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204-255
V 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~,®~ - ~~~ Well History File Identifier Organizing (done> RESCAN ~olor Items: ~Greyscale Items: ^ Poor Quality Originals: ,ws,aea uiumiuiiuuu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: a.sG~~eeded iuuiuiniiuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: b !s/ Project Proofing II I II II II II III I I III BY: Maria Date: ~ f ~,3 / ~ ~ /s/ ---.~ Scanning Preparation ~_ x 30 = ~o~~ + ~~ =TOTAL PAGES ~~~ (Count does not include cover sheet) BY: Maria Date: ~ /s/ Production Scanning III (VIII VIII II III Stage 1 Page Count from Scanned File: ~ -1 (count does inc~ude cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: _ Maria Date: `' J~3~ ~~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO f BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II (II'I II I II II I I III ReScanned II I II'l II I I III (IIII BY: Maria Date: !s/ Comments about this file: Quality Checked III II'III III II'I III 10/6/2005 Well History File Cover Page.doc • M Marathon MARATHON Oil Company October 27, 2008 ~r. ~..~` .~ ~,~~5 . ~ is _, Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Ninilchik Gas Field Well: Grassim Oskolkoff #3 Dear Mr. Maunder: ~a~ " ~~~ Attached for your records is the Report of Sundry Well Operations, 10-404, for GO-3 well. This report covers the work performed to adjust the velocity string setting depth covered under sundry approval #308-322. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~~~ ~~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File Well Schematic KJS KDW ~~ /D o~-+O~' STATE OF ALASKA ,~~ `IU~ ALA~OIL AND GAS CONSERVATION COMfV~ON ' ~~ REPORT OF SUNDRY WELL OPERA~OI~S" `~`'~"' ,, 1. Operations Abandon Repair Well Plug Perforations Teti ° `te Other ~ Install Velocity Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ; ^ Waiver^ ' T'rrne~ztension ^ String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^~ Exploratory^ 204-255 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20548-00-00 7. KB Elevation (ft): 9. Well Name and Number: 187' (21' AGL) ' Grassim Oskolkoff #3 ' 8. Property Designation: 10. Field/Pool(s): ADL 384305 /ADL 389180 Ninilchik Unit / Tyonek Pool 11. Present Well Condition Summary: Total Depth measured 13,711' ~ feet Plugs (measured) NA true vertical 8,147' ~ feet Junk (measured) NA Effective Depth measured 13,633' ~ feet true vertical 8,019' ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 99' 99' 3,060 psi 1,500 psi Surface 2,486' 9-5/8" 2,507' 1,772' 5,750 psi 3,090 psi Intermediate 7,299' 7" 7,320' 3,424' 7,240 psi 5,410 psi Production Liner 6,701' 4-1/2" 13,750' 8,127' 8,430 psi 7,500 psi Perforation depth: Measured depth: 10,612' -12,854' Gross True Vertical depth: 5,244' - 7,29 7' Gross 4-1 /2" L-80 7,049' Tubing: (size, grade, and measured depth) 1-3/4" QT-900 12,485' Packers and SSSV (type and measured depth) Baker 4-1/2" 2.XP 7,049' 12. Stimulation or cement squeeze summary: Intervals treated (measured): The 1-3/4" velocity string was raised 300'. The new velocity string setting depth is 12,485' MD. Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,050 1 0 322 Subsequent to operation: 0 1,250 1 0 281 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-322 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician 4 .. r Signature ,, Phone (907) 283-1371 Date October 27, 2008 r-~ r ,,., , t ~ ~S Form 10-404 Revised 04/2006 E 4 ~ ~~°~-? ~~-~ '` - ~~ ~ ~ ZQ~~ Submit Original Only ~ ~~~ . ~ ~1~ Marathon ~ Operations Summary Report ~ M„~ TMs, ; 0i1 ~,,, Well Name: GRASSIM OSKOLKOFF Re ort Date: 9272008 Job Cate o R&M MAINTENANCE 24 Hr Summary Spot in tank, gas buster, and CT equipment. Stump test BOP. Well flowing up TBG ! CT annulus at 1 MM, 325 psi Start Time End Time Dur hrs 0 5 Code Activi Code Ops Status Trouble Code Comment 09:00 10:00 1.00 SAFETY MTG AF Hold prejob safety meeting. Discuss BJ JSA and ASRC JSA. Assign tasks. 10:00 15:00 5.00 RURD COIL AF Spot and RU tank, gas buster, and CT equipment. 15:OD 16:00 1.00 TEST BOPE AF Perform full initial BOP test 250/4500 si. ood test. 16:00 17:00 1.00 SECURE WELL AF Secure well and leave location. Re ort Date: 9782008 Job Cate o R&M MAINTENANCE 24 Hr Summary Pull and cut 300' of v-string. Hang off. Hanger did not test. Well flowing up TBG / CT annulus at 1 MM, 325 psi Start Timz End Time Dur hrs O s Code Rctivi Code Ops Status Trouble Code Comment 08:~ 09:00 1,00 SAFETY MTG AF Hold prejob safety meeting. Discuss BJ JSA and ASRC JSA. Assign tasks. 09:00 10:30 1.50 RURD COIL AF RU BOP and flowback lines. 10:30 10:45 0.25 TEST EQIP AF Shell test and test flowback lines. 10:45 12:45 2.00 RUNPUL COIL AF PU injector and stab on well. 12:45 13:15 0.50 RURD COIL AF Latch hanger and PU v-string above BOP. Set in slips and lock slips. 13:15 16:30 3.25 RURD COIL AF Cut off hanger asst'. Dress both sides of CT for double dimple-on. Make up dimple-on. 16:30 19:00 2.50 RURD COIL AF POH 300' of 1.75 CT. Cut i e and dress for han er ass .Reconnect hanger asst'. LD 300' of CT. Dress CT for running tools. 19:00 19:30 0.50 TEST EQIP AF Land han er and lock down. Tagged 2 times in XO above swab valve. Could not pressure test hanger. 19:30 20:30 1.00 SECURE WELL AF Secure well for night. Close permit and sign out. leave location Daily Operations Re ort Date: 9292008 Job Cate o R&M MAINTENANCE 24 Hr Summary Pulled and redressed v-string hanger. Well flowing up TBG ! CT annulus at 1 MM, 325 psi Sta rt Tirr~z End Time Dur hrs 0 sCode Aotivi Code Ops Status Trouble Code Comment 09:00 10:00 1.00 SAFETY MTG AF Hold prejob safety meeting. Discuss BJ JSA and ASRC JSA. Assign tasks. 10:D0 10:45 0.75 RURD COIL AF RU BHA and stab on well. 10:45 11:30 0.75 RUNPUL COIL AF Latch and ull v-strin into lubricator. Close slips and bleed down. 11:30 13:00 1.50 RURD COIL AF Pump to 1000 psi with N2 and release G5 from hanger. Redress hanger. Straighten CT with hydraulic straightener. Reinstall hanger. 13:00 13:30 0.50 RURD OTHR AF Land han er. No test. Pumping into tesat matches pressure above hanger at 0 psi and 800 psi._Hanger is sealed at lower seal and isolated from TBG / CT annulus. 13:30 16:00 2.50 RURD COIL AF RD all BJ equipment and release BJ. 16:00 16:30 0.50 SAFETY MTG AF Hold PJSM with Pollard crew. Discuss Pollard JSA and assign duties. 16:30 17:30 1.00 RURD SLIK AF Spot and RU slickline unit 17:30 19:30 2.00 RUNPUL SLIK AF .Saw fluid level at 10 500'. 19:3D 20:15 0.75 RURD SLIK AF Jumped upper pulley at 12,5D0'. Rigged up second pulley on crane to lift wire. Set down tools at 12,556' WLMD and released all tension from wire. Replaced wire onto upper pulley. 20:15 20:45 0.50 RUNPUL SLIK AF Attempted to pull plug with 8DD psi. Reduced pressure to 400 psi surface and ulled lug. POH. Recovered plug. 20:45 22:00 1.25 RURD SLIK AF RD and release slickline. Blew down N2 to buster and made water to tank. SI well and had 500 psi in 30 min. www.peloton.com Report Printed: 10272008 Grassim Oskolkoff #3 tertv Des: ADL 384305 /ADL 389180 levtion: 187' (21' AGL / KB) > #: DD.04.10981.CAP.CMP.02 229,103.63 2,255,186.000 ude: 60° 09' 53.0430" N ita ude: 151 ° 29' 14.3564" W ~: 1 /22/2005 10:30 hrs 2/25/2005 22:00 hrs released: hrs KOP @ 250' MD(ND Build 4.0 deg/100' from 250-2000' Hold 70 deg from 2000.8090' MD Drop 1.5 deg/100' to 11470' MD Hold 23 deg from 17470' to TD at ' MD Azimuth: 255 deg. Ninilchik Unit 3,221' FSL, 2,914' FEL Sec. 23, T1 N, R13W, S.M. J ~ ng amng - v.r, .~ z.ns, L-au, cunress nnoa ng String - 4.5", 12.6#, L-80, Hydril 533 r Chemical Injection Nipple @ 2412' MD (Top) 5.930" OD/3.858" ID 8430 psi bursU7500 psi collapse Liner Packer with 15' Tieback Extension @ 7049' MD (Top) Lock Liner Hanger @ 7074' MD (Top) er Joints @ 9622-9673' MD (Two 19-20' long) er Joints @ 11,691-11,730' MD (Two 19-20' long) ing Collar @ 13,652' MD (Top) Collar @ 13,685' MD (Top) Shoe @ 13,750' MD (Bottom) 2-5/8" Cores: Cement Top at 1.9794'-9875' KB (Cut 81' Recvd 66.9') @ -10,000' MD 2. 12,212'-12,301 KB (Cut 89' Recvd 70.15 Expro Radial Bond 1314" OD Coiled Tubing Velocity String: @ 12,485' MD BHA includes 2.50" OD x 1.50" ID CT grapple connector, 2.50" OD x 1.50" ID x 10' long box x box straight bar, 1.91" OD x 1.25" PXN (1.135" no-go) profile nipple, 8 3.50" OD x 2.50" OD (1.50" ID bottom) wirline reentry guide. Tagged PBTD at 13,633' KB with Expro CBL/GR. Cleaned out to 13,570' MD with BJ CT (w/ 3.80" OD centralizer) Formation Tops: Formation Depth (MD) Depth (NDl Beluga Tyonek TD ~ C ~ C ~ C ~ C J C ~ C ~ C ~ c J C TD: 13,771' MD 8,147' ND Intermediate Casing 7" L-80 26 ppf BTC Top Bottom MD 0' 7,320' TVD 0' 3,424' 8-1 /2" hole cmt w/ 305 sks (134.4 bbls) 12.Sppg Lead & 167 sks (34.7 bbls) 15.8 ppg Tail. Plug did not bump, no cmt to surface, floats held. Liner 4.1/2" L-80 12.75 ppf Hydril 533 Top Bottom MD 7,049' 13,750' ND 3,331' 8,127' 6.1/8" hole cmt w1664 sks 12.7 ppg Tail (NO spacer or cmt to surface) Lost partial circulation after pumping 230 bbls cmt Pollard Temp Log indicated TOC @ 70,350' MD before Liner Top Sqz Squeezed Liner Top w1500 sks 12.7 ppg cmt (88 bbl cmt below 12.7ppg) • M MARATNOM Conductor 20" K-55 133 ppf PE Top Bottom MD 0' 99' ND o' ss' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 2,507' ND 0' 1,772' 12-1 /4" hole cmt wl t 519 sks (232bb1s) 12ppg cmt w/ 27 bbls cmt to surface MD 0,612'-10,632, 20 ft 0,866'-10,886, 20 ft 0,866'-10,886, 20 ft 1,826'-11,840, 14ft 1,830'-11,840, 10 ft 1,956'-11,972, 16 ft 1,956'-11,973, 17 ft 2,223'-12,238, 15 ft 2,242'-12,267, 25 ft 2,354'-12,398, 44 ft 2,564'-12,586, 22 ft 2,564'-12,587, 23 ft 2,606'-12,626, 20 ft 2,607'-12,636' 29 ft 2,626'-12,668, 42 ft 2,636'- 12,665' 29 ft 2,840'-12,854' 14 ft ND 5,244'- 5,261' 5,467'- 5,484' 5,467'- 5,484' 6,345'- 6,358' 6,349'- 6,358' 6,465'- 6,479' 6,465'- 6,480' 6,712'- 6,726' 6,730'- 6,753' 6,835'- 6,875' 7,029'- 7,049' 7,029'- 7,050' 7,068'- 7,086' 7,069'- 7,095' 7,086'- 7,125' 7,095'- 7,122' 7,284'- 7,297' Gun Date Owen 3.375" 6 SPF 9/1 312 0 0 5 Owen 3.375" 6 SPF 9/13/2005 Owen 3.375" 6 SPF 10/29/2007 Owen 3.375" 6 SPF 10/29/2007 Owen 3.375" 6 SPF 9/08/2005 Owen 3.375" 6 SPF 10/29/2007 Owen 3.375" 6 SPF 9/08/2005 Owen 3.375" 6 SPF 9/08/2005 Owen 3.375" 6 SPF 9/07/2005 Owen 3.375" 6 SPF 9/06807/2005 Owen 3.375" 6 SPF 9/02/2005 Owen 3.375" 6 SPF 10/28/2007 Owen 3.375" 6 SPF 8/31/2005 Owen 3.375" 6 SPF 10/28/2007 Owen 3.375" 6 SPF 9/06807/2005 Owen 3.375" 6 SPF 10/28/2007 Owen 3.375" 6 SPF 8/31/2005 Well Name 8 Number: Grassim Oskolkoff #3 Lease: Ninilchik Unit County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations (MD): 10,612' - 12,854' (ND): 5,244' - 7,297' An le/Perfs: 25° An le KOP and Depth: KOP (ND Date Completed: Completion Fluid: RKB: 21' Revised by: Kevin Skiba Last Revision Date: 10/27/08 • - SARAH PALIN, GOVERNOR ~ Al`D ~ S ~58~ ® 333 W. 7th AVENUE, SUITE 100 v r T ~ ~ T 7~T C®1~TSFRQA~Ol` 1.®~II~75I®l~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ken Walsh Senior Production Engineer Marathon Oil Company j ,~ PO Box 1949 ~~°°'~~~~ `'' ~'~ ~ `~ Z(l~~ Kenai AK 99611-1949 - c~`~' ao~+ Re: Ninilchik Unit, Tyonek undefined Gas Pool, Grassim Oskolkoff #3 Sundry Number: 308-322 Dear Mr. Walsh Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Corrunission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster Commissioner DATED this ~? day of September, 2008 Encl. • M Marathon MARATHON Oil Company September 8, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Well: Ninilchik Unit Grassim Oskolkoff #3 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 s~~ ~ o zoos Alaska C`ll ~ C~ ~ ~c~~. Ocmr~ission fa~;:?v'= ale ~o,~ - Marathon installed a velocity string in GO-3 in November of 2007. Efforts to produce up this tubing string have been unsuccessful. There are two probable conditions that appear to be preventing flow. The tubing string appears to be set below its optimal operating depth and the tubing hanger appears to be leaking. Marathon proposes to rectify both conditions by replacing the tubing hanger while raising the velocity string 300'. Attached for your records is the Application for Sundry Approvals 10-403 requesting permission to perform this work. September 15, 2008 is the estimated date for commencing this operation. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~~:.~.~ sue. Kevin J. Skiba Engineering Technician Enclosures: 10-403 Application for Sundry Approvals Operational Procedure Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File KJS KDW .t~~ STATE OF ALASKA 9/~~~, ~' ~AL~ OIL AND GAS CONSERVATION COM~ION APPLICATION fOR SUNDRY APPROVALS~~ I << 20 AAC 25.280 q~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Pull CT Tail Uphole Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ ~ Exploratory ^ 204-255 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20548-00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Grassim Oskolkoff #3 9. Property Designation: ~ 10. KB Elevation (ft): 11. Field/Pool(s): ADL 384305 /ADL 389180 21' Ninilchik Unit / Tyonek Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,711' 8,147 ~ 13,633' - 8,019' ~ NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 99' 20" 99' 99' 3,060 psi 1,500 psi Surface 2,507' 9-5/8" 2,507' .1,772' 5,750 psi 3,090 psi Surface 7,320' 7" 7,320' 3,424' 7,240 psi 5,410 psi Intermediate Production 6,701' 4-1/2" 13,750' 8,127' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,612' - 12,854' Gross 5,244' - 7,297' Gross 1-3/4" QT-900 12,785' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 4-1/2" ZXP 7,049' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development^ ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 9/15/2008 Oil ^ Gas Q - Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Senior Production Engineer Signature ~ ~ Phone (907) 283-1311 Date 9/8/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~. Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~©O ~6i ` ~~ ~~~ ~ °~ST ~-~ e \ O~l~l~~~ Subsequent Form Required: "'1.0 ~ ®~~ ~~~ ~ ~oo~ APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: ~_ Z. __ Form 10-40 Revised 06/20 ~ ~ ~ ~ ~F ~ ~ ~ Submit in Duplicate • M MARATHON • MARATHON OIL COMPANY ALASKA REGION Grassim Oskolkoff GO- 3 Raise CT String Procedure (8/25/2008) WBS # Requested Notes: This procedure covers work to raise the 1.75" OD coil tubing velocity string which is currently installed @ 12,785' to 12,485'. Current hanger appears to be leaking. Previous efforts to flow this well up the velocity string @ 12,785' have proven unsuccessful. Procedure: Pulling 1-3/4" CT 1. MIRU Pollard Wire line Services. Hold PJSM and obtain Safe Work Permit. Install wire line valve with pump-in sub to Otis tree cap connection. Pressure test wire line valve and lubricator with pump to 2500 psig. 2. RIH tap top of profile with 1.25" GR. Verify the tubing is open. RIH to profile @12,785' with 1.25" brush. 3. RIH w/ 1-1/4" tool string with 1.18" BST plug. Set plug in profile @ 12,785'CTM. RD Pollard.. 4. MIRU MOC flow-back eauipment. Including open-top flow-back tank, choke skid, gas buster, and flow back iron. MIRU 500 bbls. Rain-for-Rent fluid supply tank. Lay liner and berm area around tank and wellhead. Load supply tank with 6% KCL. Deliver diesel-fuel man-lift and two light towers. Lock out electrical connections and remove well house. 5. MIRU BJ 13/." coil tubing and nitrogen units. Conduct pre job safety meeting and obtain Safe Work Permit. Spot CTU with 1~/." CT work reel, and pumping equipment. Nipple up and test CT BOP's and flowback iron to 250/4500 psi with 6% KCL water. Stab CT work string in injector. Make up CT connector. Pull test CT connector to 18,000 lbs. B/D v-string annulus, relieving any trapped pressure. 3 `ZCi -1 ~1 ~~ o r '1.x,3 --` a~ *** Notify the AOGCC James Regg Ca) 907-27r~-7,6'2124 or longer) prior to testing the BOP's 6. Makes tool string with 3" Weatherford GS to latch into the velocity string hanger. Pull test CT mandrel connection/GS assembly to CT string weight plus 5,000 lbs. Slack off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 7. Back off lock-down screws on the hanger. PU coil head above BOP's, set tubing rams. B/D velocity string. PU injector by walking up coil. Install 1-3/4" polish rod clamp and C-plate from top of BOP. Cut coil above and below the GS. MU Roll-on coil connector. Reel 300' of coil tubing onto work string. 8. Cut coil tubing. PUH to span WHA for final landing depth of +/- 12,485'. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. GO-3 Raise CT Velocity String Procedure MBS - 9/8/2008 10:36:09 AM Edited 9/8/2008 KDW Page 2 of 2 ~ • Release WHP above tubing rams to the flow back tank. Nipple injector off of WHA. Walk injector up CT. Install C-plate above BOP and 1.75" polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT grapple, 18" x 2-1/16" IJ Box x pin spacer pup, and new "pack-off' style 4" Vetco hanger assembly. 9. MU Vetco Coil Tubing Hanger and Weatherford GS Running Tool. Swing Injector and lubricator away from WH. Vetco to connect VGCT Coil Tubing Hanger (4" Nom C/W 3" Baker Fishing neck with 2- 3/8" 8rd Box and 2" BPCV Profile) to hang coil tubing with coil grapple. While Vetco is making up CT hanger, BJ CoilTech to connect Weatherford GS tool string assembly to coil on reel.. Dimple-on a 1.75" CT connector. Pull test CT connector (20,000 lbs.) using 1.125" 10 SA box x 1-1/2" MT pin crossover and 1-1/2" MT box pull plate. Pressure test CT connector. Tool string will consist of 1-3/4" slim line dimple-on, 1-3/4" DF check valve, 1.125' 10 SA box x 1-1/2" MT pin X-over and 3" GS spear. PU or lay down 4" lubricator as needed to cover GS tool string and Vetco CT hanger. 10. Latch GS spear to Vetco mandrel after PU injector. Remove 1.75" polish rod clamp and C-plate from top of BOP. Walk injector down CT and nipple injector/lubricator to top of BOP. Pull test CT mandrel connection/GS spear assembly to CT string weight plus 5,000 lbs. Slack-off weight to CT string weight. Equalize WHP across tubing rams. Unlock tubing/slip rams. Open BOP tubing/slip rams. 11. RIH and land. Vetco CT hanger per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack-off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Down Screws. 12. Release 1-3/4" GS Running Tool. Set down weight on Hanger. Pressure up using 6% KCL water work string to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Release pressure when spear is both unlatched and above mandrel. 13. Purge KCL water from CT remaining on reel trailer with nitrogen. Allow N2 to vent to flow-back tank. 14. RDMO and release equipment. RD flow-back iron. Release tanks and all rental equipment to vendors. 15. MIRU Slick line Unit. Pressure test to 1.5 Times WH Pressure with 6% KCL water. RIH w/ 1.25" GR to nipple landing depth of 1-3/4" CT string. RIH and pull 1.18" BST blanking plug. RDMO Slick line. CONTACTS Ken Walsh 907-283-1311 (w) 907-394-3060 (cell) David Martens: 713-296-3302 (w) 832-472-6249(cell) Lyndon Ibele: 907-565-3042 (w) 907-748-2819 (cell) EMERGENCY CONTACTS: KGF Operators: 907-283-1305 Emergency Dial 911 GO-3 Raise CT Velocity String Procedure MBS - 9/8/2008 10:36:09 AM Edited 9/8/2008 KDW ~: 50-133-20548-00-00 lerty Des: ADL 384305 /ADL 389180 °_levtion: 187' (21' AGL / KB) i #: DD.04.10981.CAP.CMP.02 229,103.63 2,255,186.000 ude: 60° 09' 53.0430" N itude: 151 ° 29' 14.3564" W d: 1/22/2005 10:30 hrs 2/25/2005 22:00 hrs Released: hrs 4.0 deg1100'from 250.2000' 70 deg from 2000-8090' MD 1.5 degH00'to 11470' MD 23 deg from 11470' to TD at Grassim OskolkofF #3 Ninilchik Unit 3,221' FSL, 2,914' FEL Sec. 23, T1 N, R13W, S.M. ~ ~ Chemical Injection Nipple @ 2412' MD (Top) 5.930" OD/3.858" ID 8430 psi bursU7500 psi collapse • M ~-n~oM Conductor 20" K-55 133 ppf PE Top Bottom M D 0' 99' TVD 0' 99' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 2,507' TVD 0' 1,772' 12-1 /4" hole cmt w/ t 519 sks (232bb1s) 12ppg cmt wl 27 bbls cmt to surface Intermediate Casing 7" L-80 26 ppf BTC Top Bottom MD 0' 7,320' TVD 0' 3,424' 8-1/2" hole cmt w/ 305 sks (134.4 bbls) 12.Sppg Lead 8 167 sks (34.7 bbls) 15.8 ppg Tail. Plug did not bump, no cmt to surface, floats held. Liner 4-1/2" L-80 12.75 ppf Hydril 533 Top Bottom MD 7,049' 13,750' TVD 3,331' 8,127' 6-1 /8" hole cmt w/664 sks 12.7 ppg Tail (No spacer or cmt to surface) Lost partial circulation after pumping 230 bbls cmt Pollard Temp Log indicated TOC @ 10,350' MD before Liner Top Sqz Squeezed Liner Top w1500 sks 12.7 ppg cmt (88 bbl cmt below 12.7ppg) 2-5/8" Cores: 1.9794'-9875' KB (Cut 81' Recvd 66.9') 2.12,212'-12,301 KB (Cut 89' Recvd 70.15') Tvonek Perfs: MD TVD Gun Date 10,612'- 10,632, 20 ft 5,244'- 5,261' Owen 3.375" 6 SPF 9/13/2005 10,866'- 10,886, 20 ft 5,467'- 5,484' Owen 3.375" 6 SPF 9/13/2005 10,866'- 10,886, 20 ft 5,467'- 5,484' Owen 3.375" 6 SPF 70/29/2007 11,826'-11,840, 14 ft 6,345'- 6,358' Owen 3.375" 6 SPF 10/29/2007 11,830'-11,840, t0 ft 6,349'- 6,358' Owen 3.375" 6 SPF 9/08/2005 11,956'-11,972, 16 ft 6,465'- 6,479' Owen 3.375" 6 SPF 10/29/2007 11,956'-11,973, 17 ft 6,465'- 6,480' Owen 3.375" 6 SPF 9/08/2005 12,223'-12,238, 15 ft 6,712'- 6,726' Owen 3.375" 6 SPF 9/08/2005 12,242'-12,267, 25 ft 6,730'- 6,753' Owen 3.375" 6 SPF 9/0712005 12,354'-12,398, 44 ft 6,835'- 6,875' Owen 3.375" 6 SPF 9/06&07/2005 12,564'-12,586, 22 ft 7,029'- 7,049' Owen 3.375" 6 SPF 9/02/2005 12,564'-12,587, 23 ft 7,029'- 7,050' Owen 3.375" 6 SPF 10/28/2007 12,606'-12,626, 20 ft 7,068'- 7,086' Owen 3.375" 6 SPF 8/31/2005 12,607'-12,636' 29 ft 7,069'- 7,095' Owen 3.375" 6 SPF 10/28/2007 12,626'-12,668, 42 ft 7,086'- 7,125' Owen 3.375" 6 SPF 9/06&07/2005 12,636'-12,665' 29 ft 7,095'- 7,122' Owen 3.375" 6 SPF 10/28/2007 12,840'-12,854' 14 ft 7,284'- 7,297' Owen 3.375" 6 SPF 8/31/2005 Well Name 8 Number: Grassim Oskolkoff #3 Lease: Ninilchik Unit County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations (MD): 10,612' -12,854' (TVD): 5,244' - 7,297' Angle/Perfs: 25 DEGREES Angle @KOP and Depth: 2.5 @ 200' -Max angle 69 KOP (TVD): Date Completed: Completion Fluid: RKB: Prepared By: Mike Sulley Last Revision Date: 03/26/08 tr~J Permit #: 204-255 API #: 50-133-20548-00-00 Proaertv Des: ADL 384305 /ADL 389180 KB Elevtion: 187' (21' AGL / KB) WBS #: DD.04.10981.CAP.CMP.02 X= 229,103.63 Y= 2,255,186.000 Latitude: 60° 09' 53.0430" N Longitude: 151 ° 29' 14.3564" W Spud: 1/22/2005 10:30 hrs TD: 2/25/2005 22:00 hrs Rig Released: hrs 4.0 deg/100' from 250.2000' 70 deg from 2000-8090' MD 1.5 deg/100' to 11470' MD 23 deg from 11470' to TD at ' MD 255 deg. Grassim Oskolkoff #3 Ninilchik Unit Proposed 3,221' FSL, 2,914' FEL Sec. 23, T1 N, R13W, S.M. ng arnng - v.o , ~~.os, c-au, rsunress moo ng String - 4.5", 12.6#, L-80, Hydril 533 ~r Chemical Injection Nipple @ 2412' MD (Top) 5.930" OD/3.858' ID 8430 psi bursU7500 psi collapse Liner Packer with 15' Tieback Extension @ 7049' MD (Top) Lock Liner Hanger @ 7074' MD (Top) er Joints @9622-9673' MD (Two 19-20' long) er Joints @ 11,691-11,730' MD (Two 19-20' long) ling Collar @ 13,652' MD (Top) t Collar @ 13,685' MD (Top) Shce @ 13,750' MD (Bottom) 2-5/8" Cores: ~~__- Cement Top at 1.9794'-9875' KB (Cut 81' Recvd 66.9') @ -10,000' MD 2. 12,212'-12,301 KB (Cut 89' Recvd 70.15') Expro Radial Bond Log @ 12,785' MD (12,485' MD Proposed) ~ includes 2.50" OD x 1.50" ID CT grapple connector, 2.50" OD x 1.50" ID x 10' long x box straight bar, 1.91" OD x 1.188" BST )" no-go) profile nipple, & 3.50" OD x 2.50" OD (1.50" ID bottom) ne reentry guide. out to 13,570' MD with BJ CT (wl 3.80" OD centralizer) Death (MDl Depth ITVDt Liner 4-1/2" L-80 12.75 ppf Hydril 533 Top Bottom MD 7,049' 13,750' TVD 3,331' 8,127' 6-118" hole cmt w/664 sks 12.7 ppg Tail (No spacer or cmt to surface) Lost partial circulation after pumping 230 bbls cmt Pollard Temp Log indicated TOC @ 10,350' MD before Liner Top Sqz Squeezed Liner Top w1500 sks 12.7 ppg cmt (88 bbl cmt below 12.7ppg) MaRaTNON Conductor 20" K•55 133 ppf PE Top Bottom MD 0' 99' TVD 0' 99' Surface Casino 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 2,507' TVD 0' 1,772' 12-1 /4" hole cmt w/ t 519 sks (232bb1s) 12ppg cmt wl 27 bbls cmt to surface Intermediate Casing 7" L$0 26 ppf BTC Top Bottom MD 0' 7,320' TVD 0' 3,424' 8-1/2" hole cmt w/ 305 sks (134.4 bbls) 12.5ppg Lead 8 167 sks (34.7 bbls)15.8 ppg Tail. Plug did not bump, no cmt to surface, floats held. ~ ' Tvonek Perfs: MD TVD Gun Date ' 10,612'-10,632, 20 ft 5,244'- 5,261' Owen 3.375" 6 SPF 9/13/2005 10,866'-10,866, 20 ft 5,467'- 5,484' Owen 3.375" 6 SPF 9/13/2005 10,866'- 10,886, 20 ft 5,467'- 5,484' Owen 3.375" 6 SPF 1012912007 11,826'-11,840, 14 ft 6,345'- 6,358' Owen 3.375" 6 SPF 10/29/2007 11,830'-11,840, 10 ft 6,349'- 6,358' Owen 3.375" 6 SPF 9108/2005 11,956'-11,972, 16 ft 6,465'- 6,479' Owen 3.375" 6 SPF 10/29/2007 ~ ~ 11,956'-11,973, 17 ft 6,465'- 6,480' Owen 3.375" 6 SPF 910812005 12,223'- 12,238, 15 ft 6,712'- 6,726' Owen 3.375" 6 SPF " 9/08/2005 ~ c 12,242'-12,267, 25 ft 6,730'- 6,753' Owen 3.375 6 SPF 9/07/2005 j C 12,354'-12,398, 44 tt ' 6,835'- 6,875' ' ' Owen 3.375" 6 SPF " 9/06&07/2005 ~ c 12,564 -12,586, 22 ft - 7,049 7,029 6 SPF Owen 3.375 9/02/2005 ~ ~ 12,564'-12,587, 23 ft 7,029'- 7,050' Owen 3.375" 6 SPF 1 0/2 812 0 0 7 12,606'-12,626, 20 ft 7,068'- 7,086' Owen 3.375" 6 SPF 8131/2005 ~ ~ 12,607'- 12,636' 29 ft 7,069'- 7,095' Owen 3.375" 6 SPF 10/28/2007 ~ C 12,626'-12,668, 42 ft 7,086'- 7,125' Owen 3.375" 6 SPF 9/0680712005 12,636'- 12,665' 29 ft 7,095'- 7,122' Owen 3.375" 6 SPF 1 012 8/2 0 0 7 12,840'-12,854' 14 ft 7,284'- 7,297' Owen 3.375" 6 SPF 8131/2005 ~~ TD: 13,771' MD 8,147' TVD Well Name 8 Number: Grassim Oskolkoff #3 Lease: Ninilchik Unit County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations (MD): 10,612' - 12,854' (TVD : 5,244' - 7,297' Angle/Perfs: 25 DEGREES An le KOP and Depth: 2.5 @ 200' -Max an le 69 KOP (TVD): Date Completed: Completion Fluid: RKB: Prepared By: Mike Sulley Last Revision Date: 03/26/08 MN Laboratories, Inc. (832) 237-4000 Fax: (832) 237700 8845 Fallbtrook Drive, Houston, Texas 77064 Release Form Date: 4/22/2005 OMNI Employee Authorizing Release: David SuttoNJennifer Benefield Means Of Delivery: DHL - Tracking # 811 8892 891 OMNI File Number: A-33128 ~~t~Ep APR ~ ~ 2000 Well information: Marathon Oil Company Grassim Oskolkoff No. 3 Well Ninilchik Fietd Kenai Pennisula Borough, Alaska Material Released: Core 1: 17 samples, Core 2: 20 Samples, Core 3: 25 Samples, Cie 4.65 Samples Individual Requesting Release: Dave Brimbeny -Marathon Individual Authorizing Release: Dave Brimberry -Marathon Purpose Of Release: Client uest Address Material Was Delivered To: State of Alaska Oil & Gas Phone: 333 7th Ave. Anchorage, AK 99503 Delivery Accepted By: ~ ~~ Date: 7~. 2d0 S" Printed Name: ~ pW~M ~ (~ LC t 0.K ~, ~--~ ~ ~ .- ~s-s • • ~MNI Marathon Oil Company Grassim Oskolkoff No. 3 Well Ninilchik Field Kenai Pennisula Borough, Alaska File: A-33128 Date: 4/8/2005 State of Alaska Sam les Plug Diameter: 1.0" Requested Actual Plug Length: LAP Driller Date Sample Sample Drillin Fluid: Li uid Nifro en Name Drilled Core Sample Depth, Depth, No. No. feet feet Comments 1 1-1 9794.00 9794.15 1 1-2 9795.00 9495.00 '~ 1 1-3 9796.00 9796.00 1 1-4 9797.00 9797.05 . 1 1-5 9798.00 9798.00 1 1-6 9799.00 9799.00 ' 1 1-7 9800.00 9800.10 1 1-8 9801.00 9801.00 1 1-9 9802.00 9802.00 1 1-10 9803.00 9803.10 1 1-11 9804.00 9804.00 1 1-1 Z 9805.00 9805.00 1 1-13 9806.00 9806.10 1 1-14 9807.00 9807.00 1 1-15 9808.00 9808.00 1 1-16 9809.00 9809.15 1 1-17 9810.00 9810.00 • • MN1 Marathon Oil Company Grassim Oskolkoff No. 3 Well Ninilchik Field Kenai Pennisula Borough, Alaska File: A-33128 Date: 4/8/2005 State of Alaska Sam les Plug Diameter: 1.0" Requested Actual Plug Length: LAP Driller Date Sample Sample Drillin Fluid: Li uid Nitro en Name Drilled Core Sample Depth, Depth, No. No. feet feet Comments 2 2-1 9810.00 9810.55 , 2 2-2 .9811.00 9811.00.- 2 2-3 9812.00 9812.00 2 2-4 9813.00 9813.10 2 2-5 9814.00 9814.00 2 Z-6 9815.00 9815.00 2 2-7 9816.00 9816.05 2 2-8 9817.00 9817.00 ,i 2 2-9 9818.00 9818.00 2 2-10 9819.00 w/c 2 2-11 9820.00 w!c 2 2-12 9821.00 w/c 2 2-13 9822.00 9822.05 2 2-14 9823.00 9823.00 2 2-15 9824.00 9824.00 2 2-16 9825.00 9825.05 2 2-17 9826.00 9826.00 2 2-18 9827.00 9827.00 2 2-19 9828.00 9828.05 2 2-20 9$29.00 9829.00 2 2-21 9830.00 9830.00 2 Z-22 9831.00 w/c 2 2-23 9832.00 w/c 2 2-24 9833.00 9833.20 ~ 2 2-25 9834.00 9834.00 • • MNI Marathon Oil Company File: A-33128 Grassim Oskolkoff No. 3 Well Date: 4/8/2005 Ninilchik Field Kenai Pennisula Borough, Alaska State of Alaska Sam les Plug Diameter: 7.4" Requested Actual Plug Length: LAP Driller Date Sample Sample Drillin Fluid: Li uid Nitro en Name Drilled Core Sample Depth, Depth, No. No. feet feet Comments 3 3-1 9835.00 9835.10 3 3-2 9836.00 9836.00 3 3-3 9837.00 9837.00 3 3-4 9838.00 9838.10 3 3-5 9839.00 9839.00 3 3-6 9840.00 9840.00 3 3-7 9841.00 w/c 3 3-8 9842.00 w/c 3 3-9 9843.00 w/c 3 3-10 9844.00 9844.10 3 3-11 9845.00 9845.00 3 3-12 9846.00 9846.00 3 3-13 9847.00 9847.10 3 3-14 9848.00 9848.00 3 3-15 9849.00 9849.00 3 3-16 9850.00 9850.10 3 3-17 9851.00 9851.00 3 3-18 9852.00 9852.00 3 3-19 9853.00 9853.10 3 3-20 9854.00 9854.00 3 3-21 9855A0 9855.00 3 3 22 9856.00 9856.10 3 3-23 9857.00 9857.00 3 3-24 9858.00 9858.00 3 3-25 9859.00 9859.10 3 3-26 9860.00 9860.00 3 3-27 9861.00 9861.10 3 3-28 9862.00 Sam le Loose Tube 10 {9861-85-9862.20 in zip lock bag with slabs. Depth in this range, exact de ths not known. r~ • MNI Marathon Oii Company Grassim Oskolkoff No. 3 Well Ninilchik Field Kenai Pennisula Borough, Alaska File: A-33128 Date: 4/8/2005 State of Alaska Sam les Plug Diameter: 7.0" Requested Actual Plug Length: LAP Driller Date Sample Sample Drillin Fluid: Li uid Nitro en Name Drilled Care Sample Depth, Depth, No. No. feet feet Comments 4 4-1 12212.00 12212.35 4 4-2 12213.00 12213.00 4 4-3 12214.00 w/c 4 4-4 12215.00 12215.00 4 4-5 12216A0 12216.00 4 4~ 12217.00 12217.05: 4 4-7 12218.00 12218.00 4 4-8 12219.00 12219.00 4 4-9 12220.00 12220.00 4 4-10 12221.00 12221.35 4 4-11 12222.00 12222.00 4 4-12 12223.00 12223.00 4 4-13 12224.00 12224.00 4 4-14 12225.00 12225.00 4 4-15 12226.00 12226.00 4 4-16 12227.00 w/c 4 4-17 12228.00 w/c 4 4-18 12229.00 w/c 4 4-19 12230.00 12230.00 / 4 4-20 12231.00 12231.00. 4 4-21 12232.00 12232.OOr/ 4 4-22 12233.00 12233.05 4 4-23 12234.00 12234.00 4 4-24 12235.00 12235.00 4 4-25 12236.00 12236.25 4 4-26 12237. p0 12237.00 / 4 4-27 1223$.00 12238.00 4 4-28 12239.00 12239.30 4 4-29 12240.00 12240.00 4 4-30 12241.00 12241.00 4 4-31 12242.00 12242.30 4 4-32 12243.00 12243.00 4 4-33 12244A0 12244.00 4 4-34 12245.00 12245.05 4 4-35 12246.00 12246.00 4 4-36 12247.00 12247.00 4 4-37 12248.00 12248.10 • 4 4-38 12249.00 12249.00 4 4-39 12250.40 12250.00 4 4-40 12251.00 12251.00 4 4~1 12252.00 12252.05 4 4-42 12253.00 12253.05 4 443 12254.00 12254.00 4 4-44 12255.04 12255.02 4 4-45 12256.04 12256.55 4 4-46 12257.00 12257.05: 4 4-~l7 12258.00 12258.04 4 4-48 12259.00 12259.00 4 4-49 12260.00 12260.05 4 4-50 12261.00 12261.00 4 4-51 12262.00 12262.00 4 4-52 12263..00 12263.10 4 4-53 12264.00 12264.00 4 4-54 12265.00 12265.00 4 4-55 12266.00 12266.40 4 4-56 12267.00 12267.00 4 4-57 12268.00 12268.00 4 4-58 12269.00 12269.15 4 4-59 12270.00 12270.00 4 4-60 12271.40 12271.00 4 4-61 12272.40 12272.10 4 4~2 12273.00 12273.00 4 4-63 12274.00 12274.00 4 4-64 12275.00 12275.00 4 4-65 12276.00 12276.00 4 4-66 12277.00 12277.00 4 4-67 12278.00 12278.15 4 4~8 12279.00 12279.00 4 4-69 12280.00 12280.00 4 4-70 12281.00 no core 4 4-71 12282.00 no core r~ LJ Maunder, Thomas E (DOA) From: Ibele, Lyndon [Icibele@marathonoil.com] Sent: Monday, December 17, 2007 11:37 AM To: Maunder, Thomas E (DOA) Subject: Sundry status • Page 1 of 1 Tom-- FYI, just wanted to let you know that we have had an on-going, company-wide IT problem that may affect our ability to file sundry notices timely for a few wells. The data-base system that is used to generate alt of our downhole activity reports crashed on December 8th, and all the king's horses and all the king's men haven't been able to put Humpty-Dumpty back together yet and we have been given no timeline for completion. .~. We know we are close to the 30 day deadlines for submitting Form 404 for recent work performed on Wells G03 and G05, and the 407 for G06. However, should the afore-mentioned database not be functional in t e nex ew days, we will be unable to retrieve operations summaries that are required with the sundries, and it is likely these sundry reports could be tardy. I will keep you posted if that looks likely to occur. RE Forms 10-421, there are several pending. However, we have not yet achieved stable production rates and have been unable to perform multi-point tests on Sterling Unit wells 41-15rd and 43-gx. Those tests will be performed and submitted as soon as possible. For Wells NS-3 and GO-6, we have single-point tests only to report, because the wells are producing at maximum capacity but at very low rate. The only means to achieve multiple flow points would require that the wells be choked-back, but doing so would cause them to be produced below the unloading rate. This would not only be meaningless from amulti-point test perspective, but would also jeopardize killing the wells. We will submit a cover letter with this explanation when we submit the form 10-421 for these two wells. O~ ~~ 4/9/2009 • • ~.~- MICROFILMED 03/01 /2048 a: .,.-_ DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFicheiCvrPgs_InsertslAgicrofilm Marker.doc • M Marathon MARATHON Oil Company January 2, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Ninilchik Gas Field Well: Grassim Oskolkoff #3 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~ '~' JA1~ ~ 7 2008 Attached for your records is the 10-404 Sundry Report for GO-3 well. This report covers the velocity string installation work that Marathon completed under sundry #307-198. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report Operations Summary Well Schematic cc: Houston Well File Kenai Well File KJS DMD KDW STATE OF ALASItA ~- ~~ ~ ' ALAS OIL AND GAS CONSERVATION COM ION , :z ,; ~ .~ ~~~~ REPORT OF SUNDRY WELL OPERATIONS ~1asa,~ ~,: ~~r~,. 1. Operations Abandon Repair Well Plug Perforations Stimulate Ot~ar ~ ~ Install Velocity Performed: Alter Casing ^ PuII Tubing ^ Perforate New Pool ^ Waiver^ Time~~xtension ~] String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ~ Exploratory^ 204-255 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20548-00-00 7. KB Elevation (ft): 9. Well Name and Number: 21' Grassim Oskolkoff #3 ` 8. Property Designatiorr. , 10. Field/Pool(s): ~ ADL 384305 /ADL 389180 ~ Ninilchik Unit / Tyonek Pool 11. Present Well Condition Summary: Total Depth measured 13,7' feet Plugs (measured) NA true vertical 8,147' feet Junk (measured) NA Effective Depth measured 13,633' feet true vertical 8,019' ~ feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 99' 20" 99' 99' 3,060 psi 1,500 psi Surface 2,507' 9-5/8" 2,507' 1,772' 5,750 psi 3,090 psi Intermediate 7,320' 7" 7,320' 3,424' 7,240 psi 5,410 psi Production 0 0 0 0 0 0 Liner 6,701' 4-1/2" 13,750' 8,127' 8,430 psi 7,500 psi Perforation depth: Measured depth: 10,612' - 12,854' Gross True Vertical depth: 5,244' - 7,297' Gross 4-1 /2" L-80 7,049' Tubing: (size, grade, and measured depth) 1-3/4" QT-900 12,785' Packers and SSSV (type and measured depth) Baker 4-1 /2" ZXP 7,049' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 480 1 0 762 Subsequent to operation: 0 600 0 0 784 14. Attachments: 1 5. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of W ell Operations 16. Well Status after work: Oil ^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-198 Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Se nior Production Engineer - /~ f ~ , Signature 1 ~-~"'`- ~ . W /~ Phone (907) 283-1333 Date January 2 2008 _ , Form 10-404 Revised 04/2006 ~ ~ `~ ~ Submit Original Only • • Permit #: 204-255 API #: 50-133-20548-00-00 Property Des: ADL 384305 /ADL 389180 KB Elevtion: 187' (21' AGL / KB) WBS #: DD.04.10981.CAP.CMP.02 X= 229,103.63 Y= 2,255,186.000 Latitude: 60° 09' 53.0430" N Longitude: 151° 29' 14.3564" W Spud: 1/22/2005 10:30 hrs TD: 2/25/2005 22:00 hrs Rig Released: hrs Grassim Oskolkoff #3 MARATHON 4.0 deg/100' from 250-2000' 70 deg from 2000-8090' MD 1.5 deg/100' to 11470' MD 23 deg from 11470' to TD at ' MD 255 deg. Ninilchik Unit 3,221' FSL, 2,914' FEL Sec. 23, T1 N, R13W, S.M. >>~~ avmg - va , iz.oa, L-au, numress rv String - 4.5", 12.6#, L-80, Hydril 533 Baker Chemical Injection Nipple @ 2412' MD (Top) 5.930" OD/3.858" ID 8430 psi bursU7500 psi collapse Liner Packer with 15' Tieback Extension @ 7049' MD (Top) -ock Liner Hanger @ 7074' MD (Top) ~r Joints @ 9622-9673' MD (Two 19-20' long) ;r Joints @ 11,691-11,730' MD (Two 19-20' long) ng Collar @ 13,652' MD (Top) Collar @ 13,685' MD (Top) Shce @ 13,750' MD (Bottom) 2-5/8" Cores: I Cement Top at 1.9794'-9875' KB (Cut 81' Recvd 66.9') @ -10,000' MD 2. 12,212'-12,301 KB (Cut 89' Recvd 70.15') Expro Radial Bond Log 1-314" OD Coiled Tubing Velociri String: @ 12,785' MD BHA includes 2.50" OD x 1.50" ID CT grapple connector, 2.50" OD x 1.50" ID ~ x 10' long box x box straight bar, 1.91" OD x 1.25" PXN (1.135" no-go) profile nipple, 8 3.50" OD x 2.50" OD (1.50" ID bottom) wirline reentry guide. Tagged PBTD at 13,633' KB with Expro CBUGR. ~ ~ Cleaned out to 13,570' MD with BJ CT (wl 3.80" OD centralizer) ~ c Formation Tops: Formation Depth (MD) Deoth (TVD) Beluga Tyonek TD: TD 13,771' MD 8,147' TVD Well Name 8 Number: Grassim Oskolkoff #3 Lease: Ninilchik Unit County or Parish: Kenai Penisula Borough State: Alaska Count USA Perforations (MD): 10,612' - 12,854' (ND): 5,244' - 7,297' Angle/Perfs: Angle @KOP and Depth: KOP (ND Date Completed: Completion Fluid: RKB: Prepared By: Kevin Skiba Last Revision Date: 12/27/07 Liner 4-1 /2" L-80 12.75 ppf Hydri1533 Top Bottom MD 7,049' 13,750' TVD 3,331' 8,127' 6-1/8" hole cmt w/664 sks 12.7 ppg Tail (No spacer or cmt to surface) Lost partial circulation after pumping 230 bbls cmt Pollard Temp Log indicated TOC @ 10,350' MD before Liner Top Sqz Squeezed Liner Top w/500 sks 12.7 ppg cmt (88 bbl cmt below 12.7ppg) Conductor 20" K-55 133 ppf PE Top Bottom M D 0' 99' TVD 0' 99' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 2,507' TVD 0' 1,772' 12-1/4" hole cmt w/ t 519 sks (232bb1s) 12ppg cmt w/ 27 bbls cmt to surface Intermediate Casino 7" L$0 26 ppf BTC Top Bottom MD 0' 7,320' TVD 0' 3,424' 8-1 /2" hole cmt w/ 305 sks (134.4 bbls) 12.Sppg Lead 8 167 sks (34.7 bbls)15.8 ppg Tail. Plug did not bump, no cmt to surface, floats held. Tvonek Perfs: MD TVD Gun Date 10,612'-10,632, 20 ft 5,244'- 5,261' Owen 3.375" 6 SPF 911 312 0 0 5 10,866'-10,886, 20 ft 5,467'- 5,484' Owen 3.375" 6 SPF 9113/2005 10,866'-10,886, 20 ft 5,467'- 5,484' Owen 3.375" 6 SPF 10129!2007 11,826'-11,840, 14 ft 6,345'- 6,358' Owen 3.375" 6 SPF 10129/2007 11,830'-11,840, 10 ft 6,349'- 6,358' Owen 3.375" 6 SPF 9/08/2005 11,956'-11,972, 16 ft 6,465'- 6,479' Owen 3.375" 6 SPF 10129/2007 11,956'-11,973, 17 ft 6,465'- 6,480' Owen 3.375" 6 SPF 9108/2005 12,223'-12,238, 15 ft 6,712'- 6,726' Owen 3.375" 6 SPF 910 812 0 0 5 12,242'-12,267, 25 ft 6,730'- 6,753' Owen 3.375" 6 SPF 9/0712005 12,354'-12,398, 44 ft 6,835'- 6,875' Owen 3.375" 6 SPF 9/0680712005 12,564'-12,586, 22 ft 7,029'- 7,049' Owen 3.375" 6 SPF 9/02/2005 12,564'-12,587, 23 ft 7,029'- 7,050' Owen 3.375" 6 SPF 10/2812007 12,606'-12,626, 20 ft 7,068'- 7,086' Owen 3.375" 6 SPF 8131/2005 12,607'-12,636' 29 ft 7,069'- 7,095' Owen 3.375" 6 SPF 10/28/2007 12,626'-12,668, 42 ft 7,086'- 7,125' Owen 3.375" 6 SPF 9106807/2005 12,636'-12,665' 29 ft 7,095'- 7,122' Owen 3.375" 6 SPF 10/28/2007 12,840'-12,854' 14 ft 7,284'- 7,297' Owen 3.375" 6 SPF 8/3112005 L • • Marathon Oil Company Operations Summary Report Page 4 of 9 Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: WORKOVER Start: 10/3/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date I From - To I Hours I Code I Code I Phase I Description of Operations 10/31/2007 07:30 - 08:00 0.50 SAFETY MTG_ CTBG 08:00 - 15:00 7.00 RURD_ COtL CTBG 15:00- 15:15 0.25 SECUR WELL CTBG 11/1!2007 07:30 - 08:00 0.50 SAFETY MTG_ CTBG 08:00 - 15:00 7.00 RURD_ COIL CTBG 15:00 - 17:15 2.25 TEST_ BOPE CTBG 17:15 - 18:00 0.75 SECUR WELL CTBG 11/2/2007 07:30 - 08:00 0.50 SAFETY MTG_ CTBG 08:00 - 10:00 2.00 RURD_ COIL CTBG 10:00 - 13:00 3.00 PULD. BHA CTBG 13:00- 15:45 2.75 BLOWD OIL CTBG 15:45 - 16:00 0.25 PULD_ BHA CTBG 16:00 - 16:15 0.25 SECUR WELL CTBG 11/312007 07:30 - 08:00 0.50 SAFETY MTG. CTBG 08:00 - 10:00 2.00 RURD_ COIL CTBG 10:00 - 14:30 4.50 WORK COIL CTBG 14:30 - 14:45 0.25 SAFETY MTG_ CTBG 14:45 - 16:40 1.92 WORK COIL CTBG 16:40 - 18:00 ~ 1.33 ~ CUT_ ~ TBG_ ~ CTBG 18:00 - 18:15 ~ 0.25 ~ CUT_ ~ COIL ~ CTBG 18:15 - 21:00 f 2.751 WORK~COIL (CTBG 21:00 - 22:00 I 1.00 WORK COIL CTBG 22:00 - 23:00 I 1.001 WORK I COIL I CTBG 23:00 - 23:30 0.50 RURD_ COIL CTBG 11/4/2007 10:00 - 11:00 1.00 SAFETY MTG_ CTBG 11:00 - 11:15 ~ 0.25 ~ RURD_ COIL ~ CTBG Obtain permit, review JSA and job scope for rig up and daily operation. Spot in CTU, methanol tank, flow back equip. Unable to proceed due to high wind. Secure well and location for night, tum in permit. Obtain permk, review JSA and job swpe for rig up and daily operation. Complete rigging up CTU, flow back equipment and nipple up BOPE's. Begin 80PE test. State witness waived by Jim Rego on 10/30/2007 @ 14:20 hrs. BOPE test complete, secure well for night. Turn in pemit. Obtain permit, review JSA and job scope for running velocity sVing. Stab pipe in injector. M/U coil grapple, pull test to 15k. P/U spacer bar, centralizer, and no-go. FIII coil wl 29 bbls. 50/50 meth water / PT to 3000psi. Go to well w/injector to displace meth/water from coil. All fluid displaced, coil bled down. Decision made to rig back for night. Well and location secured, tum in permit. Obtain work permit, review JSA and procedure. PU Injector and lubricator. MU BHA on 1.75" Coil with 0.175" wall. BHA consist of grapple, straight bar, profile, cetralizer. Open well, WHP= 780 psig @ 620 MCFPD. RIH with 1.75" coil tubing velocity string to 12,795' KBD. PU weight 18000 lbs. Vetco on lease for hang off. Held tail gate safety meeting. Closed tubing slips, pin slips, sat-4000 Ibs on slips. Bled off well above tubing slips. PU injector, cut pipe 13' above hanger. Vetco dressed up coil end, made up grapple and mandrel assembly. Installed 1.75" coil connector on work string, pulled tested, came free with 7000 Ibs. Cui off and reconnect coil connector. Pulled test to 32, 000 Ibs, good test. MU Weatherford 3" GS to coil, PU injector and go to well. Locate 3" GS into top of 4" mandrel assembly on velocity string. MU lubricator to top of BOP's. Release slips. RIH with coil, coil setting down 5' short of hanoer, work coil several times could not clear cross over with 4" mandrel assembly. PUH shut slips, pin slips, blew down above BOP. Unbolt flange. Crane picked up lubricator. N2 Pressure released under the lubricator. Continued Picking up injector with crane to expose the hanger. Take injector to craddle. Veico inspected the mandrel assembly, appears the shoulder of the mandrel landing on the cross over flange under BOP. PU top section of the lubricator and went to well. Secured well, all personnel left lease. Plan to install a centralizer above the 3" GS to run mandrel assembly in morning. Obtain work permit, review JSA and procedure. Discussed yesturdays events and todays. Verify no pressure above BOP. PU injector and lubricator. WHP= 780 psig @ 310 MCFPD. rnntea: ilrznzuui c.