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Home My WebLink About202-256New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 • STATE OF ALASKA • 'Reef 34 ALASKA OIL AND GAS CONSERVATION COMMISSION Y 6 2.fl17 WELL COMPLETION OR RECOMPLETION REPORT ANE C 1 a.Well Status: Oil ❑ Gas❑ SPLUG ElOther ❑ Abandoned 0 • Suspended❑ lb.Well Class: bt0G4„,jiNW 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory Q GINJ ❑ WINJ ❑ WAGE] 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 • •202-256/316-640 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Ste 1400,Anchorage,AK 99503 10/14/2003 • 50-133-20520-00^t' 5u.3.t7 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 • 1/17/2004 • Kasilof South 1 • 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,• 4402'FSL&786'FEL Sec.25 T3N R13W,SM • 17,404'MD/9,517'TVD • ADL-0384534,ADL-0391591,FEE-Hilcorp,ADL-0391246 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 250209 • y- 2310138 • Zone- 4 • 17,545'MD/9,642'TVD • N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MDlTVD: Total Depth: x- 237254 y- 2314017 . Zone- 4 N/A; N/A N/A 5. Directional or Inclination Survey: Yes ❑(attached) No Q 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MDITVD: 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 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' 9916' 0' 5186' 12-1/4" in place,2200 sx N/A 7" 29# L-80 9916' 9935' 5186' 5194' 12-1/4" Cemented with 9-5/8"csg. N/A 3-1/2" 9.2# L-80 9923' 17504' 5189' 9605' 6-1/8" in place,675 sx N/A 24.Open to production or injection? Yes ❑ No ❑✓ 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" 9923' 9853'MD/5161'TVD tlBRNDONPO 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. �N��® NOV 0 2.017, , • Was hydraulic fracturing used during completion? Yes ❑ No Q . J LI I v I t-. Per 20 AAC 25.283(i)(2)attach electronic and printed information - DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Ls- 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 ,-6.- Form -►Form 10-407 Revised 11/2015 j CONTINUED ON P GE 2 Submit ORIGINIAL only/ etk 1.2.1 -I? /2fr f 7b RBDMS k,' � -s:1�"' 3 0 2017 /o 337 28.CORE DATA Conventional Core(s): Yes ❑ No El • Sidewall Cores:Yes ❑ No Q • 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 hiIcorp.com Printed Name: Chad Helgeson Title: Operations Manager )_ Signature: (/' L/� �T Phone: 777-8405 Date: j 2-4t�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 110 751 Hilcorp Alaska, LLC titt4 Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1 50-133-20520-00 202-256 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 1 50-133-20520-00 202-256 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 1 50-133-20520-00 202-256 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 landingjt. 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 landingjt. 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. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1 50-133-20520-00 202-256 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. • • VA Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1 50-133-20520-00 202-256 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 11bbl 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 1 50-133-20520-00 202-256 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. i Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Kasilof South 1 50-133-20520-00 202-256 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. • • Kasilof South #1 / 1L1 SCHEMATIC Ililcoru Alaska,LLC Kasilof Field Surface x Intermediate Casing Marker Plate 4/6/17 Cement Top Job 4/4/17 *i Kasilof South#1 (Motherbore- w°' Kasilof South#1L1 South Target) ., . ' (Lateral-North Target) Kasilof Field f `'�"_tot' Kasilof Field 520'FSL, 1340' FWL, it 520'FSL, 1340'FWL, Sec.28,T3N,R12W,SM I- Sec.28,T3N, R12W,SM Nal 5 ) Cast Iron Bridge Plug @ 150' {{,yConductor Dump 150'of cement 2/2/17 _.1„. 20" K-55 Top 0'MD Suspected Casing damage @ 3,205- 133 ppf PE Bottom 130'MD 130'ND 3,210' ` t+ Surface Casing Cast Iron Bridge Plug @ 3,293' 13-3/8" K-55 Top 0'MD Dump 540'of cement 2/2/17 68 ppf BTC Bottom 2860'MD 2383'ND I 16"hole with+/-750 sks 12 ppg cement Tubing chem cut @ 9,405' 1/26/17 ' II Tubing chem cut @ 9,435 1/26/17 GT Dual String Packer w/top @9853'MD ! CIBP @ 9,890'1/25/17 Size- 9-5/8"x 3-1/2"x 3-1/2" ac , Intermediate Casing Cl BP @ 9,900'1/25/17 `II die / 9-5/8" L-80 Top 0'MD Dual Tubing Strings ."...11111111111 ` / 40 and 47 pp BTC Bottom 9916'MD 5186'ND 3-1/2",9.3#,L-80,Hydril 533 Scoophead Diverter , Underreamed Section (SHD) Size-17-1/2"(9850'-10020'MD) Size- 9-5/8"x 31/2 x 3-1/2" \1.\litls\NIA" LeFORMation Junction Ii 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'MD a Leg Size-7"x 29# ZXP Liner Hanger Packer 9916'-10533'MD Size-7"x 3-1/2"w/top @ 9923' Phi j FHL Production Packer Size-7"x 3-1/2"w/top @ 10,909' 3-1/2 Liner SLPR Liner Hanger Size-3-1/2 x 7"with top at 10323' Cast Iron Bridge Plug @ 16,950' 111111 , Dump bail 25'of cement 1/10/17 �I RS Nipple • 31/2"set at 10333'MD Tvonek Perfs: ) 1 III 16,972'-16,996'MD,24 ft, PJ2506 3/24/2004 ' Tyonek Perfs: 17,012'-17,050'MD,38 ft, PJ2506 3/22&23/2004 I 3-12"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 N. TD:17,545'MD/ 9642'ND 'E_-MY � \-----____ TD:17,665'MD/ 9999'ND Cast Iron Bridge Plug @ 16,400' Dump bail 25'of cement 1/10/17 / ' ✓ Liner Liner a- 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. 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O 0 CO r-i 90• Skis 2 O! 0 a I - dam• .630 O! i 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 .��416ti OF'4... 14 �* 49 x ni *.i 011 2, • WIN C.BROWN e .' ..4/4//7 .•'•e•: . . -11, 'IDPESS1ONP• • • \\` \ •\ �- — AS 10 ` •. Ik X1:2309964.46\` \ I E:13 0996 13.4 I i LI KASILOF SOUTH NO. 1 • E EV:76.50' \ \ NORTH 1 ,\`\' N:2309896.70 ' \ �l E:1390229.06\1 ; 1 \ f� — —_ `, SCALE ® 1/ �, �l \ 0 150 300 \ I i'I I I ( I I j_. i \ , FEET x',,11 Z I i � ��OF A4 llIl V,11 m zo I of _co: -� f, III � TOWER \ o . I mo !7 n o ❑ Co q I I c.-. IAIN C. BROWN . A- O i ' j� v A I I • ,� s,s ., LS-107707 J�,�� ®®I in ..— . z R' i m \,�.. - ` 4r�At7II : ,11 PROFESS IONA1-�.P`"w451 i 1 , ,, ,,„ \-1 , „ I . (7 — I l—I/ I'� 1 ►I - �I1 i _ I_ i il1, 1 � / As 'sII I N:2309395.420-, r, -- Oyu / _ E:1390456.404 T , 4.. I 33' I �N I � /, ELEV:ZS. T 'Tull �� _ (I SECTION 28, T3N, R12W, S.M. AK, — _ _ __ � n_ WC C 1: SECTION 33 T3N, R12W, S.M. AK. N:2309378.38 ------, 50' SECTION LINE EASEMENT E:1390136.21 -) 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 I I- - WELL NOTES \ CELLAR — 1. BASIS OF GEODETIC CONTROL (EPOCH )IS AN 1 OPUS SOLUTION FROM NGS COORDINATES STATIONS"KENS CORSARP', "TSEA CORS ARP",AND"ZAN1 WAAS 1 CORS ARP"TO ESTABLISH THE — I 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 —I TOP CUT-OFF CONDUCTOR OF 151'22'43.24964"W.THE ALASKA STATE PLANE COORDINATES(ASP) —III ELEV: 67.691 FT (— ZONE 4 ARE: N=2309395.420 I ' E=1390456.404 ELEV.75.07'(NAVD88) 2. BASIS OF VERTICAL CONTROL IS NGS BM L82 PID TT0574 LOCATED WITHIN ( :. . III—I AT MILE 119 OF THE STERLING HIGHWAY HAVING AN ELEVATION OF 346.15 ! _ FEET NAVD 88 ACCORDING TO NGS PUBLISHED DATA. —III 7 7 7 IT— 1. 71 7 7 1-T—I _ °.< — II I I \. ALL DISTANCES LISTED IN US SURVEY FEET. / =III— I—I 1.---..: ::.;7.1 I LI 1_111=111E PROJECT HILCORP ALASKA, LLC REVISION: - AConsuLkiny Inc KASILOF SOUTH#1 DATE. 4/4/17 KASILOF ALASKA DRAWN BY: ICB SCALE: 1"=150' PLUG AND ABANDON EXHIBIT-A PROJECT NO. 177006 ENGINEERING/MAPPING/SURVEYING/TESTING NAD 83 BOOK NO. 16-03 P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION VOICE:(907)283-4218 FAX:(907)283-3265 SEC. 28 T03N R1 2W SHEET EMAIL:SAMCLANE@MCLANECG.COM Hilcorp Alaska,LLC 1 OF 1 SEWARD MERIDIAN, ALASKA S AOGCC PA Exhibit A Coord Conversion 3 October 2017 INPUT OUTPUT State Plane,NAD83 State Plane,NAD27 5004-Alaska 4,U.S.Feet 5004-Alaska 4,U.S.Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. KASILOF SOUTH 1 1/1 Northing/Y: 2309896.7 Northing/Y: 2310137.358 Easting/X: 1390229.06 Easting/X: 250208.405 Convergence: -1 11 56.21597 Convergence: -1 11 49.31669 Scale Factor: 0.999971238 Scale Factor: 0.999971008 Grid Shift(U.S.ft.): X/Easting=-1140020.7,Y/Northing=240.7 Datum Shift(m.): Delta Lat.=65.291,Delta Lon=-122.343 Remark: Corpscon v6.0.1,U.S.Army Corps of Engineers • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 01/ DATE: 4/06/17 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector Kasilof Field Kasilof South #1 ' PTD 2022560 ' Sundry 316-640 ' 4/04/17: I traveled down to Kasilof#1 and met with Cole Bartlewski (Hilcorp) to inspect and witness the P&A. We discussed the job and I witnessed the removal of the wellhead and the cementing of the well. They were able to cement approximately 27 ft from the top of the casing down with 3/4" conduit and a Schlumberger cement truck. I had Hilcorp verify the cut-off depth by having surveyors come to the site since they had no supporting paperwork that could confirm the cut-off depth was correct. lain Brown with McLane Consulting came out and confirmed the cut-off depth was 6.38' below a/ ground level. 4/06/17: I returned to Kasilof#1 to witness the welding of the top plate onto the conductor and verified the proper identification information was included on the top plate. Summary: After verifying cement was set at surface and the top plate was welded on and had the proper identifying information, I informed Cole Bartlewski with Hilcorp that they could proceed with burying the abandoned well. Attachments: Pictures (4) McLane Consulting Abandonment Survey SCANNED 6 2017-0406_Surface_Abandon_Kasilof-1_gc.docx Page 1 of 3 • i vi. '.. t► , k y'-r i 1 e i U O W to o kr CA Ct I • ' N CtU co4. a w 0 o CO O N o 0 I- 0. oU ^z . , ,A '''' . ,--.Sies0_6*. kik ' -, co L , e COti _,r, , o 04'( . Ij cC o o `r " O V/ +N:: 1 • • x.13. • 1' ,i,.Y a- s,,_ ..4....:4,„....... . ilk ' ' ..oii7"•.. Is,...A., Iplir JIt ip.,nt .., .„, , - . .„.. ;1. ; " ?, ♦Y` t� ;u '"", " Pr �Ci.r �1 : k'� p -v� (IIs "+r c. elIV di *.':, .),.!., ,7 • 4- ,.... strj&. 7c.16 I '46° ` . ` r �pl. ' ,*yamr,o '. 4 �l: a ud. oSh .11r4 s 41, 2017-0406_Surface_Abandon_Kasilof-1_gc.docx Page 3 of 3 • • 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 +,E ,OF. .. ,9 '11 „,„„ ol.... 49 %, v2, IAIN C.BROWN . LS-107707 �, .'..4/4/2 7 ,.•' �• `+r p ofitss,oN "albAr 0 • \\1 �� _= `. ;KAS 10 /\ i : , !.,„1„„„,,„1,„,„,„ :, , �J:2309964.46\ , '\ E:1390411.13 1 NORTH ' ` ELEV 76.50' \ \ 44` t KASILOF SOUTH NO. 1 \ `. I;III +,' 4 �''' r E:1390229.06 � ' 1 li I-µ — — . 1. — ..—. ; 1 SCALE ® 0 150 I 1 300 \---„ V::-.- =.....-. I A 1 \ I FEET 1 i AL 11 SOF q t / v X E. P S•,-ft 7, -' . '0', — — i C" of -' i� y FfMUNICAT10N � c> > *' 4.9 TOWER 'o C7 O 1 I��sIAIN C. BROWN ,�— p n �� s� LS-107707 ,� i gOCess I `f,'••, 4/4/77 4., s' J •I �I OF r r- ' I • itl ESS NAV �� M *, •It ( r,.._. I I\i ! ! ! 1 !!!!!!!!PletIO! I I(,- ::::::::::'''...--.'. I..e : 1 II i X11\‘N�SN� :,,,I1.111,),,,,,.11,, � r .. I 1 IPI lJ, r €. PL • NA239 i • _i ,•!,,,11',....„'v_',77.7.1.. 09395.420 F „ y "EN:: 1390456.404 33 SECTION LINE EASPMENTI ,ELEV 75. 7' w” --. ,,,�_.._.,_,, 1 1 SECTION 28, T3N, R12W, S.M. AK, ,.:(,:,,,,,,,,*4,,w,„,,,,,,,,-,„:„WCMC t SECTION 33, T3N, R12W, S.M. AK. 50' SECTION LINE EASEMENT N:2309378 38 .,, , I E:1390136 21 I 1 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 I • I NOTES 'N WELL CELLAR 1. BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003)IS AN I - ..I I OPUS SOLUTION FROM NGS COORDINATES STATIONS"KEN5 CORS ARP", I__ "TSEA CORS ARP",AND"ZAN1 WAAS 1 CORS ARP"TO ESTABLISH THE • I -- POSITION OF"KAS9".THE GEODETIC POSITION OF"KAS9"WAS . 1 DETERMINED TO HAVE A LATITUDE OF 60°18'51.62717"N AND A LONGITUDE TOP CUT—OFF CONDUCTOR OF 151°22'43.24964"W.THE ALASKA STATE PLANE COORDINATES(ASP) ELEV: 67.691 FT ZONE 4 ARE: N=2309395.420 . - .... - E=1390456.404 j __- ELEV.75.07(NAVD88) ___ I 2. BASIS OF VERTICAL CONTROL IS NGS BM L82 PID TT0574 LOCATED WITHIN AT MILE 119 OF THE STERLING HIGHWAY HAVING AN ELEVATION OF 346.15 I I — T �".;,: — —— FEET NAVD 88 ACCORDING TO NGS PUBLISHED DATA. sy .; III III ' 3. ALL DISTANCES LISTED IN US SURVEY FEET. 1 ( + I T I — ____, ..___._ 1__.__ PROJECT HILCORP ALASKA, LLC REVISION: - /,Consulting Inc KASILOF SOUTH #1 DATE: 4/4/17 -=‘12F KASILOF 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.BOX 468 SOLDOTNA,AK.99669 1:::11[ LOCATION VOICE:(907)283-4218 FAX:(907)283.3265 �/� SEC. 28 TO3N R12W SHEET EMAIL:SAMCLANEQMCLANECG.COM thijt-0t't3 ,Alaska, 1yy...1.,t+ OF 1 Y SEWARD MERIDIAN, ALASKA • • L Schwartz, Guy )L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, March 15, 2017 11:15 AM To: Taylor Nasse Cc: Chad Helgeson; Donna Ambruz; DOA AOGCC Prudhoe Bay Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Taylor, I think we have attempted all that can be reasonably done to this point. The next step is to cut off wellhead and see what the cement looks like in the annulus(OA). Assuming it is contaminated it should be jetted out to min.of 20 ft BGL and cemented back as proposed below. AOGCC would like notification to witness when the wellhead is cut off and when the additional cement is pumped. Also update the MOC as required. Regards, Guy Schwartz Sr. Petroleum Engineer SCANNED MAY w 2 J i t.r, � AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent:Tuesday, March 14, 2017 5:17 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Hi Guy- Last weekend we attempted to pressure test the surface x intermediate annulus to 1,300 psig per our discussion last week. The annulus would pressure up fairly quickly to the test pressure but after 30 minutes the pressure would steadily bleed off to around 750 psig. It looks like there is a small leak that slowly takes fluid when we pressure up on it, however we haven't seen gas since the initial time we attempted to cut and we haven't seen pressure on the annulus over the last few weeks that we've monitored it so it appears to be static. In order to get a sufficient permanent barrier in the surface x intermediate annulus, I would like to propose that we move forward with cutting off the rest of the wellhead.This will allow us to determine the condition of the annulus and clean out some of the contaminated cement, if necessary. After the annulus has been cleaned out, we will run pipe into the annulus (minimum 20' if possible)and circulate cement to the top of the cut. If you have any questions or need additional information, please feel free to contact me. 1 Thanks, • S Taylor From:Taylor Nasse Sent:Wednesday, February 22,2017 2:31 PM To:'Schwartz,Guy L(DOA)'<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Guy- Over the last week we kept heat on the wellhead to keep it thawed out and pumped roughly 17 bbls of water over the course of 4 days into the olet and valve that we welded over the top of the hole in the 13-3/8" casing until it appeared that the void was full of fluid (see attached picture of the wellhead and updated wellhead schematic). During this time, we were unable to sustain a fluid rate while pumping into the well at 500+ psig, so it doesn't appear to have injectivity (at this pressure, anyway). Based on the volume pumped,the annular void could be down to around 300' (assuming little to no cement). Over the weekend we continued to keep the well thawed and observed 0 psig on the well,the water level has maintained at the valve,and no LEL has been detected when the valve is opened. Based on this, it appears that the void is full of fluid and the gas has been removed. At this point, I would like to propose that we move forward with cutting and removing the remaining casing in order to evaluate the condition of the cement in the annulus and then perform a cement top job. If you have any questions or need additional information, please feel free to contact me. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell From:Taylor Nasse Sent: Friday, February 10,2017 3:45 PM To:'Schwartz, Guy L(DOA)'<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com>; Michael Erstrom<merstrom@hilcorp.com>;Chet Starke)<cstarkel@hilcorp.com>; David Wilkins<dwilkins@hilcorp.com>; Pete Iverson<ipiverson@hilcorp.com> Subject: RE: Kasilof#1/111 Sundry 316-640/641 (PTD 202-256/257) Hi Guy- Just to bring you up to speed on our progress today,we thawed out the wellhead and pumped some fluid at low pressure into the casing valve, but the annulus took little to no water before it started to come out of the flange on the other side and didn't come out of the cut in the casing at all.We have a pump that can put more pressure on it, so my plan is to add pressure and see if we can get communication with the cut.Afterwards, I'd like to weld an olet over the cut hole and add a valve to give us a way to monitor and test at this location. 2 Looking at the weather forecast, it looks like it is supposed to get colder over the weekend and then warm up starting Monday, so I was planning to shut down further work over the weekend and then restart testing on Monday or Tuesday after we have the wellhead sufficiently warm and thawed out, if that works for you. If you have any questions or need additional information, please feel free to contact me. Thanks, Taylor From:Taylor Nasse Sent: Friday, February 10,2017 10:59 AM To:'Schwartz,Guy L(DOA)'<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com>; Michael Erstrom<merstrom@hilcorp.com>;Chet Starkel<cstarkel@hilcorp.com>; David Wilkins<dwilkins@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) We've opened the OA valve throughout the rig P&A work, and the last time we had it opened was when we pressure tested the cement plug at 2,753' last Thursday. We first opened the valve when Moncla was rigging up and there was a small amount of pressure that bled off quickly,which we attributed to thermal expansion since we had recently pumped water to fill up the well. After the initial bleed-off there hasn't been any flow or pressure noticed when the valve was opened. From:Schwartz,Guy L(DOA) (ma ilto:guv.schwartz@alaska.gov] Sent:Friday, February 10,2017 8:55 AM To:Taylor Nasse<tnasse@hilcorp.com> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com>; Michael Erstrom<merstrom@hilcorp.com>;Chet Starkel<cstarkel@hilcorp.com>; David Wilkins<dwilkins@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641(PTD 202-256/257) Taylor, Plan forward sounds reasonable... Keep me posted on progress over the weekend. Do you know if OA valve was opened and checked for flow before P&A started or just based on OA gauge pressure?? I know we discussed that the records showed OA was cemented. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From:Taylor Nasse (mailto:tnasse@hilcorp.com] Sent:Thursday, February 09,2017 4:54 PM To:Schwartz,Guy L(DOA)<guv.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) 3 <whudgens@hilcorp.com>; Michael•rom<merstrom@hilcorp.com>;Chet Star el<cstarkel@hilcorp.com>; David Wilkins<dwilkins@hilcorp.com> Subject: RE: Kasilof#1/111 Sundry 316-640/641 (PTD 202-256/257) Guy- Today we were working on cutting off the wellhead for the P&A on Kasilof South#1/1L1 per Sundry 316-640/641. We were able cut the surface conductor and removed a section of it with no issues. When we started to cut the surface casing and completely penetrated the 13-3/8" surface casing,a small amount of gas released through about an approximate 1/2" hole (see photo).The gas ignited from the cutting operation with a flame about the size of a weed burner. We decided to let the flame burn while keeping a safe distance and after approximately 20-30 minutes the flame extinguished itself. The plan is to pump water into the casing valve until it comes out the hole. We will then patch the casing and see if we can pump into the well and what kind of rate/pressure we can inject. Once we have that info,we will communicate with AOGCC a plan forward before any additional work progresses on this well. If you have any questions or need additional information, please feel free to contact me. Thanks, Taylor W.Nasse,PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell From:Schwartz,Guy L(DOA) [mailto:guy.schwartzt alaska.gov] Sent:Thursday, February 02, 2017 9:51 AM To:Taylor Nasse<tnasse@hilcorp.com> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com>; Michael Erstrom<merstrom@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641(PTD 202-256/257) Taylor, Your modification to the procedure is approved as proposed below. No issue with pulling rig off to finish the last surface plug. Make sure you notify inspectors to witness the last cement plug and cut-off. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE;This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 4 • • From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent:Thursday, February 02, 2017 9:32 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com>; Michael Erstrom<merstrom@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641(PTD 202-256/257) Hi Guy- As we discussed yesterday,we would like to request a modification to steps#35-37 of the procedure to the following: 35. Set CIBP(at 150'),close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then POOH. 36. MU 1-1/2" string and run to just above CIBP.Set in hanger. 37. RD Moncla#401 WO Rig. Post WO Rig Procedure: 38. RU cementers and lay 150'of cement on top of plug through 1-1/2"string. 39. Remove well cellar and cut conductor,casing,and 1-1/2"string to 3'below ground level.Weld abandonment marker per 20 AAC 25.120. Photo document casing cut-off and welded marker. If you have any questions, please feel free to contact me. Thanks, Taylor W.Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell From:Taylor Nasse Sent:Tuesday,January 31,2017 4:09 PM To: 'Schwartz,Guy L(DOA)'<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com>; Michael Erstrom<merstrom@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641(PTD 202-256/257) Hi Guy- Per our conversation earlier, on step#9 we will modify to the following: - MU 9-5/8" CIBP on 2-7/8" work string and set at 3,300'.Tag top of CIBP,then pick up and lay 540' of cement(41 bbls).After cement has sufficiently set, pressure test cement and plug to 1,500 psig. Continue with sundry procedure at step#34. 5 • Also, attached are the drilling daily reports that were in the well file regarding cementing of the surface casing and intermediate casing. Looks like they noted cement returns on both, but we will confirm as part of the Post WO Rig abandonment procedure and add additional cement as needed. Let me know if you have any questions. Thanks, Taylor W.Nasse,PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday,January 26, 2017 10:34 AM To:Taylor Nasse<tnasse@hilcorp.com> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Taylor, The modified procedure is approved as written. Make sure you document the first passing pressure test with RTTS in step#6 on chart for 30 min. (to document the reservoir is isolated). Good job on writing this new procedure up in a logical and clear manner. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent:Thursday,January 26, 2017 10:03 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Hi Guy- 6 Per our conversation yesterday, below is the revised procedure for the Kasilof#1 1L1 P&A sundry: 1. RIH and set CIBP in Kasilof#1 below dual string packer at 9,900'. 2. RIH and set CIBP in Kasilof#1L1 below dual string packer at 9,890'. a. Attempt MIT(If it passes,follow approved sundry) 3. RIH with chemical cutter and cut Kasilof#1 above dual string packer in the middle of a joint at+/-9,400'. 4. RIH with chemical cutter and cut Kasilof#1L1 above dual string packer at the middle of a joint at+1-9,430'. 5. Continue with steps 27—31 of the sundry(pull tubing strings). 6. MU 9-5/8" RTTS on 2-7/8"work string and RIH to 3,300'. Set RTTS and test below packer to 1,750 psig. a. If pressure test doesn't pass, RIH to 9,000' and pressure test to 1,750 psig. After a good test, move up in 500' intervals to find location of problem area. 7. POOH. 8. RIH with 9-5/8"CIBP on e-line and set at+/-9,390'.Tag top of CIBP after it is set to verify. POOH. If RTTS pressure test passes at 3,300': 9. MU 9-5/8" CIBP on 2-7/8" work string and set at 3,300'. Close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up and lay 540'of cement (41 bbls). Continue with sundry procedure at step#34. If RTTS pressure test passes between 3,400' and 3,900': 10. MU 9-5/8" CIBP on 2-7/8"work string and set at location where RTTS pressure test passed. Close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up and lay volume of cement needed to place TOC at 2,760'. Continue with sundry procedure at step#34. If RTTS pressure test passes below 3900': 11. MU 9-5/8" CIBP on 2-7/8" work string and set at location where RTTS pressure test passed. Close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up and lay 100'of cement(8 bbls). Continue with sundry procedure at step#32. Please look over and let me know if this is acceptable. If you have any questions,feel free to contact me. Thanks, Taylor W.Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell From:Schwartz,Guy L(DOA) (mailto:guy.schwartz@alaska.gov] Sent:Thursday,January 26,2017 8:42 AM To:Taylor Nasse<tnasse@hilcorp.com> Cc:Chad Helgeson<chelgeson(@hilcorp.com>; Donna Ambruz<dambruz(@hilcorp.com>;Wade Hudgens-(C) <whudgens(@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Taylor, The two additional CIBP are approved..get me a revised procedure as soon as possible for the rest of the opertain. Regards, Guy Schwartz Sr. Petroleum Engineer 7 AOGCC • • 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent:Wednesday,January 25,2017 4:40 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Hi Guy- I haven't finished typing up the revised procedure based on our conversation today, but I just wanted to let you know that we're moving forward with setting a CIBP just below the dual packer at+/-9,875' in each string. I'll have the revised procedure to you early tomorrow, if that works for you. Thanks, Taylor From:Schwartz,Guy L(DOA) [ma ilto:guy.schwartz@alaska.gov] Sent:Thursday,January 19,2017 11:30 AM To:Taylor Nasse<tnasse@hilcorp.com> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@thilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Taylor, Thanks for the update... no issue with your slight modification to the procedure. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent:Thursday,January 19, 2017 10:21 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) 8 • • <whudgens@hilcorp.com> Subject: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Hi Guy- Just wanted to bring you up to speed on the Kasilof#1/1L1 P&A progress—we have both wellbores plugged back with CIBP's and 25'of cement and have tagged and verified TOC.We have also punched holes in both tubing strings and circulated produced water,so we are about ready to pressure test the plugs. I was hoping to be able to do it yesterday before Moncla was ready to rig up but we were hampered by-30 degF temperatures and were having difficulty keeping the pump truck thawed,so I wanted to let you know that we are planning to change the order of a few steps in the sundry procedure.The current plan is to pressure test the plugs using the pumps on the workover rig and then we will rig up e-line over the BOP's to cut the tubing strings(basically moving steps 15, 18 and 20 after step 26 in the procedure). If you have any questions or need additional information, please feel free to contact me. Thanks, Taylor W. Nasse,PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell 9 • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Thursday,January 26,2017 10:34 AM To: Taylor Nasse Cc: Chad Helgeson; Donna Ambruz;Wade Hudgens- (C) Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/ Taylor, The modified procedure is approved as written. Make sure you document the first passing pressure test with RTTS in step#6 on chart for 30 min. (to document the reservoir is isolated). Good job on writing this new procedure up in a logical and clear manner. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC SCANNED APR 2 8 20!?, 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent:Thursday,January 26, 2017 10:03 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Hi Guy- Per our conversation yesterday, below is the revised procedure for the Kasilof#1/ 1L1 P&A sundry: 1. RIH and set CIBP in Kasilof#1 below dual string packer at 9,900'. 2. RIH and set CIBP in Kasilof#1L1 below dual string packer at 9,890'. a. Attempt MIT(If it passes,follow approved sundry) 3. RIH with chemical cutter and cut Kasilof#1 above dual string packer in the middle of a joint at+/-9,400'. 4. RIH with chemical cutter and cut Kasilof#1L1 above dual string packer at the middle of a joint at+/-9,430'. 5. Continue with steps 27—31 of the sundry(pull tubing strings). 6. MU 9-5/8" RTTS on 2-7/8"work string and RIH to 3,300'. Set RTTS and test below packer to 1,750 psig. a. If pressure test doesn't pass, RIH to 9,000' and pressure test to 1,750 psig. After a good test, move up in 500' intervals to find location of problem area. 7. POOH. 8. RIH with 9-5/8"CIBP on e-line and set at+/-9,390'.Tag top of CIBP after it is set to verify. POOH. If RTTS pressure test passes at 3,300': 1 111 9. MU 9-5/8" CIBP on 2-7/8" wk string and set at 3,300'. Close annular ancT orpressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up and lay 540'of cement(41 bbls). Continue with sundry procedure at step#34. If RTTS pressure test passes between 3,400' and 3,900': 10. MU 9-5/8" CIBP on 2-7/8"work string and set at location where RTTS pressure test passed. Close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up and lay volume of cement needed to place TOC at 2,760'. Continue with sundry procedure at step#34. If RTTS pressure test passes below 3,900': 11. MU 9-5/8" CIBP on 2-7/8" work string and set at location where RTTS pressure test passed. Close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up and lay 100'of cement(8 bbls). Continue with sundry procedure at step#32. Please look over and let me know if this is acceptable. If you have any questions,feel free to contact me. Thanks, Taylor W.Nasse,PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday,January 26,2017 8:42 AM To:Taylor Nasse<tnasse@hilcorp.com> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Taylor, The two additional CIBP are approved..get me a revised procedure as soon as possible for the rest of the opertain. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.aov). From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent:Wednesday,January 25,2017 4:40 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) 2 <whudgens@hilcorp.com> • • Subject:RE: Kasilof#1/1L1 Sundry 316-640/641(PTD 202-256/257) Hi Guy- I haven't finished typing up the revised procedure based on our conversation today, but I just wanted to let you know that we're moving forward with setting a CIBP just below the dual packer at+1-9,875' in each string. I'll have the revised procedure to you early tomorrow, if that works for you. Thanks, Taylor From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday,January 19,2017 11:30 AM To:Taylor Nasse<tnasse@hilcorp.com> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com> Subject: RE: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Taylor, Thanks for the update... no issue with your slight modification to the procedure. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent:Thursday,January 19, 2017 10:21 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson<chelgeson@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com>;Wade Hudgens-(C) <whudgens@hilcorp.com> Subject: Kasilof#1/1L1 Sundry 316-640/641 (PTD 202-256/257) Hi Guy- Just wanted to bring you up to speed on the Kasilof#1/1L1 P&A progress—we have both wellbores plugged back with CIBP's and 25'of cement and have tagged and verified TOC.We have also punched holes in both tubing strings and circulated produced water,so we are about ready to pressure test the plugs. I was hoping to be able to do it yesterday before Moncla was ready to rig up but we were hampered by-30 degF temperatures and were having difficulty keeping the pump truck thawed,so I wanted to let you know that we are planning to change the order of a few steps in the sundry procedure.The current plan is to pressure test the plugs using the pumps on the workover rig and then we will rig up e-line over the BOP's to cut the tubing strings(basically moving steps 15, 18 and 20 after step 26 in the procedure). If you have any questions or need additional information, please feel free to contact me. 3 • • Thanks, Taylor W.Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell 4 Ka,5itoF t rth 2.6 Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Wednesday, January 25, 2017 4:04 PM elet ((V$I t7 To: Wade Hudgens - (C) Cc: Regg,James B (DOA) Subject: RE: Moncla 401 BOPE Test Attachments: Moncla 401 01-23-17 Revised.xlsx Wade, Attached is a revised report changing the FSV Misc.field to reflect "NA" and changing the Full Pressure Attained time to reflect 247 (what it initially failed at). Please update your copy. Thank you, Phoebe - Phoebe Brooks N �� '� 0201-4 Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From:Wade Hudgens- (C) [mailto:whudgens@hilcorp.com] Sent: Wednesday,January 25, 2017 5:32 AM To: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov>; Regg,James B (DOA)<jim.regg@alaska.gov>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov> Cc: Donna Ambruz<dambruz@hilcorp.com>; Taylor Nasse <tnasse@hilcorp.com> Subject: Moncla 401 BOPE Test Moncla 401 BOPE Test Form attached with Test Charts and Procedure. Thank You, Wade Hudgens Hilcorp WSM Cell 903-331-6711 Office 907-283-2505 1 • STATE OF A • LASKA OIL AND GAS CONSERVATION COMMISSION '1)1" \12yV1 BOPE Test Report Submit to: jim.regq( alaska.gov AOGCC.Inspectors a(�.alaska.gov phoebe.brooks@alaska.gov Contractor: Moncla Rig No.: 401 DATE: 1/23/17 Rig Rep.: Gamaliel Salas Rig Phone: 283-2510 Operator: Hilcorp Alaska Op. Phone: 903-331-6711 Rep.: Wade Hudgens E-Mail whudgens( hilcorp.com Well Name: Kasilof South 1 - PTD# 2022560 - Sundry# 316-640 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250-2500 - Annular: 250-2500 - Valves: 250-2500 - MASP: 2300 - MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P • Well Sign P - Upper Kelly 0 NA Housekeeping P Rig P ' Lower Kelly 0 NA PTD On Location P . Hazard Sec. NA Ball Type 2 P , Standing Order Posted P . Misc. NA Inside BOP 2 - P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 . 13-5/8"5M • P - Pit Level Indicators NA NA #1 Rams 1 • 3-1/2"Dual Flex ' P Flow Indicator NA NA #2 Rams 1 • 2-7/8"-5"VBR • P . Meth Gas Detector P P , #3 Rams 1 Blind - P H2S Gas Detector P • P • #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 2-1/16"5M • P - Inside Reel valves 0 NA HCR Valves 2 • 2-1/16"5M • P • Kill Line Valves 2 - 2-1/16"5M P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3100 P CHOKE MANIFOLD: Pressure After Closure(psi) 1700 • P Quantity Test Result 200 psi Attained(sec) 41 - P • No.Valves 8 - P • Full Pressure Attained(sec) 247 FP •,/ Manual Chokes 2 - P Blind Switch Covers: All stations Yes Hydraulic Chokes 0 NA Nitgn. Bottles#&psi(Avg.): 6x1900 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 1 V Test Time: 6.5 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: One F/P recorded,the Accumulator Full Pressure Attained was 247 seconds.Troubleshoot problem. Cleaned all three suction fitlers and retested good at 218 seconds. AOGCC Inspection 24 hr Notice Yes Date/Time 1-21-17 17:36 Waived By Jim Regg Test Start Date/Time: 12:00 1/23/2017 , (date) (time) Witness Test Finish Date/Time: 18:30 1/23/2017 Form 10-424(Revised 12/2016) Moncla 401 01-23-17 Revised.xlsx J Z42 25100 • Date: Monday,January 23,2017 64 MONCL A BOP Test Procedure Well: Kasilof #1 / 1L1 Closed Open 3-1/2" Dual Rams 1 IBOP#1 &#2 K-3, C-3,C-9,C-10 TIW#1&#2 IBOP#1 & #2 2 HCR Kill C-10& K-3 C-6,C-7, C-8 (B)Function Choke 1 &2 (8)C-6, &C-8 Manual Kill HCR Kill 3 Choke 1 & 2 C-4&C-5 Pull 3-1/2"Jts, M/U 2-7/8"Jt C-7 4 Annular, IBOP#1 HCR Choke 2-7/8" Rams Annular TIW#1 IBOP#1 Manual Choke HCR Choke Move test line to choke manifold 6 Manual Choke Blinds C-3 -' S 6 AM r 0000000". 7 /< --' : ----- 4,500 ,., 4, ,,,V '''P „.:'`1---' :',,--- -- -.',- -\-t----1 ;____:_ ------ -----__:.--"---:-,°° : -'''‘,,'N•N::\' . / ''' VO ','>'''''''' -' ''-: --L : ' : - : -----..'' -`.Y‘O ' '.. \ N N '''' 4) --`'3 ,/' .://r ",00 , .'_AL 1 .:---7"----7--1 ___:._____;:_..; - .'-----,-. 9°0 -----,2-<,NN, \\N\ / / 7 '' ' /- ‘,.00 Olt, ',. i,, ,_,_,:_' r_ --------,_3°° '-'-----,..'''''s. . - \\. \ \ 1 �/ / .:�ADO ,•^ . 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MC MP 5000 ��t�111% is •IU��,t i �l�fIfl/ uni m 1► m1 � 111tAILr��e Ul �'in��U�ina '\� i 1Hi I t y�{`11 f1--.-11;1:1 �� '��'f ll �+��n1tr �Qn, 1 METER_�_._.____ 111NI�tiiN� 111�1'�111�1i1'v t� � �� ILII 'I1il1i11t((( R((ff II( �ii t�i ii I Ii �p ; f�� ' Il� liI I RINI611ART PUT ON TKE --�"� ��!) �p��r l��I��igl � I� CH 3 / r r!i1 II� iit q� PIAM � _ ____Mt��1 �rr�rr�� («11f • 1 •'��'Ol 1 •1Rlp \r,�, 1��" OCATION kr.: /. /iL. _ gyp t �r1N �i/ �' IIll 11` ,r` ,1,►tm�e \\\ �� . REMARKS 1`4 7- ,-1--t-----/14.410141404144�►' t � 1t1 \ �� "`�� a /\\�\\\\\\\\\\\\\\\�\\�\\\ �\�\\� \\\�� `` Pm zo2-zsioo 'o,; .,, lJiI**et, 11111,„r"' ii..• ‘ ...:\"-ssp......,otil:VC #4,44/5";1. ' . ‘111\1* \ A* . .°.o.fte4fsazsaov.vft,4# -4 4410,0# ...4.... ,....0.0......4. , \,.. \444 1,...,-AT-, .....1.60.000.,..,, ,,c,.. 4, , ,, v' ‘‘,,,v,\ � V t,, \ \��`�'� 0601--_ �'. to )t) /744%,./.....Rjr, . 01/0-4° ''' ' � .//- ,,,,v,\.‘„, t, 'oc,:'' '.; '. : U Cti �. s � a~ U�4 \\V.' Nib. N, . 000,p,,.... . '''' .. . , ...,,,._,,, , .,,., , ,:::: , ,,,,,,...,, ,., , oc: 'N,:.' ,,N...,, \ '''',. ', . ''''.'''' ' ''' '...7.'''''..-.4*7.".'.''''.. 1 ...,,'.. ." ,, ', ../,'''''', OC? .. ,r /r --`--- w � b r' • • SOF THE STATE Alaska Oil and Gas ';1 of LAsKA Conservation Commission mt f tt 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ff, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov ®® AR Cs, a� rS4 Chad Helgeson S��}v ��;�1� ,� ; Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Kasilof Field, Tyonek Undefined Gas, Kasilof South 1 Permit to Drill Number: 202-256 Sundry Number: 316-640 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, P Cathy . Foerster Chair DATED this day of December, 2016. RBDPAS ! Jr„ c 5 2017 • 0RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION O 'z C 2 2016 , APPLICATION FOR SUNDRY APPROVALS / / 20 AAC 25.280 A C 1.Type of Request: Abandon 2 • Plug Perforations ]• Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend El Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:.-Rk $readoacj- 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: �7££- Exploratory Q , Development ❑ 202-256 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20520-00 • 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 ❑ No 2Kasilof South 1 9.Property Designation(Lease Number): ADL-0384529, • 10.Field/Pool(s): ADL-0384534,ADL-0391591,FEE-Hilcorp • Kasilof Field/Tyonek Undefined Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 17,545' 9,642' 17,404' 9,517' -2,300 psi N/A N/A Casing Length Size MD TVD 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 19' 7" 9,935' 5,194' 8,160psi 7,030psi Liner 7,581' 3-1/2" 17,504' 9,594' 10,160psi 10,540psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,923' Packers and SSSV Type: GT Dual Pkr; Packers and SSSV MD(ft)and TVD(ft): 9,853'MD/5,161'TVD ZXP Pkr;N/A 9,923'MD/5,189'TVD;N/A 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑., ' 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 ❑✓ . 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@hilcorp.com Printed Name Chad HelgesongeTitle Operations Manager Signature ��% /may- - Phone 907-777-8405 Date 1 z f 2Z/I 6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: t - 62_14° Plug Integrity ji BOP Test [i Mechanical Integrity Test ❑ Location Clearance ❑ Other: X 2 5'0a 5.: Gi f' -7.,,„..„-.( /,-- f'_` yy i - a+Z int c,c,,,_,,,.......-4 C' 5% G-,„ _.if/c--nvt— / W,�-I�.i J � oi,e, Post Initial Injection MIT Req'd? Yes ❑ No ❑ l I Z '1, 14 Lt Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: ) 0 --10 RBDMS 0-- Ji-,i1 t D 2017 APPROVED BY / Approved by: d,_.1J COMMISSIONER THE COMMISSION Date: , 10— (-) Ritelp4A yam- dtoofap�� SubsinForm ane Form 10-403 Revised 11/2015 valid for 12 months fro///111111 the date of approval. Attachments in Duplicate • H • • Well Prognosis Well: Kasilof South#1/111 Hilcoru 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' ND (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. • ct'43 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. /1 cr©P ' ?- 6. MU 3 1/2"tubing_punchand punch tubing at+/-3.220'. 1....---",--1....---", '� KS#1L1 wellbore 7. MU 4-1/2" CIBP and setting tool. I-) 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'. --e —* 0's" 12. RD e-line. /0 :... Pumping Procedure: 13. Bleed off any pressure on KS#1/KS#1L1. octet/ere()) 14. Connect to KS#1 and/or KS#1L1 wing valve and fill with produced water. 4rN o� �/� a. Total wellbore volume: 864 bbls .' 5-:•,s- "�-15. Pressure test CIBP's to 1,750 psig (limited to 70%SMYS of 9-5/8" L80 40 lb/ft casing). _____ Ccr„4, ,. t.- / se a=L-µ- /c` • in • • Well Prognosis Well: Kasilof South#1/111 Hilcoru 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 �A, 17. RIH and tag top of cement and verify top at 16,925'. OLi 1 . 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 e-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. F 25. NU BOPE with dual pipe rams in the upper ram cavity(see schematic). Make up blanking ported test OL sub to test joint to both tubing hangers. Test to 250 psi low/2,500 psi high. LD test joints. Make up 2- ,' k" 7/8" test joint to test VBR and annular.Test to 250 psi low/2,500 psi high. Install TWC. Test blind \•e rams. Record accumulator pre-charge pressures and chart tests. 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. UQP 32. MU 9-5/8" CIBP and TIH on 2-7/8" workstring to+/-2,960' and (100' below surface casing shoe). ,216D 33. Set CIBP, close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up y and lay 200' of cement on top of plug. POOH. c kge, 34. MU 9-5/8"CIBP and TIH on 2-7/8" workstring to+/-150' and (150' below ground level). C i sv 35. Set CIBP, close annular and pressure test plug to 1,500 psig. Open annular,tag top of CIBP,then pick up L and lay 150' of cement on top of plug. POOH. 36. RD Moncla#401 WO Rig. Post WO Rig Procedure: _/r/c#+ .-2—p1s-"t,Jrv- 'Cp (4.1;7 zess 37. Remove well cellar and cut conductor and casing to ground level.Weld abandonment marker per 20 AAC 25.120. < 3 4,4c z S• /7 0 f--; 3 42+-. low CtL . re- a Attachments: pi„4, J.e.u- "`ft /C"-r- 1- ,L,J 1. Actual and Proposed Schematic Weide-, /0.0 2. BOPE Schematic 3. Wellhead Diagram 4. RWO Sundry Revision change Form ye/L--z7 /4, • • IIKasilof South #1 / 1L1 SCHEMATIC LLCHileorp Alaska,LLKasilof 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 ___..0 IL Chemical Injection Nipples tii Conductor 2540'and 2544' M 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 It 68 ppf BTC Bottom 2860'MD 2383'TVD Size-3-1/2",9.3#,L-80,Hydril 533 Extends from GT pkr to surface r ■ I •I 16"hole with+/-750 sks 12 ppg cement t . • . GT Dual Strang Packer w/top @9853'MD Size- 9-5/8"x 3-1/2"x 3-1/2" `. � ‘b I If ! Intermediate Casing 40 an BT0 Bop 9'MD Dual Tubing Strings Ir// 40 and 47 pp BTC Bottom 9916'MD 5186'TVD 3-1/2",9.35,L-80,Hydril 533 11Y i Scoophead Diverter Underreamed Section (SHD) t Size-17-1/2"(9856-10020'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 T' p; Leg-Extended Leg Size-7"x 29# , u s Size-9-5/8"x 7"x 7" 9916'-9935'MD i F Leg Size-7"x 29# 1 ' 9916-10533'MD ZXP Liner Hanger Packer l FHL Production Packer Size-7"x 3-1/2"w/top @ 9923' I Size-7"x 3-1/2"w/top 10,909' SLPR Liner Hanger 4I. Size-3-1/2 a 7"with top at 10323' h 4'11 I l.. RS Nipple 3-1/2"Liner 3-1/2"set at 10333'MD 'I Tyonek Perfs: i 1.7 . Tvonek Perfs: i I 16,972'-16,996'MD,24 ft, PJ2506 3/24/2004 16438-16454'MD,16 ft PJ2506 4/9/2004 17,012'-17,050'MD,38 ft, PJ2506 3/22&23/2004 3-1/2"Liner 17280-17320'MD,40 ft PJ2506 4/68,8/2004 17385-17409',MD 24 ft PJ2506 4/5/2004 iii TD:17,545'MD/ 9642'TVD N— ------ �_ TD:17,665'MD/ 9999'TVD Liner 1 Liner 0 L 1 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#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' 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. i • ! II Kasilof South #1 / 1L1 PROPOSED tlila.urp.4laAka.,-,.,. Kasilof Field SCHEMATIC 4Y1 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 1 , Sec.28,T3N, R12W,SM ,e Conductor Cast Iron Bridge Plug @ 150' Dump 150'of cement 20" K-55 Top 0'MD 133 ppf PE Bottom 130'MD 130'TVD Cast Iron Bridge Plug @ 2,960' . Surface Casing Dump 200'of cement 13-3/8" K-55 Top 0'MD Dual Production Tubing 68 ppf BTC Bottom 2860'MD 2383'TVD Size-3-1/2",9.34,L-80,Hydnl 533 Extends from GT pkr to 3,200' •s r I II 16"hole with+/-750 sks 12 ppg cement I GT Dual String Packer wltop©9853'MD Size- 9-518"x 3-1/2"x 3-1/2" , WM, Intermediate Casing 9-5/8" L-80 Top 0'MD Dual Tubing Strngs �_ I�II� III��/ 40 and 47 pp BTC Bottom 9916'MD 5186'TVD 3-1/2",9.3#,L-80,Hydril 533 I Scoophead Diverter li � Underreamed Section (SHD) Size-17-1/2"(9850'-10020'MD) Size- 9-518"x 3-1/2"x 3-1/2 , I11 \\ II TAML Level 6 FORMation Junction 11 r FORMation Junction with Size 9-5/8"x 7"x 7"�_p- 'I Leg-Extended Leg Size-7"x 29# ; IN , Size-9-5/8"x 7"x 7" 9916'-9935'MD 11!—F J Leg Size-7"x 29# II I ;E 9916-10533'MD ZXP Liner Hanger Packer i i. i FHL Production Packer Size-7"x 3-1/2"w/top CO 9923' 1 IP'Lj 1( Size-7"x 3-1/2"w/top 3-1/2"Liner ,'qI 1Q909' 1SLPR Liner Hanger Size-3-1/2 x 7"with top at 10323' Cast Iron Bridge Plug @ 16,950' .)a?P RS Nipple Dump bail 25'of cement S I 1 ( - 3-1/2"set at 10333'MD Tvonek Perfs: ) It '`'3 PS Tvonek Perfs: . �yy 16,972'-16,996'MD,24 ft, PJ2506 3/24/2004 I 16438-16454'MD,16 ft PJ2506 4/9/2004 3-1/2"Liner 17280-17320'MD,40 ft PJ2506 4/ 04 17,012'-17,050'MD,38 ft, PJ2506 3/22&23/2004 \ 17385-17409',MD 24 ft PJ2506 4/5/20045/2004&8120 TD:17,545'MD/ 9642'ND IN— �_ -_�. TD:17,665'MD/ 9999'ND Cast Iron Bridge Plug @ 16,400' Dump bail 25'of cement Liner Liner 3-1/2" L-80 Top 9923'MD 5189'ND 3-112" L-80 Top 9918'MD 5187'TVD 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 • • II Kasilof Field Kasilof#1 / 1L1 12/21/2016 1bi...rp %h k...1.1.1 ola • 13-5/8" 5M Annular 3-1/2" Dual Flex cr_—__t_6122u2Au23 m E i � 1. 11111Till2-7/8"- 5" Variables IIIN c I emit I i4 IEimill 1 1 mit Blinds II amill 1 i4 Em l ,ps II N 2-1/16" 5M choke and kill valves __ III III III III IP TERI 60, J Mud Cross 1110i � 0 III III III 111111 11110 III it FII • • Kasilof Unit Kasilof#1 12/12/2016 ifilrorp Al0.h4.11C Kasilof Unit Tubing hanger,MB-196, Kasilof#1 Dual,13 5/8 X 3'A X3 34, 3.725"MCA left hand acme 20X133/SX95/8X3hX3'/: lift X 334 IBT susp,w/3" Type H BPV profiles,3: 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 111 III Tree,dual block,swab, WKM-M,11"5M FE XI 4 31/85M X3 1/8 5M,w/CIW seal pockets,AA trim,5.047" centers L � �� a Iv.--dyP L - h t- oQ 9tP/GG,� d°P L �`^, J y��,S` o ZP F p�°2�OP 42P47 .r '+ � • v4 19yoFo° 6 9 r� a `VVVV �� 0' �• G>�goA 8s q9r^Tiffs �•.,••'• ,� 4 1011 MI Tree,dual block,upper 11`ti master,WKM-M,11"SM FE sal .1 X 3 1/8 5M X 3 1/8 5M,w/ Mg "✓ , CIW seal pockets,AA trim, 5.047"centers !' Tree,dual block,master, ve WKM-M,11"5M FE X 3 1/8 J• 5M X31/8SM,w/CIW seal L-7 pockets,AA trim,5.047" l'',! centers r0 Adapter,Dual,Vetco Gray, 13 5/8 5M stdd X 11"5M stdd X 3 1/8 X 3 1/8 Bores, set up on 5.047"centers and CIW seal carriers . _ T W Multi bowl,Vetco MB-196, ...BF iro n. I :\I.- 135/83MstddbottomX --Aft..., Control line X2 13 5/8 5M FE top,w/ 2-2 1/16 5M SSO, 1 (J Guide screw for dual hangers oL.V.,,,..J (� .10:.•t.1 1.4 Starting head, III Vetco MB-196, 11111 -..--"--- 13 = 13 5/8 3M X 13 3/8 VG-Loc UM 011111111 bottom,w/2-2"LPO II 11, iiir lig ,L IIIII 20" 13 3/8" 1 1 J 9.625" 3.5" 3.5" ~ • • LID 0 N Produced Gas (Thousand Cubic Feet ("MCF") per Day) N O O O o 0 0 0 0 0 0 0 0 0 0 0 ', epi .-1 -1 00 l0 4 N O O N (n (7 s O lJ L oa o >. l 4,,_ p , = 'r0 , i m P Co -1 •c (9 4x l0 .• o lj rt P a �l0 0 0>0 �i tel, a) Q l lkr) � E I' Ln 61,E 0 m tV N he 'CV of S2 u • 6l l0 S2 E N DCr. C> l° v ro ^ �_ ;, > N o G M • l c o3 l� 4-+ � l7 o a 2 V �2E to 3 I— .I O ll l0 o Q OV V ii.--- �Cs73 ib N C6 = -0 l i O o 0 O Ol,Q, v (n a d c c T " O U' < 0r l0 o W U• L 9 yl 9_ ,r, (n Q U U 60/ 0 0 Q �4 F° o O u Y a i - OJ a a • a -it, U - 0 'I.0 ' ,6O • T IO v OSP, * ._ I• 0 - 90vh (1 on i Q 0 ,9 0, I V1 M N r1 0 Ql 00 N l0 Y1 v. en N r1 0 4t') I-1 r1 a-I .-I r1 r1 1, 0 Aea aad aale/N}o spins Jo Aea Jad dip }o sia,i.iee j UU 0 I 0 a .. • O C '13 °..... 00 / CD k ° 2 2 Q - ® ■ c 2E a2E CO 0 2 0.� § ƒ « � E 0 § � ) R E < § m F 2 ID 0 £ k < •- z0 2 cit a) v V .0 « amd in §��2 t� C 0. 0 � E § .(1." n a) ■ $ R © Pct IT z a a (11 2 at t � o 0 0 COat fg 1- k / ko - -71 li CD - _oo p 7 / 4 .- � � as � f » "0 AQ ■ E 7ci 2 b « ma k k c § L. 0 2 go - . Ac 2 . k a a) \ 0) a"2 § a §f /s . 2 2p c W a) § ■ § � ro a) . o 0. km 0. « @ ' 0 ■ *4 cid Q .2 % / § 0 _ R » cd � m . 0 A _a / a ■illk 0 « 3 . . O 09 0 50 0 ■ k k ¢ U ■ Q �. � r 2 ,,( a..9 '� $ 0 c c k 9 < 0. e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ o:;¡ - :J.5fo Well History File Identifier Organizing (done) D Two-sided 11111111111 IIIIII!I o Rescan Needed 1111111111111111111 R~CAN ~ Color Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: o Poor Quality Originals: NOTES: OVERSIZED (Non-Scannable) ~9S of various kinds: o Other:: o Other: BY: ~ Dale If/Újoft; Date if / Jt /Ó b I 0 eo + I t1 = TOTAL PAGES 3/ r¡ ~t does not include cove~ 151 151 W\P 111111111111111111I Project Proofing BY: ~ 151 mf Scanning Preparation BY: Date: p Production Scanning Stage 1 Page Count from Scanned File: 3-LR (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: L· YES BY ~ Date 4-/:;i/Dfo Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO 151 ý\t P NO BY: Maria Date: 151 III IIII111I111111I1 Scanning is complete at this point unless rescanning is required. ReScanned 11111 II 1111111 "III BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • �v bl t _ , LASM a cjl SEAN PARNELL, GOVERNOR �T ALASKA OIL AND CAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 March 19, 2012 Mr. Jim Senn Operations Manager Marathon Oil Company P.O. Box 1949 a a�lk�� Kenai, Alaska 99611 Re: Failure to Test Safety Valve System Kasilof South #1 (PTD 2022560) Dear Mr. Senn: The Alaska Oil and Gas Conservation Commission (AOGCC) has received and reviewed the explanation from Marathon Oil Company (Marathon) regarding the failure to test the safety valve system on Kasilof South #1. That explanation was provided in response to the AOGCC letter dated February 17, 2012 following an internal investigation by Marathon. Two causal factors were identified: no clear point -of- contact and owner for Marathon's safety valve system testing program, and a breakdown in communications between field personnel and Marathon's regulatory compliance representative. The corrective actions that have been or will be implemented for all Marathon - operated well safety valve systems in Alaska were clearly described in your letter dated March 7, 2012. A subsequent meeting held on March 13, 2012 with Marathon's newly established single point -of- contact for safety valve system testing further described the corrective actions being implemented by Marathon. The AOGCC is satisfied with Marathon's effort to improve compliance with safety valve system testing requirements. No further enforcement action will be pursued regarding the Kasilof South #1 violation. Sincerely, '1)( --4 r—:-/4e01,/ Cathy P. Chair, Commissioner cc: AOGCC (via Inspectors via email) P II' . • -. \�; SEAN PARNELL, GOVERNOR ALASKA 0114 AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 February 17, 2012 Mr. Kevin Skiba Marathon Alaska Production LLC P.O. Box 1949 Kenai, AK 99611 Re: Notice of Violation Failure to Test Safety Valve System Kasilof South #1 (PTD 2022560) StAithEOFEB 1 7 2012 Dear Mr. Skiba: On February 7, 2012 the Alaska Oil and Gas Conservation Commission (AOGCC) inquired about the producing status of Kasilof South #1 and well safety valve system testing. Production records indicated that the well produced intermittently during January through August 2011. Last testing of the well safety valve system occurred on January 17, 2011; AOGCC did not witness this test. There are no records of safety valve system tests on Kasilof South #1 since January 17, 2011. Based on the previous test date, the well safety valve system should have been tested when Kasilof South #1 production recommenced in August 2011. Marathon did — subsequent to the AOGCC inquiry — test the Kasilof South #1 safety valve system on February 8, 2012. The facts noted above indicate Marathon failed to properly test the well safety valve system, which would be a violation of State regulations. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with an explanation of how this event happened and what has or will be done in the future to prevent its recurrence in Marathon - operated fields. In addition, Marathon is requested to provide evidence that the safety valve system on Kasilof South #1 was operable during the time when testing was not performed. You are reminded that 20 AAC 25.265 requires a completed well to be equipped with a functional safety valve system. Further, regulations require: "(h)(5) a performance test must be conducted semi- annually, not to exceed 210 days between tests, unless the commission prescribes a different testing interval based on test performance results." "(h)(6) a well isolated from its flow line or other production offtake mechanism need not be tested at the time of the required performance test state in this subsection, but the safety valve system must be performance tested not later than five days after the well's return to stabilized production or injection." • Notice of Violation February 17, 2012 Page 2 of 2 Addition guidance regarding well safety valve system testing is provided in Industry Guidance Bulletin 10 -004. The AOGCC reserves the right to pursue enforcement action in connection with the improperly set low pressure pilot at Kasilof South #1 as provided by 20 AAC 25.535. incerely, j Daniel T. Seamount, Jr. Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • -~-_ ~ ~~ 03/01 /2008 DO NOT PLACE -: , ~. ANY NEW MATERIAL UNDER THIS PAGE F:\I,aserFiche\CvrPgs_Inserts\Microfilm Marker.doc DATA SUBMITT¡L-c~~pt~~~CE REPORT 3/2/2006 Permit to Drill 2022560 Well Name/No. KASILOF SOUTH 1 Operator MARATHON OIL CO S'pc......d.- I r-I ðet ..zO~3 API No. 50-133-20520-00-00 MD 17545/ TVD 9642 r Completion Date 3/25/2004,/' Completion Status 2-GAS Current Status 2-GAS UIC N ----_._~- _._-~- REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Reeves Quad Combo: GR I Call Den I Neutron I Sonic I Array Induct (data taken from Logs Portion of Master Well Data Maint Logl Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH rCOg----------- ._---~~-~--_._._.._---- ----- ---- Mud Log 2 Col 196 17618 Open 1:óg Mud Log 2 Col 196 17618 Open ~ Mud Log Col 9940 17545 Open '1:Õg Mud Log Col 9940 17545 Open og See Notes Col 196 17618 Open J,Gg See Notes Col 9940 17545 Open I . Received Comments ReDrill1 ReDrill1 Drilling Dynamics Drilling Dynamics ReDrill1 Well CoreslSamples Information: Name Interval Start Stop 9940 17545 Sent Received Sample Set Number Comments L ~gs 4/2212004 1130 PB1 cuttings 2860 to 17618 ~ ADDITIONAL INFORMATION Well Cored? Y lJ Chips Received? -; I I~ Daily History Received? elN @iN . Formation Tops Analysis Received? a.J.J>V -~-~-- Comments: o µ. ~~, \\J((;I\.'" '1 t/ ~ (k. (J"i.... Ð t : Ll ~.,.. '1 1Lt 1"\, '''1 1): (ü:\-~ ,..4 ~~\( "') ~ _._"--~~----~ '" lIrc.J t b.- ~~Af1 ( ~j ~ ~~·V\ ~ ".;-;~Il.c..ð"") 14 ~'\ l.U -=t ~ 'M_ Compliance Reviewed By: Date: ~Q ~rn(p ., \ . . Marathon Oil Company RECEI\IED MAY 1 2 Z005 April 10, 2005 Alaska Oil & Gas Cons. L:ommìssion Anchorage Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Alaska Asset Team Northern Business Unit P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-1350 Attached and submitted for your records is the Form 10-407 for the completion work performed in the Kasilof South #1. This well was completed in the Tyonek formation in April 2004 and tested at 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~ 'b ~~~ Ken D. Walsh Senior Production Engineer Enclosures () t....~), t L 1-\ " a STATE OF ALASKA . - -;:, ALAS~ AND GAS CONSERVATION COMMIS IVED WELL COMPLETION OR RECOMPLETION REPORT AND!\IA0ß2 2D05 -.. 1a. Well Status: OilD G~ Plugged D Abandoned D ~'I£Jõli\~D WAGD 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Developmeni~(j ~ipl&~~r 1m! GINJD WINJD WDSPL D No. of Completions Other Service D StratinBhm-Š- D 2. Operator Name: 5. Date Comp., .)~y~ 12. Permit to Drill Number: MARATHON OIL COMPANY Aband.: 202-256 3. Address: 6. Date Spudded: r 13. API Number: P. O. Box 1949, Kenai, AK 99611-1949 October 14, 2003 50-133-20520-00 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 January 17, 2004 Kasilof South #1 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 4336' FSL & 507' FEL Sec. 25 T3N-R13W, SM 104' WildcatlTyonek Total Depth: 9. Plug Back Depth(MD+ TVD): 4402' FSL &786' FEL Sec. 25 T3N-R13W, SM 17,404' 9517' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 250209 y- 2310138 Zone- 4 17545' MD 9642' TVD ADL-384534, 384529, 389502 TPI: x- 237803 y- 2313961 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 237524 y- 2314017 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: GRlCallDenlNeutronlSoniclArray 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' 5186' 12-1/4" in place, 2200 sx NIA 7" 29# L-80 9916' 9935' 5186' 5194' 12-1/4" Cemented with 9-518" csg. NIA 3-1/2" 9.2# L-80 9923' 17504' 5189' 9605' 6-1/8" in place, 675 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) 16972-16996' MD, 24 ft PJ2506, 6 SPF, 0.35" EH 3/24/2004 3-112" 9923' 9853' 17012-17050' MD, 38 ft PJ2506, 6 SPF, 0.35" EH 3/22&23/2004 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.): NIA Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: 3/28/2004 24 Test Period -+0 9209 0 20 NIA Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 3319 N/A 24-Hour Rate ... 0 9209 0 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". None Lithology - interbedded sandstone, shale and coal. r~Fr~'-' .