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Home My WebLink About204-253 · . 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. ~Q Y- - ~!5 3 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: )5 <3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ¿ YES BY eMana ) Date Lf-/ I q 107 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided 1111111111111111111 RESCAN ~olor Items: ~reYSCale Items: DIGITAL DATA o Diskettes, No. ~ther, NolType: (;..'Ð Ne> I o Poor Quality Originals: o Other: NOTES: Date ~/07 Date ~Iq jÓ7 5' SO Date: 0 BY: ~ Project Proofing BY: ~ Scanning Preparation BY: BY: Date: Maria Scanning is complete at this point unless rescanning is required. o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ~ogs of various kindSy ~ _'" n.l. ~ther:: ~ p O(Y"'^'rpS I~ mE 11111111I11 11111111 Isl mf +~ = TOTAL PAGES 157 (Count does not include cover sheet) Isl p 1111111111111111111 NO Isl W1 r NO Isl 1111111111111111111 ReScanned BY: Date: Isl Maria Comments about this file: -- ~ ~ Àr \7~~'{\~éõ\J~ &~ 1111111111111111111 Quality Checked IIIIIII111111111111 10/6/2005 Well History File Cover Page.doc ~ • /~ti~ ~ ~ ~.. ~. ~ _. ~ ~, MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFicheiCbrPgs_Inserts~Microfilm Ma~cer.doc e e ConocÓÁ,illips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Kokoda 1 Permit: 204-253 DATE: 6/12/2007 TO: Howard Okland AOGCC 333 W. ih Ave., Suite 100 Anchorage, Alaska 99503 e-mail transfer Transmitted: Kokoda 1, NPRA, Alaska 502792001100 JJ- / <. - ~O '-{ Core Labs ~ J e-trans~ (xis) ~re Labs Analysis, Kokoda 1, NPRA, CL57111-1 05057CP, June 13, 2005 Please check off each item as received, promptly sign, scan as .pdt and e-mail backtoSandra.D.Lemke@Conocophillips.com To all data reci ients: All data is confidential until State of Alaska desi nated AOGCC release date CC: Greg Receipt: Date: I;;¿ J W4.- ÀJJ'tj '- GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.Lemke@Conocoohillips.com ~t;t.iJ JUN 1 4 2007 ..--- :ta-+-~J · ~/ . ConocoPhillips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Kokoda 1 Permit: 204-253 DATE: 5/28/2007 TO: Howard Okland AOGCC 333 West. 7ft¡, Suite 100 Anchorage, Alaska 99501 H Kokoda 1, NPRA, Alaska 502792001100 Schlumberger -tÇQœgÏ$triþution) requested by AOGCC to replace missing CDROM digital data CDROM _¿'C~WG OH EDITS; Digital pdsviews; Field MSCT DLlS/PDS; log date 3/3/2005 Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data reci ¡ents: All data is confidential until State of Alaska desi nated AOGCC release date :œ~:Wi[j0I~¡iJ Date: .~ (:) ~ ~ I GIS-Technical Data Management I ConocoPhillips I Anchorage/ Alaska I Ph: 907.265.6947 Sandra.D.Lemke(&Conocophillips.com SCANNED MAY 3 1 2007 ~~v(-Àf3 I b /Jrt~ ~ l DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042530 Well Name/No. KOKODA 1 Operator CONOCOPHILLlPS ALASKA INC ~(;.. ¡ /CA /::/'Æ ù Ì3 r AæNO. 50-279-20011-00-00 MD 8045'/ / TVD 8044 Completion Date 3/16/2005 Completion Status P&A Current Status P&A UIC N .._~.._._~ ._-~----,_..~--------~ ----~ REQUIRED INFORMATION Mud Log Yes Samples No _."-,.,.~------- Directional SUNey Yes _.~--- (data taken from Logs Portion of Master Well Data Maint Interval OH/ e Start Stop CH Received Comments mn-l 108 8045 Open 108 8045 Open Drilling Dynamics Log 108 8045 Open LWD Combo Log 108 8045 Open Pore Pressure Log 108 8045 Open Gas Ratio Log 0 0 Open Core Photographs by Core Mongers 0 0 Open Core Photos (White & UV) Core Mongers 1900 7995 Open CMR SS mode, Dipole Shear Sonic Imager, Mech S.W. Coring Tool e 2550 8435 Open 0 0 Final Well Report in Digital Form 110 7991 Open GR, Neutron, RHOB, PEF, ROP, NPHI, DRHO, FET plus graphics .emf and .pdf 6823 7848 Open Mechanical SW Coring Tool, GR 6770 7600 Open CMR Sandstone Mode w/EPM 1900 7995 Open Dipole Sonic Shear Imager P & S / Upper Diploe DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens/Neut, CMR, Dipole Sonic, FMI, RSCT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ~n______~____mn.______ . pt Report: Final Well R ~ Mud Log 2 Col See Notes 2 Col og See Notes 2 Col ~ See Notes 2 Col ~ See Notes 2 Col W See Notes DV Jpg 13173 See Notes C Dls 13174 Sonic I ro C Dls 13175 Formation Micro Ima I~ C Pdf 13176 Report: Final Well R 1 i ED C Lis 13177 I nd uction/Resistivity r< See Notes 5 Col ~ See Notes 5 Col I I I I Log See Notes 25 Col L DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2042530 Well Name/No. KOKODA 1 Operator CONOCOPHILLlPS ALASKA INC Completion Status P&A Current Status P&A 25 Col 108 8045 Open 25 Col 108 8045 Open MD 8045 ~- b TVD 8044 Completion Date 3/16/2005 Density I nd uction/Resistivity Well Cores/Samples Information: API No. 50-279-20011-00-00 UIC N Dual GR, Thermal Neutron _I Poro, Stabilized Litho- Density I ROP, DGR, EWR : __I Sample Set Number Comments Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 1/5/2005. Name Interval Start Stop Received Sent e ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? 0N Q)N Chips Received? Y / N Formation Tops Analysis Received? (j)N Comments: ~"--"._- --~-- Compliance Reviewed By: - Date: ~._.~ "-----~_._~--,- . . FRANK H. MURKOWSKI, GOVERNOR AI',ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 December 29, 2005 Paul Mazzolini ConocoPhillips Alaska Inc. POBox 100360 Anchorage, AK 99510 Re: Location Clearances Kokodå # 1 (PTD 204-253) Kokoda # 5 (PTD 204-259) Iapetus # 2 (PTD 204-254) Dear Mr. Mazzolini: The Alaska Oil and Gas Conservation Commission ("AOGCC") has completed its location clearance inspection of the above reference wells. The AOGCC inspection shows the locations to be in compliance with 20 AAC 25.170, Onshore Location Clearance. The Commission requires no further work on the subject well or location. However, ConocoPhillips Alaska Inc. will remain liable if any problems should occur in the future with these wells. Final location clearance is hereby APPROVED for the above listed wells. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, .~ O( - / P.I. Supervisor ] ')é'i1 1Ib(D) DATE: August 13, 2005 THRU: FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Location Inspection Conoco Phillips vKokoda #1 PTO 204-253 Kokoda #5 PTO 204-259 Iapetus #2 PTO 204-254 Saturday. August 13. 2005; I made a Location Clearance Inspection of the Conoco Phillips exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2. I was accompanied today by Chris Brown (Conoco environmental). The exploratory locations were clean with no evidence of past drilling activity other than a small mound of dirt over the cellar area of the two Kokoda Wells and a slight depression in the cellar area of the Iapetus Well SUMMARY: I made a Location Inspection of the Conoco Phillips abandoned Exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2 I Kokoda # 1 2005-0813_Location_ Clear _Kokoda1_ cs.doc . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, -:J .:'/J. P.I. Supervisor k.~1I(.f}5" DATE: August 13, 2005 THRU: FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Location Inspection Conoco Phillips Kokoda #1 PTO 204-253 Kokoda #5 PTO 204-259 vf'âpetus #2 PTO 204-254 Saturdav. Auaust 13. 2005: I made a Location Clearance Inspection of the Conoco Phillips exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2. I was accompanied today by Chris Brown (Conoco environmental). The exploratory locations were clean with no evidence of past drilling activity other than a small mound of dirt over the cellar area of the two Kokoda Wells and a slight depìession in the cellar area of the Iapetus Well SUMMARY: I made a Location Inspection of the Conoco Phillips abandoned Exploratory wells Kokoda #1, Kokoda #5 and Iapetus #2 :¡: R Xi CtJ ~n-ol .:p i l1.ft l ;} íf(:~) L>~"\J=L<.1.... V1..é.ê'- -f\~rz_ \ \\. 'é:~, 3 lU ~ ( ls Ç\bo\Je/,. I Iapetus #2 I . , D'~ ......,i¡, i).. -;)2 -0 j ."1 \ t:: 4'" . .~<nr-, - 4-; ('1 "( oJr ~)c' \-J F~ ~ 17 J CßuL~J2.. 2005-0813_Location_ Clear _lapetus2_cs.doc ..,./ . ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 9951 0-0360 RE: Kokoda 1 Permit: 204-253 DATE: 9/15/2005 Hand deliverv TO: Helen Warman AOGCC 333 West. 7th, Suite 100 Anchorage, Alaska 99501 Transmitted: Kokoda 1, NPRA, Alaska 502792001100 CPAI has detected a depth error in the Core Labs Core Analysis CL57111-105057CP report for Kokoda 1. Sample 28W has the wrong depth. Depth for sample 28W should be 6864.5 instead of 6865.3. Please note this correction on your hardcopy report and on the digital data on CDROM or 3.5" floppy. CPAI did not ask Core Labs for redistribution of this report for this single error. If you wish CPAI to provide you with a revised digital file of this report, please advise Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. To all data recipients: All data is confidential until State of Alaska desiqnated AOGCC release date cc: Greg Wil~e0(JJL; Receipt: I - Date: ) 0 J¡ ,(:Ò ~ ) -- GIS-Technical Data Management I ConocoPhillips Anchorage, Alaska I Ph: 907.265.6947 Sandra. D. Lemke(âJConocophillips.com · . Co~illips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Kokoda 1 Permit: 204-253 DATE: 6/10/2005 Hand-delivered TO: Helen Warman AOGCC 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 Transmitted: Kokoda 1, NPRA, Alaska 502792001100 E~þ/MUdloa hardcopv report & CDROM _ Kokoda #1 Epoch Final Well Report Mudlogging Data; includes color Formation log, Drilling Dynamics, LWD Combo, Pore Pressure, and Gas Ration Log; CDROM contains reports, LAS data, PDF images and DML data; lithology remarks files, 3/5/2005. S er un MWD ~ LDWG LWD Data; digital logs and Viewer; 3.5" n::øÞy and hardcopy report l/. Final Directional Survey, Kokoda 1 0'-8045' md 1 color print and 1 film each: , / ~ /10PIDGR/EWR MDfTVD 2&5" =100' /' -tL DGR/CTN/SLD MDfTVD 2&5"=100' Schlumberger Final LDWG Open Hole edit / CDR;iws ~y6~G H edits digital and PDS files: Field MSCT DLlS Job 10687735 3/3/2005 / ~ Fie FMI in DLlS and PDS; Job 106877353/1/2005 (no prints made) 1 cot r rint and 1 film each: 3/2/2005 Dipole Sonic Shear Imager P&S/Upper Dipole 3/3/2005 binable Magnetic Resonance Tool/Sandstone Mode w/EPM 3/1/2005 ~ Kokoda 1 Core Photos, Core Mongers Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. II To all data recipients: All data is confidential untIl State of Alaska designated AOGCC reiease date confidential ê'md is available onl to owners and arlners ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 /¡7j%,j ¡ I GIS-Technical Data Management 1 ConocoPhillips 1 Anchorage, Alaska 1 Ph: 907.265.69471 Sandra. D. Lem,ke@conocoohilJ¡/Js.com . ConocÓÂ,illips . Paul Mazzolini Exploration Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 April 27, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Commission Anchorage Subject Well Completion Report for Kokoda 1 (204-253/ 305-062) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent work on the exploration well Kokoda #1. The attachments include a summary of the daily drilling operations, a directional survey, core analysis, an as-built, a summary of / the P&A operations and photos of the site. We request that this data be held confidential as required under AS 31.05.035(c) and 20 MC 25.537(d). This data is from federal lands. By submitting this data in compliance /' with the regulatory data submission requirements, ConocoPhillips Alaska, Inc. is not agreeing or acquiescing to the potential future application of the provisions of AS 31.05.035(c) and 20 MC 25.537(d) that might allow the data to be disclosed to the public after the initial 24 month confidentiality period. ConocoPhillips Alaska, Inc. reserves all rights to dispute or appeal any attempt to apply those provisions to this data in the future. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, '?~Y1~ P. Mazzolini Exploration Team Leader CPAI Drilling PMIT JB/skad 1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 Suspended 0 WAG 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions Other Service 0 Stratigraphic TestO 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: March 16, 2005 / 204-253 / 305-062 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 February 16, 2005 / 50-279-20011-00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 295' FNL, 629' FWL, Sec. 27, T11 N, R5W, UM / February 28, 2005 / Kokoda #1 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 294' FNL, 573' FWL, Sec. 27, T11N, R5W, UM 28' RKB /137' AMSL / Total Depth: 9. Plug Back Depth (MD + lVD): NPRA Exploration 304' FNL, 561' FWL, Sec. 27, T11N, R5W, UM surface 4b. Location of Well (State Base Plane Coordinates): NAD 27 10. Total Depth (MD + lVD): 16. Property Designation: Surface: x- 606278 y- 5954597 Zone- 5 /8045' MD / 8044' TVD / ALK AA084129 TPI: x-606223 y- 5954598 Zone- 5 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 606211 y- 5954588 Zone- 5 none ADL L33461 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 930' MD 21. Logs Run: GRlReslDens/Neut, CMR, Dipole Sonic, FMI, RSCT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 63# B 28' 108' 28' 108' 24" 190sxASI 9.625" 40# L-80 28' 2505' 28' 2505' 12.25" 347 sx AS III Lite, 166 sx DeepCrete cement retainer @ 2416' 23. Perforations open to Production (MD + lVD ofTop and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET n/a 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. none DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Plug #1: 7688'-7317' 160 sx Class G Plug #2: 7317'-6915' 160 sx Class G Plug #3: 6915'-6500' 160 sx Class G Plug #5: 310' to surface 183 sx AS 1 Plug #4: 2416'-525' 97 sx Class G 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) n/a Plugged and Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 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". RBDMS . . f"át;'\';<l 1 {).,'~ T't~ RECEI\/ED . 8Ft MAY 1 2 200te Attachment ~-L'_,tK. V~H APR 2 9 2005 r:J ?~. --'.~ v .. .. "", O. f"'ftA ('~""'" ...,~.."''';nn "11I"n.. ..... - --- . STATE OF ALASKA I ALASKA Oil AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Revised 12/2003 CONTINUED ON REVERSE Anchorage 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kokoda #1 Nanushuk Torok Fm Torok Turbidite Top HRZ LeU 1440' 3309' 6783' 7584' 7832' 1440' 3309' 6783' 7584' 7832' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional SUNey, As-Built 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Brassfield 265-6377 Date ó4/zï /?tx>5 :~~::~:a7~;'~ Title: Phone Drillino Team Leader Prepared by Sharon AI/sup-Drake 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. Item 1a: Classification of SeNice wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, obseNation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing InteNal). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one inteNal (multiple completion), so state in item 1, and in item 23 show the producing inteNals for only the inteNal reported in item 26. (Submit a separate form for each additional inteNal to be separately produced, showing the data pertinent to such inteNal). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). RECEIVED APR 2 9 2005 Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Alaska Oil & Gas Cons. Commission Anchorage Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/7/2005 2/8/2005 2/9/2005 2/10/2005 .i ./ ConocOPhilfips Alaska Operations Summary Report KOKODA #1 KOKODA #1 ROT - DRILLING n1334@ppco.com Doyon 141 Sub From -To Hours Code Code Phase 00:00 - 06:00 06:00 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 00:00 6.00 RIGMNT OTHR MOVE 6.00 RIGMNT OTHR MOVE 12.00 RIGMNT OTHR MOVE 12.00 RIGMNT OTHR MOVE 12.00 RIGMNT OTHR MOVE 12.00 RIGMNT OTHR MOVE 12.00 RIGMNT OTHR MOVE 24.00 RIGMNT OTHR MOVE Start: Rig Release: Rig Number: 2/7/2005 3/6/2005 '&Gas Anchorage Spud Date: 2/16/2005 End: 3/6/2005 Group: Description ofOperatrol')S Rig maint & cleaning: Continue cleaning Oil Base Mud residue f/ rig floor, pipe racks, pollution pans, and drip pans. Clean mud pits. Change out liners in # 2 mud pump from 5.5" to 6" liners, change all valves and seats. Prepare top drive to rig up scaffolding, remove bales. Clean strainers on accumulator. Rig maint & cleaning: RID scaffolding in cellar. Pressure wash top drive for maint. RU scaffolding f/ top drive. Inspect top drive. Change out swivel packing. Change filters on rig diesel filter pot. Cleaning pits. Rig maint and cleaning: Inspected & repaired low drum chain in drawworks. Change out blower motor on top drive. Clean out suction dampners on mud pumps. Inspected non reg lifting devices(shackles, chains & slings). Change bottom pipe rams in BOP stack f/ 7 5/8" to 5". Remove kill line f/ BOP stack.Cleaning pits. Steam clean skate, cleaning drip pan of UD machine in pipe shed. Rig maint & cleaning: Continue cleaning Oil Base Mud residue f/ rig floor, mezzinine, pollution pans, and drip pans, rock washer, under mud pumps, centrifical room. Cleaning mud pits. Check pre charge on all accumulator bottles, check and bring up to 1000 psi. Clean out pipe handling machine sumps. Change out hydraulic and gear oil on top drive. Test blower motor on top drive. Rig maint & cleaning: Continue cleaning Oil Base Mud residue f/ rig floor, mezzinine, pollution pans, and drip pans, rock washer, under mud pumps, centrifical room. Cleaning mud pits. Check pre charge on all accumulator bottles, check and bring up to 1000 psi. Clean out pipe handling machine sumps. Test blower motor on top drive. Check rotation of motor. Inspected elec!ricallines on top drive. Change Varco PS 15 air slips f/ 4" to 5". Inspect Lockout / tag out stations. Changed out 3 valves in Sonic manifold f/ rock washer. Removed drag chain in rock washer. Change oil in both charge pumps. Replace rear shaker mounts on all shakers in mud pits. Change out screen bed rubbers on shakers in mud pits. Note: Table top Kick while drilling drill Rig maint & cleaning: Continue cleaning rock washer, clean drag chain trough in rock washer so welder can work, cleaning mud cleaner in mud pits to disassemble and inspect cones, clean out cuttings box, clean out pipe handling machine sumps. Take down scaffolding f/ top drive. Disassemble mud cleaner cones, check oil in all mud pit agitators- good oil. Change out screen bed rubbers on shakers in mud pits, install 11 O's and 84 screens. Install new idler bearings, new sproket, new chain for drag chain to rock washer. Rig maint & cleaning: Pits: SeNice SWACO centrifuge. Rig Floor: Install new cement manifold (Welded pieces new 2"; used original valves, unions and threaded nipples) off drillers side by derrick leg. Check bearing play on top drive- results .002 play- ok. Disassemble iron roughneck to check pilot operated check valve. Quadco rep (Robert) calibrated torque guage on iron roughneck and driller's console. Qudco also calibrate weight indicator and pump pressure guage on driller's console.Crane inspector (Darren) inspected 3 rig floor tuggers and (1)manrider on rig floor(500 # rating)( checked emergency lowering pump kit f/ manrider also). Rig crew cut 10' off big tugger line & re-assemble same. Repaired and re-assemble mud cleaner cones. Replace expansion boot f/ # 1 pump in rockwasher. Rig Main!: PJSM: Pipe Shed work: Clean, prepare to paint, paint pipe Printed: 3/17/2005 1 :20:00 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/10/2005 2/11/2005 2/12/2005 2/13/2005 ConocoPhillips Alaska . ERg~20f14-> APR 29 2005 ·i .... Operations Summary Report . Alaska Od & Gas Cons. Commission Anchorage Spud Date: 2/16/2005 End: 3/6/2005 Group: . KOKODA #1 KOKODA #1 ROT - DRILLING n1334@ppco.com Doyon 141 Sub From - To Hours Code Code Phase 00:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 09:00 09:00 - 12:00 12:00 - 00:00 00:00 - 00:00 - 00:00 24.00 RIGMNT OTHR MOVE 12.00 RIGMNT OTHR MOVE 12.00 RIGMNT OTHR MOVE 9.00 RIGMNT OTHR MOVE 3.00 MOVE MOVE MOVE 12.00 MOVE MOVE MOVE MOVE 24.00 MOVE MOVE MOVE MOVE Start: 2/7/2005 Rig Release: 3/6/2005 Rig Number: Description of Op~rations handling machine. Rig Floor Area: Quadco calibrate Martin Decker guages and deadline anchor. Quadco moving cat 5 cable and coax cable f/ Rig Sense computer f/ geologist room to rig floor. Moving Rig Sense to doghouse to allow abillity to use computerized lADe report. Change out willis choke on mud manifold on standpipe. Change oil in IR pipe spinner, change bypass valve on IR. Change out torq and spinner controllR. Install ladder f/ stabbing board access. Pit & Pump room: Clean, inspect, grease bearings on conveyor chain. Repair conveyor alarm. Tear down # 1 centrifical pump in rock washer, change out #1 centrifical pump and impellar. Tear down # 2 centrifical pump, inspect impellar and re- assemble. Change out 3" Demco valve in suction to #1 centrifical f/ rock washer. Rebuilt shaker screen tension bolts. Finish drag chain inspection report. Crane inpector: inspecting lifting devices: Chain hoist, stabbing board hoist, bridge crane in cellar. General f/ rig move: Add oil to hyd rig move system, change absorb on rig move system, clean out drip pan on Rig Sub Hyd lift rams. Check tires on rig, rig modules and camp. Rig Main!: Continue inspection and rebuild of shaker screen tension nuts. Check each module for spill prevention equipment. Rebuild 3" demco valve in rock washer. Gather all RAAlSAA for proper disposal. Remove Sperry Sun MWD shack f/ roof of module. Rig Main!: Change oil in drawworks. Clean out pipe skate drip pan on rig floor. Raise skate to rig move position. Prep MCC room f/ painting. Turn brake glycol pump off, shut in pump and radiator. Rig down handy berm around rig washer. Cleaned out snow around SPO unit. Prep pipe shed f/ rig move. Rig MainU Prep for move to Kokoda #1: Pre spud meeting w rig crew on Kokoda #1. Crew training: NPRA and Polar Bear awarness. Vacum truck remove final fluids from rock washer. Prepare rock washer to move. Prepare and move pipe sheds away f/ rig, stage on pad. Load some mud products to move to Kokoda location. Disconnect Hi-line f/ camp @ 0700 hrs. Disconnect communicatons. Jack up and load camps, SDS, and shop to move to Kokoda. L.eave 1E pad @ noon. Camp moving to Kokoda: Camp convoy left 1E pad @ noon, @ ice road check point by 2L @ 1435 hrs. Camp convoy @ NPRA alpine Y @ 1715 hrs. Let traffic around and refuel trucks. Continue to move to Kokoda. Arrived @ midway camp @ 2100 hrs. Continue moving to Kokoda. Forklift loading pipe sheds w/ equipment for later move. Clean up herculite f/ under SPO unit. Load trailer w/ equip to move later. Blow down steam on rig. Note: Camp arrived @ Kokoda pad @ 0215 hrs 2/13/05 Continue moving Camp to Kokoda. Move distance 100.4 miles. Arrived @ location @ 0215hrs, 2/13/05 w/ camp. Set camp units in place w/ Peak. @ 0430 Road Sows back to 1 E pad Kuparuk. Estimated to arrive approx 8-9 am. Will move Rig sub and modules next. Disconnect rig f/ Printed: 3/17/2005 1 :20:00 PM . . ConocOPhillips Alaska RECEIV~~3Øf1~ Operations Summary Report APR 292005 > .. .... .. Legal Well Name: KOKODA #1 Alaska Oil & Gas Cons. Commission Common Well Name: KOKODA #1 SptAnl:QftM{Ø/16/2005 Event Name: ROT - DRILLING Start: 2/7/2005 End: 3/6/2005 Contractor Name: n1334@ppco.com Rig Release: 3/6/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 2/13/2005 00:00 - 00:00 24.00 MOVE MOVE MOVE hi line power @ 0700 hrs. Blow down rig water & steam. Prep modules to be moved. Leave 1E pad w/4 complex's and sub base @ 1030 hrs. Move on to 2U ice road @ 1435 hrs, No problems reported. At 1800 hrs the streering arm on the sub base failed @ Ale camp access road. Doyon took the arm off and it was taken to Alpine Doyon shop for repair. In order to keep eat's in front of modules we will go to Kokoda #1 with 3 modules. At 1930 hrs Doyon left access road, arrive Midway camp ( mile 50 ice road) @ 2400 hrs( Midnight)** Note *** Sub base and Pit module are @ Ale camp/ B70 access road ( mile 15.3) 2/14/2005 00:00 - 21 :00 21.00 MOVE MOVE MOVE Con't moving the motor, pump & boiler modules to Kokoda #1 pad. Arrive on ice pad @ 0330 hrs. Set modules staged east of conductor. @ 0415 - Peak Sows start back to PiU B70 acess road where sub and pit module are setting ( mile 15). Sows arrive @ 0730 hrs. Steering arm has arrived after a complete new steering arm has been built by Doyon and is installed on sub base. @ 0830 hrs the sub & pits left the PiU B70 road toward Kokoda. Arrived @ MidWay camp(50 miile of ice road) @ 13:15 hrs. Fueled trucks and cats and con't moving. At 16:50 hrs the pit module and cats w/ truck arrived on Kokoda pad. At 17:30 hrs 1 of the 2 Sows pulling the sub base broke down(K-296) (fuel injection pump ). Peak working to repair sow. 21 :00 - 00:00 3.00 MOVE MOVE MOVE After rearrange equipment for moving rig sub. Move f/ ice road mile marker 68 w/ 2 cats and weighted Sow on front and blade in back. Move to peak stagging area about 2 1/2 miles f/ Kokoda pad. Wait 1/2 hour for blower to get ahead of rig to work on road. Start moving @ 23:00 hrs w/ sub f/ Peak stagging area. Arrive on location w/ sub @ 23:45 hrs. Positioning rig over hole. 2/15/2005 00:00 - 02:00 2.00 MOVE POSN MOVE Spot sub base over well conductor 02:00 - 03:00 1.00 MOVE POSN MOVE Spot and set pit, pump, motor & boiler modules 03:00 - 09: 15 6.25 MOVE MOVE MOVE Trucks returning to 1 E to get 2 halfs of pipe shed and rockwasher - Rig crew hooking up all interconnects and rig seNice system. ** Rig water truck & fueler are on location. ** The water plant is making potable water ** We will have to haul "Black Water" from sewage plant until we have it sampled. 09:15 - 15:00 5.75 MOVE MOVE MOVE Move 2 pipe shed halfs and the rock washer from 1 E pad to Kokoda #1 , held safety stand down for 30 min with rig crew to discuss spill prevention *** Note*** Had 1/2 gal glycol spill. Condensate from steam drip built up and forced freeze protection glycol out of pits pressure washdown tank. It drains to the cutting conveyor and out to rock washer. The rock washer was not in place at the time. A cutting bucket had been placed under the end of the conveyor but the wind blew the fluid off to the side of the bucket. Spill reported per company SOP. 15:00 - 16:00 1.00 MOVE MOVE MOVE Install berm and spot rock washer in place 16:00 -18:00 2.00 MOVE MOVE MOVE Spot and set both pipe sheds - Install V door throat 18:00 - 20:00 2.00 MOVE RURD MOVE Set in air heater for pipe shed and bermed around same, completed rig acceptance check list and ACCEPTED RIG @ 20:00 Hrs 2/15/05 20:00 - 22:30 2.50 WELCTl NUND SURFAC NU 21 1/4" diverter and 16" knife valve and line and MU riser 22:30 - 00:00 1.50 DRILL PULD SURFAC Loaded BHA into pipe shed and took on water into mud pits 2/16/2005 00:00 - 06:00 6.00 DRILL OTHR SURFAC Cont to mix spud mud, loaded pipe shed with 154 jts of 5" DP and strapped same 06:00 - 13:45 7.75 DRILL PULD SURFAC PU and stood back 51 stds of 5" DP, then PU and stood back 10 stds of 5" HWDP with jars Printed: 3/17/2005 1:20:00 PM . . ConoçoPhiUips Alaska Operations Summa.ry ReporRECEI\/~ Function tested diverter and gas alarms then performed accumulator test, test witnessed by John Spaulding with AOOCC and Tim Lawlor with BLM was notified on upcoming test and spud PU and stood back an additional 9 stds of 5" DP and 1 std of 8" Flex Dc's MU 12 1/4" bit #1 on 8" mud motor with 1.15 deg bend Est circ and filled conductor checking surface lines for leaks, pressure tested mudline to 3,000 psi and ck ok, held diverter drill Washed down and tagged cement inside conductor at 97' then cleaned out to 108' Spudded well and drilled 12 1/4" hole from 108' to 233' (125'), ADT 2 hrs, 65 rpm's, 7-8K wob, 450 gpm, 400 psi, rot wt 40K, up wt 40K, dn wt 43K, 10.0 ppg spud mud POOH and stood back 2 stds of HWDP to motor at 30' MU 12 1/4" BHA #1 with MWD, density nuetron and PWD, oriented and uploaded MWD, held PJSM and loaded radioactive sources RIH to 233' with flex Dc's Drilled 12 1/4" hole from 233' to 952' MD/ 952' TVD, (719') ART 6 hrs, 1 0-30K wob, 90-100 rpm's, 450-550 gpm, at 450 gpm had 900 psi, at 550 psi had 1,200 psi off btm pressure and 1,300 psi on btm, off btm torque 1 K, on btm 3K ft-Ibs, rot wt 85K, up wt 81 K, dn wt 87K, Epoch mud loggers ave BGG 30 units, max gas 45 units, 10.0 ppg MW, ave ECD 10.5 ppg 12.00 DRILL DRLG SURFAC Drilled 12 1/4" hole from 952' to 2,105' MD/2,105' TVD, (1,153') ART 8 hrs, 1 0-30K wob, 105 rpm's, 600 gpm, off btm pressure 1,500, on btm 1,600 psi, off btm torque 1 K, on btm 3K ft-Ibs, rot wt 109K, up wt 105K, dn wt 11 OK, Epoch mud loggers ave BGG 100, max gas 422 units from 1,594', 10.0 ppg MW, ave ECD 10.6 ppg, no gas hydrates seen 5.00 DRILL DRLG SURFAC Drilled 12 1/4" hole from 2,105' to 2,495' MD/2,495' TVD, (390') ART 5 hrs, 1 0-30K wob, 105 rpm's, 600 gpm, off btm pressure 1,650 psi, on btm 1,750 psi, off btm torque 1 K, on btm 4K ft-Ibs, rot wt 116K, up wt 110K, dn wt 115K, Epoch mud loggers ave BGG 75, max gas 131 units, 10.0 ppg MW, ave ECD 10.8 ppg, no gas hydrates seen, pumped weighted hi vis sweep at 2,165' and had 25% increase in cuttings back from sweep, control drill at 130-150'/hr for geology from 2,300' Circ btms up for geology Drilled from 2,495' to 2,505' MD/2,505' TVD (10'), ART 1/4 hr Circ btms up for geology Drilled from 2,505' to 2,510' MD/2,510' TVD (5'), ART 1/4 hr, (95/8" Csg Pt) Circ btms up for geology, monitored well-static, pumped weighted hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ at 600 gpm at 1,700 psi and 105 rpm's, circ a total of 3X btms up, rot wt 116K, up wt 11 OK, dn wt 115K Attempted to POOH on elevators and hole swabbing, backreamed out of hole from 2,433' to 1,136' to HWDP, backreamed out at 100 rpm's, 600 gpm, 550 gpm, 1,400 psi with no problems RIH from 1,136' to 2,433' then washed 77' to btm at 2,510' with no problems Pumped weighted hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ at 600 gpm, 1,700 psi, circ 2 1/2X btms up and clean at shakers Monitored well-static Legal Well Name: KOKODA #1 Common Well Name: KOKODA #1 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 2/16/2005 13:45 - 14:45 1.00 WE LeT BOPE SURFAC 14:45 - 17:00 2.25 DRILL PULD SURFAC 17:00 - 18:30 1.50 DRILL PULD SURFAC 