~o:vurmi • • Marathon Oil Company Page 5 of 9 Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Event Name: WORKOVER Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING Date From - To Hours I Code I Cod I Phase Spud Date: 1/17/2005 Start: 10/3/2007 End: Rig Release: Group: Rig Number: 1 Description of Operations 11/4/2007 ~ 11:15 - 12:00 ~ 0.75 ~ WORK~COIL ~ CTBG 12:00 - 12:30 ~ 0.50 ~ CUT_ ~ TBG_ ~ CTBG 12:30 - 13:30 I 1.00 I WORK I COI L ICTBG 13:30 - 14:10 I O.fi7I WORK I COIL ICTBG 14:10 - 15:00 I 0.831 WORK_J COIL (CTBG 15:00 - 15:20 I 0.331 WORK~COIL ICTBG 15:20 - 18:00 I 2,671 WORK~COIL (CTBG 18:00 - 18:40 I 0.671 RURD I COIL (CTBG 18:40 - 19:00 1 0.331 RURD I COIL ~ 11!5/2007 ~ 07:30 - 08:30 ~ 1.00 ~ SAFETY ~ MTG_ ~ CTBG 08:30 - 10:30 I 2.00 I RURD I COIL ICTBG 10:30 - 12:20 I 1.83 I RURD I COIL ICTBG 12:20-13:20) 1.ODRURD (COIL (CTBG 13:20 - 16:00 I 2.671 RURD ICO{L ICTBG 16:00 - 18:30 ~ 2.50 ~ RURD_ COIL ~ CTBG 11/7/2007 ~ 08:00 - 10:00 ~ 2.00 ~ SAFETY ~ MTG_ ~ CTBG 10:00- 10:50 ~ 0.831 RURD. ISLIK ICTBG PU injector with crane, Cut and dress up coif connector below injector. Added to the BHA a 3.83" centralizer above the. 3" GS to help keep GS in center of mandrel assembly for landing in hanger. Vetco cut 3' off of coil above BOP and dressed pipe for with new grapple and installed mandrel assembly. Ready to proceed with velocity string hang off. PU injector and go to well. Locate Weatherford 3" GS into top of 4" mandrel assembly attached to velocity string. MU lubricator io top of BOP's. Pull tested mandrel assembty to 28, 0001bs, good test. Release slips, RIH with cell 12'. Landed mandrel assembiv in velocity . hanger. Vetco verified that hanger set. Pressure up on hanger seals. made several attempts but would not test, lest failed. PU on coil, Vetco released pins. Pulled up past BOP. Closed pipe slips and pinned. Blew down pressure above the BOP's. Pressure would not bleed down past 200 pstg. Could not check the. mandrel assemble seals. Release tubing slips, RIH set velocity string in tubing hanger. Landed mandrel assembly in hanger. Set hanger, verified by Vetco. Pump off GS with N2. GS would not release. N2 pressure at 2500 psig, 3000 Ib burst disk let go. GS would not release. Switched to fluid to pump off GS. Increase pump rate to 1.65 BPM, 4300 psig. GS released. PU BHA above the Swab valve. Closed valve. Bled down pressure above BOP. Take Injector to craddle. Secured well with tree cap. Total fluid pumped was 16 bbis. Secured area all personnel left lease. Plan to rebuild the tubing sups tomorrow morning (no parts for BOP's on location) priorto pulling the velocity string up and redressing the mandrel assembly. Obtain work permit, review JSA and procedure. Discussed yesturdays events and todays. Bled down pressure above swab valve, Rebuilt the 7" BOP tubing slip rubbers. Retested to 500 psig/pressure would not bleed down. Tried to pressure up to 2000 lbs. Same results.. Checked equalizing valves on 7 1/16" BOP no visual problems. Retested with same results. Not able to get the BOP tubing slips to hold pressure. Discussed options with Anchorage. Decided to pump plastic sealant between mandrel assembly and hanger. Pump plastic sealant, pressure would bleed off indicating that an upper seal was damaged or gone or both seals were gone or damaged. Closed velocity string wing valve, bled pressure to flow back tank above mandrel assembly to verify if lower seal on assembly holdirag. Not holding. Rig down BOP sent to 8J shop to stump test and repair. Left. coil tubing unit rigged up around well. Well secured. Truck on lease to PU BOP's to take to BJ shop for repairs. Note: The velocity string manderal seals will not pass pressure test. Coil will need to pull the velocity string up and redress the mandrel and reset and retest the hanger seals. Held PJSM. Filled out Safe Work Permit and JSA. Stand by for ASRC to move grove crane MIRU Pollard Wireline to tag and verify that pumpout plug at the bottom . Printed: 12/27!2007 2:18:48 PM • • Marathon Oil Company Operations Summary Report Page 6 of 9 Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1 /1 712 005 Event Name: WORKOVER Start: 10/3/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date I From - To I Hours (Code I Code ~ Phase I Description of Operations 111/7/2007 111!812007 111!9/2007 10:00- 10:50 I 0.831 RURDSLIK (CTBG 10:50 - 11:10 0.33 TEST EQIP CTBG 11:10 -12:45 1.58 ENGAG FISH CTBG 12:45 - 12:50 0.08 TEST EOIP CTBG 12:50 - 14:00 1.17 ENGAG FISH CTBG 14:00 - 15:00 1.00 WAITON EQIP CTBG 15:00 - 15:15 0.25 CHANG EQIP CTBG 15:15 - 15:20 OA8 TEST_ EQIP CTBG 15:20 -15:50 0.50 ENGAG FISN CTBG 75:50-15:55 0.08 TEST_ EQIP CTBG 15:55 - 16:30 0.58 ENGAG FISH CTBG 16:30 - 16:35 0.08 TEST_ EQIP CTBG 16:35 - 17:15 0.67 ENGAG FISH CTBG 17:15 - 17:30 0.25 RURD_ SLIK CTBG 07:20 - 07:40 0.33 SAFETY .MTG_ CTBG 07:40 - 08:20 0.67 RURD_ SLIK CTBG 08:35 - 09:25 I 0.83 I ENGAGE F SH I CTBG 09:25 - 09:30 0.08 TEST_ EQIP CTBG 09:30 - 10:30 1.00 ENGAG FISH CTBG 10:30 - 10:35 0.08 TEST EQIP (CTBG 10:35 - 11:30 0.92 ENGAG FISH CTBG 11:30 - 11:35 0.08 TEST_ EQIP CTBG 11:35 - 13:00 1.42 ENGAG. FISH CTBG 13:00 - 13:05 0.08 TEST_ EQIP CTBG 13:05 - 13:50 0.75 ENGAG FISH CTBG 13:50 - 15:20 1.50 TEST EQIP CTBG 15:20 - 15:25 0.08 TEST_ EOIP CTBG 15:25 - 16:30 1.08 ENGAG FISH CTBG 16:30 - 18:00 ~ 1.50I RURD_ISLIK (CTBG 08:00 - 08:45 0.75 SAFETY MTG_ CTBG 08:45 - 09:10 0.42 RURD SLIK CTBG 09:10 - 09:20 0.17) TEST_~EQIP CTBG 09:20 - 10:10 0.83 ENGAG FISH CTBG of the coiled tubing velocity string BHA is still attached and intact. Pressure test w! pump. RIH w/ 1" stem as gauge ring to 1940' wim, tools set down, worked tools to 2400' wim, tools not falling. POOH. Tools covered in paraffin or pipe dope (most likely graphite/oil sealant pumped previously to try to seal coil tubing hanger). Pressure test w/quick test sub RIH w/ same to 2200' tools stopped falling work tools to 2490' wim. POOH and talked with company man. Standby for tools to arrive from shop. Reconfigure tool string. Pressure test w/quick test sub RIH w/ 1.35" Gauge ring to 2' wim could not get in coil tubing hanger - POOH Pressure test w/quick test sub RIH w/ 1.25" DD Bailer to 2490' wim work bailer to 2590' wim -POOH Pressure test w/quick test sub RIH w/ 1.5"wireline scratcher to 2581' wim, worked tool to 2675' wim - POOH Lay down wireline for the night. Shut in and secure tree. Held PJSM. Filled out Safe Work Permit and JSA. RU Pollard Wireline to tag and verify that pumpout plug at the bottom of the coiled tubing velocity and to remove foreign material from the inside. of the v-string. Pressure test w! pump. RIH wlwire spear to 2627' wim, tools set down, worked toots to 2721' wim, tools not falling. POOH. Pressure test w! quick test sub RIH w/ same to 2735' tools stopped falling work tools to 2668' wim. POOH. Pressure test w/quick test sub RIH w/ 1.0" Dump Bailer filled with deisei to 2768' wim. Worked tool to 3086' and POOH. Pressure test w/ quick lest sub Lubricated 3 gals of diesel into coiled tubing through swab valve. RIH with 1.25" braided line brush to 3300' wim. Worked tool and R1H to 5905' wim. POOH. Pressure test wi quick test sub RIH w/ 1.0" chisel bit to 5930' wim, worked tool to 6250' wim -POOH Lubricated 3 gals of diesel into coiled tubing through swab valve. RIH with 1.0" chisel bit to 6300' wim. Worked tool and RIH to 7300' wim. POOH. Pressure test w/ quick test sub Lubricated 4 gals of diesel into coiled tubing through swab valve. RIH with 1.0" chisel bit to 7310' wim. Worked tool and RIH to 7454' wim. POOH. lay down wireline for the night. Shut in and secure tree. Held PJSM. Filled out Safe Work Permit and JSA. RU Pollard Wireline to tag and verify that pumpout plug at the bottom of the coiled tubing velocity and to remove foreign material from the inside of the v-string. Pressure test w! pump. .RIH 1" chisel to 7585' MD. w~mea ~ruznzuui Z:7C:4tl YM • Marathon Oil Company Page 7 of 9 Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: WORKOVER Star: 10/3/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date I From - To I Hours I Code I Code Phase I Description of Operations 11/9/2007 10:10 -10:15 0.08 TEST_ EQIP CTBG 10:15 -10:45 0.50 ENGAG FISH CTBG 10:45 - 10:50 0.08 TEST_ EQIP CTBG 10:50 -11:10 0.33 ENGAG FISH CTBG 11:10 - 11:15 0.08 TEST_ EQIP CTBG 11:15 - 11:55 0.67 ENGAG FISH CTBG 11:55 - 12:00 0.08 TEST_ EQIP CTBG 12:00 - 12:30 0.50 ENGAG FISH CTBG 12:30 - 12:40 D.17 TEST_ EQIP CTBG 12:40 - 13:40 1.00 ENGAG FISH CTBG 13:40 - 13:45 D.08 TEST_ EQIP CTBG 13:45 - 14:35 0.83 ENGAG FISH CTBG 14:35 - 14:40 0.08 TEST_ EQIP CTBG 14:40 - 15:25 0.75 ENGAG FISH CTBG 15;25 - 15:30 0.08 TEST_ EQIP CTBG 15:30 - 16:25 0.92 ENGAG FISH CTBG 16:25 - 16:30 0.08 TEST_ EQIP CTBG 16:30 - 17:15 0.75 ENGAG FISH CTBG 17:15 - 1.$:00 0.75 RURD_ SLIK CTBG 11/10/2007 08:00 - 08:30 0.50 SAFETY MTG_ CTBG 08:30 - 09:00 0.50 RURD SLIK CTBG 09:00 - 09:10 0.17 TEST_ EQIP CTBG 09:10 -16:45 7.58 ENGAG FISH CTBG 16:45 - 18:00 1.25 RURD_ SLIK CTBG 11!11!2007 08:00 - 08:30 0.50 SAFETY MTG_ CTBG 08:30 - 09:00 0.50 RURD SLIK CTBG 09:00 -09:10 0.17 TEST_ EQIP CTBG 09:10 - 16:45 7.58 ENGAG FISH CTBG 16:45 - 18:00 1.25 RURD_ SLIK CTBG 11/1212007 08:00 - 08:30 0.50 SAFETY MTG_ CTBG 08:30 - 09:00 0.50 RURD SLIK CTBG 09:00 - 09:10 0.17 TEST_ EQIP CTBG 09:10-16:45 7.58 ENGAG FISH CTBG 16:45 -18:00 1.25 RURD_ SLIK CTBG 11/14/2007 08:00 - 08:30 0.50 SAFETY MTG_ CTBG 08:30 - 09;30 1.00 WAITON OTHR CTBG 09:30 - 12:00 2,50 NUND ROPE CTBG 12:00 - 14:00 2.00 TEST_ ROPE CTBG 14:00 - 16:30 2.50 TEST_ BOPE CTBG 16:30 -18:00 1.50 TEST_ BOPE CTBG 18:00 - 18:30 0.50 SECUR WELL CTBG 11/15/2007 07:30 - 08:00 0.50 SAFETY MTG_ CTBG Pressure test w/ quick test sub RIH with 518" wire brush to 3021'. Recovered some sealant on brush. Pressure test w/ quids test sub RIH with 5/8" wire brush to 2852'. Recovered some sealant on brush. Pressure test w/ quids test sub RIH with 5/8` wire brush to 4871'. Recovered nothing Pressure test w/ quids test sub RIH with 518" wire brash to 2950'. Recovered nothing. Pressure test w/ quids test sub RIH with 1"chisel to 5000'. Recovered nothing. Pressure test w/ quids test sub RIH with 5/8" center spear to 7400'. Recovered nothing. Pressure test w/ quids test sub RIH with 518" wire brush to 7416'. Little recovery. Pressure test w/quick test sub RIH with 518" wire brush to 7416'. Little recovery. Pressure test w/ quids test sub RIH with 518" wire brush to 7416'. Little recovery. LD lubricator and secure well for night. Held PJSM. Filled out Safe Work Permit and JSA. RU Pollard Wireline to tag and verify that pumpout plug at the bottom of the coiled tubing velodty and to remove foreign material from the inside of the v-string. Pressure test wl pump. RIH 1.18" intemal wire grab. Made 5 trips and recovered about 1 cup sealant. Worked down to 7550'. LD lubricator and secure well for night. Held PJSM. Filled out Safe Work Pemtit and JSA. RU Pollard WUeiine to remove foreign material from the inside of the v-string. Pressure test w/ pump. RIH 1.18" intemal wire grab. Made 5 trips and recovered about 1 cup sealant. Worked down to 4700'. LD lubricator and secure well for night. Held PJSM. Filled out Safe Work Permit and JSA. RU Pollard Wireline to remove foreign material from the inside of the v-string. Pressure test w/ pump. RIH 1.18" intemal wire grab. Made 5 trips and recovered about 1 cup sealant. Worked down to 6700'. LD lubricator and secure well for night. Obtain permit, review JSA and job scope for rig up and daily operation.State witness waived by Mr. Bob Noble on 11/13/2007 @ 08:00 hrs. Wait on sand truck to sand location Nipple up BOPS stack and hardline. Start complete BOPE test. Still having problems with pipe/slip rams, start trouble shooting. Wrap up stack and apply heat for 1 hour, able to get a low test, no high.Pipe inserts may not be rated for colder temps. Decide to shut .down for night and regroup. Well and location secured for night, turn in permit. Obtain HOT work permit, review JSA and job scope for rig up and daily Printed: 12/2712007 2:18:48 PM • Marathon Oil Company Page 8 of 9 Operations Summary Report Legal UVell Name: GRASSIM OSKOLKOFF 3 Common We11 Name: GRASSIM OSKOLKOFF 3 Spud Date: 1!17/2005 Event Name: WORKOVER Start: 10/3/2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 1 U1512007 07:30 - 08:00 0.50 SAFETY MTG_ CTBG operation.State witness waived by Mr. Bob Noble on 11/13/2007 Q 08:00 - 11:00 3.00 RURD COIL CTBG 11:00 - 11:30 0.50 TEST_ BOPE CTBG 11:30 - 13:00 1.50 TEST BOPE CTBG 13:00 -14:20 1.33 PULD_ EQIP CTBG 14:20 -15:00 0.67 RURD_ COIL CTBG 15:00 - 15:20 0.33 TEST EQIP CTBG 15:20 - 15:45 I 0.421 ENGAGQFISH (CTBG 15:45 - 16:20 0.58 SAFETY MTG_ CTBG 16:20 - 17:45 1.42 RUNPU EQIP CTBG 17:45 - 18:00 0.25 PULD EQIP CTBG 18:00 - 18:30 0.50 PULD_ EQIP CTBG 18:30 - 19:15 0,75 NUND EQIP CTBG 19:15 - 20:30 ~ 1.25 ~ SETREL ~ LNR_ ~ CTBG 20:30 - 20:40 0.17 SECUR WELL CTBG 11/16/2007 07:30 - 08:00 0.50 SAFETY MTG_ CTBG 08:00 - 09:45 1.75 RURD_ COIL CTBG 09:45 -10:00 0.25 TEST EOIP CTBG 10:00-11`.15 ~ 1.25~ENGAG~FISH CTBG 11:15-12:30 ~ 1.25~NUND ~EOIP CTBG 12:30 - 12:50 ~ 0.33 ~ NUND ~ EQIP (CTBG 12:50 - 13:00 I 0.171 RUNPULICOIL (CTBG 13:00 - 13:15 0.25 TEST_ EOIP CTBG 13:15 - 14:00 0.75 RUNPU COIL CTBG 14:00 - 14:15 0.25 SECUR WELL CTBG 11/17/2007 07:30 - 08:00 0.50 SAFETY MTG_ CTBG 08:00 - 09:45 1.75 RURD_ C01L CTBG 09:45 - 10:00 0.25 TEST_ EQIP CTBG 08:00 hrs. Apply heat to BOPE stack, tidy up location. Close blind shears, shell test-350 lo, 4500 high. Begin testing pipe slip rams. Begin with 350 psi low working psi up in 1000# increments to 4500 psi. Good test. Pick up injector and riser with additional 4' riser. Make up 1.75" dimple connector, 3.82" centralizer, 3k burst sub, 3" GS spear. Go to well with injector, flange up riser. Shell test stack to 1000 psi. Equalize above and below emergency master valve. Vetco on location. Open well, run in 10.6' and latch hanger, pull 20k to verify GS is latched. Back out lockdown screws and PU 12.5'. Close pipe slip combi's, bleed stack above pipe rams to 0 psi. Close in choke skid to watch for psi buildup. Hold PJSM, review Vetco JSA and go over job scope. 0 psi on choke. Set down 5k on GS, psi up coil to 800psi and release from hanger. Nipple down riser from BOPS stack, breakout hanger and redress. Grapple and coil below grapple look good. Redress hanger, make up 4' spacer pipe to hanger and swing injector into position to MIU to coil grapple. Pull test GS to 3k. N/U riser to BOPE stack. Equalize psi above and below pipe rams, pull 17k on hanger and open pipe rams. RIH 17.6' and land hanger. Screw in lockdowns and attempt to PT hanger assemb. Pressure broke back at 2k down to WHP of 800 psi. Attempt to pressure back up, unable to psi up past 800 psi. Looks like hanger seals are leaking. Decision made to release from hanger, set down 5k, psi up to 1200# and release from hanger. Rig injector back for night. Secure well and location for night. Turn in permit. Obtain HOT work permit, review JSA and job scope for rig up and daily Pick up Injector and m/u 3.82" cetralizer and 3" GS spear. PT stack to 1000 psi. Open swab, rih and latch into hanger. Pull test GS spear, good. Back out lockdown screws. Pull up hole 17.6'. Close pipe/slip rams and bleed off psi. Nipple down riser and walk injector up. Manually release GS spear from hanger. Hanger seals are gone, but no apparent damage or marks on hanger. Redress hanger with new seals. Make hanger assembly up io grapple and latch up with GS spear. Walk injector back down to BOPE stack and flange up riser. P/U to 19k, equalize psi and open pipe/slips. RIH and land hanger in coil spool. Run in lock down screws and pull test agaist screws. PT hanger, failed again. PSI up coil w/ N2 and release GS from hanger. Pull GS into riser, shut swab. Bleed off WHP, put injector on cradle. Secure well and location for night. Turn in permit. Obtain HOT work permit, review JSA and job scope for rig up and daily operation. Pick up injector and m/u 3.82" cetralizer and 3" GS spear. PT stack to 1000 psi. Printed: 12/27/2007 2:18:48 PM • Marathon Oil Company Page 9 of s Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: WORKOVER Start: 10/3!2007 End: Contractor Name: GLACIER DRILLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 11/17/2007 10:00 - 11:00 1.00 ENGAG FISH CTBG Open swab, rih and latch into hanger. Pull test GS spear, good. Back out lodcdown screws. Pull up hole 17.6'. Close pipe/slip rams and bleed off psi. 11:00 - 12:30 1.50 NUND EQIP CTBG Nipple down riser and walk injector up. Manually release GS spear from hanger. Hanger seals are gone, but no apparent damage or marks on hanger. Redress hanger with new seals. Make UP hanger assembly to grapple and latch up with GS spear. (NOTE: Tested mandrel by running in and out of T' x 4" riser x-over with no damage to seals.. Also insured that mandrel is 3.995" O.D.) 12:30 - 12:50 0.33 NUND EQIP CTBG Walk injector back down to BOPE stack and flange up riser. P/U to 19k, equalize psi and open pipe/slips. 12:50 - 13:00 0.17 RUNPU COIL CTBG RIH and land hanger in coil spool. Run in lock down screws and pull test agaist screws. 13:00 - 13:30 0.50 TEST_ EQIP CTBG PT han er failed a ain. 13:30 - 14:15 0.75 WAITON OTHR CTBG S/D job while Expro arms setting tool,. meanwhile discuss options some more. 14:15 - 14:35 0.33 PUMP_ N2_ CTBG Expro finished arming, warm up N2 unit. 14:35 - 14:45 0.17 PUMP_ N2_ CTBG Psi up on GS with N2 to 1200 psi and 5k down wt. Release from hanger, PUH and close swab. 14:45 - 15:15 0.50 NUND EQIP CTBG N/D riser, pick up injector. M/U improvised dummy drift mandrel, yo back to well, n/u riser. Open well, rih slowly looking for wt. bobble indicating bad spot in WH. 15:15 - 15:45 0.50 NUND EQIP CTBG At -8.6', see good wt. bobble,. PUH into riser, shut swab, N/D riser. Remove dummy drift mandrel. 15:45 - 16:15 0.50 ENGAG FISH CTBG Open swab, rih and latch into hanger. Pull test GS spear, good. Back out lockdown screws. Pull up hole 17.6'. Close pipe/slip rams and bleed off psi. 16:15 -17:35 1.33 NUND EQIP CTBG N/D riser, laydown 4' spacer pipe and original hanger, miu new hanger to grapple and n/u riser. 17:35 - 17:50 0.25 TEST_ EOIP CTBG Equalize psi, pull string wt., and open pipe/slips. 17:50 - 17:55 0.08 RUNPU. EQIP CTBG RIH and land hanger, run in lockdown screws. 17:55 - 18:10 0.25 TEST_ EOIP CTBG PT han er to 5k for 15 min. GOOD TEST! 18:10 - 18:30 0.33 RUNPU EQIP CTBG Release GS from hanger, pull up into riser. Shut swab, bleed off n2 from coil. WHP=860psi. 18:30 - 18:45 0.25 RURD_ COIL CTBG Pop off well, set injector on cradle 18:45 - 19:00 0.25 SECUR WELL CTBG Secure well and location for night. Turn in permit. 11/20/2007 07:30 - 08:00 0.50 SAFETY MTG CTBG Obtain HOT work permit, review JSA and job scope for rig up and daily operation. Printed: 1212712007 2:18:a8 PM • M Marathon MARATHON Oil Company December 14, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Ninilchik Unit Well: Grassim Oskolkoff #3 ~t~G~,h~~~ ~~ E ~ ~ ~ 2407 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~ ~F:C ~ ~ ~~~r~ iaska Oil ~ L „ ,~,;a. Attached for your records is the 10-404 Sundry Report for GO-3 well. This sundry covers the Tyonek zone reperforating work that Marathon completed under sundry #307-320. The well is not presently flowing due to loading issues. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ` ~~ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report Operations Summary Well Schematic cc: Houston Well File Kenai Well File KJS KDW (~~ -~~. STATE OF ALASKA ~a/~D,? ALA OIL AND GAS CONSERVATION COMr~ION REPORT OF SUNDRY WELL OPERATIONS ~-~ ~ ~ ~~~% AE I__R_~ dt'a rz r°e _ 1. Operations Abandon Repair Well Plug Perforations Stimulate ~' ' " Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ ~,,,,~~tt-- Waiver^ Time Exte~S~tin~`'t Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: - ame: Development ~ ^ Ex Iorato p ry ^ 204-255 3. Address: Stratigraphic ^ Service ^ 6. API Number: , PO Box 1949, Kenai Alaska, 99611-1949 50-133-20548-00-00 7. KB Elevation (ft): 9. Well Name and Number: 21' Grassim Oskolkoff #3 8. Property Designation: ~' 10. Field/Pool(s): ADL 384305 /ADL 389180 ~ Ninilchik Unit / Tyonek Pool 11. Present Well Condition Summary: Total Depth measured 13,711' feet Plugs (measured) NA true vertical 8,147' ~ feet Junk (measured) NA Effective Depth measured 13,633' feet true vertical 8,019' feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 99' 20" 99' 99' 3,060 psi 1,500 psi Surface 2,507' 9-5/8" 2,507' 1,772' 5,750 psi 3,090 psi Intermediate 7,320' 7" 7,320' 3,424' 7,240 psi 5,410 psi Production 0 0 0 0 0 0 Liner 6,701' 4-1/2" 13,750' 8,127' 8,430 psi 7,500 psi Perforation depth: Measured depth: 10,612' - 12,854' Gross True Vertical depth: 5,244' - 7,297' Gross Tubing: (size, grade, and measured depth) 4-1/2" L-80 7,049' Packers and SSSV (type and measured depth) Baker 4-1/2" ZXP 7,049' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 480 1 0 762 Subsequent to operation: 0 600 0 0 784 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations 16. Well Status after work: Oil^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-320 Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Titte Senior Production Engineer Signature Phone (907) 283-1311 Date December 14, 2007 Form 10-404 Revised 04/2006 ~'' ~~ ~~ ~ ' l~~~ ~~ [ ~C Submit Original Only • 204-255 50-133-20548-00-00 es: ADL 384305 /ADL 389180 n: 187' (21' AGL / KB) D D .04.10981. C A P. C M P. 02 229,103.63 2,255,186.000 :ude: 60° 09' 53.0430" N ita ude: 151 ° 29' 14.3564" W d: 1/22/2005 10:30 hrs 2/25/2005 22:00 hrs Released: hrs 4.0 deg/100'from 250-2000' 70 deg from 2000-8090' MD 1.5 deg/100' to 11470' MD 23 deg from 11470' to TD at ' MD 255 deg. GO #3 Ninilchik Unit 3221' FSL & 2914' FEL Sec. 23-T1 N-R13W L l.asmy olnny -YA , ILVM, ~-ou, nr~rn ~.~„ Baker Chemical Injection Nipple @ 2412' MO (Top) 5.930" OD/3.858" ID 8430 psi bursU7500 psi collapse Liner Packer with 15' Tieback Extension @ 7049' MD (Top) Liner Hanger @ 7074' MD (Top) Joints @ 9622-9673' MD (Two 19-20' long) Marker Joints @ 11,691-11,730' MD (Two 19-20' long) Landing Collar @ 13,652' MD (Top) Collar @ 13,885' MD (Top) Shce @ 13,750' MD (Bottom) Cement Top at -10,000' MD Expro Radial Bond Log 2.5/8" Cores: 1.9794'-9875' KB (Cut 81' Recvd 66.9') 2.12,212'-12,301 KB (Cut 89' Recvd 70.15') Tagged PBTD at 13,633' KB with Expro CBLIGR. Cleaned out to 13,570' MD with BJ CT (w/ 3.80" OD centralizer) Formation Tops: Formation Depth (MD) Depth (TVD1 Beluga Tyonek TD M MARATIiOM Conductor 20" K-55 133 ppf PE Top Bottom M D 0' 99' TVD 0' 99' Surtace Casing 9-5/8" L$0 40 ppf BTC Top Bottom MD 0' 2,507' TVD 0' 1,772' 12-114" hole cmt wl t 519 sks (232bb1s) 12ppg cmt w/ 27 bbls cmt to surface Intermediate Casing 7" L-80 26 ppf BTC Top Bottom MD 0' 7,320' TVD 0' 3,424' 8-1 /2" hole cmt wl 305 sks (134.4 bbls) 12.Sppg Lead & 167 sks (34.7 bbls) 15.8 ppg Tail. Plug did not bump, no cmt to surface, floats held. Liner 4-1/2" L-80 12.75 ppf Hydril 533 Top Bottom MD 7,049' 13,750' TVD 3,331' 8,127' 6-118" hole cmt w/664 sks 12.7 ppg Tail (NO spacer or cmt to surface) Lost partial circulation after pumping 230 bbls cmt Pollard Temp Log indicated TOC @ 10,350' MD before Liner Top Sqz Squeezed Liner Top w/500 sks 12.7 ppg cmt (88 bbl cmt below 12.7ppg) Tvonek Perfs: MD TVD Gun Date 10,612'-10,632, 20 ft 5,244'- 5,261' Owen 3.375" 6 SPF 9/13/2005 10,866'- 10,686, 20 ft 5,467'- 5,484' Owen 3.375" 6 SPF 911 312 0 0 5 10,866'-10,886, 20 ft 5,467'- 5,484' Owen 3.375" 6 SPF 1012912007 11,826'-11,840, 14 ft 6,345'- 6,358' Owen 3.375" 6 SPF 10/2912007 11,830'-11,840, 10 ft 6,349'-6,358' Owen 3.375" 6 SPF 910812005 11,956'-11,972, 16 ft 6,465'- 6,479' Owen 3.375" 6 SPF 1012912007 11,956'-11,973, 17 ft 6,465'- 6,480' Owen 3.375" 6 SPF 910812005 12,223'-12,238, 15 ft 6,712'- 6,726' Owen 3.375" 6 SPF 9/08/2005 12,242'-12,267, 25 ft 6,730'- 6,753' Owen 3.375" 6 SPF 910 712 0 0 5 12,354'-12,398, 44 ft 6,835'- 6,875' Owen 3.375" 6 SPF 9/06&0712005 12,564'-12,586, 22 ft 7,029'- 7,049' Owen 3.375" 6 SPF 9/02/2005 12,564'-12,587, 23 ft 7,029'- 7,050' Owen 3.375" 6 SPF 10/28/2007 12,606'-12,626, 20 ft 7,068'- 7,086' Owen 3.375" 6 SPF 8/31/2005 12,607'-12,636' 29 ft 7,069'- 7,095' Owen 3.375" 6 SPF 10/28/2007 12,626'-12,668, 42 ft 7,086'- 7,125' Owen 3.375" 6 SPF 9/06&0712005 12,636'-12,665' 29 ft 7,095'- 7,122' Owen 3.375" 6 SPF 10/28/2007 12,840'-12,854' 14 ft 7,284'- 7,297' Owen 3.375" 6 SPF 813112005 Well Name & Number: Grassim Oskolkoff #3 Lease: Ninilchik Unit County or Parish: Kenai Penisula Borcugh State: Alaska Country: USA Perforations MD): 10,612' -12,854' TVD): 5,244' - 7,297' Angle/Perfs: Angle @KOP and Depth: KOP (TVD): Date Completed: Completion Fluid: RKB: Prepared By: Kevin Skiba Last Revision Date: 12/14/07 TD: 13,771' MD 8,147' TVD Marathon Oil Company Page 2 of z Operations Summary Report -Per Wefl Legal WeILName: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Date Event Hours Code Sub Phase Event Type --/-- Objective Report Date . From - To Code SideTrack- --/-- Description of Operations 10/298007 07;30--08:30 1.00 SAFETY MTG_ CMPPRF OH --/-- Expro Wireline on location.. Obtain a work permit, held PJSM and discussed operatiohal plan and hazards:. 08:30- 10:10 1,67 RURD ELEC CMPPRF RU eline unit. PU lubricator and lay out tool 1A;10- 10:15 0;08 SAFETY MTG_. CMPPRF Pertorating safety meeting. Shut down all cel phones;ahd post gate guard.(SAFEsystem'does not require SD of SCADA). 10:15 - 10:25 0.17 RURD_ ELEC CMPPRF Armed 29' 3-318" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 29' at 6 SPF; and PX-1 firing head on CCL. 10:25 - 10;30 0.08 TEST__ EQIP CMPPRF Pressure test lubricatorto 2040 psi:. 10:30- 12'10 1.67 RUNPUL ELEC CMPPRF RIH with well flowing at 450 MCF/day at`flowline pressure (750 psi). 12:10 - 12:20 "0.17 PERF_ CSG CMPPRF Correlated depth with CBL andArray Induction logs. Perforated 1263fr12665' MD with 750 psi surface gas pressure with well shut in, Pressure builds at about 4.5 psi/min 12:20 - 13:10 A.83 RUNPUL ELEC CMPPRF POOH with guns to 2000'. Opened well choke steadilywhile POOH with pert gun. 13:10.- 13:30 0:33 RUNPUL ELEC CMPPRF POOH with guns to surface. Bled pressure off of lubricator. LD perf gun. 1:3:30- 13:45 0.25 SAFETY MTG_ CMPPRF Perforating safety meeting. Shut down all cal phones. and poet gate guard. 13:45 - 13:55 0.17 RURD_ ELEC CMPPRF Armed 29' 3-3/8" carrier and took lubricator totree. RIH with 3.375" OD perforating gun loaded 29' at 6 SPF, and PX-1 firing head on CCL. 13:55 -14:00 0.08 TEST__ EQIP CMPPRF Pressure test lubricator quick est sub to 2000 psi. 14:00- 15:15 1.25 RUNPUL ELEC CMPPRF RIH with yell flowing at 500 MCF/day at flowline pressure (750 psi). 15:15 - 15:30 D.25 PERF CSG CMPPRF Correlated depth with CBL and Array Induction logs. Pertorated 12607-12636' MD OH with 750 psi surface .gas pressure u • Printed:. 12!1412007 10:16:52 AM Marathon Oil Company Page 3 of 7 Operations Summary Report -Per Well Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name:: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Date Event Hours Code Sub Phase Event Type •-1-- Objective Report Date From - To Code SideTrack- --/-- Description of Operations 15:15- 15:30 .0.25 PERF_ CSG_, CMPPRF wtth well shut in. Pressure builds at about 5psihttin 15:30 - 16:15 0.75 RUNPUL ELEC CMPPRF POOH with guns to 2000'. Opened well choke steadily while POOH with perf gun. 16:15- 16:30 0.25 RUNPUL ELEC CMPPRF POOH with guns to surtace. Bled pressure off of lubricator. LD perf gun. 16:30 - 16:35 0:08 SAFETY MTG CMPPRF Perforating safety meeting. Shut down all cal phones end post gate guard. 16:35 - 16:45 0.17 RURD_ ELEC CMPPRF Armed 29 3-3I8" carrier and took lubricator to tree. RIH wtth 3.375" OD perforating gun loaded 23' at 6 SPF, and PX-1 firing head on CCL. 16:45- 16:50 0.08 TEST__ EQIP CMPPRF Pressure test lubricatorquick test sub to 2000psi. 16:50- 18:15 1.42 RUNPUL ELEC CMPPRF RIH with well flowing at 520 MCF/day at flowline pressure (750 psi). 18:15- 18:25 0.17 PERF_ CSG_ CMPPRF Correlated depth with .CBL and Array Induction logs: ,Perforated 12564-12587 MD with 750 psi surface gas pressure with well shut'in. 18:25- 18:45 0.33 WORK ELEC CMPPRF Stuck gun. Worked 20 min to free gun.. 18:45- 19:35 0.83 RUNPUL ELEC CMPPRF POOH with guns to 2000'. Opened well choke steadily while POOH with perf gun. 19:35 - 19:.45 0.17 RUNPUL ELEC CMPPRF POOH with guns to surtace. Bled pressure off of lubricator. LD perf gun. Well flowing at 535 M. 19:45 - 20:30 D.75 RURD_ ELEC CMPPRF Rig back for night. 10/30/2007 08:00 - 09:00 1.00. SAFETY MTG_ CMPPRF OH --/-- Expro Wireline on location. Obtain a work. permit, held PJSM and discussed operational plan and hazards. 09:00- 10:30 1.50 RURD_ ELEC CMPPRF PU lubricator and lay out tools. 10:10 - 10:20 0.17 SAFETY MTG_ CMPPRF Perforating safety meeting. Shut down all cell phones and post gate guard.(SAFE system does not require SD of SCADA). 10:20-10:25 0.08 RURD_ ELEC CMPPRF Armed 16' 3-318" carrier and took lubricator totree. RIH wtth 3.375" OD perforating gun loaded 16' at 6 SPF, and PX-1 firing head on CCL. 10:25- 10:30 0.08 TEST__ EQIP CMPPRF Pressure test lubricator to 2000 psi. 10:30 - 11 r50 1.33 RUNPUL ELEC CMPPRF RIH with run #4 well flowing at 560 MCF/day at flowline pressure (750 psi). 11:50 - 12:05 0.25 PERF_ CSG_ CMPPRF Correlated depth with. CBL and Array Induction logs. Perforated 11,956'-11,972' MD with 750 psi surtace gaspressure with well shut in. Pressurebuilds at about 3:5 psi/min 12:05 - 13:02 0.95 .RUNPUL ELEC CMPPRF POOH with guns to 2000'. Opened well choke steadily while POOH with perf gun. 13:02 - 13:10 0.19 RUNPUL ELEC CMPPRF OOH with guns to surtace:.. Bled pressure off of lubricator. LD pert gun. 13;1.0- 13:15 0.08 SAFETY MTG_ CMPPRF Perforating safety meeting: Shut down all cell phones and postgate guard. 13:15- 13:20 0.08 RURD_ ELEC CMPPRF Armed 14' 3-318" carrier and took lubricator to tree, RIH with 3.375" OD perforating gun loaded 14 `at 6 SPF, and PX 1 firing head on'CCL. 13:20 - 1.3:25 0.08 TEST EQIP CMPPRF Pressure testlubricator quick test sub to 2000 psi. 13:25- 14;50 1.42 RUNPUL ELEC CMPPRF RIH with run #5 waif flowing at 559 MCF/day: at fla~aline pressure (750 psi)... 14:50 - 15:05 0.25 PERF_ CSG_ CMPPRF Correlated depth wkh CBL and Arrayinduction logs, Perforated 11,82t'-11.840' MD OH with 750 psi surface gaspressure with well shut in: Pressure builds at about. 5.5 psi/min. 15:05 - 16;00 .0:92 RUNPUL ELEC CMPPRF POOH with guns o 2000'. Opened well choke steadily while POOH with perf gun. 16:00 - 16:15 0.25 RUNPUL ELEC CMPPRF OOH with guns to surface.. Bled pressure off oFiubricator. LD pert gun. 1B:15 - 16:20 0.08 SAFETY MTG_ CMPPRF Perforating safety meeting. Shut down all cell phones and post. gate guard.. 16:20 - 16;30. 0.17 RURD_ ELEC CMPPRF Armed 20' 3-3/8" carrierand took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' at 6 SPF, and PX-1 firing head on CCL. 16:30- 16:35 4.08 TEST_ EQIP CMPPRF Pressure test lubricator quick test sub to 2000 psi. 16:35- 18:00 1.42 RUNPUL ELEC CMPPRF RIH with weltflowing at 678 MCF/day at flowline pressure (750 psi). 18:00- 18:05 0.013 PERF_ CSG_ CMPPRF Correlated depth with CBL and Array Induction logs. Perforated 10;866'-10,886' MD with 750 psi. surface gas pressure with well shut ih. Pressure builds at 5.O psi/min. 18:05- 19:05 1.00 RUNPUL ELEC CMPPRF POOH with guns to 2000'. Opened well choke steadily while POOH with pertgun. • • Printed: 12114!200'7 10:16:52 AM Marathon Oil Company Page 4 of 7 Operations Summary Report -Per Well Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 EvenYDate Event Hours Code Sub phase Event Type --/-- Objective Report Date From - To Code SideTrack- --/-- Description of Operations 17!30!2007 19:05- 19:15 0.17 RUNPUL ELEC CMPPRF OOH with guns to surface. Bled pressure off of lubricator> LD perf gun. Well flowing at 650 M. 19:15- 19:30 0.25 RURD_ ELEC CMPPRF RD. Turn well over to production. 19:30 - RURD ELEC CMPPRF Turn in Permit. Sign out end leave location. C~ • Printed: 12/1412007 10:18:2 AM • M Marathon MARATHON Qil Company November 8, 2007 Alaska Oil & Gas Conservation Commission Attn: Howard Ok1and 333 W. 7`~ Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon GO #3 -API 50-133-20548-00 CONFIDENTIAL Dear Mr. Okland: Alaska Asset Team United States Production Operations P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-499-8504 Fed Ex Enclosed is one CD containing confdential digital core data for the above referenced well, as listed in the attached CD Contents. The digital data includes the following: Summary of Routine Core Analysis Results Digital Photos 9794-9810.4' Digital Photos 9810.5-9828' Digital Photos 9828-9834.35' Digital Photos 9835-9853' Digital Photos 9853-9861.85' Digital Photos 12212-12236' Digital Photos 12236-12256' Digital Photos 12256-12272' Digital Photos 12272-12281' Please note that there is no core description for this core. ~S ~~($ Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead address or fax to 713-499-8504. Thank you, Kaynell Zeman Engineering Tech Enclosure l ~~CEIVED NOVZ3 Received by: 20~~ a - Gas Cons, Commission Date: Anchorage ORIGINAL GO #3 API 50-133-20548-00 CD CONTENTS Confidential ~ , 643 Core Photos 50-133-20548-00 ~` 643_Routine Core Analysis 50-133-20548-OO.xls Directory: G03 Core Photos 50-133-20548-00 12212-12236 wl 50-133-2054$-OO.jpg 12236-12256 wl 50-133-2054$-OO.lP9 12256-12272 wl 50-133-20548-OO.jR9 '12272-12281 wl 50-133-20548-OO.jpg 9794-9810.4_ 50-133-20548-OO.jpg ~ 9810.5-9828_wl 50-133-20548-OO.IP9 !9828-9834.35 wl 50-133-20548-OO.jP9 '9835-9853 wl 50-133-20548-OO.jpg p_'9853-9861.85 ~ 50-133-20548-OO.jP9 Okiand, Howard D (DOA) From: Okland, Howard D (DOA) Sent: Monday, November 05, 2007 9:37 AM To: 'cmcelmoyl@marathonoil.com' Subject: Ninilchik Unit, Grassim Oskolkoff 3 Courtney, I've been going over the well history for Grassim Oskolkoff 3, preparing it for release. I've noted that it was cored. We have received the core chips. We have not received a core description. We have not received a core analysis. Would you please send these reports as soon as possible. TNX Howard PS Temps hovering around freezing. Patiently waiting for the temps to drop into the teens. 1 DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2042550 Well Name/No. NINILCHIK UNIT G OSKOLKOFF 3 Operator MARATHON OIL CO API No. 50-133-20548-00-00 MD 13771 TVD 8147 Completion Date 9/1/2005 Completion Status 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: AI / CS / FE / DN / PD (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ,Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments i'ED C Las 13364 t-ITf"duction/Resistivity 1000 13762 Open 5/16/2005 GR SP Dens Poro Res D~ Plus EOW report, Dir Srvy, , As-Built, Daily Drilling Reports Well Cores/Samples Information: Name Interval Start Stop Sample Set Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~N Daily History Received? ~Y / N Chips Received? ~Y / N Formation Tops ~i N Analysis Y Received? ~~.V..JJ -- - Comments: ~~~~ QJ ., :.~.~~ ~ r wr, ~ v` u ~ ~ < i~ ~ Compliance Reviewed By: ____ __ _.__, _ Date: __~ LJ i ~- ~~Q~~ 0~ Q~Q~~(Q i F,wM..~.~ Ai/a-17~ OIiI aLLSS1 Vrva 333 W. 7th AVENUE SUITE 100 ~T~r COls-7ERQA7'I011T CO1~IIrIISSIOI~T , ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ken Walsh Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 Re: Ninilchik Unit, Tyonek Gas Pool, Grassim Oskolkoff #3 Sundry Number: 307-320 Dear McLaughlin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thi~~~ day of October, 2007 Encl. ,`~ _ '}- o-iz~ .~~ ~~ ~ 2,7~~ STATEA~SKA ~ /D~?o~,0~ Q ~ j j 9 ~ 007 Q/~ ~' ALA OIL AND GAS CONSERVATION COM~SION (~~ ~~ ~ as APPLICATION FOR SUNDRY APPROVALS~Jaska Oil & Gas Cons. Commission 20 AAC 25.280 Snrhnr~nn 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ~ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2.Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: ' Development 0 Exploratory ^ 204255 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20548-00-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: S i i R ? Y ^ O Grassim Oskolkoff #3 - pac ng Except on equired es No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 384305 I ADL 389180 21' Ninilchik Unit / Tyonek Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,71' ' 8,14T - ~ 13,633' 8,019' ~ NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 99' 20" 99' 99' 3,060 psi 1,500 psi Surface 2,507' 9-5/8" 2,507' 1,772' 5,750 psi 3,090 psi Surface 7,320' 7" 7,320' 3,424' 7,240 psi 5,410 psi Intermediate Production 6,701' 4-1 /2" 13,750' 8,127' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,612' - 12,854' Gross 5,244' - 7,297' Gross 41/2" L-80 7,049' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 41/2" ZXP 7,049' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 10/29/2007 Oil ^ Gas ^~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: 10/12/2007 WAG ^ GINJ ^ WINJ ^ WDSPL ^ _ Commission Representative: Tom Maunder Q4T 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Senoir Production Engineer Signature ~ Phone Date ~~~ (907) 283-1311 10/17/2007 l ' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Ir Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~ ~~t `~ ~~ 2007 Subsequent Form Required: ~lO APPROVED BY Approved by: MMISSIONER THE COMMISSION Date: ! ~~~~~. D ~i Form 10-403 Revised 06/2006 ~ 1 - Submit in Duplicate • M Marathon MARATHON Oil Company October 17, 2007 ~ ~. ~ ~ C;~: ~ ~a ;~0~?7 Alaska ~r; <~ i~as tnr~s. ~;mmissioit ~~r~cii~raye Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Ninilchik Unit Well: Grassim Oskolkoff #3 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Marathon is presently working on re-establishing gas flow to verify sufficient production before installing the coil tubing velocity string approved under Sundry #307-198. The well was jetted dry on 10/4/2007 and is currently producing 475 mcf at 765 psi. This is less than the required rate to justify velocity string installation. Marathon requests permission to reperforate some of the existing intervals to make this project economical. The chart below lists the current Tyonek perforation intervals: MD TVD Length 10,612' -10,632' 5,244' - 5,261' 20 ft 10,866' - 10,886' 5,467' - 5,467' 20 ft 11,830' - 11,840' 6,349' - 6,358' 10 ft 11,956' -11,973' 6,465' - 6,480' 17 ft 12,223' -12,238' 6,712' - 6,726' 15 ft 12,242' - 12,267' 6,730' - 6,753' 25 ft 12,354' - 12,398' 6,835' - 6,875' 44 ft 12,564' -12,586' 7,029' - 7,049' 22 ft 12,606' -12,626' 7,068' - 7,086' 20 ft 12,626' - 12,668' 7,086' - 7,125' 42 ft 12,840' - 12,854' 7,284' - 7,297' 14 ft Please contact me at (907) 283-1371 if you have any questions. Sincerely, .~1~~ ~~ Kevin J. Skiba Production Technician Enclosures: 10-403 Sundry Notice cc: AOGCC Operations Procedure Houston Well File Well Schematic Kenai Well File KDW & KJS • • M MARATHON MARATHON OIL COMPANY ALASKA REGION Ninilchik Field Grassim Oskolkoff #3 Reperforation Procedure WBS # Tvonek (10-16-2007) Note: r~,.~,....+~ ,^~ This procedure covers work to reperforate some or all of the perforations currently open in this well. The well is flowing about 450 Mcfd at about 760 psi line pressure. Operations to install a coiled tubing velocity string have been delayed until the production can be increased by reperforating the current intervals. Some or all of the intervals may be perforated to accomplish this goal. 1. PROPOSED TYONEK REPERFORATIONS Surface Wellhead Pressure SBHP 50% DD 60% DD _ Measured Depth TVD (0.469 psilft) 0.96 N2 0.57 gas 12,840-12,854', 14 ft 7284-7297' 3422 psi 1045 psi 1160 psi 12,606-12,626' 20 ft 7068-7086' 3323 psi 1030 psi 1135 psi 12,626-12,668', 42 ft 7086-7125' 3342 psi 1035 psi 1140 psi 12,564-12,586', 22 ft 7029-7049' 3306 psi 1025 psi 1130 psi 12,354-12,398', 44 ft 6835-6875' 3225 psi 1000 psi 1105 psi 12,242-12,267', 25 ft 6730-6753' 3169 psi 990 psi 1085 psi 12,223-12,238', 15 ft 6712-6726' 3154 psi 990 psi 1085 psi 11,956-11,973', 17 ft 6465-6480' 3039 psi 975 psi 1050 psi 11,830-11,840', 10 ft 6349-6358' 2982 psi 965 psi 1030 psi 10,866-10,886', 20 ft 5447-5467' 2564 psi 895 psi 905 psi 10,612-10,632', 20 ft 5244-5261' 2478 psi 890 psi 880 psi REPERFORATE TYONEK: RU Expro wireline service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Hold safety and environmental awareness meeting. Blow nitrogen pressure down to 1000 psi WHP while running in the hole with the first perforating gun. PU and RIH with CCL and 3.375" HSD guns loaded 6 SPF 60 degree-phased with SDP-3125-311 NT3 charges and PX-1 firing head. API target pen`ormance is 0.36" entrance hole and 40.25" penetration. Max gun swell in air is 3.625" OD. Correlate depth to Expro CBL/GR/CCL log. Perforate 12,840'-12,854' MD. Continue reperforating Tyonek intervals from the bottom of the well up as outlined above observing 50% perforating drawdown limits. Add perforations as needed to exceed minimum flow rate necessary to unload fluids from the wellbore and meet gas sales objective. 2. FLOW TEST WELL TO SALES. 3. PREPARE TO INSTALL CT VELOCITY STRING per separate procedure. CJ Page 2 of 2 CONTACTS Ken Walsh: 907-283-1311 (w) 907-394-3060 (c) Scott Szalkowski: 713-296-3390 (w) 713-301-9834 (c) Lyndon Ibele: 907-565-3042 (w) Clyde Scott: 713-296-2336 (w) 907-748-2819 (c) Ninilchik Operators: 907-260-7660 or 907-567-3248 (Susan Dionne Pad) KGF Operators: 907-283-1305 GO #3 Tyonek Completion Procedure KDW - 10/16/2007 2:06:04 PM • KOP @ 250' MD/TVD Build 4.0 deg/100' from 250-2000' Hold 70 deg from 2000-8090' MD Drop 1.5 deg/100' to 11470' MD Hold 23 deg from 11470' to TD at ' MD Azimuth: 255 deg. GO #3 Ninilchik Unit 3221' FSL 8 2914' FEL Sec. 23-T1 N-R13W r Chemical Injection Nipple @ 2412' MD (Top) 5.930' OD/3.858" ID 8430 psi bursU7500 psi collapse Liner Packer with 15' Tieback Extension @ 7049' MD (Top) Lock Liner Hanger @ 7074' MD (Top) er Joints @ 9622-9673' MD (Two 19-20' long) er Joints @ 11,691-11,730' MD (Two 19-20' long) ing Collar @ 13,652' MD (Top) Collar @ 13,685' MD (Top) Shoe @ 13,750' MD (Bottom) Radial Bond Log PBTD at 13,633' KB with Expro CBL/G R. out to 13,570' MD with BJ CT (w/ 3.80" OD centralizer) TD: 13,771' MD / 8147' TVD Formation Tops: Formation Deoth (MD1 Deoth (TVD) Beluga Tyonek TD • M MARATNOM Conductor 20" K-55 133 ppf ToQ Bottom M D 0' 99' TVD 0' 99' PE Surface Casino 9-5/8" 40 ppf L-80 BTC T~ Bottom MD 0' 2507' TVD 0' 1772' 12-1I4" hole with 519 sks (232 bbls)12 ppg cement with 27 bbls cement to surface. 12-5/8"Cores: 1.9794'-9875' KB (Cut 81' Recvd 66.9') 2.12,212'-12,301 KB (Cut 89' Recvd 70.15') Intermediate Casino 7" 26 ppf L$0 BTC T~ Bottom MD 0' 7320' TVD 0' 3424' 8-1 /2" hole with 305 sks (134.4 bbls) 12.5 ppg Lead + 167 sks (34.7 bbls)15.8 ppg Tail Plug did not bump, no cement to surface, floats held Tvonek Perfs: MD TVD Gun Date 10,612-10,632, 20 ft 5244-5261' Owen 3.375" 6 SPF 9/13/2005 10,666-10,886, 20 ft 5467-5467' Owen 3.375" 6 SPF 9/13/2005 11,830.11,840, 10 ft 6349-6358' Owen 3.375" 6 SPF 9/08/2005 11,956-11,973, 17 ft 6465-6480' Owen 3.375" 6 SPF 9/08/2005 12,223-12,238, 15 tt 6712-6726' Owen 3.375" 6 SPF 9/08/2005 12,242-12,267, 25 ft 6730-6753' Owen 3.375" 6 SPF 9/07/2005 12,354-12,398, 44 ft 6835-6875' Owen 3.375" 6 SPF 9/06807/2005 12,564-12,586, 22 ft 7029.7049' Owen 3.375" 6 SPF 9/02/2005 12,606.12,626, 20 ft 7068.7086' Owen 3.375" 6 SPF 8/31/2005 12,626-12,668, 42 ft 7086-7125' Owen 3.375" 6 SPF 9/06807/2005 12,840.12,854, 14 ft 7284-7297' Owen 3.375" 6 SPF 8/31/2005 Liner 4-1 /2" 12.75 ppf L$0 Hydri1533 T_g Bottom MD 7049 13750 TVD 3331 8127 6.1/8" hole with 664 sks 12.7 ppg (No spacer or cement to surface) Lost partial circulation after pumping 230 bbls cement Pollard Temp Log indicated TOC at 10350' MD before Liner Top Squeeze Squeezed Liner Top with 500 sks 12.7 ppg cement (88 bbls cement below 12.7 ppg) GO-3: 10-403 Reperforation S~dry Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 16, 2007 3:16 PM To: 'Skiba, Kevin J.