~'",., -,-"----, \ ,. , 3~ : ,. ~ í (ì , f ¡ /'j I , JPJ:ED i ! ! -:Ii ; (" 'j 1--, ssicm Form 10-407 Revised 12/2003 CONTINUED ON REVERSE NAME TVD 29. ORMATION TESTS Include and briefly su ze test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". -, 28. GEOLOGIC MARKE Beluga Tyonek 7880 13749 4378 Perf: 17031-17050 (3/22/2004)', MD 19 ft, built from NS SITP of 1500# to 6833 1600# in 1 hour, built to 1985# in 2 hours, SIFN built to 3984#. Added perfs: 17012-17031 MD, 21 ft, SIFN built to 3084# 3/23/2004 Added perfs: 16972-16996' MD, 24 ft, SITP 3089# Flow well 8219 MMCFPD @ 2933# FTP, 3/28/2004 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 Signature: t~0M,- Title: Senior Production Engineer Printed Name: Ken D. Walsh Phone: 907-283-1311 Date: 5/10/2005 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 (Motherbore- South Tan::¡et) KasHof Field 520' FSI.., 1340' FWI.., Sec. 28,T3N, R12W, SIIII J Baker TAMllevel 6 Formation Junction (Depth RT) Top of Junction @ 9901.49' Bifurcation Pt. @ 9916.54' Bottom of 7" leg @ 9945.02' c¡rmation Tops: Depth (MD} Depth (TVD} 7880 4378 13749 6833 L Conductor 20" K-55 Top O'MD 133 ppf PE Bottom 130' MD 130'TVD Surface Casing 13-3/8" K-55 Top O'MD 68 ppf BTC Bottom 2860'MD 16" hole with +1-750 sks 12 ppg Dual 3-1/2" GT Packer@9853' MD/5161' TVD. Intermediate Casing 9-5/8" 40 and 47 ppf L-80 BTC Top Bottom O'MD 9916' MD 5186' TVD Intermediate Casing 7" 211 ppf Top Bottom L-80 9916' MD 9935' MD NV 5186' TVD 5194'TVD 12-1/4" hole with +1-1550 sks 12.7 ppg + 650 sks 15.7 ppg TD: 17,545' MD I 9642' TVD 3-1/2" L·BO Top 9923'MD 5189' TVD 9.2ppf Hydril563 Bottom 17504' MP 6-1/8" hole with +1- 675 sks. 12.7 ppg cement. KasUof>South #1 KasilofFleld Kasilof South #1 (Motherbore" South Tar!:1et) KasHof Field 520' FSL, 1340' FWL, Sec, 28, T3N, R12W, SM Kasilof Field 520' FSL, 1340' FWL, Sec, 28,T3N, R12W,SM K-55 PE Top Bottom O'MO 130'MO 130' NO Surtace CasinQ ProdÙttióf\ Tubing Size - 3-1œ. 9.3#. L_ßO. Hy<lrtl533 Extends from GT pkrtosurface 13-3IS" 5Sppf K-55 BTC Top Bottom O'MO 2S60' MO 2383' NO 15" hole with +1- 750 sks 12 ppg cement S¡ze~ Intermediate Casino 9_5IS" l-SO 40 and 47 ppf BTC Top Bottom O'MD 9915' MO 51S5' NO 3·1/T,9.3#. Size - 9-5/8" x 3-112" x 3-112" Leg Size- r x 29# 9916'·9935· MD T' Leg Size., 7" x 29#- 9916'·10533· MD Size- 7" x 3_112" w/top@10,909' TO: 17,545' MO I 9542' NO liner 3-112" L-BO Top 9923' MO 9.2 ppf Hydrìl 553 Bottom 11504' MD 5" hole with +1- 515 sl\s. 1:1.1 ppg cement. 51B9' NO 9505' NO TO: 11,665' MO 1 9999'NO liner 3-112" L-BO Top 9.2ppf Hydrìl563 Bottom 6" hole with ...1-160 sl\s.12.1 þpg cem<;nt. 8 g ~ " " " .. () 8 ~ '1: ~ >-< n U2 8 n > t""' t>J 8 ~ I i~i~ii ~~~ ~x~rr;:~iji!lio! . m::! "" ~2@~Þ.~ ~; ~ t~··· ~~~~~" ;~ ~~~~~2~Þn !~ ~t;~~ ~~i1~iji ~~ ~~ ž!~~~ ~~ !§ ~f ~2~r~ b ~~m~¡: ~ ~~~ ~ ¡..J ~ U~ i ~H ~ ~~~ ~ ..'."~ - ..... --- - .I~ Q COOK INLET ß>;;;¡ÓZ€l@.¡j-':¡~.o+ m !! .. < ;¡ m r ~ ~ ~ ] þ ~ ~ ~ ~ ~ ~ ~ n ~ ~ ~ ~ ~ ~ ~ 5 , 5 " g ~ § m m ~ ~ ~ m ~ ~~ !:~ FF m~\!!i1 § ~ m Q -< l) tJ ~ ~ ~ I ~ ~ 2 ~ ~ þ ~ ~ ~ ~ . ~ ~ ~ ~ ~ m ~ ~ ~ ~ m ill 1; ~ i DRAWN BY: CRt.t CHECKED BY: MSM HDRl. SCALE: 1".. 100' \'ERT. SCALE: MIA SHaT 1 of 1 I I ' -~'-': x--_:'~.~--\: -_~J I J,?!íJ '. ~" I -~-~ II \t;;~·zf;: ¡ (I . r \'~\", ¡ r I ~ ,. I (! $I"~~ \.~. -~ (! I¡:~( ~> I:! I ¡!.~.L.I.: . "" / 1 ' " ..$.O~ ,., / ~í ',.'~_-- ,~,,~::.::'~'f¡~I":' 4",~~)I YI ~;:~" "IR-I i~,~ -+---,:;!j'! I '~~ .. ~ I I I~ ,> 'I ~~.¡!¡¡f h.:" i /: .1 ~- ~ ¡" "':C~N··i!i I !!!~:;:c_~ ~ \ -I I .: í ~ £~~ß~C ~~~~ i i ~ =1:' , k !~!:; ~ ¡¡II 'I..' ~ __ __ ~~ ~ij , ·,1 I ¡if - .. - "'-".=.' '~.~ _ . __ .-1. I \ L_-r,;,m - -/frm"""'-- ~-1' il 'OOTHoo><>noo:L~;:~;:'" -= ~ .~ --___~_ ____@\\~~\\i\\ G) o < r o -i ¡;; ~ '" '" R12W ~. TEL 9C7.2B:3.421 B F'AI< 907.293.3265 DATE Of FIElD WORK: 9/25/03 MARATHON OIL COMPANY KASlLOF PAD NO. 1 A9-BlL T 8UFIYEY R!V DATE ., F1ELO BOOK NO. 03-02 .œ NO. 033005 . . r2 () ;¿. '- ;1, 5" 0 "Motherbore" Kasilof South 1 Drilling (Reports 1 - 16) . KASILOF SOUTH 1 SUPERVISOR Gerard Ro er/Russ Trub FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Drillin at 390' OPERATION COMMENTS Finish RIU NAbors 273 rig. Cleaned out 20" conductor wI 16" bit to 130'. PIU Autotrak RST BHA and drill f/196' to 390'. 30.6 RIG NAME & NO. Nabors 273E R!G PHONE 907-260-6935 COUNTY/OTHER . 390 AUTH MD 17,300 MOC WI NR! 100.0000 ! CUM \A.JELL COST LfAKOFF Changed bit. Drilled 16" hole from 130' to 197' to allow for BHA P/U. 14:00 15:30 1.50 130 AF DRLSUR DRILL 15:30 17:30 2.00 130 AF DRLSUR TRIP 17:30 18:30 1.00 130 196 AF DRLSUR DRILL 18:30 19:30 1.00 196 196 AF DRLSUR TRIP 19:30 20:00 0.50 196 196 AF DRLSUR EQUIP 20:00 20:30 0.50 196 196 AF DRLSUR SAFETY 20:30 00:00 3.50 196 196 AF DRLSUR TRIP 00:00 03:30 3.50 196 353 AF DRLSUR DRILL 03:30 04:00 0.50 353 353 AF DRLSUR CIRC 04:00 05:30 1.50 353 353 AF DRLSUR TRIP 05:30 06:00 0.50 353 390 AF DRLSUR DRILL Move in I RU Rig, Finish RU Nabors 273 on turnkey rig MOBE, RU Slickline unit, Pump through all surface lines and pits. Finish building spud mud volume, RU and calibrate Epoch PVT system. Final rig inspection. (Note: will have to adjust daywork time, PIU 48 stds DP, MIU diverter, made spud mud during MOBE time - will adjust timelcosts when determined) Marathon operations began. Wash out to base of 20" conductor at 130' with 16" RR bit on 5-1/2" DP. POOH, stand back 2 stds drillpipe, PU 16" bit and monels De's. TIH. Spud Kasilof#1 at 1730 hrs 10/14/03. Drill 130' -196', deep enough to PU AutoTrak BHA. (Using caution due to two previous wells within 20' surface location wI poor directional surveys). Trip for BHA Repair Service equipment- Calibrate block height for Baker Inte and Epoch Safety Meeting- Handling and making up Autotrak BHA MU 16" bit and AutoTrak BHA and TIH. Drill 16" Open Hole 196' - 353' able to get (1) MWD survey. Circulate Clean Close pads on AutoTrak. Trip for BHA - PU jars and two joints of heavy weight. TIH. Drill Open Hole 353' - 390'. NOTE: Top Drive and block weight is 42,000 Ibs. Drillstring used: 5-1/2", 21.90ppf, S-135, HT55-375 COMMENTS Jeff Jones with AOGCC inspected and approved diverter system 10/14/03. Pre-spud I safety meeting held wi all crews. Printed: 4/8/2004 3:40:53 PM . . 46.0 10/15/2003 130.0 10/15/2003 196.0 10/15/2003 0-0---- O-O-NO-A-O- I-NO-BHA O-O-NO-A-O- I-NO-BHA 24Hr DIST 24Hr ROP Nabors Alaska Drilling 21 346.00 R&K Industrial 2 12.00 Marathon 2 48.00 BJ Services 2 10.00 Epoch Well Services 2 36.00 Scientific Drilling Control 1 14.00 M-I Drilling Fluids 2 24.00 Baker Hughes Inteq 6 132.00 Printed: 4/8/2004 3:40:53 PM . . 30.6 SUPERVISOR Gerard Ro er/Russ Trub FIELD NAME WILDCAT-FOR UNNAMED FIELD STATEJPROV Alaska CURRENT STATUS / MTS Drillin ahead at 930' OPERATION COMMENTS Drill from 390' to 726', attempt to kick off well with Autotrak RST, unable to turn as desired. TIH kickoff well and drill to 930'. RIG NAME & NO. Nabors 273E AUTH MD 17,300 MOC\'VI was RIG PHONE NRI I CUM WELL COST 907-260-6935 COUNTY/OTHER 100.0000 LEAKOFF Circluate clean and trip for motor I mwd. P/U BHA, MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 589.00 None 10/14/2003 ACCIDENT DESCRIPTION: REGULATORY INSP? N 06:00 09:00 3.00 390 555 AF DRLSUR DRILL Drill Open Hole Directional from 390' to 555', build to 1 degree and hold to confirm azimuth. 09:00 10:00 1.00 555 555 AF DRLSUR SURV Survey with wireline GYRO system. 10:00 14:00 4.00 555 726 AF DRLSUR DRILL Drill Open Hole Directional from 555' to 726'. Autotrak unable to achieve required tum rate to reach required azimuth. 14:00 15:30 1.50 726 726 TA DRLSUR CIRC DOTH Turn off AutoTrak, close tool, circulate hole clean for trip to pick up motor and MWD. 15:30 17:30 2.00 726 726 TA DRLSUR TRIP DOTH Trip for BHA 17:30 21:00 3.50 726 726 TA DRLSUR WAIT DOTH Wait on motor and MWD tools and motor. Align derrick top drive track, service topdrive and rig. Clean out shaker slop tanks 21:00 02:30 5.50 726 726 TA DRLSUR TRIP DOTH Unload and strap motor and MWD. RU MWD cabin and sensors. PU BHA, orient motor and UBHO and TIH to 726', 02:30 06:00 3.50 726 930 AF DRLSUR DRILL Drill Open Hole Directional, Kick off and drill from 726' - 930', ART - .3 hrs, AST - 1.8 hrs. 4 BHA DESCRIPTION Printed: 4/8/2004 3:40:57 PM . . . . .. ',.'..' " .. . '.'" ' .. . ,;. ,. . ......' . '.'. , , ., "'.. .. WELL NAME KB GL 24 HR PROG TMD TVD DFS DOL RPT# DATE KASILOF SOUTH 1 30.6 74.00 540.0 930 928 2 2 2 17-0ct-2003 > ., . . .' ' ' '. J'~ .,. '.. ' '. . . NO. 1 NATIONAL 12.000 6.000 85 356.00 1,250 712.00 2 NATIONAL I 12.000 I 6.000 85 356.00 1,250 I 712.00 0,0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 370.0 0.28 333.86 0.00 0.00 0.00 0.00 0.00 130.1 0.08 335.15 0.00 0.00 0.00 0.00 0.00 400.3 0.37 9.83 0.00 0.00 0.00 0.00 0.00 160.2 0.69 236.76 0.00 0.00 0.00 0.00 0.00 430.1 0.73 22.71 0.00 0.00 0.00 0.00 0.00 190.3 0.54 261.00 0.00 0.00 0.00 0.00 0.00 460.2 0.91 31.32 0.00 0.00 0.00 0.00 0.00 220.2 0.21 292.93 0.00 0.00 0.00 0.00 0.00 507.7 1.37 44.05 0.00 0.00 0.00 0.00 0.00 250.2 0.25 336.82 0.00 0.00 0.00 0.00 0.00 582.1 1.52 54.69 0.00 0.00 0.00 0.00 0.00 280.1 0.32 282.95 0.00 0.00 0.00 0.00 0.00 672.0 1.55 76.48 0.00 0.00 0.00 0.00 0.00 310.0 0.23 302.26 0.00 0.00 0.00 0.00 0.00 768.1 1.51 273.94 0.00 0.00 0.00 0.00 0.00 340.1 0.34 286.47 0.00 0.00 0.00 0.00 0.00 863.9 8.06 273.42 0.00 0.00 0.00 0.00 0.00 Nabors Alaska Drilling 22 323.00 R&K Industrial 4 15.00 Marathon 2 48.00 BJ Services 2 3.00 Epoch Well Services 2 36.00 Scientific Drilling Control 1 8.00 M-I Drilling Fluids 2 24.00 Baker Hughes Inteq 6 132.00 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 Printed: 4/8/2004 3:40:57 PM . vv· ..i¡i,/·,/i.· . ./ .vvv·.{/, .. ............ . >v .... i;\.......v.v....... .......v.. /. . ...vi. V .'/ V· ...... WELL NAME KB IGL 24 HR PROG TMD TVD DFS DOL RPT# DATE KASILOF SOUTH 1 30.6 74.00 1,535 3 3 3 18-0ct-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Gerard Roger/Russ Truby Nabors 273E 17,300 DX0309030CAPDRL FIELD NAME RIG PHONE ·MOC\\l1 NRI DAn v \AlI:'I I "'^~T . J""I .... ....~I I rn~T \ WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 20.000 (in) @ 130 (ft) 13.375 (in) @ 2,700 (ft) CURRENT STATUS / MTS 24 HR FORECAST DrillinQ at 1535'. Drill to 13 3/8" casing point, condition hole. OPERATION COMMENTS Drill from 930' to 1136' with mud motor and MWD. Trip for AutoTrak. Drill from 1136' to 1393'. Unable to achieve necessary build rate with AutoTrak. Trip for MWD and motor. Drill from 1393' to 1535'. .. .. .",. "F~l"' .;", ~...s ..€>' %XTI.··.j¥ MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? LAST RIG INSPECTION 575.50 None 10/14/2003 N 10/13/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: 06:00 08:30 2.50 930 1,136 AF DRLSUR DRILL Drill Open Hole Directional from 930' to 1136' with mud motor to achieve desired azimuth and build rate. ART - .5 hrs, AST - 2 hrs. 08:30 09:00 0.50 1,136 1,136 AF DRLSUR CIRC Circulate Clean 09:00 11:30 2.50 1,136 1,136 AF DRLSUR TRIP POOH and LD motor and MWD. 11:30 13:00 1.50 1,136 1,136 AF DRLSUR TRIP PU AutoTrak from derrick, upload data, and PU BHA. 13:00 13:30 0.50 1,136 1,136 AF DRLSUR TRIP TIH to 726'. 13:30 14:30 1.00 1,136 1,136 AF DRLSUR TRIP Wash/Ream from 726' to 1136', through section drilled with motor. 14:30 15:30 1.00 1,136 1,136 AF DRLSUR CIRC Circulate hole while downlinking and opening tool. 15:30 20:00 4.50 1,136 1,393 AF DRLSUR DRILL Drill Open Hole Directional from 1136' to 1393' with Auto Track. Require 4 deg/100' BUR to reach desired target at casing point but only able to acheive 2 deg/100'. ART - 3.3 hrs. 20:00 21:00 1.00 1,393 1,393 TA DRLSUR CIRC DOTH Close AutoTrak, circulate hole clean and take survey. 21:00 00:30 3.50 1,393 1,393 TA DRLSUR TRIP DOTH POOH and stand back AutoTrak and download same.. 00:30 03:30 3.00 1,393 1,393 TA DRLSUR TRIP DOTH PU and orient motor and MWD, TIH. 03:30 06:00 2.50 1,393 1,535 AF DRLSUR DRILL Drill Open Hole Directional from 1393' to 1535' with mud motor. ART - .5 hrs, AST -.1.2 hrs. I I I 1 10 1 RR2 14 16.000 HTC MX1 600674 18/18/1811/11I/ 726.0 10/17/2003 0-0-NO-A-4- I-NO-BHA 2RR2 /5 16.000 Hughes MX1 6009091 20/20/20/14/111I/ 1,136.0 10/17/2003 O-O-NO-A-O- I-NO-BHA 2RR3 16 16.000 Hughes MX1 6009091 20/20/20/14/1/11/ 1,393.0 10/18/2003 1-1-WT-A-E- 1-EC-TD BIT I RUN WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr Rap CUM HRS CUM DEPTH CUM Rap 1RR2/4 5/15 85 I 85 700 1 ,400 739 2.50 206.0 82.40 5.30 410.0 77.36 2RR2/5 5/18 120/120 550 650 216 3.30 257.0 77.88 3.30 257.0 77.88 Printed: 4/8/2004 3:41 :03 PM . . Printed: 4/8/2004 3:41 :03 PM . . 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 1,331.0 2,866 AUTH MD 17,300 - FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS Circulate hole clean. OPERATION COMMENTS Drill 1535' to 2866', casi RIG PHONE po.ioe "'II NRI ¡ CUM \OVELL COST 907-260-6935 COUNTY/OTHER 100.0000 LEAKO!'!' REGULATORYINSP? N LAST RIG INSPECTION 10/13/2003 06:00 23:00 17.00 1,535 2,628 AF DRLSUR DRILL Drill Open Hole Directional from 1535' to 2628'. AST - 6.5 hrs, ART - 3.8 hrs. 23:00 23:30 0.50 2,628 2,628 TA DRLSUR RIG RGDT Rig Repair-Replace leaking valve on pump #2 bleed off line. Pump #3 would not come on line due to bad rheostat. 23:30 05:00 5.50 2,628 2,866 AF DRLSUR DRILL Drill Open Hole Directional from 2628' to 2866', casing point- 2362' TVD. AST - 3 hrs, ART - .8 hrs. 05:00 06:00 1.00 2,866 2,866 AF DRLSUR CIRC Circulate Clean 1.532.8 1.627.5 1,723.9 23.60 28.10 33.77 290.60 293.27 294.96 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1,815.3 1,912.9 2,008.2 37.52 40.27 45.14 296.38 295.77 295.24 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Printed: 4/8/2004 3:41 :05 PM · 2,102.2 48.77 295.94 0.00 0.00 0.00 0.00 0.00 2,573.1 60.18 295.42 0.00 0.00 0.00 0.00 0.00 2,196.5 51.22 296.76 0.00 0.00 0.00 0.00 0.00 2,666.1 59.39 295.38 0.00 0.00 0.00 0.00 0.00 2,290.1 53.36 296.93 0.00 0.00 0.00 0.00 0.00 2,762.7 61.50 294.83 0.00 0.00 0.00 0.00 0.00 2,385.4 55.69 296.69 0.00 0.00 0.00 0.00 0.00 2.812.4 64.07 293.54 0.00 0.00 0.00 0.00 0.00 2,477.0 57.72 297.03 0.00 0.00 0.00 0.00 0.00 Printed: 4/812004 3:41:05 PM . . 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 2,866 AUTH MD 17,300 DX0309030CAPDRL RIG PHONE F!ELD NAME MOCV';I NRI WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STAT~PROV COUNTYIOTHER LEAKOFF Alaska CURRENT STATUS 1 MTS RIU Casin Crews and WOC. OPERATION COMMENTS Circulate hole clean. Backream from 2866' to 1000'. Circulate hole clean. TIH, tag bridge 2588'. Unable to get past. Redrill hole to TD at 2866' MD, 2370' TVD. POOH. RU casing crew and LD machine. MANHRS WORKED ACCIDENT TYPE 562.00 None 10/18/2003 ACCIDENT DESCRIPTION: 06:00 08:00 2.00 2,866 2,866 DRLSUR CIRC Finish circulating 4 bottoms up while rotating at 120 rpm. Rack back one stand each 1/2 hour. 08:00 12:30 4.50 2,866 2,866 DRLSUR TRIP Back ream from 2533' to 1000' at 120 rpm & 750 gpm. 12:30 13:00 0.50 2,866 2,866 DRLSUR CIRC Circulate Clean 13:00 14:00 1.00 2,866 2,866 DRLSUR TRIP TIH to 2588', tag bridge. Unable to get past with 30K. 14:00 16:00 2.00 2,866 2,866 TA DRLSUR DRILL DNHS Orient motor to high side, attempt to slide past obstruction without success. Attempt to wash and ream past obstruction, check shot at 2688' showed to be in new hole. 16:00 18:00 2.00 2,866 2,866 T A DRLSUR CIRC DNHS Redrill hole hole to TD at 2866'. AST -1.0, ART -.2 18:00 21:30 3.50 2,866 2,866 TA DRLSUR CIRC DNHS Circulate Clean 21:30 23:00 1.50 2,866 2,866 TA DRLSUR TRIP DNHS Wiper trip from 2866' to 2249'. 30k drag at 2640'. No fill on bottom. 23:00 04:30 5.50 2,866 2,866 TA DRLSUR TRIP POOH to run 13 3/8" casing. SLM no correction. LD BHA. Clean floor. 04:30 06:00 1.50 2,866 2,866 TA Hold safety meeting with drill crew and casing crew. RU casing eqipment. Tri-Cone Bit, Bit Sub, Positive Displacement Motor, Intergral Blade Stabilizer, MWD Tool, Hang-Off Sub, Non-Mag Drill Collar (3), Drilling Jar, Heavy Weight Drill Pipe (5), Cross Over Printed: 4/812004 3:41 :06 PM . . Printed: 4/8/2004 3:41 :06 PM . 30.6 RIG NAME & NO. Nabors 273E FJELD NAME RIG PHON:: WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS WOC OPERATION COMMENTS Run and cement 133/8", K-55, 68 ppf, BTC casing at 2860 MD. ACCIDENT TYPE None 14:30 15:00 0.50 2,866 2,866 TA 15:00 17:00 2.00 2,866 2,866 AF 17:00 17:30 0.50 2,866 2,866 AF 17:30 19:00 1.50 2,866 2,866 AF 19:00 21:00 2.00 2,866 2,866 AF 21:00 00:00 3.00 2,866 2,866 AF 00:00 06:00 6.00 2,866 2,866 AF . 24 HR PROG TMD 2,866 AUTH MD 17,300 MOC'V'/: NRI I"""U\JI.!!:! I ~n!':.T 100.0000 LEAKOFF Finish RU casing equipment, fill up tool and PIU machine. Run 13-3/8" casing from surface to 1876'. Shoe track is 2 joints Conn below Fe joint bakerlocked. CSHD Repair stabbing board Run 13-3/8" casing from 1876' to 2853'. LD casing fill up tool, PU landing joint and RIH. Tag bottom at 2863. Total 70 joints of 13-3/8", 68#, K-55, Butt casing run. Blow down top drive, install cement head, RIU cement lines and manifold. Circulate hole clean at 400 gpm with rig pump while reciprocating casing 10'. Hold PJSM with rig crew and BJ crew. Test lines to 3,000 psi. Pump 40 bbl Mud Clean II spacer, drop top plug, mix and pump cmt as follows: 750 sx type 1 cement + 18% LW-6 + 20% MPA-1 + 1.0% A2 + 0.3% CD-32 + 1 gphs FP-6L mixed at 12.0 ppg. Yield - 2.508 cflsx, total volume 335 bbl. Drop top plug an displace with 10 bbl of water from BJ. Dispalce cement with mu and rig pumps at 400 gpm. Full returns during job. Contiune to reiprocate pipe first 133 bbl displacenment, drag increased, discontinue pipe movement. Bump plug with 1500 psi, 1000 psi over displacement pressure. Circulate spacer and 15 bbls of good cement to surface. CIP at 23:30 hrs 10/20/2003. Bleed off displacement preesure, floats holding. Casing shoe at 2860' MD, top of float collar at 2777' MD. Wait on Cement. Flush out riser and annular. Close annu lar to center pipe. Clean floor, loosen bolts on diverter line. Start cleaning pits and reparing to nipple down. 6R~M Printed: 4/8/2004 3:41 :07 PM . . Nabors Alaska Drilling 22 322.00 R&K Industrial 3 26.00 Marathon 2 48.00 BJ Services 4 48.00 Epoch Well Services 2 24.00 Weatherford 5 75.00 M-I Drilling Fluids 2 24.00 Weaver Brothers (WBt) 1 1.00 Baker Hughes Inteq 6 132.00 Wildflowers and Resin 2 6.00 Printed: 4/8/2004 3:41:07 PM . . FIELD NAME RIG PHONE 24 HR PROG TMD 2,866 AUTH MD 17,300 MOCWI 100.0000 30.6 RIG NAME & NO. Nabors 273E WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS I MTS NU BOP's and clean its OPERATION COMMENTS wac. ND diverter and NIU 13-5/8" Vetco MB196 wellhead wI top at GL. Tested seals to 1800 psi. BOP's. 907-260-6935 COUNTY/OTHER LAST CASING 13.375 in 24 HR FORECAST NU BOPs, clean its, PU 6,000 DP and mix FloPro mud UD Autotrak BHA, begin NIU 13-5/8", 5m LAST RIG INSPECTION 10:00 15:30 5.50 2,866 2,866 AF 15:30 17:00 1.50 2,866 2,866 AF 17:00 21:00 4.00 2,866 2,866 AF Wait on Cement. Continue hauling fluid for disposal and prepare to ND diverter. Total WOC - 10 hrs. Remove cement head, RD diverter line, PU annular. Rough cut 133/8" casing and lay down same. Lay 16" bails and casing elevators. ND 20 riser and 20" annular preventer. Make final cut on 13 3/8" and dress off same. Install Vetco-Gray MB-196B Multibowl head (13 3/8" slip-Ioc x 13 5/8" 5m Flange). Test seals to 1800 psi for 10 minutes. Top ofWH flange at GL. PU 9 1/2" AutoTrak BHA which was stood backmin derrick, break connection and lay down same. Required 65,000 ft-Ibs to break T-2 connection. Install wear bushing and test plug to protect bowl, clear floor an remove "V" door slide. Remove diverter and riser from under rig, begin NU 135/8" 5M Hydril BOP stack. Continue to clean pits and repair leaking manifold valve. 21:00 21:30 0.50 2,866 2,866 AF 21:30 06:00 8.50 2,866 2,866 AF Nabors Alaska Drilling 22 322.00 Weaver Brothers (WBI) 1 1.00 Marathon 2 48.00 Wildflowers and Resin 2 4.00 Epoch Well Services 2 24.00 ABB Vetco Gray 1 12.00 M-I Drilling Fluids 2 24.00 Peak Trucks (nabors) 3 6.00 Baker Hughes Inteq 6 132.00 K&M 1 4.00 R&K Industrial 3 30.00 Lynden Transport 1 2.00 Veco Alaska 1 12.00 Atigun 1 1.00 Printed: 4/8/2004 3:41 :09 PM LAST BOP TEST: 10í14/2003 20.000 13.375 18.730 12.415 . . (psi) @ (ppg) (psi) @ (ppg) 130 2,368 130 2,860 3,060 3,450 Printed: 4/8/2004 3:41 :09 PM . . WELL NAME KASILOF SOUTH 1 SUPERVISOR Milton Castleman/Russ Trub FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS 1 MTS Finish RU ick u machine. OPERATION COMMENTS Finish NU BOPE, perform shell test. RU PU machine. Strap DP. 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 2,866 AUTH MD 17,300 DX0309030CAPDRL R!G PHONE 100.0000 MOC \\'1 NRI ! r:: 1M W~ll CûSï 907-260-6935 COUNTYIOTHER LEAKOFF ACCIDENT TYPE 601.00 None ACCIDENT DESCRIPTION: REGULATORY INSP? LAST RIG INSPECTION N 10/13/2003 00:30 01 :00 0.50 01 :00 03:30 2.50 2,866 2,866 2,866 AF 2,866 AF Continue NU 135/8", 5M Hydril stack, hook up Koomey lines, functions rams, install rams, install bell nipple, stabilize stack, install drip pan. Install beaver slide and catwalk. RU and perform shell test on BOP's against hydril to 3500 psi. OK. Lay down stabbing board, break cross over from fill up tool. Run wear bushing, PJSM, RU PU machine. 20.000 13.375 18.730 12.415 (psi) @ (ppg) (psi) @ (ppg) 130 2,860 130 2,368 133.00 68.00 K-55 K-55 3,060 3,450 Prìnted: 4/812004 3:41:12 PM . . RiG PHONE 24 HR PROG TMD 2,866 AUTH MD 17,300 MOC WI fiR! 100.0000 DX0309030CAPDRL WELL NAME KASILOF SOUTH 1 SUPERVISOR Milton Castleman/Russ Trub F!ElD NAME 30.6 74.00 RIG NAME & NO. Nabors 273E ¡ CU~-h \AI;:L.L "'U~ ¡ WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS/ MTS Testin BOP's OPERATION COMMENTS PU 6163' of 5 1/2" DP and stand back in derrick. Test BOP's. 907-260-6935 COUNTY/OTHER ~iCI'\kVr'" Finish RU PU machine PU 6,163' of 51/2",21.9 ppf, 5-135, HT-55-375 DP. Total 5 1/2" DP in derrick is 10,738'. Begin mixing FloPro mud in pits. 22:00 06:00 8.00 2,866 2,866 AF Pull wear bushing, install test plug. Test upper/lower TD valves, lower pipe rams, VBR, annular,choke manifold, choke and kill line valves to 250/3500 psi. Will continue to test Koomey, IBOP and blind rams. TIW failed to test and will be rebuilt or replaced and tested prior to drilling out. COMMENTS Jim Regg with AOGCC waived witness for BOP test on 10/22/03. Nabors Alaska Drilling 24 346.00 R&K Industrial 2 6.00 Marathon 4 58.00 K&M 1 24.00 Epoch Well Services 4 48.00 Lynden Transport 1 1.00 M-I Drilling Fluids 2 24.00 Weatheñord 2 36.00 Baker Hughes Inteq 5 120.00 20.000 13.375 18.730 12.415 (psi) @ (ppg) (psi) @ (ppg) 130 2,860 130 2,368 133.00 68.00 K-55 K-55 3,060 3,450 Printed: 4/8/2004 3:41 :13 PM . . ······<L'· ...... ·······i· ~.... .... .·<i. .. """....~ .i······· ." . .... ·····i\·· . ..... .. . .......i\. . ......... .i . ........ ... ... .. . ..... .... ... ..i ...... ; ...... ..iq ... .... i...;'. WELL NAME KB GL 24 HR PROG TMD TVD I DFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 29.0 2,895 2,383 10 10 10 25-0ct-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Milton Castleman/Russ Truby Nabors 273E 17,300 DX0309030CAPDRL F!ELD NAME ' PJG PHONE Ir~~~~~~oo NRI ID:ILYWELLCOST i CUM WELL COST i WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I Lt:AKU"~ Alaska 13.375 (in) @ 2,860 (ft) 9.625 (in) @ 10,500 (ft) 18.57 CURRENT STATUS / MTS 24 HR FORECAST Trouble shoot AutoTrak. Trouble shoot AutoTrak. Drill 12 1/4" hole. OPERATION COMMENTS F~"h lost BOI>,. PU AutoT~ c~~ moo. Drlll,;",~"",," LOT to 1B.6 pp, EMW. 11II MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? LAST RIG INSPECTION 700.00 None 10/21/2003 10/14/2003 N 10/13/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: 06:00 08:30 2.50 2,866 2,866 AF CSGSUF TEST Finish testing IBOP, blinds rams (250/3500 psi), and Koomey unit (capacity test). LD test joint. 08:30 09:00 0.50 2,866 2,866 AF CSGSUF TEST Test high pressure mud lines from pumps to TD to 3,500 psi- OK. 09:00 14:00 5.00 2,866 2,866 AF CSGSUR TRIP PU AutoTrak, stabilzer and bit. Surface test equipment. Change out jars. 14:00 15:00 1.00 2,866 2,866 AF CSGSUR TRIP TIH to 1750', attempt to test AutoTrak. Mud too thick coming across shakers to pump at sufficient rate. 15:00 16:30 1.50 2,866 2,866 AF CSGSUR CIRC Mud too thick coming across shakers to pump at sufficient rate to test tool. C&C to thin mud, test AutoTrak. 16:30 17:00 0.50 2,866 2,866 AF CSGSUF TRIP TIH to 2704'. 17:00 18:00 1.00 2,866 2,866 AF CSGSUF CIRC Break circulation, C&C to thin mud, tag float collar at 2776'. 18:00 19:30 1.50 2,866 2,866 AF CSGSUF TEST Test casing to 1750 psi for 30 minutes - no pressure loss. 19:30 22:30 3.00 2,866 2,866 AF CSGSUF CIRC Displace spud mud from hole with FloPro system. Clean shake beds and build additional volume. 22:30 23:30 1.00 2,866 2,866 AF CSGSUR CIRC C&C to shear new mud. Shakers unable to handle volume required for drilling. 23:30 04:00 4.50 2,866 2,866 AF CSGSUF DRILL Drill float shoe,cement, and float shoe from 2776' - 2860'. 04:00 04:30 0.50 2,866 2,895 AF CSGSUF DRILL Drill Formation 2866' - 2895'. 04:30 05:00 0.50 2,895 2,895 AF CSGSUF CIRC Circulate Clean 05:00 06:00 1.00 2,895 2,895 AF CSGSUF TEST Perform Leak Off Test (LOT). Surface pressure -1190 psi, mud weight - 8.9 ppg. LOT EMW - 18.6. ~ B.90~ - ~~µ$ ; J '~llgª "., " ....."'." 200 15/36 13/17 I 7 AI 1.0/4.0 I 0.25/20.0 10.0010.2 0.1/0.61 200 1120 I I I I I '$Î~r; f>.·¡:i 3/7 1 12.25i&Jµghes Christens¡ n HCR 605 I 710348 I 14/14/14/14/14/14/14/11 I 2,866.0 10/24/2003 I O-O-NO-A-O- I-NO-TD BIT I RUN WOB 1 RPM GPM PRESS P BIT I HRS I 24Hr DIST I 24Hr Rap 1 CUM HRS I CUM DEPTH I CUM Rap 3/7 6/12 I 80 I 80 712 1,100 375 I 0.50 I 29.0 I 58.00 I 0.50 I 29.0 I 58.00 Printed: 4/8/2004 3:41 :14 PM . . Nabors Alaska Drilling 23 345.00 R&K Industrial 4 48.00 Marathon 2 58.00 K&M 1 24.00 Epoch Well Services 4 48.00 Lynden Transport 3 3.00 M-I Drilling Fluids 2 24.00 Wildflowers and Resin 2 6.00 Baker Hughes Inteq 6 144.00 Printed: 4/8/2004 3:41:14 PM . . RIG PHONE 24 HR PROG TMD 1,054.0 3,949 AUTH MD 17,300 MOC WI 100.0000 "I~I "AI CUM ,;,'ELL COST WELL NAME KASILOF SOUTH 1 SUPERVISOR Milton Castleman/Rand Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Trj in in hole. OPERATION COMMENTS Drill with rotary steerable system from 2895' to 3949'. 30.6 RIG NAME & NO. Nabors 273E 907-260-6935 COUNTY/OTHER LEAKOFF 18.57 06:00 09:00 3.00 2,895 2,895 TA DRLlN1 CHECK LWDD Troubleshoot GR failure on BHI Auto- Track drilling system. Unable to resolve problem. Elect to drill ahead without GR. 09:00 23:30 14.50 2,895 3,949 AF DRLlN1 DRILL Drill and survey with rotary steerable system from 2895' to 3949'. 23:30 01:00 1.50 3,949 3,949 AF DRLlN1 CIRC Circulate hole clean, for wiper trip. 01:00 02:30 1.50 3,949 3,949 AF DRLlN1 TRIP Wiper trip to casing shoe, continue POOH to 1500', 02:30 03:00 0.50 3,949 3,949 AF DRLlN1 SAFETY PJSM - Cutting drill line. 03:00 05:30 2.50 3,949 3,949 AF DRLlN1 RIG Slip & cut drill line. 05:30 06:00 0.50 3,949 3,949 AF DRLlN1 RIG Service rig & top drive. Printed: 4/8/2004 3:41:16 PM . . 3,145.4 66.40 296.38 0.00 0.00 0.00 0.00 0.00 3,624.3 66.93 297.98 0.00 0.00 0.00 0.00 0.00 3,242.6 66.30 296.33 0.00 0.00 0.00 0.00 0.00 3,716.7 66.88 298.09 0.00 0.00 0.00 0.00 0.00 3,338.3 66.40 296.84 0.00 0.00 0.00 0.00 0.00 3,810.3 66.68 298.98 0.00 0.00 0.00 0.00 0.00 3,432.1 66.69 297.16 0.00 0.00 0.00 0.00 0.00 3,907.5 66.86 299.24 0.00 0.00 0.00 0.00 0.00 3,526.1 66.45 297.26 0.00 0.00 0.00 0.00 0.00 Printed: 4/8/2004 3:41:16 PM . . WELL NAME KASILOF SOUTH 1 SUPERVISOR Milton Castleman/Rand Ratliff F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin 5430'. OPERATION COMMENTS Drill from 3949' to 4999'. Wiper trip. 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 1,481.0 5,430 AUTH MD 17 ,300 MOCWI 100.0000 NRI t"'!!!!~!:I.I. t':OST RIG PHONE 907-260-6935 COUNTY/OTHER LEAKOFF 18.57 06:00 06:30 0.50 3,949 3,949 AF DRLlN1 RIG Service rig & top drive. 06:30 09:00 2.50 3,949 3,949 AF DRLlN1 TRIP Finish wiper trip. TIH from 1500' to bottom @ 3949'. 09:00 21:30 12.50 3,949 4,999 AF DRLlN1 DRILL Drill from 3949' to 4999'. 21:30 23:00 1.50 4,999 4,999 AF DRLlN1 CIRC Circulate hole clean for wiper trip. 23:00 01:30 2.50 4,999 4,999 AF DRLlN1 TRIP Wiper trip to 3950'. Hole slick, maximum overpull 30K near bottom. 01:30 02:00 0.50 4,999 4,999 AF DRLlN1 TRIP Wash 150' to bottom. 02:00 06:00 4.00 4,999 5,430 AF DRLlN1 DRILL Drill from 4999' to 5430', AVG. CONN: MAX. CONN: 8 22 Printed: 4/8/2004 3:41:17 PM . . 4,003.5 66.63 298.88 0.00 0.00 0.00 0.00 0.00 4,674.6 66.67 298.21 0.00 0.00 0.00 0.00 0.00 4,097.7 66.67 299.03 0.00 0.00 0.00 0.00 0.00 4,770.7 66.76 297.17 0.00 0.00 0.00 0.00 0.00 4,193.1 66.57 299.43 0.00 0.00 0.00 0.00 0.00 4,865.3 66.61 296.58 0.00 0.00 0.00 0.00 0.00 4,289.1 66.55 298.84 0.00 0.00 0.00 0.00 0.00 4,960.7 66.72 296.40 0.00 0.00 0.00 0.00 0.00 4,386.1 66.70 298.82 0.00 0.00 0.00 0.00 0.00 5,056.7 66.57 296.94 0.00 0.00 0.00 0.00 0.00 4,482.4 66.72 298.19 0.00 0.00 0.00 0.00 0.00 5,152.4 66.51 296.53 0.00 0.00 0.00 0.00 0.00 4,578.2 66.66 298.44 0.00 0.00 0.00 0.00 0.00 5,249.4 66.70 296.32 0.00 0.00 0.00 0.00 0.00 20.000 13.375 18.730 12.415 18.57 (psi) @ (ppg) 1,141 (psi)@ 9.30 (ppg) 130 2,860 130 2,368 133.00 68.00 K-55 K-55 3,060 3,450 Printed: 4/8/2004 3:41:17 PM . . WELL NAME KASILOF SOUTH 1 SUPERVISOR Milton Castleman/Rand Ratliff FIELD NAME 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 1,563.0 6,993 AUTH MD 17,300 RIG PHONE MOC \A.'I NRI WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Drillin 6993'. OPERATION COMMENTS Drill from 5430' to 6993'. 100.0000 LEAKOFF 18.57 ACCIDENT TYPE 614.00 None 10/28/2003 ACCIDENT DESCRIPTION: REGULATORY INSP? N LAST RIG INSPECTION 10/13/2003 06:00 12:30 6.50 5,430 6,047 AF DRLlN1 DRILL Drill with rotary steerable system from 5430' to 6047'. 12:30 14:30 2.00 6,047 6,047 AF DRLlN1 CIRC Circulate for wiper trip. 14:30 15:30 1.00 6,047 6,047 AF DRLlN1 TRIP Wiper trip to 4990', hole ok with 30K maximum overpull near bottom. 15:30 15:45 0.25 6,047 6,047 AF DRLlN1 RIG Service rig and top drive. 15:45 16:30 0.75 6,047 6,047 AF DRLlN1 TRIP TIH from 4990' to 5954'. Wash 93' to bottom @ 6047'. 16:30 06:00 13.50 6,047 6,993 AF DRLlN1 DRILL Drill with rotary steerable system from 6047' to 6993'. Control drill to maintain accepable friction factor of 0.35. MD 5,342.2 5,437.9 0.00 0.00 0.00 0.00 Printed: 4/8/2004 3:41:19 PM . . 5,722.8 66.68 294.29 0.00 0.00 0.00 0.00 0.00 6,389.5 66.84 296.59 0.00 0.00 0.00 0.00 0.00 5,818.9 66.48 294.64 0.00 0.00 0.00 0.00 0.00 6,482.4 66.70 296.95 0.00 0.00 0.00 0.00 0.00 5,915.4 66.80 294.91 0.00 0.00 0.00 0.00 0.00 6,576.0 66.52 297.33 0.00 0.00 0.00 0.00 0.00 6,008.8 66.71 295.85 0.00 0.00 0.00 0.00 0.00 6,670.9 66.71 297.92 0.00 0.00 0.00 0.00 0.00 6,103.8 66.45 296.04 0.00 0.00 0.00 0.00 0.00 6,766.7 66.62 298.73 0.00 0.00 0.00 0.00 0.00 6,199.7 66.70 295.85 0.00 0.00 0.00 0.00 0.00 6,861.5 66.74 299.43 0.00 0.00 0.00 0.00 0.00 6,295.0 66.75 296.50 0.00 0.00 0.00 0.00 0.00 LAST BOP TEST: 10/24/2003 LAST CASING TEST: 10/24/2003 NEXT BOP TEST: 10/31/2003 20.000 13.375 18.730 12.415 18.57 (psi) @ (ppg) 1,128 (psi) @ 9.40 (ppg) 130 2,860 130 2,368 133.00 68.00 K-55 K-55 3,060 3,450 Printed: 4/8/2004 3:41:19 PM . . . FIELD NAME RIG PHONE 24 HR PROG TMD 957.0 7,950 AUTH MD 17,300 MOC WI . NRI 100.0000 I"". 1M WFI L COST KASILOF SOUTH 1 SUPERVISOR Milton Castleman/Rand Ratliff 30.6 RIG NAME & NO. Nabors 273E WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin 7950'. OPERATION COMMENTS Drill from 6993' to 7950'. 907-260-6935 COUNTY/OTHER LEAKOFF 18.57 06:00 07:30 1.50 6,993 7,088 AF DRLlN1 DRILL Drill from 6993' to 7088', 07:30 09:30 2.00 7,088 7,088 AF DRLlN1 CIRC Circulate hole clean for trip, 09:30 14:30 5.00 7,088 7,088 TA DRLlN1 TRIP MiSe TOOH for wiper trip. Trip from 7088' to tight spot @ 6441'. Unable to work through with 30K overpull. Work in hole to 6550', Circulate bottoms up with no increase in cuttings in retums. Attempt to POOH, hole still tight @ 6441'. Unable to work thru tight spot. Screw into top drive and backream from 6441' to 6403'. Unable to POOH without pumps on. Pump out of hole from 6403' to 6054' with 10K to 60K overpull. Pull 1 stand in former wiper trip interval without pumps to 5960' with 10K overpull. 14:30 15:00 0.50 7,088 7,088 AF DRLlN1 RIG Service top drive. 15:00 15:30 0,50 7,088 7,088 AF DRLlN1 TRIP TIH with no problems to 6992', Wash 96' to bottom @ 7088'. 15:30 03:00 11.50 7,088 7,801 AF DRLlN1 DRILL Drill with rotary steerable system from 7088' to 7801'. Begin incorporating Soltex in mud system to stabilize coals. 03:00 04:00 1.00 7,801 7,801 TA DRLlN1 SURV MWD Circulate and evaluate illogical MWD surveys. 04:00 06:00 2.00 7,801 7,950 AF DRl!N1 DRILL Drill with rotary steerable system from 7801' to 7950'. Printed: 4/8/2004 3:41:22 PM . . 6,954.9 66.49 299.46 0.00 0.00 0.00 0.00 0.00 7,430.1 66.81 297.73 0.00 0.00 0.00 0.00 0.00 7,049.5 66.59 299.87 0.00 0.00 0.00 0.00 0.00 7,526.8 66.57 298.20 0.00 0.00 0.00 0.00 0.00 7,142.4 66.81 299.74 0.00 0.00 0.00 0.00 0.00 7,622.3 66.63 296.46 0.00 0.00 0.00 0.00 0.00 7,239.2 66.92 299.42 0.00 0.00 0.00 0.00 0.00 7.815.4 66.84 293.13 0.00 0.00 0.00 0.00 0.00 7,335.0 66.65 299.01 0.00 0.00 0.00 0.00 0.00 Nabors Alaska Drilling 23 300.00 R&K Industrial 4 48.00 Marathon 2 48.00 K&M 1 24.00 Epoch Well Services 4 48.00 Weaver Brothers (WBI) 3 6.00 M-I Drilling Fluids 2 24.00 Alaska Oil Sales 2 5.00 Baker Hughes Inteq 5 120.00 Prinled: 4/8/2004 3:41 :22 PM · WELL NAME KASILOF SOUTH 1 SUPERVISOR Milton Castleman/Rand Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin 8830'. OPERATION COMMENTS Drill from 7950' to 8830'. 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 880.0 8,830 AUTH MD 17 ,300 RIG PHO~~E MOC WI HR.! ,,..1 i.. Ulel i ...^o"W" 907-260-6935 COUNTY/OTHER 100.0000 LEAKOFF 18.57 06:00 09:30 3.50 7,950 8,140 AF DRLlN1 DRILL Drill with rotary steerable system from 7950' to 8140', 09:30 12:30 3.00 8,140 8,140 AF DRLlN1 CIRC Circulate hole clean for trip. 12:30 16:30 4.00 8,140 8,140 AF DRLlN1 TRIP TOOH from 8140' to 7854'. Take MWD check shot @ 7815'. Continue TOOH with 30K to 40K overpull to 7638'. Circulate and spot a 75 BBL pill with 3% Lube-Tex. Continue TOOH slow to 7088' with 10K to 70K overpull. 16:30 17:30 1.00 8,140 8,140 AF DRLlN1 RIG Service rig and top drive. Replace back-up wrench gripper dies in top drive pipe handler. 17:30 18:30 1.00 8,140 8,140 AF· DRLlN1 TRIP TIH from 7088' to 8043'. Wash 97' to bottom @ 8140'. 18:30 06:00 11.50 8,140 8,830 AF DRLlN1 DRILL Drill with rotary steerable system from 8140' to 8830'. Continue adding Asphasol to mud system to stabilize coals. Begin addin Lube-Tex to system to ease rotary torque, with 1-1/2% in syste this A.M. Printed: 4/8/2004 3:41:27 PM . . 7,909.7 66.61 292.84 0.00 0.00 0.00 0.00 0.00 8,384.2 66.55 294.81 0.00 0.00 0.00 0.00 0.00 8,004.4 66.61 292.22 0.00 0.00 0.00 0.00 0.00 8,476.6 66.56 295.20 0.00 0.00 0.00 0.00 0.00 8,100.3 66.81 293.64 0.00 0.00 0.00 0.00 0.00 8,571.3 66.94 296.02 0.00 0.00 0.00 0.00 0.00 8,194.2 66.61 293.79 0.00 0.00 0.00 0.00 0.00 8,668.4 66.81 296.00 0.00 0.00 0.00 0.00 0.00 8,287.1 66.62 294.21 0.00 0.00 0.00 0.00 0.00 8,764.4 66.62 296.40 0.00 0.00 0.00 0.00 0.00 Printed: 4/8/2004 3:41 :27 PM . WELL NAME KASILOF SOUTH 1 SUPERVISOR Milton Castleman/Rand Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin 10,032'. OPERATION COMMENTS Drill from 8830' to 10,032'. 30.6 RIG NAME & NO. Nabors 273E RIG PHONE 907-260-6935 COUNTY/OTHER . 24 HR PROG TMD 1,202.0 10,032 AUTH MD 17,300 MOC WI NRI 100.0000 SAPIWR!I COST I r.liNi W~¡ I r:n;:'T LEAKOFF 18.57 06:00 11 :30 5.50 11 :30 14:00 2.50 14:00 16:30 2.50 8,830 9,273 9,273 DRLlN1 DRILL DRLlN1 CIRC DRLlN1 TRIP 9,273 AF 9,273 AF 9,273 AF 16:30 17:00 0.50 17:00 18:00 1.00 18:00 06:00 12.00 9,273 9,273 9,273 DRLlN1 RIG DRLlN1 TRIP DRLlN1 DRILL 9,273 AF 9,273 AF 10,032 AF Drill with a rotary steerable system from 8830' to 9273'. Circulate hole clean for wiper trip. Pump and spot a 6% LubeTex pill. TOOH to 8140' for wiper trip without circulation or rotary. Worked thru intermittent tight hole for the duration of the trip with 20K to 60K overpull. Trip conditions were notably better after incorporating 3% LubeTex i the mud system during the last 24 hours. Service top drive. TIH with no problems to 9177'. Wash to bottom @ 9273'. Drill with a rotary steerable system from 9273' to 10,032'. Finis adding Asphasol to system. with +1- 4 ppb in system. Currently increasing LubeTex in system from 3% to 4%. Note: Difference in survey coordinates on this report, and in the data base due to a change in the magnetic correction factor being used to correct the survey data. o 120,000 150,000 23,000/18,000 Polycrystalline Diamond Bit, AutoTrak , Non Mag Float Sub, Non-Mag Integral Blade Stabilizer, Non-Mag Drill Collar (3), Drilling Jar, Heavy Weight Drill Pipe (5), Cross Over Printed: 4/8/2004 3:41:28 PM . . 8.859.3 66.38 295.60 0.00 0.00 0.00 0.00 0.00 9,424.1 66.48 293.46 0.00 0.00 0.00 0.00 0.00 8,952.1 66.28 295.55 0.00 0.00 0.00 0.00 0.00 9,520.3 66.60 293.51 0.00 0.00 0.00 0.00 0.00 9,045.5 66.15 295.35 0.00 0.00 0.00 0.00 0.00 9,614.3 66.45 292.59 0.00 0.00 0.00 0.00 0.00 9.141.2 66.67 294.97 0.00 0.00 0.00 0.00 0.00 9,709.3 66.71 292.38 0.00 0.00 0.00 0.00 0.00 9.234.8 66.57 293.14 0.00 0.00 0.00 0.00 0.00 9,803.2 66.67 292.54 0.00 0.00 0.00 0.00 0.00 9.323.3 66.58 294.19 0.00 0.00 0.00 0.00 0.00 9,897.0 66.39 291.48 0.00 0.00 0.00 0.00 0.00 Nabors Alaska Drilling 23 300.00 R&K Industrial 4 48.00 Marathon 2 48.00 K&M 1 24.00 Epoch Well Services 4 48.00 Weaver Brothers (WBI) 3 10.00 M-I Drilling Fluids 2 24.00 Alaska Oil Sales 1 4.00 Baker Hughes Inteq 4 96.00 18.57 Printed: 4/8/2004 3:41:28 PM . . cJÔr}. - ;(5& Kasilof South 1 PB 1 Drilling (Reports 17 - 49A) . . KASILOF SOUTH 1 PB1 SUPERVISOR Milton Castleman/Rand Ratliff 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 528.0 10,560 AUTH MD 17,300 FIELD NAME RIG PHo~,n: MOC·...¡¡ NRi .....·~_.5....... .........__ WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS TIH to 10,560'. OPERATION COMMENTS Drilled from 10,032' -10,560'. 907-260-6935 COUNTY/OTHER 100.0000 LEAKOFF 18.57 MANHRS WORKED 598.00 First Aid 10/30/2003 ACCIDENT DESCRIPTION: Worker cut right thumb on metal drum top. SAFETY MTG TOPICS: Safely cutting tops from metal drums. Use of proper PPE REGULATORY INSP? N 10/13/2003 06:00 15:00 9.00 10,032 10,560 AF DRLlN1 DRILL Directional Drill from 10032'-10,560'. TD of 12-1/4" hole. 15:00 17:00 2.00 10,560 AF DRLlN1 CIRC Circulate hole clean. 17:00 21:00 4.00 10,560 AF DRLlN1 TRIP POOH from 10,560' - 9935'. 10-75k drag. RIH to 10,126'. 21:00 22:30 1.50 10,560 AF DRLlN1 CIRC Circulate hole clean. 22:30 03:00 4.50 10,560 AF DRLlN1 TRIP POOH to 9935'. Hole very tight. Backream from 9935'-9150'. 03:00 03:30 0.50 10,560 AF DRLlN1 CIRC Circulate hole clean. 03:30 05:30 2.00 10,560 AF DRLlN1 TRIP POOH backreaming from 9150'- 8190'. Pulled from 8190'-8390' with 10-20k drag. 06:00 0.50 10,560 AF DRLlN1 TRIP TIH to 9600' with no problems. 3 9 Printed: 41612004 3:41 :31 PM . . Nabors Alaska Drilling 23 300.00 R&K Industrial 4 48.00 Marathon 2 48.00 K&M 1 24.00 Epoch Well Services 4 48.00 Weaver Brothers (WBI) 3 10.00 M-I Drilling Fluids 2 24.00 Alaska Oil Sales Baker Hughes 'nteq 4 96.00 Printed: 4/8/2004 3:41:31 PM . . WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Milton Castieman/Rand Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Pickin u under reamer assembl . OPERATION COMMENTS TOOH, lay down Auto-Trak 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 10,560 AUTH MD 17,300 RIG PHONE MOC W'i; , NRi I CUM ".fELL COST 907-260-6935 COUNTY/OTHER 100.0000 LEAKOFF 18.57 MANHRS WORKED 559.00 REGULATORY INSP? LAST RIG INSPECTION N 10/13/2003 06:00 07:00 1.00 10,560 10,560 AF DRLlN1 TRIP Finish wiper trip. Continue TIH from 9600' to tight spot @ 10,284'. 07:00 07:30 0.50 10,560 10,560 AF DRLlN1 TRIP Wash and ream in hole from 10,284' to bottom @ 10,560'. 07:30 10:30 3.00 10,560 10,560 AF DRLlN1 CIRC Circulate hole clean. 10:30 18:00 7.50 10,560 10,560 AF DRLlN1 TRIP Trip out of hole, conditions good with 30K maximum overpull. (SLM 2.61' difference) 18:00 21:00 3.00 10,560 10,560 AF DRLlN1 TRIP UD Auto- Trak drilling assembly. GR information not stored in tool memory due to failed fuse in tool. 21:00 21:30 0.50 10,560 10,560 AF DRLlN1 TRIP Pull wear bushing. 21:30 23:30 2.00 10,560 10,560 AF DRLlN1 TEST Set test plug with multiple attempts. 23:30 03:00 3.50 10,560 10,560 AF DRLlN1 TEST Test upper VBR rams, lower pipe rams, blind rams, stack manual and HeR valves, choke manifold, Hydril, TIW and IBOP valves, upper and lower top drive valves to 250 I 3500 psi. Run accumulator test. Test gas and H2S alarms. Methane sensor i cellar would not function properly. Received approval to repair sensor and notify AOGCC when completed. AOGCC Representative Lou Grimaldi on location to witness test. 03:00 03:30 0.50 10,560 10,560 AF DRLlN1 TEST RID test equipment, pull test plug. 03:30 04:00 0.50 10,560 10,560 AF DRLlN1 RIG Service top drive. 04:00 05:00 1.00 10,560 10,560 AF DRLlN1 CHECK P/U casing landing joint and hanger, make dummy hanger run. 05:00 05:30 0.50 10,560 10,560 AF DRLlN1 TRIP Set wear bushing. 05:30 06:00 0.50 10,560 10,560 AF DRLlN1 TRIP Picking up under reamer assembly. Printed: 4/8/2004 3:41 :33 PM . . Nabors Alaska Drilling 23 300.00 K&M 1 24.00 Marathon 2 48.00 Peak Transportation 4 12.00 Epoch Well Services 4 48.00 Baker Oil Tools 2 24.00 M-I Drilling Fluids 2 24.00 ABB Vetco Gray 2 6.00 Baker Hughes Inteq 2 48.00 Lynden Transport 1 1.00 R&K Industrial 2 24.00 Printed: 4/8/2004 3:41 :33 PM . SUPERVISOR Milton CastlemanlRand Ratliff 30.6 RIG NAME & NO. Nabors 273E FIELD NAME RIG PHO~iE WILDCAT-FOR UNNAMED FIELD STATEJPROV Alaska CURRENT STATUS / MTS Under-Reamin hole 9900'. OPERATION COMMENTS Trip in hole. Under-Ream hole from 9850' to 9900'. . I CUM WELL Cû5T LEAKOFF 18.57 06:00 11:30 5.50 10,560 10,560 AF DRLlN1 TRIP 11:30 13:00 1.50 10,560 10,560 AF DRLlN1 TRIP 13:00 19:30 6.50 10,560 10,560 AF DRLlN1 TRIP 19:30 20:00 0.50 20:00 06:00 10.00 10,560 10,560 10,560 AF 10,560 AF DRLlN1 TRIP DRLlN1 DRILL MIU Under-Reamer assembly. Weld straps on connections below reamer tool. TIH with reamer assembly. P/U Jars and 5 additional joints of 5 HWDP. TIH to bottom @ 10,560' with 30K to 45K drag through most of open hole. PIU and work thru tight spots with diminished drag on second trip through. Hole in better condition in back reamed section from 8,483' to 10,560'. TOOH to 9850'. Under-Ream 12-1/4" hole to 17-1/2" to accomodate multi-lateral formation junction. Under-Ream hole from 9850' to 9900' with slow penetration rates, averaging 5 FPH in hard calcite cemented sandstone. Monitor erratic rotary torque with sweep from 15,000 to 28,000 fUlbs while reaming. Observe increased quantity of wall cake and cuttings over shakers after trip, during 1 st circulation. Under-Reaming parameters: 5K to 20K WOB 75-95 RPM 575 to 600 GPM Printed: 4/8/2004 3:41:34 PM . . Nabors Alaska Drilling 23 300.00 R&K Industrial 2 24.00 Marathon 2 48.00 K&M 1 24.00 Epoch Well Services 2 24.00 Baker Oil Tools 2 48.00 M-I Drilling Fluids 2 24.00 Lynden Transport 1 3.00 Baker Hughes Inteq 2 12.00 Weaver Brothers (WBI) 1 1.00 Printed: 4/8/2004 3:41 :34 PM . . RIG PHONE 24 HR PROG TMD 10,560 AUTH MD 17,300 MOC ..1 NRI 100.0000 ¡CUM W~LL CU:>I WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Milton CastlemanlRand Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Chan in out under-reamer. OPERATION COMMENTS Under-Ream from 9900' to 9950', 30.6 RIG NAME & NO. Nabors 273E 907-260-6935 COUNTY/OTHER LEAKO...... 18.57 LAST SAFETY MTG 11/3/2003 06:00 17:30 11.50 10,560 10,560 AF DRLlN1 DRILL Continue under-reaming 12-1/4" hole to 17-112" from 9900' to 9950' to accomodate mulit-Iateral formation junction. Monitor 300 psi pump pressure loss while drilling. Under-Reaming parameters 5K - 20K WOB 85 -125 RPM 600 GPM 15,000 to 28,000 ftllbs TQ 17:30 18:00 0.50 10,560 10,560 TA DRLlN1 DRILL DOTH PIU and make a connection, slack off in 12-1/4" hole below under-reamed depth @ 9950'. Unable to continue under-reaming. 18:00 20:00 2.00 10,560 10,560 TA DRLlN1 CIRC DOTH Pump down diverter bar assembly and slide sleeve in circulating sub. Circulate bottoms up thru circulating sub. 20:00 02:00 6.00 10,560 10,560 TA DRLlN1 TRIP DOTH Slug pipe, TOOH. Trip was smooth, wipe thru several tight spots from 7600' to 4500' with 60K maximum over-pull. 02:00 02:30 0.50 10,560 10,560 TA DRLlN1 TRIP DOTH Discover o-ring on piston missing, causing the pressure loss while under-reaming. Attempt to stroke tool and open arms fully to 17-1/2". Arms will only open to 13-1/2". PDC cutters on tool in excellent condition. 02:30 06:00 3.50 10,560 10,560 TA DRLlN1 TRIP DOTH Rebuild circulating sub. PIU roller cone under-reamer with chisel tooth inserts. Re-weld straps over connections below reamer. I Cross Over, 9" Pony Collar, Cross Over, Double Pin Sub, Under-Reamer, Bit Sub, Pump Out Sub, Cross Over, Printed: 4/8/2004 3:41 :36 PM . . Printed: 4/8/2004 3:41 :36 PM . . WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Milton Castleman/Rand Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 10,560 AUTH MD 17,300 MOC WI . NRI !.'-l_:'''·II~.'S COST DX0309030CAPDRL RIG PHONE - ~ .. .... ....... I ""^~T "'1 !~4 ~~LL \,o\.M.". 907-260-6935 COUNTY/OTHER LEAKOFF 18.57 OPERATION COMMENTS Trip for under-reamer. LAST RIG INSPECTION 10/13/2003 06:00 08:00 2.00 10,560 10,560 TA DRLlN1 TRIP DOTH Finish welding straps over connections below under-reamer. 08:00 10:30 2.50 10,560 10,560 TA DRLlN1 TRIP DOTH TIH with under-reamer assembly to surface casing shoe. 10:30 13:00 2.50 10,560 10,560 AF DRLlN1 RIG Slip & cut drill line. 13:00 13:30 0.50 10,560 10,560 AF DRLlN1 RIG Service top drive. 13:30 16:00 2.50 10,560 10,560 TA DRLlN1 TRIP DOTH Continue TIH to 5986'. Fill drill pipe, discover reamer plugged, unable to circulate with 1000 psi. TOOH with 5 stands, break circulation with 750 psi. Attempt to continue TIH, mud u-tubing up drill pipe. 16:00 17:00 1.00 10,560 10,560 TA DRLlN1 CIRC DOTH Circulate & condition. Mix and pump slug. 17:00 22:30 5.50 10,560 10,560 TA DRLlN1 TRIP DOTH Continue TIH with under-reamer draging. Work thru numerous tight spots with multible attempts from 6250' to 7886' with 80K. Continue TIH with fewer tight spots, SID in base of under-reamed section @ 9950', Rotate under-reamer into 12-1/4" hole, continue in hole before reamer set down with nose at 10,305' and bades at 10,287'. Unable to work or wash through with multible attempts. 22:30 23:00 0.50 10,560 10,560 TA DRLlN1 CIRC DOTH Circulate & turn over mud in 12-1/4" hole @ 10,305'. 23:00 23:30 0.50 10,560 10,560 TA DRLlN1 TRIP DOTH TOOH to 9968'. 23:30 01:30 2.00 10,560 10,560 AF DRLlN1 RIG Replace gripper dies in top drive pipe hander. 01:30 02:00 0.50 10,560 10,560 TA DRLlN1 TRIP DOTH Pump open under-reamer @ 9850', wash under-reamed hole section from 9850' to 9950'. 02:00 06:00 4.00 10,560 10,560 AF DRLlN1 DRILL Continue under-reaming 12-1/4" hole to 17-112" to accomodate multi-lateral formation junction. Under-ream from 9950' to 9978'. Under-Reamer drilling parameters 15K to 20K WOB 75 to 100 RPM 600 GPM 18,000 to 21,000 ftllbs TQ After drilling through hard streak from 9955' to 9965' at 2 FPH. ROP average 10 to 15 FPH. Printed: 4/8/2004 3:41 :37 PM . . Nabors Alaska Drilling 23 300.00 Baker Oil Tools 2 48.00 Marathon 2 48.00 Weaver Brothers (WBI) 1 6.00 Epoch Well Services 2 24.00 Lynden Transport 1 2.00 M-I Drilling Fluids 2 24.00 Oilfield Hot Shot Service 1 2.00 R&K Industrial 2 24.00 S&R Enterprises 1 1.00 K&M 1 24.00 18.730 12.415 18.57 COMHDEN1\Al Printed: 4/8/2004 3:41 :37 PM . . WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratliff I Gerard Ro er FIELD NAME 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 10,560 AUTH MD 17 ,300 RIG PHONE " MOC \\'i NRi : r!!!! \.&.n:1 I ~n~T WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER LEAKOFF Alaska 18.57 CURRENT STATUS / MTS M/U 12-1/4" Clean Out Assembl OPERATION COMMENTS UR hole to 17-1/2" f/9,978' to 10,020'. CBU x 2. Attempt to TIH to TD but unable to get past 10,037'. CBU well clean. POOH, well in good condition. UD UR BHA (all 3 cones LlH). M/U 12-1/4" cleanout BHA. ACCIDENT TYPE LAST SAFETY MTG 495.00 None 11/5/2003 ACCIDENT DESCRIPTION: REGULATORY INSP? LAST RIG INSPECTION N 10/13/2003 06:00 09:30 3.50 10,560 10,560 AF DRLlN1 DRILL Continue under-reaming 12-1/4" hole from 9,978' to 10,020'. ROP decreased to 2-3 FPH at 10,020' and the decision was made to quit underreaming and adjust multi-lateral formation junction depth as needed. Under-reaming parameters: 15-20k WOB 75-100 RPM 600 GPM 18K - 21K ftIlbs TORQ. 09:30 11:30 2.00 10,560 10,560 AF DRLlN1 CIRC Drop dart to open bypass circulating sub. Pump at 230 spm, while rotating pipe 125 spm and working pipe. No indication of bypass opening. Trouble shoot circ system and found one mud pump suction valve closed. 11:30 14:00 2.50 10,560 10,560 AF DRLlN1 CIRC Open bypass and circulate well clean while working pipe at 10,020', rotating 125 rpm, and pumping 960 gpm. 14:00 14:30 0.50 10,560 10,560 AF DRLlN1 TRIP Attempt to TIH to TD of well, unable to get below 10,037'. 14:30 15:30 1.00 10,560 10,560 AF DRLlN1 CIRC CBU then pull (3) stds wet to get above under reamed section. Flow check - OK and pump slug. 15:30 21:00 5.50 10,560 10,560 AF DRLlN1 TRIP POOH f/9740'. Hole in excellent condition wI one tight spot 15 at - 7200'. (K&M estimated OH friction factor .25 and cased hole .15. Note: mud contains 5% LubeTex Oil). 21:00 23:30 2.50 10,560 10,560 TA DRLlN1 TRIP BITD Inspect under-reamer BHA, all (3) cones lost in hole. Arms extend fully to - 16-3/4" O.D. Welder cut off welded straps and UD BHA. 23:30 01:00 1.50 10,560 10,560 AF DRLlN1 RIG Service Rig and Topdrive. 01:00 06:00 5.00 10,560 10,560 TA DRLlN1 TRIP WOE Begin PIU cleanout BHA. M/U bit sub, bypass sub and 12-1/4" (4) spiral bladed Kutrite tapered stabilizer wi smooth 0.0. on a 7-3/4" DC. Twice Baker send the wrong type stabilzer to location. Wait on 12" string stab from BHI Anchorage. Printed: 4/8/2004 3:41 :39 PM . . Nabors Alaska Drilling 23 300.00 K&M 1 24.00 Marathon 2 48.00 Baker Oil Tools 2 48.00 Epoch Well Services 2 24.00 Lynden Transport 2 3.00 M-I Drilling Fluids 2 24.00 Oilfield Hot Shot Service 1 2.00 R&K Industrial 2 16.00 Swaco 1 6.00 Printed: 4/8/2004 3:41 :39 PM . . RIG PHONE 24 HR PROG TMD 10,560 AUTH MD 17,300 MOC WI NR! ;~! lat ur~" I ---- WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratliff I Gerard Ro er FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS POOH wI cleanout assembl OPERATION COMMENTS Finish MIU BHA. TIH wI cleanout assembly. Work thru tight spot 6,261' to 6,323'. TIH to 10,042'. Ream tighthole from 10,042' to hole TD of 10,560'. CBU. POOH to UR section. CBU and wash thru UR section 9,850' to 10,020'. Slug pipe, POOH for csg. 30.6 RIG NAME & NO. Nabors 273E 907-260-6935 COUNTY/OTHER 100.0000 LEAKOFF 18.57 MANHRS WORKED ACCIDENT TYPE 480.00 None ACCIDENT DESCRIPTION: 06:00 08:00 2.00 10,560 10,560 TA DRLlN1 TRIP DNJK 12" String stabilizer arrived on location, measure same and complete MIU of cleanout BHA. Note well taking - 4 bbls/hr fluid). 08:00 10:00 2.00 10,560 10,560 TA DRLlN1 TRIP DNJK TIH wI 12-1/4" cleanout assembly to 2,790'. Fill DP and break circulation. 10:00 10:30 0.50 10,560 10,560 TA DRLlN1 RIG TOPS Trouble shoot topdrive hydraulic hose leak. 10:30 17:00 6.50 10,560 10,560 TA DRLlN1 TRIP DOTH TIH from 2,790'. Tagged bridge at 6261' and could not work past. Wash I ream I backream tight interval from 6,261' to 6,323'. Continue TIH to 10,042' 17:00 19:30 2.50 10,560 10,560 TA DRLlN1 TRIP DOTH Sat down at 10,042' which is 22' below the UR section. Wash I Ream I Backream hole from 10,042'. Hole noteably tight from 10,210' to 10305' (stalled topdrive numerous times, suspect reaming on cone debris LlH from UR). Finish reaming to TD 10,560' - sat down 25k WOB and bit running smoothly on bottom, suspect no cone debris present on bottom. 19:30 21:00 1.50 10,560 10,560 TA DRLlN1 CIRC DOTH CBU x 1.5 at 220 spm, 2750 psi while rotating 145 rpm, and working pipe. 21:00 21:30 0.50 10,560 10,560 TA DRLlN1 TRIP OOTH Drop bar to open fluid bypass I diverter sub. POOH (6) stands to the base of the UR section @ 10,020'. 21:30 00:30 3.00 10,560 10,560 TA DRLlN1 CIRC DOTH CBU X 3 at 220 spm, 2400 psi while rotating pipe at 145 rpm and working pipe across the UR section from 9,850' to 10,020'. 00:30 06:00 5.50 10,560 10,560 TA DRLlN1 TRIP DOTH POOH to run casing. Minimal drag in OH. Hole in good shape no indication of previous tight spot at - 6300'. Printed: 4/8/2004 3:41 :43 PM . . 20.000 13.375 133.00 68.00 K-55 K-55 3,060 3,450 Printed: 4/8/2004 3:41:43 PM . . 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 10,560 AUTH MD 17,300 ,C!:ADMlAC!: rnctT i I FIELD NAME RIG PHONE MOC.-';¡ NRl -..,."...-.. ............... 907-260-6935 COUNTY/OTHER 100.0000 LEAKOFF 18.57 - 5,150' Set & Test Packoff. Begin running 9-5/8" casing wI Baker 06:00 09:30 3.50 10,560 10,560 TA DRLlN1 TRIP DOTH RIB 5" HWDP. UD jars, De's and Stabs and 12-1/4" rock bit. Definite indication of bit and string mill stabilizer tuming on cone debris from the UR cones LlH. Clear the rig of excess tools. 09:30 10:30 1.00 10,560 10,560 AF CSGIN1 EQUIP RU casing stabbing board. 10:30 13:00 2.50 10,560 10,560 AF CSGIN1 EQUIP PJSM, Changed out TPR's (3.5" x 6" VBR) to 9-5/8" casing rams. 13:00 13:30 0.50 10,560 10,560 AF CSGIN1 EQUIP Move casing tools & centralizers to the rig floor. 13:30 14:30 1.00 10,560 10,560 AF CSGIN1 TEST PIU testjoint. Pull the wearbushing and set the test plug. Clos the hydril annular preventer and tested the casing ram bonnet door seals to 250 I 3,500 psi. Pull the test plug and UD the test joint assembly. 14:30 16:00 1.50 10,560 10,560 AF CSGIN1 EQUIP Move 7" casing and formation junction assembly to pipe rack. RlU PIU machine and RlU power tongs. 16:00 20:30 4.50 10,560 10,560 AF CSGIN1 CSG PIU and run - 586' of 7", 29#, N-80, New Vam and NSCC casing wi float shoe, float collar and landing collar. PIU and MI Baker 9-5/8" by dual 7" Formation Junction. 20:30 21:30 1.00 10,560 10,560 AF CSGIN1 EQUIP RU 9-5/8" casing spider slips and elevators. RlU Weatherford 9-5/8" LaFleur casing fill up tool. 21:30 06:00 8.50 10,560 10,560 AF CSGIN1 CSG PJSM, Run Formation Junction on (5) joints of 9-5/8",47#, L-80, DWC-SR casing followed by 9-5/8", 40#, L-80, DWC-SR casing. At 06:00 hrs at - 5,150' and only encountered (1) tight spot of 30k down at - 5,050'. Continue running casing. Filling casing every joint wi FlU tool and verifying every (5) joints. To this depth, OH casing FF of 0.4 and casing FF of 0.2. Printed: 4/8/2004 3:41 :46 PM · 20.000 13.375 18.730 12.415 18.57 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 130 2,860 130 2,368 133.00 68.00 K-55 K-55 3,060 3,450 Printed: 4/8/2004 3:41:46 PM · 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 10,560 AUTH MD 17,300 F!ELD NAME RIG PHONE mvCWi NRi ¡CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER Alaska CURRENT STATUS I MTS PIU Baker's Swed e BHA OPERATION COMMENTS Finish running the 9-5/8" by 7" intermediate casing string to 10,533'. Appeared to push junk f/10, 140' to 10,533'. Break circ on 13-3/8" by 9-518" annulus. RID casing tools. Set I test packoff. Change out rams. Circ on csg x csg. PIU swedge BHA. 06:00 16:30 10.50 10,560 10,560 AF CSGIN1 CSG Continue running 9-5/8" 40# and 47#, L-80, DWC-SR casing. PIU Vetco fluted WH casing hanger and land same at 33.03' RKB. Weights: PIU 330k, SIO 180k with a block weight of 46k. Per K&M, OH friction factor of 0.35 and cased hole friction facto of 0.2. Tight spot (50k) at - 7,000', - 8,550' . Appeared to push junk down hole from - 10,140' to TD of 10,533' (had to work pipe wI 20-40k down and up to 100k overpull). Top of casing shoe (motherbore) 10,531.31' Bottom of casing shoe (motherbore) 10,533.33'. (TVD = 5.417') Top of Float collar (motherbore) 10,453.03' Packoff bushing (sting in PBR) 10,435.40' Bottom of second leg 9,937.63' Bifurcation Point (Junction Crotch) 9,916.54 Top of Formation Junction Key 9,9.4.41' Acutal top of Formation junction sub 9901.49' Top of Diverter wedge 9,900.89 16:30 17:30 1.00 10,560 10,560 AF CSGIN1 CIRC Using the casing FlU tool, and the fluted hanger landed, break circulation and circ 2700 stks at 61 spm (255 gpm) at 1,300 psi while RID casing tongs and stabbing board. Back out the landing joint and UD same. 17:30 20:30 3.00 10,560 10,560 AF CSGIN1 EQUIP RID casing elevators, long bails, FlU tool and RlU handling equipment for DP. Drain the mud from the BOP stack. Set the hanger packoff and verify position. Run in hold down pins. Tes the packoff seals to 5,000 psi. Change top pipe rams from 9-5/8" casing rams to 3-1/2" x 6" VBR's. RlU second 2" valve on wellhead for 13-3/8" by 9-518" annulus. 20:30 21:30 1.00 10,560 10,560 AF CSGIN1 TEST Set the test plug and test the top pipe ram's bonnet seals to 250 I 3,500 psi. Pulled test plug and set short wearbushing. 21:30 00:00 2.50 10,560 10,560 AF CSGIN1 CIRC RlU return circulating lines from the (2) WH valves on 13-3/8" b Printed: 4/8/2004 3:41 :48 PM · 21 :30 00:00 2.50 10,560 10,560 AF CSGIN1 CIRC 9-5/8" annulus. Close blind rams and break circulation down 9-5/8" casing, taking returns from (2) WH valves into pits. Circulate at 83 spm (348 gpm) at 1,000 psi for a total of 1500 strokes. TOPS High winds forcing topdrive into monkey board. Held PJSM - RIU, re-align and tension down the topdrive torque tube. Service Rig, topdrive and crown. PIU Baker's Formation Junction swedge BHA. 00:00 02:30 2.50 02:30 03:00 0.50 03:00 06:00 3.00 10,560 10,560 TA CSGIN1 RIG 10,560 10,560 10,560 AF 10,560 AF CSGIN1 RIG CSGIN1 TRIP COMMENTS Intermediate casing is 9-5/8" from surface to -9900' then 7" from the Formation Junction. Casing burst in DIMS is for the weakest, 9-5/8" 40# pipe. Nabors Alaska Drilling 23 300.00 Baker Oil Tools 3 55.00 Marathon 3 72.00 Weatherford 7 60.00 Epoch Well Services 2 24.00 ABB Vetco Gray 1 10.00 M-I Drilling Fluids 2 24.00 Oilfield Hot Shot Service 1 2.00 K&M 1 18.00 LAST BOP TEST: 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 (psi) @ (ppg) 10,533 5,417 29.00 L-80 5,750 Printed: 4/6/2004 3:41:46 PM . . r <, <.. < « .. .'.'.,)/ i y.. ,....'..'...,",."..'."'....."......... ...... '..' ..) .'·',·'ii" .i{y I i{ iF .,. i", .,.'." '",', . .. ",' ."",,' ,',.,' . ......,., ,'.,.. '.... ... ." ,.i ...,.,,'{.,..; WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# I~ATE KASILOF SOUTH 1 PB1 30.6 74.00 10,560 5,427 26 26 26 10-Nov-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS I"'DIWR~ r.nST Gerard ROCIer I Russ Trubv Nabors 273E 17,300 DX0309030CAPDRL FIELD NAME RIG PHONE MOC \.., ·NRi ID"uvu,-1' "n~T ¡CUM \,Vï=1 î r.O~T II. W," . ..(:s 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) @ 17,232 (ft) CURRENT STATUS / MTS 124 HR FORECAST LD BHA PU cement stinger, TIH and cement 7" x 9 5/8" casing. OPERATION COMMENTS Trip in hole with swedging BHA. break circulation around casing every 6 hours. Swedge out preformed 7" leg. POOH. b §¡'L.'