18:30 - 19:45 1.25 DRILL OTHR SURFAC 19:45 - 20:15 0.50 DRILL CIRC SURFAC 20: 15 - 23:00 2.75 DRILL DRLG SURFAC 23:00 - 00:00 1.00 DRILL TRIP SURFAC 2/17/2005 00:00 - 03:00 3.00 DRILL PULD SURFAC 03:00 - 12:00 9.00 DRILL DRLG SURFAC 12:00 - 00:00 2/18/2005 00:00 - 05:00 05:00 - 05:45 0.75 DRILL CIRC SURFAC 05:45 - 06:00 0.25 DRILL DRLG SURFAC 06:00 - 06:45 0.75 DRILL CIRC SURFAC 06:45 - 07:00 0.25 DRILL DRLG SURFAC 07:00 - 09:00 2.00 DRILL CIRC SURFAC 09:00 - 11 :15 2.25 DRILL WIPR SURFAC 11:15 -12:30 1.25 DRILL WIPR SURFAC 12:30 - 14:00 1.50 DRILL CIRC SURFAC 14:00 - 14:15 0.25 DRILL OBSV SURFAC Start: Rig Release: Rig Number: Alaska Oil & G$¡fua;D.Jí.2~g6l2005 2/7/2005 Anftn1¡lâge 3/6/2005 3/6/2005 Group: Description of Operations Printed: 3/17/2005 1:20:00 PM . . ~noçoPhiltiPS Alaska . ~E CEIVED Pagí;}xpdf 14 Operations Summary Repo . APR 2 9 2005 Legal Well Name: KOKODA #1 Alaska Oil & G~b~ð-aç~~~~}~~05 Common Well Name: KOKODA #1 Event Name: ROT - DRILLING Start: 2/7/2005 AI'; w.age 3/6/2005 Contractor Name: n1334@ppco.com Rig Re ease: 3/6/2005 Group: Rig Name: Doyon 141 Rig Nu TIber: Date From- To Hours Code Sub Phase Description of Operations Code 2/18/2005 14:15-18:00 3.75 DRILL TRIP SURFAC Attempted o POOH on elevators from 2,510' and well not taking proper fill due to s Nabbing, pumped out of hole from 2,433' to 324', pumped out at 50 r~ m's, 315 gpm at 500 psi, POOH from 324' to 232' to BHA #1, no prot lems pumping out and had a large amount of sand and clay back while pumping out 18:00 - 18:30 0.50 DRILL OTHR SURFAC Circ thru B -tA with water to clean out tools and cleaned rig floor 18:30 - 23:00 4.50 DRILL PULD SURFAC LD 12 1/4" BHA #1, held PJSM and removed radioactive sources, LD flex De's, c ownloaded MWD and LD remaining BHA, cleared rig floor 23:00 - 00:00 1.00 CASE RURD SURFAC Began RU þoyon's 9 5/8" csg equipment 2/19/2005 00:00 - 00:45 0.75 CASE RURD SURFAC Fin RU Do on's 95/8" csg equipment with Franks fill up tool 00:45 - 01 :00 0.25 CASE SFTY SURFAC Held PJSM with rig crew and tong operator 01 :00 - 06:30 5.50 CASE RUNe SURFAC MU 9 5/8" loat shoe, 2 jts of 9 5/8", 40#, L-80, BTC csg and fit collar, thread lock ßd conn below Fe and circ thru shoe track, RIH with 9 5/8" csg to 2,47 17, with no problems, MU hanger and landed csg with float shoe at 2,5 þ5' and float collar at 2,424', no problems RIH, Ran a total of 64 jts (2,45 ß.40') of 95/8",40#, L-80, BTC csg and 2- pup jts, total including fl at equip, csg and hanger, 2,477.17', ran 17 bow spring centralizer~ and 3 stop rings per well plan, st wt up 122K, dn wt 112K 06:30 - 08: 15 1.75 CEMEN CIRC SURFAC Began to c rc and condition mud thru fill up tool, staged pump rate up to 6 bpm at 3 o psi, circ 500 bbls of mud while conditioning same, st wt up 112K dr wt 109K 08: 15 - 08:45 0.50 CEMEN RURD SURFAC LD Franks III up tool and MU Dowells cement head 08:45 - 10:45 2.00 CEMEN CIRC SURFAC Fin circ an( cond mud for cementing, staged pump rate up to 6 bpm, 300 psi, co ditioned mud from 10.2 ppg, 63 vis, PV 19, YP 41 to 10.0 ppg, 43 vis PV 16, YP 26, reciprocated pipe with no problems and full returns, he Id PJSM with Dowell, APe vac truck drivers and rig crew while circ h þle 10:45 - 12:30 1.75 CEMEN PUMP SURFAC Turned ove r to Dowell and pumped 10 bbls of CW 100 with red dye at 8.3 ppg, pr ssure tested lines to 3,500 psi, pumped add. 40 bbls of CW 100 (50 bbl I> Total), then pumped 41 bbls of 10.5 ppg Mudpush, ave 5 bpm at 190 psi, shut down and dropped btm plug, began mixing and pumping Ie d cement, pumped 275 bbls, 347 sxs of 10.7 ppg, 4.45 yield Arctic set Lite cmt with add., ave 6 bpm at 110 psi, followed with 73 bbls, 16 sxs of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add. ave 5 Jpm at 300 psi, reciprocated pipe with full returns, st wt up 125K, dn w 122K, shut down and dropped top plug. NOTE: After pumping 2 o bbl$ of lead cement began to see red dye at surface, after 260 bbl$h¡ d good red dye to surface 12:30 - 13:15 0.75 CEMEN DISP SURFAC Dowell purr ped 20 bbls FW and turned over to rig and rig displaced cmt with 164.5 bls of 10.0 ppg mud, ave 6 bpm, initial pressure 300 psi, max pressL re 610 psi, slowed to 4 bpm and bumped plugs on calc displaceme nt to 1,275 psi, reciprocated pipe till 12:4þ hrs and 90 bbls into disp,lac ement with 274 bbls of lead cement out of shoe, ck floats and floats ~ eld, CIP at 13:00, NOTE: Did not see any 10.7 ppg lead cement to ~ urface, Tim Lawlor with BLM witnessed cement job 13:15-14:45 1.50 CASE RURD SURFAC RD cemßnt head, LD landing jt and RD csg equipment 14:45 - 17:15 2.50 WELCTL NUND SURFAC NO 21 114" 2M diverter, knife valve and 16" line 17:15 - 18:15 1.00 DRILL OTHR SURFAC Loaded wel Ihead into cellar, RU flare line and put 60 jts of 5" DP in pipe shed an~ s rapped 18:15 - 22:30 4.25 CEMENl RURD SURFAC offloade~ a d strapped 1 1/4" CS hydriJ, attempted to RIH between 9 5/8" x 1~" c onductor and would not go thru FMC fluted hanger, RIH with plumb bpb nd tagged TOe at 88' GU116' RKB, RIH with 3/4" conduit and tagged up at 88' GU116' RKB, welded up 80' of 1" tbg I ¡ I Printed: 3/17/2005 1:20:00 PM I / ConocoPhillips Alaska RE C E.IVE"eØ9f1~> Op~rations Summary Report APR29 2005 Legal Well Name: KOKODA #1 I Alaska Oil & Gas Cons. Commission Common Well Name: KOKODA #1 Sp~fk_é2/16/2005 1 Event Name: ROT - DRILLING Start:: 2/7/2005 End: 3/6/2005 Contractor Name: n1334@ppco.com Rig ~elease: 3/6/2005 Group: Rig Name: Doyon 141 Rig Number: From- To HO.urs Code Sub Phase Description of Operations Code 2/19/2005 22:30 - 23:30 1.00 CEMEN CIRC SURFAC RIH with 11" tbg to 80' GU1 08' RKB, circ 33 bbls of 9.7 ppg mud in 9 5/8" x 16" annulus, circ at 1 bpm at 60 psi 23:30 - 00:00 0.50 CEMEN TOPJ SURFAC Began t~ pump cement for top job, Dowell pumped 2 bbls of water, then began to pump AS 1 cement at 15.7 ppg and .93 yield, have pumped 20 bbls ,s of report time at .6 bpm at 60 psi with no cement to surface 2/20/2005 00:00 - 04:00 4.00 CEMEN PUMP SURFAC Fin pumwing top job #1 from 80' GU108' RKB, pumped a total of 84 bbls of 15.7 Pþg, .93 yield AS-1 cmt with no cmt to surface, pumped at .6 bpm at 6!5 psi, CIP at 01 :45, POOH with 1" stinger and washed out same 04:00 - 08:00 4.00 WAlTON SPLY SURFAC Waited qn Dowell to deliver additional cement for top job #2, had to send purpp truck to Iapetus to cmt conductor, changed out ring gasket on BOP ~dapter spool 08:00 - 10:00 2.00 DRILL PULD SURFAC PU and ~tood back 20 additional stds of 5" DP 10:00 - 12:00 2.00 RIGMNT RSRV SURFAC SeNiced, top drive and drawworks, performed derrick inspection 12:00 - 15:30 3.50 WAlTON SPLY SURFAC Cont to wait on Dowell, welded up an add 74' of 1" stinger for 154' total 15:30 -16:15 0.75 CEMEN CIRC SURFAC RIH with '1" stinger and tagged cmt at 88' GU116' RKB, attempted to wash down at .5 bpm at 70 psi and was unable to go deeper, circ 17 bbls of 9.7 ppg mud with full returns, NOTE Tim Lawlor with BLM was on location and witnessed tag 16:15 -17:45 1.50 CEMEN PUMP SURFAC Turned dver to Dowell and began pumping Arctic set Lite cmt at 10.7 ppg and \4.45 yield, after pumping 7 bbls of cmt had cmt to surface, pumped ~ total of 20 bbls of cmt with 13 bbls of good 10.7 ppg cmt to surface, þumped at an ave of .6 bpm at 130 psi, CIP at 17:30, POOH with 1" s1inger, Tim Lawlor with BLM witnessed cementing 17:45 - 18:30 0.75 CEMEN RURD SURFAC LD 1" sti~ger and washed out, RD Dowell 18:30-19:15 0.75 WELCTL NUND SURFAC Orientediand NU FMC 11" 5M Gen V wellhead and tested seal to 1,000 WELCTL psi for 1 q min and ck ok 19:15-21:30 2.25 NUND SURFAC NU 13 5~8" 5M BOP stack with check valve on kill line per BLM requirem;ents+ 21 :30 - 00:00 2.50 WELCTL BOPE SURFAC RU and ti>egan testing BOP's, testing rams, valves and choke manifold to 250 psi low and 5,000 psi high, NOTE Tim Lawlor with BLM and John Spaulding with AOGCC is on location witnessing test 2/21/2005 00:00 - 04:00 4.00 WELCTL BOPE SURFAC Fin testirlg BOP's, tested rams, manifold and valves to 250 psi low and 5,000 psi high, tested Annular to 250 psi and 3,500 psi, (dart valve failed), t~t witnessed by John Spaulding with AOGCC and Tim Lawlor with BLM 04:00 - 04:30 0.50 DRILL PULD SURFAC Pulled tebt plug and installed wear bushing 04:30 - 08:00 3.50 DRILL PULD SURFAC MU 8 1/4" BHA #2 with 6 7/8" motor with .93 deg bend, MWD, density nuetron and PWD, oriented and uploaded MWD, held PJSM and loaded rádioactive sources, RIH to 390' and shallow tested MWD 08:00 - 09:30 1.50 DRILL TRIP SURFAC RIH from 390' to 2,420' 09:30 - 11 :15 1.75 DRILL CIRC SURFAC Circ and !cond mud for csg test, circ at 450 gpm at 850 psi, evened MW in and out at 9.8 ppg, st up wt 102K, dn wt 107 11:15-12:15 1.00 CASE DEQT SURFAC RU and tested 9 5/8" csg to 2,500 psi for 30 min 12:15 - 13:30 1.25 WELCTL BOPE SURFAC RU and tested re-built dart valve that had failed during test, tested valve to 250 psi and 5,000 psi and ck ok 13:30 - 14:45 1.25 CEMEN DSHO SURFAC RIH from 2,420' and tagged plugs above float collar, drilled out float collar at 2,424', shoe track and float shoe at 2,505', drilled 20' of new hole to 2;530' MD/2,530' TVD, drilled at 4-7K wob, 60 rpm's, 424 gpm at 1,000 psi, rot wt 111 K, up wt 105K, dn wt 112K 14:45 - 15:30 0.75 DRILL CIRC SURFAC Circ hole: clean for LOT/FIT, circ at 424 gpm at 1,000 psi evening MW in and o~t at 9.8 ppg 15:30 - 16:30 1.00 DRILL FIT SURFAC RU and 1erfOrmed FIT to 15.9 ppg EMW, 800 psi at 2,506' TVD with Printed: 3/1712005 1:20:00 PM . . I legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ConocoPhillips Alaska Operations Summary Report A/ash nil R. r.~~ rnnt! (', Anchorage Spud Date: 2/16/2005 End: 3/6/2005 Group: . KOKODA #1 KOKODA #1 ROT - DRilLING n 1334@ppco.com Doyon 141 . RECEIV6Qe70f14 APR 2 9 2005 . , Start: Rig Release: Rig Number: 2/7/2005 3/6/2005 Date From - To Hours Code Sub Phase Code 2/21/2005 15:30 - 16:30 1.00 DRILL FIT SURFAC 16:30 - 18:00 1.50 DRILL DRLG PROD 18:00 - 18:30 0.50 DRILL CIRC PROD 18:30 - 00:00 5.50 DRILL DRLG PROD 2/22/2005 00:00 - 05:15 05:15 - 06:00 06:00 - 07:30 5.25 DRILL DRLG PROD 0.75 DRILL CIRC PROD 1.50 DRILL WIPR PROD 07:30 - 08:00 0.50 DRILL WIPR PROD 08:00 - 08:30 0.50 DRILL REAM PROD 08:30 -12:00 3.50 DRILL DRLG PROD 12:00-21:45 9.75 DRILL DRLG PROD 21 :45 - 22:45 1.00 DRILL CIRC PROD 22:45 - 00:00 1.25 DRILL WIPR PROD 2/23/2005 00:00 - 00:30 0.50 DRILL WIPR PROD 00:30 - 00:45 0.25 DRILL CIRC PROD Description of Operations 9.8 ppg MW Drilled 8 1/2" hole from 2,530' to 2,698' MOl 2,698' TVD (168'), ART 1.2 hrs, 5-15K wob, 100 rpm's, 500 gpm, 1,300 psi, rot wt 109K, up wt 114K, dn wt 116K, off btm torque 2K ft-Ibs, on btm 3K ft-Ibs Circ hole clean and performed PWD baseline, circ at 510 gpm, 1,350 psi with 105 rpm's and had a clean hole ECD of 10.3 ppg Drilled 8 1/2" hole from 2,530' to 3,280' MOl 3,280' TVD (582'), ART 4 hrs, 3-15K wob, 110 rpm's, 120 spm, 510 gpm, off btm pressure 1,500 psi, on btm 1,750 psi, rot wt 125K, up wt 119K, dn wt 121 K, off btm torque 2K ft-Ibs, on btm 5K ft-Ibs, 9.8 ppg MW, ave ECD of 11.1 ppg, mudloggers aye BGG 60 units, max gas 117 units from 2,736', pumped weighted hi vis sweep at 3,162' with 10% increase in cuttings back from sweep Drilled 8 1/2" hole from 3,280' to 3,719' MOl 3,719' TVD (439'), ART 4.7 hrs, 5-15K wob, 110 rpm's, 120 spm, 510 gpm, off btm pressure 1,600 psi, on btm 1,900 psi, rot wt 135K, up wt 129K, dn wt 134K, off btm torque 2K ft-Ibs, on btm 6K ft-Ibs, 9.8 ppg MW, ave ECD of 11.3 ppg, mudloggers ave BGG 40 units, max gas 70 units from 3,318", pumped weighted hi vis sweep at 3,630' with 20% increase in cuttings back from sweep Circ 2 1/2X btms up for wiper trip and clean at shakers, circ at 530 gpm, 1,650 psi and 110 rpm's, ECD before while drlg 11.3 ppg, ECD after circ hole clean 10.9 ppg Wiped hole 13 stds to shoe at 2,505', POOH from 3,719' to 2,887' aye 10K drag, at 2,970' had 25K drag and dropped right off, after 7 stds hole swabbing and did not take proper hole fill, pumped out of hole from 2,887' to 2,608' then pulled out to shoe at 2,505', no real tight spots POOH, pumped out at 70 rpm's, 300 gpm at 750 psi RIH from 2,505' to 3,627' with no problems Washed 92' to btm from 3,627' to 3,719' with no problems, washed at 110 rpm's, 510 gpm at 1,500 psi, at btms up had 165 units of gas from wiper trip Drilled 81/2" hole from 3,719' to 3,960' MD/3,960' TVD (241'), ART 2.5 hrs, AST .5 hrs 10-15K wob, 110 rpm's, 125 spm, 525 gpm, off btm pressure 1,600 psi, on btm 1,900 psi, rot wt 139K, up wt 134K, dn wt 131 K, off btm torque 2.5K ft-Ibs, on btm 6K ft-Ibs, 9.8 ppg MW, aye ECD of 11.0 ppg Drilled 81/2" hole from 3,960' to 4,741' MD/4,741' TVD (781'), ART 6.1 hrs, AST .3 hrs, 5-15K wob, 110 rpm's, 125 spm, 525 gpm, off btm pressure 1,800 psi, on btm 2,100 psi, rot wt 152K, up wt 146K, dn wt 146K, off btm torque 2.5K ft-Ibs, on btm 5K ft-Ibs, 9.8 ppg MW, ave ECD of 11.4 ppg, mudloggers ave BGG 30 units, max gas 53 units from 4,055', pumped hi vis sweeps at 4,208' and 4,650' with 10-20% increase in cuttings back from sweep Circ 3X btms up for wiper trip and clean at shakers, circ at 525 gpm, 1,800 psi and 110 rpm's, ECD while drlg 11.4 ppg, ECD after circ hole clean 11.1 ppg Wiped hole 11 stds to 3,627', POOH on elevators from 4,741' to 3,627' with no problems and hole took calc fill RIH from 3,627' to 4,648' Washed 93' to btm from 4,648' to 4,741' with no problems or fill, washed down at 110 rpm's, 525 gpm at 1,800 psi, max gas at btms up from wiper trip 190 units .... . . Printed. 3/17/2005 1.20.00 PM . . ~ ConocoPhillips Alaska RECE/VStJ8>Of14 Operations Summary Report APR 292005 ..... AI:u·,,,, n:1 n ~ .... Legal Well Name: KOKODA #1 -.. .... Ucl~ lJons. Commission Common Well Name: KOKODA #1 sp1r¿ff!J«M82/16/2005 Event Name: ROT - DRILLING Start: 2/7/2005 End: 3/6/2005 Contractor Name: n1334@ppco.com Rig Release: 3/6/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 2/23/2005 00:45 - 14:45 14.00 DRILL DRLG PROD Drilled 81/2" hole from 4,741' to 5,762' MOl 5,762' TVD (1,021'), ART 10.5 hrs, 5-15K wob, 110 rpm's, 125 spm, 525 gpm, off btm pressure 2,050 psi, on btm 2,375 psi, rot wt 172K, up wt 169K, dn wt 171 K, off btm torque 3K ft-Ibs, on btm 6K ft-Ibs, 9.9 ppg MW, ave ECD of 11.4 ppg, max ECD 11.5 ppg, mudloggers ave BGG 30 units, max gas 38 units from 5,628', no conn gas, pumped hi vis sweep at 5,298' with no increase in cuttings. 14:45 - 15:45 1.00 DRILL CIRC PROD Pumped hi vis sweep at 5,762' and circ out, had no increase in cuttings from sweep, circ an add. btms up and clean at shaker, circ hole at 525 gpm at 2,050 psi, 110 rpm's, monitored well-static 15:45 - 16:30 0.75 DRILL WIPR PROD Wiped hole 10 stds from 5,762' to 4,741' with no problems and hole took calc fill of 9 bbls 16:30 - 17:00 0.50 DRILL WIPR PROD RIH from 4,741' to 5,669', washed 93' to btm at 5,762' with no problems or fill 17:00 - 17:30 0.50 DRILL CIRC PROD Fin circ btms up after'wiper trip, max gas at btms up 94 units, circ at 525 9pm, 2,050 psi at 110 rpms, ECD while drlg 11.4, ECD down to 11.1 ppg after circ btms up 17:30 - 00:00 6.50 DRILL DRLG PROD Drilled 8 1/2" hole from 5,762' to 6,227' MOl 6,227' TVD (465'), ART 4.7 hrs, AST .3 hrs, 1 0-15K wob, 110 rpm's, 125 spm, 525 gpm, off btm pressure 2,125 psi, on btm 2,400 psi, rot wt 179K, up wt 177K, dn wt 178K, off btm torque 3K ft-Ibs, on btm 7K ft-Ibs, 10.0 ppg MW, ave ECD of 11.4 ppg, max ECD 11.5 ppg, mudloggers ave BGG 30 units, max gas 53 units from 6223', no conn gas, pumped hi vis sweep at 6,227' with no increase in cuttings. 2/24/2005 00:00 - 06:30 6.50 DRILL DRLG PROD Drilled 8 1/2" hole from 6,227' to 6,678' MOl 6,678' TVD (451'), ART 5.3 hrs, 10-15K wob, 110 rpm's, 125 spm, 525 gpm, off btm pressure 2,200 psi, on btm 2,500 psi, rot wt 187K, up wt 185K, dn wt 183K, off btm torque 2K ft-Ibs, on btm 6K ft-Ibs, 10.0 ppg MW, ave ECD of 11.4 ppg, mudloggers ave BGG 30 units, max gas 52 units from 6,288', no conn gas 06:30 - 08: 15 1.75 DRILL CIRC PROD Pumped hi vis and circ out, had no increase in cuttings from sweep, circ a total of 3X btms up and was clean at shakers, circ at 525 gpm, 2,200 psi at 110 rpm's, monitored well-static 08:15 - 08:45 0.50 DRILL TRIP PROD POOH 5 stds and hole did not take proper fill, calc fill 3.75 bbl, actual fill 2 bbls 08:45 - 09:15 0.50 DRILL TRIP PROD RIH from 6,230' to 6,678' 09:15 - 10:00 0.75 DRILL CIRC PROD Circ btms up to check for gas, max gas 50 units, circ at 525 gpm at 2,200 psi 10:00 - 15:30 5.50 DRILL TRIP PROD POOH 5 stds and hole took calc. fill, pumped dry job and POOH from 6230' to 3,510' with no problems, pulled 25-30K over from 3,510' to 3,250, rotated out from 2,950 to 2,878, pulled 20K over from 2,878' to 2,600', POOH to 2,490' (shoe @ 2,505') and monitored well-static, POOH to BHA at 196' standin9 back HWDP, monitored well-static 15:30 - 18:30 3.00 DRILL PULD PROD Held PJSM on Changing out BHA's, stood back flex De's then removed radioactive sources, downloaded MWD and pulled probe, LD motor and bit #2 18:30 - 21 :00 2.50 DRILL PULD PROD MU 8 1/2" BHA #3, rotary assembly and RIH to 330', MU 8 1/2" bit and Sperry's DGRlWRlPWD tool and uploaded MWD and loaded radioactive sources, RIH to 330' and shallow tested MWD 21:00 - 22:15 1.25 DRILL TRIP PROD RIH with BHA #3 from 330' to 2,466' 22:15 - 23:30 1.25 RIGMNT RSRV PROD Slip and cut 63' of drilling line and seNiced top drive 23:30 - 00:00 0.50 DRILL TRIP PROD RIH from 2,466' to 3,490 2/25/2005 00:00 - 01 :15 1.25 DRILL TRIP PROD RIH with BHA #3 from 3,490' and set 30K st wt down at 5,030' Printed: 3/17/2005 1 :20:00 PM . . ConocoPhillips Alaska Pag~9Qf14 Operations Summary Report RECEIVED APR ? 9 2005 legal Well Name: KOKODA #1 Alaska Oi~&atJèqR~¿;~è~n Common Well Name: KOKODA #1 Event Name: ROT - DRilLING Start: 2/7/2005 Enê!1chorage:3/6/2005 Contractor Name: n1334@ppco.com Rig Release: 3/6/2005 Group: Rig Name: Doyon 141 Rig Number: Sub .... Date From - To Hours Code Code Phase Description of Operations . 2/25/2005 01:15 - 01:45 0.50 DRILL CIRC PROD Est Circ staging pump rate up to 525 gpm, 2,100 psi and 110 rpm's and washed from 4,976' to 5,069', did not see tight spot, circ btms up, max gas 115 units and had a large amount of shale and clay back while circ 01 :45 - 03:00 1.25 DRILL TRIP PROD RIH from 5,069' to 6,554' with no problems 03:00 - 04:00 1.00 DRILL CIRC PROD Washed down from 6,554' to 6,600' and logged down from 6,600' to btm at 6,678', circ btms up, max gas 110 units, circ at 525 gpm at 1,950 psi and 110 rpm's 04:00 - 07: 15 3.25 DRILL DRLG PROD Drilled 8 1/2" hole control drilling at 50'/hr looking for core point from 6,678' to 6,810' MOl 6,810' TVD, (132') ART 2.62 hrs, 5-15K wob, 120 rpm's, 525 gpm, off btm pressure 1,950 psi, on btm 2,000 psi, off btm torque 3K ft-Ibs, on btm 3K, rot wt 190K, up wt 187K, dn wt 188K, 10.3 ppg MWave ECD 11.3, ave BGG 30 units 07: 15 - 08:00 0.75 DRILL CIRC PROD Circ btms up for samples at 6,810', max gas 103 units 08:00 - 08:30 0.50 DRILL DRLG PROD Drilled 81/2" hole from 6,810' to 6,828', ART 1/2 hr 08:30 - 09:15 0.75 DRILL CIRC PROD Circ btms up for samples at 6,828', max gas 215 units 09: 15 - 09:45 0.50 DRILL DRLG PROD Drilled 8 1/2" hole from 6,828' to 6,837' MOl 6,837' TVD (Core Pt.) ART 112 hr, 5-15K wob, 120 rpm's, 525 gpm, off btm press 1,975 psi, on btm 2,000 psi, rot wt 190K, up wt 187K, dn wt 188K 09:45 - 12:00 2.25 DRILL CIRC PROD Circ btms up to check gas and for sample, max gas 265 units, cont to circ hole clean while adding .2 ppb of potassium iodide tracer to mud system, circ a total of 2X btms up and clean at shaker, circ at 525 gpm, 1,975 psi, 120 rpm's, monitored well-static 12:00 - 13:00 1.00 DRILL WIPR PROD Wiped hole 10 stds to 5,898' with no problems and hole took calc fill 13:00 - 13:30 0.50 DRILL WIPR PROD RIH from 5,898' to 6,740' then washed down 97' to btm with no problems or fill 13:30 - 14:15 0.75 DRILL CIRC PROD Circ btms up after wiper trip, max gas 47 units, circ at 525 gpm, 1,975 psi, monitored well-static 14:15 -18:00 3.75 DRILL TRIP PROD POOH wet 5 stds to 6,370' and hole took calc fill, pumped dry job and cont POOH to 2,469' with no problems, monitored well at shoe-static, POOH to BHA at 179' 18:00 - 20:30 2.50 DRILL PULD PROD POOH & LD BHA #3, held PJSM and removed radioactive sources, stood back stand of flex DC's, downloaded MWD and LD same 20:30 - 20:45 0.25 CORE SFTY PROD Held PJSM with Baker Hughes Inteq reps and rig crew on MU coring assembly 20:45 - 22:45 2.00 CORE PULD PROD MU 8 1/2" coring BHA #4, 8 1/2" core bit, 120' of 6 3/4" x 4" core bbl & RIH to 137', string up wt 45K, dn wt 45K 22:45 - 00:00 1.25 CORE TRIP PROD RIH with BHA #4 from 134' to 2,431', string up wt 88K, dn wt 93K 2/26/2005 00:00 - 02:30 2.50 CORE TRIP PROD RIH with coring BHA #4 from 2,431' to 6,795' 02:30 - 03:00 0.50 CORE WASH PROD Washed down from 6,795' to 6,837' with no problems, 295 gpm at 750 psi 03:00 - 04: 15 1.25 CORE CIRC PROD Circ btms up at 6,837', max gas at btms up 60 units, circ at 295 gpm 700 psi at 20 rpm's, st wt up 175K, dn wt 178K, dropped 1 1/4" ball and pumped down to seat, with ball on seat took SPR's with both pumps 04:15 - 09:15 5.00 CORE CORE PROD Cut 8 1/2" x 4" Core from 6,837' to 6,873' (36') when core bbl jammed (Driller inadvertantly shut down pump while coring), Cored at 70 rpm's, 12-14K wOb, 270 gpm at 820 psi, rot wt 181K, up wt 181K, dn wt 184K, max gas 141 units from 6,838' 09:15-10:15 1.00 CORE CIRC PROD Circ btms up at 6,873', max gas at btms up 68 units, circ at 335 gpm, 1,000 psi and 30 rpm's, monitored well-static 10:15 - 15:00 4.75 CORE TRIP PROD POOH to 6,424' and hole took calc fill, monitored well-static, pumped dry job and cont POOH per trip schedule with core to 2,431' with no problems 15:00-15:15 0.25 CORE OTHR PROD Monitored well at shoe for 15 min, well-static \.,. Crl Printed: 3/17/2005 1:20:00 PM Start: 2/7/2005 Rig Release: 3/6/2005 Rig Number: REC~V~t514 APR 292005 II & Gas Cons Comn" . Spud DcAer;fid~á?i¿005 18810 End: 3/61~005 Group: ConocoPhillips Alaska Operations Summary Report Legal Well Name: KOKODA #1 Common Well Name: KOKODA #1 Event Name: ROT - DRILLING Contractor Name: n 1334@ppco.com Rig Name: Doyon 141 Prom... To Hours Code Sub Phase Code 2/26/2005 15:15-18:15 3.00 CORE TRIP PROD 18:15 -18:30 0.25 CORE SFTY PROD 18:30 - 20:00 1.50 CORE RCVR PROD 20:00 - 21 :45 1.75 CORE PULD PROD 21 :45 - 00:00 2.25 DRILL PULD PROD 2/27/2005 00:00 - 01 :15 1.25 DRILL TRIP PROD 01:15 - 03:15 2.00 RIGMNT RSRV PROD 03: 15 - 05:30 2.25 DRILL TRIP PROD 05:30 - 06:00 0.50 DRILL REAM PROD 06:00 - 06:45 0.75 DRILL CIRC PROD 06:45 - 16:30 9.75 DRILL DRLG PROD 16:30 - 17:00 0.50 DRILL CIRC PROD 17:00 - 18:00 1.00 DRILL DRLG PROD 18:00 - 18:30 0.50 DRILL CIRC PROD 18:30 - 00:00 5.50 DRILL DRLG PROD 2/28/2005 00:00 - 03:00 3.00 DRILL DRLG PROD 03:00 - 04:00 1.00 DRILL CIRC PROD 04:00 - 04:15 0.25 DRILL OBSV PROD 04:15 - 06:00 1.75 DRILL WIPR PROD 06:00 - 06:45 0.75 DRILL WIPR PROD 06:45 - 08:30 1.75 DRILL CIRC PROD 08:30 - 08:45 0.25 DRILL OBSV PROD 08:45 - 13:15 4.50 DRILL TRIP PROD Description of Operations Cont to POOH from 2,431' to Core bbl at 134' per trip schedule, monitored well at HWDP and POOH standing back same and retrieved 1 1/4" ball, calc fill on trip out 63 bbls, actual fill 69 bbls Held PJSM on LD core bbls with Baker reps and rig crew Pulled out and recovered 4" inner core bbls and LD same POOH and LD 6 3/4" core bbls and bit, cleared rig floor, (recovered 34' of cofe) MU 81/2" BHA #5 RIH to 219', MU bit #5 (RR bit #2),67/8" motor with 1.035" bend with DGRlEWRlPWD/DM Nuetron ACALlTM, oriented and uploaded MWD, held PJSM and loaded radioactive sources RIH to 219' RIH from 219' to 2,051' and shallow tested MWD SeNiced top drive and drawworks, re-Ieveled sub base RIH from 2,051' to 6,785', had 15K drag from 4,550'-4,580', no other problems RIH Washed 88' from 6,785' to 6,873' with no problems Circ btms up at 6,873', max gas at btms up 84 units, circ at 530 gpm at 2,200 at 110 rpm's Drilled 8 1/2" hole from 6,873' to 7,500' MOl 7,500' TVD (627') ART 7.8 hrs, 1 0-15K wob, 120 rpm's, 125 spm, 530 gpm, off btm pressure 2,300 psi, on btm 2,575 psi, off btm torque 2.5K ft-Ibs, on btm 2-8K ft-Ibs, rot wt 205K, up wt 201 K, dn wt 204K, 10.3 ppg mw, ave ECD 11.25 ppg, ave BGG 45 units, max gas 523 units from 7,237' and 1,130 units from 7,458' Circ btms up at 7,500', max gas at btms up 1,100 units, 10.3 ppg mw gas cut to 9.3 ppg, circ at 530 gpm at 2,300 psi, monitored well-static Drilled 8 1/2" hole from 7,500' to 7,557' MD/7,557' TVD (57') ART .5 hrs Circ btms up at 7,557', max gas at btms up 995 units, 10.3 ppg mw gas cut to 9.5+ ppg, circ at 530 gpm at 2,300 psi, monitored well-static Drilled 8 1/2" hole from 7,557' to 7,874' MOl 7,874' TVD (317') ART 4.2 hrs, 10-15K wob, 120 rpm's, 125 spm, 530 gpm, off btm pressure 2,250 psi, on btm 2,575 psi, off btm torque 3K ft-Ibs, on btm 5K ft-Ibs, rot wt 210K, up wt 206K, dn wt 209K, 10.3 ppg mw, ave ECD 11.3 ppg, ave BGG 150 units, max gas 518 units from 7,583', connection gas ave 10-20 units over BGG Drilled 8 1/2" hole from 7,874' to 8,045' MOl 8,045' TVD (TO) (171') ART 2.1 hrs, 10-15K wob, 120 rpm's, 125 spm, 530 gpm, off btm pressure 2,300 psi, on btm 2,700 psi, off btm torque 3K ft-Ibs, on btm 6K ft-Ibs, rot wt 215K, up wt 210K, dn wt 213K, 10.3 ppg mw, ave ECD 11.4 ppg, ave BGG 130 units, max gas 164 units from 7,990', pumped hi vis sweep at 7,990' with no increase in cuttings Circ hole clean for wiper trip, circ 2X btms up and clean at shakers, circ at 530 gpm, 2,400 psi, 120 rpm's, final BGG 70 units, final ECD 11.2 ppg Monitored well-static, blow down top drive Wiped hole 20 stds from 8,045' to 6,140', ave 5K drag, pulled 25K over at 7,000 and 6,920' worked thru spots and had no problem, no other tight spots on trip out, monitored well at 6,140' well-static RIH from 6,140' to 7,992' then washed 53' to btm with no problems Circ hole clean for trip out of hole, circ 2X btms up and clean at shakers, circ at 530 gpm, 2,400 psi, 120 rpm's, max gas at btms up after wiper trip 800 units Monitored well-static POOH wet 10 stds to 7,160' with no problems and hole took calc fill, ;/ Printed: 3/17/2005 1 :20:00 PM . / ... ConocoPhillips Alaska RECEI~E8Oft4 Operations Summary Report APR2 92005 . .. Legal Well Name: KOKODA #1 Alaska Oil &~a~C~~ Çjmmission Common Well Name: KOKODA #1 Spud a: 6 Event Name: ROT - DRILLING Start: 2/7/2005 End: nc or~b2005 Contractor Name: n1334@ppco.com Rig Release: 3/6/2005 Group: Rig Name: Doyon 141 Rig Number: Date From ~ To Hours Code Sub Phase Description of Operatipns Code 2/28/2005 08:45 - 13:15 4.50 DRILL TRIP PROD pumped dry job and cont POOH to 2,474' with no problems 13:15 -13:45 0.50 DRILL OBSV PROD Monitored well at shoe for 30 min and well was static 13:45 - 15:00 1.25 DRILL TRIP PROD POOH from 2,474' to HWDP at 1,081', monitored well-static, POOH standing back HWDP to BHA at 217' 15:00 - 17:45 2.75 DRILL PULD PROD POOH LD BHA #5, LD NM flex De's, held PJSM and removed radioactive sources, downloaded MWD and fin LD BHA, calc fill on trip out 77 bbls, actual fill 82 bbls 17:45 -18:15 0.50 DRILL PULD PROD Pulled wear bushing 18:15 - 22:15 4.00 WELCTl BOPE PROD RU ahd tested BOPE, tested valves, manifold and rams to 250 psi low and 5,000 psi high, tested annular to 250 psi low and 3,500 psi high, no failures, NOTE: Chuck Scheve W/AOGCC waived witnessing of test 22:15 - 22:30 0.25 DRILL PULD PROD Installed wear bushing 22:30 - 22:45 0.25 LOG SFTY PROD Held PJSM with rig crew and Schlumberger wireline (SWS) on RU of wireline and upcoming operations 22:45 - 00:00 1.25 LOG RURD PROD RU SWS wireline and scheves 3/1/2005 00:00 - 01 :15 1.25 LOG RURD PROD Finish RU Schlumberger. MU logging tools. 01:15-02:15 1.00 LOG ELOG PROD RIH wI CMR to 7620'. Log up to 7480'. Tool stuck. 02:15 - 08:45 6.50 LOG ELOG PROD Work tool free. Log up to 7406'. Tool stuck. Worked tool free. Log up to 7366'. Tool stuck. Worked tool free. 08:45 - 10:45 2.00 LOG ELOG PROD Log up to 6770. POH with CMR tool. 10:45 - 12:00 1.25 LOG RURD PROD LD tools. RD Schlumberger. 12:00 - 12:30 0.50 LOG TRIP PROD MU BHA # 7 (clean out-wiper trip). 8 1/2" bit, nb stab, nmdc, stab, 4 hwdp, jars, 25 hwdp. 12:30 -13:15 0.75 LOG TRIP PROD Trip in hole fl 946' to 2487'. pu wt 97k, so wt 100k 13:15 -14:15 1.00 RIGMNT RSRV PROD Slip and cut 110' drilling line. 14:15 - 17:00 2.75 LOG TRIP PROD TIH f/2487'-3997'. Wash @ 2796'-2886', 3160'-3250', 3903'-3996' 17:00 - 18:30 1.50 LOG TRIP PROD Con't trip in f/3996' to 6045', fill pipe, con't to 7285'. Set down @ 7285'. 18:30 - 19:30 1.00 LOG TRIP PROD Wash and ream @ 7285' wI 100 rpm, 125 spm(530gpm)/1600 psi. Wash and ream 7285' to 7440'. 19:30 - 20:30 1.00 LOG TRIP PROD Continue in hole to TO @ 8045'. PU wt 200k, SO wt 188k, Rot wt 195k 20:30 - 22:00 1.50 LOG CIRC PROD Circ and condition mud and hole f/logs. CBU, rotate and recip fl 8045' to 8000', pump 25 bbl hi vis sweep, circ sweep out of hole. Circ 125spm (530gpm)/1600 psi. Max gas units 1470. Background 80-100 units. PU wt 202k, SO wt 206k, Rot wt 206k, torque 2k, recip wI 100 rpm. SPR. Monitor well. OK. 22:00 - 00:00 2.00 LOG TRIP PROD Pull 10 stands. Tight@ 7571' & 7445', work through both a couple of times, OK. Monitor well. Pump dry job, blow down top drive. POOH. 3/2/2005 00:00 - 02: 15 2.25 LOG TRIP PROD POH f/7065' to 3300'. No hole problems. Calc fill 37.5 bbls, actual 39.7bbls 02: 15 - 03:00 0.75 LOG CIRC PROD Circ hole clean. 530 gpm at 1100 psi. Blow down top drive. 03:00 - 05:00 2.00 LOG TRIP PROD POH f/3300' to 3144'. Hole tight and swabbing. Back reamed to 3081'. Attempt to pull without pump. Hole tight and swabbing. Back ream. Hole packed off at 3047'. Regained circulation. Back reamed to 2890'. Attempt to pull without pump. Hole swabbing. Back reamed to 2524'. POH to 2485'. Monitor well. 05:00 - 08:30 3.50 LOG TRIP PROD RIH to and tag up at 8011'. Fill pipe every 20 stds. 08:30 - 08:45 0.25 LOG CIRC PROD Fill pipe. Wash and ream from 8011' to 8045'. Hard fill from 8030' to 8045'. 08:45 -10:15 1.50 LOG CIRC PROD Circ hole clean. Large amount of clay and shale in returns. Increase mud wt to 10.5 ppg. Spot 40 bbl resinex pill across LeU and HRZ. 10:15 -12:00 1.75 LOG TRIP PROD POOH 10 stands fl 8045' to 7166', checking fl proper fill. OK. 12:00 -15:00 3.00 LOG TRIP PROD Pump dry job, POOH f/7166' to 2491'. No problems. 