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202-257
• • RECEIVED STATE OF ALASKA MAY 26 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AI ' Oc 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ • Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑� GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 4/6/2017 ' • 202-257/316-641 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Ste 1400,Anchorage,AK 99503 10/14/2003 - 50-133-20520-60-"X.) A,u-y.it. 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 520'FSL&1340'FWL Sec.28 T3N R12W,SM 12/28/2003 ' Kasilof South 1L1 ., Top of Productive Interval: 9. Ref Elevations: KB: 104' • 17. Field/Pool(s): GL: 74' • BF: Kasilof/Tyonek Undefined Gas • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:ADL-0384529, • 2230'FSL&4382'FEL Sec. 19 T3N R12W,SM • 17,543'MD/9,885'TVD • A.37,ADL-0391591,FEE-Hilcorp,ADL-0391246 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land U e�Perr t: Surface: x- 250209' y- 2310138 • Zone- 4 • 17,665'MD/9,999'TVD • N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 239256 y- 2317357 Zone- 4 N/A; N/A N/A 5. Directional or Inclination Survey: Yes ❑(attached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,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 if necessary N/A SCANNED NOV 0 3201Z 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' 130' 0' 130' Driven N/A 13-3/8" 68# K-55 0' 2860' 0' 2383' 16" in place,750 sx N/A 9-5/8" 40#&47# L-80 0' 1851' 0' 1541' 12-1/4" in place,2200 sx N/A 7" 29# L-80 9916' 10533' 0' 3397' 12-1/4" Cemented with 9-5/8"csg. N/A 3-1/2" 9.2# L-80 9918' 17644' 5187' 9980' 6-1/8" in place,700 sx N/A 24.Open to production or injection? Yes ❑ No Q • 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 9918' 10,909'MD/5,161'TVD PtiANDrN ) 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. u /4�f Was hydraulic fracturing used during completion? Yes 111 No 2 • • Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A 24-Hour Rate Form 10-407 Revised 11/2015re-�j CONTINUED ON PAG RBDMS w I�1 E�2 17 Submit ORIGINIAL onl 1 is(�-( 7 ge 0.07///� H1 J 0 �OI/ .4A tJ '7 - r/7 V • 28.CORE DATA Conventional Core(s): Yes ❑ No • Sidewall Cores: Yes ❑ No ❑., • If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q • Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. N/A N/A Formation at total depth: 31. List of Attachments: Operations Summary, Schematic,MIT-IA, Photo document casing cut-off/cment top/welded plate. Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Taylor Nasse-777-8354 Email: tnasse((]�hllcorp.Com Printed Name: Chad Helgeson Title: Operations Manager Signature: 1/:,-1/40— Phone: 777-8405 Date: 5124,11 7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records 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 interval to be separately produced, showing the data pertinent to such interval). 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. 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. 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. Item 31: 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. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • Cit Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1L1 E-Line 50-133-20520-60 202-257 1/8/17 4/6/17 Daily Operations: 01/08/2017 -Sunday PTW and JSA. Spot equip and rig up lubricator on the KS-1L1. PT to 250 psi low and 2,500 psi high. RIH with 2.75" CIBP with 3 roller bogies and could not see perfs. Found 2" log in 0-drive and used it to tie into. Ran a correlation log and send to town. Got the ok to set plug at 16,400'. Set plug with 2,020 psi on tubing. Lost 200 lbs line wt when set. Pick up 30' and went back down and tagged. POOH. Setting tool looked good. SDFN. Secure well. 01/09/2017- Monday PTW and JSA. Rig up lubricator on the KS-1. PT to 250 psi low and 2,500 psi high.TP - 700, CP- 1,850 psi. RIH with 2.75" CIBP with 3 roller bogies and could not see perfs. Used a short joint 16,776' to tie into. Ran a correlation log and send to town. Got the ok to set plug at 16,950'. Set plug with 700 psi on tubing. Lost 200 lbs line wt when set. Pick up 30' and went back down and tagged. POOH. Setting tool looked good. SDFN. Got cement in and will start early in AM to get 4 cement runs in. 01/10/2017-Tuesday PTW and JSA. Rig up lubricator on the KS-1. PT to 250 psi low and 2,500 psi high. TP-700, CP - 1,850 psi. Make 2 runs (KS-#1) with 2-1/2" x 20' cement dump bailer and dump cement on top of plug at 16,950' (25' of cement). Est TOC is 16,925'. Cement in place at 1105 hrs. POOH. Good dumps on both. Had tight spot at 9,935'. Had to work thru it. Saw no fluid level. Make 2 runs (KS-1/L1) with 2-1/2" x 20' cement dump bailer and dump cement on top of plug at 16,400' (25' of cement). Est TOC is 16,375'. Cement in place at 1635 hrs. POOH. Good dumps on both. Had tight spot at 9,853' and 10,333' coming out of hole. Had to work thru it. Saw FL at 7500'. Rig down lubricator and WOC. 01/15/2017 -Sunday PTW and JSA. Warming equipment up and rigging up lubricator on KS-1/L1. PT to 250 psi low and 2,500 psi high. RIH with 1-11/16" tubing punch (10 shots) and tie into Pollard Plug setting log.Tag TOC at 16,371' (est TOC 16,375'). Get ok to tubing punch at+/- 3,200'. POOH to Chem injection nipple at 2,544' per schematic. Spot shot from 3,208' to 3,210'. (Have a collar at 3,201'). Bleed pressure off casing. Fired punch and gained 750 psi on casing and lost 100 psi on tubing from 1,800 to 1,700. POOH and swapping to KS-1. Swap over to KS-1 side. RIH with 1-11/16" tubing punch (10 shots) and tie into Pollard Plug setting log. Tag TOC at 16,925' (est TOC 16,925'). Get ok to tubing punch at+/- 3,200'. POOH to Chem injection nipple at 2,540' per schematic for tie in. Spotted shot and fired punch from 3,208' to 3,210' with 650 psi on tubing lost 100 psi.The collar was at 3,201'just like 1/L1. We bled pressure off casing to 100 psi before firing. Rig down lub and secure well. Will fill tubing in AM. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1L1 E-Line 50-133-20520-60 202-257 1/8/17 4/6/17 Daily Operations: 01/16/2017 - Monday PTW and JSA. Bleeding pressure off well. Spot Pollard pump truck and rig up. Hook vac truck up to Pollard pump truck and start pumping fluid. Got approx. 40 bbl away out of 80 bbl and Y screen on pump truck stopped up. Cleaned screen and screen plugged right back up with rocks, sticks and real thick mud. Send vac truck back to KGF to clean out and pick up another load of fluid. Wait on vac truck. Drain hoses on pump truck. Vac truck arrives and hook up to Pollard pump truck. Found pump truck froze up somewhere inside. Put heater hose on tank to thaw out. Pumped 90 bbl with 60 bbl at 1 bpm and 30 bbl at .5 bpm down casing while venting from both sides of tubing while vac truck went to get another load at Falls Creek. Start pumping at 1 bpm at 250 psi and with 160 bbls away got fluid back from both tubing sides. Pickled pump truck and secure well. Will see if we get any fluid swap in morning. 01/17/2017 -Tuesday PTW and JSA. Hook test pump up to KS-1 and pump 25 gal methanol down tubing to freeze protect. Pump 40 gal down KS-1/1L1 to freeze protect. Bleed casing from 500 psi to 250 psi. Got gas back. Got vac truck out with 80 bbls. Start pumping down casing until pressure reached 1,750 psi. Stop pumping (40 bbls)for test and pressure started bleeding off. Went to 997 in 20 min. Found a small leak on needle valve. Pump casing back up to 1750 psi (30 bbls) and still bled off. Found tubing flange was leaking. Greased ring and retighten flange. Pump truck froze up again while doing that. Put heater on pump truck tank and thawed it out. Pickled pump truck with methanol. Secured well. 01/19/2017-Thursday RDMO Pollard EL and pump truck. Mobe Moncla 401 from Swanson River. Removed snow from pad and offloaded equipment. Laid felt and containment for rig. Spotted beam and WOR. Placed heaters for wellhead and WOR. SDFN. Night watch on tower. 01/20/2017 - Friday Held PJSM. Discussed daily activities. Swept and shoveled snow from containment. Continued off loading equipment for trailers. Spotted choke house, pit, gas buster and pump. MU circulating lines to same. Received dual handling tool from Weatherford. Spotted heaters, generator, Koomey unit and pusher shack. Ran heater ducts to equipment. Installed winterization for the carrier and pits. Off loaded BOP'S. Covered and heated same. SDFN. Night watch on tower. 01/21/2017-Saturday Held PJSM, discussed daily OPS, cont RU winterization for Moncla 401. Connected circulating lines from manifold to the wellhead. Offloaded 80bbls of produced water in rig pit. SITP/SICP 50psi. Bled off pressure to gas buster. Lined up manifold to pump down the csg returns up both tbg strings. Started pumping 4 bpm and broke circulation after pumping 40bbls. Continued circulating 250bbls and SD pump. Monitored well static. SI both tbg string and pressured up on cement plugs to 1,750psi. SD pump and charted, 5 mins pressure bled off 550psi with no leaks at surface. Made several attempts and couldn't get a good test. Discussed problem with ops engineer. Disconnected circulating lines from wellhead. Set BPV's and ND the production tree and inspected both lifting threads and plugged off control lines. SDFN. Night watch on tower. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date • Kasilof South 1L1 E-Line 50-133-20520-60 202-257 1/8/17 4/6/17 Daily Operations: 01/22/2017 -Sunday Held PJSM and discussed daily ops with rig crew. NU 13" 5M BOP's from bottom to top drilling spool, 13" 5m double gate (blinds on bottom and 2-7/8"-5" VBR's on top), 13" 5m single with 3-1/2" dual ram and 13" 5m annular preventer. Continued winterization for rig equipment. MU ck/kill lines from stack to manifolds. RU floor, windwalls and stairs. Laid out control lines from Koomey to BOP stack. Built winterization around BOP stack and continued winterization for rig equipment. SDFN. Night watch on tower. 01/23/2017- Monday Held PJSM. Connected the hydraulic hoses from BOP stack to the Koomey unit. Function tested BOP's. Finished winterization. Loaded pit with 80 bbls PW. Flooded manifold, ck/kill lines and BOP stack. MU the 3-1/2" test jts. Circulated BOPE for 5 mins. Performed the shell test and charted. 250-2,500psi, good test. Notified the AOGCC and witness waived by Jim Regg. Performed BOPE test per AOGCC reg as follows: gas detection, annular 250-2,500psi, rams 250-2,500psi, valves 250-2,500psi and Koomey drawdown test. 1 F/P on Koomey unit, cleaned filters and retested good. Tested with 2-7/8" and 3-1/2" test joints. BOPE test completed. 24 hour witness notification given 1/21/16 @ 17:36hrs. 01/24/2017 -Tuesday Held PJSM, discussed daily ops. Pulled BPV from #1L1. MU landing jt. MIRU SL. MU 3-1/2" AD-2 Stop and RIH and set @ 3,315'. POOH. PU/MU 2-1/2" SB w/W-plug and RIH set plug @ 3,315'. POOH. Lined up manifold to pump down the csg, pumped 3bbls and pressured up to 1,750psi and leaked off to 1,100psi in 5 mins. Made several attempts w/ no test. BO/LD landing jt from #1L1 and set a BPV. MU landing jt on #1 and RU lubricator, MU 3-1/2" AD2 Stop and RIH and set @ 3,350'. POOH. PU/MU 2-1/2" SB w/w-plug and set down @ 3,208'. Worked thru tbg punch and cont to 3,350'. Worked plug and couldn't shear off plug. RIH w/same to 3,350' and set plug but couldn't shear off. Stayed latched while testing. Closed Hydril, lined up manifold to pump down the csg, pumped 3bbls and pressured up to 1,750psi and leaked off to 1,100psi in 5 mins. Made several attempts w/ no test. POOH with SL. Lost plug at 2,576', the SB unlatched while POOH. LD SL for night. SDFN. Night watch on tower. 01/25/2017-Wednesday Held PJSM RD SL on KS#1. RIH w/2-1/2"JDC to 3,208'. Set down and latched W circulating plug and POOH w/ plug, LD same. RIH 3-1/2" GS to 3,350' latched AD2 stop, 1 jar lick and pulled free. POOH w/AD2 stop and LD same. Moved to KS#1L1. RIH w/2-1/2"JDC to 3,315'. Set down and latched W circulating plug, 3 jar licks and POOH w/ plug, LD same. RIH 3-1/2" GS to 3,315' latched AD2 stop and POOH w/same. RDMO SL. Discussed plan with Ops Engineer. Stand-by for EL to arrive. Serviced rig and removed snow from containment. MIRU EL on #1, MU CCL and setting tool and 2.75" CIBP. RIH, correlated with SLB perf log and set CIBP @ 9,900' between the liner top and pkr. POOH. LD Set tool and redressed for second run. RU EL on #1L1. RIH w/2.75" CIBP. RIH, correlated with SLB perf log and set CIBP @ 9,890' (below pkr). POOH. LD EL. BO/LD landing jt. Closed blinds and lined manifold to pump down the csg. Started pump and pressured up 1,800psi. Pressure bled off to 1,300psi in mins. Bled off to pit. Secured well and SDFN. Night watch on tower. S Hilcorp Alaska, LLC f ' Well Operations Summary Y Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1L1 E-Line 50-133-20520-60 202-257 1/8/17 4/6/17 Daily Operations: 01/26/2017 -Thursday Held PJSM, discussed daily ops. RU Weather dual handling tools. PU/MU 3-1/2" landing joint for both tbg strings. Opened csg and BOLDS. Latched landing joints and PU on the completion strings, unseated hanger at 70K, continued pulling to 150K and set both stings in the slip. RU EL on #1 string. RIH w/chemical cutter to pkr at 9,853' and logged up to cut depth and cut tbg @ 9,405' (middle of a joint). After, cut pipe, moved 4' up hole. POOH. RU EL on #1L1 string. RIH w/chemical cutter to pkr at 9,853' and loaded up to cut depth and cut tbg @ 9,435' (middle of a joint). After, cut pipe, moved 4' up hole. POOH. RDMO EL. Pulled hanger to surface w/dual string weight 105K. Serviced hanger and disconnected control lines. RU Tongs and power pack. BO/LD Landing jts and dual hanger. Secured well and SDFN. Night watch on tower. 01/27/2017 - Friday Held PJSM, discussed daily activities TOH L/D the dual completion string and control lines. Removing Canon clamp on both string every other jt. Cut control line in 30' section for scrape. Sting weight off bottom was 105K. Completion started dragging while 25K over pulls after 100'joint OOH. All clamps accounted for. Secured control lines and set pipe in the slips. Closed dual pipe rams. SDFN. Night watch on tower. 01/28/2017-Saturday Held PJSM, continued TOH w/dual completion string dragging 25K over to chemical injection subs, had to work tbg several times to get the twist out. L/D chemical injection subs.Tbg pulling free after getting the subs OOH. RD Weatherfords dual elevators and RU 3-1/2" YT elevators. Secure#1 string in slips with the safety clamp. Latched #1L1 string and TOH. No issues pulling string. L/D 220 joints. Secured well and SDFN. 01/29/2017-Sunday Held PJSM, performed well control drill with crew. Continued TOH with #1L1 3-1/2" completion string. L/D 89 jts and 1 cut joint. RD Weatherfords dual slips and control panel. RU Moncla's slips. Latched #1 and TOH L/D 157 joints of 3-1/2" #9.3 Hydril 533. Leaving 70 joints in the hole (weight 19K for RTTS). RD 3-1/2" YT elevators and RU 2-7/8" MYT elevators. Prep rig to RIH. PU/MU RTTS and tallied, racked and tallied 107 joints of 2-7/8" 7.9# P110 PH6.TIH w/RTTS and 50 joints of 2-7/8" PH6 to 1,500'. MU TIW and set pipe in slips and closed in pipe rams. SDFN. Night watch on tower. 01/30/2017- Monday Held PJSM and discussed daily activities. Prep rig to TIH, continue TIH w/ RTTS and 57 joints of 2-7/8" PH6 to 3,307'. Lined up manifold and filled well with 35 bbls of PW. Set RTTS @ 3,307' and pressure up on the csg to 1,800psi-bled off to 1,000psi in 5mins. Swapped pump to tbg side and pressured to 1,850psi (below RTTS), held and charted for 30mins, good test. Bled off pressure. Released RTTS. Prep rig to pull workstring.TOH w/53 stands 2-7/8" PH6. BO/LD 9- 5/8" RTTS. RD 2-7/8" MYT elevators and RU 3-1/2" YT elevators. TOH LD 69 joints and 1 cut joint of 3-1/2" 9.3# Hydril 533. Cleaned and cleared rig floor. Organized rig and inventoried. Secured well and SDFN. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1L1 E-Line 50-133-20520-60 202-257 1/8/17 4/6/17 Daily Operations: 01/31/2017-Tuesday Held PJSM and discussed daily activities. PU/MU test equipment, MU test plug, 2-7/8" test jt, TIW and I-BOP. Flooded BOPE equipment and circulated the air out. Performed shell test 250-2,500psi, good test. Contacted AOGCC Rep and waited for arrival. Performed BOPE Test Per AOGCC Reg as follows: gas detection, annular 250-2,500psi, rams 250- 2,500psi, valves 250-2,500psi and Koomey drawdown test. 1 F/P on Koomey unit, cleaned filters and retested good. Tested with 2-7/8" and 3-1/2" test joints. BOPE test completed. 2 F/P were recorded, flange leak on annular preventer and flange leak on kill line.Tightened and retested good. AOGCC Witness by Jeff Jones. Replaced kill line hose due to bend radius. Shell tested done 250-2,500psi, good test. MIRU EL, MU 9-5/8" CIBP and CCL, RIH and tagged cut joint at 9,405' PU to 9,393' and set CIBP. POOH. RDMO EL. Secured well and SDFN. 02/01/2017 -Wednesday Held PJSM and discussed daily activities. PU/MU 9-5/8" CIBP and TIH with 2-7/8" PH6 workstring. Set CIBP at 3,293' KB.Tagged CIBP to confirm set. PU to 3,270', L/D a single and set slips. MIRU SLB cement unit. Ran hardline to rig floor and MU to 2-7/8" workstring. Offloaded 30bbls of FW in Pollards hot oil unit. Heated water to 75degF. PJSM. Pumped water to cement unit and primed up cement pump. Pumped 18.8bbls FW spacer. SD and PT lines 2,000psi. Batched up cement @ 15.8ppg. Started pumping cement down tbg @ 3bpm and pumped away 42bbl. Slowed pump down to 2bpm and pump 11bbI displacement away. SD. RDMO SLB TOH L/D 30 joints. MU Kelly hose to workstring and rev circulated 20 bbls to cleanup tbg. Continued TOH L/D 79 joints and the setting tool. Secured well and SDFN. Night watch on tower. 02/02/2017 -Thursday Held PJSM. MIRU SL and waited on State Inspector Jeff Jones to arrive on location. RDMO SL due to AOGCC Inspector requested TOC to be tagged with pipe. PU/MU 2-7/8" mule shoe and TIH on 2-7/8" PH6 workstring. With State Inspector witness tagged TOC w/8k down @ 2,753' KB. PU and L/D 1 joint down. Closed pipe rams. MU TIW and Kelly hose. Started pumping and broke circulation. Pressured up on csg to 1,500psi. Charted for 30mins, good test. Bled off pressure. RU Kelly hose and TIW valve.TOH with 92jts of 2-7/8" PH6 worksting. PU/MU 9-5/8" CIBP.TIH w/same on 2- 7/8" workstring and set CIBP at 150' below ground level. Released setting tool and tag plug to confirm set.TOH, LD worksting and setting tool. Closed blind ram and pressured up on CIBP to 1,500psi. Charted for 30mins, good test. Bled off pressure. SDFN. Night watch on tower. 02/03/2017 - Friday Held PJSM, discussed daily ops. Cleaned and cleared floor. RD the windwalls, stairwell and rig floor. Disconnected kill/ck line and hydraulic control lines from BOP stack. ND the 13-5/8" BOP Stack. PU 4 joints of 1-1/2" 10RD pipe and RIH to 128'. Hung string off at the tbg head leaving 2' stump for cementing. RDMO Moncla 401 and associated equipment. MOBE Moncla 401 to Greystone 1. 02/06/2017 - Monday MIRU cementers, begin mixing cement. Pump 13 bbls of cement into well.Verify cement is to surface. RDMO cementers. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1L1 E-Line 50-133-20520-60 202-257 1/8/17 4/6/17 Daily Operations: 02/09/2017 -Thursday 2/9/17 -Conducted PJSM, filled out permits, discussed project and hazards with cutting off wellhead. Notified Lou Grimaldi with AOGCC that would be cutting wellhead off around 10AM. He said to start and would inspect work when he arrived. Entered cellar and started cutting off the wellhead. Surface conductor was cut and removed. Started cutting into the 13-3/8" surface casing and when the pipe was penetrated, a small amount of gas released through a 1/2" hole. The gas ignited from the cutting operation with a small flame. Communicated with engineers and safety team, the situation, and let the flame self extinguish. Lou Grimaldi onsite to witness flame before it self extinguished after burning for 20-30 minutes. No injuries or damage due to release. Monitored casing, no flow from hole. Removed casing valve flanges to inspect valves,valves were plugged. Secured area and SDFN. 02/10/2017 - Friday Held pre-job review and filed permit required, confined space entry permit and hot work permits before starting work. Connected hoses to casing valves and pressured up from casing valve to 500psi and saw no communication with the hole below casing valve. The seal at the intermediate casing hanger leaked from the 13-3/8" to the 9-5/8" intermediate, so could not pressure up to more than 100 psi after seal started leaking. Flowed water across the top of the casing to a tank. Welder installed weldolet over hole on 13-3/8". Installed valve and gauge to monitor. Ambient temps 0 to 10 deg F. Communicated with engineers and AOGCC plans forward with the well secure to wait until warmer weather to complete water pump operations and testing casing. Secured well and SDFN. 02/11/2017 -Saturday Checked well status, looked secure, no leaks 02/14/2017 -Tuesday Indirect heater in cellar heating wellhead overnight with tarp over cellar. Wellhead warm and pumped 150 gal into o- let below casing valves. Did not pressure up. SDFN to get more water. Left heat on wellhead. 02/15/2017 -Wednesday Fill PC X SC annulus up with fresh water from vacuum truck. Pump and bleed annulus utilizing pneumatic Haskell pump. Pumped 11 bbls of fresh water. Pumped annulus up to 525#and bled off gas pressure numerous times. 02/16/2017-Thursday Continue filling 13-3/8" x 9-5/8" annulus with water. Pumped 3 bbls while pressuring up to 525 psig and bleeding off gas multiple times. 02/17/2017- Friday Continue filling 13-3/8" x 9-5/8" annulus with water. Pumped 3 bbls while pressuring up to 525 psig and bleeding off gas multiple times. ! • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1L1 E-Line 50-133-20520-60 202-257 1/8/17 4/6/17 Daily Operations: 04/04/2017 -Tuesday Obtain PTW. Hold safety meeting with HAK safety rep, Cruz vac truck drivers, Pollard crane op, state rep Guy Cook and welder. 24 hr P&A witness notification sent 4/3/17 @ 13:23. Informed by Mike Quick on 4/3/17 @ 14:55. Sending state rep Guy Cook to witness P&A. Spot Crane and Welders truck. 2x cruz Vac trucks. 1 loaded with 60 bbls fresh water from saxon 169. 80*F. 2nd Cruz truck empty to take returns and clean up fluid from SLB cement truck. Make up 3" nylon slings to casing hanger. Sniff 13-3/8" x 9-5/8" annuli. No signs of gas. Cut sections out of 13-3/8" casing. Cut 9-5/8" casing with torch. Torch mouse hole in 9-5/8" casing and cut 2" pipe used for previous top job. Manually rock wellhead back and forth to break remaining cement bond. Wellhead free. Evacuate all personnel from cellar and lift wellhead out and set on ground. 25 sticks of 3/4" conduit 10' in length on location. Install 6 mil visqueen plastic containment barrier double layered in cellar. Cut and secure visqueen to 20" conductor casing with duct tape, ratchet strap and another few layers of tape. Install slips on wellhead. RIH with conduit pipe.Tagged at 27.4". Walk joints of pipe around casing annuli to attempt greater depth. Not able to make anymore hole. Half of casing area was solid. Other half was thick sludge. Rig up cam-lock fitting on 3/4" conduit. Attempt to vac out fluids. Fluid level in casing was 2.3' from cut. POOH to inspect. Found bottom of conduit tool string full of unset cement consisting of dark grey and smelt like cement. Clean out 2' of solids from conduit pipe. SLB cement truck rigging up. SLB JSA completed. RIH with same 3/4" conductor pipe tagged top of hard portion at 27.5'. Pick up 2". Secure conduit string in slips. Rig up x over from 3/4" NPT to 2" 1502 iron and MU to SLB cement pump truck. Start mixing cement from ABT to cement pump. 13-3/8" x 9-5/8" volume is .0837866 bbls/ft or 11.9'/bbl/ft. Cement volume required at 27' is 2.2 bbls. Online with 15 ppg Class G cement. Pumping down hole with C-pump only. Max pressure seen during treatment was 90 psi. Cement to surface. State Rep Guy Cook inspects cement job and is satisfied with results. Start pulling well bore returns from cellar containment with Cruz vac truck. POOH with 3/4" conduit pipe. Break down joints and remove tools from cellar. Remove visqueen cellar containment. Clean up SLB cement pump with dirty truck. SLB rigging down. Manifest Cruz vac trucks for G&I. Location cleaned up and secured. Following day CO man will inspect cement level and cement quality and report to state rep and HAK town engineers. McLane Consulting was on location surveying virgin ground level to compare with pad level and casing cut level. Rep indicated that current casing P&A depth was 6.38' below native/natural ground level. Current P&A level of Kasilof #1 has fulfilled the state's requirements of being secured 3' below natural ground level. McLane Consulting sent documentation to state rep and HAK management. 04/06/2017 -Thursday On location with production welder. Cellar filled with water. Called out vac truck. Remove 40 bbls of fluid from cellar. Confirm cement is still solid and intact. Take pictures and video. Send to town engineer. Weld marker plate on 20" conductor pipe. Guy Cook from state was there to witness. • • 11 Kasilof South #1 / 1L1 Kasilof Field SCHEMATIC Ilileorp Alaska,LLC Surface x Intermediate Casing Marker Plate 4/6/17 Cement Top Job 4/4/17 Kasilof South#1 (Motherbore- .:,„, Kasilof South#1L1 South Target) 'r}t., (Lateral-North Target) Kasilof Field41 ,, `*" Kasilof Field 520'FSL, 1340'FWL, ,' ''t. 520'FSL, 1340'FWL, Sec.28,T3N, R12W,SM t Sec. 28,T3N, R12W,SM 4 Maki Cast Iron Bridge Plug @ 150' itt ?ttConductor Dump 150'of cement 2/2/17 ' 20" K-55 Top 0'MD / Suspected Casing damage @ 3,208'- ` y 133 ppf PE Bottom 130'MD 130'TVD 3,210' ' -^`' Surface Casing Cast Iron Bridge Plug @ 3,293' 11 13-3/8" K-55 Top 0'MD Dump 540'of cement 2/2/17 68 ppf BTC Bottom 2860'MD 2383'TVD I 16"hole with+/-750 sks 12 ppg cement Tubing chem cut @ 9,405' 1/26/17 Tubing chem cut @ 9,435' 1/26/17 GT Dual String Packer w/top @9853'MD .. I CIBP @ 9,890'1/25/17 Size- 9-5/8"x 3-1/2"x 3-1/2" ` I,IIS] Intermediate Casing CIBP @ 9,900'1/25/17 IR<! M1 / 9-5/8" L-80 Top 0'MD Dual Tubing Strings .n."1.11111111111,in / 40 and 47 pp BTC Bottom 9916'MD 5186'TVD 3-1/2",9.3#,L-80,Hydril 533 i 1� Scoophead Diverter Underreamed Section (SHD) Size-17-1/2"(9850'-10020'MD) Size- 9-5/8"x 3-1/2 x 3-1/2 TAML Level 6 FORMation Junction n ''';'), FORMation Junction with Size-9-5/8"x 7"x 7" �� Leg-Extended Leg Size-7"x 298 Size-9-5/8"x 7"x 7" 9916'-9935'MD Leg Size-7"x 29# ZXP Liner Hanger Packer 9916'-10533'MD Size-7"x 3-1/2"w/top @ 9923' FHL Production Packer hil Size-7"x 3-1/2"w/top @ 1Q909' 3-1/2"Liner SLPR r anger Cast Iron Bridge Plug @ 16,950' Size-3L1/2 inex 7 H"w th top at 10323' Dump bail 25'of cement 1/10/17 � ll II RS Nipple 3-1/2"set at 10333'MD ITvonek Perfs: 16,972'-16,996'MD,24 ft, PJ2506 3/24/2004 Pen s: 17,012'-17,050'MD,38 ft, PJ2506 3/22&23/2004 I 3-1/2"Liner \ 16438-16454'MD,16 ft PJ2506 4/9/2004 17280-17320'MD,40 ft PJ2506 4/6&8/2004 /" 17385-17409',MD 24 ft PJ2506 4/5/2004 Mt TD:17,545'MD/ 9642'TVD �-- \�_ �=. TD:17,665'MDI 9999'ND Cast Iron Bridge Plug @ 16,400' Dump bail 25'of cement 1/10/17 Liner Liner 3-1/2" L-80 Top 9923'MD 5189'TVD 3-1/2" L-80 Top 9918'MD 5187'ND 9.2 ppf Hydril 563 Bottom 17504'MD 9605'ND 9.2 ppf Hydril 563 Bottom 17644'MD 9980'ND 6"hole with+/-675 sks.12.7 ppg cement. 6"hole with+/-700 sks.12.7 ppg cement. Kasilof South#1: Total Depth Location Kasilof South#11_1: Total Depth Location 4402'FSL&786'FEL Sec.25 T3N-R13W,SM 2230'FSL&4382'FEL Sec.19 T3N-R12W,SM KOP @ 500'MD/TVD KOP @ 500'MD/TVD Build 3.0 deg/100 from 500-3090' J Build 3.0 deg/100 from 500-3090' Hold 66-72 deg from 3090-13,502' Hold 66-72 deg fro1:5 3090-10,533'MD Drop 1.5 deg/100 to 15,674' KOP @ 10,533'MD/5432'TVD at 66 deg Final angle of 27.6 deg Hold 66 deg from 10,533'-13,097'MD Azimuth:270 deg. Drop 1.5 deg1100 to 15,665' Final angle of 19.5 deg Azimuth:316 deg. Revised by: DMA Date: 4/25/2017 r • :, • -.ty. ar z' ',, CO LI • 12) 11.' 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Oz • Lower Upper BARO Chassis Module Module Module Left Scale Right Scale Serial Number 568966 567604 567604 Model NV 3KPSI Message Store South Kenai Asset 3K PSI Hilcorp AK Userspan 1.00000 Offset Datatype Upper Units PSI G PSI G Tare Average User Factor User Offset User Resolution Firmware Version R080016 R090009 Calibration Due 12-Dec-17 Run Index 0 Run Start Time 29-Dec-16/07:48.09 Run Duration 5 days 8 hours 40 minutes Run Tag Kasilof IA MIT Logging Interval 60.0 Data Points Point# Time Right-PSIG 6286 104:45:00.0 1799.1 6287 104:46:00.0 1810.7 6288 104:47:00.0 1810.4 6289 104:48:00.0 1811.9 6290 104:49:00.0 1812.9 6291 104:50:00.0 1813.7 6292 104:51:00.0 1814.2 6293 104:52:00.0 1814.2 6294 104:53:00.0 1814.7 6295 104:54:00.0 1815.1 6296 104:55:00.0 1815.5 6297 104:56:00.0 1815.8 6298 104:57:00.0 1816.1 6299 104:58:00.0 1816.3 6300 104:59:00.0 1816.5 6301 105:00:00.0 1816.8 6302 105:01:00.0 1816.9 6303 105:02:00.0 1817.0 6304 105:03:00.0 1817.2 6305 105:04:00.0 1817.2 6306 105:05:00.0 1817.4 6307 105:06:00.0 1817.5 6308 105:07:00.0 1817.6 6309 105:08:00.0 1817.5 6310 105:09:00.0 1817.7 6311 105:10:00.0 1817.8 6312 105:11:00.0 1817.8 6313 105:12:00.0 1817.7 6314 105:13:00.0 1817.8 6315 105:14:00.0 1817.8 6316 105:15:00.0 1817.8 6317 105:16:00.0 1817.9 6318 105:17:00.0 1817.8 6319 105:18:00.0 1817.9 6320 105:19:00.0 1817.9 6321 105:20:00.0 1817.9 6322 105:21:00.0 1817.9 6323 105:22:00.0 1817.9 6324 105:23:00.0 1815.9 6325 105:24:00.0 15.4 6326 105:25:00.0 5.5 6327 105:26:00.0 5.5 6328 105:27:00.0 5.9 • • 4/4/2017 Iain Brown,PLS McLane Consulting Inc. PO Box 468 Soldotna,AK 99669 Hilcorp Alaska LLC;Kasilof South#1 P&A Survey Enclosed is Exhibit A for the Plug and Abandonment of the Kasilof South#1 Well,in Kasilof Alaska. The Field work for this survey was conducted on April 4,2017. The work consisted of providing accurate field elevations in order to meet all the requirements necessary for cutting off the existing conductor. Several original/native ground points were observed and their elevations averaged. The elevation on the top of the pipe after it had been cut was also observed,and finish grade of the gravel pad was observed. Previous on-site control from construction of the Kasilof#1 Pad was recovered and checked to ensure continued accuracy. All Survey data has been adjusted to match the NGS OPUS solution both horizontally and vertically,please see the attached Exhibit A for the Basis of Geodetic Coordinates and the Basis of Elevation. The Results of the survey are as follows: The average elevation of original or native ground:74.342 US Feet The finish grade elevation of the gravel pad:73.733 US Feet The top of the pipe after cut-off:67.961 US Feet The top of Cut-off was found to be 6.38 US Feet below the elevation of Original/Native ground,which exceeds the required three(3)feet. We appreciate the opportunity to work with Hilcorp on this project. Please review the attached Exhibit A and if you have any questions or concerns,please contact us at 907-529-6466. Iain Brown,PLS McLane Consulting Inc. 907-529-6466 ibrown@mclanecg.com OF111 lawQ ,. gS' I *i 491-11 '\ *�i 0 /, � IAIN C.BROWN : Q .0 s • LS-107707cr- • SF/ � S ONA !�!AI,►\\:••%` A • 0 -____i \ ./" , \l. AS 10 :::E2:3:0796964.46\ , \ :1390411.13 `\ NORTH .50' KASILOFSOUTHNO. 1N:2309896.70 1 Ipplj�lll'� ��� E:1390229.06 \ � I� —._— 1 _ I _ I 111)1� 1 I SCALE 0� 150I 300 FEET 1 - • IN'- 1 • r '''/' 65, A I I I ��� 9 A�q III �U// si D I I' •�`P .44A. it �I� � � ; �� ▪ *:491ti *I -- NICATION s i TOWER , c Q 1 I I fl ,• .. sF 0 p (e p : �62-d,,,:... IAIN C. BROWN r_g- 1 I i ' /, s� LS-107707 -�'_ I 0 w ACCfSg .: / H I '1'F '-•.,4/4/17.••• y�� — _ r. ,q I� op P 111 I '1 I .-...-... 1r I , I 1 ROFESS I ONP\- P`�� m c baa 1 I �(1\\VNA-N , . .,. Ig: R . Ili - rt 1 a(-'I/� ti AS 9 :2309395.420 '— -- -'E•1390456.404 33' I �II�I. , ' ., LEE75.a7' I SECTION 28, T3N, R12W, S.M. AK,_ + F WC CCSECTION 33, T3N, R12W, S.M. AK. E:13900136.21136.21 , 50' SECTION LINE EASEMENT E:23 I ELEV:71.55' I NATURAL GROUND AVERAGE ELEV: 74.432 FT FINISH GRADE GRAVEL PAD CONDUCTOR CUT-OFF ELEV: 73.733 FT — TYPICAL SECTION — — — NOT TO SCALE 1 _ — I: i I = NOTESWELL II CELLAR '— 11_ 1. BASIS OF OPUS SOLUTION FTROM NGS CIC OOORDINATL AND DES STATIONS 83 POSITION(KEN5 CORSEPOCH )ARP',IS AN i— I "TSEA CORS ARP",AND'ZAN1 WAAS 1 CORS ARP"TO ESTABLISH THE — 1 I,— _ POSITION OF"KAS9".THE GEODETIC POSITION OF"KAS9"WAS DETERMINED TO HAVE A LATITUDE OF 60°18'51.62717"N AND A LONGITUDE III TOP CUT—OFF CONDUCTOR —1 OF 151°22'43.24964"W.THE ALASKA STATE PLANE COORDINATES(ASP) --11 1 ELEV: 67.691 FT iJ1 _ ZONE 4 ARE: N=2309395.420 III —I E=1390456.404 _ ELEV.75.07'(NAVD88) — 2. BASIS OF VERTICAL CONTROL IS NGS BM L82 PID TT0574 LOCATED WITHIN 1 I I ;:• f 11I AT MILE 119 OF THE STERLING HIGHWAY HAVING AN ELEVATION OF 346.15 ; .'y:. FEET NAVD 88 ACCORDING TO NGS PUBLISHED DATA. =11 —TT _ T-7 IT— . T'• - r iT 3. ALL DISTANCES LISTED IN US SURVEY FEET. / I 1E11 -) 1 -1 4:911,. .-1 11=111E11 -1 —111-11-111— 111-111-111-111- PROJECT HILCORP ALASKA, LLC REVISION: - Lkik Consulting Inc KASILOF SOUTH #1 DATE: 4/4/17 HKASILOF ALASKA DRAWN BY: ICB PLUG AND ABANDON EXHIBIT-A SCALE 1"=150' PROJECT NO. 177006 ENGINEERING/MAPPING/SURVEYING/TESTING NAD 83 BOOK NO. 16-03 P.O.07) 8342168 8DOF AK.(907)283-3265 LOCATION SEC. 28 TO3N R12W VOICE:(907)283-0218 FAX:(907)283-3265 SHEET EMAIL:SAMCLANE@MCLANECG.COM Hilcorp Alaska,LLC 1 OF 1 SEWARD MERIDIAN, ALASKA • • v" Ty y/,� 9 THE STATE Alaska Oil and Gas OfA LAsKA Conservation Commission 333 West Seventh Avenue 'fi R GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson ���� , t r t ' Operations Manager S— O Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Kasilof Field, Tyonek Undefined Gas, Kasilof South 1 L 1 Permit to Drill Number: 202-257 Sundry Number: 316-641 Dear Mr. Helgeson: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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. Sincerely, Cathy . Foerster ,,�p� Chair DATED this a day of December, 2016. /2 �y 5i �� RUDr, s CL Jrii4 c J L;I/ 0 • RECEIVED STATE OF ALASKA DEL 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION I(' ( APPLICATION FOR SUNDRY APPROVALS �T�IJJ j Z( 1�ACIGGC 20 AAC 25.280 1.Type of Request: Abandon ❑., . Plug Perforations r • Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: F ,t'... 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: �/ Exploratory 0 • Development ❑ 202-257 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 111Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20520-60 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(a) Will planned perforations require a spacing exception? Yes 111No 2Kasilof South 1L1 - 9.Property Designation(Lease Number): ADL-0384529, • 10.Field/Pool(s): ADL-0384534,ADL-0391591,FEE-Hilcorp,ADL-0391246 • Kasilof Field/Tyonek Undefined Gas ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 17,665' ` 9,999' • 17,543' 9,885' —2,300 psi N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 130' 20" 130' 130' 3,060psi 1,500psi Surface 2,860' 13-38" 2,860' 2,383' 3,450psi 1,950psi Intermediate) 9,885' 9-5/8" 9,916' 5,186' 5,750-6,870psi 3,090-4,750psi Intermediate2 617' 7" 10,533' 5,432' 8,160psi 7,030psi Liner 7,726' 3-1/2" 17,644' 9,980' 10,160psi 10,540psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 10,333' Packers and SSSV Type: GT Dual Pkr; Packers and SSSV MD(ft)and ND(ft): 9,853'MD/5,161'ND FHL Pkr;N/A 10,909'MD/5,582'ND;N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 2 • Stratigraphic❑ Development❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: January 4,2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned D - 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnasse(C7hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature / Lr�`�Z� Phone 907-777-8405 Date 1 ZiZ.Z1/ (a COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' tlt - ( 22-( l Plug Integrity le BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: jiL 2-5-00 p.S Bt.)/P 7.;S f 1 (), j ) /til e-0-, //n y�7_ f- )k k die, c„,,,,„,.,-- G'.-.t.'-..S i E%Lt�. '�t'/��^C�.J'IL t4-N./1 ( '."E7 G✓.lY 4�C_c'-0* o I_& Post Initial Injection MIT Req'd? Yes ❑ No ❑ (�((77 LL / (( ��� t t,Z �� L Spacing Exception Required? Yes ❑ No Subsequent Form Required: f 0 41 6 7-' RBDi S l i ,l 4 ti 2017 APPROVED BY Approved by: i)sid/7 COMMISSIONER THE COMMISSION Date:/2 )� (.° / `� Submit Form and Form 10-403 Revised 11/2015 (� Ripeeiticikt:valid for 12 months from th ate of approval. Attachments in Duplicate V 12'h ! /s`� /2, 2:7, i4, • • S Well Prognosis Well: Kasilof South#1/111 Hilcorp Alaska,LL Date: 12/21/2016 Well Name: Kasilof South#1/1L1 API Number: 50-133-20520-00/-60 Current Status: Shut-In Well Leg: N/A Estimated Start Date: January 4th, 2016 Rig: Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 202-256/202-257 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907)903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (C) AFE Number: Maximum Expected BHP: —3,931 psi @ 9,153' TVD (Assumed 0.43 psi/ft gradient) Max. Potential Surface Pressure: —2,300 psi (Based on current surface pressure) • Brief Well Summary Kasilof South #1 and Kasilof South #1L1 were drilled in 2003 and completed in the Tyonek in 2004. The lateral wellbore did not find commercial gas; however,the Kasilof South#1 produced until 2014 when it was shut in. The purpose of this work/sundry is to plug and abandon the Kasilof South#1 (KS#1) and Kasilof South #1L1 (KS #1L1) per 20 AAC 25.112 and 20 AAC 25.120. Notes Regarding Wellbore Condition • Well is currently shut in with 700 psig on Kasilof#1 and 2,200 psig on Kasilof#1L1. llJ�F fel 1 1-- 1.4 bi c.t '5 -(may) r14,' s_ Cf (7.--4•7-4 E-Line Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. KS#1 wellbore 2. MU 3-1/2" CIBP and setting tool. 3. RIH and set CIBP at+/- 16,950'. POOH w/setting tool. 4. MU dump bailer and fill w/cement. 5. RIH and dump cement on top of CIBP (25' =9 gallons). POOH w/dump bailer. 6. MU 3-1/2" tubing punch and punch tubing at+/-3,220'. - KS#1L1 wellbore 7. MU 4-1/2" CIBP and setting tool. 8. RIH and set CIBP at+/- 16,400'. POOH w/setting tool. 9. MU dump bailer and fill w/cement. 10. RIH and dump cement on top of CIBP (25' =9 gallons). POOH w/dump bailer. 11. MU 3-1/2" tubing punch and punch tubing at+/-3,220'. • • 12. RD e-line. Pumping Procedure: 13. Bleed off any pressure on KS#1/KS#1L1. 14. Connect to KS#1 and/or KS#1L1 wing valve and fill with produced water. ilfot-` f a. Total wellbore volume: 864 bbls „Tn.? 15. Pressure test CIBP's to 1,750 psig(limited to 70%SMYS of 9-5/8" L80 40 lb/ft casing). . —. r • • Well Well: KasilofPrognosis South#1/111 Ililcorp Alaska,LL Date: 12/21/2016 E-Line Procedure: 16. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. KS#1 wellbore 17. RIH and tag top of cement and verify top at 16,925'. 18. MU 3-1/2" chemical cutter or radial torch cutter and cut tubing at+/-3,200'. KS#1L1 wellbore 19. RIH and tag top of cement and verify top at 16,375'. 20. MU 3-1/2" chemical cutter and cut tubing at+/-3,200'. 21. RD a-line. WO Rig Procedure: 22. MIRU Moncla 401 rig. 23. Circulate well with PW by pumping down the tubing and taking returns up the annulus. 24. Set BPV's. ND Tree. 25. NU BOPE with dual pipe rams in the upper ram cavity(see schematic). Make up blanking ported test sub to test joint to both tubing hangers. Test to 250 psi low/2,500 psi high. LD test joints. Make up 2- 7/8"test joint to test VBR and annular.Test to 250 psi low/2,500 psi high. Install TWC. Test blind 175'- rams. Record accumulator pre-charge pressures and chart tests. G a. Notify AOGCC 24 hours prior to testing at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 26. Pull TWC. 27. RU dual handling equipment. 28. MU landing joints to the hangers. BOLDS. Latch elevators to the landing joints. 29. Pull tubing hanger to the floor. 30. POOH with the dual completion to the tubing cut at 3,200' MD. Lay down all the 3-1/2"tubing and completion jewelry. 31. RU 2-7/8" handling equipment. G�( 32. MU 9-5/8" CIBP and TIH on 2-7/8" workstring to+/-2,960' and (100' below surface casing shoe). • 33. Set CIBP, close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up and lay 200' of cement on top of plug. POOH. 34. MU 9-5/8" CIBP and TIH on 2-7/8" workstring to+/-150' and (150' below ground level). 6.1!,3!� 35. Set CIBP, close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up and lay 150' of cement on top of plug. POOH. 36. RD Moncla#401 WO Rig. Post WO Rig Procedure: —� N0�-,-f7 l p t ri- 71.0 to 37. Remove well cellar and cut conductor and casing to ground level. Weld abandonment marker per 20 AAC 25.120. 3 CJ���rCt. �j'-zl ro c,� 1 Attachments: 1. Actual and Proposed Schematic � ,� 46 ccz ► -, t 51.1) u" " " 2. BOPE Schematic r- �' w�(�P..PAck. 3. Wellhead Diagram 4. RWO Sundry Revision change Form • • II Kasilof South #1 / 1L1 SCHEMATIC Hilease Alaska,LLC Kasilof Field Kasilof South#1 (Motherbore- Kasilof South#1L1 South Target) (Lateral-North Target) Kasilof Field Kasilof Field 520'FSL, 1340'FWL, LL520'FSL, 1340' FWL, Sec.28,T3N, R12W,SM Sec.28,T3N, R12W,SM oil 1 Chemical Injection Nipples Conductor 2540'and 2544' 20" K-55 Top 0'MD +' 133 ppf PE Bottom 130'MD 130'TVD Surface Casing 13-3/8" K-55 Top 0'MD Dual Production Tubing - I 68 ppf BTC Bottom 2860'MD 2383'TVD Size-3-1/2",9.3#,L-80,Hydril 533 Extends from GT pkr to surface I it 16"hole with+/-750 sks 12 ppg cement GT Dual StringPacker w/top £ X9853'MD ,e Size- 9-5/8"x 3-1/2"x 3-1/2" 17' Intermediate Casing i9-5/8" L-80 Top 0'MD Dual Tubing Strings11 40 and 47 pp BTC Bottom 9916'MD 5186'TVD 3-1/2",9.3#,L-80,Hydril 533 I Scoophead Diverter 1 Underreamed Section (SHD) i Size-17-1/2"(9850'-10020'MD) Size- 9-5/8"x 3-1/2"x 3-1/2" \ TAML Level 6 FORMation Junction I \ FORMation Junction with Size-9-5/8"x 7"x 7" _________÷ i I Leg-Extended Leg Size-7"x29# M I. Size-9-5/8"x 7"x 7" 9916'-9935'MD i I— Leg Size-7"x 29# 1 I. { 9916'-10533'MD ZXP Liner Hanger Packer t FHL Production Packer Size-7"x 3-1/2"w/top @ 9923' t Size-7"x 3-1/2"w/top(d 10,909' SzLPR Liner Hanger <+ Size-3-1/2 x 7"with top at 10323' '',1 RS Nipple 3-1/2"Liner31/2"set at 10333'MD Tvonek Perfs: Tvonek Perfs: 16,972'-16,996'MD,24 ft, PJ2506 3/24/2004 16438-16454'MD,16 ft PJ2506 4/9/2004 3-1/2"Liner 17280-17320'MD,40 ft PJ2506 4/6&8/2004 17,012'-17,050'MD,38 ft, PJ2506 3/22&23/2004 17385-17409',MD 24 ft PJ2506 4/5/2004 TD:17,545'MD/ 9642'TVD i... TD:17,665'MD/ 9999'ND Liner Liner 3-1/2" L-80 Top 9923'MD 5189'ND 3-1/2" L-80 Top 9918'MD 5187'TVD 9.2 ppf Hydril 563 Bottom 17504'MD 9605'TVD 9.2 ppf Hydril 563 Bottom 17644'MD 9980'ND 6"hole with+/-675 sks.12.7 ppg cement. 