./i'.,j ./" . '·F ,.~~100h ....¡¿ """"/1 ~wr¡¿D/.& .;,¡¡e¡' ~., MANHRS WORKED ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST LAST STOP CARD AUDIT I REGULATORY INSP? I ~ST RIG INSPECTION 512.00 None 11/8/2003 11/8/2003 N 10/13/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pinch points during tripping pipe and good communications on crew change. 06:00 07:30 1.50 10,560 10,560 AF CSGlN1 RIG Adjust top drive torque tube to prevent blocks from hitting derrick boards. 07:30 08:30 1.00 10,560 10,560 AF CSGIN1 TRIP PU 2 stds HWDP, accelerators and one stand DP. 08:30 09:30 1.00 10,560 10,560 AF CSGIN1 CIRC Close hydril, break circulation down casing taking retums from 9 5/8" x 13 3/8" annulus. 09:30 11:30 2.00 10,560 10,560 AF CSGIN1 TRIP TIH to 1780, screw into each stand to prevent mud flowing back DP. 11:30 12:00 0.50 10,560 10,560 AF CSGIN1 CIRC Pump slug. 12:00 16:00 4.00 10,560 10,560 AF CSGIN1 TRIP Continue TIH wI BOT swedging BHA. 16:00 16:30 0.50 10,560 10,560 AF CSGIN1 TRIP Make up BOT pump in assembly 16:30 17:00 0.50 10,560 10,560 AF CSGIN1 TRIP Continue TIH to 9860'. 17:00 18:30 1.50 10,560 10,560 AF CSGIN1 CIRC Close hydril, break circulation down casing taking returns from (2) Wh valves, 60 spm at 990 psi for 2500 stks. 18:30 20:00 1.50 10,560 10,560 AF CSGIN1 CSG Drop ball, tag up onjuction at 9,920', DP measurement, wait 30 mins. Pump down drill pipe until ball seats. Pressure up to 2500 psi with rig pump. Continue swedging opertions with BOT pump. After completion of swedging operation, increase pressure to 5,500 psi to blowout setting ball. 20:00 23:30 3.50 10,560 10,560 AF CSGIN1 TRIP Pull three stands, saw 20' of additional 20-30 K drag prior to pulling free - indicting all of 7" had been swedged out. Break am lay down BOT circulating subs. 23:30 00:30 1.00 10,560 10,560 AF CSGIN1 TRIP POOH. 00:30 01:00 0.50 10,560 10,560 AF CSGIN1 CIRC Close hydril, break circulation down casing taking returns from 9 5/8" x 13 3/8" annulus, 58 spm at 950 psi. 01:00 06:00 5.00 10,560 10,560 AF CSGIN1 TRIP Finish POOH, lay down swedging BHA. COMMENTS NOTE: Got BOP test extension from Lou Grimaldi wI AOGCC till after cementing the 9-5/8" by 7" casing. 9.90 l~pl I~GI"...'..,'"."I_ 1<1 l¢qM/ÇqSì'j ··..,FV· Åýl'fp·· ø~~s'W~!8TElpl OIW PWilÌl Glldà çªG,z(.,yt\il~fHz~·lt;:¡MÈI.~~ ..I~R~M 90 26/44 15/20 4.21 I 1.0/10.0 5/85 0.25/10.0 I 9.5010.4 0.2/2.0 I 29,000/60 I I I I I Printed: 4/8/2004 3:41:49 PM 20.000 13.375 7.000 18.730 12.415 6.184 18.57 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) (psi) @ (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:41:49 PM 30.6 RIG NAME & NO. Nabors 273E FIELD NAME RIG PHONE 24 HR PROG TMD 10,560 AUTH MD 17,300 MOC WI NRI "'!!!,! "-JELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Reverse out cement strin tool and Mwd . OPERATION COMMENTS LD BHA, break circulation down casing. TlH with cement stinger and cement 7' x 9 5/8" casing. CIP 0500 hrs 11/11/03. LEAKOFF 06:00 08:00 2.00 10,560 10,560 AF CSGIN1 TRIP 08:00 09:00 1.00 10,560 10,560 AF CSGIN1 CIRC 09:00 11:30 2.50 10,560 10,560 AF CSGIN1 TRIP 11:30 13:30 2.00 10,560 10,560 AF CSGIN1 RIG 13:30 21:30 8.00 10,560 10,560 AF CSGIN1 TRIP 21:30 22:00 0.50 10,560 10,560 AF CSGIN1 CIRC 22:00 00:30 2.50 10,560 10,560 AF CSGIN1 CIRC 00:30 05:00 4.50 CSGIN1 CEMT 10,560 10,560 AF REGULATORY INSP? N UD Baker's Swedge BHA. Indications of proper swedging of collapsed leg. Close the blind rams and Circulate and Condition Mud in the 13-3/8" by 9-518" casing. 80 spm, 1,000 psi. TIH and UD (3) stands of 5" HWDP and (5) stands of 5-1/2" DP from the driller's side set back area. Change out topdrive saver sub (I BOP valve) and pipe handller gripper dies. PIU Baker's Formation Junction cementing Stinger seal assembly. TIH PIU 21 jts of 4", 15.70 ppf, S-135, HT -40 DP. Con't TIH wI 5-1/2" DP. PIU cementing head and swivel. C&C mud, pump DP volume @ 82 spm, 1000 psi up the 9-5/8" casing. Sting seals into packoff bushing and bottom out locator. Close the hydril and test 9-5/8" by DP annulus & Formation Junction t 1,000 psi for 5 minutes - O.K. Bled back pressure and trapped 750 psi on the 9-5/8" by DP annulus. C & C mud down DP and up 13-3/8" by 9-518" annulus for cement job at 70 spm, 1050 psi PJSM with all involved personnel. Test lines to 4,000 psi. Replace cement hose on rig floor. Mix and pump 30 bbl MCS-4D sweep at 10.0 ppg, 1550 sx Class G + 2% KCI + 22% LW-6 + 5% MPA-1 + .9% BA-10 + .2% FL-63 + .15% A-2 + .6% CD-32 + .1 % R-3 + 1 ghs FP-6L, mixed at 12.7 ppg, yield - 1.787 cf/sx, 493 bbls. Tailed with 650 sx Glass G + 2%KCI + .9% BA-1Q + .2% FL-63 + .35% A-2 + .6% CD-32 + .25% R-3 + 1 ghs FP-6L, mixed at 15.7 ppg, yield - 1.184 cf/sx, 137 bbl. Drop dart and displace with 10 bbl water from BJ and 187 bbl mud with rig pump. Bump dart with 197 bbl total - 10 bbl prior to calculated 207 bbl displacement, with 500 psi over displacemen pressure. CIP - 0500 hrs 11/11/03. Recovered - 87 bbl contaiminated mud wI cement back to surface. Check floats, Printed: 4/8/2004 3:41:53 PM · 00:30 05:00 4.50 10,560 10,560 AF CSGIN1 CEMT 05:00 06:00 1.00 10,560 10,560 AF CSGlN1 CIRC floats holding. Bleed off trapped 750 psi annulus pressure. Put 300 psi on drill pipe and sting out of packoff bushing. Observe pressure drop when seals cleared. Pump 30 bbls down drill string to insure dart was not in string. Reverse out two drill string volumes. At report time observing cement contaminated mud 80 bbls after bottoms up. Shut down and check floats, no flowback up drill string. Continue reverse out. Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Oil Tools 23 340.00 Weaver Brothers (WBI) 2 48.00 R&K Industrial 2 24.00 BJ Services 2 24.00 Wildflowers and Resin 2 48.00 2 2 4 2 4.00 24.00 40.00 10.00 18.57 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) (psi) @ (ppg) 130 2,860 10,533 130 2,368 5,417 K-55 K-55 L-80 3,060 3,450 5,750 LAST CASING TEST: 10/24/2003 20.000 13.375 7.000 18.730 12.415 6.184 133.00 68.00 29.00 Printed: 4/8/2004 3:41 :53 PM 24 HR PROG TMD 30.6 10,560 RIG NAME & NO. AUTH MD Nabors 273E 17,300 RIG PHONE MOC WI NR! CUM WEll COST WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS POOH 907-260-6935 100.0000 COUNTY/OTHER LAST CASING LEAKOFF 7.000 in 24 HR FORECAST PU 7,000' of 4" DP. Test BOP's, TIH with clean out BHA. OPERATION COMMENTS Circulate hole clean. POOH and LD cement stinger. Trip in hole with FJD running tool and MWD. Cut drill line and continue TIH. Engage top of junction and confirm orientaion of same. Drop gyro and POOH. REGULATORY INSP? 06:00 06:30 0.50 10,560 10,560 AF CSGIN1 CIRC Finish reversing out. 06:30 08:00 1.50 10,560 10,560 AF CSGIN1 CIRC Circulate bottoms up. 08:00 10:00 2.00 10,560 10,560 AF CSGIN1 TRIP POOH to junction - circulate and flush junction. 10:00 15:00 5.00 10,560 10,560 AF CSGIN1 TRIP POOH and LD cement stinger. 15:00 17:30 2.50 10,560 10,560 AF CSGIN1 TRIP PU FJD running tool and MWD, test MWD, remove ports on FJD running tool to allow higher flow rates. Retest MWD. 17:30 18:30 1.00 10,560 10,560 AF CSGIN1 TRIP TIH to 2450'. 18:30 20:30 2.00 10,560 10,560 AF CSGIN1 RIG Slip and Cut Drill Line 20:30 23:00 2.50 10,560 10,560 AF CSGIN1 TRIP TIH to top of junction at 9900'. 23:00 01:00 2.00 10,560 10,560 AF CSGIN1 SURV Break circulation, confirm MWD working. Engage diverter and plu to verify, pulled it wI 40k overpull accidently - reset same. Orient into top of junction, pump up MWD survey to confirm orientaion. (Hydraulic release GS typre spear pulling tool) PU out of junction and repeat two more times to confirm reading. Leg 1 (motherbore) of junction is laying 180 degrees from high side of the hole. 01:00 02:00 1.00 10,560 10,560 AF CSGIN1 SURV Drop gyro survey, allow to free fall and then pump to bottom. Pump Slug. 02:00 06:00 4.00 10,560 10,560 AF CSGIN1 TRIP POOH COMMENTS Another BOP test extension given by AOGCC Lou Grimaldi until after FJ orientation and then PIU 4" DP. Must test before PU drill out assembly. 24 hr notice given and will notify Tom Monder. I FJD RUNNING TOOL, Bumper Sub, MWD Tool, Cross Over Printed: 4/8/2004 3:41 :54 PM NEXT BOP TEST: 11/9/2003 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 (psi) @ (ppg) 10,533 5,417 29.00 L-80 5,750 Printed: 4/8/2004 3:41:54 PM WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Gerard Ro er I Russ Trub FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS RD BOP test e ui ment. OPERATION COMMENTS LD orientation BHA, PU and RIH with 7,077' of 4" DP, POOH and stand back same. Test BOP's. 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 10,560 AUTH MD 17,300 907-260-6935 COUNTY/OTHER MOC WI . NRI 100.0000 DX0309030CAPDRL i DAILY WELL COST ,r.! I~" "Alel I ,..-...- , PJG PHONE LEAKOFF for Autotrac. 06:00 08:30 2.50 10,560 10,560 AF CSGIN1 TRIP 08:30 20:00 11.50 10,560 10,560 AF CSGIN1 TRIP 20:00 23:30 3.50 10,560 10,560 AF CSGIN1 TRIP 23:30 06:00 6.50 10,560 10,560 AF CSGIN1 TEST Finish POOH, LD FJD running tool and MWD. RU PU machine, finish strapping 4" DP. PU and RIH wI 7,077' of 4",15.7 ppf, S-135, HT-40 DP. POOH and stand back 4" in derrick. Pull wear bushing and install test plug. Test Hydril, upper and lower top drive valves, choke manifold, 5 1/2" pipe rams, blind rams, 5 1/2" TIW and IBOP, and 4" TIW and IBOP to 250 psi low and 3500 psi high for five minutes.Test VBR with both 5 1/2' and 4" drill pipe to 250 psi low and 3500 psi high for five minutes. Run accumulator test. Test gas and H2S alarms. Tom Maunder, AOGCC, waived witnessing of BOP test. I Tri-Cone Bit, Bit Sub. Drill Collar (6), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), Drill Pipe (18), Cross Over Nabors Alaska Drilling Marathon 2 2 24.00 24.00 Printed: 4/8/2004 3:41 :55 PM 20.000 13.375 7.000 18.730 12.415 6.184 18.57 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) (psi) @ (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:41:55 PM F!ELD NAME RIG PHONE 24 HR PROG TMD 20.0 10,580 AUTH MD 17 ,300 MOC WI 100.0000 TVD 5,435 WBS 30.6 RIG NAME & NO. Nabors 273E DX0309030CAPDRL NR! I DA!l Y WEll COST CUM WEL.L. COST 907-260-6935 COUNTY/OTHER lEAKOFF rior to shoe test. for AutoTrack 06:00 10:00 4.00 10,560 10,560 AF CSGIN1 TRIP Clear floor, PU up 6" mill tooth bit and slick BHA and 6 stands 0 4" DP. 10:00 18:00 8.00 10,560 10,560 AF CSGIN1 TRIP TIH, tag packoff bushing at 10,438' DP measurment. 18:00 20:00 2.00 10,560 10,560 AF CSGIN1 CIRC Displace hole with new 9.0 ppg FloPro mud. 20:00 22:00 2.00 10,560 10,560 AF CSGIN1 TEST Test 7" x 9 5/8" casing and junction to 1800 psi for 30 minutes. 22:00 03:30 5.50 10,560 10,560 AF CSGIN1 DRILL Drill out pack off bushing, landing collar, float collar, shoe track, and float shoe. 03:30 05:30 2.00 10,560 10,560 AF CSGIN1 CIRC Wash down to bottom of 12 1/4" hole at 10,560'. Hole packing off and torquing up, having to wash and ream 3'·5' at a time an ream back to the shoe to keep from packing off. Acts like loose fill and cuttings and not junk. 05:30 06:00 0.50 10,560 10,580 AF CSGIN1 DRILL Drill new formation from 10,560' to 10,580', LOT depth. 12,000 210 139 I 0.50 Tri-Cone Bit, Bit Sub, Drill Collar (6), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), Drill Pipe (18), Cross Over 1,900 1,900 586.04 586.04 1 NATIONAL 2 NATIONAL Printed: 4/8/2004 3:41:57 PM Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Oil Tools LAST BOP TEST: 11/13/2003 20.000 13.375 7.000 18.730 12.415 6.184 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) (psi) @ (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 18.57 Printed: 4/8/2004 3:41:57 PM WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Gerard Ro er I Russ Trub . FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS 1 MTS TlH OPERATION COMMENTS C&C 9.0 ppg mud. Perform FIT on 7" shoe to 16.08 ppg EMW. AutoTrak BHA. KB 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 10,580 AUTH MD 17 ,300 . MOC WI NR! "'1 1M WF'-l COST RIG PHONE 907-260-6935 COUNTY/OTHER 100.0000 LEAKOFF 16.08 Drop gyro, C&C mud. TOOH wI clean out BHA,PU and RIH with 4 3/4" C&C mud after drilling 20' of new formation. Pull into casing an con't C&C 9.0 ppg FloPro mud. 08:30 09:00 0.50 10,580 10,580 AF CSGIN1 TEST Perform FIT wI 2,000 psi spp, 9.0 ppg mud @ depth of 10,580' MD (5,435' TVD) for shoe test of 16.08 ppg EMW. 09:00 10:30 1.50 10,580 10,580 AF CSGIN1 CIRC Circulate and Condition Mud 10:30 19:30 9.00 10,580 10,580 AF CSGIN1 TRIP Trip for BHA 19:30 21:00 1.50 10,580 10,580 AF CSGIN1 TRIP BHA/Bit Handling 21:00 01:30 4.50 10,580 10,580 AF DRLPR TRIP RIU and PIU 4-3/4" Autotrak tool. Plug in and confirm tool functions. MIU 6" HeR 405 PDC bit. MIU drilling BHA. 01:30 06:00 4.50 10,580 10,560 AF DRLPR TRIP TIH with 4" x 5 1/2" tapered string. 15 BHA DESCRIPTION I Polycrystalline Diamond Bit, RST, Auto Trak Gen 3.0, 5-7/8" , Non Mag Float Sub, 5-7/8" Non-Mag Integral Blade Stabilizer, Non-Mag Drill Collar (3), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), 4" (43 STDS) Drill Pipe (129), Cross Over 602.80 602.80 1 NATIONAL 2 NATIONAL Printed: 4/8/2004 3:41:58 PM Nabors Alaska Drilling 23 340.00 Scientific Drilling Control 1 24.00 Marathon 2 48.00 Lynden Transport 1 1.00 Epoch Well Services 2 24.00 S&R Enterprises 1 2.00 M-I Drilling Fluids 2 24.00 Weaver Brothers (WBI) 1 3.00 R&K Industrial 3 18.00 Atigun 2 5.00 Baker Hughes Inteq 5 60.00 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 2,000 (psi) @ (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 3,060 3,450 5,750 20.000 13.375 7.000 18.730 12.415 6.184 K-55 K-55 L-80 Printed: 4/8/2004 3:41:58 PM R!G PHONE 24 HR PROG TMD 224.0 10,804 AUTH MD 17,300 MOC W! 100.0000 DX0309030CAPDRL 30.6 RIG NAME & NO. Nabors 273E , NR! ,nAil v \A1F=! I !"::!"!~'!" . r.!!M WF!! r.n~T WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS 1 MTS Run surface check on back u AutoTrak OPERATION COMMENTS TIH with AutoTrak, drill 10,580' - 10,804'. Lost hydraulic pressure to steering ribs on AutoTrak. 43/4" AutoTrack. 907-260-6935 COUNTY/OTHER LEAKOFF 16.08 Circulate 2 X bottoms up. POOH and change out 06:00 09:30 3.50 10,580 10,580 AF DRLPR TRIP TIH w/4 3/4" AutoTrak to 10,530'. Break circ and safety wash the rathole below the casing shoe to TD of 10,580' 09:30 10:00 0.50 10,580 10,580 AF DRLPR RIG Service top drive while C&C mud and taking slow pump rates. 10:00 15:30 5.50 10,580 10,804 AF DRLPR DRILL Drill from 10,580' - 10,804'. ADT - 3.2 hrs. Lost hydraulic pressure to ribs on AutoTrak. 15:30 18:30 3.00 10,804 10,804 TA DRLPR CIRC MWD Circulate 2 x bottoms up at 300 gpm, 2100 psi while rotating 120-140 rpm and working pipe. Flow check well and and pump slug. 18:30 02:00 7.50 10,804 10,804 TA DRLPR TRIP MWD POOH from 10,804'. 02:00 06:00 4.00 10,804 10,804 TA DRLPR TRIP MWD RIB HWDP DC. Download and LD AutoTrak. Break off steerin section off MWD for shipment to town. UD AutoTrak and MWD. Pick up and run diagnostic check on back up AutoTrak. COMMENTS Replaced MWD surveys with Gyro survey run on 11/15/2003. 4,453.20 195 145 13,000/1 3.90 BHA DESCRIPTION Polycrystalline Diamond Bit, RST, Auto Trak Gen 3.0, 5-7/8" , Non Mag Float Sub, 5-7/8" Non-Mag Integral Blade Stabilizer, Non-Mag Drill Collar (3), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), 4" (43 STDS) Drill Pipe (129), Cross Over Printed: 4/8/2004 3:42:04 PM . , ..... .............. . .<> >( . ......... ........ c . ........... .·..i..··.·······//c, """'.. I / . ... ........ ................. .,. ..... ... , ... ...... ............. ..... WELL NAME IKB IGL 24HRPROGTMD ITVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 PB1 30.6 74.00 224.0 10,804 5,516 32 32 32 16-Nov-2003 .. '.'.' -..................' .i.~ ; NO! ........... ./> 1 NATIONAL 12.000 6.000 72 301.40 2,100 301.40 2 NATIONAL 12.000 301.40 20 625 3 NATIONAL 12.000 301.40 20 625 '. . .................... "'T\Jh'C\i~_ 'ß,1p/ lì'JþG 'WP' 'Y$ 'C~'" .,., 0.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4,142.6 66.88 299.59 2,899.94 1,046.64 1,046.64 -2,075.35 0.38 103.1 0.31 249.12 103.10 -0.10 -0.10 -0.26 0.30 4,332.3 66.68 299.24 2,974.73 1,132.27 1,132.27 -2,227.21 0.20 195.2 0.37 256.11 195.20 -0.26 -0.26 -0.78 0.08 4,427.9 66.53 298.89 3,012.69 1,174.89 1,174.89 -2,303.90 0.37 287.2 0.26 271.14 287.20 -0.33 -0.33 -1.28 0.15 4,525.0 66.58 298.71 3,051.32 1,217.81 1,217.81 -2,381.96 0.18 382.9 0.58 20.76 382.89 0.13 0.13 -1.32 0.74 4,618.0 66.69 298.59 3,088.20 1,258.74 1,258.74 -2,456.89 0.17 478.5 1.22 48.93 478.48 1.25 1.25 -0.39 0.79 4,712.3 66.62 298.27 3,125.57 1,299.96 1,299.96 -2,533.02 0.32 574.2 1.43 69.04 574.16 2.35 2.35 1.50 0.53 4,807.6 66.75 297.17 3,163.29 1,340.67 1,340.67 -2,610.50 1.07 669.8 0.73 91.81 669.74 2.76 2.76 3.22 0.85 4,903.6 66.67 297.08 3,201.25 1,380.87 1,380.87 -2,688.98 0.12 765.5 5.05 268.49 765.33 2.63 2.63 -0.38 6.04 5,000.5 66.73 297.18 3,239.58 1,421.45 1,421.45 -2,768.18 0.11 861.2 9.38 275.84 860.25 3.31 3.31 -12.36 4.62 5,096.9 66.51 297.26 3,277.83 1,461.93 1,461.93 -2,846.87 0.24 1,005.6 11.86 286.14 1,002.18 8.63 8.63 -38.33 2.16 5,192.7 66.57 296.89 3,315.97 1,501.93 1,501.93 -2,925.12 0.36 1,101.1 13.41 293.50 1,095.37 15.78 15.78 -57.91 2.34 5,289.2 66.94 296.31 3,354.05 1,541.63 1,541.63 -3,004.40 0.67 1,190.5 14.94 291.61 1,182.05 24.15 24.15 -78.13 1.79 5,385.2 66.56 295.78 3,391.95 1,580.36 1,580.36 -3,083.64 0.64 1,284.7 16.60 290.65 1,272. 70 33.37 33.37 -102.01 1.78 5,479.8 66.79 295.48 3,429.41 1,617.93 1,617.93 -3,161.97 0.38 1 ,379.2 19.31 289.65 1,362.59 43.39 43.39 -129.37 2.89 5,575.2 66.73 295.08 3,467.05 1,655.37 1,655.37 -3,241.23 0.39 1,474.1 21.57 289.41 1,451.51 54.46 54.46 -160.60 2.38 5,671.8 66.83 295.07 3,505.14 1,692.99 1,692.99 -3,321.64 0.10 1,568.8 24.79 290.25 1,538.55 67.12 67.12 -195.65 3.42 5,767.0 66.89 295.15 3,542.55 1,730.14 1,730.14 -3,400.91 0.10 1,663.0 30.38 293.46 1,622.02 83.46 83.46 -236.07 6.14 5,863.9 66.66 295.57 3,580.76 1 ,768.28 1,768.28 -3,481.37 0.46 1,759.4 34.93 294.96 1,703.16 104.82 104.82 -283.47 4.79 5,956.5 66.68 295.91 3,617.43 1,805.20 1,805.20 -3,557.96 0.34 1,855.8 37.28 295.66 1,781.04 129.11 129.11 -334.82 2.47 6,051.9 66.69 296.39 3,655.19 1,843.81 1,843.81 -3,636.61 0.46 1,951.3 41.79 295.48 1,854.67 155.34 155.34 -389.64 4.72 6,145.5 66.84 296.32 3,692.12 1,882.00 1,882.00 -3,713.68 0.17 2,047.4 46.26 295.54 1,923.75 184.09 184.09 -449.90 4.65 6,241.0 66.59 296.63 3,729.87 1,921.10 1,921.10 -3,792.20 0.40 2,142.6 49.10 297.26 1,987.85 215.41 215.41 -512.93 3.27 6,337.3 66.61 296.95 3,768.11 1,960.94 1,960.94 -3,871.09 0.31 2,237.2 51.11 297.98 2,048.52 249.06 249.06 -577.23 2.20 6,433.4 66.60 297.41 3,806.27 2,001.23 2,001.23 -3,949.55 0.44 2,351.3 53.12 298.09 2,118.58 291.39 291.39 -656.71 1.76 6,529.9 66.80 297.68 3,844.44 2,042.21 2,042.21 -4,028.13 0.33 2,425.6 55.22 299.00 2,162.07 320.17 320.17 -709.62 3.00 6,623.3 66.80 298.21 3,881.24 2,082.44 2,082.44 -4,103.97 0.52 2,522.0 57.80 298.63 2,215.26 358.92 358.92 -780.06 2.70 6,718.4 66.91 298.85 3,918.62 2,124.21 2,124.21 -4,180.80 0.63 2,618.4 59.13 297.80 2,265.68 397.76 397.76 -852.46 1.56 6,814.2 66.45 299.39 3,956.54 2,167.02 2,167.02 -4,257.65 0.71 2,712.5 58.91 297.41 2,314.12 435.14 435.14 -923.95 0.43 6,914.5 66.79 299.87 3,996.34 2,212.54 2,212.54 -4,337.68 0.55 2,806.3 63.12 296.70 2,359.56 472.44 472.44 -997.01 4.54 7,004.0 66.82 300.14 4,031.59 2,253.67 2,253.67 -4,408.92 0.28 2,995.3 64.65 296.56 2,442.75 548.51 548.51 -1,148.71 0.81 7,097.0 66.52 300.15 4,068.42 2,296.56 2,296.56 -4,482.76 0.32 3,090.0 66.44 296.98 2,481.95 587.33 587.33 -1,225.67 1.93 7,190.5 66.47 300.06 4,105.71 2,339.57 2,339.57 -4,556.94 0.10 3,185.2 66.28 296.97 2,520.13 626.89 626.89 -1 ,303.40 0.17 7,285.5 66.86 299.71 4,143.34 2,383.03 2,383.03 -4,632.57 0.53 3,280.5 66.33 296.98 2,558.43 666.48 666.48 -1,381.17 0.05 7,381.2 66.72 299.24 4,181.06 2,426.31 2,426.31 -4,709.14 0.47 3,376.5 66.65 297.29 2,596.72 706.63 706.63 -1,459.51 0.45 7,475.7 66.87 298.42 4,218.29 2,468.19 2,468.19 -4,785.23 0.81 3,473.0 66.47 297.80 2,635.11 747.57 747.57 -1,538.01 0.52 7,569.4 66.72 297.57 4,255.22 2,508.61 2,508.61 -4,861.27 0.85 3,567.9 66.49 298.25 2,672.98 788.45 788.45 -1,614.82 0.44 7,664.0 66.64 296.30 4,292.67 2,547.96 2,547.96 -4,938.72 1.24 3,664.2 66.86 298.59 2,711.11 830.54 830.54 -1,692.59 0.50 7,757.0 66.66 294.80 4,329.53 2,584.79 2,584.79 -5,015.75 1.48 3,760.0 66.80 299.07 2,748.80 873.01 873.01 -1,769.75 0.46 7,853.7 66.63 293.42 4,367.86 2,621.05 2,621.05 -5,096.78 1.31 3,857.2 66.77 299.75 2,787.12 916.88 916.88 -1,847.57 0.64 7,949.7 66.76 293.29 4,405.84 2,656.00 2,656.00 -5,177.72 0.18 3,953.0 66.80 299.72 2,824.88 960.54 960.54 -1,924.02 0.04 8,045.6 66.71 293.72 4,443.72 2,691.14 2,691.14 -5,258.51 0.42 4,047.3 66.52 299.62 2,862.24 1,003.40 1,003.40 -1,999.25 0.31 8,141.4 66.78 294.30 4,481.55 2,726.95 2,726.95 -5,338.91 0.56 Printed: 4/8/2004 3:42:04 PM . . ....... ........;; i ......... ....c······c· .. ,c'. / ............ c:.·.c '''''';.:i; Ii ......,... i· . .; . I· .i . . ······C.. . ..... ..' ; ...... '. . WELL NAME KB IGL 24HRPROGITMD ITVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 PB1 30.6 74.00 224.0 10,804 5,516 32 32 32 16-Nov-2003 , .......... ...../.... .... i. ..... ..... . ...... ·s········.., ...·.··....·i_ .·..MÔ·· INCL.······ ·.····/·X~; It"! c,·y"p .......... '.- 8,236.9 66.89 294.43 4,519.11 2,763.18 2,763.18 -5,418.89 0.17 9,566.6 66.68 293.14 5,047.73 3,275.77 3,275.77 -6,525.95 0.12 8,332.7 66.78 294.97 4,556.80 2,799.98 2,799.98 -5,498.91 0.53 9,660.0 66.64 292.37 5,084.73 3,308.94 3,308.94 -6,605.04 0.76 8,429.9 66.55 295.34 4,595.30 2,837.92 2,837.92 -5,579.70 0.42 9,755.6 66.68 291.70 5,122.61 3,341.87 3,341.87 -6,686.40 0.64 8,524.3 66.60 295.49 4,632.68 2,875.12 2,675.12 -5,657.99 0.30 9,649.4 66.43 291.38 5,159.93 3,373.47 3,373.47 -6,766.45 0.41 6,619.0 66.49 295.75 4,670.22 2,912.71 2,912.71 -5,736.39 0.41 9,943.6 66.50 290.85 5,197.62 3,404.64 3,404.64 -6,847.16 0.52 8,715.2 66.62 295.71 4,706.34 2,951.06 2,951.06 -5,815.95 0.35 10,038.6 66.70 290.22 5,235.27 3,435.16 3,435.16 -6,928.66 0.65 6,609.3 66.61 295.65 4,745.39 2,988.54 2,968.54 -5,893.91 0.06 10,134.9 66.53 289.58 5,273.50 3,465.25 3,465.25 -7,011.77 0.64 6,901.6 66.24 295.35 4,782.16 3,024.99 3,024.99 -5,970.32 0.69 10,228.9 66.35 289.41 5,311.07 3,494.00 3,494.00 -7,092.99 0.25 6,996.7 66.19 295.27 4,621.32 3,062.97 3,062.97 -6,050.65 0.09 10,255.2 66.41 289.39 5,321.61 3,502.01 3,502.01 -7,115.72 0.24 9,091.1 66.46 295.04 4,858.42 3,096.95 3,096.95 -6,127.24 0.37 10,323.9 66.61 289.16 5,348.99 3,522.61 3,522.81 -7,175.20 0.42 9,185.6 66.61 294.74 4,696.13 3,135.51 3,135.51 -6,206.04 0.33 10,417.7 66.41 289.28 5,386.38 3,551.13 3,551.13 -7,256.43 0.24 9,282.9 66.42 294.02 4,934.63 3,172.27 3,172.27 -6,267.16 0.71 10,610.9 66.82 290.49 5,463.06 3,611.44 3,611.44 -7,423.18 0.61 9,378.9 66.53 293.61 4,973.14 3,207.61 3,207.81 -6,367.68 0.41 10,703.7 66.86 289.49 5,499.56 3,640.61 3,640.61 -7,503.36 0.99 9,473.8 66.57 293.10 5,010.91 3,242.32 3,242.32 -6,447.61 0.49 10,764.4 66.65 288.29 0.00 0.00 0.00 0.00 0.00 ...... .;. i'; .) ...... Nabors Alaska Drilling 23 340.00 Baker Hughes Inteq 5 60.00 Marathon 2 48.00 R&K Industrial 1 6.50 Epoch Well Services 2 24.00 BJ Services 1 2.50 M-I Drilling Fluids 2 24.00 LAST BOP TEST: 11/13/2003 LAST CASING TEST: 11/13/2003 NEXT BOP TEST: 11/20/2003 - ~- ;'.;;; -~~ - 'i.; 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.08 2,000 (psi) @ (ppg) 10,533 5,417 29.00 L-80 5,750 . Printed: 4/8/2004 3:42:04 PM RIG PHONE 24 HR PROG TMD 10,804 AUTH MD 17 ,300 !!I!OC WI NRI 100.0000 DX0309030CAPDRL , DAILY WELL COST r.;._ .__. - . ---_ KB 30.6 RIG NAME & NO. Nabors 273E 907-260-6935 COUNTY/OTHER LEAKOFF 16.08 fuel and water lines. POOH. Diesel fuel gelled due to cold. Secure 06:00 06:30 0.50 10,804 10,804 TA DRLPR TRIP MWD Finish uploading to AutoTrak BHA. 06:30 08:00 1.50 10,804 10,804 TA DRLPR TRIP MWD Make up bit and trip in hole to 1,294'. 08:00 08:30 0.50 10,804 10,804 TA DRLPR TEST MWD Shallow test AutoTrak - OK. 08:30 14:30 6.00 10,804 10,804 TA DRLPR TRIP MWD TIH to 10,453'. Noted - 10 k drag thru top of junction, 14:30 15:00 0.50 10,804 10,804 TA DRLPR TEST MWD Fill pipe, down link to AutoTrak to test - OK. Service rig, top drive, blocks and crown. C&C mud. Obtain SPR's. 15:00 15:30 0.50 10,804 10,804 TA DRLPR TRIP MWD TIH to 10,668'. Tag tight spots at 10,668' - 10675'. 15:30 16:30 1.00 10,804 10,804 TA DRLPR TRIP MWD Wash I Ream tight hole from 10,650' -10,804', Hole packing 0 at - 10,675-10,700', 300 gpm, 2,500 psi. (Pressrues are - 400 psi higher than previous 4-3/4" Autotrak run). 16:30 17:00 0.50 10,804 10,811 AF DRLPR DRILL Drill 10,804' -10,811',300 gpm and 2,700 psi. ADT -.1 hr. Lost hydraulic pressure to ribs on AutoTrak when performing down -link. 17:00 18:30 1.50 10,811 10,811 TA DRLPR CIRC MWD Circulate one bottoms up at 300 gpm and 2700 psi while rotatin pipe 120 rpm , working pipe and performing diagnostics on Autotrak. Flow Check well - OK Mix and pump slug. Max trip gas 21 units. 18:30 23:30 5.00 10,811 10,811 TA DRLPR TRIP MWD POOH for MWD and motor. Noted 15K drag at top of junction. POOH to 3220' 23:30 06:00 6.50 10,811 10,811 TA DRLPR WAIT WOW Lost boilers due to ice crystals in fuel filters and diesel. Blow down all water and steam lines on rig. At 0130 hours rig engines started going off line. Install and close TIW on drill string and close top pipe rams. Air compressor is running off day tank with treated diesel suppling air to accumulator. Continue draining lines while waiting on diesel addidtive, diesel and heaters. Diesel and additives arrived at 0400, refired boiler at 0430. Bringing engines on line and thawing out frozen lines on rig. Temperature (-15 deg F) Printed: 4/8/2004 3:42:07 PM 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 2,000 (psi) @ (ppg) 130 2,860 10,533 130 2,368 5,417 3,060 3,450 5,750 Printed: 4/8/2004 3:42:07 PM < ..···.i <. ... Xi ....... .......... .:...... .. ... ·/i ..... ......... ... ..... ... ...... ... .... /..... .... .... ....... .... i> WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL RPT# DATE KASILOF SOUTH 1 PB1 30.6 74.00 156.0 10,960 5,596 34 34 34 18-Nov-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Gerard Roaer I Russ Trubv Nabors 273E 17,300 DX0309030CAPDRL F!ElD NAME RIG PHONE MCC\'VI NRI ! D'" ~ ...~.. ~~s- I CüM ~NEi..L COST , I I'\ILoI ---.. ..~ 1 WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 " STATEJPROV COUNTY/OTHER I LAST CASING I NEJ.., ~",'>Ir". - I LEAK OFF Alaska 7.000 (in) ((ù 1 0,533 (ft) 3.500 (in) ((ù 17,232 (ft) 16.08 CURRENT STATUS / MTS \24 HR FORECAST Drillino at 10,960'. Drill 6" directional open hole per plan. OPERATION COMMENTS Finish POOH and LD AutotTrac. TIH wI motor and MWD. Drill 10,811' - 10,960'. " .' '/!,..;.';, ""c:r""~~,;g" "I" '''¡,,¡~, ,"" '" .nM, ¡. ......... ·.U· MANHRS WORKED ACCIDENT TYPE I LAST SAFETY MTG l~oP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? LAST RIG INSPECTION 520.00 None 11/17/2003 1111312003 11/16/2003 N 11/13/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Reviewed safety alerts and bulletins 06:00 07:00 1.00 10,811 10,811 TA DRLPR WAIT WOW Finish thawing out frozen lines. 07:00 09:00 2.00 10,811 10,811 TA DRLPR TRIP MWD Check for pressure, open rams and POOH. 09:00 15:30 6.50 10,811 10,811 TA DRLPR TRIP MWD Download AutoTrak, break out bit (small piece of carbide blocking one nozzle), LD AutoTrak and MWD. PU motor, MWD, pony collar and stabilzer. Orient and surface test MWD. Make up bit. 15:30 17:00 1.50 10,811 10,811 TA DRLPR TRIP MWD TIH with flex collars, 4" HWDP and 4" DP to 1325'. Torque on iron roughneck had not been reset to 17,000 ft-Ibs for 4" DP after making up BHA 17:00 18:30 1.50 10,811 10,811 TA DRLPR TRIP MWD POOH 11 stds of 4" and rack back. RIH same 11 stds making up to correct torque. RIH to 1325'. 18:30 19:00 0.50 10,811 10,811 TA DRLPR TRIP MWD Shallow test MWD and motor - OK. 300 gpm at 1400 psi. 19:00 01:30 6.50 10,811 10,811 TA DRLPR TRIP MWD TIH to 10,500', fill pipe every 2500'. Saw 5-10K drag as passec bifurcation point at 9,920'. 01:30 02:30 1.00 10,811 10,811 TA DRLPR CIRC MWD Fill pipe and take SPR's. Circulate and clean old 12 1/4" hole 10,530' to 10,560' while changing filters on #2 motor. 02:30 03:00 0.50 10,811 10,811 TA DRLPR TRIP MWD Precautionary wash and ream from 10,675' to 10,811'. No fill or hole problems. 03:00 06:00 3.00 10,811 10,960 AF DRLPR DRILL Directional drill with motor 10,811' to 10,960'. AST - .6 hrs, ART - 1.0 hrs. 300 gpm, 2200 -2500 psi and 120 rpm. ~9'20~ ~ "'... , .......... ~!='!,i~···I···'!'(J',,~i 60 13129 12116 I 5.01 1.0/5.0 195 I 9.2010.3 0.213.0 37,600 160 I I . B.~..... , ~ .. .. . ..... . ... ~~È MÂN~F.. . ..T¥~~.. ... .... RR111 6.000 Hughes HCR405 7103527 11/11/11/11111111 10,804.0 11/1612003 O-O-NO-A-X- I-PN-BHA RR211 6.000 Hughes HCR405 7103527 11/11/11/1111111I 10,811.0 11/17/2003 O-O-NO-A-O- I-NO-BHA BIT I RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 6RR1/11 5/10 1401140 300 2,700 541 70.00 0.10 7.0 70.00 6RR2/12 2/7 1120 300 2,250 553 1.60 149.0 93.13 1.60 149.0 93.13 . . Printed: 4/8/2004 3:42:08 PM · WELL NAME KASILOF SOUTH 1 PB1 BHA NO. 29 130 145 12,000/14,500 4.00 Polycrystalline Diamond Bit, Positive Displacement Motor, Non-Mag Integral Blade Stabilizer, Non-Mag Pony Collar, Non-Mag Crossover Sub, MWD Tool, Non-Mag Drill Collar (3), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), 4" (43 STDS) Drill Pipe (129), Cross Over 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 2,000 (psi) @ (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:08 PM WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Milton Castlemanl Russ Trub F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin at 12008'. OPERATION COMMENTS Drill to 11,815'. Circulate hole clean. 30.6 RIG NAME & NO. Nabors 273E R!G PHONE 907-260-6935 COUNTY/OTHER LEAKOFF 16.08 Directional drill with motor 10,960' to 11,815'. AST - 2.6 hrs. ART - 6.2hrs. 300 gpm and 130 rpm while rotating. 20:00 22:30 2.50 11 ,815 11,815 AF DRLPR CIRC Circulate and condition hole for short trip. 300 gpm and 130 rp while recipricating one stand for 2 bottoms up. 22:30 00:30 2.00 11,815 11,815 AF DRLPR TRIP POOH to casing shoe, maximum overpull seen was 20k. Each time broke back clean. 00:30 01:00 0.50 11,815 11,815 AF DRLPR RIG Service rig, top drive, blocks and crown. 01:00 02:30 1.50 11,815 11,815 AF DRLPR TRIP TIH to 11,720', hole in good condition. Precautionary wash and ream 11,720'to 11,815'. 02:30 06:00 3.50 11,815 12,008 AF DRLPR DRILL Drill 11,815' to 12008'. AST -1 hrs. ART -1.6 hrs.300 gpm an 140 rpm while rotating. KILL SPM / PRESSURE 30 850 30 825 Printed: 4/8/2004 3:42:10 PM ·\ . 10,983.2 67.72 281.51 5,607.76 3,714.26 3,714.26 -7,750.09 4.37 11,457.9 66.47 268.04 5,795.44 3,729.68 3,729.68 -8,184.54 1.31 11,077.0 66.27 276.50 5,644.44 3,727.79 3,727.79 -7,835.32 5.15 11,553.7 66.86 267.88 5,833.39 3,726.55 3,726.55 -8,272.45 0.44 11,170.6 65.75 273.00 5,682.50 3,734.87 3,734.87 -7,920.52 3.46 11,649.8 67.03 267.27 5,871.02 3,722.81 3,722.81 -8,360.80 0.61 11,264.0 66.74 268.44 5,720.14 3,735.93 3,735.93 -8,005.97 4.59 11,747.0 67.49 267.30 5,908.60 3,718.56 3,718.56 -8,450.34 0.47 11,362.4 67.69 267.75 5,758.25 3,732.92 3,732.92 -8,096.64 1.16 11,841.1 66.58 269.50 5,945.32 3,716.14 3,716.14 -8,536.94 2.36 LAST BOP TEST: 11/13/2003 LAST CASING TEST: 11/13/2003 NEXT BOP TEST: 11/20/2003 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.08 2,000 (psi) @ (ppg) 10,533 5,417 29.00 L-80 5,750 Printed; 4/8/2004 3;42;10 PM · WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Milton Castlemanl Rand Ratlif FIELD NAME 30.6 RIG NAME & NO. Nabors 273E 13,685 AUTH MD 17,300 R!G PHONE MOC WI NRf I CUM \.\"ElL. COST 907-260-6935 COUNTY/OTHER 100.0000 Lt:A.l'\.ut"r 16.08 06:00 18:00 12.00 12,008 13,053 AF DRLPR DRILL Directional drill wI motor 12,008'-13,053'. AST- 0.6 hrs ART- 7.5 hrs. 300 gpm and 140 rpm while rotating. 18:00 21:00 3.00 13,053 13,053 AF DRLPR CIRC Circulate hole for short trip. 300 gpm and 125 rpm while recipricating one stand for 2-btms up. 21:00 22:30 1.50 13,053 13,053 AF DRLPR TRIP POOH to 11,720'. Maximum overpull30k. Hole in good shape. 22:30 23:00 0.50 13,053 13,053 AF DRLPR RIG Service Top Drive. 23:00 00:00 1.00 13,053 13,053 AF DRLPR TRIP TIH to 13,053', hole in good shape. Precautionary wash and ream f/12,957'-13,053'. 00:00 06:00 6.00 13,053 13,685 AF DRLPR DRILL Directional drill wI motor 13,053'-13,685'. ART - 3.8 hrs. 300 gpm and 140 rpm while rotating. NO. MAKE OF PUMP 1 NATIONAL 3 NATIONAL KILL SPM I PRESSURE 35 1 ,100 35 1,200 Printed: 4/8/2004 3:42:13 PM I . . ~ KB IGL 24HRPROGTMD TVD I 30.6 74.00 1,677.0 I 13,685 6,680 WELL NAME KASILOF SOUTH 1 PB1 .. ..,..---- ~ :~~- -~- , . IDFS IDOL IRPT# DATE I 36 I 36 I 36 20-Nov-2003 . AVG. CONN: MAX. CONN: :. Mp, :INþL' 11 ,938.0 66.55 12,031.7 66.92 12,127.5 67.06 12,222.6 65.04 12,316.7 64.76 12,409.4 65.32 12,506.9 65.70 12,599.1 66.16 12,695.1 66.20 >i. ... · ····i . ............ ·········'i> .......... < ·.1. <>liØ~'"Tª units I AVG. TRIP: 23 i AVG. BKGRD: 2 MAX. TRIP: MAX. DRL: 35 ..."'.,_............~ c:_..!.~._ 5.983.85 3,716.25 3,716.25 -8,625.84 1.08 12,790.6 66.38 270.52 6,331.14 3,729.19 3,729.19 -9,404.31 0.33 6,020.86 3,716.97 3,716.97 -8,711.92 0.50 12,887.9 66.46 270.20 6,370.07 3,729.75 3,729.75 -9,493.48 0.31 6,058.31 3,717.48 3,717.48 -8,800.10 0.15 12,980.4 66.69 269.57 6,406.84 3,729.58 3,729.58 -9,578.36 0.67 6,096.92 3,718.69 3,718.69 -8,887.00 2.29 13,075.6 67.07 269.98 6,444.22 3,729.24 3,729.24 -9,665.91 0.56 6,136.83 3,720.81 3,720.81 -8,972.18 0.47 13,167.5 67.07 268.58 6,480.03 3,728.17 3,728.17 -9,750.54 1.40 6,175.95 3,722.96 3,722.96 -9,056.20 0.68 13,263.0 67.26 269.08 6,517.09 3,726.38 3,726.38 -9,838.54 0.52 6,216.37 3,724.81 3,724.81 -9,144.91 0.44 13,357.0 67.34 270.51 6,553.37 3,726.07 3,726.07 -9,925.25 1.41 6,253.97 3,726.57 3,726.57 -9,229.07 0.55 13,452.9 67.24 269.00 6,590.39 3,725.69 3,725.69 -10,013.7 1.46 6,292.74 3,728.18 3,728.18 -9,316.88 0.49 13.546.5 67.48 269.21 6,626.42 3,724.34 3,724.34 -10,100.0 0.33 IVU VS 270.64 270.32 270.35 271.24 271.62 271.31 271.08 271.31 270.80 Nabors Alaska Drilling 23 340.00 Baker Hughes Inteq 5 60.00 Marathon 3 50.00 S&R Enterprises 1 3.00 Epoch Well Services 4 48.00 R&K Industrial 2 6.00 M-I Drilling Fluids 2 24.00 Weaver Brothers (WBI) 1 1 .00 .. ".' .:, ..... LAST BOP TEST: 11/13/2003 LAST CASING TEST: 11/13/2003 NEXT BOP TEST: 11/2012003 !b~'" ~~~l·-",~~J 18.730 (psi) @ (ppg) 130 130 133.00 K-55 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 6.184 16.08 2,000 (psi)@ (ppg) 10,533 5,417 29.00 L-80 20.000 13.375 7.000 3,060 3,450 5,750 Printed: 4/8/2004 3:42:13 PM · WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Milton Castlemanl Rand Ratlif F!ELD NAME KB 24 HR PROG TMD 501.0 14,186 AUTH MD 17,300 MûC Vvl NRI 100.0000 DX0309030CAPDRL 30.6 RIG NAME & NO. Nabors 273E RIG PHONE "' .... ...... '&'~I I I"nC;:T ' -. '.. '.'~I' "'nc;:;y WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Pull out of hole to Test BOPE, OPERATION COMMENTS Directional drill from 13,685'-14,186', Circ hole clean. LAST CASING 7.000 in 24 HR FORECAST Con't POOH. Test BOPE. PIU BHA. Cut Drill line. TIH. LEAKOFF 16.08 06:00 14:30 8.50 13,685 14,186 AF DRLPR DRILL 14:30 18:30 4.00 14,186 14,186 AF DRLPR CIRC 18:30 01:00 6.50 14,186 14,186 AF DRLPR TRIP 01:00 03:00 2.00 14,186 14,186 TA DRLPR RIG 03:00 06:00 3.00 14,186 14,186 AF DRLPR TRIP Directional drill from 13,685'-14,186'. ART-2.8 AST-2.6. 300 gpm and 140 rpm while rotating. Begin to drop angle @ 13,714'. Sliding -30'1 stand. Circulate hole clean recipricating dill pipe and rotaing 135 rpm. POOH to 9,724' max drag 30k. Hole in good condition, Had 10-20k drag thru bifurcation point. SOTH Trip tank pump not pumping properly. Attempt to isolate rig pit for hole fill. Could not accurately measure hole fill. Work on trip tank to pump properly. Con't pooh to 3300'. Extension for BOP Test issued by Jim Regg AOGCC 11/19/2003. 135,000 164,000 21,500/22,500 31 BHA DESCRIPTION Polycrystalline Diamond Bit, Positive Displacement Motor, Non-Mag Integral Blade Stabilizer, Non-Mag Pony Collar, Non-Mag Crossover Sub, MWD Tool, Non-Mag Drill Collar (3), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), 4" ( 43 STDS) Drill Pipe (129), Cross Over Printed: 4/8/2004 3:42:15 PM · 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 2,000 (psi) @ (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:15 PM . . ... < >... .........{ ....>... .... .'. ........ ..' ........ ..... J,D' ... .'7;:/- ''''L''' .. . ............ ..> L· .. .. ..... ........ ............... ,. .. .':.'.< '. ....... ........ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL \RPT# DATE KASILOF SOUTH 1 PB1 30.6 74.00 14,186 6,915 38 38 38 22-Nov-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Randy Ratliff/Milton Castleman Nabors 273E 17,300 DX0309030CAPDRL FIELD NAME RIG PHONE MOCWI ¡'¡RI I DAii. Y WELi. COST tCL," ..~~~ v___ I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 ST A TElPROV COUNTY/OTHER I LAST CASING INEXI ~A5INIõ - I LEAKOFF Alaska 7.000 (in) (ã>. 10,533 (ft) 3.500 (in) (ã>. 17,232 (ft) 16.08 CURRENT STATUS / MTS 24 HR FORECAST Wash and ream to btm @ 13800'. Drill Directional 6" hole. OPERATION COMMENTS Con't POOH. Test BOPE. Replace motor. Cut drill line. TlH to 13,800'. N ,;:y" 'y,"'~'W'''WT;' ,.,..~<';.. '"i.,.. ih ...:......p,.'/."......:.. ............:.. .... MANHRS WORKED I ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? LAST RIG INSPECTION 534.00 First Aid 11/21/2003 11/21/2003 11/21/2003 N 11/21/2003 ACCIDENT DESCRIPTION: Worker twisted left ankle in cellar area. SAFETY MTG TOPICS: Changing tong dies. Dangers of working with lanyard loose around moving equipment. 06:00 08:00 2.00 14,186 14,186 AF DRLPR TRIP Con't POOH to 338'. 08:00 08:30 0.50 14,186 14,186 AF DRLPR TRIP POOH wI BHA to MWD 08:30 09:30 1.00 14,186 14,186 AF DRLPR TRIP Download MWD 09:30 10:00 0.50 14,186 14,186 AF DRLPR TRIP Lay down drilling jars and XO 10:00 15:00 5.00 14,186 14,186 AF DRLPR TEST Test Hydril, upper and lower top drive valves, choke manifold, 5-1/2" pipe rams, blind rams, 5-1/2" TIW and IBOP, 4" TlW and IBOP to 250 psi low and 3500 psi high for five minutes. Test VBR with both 5-1/2" and 4" drill pipe to 250 low and 3500 high for five minutes. Run accumulator test. Test gas and H2S alarms. Jim Regg, AOGCC, waived witnessing of BOP test. 15:00 16:30 1.50 14,186 14,186 AF DRLPR TRIP UD motor. PIU New Motor - orient with MWD. 16:30 17:00 0.50 14,186 14,186 AF DRLPR TRIP Install wearbushing (9.0" ID) 17:00 18:30 1.50 14,186 14,186 AF DRLPR TRIP M/U Bit, RIH with BHA to 338'. 18:30 19:00 0.50 14,186 14,186 AF DRLPR TRIP Con't TIH to 1275'. 19:00 19:30 0.50 14,186 14,186 AF DRLPR TRIP Shallow test MWD. Good Test. 19:30 20:00 0.50 14,186 14,186 AF DRLPR SAFETY Hold PJSM. Review new Drill line cut and slip procedure wI Toolpusher and crew. 20:00 21:30 1.50 14,186 14,186 AF DRLPR RIG Slip and Cut Drill Line 21:30 01:30 4.00 14,186 14,186 AF DRLPR TRIP RIH with 74 stands 4" drill pipe. 01:30 02:30 1.00 14,186 14,186 AF DRLPR TRIP PIU an addtional 24 jts of 4" drill pipe. 02:30 06:00 3.50 14,186 14,186 AF DRLPR TRIP TIH. 10K drag at Bifurcation Point (Crotch of FORMation Junction). 10K drag beginning at 12,600'. 10k-30k drag beginning at 13,200'. 30-40k drag at 13,600'. wash and ream from 13,600'-13,800'. ,.,..~, .··",..::,,1 9.50 f·~pl I~"J'I ~~_. _. ¡iv pviYp GEb~.J . T .... biW. '161/C;!' 142$ . JJMFJ¡:i.!íI~~ÞM 62 13/29 12/16 I 4.51 1 1.0/5.0 195 12.5 9.7010.5 0.3/2.31 28,000 /~O 1 1 I Printed: 4/8/2004 3:42:16 PM · units NEXT BOP TEST: 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.08 1,859 (psi) @ 9.50 (ppg) 10,533 5,417 29.00 L-80 5,750 Printed: 4/8/2004 3:42:16 PM · WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratliff/Milton Castleman F!ELD NAME 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 409.0 14,595 AUTH MD 17,300 RIG PHONE MOC..a.¡: I'I~I WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS TlH 1,318'. OPERATION COMMENTS TIH to 14,186'. Directional drill f/14,186'-14,595'. motor. TIH to 1318'. 907-260-6935 COUNTY/OTHER 100.0000 Surveys not responding to sliding. POOH. Motor to MWD orientation turned 90 deg. Replace 06:00 07:00 1.00 14,186 14,186 AF DRLPR TRIP Con't wash and ream to btm f/13,800' - 14,186'. Seeing some areas where reaming required with 10-20k wt and 300 psi differential on motor. 07:00 14:30 7.50 14,186 14,595 AF DRLPR DRILL Directional drill 6" hole f/14,186' - 14, 595'. ART - 2.0 AST- 2.8. Surveys showing no progress dropping angle. No significan change in azimuth or angle while slide drilling. 14:30 16:00 1.50 14,595 14,595 TA DRLPR CIRC MTRD Circulate while evaluating survey indications. 16:00 02:00 10.00 14,595 14,595 TA DRLPR TRIP MTRD POOH. Hole in good condition. 35k overpull at Bifurcation Poin (CROTCH of FORMation Junction) slack off and rotated drill string 1-round. pull thru Bifurcation Point with 20k overpull. 02:00 04:00 2.00 14,595 14,595 TA DRLPR TRIP MTRD UD Stop sub, stabilizer, pony collar, and motor. Found that motor and MWD orientation had turned 90 deg. Visual inspection showed 2- connections below MWD tool had possibl tightened, resulting in the turn. 04:00 04:30 0.50 14,595 14,595 TA DRLPR TRIP MTRD Interrogate MWD. 04:30 05:00 0.50 14,595 14,595 TA DRLPR TRIP MTRD Replace Motor, stabilizer, pony collar, and stop sub. 05:00 06:00 1.00 14,595 14,595 TA DRLPR TRIP MTRD TIH to 1318'. Shallow test MWD. RR3/1 RR4 11 BIT I RUN 6RR3/13 Printed: 4/8/2004 3:42:18 PM - 3,000 301.40 301.40 301.40 45 45 1,250 1,300 units LAST BOP TEST: 11/21/2003 LAST CASING TEST: 11/13/2003 NEXT BOP TEST: 11/28/2003 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,0;9 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.08 1,859 (psi) @ 9.50 (ppg) 10,533 5,417 29.00 L-80 5,750 Printed: 4/8/2004 3:42:18 PM WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratliff/Milton Castleman FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Directional Drill 6" hole 14,915'. OPERATION COMMENTS TlH to 14,595'. Directional drill 6" hole f/14,595' - 14,915'. 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 320.0 14,915 AUTH MD 17 ,300 R!G PHONE MOC \.an NRI 907-260-6935 COUNTY/OTHER 100.0000 I CU~ ~~:L :~~~ . 16.08 06:00 06:30 0.50 14,959 14,595 TA DRLPR TRIP MTRD Shallow test MWD @ 1,318'. 06:30 07:00 0.50 14,595 14,595 TA DRLPR RIG MTRD Service Top Drive and Torque Tube, Adjust Bail Clamps and Brakes. 07:00 10:00 3.00 14,595 14,595 TA DRLPR TRIP MTRD TIH to 8,214'. 10:00 16:00 6.00 14,595 14,595 TA DRLPR TRIP MTRD Change to 5-1/2" handling tools. Con't TIH to 14,313'. Safety wash from 14.313'-14,595'. No drag thru Bifurcation Point (Crotch of FORMajunction). No fill on btm. 16:00 17:30 1.50 14,595 14,619 AF DRLPR DRILL Directional Drill f/14,595' - 14,619'. AST-0.6. 17:30 18:30 1.00 14,619 14,619 TA DRLPR RIG RGDT Troubleshoot lubrication pump on topdrive. 18:30 23:00 4.50 14,619 14,784 AF DRLPR DRILL Directional Drill f/14,619'-14,784'. Rotating 125 rpm wI 300 gpm. ART 1.8 AST-2.0. 23:00 00:00 1.00 14,784 14,784 TA DRLPR RIG RGDT Repair hydraulic leak on Top Drive 00:00 06:00 6.00 14,784 14,915 AF DRLPR DRILL Directional drill f/14,784'-14,915'. Sliding 30-40'/100'. Rotating 125 rpm wI 300 gpm ART-1.1 AST-2.8. 20,000 245,000 130,000 180,000 17,500/16,000 44.40 POlycrystalline Diamond Bit, Positive Displacement Motor, Non-Mag Integral Blade Stabilizer, Non-Mag Pony Collar, Non-Mag Crossover Sub, MWD Tool, Non-Mag Drill Collar (3), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), 4" ( 82 STDS) Drill Pipe (246), Cross Over Printed: 4/8/2004 3:42:21 PM e 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,831 (psi) @ 9.60 (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:21 PM e SUPERVISOR Rand Ratliff/Milton Castleman FIELD NAME 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 950.0 15,865 AUTH MD 17,300 RIG PHONE MOC \\'; NRI I CüM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Directional drill 6" hole 15865' OPERATION COMMENTS Directional drill 6" hole f/14,915' - 15,642'. 100.0000 16.08 06:00 22:30 16.50 14,915 15,642 AF DRLPR DRILL Directional Drill 6" hole from 14,915' - 15,642'. ART -4.2 AST-7.5. Rotary 125 RPM 300 GPM. Sliding 40-17' /100'. 22:30 23:00 0.50 15,642 15,642 AF DRLPR CIRC Circulate hole while recripicating 90'. 23:00 00:30 1.50 15,642 15,642 AF DRLPR TRIP POOH to 14,500', 10-15k drag over PU weight. 35k drag @ 15,315', Hole in good condition. 00:30 01:30 1.00 15,642 15,642 AF DRLPR TRIP TIH to 15,642'. Safety wash f/15,548-15,642'. no fill. Hole in good condition. 01:30 06:00 4.50 15,642 15,865 AF DRLPR DRILL Directional drill f/15,642'-15,865'. End of Drop - 15,647'. ART-2,O AST-.7 Rotary 125 RPM 300 GPM. 3,500 301 .40 301.40 40 30 1,375 1,150 Printed: 4/8/2004 3:42:26 PM · AVG. CONN: MAX. CONN: units 23 448 INCL 14,902.6 50.49 269.31 7,321.47 3,738.13 3,738.13 -11,258.3 2.40 15,380.4 38.37 267.22 7,662.15 3,718.56 3,718.56 -11,591.2 2.50 14,995.4 48.84 266.94 7,381.54 3,735.83 3,735.83 -11,329.0 2.64 15,476.1 36.21 268.94 7,738.28 3,716.60 3,716.60 -11,649.2 2.51 15,091.1 45.77 266.32 7,446.42 3,731.71 3,731.71 -11,399.2 3.24 15,572.2 34.27 268.35 7,816.77 3,715.30 3,715.30 -11,704.6 2.05 15,188.2 42.53 265.69 7,516.09 3,727.01 3,727.01 -11,466.6 3.37 15,668.0 31.87 266.70 7,897.04 3,713.06 3,713.06 -11,756.8 2.68 15,284.0 40.61 265.82 7,587.75 3,722.30 3,722.30 -11,530.0 2.01 15,762.8 30.84 265.89 7,978.00 3,709.88 3,709.88 -11,806.0 1.17 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,831 (psi) @ 9.60 (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:26 PM . . WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand RatlifflMilton Castleman 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 823.0 16,688 AUTH MD 17,300 FIELD ¡-iAME RIG PHONE NiûC Wi NRi DX0309030CAPDRL I GAiLY WELL COST I CUM WELL CU,," I WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Wi er tri 16,688'. OPERATION COMMENTS Directional drill f/15,865'-16,685'. Circulate hole clean. Wiper trip to 15,548'. 100.0000 16.08 Directional drill f/15,865'-15,993'. ART-1.5 gpm. 08:00 09:00 1.00 15,993 15,993 TA DRLPR DRILL MWD Restart MWD. (MWD had quit plusing) 09:00 17:30 8.50 15,993 16,307 AF DRLPR DRILL Directional drill f/15,993'-16,307. ART-5.1 AST 1.2 Slowed Rotary to 80 rpm @ 16,146' to reduce drop rate while rotating. 300 gpm. 17:30 18:00 0.50 16,307 16,307 AF DRLPR RIG Tighten service loops on Top Drive and service same. 18:00 02:00 8.00 16,307 16,688 AF DRLPR DRILL Directional drill f/16,307' - 16,685'. ART - 2.5 AST-1.2. 80 rpm and 300 gpm. 02:00 03:30 1.50 16,688 16,688 AF DRLPR CIRC Circulate hole clean while rotating @ 125 rpm and reciprocating drill pipe 90'. 03:30 04:30 1.00 16,688 16,688 AF DRLPR TRIP POOH to 15, 548'. 10-15k over PIU weight. Hole in good condition. 04:30 05:00 0.50 16,688 16,688 AF DRLPR RIG Service Top Drive. 05:00 06:00 1.00 16,688 16,688 AF DRLPR TRIP TIH 16.688'. Safety wash from 16,594' - 16,688'. No fill. Hole in good condition on TIH. 0,000 140,000 210,000 24,500/23,500 Polycrystalline Diamond Bit, Positive Displacement Motor, Non-Mag Integral Blade Stabilizer, Non-Mag Pony Collar, Non-Mag Crossover Sub, MWD Tool, Non-Mag Drill Collar (3), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), 4" ( 82 STDS) Drill Pipe (246), Cross Over Printed: 4/8/2004 3:42:28 PM · e 15,859.0 29.97 265.89 8,060.97 3,706.39 3,706.39 -11,854.6 0.90 16,330.1 25.34 265.28 8,479.35 3,690.40 3,690.40 -12,070.3 0.80 15,955.0 26.50 265.63 6,144.74 3,703.01 3,703.01 -11,901.4 1.53 16,424.7 25.43 264.45 8,564.61 3,686.76 3,666.76 -12,110.7 0.39 16,046.5 27.75 266.29 8,227.20 3,699.96 3,699.98 -11,945.3 0.63 16,522.1 25.10 263.21 6,652.90 3,682.30 3,682.30 -12,152.0 0.64 16,140.4 26.67 265.66 6,308.92 3,697.04 3,697.04 -11,967.2 1.21 16,617.2 23.30 264.35 8,739.64 3,678.06 3,678.06 -12,190.8 1.96 16,239.2 26.07 265.36 8,397.44 3,693.61 3,693.61 -12,031.0 0.62 Nabors Alaska Drilling 23 340.00 R&K Industrial 2 12.00 Marathon 2 48.00 Lynden Transport 2 6.00 Epoch Well Services 4 48.00 S&R Enterprises 1 3.00 M-I Drilling Fluids 2 24.00 Sperry Sun 3 36.00 Baker Hughes Inteq 7 68.00 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,831 (psi) @ 9.60 (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:28 PM e SUPERVISOR Rand Ratliff/Milton Castleman 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 930.0 17,618 AUTH MD 17,300 MOC WI NRI 100.0000 ....PIWBS COST FIELD NAME RIG PHONE DX0309030CAPDRL I CAlLY WELL COST I CüM WEll COS"r WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Service To Drive 16,211'. OPERATION COMMENTS Directional Drill to TD @ 17,618' MD, 9,700' TVD, 12,975' VS. Circulate. 16.08 PIU MWD 10 in tools. TIH 01 :00 03:00 2.00 17,618 17,618 AF DRLPR CIRC Directional drill f/16,688'-17,618'. ART-12.9 AST-O. Rotary 10 rpm 300 gpm. TO of 6" hole @ 17,618' MD, 9700 TVD, 12,957' VS. Circulate btms up for samples. Rotating @ 100 rpm 300 gpm and reciprocating 75'. POOH to 16,211'. At 17,060' drag increase to 40k over. Backream coal section f/17,070-17,030'. Con't POOH to 16,211'. Drag 10-20k over normal PIU weight. Hole in good condition. Service Top Drive. Change dies in gripper. 03:00 05:00 2.00 17,618 17,618 AF DRLPR TRIP 05:00 06:00 1.00 17,618 17,618 AF DRLPR RIG 19 BHA DESCRIPTION 340,000 145,000 24,500/22,000 POlycrystalline Diamond Bit, Positive Displacement Motor, Non-Mag Integral Blade Stabilizer, Non-Mag Pony Collar, Non-Mag Crossover Sub, MWD Tool, Non-Mag Drill Collar (3), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), 4" ( 82 STDS) Drill Pipe (246), Cross Over Printed: 4/8/2004 3:42:30 PM · 16,713.0 21.20 263.51 8,828.30 3,674.24 3,674.24 -12,226.8 2.22 17,182.6 14.75 262.03 9,275.70 3,658.28 3,658.28 -12,367.7 0.75 16,805.6 19.47 264.41 8,915.12 3,670.84 3,670.84 -12,258.8 1.90 17,277.0 13.10 258.62 9,367.32 3,654.51 3,654.51 -12,390.1 1.95 16,898.8 18.38 264.58 9,003.29 3,667.94 3,667.94 -12,288.9 1.17 17,373.4 12.76 260.96 9,461.28 3,650.68 3,650.68 -12,411.3 0.65 16,994.1 16.72 263.74 9,094.15 3,665.03 3,665.03 -12,317.5 1.76 17,468.1 12.21 260.23 9,553.74 3,647.34 3,647.34 -12,431.5 0.60 17,088.8 15.45 261.75 9,185.14 3,661.73 3,661.73 -12,343.5 1.46 Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Hughes Inteq 23 340.00 R&K Industrial 2 48.00 Lynden Transport 4 48.00 S&R Enterprises 2 24.00 Sperry Sun 7 68.00 2 2 1 3 12.00 6.00 3.00 36.00 LAST BOP TEST: 11/21/2003 LAST CASING TEST: 11/13/2003 NEXT BOP TEST: 11/28/2003 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,774 (psi) @ 9.80 (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:30 PM WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratliff/Milton Castleman 30.6 RIG NAME & NO. Nabors 273E FIELD NAME RIG PHONE 907-260-6935 COUNTY/OTHER 06:00 07:00 1.00 17,618 17,618 AF DRLPR TRIP 07:00 17:00 10.00 17,618 17,618 AF DRLPR CIRC 17:00 19:00 2.00 17,618 17,618 AF DRLPR TRIP 19:00 19:30 0.50 17,618 17,618 AF DRLPR RIG 19:30 20:00 0.50 17,618 17,618 AF DRLPR TRIP 20:00 22:30 2.50 17,618 17,618 AF DRLPR CIRC 22:30 06:00 7.50 17,618 17,618 AF DRLPR TRIP . 24 HR PROG TMD 17,618 AUTH MD 17,300 MOC v., NRI I CUM W~LL ::>:~n 100.0000 16.08 in tools. TIH. TIH f/16,211'-17,618'. 20-30k drag @ 17,060'. Rest of hole in good condition. Circulate well. At btms up had 948 units gas with mud cut from 9.8-8.8 ppg. Raise mud weight to 10. 3 ppg. Background gas dropped to 20 units. POOH from 17,618' -16,210'. 20-30k drag @ 17,060'. Rest of hole in good condition. Service Top Drive, Blocks, and Crown. TIH from 16,210' - 17,618', Safety wash f/17,550'-17,618'. 10k drag @ 17,060'. Rest of hole in good condition. Circulate btms up. Max gas 227 units. Mud cut from 10.3-10.2 ppg. Background gas dropped to 18 units. Pump slug. POOH to 9000'. 10k drag @ 17,060'. 10-30k drag through coal in angle drop section of hole @ 15,250' and 14,545'. Rest of hole in good condition. Pulled 25k over 3-times @ Bifurcation Point (Crotch of FORMation Junction). R01ated drill string 1-1/2 turns. Pulled through Bifurcation point w/10k drag, 'Note: Received extension from Winton Hebert- AOGCC to delay BOP testing until we are ready to drill out the second leg of well. No BOP testing required while logging, running the liner or during the completion and well test phase. Printed: 4/8/2004 3:42:33 PM . . WELL NAME BIT I RUN 6RR4! 14 365,000 215,000 26,000 I Polycrystalline Diamond Bit, Positive Displacement Motor, Non-Mag Integral Blade Stabilizer, Non-Mag Pony Collar, Non-Mag Crossover Sub, MWD Tool, Non-Mag Drill Collar (3), Cross Over, Heavy Weight Drill Pipe (3), Cross Over, Drilling Jar, Cross Over, Heavy Weight Drill Pipe (2), 4" ( 82 STDS) Drill Pipe (246), Cross Over 30 1,500 units 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,633 (psi) @ 10.30 (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:33 PM · FIEL.D NAME RIG PHONE 24 HR PROG TMD 17,618 AUTH MD 17,300 MOC WI NRi 100.0000 DX0309030CAPDRL I DAiLY WELL COST I CUM WELL COSl - --.. -^-JP"-71'\ WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratliff/Milton Castleman 30.6 RIG NAME & NO. Nabors 273E WILDCAT-FOR UNNAMED FIELD 907-260-6935 COUNTY/OTHER 16.08 in tools. 06:00 06:30 0.50 17,618 17,618 AF DRLPR TRIP Con't POOH to 8215'. 06:30 13:00 6.50 17,618 17,618 AF DRLPR TRIP Change over to 4" handling tools. Con't POOH to BHA. SLM-2.47' long. No correction. 13:00 15:00 2.00 17,618 17,618 AF DRLPR TRIP UD directional drilling BHA . 15:00 16:00 1.00 17,618 17,618 AF EVALPR CLEAN Clear and clean rig floor prepare to PIU BHA #20. "Note while out of hole, functioned BOP equipment and tested gas and H2S alarms. 16:00 20:00 4.00 17,618 17,618 AF EVALPR MwdLwd PIU Halliburton Sperry Sun LWD I MWD logging assembly. Distance from bit to: ERW 12.99' DGR 20.05' DM 31.88' SLD 47.36' CTN 56.78' BAT 74.65' 20:00 21:00 1.00 17,618 17,618 AF EVALPR MwdLwd Shallow test tools. Load source in tool string. 21:00 22:00 1.00 17,618 17,618 AF EVALPR TRIP TIH to 1720'. 22:00 01:00 3.00 17,618 17,618 TA EVALPR RIG RGDT Repair gripper on Top Drive- Troubleshoot electrical control. Found blown fuse in PLC controller. Replace fuse. 01:00 01:30 0.50 17,618 17,618 AF EVALPR MwdLwd Calibrate block height for Halliburton Sperry Sun depth tracking system. 01:30 04:00 2.50 17,618 17,618 AF EVALPR TRIP Con't TIH to 7846'. Filling 4" DP every 30 stands. 04:00 06:00 2.00 17,618 17,618 AF EVALPR TRIP Change over to 5-1/2" handling tools. Con't TIH to 10,700'. No drag at Bifurcation Point (Crotch of FORMation Junction). Printed: 4/8/2004 3:42:34 PM 7,846.14 0 I Polycrystalline Diamond Bit, Bit Sub, GR I Res MWD , DM MWD , ASLD I CTN MWD , Sonic MWD , TM MWD . Drilling Jar, Cross Over, Heavy Weight Drill Pipe (5), 4" Drill Pipe (237), Cross Over units Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Directional Drillingl MWD Sand Truck Long Haul Trucking MWD I LWD Logging LAST CASING TEST: 11/1312003 NEXT BOP TEST: 11/28/2003 20.000 13.375 7.000 18.730 12.415 6.184 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,633 (psi) @ 10.30 (ppg) Printed: 4/8/2004 3:42:34 PM WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratliff/Milton Castleman 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,618 AUTH MD 17,300 MOC .ÿ¡ NRI WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATBPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Lo in fluvial sand formations. OPERATION COMMENTS Con't TIH to 17,618'. Perform open hole 100.0000 I CU~ ~:~L ~~! '._ . FIELD NAME RIG PHONE ------ 16.08 06:00 10:30 4.50 17,618 17,618 AF EVALPR TRIP Con't TIH f/10,700' - 17,618'. Safety wash f/17,456'-17,618'. No fill. Hole in good condition. 10:30 12:00 1.50 17,618 17,618 AF EVALPR CIRC Circulate btms up. Max gas 470 units. Mud cut from 10.3 - 9.5 ppg. 12:00 14:00 2.00 17,618 17,618 AF EV ALPR LOG Perform open hole logging of fluvial sands in the Tyonek formation with MWD I LWD f/17,618' -17,446'. 14:00 16:00 2.00 17,618 17,618 TA EV ALPR RIG RGDT Repair electrical short in Top Drive service loop. 16:00 06:00 14.00 17,618 17,618 AF EV ALPR LOG Con't open hole logging wI MWD I LWD f/17,446' - 15,960'. 1 NATIONAL 1,325 2 NATIONAL 1,350 units AVG. CONN: 16 MAX. CONN: 23 Printed: 4/8/2004 3:42:38 PM ùOMÞANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,633 (psi) @ 10.30 (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:36 PM · 907-260-6935 COUNTY/OTHER 24 HR PROG TMD 17,618 AUTH MD 17 ,300 MOC WI NRI 100.0000 I CUM WELL COS , WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratlíff/Milton Castleman FIELD NÃME 30.6 RIG NAME & NO. Nabors 273E RiG PHONE 16.08 06:00 01:00 19.00 17,618 17,618 AF EV ALPR LOG Con't open hole logging wI MWD I LWD fl 15,960' - 14,070'. Hole attempting to pack off in coal sections @ 15,429', 14,780-14,771', and 14,070'. Gas from packoffs 300-175 units above background. A large amount of small coal cuttings at btms up. 01:00 02:00 1.00 17,618 17,618 TA EVALPR TRIP DNHS Hole packed off while logging at 14,070'. Could rotate and mov pipe between tool joints, but could not circulate. Could not lowe in hole without rotating. Rotate in hole to 14,415'. Could see tool jts dragging on 8' section of hole. 02:00 04:00 2.00 17,618 17,618 TA EVALPR CIRC DNHS Circulate hole clean rotating @ 125 rpm 300 gpm. Reciprocating drill pipe 93'. Saw medium amount of fine cuttings at btms up. 04:00 04:30 0.50 17,618 17,618 TA EVALPR TRIP DNHS Ream open hole f/14,415' -14,070'. 04:30 06:00 1.50 17,618 17,618 AF EV ALPR LOG Open hole logging f/14,070' - 13,941'. BHA DESCRIPTION Printed: 4/8/2004 3:42:37 PM · 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,633 (psi) @ 10.30 (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:37 PM · WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Rand Ratliff/Milton Castleman FIELD NAME 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,618 AUTH MD 17,300 907-260-6935 COUNTY/OTHER 100.0000 ·1 CU~ WELL COST , RIG PHONE MOC wï HR. 16.08 in tools at 11,240'. 06:00 22:00 16.00 22:00 22:30 0.50 17,618 17,618 17,618 AF 17,618 TA EV ALPR LOG EVALPR CIRC Log open hole wI MWD I LWD f/13,941'-12,131', DNHS Hole packed off @ 12,131'. Ream stand down. Pump pressure retumed to normal. 28 units gas at btms up. Con't to log open hole f/12,131'-11,240'. Open hole attemped to pack off at 11,835'. Prevented by slacking off and working one stand. 