15:00 - 16:00 1.00 LOG TRIP PROD Monitor well f/15 min, static. POOH f/2491' to 946'. Printed: 3/17/2005 1 :20:00 PM · ConocoPhillips Alaska APR 2 9 2005 Ppge120f14 Op.erations Summary &ßc:afi\ Gas Cum., !;r¡mmi$$IGf1 Legal Well Name: KOKODA #1 Common Well Name: KOKODA #1 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 3/2/2005 16:00 - 17:15 1.25 LOG TRIP PROD 17:15 -18:30 1.25 LOG RURD PROD 18:30 - 00:00 5.50 LOG ELOG PROD 3/3/2005 00:00 - 00:30 0.50 LOG PULD PROD 00:30-01:15 0.75 LOG PULD PROD 01:15-05:00 3.75 LOG ELOG PROD 05:00 - 06:00 1.00 LOG PULD PROD 06:00 - 07:00 1.00 LOG PULD PROD 07:00 - 08:00 1.00 LOG ELOG PROD 08:00 - 09: 15 1 .25 LOG PULD PROD 09:15 - 12:00 2.75 LOG ELOG PROD 12:00 - 14:45 2.75 LOG ELOG PROD 14:45 - 15:30 0.75 LOG PULD PROD 15:30 - 16:30 1.00 RIGMNT RSRV PROD 16:30 - 18:15 1.75 LOG OTHR PROD 18:15-18:45 0.50 LOG RURD PROD 18:45 - 21: 15 2.50 LOG OTHR PROD 21:15-21:45 0.50 ABAND PULD ABANDN 21 :45 - 23:00 PULD ABANDN 23:00 - 00:00 1.00 ABAND RURD ABANDN 3/4/2005 00:00 - 02:00 2.00 CEMEN PULD ABANDN 02:00 - 02:15 0.25 CEMEN RURD ABANDN 02: 15 - 03:00 0.75 CEMEN TRIP ABANDN 03:00 - 03:45 0.75 CEMEN CIRC ABANDN 03:45 - 04:45 1.00 CEMEN TRIP ABANDN 04:45 - 05:30 0.75 CEMEN CIRC ABANDN 05:30 - 06:45 1.25 CEMEN TRIP ABANDN 06:45 - 07:30 0.75 CEMEN CIRC ABANDN 07:30 - 08:15 0.75 CEMEN TRIP ABANDN 08: 15 - 08:45 0.50 CEMEN CIRC ABANDN 08:45 - 09:30 0.75 CEMEN TRIP ABANDN 09:30 - 11: 15 1.75 CEMEN CIRC ABANDN 11:15 -11:30 0.25 CEMEN TRIP ABANDN 11 :30 - 12:00 0.50 CEMEN CIRC ABANDN 12:00 - 14:30 2.50 CEMEN CIRC ABANDN 14:30 - 15:00 0.50 CEMEN PLUG ABANDN Start: 2/7/2005 Rig Release: 3/6/2005 Rig Number: Spud Date: 2/16/2005 End: 3/6/2005 Group: Description ofQperations POOH, stand back HWDP and jars. Break bit, LID BHA #7. Calc fill 75 bbls, actual 81 bbls. Note: Functioned top & bottom rams and annular and blind rams. PJSM wI Schlumberger. RU Schlumberger logging tools. Surface test tools. OK. Schlumberger WL RIH wI rotary core tools to 7680', take 30 cores, POOH. Schlumberger LID rotary core tools, recovered 28 of 30 cores. Schlumberger make up Sonic I FMI toolstring. Schlumberger WL, RIH wI Sonic I FMI toolstring, log f/8040' to 2000', POOH. Schlumberger LID Sonic I FMI toolstring. Schlumberger MU rotary core tools, check tools @ surface. Schlumberger RIH to 2400' wI rotary core tools, tool failure. POOH. Schlumberger trouble shoot tools, change out coring tool. Schlumberger RIH to 7600' wI rotary core tools. Schlumberger Rotary sidewall core 7560' to 7235'. POOH. Schlumberger LID 13 of 14 cores, and LID logging tools. SeNice top drive and DW. Evaluate logs, wait on orders. RID Schlumberger Wireline. Evaluate logs. Wait on orders. PU clean out BHA from pipe shed. Break off (2) 8 1/2" stab's, NMDC, LID same. TIH w/10 stands HWDP wI jars fl derrick. LID 5" HWDP and jars. Note: Functioned blind rams and upper pipe rams. RU 3 1/2 tongs to run 3 1/2" EUE 9.3 ppf L-80 stinger on 5" DP. PJSM. PU and RIH wI 32 jts 3 1/2" tbg for cement stinger. RD tbg equipment. RIH wI 5" DP to 2480'. Note: Functioned top & bottom pipe rams Circ and condition mud. Stage up to 530 gpm, 600 psi, circ 3500 strokes (352 bbls). RIH wI 5" DP to 3975'. Circ and condition mud. Stage up to 530 gpm, 800 psi, circ 4000 strokes (402 bbls). RIH wI 5" DP to 6018'. Circ and condition mud. Stage up to 530 gpm, 1080 psi, circ 4000 strokes (402 bbls). RIH wI 5" DP to 7000'. PU wt 143k, SO wt 150K Circ and condition mud. Circ @ 40 spm, 170 gpm, circ 1145 strokes (115 bbls) RIH wI 5" DP to 7900'. Calc displacement fl trip 56.25 bbls, actual 57.75 bbls. PU wt 159k, SO wt 150k. Circ and condition mud. Spot 25 bbls hi-vis pill (gel 300+ vis) POOH to 7700'. Circ and condition mud. Circ @ 530 gpm, 1275 psi. Circ and condition mud. Circ @ 510 gpm, 1200 psi. PU wt 155k, SO wt 163k Dowell mix and pump cement plug #1. Pump 20 bbls water ahead, mix and pump @ 5 bpm 33 bbls (160 sx) class G wI additives @ 15.8 ppg, follow wI 4 bbls water. Rig displace balanced plug @ 10.5 bpm w/1158 strokes (116.6 bbls) 10.5 ppg mud. Initial 1150 psi, final 1500 psi. Printed: 3/17/2005 1:20:00 PM ConocoPhillips Alaska APR 2 9 Z005 Operations Summary ReDort . A1askã 1)11 & Gas Cons. Commission nc orage Spud Date: 2/16/2005 End: 3/6/2005 Group: Slowed down to 5.4 bpm @ 500 psi fllast 5 bbls. POOH slow fl 7688' to 7317'. Circ@ 130 spm, 550 gpm wI 1300 psi. Dowell mix and pump cement plug #2. Pump 20 bbls water ahead, mix and pump @ 5 bpm 33 bbls (160 sx) class G wI additives @ 15.8 ppg, follow wI 4 bbls water. Rig displace balanced plug @ 10.5 bpm wI 1089 strokes (109.7 bbls) 10.5 ppg mud. Initial 1150 psi, final 1410 psi. Slowed down to 5.4 bpm @ 500 psi fllast 5 bbls. 0.75 CEMEN TRIP ABANDN POOH slowfl7317' to 6915'. 0.75 CEMEN CIRC ABANDN Circ @ 120 spm, 510 gpm wI 1200 psi. 0.75 CEMEN PLUG ABANDN Dowell mix and pump cement plug #3. Pump 20 bbls water ahead, mix and pump @ 5 bpm 33 bbls (160 sx) class G wI additives @ 15.8 ppg, follow wI 4 bbls water. Rig displace balanced plug @ 10.5 bpm w/1 020 strokes (102.7 bbls) 10.5 ppg mud. Initial 1100 psi, final 1330 psi. Slowed down to 5.4 bpm @ 500 psi fl final 5 bbls. POOH slow fl 6915' to 6500'. Circ @ 120 spm, 510 gpm w/1125 psi. Circ 2 BU (6200 strokes)(624 bbls) Monitor hole,POOH f/6500' to 4685'. Circ @ 70 spm, 300 gpm wI 350 psi while WOC. Circ @ 4685', 70 spm, 300 gpm wI 350 psi while woe. RIH fl 4685' to 6451, break circ @ 40 spm wI 21 0 psi. PU wt 135k, SO wt 142k Circ down f/6451' @ 4 bpm, tag top of plug w/10k while circ @ 4 bpm, 250 psi. Witness of tag by BLM Petroleum Engineering Technician Tim Lawlor. Blow down top drive. POH wI 5" DP to 1004'. RU tbg tongs and elevators. POH LD 23 jts 3 1/2" tbg. Std back 3 stds in derrick. RD tbg equipment. Clear floor. PJSM on MU and running of 9 5/8" cement retainer. MU and RIH w/9 5/8" Baker "K-1" cement retainer to 2416' (Shoe @2505'). Set Baker model "K-1" cement retainer @ 2416'. Establish inj rate of 900 psi wI 1.25 bpm. broke down wI 24 strokes pumped. PU wt 75K, SO wt 78k. 0.25 ABAND CIRC ABANDN Circ @ 210 gpm wI 300 psi. 1.50 CEMEN PUMP ABANDN Dowell mix and pump cement plug #4. Pump 10 bbls water ahead, mix and pump @ 5 bpm 20 bbls (97 sx)class G wI additives @ 15.8 ppg, follow w/4 bbls water. Stab into retainer. Rig displace @ 3.5 bpm, unsting @ 331 strokes (34.8bbls) 10.5 ppg mud pumped. Witness of setting retainer & pumping cement by BLM rep Tim Lawlor. Calculated 110' cement in OH below shoe using 20% excess, 89' below retainer in csg, 53' on top of retainer. POOH f/2416' to 525'. Pull slow and allow 4 bbls of cement to lay on top of 9 5/8" Baker "K-1" cement retainer. (53' inside of 9 5/8" 40 ppf). Circ and spot gel pill spacer @ 525'. POOH to 310'. Displace 10.5 ppg mud in hole to 8.34 ppg water. Con'! POOH, LID Baker running tool. NID BOPE. Remove FMC casing head. RIH w/10 jts total, 310' of 31/2" 9.3 ppf, L-80, EUE tubing for surface plug. Dowell miø< and pump cement plug #5. Mix and pump @ 3 bpm 30.4 bbls (183 sx) AS1 @ 15.7 ppg. Returns measured @ 15.6 ppg in cellar. . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: KOKODA #1 KOKODA #1 ROT - DRILLING n1334@ppco.com Doyon 141 Date Prom - To Hours Code Sub Phase Code 3/4/2005 14:30 - 15:00 0.50 CEMEN PLUG ABANDN 15:00 - 15:30 0.50 CEMEN TRIP ABANDN 15:30 - 16:30 1.00 CEMEN CIRC ABANDN 16:30 - 17:00 0.50 CEMEN PLUG ABANDN 17:00 - 17:45 17:45 - 18:30 18:30 -19:15 19:15 - 20:00 0.75 CEMEN TRIP ABANDN 20:00 - 20:30 0.50 CEMEN CIRC ABANDN 20:30 - 21 :45 1.25 CEMEN TRIP ABANDN 21 :45 - 00:00 2.25 CEMEN CIRC ABANDN 3/5/2005 00:00 - 02:00 2.00 CEMEN CIRC ABANDN 02:00 - 03:30 1.50 CEMEN TRIP ABANDN 03:30 - 04:00 ABANDN 04:00 - 07:00 3.00 ABAND ABANDN 07:00 - 07:30 0.50 ABAND ABANDN 07:30 - 09:30 2.00 ABAND ABANDN 09:30 - 10:00 0.50 ABAND ABANDN 10:00 - 10:30 0.50 ABAND ABANDN 10:30 - 12:45 2.25 ABAND ABANDN 12:45 - 13:00 13:00 - 14:30 14:30 - 15:15 0.75 CEMEN TRIP ABANDN 15:15 -16:00 0.75 CEMEN TRIP ABANDN 16:00 - 16:45 0.75 CEMEN TRIP ABANDN 16:45 - 19:15 2.50 WELCT NUND ABANDN 19:15 - 20:45 1 .50 CEMEN TRIP ABANDN 20:45 - 21:15 0.50 CEMEN PUMP ABANDN Start: 2/7/2005 Rig Release: 3/6/2005 Rig Number: Description of Operations Printed: 3/17/2005 1:20:00 PM ConocoPhillips Alaska RECE\VED Operations Summary Report ~PR 2 9 20G5 legal Well Name: KOKODA #1 Common Well Name: KOKODA #1 Event Name: ROT - DRilLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 3/5/2005 20:45 - 21:15 0.50 CEMEN PUMP ABANDN 21:15-21:45 0.50 CEMEN TRIP ABANDN 21 :45 - 22:00 0.25 CEMEN PUMP ABANDN Start: Rig Release: Rig Number: ìtìQf\ ('1'.' &·':·B't ' ! .... M$$k3 vI! dO'. . . " .. . Þ.~19ð~~te: 2/16/2005 2/7/2005 End: 3/6/2005 3/6/2005 Group: Description of Operation$ 22:00 - 22:30 22:30 - 00:00 Witness of job by BLM Petroleum Enginerring Technician Tim Lawlor. Sucked returns fl cellar and washed up to cellar. POOH w/3 1/2" tubing. No water used to flush pipe. Dowell mix and pump cement to top off pipe displacement of 1 bbl (14'). Mix and pump @ 3 bpm, 6.27 bbls (38 sx) AS1 @ 15.7 ppg. Witness of job by BLM Petroleum Enginerring Technician Tim Lawlor. Sucked returns fl cellar and washed up to cellar. 0.50 CEMEN RURD ABANDN RID, blow down cementing lines. 1.50 ABAND OTHR ABANDN LID 21 stands of 5" dp fl derrick using mouse hole. Cleaning pits and rock washer. Note: At 0330 hrs 3/6/2005, hard cement 2 1/2" below top of starting head. LID 58 stands of 5" dp fl derrick using mouse hole. Cleaning pits and rock washer. PJSM on upcoming rig move. Fluids removed fl rock washer and pits @ 0300 hrs. Remove drill pipe fl shed. Blowing down rig. Disconnect seNice lines & electric. Note: At 0330 hrs 3/6/2005, hard cement 2 1/2" below top of starting head. Rig released fl 5 mile move fl Kokoda #1 to Kokoda #5 @ 0400 hrs 3/6/2005. 3/6/2005 00:00 - 03:00 3.00 ABAND OTHR ABANDN 03:00 - 03:15 0.25 ABAND OTHR ABANDN 03: 15 - 04:00 0.75 ABAND OTHR ABANDN 04:00 - ABAND ABANDN Printed: 3/17/2005 1 :20:00 PM . . RECE/VECi APR .2 9 2005 Alaska Oil & Gas Ar¡¡;híJiì:){lIJ Removed covering from well and cellar. Removed cellar. Excavated arou.nã well head down to 4' below tundra level. Kokoda # 1 Surface P&A 3-13-05 Secured site with barricades, conducted pre-job safety meeting, filled out confined space entry permit. Drilled Y2" hole into side of 16" conductor and drained water from outer annulus. Followed procedure for Hot Work Permit, 0- LEL. Cut 16" pipe and 9-5/8" pipe 3' below tundra level. 9-5/8" casing full of cement (solid). The annulus between the 16" and the 9-5/8" was full of water. Lowered 1" pipe down annulus and tagged top of cement at 31 ft. Pulled 1" pipe out. Secured area with barricades. Put heater on well bore to prevent from freezing. Set up equipment to do top job from 31 f t. 3-15-05 Ran 1" pipe down 16" X 9-5/8" annulus to 31 ft (TOC). NU pump truck, pumped 6.2 bbls 10.7 ppg ARTICSET Lite cememt from 31 ft picking up returns with vac truck. Good clean cement to surface. Shut down rinsed lines, secure site and wait on cement 24 hrs. 3-16-05 Cleared blown snow out of hole. The heater left on the hole had melted the blowing snow and had approximately 3' of water in bottom of hole. Vac truck sucked out standing water. Cleared snow off pipe. Confirmed hard cement at surface. BLM (Tim / Lawler) witness hard cement at surface. Welded cover plate on top of 16" pipe with 'l4" weep hole over all casing strings with the following information bead welded into the top: ConocoPhillips Alaska, Inc. Kokoda # 1 PTD# 204-253 API # 50-279-20011-00 Back filled cellar with gravel as needed. Cleared ice pad location and demob all materials and equipment. . Halliburton Global . Company: Engineer: Tool: Tied-to: Field: Zone 5 (Nad 83) Exploration Map System:US State Plane Coordinate System 1983 Geo Datum: GRS 1980 Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 5 Well Centre bggm2004 Site: Kokoda Site Position: Northing: 5972477.00 ft Latitude: 70 20 4.687 N From: Map Easting: 1738386.00 ft Longitude: 153 12 18.693 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.00 deg Well: Kokoda #1 Slot Name: Kokoda Well Position: +N/-S-18267.34 ft Northing: 5954313.09 ft Latitnde: 70 17 4.985 N +E/-W 7674.82 ft Easting : 1746298.08 ft Longitude: 153 8 35.105 W Position Uncertainty: 0.00 ft Wellpath: Kokoda #1 Drilled From: Well Ref. Point 50279200110000 Tie-on Depth: 24.80 ft Current Datum: Kokoda #1 : Height 161.70 ft Above System Datum: Mean Sea Level Magnetic Data: 2/11/2005 Declination: 22.50 deg Field Strength: 57424 nT Mag Dip Angle: 80.37 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 24.80 0.00 0.00 262.52 Survey Program for Definitive Wellpath Date: 4/12/2005 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 232.15 7963.41 Kokoda #1 (232.15-7963.41) MWD MWD - Standard Survey 24.80 0.00 0.00 24.80 -136.90 0.00 0.00 5954313.09 1746298.08 TIE LINE 232.15 0.62 56.61 232.15 70.45 0.62 0.94 5954313.72 1746299.01 MWD 318.48 0.44 40.12 318.47 156.77 1.13 1.54 5954314.24 1746299.60 MWD 412.26 0.19 42.97 412.25 250.55 1.52 1.88 5954314.63 1746299.94 MWD 501.39 0.19 333.07 501.38 339.68 1.76 1.91 5954314.87 1746299.97 MWD 589.56 0.36 331.59 589.55 427.85 2.13 1.71 5954315.24 1746299.76 MWD 683.05 0.36 306.18 683.04 521.34 2.56 1.34 5954315.67 1746299.38 MWD 770.17 0.47 331.03 770.16 608.46 3.04 0.94 5954316.14 1746298.98 MWD 862.24 0.31 313.09 862.22 700.52 3.54 0.58 5954316.63 1746298.61 MWD 953.22 0.44 14.91 953.20 791.50 4.04 0.49 5954317.14 1746298.51 MWD 1044.36 0.47 354.11 1044.34 882.64 4.75 0.54 5954317.85 1746298.55 MWD 1135.99 0.38 348.80 1135.97 974.27 5.42 0.44 5954318.52 1746298.45 MWD 1228.91 0.26 332.45 1228.88 1067.18 5.91 0.29 5954319.01 1746298.28 MWD 1322.04 0.09 281.93 1322.01 1160.31 6.12 0.12 5954319.21 1746298.11 MWD 1415.02 0.14 274.18 1414.99 1253.29 6.14 -0.07 5954319.23 1746297.92 MWD 1505.99 0.12 89.67 1505.96 1344.26 6.15 -0.08 5954319.24 1746297.91 MWD 1601.06 0.31 35.17 1601.03 1439.33 6.36 0.16 5954319.45 1746298.15 MWD 1694.13 0.20 325.53 1694.10 1532.40 6.70 0.22 5954319.79 1746298.20 MWD 1787.01 0.19 280.74 1786.98 1625.28 6.86 -0.03 5954319.95 1746297.96 MWD . Halliburton Global . RECEIVED APR 2 9 Z005 1879.99 0.25 274.89 1879.96 1718.26 6.91 -0.38 5954319.99 1746297.60 MWD 1972.14 0.28 231.80 1972.11 1810.41 6.79 -0.76 5954319.86 1746297.23 MWD 2065.11 0.19 207.52 2065.08 1903.38 6.51 -1.01 5954319.58 1746296.98 MWD 2158.17 0.17 308.65 2158.14 1996.44 6.46 -1.19 5954319.53 1746296.80 MWD 2249.93 0.09 253.96 2249.90 2088.20 6.52 -1.36 5954319.59 1746296.63 MWD 2345.76 0.14 254.66 2345.73 2184.03 6.47 -1.55 5954319.54 1746296.44 MWD 2407.62 0.31 302.05 2407.59 2245.89 6.54 -1.76 5954319.60 1746296.23 MWD 2521.53 0.14 73.15 2521.50 2359.80 6.74 -1.89 5954319.81 1746296.10 MWD 2615.18 0.17 67.35 2615.15 2453.45 6.83 -1.65 5954319.90 1746296.33 MWD 2705.39 0.09 301.61 2705.36 2543.66 6.92 -1.59 5954319.99 1746296.39 MWD 2800.68 0.36 311.70 2800.65 2638.95 7.16 -1.88 5954320.22 1746296.10 MWD 2894.44 0.33 351.42 2894.41 2732.71 7.62 -2.14 5954320.68 1746295.84 MWD 2985.93 0.25 0.21 2985.89 2824.19 8.08 -2.17 5954321.14 1746295.79 MWD 3078.99 0.22 285.24 3078.95 2917.25 8.33 -2.35 5954321.39 1746295.62 MWD 3172.18 0.76 279.43 3172.14 3010.44 8.48 -3.13 5954321.52 1746294.83 MWD 3263.32 0.76 282.90 3263.27 3101.57 8.71 -4.31 5954321.74 1746293.64 MWD 3357.88 0.84 284.13 3357.82 3196.12 9.02 -5.60 5954322.03 1746292.36 MWD 3451.88 0.86 284.50 3451.81 3290.11 9.37 -6.95 5954322.36 1746291.00 MWD 3542.68 1.21 258.83 3542.60 3380.90 9.35 -8.55 5954322.32 1746289.40 MWD 3634.24 1.19 258.77 3634.14 3472.44 8.98 -10.43 5954321.92 1746287.53 MWD 3728.54 1.36 262.81 3728.41 3566.71 8.65 -12.50 5954321.56 1746285.46 MWD 3820.01 1.06 258.64 3819.86 3658.16 8.35 -14.41 5954321.23 1746283.56 MWD 3910.41 0.45 256.62 3910.26 3748.56 8.10 -15.57 5954320.97 1746282.40 MWD 4007.57 0.80 267.32 4007.41 3845.71 7.98 -16.62 5954320.83 1746281.35 MWD 4100.65 0.57 280.14 4100.48 3938.78 8.03 -17.73 5954320.87 1746280.24 MWD 4193.62 0.69 264.30 4193.45 4031.75 8.06 -18.74 5954320.88 1746279.23 MWD 4286.71 0.69 281.40 4286.53 4124.83 8.11 -19.85 5954320.92 1746278.12 MWD 4379.82 0.93 273.13 4379.63 4217.93 8.26 -21.15 5954321.05 1746276.82 MWD 4470.30 1.11 279.83 4470.10 4308.40 8.45 -22.75 5954321.22 1746275.22 MWD 4564.86 1.00 272.05 4564.64 4402.94 8.64 -24.47 5954321.38 1746273.49 MWD 4653.21 1.03 284.95 4652.98 4491.28 8.87 -26.01 5954321.59 1746271.95 MWD 4750.58 0.67 289.50 4750.34 4588.64 9.29 -27.39 5954321.99 1746270.56 MWD 4844.04 0.66 300.32 4843.79 4682.09 9.74 -28.37 5954322.43 1746269.58 MWD 4938.27 0.40 282.31 4938.02 4776.32 10.09 -29.16 5954322.76 1746268.78 MWD 5028.42 0.25 264.38 5028.16 4866.46 10.13 -29.67 5954322.80 1746268.28 MWD 5122.68 0.49 248.37 5122.42 4960.72 9.96 -30.25 5954322.63 1746267.70 MWD 5215.22 0.72 266.34 5214.96 5053.26 9.78 -31.19 5954322.43 1746266.75 MWD 5308.50 0.94 280.96 5308.23 5146.53 9.89 -32.53 5954322.52 1746265.42 MWD 5398.81 0.99 290.41 5398.53 5236.83 10.30 -33.99 5954322.91 1746263.95 MWD 5493.41 1.02 281.72 5493.11 5331.41 10.76 -35.58 5954323.35 1746262.36 MWD 5586.28 1.02 272.00 5585.97 5424.27 10.96 -37.21 5954323.52 1746260.72 MWD 5676.19 1.22 265.48 5675.86 5514.16 10.91 -38.97 5954323.45 1746258.97 MWD 5769.61 0.87 242.99 5769.26 5607.56 10.51 -40.59 5954323.02 1746257.35 MWD 5864.33 0.87 227.02 5863.97 5702.27 9.69 -41.76 5954322.19 1746256.19 MWD 5957.80 0.84 226.10 5957.43 5795.73 8.73 -42.77 5954321.22 1746255.19 MWD 6050.98 1.05 233.62 6050.60 5888.90 7.75 -43.95 5954320.22 1746254.03 MWD 6143.65 1.33 246.87 6143.25 5981.55 6.83 -45.62 5954319.27 1746252.37 MWD 6236.59 1.25 247.69 6236.17 6074.47 6.02 -47.55 5954318.44 1746250.45 MWD 6329.17 1.17 252.40 6328.73 6167.03 5.35 -49.39 5954317.74 1746248.63 MWD 6421.74 0.94 249.55 6421.28 6259.58 4.80 -51.00 5954317.17 1746247.02 MWD 6513.53 0.70 237.36 6513.06 6351.36 4.23 -52.18 5954316.59 1746245.85 MWD 6593.23 1.03 226.08 6592.75 6431.05 3.47 -53.10 5954315.81 1746244.94 MWD . Halliburton Global . 6701.17 1.18 225.17 6700.67 6538.97 2.02 -54.59 5954314.34 1746243.47 MWD 6795.55 0.93 221.91 6795.04 6633.34 0.76 -55.79 5954313.06 1746242.29 MWD 6886.42 0.88 231.31 6885.89 6724.19 -0.22 -56.83 5954312.07 1746241.26 MWD 6979.25 0.67 232.38 6978.72 6817.02 -1.00 -57.82 5954311.27 1746240.29 MWD 7073.60 0.69 226.68 7073.06 6911.36 -1.73 -58.67 5954310.54 1746239.45 MWD 7166.54 0.57 256.98 7165.99 7004.29 -2.22 -59.52 5954310.04 1746238.60 MWD 7259.54 0.62 228.48 7258.99 7097.29 -2.65 -60.35 5954309.59 1746237.78 MWD 7352.26 1.03 227.89 7351.70 7190.00 -3.55 -61.34 5954308.68 1746236.80 MWD 7439.83 0.93 224.36 7439.26 7277.56 -4.58 -62.42 5954307.63 1746235.73 MWD 7536.35 1.00 218.92 7535.76 7374.06 -5.80 -63.50 5954306.40 1746234.67 MWD 7629.46 0.86 216.69 7628.86 7467.16 -6.99 -64.43 5954305.20 1746233.76 MWD 7722.87 0.76 228.76 7722.26 7560.56 -7.96 -65.31 5954304.21 1746232.89 MWD 7814.33 0.86 231.57 7813.71 7652.01 -8.79 -66.31 5954303.37 1746231.91 MWD 7907.68 0.51 266.35 7907.05 7745.35 -9.25 -67.27 5954302.90 1746230.95 MWD 7963.41 0.38 295.43 7962.78 7801.08 -9.18 -67.69 5954302.95 1746230.54 MWD /' 8045.00 0.38 295.43 8044.37 /' 7882.67 -8.95 -68.17 5954303.18 1746230.04 MWD RECE~' l'- APR 2 9 Alaska Oil & Gas i..,\h;,:J¡C".,'d(W AnchoraQ'i: . E RIPTlON DE IPTlON DRAWN PER K05015ACS NOTES: 1. COORDINATES OBTAINED BY GPS RAPID STATIC METHODOLOGY, USING LEICA SERIES 500 RECEIVERS. DATA PROCESSED BY NATIONAL GEODETIC SURVEY "ON-LINE POSITIONING USER SERVICE" (OPUS), RESOLVED FROM THE FOLLOWING BASE STATIONS: A. PBOC (PRUDHOE BAY CORS) B. FAIR (GILMORE CREEK OBS CORS) C. CENA (CENTRAL ALASKA CORS) 2. HORIZONTAL DATUM IS NAD83, ZONE 5, ALASKA. 3. VERTICAL DATUM IS ORTHOMETRIC REFERENCED TO GEOID 99. 4. ALL DISTANCES ARE TRUE. N SARROW ~'" + GEAl..iFCRT SEA 'Y).~.. // )~)\ ~'" ~ ,.,-~"fr.-'" -J ~ ~'- '\. ~' t '~ {,H!RRISOt\ BAY PRUOHOE BAY J Teshèkpuk"",' ~-~. ¡ ø )LCke I C>~ NPRA ~ø KOKODA 1 ~ ( KOKODA 1 LOCATED WITHIN PROTRACTED SEC. 27 T 11 N, R 5 W, UMIAT MERIDIAN. 295' r.N.L.. 629' F. W.L. LAT = 70'17'05.101" N LONG = 153'08'34.999" W Y = 5,954,313.09' X = 1,746,298.08' TOP CONDUCTOR ELEV.= 137.05' TOP OF RIG PAD ELEV. = 136.9' GROUND ELEVATION= 133.6'. VICINITY MAP NOT TO SCALE RECEI\/ED APR 2 9 2005 / N Alaska Oil & Gas Cons. CommissÎon ~~~'D~ ~~ cr' _ ... ",,,\~.....,,,,,,,,,,,~,, . r ~.:r..... '" t.... . -.J.' ... "".... . .... .... , ¡ J:.¡ 49th \* , " ·····:·······························,····\·····1 ~ ~ ~I.....'....I..........I..........I...I..........- P: ;Q . . Q:: ill i! ~ \. BRIAN G. MANGOLD l Ell 1'J&. """-. .. .+ /.,# . ~ ó), '" LS-8626 ..' ~- · .... ~ +. .+ .;)-.. . ",.. 1>..i' ..... .... '3 ~ 'IIIIf. '"/\ -" ,,- C"\. ~ .... v A ............ ~v.. -_.. 7ibF"tSSION~\' \, ~.. ""~~'~.~ SCALE: 1" = 200' 21122 -+ 28 27 Jj ,. ---í , ' --\ \ ) ----- , - - \' ~ _____ / ----- - '1-.0'1-. of;) to. \ , , SURVEYOR'S CERTlFICA TE \ , I HEREBY CERTIFY THA T I AM PROPERL Y REG/STEREO AND LICENSED TO PRACTICE LAND SURVEYING IN THE STA TE OF ALASKA AND THA T THIS PLA T REPRESEN TS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THA TALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBRUARY 13, 2005. \ \--- þ.Q - / ~\~ ~ / ----- / , , 629' \~\~S þ.Q ~ \Ct- f? 0.. t- -0 0' 00 ~1 Øl LOUNSBURY lie ASSOCIATES. INC. SURVEYORS ENGIN1!I!RS PLANNERS , ConocJPhillips Alaska, Inc. CADD FILE NO. DRAWING NO: LK601D592 2 UNIT: M1 MODULE: XXXX KOKODA 1 / EXPLORATORY WELL CONDUCTOR ASBUIL T LOCATION PART: AREA: 00 REV: 1 CEA-M1 XX-501 D592 1 OF 1 PRESSURE INTEGRITY TEST Jo l\-- ~ CONOCOPHILLlPS Alaska, Inc. ;;ts Well Name: T f(OKODA #1 I Rig: Doyon 141 Date: 2/21/2005 Volume Input Volume/Stroke Pump Rate: Pump I... : .;.;.;.;.:.:.;.:.;.:.:.:.:.:.:.:.:.: Drilling Supervisor: NiGk SG;;:j¡:~síP¡;,ter WIls(¡¡"¡ w.ed: #1 Mud Pump ................. :!I!::i:I:!li:I:!~'I~1 Strokes .... II~~II~II Bbls/Strk .... Strkjmin ... Type of Test: I Casing Shoe Test LOT/AT I ...1 Pumping down I annulus and DP. I... .:.:.:.:.:.:.:.:.;.;.:.:.:.:.:.:.:.: Casin Test Pressure InteQritv Test Hole Size: 112-1/4" I... Casing Shoe Depth I Hole Depth Pumpina Shut-in Pumpina Shut-in RKB-CHF:T 28.01Ft 2,505 I Ft-MDI 2,5051 Ft-TVDI I 2.5301 Ft-MD I 2,5301 Ft-TVD Strks psi Min psi Strks psi Min psi 19-5/8" 1...1 ...................., .................. CasinQ Size and Description: 40#/Ft L-80 BTC ':! 125 ::::25.0a. }}}}~:::::::2~ :::~://mt2~ '$ØØ 0 0 ..,...". . """"" . . '" :::::::::::::::::::, ,:, ,':: Casina Test Pressure IntearitvTest 4 290 1 }25.P.a. ::::::::::::::::::::::::4.: ~~:~))J'Hia 0.25 ··SOo. .:.:.:.:-:.:.:.:-:. :,' :::::::::::::::::::, ,,:, "':.: Mud Weight: 9.$ Mud Weight: 9.B - 2 ~:~:2ø.o.Ø (~::(:)))ß.: )))~(&:!iìa. 0.5 "'SOO ppg ppg :~:~:~:~:r~:r., "': ,,:,.~ :~~~~ßØ-ø. t::))m/?t )))):IØ-º ····SUo; Mud 10 min Gel: 18.0 Lb/100 Ft2 Mud 10 min Gel: 17.0 Lb/100 Ft2 ::::::::::::::::~:'- }}iß.Y$.: 3 1 ......... . :::::::;:;:;;;:;:;:,:",:,:.:,,: Test Pressure: 2,500 psi Rotating Weight: 10.000 Lbs :/::/wnuJ \m:m~ö.o: 4 ~m~$.oø. 1 .5 (> '." Rotating Weight: Lbs BlockslTop Drive Weight: 34,000 Lbs ):):42 \4JaiO¡ 5 }2.5.0a. 2 " BlockslTop Drive Weight: 35,OÜO Lbs Desired PIT EMW: 16.0 ppg :\:))44- ~~~~4~3o.0: 6 /'2500. 2.5 (\$J'¡PQ Estimates for Test: 1.9 bbls Estimates for Test: 808 psi 0.6 bbls :::m:W:\4ø- .::::J4$p.: 7 \~$ø.º 3 ///\:~¡$.ø.ø 1...1 ... :))))1:1 mmH~~~¡ 8 ::::25.0a. 3.5 ::::~:::~:::~~¡/s.ô.Q EMW = Leak-off Pressure + Mud Weight = 800 PIT 15 Second :\:::):n~ø. \4~$.aiP.¡ 9 ~Œ500. 4 :::)($.PQ 0.052 TVD 0.052 2505 + 9.8 Shut-in Pressure. psi :\\\q~~ ):207$.~ 10 \~$ø.º 4.5 \Hi?\aø.ø x x EMW at 2505 Ft-M D (2505 Ft-TVD) = 15.9 PPQ 800 ~::???:~i :::::1200: 15 :m~$.ø.ø 5 ::::::~::::::::::;ãøø 3000 ~ Lost 0 psi during test, held 1 00% ~ ::::::::::::::::21 )24ð.0 20 ::::iiøø 5.5 :::::::::::::::::::Iij of test pressure. ))))~8 :)2$.00 25 \1500 6 :m:m:m::n~ø I 30 \250a. 6.5 ()))~aQa . ,*,*,Ú~~,*,*,~~i,·······,' 2500 ~ ' . ':-""",*,"''''~Â 7 ))]~QQ " .I 7.5 ?//:/~SUo. " ~ .................. 2000 ,.íZ 8 \::m:\:m$.ø.ø .I 8.5 \:)):aoO; w ". ~ - 9 :\$",SUO; :::J ~ en 1500 .- 9.5 :)):eøQj! ' . en .- w ...- 10 ~ .-. "- - 1000 - II ;Q. ~. ":. .::::;::::::::::~:::::::::::::;::~:::::::.. 1t:Y .I Ii!I .JS 500 " .I I.JØ - - - 0 0 1 2 3 0' 5' 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume -V-CASING TEST - LEAK-OFF TEST 0 PIT Point Pumned Bled Back PumDed Bled Back 2.8 BbTs 2.8 Bbls 0.7 Bbls O.71Bbls Comments: . ~ Page 1 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report .~ WELL NAME I JOB NUMBER I EVENT CODE 24 HRS PROG ¡TMD !TVD DFS I REPT NO. [DATE KOKODA #1 ; ODR 8,045.0 8,045.0 25.00 26 . 3/4/2005 SUPERVISOR I RIG NAME & NO. ! FIELD NAME I OCS NO. I AUTH MD iDAILYTANG !CUM TANG D. Lutrick IG. Rizek n1334(â1ppco.co Dovon 141 I NPRA . 8,078.0 I 0 I . 0 CURRENT STATUS I ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD ! CUM INT ANG WI MUD POOH wI cement strina. 2000' (â1 0600 hrs. 0 ! 0 24 HR FORECAST I DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Circ wI WOC, RIH taq TOC, POOH, run retainer, cmt, POH, cmt, ¡ 3/4/2005 133,334 5,527,009 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE . AUTH. , 15.95 10045962 i LAST SURVEY: DATE TMD INC AZIM [LAST CASING i NEXT CASING ¡LAST BOP PRES TEST 2/28/2005 8,045.00 0.380 295.430 9.625 (in) (â1 2,505.0 (ft)' (in) (â1 (ft) . 2/28/2005 DENSITY(ppg) 10.50 I PP I ECD !10.94! MUD DATAl DAILY COST I 0 I CUM COST I 0 FV I PVIYP I GELS WUHTHP i FCIT.SOL· OILlWAT I %Sand/MBT I Ph/pM I Pf/Mf I CI i Ca i H2S I LIME I ES 62 I 21/24 I 8119 5.01 I 11 I I 0.3/12.5 i 8.91 I 0.05/1 I i 60 i ! I BHA NO. ] 7 I BHA 1 HOLE CONDITIONS I BIT NO. I BHA WT. BELOW JARS STRING WT. UP i STRING WT. DN STRING WT. ROT I TORQUE / UNITS I BHA LENGTH 159 I 150 155 I ft-Ibf i 1,004.70 ITEM DESCRIPTION I NO JTS I LENGTH I O.D. I.D. I CONN SIZE CONN TYPE mule shoe i 1 I 0.47 ! 4.520 2.990 I 3 1/2" eue tbg ! 32 I 1,003.05 I 4.500 2.990 I Crossover I 1 I 1.18 I 6.125 3.000 I PUMP 1 HYDRAULIC DATA NO. I MAKE OF PUMP STROKE (in) I LINER SPM Q I PRESS. TOTAL Q I KILL SPM / PRESSURE I 1 I Emsco 12.000 I 0.00 I 40 260 2 i Emsco 12.000 I 0.00 I 40 250 OPERATIONS SUMMARY FROM TO HOURS CODE ¡TROUBLE SUB PHASE DESCRIPTION 00:00 02:00 2.00 I CEMENT P PULD ABANDN PJSM. PU and RIH wI 32 jts 31/2" tbg for cement stinger. 02:00 02:15 0.25 I CEMENT ~ RURD iABANDNj RD tbg equipment. 02:151 03:00 I 0.75 I CEMENT ~ TRIP I ABANDN! RIH wI 5" DP to 2480'. ! : I ¡ I I Note: Functioned top & bottom pipe rams 03:00 ¡ 03:45 ! 0.75 I CEMENT ~ CIRC I ABANDNI Circ and condition mud. Stage up to 530 gpm, 600 psi, circ 3500 strokes (352 , ! i bbls). 03:45 . 04:45 j 1.00 CEMENT R ITRIP ,ABANDN RIH wI 5" DP to 3975'. 04:45 05:30 I 0.75 I CEMENT ~ CIRC IABANDN Circ and condition mud. Stage up to 530 gpm, 800 psi, circ 4000 strokes (402 , ' I bbls). i 05:30 06:45 1.25 CEMENT ~ ¡TRIP IABANDN: RIH wI 5" DP to 6018'. 06:45 07:30 I 0.75 (CEMENT 4 !CIRC I ABANDNI Circ and condition mud. Stage up to 530 gpm, 1080 psi, circ 4000 strokes (402 ! . bbls).' I 07:30 08:15 0.75 CEMENT ~ TRIP ABANDN RIH wI 5" DP to 7000'. PU wt 143k, SO wt 150K 08:15 ¡ 08:45 i 0.50 CEMENT R CIRC ABANDN Circ and condition mud. Circ @ 40 spm, 170 gpm, circ 1145 strokes (115 bbls) 08:45 ! 09:30 I 0.75 I CEMENT ~ TRIP ABANDN RIH wI 5" DP to 7900'. Calc displacement fl trip 56.25 bbls, actual 57.75 bbls. I , ¡ I I I I PU wt 159k, SO wt 150k. 09:30 11 :15 1.75 . CEMENT ~ !CIRC ABANDN Circ and condition mud. Spot 25 bbls hi-vis pill (gel 300+ vis) 11 :15 11 :30 0.25 CEMENT M TRIP ABANDN POOH to 7700'. 11:30 I 12:00 0.50 CEMENT M ICIRC ABANDNj Circ and condition mud. Circ @ 530 gpm, 1275 psi. 12:00 14:30 2.50 ! CEMENT ~ CIRC ABANDN Circ and condition mud. Circ @ 510 gpm, 1200 psi. PU wt 155k, SO wt 163k 14:30 15:00 : 0.50 I CEMENT ~ IPLUG I ABANDNI Dowell mix and pump cement plug #1. Pump 20 bbls water ahead, mix and I I I I i ,pump @ 5 bpm 33 bbls (160 sx) class G wI additives @ 15.8 ppg, follow w/4 I ! I bbls water. Rig displace balanced plug @ 10.5 bpm w/1158 strokes (116.6 Printed: 3/13/2005 6:43:53 PM J Page 2 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME I JOB NUMBER i EVENT CODE ! 24 HRS PROG ITMD ITVD IDFS ! REPT NO. I DATE KOKODA #1 I ¡ ODR i . 8,045.0 , 8,045.0 i 25.00 I 26 I 3/4/2005 OPERATIONS SUMMARY FROM TO I HOURS i CODE ITROUBLE! SUB I PHASE DESCRIPTION 14:30 I 15:00 i 0.50 ! CEMENT PLUG !ABANDNI bbls) 10.5 ppg mud. Initial 1150 psi, final 1500 psi. Slowed down to 5.4 bpm @ I 1 i I I i 500 psi fllast 5 bbls. 15:00 15:30 0.50 I CEMENT R !TRIP iABANDN! POOH slow f/7688' to 7317'. 15:30 116:30 1.00 CEMENT Fi !CIRC I ABANDNI Circ @ 130 spm, 550 gpm wI 1300 psi. 16:30 17:00 0.50 CEMENTF PLUG ABANDN Dowell mix and pump cement plug #2. Pump 20 bbls water ahead, mix and i pump @ 5 bpm 33 bbls (160 sx) class G wI additives @ 15.8 ppg, follow wI 4 I bbls water. Rig displace balanced plug @ 10.5 bpm wI 1089 strokes (109.7 i bbls) 10.5 ppg mud. Initial 1150 psi, final 1410 psi. Slowed down to 5.4 bpm @ i 500 psi f/last 5 bbls. 17:00117:45 0.75 ¡CEMENT F! ITRIP I ABANDN POOH slow f/7317' to 6915'. 17:45 118:30 0.75 ¡CEMENT R iCIRC i ABANDN Circ @ 120 spm, 510 gpm wI 1200 psi. 18:30 19:15 0.75 CEMENT F PLUG I ABANDNI Dowell mix and pump cement plug #3. Pump 20 bbls water ahead, mix and i 1 pump @ 5 bpm 33 bbls (160 sx) class G wI additives @ 15.8 ppg, follow w/4 i I bbls water. Rig displace balanced plug @ 10.5 bpm wI 1020 strokes (102.7 ¡ I bbls) 10.5 ppg mud. Initial 1100 psi, final 1330 psi. Slowed down to 5.4 bpm @ i 1 500 psi fl final 5 bbls. 19:15 20:00 0.75 CEMENT F ITRIP i ABANDNi POOH slow f/6915' to 6500'. 20:00 20:30 I 0.50 CEMENT F CIRC jABANDNI Circ @ 120 spm, 510 gpm w/1125 psi. Circ 2 BU (6200 strokes)(624 bbls) 20:30 ! 21 :45 1.25 ! CEMENT F! ¡TRIP I ABAN ON I Monitor hole,POOH f/6500' to 4685'. 21 :45 i 00:00 ! 