` Cc: Walsh, Ken Subject: RE: GO-3: 10-403 Reperforation Sundry Thanks Kevin. I understand that you were out of the office. Tom From: Skiba, Kevin J. [mailto:kskiba@marathonoil.cam] Sent: Tuesday, October 16, 2007 3:05 PM To: Maunder, Thomas E (DOA) Cc: Walsh, Ken Subject: GO-3: 10-403 Reperforation Sundry Tom, Page 1 of 2 ._--- ~~~-~-. This is a follow up to our phone conversation about the 10-403 Sundry for reperforating GO-3 well. As I stated, t am presently working on this Sundry and will be getting it out to you soon. Thank you for your cooperation, Kevin Slaba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 From: Maunder, Thomas E (DOA) [mailtoaommaunder@alaska.gov} Sent: Friday, October 12, 2007 3:55 PM To: Walsh, Ken Subject: RE: GO #3: PTD #204-255 Ken, I spoke with Commissioner Seamount and he has given you oral approval to proceed. However, a 403 will need to be submitted on Monday. Good luck getting the well "in". Tom Maunder, PE AOGCC From: Walsh, Ken [mailto:.kdwal_sh@marathonol.com] Sent: Friday, October 12, 2007 3:39 PM 10/16/2007 GO-3: 10-403 Reperforation S~dry • Page 2 of 2 To: Maunder, Thomas E (DOA) Cc: Cissell, Wayne E,; Donovan Jr, Dennis M.; Grant, Patrick; Ibete, Lyndon; Mullin, Mickey; hang, Craig L.; Skiba, Kevin J.; Sulley, Michael; Walsh, Ken Subject: GO #3: Pl"D #204-255 Tom, Marathon is currently in the middle of work to jet the GO #3 we11 in to re-establish gas flow before installing a coiled tubing velocity string under Sundry Approval #307-198. We have jetted the we{{ dry but are having difficulty obtaining a gas production rate worthy of installing the v-string. The rate is currently at 350-400 Mcfd at sales line pressure of 760 psi. At this point, Marathon requests permission to reperforate some of the existing intervals that have been perforated in this well to increase production prior to running the velocity string. Can we do this without filing a 10-403 but file a 10-404 per our recent discussions? The current Tyonek perforations are listed below and in the attached wellbore diagram. Picture (Enhanced Metaiile] «GO #3 Wellbore Diagram.xls» Regards, ~~ Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) 10/16/2007 GO #3: PTD #204-255 ~ Page 1 of 2 Maunder, Thomas E (DOAj From: Maunder, Tharnas E (DOA) Sent: Friday, October 12, 2007 3:55 PM Ta: Walsh, Ken a~ ~ _ ~~ Subject: RE: GO #3: PTD #204-255 Ken, I spoke with Commissioner Seamount and he has given you oral ap rovai to proceed. However, a 403 will need to be submitted on Monday. --# 1>,.54:~~c~, cgr~c..~~ ~~ ~D/I ~ Good luck getting the well "in". Tom Maunder, PE taa,~•c,~c bEcr.orvc~c~or.~ilWp~~ AOGCC ~c~-~-hOr ~ ~J~ cs S S Opr c~5 ~~ ~ L~ From: Walsh, Ken [mailto:kdwalsh@marathonoiLcom] Sent: Friday, October 12, 2007 3:39 PM Ta: Maunder, Thomas E (DOA} Cc: Cissell, Wayne E.; Donovan Jr, Dennis M.; Grant, Patrick; Ibele, Lyndon; Mullin, Mickey; Rang, Craig L.; Skiba, Kevin J,; Salley, Michael; Walsh, Ken Subject: GO #3: PTD #204-255 Tom, Marathon is currently in the middle of work to jet the GO #3 well in to re-establish gas flow before installing a coiled tubing velocity string under Sundry Approval #307-198. We have jetted the well dry but are having difficulty obtaining a gas production rate worthy of installing the v-string. The rate is currently at 350-400 Mcfd at sales line pressure of 760 psi. At this point, Marathon requests permission to reperforate some of the existing intervals that have been perforated in this well to increase production prior to running the velocity string. Can we do this without filing a 10-403 but file a 10-404 per our recent discussions? The current Tyonek perforations are listed below and in the attached wellbore diagram. ` T;aash F'b tYt: M6 TVO pun Cass 70,972.10,88 2B 7'E 64446297' o:ren 8.876^9 BPF B778f1B9i 19,898-19,889, 3Y tk 6#67.6487' O^an 8.876°8 BPF 817872886 tt,ss9-t+,s49, 791! 984Ba868' pr.'Ba8.s76°9 ePF BAa7299s 17,869-11,878, 1T tt 9496489' p::•Bn8.87i°9 BPF BASI2996 @,228-74,28$ ti 1'k 9714-9738' Oa sn 8.876"8 ~F BA872886 72,242_72,297, 2611 97888768' p:asa 1.871°8 8PF BA772B06 12,564-72,888, d41k 9886~T6' O:'sp 8.8T6"9 BPF BAB60fABB6 7R.6B4-12.889. 421! 7828.7848' O.': Ba 8.876"9 BFf BA272986 72,988-12,929, 2B tE 7098.7988' p::'sa8.876"A BFF 881 12,929-72,998, 427E 7989)726' o:'sp S.ST6"9 BPF BA9i87R806 72,849-14,864, 1411 T484J2BT' Orin 8.871°9 BPF 81811!891 «GO #3 Wellbore Diagram.xts» Regards, ~~ Ken D. Walsh i of22i~oo~ 17 ~ fA~ ~_~ ~ I E.,~ - SARAH PAL/N, GOVERNOR Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611 ~~ Oaay ~ ~ 333 W. 7th AVENUE, SUITE 100 C011TSER~'ATI011T C011i1-IISSIOR ~ ANCHORAGE, ALASKA 99501-3539 r PHONE (907) 279-1433 FAX (907) 278-7542 Dennis Donovan Re: Ninilchik Unit, 'I~onek Gas Pool, Grassim Oskolkoff #3 Sundry Number: 307-198 Dear Mr. Donovan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907j 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commissian grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on_the 23rd day .following the date of-this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of June, 2007 Encl. av~ -ass" STATE OF ALASKA ~~ ~ fJ~ 6 ~~~ ALA OIL AND GAS CONSERVATION C M ~ ON ~` J~~ ~ ~ ~~~~ APPLICATION FOR SUNDRY APPROVALS ,`~ 20 AAC 25.2so ~i~ska tlii ~ Gas ~©n~. ~~mmission 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ ' Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ V-String Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Com an Development ^ Exploratory ^ 204-255 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611 50-133-20548-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Ninilchik Unit, Grassim Oskolkoff # 3 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 384305 /ADL 389180 21' Ninilchik Unit/Tyonek Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,711' 8147 13,633' 8019' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 99' 20" 99' 99' 3060 psi 1500 psi Surface 2507' 9-5/8" 2507' 1772' 5750 psi 3090 psi Intermediate 7320' 7" 7320' 3424' 7240 psi 5410 psi Production Liner 6701' 4-1/2" 13750' 8127' 8430 psi 7500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10612'-12854' Gross 5244'-7297' Gross 4-1/2" L-80 7049' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 4-1/2" ZXP 7049' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ^~ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: 1-Jul-07 Commencing Operations: Oil ^ Gas ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Dennis Donovan Title Production Engineer Signature Phone (907) 283-1333 Date 8-Jun-07 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~~ ~ ` ~„~ e ~~~~.~ ~~ ~~~.~ ~ FJF~ ,~~N ~ ®~~~? Subsequent Form Required: ~~~ APPROVED BY Approved by: OMMISSIONER THE COMMISSION Date: ~~ Form 10-403 Revised 06/2006 ~ ~ Submit in Duplicate Re: Marathon Grassim Oskollcoff 3 Operatio Subject: Re: Marathon Grassim Oskolkoff 3 Operations From: Thomas Maunder <tom_maundernadmin.state.ak.us> Date: Wed, 10 Jan ?007 15:02:46 -0900 To: "C'onrith, Bcs Anne" ~"bcor~~~~ithr~i~~m~irathonoil.com=~ Thanks Bess Anne. This should do the trick. Similar information should be included in all future completion reports. Call or message with any questions. Tom Maunder, PE AOGCC Corwith, Bess Anne wrote, On 1/10/2007 1:10 PM: Tom, Here is an Excel file with the drilling and completion operations for Marathon's Grassim Oskolkoff 3. Please let me know if this is what you need, or if there is something else that we need to provide. «GO 3 Operations for AOGCC.ZIP» Marathon Oil Alaska -Anchorage Office Office: 907-565-3034 Cell Phone: 907-529-2989 1 of 1 1/18/2007 10:00 AM Re: G.O. #3 (204-255) Subject: Re: G.O. #3 (204-255) From: Thamas Maunder <tom_maunder c~adnlin.state.ak.us> Date: Wed, 10 Tan ?007 12:23:04 -0900 To: "~~Valsh, Ken" <l;O~~~al~l~r~r::maralhonoil.c~~m= Thanks Ken. Walsh, Ken wrote, On 1/10/2007 12:12 PM: Tom, I will make arrangements to have this information sent to your office and your attention. Ken Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) -----Original Message----- From: Thomas Maunder [mailto:tom ma.u=~de.r~~admi.n.state.ak.usJ Sent: Tuesday, January 09, 2007 2:47 PM To: Walsh, Ken Cc: Art Saltmarsh Subject: G.O. #3 (204-255) Ken, I was looking into our files on this well and it appears that the drilling summary submitted with the Form 407 is not complete. It is indicated that the well was spudded on 1/17/05, but the first daily listed on the operations report is March 1, 2005. Would you please send in the reports for operations prior to March 1. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 1/18/2007 10:00 AM • M Marathon MARATHON Oit Company September 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Ninilchik Unit/Tyonek Pool Well: Grassim Oskolkoff # 3 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 We propose to run a 1.75" velocity string in GO #3. We anticipate improving the ability of the well to unload water and to increase production. Please find a 10-403, operations program, wellbore diagram, and proposed wellbore diagram attached. If you have any questions or need further information please call me at (907) 398-1362. Sincerely, Dennis Donovan Production Engineer Enclosures: 10-403 Sundry Notice cc: AOGCC Operations Procedure Houston Well File Well Schematic Kenai Well File Proposed Well Schematic DMD KJS • • M MARATHON MARATHON OIL COMPANY ALASKA REGION Ninilchik Unit/Tyonek Pool Ninilchik Unit, Grassim Oskolkoff # 3 2007 CT Velocity String Hangoff Procedure Notes: This procedure covers work to install a 1.75" OD coil tubing velocity string to alleviate liquid loading. • Contact Vetco prior to MIRU to verify maximum hanger head 1D & mandrel OD measurements. BJ CoilTech supervisor will drift all WH connections prior to rig up to insure drift lD of individual connections. 1. Obtain Real-time Flowing Temperature-Pressure Survey. Make arrangements with the Operator to blow down well to unload fluid the day before this survey work is to be done. MIRU Expro wireline. Hold PJSM. Roundtrip a gauge ring with junk basket to tag top of fill in the production liner. RIH with CCL and 1-11/16" real-time Spartec pressure-temperature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to tag fill. Correlate depth and POOH logging to about 100' above fluid level. POOH taking 3 min benches every 500'. RDMO Expro Wireline. 2. Install Coil Tubing Head. 3. Make flowline modifications for coil tubing velocity string. Plumb in and test annular flow fine with a new 5K choke and ball valve to existing flowline. 4. MIRU MOC flow back equipment including open-top flowback tank, choke skid, gas buster, and flow back iron. MIRU closed-top 500 bbl Rain-for-Rent fluid supply tank. Lay liner and berm area around tank. Load fluid supply tank with 6% KCI and heat as necessary. Deliver diesel fuel manlift and two light plants. Remove well house and lock out electrical connections. 5. MIRU BJ coiled tubing unit with BJ work string (if needed to clean out fill) and Maration velocity string on reel. Rig up fluid and N2 pumps. RU pumping iron and flow back iron. 6. Nipple up BJ CT wellhead assembly (WHA). Dual-Combi BOP (dressed for 1-3/4" CT). Function test BOP. Stab 1-3/4" CT into injector. Install BJ coil tubing connector and pull test to 15,000 lbs. Nipple up injector to WHA. 7. Pressure test surface lines and CT eauipment with 6% KCL water. Pressure test pump iron (200 low/4500 high psi). Pump fluid to load CT. Pressure test CT, WHA and flow back iron to choke manifold (200/4500 psi). Pressure test BOP rams (200/4500 psi). Purge pressure test fluids w/ N2 to flowback tank and vent N2 pressure to flowback tank. "~-" 8. Cleanout fill in wellbore. (ONLY IF FILL IN WELL IS COVERING PERFORATIONS) MU BJ CoilTech. Pull BHA into lubricator and take to wellhead. RIH with BHA and clean out fill to TD or Specified Running Depth with 6% KCL water and 500 scfm of nitrogen. Quit pumping KCL water and RIH with CT unload fluid from well with nitrogen to the flowback tank. POOH and LD cleanout BHA. 9. MU CT BHA. Nipple injector off W HA. MU velocity string BHA to end of CT. • • Page 2 of 2 10. Nipple up infector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next Step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 11. RIH with coil tubing velocity string and BHA with well flowing to sales up Tubing-Coil Tubing annulus. 12. Cut coil tubing. PUH to span WHA for final landing depth. Set CT in BOP tubing/slip rams. Lock tubing/slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams,to the flowback tank. Nipple injector off of WHA. Walk injector up CT. Install C plate above BOP and polish rod clamp on CT. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 13. MU Vetco Coil Tubing Hanger and Baker GS Running Tool. Swing Injector and lubricator away from WH. Vetco to connect VGCT Coil Tubing Hanger. While Vetco is making up CT hanger, BJ CoilTech to connect Baker GS tool string assembly to coil on reel trailer. Pull test CT connector to 25,000 lbs. Latch GS spear to Vetco mandrel after PU injector. 14. RIH and land Vetco CT hanger per Vetco procedures. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten Lock Screws. Pressure test hanger between O-rings to 5000 psig with hand pump pressure test unit (Vetco Supplied). Tighten Lock Screws. 15. Release 3" GS Running Tool. Sit down weight on Hanger. Start pumping 6% KCL water at approximately 2 BPM through CT to release GS spear. Watch for weight change to verify release and pickup to unlatch spear. Stop pumping when spear is unlatched and above mandrel. 16. Purge KCL water from CT remaining on reel trailer with nitrogen. Allow N2 to vent to flowback tank. Pressure Up CT with N2 to remove shear plug and aluminum pump-off plug off the end of the CT. Pressure up CT string until shear down plug and aluminum pump-off plug release and fall down hole. 17. Purge N2 from CT remaining in the well. Allow N2 to vent to Flowback tank. Have a gas meter onsite to monitor LEL. Once methane is detected send production to sales. 18. FLOW TEST WELL TO SALES. 19. RDMO and release equipment. RD flowback iron. Release tanks and all rental equipment to vendors. • Permit # 204-255 GO #3 Ninilchik Unit 3221' FSL & 2914' FEL ~TMON Sec. 23-T1 N-R13W r Chemical Injection Nipple @ 2412' MD (Top) 5.930" OD/3.858" ID 8430 psi burst/7500 psi collapse Liner Packer with 15' Tieback 6ttension @ 7049' MD (Top) Lock Liner Hanger @ 7074' MD (Top) er Joints @ 9622-9673' MD (Two 19-20' long) er Joints @ 11,691-11,730' MD (Two 19-20' long) ing Collar @ 13,652' MD (Tap) Collar @ 13,685' MD (Top) Shoe @ 13,750' MD (Bottom) Expro Radial Bond Log out to 13,570' MD with BJ CT (w/ 3.80" OD centralizer) TD: 13,771' MD / 8147' TVD Formation Tops: Formation Depth (MD) Depth (TVD) Beluga Tyonek TD Conductor 20" K-55 133 ppf PE TO~1 Bottom M D 0' 99' TVD 0' 99' Surface Casino 9-5/8" 40 ppf L-80 BTC T~ Bottom MD 0' 2507' TVD 0' 1772' 12-1 /4" hole with 519 sks (232 bbls) 12 ppg cement with 27 bbls cement to surface. 2.5/8" Cores: 1.9794'-9875' KB (Cut 81' Recvd 66.9') 2.12,212'-12,301 KB (Cut 89' Recvd 70.15') Intermediate Casing 7" 26 ppf L-80 BTC T~ Bottom MD 0' 7320' TVD 0' 3424' 8-1/2" hole with 305 sks (134.4 bbls) 12.5 ppg Lead + 167 sks (34.7 bbls)15.8 ppg Tail Plug did not bump, no cement to surface, floats held MD TVD Gun Date 10,612-10,632, 20 ft 5244.5261' Owen 3.375" 6 SPF 9/13/2005 10,866-10,886, 20 ft 5467-5467' Owen 3.375" 6 SPF 9/13/2005 11,830-11,840, 10 ft 6349-6358' Owen 3.375" 6 SPF 9/08/2005 11,956-11,973, 17 ft 6465-6480' Owen 3.375" 6 SPF 9/08/2005 12,223-12,238, 15 ft 6712.6726' Owen 3.375" 6 SPF 9/08/2005 12,242-12,267, 25 ft 6730-6753' Owen 3.375" 6 SPF 9/07/2005 12,354-12,398, 44 ft 6835-6875' Owen 3.375" 6 SPF 9/06807/2005 12,564-12,586, 22 ft 7029-7049' Owen 3.375" 6 SPF 9/02/2005 12,606-12,626, 20 ft 7068-7086' Owen 3.375" 6 SPF 8/3112005 12,626-12,668, 42 ft 7086-7125' Owen 3.375" 6 SPF 9/06807/2005 12,840-12,854, 14 ft 7284-7297' Owen 3.375" 6 SPF 8/31/2005 Liner 4-1 /2" 12.75 ppf L-80 Hydril 533 TOE Bottom MD 7049 13750 TVD 3331 8127 6-1/8" hole with 664 sks 12.7 ppg (No spacer or cement to surface) Lost partial circulation after pumping 230 bbls cement 70 deg from 2000-8090' MD 1.5 de91100'to 11470' MD 23 deg from 11470' to TD at ' MD 255 deg. Chemical Injection Nipple @ 2412' MD (Top) 5.930" OD/3.858" ID 8430 psi burst/7500 psi collapse Liner Packer with 15' Tieback Extension @ 7049' MD (Top) Flex-Lock Liner Hanger @ 7074' MD (Top) Marker Joints @ 9622-9673' MD (Two 19-20' long) Marker Joints @ 11,691-11,730' MD (Two 19-20' long) Landing Collar @ 13,652' MD (Top) Collar @ 13,685' MD (Top) Float Shoe @ 13,750' MD (Bottom) Expro Radial Bond Log ~BTD at 13,633' KB with Expro CBLIGK. out to 13,570' MD with BJ CT (wl 3.80" OD centralizer) PROPOSED GO #3 Ninilchik Unit 3221' FSL & 2914' FEL ~w-nioM Sec. 23-T1 N-R13W TD: 13,771' MD 18147' TVD Liner 4-112" 12.75 ppf L-80 Hydril 533 T~ eottom MD 7049 13750 TVD 3331 8127 6-118" hole with 664 sks 12.7 ppg (No spacer or cement to surface) Lost partial circulation after pumping 230 bbls cement Conductor 20'• K-55 133 ppf PE T_~ Bottom MD 0' 99' TVD 0' 99' Surface Casing 9-518" 40 ppf L-80 BTC TDB Bottom MD 0' 2507' TVD 0' 1772' 12-114" hole with 519 sks (232 bbls) 12 ppg cement with 27 bbls cement to surface. _. _ _ _. .. 2-518" Cores: '.1.9794'-9875' KB (Cut 81' Recvd 66.9') 2,12,212'-12,301 KB (Cut 89' Recvd 70.15') Intermediate Casing 7^ 26 ppf L-80 BTC T~ Bottom MD 0' 7320' TVD 0' 3424' 8-112" hole with 305 sks (134.4 bbls) 12.5 ppg Lead + 167 sks (34.7 bbls)15.8 ppg Tail PIu9 did not bump, no cement to surface, floats held at 12885' MD BHA includes: 2.50" OD X 1.50" ID CT grapple connector, 2.50" OD X 1.50" ID X 10' long box x box straight bar, 1.91" OD X 1.25" PXN (1.135" no-go) profile nipple, and 3.50" OD x 2.50" OD (1.50" ID top box x 2.0" ID bottom) wireline re- Tyonek Perfs: TVD Gun Date MD 612-10,632, 20 ft 10 5244-5261' Owen 3.375" 6 SPF 911312005 , 866-10,886, 20 ft 10 5467-5467' Owen 3.375" 6 SPF 911312005 , 11,830-11,840, 10 ft 6349-6358' Owen 3.375" 6 SPF 910812005 956-11,973, 17 ft 11 6465-6480' Owen 3.375" 6 SPF 910 812 0 0 5 , 223-12,238, 15 ft 12 6712-6726' Owen 3.375" 6 SPF 9108/2005 , 242-12,267, 25 ft 12 6730-6753' Owen 3.375" 6 SPF 9/0712005 , 354-12,398, 44 ft 12 6835-6875' Owen 3.375" 6 SPF 9106807/2005 , 564-12,586, 22 ft 12 7029-7049' Owen 3.375" 6 SPF 9/0212005 , 606-12,626, 20 ft 12 7068-7086' Owen 3.375" 6 SPF 8131/2005 , 626-12,668, 42 ft 12 7086-7125' Owen 3.375" 6 SPF 910680712005 , 12,840-12,854, 14 ft 7284-7297' Owen 3.375" 6 SPF _ 8131/2005 '~~ Marathon MARATHON Oil Company October 17, 2005 Steve McMains AOGCC 333 West 7t" Ave Suite 100 Anchorage, AK 99501 Dear Mr. McMains: Alaska Re ion 9 Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 ~~ a ~ '> r, r , t J~ ~18~~l5 ~;, .a": ~' :;:;. tGTYIs?ttSSltlti ~,r;s,~~ra~~ Attached and submitted for your records is the Form 10-407 completion sundry for the Grassim Oskolkoff #3 well. This well is an active Tyonek gas producer. Also attached for your records is the current well schematic, directional survey, and completion history. If you would like any other information, please contact me at 394-3060 or kdwalsh _marathonoil.com. Sincerely, ~` ~. w~ Ken D. Walsh Senior Production Engineer Enclosures STATE OF ALASKA ~-- ~m ALASKA AND GAS CONSERVATION COMMISS ~ -, ~~ ~~~~ WELL COMPLETION OR RECOMPLETION REPORT AND~~~ 1a. Well Status: Oil Gas ~ Plugged Abandoned 2oAnc2s.ios GINJ^ WINJ^ WDSPL^ No. of Completions Suspended WAG 2oanc2s.>>o Other 1b. Well Cla~~g~~ I ~~'~ ~a:~ ~~ Development ^ ~Ad~~tB~ Service ^ StratigraphicTest^ 2. Operator Name: MARATHON OIL COMPANY 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: 204-255 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 6. Date Spudded: January 22, 2005 13. API Number: 50-133-20548-00 4a. Location of Wei{ (Governmental Section}: Surface: 3,221' FSL, 2,914' FEL, Sec. 23, T1 N, R13W, S.M. 7. Date TD Reached: February 25, 2005 14. Well Name and Number: Ninilchik Unit, Grassim Oskolkoff #3 Top of Productive Horizon: 1,219' FSL, 704' FEL, Sec. 21, T1 N, R13W, S.M. 8. KB Elevation (ft): 187' 15. Field/Pool(s): Ninilchik Unit/Tyonek Pool Total Depth: 919' FSL, 1,906' FEL, Sec. 21, T1N, R13W, S.M. 9. Plug Back Depth(MD+TVD): 13633' + 8019' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 229104 y- 2255186 Zone- 4 10. Total Depth (MD +TVD): 13771' + 8147' 16. Property Designation: ADL 384305 /ADL 389180 TPI: x- 220709 y- 2253273 Zone- 4 Total Depth: x- 219501 y- 2252999 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: 18. Directiona{ Survey: Yes ~ No 19. Water Depth, if Offshore: feet MSL 20. Thickness of Permafrost: 21. Logs Run: Precision Drilling: Array Induction, Compensated Sonic, Focused Electric, Dual Neutron, Photo Density. 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 20' 133 K-55 0' 99' 0' 99' Driven None 9-5/8" 40 L-80 0' 2507' 0' 1772' 12-1/4" 519 sks None 7" 26 L-80 0' 7320' 0' 3424' 8-1/2" 472 sks None 4-1/2" 12.75 L-80 7049' 13750' 3331' $127' 6-118" 664 sxs None 23. Perforations open to Produc tion (MD +TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 12,840-12,854, 14 ft 7284-7297' Owen 3.375" 6 SPF .36" EH 4-1/2" 7049' 7049' 12,606--12,626, 20 ft 7068-7086' Owen 3.375" 6 SPF .36" EH ' " " 12,626-12,668, 42 ft 7086-7125 Owen 3.375 6 SPF .36 EH 12 564-12 586 22 ft 7029-7049' Owen 3 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , , , DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: August 31, 2005 Method of Operation (Flowing, gas lift, etc.): FIOWIn Date of Test: 9/10/2005 Hours Tested: 1/24/1900 Production for Test Period Oil-Bbl: 0 Gas-MCF: 5322 Water-Bbl: 2 Choke Size: 60/64" Gas-Oil Ratio: N/A Flow Tubing Press. 1100 Casing Press: 0 Calculated 24-Hour Rate -..~ Oil-Bbl: 0 Gas-MCF: 5322 Water-Bbl: 2 Oil Gravity -API (corr): N/A 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". Interbedded gas bearing sandstone, shale and coal. Core chips from cores previously supplied. Core depths: 9794-9874 & 11212-12281 MD ~~~~~~rM1 SU 1 ~ s ~~.., Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ ~ 1 ~,J ~ ~ ~ L flTTllSSior 28. GEOLOGIC MARKER 29. RMATION TESTS NAME MD TVD Include and briefly sum a test results. List intervals tested, and attach Beluga 1523 1349 detailed supporting data as necessary. If no tests were conducted, state Tyonek 8112 3700 "None". Attached 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ken D. Walsh Printed Name: Ken D .Wa lsh Title: Senior Production Engineer / ~ ~ ~ 1""~'~ (JLM ~ ~- ~1 Signature: - ~ ( ,. .-. Phone: 907-394-3060 Date: 10/17/2005 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 KeNy 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 verfical 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 Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date -------------- ------------------------------------------ ---------------Activity -•----------------------- Depth ---- --------------------------------------------------- --------------------- 01/18/05 1 12:00 00:00 12.00 MIRU MOB RIG_ AF 61 Accept rig F/SD#4 @ 12:OOhrs 1/17/2005.^ Move in rig and camp. Spot pits, pumps, generator house, boiler house,-water tank, sub base and carrier. Raise sub and level carrier. 01/18/05 1 00:00 06:00 6.00 MIRU MOB RIG_ AF 61 Set up fuel tank. R/U outriggers. Set doghouse and choke house. Set windwalls, stairs, flowline, and poorboy degasser. Prep boiler and fire boiler. Run steam to water tank, pits and pump room. Thaw camp water unit. Take on fuel and water. Fuel support equipment. Set connex and carrier stairs. Drop skirts down on carrier. 01/19/05 2 06:0012:00 6.00 MIRU 01/19/05 2 12:00 00:00 12.00 MIRU 01/19/05 2 00:00 03:00 3.00 MIRU 01/19/05 2 03:00 06:00 3.00 MIRU RURD_ RIG_ AF RURD_ RIG_ AF RURD_ RIG_ AF RURD_ RIG_ AF 61 Remove turbo charger from#1 carrier engine.. Set back windwalls. Set connex, stairs, and flowline. Run electric lines in pitts. 61 R/U panic line, plug in electrical, set in mech shop, parts house, cuttings box, catwalk and beaver slide. Set#3 mud pump and scope up derrick. Thaw ice around rig. R/U shock hoses, carrier tarps and beaver slide. 61 PJSM. P/U top drive rail and hang off. M/U strong back to rail. Hang dog house lights. Hook up #3 mud pump. M/U choke lines to choke and gas buster. 61 PJSM. M/U turnbuckles from top drive rail to .derrick. C/O suction valves and seats on#3 mud pump. R/U #3 pump, 61 P/U top drive and hang. Cont. R/U #3 mud pump. C/O compensator on drillers side. 61 Cont. R/U top drive. C/O saver sub to 4 1/2" 1F and C/O bell guide. Service top drive. R/U bales and elevators. R/U rig floor tongs and spinners. Test drive top drive and pumps. Mix spud mud. Perform rig audit. Install mouse hole and geolograph. R/U 2 VAC trucks to transfer fluid from cellar to shakers. 61 Strap and M/U BHA. MSTD 61 Repair hydraulic leaks on top drive. 61 Drill w/17 112" mill tooth bit. Could not make any hole(TAG hard drilling@59'). 01/20/05 3 06:00 12:00 6.00 MIRU RURD_ RIG_ AF 01/20/05 3 12:00 21:00 9.00 MIRU RURD_ RIG_ AF 01/20/05 3 21:00 23:00 2.00 STRCSG PULD_ BHA_ AF 01/20/05 3 23:00 01:30 2.50 STRCSG REPAIR RIG_ TA 01!20/05 3 01:30 02:30 1.00 STRCSG DRILL_ ROT_ AF Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------- -------- ---------------- --------- ------------- ------------ -Activity ------------- ----------- -Depth_.._. ..--------------•--------------•-------- 01/20/05 3 02:30 03:00 0.50 STRCSG TRIP_ BHA_ AF 61 POOH w/17 1/2" bit. L/D bit(bit had 4 broken teeth and several chiped teeth. 01/20/05 3 03:00 03:30 0.50 STRCSG TRIP_ BHA_ TA CSOT 61 M/U 17 1/2" mill and junk basket. RIH. 01/20/05 3 03:30 06:00 2.50 STRCSG MILL ^ JUNK TA CSOT 61 Mill F/59' to 60'. 01/21/05 4 06:00 07;30 1.50 STRCSG MILL JUNK TA CSOT 61 Mill 20" shoe 50' to 61'. 01/21/05 4 07:30 09:00 1.50 STRCSG MILL_ JUNK AF 90 Mill formation F/61' to 90'. 01/21/05 4 09:00 09:30 0.50 STRCSG TRIP_ BHA_ AF 90 POOH L/D HWDP. 01/21/05 4 09:30 11:00 1.50 STRCSG REPAIR RIG_ TA MSTD 90 Inspect top drive(found crack on drillers side extension arm and sheared bolts on motor). Back out sheared bolts and replace. 01/21/05 4 11:00 13:00 2.00 STRCSG TRIP_ BHA_ AF 90 POOH L/D collars, junk basket and mill 01/21/05 4 13:00 16:00 3.00 STRCSG REPAIR RIG TA MSTD 90 Pull rotary table and repair cracked extention arm. 01/21/05 4 16:00 17:00 1.00 STRCSG RURD_ OTHR AF 90 P/U D-32 Hammer. 01/21/05 4 17:00 19:30 2.50 STRCSG RUN_ CSG_ AF 90 P/U 40' 20" CSG. Weld 20" CSG. 01/21/05 4 19:30 22:30 3.00 STRCSG RUN_ CSG_ AF 90 Weld and Drive 20" CSG. F/61' to 95' RKB. 4 BPF avg to 90' slowed to 12 bpf, 15 bpf, 19 bpf, 34 bpf, 36 bpf@95'(welded on 40' to stub in cellar and drove Joint#1 61' to 75', welded on 20' to stub above rotary and drove Joint#2 75' to 95'). 01/21/05 4 22:30 06:00 7.50 STRCSG WAITON OTHR AF 90 Shut down driving conductor due to high noise in residential ^ area. Will resume driving@07:OOhrs. Peform rig maintenance. 01/22/05 5 06:00 07:00 1.00 STRCSG WAITON OTHR AF 95 Maintenance rig while wait on morning to drive 20". 01/22/05 5 07:00 08:00 1.00 STRCSG DRIVE CSG_ AF 99 PJSM. Drive 20" conductor 95' to 99'(150+BPF). 01/22/05 5 08:00 10:00 2.00 STRCSG DRIVE_ CSG_ AF 99 Cut off 20" conductor and L/D. L/D hammer and power pack. 01/22/05 5 10:00 11:00 1.00 STRCSG RURD_ OTHR AF 99 Install rotary table and fill w/oil. Clear plugged drain valve. 01/22/05 5 11:00 12:30 1.50 SURDRL NUND WLHD AF 99 Install Vetco 20" SLC X 21 1/4" 2M flanged starting head. Test to 400psi. 01/22/05 5 12:30 14:30 2.00 SURDRL RURD_ OTHR AF 99 Install rotary table floor plates and drive chain. Align torque tube^ and install TD elevators. 01/22/05 5 14:30 20:00 5.50 SURDRL NUND BOPE AF 99 Nipple up diverter and function test same. 01/22/05 5. 20:00 23:00 3.00 SURDRL PULD_ DP_ AF 99 Strap, drift, pick up and stand back in derrick 5" drill pipe. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ----------------------------Activity_-------------------------Depth-------------------------------------...------------------------------------- 01/22/05 5 23:00 00:00 1.00 SURDRL TEST_ BOPE AF 99 Perform diverter test for AOGC. Witnessed by Jeff Jones 01/22/05 5 00:00 04:00 4.00 SURDRL PULD_ DP_ AF 99 01/22/05 5 04:00 06:00 2.00 SURDRL PULD_ BHA_ AF 99 01/23/05 6 06:00 09:30 3.50 SURDRL PULD_ BHA_ AF 99 01/23/05 6 09:3010:30 1.00 SURDRL PULD_ BHA_ AF 99 01/23/05 6 10:3011:30 1.00 SURDRL DRILL ROT AF 99 01/23/05 6 11:3012:00 0.50 SURDRL TRIP_ BHA_ TA CSOT 99 01/23/05 6 12:0013:00 1.00 SURDRL TRIP_ BHA_ TA CSOT 99 01/23/05 6 13:0014:00 1.00 SURDRL TRIP_ BHA_ TA CSOT 99 01/23/05 6 14:0015:00 1.00 SURDRL TRIP BHA TA CSOT 99 01/23/05. 6 15:0018:00 3.00 SURDRL MILL_ JUNK TA CSOT 99 01/23/05 6 18:0019:00 1.00 SURDRL TRIP BHA TA CSOT 99 01/23/05 6 19:00 21:00 2.00 SURDRL MILL_ JUNK TA CSOT 99 01/23/05 6 21:00 21:30 0.50 SURDRL TRIP BHA TA CSOT 99 01/23/05 6 21:30 22:00 0.50 SURDRL INSPCT RIG_ TA CSOT 99 01!23!05 6 22:00 23:00 1.00 SURDRL TRIP_ BHA_ TA CSOT 99 01/23/05 6 23:00 23:30 0.50 SURDRL TRIP_ BHA_ TA CSOT 99 01/23/05 6 23:30 00:30 1.00 SURDRL TRIP BHA TA CSOT 99 01/23/05 6 00:30 01:30 1.00 SURDRL TRIP_ BHA_ TA CSOT 99 01/23/05 6 01:30 03:00 1.50 SURDRL DRILL_ ROT_ TA CSOT 130 01/23/05 6 03:00 04:00 1.00 SURDRL TRIP BHA TA CSOT 130 01/23/05 6 04:00 05:30 1.50 SURDRL DRILL_ ROT_ AF 196 01/23/05 6 05:30 06:00 0.50 SURDRL TRIP_ BHA_ AF 196 01/24/05 7 06:00 06:30 0.50 SURDRL TRIP BHA AF 196 Strap and drift and pick up and stand back in derrick 5" drill pipe total of 106 jts. P/U and stand back 5" HWDP. Prep and P/U Dir. BHA. Scribe motor and MWD. Spud well@10:30 hrs 1/22/2005. Clean out conductor F/89' to 91'. (Excessive torque and rough drilling). POOH w/dir assy and rack back BHA. Inspect bit no junk damage. P/U 17 .5" mill assy and junk basket. P/U 17.5" mill and mill F/91' to 93.5'. POOH. Check mill for wear(most wear on outer 2" and gauge of mill. Empty junk basket(1 cup flat metal pieces). RIH w/17.5" mill. Mill F/93.5' to 95.5'. POOH. L/D 17.5" mill(wear on outer2" of gauge) and junk basket(3 cups of flat metal pieces). P/U 14 1/4" mill w/10 3/4"junk basket. RIH. Mill F/95.5' to 99.0'. POOH, L/D Mill assy. (Note mill showed impression of wear in the center and all across the face of mill) junk basket recovered several flat pieces of iron. Service and inspect top drive and derrick. RIH w/ 12 1!4" dir assy(attempt to drill, appears still junk in _. hole). POOH, with dir drilling assy and stand back. MIU and rih with 14" magnet, make two runs to 99' recover small pieces of iron. M/U 12 1/4" bit and two 10 3/4" basket and rih to 99'. Drill F/ 99' to 130' (ART=.50hrs) POOH and lay do junk baskets and bit, Recover several large pieces of iron. Dir drill and survey F/ 130' to 196' (ART=.8hrs). POOH and add NM CSDP. M/U NM CSDP and RIH. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------- ------- ---------------- ---------- ------------- ------------ -Activity ------------- ------------Depth------ -----•--------•-------...---- 01/24/05 7 06:30 03:30 21.00 SURDRL DRILL_ ROT_ AF 1,519 Dir drill and survey F/196' to 1519' (ART=4.7hrs AST=10.0 hrs). 01/24/05 7 03:30 04:00 0.50 SURDRL CIRC_ MUD_ AF 1,519 CBU X 2 (662 GPM. 1537 psi. 75RPM). 01/24/05 7 04:00 06:00 2.00 SURDRL TRIP_ WIPR AF 1,519 Wiper trip to 20" csg(300'@06:OOhrs). 01/25/05 8 06:00 06:30 0.50 SURDRL TRIP_ WIPR AF 1,519 POOH to 165'. 01/25/05 8 06:30 07:00 0.50 SURDRL SERVIC RIG_ AF 1,519 Service rig. 01/25/05 8 07:00 08:00 1.00 SURDRL REPAIR RIG_ TA MSTD 1,519 Replace sheared bolts on top of top drive motor. 01/25/05 8 08:00 09:30 1.50 SURDRL .TRIP_ WIPR AF 1,519 RIH to 1519'. 01/25/05 8 09:30 02:30 17.00 SURDRL DRILL_ ROT_ AF 2,508 Dir drill and survey F/1519' to 2508' (ART= 8.1 hrs AST=5.2hrs) 01/25/05 8 02:30 04:15 1.75 SURDRL CIRC_ MUD_ AF 2,508 CBU X 3 at( 345 SPM, 662 gpm, 1965 psi.)check flo, pump - ` dry job. 01/25/05 8 04:15 06:00 1.75 SURDRL TRIP_ WIPR AF 2,508 Wiper trip to 20" csg. shoe(1500' @ 06:00). 01/26/05 9 06:00 08:00 2.00 SURDRL TRIP_ WIPR AF 2,508 Cont. POOH to 165'(20-25K over F/2400' to 1500'). 01/26/05 9 08:00 08:30 0.50 SURDRL SERVIC RIG_ AF 2,508 Service rig. 01/26/05 9 08:30 11:00 2.50 SURDRL TRIP_ WIPR AF 2,508 RIH to 2508' (Could not pass@1415'. W/R 1415' to 1450'. Could not pass@1659' W/R1650' to 1710'). 01/26/05 9 11:00 12:30 1.50 SURDRL CIRC_ MUD_ AF 2,508 Circ. clean(large quantity of cutting across shakers, CBUX4, 675GPM, 1900psi, 75RPM, Max gas 169units, Static losses .256PH). 01/26/05 9 12:30 14:00 1.50 SURDRL TRIP_ WIPR AF 2,508 POOH to 1000'. 01/26/05 9 14:00 15:00 1.00 SURDRL TRIP_ WIPR AF 2,508 RIH to 2508'. 01/26/05 9 15:00 16:00 1.00 SURDRL CIRC_ MUD_ AF 2,508 Circ. cfean(CBUX3, 680GPM, 1950psi, 77RPM, max gas 59units). Drop carbide showed 10%washout. Flow check. Pump dry job. 01/26/05 9 16:00 18:00 2.00 SURDRL TRIP_ BHA AF 2,508 POOH to Bha. 01/26/05 9 18:00 20:00 2.00 SURDRL PULD_ BHA_ AF 2,508 L/D Bha. 01/26/05 9 20:00 22:30 2.50 SURCSG RURD_ CSG_ AF 2,508 PJSM:Rig up 9 5i8" csg running tools. 01/26/05 9 22:30 02:00 3.50 SURCSG RUN` CSG_ AF 2,508 PJSM: Ran 61 jts. 9 5/8" 40# L 80 BTC Csg (shoe@2507'). 01/26/05 9 02:00 02:30 0.50 SURCSG RURD_ CMT_ AF 2,508 Rig up BJ cmt head. 01/26/05 9 02:30 04:00 1.50 SURCSG CIRC` MUD_ AF 2,508 Circulate and condition mud. (172 SPM. 333 GPM, 525 psi, up100K, do 50K). 100 % Returns. 01/26/05 9 04:00 04:30 0.50 SURCSG PUMP_ CMT_ AF 2,508 PJSM prior to cementing 9 5/8" CSG. Pump 40 bbls 8.5 PPG spacer ahead. Test lines to 2000psi. 01/26/05 9 04:30 05:30 1.00 SURCSG PUMP_ CMT_ AF 2,508 Drop bottom plug. Mix and pump 519SXS Type 1 cement w/18% LW-6, 20% MPA-1, 1 % SMS, .3% CD-32, and 1gphs FP-6L to yield 232bb1s 12.Oppg slurry. Drop top plug and kick out with 5bbls water from BJ. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ------- ----------- --Activity ------------- ------------Depth .---- --------- 01/26/05 9 05:30 06:00 0.50 SURCSG PUMP_ CMT_ AF 2,508 Switch to rig pumps and displace CSG w/178bb1s 9.6ppg mud(max dis. rate 9.56PM). Bumped plug w/1250psi 700psi over last displacement pressure. Bleed back pressure and check floats. Full returns during job w/27bbls cement to surface CIP@06:OOhrs. 01/27/05 10 06:00 13:00 7.00 SURCSG NUND BOPE AF 2,508 Drain stack, flush system ,nipple do diverter 01/27/05 10 13:00 14:00 1.00 SURCSG NUND BOPE AF 2,508 Cut 9 5/8" and drain same. 01/27/05 10 14:00 17:00 3.00 SURCSG NUND BOPE AF 2,508 Set out diverter, remove 20" head, 01/27/05 10 17:00 23:00 6.00 SURCSG NUND WLHD AF 2,508 Final cut on 9 5/8" csg. and N/U Vetco Gray 11" X 5000 Multi bowl wellhead and test same to 2500 psi. Ok. 01/27/05 10 23:00 04:00 5.00 SURCSG NUND BOPE AF 2,508 N/U BOPE, Slow going, (Bad studs on DSA) No acc 01/27/05 10 04:00 06:00 2.00 SURCSG NUND BOPE TA MSBO 2,508 N/U BOPE, Slow going, (Bad studs on DSA) No acc. I '~ (Entry added to classify some of time as trouble due to slow going due to bad studs.) 01/28/05 11 06:00 07:00 1.00 SURCSG TEST_ PLUG AF 2,508 Set test plug and rig up to test BOP's 01/28/05 11 07:00 12:00 5.00 SURCSG TEST_ ROPE TA MSBO 2,508 Test bop's, Rebui{d check valve, Remove hydraulic valve from top drive for repair,Test upper rams, Dart Valve, Choke ,Valves #10-11-12 Test #1, Test #2 Check valve, outside kill, valve# 7-9-8, to 250 /2500 psi high. 01/28/05 11 12:00 16:00 4.00 SURCSG TEST_ BOPE AF 2,508 Test Annular, Upper pipe rams, Blind rams, IBOP, to 250/2500 psi Koomey test. 01/28/05 11 16:00 00:00 8.00 SURCSG TEST_ BOPE TA MSBO 2,508 Attemp to test Lower pipe rams no good, Trouble shoot problem Perform several test and chg variable rams from top to bottom single bop (all test failed to make single ram preventer 5" rams^ block close completely(one side of locks go in 25 112 turns other goes in 23 1/2 turns. ) 01/28/05 11 00:00 06:00 6.00 SURCSG NUND BOPE TA MSBO 2,508 Remove single ram preventer from stack. "Variance" given by Mr Jim Regg /Jeff Jones to drop ~1 single gate. No acc / 14 hrs do time BOPS 01/29/05 12 06:00 07:30 1.50 SURCSG NUND BOPE TA MSBO 2,508 N/U BOP stack, 01/29/05 12 07:30 09:30 2.00 SURCSG TEST_ BOPE TA MSBO 2,508 Test variable rams, blinds, choke line valves to 250 /2500 ok 01/29!05 12 09:30 10:30 1.00 SURCSG TEST_ PLUG AF 2,508 Lay do test plug and run wear bhsg 01/29/05 12 10:30 12:00 1.50 SURCSG NUND BOPE AF 2,508 Nipple up flow line 01/29/05 12 12:00 13:00 1.00 SURCSG TEST_ CSG_ AF 2,508 Pressure test csg. to 2500 psi. for 30 min (good test) Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ------ --------- ---------------- --------- -----•------- -•---•----- --Activity .------------ ------------Depth...... ..---•------------------•-------------•-----•--------•-------...------- 01/29/05 12 13:00 13:30 0.50 SURCSG PULD_ BHA_ AF 2,508 M/U Bha # 12 01/29/05 12 13:30 15:00 1.50 SURCSG TRIP_ BHA_ AF 2,508 RIH to Float collar @ 2424' 01/29/05 12 15:00 15:30 0.50 SURCSG DRILL_ CMT_ AF 2,508 Drill shoe tract F/2424' to 2508' 01/29/05 12 15:30 16:00 0.50 SURCSG DRILL_ ROT_ AF 2,528 Drill 8 1/2" hole F/2508 to 2528' (ART=.3hrs) 01!29/05 12 16:00 18:00 2.00 SURCSG CIRC_ MUD_ AF 2,528 CSU, and displace well bore fluids with 9.4 ppg. Flo-Pro. 01/29/05 12 18:0019:00 1.00 SURCSG TEST_ LOT_ AF 2,528 01/29/05 12 19:00 20:00 1.00 IN1DRL TRIP_ BHA_ AF 2,528 01/29/05 12 20:00 20:30 0.50 IN1DRL PULD_ BHA_ AF 2,528 01/29/05 12 20:30 21:30 1.00 INIDRL PULD_ BHA_ AF 2,528 01/29/05 12 21:30 01:00 3.50 IN1DRL TRIP_ BHA_ AF 2,528 01/29/05 12 01:00 01:30 0.50 IN1DRL CIRC_ MUD_ AF 2,528 01/29/05 12 01:30 06:00 4.50 {N1DRL DRILL_ ROT_ AF 2,686 01/30/05 13 06:00 06:00 24.00 IN1DRL DRILL_ ROT_ AF 4,493 01/31/05 14 06:0013:00 7.00 IN1DRL DRILL_ ROT_ AF 4,891 01/31/05 14 13:0013:30 0.50 IN1DRL CIRC_ MUD_ AF 4,891 01/31/05 14 13:3017:30 4.00 IN1DRL TRIP^ WIPR AF 4,891 01/31/05 14 17:3018:30 1.00 IN1DRL SERVIC RIG_ AF 4,891 01/31/05 14 18:30 22:00 3.50 IN1DRL TRIP_ WIPR AF 4,891 Perform L.O.T. (9.4 ppg. 1774' tvd. 920 psi. applied = 19.37 ppg.) POOH L/D Bha M/U Bha #13 (autotrack assy.) RIH to 2528' Break circ Drill ahead 8 1/2 hole, dretnl, 2528' to 2686' (ART=3 hrs) No conn drag, no gain /loss WOB 15, RPM 40, SPP 1710, SPM 306 Up 70, Dn 50, Rot 55^ No acc Drill ahead 8 1/2" hole drentl F/2686 to 4493 ftART - 15.9 hrs. Run Hi-vis sweeps @ 500' intervals to 4000' go to 250' intervals. Initial sweeps recover 30% addntl cuttings, current sweeps recover 2 - 3% addntl returns. Conn drag normal, no torque /gain /loss. WOB 10/15, RPM 70, SPP 1900, SPM 309 Up 90, Dn 50, Rot 68^ No acc / do time Drill ahead 8 1/2" hole drentl F/4493' to4891' ART=7 hrs Circ Hi-Vis sweep around, recover 3 - 4 %addntl cuttings TOH to 9 5/8" csg. shoe, 30 / 35K drag at 3900 / 3650 / 3200 / 2900, 15K at 2875 ft. No swab /gain /loss Correct hole fill. Flow check, Service rig Flow check, TIH, picking up 5" drillpipe from racks, No do drag, precaution wash 60 ft, no fill. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------------------------------------------------------------------Activity_--------------...--------Depth----....---------------------------•--------------.. 01/31/05 14 22:00 06:00 8.00 IN1 DRL DRILL_ ROT_ AF 5,361 Drill ahead 8 1/2" hole drentl F/4891' to 5361 ART=4.5 hrs^ Conn drag normal, torque reduced 4000 ft Ibs after add tube. WOB 10 / 15, RPM 70, SPP 2000, SPM 300 Up 90, Dn 50, Rot 65 No gain /loss, No acc / do time 02/01/05 15 06:00 06:00 24.00 IN1DRL DRILL ROT 02/02/05 16 06:0013:30 7.50 IN1DRL DRILL ROT 02/02/05 16 13:3014:00 0.50 IN1DRL CIRC_ MUD_ 02/02/05 16 14:0015:30 1.50 IN1DRL CIRC MUD 02/02/05 16 15:30 20:00 4.50 IN1DRL TRIP WIPR 02/02/05 16 20:00 20:30 0.50 IN1DRL SERVIC RIG_ 02/02/05 16 20:30 22:30 2.00 1N1DRL TRIP_ WIPR 02/02/05 16 22:30 01:30 3.00 IN1DRL CIRC MUD AF 6,900 Drill ahead 8 1/2" hole drentl F/5361' to 6900' ART=19.1 hrs^ Conn drag normal, no gain /loss WOB 10/15, RPM 70 ,~ SPP 2150, SPM 285. Up105, Dn55, Rot 75 ^ No gain/loss No acc/dn time AF 7,332 Drill ahead 8 1/2" hole dretnl F/6900' to 7332' ART=5.8hrs^ Connection drag normal no gain/loss. WOB 10/15, RPM 70, SPP 2300, SPM 285. ^ Up 110, Dn55, Rot 75, No gain/loss, No acc/dn time AF 7,332 CBU AF 7,332 Circ to-vis followed by hi-vis sweep around, Flow check, pump dry job. AF 7,332 POOH to 4198' , 25/ 35k drag intermittingly F17332' to 4400' no swab/ gain/loss, correct hole fill^ AF 7,332 Service rig AF 7,332 RIH to 7332' (no fill) AF 7,332 Circ ,Pumped high vis sweep around followed by a tube tech pill ,spot, flow check ,pump dry job. drop drift^ 02/02/05 16 01:30 06:00 4.50 IN1DRL TRIP BHA AF 02/03/05 17 06:00 08:00 2.00 IN1DRL TRIP_ DR_ AF 02/03/05 17 08:0010:00 2.00 IN1DRL PULD_ BHA_ AF 02/03/05 17 10:00 14:00 4.00 I N 1 EVL LOG OH AF 02/03/05 17 14:0017:30 3.50 IN1EVL LOG_ DP_ AF 02/03/05 17 17:30 20:00 2.50 IN1EVL LOG_ MUD_ AF 02/03/05 17 20:00 21:00 1.00 IN1EVL LOG OH AF 7,332 Flow check, Pooh for logs (SLM) hole in good shape. No swab /gain / loss.^ No acc / do time 7,332 Flow check. POOH for logs. 7,332 Flow check. L/D directional drilling assy. 7,332 Conduct PJSM. R/U Reeves & P/U logging tools (shuttle system) & surface test same. 7,332 Flow check. Trip in hole w/drill pipe (check pressure). 7,332 CBU X 2. 7,332 Pump messenger & deploy shuttle. Flow check & pump dry job. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date -------- -Activity ------------- ------------Depth .---- --------------------------------...----------•--------•------------.... 02/03/05 17 21:00 05:00 8.00 IN1 EVL LOG_ OH_ AF 7,332 POOH logging 7322' to surface. 02/03/05 17 05:00 06:00 1.00 IN1EVL LOG_ OH_ AF 7,332 R/D logging svc's & clear floor.^ No accidents/ down time. 02/04/05 18 06:00 12:00 6.00 IN1CSG RURD_ CSG_ AF 7,332 Flow check. Change bails, P/U handling tools, & R/U floor to run csg. 02/04/05 18 12:00 13:00 1.00 IN1CSG SAFETY MTG_ AF 7,332 Conduct safety meeting. 02/04/05 18 13:00 18:00 5.00 IN1CSG RURD_ CSG_ AF 7,332 Pull wear bushing & change pipe rams. Set test plug & test to 2500 # - OK. M/U hanger & landing jt & make dummy run. 02/04/05 18 18:00 19:00 1.00 IN1CSG RUN_ CSG_ AF 7,332 P/U & M/U shoe track &circ thru float equipment. 02/04/05 18 19:00 06:00 11.00 IN1CSG RUN_ CSG_ AF 7,332 Con't to P/U & run 7.0" 26.0 #. L-80, BTC (shoe, 2 jt shoe track, & float collar) intermediate csg. Note -CBU at 2473' & 4516'. Currently at 5602'.^ No Accidents & no injuries reported. 02/05/05 19 06:00 08:00 2.00 IN1CSG RUN_ CSG_ AF 7,332 Con't RIH w/ 7" 26.0 #, L-80, BTC csg to 6525'. 02/05!05 19 08:00 09:00 1.00 IN1CSG CIRC_ MUD_ AF 7,332 CBU. 02/05/05 19 09:00 11:00 2.00 IN1CSG RUN_ CSG_ AF 7,332 Con't rih w/ 7" csg to 7320'. Begin take wt, 5500 - 7320 ft, work pipe free all jts. Attempt recip pipe on btm, no go. M/U & land csg hanger, (shoe 7320, float 7233 ft, hgr 23 ft) 02/05/05 19 11:00 13:00 2.00 IN1CSG CIRC_ MUD_ AF 7,332 Circ / cond fluids, initial partial pkf, final circ 100%, no gain / TOSS 02/05/05 19 13:00 15:30 2.50 IN1CSG PUMP_ CMT_ AF 7,332 PJSM, R/U BJ, Cement 7" csg as per procedure: C Pump 5 bbls H2o, test lines 3000 psi, test successful. Drop plug, confirm plug dropped. Pump 30 bbls MCS4D sweep, 10 ppg. Mix /pump 305 sks (134.4 bbls) lead (12.5 ppg, G, 2.47 yield)^ Mix /pump 167 sks (34.7 bbls) tail, (15.8 ppg, G, 1.17 yield) Drop 2nd plug with 5 bbls H2o, confirm plug dropped. Displace with 271 bbls drlg mud. Plug did not bump, bleed, floats holding. ICP = 520 psi, FCP = 1140 psi, no cmt returns. Cmt in place 1530 hrs 02/05/05 19 15:30 00:00 8.50 IN1CSG NUND BOPE TA MSBO 7,332 Simultanous operations - WOC, install & test 7" pack-off, N/D BOP stack & install single gate. N/U BOP stack & clean & jet steel pits. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ---- -•------ -----------•---- •-------- ----•------- ------------- -Activity -•----•------ ----•------• Depth ----- ----------------•-------------•-----------------------------------..... 02/05/05 19 00:00 06:00 6.00 IN1CSG NUND BOPE AF 7,332 N/U choke & kill lines & koomey lines. Install riser & flow line. R/U trip tank line & drip pan. Mix mud. Change pipe rams & mud pump liners.^ C' No accidents / do time 02/06/05 20 06:00 08:00 2.00 IN1CSG NUND SOPE AF 7,332 Con't Operatiions - Change pipe rams. 02/06/05 20 08:00 18:00 10.00 IN1CSG PULD_ DP_ AF 7,332 PJSM. POOH UD 5" drill pipe out of mouse hole. 02/06/05 20 18:00 21:00 3.00 IN1CSG PULD_ EQIP AF 7,332 PJSM. Rack & prepare 4" drill pipe & complete pump liner change to 4". R/U 4" air slips & set wear bushing. 02/06/05 20 21:00 22:00 1.00 IN1CSG SLPCUT DLIN AF 7,332 PJSM. Slip & cut 43' of drilling line. 02/06/05 20 22:00 06:00 8.00 IN1CSG PULD_ DP_ AF 7,332 PJSM. P/U, drift, M/U, & trip in hole w/ 4" drill pipe.^ No Accidents & no injuries reported. 02/07/05 21 06:00 09:00 3.00 IN1CSG PULD_ DP_ AF 7,332 POOH & stand back 4" drill pipe. Pull wear bushing. 02/07/05 21 09:00 13:00 4.00 IN1CSG TEST_ BOPE AF 7,332 Set test plug. R/U & pressure test BOP stack, BOP rams, upper & lower kelly cocks, TIW, inside BOP, choke manifold, kill lines, & annular tested to 250 (low pressure)/ 2500 (high pressure}. Test accumalator, pull test plug, & set wear bushing. All BOP componants pressure tested - OK. Witness test waived Mr Jim Regg AOGCC 02!07/05 21 13:00 14:00 1.00 IN1 CSG TEST_ CSG_ AF 7,332 Pressure test 7" csg to 2500 psi for 30 min - OK. Blow. down choke & circ lines. 02!07/05 21 14:00 20:00 6.00 IN1 CSG PULD! BHA_ AF 7,332 P/U & M/U BHA # 14. Orient & test at 200 spm w/ 800 psi - OK. 02/07/05 21 20:00 01:00 5.00 IN1CSG TRIP_ DP_ AF 7,332 P/U, drift, & trip in hole w/ 4" drill pipe. 02/07/05 21 01:00 02:00 1.00 IN1CSG TRIP_ DP, AF 7,332 Rack & tally 4" drill pipe. 02/07/05 21 02:00 06:00 4.00 IN1CSG TRIP_ DP_ AF 7,332 Con't P/U, drift, & trip in hole w/ 4" drill pipe, M/U top drv^ No acc / do time 02/08/05 22 06:00 08:30 2.50 IN1CSG DRILL_ CMT_ AF 7,332 Drill cmt, float equip, & shoe track to 7232'. 02/08!05 22 08:30 09:00 0.50 IN1CSG DRILL_ ROT_ AF 7,352 Drill 20' of new hole f/ 7332' to 7352'. 02/08/05 22 09:00 11:00 2.00 IN1CSG CIRC_ MUD_ AF 7,352 CBU & displace hole w/ flo pro mud system. 02/08/05 22 11:00 12:00 1.00 IN1CSG TEST_ LOT_ AF 7,352 PJSM. R/U & perform LOT wi 9.6 ppg. (Leak off at 1510 psi & TVD at 3435'. EMW = 18.054 ppg). Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date .....................Activity_-----------------------•-Depth-----....------------------------•----------------------------------.......-- -------------------------------------------------- 02/08/05 22 12:00 06:00 18.00 PR1DRL DRILL_ ROT_ AF 8,534 Drill ahead 6 1/8 hole dretnl, 7352 - 8534 ft. ART = 10.3 hrs, AST = 2 hrs^ Conn's free, no torque /drag /gain /loss. Cuttings normal quantity /quality^ WOB 5 - 10, RPM 70, SPP 2000, SPM 255. C7 Old mud - Up 110, Dn 30, Rot 55 ,Torque 9Ci New mud - Same^ New mud with 3% tube - Up 85, Dn 30, Rot 55, Torque 7 02/09/05 23 06:00 03:00 21.00 PR1DRL DRILL_ ROT_ AF 9,794 02/09/05 23 03:00 04:30 1.50 PR1 DRL CIRC_ MUD_ AF 9,794 02!09/05 23 04:30 06:00 1.50 PR1 DRL TRIP_ WIPR AF 9,794 02/10/05 24 06:00 06:30 0.50 PR1DRL TRIP_ WIPR AF 9,794 02/10/05 24 06:30 07:30 1.00 PR1 DRL SERVIC RIG_ AF 9,794 02/10/05 24 07:30 09:00 1.50 PR1EVL TRIP_ BHA_ AF 9,794 02/10/05 24 09:0010:30 1.50 PR1EVL CIRC_ MUD_ AF 9,794 02/10/05 24 10:3012:30 2.00 PR1EVL TRIP_ BHA_ AF 9,794 02/10!05 24 12:30 14:30 2.00 PR1 EVL SLPCUT DLIN AF 9,794 02/10/05 24 14:30 18:30 4.00 PR1 EVL TRIP_ BHA_ AF 9,794 02/10/05 24 18:30 22:30 4.00 PR1EVL TRIP_ EQIP AF 9,794 02/10/05 24 22:30 23:00 0.50 PR1 EVL SERVIC RIG_ AF 9,794 02/10/05 24 23:00 03:00 4.00 PR1EVL TRIP_ EQIP AF 9,794 02/10/05 24 03:00 04:00 1.00 PR1 EVL WASH_ FILL AF 9,794 02/10/05 24 04:00 06:00 2.00 PR1 EVL CORE_ CONV AF 9,810 Directional drill 6 1/8 hole f/ 8534' to core point @ 9794'. ART = 11.9 hrs, AST = 3.4 hrs^ Conn's free, no torque /drag /gain /loss. Cuttings normal quantity /quality^ WOB 5 - 10, RPM 70, SPP 2000, SPM 255 CBU X 2. Wiper trip to CSG shoe (8000' @ 06:OOhrs). l_ No Accidents & no injuries reported. Cont. POOH to CSG shoe. Service rig. RIH to 9794'(tag ledge @ 8049' and rotate past ledge). Circ hole clean(CBUX2, 2400psi, 315gpm, 76RPM). Check flow(well static). Pump dry job. POOH to CSG shoe. Slip and cut drilling line. Con't POOH SLM. LID dir BHA. PJSM. P/U & M/U core ass'y # 1 &TIH to 2090'. Service Rig. Con't TlH w/ coring ass't' to 9794'. Drop ball & circ down drill string. Core f/ 9794' to 9810' w/ WOB @ 6 - 10K, 60 rpms, & 1550 psi(core jammed@00:430hrs attempt to continue coring). ^ No accidents & no injuries reported. 02/11/05 25 06:00 06:30 0.50 PR1 EVL CORE CONY AF 9,810 Con't coring f/ 9808' to 9810'. Unable to core ahead. 02/11/05 25 06:30 07:30 1.00 PR1 EVL CIRC_ MUD_ AF 9,810 Circ. and build dry job. Flow check and pump dry job. 02/11/05 25 07:30 15:30 8.00 PR1EVL TRIP_ BHA_ AF 9,810 POOH to core barrel. 02/11/05 25 15:30 16:30 1.00 PR1 EVL TRIP_ BHA_ AF 9,810 PJSM prior to L/D core. L/D core(recovered 16'4"). 02/11/05 25 16:30 22:30 6.00 PR1EVL TRIP_ BHA_ AF 9,810 Flow check well. P/u & TIH w/ coring ass't' to 9810', Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------------------------------------------------------------------Activity .-•---------------------.Depth --------------- ----- ------------------------------------------------------------- 02/11/05 25 22:30 00:00 1.50 PR1EVL CIRC_ MUD_ AF 9,810 CBU & drop ball. Wash to bottom w/ 190 spm @ 870 psi. 02/11/05 25 00:00 04:00 4.00 PR1EVL CORE CONY 02/11/05 25 04:00 06:00 2.00 PR1EVL TRIP BHA AF 9,835 Con't 6 118" coring fl 9810' to 9835' w/ WOB @ 6 - 10K, 60 rpms, & 1550 psi. Unaable to core ahead @ 9835'.L AF 9, 835 02/12/05 26 06:0014:00 8.00 PR1EVL TRIP_ BHA_ AF 9,835 02/12/05 26 14:0015:00 1.00 PR1EVL TRIP_ BHA_ AF 9,835 02/12/05 26 15:0016:30 1.50 PR1EVL TRIP_ BHA_ AF 9,835 02/12/05 26 16:30 21:30 5.00 PR1EVL TRIP_ TOOL AF 9,835 02/12/05 26 21:30 22:00 0.50 PR1EVL CIRC_ MUD_ AF 9,835 02/12/05 26 22:00 06:00 8.00 PR1 EVL CORE , CONY AF 9,873 02/13/05 27 06:00 07:30 1.50 PR1EVL CORE_ CONY AF 9,875 02/13/05 27 07:30 08:30 1.00 PR1EVL CIRC_ CFLD AF 9,875 02/13/05 27 08:3016:00 7.50 PR1EVL TRIP_ BHA_ AF 9,875 02/13/05 27 16:0017:00 1.00 PR1EVL TRIP_ BHA_ AF 9,875 02/13/05 27 17:0017:30 0.50 PR1EVL CLEAN_ RIG_ AF 9,875 02/13/05 27 17:3018:30 1.00 PR1EVL TRIP_ BHA_ AF 9,875 02/13!05 27 18:30 00:00 5.50 PR1EVL TRIP_ DP_ AF 9,875 02/13/05 27 00:00 06:00 6.00 PR1 DRL REPAIR RIG_ TA MSTD 9,875 02/14/05 28 06:00 07:00 1.00 PR1 DRL REPAIR RIG_ TA MSTD 9,875 02/14/05 28 07:00 06:00 23.00 PR1DRL DRILL_ ROT_ AF 10,980 Flow check well. Mix & pump dry job. POOH w/ coring assy. ^ No accidents & no injuries reported. POOH SLM. PJSM prior to L/D core. L/D core(recovered 23.3'). C/O core bit and M/U core assy. Flow check well. TIH w/ core assy. CBU & drop ball. Wash to bottom w/ 190 spm @ 870 psi. Con't 6 118" coring f/ 9835' to 9873" w/ WOB @ 4 - 8K, 60 rpms, & 1225 psi. ^ No accidents & no injuries reported. Core F/9873' to 9875'. Circ. and mix dry job. Check flow. Pump dry job. POOH. PJSM prior to L/D core. L/D core assy recovered 27.3'). Clean and organize rig floor. P/U & MiU drilling assy. T1H & test MWD. TIH w/ drill string to 9724'. Wash & ream to bottom as precaution. Trouble shoot electrical problem with top drive unit.^ No accidents & no injuries reported. Trouble shoot problem with TDS electrical control system. R/U hydraulic manual override system. Dir drill and survey F/9875' to 10,980'. (ART=10.82 hrs AST=4.71 h rs). ^ No accidents & no injuries reported. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date --------------------------------Activity_-•-----..._.....---------Depth--------------------------------------...-----....__......._-------- 02/15/05 29 06:00 06:00 24.00 PR1DRL DRILL_ ROT_ AF 11,720 Con't directional drill 6 1/8" hole f/ 10980' to 11,720'. (ART = 13.8 hrs. & AST = 2.7 hrs.). Replaced +/-15 cap gaskets for the mud pumps#1 and #2 during 24hrs.~~ No accidents & no injuries reported. 02/16/05 30 06:0015:00 9.00 PR1DRL DRILL_ ROT_ AF 12,036 02/16/05 30 15:0015:30 0.50 PR1DRL CIRC_ MUD_ AF 12,036 02/16/05 30 15;3018:00 2.50 PR1DRL DRILL_ ROT_ AF 12,175 02/16/05 30 18:0019:00 1.00 PR1DRL CIRC_ MUD_ AF 12,175 02/16/05 30 19:0019:30 0.50 PR1DRL DRILL_ ROT_ AF 12,212 02/16/05 30 19:30 06:00 10.50 PR1DRL CIRC MUD 02/17/05 31 06:00 06:30 0.50 PR1DRL CIRC_ MUD_ 02/17/05 31 06:30 08:30 2.00 PR1DRL FLOW CHEK 02/17/05 31 08:3010:00 1.50 PR1DRL TRIP_ BHA_ 02/17/05 31 10:0010:30 0.50 PR1DRL TRIP_ BHA_ 02/17/05 31 10:3012:30 2.00 PR1DRL CIRC MUD 02/17/05 31 12:3013:30 1.00 PR1DRL FLOW CHEK 02/17/05 31 13:30 15:30 2.00 PR1 DRL CIRC_ MUD_ 02/17/05 31 15:30 20:00 4.50 PR1DRL TRIP WIPR 02!17/05 31 20:00 21:30 1.50 PR1DRL TRIP_ WIPR 02/17/05 31 21:30 23:30 2.00 PR1 DRL CIRC MUD TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 TA NDLC 12,212 02!17/05 31 23:30 00:00 0.50 PR1 DRL FLOW_ CHEK TA NDLC 12,212 Dir drill and survey F/11,720' to 12,036'. Circ for samples @ 12,036'. Con't dir drill & survey f/ 12,036' to 12, 175'. Circ for samples @ 12,175'. Con't dir drill & survey f/ .12,175' to core point @ 12,212'(increase calcium carbonate conc. due to 20BPH losses while drilling @ 12,060'). Con't cire & raise mud weight gradually from 10.0 to 10.9 ppg at report time. Well continues to flow & record 400+ unit gas influx after shut in periods. Circ. at reduced rate due to 20BPH losses @ 280gpm. ^ No accidents & no injuries reported. Cont. to circ. and increase MW to 10.8ppg. Flow check for 1.5hrs(well flowed back w/606PH and decreased to 56PH flowed back total of 30BBLS). POOH wet to 11,390'(B/R tight spot@11,750', Pulled 15stands, hole not taking any fill). RIH to 12,212'. Circ. B/U (170gpm, 1450psi, 33RPM w/small losses, 155gpm, 1320psi,33RPM w/no losses max gas 1723units). Flow check for 1 hr(well flowed back w/17BPH and decreased to 2.8BPH flowed back total of 15bbls). CBU(150gpm, 1250psi, 35RPM, max gas 260units). Pump out to 9750'(122GPM, 970psi hole took +/-6bbls theoretical+/-15bbls). RIH, to 12212' (No Fill). CBU(185gpm, 1550psi, 35RPM, max gas 1096units)no losses. Monitor well bore, Flow back 6-bbl. rate started @ 60bph,^ slowed to 12bph. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ------- --------- ------------- ----------- --Activity-- ----------- ------------Depth .----- -------------------._...._....----------------....-------------------- 02/17/05 31 00:40 02:00 2.00 PR1DRL CIRC_ MUD_ TA NDLC 12,212 CBU, (185gpm,1550psi,35rpm,max gas 1000units )no losses. 02/17/05 31 02:00 03:30 1.50 PR1DRL FLOW_ CHEK TA NDLC 12,212 Monitorwellbore (Flowed back 12bb1. rate dropped from 306PH to 36PH). 02/17/05 31 03:30 06:00 2.50 PR1EVL TRIP_ BHA_ AF 12,212. POOH. 02/18/05 32 06:00 09:30 3.50 PR1 EVL TRIP_ BHA_ AF 12,212 Cont. POOH to 9403'(short 9.3bbls on hole displacement) 02/18/05 32 09:3013:30 4.00 PR1EVL TRIP_ BHA_ AF 12,212 02/18/05 32 13:30 15:30 2.00 PR1EVL FLOW_ CHEK AF 12,212 02/18/05 32 15:30 20:00 4.50 PR1EVL TRIP_ BHA_ AF 12,212 02/18/05 32 20:00 20:30 0.50 PR1 EVL FLOW_ CHEK AF 12,212 02/18/05 32 20:30 00:00 3.50 PR1EVL TRIP_ BHA_ AF 12,212 02/18/05 32 00:00 01:00 1.00 PR1EVL PULD_ BHA_ AF 12,212 02/18/05 32 01:00 05:00 4.00 PR1 EVL TRIP_ BHA_ AF 12,212 02!18/05 32 05:00 05:30 0.50 PR1EVL SERVIC RIG_ AF 12,212 02/18/05 32 05:30 06:00 0.50 PR1EVL TRIP_ BHA_ AF 12,212 02/19/05 33 06:00 08:00 2.00 PR1EVL TRIP_ BHA_ AF 12,212 02/19/05 33 08:0010:00 2.00 PR1EVL CIRC_ MUD_ AF 12,212 02/19/05 33 10:0010:30 0.50 PR1EVL CIRC_ MUD_ AF 12,212 02/19/05 33 10:30 06:00 19.50 PR1 EVL CORE r CONY AF 12,292 02/20/05 34 06:00 09:30 3.50 PR1 EVL CORE _ CONV AF 12,301 02/20/05 34 09:30 11:00 1.50 PR1 EVL FLOW_ CHEK AF 12,301 02/20/05 34 11:00 13:00 2.00 PR1 EVL CIRC_ MUD_ AF 12,301 02/20/05 34 13:00 14:00 1.00 PR1EVL FLOW_ CHEK AF 12,301 02/20/05 34 14:0014:30 0.50 PR1EVL TRIP_ BHA AF 12,301 02/20/05 34 14:3019:00 4.50 PR1EVL TRIP_ BHA_ AF 12,301 02!20/05 34 19:00 03:30 8.50 PR1EVL TRIP_ BHA_ AF 12,301 02/20/05 34 03:30 06:00 2.50 PR1 EVL PULD_ BHA_ AF 12,301 02/21/05 35 06:00 06:30 0.50 PR1EVL TRIP_ BHA_ AF 12,301 02/21/05 35 06:30 07:00 0.50 PR1 DRL TEST_ BOPE AF 12,301 Pump out of hole to CSG shoe(hole taking correct fill). While slip and cut flow check well(well static) and replace card in TDS controller box. Cont. POOH to Bha. (Hole taking correct fill plus.) Flow check (Well bore taking App. 2.46 bbl, per hr) L/D Bha M/U Core Assy #4 TIH, to 7290', Filling pipe @ 3600' and 7290' Service Rig TIH Cont. R1H w/core barrel. Circ. B/U (188GPM 1300psi, 195gpm 1355psi, max gas 1300units). Drop ball and circ down w/180gpm 1120psi. Pressure increased to 1572psi. Cut core F/12,212' to 12,292' (ART=19.5 hrs.) Core F/12292 to 12301'(ART=3.5hrs).(TOTAL 23 hrs} Flow check well(total 9bb{s back started 366PH and ended 2.626PH). CBU(180gpm,max gas 1316units) Flow check well(slight decreaseing flow) POOH wet to 11680'(10 stands, hole fill not correct) Pump out of hole to 9200' (hole fill correct) POOH, to core bbl. (hole fill correct) PJSM:L/D Core.(Cut 89', Rec. 70.15') Cont. to L/D core assy. Pull wear bushing. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date-------------------------------------------------•--...----------.Activity --•----------------------Depth ...-------------- 02/21/05 35 07:00 09:00 2.00 PR1 DRL TEST BOPE AF 12,301 Test lower pipe rams, upper variable rams, annular, blind rams, 1-12 CMV's, kill line check valve, inner and outer kill line valves. HCR and manual choke line valves. Upper and lower TD valves, floor valve and IBOP valve. All rams and valves tested to 250/2500 psi 3min. 02/21/05 35 09:00 09:30 0.50 PR1DRL TEST_ BOPE AF 12,301 Install wear ring. 02/21/05 35 09:30 10:30 1.00 PR1EVL TRIP_ BHA_ AF 12,301 M/U 6 1/8" bit and BHA. 02/21/05 35 10:30 14:00 3.50 PRIEVL TRIP BHA AF 12,301 RIH w/BHA. Test MWD. Cont. RIH to CSG shoe @ 7320' . _ _ ; 02/21/05 35 14:00 15:00 1.00 PR1 EVL SERVIC RIG_ AF 12,301 Service the rig. 02/21/05 35 15:00 17:00 2.00 PR1 EVL REPAIR RIG_ TA MSTD 12,301 Adjust controler card for the top drive. C/O priority valve on main hyd. system. 02/21/05 35 17:00 19:00 2,00 PR1EVL TRIP_ BHA_ AF 12,301 Cont. RIH. to 12162' Fill pipe. 02/21/05 35 19:00 20:00 1.00 PR1 EVL REAM_ OH_ AF 12,301 Ream core hole F/12212' to 12288'(max gas 874units). 02/21/05 35 20:00 21:00 1.00 PR1 EVL CIRC_ MUD_ TA NDMD 12,301 Circ out through open choke to equalize mud wts. differential(mud in pits had inadvertently been cut back to 10.5ppg). 02/21/05 35 21:00 21:30 0.50 PR1 EVL REAM_ OH_ AF 12,301 Ream core hole F/12288' to 12301'. 02/21/05 35 21:30 06:00 8.50 PR1 DRL DRILL_ ROT_ AF 12,480 Dir drill and survey F/12301' to 12480'(ART=3.6 AST=1.9)(increase lubtex to 4% before up 160k, do 70k, rot 105k, 12-13k torque after up 160k, do 70k, rot 105k, 11 - 12ktorque). 02/22/05 36 06:00 06:00 24.00 PR1 DRL DRILL_ ROT_ AF 13,126 Dir drill and survey F/12480' to 13126'(ART=17.8hrs AST=.4hrs). ^ Wob 5-10k, RPM 60, Up 170k, Dn75k,Rot 110k. Tq 12- 14,^ Loosing 2 bph to the hole until app. 12908' Losses increased to 20bph initially but healed up back to 2 bph with the addition of safe-carb 40 and 250. (MWD failed @ 23:OOhrs last survey 12797'. Continued to drill 500' as per AOGCC regs). 02/23/05 37 06:00 10:30 4.50 PR1 DRL DRILL_ ROT_ AF 13,233 Dir drill and survey F/13126' to 13233'(ART=4.3hrs). 02!23!05 37 10:30 12:00 1.50 PRIDRL CIRC_ CFLD TA MDMW 13,233 Circ. clean. 02/23/05 37 12:00 14:00 2.00 PR1 DRL FLOW_ CHEK TA MDMW 13,233 Flow check(flowed back a total of 15bbls, started 406PH ended 3.4BPH}, 02/23/05 37 14:0016:30 2.50 PR1 DRL TRIP_ DP_ TA MDMW 13,233 POOH(tight @ 12741', 12500', 12456' pump out F/12750' to 11985'). Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------- ------- ---------------- ---------- ------------- ------------ -Activity _.....------- ------------ Depth .----- ---------------------...--•------------------------------------------- 02/23/05 37 16:30 20:30 4.00 PR1 DRL TRIP_ DP_ TA MDMW 13,233 POOH to csg. shoe @ 7320' W/O pump (Monitor well bore static) 02/23/05 37 20:30 03:00 6.50 PR1 DRL TRIP_ DP_ TA MDMW 13,233 Continue to POOH to Bha(Correct hole fill). 02/23/05 37 03:00 03:30 0.50 PR1 DRL TRIP_ BHA_ TA MDMW 13,233 POOH Bha, lay do MWD. (MWD failed @ 23:00 on 2/21. Last survey @ 12,797') 02/23/05 37 03:30 04:00 0.50 PR1DRL TRIP_ BHA_ TA MDMW 13,233 TIH with Bha (Synchronize MWD). 02/23/05 37 04:00 06:00 2.00 PR1 DRL TRIP_ DP_ TA MDMW 13,233 TIH W/ Bha # 21. 02J24/05 38 06:00 08:00 2.00 PR1DRL TRIP_ DP_ TA MDMW 13,233 TIH to Csg shoe @ 7320' 02/24/05 38 08:00 09:00 1.00 PR1 DRL SLPCUT DLIN TA MDMW 13,233 Slip and cut drlg line 02/24/05 38 09:00 10:00 1.00 PR1 DRL SERVIC RIG_ TA MDMW 13,233 Service rig 02/24/05 38 10:00 13:00 3.00 PR1 DRL TRIP_ DP_ TA MDMW 13,233 TIH to 13173' (tight hole @ 8626') 02/24/05 38 13:00 13:30 0.50 PR1 DRL WASH_ FILL TA MDMW 13,233 Wash out fill F/13173' to 13233' 02/24/05 38 13:30 15:00 1.50 PR1DRL CIRC_ MUD_ TA MDMW 13,233 CBU, (max gas units 1980') 02/24/05 38 15:00 01:30 10.50 PR1DRL DRILL_ ROT_ AF 13,419 Drill ahead 6 1/8" hole drentl F/13,233'to 13419' (ART= 9 hrs). Reducing mw to 10.5 ppg (Lost 100% returns) 02/24/05 38 01:30 04:00 2.50 PR1 DRL MIX_ LCM_ TA NDLC 13,419 Mix and pump (40 bbl. LCM pill Consist of 50ppb 40 and 50ppb 250 Safe-guard put in place @ 83 gpm-530 psi. gained 95 °!o returns (lost 160 bbl. fluid)^ 02/24/05 38 04:00 05:00 1.00 PR1 DRL DRILL_ ROT_ TA NDLC 13,432 Drill ahead 6 1/8" hole drentl F/13419' to 13432' (ART=.1 hrs) Reduced flow rate to 185gpm. 800 psi. (lost 85 bbl.) 02/24/05 38 05:00 06:00 1.00 PR1 DRL CIRC_ MUD_ TA NDLC 13,432 Mix and pump (40 bbl. LCM pill Consist of 50ppb.40 and 50ppb 250. Safe- guard put in place @ 83 gpm 530 psi. 02/25/05 39 06:00 06:30 0.50 PR1DRL DRILL_ ROT_ AF 13,436 Drill ahead 6 1/8" hole drentl F/13432 to 13436' (ART=.5hrs) ^ Fluid lost to wellbore 35 bbls. 02/25!05 39 06:30 08:30 2.00 PR1DRL CIRC_ MUD_ TA NDLC 13,436 Mix and pump 30 bbl. Safe-guard 40 mixed @ 100 ppb. 02/25/05 39 08:30 11:00 2.50 PR1 DRL TRIP_ WIPR TA NDLC 13,436 POOH to 12220' (wellbore taking no fluid) 02/25/05 39 11:00 21:00 10.00 PR1 DRL WAITON TRET TA NDLC 13,436 Wait on Safe-guard pill to set. lower MW to 10.2 ppg. and bring pumps rates to 241 gpm in intervals with no losses occuring at end. 02/25/05 39 21:00 22:00 1.00 PR1DRL TRIP_ WIPR TA NDLC 13,436 T1H (Fill pipe 13410') 02/25/05 39 22:00 23:30 1.50 PR1 DRL CIRC_ MUD_ TA NDLC 13,463 Circ (Bring flow rate to drill rate 223 gpm.) Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------ --------- -----•-•-------- -...----------------------------- --Activity ---...------- --•----•----Depth .---- ------------------- 02/25/05 39 23:30 06:00 6.50 PR1 DRL DRILL_ ROT_ AF 13,590 Drill ahead 6 1/8" hole drentl Fl13436' to 13590 (ART = 5.1 hrs)^ Loss rate 36 bph to 96 bph. Wellbore is taking 36 bph to 96 bph while drilling. Pump rate 200 gpm. 1800 psi. Total mud loss 246 bbl. 02/26/05 40 06:00 15:30 9.50 PR1 DRL DRILL_ ROT_ AF 13,721 Drill ahead 6 1/8" hole drentl F/13590' to 13721' (ART=8.5hrs.) Dropped flowrate F/200 gpm to 150 gpm losses decreased to 5-30 bph drilling ahead losses decreased to 1-5bph. Lost a total of 100 bbls. for interval. Mud wt 10 PPG. 02/26/05 40 15:30 18:30 3.00 PR1 DRL CIRC_ MUD_ AF 13,721 Circulate for samples (148 gpm. 1000 psi.) 1-2bph losses 02/26/05 40 18:30 22:00 3.50 PR1 DRL DRILL ROT 02/26/05 40 22:00 01:30 3.50 PR1 DRL CIRC MUD 02/26/05 40 01:30 03:30 2.00 PR1DRL FLOW CHEK 02/26/05 40 03:30 06:00 2.50 PR1DRL CIRC_ MUD_ 02/27/05 41 06:00 08:30 2.50 PR1DRL CIRC MUD 02/27/05 41 08:3012:00 3.50 PR1DRL TRIP_ WIPR 02/27/05 41 12:00 13:30 1.50 PR1 DRL SAFETY MTG_ AF AF AF AF AF AF TA ESIR 13,771 Drill ahead 6 1/8" hole drentl Fl13721' to 13771' (ART=1.5hrs)^ (150 gpm flowrate.) 1-2 bph losses 13,771 Circulate for samples (150 gpm. 1000 psi.) 1- 2bph losses 13,771 Flow check,( Flow back 47 bbl.( Beginning 27 sec. per bbl. end of flow check, 4 min 55 sec. per bbl. ) 13,771 Prepare for wiper trip. Circ bottoms up @ 125 gpm, to reduce ECD , (Max gas 2300 units @ 12000 stks, no gain, no loss. No acc / do time 13,771 Continue to circulate, at reduced rate of 125gpm to reduce ecd until annulus clean of influx. (Max gas 2300 units) 13,771 13,771 02/27/05 41 13:3016:30 3.00 PR1DRL TRIP_ WIPR AF 13,771 02/27/05 41 16:3018:00 1.50 PR1DRL SERVIC RIG_ AF 13,771 02/27!05 41 18:00 20:00 2.00 PR1DRL TRIP_ WIPR AF 13,771 02/27/05 41 20:00 21:30 1.50 PR1 DRL WASH FILL AF 13,771 02/27/05 41 21:30 00:00 2.50 PR1DRL TRkP_ WIPR AF 13,771 02/27/05 41 00:00 04:00 4.00 PR1DRL CIRC_ MUD_ AF 13,771 02/27/05 41 04:00 06:00 2.00 PR1 DRL TRIP_ DP_ AF 13,771 POOH to 10721' (Tight F/9600' to 9300') Stand do following accident. Accident investigation, safety meeting. Continue POOH to 7265' Service rig and top drive TIH to 8968' Tag bridge Wash and ream 8968' to 9718' Continue to TIH to 13736', precaution wash to btm 5 ft fill. Circ and condition drilling fluid (125gpm, 750 psi.) Max gas units on bottoms up 1893 units, decreasing to 30. POOH For logs ,Drop drift, Slm pipe. Marathon Oil Corp, Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------- -------- --------------- ---------- ------------- ----------- --Activity_ ------------- ------------Depth------ -----------------------------------------•----------•------------------ 02/28/05 42 06:00 17:00 11.00 PR1DRL TRIP_ DP_ AF 13,771 POOH for Logs, SLM, 20-25K over at 12225, 9660, 8345. 12 bbl gain initial, correct hole fill beginnining 13000 ft. 02/28!05 42 17:00 19:00 2.00 PR1DRL PULD_ BHA_ AF 13,771 Handle Bha, L/D dir drilling asst' 02128!05 42 19:00 23:00 4.00 PR1EVL PULD_ BHA_ AF 13,771 PJSM: M/U logging bha (Precision Shuttle Asst') 02!28/05 42 23;00 06:00 7.00 PR1EVL TRIP_ DP_ AF 13,771 TIH W/ logging asst'. #1 Quad Combo, Fill pipe and record pressures @ 860', 3500', 7320', 9700', 11700'. 11 K do drag 8660 ft, no gain /loss. 03/01/05 43A 06:00 08:30 2.50 PR1 EVL CIRC_ MUD_ AF 13,771 CBU ,Max 1692 units gas / no 1oss1 no gain 03/01/05 43A 08:30 10:00 1.50 PR1 EVL LOG_ OH_ AF 13,771 Flow check, POH to 13762',pump messenger, flow check, pump wt. pill 03/01!05 43A 10:00 16:30 6.50 PR1 EVL LOG_ OH_ AF 13,771 Commence logging well DPC,30 fpm, 13762' to 6661' no drag, no swab/ gain/loss 03/01/05 43A 16:30 21:00 4.50 PR1 EVL TRIP_ DP_ AF 13,771 Logs completed, POH 4" DP to shuttle asst', no drag !gain / loss 03!01/05 43A 21:00 23:00 2.00 PR1 EVL PULD_ LOG_ AF 13,771 Lay out logging tools, down load data ~J Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ------------ ------------ Activity_ ------------- ------------Depth ----- -----•----------- 2005 Rid Completion Event:_ 03/01/05 16 23:00 00:00 1.00 PR1CSG PULD_ BHA_ AF 13,771 M/U Clean out Bha #1 03!01105 1B 00:00 05:30 5.50 PR1CSG TRIP_ DP_ AF 13,771 TIH 03/01/05 16 05:30 06:00 0.50 PR1CSG CIRC_ MUD_ AF 13,771 Circ and condition for liner 03/02/05 2 06:00 19:30 13.50 PR1CSG CIRC_ MUD_ AF 13,771 Circulate and condition mud, cut MW to 9.8ppg. Added Lubetex to increase concentration to 6%. add SafeCarb and Dual-Flo for wall cake/fluid foss, Asphasol to stabilize coal, Run nut plug pills as volume caliper test, resulting in annuluar volume of 380 bbls. 12880 stks. (36 % Excess volume) 03/02/05 2 19:30 20:00 0.50 PR1CSG TRIP_ WIPR AF 13,771 POOH 10 stds. to 13151' (Wellbore flowed 6-bbl. plus displacement for a total of 9.6 bbls 03!02/05 2 20:00 20:30 0.50 PR1CSG TRIP_ WIPR AF 13,771 TIH to 13771' (no problems) 03/02/05 2 20:30 23:00 2.50 PR1CSG CIRC_ MUD_ AF 13,771 CBU, at 150 gpm, 700 psi. max gas units 1756 03102!05 2 23:00 00:00 1.00 PR1CSG MIX_ LCM_ AF 13,771 Mix and put in place 30 bbl. M-I Seal pill , 10 ppb fine, 10 ppb med, 10 ppb coarse 03/02/05 2 00:00 03:00 3.00 PR1CSG TRIP_ WIPR AF 13,771 POOH to 10490" 03/02/05 2 03:00 03:30 0.50 PR1CSG CIRC_ MUD_ AF 13,771 Circ @ 150 gpm/ 530 psi. 03/02/05 2 03:30 05:30 2.00 PR1CSG CIRC_ MUD_ AF 13,771 Stage pumps up 10 min intervals, test wellbore stability, 173 gpm, 198 gpm, 198 gpm, 223 gpm, 248 gpm, 272 gpm, 300 gpm, ~ no gain /loss. 03/02/05 2 05:30 06:00 0.50 PR1CSG PULD_ DP_ AF 13,771 POOH, Laying down DP 03/03!05 3 06:00 09:30 3.50 PR1CSG PULD_ DP_ AF 13,771 Con't POOh L/D drill pipe. 03/03/05 3 09:30 10:30 1.00 PR1CSG REPAIR RIG_ TA MSTD 13,771 Rig repair to hydraulic pump. 03/03/05 3 10:30 12:30 2.00 PR1CSG PULD_ DP_ AF 13,771 Flow check, Con't POOh L/d drill pipe. 03/03/05 3 12:30 16:00 3.50 PR1CSG PULD_ DP_ AF 13,771 POOH stand back drill pipe. L/D jars, X-O, bit sub, & bit. 03/03/05 3 16:00 17:00 1.00 PR1CSG SERVIC RIG_ AF 13,771 Flow check well. Slip & cut 33' of drilling line. 03!03/05 3 17:00 19:00 2.00 PR1CSG RURD,_ CSG_ AF 13,771 PJSM. R/U floor & related equip & R/U Weatherford tongs & torque turn equipment. 03/03/05 3 19:00 22:00 3.00 PR1CSG RUN, CSG_ AF 13,771 P/U & M/U 4 1/2" 12.60#, L-80, Hyd 533 Csg shoe track (float shoe, 2 jts, 1 float collar, 1 jt, 1float collar, & 1 jt). Pump thru shoe track - OK. Note -all connections bakerlocked & torqued. 03/03/05 3 22:00 06:00 8.00 PR1CSG RUN_ CSG_ AF 13,771 Con'tto P!U & run 4 1/2" Csg to 5283'.^ No loss / gain^ No acc i 1 hr do time Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------- -------- ---------------- --------• ------------- ------------ Activity_ ------------- ------------Depth------ -------•------...--------------•----- 03/04l05 4 06:00 08:00 2.00 PR1CSG RUN^ CSG_ AF 13,771 Con't P/U & RIH w/4 1/2" 12.60#, L-80, Hyd 533 Csg. Total of 209 jts @ 6666.95'. 03/04/05 4 08:00 09:30 1.50 PR1CSG RURD_ CSG_ AF 13,771 P/U & M/U Baker ZXP liner pkr, change out elevators, & R/D Weatherford Csg crew. Fill liner. 03/04/05 4 09:30 11:00 1.50 PR1 CSG RUN_ CSG_ AF 13,771 Follow pkr with 4" dp to 7273'. 03/04/05 4 11:00 12:00 1.00 PRICSG SPOT! PILL AF 13,771 R/U & spot 20 bbl tube pill @ 7273'(100 spm & 330 psi). Initial : Up 65, Dn 40, Rot 50, Torque 3600 With Lube : Up 62, Dn 38, Rot 50, Torque 3400 03/04/05 4 12:00 14:00 2.00 PR1CSG REPAIR RIG_ TA MSTD 13,771 Rig repair( weld arm of top drive unit). Troubleshoot link~_ extend cylinders. 03/04/05 4 14:00 15:00 1.00 PR1CSG RUN_ CSG_ AF 13,771 Cont' RIH 4 1!2 liner to 8933 ft. Wellbore obstructed, can not pass. 03/04/05 4 15:00 16:00 1.00 PR1 CSG REAM_ OH_ AF 13,771 Rotate /circ /recip pipe through bridge 8933 - 9330 ft. Torque (3500), stall, various intervals, work free. No cuttings return while reaming. 03/04/05 4 16:00 16:30 0.50 PR1CSG CIRC_ MUD_ AF 13,771 Cont recip pipe, CBU. Gas 502 units, no gain /loss. 200 spm, 250 gpm, spp 450 psi 03/04/05 4 16:30 17:30 1.00 PR1CSG RUN_ CSG_ AF 13,771 Resume RIH 4 1/2 liner on 4" DP to 11522 ft. Take wt (23000 Ib) 03/04/05 4 17:30 18:30 1.00 PR1 CSG REAM_ OH_ AF Rot /circ /recip pipe 11522 - 11706 ft. Torque (3400}, work free. No cuttings return. Gas 460 units. 03/04/05 4 18:30 19:30 1.00 PR1CSG CIRC_ MUD_ AF 13,771 Cont recip pipe, CBU. Gas 630 units, no gain /loss. 200 spm, 250 gpm, spp 610 psi 03/04/05 4 19:30 21:30 2.00 PR1CSG REAM_, OH_ AF 13,771 Resume RIH 4 1/2 liner on 4" DP to 12236 ft. Take wt (17500 Ib). Rot /circ !recip pipe 12236 - 12579 ft. Torque (3450), work free. No cuttings return, Gas 600 units. 120 spm, 150 gpm, spp 710 psi, No gain /loss 03/04/05 4 21:30 05:00 7.50 PR1CSG RUN_ CSG_ AF 13,771 Resume RIH 4 1/2 liner on 4" DP. Tight hole various intervals 12579 - 13750 ft. Recip /work free. 03/04/05 4 05:00 06:00 1.00 PR1 CSG CIRC_ MUD_ AF 13,771 Circ / cond drlg fluids. Pump carbide /die markers as volume /caliper test. No acc / 2 hrs do time. 03/05/05 5 06:00 12:00 6.00 PR1 CSG CIRC_ MUD_ AF 13,771 Cont circ dye as volume caliper test. Circ #1 = 36°l0 washout, circ #2 = 33% washout. No gain /loss. Wellbore clean. Background gas 35 units. 03!05!05 5 12:00 12:30 0.50 PR1CSG SAFETY MTG_ AF 13,771 Safety meeting, all aspects cmtjob. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date----•-------•-------•-------•- ----------------------------------- Activity -•---------------•--•----Depth-----• -----------------------•-----•------•-----•-•--•-----------------•----- 03(05/05 5 12:30 13:00 0.50 PR1CSG RURD_ CMT_ AF 13,771 PJSM, place cmt equip rig floor, connect all lines to unit, rig up same. 03105!05 5 13:00 16:30 3.50 PR1CSG PUMP CMT_ AF 13,771 Pump 3 bbls H2o, test lines to 4500 psi. Pump 22.5 bbls MCS-4 sweep, 10.5 ppg. Mix I pump 254 bbls slurry (664 sks G, 2.15 yield). Wash lines, drop plug with 5 bbls H2o, confirm plug dropped. Displace cmt with 95.9 bbls gelled KCL, 74 bbls mud (175 bbls). Bump plug with 1250 psi, build to 2700 psi / 10 min. Bleed, floats holding. ICP = 580, FCP = 1250, Avg rate 4 bpm. ^ ^ Lose circ at 225 bbls slurry away, total loss in 2.5 min. Reduce rate to 2 bpm, cease pumping 3 min, build to 2 bpm. Regain circ, returns sporadic, range 0 - 100%. Estimate total losses 100 bbls. No fluid column drop at any time. Plug bumped, cmt in place 1620 hrs. 03/05/05 5 16:30 17:00 0.50 PR1CSG SETREL LNR_ AF 13,771 PJSM, slack off wt to hgr, build press to 3500, set finer hgr. Confirm liner hgr set. Sting out pkr, confirm all seals out. 03/05/05 5 17:00 18:00 1.00 PR1CSG CIRC_ MUD_ AF 13,771 CBU, no cmt returns to surface, no spacer returns. 03/05/05 5 18:00 20:30 2.50 PR1CSG RURD_ CMT_ AF 13,771 PJSM, rig do cmt hd /all related equip, release cmt unit. 03/05/05 5 20:30 06:00 9.50 PR1 CSG LOG CSG TA CPLR 13,771 PJSM, R/U Pollard, run "Quick Temp" temp log on slickline to 11000 ft. POH, download data. Cont download data temp probe R/D Pollard slickline services, release unit, Service rig Wait on temp log evaluation, determine TOC 10350 ft PJSM, Perform infectivity test resulting in 3 BPM at 1520. psi ^ at liner top. PJSM, Fill trip tank, blow do lines, prepare POH 4" DP UD liner setting tool, clear floor. PJSM, RIH 4" DP with Baker squeeze tool. PJSM, place BJ cmt equip rig floor, R/U same. 03/06/05 6 06:00 06:30 0.50 PR1CSG LOG, CSG_ TA CPLR 13,771 03/06/05 6 06:30 07:00 0.50 PR1CSG RURD_ SLIK TA CPLR 13,771 03/06/05 6 07:00 08:00 1.00 PR1CSG SERVIC RIG_ TA CPLR 13,771 03/06/05 6 08:0010:30 2.50 PR1CSG LOG_ CSG_ TA CPLR 13,771 03/06/05 6 10:3011:00 0.50 PR1CSG TEST_ CMT_ TA CPLR 13,771 03/06/05 6 11:0015:30 4.50 PR1CSG TRIP_ DP_ TA CPLR 13,771 03/06/05 6 15:3016:00 0.50 PR1CSG TRIP_ BHA_ TA CPLR 13,771 03/06/05 6 16:00 20:00 4.00 PR1CSG TRIP_ DP_ TA CPLR 13,771 03/06/05 6 20:00 21:00 1.00 PR1CSG SQUEZE CMT_ TA CPLR 13,771 Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date - .Activity -------------------------Depth ..... ---------------------------------------------------------._.. 03/06/05 6 21:00 02:00 5.00 PR1 CSG SQUEZE CMT_ TA CPLR 13,771 PJSM, Sting in /set liner top sgeeze tool, squeeze liner top (7050 - 10350, 4 1/2 X 6 1/8 annulus)^ Pump 5 bbl H2o, test lines to 4500 psi. Pump 5 bbls H2o, mix /pump 500 sks (G, 12.7 ppg, 2.15 yld)^i Total slurry 200 bbls. Hold back press through choke initial 65 bbls. Close choke, begin sgeeze to liner top annulus. Initial press 1200 psi / 3.5 bpm, final 1080 psi / 1 bpm, peak 1529 psi. Follow cmt with 5 bbls H2o / 64 bbls mud, leaving 1 bbl in DP Bleed, open annulus, flow check. Drop wiper dart, confirm dart dropped. CBU, 3.5 bbls cmt returns to surface. Cont circ clean. 03/06/05 6 02:00 02:30 0.50 PR1CSG SETREL PKR_ TA CPLR 13,771 Set ZXP Pkr with 45000 Ibs do wt. Confirm set with do wt. 03/06/05 6 02:30 06:00 3.50 PR1CSG TRIP DP_ AF 13,771 PJSM, POH 4" DP for liner top dress off. 03/07/05 7 06:00 07:00 1.00 PR1CSG TRIP_ DP_ AF 13,771 Cont POH 4" DP, lay out liner run tool 03/07/05 7 07:00 09:30 2.50 PR1CSG TRIP_ DP_ AF 13,771 PJSM, MU {finer top mill, RIH with 4" DP 03/07/05 7 09:30 10:00 0.50 PR1 CSG CLNOUT CSG_ AF 13,771 Clean out /polish liner top at 7049 ft, no indication of debris 03/07/05 7 10:00 12:00 2.00 PR1CSG CLEAN_ TANK AF 13,771 Circ fluids while clean mud pits, no debris / cmt to surface 03/07/05 7 12:0016:00 4.00 PR1CSG MIX FLD AF 03/07/05 7 16:0017:30 1.50 PR1CSG TEST_ CSG_ AF 03/07/05 7 17:30 03:00 9.50 PRICSG PULD_ DP_ AF 03/07/05 7 03;00 06:00 3.00 PR1TIE TEST BOPE AF 03/08/05 8 06:0010:00 4.00 PR1TIE TEST BOPE AF 13,771 Mix /pump inhibited 6% KCL (Congor 303A) through hole volume 13,771 PJSM, prepare /test 4 1/2 X 7 liner lap to 1500 psi 130 min. Test successful, no re-tests. 13,771 PJSM, POH laying do 4" DP, lay out liner mill, clear floor. 13,771 PJSM, prepare for test BOPE, pull mouse hole, clean out same, ^ PJSM, change pipe rams (4 to 4 1/2}, pull wear bshg, MU test plug^ and test jt, RU test pump /lines. 13,771 PJSM, test BOPE, 250/2500 psi / 5 min. To include rams, annular, choke mnfld, kill lines, mud lines^ to pump, all floor valves, top drv equip. Accumulator press / volume test, gas alarm function. Three re-tests, kill line check (debris in valve), increase accumulator press. Re- connect Epoch to pits. 13,771 Rack /strap 4 1/2 tbg. 03/08/05 8 10:0012:00 2.00 PR1TIE PULD TBG AF Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ------- ---------------- --------- ------------ ------------- -Activity-- -----...._. .------..... Depth------ -------------------------------------.....----------------------------- 03/08/05 8 12:00 13:00 1.00 PR1TIE SAFETY MTG_ AF 13,771 One hour stand down safety meeting, review all hands and support personnel, relay MOC conference call info. 03/08/05 8 13:00 15:00 2.00 PR1TIE PULD_ EQIP AF 13,771 PJSM, place tbg run equip rig floor, R/U same. 03/08/05 8 15:00 16:00 1.00 PR1TIE PULD_ BHA_ AF 13,771 M/U seal assy on 4 1/2 tbg, inspect all seals. 03/08/05 8 16:00 16:30 0.50 PR1TIE PULD TBG_ TA MSTB 13,771 Change out failed tbg tong power pack 03/08/05 8 16:30 01:30 9.00 PR1TIE PULD_ TBG_ AF 13,771 PJSM, follow seal assy with 4 1/2, 12.6#, L80, BTC tbg, inj mandrel at 2406 ft. 166 jts total. 03/08/05 8 01:30 04:00 2.50 PR1TIE PULD_ TBG_ AF 13,771 PJSM, Sting in PBR, space out, M/U tbg hgr, land hgr. Mule shoe at 7066, locator at 7048. 03/08!05 8 04:00 05:00 1.00 PR1TIE TEST_ WLHD AF 13,771 Run in LD screws, test wellhead /hgr seals to 5000 psi. 03/08/05 8 05:00 06:00 1.00 PR1TIE TEST_ TBG_ AF 13,771 03/09/05 9 06:00 06:30 0.50 PR1TIE PULD_ EQIP AF 13,771 03/09/05 9 06:3011:00 4.50 PR1TIE NUND BOPS AF 13,771 03/09/05 9 11:0013:30 2.50 PR1TIE NUND TREE AF 13,771 03/09/05 9 13:3014:30 1.00 PR1TIE TEST_ TREE AF 13,771 03/09/05 9 14:30 06:00 15.50 RDMO RURD_ RIG_ AF 13,771 03/10/05 10 06:00 12:00 6.00 RDMO RURD RIG_ AF 13,771 Prepare and test tbg /seal assy 500 psi / 15 min, Test successful, no re-test. PJSM, remove all tbg run equip rig floor PJSM, Set BPV, nipple do BOPE PJSM, install prod tree PJSM, Test primary I secondary seats, all valves /related equip to 5000 psi / 15 min. Test successful, no re-tests. Install BPV, confirm seated. PJSM, rig do rig floor, choke mnfld, kill line, fill fine, top drv, torque tube, derrick board, clean pits, mud pumps, shock hoses, partial load out trailers, lock 1 tag out all lines / connections. PJSM. R!D conex stairs to rig floor, Beaver slide, and catwalk. R/D panic line, carrier tarps, and mufflers, and drillers console. Shut down boiler, pull traps and blow down. R/D cuttings tank. Disconnect lower standpipe and cement line. Load out catwalk. R/D steam fines. 03/10/05 10 12:00 14:30 2.50 RDMO RURD_ RIG_ AF 13,771 PJSM. Scope down derrick and prep to lay over. R/D external lights. Blow down and R/D water tank. Load hanson tank and pump#3. R/D camp, Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------------------------------------------------------------------Activity-------------------......Depth---------------------------------------------•------------------------------- 03/10/05 10 14:30 00:00 9.50 RDMO RURD RIG AF 13,771 PJSM. Con't R/D operations. R/D conex stairs, bever slide & catwalk, panic line, carrier tarps, carrier mufflers, drillers console. Shut down boiler, drain traps, & blow down boiler. R/D cuttings tank & disconnect lower stand pipe & cmt Iline. R/D steam lines & load out catwalk. Move and R/U camp. ^ 0 No accidents & no injuries reported^ 0 Rig released to Ninilchik State#1 OO:OOhrs 03/10/2005. • Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ..._...Activity -------------------------Depth.............--------------........----------•-------------------------...__. 2005 Post-Rig Completion Event:_ 03/20/05 1 08:00 09:30 1.50 CLNOUT RURD SLIK AF Pollard wire line on location. Held PJSM and discussed procedure. Went over safety and environmental issues. Note: previous day equipment spotted on location. 03/20/05 1 09:30 10:30 1.00 CLNOUT TRIP_ TOOL AF MU 1 3/4" tool sting with RS, KJ, 5' stem, 5' roller stem, KH, 5' stem, 3' roller stem, kj, OJ, Sj with a 3.8" GR. RIH to tag fill. 03/20/05 1 10:30 11:30 1.00 CLNOUT TAG PKR AF GR sat down at 7068' KB at top of packer. Tried to move _ _ past would not, POOH 03/20/05 1 11:30 15:30 4.00 CLNOUT TRIP_ TOOL AF MU 3.8" tapered swedge with same tool string. RIH to 7344' KBD, sat down was able to work too string to 7527' KBD. no progress, POOH. Discussed the potetial of mud in well bore, tools seem to be slowing down so slow and then stopping as if the toosl are pushing something down hole. 03/20/05 1 15:30 17:50 2.33 CLNOUT TRIP_ TOOL AF MU a 2 1!2" DD bailer to try and get a sample and see how far we can get the tools down. RIH tagged up at 10320' KBD worked the tool string down to 13621' KBD. POOH with DD baiter. 03/20/05 1 17:50 18:30 0.67 CLNOUT TRIP_ TOOL AF OOH sample of Cement in bailer. 03/20/05 1 18:30 20:30 2.00 CLNOUT RURD_ SLIK AF RD slick line unit, cleaned up around well head. Depart location. ^ -Note: the sample of Cement is in office 03/24/05 2 09:00 11:00 2.00 CLNOUT RURD_ COIL AF BJ CT arrived on location. Obtain work permit. Held PJSM. Spot coil, crane and pumping unit around tree. 03/24/05 2 11:00 14:00 3.00 CLNOUT RURD_ COIL AF MU hard lines from coil through coke and flow back tank. Moved 500 bbls of water to supply tank. Hooked up the filter pod to recycle fluid during wash. 03/24/05 2 14:00 16:00 2.00 CLNOUT NUND BOPS AF Hammer up the BOP to the tree. BJ left lease. 03/25/05 3 07:00 07:50 0.83 CLNOUT RURD_ COIL AF BJ CT on location. Obtain a work permit, held PJSM and discussed operation. Coil 1 3/4" with dimple on connector, double check, boss, 3.$" four bladed centralizer, 3/8" dual circ sub, 1 314" chisel nozzle with 7 jets Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ----------Actiyi~!-------------------------Depth ---- --------....-•----------------------------------------------.._...------ 03/25/05 3 07:50 09:45 1.92 CLNOUT TEST_ BOPE AF PU injector and stabbed on BOP's. Loaded coil with 29 bbls FRESH WATER. PT BOPs, small leak at tree connection. S/D tighten connection continue with PT. Low pressure shell tested at 200 psi, high 4500 psig. Test good. 03/25/05 3 09:45 10:20 0.58 CLNOUT TEST_ BOPE AF Bled down closed blinds, PT blinds 200 psig, high 4500 psig, good tested. Open blinds, RIH closed tubing rams, PT @ same pressures held. Open tubing rams. Open 03/25/05 3 10:20 11:33 1.22 CLNOUT PUMP_ WTR_ AF well head. RIH pumping FRESH WATER at min rate of 0.5 BPM. CT~ at 4500, pull test coil at 7500 Ibs, continue in well. Returns to tank clean. 03/25/05 3 11:33 12:00 0.45 CLNOUT REPAIR EQIP TA MSCT When coi! at 6060' small leak below the injector. Stopped coil to tighten Bowen connection. WHP 4 psig, coil at 0 psig. Tighten connection stopped leak. Continue down hole. 03/25/05 3 12:00 13:10 1.17 CLNOUT PUMP_ WTR_ AF Coil at 10, 790' CTD, making coil pu to check weight at 2000' bites, good return to flow back tank. Increase FRESH WATER rate to 2.0 BPM. Returns brown, creamy and smells like cement. 03/25/05 3 13:10 14:35 1.42 CLNOUT WORK COIL AF Worked coil down to 13, 570' CTD, Pump rate at 2.0 BPM. PU weight at 24, 000 Ibs at this depth. PIP= 3900 psig, WHP= 110 psig, CT pressure= 3900 psig 03/25/05 3 14:35 14:50 0.25 CLNOUT PUMP_ WTR_ AF Increase PIR= 2.25 BPM, PIP= 3900 psig, WHP 110 psig, coil at 13,570' CTM. 03/25/05 3 14:50 15:00 0.17 CLNOUT PUMP_ WTR_ AF Shut down pump, drop 3/8" ball, start pump back at 2.25 BPM, PIP= 3900 psig, WHP= 115 psig, CT at^ 13, 570' CTM. 03/25/05 3 15:00 15:10 0.17 CLNOUT TRIP_ TOOL AF Ball seated shifted sub, pressure @ 3900 psig, PIR= 2.4 BPM, WHP= 115 psig, returns to tank, brown with thicker fluid, solid flakes in samples. Continue POOH with coil at 50 FPM. 03/25/05 3 15:10 16:33 1,38 CLNOUT TRIP_ TOOL AF PU weight at 13570' = 24, 000 Ibs. Monitoring tank returns while filtering water over to supply tank. Returns are still very dirty. 03/25/05 3 16:33 20:40 4.12 CLNOUT TRIP,_ TOOL AF Coil at 10, 600' CTM, decrease POOH speed to 35 FPM from the 70 degree angle pipe up to 1000'. Returns light brown and loose. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------- ------- ---------------- ----------------------------------- -Activity -----------......-------.Depth ---- ...-------------------------------------- 03/25/05 3 20:40 20:45 0.08 CLNOUT PUMPr TRET AF Coil at surface pump 6 BBLs 50150 methanol to freeze protect the coil, started up the N2 unit. Blow down coil wtih the N2. 03/25/05 3 20:45 20:50 0.08 CLNOUT RURD_ COIL AF Vac truck arrive to pull off the liquids from pump unit, hoses and tanks. Shut in well, blow down the reef and back side of reel. Lay down the injector and secured around well head. 03/25/05 3 20:50 21:10 0.33 CLNOUT RURD_ COIL AF BJ coil tech left lease. 04/09/05 4 07:30 08:00 0.50 PR1CSG SAFETY MTG_ AF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. 04/09!05 4 08:00 09:30 1.50 PR1CSG RURD_ ELEC AF Spotted Expro wirelme unit and crane truck. Removed night cap and installed WL valve. MU 7' long 3-118" weight bar, CCL/GR, and SCMT bond fogging tool to Wireline. Oilfield Hot Shot Service delivered MOC methanol skid with Haskel pump from Susan Dionne Pad. 04/09/05 4 09:30 12:00 2.50 PR1CSG RUNPUL ELEC AF RIH with Bond Log and tagged PBTD at 13,633' KB. Let THP increase to 1150 psi due to displacement while RIH with logging tools. Increased THP to 1600 psi by pumping methanol into Expro pump-in tee using MOC methanol skid. 04/09/05 4 12:00 13:00 1.00 PR1CSG RUNPUL ELEC AF Correlated depth with Precision Energy Services (PES) Array Induction openhole log run 27-Feb-2005. Logged 200' repeat section with 1600 psi THP to eliminate microannulus effect. 04/09/05 4 13:00 17:00 4.00 PR1CSG LOG_ CSG_ AF Lagged CCUGR/SCMT from 13,633' to 6900' KB at 32 fpm and with 1600 psi applied THP (fresh water in hole). 04/09/05 4 17:00 18:00 1.00 PR1CSG RUNPUL ELEC AF Bled off 1600 psi applied pressure and POOH with bond logging toots. 04/09/05 4 18:00 19:00 1.00 PR1CSG RURD_ ELEC AF RDMO Expro Wireline. 08/25/05 5 07:30 08:00 0.50 CMPPRF SAFETY MTG_ AF Rigged BJ coiled Tubing to reverse well dry for perforating. Pressure test all lines valves to 4500. Full BOP test to 4500 psi. 08/26/05 6 07:00 07:30 0.50 CMPPRF SAFETY MTG_ AF PJSM and permit at SD office. 08/26/05 6 07:30 11:00 3.50 CMPPRF RURD COIL AF RU BJ and Pressure test stripper to 4000 psi 08/26/05 6 11:00 17:00 6.00 CMPPRF JET_ N2_ AF RIH CT. Start reversing with N2 at 500' at 500 SCFlmin. Reverse well dry to 13,185', and POH. Trapped 1100 psi surface nitrogen pressure. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date --•-------Activity ..