22:30 06:00 7.50 17,618 17,618 AF EV ALPR LOG Nabors Alaska Drilling Marathon Epoch Well Services Drilling Contractor Drilling Supervision Mud Logging 23 340.00 M-I Drilling Fluids 2 48.00 R&K Industrial 2 24.00 Sperry Sun Mud Engineering Vacuum Truck MWD I LWD Logging 2 2 3 24.00 24.00 24.00 Printed: 4/812004 3:42:41 PM LAST BOP TEST: 11/21/2003 NEXT 8ÛP TEST: 12/21/2003 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.08 1,633 (psi) @ 10.30 (ppg) 10,533 5,417 29.00 L-80 5,750 Printed: 4/8/2004 3:42:41 PM RiG FHONE 24 HR PROG TMD 17,618 AUTH MD 17,300 MOC WI NRI I CUM WELL COST 30.6 RIG NAME & NO. Nabors 273E WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS End of Ori inal Drillin Phase - 2300 hrs 12/2/03 OPERATION COMMENTS Finish log open hole with LWD 11,240' - 10,533. POOH down load and lay down LWD BHA. 907-260-6935 COUNTY/OTHER 100.0000 16.08 06:00 12:30 6.50 17,618 17,618 AF EV ALPR LOG 12:30 13:30 1.00 17,618 17,618 AF EVALPR CIRC 13:30 15:00 1.50 17,618 17,618 AF EVALPR TRIP 15:00 19:00 4.00 17,618 17,618 AF EVALPR TRIP 19:00 23:00 4.00 17,618 17,618 AF EVALPR TRIP Log open hole with MWD/LWD from 11,240' to 10,533'. Ciculate bottoms up, mix and pump slug. POOH to 7,848'. Change over to 4" handling tools. POOH to Sperry Sun MWD/LWD BHA. Download LWD tools and lay down same. End of drilling phase, begin completion phase. Note: 12/17/2003 o 220 125 130 I Polycrystalline Diamond Bit, Bit Sub, GR I Res MWD , DM MWD ,ASLD I CTN MWD , Sonic MWD , TM MWD , Drilling Jar, Cross Over, Heavy Weight Drill Pipe (5), 4" Drill Pipe (237), Cross Over 20 BHA DESCRIPTION AVG. CONN: MAX. CONN: units 10 10 Printed: 4/8/2004 3:42:45 PM . . WELL NAME KASILOF SOUTH 1 PB1 COMPANY Nabors Alaska Drilling Marathon Epoch Well Services SERV!èE Drilling Contractor Drilling Supervision Mud Logging LAST BOP TEST: 11/21/2003 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.08 LAST CASING TEST: 11/13/2003 NEXT BOP TEST: 12/21/2003 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,633 (psi) @ 10.30 (ppg) 130 2,860 10,533 130 2,368 5,417 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:45 PM . . de /2 - ~S-~ Kasilof South 1 PB 1 Rig Completion (Reports 49B - 63A) . . MARATHON OIL C Daily Completion Report Exploitation - Gas WELL NAME KB 24 HR PROG TMD 17,618 AUTH MD TVD 9,700 WBS RPT# DATE 49B 03-Dec-2003 !::J!.P/W"''' COST 30.6 RIG NAME & NO. Nabors 273E ......,............... RIG PHONE WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS I MTS TIH OPERATION COMMENTS PU bit and slick BHA, TIH to condition hole to run liner. 16.08 MANHRS WORKED 149.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Removing sources from LWD SAFETY SUMMARY LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? 12/2/2003 11121/2003 N LAST RIG INSPECTION 11/21/2003 Nabors Alaska Drilling Marathon Epoch Well Services Printed: 4129/2004 4:04:19 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 PB1 KB 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,618 AUTH MD RPT# DATE 60 04-Dec-2003 SAPIWBS COST TVD 9,700 WBS 907 -260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS RIU 3-1/2" Casin Tools OPERATION COMMENTS Finish TIH, circulate and condition hole to run liner. ~IIM ""'L' Cu~, [_. n_ _ _ _ LEAKOFF 16.08 RIG PHONE MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 694.00 None 12/3/2003 ACCIDENT DESCRIPTION: 12:30 14:30 2.00 17,618 17,618 AF 14:30 18:00 3.50 17,618 17,618 AF 18:00 23:00 5.00 17,618 17,618 AF 23:00 03:00 4.00 17,618 17,618 AF 03:00 04:00 1.00 17,618 17,618 AF 04:00 BHA NO. 21 BHA DESCRIPTION MOC WI NRI 100.0000 REGULATORY INSP? N LAST RIG INSPECTION 11/21/2003 SHST Continue TIH with slick BHA to condition hole for liner. CDT: Work on wiring on top drive Continue trip in hole to 17,075'. Hole tight at 15,649' -15,660', 15,740',16,217', and 16,941'. Wash and rotate through tight spots. 20-50k WOB and high torq 15-28k ft-Ibs. Hole attempting to packoff while reaming. Work thru tight spots and backream as needed. Wash and ream 17,075' - 17,618' - no problems. Circulate and condition hole for two bottoms up. Maximum trip gas 385 units, dropped out quickly. Max gas cut mud was from 10.3 ppg to 9.8 ppg. POOH to 7,900'. Open hole in good condition, maximum overpull10-20 K over expected drag. Finish POOH with 4" DP. PU cement head and install on top of single of 5 1/2" DP. Lay on catwalk. RU pick up machine and rig floor to run 3 1/2" liner. S5 HR5 Printed: 4/29/2004 4:04:20 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas AVG. CONN: MAX. CONN: DATE 04-Dec-2003 WELL NAME KASILOF SOUTH 1 PB1 NO. MAKE OF PUMP 1 NATIONAL KILL SPM J PRESSURE MUD GAS AVG. TRIP: MAX. TRIP: 385 AVG. BKGRD: MAX. DRL: COMPANY Nabors Alaska Drilling Drilling Contractor Marathon Epoch Well Services M-I Drilling Fluids Halliburton Sperry Sun Halliburton Testing R&K Industrial Alaska Petroleum Contra Berms for test equipment PERSONNEL NO. HOURS 23 340.00 BJ Services 2 48.00 Weatherford 2 48.00 Weaver Brothers (WBI) 2 24.00 Lynden Transport 3 18.00 Wildflowers and Resin 4 48.00 Rain For Rent 1 4.00 Airport Rentals 5 42.00 5 5 1 1 3 2 7 1 2 2.00 2.00 8.00 4.00 2.00 4.00 Printed: 4/29/2004 4:04:20 PM WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Gerard Roger/Russ Trubv FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS RIH with 3 1/2" liner. OPERATION COMMENTS Rig up and run 7,240' of 3 1/2" liner. RIH wI liner on 5 1/2" DP. SAFETY st..JMMAR:Y MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST 1 LAST STOP CARD AUDIT 712.00 None 12/3/2003 111121/2003 1 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Picking up and handling liner hanger. ~y TO SUB ~ 17,618 AF CSGPRC EQUIP Finish rigging up to run 31/2" liner. 17,618 AF CSGPRC CSG Run 7,240' of 31/2",9.2 ppf, L-60. Hyd 563 casing. 17,618 AF CSGPRC EQUIP RD lay down machine, change bails and elevators. 17,618 AF CSGPRC CIRC Circulate liner volume at 52 spm, 1100 psi. 17,618 AF CSGPRC CSG PSJM, Pick up liner hanger from catwalk and make up in string. 17,618 AF CSGPRC CSG Change elevators and handling tools to 4", run 6 stands of 4" DI from derrick. Change elevators and handling tools to 5 1/2", run in hole with 3 1/2" liner on 5-1/2" DP. Fill pipe every 10 stands. At 11,500' anI below, pipe exhibiting symptoms of differential sticking while pipe is static. IECDI IMU~~ ,,,,,,,1 ~ FC/T.SOL OIW % Pf/Mf 1 CIICa LIIYIC I ¡:~ I 6RPM 1.0/10.0 5/95 /10.0 9.5010.5 0.4/2.51 25,000/40 1 1 I 1~;DD"'~;;"1 1 FROM TO HRS 06:00 07:00 1.00 07:00 19:00 12.00 19:00 20:30 1.50 20:30 21 :00 0.50 21 :00 22:30 1.50 22:30 23:00 0.50 23:00 06:00 7.00 DENSITY(ppg) FV PVIYP 65 18/30 . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas IGL 30.6 I 74.00 RIG NAME & NO. Nabors 273E .. TVD I DFS ¡DOL I RPT # DATE 9,700 I 51 51 I 51 05-Dec-2003 WBS SAPIWBS COST KB 24 HR PROG TMD 17,618 AUTH MD DX0309030CAPCMP01 MOC W! NR! I DAILY WF! I rn"T l:M WELL COST 907-260-6935 100.0000 I. _ COUNTY/OTHER LAST CASING I NEXT CASING ILEAl\.un 7.000 (in) @ 10,533 (ft) I 3.500 (in) @ 17,618 (ft) 16.08 24 HR FORECAST Run and cement 3 1/2" liner. RIG PHONE I REGULATORY INSP? 1 LAST RIG INSPECTION IN 111/21/2003 FROM 17,618 17,618 17,618 17,618 17,618 17,618 17,618 CSGPRC CSG 17,618 AF 10.50 GELS 12/16 I PP I WLlHTHP I 4.8/ I NO. I .,~,,- ~. ~.... 3 I NATIONAL -- I I<'III"'DM ~ 79.541 AVG. CONN: MAX. CONN: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M- Drilling Fluids Halliburton Sperry Sun Halliburton MUD GAS I UNITS I I AVG. TRIP: MAX. TRIP: 385 AVG. BKGRD: MAX. DRL: 5 5 SERViCE Drilling Contractor ~EL DATA NO. ~ COMPANY 23 340.00 R&K Industrial 2 48.00 Alaska Petroleum Contra 2 48.00 BJ Services 2 24.00 Weatherford 3 18.00 Baker Oil Tools 4 48.00 Veco Alaska Crane and Backhoe SERVICE NO. 1 3 1 4 3 5 ~ 4.00 20.00 2.00 48.00 72.00 40.00 Berms for test equipment Testing Printed: 4/29/2004 4:04:21 PM ·' . MARATHON OIL ANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 PB1 DATE 05-Dec-2003 Printed: 4/29/2004 4:04:21 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Gerard Ro erlRuss Trub FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS POOH with liner seWn tool. OPERATION COMMENTS TIH with 3 1/2" liner to 17618, unable to set hanger hydrauliclly, set liner on bottom and release with left hand rotation. Mix and pump 1500 sx cement. Displace with rig pump, cement to surface. Sting out of liner and displace cement from casing. POOH. KB 30.6 RIG NAME & NO. Nabors 273E RIG PHONE 907 -260-6935 COUNTY/OTHER 24 HR PROG TMD RPT# DATE 52 06-Dec-2003 SAPIWBS COST TVD 9,700 WBS 17,618 AUTH MD MOCWI 100.0000 NR! L WELL COST LEAKOFF 16.08 LAST SAFETY MTG 12/3/2003 SAFETY SUMMARY BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? 11/21/2003 N LAST RIG INSPECTION 11/21/2003 MANHRS WORKED ACCIDENT TYPE 790.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pressure testing lines and cementing operations. 11 :00 11 :30 0.50 17,618 17,618 AF 11 :30 14:00 2.50 17,618 17,618 AF 14:00 15:30 1.50 17,618 17,618 AF 15:30 20:00 4.50 17,618 17,618 AF 20:00 23:00 3.00 17,618 17,618 AF TIH with 3 1/2" liner filling pipe every 5 stds. Wash thru tight spots at 16,868' and 17,167' PU-280K, SO-120K. 22 SPM at 900 psi. Tag at 17,190', rotate through tight spot with 8 rpm and 12,000 ft-Ibs torque. Wash down last 5 stds down to 17,600' with no problem. At 17,600', PU - 285K, SO-125K, 16,500 ft-Ibs at 15 rpm. PU and make cement head in string. Break circulation and wash to bottom at 17,618'. Circulating with 20 spm and 900 psi. PU string to set liner shoe at 17,603'. Drop 0.75" setting ball (seats in the landing collar) and circulate down at 33 spm and 1800 psi. Pressure up and attempt to set hanger. Hanger should set at 1600 psi. Pressure up to 3800 psi in 100 psi increments while working pipe and attempting to set hanger with shoe 15' off bottom without success. Able to tag bottom wI liner and move it back up hole. Shear out ball seat in LC with 3800 psi. Set line on bottom and attempt release from same - with 3 rounds of left hand torque and working pipe, no success. Put in 4 more rounds of left hand torque and work down. Released from hanger, PU WT- 230K. Set back down with 1 OK on liner and circulate and condition hol with 80 spm and 1500 psi . PJSM. Verified 10-15k weight down on liner. Test lines to 4,000 psi. BJ Pump 37 bbl MCS-4 spacer weighted to 11.3 ppg. Mix and pump 1500 sx Class G + 2% KCI + 22% LW-6 + 5% MPA-1 + 0.9% BA-10 + 0.5% SMS + 0.6% CD-32 + 0.45% R-3 + 1 ghs FP6L mixed to 12.7 ppg, 478 bbl. Dropped DP wiper dart, displace with 10 bbl water from BJ, 65 bbl 2 ppb FloVis Mud, and 207 bbl of mud for a total displacement of 282 bbl. Printed: 4/29/2004 4:04:23 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 PB1 DATE 06-Dec-2003 FROM TO HRS 20:00 23:00 3.00 TO SUB 17,618 AF OPERATIONS SUMMARY PHASE OP TRBL CSGPR CEMT FROM 17,618 23:00 05:00 6.00 17,618 17,618 TA CSGPR CIRC CMTP 05:00 06:00 1.00 NO. 1 NATIONAL AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: DESCRIPTION Calculated displacement was 278 bbl. After first 109 bbl of displacement started seeing signs of cement in returns. After 197 bbls displace returns weighed 11.2 ppg. After 235 bbls returns weighed 12.0 ppg. After 270 bbls displacement returns weighed 12.6 ppg. Calculated displacement to shear dart was 205 bbls, dart sheared at 208 bbls. Volume of liner was 62 bbl. Pumped a total of 66 bbls after shearing dart without bumping plug. Still getting 12.7 ppg cement returns. Stand back cement head with heavy u-tubing from drill pipe. Screw in top drive and circulate out cement the long way. Attempt to slowly recipricate pipe while circulating out cement, could move up but not down. Slowly pull uphole while circulating out cement. Stand back two stands in derrick, while pulling each stand attempt to go down without success. Pumped 335 bbls before returns dropped from 12.7 ppg to 10.8 ppg. Start taking returns back to active system. Pull three more stands to postion end of cement stinger across from junction and circulate at 195 spm, 2500 psi to flush bifurcation point and junction diverter. Pull out of hole with stinger above junction and circulate bottoms up at - 800 gpm and 2400 psi. Once running tool I stinger assembly was above junction (in 9-5/8" casing) able to move pipe down without weight set down. Continue circulating at 800 gpm, 2400 psi while treating cement contaiminated mud system. Pump slug and POOH. 385 AVG. BKGRD: MAX. DRL: 5 5 COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Halliburton R&K Industrial PERSONNELDATA NO. HOURS COMPANY 23 340.00 Alaska Petroleum Contra 2 48.00 BJ Services 2 48.00 Baker Oil Tools 2 24.00 Weaver Brothers (WBI) 4 48.00 Oilfield Hot Shot Service 6 72.00 SERVICE Drilling Contractor Testing, RID CASING>SUMMARY LAST CASING TEST: MAX SICP MD ft SERVICE Berms for test equipment 5 5 3 2 1 40.00 90.00 72.00 4.00 4.00 Printed: 4/29/2004 4:04:23 PM . WELL NAME KASILOF SOUTH 1 PB1 . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas DATE 06-Dec-2003 CASIN SUMMARY LAST CASING TEST: MAXSICP MD ft 4,525 (psi) @ (ppg) 10,533 Printed: 4/29/2004 4:04:23 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas KB 30.6 RIG NAME & NO. Nabors 273E RIG PHONE 907-260-6935 COUNTY/OTHER 24 HR PROG TMD 17,618 AUTH MD TVD 9,700 WBS RPT# DATE 53 07-Dec-2003 SAPIWBS COST ',0 MOC WI NRI 100.0000 CUM VV1::.Li.. ""'V~I 16.08 Test BOP's. PU and TIH with spear and fishing jars. SAFETYSUMM;l,\RY LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP7 12/7/2003 12/6/2003 N SAFETY MTG TOPICS: Picking up and laying down BHA. LAST RIG INSPECTION 11/21/2003 Finish trip out of hole with liner running tool. Lay down liner hanger running tool. No indication of damage to tool. 13:00 14:00 1.00 17,618 17,618 TA HGRD Break and laydown cement head. 14:00 16:30 2.50 17,618 17,618 TA HGRD Service and change oil in top drive. Adjust torque tube and change gripper dies. 16:30 22:30 6.00 17,618 17,618 AF Test Hydril, upper and lower top drive valves, choke manifold, 5-1/2" pipe rams, blind rams, 5-1/2" TIW and IBOP, 4" TIW and IBOP to 250 psi low and 3500 psi high for five minutes. Test VBR with both 5-1/2" and 4" drill pipe to 250 low and 3500 high for five minutes. Run accumulator test. Test gas and H2S alarms. Jeff Jones with AOGCC waived BOP test witness, 12/6/03 22:30 00:00 1.50 17,618 17,618 TA HGRD Pick up spear with 4.010" grapple and 9' extension, bumber sub oil jars, and accelarator jars. 00:00 06:00 6.00 TIH with spear assembly. Spear 4.010" grapple, Extension sub, Stop Ring, Cross Over, Bumper Sub, Oil Jar, Drill Collar (6), Accelerator, Cross Over, 4" Drill Pipe (18), Cross Over AVG. CONN: MAX. CONN: MUDG;l,\S AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: 3 3 Printed: 4/29/2004 4:04:24 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas COMPANY SERVICE Nabors Alaska Drilling Drilling Contractor Marathon Epoch Well Services M-I Drilling Fluids Halliburton Testing, RID PERSONNEL DATA NO. HOURS COMPANY 23 340.00 R&K Industrial 2 48.00 BJ Services 2 48.00 Baker Oil Tools 2 24.00 Oilfield Hot Shot Service 4 12.00 SERVICE WELL NAME KASILOF SOUTH 1 PB1 3 3 3 1 30.00 9.00 72.00 4.00 LAST BOP TEST: 12/6/2003 SIZE ill 7.000 CASIN S MMARY LAST CASING TEST: NEXT BOP TEST: 12/13/2003 Printed: 4/29/2004 4:04:24 PM M:t\R:t\ffimøNø'1 [G!Ø'MPÄNY [)á.il·YiÇºrijpIØtIØh}R~pørt E){plpi~~tiPh..Gá$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL !RPT# I~ATE KASILOF SOUTH 1 PB1 30.6 74.00 17,618 9,700 54 54 54 08-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Gerard Rooer/Russ Trubv Nabors 273E DX0309030CAPCMP01 L FIELD NAME RIG PHONE MOCWI NRI IDAILYWO::" ",,...roo... ¡rlIMwCII r.OSI WILDCAT·FOR UNNAMED FIELD 907-260-6935 100.0000 [-... - ~ STATEJPROV COUNTY/OTHER I LAST CASING I NEXT CASING : Alaska 7.000 (in) cæ 10,533 (ft) 3.500 (in) @ 17,618 (ft) 1- 16.08 CURRENT STATUS / MTS 24 HR FORECAST TIH with overshot. TIH, enqaqe 3-1/2" liner and POOH. OPERATION COMMENTS Engage fish and POOH. Recovered liner hanger assembly and 13 joints of 3-1/2" liner. PU and TIHwith overshot. SAFEl7YSLlMMARY ... MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG BOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 571.00 None 12/7/2003 12/6/2003 12/3/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Well control and tripping wet pipe. FROM 1q Hf{§ FRqM .TO is.lJ~_~ ~ 06:00 07:00 1.00 17,618 17,618 TA CSGPRC CIRC HGRD Circulate bottoms up at 9751'. 07:00 09:30 2.50 17,618 17,618 TA CSGPRC FISH HGRD TIH looking for top of liner hanger. Engage fish with spear, top 0 liner hanger at 10,354'. PU prior to engaging fish - 230K, PU after engaging fish-260K. Pump rate before latching 50 spm @ 900 psi and after latching was 50 spm, 1300 psi. 09:30 10:30 1.00 17,618 17,618 TA CSGPRC TRIP HGRD POOH to 9841'. Saw 10k additional drag coming through junction. 10:30 12:00 1.50 17,618 17,618 TA CSGPRC CIRC HGRD Circulate bottoms up. at 80 spm, 1800 psi. 12:00 18:00 6.00 17,618 17,618 TA CSGPRC TRIP HGRD POOH to top of fish. 18:00 19:30 1.50 17,618 17,618 TA CSGPRC TRIP HGRD Lay down fish. Recovered ZXP packer, liner hanger assembly RIU Weatherford tubing tongs and UD 13 joints of 3-1/2" casing (pin down, thus a box looking up). All slip segments were missing from hanger body. Total recovery of 462.36'. TOF- 10,816'. 19:30 22:30 3.00 17,618 17,618 TA CSGPRC TRIP HGRD RD tubing tongs, Attempt to shuck spear, bumper sub, and oil jars from fish without success. LD fish wI fishing tools attached. 22:30 01:30 3.00 17,618 TA CSGPRC TRIP HGRD Pick up 5 3/4" overshot with 4 1/4" grapple, bumber sub, oil jars, accelerator jars and pump out sub. 01 :30 06:00 4.50 17,618 17,618 TA CSGPRC TRIP HGRD TIHwih overshot assembly. 10.30 1 ¡:\Þ I I r:qî? I IMÛD[)Â[ÂI.~.t(')§tl ~ - DENSITY(PÞ9) FV PVIYP GELS IW4IHTHpIFcrr.~òL di!l ·~k~~6d(M~-¡;lp ·1·f>f/l'I1fl¢1/9¡¡il-l~S ·.ìt¡~ßI· ·.r:sI6RP~ 82 22/34 16/22 I 7.61 I 1.0/10.0 5/95 /12.0 110.3010.810.4/2.2124,500/2201 I 1 I BRA SHANO. ItENqTH .1.EFFWf. .¡SLA¢KÒF~R()"fWt· I",,,,,,,, J$FiAHRsl.)ARI-IRp ..i:è"'''' . ...",,vpl<l"m"IKK'HV-' I' I' 23 I 1 ,278.80 I I I I I I I I I I BHA DESCRIPTION Overshot , Extension sub Top sub , Bumper Sub , Oil Jar, Drill Collar (6), Accelerator, Pumpout sub , Cross Over, 4" Drill Pipe (33), Cross Over PUMPIH¥DRAULICDATA NO. 1 MAKE OF PUMP I STROKE (ii))1 LlNER(in)I SPM Q (gpl11). '¡PREpS. (psi) I TorAuqJ KILLSPM r PRESSURE 1 I NATIONAL 1 12.000 1 6.0001 108 452.10 I 2,590 I 452.10 I . . Printed: 4/29/2004 4:04:25 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas AVG. CONN: MAX. CONN: DATE 08-Dec-2003 WELL NAME KASILOF SOUTH 1 PB1 MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: 5 5 COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids SERVICE Drilling Contractor PERSONNEL..DATA NO. HOURS COMPANY 23 340.00 Baker Oil Tools 2 48.00 Oilfield Hot Shot Service 2 48.00 BJ Services 2 24.00 Weatherford SERVICE 4 1 1 2 96.00 2.00 1.00 12.00 LAST BOP TEST: 12/6/2003 SIZE ih 7.000 16.08 CASING RY LAST CASING TEST: NEXT BOP TEST: 12/13/2003 4,525 (psi) @ (ppg) 5,740 Printed: 4/29/2004 4:04:25 PM M'AR'AmH~N~I.I.:..··e~MP'AN¥ [i)ªi!YQøtr1PI~tioll.R~.port EXplþit;:ttIØn-··~..éi·~ WELL NAME KB GL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 PB1 30.6 74.00 17,618 9,700 55 55 55 09-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Gerard Roqer/Russ Trubv Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I CAlLY WELL COST _I CUM Vvt:LL l;V:; I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 - STATE/PROV COUNTY/OTHER I LAST CASING I N EXT l.^~"",. I ~~^~;~8 Alaska 7.000 (in) @. 10,533 (ft) 3.500 (in) @ 17,618 (ft) CURRENT STATUS / MTS 24 HR FORECAST TIH TIH, enqaqe 3-1/2" liner and POOH. OPERATION COMMENTS Trip in hole and engage fish at 10,816'. Jar on fish with no movement. Perform blind backoff and POOH, recovered coupling from TOF. PU double packoff and grappel and TIH. Š~FÊm'YŠUMIVI~RY' <i iF MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG l~oP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP7 I LAST RIG INSPECTION 505.00 None 12/7/2003 12/6/2003 12/312003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Reviewed safety alerts. c>P AR¥ .... > FROM TO HR$ ·f'RgNt TO sua PHAS 06:00 07:00 1.00 17,618 17,618 TA CSGPRC TRIP HGRD TIH to 10,508'. 07:00 08:30 1.50 17,618 17,618 TA CSGPRC CIRC HGRD Circulate and conditon mud to 10.3 ppg. 08:30 10:30 2.00 17,618 17,618 TA CSGPRC TRIP HGRD Wash and rotate down from 10,508' to TOF at 10,816'. PU - 240K, SO-100k, ROT-145K. Pumping at 87 spm 1100 psi above fish, when swallow over fish, press increased by 1,100 psi and shut down pumps. 10:30 13:00 2.50 17,618 17,618 TA CSGPRC FISH HGRD Engage fish at 10816', Attempt to pull I jar fish free by working pipe wI various overpulls up to 200k maximum overpull. Jarred on fish a total of 12 times with up to 100k pre jar tension. (Fishing tool hand suspects that there is quite a bit of free tubin~ below the overshot based on the jar response). Pull 190k overpull, chain brake and hold tension 1 hr while consulting office for gameplan - no movement I loss of weight. 13:00 13:30 0.50 17,618 17,618 TA CSGPRC FISH HGRD Perform blind back-off, work total of 11 turns to the left down hole one turn at a time working pipe multiple times. Pipe free after pulling 125K overpull. 13:30 14:30 1.00 17,618 17,618 TA CSGPRC TRIP HGRD Drop dart to open pump out sub port. POOH to 9847'. Had up to 10K drag while in 7". Saw 60K drag through junction. 14:30 15:00 0.50 17,618 17,618 TA CSGPRC CIRC HGRD Pump on DP to pressure up to open shear out sub, it had opened by bar impact force. 15:00 20:00 5.00 17,618 17,618 TA CSGPRC TRIP HGRD POOH to BHA 20:00 23:00 3.00 17,618 17,618 TA CSGPRC TRIP HGRD Recovered 3 1/2", Hydril 563 coupling from TOF. Have 3 1/2", 9.2 ppf, L-80, Hydril 563 pin looking up. TOF -10,816'. Unable to remove coupling and grapple from overshot bowl, LD same. Begin to PU BHA 23 consisting of 2 packoffs and 3 1/2" basket grapple in overshot. Backup overshot bowl would not make up on extension, bowl appears to be out of round. Note: Overshot had two "V" shaped grooves scarred into side, possiblly indicating dragging junk uphole. 23:00 01:00 2.00 17,618 17,618 TA CSGPRC WAIT HGRD Wait on fishing tools. Perform rig maintenance and hold spill . . Printed: 4/29/2004 4:04:26 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 PB1 DATE 09-Dec-2003 FROM TO HRS FROM 23:00 01:00 2.00 17,618 01:00 02:30 1.50 17,618 02:30 06:00 3.50 OPERATIONSSUMMÞiRY PHASE OP TRBk WAIT HGRD drill. TRIP HGRD PU up overshot wI 3 1/2" basket grapple and 2 packoffs, bumber sub, oil jars, and accelerators. TIH with overshot. MAKE OF PUMP NATIONAL AVG. CONN: MAX. CONN: Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Drilling Contractor Baker Oil Tools Oilfield Hot Shot Service Weatherford Weaver Brothers (WBI) LAST BOP TEST: 12/6/2003 SIZE.. in 7.000 LAST CASING TEST: NEXT BOP TEST: 12/13/2003 4,525 (psi) @ (ppg) Printed: 4/29/2004 4:04:26 PM . . MI~lmME:)NE:)lL..eE:)M.PANY ÐâUy~ompletiQIlR~pørt ~~plôitation . - .G~$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 PB1 30.6 74.00 17,618 9,700 56 56 56 10-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Gerard Roaer/Russ Truby Nabors 273E DX0309030CAPCMP01 - FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM n___ y..¡::n WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 L - STATElPROV COUNTY/OTHER I LAST CASING I NEXT c.~~...." I Lt:A~U~~ Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,618 (ft) 16.08 CURRENT STATUS / MTS 24 HR FORECAST TIH TIH, flush junction and wash down to top of fish. POOH OPERATION COMMENTS TIH, engage fish and jar. POOH recover and lay down one joint of 3 1/2" liner. TIH with bit, circulating sub and magnet. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I lAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP7 I LAST RIG INSPECTION 491.00 None 12/7/2003 12/6/2003 12/3/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Cutting and slipping drill line. '< - . ...... '< ... FRQM TQ HR~ .FRQM Tþ ~ºa '< .... .,-- u",:," 06:00 07:30 1.50 17,618 17,618 TA CSGPRC TRIP HGRD TIHto 10,511' 07:30 08:30 1.00 17,618 17,618 TA CSGPRC TRIP HGRD Break circulation and wash and ream to TOF at 10,816'. PU-250, SO-100K. 60 spm at 800 psi 08:30 09:00 0.50 17,618 17,618 TA CSGPRC FISH HGRD Engage fish. Jar twice and pick up to 410 K. Fishing string jumped free, PU weight at 10,440' was 255K, 5K drag. 60 spm at 950 psi. 09:00 10:00 1.00 17,618 17,618 TA CSGPRC TRIP HGRD POOH, became stuck when OS reached bifuraction point. 10:00 11:30 1.50 17,618 17,618 TA CSGPRC STUCK HGRD Work pipe to 70K overpull twice, unable to go down. Jarred down 12 times to free pipe. Circulate and recipricate pipe, pull across junction with 1 0-15K drag. 11:30 17:00 5.50 17,618 17,618 TA CSGPRC TRIP HGRD Pump slug and POOH 17:00 18:00 1.00 17,618 17,618 TA CSGPRC TRIP HGRD LD one joint of 3 1/2" liner (31.31 '). No cement on the interior or exterior of the 3 1/2". Cutlip guide to the lower packoff was full of brittle cement. TOF at 10,847' with coupling looking up. 18:00 20:00 2.00 17,618 17,618 TA CSGPRC RIG HGRD Slip and Cut Drill Line 20:00 00:00 4.00 17,618 17,618 TA CSGPRC WAIT HGRD Wait on fishing tools, string magnet being brought from North Slope. Clear and clean rig floor while waiting on tools. 00:00 01:00 1.00 17,618 17,618 TA CSGPRC TRIP HGRD PU bit, bit sub, circulating sub, magnet, bumber sub, oil jars, and accelerator jars. 01:00 06:00 5.00 17,618 17,618 TA CSGPRC TRIP HGRD TIH to flush junction and wash down to TOF. I "'þl IECDI IMU[¡)DATAID.\\~I ICYM9P$;or ~ DENSI1"((ppg) 10.30 GI.M~il~$ ·I~ FV PVfYP GEGS IW;.lHl"HF' I FÇIT·S9L .·q!'lf%Sand/MEHlph/i?MRf(Mti¡ 9.I[Q¡) ¡CaCI2('#t%j ··H2$ 85 19/36 14/22 I 7.01 I 1.0/10.0 5/95 /12.0 110.00/1.0 I 0.2/2.21 25,000/220 I I I I BITS ßIOJ'IRUNSIZE MANUF, TYPE ISERIALN(),1 JETSORTFA 1 uo::r "u. DATE IN I Ictl.rhl,.,,...iAb RR2/1$ 6.000 Hughes STX-1 I X06JB I 20/20/20111111I I 17,618.0 12/10/2003 11-1-WT-A-E- I-JD-BHA BIT / RUN WOB I RPM I GPM PRESS P BIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP Printed: 4/29/2004 4:04:31 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 PB1 DATE 10-Dec-2003 BHA NO. BHA TORQl!E{rr\!~)(!rnih) I Tri-Cone Bit, Bit Sub, Circulating Sub, Magnet, Bumper Sub, Oil Jar. Drill Collar (6), Accelerator. Cross Over, 4" Drill Pipe (33), Cross Over COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Drilling Contractor MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: AVG. CONN: MAX. CONN: 12 12 23 340.00 Baker Oil Tools 2 48.00 Oilfield Hot Shot Service 2 48.00 Weatherford 2 24.00 2 1 1 26.00 2.00 3.00 L-80 Printed: 4/29/2004 4:04:31 PM · ....... M~R~ml7løN>øl.L\~ØMp·~N¥ lDâily .Qø.mpl~ti()tiRépør1 E;Xploi·t~ti()n -Gª$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 PB1 30.6 74.00 17,618 9,700 57 57 57 11-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Gerard Roaer/Russ Trubv Nabors 273E DX0309030CAPCMP01 --~ _n. FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST tUM ~.c.... v-v. WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 - STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING l"c"1~;~8 Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,618 (ft) CURRENT STATUS / MTS 24 HR FORECAST TIH TIH, screw into TOF, circ andlor free fish. OPERATION COMMENTS TIH to 9847'. Rotate and wash through junction. Wash and ream to 10,835'. POOH and pick up triple bushing on 17 joints of 31/2" pipe. TIH. 5Þ:FEwyšl..lMMÞ: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 546.00 None 12/7/2003 12/6/2003 12/3/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Picking up tubing from catwalk .\ .SUß._ ...... > ~ IlfBQM. TO HB~ FROM> ·\to .... 06:00 06:30 0.50 17,618 17,618 TA CSGPRC TRIP HGRD TIH to 9847'. 06:30 07:00 0.50 17,618 17,618 TA CSGPRC TRIP HGRD Circulate, 90 spm and 950 psi, and rotate, 20 rpm and 12,000 ft-Ibs, while washing through junction and bifurcation point two times. No abnormal drag or torque. Shut down pumps and rotary and work through junction two more times with no abnormal drag, 1 0-15K over string weight. 07:00 10:30 3.50 17,618 17,618 TA CSGPRC TRIP HGRD Wash and ream from 9950' to 10,835'. (12' form TOF). 10:30 11:00 0.50 17,618 17,618 TA CSGPRC CIRC HGRD Circulate open hole clean. 11 :00 12:00 1.00 17,618 17,618 TA CSGPRC TRIP HGRD Pump out of hole to 10,510'. Hole packed off when pulling into shoe, slacked off and entered shoe. 12:00 14:00 2.00 17,618 17,618 TA CSGPRC CIRC HGRD Circulate hole clean, inside 7" casing. Max gas 14 units. 14:00 14:30 0.50 17,618 17,618 TA CSGPRC TRIP HGRD POOH to 9849'. Saw normal drag through junction, 10-15K. 14:30 19:00 4.50 17,618 17,618 TA CSGPRC TRIP HGRD Pump slug and POOH. 19:00 20:30 1.50 17,618 17,618 TA CSGPRC TRIP HGRD LD BHA. Only recovered metal splinters and small pieces of unidentifiable metal on magnets Largest piece was roughly 1/2" square and 1/4" thick. 20:30 00:30 4.00 17,618 17,618 TA CSGPRC WAIT HGRD Wait on fishing tools. (Airport iced in, tools driven from Anchorage) 00:30 03:00 2.50 17,618 17,618 TA CSGPRC TRIP HGRD PJSM. RU and run a skirted Hydril 563 bushing (triple connection bushing) 17 joints 3 1/2",9.2 ppf, L-80, Hydril 563 tubing. and crossovers to 4" DP. RD tubing tongs and clear floor to run drill pipe. 03:00 06:00 3.00 17,618 17,618 TA CSGPRC TRIP HGRD Run (5) stands of 4" DP. RIH with 5 1/2" drill pipe. 10.40 1 PI' 1 1·~çt;)1 IM~~Alœq~T...1 .ÇUMCOST ¡ - QI;N§IT'((ppg) FV PVIYP Gè..S I NVL/HTHÞI Fçrr:§ø¡.. 9Nf..%Sarl .. ..Phl I@W I elicit IÇ¡¡Çlf(~%jH2sl LIMEIE.sl$~ 67 14/30 10/12 1 10.21 I 1.0/10.0 I 112.0 110.00/3.410.6/2.81 21,000/360 1 I I I I BITS ßll'IRlINI· .$IZE MANUF. TYPE I SERIAL NO. I JETSORTFA I QEPTHIN. QATEIN I .. l_rÜn. .··.,,,6./6 RR2/1~ 6.000 Hughes STX-1 1 X06JB I 20/20/20/1//111 I 17,618.0 12/10/2003 11-1-WT-A-E- I-JD-BHA BIT 1 RUN WOB I RPM I GPM PRESS I' BIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP Printed: 4/29/2004 4:04:34 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas BIT I RUN 5RR2/18 SA TORQIjF(fQªJo/fQii1) I Shoe, Triple Bushing, 3 1/2", 9.2, L-80, Hydril653 tubing (17), Cross Over, Cross Over, 4" Drill Pipe (15), Cross Over AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: units 14 14 Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Oil Tools Drilling Contractor 23 340.00 Oilfield Hot Shot Service 2 48.00 Weatherford 2 48.00 R&K Industrial 2 24.00 Steam on Wheels 2 48.00 BJ Services 1 1 1 2 2 2.00 4.00 4.00 20.00 8.00 LAST BOP TEST: SIZE ih 7.000 CASING SUMMARY LAST CASING TEST: ft 4,525 (psi) @ (ppg) 10,533 Printed: 4/29/2004 4:04:34 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas STATElPROV Alaska CURRENT STATUS / MTS MIU skirted mill BHA OPERATION COMMENTS TIH, engage TOF and establish circ around liner. Max gas 817 units. Hole packed off and re-establish circulation. Lost pump pressure. and DP jumped, released from TOF. TOH. Found washout in H563 pin on triple connection bushing. MIU TIH w mill SAFETYSl.llVIlVIARY LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Gerard Ro er/Russ Trub FIELD NAME WILDCAT-FOR UNNAMED FIELD KB 30.6 RIG NAME & NO. Nabors 273E RIG PHONE 907-260-6935 COUNTY/OTHER MANHRS WORKED ACCIDENT TYPE 568.00 None ACCIDENT DESCRIPTION: 12/7/2003 12/6/2003 SAFETY MTG TOPICS: UD tubing fish, icy conditions 24 HR PROG TMD 17,618 AUTH MD RPT# DATE 58 12-Dec-2003 SAPIWBS COST TVD 9,700 WBS MOCWI 100.0000 NRI lCUM n__"''-~v. LEAKOFF LAST CASING 7.000 in 24 HR FORECAST Mill off connection on 3-1/2" liner fl ackoff overshot 16.08 P/U LAST RIG INSPECTION N 12/3/2003 S SUMMARY TRBL HGRD Continue TIH wI triple connection bushing on 5-112", 4" DP and 3-1/2" tubing to 10,774'. PIU 220k above junction, SIO 100 k. (set down 25 k at 10,440' and 15 k overpull- crossovers above tubing nearing junction). 09:00 09:30 0.50 17,618 17.618 TA HGRD Wash/Ream from 10,774' to TOF 10,847' PIU wt 230k, SIO 100k. ROT wt 150k, 15 rpm @ 16k Torq. After washing top of fish pump rate 88 spm, 800 psi. 09:30 11:00 1.50 17.618 17.618 TA HGRD Rotate and work pipe and engage fish by screwing into Hydril 563 box. Positive pressure indictaion when fish was engaged, SID pumps. Work torq up to 20k and trap, work pipe from 20 k overpull to 10 k weight down while seating connection. 11:00 14:30 3.50 17,618 17.618 TA HGRD Begin circulating 24 spm, 1250 psi. Gradually work the pump rate up to 68 spm, 3000 psi while looking for indictaion of wiper plug landing in LC. Continue to circ and condition mud. Hole seemed to be packing off at times and building up pressure. Max gas of 817 units wI MW cut f/10.5 to 9.9 ppg on calculated BU from the liner depth. (began seeing gas from lag depth shortly below the TOF). Approximately 5,000 stks past BU. pressure increased to 3,800 psi, 14:30 16:30 2.00 17,618 17,618 TA CSGPR FISH HGRD SID pump and pressure bleeding off slow. Repressure several times and attempt a rapid bleed off on the DP to back flush any plugging debris. Check trapped torq on DP and work several times from 70k overpull to 20k down. Indications of hole packed off. Hold 3,000 psi SPP and attempt to work pipe free - gaing on circulation rate. Pull max of 400k HL and SIO to 60k HL. Appears to be injecting into the formtion at 15 spm, 2,950 psi. Unable to establish circulation. Pull up to max of 420k HL and chain the brake down - consult office. 16:30 18:00 1.50 17,618 17.618 TA CSGPR FISH HGRD Close hydril and pressure up on casing annulus to 1500 psi (3) times and perform a rapid bleed off. Work pipe and attempt to Printed: 4/29/2004 4:04:35 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 PB1 DATE 12-Dec-2003 FROM TO HRS 16:30 18:00 1.50 FROM 17,618 TO SUB 17,618 TA 18:00 19:30 1.50 17,618 17,618 TA OPERATIONS SUMMARY PHASE OP TRBL CSGPR FISH HGRD CSGPR CIRC HGRD 19:30 20:30 1.00 17,618 17,618 TA HGRD 20:30 04:30 8.00 17,618 17,618 TA HGRD 04:30 06:00 1.50 17,618 17,618 TA HGRD DESCRIPTION flush backside. Pressure up DP to 3,800 psi (3) times and perform a rapid bleed off. Work torq and overpull on string. Close hydril and pressure up on the casing annulus to 1800 psi (2) times and perform a rapid bleed off. Pressure up to 3500 psi on DP and establish minimal circulation. Work pipe wI 21 k torq and 70k overpull. Circulating at 45 spm, 3500 psi. Continue to circulate well, maintaining 3,500 psi SPP. Pump rate increasing as if well is cleaning up. Gaining on pump rate and DP pressure decreasing. Max flow rate achieved was 104 spm, 2300 psi. At 88 spm pressure is 1375 psi and was previously 88 spm at 800 psi before engaging fish. P/U to 320 k HL and DP jumped free. P/U wt after was 240k. Pump rate no 88 spm @ 900 psi. Large pieces of coal at shakers - possibly what was packing off. Circulate at 88 spm, 900 psi while mixing slug. Flow check well and pump slug. TOOH w/10 k drag in 7" casing. 40k drag thru the formation junction. UD (17) joints of 3-1/2" casing. Triple connection bushing where TOF was engaged had washed out. MIU skirted pilot mill assembly wI cut lip guide shoe to mill off Hydril 563 box. o 230 100 150 116,000 Shoe, Triple Bushing, 3 1/2", 9.2, L-80, Hydri 653 tubing (17), Cross Over, Cross Over, 4" Drill Pipe (15), Cross Over NATIONAL AVG. CONN: MAX. CONN: Nabors Alaska Drilling Marathon Epoch Well SeNices M-I Drilling Fluids Baker Oil Tools SERVICE Drilling Contractor PERSONNEL DATA NO. HOURS COMPANY 23 340.00 Weatherford 2 48.00 R&K Industrial 2 48.00 BJ SeNices 2 24.00 Alaska Pipe Recovery (A 2 48.00 MUD GAS AVG. TRIP: MAX. TRIP: units 817 AVG. BKGRD: MAX. DRL: 8 SERVICE 1 1 2 3 4.00 12.00 8.00 36.00 Printed: 4/29/2004 4:04:35 PM WELL NAME KASILOF SOUTH 1 PB1 SUPERVISOR Milton Castleman I Randv Ratli FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS PIU 3-1/2" scab liner. OPERATION COMMENTS TIH wI mill assembly. . MARATHON OIL COMPANY Daily Completion Report Exploitation ~ Gas IGL 30.6 I 74.00 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,618 AUTH MD TVD I DFS IDOL I RPT # DATE 9,700 I 59 59 I 59 13-Dec-2003 WBS SAPIWBS COST KB DX0309030CAPCMP01_ MOC WI NRI ! DAILY WELL COST 1'1 CUM W£:LL ~v~ I 907-260-6935 100.0000 I "- __ COUNTY/OTHER ¡LAST CASING I NEXT ,-"",N" L.""I\.V" 7.000 On) lID. 10,533 (ft) I 3.500 On) lID. 17,618 (ft) 16.08 24 HR FORECAST TIH wI Scab Liner, Latch onto liner, circulate, cement RIG PHONE Mill top of fish f/10,847' - 10,849'. Circulate hole clean. POOH. PIU 3-1/2" scab liner. SÄF+'ETYSUMMÄRM IBOP PSI TEST I LAST STOP CARD AUDIT 1 REGULATORY INSP? 112/6/2003 I 1 N MANHRS WORKED I ACCIDENT TYPE 1 LAST SAFETY MTG 542.00 None 112/12/2003 ACCIDENT DESCRIPTION: I LAST RIG INSPECTION 112/11/2003 SAFETY MTG TOPICS: Authorization for electrical work. IIF~QM TÓ HR~i í7~9M 06:00 07:30 1.50 17,618 07:30 08:00 0.50 17,618 08:00 09:30 1.50 17,618 09:30 10:00 0.50 17,618 10:00 13:30 3.50 17,618 13:30 15:30 2.00 17,618 15:30 18:30 3.00 17,618 18:30 01:30 7.00 17,618 01:30 02:00 0.50 17,618 02:00 03:00 1.00 17,618 03:00 03:30 0.50 17,618 03:30 04:00 0.50 17,618 04:00 04:30 0.50 17,618 04:30 06:00 1.50 17,618 ~i..<.. ..}....·.·iiii .t9SÜB~} .. 17,618 TA CSGPRC TRIP HGRD TIH wI skirted pilot mill assembly wI cut lip guide shoe to mill off Hydril563 box to 1,275'. Change handling tools from 4' to 5-1/2". Con't TIH with 5-1/2" drill pipe to 4230'. Fill DP and break circulation. Calibrate flow meter on flowline. Con't TIH to 10,847'. 20k drag thru bifurcation point. Safety wash f/10,815' -10,847' no fill. HGRD Mill top of fish f/1 0,847' - 10,849' (2') to remove casing coupling 30-60 RPM 43 SPM @ 900 psi. Increase pump rate after mill in! over to 98 SPM 2400 psi. Pressure slowly dropping to 2000 psi. Decreased rate to 70 spm after 5 minutes. HGRD Circulate hole clean.115 RPM @ 22,000 ft Ibs, 70 SPM @ 1350 psi. Recovered small pieces of hard rubber (casing wiper plug) at shale shaker. HGRD Drop drift with wire down drill pipe. POOH to BHA. First 3-stands required slight rotation to break free when pulling off the slips. 15k drag thru the bifurcation point. HGRD UD XO and accelerator jar. Set back Drill collars. Retrieve drift and wire. HGRD Break off cut lip guide from mill. Recover thin pieces of casing collar wedged in top of mill along with some additional pieces of hard rubber and aluminum. Indications of good mill run on top of fish. LID oil jar and bumper sub. Clear and clean milling assembly from the rig floor. PIU Top Drive cementing head and install1-jt of 5-1/2" drill pipe on top. UD same. HGRD RIU 3-1/2" casing tools. HGRD M/U overshot with high pressure packoff, and 14 jts of 3-1/2" 9. ppf L-80 Hyd 563 casing. 17,618 TA 17,618 TA 17,618 TA 17,618 TA CSGPRC TRIP CSGPRC TRIP CSGPRC CIRC CSGPRC TRIP HGRD HGRD HGRD HGRD 17,618 TA CSGPRC FISH 17,618 TA CSGPRC CIRC 17,618 TA CSGPRC TRIP 17,618 TA CSGPRC TRIP 17,618 TA CSGPRC TRIP 17,618 TA 17,618 TA CSGPRC CLEAN HGRD CSGPRC CEMT HGRD 17,618 TA 17,618 TA CSGPRC CSG CSGPRC CSG Printed: 4/29/2004 4:04:37 PM · MARATHON OIL COMPANY Daily Comple Exploitati WELL NAME KASILOF SOUTH 1 PB1 6RPM HA TQRQ\)E(fi1ãwmìn) I Skirted Pilot Mill , Bumper Sub, Oil Jar, Drill Collar (6), Accelerator, Cross Over, 4" Drill Pipe (33), Cross Over MAKE OF PUMP NATIONAL AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: units Drilling Contractor 20 AVG. BKGRD: MAX. DRL: 8 Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Oil Tools Weatherford 23 340.00 R&K Industrial 2 48.00 BJ Services 2 48.00 Weaver Brothers (WBI) 2 24.00 Oilfield Hot Shot Service 2 48.00 Wildflowers and Resin 1 6.00 1 1 3 1 1 12.00 2.00 6.00 2.00 6.00 CASING SUMMARY LAST CASING TEST: MAX SICP 4,525 (psi) @ (ppg) 5,740 Printed: 4/29/2004 4:04:37 PM MARAlliHONOILCOMPANY ÐiaUY· COlT1þlêtion< Repöt1 ExploitatiO!'1'"Qas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 PB1 30.6 74.00 17,618 9,700 60 60 60 14-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPMlR~ ,...n~T Castleman I Ratliff Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI IDAILY,^,~" 5T Ir.u.. ..,~" "'''~T' WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 _.~J STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,618 (ft) 16.11 CURRENT STATUS / MTS 24 HR FORECAST TOOH with Scab Liner assembly OPERATION COMMENTS TIH with scab liner and HP pack-off overshot assembly. Overshot milled liner casing stub. Unable to circulate thru liner casing shoe. Release overshot and trip out of hole. S~FE!f¥SUMMAR¥ MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I ~AST RIG INSPECTION 544.00 None 12/14/2003 12/612003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Tripping safely. 01 .......,,,< .. .... . FROM .Tþ .HRS< FROM to S~.B T~åþ ........ < ......... 06:00 07:00 1.00 17,618 17,618 TA CSGPRC CSG HGRD Finish picking up 14 joints of 3-1/2" 9.2# L-80 H563 liner casing. PIU Baker PBR assembly with 66K shear release sub. 07:00 07:30 0.50 17,618 17,618 TA CSGPRC CSG HGRD Change handling equipment from 4" to 5-1/2". 07:30 13:00 5.50 17,618 17,618 TA CSGPRC CSG HGRD Continue TIH with scab liner and high pressure pack-off overshot assembly to 8976'. 13:00 14:00 1.00 17,618 17,618 TA CSGPRC CIRC HGRD Mud u-tubing up drill pipe. Mix and pump slug. 14:00 15:30 1.50 17,618 17,618 TA CSGPRC CSG HGRD Finish TIH to 10,839'. 15:30 17:00 1.50 17,618 17,618 TA CSGPRC CSG HGRD MIU top drive cement head. Test lines to 3500 psi. 17:00 18:00 1.00 17,618 17,618 TA CSGPRC CSG HGRD Wash down to top of 3-1/2" milled liner casing stub @ 10,849'. Overshot stub, SID pump after pressure increased 50 psi. Overshot approximately 5' of stub. Resume pumping with no pump pressure increase from original circulating pressures. Over pull overshot with 20K for confirmation of fish engagement 18:00 21:00 3.00 17,618 17,618 TA CSGPRC CIRC HGRD Pump around and recover carbide. Lag indicated circulation not thru 3-1/2" casing shoe. Appears to be in vicinity of overshot. Over pull overshot with 40K for confirmation of fish engagement 21:00 21:30 0.50 17,618 17,618 TA CSGPRC TRIP HGRD Release overshot. 21:30 22:30 1.00 17,618 17,618 TA CSGPRC TRIP HGRD LID cement head. 22:30 06:00 7.50 17,618 17,618 TA CSGPRC TRIP HGRD Slug pipe, TOOH to inspect HP pack-off overshot. J;>gN$ìTY(ppg) I Ipj')J IEcp! IMU DzDA.!fAloAILYQOSTI l.cU~ço§t - 10.50 - . -- ,0 FV PVIYP &gLê I WLJHtHPI FCIT.SOL O/w %S"n~/t/1~"1'I·phipM. .1.Pf(~f .1' ¢jjÞa H~§ ÚMEE§ ¡~ 72 16/36 14/25 1 148.0/ 1 2.0/10.0 2/88 /12.0 111.80/8.21 0.8/4.61 23,500/320 1 I 1 14 MUD····G~S I UNITS units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNEL DATA PQB@06:00: COMPANY 1 SERVICE NO. HOURS COMPANY I SERVICE NO. I HºI.J~Š Nabors Alaska Drilling I Drilling Contractor 23 340.00 Marathon I 21 48.00 . Printed: 4/29/2004 4:04:38 PM · MARATHON OIL COMPANY Daily Complation Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 PB1 COMPANY Epoch Well Services M-I Drilling Fluids Baker Oil Tools Weatherford PERSONNEL. DATA NO. HOURS COMPANY 2 24.00 R&K Industrial 2 24.00 BJ Services 4 84.00 Alaska Oil Sales 1 4.00 Oilfield Hot Shot Service SERVICE SERVICE c DATE 14-Dec-2003 POB @ 06:00: NO. HOURS 1 12.00 1 4.00 1 2.00 1 2.00 12/13/2003 8,160 Printed: 4/29/2004 4:04:38 PM . MARAllilHeN 0JLQ:eMRANY ?agè1 [)ài.I'y...QØ~þl~ti.onfR~p()rt l::)ÇiþIQitatiO!'l..:Gª$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 PB1 30.6 74.00 17,618 9,700 61 61 61 15-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman / Ratliff Nabors 273E DX0309030CAPCMP01 !..- FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL CO~M W!:LL GU::;! WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATE/PROV COUNTY/OTHER I LAST CASING I NEXT v~;:>INI> I LEAKOFF Alaska 7.000 (in) (QJ. 10,533 (ft) 3.500 (in) (QJ. 17,618 (ft) 16.11 CURRENT STATUS / MTS 24 HR FORECAST Lavinq down 3-1/2" tubinq. OPERATION COMMENTS Pump and spot a P & A I Kick-off plug in motherbore lateral #1. SÂRÊTYSlJMMARY· MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG l~oP PSITEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 572.00 None 12/15/2003 12/612003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Mixing mud, using proper PPE. . C)mC)N$;~lJMMÄR¥ .. fR.qM TO. HR.$ FROM 'l"Ô $ue i PI-IA .OP. .. TRBL ""'}' 06:00 06:30 0.50 17,618 17,618 TA CSGPRC TRIP HGRD RlU tubing tongs. Hold PJSM. 06:30 08:00 1.50 17,618 17,618 TA CSGPRC TRIP HGRD UD Liner PBR assembly. Finish TOOH with 3-1/2" tubing. LID HP pack-off overshot assembly. Packing rings and seal elements damaged inside overshot. Appears that liner casing stub never reached overshot grapple. Decision made to end attempts to salvage KS #1 motherbore, lateral #1 due to mechical problems. Will set P & A I Kick-off plug and drill KS #1-L 1 north lateral out of leg #1. 08:00 14:30 6.50 17,618 17,618 TA PLUGAB TRIP HGRD TIH open ended with 3-1/2" muleshoe and tubing on drill pipe to 10,836'. 14:30 15:00 0.50 17,618 17,618 TA PLUGAB CIRC HGRD M/U top drive cementing head. Test pump lines to 3500 psi. 15:00 18:00 3.00 17,618 17,618 TA PLUGAB CIRC HGRD Circulation and condition. Hold PJSM. 18:00 18:30 0.50 17,618 17,618 TA PLUGAB CEMT HGRD Set P & A I Kick-off cement plug as follows: Pump 10 barrels fresh water spacer, followed by 210 sx Class G cement (208 cu/ft) with 0.7% CD-32 + 1 gps FP-6L mixed @ 17.0 ppg. Displace wiper plug with 5 BBLS fresh water and 197 BBLS of 10.4 ppg mud, leaving 15 BBLS excess cement in drill pipe. Cement in place @ 18:30 hours 12/14/2003. Cement plug designed for 303' in open hole (caliper + 35% excess) from 10,836' to 7" casing shoe @ 10,533', and 170' plug in 7" casing from 10,533' to 10,363' with 15 additional BBLS of cement to displaace tubing while pulling pipe. Displace plug at 10 BPM while rotating pipe at 40 RPM. 18:30 19:30 1.00 17,618 17,618 TA PLUGAB TRIP HGRD RID cement head. Pump out of hole with 5 stands of drill pipe tc 10,363', displacing remaining 15 BBLS cement out of pipe. 19:30 21:00 1.50 17,816 17,618 TA PLUGAB CIRC HGRD Circulate bottoms up, dump +1- 35 BBLS of cement contaminated mud. 21:00 21:30 0.50 17,618 17,618 TA PLUGAB TRIP HGRD TOOH with 4 stands drill pipe to 9983'. 21:30 22:30 1.00 17,618 17,618 TA PLUGAB CIRC HGRD Circulate and wash out Formation Junction. Pump and spot a Printed: 4/29/2004 4:04:40 PM WELL NAME KASILOF SOUTH 1 PB1 FROM TO HRS 21:30 22:30 1.00 22:30 23:00 0.50 23:00 05:00 6.00 05:00 05:15 0.25 05:15 06:00 0.75 AVG. CONN: MAX. CONN: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Oil Tools Baker Hughes 'nteq LAST BOP TEST: 12/6/2003 FROM 17,618 17,618 17,618 17,618 17,618 MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas DATE 15-Dec-2003 TO SUB 17,618 TA OPERATIONS SUMMARY PHASE OP TRBL PLUGAB CIRC HGRD 17,618 TA 17,618 TA 17,618 TA 17,618 TA HGRD HGRD HGRD HGRD 20 BBL pill with retarder across Junction Bifurcation point and diverter. TOOH with 5 stands of drill pipe. Slug pipe, TOOH with drill pipe. RIU tubing tongs. Hold PJSM. Laying down 3-1/2" tubing. PLUGAB TRIP PLUGAB TRIP PLUGAB TRIP PLUGAB TRIP SERVICE H 23 340.00 Weatherford 2 48.00 R&K Industrial 2 24.00 BJ Services 2 24.00 Veco Alaska 2 30.00 Carlile Transportation Sy 3 36.00 Lynden Transport 4.00 24.00 30.00 8.00 2.00 2.00 1 2 5 1 1 1 LAST CASING TEST: NEXT BOP TEST: 12/13/2003 16.11 Printed: 4/29/2004 4:04:40 PM · MÞ¡R~;Y:H(;)Ni(;)IL...G(;)MRÞ¡N¥ Pªil;Y;€o.ooF)Jêtiol') ··.·~~pôrt lE~pl.oitati(>n..(.;as WELL NAME KB IGL 24 HR PROG TMD TVD IDFS [DOL RPT# DATE KASILOF SOUTH 1 PB1 30.6 74.00 17,618 9,700 62 62 62 16-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman / Ratliff Nabors 273E DX0309030CAPCMP01 L FIELD NAME RIG PHONE MOCWI NRI DAILYWI='. ,..,.."..- two, ..~~~ v~~, WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTYIOTHER I LAST CASING NEXT CASING I LEAKOFF Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,618 (ft) 16.11 CURRENT STATUS 1 MTS 24 HR FORECAST Circulatinq bottoms UP for samples. OPERATION COMMENTS Test BOPE. TIH with steerable drilling assembly. Wash in hole from 10,273' to 10,525'. SAFETYSUJMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 594.00 None 12/15/2003 12/15/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Testing BOPE. ~NS~..~...MMA~Y ..;i>·· liFR2~i TQ .HR$ ·FR2M "1'9 $Qß ¡;18M!? fRBt ... 06:00 06:30 0.50 17,618 17,618 TA PLUGAB TRIP HGRD Finish LID 3-1/2" tubing and muleshoe sub. 06:30 07:00 0.50 17,618 17,618 TA PLUGAB TRIP HGRD RID tubing handling equipment. 07:00 09:00 2.00 17,618 17,618 TA PLUGAB TRIP HGRD LID drilling jars and 5 joints of 4" HWDP from derrick. 09:00 10:00 1.00 17,618 17,618 TA PLUGAB EQUIP HGRD Break off cross-overs, LID top drive cementing head. 10:00 10:30 0.50 17,618 17,618 TA PLUGAB TRIP HGRD Pull wear bushing, set test plug. 10:30 16:30 6.00 17,618 17,618 TA PLUGAB TEST HGRD Test BOPE, 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 I 3500 psi, 5 minutes low and high each test. Test gas and H2S alarms. Run accumulator test. AOGCC Representative Jeff Jones on location to witness test. 16:30 17:00 0.50 17,618 17,618 TA PLUGAB TRIP HGRD Pull test plug, set wear bushing. 17:00 19:30 2.50 17,618 17,618 TA PLUGAB TRIP HGRD MIU steerable drilling assembly, PIU drilling jars and 5 joints of 4" HWDP, 19:30 21:00 1.50 17,618 17,618 TA PLUGAB RIG HGRD CDT: Troubleshoot and repair rig draworks. 21:00 22:30 1.50 17,618 17,618 TA PLUGAB TRIP HGRD TIH with BHA and 15 stands of drill pipe. Shallow test MWD tool. 22:30 23:30 1.00 17,618 17,618 TA PLUGAB RIG HGRD Service top drive. Replace gripper dies in pipe handler. 23:30 04:00 4.50 17,618 17,618 TA PLUGAB TRIP HGRD Finish TIH to 10,273'. Monitor 1 OK to 15K drag with motor thru Bifurcation point of FORMation Junction. 04:00 05:30 1.50 17,618 17,618 TA PLUGAB TRIP HGRD Wash in hole from 10,273' to 10,400'. Did not see any cement at projected top of cement kick-off plug @ 10,363'. SID pump, continue in hole until bit took 25K weight @ 10,485'. Wash in hole from 10,485' to 10,505' with 0 WOB. Wash / Ream in hole from 10,505' to 10,525' (8' above 7" casing shoe @ 10,533') wit~ 5K to 6K WOB, with 200 - 250 psi differential on motor @ 10 FPM. 05:30 06:00 0.50 17,618 17,618 TA PLUGAB CIRC HGRD Circulating bottoms up for samples. Printed: 4/2912004 4:04:43 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas Page 2 of 2 6RPM 15 BHA BHA NO, TORQU¡¡; (maximin) 28 1,799.26 0 240 100 140 I BHA DESCRIPTION 6" Mill-Tooth 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 Tool, 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" Drill Pipe, Cross-Over Sub AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: units Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Oil Tools AVG. BKGRD: MAX. DRL: 23 340.00 Baker Hughes Inteq 2 48.00 Weatherford 2 24.00 R&K Industrial 2 24.00 S&R Enterprises 1 8.00 Wildflowers and Resin 3 1 4 1 2 84.00 4.00 48.00 2.00 12.00 CASING UMMARY LAST CASING TEST: NEXT BOP TEST: 12/22/2003 1,578 (psi) @ 10.50 (ppg) 8,160 Printed: 4/29/2004 4:04:43 PM .. M.«IR.«T1H0NC>lL.OC>MI.«NY Dc,i IYYOh1pløtio n.IRQþott ExpIÔitåtiÔn-G.~$ WELL NAME KB IGL 24 HR PROG TMD TVD DFS IDOL RPT# I DATE KASILOF SOUTH 1 PB1 30.6 74.00 17,618 9,700 63 63 63A 17-Dec-2003 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Castleman I Ratl iff Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCW! NR! I DAILY WEll rnC!:T fe"..·.."'" rn~T WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 i - STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAK OFF Alaska 7.000 (in) (â1 10,533 (ft) 3.500 (in) (â117,618 (ft) 16.11 CURRENT STATUS / MTS 24 HR FORECAST Well circulated wI pre-mixed Flo-Pro mud. Final report for Motherbore Lateral. OPERATION COMMENTS TIH and tag hard cement. Dress cement fl 10,565'-10,570'. Circulate hole clean. Clean pits. Displace with pre-mixed Flo-Pro mud. SAFIžTYiSUMMARM MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSITEST I LAST STOP CARD AUDIT I ~EGULATORY INSP7 I LAST RIG INSPECTION 591.00 First Aid 12/16/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: Worker dropped heater on left foot. SAFETY MTG TOPICS: Confined space entry -- .... ·.{i fROM ,.q HRS FROM <TO sUfi .. {< 06:00 07:00 1.00 10,525 10,525 TA PLUGAB CIRC HGRD Circulate btms up. Recovered no hard cement. 07:00 07:30 0.50 10,525 10,570 TA PLUGAB DRILL HGRD Wash dwon To 10,565'. Tagged hard cement, Drill fl 10,565'-10,570' . 07:30 08:30 1.00 10,570 10,570 TA PLUGAB CIRC HGRD Circulate hole clean. 08:30 09:00 0.50 10,570 10,570 TA PLUGAB TRIP HGRD POOH to 10,460'. 09:00 00:00 15.00 10,570 10,570 TA PLUGAB CLEAN HGRD Empty and clean rig pits. Fill with pre-mixed Flo-Pro mud. 00:00 00:30 0.50 10,570 10,570 TA PLUGAB TRIP HGRD TIH to 10,554'. 00:30 01:00 0.50 10,570 10,570 TA PLUGAB CIRC HGRD Clean #3 pump screen while mixing mud spacer. 01:00 03:00 2.00 10,570 10,570 TA PLUGAB CIRC HGRD Displace hole with pre-mixed 9.1 ppg Flo-Pro mud. 03:00 03:30 0.50 10,570 10,570 TA PLUGAB CLEAN HGRD Clean shale shakers. ··Prepare to kick off from Motherbore leg and drill to Kasilof South #1 Lateral #1 target. End of report for Motherbore Leg. 9.10 11"1"1 1.·EÇPil liMU[i)i[i).Þ.trA~ I iBG~i~ - QI;I\I§ITY(þpg) 1"'I!!r:::I..E$I§~~ FV PViYP G1;4§ IWwÎ-!'11ipl "'....,+.,,.\loJVY%sa...~/MElT { . P'YIi.lF'f(~1f1 GÎlCá 280 18/41 15/20 I 5.21 I 2.0/11.0 2/87 /10.0 9.50/11.5 I 0.8/3.4 [ 36,000 /250 I 20.0 I I iSIHÄ .'> BHANO. [l-ENGTt-I IEI"I"VvT. PICKUP I$LAC~ ()F~Ii\µINV I. t I\µKUVI: I~HAHRSI.JARHR$ IMWOt!R.S1.."c ClC"'~ 28 I 1,799.26 I I I I I I I I I I BHA DESCRIPTION 6" Mill-Tooth 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 Tool 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 JTS4" HWDP , 45 JTS 4" Drill Pipe , Cross-Over Sub PUMP r HMÐRAULI.C.DATA NO. I MAKE OFplJMp I STROKEI¡nr¡' L.INER.. (i6) $pM[qlgpl]1)l.pRESS. (PSi)! TOTALq[' KIL.L·SpM>/.PRESSURE 2 I NATIONAL I 12.000 I 6.000 60 [ 251.16 [ 1 ,450 I 251.16 [ MUÐGAS UNITS I units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: . . Prinled: 4/29/2004 4:04:45 PM WELL NAME KASILOF SOUTH 1 PB1 COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Hughes Inteq R&K Industrial SERVICE MARATHON Oil COMPANY Daily Completion Report Exploitation - Gas Page PERSONNELDATA NO, HOORS COMPANY 23 340.00 S&R Enterprises 2 48.00 Veco 2 24.00 S&R Enterprises 2 24.00 Carlile Transportation Sy 3 72.00 BJ Services 4 48.00 Rain For Rent SERVICE 2.00 24.00 2.00 2.00 3.00 2.00 NEXT BOP TEST: 12/22/2003 1,972 (psi) @ 9.10 (ppg) 8.160 Printed: 4/29/2004 4:04:45 PM . . Dailv Summary for Well: KASILOF SOUTH 1 Report Report MD TVD Summary -------~~!~---------~~~þ~~--------------------------------------------------------------------------------------- 17 -Dee-03 63A 17,618 9,700 TIH and tag hard cement. Dress cement f/1 0,565'- 10,570'. Circulate hole clean. Clean pits. Displace with Flo-Pro mud. 17 -Dec-03 63B 10,680 5,493 Drill from KOP @ 10,570 to 10,680'. 18-Dec-03 64 10,932 5,591 Drill from 10,680' to 10,932'. Re-Test 7" casing shoe. Trip for bit. 19-Dec-03 65 12,020 6,051 Finish tripping in hole. Slide & rotary drill from 10,932' to 12,020'. 20-Dec-03 66 13,500 6,690 Drill from 12,020' to 13,500'. 21-Dec-03 67 14,615 7,324 Slide ànd rotary drill from 13,500' to 14,615'. 22-Dec-03 68 15,465 8,000 Drill to 15,354'. Wiper trip to 12,500'. Drill to 15,465'. 23-Dec-03 69 16,275 8,732 Drill 15,465' - 16,275'. Circulate hole clean. POOH. 24-Dec-03 70 16,275 8,732 POOH and change out motor. Test BOP's. TIH. 25-Dec-03 71 16,490 8,928 Finish trip in hole. Drill 16,275' to 16,490'. MWD failed, POOH. 26-Dec-03 72 16,490 8,928 POOH, change out MWD. TIH. 27 -Dec-03 73 17,225 9,589 Wash and ream to bottom. Drill to 17,225'. 28-Dec-03 74 17,575 9,915 Drill to 17,400' MD. Increase mud weight to 10.6 ppg while circulating hole clean. Short trip to 16,101'. (Office extended TD). Drill to 17,575' MD while increasing mud weight to 10.9 ppg. 29-Dec-03 75 17,665 10,000 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. 30-Dec-03 76 17,665 10,000 Short trip to 13,000'. CBU. POOH. LD motor and MWD. Make up Reeve's logging BHA. 31-Dec-03 77 17,665 10,000 TIH with drill pipe deployed logs to 17,659'. Circulate bottoms up. Deploy logging tools and POOH logging. POOH. BHA. LD 01-Jan-04 78B 17,665 10,000 RU to run liner. Run 3-1/2" liner. 02-Jan-04 79 17,665 10,000 Run and cement 31/2" liner. Set liner hanger and release running tool. CBU. 03-Jan-04 80 17,665 10,000 CBU. POOH. BHA. RIH. Pull and Reset Diverter. POOH. 04-Jan-04 81 17,665 10,000 BHA. RIH. Polish PBR @ 10,325'. POOH. BHA. RIH. 05-Jan-04 82 17,665 10,000 RIH. Pull and reset diverter @ 9,904'. POOH. BHA. RIH. Set Packer @ 10,092'. POOH. 06-Jan-04 83A 17,665 10,000 POOH. BHA. RIH. Pull Motherbore diverter @ 9904'. POOH. BHA. Printed - 5/3/2006 - Page 5 )0 J.. _). n. . . ~o;< ~ ó{SÇ; Kasilof South 1 RD 1 Drilling (Reports 83B -98A) KASILOF SOUTH 1 SUPERVISOR Ratliff I Castleman FiELD NAME 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 9,940 AUTH MD 17 ,300 MOC Wi NR; 100.0000 I CUM WELL COST I R;G PHûNE WILDCAT-FOR UNNAMED FIELD 907-260-6935 STAT8PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS POOH OPERATION COMMENTS BHA. RIH. Set Leg #1 diverter @ 9904'. POOH. 00:00 00:30 0.50 9,940 9,940 AF DRLPR TRIP Function test FJD tool. PIU Leg #1 diverter. RIH wI BHA. 00:30 02:30 2.00 9,940 9,940 AF DRLPR TRIP RIH to 5025'. 02:30 03:00 0.50 9,940 9,940 TA DRLPR RIG SOTH Replace hydraulic torque cylinder on Iron Roughneck. 03:00 05:00 2.00 9,940 9,940 AF DRLPR TRIP Con't RIH to 9904'. 05:00 05:30 0.50 9,940 9,940 AF DRLPR TRIP Set diverter @ 9004'. Confirm unlatch wI 85K overpull. Reset diverter. Confirm set wI 30k overpull. Release FJD tool from diverter. 05:30 06:00 0.50 9,940 9,940 AF DRLPR TRIP Slug pipe. POOH to 9500'. 20.000 13.375 7.000 18.730 12.415 6.184 18.57 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) (psi) @ 10.30 (ppg) 130 2,860 9,941 130 2,368 5,198 133.00 68.00 29.00 K-55 K-55 L-80 Printed: 4/8/2004 3:42:47 PM WELL NAME KASILOF SOUTH 1 SUPERVISOR Ratliff I Castleman FIELD NAME J RiG PHONE I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Drill casin shoe. OPERATION COMMENTS POOH. Test BOPE. BHA. RIH. Displaced to new mud. 06:00 10:30 4.50 9,941 9,941 AF DRLPR TRIP POOH. 10:30 11:00 0.50 9,941 9,941 AF DRLPR TRIP UD Accelerator, Jars, bumper sub, and FJD tool. 11:00 17:30 6.50 9,941 9,941 AF DRLPR TEST Pull Wearbushing. Test Annular and VBR on 4" and 5-1/2". Test blind rams, Btm Pipe Rams, choke manifold, Top Drive IBOP, Top Drive manual TIW, TIWs (4" and 5-1/2") and IBOPs (4" and 5-1/2") to 250 low and 3500 psi high for 5 minutes each. Reset Wear bushing. 17:30 19:30 2.00 9,941 9,941 AF DRLPR TRIP PIU Directional BHA. 19:30 20:00 0.50 9,941 9,941 AF DRLPR MwdLwd Test MWD tool. 20:00 20:30 0.50 9,941 9,941 AF DRLPR TRIP Finish PIU Directional BHA 20:30 21:30 1.00 9,941 9,941 AF DRLPR TRIP RIH wI 4" Drill Pipe to 1794'. 21:30 22:00 0.50 9,941 9,941 AF DRLPR EQUIP Change handling equipment from 4" to 5-1/2". 22:00 02:30 4.50 9,941 9,941 AF DRLPR TRIP Con't TIH 9895'. 02:30 06:00 3.50 9,941 9,941 AF DRLPR CIRC Displace well with 9.2 ppg Flo-Pro Drilling Fluid. 