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Home My WebLink About207-115• Image Project Well History File Cover Pace XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q 7 - ~ ~~ Well History File Identifier Organizing (aone> ^ Two-sided III II'III II III II III ^ Rescan Needed III (I'lII II II III III RE AN DIGITAL DATA Color Items: ^ Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~'Maria~ Date: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: ~S1 ~ 8 /s/ Pp,.«P,~, e uiumuuamu BY: --aria Date: 1 ~ / ~ ~,D ~ lsl Scanning Preparation ~._ x 30 = BY: Maria Date: ~ ~. Production Scanning d + ~ =TOTAL PAGES (Count does not include cover sheet) !s! Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Pre aration: ~ES _ BY: Maria Date: r °~..~' Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. °mP ~IIIIIIIIIIII911111 Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III II'I III P 10/6/2005 WeII History File Cover Page.doc '- ~~ ~ .mom ~'~~ :.l= N MICROFILMED 6/30/2010 DO NAT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 ~ ~ A i~ ~ 2 0 ~ G Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, aa7-11~ 14 -02-~.- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-004) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-OSA 1920010 500292032701 Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-096 1820340 500292053402 Sealed Conductor NA NA 14-to 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292o7560t Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071150 Well Name/No. PRUDHOE BAY UNIT 14-02C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20318-03-00 MD 13912 TVD 8695 Completion Date 10/23/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: USIT, GR, MWD, DIR, RES, PWD, ABI, AZ, DEN, NEU, Stratasteer Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Typ Med/Frmt Number Name Scale Media No C Las 15674 Induction/Resistivity Press e Bl 1 ur u LIS Verification 16869 Induction/Resistivity Induction/Resistivity 25 Col Induction/Resistivity 25 Col 17124 See Notes 12357 12837 Open 11/9/2007 DRHO, RPM, FCNL, GR, NCNL, NPHI, RHOB, RPS Field Data 9712 11190 Case 1/22/2008 SBHPS, GR, CCL, Temp 2- Nov-2007 4189 13912 Open 9/12/2008 LIS Veri, GR, RPX, FET, RPM, RPD, RPS, ROP, FCNT, NPHI, NCNT, PEF, DRHO,RHOB 4189 13912 Open 9/12/2008 LIS Veri, GR, RPX, FET, RPM, RPD, RPS, ROP, FCNT, NPHI, NCNT, PEF, DRHO,RHOB 4455 13912 Open 11/3/2008 MD DGR, ROP, EWR, ALD, CTN 18-Oct-2008 4455 13912 Open 11/3/2008 TVDD DGR, ROP, EWR, ALD, CTN 18-Oct-2008 0 0 Open 11/3/2008 PDS, EMF and CGM graphics of EWR logs Well Cores/Samples Information; Name Sample Interval Set Start Stop Sent Received Number Comments Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071150 Well Name/No. PRUDHOE BAY UNIT 14-02C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20318-03-00 MD 13912 TVD 8695 ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y~- Analysis Y7 V~ Received? Comments: Completion Date 10/23/2007 Completion Status 1-OIL Daily History Received? Formation Tops Current Status 1-OIL ~N ~N UIC N Compliance Reviewed By: __ Date: ~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 14-02C October 29, 2008 AK-MW-5043421 14-02C: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20318-03 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20318-03 Digital Log Images: 1 CD Rom 50-029-20318-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-3536 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ f« WELL LOG TRANSMITTAL To: State of Alaska August 14, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7"' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 14-02C AK-MW-5043421 14-02C: 1 LDWG formatted CD rom with verification listing. API#:50-029-20318-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ;, , ', i. f ~:' % 'iii, Date BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~~~~1t5~ / ~ ~(~~ 3 01 /11 /08 C~ >t?~i~1I~Uts1 "~rl' NO. 4547 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt. Wall _Inh i! 1 nn rlacerin4inn r1a4a RI Cnlnr Cr1 Z-06 11594523 STATIC TEMP LOG 09/09/07 1 14-18B 11975743 SBHP SURVEY 12/08/07 1 14-02C 11767144 SBHP LOG - 11/02/07 1 H-24A 11963073 MEM CBL - ~ 11130/07 1 C-35A 11624351 CEMENT BOND & GRAVEL PACK ^a 11/03/07 1 MPH-19 11982423 USIT - (p ~f 12/10107 1 1 E-03A 11628773 MEM PROD PROFILE - ~ 05109/07 1 E-116 11434760 OH LDWG EDIT (DSI) - G 10/29/06 1 1 G-06A 11209587 MCNL - ~~ L~ 02/25/06 1 1 D-076 11162822 MCNL $- J ~ 12/04/05 1 1 G-10C 11209607 MCNL Q(,p- a 06/15/06 1 1 G-096 11649989 MCNL ~ ~}- j j (~ j b'(5J 09/11/07 1 1 K-08B 11745243 MCNL ~j '~ ~ 11/06/07 1 1 V-07 11978425 COMPOSITE CBL 12106107 1 V-07 11978425 UStT - ( 12/06/07 1 L2-33 11970801 RST J ' p ~ 07107107 1 1 03-14A 40013340 OH MWD/LWD EDIT ~ j 04/23/06 2 1 ~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - _„ :',,.: 900 E. Benson Blvd. ` - - Anchorage,Alaska 99508 tn1 r Date Delivered: ~"fi`~ ' ,g ~~ ~11~~1~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: °ff K~~TV~~ STATE OF ALASKA ~'~~~~ ` ' ALASK~L AND GAS CONSERVATION COMSION N~V `~ ~ 1Q0~ WELL COMPLETION OR RECOMPLETION REPORT AND.~~a'Oil $I G»s Cony, Iornmssi0n ~' Q 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoaAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 10/23/2007 12. Permit to Drill Number 207-115 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/18/2007 13. API Number 50-029-20318-03-00 4a. Location of Well (Governmental Section): Surface: 1262' FNL 1228' FEL 7. Date T.D. Reached 10/18/2007 14. Well Name and Number: PBU 14-02C , , SEC. 09, T10N, R14E, UM Top of Productive Horizon: 1943' FNL, 2086' FWL, SEC. 10, T10N, R14E, UM 8. KB (ft above MSL): 69.72 Ground (ft MSL): 34.7 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2934' FNL, 4682' FWL, SEC. 10, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 13820' 8694' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 675245 y- 5939078 Zone- ASP4 10. Total Depth (MD+TVD) 13912' 8695' 16. Property Designation: ADL 028312 TPI: x- 678575 y_ 5938476 Zone- ASP4 Total Depth: x- 681197 y- 5937555 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No S mi electronic nd rinted informs ion er 20 AAC 25. 