6"hole with+/-700 sks.12.7 ppg cement. Kasilof South#1: Total Depth Location Kasilof South#10: Total Depth Location 4402'FSL&786'FEL Sec.25 T3N-R13W,SM 2230'FSL&4382'FEL Sec.19 T3N-R12W,SM KOP @ 500'MD/TVD KOP @ 500'MD/TVD Build 3.0 deg/100 from 500-3090' Build 3.0 deg/100 from 500-3090' Hold 66-72 deg from 3090-13,502' Hold 66-72 deg from 3090-10,533'MD Drop 1.5 deg/100 to 15,674' KOP @ 10,533'MD/5432'TVD at 66 deg Final angle of 27.6 deg Hold 66 deg from 10,533'-13,097'MD Azimuth:270 deg. Drop 1.5 deg/100 to 15,665' Final angle of 19.5 deg Azimuth:316 deg. • • .. II Kasilof South #1 / 1L1 PROPOSED ffilcoruAlaska.LLC Kasilof Field SCHEMATIC Kasilof South#1 (Motherbore- '' 1 1 Kasilof South#1L1 South Target) [.` (Lateral-North Target) Kasilof Field Kasilof Field 520'FSL, 1340'FWL, ' -- � 520'FSL, 1340'FWL, Sec.28,T3N, R12W,SM Sec.28,T3N, R12W,SM ':‘Conductor Cast Iron Bridge Plug @ 150' Dump 150'of cement i ; 20" K-55 Top 0'MD i , ' '; 133 ppf PE Bottom 130'MD 130'ND f Cast Iron Bridge Plug @ 2,960' Dump 200'of cement i n Surface Casing 13-3/8" K-55 Top 0'MD Dual Production Tubing i 11 I 68 ppf BTC Bottom 2860'MD 2383'ND Size-3-1/2",9.3#,L-80,Hydril 533 j Extends from GT pkr to 3,200' i I 1 i I bill 16"hole with+/_750 sks 12 ppg cement GT Dual String Packer w/top @9853'MD 1+ Size- 9-5/8"x 3-1/2"x 3-1/2" _ ti 'n' Intermediate Casing EpI9-1111. 5/8" L-80 Top 0'MD Dual Tubing St ngs • 1/ 40 and 47 pp BTC Bottom 9916'MD 5186'ND 3-1/2",9.3#,L-80,Hydril 533 Scoophead Diverter Underreamed Section (SHD) 4' Size-17-1/2"(9850'-10020'MD) Size- 9-5/8'x 3-1/2 x 3-1/2" ! 1 TAML Level 6 FORMation Junction i , ;y FORMation Junction with Size-9-5/8"x 7"x 7" ^, I Leg-Extended Leg Size-7"x 29# _aa Size-9-5/8"x 7"x 7" 9916-9935'MD % FI Leg Size-7"x 29# t 9916-10533'MD 11 l ZAP Liner Hanger Packer FHL Production Packer Size-7"x 3-1/2"w/top @ 9923' iii Size-7"x 3-1/2"w/top 3-1/2"Liner 10,909' SLPR Liner Hanger Size-3-1/2 x 7"with top at 10323' Cast Iron Bridge Plug @ 16,950' Dump bail 25'of cement �� RS Nipple 3-1/2"set at 10333'MD Tvonek Perfs: I ' II Tvonek Perfs: 16,972'-16,996'MD,24 ft, PJ2506 3/24/2004 / l "Li16438.16454'MD,16 ft PJ2506 4/9/2004 17,012'-17,050'MD,38 ft, PJ2506 3/22823/2004 3-112ner 17280-17320'MD,40 ft PJ2506 4/6&8/2004 \ 17385-17409',MD 24 ft PJ2506 4/5/2004 "Thaii01,____--------H-, - TD:17,545'MD/ 9642'ND M_ �_ TD:17,665'MD/ 9999'ND ]ast Iron Bridge Plug @ 16,400' Dump bail 25'of cement Liner Liner 3-1/2" L-80 Top 9923'MD 5189'ND 3-1/2" L-80 Top 9918'MD 5187'ND 9.2 ppf Hydril 563 Bottom 17504'MD 9605'ND 9.2 ppf Hydril 563 Bottom 17644'MD 9980'ND 6"hole with+/_675 sks.12.7 ppg cement. 6"hole with+/-700 sks.12.7 ppg cement. Kasilof South#1: Total Depth Location Kasilof South#1L1: Total Depth Location 4402'FSL&786'FEL Sec.25 T3N-R13W,SM 2230'FSL&4382'FEL Sec.19 T3N-R12W,SM KOP @ 500'MD/TVD KOP @ 500'MD/TVD Build 3.0 deg/100 from 500-3090' Build 3.0 deg/100 from 500-3090' Hold 66-72 deg from 3090-13,502' Hold 66-72 deg from 3090-10,533'MD Drop 1.5 deg/100 to 15,674' KOP @ 10,533'MD/5432'TVD at 66 deg Final angle of 27.6 deg Hold 66 deg from 10,533'-13,097'MD Azimuth:270 deg. Drop 1.5 deg/100 to 15,665' Final angle of 19.5 deg Azimuth:316 deg. Revised by: TWN Date: 12/20/2016 • • 11 Kasilof Field Kasilof#1 / 1L1 12/21/2016 Nikorp%Im4ia,UM e o,sa • • 13-5/8" 5M Annular 3-1/2" Dual Flex 4a4 644 iiiit AN1 or ` off` y 3 2-7/8"- 5"Variables Blinds 1 NW . , V,A. ' -°"°"` 2-1/16" SM choke and kill valves 1111 III NU, Iliti 11111 ud Cross ,� . ern �,I • • .. nKasilof Unit Kasilof#1 12/12/2016 thin p %I...L..lit Kasilof Unit Tubing hanger,MB-196, Kasilof#1Dual,13 5/8 X 3%X 3'A, 3.725"MCA left hand acme 20X133/8X95/8X3YX3Y: lift X3'A IBT susp,w/3" Type H BPV-profiles,'''A control line nipples,prepped for seal sleeves on hanger neck,5.047"centers BHTA Dual,11"5M FE X 3 1/8 5M 5 bolt tops Tree,dual block,swab, WKM-M,11"5MFEX I 3 1/8 5M X3 1/8 5M,w/CIW �,, seal pockets,AA trim,5.047" centers 1.11 ilk II: • 41 ,9` 4'11;.),,L L� :.(� i h ti\OQ / "LCA a`PL -.� \ro cw o�,�� 444 � 2 °02i , Ir4 o �ho 04, r. -dy9 �5 9y 1-14, aszry °ptif, s' \ ,,,,,6",<,<, -9, ..7,<,4 ,<F 4 _ ...i ,4, prn) ) II al, I Eli 71110 Tree,dual block,upper 4. master,WKM-M,11"5M FE �7��qq.:, X 3 1/8 5M X 3 1/8 SM,w/ . Li v� CIW seal pockets,AA trim, CC'' 5.047"centers ' : ' II: Tree,dual block,master, WKM-M,11"5M FE X3 1/8 Jo 5MX31/85M,w/CIW seal �� /.615". pockets,AA trim,5.047" 7‘-% centers —I 40 I= �9 i Adapter,Dual,Vetco Gray, l J 135/85MstddX 11"5M .1 stdd X 3 1/8 X 3 1/8 Bores, set up on 5.047"centers and CIW seal carriers jl ITI l„....;,,..... Multibowl,Vetco MB-196, =•moi'��+�� li !• 13 3/5 8 5M E topbotw/ ..i j'I /.., ., Control line X2 om X 13 5/8 5M FE top,w/ _.. , 2-2 1/16 5M 550, 16r,Guide screw for dual hangers ,".....j , :. I .{.4 ?4 i• I. dill 1111 r4111 g'`. i i Starting head, II' 'r Vetco MB-196, .,,,,.,, 13 5/8 3M X 13 3/8 VG-Loc PIM bottom,w/2-2"LPOIIE ' mit 2 iiii Ell 20" 13 3/8" 9.625" 3.5" 3.5" • • . kt§P ' O f 2& W o co @ 0 ® c U E k o ° ch 2 � t § ƒ � a EZ S ' 2 . § fld 473 » < �. k / 2 al CI) e 6" "CI _0 « Cm2 In § 7 � : N �.s a N 03 1.32 c % : -0 ■ ■ $ 2 % ■ z tjk c kk z � N % 0 r iCL 0 � 0 Z // @ , .0i- O r kc 2g 03co » — %• U a) 2 < co c ..-c.' < 2 CD El2 E b 0 0• . 2 o k / § a. e k 230 § t « c , Cl) C / . E � 0 c . w ■ § ■ © 2 > � co q o a 4 6. a / ) o s. 4 0. 2 % « E o.o z 2 ■ 2 2 co 2 & � ; co <1 § . / 0 a . § 2 ) � 0 � � « iZ - .. 0 $ Ek co / E k c k9a Z1 C) a) Cl) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/29/10 Inspector: Bob Noble Operator: Marathon Oil Co. • Well Name: Kasilof South 1L1 • Oper.Rep: Kevin Skiba PTD No.: 202-257 Oper.Phone: 907-283-1371 Location Verified? Yes Oper.Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 04/15/04 Date AOGCC Notified: 09/14/10 Sundry No.: Well Completion Rpt • Type of Inspection: Initial . Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 700 Photos Taken? Yes IA 0 OA 0S`ANNEp AUG 1 4 2015 Condition of Wellhead: The wellhead location was verified with the use of a plot plan and wellhouse sign.This well if a duel complication.1L1 was suspended only.The drillsite had a locked gate and the well had a house.The cellar was good clean dry gravel. Condition of Surrounding Surface The location looked good and clean with no signs of any spill. Location: Follow Up Actions None Needed: Attachments: Photos(3) - REVIEWED BY: Insp.Supry JGC Comm PLB 09/2010 2010-0929_Suspend_Kasilof_South_1 L1_bn.xlsx Suspended Well Inspection—Kasilof South #1L1 PTD 2022570 - Photos by AOGCC Inspector B. Noble 9/29/2010 ,f_. l i I, I LI . ......., . II Ilii7,1ir' 1�i4116 I ( I)I' inn'li 1 10111111 iI Will - ' pi VIII/ ,.,..v [...7I� , , .. . i i i 1 • 11 p 8 P8 f t i ...... ' w , k Ali It. ig I' 1 f tii, ' d 4 .,',.!1 T‘ EMU tit ,. . . s , a1 � . 1 `I_''.•.___.___. -'.*-'''fki r o__Id'f I _ st- , ' ."1 .. .0,/ . .., ,' r it , 2010-0929_Suspend_Kasilof_South_1Ll photos.docx - Page 1 of 2 4t: It i . if 1 °'' .illt; * lit ,,,, 2 0% y is 1 ill" i 1 t. • 4 J ,. • 2010-0929_Suspend_Kasilof_South_1 L l photos.docx Page 2 of 2 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d 0 d - ~p -7 Well History File Identifier D Two-sided 1111111111111I11111 Page Count from Scanned File: __~ (Count does include cover sheet) ~~ Count Matches Number~~I:c~~giï~ztion V YES If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) RESCAN ~Ior Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, Norrype: D Poor Quality Originals: D Other: NOTES: Dale 5/7 /tJ~ Dale S 111100 I /' 6 x30= 15D BY: ~ Project Proofing BY: ~ Scanning Preparation BY: Date: Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed ""111111111" 1111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ~09S of various kinds: D Other:: mf 151 111/1111111111 "III 151 alP + :J..J-f = TOTAL PAGES I ;¡'!f (Count does not include cover she . cr1 151 'T 11111111111111 "III NO 151 wrp NO 151 11111111111111 111/1 ReScanned BY: Maria Date: 151 Comments about this file: 11I11111111111 II1II Quality Checked 11111111111I1111111 10/6/2005 Well History File Cover Page.doc • • Aubert, Winton G (DOA) From: Skiba, Kevin J. (MRO) [kskiba c@marathonoil.com] Sent: Monday, June 20, 2011 11:02 AM To: Aubert, Winton G (DOA) Subject: KS-1L1 Suspended Well Status Sundry Withdrawal Winton, '` 9 Marathon respectfully requested the withdrawal of the: • 10-404 KS -1L1 Suspended Well Inspection Report submitted on 10 -28 -10 • 10-403 KS -1L1 Suspended Well Status Extension Sundry submitted on 11 -9 -10 KS -1L1 has not been plugged back and does not meet the criteria for Suspended Well status. Approval to reclassify KS -1L1 as a Gas Well was granted on 5 -13 -11 by the AOGCC. With the recognition that KS -1L1's correct classification is that of Gas Well, withdrawal of the above mentioned submittals seems to be the appropriate action. Please let me know if you have any questions. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC Office (907) 283 -1371 5iitAltitUTJUN 2 2D3a Cell (907) 394 -1880 Fax (907) 283 -1350 1 • • Marathon Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 ( __\ MARATHON Alaska Production LLC Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 November 9, 2010 EN 12 2,010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 40174;40 ail u Gar, Cons.ComP :a 333 W 7 Ave Ancho rage Anchorage, Alaska 99501 )5 Reference: 10 -403 Application for Sundry Approvals Request: Suspended Well Extension Request Field: Kasilof Field Well: Kasilof South 1L1 Dear Mr. Aubert: Attached for your approval is Form 10 -403 Application for Sundry Approvals for well KS-1L1. This is a request for a 10 year suspension approval for well KS-1L1 which had a suspended well inspection performed on September 29, 2010. Please contact Kevin Skiba at (907) 283 -1371 if you have any questions or need additional information. Sincerely, Tiffany Stebbins Regulatory Compliance Representative Enclosure: 10 -403 cc: Houston Well File Kenai Well File KJS NEC } � , • • f 14 9.0.4, . STATE OF ALASKA �° �' 20 �� ALASKA OIL AND GAS CONSERVATION COMMISSION A a a th1& S .d Can ijrf.lfaion APPLICATION FOR SUNDRY APPROVALS .nckos'arge 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Ch- ge Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other Suspended Well Extension 0 2. Operator Name: 4. Current Well Class: 5. Pe it to Drill Number: Marathon Alaska Production LLC Development 0 Exploratory ❑ 20 57 3. Address: PO Box 1949 .. API Number: Stratigraphic El Service ❑ Kenai, Alaska 99611 -1949 50- 133 - 20520 -60 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Nu be . property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Kasilof So (Ii 1 9. Property Designation (Lease Number): 10. Field/Pool(s): ` - ADL- 0384534, ADL- 0384529, ADL- 0389502 Kasilof Field /I:, .n; Pool 11. PRESENT WELL CONDITION SUMMARY 1 Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Dep T .i ): i Plugs (measured): Junk (measured): 17,665' 9,999' 17,543' ` / 1 NA NA Casing Length Size MD 1 TVD Burst Collapse Structural �` Conductor 99' 20" (13 1 ' 130' 3,060 psi 1,500 psi Surface 2,829' 13 -3/8" 2'• • I 2,383' 3,450 psi 1,950 psi Intermediate -1 9,885' 9 -5/8" 9,*: 5,186' 5,750 - 6,870 psi 3,090 - 4,750 psi Intermediate -2 617' 7" 10, 3' ' 5,432' 8,160 psi 7,030 psi Liner 7,726' 3 -1/2" 9,980' 10,160 psi 10,540 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tu , in‘ e: Tubing Grade: Tubing MD (ft): 16,438' - 17,409' 8,880' - 9,760' ie -bac 1/2" L -80 10,333' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): Packers: GT Dual & FHL MD 9,853' & 10,909', 5,161' - 5,582' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch di Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: WINJ ❑ GINJ p WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true a : correct to the best of my knowledge. Contact Tiffany Stebbins 907 - 565 -3043 Printed Name Tiffany Stebbins 907 - 565 -3043 Title Regulatory Compliance Representative Signature i Phone Date i I/ if COMMISSION USE ONLY Conditions of approval: Notify •.mmission so that a representative may witness Sundry Number: 31 O ' 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent 'orm Required: APPROVED BY Appr, ed by: COMMISSIONER THE COMMISSION Date: Form 10 -403 Revised 1/2010 ORIGINAL Submit in Duplicate • • ENE ALASIEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (207) 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: Kasilof Field, Tyonek Pool, Kasilof South 1L1 Sundry Number: 311 -157 Dear Mr. Skiba: 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. Sincerely, aniel T. Seamount, Jr. 31a34:-of Chair DATED this) May, 2011. Encl. Mar, Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 M ARATHO N Alaska Production LLC Kenai, AK 99611 ® Telephone 907/283 -1371 Fax 907/283 -1350 May 6, 2011 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7 Ave E I V , Anchorage, Alaska 99501 2ni 3�' 0,4Y 0 Reference: 10 -403 Application for Sundry Approvals Alaska Qt! & f C H6. - mission ` Field: Kasilof Field Well: Kasilof South 1L1 Dear Mr. Aubert: Submitted for your approval is the KS-1L1 10 -403 Application foundry Approvals to convert KS-1L1 to Gas Well status from Suspended Well Status. This well was sidetracked and is currently a dual lateral /string completion. One of the laterals has been classified as a suspended well. The other lateral however is capable of production and is currently used as a swing well to meet peak production during times of high gas demand. The KS-1L1 (lateral) is shut in but not plugged back. Our request is for the re- designation of KS-1L1 to Gas Well status and remain in that state until the reservoir is , depleted and the entire well is ready to P &A. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ^ - Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Well Schematic Houston Well File Kenai Well File KJS �V�� y �f l t STATE OF ALASKA :4 , S-42 // -• 5" ALASK�L AND GAS CONSERVATION COMMISSI4. � y ,i. APPLICATION FOR SUNDRY APPROVALS C i1 �l J os /15 /wit 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Change approved program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Convert to I Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Gas well from Suspended Status - U 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development Q _ Exploratory ❑ 202 -257 - 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20520- 60 -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 ❑ No Kasilof South 1L1 - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL- 0384534; ADL- 0384529," ADL- 0389502 Kasilof Field / Tyonek Pool - 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): 17,665' - 9,999'• 17,543' 9,885'_ NA NA Casing Length Size MD TVD Burst Collapse ' Structural Conductor 99' 20" 130' 130' 3,060 psi 1,500 psi Surface 2,829' 13 -3/8" 2,860' 2,383' 3,450 psi 1,950 psi Intermediate - 9,885' 9 -5/8" 9,916' 5,186' 5,750 - 6,870 3,090 - 4,750 Intermediate - 617' 7" 10,533' 5,432' 8,160 psi 7,030 psi Liner 7,726' 3 -1/2" 17,644' 9,980' 10,160 psi 10,540 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 16,438' - 17,409' 8,880' - 9,760' / Tie -back 3 -1/2" L -80 10,333' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): - _ Packers: GT Dual & FHL MD 9,853' & 10,909', 5,161' - 5,582' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 -- Service ❑ 14. Estimated Date for 15. Well Status after proposed w Commencing Operations: Oil ❑ Gas gr(N1�' - WDSPL ❑ Plugged 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 dj P ne (907) 283 -1371 Date May 6, 2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number5', \ s1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED Other: , AY j. 0 '?0l Alaska Oil & Gs$ CO. C n n fission go t4ncfarkgs Subsequent Form Required: _ 7 J APPROVED BY ff Approved by: '+ COMMISSIONER THE COMMISSION Date: C5�0l 1 /// R • MS MAY 13 an p Form 10 -403 Revised 12/2009 Submit in Duplicate 0 • Kasilof South #1 . Kasilof Field Kasilof South #1 (Motherbore- ` Kasilof South #1L1 South Target) (Lateral -North Target) Kasilof Field Kasilof Field 520' FSL, 1340' FWL, 520' FSL, 1340' FWL, Sec. 28, T3N, R12W, SM Sec. 28, T3N, R12W, SM Chemical Injection Nipples Conductor 2540' and 2544' • 20" K -55 Top 0' MD 133 ppf PE Bottom 130' MD 130' TVD Surface Casing "Ill • 13 -3/8" K -55 Top 0' MD Dual Production Tubing :1 68 ppf BTC Bottom 2860' MD 2383' TVD Size - 3 -1/2 ", 9.3#, L -80, Hydril 533 Extends from GT pkr to surface C 1 16" hole with +/ 750 sks 12 ppg cement GT Dual String Packer w /top @9853' MD Size - 9-5/8" x 3-1/2" x 3-1/2" r Intermediate Casinq • • 9 -5/8" L -80 Top 0' MD Dual Tubing Strings ............11 11 �� 40 and 47 ppf BTC Bottom 9916' MD 5186' TVD 3 -1/2 ", 9.3#, L -80, Hydril 533 I Scoophead Diverfer Underreamed Section (SHD) Size - 17 -1/2 "(9850'- 10020'MD) Size - 9-5/8" x 3-1/2" x 3 -1/2" TAML Level 6 FORMation Junction FORMation Junction with Size - 9-5/8" x 7" x 7" =� Leg - Extended Leg Size - 7" x 29# Size - 9 -5/8" x 7" x 7" 9916-9935' MO 1'— I Leg Size - 7" x 29# • 9916-10533' MD ZXP Liner Hanger Packer M FHL Production Packer Size - 7" x 3 -1/2" w/ top © 9923 MI III II Size - 7" x 3-1/2" w/ top @ _ 1 SLPR Liner Hanger Size- 3-1/2x T' with top at10323' 3 -1/2" Liner II RS Nipple 3 set at 10333' MD Tyonek Perfs: I Tyonek Perfs: 16,972' - 16,996' MD, 24 ft, PJ2506 3/24/2004 l I 3 - 1/2" liner 1 1 6 72 4 00 :1 1 6 7 4 320: 3854' MD 16 ft PJ2506 419/2004 17,012'- 17,050' MD, 38 09, PJ2506 3/22&23/2004 / \ MD, , 40 ft PJ2506 4/6 &8/2004 17385-17409 , MD 24 ft PJ2506 4/5/2004 TD: 17,545' MD / 9642' TVD • in \ .." ∎ TD: 17,665' MD / 9999' TVD -- Liner Liner 9918' MD 5187' TVD 3.1/2" L -80 Top 9923' MD 5189' TVD 3 -1/2" L -80 Top 17644' MD 9980' TVD 9.2 ppf Hydril 563 Bottom 17504' MD 9605' TVD 9.2 ppf Hydril 563 Bottom 6" hole with +/- 675 sks. 12.7 ppg cement. 6" hole with +/- 700 sks. 12.7 ppg cement. Kasilof South #1: Total Depth Location Kasilof South #1L1: Total Depth Location 4402' FSL &786' FEL Sec. 25 T3N -R13W, SM 1 2230' FSL & 4382' FEL Sec. 19 T3N -R12W, SM 1 KOP @ 500' MD/TVD KOP @ 500' MD/TVD Build 3.0 deg /100 from 500 -3090' Build 3.0 deg /100 from 500 -3090' Hold 66 -72 deg from 3090 - 13,502' Hold 66 -72 deg from 3090 - 10,533' MD Drop 1.5 deg /100 to 15,674' KOP @ 10,533' MD/5432' TVD at 66 deg Final angle of 27.6 deg Hold 66 deg from 10,533'- 13,097' MD Azimuth: 270 deg. Drop 1.5 deg /100 to 15,665' Final angle of 19.5 deg Azimuth: 316 deg. • • ~, ~,.;~` ~ . ~`. µ~~ MICROFILMED 03101 !2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts~Miicrofilm Marker.doc I)' ~ ~þ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2022570 Well Name/No. KASILOF SOUTH 1L1 Operator MARATHON OIL CO API No. 50-133-20520-60-00 MD 17665 TVD 9999 Completion Date 4/15/2004 Completion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION Directional surve~ Mud Log Yes Samples No DATA INFORMATION Types Electric or Other Logs Run: Reeves Quad Combo: GR/Cal/Den/Neutron/SoniclArray Induction Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type I~ j'¿g }JOg Electr Digital Dataset Med/Frmt Number Name Mud Log Mud Log See Notes Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 2 Col 10570 17665 Open Drim09 Dyoom;" __ I 2 Col 10570 17665 Open 2 Col 10570 17665 Sample Interval Set Start Stop Sent Received Number Comments . l 10560 17665 4/22/2004 1131 Daily History Received? ~N Formation Tops &)N Well Cores/Samples Information: L ~ -' Cuttings ADDITIONAL INFORMATION Well Cored? Y Ð Chips Received? ~J Analysis Received? ~ comme~ #I]~O> Compliance Reviewed By: .~ Date: I ~ (Vl~. ~Co \ . . ,"'_. __ ~J . . Alaska Asset Team Northern Business Unit Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-1350 April 10, 2005 EIVED MAY 1 2 2005 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Alaska & Cons. Commissicm Am::hClfsge Dear Mr. Aubert: Attached and submitted for your records is a revised Page 1 of the Form 10-407 for the completion work performed in the Kasilof South #1 L 1. The revision corrects the casing, liner, and cementing record information posted on the original submission. If you would like any other information, please contact me at 283-1311 or kdwalsh@marathonoil.com. Sincerely, \~,-'b W~ Ken D. Walsh Senior Production Engineer Enclosure ORIGI[~AL ~"'~-- ,,;; _ STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COMMIS RECEIVED WELL COMP~ ETION OR RECOMPLETlON REPORT ANDiv~pr')'Jnnc 1 a. Well Status: OilD Ga... Plugged U Abandoned I I c;;.b. WAGD 1 b. Well Class: .~ ~oJ 20AAC25.105 ........ 20AAC 25.11~ DevelopmAlaID & GMP!ø~1iQ~t8 mi \. ....Vi ·ò. GINJD WINJD WDSPL D No. of Completions Other Service D StratiaraDhic Test 2. Operator Name: 5. Dat~a~ ~~ 12. Permit to Drill Number: '0' MARATHON OIL COMPANY Aban .: 202-257 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 1949, Kenai, AK 99611-1949 October 14, 2003 50-133-20520-60 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 520' FSL & 1340' FWL Sec. 28 T3N- R12W, SM December 28, 2003 Kasilof South #1 L 1 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 1865' FSL & 4030' FEL Sec. 19 T3N-R12W, SM 104' WildcatIT yonek Total Depth: 9. Plug Back Depth(MD+TVD): 2230' FSL & 4382' FEL Sec. 19 T3N-R12W, SM 17,543' 9885' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 250209 y- 2310138 Zone- 4 17665' MD 9999' TVD ADL-384534, 384529, 389502 TPI: x- 239696 y- 2316990 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 239256 y- 2317357 Zone- 4 18. Directional Survey: Yes 0 No D 19. Water Depth, if Offshore: 20. Thickness of Permafrost: feet MSL 21. Logs Run: Reeves Quad Combo: GRlCal/Den/Neutron/SoniclArray Induction 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED NIA 20" 133# K-55 0' 130' 0' 130' Driven NIA 13-318" 68# K-55 0' 2860' 0' 2383' 16" in place, 750 sx NIA 9-5/8" 40 & 47# L-80 0' 9916' 0' 5187' 12-1/4" in place, 2200 sx NIA 7" 29# L-80 9916' 10533' 5186' 5432' 12-1/4" Cemented with 9-5/8" csg. NIA 3-1/2" 9.2# L-80 9918' 17644' 5187' 9980' 6-1/8" in place, 700 sx NIA 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) 16438-16454' MD, 16 ft PJ2506, 6 SPF, 0.35" EH 4/9/2004 3-1/2" 9918' 9853' 17280-17320' MD, 40 ft PJ2506, 6 SPF, 0.35" EH 4/6&8/2004 17385-17409', MD 24 ft PJ2506, 6 SPF, 0.35" EH 4/5/2004 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I~as-Oil Ratio: Test Period ~ N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. N/A 24-Hour Rate ..... NIA 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". Lithology - interbedded sandstone, shale and coal ""'~'" ro"A)" ~P~A !J 2rJJ?: -- 5s;on Form 10-407 Revised 12/2003 CONTINUED ON REVERSE Kasilof South #1 L 1 (Lateral-North Target) Kasilof Field 520' 1340' FWL, Sec. 28, 13N, R12W, SM L Conductor 20" 133 ppf K·55 PI: Top Bottom O'MD 130' MD 130' TVD Surface Casing 13·3111" 68 ppf K-55 BTC Top Bottom O'MD 2860' MD 2383' TVD 16" hole with +1· 750 sks 12 ppg cement Dual 3-1/2" GT Packer @ 9853' MD/5161' TVD. Intermediate Casing 9·5/8" 40 and 47 ppf 40 ppf L-80 Top 0' MD BTC Bottom 9916' MD 5186' TVD BTC From 2729' MD to 9677' MD 7" 29 ppf L·80 Top Bottom NV 10533' MD 9916' MD 5432' TVD 5186' TVD Formation Tops: 12-1/4" hole with +/- 1550 sks 12.7 ppg + 650 sks 15.7 ppg Sterling Beluga Tyonek T-1 Tyonek T·2 Tyonek T -3 TO Depth (MD) Depth ¡TVD) N/A N/A Proposed Tvonek Perfs: 17386-17410,24 ft (4401 psi @ 9761' TVD) 17280-17320,40 ft (4422 psi @ 9678' TVD) 16444-16474,30 ft (4422 psi @ 8913' TVD) 15670·15711,41 ft (4422 psi @ 8220' TVD) 15344-15404,60 ft (4422 psi @ 7947' TVD) 15209·15234,25 ft (4422 psi @ 7802' TVD) 15124-15190,66 ft (4422 psi@ 7765' TVD) 15064-15075,11 ft (4422 psi@ 7671' TVD) 14896·14916,20 ft (4422 psi @ 7545' TVD) 14863·14878,15 ft (4422 psi @ 7516' TVD) Liner 3-1/2" L-80 Top 9918' MD 9.2 ppf Hydrii 563 Bottom 17644' MD 6·1/8" hole with +/·700 sks. 12.7 ppg cement. 5187' TVD 9980' TVD KasUofSouth #1 KasilofField Kasilof South #1 (Motherbore- South Tar!:1et) Kasilof Field 520' FSL, 1340' FWL., Sec. 28, T3N, R12W, SM Size- 20"' K·55 Top O'MO 133 ppf PE Bottom 130' MO 130' TVO Top O'MO BTC Bottom 2860' MO 2383' TVO 16"' hole with +/. 750 sks 12 ppg<:ement Intermediate Casino 9·5/8"' Top O'MO 40 and 47 ppf BTC Bottom 9916' MO 5186'TVO Size· 3-1/2'. 9.3#. L-~O, Hydnl533 Extends fromGT pkr to surface- 3-112',9.3#. 9-5I8~ x 3-112" x 3-1/2" Le¡gSiz:e - r.x 29# 99W·10533' MD 10.909' TO: 17,545' MO / 9642' TVO TO: 17,665' MO 1 9999' TVO Liner 3-112"' l-80 Top MO 9.2 ppf Hydtil 563 Bottom 6"' hole with +1- 675sks. 12.7 ppg <:ement. 5189' 9605' TVO 9918' MO l-80 Top 11644' MO 9980' TV!) 9.2 ppf HydrO 563 Bottom 6"' hole with +/- 700 sk$. 12.7 ppg <:ement. · . ~...~........".II#IíiP~;, ". .. bL. Kasilof South 1 Lateral 1 Drilling (Reports 63B - 78A) . . MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD TVD 110.0 10,680 5,493 AUTH MD WBS RPT# DATE 63B 17-Dec-2003 WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Castleman I Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Rota drillin 10,680'. OPERATION COMMENTS Drill from KOP @ 10,570 to 10,680'. KB S'ADl\^,R~ r.OST RIG PHONE MOCWI NRI 100.0000 907-260-6935 COUNTY/OTHER L~AI\.Vrl" MANHRS WORKED ACCIDENT TYPE 63.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Confined space entry. LAST SAFETY MTG 12/17/2003 BOP PSI TEST 12/15/2003 REGULATORY INSP? N LAST RIG INSPECTION 12/11/2003 03:30 05:00 10,570 10,630 AF DRLPR DRILL 05:00 06:00 1.00 10,630 10,680 AF DRLPR DRILL Kick Kasilof South #1-L 1 off out of FORMation Junction leg #1. Wash in hole from 7" casing shoe @ 10,533' to top of kick-off plug @ 10,570'. Slide drill from 10,570' to 10,630'. Rotary drill from 10,630' to 10,680'. Note: Transfer $517,000 booked cost from the Kasilof South #1 Motherbore to Kasilof South #1-L 1 Formation Junction Location cost Rig availability fee Rig mob cost 1/1 BHA SHANO. TQRQUE (maximin) 1 1,799.26 0 240 90 150 21,000/19,000 BHA DESCRIPTION Tri-Cone Bit, 4-3/4" 1 DEG M1-XL Motor, 5-7/8" NM WBS , 4-3/4" NM Pony Collar, NM Stop Sub, 4-3/4" On-Trak MWD , 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub, 5 JTS 4" HWDP , 45 JTS 4" HWDP , Cross-Over NO. MAKE OF PUMP 3 NATIONAL KILL SPM I PRESSURE Printed: 4/29/2004 4:05:42 PM WELL NAME KASILOF SOUTH 1 L 1 MD 10,533.0 10,583.0 INCL 66.64 65.30 AZIMUTH 289.50 294.11 Marathon R&K Industrial Baker Hughes Inteq Epoch Well Services LAST BOP TEST: 12/15/2003 7.000 MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas SURVE TVD VS N/S CUM EIW CUM DOGLEG 5,432.25 0.00 3,585.92 -7,356.33 0.00 5,452.62 7,731.76 3,602.87 -7,398.72 8.84 SERVICE INCL 64.86 65.20 AZIMUTH 296.92 297.48 PERSONNEL-DATA NO, HOURS COMPANY 2 5.00 M-I Drilling Fluids 4 10.00 Nabors Alaska Drilling 3 7.50 Veco Alaska 1 2.50 (psi) @ (ppg) DATE 17 -Dec-2003 N/SCUMEIW CUM DOGLEG 5,466.10 7,758.94 3,615.37 -7,424.90 8.08 5,479.19 7,785.55 3,628.21 -7,449.90 1.97 SERVICE 2.50 33.00 2.50 12/22/2003 8,160 Printed: 4/29/2004 4:05:42 PM . MJ.XRJ.XmH(1i)N(øII...CØM~J.XN¥ P¡3ge1····df2 Ðãily Ðti Iliftig~~port E~pIØi.UttiønGª$ WELL NAME KB IGL 24 HR PROG TMD TVD DFS IDOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 252.0 10,932 5,591 64 64 64 18-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman / Ratliff Nabors 273E DX0309032CAPDRL !.... FIELD NAME RIG PHONE MOCWI NRI I DAILY WEII rn~-r 1_.... .... -~_..- WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 - - -. . STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 7.000 (in) (ÍÙ 10,533 (ft) 3.500 (in) (ÍÙ 17,300 (ft) 16.02 CURRENT STATUS / MTS 24 HR FORECAST CuttinQ drill line. OPERATION COMMENTS Drill from 10,680' to 10,932'. Re-Test 7" casing shoe. Trip for bit. SJ>lFETYSUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? LAST RIG INSPECTION 532.50 None 12/18/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Laying down drill pipe. Smoking policy on location. ·.i ~- ""'·.·.··¿,;,ä~ ....... ~ FROM TO. H~S If#JI\II "(9 T~ê~.> ".....'~ 06:00 07:00 1.00 1 0,680 10,717 AF DRLPR DRILL Rotary drill from 10,680' to 10,717'. ART 0.5 hours. 07:00 08:00 1.00 10,717 10,717 AF DRLPR CIRC Circulate bottoms up. 08:00 09:30 1.50 10,717 10,717 AF DRLPR TRIP Backream to 7" casing shoe @ 10,533'. Ream I backream thru kick-off point from 10,570' to 10,630', wiping out curve. 09:30 10:30 1.00 10,717 10,717 AF DRLPR TEST FIT test 7" casing shoe @ 10,533' MD /5417" TVD to 16.0 PPG EMW (1,975 psi with 9.0 ppg mud). Monitor pressure decrease to 1,565 psi in 15 minutes. 10:30 11:00 0.50 10,717 10,717 AF DRLPR TRIP Wash in hole to bottom @ 10,717'. 11:00 14:30 3.50 10,717 10,932 AF DRLPR DRILL Rotary drill from 10,717' to 10,932'. ART 2 hours. Drill north of the 3-1/2" liner top in KS #1 lateral with 36' of clearance. 14:30 16:30 2.00 10,932 10,932 AF DRLPR CIRC Circulate bottoms up. 16:30 22:00 5.50 10,932 10,932 AF DRLPR TRIP TOOH with 5-1/2" drill pipe. UD 12 joints of excess drill pipe from derrick. 22:00 00:30 2.50 10,932 10,932 AF DRLPR TRIP Finish TOOH with 4" drill pipe and BHA. 00:30 01:00 0.50 10,932 10,932 AF DRLPR TRIP UD tri-cone bit, P/U PDC bit. 01:00 02:00 1.00 10,932 10,932 AF DRLPR MwdLwd Download new version of software to MWD tool. 02:00 03:30 1.50 10,932 10,932 AF DRLPR TRIP TlH with BHA to 1514'. 03:30 04:00 0.50 10,932 10,932 AF DRLPR TRIP Shallow test MWD tool. 04:00 06:00 2.00 10,932 10,932 AF DRLPR RIG Slip & cut drill line. [PPI I ECDI ¡M~DDJ>l"'ÄliliIçQ~T/1 IcIJMÇq$'" '- DI::N$ITY(ppg) 9.00 -,,-- FV PV¡y.p GI::LS I I· Fcrr.S(jL ..i ···.i.··.i .öf\IJ>%$an~/~I3TI~rpfiMfl.çl(cå -!:!$i ~lrIIEIì:$·16~ÞNli. 90 14/32 13/18 I 6.5/ I 1.0/4.0 /96 /0.3 1 8.80/0.1 I 11.0 I 31,000/260 I I 1 1 14 $IZI:: . MANUI'". TYPI:: ""CIA'K'A ~.iQR...TFf' DI::PTH .11\1 Pf'.T!?IN i ,......... on ;.. .ric'" 1 /1 6.000 HTC STX-1 5038988 18/18/18/////// 10,570.0 12/17/2003 2-2-WT-A-E- 1-NO-BC 2/2 6.000 HTC HCR 405 7103526 16/16/16/16////// 10,932.0 12/18/2003 3-3-WT-A-D- I-PN-PR BIT / RUN WOB 1 RPM 1 GPM PRI::SS P BIT I HRS I 24Hr DIST I 24Hr ROP 1 CUM HRS I CUM DEPTH I CUM ROP 1 /1 20 / 25 I 396 / 396 I 301 2,300 135 I 2.50 I 252.0 I 100.80 I 5.00 I 362.0 1 72.40 Printed: 4/29/2004 4:05:45 PM · MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas Page 2 of 2 WELL NAME KASILOF SOUTH 1 L 1 DATE 18-Dec-2003 BHA NO. BHA TORQU!2(mð)Ç!!11in) / PDC Bit. 4-3/4" 1 DEG M1-XL Motor, 5-7/8" NM WBS ,4-3/4" NM Pony Collar, NM Stop Sub, 4-3/4" On-Trak MWD , 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub, 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe, Cross-Over NO; 2 3 MAK!20F PUMP NATIONAL NATIONAL PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 12.000 12.000 6.000 72 301.40 COMPANY Marathon R&K Industrial Baker Hughes Inteq Epoch Well Services PERSQNN NO. HOURS 2 48.00 M- Drilling Fluids 4 48.00 Nabors Alaska Drilling 4 84.00 Veco Alaska 4 48.00 Alaska Oil Sales PRESS. (psi) TOTAL Q 301.40 2,300 301.40 35 35 900 900 MD 10,673.0 65.47 10,770.0 66.72 297.52 297.68 SU TVD VS UM EIW CUM DOG 5,490.46 7,808.82 3,639.54 -7,471.66 1.01 5,529.76 7,892.96 3,680.62 -7,550.25 1.30 1.62 2 24.00 23 276.00 1 2.50 1 2.00 CASING SUMMARY LAST CASING TEST: 12/17/2003 7.000 1,975 (psi) @ 9.00 (ppg) NEXT BOP TEST: 12/22/2003 8,160 Printed: 4/29/2004 4:05:45 PM MA.RA.lJt7IØN·...·ØIL...CØM·PA.N~ O~lly~ri!l·ing.··...R~þørt E~plóit~tiQn Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1L 1 30.6 74.00 12,020 6,051 65 65 65 19-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman / Ratliff Nabors 273E DX0309032CAPDRL FIELO NAME RIG PHONE MOC WI NRI I DAILY WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 ..I STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFf Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,300 (ft) 16.02 CURRENT STATUS 1 MTS 24 HR FORECAST Rotarv drillinq la! 12,020'. OPERATION COMMENTS Finish tripping in hole. Slide & rotary drill from 10,932' to 12,020'. S~EE"f¥StlMM~RY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 509.00 None 12/18/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Smoking policy on location. First day back. .... NSStlMMÄ.RY ~ IliFRQIY1 JQ ·.·fI~$ FRQIY1 "j"Q .i§Uß TRBL 06:00 06:30 0.50 10,932 10,932 AF DRLPR RIG Finish cutting drill line. 06:30 07:30 1.00 10,932 10,932 AF DRLPR RIG Service rig and top drive. Inspect rig draworks gear shift switch. 07:30 14:00 6.50 10,932 10,932 AF DRLPR TRIP Finish TIH to 10,788'. 14:00 14:30 0.50 10,932 10,932 AF DRLPR TRIP Wash 144' to bottom @ 10,932'. 14:30 06:00 15.50 10,932 12,020 AF DRLPR DRILL Build turn to north target azimuth. Slide & rotary drill from 10,932' to 12,020'. AST 6.6 hours, ART 4.3 hours. "'.' ". '\~~~I 9.20 I~~I ~o.oo ~Y!I~. 0.00 Fvi p'viyp GFl.,ª1 Ii 2.0/4.0 1/95 11.5 9.10/0.1 I 0.1/1.8 31~~~~l <~~i.i·I~RRi;rî 69 14/31 15/16 I 6.0/ I I 14 .,,,,nl .···i.SITS ~.ÖATF<I.N ...Ll"\,f¡"....CD~ IßIT/RlIN SIZE IY1Î\N.ØI::' T'(I'~ dEl'S ÓR TfA... r 2/2 6.000 HTC HCR 405 I 7103526 I 16/16/16/16/l//// 10,932.0 12/18/2003 I 3-3-WT-A-D- I-PN-PR BIT I RUN WOB I RPM I GPM PRESS P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP 2/2 5/15 1311 /4361 301 2,900 125 10.90 I 1,088.0 I 99.82 I 10.90 I 1,088.0 I 99.82 ... <BMA' ... 'VIVVU [I"".lr\JtrRHRg~ Rt4i.i\,K IEFFy\IT. PICKUP LA' I~HÄH '{S . II¡¡QI.H~ c:: ILI;:'~",,'n· ,'"' I. IJ\..I.~'-Iu.t: 2 I 8,208.41 I 0 220 I 105 I 150 I 14,500/14,500 I I I I I BHA DESCRIPTION PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 5-7/8" NM WBS , 4-3/4" NM Pony Collar, NM Stop Sub, 4-3/4" On-Trak MWO , 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub, 5 JTS 4" HWDP 82 Stands 4" Drill Pipe, Cross-Over PUMP1HYDRÞ.UL..IC.·DATA .NC); MAKE. OF PUMP STRQKE(ihJ pt'-IER(in) SPM Q(gpffjJ PReS$.(pSi) TOTALQ KILLsPI'i1 rÞ~E$SI.lRE 2 NATIONAL 12.000 6.000 72 301 .40 2,900 301.40 30 900 3 NATIONAL 12.000 301.40 30 925 MtlDGAS I UNITS AVG. CONN: I AVG. TRIP: I AVG. BKGRD: 20 MAX. CONN: MAX. TRIP: MAX. DRL: 38 Printed: 4/29/2004 4:05:47 PM MAR.~mæ€!i)N€!i)IL.S€!i)..M RANi\': K ~ rQ~"'4 ~~iIYÐriJ·Jin9i~~PQn E){ploitatiÒI'1Ga$ . WELL NAME IKB IGL 24 HR PROGITMD ITVD IDFS IDOL IRPT# ¡DATE KASILOF SOUTH 1 L 1 30.6 74.00 12,020 6,051 65 65 65 19-Dec-2003 lJ RVEY DATA MD INCl AZIMUTH TVD VS N/S CUM EIWCUM DOGLEG MD INCl AZIMUTH WD VS .u:-, 10,903.0 68.75 297.02 5,580.15 8.009.56 3,737.09 -7,659.61 1.53 11,475.0 63.05 307.04 5,817.03 8,510.02 3,999.96 -8,107.81 2.82 10,998.0 67.97 297.33 5,615.18 8,093.14 3,777.42 -7,738.17 0.88 11,570.0 63.49 311.06 5,859.78 8,594.22 4,053.40 -8,173.68 3.81 11,094.0 66.66 298.28 5,652.21 8,177.29 3,818.73 -7,816.51 1.64 11,662.0 64.39 312.48 5,900.19 8,676.64 4,108.46 -8,235.31 1.70 11,189.0 65.45 299.55 5,690.76 8,260.28 3,860.70 -7,892.51 1.76 11,759.0 64.96 314.14 5,941.69 8,764.22 4,168.60 -8,299.10 1.65 11,285.0 63.83 301.40 5,731.88 8,343.86 3,904.69 -7,967.27 2.42 11,856.0 65.35 316.27 5,982.45 8,852.22 4,231.06 -8,361.11 2.03 11,382.0 63.31 304.12 5,775.06 8,428.40 3,951.68 -8,040.31 2.57 RE~.EL-DATA nr"''' No.. Hgp ........ ·C9M~ANY . COMPANY SERVICE ",g. H9YR$ Marathon 2 48.00 M-I Drilling Fluids 2 24.00 R&K Industrial 2 24.00 Nabors Alaska Drilling 23 276.00 Baker Hughes Inteq 4 84.00 Alaska Oil Sales 1 2.00 Epoch Well Services 4 48.00 Oilfield Hot Shot Service 1 3.00 CASIÑG·S.tJIVîIlllÄRY ..... > LAST BOP TEST: 12/15/2003 LAST CASING TEST: 12/17/2003 NEXT BOP TEST: 12/22/2003 c: r71: li,,\ ilJbiin) ·1'>MUc. iliMDù't) I TV[)(ft) .} ·.··WT(lb/ft) Ii çg~PE···I¡::¡¡·¡~~Tirì"i\ 7.000 I 6.184 I 16.02 I 1 ,919 (psi) @ 9.20 (ppg) I 10,533 I 5,417 I 29.00 I L-80 I 8,160 Printed: 4/29/2004 4:05:47 PM MÞiRÞiTHØN OIL. CØMPÞiNY Page tot? DailY Dri.lling Røport ExpløitätiooGas WELL NAME KB IGL 24 HR PROG TMO TVD DFS IDOL IRPT# DATE KASILOF SOUTH 1L1 30.6 74.00 1,480.0 13,500 6,690 66 66 66 20-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman / Ratliff Nabors 273E DX0309032CAPDRL l~".. ...~" - FIELD NAME RIG PHONE MOCWI NRI DAILY WFI I r{"\~T "'_COT WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAK OFF Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,300 (ft) 16.02 CURRENT STATUS / MTS 24 HR FORECAST Rotary drillina @ 13,500'. OPERATION COMMENTS Drill from 12,020' to 13,500'. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 509.00 None 12/19/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: PPE for mixing mud. .~~ > FROM TO !-IRS FROM TO $I:.JI3 06:00 14:30 8.50 12,020 12,690 AF DRLPR DRILL Slide & rotary drill from 12,020' to 12,690'. AST 2.8 hours, ART 3.3 hours. 14:30 16:30 2.00 12,690 12,690 AF DRLPR CIRC Circulate hole clean for trip. 16:30 18:45 2.25 12,690 12,690 AF DRLPR TRIP Wiper trip to casing shoe. Work thru and wipe out tight spots @ 11,870', 11,780, and 11,740 with 50K over-pull. 18:45 19:15 0.50 12,690 12,690 AF DRLPR RIG Service top drive. 19:15 21:00 1.75 12,690 12,690 AF DRLPR TRIP TIH, wash 125' to bottom. 21:00 05:30 8.50 12,690 13,464 AF DRLPR DRILL Rotary drill from 12,690' to 13,464'. ART 5.3 hours. 05:30 06:00 0.50 13,464 13,500 AF DRLPR DRILL Slide drill from 13,464' to 13,500'. AST 0.6 hours. ~ ~.- . 9.40 lieÞI ~ rAil ~.i. ---- ¡:;y G~ÎiŠ>IWi..iI-lTl-lpJQl'#i~h¡PM <1§ll¢åLIr.'Í~ 1~~16RêMS 68 14/33 I 14/19 I 5.41 I 1.0/5.0 3/92 0.25/4.0 9.00/0.3 10.1/1.9 31,000/100 I I 14 ..<8. . $IZlõl MANUF. TYeê<. . t·Ciéb'Å'....'h .1. p,6.fèlN t '""'"' 2/2 6.000 I HTC HCR 405 I 7103526 I 16/16/16/16///11I I 10,932.0 12/18/2003 I 3-3-WT-A-D- I-PN-PR I3IT / RUN I WOI3 I RPM I GPM I PRESS P BIT HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP 2/2 I 5/20 I 323 / 448 I 314 I 3,400 138 12.00 I 1,480.0 I 123.33 I 22.90 I 2,568.0 I 112.14 ..... :. I SHANO. l~fF WJ. IÞlbKtlP ISLAç~uq t<Y I V)/I . SHlI,HRS IIAR1-IR~ IMWþHRglMjrR HRS $$HR$ 2 I 8,208.41 I 0 225 I 115 I 165 I 16,000/14,000 I I I I I SHA DESCRIPTION PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 5-7/8" NM WBS ,4-3/4" NM Pony Collar, NM Stop Sub, 4-3/4" On-Trak MWD , 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub, 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe, Cross-Over PUMP1HYDRAULlCDATA NO. MAKE OF PUMP STROKIõ(i i) LINER(in) SPM q(gprrt) PRESS. (psi) TOJALQ KILLSPMIÞRE$SURE 1 NATIONAL 12.000 313.96 30 1,125 2 NATIONAL 12.000 6.000 75 313.96 3,400 313.96 30 1,100 . Printed: 4/29/2004 4:05:48 PM · MARA1fHC>.NG:>II...·.eC>MBANY PailyJJ:)til.lingRepott E)(pl()itªtion$~s WELL NAME IKB IGL 24 HR PROGITMD ITVO IDFS IDOL RPT# I~ATE KASILOF SOUTH 1L 1 30.6 74.00 1,480.0 13,500 6,690 66 66 66 20-Dec-2003 MUÐ>GAS 1 UNITS I AVG. CONN: I AVG. TRIP: 50 I AVG. BKGRD: 30 MAX. CONN: MAX. TRIP: MAX. DRL: 66 SU~VEYÐÄ;rÄ .. MD INCL AZIMUTH 1YP vs N/S>GUM <¿/W GUMtDOGL<¿G MD INCL fo\411VIl) 1M. .rvp VS Nis ph 11,952.0 66.05 315.81 6,021.95 8,939.72 4,294.04 -8,421.85 0.85 12,722.0 62.53 316.13 6,348.94 9,636.50 4,797.88 -8,903.17 0.46 12,049.0 66.81 315.35 6,060.74 9,028.62 4,357.54 -8,484.08 0.90 12,815.0 62.99 315.86 6,391.50 9,719.19 4,857.35 -8,960.61 0.56 12,144.0 66.19 316.14 6,098.62 9,115.74 4,419.93 -8,544.87 1.00 12,907.0 63.84 315.73 6,432.68 9,801.46 4,916.33 -9,017.98 0.93 12,240.0 66.25 316.33 6,137.33 9,203.59 4,483.38 -8,605.64 0.19 13,000.0 64.33 315.31 6,473.32 9,885.11 4,976.01 -9,076.59 0.67 12,336.0 65.02 316.66 6,176.94 9,291.03 4,546.80 -8,665.84 1.32 13,097.0 64.80 315.07 6,514.98 9,972.70 5,038.16 -9,138.32 0.53 12,430.0 64.94 316.49 6,216.69 9,376.21 4,608.67 -8,724.39 0.18 13,192.0 64.74 314.68 6,555.47 10,058.6 5,098.79 -9,199.22 0.38 12,526.0 62.90 316.93 6,258.89 9,462.42 4,671.42 -8,783.52 2.16 13,288.0 64.27 314.22 6,596.80 10,145.2 5,159.47 -9,261.08 0.65 12,623.0 62.59 316.64 6,303.31 9,548.64 4,734.27 -8,842.56 0.42 13,385.0 63.51 314.24 6,639.49 10,232.3 5,220.23 -9,323.49 0.78 ~NN.ELiQ1i.·. Nq.· Nþ.. . S>' . ·.CQ Marathon 2 48.00 Nabors Alaska Drilling 23 276.00 R&K Industrial 2 24.00 Alaska Oil Sales 1 2.00 Baker Hughes Inteq 4 84.00 Peninsula Sanitation 1 2.00 Epoch Well Services 4 48.00 Alaska's Best Water 1 1.00 M-I Drilling Fluids 2 24.00 ..., .!> LAST BOP TEST: 12/15/2003 LAST CASING TEST: 12/17/2003 NEXT BOP TEST: 12/22/2003 slZEiill) IIDiHiTlsHOE TESTIPddjl ...MA"j(sl(;lp F MD(ftj I .TVQ;I(Ü il· .;~'" J Ag.g.... I 7.000 I 6.184 I 16.02 I 1,862 (psi) @ 9.40 (ppg) I 10,533 I 5,417 I 29.00 I L-80 I 8,160 Printed: 4/29/2004 4:05:48 PM . MA'RA'7EH€>N<€>1 LG€>M PA'N¥ P¡ag$<·4···öf2 Daily ·Drillir1.gR(i!pört ExploitatiÖhGas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 1,115.0 14,615 7,324 67 67 67 21-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman / Ratliff Nabors 273E DX0309032CAPDRL I I DAILY WELL COST ! CUM WELL COST - FIELD NAME RIG PHONE MOCWI NRI WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 - STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 7.000 (in) (â) 10,533 (ft) 3.500 (in) (â) 17,300 (ft) 16.02 CURRENT STATUS / MTS 24 HR FORECAST Slide drillinq (â) 14,615'. OPERATION COMMENTS Slide and rotary drill from 13,500' to 14,615'. SAEETYSUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I~GULATORYINSP7 I LAST RIG INSPECTION 514.00 None 12/20/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Tripping pipe safely. ~~ÄR¥ ... ..... .... FROM TO flR$ FROM ·1'0 $~ß ..... ",..,,,..,,...,,. ..".... 06:00 21:00 15.00 13,500 14,587 AF DRLPR DRILL Slide and rotary drill from 13,500' to 14,587'. AST 3.3 hours, ART 7.5 hours. Begin decreasing hole angle @ 13,500' into Tyonek Sand interval. 21:00 23:30 2.50 14,587 14,587 AF DRLPR CIRC Circulate hole clean for trip. 23:30 03:00 3.50 14,587 14,587 AF DRLPR TRIP Slug pipe, TOOH for wiper trip from 14,587' to 12,691'. Work in tight hole, working thru and wiping out numerous tight spots with 40K to 60K over-pull. Continue TOOH an additional 479' thru previous wiper trip interval to 12,212'. Hole ok above 12,499'. 03:00 03:15 0.25 14,587 14,587 AF DRLPR RIG Service top drive. 03:15 04:30 1.25 14,587 14,587 AF DRLPR TRIP TIH to tight spot @ 14,304'. 