22 1 BHA DESCRIPTION o I Mill tooth Bit, Mud Motor w/1deg bent sub, Non-Mag Welded Blade Stabilizer, Non-Mag Pony Collar, Non-Mag CSDP wI MWD , Pulser Sub, Non-Mag CSDP (3), Drilling Jar, Cross Over, Heavy Weight Drill Pipe (5), 4" Drill Pipe (45), Cross Over Printed: 4/8/2004 3:42:48 PM Nabors Alaska Drilling Drilling Contractor 26 339.00 Baker Hughes Inteq MWD I Directional Driller 4 48.00 Marathon Drilling Supervision 2 48.00 R&K Industrial Vacuum Trucks 6 72.00 Epoch Well Services Mud Logging 2 24.00 Peak Vacuum Trucks 2 24.00 M-I Drilling Fluids Mud Engineering 2 24.00 Pollard Wireline Hot Oil Truck 2 12.00 Baker Oil Tools Formation Junction 1 6.00 S&R Enterprises Septic service 1 3.00 20.000 13.375 7.000 18.730 12.415 6.184 18.57 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) (psi) @ 10.30 (ppg) 130 2,860 9,941 130 2,368 5,198 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:48 PM SUPERVISOR Ratliff I Ro er 30.6 RIG NAME & NO. Nabors 273E riel n a.IAI.U~ .·............I"',..I..~ RIG PHONE 907-260-6935 COUNTY/OTHER 24 HR PROG TMD 482.0 10,422 AUTH MD 17,300 MOC'"'' 1,n.1 ¡CUM n&.!...L......_ __ 100.0000 LI:Jo\I'\.vrr 16.01 FIT test to 16.0 ppg EMW. Rotary I Slide drill from 9,970' to 10,422'. 06:00 06:30 0.50 9,940 9,940 AF DRLPR CIRC 06:30 08:00 1.50 9,940 9,970 AF DRLPR DRILL 08:00 09:00 1.00 9,970 9,970 AF DRLPR CIRC 09:00 10:00 1.00 9,970 9,970 AF DRLPR TEST 10:00 21 :00 11.00 9,970 10,422 AF DRLPR DRILL 21:00 22:00 1.00 10,422 10,422 AF DRLPR TRIP 22:00 22:30 0.50 10,422 10,422 AF DRLPR TRIP 22:30 03:00 4.50 10,422 10,422 AF DRLPR TRIP 03:00 04:00 1.00 10,422 10,422 AF DRLPR TRIP 04:00 06:00 2.00 10,422 10,422 AF DRLPR TRIP Finish displacing well over to fresh 9.2 ppg FIe-Pro mud system. Circulate and Condition Mud. Tag top of casing shoe at 9,940' DPM. (9,937' casing strap). Orient and drill out shoe, slide drill from 9,940' to 9,970' at high side orientation. Pull back into casing for shoe test. CBU at 300 gpm @ 1400 psi. Performed Formation Integrity Test (FIT) to 1,920 psi wI 8.9 ppg mud for EMW of 16.0 ppg shoe test. Monitored bleed off - fell to 1,780 psi on 5 minutes. Slide and rotary drill 6" directional hole from 9,970' to 10,422' wI rock bit. Monitoring MWD survey interference wI other leg of junction. Approx seperation from other leg 15'. Not getting anticipated turn rate wI rock bit. Actual daily totals: AST = 4.3 hrs @ 204'. ART = 4.1 hrs @ 281'. Total hrs on mill tooth rock bit 8.4 hrs drilling. Trip out for PDC bit. Backream from 10,422' - 10,013'. Back wash from 10,013' to 9,888' (above junction). Flow check well, pump slug and blow topdrive dry. TOH for PDC bit. BHA handling. Remove 6" STX-1 rock bit and replace wI Hughes HCR 405 PDC bit. Recheck alignment of motor to MWD - O.K. TIH wI directional drilling assembly and 6" PDC bit. Function tested MWD pulser - O.K QENSITY(ppg) FV~ PYNP 95 15/34 9.00 GELs 12/16 t;Kto'M Printed: 4/8/2004 3:42:51 PM 7/1 8/1 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,893 (psi) @ 9.00 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:51 PM KB WELL NAME KASILOF SOUTH 1 SUPERVISOR Ratliff I Ro er 30.6 RIG NAME & NO. Nabors 273E FiELD NÃME KiG t'HONt: WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Drillin ahead at 11,631 OPERATION COMMENTS TIH, wash from 10,302' to bottom at 10,422'. Directional drill 6" hole from 10,422' to 11,631' 06:00 08:00 2.00 10,422 10,422 AF DRLPR TRIP 08:00 09:00 1.00 10,422 10,422 AF DRLPR RIG 09:00 11:00 2.00 10,422 10,422 AF DRLPR TRIP 11:00 06:00 19.00 10,422 11,631 AF DRLPR DRILL TIH to 7,580'. Service Rig and Topdrive Finish TIH to 10,302'. Safety wash in hole from 10,302' to bottom at 10,422'. Rotary and slide drill 6" directional hole, as per directional plan. Turn to Azim of 270 deg and drop and hold angle at - 64.5 deg. Drill from 10,422' to 11,631'. ... Surveys from 9,928' to 10,333' have the azimuth interpolated due to MWD magnetic interference wI Lateral #1. ART = 7.0 hrs for 931', AST = 5.2 hrs for 278'. Printed: 4/8/2004 3:42:53 PM . . 1.« ,., . ",··..C , C ····'··C' ;e , .<; ......' ..'.,...,. '. .. .""" e ,e< ,.'...' e</ .« .... ie"~, ,'.. , ·Ji: ;. ,.... .... ...... / ,. ..'.. ... ".."". ',,' .. ,.",'" .,.,..', ',,',." '".'.,'.' ,',.,'.,. ,,',,'.'" " WELL NAME KB IGL 24 HR PROGTMD ITVD IDFS DOL IRPT# I DATE KASILOF SOUTH 1 30.6 74.00 1,209.0 11,631 5,848 86 86 86 09-Jan-2004 ... ..'.. , ". " ....'y·,<c·· ,.,., .... .. ',. . I.!.I,~¡T$ I units AVG. CONN: I AVG. TRIP: 11 I AVG. BKGRD: . I MAX. CONN: MAX. TRIP: MAX. DRL: 251 _·...tIk., _.,.<c...........·...'., .,..y ....,., .·.···ie . "¡¡,B,.'. i"I."ryl:.l.'v",,' 9,904.0 66.47 291.07 5,181.74 0.00 3,391.59 -6,813.10 0.00 10,606.0 68.92 277.55 5,419.17 7,447.45 3,568.90 -7,447.45 2.03 9,928.0 67.22 291.07 5,191.18 6,833.69 3,399.52 -6,833.69 3.13 1 0,704.0 68.07 273.66 5,455.11 7,538.17 3,577.81 -7,538.17 3.79 10,004.0 70.93 291.07 5,218.32 6,899.92 3,425.04 -6,899.92 4.88 10,799.0 66.99 271.37 5,491.42 7,625.86 3,581.67 -7,625.86 2.50 10,048.0 71.81 290.00 5,232.37 6,938.97 3,439.66 -6,938.97 3.05 10,893.0 65.48 269.82 5,529.30 7,711.88 3,582.57 -7,711.88 2.20 10,097.0 72.25 289.00 5,247.49 6,982.90 3,455.22 -6,982.90 2.14 10,989.0 65.26 269.44 5,569.31 7,799.14 3,582.01 -7,799.14 0.43 10,160.0 71.28 287.90 5,267.20 7,039.66 3,474.16 -7,039.66 2.26 11,083.0 64.26 268.70 5,609.39 7,884.16 3,580.63 -7,884.16 1.28 10,193.0 71.64 287.25 5,277.70 7,069.49 3,483.61 -7,069.49 2.16 11,179.0 64.45 268.54 5,650.94 7,970.67 3,578.54 -7,970.67 0.25 10,252.0 70.82 286.10 5,296.68 7,123.00 3,499.64 -7,123.00 2.31 11,275.0 63.94 267.44 5,692.73 8,057.05 3,575.51 -8,057.05 1.16 10,287.0 70.85 285.30 5,308.17 7,154.82 3,508.58 -7,154.82 2.16 11,372.0 64.39 266.04 5,735.00 8,144.21 3,570.55 -8,144.21 1.38 10,333.0 70.32 284.50 5,323.46 7,196.75 3,519.74 .7,196.75 2.00 11,465.0 64.77 265.90 5,774.92 8,227.99 3,564.64 -8,227.99 0.43 10,414.0 69.88 283.02 5,351.03 7,270.72 3.537.85 -7,270.72 1.80 11,559.0 63.67 266.60 5,815.81 8,312.46 3,559.11 -8,312.46 1.35 10,509.0 69.04 279.66 5,384.37 7,357.93 3,555.35 -7,357.93 3.43 Nabors Alaska Drilling Drilling Contractor 26 339.00 M-I Drilling Fluids Mud Engineering 2 24.00 Marathon Drilling Supervision 2 48.00 Baker Hughes Inteq MWD / Directional Driller 3 36.00 Epoch Well Services Mud Logging 2 24.00 R&K Industrial Vacuum Trucks 2 24.00 IC·"'.·.·..·.,.c "'.. 2' ..... "",c, ...,.."..... C¡/ii,< ",,""h ~;,.·N}".·',··.. "./.c,·c.,".'··,·c.',;'·;;"·. c·· ......". i.',. :i.,cc·"C;" LAST BOP TEST: 1/6/2004 LAST CASING TEST: 11113/2003 NEXT BOP TEST: 111312004 œi2iL ~- ./,~~~-~- 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.01 1,839 (psi) @ 9.20 (ppg) 9,937 5,195 29.00 L-80 5,750 Printed: 4/8/2004 3:42:53 PM WELL NAME KASILOF SOUTH 1 SUPERVISOR Ratliff I Ro er 30.6 RIG NAME & NO. Nabors 273E TVD 6,437 WBS RPT# DATE 87 10-Jan-2004 SAPIWBS COST FiELD NAME RiG t'HON!: 12,910 AUTH MD 17,300 MOCWI 100.0000 NRI i CUM WELL COST 907-260-6935 COUNTY/OTHER LEAKOFf 16.01 06:00 11:30 5.50 11,631 12,111 AF DRLPR DRILL Drill 6" directional hole per directional plan from 11,631' to 12,111'. 11:30 13:30 2.00 12,111 12,111 AF DRLPR CIRC Circulate hole clean for wiper trip @ 310 gpm, 2750 psi while rotating 120 rpm and working pipe. 13:30 15:30 2.00 12,111 12,111 AF DRLPR TRIP Wiper trip from 12,111' to casing shoe. Hole in good condition. Max overpull 40k. No excess drag thru formation junction. TO to 9,814'. Monitor and secure well. 15:30 18:30 3.00 12,111 12,111 AF DRLPR RIG Service Rig, change out top drive wash pipe, service top drive and change out trip tank flowline valve. 18:30 20:30 2.00 12,111 12,111 AF DRLPR TRIP Wiper Trip, TBIH to bottom at 12,111'. Safety washed the last- 150'. Max WOB while TIH 50k. Wiped various tight spots clean. No fill on bottom. Wiper trip gas 135 units. 20:30 06:00 9.50 12,111 12,910 AF DRLPR DRILL Drill 6" directional hole from 12,111' to 12,910' (TVD = 6437') as per directional plan. Daily AST = 2.0 hrs for 115' Daily ART = 7.8 hrs for 1,164' Daily total drill time 9.8 hrs for 1,279' Printed: 4/8/2004 3:42:54 PM . . I ... . . . . , " ... . . . .~ . -~..... . -'. ... WELL NAME IKB IGL 24HRPROGITMD ITVD DFS IDOL [RPT# DATE KASILOF SOUTH 1 30.6 74.00 1,279.0 12,910 6,437 87 87 87 10-Jan-2004 ~ ~ .. . It;t-t-w; i I-';L;r.. UJ-' 23 I 8,203.66 I 8,000 I 220,000 I 115,000 I 160,000 9,500 I 8,500 I BHA DESCRIPTION PDC Bit HeR 405 , Mud Motor w/1 deg bent sub, Non-Mag Welded Blade Stabilizer, Non-Mag Pony Collar, Non-Mag CSDP w/ MWD , Pulser Sub, Non-Mag CSDP (3), Drilling Jar, Cross Over, Heavy Weight Drill Pipe (5), 4" Drill Pipe (246), Cross Over ~ I NO. I .. c' 2 I NATIONAL I 12.000 6.000 74 309.77 2,800 309.77 30 950 I . . ...... "..,... . . : . .. .<','.. .... ,r:. <UNI.::> I units AVG. CONN: AVG. TRIP: 135 I AVG. BKGRD: 10 MAX. CONN: MAX. TRIP: MAX. DRL: 133 11,654.0 63.63 266.68 5,857.97 8,397.44 3,554.12 -8,397.44 0.09 12,326.0 62.92 270.61 6,159.54 8,997.39 3,531.70 -8,997.39 0.75 11,750.0 63.35 266.58 5,900.82 8,483.20 3,549.07 -8,483.20 0.31 12,421.0 62.61 270.41 6,203.02 9,081.85 3,532.45 -9,081.85 0.38 11,848.0 63.34 265.97 5,944.79 8,570.60 3,543.38 -8,570.60 0.56 12,518.0 62.30 270.70 6,247.87 9,167.85 3,533.28 -9,167.85 0.42 11,943.0 63.64 267.70 5,987.19 8,655.47 3,538.68 -8,655.47 1.66 12,614.0 62.09 270.00 6,292.66 9,252.76 3,533.80 -9,252.76 0.68 12,039.0 63.09 268.52 6,030.23 8,741.24 3,535.85 -8,741.24 0.95 12,709.0 61.35 270.32 6,337.66 9,336.42 3,534.03 -9,336.42 0.83 12,135.0 63.58 267.83 6,073.31 8,826.98 3,533.12 -8,826.98 0.82 12,802.0 60.62 269.92 6,382.77 9,417.75 3,534.20 -9,417.75 0.87 12,230.0 63.08 269.82 6,115.96 8,911.85 3,531.38 -8,911.85 1.94 Nabors Alaska Drilling Drilling Contractor 26 339.00 Baker Hughes Inteq MWD I Directional Driller 4 48.00 Marathon Drilling Supervision 2 48.00 R&K Industrial Vacuum Trucks 2 24.00 Epoch Well Services Mud Logging 4 48.00 Oilfield Hot Shot Service 1 2.00 M-I Drilling Fluids Mud Engineering 2 24.00 S&R Enterprises 1 2.00 .< .. '. .:.; <: ':. ". . .. '. . . . . . . . ." ,.' ..:.' ,.. ....... LAST BOP TEST: 1/6/2004 LAST CASING TEST: 11113/2003 NEXT BOP TEST: 1/1312004 ~ ~,~ '.u ~ ,. . 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.01 1,839 (psi) @ 9.20 (ppg) 9,937 5,195 29.00 L-80 5,750 Printed: 4/8/2004 3:42:54 PM · WELL NAME KASILOF SOUTH 1 SUPERVISOR Ratliff I Ro er FIELD NAME 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 1,040.0 13,950 AUTH MD 17 ,300 MaC WI 100.0000 NRI CUM WELL C051 RIG PHONE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin ahead at 13,950' OPERATION COMMENTS Drilled 6" directional hole from 12,910' to 13,922'. 907-260-6935 COUNTY/OTHER LI::Ar\urr 16.01 er Ian. Circulate well clean. Wiper trip from 13,922' to 12,015'. TBIH. Drill from 13,922' to 13,950'. 06:00 23:00 17.00 23:00 02:30 3.50 12,910 13,922 13,922 AF 13,922 AF DRLPR DRILL DRLPR CIRC 05:30 06:00 0.50 13,922 13,950 AF DRLPR DRILL Drill 6" directional hole from 12,910' to 13,922' . Circulate hole clean for wiper trip @ 300 gpm, 2800 psi. while rotating 125 rpm, and working pipe. Flow check - O.K. Wiper trip from 13,922' to 12,015'. Had 50k overpulls at 13234-203', 12912', 12612', 12377', 12340', 12300'. Work thru same and wiped clean. At 12,015' flow checked - O.K. TBIH to 13,828' - hole slick. Washed I reamed the last stand down. Tight hole from 13,870' to TD at 13,922'. Drill 6" directional hole from 13,922' to 13,950' (6,939' TVD). 02:30 05:30 3.00 13,922 13,922 AF DRLPR TRIP Daily AST = 5.1 hrs for 186'. Daily ART = 8.2 hrs for 854'. Daily total drill time 13.3 hrs for 1040'. Printed: 4/8/2004 3:42:56 PM 12,899.0 61.73 269.97 6,429.54 9,502.73 3,534.12 -9,502.73 1.15 13,470.0 61.68 269.54 6,695.49 10,007.9 3,526.86 -10,007.9 0.92 12,992.0 62.37 269.73 6,473.13 9,584.88 3,533.91 -9,584.88 0.72 13,565.0 60.84 269.44 6,741.17 10,091.2 3,526.12 -10,091.2 0.89 13,088.0 61.20 269.36 6,518.51 9,669.47 3,533.24 -9,669.47 1.27 13,660.0 60.16 270.30 6,787.95 10,173.8 3,525.93 -10,173.8 1.06 13,185.0 62.09 268.37 6,564.58 9,754.81 3,531.54 -9,754.81 1.28 13,754.0 58.77 270.83 6,835.71 10,254.8 3,526.72 -10,254.8 1.56 13,280.0 63.63 268.79 6,607.92 9,839.33 3,529.45 -9,839.33 1.67 13,852.0 58.30 272.29 6,886.86 10,338.4 3,529.00 -10,338.4 1.36 13,376.0 62.44 269.08 6,651.45 9,924.87 3,527.86 -9,924.87 1.27 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,758 (psi) @ 9.50 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:42:56 PM WELL NAME KASILOF SOUTH 1 SUPERVISOR Ratliff I Ro er 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 1,110.0 15,060 AUTH MD 17,300 Mac WI MR.! 100.0000 DX0309030CAPDRL i CAlLY WELL COST CüM WELL COST FIELD NAME RIG FHONE 907-260-6935 COUNTY/OTHER 16.01 06:00 06:00 24.00 13,950 15,060 AF DRLPR DRILL Rotate and slide drill 6" directional hole from 13,950' to 15,060' Daily AST = 6.6 hrs for 184' Daily ART = 8.5 hrs for 926' Daily ADT = 15.1 hrs for 1,110'. units 5 171 0.01 Printed: 4/8/2004 3:42:59 PM 1/13/2004 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.01 1,731 (psi) @ 9.60 (ppg) 9,937 5,195 29.00 L-80 5,750 Printed: 4/8/2004 3:42:59 PM WELL NAME KASILOF SOUTH 1 SUPERVISOR Ratliff I Ro er FIELD NAME 30.6 RIG NAME & NO. Nabors 273E RIG PHONE WILDCAT-FOR UNNAMED FIELD 907-260-6935 STAT~PROV COUNTY/OTHER Alaska CURRENTSTATUS/MTS RID test e ui ment - RlU for BHA OPERATION COMMENTS Drill from 15,060' to 15,125'. Circulate hole clean. 24 HR PROG TMD 65.0 15,125 AUTH MD 17,300 MOC Wi NRi 100.0000 ¡CUM WELL COST 16.01 06:00 08:30 2.50 DRLPR DRILL 15,060 15,125 AF 08:30 12:30 4.00 15,125 15,125 AF DRLPR CIRC 12:30 22:30 10.00 15,125 15,125 AF DRLPR TRIP 22:30 01:00 2.50 15,125 15,125 AF DRLPR TRIP 01:00 06:00 5.00 15,125 15,125 AF DRLPR TEST 8/1 BHA NO. 23 Rotary and slide drill 6" directional hole from 15,060' to 15,125'. Slower than expected ROP and difficulty slide drilling. Will trip for fresh MWD, motor and bit since BOP test is due. Daily ART = 1.6 hrs for 65'. Daily AST = 0 hrs. Circulate hole clean w/310 gpm, 2750 psi while rotating 120 rpm and working pipe. Flow check well and pumped slug. TOOH from 15,125' OH in good condition. No difficulty pulling into casing or thru formation junction. (Pressure tested the choke manifold to 250 I 3500 psi during the trip out). RIB 4" HWDP and flex De's. UD MWD, motor and bit. BOP testing operations. M/U 4" test jt assembly and UD same M/U 5-1/2" testjt assembly. Pulled wearbushing and installed the test plug on the 5-1/2" test joint. Tested rams and annular and C&K lines to 250 13,500 psi on 5-1/2" and 4" DP. Tested Blinds to 250 I 3,500 psi. Reset the wearbushing. Performed Koomey unit test. BOP tests witnessed by Lou Grimaldi wI AOGCC. Printed: 4/8/2004 3:43:04 PM Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Drilling Contractor Drilling Supervision Mud Logging Mud Engineering 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,731 (psi) @ 9.60 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:43:04 PM · FiELD NÂME 24 HR PROG TMD 30.6 315.0 15,440 RIG NAME & NO. AUTH MD Nabors 273E 17,300 RiG PHONE MOC WI ' HRI ft. "'W8S COST WELL NAME KASILOF SOUTH 1 SUPERVISOR Ratliff I Ro er ¡CUM WELL CûSï WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS Drillin at 15,440' OPERATION COMMENTS PIU new directional BHA. TIH to 8,300'. directional hole from 15,125' to 15,440'. 907-260-6935 COUNTY/OTHER 100.0000 Lt:An..vr-r 16.01 Cut and slip drill line. TIH to 14,775'. Wash I Ream from 14,775' to hole TD at 15,125'. Drill6" MANHRS WORKED 06:00 06:30 0.50 15,125 15,125 AF DRLPR TEST Finish setting wear bushing. UD 4" test joint and complete RID of test equipment. 06:30 08:30 2.00 15,125 15,125 AF DRLPR TRIP M/U directional BHA wI new MWD, motor and HC407 PDC bit. Upload MWD and orient MWD to motor. 08:30 13:00 4.50 15,125 15,125 AF DRLPR TRIP TIH to 1,500' and function test MWD. Continue TIH to 8,200' filling DP every 25 stands. Change out handling equipment for 5-1/2" DP. Run (1) stand of 5-1/2" DP to - 8,300'. 13:00 14:30 1.50 15,125 15,125 AF DRLPR RIG PJSM. Fill DP. Monitor well. Cut and slip drill line. COM reset and checked. 14:30 19:00 4.50 15,125 15,125 AF DRLPR TRIP TIH from 8,300' to 14,967' filling pipe and breaking circulation every 25 stands. 19:00 20:00 1.00 15,125 15,125 AF DRLPR TRIP Fill pipe and attempt to circulate - hole packing off. Pull (2) stands and re-establish circulation. Wash I ream stand. 20:00 20:30 0.50 15,125 15,125 AF DRLPR TRIP Wash and ream in hole from 14,775' to TD at 15,125'. 20:30 06:00 9.50 15,125 15,440 AF DRLPR DRILL Rotary and slide drill 6" directional hole from 15,125' to 15, 440' (7,890' TVD). Maintain MW at 9.6 ppg and increasing Lubetex to 4% for torque & drag reduction. Daily AST = 2.4 hrs for 97' (40.4' ROP) Daily ART = 3.1 hrs for 218' (70.3' ROP) Daily ADT = 5.5 hrs for 315' (57.3' ROP) 9/1 Printed: 4/8/2004 3:43:06 PM 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,731 (psi) @ 9.60 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:43:06 PM KASILOF SOUTH 1 SUPERVISOR Ratliff I Ro er FIELD NAME 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 585.0 16,025 AUTH MD 17,300 RiG PHONe MOCWI NRI CUM WELL ¡;U" I WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Drillin at 16,025' OPERATION COMMENTS Rotary and slide drill 6" directional hole from 15,440' to 16,025' 100.0000 LEAKQFf 16.01 06:00 06:00 24.00 15,440 16,025 AF DRLPR DRILL Rotary and slide drill 6" directional hole from 15,440' to 16,025' (8360' TVD) (Note: At 15,932' crossed below the original KS #1 wellbore with estimated separation of 123') Daily AST = 3.4 hrs for 60' (17.6' ROP) Daily ART = 13.8 hrs for 525' (38' ROP) Daily ADT = 17.2 hrs for 585' (34' ROP) AVG. CONN: MAX. CONN: AVG. TRIP: MAX. TRIP: units 32 134 Printed: 4/8/2004 3:43:07 PM Nabors Alaska Drilling Drilling Contractor 26 339.00 R&K Industrial Vacuum Trucks 2 24.00 Marathon Drilling Supervision 2 48.00 Lynden Transport 1 2.00 Epoch Well Services Mud Logging 4 48.00 Oilfield Hot Shot Service 1 2.00 M-I Drilling Fluids Mud Engineering 2 24.00 Alaska Oil Sales 1 2.00 Baker Hughes Inteq MWD I Directional Driller 4 48.00 Wildflowers and Resin 2 10.00 LAST BOP TEST: 1/13/2004 LAST CASING TEST: 11/13/2003 20.000 18.730 (psi) @ (ppg) 130 130 133.00 K-55 3,060 13.375 12.415 18.57 1,079 (psi) @ 9.80 (ppg) 2,860 2,368 68.00 K-55 3,450 7.000 6.184 16.01 1,745 (psi) @ 9.55 (ppg) 9,937 5,195 29.00 L-80 5,750 Printed: 4/8/2004 3:43:07 PM 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 680.0 16,705 AUTH MD 17,300 MOC WI 'NRI 100.0000 leUM Wt:LL I..V", FiELD NAME . RiG PHONE WILDCAT-FOR UNNAMED FIELD ST A TElPROV Alaska CURRENT STATUS / MTS Drillin at 16,705' OPERATION COMMENTS Drill 6" hole from 16,025' to 16,300', 907-260-6935 COUNTY/OTHER 16.01 06:00 13:30 7.50 16,025 16,300 AF DRLPR DRILL 13:30 16:00 2.50 16,300 16,300 AF DRLPR CIRC 16:00 18:00 2.00 16,300 16,300 AF DRLPR TRIP 18:00 06:00 12.00 16,300 16,705 AF DRLPR DRILL Rotary drill 6" directional hole from 16,025' to 16,300'. ART = 6.7 hrs for 275' = 41'/hr ROP. Circulate hole clean at 300 gpm, 2,800 psi for 7,400 stks while rotating 120 rpm and working pipe. Flow check well- O.K. Wiper trip from 16,300' to 14,871' and TSIH to 16,300' Safety washed last stand down. Hole in good condition wI no tight spots encountered out or in. Rotary drill 6" directional hole from 16,300' to 16,705' (8920' TVE.1ntf,sed W ï Jff~g while drilling. (Wiper tri~t)I'Ift 0 'rf\~5' = 10.5 'Ihr ROP. Printed: 4/8/2004 3:43:10 PM Nabors Alaska Drilling Drilling Contractor 26 339.00 R&K Industrial Vacuum Trucks 2 24.00 Marathon Drilling Supervision 2 48.00 Alaska Oil Sales 1 2.00 Epoch Well Services Mud Logging 4 48.00 National Oilwell 1 1.00 M-I Drilling Fluids Mud Engineering 2 24.00 Hughes Christensen 2 2.00 Baker Hughes Inteq MWD I Directional Driller 4 48.00 LAST BOP TEST: 1/13/2004 LAST CASI NG TEST: 11/13/2003 NEXT BOP TEST: 130 2,368 5,195 133.00 68.00 29.00 3,060 3,450 5,750 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,677 (psi) @ 9.80 (ppg) 130 2,860 9,937 K-55 K-55 L-80 Printed: 4/8/2004 3:43:10 PM . 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 760.0 17,465 AUTH MD 17,300 MOC ...1 NRI 100.0000 I CUM WELL COST . RiG FHûNE WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Drillin at 17,465'. OPERATION COMMENTS Rotary drill 6" directional hole from 16,705' to 17,465' Lt:Al'\.ur- r- 16.01 . POOH. units 27 555 Printed: 4/8/2004 3:43:12 PM · !VIA Pag€! 2 of 2 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,623 (psi)@ 10.00 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:43:12 PM . . FiELD NAM~ 24 HR PROG TMD 30.6 80.0 17,545 RIG NAME & NO. AUTH MD Nabors 273E 17 ,300 KiG PHONE MOl;; Wi NRi ¡CUM WFil r.n.~:r 907-260-6935 COUNTY/OTHER 100.0000 LEAKOFF 16.01 06:00 10:30 4.50 17,465 17,545 AF DRLPR DRILL Rotary drill 6" directional production hole from 17,465' to planned TD of well 17 ,545' MD (9,642' TVD). ART = 3.4 hours for 80' (21.6 fph ROP) 10:30 14:30 4.00 17,545 17,545 AF DRLPR CIRC Circulate well clean at 300 gpm, 2,800 psi while rotating 120 rpm and working pipe. Noticed pressure decline over time, pressure fell to 1,400 psi. Check out surface equipment. SID circ (suspect washout high in string). 14:30 17:30 3.00 17,545 17,545 TA DRLPR TRIP PIPD Began TOH looking for washout. Found a washout in the body of the 5-1/2" DP joint (slip area) in the 9th stand pulled. UD same. Continue TOH total (15) stands for wiper trip across the new drilled interval to 16,107'. Hole in good condition w/1 Ok drag. TBIH to TD 17,545' without pumps, no fill- hole in good condition. 17:30 19:30 2.00 17 ,545 17 ,545 AF DRLPR CIRC Circulate hole clean and conditon mud to 10.3 ppg. Max gas from the wiper trip 180 units. Flow check well and pump a slug. 19:30 02:00 6.50 17,545 17,545 AF DRLPR TRIP Wiper trip, TOH from TD 17,545' to the 7" casing shoe. Hole in good shape. 02:00 06:00 4.00 17,545 17 ,545 AF DRLPR TRIP TIH from casing shoe to 15,800' filling pipe every 25 stands. 9/1 24 Printed: 4/812004 3:43:13 PM Nabors Alaska Drilling Marathon Epoch Well Services LAST BOP TEST: 1/13/2004 Drilling Contractor Drilling Supervision Mud Logging LAST CASING TEST: 11/13/2003 NEXT BOP TEST: 112012004 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,542 (psi) @ 10.30 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:43:13 PM · 24 HR PROG TMD 30.6 17,545 RIG NAME & NO. AUTH MD Nabors 273E 17,300 FIELD NAME RIG PHONE MOC Vii . NRI ¡CUM ŸwELL CO;,'). WILDCAT-FOR UNNAMED FIELD 907-260-6935 STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Pick u 10 in tools. OPERATION COMMENTS Finish wiper trip. Circulate hole clean. TOOH for logs. BHA. 100.0000 Lr:Þ\n..vrl 16.01 06:00 07:30 1.50 17,545 17,545 AF DRLPR TRIP Finish wiper trip. TIH f/15,800' to 17,545'. Safety washed last 120' to bottom. No fill and trip in went smooth - no tight spots encountered. 07:30 12:00 4.50 17,545 17,545 AF DRLPR CIRC CBU x 2 at 300 gpm, 2,700 psi while rotating 120 rpm and working pipe. Max gas from the wiper trip was 900 units wI 0.2 ppg cut. Gas dropped out quickly. 12:00 19:00 7.00 17,545 17,545 AF DRLPR TRIP Flow check well- O.K. Pump slug and TOOH from 17,545' for DP conveyed logs. PIU wt off bottom 370,000 Ibs. Open hole i good condition with no tight spots encountered. No problems entering the 7" casing shoe or pulling thru the formation junction TOOH wet to 4", change out handling tools and clean floor. 19:00 20:30 1.50 17,545 17,545 TA DRLPR RIG RGDT CDT: Rig Repair, Contractor owned - (2) generators went off line. Troubleshoot and discovered that #1 generator was not properly sharing the loadproperly - overs peed problem. Isolated #1 generator. 20:30 02:00 5.50 17,545 17,545 AF DRLPR TRIP Continue TOOH for DP conveyed logs. 02:00 05:00 3.00 17,545 17 ,545 AF DRLPR TRIP Stand back HWDP, clean floor and de-ice floor, and LD directional BHA. 05:00 06:00 1.00 17,545 17,545 AF EVALPR TRIP PJSM. PU 6 joints 3 1/2" DP and Reeve's logging tools. CUM ROP 38.17 BHA NO. 24 Printed: 4/8/2004 3:43:15 PM · 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1.079 (psi) @ 9.80 (ppg) 1,542 (psi) @ 10.30 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:43:15 PM 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,545 AUTH MD 17,300 MOl; Wi NRi 100.0000 I CUM WELL COST FiELD NAME RIG PHONE 907-260-6935 COUNTY/OTHER 16.01 11,000'. Finish picking up Reeves drill pipe conveyed memory logging tools. 08:00 13:30 5.50 17,545 17,545 AF EVALPR LOG TIH with 4" DP to 7800', filling pipe every 25 stds. 13:30 14:00 0.50 17,545 17,545 AF EV ALPR LOG Change handling tools to 5 1/2". 14:00 19:30 5.50 17,545 17,545 AF EV ALPR LOG Continue TIH with 5 1/2" drill pipe to 17,400', filling pipe every 2 stds. Hole in good condition. No problem thru formation junction. 19:30 20:30 1.00 17,545 17,545 AF EV ALPR LOG Wash from 17,400' to 17,545'. No fill. Rotating 30 rpm. 20:30 22:30 2.00 17,545 17,545 AF EV ALPR LOG Circulate bottoms up, 55 spm, 2100 psi. Max trip gas 180 units, max mud cut 10.3 ppg to 10.1 ppg. Gas dropped out quickly. 22:30 23:30 1.00 17,545 17,545 AF EV ALPR LOG PU to reamer shoe depth of 17,422', drop and pump down dart to deploy logging tools and open circulating ports. 23:30 00:00 0.50 17,545 17,545 AF EV ALPR LOG Check for flow, pump slug and blow down the topdrive. 00:00 06:00 6.00 17,545 17,545 AF EV ALPR LOG POOH logging open hole from - 17,500' MD at 30 fpm. Current depth 11,000' @ 06:00 hrs. Hole in great shape - no tight spots encountered. I 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 1 NATIONAL 2 NATIONAL 3 NATIONAL 12.000 12.000 12.000 6.000 1,900 237.50 237.50 237.50 30 30 800 800 Printed: 4/8/2004 3:43:17 PM G:QN!RAI¡fY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Hughes Inteq R&K Industrial Drilling Contractor Drilling Supervision Mud Logging Mud Engineering MWD I Directional Driller Vacuum Trucks 23 330.00 Reeves Wireline 2 48.00 Lynden Transport 2 24.00 Weaver Brothers (WBI) 2 24.00 Hughes Christensen 4 24.00 Wildflowers and Resin 1 8.00 3 2 1 1 2 72.00 8.00 2.00 1.00 8.00 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,542 (psi) @ 10.30 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 Printed: 4/8/2004 3:43:17 PM . . ;<tJ~- rXsç Kasilof South 1 RD 1 Rig Completion (Reports 98A -102) 30.6 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17 ,545 AUTH MD 17,300 - .....",,'Qq ~QST DX0309030CAPDRL RiG PHûNE MOCv'"'¡¡ NRi I ûAiL Y WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD STATEJPROV Alaska CURRENT STATUS / MTS End of Drillin Phase - Swtiched to Com letion Re ort. OPERATION COMMENTS Finish from 11,000' to 9,500' wI DP logs. TOOH and UD 10 907-260-6935 COUNTY/OTHER L~n...vr.-- 16.01 12:30 14:30 2.00 17,545 17,545 AF EV ALPR LOG TOOH wI DP conveyed memory logging tools - continue to log OH @ 30 fpm from 11,000' to the 7" shoe at 9,940'. Logged up to - 9,500' in casing for tie-in. TOOH at normal rates from 9,500' to surface. No tights spots in OH or problems pulling thru formation junction. UD the 3-1/2" DP and the Reeves logging tools. Confirmed that log data was recorded. RID logging equipment and clean rig floor. 06:00 12:30 6.50 17,545 17,545 AF EV ALPR LOG ... End of the drilling phase, 14:30 hrs on 1/20/04. Final drilling report. COMMENTS Steven Lambe received verbal approval from Winton Hebert wI AOGCC for 7 day BOP test extension. Now due on the 27th. 25 BHA DESCRIPTION o I Reamer Bit, LandinglCirc 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 units Nabors Alaska Drilling Marathon Epoch Well Services Drilling Contractor Drilling Supervision Mud Logging 14 119.00 M-I Drilling Fluids 2 17.00 Veco Alaska 1 8.00 Reeves Wireline Mud Engineering Vacuum Trucks 1 1 3 8.00 8.00 24.00 Printed: 4/8/2004 3:43:21 PM LAST BOP TEST: 1/13/2004 LAST CASING TEST: 11/13/2003 NEXT BOP TEST: 112012004 SIZE in 20.000 13.375 7.000 18.730 12.415 6.184 18.57 16.01 (psi) @ (ppg) 1,079 (psi) @ 9.80 (ppg) 1,542 (psi) @ 10.30 (ppg) 130 2,860 9,937 130 2,368 5,195 133.00 68.00 29.00 K-55 K-55 L-80 3,060 3,450 5,750 CONfiDENT'Al Printed: 4/8/2004 3:43:21 PM · C>lI...GC)MPJ.\N¥ > DäilY·..G~tI1pl~tionR.êpørt EXP!P¡~~~¡91"!··~Ga$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL [RPT# [DATE KASILOF SOUTH 1 30.6 74.00 17,618 9,700 64 98 98B 21-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Castleman /Trubv Nabors 273E DX0309030CAPCMP01 '- FIELD NAME RIG PHONE MOCWI NRI IDAll yw"" ,......."'... !CUMWO:" rnlli:T WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 [ STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 7.000 (in) @ 10,533 (ft) 3.500 (in) @ 17,618 (ft) 16.11 CURRENT STATUS / MTS 24 HR FORECAST Runnino 3 1/2" liner Run and cement 3 1/2" liner OPERATION COMMENTS RU and run 3 1/2" liner. SAFETYSWMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 317.00 None 12/16/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Running and picking up liner. -- .y. - I.FBÞM TO HRS .·f;ßÞM T9 eHÂ$1; ,.. ."..";;'''' 14:30 16:30 2.00 17,545 17,545 AF CSGPRC EQUIP Change out elevators, bails and adjust link-tilt. 16:30 17:30 1.00 17,545 17,545 AF CSGPRC EQUIP Pick up and make up cement head on one joint of 5 1/2" DP. 17:30 19:00 1.50 17,545 17,545 AF CSGPRC EQUIP RU casing tools and PU machine 19:00 00:00 5.00 17,545 17,545 AF CSGPRC CSG PJSM. Run 2700' of 3 1/2", 9.3 ppf, L-80, Hyd 563 liner. Made up to 6400 ft-Ibs with Torque-Turn. Fill pipe every 10 joints. 00:00 06:00 6.00 17,545 17,545 AF CSGPRC CSG PJSM with drill crew and casing crew coming on tour. Run 3 1/2",9.3 ppf, L-80, Hyd 563 liner. Fill pipe every 10 joints. 6,140' run out of 7,556'. ";v'~' .1 10.35 ~I lI::«ql I'M~~ ---~ GELS 1.0/10.00~ .......... /7.5 8.6010.1 0.1/2.31 CIIC"I;~J§RRM 56 11128 11/14 5.81 1 25,000 140 I 1 I .··.·IIIIUO·GAS I .\Jf\lIJ:;§}\ /1 units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: NO~·[)Am'Ä PC>I3@1 ~9::YS!¡<f<. COMPANY SERVICE \jQ; HQgRS Nabors Alaska Drilling 12 167.00 S&R Enterprises 1 8.00 Marathon 3 54.00 Veco 2 8.00 Epoch Well Services 2 16.00 Weatherford 6 48.00 M-I Drilling Fluids 2 16.00 CASINGSWMMARY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/2212003 SizE (in) I IDliri\ISHOETSST(ppg)1 MAXSICP J MD(ft) I JVP(ft) I "NT (lb(ft) 1 GRAPE ...liBIJ KS.... (ps i) 7.000 I 6.184 1 16.11 1 1,972 (psi) @ 9.10 (ppg) 1 10,533 I 5,417 I 29.00 1 L-80 1 8,160 Printed: 4/29/2004 4:04:46 PM WELL NAME KASILOF SOUTH 1 SUPERVISOR Castleman ITrub FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS / MTS POOH OPERATION COMMENTS Finish running 3 1/2" liner. C&C hole. . MARATHON OIL COMPANY Daily Completion Exploitation - KB 30.6 RIG NAME & NO. Nabors 273E RIG PHONE 907-260-6935 COUNTY/OTHER TVD 17,618 9,700 AUTH MD WBS RPT# DATE 99 22-Jan-2004 SAPIWBS COST MOC WI NRI 100.0000 CUM WELL COST LEAKO~~ Mix and pump 675 sx cement. Set ZXP packer, CBU and POOH. olish PBR MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 607.00 None 12/16/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pressure testing and cementing 08:30 09:00 0.50 17,545 17,545 AF 09:00 10:00 1.00 17,545 17,545 AF 10:00 11:00 1.00 17,545 17,545 AF 11:00 19:00 8.00 17,545 17,545 AF 19:00 20:00 1.00 17,545 17,545 AF 20:00 23:00 3.00 17,545 17,545 AF 23:00 00:30 1.50 17,545 17,545 AF 00:30 01 :30 1.00 17,545 17,545 AF 01 :30 02:30 1.00 17,545 17,545 AF CSGPR CIRC CSGPR CEMT CSGPR CEMT LAST STOP CARD AUDIT REGULATORY INSP? 12/17/2003 N LAST RIG INSPECTION 12/11/2003 Finish running 231 joints, 7555', of 3 1/2", L-80, 9.3 ppf, Hyd 56 liner. Make up to 6400 ft-Ibs with Torque Turn. RD LD machine and remove from catwalk, RU floor to run DP. PU Baker Flex Lock HGR,ZXP-Packer and one joint of 4". Fill liner and establish circulating rate. 20 spm - 600 psi, 30 sp - 950 psi. TIH with 3 1/2" liner on 5 1/2" drill pipe to 17,470'. Hole in good condition. Fill drill pipe and break circulation. 20 spm - 1200 psi, 30 spm- 1500 psi. PU - 260K, SO - 130K, ROT - 180K. 18 rpm at 18,000 ft-Ibs. Stop pump and slack off and tag no go at 9939'. PU 18' and install cement head and drop ball. Pumpdown ball at 3 bpm - 1500 psi. Wash down to l' above NoGo. Rot - 175K, 10 rpm at 18,500 ft-Ibs. 20 bbls prior to landing ball stop rotation and land on NoGo with 30K. Set ball and pressure up to 2600 psi to release hanger. PU to confirm released from hanger. Set back down and pressure up to 3300 psi to blow bal seat. Estabilish circualtion and work rate up to 60 spm at 3500 psi. Rotate liner at 17 rpm at 14,500 ft-Ibs. After one hour lost ability to rotate at the same time as started to lose partial returns. Reduce rate to 40 spm and 2500 psi. Returns gradual started t improve. Estimated losses of 86 bbls. Returns improving with lower pump rate Held cementing PJSM during pre-tour meeting with drill crew. B pumped 5 bbls water and tested lines to 4500 psi. Mix and pump 675 sx Class "G" + 2%KCI + 22% LW-6 + 5% MPA-1 + .9% BA-10 + .15% A-2 + .6% CD-32 + .45% R-3 + 19hs FP-6L mixed to 12.7 ppg. Yield 1.789 cf/sx. Release dart and displace cement with 70 bbls of 6% KCI with 2 ppb of Flo-Vis followed by 208.4 bbls mud. Displaced at 60 sp Printed: 4/29/2004 4:04:47 PM MJ.\RJ.\illHONOILGOMRJ.\NY Page2o.f2 DailYiCom pl¢tiQtlRø.pc:>rt l5~pl()itatiø"· "Gas WELL NAME IKB [GL 24 HR PROGITMD ITVD IDFS IDOL !RPT# I DATE KASILOF SOUTH 1 30.6 74.00 17,618 9,700 65 99 99 22-Jan-2004 OPERATIONS SUMMARY FROM TO HRS FROM TO SUB PHASE OP TRBL DESCRIÞTlöN 01:30 02:30 1.00 17,545 17,545 AF CSGPRC CEMT and 3400 psi. Bumped plug with 1000 psi over displacement pressure. CIP at 0215 hrs 1/22/2004. Full returns during cement job. Check floats - OK. 02:30 03:00 0.50 17,545 17,545 AF CSGPRC PKRPLG PU to extend setting dogs, set down on ZXP with 60,000 Ibs to set packer. Put 500 psi on drill pipe and PU until pressure bled off. 03:00 04:00 1.00 17,545 17,545 AF CSGPRC CIRC Circulate 1.5 times BU, no indication of cement. Circulate at 90 spm and 800 psi while reciprocating pipe across diverter and junction. 04:00 04:30 0.50 17,545 17,545 AF CSGPRC FLUID Spot 20 bbl pill of6% KCI with 2 ppb of Flo-Vis and retarder across top of liner and diverter. 04:30 05:30 1.00 17,545 17 ,545 AF CSGPRC EQUIP Break and LD cement head, monitor hole for 15 minutes for flow. 05:30 06:00 0.50 17,545 17,545 AF CSGPRC TRIP POOH with liner running tool. .....,.·,...."'WI'!:I1 1 0.35 ppi .IFCOI I~ål.·""''' ,';1,"""'1 10 Is t:'I.MF··I·.~RPM- Fvi .p~¡f;fþ. GEL$i V'(L!ØTHP ·1 FCIT¡~QL . 9f'!1 iPÞ(PNlIPf/Mfi <:!!(Ç:¡¡ ....c:aCI~I:i~$i 23,000 /60 . . 53 11/23 8/13 6.01 I 2.0/10.0 I 18.0 9.0010.6 0.814.0 I PU 'I" ""J\T^ Ln ·NÓ¡ J MAK6QFP!..IMP ((ih SPM ·.··Q(gÞm); I 1 NATIONAL I 12.000 6.000 60 259.10 3,500 259.10 MUÐGAS /ºNiJ;~ units AVG. CONN: I AVG. TRIP: 135 I AVG. BKGRD: 10 MAX. CONN: MAX. TRIP: MAX. DRL: 25 .è~NBI; ... iN(;J.URS Nabors Alaska Drilling 23 334.00 R&K Industrial 2 20.00 Marathon 3 72.00 Baker Oil Tools 4 72.00 Epoch Well Services 2 24.00 Halliburton 4 48.00 ----_.~-_._- M-I Drilling Fluids 2 24.00 Oilfield Hot Shot Service 1 1.00 Peak Oilfield Service Co. 1 12.00 CASINGSLJMMARY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZElin\ ···..ID(¡rÙ SHOETESJ(pþg: MAXSICP fv1Dlft\ T'lt'D(ft ) WT (lþ/ft). GRADÊ ...,....".....,c c" 7.000 6.184 16.11 1,972 (psi) @ 9.10 (ppg) 10,533 5,417 29.00 L-80 8,160 3.500 2.992 (psi) @ 9.10 (ppg) 17,502 9,603 9.30 L-80 10,160 Printed: 4/29/2004 4:04:47 PM · MÄRÄmæ~N··ioILeøMPÄN¥ jài l.ye>omþlêti ê:)nRØpon: E~plþ.itê¡ltiOI:1···."'iGas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,618 9,700 66 100 100 23-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman ITruby Nabors 273E DX0309030CAPCMP01 J_ FIELD NAME RIG PHONE MOCWI NRI I CA!L Y WELL cosïUM WCLL '"'V". WILDCAT-FOR UNNAMED FIELD 907-260-6935 1 00.0000 I LEAKOFF - STATElPROV COUNTY/OTHER I LAST CASING INEXl _._..,.u Alaska 3.500 (in) (cì) 17,502 (ft) (in) (cì) 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST POOH Finish POOH LD 4" DP. TIH to Dull diverter. OPERATION COMMENTS POOH. BHA. TIH and polish PBR. Displace casing with fresh water and circulate. POOH. SAE.E"FYStJ NI MARY MANHRS WORKED I ACCIDENT TYPE I ~AST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP7 I LAST RIG INSPECTION 507.00 None 12/16/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: RU LD machine IFROM Ie;> HRS~ S~~ - ''''''','' /..\ 06:00 10:30 4.50 17,545 17,545 AF CSGPRC TRIP Continue POOH with liner running tool standing back 5 1/2" in derrick. 10:30 11:30 1.00 17,545 17,545 AF CSGPRC TRIP Change out 5 1/2" handling tools. LD 4" single, break and LD liner running tool. Set screws on liner setting dogs sheared indicating ZXP set. 11:30 13:00 1.50 17,545 17,545 AF CSGPRC EQUIP Break and LD cement TD cement head. 13:00 14:00 1.00 17,545 17,545 AF CSGPRC RIG Change out saver sub on top drive. 14:00 15:00 1.00 17,545 17,545 AF CSGPRC TRIP MU polish mill BHA and 9 5/8" casing scraper. 15:00 18:30 3.50 17,545 17,545 AF CSGPRC TRIP TIH with PBR polish mill and casing scraper. 18:30 20:00 1.50 17,545 17,545 AF CSGPRC TRIP Work casing scraper 9,663' to 9,800'. 20:00 20:30 0.50 17,545 17,545 AF CSGPRC CLEAN Tag and polish PBR at 9923'. 20:30 22:00 1.50 17,545 17,545 AF CSGPRC TEST Drop dart and circulate down to open circulating sub. Close pipe rams and pressure test casing to 1700 psi. Observed 300 psi bleed off in 10 minutes. Repressure casing to 1700 psi. Observed 170 psi bleed off in 10 minutes. Acts as if compressing drilling fluid in hole. 22:00 02:30 4.50 17,545 17,545 AF CSGPRC CIRC Circulate across diverter at 11 bpm. Spot 20 bbl Hi-Vis Polymer pill on top of PBR and across diverter. Pull one stand. Displace hole with fresh water. Stop circulation every 170 bbls and perform 15 minute flow checks. Had 8.7 ppg returns after circulating 30% past annular volume. RU LD machine while displacing hole. 02:30 03:30 1.00 17,545 17,545 AF CSGPRC CIRC Circulate bottoms up with water to confirm liner packers are holding. Max gas 2 units. 03:30 04:00 0.50 17,545 17,545 AF CSGPRC TEST Observe well for 30 minutes prior to POOH 04:00 06:00 2.00 17,545 17,545 AF CSGPRC TRIP POOH, stand 5 1/2" DP in derrick, LD 4" DP. Dt:NSITY(ppg) 8.40 I ppl IECDI ¡nnUDDATAlbAILYCOST I ------ I CUlVlcO~H FV ÞVIYP GlæLS I WUHTHÞ J FCIT.SOL om %Sand/M~T Þh/pM Pf/Mf I CIICa I CaCI~(wt.%t .H2S LlME ES6!%ÞM I I I I I I I I I I I I I I I I I Printed: 4/29/2004 4:04:49 PM MARATHON OIL COMPANY Daily Completion Report Exploitation ~ Gas WELL NAME KASILOF SOUTH 1 DATE 23-Jan-2004 BHA TORQUE{ìnaxlìnin) I Mill, Bit Sub, Spear Extension, Cross Over, Cross Over, Stop Ring, Pump Out Sub. Drill Collar, Cross Over, Casing Scraper. Cross Over, Drill Collar (2), 4" Drill Pipe (246), Cross Over MUD GAS AVG. TRIP: MAX. TRIP: units NO. MAKE OF PUMP 1 NATIONAL AVG. CONN: MAX. CONN: AVG. BKGRD: MAX. DRL: 2 Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Peak Oilfield Service Co. 23 334.00 R&K Industrial 2 48.00 Baker Oil Tools 2 24.00 Oilfield Hot Shot Service 2 24.00 Weatherford 1 12.00 2 2 1 1 20.00 36.00 1.00 8.00 SERVICE CASI G SUMMARY LAST CASING TEST: 7.000 3.500 6.184 2.992 16.11 1,972 (psi) @ 9.10 (ppg) (psi) @ 9.10 (ppg) NEXT BOP TEST: 12/22/2003 10,533 17,502 5,417 9,603 29.00 9.30 L-80 L-80 8,160 10,160 Printed: 4/29/2004 4:04:49 PM MJ,XRJ,XlliHØN·(¡)IL,eøMRJ,XNY [)ail¥ØOmp!~tiQr;).····RØPØi"t fE}(plqitªtiº.,,~~as WELL NAME KB GL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,618 9,700 67 101 101 24-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman ITruby Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST jCl'''\AlI:'I LCU::;, WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 I STATEIPROV COUNTYIOTHER I LAST CASING I NEXT CASING ~ ILEAKOF~ - Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS I MTS 24 HR FORECAST Circulate well with Fresh Water. POOH with diverter, TIH with scraper and 5 1/2" DP OPERATION COMMENTS POOH and LD 4" DP. BHA. TIH with FJD running tool and displace hole with water. SÂ'FÊT¥SÚMI\IIAR¥ MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT REGULATORY INSP? I LAST RIG INSPECTION 548.00 None 12/16/2003 12/15/2003 12/1712003 N 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Handling and LD BHA's. Dangers of Laydown Machine _~)'R~L... :..." ~ I' IFROM ·)'0 @ßS F.~()M 1'0 $1..11:)/ ,,., .... 06:00 15:30 9.50 17,545 17,545 AF CSGPRC TRIP POOH LD 4" DP. 15:30 17:30 2.00 17,545 17,545 AF CSGPRC TRIP RIH with all 4 3/4" De's, 4" HWDP and jars. POOH, LD BHA's and milling BHA. 17:30 20:00 2.50 17,545 17,545 AF CSGPRC TRIP PU FJD running tool BHA and TIH 10 stands. 20:00 22:00 2.00 17,545 17,545 AF CSGPRC RIG Slip and cut drilline, change yoke on overriding clutch. 22:00 04:30 6.50 17,545 17,545 AF CSGPRC TRIP TIH with FJD retrieving tool and 5 1/2" DP, postion stinger across diverter.. 04:30 06:00 1.50 17,545 17,545 AF CSGPRC CIRC Pump 50 bbl Hi-Vis pill and displace hole with clean fresh water ",,","~ '\HP~I <!$~·~~il·..·1 I~~~ 1='.1 pyfyF> . FYI ""'''''I-.'F>h(PM .¢I(¢ìi'< !lp~<J/:!?~~M I I 1 I I 1 I II I1I1 I ~ ..... ~ .. I~FF\IYT I"~··'" Ibd^ !.JDC. I I I I I BHA DESCRIPTION Cleaning Stinger, FJD Running Tool , FJD Lifting Sub, Bumper Sub, Cross Over, Casing Scraper, Cross Over, Hydraulic Jars , 5" Heavy Weight Drill Pipe (6), Accelerator, Cross Over .......... I QN1'fS il units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: 1 MAX. CONN: MAX. TRIP: MAX. DRL: 2 PE~J\ "Ab COMPANY SERVICE ~q.Hqû ·ÇÖ:PANY \9~ HQURS Nabors Alaska Drilling 23 334.00 Baker Oil Tools 3 60.00 Marathon 2 48.00 Oilfield Hot Shot Service 1 1.00 Epoch Well Services 2 24.00 Weatherford 1 4.00 M-I Drilling Fluids 2 24.00 Weaver Brothers (WBI) 2 3.00 Peak Oilfield Service Co. 3 26.00 R&K Industrial 2 24.00 Printed: 412912004 4:04:54 PM MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 ASING SUMMARY LAST CASING TEST: MAX.SICP MD ft 1,972 (psi) @ 9.10 (ppg) 10,533 (psi) @ 9.10 (ppg) 17,502 DATE 24-Jan-2004 12/22/2003 BURST si 8,160 10,160 Printed: 4/29/2004 4:04:54 PM MARAmHQN/QILGQMPAN.¥ Dái .YGoro~t~tiC)n~g·po"t e.xpl(>.itªJion .;ßiaS WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,618 9,700 68 102 102 25-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman ITrubv Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST ~UM WELL CU" I WILDCAT-FOR UNNAMED FIELD 907 -260-6935 100.0000 - STATE/PROV COUNTY/OTHER I LAST CASING I NEXT CASING I Lt:A"vn Alaska 3.500 (in) (â1 17,502 (ft) (in) (â1 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Finish POOH and LD DP. RU and run dual 3 1/2" tubino. OPERATION COMMENTS Test casing annulus. Engage and pull diverter. POOH. TIH with packer. Retest casing. Displace hole with 6% KCI. POOH. LD DP. S~FE1"¥.S.I..JI\III\IIÄRY . .. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~GULATORY INSP? I LAST RIG INSPECTION 535.00 None 12/16/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: LD and rolling 5 1/2" DP "'1:""_ < l;ffi~9M rc¡·· HI'{$ ¡::RQ~ to .$µ~. ;p~~ ·X .. 06:00 06:30 0.50 17,545 17,545 AF CSGPRC CIRC Finish displacing hole with clean fresh water. o units gas on bottoms up. 06:30 08:00 1.50 17,545 17,545 AF CSGPRC TEST Pressure up on annulus to 2,000 psi observed 300 psi bleed off in 15 miunutes and 700 psi bleed of in 30 minutes. Appears to stabilze at 1300 psi. Repeat test with same results. 08:00 08:30 0.50 17,545 17,545 AF CSGPRC MONITR Perform 30 minute flow check and pump slug. 08:30 09:00 0.50 17,545 17,545 AF CSGPRC CSG Latch onto diverter at 9915', unseat with 70K overpull. Repeat with same results to confirm diverter latched. 09:00 15:00 6.00 17,545 17,545 AF CSGPRC TRIP Pull one stand, blow down top drive and choke manifold. POOH 15:00 18:00 3.00 17,545 17,545 AF CSGPRC TRIP Break and LD diverter, FJD running tool and BHA. PU bull nose, circulating sub,two stand of 5" for tailpipe and champ packer 18:00 20:00 2.00 17,545 17,545 AF CSGPRC TRIP TIH with packer and 2 stands of tailpipe. 20:00 22:15 2.25 17,545 17,545 AF CSGPRC TEST Set champ packer at 9704'. End of tail pipe at 9,891'. Test annulus above packer to 2,000 psi for 30 minutes with no bleed off. Leak possibly at ZXP packer or in junction. Leak path will be isolated from surface by GT production packer. This contingency was considered in original well design. 22:15 01:30 3.25 17,545 17,545 AF CSGPRC CIRC Pump Hi-Vis pill followed by 6% KCI with corrosion inhibitor. Displace hole. No gas on bottoms up. 01:30 06:00 4.50 17,545 17,545 AF CSGPRC TRIP PJSM, monitor hole, pump slug and POOH, LD 5 1/2" DP. IpP 1 110<:;01 II\IIO[)[)A¥Å.c:q~T..1 lþY!0COST - O¡;;N$I;rY(ppg) 8.60 FV PVIYP GELS I INLlHTHÞI FCIT.S()L OIW/'Yo$åricJ/fv'lBTf.· ·..·lpt'llVlfl CIICa H~~ 1··..·l;IM~I····E$ <·I.~~PM·· / / I I I / I I I I I I I 29,600 I I 1 1 1 BHA BHA NO. I LENGTH 1 EFFWT. PICKUP .1 SLACK.()F~ ROT INt. !TORQUE(rbaX/!11in) BJ-iAHRS 1 JAR HRS 1 J$SHRS 31 I 190.79 I I I I I I I I I I BHA DESCRIPTION Bull Bose Circulating Sub 5" Heavy Weight Drill Pipe (6), Champ Packer , Cross Over Printed: 4/29/2004 4:04:56 PM WELL NAME KASILOF SOUTH 1 NO. MAKE OF PUMP 1 NATIONAL AVG. CONN: MAX. CONN: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Peak Oilfield Service Co. LAST BOP TEST: 12/15/2003 . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: SERVICE PERSONNEI...<DATA NO. HOURS COMPANY 23 334.00 R&K Industrial 2 48.00 Baker Oil Tools 2 24.00 Weatherford 2 24.00 Weaver Brothers (WBI) 1 10.00 Halliburton SERVICE SINGS LAST CASING TEST: DATE 25-Jan-2004 units 2 20.00 3 42.00 2 14.00 1 3.00 1 16.00 NEXT BOP TEST: 12/22/2003 7.000 3.500 6.184 2.992 16.11 10,533 17,502 1,972 (psi) @ 9.10 (ppg) (psi) @ 9.10 (ppg) 5,417 9,603 L-80 L-80 29.00 9.30 8,160 10,160 Printed: 4/29/2004 4:04:56 PM . . Kasilof South 1 RD 1 Rig Completion (Reports I03A -I2IA) . MARAiHCi>NiCi>I·L<CCi>M.RANY 8ag~ 1 Óf2 Cáily CQ('I)pl.Øti9h Reþort Exploitation.-Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 69 103 103A 26-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman ITrubv Nabors 273E DX0309030CAPCMP01 I FIELD NAME RIG PHONE MOCWI NR! I DAILY WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 - - STATEJPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LI::A"'V,,: Alaska 3.500 (in) @ 17,502 (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 POOH LD DP. RU and run 3 1/2" dual tubing string. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG l~oP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 307.00 ¡None 12/16/2003 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Running dual tbg strings . ... i FROM TO HI"{~ FROM. tê) ~qª pH,ð.§!; JRE!I.. ... HV" 06:00 13:00 7.00 17,545 17,545 AF CSGPRC TRIP POOH laying down 51/2" DP, LD Champ packer. 13:00 14:00 1.00 17,545 17,545 AF CSGPRC EQUIP Rig down LD machine. 14:00 16:30 2.50 17,545 17,545 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 17,545 17,545 AF RCMP EQUIP RU dual tubing running tools, finish driftimg tubing. 19:00 23:30 4.50 17,545 17,545 AF RCMP PLRNRP PJSM. PU and run dual seal module, 5 jts tubing and dual GT packer. 23:30 06:00 6.50 17,545 17,545 AF RCMP PLRNRP Continue running dual strings of 31/2",9.3 ppf, L-80, Hydril 533 tubing making up connection to 3000 ft-Ibs. Depth at report timE 1100' DEt-j$ITY(þþg) 8.60 ippl ~ ~'OSTI 0.00 PV PVIYP ·ß~t.;$ I Ó¡yjJ ··PffMfj (:jll(:j,. ~¡¡i!ir!ljW'1<' ;I_ I I I 1 I I f 6.801 I I 29,600 I I 1 . iSBA BHANO. ¡LENGTH JêFFW1"; PICKUP I~I vVI.lfriRt'Ù JDII" WD" IAcuci:> ,'·1 $$HR? ·v [................ [..,.......' "'" 31 I 190.79 I I I I I I I I I BHA DESCRIPTION Bull Bose, Circulating Sub, 5" Heavy Weight Drill Pipe (6), Champ Packer, Cross Over M.UDiGAS 1 UNIT§ units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNEL...DATA ....pq~@q(5:ºÖ:.. COMPANY SERVICE NO. HOURS COMPANY SERVICE NP, HOµI"{$ 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 Printed: 4/29/2004 4:04:58 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 12/22/2003 BURST 8,160 10,160 Printed: 4/29/2004 4:04:58 PM / M~R'~"JjHØNØlL...CØMP~N~ ¡)áilY~ørn pl~ti9n.i~~P9r-t l3~p!qitªti(jIÌ..· "G¡:¡S WELL NAME KB IGL 24 HR PROG TMD TVD IDFS DOL IRPT# I DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 70 104 104A 27-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I "APIWBS COST Castleman ITruby Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I D."" v,.,,,,, ~~~~ I '" 1M WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 1 00.0000 L- STATEJPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Runnina dual tubina strina Finish runnina tubina. space out and land haaer. OPERATION COMMENTS Run dual tubing strings. SAFETYiSlJ·M·MAR¥ .'. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG l~oP PSI TEST I LAST STOP CARD AUDIT REGULATORY INSP? I LAST RIG INSPECTION 308.00 None 12/16/2003 12/15/2003 12/1712003 N 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Running control line II=R()M TQi 111~~ FR¢îMi T9 ~9~ J'~I1I~~.F·· . ~T::Z¡··AriV ,.....,. .1 -~ 06:00 00:00 18.00 17,545 17,545 AF RCMP PLRNRP Run 7,500' of dual tubing string. 00:00 02:00 2.00 17,545 17,545 AF RCMP PLRNRP RU to run 1/4" control line. 02:00 03:00 1.00 17,545 17,545 AF RCMP PLRNRP Install injection mandrels spaced out to be +1- 2,500' from surface. 03:00 04:00 1.00 17,545 17,545 TA RCMP EQUIP Tubing tongs broke while attempting to torque mandrels. Repair tongs. 04:00 05:00 1.00 17,545 17,545 AF RCMP PLRNRP Install and test control lines to 2500 psi. 05:00 06:00 1.00 17,545 17,545 AF RCMP PLRNRP Continue running 3 1/2" dual tubing while holding 1500 psi on control line. . yp,;: I UiHI:JI 8.60 I~ÞI FÇIT'$~~Ç?IºNv~~ ~M~ri¡:$I~f,f1~ FV pVf(p GEL$ /1 ..çliCá I I I I I 1 / 6.801 1 I 1 29,600 I 1 I I 1 MI <I ·9NIT$ I units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: . .... DA'1"Ä - COMPANY .NO. 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 CASINGSlJMMARY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SiZE Dr)) ID(in) SHÖETESTÜ5pg~ MAXSICP rvîIJ (ft) TVDifh WTilb/ft)·. GRADE BG~~I(PSI) 7.000 6.184 16.11 1,972 (psi) @ 9.10 (ppg) 10,533 5,417 29.00 L-80 8,160 3.500 2.992 (psi) @ 9.10 (ppg) 17,502 9,603 9.30 L-BO 10,160 . . Printed: 4/29/2004 4:04:59 PM dO "2 -2-5 (0 MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas 30.6 17,575 AUTH MD TVD 9,642 WBS WELL NAME KASILOF SOUTH 1 SUPERVISOR Castleman I Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV 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 #2, monitor communication with annulus during testing. KB 24 HR PROG TMD RIG NAME & NO. Nabors 273E . RIG PHONE MOCWI NRI , ÇUM WELL çu" I 907-260-6935 100.0000 COUNTY/OTHER LEAKOFF Test seals in Leg #1 to 1000 psi. Unable to MANHRS WORKED 353.00 ACCIDENT TYPE None LAST SAFETY MTG 1/27/2003 SAFETY SUMMARY BOP PSI TEST LAST STOP CARD AUDIT 12/15/2003 12/17/2003 REGULATORY INSP? N LAST RIG INSPECTION 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Running dual tubing strings. 06:00 15:30 9.50 17,545 17,545 AF RCMP 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 TIH. Land dual seal module in FORMation junction key @ 9904'. Confirm latch with 20K overpull. 15:30 18:30 3.00 17,545 17 ,545 AF RCMP TRIP Space out with tubing pup joints. M/U 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 17,545 17,545 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 17,545 17,545 TA RCMP TEST PKRD Discuss options with management. 00:00 03:00 3.00 17,545 17,545 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 17,545 17,545 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 Reg9 - AOGCC representative. Printed: 4/29/2004 4:05:02 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: SERVICE PERSONNEL DATA NO. HOURS COMPANY 12 155.00 Baker Oil Tools 3 36.00 Weatherford 1 12.00 Pollard Wireline 1 12.00 ABB Vetco Gray 1 12.00 SERVICE 3 36.00 3 36.00 3 36.00 2 18.00 Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids R&K Industrial 16.11 LAST BOP TEST: 12/15/2003 ID 6.184 2.992 NEXT BOP TEST: 7.000 3.500 1,972 (psi) @ 9.10 (ppg) (psi) @ 9.10 (ppg) 10,533 17,502 5,417 9,603 29.00 L-80 9.30 L-80 8,160 10,160 Printed: 4/29/2004 4:05:02 PM M~R:~0FH(¡))N<(¡))lL.CØMP~N¥ Dâily~ol1lþl~tionR~port ç~pl()itati()I1'" -Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 72 106 106A 29-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Castleman I Ratliff Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST tUMWJ:LLo.;U;:" WILDCAT-FOR UNNAMED FIELD 907-260-6935 1 00.0000 ~ STATE/PROV COUNTY/OTHER I LAST CASING I NEXT c.. -..",,,", I LC.AI'\.U~t Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS 1 MTS . 24 HR FORECAST TIH, open ended with 3-1/2" tubinq. OPERATION COMMENTS TOOH with dual tubing strings. LID production packer and dual seal module. 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 294.00 None 1/29/2004 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Communication while TOOH with dual tubing strings. FRQM 1'9 HR§ f'R9M TO SUB ~ .< 06:00 07:00 1.00 17,575 17,575 TA OTHER CIRC PKRD RID reverse circulating lines. Back out hold down pins on wellhead. 07:00 08:30 1.50 17,575 17,575 TA OTHER TRIP PKRD Pull dual tubing hangers. Unset dual seal module with 25K overpull. LID landing joints and hangers. 08:30 19:00 10.50 17,575 17,575 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 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD Finish TOOH to GT packer. 01:00 04:30 3.50 17,575 17,575 TA OTHER TRIP PKRD Drain BOP stack. Pull and LID 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 as sembi} does not appear to have landed in Leg #2 liner hanger seal bore. 04:30 05:00 I 0.50 I 17,575 17,575 TA OTHER TRIP PKRD RID dual handling equipment, RlU single handling equipment. 05:00 06:00 I 1.00 I 17,575 17,575 TA ¡OTHER TRIP PKRD TIH with 3-1/2" mule shoe. !'!S.N?!.!TIPP!¡ 8.65 lief'1 Ig¢ÞI .bA.TA.IPAILY9()stl li¢tJ~. 'd ·<¡;V ÞYf'fP G!ËI..$IWWHl'Hpl ",,.,¡-,, <in, ÒfV.¡ .d/MBTI···ÞþlpNfIBflOOf] ¢il¢å .·CaêI2(M%f ji¡'ÎiE:I.···E:$<I~-~PM' I / / I I I I I I I I I 29,500 I I I I I MUD GAS I UNITS I units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: . PERS.0NNELDATA ROe@\q§fQØ: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HQURS 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 4:05:06 PM WELL NAME KASILOF SOUTH 1 COMPANY Weatherford Pollard Wireline SERVICE 7.000 3.500 ID in 6.184 2.992 MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas PERSONNEL DATA NO. HOURS COMPANY 3 36.00 Oilfield Hot Shot Service 3 5.00 S&R Enterprises SERVICE 1.00 1.00 CASING SUMMARY LAST CASING TEST: 1,972 (psi) @ 9.10 (ppg) (psi) @ (ppg) 8,160 10,160 12/22/2003 10,533 17,502 5,417 9,603 L-80 L-80 Printed: 4/29/2004 4:05:06 PM :< ¿JóZ - cJ5G MAR.ATHI<2>N><2>lL.iC<2>MPANY Ðailyeornplø~ionR~p()rt 6xploitë;lti()n" Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 73 107 107A 30-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS ¡-on"AlRS COST Castleman I Ratliff Nabors 273E DX0309030CAPCMP01 I FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST JCUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 _ STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKO~~ Alaska 3.500 (in) ~ 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 PIU junk baskets and drill pipe. SAFETYSUMMÄR¥ > MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG l~oP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? 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. ·i· - ....~ TO i~R$i FR9M ·;0[9 ;PIH~~'" 06:00 08:00 2.00 17,575 17,575 TA OTHER TRIP PKRD Finish TIH with muleshoe sub on 3-1/2" tubing to 4193'. 08:00 10:30 2.50 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD TOOH, LID muleshoe sub. 13:00 13:30 0.50 17,575 17,575 AF OTHER RIG Service rig and tp drive. 13:30 15:00 1.50 17,575 17,575 AF OTHER RIG Slip and cut drill line. 15:00 16:00 1.00 17,575 17,575 TA OTHER WAIT PKRD Wait on orders. 16:00 17:00 1.00 17,575 17,575 TA OTHER TRIP PKRD M/U dual seal module, add 3.10' seal extension to existing seal assembly. 17:00 22:30 5.50 17,575 17,575 TA OTHER TRIP PKRD TIH with dual seal module on single string of 3-1/2" tubing to 9892'. 22:30 00:30 2.00 17,575 17,575 TA OTHER TRIP PKRD M/U 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 17,575 17,575 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. PENSITY(ppg) I IËCDI I MU[lDAT'A I DAisY .cdsT I I <:;lJMCOST - 8.65 I pp I FV PVfYP GELS I WL/HTIHP I FCrr.$OL OIW %S~nd/MBT I Ph/pM 1~f¡l'v1f I CIICá IC¡¡ÖI:z(wt%j H2$ LlMEI E$ 16RPM I I I I I I I I I I I I I 29,500 I I I I I Printed: 4/29/2004 4:05:07 PM · MÞi~A"'He>NOILØe>MRþ(NY [¡)~lIyQ()I;t\P lêtiC>I1R~P()tt ~~pIQltªti9":·:·->~ª$ WELL NAME KB IGL 124 HR PROGITMD ITVD IDFS DOL IRPT# 1 DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 73 107 107 A 30-Jan-2004 MUD GAS I UNlTS I units AVG. CONN: II AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNEl.. DATA POS:@Q§;OO: COMPANY SERVICE NO. HOURS COMPANY SERVlCE NO. HQURS 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 cÄsING'SUIVIIVIARY » ......... > » ... LAST SOP TEST: 12/15/2003 LAST CASING TEST: NEXT SOP TEST: 12/22/2003 SIZE (in) JO(in) SHÖETESTJpþg) MAXSICP MO(ft) T\iÔ·(ft) r.RAFiR 7.000 6.184 16.1 1 1 ,972 (psi) @ 9.10 (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 4:05:07 PM ~ . 0;;- o<sC, MJ-XB-J-XTI-IØN ØØMPJ-XNY Daily. QørnplêtiOnR.~PQ.rt Expløitªtiøn"G¡:¡s ... WELL NAME KB jGL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 74 108 108A 31-Jan-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWB!>. COST, Castleman 1 Ratliff Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 -1 - STATEJPROV COUNTYIOTHER I LAST CASING I NEXT CASING I LI:AI\U~~ Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS 1 MTS 24 HR FORECAST Washinq down, workinq junk baskets. OPERATION COMMENTS Change and test pipe rams. TIH with clean out assembly, picking up drill pipe off racks. SAFE"r¥.Sw.MMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSITEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 265.00 None 1/30/2004 12/15/2003 12/1712003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Picking up drill pipe, safety awareness around lay down machine. .. > IIFßþrvt >1'0 HRS iFßQM TO 06:00 07:30 1.50 17,575 17,575 TA OTHER TRIP PKRD LID dual seal module. Clear rig floor. 07:30 08:30 1.00 17,575 17,575 TA OTHER EQUIP PKRD RID tubing handling equipment, RlU 4" DP handling tools. 08:30 10:00 1.50 17,575 17,575 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 17,575 17,575 TA OTHER TEST PKRD Test VBR rams and bonnet seals to 250 I 3500, 5 minutes each test. 10:30 12:00 1.50 17,575 17,575 TA OTHER TRIP PKRD Pull test plug, set and lock down wear bushing. LID BOP test equipment. 12:00 13:30 1.50 17,575 17,575 TA OTHER TRIP PKRD M/U reverse basket BHA with 3 junk baskets. 13:30 15:00 1.50 17,575 17,575 TA OTHER TRIP PKRD RlU laydown machine. 15:00 15:30 0.50 17,575 17,575 TA OTHER RIG PKRD Service rig. 15:30 16:00 0.50 17,575 17,575 TA OTHER SAFETY PKRD Safety meeting. 16:00 04:30 12.50 17,575 17,575 TA OTHER TRIP PKRD TIH to 9617' with BHA, picking 4" drill pipe off racks. 04:30 05:00 0.50 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD Wash I ream in hole working reverse basket and boot baskets, attempting to PIU SS bands left in hole. Depth 9805' at 06:00 hours. Ä~~srtY(ppgY J 8.65 [þpl [ECD[ [M~"'·Ù·""""'I I"······· .",,,.... ...."..,.. ....... 7C FV PVf'(P ·1 qej$I'NL.lHTHPI Fc¡f.!¡(.)LÒ¡VY ......... . Ph¡pMI~f¡Mf·t CI{ç;a f.t~!¡ ~iMÊY Ê!¡ 1.