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): USIT, GR, MWD, DIR, RES, PWD, ABI, AZ, DEN, NEU, Stratasteer 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT Wi. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 4# H-4 rf 1 0' S rface 12 ' 7 x Ar i t l l 13- /8" 72# N- 0 urface 273 ' Surfs 2732' 17-1/2" 5904 sx Permafrost II -5l8" 47# N-SO\RS-95\L-SO urfac urfa 4394' 12-1/4" 1000 sx Cla s'G' 692 x Class'G' 7" 6# L- 4 1 7' 41 71 -1/ " 4 4 sx Lit Crete 16 x la ' 4-1/2" 12.6# L- 0 108 7' 1 8 02' 869 ' -1/8" 6 2 sx Cla s' ' 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 SPF 4-1/2", 12.6#, 13Cr80 10815' 10738' MD TVD MD TVD 11398' - 11746' 8739' - 6720' 12581' - 12816' 8703' - 8707' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12921' - 13021' 8706' - 8702' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 13066' -13126' 8700' - 8697' 13186' - 13274' 8694' - 8691' Freeze Protected with 151 Bbls Diesel 13326' - 13818' 8689' - 8693' 26. PRODUCTION TEST Date First Production: November 7, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 11/15/2007 HOUrS Tested: 12 PRODUCTION FOR TEST PERIOD OIL-BBL: 398 GAS-MCF: 2087 WATER-BBL: 297 CHOKE SIZE: 86 GAS-OIL RATIO: 5239 Flow Tubing Press. 251 Casing Press: 1400 CALCULATED 24-HOUR f2ATE~ OIL-BBL: 797 GAS-MCF: 4174 WATER-BBL: 594 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 AAC 250.071. ~,u; I;~i~_. None /~~~~D Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE /' ~' _.~ ~~: ~~~ ~ 2007 l.~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS ' NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test ' rf needed, and submit results. Attach separate sheets to this form, Permafrost Base detailed test information per 20 AAC 25.071. UG4 4594' 4423' UG1 5517' 5198' None WS2 6253' 5789' WS1 6758' 6102' CM3 7100' 6301' CM2 7808' 6725' CM 1 8890' 7371' THRZ 9631' 7847' BHRZ 9895' 8014' LCU / TKNG 9960' 8055' TJB 10677' 8515' TJA 10819' 8610' Top of Sag River 10981' 8715' Top of Shublik 11032' 8743' Base of Sag River 11404' 8738' Formation at Total Depth (Name): Base of Sag River 11404' 8738' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certify that the fore~oing is true a d correct to the best of my knowledge. II Signed Sondr Stewman i._Iitle Drilling Technologist Date ~ l '~ ` U~ PBU 14-02C 207-115 Prepared ByName/Number. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNeRn~: 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with 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). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 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. IreM 29: 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 14-02C Fully cemented 13-3/8" x 9-5/8" Annulus 2217` MD 4-1/2" X-Nipple (3.813" ID) SAFETY NOTES: CHROME 4-1 /2" TBG TREE = CiW 4-1 /16" SK 2207` MD -HES ES Cementer / BOT Screw-in Sub at 2237' MD /9-5/8", 47#, L-80, Hydril 563 2,732 13-3/8", 72#, N-80, ID=12.347" 4302` MD 7" Liner Top 7.5" x 11.6' Tie-Back Sleeve DRLG DRAFT - 9-5/8" casing, 47#, N-80 9-5/8" Whipstock /Window TOW -4455` MD BOW - 4467' MD 9-5/8" EZSV - 4490' MD GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3161 3159 10 KBG2 DCK BEK 0 10!19/07 4 5029 4775 32 KBG2 DMY BK 0 10/19/07 3 6550 5981 54 KBG2 DMY BK 0 10/19/07 2 8256 6988 53 KBG2 DMY BK 0 10/19/07 1 9834 7975 50 KBG2 DMY BK 0 10/19/07 (NOTE: 2 Stage Cement Job on 7" Liner HES ES Cementer at 7527' MD) 4-1/2", 12.6#, 13 Chrome, Vam Top Tubing 10,707' MD 4-112" X-Nipple (3.813" ID) 10,738' BOT S-3 Packer Minimum ID = 3.725" @ 10803' 4-1 /2" XN NIPPLE 10,771` MD 4-1/2" X-Nipple (3.813" ID) 10,803` MD HES XN Nipple (ID = 3.725") 7" x 4-1 /2" Liner Top 10,807' MD (Baker ZXP Packer) Bottom WLEG @10,815` MD - 7", 26#, L-80, BTC-M & TCII Liner at 10,987' MD / 8720' TVD (4329` MD - 7" XO f/BTC-M to TC-II Connections) Swell Packers: Top Oil Top Water Bottom Water Bottom Oil - -11,754' MD - -11,798' - --12,492' - --12,531' Perforations: 11,388' - 11,746' MD 12,581' - 12,816' MD 12,921` - 13,021' MD 13,073 - 13,126' MD 13,186' - 13,274' MD 13,326' - 13,818` MD 4-1/2", 12.6#, L-80, IBT-M Liner 13,906' MD Top LC -13,820' MD -- DATE REV BY COMMENTS DATE REV BY COMMENTS Tina ORIGINAL COMPLETION 9/7/07 Updated - wp11 depths 01/27/94 LAST WORKOVH2 10!20/07 JGR Rotary Sidetrack -Final 02/02!02 RNlTP CORRECTIONS 10!28!07 ITCH CORRECTIONS 06/28!02 JB/KAK TRSV CORRECTION 05/31/08 DTM WELLHEAD CORRECTION 07/27/07 RLP Updated PRUDHOE BAY UNfr WELL: 14-028 PERMfT No: 1932000 API No: 50-029-20315-03 SEC 9, T10N, R14E, 1556.49' FEL & 593.53' FNL BP Exploration (Alaska) $P EXPLORATION Page 1 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours .Task Code NPT Phase Description of Operations 9/7/2007 20:00 - 22:00 2.00 MOB P PRE Move sub from East side of pad to 14-02C. Stage sub by well. 22:00 - 00:00 2.00 MOB N WAIT PRE Waiting on trucks held up by rig moves. 9/8/2007 00:00 - 02:00 2.00 MOB N WAIT PRE Waiting on trucks to finish rig move from East side of pad to 14-02C. 02:00 - 11:00 9.00 RIGU P PRE Move rig camp and pits to west side of pad. Spot and set up camp. Stage pits for sub placement. Line up sub on well 14-02. Lay down herculite. Spot sub over well. Spot pits,. light duty shop and welding shop. Berm cuttings tank. Hold Pre-Spud meeting. Rig accept at 1100 hours. 11:00 - 13:30 2.50 WHSUR P DECOMP PJSM. Rig up secondary annulus valve. Rig up for OA test. 13:30 - 14:30 1.00 WHSUR P DECOMP PJSM. Test 13-3/8" x 9-5/8" annulus to 2000 psi for 30 minutes. Test OK. Install XO. Change out gripper blocks, saver sub and stabbing guide to 5". 14:30 - 15:30 1.00 WHSUR P DECOMP PJSM. Test DSM lubricator to 500 psi. Test OK. Pull BPV. 15:30 - 18:30 3.00 WHSUR P DECOMP PJSM. Rig up circulating lines in cellar and reverse circulate 130 bbls diesel freeze protect from tubing. Switch lines in cellar and circulate 170 bbls diesel freeze protect the long way. Shut down and blow down. Remove circulating head. 18:30 - 21:00 2.50 WHSUR P DECOMP PJSM. Install K-plug, BPV with DSM. Run in dart with Cameron to make TWC. Test from below to 1000 psi for 30 minutes and above to 1000 psi for 5 minutes, tests OK. Rig down lines and suck out tree. Bleed all voids. Grease choke manifold. 