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Home My WebLink About206-169Image 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. ~~ ~ - ~ ~ ~ Well History File Identifier Organizing (done) RESC Color Items: Greyscale Items: ~~ ^ Poor Quality Originals: ^ Other: NOTES: o..~a,a iii~miiuiiuiii DIGI L DATA Diskettes, No. ^ Other, No/Type: ^ Rescan Needed III (VIII II I I III III OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: o~ ~ /s/ ~ IIIIIIIIIIIIII VIII Project Proofing BY: Maria Date: ~ ~s~ Scannin Pre aration o~ x 30 = +_~ =TOTAL PAGES (U~ (Count does not include cover sheet) ~/~ /~ g ~Y~ BY: Maria Date: ~/~,7 ,~ /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does include cov~heet) hes Number in Scannin Pre aration: ~' YES NO Page Count Matc 9 P BY: Maria Date: [~. 111 ~ ID ~s~ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s` IIIIIII Scanning is complete at this point unless rescanning is required. () I II'I II I I Rescanned III 111111 VIII V III BY: Maria Date: ~s~ Comments about this file: Quality Checked III (I'I'I III III III P 10/6/2005 Well History File Cover Page doc • • bp BP Exploration (Alaska) Inc. Attn: Well integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7"' Avenue `� AUG 0 7 20,2 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA PM -2 l Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, l Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GPMA PM -2 Date: 04/302012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD if API 4 Initial top of cement pumped cement off date inhibitor date ft bbls ft na gal P2 -01 , 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2 -03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 .-.p P2-08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 , 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 10.20 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2 -31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2-33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2 -35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2-41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2-43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2- 458 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2-46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P2 -47 1951900 50029226280000 0.0 NA 0.0 NA NA NA P248 1921260 50029223090000 0.2 NA 0.2 NA 1.70 4/18/2012 P249 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2 -59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 ~~ ~ ~~' ~~y ~ ~, ,~~, 5 ~S 4 Y ' '~. a. ~' ~ ~ u~' ..,. +~ e :. ~, MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc ~l /~,~~( ~~~ DATA SUBMITTAL COMPLIANCE REPORT 4/12/2010 Permit to Drill 2061690 Well Name/No. PRUDHOE BAY UN PTM P2-08A Operator BP EXPLORATION (ALASK/y INC API No. 50-029-22896-01-00 MD 17506 TVD 9099 Completion Date 3/21/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surv y Yes DATA INFORMATIDN Types Electric or Other Logs Run: (data taken from logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~ e mearrrmi rvumucr ryamg J1441C mCU~a wo awrz atop ~.n Receives ~.o~n~ne~rw ED D Asc Directional Survey 17031 17506 Open 5/23/2008 (gpf Directional Survey 17031 17506 Open 5/23/2008 D D Asc Directional Survey 15662 17277 Open 5/23/2008 PB 1 pt Directional Survey 15662 17277 Open 5/23/2008 PB 1 og Induction/Resistivity 5 Col 15726 17278 Open 6/16/2008 PB 1 TVD MPR, GR 10- Mar-2008 g Induction/Resistivity 25 Col 15726 17278 Open 6/16/2008 PB 1 MD MPR, GR 10-Mar- 2008 / og Gamma Ray 25 Col 15726 17278 Open 6/16/2008 PB 1 GR 10-Mar-2008 LIS Verification 15651 17506 Open 6/16/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 16456 Induction/Resistivity 15651 17506 Open 6/16/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS pt LIS Verification 15651 17278 Open 6/16/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 16457 Induction/Resistivity 15651 17278 Open 6/16/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 15726 17506 Open 11/28/2008 MD MPR, GR Log Induction/Resistivity 5 Col 15726 17506 Open 11/28/2008 TVD MPR, GR ', Log Gamma Ray 25 Col 15726 17506 Open 11/28/2008 MD GR ~I DATA SUBMITTAL COMPLIANCE REPORT 4/12/2010 Permit to Drill 2061690 Well Name/No. PRUDHOE BAY UN PTM P2-08A Operator BP EXPLORATION (ALASKP~ INC MD 17506 TVD 9099 Completion Date 3/21/2008 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? "`:J Chips Received? ~F-f-P1- Analysis Y.f-N' Received? Comments: API No. 50-029-22896-01-00 UIC N ~N Daily History Received? Formation Tops ~N Compliance Reviewed By: Date: ~~ d~ ~ ®~~® BAKER Nt/GF~ES CUMYANY WELL NAME FIELD Baker Atlas PRINT DISTRIBUTION LIST BY EXYLUKA'I'lUN (ALASKA) 1NC CUUN'1 Y NUK'1'H SLUYE BURUUGH P2-08A STATE ALASKA POINT MCINTYRE THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1850977 Copies of Copies Digital Copies of Copies Digital Each l.og of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC Company Person PETROTECHNICAL DATA CENTER Person Address LR2-1 Address 900 E BENSON BLVD. ANCHORAGE. AK 99508 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address GSC EMB 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE. AK 99501 1 Company DNR-DIVISION OF OIL & GAS Company Person KRISTIN DIRKS Person Address 550 WEST 7TH AVE Address SUITE 802 ANCHORAGE. AK 99501 Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield, Houston. Texas 77073 This Distribution List Completed Bv: :~ ~~~ ~" DATE 6/12/2008 Page 1 of i ®~- BAKER HVGF~ES Baker Atlas PRINT DISTRIBUTION LIST CUMYAN Y BY EXYLUKA'1'IUN (ALASKA) 1NC CUUNI Y NUKTH SLUYI/ BUKUUGH WELL NAME P2-08APB1 STATE ALASKA FIELD POINT MCINTYRE THIS DISTRIBUTION LIST AUTHORIZED BY DATE 6/12/2008 CATRINA GUIDRY SO # 1850977 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC Company Person PETROTECHNICAL DATA CENTER Person Address LR2-1 Address 900 E BENSON BLVD. ANCHORAGE AK 99508 I Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address GSC EMB 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 1 Company DNR-DIVISION OF OIL & GAS Company Person KRISTIN DIRKS Person Address 550 WEST 7TH AVE Address SUITE 802 ANCHORAGE. AK 99501 Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield_ Houston. Texas 77073 This Distribution List Completed By; ,~, ~1h ~~ Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: P2-08APB1 -___ ___ __ __..__ z - __ Contains the following: f 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color prints - GR Directional Measured Depth Log (to follow) 1 color prints - GR Directional TVD Log (to follow) R _. Sent by: Catrina Guidry Date: 06/12/08 Received by: Date: , , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-0623 r Baker Hughes INTEQ rl ~ ~~j~ 7260 Homer Drive cJ Anchorage, Alaska 99518 Direct: (907) 267-6612 j (oGl~ INTEQ FAX: (907) 267-6623 • NTE I.o Data Transmittal I'®r To: State of Alaska -A®GCC 333 W. 7`h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: P2-OSA Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color prints - GR Directional Measured Depth Log (to follow} 1 color prints - GR Directional TVD Log (to follow) LAC Job#: 1850977 Sent by: Catrina Guid Date: 06/12/08 Received by: ~ Date: _ . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~J~~ `~~ 7260 Homer Drive ~Ifl~G~S Anchorage, Alaska 99518 Direct: (907) 267-6612 /~l~ I1`lT~:(2 FAX: (907) 267-6623 ~''°~ ~~ ~~r~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: May 23, 2008 Please find enclosed directional survey data for the following wells: P2-08APB 1 P2-08A G-11B 15-25B 07-OlB Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: Q ,State of Alaska AOGCC DATE: ,a 3 r.. ~ ~~ Cc: State of Alaska, AOGCC STATE OF ALASKA ~ :K~~~~ RECEIVE ALASKA OIL AND GAS CONSERVATION COMMISSION A P R 1 5 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: o~ag@ ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab 3/21/2008 -p~ 12. Permit to Drill Number 206-169 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/5/2008 J 13. API Number 50-029-22896-01-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/16/2008 ~ 14. Well Name and Number: PBU P2-08A FWL, SEC. 11, T12N, R14E, UM' FSL, 1073 18 Top of Productive Horizon: 2978' FSL, 2358' FWL, SEC. 07, T12N, R15E, UM 8. KB (ft above MSL): 49.02' ~ Ground (ft MSL): 11.08' 15. Field /Pool(s): Prudhoe Bay Field /Point Total Depth: 2560' FSL, 2352' FWL, SEC. 07, T12N, R15E, UM 9. Plug Back Depth (MD+TVD) 17506' 9099' McIntyre Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 681308 y- 5998596 Zone- ASP4 10. Total Depth (MD+TVD) 17506' 9099' 16. Property Designation: ADL 365548 " TPI: x- 693073 y- 6001851 Zone- ASP4 - 6001434 Zone- ASP4 th: x- 693078 Total De 11. SSSV Depth (MD+TVD) 1990' 1983' 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.0 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (fVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and prirted information Der 20 AAC 25.071): MWD DIR / GR / RES, GR / CCL / CNL t/%VDoiJ~.~ ~s a6iyo (90~~ ~n~~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING=DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 133# H-40 41' 110' 41' 110' 30" Driven 9-5/8" 40# L-80 38' 5469' 38' 4950' 12-1/4" 591 sx CS III, 459 sx'G', 877 sx CS III 7" 26# / 2g# 13Cr I L-80 35' 14874' 35' 8636' 8-3/4" 250 sx Class 'G' 4-1/2" 12.6# 13Cr 14 1' 8 22' 9062' 6" 435 sx Cla 'G' 2-3/8" 4.7# 13Cr / L-80 14557' 17506' 8510' 9099' 3" 58 sx Class 'G' Bonzai & Slotted Liner 23. Open to production or injec tion? ®Yes ^ No 24. TuswG RECORD If Yes, list each i MD+TVD Pe f To & Bottom nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p ; ( o 2-3/8" Slotted Section 3-1 /2", 9.2#, 13Cr 14594' 14546' MD TVD MD TVD 16586' - 17505' 9084' - 9099' 25., ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected w/ Diesel 26. PRODUCTION TEST Date First Production: April 4, 2008 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 4/6/2008 HOUrS Tested: 10 PRODUCTION FOR TEST PERIOD OIL-BBL: 853 GAS-MCF: 543 WATER-BBL: 29 CHOKE SIZE: 62 GAS-OIL RATIO: 636 Flow Tubing Press. 1,234 CaSing PreSS: 2,161 CALCULATED 24-HOUR RATE• OIL-BBL: 2,048 GAS-MCF: 1,303 WATER-BBL: 70 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAG 250.071. None `~ Form 10-407 Revised 02/2007 ~ ~. TINUED ON REVERSE SIDE ~~~ ~~~ ~ ~ (108 ~ '~ [! 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. (Kicked off in Kuparuk, P2-08) 15694' 9044' None Kuparuk 17500' 9099' Formation at Total Depth (Name): Kuparuk 17500' 9099' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,I. Signed Terrie Hubble Title Drilling Technologist Date PBU P2-08A 206-169 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit NO. / A royal NO. Drilling Engineer: Sean McLaughlin, 564-4387 (INSTRUCTIONS GeNewu: This form is designed. for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 28: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~ Code NPT I I Phase - Description of Operations 2/29/2008 00:00 - 01:30 1.50 MOB P PRE 01:30 - 10:30 9.00 MOB P PRE 10:30 - 18:00 7.50 MOB P PRE 18:00 - 00:00 6.00 MOB N RREP PRE 3/1/2008 100:00 - 10:30 10.501 BOPSUp N RREP PRE Install 2" reel. Move to Pt Mac 2-08. Spot satelite office. Accept rig at 1030. NU BOP. Complete repair of injector. Install gripper blocks, stripper, Pipe straightener, & gooseneck. Stand back injector. RU hard line & flowback tank .Install air compressor. BOPE test. Swab not holding, grease swab valve; valve not holding, regrease swab. BOPE test continues to fail after greasing swap. Troubleshoot BOPE valves. Change out choke valve #15 and rebuild valve #3. 10:30 - 13:00 2.50 BOPSU N RREP PRE Test BOPE after choke valve change. Grease valves with 501 . ..... . Clare. 13:00 - 18:00 5.00 BOPSU P PRE Test BOP s 250 psi Lo and 3500 psi hi. Test witnessed by AOGCC Rep Lou Grimaldi. 18:00 - 20:00 2.00 BOPSU P PRE Continue BOP test. 20:00 - 00:00 4.00 RIGU P PRE Pull coil across, fill coil, PT reel hardline and inner reel valve. Pump slack. Set injector down to pull BPV. 3/2/2008 00:00 - 00:30 0.50 BOPSU P PRE PU lubricator and tools for pulling BPV 00:30 - 01:00 0.50 BOPSU P PRE PJSM for pulling BPV 01:00 - 02:00 1.00 BOPSU P PRE Pull BPV, 480 psi on well. Lay down BPV tools 02:00 - 05:00 3.00 ZONISO P WEXIT MU Kendal CTC and Inteq UOC, PT to 3500 05:00 - 09:00 4.00 ZONISO P WEXIT RIH, adjust skates on injector, Holding 500 psi while RIH to 10000'. Wt check. Up wt 25K. RIH to 15500 Up Wt 38K, RIH tag WS at 15730 un corrected. Paint flag EOP 15621. RIH Park coil at 15690. 09:00 - 09:15 0.25 ZONISO P WEXIT Shut in well Inject 3/4 bpm ~ 1550 psi,1000 whp, 1/2 bpm 1165 psi 840 W H. 09:15 - 09:30 0.25 ZONISO P WEXIT PJSM for cementing squeeze job. 09:30 - 10:00 0.50 ZONISO P WEXIT Circulate at min rate .26 bpm holding 520 psi with closed choke. Batch up cement 12 bbl 15.8 cement> Pump 5 bbl H2O. PT line to 3500 psi. OK. 10:00 - 11:45 1.75 ZONISO P WEXIT Pump 12 bbl 15.8 ppg cement. 5 bbl H2O and displace with KCL. 1.5/1.0 bpm C~3 3200-2500 psi holding 500 psi WH pressure. 40 bbl away 1.45/1.0 3400 psi WH 490 psi, IA321psi . At 50 bbl slow to .75 bpm. Shutin back side at 51 bls in total. Bull head @ .75 bpm 031100, WH 880 at 53 bbls .75 bpm @1475 , WH 1247 at 54 bbls .75 bpm @ 1775, WH 1542 at 55 bbl .75 bpm @ 2556 , WH 2373 Lay in 1 for 1 to 15000 worst case PU to 14500 psi Shut down pump while POH final WH 242psi Squeeze with .2 bbls to 560 psi W H Squeeze with .5 bbls to 1000 psi WH Squeeze with .9 bbls to 1500 psi. WH No bleed off after 20 min 11:45 - 15:00 3.25 ZONISO P WEXIT Pump 35 bbl bio and wash down to 15725. POH contaminating cement to 14800'. Circulate in second 35 bbl bio pill. Holding 1500 psi wellhead for total of 3 hrs. 15:00 - 16:20 1.33 ZONISO P WEXIT Continue to circulate out excess cement through an open choke. Circulate 9.4 milling fluid to nozzle. 16:20 - 16:50 0.50 ZONISO P WEXIT POH to 14075 laying in 9.4 milling fluid. Nnnted::ii[iiluua i:ea:n rrw P~ BP EXPLORATION Page 2 of 16 Operations. Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ', Code NPT Phase Description of Operations 3/2/2008 16:50 - 19:50 3.00 ZONISO N RREP WEXIT Generator turbo overheating. Stopped POH to investigate. Generator is down for repair. Continues POOH slowly on one generator. Total trip OOH was 6.5 Hours, normal speeds would be 3.5 hours. This 3 hours is the NPT time 19:50 - 22:55 3.08 ZONISO P WEXIT Slowly POH at reduced speed and pump rate on one generator. 22:55 - 23:30 0.58 ZONISO P WEXIT At surface, lay down nozzle and MU stack jetting tool. Jet stack. 