-------•---------------Depth __......-•---------------•--•--•-----------------------•--•---------•-----.. 08/26/05 6 17:00 20:30 3.50 CMPPRF RURD_ COIL AF RD and release BJ CT. 09/01/05 7 07:30 08:00 0.50 CMPPRF SAFETY MTG_ AF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. ASRC hauled off 20% KCL water stored in tank and fresh water jetted from well to G&I yesterday. ASRC vac truck driver on location to pull a partial load of water to support lubricator and flowback iron pressure test. 09/01/05 7 08:00 10:00 2.00 CMPPRF RURD, ELEC AF MIRU Expro perforators. MU lubricator and grease head _ . Install WL valve and pump-in tee on top of swab valve. Spot MOC methanol pump skid and air compressor. Take lubricator to wellhead without guns. Pressure tested lubricator to 500 psi low and 3000 psi high with fresh water. Released pressure and drained lubricator to flowback manifold. Pressure tested MOC chicksan and flow back manifold to 500 psi low and 3000 psi high with fresh water. Bled off pressure to tank. 09/01/05 7 10:00 10:30 0.50 CMPPRF RUNPUL ELEC AF Armed 15' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 14' with SDP-3125- 311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 09101!05 7 10:30 12:30 2.00 CMPPRF PERF^ CSG_ AF Correlated depth with CBL and Array Induction logs. Perforated 12840-12854' MD with 1100 psi surface nitrogen pressure. 09/01!05 7 12:30 13:30 1.00 CMPPRF RUNPUL ELEC AF POOH with guns for 15 minutes and SICP remained constant at 1100 psi. Bled pressure off of lubricator. LD pert gun. All shots fired and round. 09/01/05 7 13:30 14:00 0.50 CMPPRF RURD_ ELEC AF Armed 20' 3-318" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125- 311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. Bled nitrogen pressure down to 1050 psi while RIH. 09!01!05 7 14:00 16:00 2.00 CMPPRF PERF_ CSG_ AF Correlated depth with CBL and Array Induction logs. Perforated 12606-12626' MD with 1050 psi surface nitrogen pressure. Pressure built to 1200 psi in 5 min, 1250 psi in 10 min, and 1300 psi in 15 min. SICP at 2100 psi one hour after perforating. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ----------•-------------------------------------------- Activity -------------------------Depth ---- -----......-----------•- 09l01l05 7 16:00 17:30 1.50 CMPPRF RUNPUL ELEC AF POOH with guns. Bled pressure off of lubricator. LD perf gun, All shots fired and round. 09/01/05 7 17:30 19:00 1.50 CMPPRF RURD_ 0 AF Rig back Expro. Will flow test well overnight maintaining at least 1100 psi FTP and discuss point-forward plan in the AM. 09/03/05 8 07:30 08:00 0.50 CMPPRF SAFETY MTG_ AF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Well had been flowed to sales for 24 hours (1700 hrs 8/31/2005 to 1700 hrs 9/1/2005). Shut well in for a short PBU overnight SICP at 7 AM on 9/2/2005 was 2665 psi in AM rs . . 09/03/05 8 08:00 09:00 1.00 CMPPRF RURD_ ELEC AF MU Spartec real-time pressure-temperature gauge with bowspring centralizers, weight bars, and CCL. Pulled tools into lubricator and took lubricator to tree. Pressure tested lubricator to 2665 psi with WHP. 09/03/05 8 09:00 09:30 0.50 CMPPRF RURD_ ELEC AF RIH with PR tools to about 2000' MD. Could not get tools to drop. POOH with tool string and bled pressure off of lubricator. Added another weight bar to tool string. MOC Operators blew down flowline to remove obstruction (small rocks) from EFM while Expro out of hole with tool string. 09/03/05 8 09:30 14:00 4.50 CMPPRF RUNPUL ELEC AF RIH with P/T tools to 13,000' MD logging down pass from 12500'. Logged up pass to 12,500' MD noting static fluid level at 12840' MD (top perf of lower interval perfed). Static BHP was 3173 psig at 12840' and 3155 psig at 12606' MD. Took static benches at 12000, 11000, 10000, 8000, 6000, 4000, and 2000' MD while POOH with logging tools. Bled pressure off of lubricator. 09!03/05 8 14:00 14:30 0.50 CMPPRF RURD! ELEC AF LD P-T tool string. Began flowing well to sales to achieve drawdown for perforating. 09/03/05 8 14:30 15:30 1.00 CMPPRF RUNPUL ELEC AF Armed 25' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 22' with SDP-3125- 311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 09/03/05 8 15:30 16:00 0.50 CMPPRF PERF^ CSG_ AF Correlated depth with CBL and Array Induction logs. Perforated 12564-12586' MD with 1100 psi surface gas pressure flowing 1.3 MMscfd (EFM not working properly to completely shut in). Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------------------------------------------------------------------Activity -----•----------------... Depth ---- --------• 09/03/05 8 16:00 17:00 1.00 CMPPRF RUNPUL ELEC AF POOH with guns for 15 minutes and began opening the EFM (started at 1330 psi at 1.6 MMscfd). Guns at surface, Well flowing 3.7 MMscfd at 1125 psi FTP. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 09/03/05 8 17:00 18:00 1.00 CMPPRF RURD^ ELEC AF Rigged down Expro wireline equipment from the tree. Will leave Expro equipment at the wellsite in anticipation of adding more perforations on 9/6/2005. Plan to flow the well to sales maintaining the FTP above 1100 psi. 09/07/05 9 07:00 07:30 0.50 CMPPRF SAFETY MTG_ AF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Flowed well since 9/2/2005 at a relatively stable rate of 3.45 MMscfd at 1100 psig FTP. 09/07/05 9 07:30 08:30 1.00 CMPPRF RURD_ ELEC AF Expro reheaded wireline and filled grease injection pump reservoir. Install WL valve and pump-in tee on top of swab valve. 09/07/05 9 08:30 10:00 1.50 CMPPRF RUNPUL ELEC AF Armed 20' 3-318" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125- 311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 09!07/05 9 10:00 10:30 0.50 CMPPRF PERF_ CSG_ AF Correlated depth with CBL and Array Induction logs. Perforated 12648-12668' MD with 1150 psi surface gas pressure flowing 1.38 MMscfd (EFM not working properly to completely shut in). 09/07/05 9 10:30 11:30 1.00 CMPPRF RUNPUL ELEC AF POOH with guns for 10 minutes with rate 1.38 MMscfd at~ 1260 psi. Opened well choke steadily while POOH with pert gun. Rate at 3.47 MMscfd at 1110 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 09/07/05 9 11:30 13:00 1.50 CMPPRF RUNPUL ELEC AF Armed 20' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125- 311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 09/07!05 9 13:00 13:30 0.50 CMPPRF PERF_ CSG_ AF Correlated depth with CBL and Array Induction logs. Perforated 12378-12398' MD with 1150 psi surface gas pressure flowing 1.36 MMscfd (EFM not working properly to completely shut in). Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------------------------------------------------------------------Activity----------._._.......----Depth.---------...._...--------------•-- ----- ----------------------------------------- 09/07/05 9 13:30 15:00 1.50 CMPPRF RUNPUL ELEC AF POOH with guns for 10 minutes with rate 1.54 MMscfd at 1260 psi . Opened well choke steadily while POOH with pert gun. Rate at 3.46 MMscfd at 1100 psig FTP when OOH. Bled pressure off of lubricator, LD perf gun. All shots fired and round. 09/07/05 9 15:00 15:30 0.50 CMPPRF RURD_ ELEC AF Rigged down Expro wireline equipment from the tree. Will leave Expro equipment at the wellsite in anticipation of adding more perforations tomorrow. Plan to flow the well to sales maintaining the FTP above 1100 psi. 09/08/05 10 07:00 07:30 0.50 CMPPRF SAFETY MTG 09/08/05 10 07:30 08:00 0.50 CMPPRF RURD ELEC 09/08/05 10 08:00 09:30 1.50 CMPPRF RUNPUL ELEC 09/08/05 10 09:3010:00 0.50 CMPPRF PERF CSG 09/08/05 10 10:00 11:00 1.00 CMPPRF RUNPUL ELEC 09/08/05 10 11:00 12:30 1.50 CMPPRF RUNPUL ELEC 09/08/05 10 12:3013:00 0.50 CMPPRF PERF CSG AF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Flowed well overnight at a relatively stable rate of 3.42 MMscfd at 1100 psig FTP. AF Install WL valve and pump-in tee on top of swab valve. Reviewed MOC Perforating Safety Checklist. AF Armed 25' 3-3l8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 22' with SDP-3125- 311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. AF Correlated depth with CBL and Array Induction logs. Perforated 12626-12648' MD with 1150 psi surface gas pressure with the well shut in at the line heater block valve. r1 ILJ AF POOH with guns for 10 minutes with SITP climbing to 1340 psi. Opened we11 choke steadily while POOH with pert gun. Rate at 3.48 MMscfd at 1095 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. Alf shots fired and round. AF Armed 25' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD pertorating gun loaded 24' with SDP-3125- 311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. AF Correlated depth with CBL and Array Induction logs. Pertorated 12354-12378' MD with 1150 psi surface gas pressure with the well shut in at the line heater block valve. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date -------. Activity ------------------------- depth ---- ----------------------------------------------- 09/08/05 10 13:00 14:00 1.00 CMPPRF RUNPUL ELEC AF POOH with guns for 10 minutes with rate 1.54 MMscfd at 1260 psi . Opened well choke steadily while POOH with perf gun. Rate at 3.41 MMscfd at 1100 psig FTP when OOH. Bled pressure off of lubricator. LD pert gun. All shots fired and round. 09/08/05 10 14:00 15:00 1.00 CMPPRF RUNPUL ELEC AF Armed 25' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 25' with SDP-3125- 311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on 09/08/05 10 15:00 15:30 0.50 CMPPRF PERF_ CSG_ AF CCL. Correlated depth with CBL and Array Induction logs. Perforated 12242-12267' MD with 1150 psi surface gas pressure with the well shut in at the line heater block valve. 09/08/05 10 15:30 16:30 1.00 CMPPRF RUNPUL ELEC AF POOH with guns for 10 minutes with rate 1.67 MMscfd at 1320 psi . Opened well choke steadily while POOH with pert gun. Rate at 3.57 MMscfd at 1100 psig FTP when OOH. Bled pressure off of lubricator. LD pert gun. All shots fired and round. 09/08/05 10 16:30 17:30 1.00 CMPPRF RURD_ ELEC AF Rigged down Expro wireline equipment from the tree. Will leave Expro equipment at the wellsite in anticipation of adding more perforations tomorrow. Plan to flow the well to sales maintaining the FTP above 1100 psi. 09/09/05 11 08:00 08:30 0.50 CMPPRF SAFETY MTG_ AF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Flowed well overnight at a relatively stable rate of 3.54 MMscfd at 1110 psig FTP. 09/09/05 11 08:30 09:00 0.50 CMPPRF RURD_ ELEC AF Install WL valve and pump-in tee on top of swab valve. Reviewed MOC Pertorating Safety Checklist. 09!09!05 11 09:00 10:00 1.00 CMPPRF RUNPUL ELEC AF Armed 18' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 15' with SDP-3125- 311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 09!09/05 11 10:00 10:30 0.50 CMPPRF PERFr CSG_ AF Correlated depth with CBL and Array Induction logs. Pertorated 12223-12238' MD with 1120 psi surface gas pressure with the well shut in at the line heater block valve. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ...................Activity -•-----------------------Depth ---- ---------------------------------------------------- -------------------------•-----•-------------- -------------------------- 09/09/05 11 10:30 12:00 1.50 CMPPRF RUNPUL ELEC AF POOH with guns for 10 minutes with SITP climbing to 1340 psi. Opened well choke steadily while POOH with perf gun. Rate at 3.87 MMscfd at 1110 psig FTP when OOH. B{ed pressure off of lubricator. LD perf gun. All shots fired and round. 09/09/05 11 12:00 13:00 1.00 CMPPRF RUNPUL ELEC AF Armed 20' 3-318" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 17' with SDP-3125- 311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on 09/09/05 11 13:00 13:30 0.50 CMPPRF PERF_ CSG_ AF CCL. Correlated depth with CBL and Array Induction logs. Perforated 11956-11973' MD with 1130 psi surface gas pressure with the well shut in at the line heater block valve. 09/09/05 11 13:30 14:30 1.00 CMPPRF RUNPUL ELEC AF POOH with guns for 10 minutes with SITP climbing to 1340 psi. Opened well choke steadily while POOH with perf gun. Rate at 3.48 MMscfd at 1095 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 09/09/05 11 14:30 16:00 1.50 CMPPRF RUNPUL ELEC AF Armed 11' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 10' with SDP-3125- 311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 09/09/05 11 16:00 16:30 0.50 CMPPRF PERF_ CSG_ AF Correlated depth with CBL and Array Induction logs. Perforated 11830-11840' MD with 1110 psi surface gas pressure with the well shut in at the line heater block valve.. 09/09/05 11 16:30 17:30 1.00 CMPPRF RUNPUL ELEC AF POOH with guns for 10 minutes with SITP climbing to 1470 psi. Opened well choke steadily while POOH with perf gun. Rate at 5.56 MMscfd at 1132 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 09/09/05 11 17:30 19:00 1.50 CMPPRF RURD,_ ELEC AF RDMO Expro Perforators. Returned well to sales maintaining no lower than 1100 psig FTP. 09!14/05 12 08:00 09:00 1.00 CMPPRF SAFETY MTG_ AF Move in and rig up wire line equipment, Held PJSM and discussed job site hazards prior to making up tool string. Met with operators and held JSA. MU 20' with 3.375" OD perforating gun loaded with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date------ -------------•----------- -----------•------......-----•-----Activity----------•-------.......Depth ---- -------------••---------------...----------------------•--------•------- 09/14/05 12 09:00 09:30 0.50 CMPPRF RURD,_ ELEC AF Held pre job arming safety meeting prior to arming gun. Shut down modems, cell phones and station person at gate. PU gun and opened up well. 09/14!05 12 09:30 10:00 0.50 CMPPRF RUNPUL ELEC AF RIH with gun #1, to perforate from 10866' to 10886' 20' gun. 09/14/05 12 10:00 11:00 1.00 CMPPRF RUNPUL ELEC AF Gun at 3000' problem falling in well with well flowing at 5.1 MMCFPD at 1100 psig at tree. Close control valve to reduce flow while running in well with gun. 09/14/05 12 11:00 11:30 0.50 CMPPRF RUNPUL ELEC AF Flow rate adjusted down to 1246 psig at 3789 MMCFPD. Open well up to bring down pressure prior to perforating by~ opening control valve. 09/14/05 12 11:30 12:00 0.50 CMPPRF RUNPUL ELEC AF Continue with tie in to array induction log with CBL to get gun on depth to perforate. CBL 4' deep to open hole log. Make correction, PU gun to pert depth. 09/14/05 12 12:00 12:30 0.50 CMPPRF PERF_ CSG_ AF Shut in well to perforate from 10866' to 10886' DIL. Well shut in to perforate, POOH with gun. Pressure was 1200 psig when gun fired. Monitor well while pulling out of hole. 09/14/05 12 12:30 13:00 0.50 CMPPRF RUNPUL ELEC 09!14/05 12 13:00 13:30 0.50 CMPPRF RUNPUL ELEC 09/14/05 12 13:30 13:50 0.33 CMPPRF RUNPUL ELEC 09/14/05 12 13:5014:50 1.00 CMPPRF PERF CSG 09/14/05 12 14:50 15:05 0.25 CMPPRF RUNPUL ELEC 09/14/05 12 15:05 15:40 0.58 CMPPRF RUNPUL ELEC AF OOH with gun, all shots fired. Monitor pressure for 30 minutes prior to making up second perforation run. After 30 minutes well at 1138 psig, 5600 MCF with 80% open on the control valve. 6 BBIs water produced to tank. AF Make up gun #2, 20'- 3.375" OD gun as before. Go to communication black out prior to arming gun with safe • firing system. Well flowing at 5600 MCFPD at 1120 psig. AF RIH with #2 gun to perforate from 10612' to 10632' DIL. Correlated CBL to array induction log, corrected depth by 5' to get on depth to perf interval. AF Shut well in to perforate. WHP built to 1140 psig, fired gun and POOH with gun. Monitor pressure for 10 minutes. AF WHP= 1600 psig after 10 minutes shut in. Open well to production to monitor well. AF Wefi flowing while POOH with gun, Wire at 4000'. Marathon Oil Corp. Ninilchik Unit, G Osko #3 204-255 Report Rept # From To Hours Phase Activity Sub Status T Type To Operations Date ----------------•-------- Activity!......-------------------Depth -.-- ---------------...... 09/14/05 12 15:40 16:40 1.00 CMPPRF RURD_ ELEC AF OOH with gun, shut in swab. bled down the lubricator and confirmed all shots fired. Continue to monitor well. RD wireline unit. 09/14/05 12 16:40 17:30 0.83 CMPPRF FLOW_ TEST AF Secure well left lease at 1730 well making 5250 MCFPD at 1095 psig. No water to surface. 10/08/05 13 08:00 08:30 0.50 PRDTST SAFETY MTG_ CS Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Well flowing at a relatively stable rate of 4.53 MMscfd at 1075 psig FTP. Placed well in test to closely monitor gas and • water rates. 10/08/05 13 08:30 10:00 1.50 PRDTST RURD_ ELEC CS MIRU Expro Wireline to run areal-time pressure- temperature (P-T) flowing BHP. Spotted equipment. RU lubricator, WL valve, and flow tee. 10/08/05 13 10:00 13:00 3.00 PRDTST LOG_ OTHR CS PU and RIH with centralizer spring, 1.375" OD Spartec PLT tool w/CCL, centralizer spring, and two (2) 1-11116" weight bars on wireline. Observed a fluid component starting at 1000' from surface while RIH (probably low side fluid}. Logged 10500'-12950' MD on down pass. Took 5 minute bench at 12,950' MD recording 1653 psig and 139.9 deg F. Did not see any positive indication of a producing fluid level. Did note strong warming trend about 10' below the top of the pert interval, 12606'-12688' MD. 10/08/05 13 13:00 15:00 2.00 PRDTST LOG! OTHR CS POOH logging P-T up pass 12950-10500' MD. POOH taking 5 min. benches at 10500', 9500', 8000', 6000', 4000', 2000', and at surface. Did not observe any positive indication of a producing fluid level. Did not swab any fluid to surface. Final rate at 4.45 MMscfd at 1085 psig FTP. 10/08/05 13 15:00 16:00 1.00 PRDTST RURD_ ELEC CS RDMO Expro Wireline. Left well flowing to sales, • • TOP BOTTOM TVD TVD Test Results t t 10612 10658 5244 5283 Add perfs 10612-10632 9/13/2005 Flowing 5.6 MMCFPD @ 1138# FTP before Flowing 5.25 MMCFPD @ 1095# FTP after 10844 10886 5447 5484 Add perfs 10866-10866 9/13/2005 Flowing 5.1 MMCFPD @ 1100# FTP before Flowing 5.6 MMCFPD @ 1138# FTP after '11830 11840 6345 6357 Add pen`s 11830-11840 9/08/2005 Flowing 3.48 MMCFPD @ 1095# FTP before Flowing 5.56 MMCFPD @ 1132# FTP after 11960 11966 ' 6464 6480 Add perfs 11956-1197 9/08/2005 Flowing 3.87 MMCFPD @ 1110# FTP before Flowing 3.48 MMCFPD @ 1095# FTP after 12223 12272 6712 6758 Core interval Add perfs 12242-12267 9/07/2005 Flowing 3.41 MMCFPD @ 1100# FTP before : :Flowing 3.57 MMCFPD @ 1100# FTP after Add perfs 12223-12238 9/08/2005 Flowing 3.54 MMCFPD.@ 1110# FTP before ' flowing 3.87 MMCFPD @ 1110'# FTP after 12354 12398 6834 6875 Add perfs 12378-12398 9/06/2005 Flow 1.36 MMCFPD @ 1150 FTP Return to full flow 3.46 MMCFPD @ 1100 FTP Add perfs 12354-12378 9/07/2005 Flowing 3.48 MMCFPD @ 1095#.FTP before `Flowing 3.41 MMCFPD @ 1100# FTP after 12556 12686 7022 7141 Add perfs 12606-12626 08/30/2005w/ 1050# SIWHP N2 cush Press. Built to 1200# SIWHP in 5 min.; to 1250# SIWHP in 10 min. to 1300# SIWHP in 15 min. to 2100# SIWHP in 1 hour Flowed 3.2 MMCFPD @ 1100# FTP after 5 hours Add perfs 12564-12586 09/02/2005 Flowing 12840 12854 7283 7296 Perf 12840-12854 w/ 1100# SIWHP N2 cush No pressure response in 15 min. 08/31/2005 • • GO #3 Ninilchik Unit 3221' FSL & 2914' FEL ~~TMON Sec. 23-T1 N-R13W Conductor 20" K-55 133 ppf PE T~ Bottom MD 0' 99' TVD 0' 99' Surface Casing 9-5/8" 40 ppf L-80 BTC Tory Bottom MD 0' 2507' TVD 0' 1772' 12-1/4" hole with 519 sks (232 bbls) 12 ppg cement with 27 bbls cement to surface. ng String - 4.5", 12.6#, L-80, Hydril 533 r Chemical Injection Nipple @ 2412' MD (Top) 5.930" OD/3.858" ID 8430 psi burst/7500 psi collapse Liner Packer with 15' Tieback Extension @ 7049' MD (Top) _ock Liner Hanger @ 7074' MD (Top) 'r Joints @ 9622-9673' MD (Two 19-20' long) ;r Joints @ 11,691-11,730' MD (Two 19-20' long) ng Collar @ 13,652' MD (Top) Collar @ 13,685' MD (Top) Shoe @ 13,750' MD (Bottom) Radial Bond Log out to 13,570' MD with BJ CT (w/ 3.80" OD centralizer) 2-5/8" Cores: 1.9794'-9875' KB (Cut 81' Recvd 66.9') 2. 12,212'-12,301 KB (Cut 89' Recvd 70.15') Intermediate Casing 7" 26 ppf L-80 BTC TOQ Bottom MD 0' 7320' TVD 0' 3424' 8-112" hole with 305 sks (134.4 bbls) 12.5 ppg Lead + 167 sks (34.7 bbls) 15.8 ppg Tail Plug did not bump, no cement to surface, floats held Tyonek Perfs: MD TVD Gun Date 12,840-12,854, 14 ft 7284-7297' Owen 3.375" 6 SPF 8/31/2005 12,606-12,626, 20 ft 7068-7086' Owen 3.375" 6 SPF 8/31/2005 12,626-12,668, 42 ft 7086-7125' Owen 3.375" 6 SPF 9/06807/2005 12,564-12,586, 22 ft 7029-7049' Owen 3.375" 6 SPF 9/02/2005 12,354-12,398, 44 ft 6835-6875' Owen 3.375" 6 SPF 9/06807/2005 12,242-12,267, 25 ft 6730-6753' Owen 3.375" 6 SPF 9/07/2005 12,223-12,238, 15 ft 6712-6726' Owen 3.375" 6 SPF 9/08/2005 11,956-11,973, 17 ft 6465-6480' Owen 3.375" 6 SPF 9/08/2005 11,830-11,840, 10 ft 6349-6358' Owen 3.375" 6 SPF 9/08/2005 10,866-10,886, 20 ft 5467-5467' Owen 3.375" 6 SPF 9/13/2005 10,612-10,632, 20 ft 5244-5261' Owen 3.375" 6 SPF 9113/2005 TD: 13,771' MD / 8147' TVD Formation Tops: Formation Death (MDl Deoth (TVD) Beluga Tyonek TD Liner 4-1/2" 12.75 ppf L-80 Hydril 533 TOP_ Bottom MD 7049 13750 TVD 3331 8127 6-1 /8" hole with 664 sks 12.7 ppg (No spacer or cement to surface) Lost partial circulation after pumping 230 bbls cement KOP @ 250' MDITVD Build 4.0 deg1100' from 250-2000' Hold 70 deg from 2000-8090' MD Drop 1.5 deg/100'to 11470' MD Hold 23 deg from 11470' to TD at ' MD Report Date: 8-Mar-2005 Client: MARATHON Oil Company Field: Ninilchik Field Structure /Slot: MGO / MGO #3 Well: MGO #3 Borehole: MGO #3 UW I/API#: Wellpath Name: MWD <0-13771> Grid Coordinate System: Alaska State Piane, Zone 4 Location Lat/Long: N60 9 53.0528, W 151 29 14.3257 Location Grid N/E Y/X: 2255186.0000 ft, 229103.6300 ft Grid Convergence Angle: -1.30 deg d Scale Factor: 0.999985 urvey /DLS Computation Method: Minimum Curvature Vertical Azimuth: 255.91 deg Vertical Section Origin: O.OON, 0.00E TVD Reference Datum: RKB TVD Reference Elevation: Rig (Glacier 1 (RKB) 187.Oft above Mean Sea Level ) Sea Bed /Ground Level El evation: 0.00 ft to Mean Sea Level Magnetic Declination: 19.68 deg Total Field Strength: 55243.38 Magnetic Dip: 73.07 deg Declination Date: 1-Oct-2004 Magnetic Declination Model: BGS Global Geomagnetic Model [1945.0-2005.0] North Reference: True Total Corr Mag North to Tr ue North: 19.68 deg Local Coordinates Referenced To: Slot Grid Coordinates Geographic Coordinates MD Inc Azi TVD TVD(SS) VS N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100ft) (ft) (ft) 0 0 0 0 -187 0 0 0 0 2255186 229103.63 N60 9 53.0528 W 151 29 14.3257 99 0.59 37.7 99 -88 -0.4 0.4 0.31 0.59 2255186.39 229103.95 N60 9 53.0568 W 151 29 14.3196 169 1 37.7 168.99 -18.01 -1.16 1.17 0.9 0.59 2255187.15 229104.56 N60 9 53.0643 W 151 29 14.3079 227 0.5 296.1 226.99 39.99 -1.36 1.68 0.98 2.08 2255187.66 229104.65 N60 9 53.0693 W 151 29 14.3062 289 2.4 260 288.97 101.97 0.14 1.57 -0.54 3.25 2255187.58 229103.13 N60 9 53.0683 W 151 29 14.3363 350 4.7 257.2 349.85 162.84 3.91 0.8 -4.23 3.78 2255186.89 229099.42 N60 9 53.0607 W 151 29 14.4093 410 7.3 255 409.51 222.51 10.18 -0.73 -10.31 4.35 2255185.5 229093.3 N60 9 53.0456 W 151 29 14.5295 472 9.4 257.5 470.85 283.85 19.18 -2.85 -19.06 3.44 2255183.58 229084.51 N60 9 53.0247 W 151 29 14.7024 531 11.8 258 528.84 341.84 30.03 -5.15 -29.67 4.07 2255181.52 229073.85 N60 9 53.0021 W 151 29 14.9120 592 14.2 257.9 588.27 401.27 43.74 -8.01 -43.09 3.93 2255178.96 229060.37 N60 9 52.9739 W 151 29 15.1772 Grid Coordinates Geographic Coordinates MD Inc Azi TVD TVD(SS) VS N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100ft) (ft) (ft) 652 17.5 256.2 645.98 458.98 60.12 -11.71 -59.05 5.55 2255175.62 229044.33 N60 9 52.9375 W 151 29 15.4926 712 20.6 256.1 702.69 515.69 79.7 -16.4 -78.06 5.17 2255171.36 229025.22 N60 9 52.8913 W151 29 15.8683 772 23.6 256.8 758.28 571.28 102.27 -21.68 -100 5.02 2255166.58 229003.17 N60 9 52.8393 W 151 29 16.3020 835 26.6 256.7 815.32 628.32 128.99 -27.8 -126.01 4.76 2255161.04 228977.02 N60 9 52.7790 W 151 29 16.8160 897 29.1 255.9 870.13 683.13 157.95 -34.67 -154.15 4.08 2255154.81 228948.74 N60 9 52.7114 W 151 29 17.3720 960 31.6 256.1 924.5 737.5 189.78 -42.37 -185.03 3.97 2255147.81 228917.69 N60 9 52.6355 W 151 29 17.9823 1022 34.6 256.2 976.43 789.43 223.64 -50.47 -217.9 4.84 2255140.45 228884.65 N60 9 52.5557 W 151 29 18.6319 1085 37.7 256.9 1027.29 840.29 260.79 -59.11 -254.04 4.96 2255132.63 228848.32 N60 9 52.4707 W 151 29 19.3461 148 39.4 257.1 1076.56 889.56 300.04 -67.94 -292.3 2.71 2255124.66 228809.88 N60 9 52.3837 W 151 29 20.1021 1209 39.4 257.6 1123.7 936.7 338.75 -76.42 -330.08 0.52 2255117.04 228771.92 N60 9 52.3002 W 151 29 20.8487 1270 40.6 257.3 1170.43 983.43 377.95 -84.94 -368.35 1.99 2255109.38 228733.47 N60 9 52.2163 W 151 29 21.6050 1334 43.1 256.4 1218.1 1031.1 420.64 -94.66 -409.92 4.02 2255100.6 228691.69 N60 9 52.1205 W 151 29 22.4266 1397 45.3 256.2 1263.26 1076.26 464.55 -105.06 -452.59 3.5 2255091.16 228648.79 N60 9 52.0181 W 151 29 23.2698 1458 46.6 255 1305.67 1118.67 508.39 -115.97 -495.05 2.56 2255081.21 228606.1 N60 9 51.9106 W 151 29 24.1089 1524 48.7 254.1 1350.13 1163.13 557.15 -128.97 -542.06 3.34 2255069.27 228558.81 N60 9 51.7826 W 151 29 25.0379 1589 52.2 255.3 1391.52 1204.51 607.25 -142.18 -590.4 5.57 2255057.16 228510.19 N60 9 51.6525 W 151 29 25.9931 1652 54.9 255.7 1428.94 1241.94 657.92 -154.86 -639.46 4.32 2255045.58 228460.86 N60 9 51.5275 W 151 29 26.9626 1715 58.6 256.1 1463.48 1276.48 710.6 -167.69 -690.55 5.9 2255033.9 228409.49 N60 9 51.4011 W 151 29 27.9722 1778 60.9 256.3 1495.21 1308.21 765.01 -180.67 -743.4 3.66 2255022.12 228356.37 N60 9 51.2733 W 151 29 29.0165 1840 63 256.8 1524.37 1337.37 819.72 -193.39 -796.61 3.46 2255010.6 228302.88 N60 9 51.1479 W 151 29 30.0681 1904 65.3 257.3 1552.27 1365.27 877.31 -206.3 -852.74 3.66 2254998.96 228246.48 N60 9 51.0208 W 151 29 31.1773 1967 67.3 257.5 1577.59 1390.59 934.97 -218.88 -909.03 3.19 2254987.65 228189.92 N60 9 50.8969 W 151 29 32.2897 2030 67.8 257.2 1601.65 1414.65 993.18 -231.63 -965.84 0.91 2254976.18 228132.83 N60 9 50.7712 W 151 29 33.4124 2093 68.4 257.8 1625.15 1438.15 1051.61 -244.28 - 1022.91 1.3 2254964.82 228075.5 N60 9 50.6466 W 151 29 34.5401 156 69.4 256.5 1647.83 1460.83 1110.37 -257.36 - 1080.21 2.5 2254953.04 228017.92 N60 9 50.5178 W 151 29 35.6725 219 69.5 256.3 1669.94 1482.94 1169.36 -271.23 - 1137.55 0.34 2254940.46 227960.28 N60 9 50.3811 W 151 29 36.8055 2282 69.2 255.9 1692.16 1505.16 1228.31 -285.39 - 1194.78 0.76 2254927.59 227902.75 N60 9 50.2416 W 151 29 37.9364 2344 69.1 256 1714.23 1527.23 1286.25 -299.45 - 1250.98 0.22 2254914.79 227846.24 N60 9 50.1030 W 151 29 39.0471 2406 69 256.3 1736.4 1549.4 1344.15 -313.32 - 1307.2 0.48 2254902.2 227789.73 N60 9 49.9665 W 151 29 40.1580 2449 69.2 257 1751.74 1564.74 1384.32 -322.59 - 1346.29 1.59 2254893.81 227750.45 N60 9 49.8751 W 151 29 40.9304 2507 69.58 257.15 1772.15 1585.15 1438.59 -334.73 - 1399.2 0.7 2254882.86 227697.27 N60 9 49.7554 W 151 29 41.9760 2525 69.7 257.2 1778.41 1591.41 1455.46 -338.48 - 1415.65 0.7 2254879.49 227680.74 N60 9 49.7185 W 151 29 42.3011 2585 69.9 256.9 1799.13 1612.13 1511.76 -351.10 - 1470.53 0.58 2254868.11 227625.59 N60 9 49.5942 W 151 29 43.3856 2648 69.9 255.3 1820.78 1633.78 1570.92 -365.31 - 1527.96 2.38 2254855.2 227567.86 N60 9 49.4542 W 151 29 44.5204 2711 69.8 255.8 1842.49 1655.49 1630.06 -380.07 - 1585.23 0.76 2254841.73 227510.27 N60 9 49.3087 W 151 29 45.6522 2776 69.9 254.9 1864.88 1677.88 1691.08 -395.50 - 1644.27 1.31 2254827.63 227450.9 N60 9 49.1567 W 151 29 46.8188 2837 69.9 255.8 1885.84 1698.84 1748.36 -409.99 - 1699.69 1.39 2254814.39 227395.17 N60 9 49.0139 W 151 29 47.9139 2901 70.1 256.7 1907.73 1720.73 1808.5 -424.28 - 1758.11 1.36 2254801.42 227336.45 N60 9 48.8731 W 151 29 49.0683 Grid Coordinates Geographic Coordinates MD Inc Azi TVD TVD(SS) VS N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100ft) (ft) (ft) 2964 69.8 256.2 1929.33 1742.33 1867.68 -438.15 - 1815.64 0.88 2254788.85 227278.62 N60 9 48.7364 W 151 29 50.2052 3028 70.1 257.1 1951.27 1764.27 1927.8 -452.03 - 1874.14 1.4 2254776.29 227219.83 N60 9 48.5996 W 151 29 51.3611 3094 70 256.5 1973.79 1786.79 1989.83 -466.20 - 1934.54 0.87 2254763.49 227159.12 N60 9 48.4600 W 151 29 52.5546 3157 69.9 256.5 1995.39 1808.39 2049.01 -480.01 - 1992.08 0.16 2254750.97 227101.28 N60 9 48.3239 W 151 29 53.6918 3219 70.1 255.6 2016.6 1829.6 2107.27 -494.06 - 2048.63 1.4 2254738.21 227044.44 N60 9 48.1854 W 151 29 54.8091 3281 70 255.6 2037.75 1850.75 2165.55 -508.55 - 2105.07 0.16 2254724.99 226987.68 N60 9 48.0426 W 151 29 55.9245 3341 69.8 255 2058.37 1871.37 2221.89 -522.85 - 2159.57 1 2254711.92 226932.87 N60 9 47.9017 W 151 29 57.0015 3404 69.7 254.7 2080.18 1893.18 2280.98 -538.30 - 2216.63 0.47 2254697.76 226875.49 N60 9 47.7495 W 151 29 58.1288 467 69.9 255.4 2101.93 1914.93 2340.1 -553.55 - 2273.75 1.09 2254683.8 226818.04 N60 9 47.5992 W 151 29 59.2576 3530 70 254.8 2123.53 1936.53 2399.28 -568.77 - 2330.94 0.91 2254669.87 226760.52 N60 9 47.4492 W 151 30 0.3877 3593 69.6 253.7 2145.28 1958.28 2458.38 -584.81 - 2387.84 1.76 2254655.11 226703.27 N60 9 47.2910 W 151 30 1.5121 3657 69.8 253.4 2167.49 1980.49 2518.35 -601.81 - 2445.41 0.54 2254639.42 226645.33 N60 9 47.1235 W 151 30 2.6497 3720 70 254.1 2189.14 2002.14 2577.47 -618.37 - 2502.21 1.09 2254624.14 226588.18 N60 9 46.9604 W 151 30 3.7720 3783 69.9 253.3 2210.74 2023.74 2636.61 -634.98 - 2559.01 1.2 2254608.82 226531.01 N60 9 46.7967 W 151 30 4.8944 3846 70 254.2 2232.34 2045.34 2695.75 -651.54 - 2615.83 1.35 2254593.54 226473.84 N60 9 46.6334 W 151 30 6.0171 3908 69.9 253.3 2253.59 2066.59 2753.95 -667.84 - 2671.75 1.37 2254578.51 226417.57 N60 9 46.4728 W 151 30 7.1220 3971 69.9 252.6 2275.24 2088.24 2813.03 -685.18 - 2728.31 1.04 2254562.44 226360.64 N60 9 46.3019 W 151 30 8.2396 4035 70 253.5 2297.18 2110.19 2873.08 -702.71 - 2785.82 1.33 2254546.21 226302.75 N60 9 46.1291 W 151 30 9.3760 4098 70.1 254.1 2318.68 2131.68 2932.25 -719.23 - 2842.68 0.91 2254530.97 226245.52 N60 9 45.9663 W 151 30 10.4996 4161 69.8 253.3 2340.28 2153.28 2991.39 -735.84 - 2899.49 1.28 2254515.65 226188.36 N60 9 45.8026 W 151 30 11.6220 4222 69.9 254.3 2361.29 2174.29 3048.62 -751.82 - 2954.48 1.55 2254500.91 226133.03 N60 9 45.6451 W 151 30 12.7086 4287 70 254.6 2383.58 2196.58 3109.66 -768.19 - 3013.3 0.46 2254485.87 226073.85 N60 9 45.4837 W 151 30 13.8710 4350 70 255 2405.13 2218.13 3168.85 -783.71 - 3070.43 0.6 2254471.64 226016.38 N60 9 45.3307 W 151 30 14.9998 4413 70 254.7 2426.67 2239.67 3228.04 -799.18 - 3127.58 0.45 2254457.46 225958.91 N60 9 45.1782 W 151 30 16.1290 477 70 254.4 2448.56 2261.56 3288.16 -815.20 - 3185.54 0.44 2254442.75 225900.6 N60 9 45.0203 W 151 30 17.2743 4541 69.9 254.5 2470.5 2283.5 3348.26 -831.32 - 3243.47 0.21 2254427.94 225842.33 N60 9 44.8614 W 151 30 18.4188 4603 69.9 255.4 2491.81 2304.81 3406.48 -846.44 - 3299.69 1.36 2254414.09 225785.78 N60 9 44.7124 W 151 30 19.5298 4666 69.9 254.5 2513.46 2326.46 3465.63 -861.80 - 3356.82 1.34 2254400.02 225728.31 N60 9 44.5609 W 151 30 20.6587 4729 69.9 254.7 2535.11 2348.11 3524.78 -877.51 - 3413.86 0.3 2254385.6 225670.94 N60 9 44.4060 W 151 30 21.7857 4791 69.8 255 2556.47 2369.47 3582.98 -892.72 - 3470.04 0.48 2254371.66 225614.43 N60 9 44.2561 W 151 30 22.8958 4855 70.1 255.5 2578.41 2391.41 3643.09 -908.03 - 3528.18 0.87 2254357.66 225555.96 N60 9 44.1051 W 151 30 24.0446 4912 70 255.7 2597.86 2410.86 3696.67 -921.35 - 3580.08 0.37 2254345.51 225503.78 N60 9 43.9738 W 151 30 25.0700 4974 69.9 256 2619.12 2432.12 3754.91 -935.59 - 3636.55 0.48 2254332.55 225447 N60 9 43.8334 W 151 30 26.1859 5039 69.9 256 2641.45 2454.46 3815.95 -950.36 - 3695.78 0 2254319.12 225387.45 N60 9 43.6878 W 151 30 27.3562 5102 69.9 255.9 2663.11 2476.11 3875.12 -964.72 - 3753.18 0.15 2254306.05 225329.75 N60 9 43.5461 W 151 30 28.4902 5165 70.1 256.6 2684.65 2497.65 3934.32 -978.79 - 3810.68 1.09 2254293.28 225271.95 N60 9 43.4074 W 151 30 29.6264 5228 70 257.7 2706.15 2519.15 3993.52 -991.96 - 3868.42 1.65 2254281.41 225213.93 N60 9 43.2775 W 151 30 30.7672 5291 70 257.4 2727.7 2540.7 4052.7 -1004.73 - 3926.22 0.45 2254269.96 225155.85 N60 9 43.1516 W 151 30 31.9095 Grid Coordinates Geographic Coordinates MD Inc Azi TVD TVD(SS) VS N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100ft) (ft) (ft) 5355 69.9 257.5 2749.64 2562.64 4112.8 -1017.79 - 3984.91 0.21 2254258.22 225096.89 N60 9 43.0228 W 151 30 33.0690 5417 69.8 257.1 2771 2584 4170.98 -1030.58 - 4041.69 0.63 2254246.7 225039.83 N60 9 42.8966 W 151 30 34.1909 5480 70.1 258.1 2792.6 2605.6 4230.14 -1043.29 - 4099.49 1.57 2254235.3 224981.76 N60 9 42.7712 W 151 30 35.3330 5543 70 258.5 2814.09 2627.09 4289.31 -1055.30 - 4157.48 .0.62 2254224.6 224923.52 N60 9 42.6528 W 151 30 36.4788 5605 70 257.3 2835.3 2648.3 4347.53 -1067.51 - 4214.44 1.82 2254213.67 224866.3 N60 9 42.5323 W 151 30 37.6044 5668 69.8 257.1 2856.95 2669.95 4406.68 -1080.62 - 4272.14 0.44 2254201.87 224808.32 N60 9 42.4030 W 151 30 38.7443 5730 70.1 258.4 2878.2 2691.2 4464.89 -1092.98 - 4329.05 2.03 2254190.8 224751.15 N60 9 42.2811 W 151 30 39.8689 5792 70.1 258.5 2899.31 2712.31 4523.13 -1104.65 - 4386.17 0.15 2254180.41 224693.78 N60 9 42.1660 W 151 30 40.9974 854 70.1 258.4 2920.41 2733.41 4581.37 -1116.32 - 4443.29 0.15 2254170.03 224636.42 N60 9 42.0508 W 151 30 42.1260 5918 69.8 257.6 2942.35 2755.35 4641.45 -1128.82 - 4502.09 1.26 2254158.86 224577.34 N60 9 41.9275 W 151 30 43.2879 5982 70 258.1 2964.35 2777.35 4701.52 -1141.47 - 4560.85 0.8 2254147.53 224518.32 N60 9 41.8027 W 151 30 44.4489 6045 70 257.5 2985.9 2798.9 4760.69 -1153.98 - 4618.71 0.89 2254136.33 224460.19 N60 9 41.6793 W 151 30 45.5922 6108 69.8 257 3007.55 2820.55 4819.83 -1167.04 - 4676.42 0.81 2254124.58 224402.21 N60 9 41.5505 W 151 30 46.7323 6171 69.9 256.2 3029.25 2842.25 4878.97 -1180.75 - 4733.95 1.2 2254112.17 224344.38 N60 9 41.4152 W 151 30 47.8691 6234 70.1 256.6 3050.8 2863.8 4938.17 -1194.67 - 4791.49 0.68 2254099.55 224286.54 N60 9 41.2779 W 151 30 49.0060 6296 70 257.2 3071.95 2884.95 4996.44 -1207.88 - 4848.25 0.92 2254087.62 224229.5 N60 9 41.1476 W 151 30 50.1275 6360 70.1 257.3 3093.79 2906.79 5056.58 -1221.15 - 4906.93 0.21 2254075.67 224170.54 N60 9 41.0166 W 151 30 51.2868 6423 70 257.3 3115.28 2928.28 5115.79 -1234.17 - 4964.7 0.16 2254063.95 224112.49 N60 9 40.8882 W 151 30 52.4283 6488 69.7 256.1 3137.68 2950.67 5176.8 -1248.21 - 5024.08 1.79 2254051.26 224052.81 N60 9 40.7497 W 151 30 53.6016 6550 69.9 256.3 3159.08 2972.08 5234.99 -1262.09 - 5080.59 0.44 2254038.65 223996 N60 9 40.6'128 W 151 30 54.7180 6613 69.9 256.1 3180.73 2993.73 5294.15 -1276.20 - 5138.04 0.3 2254025.84 223938,25 N60 9 40.4735 W 151 30 55.8532 6676 69.9 255.5 3202.39 3015.38 5353.31 -1290.71 - 5195.4 0.89 2254012.62 223880.58 N60 9 40.3304 W 151 30 56.9864 6740 69.9 255.7 3224.38 3037.38 5413.41 -1305.66 - 5253.61 0.29 2253998.99 223822.05 N60 9 40.1829 W 151 30 58.1366 6802 69.8 255.7 3245.74 3058.74 5471.62 -1320.04 - 5310.02 0.16 2253985.89 223765.34 N60 9 40.0411 W 151 30 59.2509 l~866 70.1 256.3 3267.68 3080.68 5531.74 -1334.58 - 5368.35 1 2253972.66 223706.69 N60 9 39.8976 W 151 31 0.4035 6928 69.7 255.5 3288.99 3101.99 5589.96 -1348.76 - 5424.82 1.37 2253959.75 223649.92 N60 9 39.7577 W 151 31 1.5192 6992 69.9 255 3311.09 3124.08 5650.02 -1364.06 - 5482.9 0.8 2253945.77 223591.5 N60 9 39.6068 W 151 31 2.6668 7055 70 256.1 3332.68 3145.68 5709.2 -1378.82 - 5540.21 1.65 2253932.3 223533.88 N60 9 39.4611 W 151 31 3.7991 7118 69.9 255.8 3354.28 3167.28 5768.38 -1393.19 - 5597.62 0.47 2253919.23 223476.16 N60 9 39.3194 W 151 31 4.9334 7180 69.9 254.7 3375.59 3188.59 5826.6 -1408.02 - 5653.93 1.67 2253905.68 223419.54 N60 9 39.1731 W 151 31 6.0458 7243 69.8 254.5 3397.29 3210.29 5885.73 -1423.72 - 5710.95 0.34 2253891.26 223362.18 N60 9 39.0182 W 151 31 7.1723 7298 69.8 254.5 3416.28 3229.28 5937.33 -1437.52 - 5760.69 0 2253878.59 223312.14 N60 9 38.8821 W 151 31 8.1550 7320 69.94 254.71 3423.86 3236.86 5957.98 -1443.00 - 5780.6 1.11 2253873.56 223292.11 N60 9 38.8280 W 151 31 8.5485 7329 70 254.8 3426.94 3239.94 5966.44 -1445.22 - 5788.76 1.11 2253871.52 223283.9 N60 9 38.8061 W 151 31 8.7097 7392 70.1 255.4 3448.43 3261.43 6025.65 -1460.45 - 5845.99 0.91 .2253857.58 223226.35 N60 9 38.6558 W 151 31 9.8404 7456 69.7 255.4 3470.43 3283.43 6085.75 -1475.60 - 5904.15 0.62 2253843.75 223167.86 N60 9 38.5063 W 151 31 10.9894 7519 69.5 255.9 3492.39 3305.39 6144.8 -1490.23 - 5961.35 0.81 2253830.4 223110.34 N60 9 38.3619 W 151 31 12.1197 7583 69.7 255.6 3514.7 3327.7 6204.78 -1505.00 - 6019.5 0.54 2253816.95 223051.88 N60 9 38.2162 W 151 31 13.2684 Grid Coordinates Geographic Coordinates MD fnc Azi TVD TVD(SS) VS N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100ft) (ft) (ft) 7646 70 256.5 3536.4 3349.4 6263.92 -1519.26 - 6076.9 1.42 2253803.99 222994.18 N60 9 38.0755 W 151 31 14.4024 7710 69.8 255.8 3558.39 3371.39 6324.03 -1533.64 - 6135.25 1.07 2253790.92 222935.52 N60 9 37.9336 W 151 31 15.5553 7773 69.8 257.1 3580.15 3393.15 6383.15 -1547.50 - 6192.73 1.94 2253778.37 222877.74 N60 9 37.7968 W 151 31 16.6909 7837 69.6 257.3 3602.35 3415.35 6443.16 -1560.79 - 6251.26 0.43 2253766.39 222818.93 N60 9 37.6656 W 151 31 17.8473 7900 69.3 256.8 3624.47 3437.47 6502.14 -1574.01 - 6308.75 0.88 2253754.47 222761.15 N60 9 37.5351 W 151 31 18.9832 7963 69.2 256.7 3646.79 3459.79 6561.04 -1587.52 - 6366.1 0.22 2253742.26 222703.52 N60 9 37.4018 W 151 31 20.1161 8027 68.9 256.7 3669.67 3482.67 6620.81 -1601.27 - 6424.26 0.47 2253729.82 222645.06 N60 9 37.2661 W 151 31 21.2653 8090 68.9 257.3 3692.35 3505.35 6679.57 -1614.49 - 6481.53 0.89 2253717.89 222587.51 N60 9 37.1356 W 151 31 22.3968 155 68.4 256.6 3716.01 3529.01 6740.1 -1628.16 - 6540.51 1.26 2253705.56 222528.24 N60 9 37.0007 W 151 31 23.5620 218 67.5 257.3 3739.67 3552.67 6798.48 -1641.34 - 6597.39 1.76 2253693.66 222471.08 N60 9 36.8705 W 151 31 24.6858 8281 67.1 256.8 3763.98 3576.98 6856.59 -1654.37 - 6654.03 0.97 2253681.91 222414.16 N60 9 36.7419 W 151 31 25.8048 8343 66.5 256.2 3788.4 3601.4 6913.57 -1667.67 - 6709.44 1.31 2253669.86 222358.46 N60 9 36.6106 W 151 31 26.8996 8406 66.1 256.1 3813.72 3626.73 6971.26 -1681.48 - 6765.45 0.65 2253657.32 222302.16 N60 9 36.4743 W 151 31 28.0061 8468 65.4 254.4 3839.19 3652.19 7027.78 -1695.87 - 6820.11 2.74 2253644.16 222247.18 N60 9 36.3323 W 151 31 29.0861 8532 64.1 253.9 3866.49 3679.49 7085.64 -1711.68 - 6875.8 2.15 2253629.61 222191.16 N60 9 36.1763 W 151 31 30.1862 8595 63 253 3894.55 3707.55 7141.99 -1727.74 - 6929.87 2.16 2253614.77 222136.75 N60 9 36.0178 W 151 31 31.2543 8660 62 253.2 3924.57 3737.57 7199.57 -1744.50 - 6985.03 1.56 2253599.25 222081.22 N60 9 35.8524 W 151 31 32.3441 8722 60.6 254.1 3954.34 3767.34 7253.91 -1759.81 - 7037.21 2.59 2253585.12 222028.71 N60 9 35.7013 W 151 31 33.3750 8786 59 253.7 3986.53 3799.53 7309.19 -1775.15 - 7090.35 2.56 2253570.99 221975.23 N60 9 35.5500 W 151 31 34.4249 8851 57.5 253 4020.74 3833.74 7364.41 -1790.98 - 7143.31 2.48 2253556.35 221921.94 N60 9 35.3937 W 151 31 35.4710 8914 56.2 252.9 4055.18 3868.18 7417.08 -1806.45 - 7193.73 2.07 2253542.02 221871.18 N60 9 35.2411 W 151 31 36.4672 8977 54.9 253 4090.82 3903.82 7468.96 -1821.68 - 7243.4 2.07 2253527.91 221821.18 N60 9 35.0908 W 151 31 37.4484 9041 54.1 253.4 4127.99 3940.99 7521.01 -1836.74 - 7293.28 1.35 2253513.98 221770.98 N60 9 34.9422 W 151 31 38.4338 9103 53.8 252.6 4164.47 3977.47 7571.07 -1851.40 - 7341.22 1.15 2253500.41 221722.72 N60 9 34.7976 W 151 31 39.3808 167 53.2 253.6 4202.54 4015.54 7622.45 -1866.35 - 7390.44 1.57 2253486.56 221673.18 N60 9 34.6500 W 151 31 40.3532 230 51.9 254.1 4240.85 4053.85 7672.43 -1880.27 - 7438.48 2.16 2253473.74 221624.84 N60 9 34.5127 W 151 31 41.3022 9292 51.9 254.8 4279.11 4092.11 7721.21 -1893.35 - 7485.48 0.89 2253461.72 221577.55 N60 9 34.3836 W 151 31 42.2308 9354 51.7 255.5 4317.45 4130.45 7769.92 -1905.83 - 7532.58 0.94 2253450.29 221530.19 N60 9 34.2603 W 151 31 43.1612 9416 50.5 256.9 4356.38 4169.38 7818.17 -1917.35 - 7579.43 2.61 2253439.84 221483.09 N60 9 34.1466 W 151 31 44.0868 9478 49.4 256.7 4396.28 4209.28 7865.63 -1928.18 - 7625.64 1.79 2253430.05 221436.65 N60 9 34.0396 W 151 31 44.9997 9541 48.4 256.9 4437.69 4250.69 7913.09 -1939.03 - 7671.86 1.61 2253420.25 221390.2 N60 9 33.9326 W 151 31 45.9128 9603 47.7 256.4 4479.14 4292.14 7959.2 -1949.67 - 7716.72 1.28 2253410.62 221345.11 N60 9 33.8274 W 151 31 46.7991 9665 47.3 256.8 4521.02 4334.02 8004.91 -1960.27 - 7761.19 0.8 2253401.03 221300.41 N60 9 33.7228 W 151 31 47.6776 9726 47 256.5 4562.51 4375.51 8049.63 -1970.59 - 7804.7 0.61 2253391.68 221256.68 N60 9 33.6209 W 151 31 48.5372 9791 46.4 257 4607.09 4420.09 8096.92 -1981.43 - 7850.75 1.08 2253381.88 221210.4 N60 9 33.5138 W 151 31 49.4469 9852 46.3 256.9 4649.19 4462.19 8141.06 -1991.40 - 7893.74 0.2 2253372.88 221167.19 N60 9 33.4153 W 151 31 50.2963 9913 44.8 256.1 4691.91 4504.91 8184.6 -2001.56 - 7936.09 2.63 2253363.68 221124.63 N60 9 33.3150 W 151 31 51.1328 9975 44.1 256.3 4736.17 4549.17 8228.01 -2011.92 - 7978.25 1.15 2253354.27 221082.25 N60 9 33.2127 W 151 31 51.9658 Grid Coordinates Geographic Coordinates MD Inc Azi TVD TVD(SS) VS N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100ft) (ft) (ft) 10038 42.9 256.1 4781.86 4594.87 8271.38 -2022.26 - 8020.36 1.92 2253344.88 221039.91 N60 9 33.1106 W 151 31 52.7977 10100 41.4 255.6 4827.83 4640.83 8312.98 -2032.43 - 8060.71 2.48 2253335.62 220999.35 N60 9 33.0102 W151 31 53.5947 10162 39.8 255.3 4874.9 4687.9 8353.33 -2042.57 - 8099.76 2.6 2253326.37 220960.08 N60 9 32.9101 W 151 31 54.3662 10224 38.2 255.6 4923.09 4736.08 8392.34 -2052.37 - 8137.52 2.6 2253317.42 220922.11 N60 9 32.8133 W 151 31 55.1123 10285 37.5 257.9 4971.25 4784.25 8429.76 -2060.95 - 8173.95 2.58 2253309.66 220885.5 N60 9 32.7285 W 151 31 55.8319 10349 35.3 256.3 5022.77 4835.77 8467.73 -2069.42 - 8210.97 3.74 2253302.03 220848.3 N60 9 32.6449 W 151 31 56.5632 10411 34 257.1 5073.77 4886.77 8502.97 -2077.53 - 8245.27 2.22 2253294.69 220813.82 N&0 9 32.5648 W 151 31 57.2409 10473 32.8 256.7 5125.53 4938.53 8537.1 -2085.26 - 8278.51 1.97 2253287.71 220780.41 N60 9 32.4884 W 151 31 57.8976 537 32 256.8 5179.56 4992.56 8571.39 -2093.12 - 8311.89 1.25 2253280.6 220746.87 N60 9 32.4108 W 151 31 58.5570 599 30.9 256.4 5232.45 5045.46 8603.73 -2100.62 - 8343.36 1.81 2253273.82 220715.24 N60 9 32.3368 W 151 31 59.1787 10661 29.8 256.1 5285.96 5098.96 8635.06 -2108.06 - 8373.79 1.79 2253267.06 220684.65 N60 9 32.2632 W 151 31 59.7798 10724 28.9 255.8 5340.87 5153.87 8665.94 -2115.56 - 8403.75 1.45 2253260.24 220654.53 N60 9 32.1892 W 151 32 0.3716 10786 27.9 256.3 5395.41 5208.41 8695.43 -2122.67 - 8432.36 1.66 2253253.78 220625.76 N60 9 32.1190 W 151 32 0.9369 10848 26.9 255.5 5450.45 5263.45 8723.96 -2129.62 - 8460.04 1.72 2253247.46 220597.94 N60 9 32.0504 W 151 32 1.4836 10910 26.1 255.3 5505.94 5318.94 8751.62 -2136.59 - 8486.81 1.3 2253241.09 220571.02 N60 9 31.9815 W 151 32 2.0124 10972 25.2 256.3 5561.83 5374.83 8778.46 -2143.18 - 8512.82 1.61 2253235.09 220544.87 N60 9 31.9165 W 151 32 2.5264 11034 25.1 256.4 5617.95 5430.95 8804.81 -2149.39 - 8538.43 0.18 2253229.45 220519.13 N60 9 31.8550 W 151 32 3.0322 11097 24.8 256.8 5675.07 5488.07 8831.38 -2155.55 - 8564.28 0.55 2253223.87 220493.14 N60 9 31.7942 W 151 32 3.5429 11159 24.4 258.3 5731.44 5544.44 8857.18 -2161.12 - 8589.48 1.2 2253218.88 220467.83 N60 9 31.7392 W 151 32 4.0407 11221 23.3 257.7 5788.15 5601.15 8882.23 -2166.33 - 8614 1.82 2253214.22 220443.19 N60 9 31.6877 W 151 32 4.5252 11283 23.1 259 5845.14 5658.14 8906.63 -2171.26 - 8637.92 0.89 2253209.83 220419.17 N60 9 31.6390 W 151 32 4.9977 11347 22.8 259.7 5904.07 5717.07 8931.54 -2175.87 - 8662.44 0.63 2253205.77 220394.55 N60 9 31.5934 W 151 32 5.4822 11408 22.3 260 5960.41 5773.41 8954.88 -2180.00 - 8685.47 0.84 2253202.17 220371.43 N60 9 31.5526 W 151 32 5.9371 11471 22 260.3 6018.76 5831.76 8978.56 -2184.06 - 8708.87 0.51 2253198.63 220347.95 N60 9 31.5124 W 151 32 6.3995 535 22.5 261.7 6077.99 5890.99 9002.7 -2187.85 - 8732.81 1.14 2253195.38 220323.93 N60 9 31.4750 W 151 32 6.8723 1598 23.7 260.9 6135.94 5948.94 9027.31 -2191.59 - 8757.24 1.97 2253192.19 220299.42 N60 9 31.4379 W 151 32 7.3550 11661 24.4 259.3 6193.47 6006.47 9052.91 -2196.01 - 8782.53 1.52 2253188.34 220274.04 N60 9 31.3942 W 151 32 7.8546 11724 23.6 259.1 6251.02 6064.02 9078.49 -2200.81 - 8807.7 1.28 2253184.11 220248.77 N60 9 31.3468 W 151 32 8.3518 11787 23.1 257.2 6308.86 6121.86 9103.44 -2205.93 - 8832.14 1.43 2253179.54 220224.23 N60 9 31.2961 W 151 32 8.8346 11850 22.5 257 6366.94 6179.94 9127.85 -2211.38 - 8855.93 0.96 2253174.63 220200.31 N60 9 31.2423 W 151 32 9.3047 11914 22.9 256.6 6425.98 6238.98 9152.54 -2217.02 - 8879.98 0.67 2253169.53 220176.15 N60 9 31.1866 W 151 32 9.7797 11977 23.3 256.9 6483.93 6296.93 9177.26 -2222.69 - 8904.04 0.66 2253164.41 220151.97 N60 9 31.1306 W 151 32 10.2550 12040 22.9 257.6 6541.88 6354.88 9201.97 -2228.14 - 8928.14 0.77 2253159.5 220127.74 N60 9 31.0767 W 151 32 10.7312 12103 21.9 258.8 6600.13 6413.13 9225.95 -2233.06 - 8951.64 1.75 2253155.11 220104.14 N60 9 31.0281 W 151 32 11.1954 12151 21.3 259.4 6644.76 6457.76 9243.6 -2236.40 - 8968.99 1.33 2253152.16 220086.72 N60 9 30.9951 W 151 32 11.5382 12231 20.4 260 6719.52 6532.52 9272.01 -2241.49 - 8997 1.16 2253147.7 220058.6 N60 9 30.9447 W 151 32 12.0916 12293 20.4 260.8 6777.63 6590.63 9293.55 -2245.10 - 9018.31 0.45 2253144.58 220037.22 N60 9 30.9091 W 151 32 12.5126 12355 21.6 257.6 6835.51 6648.51 9315.73 -2249.28 - 9040.13 2.68 2253140.89 220015.31 N60 9 30.8678 W 151 32 12.9435 Grid Coordinates Geographic Coordinates MD Inc Azi TVD TVD(SS) VS N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/10Qft) (ft) (ft) 12419 22.1 252.7 6894.92 6707.92 9339.53 -2255.39 - 9063.13 2.95 2253135.3 219992.18 N60 9 30.8074 W 151 32 13.3979 12482 22.1 252.6 6953.29 6766.29 9363.19 -2262.46 - 9085.75 0.06 2253128.74 219969.41 N60 9 30.7376 W 151 32 13.8448 12545 23.1 253.1 7011.45 6824.45 9387.36 -2269.59 - 9108.89 1.62 2253122.13 219946.12 N60 9 30.6672 W 151 32 14.3018 12607 22.8 253.1 7068.54 6881.54 9411.51 -2276.62 - 9132.02 0.48 2253115.62 219922.83 N60 9 30.5978 W 151 32 14.7587 12671 22.9 253.1 7127.52 6940.52 9436.33 -2283.84 - 9155.8 0.16 2253108.94 219898.9 N60 9 30.5265 W 151 32 15.2285 12734 22.5 252.9 7185.64 6998.64 9460.61 -2290.95 - 9179.05 0.65 2253102.35 219875.49 N60 9 30.4563 W 151 32 15.6877 12797 22.4 253.1 7243.87 7056.87 9484.64 -2297.99 - 9202.06 0.2 2253095.84 219852.33 N60 9 30.3868 W 151 32 16.1422 12920 22.1 252.6 7357.71 7170.71 9531.15 -2311.72 - 9246.56 0.29 2253083.11 219807.54 N60 9 30.2513 W 151 32 17.0213 049 22.1 252.6 7477.23 7290.23 9579.6 -2326.23 - 9292.87 0 2253069.65 219760.91 N60 9 30.1080 W 151 32 17.9361 3178 22.3 253.6 7596.67 7409.67 9628.28 -2340.40 - 9339.5 0.33 2253056.53 219713.97 N60 9 29.9681 W 151 32 18.8573 13240 22.3 254.1 7654.03 7467.03 9651.79 -2346.94 - 9362.1 0.31 2253050.5 219691.23 N60 9 29.9035 W 151 32 19.3037 13303 22.5 254 7712.28 7525.28 9675.79 -2353.54 - 9385.19 0.32 2253044.42 219668 N60 9 29.8383 W 151 32 19.7597 13361 22.5 253.5 7765.86 7578.86 9697.97 -2359.75 - 9406.5 0.33 2253038.7 219646.56 N60 9 29.7770 W 151 32 20.1806 13429 21.8 253.7 7828.84 7641.84 9723.58 -2366.99 - 9431.09 1.04 2253032.01 219621.81 N60 9 29.7055 W 151 32 20.6664 13492 21,5 252.8 7887.4 7700.4 9746.8 -2373.69 - 9453.35 0.71 2253025.82 219599.41 N60 9 29.6394 W 151 32 21.1061 13554 21.6 253.8 7945.06 7758.07 9769.55 -2380.23 - 9475.16 0.61 2253019.77 219577.45 N60 9 29.5748 W 151 32 21.5369 13612 21.4 254 7999.03 7812.03 9790.79 -2386.13 - 9495.58 0.37 2253014.33 219556.9 N60 9 29.5166 W 151 32 21.9404 13660 21.5 253.9 8043.7 7856.7 9808.34 -2390.98 - 9512.45 0.22 2253009.86 219539.93 N60 9 29.4686 W 151 32 22.2736 13676 21.4 254.3 8058.6 7871.6 9814.19 -2392.58 - 9518.08 1.11 2253008.39 219534.27 N60 9 29.4528 W 151 32 22.3847 13712 21,6 253.8 8092.09 7905.09 9827.37 -2396.21 - 9530.76 0.75 2253005.05 219521.5 N60 9 29.4170 W 151 32 22.6353 13771 21.6 253.8 8146.95 7959.95 9849.08 -2402.27 - 9551.62 0 2252999.46 219500.52 N60 9 29.3572 W 151 32 23.0473 • ~~ • • Marathon Oil Company. Page 1 of 4 Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: ORIGINAL COMPLETION Start: 2/10/2005 End: Contractor Name: GLACIER DRILLLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From.