21:00 - 22:00 1.00 WHSUR P DECOMP PJSM. ND tree and adapter flange. Remove from cellar. Screw XO in hanger, 17-1/2 turns to the right. Threads look good. Check atl lock down screws. Remove hooks from .BOP crane and hook up to BOP stack. 22:00 - 00:00 2.00 BOPSU P DECOMP PJSM. Pick up stack. Attempt to move onto well, no go. Set back on cradle. Adjust chains. Set stack on well head. 9/9/2007 00:00 - 01:00 1.00 BOPSU P DECOMP PJSM. Finish stabbing BOP stack on wellhead and rigging up. 01:00 - 04:00 3.00 BOPSU P DECOMP PJSM. Nipple up BOP stack and equipment. 04:00 - 11:00 7.00 BOPSU P DECOMP Test BOPE to 250 psi low, 3500 psi high. Test Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Sheve with AOGCC. Test witnessed by WSL Mitch Skinner and Bill Decker, TP John Castle and Ronnie Dalton. 11:00 - 14:30 3.50 DHB P DECOMP PJSM. Pull dart from BPV. Rig up DSM lubricator. Pull BPV. Break and LD DSM lubricator and extention. Pick up and MU lower top drive hydraulic IBOP. Install clamp hook up Tines and saver sub. Bring up casing equipment and control line spooler. Make up landing joint and LD in pipe shed. 14:30 - 17:00 2.50 PULL N SFAL DECOMP Remove and re-install lower IBOP hydraulic valve. 17:00 - 18:00 1.00 PULL P DECOMP PJSM. Bring up landing joint. Jay into hanger with 17-1/2 turns to the right. MU top drive. BOLDS. Unseat hanger with 125k. String weight of 80k after pulling free. Pull hanger to floor. Break out and lay down. Rig up XO, TIW and circulating head. 18:00 - 20:00 2.00 PULL P DECOMP PJSM. Circulate surface to surface at 110 gpm with 200 psi.. Clear and clean floor. Pump slug. Rig down. 20:00 - 23:30 3.50 PULL P DECOMP PJSM. Pull and LD 4-1/2" tubing to SSSV. Rig down and LD control line spooler. Recovered 53 full joints, 1 pup at 5.70, 28 SS bands and 1 SSSV. 23:30 - 00:00 0.50 PULL P DECOMP Pul(4-1/2" tubing. 9/10/2007 00:00 - 01:30 1.50 PULL P DECOMP PJSM. Pull 4-1/2" tubing to 2974'. 01:30 - 02:00 0.50 PULL N SFAL DECOMP Skate control panel blew fuse. Replace fuse. Panel had loose Printed: 10/25/2007 1:23:48 PM BP EXPLpRATlO'N Page 2 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date. I From - To ~ Hotars I Task (Code I NPT I .Phase I Description of Operations .9/10/2007 01:30 - 02:00 0.50 PULL N SFAL DECOMP lock nut. 02:00 - 02:30 0.50 PULL P DECOMP PJSM. Service rig, lubricate top drive. 02:30 - 05:30 3.00 PULL P DECOMP POOH with remaining tubing. Recovered 176 full joints, 1 pup joint at 5.70', 1 SSSV, 2 GLM, 1 cut joint at 5.56' and 28 SS bands. 05:30 - 06:30 1.00 PULL P DECOMP PJSM. Rig down casing equipment and clean floor. 06:30 - 08:00 1.50 BOPSU P DECOMP PJSM. Rig up and test bottom rams and lower IBOP. Test to 250 psi low, 3500 psi-high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Bill Decker and TP Ronnie Dalton. 08:00 - 09:00 1.00 CLEAN P DECOMP PJSM. Pick BHA up beaverslide. 09:00 - 11:00 2.00 CLEAN P DECOMP PJSM. Make up 9-5/8" casing scraper BHA to 310'. 11:00 - 12:00 1.00 CLEAN P DECOMP PJSM. Pick up and RIH with 5" DP to 1161'. 12:00 - 12:30 0.50 CLEAN P DECOMP PJSM. Adjust brakes and inspect draworks. 12:30 - 16:00 3.50 CLEAN P DECOMP PJSM. Pick up remaining 5" DP and RIH to 5496'. Fill pipe at 90 joints. PU a total of 165 joints. 16:00 - 18:00 2.00 CLEAN P DECOMP PJSM. Make up top drive and establish circulation at 600 gpm with 940 psi. Pump sweep surface to surface. Up weight 145k, down 125k, RT 135k. Pump slug. 18:00 - 19:30 1.50 CLEAN P DECOMP PJSM. POOH to 310'. 19:30 - 20:30 1.00 CLEAN P DECOMP PJSM. Rack back collars. Break and lay down scrapers. Empty boot baskets and lay down. 20:30 - 21:30 1.00 EVAL N WAIT DECOMP Waiting on SWS E-line unit. USIT flown in from Kenai. 21:30 - 22:30 1.00 EVAL P DECOMP PJSM with SWS. Spot E-line unit. PU and rig up E-line unit. 22:30 - 00:00 1.50 EVAL P DECOMP RIH with SWS. Run USIT/CCL/GR in cement and corrosion. mode. 9/11/2007 00:00 - 07:00 7.00 EVAL P DECOMP Run USIT/CCL/GR in cement and corrosion mode in 9-5/8" casing. Evaluating logs. 07:00 - 09:00 2.00 DHB P DECOMP PJSM, Arm firing head & P/U EZSV 09:00 - 11:00 2.00 DHB P DECOMP RIH w/EZSV set @ 4490' L/D Running Tool 11:00 - 11:30 0.50 DHB P DECOMP PJSM, Test EZSV to 1500 psi for 15 min. Good Test 11:30 - 12:00 0.50 DHB P DECOMP Test and Load String Shot 12:00 - 16:00 4.00 CASE P DECOMP PJSM w/SWS Bring Shooting Head to Floor and String shot sleeve - M/U & RIH to 2244' and Fire String Shot - POH Rig Down wireline -Suck out stack - Install plug and close blinds 16:00 - 18:00 2.00 BOPSU P DECOMP PJSM - Close top rams on 9 5/8" Test Jt - Test to 250 Low and 3500 high as per AOGCC -Test Witness waived by Lou Grimaldi AOGCC State Rep. 18:00 - 19:00 1.00 FISH P DECOMP PJSM/ Bring Cutter BHA to Rig Floor M/U on single - L/D Single in Shed, Adjust bail links for elevators 19:00 - 21:00 2.00 FISH P DECOMP PJSM RIH to 2185' - RIH into hole slow as per Baker Service Rep. - Install blower hose - P/U stand, M/U Top Drive, Establish Circulation - Locate Collars @ 2199' and 2237' - P/U 20' @ 221 T - Up wt 731< and DN wt 73K 21:00 - 22:00 1.00 FISH P DECOMP Establish Milling Parameters - 15 RPMS 13500 ft./ibs. torque Printed: 10/25/2007 1:23:48 PM $P EXPLORATION Page 3 of 32 Operatiolns Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 9/11/2007 21:00 - 22:00 1.00 FISH P DECOMP -Bring pump on @ 90 GPM, 200 psi - Free TO @ 3500 - Begin torque and bring up pump to 239 GPM, 865 psi, RPMS 50 - Cut 9 5/8" torque with cutting 5-15K stall top drive - Back off pump P/U establish RT -Bring up pump and restart cut, PSI drop of 600 psi and torque drop to 1500 - Verify cut ,Well began flowing -Shut down RT and pump - P/U Yool jt., monitor well, shut in as per co. rep. - Let PSI stabilize, SHCP = 10 psi, SIDPP = 30 psi 22:00 - 00:00 2.00 CASE P DECOMP Displaced to Heated Sea Water ciculating through poor boy degasser conducting well kill drill at the same time - Establish Kill plan and established circulation to choke and degasser @ 119 GPM 360 psi, Pumped full circulation and shut down and monitored well - well is static 9/12/2007 00:00 - 01:30 1.50 FISH P DECOMP Attempted to Establish Circulation - Pumped to 30 strokes, 2.6 bbls, to 1500 psi, Held 15 min., bled off -Pumped to 30 strokes, 2.6 bbls, to 1500 psi, Held 15 min., bled off -Pumped to 30 strokes, 2.6 bbls, to 1500 psi, Held 5 min., bled off - Unable to establish circulation btwn 13 3/8" and 9 5/8" annulus 01:30 - 03:30 2.00 FISH P DECOMP POH - UD BHA 03:30 - 06:00 2.50 WHSUR P DECOMP Attempt to pull 9 5/8" Upper and Lower Pack off - Pulled up to 15K and would not pull, Dogs popped out -Attempted three times without success 06:00 - 06:30 0.50 FISH P DECOMP PJSM L/D Pack Off Retrieving Tool and P/U 9 5/8" Casing tools - M/U floor valve to cross over 06:30 - 09:00 2.50 FISH P DECOMP PJSM M/U Spear & spear into 9 5/8" casing - Pull 9 5/8" to Floor, pulled free @ 205K - Unable to circulate - UD Spear, Hanger, and pup Jt - R/U XO, TIW & screw into top drive - Attempted to break circulation, pressure up to 1500 psi and worked pipe - Bled off pressure and worked pipe - While working pipe gas migrated up through arctic pac. Arctic Pac burped onto floor. Closed annular immediately; no further gas migration. - Pressure up to 1000 psi and worked pipe 09:00 - 12:00 3.00 FISH P DECOMP Clean Arctic Pac off floor & Derrick. 12:00 - 18:30 6.50 FISH P DECOMP PJSM. -Pressure test Little Red Hot Oil to 3000 psi, Good Test - Reverse. circ. 180 deg. diesel down O/A - 1/2 BPM to 750 psi taking returns to pits Printed: 10/25/2007 1:23:48 PM BP EXPLORATION Page 4 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date. From - To Hours Task Code NPT I Phase ( Description of Operations 9/12/2007 12:00 - 18:30 6.50 FISH P 18:30 - 21:00 I 2.501 FISH I P 21:00 - 23:00 I 2.001 FISH i P 23:00 - 00:00 I 1.001 FISH I N 19/13/2007 100:00 - 11:00 I 11.001 FISH I N 11:00 - 23:30 I 12.501 CASE I P 23:30 - 00:00 I 0.501 CASE 1 P 19!14/2007 100:00 - 03:00 I 3.001 FISH I P 03:00 - 07:00 I 4.001 FISH I P DECOMP -Bring rates up to 1bpm 1200 psi -Spot 127 bbls diesel taking returns to cutting tank - Shut in to let soak DECOMP Displace Arctic Pack -Open up and pump the long way with 110 deg heated seawater - ICP 240 GPM @ 750 psi, FCP 265 psi - pumped a total of 258 bbls - bled off, left open to stabilize - Pump slug @ 210 gpm & 220 psi bleed off DECOMP -Blow Down hoses, R/D cellar and blow out lines to cuttings tank - Clear floor of unnecessary equip. - Prepare floor to L/D 9 5/8" casing RREP DECOMP Rlg Repair -While lowering Top Drive down to break off crossover to 9 5/8" the manrider line hung on Top Drive and broke Kelly Hose Clamp - Secured scene and inspected visually - Inspected manrider line, Top Drive, and Kelly Hose for damage - All equipment remained intact, no objects dropped RREP DECOMP PJSM on Repairing Top Drive -Complete Derrick Inspection - Remove flow tube and upper IBOP and repair actuator valve - Remove Flow tube clamp and repair -Install IBOP and Flow tube -Secure secondary restraints - Change out Off Driller side Manrider Cable - Pressure test Surface Equipment DECOMP Lay down 9 5/8" 47# BTC Casing -Connection extremely tight, Rigged up double line on rig tongs to breakout connections, 80-90% of connections galled and damaged - 54 total joints recovered - 9 Bow Spring centralizers recovered - 1 cut joint @ 18.35 feet DECOMP Rig Down handling equipment -Clear floor of excess equipment - Clean Up Arctic pac around rotary table work area DECOMP P/U and Make up BHA -Washpipe shoe , 1Jt. Washpipe, W.O. Boot Basket, Double pin sub, Scraper, Bit sub, Float sub, Lub Bumper sub, Oil jar, 9 Drill collars, Pump out sub DECOMP RIH to 1325' - @ 852' pumped 25 bbls of hot diesel chased with 75 bbls of hot sea water -Continue to stage in hole and pump diesel to clean up arctic pac - @1325' pumped 25 bbls of hot diesel chased with 75 bbls of hot sea water -Continue to stage in hole and pump diesel to clean up arctic pac Printetl: 10/25/2007 1:23:48 PM BP EXPLORA710N Page 5 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date Frorn - To Hours Task .Code NPT Phase Description of Operations 9/14/2007 03:00 - 07:00 4.00 FISH P DECOMP - @1797' pumped 25 bbls of hot diesel chased with 75 bbls of hot sea water -Continue in to 2174' 07:00 - 07:30 0.50 FISH P DECOMP Wash down from 2174' to 2247' -45 rpms / 1k ft/Ibs 252 gpm / 120 psi - PUW 90k /SOW 85k / RtWt 88k Wash over stump without problems 07:30 - 10:30 3.00 FISH P DECOMP Circ bottoms up through Poor Boy Degasser -ICP @ 92 gpm = 90 psi / FCP @ 92 gpm = 55 psi -Monitor well, Static -Break circ. with 25 bbls of seawater followed with 25 bbls of diesel, -Displace well to 9.8 ppg brine -Monitor well, static 9.8 ppg brine in/out 10:30 - 14:00 3.50 FISH P DECOMP POH to BHA 14:00 - 15:00 1.00 FISH P DECOMP L/D Wash Pipe and 13 3/8" Casing Scraper BHA 15:00 - 16:30 1.50 FISH P DECOMP M/U Back-off BHA -Bull Nose, 9 x SDC's, XO, Blank sub, Lower Anchor, Power Section, Upper Anchor, XO, POS 16:30 - 18:00 1.50 FISH P DECOMP RIH filling pipe with fresh water 18:00 - 20:00 2.00 CASE P DECOMP PJSM, Rig Up pump in sub and test pump lines -Set Bottom Anchor @ 2256' -Set Top Anchor @ 2229' -Back off casing @ 3600 psi Cycle Back-off 12x for a total of 6 1/4 turns Release Anchors and Rig Down Surface equipment 20:00 - 21:30 1.50 CASE P DECOMP POH to BHA -Monitor well, static 9.8 ppg brine in/out 21:30 - 00:00 2.50 CASE P DECOMP UD Back off BHA 9/15/2007 00:00 - 01:00 1.00 FISH P DECOMP M/U 9 5/8 Cut Joint spear assembly -Bull Nose, 9 5/8 spear, Spear Extension, Stop Sub, Bumper Sub 01:00 - 01:30 0.50 FISH P DECOMP Pre-Job safety meeting with crew coming back from days off -Unable to have Pre Tour meeting due to late arrival of flight 01:30 - 02:30 1.00 FISH P DECOMP RIH 02:30 - 03:00 0.50 FISH P DECOMP Latch on to Cut Stub -Rackoff 6 turns, and pull on stub, stub pulled free without resistance -monitor well, static 9.8 ppg in/out 03:00 - 04:00 1.00 FISH P DECOMP POH 04:00 - 05:00 1.00 FISH P DECOMP L/D Spear BHA and Cut Joint stub (18.80') -Threads are good shape, Screw collar on to verify condition -Clear & Clean Rig Floor 05:00 - 07:30 2.50 CASE P DECOMP R/U to run 9 5/8" casing -PJSM with All Personnel 07:30 - 14:00 6.50 CASE P DECOMP Run 9 5/8" Tie-Back String -Baker Screw in sub with Overshot guide -HES Baffle Collar and pup jt, -HES ES Cementer -54 joints of 47# L-80 Hydrill 563 -2 Space out Pup Jts. -26 Bow spring centralizers -Jet Lube seal guard joint compound Printed: 10/25/2007 