 TRIP_ DP_ SURCSG 10:30 - 12:00 1.50 DRILL_ CMT_ SURCSG 12:00 - 13:00 1.00 DRILL_ CMT_ SURCSG 13:00 - 13:30 0.50 DRILL_ ROT_ SURCSG 13:30 - 14:00 0.50 CIRC_ MUD_ SURCSG 14:00 - 15:30 1.50 CIRC_ MUD_ SURCSG 15:30 - 16:30 1.00 TEST_ LOT_ SURCSG 16:30 - 17:00 0.50 REPAIR RIG_ IN1 DRL 17:00 - 06:00 13.00 DRILL_ ROT_ INi DRL 7/28/2005 06:00-15:00 9:00 DRILL_ 'ROT_ INIDRL 15:00-16:00 1.00 CIRC, MUD_ INIDRL 16:00-18:00 2.00 TRIP_ WIPR INi DRL 18:00 - 19:30 1.50 SERVIC RIG_ IN1 DRL 19:30 - 20:30 i.00 TRIP_ WIPR INIDRL 20:30 - 21:00 0.50 TRIP_ WIPR INIDRL ~ 21:00 - 06:00 9.00 DRILL_ ROT_ IN1 DRL 7/29/2005 06:00 - 00:00 18.00 DRILL_ ROT_ IN1 DRL 00:00 - 02:00 2.00 REPAIR RIG INIDRL 02:00 - 03:30 1.50 DRILL_ ROT_ IN1 DRL Page 2 of 9 Spud Date: 7/23/2005 ~ Event Type --(-- Objective SideTrack- -- -- Description of Operations bbls Of mud to D~place DP. Trace cmt to surface. ICP = 316 psi, FCP = 617 psi Un Sting From Float Collar Pull Two Stands, Drop DP Wiper Dart, Circ DP And 13 318 Clear of Cmt. Approx 2 bbls cmt retuurns. POOH W/ Stab 1[i Tool PJSM: WOC, Clear Floor, Empty Pits, Flush Stack, N/D Diverter OH --/-- PJSM:P/U Diverter And Rough Cut 13 3/8 And N/D Diverter Note: Cemt Found 10' Below Head. PJSM: Remove 20" Starting Head. Cut 20" And Make Final Cut On 13 3/B.:Install 13 3/8 Vetco Gray Multi Bowl Head And Test to 1500 psi.For i 5 min. Good Test. Move Parts House Set Bop Stack Inside Gray Iron PJSM: Nipple Up BOP Stack And Related Items And Load Pipe Rack W/ 90 Jts. 5" D/P PJSM: P/U Test JT. Set Test Plug, Shell Test Stack W/Annular and Test Inside Kill Valve/Choke Manfold i Valves # 2,4 And 7 to 250 f 2500psi. Set Wear Bushing R!D Test Joint. PJSM: RIH W/ HWDP And Jars Rabbit 100 Jts 5" D/P, Stand Back In Derrick. PJSM: R/U Test Jt. Pull Wear Bushing, Test BOP Stack And All Related Equipment 250/2500. Test witnessed By AOGC Rep. Lou Grimaldi. Pull Test Plug, Set Wear Bushing L/D Test Joint M/U 12 1/4 BHA OH --/-- PJSM :M/U 122/4 BHA # 3 PJSM :Test 13 3/8 CSG. TO 2500 For 30 Min. Ok PJSM : P/U 23 Jts. D/P Rabbit And RIH, Tag Cement At 1858'. Clean Out Cement F-1858 TO 1867/ Drill F/C At 1867'. Cmt. to 1873'. Clean Out Cement F 1873 To 1951/ Drill Shoe F 1951 To 1953 C!O Cmt F 1953 To 1955 Drill F 1955 To 1975 (ART = .25) CBU At 1955 / To Clean Up Drilled Cmt. And to C/ O Mud PJSM Clean Pill Pit, Mix And Pump 30bb1. Flo- Vis Spacer Displace Hole W/ 8.8ppg Flow Pro Mud. PJSM; Run LOT'( 8.8ppg mw 440psi At 1868 TVD=13.4 E MW). PJSM :Change 4" Demco Valve On Stand Pipe. Drill F- 1975' T03230' (Art= 7.8 AST=.9) No Drag, TO, Losses Gains (Fluid Loss Over Shakers) No Accidents Splis, Near Misses OH --/-- Dir drill`and survey F/3230' to 3821'( ART=4.8 AST=2.2). - Circ. clean(CBUX2 , 635gpm, 1750psi, 70RPM). Pump dry job. POOH(hole in good condition). PJSM: Service Rig, T/D, Blocks, Crown, Swivel And Carrier. P/U And Install New D/P Spinners PJSM: TIH T-3791', Tag Fill/ Tight Hole Break Circ. Ream And Wash F-3791' To 3820' Dir Drill And Survey F/3821' To 4465' ( No Gain ,Losses, Or excessive Torque. (ADT=4.2 AST=1.3 ) No Accidents No Spills. OH --1-- Dir drill and survey F/4465' to 5330' (ART= 8.15 AST=4.5) (add 3% lubtex to mud ~ 4844' Reduced drag by 10K and torque before 8750ft-Ib after 7200ft-Ib). Trouble Shoot Top Drive Hydralics, Link tilt not operating. Unable To make a Connection Circ, Rotate and Reciprocate Pipe During Repair Of T/D (No Drag OrTorque Increase.) Drill And Survey F-5330' to 5460' (ART= 1.5 Hr.) • • Printed: 10/20/2005 11:28:23 AM Operations Summary Report -Per Well Legal Well Name: Common Well Name: Event Date Event Report Date ~ From - To 03:30 - 06:00 7/30/2005 06:00 - 06:30 06:30 - 12:30 Marathon pii Company CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 4th - ~ -, - Hours Code i Fha~e ~ C~u;1e 2.50 CIRC, MUD_ INIDRL 0.50 CIRG~ MUD_ INIDRL 6.00 REPAIR RIG INIDRL 12:30 - 15:00 2.50 TRIP_ WIPR IN1 DRL 15:00-16:00 1.00 SERVIC RIG_ INIDRL 16:00-17:30 1.50 TRIP_ WIPR INIDRL 19:30 - 21:30 2.00 CIRC MUD_ IN1 DRL 21:30 - 22:30 1.00 TRIP_ WIPR IN1 DRL 22:30 - 23:30 1.00 TRIP_ WIPR IN1 DRL 23:30 - 00:30 1.00 CIRC_ MUD_ IN1 DRL 00:30 - 04:00 3.50 TRIP_, WIPR IN1 DRL 04:00 - 06:00 2.00 PULD, BHA_ INIDRL 7/31/2005 06:00 - 06:30 0.50 TRIP_ BHA_ IN1 DRL 06:30 - 08:00 1.50 RURD_ CSG_ INICSG 08:00 - 08:30 0.50 RUNPU 'WBSH INICSG 08:30 - 09:30 1.00 TEST_ BOPE INICSG 09:30 - 10:00 0.50 RURD_ CSG_ INICSG 10:00 - 14:30 4.50 RURD_ CSG_ INICSG 14:30 - 15:30 1.00 RUN! CSG_ INICSG 15:30 - 21:30 6.00 RUN_ CSG_ IN1 CSG 21:30 - 00:00 2.50 CIRC_ MUD_ INICSG 00:00 - 02:00 2.00 PUMP_ CMT_ INICSG 02:00 - 04:30 2.50 RURD_ CSG_ INICSG 04:30 - 05:30 1.00 TEST_ WLHD INICSG 05:30 - 06:00 0.50 RURD_ CSG_ IN1 CSG 8!1/2005 06:00 - 06:30 0.50 RURD_ EOIP INICSG 06:30 - 08:00 1.50 TEST_ BOPE INICSG 08:00 - 10:00 2.00 RURD_ EOIP INICSG 10:00 - 12:30 2.50 PULD_ BHA_ INICSG 12:30 - 17:30 5.00 PULD_ DP_ INICSG 17:30 - 18:00 0.50 CUT_ WIRE INICSG 18:00 - 19:00 1.00 TEST_ CSG_ INICSG 19:00 - 20:00 1.00 TRIP_ DP_ INICSG Page 3 of 9 Spud Date: 7/23/2005 Event Type --l=-'Objective SideTrack- -- -- Description of Operations Pump Hi Vis Sweep At 636 gpm 2050psi. rpm 90 circ. shakers clean(total CBUX3, Hvy. Returns Coal, Clay And Sand). , OH --1-- Check flow(losses 1-2 BPH) and pump dry job. Top drive link tilt bleeding off. Pull 1 stand and trouble shoot TD. Reciprocate DP every 30min. C!O several hydraulic valves without success. C/O link tilt cylinder to repair TD. POOH to CSG shoe(hole in good condition). Service rig. RIH. T/ 4550 Tight spot. Work And Stack 25k Down No Go Break Circ. Wash/ Ream F/ 4550 To 4566 and F/ 5370 to 5385'. RIH To 5375 Circ/ Ream F/ 5375 To 5460'. Pump Hi Vis Sweep And Drop Carbide/ Lag Approximatley 7 bbls Over Gage.At 5460' Pump At 650 gpm 2050psi 90 rpm. Hvy Returns Of Coal, Sand And Clay, B/U gas 262units) CBUX2 PJSM: Monitor Well POOH (To 4550' Hole Clean No Gains, Losses Or Excessive Drag. RIH To 5460' Hole Clean No Drag Or Tight Spots. CBU At 655 GPM 2050 psi 90 RPM B/U gas 30 units. PJSM: Monitor WeII,Pump Dry Job/ Pooh SLM /To Run 9 5/8 Csg. (No Drag, Gains Or Loss) Hole Taking Correct Fill. No Correction On SLM To Tally. PJSM: Lay Down, 12 1/4 BHA. OH --/-- Cont. POOH and UD BHA, Clear rig floor. C/O variable rams to 9 5/8" CSG rams. Pull wear bushing. Set test plug and'-.test joint. Shell test BOP to 250/2500psi 10min. P/U 9 5/8" LJ and hanger and make test run. PJSM. R/U long bales and CSG elevators. Adjust torque tube. R/U CSG tongs and tools. PJSM. Bakerlokand M/U shoe tract. Circ. through shoe tract and check floats. Run 128 Jts. 9 5/8" 40ppf L-80 Butt CSG M/U Landing JT And 9 5/8 x 13 5!e Vetco Hanger. Shoe Set At 5410' F/C At 5325' Up Wt. 230k Dn.'-~/Vt. 130k. Correct Displacement/ No Drag/ Or Bridges PJSM: M/U Cement Head And Circ 1 1/2 x Csg, Volume And Cond. Mud For Cmt./ Circ At 150 Spm. 250 gpm = 250 psi PJSM:Pump 5 bbl. Water/ Test Lines to3000. Pump 30 bbl. MCS-4 Spacer Drop Bttm. Dart Pump 74.69bbls 12.5ppg. Lead Cmt. +2.2% bowc.SMS,.S°l°bowc. FL-52,.2% bowc CD-32,bowc CaCI .05% bowc + 1 gps FP6L. Follow W/ 45.10 bbls Of 15.8 ppg. Class G Cemt. With 2%bowc KCL+ .05%bowc FL-32+ .3% bowc CD-32+.15% bowc+ASA-301+ .1 % R-3 + 1 gps FP6L. Displace W 5 bbl Water and 398.7 bbls mud At 250 psi 7 bbls Per Min. Using Rig Pumps. Bump Plug To 1500 psi. Release Floats Held Bleed Back 2 bbls. 2 to 3 % Change In returns Throughout Job. Cement In Place At 0200 Hr. PJSM: R/D Csg. Tools, UD Landing Joint, Change& Bails Install packoff, Test To 5000psi For 15 Min. Test Good R/U Floor, Align Torque Tube And Hang Tongs OH --/-- Adjust torque tube and R/U DP tools. PJSM. C/O 9 518" CSG rams to 2 7/8" X 5 1/2° variable rams. Test door seals to 250/2500psi 5min. Adjust TD torque tube. M/U 8.5" bit and BHA. RIH w/BHA. P/U 100jnts 5.0" DP w/RIH. PJSM: Slip 33" Drlg. Line& Ck. Crown-o-Matic PJSM: Test 9 5/8 Csg. To.2500 psi Hold F/30 Min Test Good. RIH F-3921' To 5326' • • Printed: 10120!2005 11:28:23 AM ...Marathon Oil Company Operations (Legal Well Name: Common Well Name: Event Date iEvent Report Date : FromTo 20:00 - 21:00 21:00 - 21:30 21:30 - 23:00 23:00 - 00:00 00:00 - 06:00 CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 r Hours ~ Code ~ Sub. J Phase i Code 1.00 DRILL_ CMT_ INICSG 0.50 DRILL_ ROT_ INICSG 1.50 CIRC_ MUD_ INICSG i.00 TEST_ LOT_ INICSG 6.00 DRILL ROT PRIDRL 8/212005 06:00 - 18:30 12.50 DRILL_ ROT_ PR1 DRL 18:30 - 20:00 1.50 CIRC MUD PR1 DRL 8/3/2005 8/4!2005 8/5/2005 20:00 - 22:30 I 2.501 TRIP I WIPR I PR1 DRL 22:30-23:30 1.00 SERVIC .RIG_ PRIDRL 23:30-00:30 1.00 TRIP_ .WIPR PRIDRL 00:30 - 06:00 5.50 DRILL ROT PR1 DRL 06:00 - 04:00 22.00 DRILL_ ROT_ PR1 DRL mmary Report -Per Well Spud Date: 7/23/2005 Page 4 of 9 Event Type --1-- Objective SideTraek -- Descnption of Operations Tag FJC At 5326' Drlg. F/C & Shoe Track To 5409' Drlg. Shoe To 5410. Clean Out F- 5410' To 5460' Drill New Hole F- 5460 To 5480' Circ. And Condition Mud For L/O Test Perform LOT (9.3 ppg. MW + 1000psi ~ 4962' TVD = 13.1 EMW . Drill/ Slide & Survey F-5480' To 5872' (Rot=3.5 AST=1.1) No Gain Or Loss, Torque 2500-2850K. No Accidents,Spills or N/M. OH --/-- Dir drill and survey F/5872' to 6940' (ART=10 AST=). Pump Hi-Vis Sweep CBU 2x (Sweep Returned WJ 250-300 °f° Increase In Cuttings Over Shakers. Circ At 550 Gpm 2050 Psi PJSM: Wiper Trip To Shoe At 5410. Pulled tight At 6570, 6549, 6431, 5908, 5844 Wash And Ream F- 6240 - 6224,.5935 and 5580'. No Gains Or loss. (Naive Dri-I 35 Sec.) Service Rig, Top Drive, Crown, Drawworks, Carrier, And Blocks RIH: F- 5410 To 6940 (Wiper) Hole SIicW No Fill. No Gain/ Loss. Max Gas 240 Units On B/U. Pump Sweep Drill F- 6940- To 7254' (ART=13.7 AST= 0) Sweep Returned W/ 100% Increase In Cuttings. No Gain. No Loss. Torque 25128. OH --/-- Dir drill and survey F/7254' to 8400'. Pump 10.5ppg weighted sweep @ 7568' & 8200'. 100% increase in returns On each. ART=18.2 Hr. No Gain/ Loss (Max Gas 670 Units) 04:00 - 06:00 2.00 CIRC_ MUD_ PR1 DRL Circ. Condition Hole/ Mud For Wiper Trip( logs 08400' while wait on final TD from Geo. Dept. Pump weighted & Hi-Vis Sweeps 100% Inc. of cuttings over shakers. 06:00 - 07:30 1.50 DRILL_ ROT_ PR1 DRL OH --/-- Dir dril and survey F/8400' to 8450'(ART=1.Ohrs). 07:30 - 08:30 1.00 CIRC_ MUD_ PRIDRL Circ. clean(CBUX2, 520gpm, 85RPM, 1850psi}. 08:30 - 11:00 2.50 TRIP_ WIPR PR1 DRL Flow check. POOH to 8076. Pump dry job Cont. POOH. Tight 07934', 776', 7615', 7462', 7360', 7335', 7193', 7168', 7118', 6987', 6940'. W/R 7761'-7758', 7624'-7600', 7575'-7570, 7020'-6949'. 11:00 - 12:00 1.00 CIRC_ MUD_ PR1 DRL Circ. clean 6890'-6950' (CBU X 2,500 gpm, 85 RPM fair amount of clay across shakers). 12:00 - 14:30 2.50 TRIP_ WIPR PR1 DRL Cont. POOH to CSG shoe. Tight 0 6879', 6843', 6814', 6751', 6686', 6661', 6566', 6106', 6068'. 14:30 - 15:00 0.50 SERVIC RIG_ PR1 DRL Service rig. 15:00 - 16:30 1.50 TRIP_ WIPR PR1 DRL RIH. Tag bridge 0 8384'. Wash F/8328' to 8450'. 16:30 - 18:30 2.00 CIRC_ MUD_ PRi DRL Circ. clean (GBUX3, 500gpm, 85RPM, 2000psi, i440units B!U gas, large amount of clay across shakers). 18:30 - 02:00 7.50 TRIP_ DP_ PR1 DRL POOH (SLM). Tight spot 0 6260'. L/D Directional tools and bit - no correction on SLM. 02:00 - 03:30 1.50 LOG_ OH_ PR1 EVL PJSM. R/U Precision WLS. M/U E-line tools. 03:30 - 06:00 2.50 LOG_ OH_ PR1 EVL Run Precision Quadcombo tools. 06:00 - 08:30 2.50 LOG_ OH_ PR1 EVL OH --/-- Log Precision Quadcombo. 08:30 - 09:30 1.00 LOG_ OH_ PR1 EVL R/D Precision E/L. 09:30 - 11:00 1.50 PULD_ DP_ PRIEVL L!D 5" HWDP. 11:00 - 14:00 3.00 TRIP_ DP_ PRi EVL RIH w/open end8d 5" DP. 14:00 - 14:30 0.50 PULD_ DP_ PR1 EVL Cont. RIH P/U 5"' DP from rack to 8448'. { 14:30 - 16:30 2.00 CIRC MUD_ PRIEVL CBU (3960 unifs`gas 0 B/U). Shut in well and circ. through choke and increase MW to 10ppg. 16:30 - 17:00 0.50 CIRC_ MUD_ PRIEVL After 8660 stks of 19000 stks (full circ). Open BOP and cont. to circ. gas 300units and falling. Drawworks brakes slipped and Top Drive elevators hit rig floor. No injuries but damage to top drive unit. 17:00 - 22:00 5.00 CIRC_ MUD_ PR1 EVL Cont. to circ. and: occaisionally work pipe while repair top drive and investigate incident. 22:00 - 22:30 0.50 CIRC, MUD_ PR1 EVL Flow check and pump slug. J Printed: 10/20/2005 11:28:23 AM Marathon Oil Company Page 5 of 9 Operations Summary Report -...Per Welt Legal Well Name: CA NNERY LOOP UNIT 10 Common Well Name: CA NNERY LOOP UNIT 10 Spud Date: 7123!2005 Event Date ~ Event ~ ~ Hours ~ Code ~ Sub ~ Phase _ _ ~ Event Type --/- Objective Report Date From - To Code ~ SideTrack- -,-- Description of Operations 22:30 - 00:00 1.50 TRIP_ DP_ PR1 EVL POOH to 7563'. 00:00 - 01:00 1.00 LOG, OH_ PR1 EVL PJSM prior to running E/L. R/U precision E/L. 01:00 - 06:00 5.00 LOG_ OH_ PR1 EVL Run Precision CFRT(31of 40 points for 1 of 3 intervals done ~06:OOhrs). 8/6/2005 06:00 - 08:30 2.50 LOG, OH~ PR1 EVL OH --/-- Cont. Running CFRT log. POOH w{CFRT and RID Precision E/L. 08:30 - 09:00 0.50 TRIP_ DP, PR1 EVL POOH to 6800'. ,, 09:00 - 09:30 0.50 LOG OH, PR1 EVL R/U Precision E/C. 09:30 - 11:00 1.50 LOG_ OH_ PR1 EVL Troubleshoot CRFT tools. i 1:00 - 15:30 4.50 LOG_ OH_ PR1 EVL Run CFRT log.;. - 15:30 - 19:00 3.50 LOG, OH_ PR1 EVL CIO CRFT tools and calibrate. RIH. 19:00 - 22:00 3.00 LOG_ OH_ PR1 EVL Run CFRT tools..- Tools failed POOH w/CFRT. Repair tools. 22:00 - 23:00 1.00 LOG_ OH^ PR1 EVL RIH w/CFRT. Tools failed. Troubleshoot tools. 23:00 - 00:00 1.00 LOG_ OH_ PR1 EVL R/D Precision E/L. 8/6/2005 ~ Event 00:00 - 00:30 0.50 TRIP_ DP_ PRICSG 00:30 - 01:30 1.00 CIRC_ MUD_ PRICSG 01:30 - 06:00 4.50 INSPCT RIG_ PR1 CSG 18/7/2005 06:00 - 08:30 2.50 INSPCT RIG_ PRICSG ~ 08:30-10:30 2.00 TRIP_ DP_ PRICSG 10:30 - 11:00 0.50 SLPCUT DLIN PRICSG 11:00 - 17:30 6.50 REPAIR RIG_ PRICSG i 17:30 - 20:30 3.00 TR1P_ DP_ PRICSG 20:30 - 21:30 1.00 TRIP_ BHA_ PRICSG 21:30 - 02:00 4.50 TRIP_ DP~ PRICSG ~ 02:00 - 03:30 1.50 CIRC_ MUD_ PR1 CSG 03:30 - 06:00 2.50 PULD_ DP~ PRICSG 18/812005 06:00 - 12:00 6.00 PULD_ DP_ PRICSG 12:00 - 12:30 0.50 RUNPU WBSH PRICSG 12:30 - 17:00 4.50 RURD_ CSG_ PRICSG 17:00 - 00:30 7.50 RUN! CSG_ PRICSG 00:30 - 01:00 0.50 CIRC_ MUD_ PRICSG 01:00 - 06:00 5.00 RUN_ CSG_ PRICSG 8/9/2005 06:00 - 09:00 3.00 RUN_ CSG_ PR1 CSG 09:00-10:30 1.50 CIRC_ MUD_ PRICSG 10:30-14:30 4.00 LOG_ CSG_ PRICSG 14:30 - 15:30 1.00 PUMP_ CMT_ PRICSG 15:30 - 16:30 1.00 CIRC_ MUD_ PRICSG 16:30 - 17:00 0.50 PUMP_ CMT_ PRICSG 17:00 - 18:00 1.00 PUMP_ CMT_ PRICSG Move to completion operations OO:OOhrs 08/06/2005. ORIGINAL COMPLETION --/-- Exploitation -Gas RIH to 8450'. Ciro.(470gpm,1000psi,270 units gas). Circ.(470gpm,1000psi,270 units gas). POOH to 8378'. R/U circ. line and circ(136gpm, 290psi) while clean top drive, bales, and elevators for inspection. C/O service loop tarp while doing inspection(inspection found cracked pins that pin link tilt cylinders to top drive). OH --f-- Cont. to circ. wlcement hose (135gpm, 290psi) while inspect TD, bales and elevators. POOH to CSG shoe. PJSM. Slip and cut 115' of drilling line. Resurface drawworks drum brakes. C/O brake pads. Adjust brake linkage. POOH w/open ended DP. P/U cleanout BHA. RIH to 8450'(hole in good condition, wash last stand down, no fill). circ. clean (CBU:X 2, 520 gpm, 1575 psi, 82 RPM, 270 units gas). Flow check pump dry job. POOH L/D DP. OH --/-- Cont. POOH L/D DP, HWDP and Bit. Pull wear bushing. PJSM for Excape completion. C!O bales and elevators. RID DP tongs. R/U Weatherford CSG tools. R/U Expro control line sheaves. Run 3 1/2" 9.3PPF L-80 Excape completion. Run 12 modules total to 2800'. circ. ~ 2800'. ' Cont. running 3.5" Excape completion (6000' ~ 06:OOhrs). OH --/-- Cont. run 3 1/2" CSG (total 12 modules and 250 jnts P/U 93K, S/O 65K, shoe 8419', FC 8383'). R/U circulating hose and circ. CSG(307gpm, 1800psi, B/U gas 160units). R/U Expro W/L while circ. PJSM. Run Correlation log. PJSM. R/U cement head. Pump 250bb1s inhibited mud ahead. Mix and pump 5bbls 11.Oppg spacer ahead. Test lines to 3500psi. Mix and pump 35bbls 11 ppg spacer. Mix and pump 1324SXS "G" cement wJ1.2°I°BA-56, .3°f°R-3, .5%EC-1, .3%SMS, igphs FP-6L to yield 274bb1s 15.8ppg C7 • Printed: 10/20/2005 11:28:23 AM Marathon Oil Company Operations Summary Report -Per Well !Legal Well Name: CANNERY LOOP UNIT 10 Common Well Name: CANNERY LOOP UNIT 10 Event Date ~ Event i ~ Sub Hours Code Phase Report Date ~ Frorn - To _ ~ _ ~ _ _ ~ Code ~ 17:00- 18:00 ~ 1.00 PUMP_~CMT_ PRICSG 18:00 - 00:00 ~ 6.00 ~ CLEAN_ ~ RIG_ ~ PR1 CSG 00:00 - 06:00 ~ 6.00 ~ CLEAN_~ RIG_ ~ PR1 CSG 8/10/2005 06:00 - 08:00 2.00 NUND BOPE PRICSG 08:00 - 08:30 0.50 NUND TREE PRICSG 08:30 - 09:30 1.00 NUND TREE PRICSG 09:30 - 10:30 1.00 NUND TREE PRICSG 10:30 - 11:30 1.00 TEST_ TREE PRICSG 11:30 - 12:30 1.00 TEST_ TREE PRICSG 12:30-13:00 0.50 RUNPU EOIP PRICSG 13:00 - 00:00 11.00 RURD_ RIG RDMO 00:00 - 06:00 ~ 6.001 RURD_! RIG_ RDMO 8/11/2005 06:00 - 12:00 I 6.001 KURD. ~ RIG RDMO 8/17/2005 Event 8/17/2005 08:00 - 08:15 0.25 SAFETY MTG_ WBPREP 08:15 - 08:30 0.25 SAFETY MTG_ WBPREP 08:30 - 10:30 2.00 RURD_ ELEC WBPREP 10:30 - 12:00 1.50 RUNPU ELEC WBPREP 12:00 - 15:00 3.00 LOG_ CSG_ WBPREP 15:00 - 16:00 1.00 RURD_ ELEC WBPREP 8/24/2005 06:00 - 18:00 12.00 RURD_ STIM CMPSTM 8/2512005. 