04:30 05:30 1.00 14,587 14,587 AF DRLPR TRIP MIU top drive. Attempt to establish circulation with hole packing off. Work pipe and establish circulation, working pump rate up slowly. Ream / backream thru tight spot @ 14,304' until gone. Wash / ream in hole 283' to bottom @ 14,587'. 05:30 06:00 0.50 14,587 14,615 AF DRLPR DRILL Slide and rotary drill from 14,587' to 14,615'. AST 0.1 hours, ART 0.1 hours. Wiper trip gas 500 units. 9.60. I$çp IN~IUAILYÿ9¡;;T 1 lçq~tÇQ$T -- A FV . ~V/'fP ·9$1..$ I þ/'fl 'IÞh/pNtI!'WW .1 çl(ça I Çåci2(Wt9f.f Hi$ l.IM!?I·E$T~R~iW 63 15/39 15/19 I 4.6/ I 1.0/7.5 3/89 0.25/7.0 1 9.50/0.4 10.2/0.21 32,000 /80 I I I 17 BITS .... ßIT/R.lJN\SI4E MANUF. TYPE I>$!?RIÀLNQ, 1 . ..J!?"fsÞRTFÀ . . I PE;PTH I/IIPATE;J"" I "........ .r-Ll::! 2/2 I 6.000 HTC HCR 405 1 7103526 1 16/16/16/16////// 1 10,932.0 12/18/2003 I 3-3-WT-A-D- I-PN-PR BIT 1 RUN WOB 1 RPM 1 GPM PRESS PBIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS ICUM DEPTH 1 CUM ROP 2/2 5/20 1311 /4361 301 3,800 130 I 11.00 1 1,115.0 1 101.36 I 33.90 1 3,683.0 1 108.64 BHA BHANO. 1 LENGTH IEFFWr PICK UP 1~I.ACK OF~HÖT\NT. ITQRQUE (ma¡qmin) IBHAHR$ IJAf{HRS IMWDHRSIMTR HRS IS5 HRS 2 I 8,208.41 I 0 250,000 I 120,000 I 175,000 I 17,500/14,000 I I I I I BHA DESCRIPTION PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 5-7/8" NM WBS , 4-3/4" NM Pony Collar, NM Stop Sub, 4-3/4" On-Trak MWD , 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar , 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub, 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe , Cross-Over Printed: 4/29/2004 4:05:52 PM · M~R~mHmrsl.·mIL<mmMPJ.XrsI¥ Page2Øt2 DáilyDrilHrigHepørt eXpIQit~ti()I'lGas WELL NAME IKB [GL 24 HR PROGITMD ITVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1L 1 30.6 74.00 1,115.0 14,615 7,324 67 67 67 21-Dec-2003 PUMPIHYÐRAULlCÐA'"UA NO. MAKE OF PUMP STROKE (ih) I,IIIIER(in) SPM Q(gpm) PRESS.(p~i) TOTAkQ KILL sÞM.} 2 NATIONAL 12.000 301.40 30 1,300 3 NATIONAL 12.000 6.000 72 301.40 3,800 301.40 30 1,350 MUÐGAS 1 UNITS I AVG. CONN: I AVG. TRIP: 500 I AVG. BKGRD: 50 MAX. CONN: MAX. TRIP: MAX. DRL: 195 ·.···~lJrcv DAT, .... MQ INCI, AZIMUTH liVct 'IS IlIIiS ¡:;h <MP INCL .'¥'UV!\J ,r TVD 'IS .,." 13,480.0 62.56 314.54 6,682.56 10,316.9 5,279.46 -9,383.99 1.04 14,046.0 56.83 316.59 6,966.07 1 0,806.5 5,636.49 -9,719.05 1.88 13,574.0 61.62 316.42 6,726.56 10,399.9 5,338.68 -9,442.24 2.03 14,141.0 54.61 317.08 7,019.57 10,884.9 5,693.74 -9,772.75 2.38 13,670.0 60.60 317.91 6,772.95 1 0,484.0 5,400.31 -9,499.38 1.72 14,237.0 53.08 317.33 7,076.21 1 0,962.4 5,750.62 -9,825.41 1.61 13,765.0 59.81 317.08 6,820.15 1 0,566.4 5,461.09 -9,555.08 1.13 14,331.0 50.56 317.15 7,134.31 11,036.3 5,804.87 -9,875.57 2.69 13,860.0 59.23 317.15 6,868.34 10,648.2 5,521.07 -9,610.80 0.61 14,425.0 48.90 316.76 7,195.07 11,108.0 5,857.28 -9,924.52 1.79 13,953.0 58.57 316.80 6,916.38 10,727.9 5,579.29 -9,665.13 0.78 14,520.0 46.73 317.30 7,258.86 11,178.4 5,908.78 -9,972.50 2.32 PE~.~#f<~ H~:.~. ,",' ,. N9, . .. .. HO Marathon 2 48.00 Epoch Well Services 4 48.00 R&K Industrial 2 24.00 M-I Drilling Fluids 2 24.00 Baker Hughes Inteq 4 84.00 Nabors Alaska Drilling 23 286.00 i~I..··"'·"'·"'¡¡""~I.· ..« LAST BOP TEST: 12/15/2003 LAST CASING TEST: 12/17/2003 NEXT BOP TEST: 12/22/2003 ~17r::iiriY < ·IE)(in) .·· $I-t~)I:¡\,t;;),·(phb)1 "'; .¡<···<MÓ(ftY. ·..1.·. ·l'\ÎÔ(ft) ·1 ...,.,.".<"¡,,,, t GRADê .··.1 <J:jUKð<1 OCt ·.vv \''''O'} IOSI: 7.000 I 6.184 I 16.02 I 1,806 (psi) @ 9.60 (ppg) 1 10,533 I 5,417 I 29.00 I L-80 I 8,160 Printed: 4/29/2004 4:05:52 PM · MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR RatlifflTrub FIELO NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin at 15,465'. OPERATION COMMENTS Drill to 15,354'. Wiper trip to 12,500'. KB 24 HR PROG TMD 850.0 15,465 AUTH MD TVD 8,000 WBS RPT# DATE 68 22-Dec-2003 30.6 RIG NAME & NO. Nabors 273E SAPIWBS COST I l RIG PHONE MOCWI 100.0000 NRI DA!L Y WELL COST -.lCUM WELL COST NEXT CAv,,,u LEAKOfl- 16.02 907-260-6935 COUNTY/OTHER Drill to 15,465'. MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 508.00 None 12/20/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Review IADC Safety Alerts. SAËErrYSUMMAR¥ BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? 12/15/2003 12/17/2003 N LAST RIG INSPECTION 12/11/2003 06:00 19:30 13.50 14,615 15,354 AF DRLPR DRILL Slide and rotary drill from 14,615' to 15,354'. ART - 4.6 hrs, AST - 5.7 hrs. 19:30 22:00 2.50 15,354 15,354 AF DRLPR CIRC Circulate hole clean, check for flow, mix and pump slug. 22:00 00:30 2.50 15,354 15,354 AF DRLPR TRIP POOH to 12,500'. Average overpuII10-20K. Tight spots and associated overpulls as follow: 14,590' - 14,620 '(50K), 14,500' (40K), 13,950' (35K), 13,880' (50K), 13,700' - (40K), 13,300'- (40K). Overall hole in good condition. 00:30 01:00 0.50 15,354 15,354 AF DRLPR RIG Service top drive and crown. 01:00 03:00 2.00 15,354 15,354 AF DRLPR TRIP TlH to 15,354'. Wash down last 3 stands as precaution. Hole in good shape. 03:00 06:00 3.00 15,354 15,465 AF DRLPR DRILL Slide and rotary drill 15,354' to 15,465'. ART - 1.1 hrs, AST - .4 hrs. Maximum trip gas was 960 u. / PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 5-7/8" NM WBS ,4-3/4" NM Pony Collar, NM Stop Sub, 4-3/4" On-Trak MWD , 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub, 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe, Cross-Over NO. MAKE OF PUMP 1 NATIONAL KILL SPM I PRESSURE 30 1 ,440 Printed: 4/29/2004 4:05:53 PM . M.ÞtR..ÞtJfH<DN....·<DIL.€<DM P.ÞtN¥ '"". ..... . rd~!Z 41,01. E)ªiIYE)rinihg··. R.èpo.1"t EXplöit::1t¡QniG~l$ WELL NAME KB IGL 24 HR PROGITMD TVD IDFS IDOL RPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 850.0 15,465 8,000 68 68 68 22-Dec-2003 PUMPIHWDRAULlC DATA NO. MAKE OF PUMP ISTROKS(irt)l· I.INeR(in) SP~!Q(9PÔi)!PRESS. (psi) I rotALQI KILL SPM 1 pRESSURE 2 NATIONAL 1 12.000 I 1 1 I 293.02 1 30 1 ,400 MUD GAS 1 UNITS 1 AVG. CONN: I AVG. TRIP: 960 I AVG. BKGRD: 14 MAX. CONN: MAX. TRIP: MAX. DRL: 234 ··;lJRVEY..DATA MD INCL AZIMUTH TVD V$ N/SCUM EIVVCUM DOGLEG MD INCL ALIIVIUI.H TYþ. ·87$ .1/<:,....1 14,613.0 45.81 317.07 7,323.15 11 ,245.6 5,958.08 -10,018.1 1.01 15,092.0 36.38 316.89 7,684.72 11,558.7 6,188.16 -10,230.6 1.06 14,709.0 44.24 316.91 7,391.00 11,313.5 6,007.74 -10,064.5 1.64 15.187.0 34.55 316.49 7,762.09 11,613.8 6,228.27 -10,268.4 1.94 14,805.0 41.86 317.60 7,461.15 11,379.0 6,055.85 -10,108.9 2.53 15,288.0 31.57 317.36 7,846.73 11,668.9 6,268.50 -10,306.0 2.99 14,901.0 39.92 317.52 7,533.71 11,441.8 6,102.23 -10,151.3 2.02 15,381.0 29.81 316.73 7,926.70 11,716.3 6,303.24 -10,338.4 1.92 14,996.0 37.35 317.41 7,607.92 11,501.1 6,145.93 -10,191.4 2.71 .... ~ ..... i~~~ .. ciì2bM...ì2 \jq~ .··i'tOI.Í~s Marathon 2 48.00 Epoch Well Services 4 48.00 Veco Alaska 1 18.00 M-I Drilling Fluids 2 24.00 Baker Hughes Inteq 4 84.00 Nabors Alaska Drilling 23 286.00 .CASINGSWMI\IIARV. LAST BOP TEST: 12/15/2003 LAST CASING TEST: 12/17/2003 NEXT BOP TEST: 12/22/2003 >SIZE·Yin) IIDlihY ISHOETESTYnna)!> ... ....~II.ð.y C:IÞP >1 Mbi(ft) .tTVþ(ft} .1.\lVïWþlft} I. r::t"nI:l"\P .1>BURs¡f(þ~¡}·:· 7.000 I 6.184 1 16.02 I 1,806 (psi) @ 9.60 (ppg) 1 10,533 I 5,417 1 29.00 1 L-80 I 8,1 60 Printed: 4/29/2004 4:05:53 PM MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas Page 1 of 2 WELL NAME KB KASILOF SOUTH 1L 1 30.6 SUPERVISOR RIG NAME & NO. Trub Nabors 273E FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATE/PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Pum slu and POOH OPERATION COMMENTS Drill 15,465' - 16,275'. Circulate hole clean. POOH. 24 HR PROG TMD 810.0 16,275 AUTH MD TVD 8,732 WBS RPT# DATE 69 23-Dec-2003 SAPIWB" r-n':¡T DX0309032CAPDRL MOCWI 100.0000 NRI MANHRS WORKED 508.00 ACCIDENT TYPE None LAST SAFETY MTG 12/20/2003 SAFETY SUMMARY BOP PSI TEST LAST STOP CARD AUDIT 12/15/2003 12/1712003 REGULATORY INSP? N LAST RIG INSPECTION 12/11/2003 ACCIOENT DESCRIPTION: SAFETY MTG TOPICS: Inspection of air tuggers and man rider requirements. 06:00 02:30 20.50 15,465 16,275 AF DRLPR Slide and rotary drill from 15,465' - 16,275'. ART - 15.9 hrs, AST - 1.0 hrs. At last attempt to slide, bit weight was not drilling off and motor was stalling. 02:30 05:30 3.00 16,275 16,275 AF DRLPR CIRC Circulate 2 bottoms up, 300 gpm, 3200 psi, 130 rpm. 05:30 06:00 0.50 16,275 16,275 AF DRLPR TRIP Pump slug and POOH / PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 5-7/8" NM WBS ,4-3/4" NM Pony Collar, NM Stop Sub, 4-3/4" On-Trak MWD , 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub, 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe, Cross-Over AVG. CONN: MAX. CONN: KILL SPM J PRESSURE NO. MAKE OF PUMP 1 NATIONAL 58 105 AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: 50 75 MD 15,474.0 Printed: 4/29/2004 4:05:55 PM . MARAffiH€JN.OIL.iS€JMPANY Pªge2 Øf2 D~lIyÐri.U ingRøport Explôitatiòn Ga~ WELL NAME IKB IGL 24 HR PROGITMD ¡TVD ¡OFS IDOL !RPT# ¡DATE KASILOF SOUTH 1L 1 30.6 74.00 810.0 16,275 8,732 69 69 69 23-Dec-2003 SURVEY DATA MD INCL AZIMUTH TVO VS N/SCUM E/WCUM DOGLEG MO INCL AZIMUTH TVD ..·V$ N/S CUM E/WCUM DOGLEG 15,665.0 25.20 314.76 8,178.16 11,848.2 6,398.85 -10,429.2 2.28 15,947.0 25.07 315.85 8,432.74 11,969.5 6,486.66 -10,512.8 0.47 15.760.0 25.93 317.22 8,263.86 11,889.2 6,428.34 -10,457.6 1.36 16,042.0 24.75 315.89 8,518.90 12,009.5 6,515.38 -10,540.7 0.34 15,854.0 25.36 316.61 8,348.60 11,929.8 6,458.05 -10,485.4 0.67 16,139.0 24.01 315.93 8,607.25 12,049.5 6,544.14 -10,568.5 0.76 PERSONNEbÐATA P9ê.@Q6:QQ: COMPANY SERVICE NO. HOURS . COMpANY SERVICE .~p. HÓIJR~ Marathon 2 48.00 M-I Drilling Fluids 2 24.00 Veco Alaska 1 16.00 Nabors Alaska Drilling 23 286.00 Baker Hughes Inteq 4 84.00 S&R Enterprises septic 1 2.00 Epoch Well Services 4 48.00 CASING SUMMARY LAST BOP TEST: 12/15/2003 LAST CASING TEST: 12/17/2003 NEXT BOP TEST: 12/22/2003 ·'IIDfiht.<lsHOÊ·""i4à4 .I <MAXSICP \1 Mod'!)····. 1 ìWÒ:Cft) < 1 ¡." <I liE}!t!IK~T(P$ ) ;:)ILt::·!m) V.V·liuD/m· 7.000 I 6.184 I 16.02 I 1,806 (psi) @ 9.60 (ppg) 1 10,533 1 5,417 I 29.00 1 L-80 1 8,160 Printed: 4/29/2004 4:05:55 PM MARATHON OIL COMPANY Page 1 of 2 WELL NAME KASILOF SOUTH 1L 1 SUPERVISOR Roqer/Trubv FIELO NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS TIH OPERATION COMMENTS POOH and change out motor. Test BOP's. TlH. IDFS IDOL IRPT# DATE 70 70 70 24-Dec-2003 SAPIWBS COST DX0309032CAPDRL 1 _ MOCWI NRI DAILYWELLCO¡;T I~.....····· --- 907-260-6935 100.0000 i _,__ .__ COUNTY/OTHER I LAST CASING NEXT -';ASING ILEAKOFF 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,300 (ft) 16.02 24 HR FORECAST TIH and drill to TD. Daily Drilling Report Exploitation Gas IGL 30.6 74.00 RIG NAME & NO. Nabors 273E 24 HR PROG TMO 16,275 AUTH MD TVD 8,732 WBS KB RIG PHONE MANHRS WORKED I ACCIOENT TYPE I LAST SAFETY MTG 518.00 None 112/20/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Test BOP's. SAFEtFYStJMMÄRY ¡BOP PSI TEST 1 LAST STOP CARO AUDIT 1 REGULATORY INSP? 112/15/2003 112/17/2003 1 N LAST RIG INSPECTION 12/11/2003 1 FROM TO HRS FROM TO SUB 06:00 16:00 10.00 16,275 16,275 AF 16:00 18:30 2.50 16,275 16,275 AF 18:30 00:00 5.50 16,275 16,275 AF - DRLPR TRIP Trip for bit. No unusual drag in open hole. 10-15K drag as motor past bifurcation point. Handling BHA, LD motor, PU new motor and orient same. PU 5" and 4" test joints. Test upper and lower pipe rams, blind rams, stack manual & HCR valves, choke manifold, Hydril, upper and lower top drive safety valves, HT40 & HT55-375 TIW and IBOP valves to 250 / 3500 psi, 5 minutes low and high each test. RD test joints. Pull test plug and install wear ring. Test gas and H2S alarms. Run accumulator test. =1 .. DRLPR TRIP DRLPR TEST 70 15/39 AOGCC witness of BOP test waived by Jim Regg - 0900 hrs 12/23/2003 0.50 16,275 16,275 AF DRLPR TRIP Make up bit and RIH with motor and monels. 0.50 16,275 16,275 AF DRLPR RIG Service rig and top drive. 1.00 16,275 16,275 AF DRLPR TRIP Finish running BHA in hole, shallow test MWD-OK. 4.00 16,275 16,275 AF DRLPR TRIP TIH with 4" DP and 5 1/2" DP. 10.00 1 PP I IECDI IM~ I ~7~~ : W~~P: ~c~7,~n; '-: ~:¡"r' :~',~:~80 I ~,r~ - 00:00 00:30 00:30 01 :00 01 :00 02:00 02:00 06:00 ~ J H2S LIME ·E~· T 6RPM 1 1 TYPE HCR 405 HC407 7103526 7101193 16/16/16/16/1//// 16/16/16/16/11/// [)~EPTH 11\1 nil. T¡:: 11\1 Ln.n.1 "" n " 10,932.0 12/18/2003 3-3-WT-A-D- I-PN-PR 16,275.0 12/24/2003 O-O-NO-A-D- I-NO-BHA å.ITiRUN SIZE 2/2 6.000 3/3 6.000 MANUF. HTC HC "'¡::DIAll\ln BIT I RUN WOB I RPM 1 GPM PRESS P BIT I HRS I 24Hr DIST 1 24Hr ROP I CUM HRS 1 CUM DEPTH I CUM ROP BHÄ BHA NO. ILENGTH. ·.IEFFVVJ;. IRi~K(JP .1 SLACK OF~R9Twr. 1 tORQUE (maximin) .IBH.A,Hþ.S I JARH~$ MWD HR$IMTR.HRß.I~SHR$ 3 I 8,208.44 I I I I / I I I I I BHA DESCRIPTION PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 4-3/4" NM Pony Collar, 5-7/8" NM WBS NM Stop Sub, 4-3/4" On-Trak MWD , Printed: 4/29/2004 4:05:56 PM WELL NAME KASILOF SOUTH 1 L 1 MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas DATE 24-Dec-2003 B A BHA DESCRIPTION 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub 4" HWDP , 82 Stands 4" Drill Pipe, Cross-Over COMPANY Marathon Veco Alaska Baker Hughes Inteq Epoch Well Services SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 48.00 M-I Drilling Fluids 1 16.00 Nabors Alaska Drilling 4 84.00 R&K Industrial 4 48.00 BJ Services 2 24.00 23 286.00 1 6.00 2 6.00 CASING SUM ARY LAST CASING TEST: 12/17/2003 MAX SICP 1,806 (psi) @ 9.60 (ppg) NEXT BOP TEST: 12/22/2003 8,160 Printed: 4/29/2004 4:05:56 PM · MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas WELL NAME KB 24 HR PROG TMO 215.0 16,490 AUTH MD TVD 8,928 WBS RPT # DATE 71 25-Dec-2003 SAP/WBS COST 30.6 RIG NAME & NO. Nabors 273E RIG PHONE MOCWI 100.0000 NR! CUM WFLL COST 1 WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS POOH OPERATION COMMENTS Finish trip in hole. Drill 16,275' to 16,490'. 907-260-6935 COUNTY/OTHER LEAKOFF 16.02 MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 496.00 None 12/24/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Tripping wet pipe. 12/17/2003 REGULATORY INSP? N LAST RIG INSPECTION 12/11/2003 FROM 06:00 07:00 1.00 16,275 16,275 AF DRLPR RIG 07:00 11:30 4.50 16,275 16,275 AF DRLPR TRIP 11:30 14:00 2.50 16,275 16,275 AF DRLPR TRIP Change out saver sub Trip in hole to 16,115', fill pipe every 25 stands. Wash and ream 16,115' to 16,275'. Pump pressure increasing, circulate and work pipe until pressures stabilize. Maximum trip gas - 2,000 units with mud cut from 10.0 to 8.4 ppg. Large volume of fine coal across shakers at bottoms up. Drill directional hole 16,275' - 16,490'. ART - 8 hrs, AST-O hrs. Increase mud weight to 10.2 while drilling. MWD quit pulsing. Circulate hole clean while pumping 300 gpm and rotating 127 rpm. Check for flow, pump slug and POOH. 25-30K overpull first three stands, then 10-15K overpull. Continue POOH for MWD change out. 14:00 00:00 10.00 16,275 16,490 AF DRLPR DRILL 00:00 02:00 2.00 16,490 16,490 TA DRLPR CIRC MWD 02:00 06:00 4.00 16,490 16,490 TA DRLPR TRIP MWD 3/3 CU M ROP 25.63 BHA NO. BHA TORQUE (rT1<1x1rrlih) o 320 140 195 / PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 4-3/4" NM Pony Collar, 5-7/8" NM WBS , NM Stop Sub, 4-3/4" On-Trak MWD , 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub, 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe, Cross-Over Printed: 4/29/2004 4:05:57 PM · MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas Page 2 of 2 WELL NAME KASILOF SOUTH 1L 1 DATE 25-Dec-2003 NO. 1 3 MAKE OFPUMP NATIONAL NATIONAL PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 12.000 6.000 70 293.02 12.000 PRESS. (psi) TOTAL Q 3,500 293.02 293.02 KILL SPMI PRESSURE 30 1,330 30 1,340 70 135 MUD GAS AVG. TRIP: MAX. TRIP: units 18 265 AVG. CONN: MAX. CONN: 2,025 AVG. BKGRD: MAX. DRL: COMPANY Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 48.00 Nabors Alaska Drilling 4 84.00 R&K Industrial 4 48.00 Lynden Transport 2 24.00 Jacknski Sanding 23 280.00 2 8.00 1 2.00 1 2.00 LAST BOP TEST: SIZE in 7.000 NEXT BOP TEST: Printed: 4/29/2004 4:05:57 PM MÄRÄ1H71Ø>NØ>IEeØ>M~ÄN¥ E)aii!yE)rill irtgR~p()rt ~xploitatiønGª$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 16,490 8,928 72 72 72 26-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Roqer/Trubv Nabors 273E DX0309032CAPDRL FIELD NAME RIG PHONE MOCWI NRI I DA!LYWFII ,..,..ro.... !.-.... ...-.. -_~T WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 ." STATElPROV COUNTY/OTHER I LAST CASING I NEXT l;ASING I LEAKOFF Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,300 (ft) 16.02 CURRENT STATUS / MTS 24 HR FORECAST TlH Drill ahead, 6" production hole per plan. OPERATION COMMENTS POOH, change out MWD. TIH. SAFETY SUMMARY . >. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? LAST RIG INSPECTION 536.00 None 12/24/2003 12/23/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Cutting drill line. ~ f.......V ...... .... > .·i··i.··. IIFfiQM IQ <Hfis ·F'8QI\ÌI i$Qij < ... 'I!YI~ 06:00 07:30 1.50 16,490 16,490 TA DRLPR TRIP MWD POOH to 8200', 07:30 08:00 0.50 16,490 16,490 TA DRLPR TRIP MWD Change handling tools to 4". 08:00 12:00 4.00 16,490 16,490 TA DRLPR TRIP MWD POOH to BHA. 12:00 14:30 2.50 16,490 16,490 TA DRLPR TRIP MWD POOH with heavy weight and flex collars, break bit and motor. Change out MWD and surface test same. Make up motor and orient same. 14:30 16:30 2.00 16,490 16,490 TA DRLPR TRIP MWD Make up bit and trip in hole to 1506'. 16:30 17:00 0.50 16,490 16,490 TA DRLPR TRIP MWD Shallow test MWD. Found crow's foot on rig floor, was previously installed in top stand of flex monels. 17:00 18:00 1.00 16,490 16,490 TA DRLPR TRIP MWD POOH to monels, install crow's foot. 18:00 22:30 4.50 16,490 16,490 TA DRLPR TRIP MWD TIH to 8200'. 22:30 23:00 0.50 16,490 16,490 TA DRLPR TRIP MWD Change handling tools to 5 1/2". 23:00 00:00 1.00 16,490 16,490 TA DRLPR TRIP MWD TIH to 9821'. 00:00 02:00 2.00 16,490 16,490 AF DRLPR RIG PJSM. Slip and cut drill line. Check crown-saver. 02:00 06:00 4.00 16,490 16,490 TA DRLPR TRIP MWD TIH, break circulation every 20 stands.. No drag through bifurcation point. Continue TIH. !RP··¡ I~Ç61 1_ .«1.".- _.....1 UÇUMCq$" ' .- .. ......"'!~, 'It'H¡ 10.20 ¡;v ·1·Þ\lrYp. ·Gg~$I.""/UTi.J" 1 F¢/T.~q4< i....0l'fr<PWÞMlpf/Mf þ!/ça ·i fCaCI2(v1~~I;I~S LiMEJ.g~I§RêM 75 16/40 17/21 I 5.0/ 1 1.0/11.0 3/87 0.30/7.5 9.50/0.2 10.2/2.2129,500/1001 I I 1 BITS l;3iT1RI,)N SIZE MANUF. TYPE $pRIALN(j, JETSORTFA i.;Il:.r'1 n '1'1 'pATR !II! lin,n, A... 3/3 6.000 HC HC407 7101193 16/16/16/16/11/// 16,275.0 12/24/2003 O-O-NO-A-D- I-NO-BHA 3RR1 /4 6.000 HC HC407 7101193 16/16/16/16////// 16,490.0 12/25/2003 1-2-CT-S-D-I-LT-TD BIT 1 RUN WOB 1 RPM 1 GPM PRESS P BIT HRS 1 24Hr DIST 1 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP BHA BHA NO. I LENGTH I Eff VVT. PICK UP Icn "1' ·~"VVT. 1 TORQÙ¡: (rnåXlrniri) ISHA HRS JAR HR$ I MWD HR$I MIRf-lRS ISS)-IR$ 4 I 8,208.19 I I I I / I I I I I BHA DESCRIPTION PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 4-3/4" NM Pony Collar, 5-7/8" NM WBS NM Stop Sub, 4-3/4" On- Trak MWD , . . Printed: 4/29/2004 4:05:59 PM MARATHON Oil COMPANY Daily Drilling Report Exploitation Gas Page 2 of 2 AVG. CONN: MAX. CONN: DATE 26-Dec-2003 WELL NAME KASILOF SOUTH 1L 1 BHA BHA DESCRIPTION 3-1/2" NM Flex Collar. 3-1/2" NM Flex Collar. 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, 4" HWDP , 82 Stands 4" Drill Pipe, Cross-Over MUD GAS AVG. TRIP: MAX. TRIP: units AVG. BKGRD: MAX. DRL: SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 48.00 M-I Drilling Fluids 4 84.00 Nabors Alaska Drilling 4 48.00 S&R Enterprises SERVICE 2 25 1 Marathon Baker Hughes 'nteq Epoch Well Services CASISUMMARY LAST CASING TEST: 12/17/2003 MAX SICP MD ft 1,806 (psi) @ 9.60 (ppg) 10,533 NEXT BOP TEST: LAST BOP TEST: 12/23/2003 Printed: 4/29/2004 4:05:59 PM . M~R.Þ"Fl7lmNiml.It..¢mMR~NY Dªi'ME)rillingiR.~p()1"t e~þlºitâtioniCS~s WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 735.0 17,225 9,589 73 73 73 27-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MO WBS I SAPIWR~ rn~T Roaer/Trubv Nabors 273E DX0309032CAPDRL FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL r.n~ CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTY/OTHER I LAST CASING NEXT CASING I LEAKOFF Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,300 (ft) 16.02 CURRENT STATUS / MTS 24 HR FORECAST Drillina Drill to 17,400'. Short trip. POOH to log. OPERATION COMMENTS Wash and ream to bottom. Drill to 17,225'. SAfI::'ETYSOMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I ~OP PSITEST I LAST STOP CARO AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 539.00 None 12/24/2003 12/23/2003 12/17/2003 12/11/2003 ACCIOENT DESCRIPTION: SAFETY MTG TOPICS: Tripping and pinch points IIFRQIV! ·.rq "~RS ~ TQ i$µ~ "N$~ .... .... TRB . "~!' ii 06:00 07:30 1.50 16,490 16,490 TA DRLPR TRIP MWD Wash and ream 16,015' to 16,490', no hole problems. 07:30 06:00 22.50 16,490 17,225 AF DRLPR DRILL Drill directional hole 16,490' to 17,225'. ART- 17.7 hrs, AST-C hrs. 125 rpm, 300 gpm, 3500 psi. lippl K¡;çl !I IMgAIOAILY 1..ihiIMiho',W - O¡:t-I~ITY(þpg) 10.25 "\'OC::T ''''''' FV PVfYP GELS 1'1Ì1I/'-'-twc 1 iQÍ'/!Pt1(PIVl .Pf/lVlf GI/C¡¡ u.,Ci Lhv¡~1 it:", iR"",'''i 60 14/41 15/19 I 4.8/ 1 1.0/11.0 3/87 0.50/10.0 9.50/0.3 0.2/2.0 29,500/100 1 1 I 1 i i > .......~ ß!TlR!;!N .~I~$ MANUF. I ·Ttp¡;. . 1¡:[#RIA¡ldn··. I ~.. 1 .. ...... 1,.11;:1', ...~..,.,."..,...J.' 3RR1 /4 6.000 HC 1 HC407 1 7101193 16/16/16/16/1//// 16,490.0 12/25/2003 1 1-2-CT-S-D- I-L T-TD BIT 1 RUN WOB I RPM I GPM 1 PRESS PBIT HRS 24Hr OIST 1 24Hr ROP ¡CUM HRS I CUM DEPTH I CUM ROP 3RR1 /4 5/ 15 1120/ 1251 293 1 3,500 131 17.70 735.0 1 41.53 I 17.70 I 735.0 I 41.53 M 1~ ........ . tlUA"'" ··.IÊFF'Í\ff'i ·.··IRIG~Pø: .1 ,~~s~ ....., 4 I 8,208.19 I 0 I 335 / I I I I BHA DESCRIPTION PDC Bit 4-3/4 " 1 DEG M1-XL Motor , 4-3/4" NM Pony Collar , 5-7/8" NM WBS , NM Stop Sub 4-3/4" On- Trak MWD , .. 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar 4-3/4" Combo Drilling Jar, Cross-Over Sub 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe . Cross-Over .... iPlì~~'iå;~:I( iiêÄmÄ NO. IVIAKEOFPUMP q(gpm). PRESS;(þ~i) rOrALQ KII .è;:blÍll ,., 1 NATIONAL 12.000 6.000 70 293.02 3,500 293.02 35 1,525 3 NATIONAL 12.000 293.02 35 1,550 MUD.GAS I UNITS ¡ units AVG. CONN: 48 I AVG. TRIP: 730 I AVG. BKGRD: 58 MAX. CONN: 155 MAX. TRIP: MAX. DRL: 224 SURVEY DATA MD INÇL AZIMUTH TVD VS N/$CUM EIW CUMDQGLEG MD INCL AZIMUTH TVD VS l'l/e (>, I¡;:"" 16,422.0 24.68 316.74 8.865.92 12,164.3 6,626.43 -10,648.6 1.04 16,614.0 25.89 316.68 9,039.44 12,246.5 6,686.82 -10.704.3 0.75 16,518.0 25.40 317.90 8,952.89 12,204.9 6,656.30 ·10,676.1 0.91 16,703.0 26.41 316.97 9,119.33 12,285.7 6,715.43 -10,731.2 0.60 Printed: 4/29/2004 4:06:04 PM . . MJ>tRJ>t0FHC>NC>IIZûC>MPJ>tN¥ Ðâlly[)rillihg HØport J;?<pJoitàtio"'Gª~ WELL NAME IKB [GL 24 HR PROGITMD ITVD IOFS IDOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 735.0 17.225 9.589 73 73 73 27 -Dec-2003 URVEY DATA MD INCL AZIMUTH TVD VS N/S CUM E/VVCUM DOGLEG MD INCL AZIMUTH TVD VS 16.800.0 25.85 316.60 9.206.41 12.328.4 6.746.56 -10.760.4 0.60 16,989.0 25.65 316.27 9.376.82 12,410.1 6.805.79 -10,816.8 0.16 16,893.0 25.51 316.42 9.290.23 12.368.7 6.775.80 -10.788.1 0.38 17,085.0 25.62 316.91 9,463.37 12,451.7 6.835.96 -10.845.3 0.29 RERSONNEL.DATA PÇ)B@06:PQ: COMPANY SERVICE NO. HOURS COMPANY NO. HOURS Marathon 2 48.00 Nabors Alaska Drilling 23 330.00 Baker Hughes Inteq 4 84.00 S&R Enterprises 1 2.00 Epoch Well Services 4 48.00 Alaska Oil Sales 1 2.00 M-I Drilling Fluids 2 24.00 Lynden Transport 1 1.00 ÒASING>SLlMl\IIARY }} LAST BOP TEST: 12/23/2003 LAST CASING TEST: 12/17/2003 NEXT BOP TEST: 12/30/2003 SIZt::(Îlil >IÓlirÙ d' I ..·..MÎ;)(ft) I TVÔ(ft) I \N1"(lb/ft)/ GRApE ..·I./¡::¡¡··· .< . IDDQI! < 7.000 I 6.184 I 16.02 I 1 ,806 (psi) @ 9.60 (ppg) I 10,533 I 5,417 I 29.00 I L-80 I 8,1 60 Printed: 4/29/2004 4:06:04 PM . . MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas SUPERVISOR Ro er/Trub FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Drillin at 17,575' MD. OPERATION COMMENTS Drill to 17,400' MD. Increase mud weight to 10.6 ppg while circulating hole clean. Short trip to 16,107'. while increasing mud weight to 10.9 ppg. WELL NAME KASILOF SOUTH 1 L 1 KB 30.6 RIG NAME & NO. Nabors 273E RIG PHONE 907-260-6935 COUNTY/OTHER 24 HR PROG TMD 350.0 17,575 AUTH MD RPT# DATE 74 28-Dec-2003 SAPIWBS COST TVD 9,915 WBS MOCWI 100.0000 DX0309032CAPDRL I DAILY WEt I ,.,,...~ CUM WELL COST NEXT l.A:;ING Lt::At\.U¡-¡- 16.02 NRI (Office extended TO). Drill to 17,575' MD MANHRS WORKED ACCIDENT TYPE 547.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Spill Drill and proper response 12/23/2003 SAFETY SUMMARY BOP PSI TEST LAST STOP CARD AUDIT 12/17/2003 REGULATORY INSP? N LAST RIG INSPECTION 12/11/2003 LAST SAFETY MTG 12/24/2003 06:00 11 :00 5.00 17,225 17,400 AF DRLPR DRILL 11 :00 14:30 3.50 17,400 17,400 AF DRLPR CIRC 14:30 18:00 3.50 17 ,400 17,400 AF DRLPR CIRC 18:00 22:00 4.00 17,400 17 ,400 AF DRLPR TRIP 22:00 06:00 8.00 17,400 17,575 CS DRLPR DRILL Drill 6" directional hole from 17,225' to 17,400' MD (9750' TVD) Planned Casing Point. Drilling w/125 rpm, 24k Torq, 300 gpm at 3,500 psi. Incr MW from 10.3 to 10.4 ppg while drilling. ART - 4 hrs, AST - 0 hrs. Circulate hole clean circ up samples at 300 gpm, 3,300 psi. Stood back (1) stand after 1 BU. Continue to CBU. Had 500 units of gas (background 80 units) w/ MW cut from 10.4 to 9.7 ppg. Simulate connection and flow check well - slight flow. Kick in pumps and kill w/ ECD. Continue to circulate and increase MW from 10.4 ppg to 10.6 ppg. Had 300 units of connection gas from simulated connection. Cont circ until 10.6 ppg mud around. Flow check. Wiper trip from 17,340' to 16,014'. Had 60-70K drag on first (2) stands, 10-25k drag there after. Hole in good condition. TBIH to 17,058'. Safety washl ream in hole from 17,058' to TD at 17,400'. Maximum short trip gas 1450 units, mud cut from 10.6 ppg to 9.4 pg. Drill 6" directional hole from 17,400' to 17,575' (9915' TVD). Dril with 125 rpm, 24.5k torque, 300 gpm at 3600 psi. Increase mud weight from 10.6 ppg to 10.9 ppg while drilling. Current projected TD - 17,665' MD, 10,000' TVD. ART - 6.4 hrs, AST- hrs. Note: Change of scope from office. TD was extended from 9,750' TVD to 10,000' TVD w/ AOGCC approval. COMMENTS Verbal approval from Mr. Winton Hebert w/ AOGCC to Steven Lambe to extend casing point to 10,000' TVD @ 3:30 pm 12/27/03. Printed: 4/29/2004 4:06:06 PM MÄ~»'TH(11)N(11)1 L...·G(11)MR.ðtNY Pêge2 df2 ])aily··I:)~¡ll¡hg.~Øpòrt eXþloitªtio.n Gas WELL NAME IKB IGL 24 HR PROGITMD ITVD IDFS IOOL IRPT# ¡DATE KASILOF SOUTH 1L 1 30.6 74.00 350.0 17,575 9,915 74 74 74 28-Dec-2003 PEN~ITY(þþg) 10.80 Ippl IECD IMI.JD.DA'.AI DAILY COST I çtl~CO$t Fvl WURTHI' '1 %såÌ\dllVÌaT Ph/ÞM. .IPf/r,nfl ! CåCI2(wt%X H;!$ LlME!ESI T PVNP GELS FC/T.SOL OIW CllCa 6RPM 63 I 17/46 17/21 5.0/ I 1 .0/13.0 3/87 0.60/10.0 9.30/0.2 10.2/2.1 I 28,000 180 I I I I BITS IßITIRUN SIZE MANUF. I TYPE I... SERIAL Nct JETSORTFA I DEPTH IN bÂl1:;1~1 I-O;D&-B-GiO-R 3RR1 /4 6.000 HC I HC407 I 7101 193 16/16/16/16///11I I 16,490.0 12/25/2003 I 1-2-CT-S-D- I-L T-TD BIT / RUN WOB I RPM I GPM I PRESS P BIT HRS I 24Hr DIST I 24Hr ROP CUM HRS I CUM DEPTH CUM ROP 3RR1 / 4 1 5 I 18 1120 / 1 ,30q 293 [ 3,800 138 10.40 I 350.0 I 33.65 28.10 I 1 ,085.0 38.61 ~ > HRS.·..I.S$~ 1ª~í\·NQ. ILEN$T8. IIEFF\'lfL .1 PIAk:(" P. I.RI I""'~ '''''' ·.·IJAKt;1K¡:¡ ....~ .,. 4 I R ?nR 1 Q I 15 1 355 1 145 I 195 / I 1 1 I BHA DESCRIPTION PDC Bit , 4-3/4" 1 DEG M1-XL Motor 4-3/4" NM Pony Collar 5-7/8" NM WBS , NM Stop Sub , 4-3/4" On-Trak MWD 3-1/2" NM Flex Collar , 3-1/2" NM Flex Collar , 3-1/2" NM Flex Collar 4-3/4 " Combo Drilling Jar , Cross-Over Sub , 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe , Cross-Over Pl..IMP,IH'YDRAil..lI..;ICDATA c'.',,-,..;æ NP. MAKE OF PUMP ISTROf<E (jh)lqNER(ir)L·.~èM ·Qt9p!JJ) · PRE$$;(p¡¡!)1 Tq1'AI..Q I ...1<111·'. RPM 1 NATIONAL I 12.000 I 6.000 70 293.02 I 3,600 I 293.02 I <.. I UN!T~ I units AVG. CONN: 155 I AVG. TRIP: 1 ,530 I AVG. BKGRD: 1 16 MAX. CONN: 290 MAX. TRIP: MAX. DRL: 463 - .... > ~ MP INCI.. ND \1$' .,'~ "". ~ JN~ç Am... IT' tVP VS ,.."", -10,9~:.9 0.77 17,180.0 24.59 315.61 9,549.39 12,492.0 6,865.09 -10,873.2 22.82 316.21 9,719.80 12,566.5 6,918.71 17,273.0 23.54 316.13 9,634.31 12,529.9 6,892.30 -10,899.6 1.15 17,463.0 20.94 313.76 9,809.81 12,602.6 6,944.28 -10,950.51 2.15 PER$øNNel..~ ~ C.OMPANY SERviCE NO, . HQµRS ... NY . . Marathon 2 48.00 S&R Enterprises 1 2.00 Baker Hughes Inteq 4 84.00 Alaska Oil Sales 1 2.00 Epoch Well Services 4 48.00 Weaver Brothers (WBI) 2 4.00 M-I Drilling Fluids 2 24.00 Reeves Wireline 3 3.00 Nabors Alaska Drilling 23 330.00 Weatherford 1 2.00 ... CASINGSUMMAR'Y .. LAST BOP TEST: 12/23/2003 LAST CASING TEST: 12/17/2003 NEXT BOP TEST: 12/30/2003 SIZElin) .IIDlihflsHOE TE$T(þpg)1 MAXSICP I M[)lft) I TVD(fH I WT(lb/tl) I G~D¡; I åLJR.ST (psh 7.000 I 6.184 I 16.02 I 1 ,806 (psi) @ 9.60 (ppg) I 10,533 I 5,417 I 29.00 I L-80 I 8,1 60 . MUDINVENTOR¥ ITEM I ·UNIT$ USAGE COST I I I . . Printed: 4/29/2004 4:06:06 PM · MARATHONQIL.iOOMRANY Råg.e.1òf2 [)ªiIYD"illiQ.gR~pøtt Expl () itati()I'lGa$ WELL NAME KB IGL 24 HR PROG TMO TVO IDFS IOOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 90.0 17,665 10,000 75 75 75 29-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Roaer/Trubv Nabors 273E DX0309032CAPDRL FIELD NAME RIG PHONE MOCWI NRI I DAILY IN'" L CO!<T ! CUM W~I I ,.._eo-r nO ..-J"" WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 -_. . STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASiNG I LEAKOFF Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,630 (ft) 16.02 CURRENT STATUS / MTS 24 HR FORECAST POOH OPERATION COMMENTS Drill to 17,665'. Short trip to 17,058'. Circulate and raise weight to 11.4 ppg. Short trip to 16,680'. Drag increasing on short trip. Circulate bottoms up. POOH to shoe. .5ÄFETY.5l.1MMÄR¥ ..... MANHRS WORKED I ACCIOENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARO AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 545.00 None 12/24/2003 12/23/2003 12/17/2003 12/11/2003 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Review IADC Safty Alerts and working on icy location .Ii'iHC' , III~MMARY .. IIFROM .."I"Ö ~ ..·f"R()1I!1 TO $µâ·· FíBASE TRBL ... 06:00 09:30 3.50 17,575 17,665 CS DRLPR DRILL Drill 6" directional hole from 17,575' MD to 17,655' MD (10,000' TVD). Drill with 125 rpm, 24.5k torque, 30 gpm and 3600 psi. Raise MW to 11.0 ppg while drilling. 09:30 13:00 3.50 17,665 17,665 AF DRLPR CIRC Circualte hole clean while raising weight to 11.1 ppg. 13:00 14:00 1.00 17,665 17,665 AF DRLPR TRIP Make short trip to 17,058' MD. TIH to 17,617' MD. Hole in gooc condition. max overpull 60k but wiped clean. 14:00 14:30 0.50 17,665 17,665 AF DRLPR TRIP Precautionary wash and ream 17,167' to 17,665'. 14:30 17:00 2.50 17,665 17,665 AF DRLPR CIRC Circulate BU from short trip while holding mud weight at 11.2 ppg. Maximum short trip gas was 600 units with mud cut from 11.1 to 10.1 ppg. 17:00 21:30 4.50 17,665 17,665 AF DRLPR CIRC Circulate and raise mud weight to 11.4 ppg in and out. 21:30 23:00 1.50 17,665 AF DRLPR TRIP Make short trip to 16,680' MD. First 2 stands required 60-80k overpull to start moving. Stands 3 and 4 required 46-60k to start moving. Rest of trip had 20-40k overpull. Precautionary wash and ream last two stands back to bottom. 23:00 02:00 3.00 17,665 17,665 AF DRLPR CIRC Circulate 1 1/2 bottoms up. Maximum short trip gas 840 units, mud cut from 11.4 to 10.6 ppg. 02:00 06:00 4.00 17 ,665 17,665 AF DRLPR TRIP Planned to make wiper trip to 15,800'. Intermittent overpulls of 60-80k to start moving pipe. Three times become stuck while in slips, unable to move pipe with 100k overpull or free down. Screw in TD and rotate pipe, pipe frees up immediately - differentially sticking. Will extend short trip to casing shoe at 10,533'. Pump slug and continue to POOH. _u~ PENSITY(ppg) 11.40 I PP I ¡EGol IMUD DÄTÄI.qAII..YGOSTI , I CUM COST , 1_..... . ___ FV PVfYP GEI..S I WUHTHP I FC/T;SOI.. O/w %SanQiiVIBT I PhÎpM !Pf/Mf I Cl/Ca I GaCI2(wt%1 H2S LIME I Es.I·ß~èM 58 19/42 15/19 I 4.6/ I 2.0/15.0 3/82 0.75/10.0 I 9.40/0.3 10.2/2.2128,000/100 I I I I Printed: 4/29/2004 4:06:08 PM . MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas Page 2 of 2 WELL NAME KASILOF SOUTH 1L1 DATE 29-Dec-2003 CU M ROP 37.30 BHA BHANO. TORQU~(rr)¡;¡xlrr)in) 4 8,208.19 15,000 360,000 150,000 120,000 24,500/22,000 BHA DESCRIPTION PDC Bit, 4-3/4" 1 DEG M1-XL Motor, 4-3/4" NM Pony Collar, 5-7/8" NM WBS , NM Stop Sub, 4-3/4" On-Trak MWD . 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 3-1/2" NM Flex Collar, 4-3/4" Combo Drilling Jar, Cross-Over Sub. 5 JTS 4" HWDP , 82 Stands 4" Drill Pipe, Cross-Over NATIONAL AVG. CONN: MAX. CONN: 68 120 units 15 Marathon Baker Hughes Inteq Epoch Well Services Printed: 4/29/2004 4:06:08 PM M~R~mHI@) IbG~MP~NY ÐáilxÐrilli~QRøport E)(ip.I 0 itê\tior;¡!?ê\s WELL NAME KB IGL 24 HR PROG TMD TVO IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 76 76 76 30-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAP"N?" "'OST Roger/Truby Nabors 273E DX0309032CAPDRL FIELD NAME RIG PHONE MOCWI NRI I DAIL Y ~~:~L C~~_ I CU~ WELL c~~~ ^ I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 ST A TE/PROV COUNTY/OTHER I LAST CASING INEx;.~~~'ì~n) (ã) 17,630 (ft) 1~-·16.02 Alaska 7.000 (in) (ã) 10,533 (ft) CURRENT STATUS / MTS 24 HR FORECAST MU loqqinq BHA TIH. POOH with Reeve's loqs. OPERATION COMMENTS Short trip to 13,000'. CBU. POOH. LD motor and MWD. Make up Reeve's logging BHA. SÂEEmYSUMIVIARM .. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 543.00 None 12/24/2003 12/23/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Installing logging source .~RÇ.lM ..... fRPM Tq( :tø. $.Qß <TRijl.. > 06:00 10:00 4.00 17,665 17,665 AF DRLPR TRIP POOH to 13,000' MD, overpull coming of slips ceased at 14,600'. TIH to 17,665' MD, no fill. 10:00 13:30 3.50 17,665 17,665 AF DRLPR CIRC Circulate 1.5 x bottoms up. Max trip gas 565 units, mud cut 11.4 to 11.1 ppg. 13:30 20:30 7.00 17,665 17,665 AF DRLPR TRIP Pump slug, drop rabbit and POOH for logs. POOH to 8200'. 20:30 21:00 0.50 17,665 17,665 AF DRLPR TRIP Change handeling tools to 4". 21:00 01:30 4.50 17,665 17,665 AF DRLPR TRIP Continue POOH to BHA. 01:30 03:00 1.50 17,665 17,665 AF DRLPR TRIP Stand back HWDP and monels, LD motor and MWD. 03:00 06:00 3.00 17,665 17,655 AF EVALPR LOG Make up Reeves BHA and install logging tools COMMENTS Received verbal extension for BOP test from Jeff Jones AOGCC 1715 hrs 12/29/2003. ~ 1160 ~ I ECol _ C!Í\J¡¡¡¡~'I~ I J I~~LJR~I-O:O< ~o Ggl,:$IC:Äiit~¡'lIo/'¡l ii"hlPMI .Çl/C¡[ ~i·· 62 21/44 15/19 4.6/ 1 2.0/16.0 3/82 1.00110.0 9.20/0.3 0.1/2.21 27,500 /80 1 <Blms « ~i~l;i ....... MÞ.Nl)F, "fYPI; 1.<"I:Þ¡'¡i>.,hl .,I:T<inD1'''Á 1 .....,<;#';¡-j ii~þ.þ,ml;lí'! ·1< , 3RR1 /41 6.000 HC HC407 1 7101193 1 16/16/16/16/1//// I 16,490.0 12/25/2003 I 1-2-CT-S-D- I-L T-TD BIT 1 RUN WOB I RPM I GPM PRESS I" BIT HRS 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP 3RR1 /4 / I / I 1 1 31.50 I 1,175.0 I 37.30 .............<.... BRA "\.II\.~ln I~ENGTH·_ IPICKUP 1~ldl"l( 1~I..J'YVt BHA¡,jRS 1 JAR}-IR,S .".'M ';'6". H~-rI')"'D<>ls$ HRS 5 I 8,059.77 I I I I I / I I I I I BHA DESCRIPTION Reamer Bit Landing/Circ sub , 3 1/2" DP (4), Lower latch sub Upper latch sub Drill Pipe Float Sub Drill Pipe , Float Sub Cross Over, Drill Pipe (246), Cross Over PUMP IHYDRAULlCDATA NO. 1 MAKEOf'PUMP IS1'R9KEi(io)1 LI~I;R(il1) SPM I.Q(gpll) .i!PRES$..(psi)1 TOrALÒ 1 KILI.-SpM I PRESSURE: 1 1 NATIONAL I 12.000 I 6.000 I 70 I 293.02 I 3,600 I 293.02 I . . Printed: 4/29/2004 4:06:11 PM · MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas Page 2 of 2 AVG. CONN: MAX. CONN: DATE 30-Dec-2003 WELL NAME KASILOF SOUTH 1 L 1 MUD GAS AVG. TRIP: MAX. TRIP: 595 AVG. BKGRD: MAX. DRL: units 20 LAST BOP TEST: 12/23/2003 SIZE in 7.000 PERSONNEL DATA NO. HOURS COMPANY 2 48.00 R&K Industrial 2 48.00 S&R Enterprises 4 48.00 Reeves Wireline 2 24.00 Alaska's Best Water 23 350.00 SERVICE 1 1 3 1 3.00 3.00 18.00 1.00 COMPANY Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids Nabors Alaska Drilling ITEM Printed: 4/29/2004 4:06:11 PM · MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas Page 1 of 2 WELL NAME KASILOF SOUTH 1L 1 SUPERVISOR Castleman / Trub F!ELO NAME KB 24 HR PROG TMO 17,665 AUTH MD TVD 10,000 WBS RPT# DATE 77 31-Dec-2003 SAPIWBS COST 30.6 RIG NAME & NO. Nabors 273E DX0309032CAPDRL ,R!G PHONE 16.02 MOCW! NRI ,CUM .. WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATE/PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS POOH with 10 in tools OPERATION COMMENTS TIH with drill pipe deployed logs to 17,659'. Circulate bottoms up. MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 529.00 None 12/24/2003 12/23/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Tripping pipe, pinch points REGULATORY INSP? N LAST RIG INSPECTION 12/11/2003 FROM 06:00 06:30 16:00 16:30 0.50 9.50 0.50 2.50 17,665 176,555 17,655 17,655 17,655 AF 17,655 AF 17,655 AF 17,655 AF IONS SUMMARY OP TRBL EVALPR LOG EV ALPR LOG EVALPR LOG EVALPR LOG TO 06:30 16:00 16:30 19:00 19:00 20:00 1.00 17,655 17,655 AF EVALPR LOG Finish PU Reeve's logging BHA. TIH with DP deployed logs to 17,571' MD. Wash down 17,571' to 17,659'. Circulate BU while rotating and recipricating pipe. Pumping 60 spm and 2800 psi. Maximum trip gas - 240 units, mud cut 11.4 10.9 ppg. Pull one stand. Drop dart and pump down same to deploy tools and open circulating ports. Pump Slug. End of drill pipe at 17,550', bottom of logging tools when deployed and started to log - 17,648'. POOH logging. Logging speed in open hole 30 '/min, logging speed in cased hole 60 'Imino Current depth - 5,742'. 20:00 06:00 10.00 17,655 17,655 AF EVALPR LOG --Note: Jeff Jones wI AOGCC granted an extension on BOP tes for 72 hrs. Will need begin to test by 1/2/2004 midnight. Reamer Bit, Landing/Circ sub, 3 1/2" DP (4), Lower latch sub, Upper latch sub, Drill Pipe, Float Sub, Drill Pipe, Float Sub, Cross Over, Drill Pipe (246), Cross Over KILL SPM I NO. MAKE OF PUMP 1 NATIONAL AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: 240 AVG. BKGRD: MAX. DRL: units 60 Printed: 4/29/2004 4:06:14 PM · MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas WELL NAME KASILOF SOUTH 1 L 1 DATE 31-Dec-2003 COMPANY Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids Nabors Alaska Drilling SERVICE PERSQNNELDATA NO, HOURS COMPANY 2 48.00 Reeves Wireline 2 12.00 BJ Services 2 24.00 Weaver Brothers (WBI) 2 24.00 Lynden Transport 26 339.00 SERVICE POB @ 06:00: NO. HOURS 3 72.00 3 6.00 1 2.00 1 2.00 Printed: 4/29/2004 4:06:14 PM . . MARATHON OIL COMPANY Daily Drilling Report Exploitation Gas 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,665 AUTH MD TVD 10,000 WBS RPT# DATE 78A 01-Jan-2004 SAPIWBS COST WELL NAME KASILOF SOUTH 1L 1 SUPERVISOR Castleman / Trub FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS End of drillin hase 1130 hrs 12/31/2003 OPERATION COMMENTS POOH. BHA. LD logging tools. KB RIG PHONE . --- --- 907-260-6935 COUNTY/OTHER MOCWI 100.0000 NR! I CUM . ~ eLL COST L!:AKOFF 16.02 MANHRS WORKED ACCIOENT TYPE LAST SAFETY MTG 145.00 None 12/24/2003 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Handling radioactive source. REGULATORY INSP? N LAST RIG INSPECTION 12/11/2003 06:00 08:00 2.00 08:00 09:00 1.00 09:00 11 :30 2.50 17,665 17,665 17,655 17,665 17,655 17,655 EVALPR LOG EVALPR LOG EVALPR LOG POOH, continue logging to 2230' MD. Finish POOH with Reeves tools. LD logging BHA, PJSM, remove source and LD logging tools Note: End of drilling phase 1130 hrs 12/31/2003 5 BHA DESCRIPTION / Reamer Bit, Landing/Circ sub, 3 1/2" DP (4), Lower latch sub, Upper latch sub, Drill Pipe, Float Sub, Drill Pipe, Float Sub, Cross Over, Drill Pipe (246), Cross Over COMPANY Marathon Epoch Well Services M-I Drilling Fluids Nabors Alaska Drilling PERSONNEL NO. HOURS 2 12.00 Reeves Wireline 1 6.00 S&R Enterprises 1 6.00 Oilfield Hot Shot Service 16 96.00 units AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: SERVICE 3 2 1 18.00 5.00 2.00 ITEM UNITS LAST BOP TEST: 12/23/2003 SIZE in 7.000 16.02 Printed: 4/29/2004 4:06:15 PM . . :!o;< v ~57 Kasilof South 1 Lateral 1 Rig Completion (Reports 78B -83A) MA H.øNølbeøI\llPAN¥ Qâll¥~~rt'I~lêtiøn··.~~.þ()rt liE~pl.OitªJ!q l+·.GªS WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 78 78 78B 01-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Truby/Castleman Nabors 273E DX0309032CAPCMP01 1,208,800 FIELD NAME R!G PHONE MOCW! NR! I CAlLY WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 31,978.00 31,978.00 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,665 (ft) 16.02 CURRENT STATUS / MTS 24 HR FORECAST RD LD machine and RU fl oor to run drill DiDe Run and cement 3 1/2" liner. OPERATION COMMENTS RU to run liner. Run 3-1/2" liner. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARO AUDIT I ~EGULATORY INSP7 I LAST RIG INSPECTION 399.00 None 12/28/2003 12/23/2003 12/24/2003 ACCIOENT DESCRIPTION: SAFETY MTG TOPICS: PU and running tubing with PU machine FROM TO HRS FROM .1"0 .SUI3 .~~IC)NS§~RlJMARY ~ OP . TRBL 11:30 13:00 1.50 17,665 17,665 AF CSGPRC EQUIP Pick up and make up cement head on one joint of 5 1/2". 13:00 17:00 4.00 17,665 17,665 AF CSGPRC EQUIP PJSM. Change bails for running liner, clear floor of drilling tools PU and RU casing tools. RU PU machine. 17:00 05:00 12.00 17,665 17,665 AF CSGPRC CSG Make up float shoe, two shoe joints, float collar, one joint and landing collar. Continue running 3 1/2", 9.2 ppf, L-80, HYD 563, liner. making up liner to 6400 ft-Ib with torque turn machine. Length of liner - 7,285.21' 05:00 06:00 1.00 17,665 17,665 AF CSGPRC CSG RD LD machine. Change bails and handling tools to 4" tools. PENSITY(þpg) 11.40 IEØØI In EAlp~~~'{!~...·1 1031.00 1..·¢·YMGc:)$'t 1031.00 FV PVIYP GEI.;$ J C)/V'I ql/¢~. lc:aCI2(Wt%îH~$ iI.lIJll!~.I··.. .·....~$·..··.li§RêM 64 19/36 13/16 I 4.6/ I 2.0/15.0 / 1.25/10.0 9.20/0.1 0.1/2.21 27,000 /100 I I I ~tn.ám.