1:23:48 PM BP EXPLORATION Page 6 of 32: Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date- I From - To I Hours ~ Task Code I NPT I Phase Description of Operations 9/15/2007 107:30 - 14:00 I 6.501 CASE I P 14:00 - 15:00 I 1.001 CASE I P 15:00 - 17:00 I 2.00 I CEMT I P 18:30 - 22:00 3.50 BOPSUR P 22:00 - 00:00 I 2.00) BOPSUR P 19/16/2007 100:00 - 02:30 I 2.501 BOPSUf~ P 02:30 - 04:00 1.50 BOPSU~ P 04:00 - 09:30 5.50 BOPSU P DECOMP -18,000 ft /Ibs of make up torque -PUW 125k / SOW 80K DECOMP Make Top Drive and screw in to casing -12 turns, 10,000 ft/Ibs of torque -Pull 250K on casing -good -While pressuring up to 2000 psi, ES Cementer shifted open @ 1250 psi -Drop Bomb to confirm cementer is in the open position DECOMP Hold PJSM & RU Cement head and Cementers, CBU, Pump 5 bbl water, test cement lines to 4000 psi, Pump 15 bbls.10.5 ppg. MudPush, Pump 143 bbls Class G Tail Cement @ 15.8 ppg, Drop plug and kick out with 5 bbls water, Displace cement @ 8 bpm, Slow pumps to 2 BPM 10 bbls prior to bumping plug, Bump Plug on strokes to 2000 psi ,close ES Cementer, Bleed off and check for flowback, Float Holding -15 barrels of cement back to surface -CIP @ 17:00 hrs DECOMP Flush Stack And Rig Down Cementing equipment DECOMP Nipple Down BOP's -Set Slips w/ 100K -Cut 9 5/8 casing with Wachs cutter -set BOP's back on stump -Remove Tubing pool DECOMP Install Lower Packoff, Nipple up New Tubing Spool -N/U BOP's DECOMP Finish Nippling up Tubing Spool And BOP Stack -Test 9 5/8" Packoffs to 3800 psi for 30 min DECOMP Change Top Set of Rams to 3 x 6 Variable DECOMP R/U and Test BOP's PJSM, Continue to Test BOPE, 250 low, 3500 psi high, holding each test for 5 min. 5" Test Joint -Test #1 -Blind Rams, HCR Kill & Choke, -Test #2 -choke manifold valves 1, 2 & 3,14,16 and Kill Manual Valve -Test #3 -choke manifold valves 4, 5, 6 -Test #4 -choke manifold valves 7, 8, 9 -Test #5 -choke manifold valves 10, 11 -Test #6 -choke manifold valves 12, 13, -Test #7 -choke manifold valve 15 -Test #8 -hydraulic choke & manual choke Unable to Get Test Plug to hold pressure 09:30 - 11:30 2.00 BOPSU N SFAL DECOMP Changeout Test Plug 11:30 - 13:30 2.00 BOPSU P DECOMP Complete BOP Test -Test #9 -Lower Pipe Rams -Test #10 -Annular 250 Low / 2500 High -Test #12 -Top Rams, Inside Mud Cross, lower TIW Valve -Test #13 -Lower Rams, IBOP Perform accumulator Test -3000 psi, bleed down to 1600 psi 200 psi recovery 27 secs Printed: 10/25/2007 1:23:48 PM $P EXPLORATION Page 7 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date: From = To Hours Task Code NPT Phase Description of Operations 9/16/2007 11:30 - 13:30 2.00 BOPSU P DECOMP Full 3000 psi recovery 1 min 47 sec 6 Bottle of Nitrogen avg. 2100 psi Test witnessed by BP WSL Bill, Decker and Dave Newlon NAD TP Ronnie Dalton and Jon Castle Witness of test waived by Lou Grimaldi, AOGCC. 13:30 - 14:00 0.50 BOPSU P DECOMP Service Top Drive & Draw works 14:00 - 15:30 1.50 CLEAN P DECOMP Make up clean out BHA 8 1/2" mill tooth bit, 8 1/2 String mill, 2 Boot Baskets, Scraper, Bit Sub, Bumper Sub, Oil Jar, 9 - DC's 15:30 - 17:30 2.00 CLEAN P DECOMP RIH Picking up Drill pipe 1 x 1 Tag Cement @ 2194' 17:30 - 19:30 2.00 CLEAN P DECOMP Drill Cement, Plugs and Cementer to 2231' -430 gpm / 400 psi, -70 rpm / 2-4 TO - WOB 10- 25k 19:30 - 20:00 0.50 CLEAN P DECOMP Test Casing to 2000 psi for 5 Min after drilling through cementer and plugs 20:00 - 21:00 1.00 CLEAN P DECOMP Drill Baffle Plate -430 gpm / 400 psi, -70 rpm / 2-4 TO - WOB 10- 25k 21:00 - 21:30 0.50 CLEAN P DECOMP Pump 20 bbl Hi-Vis sweep -600 gpm / 700 psi 21:30 - 23:30 2.00 I CLEAN P 23:30 - 00:00 0.50 CLEAN P 9/17/2007 100:00 - 00:30 0.501 CLEAN ~ P 00:30 - 01:00 I 0.501 CLEAN I P 01:00 - 02:30 I 1.501 CLEAN I P 02:30 - 04:00 1.50 CLEAN P 04:00 - 05:30 1.50 CLEAN P :30 - 08:30 I 3.00 I STWHIPI P 08:30 - 11:00 2.50 STWHIP P 11:00 - 12:00 1.00 STWHIP P Sweep Brought back Residual Arctic Pac and 10% increase in cuttings DECOMP RIH Picking up Drill pipe 1 x 1 Tag Cement @ 4480' Stack 25k on EZSV, O.K. DECOMP CBU @ 620 gpm 1020 psi Puw = 125k Sow = 115 k 9.5 ppg Brine in and out DECOMP Finish Circulating Hole Clean -Residual Arctic Pac Returns with Brine 620 gpm / 970 psi DECOMP Test 9 5/8" Casing down to ESZV 3500 psi / 30 min Charted test Good Test DECOMP Displace to 9.5 ppg LSND Mud -Pump 50 Bbl Hi-Vis Spacer -620 gpm / 700 psi -25 rpm / 3k Tq. DECOMP Monitor Well, Static 9.5 ppg in /out POH DECOMP L/D Cleanout BHA -Clear Floor WEXIT P/U Whipstock and Window Milling Assembly -PJSM With Baker Fishing hand, HES MWD and NAD Rig Crew -Surface test MWD on first stand of DP, MWD Tested WEXIT RIH to 4361' WEXIT Orient Whipstock @ 69 degrees right of high side Printed: 10/25/2007 1:23:48 PM ~ ~ Iii $P EXPLORATION Page 8 of 32 :.:Operations Summalry Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date. From - To Hours Task. Code NPT Phase Description of Operations 9/17/2007 11:00 - 12:00 1.00 STWHIP P WEXIT -RIH and Tag ESZV at 4479' -Set Anchor with 25k down, Verify anchor -Shear off Bolt with 40k 12:00 - 23:30 11.50 STWHIP P WEXIT Start Milling TOW @ 4455' BOW @ 4471' - 450 gpm / 1280 psi - 80 rpm / 4- 12k Tq. 275 Ibs of Metal Shaving recovered Mill out to 4493' (22' of Open Hole) 23:30 - 00:00 0.50 STWHIP P WEXIT Pump Super Sweep surface to surface @ 446 gpm / 1280 psi Sweep Brought up 30% Increase in cuttings Dress & Work Window while Circulating, 100 rpm / 4k Tq 9/18/2007 00:00 - 00:30 0.50 STWHIP P WEXIT Finish circulating hole clean - 9.5 ppg MW In /Out 00:30 - 01:00 0.50 STWHIP P WEXIT Pull milling assembly into the casing and perform LOT to 12.53 ppg EMW -9.5 ppg MW -TOW @ 4455 MD / 4320' TVD -Pressure Leak off @ 680 psi -2.6 bbls pump / 2.5 return 01:00 - 03:00 2.00 STWHIP P WEXIT POH to BHA 03:00 - 05:00 2.00 STWHIP P WEXIT L/D DC's and BHA -Starting mill 3/16" undergauge, upper mills full gauge 05:00 - 06:00 1.00 STWHIP P WEXIT Pull Wear Bushing -Flush stack for metal cuttings -Function Rams -Flush stack with Wash Tool -Install Wear Bushing 06:00 - 08:30 2.50 DRILL P INT1 PJSM on Safe Handling off the GeoPilot Tool, HES Directional and NAD Rig crew in attendance -R/U Bypass lines to Geopilot control manifold -P/U BIT, Geopilot , MWD and Flex NMDC's 08:30 - 09:00 0.50 DRILL P INT1 Surface Test GeoPilot and MWD's -450 gpm / 650 psi 09:00 - 12:00 3.00 DRILL P INT1 RIH, -Picking up 5" HWDP and 33 Jts of DP -Ran stands to 4338' 12:00 - 13:00 1.00 DRILL P INT1 Slip and cut drilling line 13:00 - 13:30 0.50 DRILL P INT1 Service Top Drive, Draw Works and Crown 13:30- 14:00 0.50 DRILL P INT1 Break Circulation, Establish Parameters -Establish Baseline ECD readings -100 & 120 RPM and 550 gpm = 10.2 ppg ECD -100 & 120 RPM and 600 gpm = 10.3 ppg ECD -80 rpm & 100 rpm / 650 gpm = 10.3, 120 rpm / 650 gpm = 10.4 ppg 14:00 - 14:30 0.50 DRILL P INT1 Wash down to 4475' @ 625 gpm 1400 psi Ream open hole past Bottom of Window 4471 - 4493 Y -45 r m 3500 ft/Ibs Tor ue 1 :30 - 16:00 1.50 DRILL P INT1 Directional Drill from 4493 to 4576' (4367' tvd) -Stage Rpms up from 80 to 120 RPM's / 4 - 14k fUlbs Torque -625 gpm ! 