2.25 I CEMENT F! CIRC I ABANDN! Circ @ 70 spm, 300 gpm wI 350 psi while WOC. 24 HR SUMMARY: MU 31/2" tbg stinger, RIH on DP, circ @ 2480', 3975', 6018', 7000', 7900', spot pill, POH to 7700', Dowell mix & pump plug #1, POH to 7317', circ, Dowell mix & pump plug #2, POH to 6915', Dowell mix and pump plug #3, POH to 6500', circ,POH to 4685',circ PERSONNEL DATA COMPANY i SERVICE j NO. ¡HOURS COMPANY I SERVICE ! NO. HOURS Halliburton - Sperry-Sun -I I 31 Other I 21 Halliburton - Sperry-Sun -I I 1 I i ConocoPhillips Company I I 3! Epoch Well SeNices Inc I I 2, Doyon Drilling Inc , 29 Fairweather E&P SeNice I 1 Doyon Universal SeNice I 7 M-I Drilling Fluids ! i 2 ' Alaska Clean Seas ! 2 North Slope Subsistance i I 1 ! ASRC Energy SeNices ( I 3: MATERIALS 1 CONSUMPTION ITEM I UNITS I USAGE I ON HAND ITEM UNITS 1 USAGE ON HAND Rig Water , bbls I 355 I 375 I Fuel- Storage Tank gals j i Camp, Potable wate I gals 1 5,950 I 10,070 Fuel- RiglCamp ! gals 4,140 11,940 RESERVOIR AND INTERVAL DATA RESERVOIR NAME j ZONE i TOP BASE i COMMENTS KRU 1R-18 i Kokoda #1 i O· 01 Printed: 3/13/2005 6:47:30 PM ~ Page 1 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME I JOB NUMBER I EVENT CODE 124 HRS PROG ITMD ¡TVD IDFS ! REPT NO. I DATE KOKODA #1 1 ; ODR . ; 8,045.0 i 8,045.0 ì 26.00 I 27 I 3/5/2005 SUPERVISOR RIG NAME & NO. 1 FIELD NAME I OCS NO. ! AUTH MD ! DAILY TANG ¡CUM. TANG D. Lutrick IG. Rizek ! n1334@ppco.co Doyon 141 NPRA i 8,078.0 I 0 ; 0 CURRENT STATUS I ACCIDENTS LAST 24 HRS.? [DAILY INT WIO MUD I CUM INT ANG ~/ MUD Ria released fl Kokoda #1 to move to Kokoda #5 @ 0400 hrs 3/6/0 i I 0 24 HR FORECAST ! DATE OF LAST SAFETY MEETING I DAILY TOTAL i CUM COST WI MUD LID 5" DP f/ derrick, clean pits, remove fluids, release riq I 3/5/2005 283,406 ; 5,810,415 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF !AFE I AUTH. I I . , 15.95 10045962 ¡ LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING i LAST BOP PRES TEST 2/28/2005 8,045.00 0.380 295.430 1 9.625 (in) @ 2,505.0 (ft)· (in) @ (ft) I 2/28/2005 DENSITY(ppg) ! I PP I iECD! ¡MUD DATAl DAILY COST ¡ 0 1 CUM COST I 0 FV PVIYP I GELS ! WUHTHP i FCIT.SOL i OIUWAT I "IoSand/MBT ! Ph/pM I Pf/Mf i CI I Ca I H2S I LIME ¡ ES I / ì I I I I I I I I ¡ I i i 1 I , I I BHA NO. I 7 I BHA 1 HOLE CONDITIONS I BIT NO. I BHA WT. BELOW JARS . STRING WT. UP I STRING WT. DN ¡ STRING WT. ROT I TORQUE / UNITS I BHA LENGTH 135 I 142 ! 135 I ft-Ibf i 1,004.70 ITEM DESCRIPTION I NO JTS I LENGTH O.D. J I.D. i CONN SIZE CONN TYPE mule shoe I 1 0.47 4.520 2.990 3 1/2" eue tbg I 32 1,003.05 4.500 2.990 Crossover ¡ 1 1.18 6.125 3.000 I OPERATIONS SUMMARY FROM TO I HOURS CODE TROUBLE SUB PHASE I DESCRIPTION 00:00 i 02:00 2.00 CEMENT R CIRC ABANDNI Circ @ 4685', 70 spm, 300 gpm wI 350 psi while WOC. 02:00 I 03:30 1.50 ¡ CEMENT R TRIP i ABANDNI RIH fl 4685' to 6451, break circ @ 40 spm w/21 0 psi. PU wt 135k, SO wt 142k 03:30 i 04:00 I 0.50 !ABANDN F OTHR IABANDNI Circ down f/6451' @ 4 bpm, tag top of plug w/10k while circ @ 4 bpm, 250 i i 1 I psi. Witness of tag by BLM Petroleum Engineering Technician Tim Lawlor. 04:00 i 07:00 i 3.00 IABANDN F TRIP ABANDN Blow down top drive. POH wI 5" DP to 1004'. 07:00 I 07:30 I 0.50 ABANDN F RURD I ABANDN RU tbg tongs and elevators. 07:30 I 09:30 ¡ 2.00 iABANDN F PULD I ABANDN POH LD 23 jts 3 1/2" tbg. Std back 3 stds in derrick. 09:30 10:00 ¡ 0.50 ABANDN F IRURD ABANDN . RD tbg equipment. Clear floor. 10:00 10:30 0.50 iABANDN F SFTY ABANDN PJSM on MU and running of 95/8" cement retainer. 10:30 12:451 2.25 ]ABANDN ~ TRIP ·ABANDNI MU and RIH w/9 5/8" Baker "K-1" cement retainer to 2416' (Shoe @2505'). I , I ¡ Set Baker model "K-1" cement retainer @ 2416'. Establish inj rate of 900 psi wI 1 I I I I 1.25 bpm. broke down wI 24 strokes pumped. PU wt 75K, SO wt 78k. 12:45113:00 0.25 !ABANDN F1 iCIRC !ABANDN Circ @ 210 gpm wI 300 psi. 13:00 14:30 1.50 CEMENT 1 ¡PUMP I ABANDNI Dowell mix and pump cement plug #4. Pump 10 bbls water ahead, mix and ¡pump @ 5 bpm 20 bbls (97 sx) class G wI additives @ 15.8 ppg, follow wI 4 I I bbls water. Stab into retainer. Rig displace @ 3.5 bpm, unsting @ 331 strokes I I !( 34.8bbls) 10.5 ppg mud pumped. I I Witness of setting retainer & pumping cement by BLM rep Tim Lawlor. ¡ I I I Calculated 110' cement in OH below shoe using 20% excess, 89' below I I I I ! retainer in csg, 53' on top of retainer. 14:30115:15 0.75 I CEMENT R [TRIP i ABANDNI POOH fl 2416' to 525'. Pull slow and allow 4 bbls of cement to lay on top of 9 I i i 1 I 15/8" Baker "K-1" cement retainer. (53' inside of 9 5/8" 40 ppf). 15:15116:00 0.75 I CEMENT 1 ITRIP !ABANDNI Circ and spot gel pill spacer @ 525'. POOH to 310'. Displace 10.5 ppg mud in I I I I I ! hole to 8.34 ppg water. 16:00' 16:45 i 0.75 CEMENTF ITRIP ABANDNI Con't POOH, LID Baker running tool. 16:45 19:15 : 2.50 ,WELCTL F [NUND i ABANDNI NID BOPE. Remove FMC casing head. 19:15 20:45 1.50 I CEMENT F TRIP ABANDN RIH w/1 0 jts total, 310' of 3 1/2" 9.3 ppf, L-80, EUE tubing for surface plug. 20:45 21 :15 i 0.50 ì CEMENT R IpUMP ABANDN! Dowell mix and pump cement plug #5. Mix and pump @ 3 bpm 30.4 bbls (183 Printed: 3/13/2005 6:40:33 PM -, Page 2 of 2 KOKODA #1 ConocoPhillips Alaska, Inc. Daily Drilling Report : JOB NUMBER I' EVENT CODE 124 HRS PROG ! TMD ! TVD ! DFS I ODR . I 8,045.0 ' 8,045.0 i 26.00 IREPTNO. I DATE i 27 I 3/5/2005 WELL NAME 21:15 21:45 0.50 21 :45 22:00 0.25 CODE ITROUBLEI SUB CEMENT í ¡PUMP I i ¡ CEMENT R I CEMENT 1 ¡ TRIP PUMP OPERATIONS SUMMARY PHASE I DESCRIPTION I ABANDNIsx) AS1 @ 15.7 ppg. Returns measured @ 15.6 ppg in cellar. Witness of job I I' by BLM Petroleum Enginerring Technician Tim Lawlor. Sucked returns fl cellar ! , and washed up to cellar. ABANDNI POOH w/3 1/2" tubing. No water used to flush pipe. I ABANDNI Dowell mix and pump cement to top off pipe displacement of 1 bbl (14'). Mix I I and pump @ 3 bpm, 6.27 bbls (38 sx) AS1 @ 15.7 ppg. Witness of job by , : BLM Petroleum Enginerring Technician Tim Lawlor. Sucked returns f/ cellar I I and washed up to cellar. ABANDNI RID, blow down cementing lines. ABANDNI UD 21 stands of 5" dp fl derrick using mouse hole. Cleaning pits and rock ¡washer. I Note: At 0330 hrs 3/6/2005, hard cement 2 1/2" below top of starting head. FROM TO i HOURS 20:451 21 :15; 0.50 I I 22:00 22:30 0.50 22:30 ! 00:00 1 1.50 I . , I 1 . CEMENT R ,ABANDN F, I ' , I I I RURD OTHR 24 HR SUMMARY: Circ @ 4685', RIH, tag plug @ 6502' w/10K, POOH, LID 31/2" tbg, stand back 3 stds tbg, MUlRIH Cmt retainer @ 2416', estab injec rate, Dowell cmt, POOH to 525', spot pill, disp to water, POH, N/D, RIH to 310', cmt, POH, cmt, LID 5" DP PERSONNEL DATA COMPANY I SERVICE NO. ' HOURS COMPANY ¡ SERVICE I NO. HOURS Halliburton - Sperry-Sun - 3 Other 1 Halliburton - Sperry-Sun - , 1 ConocoPhillips Company I 3! Epoch Well SeNices Inc 1 4: i Doyon Drilling Inc I 29 Fairweather E&P SeNice 1 ! Doyon Universal SeNice 1 7' M-I Drilling Fluids I 2 I Alaska Clean Seas I 2 North Slope Subsistance I 1 ASRC Energy SeNices ( ! i 3 MATERIALS 1 CONSUMPTION ITEM I UNITS I USAGE ON HAND ITEM I UNITS I USAGE I ON HAND Rig Water \ bbls I 404 71 !I Fuel- Storage Tank ! gals i I Camp, Potable wate I gals I 5,490 8,765 II Fuel- RiglCamp I gals 3,270 I 9,610 RESERVOIR AND INTERVAL DATA RESERVOIR NAME I ZONE I TOP BASE I COMMENTS KRU 1R-18 I Kokoda #1 ! 255 01 Printed: 3/13/2005 6:46:48 PM Re: Kokoda #1 e e Tom, These are my notes on Kokoda#l. The surface casing cement (Lead: 273.43 bbls, 10.7 lb/gal, 4.45 yield & Tail: 74.78 bbls, 12.0 lb/gal, 2.47 yield) did not return to surface. A 1 inch pipe was inserting down the annulus (cement tagged @ 88ft) and more cement (82 bbls, 15.7 lb/gal, 1.16 yield) was pumped down. That cement was also not returned to surface. Twenty barrels of lighter cement (20 bbls, 10.7 lb/gal, 4.45 yield) was pumped down the 1 inch later and was returned (8 bbls) to surface. When the well head was cut off there was 2 feet of cement at the very top of the annulus but the rest had fallen away to 31 feet. The tape was lowered down the annulus to get an idea where the level of cement ended up. Then a 3/4 inch conduit was lowered to tag the cement. This was the method used on both the other top jobs which I witnessed on this well. Both Jeff and I agreed that the cement should be pumped and I requested Rick Overstreet to do so. The following day 6.2 bbls (approx 2 bbls returned) were pumped down a 30 foot,1 inch pipe and cement was returned to surface. The following day I returned to the well, the cement was still in place and had solidified. The cap was then welded on. If you have suggestions on what can be done differently (for possible future problems) please give me a call or email. Tim Lawlor BLM-Alaska Energy & Minerals Phone: 907-267-1442 Cell: 907-240-5243 Fax: 907-267-1304 Thomas Maunder <tom maunder@admi n.state.ak.us> To 03/14/2005 03:10 PM "Brassfield, Tom J" < L9._f:':1_:';¡:_:.ª-~9:§~!i~1 d@_s:s2~S:J..s:?P~g~~.....:....s:S2 m> cc Jim Regg .s.j~.I!1_1:.:.~99~~ª!!.l_i!?:...:..§_t::9:!::-_~.:_9.:~_:.~§2'_, Tim Lawler <Tim Lawlor@ak.blm.gov>, Greg Noble <greg noble@blm.gov>, AOGCC North Slope Office <aogcc prudhoe bay@admin.state.ak.u s> Subject Re: Kokoda #1 10f2 3/23/2005 3 :44 PM FW: Kokoda #1 surface P&A e e Subject: FW: Kokoda #1 surface P&A From: "Brassfield, Tom J" <TOM.J.Brassfield@conocophillips.com> Date: Wed, 16 Mar 2005 17:01:11 -0900 To: tom _ maunder@admin.state.ak.us dOL\- :)S'7 Tom, FYI. Tom -----Original Message---- From: Brassfield, Tom J Sent: Wednesday, March 16, 2005 4:57 PM To: tom_maunder@admin.state.ak.us Subject: Kokoda #1 surface PM Tom, FYI. Info from Rick Overstreet. Tim Lawlor with the BLM wi1nessed the P&A. Tom -----Original Message---- From: 2L Pad Co-Man Sent: Wednesday, March 16, 20054:23 PM To: Brassfield, Tom J Cc: 'Jeff Jones Üeff-Îones@admim.state.ak.us)'; 'John Spaulding Üohn_spaulding@admin.state.ak.us)'; 'tlawlor@ak.blm.gov' Subject: Kokoda #1 surface PM «Kokoda 1, P&A 2 002.jpg» «Kokoda 1 , P&A 2 001.jpg» «Kokoda 1, P&A 2 005.jpg» «Kokoda #1 P&A.doc» Content-Description: Kokoda 1, P&A 2 002.jpg Kokoda 1, P&A 2 002.jpg Content-Type: image/jpeg Content-Encoding: base64 Content-Description: Kokoda 1, P&A 2 001.jpg Kokoda 1, P&A 2 001.jpg Content-Type: image/jpeg Content-Encoding: base64 Content-Description: Kokoda 1, P&A 2 005.jpg Kokoda 1, P&A 2 005.jpg Content-Type: image/jpeg Content-Encoding: base64 10f2 ~O- ~ L.." f(.c~0 12/22/2005 12:48 PM FW: Kokoda #1 surface P&A e e Content-Description: Kokoda #1 P&A.doc Kokoda #1 P&A.doc Content-Type: application/msword Content-Encoding: base64 20f2 12/22/2005 12:48 PM e e Kokoda # 1 Surface P&A 3-13-05 Removed covering from well and cellar. Removed cellar. Excavated around well head down to 4' below tundra level. Secured site with barricades, conducted pre-job safety meeting, filled out confined space entry permit. Drilled W' hole into side of 16" conductor and drained water from outer annulus. Followed procedure for Hot Work Permit, 0- LEL. Cut 16" pipe and 9-5/8" pipe 3' below tundra level. 9-5/8" casing full of cement (solid). The annulus between the 16" and the 9-5/8" was full of water. Lowered 1" pipe down annulus and tagged top of cement at 31 ft. Pulled 1" pipe out. Secured area with barricades. Put heater on well bore to prevent from freezing. Set up equipment to do top job from 31 f t. 3-15-05 Ran I" pipe down 16" X 9-5/8" annulus to 31 ft (TOC). NU pump truck, pumped 6.2 bbls 10.7 ppg ARTICSET Lite cememt from 31 ft picking up returns with vac truck. Good clean cement to surface. Shut down rinsed lines, secure site and wait on cement 24 hrs. 3-16-05 Cleared blown snow out of hole. The heater left on the hole had melted the blowing snow and had approximately 3' of water in bottom of hole. Vac truck sucked out standing water. Cleared snow off pipe. Confirmed hard cement at surface. BLM (Tim Lawler) witness hard cement at surface. Welded cover plate on top of 16" pipe with W' weep hole over all casing strings with the following information bead welded into the top: ConocoPhillips Alaska, Inc. Kokoda # 1 PTD# 204-253 API # 50-279-20011-00 Back filled cellar with gravel as needed. Cleared ice pad location and demob all materials and equipment. Kokoda ,P&A ! of PM Kokoda , 00 of ¡ 12/22/2005 12:48 PM Kokoda !, P &A J of! PM e e Kokoda Well Status As of 3/18/05 Kokoda #1 Spudded well 2/16/05. Drilled 12-1/4" surface hole to 2510' MD/TVD. Ran & cemented 9-5/8",40 PPF, L-80, BTC casing to 2505' MD/TVD. Reciprocated pipe and had full returns throughout job. Did not see any 10.7 ppg lead cement to surface. Performed two top jobs from 88' (tagged-up with 1" stinger) with the second job getting cement back to surface. Completed testing ofthe BOPE, drilled shoe track and 20' of new hole to 2530' MD/TVD. Performed FIT to 15.9 ppg EMW. Drilled 8-112" hole to 6678' and POOH for rotary BHA. Drilled to core point at 6837' POOH. Core from 6837' to 6873' (36'). POOH LD core (recovered 34' of core). Drilled 8-1/2" hole to TD at 8045' MD/TVD. Tested BOPes. Ran e-line logs requiring a wiper trip between logging runs. P&A'd well per approvals and released rig at 0400 hrs 3/6/05. RE: Kokoda # 1 e - Tom, Rick has discussed the plans forward with both the AOGCC Field representative and with Tim Lawlor the BLM rep. We have already agreed to notify both parties when we will be placing the cement and when the cement is in place so all who are interested can verify top of cement before welding-on the P&A cap/marker. Tom -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, March 14 m;mmimÖosmj;iîï?M- __mm_mmmmm_mmmmm_mm_mmm To: Brassfield, Tom J Cc: Jim Regg¡ Tim Lawler¡ Greg Noble¡ AOGCC North Slope Office Subject: Re: Kokoda #1 Tom, How long after the annulus is full?? witnessed/verified cement is pumped will be allowed to assure that the We believe that "a cement filled annulus" should be either by ourselves or the BLM Inspector prior to the cap being welded on. Please advise. Tom Maunder, PE AOGCC Brassfield, Tom J wrote: Tom, plans are to fill the 16" x 9-5/8" annulus with ARCTICSET Lite (mixed at 10.7 ppg) via the 1" at 30' ± after we complete the Kokoda #5 surface job. This should take place later on tonight early tomorrow morning. Talked to Rick Overstreet and he will advise AOGCC/BLM slope folks of his activities. Tom -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday I March 14··;...···...2..cfo..š..·_·..i·Q"··;··42··..··AMmm....... ..........................._..............mm..................mm............·........·_...·... To: Brassfield, Tom J Subject: Kokoda #1 Tom, Jeff Jones was out to examine/witness the cutoff on the subject well. There was apparently no cement at surface in the conductor x surface casing annulus. Kind of surprising given the 2 top jobs. Apparently a tag with a plumb bob was conducted and Jeff would not accept it and a tag with "available" 1" pipe was made and no cement was encountered to about 31'. Jeff's requirement was to pump/circulate cement. If you have some further information on this matter could you provide it?? Like I said, interesting that nothing was tagged after the other operations. Thanks, Tom Maunder, PE ~"'~~~ 1 of2 12/22/2005 12:36 PM . . State of Alaska Alaska Oil and Gas Conservation Commission MEMORANDUM TO: Jim Regg . P.I. Supervisor KeíL{ Jeff Jones Petroleum Inspector , DATE: 7'7..S'06 '1 , SUBJECT: March 13, 2005 FROM: Plug & Abandonment Kokoda #1 Conoco-Phillips Alaska Inc. (CPA!) NPRA Exploration ~ 2~ .,lö7' -;¿ ç -l th CONFIDENTIAL '"--~,..".".~."=--,-...=._o.=~_=.~~.,=,_..",,~~ Section: 27 Lease No.. Operator Rep.: Rick Overstreet Township: 11 N Drilling Rig: Doyon 141 I~ange: 5W Rig Ele,vation: 27.5' Meridian: Umiat Total Depth: 8,045' TVD/MD Conductor: Surface: Intermediate: Production: Liner: Tubing: CasinalTubina Data: 16" O.D. Shoe@ 109' MD 95/8" O.D. Shoe@ 2505' MD 0.0. Shoe@ O.D. Shoe@ O.D Shoe@ 0.0. Tail@ Casin!! Removal: Casing Cut@ 4' below grade Casing Cut@ 4' below grade Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Tvpe Plua Ib Founded on Bottom Pluaaina Data: Top of Cement Mud Weight Pressure ottom up) of Cement D~h Verifiedl? above plug Test Applied ODen Hole Balanced 7700' MD 7317' MD NO 10.5 PPG ODen Hole Balanced 7317' MD 6915' MD NO 10.5 PPG ODen Hole Balanced 6915' MD 6500' MD BLM T. Lawler 10.5 PPG Annulus Retainer 2416' MD 2363' MD BLM T. Lawler 8.3 PPG Casino Stub Balanced 310' MD 31' MD Yes 8.3 PPG Tvpe Plua Open Hole Perforation Annulus Casing Stub Surface Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag No March 13, 2005: I traveled to Conoco-Phillips Alaska Inc.'s (CPAI) NPRA exploratory well Kokoda #1 location to witness a casing cut off and marker plate plug and abandonment operation. The well casing had just been excavated to a depth of +/-4 feet below (rade on my arrival. I discussed the upcoming P&A procedures with CPAI representative Rick Overstreet and Bureau of Land Management (BLM) representative Tim Lawler while the casing stubs were being cut off. Once the cut off casing was removed, It was apparent that no cement existed in the 16" X 9 5/8" well annulus. I requested that the depth of the top of cement (TOC) in this annulus be determined and a weighted strapping gauge was lowered to a depth of 13' MD where it seemed to stop. I requested that a small diameter pipe be used to further verifý the TOC, and 1" pipe was lowered into the annulus to a deptll of 31' MD. where it stopped descending. When the pipe was removed, I inspected the "sample end" and could find no traces of cement. There were no more sections of small diameter pipe on location and no cementing apparatus, so after consultation with Mr. Overstreet and Mr Lawler, I requested that more 1" pipe be transported to the location and used to determine the actual TOC, and sufficient cement be pumped to fill the annulus from that depth to surface prior to welding the marker plate on the casing stubs. I inspected the marker plate and noted that the required information was bead-welded to the surface. Mr Lawler (BLM) indicated he would witness the remedial cementing and marker plate installation and report the outcome of these operations to the AOGCC Anchorage office. Summary: I witnessed the plug and abandonment cut off of the casing stubs on CPAI's NPRA exploratory well Kokoda #1, noting that no cement existed in the 16" X 9 5/8" annulus. I requested CPAI perform remedial procedures and verified the correct information was welded to the marker plate. ££.i. Rick Overstreet (CPA I) Distribution: orig - Well File c . Operator c - DNRIDOG c - Database c - Rpt File c - Inspector Attachments: CPAI Daily Drilling Reports (4) BLM Tim Lawler e-mail report (1) Well Site Photos (4) Rev.:5/28/00 by L.R.G. 2005-0313_P&A_Kokoda1_ij.xls 3/25/2005 Kokoda #1 (ConocoPhillips) Surface Abandonment Inspection Photos from Jeff Jones, AOGCC March 13, 2005 Prep work for casing cut of Kokoda #1 Casing stub - no cernentto surface in annulus 1 2 '- '~ ~ ConocoPhillips Alaska, Inc. Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage, AK 99510 phone 907.263.4859 TRANSMITTAL TO: AOGCC 333 W 7TH AVE Anchorage, AK 99501 DATE: 03-08-05 AIRBILL: 5325448 CPBV 05-03-08-12 CHARGE CODE#: 10045962 OPERATOR: CPAI WELL: KOKODA 1 SAMPLE TYPE: DRIES/CPE NUMBER OF BOXES: 1 Box 1 Bundle (6 boxes) SAMPLES SENT: KOKODA 1 Core plug ends 6837 -6870 Dries 90-8045 41 /(71 ~OJ\JN 0;620D1 SENT BY: Mike McCracken . ..' . ..4L. ,-'fI'.~ UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED BY: ~ ()~ ConocoPhillips Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Dan Przywojski DATE: q ~ )..,f4~ ;l ~ '1-'À S-) ConocoPhillips Kokoda #1 "'-, "~ -# II 7) Alaska State Samples 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 6837.0./ 6838.0 ~ 6839.0 "., 6840.0/ 6841.0 ,.. 6842.0 ,., 6843.0 ,., 6844.0 ... 6845.0 ". 6846.0 ,.. 6847.0 " 6848.0 ' 6849.0 ,.. 6850.0/- 6851.0 ", 6852.0 ., 6853.0 ". 6854.0 -- 6855.0 ~ 6856.0 ,.. 6857.0 ,. 6858.0 - 6859.0 ,., 6860.0 ", 6861.0 ... 26 27 28 29 30 31 32 33 34 6862.0/' 6863.0 ... 6864.0 .Þ , 6865.0 6866.0 ... 6867.0 ," 6868.0 ./ 6869.0 ~ 6870.0 ~ March 1, 2005 CL File 105057 Å-Ov! - :Af- j ~ ç",~ .~ ~ . '·U·. Œ· (fin ~. ~A nil I~\ ~~ Ü~t( ffiö \\. . U . \ ¡ U-¡\ ru·· !\ \ .I'ï î. '-Ii.....:::! U . U . U AI',ASIiA. OIL AND GAS CONSERVATION COMMISSION I- I FRANK H. MURKOWSKI. GOVERNOR ! í Joi /~s~ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Drilling T earn Leader P.O. Box 100360 Anchorage, Alaska 99510 Re: Kokoda # 1 Sundry Number: 305-062 Dear Mr. Mazzolini: 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 liday or weekend. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. DATED this iff'day of March, 2005 Enc!. MRR-03-2005 16:01 DRLG / WELLS '. y. ConocoPhillips 907 265 1336 P.02 . Pœt OffIce Box 100360 Anchorage. Ala$ka 99510-0360 March 4, 2005 IIftECE·'VED Commìssioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 MAR 0 4 2005 "ltR_c..f;U tlltT ~ Re: Application for Sundry approval to Plug and Abandon Conoco Phillips Kokoda #1 Surface Location: 295' FNL, 629' FWL, Sec. 27, T11N, R5W, UM or ASP4, NAD 27 coordinates of X=606,278 & V=5,954,597 Target Location: 295' FNL, 629' FWL, Sec. 27, T11N, R5W, UM BHL: 295' FNL, 629' FWL, Sec. 27, T11N, R5W, UM CONFIDENTIAL Dear Commissioner: ConocoPhillipS Alaska, Inc. would like to permanently plug and abandon the Kokoda #1 wellbore, located in the National Petroleum Reserve-Alaska. Doyon 141 spud this well on 2/16/05 and TD'd the well on 2/28/05. The attached Sundry and back-up information describes the P&A procedure for the existing weJlbore and has been discussed with AOGCC personnel. If you have any questions or require any further information, please contact me at 265-6377 or Paul Mazzolini at 2634603 Sincerel ~~assfœld Sr. Drilling Engine r MAR-03-2005 16:01 D¡ / WELLS STATE OF ALASKA . 907 265;~0\. P}t.", f L.I. ALASKA OIL AND GAS CONSERVATION COMMISSION " ;..z ~ \ APPLICATION FOR SUNDRY APPROVAL ~ 20 MC 25 280 ."-J 1. Type of Request: Abàndon 0 Suspend 0 Operational shutdown 0 ~erfurate 0 Variance 0 Annular Dispos.D Alter ca$ing 0 Rep¡¡¡ir well 0 Pll.Ig Pertoration$ .0 $liml,llëlte D Time ¡;xtel18ion 0 Other 0 Change approved program D Pull Tubing 0 Perforate New Pool 0 Re-entBl' Suspended \/Veil 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConOCOPhillips Alaska. Inc_ Development 0 Exploratory 0 204-253 3. Address: Stratigraphic 0 SeNice 0 6. API Number: P. O. Box 100360, Anchorage. Alaska 99510 50-279-20011-00 7. KB Elevation eft): 9. Well Name and Number: 28' RKB, 137' AMSL Kokoda #1 a. Property De$ignation: 10. FieldIPool$($): ADL AA0S4129/ ALK L334S, Exploration 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): effective Depth MO (ft): Effective De¡)th TVD (ft): PlugS (measured) Junk (measured): Casing Length Size MD TVD Burst Collap$é Structural Conductor 80' 16" 108' 108' na na Surface 2428 9.625" 2505 2505 5750 3090 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth we eft): Tubing S~e: Tubing Grade: Tubing MD (ft); None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments; Description Summary of Proposal 12] 13. Well Class after proposed work: Detailed Operations Program [2] BOP Sketch 0 Exploratory 11] Development 0 ServJce 0 14. Estimated Date for 15. Well Status after pl"e)pOSecI wOrk: Commencing Operations: 3/4/2005 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: ¡:¿¡J:..' r" ~ Date: 313105 WAG 0 GINJO WINJD WDSPL 0 Commission Representative: Tom Maunder 17. I hereby oertify t~t the foregoing is trlJè and correct to the best of my knOWledge. Contact Tom Brassfield 265-6377 Printed Name Paul Mazzolini Trtle Drilling Team Leader Signature ~JM /J' ~ Phone 263-4603 Date 314/05 -r ·11 r- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry N~;;; ~S-\)bd R Plug Integrity~ BOP Test 0 Mechanical Integrity TestD Location Clearance ~ ,.... - ""'"" ~L M. -rrl' Ct-- \ QC"",,Ot-.. ~, ~ .-\,,~S "'> . MAR 0 4 2005 ..,QI&CìIIC- {;UI-WIIJ S",~/j;O~ ANtll" Date:~hJ¿ App-""'i ~ I~'((¡ ~ 6Y ORDER OF COMMISSIONER THe COMMISSION \../' '--" ~ I I FOtr'r11~03 Revised 2/2003 RBDMS 8Ft MAR 0 8 20D5 0 R \ G \ N Þ\ L SUBMIT IN DUPLICATE MAR-03-2005 16:01 '. . / WELLS Kokoda #1 Final P&A CONFIDENTIAL Revised 3/4/05 by T J8 907 265 1336 P.04 . Summary: Kokoda:#1 well was spudded 2015 hrs on 2/16/05 and TD'd on 2/28/05. After running e-line logs and evaluation of the rotary sidewall cores the decision was made to P&A the wellbore on 3/3/05. Please see the attached wellbore schematic for details. 1. Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Mobilize and rig up D/S for well P&A operation. 3, Spot a viscosified mud gel pill from 7900' to 7700'. Spot a balanced cement plug from 7700'MD to 650Q'MD (approx. 320' above top of the Brookian interval @6820' MD)_ This plug will be laid in three 400' intervals- Total cemented interval is approx. 1200' in length. This will cover the three sand packages penetrated in the well (7570' to 7448' MD, 7293' to 7160' MD, & 6870' to 6820' MD) WOC and prepare to tag top plug ~~~~ AOGCC representative to witness. ß L \-\ l."",>\,(ctcÇ()" \o<:Ct-bat'-, 4. By the down squeeze method through a retainer set 50' minimum above the shoe (or approx. 2455' MD) pump cement plug #2 as per AOGCC regulations. Pump sufficient cement through the retainer to extend 150' below (50' of casing volume plus 100' of open hole) and lay a 50' cement cap on top of the retainer. Weight test retainer beforV pumping cement. Not requited to tag the plug. Leave 10.5 ppg mud above and below the plug. (Weight of mud needed to TD the hole) 5. Spot a viscosified mud gel pill from 500' to 300', Spot a balanced Arctic Set 1 cement plug #3 from 300' to surface. 6. Clear lines and shut down pumps. Rig down cementing unit and clean up. 7. Cut off wellhead and all casing strings at 3 feet below ground level. Send casing head with stub to Materials for repair / re~dressing_ 8. Weld cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top: Conoco Phìllips Alaska, Inc. Kokoda #1 PTD# 204-253 API# 50-279·20011-00 9. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob aU materials and equipment. T JB 3/4/05 Fíle;Kokoda #1 RECEIVED MAR 0 .4 2005 )~~ Paul Mazzol i Exploration Team Leader "'QI¡Gllc.a~I¡orj AId..- TJB 3/4/05 MAR-03-2005 16:01 '. 16" COnductor @ "'/.109' MD Surface C3g. 9-5/8"4Ot.I L.BO erc (25Q5' MO I 2505 lVD) ca~ point BrookIan Sadd IrII~rvals@ &3ZO' ~1fl0' 7160'.7293' 74487670' DRLG / WELLS . Kokoda #1 Proposed PM Schematic Revi$ed 3/4101$ by T J8 10.5 ppg mild :roo' cemenl plug 10 surface AS1 miXe<I~1S.7ppgw/ yleld-O.93 cuttlsk or ap¡)l'Ox 137 slls ~elalner ast at :2455' wI 1SO' of œment below 8< SO' .above or approx. 115 aka of Class "G" w/a«liIiVss 15.8 ppg wlylald= 1.17 cuftlsk 1200' balanced cement plug set in 3-400' $!ags$ (7700' to 6500' MD) ClÜ$ G w/add~ive$ 1 5.S ~~g wly!e1g-, ,1 Ei cufUet< approx. 489 sics 10.5 PM mug TD 1\1I8045' MD /"ND 907 265 1336 . RECEIVED MAR 0 4 ..... Oi It GII 0.. Cwa IiltiJr Ar.cI\~ T J6 314'05 P.05 TOTAL P. 05 e e Kokoda Well Status Kokoda #1 Spudded well 2/16/05. Drilled 12-1/4" surface hole to 2510' MD/TVD. Ran & cemented 9-5/8" 40 ppf L-80 BTC casing to 2505'. Reciprocated pipe and had full returns throughout job. Did not see any 10.7 ppg lead cement to surface. Performed two top jobs from 88' (tagged-up with 1" stinger) with the second job getting cement back to surface. Completed testing of the BOPE stack, drilled shoe track and 20' of new hole to 2530' MD/TVD. Perforemd FIT to 15.9 ppg EMW. Drilled 8-112" hole to 6678' and POOH for rotary BHA. Drilled to core point at 6837' POOH. Core from 6837' to 6873' (36'). POOH LD core (recovered 34' of core). Drilled 8-1/2" hole to TD at 8045' MD/TVD. Current status as of 1630 hrs 2/28/05: RU to test BOPEs and get ready to E-line log after BOPE test. .<it> . . IK\ ~ f/~ ~.~ W l~ /Jlj L.;::J J'ì.J !-.v U ~ LFù FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COmoSSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchoraga, Alaska 99510-0360 Re: Kokoda #1 ConocoPhillips Alaska, Inc. Permit No: 204-253 Surface Location: 295' FNL, 629' FWL, SEC. 27, TIIN, R5W, UM Bottomhole Location: 295' FNL, 629' FWL, SEC. 27, TIIN, R5W, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10-403AD prior to the approval of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In your application, it is indicated that testing and stimulation of the productive intervals in the well may be performed. A Sundry Application (Form 403) detailing the planned activities should be submitted for approval. 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 II> . . 4 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 1 ess any required test. Contact the Commission's petroleum field inspector at (907) 659-. ager). DATED thistday of January, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 6 Á./L\ . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of Work: Drill~ RedrillU 1 b. Current Well Class: Exploratory~ Development Oil U Multiple Zone D Re-entry D Stratigraphic Test D Service D Development Gas D Single Zone 0 2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 Kokoda #1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 8078' TVD: 8078' NPRA Exploration 4a. Location of Well (Governmental Section): 7. Property Designation: /' ./ Surface: 295' FNL, 629' FWL, Sec. 27, T11 N, R5W, UM ALK AA084129 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 295' FNL, 629' FWL, Sec. 27, T11N, R5W, UM ADL L33461 February 10, 2005 Total Depth: 9. Acres in Property: 14. Distance to 295' FNL, 629' FWL, Sec. 27, T11 N, R5W, UM ,/ 5756 Nearest Property: 10265' @ TD 4b. Location of Well (State Base Plane Coordinates): '15"''1 .AR ç 10. KB Elevation 15. Distance to Nearest ~'¿'Jf S"'J5 7 / i- <I. 0 28' RKB & GL 150' Well within Pool:Caribou #26-22-1 ,6.8 mile Surface: x- .J74¡:;? / y- ..