- To Hours Code Cod Phase. Description of Operations 3/1/2005 23:00 - 00:00 1.00 PULD_ BHA_ PR1CSG M/U Clean out Bha #1 00:00 - 05:30 5.50 TRIP_ DP_ PRICSG TIH 05:30 - 06:00 0.50 CIRC_ MUD_ PR1CSG Circ and condition for liner 3/2/2005 06:00 - 19:30 13.50 CIRC_ MUD_ PR1CSG Circulate and condition mud, cut MW to 9.8ppg. Added Lubetex to increase concentration to 6%. add SafeCarb and Dual-Flo for wall cake/fluid loss, Asphasol to stabilize coal, Run nut plug pill as volume caliper test, resulting in annuluar volume of 380 bbls. 12880 stks. (36 % Excess volume) 19:30 - 20:00 0.50 TRIP_ WIPR PR1CSG POOH 10 stds. to 13151' (Wellbore flowed 6-bbl. plus displacement for a total of 9.6 bbls 20:00 - 20:30 0.50 TRIP_ WIPR PR1CSG TIH to 13771' (no problems) 20:30 - 23:00 2.50 CIRC_ MUD_ PR1CSG CBU, at 150 gpm, 700 psi. max gas units 1756 23:00 - 00:00 1.00 MIX_ LCM_ PR1 CSG Mix and put in place 30 bbl. M-I Seal pill , 10 ppb fine, 10 ppb med, 10 ppb coarse 00:00 - 03:00 3.00 TRIP_ WIPR PR1CSG POOH to 10490" 03:00 - 03:30 0.50 CIRC_ MUD_ PR1CSG Circ @ 150 gpm/ 530 psi. 03:30 - 05:30 2.00 CIRC_ MUD_ PR1CSG Stage pumps up 10 min intervals, test Wellbore stability, 173 gpm, 198 gpm, 198 gpm, 223 gpm, 248 gpm, 272 gpm, 300 gpm, no gain /loss. 05:30 - 06:00 0.50 PULD_ DP_ PR1CSG POOH, Laying down DP 3/3/2005 06:00 - 09:30 3.50 PULD_ DP_ PR1CSG Con't POOh UD drill pipe. 09:30 - 10:30 1.00 REPAIR RIG_ PR1CSG Rig repair to hydraulic pump. 10:30 - 12:30 2.00 PULD_ DP_ PR1CSG Flow check, Con't POOh Ud drill pipe. 12:30 - 16:00 3.50 PULD_ DP_ PR1 CSG POOH stand back drill pipe. UD jars, X-O, bit sub, & bit. 16:00 - 17:00 1.00 SERVIC RIG_ PR1CSG Flow check well. Slip & cut 33' of drilling line. 17:00 - 19:00 2.00 RURD_ CSG_ PR1CSG PJSM. R!U floor & related equip & R/U Weatherford tongs & torque turn equipment. 19:00 - 22:00 3.00 RUN_ CSG_ PR1CSG P/U & M/U 4 1/2" 12.60#, L-80, Hyd 533 Csg shoe track (float shoe, 2 jts, 1 float collar, 1 jt, 1float collar, & 1 jt). Pump thru shoe track - OK. Note -all connections bakerlocked & torqued. 22:00 - 06:00 8.00 RUN_ CSG_ PR1CSG Con't to P/U & run 4 1/2" Csg to 5283'. No loss /gain No acc / 1 hr do time 3/4/2005 06:00 - 08:00 2.00 RUN_ CSG_ PR1 CSG Con't P/U &RIH w/ 4 1/2" 12.60#, L-80, Hyd 533 Csg. Total of 209 jts @ 6666.95'. 08:00 - 09:30 1.50 RURD_ CSG_ PR1CSG P/U & M/U Baker ZXP liner pkr, change out elevators, & R/D Weatherford Csg crew. Fill liner. 09:30 - 11:00 1.50 RUN_ CSG_ PR1 CSG Follow pkr with 4" dp to 7273'. 11:00 - 12:00 1.00 SPOT_ PILL PR1CSG R/U & spot 20 bbl tube pill @ 7273'(100 spm & 330 psi). Initial : Up 65, Dn 40, Rot 50, Torque 3600 With Lube : Up 62, Dn 38, Rot 50, Torque 3400 12:00 - 14:00 2.00 REPAIR RIG_ PR1 CSG Rig repair( weld arm of top drive unit). Troubleshoot link extend cylinders. 14:00 - 15:00 1.00 RUN_ CSG_ PR1CSG Cont' RIH 4 1/2 liner to 8933 ft. Wellbore obstructed, can not pass. 15:00 - 16:00 1.00 REAM_ OH_ PR1 CSG Rotate /circ /recip pipe through bridge 8933 - 9330 ft. Torque (3500), stall, various intervals, work free. No cuttings return while reaming. 16:00 - 16:30 0.50 CIRC_ MUD_ PR1CSG Cont recip pipe, CBU. Gas 502 units, no gain /loss. 200 spm, 250 gpm, spp 450 psi 16:30 - 17:30 1.00 RUN_ CSG_ PR1CSG Resume RIH 4 1/2 liner on 4" DP to 11522 ft. Take wt (23000 Ib) 17:30 - 18:30 1.00 REAM_ OH_ PR1 CSG Rot /circ /recip pipe 11522 - 11706 ft. Torque (3400), work free. No cuttings return. Gas 460 units. 18:30 - 19:30 1.00 CIRC_ MUD_ PR1CSG Cont recip pipe, CBU. Gas 630 units, no gain /loss. 200 spm, 250 gpm, spp 610 psi Printed: 70/5/2005 72:08:22 PM "e • • Marathon Oil Company Page 2 of 4 Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name; GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: ORIGINAL COMPLETION Start: 2/10/2005 End: Contractor Name: GLACIER DRILLLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase I Description of Operations 3/4/2005 19:30 - 21:30 2.00 REAM_ OH_ PR1 CSG Resume RIH 4 1/2 liner on 4" DP to 12236 ft. Take wt (17500 Ib). Rot / circ / recip pipe 12236 - 12579 ft. Torque (3450), work free. No cuttings return, Gas 600 units. 120 spm, 150 gpm, spp 710 psi, No gain /loss 21:30 - 05:00 7.50 RUN_ CSG_ PR1CSG Resume RIH 4 1/2 liner on 4" DP. Tight hole various intervals 12579 - 13750 ft. Recip /work free. 05:00 - 06:00 1.00 CIRC_ MUD_ PR1CSG Circ / cond drlg fluids. Pump carbide /die markers as volume /caliper test. No acc / 2 hrs do time. 3/5/2005 06:00 - 12:00 6.00 CIRC_ MUD_ PR1 CSG Cont circ dye as volume caliper test. Circ #1 = 36% washout, circ #2 = 33% washout. No gain /loss. Wellbore clean. Background gas 35 units. 12:00 - 12:30 0.50 SAFETY MTG_ PR1 CSG Safety meeting, all aspects cmt job. 12:30 - 13:00 0.50 RURD_ CMT_ PR1CSG PJSM, place cmt equip rig floor, connect all lines to unit, rig up same. 13:00 - 16:30 3.50 PUMP_ CMT_ PR1CSG Pump 3 bbls H2o, test lines to 4500 psi. Pump 22.5 bbls MCS-4 sweep, 10.5 ppg. Mix /pump 254 bbls slurry (664 sks G, 2.15 yield). Wash lines, drop plug with 5 bbls H2o, confirm plug dropped. Displace cmt with 95.9 bbls gelled KCL, 74 bbls mud (175 bbls). Bump plug with 1250 psi, build to 2700 psi / 10 min. Bleed, floats holding. ICP = 580, FCP = 1250, Avg rate 4 bpm. Lose circ at 225 bbls slurry away, total loss in 2.5 min. Reduce rate to 2 bpm, cease pumping 3 min, build to 2 bpm. Regain circ, returns sporadic, range 0 - 100%. Estimate total losses 100 bbls. No fluid column drop at any time. Plug bumped, cmt in place 1620 hrs. 16:30 - 17:00 0.50 SETREL LNR_ PR1 CSG PJSM, slack off wt to hgr, build press to 3500, set liner hgr. Confirm liner hgr set. Sting out pkr, confirm all seals out. 17:00 - 18:00 1.00 CIRC_ MUD_ PR1CSG CBU, no cmt returns to surface, no spacer returns. 18:00 - 20:30 2.50 RURD_ CMT_ PR1CSG PJSM, rig do cmt hd /all related equip, release cmt unit. 20:30 - 06:00 9.50 LOG_ CSG_ PR1CSG PJSM, R/U Pollard, run "Quick Temp" temp log on slickline to 11000 ft. POH, download data. 3/6/2005 06:00 - 06:30 0.50 LOG_ CSG_ PR1CSG Cont download data temp probe 06:30 - 07:00 0.50 RURD_ SLIK PR1 CSG R/D Pollard slickline services, release unit. 07:00 - 08:00 1.00 SERVIC RIG_ PR1CSG Service rig 08:00 - 10:30 2.50 LOG_ CSG_ PR1CSG Wait on temp log evaluation, determine TOC 10350 ft 10:30 - 11:00 0.50 TEST_ CMT_ PR1CSG PJSM, Perform infectivity test resulting in 3 BPM at 1520 psi at liner top. 11:00 - 15:30 4.50 TRIP_ DP_ PR1CSG PJSM, Fill trip tank, blow do lines, prepare POH 4" DP 15:30 - 16:00 0.50 TRIP_ BHA_ PR1CSG UD liner setting tool, clear floor. 16:00 - 20:00 4.00 TRIP_ DP_ PR1CSG PJSM, RIH 4" DP with Baker squeeze tool. 20:00 - 21:00 1.00 SQUEZ CMT_ PR1CSG PJSM, place BJ cmt equip rig floor, R/U same. 21:00 - 02:00 5.00 SQUEZ CMT_ PR1 CSG PJSM, Sting in /set liner top sgeeze tool, squeeze liner top (7050 - 10350, 4 1/2 X 6 1/8 annulus) Pump 5 bbl H2o, test lines to 4500 psi. Pump 5 bbls H2o, mix /pump 500 sks (G, 12.7 ppg, 2.15 yld) Total slurry 200 bbls. Hold back press through choke initial 65 bbls. Close choke, begin sgeeze to liner top annulus. Initial press 1200 psi / 3.5 bpm, final 1080 psi / 1 bpm, peak 1529 psi. Follow cmt with 5 bbls H2o / 64 bbls mud, leaving 1 bbl in DP Bleed, open annulus, flow check. Drop wiper dart, confirm dart dropped. CBU, 3.5 bbls cmt returns to surface. Cont circ clean. 02:00 - 02:30 0.50 SETREL PKR PR1 CSG Set ZXP Pkr with 45000 Ibs do wt. Confirm set with do wt. Printed: 10/5/2005 12:08:22 PM • • Marathon Oil Company Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOF F 3 Event Name: ORIGINAL COMPLETION Contractor Name: GLACIER DRILLLING Rig Name: GLACIER DRILLING Date From - To Hours Code Phase Code : 3/6/2005 02:30 - 06:00 3.50 TRIP_ DP_ PR1CSG 3/7/2005 06:00 - 07:00 1.00 TRIP_ DP_ PR1CSG 07:00 - 09:30 2.50 TRIP_ DP_ PR1CSG 09:30 - 10:00 0.50 CLNOU CSG_ PR1CSG 10:00 - 12:00 2.00 CLEAN_ TANK PR1CSG 12:00 - 16:00 4.00 MIX_ FLD_ PR1CSG 16:00 - 17:30 1.50 TEST CSG PR1CSG 17:30 - 03:00 9.50 PULD_ DP_ PR1CSG 03:00 - 06:00 3.00 TEST BOPE PR1TIE ~ 3/8/2005 ~ 06:00 - 10:00 ~ 4.00 TEST_ BOPE ~ PR1TIE 10:00 - 12:00 2.00 PULD_ TBG_ PR1TIE 12:00 - 13:00 1.00 SAFETY MTG PR1TIE 13:00 - 15:00 2.00 PULD_ EOIP PR1TIE 15:00- 16:00 1.00 PULD_ BHA_ PR1TIE 16:00 - 16:30 0.50 PULD_ TBG_ PR1TIE 16:30 - 01:30 9.00 PULD TBG PR1TIE 01:30 - 04:00 ~ 2.50 ~ PULD_ ~ TBG_ ~ PR1TIE 04:00 - 05:00 1.00 TEST_ WLHD PR1TIE 05:00 - 06:00 1.00 TEST TBG PR1TIE '3/9/2005 06:00 - 06:30 0.50 PULD_ EOIP PR1TIE 06:30 - 11:00 4.50 NUND BOPE PR1TIE 11:00 - 13:30 2.50 NUND TREE PR1TIE 13:30 - 14:30 1.00 TEST TREE PR1TIE 14:30 - 06:00 ~ 15.50 ~ RURD_~ RIG_ ~ RDMO '.3/10/2005 ~ 06:00 - 12:00 ~ 6.00 ~ RURD_~ RIG_ ~ RDMO 12:00 - 14:30 ~ 2.50 ~ RURD_~ RIG_ RDMO 14:30 - 00:00 ~ 9.50 ~ RURD_~ RIG_ ~ RDMO Page 3 of 4 Spud Date: 1/17/2005 Start: 2/10/2005 End: Rig Release: Group: Rig Number: 1 Description of Operations PJSM, POH 4" DP for liner top dress off. Cont POH 4" DP, lay out liner run tool PJSM, MU liner top mill, RIH with 4" DP Clean out /polish liner top at 7049 ft, no indication of debris Circ fluids while clean mud pits, no debris / cmt to surface Mix /pump inhibited 6% KCL (Congor 303A) through hole volume PJSM, prepare /test 4 1/2 X 7 liner lap to 1500 psi / 30 min. Test successful, no re-tests. PJSM, POH laying do 4" DP, lay out liner mill, clear floor. PJSM, prepare for test BOPE, pull mouse hole, clean out same, PJSM, change pipe rams (4 to 4 1/2), pull wear bshg, MU test plug and test jt, RU test pump /lines. PJSM, test BOPE, 250/2500 psi / 5 min. To include rams, annular, choke mnfld, kill lines, mud lines to pump, all floor valves, top drv equip. Accumulator press /volume test, gas alarm function. Three re-tests, kill line check (debris in valve), increase accumulator press. Re-connect Epoch to pits. Rack /strap 4 1/2 tbg. One hour stand down safety meeting, review all hands and support personnel, relay MOC conference call info. PJSM, place tbg run equip rig floor, R/U same. M/U seal assy on 4 1/2 tbg, inspect all seals. Change out failed tbg tong power pack PJSM, follow seal assy with 4 1/2, 12.6#, L80, BTC tbg, inj mandrel at 2406 ft. 166 jts total. PJSM, Sting in PBR, space out, M/U tbg hgr, land hgr. Mule shoe at 7066, locator at 7048. Run in LD screws, test wellhead /hgr seals to 5000 psi. Prepare and test tbg /seal assy 500 psi / 15 min. Test successful, no re-test. PJSM, remove all tbg run equip rig floor PJSM, Set BPV, nipple do BOPE PJSM, install prod tree PJSM, Test primary /secondary seals, all valves /related equip to 5000 psi / 15 min. Test successful, no re-tests. Install BPV, confirm seated. PJSM, rig do rig floor, choke mnfld, kill line, fill line, top drv, torque tube, derrick board, clean pits, mud pumps, shock hoses, partial load out trailers, lock /tag out all lines /connections. PJSM. R/D conex stairs to rig floor, Beaver slide, and catwalk. R/D panic line, carrier tarps, and mufflers, and drillers console. Shut down boiler, pull traps and blow down. R/D cuttings tank. Disconnect lower standpipe and cement line. Load out catwalk. R/D steam lines. PJSM. Scope down derrick and prep to lay over. R/D external lights. 81ow down and R/D water tank. Load hanson tank and pump#3. R/D camp. PJSM. Con't R/D operations. R/D conex stairs, Bever slide & catwalk, panic line, carrier tarps, carrier mufflers, drillers console. Shut down boiler, drain traps, & blow down boiler. R/D cuttings tank & disconnect lower stand pipe & cmt Iline. R/D steam lines & load out catwalk. Move and R/U camp. No accidents & no injuries reported Printed: 10/5/2005 12:08:22 PM • • Marathon Oil Company Page 4 of 4' Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: ORIGINAL COMPLETION Start: 2/10/2005 End: Contractor Name: GLACIER DRILLLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 3/10/2005 14:30 - 00:00 9.50 RURD RIG_ RDMO Rig released to Ninilchik State#1 OO:OOhrs 03/10/2005. Printed: 10/5/2005 12:08:22 PM • • Marathon Oil Company Page 1 of s< Operations Summary Report ~ Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: ORIGINAL COMPLETION Start: 3/16/2005 End: Contractor Name: GLACIER DRILLLING Rig Release: Group:. Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours Code Code Phase Description of Operations 3/20/2005 08:00 - 09:30 1.50 RURD_ SLIK CLNOUT Pollard wire line on location. Held PJSM and discussed procedure. ' Went over safety and environmental issues. Note: previous day equipment spotted on location. 09:30 - 10:30 1.00 TRIP_ TOOL CLNOUT MU 1 3/4" tool sting with RS, KJ, 5' stem, 5' roller stem, KH, 5' stem, 3' roller stem, kj, OJ, Sj with a 3.8" GR. RIH to tag fill. 10:30 - 11:30 1.00 TAG_ PKR_ CLNOUT GR sat down of 7068' KB at top of packer. Tried to move past would not, POOH 11:30 - 15:30 4.00 TRIP_ TOOL CLNOUT MU 3.8" tapered swedge with same tool string. RIH to 7344' KBD, sat down was able to work too string to 7527' KBD. no progress, POOH. Discussed the potetial of mud in well bore, tools seem to be slowing down so slow and then stopping as if the toosl are pushing something ~ down hole. 15:30 - 17:50 2.33 TRIP_ TOOL CLNOUT MU a 2 1/2" DD bailer to try and get a sample and see how far we can get the tools down. RIH tagged up at 10320' KBD worked the tool string down to 13621' KBD. POOH with DD bailer. 17:50 - 18:30 0.67 TRIP_ TOOL CLNOUT OOH sample of Cement in bailer. 18:30 - 20:30 2.00 RURD_ SLIK CLNOUT RD slick line unit, cleaned up around well head. Depart location. 3/24/2005 09:00 - 11:00 2.00 KURD COIL CLNOUT 11:00 - 14:00 3.00 RURD COIL CLNOUT 14:00 - 16:00 2.00 NUND BOPE CLNOUT 3/25/2005 07:00 - 07:50 0.83 RURD COIL CLNOUT 07:50 - 09:45 1.92 TEST BOPE CLNOUT 09:45 - 10:20 0.58 TEST BOPE CLNOUT 10:20 - 11:33 1.22 PUMP WTR CLNOUT 11:33 - 12:00 0.45 REPAIR EOIP CLNOUT 12:00 - 13:10 1.17 PUMP WTR CLNOUT 13:10 - 14:35 1.42 WORK COIL CLNOUT 14:35 - 14:50 0.25 PUMP WTR CLNOUT 14:50 - 15:00 0.17 PUMP WTR CLNOUT 15:00 - 15:10 0.17 TRIP TOOL CLNOUT Note: the sample of Cement is in office BJ CT arrived on location. Obtain work permit. Held PJSM. Spot coil, crane and pumping unit around tree. MU hard lines from coil through coke and flow back tank. Moved 500 bbls of water to supply tank. Hooked up the filter pod to recycle fluid during wash. Hammer up the BOP to the tree. BJ left lease. BJ CT on location. Obtain a work permit, held PJSM and discussed operation. Coil 1 3/4" with dimple on connector, double check, boss, 3.8" four bladed centralizer, 3/8" dual circ sub, 1 3/4" chisel nozzle with 7 jets PU injector and stabbed on BOP's. Loaded coil with 29 bbls FRESH WATER. PT BOPs, small leak at tree connection. S/D tighten connection continue with PT. Low pressure shell tested at 200 psi, high 4500 psig. Test good. Bled down closed blinds, PT blinds 200 psig, high 4500 psig, good tested. Open blinds, RIH closed tubing rams, PT @ same pressures held. Open tubing rams. Open well head. RIH pumping FRESH WATER at min rate of 0.5 BPM. CT at 4500, pull test coil at 7500 Ibs, continue in well. Returns to tank clean. When coil at 6060' small leak below the injector. Stopped coil to tighten Bowen connection. WHP 4 psig, coil at 0 psig. Tighten connection stopped leak. Continue down hole. Coil at 10, 790' CTD, making coil pu to check weight at 2000' bites, good return to flow back tank. Increase FRESH WATER rate to 2.0 BPM. Returns brown, creamy and smells like cement. Worked coil down to 13, 570' CTD, Pump rate at 2.0 BPM. PU weight at 24, 000 Ibs at this depth. PIP= 3900 psig, WHP= 110 psig, CT pressure= 3900 psig Increase PIR= 2.25 BPM, PIP= 3900 psig, WHP 110 psig, coil at 13,570' CTM. Shut down pump, drop 3/8" ball, start pump back at 2.25 BPM, PIP= 3900 psig, WHP= 115 psig, CT at 13, 570' CTM. Bail seated shifted sub, pressure @ 3900 psig, PIR= 2.4 BPM, WHP= Printed: 10/5/2005 12:08:50 PM • • Marathon Qil Company Page 2 of 6` Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: ORIGINAL COMPLETION Start: 3/16/2005 End: Contractor Name: GLACIER DRILLLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date. From - To Hours Code Code Phase Description of Operations 3/25/2005 15:00 - 15:10 0.17 TRIP_ TOOL CLNOUT 115 psig, returns to tank, brown with thicker fluid, solid flakes in samples. Continue POOH with coil at 50 FPM. 15:10 - 16:33 1.38 TRIP_ TOOL CLNOUT PU weight at 13570' = 24, 000 lbs. Monitoring tank returns while filtering water over to supply tank. Returns are still very dirty. 16:33 - 20:40 4.12 TRIP_ TOOL CLNOUT Coil at 10, 600' CTM, decrease POOH speed to 35 FPM from the 70 degree angle pipe up to 1000'. Returns light brown and loose. 20:40 - 20:45 0.08 PUMP_ TRET CLNOUT Coil at surface pump 6 BBLs 50/50 methanol to freeze protect the coil, started up the N2 unit. Blow down coil wtih the N2. 20:45 - 20:50 0.08 RURD_ COIL CLNOUT Vac truck arrive to pull off the liquids from pump unit, hoses and tanks. Shut in well, blow down the reel and back side of reel. Lay down the injector and secured around well head. 20:50 - 21:10 0.33 RURD_ COIL CLNOUT BJ coil tech left lease. 4/9/2005 07:30 - 08:00 0.50 SAFETY MTG_ PR1CSG Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. 08:00 - 09:30 1.50 RURD_ ELEC PRICSG Spotted Expro wireline unit and crane truck. Removed night cap and installed WL valve. MU 7' long 3-1/8" weight bar, CCUGR, and SCMT bond logging tool to wireline. Oilfield Hot Shot Service delivered MOC methanol skid with Haskel pump from Susan Dionne Pad. 09:30 - 12:00 2.50 RUNPU ELEC PR1CSG RIH with Bond Log and tagged PBTD at 13,633' KB. Let THP increase to 1150 psi due to displacement while RIH with logging tools. Increased THP to 1600 psi by pumping methanol into Expro pump-in tee using MOC methanol skid. 12:00 - 13:00 1.00 RUNPU ELEC PR1CSG Correlated depth with Precision Energy Services (PES) Array Induction openhole log run 27-Feb-2005. Logged 200' repeat section with 1600 psi THP to eliminate microannulus effect. 13:00 - 17:00 4.00 LOG_ CSG_ PR1CSG Logged CCUGR/SCMT from 13,633' to 6900' KB at 32 fpm and with 1600 psi applied THP (fresh water in hole). 17:00 - 18:00 1.00 RUNPU ELEC PR1CSG Bled off 1600 psi applied pressure and POOH with bond logging tools. 18:00 - 19:00 1.00 RURD_ ELEC PR1CSG RDMO Expro Wireline. 8/25/2005 07:30 - 08:00 0.50 SAFETY MTG_ PR1CSG Rigged BJ coiled Tubing to reverse well dry for perforating. Pressure test all lines valves to 4500. Full BOP test to 4500 psi. 8/26/2005 07:00 - 07:30 0.50 SAFETY MTG_ CTBG PJSM and permit at SD office. 07:30 - 11:00 3.50 RURD_ COIL CTBG RU BJ and Pressure test stripper to 4000 psi 11:00 - 17:00 6.00 RUNPU COIL CTBG RIH CT. Start reversing with N2 at 500' at 500 SCF/min. Reverse well dry to 13,185', and POH. Trapped 1100 psi surface nitrogen pressure. 17:00 - 20:30 3.50 RURD_ COIL CTBG RD and release BJ CT. 9/1/2005 07:30 - 08:00 0.50 SAFETY MTG_ CMPPRF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. ASRC hauled off 20% KCL water stored in tank and fresh water jetted from well to G&I yesterday. ASRC vac truck driver on location to pull a partial load of water to support lubricator and flowback iron pressure test. 08:00 - 10:00 2.00 RURD_ ELEC CMPPRF MIRU Expro perforators. MU lubricator and grease head. Install WL valve and pump-in tee on top of swab valve. Spot MOC methanol pump skid and air compressor. Take lubricator to wellhead without guns. Pressure tested lubricator to 500 psi low and 3000 psi high with fresh water. Released pressure and drained lubricator to flowback manifold. Pressure tested MOC chicksan and flow back manifold to 500 psi low and 3000 psi high with fresh water. Bled off pressure to tank. 10:00 - 10:30 0.50 RUNPU ELEC CMPFLW Armed 15' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 14' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 10:30 - 12:30 2.00 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated Printed: 10/5/2005 12:08:50 PM • ~ Marathon Oil Company Page 3 of 6 Operations Summary-Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: ORIGINAL COMPLETION Start: 3/16/2005 End: Contractor Name: GLACIER DRILLLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date I From.- To Hours ! Code ~ Code Phase , Description`of Operations 9/1/2005 10:30 - 12:30 12:30 - 13:30 13:30 - 14:00 14:00 - 16:00 16:00 - 17:30 17:30 - 19:00 9/3/2005 07:30 - 08:00 08:00 - 09:00 2.00 PERF_ CSG_ CMPFLW 12840-12854' MD with 1100 psi surface nitrogen pressure. 1.00 RUNPU ELEC CMPFLW POOH with guns for 15 minutes and SICP remained constant at 1100 psi. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 0.50 RURD_ ELEC CMPFLW Armed 20' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. Bled nitrogen pressure down to 1050 psi while RIH. 2.00 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 12606-12626' MD with 1050 psi surface nitrogen pressure. Pressure built to 1200 psi in 5 min, 1250 psi in 10 min, and 1300 psi in 15 min. SICP at 2100 psi one hour after perforating. 1.50 RUNPU ELEC CMPFLW POOH with guns. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 1.50 RURD_ CMPFLW Rig back Expro. Will flow test well overnight maintaining at least 1100 psi FTP and discuss point-forward plan in the AM. 0.50 SAFETY MTG_ CMPPRF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Well had been flowed to sales for 24 hours (1700 hrs 8/31/2005 to 1700 hrs 9/1/2005). Shut well in for a short PBU overnight. SICP at 7 AM on 9/2/2005 was 2665 psi in AM. 1.001 RURD I ELEC 09:00 - 09:30 0.50 RURD ELEC 09:30 - 14:00 4.50 RUNPU ELEC 14:00 - 14;30 I 0.501 RURD I ELEC 14:30 - 15;30 1.00 I RUNPULI ELEC 15:30 - 16:00 16:00 - 17:00 17:00 - 18:00 9/7/2005 07:00 - 07:30 0.50 PERF_ CSG_ 1.00 RUNPU ELEC 1.00 RURD_ ELEC 0.50 SAFETY MTG CMPPRF MU Spartec real-time pressure-temperature gauge with bowspring centralizers, weight bars, and CCL. Pulled tools into lubricator and took lubricator to tree. Pressure tested lubricator to 2665 psi with WHP. CMPPRF RIH with P/T tools to about 2000' MD. Could not get tools to drop. POOH with tool string and bled pressure off of lubricator. Added another weight bar to tool string. MOC Operators blew down flowline to remove obstruction (small rocks) from EFM while Expro out of hole with tool string. CMPPRF RIH with P/T tools to 13,000' MD logging down pass from 12500'. Logged up pass to 12,500' MD noting static fluid level at 12840' MD (top pert of lower interval perfed). Static BHP was 3173 psig at 12840' and 3155 psig at 12606' MD. Took static benches at 12000, 11000, 10000, 8000, 6000, 4000, and 2000' MD while POOH with logging tools. Bled pressure off of lubricator. CMPPRF LD P-T tool string. Began flowing well to sales to achieve drawdown for perforating. CMPFLW Armed 25' 3-3/8" carrier and took lubricator to tree. R!H with 3.375" OD perforating gun loaded 22' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 12564-12586' MD with 1100 psi surface gas pressure flowing 1.3 MMscfd (EFM not working properly to completely shut in). CMPFLW POOH with guns for 15 minutes and began opening the EFM (started at 1330 psi at 1.6 MMscfd). Guns at surface. Well flowing 3.7 MMscfd at 1125 psi FTP. Bled pressure off of lubricator. LD perf gun. All shots fired and round. CMPFLW Rigged down Expro Wireline equipment from the tree. Will leave Expro equipment at the wellsite in anticipation of adding more perforations on 9/6/2005. Plan to flow the well to sales maintaining the FTP above 1100 psi. CMPPRF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Flowed well since 9/2/2005 at Printed: 10/5/2005 12:08:50 PM • • Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Marathon ~iI Com an Page 4 of 6 Spud Date: 1/17/2005 End: Group: p Y Operations Summary Report GRASSIM OSKOLKOFF 3 GRASSIM OSKOLKOFF 3 ORIGINAL COMPLETION GLACIER DRILLLING GLACIER DRILLING Start: 3/16/2005 Rig Release: Rig Number: 1 Date From - To 9/7/2005 07:00 - 07:30 07:30 - 08:30 08:30 - 10:00 10:00 - 10:30 10:30 - 11:30 11:30 - 13:00 13:00- 13:30 13:30 - 15:00 15:00 - 15:30 9/8/2005 07:00 - 07:30 07:30 - 08:00 08:00 - 09:30 09:30 - 10:00 10:00 - 11:00 11:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 15:00 Hours Code Cod Phase Description of Operations 0.50 SAFETY MTG_ CMPPRF a relatively stable rate of 3.45 MMscfd at 1100 psig FTP. 1.00 RURD_ ELEC CMPPRF Expro reheaded wireline and filled grease injection pump reservoir. Install WL valve and pump-in tee on top of swab valve. 1.50 RUNPU ELEC CMPFLW Armed 20' 3-3/8" carrier and took lubricator to tree. RIH with 3,375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 12648-12668' MD with 1150 psi surface gas pressure flowing 1.38 MMscfd (EFM not working properly to completely shut in). 1.00 RUNPU ELEC CMPFLW POOH with guns for 10 minutes with rate 1.38 MMscfd at 1260 psi. Opened well choke steadily while POOH with pert gun. Rate at 3.47 MMscfd at 1110 psig FTP when OOH. Bled pressure off of lubricator. LD pert gun. All shots fired and round. 1.50 RUNPU ELEC CMPFLW Armed 20' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 12378-12398' MD with 1150 psi surface gas pressure flowing 1.36 MMscfd (EFM not working properly to completely shut in). 1.50 RUNPU ELEC CMPFLW POOH with guns for 10 minutes with rate 1.54 MMscfd at 1260 psi . Opened well choke steadily while POOH with pert gun. Rate at 3.46 MMscfd at 1100 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 0.50 RURD_ ELEC CMPFLW Rigged down Expro wireline equipment from the tree. Will leave Expro equipment at the wellsite in anticipation of adding more perforations tomorrow. Plan to flow the well to sales maintaining the FTP above 1100 psi. 0.50 SAFETY MTG_ CMPPRF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Flowed well overnight at a relatively stable rate of 3.42 MMscfd at 1100 psig FTP. 0.50 RURD_ ELEC CMPPRF Install WL valve and pump-in tee on top of swab valve. Reviewed MOC Perforating Safety Checklist. 1.50 RUNPU ELEC CMPFLW Armed 25' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 22' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 12626-12648' MD with 1150 psi surface gas pressure with the well shut in at the line heater block valve. 1.00 RUNPU ELEC CMPFLW POOH with guns for 10 minutes with SITP climbing to 1340 psi. Opened well choke steadily while POOH with perf gun. Rate at 3.48 MMscfd at 1095 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 1.50 RUNPU ELEC CMPFLW Armed 25' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 24' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 12354-12378' MD with 1150 psi surface gas pressure with the well shut in at the line heater block valve. 1.00 RUNPU ELEC CMPFLW POOH with guns for 10 minutes with rate 1.54 MMscfd at 1260 psi . Opened well choke steadily while POOH with perf gun. Rate at 3.41 MMscfd at 1100 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 1.00 RUNPU ELEC CMPFLW Armed 25' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD Printed: 10/5/2005 12:08:50 PM • • Marathon-Oil Company Page 5 of s Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: ORIGINAL COMPLETION Start: 3/16/2005 End: Contractor Name: GLACIER DRILLLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To 9/8/2005 14:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 17:30 9/9/2005 08:00 - 08:30 08:30 - 09:00 09:00 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 16:00 16:00 - 16:30 16:30 - 17:30 17:30 - 19:00 9/14/2005 08:00 - 09:00 Hours Code Code Phase Description of Operations 1.00 RUNPU ELEC CMPFLW perforating gun loaded 25' with SDP-3125-311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 12242-12267' MD with 1150 psi surface gas pressure with the well shut in at the line heater block valve. 1.00 RUNPU ELEC CMPFLW POOH with guns for 10 minutes with rate 1.67 MMscfd at 1320 psi . Opened well choke steadily while POOH with perf gun. Rate at 3.57 MMscfd at 1100 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 1.00 RURD_ ELEC CMPFLW Rigged down Expro wireline equipment from the tree. Will leave Expro equipment at the wellsite in anticipation of adding more perforations tomorrow. Plan to flow the well to sales maintaining the FTP above 1100 psi. 0.50 SAFETY MTG_ CMPPRF Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Flowed well overnight at a relatively stable rate of 3.54 MMscfd at 1110 psig FTP. 0.50 RURD_ ELEC CMPPRF Install WL valve and pump-in tee on top of swab valve. Reviewed MOC Perforating Safety Checklist. 1.00 RUNPU ELEC CMPFLW Armed 18' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 15' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 12223-12238' MD with 1120 psi surface gas pressure with the well shut in at the line heater block valve. 1.50 RUNPU ELEC CMPFLW POOH with guns for 10 minutes with SITP climbing to 1340 psi. Opened well choke steadily while POOH with perf gun. Rate at 3.87 MMscfd at 1110 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 1.00 RUNPU ELEC CMPFLW Armed 20' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 17' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 11956-11973' MD with 1130 psi surface gas pressure with the well shut in at the line heater block valve. 1.00 RUNPU ELEC CMPFLW POOH with guns for 10 minutes with SITP climbing to 1340 psi. Opened well choke steadily while POOH with perf gun. Rate at 3.48 MMscfd at 1095 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 1.50 RUNPU ELEC CMPFLW Armed 11' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 10' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF_ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs. Perforated 11830-11840' MD with 1110 psi surface gas pressure with the well shut in at the line heater block valve. 1.00 RUNPU ELEC CMPFLW POOH with guns for 10 minutes with SITP climbing to 1470 psi. Opened well choke steadily while POOH with perf gun. Rate at 5.56 MMscfd at 1132 psig FTP when OOH. Bled pressure off of lubricator. LD perf gun. All shots fired and round. 1.50 RURD_ ELEC CMPFLW RDMO Expro Perforators. Returned well to sales maintaining no lower than 1100 psig FTP. 1.00 Move in and rig up wire line equipment, Held PJSM and discussed job site hazards prior to making up tool string. Met with operators and held JSA. MU 20' with 3.375" OD perforating gun loaded with Printed: 10/5/2005 12:08:50 PM a , • • Marathon Oil Company Page 6 of s Operations Summary Report Legal Well Name: GRASSIM OSKOLKOFF 3 Common Well Name: GRASSIM OSKOLKOFF 3 Spud Date: 1/17/2005 Event Name: ORIGINAL COMPLETION Start: 3/16/2005 End: Contractor Name: GLACIER DRILLLING Rig Release: Group: Rig Name: GLACIER DRILLING Rig Number: 1 Date From - To Hours 'Code :.`:Code Phase Description of Operations 9/14/2005 108:00 - 09:00 1.00 SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 09:00 - 09:30 0.50 Held pre job arming safety meeting prior to arming gun. Shut down modems, cell phones and station person at gate. PU gun and opened up well. 09:30 - 10:00 0.50 RIH with gun #1, to perforate from 10866' to 10886' 20' gun. 10:00 - 11:00 1.00 Gun at 3000' problem falling in well with well flowing at 5.1 MMCFPD at 1100 psig at tree. Close control valve to reduce flow while running in well with gun. 11:00 - 11:30 0.50 Flow rate adjusted down to 1246 psig at 3789 MMCFPD. Open well up to bring down pressure prior to perforating by opening control valve. 11:30 - 12:00 0.50 Continue with tie in to array induction log with CBL to get gun on depth to perforate. CBL 4' deep to open hole log. Make correction, PU gun to pert depth. 12:00 - 12:30 0.50 Shut in well to perforate from 10866' to 10886' DIL. Well shut in to perforate, POOH with gun. Pressure was 1200 psig when gun fired. Monitor well while pulling out of hole. 12:30 - 13:00 0.50 OOH with gun, all shots fired. Monitor pressure for 30 minutes prior to making up second perforation run. After 30 minutes well at 1138 psig, 5600 MCF with 80% open on the control valve. 6 BBIs water produced to tank. 13:00 - 13:30 0.50 Make up gun #2, 20'- 3.375" OD gun as before. Go to communication black out prior to arming gun with safe firing system. Well flowing at 5600 MCFPD at 1120 psig. 13:30 - 13:50 0.33 RIH with #2 gun to perforate from 10612' to 10632' DIL. Correlated CBL to array induction log, corrected depth by 5' to get on depth to pert interval. 13:50 - 14:50 1.00 Shut well in to perforate. WHP built to 1140 psig, fired gun and POOH with gun. Monitor pressure for 10 minutes. 14:50 - 15:05 0.25 WHP= 1600 psig after 10 minutes shut in. Open well to production to monitor well. 15:05 - 15:40 0.58 Well flowing while POOH with gun. Wire at 4000'. 15:40 - 16:40 1.00 OOH with gun, shut in swab. bled down the lubricator and confirmed all shots fired. Continue to monitor well. RD wireline unit. 16:40 - 17:30 0.83 Secure well left lease at 1730 well making 5250 MCFPD at 1095 psig. No water to surface. Printed: 10/5/2005 12:08:50 PM ., Marathon MARATHON Oil Company May 9, 2005 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7`t' Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon Grassim Oskolkoff #3 CONFIDENTIAL Dear Mr. Oakland: The following confidential well data are enclosed for the above referenced well. CERTIFIED MAIL GO #3 AOGCC Dulling Pernut ............................................................................:................... digital ~ 3 3 As-Built Plat .................................................................................................................. digital Daily Drilling Report ..................................................................................................... digital Directional Survey .........................................................................................................digital EPOCH Report/Data ......................................................................................................digital One CD containing digital well logs and above data (directory list attached) ................ digital Please indicate your receipt of this data by signing below and returning one copy to me at the letterhead address. Thank you, Kaynell Zeman Geological Technician Recei Date: Enclosure • Alaska Asset Team Northern Business Unit P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-499-8504 • • Marathon Oil Co. Grassim Oskolkoff #3 '" CD Contents As-Built Plat directory: ~`-'AGO #3 As-Built Plat 11-17-04.pdF Daily Drilling Report directory: ';, ®G03 Daily Drilling Report.tiF Directional Survey directory: g_oskolkof_3_tvd_dir_sur.las Permit directory: GO #3 AOGCC Approved Per... Precision-Initial Run directory: go3_int_MAINALL, las ~~ go3_int maindepth.las ~G03_Run 1_complete.dpk ~G03_Run l~lotted.dpk Precision-Run 2 directory: ~• FINALS_Grassim Osluolkaff 3_Run 2_camplete.dpk ~• FINALS Grassim Oskolluoff 3_Run 2~lotted.dpk G03_R2_MAIN DEPTH.Ias ~~- • Marathon Oil Co. Grassim Oskolkoff #3 ` ~ CD Contents EPOCH Mud Log/Morning Reports directory: '; ~20050122.htm ~20050123.htm ... ~20050129.htm . ~20050125.h[m ~20050126.htm ~20050127.htm '~20050128.htm ~20050129.htm : ~!]20050130.htm ': ~20050131.htm '~'~20050201.htm :.. ~20050202.htm ~20050203.htm ~20050204.htm ,. ~20050205.htm ~20050206.h[m _~20050207.htm 5 ~20050208.htm :~20050209.htm ;; ~20050210.htm ~20050211.htm ~20050212.htm ~20050213.htm $~20050224.h[m ~200502t5.htm 'SJe 20050225.htm ~20050216.htm ",c~20050226.htm '; ~f20050217.htm 'aL~120050227.htm ~20050218.htm ~20050228.htm ~20050219.htm ~20050301.htm ~20050220.htm ~20050302.htm 4~20050221.htm ~20050303,htm $~20050222.htm ~20050304,htm ~20050223.htm ~20050305.htm EPOCH Mud Log/DML Data directory: G03.dbf go3.hd G03.mdx ~G03 SCLDBF ~f G03_SCL.h~X G03_tvd.dbf ~G03 Nd.mdx po3r,dbf ~f ~3r.mdx EPOCH Mud Log/PDF Files directory: ~_ G03_ DD19D.pdF -G03_~ MD.pdF ~_;jG03J91_ND.pdf EPOCH Mud Log/Remarks File directory: ~.! G03 Lxheditl.doc `,~Remarks.las EPOCH Mud Log/Well LAS File directory: uGD~3.~ EPOCH Mud Log/Well Report directory: ~~]G03~ampk~lanifest, doc WEN Report G03.doc • j ` i~ sm~ _ .9 ~i ~ i~ a j _' ~ ~ te ~ ~ + ~ ~ ' ~ 7 ~ ~ ~ ~ ~ ~ ~ ~ ) ~ ~ ~ ~ ~ , ' a ~ ~ ~ :~ 3 a ~ ' °'~ '~ ~i ~ ~~:, gym.: ).,~ :...~ ~ ~. ~.~:~ ~ FRANK H. MURKOWSKI, GOVERNOR r ~~~~ ~~~~rr ~t~~+ ~/ ~ 7 ~ ~ OI ~ A ~ O V~ 7 ~ TM - taT - ~t ~ 1a T t ~ ~ ~ CO~sSER~AilO1~ COoi1•iiSSIO~ ~ 333 W. 7 AVENUE, SU{TE 100 , ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Willard J. Tank Advanced Senior Drilling Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Re: Ninilchik Grassim Oskolkoff #3 Sundry Number: 305-030 Dear Mr. Tank: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a h 'day o eekend. A person may not appeal a Commission decision to Superior u ss rehearing has been requested. ~~ ~C/ DATED this~~day of February, 2005 Encl. x • M Marathon MARATHON Oi! Company January 28, 2005 John Norman Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Sundry Permit No.: 204-255 Well: Ninilchik Unit - Grassim Oskolkoff #3 Dear Mr. Norman Enclosed please find a SUNDRY notice concerning a change in the original permitted BOP Stack, along with the associated attachment. A test of the BOP system during beginning operations of the intermediate hole section indicated a failure in the single ram located below the annular, double ram, and mud cross. This single ram was removed for repair and is anticipated to be put back into the BOP ~ system prior to drill out of the intermediate casing string for the production hole. As noted on the original PERMIT TO DRILL, the maximum anticipated surface pressure is 2,019 psig, thus the remaining three ram stack adequately provides for well control. ~ If you require further information, I can be reached at 713-296-3273 or by a-mail at wjtank @ marathonoil.com. Sincerely, Willard J. Tank Advanced Senior Drilling Engineer Enclosures Worldwide Drilling North America P.O. Box 3128 Houston, TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 gas '" ~~~~~ STATE OF ALASKA ALA~IL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPRG'JAL 20 AAC 25.280 i~..i C,/1r Z l l i ~ ZEDS 1. Type of Request: Abandon Suspend Operational shutdown Pertorate Waiver Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program Q ~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development Q Exploratory ^ 204-255 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: / P.O. Box 3128, Houston, TX 77253 50-133-20548 7. KB Elevation (ft): 9. Well Name and Number: 187 feet (21 feet above ground level) Ninilchik Unit - Grassim Oskolkoff #3 ~ 8. Property Designation: 10. Field/Pools(s): ADL 384305 /ADL 389180 Ninilchik Unit / Tyonek Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 2,508' 1,772' 2,508' 1,772' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 99' 99' Surface. 