1350 to 1800 psi off bottom PUW - 150k SOW - 120k RtWt - 130k Printed: 10/25/2007 1:23:48 PM ~ M BP EXPLORATION Page 9 of 32 Operations 5lummary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task £ode NPT Phase Description of Qperatjons 9/18/2007 14:30 - 16:00 1.50 DRILL P INT1 ADT = .80 hrs 16:00 - 18:30 2.50 DRILL P INT1 Drilling from 4569 - 4576' experience high Torque spikes and stalling Top Drive Hole Packing off slightly; losing 5-10% flow and 200 - 400 psi increase in pressure, No Increase in pressure on PWD Excessive volume of Coal cuttings returning to surface Unable to get back to bottom from 4569 - 4576' Wash and ream hole - 550 - 650 gpm - 1400 to 1800 psi - 90 - 125 rpm / 4 - 14k ft/Ibs Torque 18:30 - 20:00 1.50 DRILL P INT1 Mad Pass Tie-in Log 4455 - 4240' -Developed Plan Forward with Anchorage base Rig team whilst Mad Passing 20:00 - 21:00 1.00 DRILL P INT1 RIH to 4528' and pump Weighted Resinex and Asphasol pill on bottom -300 gpm / 800 psi -20 bbls, 10.1 ppg MW, 5 ppb Resinex and Asphasol 21:00 - 21:30 0.50 DRILL P INT1 POH with 6 stands to 3959' Pump dry job -Monitor well ,static 9.6 ppg In/ Out 21:30 - 23:00 1.50 DRILL P INT1 POH to BHA 23:00 - 00:00 1.00 DRILL P INT1 Standback Flex DC's - Download MWD /LWD recorded Data 9/19/2007 00:00 - 01:30 1.50 DRILL P INT1 L/D Geopilot and MWD Tools 01:30 - 03:00 1.50 DRILL P INT1 M/U Motor BHA -Mill Tooth Bit, Motor set @ 1.5 AKO, Float sub, MWD /LWD / PWD, 3 x NM Flex DC's, 3 x HWDP, Jars, 17 x HWDP 03:00 - 03:30 0.50 DRILL P INT1 Shallow Test MWD -450 gpm / 1500 psi -Good Test 03:30 - 06:00 2.50 DRILL P INT1 RIH to top of Window 06:00 - 07:00 1.00 DRILL P INT1 Orient Motor Bend Toolface@ 70 degrees right of Highside, -Stop Pump, Slide out window, -Wash and Ream to Bottom -450 gpm / 1130 psi 25 rpm / 4-5k ft/Ibs Torque -Take slow pump rates and Establish parameters No Issues reaming to bottom, 3 -5k drag reaming down, Tag bottom without packing off with coal, Cutting increased 75% on bottoms up but cleaned up afterwards 07:00 - 12:00 5.00 DRILL P INT1 Directional Drill as per HES Directional Driller, 4576- 4722' - 80 Rpm , 5k Tq off / 6k Tq On - 480 gpm, 1250 psi off / 1390 psi on - 10-15k WOB -PUW 140k / SOW 125k / RtWt 135k -AST= 2.37 /ART= 0.53 ADT=3.90 -MW = 9.6 In /Out 12:00 - 00:00 12.00 DRILL P INT1 Directional Drill as per HES Directional Driller, 4722' - 5470' (5157 ' tvd) - 80 Rpm , 5k Tq off / 7k Tq On - 530 gpm, 1640 psi off / 1860 psi on - 20-25k WOB -PUW 165k / SOW 130k / RtWt 140k -AST= 3.21 /ART= 4.74 ADT=7.95 Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 1t? of 32 - Opellations Sulmlmary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 9/19/2007 12:00 - 00:00 12.00 DRILL P INT1 -MW = 9.7 In /Out ECD avg 10.5 - 10.7 ppg actual /Calculated 10.4 ppg 9/20/2007 00:00 - 01:30 1.50 DRILL P INT1 Directional Drill as per HES Directional Driller, 5470'- 5565' (5240 ' tvd} - 80 Rpm , 5k Tq off / 7k Tq On - 530 gpm, 1640 psi off / 1860 psi on - 18k WOB -PUW 165k / SOW 130k / RtWt 140k -AST= 0.59 /ART= 0.39 ADT=0.98 -MW = 9.7 In /Out ECD avg 10.5 - 10.7 ppg actual /Calculated 10.4 ppg 01:30 - 02:30 1.00 DRILL P INT1 Pump Hi-Vis Sweep and circ. hole clean for RIH with Rotary Steerable Tool - 535 gpm / 1700 psi - Sweep Brought up 20 to 25% Increase in cuttings - 2x Bottoms to clean hole Monitor well, Static 9.7 ppg in/out 02:30 - 05:00 2.50 DRILL P INT1 POH to BHA -20 to 25k drag in open hole -no swabbing or overpulls -pulled into window without problems 05:00 - 07:30 2.50 DRILL P INT1 POH to Bit -Stand Back collars ~ -Download MWD Data -Break Bit and L/D Motor 07:30 - 09:00 1.50 DRILL P INT1 PJSM, Pick up HES Rotary Steerable BHA 09:00 - 10:00 1.00 DRILL P INT1 Surface Check HES Rotary Steerable BHA and MWD -530 gpm / 430 psi 10:00 - 12:30 2.50 DRILL P INT1 RIH to 5469, -No problems running in open hole Precautionary ream last stand to bottom 12:30 - 00:00 11.50 DRILL P INT1 Directional Drill as per HES Directional Driller, 5565' - 6548 (5983 ' tvd} - 80-120 Rpm , 10k Tq off / 13k Tq On - 550 gpm, 2170 psi - 10k - 22k WOB -PUW 190k / SOW 155k / RtWt 155k -ADT=7.74 -MW = 9.7 In /Out ECD avg 10.5 - 10.7 ppg actual /Calculated 10.35 ppg 9/21/2007 00:00 - 12:00 12.00 DRILL P INT1 Directional Drill as per HES Directional Driller, 6548 - 7666 (6641'tvd) - 80-120 Rpm , 10k Tq off / 13k Tq On - 630 gpm, 2250 psi - 20-25k WOB -PUW 215k / SOW 135k / RtWt 165k -MW = 9.7 In /Out ECD avg 10.7 ppg actual /Calculated 10.52 ppg 12:00 - 00:00 12.00 DRILL P INT1 Directional Drill as per HES Directional Driller, 7666 - 8763 (7293'tvd) - 80-120 Rpm , 15k Tq off / 14k Tq On - 630 gpm, 2650 psi - 20-25k WOB Printed: 10/30/2007 11:30:51 AM ~ ~ BP EXPLORATION Page 11 of 32 Operatiolns Sumlrnary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2E5 Date From - To Hours Task Code NPT Phase Description of Operations 9/21/2007 12:00 - 00:00 12.00 DRILL P INT1 -PUW 235k / SOW 140k / RtWt 170k -MW = 9.8 In /Out ECD avg 10.77 ppg actual /Calculated 10.59 ppg 9/22/2007 00:00 - 05:00 5.00 DRILL P INT1 Directional Drill as per HES Directional D ri I I e r, 8763-8958(7412'tvd ) - 80-120 Rpm , 15k Tq off / 14k Tq On - 630 gpm, 2700 psi - 20-25k WOB -PUW 235k / SOW 140k / RtWt 170k Weighting up to 11.6 ppg with spike fluid 05:00 - 10:30 5.50 DRILL N DPRB INT1 Lost 80%- 90% of returns while pumping and losing 5-10 bbls/hr static -Monitior well for loss rate -Loss rate increase to 24 bbls / hr -Drop Circ. sub ball and open circ sub @ 3 bpm / 575 psi -Drop BHA Shut Off ball after pumping 65 bbl heavy pill to balance mud in drill pipe -Pump 50 bbl of 50# /bbl LCM pil, chase with 11.5 ppg mud 10:30 - 11:30 1.00 DRILL N DPRB INT1 Pull 10 stands to 8024', -PUW 245k - 270k -No problem with pulling 10 stands 11:30 - 12:00 0.50 DRILL N DPRB INT1 Drop Circ. Sub Closing ball -120 gpm / 470 psi -No Static losses Reciprocating Pipe at all times 12:00 - 18:00 6.00 DRILL N DPRB INT1 Let LCM pill soak, Reciprocating pipe -Attempt to establish circulation @ 2 bpm - No Go -Wait on mud from mud plant -No Static losses, unable to get any returns while pumping 18:00 - 19:00 1.00 DRILL N DPRB INT1 Pump 50 bbl 11.5 ppg pill to balance mud, 3 bpm / 540 psi -RIH to 8900, Slowly 19:00 - 21:30 2.50 DRILL N DPRB INT1 Attempt to break circ @ 3 bpm / 570 psi, - No Returns, Hole staying full, Static hole -Drop CCV (circ. Sub) ba-I, 3 bpm / 500 psi, Circ sub opn with 2050 psi -3 bpm / 490 psi with Circ. sub open -Attempt to Drop BHA Close off ball ,Mud out of balanced, -Pump 50 bbl 11.5 pill, still out of balance pumped 50 bbls of 11.5 ppg mud @ -3 bpm /440 psi -Drop BHA Close off ball 21:30 - 23:30 2.00 DRILL N DPRB INT1 Monitor well while reciprocating pipe -Wait on Mud From Mud Plant 23:30 - 00:00 0.50 DRILL N DPRB INT1 Pump 50 bbl pill / 100# /bbl LCM -3 bpm / 500 psi Chase with 150 bbls of 11.6 ppg mud -PUW - 250k SOW - 150k 9/23/2007 00:00 - 01:00 1.00 DRILL N DPRB INT1 Chase LCM pill with 11.6 ppg mud in Drill pipe to balance mud. 01:00 - 03:30 2.50 DRILL N DPRB INT1 POH -Pulled @ less than 25'/min to keep from swabbing -Hole staying static -PUW 240k - 260k Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 12 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 9/23/2007 01:00 - 03:30 2.50 DRILL N DPRB INT1 Start pulling tight @ 7125' and 45k - 60k overpull 03:30 - 05:00 1.50 DRILL N DPRB INT1 05:00 - 06:00 1.00 DRILL N DPRB INT1 06:00 - 10:30 4.50 DRILL N DPRB INT1 10:30 - 11:15 I 0.751 DRILL I N I DPRB I INT1 11:15 - 12:00 0.75 DRILL N DPRB INT1 12:00 - 13:00 1.00 DRILL N DPRB INT1 13:00 - 14:30 1.50 DRILL P INT1 14:30 - 18:00 3.50 DRILL N DPRB INT1 18:00 - 21:30 3.501 DRILL I N I DPRB i INT1 21:30 - 23:00 1.50 DRILL N DPRB INT1 23:00 - 00:00 1.00 DRILL N DPRB INT1 9/24/2007 010:45 - 03:15 1.50 DRILL N (DPRB INT1 03:15 - 04:30 I 1.251 DRILL I N I DPRB I INT1 -work up to 7075', screw in and back ream @ 45 rpm /15-21 k Tq. -Back ream to 6952', Pump @ 3 bpm, established returns Establish circ. with 10.1 ppg mud @ 2 bpm / -After displacing mud to circ. sub, lost returns Fill Drill pipe with 11.6 ppb mud to balance mud -Drop ball to close circ sub. Pump ball down on seat. Pressure up to close CCV and open BHA. POH to LD rotary steerable assembly. Pulling slow @ <20 fph to minimise swabbing from 6800' up). Rotate slowly as needed. Hole in generally good condition. Work and backream one spot at -5750'. Fill pipe with 10 bbls mud every 5 stands pulled. Continue POH to 4770'. Pulling easier above 5050' and hole taking fluid. MU top drive and attempt to break circ and establish returns @ 2.5 bpm - no success. Increase pump rate to 425 gpm to straighten rotary steerable to zero deflection - OK. POH above window with GeoPilot assembly w/o problems. Monitor well, Hole 12 bph loss rate -Clear ice from derrick -Slip and cut drilling line -Service Top Drive, Crown, Draw Works POH to top of BHA -No displacement, hole staying full, pump down Drill pipe every 5 stds PJSM with HES MWD and Rig Crew -Lay Down NM Flex DC's -Download MWD data -Lay Down Rotary steerable BHA -Clear vFloor of third party tools and clean /prep to RIH Make up Lost Circulation "Dumb Iron" BHA Bit, NB Stab, DC, IBS, Float Sub, Circ. Sub, HWDP, Jar, HWDP RIH @ 45'/min -No Returns, Hole staying full Total Losses for today 226 bbls RIH to shoe Try and break circ. @ 2 bpm, no returns, -3 bpm /returns @ 3% - 10 % ,then no returns -pump 50 bbl / 100#/bbl LCM pill, returns increase from 3% to 10 %, before LCM pill left bit -Chase LCM pill with 11.6 mud, shut down, 30 % returns @ 158 gpm Shut down, monitor well, well flowing, Monitor well for 30 min. - Flow Continuing to decrease, returns @ 1 bpm -Close in well and monitor for pressure build up. In 15 min SIDP = 30. SICP = 30 psi., No Pressure build up Printed: 10/30/2007 11:30:51 AM ~ ~ BP EXPLORATION Page 13 of 3z Operatiolns Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: .Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS ZES Rig Number: 2ES Date from - To Hours Task Code NPT Phase Description of Operations 9/24/2007 03:15 - 04:30 1.25 DRILL N DPRB INT1 -after 15 min, returns down to a trickle (1 % flow / 0.6 bpm) - well gave 85 bbls back 04:30 - 08:30 4.00 DRILL N DPRB INT1 Circulate Surface to Surface, Balance mud weights In & Out 08:30 - 09:00 0.50 DRILL I N DPRB INT1 09:00 - 09:30 0.50 DRILL N DPRB INT1 09:30 - 11:00 1.50 DRILL N DPRB INT1 11:00 - 11:30 0.50 DRILL N DPRB INT1 11:30 - 12:30 1.00 DRILL N DPRB INT1 12:30 - 13:00 0.50 DRILL N DPRB INT1 13:00 - 14:00 I 1.001 DRILL I N I DPRB I INT1 14:00 - 15:30 I 1.501 DRILL I N I DPRB I INT1 15:30 - 16:00 I 0.501 DRILL I N I DPRB I INT1 16:00 - 17:00 1.00 DRILL N DPRB INT1 17:00 - 19:00 2.00 DRILL N DPRB INT1 19:00 - 19:30 0.50 DRILL N DPRB INT1 19:30 - 21:30 2.00 DRILL N DPRB INT1 21:30 - 23:30 I 2.001 DRILL I N I DPRB I INT1 23:30 - 00:00 I 0.501 DRILL I N I DPRB I INT1 Balance out mud weights in pit 1, 2 and 3 to 10.6 ppg Pump @ 3 bpm / 150 psi ICP. Monitor flow from annulus -got back -30 bbls with flow tapering off to a trickle over 30 minutes. Allow DP to flow back, slowed to a low rate. Close in well and monitor for pressure build up. In 15 min SIDP = 0. SICP = 20 psi. -No Pressure build up Break circ at 3 bpm/200 psi and circulate until MW in & out = 10.6 ppg. Monitor well -flowed back -26 bbls in 30 min with flow diminishing to 3 bbl in 5 min at end. Continue observing well for 60 min. Flow did not stop but was down to 6 bbls in final 30 minutes of observation. Shut well in and observe 30 min PBU. SIDPP = 40 psi. SICP = 20 psi. -No Pressure build up Bleed both sides to zero and open up