23:30 - 00:00 0.50 ZONISO P WEXIT PT CTC, good to 4000 psi. Anchor on a-line has come loose, re-install UOC. 3/3/2008 00:00 - 01:00 1.00 STWHIP N DFAL WEXIT Re-install Inteq UOC 01:00 - 01:30 0.50 STWHIP P WEXIT PJSM for PU window milling BHA 01:30 - 02:00 0.50 STWHIP P WEXIT MU window milling BHA 02:00 - 03:30 1.50 STWHIP P WEXIT RIH 03:30 - 06:40 3.17 STWHIP N RREP WEXIT Generator threw a rod. POOH for extensive generator repairs. 06:40 - 07:20 0.67 STWHIP N RREP WEXIT L/D milling BHA 07:20 - 08:00 0.67 STWHIP N RREP WEXIT reverse pump 5 bbl McOH into coil. 08:00 - 10:40 2.67 STWHIP N RREP WEXIT Prep for Generator 1 removal. Disconnect generator. drain radiator. Remove radiator and front panel assembly. 10:40 - 15:15 4.58 STWHIP N RREP WEXIT Sim Ops RU Little Red to pump slack in coil. Pump one CT volume to warm CT 1 bpm @ 1800 psi 100F. Pump slack Cut 8' Ct 1' wire. Rd Hot Oil. Spot stack of matting boards on off driller side. Pull gen set #1 from motor room onto matting boards. 15:15 - 18:00 2.75 STWHIP N RREP WEXIT Remove Gen set from motor room. Remove replacement generator from connex and stage on matting boards. 18:00 - 00:00 6.00 STWHIP N RREP WEXIT Installing replacement generator 3/4/2008 00:00 - 03:30 3.50 STWHIP N RREP WEXIT Continue generator replacement. Load test generator. 03:30 - 04:00 0.50 STWHIP N RREP WEXIT PU window milling BHA 04:00 - 05:00 1.00 STWHIP N RREP WEXIT RIH, ECD is open, pumping .4 BPM 05:00 - 07:20 2.33 STWHIP P WEXIT Continue to RIH, off NPT time 07:20 - 07:35 0.25 STWHIP P WEXIT Stop RIH to close EDC. EDC would not close. 07:35 - 10:50 3.25 STWHIP N DFAL WEXIT POH from 14519 ft to change EDC. 10:50 - 11:00 0.17 STWHIP N DFAL WEXIT Tagged Surface. SAFETY MEETING--covered procedures, hazards, and mitigation for LD BHA. 11:00 - 11:55 0.92 STWHIP N DFAL WEXIT Standback injector, LD BHA #3. PU Milling BHA #4, stab injector. 11:55 - 14:50 2.92 STWHIP N DFAL WEXIT RIH to 300ft, open EDC, pump minimum rate &RIH at 100 ft/min to 6000 ft, RIH at 80 ft/min to 14519 tt. 14:50 - 15:20 0.50 STWHIP P WEXIT RIH from 14519 ft to TOW. Tag cement at 15,706. ~~ -(~ 15:20 - 16:20 1.00 STWHIP P WEXIT Mill cement from 15,706-15708'. Not a steady ROP to determine start of window milling. Decide to log CCL tie-in for better depth control. 16:20 - 17:00 0.67 STWHIP P WEXIT Log CCL tie-in. Added 19.5' to CTD. 17:00 - 00:00 7.00 STWHIP P WEXIT RIH. Tagged bottom at 15726.4'. Mill window top of whipstock was set at 15726' with a 29 Deg LOHS tray. Free spin 1.45 bpm @ 3750 CTP Mill with 1.45 bpm C~3 3950 CTP at - 1'/hour 15731.5' stalled at 23:30, continue time milling 15733' at midnight 3/5/2008 00:00 - 00:30 0.50 STWHIP P WEXIT Continue milling operations, 15733', 1.45 bpm C~ 3950 CTP. F'rlfl[8tl: :1/L//LUU2f 7:~4:L1 YM BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/5/2008 00:00 - 00:30 0.50 STWHIP P WEXIT Milling at 1'/hour. 00:30 - 01:00 0.50 STWHIP P WEXIT 15734', Swap well over to Flo-pro, continue milling formation at 10'/hour 01:00 - 02:30 1.50 STWHIP P WEXIT Milled formation to 15742'. Geologist confirmed formation sand in returns. Ream window with 4 passes at <1'/min up and down. Ran through window with pump down at 10'/min with no set down. Ran through window at 10'/min C~ 1.45 bpm with no motor work. 02:30 - 06:00 3.50 STWHIP P WEXIT POOH, open EDC 06:00 - 06:30 0.50 STWHIP P WEXIT Lay out BHA. window mill gauged at 2.79" NoGo, string reamer gauged at 2.79" Go, 2.78" NoGo. 06:30 - 06:45 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for cutting coil for coil in chrome tubing maintenance. 06:45 - 07:30 0.75 DRILL P PROD1 Cut off 100' of coil for chome tubing coil management. M/U CTC and pull test. 07:30 - 08:30 1.00 DRILL P PROD1 M/U BHI coiltrak UQC and test E-line. 08:30 - 09:10 0.67 DRILL P PROD1 M/U CoilTrak build BHA #5 with used HYC BC Bit, 2.6 deg Xtreme motor and CoilTrak tools. OAL = 58.16'. 09:10 - 12:00 2.83 DRILL P PROD1 RIH with CoilTrak Build BHA #5. Circ at 0.1 BPM. RIH clean to 15,000'. CoilTrak comms failed inside downhole tools. Short in BHA. Not able to fix the downhole problem. 12:00 - 15:00 3.00 DRILL N DFAL PROD1 POH due to short in CoilTrak BHA. 15:00 - 15:15 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for C/O CoilTrak BHA. 15:15 - 16:20 1.08 DRILL N DFAL PROD1 L/O CoilTrak tools. Found EDC was shorted. Changed out EDC only. 16:20 - 19:45 3.42 DRILL N DFAL PROD1 RIH with CoilTrak Build BHA #6 with used HYC BC Bit #2, 2.6 deg motor and CoilTrak tools.. BHA OAL = 58.16'. RIH to 15,670'. 19:45 - 20:30 0.75 DRILL P PROD1 Tie in from 15670' at 100 fph. Correct +3' 20:30 - 00:00 3.50 DRILL P PROD1 Start drilling from 15744', 1.4 bpm ~ 3400 CTP. Slow drilling, difficulty getting weight to bit and no consistent drilling. Midnight depth 15795' MD, estimate 9039' TVD 3/6/2008 00:00 - 01:30 1.50 DRILL P PROD1 Continue drilling from 15785'. 1.4 BPM ~ 3400 CTP, at around 15800' the slip/stick problem went away and drilled ahead at 60-90 fph 01:30 - 05:00 3.50 DRILL P PRODi POOH for lateral assembly 05:00 - 07:15 2.25 DRILL P PROD1 Lay down drilling assembly. Reconfigure BHA for Rib Steer motor. Test Rib Steer motor and tools on rig catwalk. 07:15 - 07:30 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U Rib Steer Lateral BHA. 07:30 - 08:15 0.75 DRILL P PROD1 M/U Rib Steer CoilTrak lateral BHA with HCC Rib Steer BC Bit #3. BHA OAL = 64.55'. 08:15 - 10:45 2.50 DRILL P PROD1 RIH with lateral Rib Steer BHA #7. Circ at 0.2 bpm. RIH to 15670'. Up wt on bottom = 37K. 10:45 - 11:10 0.42 DRILL P PROD1 Log GR Tie-In. Add 4' to CTD. 11:10 - 11:20 0.17 DRILL P PROD1 RIH thru window at 20 fpm, no pump. Slight wt loss thru Nrintea: sieneuuss t:ea:n rnn BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date .From - To Hours Task ~~ Code NPT Phase Description of Operations 3/6/2008 11:10 - 11:20 0.17 DRILL P PROD1 window. about 1000# drag thru window. RIH clean to bottom. circ. 1.33 bpm, 3300 psi free spin. full returns. Tag bottom at 15,825'. 11:20 - 12:45 1.42 DRILL P PROD1 Drill lateral with Rib Steer motor and RES, 1.42 bpm, 3500-3900 psi, 0.5-1 K WOB, 86 deg incl, 80 fph, Drilled to 15900'. 12:45 - 15:00 2.25 DRILL P PROD1 Drill lateral with Rib Steer motor and RES, 1.45 bpm, 3500-4100 psi, 1-2K WOB, 90 deg incl, 60-80 fph, Drilled to 16000'. 15:00 - 15:15 0.25 DRILL P PRODi Wiper trip up to 15,830'. 15:15 - 15:45 0.50 DRILL P PROD1 Log MAD RES pass up to window at 150 fph. 15:45 - 16:00 0.25 DRILL P PROD1 RIH clean to bottom. 16:00 - 18:00 2.00 DRILL P PROD1 Drill lateral with Rib Steer motor and RES, 1.46 bpm, 3700-4100 psi, 1-2K WOB, 91 deg incl, 60-70 fph, drilled to 16075'. 18:00 - 20:15 2.25 DRILL P PROD1 Continue to drill lateral with Rib Steer motor and RES, 1.46 bpm, 3700-4100 psi, 1-2K WOB, 92 deg incl, 60-70 fph, 20:15 - 20:40 0.42 DRILL P PROD1 Wiper trip to window 20:40 - 21:15 0.58 DRILL N SFAL PROD1 Repair injector head oil leak 21:15 - 21:40 0.42 DRILL P PROD1 Wiper back in hole 21:40 - 00:00 2.33 DRILL P PROD1 Continue drilling lateral with rib steer motor and RES, 1.45 bpm C~ 3700 CTP, 1-2K WOB, 92 deg inc, 16210' at midnight, TVD 9046' 3/7/2008 00:00 - 02:40 2.67 DRILL P PROD1 Continue drilling lateral section with Rib Steer motor and RES, 3" bicenter, 1.45 BPM C~3 3760 CTP, slow drilling at 20-30 fph. 02:40 - 03:30 0.83 DRILL P PROD1 Wiper from 16300' to window 03:30 - 05:00 1.50 DRILL P PROD1 Continue drilling lateral, 1.4 BPM @ 3500 freespin, 60 ROP 16385' at 05:00 05:00 - 06:30 1.50 DRILL P PROD1 Continue drilling lateral, 1.4 BPM ~ 3500 freespin, 60 ROP, 1-2K WOB, 11.8 ecd, 50 fph, Drilled to 16420'. 06:30 - 07:20 0.83 DRILL P PROD1 Drill lateral with Rib Steer motor and RES tool. 1.45 bpm, 3600-4100 psi, 92 deg incl, 11.8 ecd, Drilled to 16450'. 07:20 - 08:00 0.67 DRILL P PROD1 Wiper trip to window, 33k up wt. Clean hole. Pulled clean thru window. 08:00 - 08:10 0.17 DRILL P PROD1 Log GR tie-in. Added 5' to CTD. 08:10 - 08:30 0.33 DRILL P PROD1 RIH clean thru window. RIH clean to bottom. 08:30 - 10:30 2.00 DRILL P PROD1 Drill lateral with Rib Steer motor and RES tool. 1.45 bpm, 3600-4100 psi, 90 deg incl, 11.9 ecd, Drilled to 16510'. 10:30 - 14:00 3.50 DRILL P PROD1 Drill lateral with Rib Steer motor and RES tool. 1.45 bpm, 3600-4100 psi, 92 deg incl, 11.9 ecd, Swap to new FloPro at 16,580'. Drilled to 16,600'. 14:00 - 15:00 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 15:00 - 16:45 1.75 DRILL P PROD1 Drill lateral with Rib Steer motor and RES tool. 1.45 bpm, 3600-4100 psi, 92 deg incl, 11.9 ecd, Loosing about 0.1 bpm returns with new FloPro. Drilled to 16,680'. 16:45 - 18:10 1.42 DRILL P PROD1 Drill lateral with Rib Steer motor and RES tool. 1.45 bpm, 3600-4100 psi, 91 deg incl, 11.9 ecd, Printed: 3/27/2008 1:54:21 PM BP EXPLORATION Page 5 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code NPT 3/7/2008 16:45 - 18:10 1.42 DRILL P 18:10 - 19:30 1.33 DRILL P 19:30 - 21:00 1.50 DRILL P 21:00 - 00:00 3.001 DRILL ~ P 3/8/2008 100:00 - 00:30 ~ 0.501 DRILL ~ P 00:30 - 01:00 0.50 DRILL N 01:00 - 02:00 1.00 DRILL P 02:00 - 02:20 0.33 DRILL P 02:20 - 04:30 2.17 DRILL P 04:30 - 05:00 I 0.501 DRILL I P PROD1 05:00 - 08:10 3.17 DRILL P PROD1 08:10 - 12:00 3.83 DRILL N DFAL PROD1 12:00 - 14:00 2.00 DRILL N DFAL PROD1 14:00 - 17:00 3.00 DRILL N DFAL PROD1 17:00 - 17:15 0.25 DRILL P PROD1 17:15 - 17:45 0.50 DRILL P PROD1 17:45 - 20:00 2.25 DRILL P PROD1 ', 20:00 - 00:00 4.00 DRILL P PROD1 3/9/2008 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 01:30 0.50 DRILL P PROD1 01:30 - 04:00 2.50 DRILL P PROD1 04:00 - 04:45 0.75 DRILL P PROD1 04:45 - 08:00 3.25 DRILL P PROD1 08:00 - 08:25 0.42 DRILL P PROD1 08:25 - 09:00 0.58 DRILL N SFAL PROD1 09:00 - 09:30 0.50 DRILL P PROD1 09:30 - 11:45 2.25 DRILL P PROD1 Open EDC when above window. Continue POOH for 1.1 deg motor, unable to drop inclination to maintain correct TVD with Rib Steer Replace broken bearings in injector chains Continue POOH Lay down Rib Steer BHA MU and test Coiltrak BHA, trouble with HOT. Install CT-Inspect PU Coiltrak lateral BHA assembly with 1.1 deg bent motor and HCC rerun bicenter bit. RIH to 15,600'. Lost communication to BHA. Check all surface lines. Downhole short again. POH for short in CoilTrak BHA. BHI determined that the Rib Steer Motor from the last run had a pin hole leak in the body, which caused the pump to run out of hydraulic oil. The drilling records indicated the pin hole leak happed while POH with the BHA, so the motor was unable to drop inclination as needed. Check BHA. Found short between upper and lower BHI quick connect. C/O LOC. Check bit and motor. Bit in new condition. M/U CoilTrak lateral /RES BHA #9 with HCC BC bit #5 and 1.1 deg Xtreme motor. BHA OAL = 67.76'. RIH with Coiltrak /RES BHA #9. Circ. at 0.2 bpm. Log GR tie-in. Added 25' to CTD. RIH clean to bottom. Drill lateral, 1.4 bpm, 3900-4300 psi, 140R TF, 1-2K wob, 91 deg incl. Dropped inclination to -87 and 9028.5 TVD POH for Rib Steer Package. Lost 1 hour due to daylight savings time Lay down drilling BHA, Bit still like new Cut 50' coil for chrome management and rehead with Kendall CTC and Baker UOC assemble and test Rib Steer BHA PU Rib Steer BHA #10 with 2.7" X 3.0" HCC bicenter bit RIH clean to 15,670'. Log GR tie-in, added 23' CTD. Repaired one bad bearing in injector drive chains. RIH clean to bottom. Drill lateral with Rib Steer, 1.4 bpm, 3700-4100 psi, 88 deg incl, 50 fph, 12.0 ecd, Spud Date: 3/5/2008 Start: 2/29/2008 End: 3/21 /2008 Rig Release: 3/21/2008 Rig Number: Phase Description of Operations PROD1 Drilled to 16,753'. PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. PROD1 Drill lateral with Rib Steer motor and RES tool. 1.4 bpm, 3600-4100 psi, 91 deg incl, 11.9 ecd, Still trying to drop inclination from 91.5 deg Drilled to 16831' with near bit still at 91.5 Deg. PROD1 Unable to get inclination to drop with rib steer. After consultation with town geologists decided to POOH for PROD1 SFAL PROD1 PROD1 PROD1 PROD1 rnntea: siznzuua t:54:n rnn BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/9/2008 09:30 - 11:45 2.25 DRILL P PROD1 Stacking wt with Rib Steer Motor. When Ribs are used, it affects WOB and the coil stacks wt instead of drilling ahead. Drilled to 17,000'. 11:45 - 12:30 0.75 DRILL P PROD1 Drill lateral with Rib Steer, 1.4 bpm, 3700-4100 psi, 88 deg incl, 20 fph, 12.0 ecd, Stacking wt using Rib Steer. Getting motor work, but very slow progress. Drilled to 17,010' 12:30 - 13:30 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 13:30 - 18:15 4.75 DRILL P PROD1 Drill lateral with Rib Steer, 1.3 bpm, 3600-4200 psi, 90-89 deg incl, 50 fph, 12.1 ecd, Stacking wt, getting motor work, Drilled to 17,149'. 18:15 - 19:50 1.58 DRILL P PROD1 Wiper trip to window. Clean hole. RIH Clean to bottom. 19:50 - 00:00 4.17 DRILL P PROD1 Drill lateral with Rib Steer, 1.3 bpm, 3600-4200 psi, 90-89 deg incl, 30 fph, 12.1 ecd, To clarify what the effect of Rib Steering tool has on ROP we went to full rib retract mode, then 25, then 45, then 75 psi steering force. ROP was unchanged at these settings. The down hole WOB only increased at the 75 psi setting by 500 lbs. 17230' at midnight 3/10/2008 00:00 - 03:00 3.00 DRILL P PROD1 Drill lateral with Rib Steer, 1.3 bpm, 3600-4200 psi, 90-89 deg incl, 30 fph, 12.1 ecd. After good drilling at -50 fph the ROP dropped to <10 FPH with -100 psi motor work. Trying various techniques to get more motor work, including retracting ribs on motor and fast RIH. 03:00 - 04:15 1.25 DRILL P PROD1 Wiper trip to window 04:15 - 04:40 0.42 DRILL P PROD1 Back on bottom, still stacking weight, with -100 psi motor work. 04:40 - 08:30 3.83 DRILL P PROD1 POOH for bit. 08:30 - 08:45 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changeing BHA. 08:45 - 10:45 2.00 DRILL P PROD1 Lay out Rib Steer BHA. Bit had 3 plugged ports on pilot. Check all CoilTrak tools. M/U Coiltrak /RES BHA with HYC BC Bit #6 ,with 1.1 deg Xtreme motor. BHA OAL = 67.77'. 10:45 - 13:55 3.17 DRILL P PROD1 RIH with CoilTrak /RES Lateral BHA #11 , Circ at 0.2 bpm. 13:55 - 14:15 0.33 DRILL P PROD1 Log GR tie-in. Added 10' to CTD. 14:15 - 14:45 0.50 DRILL P PROD1 RIH clean to bottom. Tag bottom at 17,245'. 14:45 - 17:00 2.25 DRILL P PROD1 Drill lateral, 1.3 bpm, 3700-4100 psi, 130E TF, 89 deg incl, 12.2 ecd, 20 fph. Stacking wt. Drilled to 17,277'. Geo confirmed we are drillin in Kalubik shale. Called Anc. Geo to get plan forward. 17:00 - 21:30 4.50 DRILL P PROD1 POH for open hole sidetrack Bit and motor. Clean trip up to window. POH to surface. 21:30 - 23:30 2.00 DRILL P PROD1 Lay down BHA, remove resistivity tool and adjust motor to 1.7 deg., PU HCC R60ST bit with brass cap brazed on 23:30 - 00:00 0.50 DRILL P PROD1 RIH with sidetrack BHA, 1.7 AKO motor and HCC R60 bit 3/11/2008 00:00 - 02:45 2.75 DRILL P PROD1 Continue RIH with sidetrack BHA 02:45 - 03:00 0.25 DRILL P PROD1 Tie in, +13' correction. 