á "T SSRVICE! Marathon 3 54.00 Nabors Alaska Drilling 23 237.00 Epoch Well Services 2 18.00 Baker Oil Tools 4 72.00 M-I Drilling Fluids I 2 18.00 CASING SUMMARY LAST BOP TEST: 12/23/2003 LAST CASING TEST: NEXT BOP TEST: 1/2/2004 SIZE (in) I IDlin) ISHOETESTlDDa)! MAX SICP I MD (fty J TVD(ft) I WT(lb/ft) . il ·qRADE 1St ,~~ ., 7.000 I 6.184 I 16.02 I 1,300 (psi) @ 11.40 (ppg) I 10,533 I 5,417 I 29.00 I L-80 I 8,160 . . Printed: 4/29/2004 4:06:17 PM MARAmHG>N;G>IL.eG>MRANY 6)ª.i.l.yQþl:)'lpl~tio""R~pqrt I$Xpl()jt~tIon .,G~~ WELL NAME KB IGL 24 HR PROG TMO TVO IDFS IOOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 79 79 79 02-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Trubv/Castleman Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NR! I OAIL Y WELL COST CUI.. ..___ __", I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING !NE} . --....- I LI:A"'Utt Alaska 3.500 (in) lG:J 17,644 (ft) (in) lG:J 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Circulating prior to POOH POOH. Test BOP's. OPERATION COMMENTS Run and cement 3 1/2" liner. Set liner hanger and release running tool. CBU. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST I LAST STOP CARO AUDIT I~EGULATORYINSP1 I LAST RIG INSPECTION 736.00 None 12/28/2003 12/23/2003 12/24/2003 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Pressure testing cement lines and cementing operations .__.<.~~. .. 1ì=~ºfv1 TO HRS FROM TO $Ûê 06:00 06:30 0.50 17,665 17,655 AF CSGPRC CSG Finish rig down LD machine and change bails and elevators. 06:30 08:00 1.50 17,655 17,665 AF CSGPRC CSG Pick up liner hanger. Remove set screws from liner wiper plug to lower shear value. Install hanger in string. Circulate through liner, 20 spm at 650 psi, 40 spm at 900 psi. 08:00 08:30 0.50 17,665 17,665 AF CSGPRC CSG Run 6 stds of 4" DP. 08:30 09:00 0.50 17,665 17,665 AF CSGPRC CSG Change handling equipment 4" to 5 1/2" tools. 09:00 13:30 4.50 17,665 17,665 AF CSGPRC CSG RIH with 5 1/2" drill pipe to 9850', filling pipe every 20 stands. PU -120K, SO-95K, RW - 100K, 15 RPM at 4,000 ft-Ibs, 20 spm at 675 psi and 40 spm at 1050 psi. Continue RIH to 16,419' filling pipe every 20 stands. 13:30 19:00 5.50 17,665 17,665 AF CSGPRC CSG Wash and ream down from 16,149' to 17,647'. 4-15 rpm. 20-40 spm, 800 - 1600 psi. 19:00 19:30 0.50 17,665 17,665 AF CSGPRC CIRC Blow down top drive, PU and MU cement head and one single. 19:30 00:00 4.50 17,665 17,665 AF CSGPRC CIRC Wash down from 17,647'- 17,663'. Circulate and condition hole. 40 spm -1600 psi. Reciprocate pipe 35' while rotating at 4-6 rpm, 12,500 -16,500 ft-Ibs. 00:00 03:30 3.50 17,665 17,665 AF CSGPRC CEMT Hold PJSM, pump 5 bbl water, test lines to 4500 psi. Mix and pump 700 sx Class "G" + 2% KCI + 22% LW-6 + 5% MPA-1 + .9% BA-10 + .15% A-2 + .6% CD-32 + .45% R-3 + 1 gphs FP-6L, mixed to 12.7 ppg, yield 1.789 cf/sx. Drop plug and displace with rig pump and 11.5 ppg mud. Reciprocate pipe 35' and rotate at 4-6 rpm with 12,500 - 16,000 ft-Ibs torque. Move pipe until last 30 bbls of displacement. Bump plug to 2700 psi, 400 psi over displacement pressure. Increase pressure to 2800 psi. Slack off and confirm hanger set. Bleed off pressure and confirm floats are holding. LD cementing head. Pressure up down drill string to 3800 psi and hold for 5 minutes. Bleed of pressure to 500 psi. PU on drill string and observe pressure drop as stinger pulled through bushing and confirmed running tool released. Had full returns during cement job. 03:30 06:00 2.50 17,665 17,665 AF CSGPRC CIRC Circulate 1 1/2 times BU 10 bpm, recovered 25 bbls of cement . . Printed: 4/29/2004 4:06:20 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 DATE 02-Jan-2004 FROM TO HRS 03:30 06:00 2.50 FROM 17,665 SUB 17,665 AF OPERATIONS SUMMARY PHASE OP TRBL CSGPR CIRC DESCRIPTION contaminated mud. Pull three stands and flush junction at 10 bpm while slowly pulling through junction. Continue to circulate while building slug. MAKE OF PUMP NATIONAL SERVleE Marathon Epoch Well Services M-I Drilling Fluids Nabors Alaska Drilling 3 72.00 Baker Oil Tools 2 24.00 BJ Services 2 24.00 Weatherford 23 336.00 R&K Industrial 4 96.00 4 48.00 5 100.00 3 36.00 LAST BOP TEST: 12/23/2003 SIZE 7.000 3.500 CASING SU MARY LAST CASING TEST: NEXT BOP TEST: 1/2/2004 6.184 2.992 16.02 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) 10,533 17,644 5,417 9,980 29.00 L-80 9.20 L-80 8,160 10,160 Printed: 4/29/2004 4:06:20 PM MÄR~mHøN>øll..}~ØMP~N¥ }) Q~ily·QøO'tp.l~tiol?i~gp()r1 ...... f;~p.loit~tiolÎ>-c::;~§ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL [RPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 80 80 80 03-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Ratliff / Castleman Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAIL : ~~L: .C~~T leu", Wt:LL "'U" I WILDCAT-FOR UNNAMED FIELD 907 -260-6935 100.0000 STATElPROV COUNTY/OTHER I LAST CASING NEXT I I Lt:A,,"U~~ Alaska 3.500 (in) @ 17,644 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST POOH RIH and polish PBR. OPERATION COMMENTS CBU. POOH. BHA. RIH. Pull and Reset Diverter. POOH. .. Š~FEtîf¥išûrhMÄR¥ ... .... ...... MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST LAST STOP CARO AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 620.00 None 1/2/2004 12/23/2003 1/2/2004 12/24/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Well Control Drill. Tripping OJ"6. I-JR$ FROM .~p~ ~_M~~R¥ , FROM TO R~~~$L .. 06:00 07:30 1.50 17,665 17,665 AF CSGPRC CIRC Circulate Hole Clean. Pump Slug. 07:30 13:00 5.50 17,665 17,665 AF CSGPRC TRIP POOH. UD Liner running tool. 13:00 14:30 1.50 17,665 17,665 AF CSGPRC CEMT PIU Cementing Head. Break off XOs and 1-jt 5-1/2" Drill Pipe. UD head. 14:30 17:00 2.50 17,665 17,665 AF RCMP TRIP LID Flex Monel DCs and 4" HWDP for inspection. Load Rig floor wI handling tools and next BHA components. 17:00 19:00 2.00 17,665 17,665 AF RCMP TRIP MIU FORMation Junction Diverter pulling assembly. 19:00 19:30 0.50 17 ,665 17,665 AF RCMP TRIP Establish pump rates for pulling tool function. 19:30 00:00 4.50 17,665 17,665 AF RCMP TRIP RIH to 9,841'. 00:00 01:00 1.00 17,665 17,665 AF RCMP TRIP Pump down f/ 9,841' - 9,915' (bottom of FJD tool). Latch on diverter at 9,903'. Release diverter wI 25k overpull. Reset diverter. Release diverter with 40k overpull. POOH w/ diverter to 9,747'. RIH to 9,903'. Reset Diverter. Pump on running tool t< release same. Released running tool with 30k overpull. Reset running tool. Turn 8-rounds to the right to manually release tool. Pull tool with 80k overpull. 01:00 01:30 0.50 17,665 17,665 AF RCMP CIRC Circulate and pump slug. 01:30 06:00 4.50 17,665 17,665 AF RCMP TRIP POOH with FJD running tool. -Note: Recieved extension from Winton Hebert- AOGCC to delay BOP testing until immediately prior to drilling out th e second leg. IpPj 1):ç;p I I~ ~~ - 11.50 eA'TA pAILycostl FV PvNP GELS ·1'A"iI..lTI..I6! i:ri,.r~nr . ..qíW.' ..M~rl :>hlpflllJrflMf I CII¢¡¡I, Pt.lfoJI61 }6S Ii3RfÎtv1 72 20/39 15/20 I 4.61 I 2.0/16.0 / 0.75/10.0 I 9.30/0.3 10.2/2.3127,000/100 I I I BHA SHANO. I LENGTH I EFF WI. PICK UP ISL.Ä¢K OFryRÞ-rWf. rÓROylò (maxlrnin) JaHAHRS IJARHgS IMJRHR$. l§qMRS 1 I 235.15 I 0 210,000 I 110,000 I I / I I I I I SHA DESCRIPTION FJD Stinger , FJD Tool , Bumper Sub Hydraulic Jar 5" HWDP (6), Accelerator Cross Over . Printed: 4/29/2004 4:06:21 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation· Gas WELL NAME KASILOF SOUTH 1 L 1 MAKE OF PUMP 3 NATIONAL COMPANY Marathon Epoch Well Services M-I Drilling Fluids Nabors Alaska Drilling PERSONNEL DATA NO. HOURS COMPANY 3 72.00 Baker Oil Tools 2 24.00 BJ Services 2 24.00 R&K Industrial 23 336.00 Wildflowers and Resin SERVICE SERVICE CASIN 5 MARY LAST CASING TEST: Page 2 of 2 DATE 03-Jan-2004 POB @ 06:00: NO. HOURS 4 96.00 4 24.00 3 36.00 1 8.00 NEXT BOP TEST: 1/2/2004 7.000 3.500 6.184 2.992 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) 10,533 17,644 5,417 9,980 29.00 9.20 L-80 L-80 8,160 10,160 Printed: 4/29/2004 4:06:21 PM M1AR1AT.H.·~.N·····~·I·.b.G~·MP1AN¥ ¡¡¡)~iIYQºl"I1pletiQ n . R~PQrt Expl()itª~i9n·i" .G~s WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 81 81 81 04-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Ratliff / Castleman Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST ! CUM WELL \;U:; I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING 17,644 (ft) I NEXT ----'ï;n) @ 0 (ft) Lt:AI\.Vn Alaska 3.500 (in) @ CURRENT STATUS / MTS 24 HR FORECAST TIH w/ FJD Tool. Pull and Reset Diverter. Run Production Packer OPERATION COMMENTS BHA. RIH. Polish PBR @ 10,325'. POOH. BHA. RIH. SAFE'f¥SÛMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 556.00 None 1/3/2004 12/23/2003 1/3/2004 12124/2003 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Confined Space Entry ...,.> ii> - ii=~Þ~ .Tþ f ß;~ 'i=ß;þ!VI 1'9 $uå .. ",. 06:00 08:00 2.00 17,665 17,665 AF RCMP TRIP Pull HWDP. Pull FJD tool. Tool in the released position. No indication of having latched into diverter. UD jars and bumper sub. 08:00 09:30 1.50 17,665 17,665 AF RCMP RIG Slip and cut drilling line 09:30 10:00 0.50 17,665 17,665 AF RCMP RIG Lubricate rig and topdrive. 10:00 11:30 1.50 17,665 17,665 AF RCMP TRIP M/U polish mill assembly. Establish pump rates thru same. RIH with 4" drill pipe. 11 :30 17:30 6.00 17,665 17,665 AF RCMP TRIP RIHto 10,306'. Established pump and weight parameters @ 9,840'. 17:30 18:00 0.50 17,665 17,665 AF RCMP CLEAN Polish Packer and PBR to 10353'. Top of packer @ 10,325' (DPM). 18:00 20:00 2.00 17,665 17,665 AF RCMP CIRC Spot polymer pill f/10,353' - 9,993'. POOH to 9,993'. 20:00 20:30 0.50 17,665 17,665 AF RCMP CIRC Drop Dart and open circulating sub @ 9,963'. 20:30 21:30 1.00 17,665 17,665 AF RCMP CIRC Circulate and wash diverter and junction f/9,963' - 9,870'. Pumping 20 bpm @ 3100 psi and rotating @ 30 rpm. Minor increase in cuttings on bottoms up. 21:30 22:00 0.50 17,665 17,665 AF RCMP CIRC Con't wash out of hole to 9,647'. 22:00 22:30 0.50 17 ,665 17,665 AF RCMP CIRC Pump slug. 22:30 04:00 5.50 17,665 17,665 AF RCMP TRIP POOH w/ Polish Mill. Indicators showed full engagement in PBR. 04:00 04:30 0.50 17,665 17,665 TA RCMP TRIP DOTH P/U FJD Tool. Function test release w/ rig pump. Release @ 8~ spm. 800 psi. 04:30 05:30 1.00 17,665 17,665 TA RCMP TRIP DOTH P/U Jars and Bumper Sub w/ accelerator. 05:30 06:00 0.50 17,665 17,665 TA RCMP TRIP DOTH TIH to 2,000'. DI:I'J~I]"'((þpg) 1 11.70 1 PP I IEeÞI IMUDDhllYAlþAILY¢OST I CUM COST FV PVlYP GELS .I\III~ìl·Ù·HP 1 FCIT.SOL OIW '¡'SåhdiMST I Ph/pfl'l I· pt/Mf. I CIICa ·IC¡1GI2(wt%j H2S LlNIIËI···p~16~pM 71 20/38 14/20 1 5.2/ ! 2.0/17.0 / 0.50/10.0 1 9.30/0.3 10.2/2.4127,000/100 1 I I 1 BHA IßHÄNQ. I LENGTH 1 EFF I/JIT. PICKUP ·I!':I ""/h,,c'¡RQr I/JIT. 1 TORQUE (max/min) I aHA HRêIJAFtHR~ 1 MWDHR$.IMtRH~$·I$~·HRS 3 I 235.15 I I i I I I I I I I . Printed: 4/29/2004 4:06:23 PM · . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas BHA BHA DESCRIPTION FJD Stinger, FJD Tool, Bumper Sub, Hydraulic Jar, 5" HWDP (6), Accelerator, Cross Over WELL NAME DATE KASILOF SOUTH 1 L 1 04-Jan-2004 NO. 1 2 MAKE OF PUMP NATIONAL I NATIONAL C DATA M Q (gpm) 418.61 418.61 PRESS. (psi) TOTAL Q 3,100 837.22 3,100 837.22 KILL SPM I PRESSURE NEXT BOP TEST: 8,160 10,160 COMPANY Marathon Epoch Well Services M-I Drilling Fluids Nabors Alaska Drilling SERVICE PERSO NO. HOURS 3 72.00 2 24.00 2 24.00 23 336.00 ATA COMPANY Baker Oil Tools R&K Industrial S&R Enterprises Oilfield Hot Shot Service 10,533 17,644 5,417 9,980 29.00 9.20 L-80 L-80 Printed: 4/29/2004 4:06:23 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Ratliff / Castleman FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS POOH IGL 30.6 1 74.00 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,665 AUTH MD TVD IDFS IDOL IRPT# DATE 10,000 1 82 82 1 82 05-Jan-2004 WBS SAPIWBS COST KB DX0309032CAPCMP01 MOC WI NR! ! DAILY WELL COST 1 CUM \lYt:LL "v~ 907-260-6935 100.0000 1 _ COUNTY/OTHER I L;~~~;~;~~ @ 17 ,644 (ft) I NEXT "A"'~~n) @ 0 (ft) 24 HR FORECAST POOH. Retrieve Motherbore diverter. Run leg #1 diverter RIG PHONE I ~~~,,~, , OPERATION COMMENTS RIH. Pull and reset diverter @ 9,904'. POOH. MANHRS WORKED ¡ACCIDENT TYPE ¡LAST SAFETY MTG 528.00 None 1/5/2004 ACCIDENT OESCRIPTION: BHA. RIH. Set Packer @ 10,092'. POOH. SÄREIF¥SWMMÄR¥ IBOP PSI TEST I LAST STOP CARO AUDIT I REGULATORY INSP? 112/23/2003 1/4/2004 N 1 LAST RIG INSPECTION 112/24/2003 SAFETY MTG TOPICS: Confined Space Entry. PJSMs. _~~:å8 Ari'. ~ ..i<· FROM TO HRS fRQM TO SUB i « ......... 06:00 09:00 3.00 17,665 17.665 TA RCMP TRIP DOTH RIH. 09:00 10:30 1.50 17,665 17,665 TA RCMP TRIP DOTH Latch into diverter @ 9,904'. Confirm latch with 30k overpull. Pull 90k over and jar twice to release diverter. Pull diverter 70'. Lower and reset. Confirm latch with 30k overpull. Pump on tool to release. Pull FJD tool without additional drag. 10:30 11:00 0.50 17 ,665 17,665 TA RCMP CIRC DOTH Circulate. Pump slug. 11:00 15:30 4.50 17,665 17,665 TA RCMP TRIP DOTH POOH. 15:30 16:30 1.00 17,665 17,665 TA RCMP TRIP DOTH LID Jars, Bumper sub, Accelerator sub, and FDJ running tool. 16:30 18:00 1.50 17,665 17,665 AF RCMP EQUIP R/U to run 3-1/2" tubing. 18:00 22:00 4.00 17,665 17,665 AF RCMP PKRPLG P/U Seal Assembly (22.18'), 1-Pup 3-1/2" 9.2 ppf L-80 wllocato sub (6.29') 6-jts 3-1/2" 9.2 ppf L-80 Hyd 563 (193.02'), 3-pup jts 3-1/2" 9.2 ppf L-80 Hyd 563 (27.37'), FHL Packer assembly (9.28'), 5-jts 3-1/2" 9.2 ppf L-80 Hyd 563 (159.93'), 5" PBR assembly (11.20'). M/U PBR running tool and FJD tool (without latch). 22:00 03:00 5.00 17,665 17,665 AF RCMP PKRPLG RIH with assembly. Slide seals into PBR on liner hanger @ 10, 325'. Land out in Diverter with FJD tool @ 9904'. Btm of seal assembly 10,349'. 03:00 03:30 0.50 17 ,665 17,665 AF RCMP PKRPLG Close annular and test seal assembly to 1000 psi for 10 min down annulus. 03:30 04:00 0.50 17,665 17,665 AF RCMP PKRPLG Pressure drill pipe to 2,000 psi to set FHL packer @ 10,092'. Top of PBR @ 9920.60' - 2.23' below bifurcation point of junction. 04:00 04:30 0.50 17,665 17,665 AF RCMP PKRPLG Shear running tool with 35K overpull. POOH to 9,900'. Pump Slug. 04:30 06:00 1.50 17,665 17,665 AF RCMP TRIP POOH to 7,000'. DENSITY(ppg) I FV PVfYP 89 21/36 11.70 IF'P 1 GELS IWUHT)-tP.1 16/21 I 5.2/ I I ECD I IMlJDDATAI DÄILYCo::n I ICl.l~C;:ÖST FC/T.SOL OIW o/,Sand/MBT!Ph/pM I Pf/Mfl CI/CaICaCI2(wt%fH2$ LIME I 2.0/17.0 / 0.50/10.0 1 9.00/0.2 10.112.5127,000/100 1 I I ES I 6RPM I Printed: 4/29/2004 4:06:24 PM · . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas WELL NAME DATE KASILOF SOUTH 1 L 1 05-Jan-2004 BHA BHA NO. TQRQUE (maximin) o / FJD Stinger, FJD Tool, Bumper Sub, Hydraulic Jar, 5" HWDP (6), Accelerator, Cross Over NO. MAKE OF PUMP 1 NATIONAL SERVICE PERS NO. HOU 2 48.00 2 24.00 2 24.00 NEL DATA COMPANY Nabors Alaska Drilling Baker Oil Tools R&K Industrial Marathon Epoch Well Services M-I Drilling Fluids CASING SUMMARY LAST CASING TEST: NEXT BOP TEST: 1/2/2004 7.000 3.500 6.184 2.992 16.02 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) 10,533 17,644 5,417 9,980 29.00 9.20 L-80 L-80 8,160 10,160 Printed: 4/29/2004 4:06:24 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas KASILOF SOUTH 1 L 1 SUPERVISOR Ratliff / Castleman FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS End of Oriqinal Completion phase 24:00 hrs - 1/5/2004. OPERATION COMMENTS POOH. BHA. RIH. Pull Motherbore diverter @ 9904'. POOH. BHA. SAFETY SUMMARY ... ... IBOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? ¡LAST RIG INSPECTION 112/23/2003 1/5/2004 N 12/24/2003 IGL 30.6 I 74.00 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,665 AUTH MD TVO IDFS IDOL IRPH ¡DATE 10,000 I 83 83 I 83A 06-Jan-2004 WBS I SAPIWBS COST WELL NAME KB DX0309032CAPCMP01 MOC WI NRI ! DAILY WELL COST f CUM 907-260-6935 100.0000 I COUNTY/OTHER I LAST CASING INEX I 3.500 (in) @ 17,644 (ft) . -"-"èln) @ 0 (ft) 24 HR FORECAST Will resume completion after redrillinQ motherbore. RIG PHONE I~~~'W" MANHRS WORKED 1 ACCIDENT TYPE I LAST SAFETY MTG 550.00 1 None 1/5/2004 ACCIOENT DESCRIPTION: SAFETY MTG TOPICS: Pit Cleaning. BOP Test F;"f{PM J9 .Hf{$(.FRòÎVI ·lÒ _~~~NS_ ......... 06:00 09:00 3.00 17,665 17,665 AF RCMP TRIP POOH. 09:00 10:00 1.00 17,665 17,665 AF RCMP TRIP Breakout and UD running tool assembly. 10:00 11:30 1.50 17,665 17,665 AF RCMP TRIP M/U FJD Tool. Surface test. Finish P/U BHA. 11:30 16:30 5.00 17,665 17,665 AF RCMP TRIP RIHt09840'. 16:30 17:00 0.50 17,665 17,665 AF RCMP CIRC Wash down f/9840' - 9904'. Pump slug. Latch onto Motherbore diverter w/ 30k down weight. Unset diverter wI 82k overpull. POOH. '''' ..-.. 17:00 23:00 6.00 23:00 00:00 1.00 17,665 17,665 17,665 AF 17,665 AF RCMP RCMP TRIP TRIP UD Motherbore diverter. Some slight scarring on diverter but overall in good condition. End of completion report until through redrilling original motherbore. U;;~II~I ~~~:O l::;HP 1 FCIT.S~~C[II om I ~~O:;Mlf I -~':~d 88 21/36 1 15/22 5.0/ I 2.0117.0 / 0.50/10.0 1 9.00/0.2 I 12.5 127,000/100 I ",,;v iL~~~~ iEFF';" ',98,000 ;^;18000¡~Ó~ i¡~~~ I BHA DESCRIPTION FJD Stinger, FJD Tool Bumper Sub, Hydraulic Jar, 5" HWDP (6), Accelerator, Cross Over DIII\JID~ ..n 1 ." ,..... I "~~"" -" TnTA'Q 1 I~V. ...""" vr ru'...· . ''''I ...." I' .---. '.....'1 'v'~" 2 I NATIONAL 1 12.000 6.000 50 209.30 I 771 I 209.30 I 1 CIJM COST H2S UME I ES I 6RPM I 1 I ~ I leI! I SPM / COMPANY Marathon Epoch Well Services M-I Drilling Fluids Nabors Alaska Drilling Baker Oil Tools SERVICE PERS0NNELDATA NO. HOURS COMPANY 2 48.00 R&K Industrial 2 24.00 Weaver Brothers (WBI) 2 24.00 Lynden Transport 23 336.00 Baker Hughes Inteq 2 48.00 SERVICE POB @ 06:00: NO. HOURS 4 48.00 1 2.00 1 2.00 2 18.00 Printed: 4/29/2004 4:06:25 PM WELL NAME KASILOF SOUTH 1L 1 MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas CASING UMMARY LAST CASING TEST: MAXSICP MlDtt 1,300 (psi)@ 11.40 (ppg) 10,533 (psi) @ (ppg) 17,644 . NEXT BOP TEST: Ib/tt GRADE 29.00 L-80 9.20 L-80 DATE 06-Jan-2004 1/212004 BURST si 8,160 10,160 Printed: 4/29/2004 4:06:25 PM . . Kasilof South 1 Lateral 1 Rig Completion (Reports l03B -121B) 'i'~O~ ~~ 7 . . ~'1 MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Russ Trub FIELO NAME WILDCAT-FOR UNNAMED FIELD KB 24 HR PROG TMO 17,665 AUTH MO TVO 10,000 WBS RPT# DATE 121 B 13-Feb-2004 SAPIWBS COST 30.6 RIG NAME & NO. Nabors 273E MOCWI 100.0000 NRI ¡CUM \^!¡ RIG PHONE STATE/PROV Alaska CURRENT STATUS / MTS Ri released at 0000 hrs 2/1312004 OPERATION COMMENTS ND BOPs. NU and test tree. Rig released OOOOhrs 1/13/2004. SAf'E!:J'YSUMMARY LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT 907-260-6935 COUNTY/OTHER MANHRS WORKEO ACCIDENT TYPE 200.00 None ACCIDENT DESCRIPTION: 2/9/2004 12115/2003 12/17/2003 LAST RIG INSPECTION 12/11/2003 SAFETY MTG TOPICS: Rigging down 06:00 08:30 2.50 08:30 18:00 9.50 17,665 17,665 17,665 AF 17,665 AF RCMP RCMP NUND NUND Finish ND BOP and remove from sub. Install tubing head adaptor and master valve, test void to 5000 psi for 10 minutes. PU dual production tree and install test void to 5000 psi for 10 minutes. Pull back pressure valves and instal two way check valves. RU and test tree to 5000 psi for 10 minutes on both sides. Pull two way check valves and install back pressure valves. Rupture disks on injection mandrels on both strings with 4000 psi. Finish cleaning pits and rig floor. Load out Weatherford and Baker tools and equipment. Load out excess tubing and pup joints. Rig down and release mud trailer and excess mud chemicals. RD mud logger. 18:00 00:00 6.00 17,665 17,655 AF RCMP RIG Rig released 0000 hrs 2/13/2004. Diesel on rig at release 2618 gals at 1.33 $/gal, inc. tax AVG. CONN: MAX. CONN: AVG. BKGRD: MAX. DRL: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids SERVICE 1:... DATA COMPANY 12 155.00 R&K Industrial 1 12.00 Weaver Brothers (WBI) 2 12.00 ABB Vetco Gray 1 6.00 SERVICE POB @ 06:00: NO. HOURS 1 6.00 2 4.00 2 5.00 Printed: 4/29/2004 4:07:12 PM . . M N OIL COMPANY WELL NAME KASILOF SOUTH 1 L 1 12/22/2003 BURST si 8,160 10,160 Printed: 4/29/2004 4:07:12 PM MÄR:Ämt-tC>NC>1 L GC>MPÄNY â 1'"'é;!9~rUI [;)ªi.lyCö.mpløtipn.·Røþott RJ<\P qitátiQn-· Gas WELL NAME KB [GL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 101 101 120B 12-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Russ Trubv Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOC\-'VI NRI I CAlLY V'JELL COST I CUM WELL ~.:?-='~_ WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTY/OTHER I LAST CASING 17,502 (ft) ¡NEX' "'''''''(Tn) @ 0 (ft) 1------ Alaska 3.500 (in) @ CURRENT STATUS / MTS 24 HR FORECAST ND stack ND stack, NU tree, clean pits, release rig. OPERATION COMMENTS Run and land 3 1/2" dual strings. Test seals. Set and test dual packer. ND stack. SAEEi11¥/Sl.JMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 305.00 None 2/9/2004 12115/2003 1211712003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: ND and pinch points IFRQ'M To? HRS ·FRQ'M >l1¢1 / ±J ........~ ... ....> 06:00 09:00 3.00 17,665 17,665 TA OTHER TRIP PKRD UD two singles out of each string, space out with pup joints to have a 15' stroke plus 6' of additional pipe for setting down on seals as per Baker recommendation. M/U dual hangers and landing joints. 09:00 09:30 0.50 17,665 17,665 TA OTHER TRIP PKRD Make penetration of control line through hangers. 09:30 10:00 0.50 17,655 17,665 TA OTHER TRIP PKRD RIH and engage DSM on collet at 9904'. Attempt to shear pins to release DSM with 45K down, full string weight. Observed onl} 4' of compression with 45K down. Would not have been able to land hanger in head at this space out. 10:00 13:00 3.00 17,655 17,655 TA OTHER TRIP PKRD LD landing joints and dual hangers. Change pup joints to shorten space out by 4'. 13:00 14:00 1.00 17,655 17,655 TA OTHER TRIP PKRD Make up dual hangers and landing joints. 14:00 15:00 1.00 17,655 17,655 TA OTHER TRIP PKRD Make penetration of control line through hangers. 15:00 16:00 1.00 17,655 17,655 TA OTHER TRIP PKRD RIH and engage DSM on collet at 9904'. Shear off of DSM with 45K after four attempts. Continue to slack off and engage seals in PBRs and land hanger in wellhead. Tighten hanger holddown screws. 16:00 17:00 1.00 17,655 17,665 AF RCMP TEST Pressure up on annulus to 1500 psi, observe 30 psi/30 see loss, similar to previous test. - No returns up tubing. Both seals stung in and tested. Pressure up on long string to 3000 psi to set GT í dual packer. Test annulus to 3000 psi for 10 minutes to confirm packer set. 17:00 17:30 0.50 17,665 17,665 AF RCMP PLRNRP LD landing joints and set 3.5" BPV. 17:30 18:00 0.50 17,665 17,665 AF RCMP EQUIP LD Pollards stainsteelline and sheaves from derrick. 18:00 19:00 1.00 17,665 17,665 AF RCMP EQUIP Clear floor of control line and tubing running equipment. 19:00 00:00 5.00 17,665 17,665 AF RCMP EQUIP Clear floor of all subs, tools and equipment. LD dual mousehole. Remove catwalk, V-door, remove all rams, pull master bushing. Cleaning pits. 00:00 06:00 6.00 17,665 17,665 AF RCMP EQUIP ND BOP's, continue cleaning pits. . . Printed: 4/29/2004 4:07:07 PM WELL NAME KASILOF SOUTH 1 L 1 PI:NSIJ"((ppg) 8.65 FV PVfYP GELS AVG. CONN: MAX. CONN: Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids . . MARATHON OIL COMPANY Daily Completion Report Exploitation. Gas MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: ONNEL DATA URS COMPANY 12 155.00 Baker Oil Tools 3 30.00 R&K Industrial 2 12.00 Weatherford 2 12.00 Pollard Wireline LAST BOP TEST: 12/15/2003 ID 6.184 2.992 7.000 3.500 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 8,160 10,160 16.02 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) 10,533 17,502 5,417 9,603 29.00 L-80 9.30 L-80 Printed: 4/29/2004 4:07:07 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOf SOUTH 1 L 1 SUPERVISOR Russ Trubv FIELD NAME IGL 30.6 I 74.00 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,665 AUTH MD TVD IDFS IDOL IRPT# DATE 10,000 100 I 100 119B 11-feb-2004 WBS SAPIWBS COST KB RIG PHONE NRI DX0309032CAPCMP01 I DAILY WELL COST I CUM Wt:LL "V~. . WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Spacinq out and pickinq UP hanqer. OPERATION COMMENTS Continue running dual 3 1/2" production tubing strings. MOCWI 907-260-6935 100.0000 COUNTY/OTHER I LAST CASING I NEÀ I """,,,... 3.500 (in) @ 17,502 (ft) I (in) @ 0 (ft) 24 HR FORECAST Land hanger, test seals, NU and test tree. -- IL"~'__' . MANHRS WORKED I ACCIDENT TYPE LAST SAFETY MTG 267.00 None 2/9/2004 ACCIDENT DESCRIPTION: SÂFETYSuMMAR¥ . . IBOP PSI TEST I LAST STOP CARP AUPIT 112/15/2003 1211712003 REGULATORY INSP? N I LAST RIG INSPECTION 12/11/2003 SAFETY MTG TOPICS: Icy location, slipping hazards. I ~RbM 1"9 flR.S FRÖIVI .'rb ....$q~ .~TgêL. 06:00 13:00 7.00 17,665 17,665 TA OTHER TRIP PKRD 13:00 14:00 1.00 17,665 17,665 TA OTHER EQUIP PKRD 14:00 15:00 1.00 17,665 17,665 TA OTHER TRIP PKRD 15:00 16:00 1.00 17,665 17,665 TA OTHER TRIP PKRD 16:00 17:00 1.00 17,665 17,665 TA OTHER TRIP PKRD 17:00 18:00 1.00 17,665 17,665 TA OTHER WAIT PKRD 18:00 05:00 11.00 17,665 17,665 TA OTHER TRIP PKRD 05:00 06:00 1.00 17,665 17,665 TA OTHER TRIP ·ii....>< Y<Yi» Continue running dual strings of 3 1/2", 9.3 ppf, Hyd 563 tubing, checking each connection to 4500 ft-Ibs. RU to run injection lines. Install dual injection mandrels in string at 2500'. Connect injection line to lower mandrel and test to 1000 psi. Lower mandrel hung up in dual slips, work to free mandrel. Connect injection line to upper mandrel, unable to test line to 1,000 psi. Bad rupture disk in mandrel. Wait on new injection mandrel from town. Continue running dual strings of 3 1/2", 9.3 ppf, Hyd 563 tubing, checking each connection to 4500 ft-Ibs. Land DSM on orientation lug at 9904' with 10K down. Snap out of collet with 20K overpull to confirm latched. Repeat confirmation. Space out with pup joints and MIU dual tubing hangers. ., PKRD AVG. CONN: MAX. CONN: IECDI~ I FC/T.SOL OIW~I 1 I I I 1 I I I I MUD GAS AVG. TRIP: MAX. TRIP: . -- I UI:N;:)I f'r'(iJIJ.9) I 8.65 1 PP I FV r;v¡yp 1 GELS 1 I 1 I 1 I Cl/Ca ,. 29,500 I 1 --. H2S LIMe I 1:;:) I ...." .11 I 1 1 UNITS units I I AVG. BKGRD: MAX. DRL: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling fluids Baker Oil Tools SERVICE PERSONNELYDATA NO. HOURS COMPANY 12 155.00 R&K Industrial 1 12.00 Weatherford 2 12.00 Alaska's Best Water 2 12.00 S&R Enterprises 3 36.00 Alaska Oil Sales SERVICE POR. Nt); 2 4 1 1 1 HOURS 12.00 24.00 1.00 1.00 2.00 Printed: 4/29/2004 4:07:04 PM . WELL NAME KASILOF SOUTH 1 L 1 LAST BOP TEST: 12/15/2003 SIZE in 7.000 3.500 . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas ING/SWMMARY LAST CASING TEST: MAXSICP MDft 1,300 (psi) @ 11.40 (ppg) 10,533 (psi) @ (ppg) 17,502 12/22/2003 BURST 8,160 10,160 Printed: 4/29/2004 4:07:04 PM M1:XR1:XTHON O.ll. GOMR.A.N¥ Pßge1iof1 Ð~i!y()omplétiøh··.Répört E::~pl.ø.it¡1tion.····"··.·.~.ª$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# OATE KASILOF SOUTH 1L 1 30.6 74.00 17 ,665 10,000 99 99 118B 10-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Russ Trubv Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTY/OTHER I LAST CASING 17,502 (ft) INEXTl."""(7n) @ O(ft} I ~~~..~. . Alaska 3.500 (in) @ CURRENT STATUS / MTS 24 HR FORECAST Waitina on weather, due to excessive wind Qusts OPERATION COMMENTS Continue running 3-1/2" dual production tubing strings. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT REGULATORY INSP? I LAST RIG INSPECTION 267.00 None 2/9/2004 12115/2003 12/17/2003 N 12/1112003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Tripping puipe, handling two strings of tubing. _\~ßt, ... ~ 1f:~9M .iT9 H~$ ·f'~ºMi 1"9. .... 06:00 08:30 2.50 17,665 17,665 TA OTHER TRIP PKRD Continue TIH with 3-1/2" 9.3# L-80 dual production tubing strings from 2462' to 3552'. 08:30 14:00 5.50 17,665 17,665 TA OTHER TRIP PKRD Discover Hydril 533 connections on both strings loose. Check numerous connections that did not meet minimum torque requirements. TOOH to production packer assembly. 14:00 04:30 14.50 17,665 17,665 TA OTHER TRIP PKRD TIH with 3-1/2" dual production tubing strings to 4827'. Torque turn all connections to 4500 ftllbs. 04:30 05:00 0.50 17,665 17,665 TA OTHER RIG PKRD Shut down due to excessive winds with tubing in derrick. Service rig and top drive. 05:00 06:00 1.00 17,665 17,665 TA OTHER WAIT PKRD Wait on weather. 8.65 I.. 1 ¡'F~I ¡~,¡ I CUM~ ------ iFV ··f?Ylr:if? ·~~ËS YV""'I'1' I'1,..rFëtr~hIQiW. ·.i¢iiÞ~ :I"''''I~' ., . ti I I I I I I I I I 29,500 I I I I I .. ·.···I\IIU[)·(;».5 I \-INrrS I units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: COMPANY Nö.iP'~~ r-·~~:~GIE Nabors Alaska Drilling 12 155.00 R&K Industrial 2 12.00 - Marathon 1 12.00 Weatherford 4 24.00 Epoch Well Services 2 12.00 Alaska's Best Water 1 1.00 M-I Drilling Fluids 2 12.00 S&R Enterprises 1 1.00 Baker Oil Tools 3 36.00 Alaska Oil Sales 1 2.00 CASING SUMMARY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SiZE (in) ID(in) SHOE TEST (Dt)(j; MAXSICP MO(ft) TvQ (ft) WT (Ib/ft) GRADE BtJRST (psi) 7.000 6.184 16.02 1,300 (psi) @ 11.40 (ppg) 10,533 5,417 29.00 L-80 8,160 3.500 2.992 (psi) @ (ppg) 17,502 9,603 9.30 L-80 10,160 . . Printed: 4/29/2004 4:07:02 PM . . <> M~R~TPRØ ØØMR~N,( t-!a9~...·lPT;¿ pailY· Cq.....þlêtj9l1Repòrt Exþ'ØitatiÇ)Il'I·.·.~····.Gàs WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL !RPT# DATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 98 98 117B 09-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIW8S COST Randv Ratliff Nabors 273E DX0309032CAPCMP01 I DAILY WELL COST I CUM "JELL COSl .- FIELD NAME RIG PHONE MOC\A/! NRI WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT ëASING I LEAKOFF Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Runninq dual production tubinq strinqs @ 2462'. OPERATION COMMENTS LDDP and BHA. P/U FORMation Junction dual seal module and dual production packer assembly. Running dual strings of 3-1/2" production tubing. SAFETY/S.lJMMÄRY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG~ ·I~OP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 259.00 None 2/9/2004 12115/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Laying down drill pipe. Running tubing, communication. ~ .- it .. FRqrJ¡/ 1"Ó H~§ f~qM. $va .. .... 06:00 15:30 9.50 17,665 17.665 TA OTHER TRIP PKRD Lay down 5-1/2" and 4" drill pipe. 15:30 16:00 0.50 17,665 17,665 TA OTHER TRIP PKRD RID laydown machine. 16:00 17:00 1.00 17,665 17.665 TA OTHER TRIP PKRD UD jars and HWDP. UD and clean junk baskets, recover 2 stainless steel methanol injection line bands. +1- 47 Bands recovered +1- 14 Bands left to recover. 17:00 18:00 1.00 17,665 17.665 TA OTHER CLEAN PKRD Clear rig floor, UD excess tools and equipment. 18:00 20:30 2.50 17,665 17.665 TA OTHER NUND PKRD Pull wear bushing, set test plug. Change upper pipe rams from VBR's to 3-1/2" dual rams. 20:30 21:00 0.50 17,665 17,665 TA OTHER TEST PKRD Test upper pipe ram bonnets to 250 I 3500 psi, 5 minutes each test. Pull test plug. 21:00 21:30 0.50 17,665 17,665 TA OTHER TRIP PKRD RlU 3-1/2" dual tubing handling equipment. 21:30 22:00 0.50 17,665 17.665 TA OTHER TRIP PKRD UD 2 stands of 3-1/2" tubing out of derrick. 22:00 01:00 3.00 17,665 17,665 TA OTHER TRIP PKRD Hold safety meeting. P/U dual seal module I GT production packer assembly. MIU custom made clamp on top of packer, torque 16 set screws to 51 ftIIbs each. 01:00 01:15 0.25 17,665 17,665 TA OTHER SAFETY PKRD Hold safety meeting. 01:15 06:00 4.75 17,665 17,665 TA OTHER TRIP PKRD TIH with dual strings of 3-1/2" 9.3# H533 production tubing to 2462'. I PI' I ¡ECDI IMU.AJPA11..Yc;:qS......1 ISl.IMCO$'" - DI2I\1SITY(ppg) 8.65 FV PVIYP GE.LS .IW~i!. n.¡p I FC/T.$ÒL ..qrf!. ··.¿..SáPh/pMI~f/MfJ ~I/~a IC~CI2(wt%j.·H?SI!.iI,~·,..L ..."ëC I I I I I I I I I I I I 29,500 I I I I I MlJDGÄS I UNITS units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNELDÄTA POB @06:0q: COMPANY I SERVICE NO. HOL!f{$>11 COMPANY I SERVICE j NO. 1.HQ@§ Nabors Alaska Drilling I 12 155.00 Marathon I I 1 I 12.00 Printed: 4/2912004 4:07:01 PM MARATHONOIL)GOMPANY n. ri F<:!!:::II::L.·.· Dãily Gqtr1pletiøn Report E)(pl9itation ..Gas WELL NAME KB IGL 124 HR PROGITMD ITVD IDFS DOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 98 98 117B 09-Feb-2004 PERSONNEL DATA i"'uq COMPANY SERVICE NO. HOURS COMPANY SERVICE .··NÖ. .............. ''c"W Epoch Well Services 2 12.00 R&K Industrial 2 8.00 M-I Drilling Fluids 2 12.00 Weatherford 4 24.00 Baker Oil Tools 3 36.00 CASiNG stfIVíMÀR.Y .. LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE lin) IDlin) SHOE TEST (ppg; o"'vb'r'n MD (fiY T\lo¡ftj V'lT(lb/fi) GRADE ßl.Jß.ST (p~i) 7.000 6.184 16.02 1 ,300 (psi) @ 1 1.40 (ppg) 10,533 5,417 29.00 L-80 8,1 60 3.500 2.992 (psi) @ (ppg) 17,502 9,603 9.30 L-80 10,160 . . Printed: 4/29/2004 4:07:01 PM ) MJ:XRJ:X"UHON·.. .Oll..iG.OMBJ:XN¥ Pagè1·..of2 [)àily. GQrnpIØ~¡oniRØpørt Exploitation - Gas WELL NAME KB GL 24 HR PROG TMO TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 97 97 116B 08-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Randy Ratliff Nabors 273E DX0309032CAPCMP01 - - FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST ! CUM VYI::L&.. v_... . WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASINI> I LEAKOFF Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Lavino down drill pipe. Lay down drill pipe, run dual production tubing strings OPERATION COMMENTS TOOH and UD dual dummy test seal assembly. TIH and displace with packer fluid. Laying down drill pipe. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 286.00 None 2/8/2004 12115/2003 12/1712003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Laying down dual seal module assembly and drill pipe. OPEf_ IF'RQM TO ~R~ F;R(DM -rÔ 6Uß ~~A~¡:i 06:00 11:30 5.50 17,665 17,665 TA OTHER TRIP PKRD TOOH to packer assembly. 11:30 12:00 0.50 17,665 17,665 TA OTHER TRIP PKRD LID drill pipe handling tools, RIU 3-1/2" dual tubing handling equipment. 12:00 15:00 3.00 17,665 17 ,665 TA OTHER TRIP PKRD UD Y -Block, GT dual packer, and dual seal module assembly·s. Found 1 stainless steel band on top of DSM, +1- 16 bands left to recover. 15:00 15:30 0.50 17,665 17,665 TA OTHER TRIP PKRD Change handling equipment, clear rig floor. 15:30 16:00 0.50 17,665 17,665 TA OTHER RIG PKRD Service rig and top drive. 16:00 16:30 0.50 17,665 17,665 TA OTHER TRIP PKRD M/U junk basket BHA. 16:30 17:00 0.50 17,665 17,665 TA OTHER RIG PKRD Repair and re-test crown-o-matic. 17:00 22:00 5.00 17,665 17,665 TA OTHER TRIP PKRD TIH with BHA to 9867'. 22:00 23:30 1.50 17,665 17,665 TA OTHER RIG PKRD Slip and cut drill line. 23:30 02:00 2.50 17,665 17,665 TA OTHER TRIP PKRD RIU laydown machine. Finish preping pits for displacement. 02:00 03:30 1.50 17,665 17,665 TA OTHER CIRC PKRD Wash down to 9890'. Pump a 100 BBL, 6% KCL spacer. Displace hole with clean 6% inhibited KCL water, with BJ W-14 friction reducer and Conqor A303 corrosion inhibitor. 03:30 04:00 0.50 17,665 17,665 TA OTHER CIRC PKRD Slug pipe, blow top drive down. 04:00 06:00 2.00 17,665 17,665 TA OTHER TRIP PKRD Hold safety meeting, LDDP. DENSITY(ppg) 8.65 Ippl IEçol IM.ûDDÂ"'A.li·.PAj~'(çd~T··..·1 1..ÇUiVI<?·PS]" Wi../I-ITHP I %S~~d/MBT I I. PflMf I ·Tcaçl~('oVto¡.,j~~~ - LIIVIEI -~ FV PVNP GELS FC/T.SOL Ofw Ph/pM l".1/\;,.a 1:;) ¡óRPM I I I I I I I I I I I I 29,500 I I I 1 I MUD GAS I UNITS I units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNEL DATA PQß···.@()6:9(): COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Nabors Alaska Drilling 12 155.00 M-I Drilling Fluids 2 12.00 Marathon 1 12.00 Baker Oil Tools 3 36.00 Epoch Well Services 2 12.00 Oilfield Hot Shot Service 1 3.00 Printed: 4/29/2004 4:07:00 PM WELL NAME KASILOF SOUTH 1 L 1 COMPANY R&K Industrial SERVICE . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas CASING SUMMARY LAST CASING TEST: MAX/SlOP MD ft 1,300 (psi) @ 11.40 (ppg) 10,533 (psi) @ (ppg) 17,502 . 5,417 9,603 SERVICE 29.00 9.30 L-80 L-80 8,160 10,160 Printed: 4/29/2004 4:07:00 PM . . .. MARATt:I.(:¡)NT€Ub>0(:¡)MPANV D~lIy ..OomþløfiÞÔRepOrf Expl()i~ / WELL NAME KB GL 24 HR PROG TMD TVD IDFS IDOL !RPT# fDATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 96 96 115B 07-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MO WBS I SAPIWBS COST Randv Ratliff Nabors 273E DX0309032CAPCMP01 FIELD NAME R!G PHONE Mae WI NR! I CAlLY WELL COST I CUM WELL COST I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING 17,502 (ft) INEXTl.A'''(~n) @ 0 (ft) 1'-t:f\l'\.ul""t' Alaska 3.500 (in) @ CURRENT STATUS 1 MTS 24 HR FORECAST TOOH with dual seal module assembly. OPERATION COMMENTS Make successful dual seal module I GT packer dummy test run. SÄFETYsllMMÄR.Y MANHRS WORKED I ~CCIOENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 248.00 None 2/6/2004 12115/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Handling dual string tools and pinch points. O!¥ IAn'" .. i .. . P8ASOÞ iT .·T. FRoM fQ HRS FROM ...0 iSl)l3 J;RßP .!'''''.' 06:00 07:00 1.00 17,665 17,665 TA OTHER TRIP PKRD Finish RIU 3-1/2" dual string handling tools and equipment. 07:00 12:00 5.00 17,665 17,665 TA OTHER TRIP PKRD MIU dual seal module and GT packer assembly. Unable to install custom made clamp above packer in the field due to the close tolerance of the clamp and GT packer mandrels. 12:00 13:00 1.00 17,665 17,665 TA OTHER TRIP PKRD LID GT packer assembly. 13:00 18:30 5.50 17,665 17,665 TA OTHER WAIT PKRD Send GT packer assembly to shop for clamp installation. 18:30 22:00 3.50 17,665 17,665 TA OTHER TRIP PKRD MIU GT packer assembly to dual seal module. Install custom made Y-Block running assembly. 22:00 04:30 6.50 17,665 17,665 TA OTHER TRIP PKRD TIH to 9874' with assembly on drill pipe to make dummy test run. 04:30 05:30 1.00 17,665 17,665 TA OTHER TRIP PKRD Slack off and land dual seal module in FORMation Junction collet lug @ 9904' with 1 OK. PIU and snap out to collet profile with 30K overpull. Re-set DSM, slack off and shear off assembly with 15K, continue slacking off landing dual seal assemblies in Leg #1 and #2 seal bores simultaneously. Test seals in both legs down drill pipe to 500 psi with 8.9 PPG KCL water for 15 minutes with no leak-off. Release pressure, pull seals with 10K overpull, continue P/U and snap DSM out of collet profile with 30K overpull. 05:30 06:00 0.50 17,665 17,665 TA OTHER TRIP PKRD Slug pipe, blow down top drive. DENSITY(Ppg) 8.90 IF''''! IECD IMllD DATAl W\ILYc(:>s....1 iá' FV PVIYP I GELS I i.iilL..I+d'" I. FC/T.SOL OIW %$ål1c1/MBT I Ph/pM [pf/lVi; I \",ii1l\",iiCl 82$ LIN!p ES lijK~lv;i 35 5/11 I 4/5 / I 11.0 199 I I 8.001 I I I 51,000 I I MUD GAS UNITS .1 units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERS0NNELDATA PpB@06lPO: COMPANY I SERVICE NO. HQYRS.II COMPANY I SERVICE NO. HÖI.)RS Nabors Alaska Drilling I 12 155.00 Marathon I 1 I 12.00 Printed: 4/29/2004 4:06:59 PM WELL NAME KASILOF SOUTH 1 L 1 COMPANY Epoch Well Services M-I Drilling Fluids Baker Oil Tools Oilfield Hot Shot Service . . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas SERVICE PERSONNELÐATA HOURS COMPANY 2 12.00 R&K Industrial 2 12.00 Alaska Oil Sales 3 36.00 Weatherford 1 3.00 S&R Enterprises 6.00 2.00 8.00 2.00 SERVICE 1 1 1 2 6.184 2.992 NEXT BOP TEST: 12/22/2003 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) 10,533 17,502 5.417 9,603 29.00 9.30 L-80 L-80 8,160 10,160 Printed: 4/29/2004 4:06:59 PM MARATH(i!).NC>U,.,Q(i!)MPAN¥ [)aily.~øtnplêtÎ9nR~pørt l3~þIØitâtio.ni~.·Gª$ WELL NAME KB IGL 24 HR PROG TMD TVD DFS IDOL JRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 95 95 114B 06-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Randv Ratliff Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM ..~~~ V~V '-_ I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTYIOTHER I LAST CASING I NEXT C..."".'" I ~-~.._. . Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS I MTS 24 HR FORECAST RIU 3-1/2" Tubinq handlinq tools. Make dualleq dummy seal test run. OPERATION COMMENTS Test Leg #1 PBR seals. Pressure test intermediate casing. Pull Leg #1 diverter. SAF'ETYStJMMÄR¥ MANHRS WORKEO I ~CCIDENT TYPE I ~AST SAFETY MTG IBOP PSI TEST I ~AST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 236.00 None 2/5/2004 12115/2003 12/1712003 N 12/11/2003 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Handling BHA's, tripping pipe. > > -- > ..... IFRPM TO it'!~$ F~9M· it¢i\..··.i $IJ~ ". 06:00 10:00 4.00 17,665 17,665 TA OTHER TRIP PKRD Finish TIH with PBR seal assemby and 9-5/8" Champ Packer to 9830'. 10:00 11:30 1.50 17,665 17,665 TA OTHER TRIP PKRD Wash in hole with seal assembly @ 2 BPM to top of Leg #1 FHL Packer PBR @ 9918'. Attempt to enter PBR with blunt nose seal assembly several times without success. Rotate seals while slacking off to avoid setting the Champ Packer, still unable to enter the SB. Finally jar seals into top of PBR after several attempts, monitor pump pressure increase upon entry. SID pump and release pressure. Slack off 10' and land seals in bottom of PBR @ 9928', confirming PBR length and placement. Test seals to 1000 psi. PIU seals 5', rotate pipe and set Champ Packer with seal element @ 9871' with 40K (32' above collet lug in FORMation Junction) 11:30 12:30 1.00 17,665 17,665 TA OTHER TEST PKRD Pressure test 9-5/8" Intermediate casing above packer to 2000 psi with 8.9 PPG water for 15 minutes with no leak-off. Increase pressure to 3000 psi and monitor for 30 minutes with no leak-off 12:30 13:00 0.50 17,665 17,665 TA OTHER TRIP PKRD Pressure up on DP to 500 psi. Pull seals out to PBR while unsetting Champ Packer. Monitor pressure loss after picking seals up 4'. 13:00 13:30 0.50 17,665 17,665 TA OTHER TRIP PKRD Slug pipe. Blow down top drive and choke manifold. 13:30 17:30 4.00 17,665 17,665 TA OTHER TRIP PKRD TOOH to BHA. 17:30 20:00 2.50 17,665 17,665 TA OTHER TRIP PKRD LID seal assembly and Packer. Discover 1 SS band lodged in O-Jar mandrel housing. PIU FJD tool and function test collet. 20:00 23:30 3.50 17,665 17,665 TA OTHER TRIP PKRD TIH with FJD to 9826'. 23:30 01:00 1.50 17,665 17,665 TA OTHER TRIP PKRD Wash down and place FJD stinger thru diverter and circulate clean. Pump slug, engage Leg #1 Swage Diverter after several attempts, pull diverter free with 1 OOK over-pull. 01:00 01:30 0.50 17,665 17,665 TA OTHER RIG PKRD Service rig and top drive. 01 :30 04:30 3.00 17,665 17,665 TA OTHER TRIP PKRD TOOH to BHA. 04:30 05:30 1.00 17 ,665 17,665 TA OTHER TRIP PKRD LID Junk baskets, FJD tool, and Leg #1 swage diverter. Discover 1 SS band wedged in between FJD tool orientation . . Printed: 412912004 4:06:55 PM WELL NAME KASILOF SOUTH 1L 1 FROM TO HRS 04:30 05:30 1.00 05:30 06:00 0.50 AVG. CONN: MAX. CONN: FROM 17,665 17,665 Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids 6.184 2.992 . . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas TO SUB 17,665 TA 17,665 TA OPERATIONS SUMMARY PHASE Of> TRBL DESCRIÞTlON OTHER TRIP PKRD profile and diverter housing. OTHER TRIP PKRD RIU 3-1/2" tubing handling tools. Recover 2 stainless steel bands last 24 hours, +1- 17 left t recover. AVG. BKGRD: MAX. DRL: 3 36.00 1 1.00 1 6.00 2 2.00 NEXT BOP TEST: 12/22/2003 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) 10,533 17,502 5.417 9,603 29.00 9.30 L-80 L-80 8,160 10,160 Printed: 4/29/2004 4:06:55 PM , MARATHC>N<Dll...€<DMF?AN'Y [)åil'l<~()tnþ!~tiöJ1··.RØþort E:¡Çplói~ØtiÖrf..·.~Ø$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 94 94 113B 05-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I ""PIWRS COST Randy Ratliff Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DA!L ~ ~ELL COST ¡CUM WELL COST I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATEJPROV COUNTY/OTHER I LAST CASING INEXTL __u._ I ~~~n~. . Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST TIHwith PBR seal assembly and Champ Packer. OPERATION COMMENTS Continue fishing for stainless steel band debris lost in hole, recover 8 today. Clean out FORMation Junction Leg #1 FHL Packer PBR wth polish mill. SÂFE~St.n··· MÂR.¥ ...... MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 245.00 None 2/4/2004 12115/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pinch points, tripping pipe, handling BHA's. IFROM 19 J- R§< ..·FR9M···· to $Ûâ - ~ ... < 06:00 08:00 2.00 17,665 17,665 TA OTHER TRIP PKRD Finish TOOH with reverse basket. 08:00 09:30 1.50 17,665 17,665 TA OTHER TRIP PKRD Clean out reverse and junk baskets. Recover 6 stainless steel methanol injection line bands in reverse basket, junk baskets were empty. MIU BHA. 09:30 12:30 3.00 17,665 17,665 TA OTHER TRIP PKRD TIH to 9843'. 12:30 14:00 1.50 17,665 17 ,665 TA OTHER TRIP PKRD Wash I Ream in hole to top of Leg #1 FHL Packer PBR @ 9918'. Pump a 50 BBL Hi-Vis polymer sweep, work reverse anc junk baskets attempting to PIU SS band debris. 14:00 17:30 3.50 17,665 17,665 TA OTHER TRIP PKRD Slug pipe, blow down top drive. TOOH to BHA. 17:30 18:30 1.00 17,665 17,665 TA OTHER TRIP PKRD Clean out reverse and junk baskets. Found 1 SS band in junk basket. UD reverse basket, P/U a 3-9/16" OD PBR polish mill. 18:30 21:45 3.25 17,665 17,665 TA OTHER TRIP PKRD TIH to 9846'. 21:45 22:15 0.50 17,665 17,665 TA OTHER TRIP PKRD Wash I ream in hole to top of Leg #1 FHL Packer PBR @ 9918'. Clean out PBR from 9918' to 9926'. 22:15 00:00 1.75 17,665 17,665 TA OTHER TRIP PKRD Trip for BHA to 6500'. 00:00 00:30 0.50 17,665 17,665 TA OTHER RIG PKRD Service rig and top drive. 00:30 02:30 2.00 17,665 17,665 TA OTHER TRIP PKRD Finish TOOH to BHA. 02:30 05:00 2.50 17,665 17,665 TA OTHER TRIP PKRD LID polish mill and 2, 4-3/4" drill collars. Wear pattern on bottom of polish mill locator sub confirms depths. Found 1 SS band while cleaning out junk baskets. P/U 3' 80-36 molded seal assembly. PIU 9-5/8" champ packer and finish MIU BHA. 05:00 06:00 1.00 17,665 17,665 TA OTHER TRIP PKRD TIH with BHA. Recover 8 Stainless steel bands last 24 hours, +/- 19 left to recover. DEN$ITY(ppg)<.·1 8.85 Ipp I IEG.DI I MUD···DATÀ DÄIL'(CØ$T I rClJMC()~t - - = FV PVNP ~Ek.$j W(4HTHPI FCIT;$OL OIW 'M¡and/Mln I Ph!P.1VI Iptli'J1f I \.il/\.ia I ~~CI2(wt%~.I-I2.$ LlMt: I t:~I\I·,~·M 38 5/12 5/7 I / I I I I I 8.001 I I I 48,000 I I I I I . . Printed: 4/29/2004 4:06:54 PM M.t\RJ\.THQNQlbeøMPAN¥ Page2Öf2 Dållyeol11pl~ti9rtRépo r1: ç)<.p I ()¡táti()n-.~á$ WELL NAME KB GL 124 HR PROGITMD ITVD IDFS DOL IRPT# I DATE KASILOF SOUTH 1 L1 30.6 74.00 17,665 10,000 94 94 113B 05-Feb-2004 MtlDGAS I UNITS I units AVG. CONN: AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNEL DATA PQ¡3@O€5:0Q: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Nabors Alaska Drilling 12 155.00 Baker Oil Tools 3 36.00 Marathon 2 24.00 Oilfield Hot Shot Service 1 1 .00 Epoch Well Services 2 12.00 S&R Enterprises 1 1 .00 M-I Drilling Fluids 2 12.00 Halliburton 1 4.00 CASINGSÛMMÄRY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE(irÙ ID(irJ) SHOE ·11:.::> (PPQ MD(ftJ TVD(ft) vvt(lp/ft) . GRADE 7.000 6.184 16.02 1 ,300 (psi) @ 1 1 .40 (ppg) 10,533 5,417 29.00 L-80 8,1 60 3.500 2.992 (psi) @ (ppg) 17,502 9,603 9.30 L-80 10,160 . . Printed: 4/29/2004 4:06:54 PM M~R~TH(1)N;€)u...;··e(1)MP~NY [¡)ai Iy eQl'Qpl~ti.QrtRep()rt I:~P biti:lti()h..Gª~ WELL NAME KB IGL 24 HR PROG TMO TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 17 ,665 10,000 93 93 112B 04-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Randv Ratliff Nabors 273E DX0309032CAPCMP01 FIELO NAME RIG PHONE MOCWI NRI I DAILY WELL COST i CUM WELL COS1 I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT '-'ASING I Lt:A,,"V~~ Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS 1 MTS 24 HR FORECAST TOOH with reverse basket. OPERATION COMMENTS Change FORMation Junction diverters. TIH with reverse basket to PIU debris left in hole. ŠÄFfETYSUIVIMÄRY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSITEST I LAST STOP CARD AUOIT I ~EGULATORY INSP? I LAST RIG INSPECTION 244.00 First Aid 2/2/2004 12115/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: NAD employee slipped on ice and strained his shoulder. SAFETY MTG TOPICS: Remain focused during back to back trips. FROM TO HR$; ;f3RQNi·; to >.SPß _M~R~ .;;.. « 06:00 06:15 0.25 17,665 17,575 TA OTHER TRIP PKRD Finish TIH with FJD tool to 9889'. 06:15 07:00 0.75 17,665 17,665 TA OTHER TRIP PKRD Wash down and place FJD stinger thru diverter. Circulate 25 BBLS @ 4 BPM to clean diverter. Pump slug and engage Leg #2 diverter @ 9904'. Pull off of diverter several times with 20K overpull. Circulate and function FJD tool. Re-engage and pull diverter free with 90K overpull. 07:00 11:00 4.00 17,665 17,665 TA OTHER TRIP PKRD Blow down top drive, TOOH to BHA. 11:00 13:00 2.00 17,665 17,665 TA OTHER TRIP PKRD UD Leg #2 diverter. UD FJD tool and PIU re-dressed tool. Engage Leg #1 swage diverter. Finish PIU BHA. 13:00 16:30 3.50 17,665 17,665 TA OTHER TRIP PKRD TIH with diverter to 9889'. 16:30 17:00 0.50 17,665 17,665 TA OTHER TRIP PKRD Place Leg #1 swage diverter in FORMation Junction collet lug @ 9904'. Snap out of collet with 115K overpull. Re-set diverter, confirm set with 30K overpull. Circulate and release diverter. 17:00 21:00 4.00 17,665 17,665 TA OTHER TRIP PKRD Slug pipe, blow down top drive. TOOH to BHA. 21:00 22:30 1.50 17,665 17,665 TA OTHER TRIP PKRD Lay down FJD tool. Re-configure BHA, picking up 2, 4-3/4" drill collars and 5-3/4" OD reverse globe basket. 22:30 00:00 1.50 17,665 17,665 TA OTHER TRIP PKRD TIH to 3530'. 00:00 00:30 0.50 17,665 17,665 TA OTHER RIG PKRD Service rig and top drive. 00:30 02:30 2.00 17,665 17,665 TA OTHER TRIP PKRD Finish TIH to 9747'. 02:30 04:30 2.00 17 ,665 17,665 TA OTHER TRIP PKRD Pump reverse basket diverter ball down drill pipe. Wash in hole to top of Leg #1 FHL Packer PBR @ 9918'. Pump a 50 BBL Hi-Vis polymer pill, work reverse and junk baskets attempting to PIU stainless steel bands lost in hole. 04:30 06:00 1.50 17,665 17,665 TA OTHER TRIP PKRD Slug pipe, blow down top drive and TOOH. D~N$'TY(ppà) I 8.75 I PP IECDI IIVIUD.lb~I'YCO$TI - CUMCO$T FV PVIYP GEL$ I ;WI.:IHtHP I FCIT.$OL olW.*4§à" .;.; Ph/pM I PflMf I Cl/Ca I CaCI2(v1%fH2S LIME I E~..lijRPr¡ " 37 5/11 5/6 I I I I I 1 I I I I I 44,000 I I I I MUD GAS I UNIT$ units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: . . Printed: 4/29/2004 4:06:49 PM . . MARATHC>fSlCDIl..GC>M RAfSlY Ð.é1ilyGÒmplètioITReÞQrt Explojt~tion - Gas WELL NAME KB IGL 124 HR PROGITMD ITVD IDFS DOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 93 93 112B 04-Feb-2004 PERSONNEl.. DATA PQB@Q6:QO; COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Nabors Alaska Drilling 12 155.00 Baker Oil Tools 3 36.00 Marathon 2 24.00 Oilfield Hot Shot Service 1 3.00 Epoch Well Services 2 12.00 Alaska Oil Sales 1 1.00 M-I Drilling Fluids 2 12.00 S&R Enterprises 1 1.00 CASING SUMMARY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE(ih) IDOn) SHOE TEST (Dbal MAXSICP MDÜÙ TVD(ft) WT(ll:i/ftY GRADE pv!"\prlP;;;1) 7.000 6.184 16.02 1,300 (psi) @ 1 1.40 (ppg) 10,533 5,417 29.00 L-80 8,1 60 3.500 2.992 (psi) @ (ppg) 17,502 9,603 9.30 L-80 10,160 Printed: 4/29/2004 4:06:49 PM . . MARATHONOILO"OMRAN¥ t>äil¥~·ømpl~tiøflRèP()rt Exploit~tion -~.~$ . WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 92 92 111 B 03-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAP/WBS COST Castleman I Ratliff Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I"AIIVW'''' ""ST ¡CUM WELL COST I ...,......., ......L..""'..... WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOf~ Alaska 3.500 (in) (ã) 17,502 (ft) (in) (ã) 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST TIH with Leq #2 Diverter pullinq tool. Pull Leq #2 Diverter, Run Leq #1 Diverter OPERATION COMMENTS TIH.Polish Leg #2 liner setting sleeve and seal bore.POOH.BHA.RIH. Confirm and test seal bore length with seal assembly. POOH. BHA. RIH. SAFETY SUMMARY MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 241.00 None 2/2/2004 12/15/2003 12/17/2003 12/11/2003 ACCIOENT DESCRIPTION: SAFETY MTG TOPICS: Handling BHA's. øPE~mløNSSUMM~RY ; ·FRÞ~ )tÞ ÅRS FROM ,.q SUB PHASE OP TR:BL "V" )i.·..).· 06:00 07:30 1.50 17,665 17,665 TA OTHER TRIP PKRD Finish TlH to 9850'. 07:30 09:00 1.50 17,665 17,665 TA OTHER CLEAN PKRD Wash down to Leg #2 liner top @ 9920'. Polish ZXP liner setting sleeve from 9920' to 9925' and seal bore from 9927' to 9932' with 5-1/8" x 3-7/8" tandem polish mill. Pump 50 BBL Hi-Vis polymer pill. 09:00 13:30 4.50 17,665 17,665 TA OTHER TRIP PKRD Trip to BHA. 13:30 14:30 1.00 17,665 17,665 TA OTHER TRIP PKRD LID polish mill, wear pattern on bottom of dress-off mill confirms polish mill depths. Clean out junk baskets, find 1 piece of stainless steel band debris. PIU a 2' 80-40 molded seal assembly on joint of 2-7/8" tubing. 14:30 17:30 3.00 17,665 17,665 TA OTHER TRIP PKRD TIH with seal assembly to 9869'. 17:30 18:15 0.75 17,665 17,665 TA OTHER TEST PKRD Wash in hole into top of Leg #2 liner setting sleeve at 2 BPM. Monitor pressure increase when seal assembly entered liner seal bore at 9927'. SID pump and bleed off pressure. Slack off 9' and land seal assembly in bottom of seal bore @ 9936', confirming seal bore length and placement. Test seals to 1000 psi. Pull seals out of bore and rotate drill string 180 degrees. Work pipe to rotate seals on bottom, re-Iand seals with no problem. 18:15 18:45 0.50 17,665 17,665 TA OTHER CIRC PKRD Pull seals out of seal bore 1'. Circulate around a 50 BBL Hi-Vis sweep @ 23 BPM to clean hole. 18:45 19:15 0.50 17,665 17,665 TA OTHER CIRC PKRD Pump and spot a 30 BBL Hi-Vis polymer pill in liner setting sleeve and across the FORMation junction. Pull 5 stands of drill pipe 19:15 20:15 1.00 17,665 17,665 TA OTHER RIG PKRD Slip and cut drill line. Re-set and test crown-o-matic. 20:15 23:30 3.25 17,665 17,665 TA OTHER TRIP PKRD Trip to BHA. 23:30 00:30 1.00 17,665 17,665 TA OTHER TRIP PKRD LID seal assembly and 2, 4-3/4" Drill collars. Seals looked good, no evidence of contact with band debris while in seal bore Seals worn on 1 side from riding on low side of hole during trip. No debris present in junk baskets. 00:30 02:00 1.50 17,665 17,665 TA OTHER TRIP PKRD P/U FJD pulling tool. Function test tool in rotary, unable to Printed: 4/29/2004 4:06:45 PM · . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation ~ Gas WELL NAME KASILOF SOUTH 1 L 1 OPERATIONS SUMMARY PHASE OP TRBL OTHER TRIP PKRD FROM TO HRS 00:30 02:00 1.50 FROM 17,665 TO SUB 17,665 TA 02:00 06:00 4.00 17,665 17,665 TA OTHER TRIP DESCRIPTION retract collet. Change to back-up FDJ tool and perform successful function test. Finish picking up remainder of BHA. TIH with FJD tool to retrieve Leg #2 diverter. PKRD AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: Nabors Alaska Drilling Marathon Epoch Well Services PERSONNEL DATA NO. HOURS COMPANY 12 155.00 M-I Drilling Fluids 2 24.00 Baker Oil Tools 2 12.00 Weaver Brothers (WBI) 2 3 1 12.00 36.00 2.00 6.184 2.992 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) LAST CASING TEST: MD ft 10,533 17 ,502 12/22/2003 8,160 10,160 Printed: 4/29/2004 4:06:45 PM MA~rrHl(¡')N(¡')ILC(¡,)M9ANY D~lily\Col"T1 þIQtion)R.epOrt I:.>c:pløit~tiof'l -ßas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 91 91 110B 02-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman I Ratliff Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCW! NR! I DAILY WELL COST ! CUM Wt:LL <.;u:> , WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 ST A TE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 3.500 (in) (â>. 17,502 (ft) (in) (â>. 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST TIH with polish mill. OPERATION COMMENTS Continue fishing for stainless steel methanol injection line bands in hole. Make 2 trips with go lobe basket, recover 9 bands. SÄIt;E'I'YSUMMARY MANHRS WORKED I ~CCIOENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 239.00 None 2/1/2004 12115/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Handling BHA's. Securing air tugger lines properly after use. IFRQM fuþ ··8f{$ FRQM· ,,0 ~l..Ja pl-tAS¡: IIIMMAå¥ ,._,. 06:00 07:00 1.00 17,665 17,665 TA OTHER TRIP PKRD Finish PIU 5-3/4" Reverse Globe Basket BHA. 07:00 11:00 4.00 17,665 17,665 TA OTHER TRIP PKRD TIH with BHA to 9880'. 11 :00 12:30 1.50 17,665 17,665 TA OTHER CIRC PKRD Pump down reverse basket diverter ball, with 250 psi increase after ball shifted sleeve in basket. Wash down to the top of Leg #2 ZXP liner top isolation packer @ 9920'. Pump a 50 BBL Hi-Vis polymer sweep, work reverse and junk baskets, attempting to PIU stainless steel methanol injection line debris left in hole. 12:30 16:00 3.50 17,665 17,665 TA OTHER TRIP PKRD Slug pipe, TOOH to BHA. 16:00 17:30 1.50 17,665 17,665 TA OTHER TRIP PKRD Break down and clean out baskets. Recover 8 SS bands in reverse basket, did not recover any debris in junk baskets. MIU same BHA. 17:30 21:00 3.50 17,665 17,665 TA OTHER TRIP PKRD TIH to 9844'. 21:00 22:00 1.00 17,665 17,665 TA OTHER CIRC PKRD Wash in hole 76' to top of Leg #2 ZXP liner top isolation packer @ 9920'. Pump a 50 BBL Hi-Vis polymer sweep, work reverse and junk baskets, attempting to PIU stainless steel methanol injection line debris left in hole. 22:00 02:00 4.00 17,665 17 ,665 TA OTHER TRIP PKRD Slug pipe, TOOH to BHA. 02:00 04:00 2.00 17,665 17,665 TA OTHER TRIP PKRD TOOH with BHA, recover 1 SS band in junk basket. Reverse globe basket was empty. UD reverse basket, PIU 3-7/8" OD X 5-1/8" OD tandem polish mill. 04:00 06:00 2.00 17,665 17,665 TA OTHER TRIP PKRD TIH with polish mill. Stainless steel bands Daily recovery +1-9 Total recovered +1- 34 Left in hole +1- 27 DENSITY(¡;¡pg). I 8.70 ·gÞI IEGOI I I\I1UD DATAl DApCOST I ..... .-- )LJMCOST FV PVIYP GEL~ I WGII-ITHP I FC/T.SOL OIW r,Sand/MEiT I Ph/PM I Pf/Mf .....,.....<1 1·"al..;'¡¡(Wt%~ .1-I2S LIME I ES 16RPM- I I I I I / I / I I I I I 32,500 I I I I I . . Printed: 4/29/2004 4:06:44 PM WELL NAME KASILOF SOUTH 1 L 1 AVG. CONN: MAX. CONN: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services LAST BOP TEST: 12/15/2003 7.000 3.500 6.184 2.992 . . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas MUD GAS AVG. TRIP: MAX. TRIP: SERVICE PERSONNEL DATA NO. HOURS COMPANY 12 155.00 M-I Drilling Fluids 2 24.00 Baker Oil Tools 2 12.00 16.02 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) 5,417 9,603 10,533 17,502 AVG. BKGRD: MAX. DRL: SERVICE DATE 02-Feb-2004 units 2 3 12.00 36.00 NEXT BOP TEST: 12/22/2003 29.00 9.30 L-80 L-80 8,160 10,160 Printed: 4/29/2004 4:06:44 PM M~R~"U*IG>NC>U.. CC>MR~N'¥ PaiIYQørop!etlonR~r~ort e){ploitatiøll-~ª$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# OATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 90 90 109B 01-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman I Ratliff Nabors 273E DX0309032CAPCMP01 FIELO NAME RIG PHONE MOCWI NRI I DA!l Y WELL COST ! C'" I.. '^n·'_LL \"U.;J I I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 ! 17,502 (ft) INEX' """"'(Tn) @ 0 (ft) .- I LEAKOFf STATElPROV COUNTY/OTHER I LAST CASING Alaska 3.500 (in) cæ CURRENT STATUS I MTS 24 HR FORECAST RIH. Run 5-7/8" Reverse circulatinç basket. Run polish mill OPERATION COMMENTS Run 8-1/8" reverse circulating basket.POOH.BHA.RIH.Set Leg #2 diverter.POOH. BHA. SAFSE1FYSl.JMMARY .i· MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSITEST I LAST STOP CARD AUOIT I ~EGULATORY INSP? I LAST RIG INSPECTION 264.00 None 1/30/2004 12/15/2003 12/17/2003 12/11/2003 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Slips, trips, and falls. Handling BHA. . .. ~ {...... {/ ........ ¡FROM "TO i.HRS to ~9.~ / .............. 06:00 07:00 1.00 17,665 17,665 TA OTHER TRIP PKRD Wash I ream in hole working reverse basket and boot baskets, attempting to PIU SS bands left in hole to 9895'. 07:00 09:00 2.00 17,665 17,665 TA OTHER CIRC PKRD Pump 50 bbl High Vis sweep and circulate to surface. 09:00 13:30 4.50 17,665 17,665 TA OTHER TRIP PKRD POOH 13:30 14:30 1.00 17,665 17,665 TA OTHER TRIP PKRD UD Reverse circulating basket and junk baskets. Recovered 2 stainless steel bands in junk baskets, no recovery in reverse circulating basket. Total of 36 bands left in hole. 14:30 15:00 0.50 17,665 17,665 TA OTHER TRIP PKRD PIU FJD running tool and function test. 15:00 15:30 0.50 17,665 17 ,665 TA OTHER RIG PKRD Change out dies in Top Drive gripper. 15:30 17:00 1.50 17,665 17,665 TA OTHER TRIP PKRD PIU Leg #2 diverter and engage FJD running tool. PIU remaine of BHA. 17:00 20:30 3.50 17,665 17,665 TA OTHER TRIP PKRD TIH to 9904'. 20:30 21:00 0.50 17,665 17,665 TA OTHER TRIP PKRD Set Leg #2 diverter in junction. Release running tool from diverter. 21:00 00:00 3.00 17,665 17,665 TA OTHER TRIP PKRD POOH to 6400'. 00:00 00:30 0.50 17,665 17,665 TA OTHER RIG PKRD Service Rig 00:30 03:00 2.50 17,665 17,665 TA OTHER TRIP PKRD Con't POOH wI 4" Drill Pipe. 03:00 04:30 1.50 17,665 17,665 TA OTHER TRIP PKRD LID FJD Tool. Clean junk baskets. Recovered 1-stainless steel band in junk baskets. Total of 35 bands left in hole. 04:30 05:00 0.50 17,665 17,665 TA OTHER CLEAN PKRD Clean Rig Floor of Excess Equipment 05:00 06:00 1.00 17,665 17,665 TA OTHER TRIP PKRD P/U 5-3/4" reverse circulating basket assembl{ DE~êITY(PP9) I 8.70.1 !ÈCD! I.DA[AIDAILYCO$T! IÇ~LIIVIEI - FV PVNP GELS] . THP I FC/T,SOL 01'// I1cJlMsl'T Ph/þ \¡ IPf/Mf I CIIÇ¡¡ gs I 6RPMi I I I I I I I I I I I I I 31,0001 I I I I MUD GAS I UNITS I units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: . . 5{ð2 -:ÃS 7 Printed: 4/29/2004 4:06:42 PM . . MA-RA10HC>NC>lL.e.C>MPAN¥ Pª9$2of2 Dái l'Ieølftþl.~tiØl1>R~Po.rt . E;XplQit<ltion - c;a~ WELL NAME KB IGL 124 HR PROGITMD ITVD IDFS DOL IRPH I~ATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 90 90 109B 01-Feb-2004 PERSC>NNELDATA pqa¡¡:))oR'ho' COMPANY NO. HOURS COMPANY SERVICE N(). HQOR.S Nabors Alaska Drilling 12 155.00 R&K Industrial 1 12.00 Marathon 2 24.00 Baker Oil Tools 2 24.00 Epoch Well Services 1 12.00 Weatherford 2 24.00 M-I Drilling Fluids 1 12.00 Alaska Oil Sales 1 1 .00 CASING SUMMARY LAST BOP TEST: 12/1 512003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE (in) lOOn) SHOE TEST(DDCI) MAX SICP MDTft) WOlf!) VVI«ID/I GRADE BlJ";:>I.lu::¡n 7.000 6.184 16.02 1 ,300 (psi) @ 1 1 .40 (ppg) 10,533 5.417 29.00 L-80 8,1 60 3.500 2.992 (psi) @ (ppg) 17,502 9,603 9.30 L-80 10,1 60 Printed: 4/29/2004 4:06:42 PM · d....O;2. - -::<6 7 M~R~[HØNiØll.....i~ØMP~N¥ [)ªilyØÞmpletion~ép()rt Exþloitªtiprti.,Gäs WELL NAME KB IGL 24 HR PROG TMD TVO IDFS IDOL IRPT# DATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 89 89 108B 31-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman I Ratliff Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST ! CUM Wt:LL \'-Vi) , I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CA::iINli I Lt:AI\.Uff Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS 1 MTS 24 HR FORECAST Washinq down, workinq iunk baskets. OPERATION COMMENTS Change and test pipe rams. TIH with clean out assembly, picking up drill pipe off racks. .. SAFE¡)';YSUMMARY MANHRS WORKEO I ~CCIDENT TYPE I LAST SAFETY MTG I~OP PSITEST I LAST STOP CARD AUOIT I~EGULATORYINSP? I LAST RIG INSPECTION 265.00 None 1/30/2004 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Picking up drill pipe, safety awareness around lay down machine. FRQM fQ Ms .FRQ.M fô -=- ~ IJ 06:00 07:30 1.50 17,665 17,665 TA OTHER TRIP PKRD UD dual seal module. Clear rig floor. 07:30 08:30 1.00 17,665 17,665 TA OTHER EQUIP PKRD RID tubing handling equipment, RlU 4" DP handling tools. 08:30 10:00 1.50 17,665 17,665 TA OTHER NUND PKRD Set test plug. Change upper pipe rams from 3-1/2" dual rams to VBR rams. No SS injection line bands present in ram cavity. 10:00 10:30 0.50 17,665 17,665 TA OTHER TEST PKRD Test VBR rams and bonnet seals to 250 I 3500, 5 minutes each test. 10:30 12:00 1.50 17,665 17,665 TA OTHER TRIP PKRD Pull test plug, set and lock down wear bushing. UD BOP test equipment. 12:00 13:30 1.50 17,665 17,665 TA OTHER TRIP PKRD MIU reverse basket BHA with 3 junk baskets. 13:30 15:00 1.50 17,665 17,665 TA OTHER TRIP PKRD RlU laydown machine. 15:00 15:30 0.50 17,665 17,665 TA OTHER RIG PKRD Service rig. 15:30 16:00 0.50 17,665 17,665 TA OTHER SAFETY PKRD Safety meeting. 16:00 04:30 12.50 17,665 17,665 TA OTHER TRIP PKRD TIH to 9617' with BHA, picking 4" drill pipe off racks. 04:30 05:00 0.50 17,665 17,665 TA OTHER CIRC PKRD Pump down reverse globe basket diverter ball @ 8 BPM. Did not see any pressure increase when ball reached basket seat. 05:00 06:00 1.00 17,665 17 ,665 TA OTHER TRIP PKRD Wash I ream in hole working reverse basket and boot baskets, attempting to P/U SS bands left in hole. Depth 9805' at 06:00 hours. DENSlrY(þþg) ·1 8.65 1·»pl r~ê~1 I~" 'n'n""~~i'J-1 I (::\.IMCÇ>sr FV PVNP iGgL$1 I,,..,,·,..,..~QNV -I CllCa ·.ICa¢12(vit%1H2S ¡.:J.MFli~$ ·..I···$~PI'!I I I I I I I I 1 I I I 29,000 I I I I MUD GAS I I..!N!i'S units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNELDÄTA POEf@06:0p: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Nabors Alaska Drilling 12 155.00 M-I Drilling Fluids 1 12.00 Marathon 2 24.00 R&K Industrial 1 12.00 Epoch Well Services 1 12.00 Baker Oil Tools 2 24.00 Printed: 4/29/2004 4:06:41 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation ~ Gas WELL NAME KASILOF SOUTH 1 L 1 COMPANY Weatherford Oilfield Hot Shot Service SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 24.00 Alaska Oil Sales 1 1.00 SERVICE CASING UMMARY LAST CASING TEST: MAX SICP 1,300 (psi) @ 11.40 (ppg) (psi) @ (ppg) 10,533 17,502 5,417 9,603 L-80 L-80 POB @ 06:00: NO. HOURS 1 1.00 12/22/2003 8,160 10,160 Printed: 4/29/2004 4:06:41 PM tJ 2-- 5 MARATI7I(¡)N..(¡)U,=~(¡)Mf>AN¥ Pªily·~(j1J1PJ~tiôô~~Pprt E)Ç.ploitatiQI1. ..<Ç?ª~ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS [DOL IRPT# [DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 88 88 107B 30-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Castleman I Ratliff Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST ! CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 - STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 3.500 (in) (â) 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST LID dual seal module. PIU iunk baskets and 4" drill pipe. OPERATION COMMENTS Attempt to circulate injection lines bands out of hole @ 4193'. TIH with dual seal module on single string of 3-1/2" tubing. Unable to reach liner seal bore. TOOH to P/U junk baskets and drill pipe. .·oBr-E:,·y(ê:.l MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 296.00 None 1/30/2004 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pinch points, forklift safety. ... ~.~........... > ....... . 'Y i«. FROM Te) Hf'{$ Ie) slJ.a 06:00 08:00 2.00 17,665 17,665 TA OTHER TRIP PKRD Finish TIH with muleshoe sub on 3-1/2" tubing to 4193'. 08:00 10:30 2.50 17,665 17,665 TA OTHER CIRC PKRD Circulate around a 100 BBL Hi-Vis polymer sweep @ 30 BPM, attempting to wash stainless steel methanol injection line bands out of hole. Recover 1 band @ shaker, 3 in pollution pan, and fish 1 out of BOP stack. +1- 38 bands still in hole. 10:30 13:00 2.50 17,665 17,665 TA OTHER TRIP PKRD TOOH, LID muleshoe sub. 13:00 13:30 0.50 17,665 17,665 AF OTHER RIG Service rig and tp drive. 13:30 15:00 1.50 17,665 17,665 AF OTHER RIG Slip and cut drill line. 15:00 16:00 1.00 17,665 17,665 TA OTHER WAIT PKRD Wait on orders. 16:00 17:00 1.00 17,665 17,665 TA OTHER TRIP PKRD M/U dual seal module, add 3.10' seal extension to existing seal assembly. 17:00 22:30 5.50 17,665 17,665 TA OTHER TRIP PKRD TlH with dual seal module on single string of 3-1/2" tubing to 9892'. 22:30 00:30 2.00 17 ,665 17,665 TA OTHER TRIP PKRD MIU circulating hose on tubing. Slack off and land dual seal module on lug in FORMation Junction @ 9904'. Attempt unsuccessfully to latch collet on DSM with 5K to 1 OK with multiple attempts. Inadvertanly shear off DSM without confirming latch or depth. Continue in hole, set down with seal assembly @ 9925', 5' into ZXP isolation packer setting sleeve. Circulate and attempt to wash down to top of seal bore @ 9927.5', unable to make any hole. Monitor pump pressure increase when setting down. Assume SS band debris is obstructing entry into seal bore. 00:30 06:00 5.50 17,665 17,665 TA OTHER TRIP PKRD TOOH, drain BOP stack, no stainless steel bands on top of dual seal module. Observe a few marks on seal assembly mule shoe. QENsITY(ppg} 8.65 Ipp I IE9D IMUD DATA [))\lI..Y COST .1 I Ciy.Nt9QST LIME;IE;~ I· 6RPf.:t FV PVfYP GELS I WL./HfHP I FCrr.SOL OIW %$al1d/M~,.1 Rþlp@! Pf/Mf I CIICa [CaCI#(Vi!t6(yj·. .~~S I I I I I I I I I I I I I 29,500 I I I I I . ;( :< 1 Printed: 4/29/2004 4:06:40 PM . MJ,XRJ,XjJfH(¡)N (¡)I L CØMPJ,XN¥ Page2 of2 D>àiIY~(;)mPI~~iøt1/Reþørt EJtP I qJtatiq I) ...Gas WELL NAME KB IGL 124 HR PROG!TMD ITVD IDFS DOL IRPT# I DATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 88 88 107B 30-Jan-2004 MUD GAS I UNITS I units AVG. CONN: i AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNEL DATA POB@Q6:QQ: . COMPANY SERVICE NO: HOURS COMPANY NO. HOURS Nabors Alaska Drilling 12 155.00 Baker Oil Tools 3 36.00 Marathon 2 24.00 Weatherford 3 36.00 Epoch Well Services 1 12.00 Oilfield Hot Shot Service 1 2.00 M-I Drilling Fluids 1 12.00 Alaska Oil Sales 1 1.00 R&K Industrial 1 12.00 Peak Oilfield Service Co. 3 6.00 êÄSING··.SÙIVI·I\IIARY ... / ..... LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 'ÒO!)) SHOË TEST (PPQ) ..MÒift) . TVÖ(ft) ..··GRAôE) £2;// J!VI·.(IO/11}·· 7.000 6.184 16.02 1,300 (psi) @ 11.40 (ppg) 10,533 5,417 29.00 L-80 8,1 60 3.500 2.992 (psi) @ (ppg) 17 ,502 9,603 9.30 L-80 10,160 Printed: 4/29/2004 4:06:40 PM 0;" ." ~57 .. M~~mH€)Ni€)IL·C€)MP~N¥ [)éliIYCQOOpIØ.tiÒh·.RØþØrt Explc)it~tiºn" G~$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# ¡DATE KASILOF SOUTH 1 L 1 30.6 74.00 17,665 10,000 87 87 106B 29-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I <>ADMlRS COST Castleman I Ratliff Nabors 273E DX0309032CAPCMP01 I FIELD NAME RIG PHONE MOCWI NRI I DAIL ~~E':':_C~~T I CUM WELL COST 1 WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING .INEXT 1-- ...-. . Alaska 3.500 (in) (â1 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST TlH, open ended with 3-1/2" tubinQ. OPERATION COMMENTS TOOH with dual tubing strings. UD production packer and dual seal module. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT REGULATORY INSP? I LAST RIG INSPECTION 294.00 None 1/29/2004 12/15/2003 12/17/2003 N 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Communication while TOOH with dual tubing strings. ~~ .. - . < FROM TO Ii~$ $.0$ PHASE .. 06:00 07:00 1.00 17,665 17,665 TA OTHER CIRC PKRD RID reverse circulating lines. Back out hold down pins on wellhead. 07:00 08:30 1.50 17,665 17,665 TA OTHER TRIP PKRD Pull dual tubing hangers. Unset dual seal module with 25K overpull. UD landing joints and hangers. 08:30 19:00 10.50 17,665 17,665 TA OTHER TRIP PKRD TOOH with dual tubing strings to 4425'. Remove SS bands, spool up dual stainless steel methanol injection lines. Recover 281 bands, leaving 61 in hole. 19:00 21:00 2.00 17,665 17,665 TA OTHER CIRC PKRD Circulate around an 80 BBL Hi-Vis sweep @ 5 BPM 250 psi, attempting to circulate out SS bands, no recovery. Pump rate limited while circulating around Model GT packer. 21:00 01:00 4.00 17,665 17,665 TA OTHER TRIP PKRD Finish TOOH to GT packer. 01:00 04:30 3.50 17,665 17,665 TA OTHER TRIP PKRD Drain BOP stack. Pull and UD GT packer and dual seal module. Recover 18 SS bands, riding out of hole on top of packer assembly. Total of 43 bands still in hole. Seal assembll does not appear to have landed in Leg #2 liner hanger seal bore. 04:30 05:00 0.50 17,665 17 ,665 TA OTHER TRIP PKRD RID dual handling equipment, RlU single handling equipment. 05:00 06:00 1.00 I 17,665 17,665 TA 10THER TRIP PKRD TIHwith 3-1/2" mule shoe. LIe"!",,,, IPP9rl I~p I IECel IM(,jDÐ~Îi~I[)Âjl.Y(;Q~T.·.1 li(:;YM¢O§T - 8.65 ,... -- ¡;v iPV"'¡þ Ggt;,S I VVl..lf· "J'Hf' I FC/T:SOL OIW %Sandi~~t lJ:ìþJp~ ·.I·.···..pf(Mf ····1· ......,,(1 I CaÇI2(\\(t%j H2S ·..Li!M~1 i~~i ...I!\~PIW I I I I I I I I I I I I I 29,500 I I I I I ... ··..MUDGAS I UNITS I units ...... AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSQNNEL DATA POB@06:QO: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Nabors Alaska Drilling 12 155.00 M-I Drilling Fluids 1 12.00 Marathon 2 24.00 R&K Industrial 1 12.00 Epoch Well Services 1 12.00 Baker Oil Tools 3 36.00 . ~ Printed: 4/29/2004 4:06:37 PM MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1L 1 PERSONNEL DATA NO. HOURS COMPANY 3 36.00 Oilfield Hot Shot Service 3 5.00 S&R Enterprises SERVICE POB @ 06:00: NO. HOURS 1 1.00 1 1.00 COMPANY Weatherford Pollard Wireline SERVICE CASIN >5·· MMARY LAST CASING TEST: MAXSICP MDft 1,300 (psi) @ 11.40 (ppg) 10,533 (psi) @ (ppg) 17,502 12/22/2003 Printed: 4/29/2004 4:06:37 PM c:?tJ 2 - 7 MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Castleman I Ratliff FIELD NAME KB 24 HR PROG TMD 17,665 AUTH MD TVD 10,000 WBS DATE 28-Jan-2004 SAPIWBS COST I 30.6 RIG NAME & NO. Nabors 273E RIG PHONE MOCWI NRI , CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTY/OTHER LEAKOFF Alaska CURRENT STATUS / MTS Pre are to TOOH with tubin strin s. OPERATION COMMENTS Finish TIH, picking up dual production tubing strings. Shear pins in dual seal module and land seals. Test seals in Leg #1 to 1000 psi. Unable to test seals in leg #2, monitor communication with annulus during testing. SAFETMSUMMARM BOP PSI TEST LAST STOP CARD AUDIT 12/15/2003 12/17/2003 LAST RIG INSPECTION MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 353.00 None 1/27/2003 ACCIDENT DESCRIPTION: 12/11/2003 SAFETY MTG TOPICS: Running dual tubing strings. 06:00 15:30 9.50 17,665 17,665 AF TRIP Finish TIH, picking up dual strings of 3-1/2" production tubing. Attach dual stainless steel methanol injection lines with 2 SS bands per joint. Maintain 2500 psi on injection lines while TlH. Land dual seal module in FORMation junction key @ 9904'. Confirm latch with 20K overpull. 15:30 18:30 3.00 17,665 17,665 AF RCMP TRIP Space out with tubing pup joints. MIU dual tubing hangers and landing joints. Slack off and shear dual seal module with 20K compression. Continue slacking off landing seals in Leg #1 and #2 PBR's, landing tubing hangers in wellhead with 50K. 18:30 21:30 3.00 17,665 17,665 TA RCMP TEST PKRD Run in hold down pins on wellhead. RIU to test seals. Attempt to pressure up on annulus to test Leg #1 and #2 PBR seal assembly's. Discover communication with annulus, monitor flo up Leg #2 tubing string @ 1.5 BPM with charger pump. Close TIW valve on Leg #2. Pressure up on annulus, successfully testing Leg #1 upper PBR seals to 1000 psi. 21:30 00:00 2.50 17,665 17,665 TA RCMP TEST PKRD Discuss options with management. 00:00 03:00 3.00 17,665 17,665 TA RCMP TEST PKRD Break circulation, reverse circulating. Discover tubing hangers leaking. Further tighten wellhead hold down pins, with no change. Pull tubing hangers out of well head, clean and re-Iand hangers approximately 1" lower. 03:00 06:00 3.00 17,665 17,665 TA RCMP CIRC PKRD Reverse circulate up Leg #2 tubing string with a 30 BBL Hi-Vis polymer pill with red dye added at 5 BPM, 350 psi to gain information about depth of communication. Recover dye in returns 70 BBLS early. Dump 125 BBLS of interface with continued dye in returns. Dye is strung out, information obtained is inconclusive. Receive a second weekly BOP test extension until 2/3/2004 from Jim Regg - AOGCC representative. Printed: 4/29/2004 4:06:34 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas Page 2 of 2 AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: WELL NAME KASILOF SOUTH 1L 1 DENSITY(ppg) 8.65 FV PVNP GELS I COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids R&K Industrial 12 155.00 Baker Oil Tools 3 36.00 Weatherford 1 12.00 Pollard Wireline 1 12.00 ABB Vetco Gray 1 12.00 3 36.00 3 36.00 3 36.00 2 18.00 LAST BOP TEST: 12/15/2003 ID 6.184 2.992 CASING SUMMARY LAST CASING TEST: 7.000 3.500 16.02 1,300 (psi) @ 11.40 (ppg) (psi) @ 9.10 (ppg) NEXT BOP TEST: 12/22/2003 10,533 17,502 5,417 9,603 29.00 L-80 9.30 L-80 8,160 10,160 Printed: 4/29/2004 4:06:34 PM M~IR~TH(¡)N(OII.::.GOMR~N¥ Ðâily<CórrJpleti()nRèþól"t Exploitation -Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS DOL IRPT# I DATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 85 85 104B 27-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MO WBS I SAPIWBS COST Castleman ITrubv Nabors 273E DX0309032CAPCMP01 1- FIELD NAME R!G PHONE MOCWI NRI I DA!l Y WEll COST ! CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTY/OTHER I LAST CASING I NEXT """,,"'.. I LEAKOFF Alaska 3.500 (in) @ 17,644 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Runninq dual tubinq strinq Finish running tubing, space out and land hager. OPERATION COMMENTS Run dual tubing strings. sAFETYSUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 308.00 None 12/16/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Running control line . _~C MM~R¥ IFRQNÎ TQ HR~ fRQM i1'9 $liJI:J RBL 06:00 00:00 18.00 17,665 17,665 AF RCMP PLRNRP Run 7,500' of dual tubing string. 00:00 02:00 2.00 17,675 17,665 AF RCMP PLRNRP RU to run 1/4" control line. 02:00 03:00 1.00 17,675 17,665 AF RCMP PLRNRP Install injection mandrels spaced out to be +1- 2,500' from surface. 03:00 04:00 1.00 17,675 17,665 TA RCMP EQUIP Tubing tongs broke while attempting to torque mandrels. Work on tongs. 04:00 05:00 1.00 17,675 17,665 AF RCMP PLRNRP Install and test control lines to 2500 psi. 05:00 06:00 1.00 17,675 17,665 AF RCMP PLRNRP Continue running 3 112" dual tubing while holding 1500 psi on control line. I··ppl Igçl ,I r~'~*,í:jI;'~ì\î'!il Ic~ptØ - P~i'I~ITY(þþgJ 8.60 FV PVlYP ¢Elis ··II:i(ÚT$q.~ 9Nv ·~WPf.íl.~ftf.íllJ <Çl/Cá ,*Îf.íI~J. i :¡$F§RPIIII I I I 1 1 I I 6.801 I I 29,600 I I I I 1 MliJDGAs .. .. ··.1\ .l!JNITS .1 units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: ~e~~9~~E~~ ..... - COMPANY NO;. . HOURS Nabors Alaska Drilling 12 168.00 R&K Industrial 1 3.00 Marathon 3 36.00 Baker Oil Tools 2 36.00 Epoch Well Services 1 12.00 Weatherford 3 36.00 M-I Drilling Fluids 1 12.00 Pollard Wireline 2 5.00 .. CASING SUMMARY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE On) .Iolio) Sl'iOE·TEST(ppq) MAXSICP MD(ft} TVD(fn wr (Ib/ft) GRADE EÎ~Ú)Si). 7.000 6.184 16.02 1,300 (psi) @ 11.40 (ppg) 10,533 5,417 29.00 L-80 8,160 3.500 2.992 (psi) @ 9.10 (ppg) 17,644 9,980 9.30 L-80 10,160 . . Printed: 4/29/2004 4:06:33 PM M~~~j(tH lL.eÐMP~N¥ Däil~ie~r11PI~t¡ø~i~eÞórt ex,plq.itªtipn'-iGª$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1L 1 30.6 74.00 17,665 10,000 84 84 103B 26-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MO WBS SAPIWBS COST Castleman ITrubv Nabors 273E DX0309032CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI ! DAILY WELL COST I CUPv. nr:::L.L ~\JI6 I I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAK OFF Alaska 3.500 (in) @ 17,644 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST RIH with tubina Finish POOH and LD DP. RU and run dual 3 1/2" tubing. OPERATION COMMENTS RU and run 3 1/2" dual tubing string. SÄ.lfBTYSUI\IIMARY ...... MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT REGULATORY INSP? I LAST RIG INSPECTION 307.00 None 12/16/2003 12/15/2003 1211712003 N 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Running dual tbg strings IF~OM TO H~$i FRQM ·'"1'9 >ArS'" ii ... 14:00 16:30 2.50 17,665 17,665 AF RCMP TEST Pull wear ring and set test plug. Install 3 1/2" dual rams in uppe rams. Test door seals to 250 low and 3500 high. Pull and LD test plug. Clear floor. 16:30 19:00 2.50 17,665 17,665 AF RCMP EQUIP RU dual tubing running tools, finish driftimg tubing. 19:00 23:30 4.50 17,665 17,665 AF RCMP PLRNRP PJSM. PU and run dual seal module, 5 jts tubing and dual GT packer. 23:30 06:00 6.50 17,665 17,665 AF RCMP PLRNRP Continue running dual strings of 3 1/2", 9.3 ppf, L-80, Hydril 533 tubing making up connection to 3000 ft-Ibs. Depth at report timE 1100' ·.,H''''' .!t!K~# 8.60 Ip~1 l"cI> I 110)¡ J)~ COST 1 ~ri\!j!t\!t F\l ·PVNP GEÞ§I·Y~9nl<1r 1·9.~iii%$~ri·... ..·.1· ···p(irJjf·.l· .bl(C~ ",,,..' iltjKIJOO I I I I I I I 8.60/1/1 29,500 I 1 .MI.II'lI~1ì!~ J :P~!"1'§ units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: RERSONNELÐA.mA. ~ COMPANY SERVICE NO, HOURS COMPANY Nabors Alaska Drilling 12 168.00 R&K Industrial 1 10.00 Marathon 3 36.00 Baker Oil Tools 3 36.00 Epoch Well Services 1 12.00 Weatherford 2 24.00 M-I Drilling Fluids 1 12.00 Halliburton 1 4.00 Peak Oilfield Service Co. 1 5.00 CASINGSUMMA.RY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE (in) ID(jn) St-IO!STE"ST(Dba1 MAXSICP MO(ft) TVDXft) WT (!bItt) GRADE BURST· (bsit 7.000 6.184 16.02 1,300 (psi) @ 11 .40 (ppg) 10,533 5,417 29.00 L-80 8,160 3.500 2.992 (psi) @ 9.10 (ppg) 17,644 9,980 9.30 L-80 10,160 Printed: 4/29/2004 4:06:30 PM . . ~:i)~~S::. Î, Kasilof South 1 Lateral 1 Completion Report (Reports 1 - 15) . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Tom Kloberdanz FIELD NAME KB 24 HR PROG TMO TVD 30.6 RIG NAME & NO. AUTH MD WBS DATE 05-Mar-2004 SAPIWBS COST , "'0 DX0309032.CAP .CMP .02 RIG PHONE MQCWI NRI I DAILY WELL COST ,CUM WELL COST WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS S ottin Halliburton Well Test E ui ment and Rental Tanks OPERATION COMMENTS ASRC picked up liner and berm left over from drilling operations. Spotted Halliburton Well Test Equipment. SlXFETYSUMMlXRY ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST LAST STOP CARO AUDIT REGULATORY INSP? COUNTY/OTHER 100.0000 LEAKOFF ui ment and berm liner MANHRS WORKED LAST RIG INSPECTION 38.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Slips, trips, and falls N 08:00 AF SITLOC LOC Location Clean up: ASRC cleaned up location from drilling operations. PU old liner and berm and leveled ground with loader. Spotted Halliburton Well Test separator, lab, and pipe racks. Delivered 500 bbl Rain-for-Rent tank, MOC flowback tank, gas buster, methanol test skid, methanol tank, chicksan, choke manifold, and cement barrels. Artie Slope Regional Cor Halliburton CASING UMMARY LAST CASING TEST: NEXT BOP TEST: (psi) @ (ppg) Printed: 4/29/2004 4:07:43 PM WILDCAT-FOR UNNAMED FIELD STATE/PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Ri in U Halliburton Flow Test E ui ment. OPERATION COMMENTS Rigging up Halliburton Flow Test Equipment. WELL NAME KASILOF SOUTH 1L 1 SUPERVISOR Tom Kloberdanz FIELD NAME MANHRS WORKEO ACCIDENT TYPE LAST SAFETY MTG 26.00 None ACCIOENT OESCRIPTION: SAFETY MTG TOPICS: Artie Slope Regional Cor PU Liner and berm Halliburton Well Testers LAST BOP TEST: 3.500 .' . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas KB RPT# DATE 2 06-Mar-2004 SAPIWBS COST 24 HR PROG TMD TVD 30.6 RIG NAME & NO. AUTH MD RIG PHONE MOCWI 100.0000 NRI I CUM WeLL I.U::; I LAST STOP CARD AUDIT REGULATORY INSP? N LAST RIG INSPECTION LAST CASING TEST: NEXT BOP TEST: (psi) @ (ppg) Printed: 4/29/2004 4:07:44 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Ken Walsh FIELD NAME KB 24 HR PROG TMD TVD 30.6 RIG NAME & NO. AUTH MD WILDCAT-FOR UNNAMED FIELD STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Ri in u Halliburton Well Test E ui ment. OPERATION COMMENTS Rigging up Halliburton Well Test equipment and lines. Laying liner and berm. SAFETY SUMMARY BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? MOCWI 100.0000 WBS DX0309032.CAP.CMP.02 DAILY WELL COST I CUM YYr:L~_':.U~~ NRI RIG PHONE Set as buster MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 37.50 None ACCIOENT DESCRIPTION: N LAST RIG INSPECTION SAFETY MTG TOPICS: AF MIRU Layed and made up Halliburton 3" test lines to vent stack and to wellhead. MU Halliburton 3-1/8"5K x 3" 1502 flanges downstream of SSV on both sides of the dual tree. Layed and made up one 3" test line to tee into both wings of the tree and one 3" fluid line to Rain-for-Rent tank. ASRC continued to lay liner and berm around test lines and other equipment. Spotted Veco office skid. Airport Rental delivered 65 KW generator, air compressor with 2 sections of 50' hose, 45-25 Manlift, two light plants, and Chinook heater. Carlisle trucking delivered vent stack. Veco vac truck delivered 16 bbls. 50/50 glycol water and filled separator bath. Veco delivered 45 ton crane. Artie Slope Regional Cor PU Liner and berm Halliburton Well Testers Supervision Vac Truck for Glycol (psi) @ (ppg) Printed: 4/29/2004 4:07:47 PM . . MARATHON OIL CO WELL NAME TVD KASILOF SOUTH 1L 1 SUPERVISOR RIG NAME & NO. AUTH MD WBS Ken Walsh FIELD NAME RIG PHONE MOCWI NRI RPT# OATE 4 10-Mar-2004 SAPIWBS COST WILDCAT-FOR UNNAMED FIELD 100.0000 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Finish ri in u testers. Pull BPV's. Set as buster. OPERATION COMMENTS Continued rigging up Halliburton Test equipment and preparations for non-rig completion work. LEAKUrr MANHRS WORKEO 61.00 ACCIDENT TYPE LAST SAFETY MTG None ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: Slipping on ice and liner. FROM HRS 08:00 12:00 4.00 . TIONS SUMMARY OP TRBL TEST FROM AF MIRU 12:00 17:00 5.00 AF MIRU TEST ! cur;, .....~... ,-,v':' I REGULATORY INSP? N LAST RIG INSPECTION Finished rigging up Halliburton test lines. Udelhoven delivered "bang box" electrical panel from Ninilchik warehouse. Udelhoven wired Halliburton lab and separator, MOC water well, and Veco office to panel to diesel generator. ASRC welded satellite stand to Halliburton lab. ASRC continued to berm liner. Set gas buster on flowback tank-chained and boomered down buster to tank. R&K delivered methanol tank. Set methanol tank in bermed area and Veco vac truck filled with about 30 bbls. methanol water. Cook Inlet Safety delivered H2S/LEL sensoring equipment. Vetco pulled BPV from tubing hanger. Closed and locked master valves. Two Veco roustabouts cleaned out ice from water well house and began rigging up chicksan from wellhead to choke skid and then to gas buster and flowback tank. Alaska Oil Sales delivered 990 gals diesel t ASRC rental storage tank. Rigged up Cook Inlet Safety sensors and lines to control building. Veco roustabouts pulled out water well power supply line from snow berm to use as power cable to generator. ASRC cleaned up 5 gal. spill of glycol from portable toilet and sent with MOC to KGF for handling. Airport Rentals replaced faulty Chinook diesel-fired heater. COMPANY Artie Slope Regional Cor Halliburton Marathon SERVICE Roustabouts LEL Monitoring Equipme Electrician SERVICE PU Liner and berm Well Testers Supervision 3 4 1 18.00 18.00 4.50 Veco Alaska Cook Inlet Safety Udelhoven Oilfield Syste 2 2 1 10.00 6.00 4.50 CASING SUMMARY LAST CASING TEST: MAX SICP MD ft (psi) @ (ppg) 17,644 Printed: 4/29/2004 4:07:51 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1L1 SUPERVISOR Ken Walsh FIELD NAME KB 30.6 RIG NAME & NO. RIG PHONE WILDCAT-FOR UNNAMED FIELD STAT~PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Erect vent stack, electrical tie-in, load tank w/water. OPERATION COMMENTS Finished rigging up well test equipment and lines. 24 HR PROG TMD TVD RPT# DATE 5 11-Mar-2004 AUTH MD WBS SAPIWBS COST DX0309032.CAP.CMP.02 I MOC WI NRI I nAIL Y WELL COST I CUM WELL COST I MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 50.50 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Electrical Hazards. LAST RIG INSPECTION 3/10/2004 REGULATORY INSP? N 08:00 13:00 5.00 AF MIRU TEST 13:00 16:00 3.00 AF MIRU TEST Veco routabouts finished digging out electrical supply wires (left over from drilling) to use as tie-in power from the electric generator to the water well. S&R replaced damaged portable toilet. Udelhoven electrician made final tie-in for water well power. Carlisle Trucking PU trailer after Veco crane operator removed and set Flare Stack Inc. base and 30" x 40' vent stack. Weaver Bros. delivered 650 gals methanol to methanol tank. Veco vac truck delivered 80 bbls. of fresh water. Offtoaded 15 bbls. of fresh water into methanol water tank and placed the remaining water in the clean fluid tank. Vacuumed out the standing water in the water well house. Repositioned choke manifold and methanol skid to accomodate coil tubing operations. MU vent stack to base. MU flange swedge and Halliburton Well test lines to vent stack while waiting on replacement man lift from Airport Rentals (manlift fuel supply problems). Disconnected lifting cables from vent stack with manlift. Set cement barrels and tied down vent stack guy wires to barrels. Shoveled snow from liner and layed down plywood. COMPANY Artie Slope Regional Cor Halliburton Marathon Veco Alaska SERVIOE PU Liner and berm Well. Testers Supervision Roustabouts 2 4 1 2 10.00 18.00 4.50 10.00 Cook Inlet Safety Udelhoven Oilfield Syste Veco Alaska LEL Monitoring Equipme Electrician Vac Truck 3.00 3.00 2.00 Printed: 4/2912004 4:07:52 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1L 1 SUPERVISOR Ken Walsh I Crai Meese FIELD NAME KB 24 HR PROG TMD 30.6 RIG NAME & NO. AUTH MD TVD RPT# DATE 6 13-Mar-2004 WBS SAPIWBS COST DX0309032.CAP .CMP .02 NRI I DAiLY WELL COST CUM WeLL <.;U:; I RIG PHONE MOCWI WILDCAT-FOR UNNAMED FIELD STATE/PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Pre are to PU BHA and test CIT BOP's. OPERATION COMMENTS RU CIT stack in preparation for well bore cleanout operation. LE:.I'\n..vrr MANHRS WORKED ACCIOENT TYPE LAST SAFETY MTG 16.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: REGULATORY INSP? N 04:00 05:00 1.00 AF WBCO CLTBG Install 3-1/8" 5K x 3-1/6" 10K flange to top of tree. Move CIT stack from Kasilof State #1rd (motherbore) to Kasilof State #1 L 1 (lateral). MU 3-1/8" 5K x 3-1/16" 10K flange to top of tree. MU 3-1/16" 1 OK flange connection below flow cross of CIT stack. 05:00 06:00 1.00 AF WBCO CL TBG Attempting to break lubricator and layout motor assembly. BJ Services Halliburton Marathon Veco Alaska Coil Tubing Well Testers Supervision Crane Operator 4 1 1 1 8.00 Veco Alaska 2.00 Weatherford 2.00 Veco Alaska 2.00 Vac Truck CT BHA Vac Truck LAST BOP TEST: NEXT BOP TEST: 3.500 Printed: 4/29/2004 4:07:53 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas 30.6 24 HR PROG TMD TVD RPT# 7 DATE 14-Mar-2004 SAPIWBS COST ) WELL NAME KASILOF SOUTH 1L 1 SUPERVISOR Ken Walsh I Crai Meese FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS 1 MTS Tem oraril sus end 0 erations Kasilof State #1 L 1. OPERATION COMMENTS LD motor, mill, and hyd. disconnect from KS #1rd cleanout. PU and RIH with mill, motor, jars on coil tubing to 17,520' CTM. Circulate 2X BU. POOH CÎrc 1.4 BPM. Temp suspend Ops Kasilof State #1 L 1. KB RIG NAME & NO. AUTH MD RIG PHONE MOCWI 100.0000 WBS DX0309032.CAP .CMP .02 I DAILY WELL COST I CUM WI:L.L. COST NRI COUNTY/OTHER MANHRS WORKED 230.00 LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? LAST RIG INSPECTION 3/10/2004 N SAFETY MTG TOPICS: 06:00 07:00 1.00 AF WBCO CL TBG Broke lubricator and layout motor assembly. Motor was severely pitted on entire OD surface and had very fine metallic particles magnetically attached to it. Motor was bent and mill missing 1/3 of two outside carbide buttons on the face. Layed down motor, mill, and hydraulic disconnect. Installed new rupture disc in rupture sub. 07:00 07:30 0.50 AF WBCO SAFETY Held PJSM. Veco vac truck on location with a load of fresh water. Mixed BJ Services FRW-14 at 1 gpt into fresh water and offloaded into clean fluid tank. 07:30 08:30 1.00 AF WBCO CL TBG PJSM. Test lines 250/5500. Test pipe rams 250/4500. Test aux rams 250/4500. Test blind rams and flow back iron 250/4500. 08:30 10:00 1.50 AF WBCO CL TBG Break lubricator. MU Weatherford BHA as follows: 2.20" OD 1-1/2" Coil Connector, 2.20" OD Dual Check Valve, 2.25" OD Dual Acting Jar, 2.25" OD Hydraulic Disconnect (5/8" Ball Drop), 2.25" OD Rupture Sub (5K Rupture Disk), 2.15" OD X-Over (1/14" Reg x 1-1/2" MT), 2.125" OD PDM, 2.805" OD 5 Bladed Junk Mill. MU lubricator. Shell test BOP stack 250/4500 psLs: 10:00 10:30 0.50 AF WBCO CL TBG Displaced methanol water from CT with 34 bbls. fresh water. Confirm motor operating. 10:30 20:00 9.50 AF WBCO CL TBG RIH breaking circ every 15 min: 3100' wt check 5000 Ibs 6100' wt check 8900 Ibs 9000' wt check 11000lbs 9800' wt check 12200 Ibs PUH and started pumping fresh water at 1 BPM. RIH and drille about l' cement stringer at 9994'. Continued RIH making weigh checks: 10360' wt check 12000 Ibs 10600' wt check 12000 Ibs Printed: 4/29/2004 4:07:54 PM . MARATHON . COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1L 1 DATE 14-Mar-2004 FROM TO HRS FROM TO SUB 10:30 20:00 9.50 AF OPERATIONS SUMMARY PHASE OP TRBL WBCO CL TBG DESCR!PTION 20:00 23:00 3.00 AF WBCO CL TBG 23:00 03:30 4.50 AF WBCO CLTBG 03:30 04:00 0.50 AF WBCO CLTBG 04:00 04:30 0.50 AF WBCO CLTBG 11000' wt check 12500 Ibs 11600' wt check 15400 Ibs (PU wt. abnormally high due to increase in packoff pressure applied to control slight fluid leak from CT packoff) 12000' wt check 15500 Ibs 12500' wt check 17000 Ibs 13000' wt check 17500 Ibs 13500' wt check 18000 Ibs 14086' wt check 18500 Ibs - Tagged slight restriction-Passed easily-no motor action noted. 14530'wtcheck 19000lbs 15100' wt check 20500 Ibs 15500' wt check 21000 Ibs 16000' wt check 23000 Ibs 16500' wt check 25000 Ibs 16700' wt check 25500 Ibs 17000' wt check 26500 Ibs 17300' wt check 28000 Ibs - Tagged slight obstruction-Passed easily 17520' wt check 29000 Ibs - PU to 17450' and RBIH to 17520' Circ 2X BU (230 bbls) @ 17520'. Move CT uphole 75' every 75 bbls pumped. POOH with CIT while circulating 1.4 BPM. Displace CIT with methanol water. Blow lines dry across tree. Break 3-1/16" 10K nange connection below nOW cross. PU stack. Move back to motherbore side of dual tree (Kasilof State #1rd). Temporarily suspend operations on Kasilof State #1 L 1. BJ Services Coil Tubing Vac Truck Halliburton Well Testers CT BHA 2 Marathon Supervision Vac Truck 2 Veco Alaska Crane Operator Vac Truck 1 Printed: 4/29/2004 4:07:54 PM . . WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Ken Walsh I Crai Meese FIELD NAME KB TVD DATE 15-Mar-2004 SAPIWBS COST RIG NAME & NO. AUTH MO RIG PHONE MOC WI NRI 100.0000 CUM WELL COST WILDCAT-FOR UNNAMED FIELD STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Pre to RIH with venturi 'unk basket on CT OPERATION COMMENTS RUlTest CIT BOP. PU venturi junk basket and begin RIH. LEAKOFF MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 36.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pressure testing operations, slick location REGULATORY INSP? N LAST RIG INSPECTION 02:30 02:45 0.25 WBCO CLTBG Install 3-1/8" 5K x 3-1/16" 10K flange to top of tree. Move C/T stack from Kasilof State #1rd (Motherbore) back to Kasilof State #1 L 1 (Lateral). MU 3-1/16" 10K flange connection below flow cross of C/T stack. 02:45 03:00 0.25 WBCO SAFETY PJSM. 03:00 04:00 1.00 WBCO CLTBG Tested pipe, auxilary, and blind rams 250/4500 psi with methanol water. 04:00 04:30 0.50 WBCO CLTBG Broke lubricator and PU Weatherford venturi junk basket with 8' extension and 2.850" shoe, hydraulic disconnect, dual acting jars, dual checks, and 1-1/2" coil connector. MU lubricator. 04:30 05:00 0.50 WBCO CLTBG Shell test BOP and lubricator to 1000 psi with methanol water. 05:00 05:30 0.50 WBCO CLTBG Displace methanol water from C/T with fresh water. 05:30 06:00 0.50 WBCO CLTBG Open well and begin RIH with venturi BHA on C/T. BJ Services Coil Tubing 4 12.00 Veco Alaska Vac Truck 6.00 Halliburton Well Testers 1 3.00 Weatherford CT BHA 2 6.00 Marathon Supervision 1 3.00 R&K Industrial Vac Truck 1 3.00 Veco Alaska Crane Operator 1 3.00 Peak Oilfield Service Co. Vac Truck Printed: 4/29/2004 4:07:58 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1L 1 SUPERVISOR Ken Walsh I Crai Meese FIELD NAME KB 24 HR PROG TMD TVD DATE 16-Mar -2004 30.6 RIG NAME & NO. AUTH MO RIG PHONE MOCWI 100.0000 WBS DX0309032.CAP .CMP.02 I DAILY WELL COST I CUM WELL COST "''''''/WRS COST NRI WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS POOH with CIT OPERATION COMMENTS PU and RIH with Venturi junk basket on C/T and cleanout well bore to 17,512'. Spot 6% KCL on bottom. extension and shoe in hole. MU cement mill BHA. RIH and push fish to 17.478'. POOH with CT. COUNTY/OTHER POOH with CT. Left Junk basket MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 264.00 None ACCIDENT DESCRIPTION; SAFETY MTG TOPICS: Fall protection, Good Housekeeping, Communication SAFETYSt1.l·M.MARY BOP PSI TEST LAST STOP CARD AUOIT REGULATORY INSP? 3/15/2004 N LAST RIG INSPECTION 06:00 08:00 2.00 AF WBCO CL TBG RIH with venturi BHA on CIT at 75 FPM to liner top making following wt checks and pumping fresh water at 1 BPM: 2500'wtcheck-3500# 7100'wtcheck-8100# 9800'wtcheck-11000# 08:00 08:30 0.50 AF WBCO SAFETY Held Prejob Safety Meeting. Reviewed work permit, hazards, and operational plan. 08:30 12:30 4.00 AF WBCO CL TBG RIH with venturi BHA on CIT at 40 FPM to liner top making following wt checks and pumping fresh water at 1 BPM: 11100' wt check- 12000# 11600' wt check- 12500# 12000'wtcheck-13000# 12500' wt check- 14000# 13000'wtcheck-14500# Increased circulation rate from 1.2 BPM to 1.35 BPM 13600' wt check- 15000# 16550' wt check- 21000# 14000' wt check- 16000# 17000'wtcheck-22000# 14600'wtcheck-16500# 17250' wt check- 22500# 15100' wt check- 17500# 17500'wtcheck-23500# 15600' wt check- 18500# 17512' Tag TD - PU at 24000# 16000' wt check- 19500# 12:30 13:00 0.50 AF WBCO CL TBG PUH to 17456' and then RIH to 17508' MD. Pumped 30 bbls. of 6% KCL water and displaced to the end of the coil tubing with 3 bbls. of filtered fresh water. KCL water placed from 17,508' to 14031' MD. 13:00 16:30 3.50 AF WBCO CL TBG Shut down pumps. POOH with venturi junk basket, jars, MHA, and coil tubing maintaining a pulling rate of 50 FPM to the liner top and 110 FPM to surface. 16:30 17:00 0.50 AF WBCO CL TBG Displaced coil tubing with methanol water. Printed: 4/29/2004 4:08:01 PM M7\~"FH(;)N ¡(IV I..··.~''''...·. Dâily ··CQmpl~tiør)R.êpQ.n: Explditª.ti9n-i(Pª$ WELL NAME IKB [GL 24 HR PROGITMO TVO IDFSO jDOL9 tPT#9 ¡OATE KASILOF SOUTH 1L 1 30.6 74.00 16-Mar-2004 .RÄ17IØNSSUM~~RY .. FROM TO HRS FROM irO SUB 'OP .. TRBL -~-.'-'''' .~.. 17:00 18:00 1.00 AF WBCO CL TBG Break lubricator and LD venturi junk basket and jar assembly. FISH: LEFT 9.57': VENTURI JUNK BASKET EXTENSION (2.625" OD WITH SCREEN sticking up above box -2") WITH 2.85" OD SHOE IN HOLE. CS HYDRIL CONNECTION THREADS ON BOTTOM ARE NOT DAMAGED-APPEARS TO HAVE BACKED OFF. 18:00 19:00 1.00 AF WBCO CLTBG Consult office: Will make bit run to push fish to bottom and leav~ in rathole. Pull test CIT to 20,000 lb. PT CIT to 3500 psi. MU Weatherford BHA as follows: 2.75" OD cement mill, 2" OD X-O (1-1/2" MT bxb), 2.25" OD Hydraulic disconnect, 2.25" OD X-O (1-1/4" Reg x 1-112" MT bxp), 2.25" OD Dual acting jar, 2.20" OD Dual check valve, 2.20 OD Coil connector. 19:00 20:00 1.00 AF WBCO CL TBG PJSM and review operations plan. MU lubricator. Shell test BOP and lubricator to 1000 psi with methanol water. 20:00 20:30 0.50 AF WBCO CL TBG Displace methanol water from CIT with fresh water. 20:30 03:30 7.00 AF WBCO CL TBG Open well and RIH with CIT. Pump 1 BPM from 2500' to 14000', then SD pumps. 5300' wt check- 5000# 13950' wt check- 13500# 9257' wt check- 9500# 14150' Possible tag (800# wt loss) 10450' wt check- 10200# 14450' wt check- 15500# 10950' wt check- 10400# 14950' wt check- 15300# 11450' wt check- 11000# 15450' wt check-16000# 11950'wtcheck-11500# 15950'wtcheck-18000# 12450' wt check- 12200# 16500'wtcheck-18500# 12950' wt check- 13000# 16950' wt check- 19200# 13450' wt check- 12250# 17250' wt check- 20200# 17478' Tag and set 6K down. Could not push fish further DH (Note: Bottom perf will be 17,410'). 17478' wt check 21000 #. 03:30 06:00 2.50 AF WBCO CL TBG POOH with CT (CT @ 9000' at report time). PERSONNELDA17A ~~¿R$ COMPANY SERVICE NO. HOURS COMPANY SERVICE BJ Services Coil Tubing 8 96.00 R&K Industrial Vac Truck 2 24.00 Halliburton Well Testers 2 24.00 Phone hookup 3 15.00 Marathon Supervision 2 24.00 I.I.S.C.O. SCADA Hookup 1 5.00 Veco Alaska Crane Operator 2 24.00 Udelhoven Oilfield Syste Electrician 1 4.00 Weatherford CT BHA 2 48.00 CASING>5UMMÄRY LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE (in) I ID(ii)) .ISf-IOET¡;:ST(PPQ) MAXSICP I MP (ft) I TVD (ft) I WT(lb/1't) t GRADE I BURST (psi! 3.500 I 2.992 I (psi)@ (ppg) I 17,644 I 9,980 I I I . . Printed: 4/29/2004 4:08:01 PM . . WELL NAME KB TVD RPT# OATE KASILOF SOUTH 1 L 1 30.6 10 17-Mar-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Ken Walsh I Don E non DX0309032.CAP .CMP .02 FIELO NAME RIG PHONE MOCWI NRI DAILY WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 100.0000 STATElPROV COUNTY/OTHER LEAKOFF Alaska CURRENT STATUS 1 MTS POOH and stand back BJ CT e ui ment. OPERATION COMMENTS POOH wlCT and junk mill. Moved to KS #1rd to run Reeves cased hole memory logs. Temporarily suspend operations. RU Reeves and run GRlCCL/Neutron/Density/CaliperlSonic CBL log, tag at 17,422'. SAFETY" MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST REGULATORY INSP? LAST RIG INSPECTION 105.00 None N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Concurrent well operations, hazards, focus. 06:00 07:00 1.00 AF WBCO CL TBG POOH with CT. 07:00 07:30 0.50 AF WBCO SAFETY Held Prejob Safety Meeting. Reviewed work permit, hazards, and operational plan. 07:30 08:00 0.50 AF WBCO CLTBG Displaced water from CT with 50/50 methanol water. 08:00 10:00 2.00 AF WBCO CLTBG Broke lubricator and LD Weatherford 2.75" OD cement mill, X-O, 2.25" OD Hydraulic disconnect, X-O, 2.25" 00 Dual acting jar, 2.20" OD Dual check valve, and 2.20" OD Coil connector. No new marks on any of the equipment. LD speed lubricator and injector head (installed .109" wall dimple on connector to CT). 10:00 11:30 1.50 AF WBCO CL TBG ND CT BOP and riser spool from top of swab valve flange. 11 :30 12:00 0.50 AF WBCO CL TBG Cleanup and stow tools. Secure equipment. Temporarily suspend operations. Move to KS #1 rd to run cased hole logs. 12:00 00:00 12.00 AF WBCO WAIT Temporarily suspend operations while running cased hole logs on KS # 1rd. 00:00 01:00 1.00 AF WBCO LOG RU cresent shaped 5m flange to dual tree with pollard rental pump in tee. PU first part of tool string and begin in hole. Ice in flowline restricts running in hole. Lay down tools while rigging up vac truck and heater to lines and tree. 01:00 02:00 1.00 AF WBCO LOG MU tool string consisiting of 2.25" OD Reeves cased hole memory logging tools: (GRlCCL/NeutronlDensity/Caliper/Sonic). MU battery pack at 1 :56:00, PU to install nuclear sources, nuclear device fails to sense battery power. 02:00 03:00 1.00 AF WBCO LOG Battery checks out good, change out memory section. MU battery pack at 02:16:30, PU to nuclear density tools, activation OK, Install nuclear sources and Well Tee's 2-1/8" OD wireline tractor with Veco crane. Overall length of logging tools is 71.63'. Overall length of tractor is 20.33'. With top of wireline tool string at pump in sub set wireline counter to 88.63' to reflect KB measurement (added 17 feet to tool string as pump in sub is Printed: 4/29/2004 4:08:02 PM WELL NAME KASILOF SOUTH 1 L 1 . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas FROM TO HRS FROM 02:00 03:00 1.00 03:00 06:00 3.00 Reeves Wireline BJ Services Halliburton Marathon Veco Alaska LAST BOP TEST: SIZE in 3.500 SERVICE Cased hole logging Coil Tubing Well Testers Supervision Crane Operator OPERATIONS SUMMARY SUB ÞHASE OP TRBL PI::SCRIPTION AF WBCO LOG 13.5' above ground-17 feet below KB height). AF WBCO LOG RIH with 2.25" OD Reeves cased hole memory logging tools: (GRlCCL/NeutronlDensity/CaliperISonic) and WellTec's 2-1/8" OD wireline tractor. Loose tension on cable at 17,472', on PU reached full line tension of 4800 Ibs at 17,422'. (psi) @ (ppg) 2 12.00 Weatherford CT BHA 2 3.00 4 24.00 R&K Industrial Vac Truck 2 16.00 1 12.00 I.I.S.C.O. SCADA Hookup 1 5.00 1 12.00 Udelhoven Oilfield Syste Electrician 1 4.00 1 12.00 Veco Alaska Vac truck operator 1 5.00 LAST CASING TEST: NEXT BOP TEST: Printed: 4/29/2004 4:08:02 PM .... M~~~m¡.. O.Nic¡)·.I.·I.1;·.·ØC¡)M·PAN¥ [:)éliIY'Ø)ømp!~~iøn\Rêp()rt liEx.p 1()¡~ªtl·9j)·..-Gá$ WELL NAME KB [GL 24 HR PROG TMD TVD IDFSO IDOL IRPT# I DATE KASILOF SOUTH 1 L 1 30.6 74.00 11 11 18-Mar-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I !:APIWBS COST Ken Walsh I Don Eynon DX0309032.CAP .CMP .02 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM \\fELL COST i WILDCAT-FOR UNNAMED FIELD 100.0000 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOH Alaska 3.500 (in) (a1 17,644 (ft) (in) (a1 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Loq/POOH w/Reeves cased hole loqs. Jet well dry and trap N2 Jet KS #1 rd dry with CT and trap N2 pressure. OPERATION COMMENTS Logged memory CBUSonic/Density/Neutron from PBTD of 17,422 to 12,500' MD. POOH and downloaded data. RIH with BJ CT. Jetted well dry to 17,429' KB. POOH with CT. Trapped 1700 psi nitrogen pressure. Suspend operations. Move to KS #1rd. ::>A....t::yXQI "c. " MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 190.50 None 3/15/2004 ACCIDENT OESCRIPTION: SAFETY MTG TOPICS: PPEIConcurrent opsloverhead work/trip&fall hazards. .,,<¡; IF~ºM r9 HRS TÒ. .*.\.í~ i 06:00 09:00 3.00 AF WBCO LOG PUH logging to 12,500' MD. 09:00 10:00 1.00 AF WBCO LOG POOH and lay down tractor. BJ CoilTech on location to RU for CT jetting operations. 10:00 12:30 2.50 AF WBCO LOG Lay down and isolate nuclear sources. Download data from memory logging tools. Begin depth-time correlation of memory logs. RD Reeves. RU BJ Coiltec wellhead flange, riser, and CT BOP. Vehicle accident: Welltec supervisor moving Reeves pickup slid on short icy incline into light plant outrigger. Driver moving at low rate of speed. Pickup dented on underside of passenger's side behind door. No injuries. Driver was using Reeves employee as spotter but spotter on wrong end of pickup to identify hazard potential. No damage to light plant. 12:30 13:00 0.50 AF WBCO SAFETY Prejob Safety Meeting for coil tubing operations. 13:00 14:00 1.00 AF WBCO CLTBG PU injector head and move to wellhead. MU 1-3/4" OD wash nozzle, 4' long straight bar, and double checks to 1-1/2" OD coil tubing connector. Pull test CT connector. Function test BOP's. MU injector head to CT BOP. 14:00 16:00 2.00 AF WBCO CL TBG RU nitrogen transport to nitrogen pumping unit. Attempted BOP test but leaking below BJ flange to swab valve. Changed out ring gasket. 16:00 17:00 1.00 AF WBCO CLTBG Pressure tested CT BOP and lines to 300/4500 psi. 17:00 18:30 1.50 AF WBCO CL TBG Cooled down nitrogen unit. Displaced methanol water with nitrogen. 18:30 21:30 3.00 AF WBCO CL TBG RIH with CT while pumping nitrogen at min rate to balance hydrostatic pressure of fluid in wellbore. Weight checks: @ 11500' PU 7000 Ibs SO 2000 Ibs. @ 14000' PU 9000 Ibs SO 3000 Ibs. 21 :30 23:00 1.50 AF WBCO CL TBG Increase nitrogen rate to 1500 scfpm. Jet well recovering 111 bbls of fluid. Check weights at 14000' after jetting, with PU . . Printed: 4/29/2004 4:08:03 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 OPERATIONS 5 PHASE OP TR WBCO CL TBG FROM 21 :30 23:00 1.50 TO SUB AF 23:00 01 :00 2.00 AF WBCO CL TBG 01 :00 02:00 1.00 AF WBCO CL TBG 02:00 06:00 4.00 AF WBCO CL TBG BJ Services Halliburton Marathon Veco Alaska R&K Industrial Coil Tubing Well Testers Supervision Crane Operator Vac Truck 4 76.00 I.I.S.C.O. 3 36.00 Veco Alaska 2 24.00 Reeves Wireline 2 24.00 WellTec 11.00 13.00 6.50 DATE 18-Mar-2004 10500, SO 3000. CT pressure gradually increased at end of jetting to 3800 psi and leveled off. Put nitrogen pump into recirc and shut in CT annulus. RIH to jet dry remainder of well. Check weight while RIH, @ 15000' PU 12000 Ibs SO 3000 Ibs. @ 16000' PU 13500 Ibs SO 3000 Ibs. @ 17000' PU 14750 Ibs SO 4000 Ibs. Tag bottom at 17429' KB with 3500 Ibs @ 17429' PU 15000 Ibs SO 4000 Ibs. PU to 17410 to jet well. Begin pumping N2 at 1500 scfpm. Increased rate to 2000 scfm at 01 :30. 141 bbls recovered. Returns minimal .25 bpm. Begin POOH to sweep water out of hole. PU weight 18000 Ibs. At 02:30 148 bbls recovered. 02:45 returns dry for 15 minutes. 03:05 returns still dry, 148 bbls recovered out of possible 151. Turn nitrogen pump to recirc and continue to POOH. Pump down kill line to increase wellhead pressure to 1700 psi. Out of the hole with CT at 0600 hrs SCADA Hookup Vac truck operator Cased hole logging Wireline tractor 1 2 1 LAST BOP TEST: Printed: 4/29/2004 4:08:03 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas 30.6 RIG NAME & NO. AUTH MD WBS DX0309032.CAP .CMP .02 DATE 19-Mar-2004 SAPIWBS COST WELL NAME KASILOF SOUTH 1L 1 SUPERVISOR Ken Walsh I Don E non FIELD NAME KB 24 HR PROG TMO TVD RIG PHONE MOCWI NRi I DAILY WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 100.0000 STATE/PROV COUNTY/OTHER LEAKOFF Alaska CURRENT STATUS / MTS Jet KS #1 L 1 d with CT and tra N2 ressure. N2 ressure. OPERATION COMMENTS Finished POOH with jetting BHA. Trapped 1700 psi N2 WHP for underbalance perforating. Suspend operations pending completion of KS #1rd perforating and testing. MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 16.00 None ACCIOENT DESCRIPTION: SAFETY MTG TOPICS: 3/15/2004 REGULATORY INSP? N LAST RIG INSPECTION BJ Services Halliburton Marathon Coil Tubing Well Testers Supervision Crane Operator SCADA Hookup Vac truck operator LAST BOP TEST: 3.500 LAST CASING TEST: NEXT BOP TEST: Printed: 4/29/2004 4:08:05 PM . MARATH€>N€>IL. AN¥" Pªil~~omplêJiÔhae.pºr1: ~~ploi.ta.tiQI1...~~$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFSO 100L IRPT# DATE KASILOF SOUTH 1L 1 30.6 74.00 13 13 06-Apr-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Ken Walsh DX0309032.CAP .CMP .02 I FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM WELL ~.....;:" I WILDCAT-FOR UNNAMED FIELD 100.0000 STATElPROV COUNTY/OTHER I LAST CASING I NEXT C.l.un__ I Alaska 3.500 (in) (â) 17,644 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Perforated Tvonek 17,385' - 17,409' MD. Perforate TvoneklRun GRlCCL strip log. OPERATION COMMENTS Perforated Tyonek 17,385' - 17,409' MD. SÄFETYSÜMI\IIAR.¥ MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST I LAST STOP CARD AUDIT REGULATORY INSP? I LAST RIG INSPECTION 122.50 None 3/15/2004 N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Trapped Pressure/ManliftlSlips,Trips, and Falls .~Û~_·. ... .} ~ ,,"Þr.iùî TÒ flIf{~ f:89M 1"9· TR~l,· 'I....'" . .,... 07:00 07:30 0.50 AF PERF SAFETY Held Prejob Safety Meeting to review work permit, hazards, and operational plan. 07:30 11:00 3.50 AF PERF PERF MIRU Schlumberger wireline to perforate the Tyonek. Removed tree cap flange and installed 3-1/8" 5K X 6-1/2" Otis crescent flange. MU lubricator and pulled Gun GRlCCL thru lubricator. MU flow tee, WL valve, and lubricator to flange connection. Spent 45 minutes repairing MOC Haskel pump skid. 11:00 12:30 1.50 AF PERF PERF Pressure test lubricator, tee, and WL valve to 300 psi low and 3500 psi high with methanol using MOC methanol skid. Sled back methanol to tank. Armed perforating gun and picked up into lubricator. MU lubricator and opened well. 12:30 15:00 2.50 AF PERF PERF RIHwith 1.1' of 2.63" OD rollers, 26.2' of 2.5" OD perforating guns (24' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 1-11/16" OD Gun-GR, 2.63" OD rollers, adapter head, and rope socket on Welltec 0.32" wireline. 15:00 16:30 1.50 AF PERF PERF Correlated GR and CCL depth with Reeves composite log. Tagged PSTD (top offish) at 17,478' WL measurement. Perforated the Tyonek interval 17385'-17409' MD. WHP was 1525 psi on data header transducer before perforating. After perforating, transducer pressure was 1515 psi at 15 minutes. GR and CCL quit working immediately after perforating. 16:30 18:00 1.50 AF PERF PERF POOH with perforating assembly. 18:00 18:30 0.50 AF PERF PERF Sled off 1500 psi lubricator pressure through vent stack. LD perforating guns. All shots fired and round. 18:30 19:00 0.50 AF PERF PERF SWIFN. PERSONNE.l.PATA POS.@QE.ì:QQ: COMPANY SERVICE ····11I0. HOURS COMPANY SERVICE NO. HOURS Schlumberger Perforators 4 68.00 Veco Alaska Crane Operator 1 12.50 Halliburton Well Testers 1 24.00 I.I.S.C.O. SCADA Hookup 1 4.00 Marathon Supervision 1 14.00 . Printed: 4/29/2004 4:08:08 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas LAST BOP TEST: SIZE< in 3.500 WELL NAME KASILOF SOUTH 1L 1 Printed: 4/29/2004 4:08:08 PM MA1RA1"FH(¡)N(¡)Il...·. e A1N¥ .... ]¡)a.ily~Ømpl~tion~êpØt'"t 1B·)(þIØ¡tátiØn -i<?~~ WELL NAME KB IGL 24 HR PROG TMD TVD jDFSO 100L IRPT# I DATE KASILOF SOUTH 1L 1 30.6 74.00 14 14 07-Apr-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Ken Walsh DX0309032. CAP .CMP .02 FIELD NAME RIG PHONE MOCWI NRI I CAlLY WELL COST I CUM WELL COST I WILDCAT-FOR UNNAMED FIELD 100.0000 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LI:A,,"vrr Alaska 3.500 (in) (cjJ. 17,644 1ft) (in) (cjJ. 0 1ft) CURRENT STATUS / MTS 24 HR FORECAST Perforate TvoneklRun GRlCCL strip 100. Perforate Tvonek 17280'-17300'. OPERATION COMMENTS Perforated Tyonek 17,300' - 17,320' MD. Ran GRlCCI correlation strip to 9700' SÄFE'F"YSCnnMÄR¥ MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 93.00 None 3/15/2004 ACCIOENT DESCRIPTION: SAFETY MTG TOPICS: Trapped pressurelpinch pointslicy spots .. _T~~~M~ ~ ~ f~<:>I'!I·. ·T9 H~~> f~9M. ..1;9 > . 06:30 07:00 0.50 AF PERF PERF Start equipment. Layout perforating guns. 07:00 07:30 0.50 AF PERF SAFETY Held Prejob Safety Meeting to review work permit, hazards, and operational plan. 07:30 08:00 0.50 AF PERF PERF Armed perforating gun and picked up into lubricator. MU lubricator and opened well. SIWHP was 1495 psi (nitrogen). 08:00 11:30 3.50 AF PERF PERF RIH with 1.1' of 2.63" OD rollers, 22' of 2.5" OD perforating guns (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 0.9' rollers, 6' of 2.185" OD wieght bar, 1-11/16" 00 Gun-GR, adapter head, and rope socket on Welltec 0.32" wireline. 11 :30 14:00 2.50 AF PERF PERF Correlated depth with Reeves composite log. Spent 1-1/2 hrs. troubleshooting Schlumberger's electronics to acquire and print a correlatable strip. Perforated the Tyonek 17300'-17320' with 1485 psi surface nitrogen pressure. No pressure response after 1 hour. 14:00 16:30 2.50 AF PERF PERF POOH logging GRlCCL strip to 9700'. 16:30 17:30 1.00 AF PERF PERF POOH with Gun-GR and perforating gun. 17:30 18:30 1.00 AF PERF PERF Bled off 1460 psi lubricator pressure through vent stack. LD perforating guns. All shots fired and round. Left well open to SPIOR and Barton gauges with 1460 psi. DATA. . .''''"'""" Ej SERVICE NO. , ~",....~... , NO. Schlumberger Perforators 4 44.00 Veco Alaska Crane Operator 1 11.00 Halliburton Well Testers 1 24.00 I.I.S.C.O. SCADA Hookup 1 2.00 Marathon Supervision 1 12.00 CASINGSlJMMARY LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: SIZE (in) IP (ifl}I$HOE TE$T(þpg MAX SICP I MP(ft) I T"VD(ft) I WT(lb/ft) 1 GRAPE .1 öU~öITPSIY 3.500 2.992 1 (psi)@ (ppg) 1 17,644 1 9,980 1 I I . . Printed: 4/29/2004 4:08:09 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Ken Walsh FIELD NAME KB 24 HR PROG TMD TVD SAPIWBS COST 30.6 RIG NAME & NO. MOC WI NRI 100.0000 I CUM WELL COST AUTH MD RIG PHONE WILDCAT-FOR UNNAMED FIELD STATE/PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Failed attem t to erforateT onek 17280'-17300'. OPERATION COMMENTS Aborted attempt to perforate 17280'-17300' MD. Install different wireline. L~J.\I'\.Vrr Test well? MANHRS WORKED 93.00 ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST None LAST STOP CARD AUDIT REGULATORY INSP? 3/15/2004 N LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Slips and fallslperforating safety. 06:30 07:00 0.50 AF PERF PERF Start equipment. Layout perforating guns. 07:00 07:30 0.50 AF PERF SAFETY Held prejob Safety Meeting to review work permit, hazards, and operational plan. 07:30 08:00 0.50 AF PERF PERF Armed perforating gun and picked up into lubricator. MU lubricator and opened well. SIWHP was 1465 psi (nitrogen). 08:00 10:00 2.00 AF PERF PERF RIH with 1.1' of 2.63" OD rollers, 22' of 2.5" OD perforating guns (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 0.9' rollers, two 6' of 2.185" OD wieght bars, CCL, adapter head, an rope socket on Welltec 0.32" wireline. 10:00 10:30 0.50 AF PERF PERF RIH to 17380' MD and made correlation tie-in up to marker joint at 16880-16886' MD. Started RIH to make second pass but set down at 16986' MD. When set down, trapped torque turned top shieve which wrapped wireline between shieve and top of grease head on lubricator. 10:30 11 :30 1.00 AF PERF PERF Spent one hour unwrapping wireline. POOH about 200' to inspect wireline. 11:30 12:00 0.50 AF PERF PERF Discovered damaged wireline (one foot section about 150' above 16986' MD. Armor strands overlapped but not broken). Appears that trapped torque and line compression opened up the armor and this section was most likely damaged while entering the grease flow tubes. Could not repair cable. Marked damaged spot with spray paint. 12:00 13:30 1.50 AF PERF PERF POOH with live perforating gun. Reviewed procedure to handle and disarm armed perforating gun while POOH. Made preparations to haul out a reel of Schumberger 0.23" wireline. 13:30 17:30 4.00 AF PERF PERF LD and disarmed perforating guns. Changed out reel of damaged WellTec 0.32" wire for reel of Schlumberger 0.23" wire. Changed out WL valve and flow tubes to accomodate ne wireline. Rebuilt control head. Printed: 4/29/2004 4:08: 1 0 PM WELL NAME KASILOF SOUTH 1 L 1 COMPANY Schlumberger Halliburton Marathon . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas . SERVICE Perforators Well Testers Supervision PERSONNEL DATA HOURS COMPANY 4 44.00 Veco Alaska 1 24.00 I.I.S.C.O. 1 12.00 CASING UMMARY LAST CASING TEST: MAX SICP (psi) @ (ppg) SERVICE Crane Operator SCADA Hookup 11.00 2.00 NEXT BOP TEST: Printed: 4/29/2004 4:08:10 PM . M'AR'A7[!HC>·N<C>I·L..iCC>.M.R'ANft 12)ª'IYCgrnpløtibh. ~@Pºrt çtç.p.loität.i.<:)1"1 d Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFSO IDOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 16 16 09-ADr-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Craig Meese DX0309032.CAP.CMP.02 1 FIELD NAME RIG PHONE MOCWI NRI \DA"VW':" rn~T ! CUM WELL. I;U:> I WILDCAT-FOR UNNAMED FIELD 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKU~~ Alaska 3.500 (in) @ 17,644 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Prepare to perforate additional Tyonek interval. Perforate Tyonek 16438' - 16454'. Test well? OPERATION COMMENTS Perforate Tyonek 17280' - 17300' MD. ŠÄFETYS.l:.lMIÎIIARY . MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUOIT I ~EGULATORY INSP7 I LAST RIG INSPECTION 98.00 None 3/8/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Slips and fallslperforating safety. ~ -- r . i - fß!:?M: iJ;!:? FRÔiV! <J¡p <$9$. </ 07:00 08:00 1.00 AF PERF PERF Start equipment. 08:00 08:30 0.50 AF PERF PERF Attempt to calibrate strain gauge for 0.23 wire. Strain gauge damaged. Order out replacement. 08:30 09:00 0.50 AF PERF PERF SIWHP = 1430 psi (nitrogen). Close upper master and bleed off pressure to Halliburton. PU and MU lubricator. 09:00 09:30 0.50 AF PERF SAFETY Held Prejob Safety Meeting to review work permit, hazards, and operation plan. 09:30 10:30 1.00 AF PERF PERF Pressure test lubricator, tee, and WL valve to 300 psi low and 3500 psi high with methanol using MOC methanol skid. Bled back methanol to tank. Armed perforating gun and picked up into lubricator. MU lubricator and opened well. SIWHP = 1430 psi (nitrogen). 10:30 15:00 4.50 AF PERF PERF RIH with 1.1' of 2.63" OD rollers, 22' of 2.5" OD perforating gun (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 0.9' rollers, one 6' of 2.185" OD weight bars, CCL, adapter head, anc rope socket on 0.23" wireline. 15:00 16:00 1.00 AF PERF PERF RIH to 17380' MD and made correlation tie-in up to marker joint at 16880-16886' MD. Make depth correction and pull confirmation strip up to marker joint. Perforate Tyonek 17280'- 17300' with 1427 psi surface nitrogen pressure (Perf @ 15:55). Good indication guns fired. Pull guns uphole immediately after firing. No pressure response after perforating. 16:00 17:30 1.50 AF PERF PERF POOH with perforating gun. 17:30 18:30 1.00 AF PERF PERF Bled off 1450 psi lubricator pressure through vent stack. LD perforating gun. All shots fired and round. Left well open to SPIDR and Barton gauges with 1410 psi. PERSQNNELDATA pÞê@ù6:0ö: . COMPANY SERVICE NO. HOURS COMPANY NO. .HPÛR$ Schlumberger Perforators 4 48.00 Marathon Supervision 1 12.00 Halliburton Well Testers 1 24.00 Veco Alaska Crane Operator 1 12.00 Printed: 4/29/2004 4:08:12 PM WELL NAME KASILOF SOUTH 1L 1 COMPANY I.I.S.C.O. LAST BOP TEST: SIZE in 3.500 . SERVICE SCADA Hookup . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas CA ING MMARY LAST CASING TEST: MAX SICP (psi) @ (ppg) Printed: 4/29/2004 4:08:12 PM ...... MARAmæeN()ILøeMRAN"'t" ЪilyØørhpl~*!p~~~ppf'1: EE)(iP!·øitãfiQtr ~~~$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFSO IDOL IRPT# DATE KASILOF SOUTH 1 L 1 30.6 74.00 17 17 10-ADr-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Craiq Meese DX0309032.CAP.CMP.02 FIELO NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM WI:LL cuST I WILDCAT-FOR UNNAMED FIELD 100.0000 . . . -- STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CA:;INü 1---'" Alaska 3.500 !in) (Œ 17,644 (fO (in) @ 0 (ft) CURRENTSTATUS/MTS 24 HR FORECAST Monitor BU. Monitor BU. OPERATION COMMENTS Perforate Tyonek 16438' - 16454' MD. Blow well down in increments. SI and monitor BU overnight. C!IA ......... .......... ........ / ..... MANHRS WORKED I ACCIOENT TYPE I LAST SAFETY MTG I BOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 104.00 None 3/9/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Slips and fallslperforating safety. SUMM lilt ....... ......... '. IF~pM TO H!3S .1=~pM/ ·tP $9ê RBL / 06:45 07:15 0.50 AF PERF PERF Start equipment. 07:15 07:30 0.25 AF PERF SAFETY Held Prejob Safety Meeting to review work permit, hazards, and operation plan. 07:30 07:45 0.25 AF PERF PERF SIWHP = 1409 psi (nitrogen). Close upper master and bleed off pressure to Halliburton. PU and MU lubricator. 07:45 08:00 0.25 AF PERF PERF Armed perforating gun and picked up into lubricator. MU lubricator and opened well. SIWHP = 1409 psi (nitrogen). 08:00 15:00 7.00 AF PERF PERF RIH with 1.1' of 2.63" OD rollers, 22' of 2.5" OD perforating gun (16' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 0.9' rollers, one 6' of 2.185" OD weight bars, CCL, adapter head, an rope socket on 0.23" wireline. Note: Encountered difficulty working gun assembly past 10324'. Work approx 2 hrs before gun would pass. 15:00 16:20 1.33 AF PERF PERF RIH to 16950" MD and made correlation tie-in. Make depth correction and pull confirmation strips. Note: Prior to firing guns, opened WV to closed valve at test sep in order to monitor perf event on Barton gauge. Valve cracked a Halliburton and lost approx 154 psi (SIWHP dropped from 1410 psi to 1255 psi before caught). Perforate Tyonek 16438' - 16454' with 1255 psi surface nitrogen pressure (Perf @ -16:20). Good indication guns fired. Pull guns uphole immediately after firing. No pressure response after perforating. 16:20 18:00 1.67 AF PERF PERF POOH with perforating gun. 18:00 18:30 0.50 AF PERF PERF Bled off 1240 psi lubricator pressure through vent stack. LD perforating gun. All shots fired and round. Left well open to SPIDR and Barton gauges with 1240 psi. 18:30 19:30 1.00 AF FLOW FLOW Blow well down on 14/64" var ck to 900 psi WHP. SI & monitor. No inflow. 19:30 20:30 1.00 AF FLOW FLOW Blow well down on 14/64" var ck to 700 psi WHP. SI & monitor. No inflow. . . Printed: 4/29/2004 4:08:13 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 L 1 FROM HRS 20:30 23:00 2.50 FROM SUB AF OPERATIONS SUMMARY PHASE OP TRBL 23:00 06:00 7.00 AF FLOW MONITR t>E$CRIPr'ON Blow well down on var ck to 0 psi WHP (10 psi on Barton guage). SI well and left well open to SPDR and Barton gauges. Note: All blow down gas has been 0.9 sp gr nitrogen by Ranare flow stream monitor. Monitor well pressure BU overnight. SIWHP = 14 psi @ 0600 on Barton gauge. FLOW FLOW COMPANY Schlumberger Halliburton Marathon Perforators Well Testers Supervision 4 48.00 Veco Alaska 1 24.00 I.I.S.C.O. 1 18.00 Crane Operator SCADA Hookup Printed: 4/29/2004 4:08:13 PM · WELL NAME KASILOF SOUTH 1 L 1 SUPERVISOR Crai Meese FIELD NAME KB TVD RIG NAME & NO. AUTH MD RIG PHONE MOCWI WBS DX0309032.CAP.CMP.02 I DAILY WELL COST [Cl.;m .. ___ _~u . NR: WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Monitor BU. OPERATION COMMENTS Ran PL T to obtain Static BHP, Temp and fluid gradients. Verified perf placement and prior CCUGR tie-in runs. SAF.ET"YSUMMAR¥ LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? COUNTY/OTHER 100.0000 LEAI._. . MANHRS WORKEO ACCIDENT TYPE 132.00 None ACCIOENT DESCRIPTION: 3/14/2004 LAST RIG INSPECTION N SAFETY MTG TOPICS: Communication, muster area, slips, falls, spring break-up pot holes 07:00 08:00 1.00 AF OTHER LOG MI and spot Schlumberger ElL equipment. 08:00 08:30 0.50 AF OTHER LOG Held Prejob Safety Meeting to review work permit, hazards, and operation plan. 08:30 09:00 0.50 AF OTHER LOG RU Schlumberger wireline to run PL T. Removed tree cap flang and installed 3-1/8" 5K x 6-1/2" Otis crescent flange. MU lubricator and pulled Gun GRlCCL thru lubricator. MU flow tee, WL valve, and lubricator to flange connection. 09:00 09:15 0.25 AF OTHER LOG PU Schlumberger GRlCCLlPL T tool and pulled into lubricator. MU lubricator to wellhead. 09:15 09:45 0.50 AF OTHER LOG Pressure test lubricator, tee, and WL valve to 2000 psi with methanol using MOC methanol skid. Bled back methanol to tank. 09:45 16:45 7.00 AF OTHER LOG RIH with PL T (PSPT-NB) tool logging temperature and pressur to 17430'. Surface pressureltemp measured by Schlumberger was 59 psia 143 F and 40 psi 143 F on Barton Gauge. 16:45 17:30 0.75 AF OTHER LOG Correlate PL T log to Reeves CBL. Made 3 logging passes across perfs 17280' - 17320' at various CCL gain settings. CCL shows perfs correctly aligned across GR sand response. Note: Could not get deep enough to see deepest perfs 17,385'- 17409' due to length of PL T tool string. 17:30 19:05 1.58 AF OTHER LOG Recorded 5 min stops in water leg as follows: 17:33: 17400': 596.58 psia 1167.3 F. Recorded 1 hr 15 min stop in water leg as follows: 17:45: 17280': 558.36 psia 1166.2 F. 19:00: 17280': 559.86 psia 1166.3 F. Recorded 5 min stop in water leg as follows: 19:05: 16700': 332.77 psia 1157.3 F. 19:05 19:25 0.33 AF OTHER LOG Made logging pass across perfs 16438' - 16454'. CCL shows perfs correctly aligned across GR sand response. 19:25 00:00 4.58 AF OTHER LOG Recorded 5 min stop in water leg as follows: Printed: 4/29/2004 4:08:14 PM WELL NAME KASILOF SOUTH 1L 1 . . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas FROM TO HRS FROM TO SUB 19:25 00:00 4.58 AF 00:00 00:30 0.50 00:30 01 :30 1.00 COMPANY Schlumberger Halliburton Marathon Perforators Well Testers Supervision OPERATIONS SUMMARY PHASE OP TRBL OTHER LOG AF PSS¢FtIPTION 19:25: 16200': 136.75 psia 1151.6 F. Logged Water Contact at 16,022'. Recorded 5 min stops in gas column as follows: 19:33: 15920': 69.22 psia 1149.9 F. 19:41: 15740': 69.21 psia 1149.1 F. 20:20: 12000': 66.40 psia 1124.3 F. 20:45: 8000': 64.20 psia 1108.5 F. 21 :30: 4000': 61.50 psia I 86.5 F. 23:45: Recorded 15 min stop at Surface: Final surface pressure I temp measured by Schlumberger was 59.50 psia I 43.5 F and 40 psi 146 F on Barton guage. Closed master valve and bled off lubricator. LD lubricator and PL T tools. ND WL valve and flow tee. RD Schlumberger. Closed master valves and bled off lubricator. LD lubricator and PL T tools. ND WL valve and flow tee. RD Schlumberger and prep to move out. Secure well and proceed with pressure monitoring as follows: KS#1 L 1: Monitor with SPDR and Barton gauges. KS#1 rd: Monitor with Data Trap gauge. OTHER LOG AF OTHER LOG Printed: 4/29/2004 4:08:14 PM . . Alaska Asset Team Northern Business Unit Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-1350 April 5, 2005 RECE"/F:O MAY () Ð Z005 Alaa:k¡a Oil &, ..... .' .. Lun;,;, t:om¡r¡luion Ar¡r;horcgé Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Attached and submitted for your records is the Form 10-407 for the completion work performed in the Kasilof South #1 L 1. This well was completed in the Tyonek formation in April 2004 but did not yield a commercial gas rate. The wellbore has been suspended since April 15, 2004 pending an engineering and economic analysis. Also attached for your records are the operational history for the non-rig completion operations, the final directional survey, and a well schematic. If you would like any other information, please contact me at 283-1311 or kdwalsh@marathonoil.com. Sincerely, I~^,-D.W~ Ken D. Walsh Senior Production Engineer Enclosures OR I ¡,f^ L ¡J li ,,"'~ ALAS~L AND ~:~T~g~S~~:A~ON COMMIS& REet:lVI::'b WELL COMPLETION OR RECOMPLETION REPORT AND LOt!;W 0 9 2005 1a. Well Status: O¡IU GasU Plugged U Abandoned U Suspended ~ WAGD 1b. Well Class: Alaska W' §b,§' 20MC 25.105 20MC25.110 Development D xp ~. GINJD WINJD WDSPL D No. of Completions Other Service D StratigraPhï6lfQÒ@ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: MARATHON OIL COMPANY Aband.: 04/15/04 202-257 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 1949, Kenai, AK 99611-1949 October 14, 2003 50-133-20520-60 4a. Locat¡on of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 520' FSL & 1340' FWL Sec. 28 T3N- R12W, SM December 28,2003 KasUof South #1 L 1 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 1865' FSL & 4030' FEL Sec. 19 T3N-R12W, SM 104' W¡ldcatlTyonek Total Depth: 9. Plug Back Depth(MD+ TVD): 2230' FSL & 4382' FEL Sec. 19 T3N-R12W, SM 17,543' 9885' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 250209 y- 2310138 Zone- 4 17665' MD 9999' TVD ADL-384534, 384529, 389502 TPI: x- 239696 y- 2316990 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 239256 y- 2317357 Zone- 4 18. Directional Survey: Yes ~ No D 19. Water Depth, if Offshore: 20. Thickness of Permafrost: feet MSL 21. Logs Run: Reeves Quad Combo: GRlCal/Den/Neutron/SoniclArray Induction 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED N/A 20" 133# K-55 0' 130' 0' 130' Driven NIA 13-318" 68# K-55 0' 2860' 0' 2383' 16" in place, 750 sx NIA 9-5/8" 40 & 47# L-80 0' 1851' 0' 1541' 12-1/4" in place, 2200 sx NIA 7" 29# L-80 9916' 10533' 0' 3397' 12-1/4" Cemented with 9-518" csg. NIA 3-1/2" 9.2# L-80 9918' 17644' 5187' 9980' 6-1/8" in place, 700 sx NIA 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) 16438-16454' MD, 16 ft PJ2506, 6 SPF, 0.35" EH 4/9/2004 3-1/2" 9918' 10909' 17280-17320' MD, 40 ft PJ2506, 6 SPF, 0.35" EH 4/6&8/2004 17385-17409', MD 24 ft PJ2506, 6 SPF, 0.35" EH 4/5/2004 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for O¡I-Bbl: Gas-MCF: Water-Bbl: Choke Size: I~as-Oil Ratio: Test Period ~ NIA Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: OU Gravity - API (corr): Press. N/A 24-Hour Rate ..... NIA 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". Lithology - interbedded sandstone, shale and coal RBDMS BFf ". (! 70D5 on i L . ¡.\ '* ~~ I,;ommissi, Form 10-407 Revised 12/2003 CONTINUED ON REVERSE NAME GEOLOGIC MARKER M 29. ORMATION TESTS 28. TVD Include and briefly sum rize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Beluga Tyonek 7880 14309 4378 Perf: 17385-17409', MD 24 ft, no flow,4/5/2004 7120 Added perfs: 17280-17320' MD, 40 ft, no flow, 4/6&8/2004 Added perfs: 16438-16454' MD, 16 ft, no flow, 4/9/2004 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ken D. Walsh Printed Name: Ken D. Walsh Signature: Title: Senior Production Engineer .vJ~ Phone: 907-283-1311 Date: 5/5/2005 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 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with prod 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 in 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". Form 10-407 Revised 12/2003 KasilofSouth#1 L 1 (Lateral-North Taraet) Kasilof 520' F$L. 1340' FWl, Sec. 28, T3N,R12W,$M J Baker TAML Level 6 Formation Junction (DepthRT) Top of Junction @ 9901.49' Bifurcation PI. @ 9916.54' Bottom of 7" leg No-Go @ 9934.99' Bottom of 7" leg @ 9937.63' Formation Tops: Depth (MD) Depth (TVD) N/A NfA TD: 17,665' MD I 9999' TVD L Conductor 20" 133 ppf Top Bottom O'MD Surface CasinQ 13·3/S" 68 ppf Top 16" hole wîth+f-750 sl(s 12 ppg Dual 3·1/2" GT Packer @ 9S53' MD/5161' WD. Intermediate Casinç¡ 9·5/S" 40 and 47 ppf L-SO BTC Intermediate Casinç¡ 7" 29ppf L-BO New Yam 12-1/4" hole with +1-1550 sks 12.7 3-1/2" L-BO 9.2 ppf Hydril 563 6-1/S" hole with +1- 700 sks. 12.7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From-To 3/5/2004 08:00 - 20:30 3/6/2004 08:00 - 16:00 3/9/2004 08:00 - 17:00 3/10/2004 08:00 - 12:00 12:00 - 17:00 3/11/2004 08:00 - 13:00 13:00 - 16:00 e e Marathon Oil Company tions Summary'" KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors Spud Date: 10/14/2003 End: Group: Start: 3/4/2004 Rig Release: Rig Number: 273E Description of Operations Sub Code Code 12.50 LOC LCLN SITLOC Location Clean up: ASRC cleaned up location from drilling operations. PU old liner and berm and leveled ground with loader. Spotted Halliburton Well Test separator, lab, and pipe racks. Delivered 500 bbl Rain-for-Rent tank, MOC flowback tank, gas buster, methanol test skid, methanol tank, chicksan, choke manifold, and cement barrels. 8.00 TEST OTHR MIRU ASRC layed liner and berm around wellhead, tanks, 1000 gal diesel fuel tank, and Halliburton Separator. Halliburton began rigging up flowback equipment. 9.00 TEST OTHR MIRU Layed and made up Halliburton 3" test lines to vent stack and to wellhead. MU Halliburton 3-1/8"5K x 3" 1502 flanges downstream of SSVon both sides of the dual tree. Layed and made up one 3" test line to tee into both wings of the tree and one 3" fluid line to Rain-for-Rent tank. ASRC continued to lay liner and berm around test lines and other equipment. Spotted Veco office skid. Airport Rental delivered 65 KW generator, air compressor with 2 sections of 50' hose, 45-25 Manlift, two light plants, and Chinook heater. Carlisle trucking delivered vent stack. Veco vac truck delivered 16 bbls. 50/50 glycol water and filled separator bath. Veco delivered 45 ton crane. 4.00 TEST OTHR MIRU Finished rigging up Halliburton test lines. Udelhoven delivered "bang box" electrical panel from Ninilchik warehouse. Udelhoven wired Halliburton lab and separator, MOC water well, and Veco office to panel to diesel generator. ASRC welded satellite stand to Halliburton lab. ASRC continued to berm liner. Set gas buster on flowback tank-chained and boomered down buster to tank. R&K delivered methanol tank. Set methanol tank in bermed area and Veco vac truck filled with about 30 bbls. methanol water. Cook Inlet Safety delivered H2S/LEL sensoring equipment. Vetco pulled BPV from tubing hanger. Closed and locked master valves. Two Veco roustabouts cleaned out ice from water well house and began rigging up chicksan from wellhead to choke skid and then to gas buster and flowback tank. Alaska Oil Sales delivered 990 gals diesel to ASRC rental storage tank. 5.00 TEST OTHR MIRU Rigged up Cook Inlet Safety sensors and lines to control building. Veco roustabouts pulled out water well power supply line from snow berm to use as power cable to generator. ASRC cleaned up 5 gal. spill of glycol from portable toilet and sent with MOC to KGF for handling. Airport Rentals replaced faulty Chinook diesel-fired heater. 5.00 TEST OTHR MIRU Veco routabouts finished digging out electrical supply wires (left over from drilling) to use as tie-in power from the electric generator to the water well. S&R replaced damaged portable toilet. Udelhoven electrician made final tie-in for water well power. Carlisle Trucking PU trailer after Veco crane operator removed and set Flare Stack Inc. base and 30" x 40' vent stack. Weaver Bros. delivered 650 gals methanol to methanol tank. Veco vac truck delivered 80 bbls. of fresh water. Offloaded 15 bbls. of fresh water into methanol water tank and placed the remaining water in the clean fluid tank. Vacuumed out the standing water in the water well house. 3.00 TEST OTHR MIRU Repositioned choke manifold and methanol skid to accomodate coil tubing operations. MU vent stack to base. MU flange swedge and Halliburton Well test lines to vent stack while waiting on replacement manlift from Airport Rentals (manlift fuel supply problems). Disconnected lifting cables from vent stack with manlift. Set cement barrels and tied down vent stack guy wires to barrels. Shoveled snow from liner and layed down plywood. Printed: 5/3/2005 8:13:29 AM e e ~m~~ ~ Summary;Be Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors Start: 3/4/2004 Rig Release: Rig Number: 273E Spud Date: 10/14/2003 End: Group: Date From - To Hours. Code ~Je Phase of Operatio~$ 10:00 - 10:30 1.00 CL TBG RURD CLNOUT Install 3-1/8" 5K x 3-1/6" 1 OK flange to top of tree. Move CIT stack from Kasilof State #1rd (motherbore) to Kasilof State #1 L 1 (lateral). MU 3-1/8" 5K x 3-1/16" 10K flange to top of tree. MU 3-1/16" 10K flange connection below flow cross of CIT stack. 1.00 CL TBG RURD CLNOUT Attempting to break lubricator and layout motor assembly. 1.00 CL TBG RURD CLNOUT Broke lubricator and layout motor assembly. Motor was severely pitted on entire OD surface and had very fine metallic particles magnetically attached to it. Motor was bent and mill missing 1/3 of two outside carbide buttons on the face. Layed down motor, mill, and hydraulic disconnect. Installed new rupture disc in rupture sub. 0.50 SAFETY SMTG CLNOUT Held PJSM. Veco vac truck on location with a load of fresh water. Mixed BJ Services FRW-14 at 1 gpt into fresh water and offloaded into clean fluid tank. 1.00 CL TBG RURD CLNOUT PJSM. Test lines 250/5500. Test pipe rams 250/4500. Test aux rams 250/4500. Test blind rams and flow back iron 250/4500. 1.50 CL TBG RURD CLNOUT Break lubricator. MU Weatherford BHA as follows: 2.20" OD 1-1/2" Coil Connector, 2.20" OD Dual Check Valve, 2.25" OD Dual Acting Jar, 2.25" OD Hydraulic Disconnect (5/8" Ball Drop), 2.25" OD Rupture Sub (5K Rupture Disk), 2.15" OD X-Over (1/14" Reg x 1-1/2" MT), 2.125" OD PDM, 2.805" OD 5 Bladed Junk Mill. MU lubricator. Shell test BOP stack 250/4500 psi.s: 0.50 CL TBG RURD CLNOUT Displaced methanol water from CT with 34 bbls. fresh water. Confirm motor operating. 9.50 CL TBG RICT CLNOUT RIH breaking circ every 15 min: 3100' wt check 5000 Ibs 6100' wt check 8900 Ibs 9000' wt check 11000 Ibs 9800' wt check 12200 Ibs PUH and started pumping fresh water at 1 BPM. RIH and drilled about l' cement stringer at 9994'. Continued RIH making weight checks: 10360' wt check 12000 Ibs 10600' wt check 12000 Ibs 11000' wt check 12500 Ibs 11600' wt check 15400 Ibs (PU wt. abnormally high due to increase in packoff pressure applied to control slight fluid leak from CT packoff) 12000' wt check 15500 Ibs 12500' wt check 17000 Ibs 13000' wt check 17500 Ibs 13500' wt check 18000 Ibs 14086' wt check 18500 Ibs - Tagged slight restriction-Passed easily-no motor action noted. 14530' wt check 19000 Ibs 15100' wt check 20500 Ibs 15500' wt check 21000 Ibs 16000' wt check 23000 Ibs 16500' wt check 25000 Ibs 16700' wt check 25500 Ibs 17000' wt check 26500 Ibs 17300' wt check 28000 Ibs - Tagged slight obstruction-Passed easily 17520' wt check 29000 Ibs - PU to 17450' and RBI H to 17520' 3.00 CLTBG RICT CLNOUT Circ 2X BU (230 bbls) @ 17520'. Move CT uphole 75' every 75 bbls pumped. 3/13/2004 04:00 - 05:00 3/14/2004 05:00 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 08:30 08:30 - 10:00 10:30 - 20:00 20:00 - 23:00 Printed: 5/3/2005 8:13:29 AM e e '<'Æ ? Oil Company '.. Operati~nsSummary Report 4.50 CL TBG POCT CLNOUT POOH with C/T while circulating 1.4 BPM. 0.50 CL TBG RURD CLNOUT Displace C/T with methanol water. Blow lines dry across tree. 0.50 CL TBG RURD CLNOUT Break 3-1/16" 10K flange connection below flow cross. PU stack. Move back to motherbore side of dual tree (Kasilof State #1 rd). Temporarily suspend operations on Kasilof State #1 L 1. 0.25 CL TBG RURD CLNOUT Install 3-1/8" 5K x 3-1/16" 10K flange to top of tree. Move C/T stack from Kasilof State #1 rd (Motherbore) back to Kasilof State #1 L 1 (Lateral). MU 3-1/16" 10K flange connection below flow cross of C/T stack. PJSM. Tested pipe, auxilary, and blind rams 250/4500 psi with methanol water. Broke lubricator and PU Weatherford venturi junk basket with 8' extension and 2.850" shoe, hydraulic disconnect, dual acting jars, dual checks, and 1-1/2" coil connector. MU lubricator. Shell test BOP and lubricator to 1000 psi with methanol water. Displace methanol water from C/T with fresh water. Open well and begin RIH with venturi BHA on C/T. RIH with venturi BHA on C/T at 75 FPM to liner top making following wt checks and pumping fresh water at 1 BPM: 2500' wt check- 3500# 7100'wtcheck-8100# 9800' wt check- 11000# 0.50 SAFETY SMTG CLNOUT Held Prejob Safety Meeting. Reviewed work permit, hazards, and operational plan. 4.00 CL TBG RICT CLNOUT RIH with venturi BHA on C/T at 40 FPM to liner top making following wt checks and pumping fresh water at 1 BPM: 11100' wt check- 12000# 11600' wt check- 12500# 12000' wt check- 13000# 12500' wt check- 14000# 13000' wt check- 14500# Increased circulation rate from 1.2 BPM to 1.35 BPM 13600' wt check- 15000# 16550' wt check- 21000# 14000' wt check- 16000# 17000' wt check- 22000# 14600' wt check- 16500# 17250' wt check- 22500# 15100' wt check- 17500# 17500' wt check- 23500# 15600' wt check- 18500# 17512' Tag TD - PU at 24000# 16000' wt check- 19500# 0.50 CL TBG RICT CLNOUT PUH to 17456' and then RIH to 17508' MD. Pumped 30 bbls. of 6% KCL water and displaced to the end of the coil tubing with 32 bbls. of filtered fresh water. KCL water placed from 17,508' to 14031' MD. 3.50 CL TBG POCT CLNOUT Shut down pumps. POOH with venturi junk basket, jars, MHA, and coil tubing maintaining a pulling rate of 50 FPM to the liner top and 110 FPM to surface. 0.50 CL TBG POCT CLNOUT Displaced coil tubing with methanol water. 1.00 CL TBG RURD CLNOUT Break lubricator and LD venturi junk basket and jar assembly. FISH: LEFT 9.57': VENTURI JUNK BASKET EXTENSION (2.625" OD WITH SCREEN sticking up above box -2") WITH 2.85" OD SHOE IN HOLE. CS HYDRIL CONNECTION THREADS ON BOTTOM ARE NOT DAMAGED-APPEARS TO HAVE BACKED OFF. 1.00 CL TBG RURD CLNOUT Consult office: Will make bit run to push fish to bottom and leave in rathole. Pull test C/T to 20,000 lb. PT C/T to 3500 psi. '...j v Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors From-To Hours Cod e"Sub Phase Code '/:>{j: 3/14/2004 23:00 - 03:30 03:30 - 04:00 04:00 - 04:30 3/15/2004 02:30 - 02:45 02:45 - 03:00 0.25 SAFETY SMTG CLNOUT 03:00 - 04:00 1.00 CL TBG RURD CLNOUT 04:00 - 04:30 0.50 CL TBG RURD CLNOUT 04:30 - 05:00 0.50 CL TBG RURD CLNOUT 05:00 - 05:30 0.50 CL TBG RURD CLNOUT 05:30 - 06:00 0.50 CL TSG RICT CLNOUT 3/16/2004 06:00 - 08:00 2.00 CL TSG RICT CLNOUT 08:00 - 08:30 08:30 - 12:30 12:30 - 13:00 13:00 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 19:00 Spud Date: 10/14/2003 End: Group: Start: 3/4/2004 Rig Release: Rig Number: 273E Des~tiption of Operations Printed: 5/3/2005 8:13:29 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors '::,-.' Oil/Cpmpan¥r~; , Summary Report . e Spud Date: 10/14/2003 End: Group: Start: 3/4/2004 Rig Release: Rig Number: 273E Dêscription of 1.00 CL TBG RURD CLNOUT MU Weatherford BHA as follows: 2.75" OD cement mill, 2" OD X-O (1-1/2" MT bxb), 2.25" OD Hydraulic disconnect, 2.25" OD X-O (1-1/4" Reg x 1-112" MT bxp), 2.25" OD Dual acting jar, 2.20" OD Dual check valve, 2.20" OD Coil connector. 1.00 CL TBG RURD CLNOUT PJSM and review operations plan. MU lubricator. Shell test BOP and lubricator to 1000 psi with methanol water. 0.50 CL TBG RURD CLNOUT Displace methanol water from C/T with fresh water. 7.00 CL TBG RURD CLNOUT Open well and RIH with C/T. Pump 1 BPM from 2500' to 14000', then SD pumps. 17478' Tag and set 6K down. Could not push fish further DH (Note: Bottom perf will be 17,410'). 17478' wt check 21000 #. POOH with CT (CT @ 9000' at report time). POOH with CT. Held Prejob Safety Meeting. Reviewed work permit, hazards, and operational plan. Displaced water from CT with 50/50 methanol water. Broke lubricator and LD Weatherford 2.75" OD cement mill, X-O, 2.25" OD Hydraulic disconnect, X-O, 2.25" OD Dual acting jar, 2.20" OD Dual check valve, and 2.20" OD Coil connector. No new marks on any of the equipment. LD speed lubricator and injector head (installed .109" wall dimple on connector to CT). ND CT BOP and riser spool from top of swab valve flange. Cleanup and stow tools. Secure equipment. Temporarily suspend operations. Move to KS #1 rd to run cased hole logs. Temporarily suspend operations while running cased hole logs on KS # 1 rd. RU cresent shaped 5m flange to dual tree with pollard rental pump in tee. PU first part of tool string and begin in hole. Ice in flowline restricts running in hole. Lay down tools while rigging up vac truck and heater to lines and tree. CSGD CLNOUT MU tool string consisiting of 2.25" OD Reeves cased hole memory logging tools: (GRlCCUNeutron/Density/CaliperISonic). MU battery pack at 1 :56:00, PU to install nuclear sources, nuclear device fails to sense battery power. CSGD CLNOUT Battery checks out good, change out memory section. MU battery pack at 02:16:30, PU to nuclear density tools, activation OK, Install nuclear sources and WellTec's 2-1/8" OD wireline tractor with Veco crane. Overall length of logging tools is 71.63'. Overall length of tractor is 20.33'. With top of wireline tool string at pump in sub set wireline counter to 88.63' to reflect KB measurement (added 17 feet to tool 3/16/2004 18:00 - 19:00 19:00 - 20:00 20:00 - 20:30 20:30 - 03:30 03:30 - 06:00 2.50 CL TBG RURD CLNOUT 3/17/2004 06:00 - 07:00 1.00 CL TBG RURD CLNOUT 07:00 - 07:30 0.50 SAFETY SMTG CLNOUT 07:30 - 08:00 0.50 CL TBG RURD CLNOUT 08:00 - 10:00 2.00 CL TBG RURD CLNOUT 10:00 - 11 :30 1.50 CL TBG RURD CLNOUT 11 :30 - 12:00 0.50 CL TBG RURD CLNOUT 12:00 - 00:00 12.00 WAIT OTHR CLNOUT 00:00 - 01 :00 1.00 LOG CSGD CLNOUT 01 :00 - 02:00 1.00 LOG 02:00 - 03:00 1.00 LOG 5300' wt check- 5000# 9257' wt check- 9500# 10450' wt check- 10200# 10950' wt check- 10400# 11450' wt check- 11000# 11950' wt check- 11500# 12450' wt check- 12200# 12950' wt check- 13000# 13450' wt check- 12250# 13950' wt check- 13500# 14150' Possible tag (800# wt loss) 14450' wt check- 15500# 14950' wt check- 15300# 15450' wt check- 16000# 15950' wt check- 18000# 16500' wt check- 18500# 16950' wt check- 19200# 17250' wt check- 20200# Printed: 5/3/2005 8:13:29 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/17/2004 3/18/2004 3/19/2004 02:00 - 03:00 03:00 - 06:00 06:00 - 09:00 09:00 - 10:00 10:00 - 12:30 12:30 - 13:00 13:00 - 14:00 e e , Marathon Oil Company Summary Report KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors To Hours :de Sub Code 1.00 LOG 3.00 LOG CSGD CLNOUT CSGD CLNOUT 3.00 LOG 1.00 LOG CSGD CLNOUT CSGD CLNOUT 2.50 LOG CSGD CLNOUT 0.50 SAFETY SMTG CLNOUT 1.00 CL TBG RURD CLNOUT 14:00 - 16:00 2.00 CL TBG RURD CLNOUT 16:00 - 17:00 1.00 CL TBG RURD CLNOUT 17:00 - 18:30 1.50 CL TBG RURD CLNOUT 18:30-21:30 3.00 CL TBG RICT CLNOUT 21 :30 - 23:00 23:00 - 01 :00 01 :00 - 02:00 02:00 - 06:00 06:00 - 08:00 1.50 CL TBG JET CLNOUT 2.00 CL TBG RICT CLNOUT 1.00 CL TBG JET CLNOUT 4.00 CL TBG POCT CLNOUT 2.00 CL TBG RURD CLNOUT Spud Date: 10/14/2003 End: Group: Start: 3/4/2004 Rig Release: Rig Number: 273E Description of string as pump in sub is 13.5' above ground-17 feet below KB height). RIH with 2.25" OD Reeves cased hole memory logging tools: (GR/CCUNeutron/Density/CaliperISonic) and WellTec's 2-1/8" OD wireline tractor. Loose tension on cable at 17,472', on PU reached full line tension of 4800 Ibs at 17,422'. PUH logging to 12,500' MD. POOH and lay down tractor. BJ CoilTech on location to RU for CT jetting operations. Lay down and isolate nuclear sources. Download data from memory logging tools. Begin depth-time correlation of memory logs. RD Reeves. RU BJ Coiltec wellhead flange, riser, and CT BOP. Vehicle accident: Well tee supervisor moving Reeves pickup slid on short icy incline into light plant outrigger. Driver moving at low rate of speed. Pickup dented on underside of passenger's side behind door. No injuries. Driver was using Reeves employee as spotter but spotter on wrong end of pickup to identify hazard potential. No damage to light plant. Prejob Safety Meeting for coil tubing operations. PU injector head and move to wellhead. MU 1-3/4" OD wash nozzle, 4' long straight bar, and double checks to 1-1/2" OD coil tubing connector. Pull test CT connector. Function test BOP's. MU injector head to CT BOP. RU nitrogen transport to nitrogen pumping unit. Attempted BOP test but leaking below BJ flange to swab valve. Changed out ring gasket. Pressure tested CT BOP and lines to 300/4500 psi. Cooled down nitrogen unit. Displaced methanol water with nitrogen. RIH with CT while pumping nitrogen at min rate to balance hydrostatic pressure of fluid in well bore. Weight checks: @ 11500' PU 7000 Ibs SO 2000 Ibs. @ 14000' PU 9000 Ibs SO 3000 Ibs. Increase nitrogen rate to 1500 scfpm. Jet well recovering 111 bbls of fluid. Check weights at 14000' after jetting, with PU 10500, SO 3000. CT pressure gradually increased at end of jetting to 3800 psi and leveled off. Put nitrogen pump into recirc and shut in CT annulus. RIH to jet dry remainder of well. Check weight while RIH, @ 15000' PU 12000 Ibs SO 3000 Ibs. @ 16000' PU 13500 Ibs SO 3000 Ibs. @ 17000' PU 14750 Ibs SO 4000 Ibs. Tag bottom at 17429' KB with 3500 Ibs @ 17429' PU 15000 Ibs SO 4000 Ibs. PU to 17410 to jet well. Begin pumping N2 at 1500 scfpm. Increased rate to 2000 scfm at 01:30. 141 bbls recovered. Returns minimal .25 bpm. Begin POOH to sweep water out of hole. PU weight 18000 Ibs. At 02:30148 bbls recovered. 02:45 returns dry for 15 minutes. 03:05 returns still dry, 148 bbls recovered out of possible 151. Tum nitrogen pump to recirc and continue to POOH. Pump down kill line to increase wellhead pressure to 1700 psi. Out of the hole with CT at 0600 hrs Heated BJ kill line with Chinook heater to clear ice plug. ND flange connection from BJ riser to swab valve and moved over to KS #1 rd. Temporarily suspend operations until after KS #1rd is perforated and tested. Printed: 5/3/2005 8:13:29 AM e e Mªrat/)oo Oil Compat7tY atlons Summary Report 0.50 SAFETY SMTG CMPPRF Held Prejob Safety Meeting to review work permit, hazards, and operational plan. 3.50 PERF RURD CMPPRF MIRU Schlumberger wireline to perforate the Tyonek. Removed tree cap flange and installed 3-1/8" 5K x 6-1/2" Otis crescent flange. MU lubricator and pulled Gun GRlCCL thru lubricator. MU flow tee, WL valve, and lubricator to flange connection. Spent 45 minutes repairing MOC Haskel pump skid. 1.50 PERF RURD CMPPRF Pressure test lubricator, tee, and WL valve to 300 psi low and 3500 psi high with methanol using MOC methanol skid. Bled back methanol to tank. Armed perforating gun and picked up into lubricator. MU lubricator and opened well. 2.50 PERF WLNC CMPPRF RIH with 1.1' of 2.63" OD rollers, 26.2' of 2.5" OD perforating guns (24' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 1-11/16" OD Gun-GR, 2.63" OD rollers, adapter head, and rope socket on Welltec 0.32" wireline. 1.50 PERF WLNC CMPPRF Correlated GR and CCL depth with Reeves composite log. Tagged PBTD (top of fish) at 17,478' WL measurement. Perforated the Tyonek interval 17385'-17409' MD. WHP was 1525 psi on data header transducer before perforating. After perforating, transducer pressure was 1515 psi at 15 minutes. GR and CCL quit working immediately after perforating. POOH with perforating assembly. Bled off 1500 psi lubricator pressure through vent stack. LD perforating guns. All shots fired and round. SWIFN. Start equipment. Layout perforating guns. Held Prejob Safety Meeting to review work permit, hazards, and operational plan. Armed perforating gun and picked up into lubricator. MU lubricator and opened well. SIWHP was 1495 psi (nitrogen). RIH with 1.1' of 2.63" OD rollers, 22' of 2.5" OD perforating guns (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 0.9' rollers, 6' of 2.185" OD wieght bar, 1-11/16" OD Gun-GR, adapter head, and rope socket on Welltec 0.32" wireline. 2.50 PERF WLNC CMPPRF Correlated depth with Reeves composite log. Spent 1-1/2 hrs. troubleshooting Schlumberger's electronics to acquire and print a correlatable strip. Perforated the Tyonek 17300'-17320' with 1485 psi surface nitrogen pressure. No pressure response after 1 hour. POOH logging GRlCCL strip to 9700'. POOH with Gun-GR and perforating gun. Bled off 1460 psi lubricator pressure through vent stack. LD perforating guns. All shots fired and round. Left well open to SPIDR and Barton gauges with 1460 psi. Start equipment. Layout perforating guns. Held Prejob Safety Meeting to review work permit, hazards, and operational plan. Armed perforating gun and picked up into lubricator. MU lubricator and opened well. SIWHP was 1465 psi (nitrogen). RI H with 1.1' of 2.63" OD rollers, 22' of 2.5" OD perforating guns (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 0.9' rollers, two 6' of 2.185" OD wieght bars, CCL, adapter head, and rope socket on Welltec 0.32" wireline. 0.50 PERF WLNC CMPPRF RIH to 17380' MD and made correlation tie-in up to marker joint at Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors Hours C d Sub Ph o e'Eode ase 4/6/2004 07:00 - 07:30 07:30 - 11 :00 11 :00 - 12:30 12:30 - 15:00 15:00 - 16:30 16:30 - 18:00 1.50 PERF WLNC CMPPRF 18:00 - 18:30 0.50 PERF WLNC CMPPRF 18:30 - 19:00 0.50 PERF RURD CMPPRF 4/7/2004 06:30 - 07:00 0.50 PERF RURD CMPPRF 07:00 - 07:30 0.50 SAFETY SMTG CMPPRF 07:30 - 08:00 0.50 PERF RURD CMPPRF 08:00 - 11 :30 3.50 PERF WLNC CMPPRF 11 :30 - 14:00 14:00 - 16:30 2.50 PERF WLNC CMPPRF 16:30 - 17:30 1.00 PERF WLNC CMPPRF 17:30 - 18:30 1.00 PERF RURD CMPPRF 4/8/2004 06:30 - 07:00 0.50 PERF RURD CMPPRF 07:00 - 07:30 0.50 SAFETY SMTG CMPPRF 07:30 - 08:00 0.50 PERF WLNC CMPPRF 08:00 - 10:00 2.00 PERF WLNC CMPPRF 10:00 - 10:30 Spud Date: 10/14/2003 End: Group: Start: 3/4/2004 Rig Release: Rig Number: 273E Description of Operatio Pr¡ nted: 513/2005 8: 13:29 AM e e \/" ?'~'J~i Marathon Oil Company Operations Summary Report 0.50 PERF WLNC CMPPRF 16880-16886' MD. Started RIH to make second pass but set down at 16986' MD. When set down, trapped torque turned top shieve which wrapped wireline between shieve and top of grease head on lubricator. 1.00 PERF WLNC CMPPRF Spent one hour unwrapping wireline. POOH about 200' to inspect wireline. 0.50 PERF WLNC CMPPRF Discovered damaged wireline (one foot section about 150' above 16986' MD. Armor strands overlapped but not broken). Appears that trapped torque and line compression opened up the armor and this section was most likely damaged while entering the grease flow tubes. Could not repair cable. Marked damaged spot with spray paint. 1.50 PERF WLNC CMPPRF POOH with live perforating gun. Reviewed procedure to handle and disarm armed perforating gun while POOH. Made preparations to haul out a reel of Schumberger 0.23" wireline. 4.00 PERF WLNC CMPPRF LD and disarmed perforating guns. Changed out reel of damaged WellTec 0.32" wire for reel of Schlumberger 0.23" wire. Changed out WL valve and flow tubes to accomodate new wireline. Rebuilt control head. Start equipment. Attempt to calibrate strain gauge for 0.23 wire. Strain gauge damaged. Order out replacement. SIWHP = 1430 psi (nitrogen). Close upper master and bleed off pressure to Halliburton. PU and MU lubricator. Held prejob Safety Meeting to review work permit, hazards, and operation plan. Pressure test lubricator, tee, and WL valve to 300 psi low and 3500 psi high with methanol using MOC methanol skid. Sled back methanol to tank. Armed perforating gun and picked up into lubricator. MU lubricator and opened well. SIWHP = 1430 psi (nitrogen). 4.50 PERF WLNC CMPPRF RIH with 1.1' of 2.63" OD rollers, 22' of 2.5" OD perforating gun (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 0.9' rollers, one 6' of 2.185" OD weight bars, CCL, adapter head, and rope socket on 0.23" wireline. 1.00 PERF WLNC CMPPRF RIH to 17380' MD and made correlation tie-in up to marker joint at 16880-16886' MD. Make depth correction and pull confirmation strip up to marker joint. Perforate Tyonek 17280' - 17300' with 1427 psi surface nitrogen pressure (Perf@ 15:55). Good indication guns fired. Pull guns uphole immediately after firing. No pressure response after perforating. POOH with perforating gun. Sled off 1450 psi lubricator pressure through vent stack. LD perforating gun. All shots fired and round. Left well open to SPIDR and Barton gauges with 1410 psi. Start equipment. Held prejob Safety Meeting to review work permit, hazards, and operation plan. SIWHP = 1409 psi (nitrogen). Close upper master and bleed off pressure to Halliburton. PU and MU lubricator. Armed perforating gun and picked up into lubricator. MU lubricator and opened well. SIWHP = 1409 psi (nitrogen). RIH with 1.1' of 2.63" OD rollers, 22' of 2.5" OD perforating gun (16' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 0.9' rollers, one 6' of 2.185" OD weight bars, CCL, adapter head, and rope socket on 0.23" wireline. Note: Encountered difficulty working gun assembly past 10324'. Work Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors - To Hours Sub Phase Code 4/8/2004 10:00 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 13:30 13:30 - 17:30 4/9/2004 07:00 - 08:00 1.00 PERF RURD CMPPRF 08:00 - 08:30 0.50 PERF RURD CMPPRF 08:30 - 09:00 0.50 PERF WLNC CMPPRF 09:00 - 09:30 0.50 SAFETY SMTG CMPPRF 09:30 - 10:30 1.00 PERF WLNC CMPPRF 10:30 - 15:00 15:00 - 16:00 16:00 - 17:30 1.50 PERF WLNC CMPPRF 17:30 - 18:30 1.00 PERF RURD CMPPRF 4/10/2004 06:45 - 07:15 0.50 PERF RURD CMPPRF 07:15 - 07:30 0.25 SAFETY SMTG CMPPRF 07:30 - 07:45 0.25 PERF WLNC CMPPRF 07:45 - 08:00 0.25 PERF WLNC CMPPRF 08:00 - 15:00 7.00 PERF WLNC CMPPRF Start: 3/4/2004 Rig Release: Rig Number: 273E Spud Date: 10/14/2003 End: Group: Printed: 5/3/2005 8:13:29 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Marathon Oil Company KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors 4/10/2004 08:00 - 15:00 15:00 - 16:20 Code 7.00 PERF 1.33 PERF WLNC CMPPRF WLNC CMPPRF 16:20 - 18:00 1.67 PERF WLNC CMPPRF 18:00 - 18:30 0.50 PERF RURD CMPPRF 18:30 - 19:30 1.00 FLOW WELL CMPFLW 19:30 - 20:30 1.00 FLOW WELL CMPFLW 20:30 - 23:00 2.50 FLOW WELL CMPFLW 23:00 - 06:00 7.00 MONITR MNwL CMPFLW 4/15/2004 07:00 - 08:00 1.00 LOG CSGD OTHER 08:00 - 08:30 0.50 LOG CSGD OTHER 08:30 - 09:00 0.50 LOG CSGD OTHER 09:00 - 09:15 0.25 LOG CSGD OTHER 09:15 - 09:45 0.50 LOG CSGD OTHER 09:45 - 16:45 7.00 LOG CSGD OTHER 16:45 - 17:30 0.75 LOG CSGD OTHER 17:30 - 19:05 19:05 - 19:25 1.58 LOG CSGD OTHER 0.33 LOG CSGD OTHER Spud Date: 10/14/2003 End: Group: Start: 3/4/2004 Rig Release: Rig Number: 273E Description of Operations approx 2 hrs before gun would pass. RIH to 16950" MD and made correlation tie-in. Make depth correction and pull confirmation strips. Note: Prior to firing guns, opened WV to closed valve at test sep in order to monitor perf event on Barton gauge. Valve cracked at Halliburton and lost approx 154 psi (SIWHP dropped from 1410 psi to 1255 psi before caught). Perforate Tyonek 16438' - 16454' with 1255 psi surface nitrogen pressure (Perf @ -16:20). Good indication guns fired. Pull guns uphole immediately after firing. No pressure response after perforating. POOH with perforating gun. Bled off 1240 psi lubricator pressure through vent stack. LD perforating gun. All shots fired and round. Left well open to SPIDR and Barton gauges with 1240 psi. Blow well down on 14/64" var ck to 900 psi WHP. SI & monitor. No inflow. Blow well down on 14/64" var ck to 700 psi WHP. SI & monitor. No inflow. Blow well down on var ck to 0 psi WHP (10 psi on Barton guage). SI well and left well open to SPDR and Barton gauges. Note: All blow down gas has been 0.9 sp gr nitrogen by Ranarex flow stream monitor. Monitor well pressure BU overnight. SIWHP = 14 psi @ 0600 on Barton gauge. MI and spot Schlumberger ElL equipment. Held Prejob Safety Meeting to review work permit, hazards, and operation plan. RU Schlumberger wireline to run PL T. Removed tree cap flange and installed 3-1/8" 5K x 6-1/2" Otis crescent flange. MU lubricator and pulled Gun GRlCCL thru lubricator. MU flow tee, WL valve, and lubricator to flange connection. PU Schlumberger GRlCCUPL T tool and pulled into lubricator. MU lubricator to wellhead. Pressure test lubricator, tee, and WL valve to 2000 psi with methanol using MOC methanol skid. Bled back methanol to tank. RIH with PL T (PSPT-NB) tool logging temperature and pressure to 17430'. Surface pressureltemp measured by Schlumberger was 59 psia I 43 F and 40 psi I 43 F on Barton Gauge. Correlate PL T log to Reeves CBL. Made 3 logging passes across perfs 17280' - 17320' at various CCL gain settings. CCL shows perfs correctly aligned across GR sand response. Note: Could not get deep enough to see deepest perfs 17,385' - 17409' due to length of PL T tool string. Recorded 5 min stops in water leg as follows: 17:33: 17400': 596.58 psia 1167.3 F. Recorded 1hr 15 min stop in water leg as follows: 17:45: 17280': 558.36 psia 1166.2 F. 19:00: 17280': 559.86 psia 1166.3 F. Recorded 5 min stop in water leg as follows: 19:05: 16700': 332.77 psi a 1157.3 F. Made logging pass across perfs 16438' - 16454'. CCL shows perfs correctly aligned across GR sand response. Printed: 5/3/2005 8:13:29 AM · I e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors Start: 3/4/2004 Rig Release: Rig Number: 273E Description ofOperéitiôns Spud Date: 10/14/2003 End: Group: 4/15/2004 19:25 - 00:00 4.58 LOG 00:30 - 01 :30 1.00 LOG CSGD OTHER Recorded 5 min stop in water leg as follows: 19:25: 16200': 136.75 psia /151.6 F. Logged Water Contact at 16,022'. Recorded 5 min stops in gas column as follows: 19:33: 15920': 69.22 psia 1149.9 F. 19:41: 15740': 69.21 psia/149.1 F. 20:20: 12000': 66.40 psia 1124.3 F. 20:45: 8000': 64.20 psia 1108.5 F. 21 :30: 4000': 61.50 psia I 86.5 F. 23:45: Recorded 15 min stop at Surface: Final surface pressure I temp measured by Schlumberger was 59.50 psia I 43.5 F and 40 psi I 46 F on Barton guage. CSGD OTHER Closed master valve and bled off lubricator. LD lubricator and PL T tools. ND WL valve and flow tee. RD Schlumberger. CSGD OTHER Closed master valves and bled off lubricator. LD lubricator and PL T tools. ND WL valve and flow tee. RD Schlumberger and prep to move out. Secure well and proceed with pressure monitoring as follows: KS#1 L 1: Monitor with SPDR and Barton gauges. KS#1 rd: Monitor with Data Trap gauge. 00:00 - 00:30 0.50 LOG Printed: 5/3/2005 8:13:29 AM ~ Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 · Alaska.ess Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 April 22, 2004 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 Delivered by Courier RE: Marathon Oil Company CONFIDENTIAL Well Sa!llP~ ~( '3 c Marathon Cannery Loop No: 7 :2- u3 - f/(~ '> '1 Marathon Paxton No. 1 .2.0 '-1- 0 rð f J Marathon Falls Creek No.4 J () 3 - ~.l ! ::Ii ( J Marathon Kasilof South No.IRDJ.o 1. - :l \~<,. :;:t 1\;' 0 Marathon Kasilof South No. LlL ?J:\;). - :( \-ì -:ì! \ l ~ \ The following CONFIDENTIAL well samples are being forwarded to AOGCC as shown on the attached listi. When the samples have arrived, please confirm your receipt by signing one copy of this letter and returning to my attention at the letterhead address. Thank you, Kaynell Zeman Technical Assistant 1)/ f, ! Re,,;vedby AH--w'-Ni ()~ Date: d )~ A-r ~ "-l ,..- / .;- r;..( t l£yr-\ . Marathon Kasilof South No. lrd (KAS lrd) AND Marathon Kasilof South No. LlL (KAS LIL) (lateral portion) KasilofUnit, Cook Inlet, Alaska Sec. 28, T-3-N, R-12-W, Seward Meridian v ^ ~ 1.-,.1 A PI iJ.. <;on1?O'i20000 a. ,,_-v I J. ',J-rJ I LG.t\ Kasilof #LIL (lateral) Well Samples 10,580 11 ,220 lA 11,220 12,080 2A 12,080 12,760 3A 12,760 13,660 4A 13,660 14,520 5A 14,520 15,400 6A 15,400 16,400 7A 16,400 17,160 8A 17,160 17,665 9A )..~ ~ - ;t \" 1 . Page 3 CONFIDENTIAL CONFIDENTIAL tf ' I::' l . Formation Tops: Formation Sterling Beluga Tyonek T-1 Tyonek T-2 Tyonek T-3 TD Depth (MD) Depth (TVD) N/A N/A "-¿'ùl.. -is 1 . Kasilof South #1 L 1 (Lateral-North Taraet) Kasilof Field 520'FSL,1340'FVVL, Sec. 28, T3N, R12VV, SM ~ J L Conductor 20" K-55 Top O'MD 133 ppf PE Bottom 130' MD 130' TVD Surface Casina 13-3/8" K-55 Top O'MD 68 ppf BTC Bottom 2860' MD 2383' TVD 16" hole with +/- 750 sks 12 ppg cement Dual 3-1/2" GT Packer@ 9853' MD/5161' TVD. Intermediate Casina 9-5/8" 40 and 47 ppf 40 ppf L-80 Top 0' MD BTC Bottom 9916' MD 5186' TVD BTC From 2729' MD to 9677' MD 7" 29 ppf L-80 Top Bottom NV 10533' MD 9916' MD 5432' TVD 5186' TVD 12-114" hole with +/- 1550 sks 12.7 ppg + 650 sks 15.7 ppg Proposed Tvonek Perfs: 17386·17410,24 ft (4401 psi @ 9761' TVD) 17280-17320,40 ft (4422 psi @ 9678' TVD) 16444-16474,30 ft (4422 psi @ 8913' TVD) 15670-15711,41 ft (4422 psi @ 8220' TVD) 15344-15404,60 ft (4422 psi @ 7947' TVD) 15209-15234,25 ft (4422 psi @ 7802' TVD) 15124-15190,66 ft (4422 psi @ 7765' TVD) 15064-15075,11 ft (4422 psi @ 7671' TVD) 14896-14916,20 ft (4422 psi @ 7545' TVD) 14863-14878,15 ft (4422 psi @ 7516' TVD) Liner 3-1/2" L-80 Top 9918' MD 9.2 ppf Hydril563 Bottom 17644' MD 6-1/8" hole with +/- 700 sks. 12.7 ppg cement. TD: 17,665' MD / 9999' TVD 5187' TVD 9980' TVD · Alaska .ess Unit '"' Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 29, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 West yth Ave Anchorage, Alaska 99501 Reference: Kasilof South # 1 L 1 Dear Mr. Aubert: Enclosed is the Application for Sundry Approval for change of depth for Kasilof South #1 L 1. If you need additional information, I can be reached at 907-564-6319 or pkberga@marathonoil.com. Sincerely, Ø(~ Peter K. Berga Drilling Superintendent Enclosure bjv o :\Permanent\ Wellrpts\KS#1 \aogccclt.doc . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISS I APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 WG,Æ LIs 0 I U>tJ 3 O'7-S ~2{3'/3 1. Type of Request: Annular DisposalD Abandonc=J Suspend Well e=] Operation Shutdown D Perforate D Variance e=] Alter Casing c=J Repair Welle=] Plug Perforations D StimulateD Time Extension e=] OtherD Change Approved Program Q:J Pull TUbinge=] Perforate New Pool D Re-enter Suspended Welle=] 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company Deve,opmentB EXPloratOry~ 202-257 ,/ 3. Add ress: Stra~graphic Service 6. API Number: / P.O .Box 196168, Anchorage, AK 99519-6168 50- 133 20520-60 7. KB Elevation (ft): 9. Well name and number: 115' Kasilof South #1 L 1 8. Property Designation: 10. Field/Pools(s): ADL 384534,384529,389502 Wildcat 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft.) Total Depth TVD (ft): ¡Effective Depth MD (ft): I Effective Depth TVD (ft): Plug (measured): Junk (measured): 17,665' 10000' OH OH Casing Length Size MD TVD Burst Collapse Structural Conductor 130 20" 133" 130 130 1200 (80%) 2448 (80%) Surface 2680 13 3/8" 68 K-55 2680 2297 2760 (80%) 1560 (80%) Intermediate 9904 95/8 40 & 47 L-80 9902 5177 4600 (80%) 2472 (80%) Production 632' 7 29" L-80 10,533 5432 6528 (80%) 5616 (80%) Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: ITubing Grade: ¡Tubing MD (ft.): Packers and SSSV Type: Packers and SSSV MD (ft): RECEIVED 12. Attachments: Description Summary of Proposal 9 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch Exploratory 0 Development ~ 2 Çseooõ=J .-' 14. Estimated Date for 15. Well Status after proposed workAiækaOi~SCons.Commíaalon Commencing Operations: 12/27/2003 / Oil D Gas [TI Plugged ., dtorage Abandoned D . 16. Verbal Approval Date:12/27/2003 / WAG D GINJD WINJD WDSPL D Commission Representative Mr. Winton Aubert 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Peter K. Berga Title Drilling Superintendent Signature ø~ Phone 9P7. .)~'I. '3/' Date 12/29/03 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ¡Sundry Number: 9-;0 1;., ~q I Plug Integrity D BOP Test D Mechanical Integrity Test c=J Location Clearance D Other: Subsequent Form Requested: (·--..tp- '-I 0 7 f?/š/ /~ ~'I ~) , BY ORDER OF Approved by: -----~-+ .. J ..-k/G~ COMMISSIONER THE COMMISSION Date: -. \ ".~. , Form 10-403 Revised 2/2003 fØ)MS 8ri\.. JAM \) 7 lU~ Submit in duplicate '" Pt. Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 Projection ~1f 1fŒ (fir !Æ~!Æ~æ!