06:00 - 18:00 12.00 RURD_ STIM CMPSTM 8/26/2005 06:00 - 18:00 12.00 RURD_ STIM CMPSTM 8/27/2005 06:00 - 18:00 12.00 RURD_ STIM CMPSTM 8!30/2005 06:00 - 18:00 12.00 RURD_ STIM CMPSTM 8/31/2005 06:00 - 11:30 5.50 RURD_ STIM CMPSTM Page 6 of 9 Spud Date: 7/23/2005 Event Type --/-- Objective SideTrack- ---- Description of Operations slurry. Wash up,lines to slop tank. Drop plug and displace wl73bbls 6%KCL brine.. Bump plug wl2700psi 500psi over displacement pressure. Check floats OK. CIP~ 18:OOhrs. Pipe reciprocated while cementing. 100% returns during entire job. R/D cement head and lines. While WOC: Flush w/water all lines to pumpsl,2,and 3 and choke. RID drip pan, BOP turnbuckles, bell ;nipple, trip tank lines, clean trip tank. Empty mud pits. Change oil in #2 carrier engine. Install new hanging line for DP spinners. ' PJSM. While WOC: NID choke and kill lines. NID fill up line. Wah and pump out cellar. Blow down mud and choke lines. R/D panic line, carrier tarp, and mufflers, choke and gas buster, stand pipe manifold. Break lower stand pipe and cement line, splash guards. UD mouse hole, Weatherford tools and units. Clean mud pits. R/D Auto driller, trip tank, koomey lines. Spot in BOP stand. Break and remove BOP bolts. OH --/-- PJSM. Lift BOP stack. Set slips w/95K. Rough cut 3 1/2" CSG. UD cut joint. Set BOP aside. Make final cut and dress off. Install pack off and test to 5000psi/10min. Install TWC and N/U tree. Test tree void to 5000psi/10min. Test tree to 10000psi/10min. Pull TWC and run BPV. RID bales and elevators. R/D centrifudge cuttings tank and load out. PJSM. R/D slide, service loop, kelly hose, set TD in rack and lay down. R!D turnbuckles. Laydown torque tube. Pickle pumps#1 and #2. RID derrick board. R/D stairs above BOP connex and beaver slide. R/D cylinder socks and T-bar. Prep derrick and scope down. Prep to layover derrick. Prep to move MI and directional drillers trailer. R/D water line and communications line. Install new teflon on TD slide. R/D drillers console and brake linkage. Load trailers. PJSM. R/D choke and dog house electrical and service lines. Prep cellar. Pull trip tank. RID panic line. PJSM for crane work. R/D back ~vindwalls and landing. Lay derrick over. Crane down derrick house, stairs, BOP landing, conex, dog house and choke+house, front windwalls, sub outriggers and flowline. OH --1-- PJSM, Rig do i break all components, make ready for move to KTU 43-6xrd2 Release Glacier dig #1 this date 1200 hrs No do time / acc.`': ORIGINAL COMPLETION --/-- Exploitation -Gas OH --1-- Arrive at gas field, sign in, and obtain work permit. Discuss job ahd safety issues Survey location and conduct job sight meeting. RU eline unit to wellbore with packoff and CBL tool. RU empty drum for wellbore fluid (KCIj displacement. RIH w/ CBL tool checking correlation and drift. Tag at 8,336' PUH with CBL tool evaluating cement. RD wireline equipment OH --/-- Transport 10 frac tanks to location. Spot 9 for frac job and 1 for CT unit. Manifold frac tanks. OH --/-- Start hauling water and filling frac tanks. Started laying out liner for frac equipment foot prints. OH --1-- Finished hauling water and filling frac tanks. Continued laying out lilner for frac equipment foot prints. OH --/-- Mixed 6% KCL in frac tanks and CT tank. Finished laying out pad liner for frac equiment foot prints. OH --/-- Started RU frac trucks, sand kings, well testers, and CTU. Pressure tested CTU lines and pum truck to 4500 psi. OH --/-- Finsished RU of frac equipment and well test equipment. Pressure test frac trucks and lines to 9500 psig. Pressure test well test equipment to 4500 psig. • C Printed: 10/20/2005 11:28:23 AM Marathon Oil Company Operations Summary Report -Per Well Legal Well Name: Common Well Name: Event Date I Event Report Date From - To 11:30 - 13:00 9(112005 06:00 - 07:00 07:00 - 08:00 08:00 - 08:15 08:15 - 08:30 08:30 - 09:15 09:15 - 10:00 10:00 - 10:30 I 10:30 - 11:45 i 11:45 - 12:15 I i 12:15 - 12:45 12:45 - 13:15 13:15 - 13:45 13:45 - 14:45 CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 Hours Code i Suh .Phase Code 1.50 ~PERF_ ~ CSG_ CMPSTM 1.00 INSPCT EOIP CMPSTM 1.00 SAFETY MTG_ CMPSTM 0.25 PUMP _FRAC CMPSTM 0.251 PUMP_I FRAC CMPSTM 0.75 ~ FLOW_~ BACK I CMPSTM 0.751 PUMP I FRAC I CMPSTM 0.501 PUMP_P'-FRAC CMPSTM 1,25 SERVIC EQIP CMPSTM 0.50 PUMP FRAC CMPSTM 0.501 PUMP_~ FRAC I CMPSTM 0.501 PUMP (FRAC (CMPSTM 0.501 PUMP_ _I FRAC I CMPSTM 1.001 PUMP_I FRAC (CMPSTM Page 7 of 9 Spud Date: 7/23/2005 Event Type -/-- ©bjective _SideTrack- ~-l-- Description of Operations RU expro firing lines and monitoring equipment. Pressure tested firing line to 10,000 pstg. Opened up green firing line. Pressure up to 6050 psig and fired Module 1 guns Perforatino 8265-8275' RKB. Good indications of gun firing. RD Expro and SDFN. OH --/-- Inspect frac equipment and lines. Warm up frac trucks and gel up fluid. Hold PJSM. Discussed frac operations, chemical trcaing, module pertorating, and well testing. Open well. SITP = 615 psig (estimated BHP = 4100 psig) Perform injection test with 30 bbis 6% KCL. (SIP = 2845 psig. FG = 0.81 psi/ft. (Total Load = 30 bbls) Frac mod 1 perts (8265-8275' RKB) w/ BJ Lightning_V_1800 wtr based system at 15 BPM at max TP = 5897 psi. Ramp 2.0 - 8.0 ppa. Job screened out to 9150 psig surface pressure with 8 ppg on perts and 60 bbls of flush pumped (11 bbls short) Place 15858 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand) or 86% of design. Tot Load = 184 bls)I. Tagged w/ ProTechnics CFT 1100 chemical tracer and field tracer AUM 01 (cumm. load = 214 bbls) (Strap chemical tanks post frac) Open well up and attempt to flow same. Flowed back 72 bbls of flush volume to flowback tank. (Tubing volume to module 1 perts) Pumped 72 bbls of pad volume back into well. Ready to pert and frac module 2. Perforate Module 2 from 6219-8229' with +/- 3200 psig on yellow line. Frac mod 2 perts w/ BJ Lightning_V_1800 wtr based system at 15 BPM at max TP = 5000 psi. Ramp 1.0 - 8.0 ppa. Place 21888 Ibs prop {87.5 % 20!40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 217 bbl. Tagged w/ ProTechnics CFT 1200 chemical tracer (cumm. load = 431 bbls) (Strap chemical tanks post frac) Perforate Module 3 from 8098-8108' with +!- 5175 psig on yellow line. Frac mod 3 perts w/ BJ Lightning_V_1800 wtr based system at 15 BPM at max TP = 7200 psi. Ramp 1.0 - 8.0 ppa. Extend 2 and 4 ppg stages to work pert friction. Place 28028 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load= 253 bbl. Tagged w/ ProTechnics CFT 1400 chemical tracer (cumm. load = 684 bbls) (Strap chemical tanks post frac) Flex sand king coupler broke. Replace same with spare off of other sand king in KGF. Perforate Module'4 from 7965-7975' with +/- 6100 psig on yellow line. Frae mod 4 perts w/ BJ Lightning_V_1800 wtr based system at 15 BPM at max TP = 6200 psi. Ramp 2.0 - 8.0 ppa. Place 26739 Ibs prop (87,5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 216 bbl. Tagged w/ ProTechnics CFT 1500 chemical tracer {cumm. load = 900 bbls) (Strap chemical tanks post frac) Perforate Module 5 from 7716-7726' with +/- 7300 psig on yellow line. Frac mod 5 perts w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 4000 psi. Ramp 2.0 - 8.0 ppa. Place 25411 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 207 bbl. Tagged w/ ProTechnics CFT 1600 chemical tracer (cumm. load = 1107 bbls) (Strap chemical tanks post frac) Perforate Module 6 from 7174-7184' with +I- 9470 psig on yellow line. Frac mod 6 perts w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 4580 psi. Ramp 1,0 - 8.0 ppa. Place 22682 Ibs prop (87.5 % 20/40 Ottawa & 12,5% 12/20 Flex Sand). Tot Load = 205 bbl. Tagged w/ ProTechnics CFT 1900 chemical tracer (cumm. load = 1312 bbls) (Strap chemical tanks post frac) Perforate Module 7 from 7083-7093' with +1- 9470 psig on red line. Frac mod 7 perts w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP =8100 psi. Ramp 2.0 - 8.0 ppa. Job screened out after 58 bbls flush pump (3 bbl short or 89% of design) Pface 23178 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 191 bbl. Tagged w/ ProTechnics CFT 2000 chemical tracer (cumm. load = 1503 bbls) (Strap chemical tanks post frac) Perforate Module 8 from 7030-7040 with +/- 4780 psig on red line. Attempt to pump in to module 8 perts without success. ( Estimate 2 ppg across from perts) Pressure up three times without success to 8300 psig. Open well up to flow back. Flowed back 15 bbls to surge perts. Attempt to pump in to Module 8 perfs'with 8800 psig without success. Open up well • rrm~ea: wizwzuv° 7,7:Ztl:Z:! HM 4' Marathon Oil Company Operati©ns Summary Report -Per Well Legal Well Name: CANNERY LOOP UNIT 10 Common Weil Name: CANNERY LOOP UNIT 10 Event Date I Event ~ Sub i Hours Code Phase Report Date_ from - To _ ~ _ 'I _ Code ~ - _ 13:45 - 14:45 1.00 PUMP_ FRAC CMPSTM 14:45 - 15:15 0.50 PUMP FRAC CMPSTM 15a 5 - 15:45 ~ 0.50 ~ PUMP_~ FRAC ~ CMPSTM 15:45 - 16:00 ~ 0.251 PUMP_~ FRAC ~ CMPSTM 16:00 - 16:15 I 0.251 PUMP I FRAC I CMPSTM 16:15 - 16:30 ~ 0.251 PUMP_ FRAC CMPSTM 16:30 - 17:00 0.50 RURD_ STIM CMPSTM 17:00 - 18:00 1.00 RURD_ STIM CMPSTM 18:00 - 18:30 0.50 RURD_ COIL CLNOUT 18:30 - 19:00 0.50 RURD_ COIL CLNOUT 19:00 - 21:00 2.00 RURD_ COIL CLNOUT 21:00 - 23:00 2.00 RURD_ COIL CLNOUT 23:00 - 00:00 1.00 RURD_ COIL CLNOUT 00:00 - 01:45 1.75 RUNPU COIL CLNOUT 01:45 - 04:15 2.50 RUNPU COIL CLNOUT 04:15 - 05:00 0.75 JET_ N2_ CLNOUT 05:00 - 06:00 1.00 JET N2_ CLNOUT 9/2/2005 06:00 - 07:00 1.00 JET! N2_ CLNOUT 07:00 - 07:30 0.50 JET_ N2_ CLNOUT 07:30 - 08:00 0.50 JET_ 'N2_ CLNOUT 08:00 - 09:00 1.00 RUNPU COIL CLNOUT 09:00 - 10:00 1.00 KURD _ COIL CLNOUT 10:00 - 11:30 I 1.501 FLOW I TEST I CMPFLW Page 8 of 9 Spud Date: 7/23/2005 Event Type --(-- Objective SideTrdck- --, -Description of Operations again and flow back 74 bbls. Attempt to pump into well. Pumped 72 bbls with final pump pressure +/-3500 psig Frac mod 8 perfs w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 5600 psi. Ramp 1.0 - 8.0 ppa. Place 22534 Ibs prop (87.5 % 20/40 Ottawa & 12.5°1° 12(20 Flex Sand). Tot Load = 201 bbl. Tagged w/ ProTechnics CFT 2100 chemical tracer (cumm. load = 1704 bbls) (Strap chemical tanks post frac) b Perforate Module 9 from 6956-6966' with +/- 5610 psig on red line. Frac mod 9 perfs w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 2750 psi. Ramp 2.0 - 8.0 ppa. Place 24961 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 196 bbl. Tagged wf ProTechnics CFT 2200 chemical tracer (cumm. load = 1900 bbls) (Strap chemical tanks post frac) Perforate Module 10 from 5877-5887' with +/- 7220 psig on red line. Frac mod 10 perfs w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 2830 psi. Ramp 2.0 - 8.0 ppa. Place 22374 Ibs prop (87.5 % 20/40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 175 bbl. Tagged w/ ProTechnics CFT 1000 chemical tracer (cumm. load = 2075 bbls) (Strap chemical tanks post frac) Perforate Module:ll from 5710-5720' with +/- 8210 psig on red line. Break-down mod 11 perfs w/ BJ Lightning_V_1600 virtr based system at 15 BPM at max TP = 3960 psi. Final pressure = 2800 psig. Tot Load = 25 bbl. Tagged w/ ProTechnics CFT 2500 chemical tracer (cumm. load = 2100 bbls) (Strap chemical tanks post frac) Perforate Module 12 from 5671-5681' with +/- 10150 psig on red line. Frac mod 12 and 11 intervals w/ BJ Lightning_V_1600 wtr based system at 15 BPM at max TP = 3595 psi. Ramp 2.0 - 8.0 ppa. Place 33228 Ibs prop (87.5 20!40 Ottawa & 12.5% 12/20 Flex Sand). Tot Load = 219 bbl. Tagged w/ ProTechnics CFT 2500 chemical tracer (cumm. load = 2319 bbls) (Strap chemical tanks post frac) Hold RD safety meeting and discuss frac equipment clean up and RD operations. RD frac lines and frac trucks. Hold PJSM and discuss coil tubing operations and cleanout procedure. Function test BOPs. Attempt to unlock blindrams without success. Change out BOPS and function test same. Stab injector head. Break circulation. Replace leaking o-ring on injector head Bowen connection. Pressure test BOPs 200 to / 4500 high. RIH with CT Pump circulating at min rate to 5500'. Take PU and SO weights. Increase pumps to 2 BPM. RlHwith CT. Break module 12 flapper at 5677 CTM, RIH and break Module 11 flapper at 5716' CTM, RIH. Did not find Module 10 flapper. Continue RIH to PBTD of 8339' CTM (could not wash further) Broke flappers in modules 9, 8, 6, 5 at ~' 6976', 7049', 7196', and 7723' CTM, respectively. Uncertain flapper breaks in modules 7 and 3, at 7093' and 8105' CTM, respectively. Did not find flappers in modules 4 and 2, at 7972' and 8228' CTM, respectively. Decrease fluid pump rate to 1.5-1.75 bpm and start Nitrogen at 400 scfm. Circulate at 8339' CTM. WHP = 90 psig. Slowly POOH to :above perforations to 5450' CTM. Field detectable tracer ihdicated fluid flow from Module 1. Reduce fluid ~ rate to .75 bpm. Nitrogen still at 400 scfm. WHP ~ 120 psig. OH --/-- Cut fluid rate to zero and increase Nitrogen to 500 scfm at 5450' CTM jetting above perfs. WHP = 77 psig Increase Nitrogen to 700 scfm. WHP increased to 450 psig. - WHP increasing..; WHP = 630 psig. Decreased nitrogen to 500 scfm Well=flowing. Shut down nitrogen and POOH with CT. Had good show on FDT 01 in Module 1 indicating Mod 1 flowback. Open well flow stream through tree flowline and through sand buster. Closed swab valve and blew down CT nitrgoen pressure. RD injector head and secured remaining CT equipment. Released CT crew. Monitor well flow for gas. Able to put well into separator at 1100 hours. Well still very sluggish. Initial test rate = 1.2-1.6 mmcfd, 1800-2000 bwpd and 800-1000 psig FTP • L' Nnntetl: 10120/2005 11:28:23 AM Marathon Oil Company Page 9 of 9 Operations Summary Report -Per Well Legal Well Name: Common Well Name: Event Date !Event Report Date I From - Ta 11:30 - 13:30 13:30 - 06:00 9/3/2005 06:00 - 06:00 9/4/2005 06:00 - 06:00 9/5/2005 06:00 - 06:00 9/6/2005 06:00 - 06:00 9/7/2005 06:00 - 06:00 9(8/2005 106:00 - 06:00 9/9/2005 9/10/2005 9/23/2005 06:00 - 06:00 06:00 - 09:00 09:00 - 18:00 07:30 - 07:45 07:45 - 08:00 08:00 - 09:00 09:00 - }0:00 10:00 - 11:00 11:00 - 15:30 15:30 - CA NNERY LOOP UNIT 10 CA NNERY LOOP UNIT 10 Spud Date: 7/23/2005 Hours ~ ~ Gode ~ Sub ~ Phase I Event Type --/-- Ob}ective Code iSideTrac4<- - -- Descriptio~~ of Operations 2.00 FLOW_ TEST CMPFLW Continued flowing well through test separator. Separator pressure at 450 psig. FTP = 950 to 1150 psig. Gas = 0.7 to 2.8 mmcfd Water = 1000 to 2000 bwpd. FDTs now indicate fluid flow back from modules 1 and 12 and 11 frac stages. 16.50 FLOW, TEST CMPFLW Continued flow testing well Gradully increasing separator pressure to 90Q psig. Well rate increased from 2 mmcfd to 6~3 mmcfd, FTP frorl7 1150 to 1200 psig. Water from 1000 to 670 bwpd. Cumm water = 1210 bbls or +/- 52% of frac load. 24.00 FLOW_ TEST CMPFLW OH --/-- Flow tested well. Over past 24 hours well rate went from 6.45 mrpcfd to 6.87 mmcfd. Water from 960 bpd to 497 bpd. FTP from 1200 to 1260 psig. Well makikng only trace amounts of flex sand and proppant. BHP line purged several times and shousd: be giving good reading. Estimated max drawdown on Module 1 = 57.6% (using 4104 psig as SBHP anti FBHP of 1740) Cumm water recoverd = 1804 bbls or 78% of frc load of 2319 bbls. 24.00 FLOW_ TEST CMPFLW OH --/-- Flowed well through test equipment. Well making approximately 7 mmcfd, +/- 500 bwpd, with FTP = 1250 psig. Making only trace amounts of flex/proppant. Cumm water recovered = 2300 bbls or 99%frac load. 24.00 FLOW_ TEST CMPFLW OH --/-- Continued to flow test well. As of 0600 9/5/2005 FTP = 1200 psig, Gas = 6.947 mmcfd, Water = 455 bpd, BHP = 1717 psig (estimated) Cumm water recovered = 2740 bbls or 118°1° of frac load. 24.00 FLOW` TEST CMPFLW OH --/-- Flow tested well. As of 0600 hrs 9/6/2005 FTP = 1240 psig, Gas .