03:00 - 03:30 0.50 DRILL P PROD1 Continue RIH, tagged up at 15745', able to work slowly Printed: siznzuua i:oa:n rnn BP EXPLORATION Page 7 of 16' Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date 'li From - To Hours Task ~'I Code NPT Phase Description of Operations 3/11/2008 03:00 - 03:30 0.50 DRILL P PROD1 (without pumping) down to 15770', smooth running from there, pump on at .3 BPM at 16000' while RIH through open hole 03:30 - 03:45 0.25 DRILL P PROD1 Tag bottom at 17255', work bit on bottom to remove brass cap. 03:45 - 05:00 1.25 STKOH P PROD1 Start backream from 17060', Pulled up 7' of coil stretch then up to 17018' at 30 FPH 05:00 - 06:45 1.75 STKOH P PROD1 Second back ream pass up to 17018'. 06:45 - 09:30 2.75 STKOH P PROD1 RIH to 17,050'. Ream down to 17,060' with 175R TF at 30 fph. Park bit at 17060', 170R TF for 10 min. Time drill 1 fph for 1 ft. Time drill 2 fph for 2 ft. 09:30 - 10:10 0.67 STKOH P PROD1 Drill open hole side track with 170R TF at 10 fph, 1.3 bpm, 3650 psi, 0.2 k wob. Drilled down to 17080'. Well is not sidetracked. Basket must still be on bit. 10:10 - 13:45 3.58 STKOH P PROD1 RIH to bottom to break off basket from R-60 sidetrack bit. Very difficult shales. Stacking wt at 17,265'. Overpull. Work coil trying to get back to bottom. Ream bottom 40' several times to get to bottom. Finally worked to bottom and drilled to 17.282'. Swapped to new FloPro while reaming trough. Pull up to open hole sidetrack. 13:45 - 16:20 2.58 STKOH P PROD1 Ream down at 170R TF, 1.4 bpm, 30 fph to cut trough above OH sidetrack depth. Backream at 30 f h u to 17 030'. Ream down at 30 fph to 17050' and 20 fph to 17060'. 16:20 - 18:30 2.17 STKOH P PROD1 Park bit at 17060' for 20 min. 170R TF. Drill OH sidetrack at 1 fph for 1 ft. Drill OH sidetrack at 2 fph for 4 ft. 18:30 - 21:50 3.33 STKOH P PROD1 Continue sidetrack attempt from 17,062.7 ft to 17,069 ft at 2 ft/hr. 20:30 - 17,066.5 ft, WOB = 0.23 Klbs. 21:50 - 22:00 0.17 STKOH P PROD1 At 17,069 ft time drill at 5 - 10 ft/hr. Initial WOB is 0.24 Klbs, falling away to 0.16 Klbs. 22:00 - 22:15 0.25 STKOH P PROD1 Slowly increase ROP to 60 fUhr, then 100 ft/hr. No indication of a sidetrack. 22:15 - 00:00 1.75 STKOH N DPRB PROD1 Run DGS past sidetrack point to confirm surveys. POOH. 3/12/2008 00:00 - 02:30 2.50 STKOH N DPRB PROD1 Continue POOH with BHA #12. 02:30 - 03:00 0.50 STKOH N DPRB PROD1 Tag stripper. Break off well, stand back injector. Break BHA at motor and stand back in derrick. Remove motor and bit, bit has about half of cutters damaged, on the nose and around outside. 03:00 - 03:40 0.67 STKOH N DPRB PROD1 MU BHA #13 - 2.73" R60 sidetracking bit + 2-3/8" BHI X-treme motor with 2.1 deg AKO setting. 03:40 - 04:10 0.50 STKOH N SFAL PROD1 Replace roller bearing on injector. 04:10 - 07:15 3.08 STKOH N DPRB PROD1 RIH with open hole sidetrack BHA with R-60 sidetrack bit and 2.1 deg motor. No pump to preserve sidetrack bit and brass basket 07:15 - 07:45 0.50 STKOH N DPRB PROD1 Log GR tie-in added 57' to CTD. biggest depth correction. 07:45 - 08:30 0.75 STKOH N DPRB PROD1 RIH and sat down on bottom of window at 15,733' with 20 L TF. Sat down several times at bottom of window with various high side TF. Pflflt2tl: 3/L7/LUUB 1:54:"Ll PM BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/12/2008 07:45 - 08:30 0.75 STKOH N DPRB PROD1 Circ at 0.5 bpm and try to work thru window with 20L TF. No luck Circ at 0.75 bpm and try to work thur window with 20L TF, highside, 30R TF and 60L TF. Not able to et thru window. 08:30 - 11:15 2.75 STKOH N DPRB PROD1 POH. 11:15 - 11:30 0.25 STKOH N DPRB PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA. 11:30 - 13:00 1.50 STKOH N DPRB PROD1 Check sidetrack R-60 bit. 1 broken outside cutter. Brass basket was gone. Adjust motor to 1.1 deg, M/U 2.80" diamond D-331 mill and 2.79" reamer. BHA OAL = 59.2'. 13:00 - 15:45 2.75 DRILL N DPRB PROD1 RIH with window dressin BHA #14 with 2.8" parabolic mill, string reamer and 1.1 deg motor. Circ at 0.1 bpm. 15:45 - 16:30 0.75 DRILL N DPRB PROD1 Log GR Tie-in. added 124' to CTD. adjust measuring wheel. 16:30 - 17:30 1.00 DRILL N DPRB PROD1 Ream down with 2.80" mill. Ream down thru window with 200 psi motor work and 1400# WOB. Ream thru window easy, no problem. Back ream and ream down clean thru window. RIH clean to 15790', Stack wt and ream down, Ream down clean to 16,090'. Ream down with motor work to 16,120'. RIH clean to 17,200'. 17:30 - 18:30 1.00 DRILL N DPRB PROD1 POH, circ at 1.45 bpm, 3500 psi, Clean hole back to window with mill and reamer. 18:30 - 19:45 1.25 DRILL N DPRB PROD1 Back ream thru window, Ream down, back ream again at 1 - 2 ft/min. Very little motor work seen. 19:45 - 22:40 2.92 DRILL N DPRB PROD1 POOH. Open circ sub and circulate 1.7 bpm while POOH. 22:40 - 22:55 0.25 DRILL N DPRB PROD1 SAFETY MEETING. Review procedures, hazards and mitigations for BHA changeout and cable slack management. 22:55 - 23:20 0.42 DRILL N DPRB PROD1 Tag stripper. Break off injector, stand back. Remove BHA and break at motor. Re-run motor and shim it for 2.1 deg AKO. Mill and string reamer in gauge, like new condition. Ensure well is full then shut master valve, prepare for slack maintenance. 23:20 - 00:00 0.67 DRILL N DPRB PROD1 Cut off cable head and install boot on cable. Make up injector to well and pump backwards with FloPro at 2.9 bpm / 4,500 psi then 10 bbls water. 3/13/2008 00:00 - 00:40 0.67 DRILL N DPRB PROD1 Break off well, install CT connector. Cut off 174 ft of pipe to find cable. 00:40 - 01:10 0.50 DRILL N DPRB PROD1 Pump 10 bbls water out of CT. 01:10 - 02:00 0.83 DRILL N DPRB PROD1 Cut CT to find a suitable spot, then install CT connector. 02:00 - 03:20 1.33 DRILL N DPRB PROD1 Pull test CT connector to 30 Klbs, good. Circulate through CT then install cable head. 03:00 -Circulate through CT to warm it up. 03:20 - 03:40 0.33 DRILL N DPRB PROD1 Test cable connection, good the second time. Pressure test CT connector to 4,000 psi, good. 03:40 - 04:20 0.67 DRILL N DPRB PROD1 Pick up BHA #15 - 2.75" HYC 4-bladed bit with 2.1 deg AKO motor. 04:20 - 07:20 3.00 DRILL N DPRB PROD1 RIH. Open circ sub and pump forward 50 bbls while RIH, then Printed: 3/27/2008 1:54:21 PM • BP EXPLORATION Page 9 of 16 Operations. Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To'! Hours ' Task Code NPT ~! Phase Description of Operations 3/13/2008 04:20 - 07:20 3.00 DRILL N DPRB PROD1 shut down pump and close circ sub, continue RIH. 07:20 - 07:45 0.42 DRILL N DPRB PROD1 Log down with GR at 15625' to tie-in. Added 52 ft. 07:45 - 08:30 0.75 DRILL N DPRB PROD1 RIH clean thru window. RIH clean to 17,060'. Backream up to 17,030'. 08:30 - 12:00 3.50 DRILL N DPRB PROD1 Trough down in openhole with 170R TF at 20 fph, 1.4 bpm, 3500 psi. BHA sto ed slidin at 17 032'. Possible ledge to start sidetrack off of. Start troughing from 17,000' down with 170R TF at 20 fph. Stacked wt at 17,018'. Slide stopped. Pick up and trough down at 30 fph to keep sliding. Troughed from 17,000-17,031'. 12:00 - 13:40 1.67 STKOH N DPRB PROD1 Trough down the second time from 17000-17031'. 13:40 - 16:50 3.17 STKOH N DPRB PROD1 Park bit at 17,031' for 20 min. Drill 1 fph, 170R TF, 1.4 bpm, 3550 psi, No WOB or motor work seen. Trouble sliding had to pick up and re-start 1/2' high. Drilled to 17033.2' at 1 fph. 16:50 - 19:40 2.83 STKOH N DPRB PROD1 Time drill at 2 fph, 170R TF, 1.4 bpm. 18:30 - 17,035.2 ft 1.31 / 1.29 bpm, 3,380 psi, near bit = 87.6 deg inclination. 19:00 - 17,035.5 ft 1.3 / 1.28 bpm 3,400 psi, near bit = 87.5 deg inclination. 19:30 - 17,036.1 ft 1.3 / 1.27 bpm 3,420 psi, near bit = 87.6 deg inclination. 19:40 - 21:20 1.67 STKOH N DPRB PROD1 Stacking surface weight, no WOB or motor work seen, pick up to 17,000 ft. Perform another troughing pass from 17,000 to 17,030 ft at 30 ft/hr. Stacking surface weight at 17,025 ft with no increase in WOB, pick up is 39 Klbs. Try to work back to time drilling depth at 30 Whr, stacking weight again at 17,029 ft. Pick up and go back to bottom of trough at 2 ft/min, 1.34 / 1.33 bpm. 21:20 - 23:00 1.67 STKOH N DPRB PROD1 Slow down at 17,032.5 ft to time drill at 2-4 Whr. Surface weight = 9720 Ibs, WOB = 0.02 Klbs, 1.34 / 1.33 bpm at 3,760 psi, near bit inc = 87.4 deg. 22:00 - 17,034.1 ft, Surface weight = 7.5 Klbs, ROP = 1-2 ft/hr, 1.34 / 1.33 bpm ~ 3,770 psi, near bit inc = 87.44 deg, WOB = 0. 22:30 - 17,035.8 ft, weight = 6.4 Klbs, 1.3 / 1.29 bpm ~ 3,660 psi, near bit inc = 87.5 deg, WOB = 0.01 Klbs. Try working BHA down from 17,035 ft in 0.1 ft increments every 3-5 min. 23:00 - 00:00 1.00 STKOH N DPRB PROD1 Stacking surface weight at 17,037 ft with no WOB, pick up. Trough from 17,025 ft down to 17,035 ft, and back up again to 17,020 ft. Repeat. Resume time drilling from 17,035.5 ft at 1-2 ft/hr. 3/14/2008 00:00 - 01:50 1.83 STKOH N DPRB PROD1 Continue time drilling from 17,035.7 ft. 01:20 - 17,038 ft, ROP = 4-5 Whr, WOB = 0.02 Klbs, Weight = 4.8 Klbs, near bit inc = 87.6 deg, 1.25 / 1.25 bpm ~ 3,540 psi. 01:50 - 02:10 0.33 STKOH N DPRB PROD1 Stacking weight at 17,039 ft, pick up to 17,030 ft. F'rlflt8tl: J/"6//'LUUt3 1:54:61 YM BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code ! NPT Phase 3/14/2008 01:50 - 02:10 0.33 STKOH N DPRB PROD1 02:10 - 03:20 1.171 STKOH N DPRB PROD1 03:20 - 05:00 1.671 STKOH N DPRB PRODi 05:00 - 05:20 0.331 STKOH N FLUD PROD1 05:20 - 08:45 3.421 STKOH N FLUD PROD1 08:45 - 09:00 0.251 STKOH N FLUD PROD1 09:00 - 10:15 1.251 STKOH N FLUD PROD1 10:15-19:45 I 9.50160PSUpP I IPRODI 19:45 - 20:10 0.42 BOPSU P PROD1 20:10 - 20:20 0.17 BOPSU P PROD1 20:20 - 20:35 0.25 STKOH N FLUD PROD1 20:35 - 21:10 0.58 STKOH N FLUD PROD1 21:10 - 00:00 2.83 STKOH N FLUD PRODi 3/15/2008 00:00 - 00:20 0.33 STKOH N FLUD PROD1 00:20 - 00:40 0.33 STKOH N FLUD PROD1 00:40 - 01:25 0.751 STKOH N FLUD PROD1 01:25 - 02:30 1.081 DRILL N DPRB PROD1 Description of Operations Run past 17,040 ft at 3 fUmin, nothing seen. Pick up to 17,000 ft, shut down pump and RIH for dry tag. RIH from 17,000 ft to 17,045 ft at 2.8 fUmin. Clean pass, no weight bobbles or ledges seen. Sidetrack attempt failed. Lay in liner pill + 3 ppb Alpine beads from 17,200 ft in case it is decided to run liner instead. While laying in liner pill tag at 17,046 ft and take weight with good motor work. Decide to make another sidetrack attempt here. Stacking weight at 17,056 ft, pick up. RIH to 17,052 ft and tag, try to drill ahead. WOB = 2.04 Klbs, ROP = 62 ft/hr. 1.27 / 1.26 bpm C~ 3,600 psi. Stall at 17,055 ft, pick up. Drill to 17,059 ft and start stacking weight. Run back in to 17,054 ft and tag, 2.60 Klbs WOB and 100 - 300 psi motor work. Near bit inc at 88.38 deg. Stack weight at 17,060 ft. Run in to this depth again and tag, set down 3.62 Klbs WOB with no motor work. Pick up and RIH, try to get some motor work. Tag at 17,060 ft and set down 3.34 Klbs WOB, no motor work. Repeat 2 more times setting 3 - 4 Klbs WOB at various running speeds, no motor work seen. POOH to inspect bit and motor. Pull through window and open circ sub. POH to surface. SAFETY MEETING. Review procedure, hazards and mitigation for laying out BHA. Lay out CoilTrak, motor and bit. Motor was completely locked up, it would not turn at all. Bit was in new condition. Performed weekly BOPE pressure /function test. Test witness waived by AOGCC inspector Chuck Scheeve. Send BOPE test report to AOGCC. Greased tree and rig valves to get pressure test. Test inner reel valve, good. Open master, SSV, and swab valve on tree. Install fusible cap on SSV. SAFETY MEETING. Review procedure, hazard and mitigation for MU BHA. MU BHA #16 -1.5 deg AKO lateral assy with Resistivity. RIH Continue RIH. Log GR down from 15,660 ft. Correct +12 ft. Resume RIH. Pass window on first attempt at 30L. At 17,030 ft turn BHA down to 180R, reduce pump to 0.35 bpm. Continue RIH at 6 ft/min to try and find sidetrack ledge. Tag at 17,057 ft with WOB = 2.92 Klbs and motor work. Pick up and go to drilling rate. Ease back down to 17,056 ft and start drilling. Drill to 17,059 ft and stop sliding, stacking weight with no motor work. Nnnted::trzn2uua 1:54:21 YM BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: i Date From - To ;Hours; Task 'Code NPT Phase Description of Operations 3/15/2008 01:25 - 02:30 1.08 DRILL - N DPRB - PROD1 Increase rate to 1.32 bpm @ 3,800 psi free spin. 17,062 ft, WOB = 3.2 Klbs, CT weight = 4.8 Klbs. Turn to 150R and drill slowly, still difficult sliding. 02:30 - 03:30 1.00 DRILL N DPRB PROD1 Drill from 17,068 at 1.30 / 1.26 bpm with 100 - 400 psi motor work. Initial ROP = 33 ft/hr, WOB = 3.6 Klbs, Near bit inc = 86.2 deg. Hole is sidetracked from on final lateral at 17 060'. Drilled to 17,075 ft, stacking weight difficult sliding. 03:30 - 03:40 0.17 DRILL N DPRB PROD1 Wiper trip from 17,075 ft to 17,025 ft. 03:40 - 05:00 1.33 DRILL N DPRB PROD1 Drill from 17,075 ft to 17,090 ft. Repeatedly stacking weight past 17,080 ft. Getting good WOB 3-4 Klbs but little motor work. Pick up from 17,090 ft to try and get weight back. 05:00 - 06:30 1.50 DRILL N DPRB PROD1 Continue drilling lateral past 17,100 ft at negative string wt. 1.3 bpm, 3650-4200 psi, 86 deg incl, Drilled to 17,113'. 06:30 - 08:00 1.50 DRILL N DPRB PROD1 Ream open hole sidetrack window area to open it up, backream at 170R, ream down 170R, Backream at highside, ream down lowside. 08:00 - 08:15 0.25 DRILL N DPRB PROD1 Drill OHS lateral, Stacking wt with no drilling progress. 08:15 - 10:00 1.75 DRILL N DPRB PROD1 Wiper trip to window. Clean hole. RIH clean to 17,000'. 10:00 - 13:00 3.00 DRILL N DFAL PROD1 Short to BHI CoilTrak tools. Pull to window to check collector in reel stand. Short is downhole. POH for tool failure. 13:00 - 13:15 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing out BHA. 13:15 - 16:20 3.08 DRILL N DFAL PROD1 Lay out CoilTrak tools. Determine short was in connection between upper and lower quick connect. Third time on this well. Connection pin in upper quick connect should be replaced about every four trips. We had 6 trips with this pin when it failed. M/U Coiltrak Lateral /RES /Agitator BHA #17. BHA OAL = 75.67'. 16:20 - 19:15 2.92 DRILL N DFAL PROD1 RIH with CoilTrak /RES /Agitator Lateral BHA #17 with HCC BC Bit #12 and 1.1 deg Xtreme motor. BHA OAL = Circ. at 0.2 bpm. 19:15 - 19:30 0.25 DRILL N DFAL PROD1 Log GR down from 15,660 ft. Correct +12 ft. 19:30 - 20:30 1.00 DRILL N DFAL PROD1 Resume RIH. Pass through window on 1st attempt at 30L. 20:30 - 21:45 1.25 DRILL P PROD1 Tag bottom at 17,107 ft and drill to 17.138 ft. Initial WOB is 2.92 Klbs, CT weight = 1-2 Klbs, 100-500 psi motor work. Start stacking weight right away with little motor work. Pick up, free spin = 3,900 psi C~ 1.24 ! 