2,487' 9 5/8" 2,508' 1,772' 5,750 psi 3,090 psi Intermediate Production Liner Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ SOP Sketch Q Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/28/2005 Oil ^ Gas^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: 1/28/2005 WAG [] GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Jim Regg 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Winton Aubert Printed Name ~ Willard J. Tank Title Advanced Senior Drilling Engineer Signature Phone 713-296-3273 Date 1/28/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3!"a~j'_,,. ~ 3 Q Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. L7f-~ ~~.F~ X °~ ~~~5 2 Subsequent F uired• hJ h~ ~ tM / APPROVED BY Approved /~ COMMISSIONER THE COMMISSION Date: // E,G/ Form 10-403 Revised 11/2004 Submit in Duplicate v ~~ ~~L: >~ • Marathon Oil • -• Well Grassim Oskolkoff #3 BOP Stack (Revised) 13 5/8" SM Cross Re: BOP, Variance for Maranthon oil GO#3 /Glacier Rig #1 «~ Subject: R'c.: BOP, Variance for lV'laranlhort oil GO,~> ;' Glacier 1Zi~~ ~ 1 ,~ From: Janes Rcgg jini regg@aclmin.state.ak.us-~ l,. Datc: F ri, ~~ tan ?Oi1~ OS:S(l: 4 O9llO ~~~ To: ~l~einp-Help-Aladri~ig'~alasl:adrillin~~~cr;mast#iol~loiLcom= Please advise when repaired ram preventor is installed; next BOP test would be a good opportunity for Commission witness. Jim Regg AOGCC Inspection Supervisor Temp-Help-Aladring wrote: Jim, We went exhausted all efforts to get a test with the single ram preventor, changed ram blocks twice ,and sealing elements once, the trouble was that the rams would not fully close, and we believe that something is broke or a piece of rubber is off of the piston on one side not letting piston close fully, Closing unit was functioning correct, Weatherford rentals tech came to location to assist in this , we will send the preventor to Kenai today and they will tear it down and repair and have it ready to reinstall on the next hole section. BOP Configuration will be as follows, 13 5/8" X 5000 Psi. Annular Double 13 5/8" X 5000 With Variable bore rams in top and Blinds in bottom ram We will be drilling the intermediate section of the wellbore and setting pipe and reinstalling the :ram preventor before the production section . Thanks Larry Myers 1 of 1 1/28/2005 8:50 AM Willard Tank Advanced Senior Drilling Engineer Marathon Oil Company P.O. Box 3128 Houston, TX 77253 Re: Grassim Oskolkoff #3 Marathon Oil Company Permit No: 204-255 Surface Location: 3221' FSL, 2914' FEL, SEC. 23, T1N, R13W, S.M. Bottomhole Location: 814' F5L, 1942' FEL, SEC. 21, T1N, R13W, S.M. Dear Mr. Tank: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t tness any required test. Contact the Commission's petroleum field inspector at (907) 659- 60 (pager). DATED this day of December, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ Marathon MARATHON Oit Company December 21, 2004 John Norman Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application Field: Ninilchik Well: Ninilchik Unit - Grassim Oskolkoff #3 Dear Mr. Norman Worldwide Drilling North America P.O. Box 3128 Houston, TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 R~~~ 1~ ~~ DEC272004 Alaska Oi[ & Gas Cons. Curnm6ssiol~ Anchorage Enclosed please find the PERMIT TO DRILL application, along with the associated attachments and filing fee of $100. The intent is to drill a Tyonek development well. If you require further information, I can be reached at 713-296-3273 or by a-mail at wjtankC~ marathonoil.com. Sincerely, i %" Willard J. Tan Advanced Senior Drilling Engineer Enclosures STATE OF ALASKA SKA OIL AND GAS CONSERVATION C ~iVIISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill ~ Redrill Re-entry ~ 1b. Current Well Class: Exploratory Development Oil Multiple Zone ~ Stratigraphic Test ~ Service ~ Development Gas Q Single Zone 2. Operator Name: Marathon Oil Company 5. Bond: Blanket ~ Single Well Bond No. 5194234 11. Well Name and Number: Ninilchik Unit - Grassim Oskolkoff #3 3. Address: P.O. Box 3128, Houston, TX 77253 6. Proposed Depth: MD: 13,765 TVD: 8,100 12. Field/Pool(s): Ninilchik Unit 4a. Location of Well (Governmental Section): Surface: 3,221' FSL, 2,914' FEL, Sec. 23, T1 N, R13W, S.M. ~ 7. Property Designation: ADL 384305 /ADL 389180 Tyonek Pool Top of Productive Horizon: 1,593' FSL, 4,120' FEL, Sec. 22, T1 N, R13W, S.M. 8. Land Use Permit: 13. Approximate Spud Date: January 7, 2005 '~ Total Depth: 814' FSL, 1,942' FEL, Sec. 21, Ti N, R13W, S.M. ~ 9. Acres in Property: 3,918 / 5,550 14. Distance to Nearest Property: 3,100 ft (fee-private) 4b. Location of Well (State Base Plane Coordinates): Surface: x - 229,103.63 y - 2,255,186.00 Zone - 4 10. KB Elevation (Height above GL): (21' AGL) 187 feet 15. Distance to Nearest Well Within Pool: S,ooo ff. to GO #2 16. Deviated wells: Kickoff depth: 250 feet Maximum Hole Angle: 70 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3,875 Surface: 2,019 ` 18. Casing Program: Size Specifications Setting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 133 K-55 PE i00' 0' 0' 121' 121' 12 1/4" 9 5/8" 40 L-80 BTC 2,479' 0' 0' 2,500' 1,76T 517 sacks 8 1/2" 7" 26 L-80 BTC 7,271' 0' 0' 7,292' 3,406' 456 sacks 6 1/8" 4 1/2" 12.75 L-80 Hydril 533 6,644' 7,100' 3,340' 13,765' 8,100' 466 sacks 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate , Production Liner Perforation Depth MD (ft): Perforation Depth D ft)- • , Asask~a Olt & Gas Cans• tammisslon 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Shallow Hazard Analysis Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Willard J. Tank Title Advanced Senior Drilling Engineer Signature Phone 713-296-3273 Date December 21, 2004 Commission Use Only Permit to Drill Number: ZQ - S API Number: 50- ~3~5' - ~ Q S ~ ~ Permit Approval _ Date: ~~ .~v/~ See cover letter for other requirements. Conditions of approval S p fired Yes ~ No ~ Mud log required Yes [] No _ rog n Ifide measures Yes ~ No ~ Directional survey required Yes No Other: t ~ ~ ~ S~7 ©P S f , APPROVED BY /~ Approved by: THE COMMISSION Date: 1 38 (/ Form 10-401 Revised 06/2004 1..~~~~~ ' 4 Submit inDuplicate "*~.``, • • / ~ MARATHON MARATHON OIL COMPANY DRILLING PROGRAM Ninilchik Unit Grassim Oskolkoff #3 Original ~~~~/ 12/21/04 Alaska iii & 6~s t;cra. ~;r~mmissior~ ~n~itarage Originator: W.J. Tank i'!/ ~~ Drilling Superintendent: P.K. Berga North America Drilling Manager: B.J. Roy Page 1 of 13 • • Table of Contents General Well Data ...................................................................................................................................................................3 Geologic Program Summary ...................................................................................................................................................3 Summarv of Potential Drilling Hazards ....................................................................................................................................4 Formation Evaluation Summary ..............................................................................................................................................4 Drilling Program Summary ......................................................................................................................................................5 Casing Program .......................................................................................................................................................................6 Casing Design .........................................................................................................................................................................6 Maximum Anticipated Surface Pressure .................................................................................................................................6 BOPE Program ........................................................................................................................................................................8 Wellhead Equipment Summary ..............................................................................................................................................9 Directional Program Summary ................................................................................................................................................9 Directional Surveying Summary ............................................................................................................................................10 Drilling Fluid Program Summary ...........................................................................................................................................10 Drilling Fluid Specifications ....................................................................................................................................................11 Solids Control Equipment ......................................................................................................................................................1 i Cement Program Summary ...................................................................................................................................................12 Bit Summary ..........................................................................................................................................................................12 Hydraulics Summary .............................................................................................................................................................13 Formation Integrity Test Procedure .......................................................................................................................................13 Page 2 of 13 • General Well Data • Weil Name Grassim Oskolkoff #3 Lease/License Surface Location 3,221' FSL, 2,914' F EL, Sec. 23, T1 N, R13W, S.M. WBS Code DD.04.10981.CAP.DRL SIoUPad ad sim Oskolkoff Field Ninilchik Unit Spud pate 1/7/05 (est.) KB Elev. 187 County/Province Kenai Peninsula API No. Ground Level Elev. 166 State /Country Alaska Weil Class Development Perm. Datum KB Total MD 13,765' Rig Contractor Glacier Drilling Water Depth N/A TotatTVD 8,100' Rig Name #1 Water Protection Depth Comments: Geologic Program Summary Formatiar~ MD -RKB ft) TVD -RKB (ft) Pore Pressure (psi) Pore Pressure p ) Ldhoio Possible Flukt Content Beluga (Not a Prod Target) 1,544 1,375 8.46 Sandstone Water Tyonek (Target) 8,114 3,687 9.20 Sandstone Gas Tyonek T-2 (Target) 8,788 3,972 9.20 Sandstone Gas Tyonek T-3 (Target) 11,240 5,777 9.20 Sandstone Gas Gomments: Surface Location Coordinates From Lease/Biock Lines 3,22i' FSL, 2,914' FEL, Sec. 23, T1 N, R13W, S.M. Latitude 60° 09' 53.053" N Longitude 151 ° 29' 14.326" W UTM North (Y) 2,255,186.00' UTM'East (x} 229,103.63' Tolerance Depth Horizontal Displacement ft Directional Target MD (ft TVD (ft) Location +N/-S (Y} +E/-W X) Tolerance (ft) Tyonek 8,114 3,687 1,593' FSL, 4,120' FEL, Sec. 22, T1 N, R13W, S.M. -1,628 -6,486 Circle 250' radius Tyonek T-2 8,788 3,972 1,444' FSL, 4,712' FEL, Sec. 22, T1 N, Ri3W, S.M. -1,777 -7,078 Circle 250' radius Tyonek T-3 11,240 5,777 1,056' FSL, 918' FEL, Sec. 21, T1N, R13W, S.M. -2,165 -8,627 Circle 250' radius TD 13,765 8,100 814' FSL, 1,942' FEL, Sec. 21, T1N, R13W, S.M. -2,407 -9,588 Comments: Page 3 of 13 • • Summarv of Potential Drilfina Hazards Hazard Event Discussion Coal stability in intermediate and reduction hole sections Utilize an asphanol chemical to protect coals. Use proper mud weight to stabilize coals. Torque concerns in intermediate and reduction hole sections Use good hole cleaning techniques with high pump rates. Add lubricant where necessary. Comments: Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No HzS is anticipated. ~ Gas sands will be encountered from +/- 8,114' MD (3,687' TVD) to total depth of the well. These sands will run from slightly depleted to slightly above normal pressure. The Flo-Pro mud system that will be properly weighted to hydraulically control all sands and lost circulation materials will be available on location, if required. Formation Evaluation Summarv Interval LWD Electric Logs Mud Surface 0' - 2,500' MD None None None Intermediate 2,500' - 7,292' MD None Reeves Quad Combo on shuttle. Pull GR- Neutron to surtace inside casing. Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Production 7,292' - 13,765' MD None Reeves Quad Combo and MFT Pressures. Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Completion N/A GR, CGL N!A Coring Requirements: 2 - 90' cores. One to be taken at approximately 4,600' TVD and one at approximately 6,700' TVD. Final depths to be determined during drilling operations. Comments: Page 4 of 13 Drilling Program Summary CONDUCTOR: 1. Actua120" conductor depth from driving operations w~s 6 ft. RKB. 2. Move in and rig up rotary drilling rig. PU 17 112" bit and collars. 3. Drill to +/- 100' RKB. POOH. 4. PU hammer. Drive 20" conductor to depth. RD hammer. 5. Install starting head 20" SLC x 21 1/4", 2M flanged. 6. Nipple up 21 1/4", 2M diverter, 16" diverter valve, and 16" diverter line. ~ 7. Function test diverter and diverter valve. SURFACE: 1. Drill a 12 1/4" hole to 2,500' MD (1,767' TVD) per the directional plan. (Have 16" mill on location in case drive shoe is pinched.) 2. Run and cement 95/8" casing. ~ 3. Cut off 9 5/8" casing. ND diverter. 4. Install 9 518" slip lock connection X 11" 5M flanged multibowl wellhead. 5. NU 11" 5M X 135/8" adapter spool. NU 13 5/8" 5M BOP'S. Test BOP's and choke manifold to 250/2,500 psi. 6. Set wear bushing. Test surface casing to 2,500 psi INTERMEDIATE: 1. PU 8 1/2" PDC bit and rotary steerable directional BHA. Drill out float equipment and 20' of new formation. CBU. 2. Test shoe to leak off. Estimated EMW is 19.0 ppg. 3. Drill 8 1/2" directional hole to 7,292' MD (3,406' TVD) as per directional program, short tripping as required. ~ 4. At TD circulate hole clean. Make wiper trip. TOOH. 5. RU logging company. Run open hole logs on drill pipe utilizing the shuttle system. TOOH with logging tool. Pull wear bushing. 6. Change out pipe rams with 7" casing rams in single ram. Run test plug and test casing rams to 2,500 psi. ~ 7. Run and cement 7" casing. Land hanger in multibowl wellhead. 8. Back out landing joint. Change out 7" casing rams with pipe rams. Run test plug and test BOP's to 250!2,500 psi. 9. Set wear bushing. Test intermediate casing to 2,500 psi. PRODUCTION: i . PU 6 118" PDC bit and directional BHA. Drill float equipment and 20' of new formation. CBU. 2. Test shoe to leak off. Estimated EMW 17.0 ppg. 3. Drill a 6 1/8" hole to approximately 9,815' MD (4,600' TVD) as per the directional program, short tripping as required. POOH for coring assembly. TIH with core bit and barrel and cut 90' of core. TOOH with core. 4. TIH with 6 1!8" directional assembly and continue drilling per directional program, short tripping as required. Drill to approximately 12,243' MD (6,700' TVD). POOH for coring assembly. TIH with core bit and barrel and cut 90' of core. TOOH with core. 5. TIH with 6 i!8" directional assembly and continue drilling to an anticipated TD of 13,765' MD (8,100' TVD). ~ 6. At TD circulate hole clean. Make wiper trip. TOOH. 7. RU logging company. Run open hole logs as per plan. RD logging company. 8. TIH w/ 6 1/8" tri-cone bit to TD for wiper trip. TOOH and laydown BHA and drill pipe. Pull wear bushing. 9. Run 4 1!2" Hydril 533 casing liner with hanger and liner hanger packer on drill pipe to TD. On bottom reciprocate and rotate liner while circulating the hole. Cement casing as per the attached cementing program, while reciprocating and rotating liner, displacing cement with gelled KCI. Bump plug with 500 psi aver displacement pressure. 10. Set liner hanger (liner top at approx. 7,100' MD (3,340' TVD), disconnect from liner, circulate excess cement, set liner hanger packer. TOOH. (If no cement is circulated, prepare to down squeeze liner top, prior to setting packer.) 11. PU mill for 4 1/2" along with string mill for 7" casing. Make cleanout trip to top of 4 1!2" liner with mill combo on drill pipe. 12. Polish 4 1/2" liner seal bore. TOOH laying down. Page 5 of 13 • • 13. Run 4 1/2" tubing with seal unit. Displace hole with 6 % KCL. Space out tubing and land hanger. ND BOP, NU tree and test to 5,000 psi. ~ 14. Rig down and move out drilling rig. COMPLETION: Completion will be done without a rig. Casino Program MD ft) Connection API. Ratings Casing Size (in) T Bottom Weight (Ibslft) ~ Grade / T e O. D. (in) Makeup Torque (ft-Ibs) Hole Siae l~-) .r ~ ~ a ~ ~ U ~ ~- 9 5!8 Surface 2,500 40 L-80 BTC 10.625 N/A * 12 1/4 5,750 3,090 916 7 Surface 7,292 26 L-80 BTC 7.656 16,500 ** 8 1/2 7,240 5,410 667 41/2 7,100 13,765 12.75 L-80 Hydril533 4.926 13,120 61/8 8,430 7,500 288 Comments: Make-up torque shown for the Hydril 533 is 80% of yield. The final make up torque for the liner should be above any potential torque that would be used to release the running tool from the hanger. See liner running procedure for more details. * The make up of the buttress connection will be to the proper mark. ** Torque rings will be utilized in the buttress connections to provide some torque capability. The make-up torque shown is 80% of maximum for 261b/ft torque rings (21,080 fUlbs). Final make-up torque should be determined at the well site. Casing Design Casing Shoe Safety Factors Casing Setting Mud Wt Frac. Form Ma~mum Surface ~ ,~ Size Weight Depth When Set Grad Press Pressure ~ , °' (in) (1t:Jft) Grade (TVD) (Il~gal) (Ib/ al) (Ib/ I) (psi) 00 95/8 40 L-80 1,767 9.4 19.0 8.46 729 3.60 2.81 3.71 7 26 L-SO 3,406 10.0 17.0 8.46 2,019 2.29 2.62 2.81 41/2 12.75 L-80 8,100 10.2 17.0 9.20 2,019 2.13 1.75 1.97 Comments: Maximum Anticipated Surface Pressure Casing Size (in) setting. Depth TVD ft) MAWP * psi MASP ** (psi) MudlGas Ratio 9 5/8 1,767 3,924 729 3080 7 3,406 5,866 2,019 30170 4112 8,100 5,866 2,019 30/70 " MAWP =Maximum allowable working pressure *" MASP =Maximum anticipated surface pressure Comments: Page 6 of 13 • • MASP / MAWP CALCULATIONS: Surface casing: 9 5/8" (2.500' MD. 1,767' TVD) MASPf,~ _ ((Fracture gradient at shoe + S.F.) x .052 x TVDsnoe) -Hydrostatic pressure of gas column at the shoe. MASPf,~ _ (19.0 ppg + 0.5 ppg) x .052 x 1,767' - (.1 psUft x 1,767') MASPf,~ = 1,792 psi - 177 psi MASP~,~ = 1,615 psi. MASPbnp = BHPopen nods td -Hydrostatic pressure of mud portion -Hydrostatic pressure of gas portion MASPbnp = (8.46 ppg x .052 x 3,406') - (0.3 x 10.0 ppg x .052 x 3,406') - (0.7 x 0.1 psi/ft x 3,406') MASPbnp = 1,498 psi - 531 psi - 238 psi MASPbnp = 729 psi MASP =MASPbnp = 729 psi MAWP = (0.7 x Casing Burst) - (Mud Wt. -Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 5,750) - (9.4 - 8.3) x .052 x 1,767' MAWP = 4,025 psi -101 psi = 3,924 psi Intermediate casina: 7" (7.292' MD, 3.406' TVD) MASPr~ac =((Fracture gradient at shoe + S.F.) x .052 x TVDsnoe) -Hydrostatic pressure of gas column at the shoe. MASPt~c = (17.0 ppg + 0.5 ppg) x .052 x 3,406' - (.1 psi/ft x 3,406'} MASPt~ = 3,099 psi -341 psi MASPf~~ = 2,758 psi. MASPbnp = BHP~,,,,o,e,d -Hydrostatic pressure of mud portion -Hydrostatic pressure of gas portion MASPbnp = (9.20 ppg x .052 x 8,100') - (0.3 x 10.2 ppg x .052 x 8,100') - (0.7 x 0.1 psi/ft x 8,100') MASPe,p = 3,875 psi - 1,289 psi - 567 psi MASPbnp = 2,019 psi MASP =MASPbnp = 2,019 psi MAWP = (0.7 x Casing Burst) - (Mud Wt. -Backup Fluid Wt.) x .052 x TVD MAWP = (0.7 x 8,430) - (10.2 - 10.0) x .052 x 3,406' MAWP = 5,901 psi - 35 psi = 5,866 psi Production finer: 4 1/2" (Ton - 7,100' MD, 3.340' TVD) (Bottom -13,765' MD, 8,100' TVDI MASP = MASP• = 2,019 psi MAWP = MAWP7• = 5,866 psi Page 7 of 13 • • ROPE Program Casing Test Test Casing Test Fluid Pressure Size MAWP MASP Press Density. BOPS tow/High .Casing (in) (psi) (psi) (psi) (Ib/ ) Size & Rating (psi) (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram Surface 9 5/8 3,924 729 2,500 9.4 (1) 13 5/8" 5M blind ram 250/2,500 (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets (1) 13-5/8" 5M pipe ram (1) 13-5/8" 5M annular (i) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram Intermediate 7 5,866 2,019 2,500 10.0 250!2,500 (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets (1) 13-5/8" 5M pipe ram (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram Production Liner 4 1/2 5,866 2,019 2,500 10.2 25012,500 (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets (1) 13-5/8" 5M pipe ram Comments: Blowout Preventers i The blowout preventer stack will consist of a 13-518" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single pipe ram. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and avacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Casing Test Pressures Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Page 8 of 13 • Wellhead Equipment Summarv Component Description Casing Hanger Type 103/4" x T' Fluted Casing Head 11" 5M X 9-5/8" Slip Loc W/ 2, 2" LPO, Landing Base for 20" Conductor, U, AA, PSL1, PRi Mandrel 11" 5M Studded Bottom X 11" 5M Flg Top, W/ 2, 2-1/16" 5M Studded Outlets, 11" x 4 1/2" Mandrel Tubing Head U,AA,PSLI,PR1 with 4" H BPV threads Adapter Flange 11" 5M X 4-1/16" 10M W/Seal Pocket Comments: Directional Program Summarv Build Tum Coordinates Sec.: No. Description MD (ft) TVD (ft) Rate (°/1~') Rate (°/100') Dogleg. (°/100') Inclination (deg) ' Azimuth (deg) i.N!-S (ft) +E/-W (ft) VS (ft) 1 Tie On 0 0 0 0 0 0 255.91 0 0 0 2 KOP 250.00 250.00 0 0 0 0 255.91 0 0 0 3 Build up Section 4.00 0 4.00 255.91 4 End of Build 2,000.00 1,596.01 4.00 0 4.00 70.00 255.91 -229.46 -914.13 942.49 5 Hold Section 0 0 0 70.00 255.91 6 End of Hold 8,113.64 3,687.00 0 0 0 70.00 255.91 -1,628.14 -6,486.21 6,687.43 7 Drop Section -1.50 0 1.50 255.91 8 End of Drop 11,239.50 5,777.00 -1.50 0 1.50 23.11 255.91 -2,165.39 -8,626.53 8,894.15 9 TD 13,765.22 8,100.00 0 0 0 23.11 255.91 -2,406.77 -9,588.12 9,885.58 Comments: Vertical section calculated from a reference azimuth of 255.91° taken from surface location to bottom hole location. Potential Well Interference: Well Distance (ft) Death (MD) Grassim Oskolkoff #1 152.84 Surface Grassim Oskolkoff #2 193.59 328.08 No serious interference exists. See attached directional plan and anticollision analysis for more details. Page 9 of 13 ~ • L vd ^q U C N N 2 Directional Surveying Summary 0 0 0 (`7 + L C O Z L 0 Interval MWD Survey Magnetic Multishot Gyro Multishot Comments 0 - 2,500' X 2,500' - 7,292' X 7,292' - 13,765' X Comments: Drilling Fluid Program Summarv Interva l - ND Minimum I nventory From To Density Gel (ft) (ft) (Ib/gal) Fluid Description Additives Viscosifier Barite 0 1,767 8.6 - 9.4 Gel / Gelex Spud Mud Gel, Gelex, Soda Ash, Caustic, Barite, Polypac Supreme UL, Sodium Meta Bisulfate Flo-Vis, Polypac UL, KCI, SafeCarb F&M, 1,767 3,406 9.4 - 10.0 6% Flo-Pro w/ Safecarb Asphasol Supreme, Lubetex, Caustic, Conqor 404, Sodium Meta Bisulfate, Klagard Flo-Vis, DualFlo, KCI, Greencide 25G, SafeCarb 3,406 8,100 9.6 10.2~~ 6% Flo-Pro w/ Safecarb F, Asphasol Supreme, Barite, Caustic, Conqor ~ 404, Sodium Meta Bisulfate, Klagard, Lubetex Comments: See mud prognosis for details. Sized CaCO3 (SafeCarb) will be used to control leakoff. Page 10 of 13 Vertical Section at 255.91 ° [3500fUin] West(-)/East(+) [3000fUin] ~ J Drilling Fluid Saecifications • Interval - TVD LSRV From ft Tp (ft) Density (Ib/gal) Vis (sec/gt) 1 min (Ib./100Ftz) PV (cP) YP (Ib/100 ft~ - Fluid Less (cc) pH Ddll Solids. (%)- 0 1,767 8.6 - 9.4 60 - 100 N/A 25 - 35 NC - 10/12 +/- 9.5 < 7 1,767 3,406 9.4 - 10.0 30,000 8 - 12 7 - 9 +!- 9.5 +/- 7.5 3,406 8,100 9.6 -10.2 30,000 10 - 14 5 - 7 +/- 9.5 +/- 5 Comments: As a standard practice for tie-back string completions, displace the drilling mud above top of liner with brine treated with corrosion inhibitor (Congor 303A) at a concentration of 1 drum per 100 barrels of fluid. See mud prognosis for details. Solids Control Equipment m m ~ ~ ~ m ~ ~ ~ C t~ Y ~ ` r ~ ' ~ ~ ~ ~ ~ ~ ~ U n Interval U U l Comments 0 - 13,765' MD X X X X Closed Loop System, Full Containment Item Equipment Specifications (quantity, desi pe, brand, model, fknrr ca c' ,etc Shaker 2 -Derrick Model 2E48-90F-3TA Desander N!A DesiBer 1 -Derrick Model 0522 Mud Cleaner N/A C~trifuge 2 - MI/Swaco units Cuttings Dryer N/A Cuttings Injection Marathon G&I Facility Zero Discharge N/A Comments: The solids control equipment will consist of two flowline cleaners, a desilter, and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. Page 11 of 13 ~ • Cement Prostram Summary Depth Gauge Top of cement Open casing Size {in) MD (ft ND (ft Hde Size in) MD ft) ND (ft) Ann V~ To TOC (ft~ Slurry. Vol {ft~} WOC Time (hrs} Hde Excess %} 9 5!8 2,500 1,767 12 1/4 0 0 887 1,297 8 50 7 7,292 3,406 8 112 2,000 1,596 687 917 8 35 4 112 13,765 8,100 6 1 /8 7,100 3,340 630 853 N/A 35 Mix: Water Compressive Casing Size Density Qty Yield Slurry Vol TOC MD Qty Wl. FW Strength i) {in) Slurry Cement Description (If~gal) (sx} (ft /sx) (ft~ (ft) (gal/sx) .. .Type (cc) (%) 8 hr 24 hr 9 518 Tail Type I Cement 12 517 2.51 1,297 0 11.28 Fresh 812 0 500 Lead Class"G" 12.5 295 2.47 729 2,000 13.79 Fresh 7 Tail Class "G" 15.8 161 1.17 188 6,292 4.99 Fresh 4 112 Tail Class "G" 13.5 466 1.83 853 7,100 9.22 Fresh Comments: See cement prognosis for details and spacer specifications. Bit Summarv {nterva l - MD Type Recommended Estimated From {ft To ft) Size (in) Manufacturer Model No. IADC WOB {kips) RPM Rotating Hours f3OP ftfir} 0 2,500 12 Y, Christensen MX-C1 117 2 - 5 80 - 300 2,500 7,292 8'/z Christensen HCM 605 M223 Up to 25 Motor 7,292 13,765 6 1(8 Christensen HCM 5052 M323 Up to 25 Motor Comments: See bit prognosis for additional information. Page 12 of 13 • • Hydraulics Summary Rig mud pumps available are shown below. Max Press ® Displacement t.iner ID Stroke 90°~ WP 95% eff Max R83a Hod Sections Used Qty Matte Model (in) (in) (psi) (gaUstroke) (s1~91~) pn 5 8 2,597 2.04 125 / 255 Surface 3 National Oil Well A600PT 5 8 2,597 2.04 1251255 Interrnediate 5 8 2,597 2.04 125 / 255 Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Depth-MD (ft) Hole Size in) Pump Rate gpm Standpipe Pressure (Psi) Min AV (fpm) ECD (Ib/ ) Nozzle Size (32"s) Remarks 0 - 2,500 12 1/4 575 1,588 103 5 - 15's MI Virtual Hydraulics 2,500 - 7,292 8 112 525 2,368 217 5 - 15's MI Virtual Hydraulics 7,292 - 13,765 6 1/8 270 2,825 296 3 - 24's Actual Data from SD #3 (~ 10,254' MD) Comments: See separate hydraulics calculations. 4" drillpipe used in all hole sections. Formation Integrity Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test SOPs 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 1J2 bpm while recording casing and drillpipe pressures at 112 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Page 13 of 13 i Marathon Oil Well Grassim Oskolkoff #3 Diverter 21 1/4" 2M Diverter _,~ Diverter Spool 16" Automatic Knife Valve 16" Diverter Line ~~ Marathon Oif Weli Grassim Oskotkoff #3 BOP Stack 13 5/8" 5M Cross • Marathon Oil Well Grassim Oskolkoff #3 Choke Manifold To Gas Buster To Blooey Line Bleed off Line to Shakers x x x oot ~ }-- u oo~ -i ~ e °~ 0 x x x x X X ~~ X X * 3" 5M Valves x 2 9l16" 10M Swaco 3 1/8" 5M Manually Hydraulically Operated Adjustable Choke Choke From BOP Stack • • Surface Use Plan for Ninilchik Unit -Grassim Oskolkoff #3 Surface location: Anticipated at 3,221' FSL, 2,914' FEL, Sec. 23, T1 N, R13W, S.M. 1) Existing Roads The Sterling Highway will be used for access to the Grassim Oskolkoff #3 well and is shown on the attached map. Ninilchik, Alaska is the nearest town to the site. 2) Access Roads to be Constructed or Reconstructed No new roads will be required to access Grassim Oskolkoff #3. 3) Location of existing wells Well Grassim Oskolkoff #3 will be drilled on Grassim Oskolkoff pad. A pad drawing is enclosed that shows existing wells and the proposed location of Grassim Oskolkoff #3. 4) Location of existing and/or proposed facilities The locations of existing production facilities on the Grassim Oskolkoff pad are shown on the enclosed pad drawing. A flowline will be installed from the Grassim Oskolkoff #3 wellhead to an existing heater and separator. 5) Location of Water Supply A water supply well exists on the pad that Grassim Oskolkoff #3 will be drilled from. This is shown on the pad drawing. 6) Construction Materials No construction is planned on the pad. 7) Methods of handling waste disposal; a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-i 8 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals • • Unused chemicals will be returned to the vendors that provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8) Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9) Plans for reclamation of the surface Grassim Oskolkoff #3 will be drilled from an existing pad. Reclamation of the pad, if required by the landowner, will occur after the abandonment of Grassim Oskolkoff #3 and the other existing wells on the pad. 10) Surface ownership Marion Oskolkoff is the surface owner of the land at the Grassim Oskolkoff pad. 11) Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors. and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: l Z 2 / /d `~ Name and Title: Willard J. Tank, vanced Senior Drilling Engineer Marathon Oil Company P. O. Box 3128 Houston, TX 77253 (713) 296-3277 • • /a~~ 0 GO NO. 1 WELL Q GO N0.2 WELL EXPLORATION PAD 2914' FEL GO N0.3 WELL 18" DIAM.CASING ELEVATED PRODUCTION ."PAD N ~0~: !~ o M ~~ \ ` ~ 23 4 .-~'CE OF A~q ~~l '~P'••• `r'f-~~j . ~.~ ~, ~ -.M. SCOTT McIANE ~ ~, ~ 4928-5 ~ l~''~ess`aa-~``~~` GO NO. 3 I 2914' FEL 3221' FSL SECTION 23 I T1N., R13W., S.M., AK GRID N: 2255186.00 GRID E: 229103.63 LATITUDE: 60°09'53.053"N I LONGITUDE: 151 °29'14.326"W ELEV. 166 FT. ~ ~~ ~ ~~4:~.. 1. BASf3 OF HORIZONTAL COORDINATES AND ELEVATIONS IS NGS MONUMENT V82 AT MILE POST 127.80E THE STERLING HIGHWAY. THE ELEVATION OF V821S 283,59 FEET (NGVD 29). THE HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 2I ZONE 4 AND ARE BASED ON PUBLISHED COORDINATES FROM THE STATE OF ALASKA DEPARTMENT OF TRANSPORTATION AND PUBLIC FACILITIES GEOREFERENCING PROdEGT PHASE I AND II GPS CONTROL POINrs. ® NATURAL GAS WELL SURFACE LOCATION Consulting Group ~~~~ ETON (v~cLane Testing A,~,~„ , «n DATE BY APP RSMSKIIB Boat N0.: EL 907.263.421 B FAX 907.263.3265 N0.: O4.T0~ ~ Na: D4~ Marathon -.,D,. NARATHON Oil Company ORAYM 8Y: MSI{ • D1"~' APPNO""L GO PAD NINILCHIK, ALASKA NORTH ,~ GO N0.3 WELL AS-BUILT SURFACE LOCATION SCALE DMN. s DATE b7olw fYE N0. 0. i ~~ e o~ I ~~ NaNw Rsgbn MOD DISC SYST WIC N0. I8V 00 0 00 0001 1 O Marathon Oil Company Project: Grassim Oskolkoff #3 ~ :b' • CAS ~^. • < i+ I L ~ .r 1 `. ~. • !~ `.. y+ ~ ~ . y~ ~ jY •1 Raw 7~.;,-.1 _ ~~q.. - :q+~-,+/{_~.<' .. I - .. ~ a. 1 G , ~ •` of ,y~ ~?+.' ~~~- %-t~ -'' ~. ~ r ~,~~ --.fir I j ~ _-..- '~ ;-~ Project Location ~ ~ j-... - _ . ~ ,-~..,--~~-- ~--=~ ~ ~. 1 ^ ~ ~, ~_. t SE 1/4, NW 1/4, Sec 23, T1N, R13W ~ - ,~ti f ' ~ ~ - ~~ ,~~,, ~~~/ ~ -~ ~. -~-- • ~~ _~ • ~4 , G`''am ~ ~ _ '~,•.~_r''i + ._ 1 /~ ~ 'v/ "~ .:~- ~ .. nc ~ ~ IS. ~ 1._~.-. fr _ay ___.•i M1 i t Y 4 ~{, ! ^ ~ ~" 7 ~ 1 r- • . NINILCHIK . ~ ~ ~ ~ .. Y a Y _ + + - _ _ O _ - ~ - _ - ~ j w ~ . • ' Marathon Grassim Oskolkoff "'"' - -- _ - / •• _ _ PTD 13,765' MD; 8100' TVD .. ~~ r - -_ " -- - - ~- - ~ . ~ -' __ _~ _ _ _ - - • I - ~ 6 a y _ ,-- -- ,. ,. _ . 9 Hmu su ...~.....~ vo. ,~.. ., , .. ~. ~~ ~~~ ~wom.w.,,.v.a. i~.~~i~~:~n ~~~ ,,, n...~_. ..._~_..~..., ,~,..,, GLACIER DRILLING RIG #1 ~' MUD PITS AND PUMP ROOM LAYOUT //,~~ MARATHON Oil Company ^^ ~~ Location: Kenai Peninsula, Alaska Slot: MGO #3 vvnirr7 Field: Ninilchik Field Well: MGO #3 INTEQ Installation: MGO Wellbore: MGO #3 Ver 3 Scale 1 cm = 400 ft East (feet) -> -10400 -9600 -8800 -8000 -7200 -6400 -5600 -4800 -0000 -3200 -2400 -1600 Created by : Planner Date plotted : 14-Deo•2004 Plot reference Is MGO #3 Ver 3. Ref wellpath is MGO #3 Ver 3. Coordinates are 1n feet reference MGO ff3. True Vertical Depths are reference Rig Datum. Measured Depths are reference Fiig Datum. Rip Datum: Datum #1 Rig Datum to Mean Sea Level: 187.00 ft. Plot North is aligned to TRUE North. ~~ O~ ~O~` o~ OJ~~\Ob'~~' ~\~ ~~~~OO<OQ ry ~ ~C ~o~~`~`SGO'~ ~~, ~0a ~1 -800 n -1600 0 -2400 ~ 4-t -3200 4= o $00 I ~ -0 a~ c~ ~ 800 1600 yy 2400 .-. t w Q 3200 fy ~ 4000 4800 d 7 L ~ 5600 1 V 6400 7200 8000 8800 N -0000 ~' io RKB Elevation: 187' KOP 12.00 24.00 DLS: 4.00 deg/100ft 52.00 EOG WELL PROFILE DATA Point MD Inc Azi TVD North East daglt00ft V. Seel T+e on 0.00 0.00 255.91 0.00 0.00 0.00 0.00 0.00 KOP 250.00 0.00 255.91 250.00 0.00 0.00 0.00 0.00 End of Buitd 2000.00 70.00 255.91 1596.01 -229.46 -914.13 4.00 942.49 Target 8113.64 70.00 255.91 3687.00 -1828.14 -6486.21 0.00 6687.43 Target 11239.50 23.17 255.91 5777.00 -2165.39 -8626.53 1.50 11894.15 T.D. & Entl d Hold 13765.22 23.11 255.91 8100.00 -2406.77 -9588.12 0.00 9805.58 Begin Drop 65.5 61.00 52.00 47 MARATHON -800 0 800 800 OG COQ ~ {`} 0 MGO#3 T Tyonek - 911/04 -~- MGO#3 T2 - 9!1/04 ;p\ DLS: 1.50 deg/100ft 38.50 32.50 26.50 EOD -Target MGO#3 T3 - 9/1/04 TD 3 -aaoo ;; S -800 -0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 Scale 1 cm = 400 ft Vertical Section (feet) -> Azimuth 255.91 with reference 0.00 N, 0.00 E from MGO #3 • MARATHON Oil Company,MGO #3 PROPOSAL LISTING Page 1 __ MGO, Wellbore: MGO #3 Ver 3 ~~ MARATHON Ninilchik Field,Kenai Peninsula, Alaska Wellpath: MGO #3 Ver 3 INTE Date Printed: 14-Dec-2004 Q We_ ilbo~e _ _ T -` I Name Created Last Revised MGO #3 Ver 3 1-Oct-2004 14-Dec-2004 weir - N me -- ist Revised ---- --- -- _`_ _~___ -Oct-2004 Slot - - _ -- - -- -- _ _ __ -- -_-_`_~_ J -- - --- m hi rid E ti Latitude n stud North t MGO #3 2255186.0000 229103.6300 N60 9 53.0528 W151 29 14.3257 3235.62N 2372.94E insta~iation _ _ _ _ _ _ _ __ m Eastin Northi Coord S stem Name ' ` North Ali nment MGO 226657.854 2252005.162 AK-4 on NORTH AMERICAN DATUM 1927 datu True .Field ame Easti Northi Coons S stem Name No t Ninilchik Field 226657.8482 2252005.1188 AK-4 on NORTH AMERICAN DATUM 1927 datu True Comments -- _ __ - _ _ Same geometry as Vers#2, surtace location has changed from Vers#2 slightly All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #1 187.Oft above Mean Sea Level ) Vertical Section is from O.OON 0.00E on azimuth 255.91 degrees Bottom hole distance is 9885.58 Feet on azimuth 255.91 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated • MARATHON O[I Company,MGO #3 MGO, MARATHpN Ninilchik Field,Kenai Peninsula, Alaska • PROPOSAL LISTING Page 2 Wellbore: MGO #3 Ver 3 Wellpath: MGO #3 Ver 3 Date Printed: 14-Dec-2004 `~, ~I f INTEQ Weil at h Grid Re ort MD[ft) Incjdeg] Azi[deg] ND[ft) Station Position Y Station Position X Dogleg Seven Vertical Section ft Fasting. Northing ~i 0.00 0.00 255.91 0.00 O.OON 0.00E 0.00 0.00 229103.63 2255186.00 100.00 0.00 255.91 100.00 O.OON 0.00E 0.00 0.00 229103.63 2255186.00 200.00 0.00 255.91 200.00 O.OON 0.00E 0.00 0.00 229103.63 225518 .00 250.00 0.00 255.91 250.00 O.OON -0.OOE 0.00 0.00 229103.63 2255186.00 350.00 4.00 2 5.91 349.92 0.85S 3.38W 4.00 3.49 229100.23 225518 .2 450.00 8.00 255.91 449.35 3.39S 13.52W 4.00 13.94 229090.04 2255182.91 ' 550.00 12.0 255.91 547.81 7.62S 30.36W 4.00 31.30 229073.11 2255179.06 650.00 16,00 255.91 644.82 1 .51S 53.82W 4.00 55.49 229049.52 225517 .71 750.00 20.00 255.91 739.91 21.03S 83.78W 4.00 86.38 229019.39 2255166.86 50.00 24.00 255.91 832.61 30.15S 120.11 W 4.00 123.84 228982.87 2255158.56 950.00 28.00 255.91 922.47 40.82S 162.62W 4.00 167.67 228940.13 2255148.85 1050.00 32.00 255.91 1009.05 52.99S _ 211.11 W 4.00 217.66 228891.39 2255137.78 1150.00 36.00 255.91 1091.94 66.60S 265.33W 4.00 273.56 228836.87 2255125.39 1250.00 40.00 255.91 1170.72 _ 81.59S 325.03W 4.00 335.12 228776.85 2255111.75 1350.00 44.00 255.91 1245.03 97.88S 389.92W 4.00 402.02 228711.61 2255096.93 1450.00 48.00 255.91 1314.48 115.39S 459.68W 4.00 473.94 228641.48 2255081.00 1550.00 52.00 255.91 1378.74 134.03S 533.96W 4:00 550.52 228566.80 2255064.03 1650.00 56.00 255.91 1437.51 153.72S 612.41 W 4.00 631.41 228487.92 2255046.11 1750.00 60.00 255.91 1490.49 174.37S 694.65W 4.00 716.20 228405.25 2255027.32 1850.00 64.00 255.91 15 7.43 195.86S 780.27W 4.00 804.47 228319.16 2255007.76 1950.00 68.00 255.91 1578.09 218.10S 868.86W 4.00 895.81 228230.10 2254987.53 2000.00 70.00 255.91 1596.01 229.46S 914.13W 4.00 942.49 228184.58 2254977.19 2100.00 70.00 255.91 1630.21 252.34S 1005.27W 0.00 1036.46 228092.95 2254 56.37 2200.00 70.00 255.91 1664.42 275.22S 1096.41 W 0.00 1130.43 228001.32 2254935.55 2300.00 70.00 255.91 1698.62 298.09S 1187.55W 0.00 1224.39 227909.69 2254914:73 2400.00 70.00 255.91 1732.82 320.97S 1278.69W 0.00 1318.36 227818.06 2254893.91 2 00.00 70.00 255.91 _ 1767.02 343.85S 1369.84W 0.00 1412.33 227726.42 2254873.09 i 2600.00 70.00 255.91 1801.22 366.73S 1460.98W 0.00 1506.30 227634.79 2254852.27 2700.00 70.00 255.91 1835.43 389.61S 1552.12W 0.00 1600.27 227543.16 2254831.45 2800.00 70.00 255.91 1869.63 412.48S 1643.26W 0.00 1694.24 227451.53 2254810.63 2900.00 70.00 255.91 1903.83 435.36S 1734.40W 0.00 1788.21 227359.90 2254789.81 3000.00 70.00 255.91 1938.03 458.24S 1825.55W 0.00 1882.18 227268.26 2254768.99 3100.00 70.00 255.91 1972.23 481.12S _ 1916.69W 0.00 1976.15 227176.63 2254748.17 3200.00 70.00 255.91 2006.43 504.OOS 2007.83W 0.00 2070.12 227085.00 2254727.35 3300.00 70.00 255.91 2040.64 526.87S 2098.97W 0.00 2164.09 226993.37 2254706.53 ~ 3400.00 70.00 255.91 2074.84 549.75S 2190.11 W 0.00 2258.06 226901.73 2254685.71 3500.00 70.00 25 .91 _ 2109.04 572.63S 2281.25W 0.00 2352.03 226810.10 2254664.89 3600.00 70.00 255.91 2143.24 595.51S 2372.40W 0.00 2445.99 226718.47 2254644.07 3700.00 70.0 255.91 2177.45 61$.39S 2463.54W 0.00 2539.96 226626.84 2254623.25 3800.00 7 .00 255.91 2211.65 641.26S 2554.68W 0.00 2633.93 226535.21 22 602.43 3900.00 70.00 255.91 2245.85 664.14S 2645.82W 0.00 2727.90 226443.57 2254581.61 4000.00 70.0 25 .91 2280.05 687.02S 2736.96W 0.00 2821.87 226351.4 2254560.79 4100.00 70.00 255.91 2314.25 709.90S 2828.10W 0.00 2915.84 226260.31 2254539.97 4200.00 70.00 255.91 2348.45 732.78S 2919.25W 0.00 3009.81 226168.68 2254519.16 4300.00 70.00 255.91 2382.66 755.65S 3010.39W 0.00 3103.78 226077.05 2254498.34 4400.00 70.00 255.91 2416.86 778.53S 3101.53W 0.00 3197.75 225985.41 2254477.52 4500.00 70.00 255.91 2451.06 801.41S 3192.67W 0.00 3291.72 225893.78 22 456.70 4600.00 70.00 255.91 2485.26 824.29S 3283.81 W 0.0 3385.69 225802.15 2254435.88 4700.00 70.00 255.91 2519.47 847.17S 3374.95W 0.00 3479.66 225710.52 2254415.06 4800.00 70.00 55.91 2553.67 70.04S 3466.10W 0.00 3573.63 225618.89 2254394.24 4900.00 _ _ 70.00. _ 255.9E _2587.87. _892.925 3557.24W 0.00 3667.60 225527.25 2254373.42 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #1 187.Oft above Mean Sea Level ) Vertical Section is from O.OON 0.00E on azimuth 255.91 degrees Bottom hole distance is 9885.58 Feet on azimuth 255.91 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated MARATHON O[I Company,MGO #3 MGO, MARATHON Ninilchik Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Wellbore: MGO #3 Ver 3 Wellpath: MGO #3 Ver 3 Date Printed: 14-Dec-2004 If ~;Ryr; ~ 1 INTEQ Weil' at h Grid Re ort MD[ft} Inc[deg] Azi[deg] ND[ft) Station Position Y Station Position X Dogleg Severi Vertical e ft Fasting. Nortttirtg 5000.00 70.00 255.91 2622.07 915.80S 3648.38W 0.00 3761.56 225435.62 2254352.60 5100.00 70.00 255.91 2656.27 938.685 3739.52W 0.00 3855.53 22 343.99 22543 1.78 5200.00 70.00 255.91 2690.47 961.56S 3830.66W 0.00 3949.50 225252.36 254310.96 5300.00 70.00 255.91 2724.68 984.43S 3921.80W 0.00 4043.47 225160.73 225429 .14 5400.00 70.00 255.91 275 .88 1007.31S 4012.95W 0.00 4137.44 225069.09 2254269.32 5500.00 70.00 255.91 2793.08 1030.19S 4104.09W 0.00 4231.41 224977.46 2254248.50 00.00 70.00 255.91 2827.28 1053.07S 4195.23W 0.00 4325.38 224885.83 2254227.68 700.00 70.00 25 .91 2861.49 1075.95S 4286.37W 0.00 4419.35 224794.20 2254206.86 5800.00 70.00 255.91 2895.69 1098.83S 4377.51 W 0.00 4513.32 224702.56 2254186.04 5900.00 70.00 25 .91 2929.89 1121.70S 4468.66W 0.00 4607.29 224610.93 2254165.22 6000.00 70.00 255.91 2964.09 1144.58S 4559.80W 0.00 4701.26 224519.30 2254144.40 6100.00 70.00 255.91 2998.29 1167.465 _ 4650.94W 0.00 4795.23 224427.67 2254123.58 6200.00 70.00 255.91 3032.49 1190.34S 4742.08W 0.00 4889.20 224336.04 2254102.76 6300.00 70.00 255.91 3066.70 1213.21S 4833.22W 0.00 4983.16 224244.40 2254081.94 6400.00 70.00 255.91 3100.90 1236.09S 4924.36W 0.00 5077.13 224152.77 2254061.12 6500.00 70.00 255.91 3135.10 1258.97S 5015.51 W 0.00 5171.10 224061.14 2254040.31 6600.00 70.00 255.91 3169.30 1281.85S 5106.65W 0.00 5265.07 223969.51 2254019.49 6700.00 70.00 255.91 3203.51 1304.73S 5197.79W 0.00 5359.04 223877.88 2253998.67 6800.00 70.00 255.91 3237.71 1327.61S 5288.93W 0.00 5453.01 223786.24 2253977.85 69 0.00 70.00 255.91 3271.91 1350.48S 5380.07W 0.00 5546.98 223 94.61 2253957.03 700. 70.00 255.91 3306.11 1373.36S 5471.22W 0.00 5640.95 223602.98 2253 36.21 7100.00 70.00 255.91 3340.31 1396.24S 5562.36W 0.00 5734.2 223511.35 2253915.39 720 .00 70.00 255.91 3374.51 1419.12S 56 3.50W 0.00 5828.89 223419.72 2253894.57 7300.00 70.00 255.91 3408.72 1441.99S 5744.64W 0.0 5922.86 223328.08 2 53 73.75 7400.00 70.00 255.91 3442.92 1464.87S 5835.78W 0.00 6016.3 223 36.45 225 52.93 7500.00 70.00 255.91 3477.12 1487.75S 5926.92W 0.00 6110.80 223144.82 2253832.11 7600.00 70.0 255.91 3511.32 1510.63S 6018.07W 0.00 6204.77 223053.19 2253 11.29 7700.00 70.00 255.91 3545.53 1533.51 S 6109.21 W 0.00 6298.73 222961.55 2253790.47 7800.00 70.00 255.91 3579.73 1556.39S 6200.35W 0.00 6392.70 222869.92 2253769.65 7900.00 70.0 255.91 3613.93 1579.26S 6291.49W 0.00 6486.67 222778.29 2253748.83 8000.00 70.00 255.91 3648.13 1602.14S 6382.63W _ 0.00 6580.64 222686.66 2253728.01 8100.00 70.00 255.91 3682.33 1625.02S 6473.77W 0.00 6674.61 222595.03 2253707.19 8113.64 70.00 255.91 3687.00 1628.14S 6486.21 W 0.00 6687.43 222 82.52 2253704.35 8213.64 68.50 255.91 3722.43 1650.91 S 6576.91 W 1.50 6780.94 222491.34 2253683.63 8313.64 67.00 255.91 _ 3760.29 1673.44S 6666.67W 1.50 6873.50 222401.09 2253663.13 8413.64 65.50 255.91 3800.57 1695.72S 6755.45W 1.50 6965.02 222 11.84 2253642.85 8513.64 64.00 255.91 3843.22 1717.74S 6843.17W 1.50 7055.47 222223.64 2253622.81 8613.64 62.50 255.91 3888.23 17 9.48S 6929.78W 1.50 7144.76 222136.57 2253603.03 8713.64 61.00 255.91 3935.56 1760.93S 7015.21 W 1.50 7232.65 222050.67 2253583.51 8813.64 59.50 255.91 3985.18 1782.07S 7099.42W 1.50 7319.67 221966.02 2253564.28 8913.64 58.00 255.91 4037.06 1802.88S 7182.34W 1.50 7405.15 221882.65 2253545.34 9013.64 56.50 255.91 4091.15 1823.35S _ 7263.91 W 1.50 7489.26 221800.64 2253526.70 9113.64 55.00 255.91 4147.43 1843.48S 7344.OSW 1.50 7571.91 221720.04 2253508.39 9213.64 53.50 255.91 4205.85 1863.24S 7422.79W 1.50 7653.07 221640.91 2253490.41 9313.64 52.00 255.91 4266.38 1882.62S 7499.99W 1.50 7732.67 221563.29 2253472.77 9413.64 50.50 255.91 4328.97 1901.60S 7575.63W 1.50 7810.65 221487.24 2253455.49 9513.64 49.00 255.91 4393.58 1920.18S 7649.66W 1.50 7886.97 221412.82 2253438.59 ~ 9613.64 47.50 255.91 4460.17 1938.35S 7722.02W 1.50 7961.58 221340.07 2253422.06 i 9713.64 46.00 255.91 4528.69 1956.08S 7792.66W 1.50 8034.41 221269.05 2253405.92 9813.64 44.50 255.91 4599.09 1973.37S _ 7861.54W 1.50 8105.43 221199.80 2253390.18 9913.64 43.00 255.91 4671.32 1990.20S 7928.61 W 1.50 8174.58 221132.37 2253374.86 All data is in Feet unless othenrrise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #1 187.Oft above Mean Sea Level ) Vertical Section is from O.OON 0.00E on azimuth 255.91 degrees Bottom hole distance is 9885.58 Feet on azimuth 255.91 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated MARATHON Oil Company,MGO #3 MGO, MARATHON Ninilchik Field,Kenai Peninsula, Alaska U PROPOSAL LISTING Page 4 Wellbore: MGO #3 Ver 3 Wellpath: MGO #3 Ver 3 Date Printed: 14-Dec-2004 ~i~ IN'I'EQ Weii at h Grid Re ort MDIftI I~I~9l Azi[deg] ND[ft] Station Po ition Y Station Position X Dogleg Severi Vertical. S Fasting Northing ' li 10013.64 41.50 255.91 4745.34 2006.57S 7993.82W 1.50 8241.81 221066.80 2253359.97 10113.64 40.00 255.91 4821.09 2022.46S 8057.13W 1.50 8307.09 221003.15 2253345.51 10213.64 38.50 255.91 4898.53 2037.87S 8118.49W 1,50 8370.36 220941.46 2253331.49 10313.64 37.00 255.91 4977.60 2052.77S 8177.87W 1,50 8431.58 220881.76 2253317.92 10413.64 35.50 255.91 5058.24 2067.17S 8235.22W 1,50 8490.70 220824.10 2253304.82 10513.64 34.00 255.91 5140.40 2081.05S 8290.50W 1.50 8547.70 220768.52 2253292.20 10613.64 32.50 255.91 5224.03 2094.40S 8343.68W 1.50 8602.53 220715.06 2253280.05 10713.64 31.00 255.91 5309.06 2107.21S 8394.72W 1.50 8655.15 220663.75 2253268.39 10813.64 29.50 255.91 395.44 2119.47S 8443.58W 1.50 87 5.53 220614.62 2253257.23 10913.64 28.00 255.91 5483.11 2131.18S 8490.23W 1.50 8753.62 22 567.72 2253246.57 11013.64 26.50 255.91 5572.01 2142.33S 8534.64W 1.50 8799.41 220523.08 2253236.43 11113.64 25.00 255.91 5662.08 2152.91S 8576.77W 1.50 8842.85 220480.71 2253226.80 11213.64 23.50 255.91 5753.25 2162.90S 8616.61 W 1.50 8883.92 220440.66 2253217.70 11239.50 23.11 255.91 5777.00 2165.39S 8626.53W 1.50 8894.15 220430.69 2253215.44 11300.00 23.11 255.91 5832.64 2171.18S 8649.56W 0.00 5917.90 220407.53 2253210.18 11400.00 23.11 255.91 5924.62 2180.73S 8687.64W 0.00 8957.15 220369.25 2253201.48 11500.00 23.11 255.91 6016.59 2190.29S 8725.71 W 0.00 8996.41 220330.98 2253192.78 11600.00 23.11 255.91 6108.56 2199.85S _ 8763.78W 0.00 9035.66 220292.70 2253184.09 11700.00 23.11 255.91 6200.54 2209.40S 8801.85W 0.00 9074.91 220254.42 2253175.39 11800.00 23.11 255.91 6292.51 2218.96S 8839.92W 0.00 9114.17 220216.15 2253166.69 11900.00 23.11 255.91 6384.48 2228.52S 8878.OOW 0.00 9153.42 220177.87 2253157.99 12000.00 23.11 255.91 6476.46 2238.07S 8916. 