= 7.1 mmcfd, Water = 465 bpd, estimated FBHP 1706 psig. Well making only very small trace of flex/proppant. Cumm water = 3151 bbls or 136% of 2319 bbl frac load. 24.00 FLOW_ TEST CMPFLW OH --(-- Continued flow testing well: FTP = 1150 psig Gas = 6.994 mmcfd Water = 366 bpd BHP = 1697 psig Cumm water rec = 3528 bbls 24.00 FLOW_ TEST CMPFLW OH --/-- Continued to flow test well: FTP = 1200 psig Gas = 6.86 mmcfd Water = 364 bbls BHP = 1690 psig' Cum Water Rec= 3877 bbls ?4 00 FLOW TEST CMPFLW . _ OH --/-- Continued to flow test well: 1 FTP = 1200 psig`- Gas = 6.66 mmcfd Water = 364 bpd- BHP = 1686 psig Cumm Water Rec = 4288 bbls 3.00 FLOW_ TEST CMPFLW OH --/-- Flowed well. 9.00 RURD_ OTHR CMPFLW RD Well testers. `Final report 0.25 SAFETY MTG_ PRDTST OH --/-- Sign in at office, discuss work, issue work permit 0.25 SAFETY MTG_ PRDTST Hold location safety meeting, fill out JSA. 1.00 RURD_ SLIK PRDTST RU Slickline. 1.00 TAG_ BOTM PRDTST PU 20' 1-11!16" dummy gun. Run to 8346' KB. 1.00 WAITON EQIP PRDTST Stand by for Protechnics equipment. 4.50 LOG_ CSG_ PRDTST RIH w/ corelab logging tool to 5500' KB. Log to 8300'KB making three passes at 60fpm, 90fpm, and 120fpm. RURD_ SLIK PRDTST RD slickline and spot equipment on CLU 9. • • Printed: 10/20/2005 11:28:23 AM • • Marathon Oil Company Page 1 of 2 Well Summary<Report Legal Name: CANNERY LOOP UNIT 10 Common Name: CANNERY LOOP UNIT 10 Weli Location Country: USA API #: 50133205530000 Well I D: 205-106 State/Prov: ALASKA County: Kenai Peninsula Location: 7- 5-N 11-W 1 Field Name: CANNERY LOOP UNIT Block: Slot No: Platform: License No: License Date: Licensee: Spud Date~fime:7/23/2005 - 06:00 P&A Date: Surtace /Bottom Hole Coordinates Surface Location Eottom Hole Loc ation Latitude: 60.53246 Longitude: -151.26344 Distance North/(-)South: -273.00 (ft) (ft) Distance East/(-)West: 520.00 (ft) {ft) Measured From: Section 7, T5N, R11W, S.M. Reference Elevations Permanent Datum: KELLY BUSH ING Datum Elev: 41.00 (ft) Kelly Bushing: 41.00 (ft) Water TMD: (ft) Ground Level/Mudline:20.00 (ft) Measured Depth: (ft) Casing Flange: (ft) Date Measured: TVD: (ft) Tubing Hanger: (ft) Date Measured: Plugback TM D: (ft) KB to Datum: {ft) Fill: (ft) KB to GUMudline: 21.0 (ft) / (ft) Deviated Wel l: Y ...Operator /Well Information Operator: MARATHON OIL COMPANY Region: ALASKA REGION Division: AR District: Well Type: DRY GAS Status: Geological Play: Authorized TVD: 7,976 (ft) Authorized TMD: 8,426 (ft) Event Summary Event Type ~ Objective ~ Start Date End Date Auth. Cost Last Est. ORIGINAL DRILLING Exploitation Gas 7/21/2005 8/6/2005 5,433,600 7/21/2005 ORIGINAL COMPLETION Exploitation -Gas 8/6/2005 8/11/2005 5,433,600 7/21(2005 ORIGINAL COMPLETION Exploitation -Gas 8/17/2005 9/23/2005 5,433,600 7/21/2005 Hole Section ST ~ Pilot; Size ; Top MD ~ Bottom MD ! Top TVD i Bottom TVD i Plan MD f Plan TV D I ~ Start End No. ;.Hole. (in) (ft) I ({t) I (ft) (ft) (ft) I (ft) ! .Date j Date OH N 20.000 21.0 123.0 7/21/2005 7/23/2005 OH ~ N 16.000 123.0 1,955.0 7/23/2005 7/26/20 5 0 OH ~ N ~ 12.250 1,955.0 5,460.0 7!26/2005 7/31/2005 Printed: 1072012005 1:12:41 PM L' Marathon Oil Company Well Summary Report Page 2 of 2 Legal Name: Common Name: CANNERY LOOP UNIT 10 CANNERY LOOP UNIT 10 ST Pilot Size No. Hole (in) Hole Section Top MD Bottom MD Top TVD Bottom TVD Plan MD (ft) (ft) (ft) (ft) (ft) Pfan TVD Start End (ft) Date Date OH N 8.500 5,460.0 8,450.0 7/31/2005 8/4/2005 Printed: 10/20/2005 1:12:41 PM • API: 50-133-20553-00 RT-GL: 21.00' RT-TH F: 21.70' 273' FSL, 520' FEL, Sec. 7, T5N, R11W, S.M. Tree cxn = 4-3/4" Otis ~ TOC (est.) - 500' above 9-5/8" shoe Excape Svstem Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB1: Module 1 - NA Module 2 - 8240' Module 3 - 8118' Module 4 - 7985' Module 5 - 7736' Module 6 - 7196' Module 7 - 7106' Module 8 - 7049' Module 9 - 6976' Module 10 -5897' Module 11 -5729' Module 12 -5690' CLU - 10 ~ M ~wrewTMOM Drive Pipe: 20", 133 ppf, K-55 to 133' Surface Casing: 13-3/8", 68 ppf, L-80, BTC @ 1953' Cmt w/ 606 sx. of Type 1 at 12.0 PP9• Int. Casina: 9-5/8", 40 ppf, L-80, BTC @ 5410' Cmt w/ 75 bbl of class G lead @ 12.5 ppg and 45 bbls Class G tail @ 15.8 ppg Prod. Tubing: 3-1/2", 9.3 ppf, L-80, EUE 8rd with 6.25" OD control line protectors to 8419' Cmt w/ 1324 sx of class G at 15.8 ppg - 12 Excape modules placed - Green control line fired module 1 - Yellow control line fired modules 2 thru 8 - Red contol line fired modules 9 thru 12 -Ceramic flapper valves below each module except for module 1 Module 1 - 8265 - 8275' Module 2 - 8219 - 8229' Module 3 - 8098 - 8108' Module 4 - 7965 - 7975' Module 5 - 7716 - 7726' Module6-7174-7184' Module 7 - 7083 - 7093' Module 8 - 7030 - 7040' Module 9 - 6956 - 6966' Module 10 - 5880 - 5890' ible Patch- 5712'-5738' ID=1.50" 12 - 5674 - 5684' Well Name & Number: CLU - 10 Lease: Cannery Loop Gas Field County or Parish: Kenai State/Prow. Alaska Country: USA Perforations (MD) See Above (TVD) Angle/Perfs Angle @ KOP and Depth BHP: BHT: Completion Fluid: 6% KCL Dated Completed: 8/31/2005 Prepared By: J. R. Thompson Last Revison Date: 8/26/2005 TD - 8450' PBTD - 8382' :~ ~~ ~ ~~ ~ ~ l~ ~~ ~~ ~ ~ ~ ~ ~k ~ 3 ~ 'ID' ~ ~ 9 ~` '_ ~' 1 ~ "_ ~ '~ FRANK H. MURKOWSK/ GOVE ~,~~~ ~~~~+rgg~~ ~t~~ ~t ~~ ~-7~A OIIt t~-«1 Vr~-7 ~ 333 W. 7r" AVENUE, SUITE 100 COI~TSER'QATIOI~T COMl~'IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Willard Tank Advanced Senior Drilling Engineer Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Re: Cannery Loop # 10 Marathon Oil Company - Permit No: 205-106 Surface Location: 273' FSL, 520' FEL, SEC. 7, TSN, R11W, S.M. Bottomhole Location: 80' FNL, 1255' FWL, SEC. 17, T5N, R11W, 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 from obtaining additional permits or approvals required by law from 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 oft Commission to witness any required test. Contact the Commission's petro u field inspector at (907) 659- 3607 (pager). ~"1 A N DATED this day of July, 2005 cc: Department of Fish 8s Game, Habitat Section w J o encl. Department of Environmental Conservation w/o encl. i M Marathon MARATHON Oi! Company July 8, 2005 John Norman Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application Field: Cannery Loop Well: Cannery Loop Unit - CLU 10 Dear Mr. Norman Worldwide Drilling North America P.O. Box 3128 Houston, TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 JUL ~ ~ X005 Alaska Oit & Gas C~oasg~on"~~'~~`~ pnch 9 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 exploitation 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 713-296-3273 or by a-mail at wjtank ~ marathonoil.com. Sincere) , ~ i.~'~ ~ ~~, ~ ~5S arL~ Y ~ ~„ ~, Willard J. Tank Advanced Senior Drilling Engineer Enclosures OR16!NgL 1 STATE OF ALASKA KA OIL AND GAS CONSERVATION C ~ ~JIISSION PERMIT TO DRILL / 2O AAC 95_~~5 ,~~~ 7/tt~u''~s RE~~fVE~ J U L ~ ~ 200 1a. Type of Work: Drill ~ Redrill 1b. Current Well Class: Exploratory Dev i Re-entry ~] Stratigraphic Test ~ Service ~ Development GasA~tp$8~e Zone Q 2. Operator Name: 5. Bond: Blanket ~ Single Well ~ 11. Well Name and Number: Marathon Oil Company Bond No. 5194234 CLU #10 r 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 3128, Houston, TX 77253 MD: 8,426 TVD: 7,976 Cannery Loop Unit /Beluga 4a. Location of Well (Governmental Section): 7. Property Desicnation: ~~ ~ - .. y~,,,~a/ Surface: 273' FSL, 520' FEL, Sec. 7, T5N, R11 W, S.M. / (~~ r~ ~dve ~~k~/~ ~jp,~,5/ Top of Productive Horizon: 8. Land Use F'erma: 13. Approximate Spud Date: 80' FNL, 1,255' FWL, Sec. 17, T5N, R11W, S.M. July 22, 2005 Total Depth: 9. Acres in Property: 14. Distance to Nearest 80' FNL, 1,255' FWL, Sec. 17, T5N, R11W, S.M. ~ 57.25 Property: 382 ft (ADL02397) 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x -272,452.10 y - 2,388,727.00 Zone - 4 (Height above GL): {21' AGL) 41 .feet Within Pool: 1,488 ft. to CLU #9 16. Deviated wells: Kickoff depth: 750 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.Q35) Maximum Hole Angle: 33.98 degrees Downhole: 3,733 Surface: 1,931 ~ 18. Casing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 PE 102' 0' 0' 123' 123' 16" 13318" 68 L-80 BTC 1,901' 0' 0' 1,922' - 1,850' 600 sacks ~' 12 1/4" 9 5/8" 40 L-80 BTC 5,430' 0' 0' 5,451' 5,001' 445 sacks i 8 1/2" 3 1/2" 9.3 L-80 EUE 8,405' 0' 0' 8,426' 7,976' 1,296 sacks i 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD {ft): Effect. Depth TVD {ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot .Shallow Hazard Analysis Property Plat Q Diverter Sketch Q Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirements 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 Advanced Senior Drilling Engineer Signature Phone 713-296-3273 Date July 8, 2005 Commission Use Only Permit to Drill API Nu er: Permit Approval See cover letter for other Number: ,~~ _ io f33 " 2 ~ ~,~~ 5 - Date: 7 1 ~{ ~ ~ requirements. Conditions of approval Samples r quired Yes ~ No ~ Mud log required Yes [] No dr sul ' easures Yes ~ No ~ Directional survey required Yes ~ No _ Other: ( S~ ~ ~ ~~ ° APPROVED BY 4 d '"'> ; ~ pprove ,, E COMMISSION Date: r ' Form -401 Re 'sed 06/2004 • / Submit inDuplicate i • • MARATHON MARATHON OIL COMPANY DRILLING PROGRAM Cannery Loop Unit CLU #10 Original 7/8/05 Originator: W.J. Tank :/~ ~ ;`~- Drilling Superintendent: P.K. Berga North America Drilling Manager: B.J. Rov Page 1 of 14 • • 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 BOPE Program ........................................................................................................................................................................8 Wellhead Equipment Summary ..............................................................................................................................................9 Directional Program Summary .............................................................................................................................................. ..9 Directional Surveying Summary ............................................................................................................................................ 10 Drilling Fluid Program Summary ............... ........................................................................................................................ 10 Drilling Fluid Specifications .................................................................................................................................................... 11 Solids Control Equipment ...................................................................................................................................................... 11 Cement Program Summary ................................................................................................................................................... 12 Regulatory Waivers and Special Procedures ........................................................................................................................ 12 Bit Summary .......................................................................................................................................................................... 13 Hydraulics Summary ............................................................................................................................................................. 13 Formation Integrity Test Procedure ....................................................................................................................................... 14 Page 2 of 14 • • General Well Data Well Name. CLU #10 Lease/Lkense Sorts Location 273' FSL, 520' FEL, Sec. 7, T5N, R11W, S. M. WBS Code DX.04.11032.CAP.DRL SbUPad CLU Pad 1 Field Cannery Loop Unit Spud'Dsate 7/22/05 (est.) KB F•lev. 41 Cou+ttylProvince Kenai Peninsula APl No. Ground Lsvel Elev. 21 State /Country Alaska WeN Class Development Penn. Da#tsn KB Total MD 8,426' Rig Contractor Glacier Drilling Water Depth WA Total TVD 7,976' Rig Name #1 Water Protection Depth Comments: Geologic Program Summary Fcxsr~ation MD - RKB ft TVD - RKB (ft) Por® Pressure Pore Pressur® Fluid. Sterling A-8 (Not a Prod Target) 4,562 4,126 6.73 Sandstone Gas /Water Sterling B-2 (Not a Prod Target) 4,820 4,376 6.73 Sandstone Gas /Water Sterling C-1 (Not a Prod Target) 5,436 4,986 6.73 Sandstone Gas /Water Upper Beluga (Primary Target) 5,636 5,186 4.04 Sandstone Gas Middle Beluga (Primary Target) 6,286 5,836 4.04 - 8.85 Sandstone Gas Lower Beluga (Primary Target) 7,036 6,586 4.04 - 8 5 Sandstone Gas Tyonek (Not a Prod Target) 8,251 7,801 •0 Coal, Silt, Shale Gas Comments: Surface Location Coordinates From Laasts/Block Lines 273' FSL, 520' FEL, Sec. 7, T5N, R11 W, S.M. Latitude 60° 31' 56.840" N Longitude 151 ° 15' 48.373" W UTM North (Y) 2,388,727.00' UTM"East {x) 272,452.10' 7 ~~ D' . meat fi) Dk Target MD ft TVD ft Location +NI=S +E/-W (X Toierance (tt) Upper Beluga 5,636 5,186 80' FNL, 1,255' FWL, Sec. 17, T5N, R11W, S.M. -353 1,775 Circle 250'radius TD 8,426 7,976 80' FNL, 1,255' FWL, Sec. 17, T5N, Ri1W, S.M. -353 1,775 Circle 250' radius Comments: f~ Page 3 of 14 • • Summarv of Potential Drilling Hazards hlszard Event D Lost Circulation in Low Pressure Sterling and Belu a sands 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 (BOPS 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 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 +/- 4,562 MD (4,126' TVD) to total depth of the well. These sands will run from highly depleted to slightly above normal pressure. Lost. circulation and differential sticking are potential hazards in some of the l Sterling and Beluga sands. 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. Weighting material will available on location for proper well control. Formation Evaluation Summarv Interval LWD Electric Logs Surface 0' - 1,922' MD None None None Intermediate 1,922' - 5,451' MD None None Basic with GCA, shale density, temperature in and out, sam le collection (10' sam es). Producti~ 5,451' - 8,426' MD None Reeves Glued Combo and MFr. Pu11 GR- Neutron to surtace inside casing. Basic with GCA, shale density, temperature in and out, sam le collection (10' sam es). Completion N/A GR, CCL NIA Coring Requirements: None Comments: Page 4 of 14 Drilling Program Summary CONDUCTOR: 1. Drive 20" conductor to +/-100 ft. RKB. 2. Move in and rig up rotary drilling rig. 3. Install starting head 20" SLC x 21 1/4", 2M flanged. 4. Nipple up 21 1/4", 2M diverter, 16" diverter valve, and 16" diverter line. 5. Function test diverter and diverter valve. SURFACE: 1. Drill a 16" hole to 1,922' MD (1,850' TVD) per the directional plan. 2. RIH with 133/8" 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 133/8" casing. Sting out, shear out drill pipe wiper plug, and circulate drill pipe clean. TOOH with inner string. 3. Cut off 133/8" casing. ND diverter. 4. Install 133/8" slip lock connection X 13 518" 5M flanged multibowl wellhead. 5. NU 135/8" 5M BOP'S. Test BOP'S and choke manifold to 250/2,500 psi. 6. Set wear bushing. 7. Test surface casing to 2,500 psi. INTERMEDIATE: 1. Drill out float equipment and make 20' of new hole. CBU. 2. Test shoe to leak off. Estimated EMW is i 4.7 ppg. 3. Drill 12 1/4" directional hole to 5,451' MD (5,001' TVD) as per directional program, short tripping as necessary (1,000' or 24 hours, but can be extended depending on hole conditions). 4. At TD circulate hole clean. Make wiper trip: TOOH. ` 5. Change out variable pipe rams with 95/8" casing rams. Run test plug and test casing rams to 2,500 psi. 6. Run and cement 95/8" casing. Land hanger in multibowl wellhead. 7. Back out landing joint. Change out 95/8" casing rams with variable pipe rams. Run test plug and test rams to 250/2,500 psi. 8. Set wear bushing. Test casing to 2,500 psi. PRODUCTION: 1. Drill float equipment and 20' of new formation w/ 8 1/2" bit. CBU. 2. Test shoe to leak off. Estimated EMW 13.0 ppg. 3. Drill a 8 1/2" hole to 8,426' MD (7,976' TVD) per the directional program, short tripping as necessary (1,000' or 24 hours, but can be extended depending on hole conditions). 4. At TD circulate hole clean. Make wiper trip. TOOH. 5. RU logging company. Run open hole logs as per plan. RD logging company. 6. TIH w/ 8 1/2" bit to TD for wiper trip. TOOH to 9 5/8" shoe and circulate until log evaluation is complete for picking EXCAPE modules. After picks are made, trip to TD and circulate clean. TOOH and laydown BHA and drill pipe. Pull wear bushing. 7. RU and run 3 1/2" EXCAPE casing string. RU logging company to correlate EXCAPE modules to open hole logs. RD logging ~ company. 8. Cement 3 1/2" casing while reciprocating. Bump plug with 500 psi over displacement pressure. WOC. 9. PU 3 1/2" casing. PU BOP stack. Run control and electric lines out•tubing head outlet. Set slips. Cut 3 1/2" casing. 