~ Zone- 5 (Height above Gl): 16. Deviated wells: 17. Anticipated Pressure (see 20 AAC 25.035) Kickoff depth: 0 ft. Maximum Hole Angle: 0° Max. Downhole Pressure: 4243 psig I Max. Surface Pressure: 1519 psig 18. Casing Program Setting Depth Quantity of Cement Size SDecifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 63# B PEB 80' Surface Surf. 108' 108' 190sxAS I 12.25" 9.625" 40# L-80 BTC 2472' Surf. Surf. 2500' 2500' 340 sx AS III Lite, 170 sx Class G 8.5" 7" 26# L-80 BTCM 8050' Surf. Surf. 8078' 8078' 180 sx Class G + additives 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill an~-Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective DePth:,\ f!! Junk (measured) ..:1:::/11_ Casing Length Size Cement Volume MD Uj:'r ~ · V~nD Structural III,.,/,... '" - ~ 2 JIi,., -- Conductor -.. "'II <I R ft. -"'vc¡. Surface 11_ "'o.I}ß 1". Intermediate '''/I¡ "Iba . ""Ifl1Ïs'fi.._ Production -., Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 BOP Sketch W Drilling Program~ Time v. Depth Plot ~ Shallow Hazard Analysis l;J Property Plat D Diverter Sketch D Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Brassfield 265-6377 Printed NaI./-:1 Paul Mazzolini Title Drilling Team Leader J¿}t¿)p-c¡- Signature' ~i1¡;Id.j/ft '?:hl Phone Date r u '/I - _. ',~ ( .,}t-' ~~ ~ rnn AI/.~/Jn-nrakR / ?/ Commission Use Only Permit to Drill / API Number: permitA~f/¿ Š- See cover letter Number: 2c>t(-2S'3 50- 27C)~ ¿OD/ / -CJÒ Date: I ~ t:l for other requirements I Conditions of approval: Samples required ~ Yes D No Mud log required ~ Yes D No Hydrogen sulfide measures ø Yes D No Directional sUNey required g Yes~ D No ( ~ ~1'1.<:{V\'t.-h~ ót-\,~ Othm W~\. .ß~ ~"'> \-\."~"SI:J.. \ !::. '\ ~';l!. S"-'"'~. T«<>\' . ~ A~"''''-<:, ,,~ "1>'( 9'~~ '-\òJ:,:~~~~'o". ,¡ Jc (' Appr ed b : ~ THE COMMISSION Date:" 0 '--t::/' I ~ '-- OR , , Form 10-401 ~d 06/2004· Submit in du licate f G1NAL p · Conoco Phillips AI!a. Inc. Drill and Case Plan for Kokoda #1 General Procedure: 1. MIRU Doyon 141 over pre-installed 16" conductor casing with welded landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. ./ 3. Spud well and drill 12 1/4" hole to the surface casing point at 2500' MD/2500' 1VD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 V2" bit and BHA and RIH to top of float equipment. · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT (or FIT if gradient reaches 16 ppg equivalent) · Record results and fax to town , , 9. Drill 8V2" hole to TD at approx. ±8078' MD/±8078' 1VD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. · Condition hole and mud for e-line logs. ' 10. Log 8-1/2" wellbore as necessary. 11. Run 7" production string to TD (est.@ 8078' MD / 8078' 1VD). Cement casing to bring cement ±1000' above 7" shoe. 12. Make a cleanout run with bit and scrapers · Displace to filtered seawater or brine- depending on formation pressure. · Pressure test well to 3000 psi for 30 minutes (perform low pressure test on liner lap). · Record results and fax to town 13. Run and land 3-1/2" tubing per schematic. 14. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 15. Secure well, release rig. 16. MIRU well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or trucked to Kuparuk or Alpine production facilities. 17. Upon completion of testing or if the well is not completed, plug and abandon the well, or temporarily shutdown per applicable regulations. Thoroughly clean location and block off further ice road access to location. ORIGINAL · Conoco Phillips AI~a, Inc. DRilLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRilLING AREA RISKS Kokoda #1 Drillina Fluid Proøerties: Spud to surface casing point 10.0 - 10.2 ppg 16 - 26 30 - 40 75 - 90 10 - 20 15 - 40 7 - 15 9.5 - 10 ± 10% Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids Production Hole Drill out to 8078' TD 9.8 - 10.3 ppg ,/ 6 - 20 25 - 35 75 - 90 10 - 20 14 - 20 <6 9.0 - 10 < 11% Drilline: Fluid System: Equipment list for Doyon 141 should be on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Suñace Pressure and Casin9 Desian: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size 16" 9-5 8" 7" Casing Settin De th 108' MD / 108' 1VD 2500' MD / 2500' 1VD 8078' MD / 8078' 1VD Expected Maximum Mud Weights: Pore Pressure Gradient 8.33 8.33 ,/ 10.1 ¡/ Pore Pressure 47 1082 4243 ./ ./ 12-1/4" surface hole to 2500' MD / 2500' 1VD: 10.2 ppg, elevated pore pressures of up to 10.0 ppg may be present just below the permafrost at -575' 55. (See Seismic Pore Pressure Analysis attached.) 8-1/2" Production hole to 7623' MD /7623' 1VD: 10.3 ppg The pore pressure is predicted to increase below -7000' 55 (7178' MD/TVD) from normal pressure gradient to up to 10.1 ppg at TD of 8078' ./ MD/TVD. Procedure for Calculating Maximum Anticipated Surface Pressure: OR\G\NAL · . Conoco Phillips Alaska, Inc. MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) - 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.11 = Gas Gradient in psi/ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR Where: 2) MASP = FPP - (0.11 x D) FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D = [(11.0 x 0.052) - 0.11] x 108' = 50 psi OR MASP = FPP - (0.11 x D) = 1065 - (0.11 x 2458') = 795 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(13.8 x 0.052) - 0.11] x 2500' MASP = 1519 psi OR MASP = FPP - (0.11 x D) = 4243 - (0.11 x 8078') = 3354 psi Casing Design Performance Properties Size 16" 9-5/8" 7" Joint 979 M 667 M Body 916 M 519 M Tensile Strength Grade B L-80 L-80 Connection PEB BTC BTC-M Casing Setting Depth Rational: 16" @ 108' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8" @ 2500' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8-1/2" hole to top of reservoir. 7" @ 8078' MD RKB Production casing is set at TD in a successful case. ORIGiNAL · ! Conoco Phillips Alas a, Inc. Well Proximity Risks: None Drilling Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Kokoda #1 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. See attached Pre-Drill Seismic Pore Pressure Prediction which includes offset well mud weight versus ¡/ depth graphs and predicted formation pressure gradient for Kokoda #1. Annular Pumpin9 ODerations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disDosal well but will be recycled or held for an open annulus.) The Kokoda #1 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. CPAI may request approval to inject or dispose of fluids in the Kokoda #1 9-5/8" x 7" annulus at a later ./ date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 MC 25.080. Geology: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (ss) UNCERTAINTY POSSIBLE FLUID EST. PORE RKB - 178' TYPE PRESSURE Dsi Permafrost 575' 100' 326 Nanushuk 1150' 250' 575 Torok 3250' 200' 1484 Torok Objective 6750' 150' Probable Oil and/or 3000 Gas HRZ 7450' 150' 3610 LCU 7700' 150' 4056 TD 7900' 150' 4242 Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 - Surface Casing setting depth) LWD: GR/Res/Density/Neutron ,/ 8-1/2" Production Hole (9-5/8" Shoe to TD) OR1Gll~AL · Conoco Phillips Alala, Inc. LWD: GR/Res/Density/Neutron/PWD ¡/ Wireline: Dipole Sonic/Formation imaging, MDT sampling tooljCMR nuclear magnetic resonance, Rotary coring tool ./ II. Coring No conventional cores. MSCT wireline cores, see Logging above " II. Mudlogging / Mudlogging service should be in operation from the base of the conductor casing to TD. Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Thirty to sixty-foot (30'-60') wet and dry samples will be collected from surface to surface casing .- setting depth. Thirty-foot (30') wet and dry samples will be collected from surface casing setting depth to well v TD and ten-foot (10') wet and dry samples, or continuous, collected across any hydrocarbon intervals. III. Flow Testing Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build-up. The flow period will be determined on-site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build-up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. ORIGINAL · . Conoco Phillips Alaska, Inc. Kolkoda #1 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12,-1/4" Hole / 9-5/8" Casing Interval Event Gas Hydrates Risk Level Low / Clay Balling Medium Abnormal Pressure in Surface Formations Medium ~ Lost Circulation Medium 8- :1/2" Hole Event Lost circulation Risk Level Low Hole swabbing on trips Low Directional Control Low Sloughing Shale, Tight Hole Medium Abnormal Reservoir Pressure Medium ~ Hydrogen Sulfide gas Low M iti ation Strate Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud tem eratures Maintain planned mud parameters, Increase mud weight, use weighted swee s, reduce fluid viscosi , control ROP. Diverter drills, increased mud weight. Predicted pore pressure may be as high as 10.0 ·ust below ermafrost at -575' SS. Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled runnin seeds. " M iti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- lanned LCM ills, lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, wei hted swee s. BHA design, on-sight geologic review and advisement of otential slum blocks. Increased mud density and fluid composition according to plan, controlled tri seeds swee s ECD monitorin . Well control drills, increased mud weight, pore pressure is predicted to increase from normal gradient above -7000' ss to 10.1 at TD of -7900 ss. H2S drills, detection systems, alarms, standard well control practices, mud scaven ers ORIGINAL . . Kokoda #1 Proposed Completion Schematic Single Completion ConocJPhßlips 16" conductor J @ +1-109' MD Optional TAM 9-518" Port Co/lar Stnd Grade BTC Threads (+/- 1000' MDITVD) Surface O5g. 9-5/B'40# L-BO BTC (2500' MD 1 2500' TVD) Casing point 3-1/2" FMC Gen V tubing hanger, 3-1/2' L-BO EUEBRD pin down. Special Drift 2.91" 3-1/2", L-BO, 9.3# EUEBRD Spaceout Pups as Required. Special Drift 2.91" Optional 3-1/2" Cameo DS Landing Nippie with 2.B75" ID No-Go profile set @ +/- 500' MD. Use 0/ port collar at the discretion 0/ the drilling team. 3-1/2" x 1-y," Cameo MMG GLM with dummy valve @ 2500' +/- 3-1/2", L-BO, 9.3# EUE Brd Mod Tubing. Brookian Sand Perfs @ 6928' +/- (to be done after rig moves off) 3-1/2" x 1-%" Cameo MMG GLM w/ RK shear out valve 1 joint 3-1/2', L-BO. 9.3# EUE Brd Mod Tubing 3-1/2" Cameo 'D' nipple w/2.B13" No-Go profile. 1 joint 3-1/2", L-BO. 9.3# EUE Brd Mod Tubing 3-y,," Weatherford Electric Cable Smart Mandrel w/cable to surface 1- joint 3-1/2". L-BO, 9.3# EUE Brd Mod Tubing 6' Pup Joint 3-1/2", L-BO. 9.3# EUE Brd Mod Tubing. Baker 'B0-40' PBR, 12' Long, with seal assembly. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer. Minimum ID through the packer 3.00". 1 joint 3-1/2", L-BO. 9.3# EUE Brd Mod Tubing 10' Pup Joint 3-112", L-BO. 9.3# EUE Brd Mod Tubing. 3-1/2" Cameo 'D' nipple w/2.75" No-Go profile. 10' Pup Joint 3-1/2', L-BO, 9.3# EUE Brd Mod Tubing. Baker 3-1/2' WL Re-entry Guide w/ shear out sub. Tubing tail 50' above top pianned perforation. Production csg. 7" 26# L -BO BTCM (+/- B07B' MD) TD @ B07B' MD / B07B' TVD (200' MD below the LCU) T JB 12/2/04 ORIGINAL 116" Conductor Casing at 108' MD I RKB I Base of permafrost 753' MD 9·5/8" Surface Casing at 2,500' MD Top of Cement at 5,928' MD 7" Production Casing at 8,078' MD . Kokoda #1 WELLBORE SCHEMATIC and CEMENT DESIGN 12·1/4" H 8.1/2" How . Conductor Casing Size / Hole Size Depth: Top of Cement Excess Calculated: Volume Catculations: (108 If) (170cf) (0.7854 cf/lf) 1(0.93 cf/sx) Slurry Volume: 170 cf Slurry Weight 15.7 ppg Slurry Yield 0.93 cflsx 16" in 20" hole 108' MD RKB Surface 100% (2.00) = 170 cf 190sx or Arctic Set 1 190 sx rounded Surface Casing Stage 1: Volume excess 9-518" in 12-1/4" hole (4.50) = 1,061 cf (1.45) = 430 cf (753 if) (947 If) (1,491 cf) (800 If) (363cf) (0.3132 cf/lf) (0.3132 cf/lD 1(4.44 cf/sx) (0.3132 cf/if) 1(2.40 cf/sx) Lead Tail shoe joint vol 34 cf ... 336 sx (1.45) = 363 cf 166 sx System: Lead (Arctic Set 3 Lite cement... 9% D44 (NaCI)... 30% D53 (gyp) ... 50% D124 (spheres)... 1.5% S1(CaCI,)... 1.5% D79 (ext.)... 0.4% D46 (defoam.) Tail (LiteCrete @ 12.0 ppg) Lead Slurry Volume: 1,491 cf Slurry Weight 10.7 ppg Slurry Yield 4.44 cflsx Thickening Time 6.0+ hours Tail Slurry Volume: 363 cf Slurry Weight 12.0 ppg Slurry Yield 2.40 cf/sx Thickening Time 3.5· 4.5 hours or 340 sx Arctic Set 3 Lite or 170 sx Class G PrOduction Casing Size I Hole Size Depth: Top of Cement Excess Calculated: BHT (Static): Volume around 7 " (2,150 If) shoe joint vol 17 cf... (409 cf) (0.1268 cf/lf) 1(1.17 cf/sx) System: (Class G cement... 1 % D800 ... 0.2% D46 ... 0.3% D65 Slurry Volume: 426 cf Slurry Weight 15.8 ppg Slurry Yield 1.17 cf/sx Thickening Time 3.5 - 4.5 hours 7" in 8-1/2" hole 8,078' 5.928' 50% 160' F 130" F BHT (Girc): excess (1.50) = 409 cf 364 sx or 370 sx Class G Cement volumes and blends are estimates only and subject to change before pumping. ORIGINAL 12/812004 ¡Text Box I ROP o 1,000 I - -1- ----r----I-· -t - - -!- ---I---T- I I I I I 2,000 I ~I _1_ - - -+ 1- - - --1- 3,000 I _--.l___L I I " _ _.1_ .J _ _ _ .L _ I _-1__ ___i___l_ I I I I I I 4,000 -- = --- -= .... Q, ~ Q 5,000 _I___-!-___I__ I I I I _ _ ~ _-'i _~__._i.__ ~----- --I---I---I~ ------T I I Th: Ril!.= AFE Davs = #VALUEI Actual Davs = 0.00 o hours Spud = Release = AFE#= AFE $ = Actual Total $ = $0 lnfanl!.ible $ = $0 Non-Planned $ '" $0 Change of Scope $ = $0 Scope Trouble $ = $0 Trouble $ = $0 Mud $ = $0 Planned Time = 0 hours Non-Planned Time = 0 hours Scope Cbange Time = 0,0 hours Scope Trouble Time = 0,0 hours Trouble Time = 0.0 hours ~ Total CPF = #NUM! Intangible CPF '" #NUM! Planned CPF = #NUM! Non-Planned CPF = #NUM! Scope Change CPF = #NUM! Scope Trouble CPF = #NUM! Trouble CPF = #NUM! Mud CPF = #NUM! MIRU = 0 hours Planned Days/lOK #VALU Actual Days/lOK #NUM! Planned TD = ft Actual TD = #NUM! ft Drlg. Foreman = Drlg. Engineer = ,n ~ I I I I I I I I I I 6,000 I I I I I I I I I - -1- - - T - - -1-- - ~ - - -.- T --I---î -T---I~ î---r ~ ~I ~ T - -1-- . I I I I I I I I I I I , I I I I 7,000 I I - - - 1- - - + - - -1--- ---! - - - I--- - -. + -1- -- AFE Est. vs. Actual I , I I I I I I I $20,000,000 I I $] 8,000,000 ------ I $16,000,000 I I $]4,000,000 ~----- I $] 2,000,000 I I 8,000 --1- ~ ., --1--- $10,000,000 '" I $8.000,000 I $6,000,000 I I $4,000,000 ------ I $2,000,000 ------ I $0 Planned Actual 9,000 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 Days I I . . ConocoPhillips Alaska Inc. Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #1 Kokoda #1 ConocóPÍ1i1lips Plan: Plan: Kokoda #1 (wp01) Standard Planning Report 19 November, 2004 ORIGINAL conoctÃilUps ê :§ 3000 <::) <::) Il) "... ~ ..c 3750 ã. (j) o ro .2 4500 t Q) > (j) :::¡ ¡.:: 5250 Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based -750 o 750 1500 2250 6000 6750 7500 8250 9000 ~ . ConocÓPhillips EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #1 Kokoda #1 Plan: Kokoda #1 (wp01) Map System: Goo Datum: Map Zone: US State Plane 1983 North American Datum 1983 /'" Alaska Zone 5 Site Kokoda Site Position: From: Position Uncertainty: Northing: Easting: Slot Radius: Map 0.000 ft Well Well Position +NI-S +EI-W 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: Position Uncertainty Will/bore Kokoda #1 Modèl Name Sample Date BGGM2004 Plan: Kokoda #1 (wp01) Audit Notes: Version: Phase: . SPERRY_SUN HES Planning Report Local Co-ordinate Referençe: lVD Reference: MD Reference: North Referençe: Survey Calculation Method: Well Kokoda #1 Kokoda #1 178 ft @ 178.000ft (178 ft above MSL) Kokoda #1 178 ft @ 178.000ft (178 ft above MSL) True / Minimum Curvature System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,972,477.000ft 1,738,386.000 ft Latitude: Longitude: Grid Convergence: 700 20' 04.804" N 153012' 18.587" W 0.750 5,954,313.000 ft , 1,746,298.000 ft ,. ft Latitude: Longitude: Ground Level: 70017' 05.101" N 153008' 35.001" W 0.000 ft Declination (0) 11/17/2004 80.34 57,410 22.61 PLAN Tie On Depth: 28.000 28.000 6,928.000 8,078.000 0.000 0.000 0.000 0.000 0.000 0.000 28.000 6,928.000 8,078.000 +NI-S (It) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 Kokoda #1 Torok Obj. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11/19/2004 6:51:14AM COMPASS 2003.11 Build 41 Page 2 of 3 ORtG\~JAL . . eonoOO'Pt,illips SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #1 Kokoda #1 Plan: Kokoda #1 (wp01) Vertical DePth +NJ..s (ft) (ft) 28.000 0.000 0.000 28.000 0.000 0.000 0.000 0.00 0.00 SHL -- 295ft FNL & 4651ft FEL, Sec27-T11N-R05W 100.000 0.000 0.000 100.000 0.000 0.000 0.000 0.00 0.00 199.999 0.000 0.000 199.999 0.000 0.000 0.000 0.00 0.00 753.000 0.000 0.000 753.000 0.000 0.000 0.000 0.00 0.00 Base Permafrost 1,328.000 0.000 0.000 1,328.000 0.000 0.000 0.000 0.00 0.00 Nanushuk Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Kokoda #1 Kokoda #1 178 ft@ 178.000ft (178 ft above MSL) Kokoda #1 178 ft @ 178.000ft (178 ft above MSL) True Minimum Curvature 0.00 0.00 0.00 0.00 0.00 3,428.000 0.000 0.000 3,428.000 0.000 0.000 0.000 0.00 0.00 0.00 Torok 6,928.000 0.000 0.000 6,928.000 0.000 0.000 0.000 0.00 0.00 0.00 Target (Torok Objective) : 6928.000ft MO, 6928.000ft TVO, (295ft FNL, 4651ft FEL, Sec27-T11N-RSW - Torok Objective - Kokoda #1 Torok ( 7,628.000 0.000 0.000 7,628.000 0.000 0.000 0.000 0.00 0.00 0.00 HRZ 7,878.000 0.000 0.000 7,878.000 0.000 0.000 0.000 0.00 0.00 0.00 LCU 8,078.000 0.000 0.000 8,078.000 0.000 0.000 0.000 0.00 0.00 0.00 TO (BHL)-S07S.000 ft MD, S07S.000 ft TVD; 295ft FNL & 4651ft FEL, Sec27-T11N-R5W Kokoda #1 Torok Obje' - plan hits target - Point 28.010 6,928.000 8,078.000 0.00 0.000 5,954,313.000 1,746,298.000 70017' 05.101" N 153008' 35.001" W 0.00 6,928.000 0.000 vertical DePth (ft) 753.000 1,328.000 3,428.000 6,928.000 7,628.000 7,878.000 Name Base Permafrost Nanushuk Torok Torok Objective HRZ LCU 0.00 0.00 0.00 0.00 0.00 0.00 Vertical DePth (ft) 28.010 6,928.000 8,078.000 Local Coordinates +NJ..s +EI-W (ft) (ft) 0.000 0.000 0.000 SHL - 295ft FNL & 4651ft FEL, Sec27-T11N-R05W Target (Torok Objective) : 6928.0000 MD, 6928.0000 TVD, (295ft FNL, 4651ft F TD (BHL)-8078.000 ft MD, 8078.000 ft TVD; 295ft FNL & 4651ft FEL, Sec27- T1 0.000 0.000 0.000 11/1912004 6:51:14AM COMPASS 2003.11 Build 41 Page 3 of 3 ORtG\N,AL . . ConocoPhillips Alaska Inc. Exploration Wells ASP Zone 5 (Kokoda) Kokoda Kokoda #1 Kokoda #1 ConocóPÍ1illips Plan: Plan: Kokoda #1 (wp01) Standard Planning Report - Geographic 08 December, 2004 OR\G\NAL . eonocÓPhillips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda Kokoda Kokoda #1 Kokoda #1 Plan: Kokoda #1 (wp01) Map System: Geo Datum: Map Zone: US State Plane 1983 North American Datum 1983 Alaska Zone 5 Site Kokoda Site Position: From: Map Position Uncertainty: Northing: Easting:: Slot Radius: 0.000 ft Well Kokoda #1 Well Position +N/-S +E/-W Position Uncertainty -18,267.435 ft 7,674.726 ft 0.000 ft Northing: Easting: Wellhead Elevation: Wellbore Kokoda #1 BGGM2004 11/17/2004 Deaip Audit Notes: Version: Plan: Kokoda#1 (wp01) Phase: VertiCal Depth (It» +NI-S eft) 28.000 6,928.000 8,078.000 0.000 0.000 0.000 0.000 28.000 -18,267.435 0.000 6,928.000 -18,267.435 0.000 8,078.000 -18,267.435 Local Co-ordinate Reference: TVO Reference: MD Reference: I\IorIh Reference: Survey Calculation Method: Site Kokoda Kokoda #1 178 ft @ 178.000ft (178 ft above MSL) Kokoda #1 178 ft @ 178.000ft (178 ft above MSL) True Minimum Curvature System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,972,477.oooft 1,738,386.oooft Latitude: Longitude: Grid Convergence: 700 20' 04.804" N 1530 12' 18.587" W 0.750 5,954,313.000 ft 1,746,298.000 ft ft 70017'05.101" N 1530 08' 35.(X)1" W 0.000 ft Latitude: Longitude: Ground Level: Declination CO) Dip Angle CO) 22.61 57,410 80.34 PLAN 28.000 Tie On Depth: +NI-S (It) 18,267.431 +EI-W eft) 7,674.726 7,674.726 7,674.726 0.00 0.00 0.00 0.00 0.00 Kokoda #1 Torok 01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 12/81200410:21:31AM Page2of3 COMPASS 2003.11 BuDd 48 ORIGINAL . eonoa;p.,illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. NAD 83 Exploration Wells ASP Zone 5 (Kokoda Kokoda Kokoda #1 Kokoda #1 Plan: Kokoda #1 (wp01) J.¡ocal Co..ordinate RèferenCe: TVD Reference:- MD Reference: North RefeIence: Survey Calculation Method: Site Kokoda Kokoda #1 178 ft @ 178.000ft (178 ft above MSL) Kokoda #1 178 ft @ 178.000ft (178 ft above MSL) True Minimum CUNature VèI'tK:aI !qdinat!òn ~ -Depth +Nl-'l on' rJ (.) (.) 28.000 0.000 0.000 28.000 ·18,267.435 SHL -- 295ft FNL & 4651ft FEL, Sec27-T11N-R05W 100.000 0.000 0.000 100.000 ·18,267.435 199.999 0.000 0.000 199.999 ·18,267.435 753.000 0.000 0.000 753.000 ·18,267.435 Base Permafrost 1,328.000 0.000 Nanushuk 3,428.000 Torok 6,928.000 0.000 0.000 6,928.000 ·18,267.435 7,674.726 5,954,313.000 1,746,298.000 70° 17' 05.101" N 153° 08' 35.001" W Target (Torok Objective) : 6928.000ft MD, 6928.000ft TVD, (296ft FNL, 4651ft FEL, See27 - T11N-R5W - Torok Objective - Ko 7,628.000 0.000 0.000 7,628.000 ·18,267.435 7,674.726 5,954,313.000 1,746,298.000 70° 17' 05.101" N 153° 08' 35.001" W HRZ 7,878.000 LCU 8,078.000 0.000 0.000 8,078.000 ·18,267.435 7,674.726 5,954,313.000 1,746,298.000 70° 17' 05.101" N 153° 08' 35.001" W TD (BHl)-8078.000 ft MD, 8078.000 ft TVD; 296ft FNL & 4661ft FEL, Sec27 -T11N-R6W Meø.Þd 0.000 +EI-W (ft) 7,674.726 7,674.726 7,674.726 7,674.726 0.000 3,428.000 ·18,267.435 7,674.726 1,328.000 ·18,267.435 7,674.726 0.000 0.000 0.000 7,878.000 ·18,267.435 7,674.726 Targea Target PUma -1ritImiss target . Shape TVD (ft) +EPN ft 5,954,313.000 1,746,298.000 70° 17' 05.101" N 153° 08' 35.001" W +Nl-S It 5,954,313.000 1,746,298.000 5,954,313.000 1,746,298.000 5,954,313.000 1,746,298.000 70° 17' 05.101" N 70° 17' 05.101" N 70° 17' 05.101" N 153° 08' 35.001" W 153° 08' 35.001" W 153' 08' 35.001" W 5,954,313.000 1,746,298.000 70° 17' 05.101" N 153° 08' 35.001" W 5,954,313.000 1,746,298.000 70° 17' 05.101" N 153° 08' 35.001" W 5,954,313.000 1,746,298.000 70° 17' 05.101" N 153° 08' 35.001" W Kokoda #1 Torok Obj - plan hits target - Point 0.00 0.00 6,928.000 -18,267.435 7,674.726 5,954,313.000 1,746,298.000 70° 17' 05.101" N 153° 08' 35.001" W Verfic:aI Depth (ft) 753.000 1,328.000 3,428.000 6,928.000 7,628.000 7,878.000 (ft) 753.000 1,328.000 3,428.000 6,928.000 7,628.000 7,878.000 Name SHL -- 295ft FNL & 4651ft FEL, Sec27-T11 N-R05W Target (Torok Objective) : 6928.oooft MD, 6928.000ft TVD, (295ft FNL, 4 TO (BHL)-8078.000 ft MD, 8078.000 ft TVD; 295ft FNL & 4651ft FEL, Se 12/8/200410:21:31AM Page 3 of 3 COMPASS 2003.11 Build 48 Base Permafrost Nanushuk Torok Torok Objective HRZ LCU Local Coordinates +NI-S +EI-W (ft) (ft) -18,267.435 7,674.726 -18,267.435 7,674.726 -18,267.435 7,674.726 ORIGINAL ·. . From: Monte Mabry Joe Comisky 20 November, 2004 ATO - 1328 PR -2012 Interoffice ~ ConocoPhillips To: Date: Subject: Pre-Drill Seismic Pore Pressure Analysis for Proposed Wells: Kokoda #1, #2, #3, #4, #5, Noatak #1, Bounty #1 , and Defiance #1, CONFIDENTIAL Cc: Mike Faust Lisa Isaacson ATO - 1376 PR - 2022 The purpose of this memo is to report and review the seismic velocity based pore pressure estimates for the proposed NPRA wells listed above. Summary Seismic velocity data were used to estimate pore pressure gradients likely to be encountered at the wells listed above. Local normal compaction trend lines (NCTLs) and local velocity-to-pore pressure gradient translations were established using control from the Trailblazer A-1 , Trailblazer H-1 and North Inigok wells. Additional wells not located within the seismic volumes were the East Teshekekpuk #1, and Ikpikpuk #1 test wells. To estimate pore pressure gradients, a calibrated normal compaction trend and a translation function established from the control wells were applied to seismic velocities in 3D sub-volumes extracted from larger 3D seismic velocity volumes. The velocity data indicate no apparent v shallow hazards at the proposed surface locations. However, based on seismic velocity I and offset data, moderately elevated pore pressure gradients (9.5 to 10.0 ppg) may be present v below the base of permafrost (-500' TVD) at all well locations. Seismic Processina: The accuracy of seismic pore pressure analysis depends critically on the accuracy of the input velocity field. The velocities used in this study were generated using ConocoPhillips' proprietary AVEL1,2 program, an automated high-resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a seismic velocity field defined at every CDP and every 4 milliseconds. I Swan, H.W., 2001, Velocities from amplitude variations with offset, Geophysics, v. 66, no. 6, p. 1735-1743. 2 Kan, T. K., and Swan, H. W., 2001, Geopressure prediction from automatically-derived seismic velocities, Geophysics, v. 66, no. 6, p. 1937-1946. ORflGINAL ~ . . ... Apparent pressure buildups can result from velocity changes due to local lithology changes. For example, the low-velocity, low-density HRZ shales show up as overpressured zones, though they are often drilled with out problems using relatively low mud weights. Other potential causes of apparent pressure anomalies include errors in the velocity pick and lor inaccuracies in shallow seismic velocities due to low fold. Potential for the Presence of Gas Hvdrates and Seismic Pressure Prediction It is possible that methane hydrates in or around the base of the permafrost transition zone will not exhibit acoustic properties that are sufficiently different from permafrost to be detected seismically. Nevertheless, hydrates can pose a significant drilling risk if proper safeguards are not in place. Gas-charged sands and hydrates within the permafrost zone are thought to have contributed to the blowout at the Cirque #1 well (approximately 10 miles southeast of Oberon #1). A thin zone of over-pressured, gas-charged sands was observed at the base of permafrost in the Cirque #2 well. Previous analysis (Heinlein, 20003) shows that there is no apparent indication of the vé presence of gas hydrates or free gas within or below the permafrost layer on either 2D or 3D seismic data in the area surrounding the Cirque wells. Thin gas-charged sands sitting immediately below the permafrost (in the K-10 interval) also may not appear as a potential pore ,/ pressure anomaly on 2D or 3D seismic. Pressure Prediction Procedure: ConocoPhillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to estimate pore pressure gradients. Data from the existing control wells were used to establish a local normal compaction trend line (NCTL) and local velocity vs. pressure translation trend model. These models have been updated from previous NPRA models (Wyndriski 1999; Heinlein and Kilsdonk, 2000; Buggenhagen, 2002) to include additional data and better fit all available data. The current models differ in details from earlier models but produce similar results with slightly improved fits to offset well data. Procedure 1.) Open hole wireline logs for the control wells were compared to the seismic interval transit time (ITT) and show a good match after 7 us/ft were added to the seismic ITT. Special care was taken to ensure bulk density measurements were not reading too low due to washout and rugose zones in the well bore. 2.) In the area that includes the 3 main control wells (Trailblazer A-1, Trailblazer H-1, and the N. Inigok #1) the logarithmic slope of the seismic-based NCTL is -2.7e-5 with intercepts between 132 and138 us/ft. The log-based NCTL is -2.7e-5 with intercepts between 125 and 130 us/ft. A logarithmic slope of -2.7e-5 and intercept of 135 us/ft was used for all seismic-based predictions at the prospect locations. 3.) The inverse ratio of interval transit times (ITT), recorded by wireline sonic logs (ßT) in the existing wells or by seismic velocities in the proposed wells, to interval transit times predicted by downward extensions of the NCTLs were calculated. These values are the interval transit time ratios, ITT nlTT Q. 4.) A translation trend model was established by comparing transit time ratios (ITTnmo) to mud weights in offset wells. This model calculates pore pressure gradients (PPG) using the Eaton's equation4 fore pore pressure. 3 Heinlein, K. H., 2000, Pre-drill seismic pore prediction for proposed well location: Cirque #3, Phillips Alaska, Inc. 4 Eaton, Ben A, 1975. The equation for geopressure prediction from well logs, SPE 5544. ORIGINAL t . . " or equivalently PPG = OBG - [OBG - PPGn] (lIT rIfT o)N VESNESn = (lIT rIfT o)N where: PPG is the pore pressure gradient OBG is the overburden gradient PPGn is the normal (not overpressured) pore pressure gradient (8.65 pgg or 0.45 psi/ft) lIT n is the normal (not overpressured) interval transit time lITo is the observed interval transit time N is the Eaton exponent. VES is the vertical effective stress VESn is the normal (not overpressured) vertical effective stress In this case appropriate values of N were found to lie between 0.8 (best fit) and 1.0 (high side estimate). 5.) Fracture gradients were calculated using the Eaton method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile (from a West Cameron model). Bulk densities were computed from seismic data using the equation: Rhob = A (V)B Where Rhob is bulk density in glcc, V is seismic interval velocity in ft/s, and A and Bare constants with values of 0.14904 and 0.30467, respectively. Pressure Calibration from Offset Control Wells Located Within Seismic Volumes Two 3D seismic volumes were used in this regional study (Figure 1). The NPRA3D survey encompasses the 3 control wells, along with a majority of the prospects for 2005. The TESH123 survey encompasses all of the 2005 prospects. The TESH123 survey does not include any of the three calibration wells. The workflow using two different surveys (one for calibration and one for prospect calculations) first involved comparing the smoothed sonic logs from the 3 calibration wells to the unscaled seismic lIT from the NPRA3D survey. A better match between the seismic and well data was accomplished by adding 7 us/ft to the NPRA3D traveltimes (Figure 2). Seismic lIT extractions from the NPRA3D and TESH123 surveys were then compared at the Kokoda #2 location to investigate any discrepancies between the two seismic datasets. The extractions at the Kokoda #2 location are reprèsentative of all the prospects and show that the TESH123 velocities more precisely image the base of permafrost compared to the NPRA3D survey. Figure 3 shows the seismic lIT in the shallow section just below permafrost is faster in the TESH123 dataset compared to the NPRA3D survey. Seismic lIT values from the two surveys are essentially identical below 3000' TVD below MSL. The observations from Figure 3 suggest if seismic lIT values were available from the TESH123 survey at the N. Inigok location, they would show a better tie in the shallow section compared to the NPRA3D merge seismic lIT values. N. Inigok #1 Test Well Figure 4 shows sonic velocity based pore pressure/ fracture / overburden gradient analyses of this well plotted with observed mud weights, formation tops, and drilling data. Both a best-fit analysis and a "high-side" fit analysis are shown. The left track contains the wireline sonic (black curve) and the NCTL (red line). The right track contains the pore pressure gradient calculations (blue curves), actual mud weights (green curve), and the calculated fracture gradient (red curve). Casing points, areas of hole problems, and formation tops are as labeled. nR,· 1 hi ~I...