7W 0.00 192.67 220139.59 2253149.30 12100.00 23.11 255.91 6568.43 2247.63S 8954.14W 0.00 9231.93 220101.32 2253140.60 12200.00 23.11 255.91 6660.41 2257.19S 8992.21 W 0.00 9271.18 220063.04 2253131.90 12300.00 23.11 255.91 6752.38 2266.74S 9030.28W 0. 0 9310.43 220024.76 2253123. 1 12400.00 23.11 255.91 6844.35 2276.30S 9068.36W 0.00 9349.69 219986.48 2253114.51 12500.00 23.11 255.91 693 .33 2285.86S 9106.43W 0.00 9388.94 219948.21 2253105. 1 12600.00 23.11 255.91 7028.30 2295.41S 9144.50W 0.00 9428.19 219909.93 2253097.12 12700.00 23.11 255.91 7120.28 2304.97S 9182.57W 0.00 9467.45 219871.65 2253088.42 12800.00 23.11 255.91 7212.25 2314.53S 9220.65W 0.00 9506.70 219833.38 2253079.72 12900.00 23.11 255.91 7304.22 2324.08S 9258.72W 0.00 9545.95 219795.10 2253071.03 13000.00 23.11 255.91 7396.20 2333.64S 9296.79W 0.00 9585.21 219756.82 2253062.33 13100.00 23.11 255.91 7488.17 2343.20S 9334.86W 0.00 9624.46 219718.55 2253053.63 13200.00 23.11 255.91 7580.15 2352.75S 9372.93W 0.00 9663.71 219680.27 2253044.94 13300.00 23.11 255.91 7672.12 2362.31 S 9411.01 W 0.00 9702.97 219641.99 2253036.24 1 00.00 23.11 255.91 7764.09 2371.87S 9449.08W 0.00 9742.22 219603.72 2253027.54 13500.00 23.11 255.91 7856.07 2381.42S 87.15W 0.00 9781.47 219565.44 225 018.85 13600.00 23.11 255.91 7 48.04 2390.98S 9525.22W 0.00 9820.73 219527.16 22 3010.15 1 700.00 23.11 255.91 8040.01 2400.54S 9563.29W 0.00 9859.98 219488.88 2253001.45 13765.22 23.11 255.91 8100.00 2406.77S 9588.13W 0.00 9885.58 219463.92 2252995.78 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #1 187.Oft above Mean Sea Level ) Vertical Section is from O.OON 0.00E on azimuth 255.91 degrees Bottom hole distance is 9885.58 Feet on azimuth 255.91 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated • MARATHON Oil Company,MGO #3 MGO, MARATHON Ninilchik Field,Kenai Peninsula, Alaska • PROPOSAL LISTING Page 5 Wellbore: MGO #3 Ver 3 Wellpath: MGO #3 Ver 3 Date Printed: 14-Dec-2004 ~f~ iNTEQ Comme nts ~ M 7VD ft ft Eas ft Comment I 250.00 25 .00 O.OON 0.00E i KOP 2000.00 1596.01 229.46S 914.13W _ EOC i 811 .64 3687.00 1628.14S 6486.21 W Be in Dro 11239.50 5777.00 2165.395 8626.53W EOD -Target i 13765.22 8100.00 2406.77S 9588.13W TD i Tar ets N m North ft a t ft TVD ft Lati e L stud Eastin Northi Last Re ' MGO#3 T3 - 9/1/0 2175.01S 8500.97W 5777.00 N60 9 31.603 W151 32 2.29 220556.00 2253203.00 10-Feb-2003 MGO#3 T2 - /1/0 1942.74S 7736.99W 3972.00 N60 9 33.895 W151 31 47.19 221325.00 225341 .00 10-Feb-2003 MGO#3 T Tyonek 1719.10S 9/1/04. 7000.83W 3687.00 ~ N60 9 36.102 W151 31 32.65 222066.00 - 2253625.00 -- 10-Feb-2003 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Datum #1 187.Oft above Mean Sea Level ) Vertical Section is from O.OON 0.00E on azimuth 255.91 degrees Bottom hole distance is 9885.58 Feet on azimuth 255.91 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~,!R~~ ' MARATHON Oil Company ~~S Location: Kenai Peninsula, Alaska SIOt: MGO #3 INTEQ Field: Ninilchik Field Well: MGO #3 Installation: MGO Wellbore: MGO #3 ver 3 t:reatecoy: runner Date plotted : ,4Deo-2004 Plot reference is MGO #3 Ver 3. Ref wellpath is MGO #3 Ver 3. ~~I Coordinates are in feet reference MGO #3. ~, True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Scale 1 I;IglDatttAtQo{~tean sea Level: ,szoo n. East (feet) -> Plot North is aligned to TRUE North. -1520 -1440 -1360 -1280 -1200 -1120 -1040 -960 -880 -800 -720 -640 -560 -480 -400 -320 -240 -160 . __I I I I I I - ~ ---- 1- L_ ~.._ 1 _ L 1-_ - ~_.___ __ - 1. _. 1 ---~-- ~---~ ~c~~`i 1500 00 1700 1500 1700 M MARATHON -80 0 80 160 240 320 1300 1100 900 700 500 '~ 300 1500 1300 1100 900 700 5~0 700 900 1100 1300 480 400 320 240 160 n 80 ~ 0 ~ M ~D ~D .r -80 ~'' -160 -240 -320 m m n -400 ~ I A O X80 ~ ~~~~ '! MARATHON Oil Company ~Qr~s LOCation: Kenai Peninsula, Alaska Slot: MGO #3 INTEQ Fleld: Ninilchik Field WEII: MGO #3 Installation: MGO Wellbore: MGO #3 ver 3 rested by : Planner '. _ Date plotted : 14-Dec-2004 ' Plot reference is MGO #3 Ver 3. Ref wellpath is MGO #3 Ver 3. Coordinates are in feel reference MGO #3. '. True Vertical Depths are reference Rig Datum. I Measured Depths are reference Rig Datum. I Rig Datum: Datum #1 Rig Datum to Mean Sea Level: 187.00 ft. '~, Plot No igned to TRUE North. s~ie 1 ~m~~~ ~ - - ~ East feet) -> -3400 -3300 -3200 -3100 -3000 -2900 -2800 -2700 -2600 -2500 -2400 - 300 -2200 -2100 -2000 -1900 I I -.1 . 1-----1---1 ---'--_L -. `-~-~-----.!__.-~ 11---.1. 1- 1 1 -!_ ~ I I I I ~~ ~w MGO #2 I - 4300 2900 I \ 4100 ,.,,ro^„~,,., _ __ . _ _ 4900 _ 4700 3900 2700 2500 ~ 3700 4500 4300 3500 4100 _ 3900 3700 3300 2100 ~ 3100 2300 M MARATHON 1800 -1700 -1600 -1500 -1400 -1300 -1200 I I i-L-- - I_ L l 1 1_-- 1_.. ~ i L~ 300 I 200 - --- _.._ -- MGO #2 r 2300 - 100 - 0 -100 l 1900 ,- _ _ 3300 _ 3100 ,~ 2900 ~~ A -200 ~ Me0µ3Ve~~ ~ -300 3 .~ - X00 ~'' -500 ,___ 2900 *~~.., -600 Ir -700 m n -000 ~ I I Q - _900 ~ ~,,,! R~~ '~ MARATHON Oil Company ~~S ii LOCation: Kenai Peninsula, Alaska SIOt: MGO #3 INTE:(~ Field: NinilchikField Well: MGO#3 Installation: MGO Wellbore: MGO #3 Ver 3 Created by : Planner Date plotted : 14-Dec-2004 PIo4 reference is MGO #3 Ver 3. Ref wellpath is MGO #3 Ver 3. I Coordinates are in feet reference MGO #3. i True Vertical Depths are reference Rig Datum. ~~~. Measured Depths are reference Rig Datum. Rig Dalum: Datum #1 Rig Datum to Mean Sea Level: 187.00 ft. Plol North is aligned to TRUE North. I SCB~e ~ Cfll = 200 fl - -- -- - East (feet-> -10400 -10000 -9600 -9200 -8800 -8400 -8000 -7600 -7200 -6800 -6400 -6000 -56 -5200 4800 - I---~J---L I I-- ----- -- -- -----~------- -~1 1_ L- I l _.----- ---- ~ --- ~~ M MARATHON 4400 -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 ~_-l.-.I I I___. I I _L---I I J--- -.. _._~ 1200 800 10~gQoQ~ 5500 Y5Tj~~0p 0 5000 aoo 'MGO#2 ~ $0075007000 6500 3 -4500 3000 _2500 -- - _ 7000 5500 4500 4000 ~p~ MGO#2~ 8000 7500 6500 6000 0000 - - -EiII00 ~----~_ o 5500 4000 5000 ~- 4500 _ 3500 3500 ~O"3ve~~ 400 4000 3000 3500 4500 MGO #3 Ver 3 ~~ 00500 8ood5od 5500 5000 4000 3000 ~_r- -- ~ ,~ _ -soo -lzoo tD - tD .~ -lsoo `-' - -zooo -zooo -zaoo °' m 3200 N O O 3600 ~ ~ ~ MARATHON Oil Company ~.. ~ __ __ LOCatiOn: Kenai Peninsula, Alaska SIOt: MGO #3 Field: Ninilchik Field Well: MGO #3 INTF.Q Installation: MGO Wellbore: MGO #3 Ver 3 Dreated by : Planner Date plotted : 1MDec-2004 lotlot reference is MGO #3 ~$ ~ Ref welipath is MGO #3 Ver 3. Coordinates are in feet reference MGO #3. True Vertical Deplhs are reference Rig Datum. '.. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to Mean Sea Level: 187.00 ft. Plot North is aligned to TRUE North. TRUE NORTH 350 0 10 0 340 20 ~~ 330 30 300 290 280 270 260 250 24( 200 160 190 180 170 Normal Plane Travelling Cylinder -Feet All depths shown are Measured depths on Reference Well M MARATHON ~N 300 i0 70 80 90 100 110 120 210 15U MARATHON O[I Company CLEARANCE LISTING Page 1 ~/~~ MGO #3 Ver 3, MGO #3 Ver 3 Date Printed: 14-Dec-2004 MARATHON MGO #3, MGO Ninilchik Field, Kenai Peninsula, Alaska INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and Magnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/1000ft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casings are NOT included Hole size/Casings are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.OOstandard deviations. Closing Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation ~11b Wel'I Name Government ID Last Revised. MGO #3 1-Oct-2004 ;S[Ot Field - - - - . Name Eastin Northin - Coord S stem Name ___ __ __ __ North Alignment Ninilchik Field 226657.848 2252005.118 AK-4 on NORTH AMERICAN DATUM 1927 datu _ True Clearance Summa Offset Offset Offset Offset Minimum MD[ft] Diverging Ellipse Ellipse Clearance Clearance WaIlName Wellbore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft] ft ft MGO #1 MGO #1 MGO #1 MGO 152.8 0.00 0.00 MGO #2 MGO #2 MGO #2 MGO 193.5 328.0 328.0 All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 187.Oft above Mean Sea Level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated • MARATHON O[I Company MGO #3 Ver 3, MGO #3 Ver 3 MARATHQN MGO #3, MGO L' CLEARANCE LISTING Page 2 Date Printed: 14-Dec-2004 Ninilchik Field, Kenai Peninsula, Alaska ~~~ ~i iNTEQ Clearance Dat a :Reference MD[ft] Reference TVD[ft] Reference North[ft] Reference East[ft] Offset Well Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] Angle From ... Highside d Closest Approach Distance ft ElNpse, .Separation [ftj' 0.00 0.00 O.OON 0.00E MGO #2 0.00 0.00 100.52N 166.02 58.8 194.0 100.0 100.0 O.OON 0.00E MGO #2 99.4 99.40 100.85N 166.06 58.7 194.2 200.0 200.0 O.OON 0.00E MGO #2 199.11 199.11 101.72N 166.04 58.5 194.7 250.0 250.0 O.OON 0.00E MGO #2 254.2 254.2 102.45N 165.14 58.2 194.3 328.0 328.0 0.525 2.06 MGO #2 338.5 338.3 104.05N 160.53 161.4 193.5 350.0 349.9 0.85S 3.38 MGO #2 362.4 362.1 104.53N 158.55 161.1 193.5 450.0 449.3 3.39S 13.52 MGO #2 471.6 470.6 106.18N 145.97 159.7 194.6 550.0 547.81 7.62S 30.36 MGO #2 582.4 579.8 106.02N 127.40 158.6 197.0 650.0 644.8 13.51 53.82 MGO #2 688.8 683.7 105.47N 104.51 157. 201.8 750.0 739.91 21.03 83.78 MGO #2 792.7 784.3 105.32N 78.40 156.6 210.3 850.0 832.61 30.15 120.11 MGO #2 897.7 885.0 105.66N 48.74 155.8 222.9 950.0 922.4 40.82 162.62 MGO #2 1010.4 991.1 105.68N 10.97 154.8 237.3 1050.0 1009.0 52.99 211.11 MGO #2 1122.51 1093. 105.36N 33.69 153.7 252.5 1150.0 1091.9 66.60 265.33 MGO #2 1236.4 1194.8 105.16N 86.43 152.3 268.51 1250.0 1170.7 81.59 325.03 MGO #2 1347.2 1289.4 104.30N 144.23 150.9 285.1 1350.0 1245.0 97.88 389.92 MGO #2 1463.2 1384.1 102.90N 211.02 149. 302.7 1450.0 1314.4 115.39 459.68 __ MGO #2 1574.2 1469.9 101.80N 281.47 147.9 321.0 1550.0 1378.7 134.03 533.96 MGO #2 1682.7 1550.7 101.27N 353.88 146. 342.5 1650.0 1437.51 153.72 612.41 MGO #2 1791.1 1627.3 101.28N 430.46 145.1 366.31 1750.0 1490.4 174.37 694.65 MGO #2 1898.4 1699.11 102.19N 510.35 143.7 392.3 1850.0 1537.4 195.86 780.27 MGO #2 2009.7 1768.9 103.79N 596.93 142. 420.7 1950.0 1578.0 218.10 868.86 MGO #2 2113.5 1830.31 106.25N 680.59 141.0 451.9 2000.0 1596.01 229.46 914.13 MGO #2 2169.1 1861.4 108.10N 726.53 140.3 468.6 ~I1 CCU .L L~J_~~L ~ ~ A__~ __~ _ T. ~ R___ v~av~ txtii~ruv~c vui v~ ~ vw rev farm Well- Wellbore Surve Name MD ft Surve T 1 ~ E I MGO #2 MGO #2 GYRO<0-2500 2500.0 No Tool No Model MGO 2 MGO #2 _ MWD<2500-12026'> 12026.0 No Tool No Model All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 187.Oft above Mean Sea Level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated • M MARATHON MARATHON O[I Company MGO #3 Ver 3, MGO #3 Ver 3 MGO #3, MGO r-- CLEARANCE LISTING Page 3 Date Printed: 14-Dec-2004 Ninilchik Field, Kenai Peninsula, Alaska ~._ 1~! INTEQ i~l@a~a~tC@ Uat a .Reference MD[ft] Reference TVD[ft] .Reference North[ft] Reference East[ft] Offset Well Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] Angle From Highside d Cbsest Approa~ Distance ft fNipse Separation [ft] 0.00 0.00 O.OON 0.00E MGO #1 0.00 0.00 123.08N 90.62 36.4 152.8 0.00 0.00 O.OON 0.00E MGO #1 0.00 0.00 123.08N 90.62 36.4 152. 100.0 100.0 O.OON 0.00E MGO #1 99.41 99.41 123.31 N 90.68 36.3 153.0 200.0 200.0 O.OON 0.00E MGO #1 198.8 198.8 123.92N 90.81 36.2 153.6 250.0 250.0 O.OON 0.00E MGO #1 249.1 249.1 124.74N 90.26 35.9 153.9 350.0 349.9 0.85S 3.38 MGO #1 349.61 349.3 128.64 85.49 138. 157. 450.0 449.3 3.39S 13.52 MGO #1 448.9 447.9 135.73N 75.64 136. 165.2 550.0 547.81 7.62S 30.36 MGO #1 547.3 545.0 144.93N 63.08 134. 178.9 650.0 644.8 13.51 53.82 MGO #1 643.91 639.9 155.90 48.84 133. 198.1 750.0 739.91 21.03 83.78 MGO #1 739.7 733.6 168.36 33.05 133.6 222.6 850.0 832.61 30.15 120.11 MGO #1 832.6 823.6 183.21 N 14.85 133.2 252.61 950.0 922.4 40.82 162.62 MGO #1 925.8 912.3 200.99N 7.03 132. 287.7 1050.0 1009.0 52.99 211.11 MGO #1 1018.21 998.5 221.35N 33.32 131. 327.0 1150.0 1091.9 66.60 265.33 MGO #1 1108.11 1081.0 243.01 61.77 130. 370.6 1250.0 1170.7 81.59 325.03 MGO #1 1197.3 1161.3 266.14N 92.90 129. 418.2 1350.0 1245.0 97.88 389.92 MGO #1 1286.6 1239.0 291.73 128.68 128.1 469.1 4f~~e# Wellbore Surve Tooi Pro rams Well Wellbore Surve a MD ft Surve Tool rror Mod MGO #1 MGO #1 PMSS<0-11600'> 11600.0 No Tool No Model All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Datum #1 187.Oft above Mean Sea Level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated File Edit Proftles Table Tools Offset Data Units Window Help ~"". J ~ "E _1J ~ ~20 (1i ~i ~ I 1 3° 1 30 Li Wellbore Details) Offset Data Wellpath 181'. E ~~ ~~~ [-- Coordinates --------- - MD _- -- TVD - ----- I l' Field r' Instalation ~ 51ot ~ Slot C` Rig Datum ' C` Field ("' Installation C 51ot ~ Rig Datum Datum P: Datum #1 [187.0] 30-Sep-2004 J © Paradigm Geophysical Ltd. 2003 Q I I Mar W°~o d~~hCr oll C cat'On: ass''ri p '°anY kenal' Alaska°ff#3 G ~ V ID 1' O R . o s • ~ ,. "~cT ~- ~ °~~ ~ ~~ F ~°re ~~ pared F vl/~ ~N or.• k // Gr ~lL e,~ai p assim C~0 ~ni Os ~A n ~ ~. ~~~~ /ate. 3 Prepared by. ReV ~ewea b . ~ohy ~yka~sk r 3'• $a y P esej'ted to. ~ ~art'os ~tll Tahk 1 %, I FHG rHTFG I~FFR1~ rFD D~~e~ber IS P~H ~~ Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: Will Tank Will: • Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Enclosed is the recommended drilling fluid program for the Grassim Oskoloff #3 Well to be drilled next year. The following is a brief synopsis of the program. Overview: GO #3 is a development well targeting the Tyonek formation at the Susan Dionne field. A GeUGelex spud mud is recommended for the surface interval. Two Flo-Pro fluids will be used for the intermediate and production intervals. After logging the production interval, the well will be completed with 4-1/2" liner cemented in place. Surface Interval: A standard fresh water GeUGelex spud mud will be used. Initial funnel viscosity should be in the 50 - 75 sec/qt range. Lower funnel viscosity to 45 - 60 sec/qt after gravel has been drilled. Lower fluid loss to 10 - 12 cc's API prior to running surface casing. Intermediate Interval: This interval will be drilled with the same type of Flo-Pro fluid used on the SD #3 well. After drilling out the surface cement, the well will be displaced to the new fluid. SafeCarb bridging material will be maintained according to the mud program to minimize losses to the formation. Lubricants should be added on a as-needed basis. Production Interval: This interval will be drilled with the standard non-damaging Flo-Pro fluid used on non-excape wells. After drilling out the intermediate cement and 20 - 25 feet of new hole, the well will be displaced to the new fluid. Fluid loss should be maintained @ 5 - 7 cc's API for this interval. Completion: The completion will consist of a 4-1/2" liner cemented in place. This will be tied back to the surface with a 4- 1/2" completion string. Corrosion control will be added to the 6% KCl brine that will remain in the 4-1/2" x 7" annulus prior to tie-back. Tony Tykalsky Project Engineer M-I Drilling Fluids Reference Well: GO #1 & GO #2 NOTE: This program is provided as a guide only. Well conditions will always dictate fluid properties required. ~~ • • ~~ Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. EXECUTIVE SUMMARY ~,~~+:,x~, sa~~ s~~ , ~~. ~M'-RONM@~p~. Our overall goal is no M-I/Swaco HSE incidents while providing fluids and solids control services to our customer. Our goal for GO #3 is to remove drill solids from the mud system at a cost of less ! .than $0.23 per pound. This has been the average for the last four years of centrifuge ~ van operations JM Our goal for GO #3 is to drill the well at a fluid cost of less than $19.48 per foot with a total volume of fluid used less than 5233 barrels. Use of the MI Swaco centrifuge van for the last four years has provided an estimated savings in dilution and disposal costs to Marathon Oil of over $800,000. With continued usage of our equipment, we expect to provide more savings to you during future operations. ~~ • Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Interval Benchmarks and Targets Drilling Intervals Depth Benchmark 1 Benchmark 2 Benchmark 3 Benchmark 4 Interval eft) Fluid cost per foot Volume Usage Solids Removal 0 - 2500' < $4.16 ft < 1676 bbls 2500 - 7292' < $30.06 ft < 1928 bbls 7292 - 13765' < $17.56 ft < 1379 bbls Total Project Avg. Max. Targets for < $19.48 < 5233 bbls < $0.23 lb o Spills from Centrifug Drilling Van Operation Interval ~:~ • • '~ Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Project Summary Casing Hole Casing Depth ND Mud Mud Sum Interval Size Size Program System Weight Days.. Mud Cost (in) (in) (ft) (ft) Solids Control (ppg) 9-5/8" 12-1/4" 2500' 1767' GeUGelex Spud 8.6 - 9.4 5 $10,394 f ~ Mud _ ,, '~ Screens 150/1$0 + mesh Desilter ` ,r,. Centrifuge Van 7" 8-1/Z" '° 7292' 3406' Flo-Pro 9.4 -10.0 . 10 $.144,071. ,, w/SafeCarb Screens 180 - 210 mesh Desilter '' ,;::.. Centrifuge Van 4-1/2" 6-1/8" 13765' 8100' Flo-Pro .6 10. 10 $113,680 w/SafeCarb -'~~~ Screens 230 - 210 mesh Desilter Centrifuge Van 4-1/2" 6-1/8" Completion 13?65' 8100' 6% KCl 8.55 4 $3,314 - Utilize all solids control equipment to minimize the build up of drill solids in the system (if possible, centrifuge the surface mud during trips to reduce drill solids). - Condition the mud prior to running casing for all intervals. - Cost does not include any considerations for whole mud losses. - Cost includes 3% Lubetex concentration for intermediate and production interval. • ~~ Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Product Usage Summary PRODUCT Surface 12-114" Intermediate 8-1/2" Production 7" Completion 3-1/2" Total Usage % of Total Cost` M-I Bar 84 1350 1379 0 2813 7.01 M-I Gel 670 0 0 0 670 1.93 Gelex 21 0 0 0 21 0.09 Soda Ash 12 13 10 0 35 0.19 Caustic Soda 17 19 17 0 50 0.48 Con or 404 0 4 5 0 9 3.84 Sodium Meta Bisulfate 17 39 28 3 87 2.11 Bicarb 17 13 10 0 40 0.26 Con or 303A 0 0 0 1 1 0.18 F1oVis 0 154 110 0 264 19.28 Desco CF 17 0 0 0 17 0.30 DualFlo 0 0 138 0 138 4.50 Polypac UL 10 77 0 0 87 5.05 Greencide 25G 0 0 2 0 2 1.22 Bioban BP Plus 0 77 55 0 132 1.08 KCl 0 810 579 105 1494 6.97 Kla and 0 26 19 0 45 11.59 Safecarb 0 386 276 0 662 4.29 Lubetex 0 44 31 0 75 20.41 Defoam X 0 21 8 0 29 0.95 Asphasol Su reme 0 154 110 0 264 8.27 En ineer Service 5 10 10 4 29 ~~ • • '~ Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Offset Well Information Well Hole Size Depth PPG PV YP FL Comments GO #1 12.25" 945 8.6 14 26 9.9 Spud in, drlg ahead 1479 8.8 20 32 7.4 Short trip, OK 1897 8.9 20 35 7.3 Trip for bit & motor 2468 9.6 22 32 7.6 Drlg ahead w/short trip 2500 9.4 18 26 9 Drlg to T.D., run casing 8.5" 3488 9.45 8 22 9.8 Drig out, displace mud, drlg ahead 4138 9.55 9 27 9.8 Run solids van, add lubetex for sliding 4762 9.7 9 24 10.8 Added DD for clays, running solids van 5248 10.1 13 29 8.8 Running centrifuge van for dry Jobs 5617 9.75 10 23 8.1 Drlg ahead, diff stuck, work free, short trip 6290 9.75 10 24 6.9 Condition mud, drlg ahed 6567 9.8 10 21 7.2 Drlg ahead POH for BOPS & BHA 6976 9.55 9 23 8.5 RIH drlg ahed 7358 9.8 8 18 7.3 Drlg ahead, short trip, weight up for running shale 7578 10 9 17 7.5 Ream to bottom, drlg ahead 8086 9.6 14 30 6.2 Drlg to casing point, condition hole for logs, add lubetex 8086 10 9 27 6.3 Finish logging, run and cement casing 6.125" 8765 10 9 23 7.3 Drlg out, blend old/new mud drlg ahead 9393 9.9 9 22 6.4 Drlg ahead, POH, lost cone 9393 10.1 10 21 6.4 Fish for bit cone 9404 10.1 10 20 6.5 RIH w/mill, work to td, RIH w/drlg assembly 9718 10 9 28 6.4 Drill ahead 10010 10 9 28 5 CBU, POH 10443 10 12 31 5.6 5' fill on bottom, increased connection gas 11016 10 12 29 5.8 Drlg ahead, run van for drill solids 11305 10.05 12 28 6.4 Drlg ahead 11600 10 11 27 6.2 POH for logs, 11600 10 11 27 6.2 Run & cement 4-1/2" liner '~ • • Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Offset Well Information GO #2 12.25" 866 9 15 33 10 Spud in, drlg to 866, trip for BHA 1163 9.65 21 42 7.2 Drlg ahead, hard to slide 1495 9.6 16 44 6.2 Drlg ahead, added Lubetex to help slide 1695 9.45 13 40 6.9 Drlg ahead, trip fo new BHA, drlg ahead 2240 9.8 13 37 8 Drlg ahead, run centrifuge and desilter for solids 2500 9.75 14 38 8 Drlg to csg point, cond hole run casing 8.5" 2935 10.1 8 28 7.8 Drlg out, disp to new mud, drlg ahead 3639 10.05 10 29 7 Solids building up, start centrifuge van, 4355 10.1 11 30 8.4 Drlg ahead, run centrifuge van 4702 10.1 13 31 8.2 Drlg ahead, run centrifuge van 5344 10.15 14 31 8 MBT increasing, dump and dilute 5727 10.2 13 26 8.2 MBT increasing, dump and dilute 6247 10.25 14 24 7.5 Rig repair, circulate & cond mud 6507 10.1 14 31 8.9 POH test BOPE 6667 10.35 17 33 8 RIH, mad pass log well, 7030 10.2 16 28 7.3 Drlg ahead 7345 10.2 17 23 7 Short trip, backream as needed 7788 10.3 16 28 7.5 Stuck @ 7113', coal, backream, add lubetex to 2% 8118 10.35 18 29 9 Increase lubetex concentration to 3% 8422 10.35 18 28 8.8 Centrifuge mud for fines (MBT) 8530 10.3 18 30 8.6 Sweep hole, POH for logs 7" 8644 9.5 7 20 5.5 Drlg out, disp to new mud, drlg ahead 9402 9.6 8 23 4.5 Drlg ahead 10018 9.95 10 26 5.2 Increase mud weight to 9.9 PPG 10835 9.95 12 28 5.8 Dump & dilute to reduce drill solids 11338 10.15 11 23 5.8 Inc mud weight for high trip tgas 11995 10.25 10 27 6.6 Losing mud to hole after weight up 12026 10.4 11 26 6.4 Swabbing, increase mud weight, pump OOH 12026 10.4 8 24 6.5 Logs hit bridge at 8640' 12026 10.45 8 24 6 Difficulty logging, engr released 11/4 1~ ~~ • • '~ Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Plans & Procedures ~ COMMUNICATION -The Field Mud Engineer will communicate daily with the In-Town Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, possible changes to the mud program, and proposals to use products not included in the mud program. ~ Whole Mud Losses to the formation - Refer to fluid formulas and the Optibridge charts for maintaining proper bridging material concentration in the mud system while drilling the intermediate and production intervals. ~ FLUID LOSS CONTROL - In the intermediate interval the API fluid loss will be maintained in the 7 - 9 cc's range. In the production interval the API fluid will be maintained in the 5 - 7 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum . It is particularly important to maintain a low hardness (<200 ppm Ca) for effective use of DualFlo, therefore cement contamination should be completely treated as rapidly as possible prior to adding DualFlo to control or reduce fluid loss. NOTE: If additions of DualFlo do not appear to be lowering the fluid loss adequately, then switch to additions of Polypac Supreme SL after consultation with town. ~ LSRV - When drilling with a F1oPro fluid, the low shear rate rheology should be maintained around 30,000 cps. In addition to adequate additions of F1oVis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted high LSRV. ~ DRILL SOLIDS -MBT -The MBT should be kept at less than 5 ppb in the production interval through aggressive use of solids equipment and dilution as needed. ~ MIXING CONDITIONS -Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCl should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. ~ CORROSION - Congor 404 additions should be made daily when drilling with F1oPro fluid in order to maintain a Congor 404 concentration of +/- 2000 PPM. ~ CORRISION - Sodium Meta Bisulfate additions should be made daily as needed with any fluid in the hole. Maintain a DO reading of less than 3 ppm ~ GREENCIDE 25G ADDITIONS - Greencide 25G additions should be made daily when drilling in the production interval, in the range of 5 gallons per day. ~ SOLIDS VAN USAGE -The Solids Van should be used whenever drill solids become un-acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the determining condition for when to use the Solids Van. ~ WEIGHTING UP -All increases in mud weight should be accomplished with barite additions. In the production interval, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. ~~ • Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Interval Summary -12-1/4" hole 0 - 2500' Drilling Fluid System GeUGelex Spud Mud Key Products MI Gel / Gelex /Soda Ash /Caustic Soda / MI Bar / PolyPac Supreme UL /Sodium Meta Bisulfate Solids Control. Shale Shakers / Desilter /Centrifuge Van Recommended shaker screens - 150 - 180 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Interval Drilling Fluid Properties Depth Mud Funnel Yield API Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (sec./qt) (lb./100ft2) (ml/30min) {%) 0 - 2500' 8.6 - 9.4 60 - 100 25 - 35 NC -10/12 +/- 9.5 < 7% - Treat drill water with Soda Ash to reduce hardness. - Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 sec.gt funnel viscosity. - Lower funnel viscosity to +/- 60 after gravel zone has been drilled. - Add Gelex as needed to maintain sufficient viscosity for hole cleaning. - Increase funnel viscosity if fill on connections begins to occur. - Reduce fluid loss with additions of Polypac Supreme UL prior to running surface casing. - Add 2 - 5 PPB of M-I Seal Fine to mud system if seepage losses becomes a problem.. - Condition mud prior to cementing casing to reduce yield point and gel strengths. - Estimated volume usage for interval - 1676 barrels. - Estimated haul off volume - 2915 barrels. CJ.J.~.~ • • Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Interval Summary - 8-1/2" hole 2500 - 7292' Drilling Fluid System Flo-Pro Fluid Key Products Flo-Vis / PolyPac UL / KCl / SafeCarb F & M, Asphasol Supreme / Lubetex / Caustic Soda / Conqor 404 /Sodium Meta Bisulfate / Kla and Solids Control Shale Shakers / Desilter /Centrifuge Van Recommended shaker screens - 210 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions nterval Drilling Fluid Properties Depth Mud Plastic LSRV API Drill. Interval Weight Viscosity 1 min .Fluid Loss pH Solids (ft) (ppg) (c •) (cps) (mU30min) (%) 2500 - 7292' 9.4 -10.0 8 - 12 20 - 30,000 7 - 9 +/- 9.5 +/- 7.5 - Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. - After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak off test. - Maintain DO reading of less than 3 ppm with additions of Sodium Meta Bisulfate. - Maintain Conqor 404 concentration of 2000+ ppm. - If running coals become a problem, increase Asphasol Supreme additions. - Estimated volume usage for interval -1928 barrels. - Estimated haul off volume - 2690 barrels. - Condition mud prior to running 7" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~~ ~ ~ • r: Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Intermediate Interval Fluid Formula ~~ ~~ ~_,_~- MUDCALC 4.5 -Water-Based Mud Calculation 8-1/2" Interval from 2500 - 7292' In ut Out ut -1 bbl Order of Products Concentration: ' Volume Product Addition Field, Ib Lab, m Field, bbl Lab, ml Usa e 1 Water 317.07 317.07 0.906 317.07 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 Flovis 2.00 2.00 0.004 1.33 Viscosit 4 Pol ac Su reme UL 2.00 2.00 0.004 1.25 Fluid Loss Control 5 Caustic Soda 0.50 0.50 0.001 0.23 H Control 6 KlaGard 6.00 6.00 0.016 5.45 Inhibition 7 As hasol Su reme 4.00 4.00 0.010 3.33 Wellbore Stabilit 8 Potassium Chloride 20.24 20.24 0.024 8.47 Inhibition 9 Con or 404 2.00 2.00 0.004 1.43 Corrosion Control 10 SafeCarb 10 10.00 10.00 0.010 3.57 Brid in A ent 11 MI Bar 30.24 30.24 0.021 7.20 Mud Wei ht 12 Sodium Meta Bisulfate 0.50 0.50 0.002 0.56 Ox en Scaven er If for ue becomes a roblem add u to 5% of the followin 13 Lubetex 14.00 14.00 0.041 14.43 Lubricit Total 394.8 394.8 Estimated Volume llsa a 1928 barrels Calculated Mud Wei ht .Total Chloride 9.400 29600 Descri tion GO #3 Intermed iate Interval Mud Wei ht 9.4 Preh drated Gel No Wei ht Material Code MI Bar Preh drated Gel Conc. Wei ht Material SG 4.2 :KCI Chloride Wei ht Material Price KCI Wt% 6 1~ ~~ ~~ ~~ C Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Interval Summary - 6-1/8" hole 7292 - 13765' Drilling Fluid System Flo-Pro Fluid Key Products Flo-Vis / DualFlo / KCl / Greencide 25G / SafeCarb 10/ MI Bar / Caustic Soda / Conqor 404 /Sodium Meta Bisulfate / a and / Lubetex Solids Control Shale Shakers / Desilter /Centrifuge Van Recommended shaker screens - 210 - 230 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions, stuck pipe. nterval Drilling Fluid Properties Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (pp (cp.) (cps) (mU30min) (%) 7292 - 13765' 9.6 0. 10 -14 20 - 30,000 5 - 7 +/- 9.5 +/- 5% - Use one rig pit for drilling out intermediate casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. - NOTE: Initial formula does not call for Lubricant. However lubricant additions should be monitored for there effectiveness with the enclosed data sheet. - If running coals become a problem, treat with a 2 PPB addition of Asphasol Supreme. - Periodic additions of Greencide 25G will be needed to control bacteria build-up. - Estimated volume usage for interval - 1379 barrels. - Estimated haul off volume - 2818 barrels. - Condition mud prior to running 4-1/2" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~~ r i • r-e L~ Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Production Interval Fluid Formula MI Sy~~__`.~ MUDCALC 4.5 -Water-Based Mud Calculation M-I L.L.C. 6-1/8" Interval from 7292 -13765' Input Descri tion GO #3 Production Interval Mud Wei ht 9.4 reh drated Gel No Wei ht Material Code MI Bar rated Gel Conc. Wei ht Material SG 4.2 KCI Chloride Wei ht Material Price KCI Wt% 6 Out ut -1 bbl Order of Products Concentration Volume Product Addition Field, Ib Lab,. m Field, bbl Lab, ml Usa e 1 Water 317.07 317.07 0.906 317.07 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 Flovis 1.50 1.50 0.040 1.00 Viscosit 4 DualFlo 5.00 5.00 0.010 3.33 Fluid Loss Control 5 Caustic Soda 0.50 0.50 0.001 0.23 H Control 6 KlaGard 6.00 6.00 0.016 5.45 Inhibition 7 As hasol Su reme 4.00 4.00 0.010 3.33 Wellbore Stabilit 8 Potassium Chloride 20.24 20.24 0.024 8.47 Inhibition 9 Con or 404 2.00 2.00 0.004 1.43 Corrosion Control 10 SafeCarb 10 10.00 10.00 0.010 3.57 Brid in A ent 11 MI Bar 51.42 51.42 0.035 12.24 Mud Wei ht 12 Sodium Meta Bisulfate 0.50 0.50 0.002 0.56 Ox en Scaven er If for ue becomes a roblem add u to 5% of the followin 13 Lubetex 14.00 14.00 0.041 14.43 Lubricity Calculated Mud 411.6 411.6 9.800 29600 Volume Usape I 1379 barrels ~ ~~ • • Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Interval Summary -Completion Procedures Corrosion Control Additive in Casing x Tubing Annulus Well Grassim Oskoloff #3 Volumes: Tubing Volume a-112" Tubing Annular Volume Casing x Tubing 3.992 x 7142 ft Packer @ 7142 ft MD 6.276 @ 7292 ft MD 4.50 @ 13765 ft MD 110.61 barrels 135.62 barrels Total Annular Volume 135.62 Tubing Volume 11o.s1 Total Hole Volume 2as.23 Treatment Procedures. 1. After the 4-1 /2" tubing is run and the drilling fluid is conditioned, build at least 260 barrels of 6% KCL brine. 2. Displace mud out of well with the 6% KCL brine. Add 1 drum of Conqor 303A and 2 sack of Sodium Meta Bisulfate to the first 135 barrels of brine pumped., 3. Displace the 135 barrels of treated fluid with an additional 110 barrels of brine prior to setting the tubing hanger. 4. This procedure will place corrosion control in the 4-1 /2" x 7" annulus. ~~ ~~ • • '~ Marathon Oil Company Well Name: Grassim Oskoloff#3 Location: Kenai, Alaska. HSE Issues HANDLING OF DRILLING FLUID PRODUCTS HEALTH AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENTAL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centrifuge solids van, insure all hoses and connections between the van and the rig are secure. • ^i~ Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS Product Function Health Flammability Reactivity PPE M-I BAR Weighting Agent *1 0 0 E M-I GEL Viscosity control *1 1 0 E GELEX Bentonite Extender 1 1 0 E FLOVIS Viscosifier 1 1 0 E DUAL-FLO Modified Starch 1 1 0 E POLYPAC Fluid Loss Reducer *1 1 0 E XCD Viscosifyer 1 1 0 E HEC Loss Circulation Material 1 1 0 E Safe-Garb F,M,C Bridging and weighting agent *1 0 0 E LO WATE Weighting agent. *1 0 0 E Nut Plug Loss Circulation Material *1 1 0 E M-I Seal F, M, C Loss circulation Material *1 1 0 E Mix II F,M,C Loss circulation Material *1 1 0 E DESCO CF Dispersant 1 1 0 E SPERSENE CF Dispersant 1 1 0 E TANNATHIN Dispersant 1 1 0 E VENTROL 401 Surfactant ? ? ? ~ SALT (Solar) Densifier 1 0 0 E BROMIDE (Naar) 8~ Brine Solution Densifier 1 0 0 F POTASSIUM CHLORIDE - Shale Inhibitor 1 0 0 E ~~~ • • Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS Product Function Health Flammability Reactivity PPE CAUSTIC SODA Ikalinity control 3 0 1 X CAUSTIC POTASH pH Modifier 3 0 1 X BORAX Inorganic Borate 1 0 0 E SAPP Sodium Pyrophosphate *1 0 0 E SODA ASH Ikalinity control 1 1 0 E SODIUM BICARBONATE Ikalinity control 1 0 0 E CITRIC ACID pH Adjuster 1 0 0 E BIOBAN BP-PLUS Biocide *2 0 0 J GREEN CIDE 25G - Biocide 3 0 0 J DEFOAM X- Defoamer 1 1 0 J G-SEAL Sized graphite LCM 1 1 0 E KLA-GARD Shale Control agent 0 1 0 J LUBE TEX Lubricant 1 1 0 J D-D CWT Detergent 2 1 0 J Concor 404 Corrosion Inhibitor 1 1 0 J SAFEKLEEN Drilling fluid additive 1 1 0 J sphasol D Shale Inhibitor 1 1 0 J Soltex Shale Inhibitor 1 1 0 J Sodium Meta Bisulfate Oxygen Scavenger 1 1 0 J ~~ • U Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 -Severe hazard 3 -Serious hazard 2 -Moderate hazard 1-Slight hazard 0 -Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A -Safety Glasses B -Safety Glasses, Gloves C -Safety Glasses, Gloves, Synthetic Apron D -Face Shield, Gloves, Synthetic Apron E -Safety Glasses, Gloves, Dust Respirator F -Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G -Safety Glasses, Gloves, Vapor Respirator H -Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I -Safety Glasses, Gloves, Dust and Vapor Respirator J -Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K -Air Line Hood or Mask, Gloves, Full Suit, Boots X -Consult your supervisor for special handling directions ~~ r~ U ~~ Marathon Oil Company Well Name: Grassim Oskoloff #3 Location: Kenai, Alaska. Contacts Contact Title a-mail Work Cellular Pete Berga Drilling pkberga@marathonoil.com 907 565-3032 907 231-0663 Marathon Superintendent Will Tank Drilling Engineer wjtank@marathonoil.com 713 296-3273 713 203-8398 Marathon Tony Tykalsky Project Engineer ttykalsky@miswaco.com 907 274-5011 907 227-2412 MI SWACO Richard Couey Warehouse Manager rcouey@miswaco.com 907 776-8680 907 252-4218 MI SWACO Michael Barry Senior Field gratefulmen@hotmail.com 907 260-4666 907 590-3636 MI SWACO Engineer (home) Locke Rooney Field Engineer rooneyl@alaska.net 907 235-0598 907 590-3636 MI SWACO (home) Roland Lawson / Drilling Foremen 907 283-1312 Larry Myers /Dave Morris Marathon Responsibilities - MI Project Engineer and will coordinate daily between the Marathon office, rig, warehouse, and the M-I field engineers. - Well progress will be monitored to look for any changes, which will improve the efficiency of the operation or avert trouble. - Field Engineers will monitor and supervise product inventory to include re-palletizing any products for shipment to other locations at the end of the well. - Field Engineers will communicate with office personnel (Marathon & MI SWACO) for approval of any changes in the mud program (including introduction of new products). - Field Engineers will produce a recap at the end of the well based on daily activities. Recap should include any lessons learned that may be used to provide better service on future wells. Lessons learned can include changes in procedures, product additions, equipment usage, and/or utilization of any third party service. • Check No Check Date Bank Bank No Vendor No Marathon Oil Company ACCOUNTS PAYABLE DEPARTMENT Hndig 1155456 12/17/2004 NCBAS 7780 5001123 P. O. Box 3128 Houston, TX 77253 Accts Payable Contact Center phone: 918-925-8097 HS -: iYtvOk2 N.amber ~ '~~; tF1Y010~:pate AecumenE id0: ~ ReRtit CCItlnl2ttt ~;:~~ ,: GrcrsslmotrrK ~ ~ ~~ t]isccurtf ~~ lrtvorce)PayArriciu~f ~ ;: L100.00 12/16/2004 1900041690 100.00 100.0 TOTAL: 100.00 100.0 DEG 2 ~ 200~- ~~~5~~ o~~ ~ ~~~ c~~~. ~d~-~os~a®~ k~chorage • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGR.APHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,~~ss M. ~~o ~~o`~ ~~ Development Service Exploration Stratigraphic CHECK WA.A.T ADD-OHS "CLUE"~ APPLIES (OPTIONS) • MtTLTI The permit is for a new wellbore segment of LATERAL existing well Permit No, API No. (lf AP] number Production. should continue io be reported as last two. (2) digits a funciion~of the original API number• stated are between 60-69) above. PILOT DOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated •in both name (name on permit plus P]~ and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACDVG The permit is approved subject •to full EXCEPTION compliance with 20 AAC 25.055. Approval io perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. SCompanv Name) assumes the liability of any protest to the spacing ,exception that may occur. DRY DITCH All dry ditch sample sets submiried 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 ] 0' sample intervals through target zones. WELL PERMIT CHECKLIST: Field & Pool NINILCHIK, GO TYONEK UNDEF GAS - 562540 Well Name: NINILCHIK UNIT, G OSKOLKOFF 3 Program DEV Well bore seg PTD#:2042550 Company MARATHON OIL CO Initial ClasslType DEV! 1-GAS GeoArea Unit OnlOff Shore On Annular Disposal Administration 1 Permit_feeattached__________________________________ __________ Yes_____ __________ 2 Lease number appropriate....._-.____________________ ________ __Yes-____ __..-____._______ 3 Unique well-name and number--- -- --- ------- ----- -- -- - Yes- --- -- --- --- ----- - ---- - - - --------------------------------- 4 Well located in_a_detined-pool--------------------------- ----- N°------ ---------------- ----------------------------------------------------- 5 Well locatedproperdiskancefromdrillingunit_boundary------------- -------___ Yes_____ _________________ -_-----__-__.._______,_______,_--_--__--__- __-,_, 6 Well locatedproperdiskancefromotherwells___________________ ___________ Yes_____ ______ 7 Sufficient acreage availablein_drillingunit_-__________________ __________Yes____ -------.__------__. - - -- - - 8 If.deviated,is_wellboreplat-included_ --_,__,______._.____ __________Yes____ --_-._ 9 Operator only affected party - - - - Yes - - - - - - - - - 10 OpQ[atorhas-approprlafebondinforce----------------------- ---------- Yes----- .-----------------......--------.---------------, 11 PermitsanbeissuedwithoutconservatiQnorder_,-_-____________ _____ ____ Yes_____ ____ ----------------------------------------------------------------- Appr Date 12 Permit can be issued without administ[ativ_e_approval___----------- ----------Yes__-._ __--__-.__-.__-----_-.-_--_--__--__--__--_-____ -_-_-_______--.__-- RPC 1212912004 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by Injection Order # (put1O# in_ comments)-(Fpr- NA_ _ _ - _ _ - - _ _ : _ 15 Allwells-wihin 114_mile area_of review identified (Far service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ .. _ _ _ . - _ , - _ _ . _ _ _ _ _ _ _ - - _ 16 Pre-produced injector. duration of pre production less than 3 months. (For service well only) - . NA - _ - - _ - - - _ _ . _ - - , 17 _ACMP_Finding of Consistency_h_as been issued_for this project- - - - - - - - - - - - - - - - - - - - NA _ _ _ _ _ _ , ' _ _ Engineering 18 _Conductorctring-provided - - - Yes - - -- 20" @ 61'._ - - - - - - ~ - - 19 Surface casing protects all,known USDWs - - - Yes - - - - - - - - - 20 CMT vol-adequate_to circ_ulate_on conductor& surf-csg - - - - - - - Yes _ _ _ _ _ _ _ Adequate excess. _ _ , _ _ , _ 21 CMT vol-adequate_to tie-in long string to-surf csg_ - - - - - Y_es 22 CMT will cover-all known_productive horizon_s_ Yes -- - - - - - - - - - - - 23 Casing designs adequate for C, T,B&-permafrost----------------- ----- Yes ----- ---------------- --------------------------------------------- 24 Adequatetankage_orreservepit___________________________ ______ ___Yes-__--_ -Glacier-Rig 1.-__--__,_ 25 If_a_re-drill,has_a10-403forabandonmentbeenapproved,_.---_---- ---------- NA.___ --Newwell..,-__--_---_-_---__-.------..-- 26 Adequatewellboreseparation.proposed........ __~___________ ___ __ __Yes______ __ __.__~________ __ __________ __ __ ___ __ __ -_ ----------------- 27 Itdiverterrequired,doesitmeetregulations__________________-_ ___---.-_Yes--__-- _--_-..-.--__-_--_--___--_ Appr Date 28 Drillingfluid_programschematic&equipfistadequate___ Yes------ -MaxMW-102-ppg._.---.________,__.__-__----------------------- WGA 1212912004 29 _B_OPEs,_dotheymeetregulation___________________________ __________Yes_____ _____ _,-______,_-,.__--_-___---_..-,--_--__-_„_--_--___--__------ 30 BOPS-press rating appropriate; test to-(putpsig in comments)__________ ___ ______Yes______ _Testt_o2500psi._MSP2019psi..___-_,_______________._____-__---,-___.-__-----_ 31 Chgke_manifoldcompliesw/API_RP-53(May84)----------------_ __-._---_-Yes___._ ____.___,_____,_-,._ - - 32 Work willoccurwithoutoperationshutdown_____----------- ----------Yes------ -------------.----------------------------------------------------.- 33 Is presence of H2S gasprobable. - - N0- - - - - - - 34 Me_chanical_conditicn of wells within AOR verified (Forservice well only) _ _ _ _ _ _ _ _ _ __ _ _ _ NA_ - . _ . - _ -- - _ , - _ . _ _ - _ _ _ -- - - - - - Geology X 35 Permit can be issuedwlohydrogen_sulfidemeasures_________.____ ___.__ __Yes______ --- _______________________________ - - 36 Data-presented on potentialoverpres_su[ezones-_-----._________ __________ NA_______ _____________________._--_____-----._-,._-____-----__--__--__--__ Appr Date 37 Seismic analysis of shallow gas-zones. _ . NA - - - - - , - - - - - - - - - - - - - - - - - RPC 12!29!2004 38 Seabed condition survey-(if off-shore) NA -- - -- - - - -- 39 Contact name/phone_for weekly progress_repotts [exploratory only)- - - - - - - - - - - - - - - - - NA _ - _ _ _ _ , _ _ - - , - _ _ Geologic Engineering Public Commissioner: Date: Commissioner. Date one r Date ~~'S l2~3a'~ ~~'~°/Q~