10. LD BOP. Set 3 1/2" packoff. NU 135/8" 5M X 3 1/8" 5M tubing head adapter and 3 1/8" 5M tree. Test tree to 5,000 psi. 11. Rig down and move out drilling rig. 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 14 Casino Program • MD ft connection APf caging Size (in) T Bottom West fbs/ft) Grade T pe O. D. in) Makeup Torque ft-tbs Hale Size (in) ~ ~ . ~ ~ ,,,, 133/8 Surface 1,922 68 L-80 BTC 14.375 fJ/A' 16 5,020 2,260 1,545 95/8 Surface 5,451 40 L-80 BTC 10.625 WA' 12 1/4 5,750 3,090 979 31/2 Surface 8,426 9.3 L-80 Srd 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 Sa#ety F Casing Size (in) 1Nt (} Carade ~ Setting Depth (Np) Mud Wt When Set t-b/9~) Fraa. Grad (~ ) Farm Press (!b/ ) Maxirr-um Surface Pressure fig) m ,~¢ 1- 133/8 68 L-80 1,850 9.0 14.7 8.5 651 3.15 1.97 4.17 95/8 40 L-80 5,001 9.5 13.0 6.7 1,931 1.60 .11 2.64 31/2 9.3 L-80 7,976 10.0 15.0 9.0 1,931 1.14 3 1.60 Comments: Maximum Anticipated Surface Pressure Casing Size Setting Depth ND MAWP * MASP "* Mud/Gas 133/8 1,850 3,447 651 30/70 95/8 5,001 3,895 1,931 / 30/70 31/2 7,976 6,905 1,931 30/70 * MAWP =Maximum allowable working pressure ** MASP =Maximum anticipated surface pressure Comments: MASP / MAWP CALCULATIONS: Surface casing: 13 318" f 1,922' MD. 1,850' TVD) MASPt,~ _ ((Fracture gradient at shoe + S.F.) x .052 x TVDsr,oe) -Hydrostatic pressure of gas column at the shoe. MASPi,~ _ (14.7 ppg + 0.5 ppg) x .052 x 1,850' - (.1 psi/ft x 1,850') MASPtrac = 1,462 psi - 185 psi MASP~~ = 1,277 psi. Page 6 of 14 ~ • MASP~, = BHP„ nae,d -Hydrostatic pressure of mud portion -Hydrostatic pressure of gas portion MASP~ _ (6.7 ppg x .052 x 5,001') - (0.3 x 9.5 ppg x .052 x 5,001') - (0.7 x 0.1 psUft x 5,001') MASP~ = 1,742 psi - 741 psi - 350 psi MASP~ = 651 psi MASP = MASP~ = 651 psi MAWP = (0.7 x Casing Burst) - (Mu t. -Backup Fluid Wt.) x .052 x TVD MAW P = (0.7 x 5,020) - (9.0 - 8 x 52 x 1,850' MAWP = 3,514 psi - 67 psi = ,44y(si Intermediate casina: 9 5/8" (5,4;;51' ~MD, 5.001' TVD) MASP,~ _ ((Fracture gradient at shoe + S.F.) x .052 x TVDsr,~) -Hydrostatic pressure of gas column at the shoe. MASP,~ _ (13.0 ppg + 0.5 ppg) x .052 x 5,001' - (.1 psUft x 5,001') MASPt,~ = 3,511 psi - 500 psi MASP,~ = 3,011 psi. MASP~ = B ove„ rw~a w -Hydrostatic pressure of mud portion -Hydrostatic pressure of gas portion MASP,,i,p = .O~ppg x .052 x 7,976') - (0.3 x 10.0 ppg x .052 x 7,976') - (0.7 x 0.1 psUft x 7,976') MASP~ _ 33 psi -1,244 psi - 558 psi MASPw,p = 1,931 psi l MASP = MASP,,i,p = 1,931 psi MAWP = (0.7 x Casing Burst) - (Mud Wt. -Backup Fluid Wt.) x .052 x TVD MAW P = (0.7 x 5,750) - (9.5 - 9.0) x .052 x 5,001' MAW P = 4,025 psi -130 psi = 3,895 psi Production casina: 3 1/2" (8.426' MD. 7,976' TVD) MASPr~ _ ((Fracture gradient at shoe + S.F.) x .052 x TVDsr,~) -Hydrostatic pressure of gas column at the shoe. MASP,~ _ (15.0 ppg + 0.5 ppg) x .052 x 7,976' - (.1 psi/ft x 7,976') MASPf~ = 6,429 psi - 798 psi MASP,~ = 5,631 psi. MASP~ = P ~,~ -Hydrostatic pressure of mud portion -Hydrostatic pressure of gas portion MASP~, = 9. ppg x .052 x 7,976') - (0.3 x 10.0 ppg x .052 x 7,976') - (0.7 x 0.1 psUft x 7,976') MASP~ _ 33 psi -1,244 psi - 558 psi MASP~ = 1,931 psi ~ MASP = MASP~ = 1,931 psi MAWP = (0.7 x Casing Burst) - (Mud Wt. -Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 10,160) - (10.0 - 9.5) x .052 x 7,976' MAWP = 7,112 psi - 207 psi = 6,905 psi Page 7 of 14 • ROPE Program • Casing Tes# Test Coq Test Fluid Pr~stire Size MAWP (vtASP Press Density BOPS l.owJl-ligat ! (~) (p~) fpsi? ~) Iq{ Size & (~) (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram Surface 133/8 3,447 651 2,500 9.0 (1) 13 5/8" 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) 13-5/8" 5M pipe ram Intermediate 95/8 3,895 1,931 2,500 9.5 (1) 13 5/8" 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) 13-5/8" 5M pipe ram Production 3 1/2 6,905 1,931 2,500 10.0 (1) 13 5/8" 5M blind ram 250/2,500 (1) 13-5/8" 5M drilling spool with 3-1/8" 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 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" 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 avacuum-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. Page 8 of 14 Wellhead Equipment Summary . Casing ~~ TYpe Casing Head 13-518" 3M X 13-3/8" Slip Loc W/ 2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL1, 13 5/8" x 95/8" Fluted PR1 Mandrel Tubing Head 13-5/8" 3M Studded Bottom X 13-5/8" 5M Flg Top, W/ 2, 2-1/16" 5M Studded Outlets, 135/8" x 3 1/2" Manual U,AA,PSLI,PR1 Sli Adapter Flange 13-5i8" 5M X 3-1/8" 5M W/Seal Pocket and 3" H BPV 'T'hreads Comments: Control lines and electric cable for the EXCAPE system will be routed through the tubing head side outlet. Directional Program Summary Build- Turn Sec.. No. Dagcxl MD {ft) TVD (ft) Rate (°/100') Rate (°/100') Dogleg (°/1~') lra;lutaiiort f~9) Azunuth (deft) +t~U-S (ft) +F.! W (ft, VS (tt) 1 Tie On 0 0 0 0 0 0 101.25 0 0 0 2 KOP 750.00 750.00 0 0 0 0 101.25 0 0 0 3 Build up Section 3.00 0 3.00 101.25 4 End of Build 1,882.52 1,817.33 3.00 0 3.00 33.98 101.25 -63.60 319.81 326.08 5 Hold Section 0 0 0 33.98 101.25 6 End of Hold 3,370.63 3,051.34 0 0 0 33.98 101.25 -225.80 1,135.46 1,157.69 7 Drop Section -1.50 0 1.50 101.25 $ End of Drop to tha Target 5,635.72 5,186.00 -1.50 0 1.50 0.00 101.25 -353.00 1,775.08 1,809.84 9 TD 8,425.72 7,976.00 0 0 0 0.00 101.25 -353.00 1,775.08 1,809.84 Comments: Vertical section calculated from a reference azimuth of 101.25° taken from surface location to bottom hole location. Potential Well Interference: Well Distance (ft1 Death (MD) CLU #9 67.66 716 CLU #8 73.71 Surface CLU #1 & 1 RD 99.84 1,414 CLU #6 148.81 1,147 CLU #5 280.97 Surface CLU #7 337.39 317 No serious interference exists. See attached directional plan and anticollision analysis for more details. Page 9 of 14 • N t a `~ r a~ 2 O O O r r 0 r 5 0 • Directional Surveying Summary Interval MWD Survey Magnetic Multishot Gyro Multishot Comments 0 - 1,922' X 1,922' - 5,451' X 5,451' - 8,426' X Comments: Drilling Fluid Program Summary Interva l - ND Minimum Inventory From To Density Gel (ft) (ft) (Ib/gal) Fluid Description Additives Viscosifier Barite Gel, Gelex, Soda Ash, Caustic, Barite, 0 1,850 8.6 - 9.4 Gel / Gelex Spud Mud Polypac Supreme UL, Sodium Meta Bisulfate Flo-Vis, Polypac Supreme UL, KCI, 1,850 5,001 9.0 - 9.5 6% Flo-Pro w/ Safecarb SafeCarb F&M, Barite, Caustic, Conqor 404, Sodium Meta Bisulfate, Lubetex Flo-Vis, Polypac Supreme UL, KCI, 5,001 7,976 9.0 l~t~ 6% Flo-Pro w/ Safecarb SafeCarb F&M, Barite, Caustic, Conqor 404, <-/ Sodium Meta Bisulfate Comments: See mud prognosis for details. The mud system from the intermediate section will be utilized in the production hole section instead of building a new mud for that section. Sized CaCO3 (SafeCarb) will be used to control leakoff. Page 10 of 14 Vertical Section at 101.25° [2500ft/in] West(-)/East(+) [1000fUin] • • Drilling Fluid Saecifications Interval - TVD LSRV From ft To ( Density (~~) Vis (riedgt} 1 min (IbJ100ft2) PV (cP) YP (lb/100 ft~) Flukt t~s (ix) plat DriU Solids (9a) 0 1,850 8.6 - 9.4 60 - 100 N!A 25 - 35 NC - 12 +/- 9.5 < 7 1,850 5,001 9.0 - 9. 30,000 + 8 - 12 7 - 9 +/- 9.5 +/- 5 5,001 7,976 9.0 0.0 30,000 + 10 - 14 6 - 8 +/- 9.5 +/- 5 Comments: J As a standard practice for long string completions, the drilling mud that will remain above the top of cement on the 3 3~" production casing will be treated with corrosion inhibitor (Congor 303A) at a concentration of 1 drum per 100 barrels of drilling fluid. See mud prognosis for details. Solids Control Eauipment i ~ (r~ m ~ U ~ G ~ O NC IntBrYal U U 0 - 8,426' MD X X X X Closed Loop System, Full Containment - -- _ _ , Equipm Speci~Catlaris lt~- (rn~tantity_ ri~im tvrua_ tuancl. mtx~i_ flow caaeelly_ etel Shaker 2 -Derrick Model 2E48-90F-3TA N/A Des~ter 1 -Derrick Model 0522 Mud. Ctearser N/A Centrifuge 2 - MI/Swaco units CuFtk~ps Dryer'. N/A C It~ectiort Marathon G&I Facility zero q wA Comments: The solids control equipment will consist of two flowline cleaners, a desilter, and the Ntl 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. Page 11 of 14 • ~ Cement Program Summary De pth Gauge Top ~ Cement Gash Size. {h) MD TYD ft Hole Sire ~ lMD fU TVD ft Ann Vd To TOC (ftg) Slurry Wd fft') WQG Tirr~ ties} How Suess %) 133/8 1,922 1,850 16 0 0 872 1,507 8 75 95/8 5,451 5,001 12 1/4 4,000 3,600 454 716 8 50 31/2 8,426 7,976 81/2 4,900 4,454 1,171 .1,516 WA 35 iWx vYat~ ~ Caa~ng 3be Density ~ OtY ~ Yield Slurry Vol TOC AAD Qty Wt. FW ~~~ (~) Cement t~s~) t:~ (fr'/sx) (~ (ft) tgaltsx) Type tom} tx} 13 hr 24 hr 133/8 TaA Type 1 Cement 12.0 600 2.51 1,507 0 11.28 Fresh 8i2 0 196 818 lard Class"G" 12.5 213 2.10 447 4,000 11.92 Fresh 273 769 9 5/8 Tall Class "G" 15.8 232 1.16 269 4,951 9.31 Fresh 0 0 208 981 3 1/2 Tall Class "G" 15.8 1,296 1.17 1,516 4,900 4.97 Fresh 24 0 226 2,632 Comments: See cement prognosis for details and spacer specifications. Reaulatorv 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 CLU #10. We are requesting that the BOP stack be configured with one pipe ram instead of two, due to rig height restrictions in the running of the 3 1/2" production casing. The height restriction involves having rig crew members routing control line and electrical line through one of the tubing head outlets after the 3 1I2" 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 the Kenai Gas Field and the Cannery Loop Unit itself and were granted. No problems were encountered while doing this operation on any of the wells. Also due to MASP below 2,000 psi, only a 3,000 psi BOP stack would be required for this work if it was economic to change out BOP stacks 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 encountered. r 1^-~-'``~ ~'c, r~ "~' ~ ~ ~~.~,~ ~ c~ ~" Page 12 of 14 • ~ Bit Summarv Interva l - MD Type QrxJ!ad Estim~ed Fran To ( Size h urer Model Plo. tADC wOl3 RA1A Fiqurs FiOP' 0 1,922 16 Christensen MX-DS1 DX i 15 1 - 4 80 -350 1.,922 5,451 12 1/4 Christensen HCM506Z M323 Up to 52 Motor 5,451 8,426 8 1/2 Christensen HCM605 M323 Up to 25 Motor Comments: Ifi a second bit is necessary for the 12 ~/a" hole a MX-C3 (IADC 137) should be used to finish this section. Back up bits for the 8 ~h" hole section will consist of mill tooth and TCI tricone bits. See bit prognosis for additional information. Hydraulics Summarv Rig mud pumps available are shown below. Max Press ® Dia Liner ID Stroke 90% WP 9596 eff Max Rate ay Make Model (n) (in) (psi) (gaUstroks} (~x~ntgpm} (1n 5 8 2,597 2.04 125 / 255 Surface 3 NatiW~' Oil A600PT 5 8 2,597 2.04 1251255 Intermediate 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. Standpipe Min Nozale Qagth-MD Size Putttp t3ate Pressure AV EGD Size h f ) Ital 32's E3ernatks 3 -18's 0 -1,922 16 650+ 1,850 69 1-15 1,922 - 5,451 12 1/4 662 2,000 130 6 - 13's Actual Data from CLU 8 (~ 6,722' MD) 5,451 - 8,426 8 1/2 465 1,800 241 5 - 15's Actual Data from CLU 9 (~ 9,100' MD) Comments: See separate hydraulics calculations. Annular velocities in the 16", 12 ~/o", and 8'/2" holes were calculated using 5" drillpipe. 5"drillpipe should be used to drill all hole sections to maximize hole cleaning, while minimizing stand pipe pressure. Page 13 of 14 • • Formation Integrity 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 14 of 14 • Marathon Oil Well CLU #10 Diverter Flow line 21 114" 2M Diverter -~ 16" Automatic Knife Valve ~~ Diverter Spool .~ uu tJ u 16" Diverter Line ~ • Marathon Oil Well CLU #10 BOP Stack 13 5!8" 5M Cross Marathon Oil Well CLU #10 Choke Manifold ~ To Gas Buster To Blooey Line Bleed off Line to Shakers • • Surface Use Plan for Cannery Loop Unit, well CLU #10 Surface location: 273' FSL, 520' FEL, Sec. 7, TSN, R11 W, S.M. 1) Existing Roads Existing roads which will be used for access to CLU #10 are shown on the attached map. Kenai, Afaska 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 CLU #10. 3) Location of existing wells Well CLU #10 will be drilled on Cannery Loop Unit pad 1. A pad drawing is enclosed that shows existing wells. 4) Location of existing and/or proposed facilities The locations of existing production facilities in the CLU pad 1 are shown on the enclosed pad drawing. These facilities will be upgraded to handle the additional gas production. 5) Location of Water Supply A water supply well exists on the pad that CLU #10 will be drilled from. This is shown on the pad drawing. ti) Construction Materials No construction is planned on the pad. 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 f 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 Welf 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 The existing sewer system on the pad will be utilized. / 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. The camp will utilize the existing sewer system. 9) Plans for reclamation of the surface CLU #10 will be drilled on an existing pad. Reclamation of the pad will occur after the abandonment of CLU #10 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from the U.S. Fish and Wildlife Service prior to any reclamation work beginning. 10) Surface ownership The surface owner of the land in the Cannery Loop Unit is Marathon Oil Company. 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. Date: ~ ~/ ~~ Name and Title: ~~.vvv~~ Willard J. Tank, Advanced Senior Drilling Engineer Marathon Oil Company P. O. Box 3128 Houston, TX 77253 (713) 296-3277 NONITOR WELL _„~~ ~1V nEASEME x X PROPERTY LII~ I ~ CLU NO. 10 ~% 20" CONDUCTOR I II 13 4~ CLU NO.'10 ~ASBUILT LOCATION = OAS WELL ASP ZONE 4 NAD27 TRAGTA I LL ~GONDUCTaa %~ N: 2388727 00 KENAI SPIT SUBgVLSION N0.2 . E: 272152.10 SECTWN7770/R7IW SM AK I I~ LAT: 80'3158.840' 520' FEL I LONG: -161.1548.373• I FEL = 520' \\ I I FSL = 273' I ELEV = 19.T (MSL) x 87 TOSN R11 W SM AK I ~ I I ® CLU N0.8 •DANOER• I GAS WELL BURIED fIOW L81E3 c' W I x C xN WELL 110U8E W GASWELL . a' B' DU WELL WATER WELL Q BURnWO CL~ N~., o I 4 OAS WELL I } I 1°~L NoUSE CLU N0.5 ~ 273' FSL ~ W a ~ wl v iELL i sE CLU NO. B EkI9TNG GRAVEL PAD I ~y~/ELL ELEVATON•21'2 ~ ~ W WELL NWSE I ~ # WASTE WA B WATER LINE BURIED S i ~ PROPERTYYLN/E _ ~~ ~ _ -- _ - w~ _ ~~~~-_ I ~~~ x e7i~--- 3' A10NUMENT - N: 2388/70.38 E: 271528.88 EIEV..22.4T ``~~\\\\11' ~~,~~ OF A(qs ~~ ., y: '~ ;:.... 49 .....................:: .........................:....... ~ o ~, M. SCOTT McLANE _~ ~~~ ~ 4928-S ~" ~ A CIWNLINK FENCE CONTiOL POINT%773 N: 430878850 31N6 COR E: 47402452 ELEV.•20.14' 7 8 ~ X~ I 50' • REBOILER 8 NEATER CLU .7 GAS wEu w wEU NousE NK)NITOR coNTRa Bl%LDING OVERHEAD SBPULgNG PIPE SYBTEM CANNERY ROAD ^~^_~~ ~~^~ A _ KENa pn LBrtrs _ ~ ~_ ~ SECTION LINE ~ ~ ~ ~' ~~_ ~ I ~ ~ ~ z ~~ II I w ~ ~ Y U I a / D) /} I - 7 B 10 17 BECTON CORNER 3• MONUMENT N: 4388M4.45 E: 272087.50 ELEY. • 24.55' ~ GENERAL NOTES ~ 1) BASIS OF COORDINATES IS U.S.C. & G.S. TRI STATION AUDRY IN ALASKA STATE PLANE NAD 27 ZONE 4. 2) BASIS OF ELEVATION IS MEAN SEA LEVEL = 0.00' FOR ELEVATIONS SHOWN. 3) BEARINGS SHOWN HEREON ARE GRlD UNLESS OTHERWISE NOTED. 4) AUDRY LOCATION: N: 2382045.42 E: 269866.75 5) 3" SECTION CORNER MONUMENT IN MON BOX SERVES AS A TBM WITH AN ELEVATION = 24.66'. PROJECT REVIS~N: MARATHON M CANNERY LOOP UNIT NO 1 ATE, 5/96 DII ~~~Y . BUILT LOCATION NO 10 WELL AS C L U DRAWN BY: CRM . ~~~ ~~A ~ - . . . . SCALE: P =100' • SURFACE LOCATION DIAGRAM PROJECT NO. 0530 BOOK NO. 04-15 CIX15UI GC ENGWEERING/MAPPING/SURVEYING (TESTING P.O. BOX 468 SOl.DOTNA, AK.99B~ cLane esting Y°E;~ TSgMC~lAN1E~ LANEC .C01A LOCATION S7 T5N R11W KENAI PENINSULA, ALASKA SHEET '~ of • • a ,% ' `til 4 •• - .O. w- }~;- • y _ ~' ..} { •_ ~ - ., - - t n y~ 4- 'y. I`~ ~- • ~x + ' ~ ~ -~ r ~ ` Q- I • e ~ ~ ~ q l~.o ~~ ~~ORPO$ATE ,~ ~ - BOU{?DA~T __T . __~ ~ ~ } .,I.-_ " ~ },~. ~ a t_ t ..t._ I 1 24 ~_ ~+A~-i '.- ~ X20 ..~.+ 22 '1 4 _ ~ 4 ,. +*{ _ _ _, i 1 24 -~ 0, ' a ~~ s ~- ~ ~ n.)_. ~ p. ,.. +1' 41 w.? a .y'4 ~ ~ ~ 1. ^Ipp . y ~. -, , t .~_ '^-- a ~+} ,. ' ,~. _~ ^_ 1. 'L~-,~ ~' - _ 1• •!~ ~f • ' •, .. t ~ - - ~c_.+i S a I e - ~- •1.. ~ i y. ~ ~- -" ~ m I ssY 36 ¢~ 31 '''~ 32 i ~ ~~ 33 ,. • apt i~ ~ 35 36 - T s N • .i cry `0p - _ : !' ~. Kenai ~~ /. s r• I,~ ~ •' ~ _ :: ~, `•~ 0 6i ~ ~ ~ ~ , ~ ~ _ _ 1 • ~ • • ~ \~ ~ - I ~ ~ ~w^- ~ Fem. ~ H~ ~ _ ~~ -.--~_ ~.~. ~ M I .• , .. • ..^~i _ - ~~-. ~ I ~ .~_._ 2 y ~67at ~ ± ,~ I rr ~ tom, ~ ! ~ E .. _ , C8OrieTy Loop 1~1J• 1 `- ~ ii` ~..