Æ l' A. I,ASIiA. OIL Alft) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR S. S. Lambe Senior Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage Alaska 99519 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KasilofSouth #lLl Marathon Oil Company Permit No: 202-257 Surface Location: 520' FSL, 1340' FWL, Sec. 28, T3N, R12W, SM Bottomhole Location: 2037' FSL, 1106' FWL, Sec. 19, T3N, R12W, SM Dear Mr. Lambe: Enclosed is the approved application for permit to drill the above referenced exploration 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the 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. The permit is for a new wellbore segment of existing well Kasilof South 1, Permit No 202-256, API 50- 133-20520-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ ·/7 ~~ Randy Ruedrich . \ Commissioner . BY ORDER OF THE COMMISSION DATED this2..'f day of June, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section e . Alaska Business Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561·5311 Fax 907/564-6489 December 27, 2002 Cammy Oechsli AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mrs. Oechsli: Attached is the Permit to Drill for Well Number Kasilof South #1 L 1, and the accompanying schematics and procedure. Kasilof South #L 1 is a lateral to be drilled from Kasilof South #1 with a spud date of November 15th, 2003. Kasilof South #1 L 1 will be drilled targeting the Beluga and Tyonek Reservoirs in Kasilof Field. Due to the complexity of the well, I am proposing to come across and introduce both Kasilof South #1 and Kasilof South #1 L 1. I believe the meeting would clarify a lot of technical issues that are difficult to capture in the permitting program. If you feel the meeting can add value, please let me know and I will come to your office. If you would like any other information, please contact me at 564-6332 or sslambe@marathonoil.com. Sincerely, Ji ~ ~,«,.,>" """'~'_"W""W"""'~"""'" ,,/ .,.., "'." "".."...' '.¿"'/? Steven S. Lambe Drilling Engineer Enclosure ssl RECEJ\!ED Df.t.]Ð 1NL Alaska 011 Ò"jJí¡~í~lºn Ar¡c~,;(Þ( a,;-e g:lcmnldrlglsterl i nglsu44-1 0IAOGCCPTDKS#1 .xls .. STATE OF ALASKA . ALAS.IL AND GAS CONSERVATION COMMI.., DN PERMIT TO DRILL 210 MC 25.005 ¡¡J 1a. Type of Work Drill [8] Re-Drill D 1b. Type of well. Exploratory0 Stratigraphic TestD Development Oil D Re-EntryD Deepen D serviceD Development Gas D Single ZoneD Multiple Zone [8] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 115 KB feet Wildcat 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 ADL-384534, 384529, 389502 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 MC 25.025) 520'FSL, 1340'FWL, Sec. 28, T3N, R12W, S.M. Kasilof Exploration Unit Blanket Surety At top of Productive Interval 8. Well Number / Number 584'FNL, 170TFEL, Sec. 30, T3N, R12W, S.M. Kasilof South #1 L 1 5194234 At Total Depth 9. Approximate Spud Date Amount 203TFSL, 1106'FWL, Sec. 19, T3N, R12W, S.M. 11/15/03 , $200,000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) Property Une(unit boundary) / / 4,700' feet 3000 feet 16260 16,804' MD / 9,300' TVD feet 16. To be Completed for Deviated Wells 17. Anticipated Pressure (see 20 MC 25.035 (e) (2») Kickoff Depth 500 feet Maximum Hole Angle 66 " Maximum Surface /' 3089 psig at Total Depth (TVD) 9300 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement (J " Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 PE +/-120' 0' 0' +1-120' +/-120' Proposed / Existing ~ ~ 13 3/8" 68 L-80 BTC 2700' 0' 0' 2700' 2245 Proposed I Existing 12 1/4" 9-5/8x7x7 47,40, 26 L-80 Hydril 563 10500 0' 0' 10500 5400 Proposed I Existing 6-1/8" 31/2" 9.3 L-80 Hydril 563 6932 10110 5260 16804 9300 675 sx /' The Kasilof South #1 L 1 will be direction ally drilled to an estimated total depth of 16804' md, 9300' tvd from Kasilof South #1 at a measured depth of 10,125'. Kasiof South #1 is a proposed well on an existing pad located at mile 4.2 Coho Loop Road. The drilling rig currently being evaluated is Nabors Rig #273. The Well will be the first leg from the Mother Bore in a TAML level #6 Multi-lateral Well. This is the Second of two Permit to Drill programs. Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing, Blowout Prevention Equipment drawings, Completion Schematic. 20. Attachments Filing Fee[8] Property Plat[8] BOP Sketch[8] Diverter Sketch [8] Drilling Program [8] Drilling Fluid Program 0 Time vs Depth PlotD Refraction AnalysiSD Seabed ReportD 20 AAC 25.050 ReqUirementsD 21_ I '"eby œrt;fy th,1 the ¡"'ego;o, Æ """'ct 10?2' of my koowled,e ___~ 564-6332 Signed S. S. Lambe Title Senior Drilling Engineer Date 12/27/2002 Commissìõl1 Use Only Permit Number IAPI Number APprovall,72-f//t. ~;~r~t~rr- " --- 202-- :7-57 50-/.:3:3 ~.2D52D-Cø6 b:J r tel s ~ 9LIJ' Conditions of Approval Samples Required DYes 0NO Mud Log Required [XJYes DNo Hydrogen Sulfide Measures DYes ~NO Directional Survey Required [K Yes DNO DEC J 0 2002 Required Working Pressure for BOPE D2M D3M D5M D10M D15M Other: I-\Iaska Oil & Gas Cons. Commission Anchorage ~ /.A ~ by order of ¿/~/ð1 Approved by 7" J Commissioner the Commission Date Form 10-401 Rev. 12·1·85 / " : Submit in Triplicate --..... Marathon Oil Company Alaska Region . pre.d By: Approved By: Date: S.S. Lambe 12/27/02 Drilling Program Well: Kasilof South #1 L 1 AFE: To be AssiQned Area: Kasilof Drilling Contractor: Nabors DrillinQ - Tenative Rig: Nabor's 273 Geologic Program Depth Target Locations FSL FWL Block MD TVD Tolerance Surface 520' 1340' Sec. 28, T3N, R12W, SM 35' RKB 35' RKB Beluga Entry 4,176' 8,327' Coordinates from Wellhead 11,686' 5,900' North West Tyonek Entry 5,275' 9,529' Coordinates from Wellhead 13,505' 6,700' North West Bottom Hole 6,783' 10,794' Coordinates from Wellhead 16,804' 9,300' North West RKB Elevation: RKB to MSL 115'. GL to MSL 80' Total Depth: TVD 9.300' MD 16.804' Max. Angle None Anticipated / None Anticipated / 66.00 Course 320.00 Abnormal Pressures: Subnormal Pressures: Coring and DST's: Cased hole test in Tyonek post riQ completion. No CorinQ Mud Logging: Contractor: Epoch Start Depth: Junction Point @ 10.125' MD Services: Basic with GCA. shale density. temperature in and out, sample collection. 10' samples below Intermediate Logging Program: Contractor: Sperry for LWD. Schlumberqer for Cased hole LOQS LWD Wireline Logs Production Quad Combo Cement Mapping Tool, Possible FMI, Possible CMR Kasilof South #1 L1 Drilling prograrnpage 1 of 9 Drilling Program Summary . e Production: PU and RIH Leg #2 Drilling Diverter. Set in Junction @ 10,100'. POOH and LD Running Tool. MU and RIH 6-1/8" Drilling BHA. Drill float equipment and 20' - 25' of new hole with 6-1/8" Bit. CBU. Test shoe to leak off (17 ppg anticipated). Drill ahead 6-1/8" on 320 degree Azimuth to 16,804' per attached directional program. At TD, condition hole and trip for LWD. MWD log 6- 1/8" hole section. If required by geologist, DP convey CMR & FMI. Run and Cement 3-1/2" liner. Dress PBR. Pull Leg #2 Drilling Diverter. Displace hole to Inhibited brine. Run Completion. Casing Program API Values Casing Casing Hole Size Size Set Set To Weight Casing Conn (in) Burst Collapse Tension (in) From (MD) (ppf) Grade Type (psi) (psi) (K Ibs) (MD) 13-3/8" 0' 2700' 68 L-80 BTC 17-1/2" 5,020 2,270 1,556 9-5/8" x 7" 0' 10,125' 40 & 47 L-80 H-563 12-1/4" 5,750 3,090 979 3 1/2" 10,110' 16,804' 9.3 L-80 r H-563 ,/ 6-1/8" 10,160 10,530 202 Make sure 7" casing float equipment is PDC drillable. All tubulars are new. Casing Design Fracture Formation Casing Casing Setting Gradient Pressure at Design Factors Size Weight Casing Depth at Shoe Shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 13-3/8" 68 L-80 2245' 15.5 8.6 1668 3.07 2.09 3.72 9-5/8" 40 & 47 L-80 5265' 17.0 8.6 2032 1.88 1.16 2.99 3 1/2" 9.3 L-80 9300' 15.0 8.6 3089 3.67 2.27 1.67 /' Kasilof South #1 L1 Drilling programpage 2 of 9 · e Directional Program Turn: 10.125' MD Direction: 295 Gyro Co: Build Rate: 3.0 To: 66 deQ @ 2245' TVD Turn Rate: 1.5 To: 320 Az @ 6700' TVD Drop Rate: 1.5 To: 30 deQ @ 7.980' TVD Directional Co: Baker Huqhes INTEQ KOP: 500' Direction: 295 Drop Depth: 12.659' MDI 6.294' TVD Gyro Survey Required: Magnetic Multishots Required: General Calculation of Maximum Anticipated Suñace Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. Suñace Casing @ 2245' TVD MASP = (FG + SF) * 0.052 * TVDs - (GG * TVDs) MASP = (15.5 + 1.0) * 0.052 * 2245' - (0.115 * 2245') MASP = 1668 psi Intermediate @ 5265' TVD / MASP = «PP * .052 * TVDtd) - (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd)) MASP = (8.6 * 0.052 * 9300) - (0.3 * 0.052 * 9.5 * 9300) - (0.7 * 0.115 * 9300)) MASP = 2032 psi Production @ 9300' TVD MASP = P~l 0.052 * TVDf - (GG * TVDf) MASP = 8.6 * 0.05:; 9300' - (0.115 * 9300') MASP = 3089 psi Kasilof South #1 L1 Drilling programpage 3 of 9 Cementing Program Production Liner Size: 3 1/2" Tail Slurry: Top of Cement: Specifications: Compress Strength: Total Volume: . Contractor: BJ Services e Setting Depth: 16,804' MD/ 9300' TVD Annular Volume 10125' to 16804' with 6" gauge hole: 922 ft3 Density:~ ppg, Yield:~ ft3/SX'~sx, cf: 1205 ft3 10500'MD/ 5400' TVD Class G + additives Mixed w/ fresh water psi in hrs psi in hrs, 1205 ft3, ~% Open Hole Excess, WOC Time: 10 hrs Note: Standard policy is to pump a minimum of 50% excess without a caliper log and 25% excess with a caliper log. Kasilof South #1 L1 Drilling programpage 4 of 9 - e Diverter and BOP Program The blowout preventer stack will consist of a 135/8",5000 psi annular, a 135/8",5000 psi double ram preventer with blind rams on bottom and pipe rams on top, a 135/8",5000 psi drilling spool (mud cross) with 3 1/8",5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 31/8",5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas separator. Casing Casing Test Low/High Size MASP Test BOPS (psi) Casing (in) (psi) (psi) Size & Rating Production 3~" 3089 2700 (1) 13-5/8" 5M Annular 25013500 Liner (9.S ppg (1) 13-5/8" 5M Blind ram 25013500 mud) (2) 13-5/8" 5M Pipe ram 25013500 ./ Casing Test Pressure Calculations 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 or (3) AOGCC requirements. 3 %" Production Liner at 9300' TVD CTPMASP = 2658 psi Test to 2700 psi CTPBurst = 10160 * 0.7 - «9.8-8.3) * 0.052 * 9300) = 6387 psi Kasilof South #1 L1 Drilling programpage 5 of 9 e e Mud Program Contractor: MI Drilling Fluids Interval (MD) Mud Weight From To (ppg) Water Loss Mud Type 10,125' 16,804' 9.0 -9.8 / 8 - 10 Flo Pro with Lubricant See attached mud program. Chlorides must stay below 30,000 ppm. Corrosion inhibitor to be used at all times. Use lubetex as needed for torque and drag reduction. Wellhead Program Manufacturer ABB Vetco Gray Model MB 196 Split Multi-bowl System 13-5/8" 5M system Tubing Head 13-5/8" 3M X 13-5/8" 5M Tubing Hanger 13-5/8" x 3-1/2" x 3-1/2" Split dual Hangers Detailed Drilling Procedure Formation Leak off Test 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 drill pipe 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. Kasilof South #1 L1 Drilling programpage 6 of 9 e e Bit Program The following guidelines are recommended for use on this well. Actual drilling conditions and dull grading should be used to select the proper bit for the next interval. Interval Bit Size IADC WOB RPM (MD) (in) Bit Model Code (k Ibs) 10,125' - 16,804' 6-1/8" TBD Drill String Item Ppf Makeup Torque Max Pull - Premium 3 %" HWDP, 3 Y:tlF 24.4 12,000-13,200 ft.-Ibs. 248,400 Ibs. 4", S-135, HT 38 15.53 13,500-19,800 ft.-Ibs. 403,500 Ibs. 5" S-135, 5W' FH 23.4 36,242 ft.-Ibs. 712,070 Ibs. ./ Hydraulics Program Rig mud pumps available are shown below. Size liners according to hole size. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model (in) (in) (97% eft) (spm) National 12-P-160 6" 12" 4670 4.275 140 National 12-P-160 6%" 12" 3980 5.016 140 National 12-P-160 7" 12" 3430 5.820 140 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Rate Standpipe Nozzle Depth Hole Size (gpm) Pressure AV ECD Size (MD) (in) (psi) (fpm) (ppç ) (32"s) Remarks 16804' 6 1/8" 350 2550 398 12.3 TFA=1.22 RST Drilling Kasilof South #1 L1 Drilling programpage 7 of 9 · e OPERATIONAL PROCEDURE: KASILOF SOUTH #1~!I:f-ILLlNG PROGRAM. 1. PU leg #2 Drilling6ive~ on FJD running tool. RIH and set Leg #2 diverter. Verify setting and POOH. (~~/" 2. LD FJD running tool. 3. MU & RIH Leg #2 Drilling BHA. Drill out Shoe + 25' of New Hole. Perform LOT. Displace hole over to a new 9.5 ppg FLO-PRO mud system. 4. Drill ahead t<¡9D, 9,300' TVD, 320" Azimuth as per the directional plan. 5. Note: Watch for cuttings beds in the 9-5/8" by DP annulus. When Pulling OOH, circulate and Rotate above junction to clear cuttings from 9-5/8" casing. 6. NOTE: TD will be called 200' below last gas shows from mud loggers 7. At TD, Circulate Hole clean & POOH. LD Drilling BHA. If required, DP convey CMR, then FMI. 8. PU Quad Combo LWD RIH to TD. Start logging out @ 90'/hr rotating @ 30 rpm to the Top of Gas or Junction. RIH to TD and condition for the Liner. 9. Fluid caliper OH with Carbide for Liner Cementing operations 10. POOH & LD/RD LWD equipment. 11. MU Shoe Track of Float Shoe, 2 jnts, Float Collar, 2 joints, Landing Collar. 12. RIH on xxx joints of 3-1/2",9.3#, L-80, Hydril563, Range 3 casing. Plan 40' stand off from bottom and hanger @ Leg # 2 No-Go 10,125'. ../' 13. MU shortened ZXP Liner Hanger/Packer, Run,ning Tool on 5" DP. 14. RIH with Liner and Tag NO-GO in base of leg #2. PU to neutral weight. Drop Ball and set liner hanger. Circulate and Condition hole while rotating prior to~e enting. 15. Pump pre-flush, Sure-Bond I (LCM), Water Spacer, and((//nnular volumes of 12.5 ppg high / strength (Ninilchik Recipe) cement. Displace with 2#/BBL Flo-Pro Gel pill. 16. Bump plug and Set packer. PU and reverse circulate excess cement. 17. POH and Lay down Cementing BHA. 18. WOC. PU and RIH PBR polishing mill with 20' extension for cleaning out top 3-1/2". 20. Close bag and Test TOL to 1500 psi. Displace /~hibited brine. POOH & LD BHA. / ) MU FJD pulling tool. RIH and pull leg #2 dril1ing Div~r. POOH LD DP & BHA. ....// \'__><p'o""''''''-"" Kasilof South #1 L1 Drilling programpage 8 of 9 19. KASILOF SOUTH #1 and .SILOF SOUTH #1 L 1 e COMPLETION PROGRAM. 21. RU dual handling equipment. 22. PU Seals, DSM, and GT packer per attached diagram. 23. RIH wI Dual 3-1/2" Tubing to 2,500' from surface. 24. MU chemical injection mandrels spaced 2 joints apart attaching ~" SS control line with bands. 25. Continue RIH with completion and lightly tag DSM on Alignment lug. 26. PU and Space out Tubing Hangers. 27. RIH and shear latch from DSM. Land completion. 28. / Pressure down leg #1 and #2 to ensure seals are engaged. Hydraulically set GT packer against glass disk in leg #1. 29. Terminate Control lines, Set BPVs. 30. ND BOP's & NU Dual Tree And Test. 31. Release Rig. Kasilof South #1 L1 Drilling programpage 9 of 9 0 800 1600 ~ 2400 +- Q) Q) '+- '-" 3200 .!: +- Q.. Q) 4000 0 0 4800 () +- L Q) > 5600 Q) :J L 6400 l- I V 7200 8000 8800 9600 ¡Created by Sutherland For: S Lambe ¡ Dote plotted : 21 -Oct - 2002 I Plot Reference is KS# 1 (MB) Version #3. Coordinates ore in feet reference slot #KS1. I""' "",,,, ~:!f.",."œ '0< <œ. ~ +0 20 Conductor c:F' C)" 0) C)~C) ,'"Y C)C) '")," C)C) OLS: 3.00 deg per 100 It r0 . C)C) ,,:>":>' C)0 b<'"),' C)C) !0 , . Cj C)C) "o~~",. 13 3/8 Casing ~ End of Curve TANGENT ANGLE 66.00 DEG o 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 12800 13600 14400 Vertical Section (feet) -> MARATHON Oil company I Structure: KasHof Well: KS#1 I L-~~XPIO:~___~:fion : Kena~~:ins~. Alaska I <- West (feet) 6000 5000 4000 3000 1000 13000 12000 11000 10000 9000 8000 7000 2000 ú' 84 ~o ,,-\ '0 ~'\. '0 ,,~ 00" 0 <0 <0 . ,,'" ". ~::...Ò " ~ 0 ~...., <1~ '" , ,>-0 0;-0 '0 nO'.... 0" '<,. ,<,-\ G 0" \ v <;), " ",-1 \. ..~ " ",-\-:- ". 0\ "., Ò 0 <v".",.::t 'Jv , ") Ò" <V" '0°..... ,6:: ,,'0 <v".. è;-v 0\. ,,'0 ¿:;.-e:- 00' ',<0 Ò 0.... '" v 270.00 AZ··.. <V" "\ G°,y'...{)Cò "'~ ~ 0 8~~~Ü) <ç0": ",' <;),0 :'0-\ :'0-\ ::...ò~ èt 0" 0\ <V" <v"..(-.O 0" \'t Ò èt ° 0\ '" -\ ". <V" 0" ::",vo; Ò ") '" -\ ~p <V" -2[}fj '°0 4.2' Ò o.,ò' . ,,-^'(' 0.... \. GO ° "\ "Ò ~ ~ ~~ ~0~' . to. ° ,,:>0 . ,,'0 "G 0.... 'Jv GO ¿;. \Cò 0' Ý) ~ Ü) .)v :0 ~v 13 3/8 Casing ~ End of Curve po.::. 20 Conductor Entry T yonek 65.62 . 61.07 6602 Tyonek Entry Begin Drop Entry 56.68 ','0 60.83 51.00 ", 54.83 46.50·\, 50.33 42.00, 45,83 37.50 \ 41.33 33.00" 36.83 End of Drop 30.00 \ 32.33 \ 29.96 End of Drop DLS: 1.50 deg per 1 DO ft OLS: 1.50 deg per 100 ft \ \ Tyonek Bose 3 1/2 Liner Tyonek Base 3 1/2 Liner Azimuth 289.88 with reference 0.00 N, 0.00 E from slot #KS1 o 7000 6000 5000 - I 4000 Z 0 ..... - ::y 3000 ~ - CD CD - 2000 '-" 1000 0 e e e MARATHON Oil Company Kasilof KSIL2 slot #KSl Exploration Kenai Peninsula, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License KS#l L2 Version #3 prop5285 Date printed Date created Last revised 21-0ct·2002 28-Aug-2002 21·0ct-2002 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 248860.988,2309612.367,999.00000,N Slot location is n60 18 58.475,w151 22 39.924 Slot Grid coordinates are N 2310122.000, E 250212.001 Slot local coordinates are 537.91 N 1340.05 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e e MARATHON Oil Company PROPOSAL LISTING Page 1 Kasilof, KS1L2 Your ref KS#l L2 Version #3 Exploration, Kenai Peninsula, Alaska Last revised , 21-0ct-2002 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 10125.00 66.00 295.00 5264.76 3345.50 N 7174.45 W 0.00 7854.66 Multi-Lateral Junction 10125.01 66.00 295.00 5264.76 3345.50 N 7174.46 W 1. 50 7854.67 KOP 10200.00 65.95 296.23 5295.30 3375.11 N 7236.22 W 1. 50 7922.72 10300.00 65.90 297.87 5336.09 3416.64 N 7317.53 W 1. 50 8013.66 10400.00 65.87 299.52 5376.95 3460.46 N 7397.59 W 1. 50 8104.76 10500.00 65.85 301.16 5417.84 3506.55 N 7476.35 W 1. 50 8195.97 10600.00 65.86 302.80 5458.75 3554.88 N 7553.74 W 1. 50 8287.22 10700.00 65.88 304 .45 5499.63 3605.41 N 7629.73 W 1. 50 8378.44 10800.00 65.92 306.09 5540.47 3658.11 N 7704.26 W 1. 50 8469.58 10900.00 65.97 307.73 5581. 24 3712.95 N 7777.27 W 1. 50 8560.58 11000.00 66.05 309.37 5621. 90 3769.89 N 7848.71 W 1. 50 8651.37 11059.99 66.10 310.35 5646.23 3805.03 N 7890.80 W 1. 50 8705.71 End of Turn 11500.00 66.10 310.35 5824.52 4065.50 N 8197.36 W 0.00 9103.85 11686.30 66.10 310.35 5900.00 4175.79 N 8327.15 W 0.00 9272.43 Beluga Entry 12000.00 66.10 310.35 6027.11 4361.49 N 8545.71 W 0.00 9556.29 12500.00 66.10 310.35 6229.69 4657.48 N 8894.07 W 0.00 10008.72 12658.89 66.10 310.35 6294.07 4751.53 N 9004.77 W 0.00 10152.50 End of Hold 12700.00 65.62 310.78 6310.89 4775.93 N 9033.26 W 1. 50 10189.61 12800.00 64.47 311.85 6353.07 4835.79 N 9101.36 W 1. 50 10279.11 12900.00 63.33 312.93 6397.06 4896.32 N 9167.69 W 1. 50 10367.48 13000.00 62.20 314.03 6442.83 4957.50 N 9232.20 W 1. 50 10454.66 13100.00 61.07 315.16 6490.34 5019.28 N 9294.86 W 1. 50 10540.58 13200.00 59.96 316.31 6539.56 5081.61 N 9355.61 W 1. 50 10625.19 13300.00 58.85 317.49 6590.46 5144.46 N 9414 .43 W 1. 50 10708.42 13400.00 57.76 318.70 6643.00 5207.78 N 9471.25 W 1. 50 10790.23 13500.00 56.68 319.94 6697.15 5271. 53 N 9526.06 W 1. 50 10870.55 13505.19 56.62 320.00 6700.00 5274.85 N 9528.85 W 1. 50 10874.68 KS1 L2 . Tyonek Entry . 10/14/02 13505.21 56.62 320.00 6700.01 5274.86 N 9528.86 W 1. 50 10874.69 End of Turn/Continue Drop 13579.86 55.50 320.00 6741.69 5322.30 N 9568.67 W 1. 50 10933.64 13679.86 54.00 320.00 6799.40 5384.86 N 9621. 16 W 1. 50 11011.37 13779.86 52.50 320.00 6859.23 5446.24 N 9672.66 W 1. 50 11087.63 13879.86 51.00 320.00 6921.14 5506.39 N 9723.14 W 1. 50 11162.38 13979.86 49.50 320.00 6985.08 5565.29 N 9772.56 W 1. 50 11235.56 14079.86 48.00 320.00 7051.01 5622.88 N 9820.88 W 1. 50 11307.12 14179.86 46.50 320.00 7118.89 5679.13 N 9868.08 W 1. 50 11377.01 14279.86 45.00 320.00 7188.67 5734.00 N 9914.12 W 1. 50 11445.19 14379.86 43.50 320.00 7260.30 5787.45 N 9958.98 W 1. 50 11511.61 14479.86 42.00 320.00 7333.73 5839.45 N 10002.61 W 1. 50 11576.21 14579.86 40.50 320.00 7408.91 5889.96 N 10044.99 W 1. 50 11638.97 14679.86 39.00 320.00 7485.79 5938.94 N 10086.09 W 1. 50 11699.83 14779.86 37.50 320.00 7564.32 5986.37 N 10125.88 W 1. 50 11758.76 14879.86 36.00 320.00 7644.44 6032.20 N 10164.34 W 1. 50 11815.71 14979.86 34.50 320.00 7726.11 6076.41 N 10201.44 W 1.50 11870.64 15079.86 33.00 320.00 7809.25 6118.97 N 10237.15 W 1. 50 11923.52 15179.86 31.50 320.00 7893.82 6159.84 N 10271.45 W 1. 50 11974.31 15279.80 30.00 320.00 7979.71 6198.99 N 10304.29 W 1. 50 12022.95 End of Drop 15500.00 30.00 320.00 8170.41 6283.33 N 10375.07 W 0.00 12127.75 16000.00 30.00 320.00 8603.41 6474.85 N 10535.77 W 0.00 12365.71 16500.00 30.00 320.00 9036.42 6666.36 N 10696.47 W 0.00 12603.68 16804.35 30.00 320.00 9300.00 6782.94 N 10794.29 W 0.00 12748.53 KS1 L2 . Base Tyonek - 10/14/02 All data is in feet unless otherwise stated. Coordinates from slot #KS1 and TVD from Est. RKB {101.00 Ft above mean sea level} . Bottom hole distance is 12748.53 on azimuth 302.14 degrees from wellhead. Total Dogleg for wellpath is 53.34 degrees. Vertical section is from wellhead on azimuth 302.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e MARATHON Oil Company Kasilof,KSlL2 Exploration,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref KS#l L2 Version #3 Last revised : 21-0ct-2002 Measured Inelin. Azimuth True Vert Depth Degrees Degrees Depth R E C TAN G U L A R COO R DIN ATE S Dogleg Deg/lOOft Vert Sect All data is in feet unless otherwise stated. Coordinates from slot #KSl and TVD from Est. RKB (101.00 Ft above mean sea level). Bottom hole distance is 12748.53 on azimuth 302.14 degrees from wellhead. Total Dogleg for wellpath is 53.34 degrees. Vertical section is from wellhead on azimuth 302.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . e MARATHON Oil Company Kasilof, KS1L2 Exploration,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Your ref KS#l L2 Version #3 Last revised : 21-0ct-2002 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 10125.00 5264.76 3345.50 N 7174.45 W Multi-Lateral Junction 10125.01 5264.76 3345.50 N 7174.46 W KOP 11059.99 5646.23 3805.03 N 7890.80 W End of Turn 11686.30 5900.00 4175.79 N 8327.15 W Beluga Entry 12658.89 6294.07 4751.53 N 9004.77 W End of Hold 13505.19 6700.00 5274.85 N 9528.85 W KS1 L2 . Tyonek Entry . 10/14/02 13505.21 6700.01 5274.86 N 9528.86 W End of Turn/Continue Drop 15279.80 7979.71 6198.99 N 10304.29 W End of Drop 16804.35 9300.00 6782.94 N 10794.29 W KS1 L2 . Base Tyonek - 10/14/02 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 10125.00 n/a n/a n/a 5264.76 5264.76 5264.76 5264.76 3345.50N 7174.45W 10500.00 5417.84 3506.55N 7476.35W 7 Casing 3345.50N 7174.45W 16804.35 9300.00 6782.94N 10794.29W 3 1/2 Liner 3345.50N 7174.45W 2700.00 5264.76 3345.50N 7174.45W 13 3/8 Casing 3345.50N 7174.45W n/a 5264.76 3345.50N 7174.45W 20 Conductor Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- KSl L2 - Beluga Entr KSl L2 - Tyonek Entr KSl L2 - Base Tyonek 5900.00 6700.00 9300.00 4023.51N 5274.85N 6782.94N 8424.31W 9528.85W 10794.29W 15-0ct-2002 15-0ct-2002 15-0ct-2002 · e SURFACE USE PLAN FOR KASILOF SOUTH #1 L 1 WELL Surface Location: SW 1/4 of SW 1/4, Sec. 28, T3N, R12W, S.M. 1. Existing Roads The Coho Loop Road off of the Sterling Highway will be used for access to the Kasilof South #1 L 1 well and is shown on the attached map. Kasilof, Alaska is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed No new roads are required. The existing pad will be used. 3. Location of Existing Wells Two wells were previously drilled and abandoned from the existing pad. Kasilof State #1 in 1964, and Kasilof State #2 in 1968. No producing or non-abandoned wells are located in the vicinity. 4. Location of Existing and/or Proposed Facilities No facilities are proposed at this time. 5. Location of Water Supply A water well will be drilled from the pad to a point below any local potable drinking waster sources as stipulated. 6. Construction Materials No materials are required. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 in the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). M:\Wells\Kasilof\KS#1 L 1 Permit to Drill\SURFUSE.doc Surface Use Plan Kasilof South #1 L 1 Well Page 2 . e b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the water well on the pad. S & R will collect and transport sanitary wastes to their ADEC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Reclamation of the pad, if required by the landowner, will occur after abandonment of all wells. 10. Surface Ownership Marathon Oil Company is the surface owner of the land at the Kasilof South #1 L 1 well. 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 M:\Wells\Kasilof\KS#1 L 1 Permit to Drill\SURFUSE.doc Surface Use Plan Kasilof South #1 L 1 Well Page 3 . e 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: December 27, 2002~___,_~ Name & Title: ~ ~ ~ Marathon Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6332 SeF1ier.,Drillinq Enqineer M:\Wells\Kasilof\KS#1 L 1 Permit to Drill\SURFUSE.doc I Well KasilofSouth#l 6% KCl FloPro System Estimated Proosity - 5 - 40 mDarcy Flo-Vis, KCI, Ventro1401, Lubetex, AsphasolD SafeCarb F & M, Conqor 404, Drilling Detergent, KlaGuard Shale Shakers / Desilter / Centrifuge Coal sloughing, drill solids buildup, seepage losses, bit balling, high torque & drag · Isolate one pit with completion fluid to drill out cement. Add ppb Biozan to cleaout. Do not displace the wellbore to new fluid until after a successfulleakofftest. · Clean other rig pits and build new FloPro fluid using the formula listed on the next · Maintain 2 ppb concentrations of both Ventrol401 and Asphasol D. · Maintain Conqor 404 concentration at +/- 2000 ppm. · Increase Ventrol 401 and Asphasol D concentrations if running coal becomes a problem. .. Centrifuge surface system during trips to aid in removing drill solids. · Alternate additions of Greencide 25G and SafeScav NA. .. Maintain a tight wallcake and keep mud weight as low as possible to reduce the potential for differential sticking. Maintain the 3 to 1 ratio of SafeCarb Fine & Medium. lit Keep a supply of Pipe Lax on location order to readily spot a pill around stuck pipe. M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Well Kasilof South #1 M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax e Marathon Oil Well Kasilof South #1 L 1 Anticipated BOP Stack ¡FlOW Nipple I ------. 13 5/8" 5M Annular Preventer 13 5/8" 5M Double Ram Preventer 3 1/8" 5M Manually Operated Valves -----. ~ I Flow Line I I Pipe Ram I I Blind Ram I ~~ [[I@I1][[I@I1] Œ!D IChoke I 1351S"5MCross I ~ 13 5/8" 5M Single Ram Preventer ~ I Pipe Ram I e /" (" / 3 1/8" 5M Hydraulically Operated Valve ÞI DI0IIJ[I@J]] t 31/8" 5M Manually Operated Valve / e Marathon Oil Well Kasilof South #1 L 1 Anticipated Choke Manifold e ¡TO Gas Buster I c:=m~~ Bleed off Line to Shakers ITO Blooey Line I 13" 5M Valves i t 2 9/16" 10M Swaco Hydraulically Operated Choke I From BOP Stack I 3 1/8" 5M Manually Adjustable Choke · 1203/4" 3M Diverter I ~ I Diverter Spool Marathon Oil Well Kasilof South #1 L 1 Anticipated Diverter .. \ e Flow line 116" Automatic Hydraulic Valve I X 116" Diverter Line Size - 3-112" x Size - 9-5/6" x 3-1/2" x 3-1/2" Size - 9-5/6" x 3-1/2" x 3-112" Length - 40ft Size - 6" Size - 9-5/6" x 7" x 7" Depth -10,100 Size - 17-1/2" x 200ft Depth - 1 0,000 - 1 O,200ft Size - 7" x 3-112 Size - 3-1/2" Size -3-1/2" TYONEK T2 C.I. :::: 25()' MILES MARATHON OIL COMPANY ALASKA PRODUCTION REGION KASILOF Kasilof South #1 and#1L Locations COOK INLET, ALASKA w.1.: 100% August2QQ2 0:\freehand\exploitation\kaspermitlocQ3.fh9 Kasilof South #1 & Kasilof South #1 L 1 Site Map Marathon - KasilofPad / Air Photo Overlay e . Oð-d5~ Subject: Marathon - KasilofPad / Air Photo Overlay From: "Underwood Jr, Charles A." <CAUnderwood@MarathonOi1.com> Date: Wed, 5 Mar 200308:40:15 -0900 To: <tom _ maunder@admin.state.ak.us> Tom, Here is the overlay of the as-built design on a color air photo. When printed out on letter size the scale is 1 "=200'. Chick «033006-CORE-image-2 of 5.pdf» Content-Description: 033006-CORE-image-2 of 033006-CORE-image-2 of 5.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/24/200410:37 AM MCG# 03-300~ 033006 -CORË.DWG PROJECT MARA r¡"'¡ON OIL COMPANY KA51LOF No.1 P.O. Box 468 SOLDOTNA. AK 99669 "" 'lN1 LOCATION seCTION 2&, TQIJ.N~IP :;, NO~I-I, ~E 12 WEST, seWARD ME~ICIAN, .AK, KENAI PENIN.eUI-A 6OFëOI.JGI-I REVISION CONSULTING GROUP PURPOSE KASII-OF No.1 EXPANSION OF eXISTING G~VE:I- PAD DATE TESTING APPLICANTS MA~TI-ION OIl- COMpANY P.O. 60X 1961&& ANCI-IOFii!AGE, AI< S'9SIS-&I&& SHEET NO. OF 2 RE: Kasilof South #1 L 1 . ~ Subject: RE: Kasilof South #1 L 1 Date: Thu, 6 Feb 2003 10:52:24 -0900 From: "Lambe, Steven S." <SSLambe@MarathonOil.com> To: "Tom Maunder" <tom_maunder@admin.state.ak.us> Tom- Thanks for getting back to me. To directly answer your questions: 1) Pipe rams will be clarified later with the solidification of the rig contract. 3-1/2 x 6 will be the optimum choice. 2) The surface location is slightly North, and the new well trajectory will be both North and Above the previous 2 well paths. I can provide a well path map of the 3 wells if required. 3) There are 3 parcels of property associated with the Kasilof Pad. The North Lot is jointly owned by Marathon and Unocal, the middle lot 100% Marathon, and the South Parcel joint Marathon and Unocal. There are no third party (Private) land owners involved. Any other questions or concerns, please let me know. All the best, Steven -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl Sent: Tuesday, February 04,20034:40 PM To: Lambe, Steven S. Subject: Kasilof South #1 L 1 Steve, I have had a preliminary look at your lateral well plan. Neat, but I have a couple of questions. 1--What size pipe rams will you be using, 3-1/2 x 6 or 2-7/8 x 5? 2--Where are the P&Aed wells with regard to your new well? More likely a question for the mother-bore. 3--ln the surface use plan, #10 it is noted that Marathon is the surface owner. Is that true?? I would have expected Marathon to be the lessor(?). Than ks Tom 1 of 1 2/26/20033:47 PM ".. ~, e e 20"L- ZS:7 MARATHON KASILOF EXPLORATON UNIT - GEOLOGIC DESCRIPTION OF HYDROCARBON AND ABNORMAL PRESSURE OCCURRENCE JUNE 2003 CONFIDENTIAL Marathon Oil Company is requesting a Spill Contingency Plan and Financial Responsibility Exemption for the Kasilof Exploration Unit (KEU). Similar exemptions were granted for Marathon's Ninilchik Exploration Unit and Kenai Gas Field that have the same reservoir objectives (Tyonek and lor Beluga) and similar depths (5000-9500' TVD). The well and seismic data applicable to the KEU indicate that the work at KEU will not encounter shallow gas anomalies, abnormally high pressure or liquid hydrocarbons (oil; see attached map). Marathon expects to encounter pressure gradients not exceeding 0.5 psi/ft (Mud Weight equivalent - 9.6 #/gallon) while performing drilling, workover or recompletion operations above 9500' true vertical depth (TVD). The completion operations will typically employ nitrogen backpressure prior to perforating the wells. Wellhead pressure equipment will be used for perforating and testing. Drilling operations will use mud weights below 11 #/gallon unless unstable hole conditions created by sloughing coal dictate a higher mud weight. Surrounding well data supports these expectations and plans. These nearby wells drilled the gas prospective Beluga and Tyonek section at comparable depths using mud weights not exceeding 10.9 #/gallon and recognized no over pressured strata. Union Kasilof State 1 (UKS1), Sec. 28-T3N-R12W, 10.7#/gallon, 1964 Union Kasilof State 2 (UKS2), Sec. 28-T3N-R12W, 10.1#/gallon, 1964 Mesa Kasilof Unit 2 (MKU 2), Sec. 18-T3N-R12W, 9.8#/gallon, 1968 Union Kasilof Unit 1 (UKU1), Sec. 30-T3N-R12W, 10,4#/gallon, 1967 SOCAl Cape Kasilof (SCK1), Sec. 25-T3N-R13W, 10.9#/gallon, 1974 Drill Stem Testing in the MKU2 and SCK1 identified pressure gradients of 0.47 psi/foot (9.2 #/gallon) and 0.43 psi/ft (8.4 #/gallon) in the Tyonek and Beluga gas sandstones respectively. The seismic data across the exploration unit have no pressure anomaly signatures or shallow gas anomalies. The well control coupled with the seismic satisfactorily evaluates the area for abnormal pressure and indicates none. Tests and mudlog data indicate that methane is the only hydrocarbon expected for the prospective section above the requested TVD limit. SCK1 And MKU2 flowed gas to surface from Drill Stem Tests in the Beluga and Tyonek sandstone beds (respectively) to be evaluated by the proposed work. No liquid hydrocarbons were recovered on these tests. Mudlog shows are characterized by C1 (methane) and are absent of the liquid hydrocarbon indicators of C5 and higher. Traces of C2, C3 and occasional C4 are noted on some mud logs from the coal intervals and prospective gas sandstones. The C1-C4 gas MARATHON KASILOF EXPLORATON UNIT - GEOLOGIC DESCRIPTION OF HYDROCARBON AND ABNORMAL PRESSURE OCCURRENCE Page 1 e e shows in the sandstone beds are indicative of the methane only gas produced from tests and gas productive wells on the Kenai Peninsula. Two wells that were drilled from the surface location for KEU work (Sec. 28-T3N-R12W), UKS1 and UKS2, did not encounter indications of liquid hydrocarbons as noted above. Gas samples collected from the Tyonek at Kenai Gas Field and the Ninilchik Exploration Unit have gas compositions that are predominately methane (see attached gas analysis). The combined percentage of ethane and heavier gases are less than 1 %. This gas composition should be expected at the KEU from production above 9500' TVD. A minor oil show, C5 gas, occurs in the SCK1 well at 13,330'. This show was in the Hemlock significantly below the 9500' TVD base of the gas prospective interval that Marathon is targeting. The TVD tops and possible hydrocarbons for the zones that were drilled in the SCK1 well (drilled to the Tertiary West Foreland Formation) document the vertical segregation ofthe gas and oil potential in the KEU. Formation Sterling Beluga B2 B3 Tyonek T2 T3 T4 T5 Hemlock West Foreland Total Depth SCK1 Surface 4249 5338 6147 6728 7378 8614 10348 11976 12594 10879 14775 Hydrocarbon Potential None Gas Gas Gas Gas Gas Gas None None except slight oil at base near Oil Oil Given the above data, no drilling hazards or liquid hydrocarbons are expected while doing the well work within the KEU above the 9500' TVD limit listed above, thus eliminating the need for a C-plan or Financial Responsibility related to oil discharge. Attachment: Kasilof Exploration Unit Tyonek T2 Map Kasilof Exploration Unit Cross Section Kenai Gas Field Gas Sample Analysis- 2L Ninilchik Exploration Unit Gas Sample Analysis - Corea Creek Federal 1 MARATHON KASILOF EXPLORATON UNIT - GEOLOGIC DESCRIPTION OF HYDROCARBON AND ABNORMAL PRESSURE OCCURRENCE Page 2 !iWq1(:~[)$WÞÄ~@¥W¡¡¡~ 12/23/2002 1900049516 Filing Fee For Permit To Or ill KasiLof South OTAL: A~~gul~¥Šir~: Y~BLE DEPARTMENT Jackie Abert Phone: 713-296-4336 Hndlg AL 1055459 12/30/2002 NCBAS 7780 5001123 Marathon Oil Company P. O. Box 3128 Houston, TX 77253 Check No Check Date Bank Bank No Vendor No 100.00 100.00 !nvolce/Pay Amount 100.0 100.0 GEC æ . At ka Oil & Gas Gons. G mrnission ... Anchorage (FOLD ON PERFORATION BELOW AND DETACH CHECK STUB BEFORE DEPOSITING) 11100 0 ~ 0 5 5 ~ 5 ~ III I: 0 ~ .~ 20 3 B ~ 5 I: 0 ~ B 3 ~ B ~ III e . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ø ÝI·~fc-£h-I/.-/ ~ I . PTD# 2-/)Z-¿Ç7 CHECK WHAT ADD-ONS "CLUE" I APPLIES (OPTIONS) . MULTI The permit is for ~ nr ~el~e/egment of tI LATERAL existing well ~9ß>·· .£Ä :::> Permit No,2Ql.-ZSbAPI N~733- ZC>SZL>-~ (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. Pll..OT HOLE In accordance with 20 AAC 25.005(t), all (PH) 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 fuD EXCEPTION compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv 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: 07/10/02 Ojody\templates FIELD & POOL ADMINISTRATION APPR SFD DATE 6/23/2003 (For Service Well Only) (For Service Well Only) (For Service Well Only) ENGINEERING APPR WGA DATE 3/26/2003 GEOLOGY (For Service Well Only) APPR SFD WELL NAME Kasilof South 1 L 1 PROGRAM Exploratory (EXP) -1L Development (DEV) _ Redrill_ Service (SER) _ Well bore seg -1L Annular disposal para req GEOLAREA 820 UNIT No. 011110 ON/OFF SHORE On COMPANY Marathon Yes Mu~i-Iateral well: fee waived per 20 AAC 25.005(d); check should be returned to Marathon. SFD Yes Top productive interval and TD located in ADL 384529. Yes No Exploratory well Yes Well is located within the Kasilof Unit, approved by DNR-DOG on October 25, 2002. Yes Spacina exception not reauired: this will be a lateral branch of an existina well. Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes 35. Permit can be issued w/o hydrogen sulfide measures ...... ... ......... ... ........................ .., ... Yes 36. Data presented on potential overpressure zones .................. .,. .................. ... ............... Yes DATE 37. Seismic analysis of shallow gas zones ..................... ... ... ...... ... ..................... ............. Yes 000000 - Exploratory Initial ClassfType EXP /1-GAS 1. Permit fee attached ... ... ... .., ... ... ... .., ... ... ... .,. ... ... ... ... ... ... ... ... ... '" .., ... ... ... ... ... ... ... .,. ... 2. Lease number appropriate .., ... ... ... .., ... ... ... .,. ... ... ... ... ... ... ... ... ... ... .., ... ... ... .., ... ... ... .,. ... 3. Unique well name and number ... ... ... ............... ................................. ... ......... ............ 4. Well located in a defined pool... ... ............................................................ ... ... ........... 5. Well located proper distance from drilling unit boundary ........................... ......... ............. 6. Well located proper distance from other wells ....................................... ........................ 7. Sufficient acreage available in drilling unit ........................... .,. ... .................................. 8. If deviated, is well bore plat included .................. .............................. ... ........................ 9. Operator only affected party ... ... ... ... ... ... ... .., ... '" ... .., '" ... ... .,. ... ... ... ... ... ... ... ... ... ... .., .... 10. Operator has appropriate bond in force ...... .,. ...... ... ... ... ...... ...... ... .., ......... .., ...... ... ...... 11. Permit can be issued without conservation order ... ... ... ... ......... ... ...... ... ... ... ... ... ... ......... 12. Permit can be issued without administrative approval................................. .., ............... 13. Can permit be approved before 15-day wait ........................... .................. .................. 14. Well located within area and strata authorized by Injection Order # 15. All wells within 1/4 mile area of review identified ..................... ..................... ................ 16. Pre-produced injector: duration of pre-production less than 3 months............... ... ... ... ... .. 17. ACMP Finding ofConsi¡¡tency has been issued for this project ..................... .................. NA 18. Conductor string provided ... '" ... ... .., ... ... ... .,. ... ... ... ... ... ... ... ... ... ... ...... ... ... ... ... ... ... ..... 19. Surface casing protects all known USDWs ... .......................................... ...... ... .......... 20. CMT vol adequate to circulate on conductor & surf csg .............................. .................. 21. CMT vol adequate to tie-in long string to surf csg ................................. ... ... ................. 22. CMT will cover all known productive horizons ............................................................. 23. Casing designs adequate for C, T, B & permafrost .................. ..................... ............... 24. Adequate tankage or reserve pit ... ... ............ ... ............ ............... ... ... ............... ......... 25. If a re-drill, has a 10-403 for abandonment been approved ... ... ... ...... ... ... ......... ... ...... ..... 26. Adequate wellbore separation proposed ... ............ ... ... ...... ...... ................................... 27. If diverter required, does it meet regulations .., ... ... ... ...... ......... ... ...... ... ... ... ... ... ......... ... 28. Drilling fluid program schematic & equip list adequate ." ... ......... ..................... .............. 29. BOPEs, do they meet regulation ...... ............... ... ... .,. ...... ......... .............................. ... 30. BOPE press rating appropriate; testto ....................... 3500 psig ........................... 31. Choke manifold complies w/API RP-53 (May 84) ......... ... ... ... ..................... ... .............. 32. Work will occur without operation shutdown ............ ............ ....................................... 33. Is presence of H2S gas probable ............ ... .......................................... ... ................. 34. Mechanical condition of wells within AOR verified ........................ ........................... ..... 6/23/2003 38. Seabed condition survey (if off-shore) ... ......... ... ... ... ...... ... ... ... ...... ......... ......... ...... ..... 39. Contact name/phone for weekly progress reports [exploratory only] .............................. GEOLOGY: RPC: SFD:SFD ENGINEERING: RES. ENGINEERING: ~SSION:.." '.. S 6 /..>-0'~ ~ ::.X ::. DTS D6Ir1Í~ "-, ...LIIoB: ~ -r- ~ q:,. Yes Yes Yes Yes Yes Yes Yes Yes Yes . -¿I (fU~: I-'er Nina jruale, U\.:j\.;: Maratnon nas not yet submitted a Coastal Project Questionnaire or held a pre-application meeting. ~/"/U~: I-'re-app meeting was held. 3/25/03: Nina Brudie: DNR single agency, 30-day review, starting -4-1-03. SFD 6/20/03: ACMP consistency determination not needed prior to approval of permit to drill per Rob Mintz. SFD NA Not Applicable NA Sidetrack of existinQ wellbore. SFD NA Not Applicable NA Not Applicable A}".L. ~273\) NA Not Applicable A.f1IJ -.. .... NA Not Applicable Max MW 9.8 PPO. MSP 3089 psi. e No NA Not Applicable None noted in offset exploratory wells. Rig will be eauipped with sensors and alarms. SFD DSTs in nearby Kasilof Unit 2 & Cape Kasilof 1 indicate pressure gradients less than 9.2 ppg EMW in Tyonek and Beluga; 9 - 9.8 ppg mud will be used. David Brimberry, Marathon: no shallow gas. abnormal pressure. or other drilling hazards are anticipated (see also "MARATHON KASILOF EXPLORA TON UNIT - GEOLOGIC DESCRIPTION OF HYDROCARBON AND ABNORMAL PRESSURE OCCURRENCE, JUNE 2003" in this well file). NA Onshore surface location. Yes Steven Lambe DrillinQ Enaineer, 564-6332 Comments/Instructions Well will be mud logged below surface csg. Dry cuttings samples not required. Immediately adjacent wells Kasilof State 1 and 2 have cuttings samples from 1500-16121' and 2050-6686' MD. respectively. Nearby offset wells Kasilof Unit 1 and Cape Kasilof 1 have cuttings samples from 630- 5500' and 510-14015' MD, respectively. SFD e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information.