1.22 bpm. 21:45 - 00:00 2.25 DRILL P PROD1 Stall at 17,138 ft, pickup is 39 Klbs some overpull off bottom. Resume drilling at 17,138 ft at 1.24 / 1.24 bpm, 4,000 psi. WOB is 2.0 Klbs, CT weight is 0 - 5 Klbs. Stall at 17,166 ft, continue drilling at ROP = 60 fUhr, WOB = 1 - 2 Klbs, CT weight = 0 - 5 Klbs. 3/16/2008 00:00 - 01:40 1.67 DRILL P PROD1 Continue drilling from 17,203 ft to 17,250 ft. 01:40 - 03:15 1.58 DRILL P PROD1 Wiper trip from 17,250 ft to 15,750 ft. 03:15 - 05:00 1.75 DRILL P PROD1 Drill from 17 250 ft t 1 05:00 - 06:10 1.17 DRILL P PROD1 Drill from 17,282 to 17,303 ft at 10 - 30 ft/hr, WOB = 2-3 Klbs, CT weight is -7 Klbs, 1.25 / 1.22 bpm ~ 4,200 psi. 06:10 - 08:30 2.33 DRILL P PROD1 Stacking weight at 17,303 ft, pick up is 39 Klbs. Printetl: 3/27/2008 1:54:Ll PM ~ ~ BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date ~ From - To Hours ~ Task (Code NPfi Phase Description of Operations -___ _ _ - 3/16/2008 06:10 - 08:30 2.331 DRILL P PROD1 Continue drilling slowly past 17,305 ft. Difficult weight transfer. 08:30 - 10:10 1.67 DRILL P PRODi 10:10 - 12:00 1.83 DRILL P PROD1 12:00 - 14:00 2.00 ~ DRILL ~ P ~ ~ PROD1 14:00 - 16:45 ~ 2.75 ~ DRILL ~ P ~ ~ PROD1 16:45 - 17:50 1.08 DRILL P PROD1 17:50 - 18:15 0.42 DRILL P PROD1 18:15 - 19:40 1.42 DRILL P PROD1 19:40 - 21:10 1.50 DRILL P PROD1 21:10 - 21:25 0.25 DRILL P 21:25 - 21:45 0.33 DRILL P 21:45 - 23:00 1.25 DRILL P 23:00 - 23:30 0.50 DRILL P 23:30 - 00:00 0.50 DRILL P 13/17/2008 100:00 - 01:30 I 1.501 DRILL I P 01:30 - 03:00 1.50 ~ DRILL P 03:00 - 06:45 3.75 DRILL P 06:45 - 07:00 0.25 DRILL P 07:00 - 08:00 1.00 DRILL P 08:00 - 08:15 0.25 CASE P 08:15 - 11:00 I 2.751 CASE I P PROD1 PROD1 1.3 bpm, 4000-4200 psi, 2.5K wob, 12.1 ecd, 88 deg incl, 30 fph. Drilled to 11,367'. Wiper trip to window. Clean hole. RIH clean to bottom. Drill lateral, 1.2 bpm, 3900 - 4200 psi, 1.6 k wob, 30 fph, 84 deg incl, Drilled to 17,415'. Drill lateral, 1.2 bpm, 3900 - 4200 psi, 1.6 k wob, 30 fph, 90 deg incl, Drilled to 17,460'. Drill lateral, 1.2 bpm, 3900 - 4200 psi, 1.6 k wob, 20 fph, 92 deg incl, Drilled to 17,498'. Wiper trip to window. Log GR tie-in at window. Added 6' CTD. RIH clean to bottom. Slightly ragged hole from 17,300 ft to TD. Drill from 17,500 ft to 17,508 ft. Stacking weight and very low ROPs. Pickup from 17,506 ft is 40 Klbs. - Take geologic samples now at 30 min intervals to detect shale as soon as possible. Pull a 200 ft wiper back to 17,300 ft. Hole is in poor condition, 4-5 Klbs overpull during wiper and stacking weight while running in. Drill from 17,508 ft. Stacking -8 Klbs CT weight to drill ahead, WOB = 3.1 Klbs. ROP 0 - 10 Whr at 1.26 / 1.23 bpm ~ 4,250 psi. Sample at 21:30 is 50% shale, call TD. ROP is too slow to drill GR tool past the shale zone. *** Security Notified at 22:00 of rig move 72hrs from now. *** PROD1 Pull wiper trip back through window. PROD1 Log GR down from 15,660 ft to tie-in. Correct +2 ft. PROD1 RIH to bottom for cleanout and lay in liner pill. Clean hole up to a depth of 17,300 ft. PROD1 Continue wiper trip to bottom. Slightly ragged hole seen after 17,300 ft. Ta bottom at 17 506 ft, then pick up for wiper trip back to 17,300 ft. Repeat 2 more times until hole is clean in this area. PROD1 Lay in 26 bbl liner pill from TD of new 9.3 ppg FloPro with 5% tube and 3 ppb Alpine beads. POOH. Pull thorugh window and pump 1.26 bpm to clean 4-1/2" casing. PROD1 POH to surface. Circ at full rate thru open EDC while POH. PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out BHA. PROD1 Lay out Coiltrak drilling BHA. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping inhibitor and blowing down reel with N2. RUNPRD Pumped 50 bbl rig water thru coil. 17 bbl inhibitor, 5 bbl Nnntea: siznzuua i:oa:n rnn ~ ~' BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase I Description of Operations __I 3/17/2008 08:15 - 11:00 2.75 CASE P RUNPRD MEOH. Blow down reel with N2 to Tiger tank. Bleed off pressure in coil. 11:00 - 12:15 1.25 CASE P RUNPRD Cut off SWS CTC and cap end of E-Line. M/U internal grapple and pull test. 12:15 - 12:30 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil stub to reel and securing the coil on the reel. 12:30 - 16:00 3.50 CASE P RUNPRD Pull coil to reel and secure coil on reel with crossbar and chains. Pick reel with overhead crane and prep to lower reel onto trailer. 16:00 - 16:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and ~ mitigation for lowering E-Coil reel onto trailer and picking up E-Free coil. 16:15 - 17:45 1.50 CASE P RUNPRD Open Bombay door and lower 2" E-coil to trailer and secure reel on trailer. Pick 2" E-Free coil from trailer and secure in reel stand. Install hardline inside reel. M/U internal grapple and pull test. 17:45 - 18:20 0.58 CASE P RUNPRD Pull coil into injector. Cut off internal grapple and Weld on SWS CTC. 18:20 - 18:40 0.33 CASE P RUNPRD SAFETY MEETING. Discuss hazards, fire watch responsibilities, and crew placement for welding on CTC. 18:40 - 19:30 0.83 CASE P RUNPRD Weld on CT connector. Hook up 1502 iron iside reel. 19:30 - 20:20 0.83 CASE P RUNPRD Pull test CT connector to 35 Klbs, good. Install dart catcher on end of CT. Nordic crew change. 20:20 - 21:20 1.00 CASE P RUNPRD Line up to fill reel. Pump 6.7 bbls McOH then shut in inner reel valve, PT reel hardline to 4,000 psi, good. Open up and pump 4 bbls water then switch to mud, fill reel. 21:20 - 22:00 0.67 CASE P RUNPRD Insert volume dart and pump it forward. Reel volume is 41.8 bbls. Shut down and install test plate, PT connector to 4,000 psi, good. 22:00 - 22:30 0.50 CASE P RUNPRD Pre are to run liner.. MU safety joint, stand back injector and circulate while running liner. 22:30 - 22:50 0.33 CASE P RUNPRD SAFETY MEETING. Discuss procedures, hazards and mitigations for running slotted + solid liner. 22:50 - 00:00 1.17 CASE P RUNPRD Run liner as per program: 2-3/8" Guide Shoe, 29 joints 2-3/8" STL 4.7 ppf L-80 slotted liner, 5 'ts 2-3/8" STL 4.7 f L-80 solid liner Ported baffle plate, Float Collar, 2 solid pups, O-ring Sub, 61 joints 2-3/8" STL 4.7 ppf Chrome solid liner with cementralizers, BOT 13CR80 Chrome De to ment Sleeve. Total Liner BHA Length: 2,949.50 ft 3/18/2008 00:00 - 03:00 3.00 CASE P RUNPRD Continue running 2-3/8" solid liner. Run total of 61 jts of solid liner. Liner total length with Baker equipment = 2,949.5'. 03:00 - 03:30 0.50 CASE P RUNPRD SAFETY MEETING. Discuss hazards, procedures and mitigations for running 1 "CSH string inside the 2-3/8" liner. 03:30 - 04:00 0.50 CASE P RUNPRD Roll excess 2-3/8" liner off to to side so 1" CSH can be picked up. rnrnea: aienzuuo i:ov:zi rm • BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date II From - To Hours Task Code NPT 3/18/2008 03:30 - 04:00 0.50 CASE P 04:00 - 08:30 4.50 CASE P Spud Date: 3/5/2008 Start: 2/29/2008 End: 3/21 /2008 Rig Release: 3/21/2008 Rig Number: Phase ~ Description of Operations RUNPRD Change out dies on Little Jerk tongs so it can grip 1"CSH. RUNPRD Run 1"CSH. Sting into O-Ring sub with 1"slick stick. Pick up and space out with pup jts. Fill backside of 1 "CSH with water. Press test against O-Ring sub with 600 psi. Good test. 08:30 - 11:10 2.671 CASE P 11:10 - 11:55 0.751 CASE P 11:55 - 16:30 I 4.581 CASE I P 16:30 - 16:45 I 0.251 CEMT I P 16:45 - 18:00 1.25 CEMT P 18:00 - 19:00 1.00 CEMT P 6rlH VHL = GAO 1 . I . RUNPRD RIH with liner on E-Free 2" coil. Circ at 0.2 bpm. Up Wt at 15,700' = 40K. RIH clean thru window at 15,726'. RUNPRD RIH clean in open hole. RIH past open hole sidetrack at 17,060' clean. RIH clean to TD. Landed liner at 17,507' CTD. Pick up with 44K and land liner again at same depth. Liner is landed on bottom. RUNPRD Circ. 5/8" AL ball to release from liner with CTLRT. Up weight is 32 Klbs after release. 1.0 bpm, 3750 psi.Swap well to 9.3 ppg KCL. RUNPRD PJSM for cement job. Communications and PT value and launch sequence discussed. RUNPRD Circualte 1.3 bpm @ 3850 psi. Bump 2 bbl H2O and PT to 6000 psi. Pump 11.9 bbl cement 15.8 ppg. 1.37/1.32 bpm ~ 4050 psi. Close choke. Flush Bio to cementers. RUNPRD Launch dart and zero in /out MM. Chase with 29.5 bbls of 2 ppb biozan water then KCI water at 1.25 / 1.19 bpm, 4,050 psi. Pressure increases when cement starts into CSH. Reduce rate to 1.0 / 0/97 bpm C~? 4,400 psi. Zero out MM at 31.7 bbls displacement, when cement turns corner. Slow down pump to 0.5 bpm at 37 bbls in to watch for dart landing. then stop pumping. 19:00 - 22:00 3.00 CEMT P RUNPRD Shut down pump at 43.8 bbls in. Total of 11.9 bbls cement behind i e. Pick up out of seals then pump minimum rate. Run back down to O-ring sub and contaminate with biozan. Stop just above O-ring sub and circ 2 bbls biozan at minimum rate. POOH replacing coil voidage. 22:00 - 22:15 0.25 CEMT P RUNPRD SAFETY MEETING. Discuss procedures, hazards and mitigations for laying out BHA and standing back 1" CSH. 22:15 - 23:40 1.42 CEMT P RUNPRD Tag stripper. Break off riser, stand back injector and circulate while pulling CSH. Stand back CSH in doubles. 23:40 - 00:00 0.33 EVAL P LOWERI Run BHA #19. 1.875" diamond speed mill, 1.69 X-treme motor, 1/2" ball circ sub, 5/8" ball disconnect, 72 jts of 1"CSH, 3/4" ball disconnect, check valve, lockable swivel. Total BHA length is 2,249.57 ft. 3/19/2008 00:00 - 01:40 1.67 EVAL P LOWERI Continue running BHA #19. 01:40 - 04:00 2.33 EVAL P LOW ER1 MU injector to wellhead. RIH. 04:00 - 06:15 2.25 EVAL N CEMT LOW ER1 Stop at 12,000 ft and wait on cement. UCA shows zero Printed: 3/27/2008 1:54:21 PM BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date ~~, From - To Hours Task Code NPT li Phase; Description of Operations 3/19/2008 04:00 - 06:15 2.25 EVAL N 06:15 - 08:10 ~ 1.92 ~ EVAL ~ P 08:10 - 10:00 1.83 EVAL P 10:00 - 14:30 4.50 EVAL N 14:30 - 15:00 I 0.50 I EVAL I N 15:00 - 18:00 3.00 EVAL P 18:00 - 19:20 1.33 EVAL P 19:20 - 21:40 I 2.33 I EVAL I P 21:40 - 00:00 I 2.331 EVAL I P 3/20/2008 00:00 - 02:20 2.33 EVAL P 02:20 - 03:40 1.33 EVAL P 03:40 - 04:40 04:40 - 07:30 07:30 - 08:20 1.00 EVAL N 2.83 EVAL N 0.83 EVAL N 08:20 - 11:30 11:30 - 12:15 12:15 - 14:00 14:00 - 14:15 3.17 EVAL N 0.75 EVAL N 1.75 WHSUR P 0.25 WHSUR P CEMT LOW ER1 compressive strength after 6.75 hrs 05:00 -UCA zero psi after 7 hr 56 min. LOWERI Cement in place 11 hours. RIH to "O"Ring sub while waiting on UCA 500psi, Liner top clean. Continue to RIH lbpm ~ 3060 psi. taq at 16405 uncorrected. LOWERI POH to liner top CEMT LOWERI WOC 13:50 hrs 500 psi compressive strength.1100 psi at 14:30 hrs CEMT LOWERI Attempt to Test lap to 2000 psi.. Broke down at 1800 psi. Repressure to 1633psi bleed off to 1240 in 3 minute. Failed to test. LOWERI RIH 16,405' Mill out O ring sub..98 bpm @ 3650 psi 3400 psi FS. Stall at 16417.9' PU Wt 34K. Possibly baffle plate. LOWERI Stall at 16,417.9 ft. Pick up and run back in slowly, stall at 16,415 ft. Pump a biozan sweep around. Run in and mill slowly from 16,415 ft to 16,416.6 ft. LOWERI Pick up to check FS and up weight. FS = 3,660 psi, up weight is 32 Klbs clean pickup. Run in slowly to 16,416.08 ft, take around 200 - 300 psi motor work here. Mill slowly to 16,417 ft. Stall at 16,417 ft, clean pickup. Ease back down to 16,417 ft. Mill slowly from here. LOWERI Pump a 5 bbl biozan sweep. Appear to have milled through obstruction, increase ROP. RIH at 10 fUmin to 16,750 ft. Slow down when entering slotted liner. Pull back up hole from 16,750 ft after sweep is out. Pull back to 16,400 ft then run back to 16,420 ft, nothing seen. Drop a 1/2" circ ball, start POOH. Ball seats and shears at 4.200 psi. Pump 1.20 bpm on way out. LOWERI Continue POOH. LOWERI Tag stripper. Break off CT riser and stand back injector. Stand back CSH, 36 stands in derrick. CEMT LOWERI Pick up BHA #20 -Liner top packer. CEMT LOWERI RIH. CEMT LOWERI Stab into seal stem seen 250 psi increase. RIH 4' stack 10K. Shutin 07:35 hrs 1937 psi a ~ 07:37 hrs 1923 psi ~ ~ ~_ ~i '~ 07:41 hrs 1908 psi ~ t S 1 ~ 07:48 hrs 1890 psi ~~ i~ L 08:01 hrs 1875 psi ~ ~ ~ ~~ ,[ 08:07 hrs 1868 psi Lost 55 psi in 30 min Good Test. Breed off unsting. ~~ CEMT LOWERI POH. CEMT LOWERI LD BHA and KB packer. PU swizzel stick POST Flush stack. RIH to 5500'. POST PJSM for Ru and freeze protecting using Little Red to transfer diesel to rig. Printetl: 3/'L 7/2UU8 1:54:'[1 PM • BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: P2-08 Common Well Name: P2-08 Spud Date: 3/5/2008 Event Name: REENTER+COMPLETE Start: 2/29/2008 End: 3/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/21/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hotars Task i Code NPT Phase Description of Operations P POST Circulate diesel to nozzel at 2 bpm ~ 2340 psi. POH. Circulate 3/20/2008 14:15 - 16:15 2.00 WHSUR 16:15 - 18:30 I 2.251 WHSUR I P I I POST 18:30 - 19:00 0.50 WHSUR P POST 19:00 - 20:30 1.50 WHSUR N SFAL POST 20:30 - 20:45 0.25 WHSUR P POST 20:45 - 21:15 0.50 WHSUR P POST 21:15 - 21:20 0.08 WHSUR P POST 21:20 - 21:30 0.17 WHSUR P POST 21:30 - 22:00 0.50 WHSUR P POST 22:00 - 23:20 1.33 RIGD P POST 23:20 - 00:00 0.67 RIGD P POST 3/21/2008 00:00 - 01:20 1.33 RIGD P POST 01:20 - 01:30 0.17 RIGD P POST 01:30 - 01:40 0.17 RIGD P POST 01:40 - 04:10 2.50 RIGD P POST 04:10 - 04:25 0.25 RIGD P POST 04:25 - 06:00 1.58 RIGD P POST 06:00 - 06:15 0.25 RIGD P POST 06:15 - 08:00 1.75 RIGD P POST 08:00 - 18:00 10.00 RIGD N WAIT POST thru choke holding 450 WH pressure. Shut in well final WHP = 340 psi. PU Lubricator and RU same.Test Lubricator to 1000 psi. OK. Open master & swap 340 psi well head pressure. Set BPV. Close master valve. Clear rig floor of BPV lubricator and running equipment. Repair N2 unit. Line to flowback tank is frozen. Try to pump McOH through with rig pump, able to push fluid out to tank. Pump 3-4 bbls out to flowback tank to clear line. MU injector to wellhead. Line up to fresh water to start reel purge sequence. SAFETY MEETING. Discuss procedures, crew placement, hazards and mitigations for purging reel with N2. Pump 40 bbls fresh water, followed by 14 bbls inhibited water, followed by 2 bbls McOH. Shut down fluid pump and line up valves to start N2 down the reel. Oil sprays from N2 deck engine, shut down pump. Spill from N2 unit: Ice plug forms in breather cap on N2 unit deck engine, resulting in motor oil spray from dipstick tube. Total of 0.5 gal of motor oil spilled onto pad. Spill reported to x5700 and entered into Traction 2008-IR-2583674. Contaminated snow scraped up and disposed of at SRT. Spill is non-recordable due to < 1 gal. Resume circulation at minimum rate while repairing N2 unit. Unit is ready, purge reel with 1,500 scfm for 10 minutes. Shut down and allow coil to bleed off. SAFETY MEETING. Discuss procedures, hazards and mitigations for cutting off CT connector, installing grapple connector and pulling CT across. Break off well. Cut off CT connector and dress end for grapple connector. Install