• r ~^~l i •o ~ ' ,~ + ,~ ,~ / _ F . • a Pad : ~ -~ ,. -- -~ ~ ~ ~ s ~~- ~~° <. i ti„ ~, 8 I I~7'-1 t:~ 15 ~aF-c -tom' ~~' -1A~ i~~ 13 ~ ~ ~ 1 I I f -~~ ~ 1 K~S/LOFI _ ~ ~ .R~~ ~ r Xa0 ~~" ~ ~ ~ 19 i - ~ ~O .. t '21 ~ j ~_, ?,2 ~\ 23. - ~ 24 ~ °i ` L 30 i 29 ~ i_ 28 ` I 27 •. ~~ 2E2 -° 25 ENAI 641 ~_ ~~~s,~or .. ..~ •15 • ~ -ua.oo~cw~•uwvn. ww•,...o+ .ac"`w,~l .• t ~Z~.f.' 151'0 ~~ SCALE 1:63,360 KENAI (C-4), ALASKA (1951) Marathon Oil Company Project: Cannery Loop Unit No. 10 • • Canner Loo a ~~ 0 _ ---- . • ~ ~ ~ . . = ~ . ~ a 859 ., ,~ . ~~ • ,+twa ,'- a. ' ~ ., ,'~ _ ~ ~ ~ ~~ ~ r r• ,~' ~~ ~ r, ~ + r l ~~ - l CL-1 755 -58 1 ,. ~~~ i n ~_ a Cannery Loop ~°~° "'~'~~'°" a' °onipary ~ ~ °°"'~' ~"'°" Middle Beluga Depth Structure Map ~, ~, , C.I. = 50 feat June, 2005 GLACIER DRILLING RIG #1 ~ MUD PITS AND PUMP ROOM LAYOUT ~~ ~~~ Banc INTEQ t°n -500 (V E U ~ r N U ~ 500 1000 1500 2000 2500 ~+ 3000 t Q 3500 ~ 4000 4500 7 ~- 5000 1 V 5500 6000 6500 7000 7500 8000 8500 ARATHON Oil Com ny Location: Cook Inlet, Alaska Slot: CLU-10 Field: Cannery Loop Unit Well: CLU-10 Installation: Pad #1 Wellbore: CLU-10 Ver 1 MARAT HQN Scale 1 cm = 100 ft East (feet) -> -200 -0 200 400 600 800 1000 1200 1400 1600 1800 2000 ~ 13 3/bin Casing 0.00 KOP 6.00 12.00 DLS: 3.00 deg/100ft 24.00 ~~ 30.00 13 3/8in Casing 33.98 End of Build 33.98 End of Hold 29.48 26.48 DLS: 1.50 deg/100ft 20.48 17.48 14.48 11.48 8.48 9 5/bin Casing 5.48 Y,48 CLU10 - T/Upper Beluga - 6/13/05 0.00 CLU10 - TD - 6/13/05 3 1/tin Liner -500 -0 500 1000 1500 2000 2500 some, l:~(e~i~al Section (feet) -> Azimuth 101.25 with reference 0.00 N, 0.00 E from CLU-10 ~' .Q CLU10 - T/Upper Beluga - 6!13/05 '~ CLU10 - TD - 6/13/05 9 5/bin Casing 3 1/2in Liner, 200 -200 ^ Z -400 ~ 3 -600 ~ rt v -600 ~ in -looo ~ t °o -1200 ~ WELL PROFILE DATA PoMt MD Inc Axl TVD North East deg1100ft V. Sect Tie on 0.00 0.00 101.25 0.00 0.00 0.00 OAO 0.00 KOP 750.00 0.00 10125 750.00 0.00 0.00 0.00 0.00 End of Butld 1882.55 33.98 101.25 1817.33 X3.60 319.81 3.00 326.08 End of Hold 3370.63 33.98 101.25 3051.34 -225.80 1135.48 0.00 1157.89 Target CLU10 - T/Upper 5635.72 0.00 101.25 5188.00 353.1%1 1775.08 1.50 1809.84 T.D. $ Target CLU10 - T 8425.72 0.00 0.00 7876.00 353.00 1775.08 0.00 1809.84 c;reateo oy : rlarmer Date potted : 1-JW-2005 Plot reference is CLU•10 Ver 1. Ref we0path is CLU-10 Ver 1. Coordinates ere M feet reference CLU-10. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rlg Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 41.00 ft. Plot North is aligned to TRUE North. • MARATHON Oil Company,CLU-10 J~~ Pad #1, MARATHON Cannery Loop Unit,Cook Inlet, Alaska • PROPOSAL LISTING Page 1 Wellbore: CLU-10 Ver 1 Wellpath: CLU-10 Ver 1 Date Printed: 1-Ju1-2005 ~_ . iNTEQ Wellbore _. - Name Created ___ L s~ t Rev~~ --- --- CL -10 Ver 1 _ __ 13-Jun-2005 ____ ______ 1-Jul-2 Well -- ~ _ ~ tl St ~; LU-10 1 Jun-2 5 Slot _ e n itu LU-1 2 727.00 72452.1000 N6 1 56.8398 W151 15 48.3734 80. 6N 532. W Installation N Nit Att9+~n~1_: Pad #1 272978.9033 2388436.2080 AK-4 on NORTH AMERI AN DATUM 1927 datum True Field ame nne Loo nit 272978.9033 2388436.2 80 AK-4 on N RTH AM RICAN DAT M 1 7 t m Tr e Comment All data is in Feet unless otherwise stated Coordinates are from Sbt MD's are from Rig and ND's are from Rig (Datum #1 41.Ott above mean sea level ) VerBcal Section is from O.OON 0.00E on azimuth 101.25 degrees Bottom hole distance is 1809.84 Feet on azimuth 101.25 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated • MARATHQN MARATHON Oil Company,CLU-10 Pad #1, Cannery Loop Unit,Cook Inlet, Alaska • PROPOSAL LISTING Page 2 Wellbore: CLU-10 Ver 1 Wellpath: CLU-10 Ver 1 Date Printed: 1-Ju1-2005 iii ~~ INTEQ we ll atn c rla tte ort ~ MD[ftJ Inc[de9J ~degl TVt~#J Ittl East{ftJ pogleg Vectkal Easlirrg Northing 0.00 0.00 101.25 0.00 O.OON 0.00E 0.00 0.00 272452.10 2388727.00 100.00 .0 101.25 100.0 .0 N 0.00E 0.00 0. 272452.1.0 23 727. 0 200.00 0.00 101.25 2 0.00 O.OON 0.00E 0.0 0.00 272452.10 23 727. 0 300.00 0.00 101.25 300.00 O.OON 0.00E 0. 0 0.0 272452.10 23 727.00 400.0 0.00 101.25 400.00 O.OON 0.00E 0.00 0. 0 272452.1 23 8727.0 500.00 0.00 101.25 5 0.00 O.OON 0.00E 0.00 0.00 272452.10 2388727. 0 0.00 1 1.25 6 0.00 0. ON 0.00E 0.00 0.0 272452.1 23 8727. 7 .00 0. 0 101.25 7 . 0 .OON 0.00E 0.00 0.00 2724 2.1 38 7 7. 750.00 .00 1 1.25 750.00 0.0 N 0. E 0. 0.00 27 452.1 388727. 8 .00 .0 101.5 84 0. 1 2.57E 3. 2. 272454.6 87 950.00 6.00 101.25 949.63 2.04S 10.26E 3.00 10.46 272462.32 2388724.76 1 5 .00 9.00 101.2 1048.77 4. 9 23. 6E 3. 23.51 2724 5.07 2 721.97 1150.00 12.00 101.25 1147.08 8.14S 40.93E 3.00 41.74 272492.87 2388718.08 1250.00 15.00 101.25 1244.31 12.69S 63.83E 3.00 65.08 272515.67 2388713.08 1 50.00 18.00 101.25 1340.18 18.23S 91.68E 3.00 93.48 272543.41 2 8 7 7.01 1450.00 21.00 101.25 1434.43 24.74S 124.42E 3.00 126.85 272576.01 2388699.88 1550.00 24.00 101.25 1526.81 32.20S 161.94E 3.00 165.12 272613.9 2388691.69 1650.00 27.00 101.25 1617.06 40.60S 204.16E 3.00 208.16 272655.44 2388682.49 1750.0 3 .00 101.2 17 .93 49.91S 250.96E 3.00 255.87 2727 2.04 2 88672.29 18 .00 3 .00 101.25 17 0.18 60.10S 302.20E 3.00 0 .12 727 3.0 2 1.12 1882.5 33.98 101.25 1817.33 63.6 S 319.81E 3.00 326.0 272770.62 2 8657. 8 19 0. 33.8 1 1.2 1831. 65. OS 329.3E 0.00 .8 2727 0.1 2 88 5.19 2000.00 33.98 101.25 1914.7 7 .4 S 384.19E 0.0 391.71 2728 .74 3 864. 4 2100.00 33.9 101.2 19 7.65 87.30S 4 .00E 447. 2728 9. 3 23 86 1. 9 22 3 . 1 1. 20 .58 8.20S 4 .81E .4 272943.2 2 1 . 2300.00 33.98 101.25 2163.51 109.10S 548.63E 0.00 559.37 272998.51 2388607.39 400.00 3.98 101.25 2246.4 120.OOS 03.44E 0.0 615.25 27 3.1 38 .44 2500.00 33.98 101.25 2329.36 130.90S 658.25E 0.00 671.14 273107.69 2388583.49 2600.00 33.98 101.25 2412.29 141.80S 713.06E 0.00 727.02 273162.28 2388571.54 27 0.00 3 .98 101.25 24 5.22 152.70S 767.87E 0.00 782.1 27 216.87 2 5 9. 9 2800.00 33.98 101.25 2578.14 163.60S 822.68E 0.00 838.79 273279.46 2388547.64 2900.00 33.98 101.25 2661.7 174. 1S 877.50E 0.0 894.6 273326.05 2388535.69 3000.00 33.98 101.25 2743.99 18 .41 S 932.31E 0. 9 .57 273380.64 23 52 .74 100.00 33.98 101.25 2826.92 196.31S 987.12E 0.0 1006.45 273435.23 2388 11.79 2 0. 0 33.98 101.25 2 09.85 2 7. iS 1041.93E 0.0 1 2. 27 489. 23 9 . 3300.00 33.98 101.25 29 2.78 218.10S 1096.74E 0.00 1118.22 273544.41 238 87. 3370. 33.98 101.2 3051.34 22 .80S 1135.46E 0.00 1157.9 273582.96 2 7 .4 3470. 32.4 101.25 31 4.99 236.49S 1189.20E 1.50 1212.48 273636.49 2 67.7 357 .63 30.9 101.2 3220.0 246.75 1240.77E 1.5 1265.07 273687.85 2 5 .4 3670.63 29.48 101.2 33 6.45 256.57 129 .15E 1.5 1315.41 273737.03 2 844 .72 3770.63 27.98 101.25 3394.14 265.94S 1337.28E 1.50 1363.47 273783.97 2388435.45 3870.6 26.48 101.25 3463.06 274.8 S 1382.15E 1.5 1409.22 2738 8.6 2388425. 7 3970.63 24.98 101.25 3573.14 283.33S 1424.73E 1.50 1452.63 273871.06 2388416.38 4070.63 23.48 101.25 36 .33 291.33S 1464.97E 1.50 1493.66 273911.15 2388407.61 4170.3 21.98 101.25 3756.57 298.87S 1502.86E 1.50 1532.29 273948.88 2388399.35 4270.63 20.48 101.25 3849.78 305.93S 1538.37E 1.50 1568.50 273984.25 2388391.61 4370.63 18.98 101.25 3943.91 312.51S 1571.47E 1.50 1602.25 274017.22 238 384.3 4470.6 17.48 101.25 40 8.89 318.61 S 1602.15E 1.50 1633.52 274047.77 2 8 377.70 4570.6 15.98 101.25 41 4.65 324.23S 1630.38E 1.50 1662.30 274 75.88 2 8 71.55 4670. 14.48 1 1.25 42 1.14 329.35S 1656.14E 1. 0 16 8. 7 274101.54 238 65.9 4770.6 12.98 101.25 4328.28 333.98S 1679.41E 1.50 1712.29 274124.71 2 88360.86 All data is in Feet unless otherwise stated Coordinates are from Sbt MD's are from Rig and TVD's are from Rig (Datum #1 41.Oft above mean sea level ) Vertical Section is from O.OON 0.00E on azimuth 101.25 degrees Bottom hole distance is 1809.84 Feet on azimuth 101.25 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated MARATHON Oil Company,CLU-10 '~~ Pad #1, MARATHON Cannery Loop Unit,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Wellbore: CLU-10 Ver 1 Wellpath: CLU-10 Ver 1 Date Printed: 1 ~lu1-2005 ~i~ INTEQ Well.... ath Grid R® ort -+~(ft1 tnc{degl ND[tt] t'~I~I East~ftJ Dogleg Vet#caf North 4870.63 11.48 101.25 4426.01 338.11S 1700.18E 1.50 1733.47 274145.40 2388356.33 4 70.63 10 . 4524.26 41.74S 1718.43E 1. 17 2. 741 5 070.63 .4 101.25 4622.96 344. 7S 1734.16E 1.50 17 .12 27417 .24 2 8.92 5170.63 6.98 101.25 4722.5 347.49S 1747.34E 1. 1781. 2741 2.37 2 46. 527. 5.48 1 1.25 4 21.4 4 .60S 1757. SE 1. 0 1792.41 0 . 7 .7 5370.63 .98 101.5 4921.12 351.21S 1766.06E 1. 0 100.64 274211.2 2 1. 7 70.63 2.4 101.2 20.96 3 2. 1 1771.58E 1.50 1 6.27 7421. 2 7 557. .98 1 1. 5 512.1 352.89S 1774. E 1. 1 9.2 27421 4 .1 56 .72 0. 1. 51 35 . S 1775.0E 1. 1 9. 274 7 .00 0. 101.25 5 .2 3 3. 177 .08E 1 9. 274 .0 5800.00 0.00 101.25 5350.28 353.OOS 1775.08E 0.00 1809.84 274220.00 2388340.00 9 0. 0 1 1.2 .28 S 1775.08E 0. 180 .84 74 6000.00 0.00 101.25 5550.28 353.OOS 1775.08E 0.00 1809.84 274220.00 2388340.00 6100.00 0.00 101.25 5650.28 353.OOS 1775.08E 0.00 1809.84 274220.00 2388340.00 6200.0 0.00 101.25 5750.28 53.00 1775.08E 0.00 18 9. 27422. 23 340.00 6300.00 0.00 101.25 5850.28 53.OOS 1775.08E 0.00 1809.84 274220.00 2388340.00 64 0.0 .00 .101.25 5950.28 53. OS 1775. E 0.00 1809.84 274220.00 2 340.00 6500. 0.00 101.25 6050.28 353.OOS 1775.08E 0.00 1809.84 274220.00 2 8 0.00 6 0. 0.00 101.25 150.28 353.OOS 1775.08E 0.00 1809.84 274220.0 2 8 4 .00 0 0. 0 1 1.2 250.28 353.0 S 1775.08E 0.00 1809.84 274 2 . 23 34 0 6800.00 .00 101.25 6350.28 353.OOS 1775.08E 0. 0 1809.84 27422.0 2 8340.00 90 . .00 1 1. 5 .2 353.0 S 1775.08E 0. 0 .1809.84 2742 2 700. .0 101.2 0.2 353.OOS 1775.08E 0. 0 1809. 274 20. 2 0. 710.0 0. 101.2 50.2 353. S 1775. E 0.0 18 9.84 274 20. 7200. .00 101.25 7 . 8 353. 177 .0 E 1 0 .84 274 2 . 7300.00 0.00 101.25 6850.28 353.OOS 1775.08E 0.00 1809.84 274220.00 2388340.00 7400. . 0 101.5 .2 .00 1775. E 18 742 .00 34 7 .00 0.00 101.25 7050.2 353.OOS 1775.08E 0.00 1809.84 274220.00 2 0.00 7600.00 0.00 101.25 7150.28 353.OOS 1775.08E 0.00 1809.84 274220.00 2 340.00 7 . 0 0. 101.25 7250.28 3 S 1775.08E 0.00 1809. 274220. 2388340.00 7800.00 0.00 101.25 7350.28 353.OOS 1775.08E 0.00 1809.84 274220.00 2388340.00 7 0.00 101.25 74 .2 353.OOS 1775.0E 0.00 1 9.84 274220.0 .00 000.00 0.00 1 1.2 7550.8 3 3. OS 1775.08E 0. 1 0 . 27422 .00 100.00 0.0 101.25 7650.28 3 S 1775.08E 0.00 1 274220.00 238834 . 2 0. 1. 5 77 . 0 1775. E 0.00 1 74 8 0.00 0. 101.25 7 5 .2 3 3.OOS 1775.08E 0.00 1 .84 274220. 2 .00 97. 0.0 101.25 7 48.12 5 .00 1775:08E 0. 0 1 74 2 . 4 0. 1 1. 7 .2 3 3. 1775.08E 0.00 1 274 2 2 .7 0.00 .0 79 3 .0 S 1775. 8E 0.00 1 274 2 . 2 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #1 41.Oft above mean sea level ) Vertical Section is from O.OON 0.00E on azimuth 101.25 degrees Bottom hole distance is 1809.84 Feet on azimuth 101.25 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated • MARATHON Oil Company,CLU-10 ~~~ Pad #1, MARATHON Cannery Loop Unit,Cook Inlet, Alaska • PROPOSAL LISTING Page 4 Wellbore: CLU-10 Ver 1 Wellpath: CLU-10 Ver 1 Date Printed: 1-Ju1-2005 t INTEQ Hole Sections - - --- Dianeter Start Start Start Start Erxi F.nd Enf! Start WaYtxxe 16.000 0.00 0.00 O.OON 0.00E 1921.95 1850.00 67.89S 341.41E CLU-10 Ver 1 1/4 921.5 1850.00 67. S 341.41E 5450.6 5 1.0 .13 1 7 .6 E -1 V r1 ~2 5450.65.. 5001.00 352.13S 1770.68E 8425.72 7976.00 353.OOS_ 1775.08E CLU-10 Ver 1 _ Casn s Name Top Top Tpp Top Shoe Shoe TV Shoe Shoe WaBbare 1 in Casi 0. .0 N 0. E 1 21.5 18 67.89 1.41E -1 1 9 in asi 0. 0. N 0.00E 54 .65 5 1. 0 52.13 1770.68E -1 r 1 3 1/tin Liner 0.00 0.00 O.OON 0.00E 8425.72 7976.00 353.OOS 1775.08E CL -10 Ver 1 Ta r ets _~ No d E NorhtLn L~st~39Yis+~ CLU10-T/Upper lu a - 13/ 5 353.OOS 1775.08E 5186.00 N60 3153.36 W151 1512.89 274220.00 2388340.00 18-Sep-2003 CLU10 - TD - !1 0 353.OOS 1775.08E 7976.00 N60 31 53.36 W151 1512.89 274220.00 2388340.00 18-Sep-2003 AU data is in Feet unless otherwise stated Coordinates are from Sbt MD's are from Rig and ND's are from Rig (Datum #1 41.Oft above mean sea level ) Vertical Section is from O.OON 0.00E on azimuth 101.25 degrees Bottom hole distance is 1809.84 Feet on azimuth 101.25 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~~R ^ - MA THON Oil Company HUGHES 'I Location: Cook Inlet, Alaska Slot: CLU-10 ' Field: Cannery Loop Unit Well: CLU-10 ~~, INTF,Q ~ Installation: Pad#1 _ - Wellbore: CLU-10Ver1 i MARATHON Scale 1 cm = 10 ft East feet) -> -40 -20 0 20 40 60 80 100 120 140 160 80 200 220 240 260 280 300 320 340 360 380 400 100 ~- i i ~ i. _i - ~ .L~__~ -L _~- _L __~_: L._~~ L ~--~-i i ~_ ~-_~_ ~s_~~_~ i i -~~__ i i ~_i 100 v ~~ °°~ ` 1300 80 $~ 1500 • ' 1550 1250 60 1450 • 60 '1200 ' 1500 laoo . 40 11so - 40 1450 . _ 1350. '1100 r 20 1050. 20 .1300 1400 . 1000 . Op O 0 ~OA`~ .~00,~0`OO^,~00 ^00 00 O 950. .1250 1350. ~ 0 ~ ~~" ,~'L`' ,~00 0 .1200 1250 ~' A -20 ^ ^,50 ~~0850 9 by0 ~y00 .1150 1300 • ,; 1~ I~ -20 ^ ^ 800. 1100 ra0~ 1250. h ~ ASS 1150 , ~p uA O ~~ 750. 1050. sh00 ~ X00 100 ~`SSp ~ . o1100 ' 850 I- -40 ~ ~ 1000 , 01200 ~ 00 •100010 ' 800 7 ~ ~ 00 ~~00 ,~`L~ s`tiy0 ,300, 950 ^0h ~ SAO X00 ~ • 950 050 ' 750 I -60 ~ O -60 ~ ~.'` 1150 Fsp ^ 850900. '~ ~O v Z ~ h0 00 h0 O O ~ 8500 ' 1100 800 ' ~ 1 0 0 00 00 ~0~ ~O 750 . -80 • -80 750 .1050 • 1000 ~ -100 -100 • 950 ~ I -120 -120 -140 ' / -140 ~ ~ ~ 0 u _160 ~~ -160 ~ I ~ U r y -180 0 ~ -180 ~ U ~ i -40 -20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 Scale 1 cm = 10 ft East (feet) -> ~i,~ ', MARATHON Oil Company ': ~~~ r Location: Cook Inlet, Alaska Slot: CLU-10 ~ Field: Cannery Loop Unit Well: CLU-10 INTEQ Installation: Pad #1 Wellbore: CLU-10 Ver 1 ~- -- -- -- -- - - - --- -- -- MARATHON Scale 1 cm = 40 ft East (feet) -> 320 400 480 560 640 720 800 880 960 1040 1120 1200 1280 1360 1440 1520 1600 1680 1760 1840 1920 2000 ~ ~ ~ ~ ~ ~ ~ ~ i~~ ~~~ -~ -- _ ~_ pan 240 160 80 0 -80 -160 A -240 d -320 w .C G -400 Z -480 -560 -640 -720 0 v 1~ -800 U -880 U 160 80 0 -80 -160 -240 A Z -320 ~ -400 ~ .... -480 -560 -640 -720 ~' in -800 II -880 A O 320 400 480 560 640 720 800 880 960 1040 1120 1200 1280 1360 1440 1520 1600 1680 1760 1840 1920 2000 Scale 1 cm = 40 ft East (feet) -> Date potted : 14.1un-2005 Pot reference is CLU-10 Ver 1. Ref vregpafh Is CLU•10 Ver 1. Coordinates are in feet reference CLU-10. True Vertical Depths are reference Rip Datum. ' Measured Depths ere reference Rp Datum. Rlg Datum: Datum #1 Rig Dalum to mean sea level: 41.00 fl. Pot North Is aligned b TRUE North. ri.~ ~GHES INTEQ ~ARATHON Oil Com~ny Location: Cook Inlet, Alaska Slot: CLU-10 Field: Cannery Loop Unit Well: CLU-10 Installation: Pad #1 Wellbore: CLU-10 Ver 1 ® TRUE NORTH 350 0 340 10 20 Io 290 280 270 260 250 190 180 170 MARATHON X10 80 90 100 110 Normal Plane Travelling Cylinder -Feet All depths shown are Measured depths on Reference Well 200 160 MARATHON Oil Company CLEARANCE LISTING Page 1 ~ilf~ '~ CLU-10 Ver 1, CLU-10 Ver 1 Date Printed: 14-Jun-2005 MARATHON CLU-10, Pad #1 Cannery Loop Unit, Cook Inlet, Alaska INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and Magnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/1000ft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casings are NOT included Hole size/Casings are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.OOstandard deviations. Closing Factor Confidence limit of 99.80% Errors on Ref start at Sbt Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation Wellbore Flame c,•eated Last Rev{sea CLU-10 Ver 1 13-Jun-2005 13-Jun-2005 Well - Name Govemrrsent ID Last Revised_--- - CLU-10 13-Jun-2005.. - S'IOt Name _ Grid No ~ Lo itude NQrt~ East_ _ LU-10 2388727.0 00 27245 .100 N 1 56.3 W 151 15 48.3734 2 N 2. W -_- - In~f~ll~tinn _ Field _ Name Ea N _ Coord System Name. North AU nmenk Canne Loo Unit 272978.9033 2388436.2080 AK-4 on NORTH AMERI AN DAT M 1927 datum True ~ieara nce-sum ma Offset WeUlJame Offset Wellbore Offset Sbt Offset Structure Minimum Distance ft MD[ft] Diverging From[ft] EUipse Separation ft ENipse MD{ft] Clearance Factor Cleararuu~ MD{ft] i I CLU-9 CLU-9 CLU-9 Pad #1 67.66 716.11 716.11 64.98 738.19 9.85 29 .35 LU-8 LU- CLU-8 Pa #1 73.71 0.00 0.00 72.95 22 .66 2 .11 216 .3 CLU-1 CLU-1 Rd CLU-1 Pad #1 99.84 1414.26 1414.26 CLU-1 CLU-1RdPB1 LU-1 Pad #1 99.84 1414.26 1414.26 CLU-1 CLU-1 CLU-1 Pad #1 9.84 1414.26 1414.26 CLU-6 CLU-6 CLU-6 Pad #1 148.81 1146.60 1146.60 142.62 1181.10 20.05 1476.38 LU-5 CLU-5 CLU-5 Pad #1 280.97 0. 0 16 0. 