~ I ~~rf,)l 'j ','~ \$)<;' ~ i \i l~,~~ . . . . 1- Mud weights and drilling data indicate low pore pressure gradients « 1 0 PPG) down to almost 7500 feet where mud weights were increased to 11 ppg to control shale and gas returns. The sonic data show an increase in lIT (decrease in velocity) at the same depth that is interpreted as a pore pressure gradient increase. The increase occurs at or very near the top of the HRZ. /' The seismic-based analysis in Figure 5 shows a reasonable tie between the log-based interpretation and the drilling indicators. As noted in Figure 3 , the NPRA3D seismic lIT extraction used for this calibration does a poor job in imaging the base of permafrost in the shallow section of the well. A seismic-based NCTL with an intercept of 132 us/ft was used in the calculations. Trailblazer H-1 Figures 6 and 7 are sonic and NPRA3D seismic-based pore pressure gradient estimates for the Trailblazer H-1. Mudweights (green) are the equivalent circulating densities as monitored at the well-site and are typically 0.5 to 1 ppg less than what is measured at the surface flowline. The NCTL has an intercept value of 125 us/ft at this well compared to the value of 130 us/ft used at the N. Inigok test well (10 miles to the south). Both the sonic and seismic analyses suggest ,/ normal pressure gradients below the 9 5/8" shoe until the HRZ was encountered at 6800' TVD rKB. Below 6800' TVD rKB, both the logs and seismic data suggest an increase in the pore pressure gradient to as high as 10.5 ppg. The zone from 6700' to 6800' is also noted in the drilling report as having mud losses/gains and high connection gas readings. Trailblazer A-1 Figures 8 and 9 are similar (best-fit and high-side) sonic and NPRA3D seismic-based pore pressure gradient estimates for the Trailblazer A-1. Both the log and seismic-based pressure gradient calculations are similar to the Trailblazer H-1. Its also worth noting that tight hole conditions were encountered during trips in both Trailblazer wells, more likely caused by borehole swelling due to clays reacting with the drilling mud and not pressure imbalances. Additional Wells Log and drilling data from both the E. Teshekpuk and Ikpikpuk test wells were used to quantify the relationship between sonic log response and pressure. These two wells were not included within either of the two seismic surveys used in this study and are simply shown here as an addendum. The NCTL for both wells is different compared to the trends used in the Kokoda and Trailblazer areas. Figure 10 shows the log-based pressure profile for the E. Teshekpuk test well. This well drilled with near normal « 1 0 ppg) mudweights to the basement at 10700' TVD rKB. An increase in connection gas was noted in the Pebble Shale/HRZ interval at 7100' TVD rKB. This increase in connection gas corresponds to an increase in the log-derived pore pressure gradient. The Ikpikpuk test well (Figure 11) encountered higher pressure gradients within the HRZ compared to the E. Teshekpuk well. Mudweights in this interval were raised to as high as 12 ppg to control sloughing shale. Stuck pipe and lost circulation incidents were also encountered. Pore pressure gradients computed from the sonic log reflect the increase in mudweight. Seismic Pore Pressure Analvses for Proposed Wells ORI(;'~\LA\ . ... 4 "" . . . Seismic lIT extractions from the TESH123 survey were used to calculate the expected pore pressure gradients for the wells presented in Table 1. Also included in Table 1 are the inline and xline numbers that locate the well within the TESH123 seismic volume. The seismic lIT values were scaled by adding 7 us/ft, as this provided the best match to the sonic logs in the control wells (Figure 2). Table 1 - Prospect names and locations within the TESH123 Survey WELL SURFACE LOCATION NAME Inline, Xline Tesh. 1,2,3 Merge 3D Kokoda 1 5352,10122 Kokoda 2 5374,10232 Kokoda 3 5365,10040 Kokoda 4 5487,10273 Kokoda 5 5483,10245 Noatak 1 5469,10415 Defiance 1 6001 ,10248 Bounty 1 5740,10051 Figures 12 through 19 show the expected pore pressure profile for all of the 2005 prospects. Each Figure shows the seismic lIT extraction from the TESH123 with a NCTL calibrated using the control wells. The NCTL for all the prospects have a logarithmic slope of -2.7e-5 and an intercept of 135 us/ft. All depths are referenced to TVD with a KB = 0'. The seismic-based predictions are similar for each prospect with these broad observations: 1. TVD depth to the base of permafrost is -500 ft. ,/ 2. Elevated pore pressure gradients (10 ppg) may be present directly below permafrost. ,/ The pore pressure gradients decrease back to normal around 2000 ft TVD. 3. The pore pressure gradient increases at each prospect above normal pressure -7000 ft ,/ TVD and steadily increase to as high as 12 ppg at 10,000 ft TVD. Figure 20 shows the seismic lIT profile and intersects all of the 2005 well locations. Figures 21 and 22 show the expected pore pressure gradient calculated from the TESH123 survey. Conclusions Seismic velocity data indicate no shallow hazards at the proposed surface locations for v' the Kokoda #1, #2, #3, #4, #5, Noatak#1, Bounty #1, and Defiance #1 prospect locations. However, seismic velocities at each location indicate that: (1) slightly elevated pore pressure gradients of 9.5 to 10.0 ppg are possible in the shallow section below permafrost and (2) pore .; pressure gradients up from 11 to 12 ppg may occur below 10000' TVD at all locations. ORIG\~J$~L . . /". ,- " /0 "- -f" - ';', Figure Captions <..<0~. ' .\ ,~, 1. Basemap showing the location of the control wells (Trailblzaer A-1, H-1, a~~f?e~.,lri t; ·-~II<)., and seismic volumes used in the study. A line of section (A to A') intersects all"of;ft;(e. 20oQ~ø'" prospects. Two seismic surveys were used in the study and are presented as t~·~"outlifu. Þ':') (TESH123) and green outline (NPRA3D). The three control wells are located withiR.Jh~PR ~d outline. All of the 2005 prospects are located within the TESH123 outline. '\, Q>¡p,. ~~ 2. Sonic Log vs. Seismic ITI comparison at control wells. The smoothed sonic log for ea~~~y presented in green while the scaled seismic velocities are presented in black. The best ~at~~ between seismic and log-based ITI was achieved when 7 us/ft was added to the seismics. . Seismic ITI extractions for these wells were taken from the NPRA 3D Merge survey. 3. Comparison of seismic ITIs at the Kokoda #2 location from the NPRA3D and TESH123 surveys. The green curve represents the TESH123 survey while red represents the NPRA3D survey. 4. Log characterization of geopressured intervals for the N. Inigok test well. The left track contains the sonic log with red shale points. The NCTL is presented in red and has a slope of -2.7e-5 and intercept of 130 us/ft. The right side shows the PPFG profile with the PPG in blue, drilling mud weights in green, FG in red and OBG in black. The sonic log has been smoothed for comparison to seismic, and the top of geopressure is readily identified at 7000' TVD. 5. Seismic estimation of the PPFG profile for the N. Inigok test well. Seismic ITIs were extracted from the NPRA3D survey. The NCTL has a slope of -2.7e-5 and an intercept of 132 us/ft. 6. Log characterization of geopressured intervals for the Trailblazer H-1 well. The left track contains the sonic log with red shale points. The NCTL is presented in red and has a slope of -2. 7e-5 and intercept of 125 us/ft. The right side shows the PPFG profile with the PPG in blue, drilling mud weights in green, FG in red and OBG in black. Of note, the drilling mudweights presented here are the equivalent circulating densities which tend to be -1 ppg higher than the mudweight measured at the flowline. The sonic log has been smoothed for comparison to seismic, and the top of geopressure is readily identified at 6700' TVD. Shale points within the geopressured interval were not taken in the slower HAZ due to the high kerogen content of the shale. 7. Seismic estimation of the PPFG profile for the Trailblazer H-1 well. Seismic ITIs were extracted from the NPAA3D survey. The NCTL has a slope of -2.7e-5 and an intercept of 135 us/ft. 8. Log characterization Of geopressured intervals for the Trailblazer A-1 well. The left track contains the sonic log with red shale points. The NCTL is presented in red and has a slope of -3.4e-5 and intercept of 130 us/ft. The right side shows the PPFG profile with the PPG in blue, drilling mud weights in green, FG in red and OBG in black. Of note, the drilling mudweights presented here are the equivalent circulating densities which tend to be -1 ppg higher than the mudweight measured at the flowline. The sonic log has been smoothed for comparison to seismic, and the top of geopressure is readily identified at 6800' TVD. Shale points within the geopressured interval were not taken in the slower HAZ due to the high kerogen content of the shale. 9. Seismic estimation of the PPFG profile for the Trailblazer A-1 well. Seismic ITIs were extracted from the NPAA3D survey. The NCTL has a slope of -2.7e-5 and an intercept of 138 us/ft. 10. Log characterization of geopressured intervals for the East Teshekpuk Lake test well. The left track contains the sonic log with red shale points. The NCTL is presented in red and has a slope of -3.4e-5 and intercept of 142 us/ft. The right side shows the PPFG profile with the PPG in blue, drilling mud weights in green, FG in red and OBG in black. An increase in trip gas (TG) was noted -7000' TVD corresponding to an increase in the shale PPG. 11. Log characterization of geopressured intervals for the Ikpikpuk#1 test well. The left track contains the sonic log with red shale points. The NCTL is presented in red and has a slope of -3.4e-5 and intercept of 130 us/ft. The right side shows the PPFG profile with the PPG in blue, drilling mud weights in green, FG in red and OBG in black. Two DSTs were conducted but had poor recovery and did not reach a true formation pressure after the buildup. Drilling indicators of the ORIGINAL . . geopressured Kingak section include spalling shale and stuck pipe. There were also two instances of lost returns within the geopressured interval below 7000' TVD. 12. Seismic pore pressure analysis for the Kokoda #1 prospect location. The seismic ITT was extracted from the TESH123 survey at the inline and xline location presented in Table 1. The NCT has a slope of -2.7e-5 and an intercept of 135 us/ft. The analysis shows slightly elevated pore pressure gradients directly below permafrost and near normal gradients by 2000' TVD. The expected pore pressure gradient increases at 7000' TVD to as high as 11.8 ppg at 9500' TVD. No shallow hazards are present at this well location. 13. Seismic pore pressure analysis for the Kokoda #2 prospect location. The seismic ITT was extracted from the TESH 123 survey at the inline and xline location presented in Table 1. The NCT has a slope of -2.7e-5 and an intercept of 135 us/ft. The analysis shows slightly elevated pore pressure gradients directly below permafrost and near normal gradients by 2000' TVD. The expected pore pressure gradient increases at 7000' TVD to as high as 11.5 ppg at 9600' TVD. No shallow hazards are present at this well location. 14. Seismic pore pressure analysis for the Kokoda #3 prospect location. The seismic ITT was extracted from the TESH123 survey at the inline and xline location presented in Table 1. The NCT has a slope of -2.7e-5 and an intercept of 135 us/ft. The analysis shows slightly elevated pore pressure gradients directly below permafrost and near normal gradients by 2000' TVD. The expected pore pressure gradient increases at 7000' TVD to as high as 12 ppg at 10000' TVD. No shallow hazards are present at this well location. 15. Seismic pore pressure analysis for the Kokoda #4 prospect location. The seismic ITT was extracted frqm the TESH123 survey at the inline and xline location presented in Table 1. The NCT has a slope of -2.7e-5 and an intercept of 135 us/ft. The analysis shows slightly elevated pore pressure gradients directly below permafrost and near normal gradients by 2000' TVD. The expected pore pressure gradient increases at 7000' TVD to as high as 11.4 ppg at 9800' TVD. No shallow hazards are present at this well location. 16. Seismic pore pressure analysis for the Kokoda #5 prospect location. The seismic ITT was extracted from the TESH123 survey at the inline and xline location presented in Table 1. The NCT has a slope of -2.7e-5 and an intercept of 135 us/ft. The analysis shows slightly elevated pore pressure gradients directly below permafrost and near normal gradients by 2000' TVD. The expected pore pressure gradient increases just below 7000' TVD to as high as 12 ppg at 9500' TVD. No shallow hazards are present at this well location. 17. Seismic pore pressure analysis for the Noatak #1 prospect location. The seismic ITT was extracted from the TESH123 survey at the inline and xline location presented in Table 1. The NCT has a slope of -2.7e-5 and an intercept of 135 us/ft. The analysis shows slightly elevated pore pressure gradients directly below permafrost and near normal gradients by 2000' TVD. The expected pore pressure gradient increases at 7500' TVD to as high as 11.0 ppg at 9000' TVD. No shallow hazards are present at this well location. 18. Seismic pore pressure analysis for the Bounty #1 prospect location. The seismic ITT was extracted from the TESH123 survey at the inline and xline location presented in Table 1. The NCT has a slope of -2.7 e-5 and an intercept of 135 uslft. The analysis shows slightly elevated pore pressure gradients directly below permafrost and near normal gradients by 2000' TVD. The expected pore pressure gradient increases at 7500' TVD to as high as 11.5 ppg at 10000' TVD. No shallow hazards are present at this well location. 19. Seismic pore pressure analysis for the Defiance #1 prospect location. The seismic ITT was extracted from the TESH123 survey at the inline and xline location presented in Table 1. The NCT has a slope of -2.7e-5 and an intercept of 135 uslft. The analysis shows slightly elevated pore pressure gradients directly below permafrost and near normal gradients by 2000' TVD. The expected pore pressure gradient increases at 7000' TVD to as high as 11.0 ppg at 10500' TVD. No shallow hazards are present at this well location. 20. Seismic ITT cross-section from A-A' (see basemap) intercepting all 2005 prospect locations. ORIGJ~LAI . . _'-. '7" .-j -. '~I-,=-.'"" . . 21. Pore Pressure gradient cross-section using the high-side model. Purple colors represent normal pressure gradients while blue to green represent pore pressure gradients in the neighborhood of 10 to 12 ppg. No shallow hazards are indicated within the area of the 2005 prospects. 22. Pore Pressure gradient cross-section using the low-side model. Purple colors represent normal pressure gradients while blue represent pore pressure gradients in the neighborhood of 10 to 11 ppg. No shallow hazards are indicated within the area of the 2005 prospects. ORH3'N,AL '" 00..1 6010000 - 6000000 ~ 5990000 - 5960000 5910000 5:960000 5950000 5940000 593:0000 5320000 5910000 5S'OOOOO o 'rnAIL6LAZR!'\ _:HI 640000 65000(1 ,> / ' 660000 . 6'iOOOO 660000 690000 1 I OEPTII (DBlum ,etm RKB, 1B6fiabo", MSL) 89 DEPIH (DBlum ,etm RKB.1B6tabo", MSL) 89 3000 10000 10364 80 120 140 DEPTH (D&1um ,etl» RKB.1GBtabo'.MSl) 89 80 100 120 140 4' )' 2 2000 :3000 4000 5000 13000 7000 8000 9000 10000 11000 (Da:!:u..n sei:ro MSL) 12 3 12000 NPRA below MSL. datasets are ? ". . . 3 Project: N PRA3D Well:N. NCTL: 130, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 10. + 11 ¡;;J 100 = 13U91 = -2.7Ue?5e-85 * Kick I 1'10"" X Drili Slem Teat II!I I.eall-Gff Teat Formaüon Top ... Sid....,k I...caü"" 12166 20 10 11 12 13 14 Iblgal (Sohic HCT!.: U'_21J./DEF, Top Eallln Eltp = U) (Sonic NCT!.: 13*_27 JJDEF, Top Eallln Exp = 1) ... Figure 4 Project: NPRA3D Well:N. NCTL: 132, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 DEPTH (O<!lum ..1m RKB.166ftabov. M$L) 30 M_ilfli,,-oU1 .. + A I8J 80 100 120 1.0 160 180 = 132 = -2.18882e-85 * Kiell/Flow X Drill Sb!m Teort a l.eall-1Iff Teort - I'ormlltion Top "- Sidelr....k Lo"lItion 1216 10 11 12 13 14 15 Ibtgal (Sonic NCTL:132_2TJIDEI', Top Eatlln Exp = U) (Soni" NCTL: 132_Z1J.UDEI', Top Eatlln Exp = 1) 16 17 18 19 20 '" "~-,~ ~ B~~ Figure Project: NPRA3D Well: Trailblazer H1 NCTL: 125, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 . . 1012104 J. Comisky 80 120 19 140 160 100 = 125 = -2.1e-85 * X II!I 180 10 11 12 NCTt 13 14 15 Ibl¡ai Top E:aiD1I EXp = U) Tol' E:aiDn Exp = 1) 16 11 18 Kick I flow Drill stem Test l.ealt-cfI Test formation T 01' ...... Siclelr....lcl.ocati".. ... . Test ~ prea.-a.ure EI lost Círc"I¡;OOo" Zon".. a.. stuck lucsdicn " Figure 6 10/2/04 J. Comisky Project: NPRA3D Well: Trailblazer H1 NCTL: 135, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 . . DEPTH (Do1um .etm RK6, 83it abo.e M$L) 29 3000 4000 ... + ß. ¡g¡ 100 NCTl = 135 lc!!""illlmie = -USS97e-85 * Test }{ i!I - FormlJllion Top .", SidelJr",," LoclJlli..n 10 11 12 13 14 Iblgal (Sonic NCTL:135_27_UOEf', Top Eaton = U) (Sonic NCTL:135_27_UOEf', Top Eaton = i) 18 19 v Figure 7 Project: NPRA3D Well: Trailblazer A 1 NCTL: 125, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 TIIIIILIILIIZEIIII-1 1000 * X I!II - !'"",,,"öon Top ... Sidetrack Localion -e. Figure 8 1 0/2/04 J. Comisky TRAilBLAZER j\-1 ao 12 13 Hcn log....ì!!Im¡c !S0..ic NCn:138_21_IIDEF, ¡Sollic !4CTl..: 138_21 JJDEF, 10. + Teet .A Preasure 181 log! Cír"u!.wo.. ZOIl"" lo".wo.. !IE }{ ell I Fi..... p..i.".... x .... 14 16 !Ii/gal =U) = 1) Project: NPRA3D Well: Trailblazer A1 NCTL: 138, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 FEET 2S e 16 S106 17 18 lS 20 Figure 9 " Project: NPRA3D We!!: E. Teshekpuk lake #1 NCTL: 142, -3.4e-5 Modified Eaton Method: e:::::O.6 lips 1012104 J. Comisky EVESII 110. + Ii IE! FEn 28 10000 Ncn 11 12 13 H 15 lill¡¡ai (Sonic Hen.: 143_34_UDEF, Top Emn Exp = $.I.) 10733 .... Figure 10 x Project: N PRA3D Well: Ikpikpuk #1 NCTL: 130, -3.4e-5 Modified Eaton Method: e=0.8, 1.0 53 1000 2000 3000 4000 5000 5000 7000 8000 9000 10000 11000 12000 Mcn lIIgarillllmic 80 = 13. = -3.39991e-05 ;IE Kïck Il'low X Drill SlJem Teat I!II leû-oIfTeat I'ormalion Top .... Siclelr",,¡¡ lOCl1lÜon 16053 9 10 11 12 14 15 Ibl¡aI (Sonic MCn.: 13e_34JJDEI', Top E.n Exp = U) (Sonic HCTl:130_34ßDEI', Top E.n Exp = 1) 16 17 18 19 ... ;- A 121 .". Figure 11 ~ II' J Project: TESH 123 We!!: Kokoda #1 NCTL: 135, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 '" o I( ~ $..¡ ~ ~ 10000 11000 12134 60 80 100 K<:illnle.c"pt m Gl = 135 log....itllm;c SI"I''' = -2.7,,-85 11 12 13 14 15 Ibilla! (SOli;" 1I<:1l:135 27 IIOEI', Tol' EIIIDII Exl' = U) (Sollic NCil: 13S=27)JOEI', Top EIIIDn E1Ip = 1) 16 Figure 12 ... Project: TESH123 Well: Kokoda #2 NCTL: 135, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 IIEPT!! (DaJum ,etm RKB, 1291tabo,e MSL) 30 ~ ;;;..- ~ 10000 11000 121 140 160 180 20 12129 21 60 80 100 120 Hcn. 11rti!.""pt at Gl = 135 log....i!IIm¡" Slop" = -2.1.......-.5 8 10 11 12 13 14 15 Iblgal (S"n¡c HCTt: 135_21JJDEF, T"p Elrti!n = U) (Soni" NCTl: 135_UJ)EF, Top Emil = 1) 16 17 18 19 Figure 13 Project: TESH123 Well: Kokoda #3 NCTl: 135, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 1012104 J. Comisky '" o II ~ ~ t..; 80 100 NCT\. Il'I!x!rcepllll: G\. = 135 \.ogMílhmic Slope = -2.18'0""-05 10 11 12 13 14 15 Ibilllll: (Sonic HCT\.: 135 27 UDEf, Top E:oIIIn EliI' = U) (Sonic HCR: 135)7)I)Ef, Top E:oIIIn Exl' = 1) 16 17 Figure 14 5000 6000 ~ 7000 ~ 8000 9000 DEPTH (DoIum ,etm RKB.1 081t aDove MSl) o 1000 2000 3000 4000 10000 11000 100 .. 135 .. -2.10884e-05 9 10 11 13 Project: TESH123 Well: Kokoda #4 NCTL: 135, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 14 15 IlIlgal ..U¡ .. 1) Figure 15 Project: TESH 123 Well: Kokoda #5 NCTL: 135, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 .' IIEI"" (Da!um ,etm RKB .130 11 MOV. M$L) o 1000 2000 3000 4000 5000 6000 ~ ;, 7000 E-4 8000 9000 10000 80 100 = 135 = -2.1..-85 12130 21 120 140 160 180 10 11 12 13 14 15 IbI¡aI NCTi.:135_21_IIIIEI', Top Eakin = U) NCTi.:135_27_IIDEI', Top Eakin = 1) 16 17 18 19 20 "oillaon ~,~"~ Figure 16 Project: TESH123 Well: Noatak #1 NCTL: 135, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 FEET o 1000 <It', o II ~ ~6 j'..; ~ ;;..- ~ 60 80 100 NCT!. illlercept !!:I: GL = 135 i.ogarilllmic Slope = -2.7e-85 11 12 15 Ib/ga! (S....ic HCT!.: 135 27 UDEF, Top Ellie.. Exp = U) (So..ic HCT!.: 135)7)JDEF, Top Ellie.. Exp = 1) 16 17 Figure 1 Project: TESH 123 Well: Bounty#1 NCTl: 130, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 10/2/04 J. Comisky '" o II g :... 800 900 1100 NCTL 8 10 13 14 15 Iblgal ><---135_21_88 J'PEA !Sollic NCTL: 135_21 JJDEI', YOI' EalDlI Ellp " U) - <2>-13531_18_PPEA !Sollic NCYL: 135_21JJDEI', YOI' EalDlI EliI' " i) ~ 138 21 10 08G ---135-21-10-08G ~~~---- tHCr(U):GEA 20 16 17 18 Figure 18 " , 10/2104 J. Comisky Project: TESH123 Well: Defiance#1 NCTL: 130, -2.7e-5 Modified Eaton Method: e=0.8, 1.0 DEPTH (08fum ,etm RKB. 5311 abo.. MSL) o 90 '" o II ~ ;.. 60 30 100 I4CTlllllercepllll: GL = 135 L"!I....i1IImí" Slope" -2 ~55SS,,-.5 12 13 14 15 IbtgaJ (Sonic HCTa..: 135_21JJI)EF, Top 10""'" Exp" U!j (Sonic NCTI..:135_21_UDEF, Top E""'n Exp" 1) 1G 18 19 20 12053 21 I'Oi8#01l Figure 19 ~ 2000 ~ '-" ~ r/) 4000 ~ ~ 6000 0 1'""""'"1 (l) v.D 6000 Noatak 1 Kokoda 4 Kokoda 5 Kokoda 2 Kokoda 1 Kokoila 3 Defiance 1 Bounty 1 10000 5 5 5 . o , o . In l.iDS ... - 1 o 5 X_line 2 51I~3 5 5 ~H~õ¿ 02~420 . ! . . DI!"!Iif' 1 55~J~:6 ~99200 4 6 6 P. 1 3 6~~p: 1 1 P 0 , 2 - 0 5 4 6 4 12000 13"915 ss-section from Teshl " 40.0 47.5 55.0 62, ~ 10.0 11.5 65.0 92.5 100.0 107.5 115.0 122.5 130.0 131.5 145.0 152.5 160.0 167.5 1'15.0 162.5 1:90.0 197.5 205.0 212.5 220.0 221. ::; 235.0 242.5 250.0 3 Survey Figure 20 , .. " " Noatak 1 Kokoda 4 Kokoda 5 Kolmda 2 Kokoda 1 Kokoda 3 Defiance 1 Bounty 1 2000 4000 6000 00 6000 IDODD 12000 13915 21 "" ~ Defiance 1 5 8 1 4 5 , 4 . 00 50 00 50 00 50 50 00 50 Low Cross- Figure 22 . . Conoc6Phillips Box 100360 Alaska 99510-0360 RECEIVED DEC 2 ~ 2004 December 20, 2004 A'ªska Oil & Gas CO!)¡, Líormni..iQo Anchorage Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Target Location: Bottom Hole Location: Kokoda #1 (Exploratory Test) 295' FNL, 629' FWL, Sec 27, T11N-R5W X=1,746,298, Y=5,954,313 ASPS NAD83 295' FNL, 629' FWL, Sec 27, T11N-R5W 295' FNL, 629' FWL, Sec 27, T11N-R5W Re: Application for Permit to Drill: Surface Location: Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the National Petroleum Reserve - Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling 12-1/4" surface hole to approx. 2500' followed by an 8-1/2" wellbore to the objective with a LWD logging suite for evaluation. E-line logs will be run to determine if the well will be cased (with 7") and tested post-rig or be P&A'd. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" production casing if completed , and 3-1/2" tubing. There is a possibility that CPAI could request authorization for the disposal of drilling waste via the annulus by filing with the AOGCC a 10-403 supplement with additional information as required under 20 AAC 25.080. Please find attached information as required by 20 MC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 MC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 MC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 MC 25.005 (c) (2)- straight hole. 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 141) as required by 20 MC 25.035 (a) (1) and (b) have been submitted previously. ORIGINAL . . 5) A complete proposed casing and cementing program is attached as per 20 MC 25.030. A well bore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program as required by 20 MC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 MC 25.061(a). are attached in this APD package 8) ConocoPhillips does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 9) Complete logging, and mud logging operations are planned and descriptions are attached. The following are ConocoPhillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 MC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs (20 MC 25.071) Greg Wilson, Geologist 263-4748 The anticipated spud date for this well is February 10, 2005. If you have any questions or require further information, please contact Tom Brassfield at (907) 265- 6377 or Paul Mazzolini at (907) 263-4603 Sincerely, J¡1--J Tom Brassfield Senior Drilling Engineer cc: CONFIDENTIAL - Kokoda #1 Well File Paul Mazzolini ATO-1570 Bill Smalstig ATO-1308 N fl [11 Kokoda # 1 Info . . Steve, received your telephone message. Think we are answering your questions- if not please advise! · Kokoda #1 surface coordinates in NAD 27 ASP5 are: X=606,278 & Y=5,954,597 · The Pre-drill seismic pore pressure analysis dated 11/20104 from Comisky indicates"no shallow hazards at the proposed surface locations". We do not anticipate any shallow gas. As always, mitigation procedures for Exploration wells will be in effect Le. Mud Loggers form spud to TD, diverter drills, controlled drilling throughout the surface hole, 10 ppg from spud, and heightened crew awareness. Any questions, please advise. Tom 265-6377 275-7352 (pager) 1 of 1 1/4/2005 11 :45 AM . . SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK 99501 1084 D"',*-~Z2f?b;J-~' $ laD. 00 ... A Sæur1!yFetltllrea l1ULLARS-"-W ---~.M.B8~ 4-, ~... ·0. . H·Ä.S.E. Chas. Manhattan Bank USA, N.A. Valid Up! 5000 Dollars U . - .~~.'"'-"-""." g:^-i..<JL 7;3 I Ibb ¡~~I: 2 ¡8~? I'JO?C¡ 2-?bll~8~ ~Jt~-~ UMVER$At . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME kokDd:L / 2Dt/ - 2.5'3 PTD# Development Service /' Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUE", APPLIES (OPTIONS) MULTI Tbe permit is for a new weJlbore segment of LATERAL existing well . Permit No, API No. . (If API number Production. should continue to be reported as last two. (2) digits a function 'of tbe original API number, stated are between 60-69) above. PILOT HOLE In accordance with . 20 AAC 25.005(1), an (PH) records, data and logs acquired .for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) " and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25..055~ Approval to penorate and produce is contingent upon issuance of ~ conservation order approving a spa cing ex ception. (Companv Name) assumes the liability of any protest to tbe spacing f~)Ception tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe /' SAMPLE Commission must be in no greater 1ban 30' sample intervals from below tbe permafrost or from where samples are fint caught and ] 0' sample iliter:vaJs through target zones. PTD#: 2042530 Administration Unit Appr SFD Date 1/4/2005 Engineering Appr Date TEM 1/4/2005 ~'(q Geology Appr SFD Date 1/4/2005 Geologic 151joner: Field & Pool Well Name: KOKODA 1 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType EXP I PEND GeoArea 890 1 Permitfee attaçhe~ . . . . . . . . . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . . 2 lease .number .apRropriate . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . federal lease M084129 . . . . . . . . . . 3 .U.nique well.n.arne.aod oumb.er . . . . . . . _ . . . . _ _ _ . . _ . . . . '. . _ _ _ _ _ _ _ . . . _ . .Yes. . . _ . . . _ . . . _ _ . _ _ _ _ _ . . _ . . _ _ . . . _ . _ . . _ _ . _ _ . . . . . _ _ _ _ . _ . _ _ . _ _ . . . . . . _ _ . . _ _ . . . . . . . 4 Well located in.a.d.efine.d.pool . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . No . . . . . . . Exp]oration well. . 5 WelUocaled pr.oper .distance from driJling unitb.ound.ary. . . _ _ . . . . . .Yes. _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 Well located proper distance. from Qtber welJs. . . . . . . . . . . Yes . . . l'JeaJest well is Caribou 26-22 #1, - 7 miles to .the. SSE, .Nortb lnigok #1 is next çlosest at 9 miles to .the E. . 7Suffiçient <lçreage.ayailable indJilJiog unjt. . . . _ . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . 8 If deviated, js. weJlbore platincJuded . . . . . . . NA . . VertiC<lI well, . .. ................ . . . . . . . . . . . . . 9 .O-per.ator onl}' affeçted party. . . . . . . . . . . _ _..... . . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . 10 _O-perator bas.appropriate.b.ond inJQrce . _ _ _ _ _ _ _ _ _ _ . . . . . . . _ _ _ . _ _ _ _ _ . . . . . . Yes. . _ _ _ . . . . . _ _ _ . _ _ _ _ _ _ . . . _ . . . . . _ . . _ . _ _ _ . . . . . _ _ . _ _ _ _ _ _ _ _ . . . . . . . . . . . . _ _ _ . . . . . _ . 11 Permit can Þe issued witbout conservation Qrder. . . . _ . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . 12 PermilC<lo Þe issued wjtbout ad.ministratille.approval . . . . . . . . . . . . . . . . . .. '.... .Yes. . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . _ . . . . . . . . 13 Can permit be approved before 15-day wait Yes 14 WelUocaled within area and strata authQrized by.lojectioo Orde r#(putlO#incOO1rneotS).(FQrNA ...... ........ .... _ _. .......... _. 15 .AJI we IJ s. witnin Jl4_mile_area_of reyiew ideotified (For ~eNjc.e.well onl}'). . . . _ . _ _ _ _ . _ _ _ . .NA . . . . . . _ . . _ _ _ _ . _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ . _ _ . . . . . _ _ . _ . _ _ _ . . . . . . . . . . . . . . _ _ _ . _ _ . . 