grapple connector and pull test. Pull CT across and secure it to shipping drum. Remove grapple connector. Continue rig down. Vac remaining fluid from flowback tank and pits. Stand injector back, set it on legs. Prepare to replace annular BOP element. SAFETY MEETING. Discuss hazards and mitigations for changing out annular element. Replace annular BOP element. SAFETY MEETING. Discuss hazards, crew placement, and procedure for cut and slip of drilling line. Cut and slip 45 ft of drilling line. PJSM for ND BOP. ND BOP and NU tree cap and test. ** Ria released Osnn Wait on weather to start rolling tires, temp < -40. Printed: 3/27/2008 1:54:21 PM • • b BP Alaska r p Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 3!17!2008 Time: 10:49:02 Pagc: 1 °Fiehl: Point McIntyre Co-ardirate(NE) Rekrence: Well: P2-08, True North :Site: Pt Mac 2 Vertical (1'VD) Retertnce: P2-08 49.0 Well: P2-0$ Sakios (VS) Re&reee; Well (O.OON,O.OOE,76.84Azi) WeBpath: P2-08APB1 Survey CAkwhrt~® Method: Minimum Curvature Db: Orade Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map 7.oue: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordiuate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 59951 40.76 ft I.atitnde: 70 23 32.530 N From: Map Eastiug: 674873.98 ft Longitude: 148 34 37.934 W Position Uncertainty: 0.00 ft North Retereuee: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg WeII: P2-08 Slat Name: 08 P2-08 Well Position: +N/-S 3303.59 ft Northing: 5998595.59 ft Latitude: 70 24 4.992 N +E/-W 6513.96 ft Easting : 681308.47 ft Longitude: 148 31 27.090 W Positioe Uncertatuty: 0.00 ft We0path: P2-08APB1 Drilled From: P2-08 500292289670 Tie-on Depth: 15662.62 ft Current Datum: P2-08 Height 49.02 ft Above System Datum: Mean Sea Level Magnetic Data: 2/29/2008 Declination: 23.44 deg Field Strength: 57679 uT Mag Dip Aogk: 81.00 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.22 0.00 0.00 76.84 Survey Program for Definitive Welipatb Date: 12/4/2006 Validated: Yes Version: 4 Actual From To Survey Tookode Tool Name ft ft 100.00 15662.62 Survey #1 MWD Standard (100.00 MWD MWD -Standard 15726.00 17277.00 MWD (15726.00-17277.00) MWD MWD -Standard Annotatioe MD TVD ft. ft 15662.62 9026.33 TIP 15726.00 9062.30 KOP 17277.00 9086.33 TD Survey: MWD Start Date: 3/6/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Igcl `Azim TVD SysTVD N/S FJW MapN MapE VS I)LS Tool ft tieg deg R ft - ft ft ft ft ft deg/100ft 15662.62 55.69 70.00 9026.33 8977.31 2993.84 10168.38 6001835.07 691400.57 10582.92 0.00 MWD 15726.00 55.14 69.98 9062.30 9013.28 3011.69 10217.41 6001854.11 691449.15 10634.72 0.87 MWD 15726.00 55.14 69.98 9062.30 9013.28 3011.69 10217.41 6001854.11 691449.15 10634.72 0.00 MWD 15726.00 55.14 69.98 9062.30 9013.28 3011.69 10217.41 6001854.11 691449.15 10634.72 0.00 MWD 15726.00 55.14 69.98 9062.30 9013.28 3011.69 10217.41 6001854.11 691449.15 10634.72 0.00 MWD 15726.00 55.14 69.98 9062.30 9013.28 3011.69 10217.41 6001854.11 691449.15 10634.72 0.00 MWD 15766.28 67.33 73.37 9081.65 9032.63 3022.71 10250.87 6001865.93 691482.34 10669.82 31.14 MWD 15778.85 73.35 74.30 9085.88 9036.86 3026.00 10282.24 6001869.50 691493.62 10681.64 48.40 MWD 15786.98 79.04 74.87 9087.82 9038.80 3028.10 10269.85 6001871.78 691501.17 10689.52 70.32 MWD 15796.76 83.38 75.55 9089.31 9040.29 3030.57 10279.19 6001874.47 691510.45 10699.18 44.90 MWD 15831.96 84.47 77.87 9093.04 9044.02 3038.61 10313.25 6001883.34 691544.31 10734.18 7.25 MWD • by BP Alaska $ Baker Hughes INTEQ Survey Report iNTEQ Cowpany: BP Amoco Date: 3/17/2008 Time: 10:49:02 Page: 2 Field: Point McIntyre Ge-ord~atc(NE} Reference: Well: P2-08, True North Site: Pt Mac 2 Ver~icsl (TVD} Reference: P2-OS 49.0 Well: P2- 08 Sectise (VS) Reference: Well (O.OON,O.OOE,76.84Azi) Wellpat6: P2-08APB1 Sarvey CakakNiea Metbod: Minimum Curvature Db: Orade Survey MD Iacl A zim TVD Sys TVD N/S E/W Maple MapE VS DLS Tool ft- deg -deg ft ft ft ft $ ft ft deg/100ft 15868.10 85.64 77.42 9096.15 9047.13 3046.32 10348.42 6001891.90 691579.28 10770.18 3.47 MWD 15900.24 87.79 79.28 9098.00 9048.98 3052.80 10379.84 6001899.14 691610.53 10802.25 8.84 MWD 15930.34 88.19 80.60 9099.05 9050.03 3058.05 10409.46 6001905.11 691640.01 10832.29 4.58 MWD 15961.98 88.96 82.94 9099.84 9050.82 3062.58 10440.76 6001910.39 691671.20 10863.80 7.78 MWD 15990.66 89.82 84.83 9100.14 9051.12 3065.63 10469.28 6001914.14 691699.63 10892.26 7.24 MWD 16021.14 89.85 86.66 9100.23 9051.21 3067.89 10499.67 6001917.13 691729.95 10922.37 6.00 MWD 16057.62 90.58 88.80 9100.09 9051.07 3069.34 10536.12 6001919.46 691766.35 10958.19 6.20 MWD 16090.56 91.69 90.56 9099.44 9050.42 3069.52 10569.05 6001920.45 691799.27 10990.30 6.32 MWD 16122.60 91.93 90.37 9098.43 9049.41 3069.26 10601.08 6001920.96 691831.29 11021.43 0.96 MWD 16155.28 92.37 90.41 9097.20 9048.18 3069.04 10633.73 6001921.53 691863.94 11053.17 1.35 MWD 16185.82 93.35 91.39 9095.68 9046.66 3068.56 10664.23 6001921.80 691894.44 11082.76 4.54 MWD 16216.54 92.86 91.78 9094.02 9045.00 3067.71 10694.89 6001921.69 691925.11 11112.43 2.04 MWD 16248.42 91.32 95.00 9092.85 9043.83 3065.83 10726.69 6001920.58 691956.94 11142.96 11.19 MWD 16278.10 91.66 97.04 9092.08 9043.06 3062.72 10756.19 6001918.18 691986.51 11170.98 6.97 MWD 16308.92 92.06 98.50 9091.08 9042.06 3058.55 10786.72 6001914.76 692017.12 11199.75 4.91 MWD 16340.27 92.00 100.88 9089.97 9040.95 3053.28 10817.60 6001910.24 692048.12 11228.62 7.59 MWD 16370.66 90.95 102.75 9089.19 9040.17 3047.06 10847.33 6001904.74 692077.99 11256.16 7.06 MWD 16399.84 91.35 104.84 9088.60 9039.58 3040.10 10875.66 6001898.48 692106.48 11282.17 7.29 MWD 16429.14 92.00 107.17 9087.75 9038.73 3032.03 10903.81 6001891.09 692134.82 11307.74 8.25 MWD 16459.64 91.96 106.53 9086.69 9037.67 3023.19 10932.98 6001882.96 692164.20 11334.14 2.10 MWD 16491.70 89.79 106.17 9086.20 9037.18 3014.17 10963.74 6001874.69 692195.16 11362.03 6.86 MWD 16522.98 91.97 107.46 9085.72 9036.70 3005.12 10993.68 6001866.37 692225.31 11389.12 8.10 MWD 16557.25 90.71 107.24 9084.92 9035.90 2994.91 11026.38 6001856.95 692258.24 11418.64 3.73 MWD 16590.30 91.81 107.79 9084.19 9035.17 2984.96 11057.89 6001847.78 692289.98 11447.06 3.72 MWD 16620.84 92.58 107.71 9083.02 9034.00 2975.66 11086.95 6001839.18 692319.26 11473.24 2.53 MWD 16650.83 93.03 108.92 9081.56 9032.54 2966.25 11115.39 6001830.46 692347.92 11498.79 4.30 MWD 16682.57 93.41 109.19 9079.77 9030.75 2955.90 11145.34 6001820.85 692378.11 11525.60 1.47 MWD 16711.50 93.23 108.99 9078.10 9029.08 2946.46 11172.64 6001812.07 692405.62 11550.03 0.93 MWD 16743.22 91.23 108.05 9076.86 9027.84 2936.39 11202.69 6001802.73 692435.91 11577.00 6.97 MWD 16775.22 91.01 108.82 9076.24 9027.22 2926.27 11233.04 6001793.36 692466.50 11604.25 2.50 MWD 16807.18 91.66 107.92 9075.49 9026.47 2916.20 11263.36 6001784.03 692497.05 11631.49 3.47 MWD 16837.84 91.47 109.18 9074.66 9025.64 2906.45 11292.42 6001774.98 692526.34 11657.56. 4.15 MWD 16869.09 85.89 110.18 9075.38 9026.36 2895.93 11321.83 6001765.18 692555.98 11683.80 18.14 MWD 16899.90 86.10 111.45 9077.53 9028.51 2885.01 11350.55 6001754.96 692584.97 11709.29 4.17 MWD 16942.54 87.45 114.97 9079.93 9030.91 2868.24 11389.67 6001739.14 692624.48 11743.56 8.83 MWD 16971.88 88.34 115.06 9081.01 9031.99 2855.84 11416.24 6001727.39 692651.34 11766.61 3.05 MWD 16999.88 88.10 113.84 9081.88 9032.86 2844.26 11441.72 6001716.43 682677.09 11788.78 4.44 MWD 17031.40 88.43 113.03 9082.83 9033.81 2831.73 11470.62 6001704.61 692706.29 11814.08 2.77 MWD 17063.14 90.52 112.36 9083.12 9034.10 2819.48 11499.90 6001693.08 692735.86 11839.80 6.91 MWD 17101.12 89.94 113.14 9082.97 9033.95 2804.79 11534.93 6001679.25 692771.22 11870.57 2.56 MWD 17136.82 87.79 114.02 9083.67 9034.65 2790.52 11567.64 6001665.77 692804.27 11899.17 6.51 MWD 17168.52 87.54 113.59 9084.97 9035.95 2777.73 11596.62 6001653.69 692833.55 11924.48 1.57 MWD 17199.10 89.45 114.06 9085.77 9036.75 2765.39 11624.58 6001642.03 692861.80 11948.89 6.43 MWD 17233.40 89.63 113.63 9086.04 9037.02 2751.52 11655.95 6001628.93 692893.50 11976.29 1.36 MWD 17277.00 89.63 113.63 9086.33 9037.31 2734.04 11695.90 6001612.43 692933.85 12011.20 0.00 MWD • • BP Alaska ~R r by Nu+rr~s Baker Hughes INTEQ Survey Report INTEQ Company: BP AmoCO Date: 3/17/2008 Time: 10:51:22 Page: t Fietd: Point McIntyre Cs~rdiaate(NE) Reference: Well: P2-08, True North Site: Pt Mac 2 Verbal (TVB) Reference: P2-OS 49.0 Weli: P2-08 Seetiaa (VS) Reference: Well (O.OON,O.OOE,77.88Azi) Wellpath: P2-08A S®rvey Cakalatioo Method: Minimum Curvature Db: Orade Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1868) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geamagaetic Model: bggm2007 Site: Pt Mac 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5995140.76 ft Latitude: 70 23 32.530 N From: Map Fasting: 674873.98 ft Longitude: 148 34 37.934 W Posittoa Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: P2-08 Slot Name: 08 P2-08 Weli Position: +N/-S 3303.59 ft Northing: 5998595.59 ft Latitude: 70 24 4.992 N +E/-W 6513.96 ft Fasting : 681308.47 ft Longitude: 148 31 27.090 W Positaa Uncertainty: 0.00 ft Weilpath: P2-08A Drtlkd From: P2-08AP61 500292289601 Tie-on Depth: 17031.40 ft Current Datum: P2-08 Height 49.02 ft Above System Datu m: Mean Sea Level Magnets Data: 3/17/2008 Declination: 23.42 deg Field Strength: 57680 aT Mag Dip Angle: 81.00 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.22 0.00 0.00 77.88 Survey Prograro for Definitive Wellpath Date: 3/17/2008 Validated: Yes Version: 1 Actual From To Survey Toolcode Tool Name ft ft 100.00 15662.62 Survey #1 MWD Standard (100.00 MWD MWD -Standard 15726.00 17031.40 MWD (15726.00-17277.00) (1) MWD MWD -Standard 17060.00 17506.00 MWD (17060.00-17506.00) MWD MWD -Standard ~nnofation MD TVD ft tt 17031.40 9082.83 TIP 17060.00 9083.98 KOP t 7506.00 9098.67 TD Survey: MWD Start Date: 3!17/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path • by BP Alaska s Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 3117/2008 Time: 10:51:22 Page: 2 Fiehl: Point McIntyre Co-ordhlEjReference: Well: P2-08, True North Site: Pt MaC 2 Vert~at (TVD) Refereace: P2-08 49.0 Weg: P2-OS Sect~e(VS}Refereece: Well (O.OON,O.OOE,77.88Azi) Welipath: P2-08A Sarvey CaienMHee Method: Minimum Curvature Db: Orade Sarvey MD Ind Azim TVD Sys TVD N/S F./1V MapN AfapE VS DLS Tool ft deg . ...:deg ft ft ft ft tt ft ft deg/100ft 17031.40 88.43 113.03 9082.83 9033.81 2831.73 11470.62 6001704.61 692706.29 11809.49 0.00 MWD 17060.00 86.94 116.20 9083.98 9034.96 2819.83 11496.60 6001693.34 692732.54 11832.39 12.24 MWD 17089.91 85.39 119.53 9085.99 9036.97 2805.88 11522.98 6001680.04 692759.25 11855.25 12.26 MWD 17120.49 87.51 128.45 9087.88 9038.86 2788.83 11548.28 6001663.62 692784.93 11876.39 29.93 MWD 17151.31 88.93 134.46 9088.84 9039.82 2768.45 11571.33 6001643.80 692808.50 11894.67 20.03 MWD 17182.19 90.61 140.65 9088.97 9039.95 2745.67 11592.16 6001621.54 692829.87 11910.25 20.77 MWD 17212.45 86.68 142.17 9089.68 9040.66 2722.03 11611.03 6001598.36 692849.30 11923.73 13.92 MWD 17241.47 85.26 139.04 9091.72 9042.70 2699.67 11629.40 6001576.45 692868.21 11937.00 11.82 MWD 17275.43 88.19 134.76 9093.66 9044.64 2674.92 11652.56 6001552.27 692891.96 11954.44 15.26 MWD 17305.81 90.49 129.62 9094.01 9044.98 2654.53 11675.06 6001532.43 692914.95 11972.16 18.53 MWD 17339.19 88.37 128.24 9094.34 9045.32 2633.55 11701.02 6001512.10 692941.41 11993.14 7.58 MWD 17369.37 82.56 125.02 9096.73 9047.71 2615.61 11725.15 6001494.75 692965.96 12012.97 21.99 MWD 17405.37 84.94 123.21 9100.65 9051.63 2595.54 11754.77 6001475.41 692996.07 12037.72 8.29 MWD 17438.17 90.74 122.74 9101.88 9052.86 2577.71 11782.26 6001458.25 693023.97 12060.85 17.74 MWD 17466.91 93.25 120.99 9100.88 9051.86 2562.55 11806.65 6001443.68 693048.72 12081.51 10.64 MWD 17506.00 93.25 120.99 9098.67 9049.65 2542.46 11840.10 6001424.41 693082.65 12110.00 0.00 MWD TREE = FMC WELLHEAD = CMI ACTUATOR = BAKER C KB. ELEV = BF. ELEV = KOP = 2933' Max Angle = 93 @ 16,682' Datum MD = 15330' Datum ND = 8800' SS P2-08A DRLG DRAFT 9-518" CSG, 40#, L-80, 10 = 8.835" ~ 546 J' Minimum ID = 1.87" @ 16435' O-RING SUB, FLOAT CLR, DN SUB 7" CSG, 26#, L-80, ID = 6.276" I-{ 14500' TOP OF 2-3/8" 13cr80 LNR (~ 14557' 3-1/2" TBG, 9.2#, 13CR, .00914 bpf, ID = 3.068" ~ 14594' TOP OF 4-1/2" LNR 14591' EST. TOC 14760' 7" CSG, 29#, L-80, ID = 6.184" 14874' Mechanical Whipstock 15726' PERFORATION SUMMARY REF LOG: ANGLE AT TOPPERF: 92° @ 16586' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3(8" 16586 - 17505 O 03/17/08 SLOTTED LNR PBTD 15932' 4-1/2" LNR, 12.6#, 13Cr. 0.0152 bpf, 10 = 3.958" 15971' ST MD ND DEV TYPE VLV LATCH PORT DATE 1 4198 4049 38 FMHO DMY RK 0 01/17/07 2 5464 4947 45 FMHO DOME RK 16 03/31 /08 3 8447 6096 75 FMHO DMY RK 0 07/17/99 4 10525 6891 64 FMHO SO TG 20 03/31/08 5 12470 7696 69 FMHO DMY RK 0 11 /21 /98 6 14207 8375 65 FMHO DMY RK 0 11/21!98 7 14482 8482 68 FMHO DMY TG 0 01/17/07 14546' -j 7" X 3-1/2" BAKER S-3 14571' 3-1/2" HES X NIP, ID = 2.81" 14582' 3-1/2" HES XN NIP, MILLED IO = 2.80" 14593' ~~ 3-1/2" WLEG 14596' ELMD TT LOGGED 08/30/99 16435' (-I BOTTOM OF CEMENT 16435' -jBaffle plate Milled out to 1.87" I 2-318" 13Cr80 cemented/slotted liner DATE REV BY COMMENTS DATE REV BY COMMENTS 12/08/98 ORIGINAL COMPLETION 03/21108 NORDICI CTD SIDETRACK 04/06!08 SWC/SV GLV C/O (03/31/08) POINT MCINTYRE UNfT WELL: P2-08A PERMIT No: 2061690 API No: 50-029-22896-01 SEC 11 T12N R14E 3858.04 FEL 2188.45 FNL BP Exploration (Alaska) • '~ 1990' ~~ 3-1/2", HES SERIES 10, TRSSSV, ID = 2.81" GAS LIFT MANDRELS • ALASKA OIL AND GAS CONSERVATION COMMISSION Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 r SARAH PALIN, GOVERNOR 333 W. 7`h AVENGE, SGITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 F.VC (907)276-75423 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P2-08A BP Exploration (Alaska) Inc. Permit No: 206-169 Surface Location: 18' FSL, 1073' FWL, SEC. 11, T12N, R14E, UM Bottomhole Location: 2394' FSL, 3268' FWL, SEC. 07, T12N, R15E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED thisday of December, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~n STATE OF ALASKA ~~,~~'+' ALAS~IL AND GAS CONSERVATION COMMI~N ~~~ PERMIT TO DRILL 20 AAC 25.005 DEC072006 Alaska Oil & Gas Cons. Commission 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is C~9~r: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU P2-08A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 18400 TVD 9041ss 12. Field /Pool(s): Prudhoe Bay Field /Point 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 365548 McIntyre Pool FSL, 1073 FWL, SEC. 11, T12N, R14E, UM 18 Top of Productive Horizon: 3014' FSL, 710' FWL, SEC. 07, T12N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: March 1, 2007 Total Depth: 2394' FSL, 3268' FWL, SEC. 07, T12N, R15E, UM 9. Acres in Property: 3601 14. Distance to Nearest Property: 1,150' 4b. Location of Well (State Base Plane Coordinates): Surface: x-681308 y-5998596 Zone-ASP4 10. KB Elevation (Height above GL): 49.02 feet 15. Distance to Nearest Well Within Pool: 1,475' 16. Deviated Wells: Kickoff Depth: 15726 feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA :035) Downhole: 4150 Surface: 25 18. C in Pr ram: S cift tions To - ttin De th - B om n i f C n .f. ors cks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD inclu m sta a data 3" 2-3/8" 4.7# 13Cr / L-80 STL 38 14561' 8462' 18400' 9041' 73 sx Class'G' B nzai & Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 15971 Total Depth TVD (ft): 9203 Plugs (measured): None Effective Depth MD (ft): 15932 Effective Depth TVD (ft): 9181 Junk (measured): None asing Length ize - ement Volume MD Conductor! Structural 69' 2 Driven 110' 110' Surface 5431' 9-5/ " 591 sx CS III 4 9 sx Class'G' 877 sx CS III 5469' 4950' Intermediate 14839' 7" 250 sx Class 'G' 14874' 8636' Pr i n Liner 1380' 4-1/2" 43 sx Cla s'G' 14591' - 15971' 8522' - 9203' Perforation Depth MD (ft): 15700' - 15790' Perforation Depth TVD (ft): 9047' - 9099' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By Name/Number: Si nature ~~ Phone 564-4387 Date I~ ~ t3~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Numb r. ~- API Number: 50-029-22896-01-00 Permit Approval Date: ' ( See cover letter for h rr uiremen s Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~ 2 S ~ ~ t7 r~C ~ 3 $r7 O ~0 L.t l wr.L t~.