280.41 131.23 21.79 2411.42 CLU-7 CLU-7 CLU-7 Pad #1 337.39 317.00 317.00 336.16 328.08 73.60 1509.19 Reference Wellbore Surve Too'I Pro ram surv ft u e Tool Model PI nn 3 7.84 Navi T k Standar AU data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1D) Prepared by Baker Hughes Incorporated L` MARATHON Oil Company J'~ CLU-10 Ver 1, CLU-10 Ver 1 M^ARATHON CLU-10, Pad #1 • CLEARANCE LISTING Page 2 Date Printed: 14-Jun-2005 Cannery Loop Unit, Cook Inlet, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated ~^ INTEQ C MARATHON Oil Company I~~ CLU-10 Ver 1, CLU-10 Ver 1 M^ARATHON CLU-10, Pad #1 CLEARANCE LISTING Page 3 Date Printed: 14-Jun-2005 Cannery Loop Unit, Cook Inlet, Alaska .:r ,~ . ~1~:- INTEQ Clearance Data. Reference MD[ftJ Reference TVD(ft] Reference North[ftJ Reference East[ft] Offs~tWep Offset MDIft] Offset TVD[ft] Offset North[ftJ Offset East[ft] Angle From Highside Cbsest Approach Distance ft Eliipse Separation [ftJ 0.00 0.00 O.OON 0.00E CLU-5 28.79 -0.21 100.59S 262. 5E 111.0 28 .97 280.75 100.00 100.00 O.OON 0.00E CLU-5 128.36 99.36 100.18S 262.68E 110.9 281.13 280.45 131.23 131.23 O.OON 0.00E CLU-5 159.17 130.16 9 .93S 262.87E 110.8 281.2 280.41 200.00 200.00 O.OON 0. OE CLU-5 227.19 198.19 99.24S 263.45E 110.6 281.53 280.47 .0 300.00 O.OON 0.00E CLU-5 326.15 297.12 98.08S 64.64E 110. 2 2. 5 280. 2 40 .0 4 0. 0 O.OON 0. OE CLU-5 425.24 396.19 96. 2S 26 .27 110. .3 281. 7 5 0.00 00.0 .OON .0 E CLU-5 522.71 493.59 4.34 269.11E 109. 2 5.2 28 . 7 6 0. 0 600.00 0.0 N .00E L -5 61 .97 5. 4 90.44 27 .82E 1 2 2 9 700.0 700.00 . ON E CLU-5 7 8.86 67 .10 84.77S 2 0. 0 1 2 4. 2 1.0 7 7 .0 0. N 0.00E CLU-5 755.51 725. 1.36S 2 .44E 1 5. 97.8 2 .55 8 .0 849.95 .51S 2. 7E CL - 845.54 14.41 7 .99S 296.61E 2. 30 .16 30 .45 950.00 949.63 2.04S 10.26E CLU-5 938.79 906.14 65.23S 310.84E 0.6 310.21 305.98 10 0.00 104 .77 4.59 2 .0 E LU-5 102 .31 994.64 54.97 2 .84E 312.5 07. 3 1150.00 1147.08 8.145 40.93E CLU-5 1121.60 1084.01 41.92S 345.76E -4.8 313.11 307.63 1250.00 1244.31 12.69S 63.83E CLU-5 1211.05 1169.86 27.24S 366.14E - .3 311.69 305.50 1 50.0 1340.18 18.23S 91.68E CLU-5 1300.38 1254.71 10.80S 388.72E -12.2 309.18 302.2 1450.00 1434.43 24.74S 124.42E CLU-5 1387.46 1336.41 6.78N 413.16E -16.5 306.56 298.85 1550.00 1526.81 32.20S 1 1.94E CLU-5 1470.44 141 .00 25.44N 439.08E -21. 05.0 296. 8 1650.00 1617.06 40.60S 204.16E CLU-5 1558.52 1493.16 46.83N 468.64E -2 .8 04.86 295.43 1750.00 1704.93 49. 1S 25.6E CLU-5 1 2.2 156 .44 68.30N 498. E -32.4 306.27 295. 1 0.00 1790.18 60.10S 302.20E CLU-5 1717.5 1635.03 89.30N 27.57E -37.8 11.7 .18 1882.55 1817.33 63.60S 319.81E CLU-5 1743.10 1656.77 96.63N 537.86E -39.6 314.64 2.65 1900. 1 31.8 65. 329.38E CLU-5 1757.00 1668.72 100.73N 543.65E 0.6 31 .45 304.22 2000.00 1914.73 7 .40S 384.1E CLU-5 1836.28 1735.7 12 . 1N 577. E -46.3 331. 318.21 21 0.0 1997.65 87.30S 439.0E CLU-5 1914.74 1800.97 150.94N 613.38E -51. 354.75 339 32 2200. 20 0. 8. OS 493.81E L -5 1991.25 1 63.04 176.78N 649.88E - 5. 3 .79 66. 2300.00 2163.51 109.10S 548.63E CLU-5 2066.67 1922.39 203.54N 687.94E -59.4 418.68 399.63 2400.0 2246.4 120.0 S 603.44E CLU-5 2144.34 1 2.01 232. 3N 728.34E 2.5 458.12 437.13 2411.42 2255.90 121.25S 609.70E CLU-5 2154.34 1989.61 236.46N 733.60E -62.9 462.84 441.60 2500.00 2329.36 130.90S 658.25E CLU-5 2221.00 2039.57 262.51N 769.20E 5.2 501.06 478.13 Offse# WeElbore Surve Tool Pro rams u s ~r CL -5 CLU-5 MWD <0-8511'> 8511.00 MTC collar S ndard LU-5 CLU-5 Di meter < 600-11420'> No Tool 11420.0 N T I No M d I AU data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated C` MARATHON Oil Company ~~ CLU-10 Ver 1, CLU-10 Ver 1 MARATHON CLU-10, Pad #1 CJ CLEARANCE LISTING Page 4 Date Printed: 14~un-2005 Cannery Loop Unit, Cook Inlet, Alaska ~.^ ~i INTEQ Clearance Data Reference MD[ft) Reference TYD(fti Reference Norgi[itj Referer~e East~~] Offset V1feU Offset MD[it] O#set ND(ft} Offset NorNs[ft~ Of~et East{ftJ Ar~gls From aside Cbasest Reproach Distance Ett Elyse Separation [~3 _ 0.00 0.00 O.OON .0 E CLU-6 1.88 0.38 159.61 S 55.55E 160.8 168. 1 100.00 100.00 O.OON 0. E CLU-G 102.64 101.14 159.16S 55.61E 160.7 1 8.60 167.99 2 .0 2 . 0 .OON E CLU-6 203.61 2 2.10 158.02S 5.77E 16 .6 1 1 . 7 300.00 300.0 0. ON 0.00E CLU-6 303.28 301.76 156.69S 56.09E 160.3 1 6.43 164. 3 4 0. 400.00 N E L -6 404.61 4 3. 154.97 .87E 1 1 .1 1. 4 5 .00 O.OON 0.0E LU-6 506.17 151.67 58.76E 15 .8 1 .72 1 .47 60 .00 .OON E CL - 60 .61 6 3.72 146.73S 64.17 5 .4 1 7. 7 7 700.0 O.OON 0. E CL 7 8.58 7 5.57 137.2 75.58 151.2 1 .72 7 750.0 0. 0. E -6 757.84 7 3.79 1 8 S 3.39 147. 1 5 1. 2 . 5 0.51 2 7E C U 8 2.99 6.48 117. 9S 100.46E 1. 8 1 9 2. 10.6 L -6 948.37 8.42 103.7 121.6E 31.1 1 1. 1050.00 1048.77 4.59S 23.06E CLU-6 1043.82 1029.38 88.08S 145.80E 22.8 149.70 144.51 1146.0 114 .76 40.5 LU-6 1134.75 1114.41 .91 172. 1 14.1 1 1 1150.00 1147. 8.14S 40.93E CLU-6 1137.20 1116.68 69.36S 173.13E 13.3 148.82 142.80 1181.10 1177.45 9.455 47.52E CLU-6 1166.02 1143.27 62.96S 182.21E 10.1 148.91 142.62 12 0. 1244.1 12.69S 63.83E CLU-6 1229.59 1201.34 47.87S 203.21E 2.8 1 . 3 1 3.25 1350.00 1340.18 18.23S 91.68E CLU-6 1320.89 1283.51 24.10S .235.11E -8.3 1 .33 146.83 141 .7 1 7. 22.07 110. E CL 1 76.44 1332.7 8.4 S 255.4 E -1 1 .9 1 1. 14 .00 1434.43 24.74S 124.42E CL -G 1411.00 1363.16 1.62N 268.4 E -19.5 162.88 1 .78 147. 1458.9 2 .62S 133.85E -6 14 . 4 13 .0 8.51 N 277. E -2 .3 1 1 7. 1 1 0.0 1 2 . 1 2.20S 161.94E L -6 4 3. 1 1434.14 27. N 301.44E -2 . 177.6 1 2 1650.00 1617.06 40.60S 204.16E CLU- 1574.90 1502.26 54.22N 337.18E - .1 1 1 17 .0 1704. 4 .91 25 . E C U 1 3.71 1 5. 82.62N 74.56E -45. 2 7.7 1 .00 1790.18 6 .1 S 302.20E C U 1723.3 1619.07 109.56N 410.57E -5 . 2 1 2 1. 7 1 2.55 1817.3 63. 31.1 C U-6 1747.67 1 36.0 119.1 N 42 .67E 277.7 . 4 1 00. 1831. 65.0 329.3E L -6 17 2.75 1647.77 12 .19N 4 .07E -53.1 2 .21 7 . 1 2000.00 1914.73 76.40S 384.19E CLU-6 1 35.17 1698.97 154.84N 473.81E -57.4 328.72 313.60 1 . 0 1997. 7.3 4 E CLU- 1 .21 1747. 1 8N 16. OE -60.6 7 . 1.1 2200.00 2080.58 98.20S 493.81E CLUB 1981.84 1796.79 218.31N 562.75E -63.2 4 .66 411.71 2300.00 2163.51 109.105. 548.63E __ _ CLUB .1 ___.2045.50 ..1837.32 _ 247.27N 602.38E -64.9 4 6.10 465.47 ~ Offset Wellbore Survey Tool Programs ~ tAlwll W~lhnra Siuvev Alarr~a lAlNffi Qurvnu Tent t=[ror ~lo[{® All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 41.Off above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated MARATHON Oil Company J~~ CLU-10 Ver 1, CLU-10 Ver 1 M^ARATHON CLU-10, Pad #1 CLEARANCE LISTING Page 5 Date Printed: 14-Jun-2005 Cannery Loop Unit, Cook Inlet, Alaska i ~ t~ INTEQ Clearance Data Referert~ MtXftj Reference TYD(ftj Refsrefice North(ftj ttefere East(~j wea Onset MO[ft] Offset T~iD[ft} offset North[fl} Oifsat East(ff) Angt® From Higl~ide Closest Approaclh Distaruae Ellipse S~eration , fit) 0. 0 . 0 O.OON 0.00E CLU-7 1.32 0.32 8 .3 S 32 .26E 1 5. 3 .27 3 .24 100.00 100.00 O.OON 0.00E CLU-7 101.96 100.96 89.45S 326.06E 105.3 3 .11 337.6 200. 2 0. 0. N 0.00E U-7 202.3 2 1. 3 8 .76S 325. 1 .4 37. 2 0.00 300.00 .OON 0.00E C U-7 301.28 300.27 89.7 325. E 1 5.4 337.41 3 6.2 317.0 317.0 . ON 0.00E -7 318.0 317.00 8 .6 S 32.6E 1 5.4 37. 2 .0 .08 .0 E C -7 328.47 327.46 89.53S 325.2 1 .4 37.41 .00 4 .00 0. N 0. E CL -7 395.88 394.8 .10S 32 .3 1 .1 7 3 0. 0 500. 0. N 0. OE U-7 491.03 4 9.86 4.14 2 .6 104. 1 3 8. .0 6 0.00 C -7 841 2. 7 .71 34. E 1 .41 700. 7 0. N .00E L -7 67 .20 671. 7 .475 2. 7E 101.6 3 .74 .1 7 75 . 0. N 0.00E U-7 714. 712.7 .98 7.4E 1 5. 3 850.00 849.95 0.51S 2.57E CLU-7 797.00 791.88 51.39S 360.67E -3.1 366.33 363.08 9 0. 2. S 1 .2 E L -7 72.7 6 .6 36.16 7. E 77. 7 1050.00 1048.77 4.59S 23.06E CLU-7 945.75 932.14 17.49S 396.14E -8.9 391.09 386.83 1150.00 1147.08 8.14S 40.93E CLU-7 1018.39 997.33 4.67N 419.21E -12.4 407.04 402.21 1250. 1244.31 12. 9S 3.8E C -7 1090.50 1060.36 2 .85N 444.57E -16.0 424.9 41 .50 1350.00 1340.18 18.23S 91.68E CLU-7 1153.83 1113.24 53.60N 469.04E -19.4 446.17 440.28 14 .0 14 .43 24.74S 124.42E L -7 1218.5 1164. 82. 7N 496. 7E -2 .1 471.6 4 .4 1509.1 1489.35 29.05S 146. 6E C U-7 12 .41 1192.60 9 .77N 512.4 E -2 .1 4 .75 482.11 1 1. 151 .4 1. 7S 15 .7 E -7 1274.7 12 7.14 1 9.05N 1. E -2 .1 .74 1. 7 1 . 0 152.1 2.20S 161. E CLJ~ 127.0 12 7.3 1 .1 N 5 1.3E -2 .1 1. .47 Offset Wellbore Surve Tool Pro rams. WeU Wellbore 7 Eno[ AA dAo g -7 CL -7 _ MWD_<0-~64> _ __ 10864,00 Navi Trak S M All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated • MARATHON Oil Company J~~ CLU-10 Ver 1, CLU-10 Ver 1 M^ARATHON CLU-10, Pad #1 • CLEARANCE LISTING Page 6 Date Printed: 14-Jun-2005 Cannery Loop Unit, Cook Inlet, Alaska INTEQ C learance Data Reference MD(ft] Reference TVD{ftJ Reference tJprtit[fti EasgRJ WAN Oast MD(fti Clffaet TvD~tl Offset NorUs(ftj Offset East[ftl Anglo From Closest ~ Dlsl~noe Ift1 0.0 . 0 0. N 0.00E LU-8 0.99 -0.01 65.39S 34.01E 152.5 73.71 73 100.00 100.00 O.OON 0.00E CLU-8 100.96 99.96 65.30S 34.25E 152.3 73.73 73.23 2 .00 200. . 0 0. E 200.85 199. 65.05 . 8E 1 1. 7 . 1 7 .97 229.6 229. O.OON 0.00E LU-8 230.35 229.34 4.86S 35.42E 151.4 73.0 72.95 . 0 00. 0. N .00 CLU-8 00.05 298.96 8S 38. 5E 14 . 74.1 3 3 4 4 0. ON 0.00 L - 3 .92 97. 61. 1S 45.4E 14 .7 7 .76 5 0. 0. 0 .0 N E L -8 498.5 4 6.73 . 2S 54.78E 13 . 45 0.00 60.0 E L -8 597.21 594.67 54.42 .46 1 .7 0. 7 N L -8 6 5.21 6 1. 47.0 S 79. 1 E 1 9 8. 7 750.0 N 0.00 CL - 74 . 7 8. 40.1 88.49 114. .12 .8 .51 S . 7 C -8 8. 0.49 .77 108. E 110.1 1 918.64 918.42 1.45S 7.30E CL -8 901.74 890.62 14.59S 122.63E -4.7 119.36 115.13 95 . 94 .63 2.04 1 E L -8 930.1 917.5 9.1 13 .0 E -7.7 12 . 11 . 1050.00 1048.77 4.59S 23.06E CLU-8 1017.66 999.46 7.92N 155.50E -15.9 141.87 136.93 1150.00 1147.08 8.14S 40.93E CLU-8 1101.75 1076.14 24.97N 185.44E -22.4 164.35 158.88 1250. 1244.31 12.6 63. 3E CL -8 1178.51 1143.12 41.36N 219.08E -27.1 193.04 187.06 1350.00 1340.18 18.23S 91.68E CLU-8 1268.98 1219.53 61.38N 263.19E -31.4 224.30 217.63 14 .0 1434.43 24.74S 124.4E L -8 1355.8 1 92.17 0.55N 306.7 E - 4.9 254.07 4 . 2 15 .00 1 26.81 32.20S 161. E L -8 1441.93 1 2.84 1 LOON 351.49E -38.2 2 275.44 1 1617.6 40. 2 .16 1 19.1 1424.4 1 0. 393. E 1 17 .00 17 4. 3 49.1 250. 6E CL 15 7.33 1484.4 142. N 4 E -43.5 7. .91 1850.0 179 .1 60.10S 302.20E CLU-8 1669.26 1 37. 164.35N 481.91 E -4 . 3 2.66 70.44 1 2. 5 1817.33 63.6 S 31 .81E U-8 169. 1 .4 172.0 N 4 6.22E -4 . 1 1 1. 0 65.5 S 2 . E U-8 1702.80 1 1.70 175.43N 2E -4 . 401.23 . 0 2 .00 1914.7 76.4 384.19E L -8 1777.68 1 1 . 5 201.08N 5 .27E -4 .7 44 . 427.22 10 . 1 97.65 87.30 439.0E C U-8 1 62.12 1 70.1 230.13N 6 5.4E -52. 48 .4 4 .4 2165.35 2051.85 94.43S 474.82E CLU-8 1915.79 1706.24 249.14N 640.47E -53.6 514.71 496.40 Offset Wellbore Surve Tool Pro_g_r_ams Wel! Name tl untev 7001 F Mcxi l~ CLU-8 CL -8 MWD <0- 777> 9777.00 Na i Trak Ma C rrect All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated • MARATHON Oil Company '~~ CLU-10 Ver 1, CLU-10 Ver 1 MARATHON CLU-10, Pad #1 • CLEARANCE LISTING Page 7 Date Printed: 14-Jun-2005 Cannery Loop Unit, Cook Inlet, Alaska i f~l ; INTEQ Clearance Da#a Reference MD{ft] Referenc~i TVD{ftJ Refereru~ NwUi[ftl East[ft) OL't~t Weq ~fset MD{ft] T1/D{tl] No-1~1l~1 Offset East(f#J Angle From Fliahsid® Ctctaeat Approach Distarsoe F~iiip~e Salon (ft~ ', 0. 0 0.00 O.OON 0. E CLU-9 1.11 0.11 6 . SS 2 . W -159.2 74.41 74.3 100.00 100.00 O.OON 0.00E CLU-9 101.32 100.32 69.22S' 26.54W -159.0 74.13 73.70 2 0.0 2 .OON E CLU-9 201.62 20.1 .27S 2 . W -15 .5 7 .40 7 . 300.00 300.00 O.OON .00E CL -9 301.56 300.55 67.34S 27.16W -1 .0 72.61 71.46 40 .00 4 .00 0.00 0. E LU-9 4 2.16 401.14 6 .58 2 .1 W -1 .6 71.5 70.0 50 . 5 O.OON .0 E CL - 502.2 501.16 6.24S .59 -161. 7 . 6 .1 00. 600.00 0.0 N 0. E CLU- 2.10 60.2 6.45 16.58W -1 .0 6 .4 6. 70 .00 7 0.00 N 0 701.97 70.2 67. 1 S 7.1 W -174. 7. 1 71 .11 71 .11 E U- 717.98 716.11 .47 -17 .7 7. 1 738.1 73 .1 0. E C - 7 9.81 737.75 7. .1 -17 .2 7.7 7 0. 750.00 0. E L -9 751.44 74 . 6 .82S 0. -179. 7. 850.00 849.95 0.51S 2.57E CLU-9 850.55 847.15 68.95S 14.89E 68.5 69.59 66.40 949. 2. 10.2E CLU-9 950.1 4. 69.4 S 33. 5 .4 71.5 67.89 1050.00 1048.77 4.59S 23.06E CLU-9 1048.51 1040.63 68.46S 56.40E 50.8 72.51 68.27 1150.00 1147.08 8.14S 40.93E CLU-9 1146.14 1134.34 67.27S 83.76E 42.1 74.11 69.24 1250.00 1244.1 12. S 3. 3E CL -9 1243.35 1226.79 66.37S 113.73E 34.7 75.3 69.7 1350.00 1340.18 18.23S 91.68E CLU-9 1339.37 1315.65 64.28S 150.00E 25.6 78.25 72.05 1 1434.43 24.74S 1 4.42E LU-9 1437.71 1404.9$ 6 .21 190. E 15.7 74.17 1550.00 1526.1 2.20S 161.94E CLU-9 1530.62 1487.05 53.41S 233.87E 4.6 84.87 77.83 1 1617.6 4 . 204.1E L - 1 24.4 1 66.24 46.34 2 2. E -6.0 9 . . 2 17 17 4. 3 49. 1 S 2 E C - 1717. 1643.86 3 . 33 .18E -14. 104. 1850.00 17 0.18 60.10S 3 2.20E CLU- 1810.74 1718.00 31.6 390.49E -22.8 117.5 1 .37 18 2.55 1817.33 63.6 1 .81E CL -9 1841. 1741.6 2 7S 40.3 - .1 1 2.14 1 1 1 1. 65. 32 . E C -9 1857.66 17 .52 27.7 S 419.7 4.7 14. 0 2 1 14.73 76.4 S 3 E C U-9 19 1.68 1 .44 2. S 47 . - 1. 41. 1 .6 21 1997.6 7.3 4 CL - 2046.3 1 .62 1 .75 2. E -3 14 .76 2200.00 2080.58 98.20S 493.81E CLU-9 2143.11 1968.37 5.52S 607.38E -38.9 184.61 168.12 300. 21 1 109.1 E U-9 2240.7 2 . 2 2.7 N 72.12E -41.6 . 7 187.9 2400.00 2246.43 120.OOS 603.44E CLU-9 2339.78 2114.80 10.24N 737.72E -43.6 228.74 207.34 2500.00 2329.36 130.90S 658.25E CLU-9 2438.72 2188.81 17.92N 802.93E -45.3 250.67 226.77 260. 2412.2 141.80S 713.06E CLU-9 2537.48 2263.23 25.32N 7.43E -4 .9 2 .00 245. 2700.00 249522 152.70S 767.87E CLU-9 2635.19 2337.09 32.17N 931.03E -48.1 292.92 263.96 2 2 78.14 1 3.6 2 . E C U- 2732.5 241 .1 9. N 99 . -49.1 14.1 2 .17 2900.00 2661.07 174. 1 S 877.50E CLU-9 2831.77 2485.17 4 .7 N 1059.5 E - .0 3 .57 1.58 2 6. 5 26 1.21 178.47S 897.42E L -9 28 1 2509.41 4 .03N 1080.59 - .3 3.37 2 .16 2718.42 182.04S 91 .4 E L - 2892.47 2530.76 5 .19N 1 .42E -5 . .7 31 .1 000.00 2744.00 1 5.41S 932.31E CLU-9 2918.97 2550.44 52.31N 1117. 5E -50.7 357.1 321.65 31 0.00 2826.92 1 .31S 9 7.1E CLU- 3011.80 2618.72 60. N 1179.42E -51.4 2. .71 3200.00 290.5 2 7.21S 1041.93E CLU-9 3108.17 268 .26 6 .86N 144.52E -51. 4 7.32 6.21 300.00 2992.78 218.1 S 1096.74E CLU-9 3203.69 27 .87 77.03N 1 09.42E -52. 4 2.49 3370.6 3051.34 22 .8 S 1135.4E CLU-9 3271.69 2 8.17 82.62N 1355. 1 E - 2.5 4 .40 4 .1 3470.63 3134.99 236.49S 1189.20E CLU-9 3368.30 2877.96 90.17N 1422.30E -52.9 476.56 429.06 3570.6 3 20.05 24 .7 S 1 40.77E CL - 34 1.79 2 5.18 97.2 N 1486.8 E -53.0 04.4 4 5. 3670.63 3306.45 256.57S 1290.15E CLU-9 3556.09 3012.68 104.56N 1552.32E -52.9 34.27 483.05 t?ffset Wellbore Surve Too! Pro rams -- A, Surv ft T Model C U-9 LU-9 MWD < - 100> 9100.00 N vi Tr k Sa d Ma orr ct AU data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated • MARATHON Oil Company J~ CLU-10 Ver 1, CLU-10 Ver 1 M^ARATHON CLU-10, Pad #1 r CLEARANCE LISTING Page 8 Date Printed: 14-Jun-2005 Cannery Loop Unit, Cook Inlet, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1D) Prepared by Baker Hughes Incorporated ~~~ INTEQ • MARATHON Oil Company '~ CLU-10 Ver 1, CLU-10 Ver 1 MARATHON CLU-10, Pad #1 • CLEARANCE LISTING Page 9 Date Printed: 14-Jun-2005 Cannery Loop Unit, Cook Inlet, Alaska ^'.,~~ ; INTEQ Clearance Data - Reference MD[ft] ' ___ Reference ND[ft] ' Ref®rence North[ft} Reference East(ftj Offset Well Offset MD[ft] Offset ND[ft} Offset North[ftJ O€fsat East[ft] A»gle From Hl~hside de Closes! Approach Distance ft.. Ewe Separation [ft] - 0.00 0.00 O.OON 0. OE CLU-1 1.00 0.00 85.24S 144.57E 120.5 167.83 100.00 100.00 O.OON 0.00E CLU-1 101.00 100.00 85.24S 144.57E 120.5 167.83 2 0. 0 2 0.0 .0 N 0.0E CLU-1 201.00 20 .00 5.24S 144.57E 1 0.5 167.8 300.0 300.00 O.OON 0.00E CLU-1 301.00 300.00 8 .24S 144.57E 120.5 167.3 4 .00 40 .00 O.OON 0.0E CLU-1 401.00 400.00 .24S 144.57E 120.5 1 7. 3 500.0 500.00 .OON 0.0E CLU-1 500.85 499.85 85.25S 144.57E 120.5 1 7.83 6 0.00 600.0 ON 0.0E CLU-1 600.75 5 9.7 8 .6 S 144.53E .7 1 .02 700.00 70.0 N 0.0E L -1 7 2.6 7 1.62 4.90 144. E 12 .4 1 7. 7 0. 0 7 0.00 O.OON 0.00E L -1 752.74 751.70 83.17 145.4 11 1 850.00 849.95 1S 2. 7E CLU-1 5 .74 852.36 7 .74 147.75E 16. 16 . 9 0.00 949.63 2.04 10.26E CL -1 52.0 949.43 1. S 1 3.07E 11.4 1 .72 1050.00 1048.77 4.59S 23.06E CLU-1 1049.24 1044.74 43.98S 160.84E 4.7 143.36 11 .00 1147.08 8.14S 4 .93E CLU-1 1146. 1139.6 23.95S 1 9. 2E -4.3 12 .2 1250.00 1244.31 12.69S 63.83E CLU-1 1241.92 1232.09 2.03S 176.93E -16.7 114.26 1350.00 1340.18 18.23S 91.68E CLU-1 1334.90 1321.73 21.54N 184.34E -34.0 102.51 1414.2 1400.94 22.31S 112.17E CLU-1 1393.35 1377.78 37.49N 188.70E -47.5 99.84 1450.00 1434.43 24.74S 124.42E CLU-1 1425.13 1408.17 46.54N 190.96E -55.3 100.99 15 0 1 26.81 32.2 S 1 1.94E CLU-1 1511.04 14 9. 3 72.24N 196.86E -75. 11 .1 16 .00 1617.06 40.60S 204.16E CLU-1 1592.74 1566.96 98.91N 202.18E -91.4 148.24 17 .00 1704.93 49.1 2 .96E CLU-1 1 77.30 1645.91 127.82N 210. E -1 1.7 1 1.49 18 0.00 1790.18 60.1 302.20E CLU-1 1758.00 1719.6 156.1 N 225.86E -10 .9 2 9. 1882.55 1817.33 63.60S 319.81E CLU-1 1781.10 1740.8 164.95N 231.06E -107. 