16 PJe-produ~ed iojector; ~ur<ltionof pre--pro~uction les$. than 3 months (For service well QnJy) . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 117 ACMPFïndjngof CQn.sisteocy.h.as Þeenj$.sued for.tbis projeçt . . . . . . . . . . . . . NA . . . KQkoda 1 is outside oOhe coastalzone, So no.relliew is neceS$.afY-.. ....... . . . . . . . . . . 18 .C.ooductor stringpJQvided . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .S.urfaœ casing pJotectsalLknownUSOWs .............. _ ........... Yes..... .I'JQknowoUSDWs.. Casingdeplhsimilar.toolher.weJlstn.thisarea.OffsetwelJda.taindica.tes.sJJrfacecasing.a. 20CMT vol adeQu.ate.to çirc.ulateonconduçtor & SUJf.csg . . . . . . . . . . . . .Yes. . . . proposed will proteçtany sub-permafr.ostwater with <10,000 PRm TDS..SFD. . . . . . . . . . . . . . . . 21 .CMTvoladeQuate.totie-inJongstringtosurfC$.g. ...... .............. No...... .Allhydrocarbon.zooes.!Qbecoyered..An.nulardisposaJrnaybeRrORosed.._. ........... 22CMTwiIJ coyer.aJl kno.wnpro.ductiye borizon.s. . . . . . . . . . . _ . . . . . . . . .Yes. . . . . . . . . . . . . . .. ................ 23 .C.asiog de.sigos adequate for C,T, B.&.permafr.ost . . . . . Yes . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 .Mequ<lte.tan.kage.oJre.servepit. ...... ....... . .Yes...... . Bigjs.equippe.dwitbsteelpitS..Norese.rve.pjt-planoed, Waste.pJanoed.to Þe bauJed to disposal wells, .. 25 Ifa.re-drill~ basa 10-403 for <lbandonme.nt beeo apPJoved . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 A~equ<lte.wellbore~eparatjon.propOsed_. _..... _. _ _. _ _ _ _. _ _ _. _. _ _. _.. _ _. _Yes_ _ _ _ _. .There.areoootberwelJb.ore.sjn.thetmme~iate_aJea, _ _.. _.. _ _.... _. _... _ _ _. _ _ _ _ _ _ _... _ _ __ 27 If.diverter Jeq.uiJed, does jt.meet reguJations. . . . . . . . . . . . . . . .Y.es . . . . _ _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28 .DJilJiog fJuidprogram schematic.& eq.uipJistadequate. . . . . . . . . . . . . . . . Yes _ . . . . . . Maximum expected formation pressure 10.1 EMW.. MWplanned up.to jO.3 ppg. . . . . . . . .. ........ 29 .BOPEs,do.they meetreguJation . . . . . . . _ _ . . . . . . . . . . . . . . _ ...... Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 _BOPE-Pfessratiogap-propriate;.testto.(pu.tpsig in comments) ........... .Yes..... . MASF'calcuJate.d.per20.AAG25,Q05Cc)(4)lA)3354psi..5000P$.iBOPtest. ................... 31 .C.hokemanifold compJie$. w/APIRP-53 (May 84) . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . 32 Work wiJI occur without.operatjonsbutdo.wn. . . . . . . . . . . . . .Yes.. . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . 33 .Is Rresence of H2S gas. RrQb.aÞle . ... . . . . . . _ . . . . . . . . . . . . . . . . . No . . _ . . . . 1:f2S isuolikely withoul penetrating LisbJJrne.. Big js. equipped with .sensors .and alarms. . . . . . . . _ 34 Me~ba.nicaLcpodjtion of wells within AOR yerified (For.s.ervice welJ onl}'). . . . . . . . NA . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . Well bore seg Annular Disposal o o Program EXP On/Off Shore On - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . .. 35 Permil c.ao Þe issued wfo hydrogen. s.ulfide meas.ures. . . . . . . . . . . . . . . . . . . . . . . . . No . . Explora.tory welt oearest offsetis 7 mHes.aW<lY. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36 .DatapJeseoted on. Rote.ntial ovemressurezones . . . . . . . .Yes. . . . . . See.c.ornrn.ents,.below, . . . . . . .. ......... _ . . _ . . . . 37 .Seismic.analysjs. of sbaJlow gas.zooes. . . _ . . . . . . . . .Yes . . . . ShaJlow gas not expecte.d.per TBrassfjeJd emajl of 12,2902.004. Mud J0-9gers wiJI be on dut}' from sp.ud to TO. . 38Seabedconditioo survey (if off-shore) . . . . . _ . . . . .. ............ _ . . . . . . . . NA . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39 . Contact namelphoneJor.weekly progressreRorts [exploratory .only] . . . . .Yes. . . . . . . Tom l3r.ass.field,.2.65-ß3ï'7, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Date: l(tlS Engineering Commissioner: Date Seismic pore pressure analysis indicates 10.0 ppg pressure may be present below base of permafrost (at 500' MD). Pressure is expected to decrease to normal by 2000' MD, and remain normal from 2000' to 7000' MD, then increase again beginning at 7000' MD. Pressure is expected to reach -10.1 (possilby 10.5 ppg) at proposed TD of 8078' MD. Mudloggers and gas detection equipment will be utilized from base conductor to TD. f63liC ì9l.-,,;ooe, Date y~~ . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . . ^ à '-I - ;( f-1 ..r. ".-""'"'' '..~.-......-...'''''~........"...'..........."...............""...................'.....'"......."..._¡. I ~··'O··,··) T'{·"ó·(c"'.,'·'·" ....~."... " . . C 'J~~ i'ì IV tJt~ 111\L ~/ ConocoPhillips Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA KOKODA #1 Provided by: ~ EPOCH Approved by: Andrew Buchanan Compiled by: Brian O'Fallon Fletcher England Date: 03105105 Distribution: Conoc~illips Alaska, Inc. Kokoda #1 · TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW........................... .................... ............... ................... ............ ....... 2 1.1 Equipment Summary.... ....................... ........... ........ ........... ................ ............. .............. ............... ..........2 1 .2 Crew........................................................................................................................................ ................3 2 WELL DETAILS.......................................................................................................... .............. ........... .......4 2.1 Well Summary... .......................................................... .............. ........................................ ..................... 4 2.2 Hole Data................................................................................................................................. ...... .........4 3 GEOLOGICAL DATA. ............ ......... ................................................................................................... ......... 5 3.1 Lithostratigraphy...................................................................................................... ....................... ........ 5 3.2 Mudlog Summary ................................................................................ ................................ ................... 6 3.3 Gas Samples... ......................................... ......... .......... ............... ....................... ................ ..................... 9 3.4 Connection Gases............... ............ .... .......... ....................... ......................................... ....................... 10 3.5 Sampling Program / Sample Dispatch ................................................................................................ 11 4 PRESSURE / FORMATION STRENGTH DATA.....................................................................................12 4.1 Formation Integrity/Leak Off Tests......... .............................. ...... ...................................... ...... .............12 4.2 Wireline Formation Tests. ............................. .................... ...... .............................................. ............... 12 4.3 Pore Pressure Evaluation Introduction ................................................................................................12 · 4.4 Pore Pressure Evaluation Conclusions ...............................................................................................12 4.5 Pore pressure evaluation........... ....................................... .......... ............ .............. ......................... ......14 5 DRILLING DATA...................... .................... .......................... ............ .................... .............. .....................15 5.1 Survey Data........................... ........... .................................................................................................... 15 5.2 Bit Record............ ...................... ......... ............. ............................ ............ .................................... ......... 18 5.3 Mud Record........ .......... .............. ....................... ........ ............. ..... ............ ............. ........... ..... ................ 19 6 MORNING REPORT....................................................................................................... ................. ........ 20 Enclosures 2"/100' Formation Log (MD) 2"/100' Drilling Dynamics Log 2"/100' Gas Ratio Log 2"/100' LWD / Lithology Log 2"/100' Pore Pressure Log · [~ EPOCH 1 .,.,./ ConocoPhillips Alaska, Inc. Kokoda #1 . 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary . Parameter Equipment Type 1 Position Total Comments Downtime QGM Agitator (Mounted in Combined downtime plugged gas line Ditch gas possum belly) 45 min. occurrences. Blew back or switched Flame ionization total gas & lines and filled in gas data relative to chromatography. Quadco Gas measurements. Effective Circulating From Sperry-Sun 0 Density (ECD) Epoch sensor positioned on faulty Hook Load 1 Weight Hydraulic pressure transducer 12 hours hydraulic source for quick connect. on bit Repositioned sensor and functioned properly (1050'). Mud Flow In Derived from StrokeslMinute and 5min. (see pump stroke counters below) Pump Output Mud Flow Out From Quadco 0 Mudlogging unit HP Compaq Pentium 4 (X2, DML 0 On UPS when power down on rig computer system & Rigwatch) Mudlogging unit DAC In-unit data collection/distribution 0 On UPS when power down on rig box center Pit Volumes, Pit From Quadco 0 GainlLoss Pump Pressure From Quadco 0 Pump stroke counters Magnetic proximity sensor 5 min. Cable came loose on two occasions and reattached immediately. Quadco Well Quadco System in Mudlogging Monitoring 0 On UPS when power down on rig. Components Unit Primary draw-works block Rate of penetration position indicator 0 Optical encoder on draw-works RPM From Quadco 0 Torque From Quadco 0 Questionable calibration as sometimes recorded "0" torque. . [1 EPOCH 2 ,,../ ConocoPhiiii ps Alaska. Inc. Kokoda #1 · 1.2 Crew Unit Type Unit Number Arctic Series 10 Skid ML012 Mudloggers Years D~ls Sample Catchers Years Days Technician Days *1 Brian Q'Fallon 17 13 Randv UnQer 5 13 Peter Ramsev Fletcher England 4 13 Robert Haverfield 1 13 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well Additional Comments · · [~ EPOCH 3 Conoc~illips Alaska, Inc. Kokoda #1 · 2 WELL DETAILS 2.1 Well Summary Well: Kokoda #1 API Index #: 50-279-20011-00 Lat: 70.297783N Field: NPRA Suñace Co-Ordinates: Long: 153.143000W SEC 27 T11N R5W 295' FNL 629' FWL Borough: North Slope Primary Target Depth: 6783' MD State: Alaska TD Depth: 8045' MD (Vertical) Rig Name 1 Type: Doyon #141 1 Arctic Triple Suspension Date: Primary Target: Lower Cretaceous Torok License: (Brookian) Sands Spud Date: 2/16/05 Ground Elevation: 136.9' pad, 133.6' ground Completion Date: 3/6/2005 RT Elevation: 164.9' Completion Status: Plug and Abandon Secondary Target Depth: Classification: Exploration TD Date: 2/28/05 TD Formation: Miluveach Shale Days Testing: 0 Days Drilling: 13 · 2.2 Hole Data Maximum Depth TD Mud Deviation Casing! Shoe Depth FIT Hole Section MD TVDSS Weight Coring MD TVDSS (ft) (ft) Formation (ppg) (Oinc) Liner (ft) (ft) (ppg) Conductor 108 +57 Colville Gr NA 16" 108 +57 N/A 121/4" 2510 -2345 Nanushuk 10.0 Vertical 9 5/8" 2505 -2340 15.7 8 1/2" 8045 -7880 Miluveach 9.8-10.3 well 6837'- N/A 6873' Additional Comments Surface hole was drilled to 2510' with 10.0 mud with no problems. Hole was tight from sands on trip out. Required pumping out to HWDP, wiper trip to bottom, and backreaming out of hole. Due to massive, porous sands, the surface casing required two top cement jobs to get sufficient cement to surface. The 8 W' hole section was drilled to 6678' with no significant problems. Several brief slides were necessary to maintain a vertical hole. Due to large volumes of clay cuttings in the mud column, ECD's were a concern. Rate of penetration was controlled in the upper part of the section to ensure sufficient hole cleaning. Wiper trips were performed as needed with some tight spots requiring backreaming. Mud weight was 9.8 - 10.0. At 6678', the mud motor was laid down and MWD sensors were moved immediately behind the bit to assist with picking the core point. Core point was picked at 6837'. Core was drilled with 10.3 mud from 6837' to 6873' when the barrel jammed. The core was retrieved. A directional BHA and 10.3 ppg mud was used to drill total depth at 8045' MD. Shale bridging was a problem on the subsequent trip in at 5030'. The string was worked free and the cavings circulated out. Sloughing shales and claystone were a significant problem after TD. The first wireline run was unsuccessful due to tight hole. Two cleanout runs were performed and mud weight raised to 10.5 before logging the hole. · [~ EPOCH 4 Conoc~illips Alaska, Inc. Kokoda #1 · 3 GEOLOGICAL DATA 3.1 Lithostratiaraphv LWO tops refer to provisional picks provided by the Wellsite Geologist. PROGNOSED LWD PICK FORMATION MD TVDSS MD TVDSS (ft) (ft) (ft) (ft) Base Permafrost 740 -575 920 -755 Nanushuk 1315 -1150 1440 -1275 Torok Formation 3415 -3250 3309 -3144 Torok objective 6915 -6750 6783 -6618 Top HRZ 7615 -7450 7584 -7419 LCU 7865 -7700 7832 -7667 TO (-200' below LCU) 8065 -7900 8045 -7880 · · [~ EPOCH 5 Conoc;pJ,illips Alaska, Inc. Kokoda #1 · 3.2 Mudloa Summary Suñace to Base of Permafrost First Returns 108' to 920' MD (+57' to -755' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum I Minimum Average Maximum Minimum Average 245 I 8.7 108 49 0 20 This interval was dominated by massive sands with interbedded clay, silt, and ash. Sands were very fine to coarse to pebbles near the surface and poorly sorted. Samples consisted of mostly unconsolidated grains with occasional friable grain to matrix supported cuttings. Abundant coal/carbonaceous shale was logged in the first 300 feet. Claystones were typically very soft, pasty, and massive. Scattered shell fragments were observed. No significant gas peaks were observed. Base of Permafrost to top Nanushuk 920' to 1440' MD (-755' to -1275' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 252 25 162 81 1 47 · This brief section was distinguished by a large increase in clay cuttings immediately below the permafrost, followed by continued massive sands with a noticeable increase in silt content. No significant gas peak was associated with penetration of the permafrost boundary. Background gas rose from -40u to -60u below the permafrost approaching the Nanushuk. Nanushuk to top Torok 1440' to 3309' MD (-1275' to -3144' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 361 8.8 133 422 2 73 Massive sands with continued claystone and silty shale interbeds were encountered in the upper part of this section. The first incipient shaly cuttings appeared in samples below 1250'. A small amount of ethane was first recorded below 1300'. Gas levels began to rise after penetrating sands below 1400' with a maximum of 422u recorded at 1594'. Butane also first appeared on chromatograms coincident with the same high gas zone. Propane was not recorded until sands below 21 00' were penetrated. Gas levels gradually fell below 1 OOu with increasing silt content below 2300'. Propane and butane faded to traces below 2350'. Surface casing was set in a siltstone at2510'. Sands in this section are typically light brownish gray to moderate yellowish brown overall with individual grains ranging from translucent, amber-hued to clear quartz and a variety of undifferentiated dark gray to black lithic clasts and detritus. They ranged from very fines and silty to coarse, with the bulk being fine upper to medium lower grain sizes. Samples revealed mostly unconsolidated cuttings with traces of hard, carbonate cemented matrix supported sandstone. Below the surface casing point, sands decreased dramatically with a concurrent increase in claystone. Claystone cuttings were typically various shades of brownish gray to gray, poorly preserved, and very soft. Trace cuttings with fissility were noted. Silty interbeds with thin very tine sand stringers punctuated the claystones through this section. · [~ EPOCH 6 y ConocoPhillips Alaska, Inc. Kokoda #1 · Torok to Torok objective 3309' to 6783' MD (-3144' to -6618' TVDSS) Drill Rate (ftlhr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 256 14.8 93.4 81 10 33 The Torok interval drilled was dominated by thick, brownish gray claystones and shales with increasing fissility and cuttings preservation with depth through the section. Clays and shales were often silty, grading to a siltstone or silty shale. Siltstone interbeds with disseminated very fine grain sand were scattered through the section. Below about 6000', the thickness of shale beds decreased with a concurrent increase in sandy siltstonelvery fine grain sandstone intervals. None of the sandstones through this section displayed any fluorescence. Propane and butane reappeared after penetrating the top ofthe Torok and persisted throughoutthe interval. Pentane was recorded below 5850' and continued in at least trace amounts to the objective. Background gas of 30u was very stable through this section. A zone of slightly elevated gas was penetrated between 5000'- 5200' with a high of 81 u recorded at 5062'. Torok objective to top HRZ 6783' to 7570' MD (-6618' to -7405' TVDSS) Drill Rate (ftlhr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 174 1.8 82.3 1130 20 188 · The Torok objective included three oil bearing dominantly sandstone intervals separated by two intervals of interbedded siltstone, claystone, shale, and sandstone. The three sandstone intervals are characterized by high show gas, from 90 to 1130 units, and massive sandstones with thin interbeds of siltstone, claystone, and shale. Background gas between the sandstone intervals varied from 20-50 units with minor show gas up to 80 units in thin zones. The sandstones intervals are 6815' to 6870', peaking at 265 units, 7180'to 7300', peaking at 523 units, and 7445-7570', peaking at 1130 units. The upper sandstone was cored from 6837' to 6873', All three sandstone bodies were medium light gray to medium gray, with pervasive brownish hues, to light brownish gray, and of similar character and composition. Grain sizes were overall notably slightly larger in the basal sand sequence, before grading to predominantly siltstone above the HRZ contact. Composition was dominantly clear to translucent quartz, with 10 to 20 percent of dominantly black to dark brown carbonaceous lithics and minor other lithics and silicates. Grain sizes in the upper two sandstones were very fine to fine, and in the basal sandstone fine to very fine with scattered medium lower. The overall character of the sandstones included grain supported with predominantly subangular grains, moderately well to moderately sorted with a slight clay and slightly argillaceous (carbonaceous/organic) matrix, poorly to moderately well consolidated with a very slight to slight calcareous cement, and very poor to poor visible porosities. Fluorescence decreased overall with depth from a pervasive bright yellow in the upper sandstone to a spotty dull yellow green in the basal sandstone, though diffuse to blooming cuts were pervasive in cleaner sands throughout, with some stow streaming cuts more pervasive in the upper two sandstone intervals commonly associated with increasing clay matrix. The interval between the first and second sandstone objectives, from 6870' to 7180', was much sandier than the lower interval. Sandstone was light gray to light brownish gray, and very fine to fine lower grains with a clay and silt matrix. Sandstones were thin, and gradational and interbedded with siltstone and claystone, brownish · gray to medium gray with brownish hues, and exhibiting some platyness and incipient fissilily grading to shale. [~ EPOCH 7 · · · Conoc;Pt,illips Alaska, Inc. Kokoda #1 The brownish color was due to varying small percentages of organic and carbonaceous matter, as a clay contaminant or disseminated and as streaks or partings. Traces of micro flakes of mica occurred in all but the cleaner sandstone. Cuttings were non to slightly to moderately calcareous, especially in silty and sandy zones, firm when calcareous, to soft and soluble with less calcite and increasing clay. The lower interval between the second and third objective sands, from 7300' to 7445', is predominantly shale and siltstone, medium dark gray with brownish hues to brownish gray, with overall slight to moderate organic clay contamination, slight carbonaceous matter, traces to slight micro flakes of mica and micro pyrite, and non to slightly calcareous. Some carbonaceous shale, grayish black with brownish hues, moderately to highly organic and often with fissility characterized by carbonaceous or remnant carbonaceous partings, were observed more commonly in the upper portion of the interval. Siltstone graded occasionally to silty very fine to fine grained sandstone. Top HRZ to LCU 7570' to 7832' MD (-7405' to -7667' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum Average Maximum Minimum AveraQe 177 19.6 88.6 518 86 217 The HRZ is dominated by brownish black to brownish gray carbonaceous shale, with moderately to highly organic clay, and common flSSility, especially in the upper shales, due to remnant carbonaceous matter and bookleaf partings of carbonaceous matter. The interval is commonly slightly silty, with some thin beds of variably argillaceous siltstone and sandstone. Traces to slight micro pyrite, especially associated with carbonaceous matter, and traces of micro flakes of mica, occur throughout. LCU to Miluveach TD 7832' to 8045' MD (-7667' to -7880' TVDSS) Drill Rate (ftIhr) Total Gas (units Maximum Minimum Average Maximum Minimum AveraQe 168 24 76.5 165 54 123 Shales encountered below the LCU were shades of yellowish brown and typically produced well preserved blocky to wedgelike cuttings with rounded edges. Well developed fissility and a subresinous luster were noted. They were thinly laminated, micaceous, with common pyrite coatings and c~rbonaceous laminae. Thin, silty shale interbeds with traces of very fine sand were observed. Light-colored clay interbeds were also observed. U EPOCH 8 · · · Conoc~hillips Alaska, Inc. Kokoda #1 3.3 Gas Samples 1unit = 0.05% Methane Equivalent Sample Depth Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=0.05% (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) M.E. 1 500 8 2121 2 1000 61 13332 3 1500 85 14057 277 4 2000 75 14526 274 30 5 2505 35 7374 179 6 3000 54 11 033 123 7 3500 50 9536 215 101 20 30 8 4000 28 8145 233 107 6 5 9 4500 26 7914 199 78 8 7 10 4600 23 6826 200 82 14 11 11 4700 28 8021 224 95 9 6 12 4800 33 9593 217 85 16 8 13 4903 48 11775 261 102 20 8 14 5003 25 7197 165 95 8 4 15 5105 42 9364 217 94 18 15 16 5206 23 5564 132 61 18 6 17 5301 36 7587 183 107 22 12 18 5398 28 6598 164 111 23 11 19 5511 28 6926 154 75 28 14 20 5600 22 5500 184 107 32 15 21 5700 26 6129 168 82 32 15 22 5802 22 6094 168 113 27 13 23 5900 24 6887 224 128 40 22 5 2 24 6000 29 7226 255 165 65 42 28 12 25 6100 34 7614 254 135 35 29 10 3 26 6200 40 7909 272 147 30 28 8 2 27 6310 37 8402 356 190 44 15 7 3 28 6405 33 8226 418 239 97 57 11 1 29 6499 27 6724 362 226 61 41 11 2 30 6700 24 6404 318 174 25 20 5 2 31 6789 47 9135 700 474 94 130 24 13 32 6800 55 10334 815 541 91 151 28 14 33 6809 63 10378 935 665 145 227 64 28 34 6822 207 17631 2635 2163 403 688 201 194 35 6832 265 17697 2704 2382 468 856 237 242 36 6840 111 20491 1811 1527 188 419 106 110 37 6850 50 8087 702 599 73 164 31 28 38 6860 98 15229 1566 1559 239 537 146 132 39 6866 125 19432 2128 2093 290 665 175 172 40 6870 78 12086 1205 1162 168 391 110 90 41 6900 39 7188 481 393 65 165 60 45 42 7002 47 5890 499 408 66 172 71 50 43 7100 38 6002 420 310 42 180 45 30 [~ EPOCH 9 · · · ",/ ConocoPhillips Alaska, Inc. Kokoda #1 Sample Depth Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=O.05% (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) M.E. 44 7183 90 19430 1267 682 76 204 56 60 45 7195 220 42242 3115 1706 184 449 106 90 46 7223 410 66314 5856 3369 343 857 173 175 47 7240 450 72099 6484 3738 412 1011 206 241 48 7300 115 17199 1751 1126 126 356 85 80 49 7400 49 7064 808 542 80 155 67 50 50 7450 1070 200887 32704 19584 1596 4651 712 778 51 7475 750 164410 23822 13593 1034 3306 546 700 52 7500 710 169286 22231 11441 830 2659 523 707 53 7530 495 89130 10816 5660 408 1477 321 519 54 7540 830 177560 30474 20151 1655 5291 970 1088 55 7600 347 44893 6093 3387 332 855 170 193 56 7700 171 22172 3008 2103 295 831 216 302 57 7800 126 13551 1837 1604 209 874 234 326 58 7898 127 13956 2004 1787 300 825 228 301 59 8000 134 15909 2073 1689 231 720 200 265 60 8045 107 11276 1478 1322 199 657 186 253 3.4 [~ EPOCH 10 · Conoc;,)hillips Alaska, Inc. Kokoda #1 3.5 Samplinq Proqram 1 Sample Dispatch Set Type 1 Purpose Frequency Interval Dispatched to CPAI Unwashed Biostratigraphy 30' 108' - 8045' MD ABV 100 A 619 East Ship Creek Ave Ste 102 Set owner: CPAI 10' 6840 - 6870' MD Anchorage, AK 99502 Attn: D. Przvwoiski CPAI Unwashed Biostratigraphy 30' 108' - 8045' MD ABV 100 B Set owner: Pioneer 10' 6840 - 6870' MD 619 East Ship Creek Ave Ste 102 Resources Anchorage, AK 99502 Attn: D. Przvwojski CPAI Unwashed Biostratigraphy 30' 108' - 8045' MD ABV 100 C 619 East Ship Creek Ave Ste 102 Set owner: Anadarko 10' 6840 - 6870' MD Anchorage, AK 99502 Attn: D. Przvwoiski CPAI Washed, screened & dried 30' 108' - 8045' MD ABV 100 D Reference Samples 10' 6840 - 6870' MD 619 East Ship Creek Ave Ste 102 Set owner: CPAI Anchorage, AK 99502 Attn: D. Przvwoiski Washed, screened & dried CPAI Reference Samples 30' 108' - 8045' MD ABV 100 E 619 East Ship Creek Ave Ste 102 Set owner: Pioneer 10' 6840 - 6870' MD Anchorage, AK 99502 Resources Attn: D. Przvwojski CPAI Washed, screened & dried 30' 108' - 8045' MD ABV 100 F Reference Samples 10' 6840 - 6870' MD 619 East Ship Creek Ave Ste 102 Set owner: ASRC Anchorage, AK 99502 Attn: D. Przvwojski CPAI Washed, screened & dried 30' 108' - 8045' MD ABV 100 G Reference Samples 10' 6840 - 6870' MD 619 East Ship Creek Ave Ste 102 Set owner: AOGCC Anchorage, AK 99502 Attn: D. przvwoiski CPAI Washed, screened & dried 30' 108' - 8045' MD ABV 100 H Reference Samples 10' 6840 - 6870' MD 619 East Ship Creek Ave Ste 102 Set owner: BLM Anchorage, AK 99502 Attn: D. Przywojski CPAI Washed, screened & dried 30' 108' - 8045' MD ABV 100 I Reference Samples 10' 6840 - 6870' MD 619 East Ship Creek Ave Ste 102 Set owner: Anadarko Anchorage, AK 99502 Attn: D. Przvwoiski Gas bags 500' 500' - 4500' MD Isotech Laboratories, Inc. Routine intervals and J significant peaks above 100' 4500' - 8045' MD 1308 Parkland Court backQround 10' 6840 - 6870' MD Champaign,IL 61821 K Onsite Samplex Samples 30' 108' - 8045' MD To on-site geologist 10' 6840 - 6870' MD · · Sample frequency was locally altered according to drill rate constraints and zones of Interest. [~ EPOCH 11 y ConocoPhillips Alaska, Inc. Kokoda #1 . 4 PRESSURE I FORMATION STRENGTH DATA 4.1 Formation InteQritv/Leak Off Tests E uivalent mud we' MD (ft is calculated from rota table. FIT 1 LOT ( EMW) 15.7 FORMATION Nanushuk 4.2 Wireline Formation Tests No Data. 4.3 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of a well; Background Gas (BG) Resistivity (RES) Hole Conditions (HC) Trip Gas (TG) Mud Weight (MW) Connection Gas (CG) Corrected 0 exponent (DXC) Equivalent Circulating Density (ECD) . Quantitative Methods The primary indicators used for pore pressure evaluation were gas trends, as DXC and RES data plots did not suggest any reliable trends, especially in the 8 Y2" hole section. Factors such as controlled drill rates, POC bits, and absence of clean shale baselines to establish compaction trends precluded reliable estimation. The variable nature of the shales (predominantly claystone) contributed to the absence of a reliable baseline, variably silty from surface down through the Torok objective, where significant gas was encountered, to carbonaceous throughout the HRZ and into the LCU. Qualitative estimation was weighted heavily on gas trends relative to MW and ECO, including increases in background gas, appearance and trends of connection gases, magnitude of trip gases, and surface manifestations of hole conditions. ECD data was measured downhole, continuously while drilling (MWD), and provided by Sperry-Sun. 4.4 Pore Pressure Evaluation Conclusions 1) Surface Hole -12 %" (108' to 2510') Pore pressure was estimated to vary from 8.7 ppg to 9.6 ppg in the surface hole, through the permafrost section and upper Nanushuk formation. Surface was drilled with a 10# mud, and ECD in the 12 %" hole was measured consistently between 1 0.2 and 1 0.3. No connection gas was encountered, and only 53 units of wiper gas recorded at casing depth. . Pore Pressure was estimated to peak with a high gas of 422 units associated with a Nanushuk Sand at 1594'. Background gas had overall been increasing since the base of the permafrost to that point, and then gradually decreased down to casing depth. Background gas averaged 20 units in the permafrost, then 43 units to the top of the Nanushuk, and 13 units overall in the Nanushuk overlapping with the 8 Y2" hole. It is estimated that the pore pressure at casing point returned to a normal gradient of 8.7 ppg, especially as only ~ EPOCH 12 Conoc;Phillips Alaska, Inc. Kokoda #1 . 53 units of wiper gas was recorded. Dxc data tends to support these conclusions on the Dx versus Depth chart for 12.25" hole, where a trend line was established in the permafrost and extended to casing depth. A polynomial trend drops below the trend line at the base of the permafrost, indicating higher pressure, and returns above the trend line before casing depth. Resistivity data is more random, and scattered in the permafrost section. 