~~~M I I I I 1 I I I ¡ I 1 I I 1 29,000 I 1 1 [ BRA BHANO. I LENCfTH ·IEFFWT. PICK UP 1 SLACK OF~ROT V'lJ. ItqRQL/E·(maxlmin) IBHAHRS IJARHR$ IMWDHRS IIVIII)t1tt;:> .lssf-jRš 32 I 113.22 I I I I I I I I I I BHA DESCRIPTION Reverse Basket, Cross Over, Junk Basket, Junk Basket, Junk Basket, Cross Over, 3 Joints 5" HWDP , Cross Over, Cross Over MWDGAS UNITS 1 units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: Printed: 412912004 4:05:08 PM WELL NAME KASILOF SOUTH 1 COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids R&K Industrial 7.000 3.500 6.184 2.992 16.11 MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas Page 2 of 2 SERVICE PERSONNEI..ÐATA NO. HOURS COMPANY 12 155.00 Baker Oil Tools 2 24.00 Weatherford 1 12.00 Oilfield Hot Shot Service 1 12.00 Alaska Oil Sales 1 12.00 SERVICE 1,972 (psi) @ 9.10 (ppg) (psi) @ (ppg) 10,533 17,502 5,417 9,603 29.00 9.30 L-80 L-80 POB @ 06:00: NO. HOURS 2 24.00 2 24.00 1 1.00 1 1.00 12/22/2003 8,160 10,160 Printed: 4/29/2004 4:05:08 PM d.DZ - :<S(p MARATHON OIL C ANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 SUPERVISOR Castleman I Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS I MTS RIH. OPERATION COMMENTS Run 8-1/8" reverse circulating basket.POOH.BHA.RIH.Set Leg #2 diverter.POOH. BHA. SAF'EmMSllMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 264.00 None 1/30/2004 112115/2003 1211712003 IN ACCIDENT DESCRIPTION: IGL 30.6 I 74.00 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,575 AUTH MD TVD I DFS IDOL 9,642 I 75 109 WBS .. I RPT# DATE I 109A 01-Feb-2004 SAPIWBS COST KB DX0309030CAPCMP01 MOC WI NRI ! DAILY WEll f'n"T I CUM WELL COST 907-260-6935 100.0000 I -----L COUNTY/OTHER I LAST CASING I NEXT CASING ILEAKOFF I 3.500 (in) @ 17,502 (ft) I (in) @ 0 (ft) 24 HR FORECAST Run 5-7/8" Reverse circulating basket. Run polish mill RIG PHONE I LAST RIG INSPECTION 112/11/2003 SAFETY MTG TOPICS: Slips, trips, and falls. Handling BHA. i" -- ..... ...~ IÊr{QM .r9 WR$ FRPN!·· ...>1"9. .. sQÎ;i ,~ ..., 06:00 07:00 1.00 17,575 17,575 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 17,575 17,575 TA OTHER CIRC PKRD Pump 50 bbl High Vis sweep and circulate to surface. 09:00 13:30 4.50 17,575 17,575 TA OTHER TRIP PKRD POOH 13:30 14:30 1.00 17,575 17,575 TA OTHER TRIP PKRD LID 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 17,575 17,575 TA OTHER TRIP PKRD PIU FJD running tool and function test. 15:00 15:30 0.50 17 ,575 17,575 TA OTHER RIG PKRD Change out dies in Top Drive gripper. 15:30 17:00 1.50 17,575 17,575 TA OTHER TRIP PKRD PIU Leg #2 diverter and engage FJD running tool. PIU remaine of BHA. 17:00 20:30 3.50 17,575 17,575 TA OTHER TRIP PKRD TIH to 9904'. 20:30 21:00 0.50 17,575 17,575 TA OTHER TRIP PKRD Set Leg #2 diverter in junction. Release running tool from diverter. 21:00 00:00 3.00 17,575 17,575 TA OTHER TRIP PKRD POOH to 6400'. 00:00 00:30 0.50 17 ,575 17,575 TA OTHER RIG PKRD Service Rig 00:30 03:00 2.50 17,575 17,575 TA OTHER TRIP PKRD Con't POOH wI 4" Drill Pipe. 03:00 04:30 1.50 17,575 17,575 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 ,575 17,575 TA OTHER CLEAN PKRD Clean Rig Floor of Excess Equipment 05:00 06:00 1.00 17,575 17,575 TA OTHER TRIP PKRD PIU 5-3/4" reverse circulating basket assembly. DENSITY(ppg) FV PVNP I 8.70 I ÞÞ I GELS I wLlHtHP I / I I I IECDI IMll~w;:" I FC/T.SOL Olw %Sand/MBT I Ph/pM I Pf/Mf I / I / I I I I I --------- CI/Ca I I CUM COST ) ~ LIME ES 16RPM I I I 31,0001 I BAA BHA NO. I LENGTH I pFFVVT. PICKUP I SLACK OF~ROTWT. I TORQUE (maximin) l.aHA HRS. IJARHRS IMTR H~s.I~$HR$ 33 I 175.99 I I I I I I I I I I BHA DESCRIPTION Leg #2 Diverter , FJD Diverter Running Tool, FJD Lift Sub, Bumper Jar, Hydraulic Jar, 3 JTS 5" HWDP , Accelerator Jar , Cross Over, Junk Basket, Junk Basket, Junk Basket, Cross Over, Cross Over, Cross Over Printed: 4/29/2004 4:05:11 PM WELL NAME KASILOF SOUTH 1 NO. MAKEOFPUMP 2 NATIONAL AVG. CONN: MAX. CONN: Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids 7.000 3.500 6.184 2.992 16.11 MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas KILL SPM / PRESSURE MUD GAS AVG. TRIP: MAX. TRIP: units ERSONNEL DATA HOURS COMPANY 12 155.00 R&K Industrial 2 24.00 Baker Oil Tools 1 12.00 Weatherford 1 12.00 Alaska Oil Sales CASING UMMARY LAST CASING TEST: 1,972 (psi) @ 9.10 (ppg) (psi) @ (ppg) 10,533 17,502 5,417 9,603 29.00 9.30 Printed: 4/29/2004 4:05:11 PM M,6¡R,6¡æI+l0N·0ILC0MP,6¡N¥ Ðaily,CC)mþløtiqh~øþ()rt Exploit;:ition- Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL !RPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 76 110 110A 02-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS ''''''MI''~ COST Castleman I Ratliff Nabors 273E DX0309030CAPCMP01 , - FIELD NAME R!G 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 17,502 (ft) INEXT'-""'N(~n) @ 0 (ft) I LEAKOFF Alaska 3.500 (in) @ CURRENT STATUS / MTS 24 HR FORECAST TIH with Dolish mill. OPERATION COMMENTS Continue fishing for stainless steel methanol injection line bands in hole. Make 2 trips with golobe basket, recover 9 bands. SÄFE!'[YSÚMMÄRV.. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 239.00 None 2/1/2004 12115/2003 12/1712003 12/11/2003 ACCIDENT DESCRIPTION: - SAFETY MTG TOPICS: Handling BHA's. Securing air tugger lines properly after use. ~ ,.' _ÍlI~NS/~ÛMM~~ fiRS FRÞr4 tÞ ,. OR ,. TRBL ...,.... '" 06:00 07:00 1.00 17,575 17,575 TA OTHER TRIP PKRD Finish P/U 5-3/4" Reverse Globe Basket BHA. 07:00 11:00 4.00 17,575 17,575 TA OTHER TRIP PKRD TIH with BHA to 9880'. 11:00 12:30 1.50 17,575 17,575 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 P/U stainless steel methanol injection line debris left in hole. 12:30 16:00 3.50 17,575 17,575 TA OTHER TRIP PKRD Slug pipe, TOOH to BHA. 16:00 17:30 1.50 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD TIH to 9844'. 21:00 22:00 1.00 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD Slug pipe, TOOH to BHA. 02:00 04:00 2.00 17,575 17,575 TA OTHER TRIP PKRD TOOH with BHA, recover 1 SS band in junk basket. Reverse globe basket was empty. LID reverse basket, P/U 3-7/8" aD x 5-1/8" aD tandem polish mill. 04:00 06:00 2.00 17,575 17,575 TA OTHER TRIP PKRD TIH with polish mill. Stainless steel bands Daily recovery +1-9 Total recovered +1- 34 Left in hole +1- 27 Di:\SITY{ppg) 8.70 Ipp IEC!) I IMIJ òl:)AtAI DAlliY9C>§l"1 1 CUM¢QST -~ FV PV/yP GELS I \iVUHTHP I FC/T.SOL om ·/.$al1dÎME:!T 1 Ph/plVl I ,. Pf/Mf I' CIICa IC<.lCI2{wt%j 1-12$ L.IM!;I ~:>' I "r~'p1VI I I I I I I I I I I I I I 32,500 I 1 1 1 1 . . ~ ();l. -:z5 ~ Printed: 4/29/2004 4:05:16 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 I 3-7/8 x 5-1/8" Tandem Polish Mill , (2) 4-3/4" Drill Collars, Cross Over, Cross Over, Junk Basket, Junk Basket, Junk Basket, Cross Over, Bumper Jar, Hydraulic Jar, 2 JTS 5" HWDP , Accelerator Jar, Cross Over, Cross Over AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: units CO!VIPANY Nabors Alaska Drilling Marathon Epoch Well Services SERVICE PERSONNEL D NO. HOURS C 12 155.00 M-I Drilling Fluids 2 24.00 Baker Oil Tools 2 12.00 2 3 12.00 36.00 CASING SUMMARY LAST CASING TEST: NEXT BOP TEST: 12/22/2003 1,972 (psi) @ 9.10 (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 4:05:16 PM . . M~R~illHIDNIDlb ·.eIDMP~N¡Y [)ai !¥e0I'TlPl~ti()nRøpørt ßxplºit~tion"~~$ WELL NAME KB GL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 77 111 111A 03-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIW8S COST Castleman I Ratliff Nabors 273E DX0309030CAPCMP01 .- FIELD NAME R!G PHONE MOCWI NR! I CAlLY WELL COST I~UM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 - STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 3.500 (in) @ 17,502 (ft) (in) @ 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.BHARIH. Confirm and test seal bore length with seal assembly.POOH. BHA. RIH. SAFeÌ'¥·S!.JMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG l~oP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 243.50 None 2/2/2004 12/15/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Handling BHA's. 1.- .. ......... >;¡ . FROM 1'0 ··.f¡RS FROM 1'q .......~µ~ 111!I'! < 06:00 07:30 1.50 17,575 17,575 TA OTHER TRIP PKRD Finish TIH to 9850'. 07:30 09:00 1.50 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD Trip to BHA 13:30 14:30 1.00 17,575 17,575 TA OTHER TRIP PKRD UD 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 ,575 17,575 TA OTHER TRIP PKRD TIH with seal assembly to 9869'. 17:30 18:15 0.75 17,575 17,575 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 17,575 17,575 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 17,575 17,575 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 17,575 17,575 TA OTHER RIG PKRD Slip and cut drill line. Re-set and test crown-o-matic. 20:15 23:30 3.25 17,575 17,575 TA OTHER TRIP PKRD Trip to BHA 23:30 00:30 1.00 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD PIU FJD pulling tool. Function test tool in rotary, unable to Printed: 4/29/2004 4:05:17 PM · . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas 30.6 IGL I 74.00 24 HR PROG I TMD ITVD I DFS IDOL I RPT # IDA TE I 17,575 9,642 I 77 111 I 111A 03-Feb-2004 WELL NAME KASILOF SOUTH 1 KB FROM TO HRS 00:30 02:00 1.50 FROM 17,575 TO SUB 17,575 TA OPERATIONS SUMMARY PHASE OP TRBL OTHER TRIP PKRD ."".. 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. 02:00 06:00 4.00 17,575 17,575 TA OTHER TRIP PKRD DENSITY(ppg) 8.75 I PP I rECD IMUD DATAl DAILY COST I I CUM COST FV PVIYP GELS WL/HTHP I FC/T.SOL OIW %Sand/MBTI Ph/pM I Pf/Mf I \,;I/Ca ICaCI2(wt%j H2S LIME ES 6RPM I I I I I I I I I I I I I 40,000 I I I I I BHA NO. I LENGTH Icrr WI I PICK UP I SLACK I r\V I VV I. II u~~~ I RHA I-R~ lAC wc'" I....:::: ..._ 1 MTR HRS ~ 38 I 131.62 I I I I I I I I I BHA DESCRIPTION FJD Stinger, FJD Diverter Running Tool FJD Lift Sub, Bumper Jar, Hydraulic Jar, 2 JTS 5" HWDP , Accelerator Jar, Cross Over Junk Basket, Junk Basket, Junk Basket Cross Over, Cross Over, Cross Over ~ ,...- ~ - I UNITS I units AVG. CONN: MAX. CONN: I AVG. TRIP: MAX. TRIP: I AVG. BKGRD: MAX. DRL: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Oil Tools SERVICE ~ONNEL DATA NO. I HOURS COMPANY 12 155.00 Oilfield Hot Shot Service 2 24.00 Alaska Oil Sales 2 12.00 Alaska's Best Water 2 12.00 S&R Enterprises 3 36.00 ~ 1 2.00 1 1.00 1 0.50 3 1.00 LAST BOP TEST: 12/15/2003 SIZE (in) ID (in) ~HUI:: II::::> . (ppg) 7.000 6.184 16.11 3.500 2.992 CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) 1,972 (psi)@ 9.10 (ppg) 10,533 (psi) @ (ppg) 17,502 12/22/2003 ~ ,~^~ 'u" TVD (ft) 5,417 9,603 NEXT BOP TEST: WT (lb/ft) GRADE 29.00 L-80 9.30 L-80 8,160 10,160 Printed: 4/29/2004 4:05:17 PM MÄRÄ17H€>N€>IILC€>MPJ:\NY Dê:Jllyßol1")plQtiþnRøport ExpIOitation~Gª$ .... WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 78 112 112A 04-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS 10 ^ DItAII::tC!: ,...n~T Randv Ratliff Nabors 273E DX0309030CAPCM PO 1 FIELD NAME RIG PHONE MOCWI NRI ID"" v....~.. _-~- I~o ...... ---- ,,~ 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) @ 17,502 1ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST TOOH with reverse basket. OPERATION COMMENTS Change FORMation Junction diverters. TIH with reverse basket to P/U debris left in hole, SAFETYSUMMAR'f MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I~EGULATORYINSP? I LAST RIG INSPECTION 244.00 First Aid 2/2/2004 12115/2003 12/1712003 12/11/2003 ACCIDENT DESCRIPTION: NAD employee slipped on ice and strained his shoulder. SAFETY MTG TOPICS: Remain focused during back to back trips. ... ~NS~~ ~ IFRPM 19 fiRs FRqM imp $Yß TRS ........ .., .",. 06:00 06:15 0.25 17,575 17,575 TA OTHER TRIP PKRD Finish TIH with FJD tool to 9889'. 06:15 07:00 0.75 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD Blow down top drive, TOOH to BHA. 11 :00 13:00 2.00 17,575 17,575 TA OTHER TRIP PKRD UD Leg #2 diverter. LID FJD tool and PIU re-dressed tool. Engage Leg #1 swage diverter. Finish PIU BHA. 13:00 16:30 3.50 17,575 17,575 TA OTHER TRIP PKRD TIH with diverter to 9889', 16:30 17:00 0.50 17,575 17,575 TA OTHER TRIP PKRD Place Leg #1 swage diverter in FORMation Junction collet lug @ 9904'. Snap out of collet with 115Koverpull. Re-set diverter, confirm set with 30K overpull. Circulate and release diverter. 17:00 21:00 4.00 17,575 17,575 TA OTHER TRIP PKRD Slug pipe, blow down top drive. TOOH to BHA. 21:00 22:30 1.50 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD TIH to 3530'. 00:00 00:30 0.50 17,575 17,575 TA OTHER RIG PKRD Service rig and top drive. 00:30 02:30 2.00 17,575 17,575 TA OTHER TRIP PKRD Finish TIH to 9747'. 02:30 04:30 2.00 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD Slug pipe, blow down top drive and TOOH. I PP ! II\ÎI.UDDATÂ I þAIL.yCOST I I.· COM COsT ~ D¡:NSITY(ppg) 8.75 !¡:cp FV PVNP GELS I Wl./HTHP I FC/T.SOL OIW %Sari~¡MBT I Ph/pM I Pf/Mf I CIICa ICaCIZ(wt%jH2S LIME I ES H~PM 37 5/11 5/6 I I I I I I I I I 1 I 44,000 I I I I I BHA BHA NO. ·1 LENGTH !Ef'FWT. PICK UP I SLACK OF~ ROJWT. I TORQUE (ma¡µrnin) I BHA HRS ¡JAR HR$ IMV\I[) HRSIMtR HRS .j$SHRS 39 I 180.80 I I I I I I I I I I . . Printed: 4/29/2004 4:05:18 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas HA BHA DESCRIPTION 5-3/4" Reverse Globe Basket, Collars, Cross Over, , Cross Over, Bumper Jar, Hydraulic Jar, 2 JTS 5" HWDP , Accelerator Jar, Cross Over, Cross Over MUD GAS units WELL NAME KASILOF SOUTH 1 AVG. CONN: MAX. CONN: AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids SERVICE PERSONNEL DATA NO. HOURS COMPANY 12 155.00 Baker Oil Tools 2 24.00 Oilfield Hot Shot Service 2 12.00 Alaska Oil Sales 2 12.00 S&R Enterprises 3 1 1 1 36.00 3.00 1.00 1.00 LAST BOP TEST: 12/15/2003 C SING SUMMARY LAST CASING TEST: 7.000 3.500 6.184 2.992 16.11 1,972 (psi) @ 9.10 (ppg) (psi) @ (ppg) NEXT BOP TEST: 12/22/2003 L-80 L-80 8,160 10,160 10,533 17,502 5,417 9,603 29.00 9.30 Printed: 4/29/2004 4:05:18 PM . e . MÄ~Ä$H~N~IL.G~MAÄN;Y .... t""qg.~ I DáHyCompletiøn· R~PQrt (:xploitØtiOn ,.Q~$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 79 113 113A 05-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I "APIWBS COST Randy Ratliff Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 ) '-- STATE/PROV COUNTY/OTHER I LAST CASING I NEXT <'A"ING I LEAk-v," Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST TIH with 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. SÄËETYSUMMÄRY MANHRS WORKED I ACCIDENT TYPE I :LAST SAFETY MTG I~Op PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP7 I LAST RIG INSPECTION 245.00 None 2/4/2004 12115/2003 12/1712003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pinch points, tripping pipe, handling BHA's. IAHiI . > .i i FROM TO HRS FRPIlÎl· TO !?Ii!ß f,>~.i\ŠE of,> ""ßß~ .,. "pl~ 06:00 08:00 2.00 17,575 17,575 TA OTHER TRIP PKRD Finish TOOH with reverse basket. 08:00 09:30 1.50 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD TIH to 9843'. 12:30 14:00 1.50 17,575 17,575 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 and junk baskets attempting to PIU SS band debris. 14:00 17:30 3.50 17,575 17,575 TA OTHER TRIP PKRD Slug pipe, blow down top drive. TOOH to BHA. 17:30 18:30 1.00 17,575 17 ,575 TA OTHER TRIP PKRD Clean out reverse and junk baskets. Found 1 SS band in junk basket. LID reverse basket, PIU a 3-9/16" aD PBR polish mill. 18:30 21:45 3.25 17,575 17 ,575 TA OTHER TRIP PKRD TIH to 9846'. 21:45 22:15 0.50 17,575 17,575 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 17,575 17 ,575 TA OTHER TRIP PKRD Trip for BHA to 6500'. 00:00 00:30 0.50 17,575 17,575 TA OTHER RIG PKRD Service rig and top drive. 00:30 02:30 2.00 17,575 17,575 TA OTHER TRIP PKRD Finish TOOH to BHA. 02:30 05:00 2.50 17,575 17,575 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. PIU 3' 80-36 molded seal assembly. PIU 9-5/8" champ packer and finish MIU BHA. 05:00 06:00 1.00 17,575 17,575 TA OTHER TRIP PKRD TIH with BHA. Recover 8 Stainless steel bands last 24 hours, +1- 19 left to recover. DENSITY(ppg)I I PP I I.ECO I II\iIUDDÄTÄI DAILY<;:ÓST I ...- 'çYrJI¢(:)st - 8.85 FV PVfYP GELS I WL/HTHP I FC/T.SOl. OIW %sand/1ViBT I Ph/pM I Pf/lVlf \';;'1/"'" a '1...~~12(wt%j H~S LlrJlEI ESJSRF'I'II 38 5/12 5/7 I I I I / 8.001 I I I 48,000 I I I I I Printed: 4/29/2004 4:05:24 PM · e MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 BHA NO. BHA TORQWE(rnaxlmin) I Seal Assembly, 1 JT 3-1/2" Vam Tubing, Cross Over, Cross Over, Cross Over, 3-1/2" DP Pup Joint, Cross Over, 9-5/8" Champ Packer, Bumper Jar, Hydraulic Jar, 2 JTS 5" HWDP , Accelerator Jar, Cross Over, Junk Basket, Junk Basket, Junk Basket, Cross Over, Cross Over, Cross Over AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: units AVG. BKGRD: MAX. DRL: Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids 12 155.00 Baker Oil Tools 2 24.00 Oilfield Hot Shot Service 2 12.00 S&R Enterprises 2 12.00 Halliburton 3 1 1 1 36.00 1.00 1.00 4.00 SERVICE 7.000 3.500 6.184 2.992 1,972 (psi) @ 9.10 (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 4:05:24 PM MA.RATHG>NQILCØMRA.NY Pagè1·.····0f.~ DCJilyGôrnþl~tiôn ·Reþôr1: (:);Çþ fgitªt¡ptt,.(,1¡;is . WELL NAME KB GL 24 HR PROG TMD TVD IDFS IDOL IRPT# I DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 80 114 114A 06-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS I SAPIWBS COST Randv Ratliff Nabors 273E DX0309030CAPCMP01 FIELD NAME R!G PHONE MOCWI NRI I DAILY WFI I rn"T J CUM WELL COST 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) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST RIU 3-1/2" Tubina handlina tools. Make dual lea dummy seal test run. OPERATION COMMENTS Test Leg #1 PBR seals. Pressure test intermediate casing. Pull Leg #1 diverter. SAFETY SUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG IBOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 236.00 None 2/5/2004 12115/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Handling BHA's, tripping pipe. .. p~ .ii . IFRÞM TO ·HRS FROM TO SUB \i ..,..,. 06:00 10:00 4.00 17,575 17 ,575 TA OTHER TRIP PKRD Finish TIH with PBR seal assemby and 9-5/8" Champ Packer to 9830'. 10:00 11:30 1.50 17,575 17,575 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 unabl~ 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 17,575 17,575 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 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD Slug pipe. Blow down top drive and choke manifold. 13:30 17:30 4.00 17,575 17,575 TA OTHER TRIP PKRD TOOH to BHA. 17:30 20:00 2.50 17,575 17,575 TA OTHER TRIP PKRD UD seal assembly and Packer. Discover 1 SS band lodged in a-Jar mandrel housing. PIU FJD tool and function test collet. 20:00 23:30 3.50 17,575 17,575 TA OTHER TRIP PKRD TIH with FJD to 9826'. 23:30 01:00 1.50 17,575 17,575 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 100K over-pull. 01:00 01:30 0.50 17,575 17,575 TA OTHER RIG PKRD Service rig and top drive. 01:30 04:30 3.00 17,575 17,575 TA OTHER TRIP PKRD TOOH to BHA. 04:30 05:30 1.00 17,575 17,575 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: 4/29/2004 4:05:26 PM · . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 OPERATIONS SUMMARY PHASE OP TRBL OTHER TRIP PKRD OTHER TRIP PKRD DESCRIPTION profile and diverter housing. RIU 3-1/2" tubing handling tools. FROM TO 04:30 05:30 1.00 05:30 06:00 0.50 FROM 17,575 17,575 TO SUB 17,575 TA 17,575 TA Recover 2 stainless steel bands last 24 hours, +1- 17 left t recover. DENSITY(ppg) FV PVIYP 38 6/11 I FJD Stinger, FJD Diverter Running Tool, FJD Lift Sub, Bumper Jar. Hydraulic Jar. 2 JTS 5" HWDP , Accelerator Jar, Cross Over, Junk Basket, Junk Basket, Junk Basket, Cross Over. Cross Over. Cross Over AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: units AVG. BKGRD: MAX. DRL: Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids 12 155.00 Baker Oil Tools 1 12.00 Oilfield Hot Shot Service 2 12.00 Halliburton 2 12.00 R&K Industrial 3 1 1 2 36.00 1.00 6.00 2.00 6.184 2.992 16.11 NEXT BOP TEST: 12/22/2003 1,972 (psi) @ 9.10 (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 4:05:26 PM MARATHeNølL CØMPAN¥ Dai I~t C9I"tlpl(:}tiorrR~pórt ....... E~ploitation ·~Ga$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASllOF SOUTH 1 30.6 74.00 17,575 9,642 81 115 115A 07-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Randv Ratliff Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST i CUM WELL COST , WilDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 I NEXT CASING - - STATE/PROV COUNTY/OTHER I LAST CASING I LEAKOFF Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST TOOH with dual seal module assemblv. OPERATION COMMENTS Make successful dual seal module I GT packer dummy test run. SÄFEII'Y:SUiIlMÄRY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG l~oP PSI TEST 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. OPERÞ("PIONSSUMMARY FROM TQ H.RS FRQM Tq sua PHASE .oP TRaL 06:00 07:00 1.00 17,575 17,575 TA OTHER TRIP PKRD Finish R/U 3-1/2" dual string handling tools and equipment. 07:00 12:00 5.00 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD UD GT packer assembly. 13:00 18:30 5.50 17 ,575 17,575 TA OTHER WAIT PKRD Send GT packer assembly to shop for clamp installation. 18:30 22:00 3.50 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD TIH to 9874' with assembly on drill pipe to make dummy test run. 04:30 05:30 1.00 17,575 17,575 TA OTHER TRIP PKRD Slack off and land dual seal module in FORMation Junction collet lug @ 9904' with 10K. P/U 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 PIU and snap DSM out of collet profile with 30K overpull. 05:30 06:00 0.50 17,575 17,575 TA OTHER TRIP PKRD Slug pipe, blow down top drive. 8.90 Ipþ I IEc;DI IMOPPA"PAþ~lliyçq$fl I.cQMCOST - DEN$ITY(ppg) i:$·..·.··.li~~RM\ FV PVIYP Gi:LS· I.YvI4HTHi;>1 FblT;$o~1 OIW %Sal1d/MS'rI Ph/PM I þf/Mf I CI/Ca I CðCI2(Wt%jH.zs LIfV!EI 35 5/11 4/5 I / I 11.0 /99 / I 8.001 I I I 51,000 I I I I I MUD GAS I UNITS I units AVG. CONN: I AVG. TRIP: I AVG. SKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: PERSONNEt·DATA P()!3 @OQ:QO: COMPANY I SERVICE NO. HOURS COMPANY I SERVICE NO. I HqU"$ Nabors Alaska Drilling I 12 155.00 Marathon I 1 I 12.00 . . Printed: 4/29/2004 4:05:27 PM . . MARATH€lN/€llL.··c;€lMPANY Page 2 ofi2 Dallyc;Òl11pl~tiØ.I'1Re port E;1(pl()i~ati()Il-Gas WELL NAME KB IGL 124 HR PROGITMD ITVD IDFS DOL IRPT# I DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 81 1 15 115A 07-Feb-2004 PERSONNEL.DATA POI:I@ 06:09: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Epoch Well Services 2 12.00 R&K Industrial 1 6.00 M-I Drilling Fluids 2 12.00 Alaska Oil Sales 1 2.00 Baker Oil Tools 3 36.00 Weatherford 1 8.00 Oilfield Hot Shot Service 1 3.00 S&R Enterprises 2 2.00 CASING SUMMARY ... LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE (in) IDlin) SHOETEST (DDO) MAXSICP . MD.(ft) TVÖ(ft) \l\tr(1 blft) GRADE .QI,I"q·lilP:;iI) 7.000 6.184 16.1 1 1,972 (psi) @ 9.10 (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 4:05:27 PM . . I\lIÄR.Ä0FHI<ÐN<Ðlb€<ÐM RÄN¥ [)ªily€ørtaPl~ti()nR.ðpórt 1;·~PI().itê1ti()I1···.."Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL RPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 82 116 116A 08-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Randv Ratliff Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I CAli v W"" r-"'ST ! CUM WELL COST I .... .........."'..... WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 1 STATEJPROV COUNTY/OTHER I LAST CASING I NEXT CA:;ING I LEAKOFF Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Lavina down drill pipe. Lav down drill pipe, run dual production tubinQ strings OPERATION COMMENTS TOOH and UD dual dummy test seal assembly. TIH and displace with packer fluid. Laying down drill pipe. SAF'ETYSUMMAR¥ MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? 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. ~SÛ~ . « IFRÕM. 1'P !-I~~.. f"~QM... iT9 $LJi3 f!!-I;t.;§F .t~êL. 06:00 11:30 5.50 17,575 17,575 TA OTHER TRIP PKRD TOOH to packer assembly. 11:30 12:00 0.50 17,575 17,575 TA OTHER TRIP PKRD UD drill pipe handling tools, R/U 3-1/2" dual tubing handling equipment. 12:00 15:00 3.00 17,575 17,575 TA OTHER TRIP PKRD LID 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 17,575 17,575 TA OTHER TRIP PKRD Change handling equipment, clear rig floor. 15:30 16:00 0.50 17,575 17,575 TA OTHER RIG PKRD Service rig and top drive. 16:00 16:30 0.50 17,575 17,575 TA OTHER TRIP PKRD M/U junk basket BHA. 16:30 17:00 0.50 17,575 17,575 TA OTHER RIG PKRD Repair and re-test crown-o-matic. 17:00 22:00 5.00 17,575 17,575 TA OTHER TRIP PKRD TlH with BHA to 9867'. 22:00 23:30 1.50 17,575 17,575 TA OTHER RIG PKRD Slip and cut drill line. 23:30 02:00 2.50 17,575 17,575 TA OTHER TRIP PKRD R/U laydown machine. Finish preping pits for displacement. 02:00 03:30 1.50 17,575 17,575 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 17,575 17,575 TA OTHER CIRC PKRD Slug pipe, blow top drive down. 04:00 06:00 2.00 17,575 17,575 TA OTHER TRIP PKRD Hold safety meeting, LDDP. . !-'....~,.... '\I'~~I 8.65 I.PF'I IE¢D I '-1 PAiL. ·96$" .1 ~..C'MEI?Ë$16RRM ¡;'Ì I'\.INI' GEL..sl\i\lWHTHI'I I:'-! I';:'!i?!-. .·ö/'fJ.I'!1lpMI·. N!Mfl CIICa I I 1 I 1 I I I I I I I I 29,5UO I I 1 I 1 BHA BHA NO, I LENGTH IEFF\iVY. ·.lpIÇK UP ISlß.CK ºf~ ROT \iVY. 1 TOR9UE (llla)(Jmjh) IBHAHRS 1 JAR HR§ IMWD HRßIfY1,.l'fHR$ ·I$SHR$. 42 I 110.23 I I I I I I I I I I I BHA DESCRIPTION Junk Basket, Junk Basket, Junk Basket, Cross Over, Bumper Jar, Hydraulic Jar, 2 JTS 5" HWDP , Accelerator Jar, Cross Over, Cross Over MUD GAS 1 UNITS .1 units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: Printed: 4/29/2004 4:05:30 PM MARATfi<DN<DlbØ<DMPANY Pagè2·.·.Ôf2 [)ally..·.ypmÞlêtioJ1··Røport E:x.Pløit~tiQn ~Gas WELL NAME KB IGL 124 HR PROGITMD ITVD IDFS DOL IRPT# .IDATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 82 1 1 6 116A 08-Feb-2004 PERSONNELÐATA POB@Qß;OP: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO; HOURS I Nabors Alaska Drilling 12 155.00 Baker Oil Tools 3 36.00 Marathon 1 12.00 Oilfield Hot Shot Service 1 3.00 Epoch Well Services 2 12.00 R&K Industrial 4 48.00 M-I Drilling Fluids 2 12.00 Weatherford 2 8.00 CASING SUMMÄRY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE On) ID(if1).. SHOE TEST (PPQ) MAXSICP MD{ft) T\lO(ft) \lVT(lþ/ft) . GRADE ..BÙRS;r(bs¡) 7.000 6.184 16.1 1 1 ,972 (psi) @ 9.10 (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 4:05:30 PM .' . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 SUPERVISOR Randy Ratliff FIELD NAME WILDCAT-FOR UNNAMED FIELD IGL 30.6 I 74.00 RIG NAME & NO. Nabors 273E 24 HR PROG TMD 17,575 AUTH MD TVD IDFS IDOL IRPH DATE 9,642 I 83 117 I 117 A 09-Feb-2004 WBS SAPIWBS COST DX0309030CAPCMP01 - MOC WI NRI I DAILY WELL COST I CUM WELL COST 100.0000 I - - I NEXT C~"II'" ILEAKOFF 17,502 (ft) I (in) @ 0 (ft) KB R!G PHONE STATE/PROV Alaska CURRENT STATUS 1 MTS Runnino dual production tubino strinos (â) 2462'. OPERATION COMMENTS LDDP and BHA. PIU FORMation Junction dual seal module and dual production packer assembly. tubing. 907-260-6935 COUNTY/OTHER I LAST CASING I 3.500 (in) @ 24 HR FORECAST Running dual strings of 3-1/2" production MANHRS WORKED I ACCIDENT TYPE ¡LAST SAFETY MTG 259.00 None 2/9/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Laying down drill pipe. Running tubing, communication. SAFETYSlJMMARY IBOP PSI TEST ¡LAST STOP CARD AUDIT I REGULATORY INSP? 112/15/2003 12/17/2003 N I LAST RIG INSPECTION 112/11/2003 Ofl.ERATIONSS.LJ.MMARY FROM TO HRS FROM TO SUB. PHASE OP TRBL DESCRIPTION . 06:00 15:30 9.50 17,575 17,575 TA OTHER TRIP PKRD Lay down 5-1/2" and 4" drill pipe. 15:30 16:00 0.50 17,575 17,575 TA OTHER TRIP PKRD RID laydown machine. 16:00 17:00 1.00 17,575 17,575 TA OTHER TRIP PKRD LID jars and HWDP. LID 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 17,575 17,575 TA OTHER CLEAN PKRD Clear rig floor, LID excess tools and equipment. 18:00 20:30 2.50 17,575 17,575 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 17,575 17,575 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 17,575 17,575 TA OTHER TRIP PKRD RlU 3-1/2" dual tubing handling equipment. 21:30 22:00 0.50 17 ,575 17,575 TA OTHER TRIP PKRD LID 2 stands of 3-1/2" tubing out of derrick. 22:00 01:00 3.00 17,575 17,575 TA OTHER TRIP PKRD Hold safety meeting. PIU dual seal module I GT production packer assembly. M/U custom made clamp on top of packer, torque 16 set screws to 51 ftllbs each. 01:00 01:15 0.25 17,575 17,575 TA OTHER SAFETY PKRD Hold safety meeting. 01 :15 06:00 4.75 17,575 17,575 TA OTHER TRIP PKRD TIH with dual strings of 3-1/2" 9.3# H533 production tubing to 2462'. DENSITY(ppg) I FV PVIYP I 8.65 I PP I GELS I WUHTHP I I I I I IE CD I 1MLJD DATAl DAILY COST I FC/T.SOL OIW %Sand/MBT I Ph/pM I Pf/Mf I I I I I I I I I Cl/Ca 29,500 I I CUM COST ICaCI2(wt%j H2S I I LIME I ES I 6RPM I I BHA BHA NO. I LENGTH IEPf Wr. PICKUP I SLACK ()FM ROT vvr·l"n5RQUE(max/min) IBHA HR$IJÄRHRS IMVVD HR$IMTRHRS IS$HRS 42 I 110.23 I I I I I I I I I I BHA DESCRIPTION Junk Basket Junk Basket, Junk Basket, Cross Over, Bumper Jar Hydraulic Jar, 2 JTS 5" HWDP , Accelerator Jar Cross Over Cross Over Printed: 4/29/2004 4:05:32 PM · WELL NAME KASILOF SOUTH 1 AVG. CONN: MAX. CONN: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids SERVICE e MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas MUD GAS AVG. TRIP: MAX. TRIP: units AVG. BKGRD: MAX. DRL: PERSONNEL DATA NO. HOURS COMPANY 12 155.00 Baker Oil Tools 1 12.00 R&K Industrial 2 12.00 Weatherford 2 12.00 SERVICE 3 36.00 2 8.00 4 24.00 NEXT BOP TEST: 12/22/2003 1,972 (psi) @ 9.10 (ppg) (psi) @ (ppg) 10,533 17,502 5,417 9,603 29.00 9.30 L-80 L-BO 8,160 10,160 Printed: 4/29/2004 4:05:32 PM . e MJSiRJSimHONOIL aOMPJSiNY Pqgß1···of1 Dªilyadmplêtion.iRêþo.rt E)¡ÇþloitªtìQÔ..ßÇ\$ WELL NAME KB IGL 24 HR PROG TMD TVD [DFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 84 118 118A 10-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS s....nnAIQQ r:nST Randv Ratliff Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI I DAILY WFI I "n"T ~M WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Waitinq on weather, due to excessive wind qusts. OPERATION COMMENTS Continue running 3-1/2" dual production tubing strings. SAFEmYisl.JMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I~OP PSI TEST I LAST STOP CARD AUDIT REGULATORY INSP? I LAST RIG INSPECTION 267.00 None 2/9/2004 12/15/2003 12/17/2003 N 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Tripping pipe, handling 2 tubing strings. .^........ ···~~.S~.~..~.M.~.R'( .. ,.Þi HR.S FROM "þ $Úâ pfiAà~ .~ .. . "~.,, TRBL 06:00 08:30 2.50 17,575 17,575 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 17,575 17,575 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 17,575 17,575 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 17,575 17,575 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 17,575 17,575 TA OTHER WAIT PKRD Wait on weather. Ipp IEeb IM!.JDO~mÄI.. .[)AIl.Y99~tl 1·.·¢qMqº~T·.· -----. : DENSITY(ppg) 8.65 FV PVIYP GELS I WIilHTHP I FC/TiSOL om '(.$~~!I/MBTI ·PÞ/pM ·1 pj(Mfi I QliQ& iH2S 4!1VU;1 E$:I$BP!~ 1 I I I I I 1 I I I I I I 29,500 I I I I MUÐGAS I Qt"lt~ units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: NÔ;P¡_ ... ~ .. Nabors Alaska Drilling 12 155.00 R&K Industrial 1 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 CASINGiSUMMARY LAST BOP TEST: 12/15/2003 LAST CASING TEST: NEXT BOP TEST: 12/22/2003 SIZE (in) ID (in) SHOE TEST (ppa) MAXSICP MD (ft) TVD(ft) WT (Îb/ft) GRADE . EH.JRST(pSi) 7.000 6.184 16.11 1,972 (psi) @ 9.10 (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 4:05:34 PM WELL NAME KASILOF SOUTH 1 . . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas CASING)SUMMA LAST CASING TEST: MAXSICP MDft 1,972 (psi) @ 9.10 (ppg) 10,533 (psi) @ (ppg) 17,502 NEXT BOP TEST: 12/22/2003 5,417 9,603 8,160 10,160 29.00 L-80 9.30 L-80 Printed: 4/29/2004 4:05:35 PM . . MARA"I!1HCDNCDU..6CDMPANY Pª9Ef lÔf2 D~ i IYPPrtl pIØtionRE).p.òrt I;xplòitatiQn-G;;t$ WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 85 119 119A 11-F eb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Russ Truby Nabors 273E DX0309030CAPCMP01 --~ FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST J CUM Wt:LL VV_. , WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 .20 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I Lc""OFF Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST SpacinQ out and pickinQ up hanger. Land hanQer, test seals, NU and test tree. OPERATION COMMENTS Continue running dual 3 1/2" production tubing strings. 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 267.00 None 2/9/2004 12/15/2003 12/17/2003 N 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Icy location, slipping hazards. IFRØ~ "fp HRS FRq~ T9 .$',!~ ~ .1"R~P ii 06:00 13:00 7.00 17,665 17,665 TA OTHER TRIP PKRD Continue running dual strings of 3 1/2",9.3 ppf, Hyd 563 tubing, checking each connection to 4500 ft-Ibs. 13:00 14:00 1.00 17,665 17,665 TA OTHER EQUIP PKRD RU to run injection lines. 14:00 15:00 1.00 17,665 17,665 TA OTHER TRIP PKRD Install dual injection mandrels in string at 2500'. Connect injection line to lower mandrel and test to 1000 psi. 15:00 16:00 1.00 17,665 17,665 TA OTHER TRIP PKRD Lower mandrel hung up in dual slips, work to free mandrel. 16:00 17:00 1.00 17,665 17,665 TA OTHER TRIP PKRD Connect injection line to upper mandrel, unable to test line to 1,000 psi. Bad rupture disk in mandrel. 17:00 18:00 1.00 17,665 17,665 TA OTHER WAIT PKRD Wait on new injection mandrel from town. 18:00 05:00 11.00 17,665 17,665 TA OTHER TRIP PKRD 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. 05:00 06:00 1.00 17,665 17,665 TA OTHER TRIP PKRD Space out with pup joints and M/U dual tubing hangers. I Pi=! I H~¢ÞI IM(JDt)A"~I.[)~lt'("êP.. I ç.s!~(... 1 1]I~í':I - 8.65 oiV! .O¡·Sån~~&T·I··· i=!hÎpr.1.·.··I··· Pf . ~v ··pviYP Gglis.1 'n'" I ··.yJ/cci· E$IßRf'~ / I I I I I I I I I I I 29,500 I I I I I MUD GAS I .VNI"fS I units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL PERSC:>NNELDATA POB@06:0Q: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS 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 Printed: 4/29/2004 4:05:35 PM WELL NAME KASILOF SOUTH 1 DENSITY(ppg) 8.65 FV PVIYP GELS AVG. CONN: MAX. CONN: COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids . . MARATHON OIL COMPANY Page 2 of 2 Daily Completion Report Exploitation - Gas MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: SERVICE RERSONNELDATA NO. HOU.RS COMPANY 12 155.00 Baker Oil Tools 3 30.00 R&K Industrial 2 12.00 Weatherford 2 12.00 Pollard Wireline 3 36.00 2 12.00 2 24.00 2 24.00 CASING SU MARY LAST CASING TEST: 6.184 2.992 NEXT BOP TEST: 12/22/2003 8,160 10,160 1,972 (psi) @ 9.10 (ppg) (psi) @ (ppg) 10,533 17,502 5,417 9,603 29.00 9.30 L-80 L-80 Printed: 4/29/2004 4:05:37 PM . . M~a~T'H(¡)N····()lL..····P()MR~N¥ Da.UyPOr1)þletiQI'1Report E)(ploit~tion - Gas WELL NAME KB IGL 24 HR PROG TMD TVD IDFS IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 17,575 9,642 86 120 120A 12-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Russ Trubv Nabors 273E DX0309030CAPCMP01 FIELD NAME RIG PHONE MOCWI NRI 1 DAILY WELL COST J cur" WELL <.;u;, I WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 - STATE/PROV COUNTY/OTHER 1 LAST CASING I NEXT CASING I LEAl\. Un Alaska 3.500 (in) @ 17,502 (ft) (in) @ 0 (ft) CURRENT STATUS / MTS 124 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. SAFEEJ"YSUMMARY MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG l~oP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 305.00 None 2/9/2004 12115/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: ND and pinch points _IP iHå$ - .·TC) $q~ </~ 06:00 09:00 3.00 17,665 17,665 TA OTHER TRIP PKRD LID 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 17,655 TA OTHER TRIP PKRD Make penetration of control line through hangers. 09:30 10:00 0.50 17,655 17,655 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 only 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 sec 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 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 mouse hole. 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 4:05:37 PM . . c:2éJ ¿ - ðt-5 r. MARATHmN··.mILuemMPANY D~iIY ..GomPI~tioIiRøÞÞr1: Exploitation"(;éJ$ WELL NAME KB IGL 24 HR PROG TMD ND IDFS IDOL RPT# DATE KASILOF SOUTH 1 30.6 74.00 17,665 10,000 87 121 121A 13-Feb-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Russ Trubv Nabors 273E DX0309030CAPCMP01 '-- FIELD NAME RIG PHONE MOCWI NRI DAILY WELL COST ! CUM WELL COST WILDCAT-FOR UNNAMED FIELD 907-260-6935 100.0000 1 STATElPROV COUNTY/OTHER I LAST CASING I NEXT CASING I LEAKOFF Alaska 3.500 (in) (Q) 17,502 (ft) (in) (Q) 0 (ft) CURRENT STATUS / MTS 24 HR FORECAST Ria released at 0000 hrs 2/13/2004 OPERATION COMMENTS ND BOPs. NU and test tree. Rig released OOOOhrs 1/13/2004. SAFETYStlMMARY MANHRS WORKED I ~CCIDENT TYPE I LAST SAFETY MTG ¡BOP PSI TEST I LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 200.00 None 2/9/2004 12115/2003 12/17/2003 12/11/2003 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Rigging down i~~ ~ ~ .... FROM TO HR$ FR~M 19 ..i§lJß ... 06:00 08:30 2.50 17,665 17,665 AF RCMP NUND Finish ND BOP and remove from sub. 08:30 18:00 9.50 17,665 17,665 AF RCMP NUND 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. 18:00 00:00 6.00 17,665 17,655 AF RCMP RIG 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. Rig released 0000 hrs 2/13/2004. Diesel on rig at release 2618 gals, at 1.33 $/gal inc. tax. DENSI!Y(PR!J)! 8.65 I pp I l¡;çÖI 1.·MU]).·PÄifA.I·..·[)~!(.;"(9þ§t·.·.1 I FV PYNP I GELS WL/I-I,.8pl FCIT.SOL OIW %S~nd/MBTI Ph/pM jkf/Mf J dliG" )-12$ ËIMgliE$I$i'{pM I I I I I I I I I I I / I 29,500 I I I I I MUD/GAS I '\JNl"rs I units AVG. CONN: I AVG. TRIP: I AVG. BKGRD: MAX. CONN: MAX. TRIP: MAX. DRL: . PERSONNELDAifA POB@ Q6:QO: COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Nabors Alaska Drilling 12 155.00 R&K Industrial 1 6.00 Marathon 1 12.00 Weaver Brothers (WBI) 2 4.00 Epoch Well Services 2 12.00 ABB Vetco Gray 2 5.00 M-I Drilling Fluids 1 6.00 Printed: 4/29/2004 4:05:38 PM . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas . WELL NAME KASILOF SOUTH 1 CASINGSU MARY LAST CASiNG TEST: MAXSICP MD ft 1,972 (psi) @ 9.10 (ppg) 10,533 (psi) @ (ppg) 17,502 NEXT BOP TEST: GRADE L-80 L-80 12/22/2003 BURST si 8,160 10,160 Printed: 4/29/2004 4:05:38 PM . . ~02 -~Sç, Kasilof South 1 Completion Report (Reports 1 - 18) . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 SUPERVISOR Tom Kloberdanz FIELD NAME KB 24 HR PROG TMD TVD RPT# DATE 1 05-Mar-2004 ¡¡APIWBS COST 30.6 RIG NAME & NO. AUTH MD WBS WILDCAT-FOR UNNAMED FIELD STATElPROV COUNTY/OTHER 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. MOC WI NRI 100.0000 DX0309030.CAP .CMP .02 I CUM WELL C051 RIG PHONE ui ment, berm liner. Spotted Halliburton Well Test Equipment. MANHRS WORKED 38.00 ACCIDENT DESCRIPTION: ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? N SAFETY MTG TOPICS: Slips, trips, and falls COMPANY SERVICE Artic Slope Regional Cor PU Liner and berm Halliburton Well Testers 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. Haul Supervision 3.500 CA ING SUMMARY LAST CASING TEST: MAX SICP ft (psi) @ (ppg) 17,504 NEXT BOP TEST: Printed: 4/29/2004 4:07:13 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KB KASllOF SOUTH 1 30.6 SUPERVISOR RIG NAME & NO. Ken Walsh FIELD NAME RIG PHONE WilDCAT-FOR UNNAMED FIELD STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Ri in u Halliburton Flow Test E ui ment. OPERATION COMMENTS Rigging up Halliburton Flow Test Equipment. 24 HRPROG TMD TVD RPT# DATE 2 06-Mar-2004 AUTH MD WBS SAPIWBS COST DX0309030.CAP.CMP.02 MOC WI NR! I CUM n___ ___. 100.0000 MANHRS WORKED 26.00 ACCIDENT TYPE LAST SAFETY MTG None SAFETY S BOP PSI TEST REGULATORY INSP? N LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM 08:00 Artie Slope Regional Cor Halliburton lAST BOP TEST: 3.500 Printed: 4/29/2004 4:07:14 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas KASILOF SOUTH 1 SUPERVISOR Ken Walsh FIELD NAME WILDCAT-FOR UNNAMED FIELD ST A TE/PROV Alaska CURRENT STATUS / MTS Ri in u Halliburton Well Test E ui ment. OPERATION COMMENTS Rigging up Halliburton Well Test equipment and lines. 30.6 RIG NAME & NO. 24 HR PROG TMD TVD RPT# DATE 3 09-Mar-2004 SAPIWBS COST WELL NAME KB RIG PHONE MOCWI 100.0000 NRI DAILY WELL COST J CUM WELL COST NEXT CASING """"V, , AUTH MD COUNTY/OTHER Set as buster Laying liner and berm. REGULATORY INSP7 N LAST RIG INSPECTION MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 37.50 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Hammering up pipe. FROM TO 08:00 17:00 9.00 SUB AF OPERAT PHASE MIRU TEST Artie Slope Regional Cor PU Liner and berm Halliburton Well Testers 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. CASING SU MARY LAST CASING TEST: MAX SICP (psi) @ (ppg) Printed: 4/29/2004 4:07:15 PM · MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas RPT # DATE 4 10-Mar-2004 SAPIWBS COST WELL NAME KB 24 HR PROG TMD TVD KASILOF SOUTH 1 30.6 SUPERVISOR RIG NAME & NO. AUTH MD Ken Walsh FIELD NAME RIG PHONE MOC WI NRI 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. L.t;I"'n......, . CUM WEL' cu:; I L .- MANHRS WORKED 61.00 ACCIDENT TYPE LAST SAFETY MTG None REGULATORY INSP? N LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Slipping on ice and liner. 08:00 12:00 4.00 AF MIRU TEST 12:00 17:00 5.00 AF MIRU TEST 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 Artic Slope Regional Cor Halliburton Marathon SERVICE PU Liner and berm Well Testers Supervision PERSONNEL DATA NO. HOURS COMPANY 3 18.00 Veco Alaska 4 18.00 Cook Inlet Safety 1 4.50 Udelhoven Oilfield Syste SERVICE: Roustabouts LEL Monitoring Equipme Electrician 2 2 1 10.00 6.00 4.50 eASIN.G l.IMMARY LAST CASING TEST: MAXSICP MD ft (psi) @ (ppg) 17,504 Printed: 4/29/2004 4:07:18 PM WELL NAME KB KASILOF SOUTH 1 30.6 SUPERVISOR RIG NAME & NO. Ken Walsh FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STATE/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. TVD RPT # DATE 5 11-Mar-2004 SAPIWBS COST AUTH MD WBS DX0309030.CAP .CMP .02 MOCWI 100.0000 NRI CUM WI:LL COST I MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG 50.50 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Electrical Hazards. SAFETY SUMMARY BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? N LAST RIG INSPECTION 08:00 13:00 5.00 AF MIRU TEST 13:00 16:00 3.00 AF MIRU TEST Artic Slope Regional Cor Halliburton Marathon Veco Alaska PU Liner and berm Well Testers Supervision Roustabouts 2 4 1 2 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. 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 Cook Inlet Safety Udelhoven Oilfield Syste Veco Alaska LEL Monitoring Equipme Electrician Vac Truck 3.00 3.00 2.00 CAS1NG·.SUMMARY LAST CASING TEST: MAX SIC? MD ft (psi) @ (ppg) 17,504 Printed: 4/29/2004 4:07:19 PM · . MARATHON OIL COMPANY Page 1 of 2 Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 SUPERVISOR Ken Walsh I Crai Meese FIELD NAME KB 24 HR PROG TMD TVD RPT # DATE 6 12-Mar-2004 SAPIWBS COST 30.6 RIG NAME & NO. AUTH MD WBS RIG PHONE MOCWI 100.0000 NRI CUIII, ..___ __¥' WILDCAT-FOR UNNAMED FIELD STATEIPROV Alaska CURRENT STATUS 1 MTS RIH with motor assembl on CT OPERATION COMMENTS MIRU BJ Coil Tech to clean out wellbore with a motor and mill. Test lines, BOP, and well test lines. MU motor assembly and RIH. COUNTY/OTHER LEAKOI"I" MANHRS WORKED ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST 311.50 None 3/11/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pressure testing operations, slips, falls LAST STOP CARD AUDIT REGULATORY INSP? N 08:00 08:30 AF WBCO SAFETY Held Prejob Safety Meeting. 08:30 12:00 AF WBCO CLTBG MIRU BJ CoilTech Coiled Tubing Equipment and Veco 45-ton crane. Spotted equipment. Offloaded injector head, hoses, lubricator, and BOP. Veco vac truck filled Rain-for-Rent tank with fresh water blended with 1 gpt BJ FRW-14 friction reducer and and Steam-on-Wheels heated to 80 deg. Mike's delivery delivered water and cooler. Connected 1-1/2" tapered coil tubing string (0.156 wall to 0.125 wall OT 900) to injector head. Layed out and made up BJ fluid lines. Halliburton pressure tested flowback lines to well to 100 psi with air. 12:00 21:00 9.00 AF WBCO CL TBG Changed out tree cap connection to 3-1/8" 5K x 3-1/16" 10K crescent flange. PU and MU BJ flowcross and lubricator to treetop flange. PU and MU coil tubing BOP to flow cross. PU and MU lubricator to BOP. PU injector head. Displace CT to methanol water. Pig CT. Pull test of CT to 20,000 lb. Test CT to 250/4500. Make up injector head. 20:00 23:30 3.50 AF WBCO CL TBG PJSM. Test lines 250/5500. Test pipe rams 300/4500. Test aux rams 300/4500. Test blind rams and flow back iron 250/4500. 23:30 01:30 2.00 AF WBCO CL TBG Break lubricator. MU Weatherford BHA as follows: 2.20" aD 1-1/2" Coil Connector, 2.20" aD Dual Check Valve, 2.25" aD 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" aD 5 Bladed Junk Mill. MU lubricator. Shell test BOP stack 250/4500 psi. 01:30 03:00 1.50 AF WBCO CL TBG Displace methanol water from CT. Confirm motor operating. 03:00 06:00 3.00 AF WBCO RIH breaking circ every 15 min: 3000' wt check 4400 Ibs 6000' wt check 7500 Ibs 9000' wt check 10500 Ibs 9850' wt check 11500 Ibs Printed: 4/29/2004 4:07:20 PM WELL NAME KASILOF SOUTH 1 FROM 03:00 06:00 3.00 COMPANY BJ Services Halliburton Marathon Veco Alaska LAST BOP TEST: 3.500 FROM SERVICE Coil Tubing Well Testers Supervision Crane Operator MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas DATE 12-Mar-2004 TO SUB AF OPERATIONS SUMMARY PHASE OP TRBL WBCO DESCRIPTION Note: No indication of restrictions/debris through liner top. 10400' wt check 12000 Ibs 10900' wt check 12200 Ibs 11400' wt check 12300 Ibs 11900' wt check 12400 Ibs PERSONNEl..ÐATA NO. HOURS C.QMPANY 6 144.00 Cook Inlet Safety 2 48.00 Steam on Wheels 2 24.00 Veco Alaska 2 24.00 Weatherford LEL Monitoring Equipme Steam Vac Truck CT BHA 1 1 1 2 4.00 12.00 7.50 48.00 NEXT BOP TEST: Printed: 4/29/2004 4:07:20 PM . . MARATHON OIL COMPANY Daily pletio Exploitation WELL NAME KASILOF SOUTH 1 SUPERVISOR Ken Walsh I Crai Meese FIELD NAME KB 30.6 RIG NAME & NO. RIG PHONE port TVD DATE 13-Mar-2004 SAPIWBS COST AUTH MD MOC \0"/1 NRI I CUM WELL COST WILDCAT-FOR UNNAMED FIELD 100.0000 STATElPROV COUNTY/OTHER LEAKOFF Alaska CURRENT STATUS / MTS Tem oraril sus end 0 erations Kasilof State #1rd. OPERATION COMMENTS RIH with mill, motor, jars on coil tubing to 17,231' CTM, milling low side cement stringers from 14,615' - 17,231'. Circ 2X BU. POOH with C/T. Temporarily suspend operations Kasilof State #1 rd. MANHRS WORKED 229.00 ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST None 3/11/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: FROM TO 06:00 08:30 2.50 AF WBCO CL TBG 08:30 14:00 5.50 WBCO CL TBG AF 14:00 19:00 5.00 AF WBCO CL TBG 19:00 21:30 2.50 21 :30 02:00 4.50 02:00 03:00 1.00 WBCO CL TBG AF WBCO WBCO CL TBG CL TBG AF AF LAST STOP CARD AUDIT REGULATORY INSP? N RIH with mill, motor, and hydraulic jars on 1-1/2" coil tubing fro 12,400' to 14,615' without pumping. Tagged up on restriction. PUH 50' and started pumping fresh water with friction reducer at 1.3 BPM with good returns. RIH at 10-20 fpm pumping 1.3 BPM slick fresh water working through multiple cement stringers (drilling off quickly-appears to be cement on the low side of the casing). Obtaining modest cement returns. Stalled motor at 14969'; 15752'; 15,842'; and 16585'. RIH to 16,661' pumping and milling. Increased fluid rate to 1.5 BPM and continued RIH with motor and mill. More stringers but still running at 200-300 FUhr. Increased weight checks from every 150' to every 50'. Performed weight checks while pulling up hole 50' to clean hole. Milled low-side cement stringers from 16661'-17196'. Weight checks as follows: 16661'- 29000 # 16801'- 29000# 16900'- 29800# 17020'· 32300# 17056'- 32400# 17106'- 33400# 17156'- 34000# 17206'- 35000# 17231'- 37000#: PU 50' and mill back down to 17231' 17231'- 36000# PU to 17265'. Circ 2X BU (225 bbls) @ 17221'. Move CT uphole 100' every 50 bbls pumped. POOH with C/T while circulating 1.5 BPM. Displace CIT with methanol water. Blow lines dry across tree. Printed: 4/29/2004 4:07:21 PM MA pletion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 DATE 13-Mar-2004 FROM TO HRS 03:00 04:00 1.00 FROM SUB AF OPERATIONS SUMMARY PHASE OP TRBL WBCO CL TBG DESCRIP"ION Break 3-1/16" 10K flange connection below flow cross. PU stack. Move to lateral side of dual tree (Kasilof State #1 L 1). Temporarily suspend operations on Kasilof State #1rd. COMPANY BJ Services Halliburton Marathon SERVICE Coil Tubing Well Testers Supervision PERSONNEL DATA NO. HOURS COMPANY 9 103.00 Veco Alaska 2 22.00 Veco Alaska 2 22.00 Weatherford Crane Operator Vac Truck CT BHA 2 2 2 22.00 16.00 44.00 NEXT BOP TEST: Printed: 4/29/2004 4:07:21 PM . . MAR L COMPANY Daily Completion Report Exploitation w Gas WELL NAME KB KASILOF SOUTH 1 30.6 SUPERVISOR RIG NAME & NO. Ken Walsh I Crai Meese FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STATBPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Pre are to PIU BHA & test efT BOP's. OPERATION COMMENTS Prep for venturi junk basket cleanout run. 24 HR PROG TMD TVD RPT# DATE 8 14-Mar-2004 AUTH MD WBS SAPIWBS COST DX0309030.CAP .CMP .02 MOC WI NKi DAILY WELL COST I CUM WELL COST 100.0000 LEAKOFF MANHRS WORKED 18.00 ACCIDENT TYPE LAST SAFETY MTG None 3/11/2004 REGULATORY INSP? N LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: 04:30 05:30 1.00 WBCO CL TBG Install 3-1/8" 5K x 3-1/16" 10K flange to top of tree. Move C/T stack from Kasilof State # 1 L 1 (Lateral) back to Kasilof State #1rd (Motherbore). MU 3-1/16" 10K flange connection below flow cross of CIT stack. Break lubricator, layout and inspect motor assembly. 05:30 06:00 0.50 WBCO CL TBG BJ Services Halliburton Marathon Coil Tubing Well Testers Supervision LAST BOP TEST: LAST CASING TEST: (psi) @ (ppg) NEXT BOP TEST: Printed: 4/29/2004 4:07:22 PM . . PANY Daily Completion Report Exploitation· Gas WELL NAME KASILOF SOUTH 1 SUPERVISOR Ken Walsh I Crai Meese FIELD NAME KB 24 HR PROG TMD TVD 30.6 RIG NAME & NO. AUTH MD RIG PHONE MOCWI NRI DATE 15-Mar-2004 SAPIWBS COST ¡CUM WELL COSl WILDCAT-FOR UNNAMED FIELD 100.0000 STATE/PROV COUNTY/OTHER LEAKOFF Alaska CURRENT STATUS / MTS Tem oraril sus end 0 erations Kasilof State #1rd OPERATION COMMENTS PU and RIH with Venturi junk basket on CIT and cleanout well bore to 17,246'. Spot 6% KCL water from 17,216' - 13,878' MD. POOH with CT and venturi junk basket. LDand inspect contents of junk basket. Temporarily suspend operations Kasilof State #1rd. MANHRS WORKED 240.00 ACCIDENT TYPE LAST SAFETY MTG None 3/14/2004 REGULATORY INSP? N ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Electrical and wind hazards. LAST RIG INSPECTION 06:00 07:30 1.50 AF WBCO CL TBG 07:30 08:00 0.50 AF WBCO SAFETY 08:00 10:00 2.00 AF WBCO CL TBG 10:00 10:30 0.50 AF WBCO CL TBG 10:30 11:00 0.50 11:00 11:30 0.50 11:30 19:00 7.50 AF WBCO CL TBG AF AF WBCO WBCO CLTBG CLTBG Changed out stripper rubber on CT grease head. Attempted to test CT BOP's-shut down to tighten flange connection below BOP to riser spool. Held Prejob Safety Meeting. Performed successful BOP test with methanol water: 250 psi/4500 psi pipe, safety, and blind rams. Bled off pressure. R&K vac truck finished emptying flowback tank. Broke lubricator and PU Weatherford venturi junk basket with 8' extension and 2.850" mule shoe guide, hydraulic disconnect, dual acting jars, dual checks, and 1-1/2" coil connector. Set CT at GL to 30' KB. MU lubricator and opened master valves. Shell tested BOP and lubricator to 1000 psi with 50/50 methanol water. Displace methanol water from CT with fresh water. Run in Hole with venturi BHA on Coiled Tubing. Started pumping fresh water at 1 BPM while continuing to run in hole. No problem through smallest ID of 2.887" at chemical injection nipple at 2544' MD. Made following weight checks while RIH pumping fresh water at 1 BPM: 3000'wtcheck-3200# 6000'wtcheck-6300# 9100' wt check- 9500# 9900'wtcheck-10500# 10500' wt check- 11000# 11000'wtcheck-11000# 11500'wtcheck-11800# 12000'wtcheck-12500# 13100' wt check- 14500# 13600' wt check- 15000# 14000' wt check- 15500# 14500'wtcheck-16500# 15000' wt check- 17000# 15500' wt check- 18500# 16000' wt check- 19500# 16500'wtcheck-21000# Increase rate to 1.2 B PM 17000' wt check- 21500# Printed: 4/29/2004 4:07:24 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 DATE 15-Mar-2004 OPER.AfflQNSSUMMARY TO SUB PHASE OP TRBL AF WBCO CL TBG 17206' wt check- 21500# 17246' Tag, not washing off: wt check 22000# 17246' Re-tag, not washing off: wt check 22500# PU to 17216'. Circ 29 bbl 6% KCL from vac truck and displace out end of CT to back side in order to spot 6% KCL across interval 17246' - 13878'. SD circ and POOH (50fpm to liner and 75 fpm in tubing). Blow lines dry across tree. Break out lubricator. LD and inspect contents of venturi junk basket and screen. Found +1- 2 cups debris as follows: - +1- 20 pieces - 1" x 1" cement sheaths - smaller pieces and ground cement - several small pieces metal to 1" AF WBCO CL TBG Install nozzel to CIT and MU lubricator. Displace C/T with methanol water. AF WBCO Break 3-1/16" 10K flange connection below flow cross. PU stack. Move to lateral side of dual tree (Kasilof State #1 L 1). Temporarily suspend operations Kasilof State #1rd. FROM TQ HRS 11:30 19:00 7.50 19:00 20:20 1.33 AF WBCO CL TBG 20:20 01:00 4.67 AF WBCO CLTBG 01:00 01:30 0.50 AF WBCO CLTBG 01 :30 02:00 0.50 02:00 02:30 0.50 BJ Services Halliburton Marathon Coil Tubing Well Testers Supervision Printed: 4/29/2004 4:07:24 PM , .,. M~RA:mløNQlb,GØMP~N¥ Páge··.1 t>·íiI·ilyeornÞl~tiQh'~~ por¡t E:~pJoitatiOI'l·.~·ßa~ WELL NAME KB IGL 24 HR PROG TMD TVD IDFSO IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 10 10 17-Mar-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Ken Walsh / Craig Meese DX0309030.CAP .CMP .02 - FIELD NAME RIG PHONE MOCWI NRI I DAILY WELL COST !eUMy..___~_M WILDCAT-FOR UNNAMED FIELD 100.0000 ~ 17,504 (ft) I NEXT -"-"ìTn) @ 0 (ft) I LEAKOFF - STATElPROV COUNTY/OTHER I LAST CASING Alaska 3.500 (in) @ CURRENT STATUS / MTS 24 HR FORECAST Run memory cased hole logs on WL tractor 17220' to 12500' Suspend oDerations. Move to KS #1 L 1 OPERATION COMMENTS MIRU Reeves wireline and Well Tee tractor. Logged memory CBLlSonic/Density/Neutron from PBTD of 17,220 to 12500' MD. POOH and downloaded data. ......... " . ... i~ð. , .. ..T. " .... MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG I BOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 179.00 None 3/14/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: -- ~ ....... ... . ~ij9ry1i ;rQ HB$ FR9M "TO "~þ~ ... 09:30 11:00 1.50 AF OTHER LOG MIRU Reeves cased hole logging and WellTec wireline tractor. Reeves calibrated tools and then spotted wireline unit. 11 :00 11:30 0.50 AF OTHER SAFETY Held Prejob Safety Meeting with Reeves, WellTec, and Veco personnel. 11:30 13:00 1.50 AF OTHER LOG Changed out swab valve flange from blind to 3-1/8" 5K x 6-1/2" Otis. MU Pollard rental crossover and flowtee to Otis connection. MU MOC chicksan to flow tee (chicksan connected to choke manifold and then to flowback tank). 13:00 15:00 2.00 AF OTHER LOG PU 2.25" aD Reeves cased hole memory logging tools: (GRlCCLlNeutron/Density/CaliperlSonic) and WellTec's 2-1/8" OD wireline tractor with Veco crane. Placed battery pack in memory sub at 13:37:38 hrs. Overall length of logging tools is 73.07'. Overall length of tracto is 20.33'. 15:00 17:00 2.00 AF OTHER LOG RIH with cased hole logging tools making weight checks to hard tag at 17,220' MD loggers MD. Did not have to engage tractor to get to PBTD. No obstructions noted while RIH. 17:00 20:00 3.00 AF OTHER LOG PUH logging to 12,500' MD. 20:00 22:00 2.00 AF OTHER LOG POOH and lay down tractor. Cable head wet, dry out cable head and fill with new grease. RU re-built cable head to tractor and active to confirm cable head integrity. 22:00 00:00 2.00 AF OTHER LOG Lay down and isolate nuclear sources. Download data from memory logging tools. Begin depth-time correlation of memory logs. Temporarily suspend operations on KS #1rd and shift to KS #1 L1 for cased hole logging operations. 00:00 06:00 6.00 AF OTHER WAIT Perform cased hole logging operations on KS #1 L 1. PERSONNEL DATA POB@O§:Q(): COMPANY I SERVICE NO. HOURS II COMPANY I SERVICE I NO. I HþIJRS Reeves Wireline I Wire line logs 2 96.00 II Halliburton I Well Testers I 1 I 24.00 Printed: 4/29/2004 4:07:28 PM . WELL NAME KASILOF SOUTH 1 COMPANY Marathon Veco Alaska SERVICE Supervision Crane Operator . MARATHON OIL COMPANY Daily Completion Report . Exploitation - Gas DATE 17-Mar-2004 PERSONNEL DATA NO. HOURS COMPANY 2 24.00 R&K 2 19.00 Vac Truck Printed: 4/29/2004 4:07:28 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation· Gas 30.6 RIG NAME & NO. 24 HR PROG TMD TVD RPT# DATE 11 19-Mar -2004 SAPIWBS COST WELL NAME KASILOF SOUTH 1 SUPERVISOR Ken Walsh I Don E non FIELD NAME KB AUTH MD WBS RIG PHONE MOC WI NRI 100.0000 I CUM WI:LL ¡;U:S , WILDCAT-FOR UNNAMED FIELD STATE/PROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Jet KS #1 rd d with CT and tra N2 ressure. OPERATION COMMENTS RIH with BJ CT. Jetted well dry to 17,210' KB. LI:.A~Vrl'" March 22nd, 2004 MANHRS WORKED ACCIDENT TYPE 164.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Trip hazards, ice plugs, looking out for the other guy Trapped 1770 psi nitrogen pressure. RDMO BJ CT, Suspend operations. BOP PSI TEST LAST STOP CARD AUDIT REGULATORY INSP? N LAST RIG INSPECTION 08:00 08:30 0.50 AF WBCO SAFETY Held Prejob Safety Meeting with all personnel on location. Reviewed and signed work permit. Discussed hazard prevention and job outline. 08:30 10:00 1.50 AF WBCO CLTBG Check jetting nozzle, straight bar, and double flappers for plugging agent. Found two ports plugged with ice. PU BJ Coiltech injector head, BOP, and riser as entire assembly from KS #1 L 1 and MU to swab valve flange on KS #1 rd. Load CT with methanol water for BOP pressure test. 10:00 12:30 2.50 AF WBCO CL TBG Pressure tested CT BOP's to 250/4500 psi with methanol water. Cooled down nitrogen unit. Displaced methanol water to tank with nitrogen. 12:30 17:00 4.50 AF WBCO CL TBG Open well and RIH with 1-3/4" OD wash nozzle, 4' long straight bar, and double checks on 1-1/2" OD coil tubing pumping nitrogen at minimum rate (to prevent CT collapse). Pull Weight Checks: 3100' - 2000# 14200' - 9000# 6200' - 4200# 15300'- 10900# 9800' - 6000# 16150'- 12000# 11000' - 6800# 17000' - 14000# 12000' - 7100# 17216' - 14500# 13100' - 8500# Tag depth is 17216' KB. 17:00 18:00 1.00 AF WBCO CL TBG Increased nitrogen pump rate from 500 scfm to 1500 scfm at 3800 psi. Pumped for 30 minutes recovering 142 out of 149 bbl calculated capacity. 