256.88 19 . 0 18 1. 0 5.50S 2.8E CLU-1 179 .50 1753.49 170.57N 234.47E -1 26.22 2 00.00 1914.7 76.4 S 384.19E CL -1 1874.9 18 2. 20 .1 N 256.5 E -111.4 320. 21 0. 1 97.65 7.3 S 43 .00E CLU-1 1948.0 18 3.4 235.22N 280.72E -11 37 7 2 00.00 20 98.20S 4 3. 1E CLU-1 2019.78 1941.65 269.31N 05.36E -112.7 4 5 2300.00 2163.51 109.10S 548.63E CLU-1 2108.69 2013.26 311.50N 336.93E -112.8 494.26 Offset Weltbore Surve- Tool Pro rams -- eU W M ft Sum T ,1 1= i~__ CLU-1 U-1Rd MWD<9768-10835'> 10837.00 Navi Tr k Ma C rrected AU data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 41.Off above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated • MARATHON Oil Company J~~ CLU-10 Ver 1, CLU-10 Ver 1 MARATHON CLU-10, Pad #1 • CLEARANCE LISTING Page 10 Date Printed: 14-Jun-2005 Cannery Loop Unit, Cook Inlet, Alaska ~. 'Y ~ 1 r. , INTEQ Clearanc~a Data Reference o(ff) Reference TVq[~l Reference -~,,c~i ~I~i O We11 Of~et N Uifset TVDIf#i Offset. Na1h(tt1 Offset Eastjft] Angle ~ From Cfasest l~rpr®ach Dismrros E~lps® Separation [#) 0.0 0. O.OON 0. E CLU-1 1.00 0.00 85.24S 144.57E 120.5 1 7.83 100.00 100.00 O.OON 0.00E CLU-1 101.00 10 .00 5.24S 144.57E 120.5 167.83 2 0. 2 . 0 0.0 N .00E L -1 2 1. 0 20 . 85.24 1 .57 1 167 300. 00.00 O.OON 0.00E LU-1 301. .00 8 .24 144. 7E 120. 167.8 400. 40 .00 0. N 0. E L -1 401.00 4 .00 85.24S 144. 7E 1 1 7. .00 .00 .0 N 0.00E CL -1 500. 49.5 .25S 144 7E 2 . 1 7.8 .00 600.0 N 0. E CL -1 6 .75 59 .7 5.69 144.53E 1 .7 7 7 .0 O.OON OE L -1 7 2.63 7 2 84.9 S 144. E 1 1 75 7 0. U-1 752.74 7 1.70 83.17 4 .04E 11 1 0. 84.5 0.51 2. 7 L -1 853.74 8 2.36 5.74S 147.75E 1 .2 1 95 . 9.63 2. S 1 .2 E -1 52.00 949.4 61.5 15 .07E 11.4 1 .72 1050.00 1048.77 4.59S 23.06E CLU-1 1049.24 1044.74 43.98S 160.84E 4.7 14 .36 11 .00 1147.0 .14S 40 93E LU-1 1146.53 11 0 23.9 16 .02 -4.3 1 9. 1250.00 1244.31 12.69S 63.83E CLU-1 1241.92 1232.09 2.03S 176.93E -16.7 114.26 1350.00 1340.18 18.23S 91.68E CLU-1 1334.90 1321.73 21.54N 184.34E -34.0 102.51 1414.26 1400.94 22.31S 112.17E CLU-1 13 3.35 1377.78 37.49N 1 8.70E -47.5 99. 4 1450.00 1434.43 24.74S 124.42E CLU-1 1425.13 1408.17 46.54N 190.96E -55.3 100.99 1550.0 1 2 .81 3 .20 161. 4E CLU-1 .1511.4 148 .9 72.24N 19 . E -75. 11 .1 16 .00 1 17.06 40.60S 204.16E CLU-1 1592.74 1 .96 98.91 N 202.18E - 1.4 14 .24 17 .0 17 . 3 49. 1S 25 . E CL -1 1677.30 164 .91 127. 2N 210. 4E -1 1.7 191.4 1 . 0 17 .18 60.10S 302.20 L -1 1758.00 171 .96 1 .16N 225. E -10 . 2 18 2.55 1817.33 63.60 319.81E CLU-1 1781.10 174 .68 164.95N 231.06E -107.8 2 . 8 190 .0 18 1. 6 .50S 32 .38E CLU-1 1795.50 17 .4 17 .57N 234.47 -1 2 .2 0. 1 14.73 7 .40 .19E CLU-1 1874.9 1 2 2 3.14N 256. -111.4 2 . 1 . 0 1997. 7.30S 9 OOE CLU-1 1948.00 1 .49 235.22N 2 E -11 .3 7 . 7 20 . 2 0.58 98.2 S 493.81E CL -1 2019.7 1941.6 26 . 1N 5.36 -11 .7 4 5.75 2300.00 2163.51 _ 109.10S__ 548.63E CLU-1 2108.69 2013.26 311.50N _ 336.93E -112.8 _ 494.26 ©ffset Wetlbore Surve Tool :Pro rams w urv T LU-1 CLU-1RdP61 _ MWD<5750-10725'> 10727.00 Nevi Trak Ma rr cted AJI data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated • MARATHON Oil Company '~ CLU-10 Ver 1, CLU-10 Ver 1 MARATHON CLU-10, Pad #1 • CLEARANCE LISTING Page 11 ~`~ Date Printed: 14-Jun-2005 ~; Cannery Loop Unit, Cook Inlet, Alaska TNTEQ Clearance Data Reference MD(ftJ Reference TVD[ft] Reference North(kj Reference East[ttj Offe~'Wea~ Offset. MD{ftJ Offs TVDIRJ Offset.. North[ftj Offset East[ftj Ante From de CbsQSt Approach Distance ft E~pse Separa#ion jftJ 0.0 .00 O.OON 0.00E CLU-1 1.00 0.00 85.24S 144.57E 12 .5 167.83 _ 100.00 100.00 O.OON 0.00E CLU-1 101.00 100.00 85.24S 144.57E 120.5 167.83 2 0 200.0 0. ON 0.00 CLU-1 201.00 20 . 85.24S 1 . 7E 1 1 7 8 300.00 . 0 O.OON 0.00E LU-1 301.00 300.00 85.24S 144.57E 1 0.5 167. 4 0.0 4 O.OON 0. E LU-1 4 1.00 400. 8 .24 144.57E 1 0. 1 7. N .00E CLU-1 500.85 4 9. 5 5S 144. 7E 1 0.5 1 7. .00 N 0. E CLU-1 600.75 5 9.7 8 .6 144.5E 12 . 1 70 .00 7 0. N .00E CL -1 7 2. 3 701.62 84.9 S 144. 1 7. 7 7 .0 N E L -1 7 2.74 7 1.7 .17 14 17 1 7 8 9. 5 0. 2.57 CL -1 853.74 52.3 75.74S 147.7 16. 950. 2.04S 1 .2 E C U-1 952.00 .4 61.58S 153. E 11.4 1 .72 1050.00 1048.77 4.59S 23.06E CLU-1 1049.24 1044.74 43.98S 160.84E 4.7 143.36 11 .00 1147. 8.14 40.93E CLU-1 1146.3 1139. 23. 16.2E -4 1 28 1250.00 1244.31 12.69S 63.83E CLU-1 1241.92 1232.09 2.03S 176.93E -16.7 114.26 1350.00 1340.1 18.23S 91.68E CLU-1 1334.90 1321.73 21.54N 184.34E -34.0 102.51 1414.26 14 0. 22.31 S 112.17E CLU-1 1393.35 1377.78 7.49N 188.70E -47. 9. 1450.00 1434.43 24.74S 124.42E CLU-1 1425.13 1408.17 46.54N 190.96E -55.3 100.99 1 5 .0 1 2 . 1 32. OS 1 1.94E LU-1 1511.4 14 9.93 72.24N 196. E -7 . 116.13 1650.00 1617. 40.60S 204.16E CLU-1 1592.74 1 .96 8.91N 202.18E -91.4 148.2 17 17 4 .9 S 2 E LU-1 1 77.30 1645.1 1 7. 2N 21 -101.7 1 1.4 1 17 .1 60.1 E LU-1 175 .00 1719.96 1 .16N 22.6E -1 23 . 18 2. 1 17.3 63. S 19. 1E CL -1 1781.10 1740.68 164.95N 231. 6E -107.8 2 .88 1 00. 1 1.8 65. OS 329.38E L -1 1795.50 17 3.49 170. 7N 2 .47 -108. 6 .22 2 1 14.73 76.40S 384.1E CLU-1 1874.99 1822.54 2 .14N 256. -111.4 21 0.00 1 7. 87. S 9.0E C -1 1948.00 1883.4 23 .22N .72 -11 7 . 7 200.00 2 9 . S 49 .81E CL -1 2019.78 1941.6 2 9.31 N 5. -11 .7 .7 2300.00 2163.51 109.10S 548.63E CLU-1 2108.69 2013.26 391.50N 336.93E -112.8 494.26 Offset Wellbore Surve Tool 'Pro rams - weu weu~® ~ _ 1. L -1 CLU-1 GMS <0-12010'> No Tool 12010.00 No Tool All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Datum #1 41.Oft above mean sea level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated File Edt Profiles Table Tools Offset Data Units ~ ~ J~ ~ f ri f~ t~„y .~J ~... r t~l~ ~~ ~IeU atllT ts~ Comnrersts~ Errors) Hole SectionslCasings, JJ J xJ J f E J~ J~J venooreDetarlslOffsetData :...._._.P_._.., arge _______ Name CLU•10 Ver 1 ~ ID 775488 - _ _.- -- -- _ ____ _ i . _ -- - N i i East ~' -Azimuth - - 101.247 -~ r Default C' S ecia6sed North I Arbitr tie , ~ Start MD ~ -r=i k -TVD i i .l0 k ~ ~ SecCion P - - ---- r ~Y I MD [ft] Inc [deg] Azi [deg] ND [ft] North [ft] P East [ft] } DLS Tface VS [ft] ~1- i i Ide91100ft] ~ [deg]. ~ _ ~-_~_._ -- -- _ _... ,,.-. _ __~- -__- _, .---. ~ ~ ~ emus 0.00: C_J ~~~ I ur:~~r~ re (~ ; ar~ra I r t' .: F r!d f - -; f =,r, t~ ' I f 'a: ~'dp.ytti f ''•:vrll f Fi~,~ f,i --:L __e -, I - Coordinates I MD -' {' Feld C' Installation C` Sbt C R~ Datum i Datum P: Datum #1 [41.0] 13Jun-2005 II - ~9 C' Field (' Installation rSlot - - ------ ------ C' Slot C Rg Datum --- ----- -------- --• © Paradigm G eophysical Ltd. 2003 ,'J ~~ • • Marathon Oil Company ,'~E Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. INTEGRATED FLUIDS ENGINEERING PROJECT PLAN ~. - IFE ~ • Prepared For: MARATHON OIL COMPANY Well Cannery Loop Unit #10 Kenai Peninsula, Alaska Prepared by: Tony Tykalsky Reviewed by: Mark Fairbanks Presented to: Will Tank July 1, 2005 ~~ ~ • '~~ Marathon Oil Company Well Name: Cannery Loop Unit #10 _ 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 Cannery Loop Unit #10 Well to be drilled this year. The following is a brief synopsis of the program. Overview: CLU #10 is a development well targeting the Beluga formation at the Cannery Loop field. Flo-Pro fluid will be used for the intermediate and production intervals. After logging the production interval, the well will be completed with a 3-1/2" excape system cemented in place. Surface Interval: The surface interval will be drilled with the standard GeUGelex spud mud. No problems were noted in this interval while drilling Cannery Loop # 8 & 9. Intermediate Interval: This interval will be drilled with aFlo-Pro NT 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. NOTE: Since this fluid will also be used in the production interval, care should be taken to maintain recommended mud properties while drilling the intermediate interval. Production Interval: This interval will be drilled with the same fluid that was used to drill the intermediate interval. The fluid will be pre-treated with Bicarb and/or citric acid prior to drilling out the cement. Any further fluid dilutions will be made in order to keep the mud properties at the recommended specifications. Fluid loss should be maintained @ 7 - 9 cc's API for this interval. NOTE: Mud weights as high as 10.0 PPG may be needed to control coal ag s at the bottom of this interval. Completion: The cement will be displaced with 6% KCl brine for the completion phase of the program. Conqor 303A and Sodium Meta Bisulfate will be added to the drilling fluid that will be left between the 3-112" completion string and the 9-518" casing on the final circulation prior to cementing. • Tony Tykalsky Project Engineer /M-I SWACO Reference Wells: CLU #7, CLU #8, CLU #9 Marathon Oil Company Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. NOTE: This program is provided as a wide only. Well conditions will always dictate fluid properties required. EXECUTIVE SUMMARY Our overall goal is no spills and no incidents while providing fluids and solids controi services to Marathon Oil Company. ., Our goal for Cannery Loop #90 is to remove drill solids from the mud system at a cost of less than $0.25 per pound. This has been the average for the last three ~ ~ • years of centrifuge van operations With fibs revised fluid formulation (utilizing the intermediate interval fluid foe the production infierval~, we expect to drill this wait for a product cost of iess than $27.52 per foot. Use of the MI Swaco centrifuge van for the last four years has provided an estimated savings in dilution and disposal costs to Marathon Oil of over $800,000. '~ With continued usage of our equipment, we expect to provide more savings to you during future operations. ~~ • • '~ Marathon Oil Company Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. Interval Benchmarks and Targets Drilling Intervals Depth Benchmark 1 Benchmark 2 Benchmark 3 Benchmark 4 Interval ~ft~ Fluid cost per foot Volume Usage Solids Removal 0 -1922' < $5.69 ft < 2312 bbls 1922 - < $41.20 ft < 2744 bbls 5451' 5451 - < $25.41 ft < 1235 bbls 8426' Total Avg. Max. Project < $27.52 ft <6291 bbls < $0.25 Ib No Spills from Targets for Centrifuge Van Drilling Operation interval ~~ • ~ '~ Marathon Oil Company Well Name: Cannery Loop Unit #10 _ Location: Kenai, Alaska. Project Summary Casing Hole Casing Depth ND Mud Mud Sum Interval Size Size Program System Weight Days Mud Cost (in) (in) (ft) (ft) Solids Control (ppg} 13 3/8" 16" r~ ,~~, 1922' 1852' GeUGelex Spud K `~~ Mud 8.6 - 9.4 5 ~ 14,852 3 ,,~~ nr Screens 150/180 ,~` mesh ~ ~ ~ ~ Desilter Centrifuge Van ,~,~~„ 9 5/8" 12-114" " 5451' 5001' Flo-Pro ' w/SafeCarb 9.0 - 10 $153,198 .~;~ Screens 180 - 210 < 9.5 mesh r ~ Desilter ?z` Centrifuge Van 3-1/2" 8-1/2" ''~` 8426' 7976' Flo-Pro w/SafeCarb 9. - 7 $$1,076. Screens 230 - 210 0.0 mesh `r' Desilter Centrifuge Van 3 1/2" 8-112" Completion 8426' 7976' 6% KCl 8.55 3 $9,239 - Utilize all solids control equipment to minimize the buildup 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 includes the use of 2% Lubetex in the intermediate and production intervals. ~~: • • IFE Marathon Oil Company - Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. Estimated Product Usage Summary PRODUCT Surface 16" Intermediate 12-1/4" Production 8-1/2" Completion 3-1/2" Total Usage % of Total Cost M-I Bar 0 412 988 0 1400 4.48 M-I Gel 694 0 0 0 694 2.52 Gelex 29 0 0 0 29 0.15 Soda Ash 12 14 12 0 38 0.27 Caustic Soda 12 27 12 0 51 0.74 Conqor 404 0 6 4 0 10 5.36 Sodium Meta Bisulfate 23 27 12 5 67 1.86 Bicarb 12 14 12 0 38 0.27 Conqor 303 0 0 0 5 5 1.02 F1oVis 0 219 99 0 318 26.61 Desco CF 12 0 0 0 12 0.21 Polypac UL 12 110 49 0 171 11.38 Bioban BP Plus 0 27 99 0 126 1.18 KCl 0 1152 519 76 1747 9.33 Safecarb 0 1097 494 0 1591 12.89 Lubetex 0 44 20 0 64 19.95 Citric Acid 0 0 6 0 6 0.25 Defoam X 0 30 7 0 37 1.39 Engineer Service 5 10 7 3 25 ~~ • • Marathon Oil Company E Well Name: Cannery Loop Unit #10 ~~ Location: Kenai, Alaska. Offset Well Information Well Hale Size Depth PPG PV YP FL Comments CLU #7 16 123 8.7 24 28 14.2 Spud in, drill ahead 727 8.8 22 27 16.0 Drlg ahead 1684 9.0 17 24 11.6 DrUI ahead 1796 9.2 23 24 10.8 Drig to casing point, trip (clean stabilizer of clay), condition hole 12.25 2237 9.0 10 20 9.4 Drill out, displace to FloPro, Run LOT, drig ahead 3758 9.3 8 22 7.6 Drlg ahead, run centrifuge van for solids 4806 9.1 8 21 7.4 Drlg ahead, add Lubetex for directional work 4930 9.3 9 23 7.8 POH, chenge MWD, RIH tight 1920 - 2886' 5557 9.4 13 30 8.6 Drlg ahead 6123 9.3 15 27 8.2 Drig ahead, POH, test IiOP's 7015 9.4 19 31 7.6 RIH work tight spots.. drlg ahead 7780 9.5 15 29 8.8 Drlg to casing point, short trip OK 7 8406 9.5 9 24 6.2 Drlg out csign, displace to new mud, drig ahead 8924 9.4 10 25 6.6 Calcium concentration increasing, treat mud for bacteria, drlg ahead 9270 9.4 9 25 6.0 Drlg ahead 10034 9.4 10 35 6.8 Drlg ahead, POH for mud motor 10424 9.4 9 28 6.6 Dump & dilute to reduce solids after trip, drlg ahead 10864 9.8 10 28 6.2 Increase mud weight &lubetex concentration, drlg to TD, fog well, run liner, OK CLU #8 16 120 8.6 8 15 18.8 Spud in, drill ahead 1047 8.8 15 26 18.4 Drlg ahead 1821 9.2 8 23 11.8 Drlg to casing point, run surface casing 12.25 2814 9.1 6 22 10.2 Drlg out, displace to FloPro, Run LOT, drlg ahead 4818 9.2 7 20 8.4 Drlg ahead 6252 9.3 11 23 7.8 Drlg ahead, running 396 lubricant 6722 9.3 10 25 8.6 Drlg to casing point, Run 9-518" casing 8.5 6745 9 7 19 8.8 Drig out, displace to FloPro, drig ahead 7955 9.3 9 23 8.6 Drlg ahead, add lubetex to lower torque 8831 9.45 10 20 8.6 Drlg ahead 9777 9.95 12 27 8.8 Drlg to TD, weight up for gas, condition hole, log same, run tubing & cement same CLU #9 16 217 8.8 16 25 13.6 Spud in, drill ahead 1682 8.9 8 22 12.8 Drlg ahead, short trip OK, drig ahead 2063 9.25 9 21 9.2 Drig to casing point, run surtace casing 2063 9.2 7 20 10.4 No cment to surface, do top job. 12.25 2830 9.15 13 20 7.6 Drig out, LOT = 15.8 ppg, drig ahead 4575 9.1 7 19 7.2 Drig to 4006, short trip ok, drig ahead 5994 9.1 8 19 6.8 Drlg to csg point, wiper trip OK, POH run casing 8.5 6155 9.2 8 19 7.6 Drig out, L07, drig ahead. 7460 9.4 15 22 7.2 Drlg ahead, short trip OK, drlg ahead 8842 9.7 21 20 4.5 Drlg ahead, short trip OK, drlg ahead 9100 9.8 20 20 4.7 TD well, log, stuck wire4ine, 9100 10.3 21 23 4.7 Weight up due to gas, deanout run, run excape completion '~ • • '~ Marathon Oil Company Well Name: Cannery Loop Unit #10 _ 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 Stering C1 and Upper Beluga 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 between 6 - 8 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 . ~ LSRV - When drilling with a FloPro fluid, the low shear rate rheology should be maintained at approximately 30,000 cps. In addition to adequate additions of FloVis 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 7.5 ppb in the intermediate and production intervals 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 KCI 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 - Congor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Congor 404 concentration of +/- 2000 PPM. ~ CORRISION - Sodium Meta Bisulfate additions should be made daily as needed with any fluid in the hole. Maintain a DO reading of less than 3 ppm ~ 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. • • '~ Marathon Oil Company Well Name: Cannery Loop Unit #10 _ Location: Kenai, Alaska. Interval Summary -16" hole 0 -1922' Drilling. Fluid System Gel/Gelex 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 nterval Drilling Fluid Properties Depth Mud Funnel Yield API Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (sec./qt) (lb./100ftz) (ml/30min) (%) 0 - 1922' 8.6 - 9.4 60 - 100 25 - 35 NC - 12 +f- 9.5 < 7% - Treat drill water with Soda Ash to reduce hardness. - Build spud mud with 20 - 25 PPB M-I Gel to +/-.100 seconds/quart 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 of Polypac Supreme UL prior to running surface casing. - Add Sodium Meta Bisulfate to maintain a DO of < 3 PPM. - Condition mud prior to cementing casing to reduce yield point and gel strengths. - Estimated volume usage for interval - 2312 barrels. - Estimated haul off volume - 3823 barrels. ~~ ~ ~ • • '~ Marathon Oil Company Well Name: Cannery Loop Unit #10 _ Location: Kenai, Alaska. Interval Summary -12-1/4" hole 1922 - 5451' Drilling Fluid System Flo-Pro Fluid Key Products Flo-Vis / PolyPac Supreme UL / KCl / SafeCarb F & M / MI Bar / Caustic Soda / Conqor 404 /Sodium Meta Bisulfate / Lubetex 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 nterval Drilling Fluid Properties Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss MBT Solids (ft) ~pPg) ~cP•) (cPs) ~mU30min) ~%) 1922 - 5451' 9.0- < 9.5 8 - 12 30,000+ 7 - 9 < 7.5 +/- 5% - Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the enclosed fluid formula. - After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak off test - If running coals become a problem, treat with a 2 PPB addition of Asphasol D. - If torque or sliding problems occur, add 1 - 2%Lubetex. - NOTE: This fluid will be used in the production interval. It is inherent to maintain proper fluid properties for that purpose. - Estimated volume usage for interval - 2744 barrels. - Estimated haul off volume - 3087 barrels. - Condition mud prior to running 9-5/8" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. • Fluid Formula - • Marathon Oil Company Well Name: Cannery Loop Unit #l0 Location: Kenai, Alaska. 