2) 8 %" hole (2510' to 8045', Total Depth) Pore pressure is estimated to vary from 8.7 ppg to 10.0 ppg, maintaining a normal 8.7 gradient in the Torok Shale, increasing to 9.7 in the objective sands, and increasing slightly to 10.0 ppg in shales to total depth. Mud weight was maintained at 9.8-10 ppg in the lower Nanushuk and Torok shales, and increased just above the Torok objective to 10.3-10.4 ppg, and maintained to total depth. ECD's in the smaller 8.5" hole increased overall gradually in the Nanushuk from 10.2 ppg to approximately 11.2 ppg at the top of the Torok, despite the constant mud weight. ECD's varied from 10.6 to 12.1 from the top of the Torok to Total Depth, averaging approximately 11.4, with no noticeable change after the increased mud weight. Average background gas decreased in the Nanushuk and averaged only 33 units in the Torok Shale, supporting the normal pressure gradient of 8.7 ppg. . Gas Sands in the Torok objective indicated a pressure trend, but it should be noted that the ECD throughout the Torok objective remained relatively constant at approximately 11.2 ppg. Show Gas in the first Torok Sand peaked at 265 units while circulating out core point at 6837'. After circulating bottoms up gas dropped quickly to a background of 35 units. No detectable connection gases, and only 44 units of wiper gas and 80 units of trip gas indicated little change in pore pressure, estimated at 9.1 ppg. However, a slight background increase approaching the second Torok Sand at 7190', and a higher show gas of 523 units in a sand similar to the first, indicated some pressure increase. Moreover, the first detectable connection/swab gas for the well, 80 units, was encountered entering this sand, although no flow was detected at the connection. With background dropping quickly after drilling through the sand, and no flow after a flow check after the gas peaked and with a 10+ mud cut (down from 10.4), pore pressure is still estimated well below the 10.4 mud weight, at approximately 9.5 ppg. Peak gas in the third Torok Sand above the HRZ was 1130 units with a 9.3 mud cut at 7458', but again dropped off quickly to 60 units after circulating bottoms up. A flow check this time after bottoms up and with a 10.3 mud detected no flow. Connection gases persisted after the first connection gas in the second Torok Sand, but of only 10 to 20 units. Pore Pressure is estimated at 9.7 ppg, in large part due to a relatively higher background gas after circulating out the high gas. Trip gases and possibly an overall higher background gas and lower resistivity indicate slight pore pressure increases down to total depth, estimated to as high as 10 ppg, the highest pore pressure in the well. Background gas and resistivity data, however, are inconclusive due to the predominant carbonaceous nature of the shales. The Dxc Chart data for the 8.5 inch hole, also is inconclusive. A trend line established through the Torok Shales and carried through total depth attempts to illustrate a pore pressure increase in the HRZ and LCU, but data is quite random. However, wiper gas of 800 units from a 20 stand wiper bip after TD appeared to come from bottom, and 1470 units of trip gas after reaming to bottom after a failed logging run, peaked after reaming on bottom, with only a maximum of 290 units while reaming through the Torok Sands. The 290 units lagged to the third Torok Sand. Trip gas peaks however, were very sharp, with gas returning quickly to a background of approximately 100 units and slowly diminishing. . [~ EPOCH 13 . . Conoc;Phiiii ps Alaska, Inc. Kokoda #1 . 4.5 Pore Dressure evaluation Formation Primary Secondary Interval Tops Pore Pressure (EMW) Trend Source of Interval Lithology Lithology MD TVDSS Min Max Trend Indicators Quantitative (%) (%) (ft) (ft) (DDa) (DDa) Estimate Permafrost Sd 50% Clyst 30% 108 +57 8.7 8.9 Slight Up BG RES,DXC Base Permafrost Sd 50% Sltst 30% 920 755 9.0 9.2 Sliaht Up BG RES,DXC Nanushuk Clvst 40% Sst/Sd 30% 1440 1275 8.6 8.7 Up-Dn BG,TG RES,DXC Torok Formation Clvst/Sh 70% Sltst 20% 3309 3144 8.7 8.7 Flat BG,TG RES,DXC Torok obiective Sst 50% Sltst 30% 6783 6618 8.8 9.7 Up BG,CG,TG RES,DXC Top HRZ Sh/Clvst 80% Sltst 10% 7570 7405 9.8 9.9 Sliaht Up BG,CG,TG RES,DXC LCU Sh/Clvst 90% Sltst 10% 7832 7667 9.9 10.0 Sliaht Up BG,CG,TG RES,DXC Total Depth 8045 7880 RES,DXC NOTE: Clyst = Claystone/Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sst = Sandstone [~ EPOCH 14 ConocJ'Phillips Alaska, Inc. Kokoda #1 . 5 DRilLING DATA . . 5.1 Survey Data Measured True Vertical Dogleg Incl. Azim. Vertical Northings Eastings Depth (0) (0) Depth (ft) (ft) Section Rate (ft) (ft) (ft) (0/100ft) 232.15 0.62 56.61 232.15 0.69 1.05 0.69 0.27 318.48 0.44 40.12 318.47 1.20 1.65 1.20 0.27 412.26 0.19 42.97 412.25 1.58 1.99 1.58 0.27 501.39 0.19 333.07 501.38 1.83 2.01 1.83 0.24 589.56 0.36 331.59 589.55 2.20 1.82 2.20 0.19 683.05 0.36 306.18 683.04 2.63 1.44 2.63 0.17 770.17 0.47 331.03 770.15 3.11 1.04 3.11 0.24 862.24 0.31 313.09 862.22 3.61 0.68 3.61 0.22 953.22 0.44 14.91 953.20 4.11 0.59 4.11 0.44 1044.36 0.47 354.11 1044.34 4.82 0.64 4.82 0.18 1135.99 0.38 348.80 1135.97 5.49 0.54 5.49 0.11 1228.91 0.26 332.45 1228.88 5.97 0.39 5.97 0.16 1322.04 0.09 281.93 1322.01 6.18 0.22 6.18 0.23 1415.02 0.14 274.18 1414.99 6.20 0.04 6.20 0.06 1505.99 0.12 89.670 1505.96 6.21 0.03 6.21 0.29 1601.06 0.31 35.17 1601.03 6.42 0.28 6.42 0.28 1694.13 0.20 325.53 1694.10 6.76 0.34 6.76 0.33 1787.01 0.19 280.74 1786.98 6.92 0.10 6.92 0.16 1879.99 0.25 274.89 1879.96 6.97 -0.25 6.97 0.08 1972.14 0.28 231.80 1972.11 6.85 -0.63 6.85 0.21 2065.11 0.19 207.52 2065.08 6.57 -0.88 6.57 0.14 2158.17 0.17 308.65 2158.14 6.53 -1.06 6.53 0.30 2249.93 0.09 253.96 2249.90 6.60 -1.23 6.60 0.16 2345.76 0.14 254.66 2345.73 6.55 -1 .42 6.55 0.05 2407.62 0.31 302.05 2407.59 6.62 -1.63 6.62 0.38 2521.53 0.14 73.15 2521.50 6.82 -1 .76 6.82 0.36 2615.18 0.17 67.35 2615.15 6.91 -1.52 6.91 0.04 2705.39 0.09 301.61 2705.36 6.99 -1.45 6.99 0.26 2800.68 0.36 311.70 2800.65 7.23 -1.73 7.23 0.29 2894.44 0.33 351.42 2894.41 7.70 -1.99 7.70 0.25 2985.93 0.25 0.21 2985.89 8.16 -2.03 8.16 0.10 3078.99 0.22 285.24 3078.95 8.42 -2.21 8.42 0.31 3172.18 0.76 279.43 3172.14 8.57 -3.00 8.57 0.58 3263.32 0.76 282.90 3263.27 8.80 -4.19 8.80 0.05 3357.88 0.84 284.13 3357.82 9.11 -5.47 9.11 0.08 3451.88 0.86 284.50 3451.81 9.46 -6.82 9.46 0.02 3542.68 1.21 258.83 3542.60 9.44 -8.43 9.44 0.63 3634.24 1.19 258.77 3634.14 9.07 -10.31 9.07 0.03 [~ EPOCH 15 . . . ,../ ConocoPhillips Alaska, Inc. Kokoda #1 Measured True Vertical Dogleg Incl. Azim. Vertical Northings Eastings Depth (0) (0) Depth (ft) (ft) Section Rate (ft) (ft) (ft) (0/100ft) 3728.54 1.36 262.81 3728.41 8.74 -12.37 8.74 0.20 3820.01 1.06 258.64 3819.86 8.44 -14.28 8.44 0.34 3910.41 0.45 256.62 3910.25 8.19 -15.45 8.19 0.68 4007.57 0.80 267.32 4007.41 8.07 -16.50 8.07 0.38 4100.65 0.57 280.14 4100.48 8.12 -17 .61 8.12 0.30 4193.62 0.69 264.30 4193.45 8.14 -18.62 8.14 0.23 4286.71 0.69 281.40 4286.53 8.20 -19.73 8.20 0.22 4379.82 0.93 273.13 4379.63 8.35 -21.03 8.35 0.29 4470.30 1.11 279.83 4470.10 8.54 -22.63 8.54 0.24 4564.86 1.00 272.05 4564.64 8.73 -24.36 8.73 0.20 4653.21 1.03 284.95 4652.98 8.96 -25.90 8.96 0.26 4750.58 0.67 289.50 4750.34 9.38 -27.28 9.38 0.38 4844.04 0.66 300.32 4843.79 9.83 -28.26 9.83 0.13 4938.27 0.40 282.31 4938.02 10.17 -29.04 10.17 0.32 5028.42 0.25 264.38 5028.16 10.22 -29.54 10.22 0.19 5122.68 0.49 248.37 5122.42 10.05 -30.13 10.05 0.27 5215.22 0.72 266.34 5214.96 9.86 -31.08 9.86 0.32 5308.50 0.94 280.96 5308.23 9.97 -32.42 9.97 0.32 5398.81 0.99 290.41 5398.52 10.38 -33.88 10.38 0.19 5493.41 1.02 281.72 5493.11 10.84 -35.47 10.84 0.17 5586.28 1.02 272.00 5585.96 11.04 -37.11 11.04 0.19 5676.19 1.22 265.48 5675.86 10.99 -38.87 10.99 0.26 5769.61 0.87 242.99 5769.26 10.59 -40.50 10.59 0.57 5864.33 0.87 227.02 5863.97 9.77 -41.67 9.77 0.26 5957.80 0.84 226.10 5957.43 8.80 -42.68 8.80 0.04 6050.98 1.05 233.62 6050.60 7.82 -43.87 7.82 0.27 6143.65 1.33 246.87 6143.25 6.89 -45.54 6.89 0.42 6236.59 1.25 247.69 6236.17 6.09 -47.47 6.09 0.09 6329.17 1.17 252.40 6328.72 5.42 -49.30 5.42 0.14 6421.74 0.94 249.55 6421.28 4.87 -50.92 4.87 0.25 6513.53 0.70 237.36 6513.06 4.30 -52.10 4.30 0.32 6593.23 1.03 226.08 6592.75 3.54 -53.02 3.54 0.46 6593.23 1.03 226.08 6592.75 3.54 -53.02 3.54 0.46 6701.17 1.18 225.17 6700.67 2.09 -54.51 2.09 0.14 6795.55 0.93 221.91 6795.03 0.83 -55.71 0.83 0.27 6886.42 0.88 231.31 6885.89 -0.15 -56.74 -0.15 0.17 6979.25 0.67 232.38 6978.71 -0.92 -57.72 -0.92 0.23 7073.60 0.69 226.68 7073.06 -1.65 -58.57 -1.65 0.08 7166.54 0.57 256.98 7165.99 -2.14 -59.43 -2.14 0.38 7259.54 0.62 228.48 7258.99 -2.57 -60.25 -2.57 0.32 7352.26 1.03 227.89 7351.70 -3.47 -61.25 -3.47 0.45 [~ EPOCH 16 · · · Conoc;r;.,illips Alaska, Inc. Kokoda #1 Measured True Vertical Dogleg Depth Incl. Azim. Vertical Northings Eastings Section Rate (0) (0) Depth (ft) (ft) (ft) (ft) (ft) e/1 GOft) 7439.83 0.93 224.36 7439.25 -4.50 -62.33 -4.50 0.14 7536.35 1.00 218.92 7535.76 -5.71 -63.40 -5.71 0.12 7629.46 0.86 216.69 7628.86 -6.90 -64.33 -6.90 0.15 7722.87 0.76 228.76 7722.26 -7.88 -65.22 -7.88 0.21 7814.33 0.86 231.57 7813.71 -8.70 -66.21 -8.70 0.11 7907.68 0.51 266.35 7907.05 -9.16 -67.17 -9.16 0.56 7963.41 0.38 295.43 7962.78 -9.10 -67.59 -9.10 0.46 [:I EPOCH 17 . . . Conoc;-Pt,illips Alaska, Inc. Kokoda #1 5.2 Bit Record Depth In Total Bit WOB PP Bit Make Type Jets 1 TFA MD 1 TVDSS Footage Hrs (Klbs) RPM (psi) Wear BHA ft 1 MXC1 3x18, 1x12 108' 1 +57' 1-1-WT -A-E-I-HC- TO 1 /0.856 2 OS70FNPV 6x15 / 2510' / 2345' 1-2-WT -N-X-I-NO- 2 1.035 BHA 2rr1 OS70FNPV 6x15 / 6678' /6513' 3 1.035 4 ARC-425C3 Core 6837'/6672' 4 2rr1 OS70FNPV 6x15 / 6873' / 6708' 2-2-CT -A-X-I-NO- TO 5 1.035 [~ EPOCH 18 . . ",,/ ConocoPhiiii ps Alaska, Inc. Kokoda #1 . 5.3 Mud Record Contractor :MI Mud TVDe :Spud/KCI 0 vmer Date Dept MW ECD VIS PV YP Gels FL FC Sols OIW Sd pH CI Ca h (ppa) (ppa) (s/qt) (cc) (%) Ratio (%) (mill) (mill) 12 %" section 2/16/05 237 10.0 10.34 76 26 41 14/18/19 4.8 1/ 8 0/92 0.10 9.0 31000 80 2/17105 1950 10.0 10.38 67 20 41 18/27/31 5.8 1/ 10 /90 3.00 9.0 28000 280 2/18/05 2510 10.0 61 21 54 18/27/30 6.4 1/ 9 /91 2.50 9.5 24000 300 2/19/05 2510 9.7 46 14 25 1 0/13/04 7.8 1/ 7.5 /93 0.25 8.8 23000 500 2/20/05 2510 9.8 50 16 22 9/12/13 6 1/ 8.5 /91.5 0.20 8.6 31000 300 8 %" section 2/21/05 3165 9.8 10.26 46 15 21 8/13/16 7.2 1/ 10 /90 0.5 10.0 28500 300 2/22/05 4741 9.8 1 0.46 48 17 23 11/23/32 6 1/ 8 192 0.20 9.1 33000 480 2/23/05 6226 10.0 10.67 58 20 25 12// 11.5 1/ 11.5 /89 0.10 9.1 31000 180 2/24/05 6678 10.0 10.67 55 20 25 11/25/37 0.0 1/ 10 /90 0.10 9.2 31000 160 2/25/05 6837 10.3 11.01 52 18 32 23/34/42 5.6 1/ 12 /88 0.10 9.2 31000 160 2/26/05 6874 10.3 11.04 55 20 28 12/24/30 5.4 1/ 12 188 0.10 9.1 30000 160 2/27/05 7897 10.3 10.91 59 18 28 6/18/23 4.8 1/ 11 /89 0.15 9.3 30000 120 2/28/05 8045 10.3 69 23 27 10/16/21 5.2 1/2 12 /88 0.20 9.3 32000 120 PI Abbreviations MW = Mud Weight WL = Water or Filtrate Loss Ca = Hardness Calcium YP = Yield Point Gels = Gel Strength CI = Chlorides PV = Plastic Viscosity Sd = Sand content VIS = Funnel Viscosity Sols = Solids ECD = Effective Circulating Density FC = Filter Cake O/w = Oil to Water ratio [~ EPOCH 19 · · · 6 MORNING REPORT ConocoPhillips Alaska Inc. Kokoda #1 Daily Report GLADDENIWILSON TOBY ARCHULETA DRILLING Date: 2/17/05 Time: 0400 324 324 324 Current Operations: D 11" P n Ing arameters ROP: Current: 142 Max: 240 Toraue: Current: Max: WOB: Current 18.3 Max: 20 RPM: Current: Max: PP: Current: 295 Max: 300 Lag: Strokes: 445 Time: 4.2 Circulation: Strokes: Time: ECD: Current: Max: Mud Properties I ~~~ I FL: I Ca++: YP: I cr FV' Sol: PV: I pH: MW Change: Mud Loss event: To: Reason: Depth: Depth: From: Volume: Gas Data I Ditch Gas: I Current: I 7 Gas Events I Max: 115 I Depth (MDrrvD): I 285/285 Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MDrrvD) Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MDrrvD) NONE Peaks I Depth (MDrrvD) Gas Samples I No. Depth (MDrrvD) TG C2 C3 C41 C4N C51 C5N C1 C3 C41 C4N C51 C5N C2 TG C1 Lithologies: Current: SILTSTONE 30%, SAND 20%, CLAYSTONE 20%, CARB. SHALE 20%, COAL 10% Last 24 hrs: SAND, SILTSTONE, CLAYSTONE, COAL, CARB. SHALE, TUFF I Operational Summary: I SPUD WELL, DRILL TO 236', UPLOAD MWD AND LOAD SOURCES, DRILL. Calibrations: All sensors calibrated before spudding. C1 9960 C2 1040 C3 995 IC4 1050 NC4 961 IC5 1020 NC5 963 I Failures: [~ EPOCH 20 · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report GLADDEN/WILSON TOBY ARCHULETA Date: 2/18/05 Time: 0400 Current Depth (MD): 2435 Current DRILLING Current Depth (TVD): 2435 Operations: 24 hr Footage (MD): 2111 D 11' P n Ing arameters ROP: Current: 93 Max: 360 Torque: Current: 3.2 Max: 24 WOB: Current 21 Max: 44 RPM: Current: 105 Max: 112 PP: Current: 1700 Max: 1782 Lag: Strokes: 3160 Time: 22.1 Circulation: Strokes: Time: ECD: Current: 10.86 Max: 11 Mud~Trties FV' PV: I ~:I FL: I I Gels: Sol: pH: Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: · 1594/1594 Trip Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MDfTVD) Connection Gas Depth TG C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NONE Peaks Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 1594/1594 422 34320 5227 1558 1654/1654 288 40756 2750 550 G S as amples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 1 500/500 8 2121 2 1000/1000 61 13332 3 1500/1500 85 14057 277 4 200012000 75 14526 274 Lithologies: Current: 30% SAND, 30% SILTSTONE, 30% CLAYSTONE, 10% SHALE Last 24 hrs: SANDSTONE, CLAYSTONE, SILTSTONE, TUFF DRILL FROM 324' TO 1230', LOST POWER TO RIG FOR % HOUR, DRILL FROM 1230' TO 2435' AT REPORT TIME. I Calibrations: I RAN STANDARDIZED GAS THROUGH CHROMATOGRAPH, OKAY. Operational Summary: · I Failures: [~ EPOCH 21 . . . ConocoPhillips Alaska Inc. Kokoda #1 Daily Report GLADDENIWILSON TOBY ARCHULETA Date: 2/19/05 Time: 0400 RUNNING CASING Current Operations: Current Depth Current Depth 24 hr Foota e 2510 2510 75 D 'II" P t n mg arame ers ROP: Current: NA Max: 136 Torque: Current: NA Max: 7 WOB: Current NA Max: 19 RPM: Current: NA Max: 108 PP: Current: NA Max: 1906 Lag: Strokes: NA Time: Circulation: Strokes: NA Time: ECD: Current: NA Max: Mud Properties I ~~~ I :~~ I PV: I YP: I c:H I pH: cr MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: 2435/2435 Gas Events Wiper Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDnvD) 53 2510/2510 Max while Depth C1 C2 C3 C41 C4N C51 C5N running casing (MDnvD) 90 975/975 Connection Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDnvD) NONE TG C4N C5N C51 C1 C3 C41 C2 40% SILTSTONE, SAND 30%, CLAYSTONE 20%, SHALE 10% SAND, SILTSTONE, CLAYSTONE, SHALE, CARB. SHALE, ASH Operational Summary: Drill from 2435' to 2495', CBU, drill 2495'-2505', CBU, drill 2505'-2510', 2510' picked as surface casing point, pump out to HWDP, TIH, circ (53u gas), POOH, UD BHA, rig u and run 9 5/8" casin . I Ca.librations: I Failures: [~ EPOCH 22 · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report GLADDENIWILSON TOBY ARCHULETA Date: 2120/05 Time: 0400 Current Depth (MD): 2510 Current Waiting to finish top job Current Depth (TVD): 2510 Operations: 24 hr Footaae (MD): 0 0'11" P n mg arameters ROP: Current: NA Max: Torque: Current: NA Max: WOB: Current NA Max: RPM: Current: NA Max: PP: Current: NA Max: Lag: Strokes: NA Time: Circulation: Strokes: NA Time: ECD: Current: NA Max: Mu~~res ~~ I PV: I YP: I FL: I I Gels: pH: cr Ca++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: · Gas Events · Trip Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NA Connection Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NA Peaks I Depth (MDfTVD) C51 C5N C41 C4N C1 C2 C3 TG I Lithologies: I Current: I ~~ . .. Last 24 hrs: .. Operational Summary: Run 9 5/8" casing, land @ 2505', circ and condition mud, rig up for cement job, cement per plan, rig down cement equip, NO diverter, move wellhead into cellar, ri u for and perform to cement ·ob. Calibrations: Failures: [~ EPOCH 23 . . . ConocoPhillips Alaska Inc. Kokoda #1 Daily Report I Report for: I WILSON I TOBY ARCHULETA Date: 2/21/05 Time: 0400 Current Depth (MD): 2510 Current TEST BOP Current Depth (TVD): 2510 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: NA Max: TorQue: Current: NA Max: WOB: Current NA Max: RPM: Current: NA Max: PP: Current: NA Max: Lag: Strokes: NA Time: Circulation: Strokes: NA Time: ECD: Current: NA Max: 6 300 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: Gas Data I Ditch Gas: I Current: I 0 . Avg BG : . 0 .. I Max: 15 I Depth (MDITVD): I Gas Events Trip Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDITVD) NA Connection Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDITVD) NA Peaks I Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N Gas Samples I No. I Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N I Lithologies: I Current: I NA Last 24 hrs: NA Operational Summary: Pick up 60 jts drill pipe, finish top cement job, orient and NU wellhead, NU BOP's, testin BOP's at report time. Calibrations: Calibrated total as analyzer and chromatogra h. Failures: g EPOCH 24 · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report SCALESJWILSON TOBY ARCHULETA Date: 2/22/05 Time: 0400 Current Depth (MD): 3605 Current DRILLING Current Depth (TVD): 3605 Operations: 24 hr FootaQe (MD): 1095 D 11' P t n Ing arame ers ROP: Current: 112 Max: 330 Torque: Current: Max: WOB: Current 6 Max: 17 RPM: Current: 107 Max: 113 PP: Current: 1700 Max: 1900 Lag: Strokes: 1930 Time: 16.1 Surf-Surf: Strokes: 2475 Time: 20.6 ECD: Current: 11.2 Max: 11.5 7.2 300 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: Gas Data Ditch Gas: Avg BG : · Gas Events 2736 Trip Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NA Connection Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NONE Peaks I Depth (MDfTVD) G S TG C1 C2 C3 C41 C4N C51 C5N as amples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 6 3000/3000 54 11 033 123 7 3500/3500 50 9536 215 101 LitholoQies: Current: 80% CLAYSTONE, 20% SILTSTONE Last 24 hrs: CLAYSTONE, SILTSTONE, TRACE SANDS AND CARBONACEOUS SHALE. Operational Summary: MU BHA, TIH, TEST CASING, DRILL OUT SHOE TRACK + 20' NEW HOLE, FIT TO 15.7 EMW, DRILL TO 3605' AT REPORT TIME. I Ca.librations: I Failures: · [~ EPOCH 25 · · · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report Report for: LUTRICKlWILSON TOBY ARCHULETA Date: 2123/05 Time: 0400 Current Depth (MD): 4967 Current DRILLING Current Depth (TVD): 4967 Operations: 24 hr Footage (MD): 1362 D 11" P t n Ing arame ers ROP: Current: 90 Max: 255 Toraue: Current: 0.9 Max: 17 WOB: Current 5 Max: 45 RPM: Current: 110 Max: 114 PP: Current: 2040 Max: 3076 Lag: Strokes: 2400 Time: 19.5 Surf-Surf: Strokes: 3164 Time: 25.7 ECD: Current: 11.1 Max: 6 480 MW Change: Mud Loss event: From: Volume: To: Reason: Depth: Depth: 3612/3612 Gas Events Wiper Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) 165u 3719 190u 4741 Connection Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NONE Peaks I Depth (MDfTVD) G S C51 C5N C4N C3 C41 TG C1 C2 as amples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 8 4000/4000 28 8145 233 107 9 4500/4500 26 7914 199 78 10 4600/4600 23 6826 200 82 11 4700/4700 28 8021 224 95 12 4800/4800 33 9593 217 85 13 4903/4903 48 11775 261 102 [~ EPOCH 26 · · · Current: 60% CLAYSTONE, 30% SHALE, 10% SILTSTONE. Last 24 hrs: CLAYSTONE, SILTSTONE, SHALE, TRACE SANDS. Operational Summary: DRILL TO 3719', WIPER TRIP TO SHOE, DRILL TO 4741', WIPER TRIP 11 STANDS, DRILL TO 4967' AT REPORT TIME. Calibrations: CHECKED CALIBRATION ON THA AND CHROMATOGRAPH, OKAY. Failures: [~ EPOCH 27 · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report LUTRICKlWILSON TOBY ARCHULETA Date: 2/24/05 Time: 0400 Current Depth (MD): 6480 Current DRILLING Current Depth (TVD): 6480 Operations: 24 hr Footage (MD): 1513 D 11' P t n mQ arame ers ROP: Current: 117 Max: 164 Torque: Current: 4 Max: 16 WOB: Current 8.3 Max: 21 RPM: Current: 111 Max: 114 PP: Current: 2468 Max: 3111 Lag: Strokes: 3125 Time: 25 Surf-Surf: Strokes: 4155 Time: 33.2 ECD: Current: 11.3 Max: 11.6 5.8 180 MW Change: Mud Loss event: To: 10.0 Reason: TRIP Depth: Depth: From: 9.8+ Volume: 5062/5062 · Gas Events · Wiper Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) 94u 5762/5762 17624 409 105 35 15 Connection Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) NONE Peaks I Depth (MDfTVD) C4N C51 C5N C3 C41 TG C1 C2 [~ EPOCH 28 · · · G S as am pies No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 14 5003/5003 25 7197 165 95 8 4 15 5105/5105 42 9364 217 94 18 15 16 5206/5206 23 5564 132 61 18 6 17 5301/5301 36 7587 183 107 22 12 18 5398/5398 28 6598 164 111 23 11 19 5511/5511 28 6926 154 75 28 14 20 5600/5600 22 5500 184 107 32 15 21 5700/5700 26 6129 168 82 32 15 22 5802/5802 22 6094 168 113 27 13 23 5900/5900 24 6887 224 128 40 22 5 2 24 6000/6000 29 7226 255 165 65 42 28 12 25 6100/6100 34 7614 254 135 35 29 10 3 26 6200/6200 40 7909 272 147 30 28 8 2 27 6310/6310 37 8402 356 190 44 15 7 3 28 6405/6405 33 8226 418 239 97 57 11 1 Lithologies: Current: 60% CLAYSTONE, 30% SILTSTONE, 10% SANDSTONE. Last 24 hrs: CLAYSTONE, SHALE, SIL TSTONE, MINOR SANDSTONE, TR CARB SHALE Operational Summary: DRILL TO 5762', SHORT TRIP 11 STANDS, DRILL TO 6480' AT REPORT TIME. I Ca.librations: I Failures: [~ EPOCH 29 · · · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report LUTRICKlWILSON TOBY ARCHULETA MAD PASS Date: 2/25/05 Time: 0400 6678 6678 198 Current Operations: D 11' P t n mg arame ers ROP: Current: NA Max: 139 Torque: Current: NA Max: 17 WOB: Current NA Max: 22 RPM: Current: NA Max: 112 PP: Current: NA Max: 2620 Lag: Strokes: 3200 Time: 25.6 Surf-Surf: Strokes: 4265 Time: 34.1 ECD: Current: NA Max: 5.6 160 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: Depth (MDITVD: 6485 Gas Events BU before Depth C1 C2 C3 C41 C4N C51 C5N POOH Gas (MDITVD) 45 6678/6678 CBU @ 5030 Depth C1 C2 C3 C41 C4N C51 C5N (MDITVD) 115 5030/5030 Connection Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDITVD) NONE Peaks I Depth (MDITVD) G S C1 C51 C5N TG C2 C3 C41 C4N as amples No. Depth (MDITVD) TG C1 C2 C3 C41 C4N C51 C5N 29 6499/6499 27 6724 362 226 61 41 11 2 Current: 60% CLAYSTONE, 30% SILTSTONE, 10% SHALE. Last 24 hrs: CLAYSTONE, SILTSTONE, SIL TV SHALE, SANDSTONE. g EPOCH 30 · · · DRILL TO 6678', POOH TO LD MUDMOTOR AND MOVE LWD TOOLS CLOSER TO BIT FOR PICKING CORE POINT, TIH, TIGHT @ 5030, CBU, Operational Summary: INCREASE IN SHALE CAVINGS, 115u GAS, CONT TIH, WASH LAST STAND TO BOTTOM, 11 Ou MAX WASHING TO BOTTOM, MAD PASS 6617 -6678 AT REPORT TIME. Calibrations: CALIBRATED TOTAL GAS ANALYZER AND CHROMATOGRAPH. Failures: [~ EPOCH 31 . ConocoPhillips Alaska Inc. Kokoda #1 Daily Report LUTRICKlWILSON TOBY ARCHULETA CBU BEFORE CORING Date: 2/26/05 Time: 0400 D): Current De th D): 24 hr Footage (MD): 6837 6837 159 Current Operations: D 11' P t n mg arame ers ROP: Current: NA Max: 93 TorQue: Current: NA Max: 3 WOB: Current NA Max: 13 RPM: Current: NA Max: 122 PP: Current: NA Max: 2352 Lao: Strokes: 3400 Time: 57.3 Surf-Surf: Strokes: 4500 Time: 75.6 ECD: Current: 11.01 Max: 5.6 160 MW Change: Mud Loss event: Depth: 6678 Depth: From: 10.0 Volume: To: 10.3 Reason: FORMATION 6832/6832 . Gas Events . Flow Check Depth C1 C2 C3 C41 C4N C51 C5N Connection Gas (MDfTVD) 145 6830 Wiper trip after Depth C1 C2 C3 C41 C4N C51 C5N core point (MDfTVD) 44 6837/6837 Trip Gas Depth C1 C2 C3 C41 C4N C51 C5N (MDfTVD) 80 6837/6837 [~ EPOCH 32 . . . G S as amples No. Depth (MDfTVD) TG C1 C2 C3 C41 C4N C51 C5N 30 6700/6700 24 6404 318 174 25 20 5 2 31 6789/6789 47 9135 700 474 94 130 24 13 32 6800/6800 55 10334 815 541 91 151 28 14 33 6809/6809 63 10378 935 665 145 227 64 28 34 6822/6822 207 17631 2635 2163 403 688 201 194 35 6832/6832 265 17697 2704 2382 468 856 237 242 Current: 60% SANDSTONE, 20% SILTSTONE, 20% CLAYSTONE Last 24 hrs: CLAYSTONE, SILTSTONE, SANDSTONE DRILL TO 6837' STOPPING TO CIRC SAMPLES PER GEOLOGY, CORE Operational Summary: POINT 6837', MAX GAS 265u @ 6832',10 STD WIPER TRIP, 44u WIPER GAS, POOH, LD BHA, MU CORE ASSEMBLY, TIH, Calibrations: CALIBRATED TOTAL GAS ANALYZER AND GAS CHROMATOGRAPH. Failures: [~ EPOCH 33 . ConocoPhillips Alaska Inc. Kokoda #1 Daily Report LUTRICKlWILSON TOBY ARCHULETA Date: 2/27/05 Time: 0400 Current Depth (MD): 6874 Current TRIPPING IN HOLE Current Depth (TVD): 6874 Operations: 24 hr Footage (MD): 37 D 11' P t n Ing arame ers ROP: Current: NA Max: 31 Torque: Current: NA Max: 18 WOB: Current NA Max: 17 RPM: Current: NA Max: 119 PP: Current: NA Max: 935 Lag: Strokes: 3371 Time: 27 Surf-Surf: Strokes: 4581 Time: 35.9 ECD: Current: 11.04 Max: 11.2 5.4 160 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: 6838 . Gas Events . CBU before Depth C1 C2 C3 C41 C4N C51 C5N coring (MDrrvD) 60 6837/6837 CBU after coring Depth C1 C2 C3 C41 C4N C51 C5N (MDrrvD) 68 6874/6874 G S as amPles No. Depth (MDrrvD) TG C1 C2 C3 C41 C4N C51 C5N 36 6840/6840 111 20491 1811 1527 188 419 106 110 37 6850/6850 50 8087 702 599 73 164 31 28 38 6860/6860 98 15229 1566 1559 239 537 146 132 39 6866/6866 125 19432 2128 2093 290 665 175 172 40 6870/6870 78 12086 1205 1162 168 391 110 90 Current: 40% SANDSTONE, 20% EACH SIL TV SHALE, SILTSTONE, CLAYSTONE Last 24 hrs: SANDSTONE, SIL TV SHALE, CLAYSTONE CBU, DROP BALL, GET SPR, DRILL CORE FROM 6837' to 6874', CORE Operational Summary: JAMMED, POOH, LD CORE, PU ROTARY BHA, TIH TO ABOVE SHOE, LEVEL SUB, SERVICE TOP DRIVE, TIH. Calibrations: CALIBRATED TOTAL GAS ANALYZER AND CHROMATOGRAPH. Failures: [~ EPOCH 34 · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report LUTRICKlWILSON TOBY ARCHULETA Date: 2/28/05 Time: 0400 Current Depth (MD): 8045 Current CIRCULATING Current Depth (TVD): 8045 Operations: 24 hr FootaQe (MD): 1172 D 11' P t n mg arame ers ROP: Current: NA Max: 177 Torque: Current: NA Max: 18 WOB: Current NA Max: 22 RPM: Current: NA Max: 123 PP: Current: NA Max: 2740 Lag: Strokes: 3952 Time: 31.6 Surf-Surf: Strokes: 5258 Time: 42 ECD: Current: 11.4 Max: 11.5 4.8 120 MW Change: Mud Loss event: Depth: Depth: From: Volume: To: Reason: 7458/7458 · Gas Events · Trip Gas Depth Units C1 C2 C3 C41 C4N C51 C5N (MDfTVD) 84u 6873 CBU @ 7200' 1100 CBU @ 7557' 995 Connection 10-20u (80u @ 7246) Gases [~ EPOCH 35 · · · Gas Samples No. Depth (MDnvD) TG C1 C2 C3 C41 C4N C51 C5N 41 6900/6900 39 7188 481 393 65 165 60 45 42 7002/7002 47 5890 499 408 66 172 71 50 43 7100/7100 38 6002 420 310 42 180 45 30 44 7183/7183 90 19430 1267 682 76 204 56 60 45 7195/7195 220 42242 3115 1706 184 449 106 90 46 7223/7223 410 66314 5856 3369 343 857 173 175 47 7240/7240 450 72099 6484 3738 412 1011 206 241 48 7300/7300 115 17199 1751 1126 126 356 85 80 49 7400/7400 49 7064 808 542 80 155 67 50 50 7450/7450 1070 200887 32704 19584 1596 4651 712 778 51 7475/7475 750 164410 23822 13593 1034 3306 546 700 52 7500/7500 710 169286 22231 11441 830 2659 523 707 53 7530/7530 495 89130 10816 5660 408 1477 321 519 54 7540/7540 830 177560 30474 20151 1655 5291 970 1088 55 7600/7600 347 44893 6093 3387 332 855 170 193 56 7700/7700 171 22172 3008 2103 295 831 216 302 57 7800/7800 126 13551 1837 1604 209 874 234 326 58 7898/7898 127 13956 2004 1787 300 825 228 301 59 8000/8000 134 15909 2073 1689 231 720 200 265 60 8045/8045 107 11276 1478 1322 199 657 186 253 Lithologies: Current: 60% SHALE / CARBONACEOUS SHALE, 30% CLAYSTONE, 10% SIL TSTONE Last 24 hrs: SANDSTONE, SILTY SHALE, CARBONACEOUS SHALE, SIL TSTONE, CLAYSTONE Operational Summary: TIH, CBU (84u), DRILL FROM 6873' TO 8045' TD @ 0250 HRS. NOTE: CBU GAS EVENTS DETAILED ABOVE. I Ca.librations: I Failures: [1 EPOCH 36 . . . Date: 3/1/05 Time: 0400 ConocoPhillips Alaska Inc. Kokoda #1 Daily Report 8045 8045 o Current Operations: WIRELlNE LOGS Gas Data: 5.2 120 WIPER GAS AFTER TD: 800u, SHARP PEAK, RAPIDLY TRAILED OFF TO +1- 50u. PUMP SWEEP, CIRC HOLE CLEAN, 20 STAND WIPER TRIP (800u WIPER Operational Summary: GAS), CIRC CLEAN, POOH, LD BHA, TEST BOP'S, RIG UP SCHLUMBERGER AND BEGIN LOGGING HOLE. I Ca.librations: I Failures: [~ EPOCH 37 · · · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report LUTRICK / RIZEK MARK WOODS Date: 312105 Time: 0400 Current Depth (MD): 8045 Current Backreaming @ +/- 2900' Current Depth (TVD): 8045 Operations: 24 hr FootaQe (MD): 0 4.4 160 Gas Data: Trip gas 1470u washing last stand to bottom, otherwise up to 140u washing through upper parts of hole and a peak of 290u while washing and reaming at +1- 7440'. Operational Summary: E-Iogging, wireline stuck @ 7366', work free, POOH with wireline and rig down same, MU BHA for cleanout run, RIH working thru tight spots to 8045', circ hole clean (1470u max gas), large volume of shale and clay cavings, POOH to 3300', eire, POOH, tight, backreaming @ +/- 2900' at report time. I Ca.librations: I Failures: [~ EPOCH 38 · · · ConocoPhillips Alaska Inc. Kokoda #1 Daily Report LUTRICK I RIZEK MARK WOODS Date: 3/3/05 Time: 0400 Current Depth (MD): 8045 Current Wireline Operations Current Depth (TVD): 8045 Operations: 24 hr Footage (MD): 0 4.8 160 Gas Data: Wiper gas 800u Operational Summary: Backream through tight spots to shoe, TIH, circ and raise MW to 10.5, large volume of shale slough over shakers, circ clean, spot Resinex pill, pull 10 stds wet, pump dry job, POOH, LD BHA, rig up wireline and log hole. I C~librations: I Failures: [~ EPOCH 39 . . . LUTRICK / RIZEK MARK WOODS Date: 3/4/05 Time: 0400 ConocoPhillips Alaska Inc. Kokoda #1 Daily Report 8045 8045 o Current Operations: Running in hole Gas Data: 22u max while CBU +1-2480'. 4.8 160 Operational Summary: Continue wireline operations, rig down wireline, decision made to P&A, break down BHA, RIH with HWDP, LD HWDP, RU for 3.5" stinger, RIH with 3.5" tubing from pipe shed, RD tongs, RIH on DP, CBU @ shoe, continue RIH. I Ca.librations: I Failures: [~ EPOCH 40 ~ ~Ðlt- d.-G3 -íó \j~ - J:Jp 0_ ~ p~s ~ 9-~ AOWL ~- 1);~aL -ºJ~C5 fWàJ~ CIIiP'i presents Core Photographs 'nil:,~·f;::-:~_ ! .... .' "'''';'Y·ì'A·~-1 ~ 1, .,·'U ll"\! 1· -;f ~. ) i-i Ntl{'tL ~ f".,I ,~.> .t.J~ ~."'!.... ., .-,.- , .,' .' ., { For Kokoda # 1 502792001100