~t, ~, r.~. . PROVED BY THE COMMISSION Date ~ - ~ , © ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ^ ~ ~ ~ ~ A ~ Submit In Duplicate • "" by To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin, CTD Engineer Date: December 5, 2006 Re: Point McIntyre P2-08A CTD Sidetrack Permit to Drill • The sidetrack, P2-08A, is scheduled to be drilled by Nordic 2 during the first week of March. The plan calls for a slimhole lateral with Banzai completion (solid/cemented contingency) to the Kuparuk reservoir. Pre-Rig Work: 1. S Dummy GLV's 2. F MIT-IA, and OA. 3. C Mill XN nipple to 2.8", Drift to 15,800' 4. C Caliper from 15,800' 5. C If caliper indicates reduced ID in the 4-1/2" tubing underream from 15650'-15800' 6. C Dummy WS drift to 15800' 7. O Set BPV 8. O AC-LDS; AC-PPPOT-IC, T 9. O Test MV, SV, WV 10. O Install accumulator for TRSSSV 11. O Bleed gas lift and production flowlines down to zero and blind flange 12. O Remove wellhouse, level pad The pre CTD work is slated to begin on January O1, 2007. Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Pull BPV 3. Set the 3-1/2" x 4-1/2" TTWS at 15726'. Reference Log: Perforating Record from 12/8/98 4. Cement squeeze perforations -15.8 ppg cmt (~12 bbl) 5. Mi112.8" window at 15726' and 10' of openhole. Swap the well to Flo-Pro. ~, 6. Drill Build: 3" OH, 134' 0 deg/100 planned) ~ 7. Drill Lateral: 3" OH, 4 horizontal (12 deg/100 planned) -include resistivity y 8. Run 2 3/8" solid/slotte onzai com ion leaving TOL at 14561' 9. Pump primary cement job to TOL, 5 bl of 15.8 ppg expansive liner cmt planned ~ 10. Test liner lap to 2000 psi. 11. Cleanout run to mill baffle plate 12. Run MCNL/GR/CCL log 13. Freeze protect well, Set BPV, RDMO ._._ Post-Rig Work ~ 1. Pull BPV (J 2. Install well house. Hook up flow line. s Mud Program: • Well kill: 9.2 pp rive • Milling/drilling: .2.~pg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2 3/8" 13Cr solid liner - 14561'MD to 16600'MD • 2 3/8" L-80 Slott ~tner -16600' to 18400' MD ~ • A minimum o 15 blfls 15.8 ppg expansive cement will be used for liner cementing. • TOC planned a~ 14561' Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 00 psi. /~ • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 94 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property -1150' ft • Distance to nearest well within pool -1475' ft to P2-17 Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • The maximum recorded H2S level on P2 pad is 160 ppm in well P2-60 on 10/20/2006. • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 4150 psi at 9010'ss (8.9 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 3250 psi. Sean McLaughlin CTD Drilling Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = FMC WELLHEAD= CM/ ACTUATOR = BAKER C KB. ELEV = BF. ELEV = KOP _ 2933' Max Angle = -Datum MD = DatumTVD= 75 @8469' 15330' 8800' SS ~ P2-08 9-5/8" CSG, 40#, L-80, ID = 8.835" 5469' Minimum ID = 2.750" @ 14582' 3-1/2" HES XN NIPPLE 7" CSG, 26#, L-80, ID = 6.276" I~ 14500' 3-1/2" TBG, 9.2#, 13CR .00914 bpf, ID = 3.068" I--~ 14594 TOP OF4-1/2" LNR 14591' 7" CSG, 29#, L-80, ID = 6.184" ~~ 14874' PERFORATION SUMMARY REF LOG: GR-RES ON 11/12/98 ANGLE AT TOP PERF: 55 @ 15730' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 15700-15720 O 02/23/02 2-1/2" 6 15730-15750 O 08/30/99 2-1/2" 6 15730-15775 O 02/23/02 2-1/2" 6 15750-15755 O 01/11/99 2-1/2" 6 15755-15775 O 12/08/98 2-1/2" 6 15785-15790 O 01/11/99 2-1/2" 6 15785-15790 O 02/23/02 I 3-1/2", HES SERIES 10, TRSSSV, ID = 2.81" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4198 4049 38 FMHO RK 2 5464 4947 44 FMHO RK 3 8447 6096 75 FMHO RK 4 10525 6891 64 FMHO RK 5 12470 7696 69 FMHO RK 6 14207 8375 65 FMHO RK 7 14482 8482 68 FMHO TG 14546' ~ 7" X 3-1/2" BAKER S-3 I 14571' 3-1/2" HES X NIP, ID = 2.81" 14582' 3-1/2" HES XN NIP, ID = 2.75" 14593' 3-1/2" WLEG 145 ELMD TT LOGGED 08/30/99 PBTD 1-1 5932' 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.953" 15971' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/08/98 ORIGINAL COMPLETION 11/20/00 SIS-Isl CONVERTEDTOCANVAS 02/22/01 SIS-MD FINAL 09/15/01 RN/TP CORRECTIONS 02/23/02 JAF/KK AD/REPERFS POINT MCINTYRE UNff WELL: P2-08 PERMfT No: 98-123 API No: 50-029-22896-00 SEC 11 T12N R14E 3858.04 FEL 2188.45 FNL BP Exploration (Alaska) TRFF = FMC WELLHEAD= CNV ACTUATOR = BAKER C KB. ELEV = BF. ELEV = KOP = 2933' Max Angle = 75 @ 8469' Datum MD = 15330' Datum TV D = 8800' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" Minimum ID = 2.80" ~ 14582' 3-1/2" HES XN NIPPLE (milled to 2.8") 7" CSG, 26#, L-80, ID = 6.276" -~ P2-08 A Proposed CTD Sidetrack ITop of Cement I 14561' TOP OF 2-3/8" 13cr80 LNR 14561' 3-1/2" TBG, 9.2#, 13CR, .00914 bpf, ID = 3.068" I TOP OF 4-1/2" LNR I 7" CSG, 29#, L-80, ID = 6.184" I 14591' PERFORATION SUMMARY REF LOG: GR-RES ON 11/12/98 A NGLE AT TOP PERF: 55 @ 15730' ~ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 15700-15720 O 02/23/02 2-1/2" 6 15730-15750 O 08/30/99 2-1/2" 6 15730-15775 O 02/23/02 2-1/2" 6 15750-15755 O 01/11/99 2-1/2" 6 15755-15775 0 12/08/98 2-1/2" 6 15785-15790 O 01/11/99 2-1/2" 6 15785-15790 O 02/23/02 ~~ ~- 4-1/2" LNR, 12.6#, 13Cr. 0.0152 bpf, iD = 3.952' 15971' rAS I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4198 4049 38 FMHO RK 2 5464 4947 44 FMHO RK 3 8447 6096 75 FMHO RK 4 10525 6891 64 FMHO RK 5 12470 7696 69 FMHO RK 6 14207 8375 65 FMHO RK 7 14482 8482 68 FMHO TG 14546' 7" X 3-1/2" BAKER S-3 14571' 3-1/2" HES X N~, ID= 2.81" 14582' 3-1/2" HES XN NIP, ID = 2.80" (milled to 2.8") 14593' 3-1/z" WLEG 145-~ ELMD TT LOGGED 08/30/99 I 16600' I Bottom of cement 1 2-3/8" 13Cr80 cemented/slotted liner 15726' Mechanical Whipstock DATE REV BY COMMENTS DATE REV BY COMMENTS 12/08/98 ORIGINAL COMPLETION 11/20/00 SIS-Isl CONVERTEDTOCANVAS 02/22/01 SIS-MD FINAL 09/15/01 RNITP CORRECTIONS 02/23/02 JAF/KK AD/REPERFS SAFETY NOTES: HORIZONTAL WELL I 3-1/2", HES SERIES 10, TRSSSV, ID = 2.81" I I ~ 18400' I POINT MCINTY RE UNfr WELL: P1-08 PERMfT No: 98-123 API No: 50-029-22896-00 SEC 11 T12N R14E 3858.04 FEL 2188.45 FNL BP Exploration (Alaska) by ~ BP Alaska Baker Hu hes INTE Flannin Re ort g Q g P ~~r s $ I:NTEQ Coropaay: BP AmoCO Date: 12/5/2006 Time: 15:41:52 Page: 1 Field: Point McIntyre Co-ordinate(NE) Refcrencr. Well: P2-O8, True North Site: Pt Mac 2 Vertical (TVD) Reference: P2-08 49.0 Well: P2-08 Section (VS) Referenee: Well (O.OON,O.OOE,105.OOAzi) Wellpath: Plan 2, P2-08A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Point McIntyre North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordiuate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Pt Mec 2 TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5995140 .76 ft Latitude: 70 23 32.530 N From: Map Easting: 674873 .98 ft Longitude: 148 34 37.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: P2-08 Slot Name: 08 P2-08 Well Position: +N/-S 3303.59 ft Northing: 5998595.59 ft Latitude: 70 24 4.992 N +E/-W 6513.96 ft Easting : 681308.47 ft Longitude: 148 31 27.090 W Position Uncertainty: 0.00 ft Wellpath: Plan 2, P2-OSA Drilled From: P2-08 Tie-on Depth: 15662.62 ft Current Daturo: P2-08 Height 49.02 ft Above System Datum: Mean Sea Level Magnetic Data: 12/4!2006 Destination: 24.23 deg Field Strength: 57664 nT Mag Dip Angle: 81.01 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.22 0.00 0.00 105.00 Plan: Plan #2 Date Composed: 12/4/2006 change kop to 15726 from 1 5720'md Version: 7 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <- Latitude --> <- Longitude -> Name Description "R'D +N/S tE/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft R ft ft ft P2-OSA Polygon 49.02 2763.68 9962.18 6001599.98 691200.03 70 24 32.107 N 148 26 35.114 W -Polygon 1 49.02 2763.68 9962.18 6001599.98 691200.03 70 24 32.107 N 148 26 35.114 W -Poygon 2 49.02 3163.58 9971.89 6001999.98 691200.03 70 24 36.040 N 148 26 34.814 W -Polygon 3 49.02 3424.69 11578.79 6002299.98 692800.03 70 24 38.585 N 148 25 47.703 W -Polygon 4 49.02 3381.01 13378.38 6002299.98 694600.03 70 24 38.126 N 148 24 54.958 W -Polygon 5 49.02 1379.05 13429.82 6000299.98 694700.03 70 24 18.436 N 148 24 53.556 W -Polygon 6 49.02 2429.77 11354.57 6001299.98 692600.03 70 24 28.803 N 148 25 54.320 W P2-08A Target2 9079.02 2882.09 11265.52 6001749.98 692500.04 70 24 33.253 N 148 25 56.910 W P2-08A Target3 9099.02 2395.79 12754.26 6001299.98 694000.04 70 24 28.447 N 148 25 13.301 W P2-OSA Target! 9109.02 2997.84 10618.10 6001849.98 691850.04 70 24 34.401 N 148 26 15.880 W Annotation NID TVD ft ft 15662.62 9026.33 TIP 15726.00 9062.30 KOP 15746.00 9073.50 End of 9 Deg/ 100' DLS 15840.36 9100.23 End of 38 Deg/100' DLS 16040.36 9100.23 5 16140.60 9100.23 6 16265.36 9095.82 7 16540.36 9077.61 8 16790.36 9070.04 9 by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P ~~~ spa INTEQ Company: BP Amoco Date: 12/5/2006 Time: 15:41:52 Pase: 2 Field: Point McIntyre Co-ordieate(NE) Reference: Well: P2-08, True North Site: Pt Mac 2 Vertical (TVD) Reference: P2-08 49.0 Well: P2-08 Section (VS) Reference: Well (O.OON,O .OOE,105.OOAzi) Weilpath: Plan 2, P2-08A Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 17115.36 9073.07 10 17365.36 9077.45 11 17615.36 9081.24 12 17865.36 9084.52 13 18115.36 9087.37 14 18400.00 0.00 TD Plan Section Information MD Incl Azim TVD +N/-S +E/-W DI.S Build Turn TEO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 15662.62 55.69 70.00 9026.33 2993.84 10168.38 0.00 0.00 0.00 0.00 15726.00 55.14 69.98 9062.30 3011.69 10217.41 0.87 -0.87 -0.03 181.71 15746.00 56.77 70.89 9073.50 3017.24 10233.02 9.00 8.17 4.55 25.00 15840.36 90.00 85.22 9100.23 3034.66 10320.19 38.00 35.21 15.19 25.00 16040.36 90.00 109.22 9100.23 3009.71 10517.16 12.00 0.00 12.00 90.00 16140.36 90.00 97.22 9100.23 2986.87 10614.33 12.00 0.00 -12.00 270.00 16265.36 94.02 82.76 9095.82 2986.88 10738.89 12.00 3.21 -11.57 285.70 16540.36 93.37 115.82 9077.61 2943.16 11005.94 12.00 -0.24 12.02 90.00 16790.36 90.02 85.99 9070.04 2896.48 11248.53 12.00 -1.34 -11.93 264.20 17115.36 88.95 124.98 9073.07 2811.39 11555.71 12.00 -0.33 12.00 91.70 17365.36 89.09 94.97 9077.45 2726.96 11787.96 12.00 0.06 -12.00 270.00 17615.36 89.21 124.98 9081.24 2642.54 12020.21 12.00 0.05 12.00 90.00 17865.36 89.32 94.98 9084.52 2558.11 12252.48 12.00 0.04 -12.00 270.00 18115.36 89.41 124.98 9087.37 2473.68 12484.74 12.00 0.04 12.00 90.00 18400.00 89.51 90.82 9090.13 2387.50 12751.60 12.00 0.04 -12.00 270.00 Survey MD [nci Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft, ft ~ deg/1OOft ft _ deg 15662.62 55.69 70.00 8977.31 2993.84 10168.38 6001835.07 A 691400.57 0.00 9047.03 0.00 MWD 15700.00 55.37 69.99 8998.46 3004.38 10197.33 6001846.31 691429.26 0.87 9072.28 181.71 MWD 15726.00 55.14 69.98 9013.28 3011.69 10217.41 6001854.11 691449.15 0.87 9089.77 181.72 MWD 15746.00 56.77 70.89 9024.48 3017.24 10233.02 6001860.03 691464.63 9.00 9103.42 25.00 MWD 15750.00 58.15 71.65 9026.63 3018.32 10236.21 6001861.19 691467.79 38.00 9106.22 25.00 MWD 15756.60 60.44 72.85 9030.00 3020.05 10241.62 6001863.05 691473.16 38.00 9111.00 24.59 P2-08 15760.00 61.62 73.44 9031.64 3020.92 10244.46 6001863.98 691475.98 38.00 9113.52 23.98 MWD 15770.00 65.11 75.12 9036.13 3023.33 10253.07 6001866.61 691484.52 38.00 9121.21 23.69 MWD 15780.00 68.62 76.71 9040.06 3025.57 10261.99 6001869.06 691493.38 38.00 9129.24 22.94 MWD 15790.00 72.14 78.23 9043.41 3027.61 10271.18 6001871.32 691502.52 38.00 9137.59 22.31 MWD 15800.00 75.68 79.68 9046.18 3029.45 10280.61 6001873.39 691511.90 38.00 9146.23 21.80 MWD 15810.00 79.22 81.09 9048.36 3031.08 10290.23 6001875.25 691521.48 38.00 9155.10 21.40 MWD 15820.00 82.77 82.47 9049.92 3032.49 10300.01 6001876.90 691531.22 38.00 9164.17 21.09 MWD 15830.00 86.32 83.83 9050.87 3033.68 10309.89 6001878.33 691541.07 38.00 9173.41 20.88 MWD 15840.36 90.00 85.22 9051.21 3034.66 10320.19 6001879.56 691551.34 38.00 9183.11 20.75 MWD 15850.00 90.00 86.38 9051.21 3035.37 10329.81 6001880.50 691560.94 12.00 9192.22 90.00 MWD 15875.00 90.00 89.38 9051.21 3036.30 10354.79 6001882.03 691585.89 12.00 9216.10 90.00 MWD 15900.00 90.00 92.38 9051.21 3035.91 10379.78 6001882.26 691610.88 12.00 9240.35 90.00 MWD 15925.00 90.00 95.38 9051.21 3034.22 10404.72 6001881.17 691635.85 12.00 9264.87 90.00 MWD 15950.00 90.00 98.38 9051.21 3031.23 10429.54 6001878.78 691660.73 12.00 9289.62 90.00 MWD 15975.00 90.00 101.38 9051.21 3026.94 10454.16 6001875.09 691685.46 12.00 9314.52 90.00 MWD 16000.00 90.00 104.38 9051.21 3021.37 10478.53 6001870.11 691709.95 12.00 9339.50 90.00 MWD 16025.00 90.00 107.38 9051.21 3014.53 10502.58 6001863.86 691734.15 12.00 9364.49 90.00 MWD 16040.36 90.00 109.22 9051.21 3009.71 10517.16 6001859.39 691748.84 12.00 9379.83 90.00 MWD 16050.00 90.00 108.07 9051.21 3006.62 10526.29 6001856.53 691758.05 12.00 9389.45 270.00 MWD 16075.00 90.00 105.07 9051.21 2999.50 10550.25 6001849.99 691782.17 12.00 9414.43 270.00 MWD 16100.00 90.00 102.07 9051.21 2993.63 10574.55 6001844.72 691806.61 12.00 9439.42 270.00 MWD 16125.00 90.00 99.07 9051.21 2989.05 10599.13 6001840.73 691831.28 12.00 9464.35 270.00 MWD by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P ~i~/ s INTEQ Company: BP AmoCO Date: 12/5/2006 Time: 15:41:52 Page: 3 Field: Point McIntyre Co-ord inate(NE) Referenc e: Well: P2-08, Tru e North Site: Pt Mac 2 Vertical (TVD) Refereneea P2-08 49.0 Well: P2-08 Section (VS) Reference: Well (O.OON,O.OOE,105.OOAzi) Wellpatb: Plan 2, P2-08A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SS TVD N/S E/W MapN NfapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 16140.36 90.00 97.22 9051.21 2986.87 10614.33 6001838.93 691846.53 12.00 9479.59 270.00 MWD 16150.00 90.31 96.11 9051.18 2985.76 10623.90 6001838.04 691856.13 12.00 9489.13 285.70 MWD 16175.00 91.12 93.22 9050.87 2983.72 10648.82 6001836.61 691881.09 12.00 9513.72 285.70 MWD 16200.00 91.93 90.33 9050.20 2982.95 10673.79 6001836.45 691906.07 12.00 9538.05 285.66 MWD 16225.00 92.74 87.44 9049.18 2983.44 10698.76 6001837.54 691931.02 12.00 9562.04 285.58 MWD 16250.00 93.53 84.54 9047.82 2985.18 10723.66 6001839.89 691955.87 12.00 9585.64 285.47 MVVD 16265.36 94.02 82.76 9046.80 2986.88 10738.89 6001841.95 691971.06 12.00 9599.91 285.31 MWD 16275.00 94.02 83.92 9046.13 2987.99 10748.45 6001843.30 691980.58 12.00 9608.85 90.00 MWD 16300.00 94.01 86.92 9044.38 2989.98 10773.30 6001845.89 692005.38 12.00 9632.35 90.08 MWD 16325.00 93.98 89.93 9042.64 2990.67 10798.23 6001847.18 692030.28 12.00 9656.25 90.29 MWD 16350.00 93.95 92.94 9040.91 2990.04 10823.16 6001847.16 692055.21 12.00 9680.49 90.50 MWD 16375.00 93.91 95.95 9039.19 2988.11 10848.02 6001845.83 692080.11 12.00 9705.00 90.71 MWD 16400.00 93.86 98.95 9037.50 2984.88 10872.75 6001843.20 692104.91 12.00 9729.73 90.92 MWD 16425.00 93.79 101.96 9035.83 2980.35 10897.28 6001839.27 692129.54 12.00 9754.59 91.12 MWD 16450.00 93.72 104.96 9034.19 2974.55 10921.54 6001834.06 692153.93 12.00 9779.53 91.32 MWD 16475.00 93.63 107.97 9032.59 2967.47 10945.46 6001827.57 692178.02 12.00 9804.46 91.52 MWD 16500.00 93.54 110.97 9031.02 2959.16 10968.98 6001819.83 692201.73 12.00 9829.34 91.71 MWD 16525.00 93.44 113.98 9029.50 2949.62 10992.04 6001810.85 692225.01 12.00 9854.07 91.90 MWD 16540.36 93.37 115.82 9028.59 2943.16 11005.94 6001804.73 692239.07 12.00 9869.18 92.08 MWD 16550.00 93.25 114.67 9028.03 2939.06 11014.65 6001800.84 692247.87 12.00 9878.65 264.20 MWD 16575.00 92.94 111.68 9026.69 2929.24 11037.59 6001791.58 692271.05 12.00 9903.36 264.13 MWD 16600.00 92.62 108.69 9025.47 2920.62 11061.03 6001783.53 692294.68 12.00 9928.22 263.97 MWD 16625.00 92.29 105.71 9024.40 2913.24 11084.89 6001776.73 692318.71 12.00 9953.18 263.83 MWD 16650.00 91.96 102.73 9023.47 2907.10 11109.10 6001771.18 692343.07 12.00 9978.15 263.70 MWD 16675.00 91.62 99.74 9022.69 2902.23 11133.61 6001766.91 692367.68 12.00 10003.09 263.59 MWD 16700.00 91.28 96.76 9022.06 2898.65 11158.34 6001763.93 692392.49 12.00 10027.90 263.50 MWD 16725.00 90.94 93.78 9021.57 2896.35 11183.22 6001762.24 692417.42 12.00 10052.53 263.42 MWD 16750.00 90.59 90.80 9021.24 2895.35 11208.20 6001761.84 692442.41 12.00 10076.92 263.36 MWD 16775.00 90.24 87.82 9021.06 2895.65 11233.19 6001762.75 692467.39 12.00 10100.98 263.32 MWD 16790.36 90.02 85.99 9021.02 2896.48 11248.53 6001763.95 692482.70 12.00 10115.58 263.30 MWD 16800.00 89.99 87.15 9021.02 2897.06 11258.15 6001764.76 692492.31 12.00 10124.73 91.70 MWD 16825.00 89.90 90.15 9021.04 2897.65 11283.14 6001765.96 692517.27 12.00 10148.71 91.70 MWD 16850.00 89.81 93.15 9021.11 2896.93 11308.13 6001765.85 692542.27 12.00 10173.03 91.70 MWD 16875.00 89.72 96.14 9021.21 2894.90 11333.04 6001764.43 692567.23 12.00 10197.62 91.69 MWD 16900.00 89.64 99.14 9021.35 2891.58 11357.82 6001761.70 692592.07 12.00 10222.42 91.68 MWD 16925.00 89.55 102.14 9021.52 2886.96 11382.39 6001757.69 692616.74 12.00 10247.34 91.66 MWD 16950.00 89.47 105.14 9021.74 2881.07 11406.68 6001752.38 692641.17 12.00 10272.33 91.64 MWD 16975.00 89.38 108.14 9021.99 2873.91 11430.63 6001745.81 692665.28 12.00 10297.31 91.61 MWD 17000.00 89.30 111.14 9022.28 2865.51 11454.17 6001737.98 692689.02 12.00 10322.23 91.58 MWD 17025.00 89.22 114.14 9022.60 2855.89 11477.24 6001728.92 692712.31 12.00 10347.00 91.55 MWD 17050.00 89.14 117.14 9022.96 2845.07 11499.77 6001718.66 692735.10 12.00 10371.57 91.51 MWD 17075.00 89.07 120.14 9023.35 2833.10 11521.71 6001707.22 692757.32 12.00 10395.86 91.47 MWD 17100.00 88.99 123.14 9023.77 2819.99 11542.99 6001694.63 692778.91 12.00 10419.80 91.42 MWD 17115.36 88.95 124.98 9024.05 2811.39 11555.71 6001686.34 692791.84 12.00 10434.32 91.37 MWD 17125.00 88.95 123.82 9024.23 2805.94 11563.66 6001681.09 692799.92 12.00 10443.41 270.00 MWD 17150.00 88.95 120.82 9024.68 2792.58 11584.78 6001668.25 692821.36 12.00 10467.27 270.02 MWD 17175.00 88.96 117.82 9025.14 2780.34 11606.57 6001656.54 692843.44 12.00 10491.49 270.08 MWD 17200.00 88.97 114.82 9025.59 2769.26 11628.98 6001646.01 692866.10 12.00 10515.99 270.13 MWD 17225.00 88.98 111.82 9026.04 2759.36 11651.93 6001636.67 692889.28 12.00 10540.72 270.19 MWD 17250.00 88.99 108.82 9026.49 2750.68 11675.37 6001628.56 692912.92 12.00 10565.61 270.24 MWD 17275.00 89.01 105.82 9026.92 2743.24 11699.23 6001621.71 692936.96 12.00 10590.58 270.29 MWD 17300.00 89.03 102.82 9027.35 2737.06 11723.44 6001616.11 692961.31 12.00 10615.57 270.34 MWD by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P ~.r s~~s INTEQ Company: BP Amoco Date: 12/5/2006 Time: 15:41:52 Page: 4 Field: Poi nt McInty re Co-ordinate(NE) Reference: Weil: P2-08, True North Site: Pt Mac 2 Vertica l (TVD) Reference: P2-08 49.0 Well: P2-08 Section (VS) Reference: Well ( O.OON,O.OOE,105.OOAzi) Wellpath: Pla n 2, P2-OSA Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim SS TVD N/S E/W MapN MapE DIS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 17325.00 89.05 99.82 9027.77 2732.16 11747.95 6001611.81 692985.93 12.00 10640.51 270.40 MWD 17350.00 89.07 96.82 9028.18 2728.54 11772.68 6001608.79 693010.74 12.00 10665.34 270.45 MWD 17365.36 89.09 94.97 9028.43 2726.96 11787.96 6001607.59 693026.05 12.00 10680.50 270.50 MWD 17375.00 89.09 96.13 9028.58 2726.03 11797.55 6001606.89 693035.66 12.00 10690.01 90.00 MWD 17400.00 89.09 99.13 9028.98 2722.71 11822.32 6001604.17 693060.51 12.00 10714.80 89.98 MWD 17425.00 89.10 102.13 9029.37 2718.10 11846.89 6001600.15 693085.18 12.00 10739.72 89.93 MWD 17450.00 89.10 105.13 9029.77 2712.21 11871.18 6001594.86 693109.60 12.00 10764.71 89.89 MWD 17475.00 89.11 108.13 9030.15 2705.06 11895.13 6001588.28 693133.71 12.00 10789.69 89.84 MWD 17500.00 89.13 111.13 9030.54 2696.66 11918.67 6001580.46 693157.45 12.00 10814.60 89.79 MWD 17525.00 89.14 114.13 9030.92 2687.04 11941.74 6001571.41 693180.74 12.00 10839.38 89.75 MWD 17550.00 89.16 117.13 9031.29 2676.23 11964.27 6001561.14 693203.53 12.00 10863.94 89.70 MWD 17575.00 89.18 120.13 9031.65 2664.25 11986.21 6001549.70 693225.75 12.00 10888.23 89.66 MWD 17600.00 89.20 123.13 9032.01 2651.14 12007.49 6001537.11 693247.34 12.00 10912.18 89.61 MWD 17615.36 89.21 124.98 9032.22 2642.54 12020.21 6001528.82 693260.27 12.00 10926.69 89.57 MWD 17625.00 89.21 123.82 9032.35 2637.09 12028.17 6001523.57 693268.35 12.00 10935.79 270.00 MWD 17650.00 89.21 120.82 9032.70 2623.73 12049.29 6001510.73 693289.79 12.00 10959.65 270.02 MWD 17675.00 89.22 117.82 9033.04 2611.49 12071.08 6001499.02 693311.88 12.00 10983.87 270.06 MWD 17700.00 89.22 114.82 9033.38 2600.41 12093.49 6001488.49 693334.54 12.00 11008.38 270.10 MWD 17725.00 89.23 111.82 9033.71 2590.51 12116.44 6001479.15 693357.73 12.00 11033.11 270.14 MWD 17750.00 89.24 108.82 9034.05 2581.83 12139.88 6001471.04 693381.37 12.00 11057.99 270.18 MWD 17775.00 89.26 105.82 9034.37 2574.39 12163.74 6001464.19 693405.40 12.00 11082.97 270.22 MWD 17800.00 89.27 102.82 9034.70 2568.21 12187.96 6001458.59 693429.76 12.00 11107.96 270.26 MWD 17825.00 89.29 99.82 9035.01 2563.31 12212.47 6001454.28 693454.38 12.00 11132.91 270.30 MWD 17850.00 89.31 96.82 9035.32 2559.69 12237.20 6001451.27 693479.19 12.00 11157.73 270.34 MWD 17865.36 89.32 94.98 9035.50 2558.11 12252.48 6001450.06 693494.50 12.00 11172.90 270.37 MWD 17875.00 89.32 96.13 9035.62 2557.18 12262.07 6001449.36 693504.11 12.00 11182.40 90.00 MWD 17900.00 89.32 99.13 9035.91 2553.86 12286.84 6001446.65 693528.96 12.00 11207.19 89.99 MWD 17925.00 89.32 102.13 9036.21 2549.25 12311.41 6001442.63 693553.63 12.00 11232.12 89.95 MWD 17950.00 89.33 105.13 9036.51 2543.36 12335.70 6001437.33 693578.05 12.00 11257.10 89.91 MWD 17975.00 89.34 108.13 9036.80 2536.20 12359.65 6001430.76 693602.17 12.00 11282.09 89.88 MWD 18000.00 89.34 111.13 9037.09 2527.80 12383.19 6001422.94 693625.91 12.00 11307.00 89.84 MWD 18025.00 89.36 114.13 9037.37 2518.18 12406.26 6001413.88 693649.20 12.00 11331.78 89.81 MWD 18050.00 89.37 117.13 9037.65 2507.37 12428.80 6001403.62 693671.99 12.00 11356.34 89.78 MWD 18075.00 89.38 120.13 9037.92 2495.39 12450.74 6001392.18 693694.21 12.00 11380.64 89.74 MWD 18100.00 89.40 123.13 9038.19 2482.28 12472.02 6001379.59 693715.81 12.00 11404.59 89.71 MWD 18115.36 89.41 124.98 9038.35 2473.68 12484.74 6001371.30 693728.73 12.00 11419.10 89.68 MWD 18125.00 89.41 123.82 9038.45 2468.24 1249270 6001366.05 693736.82 12.00 11428.19 270.00 MWD 18150.00 89.41 120.82 9038.70 2454.87 12513.82 6001353.20 693758.26 12.00 11452.06 270.01 MWD 18175.00 89.41 117.82 9038.96 2442.63 12535.62 6001341.49 693780.34 12.00 11476.28 270.04 MWD 18200.00 89.42 114.82 9039.21 2431.55 12558.02 6001330.96 693803.01 12.00 11500.79 270.07 MWD 18225.00 89.42 111.82 9039.47 2421.65 12580.97 6001321.62 693826.19 12.00 11525.52 270.10 MWD 18250.00 89.43 108.82 9039.72 2412.97 12604.42 6001313.52 693849.83 12.00 11550.41 270.13 MWD 18275.00 89.44 105.82 9039.96 2405.53 12628.28 6001306.66 693873.87 12.00 11575.38 270.16 MWD 18300.00 89.45 102.82 9040.20 2399.35 12652.50 6001301.06 693898.23 12.00 11600.38 270.19 MWD 18325.00 89.47 99.82 9040.44 2394.44 12677.01 6001296.75 693922.85 12.00 11625.32 270.22 MWD 18350.00 89.48 96.82 9040.67 2390.83 12701.74 6001293.74 693947.66 12.00 11650.15 270.25 MWD 18375.00 89.49 93.82 9040.89 2388.51 12726.63 6001292.03 693972.60 12.00 11674.79 270.28 MWD 18400.00 / 89.51 90.82 9041.11 2387.50 12751.60 6001291.62 693997.59 12.00 11699.17 270.31 MWD r BP Alaska ~'%~~ ` -.N.. ~,~w e„ `~ ~M ' WELLPNTH DETA,~~ Ht7GHES' Up ~~ o~ :. ,~ . " P,~~ 3 P3 D6a ~ '. Tim MD: 15662.63 Rlg: 1 Rel. Datum: qq P2~OB ryry C9.D3tt rq V_ ~u ~IU~S EI~W Eram TVD 1Ob.0D' D.DD D.DD 3).22 • '.. - - _ REFERENCE p1FORMr1TpN 1 .- ( 4-H rh L -~--t'om'-.~ 1 `Y -+ r -I-r- l - -rte ~•t H- ~-~^'i" i "Tr' _ Co-o~Einh WEI Rek '. WeM rWe:P -00. irw NOnF - .~ ...~ ~y..~ ~ ~ ~ r ~'_4 ~- ~'- ~+`r" - v~~^~vol R.r : s~ w sw E..a ~' ~_'_L ~_ _ T t._ ~-+- 1+ r`_ t` , .. ~VS)R N s,w oemaoN.o aoEr i -i ~ I i-.. ~.... ^~ 4 +-. .1 ~~_: F.. ~.'~.. r -~ -}~` f-_ ~?._;_. a..~_y-~ ~-- wes~.aaoep~ re~e zye as. i y -Y '- - I '- ' Me wn Cwv iua .-T~ ~ ~ ` ~.y y'~ . -. _.1 '. -.-T'i 1 ,.. I 1 _ ~} ~ t L ;.y. i'.. y:_ J --+-F- L .~ 1.. --~ ~ _i 'r'rr I rt ._I r :TT -~ _ ,-t -Y J.. -1---~-!-• ~, x,. .,~ _ TvD ~ . oN .. Dl.p .t.e. vs.~ r.rq« ~:.. a- ^~-~+ ~ ..U--~_ +"~i.~ T -- f Z, Tl-.T ~ .+ti, _ti -- T ~' '- s.. ND - wz ~W -. + - ~T t 1 C~` 1- t ~ t f-,-'~y -t ~?_i T ~ t+r=~-.~. :`. r rfi ~. ':•fi' ::wo:' w °oo° ,o:.ii °Ow`.; :~ wo: ;,` ;o: °, : u w :o ~ :~°,i ii eoo.-.... $.--~--.~•~~' _ _ r- t- t~ 'L' I r-`-"n-'-'"'- - - ~' .+,-r ..-- * ~'T i -r- -} +.,.o....o ao , : 300 ~_ ~.,. .,.;.__ .. f -i+ la-.-I -~ ~ I~' -~ - f ,o.),,.a...... ,:::: .oz ,:.. ,, :,>.,..z` tt.z ::a ~'..o :.~.,, ,zoz.:, ,:oo z>ooo ,,,,:w--r ___~-- ,-~ - r - _ = f1- i ' ~^ -.--r.-( En, a(.le~gYlud DLS nau,~w~, wnco ae)u ce,s,o vua ~ I ~ ~~ • r`I-~ "Y }+r~ ---L .. S 6 .. ~• a 9 $ zoos . ~ ~ " -,-r r -+ T+ t- s ;z z° _ ~ rT _ a .T.Sy _ h t- 3""~. z ~_._7_ r, y~r r- _ . _ ; _ ~ . _~ w _ rr-.-r--~-~ _ - 3zao,. r - ~' T -1-~-rT 00~ _._.. ---~T*'`-- r 1 y +-'-r--~- 7 ~~ ~' ~' " ( at ,-fir -+ - -r ~ ~- ;r '- .- . r ~_ - ~ ~ t ~~_ -+ ~ -, -T---, -f--r- - c.mo; _ ~o ~ ~ ,oo~ 02~ mo ,~ ,~ ,+.oo ~~~ T ~ ~ ___;2 ,2~ ,~ ~~ ,,~ .oDO ,.zoo .~ ,.moo ,«oo ,sue t i ' = r- '. ~, ~.=. y " _ T} West()/Eastl+) [200tt/in] ~ - -~ ~_ 1 i ~ 7---4L ~ - ~ ~~' =~ r -T - }~ ) ~,_ Fes-- .. ~ `"~ _ - . _ ._. - - - - - - - '_ ---~-^.---t-"-+--L~4r'~- =~~' ~:~ ~ T ~ r,-.. ~_ TTrt ..:-:; r_ ~ -.T?-F--"-'1 -`~~ + . - _ _~-?~ - a ~•+i-== - ~ ri-,:-_ *--rl r = 'tom - -~ ~ -_._,_ +- _*~.~ ` --~ y r ._ - ,. i ~- ~ -~- -~- _ __ _ _ oooo- _ ___ _ _ _ --- __ __ _; _ _ --r-.-...~_ ... _._ .-r -- ---~- _ __ T - _ _ ._ _ - -- - ewD 8888 emo eee0 ae00 eo0o c,oo ezo0 e~oo emo °'°°° eaoo em0 °B0° 8840 ~~ +~ ium0 vertical Section at 105.00°(l (xlfVin] ~aeoo ~+ooo ,i,o0 ++m0 lime iuae iiwe ++w0 ,ime +,eoo +,eoe imao z PM • ~- i All Measurements are from top of Riser 12/5/2006 i ~_ ~ P2-O8A bag BAG of bag of blind/shear Blind/Shears TOTs ~ of pipes/slip 2~~ combi ram/slips ~ ~ Mud Cross I I Mud Cross middle of flow cross fiddle of pipe/slip 2 3/8~~ pipe/slip TOTs ~`~~ fiddle of pipe/slips 2~~ pipe/slips Flow Tee • • Terri L. Hubale ss-si,z52 315 BP Exploration QK Inc. _ °Mastercard Check"' PO Box 196612 MB 7-5 - Artcharage, AK 995T9 771~ /t _ oArE (~"~~"VIP PAY TO THE ~ l ORDER OF -= '~ _ _ _ _ DOLLARS First National 6ank-Alaska - Anchora e, AdC 99:501 MEMO ~.i2=S-20.0060~99L,462z?i556~~• 0315 • • ~~"EI.I. d ~~IE /+ ~k~®evelopment Ser`•iee Exploratory Stratigraphic Vest lion-Conventional W"ell C'irsle Appropriate Letter /Paragraphs to be Ineluded in Transmittal Letter CHECK - ADD-ONS WHAT (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MULTI LATERAL ~ The permit is for a new wellbore segment of existing well (If last two digits in ' Permit No. . API No. ~0- API number are - between 60-69) Production should continue to be reported as a function of the original AP[ number stated above. PILOT HOLE In accordance with 20 .=~aC 25.00~(t~, all records, data and logs I ;acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (~0- - -_~ from records, data and logs ~' j ;acquired for well SPACING ~ The permit is approved subject to full compliance with 20 AAC ;EXCEPTION ! 2~.0». Approval to perforate and produce inject is contingent !upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. i DRY DCTCH 'All dry ditch sample sets submitted to the Commission must be in 'SAMPLE ! no greater than 30' sample intervals from below the permafrost or i from where samples are first caught and 10' sample intervals: ;through target zones. 'Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed 'Well ;for name of well) until after jCompanv Name) has designed and ;, implemented a water well testing program to provide baseline data j on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing 'program. Rev: l 2~i06 C:'jody'xransmittaf checklist WELL PERMIT CHECKLIST Field & Pool _ _ _ PTD#:2061690 Company BP EXPLORATION (ALASKA)_INC - _ _ __ __ _ __ _ . _ _ Initial Class/Type _ Well Name: PR_UDHOE BAY UN PTM P2-O6A ___Program DEV_ __ Well bore seg iL] _DEV ! PEND__ GeoArea 890 _ __ Unit 11650_ __ On/Off Shore Off __ Annular Disposal I,, Administration 1 Permitfee attached _ _ Yes ~ 2 Lease number appropriate Yes ~ 3 Unique well name and number Yes 4 Well located in a_defined pool _ _ _ _ ~ _ _ _ _ _ Yes 5 Well located proper distance from_ drilling unitboundary_ Yes ! 