12-1/4" Interval 12-114" Interval from 1922 - 5451' Desa'i tion Mud Wei h# W ht Material Code W ht Material SG Canne Loo 9.1 - 9.2 MI Bar 4.2 In ut Unit #10 Prey ted Gel F'reh ted Gel Conc. KCI Wt% Out ut -1 bbl No 6 Order of Products Concentration Volume Product Addition Field Ib Lab, m field, bbl Lab, ml Usa a 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 Viscosit 4 Pol ac Su reme UL 2.00 2.00 0.004 1.25 Fluid Loss Control 5 Caustic Soda 0.50 0.50 0.001 0.23 H Control 6 Potassium Chloride 19.07 19.07 0.023 7.98 Inhibition 8a SafeCarb 10 10.00 10.00 0.010 3.60 Brid in A ent 8b SafeCarb 40 10.00 10.00 0.010 3.60 Brid in A ent 9 Sodium Meta Bisulfate 0.50 0.50 0.000 0.20 Ox en $caven er 10 As hasol Su reme 2.00 2.00 0.006 2.08 Wellbore Stabili If bit ballin becomes a roblem add the followin 11 D-D CWT 1.00 1.00 0.003 1.00 Reduce BHA Ballin If for ue becomes a roblem or slidin i s difficult add u to 3% of the followin 12 Lubetex 14.00 14.00 0.041 14.43 Lubricit Total 399 399 1.000 350 Calculated Mud Wei ht 9.500 F_stimated Volume Usa a 2744 Barrels Total Chloride 29600 ~~ • • ~~'~~ Marathon Oil Company Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. Bridging Formula -12-1/4" Interval /~ Operator: Marathon Oil Company laax Permeability 350 ir,oarcy IV~6NG4(+G C]PTIBRIDGET'" well Name: CLU#10 sanaconucioevice: i, - Location: Cannery Loop Unit j ~ 1009 - 2004 MJL.L.C. - atl RiOMS Reserved Comment9: Sterling C 1 Send II Opt/mum Bridging Ageni Blend o_ a N O N Ul d v A o. a, 7 E U Penick Size (microns) D10 • D50 • D90 010 Tmgat /Bland: 0.7 ! 1 A mierons D50 Target I Bland: 16.7 ! 75S mlcrom D90 Target !Blend: 60.6 I 727.3 microns Optimum Blend for 0 to 100 % CPS Ranpe &end Name BridpiDy AgiRMIbNbO Vol X B-Safa-Garb 10 (F) 10.7 53.38 D-Safe•Carb 40 (Y) 9.3 46.62 E-Safe-Garb 250 (C) 0.0 D.00 D .. ~ y.,..._ __~. 46.6X R 53.4° Simulation Accuracy Calcium Carbonate added : 20 Iblbbl Avg Error 0 - 100 X CPS Range : 3.50 X AAa^ Error 0. 100 X CPS Range : 17.01 X - Zone of interest -Sterling C-1 & Upper Beluga sands - Pore Pressure - 4.04 -Maximum Porosity - 350 mD - Measured Depth - +/- 5436' (4986' TVD) - Build additional volume as needed using the blend listed above. ~~ ~ . • • '~ Marathon Oil Company Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. Interval Summary - 8-1/2" hole 5451- 8426' Drilling Fluid System Flo-Pro Fluid Key Products Flo-Vis / Polypac Supreme UL / KCl / SafeCarb F & M / MI Bar / Caustic Soda / Congor 404 /Sodium Meta Bisulfate 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 nterval Drilling Fluid Properties Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss MBT Solids (ft) (ppg) (cp.) (cps) (mU3Dmn) (%) 5451 - 8426' 9.0 -10.0* 10 - 14 30,000+ 6 - 8 < 7.5 +/- 5% - Pre-treat drilling fluid with Bicarb and/or citric acid prior to drilling cement. Aggressively treat out cement contamination as soon as feasible. Build additional dilution volume to maintain proper specifications. - If running coals become a problem, treat with a 2 PPB addition of Asphasol Supreme. - Estimated additional volume for interval -1235 barrels. - Estimated haul off volume - 2601 barrels. - NOTE: Coal gas at the bottom of this interval (+/- 8818' MD) may require mud weights as high as 10.0 PPG to control. - Condition mud prior to running 3-1/2" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~ • IFE Marathon Oil Company Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. Dilution Formula - 8-1/2" Interval 8-/12" Interval from 5451 - 8426' Input Des 'lion Canne Loo Unit #10 Mud Wei ht 9.0 -10.0 Preh rated Ge! No Wei ht Materia! Code MI BaR Prett rated Gel Conc. We ht Material SG 4.2 KCI Wt% 6 Order of Products .Concentration Volume ProducR Addition Field Ib Lab, m Field, bbl Lab ml Usa e 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 2.00 2.00 0.005 1.34 Viscosit 4 Pol ac Su reme UL 2.00 2.00 0.004 1.33 Fluid Loss Control 5a SafeCarb 10 15.00 22.50 0.017 5.67 Brid in A ent 5b SafeCarb 40 5.00 7.50 0.006 1.89 Brid in A ent 6 Potassium Chloride 20.76 20.76 0.025 8.68 Inhibition 7 CONQOR 404 2.00 2.00 0.004 1.43 Corrosion Control 8 Caustic Soda 0.50 0.50 0.001 0.23 H Control 9 Sodium Meta Bisulfate 0.50 0.25 0.001 0.25 Ox en Scaven er If slidin or hi h for ue becomes a roblem add 1 - 2% of the followin 10 Lubetex 7.00 7.00 0.021 7.00 Lubricit If sloughing coals become a roblem add 2 - 4 b of the followin 11 As hasol Su reme 2.00 2.00 0.004 1.33 Wellbore Stabilit Mix fluid in the order listed above. ~ 380.1 fated Mud Weight Chloride 380.1 9.050 29600 1 • • ~ IFE Marathon Oil Company Well Name: Cannery Loop Unit #10 _ Location: Kenai, Alaska. Interval Summary -Completion Procedures Corrosion Control Additive in Casing x Tubing Annulus Well Cannery Loop #10 Volumes: Tubing Volume 3-1/2" Tubing 73.30 barrels Annular Volume Casing x Tubing 334.32 barrels 3.50 x 2.992 x 8426 ft - ~ 9.625 x 8.681 @ 5451 ft M D ~, 8.500 x 3.50 @ 8426 ft MD Treatment Procedures. Open Hole x Tbg 120.23 barrels Total Annular Volume 454.55 Tubing Volume 73.30 Total Hole Volume 527.85 1. After the 3-1/2" tubing is run and the drilling fluid is circulated and conditioned for the cement job, circulate an additional 454 barrels of drilling fluid. 2. Add 1 drum of Conqor 303A and 1 sack of Sodium Meta Bisulfate for each 90 barrels of drilling fluid pumped (5 drums 8~ 5 sacks total) 3. After the 454 barrels of drilling fluid with corrosion inhibitors have been pumped downhole, begin the cement job. 4. This procedure will place corrosion control in the 3-1/2" x 9-5/8" annulus. ~~ ~~ • • IFE Marathon Oil Company Well Name: Cannery Loop Unit #10 _ 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. f -r • • _ Marathon Oil Company _= IFE Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS Product Function Health Flammability Reactivity PPE M-I BAR Weighting Agent *1 0 0 E M-I GEL Viscosity control *1 1 0 E GELEX Bentonite Extender 1 1 0 ° E FLOVIS Viscosifier 1 1 0 E DUAL-FLO Modified Starch 1 1 0 E POLYPAC Fluid Loss Reducer *1 1 0 E XCD Viscosifyer 1 1 0 E HEC Loss Circulation Material 1 1 0 E Safe-Garb F,M,C Bridging and weighting agent *1 0 0 E LO WATE Weighting agent *1 0 0 E Nut Plug Loss Circulation Material *1 1 0 E M-I Seal F, M, C Loss circulation Material *1 1 0 E Mix II F,M,C Loss circulation Material *1 1 - 0 E DESCO CF Dispersant 1 1 '' 0 E SPERSENE CF Dispersant 1 1 0 E TANNATHIN Dispersant 1 1 0 E VENTROL 401 Surfactant ? ? ? ? SALT (Solar) Densifier 1 0 0 E BROMIDE (Naar) & Brine Solution Densifier 1 0 0 F POTASSIUM CHLORIDE - Shale Inhibitor 1 0 E ~~ • • Marathon Oil Company IFE Well Name: Cannery Loop Unit #10 _ Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS Product Function Health Flammability Reactivity PPE CAUSTIC SODA Ikalinity control 3 0 1 X CAUSTIC POTASH pH Modifier 3 0 X BORAX Inorganic Borate 1 0 0 E SAPP Sodium Pyrophosphate *1 0 0 E SODA ASH Ikalinity control 1 1 0 E SODIUM BICARBONATE Ikalinity control 1 0 0 E CITRIC ACID pH Adjuster 1 0 0 E BIOBAN BP-PLUS Biocide *2 0 0 J GREEN CIDE 25G - Biocide 3 0 0 J DEFOAM X- Defoamer 1 1 0 J G-SEAL Sized graphite LCM 1 1 0 E KLA-GARD Shale Control agent 0 1 d J LUBE TEX Lubricant 1 1 0 J D-D CWT Detergent 2 1 0 J Concor 404 Corrosion Inhibitor 1 1 0 J SAFEKLEEN Drilling fluid additive 1 1 0 J sphasol D Shale Inhibitor 1 1 - 0 J Soltex Shale Inhibitor 1 1 0 J odium Meta Bisulfate Oxygen Scavenger 1 1 ~~.::.r.. ,_ J ~~ • • '~ Marathon Oil Company Well Name: Cannery Loop Unit #10 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 -Severe hazard 3 -Serious hazard 2 -Moderate hazard 1-Slight hazard 0 -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 ~~ • • '~ Marathon Oil Company Well Name: Cannery Loop Unit #10 _ Location: Kenai, Alaska.. Contacts Contact Title a-mail Work Cellular Pete Berga Drilling pkberga@marathonoil.com 907 565-3032 907 231-0663 Marathon Superintendent Will Tank Drilling Engineer wjtank@marathonoil.com 713 296-3273 713 203-8398 Marathon Tony Tykalsky Project Engineer ttykalsky@miswaco.com 907 274-5011 907 227-2412 ML SWACO Richard Couey Warehouse Manager rcouey@miswaco.com 907 776-8680 907 252-4218 MI SWACO Michael Barry Senior Field gratefulmen@hotmail.com 907 260-4666 907 590-3636 MI SWACO Engineer (home) Locke Rooney Field Engineer rooneyl@alaska.net 907 235-0598 907 590-3636 MI SWACO (home) Roland Lawson / Drilling Foremen 907 283-1312 Larry Myers /Dave Morris Marathon Responsibilities - MI Project Engineer and will coordinate daily 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. - Field Engineers will monitor and supervise product inventory to include re-palletizing any products for shipment to other locations at the end of the well. - Field Engineers will communicate with office personnel (Marathon & MI SWACO) for approval of any changes in the mud program (including introduction of new products). - Field Engineers will produce a recap at the end of the well based on daily activities. Recap should include any lessons learned that may be used to provide better service on future wells. Lessons learned can include changes in procedures, product additions, equipment usage, and/or utilization of any third party service. ~i Check No Check Date Bank .Bank No vendor Marathon Oil Company ~ °ccou Hndig P O Box 22164 NTS PAYABLE DEPARTMENT 1181799 07/07/2005 NCBAS 7780 5001123 . . Tulsa, oK 7at2t-2t 64 Accts Payable Contact Center HS Phone 918-925-6D97 '. Invgice Number Invoice6Date Document No RemiY.~`ammQnf GrossAmount Discount Invoieetpay Amount, x' L100.00 07/07/2005 1900033852 100.00 100.0 TOTAL: 100.00 100.0 E ~ ~ ~` a '~' ~, ~~n ~ ~ ~U . s,s~~ (rVLU Vrv YtrlrVrlA 1 IVN CELUVV ANU Ut I AGti (:FiEC:K STUB IiEFOHE DEPOSITING) __ 7FM2501 REVS/00 ~ -~~---- 7780 ACCOUNTS PAYABLE CHECKr ~; Marathon Oil Company. 56-389`4'2 Cf9~CKDAT~ ECI(NUMB P. O. Box 22164 `'" ep Tulsa OK 74121 2164 :07/07/2005 ;!, llf~1,799i '/OID AFTEn 1~~ ~,;,,,~ n Representatl ;, ,: NATIONAL CITY BANK ~ ~.; hfe hunched and tiQ/2Q0'}~ol[ar~ Ashland,Ohio ~~ ~ ~ ~ ~~ ,. ,. ~ ~; ~~ _ .__ 3 ~0 0 ,, s ~ -~• i~'000 L ~8 L 799ii' x:04 L 20 389 5~: 0 L8 3484ii• • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTEZR WELL NAME f ~ ~,/t~ PTD# 2.. a6~-/d ~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (p)[~ records, -data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) _assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KENAI, C.L.U. BELUGA GAS - 448575 Well Name: CANNERY LOOP UNIT 10 Program DEV _ Well bore seg ^ PTD#:2051060 Company MARATHON OIL CO .Initial ClasslType DEV / 1-GAS GeoArea Unit On/off Shore On Annular Disposal ^ Administration 1 Permit-fee attached- - - - Yes _ _ - - _ . -- - - 2 Lease number appropriaie_ - - - _ Yes This well will_be drilled on fee.acerage within the Cannery loop Unit of the_Kenai Feld 3 Unique well-name and number__--________________________ ___-.___Yes- ____ --____-__, ----------------------------------------------------------- 4 Well located in a.defined_pool- Yes - - - - - - 5 Well locatedproperdistancefromdrillingunit_boundary_ ____________ _________Yes- _____ .____--__-_____--______-.--__---_...---_____..-_-___-..__- -.-.-_ 6 Well located properdistance_fromothe-r wells_____________________ _________Yes_ ___-- ,-____ __.______ ._---____--_--____-_--__-_____-..._.____.-.____.. 7 Sufficient acreageayail_ablein.drillingunit_______________________ _______.Yes- ____ .---_____-__--__-____-_____ ---------------------------------------- 8 Ifdeyiated,is_wehboreplat_included __--___-- ------------- ---------Yes- ____ _-__---________--_________-__________ 9 OpeCator only affected party - - - - - - - - - - Yes -------------------------------------- - - - - 10 Operakorhasappropriake_bondinfQrce--------- -- ------- -- -------- Yes- ----- - -- ----------- - --- ------ -- --- ---------- -- ------- --- 11 Pecmit_canbeissuedwithoutconservationorder__________________ _________Yes- _____ ---_-._ -------------------------------------------------------------- Appr Date 12 Permit_canbeissuedwithoutadministr-ative_appr_oyal-_____________ ___--__-Yes_ _____ ___________________-__-_____--______..-______-..-.-.____-..-_--_. RPC 7N 1!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strataauthprizedbylnjection9rder#(putl9#in_comments)-(FQr-NA- ___-. -.__--__--------------------------------------_.... __-___-..-_-_ 15 All wells within114_mileareaofreyiewjdentified(Forservicewe//only)______ _________ NA _ __-__ _________.________--_______---_______- 16 Pre-produced injector; duration of preproductionl_essthan3months(Forservicewellonly)-. NA__ _____ __________________--_________--_--__._--______ ----___-___--__-___ 17 ACMP-Finding of Consistency_hasbeenissued_forthisproject___________ _________ NA_- _____ __--_--________--_____-__________--________--_______-__.__--_-.._ Engineering 18 Conductor string_p_rovided___ ____________________________ _________Yes- -__- _20"r7x123'._-______-.__-______-______---_.______-._. -------------------- 19 Su_rfacecasing_protectsallkngwnUSDWs-----------.-------- --,- ----Yes- ----- ------------------------------,--------------- -- -- --------------- 20 CMT_voladequate-tocircul_ate-onconductor-&surf_csg______________ _________Yes_ _____ _Adequateexcess,--________-_______--.___ __--__________ ----____ -..__ 21 CMT_vok adequate_to tie-in long string tosurf csg - - N0 - - - - - 22 CMTwillcoyerallknow_n_productiyehorizons-____-..__________ __ ______Yes_ ___-- -____ - - 23 Casing designs adequate forC,T,B&-permafr_ost------------------ ---------Yes- ----- --------------------------------------.----------.-----------.-- --- 24 Adequate tankage-or reserve pit___ _____________________-_ _______-Yes_ _____ _GlacierRig1._-_-.______ -_-______--__.-__ __________ -__-.__-_________ 25 If-a-re-drill,has-x10-403 forabandon_mentbeenapp.roved_____________ _________ NA__ -__-- _Newwell:--_______-.-________--________-_______----.___ __-__- ____-- 26 Adequatewellboreseparationproposed --- - ---- -- - ----- -- -- -_ Yes ---- -- ----- - ----- -- - - --------- --- --- -- --- 27 If_diverterrequired,doesitmeet-regulations___________________-- ______---Yes_ ___-. ______-_----______-_-._ Appr Date 28 Drillingfluid_prcgramschematic&equiplistadequate________________ ___ _____Yes_ ___-. -Max MW-10:0_ppg.___----.____--____..---__--_-..--..__--__.------ WGA 7/1212005 29 BOPEs,-do they meet regulation___________________________ __--__ Yes- -____ __.-_________- __- ____-- -- 30 _B_OPE-pressrafingappropriate;testto_(putpsigincomments)-_________ _________Yes_ ____. _Testt_o2500psi.-MSP1931psi._-__-_____-__---__-__________ -.---______----__ 31 Choke_manifoldcomplieswlAPI_RP-53 (May 84)______--_______-_ ___ __---Yes_ ____ _______ __________ 32 Work willoccurwithoutoperationshutdown_____________________ -____Yes __ --- ___ - - 33 Is presence-of H2S gas probable - - - NO - - - - - - - - - 34 Mechanical condition of wells within AOR verified (For-service well onlya - - _ _ NA_ _ - - _ - - - ------------------------------------------------- Geology 35 Permitcanbeissuedw/ohydrogensulfidemeasures________________ _________Yes_ _-_- -______---________--_--_____---_____ _--_______ __---_-___________ _ 36 Data_presentedonpotentialoverpressurezones-_________--______ __ NA-_ _____ --______________________________________-___.___ ___-_--_______-- Appr Date 37 Seismic analysis-of shallow gas.zones------------------------ ------ - NA-- ---- ------ --- --- ------------------------------------_-..------ ----- RPC 7!11!2005 38 Seabed condition survey_(if off-shore) - - - - - --- - - - - - - - - NA - 39 Contact namelphon_e_for_weeklypvogress-reports (exploratory on NA_ Geologic Commissioner: Engineering Date: Commissioner: Date ss ner D e (' ~ ~ ~Q~ `~ r ` ~~ ~,.~