18:00 20:30 2.50 AF WBCO CL TBG Lined up nitrogen to BJ kill line. Stopped flowing well and continued pumping nitrogen while pulling out of hole with CT. Trapped 1770 psi nitrogen surface pressure in well bore for underbalance perforating. Held joint safety meeting outlining safe operations for rig down with high winds and cold Printed: 4/29/2004 4:07:31 PM FROM TO HRS F~OM 18:00 20:30 2.50 20:30 04:00 7.50 MARATHON OIL COMPANY etion Report tion - Gas WELL NAME KASILOF SOUTH 1 AF AF TIONS SUMMARY OP TRBL CL TBG CL TBG DESCRIPTION temperatures. Rig down CT equipment. Hauled off two loads of KCL water to KGF. Release CT Unit in preparation for Falls Creek 4 Excape frac job. High winds and wind chill hamper CT rig down efforts. Stage CT equipment on edge of location for night. Will begin KS 1rd perforating operations on Monday March 22, 2004. BJ Services Coil Tubing 4 88.00 Veco Alaska Crane Operator 22.00 Halliburton Well Testers 1 22.00 I.I.S.C.O. SCADA Hookup Marathon Supervision 2 22.00 Veco Alaska Vac truck operator 10.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: Printed: 412912004 4:07:31 PM . . MARATHON OIL PANY Daily Completion Report Exploitation ~ Gas WELL NAME KASILOF SOUTH 1 SUPERVISOR Ken Walsh FIELD NAME KB 24 HR PROG TMD TVD RPT# DATE 12 23-Mar-2004 SAPIWBS COST 30.6 RIG NAME & NO. AUTH MD WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS 1 MTS Perforated T onek 17,031'-17,050' MD at 40% underbalance. OPERATION COMMENTS Perforated Tyonek 17,031' - 17,050' MD. Logged correlation strip. SAFETYSOM ARY LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT MOCWI 100.0000 WBS DX0309030.CAP.CMP.02 DAILY WELL COST I CUM WELL COST NRI RIG PHONE Lt:A~U~~ COUNTY/OTHER MANHRS WORKED ACCIDENT TYPE 84.00 None ACCIDENT DESCRIPTION: 3/14/2004 REGULATORY INSP? N LAST RIG INSPECTION SAFETY MTG TOPICS: Perforating safety, overhead loads, and communication. 07:00 0.50 AF PERF SAFETY Held Prejob Safety Meeting to review work permit, hazards, and operational plan. 07:30 12:00 4.50 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 30 minutes trying to free tools from WL tool catcher and another 30 minutes making up new grease head. 12:00 12:30 0.50 AF PERF PERF Pressure test lubricator, tee, and WL valve to 300 psi low and 3400 psi high with methanol using MaC methanol skid. Spent 30 minutes troubleshooting Haskel pump to get it working. Dropped methanol downhole and bled off 1900 psi nitrogen through Halliburton to vent stack. 12:30 13:30 1.00 AF PERF PERF PU 2.4' of 2.63" OD rollers, 21' of 2.5" OD perforating guns (19' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 1-11/16" aD Gun-GR, 2.63" aD rollers, 6' of 1-11/16" weight bars, adapter head, and rope socket on Welltec 0.32" wireline. 13:30 18:30 5.00 AF PERF PERF RIH with perforating assembly and correlated GR depth with Reeves openhole and cased hole combination log provided by MOC Geology. Perforated Tyonek interval 17,031'-17,050' MD. Nitrogen pressure at wellhead was 1500 psi before perforating. Pressure built to 1620 psi in 1 hour and to 1850 psi in two hours 18:30 20:30 2.00 AF PERF PERF POOH logging GRlCCL from 17,128' - 9730' MD. 20:30 21:30 1.00 AF PERF PERF POOH with perforating guns. Bleed off 2050 psi lubricator pressure through vent stack. LD perforating guns. All shots fired and round. 21:30 22:30 1.00 AF PERF PERF Secure well. SDFN. Opened well to Halliburton choke skid to monitor pressure buildup overnight. Printed: 4/29/2004 4:07:32 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 DATE 23-Mar-2004 COMPANY Schlumberger Halliburton Marathon SERVICE Perforators Well Testers Supervision PERSONNEL DATA NO. HOURS COMPANY 4 16.00 Veco Alaska 2 24.00 I.I.S.C.O. 1 16.00 SERVICE Crane Operator Well Test Electronics POB @ 06:00: NO. HOURS 1 16.00 1 12.00 3.500 CASING ARY LAST CASING TEST: LAST BOP TEST: (psi) @ (ppg) Printed: 4/29/2004 4:07:32 PM . MARA . COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASllOF SOUTH 1 SUPERVISOR Ken Walsh FIELD NAME KB 30.6 RIG NAME & NO. RIG PHONE WilDCAT-FOR UNNAMED FIELD STATElPROV COUNTY/OTHER Alaska CURRENT STATUS / MTS Perforated T onek 17,012'-17,031' MD. OPERATION COMMENTS Perforated Tyonek intervals: 17,012' - 17,031' MD. 24 HR PROG TMD TVD RPT# DATE 13 24-Mar-2004 AUTH MD WBS SAPIWBS COST DX0309030.CAP.CMP.02 MOCWI NRI ICUM 100.0000 LEAKOFF MANHRS WORKED 69.00 ACCIDENT TYPE LAST SAFETY MTG BOP PSI TEST None 3/14/2004 SAFETY SUMMARY LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Clearing unnecessary tools from manlift LAST STOP CARD AUDIT REGULATORY INSP? N 08:00 08:30 0.50 AF PERF SAFETY 08:30 11:00 2.50 AF PERF PERF 11:00 16:00 5.00 AF PERF PERF 16:00 17:30 1.50 AF PERF PERF 17:30 18:30 1.00 AF PERF PERF 18:30 19:00 0.50 AF PERF PERF Held Prejob Safety Meeting to review work permit, hazards, and operational plan. MU CCl, weight bars, SAFE Head, and perforating gun. Armed perforating gun and pulled into the lubricator. PU lubricator. Top shieve spun around several times wrapping wireline. After unsuccessful attempts to relieve the line torque, layed lubricator assembly down and removed tools. Installed swivel at top of tool string to prevent future line wrap. Pulled guns into lubricato and MU to wellhead. Opened well with 3070 psi SITP. Total time to fix line wrap problem was 1-1/2 hours. RIH with 2.4' of 2.63" OD rollers, 21' of 2.5" OD perforating guns (19' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 2.5" OD CCl, 2.63" OD rollers, two 6' long 1-11/16" 00 weight bars, swivel, adapter head, and rope socket on Welltec 0.32" wireline. Perforated the Tyonek interval 17,012'-17,031' MD. WHP was 3090 psi on data header transducer before perforating. Transducer pressure dropped 40 psi in one hour to 3050 psi. POOH with perforating assembly. logged eel from 17,110' - 9,700' MD while POOH. Bled off 3050 psi lubricator pressure through vent stack. lD perforating guns. All shots fired and round. Secure well. SDFN. Opened well to Halliburton choke skid to monitor pressure buildup overnight. COMPANY Schlumberger Halliburton Marathon SERVICE Perforators Well Testers Supervision PERSONNEL DATA NO. HOURS COMPANY 4 11.00 Veco Alaska 2 24.00 I.I.S.C.O. 1 12.00 SERVICE Crane Operator Well Test Electronics 10.00 12.00 Printed: 4/29/2004 4:07:34 PM . WELL NAME KASILOF SOUTH 1 . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas DATE 24-Mar-2004 CASING SUMMARY LAST CASING TEST: MAX SICP (psi) @ (ppg) Printed: 4/29/2004 4:07:34 PM . . M»¡R»¡]" IllieeMP»¡N¥i Ðãil~.·~.·~..~..pl~~i.pl)~~pøl't ç{(pl(¡)itpti.P!1······.<:9ÇiS >.. WELL NAME KB IGL 24 HR PROG TMD TVD IDFSO IDOL IRPT# DATE KASILOF SOUTH 1 30.6 74.00 14 14 25-Mar-2004 SUPERVISOR RIG NAME & NO. AUTH MD WBS SAPIWBS COST Ken Walsh DX0309030.CAP.CMP.02 - FIELD NAME RIG PHONE MOCWI NRI I ûAIL Y WELL COST ¡ CUM WELL COST WILDCAT-FOR UNNAMED FIELD 100.0000 - STATEIPROV COUNTY/OTHER I LAST CASING I NEXT C"Q"'" IL=I\.u.. Alaska 3.500 (in) <â1 17,504 1ft) (in) @ 0 (ft) CURRENT STATUS 1 MTS 24 HR FORECAST Perforated 16,972'-16,996' MD. Ran PL T. Flow test well. Flow Test Well OPERATION COMMENTS Perforated Tyonek 16,972'-16,996' MD. Ran PL T to obtain Static BHP and fluid Flow test well through Halliburton test equipment. ;:)AJ':'l::ihyN ¡ill ¡¡.¡¡¡¡AbV. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG [BOP PSI TEST LAST STOP CARD AUDIT I ~EGULATORY INSP? I LAST RIG INSPECTION 186.00 None 3/14/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Trip hazards, Arming Perforating Guns .~ 'ÌÎ""'''.' jj / FRè:>1\II tè:> !iR§ FROM rø .. .. 07:00 08:00 1.00 AF PERF EQUIP Veco crane picked up MOC choke manifold and set on Veco truck for delivery to FC #4 frac flowback project. Veco crane picked gas buster from flowback tank to be hauled to Beaver Creek 1A pad by Weaver Bros. 08:00 08:30 0.50 AF PERF SAFETY Held Prejob Safety Meeting to review work permit, hazards, and operational plan. 08:30 09:30 1.00 AF PERF PERF MU CCL, weight bars, SAFE Head, and perforating gun. Armed perforating gun and pulled into the lubricator. MU lubricator to wellhead. Opened well with 3084 psi SITP. 09:30 14:00 4.50 AF PERF PERF RIH with 2.4' of 2.63" aD rollers, 27' of 2.5" aD perforating gun stock (24' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head 2.5" OD CCL, 2.63" aD rollers, one 6' long 1-11/16" aD weight bar, swivel, adapter head, and rope socket on Welltec 0.32" wireline. Perforated the Tyonek interval 16972'-16996' MD. WHP was 3077 psi on data header transducer before perforating. Transducer pressure after: 5 min = 3084 psi 15 min = 3088 psi 30 min = 3089 psi 14:00 15:30 1.50 AF PERF PERF POOH with perforating assembly. 15:30 16:00 0.50 AF PERF PERF Bled off 3090 psi lubricator pressure through vent stack. LD perforating guns. All shots fired and round. 16:00 17:00 1.00 AF PERF LOG PU Schlumberger GRlCCUPL T tool and pulled into lubricator. MU lubricator to wellhead. 17:00 21:30 4.50 AF PERF LOG RIH with PL T (PSPT-NB) tool logging temperature and pressure. Correlated depth with GR on Reeves combination log Surface pressure measured by Schlumberger and Barton were within 2 psi. 21 :30 00:00 2.50 AF PERF LOG Logged static pressure and temperature in time drive with tools placed at top perforation of 16972' MD. Initial pressure and temperature were 4415.36 psi and 160.39 deg F. Pressure fell Printed: 4/29/2004 4:07:35 PM WELL NAME KASILOF SOUTH 1 FROM TO HRS 21 :30 00:00 2.50 00:00 04:00 4.00 04:00 05:30 1.50 05:30 06:00 0.50 Schlumberger Halliburton Marathon FROM SERVice Perforators Well Testers Supervision . MARATHON OIL COMPANY Daily Completion Report E itation - Gas TO SUB AF AF AF AF (psi) @ (ppg) DATE 25-Mar-2004 OPERATIONS SUMMARY PHASE OP TRBL PERF LOG PERF to 4412.78 psi in 10 minutes before the grease injection and packoff pressure could be increased. Pressure and temperatur stabilized at 4415.35 psi and 160.54 deg F after 2 hours. Fluid level while RIH was at 15295' MD (14.6 bbls). Calculated fluid gradient was 0.446 psilft across the entire column. Fluid gradient was 0.417 psilft at 15415'-15615' MD and 0.44 psilft at 16955'-17075' MD. POOH making 5 minute survey stops at 16500',16000', 15500', 15300',8430', and 7190' MD. Final stop at surface: 3125 psi and 34.6 deg F (Schlumberger PL T) and 3101.6 psi and 46 deg F (Barton meter). Closed master valves and bled off lubricator. LD lubricator and PL T tools. ND WL valve and flow tee. Replaced tapped blind flange on top of swab valve on KS #1 L 1 with tapped bull plug production flange. MU tree cap to Otis flange on top of KS #1 rd swab valve. Schlumberger will return to complete rigdown later in the day. Opened well to test at 0515 hrs at 3100 psi surface pressure. Halliburton attempted to take well gas to heat separator bath bu gas gravitometer indicates 0.96 sp gr nitrogen. Flowed well for one hour to Rain-for-Rent tank to obtain burnable gas(0.6 sp gr) with final pressure down to 2834 psi on a 20/64 choke. Shut well in to light separator bath burner and get bath temperature up to 120 deg F. Pressure increased to 3367 psi in 17 minutes. LOG PERF LOG FLOW FLOW 4 80.00 Veco Alaska 3 36.00 i.i.S.C.O. 1 24.00 Crane Operator Well Test Electronics 1 2 22.00 24.00 NEXT BOP TEST: Printed: 4/29/2004 4:07:35 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 SUPERVISOR Ken Walsh FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Flow Test Well OPERATION COMMENTS Flow Tested Well KB 24 HR PROG TMD TVD 30.6 RIG NAME & NO. AUTH MD RPT # DATE 15 26-Mar-2004 WBS SAPIWBS COST DX0309030.CAP.CMP.02 NRI I CUM WELL COST RIG PHONE MOCWI 100.0000 COUNTY/OTHER Lt:AI\.U~r MANHRS WORKED ACCIDENT TYPE 78.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Well test procedures/pressurized lines/ LAST SAFETY MTG 3/14/2004 REGULATORY INSP? N LAST RIG INSPECTION 06:00 08:00 2.00 AF FLOW FLOW 08:00 08:30 0.50 AF FLOW SAFETY Changed out Halliburton Textene methanol pump for MOC methanol skid pump. Heated separator bath to 125 deg F. Made final check of equipment. Veco vac truck loaded approximately 70 bbls of 50/50 methanol water and hauled to FC#4. Held Prejob Safety Meeting to discuss hazards and flow test target rates and pressures. Tightened a connection at Halliburton's separator. Began flowing well through Halliburton test separator at 0915 hrs. Initial SITP at 3289 psi. Please refer to Halliburton flow test report for detailed information on test data. Ensured that valves open to SPIDR gauge and Data Trap recorders on tree. 08:30 AF FLOW FLOW Halliburton Marathon Well Testers Supervision 3.500 Printed: 4/29/2004 4:07:38 PM · MARAT OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 WBS 24 HR PROG TMD TVD KB 30.6 RIG NAME & NO. SUPERVISOR Ken Walsh FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Flow Test Well OPERATION COMMENTS Flow-after-flow testing well. AUTH MD DATE 31-Mar-2004 !;APIWR!; COST RIG PHONE NRI DX0309030.CAP.CMP.02 DAILY WELL COST , CUM WELL COST )Q_J COUNTY/OTHER MOCWI 100.0000 Summary of well tests 3/25/04 to 3/30104 in Time Summary. SAFETY SUMMARY LAST SAFETY MTG BOP PSI TEST LAST STOP CARD AUDIT 3/14/2004 MANHRS WORKED ACCIDENT TYPE 372.00 None ACCIDENT DESCRIPTION: REGULATORY INSP7 LAST RIG INSPECTION N SAFETY MTG TOPICS: AF FLOW FLOW Well test initiated 1000 hrs 03/25/04 on 2.5" orifice plate. Date Time WHP WHT Choke Gas Rate Cum Gas Cum H2O 3/2512004 10:00 2780 40 12 2619 3/25/2004 16:00 2650 48 20 5638 1117 2.3 3/25/2004 22:30 3361 24 1349 5.6 3/26/2004 4:30 3623 2552 23.2 3/26/2004 10:00 3249 58 22 7970 4326 32.5 3/26/2004 16:00 3260 62 22 8327 6378 35.9 3/26/2004 22:00 3308 62 22 7507 39.0 3/27/20044:00 3307 62 22 7397 43.2 3/27/200410:00 3163 64 24 9774 45.3 3/27/200416:00 3131 68 24 10546 47.3 3/27/200422:00 3132 68 24 10915 51.5 3/28/20044:00 3131 66 24 11237 55.7 3/28/2004 10:00 3126 66 24 10803 56.7 3/28/2004 16:00 3298 69 21 7569 58.8 Printed: 4/29/2004 4:07:39 PM . . MARATHON OIL COMPANY pletion ort Exploitation - Gas FROM TO HRS FROM WELL NAME DATE KASILOF SOUTH 1 31-Mar-20Q4 LAST BOP TEST: OPERATIONS SUMMARY TO SUB PHASE OP TRBL AF FLOW FLOW 3/28/2004 22:00 61.9 3/29/20044:00 64.0 3/29/2004 10:00 65.0 3/29/200416:00 67.1 3/29/2004 22:00 69.2 3/30/20044:00 69.2 3/30/2004 6:00 70.2 3323 67 20 7040 26901 3317 65 20 7130 28701 3327 64 20 6230 30431 3308 65 20 6635 3283 64 21 7833 3296 62 21 7226 3295 62 21 7236 Halliburton Marathon Well Testers Supervision 3.500 Printed: 4/29/2004 4:07:39 PM . . WELL NAME KASILOF SOUTH 1 SUPERVISOR Ken Walsh FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Continue ressure buildu OPERATION COMMENTS Monitor pressure buildup. KB TVD RIG NAME & NO. AUTH MD RIG PHONE MOCWI 100.0000 WBS DX0309030.CAP.CMP.02 NRI DAILY WELL COST I CU~, ..~~~ ___, COUNTY/OTHER LEAKOff MANHRS WORKED 372.00 ACCIDENT TYPE LAST SAFETY MTG None 3/14/2004 LAST STOP CARD AUDIT REGULATORY INSP? N LAST RIG INSPECTION ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Halliburton Marathon 3.500 (psi) @ (ppg) Printed: 4/29/2004 4:07:40 PM . . MARATHON OIL COMPANY Daily Completion Report Exploitation - Gas WELL NAME KASILOF SOUTH 1 SUPERVISOR Crai Meese KB 30.6 RIG NAME & NO. FIELD NAME RIG PHONE WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS / MTS Monitor SI well with Data Tra au e. OPERATION COMMENTS Ran "Post Flow Period" PL T to obtain Static BHP and fluid gradients. SAFETY LAST SAFETY MTG BOP PSI TEST COUNTY/OTHER MANHRS WORKED ACCIDENT TYPE 88.00 None ACCIDENT DESCRIPTION: 4/10/2004 SAFETY MTG TOPICS: Communication, Slips, Trips, Falls, Pressure Ops 24 HR PROG TMD TVD AUTH MD WBS DX0309030.CAP.CMP .02 MOC WI NRI DAILY WELL COST ¡CUM ..___ ___. 100.0000 au e. MARY' LAST STOP CARD AUDIT REGULATORY IN$P? N LAST RIG INSPECTION I=ROM 06:45 07:15 0.50 AF OTHER WIRELN 07:15 07:30 0.25 AF OTHER SAFETY 07:30 08:30 1.00 AF OTHER WIRELN 08:30 09:30 1.00 AF OTHER WIRELN 09:30 10:15 0.75 AF OTHER WIRELN 10:15 12:30 2.25 AF OTHER WIRELN 12:30 17:30 5.00 AF OTHER WIRELN Start equipment. Held Prejob Safety Meeting to review work permit, hazards, and operation plan. 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. PU Schlumberger GRlCCUPL T tool and pulled into lubricator. MU lubricator to wellhead. Pressure test lubricator, tee, and WL valve to 4000 psi high with methanol using MOC methanol skid. Bled back methanol to tank. RIH with PL T (PSPT-NB) tool logging temperature and pressur to 17100'. Surface pressureltemp measured by Schlumberger was 3592 psia I 53 F and 3586 psi I 44 F on Data Trap. Correlate PL T log to Reeves CBL. Water Level noted at 16,998' (below upper perf interval). Recorded 5 min stops in water leg as follows: 13:25: 17100': 4381 psia /160.5 F. 13:35: 17050': 4362 psia /160.1 F. 13:39: 17000': 4344 psia /159.6 F. Recorded 20 min stop at top perf as follows: 13:46: 16972': 4342 psia /159.5 F. Recorded 5 min stops in gas column coming OOH as follows: 14:07: 16950': 4341 psia /159.0 F. 14:15: 16900': 4338 psia /158.2 F 14:22: 16850': 4335 psi a /157.6 F 14:30: 16800': 4331 psi a /157.0 F 14:40: 16500': 4312 psia /153.5 F 14:52: 16000': 4281 psia /148.3 F 15:19: 12000': 4097 psia /120.2 F Printed: 4/29/2004 4:07:42 PM FROM TO HRS FROM TO SUB 12:30 17:30 5.00 AF WELL NAME KASILOF SOUTH 1 17:30 20:00 2.50 Schlumberger Halliburton LAST BOP TEST: 3.500 Electric Line Well Testers . . MARATHON OIL COMPANY Daily Completion Report Exploitation. Gas OPERATIONS SUMMARY PHASE OP TRBL OTHER WIRELN DESCRIPTION AF 15:45: 8430': 3982 psia 1105.8 F 16:00 7190': 3942 psia 1100.2 F 16:25 3500': 3820 psia I 81.5 F 16:59 Recorded 15 min stop at surface: Final surface pressure I temp measured by Schlumberger was 3589 psia I 46.9 F and 3586 psi I 45 F on Data Trap. 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: Data Trap gauge monitoring KS#1rd. SPDR and Barton gauges monitoring KS#1 L 1. OTHER WIRELN (psi) @ (ppg) Printed: 4/29/2004 4:07:42 PM " . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Marathon Oil Company Operations Summary Report 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: 3/512004 08:00 - 20:30 From.. To Hours Code Sub Phase Code Date 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 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 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. 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 man lift. Set cement barrels and tied down vent stack guy wires to barrels. Shoveled snow from liner and layed down plywood. Printed: 5/3/2005 8:13:26 AM .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Marathon Oil Company Operations Summary Report 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 D~scription of Date From - To Hours Code Sub Phase Code 3/12/2004 08:00 - 08:30 08:30 - 12:00 12:00 - 21 :00 20:00 - 23:30 23:30 - 01 :30 01 :30 - 03:00 03:00 - 06:00 3/13/2004 06:00 - 08:30 08:30 - 14:00 14:00 - 19:00 0.50 SAFETY SMTG CLNOUT Held Prejob Safety Meeting. 3.50 CL TBG RURD CLNOUT MIRU BJ CoilTech Coiled Tubing Equipment and Veco 45-ton crane. Spotted equipment. Offloaded injector head, hoses, lubricator, and BOP. Veco vac truck filled Rain-for-Rent tank with fresh water blended with 1 gpt BJ FRW-14 friction reducer and and Steam-on-Wheels heated to 80 deg. Mike's delivery delivered water and cooler. Connected 1-1/2" tapered coil tubing string (0.156 wall to 0.125 wall QT 900) to injector head. Layed out and made up BJ fluid lines. Halliburton pressure tested flowback lines to well to 100 psi with air. 9.00 CL TBG RURD CLNOUT Changed out tree cap connection to 3-1/8" 5K x 3-1/16" 10K crescent flange. PU and MU BJ flowcross and lubricator to treetop flange. PU and MU coil tubing BOP to flow cross. PU and MU lubricator to BOP. PU injector head. Displace CT to methanol water. Pig CT. Pull test of CT to 20,000 lb. Test CT to 250/4500. Make up injector head. 3.50 CL TBG RURD CLNOUT PJSM. Test lines 250/5500. Test pipe rams 300/4500. Test aux rams 300/4500. Test blind rams and flow back iron 250/4500. 2.00 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. 1.50 CL TBG RURD CLNOUT Displace methanol water from CT. Confirm motor operating. 3.00 CLNOUT RIH breaking circ every 15 min: 3000' wt check 4400 Ibs 6000' wt check 7500 Ibs 9000' wt check 10500 Ibs 9850' wt check 11500 Ibs Note: No indication of restrictionsldebris through liner top. 10400' wt check 12000 Ibs 10900' wt check 12200 Ibs 11400' wt check 12300 Ibs 11900' wt check 12400 Ibs 2.50 CL TBG RICT CLNOUT RIH with mill, motor, and hydraulic jars on 1-1/2" coil tubing from 12,400' to 14,615' without pumping. Tagged up on restriction. PUH 50' and started pumping fresh water with friction reducer at 1.3 BPM with good returns. 5.50 CL TBG RICT CLNOUT RIH at 10-20 fpm pumping 1.3 BPM slick fresh water working through multiple cement stringers (drilling off quickly-appears to be cement on the low side of the casing). Obtaining modest cement returns. Stalled motor at 14969'; 15752'; 15,842'; and 16585'. RI H to 16,661' pumping and milling. 5.00 CL TBG RICT CLNOUT Increased fluid rate to 1.5 BPM and continued RIH with motor and mill. More stringers but still running at 200-300 Ftlhr. Increased weight checks from every 150' to every 50'. Performed weight checks while pulling up hole 50' to clean hole. Milled low-side cement stringers from 16661'-17196'. Weight checks as follows: 16661'- 29000 # 16801'- 29000# 16900'- 29800# 17020'- 32300# 17056'- 32400# 17106'- 33400# Printed: 5/3/2005 8:13:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/13/2004 14:00 - 19:00 . . Marathoo.·Oil Company Operation$...Summary KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors Hours Code ¿>~dbe Pha$e Spud Date: 10/14/2003 End: Group: Start: 3/4/2004 Rig Release: Rig Number: 273E DescriptionofOJ:>~r~tion~y . 5.00 CLTBG RICT CLNOUT 17156'- 34000# 17206'- 35000# 17231'- 37000#: PU 50' and mill back down to 17231' 17231'- 36000# PU to 17265'. Circ 2X BU (225 bbls) @ 17221'. Move CT uphole 100' every 50 bbls pumped. POOH with CIT while circulating 1.5 BPM. Displace CIT with methanol water. Blow lines dry across tree. Break 3-1/16" 10K flange connection below flow cross. PU stack. Move to lateral side of dual tree (Kasilof State #1 L 1). Temporarily suspend operations on Kasilof State #1rd. Install 3-1/8" 5K x 3-1/16" 10K flange to top oftree. Move CIT stack from Kasilof State # 1 L 1 (Lateral) back to Kasilof State #1 rd (Motherbore). MU 3-1/16" 10K flange connection below flow cross of CIT stack. 0.50 CL TBG RURD CLNOUT Break lubricator, layout and inspect motor assembly. 1.50 CL TBG RURD CLNOUT Changed out stripper rubber on CT grease head. Attempted to test CT BOP's-shut down to tighten flange connection below BOP to riser spool. 0.50 SAFETY SMTG CLNOUT Held Prejob Safety Meeting. 2.00 CL TBG RURD CLNOUT Performed successful BOP test with methanol water: 250 psi/4500 psi pipe, safety, and blind rams. Bled off pressure. R&K vac truck finished emptying flowback tank. 0.50 CL TBG RURD CLNOUT Broke lubricator and PU Weatherford venturi junk basket with 8' extension and 2.850" mule shoe guide, hydraulic disconnect, dual acting jars, dual checks, and 1-1/2" coil connector. Set CT at GL to 30' KB. MU lubricator and opened master valves. 0.50 CL TBG RURD CLNOUT Shell tested BOP and lubricator to 1000 psi with 50/50 methanol water. 0.50 CL TBG RURD CLNOUT Displace methanol water from CT with fresh water. 7.50 CL TBG RICT CLNOUT Run in Hole with venturi BHA on Coiled Tubing. Started pumping fresh water at 1 BPM while continuing to run in hole. No problem through smallest ID of 2.887" at chemical injection nipple at 2544' MD. Made following weight checks while RIH pumping fresh water at 1 BPM: 19:00 - 21 :30 2.50 CL TBG RICT CLNOUT 21 :30 - 02:00 4.50 CL TBG POCT CLNOUT 02:00 - 03:00 1.00 CL TBG RURD CLNOUT 03:00 - 04:00 1.00 CL TBG RURD CLNOUT 3/14/2004 04:30 - 05:30 1.00 CL TBG RURD CLNOUT 3/15/2004 05:30 - 06:00 06:00 - 07:30 07:30 - 08:00 08:00 - 10:00 10:00 - 10:30 10:30 - 11 :00 11 :00 - 11 :30 11 :30 - 19:00 19:00 - 20:20 20:20 - 01 :00 01 :00 - 01 :30 3000' wt check- 3200# 6000' wt check- 6300# 9100' wt check- 9500# 9900' wt check- 10500# 10500' wt check- 11000# 11000' wt check- 11000# 11500' wt check- 11800# 12000' wt check- 12500# 13100' wt check- 14500# 13600' wt check- 15000# 14000' wt check- 15500# 14500'wtcheck-16500# 15000' wt check- 17000# 15500' wt check- 18500# 16000' wt check- 19500# 16500' wt check- 21000# Increase rate to 1.2 BPM 17000' wt check- 21500# 17206' wt check- 21500# 17246' Tag, not washing off: wt check 22000# 17246' Re-tag, not washing off: wt check 22500# PU to 17216'. 1.33 CL TBG RICT CLNOUT Circ 29 bbl 6% KCL from vac truck and displace out end of CT to back side in order to spot 6% KCL across interval 17246' - 13878'. 4.67 CL TBG POeT CLNOUT SD circ and POOH (50fpm to liner and 75 fpm in tubing). 0.50 CL TBG RURD CLNOUT Blow lines dry across tree. Break out lubricator. LD and inspect contents of venturi junk basket and screen. Found +1- 2 cups debris as Printed: 5/3/2005 8:13:26 AM . Marathon Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors D - To Hours Code 3/15/2004 01 :00 - 01 :30 b de Phase 0.50 CL TBG RURD CLNOUT 01 :30 - 02:00 0.50 CL TBG RURD CLNOUT 02:00 - 02:30 0.50 CLNOUT 3/17/2004 09:30 - 11 :00 1.50 LOG CSGD OTHER 11 :00 - 11 :30 0.50 SAFETY SMTG OTHER 11 :30 - 13:00 1.50 LOG CSGD OTHER 13:00 - 15:00 2.00 LOG CSGD OTHER 15:00 - 17:00 2.00 LOG CSGD OTHER 17:00 - 20:00 3.00 LOG CSGD OTHER 20:00 - 22:00 2.00 LOG CSGD OTHER 22:00 - 00:00 2.00 LOG CSGD OTHER 3/19/2004 00:00 - 06:00 08:00 - 08:30 6.00 WAIT OTHR OTHER 0.50 SAFETY SMTG CLNOUT 08:30 - 10:00 1.50 CL TBG RURD CLNOUT 10:00 - 12:30 2.50 CL TBG RURD CLNOUT 12:30 - 17:00 4.50 CL TBG RICT CLNOUT . Start: 3/4/2004 Rig Release: Rig Number: 273E 9 Spud Date: 10/14/2003 End: Group: " tion of Operations follows: - +1- 20 pieces - 1" x 1" cement sheaths - smaller pieces and ground cement - several small pieces metal to 1" Install nozzel to CIT and MU lubricator. Displace CIT with methanol water. Break 3-1/16" 10K flange connection below flow cross. PU stack. Move to lateral side of dual tree (Kasilof State #1 L 1). T em porarily suspend operations Kasilof State #1 rd. MIRU Reeves cased hole logging and WellTec wireline tractor. Reeves calibrated tools and then spotted wireline unit. Held Prejob Safety Meeting with Reeves, Well Tee, and Veco personnel. Changed out swab valve flange from blind to 3-1/8" 5K x 6-1/2" Otis. MU Pollard rental crossover and flowtee to Otis connection. MU MOC chicksan to flow tee (chicksan connected to choke manifold and then to flowback tank). PU 2.25" OD Reeves cased hole memory logging tools: (GRlCCUNeutron/Density/CaliperISonic) and WellTec's 2-1/8" OD wireline tractor with Veco crane. Placed battery pack in memory sub at 13:37:38 hrs. Overall length of logging tools is 73.07'. Overall length of tractor is 20.33'. RIH with cased hole logging tools making weight checks to hard tag at 17,220' MD loggers MD. Did not have to engage tractor to get to PBTD. No obstructions noted while RIH. PUH logging to 12,500' MD. POOH and lay down tractor. Cable head wet, dry out cable head and fill with new grease. RU re-built cable head to tractor and active to confirm cable head integrity. Lay down and isolate nuclear sources. Download data from memory logging tools. Begin depth-time correlation of memory logs. Temporarily suspend operations on KS #1 rd and shift to KS #1 L 1 for cased hole logging operations. Perform cased hole logging operations on KS #1 L 1. Held Prejob Safety Meeting with all personnel on location. Reviewed and signed work permit. Discussed hazard prevention and job outline. Check jetting nozzle, straight bar, and double flappers for plugging agent. Found two ports plugged with ice. PU BJ Coil tech injector head, BOP, and riser as entire assem bly from KS #1 L 1 and MU to swab valve flange on KS #1 rd. Load CT with methanol water for BOP pressure test. Pressure tested CT BOP's to 250/4500 psi with methanol water. Cooled down nitrogen unit. Displaced methanol water to tank with nitrogen. Open well and RIH with 1-3/4" OD wash nozzle, 4' long straight bar, and double checks on 1-1/2" OD coil tubing pumping nitrogen at minimum rate (to prevent CT collapse). Pull Weight Checks: 3100' - 2000# 6200' - 4200# 9800' - 6000# 11000' - 6800# 12000' - 7100# 14200' - 9000# 15300' - 10900# 16150' - 12000# 17000'-14000# 17216' - 14500# Printed: 5/3/2005 8:13:26 AM . . . . thon Oil Company :" .·..:>:;:.ir\'·.·::(:':~>·I:·· ,';;" .:: .;.....:.. .,' ·i :.., .:. " Operation$ Summary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors Code Sub Phase Code 3/19/2004 12:30 - 17:00 4.50 CLTBG RICT CLNOUT 13100' - 8500# 17:00 - 18:00 1.00 CL TBG JET CLNOUT 18:00 - 20:30 2.50 CL TBG JET CLNOUT 20:30 - 04:00 7.50 CL TBG RURD CLNOUT 3/23/2004 07:00 - 07:30 0.50 SAFETY SMTG CMPPRF 07:30 - 12:00 4.50 PERF RURD CMPPRF 12:00 - 12:30 0.50 PERF RURD CMPPRF 12:30 - 13:30 1.00 PERF RURD CMPPRF 13:30 - 18:30 5.00 PERF WLNC CMPPRF 18:30 - 20:30 2.00 PERF WLNC CMPPRF 20:30 - 21 :30 1.00 PERF WLNC CMPPRF 21 :30 - 22:30 1.00 PERF RURD CMPPRF 3/24/2004 08:00 - 08:30 0.50 SAFETY SMTG CMPPRF 08:30 - 11 :00 2.50 PERF RURD CMPPRF Start: 3/4/2004 Rig Release: Rig Number: 273E Description Spud Date: 10/14/2003 End: Group: Tag depth is 17216' KB. Increased nitrogen pump rate from 500 scfm to 1500 scfm at 3800 psi. Pumped for 30 minutes recovering 142 out of 149 bbl calculated capacity. Lined up nitrogen to BJ kill line. Stopped flowing well and continued pumping nitrogen while pulling out of hole with CT. Trapped 1770 psi nitrogen surface pressure in wellbore for underbalance perforating. Held joint safety meeting outlining safe operations for rig down with high winds and cold temperatures. Rig down CT equipment. Hauled off two loads of KCL water to KGF. Release CT Unit in preparation for Falls Creek 4 Excape frac job. High winds and wind chill hamper CT rig down efforts. Stage CT equipment on edge of location for night. Will begin KS 1 rd perforating operations on Monday March 22, 2004. Held Prejob Safety Meeting to review work permit, hazards, and operational plan. 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 30 minutes trying to free tools from WL tool catcher and another 30 minutes making up new grease head. Pressure test lubricator, tee, and WL valve to 300 psi low and 3400 psi high with methanol using MOC methanol skid. Spent 30 minutes troubleshooting Haskel pump to get it working. Dropped methanol downhole and bled off 1900 psi nitrogen through Halliburton to vent stack. PU 2.4' of 2.63" OD rollers, 21' of 2.5" OD perforating guns (19' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 1-11/16" OD Gun-GR, 2.63" OD rollers, 6' of 1-11/16" weight bars, adapter head, and rope socket on Welltec 0.32" wireline. RIH with perforating assembly and correlated GR depth with Reeves openhole and cased hole combination log provided by MOC Geology. Perforated Tyonek interval 17,031'-17,050' MD. Nitrogen pressure at wellhead was 1500 psi before perforating. Pressure built to 1620 psi in 1 hour and to 1850 psi in two hours. POOH logging GRlCCL from 17,128' - 9730' MD. POOH with perforating guns. Bleed off 2050 psi lubricator pressure through vent stack. LD perforating guns. All shots fired and round. Secure well. SDFN. Opened well to Halliburton choke skid to monitor pressure buildup overnight. Held Prejob Safety Meeting to review work permit, hazards, and operational plan. MU CCL, weight bars, SAFE Head, and perforating gun. Armed perforating gun and pulled into the lubricator. PU lubricator. Top shieve spun around several times wrapping wireline. After unsuccessful attempts to relieve the line torque, layed lubricator assembly down and removed tools. Installed swivel at top of tool string to prevent future line wrap. Pulled guns into lubricator and MU to wellhead. Opened well with 3070 psi SITP. Total time to fix line wrap Printed: 5/3/2005 8:13:26 AM . Oil Company Operations' Summary Report . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors Sub Code Code Phase From - To Hours 3/24/2004 RURD CMPPRF WLNC CMPPRF 08:30 - 11 :00 11 :00 - 16:00 2.50 PERF 5.00 PERF 16:00 - 17:30 1.50 PERF WLNC CMPPRF 17:30 - 18:30 1.00 PERF WLNC CMPPRF 18:30 - 19:00 0.50 PERF RURD CMPPRF 3/25/2004 07:00 - 08:00 1.00 EQUIP ONFL CMPPRF 08:00 - 08:30 0.50 SAFETY SMTG CMPPRF 08:30 - 09:30 1.00 PERF RURD CMPPRF 09:30 - 14:00 4.50 PERF WLNC CMPPRF 14:00 - 15:30 1.50 PERF WLNC CMPPRF 15:30 - 16:00 0.50 PERF WLNC CMPPRF 16:00 - 17:00 1.00 LOG SPLC CMPPRF 17:00 - 21 :30 4.50 LOG SPLC CMPPRF 21 :30 - 00:00 2.50 LOG SPLC CMPPRF 00:00 - 04:00 4.00 LOG SPLC CMPPRF 04:00 - 05:30 1.50 LOG SPLC CMPPRF Spud Date: 10/14/2003 End: Group: Start: 3/4/2004 Rig Release: Rig Number: 273E Description of Opé~ions problem was 1-1/2 hours. RIH with 2.4' of 2.63" OD rollers, 21' of 2.5" OD perforating guns (19' loaded HSOPJ, 60 deg phased, 6 JSPF), SAFE Head, 2.5" 00 CCL, 2.63" OD rollers, two 6' long 1-11/16" OD weight bars, swivel, adapter head, and rope socket on Welltec 0.32" wireline. Perforated the Tyonek interval 17,012'-17,031' MD. WHP was 3090 psi on data header transducer before perforating. Transducer pressure dropped 40 psi in one hour to 3050 psi. POOH with perforating assembly. Logged CCL from 17,110' - 9,700' MD while POOH. Bled off 3050 psi lubricator pressure through vent stack. LD perforating guns. All shots fired and round. Secure well. SDFN. Opened well to Halliburton choke skid to monitor pressure buildup overnight. Veco crane picked up MOC choke manifold and set on Veco truck for delivery to Fe #4 frac flowback project. Veco crane picked gas buster from flowback tank to be hauled to Beaver Creek 1A pad by Weaver Bros. Held Prejob Safety Meeting to review work permit, hazards, and operational plan. MU CCL, weight bars, SAFE Head, and perforating gun. Armed perforating gun and pulled into the lubricator. MU lubricator to wellhead. Opened well with 3084 psi SITP. RIH with 2.4' of 2.63" OD rollers, 27' of 2.5" OD perforating gun stock (24' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, 2.5" OD eeL, 2.63" OD rollers, one 6' long 1-11/16" OD weight bar, swivel, adapter head, and rope socket on Welltec 0.32" wireline. Perforated the Tyonek interval 16972'-16996' MD. WHP was 3077 psi on data header transducer before perforating. Transducer pressure after: 5 min = 3084 psi 15 min = 3088 psi 30 min = 3089 psi POOH with perforating assembly. Bled off 3090 psi lubricator pressure through vent stack. LO perforating guns. All shots fired and round. PU Schlumberger GRlCCUPL T tool and pulled into lubricator. MU lubricator to wellhead. RIH with PL T (PSPT-NB) tool logging temperature and pressure. Correlated depth with GR on Reeves combination log. Surface pressure measured by Schlumberger and Barton were within 2 psi. Logged static pressure and temperature in time drive with tools placed at top perforation of 16972' MD. Initial pressure and temperature were 4415.36 psi and 160.39 deg F. Pressure fell to 4412.78 psi in 10 minutes before the grease injection and packoff pressure could be increased. Pressure and temperature stabilized at 4415.35 psi and 160.54 deg F after 2 hours. Fluid level while RIH was at 15295' MD (14.6 bbls). Calculated fluid gradient was 0.446 psilft across the entire column. Fluid gradient was 0.417 psilft at 15415'-15615' MD and 0.44 psilft at 16955'-17075' MD. POOH making 5 minute survey stops at 16500',16000',15500',15300', 8430', and 7190' MD. Final stop at surface: 3125 psi and 34.6 deg F (Schlumberger PL T) and 3101.6 psi and 46 deg F (Barton meter). Closed master valves and bled off lubricator. LD lubricator and PL T Printed: 5/3/2005 8:13:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 7 of 9 Oil Company Qperationš~ummaryRep.ort 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: 3/25/2004 3/26/2004 3/31/2004 04:00 - 05:30 05:30 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - Sub Phase 1.50 LOG SPLC CMPPRF tools. ND WL valve and flow tee. Replaced tapped blind flange on top of swab valve on KS #1 L 1 with tapped bullplug production flange. MU tree cap to Otis flange on top of KS #1 rd swab valve. Schlumberger will return to complete rigdown later in the day. 0.50 FLOW BACK CMPFLW Opened well to test at 0515 hrs at 3100 psi surface pressure. Halliburton attempted to take well gas to heat separator bath but gas gravitometer indicates 0.96 sp gr nitrogen. Flowed well for one hour to Rain-for-Rent tank to obtain burna Ie gas(0.6 sp gr) with final pressure down to 2834 psi on a 20/64 chok . Shut well in to light separator bath burner and get bath temperature u to 120 deg F. Pressure increased to 3367 psi in 17 minutes. 2.00 FLOW BACK CMPFLW Changed out Halliburton Textene ethanol pump for MOC methanol skid pump. Heated separator bat to 125 deg F. Made final check of equipment. Veco vac truck loade approximately 70 bbls of 50/50 methanol water and hauled to Fe 4. 0.50 SAFETY SMTG CMPFLW Held Prejob Safety Meeting to dis uss hazards and flow test target rates and pressures. FLOW BACK CMPFLW Tightened a connection at Hallibu on's separator. Began flowing well through Halliburton test separator t 0915 hrs. Initial SITP at 3289 psi. Please refer to Halliburton flow tes report for detailed information on test data. Ensured that valves op n to SPIDR gauge and Data Trap recorders on tree. FLOW BACK CMPFLW Well test initiated 1000 hrs 03/251 4 on 2.5" orifice plate. Date Time WHP WHT hoke Gas Rate Cum Gas Cum H20 3/2512004 10:00 2780 40 12 3/25/2004 16:00 2650 48 20 2.3 3/25/2004 22:30 3361 24 5.6 3/26/2004 4:30 3623 23.2 3/26/2004 10:00 3249 58 22 32.5 3/26/2004 16:00 3260 62 22 35.9 3/26/2004 22:00 3308 62 22 39.0 3/27/20044:00 3307 62 22 43.2 3/27/200410:00 3163 64 24 45.3 3/27/200416:00 3131 68 24 47.3 3/27/200422:00 3132 68 24 51.5 3/28/2004 4:00 3131 66 24 55.7 3/28/2004 10:00 3126 66 24 56.7 3/28/2004 16:00 3298 69 21 58.8 2619 5638 1117 1349 2552 7970 4326 8327 6378 7507 8263 7397 10164 9774 12149 10546 14671 10915 17296 11237 20087 10803 22885 7569 25150 Printed: 5/3/2005 8:13:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From 3/31/2004 . . Marathon Oil Comp ()p~r:ª~iqn~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 Descriptipp.of Opera Code FLOW BACK CMPFLW 3/28/2004 22:00 3323 67 20 7040 26901 61.9 3/29/2004 4:00 3317 65 20 7130 28701 64.0 3/29/2004 10:00 3327 64 20 6230 30431 65.0 3/29/200416:00 3308 65 20 6635 32083 67.1 3/29/2004 22:00 3283 64 21 7833 33933 69.2 3/30/2004 4:00 3296 62 21 7226 35744 69.2 3/30/2004 6:00 3295 62 21 7236 36357 70.2 4/6/2004 06:00 - 06:00 24.00 MONITR MSUR CMPFLW 4/11/2004 06:45 - 07:15 0.50 WIRELN RURD OTHER 07:15 - 07:30 0.25 SAFETY SMTG OTHER 07:30 - 08:30 1.00 WIRELN BHPT OTHER 08:30 - 09:30 09:30 - 10:15 10:15 - 12:30 12:30 - 17:30 17:30 - 20:00 Monitor Pressure Buildup. Start 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. 1.00 WIRELN BHPT OTHER PU Schlumberger GRlCCUPL T tool and pulled into lubricator. MU lubricator to wellhead. 0.75 WIRELN BHPT OTHER Pressure test lubricator, tee, and WL valve to 4000 psi high with methanol using MOC methanol skid. Bled back methanol to tank. 2.25 WIRELN BHPT OTHER RIH with PL T (PSPT-AlB) tool logging temperature and pressure to 17100'. Surface pressureltemp measured by Schlumberger was 3592 psia I 53 F and 3586 psi 144 F on Data Trap. 5.00 WIRELN BHPT OTHER Correlate PL T log to Reeves CBL. Water Level noted at 16,998' (below upper perf interval). Recorded 5 min stops in water leg as follows: 13:25: 17100': 4381 psia 1160.5 F. 13:35: 17050': 4362 psia 1160.1 F. 13:39: 17000': 4344 psia 1159.6 F. Recorded 20 min stop at top perf as follows: 13:46: 16972': 4342 psia 1159.5 F. Recorded 5 min stops in gas column coming OOH as follows: 14:07: 16950': 4341 psia 1159.0 F. 14:15: 16900': 4338 psia 1158.2 F 14:22: 16850': 4335 psia 1157.6 F 14:30: 16800': 4331 psia 1157.0 F 14:40: 16500': 4312 psia 1153.5 F 14:52: 16000': 4281 psia 1148.3 F 15:19: 12000': 4097 psi a 1120.2 F 15:45: 8430': 3982 psia 1105.8 F 16:00 7190': 3942 psia 1100.2 F 16:25 3500': 3820 psia I 81.5 F 16:59 Recorded 15 min stop at surface: Final surface pressure I temp measured by Schlumberger was 3589 psia I 46.9 F and 3586 psi I 45 F on Data Trap. 2.50 WIRELN RURD OTHER Closed master valves and bled off lubricator. LD lubricator and PL T Printed: 5/3/2005 8:13:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 4/11/2004 17:30 - 20:00 . . KASILOF SOUTH 1 KASILOF SOUTH 1 ORIGINAL COMPLETION NABORS Alaska Nabors Start: 3/4/2004 Rig Release: Rig Number: 273E . Phase Description of 9 Spud Date: 10/14/2003 End: Group: 2.50 WIRELN RURD OTHER tools. ND WL valve and flow tee. RD Schlumberger and prep to move out. Secure well and proceed with pressure monitoring as follows: Data Trap gauge monitoring KS#1rd. SPDR and Barton gauges monitoring KS#1 L 1. Printed: 5/3/2005 8:13:26 AM . AlaSka."1eSS 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,AJC 99501 Delivered by Courier RE: Marathon Oil Company CONFIDENTIAL Well Sa~p~ ~( 1~- Marathon Cannery Loop No. 7 ~ uJ, -F/[~ \ '1 Marathon Paxton No. 1 ':W'-I-öfi) . / JJ Marathon Falls Creek No.4 J ö J - ~.l ! :Ii ( MarathonJCasilofSouthNo.1RD;J..01--').\~(,. # l\;, 0 Marathon JCasilof South No. LlL AA~ - ::ì. \-1 -:±t \ 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, JCaynell Zeman Technical Assistant Received by: 1Lw'NJ oLlJ Date: d )~ ~ ~~ -/ .' rl', t L&-r'r-\ . Marathon KasilofSouth No.lrd (KAS lrd) AND Marathon Kasilof South No. LlL (KAS LlL) (lateral portion) KasilofUnit, Cook Inlet, Alaska Sec. 28, T-3-N, R-12-W, Seward Meridian KAS lrd API #: 5013320520000 KAS LlL API#: 50133205200600 12 Boxes - Well S ampJes Kasilof#lrd Well Samples Depth From Depth To (Feet) (Feet) Box No. 9,940 10,700 lA 10,700 11 ,340 2A 11,340 11,820 3A 11,820 12,400 4A 12,400 13,200 5A 13,200 14,100 6A 14,100 15,000 7A 15,000 15,860 8A 15,860 16,280 9A 16,280 16,830 lOA 16,830 17,320 lIA 17,320 17,545 12A ~ DÀ.. - ~ ~-<.o . Page 3 CONFIDENTIAL CONFIDENTIAL 1=* l(~Ù A) "2 ,. '- S £.e. Winton, Attached below please find the proposed completion procedures and well bore diagrams for the Kasilof South #1 and Kasilof South #1 L 1 wells. The Kasilof South #1 was drilled under Permit #202-256 and API #50-133-20520-00. The Kasilof South #1 L 1 was drilled under Permit #202-257 and API #50-133-20520-60. Marathon plans to initiate the completion wellwork on KS #1 beginning March 10, 2004. The completion wellwork for the KS #1 L 1 will run concurrent with the KS #1. As we agreed on our telephone conversation regarding this project, no Form 10-403 application will be necessary for; the completion work planned for these two wells as this email of the completion procedures and well bore diagrams will suffice for notice. However, the AOGCC does require a Form 10-403 sundry notice for gas venting estimates associated with the completion and testing phase of both wells. These forms will be forthcoming, to your attention, once I have received formation top data and well coordinate data for the productive interval tops and bottom hole locations from MaC's Geologist. I intend to be able to send these forms early next week. I have included my contact information with this email should you wish to contact me regarding this project. Regards, 1(en (j). WaCsIi «Ken Walsh (E-mail).vcf» «KS #1 L 1 WBDZIP» «KS #1 rd WBD.xls» «KS#1 Completion Procedure.doc» «KS#1 L 1 Completion Procedure.doc» Ken Walsh (E-mail)<KDWalsh@MarathonOil.com> Advanced Production Engineer Marathon Oil Company Content-Description: KS #1L 1 WBD.ZIP KS #1L 1 WBD.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 Content-Description: KS #1 rd WBD.xls KS #1rd WBD.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: KS#1 Completion Procedure.doc Content-Type: application/msword Content-Encoding: base64 . . Content-Description: KS#1 L 1 Completion Procedure.doc l KS#1 L 1 Completion Procedure.doc i Content-Type: application/msword . . MARATHON OIL COMPANY ALASKA BUSINESS UNIT Kasilof Field Kasilof State #1,dWell Test Procedure (03-02-2004) WBS # DX.03.09030.CAP.CMP.02 Completion: Non-Rig ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. OBJECTIVE: Prove a minimum gas volume in place of 8 BCF recoverable reserves. DISCUSSION: This procedure outlines recommended well test operations after KS #lrd has been drilled, cased, and cemented. The 3-112" tie-back tubing has been run and stung into the 3-112" liner and landed with a tubing hanger that has been locked down in the tubing head. The W' stainless steel control line has been connected to the methanol injection nipple placed at 2540' MD and clamped to the tubing to surface. The control line has been made up to the bottom of the hanger. A port in the wellhead allows access to the control line for methanol injection. The tubing hanger seal has been tested by Vetco by applying pressure to the control line well below the 5000 psi pressure of the methanol injection nipple rupture disc rating. The injection nipple rupture discs have been ruptured by Vetco. Vetco has installed a BPV in the tubing hanger. The 3-112" liner is full of 11.5 ppg drilling mud. The 3-112" tie-back tubing is full of 6% KCL water with FR W -14 friction reducer and Conqor A303 corrosion inhibitor. PROCEDURE: 1. Deliver clean 500 bbl. Rain-for-Rent tank, ±350 bbl. flow back tank, and MOC gas buster to location. Deliver MOC 2", 5K flowback skid (purchased from V etco) to location. Deliver MOC flowback chicksan and 3-118", 5K crescent flange connection with Otis connection to location. Deliver APC diesel fuel truck, liner, and dunnage to location. Deliver Marathon methanol injection skid with double diaphragm and Haskel pump to location. Deliver Airport Rental 65 KW rental generator, two light plants, Model 185 air compressor with air drier, and diesel-fueled manlift to location. Deliver two portable toilets, dumpster, and Tomco fork lift with fork extensions to location. 2. Hold PJSM. MIRV Halliburton well test equipment including Arctic stack pack, quiet Flare Stack Inc. vent stack, STE lab, flow line, and choke skid according to Halliburton layout design. APC to lay liner and berm around Halliburton Well Test separator, flow lines, vent stack, and diesel fuel truck. APC to lay liner and berm around Rain-for-Rent, MOC choke skid, and Veco flowback tank. Liner to be placed around wellhead and vicinity to be occupied by wireline and coil tubing equipment. A Veco crane will be required to pick up and set the vent stack Page 2 of 4 . . 3. Plumb Halliburton flow line to receive production downstream ofthe SSV valve with a 3Ys" 5K x 3" 1502 companion flange (supplied by Halliburton). Connect methanol injection pumps to the downhole injection line and to the test tree. RU pressure test pump and 100% methanol tote to 14" OD downhole chemical injection system. Load separator with about 50 bbls of 50:50 glycol water mixture. 4. MIRU Cook Inlet Safety LEL and H2S gas detection monitoring and alann system. Fill Rain-for-Rent tank with fÌ"esh water. 5. MIRU BJ Services Coil Tubing and Nitrogen Unit. Coil tubing reel to contain ±19,500' of 1-112" BJ Services (0.156 wall to 0.125 wall QT 900) tapered coil tubing work string. Remove well cap and Otis tree connection. NU BJ Services 3-118" 5K x 3-1/16" 10K flange to the top ofthe tree. Install BJ flow cross to top of3-1I16", lOK flange. Connect BJ pump suction line to Rain-for Rent fÌ"esh water tan1e Make arrangements to blend BJ FR W -14 fTIction reducer at 1 gall 1 000 gal in the BJ blender tank RU BJ filter pod and hose to transfer filtered fluid fÌ"om the flowback tank to the Rain-for Rent tank. Have Veco 45-ton crane pick up BJ coil tubing BOP. Flange up BOP to top of flow cross. Install coil tubing in injector head. MU and pull test Weatherford coil tubing connector suited for coil tubing wall thickness. Pick up injector head and lubricator with crane. MU Weatherford 2.80" OD mill (Have 2.75" OD Backup Mill on location), 2-118" Weatherford PDM, MHA (Dual checks, circ sub, and hydraulic disconnect). (Note: Max rate through the 2-118" Weatherford motor is 75 gpm.) Make up CT injector head and lubricator to BOP's. Note: Weatherford to have backup for every item listed for drilling BHA above. including coil connectors. 6. Pressure test BJ Services pump lines to 5500 psi. Pressure test CT BOP pipe and blind rams, test tree, and production string with methanol water to 250/4500 psi max pressure. Pressure test Well Tester's lines to 250/4500 psi with methanol water using BJ pump. Bleed off pressure. Open well and Rill with coil tubing and drilling BHA without circulating. Begin monitoring slackoff and pickup weight more carefully while running into the completion liner. If an obstruction is encountered before reaching the target depth of 17,375' MD (150' below base of deepest pay potential and 25' above the landing collar), PU and establish circulation of 1.3 BPM with slick fÌ"esh water. Rill and drill cement or stainless steel bands (lost in hole while running completion tubing) to target depth. PUH 20' and circulate 1-112 bottoms up or until returns are clean. Pump gel sweeps as required to clean hole. If cement solids removal fÌ"om the wellbore cannot be achieved with circulation, a mild inhibited acid (7~% HCI) will be pumped to dissolve the cement and circulate the solution to surface. POOH circulating at minimum rate with fÌ"esh water. Visually inspect drilling assembly and RU to perfonn similar operations on KS #lL#l (refer to separate Completion Procedure). LD BHA. Standback BJ coil tubing injector head and BOP's. Install MOC 3-118" 5K crescent flange with Otis connection. 7. Hold PJSM. MIRU Reeves wireline. MU lubricator and packoffto crescent Otis connection. PU and Rill with memory GR/CBL/Cased-hole Neutron and Density tools on Welltec's 2-118" OD wireline tractor. RIH and memory log fÌ"om target depth (±17,375') Kasilof State #1 rd Well Test Procedure KDW - 3/8/2004 7:09 AM Page 3 of4 . . to 12,500' MD. POOH with logging tools. Verify log data integrity. IMPORTANT: Forward data to David Brimberry to depth correct proposed perforated intervals below to the cased hole GR/CCL measurements recorded in this step. RD Reeves logging tools and move to KS #lL#l (refer to separate Completion Procedure). 8. Hold PJSM. RU BJ Services Coil Tubing and Nitrogen Unit. Test nitrogen lines to 6000 psi. MU double check assembly, lo/,¡" x 3' long straight pipe, and 2" wash tool to coil tubing connector. Pick up injector head and lubricator with crane and MU to coil tubing BOP. Pressure test lubricator. Open tree valves and Rlli with wash tool on coil tubing jetting well dry with nitrogen to 17,200' MD. POOH trapping 1480 psi surface (2653 psi BHP at 9213' TVD) nitrogen pressure in 3W' monobore to perforate the Tyonek interval at 40% underbalance. Move over to KS #lL#l (refer to separate Completion Procedure). 9. Connect MOC SPIDR gauge to Halliburton high pressure test line. Install backup SPIDR gauge at the test tree. Open wing and SSV valves to Halliburton flow test line with closed choke to monitor surface pressures during perforating and flow test. PROPOSED TYONEK PERFORATIONS (Check with David Brimberry for any measured deoth corrections orior to oerforatin2!) 17,015' - 17,053', 38' 16,970' - 17,000', 30' 9,213' 9,168' SBHP (0.48 osi/ft) 4422 4401 Surface Wellhead Pressure 40% DD 50% DD 0.96 N2 0.57 2as Measured Depth TVD 1480 1475 1785 1780 10. NU Otis crescent connection to top of swab valve. MIRU Schlumberger cased hole wireline with 0.32" mono-conductor cable (11,000 lbs breaking strength) to perforate the Tyonek. Have Welltec 2W' wireline tractor on standby for subsequent perforating runs if Schlumberger cannot get to desired depth with their guns on rollers. Lengths: 25' max loaded gun length with SAFE system= 21.8', tools = 4.7', pressure recorder=15.8'. Tractor length is 18' & weight is 180 lbs. Inspect guns and tractor (if used) prior to RIH. Verify that tractor safety subs are in place and functioning prior to Rlli. PU and RIH in the tubing with CCL, SAFE firing head, and 2.5" HSDPJ, 600, 6 JSPF 2506 HMX guns and pressure recorder (1 st run) to perforate the Tyonek intervals above. (Note: Max swell on guns in dry gas environment is 2.75" OD.) Correlate depth to corrected CCL on Reeves CBL log. Perforate and POOH. 11. After the last perforating run, PU and Rlli with Schlumberger CCLlGR/PL T tool to 16,960' MD. Record stabilized shut in pressure and temperature. POOH and LD wireline tools. RDMO Schlumberger. Kasilof State #1rd Well Test Procedure KDW - 3/8/2004 7:09 AM Page 4 of 4 . . 12. Flow test well through tree and Halliburton stack. No more than a 50% drawdown (1800 psi flowing WHP) is permitted for these intervals. The unloading rate up 3-1/2" casing is 3.6 MMCFGPD @ 1,800 psig FCP for a vertical wellbore. Consult Anchorage office Paul Williams for drawdown limitations 907-564-6403. (Note: Recommend Paul or other pressure transient analyst be onsite during testing.) Flow well until stabilized flow and pressure are achieved. Expected cleanup times are a minimum of 12 continuous hours and a maximum of 36 continuous hours. Obtain gas sample for gas analysis. Clean well until stabilized flow and pressure are achieved. Perform flow-after- flow test as prescribed by Anchorage Reservoir Engineer, Paul Williams. Shut In well and methanol injection lines for 48-hour surface PBU (SPIDR gauge). 13. The necessity of recording a second static BHP and BHT to 10' above the top perforated interval with a Schlumberger PLT tool on wireline will be decided based on operational risk and disparity of p* projections from the SPIDR data recorded before and after the flow test in the step above. 14. CONTINGENCY: Iflower perforated interval is wet, PU and Rill with Schlumberger CCL, SAFE firing head, Baker E5 long-stroke setting tool, and Weatherford 3 W', 10K cast iron bridge plug (Note: Differential rating of Weatherford BP is 10k psi down and up.) on 2W' Welltec tractor. Correlate CCL depth with corrected Reeves log and set BP above interval. POOH and RDMO Schlumberger wireline. 15. Release all rental and test equipment. Remove liner and berm. Lubricate in a BPV and shut in the well. Secure master valves shut with chain and a lock. CONTACTS Ken Walsh: 907-283-1311 (w) David Brimberry: 907-268-5660 (p) 907-394-3060 (cell) 907-564-6402 (w) 907-529-0527 (c) Ben Schoffinann: 907-564-6325 (w) 907-268-0122 (P) Paul Williams: 907-564-6403 (w) 907-529-8918 (c) Pete Berga: 907-564-6319 (w) 907 -231-0663 (p) Kasilof State #1rd Well Test Procedure KDW - 3/8/2004 7:09 AM . . Kasilof South #1~ (Motherbore-South Taraet) Kasilof Field 520' FSl, 1340' FWl, Sec. 28, T3N, R12W. 8M ~ J 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 Baker TAML Level 6 Formation Junction (Depth RTI Top of Junction @ 9901.49' Bifurcation pt. @ 9916.54' Bottom of 7" leg @ 9945.02' Formation Tops: Formation Sterling Beluga Tyonek T-1 Tyonek T-2 Tyonek T-3 TD Depth (MDI Depth (TVDI TD: 17,545' MD / 9642' TVD Dual 3-1/2" GT Packer@ 9853' MD/5161' TVD. Intermediate Casina 9-5/8" L-BO Top 0' MD 40 and 47 ppf BTC Bottom 9916' MD 5186' TVD 40 ppf BTC From 2729' MD to 9677' MD 12-114" hole with +/-1550 sks 12.7 ppg + 650 sks 15.7 ppg 7" 29 ppf Top Bottom L·80 9916' MD 9935' MD NV 5186' TVD 5194' TVD Proposed Tvonek Perfs: 16,970'-17,000' MD (4401 psi @ 9213' TVD) 17,015'-17,053' MD (4422 psi @ 9168' TV D) Liner 3-1/2" L-BO Top 9923' MD 9.2 ppf Hydrll 563 Bottom 17504' MD 6-1/8" hole with +/- 675 sks. 12.7 ppg cement. 5189' TVD 9605' TVD C) . Alaska .ass Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 2, 2004 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Delivered by Courier RE: Marathon Oil Company Kasilof South No.1 Well Samples CONFIDENTIAL The following CONFIDENTIAL well samples are being forwarded to AOGCC. A listing is attached. Marathon Oil Company Kasilof South No.1 Kasilof Prospect Kasilof Cook Inlet, Alaska Sec. 28, T-3-N, R-12-W, Seward Meridian API #: 501332052060 15 Boxes - Dry Samples 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, MARATHON OIL COMPANY 1/ 1, ,~ R,œived bY!~ 0 jJJ j 'h~ Æð-ð Y Date: Attachments ¡Jro IG~\ ~~#: (,'/L 1~¡-.ls-<.o / /3 Q AOGCC February 2,2004 Page 2 . . Marathon Oil Company Kasilof South No.1 Kasilof Prospect Kasilof Cook Inlet, Alaska Sec. 28, T-3-N, R-12-W, Seward Meridian API #: 501332052060 15 Boxes - Dry Samples Kasilof South #1 Dry Samples Depth From Depth To (F eet) (Feet) Box No. 2,860 4,000 1B 4,000 5,300 2B 5,300 6,600 3B 6,600 7,800 4B 7,800 8,700 5B 8,700 9,600 6B 9,600 10,560 7B 10,560 11,440 8B 11,440 12,360 9B 12,360 13,120 lOB 13,120 14,160 11B 14,160 14,980 12B 14,980 15,720 13B 15,720 16,700 14B 16,700 17,618 15B Kasilof South #1 - Redrilling of lost Leg . ~o 2, - '- S/.; . Winton- As we discussed on the phone, we are planning on redrilling the production interval of Kasilof South #1. The new well path twins the lost hole to the South and the Targets at depth remain unchanged. We will be landing within 500' of the lost hole and original target. We have corrected our data base to reflect the lost KS#1 production interval to KS#1 PB1. The new hole section will be drilled as KS#1. The new kick-off point will be 9,904' MD, 5,182' TVD vs the 10,300' MD, 5,336' TVD in the drilling program. The Mud and cement programs remain unchanged, and the data acquisition of Quad Combo will be acquired with Reeves. Please let me know if you need anything else. I have attached the new directional plan for your files. All the best, Steven «KS1 L 1 Rd tc.pdf» «KS1 L 1 Rd Std Rpt.pdf» «KS1 L 1 Rd pp.pdf» Content-Description: KS1 L 1 Rd tc.pdf KS1 L 1 Rd tc.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: KS1 L 1 Rd Std Rpt.pdf KS1 L 1 Rd Std Content-Type: application/octet-stream Content-Encoding: base64 r= KS1 L1Rd Content-Description: KS1 L 1 Rd pp.pdf Content-Type: appl ication/octet-stream Content-Encoding: base64 1 of 1 1/6/20043:25 PM . . MARATHON Oil Company Kasilof KSl LIRd slot #KSl Exploration Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KSl LIRd prop5596 Date printed Date created Last revised 29-Dec-2003 23-Dec-2003 29-Dec-2003 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 58.628,w151 22 39.995 Slot Grid coordinates are N 2310137.573, E 250208.731 Slot local coordinates are 553.41 N 1336.45 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . . MARATHON Oil Company PROPOSAL LISTING Page 1 Kasi1of,KS1 L1Rd Your ref KS1 L1Rd Exploration,Kenai Peninsula¡ Alaska Last revised : 29-Dec-2003 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 ATE S Deg/lOOft Sect 9904.00 66.47 291.07 5181.74 3391. 59 N 6813.10 W 0.00 6813.10 10000.00 65.94 287.98 5220.48 3420.95 N 6895.88 w 3.00 6895.88 10100.00 65.46 284.73 5261. 63 3446.61 N 6983.31 W 3.00 6983.31 10200.00 65.05 281.46 5303.50 3467.19 N 7071.76 W 3.00 7071. 76 10213.93 65.00 281.00 5309.38 3469.65 N 7084.15 w 3.00 7084.15 10300.00 64.95 27 9.58 5345.79 3483.57 N 7160.88 w 1. 50 7160.88 10400.00 64.92 277.92 5388.15 3497.35 N 7250.40 W 1. 50 7250.40 10500.00 64.90 276.26 5430.56 3508.53 N 7340.27 W 1. 