6 Well located proper distance_f[om other wells_ Yes ', 7 Sufficient acreage available in drilling unit Yes ~ 8 If deviated, is_wellbore plat included _ _ Yes _ 9 Operator only affected party- - - - - Yes 10 Operator has_approprate_ bond in force Yes j 11 Permit_can be issued without conservation order_ Yes ' 12 Permit can be issued without administrative_approval Yes Appr Date 13 Can permit be approved before 15-day wait_ _ _ _ _ _ _ _ _ _ - - _ _ _ - Yes ACS 121812006 X 14 Well located within area and strata authorized by_Injection Orde[# (put 10# in_comments) (For NA_ 15 All wells. within 1/4_mile area of review identified (For service well only) NA j, 16 Pre-produced injector: duration ofpre-production less_than 3 months_(for service well only) . NA X 17 Nonconven, gas conforms to AS31.05,030(j.1.A),Q,2_.A-l)) - _ - No_ 18 ---- -- Conductor string_p_rovided _ _ . - NA Engineering 19 Surface casing_protects_alLknown USDWs NA 20 CMT_vol_adeguate to circulate on conductor_& surf_csg - - , 21 CMT_vol adequate.to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ . _ NA- _ - _ - - - _ - _ _ X 22 CMT will coyer_all know_n_pro_ductiye horizons_ No Slotted.. 23 Casing designs adequate for C, T, B &_permafr_ost_ Yes 24 Adequate tankage_or re_serye pit _ - - - - ------------- Yes _ CTDU. _ _ _ _ 25 If a_re-drill, has_a_ 10-403 for abandonment been approved Yes 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ 27 If diverter required, does it meet_ regu_la_tions- _ . _ _ _ _ _ _ _ _ _ _ NA_ _ Sidetrack. - 28 Drilling fluid_program schematic & equip list adequate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Max MW 9,2 ppg. _ _ _ _ _ _ Appr Date P9 gOPEs,-do they meet regulation Yes WGA 12/1212006 30 BO_PE_press rating appropriate; lest t_o_(put prig in comments)_ Yes - - Test to 350Qpsi. MSP 3250 psi._ 31 Choke_manifold complies w/APL RP-53 (M_ay 84) _ _ Yes 32 Work will occur without operation shutdown_ _ _ _ Yes - 33 Is presence_of H2S gas_probable _ _ _ Yes 160_ppm on pad. _ _ - 34 .Mechanical condition of wells within AOR yer~ed (For_seruce well only) NA_ ,35 -- - _ _ __ Permitcan be issued wlo hydrogen_sulfide measures o_ - -- - _- -- - -_ Geology 36 Data presented on_ potential overpressure zones _ NA_ 37 Seism[c analysis_ of shallow gas zones_ _ _ _ _ NA_ Appr Date 38 Seabed condjtion suruey_(if off_-shore) - - - - - - - - - - - - NA - ACS 12!812006 39 l-- i Contact namelpho_ne for weekly_progress reporis_[exploratoryon1y] _ -- -- _.. - --- -- - NA_ _ _ . -- _ -_ Geologic Engineering Date: Commissioner: ommissio er: ~~ ! Z 112', S~t, Date /z-~ •~ Date • • • Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infom~ation 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. **** REEL HEADER **** MWD 08/06/10 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/03/16 1850977 O1 3.0" CTK *** LIS COMMENT RECORD *** ~!~~~~!!!! !!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version I nformation VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 15650.0000: Starting Depth STOP.FT 17506.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: P2-08A FLD FIELD: Point McIntyre LOC LOCATION: 70 deg 24' 4.992"N 148 deg 31' 27.090"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 16 Mar 2008 API API NUMBER: 500292289601 Parameter Information Block #MNEM.UNIT Value Description SECT. 11 Section TOWN.N T12N Township RANG. R14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF DF Log Measured from FAPD.F 49.02 Feet Above Perm. Datum DMF DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 49.02 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. ~0~-~~9 ~~~~ (2) All depths are Bit Depths unless (3) All True Vertical Depths (TVDSS) (4) All Formation Evaluation data is (5) Baker Hughes INTEQ utilized Coil' Advantage otherwise noted. are Subsea corrected. realtime data. Prak downhole tools and the surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final. As per David Boyer there is no depth shifting needed as the MWD data from P2-08A serves as the PDCL for this well and P2-08APB1. All resistivity data has been clipped at 2000 ohm.m. (8) Tied to P2-08 at 15726 feet MD (9013.3 feet TVDSS). (9) The sidetrack was drilled from P2-08 through a milled window in 4 1/2 inch liner. Top of window 15726.5 ft.MD (9013.6 ft.TVDSS) Bottom of window 15733.0 ft.MD (9017.2 ft.TVDSS) (10) No new formation was drilled on runs 1, 2, 4 and 7 due to rig problems and MWD tool failures. (11) The well was sidetracked from P2-08APB1 at 17060 feet MD (9034.6 feet TVDSS). (12) No new formation was drilled on runs 11 though 14 while attempting an open hole sidetrack. INTEQ run 10 occured on P2-08APB1. (13) The interval from 17466 feet to 17506 feet MD (9051.9 feet to 9049.7 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 76 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------- WDFN P2-08A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN P2-08A APIN FN Point McIntyre COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 Data presented here is final. As per David Boyer there is no depth shifting need as the MWD data from P2-08A serves as the PDCL for this well and P2- 08APB1. All resistivity data has been clipped at 2000 ohm.m. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 104 Tape File Start Depth = 15650.000000 Tape File End Depth = 17506.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 117 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN P2-O8A.xtf LCC 150 CN BP Exploration (Alaska) WN P2-08A APIN FN Point McIntyre COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME • Tape de pth ID: F 6 Curves: Name Tool C ode Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 207 Tape File Start Depth = 15651.000000 Tape File End Depth = 17506.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 220 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/03/16 1850977 O1 **** REEL TRAILER **** MWD 08/06/10 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 15650.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15650.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15700.0000 169.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15800.0000 80.9000 71.5000 8.8100 9.4890 10.4450 11.2640 15900.0000 66.5000 96.0000 6.5910 7.3880 7.5190 7.9230 16000.0000 85.4000 54.2000 6.7620 7.3880 8.1570 9.0260 16100.0000 87.6000 72.0000 9.2800 9.0960 10.9010 12.1860 16200.0000 97.5000 37.2000 10.6980 11.2790 12.7420 14.2220 16300.0000 122.0000 41.8000 9.1230 10.6070 11.7690 12.8630 16400.0000 94.7000 60.7000 8.9460 8.6430 9.1010 9.2770 16500.0000 81.7000 36.2000 19.8510 27.2080 28.0100 31.0130 16600.0000 91.0000 38.3000 17.5950 22.8040 28.0100 32.0890 16700.0000 89.7000 83.4000 20.7590 27.5750 29.4170 31.0130 16800.0000 68.7000 99.0000 27.2940 39.1660 35.7570 35.0540 16900.0000 84.6000 65.3000 22.1330 35.1520 30.9470 31.0130 17000.0000 67.3000 31.5000 17.1710 22.6810 20.9220 20.9200 17100.0000 82.6000 158.1000 14.5270 17.3040 17.1260 17.4400 17200.0000 96.1000 18.4000 18.2760 22.0380 22.4140 23.7880 17300.0000 81.5000 64.5000 19.3370 31.1900 27.8900 29.8740 17400.0000 79.0000 39.3000 27.3050 69.0150 40.8970 41.7370 17500.0000 -999.2500 98.6000 -999.2500 -999.2500 • -999.2500 -999.2500 17506.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 15650.000000 Tape File End Depth = 17506.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 15651.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15651.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15700.0000 169.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15800.0000 80.9000 71.5000 8.8100 9.4890 10.4450 11.2640 15900.0000 66.5000 96.0000 6.5910 7.3880 7.5190 7.9230 16000.0000 85.4000 54.2000 6.7620 7.3880 8.1570 9.0260 16100.0000 87.6000 72.0000 9.2800 9.0960 10.9010 12.1860 16200.0000 97.5000 37.2000 10.6980 11.2790 12.7420 14.2220 16300.0000 122.0000 41.8000 9.1230 10.6070 11.7690 12.8630 16400.0000 94.7000 60.7000 8.9460 8.6430 9.1010 9.2770 16500.0000 81.7000 36.2000 19.8510 27.2080 28.0100 31.0130 16600.0000 91.0000 38.3000 17.5950 22.8040 28.0100 32.0890 16700.0000 89.7000 83.4000 20.7590 27.5750 29.4170 31.0130 16800.0000 68.7000 99.0000 27.2940 39.1660 35.7570 35.0540 16900.0000 84.6000 65.3000 22.1330 35.1520 30.9470 31.0130 17000.0000 67.3000 31.5000 17.1710 22.6810 20.9220 20.9200 17100.0000 82.6000 158.1000 14.5270 17.3040 17.1260 17.4400 17200.0000 96.1000 18.4000 18.2760 22.0380 22.4140 23.7880 17300.0000 81.5000 64.5000 19.3370 31.1900 27.8900 29.8740 17400.0000 79.0000 39.3000 27.3050 69.0150 40.8970 41.7370 17500.0000 -999.2500 98.6000 -999.2500 -999.2500 -999.2500 -999.2500 17506.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 15651.000000 Tape File End Depth = 17506.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS **** REEL HEADER **** MWD 08/06/10 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/03/10 1850977 Ol 2.375" CTK *** LIS COMMENT RECORD *** !!~!!!!!!! !!!!!!!!! Remark File Version 1.000 !!~~~!!!!! !!!!!!!!! Extract File: ldwg.las Version I nformation VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 15650.0000: Starting Depth STOP.FT 17278.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: P2-08APB1 FLD FIELD: Point McIntyre LOC LOCATION: 70 deg 24' 4.992"N 148 deg 31' 27.090"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 10 Mar 2008 API API NUMBER: 500292289670 Parameter Information Block #MNEM.UNIT Value Description SECT. 11 Section TOWN.N T12N Township RANG. R14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF DF Log Measured from FAPD.F 49.02 Feet Above Perm. Datum DMF DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 49.02 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. ~~-~6~ ~~ (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final. As per David Boyer there is no depth shifting needed as the MWD data from P2-08A serves as the PDCL for this well. All resistivity data has been clipped at 2000 ohm.m. (8) Tied to P2-08 at 15726 feet MD (9013.3 feet TVDSS). (9) The sidetrack was drilled from P2-08 through a milled window in 4 1/2 inch liner. Top of window 15726.5 ft.MD (9013.6 ft.TVDSS) Bottom of window 15733.0 ft.MD (9017.2 ft.TVDSS) (10) No new formation was drilled on runs 1, 2, 4 and 7 due to rig problems and MWD tool failures. (12) The interval from 17246 feet to 17278 feet MD (9037.2 feet to 9037.2 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 73 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN P2-08APB1 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN P2-08APB1 APIN FN Point McIntyre COUN North Slope STAT Alaska *** I.IS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 Data presented here is final. As per David Boyer there is no depth shifting need as the MWD data from P2-08A serves as the PDCL for this well. All resistivity data has been clipped at 2000 ohm.m. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ) Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 91 Tape File Start Depth = 15650.000000 Tape File End Depth = 17278.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 104 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN P2-08APBl.xtf LCC 150 CN BP Exploration (Alaska) WN P2-08APB1 APIN FN Point McIntyre COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 181 Tape File Start Depth = 15651.000000 Tape File End Depth = 17278.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 194 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/03/10 1850977 O1 **** REEL TRAILER **** MWD 08/06/10 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes ~ M Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RPD RPS 15650.0000 -999.2500 -999.250C -999.2500 -999.2500 15650.5000 -999.2500 -999.250C -999.2500 -999.2500 15700.0000 169.9000 -999.250C -999.2500 -999.2500 15800.0000 80.9000 71.5000 10.4450 11.2640 15900.0000 66.5000 96.0000 7.5190 7.9230 16000.0000 85.4000 54.2000 8.1570 9.0260 16100.0000 87.6000 72.0000 10.9010 12.1860 16200.0000 97.5000 37.2000 12.7420 14.2220 16300.0000 122.0000 41.8000 11.7690 12.8630 16400.0000 94.7000 60.7000 9.1010 9.2770 16500.0000 81.7000 36.2000 28.0100 31.0130 16600.0000 91.0000 38.3000 28.0100 32.0890 16700.0000 89.7000 83.4000 29.4170 31.0130 16800.0000 68.7000 99.0000 35.7570 35.0540 16900.0000 84.6000 65.3000 30.9470 31.0130 17000.0000 67.3000 31.5000 20.9220 20.9200 17100.0000 96.6000 69.6000 19.0910 22.0870 17200.0000 120.5000 52.5000 13.5450 17.4030 17278.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 15650.000000 Tape File End Depth = 17278.000000 Tape File Level Spacing = 0.500000 • RAD -999.2500 -999.2500 -999.2500 8.8100 6.5910 6.7620 9.2800 10.6980 9.1230 8.9460 19.8510 17.5950 20.7590 27.2940 22.1330 17.1710 12.3930 8.7040 -999.2500 RAS -999.2500 -999.2500 -999.2500 9.4890 7.3880 7.3880 9.0960 11.2790 10.6070 8.6430 27.2080 22.8040 27.5750 39.1660 35.1520 22.6810 16.4980 11.1580 -999.2500 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP RPD RPS 15651.0000 -999.2500 -999.2500 -999.2500 -999.2500 15651.2500 -999.2500 -999.2500 -999.2500 -999.2500 15700.0000 169.9000 -999.2500 -999.2500 -999.2500 15800.0000 80.9000 71.5000 10.4450 11.2640 15900.0000 66.5000 96.0000 7.5190 7.9230 16000.0000 85.4000 54.2000 8.1570 9.0260 16100.0000 87.6000 72.0000 10.9010 12.1860 16200.0000 97.5000 37.2000 12.7420 14.2220 16300.0000 122.0000 41.8000 11.7690 12.8630 16400.0000 94.7000 60.7000 9.1010 9.2770 16500.0000 81.7000 36.2000 28.0100 31.0130 16600.0000 91.0000 38.3000 28.0100 32.0890 16700.0000 89.7000 83.4000 29.4170 31.0130 16800.0000 68.7000 99.0000 35.7570 35.0540 16900.0000 84.6000 65.3000 30.9470 31.0130 17000.0000 67.3000 31.5000 20.9220 20.9200 17100.0000 96.6000 69.6000 19.0910 22.0870 17200.0000 120.5000 52.5000 13.5450 17.4030 17278.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 15651.000000 Tape File End Depth = 17278.000000 Tape File Level Spacing = 0.250000 RAD -999.2500 -999.2500 -999.2500 8.8100 6.5910 6.7620 9.2800 10.6980 9.1230 8.9460 19.8510 17.5950 20.7590 27.2940 22.1330 17.1710 12.3930 8.7040 -999.2500 RAS -999.2500 -999.2500 -999.2500 9.4890 7.3880 7.3880 9.0960 11.2790 10.6070 8.6430 27.2080 22.8040 27.5750 39.1660 35.1520 22.6810 16.4980 11.1580 -999.2500 ~ ~ Tape File Depth Units = feet ~ ~ Tape Subfile 4 is type: LIS