50 7340.27 10600.00 64.90 274.61 5472.98 3517.11 N 7430.41 W 1.50 7430.41 10700.00 64.92 272.95 5515.39 3523.08 N 7520.78 W 1. 50 7520.78 10800.00 64.96 271.30 5557.75 3526.44 N 7611.30 W 1. 50 7611.30 10878.38 65.00 270.00 5590.90 3527.24 N 7682.31 W 1.50 7682.31 11000.00 65.00 270.00 5642.30 3527.24 N 7792.54 W 0.00 7792.54 11500.00 65.00 270.00 5853.61 3527.24 N 8245.69 W 0.00 8245.69 11609.78 65.00 270.00 5900.00 3527.24 N 8345.18 W 0.00 8345.18 12000.00 65.00 270.00 6064.92 3527.24 N 8698.85 W 0.00 8698.85 12500.00 65.00 270.00 6276.23 3527.24 N 9152.00 W 0.00 9152.00 13000.00 65.00 270.00 6487.53 3527.24 N 9605.16 W 0.00 9605.16 13500.00 65.00 270.00 6698.84 3527.24 N 10058.31 W 0.00 10058.31 13502.74 65.00 270.00 6700.00 3527 .24 N 10060.79 w 0.00 10060.79 13600.00 63.58 270.37 6742.19 3527.52 N 10148.42 W 1. 50 10148.42 13700.00 62.12 270.76 6787.83 3528.40 N 10237.40 W 1.50 10237.40 13800.00 60.66 271.16 6835.71 3529.86 N 10325.17 W 1. 50 10325.17 13900.00 59.20 271.57 6885.81 3531.91 N 10411.69 w 1. 50 10411.69 14000.00 57.75 271.99 6938.09 3534.56 N 10496.89 W 1. 50 10496.89 14100.00 56.29 272.43 6992.53 3537.79 N 10580.71 W 1.50 10580.71 14200.00 54.84 272.88 7049.07 3541.60 N 10663.10 W 1. 50 10663.10 14300.00 53.39 273.35 7107.68 3546.00 N 10743.99 W 1. 50 10743.99 14400.00 51.94 273.83 7168.33 3550.98 N 10823.34 W 1. 50 10823.34 14500.00 50.49 274.34 7230.97 3556.53 N 10901.10 W 1.50 10901.10 14600.00 49.05 274.87 7295.55 3562.66 N 10977.19 W 1. 50 10977.19 14700.00 47.61 275.42 7362.04 3569.35 N 11051. 59 W 1.50 11051.59 14800.00 46.17 276.00 7430.38 3576.61 N 11124.22 W 1. 50 11124.22 14900.00 44.73 276.60 7500.53 3584.42 N 11195.05 W 1.50 11195.05 15000.00 43.30 277.24 7572.45 3592.79 N 11264.02 W 1.50 11264.02 15100.00 41. 87 277.91 7646.08 3601.71 N 11331.10 W 1. 50 11331.10 15200.00 40.44 278 . 62 7721.37 3611.16 N 11396.22 W 1. 50 11396.22 15300.00 39.02 279.38 7798.28 3621.16 N 11459.35 W 1. 50 11459.35 15400.00 37.61 280.18 7876.74 3631. 68 N 11520.44 W 1. 50 11520.44 15500.00 36.20 281.03 7956.70 3642.72 N 11579.46 W 1. 50 11579.46 15600.00 34.79 281.94 8038.12 3654.27 N 11636.36 W 1. 50 11636.36 15674.70 33.75 282.67 8099.85 3663.23 N 11677.45 W 1. 50 11677.45 16000.00 33.75 282.67 8370.33 3702.86 N 11853.78 w 0.00 11853.78 16500.00 33.75 282.67 8786.07 3763.77 N 12124.79 w 0.00 12124.79 17000.00 33.75 282.67 9201. 81 3824.69 N 12395.81 W 0.00 12395.81 17478.89 33.75 282.67 9600.00 3883.03 N 12655.38 W 0.00 12655.38 All data is in feet unless otherwise stated. Coordinates from slot #KS1 and TVD from RKB (N273) (104.65 Ft above mean sea level). Bottom hole distance is 13237.69 on azimuth 287.06 degrees from wellhead. Total Dogleg for wellpath is 51.84 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 270.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . MARATHON Oil Company Kasilof,KSl LlRd Exploration/Kenai Peninsula, Alaska Top MD Top TVD . PROPOSAL LISTING Page 2 Your ref KSl LlRd Last revised : 29-Dec-2003 Rectangular Coords. Casing positions in string 'A' Rectangular Coords. ------------------------------ ------------------------------ Bot MD Bot TVD ----------------------------------------------------------------------------------------------------------- Casing 10125.00 nla nla nla 5272.04 5181. 74 5181. 74 5181. 74 Target name 3452.24N 339l.59N 3391.59N 3391. 59N 7005.34W 6813.10W 6813.10W 6813.10W 9904.00 17478.89 nla nla 5181.74 9600.00 5181. 74 5181. 74 3391.59N 3883.03N 3391.59N 3391.59N Targets associated with this wellpath --------------------~---------------- ------------------------------------- Geographic Location T.V.D. 6813.10W l2655.38W 6813 .10W 6813 .10W 3883.03N Rectangular Coordinates 12655.38E 23-Dec-2003 7 Casing 3 1/2 Liner 13 3/8 Casing 20 Conductor ----------------------------------------------------------------------------------------------------------- Revised Base Tyonek 9300.00 Creat~d by bm,chae! Dote plotted: 29-0ec-2003 i i i Coordinates ore in feet reference slot #KS1. ITrue Vertical Depths ore r,eference RK8 (N273). ! if~¡¡¡iJI i BAKER I 1___________r~~':GHES I Plot Reference ìs KS 1 L 1 Rd. . ! I I MARATHON Oil Company I Structure Kosilof Well; KS1 L1Rd Field Exploration Location Kenai Peninsula, Alaska < - West (feet) 12800 12400 12000 11600 11200 10800 10400 10000 9600 9200 7600 7200 EJ 4800 €Ð 5200 5600 6000 ----.. -+- () 6400 () 4- '-/ £ 6800 -+- (L () 0 7200 0 0 -+- 7600 l- () > () 8000 ::¡ l- f- I 8400 V 8800 9200 9600 DlS: 1.50 deg per 100 It 10000 6400 6800 7200 - -- 8800 8400 8000 ------------------------ 7600 8000 8400 {-.o'< ..,.,-".~ 7 Casing ~"". 0," '''''''',"'''' 7 Cas i n g <o'er <:)'0 ~'...... <0'0. ,,0,'), 0,<:) -""",,<,.. End of Turn <0 <J'. 0,<0 <:) "',~,. co~ ~<0 SJ ~._~..~_,~_ ""'.::,>-, --.: 0'< +: ---- WELL PROFILE DATA Point ----- "0 01, NO East V. Sect 9904.00 66.47 291.07 518L74 3391.59 -6813.10 6613.10 of Orop/Tum 10213.93 65.00 281.00 5309.J6 3469.65 -7064.15 7084.15 ofTum 10876.38 65.00 270.00 5590.90 3527.24 -7682.31 7682.31 of Hold 11609.78 270.00 5900.00 3527.24 -8345.18 8345.18 13502.74 65.00 270.00 6700.00 3527.24· -10060.79 10060.79 of Orop/Tum 15674.70 33.75 262.67 6D99.8~ 366J.23 -11677.45 11677.45 ......>.:.:."'~:::>~~- '-"'~>~- 6800 6400 ---- 4000 3600 ^ I I(S#J 3200 Z 0 ~ ::J 2800 ,--... ..... C1> C1> - 2400 '-" 2000 '--.....,~-. '- .::~.~.~,..,. ........ --"" End of Hold 65.00 '<"'-"'- 63.58 , "'. 60.66 .... -,,_, 57.75's '" ....~...."'......... 54.84 '" , 51.94"'" -'''" 49.05 '" "" 46.17 " '- 43.30 '" ' 40.44 \¡ " '\ 37.61 '\ 34.79 \ End of Turn/Drop 33.75 \ '\ \ \ \ \ \\ \\ '\ \\ , \ \ \ \ \'8 @ DlS: 1.50 deg per 100 ft 8800 9600 10000 10400 10800 11200 11600 12000 12400 12800 9200 Vertical Section (feet) -> Azimuth 270.00 with reference 0.00 S, 0.00 E from slot #KS 1 Created by bmichoel Dote plotted: 29-Dec-2003 Plot Reference is KS1 l1Rd. Coordinotes ore in feet reference slot #KS 1. Verticol Depths ore reference RKB miíí1lll BAKER HUGHlS 320 310 300 290 280 270 260 250 240 230 220 . ,- -e --------~-- I MARATHON ¡ I i I Structure: KasHof ___~~~~_: Exploration Oil Company i Well : KS 1 L 1 Rd Location: Kenai Peninsula. Alaska ~ ----------------- TRUE NORTH ~ 350 0 ~ 1 1 300 1 0 340 20 , J 11200 3.!0 30 330 40 50 60 70 80 90 100 11 0 120 130 140 210 150 200 160 190 180 170 Jormal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well Re: Upcoming BOP test Nabors Rig 273E . , J-Dd- -é7-S-Co Subject: Re: Upcoming BOP test Nabors Rig 273E Date: Wed, 12 Nov 200310:26:05 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Nabors 273 Supervisor <Nabors273Supervisor@MarathonOil.com> CC: "Lambe, Steven S." <SSLambe@MarathonOil.com>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Gerard, John Crisp was out 2 weeks ago, so we will waive witnessing this BOP test. Please send in the report form as usual. Tom Maunder, PE AOGCC Nabors 273 Supervisor wrote: Tom- This e-mail is to serve as notification that we will be conducting a BOP test at the Nabors rig 273E (well Kasilof South #1) this afternoon 11/12/2003 at approximately 18:00 hrs. Thanks Marathon Drilling Supervisor(s) (Gerard Roger, Russ Truby, Milton Castleman, Randy Ratliff) Nabors Rig 273E Kasilof South Well #1 Drilling Supervisor's Phone 907-260-6935 Toolpusher's Phone 907-260-6937 Rig Fax 907-260-6934 Marathon PIC: BAJ External E-mail Address:..nabors273supervisor@marathonoil.com.. Tom Maunder <tom maunderocv.admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 11/12/200310:26 AM . 1TŒ lill~ !Æ~!Æ~æ!Æ AI1ASIiA. OIL AND GAS CONSERVATION COMMISSION S. S. Lambe Senior Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage Alaska 99519 . FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kasilof South #1 Marathon Oil Company Permit No: 202-256 Surface Location: 520' FSL, 1340' FWL, Sec. 28, T3N, R12W, SM Bottomho1e Location: 1025' FNL, 773' FEL, Sec. 25, T3N, R13W, 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. 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, µ...~ L:.-~~ ~ Randy ¡(uedrich Commissioner BY ORDER OR THE COMMISSION DATED thi4iL day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section . . 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, and the accompanying schematics and procedure. Kasilof South #1 is a Wild Cat with a spud date of October 1, 2003. / KasHof South #1 will be a Multi-Lateral well, TAML Level 6 Junction, targeting the Beluga and Tyonek Reservoirs in two distinct bottom hole locations drilled from an onshore pad with Offshore Targets. Due to the complexity of the well, I am proposing to come across and introduce both Kasilof South #1 and KasHof 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, ,JkJL- Steven S. Lambe Drilling Engineer Enclosure RECEIVED ssl DECJ 1] 2002 A,!aska 01.1 & Gas Cons. Gommissioro g:\cmn\drlg\sterlinglsu44-10IAOGCCPTDKS#1.xIS a STATE OF ALASKA .. 1N6A- ~I Z-~/2-0DJ ALAS~~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 210 AAC 25.005 'fI 1a. Type of Work Drill [8] Re-Drill 0 1b. Type of well. Exploratory0 Stratigraphic TestD Development Oil 0 Re-EntryD Deepen 0 ServiceD Development Gas 0 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 AAC 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 1025'FNL, 1912'FEL, Sec. 30, T3N, R12W, S.M. Kasilof South #1 5194234 AtTotal Depth 9. APproximat~pud Date Amount 1025'FNL, 773'FEL, Sec. 25, T3N, R13W, S.M. 10101/03 $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) / ./ 5,400' feet 400 feet 16260 17,232' MD / 9,300' TVD feet 16. To be Completed for Deviated Wells 17. Anticipated Pressure (se~ AAC 25.035 (e) (2)) Kickoff Depth 500 feet Maximum Hole Angle 660 Maximum Surface 3089 psig at Total Depth (TVD) 9300 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement .dJ. Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) ¡I Driven 20" 133 K-55 PE +1-120' 0' 0' +1-120' +1-120' f" ~' 13 3/8" 68 L-80 BTC 2700' 0' 0' 2700' 2245 1050sx 12 1/4" 9-5/8x7x7 47,40,26 L-80 Hydril 563 10500 0' 0' 10500 5400 2270 sx 6-1/8" 31/2" 9.3 L-80 Hydril 563 6932 10300 5336 17232 9300 675 sx The Kasilof South #1 will be directionally drilled to an estimated total depth of 17232' md, 9300' tvd from an existing pad located at mile 4.2 Coho Loop Road. The drilling rig currently being evaluated is Nabors Rig #273. ..r- The Well will be drilled and completed as a TAML level #6 Multi-lateral Well. This is the first of 2 10-40t's. - DQlling 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 heceby <ert;fy th" th, foce90J' fU' ,"d ro'i th, b"" of my koowledg' 'JI" L 564-6332 Signed S. S. Lambe ~ ~ <----------·-:yitle Senior Drilling Engineer Date 12/27/2002 Commission Use Only Permit Number API Number )~APProval ~72 /4 See Cover Letter 2P:2- - 2.5~ 50-/-.35'" 2D 5)l) , 2... i lY] For Other Requiref!:1~nts Conditions of Approval Samples Required DYes IE1NO Mud Log Required IXJYes ~ t l t I V t u Hydrogen Sulfide Measures DYes IX! No Directional Survey Required 00 Yes DNo Required Working Pressure for BOPE D2M D3M D5M D10M D15M DEC 30 2002 Other: T -e..c; t- 1> 0 P E f., ~S""O pst. tf.~ í~iaßka on & Gas Cons, Gomm¡$$¡o~ Ie-c~ by order of '~\11CMraPt/4/l?J Approved by Commissioner the Commission Date Ð 1 -4 R -85 Submit1ñ Tri licate toOtta ø ,.~ p Marathon Oil Company Alaska Region It pre.d By: Approved By: Date: S.S. Lambe 12/27/02 Drilling Program Well: Kasilof South #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 3,735' 8,532' Coordinates from Wellhead 11,686' 5,900' North West Tyonek Entry 3,735' 10,330' Coordinates from Wellhead 13,654' 6,700' North West Bottom Hole 3,735' 12,673' Coordinates from Wellhead 17,232' 9,300' North West RKB Elevation: RKB to MSL 115'. GL to MSL 80' Total Depth: TVD 9.300' MD17.232' Max. Angle ~ 66.00 Course 270.00 Abnormal Pressures: None Anticipated -- Subnormal Pressures: None Anticipated Coring and DST's: Cased hole test in Tvonek. No Corinq Mud Logging: Contractor: Epoch Start Depth: Below Surface 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 Surface GR Intermediate GR GR Production Quad Combo Cement Mapping Tool Kasilof South #1 Drilling Program Page 1 of 13 e e Drilling Program Summary Drive Pipe: Surface: Intermediate: Production: Casing Program Drive 20" 0.0., 133#, B casing to +1- 120' BGL, 155' RKB. MIRU Drilling Rig. Install 20" SO X 20" Quick Connect, and 20" Quick Connect X 21 X" 2M DSA. NU and function test 21 X" 2M diverter system. ,. 1- It;:ii \L-Iú" Drill Jl-4-f2" hole to +/- 2,700' MD 12,245'TVD on a 2950 azimuth per the attached directionsil program. Run and cement 13-3/8" casing. Install 13-3/8" 5M Multi-Bowl AssemblY oJ). Iy 0 ~/8" casing Hanger. NU 13 5/8" 5M BOPE. Test BOPE and choke manifold to 250 / .ÞGeJO psi. Set wear bushing. Test casing to 1500 psi. c:.µ. r' S' I'; Drill out float equipment and make 20'- 25' of new hole. CBU. Test shoe to leak Offb~g anticipated). Drill 12-1/4" hole to 10,500' MD 15,400' TVD on a 2950 azimuth as per the attached directional program. Pull wear bushing. Run 9-5/8" casing and Junction pe attached program. Expand junction and install pack off assembly. RIH with inner string and cement 9-5/8" casing per attached detailed procedure. Test casing to 2000 psi. , 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 270 degree Azimuth to 17,232' per attached directional program. At TO, condition hole and trip for LWD. MWD log 6-1/8" hole section. Run and Cement 3-1/2" liner. Dress PBR. Run test string in hole. CT clean out liner. Wireline convey Cement mapping Tool. Blow down well with CT and nitrogen. Selectively perforate Tyonek interval. Establish flow, clean up, test, and perform a PBU....lsolate perforations with bridge plug. Displace gas to completion brine. Set FH packer with high pressure disk. Pull ìV1õIFÏerbore drilling diverter. . Drill and complete Lateral Leg to North Targets (320 Azimuth) under Kasilof South #1 L 1 procedure. Run Dual Completion. API Values Casing Casing Hole Size Size Set Set To Weight Casing Conn (in) Burst Collapse Tension (in) From (MD) (ppf) Gr~ Ty~ (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' 10,500' 40 & 47 L-80 H-563 12-1/4" 5,750 3,090 979 31/2" 10,300' 17,232' 9.3 L-80 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 5400' 17.0 8.6 2032 1.88 1.16 2.99 31/2" 9.3 L-80 9300' 15.0 8.6 3089 3.68 2.27 1.66 Kasilof South #1 Drilling Program Page 2 of 13 e e Directional Program Directional Co: Baker Huqhes INTEQ KOP: 500' Direction: 295 Gyro Co: Build Rate: 3.0 To: 66 deq @ 2245' TVD Turn Rate: 1.83 To: 270 Az @ 5926' TVD Drop Rate: 1.5 To: 30 deq @ 8,282' TVD Turn: 10,500' MD Direction: 270 Drop Depth: 13,653' MD/6. 700' TVD Gyro Survey Required: Magnetic Multishots Required: General Calculation of Maximum Anticipated Surface 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. Surface 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 @ 5417' 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 = PP 7°.052 * TVDf - (GG * TVDf) MASP = 8.6 * 0.057* 9300' - (0.115 * 9300') MASP = 3089 psi Kasilof South #1 Drilling Program Page 3 of 13 Cementing Program Surface Casing Size: 13-3/8" Tail Slurry: Top of Cement: Specifications: Compress Strength: Total Volume: Production Casing (----. '*) ..' . ...~'t- .,' 0-' ~l~ . ~l<;;. '-~ ':x'U -\~ Size: 9-5/8" Lead Slurry: Top of Cement: Specifications: Compress Strength: Tail Slurry: Top of Cement: Specifications: Compress Strength: Production Liner Total Volume: Size: 3 1/2" Tail Slurry: Top of Cement: Specifications: Compress Strength: Total Volume: e Contractor: BJ Services e "...."'''....~ Setting Depth, ~700'~/ 2245' TVD Annular Volume ~, with 17 1/2" gauge hole, 1875 ft3 Density, 12.0 ppg, Yld,~ ft3/sx, S~X, cf,2625 ft3 _º'MD/~' TVD Class G + additives Mixed w/ fresh water 500 psi in 8 hrs 2625 ft3, 40% Open Hole Excess, WOC Time:~ hrs Surface casing will be an inner string cement job. Setting Depth: 10500' MD/ 5400' TVD Ann. Volume 2700'to 10,500' with 12 1/4" gauge hole:2500 ft3 Densi.t~---'.LS ppg, Yld,~ ft3/sx, SX~, ct, 3594 ~/ 2154' TVD .. s G + additives Mixed w/ fresh water 500 psi in ~ hrs, 700 psi in ~ hrs Density:~ ppg, Yield:~ ft3/sx, sx:~.. x, cf: 674 ft3 ~. 9500'MD/ 5010' TVD Class G + additives Mixed w/ fresh water psi in psi in 24 hrs hrs, 4268 ft3, 30% Open Hole Excess, WOC Time: 8 hrs Setting Depth: 17232' MD/ 9300' TVD Annular Volume 10500' to 17232' with ~ gauge hole: 927 ft3 Density:~ ppg, Yield:~ ft3/sx ~x, 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 Drilling Program Page 4 of 13 e e Diverter and BOP Program The diverter system will consist of a 21 y-,", 2000 psi annular preventor and ,(16" pJl non-bifurcated vent line. The vent line will be full opening and integrated with the annular in the fail s~fê"âêsign as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. 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 13 5/8", 5000 psi drilling spool (mud cross) with 31/8",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 LowlHigh Size MASP Test BOPS (psi) Casing (in) (psi) (psi) Size & Rating Drive Pipe 20" nla nla (1) 21-1/4" 2M Annular wI HCR Valve Function Surface 13 3/8" 1668 1700 (1) 13-5/8" 5M Annular 25013000 (9.2 ppg (1) 13-5/8" 5M Blind ram 25013000 mud) (2) 13-5/8" 5M Pipe ram 25013000 Intermediate 9-5/8" 2032 1600 (9.8 (1) 13-5/8" 5M Annular 25013000 ppg mud) (1) 13-5/8" 5M Blind ram 25013000 (2) 13-5/8" 5M Pipe ram 25013000 Production 3 }i" 3089 2700 (1) 13-5/8" 5M Annular 25013500 Liner (9.8 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. 13-3/8" Surface Casing at 2245' TVD CTPMASP = 1668 psi CTPBurst = 3450 * 0.7 - «9.2-8.3) * 0.052 * 2245) = 2310 psi Test to 1700 psi 9-5/8" Intermediate at 5400' TVD CTPMASP = 2032 psi Test to 1600 psi CTPBurst = 5750 * 0.7 - «9.8-8.3) * 0.052 * 5400) = 3604 psi Junction Burst = 2500 *.8 -«9.8-8.3) * 0.052 * 5400) = 1578 psi r----- 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 Drilling Program Page 5 of 13 e e Mud Program Contractor: MI Drilling Fluids Interval (MD) Mud Weight From To (ppg) Water Loss Mud Type 0' 2700' 8.8 - 9.2 N/C - 10 Gel / Gelex 2700' 7500' 9.0 - 9.8 8 -10 Flo Pro with Lubricant 7500' 10500' 9.0 - 9.8 f" >8 Flo Pro with Lubricant 10500' 17232' 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 Multibowl System 13-518" 5M system Tubing Head 13-5/8" 3M X 13-5/8" 5M Tubing Hanger 13-5/8" x 3-112" x 3-1/2" Split dual Hangers Detailed Drilling Procedure Formation Leak off Test Suñace 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 Drilling Program Page 6 of 13 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 ~ GA- IADC WOB RPM (MD) (in) Bit Model Code (k Ibs) 0' - 2,700' j.:l.tfY i V . < TBD 117 1 0/30 220 2,700' - 10,500' 12 1/4" PDC 10,000' - 10,200' 17-112" Under Reamer for Junction 10,500' -17,232' 6-1/8" TBD Drill String Item Ppf Makeup Torque Max Pull - Premium 3 Y:t HWDP, 3 Y2"IF 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, 5Y2" 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% eff) (spm) National 12-P-160 6" 12" 4670 4.275 140 National 12-P-160 6 Y:z" 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) ~ ¡j¡ (psi) (fpm) (ppç¡ ) (32"s) Remarks 2700' .J.H12" t~ 1020 3500 89 9.5 TFA=1 RST Drilling 10500' 121/4" 950 4000 186 10.0 TFA=1.5 RST Drilling 17232' 61/8" 350 2550 398 12.7 TFA=1.22 RST Drilling Kasilof South #1 Drilling Program Page 7 of 13 e e OPERATIONAL PROCEDURE: KASllOF SOUTH #1 DRilLING PROGRAM. 1. Drive 20" Conductor to +/- 150'. Prep with Casing Head (20" aD SW x 20" Quick Disconnect). Pressure test void between seals and weld. 2. MOB in Drilling Rig. Hold Pre-spud meeting and training session for entire drilling team. 3. NU & Test 20" Diverter. I ~ " \dG~ 4. MU ~ Auto Track BHA for drilling top hole. PU 2,500' of 5" S-135 Drill pipe. Drill 17-1/2" hole to KOP @ 500'. Gelex Spud Mud will be used on this section. 5. At 500', Start Building @ 30/100' to 660 (2,700' MD) on 2950 AZ. Planned TD of 17-1/2" is 2,700' MD (2,245' TVD). Consider circulating 1.5 BU @ each stand from 45° TD as best practice to clear cuttings in higher angle section. 6. Back Ream hole to 2,000' (450) to ensure good hole cleaning in higher angle. RIH to TD and condition mud for running casing. POOH & LD drilling BHA. 7. MU Float shoe, 1 joint, Stab in float collar, & RIH 13-3/8",68 #, Buttress, L-80 casing. MU 20" x 13-3/8" Casing Hanger. RIH on Landing joint and Land 13-3/8" casing. Back out of landing joint above the annular on Left hand thread. Place centralizers as follows: 2 on bottom joint #1, 1 on joint #3, 1 on Joint #5, as required in OH, and 2 in 20" casing. / MU & RIH with inner string cementing BHA. Stab in and establish circulation. 8. 9. ./ Mix and pump pre-flush followed by 13.5 ppg cement until cement returns to surface. Launch wiper dart and displace with spud mud. Un-sting from collar, ensure checks are holding, and POOH with inner string. 10. Re-engage landing joint and back out of 13-3/8" hanger. Nt) ~Diverter. NU Multi-bowl wellhead. NU & Test BOPS. / PU 5" DP for Intermediate Hole Section. 11. 12. 13. MU 12-1/4" PDC on Auto Track BHA. RIH to stab in float collar. 14. Drill Shoe + 25' of formation. Perform LOT. Displace spud mud to Flo-Pro Mud system. 15. Drill ahead 12-1/4" hole on 295 Azimuth, 66° tangent to 10,500'. Control P-Rate for hole cleaning. ~ <60Q() l Circulate a minimum of 3 BU's to clean hole. 16. 17. POOH. LD Directional BHA. PU Positive lock open Under Reamerw/ PDC blades. Incorporate 12" Gauge to ensure Junction will drift hole. RIH & UR 12-1/4" hole from 1Q.OOO' to 10-dQ.0' to 17- 1/2". ·r "----- 18. Open Circulating sub and Circulate hole clean via pumping & Rotation. A minimum of 3 BU's. 19. Condition mud for running casing and add lubricant to 5% in OH. Kasilof South #1 Drilling Program Page 8 of 13 20. POOH. Prep to Run 9-5/8".sing, Pull Multi-bowl protector. e 21. MU 7" Shoe Track including Special landing collar for DP wiper plug, total of 8 joints 7" 29# L-80, Hydrill 563, 15' 7" 23# pup, formation Junction, 5 joints 9-5/8" 47#, xx joints 9-5/8" 40#,2,700' of 47#. RIH. / 22. Hang off 9-5/8" casing in Multi-Bowl with Junction Bifurcation point positioned @ 10,100'. 9-5/8" by 13-3/8" pack off and secure. Test void. 23. MU & RIH Formation Swage BHA to 500'. Break circulation on casing. Continue RIH. 24. No Go the Swage in the Swage Diverter. Set down and close Expansion Joints. Set Spear. Set DP in slips wi 10K tension. Drop ball. 25. Swage Leg #1 by applying pressure (4,000 psi) recording fluid pumped. Graph chart. At end of swaging operation (500 psi), shear out circulating sub. 26. PU OP & release spear. Break Circulation on Casing by OH annulus. POOH & LD BHA. 27. MU Cementing Seal BHA. RIH 28. Continue Breaking circulation to prevent mud thickening in Annulus of OH & 9-5/8". 29. Stab into Drillable Seal Sub. Close annular and test casing and Junction to 1000 psi. 30. Circulate and condition hole for Cementing. Perform a Fluid Caliper wi Carbide pills. 31. Mix & Pump Preflush, 12.5 Lead Cement, and 15.7 Tail Cement, displace with Wiper dart and mud. Planned TOC @ 2,500' MD. Use caliper hole volume or gage hole + 20 % excess. 32. Check for back flow, Reverse circulate any residual cement. 33. POOH & LD Cementing BHA. 34. MU FJD running tool & RIH wi MWD. Check and record Orientation of the formation Junction. 35. POOH & LO FJD tool. 36. MU & RIH Leg #1 Drilling BHA. 37. Drill out Shoe + 25' of New Hole. 38. Perform LOT.62iSPI e hole over to 9.5 ppg FLO-PRO mud system. Drill ahead to ,2. 3 MD, 9,300' TVD, 2700 Azimuth as per the directional plan. _ '\.OOè/ Note: Watch for cuttings beds in the 9-518" by OP annulus. When Pulling OOH, circulate and Rotate above junction to clear cutting from 9-5/8" casing. NOTE: TO will be called 200' below last gas shows from mud loggers. 39. 40. At TD, Circulate Hole clean & POOH. LD Drilling BHA & PU Quad Combo LWD. 41. RIH to TD. Start logging out @ 90'/hr rotating @ 30 rpm to the Top of Gas or Junction. RIH to TO and condition for the Liner. 42. fluid caliper OH with Carbide for Liner Cementing operations Kasilof South #1 Drilling Program Page 9 of 13 e e 43. POOH & LD/RD LWD equipment. 44. MU Shoe Track of Float Shoe, 2 jnts, Float Collar, 2 joints, Landing Collar. 45. RIH on xxx joints of 3-1/2",9.3#, L-80, Hydril563, Range 3 casing. Plan 15' stand off from bottom and hanger @ 10,300 (200' lap). 46. MU ZXP Liner Hanger/Packer, Running Tool on 5" DP. 47. RIH with Liner and Tag Bottom. PU 15'. Drop Ball and set liner hanger. 48. Circulate and Condition hole while rotating prior to Cementing. 49. Pump pre-flush, Sure-Bond I (LCM), Water Spacer, and 1.3 Annular volumes of 12.5 ppg high / strength (Ninilchik Recipe) cement. Displace with 2#/BBL KCI Flo-Pro Gel pill. 50. Bump plug and Set packer. PU and reverse circulate excess cement. 51. POH and Lay down Cementing BHA. 52. wac. PU and RIH PBR polishing will with 20' extension for cleaning out top of 3-1/2". 53. Close bag and Test TaL to 1500 psi. POOH & LD BHA. 54. PU & RIH with Seal Section and 3-1/2", 9.3#, L-80 Hydril 533 test string with Methanol Injection mandrel. Land Seals and space out for Flange Top Joint 2' off rig floor and seals l' from full engagement. 55. Close bag and test seals to 1500 psi. 56. NU & Secure 3-1/16" bore 5K Tree consisting of Dual Masters, Flow TEE, and swab valve. 57. Install actuated wing and choke to Flow tee. 58. RU 1-112" Tapered Coil Tubing Unit and N2 pump. RU Well Testing Equipment. 59. Pressure test to 5,000 psi against Swab valve with Wing and Choke open (Tree & Flanged joint previous gas tested to 5,000 psi). Note: No untested, threaded connections above BOP annular. 60. MU 2.80" Cement Mill, 2-1/8" PDM, MHA (Dual checks, circ sub, hydraulic Disconnect, and CT adapter). 61. RIH circulating slicked brine at minimum rate. Weight checks every 2000' to confirm Modeled PU & Slack off weights. 62. Drill Cement as required to Landing collar with slicked brine displacing gelled brine. Pump sweeps as required. Flag Pipe for TD with red paint. 63. POOH and LD Clean OUT BHA. Rig aside coil & RU E-line unit. 64. MU & RIH with slim hole CMT, GR, CCL, Tractor and RIH to Landing Collar. Log TD to TaL. POOH recording GR to surface for AOGCC. 65. RD E-Line and RU coil. Kasilof South #1 Drilling Program Page 10 of 13 NOTE: Intended Underbalance f.perfOrating is 40%. e 66. MU CT jetting Nozzle. RIH jetting Nitrogen to landing collar. 67. POOH & RD CT. RU E-line wi tractor assembly. 68. MU & RIH with 2-1/2" HC perforating guns 69. Perforate Tyonek zone from LWD and mud logs. NOTE: Ensure AOGCC has been notified with intended intervals and Sundry application approved. POOH. Rig down E-Line. ..,/ 70. Hold operational safety meeting. Gas is expected to be both sweet and dry. 71. Flow well through test skid to Vent Stack maintaining no more than 50% under balance. 72. Clean well until stabilized flow and pressure are achieved. Minimum Clean up time 12 hours with a maximum of 36 Hours. 73. Flow well at rate prescribed by Reservoir for 24 hours recording surface data (SPIDR). 74. Shut In well for 24 hour PBU. 75. Wait on ORDERS per Matrix. Additional zones may be perforated and tested. 76. RU E-line. MU & RIH composite Bridge plug. Record BHP and gradients. 77. Set Plug above top perforation. POOH. Bleed pressure & Test composite. RD E-line. 78. Lubricate & Bleed to fill liner with inhibited 6% KCL. Open bypass valve and displace gas to mud. 79. With perforations isolated, Unstab from Seals and circulate well. 80. POOH and Lay down 3-1/2" Test String. 81. MU PBR seal assembly, 3-1/2" Tubing,Glass Disk, Model FH production packer, xx feet of 3- 1/2" tubing, and upper PBR. Upper PBR to be set 2' - 5' from Bifurcation point. 82. RIH with Packer assembly. Fill pipe while RIH. Land out seals into ZXP PBR and Verify depth. Pressure down DP to test seals before setting Model "FH" packer. 83. PU so top of new PBR is between 2' - 5' from Bifurcation point. Set Packer and POOH. 84. LD running tool & PU FJD pulling tool. RIH to the Diverter. Circulate & flush debris. SD pumps and latch. Verify latching by applying torque. POOH with Diverter. END OF DRilLING PROCEDURE FOR KASllOF SOUTH #1. COMPLETION PROCEDURE IN KASllOF SOUTH #1 l1 DRilLING PROGRAM. Kasilof South #1 Drilling Program Page 11 of 13 KASILOF SOUTH #1 L 1 D.LlNG PROGRAM. e 85. p6g~eg #2 filling Dive r on FJD running tool. RIH and set Leg #& Verify setting and 86. LD FJD running tool. 87. 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. 88. Drill ahead tO~MD, 9,300' TVD, 320" Azimuth as per the directional plan. 89. 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. 90. NOTE: TD will be called 200' below last gas shows from mud loggers / 91. At TD, Circulate Hole clean & POOH. LD Drilling BHA. If required, DP convey CMR, then FMI. 92. 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. 93. Fluid caliper OH with Carbide for Liner Cementing operations 94. POOH & LD/RD LWD equipment. 95. MU Shoe Track of Float Shoe, 2 jnts, Float Collar, 2 joints, Landing Collar. 96. RIH on xxx joints of 3-1/2",9.3#, L-80, Hydril 563, Range 3 casing. Plan 40' stand off from bottom and hanger @ Leg # 2 No-Go 10,125'. 97. MU shortened ZXP Liner Hanger/Packer, Running Tool on 5" DP. 98. 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 Cementing. 99. Pump pre-flush, Sure-Bond I (LCM), Water Spacer, and 1.3 Annular volumes of 12.5 ppg high strength (Ninilchik Recipe) cement. Displace with 2#/BBL KCI Flo-Pro Gel pill. 100. Bump plug and Set packer. PU and reverse circulate excess cement. 101. POH and Lay down Cementing BHA. 102. wac. PU and RIH PBR polishing mill with 20' extension for cleaning out top 3-1/2". 103. Close bag and Test TaL to 1500 psi. Displace hole to inhibited brine. POOH & LD BHA. 104. MU FJD pulling tool. RIH and pull leg #2 drilling Diverter. POOH LD DP & BHA. Kasilof South #1 Drilling Program Page 12 of 13 KASILOF SOUTH #1 and ISILOF SOUTH #1 L 1 e COMPLETION PROGRAM. 105. RU dual handling equipment. 106. PU Seals, DSM, and GT packer per attached diagram. 107. RIH wI Dual 3-1/2" Tubing to 2,500' from surface. 1 08. MU chemical injection mandrels spaced 2 joints apart attaching ~" SS control line with bands. 109. Continue RIH with completion and lightly tag DSM on Alignment lug. 110. PU and Space out Tubing Hangers. 111. RIH and shear latch from DSM. Land completion. 112. Pressure down leg #1 and #2 to ensure seals are engaged. Hydraulically set GT packer against glass disk in leg #1. 113. Terminate Control lines, Set BPVs. 114. ND BOP's & NU Dual Tree And Test. 115. Release Rig. Kasilof South #1 Drilling Program Page 13 of 13 e 0 800 1600 ..--.. 2400 - () () -- '-" 3200 .!: - (l () 4000 0 0 4800 Ü - L () > 5600 () :J L 6400 l- I V 7200 8000 8800 9600 e freoted by Sutherland For: S Lambe Dote plotted : 21 -Oct - 2002 I Plot Reference Îs KS# 1 (MB) Version #3. ¡Coordinates ore in feet reference slot #KS 1. iTrue Vertical Depths are reference Est. RKB. ! ru. BAD_ HUGHIS INTEQ ~ +C> 20 Conductor c§) C)~PC) ~~ '>C)C) '} "v C)C) i' . C)C) "". C)C) ~'}. C)C) C) C) V,'~\)~",> 13 3/8 ~ End of o OLS: 3.00 deg per 100 ft Casing Curve TANGENT ANGLE 66.00 DEG 800 I iMARATHON Oil Company ---~~--~--- Structure: KasHof Well : KS# 1 Field: Exploration Location: Kenai Peninsula, Alaska < - West (feet) 13000 12000 11000 10000 9000 8000 7000 6000 5000 4000 3000 2000 1000 0 t? 84 ~O :0-\ 10 .0...,,\ ·0 " 0010, ".', 0 <0 <0 . " ..,.d ~ è--Ò " ~ v ~ -¥.¿> ,,10 .>-0 -:.::-0 "e,\'l- ,0 ° '" "':0-\ ,,0 .<,\0" c'0 '\'\ ° <v"" '::,0 , ") 0' -. "Ò 0 '\ J. ~ O¡ Ò <0 00) '" " e,,00~ <V" ''0 , è} o· ('-'J) ~r.O ,<0 Ò 0' v v 270.00 AZ'~ <v" ~ CP.;y~~\Cò e,~ ~ 0 O~"- ~Ü) (ç?0 10' '0,0 :0-\ :0-\ ~Ò £>...:.þ èt ;:;-" 0\ <v" <v" ~o 0" \'l- Ò èj:- 0 0\ '\ -\ " <v" 0" ~00) Ò ") '\ '\ <"(t <v" è--Ò . "O¡~O 0' "- cP 0 '\ "Ò C'<1 <0 ~C'<1 â " "v". ~-:.::-O . "O¡ ,,,0 0' '::,v cP Ò' \Cò 10' <-:> ~ Ü) .)v ~ ~0 Entry <[)5 '°0 4~ 13 3/8 Casing ~ End of Curve t>.:. 20 Conductor 66.02 Tyonek Entry Begin Drop 60.83 54.83 50.33 45.83 41.33 36.83 32.33 29.96 End of Drop DLS: 1.50 deg per 100 ft Tyonek Base 3 1/2 Liner Tyonek 65.62 61.07 Entry 56.68 _ 51.00 " 46.50 42.00 '. 37.50 \ 33.00- End of Drop 30.00 \ 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 12800 13600 14400 DLS: 1.50 deg per 100 ft Tyonek Bose 3 1/2 Liner Azimuth 289.88 with reference 0.00 N, 0.00 E from slot #KS1 Vertical Section (feet) -> 7000 6000 5000 ^ I 4000 Z 0 .. - ~ 3000 ..--.. -+, () () - 2000 '-" 1000 0 e e MARATHON Oil Company Kasilof KS#l slot #KSl Exploration Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License KS#l (MB) Version #3 prop5284 Date printed Date created Last revised 21-0ct-2002 28-Aug-2002 21-0ct-2002 Field is centred on n6Q 48 21.994,wlSO 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 - MARATHON Oil Company Kasilof, KS#l Exploration,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 3000.00 3500.00 4000.00 4500.00 5000.00 5500.00 6000.00 6500.00 7000.00 7500.00 8000.00 8500.00 9000.00 9500.00 10000.00 10100.00 10499.99 10500.00 10600.00 10700.00 10800.00 10900.00 0.00 0.00 0.00 0.00 0.00 0.00 295.00 295.00 295.00 295.00 0.00 3.00 6.00 9.00 12.00 295.00 295.00 295.00 295.00 295.00 15.00 18.00 21.00 24.00 27.00 295.00 295.00 295.00 295.00 295.00 30.00 33.00 36.00 39.00 42.00 295.00 295.00 295.00 295.00 295.00 45.00 48.00 51. 00 54.00 57.00 295.00 295.00 295.00 295.00 295.00 60.00 63.00 66.00 66.00 66.00 295.00 295.00 295.00 295.00 295.00 66.00 66.00 66.00 66.00 66.00 295.00 295.00 295.00 295.00 295.00 66.00 66.00 66.00 66.00 66.00 295.00 295.00 295.00 295.00 295.00 66.00 66.00 66.00 66.00 66.00 295.00 295.00 295.00 295.00 295.00 66.00 65.97 65.97 66.00 65.97 295.00 293.00 291.00 289.00 287.00 0.00 100.00 200.00 300.00 400.00 500.00 599.95 699.63 798.77 897.08 994.31 1090.18 1184.43 1276.81 1367.06 1454.93 1540.18 1622.59 1701. 91 1777.95 1850.47 1919.30 1984.24 2045.11 2101.74 2153.99 2201.70 2244.74 2366.76 2570.13 2773.50 2976.87 3180.24 3383.61 3586.97 3790.34 3993.71 4197.08 4400.45 4603.82 4807.18 5010.55 5213.92 5254.59 5417.29 5417.29 5457.99 5498.71 5539.40 5580.10 R E C TAN G U L A R COORDINATES 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 1.11 N 4.42 N 9.94 N 17.64 N 27.50 N 39.50 N 53.61 N 69.78 N 87.97 N 108.14 N 130.22 N 154.15 N 179.87 N 207.32 N 236.41 N 267.06 N 299.19 N 332.72 N 367.54 N 403.57 N 440.71 N 478.85 N- 594.67 N 787.71 N 980.75 N 1173.79 N 1366.83 N 1559.87 N 1752.91 N 1945.96 N 2139.00 N· 2332.04 N 2525.08 N 2718.12 N 2911.16 N 3104.20 N 3297.24 N 3335.85 N - 3490.28 N 3490.28 N 3527.43 N 3561. 64 N 3592.88 N 3621.11 N 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 2.37 W 9.48 W 21.31 W 37.82 W 58.98 W 84.72 W 114.97 W 149.65 W 188.66 W 231.90 W 279.25 W 330.58 W 385.74 W 444.60 W 506.97 W 572.71 W 641.62 W 713.51 W 788.19 W 865.46 W 945.10 W 1026.89 W 1275.28 W 1689.25 W 2103.23 W 2517.21 W 2931.18 W 3345.16 W 3759.14 W 4173.11 W 4587.09 W 5001.07 W 5415.04 W 5829.02 W 6243.00 W 6656.97 W 7070.95 W 7153.75 W 7484.92 W 7484.93 W 7568.37 W 7653.05 W 7738.88 W 7825.75 W Dogleg Deg/100ft . PROPOSAL LISTING Page 1 Your ref KS#l (MB) Version #3 Last revised : 21-0ct-2002 Vert Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 3.00 3.00 0.00 KOP 2.61 10.42 23.42 41.57 3.00 3.00 3.00 3.00 3.00 64.82 93.10 126.35 164.46 207.33 3.00 3.00 3.00 3.00 3.00 254.85 306.89 363.30 423.92 488.60 3.00 3.00 3.00 3.00 3.00 557.15 629.39 705.12 784.13 866.21 3.00 3.00 3.00 0.00 0.00 951.12 1038.64 1128.53 End of Curve 1401.50 1856.45 0.00 0.00 0.00 0.00 0.00 2311.40 2766.35 3221.30 3676.25 4131.20 0.00 0.00 0.00 0.00 0.00 4586.15 5041.11 5496.06 5951.01 6405.96 0.00 0.00 0.00 0.00 0.00 6860.91 7315.86 7770.81 7861.80 Multi-Lateral Junction 8225.75 End of Hold 0.00 1. 83 1. 83 1. 83 1. 83 8225.76 End of 12 1/4" Hole Section 8316.86 8408.13 8499.47 8590.76 All data is in feet unless otherwise stated. Coordinates from slot #KSl and TVD from Est. RKB (lDi.aO Ft above mean sea level). Bottom hole distance is 13212.57 on azimuth 286.42 degrees from wellhead. Total Dogleg for wellpath is 124.92 degrees. vertical section is from wellhead on azimuth 289.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ -- MARATHON Oil Company Kasilof, KS#l Exploration,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 11000.00 11100.00 11200.00 11300.00 11400.00 11500.00 11600.00 11686.02 11700.00 11750.00 11800.00 11900.00 12000.00 12100.00 12200.00 12300.00 12400.00 12500.00 12600.00 12700.00 12800.00 12900.00 13000.00 13100.00 13200.00 13300.00 13400.00 13500.00 13600.00 13653.66 13653.67 13700.00 13800.00 13900.00 14000.00 14100.00 14200.00 14300.00 14400.00 14500.00 14600.00 14700.00 14800.00 14900.00 15000.00 15100.00 15200.00 15300.00 15400.00 15500.00 65.97 66.00 65.97 65.97 66.00 285.00 283.00 281.00 279.00 277.00 65.99 66.00 65.99 65.99 66.00 275.00 273.00 271.28 271.00 270.00 66.00 66.00 66.00 66.00 66.00 270.00 270.00 270.00 270.00 270.00 66.01 66.01 66.01 66.01 66.01 270.00 270.00 270.00 270.00 270.00 66.01 66.01 66.01 66.01 66.02 270.00 270.00 270.00 270.00 270.00 66.02 66.02 66.02 66.02 66.02 270.00 270.00 270.00 270.00 270.00 66.02 65.33 63.83 62.33 60.83 270.00 270.00 270.00 270.00 270.00 59.33 57.83 56.33 54.83 53.33 270.00 270.00 270.00 270.00 270.00 51. 83 50.33 48.83 47.33 45.83 270.00 270.00 270.00 270.00 270.00 44.33 42.83 41.33 39.83 38.33 270.00 270.00 270.00 270.00 270.00 5620.82 5661. 52 5702.22 5742.93 5783.63 5824.32 5865.01 5900.00 5905.69 5926.03 5946.37 5987.04 6027.71 6068.38 6109.04 6149.71 6190.37 6231.03 6271.69 6312.35 6353.01 6393.66 6434.31 6474.96 6515.61 6556.26 6596.91 6637.55 6678 .19 6700.00 6700.01 6719.09 6762.02 6807.30 6854.90 6904.78 6956.92 7011.27 7067.80 7126.47 7187.24 7250.07 7314.91 7381.72 7450.46 7521.08 7593.52 7667.74 7743.70 7821.33 R E C TAN G U L A R COORDINATES 3646.28 N 3668.38 N 3687.37 N 3703.23 N 3715.94 N 3725.49 N 3731.86 N 3734.79 N 3735.05 N 3735.45 N 3735.45 N 3735.45 N 3735.45 N 3735.45 N 3735.45 N 3735.45 N 3735.45 N 3735.45 N 3735.45 N 3735.46 N 3735.46 N 3735.46 N 3735.46 N 3735.46 N 3735.47 N 3735.47 N 3735.47 N 3735.47 N 3735.48 N 3735.48 N 3735.48 N 3735.48 N 3735.48 N 3735.49 N 3735.49 N 3735.49 N 3735.50 N 3735.50 N 3735.50 N 3735.50 N 3735.50 N 3735.50 N 3735.51 N 3735.51 N 3735.51 N 3735.51 N 3735.51 N 3735.51 N 3735.51 N 3735.51 N 7913.54 W 8002.17 W 8091.51 W 8181.45 W 8271.90 W 8362.75 W 8453.87 W 8532.39 W 8545.16 W 8590.83 W 8636.51 W 8727.86 W 8819.22 W 8910.58 W 9001.94 W 9093.29 W 9184.65 W 9276.01 W 9367.37 W 9458.73 W 9550.10 W 9641.46 W - 9732.82 W 9824.19 W 9915.55 W 10006.92 W 10098.29 W 10189.66 W 10281. 02 W 10330.05 W 10330.06 W 10372.28 W 10462.59 W 10551.75 W 10639.69 W 10726.36 W 10811.69 W 10895.62 W 10978.11 W 11059.09 W 11138.50 W 11216.29 W 11292.42 W 11366.82 W 11439.45 W 11510.25 W 11579.18 W 11646.19 W 11711.23 W 11774.26 W Dogleg Deg/100ft 1. 50 /1. 50 1. 50 1. 50 1. 50 e PROPOSAL LISTING Page 2 Your ref KS#l (MB) Version #3 Last revised : 21-0ct-2002 Vert Sect 1. 83 1. 83 1. 83 1. 83 1. 83 8681.88 8772.74 8863.22 8953.19 9042.57 1. 83 1. 83 1. 83 1. 83 1. 83 9131.25 9219.11 9293.95 Beluga Entry 9306.04 9349.13 End of Turn 0.00 0.00 0.00 0.00 0.00 9392.08 9477.99 9563.91 9649.82 9735.73 0.00 0.00 0.00 0.00 0.00 9821. 65 9907.56 9993.48 10079.39 10165.31 0.00 0.00 0.00 0.00 0.00 10251.23 10337.15 10423.07 10508.99 10594.91 0.00 0.00 0.00 0.00 0.00 10680.83 10766.75 10852.68 10938.60 10984.70 KS1 - Tyonek Entry - 10/14/02 10984.72 Begin Drop 11024.42 11109.35 11193.19 11275.90 1. 50 1. 50 1. 50 1. 50 1. 50 11357.40 11437.64 11516.58 11594.15 11670.30 1. 50 1. 50 1. 50 1. 50 1. 50 11744.98 11818.14 11889.73 11959.69 12027.99 1. 50 1. 50 1. 50 1. 50 1. 50 12094.58 12159.40 12222.41 12283.58 12342.86 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 13212.57 on azimuth 286.42 degrees from wellhead. Total Dogleg for wellpath is 124.92 degrees. Vertical section is from wellhead on azimuth 289.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e . MARATHON Oil Company PROPOSAL LISTING Page 3 Kasilof, KS#l Your ref KS#l (MB) Version #3 Exploration, Kenai Peninsula, Alaska Last revised , 21-0ct-2002 Measured Inelin. 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/l00ft Sect 15600.00 36.83 270.00 7900.58 3735.51 N 11835.24 W 1. 50 12400.20 15700.00 35.33 270.00 7981.40 3735.51 N 11894.12 W 1. 50 12455.57 15800.00 33.83 270.00 8063.74 3735.50 N 11950.87 W 1. 50 12508.94 15900.00 32.33 270.00 8147.53 3735.50 N 12005.45 W 1. 50 12560.26 16000.00 30.83 270.00 8232.72 3735.50 N 12057.81 W 1. 50 12609.50 16057.68 29.96 270.00 8282.48 3735.50 N 12086.99 W 1. 50 12636.94 End of Drop 16500.00 29.96 270.00 8665.69 3735.49 N 12307.88 W 0.00 12844.67 17000.00 29.96 270.00 9098.87 3735.48 N 12557.58 W 0.00 13079.49 17232.15 29.96 270.00 9300.00 3735.48 N 12673.52 W 0.00 13188.51 KSl - Base Tyonek - 10/14/02 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 13212.57 on azimuth 286.42 degrees from wellhead. Total Dogleg for wellpath is 124.92 degrees. Vertical section is from wellhead on azimuth 289.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e MARATHON Oil Company Kasilof, KS#l Exploration,Kenai Peninsula, Alaska Comments in wellpath -------------------- -------------------- MD Rectangular Coords. TVD Comment ----------------------------------------------------------------------------------------------------------- e PROPOSAL LISTING Page 4 Your ref KS#l (MB) Version #3 Last revised : 21-0ct-2QQ2 500.00 500.00 0.00 N 0.00 E KOP 2700.00 2244.74 478.85 N 1026.89 W End of Curve 10100.00 5254.59 3335.85 N 7153.75 W Multi-Lateral Junction 10499.99 5417.29 3490.28 N 7484.92 W End of Hold 10500.00 5417.29 3490.28 N 7484.93 W End of 12 1/4 .. Hole Section 11686.02 5900.00 3734.79 N 8532.39 W Beluga Entry 11750.00 5926.03 3735.45 N 8590.83 W End of Turn 13653.66 6700.00 3735.48 N 10330.05 W KS1 - Tyonek Entry - 10/14/02 13653.67 6700.01 3735.48 N 10330.06 W Begin Drop 16057.68 8282.48 3735.50 N 12086.99 W End of Drop 17232.15 9300.00 3735.48 N 12673.52 W KS1 - Base Tyonek - 10/14/02 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OON O.OOE D.OOE O.OOE O.OOE 10500.00 17232.15 2700.00 150.00 5417.29 9300.00 2244.74 150.00 3490.28N 3735.48N 478.85N O.OON 7 Casing 3 1/2 Liner 13 3/8 Casing 20 Conductor 7484.93W 12673.52W 1026.89W O.OOE Target name T.V.D. Targets associated with this wellpath Revised ------------------------------------- ------------------------------------- Geographic Location Rectangular Coordinates KSl - Buluga Entry - KS1 - Tyonek Entry - KSl - Base Tyonek - 5900.00 6700.00 9300.00 ----------------------------------------------------------------------------------------------------------- 3734.84N 3735.48N 3735.48N 8533.06W 10330.05W 12673.52W 14-0ct-2002 14-0ct-2002 14-0ct-2002 e e SURFACE USE PLAN FOR KASILOF SOUTH #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 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 Permit-to-Drill\SURFUSE .doc Surface Use Plan Kasilof South #1 Well Page 2 e 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 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 currently exist; that the statements made in this plan are, to the best of my M:\ Wells\Kasilof\KS#1 Permit-to-Drill\SU RFUSE.doc Surface Use Plan Kasilof South #1 Well Page 3 e e 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. :::~ ::::ber 13. 2?J__Z¿ Marathon 011 Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6332 Senior Drillinq Enqineer M:\ Wells\Kasilof\KS#1 Permit-to-DriII\SU RFUSE.doc e 1203/4" 3M Diverter 1--. I Diverter Spool Marathon Oil Well Kasilof South #1 Anticipated Diverter e Flow line ~ 116" Automatic Hydraulic Valve ¡ X \ 116" Diverter Line e Marathon Oil Well Kasilof South #1 Anticipated BOP Stack IFlow 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 ~~ []I0]][]I0]] ŒTID IChoke 1135/8"5MCross I ~ 13 5/8" 5M Single Ram Preventer ~ I Pipe Ram I e 3 1/8" 5M Hydraulically Operated Valve Þf [[[@]1][]I0]] t 3 1/8" 5M Manually Operated Valve e Marathon Oil Well Kasilof South #1 Anticipated Choke Manifold e I To Gas Buster I ~rn0rrnOUnørmy ITO Blooey Line I Bleed off Line to Shakers t 13" 5M Valves i 2 9/16" 10M Swaco Hydraulically Operated Choke 3 1/8" 5M Manually Adjustable Choke ¡From BOP Stack I Well MI Gel / Gelex / Soda Ash I Caustic Soda / MI Bar / gent / Polypac UL / Desco CF / Lubetex Shale Shakers / Desander / Desilter / Centrifuge Hole cleaning, bit balling, difficulty building angle, buildup .. Treat drill water with Soda Ash to reduce hardness. .. Build spud mud using the formula listed on the next page. .. Maintain a high funnel viscosity throughout the entire interval. Reduce gel strengths>onlyon the last circulation prior to running surface casing. .. Reduce fluid loss to > 10 cc' s API with additions of Polypac Supreme UL prior to running sur- face casing. Ie Add 2 - 5 PPB ofM-I Seal Fine to mud system if seepage losses becomes a problem.. .. Add Lubetex as needed to aid in hole building and directional control. . Maintain sufficient hole cleaning properties of the mud. If hole cleaning becomes pump high viscosity sweeps and increase the viscosity of the mud with GellGelexadditions. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Ie, Wen KasilofSoutb#l Fluid Loss Control 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 Flo-Vis, Polypac UL, KCI, Barite, Lubetex, Ventrol401, Asphasol D SafeCarb F & M / Conqor 404 / Drilling Detergent, Lubetex -~~-----------------------~~."-^.^._~,._-~.~-~'~'~ ----~~~~_._-~ Shale Shakers I Desander I Desilter I Centrifuge Coal sloughing, drill solids buildup, seepage losses, bit balling, high torque & drag, differential sticking · Isolate one pit with spud mud to drill out cement and perform a leakoff test. · Clean other rig pits and build new FloPro fluid using the formula listed on the next page. · Increase additions ofPolypac UL to reduce API fluid to 8 cc's below 7500'. · Maintain Conqor 404 concentration at 2000 ppm. · Increase Ventrol401 and Asphasol D concentrations ifrunning 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 SafeCarb Fine & Medium. · Keep a supply of Pipe Lax on location in 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 Well Kasilof South #1 6% KCl FloPro System Estimated Proosity - 5 - 40 mDarcy Flo-Vis, DualFlo, KCl, Barite, Ventro1401, SafeCarb F & M, Conqor 404, Drilling Detergent, Shale Shakers / Desilter / Centrifuge Coal sloughing, drill solids buildup, seepage losses, bit balling, torque & drag, differential sticking · Isolate one pit with completion fluid to drill out cement. Add ppb Biozan to aid c1eaout. Do not displace the well bore to new fluid until after a successfulleakoff test. .. Clean other rig pits and build new FloPro fluid using the formula listed on the next page. III Maintain 2 ppb concentrations of both 401 and Asphasol III Maintain Conqor 404 concentration at +/- 2000 ppm. · Increase Ventro140l and Asphasol D concentrations if running coal becomes a problem. III Centrifuge surface system during trips to aid in removing drill solids. · Alternate additions of Greencìde 25G and SafeScav NA. .. Maintain a tight wallcake and keep mud weight as low as possible to reduce the differential sticking. Maintain the 3 to 1 ratio of SafeCarb Fine & Medium. · Keep a supply of Pipe Lax on location in order to readily spot a pill around M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Wen KasÏlofSouth #1 M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Kasilof South #1 & Kasilof South #1L1 Site Map TYONEK T2 0.1. :::: 250' MARATHON OIL COMPANY ALASKA PRODUCTION REGION KASILOF Kasilof South #1 and #1 L COOK INLET, ALASKA w.1.: 100% August 2002 o:\freehand\exploitation\ka$permitloc03.fh9 Size - 3-1/2" x 3-1 Size - 9-5/S" x 3-1/2" x 3-1/2" Size - 9-5/S" x 3-1/2" x 3-1/2" Length - 40ft Size - 6" 7" Size - 17 -1/2" x 200ft Depth -10,000 - 10,200ft Size - 7" x 3-1/2 Size - 3-1/2" Size - 3-1/2" Marathon - Kasilof Pad I Air Photo Overlay - e ~ 0 d - :)~~ Subject: Marathon - KasilofPad / Air Photo Overlay From: "Underwood Jr, Charles A." <CAUnderwood@MarathonOil.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 I 6/24/200410:37 AM MCG" Ø:;'·:;'ØØ6 Ø:;':;'ØØ6 ·C.ORE.DUJ::::. PROJECT MA~T¡"¡ON OIL COMPANY KASILOF No.1 P.O. 80x 468 SOLDOTNA. AK 99669 LOCATION $;CTION '2ß, Tou.NSI-II¡:;> ~ NORTH ~ 121.1.J';ST, SEWA~ MEf\ii:IDIAN, AK, I<ENAI PENINSU!..A eo~ REVISION CONSULTING GROUP PURPOSE K,ASI!..OF No.1 EXPANSION OF EXISTI~ GreAVE!.. PAD DATE TESTING APPLICANTS MAreAT~ON 011.. COMPANY p.o. eox 1'$h1E>& ANC~~, AK SS&IS·E>IE>& TEL 907.283.4218 FAX 907.2133.3265 Re: Kasilof South #1 (Mother Bore) e e Subject: Re: Kasilof South #1 (Mother Bore) Date: Wed, 26 Feb 200315:53:31 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Steve Lambe <sslambe@marathonoil.com> Hi Steve, r think you called on this note from down at the rig. Could you please get a note back to me on these points. Most important is #1. You need to make an application for an exception to the diverter regs. With those two old wells in the area, you likely have some reasonable drilling history to refer to in support of your plan. Thanks. Tom Maunder Tom Maunder wrote: > Steve, > I have looked at the PTD and have a couple of questions. > 1-- You plan 17-1/2" hole with a 16" diverter line. Doing that will take > a request for exception to the diverter requirements. Are there any > other wells nearby to look at for drilling history?? > 2-- Your junction is the weak point as far as burst is concerned. Does > this only come into play if you were to have mostly gas to surface?? > How does this effect well control?? Best well control is don't have t > get into it. > 3-- You may have said on the lateral that ram sizes are still to be > decided. > Thanks. > Tom \N\~~~ \-~ <;;,\- 'N~~..\~ ~ ~~~ ~M..b~ \' ~ +~i~\~~~~~<t4 \ (Q ,\ ~~ \ ~ 5/ t:z .. Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission \)r, 'Z, ,Q .\'-* ~~ ,,^,~-\-\--a~~\\<; (J ~4ç \ \~+. r ~\Y\.. ~c;\ \-\ If'" ~ 0, ~ Dr ~ \" ~\\:) \V\ -\-~ <L "S '\ ~« ~ 0 '" þa't~+- L Q \..(0 0 ""'->-'-\ t\ ~ -\.-\V <"Q 'I 0...:: ...,;~~",~ \N ì \":'->-.) , WNë"-.1: n? ~Q'¡...:J<r \k ì~~\'i S~0J~ \JQ' '(Î ~ ~':>~ \--\C,:,r---,- ~ \-AÙ~~ -\-~~Cé '0 h~ 1 of 1 2/26/2003 3:54 PM RE: KasilofSouth #lLl e e Subject: RE: KasilofSouth #lLl From: "Lambe, Steven S." <SSLambe@MarathonOi1.com> Date: Thu, 6 Peb 2003 10:52:24 -0900 To: "Tom Maunder" <tom_maunder@admin.state.ak.us> ~70d-dÇC, 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.us] Sent: Tuesday, February 04, 2003 4:40 PM To: Lambe, Steven S. Subject: Kasilof South #lL1 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--In 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(?) . Thanks Tom 1 of I 6/24/2004 10:37 AM .-, 2-02-- 2 S-~ e e 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 psilft (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 mud log 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 . 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 of the 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 Hvdrocarbon 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 Check No Check Date Bank Bank No Marathon Oil Company P. O. Box 3128 Houston, TX 77253 'r6åtul~~~ir~IM~~LE DEPARTMENT Jackie Abert Phone: Hndlg 1055458 12/3012002 NCBAS 7780 jMW¥~Jm~H}@~iMwWÞÄ@mMt~~ L10000 12123/2002 1900049514 Fil ing OTAL: 713-296-4336 9i~#Þ'¡:#·)W¡~1~M~~Affi~¥¡¡> · 100.0 100.0 AL RECEIVED DEC 30 2002 A1as1<a Oil & Gas Gons. Commission _.. Anchorage (FOLD ON PERFORATION BELOW AND DETACH CHECK STUB BEFORE DEPOSITING) 111000 ~O 5 5 L, 58111 1:0 L, ~ 20 38 ~ 51: 0~8 3 L,8 L,III e . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 4~rlof St;tdi / PTD# 20 2- - :zs-þ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well_, Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function· of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(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 full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater· than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07/10/02 C\jody\templates COMPANY Marathon WELL NAME Kasilof South 1 PROGRAM Exploratory (EXP) -1L Development (DEV)_ Redrill_ Service (SER)_ Well bore seg _ Annular disposal para req FIELD & POOL 000000 - Exploratory Initial ClasslType EXP 11-GAS GEOLAREA 820 UNIT No. 011110 ON/OFF SHORE On ADMINISTRATION 1. Permit fee attached ...... ... ... ... ............... ......... ... .................. ...... ...... ... ... ......... ... ...... Yes 2. Lease number appropriate ... ... ." ... ... ...... ... ... ... ... ... ... ... ... ... ... ... '.' ... ... ... ... .'. ... ... ... ... ... Yes Surface location and top productive interval in ADL 384529. TD located in ADL 384534. 3. Unique well name and number ................................................................................. Yes 4. Well located in a defined pool ...... ................................................... ... ............... ... ..... No Exploratorv well 5. Well located proper distance from drilling unit boundary ........................ ......................... Yes Well is located wtthin the Kasilof Untt, approved bv DNR-DOG on October 25, 2002. 6. Well located proper distance from other wells ................................. ... ..................... ..... Yes All older exploratory wells in area are plugged and abandoned. APPR DATE 7. Sufficient acreage available in drilling unit ............... .................. ......... ......... ... '" ...... .... Yes 8. If deviated, is well bore plat included ............ ...... ........................ ........................ ... ...... Yes SFD 6/23/2003 9. Operator only affected party ... ..' ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .... Yes 10. Operator has appropriate bond in force ... ............... ... ............... ......... ...... ...... ... ......... Yes 11. Permit can be issued without conservation order .............................. ...... .................. ... Yes 12. Permit can be issued without administrative approval..................... ...... ........................ Yes 13. Can permit be approved before 15-day wait ...... ... ........................... ........................ ... Yes (For Service Well Only) 14. Well located within area and strata authorized by Injection Order # Yes (For Service Well Only) 15. All wells within 1/4 mile area of review identified ... ...... ...... .............................. ...... ....... Yes (For Service Well Only) 16. Pre-produced injector: duration of pre-production less than 3 months............................. Yes 217103: Per Nina Brudie, DGC: Marathon has not yet submitted a Coastal Project Questionnaire or held a pre-application meeting. 3/5/03: Pre-app 17. ACMP Finding of Consistency has been issued for this project ............... ... .................. ... NA meeting was held. 3/25/03: Nina Brudie: DNR single agency, 3D-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 ENGINEERING 18. Conductor string provided ... ... ... ... ...... ... .,. ... ... ... ... .., ... ... ... ... ... ... ... ... ... ... ... ... ...... ..... Yes 20" @ 120'. 19. Surface casing protects all known USDWs .................. .............................. ... ............. Yes Surface casing shoe will be located approximately 450' offshore beneath the Cook Inlet. Surface casing will be set at 2700' MD (2245' TVD) and cemented to surface. Anv potential USDWs will be protected bv casino cemented to surface. SFD 20. CMT vol adequate to circulate on conductor & surf csg ................................. ............... Yes 21. CMT vol adequate to tie-in long string to surf csg ....................................... ................. Yes 22. CMT will cover all known productive horizons ... ... ........................ ............ ................... Yes 23. Casing designs adequate for C, T, B & permafrost ........................ ......... ..................... Yes 24. Adequate tankage or reserve pit ......... ...... ............................................. ... ............... Yes Nabors 273. 25. If a re-drill, has a 10-403 for abandonment been approved ......... ............ ............... ........ NA Not Applicable 26. Adequate wellbore separation proposed ......... .................. ..................... ... .'. .............. Yes 27. If diverter required, does it meet regulations ........................ ...... ......... ...... .., ............... Yes 28. Drilling fluid program schematic & equip list adequate ........................... ...... ................. Yes Max MW 9.8 peg. APPR DATE 29. BOPEs, do they meet regulation ...... ... ............ ...... ........................ ... ..................... ... Yes WGA 3/26/2003 30. BOPE press rating appropriate; test to .......................3500 psig ........................... Yes MSP 3089 psi. 31. Choke manifold complies w/API RP-53 (May 84) ................................. ....................... Yes 32. Work will occur without operation shutdown ............ ... ............... ..................... ... ... ...... Yes 33. Is presence of H2S gas probable ...... .................. ..................... ... .'. ...... ............... ..... No (For Service Well Only) 34. Mechanical condition of wells within AOR verified ............... ........................... .............. NA Not Applicable GEOLOGY 35. Permit can be issued w/o hydrogen sulfide measures ........................... ... ..................... Yes None noted in offset exploratory wells. Rig will be equipped wtth sensors and alarms. SFD 36. Data presented on potential overpressure zones .......................................... ............... Yes DSTs in nearby Kasilof Untt 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. 37. Seismic analysis of shallow gas zones .................. ........................ ... .'. ...................... Yes David Brimberry, Marathon: no shallow gas, abnormal pressure, or other drilling hazards are anticipated (see also "MARATHON KASILOF APPR DATE EXPLORATON UNIT - GEOLOGIC DESCRIPTION OF HYDROCARBON AND ABNORMAL PRESSURE OCCURRENCE, JUNE 2003" in this well file). SFD 6/23/2003 38. Seabed condition survey (if off-shore) ............... ... ... .................. ............ .................... NA Onshore surface location. 39. Contact name/phone for weekly progress reports [exploratory only] .............................. Yes Steven Lambe, Drilling Engineer, 564-6332 GEOLOGY: ENGINEERING: RES. ENGINEERING: COM~IS~ION>~ ..' 0' Commentsllnstructions J ~ 3-'~ ~ f Well will be mud logged below surface csg. Dry cuttings samples not required. Immediately adjacent wells Kasilof State 1 and 2 have cuttings RPC: TEM: JDH: samples from 1500-16121' and 2050-6686' MD. respectively. Nearby offset wells Kasilof Untt 1 and Cape Kasilof 1 have cuttings samples from 630- DTS: G b) ¿If/03 5500' and 510-14015' MD, respectively. SFD SFD:SFD WGA: X MJW: ~-"" ~- . £":6_ ~... " ".- Y ......V e· e