well. Slight flow from annulus and DP running over. RIH 5 stds to -4800' screwing in to each stand. PU 130 klbs. SO 120 klbs. Break circulation and work up to 3.5 bpm. Circulate to get 11.6 ppg mud out of annulus and displace with 10.6 ppg. Getting approx 75% returns. SD pumping and observe well for 30 minutes -annulus flowing back. 1st 5 min -flowed 14.1 bbls. Last 5 min -flowed back 4 bbls. Bleed off 20 psi from DP. RIH 10 stands to 5840' screwing into each stand. Break circulation and establish retums at 3.5 bpm (150 gpm). Circulate out 11.6 ppg mud with losses of 14 bbls in 15 minutes - 70% returns. Monitor well, well breathing, -gained 30.1 bbls while monitoring for 30 min. -Slowed the last 5 min. to 1.8 bbls / 5 min. -Flow continued to decline RIH with 11 stands to 6758' -tight at 6080, set jars off 2x to free, ream to 6025', full returns, no losses, Hole O.K. -Continue to RIH, intermittent tight hole 30 - 50 k to work through - Pushing fluid away RIH Circulate @ 3-4 bpm to get 10.6 ppg mud in & out -hole still taking fluid -90-95% returns -lost while circ. 25 - 30 bbls Monitor well, well breathing, -gained 28.1 bbls while monitoring for 30 min. Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 'f4 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task. Code NPT Phase Description of Operations 9/24/2007 23:30 - 00:00 0.50 DRILL N DPRB INT1 -Slowed the last 5 min. to 2.3 bbls / 5 min. -Flow continued to decline 9/25/2007 00:00 - 01:15 1.25 DRILL N DPRB INT1 RIH w/ 11 stds to 7800', screwed in on each one -intermittent tight hole, worked through without problems 01:15 - 04:00 2.75 DRILL N DPRB INT1 Circulate @ 3 bpm to get 10.6 ppg mud in & out -95% returns -lost 10 bbls while circulating. 04:00 - 04:30 0.50 DRILL N DPRB INT1 Monitor well, well breathing, -gained 22.5 bbls while monitoring for 30 min. -Slowed the last 5 min. to 0.5 bbls / 5 min. -Flow continued to decline 04:30 - 05:30 1.00 DRILL N DPRB INT1 RIH to bottom @ 8958' -No issues running in 05:30 - 09:45 4.25 DRILL N DPRB INT1 Circulate @ 3 bpm to get 10.6 ppg mud in & out. Stage pumps slowly up to 450 gpm over 1 1/2 hr monitoring losses. Lost 27 bbls during this period with loss rate increasing from 5 bph at 250 gpm to 40 bph at 450 gpm. 09:45 - 10:00 0.25 DRILL N DPRB INT1 Shut down pumps and observe -flowed back 14 bbls in 10 minutes. Flow rate steadily diminishing. 10:00 - 11:00 1.00 DRILL P INT1 Wash/ream to btm at 450 gpm. Commence drilling and losses immediately started going down to 10 bbl/hr rate. Drill to 8964'. 11:00 - 15:30 4.50 DRILL P INT1 Drill ahead with rotary assembly to 8988' MD. Low ROP 5-14 fph. Losses negligible (<5bph) at circ rate of 500 gpm. Circ 15 min. Up weight 235k, down 140k, RT 177k at 90 rpm with 12k torque on bottom. WOP 25-27k. 15:30 - 16:30 1.00 DRILL P INT1 Monitor well. Well breathing, get back 30 bbls in 15 minutes, diminishing. Mud weight in and out 10.6 ppg. Pull 5 stands. Monitor well, OK. Pump dry job. 16:30 - 21:30 5.00 DRILL P INT1 POOH to 4394' inside window. Monitor well for 15 minutes. Hole static. Continue to POOH to 701'. 21:30 - 23:00 1.50 DRILL P INT1 POOH and LD lost circulation BHA. Clear and clean floor. 23:00 - 00:00 1.00 DRILL P INT1 PJSM. Make up Geo-Pilot and MWD. 9/26/2007 00:00 - 02:00 2.00 DRILL P INT1 PJSM. Upload MWD. Make up float sub, stabilizer and 1 flex collar. Surface test MWD and Geo-Pilot at 500 gpm with 670 psi and 600 gpm with 950 psi. Make up flex collars, CCV, ball catcher, HWDP and Jars to 834'. 02:00 - 03:30 1.50 DRILL P INT1 RIH to 2727'. 03:30 - 04:00 0.50 DRILL P INT1 Flow and function test Geo-Pilot at 600 gpm with 1550 psi. Test OK. 04:00 - 05:00 1:00 DRILL P INT1 RIH to 4433'. 05:00 - 05:30 0.50 DRILL P INT1 Service top drive and crown. Install blower hose. 05:30 - 09:00 3.50 DRILL P INT1 RIH with 8-1/2" Geo-Pilot drilling assembly to 8776'. Fill every 3000'. 09:00 - 09:30 0.50 DRILL P INT1 Wash and ream to 8958' at 520 gpm with 715 psi. Torque 10-15k at 40 rpm. 09:30 - 10:00 0.50 DRILL P INT1 Log from 8958' to 8988' at 200 fpm, pumping at 520 gpm with 715 psi. 10:00 - 00:00 14.00 DRILL P INT1 Drill ahead to 9066'. Pump at 560 gpm with 2125 psi on bottom, 2000 psi off bottom. Rotate at 120 rpm with 12-16k torque off bottom, 16-20k on bottom. WOB 20-25k. Up weight 240k, down 145k, RT 180k. Printed: 10/30/2007 11;30:51 AM ~ ~ BP EXPLORATION Page 15 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task £ode NPT Phase Description of Operations 9/26/2007 10:00 - 00:00 14.00 DRILL P INT1 Continue to drill ahead to 9817' MD, 7961' TVD. Pump at 500 gpm with 1860 psi off bottom, 2030 psi on bottom. Torque 13-17k on bottom, 15k off bottom at 120 rpm. WOB 20-25k. Up weight 250k, down 150k, RT 185k. Data coming back with intermittent readings for logging. Decrease down pulses for Geo-Pilot. Decrease ROP to 50 fph. Able to double data points with good readings. Pick up drilling rate and drill ahead. Will slow to 50 fph when approaching Sag. 19/27/2007 100:00 - 03:00 I 3.001 DRILL I N I DPRB I INT1 03:00 - 08:00 I 5.001 DRILL I N I DPRB I INT1 08:00 - 00:00 I 16.001 DRILL I P I I INT1 Start spike fluid at 2100 hours/9640'. Start losing fluid at 10.9 ppg with an ECD of 11.73 ppg. Lossing as much as 120 bph. Pull up and slow pumps to 1 bpm. Bringing in new fluid and building more volume. Mud weight at 11.0 ppg. SPR's both pumps at 9721'/2200 hours. 30/320, 45/390. Build and condition mud on surface to 11.1 ppg. Rotate and reciprocate at 40 gpm with 385 psi. Establish pressure and rate at 126 gpm with 520 psi. Drop CCV operating ball. Pump and seat, shear with 2200 psi. Drop BHA shut off ball and seat. Up weight 260k, down 170k, RT 195k. Pump 45 bbl LCM pill with 75 ppb at 210 gpm with 650 psi. Increase rate to 300 gpm with 725 psi after pill cleared pipe. Losing 180 bph. Shut down and gain back 40 bbls in 10 minutes. Resume pumping at 70 gpm with 300 psi. No gain or loss at that rate. Wait on mud. Drop CCV closing ball, seat and shear at 2100 psi. Attempt to establish drilling rate of 450 gpm. Losing 400 bph. Dial pumps back to 125 gpm with no losses. Attempt to establish drilling rate of 450 gpm. Losing 400+ bph. Dial pumps back to 125 gpm with no losses. Bring rate up to 300 gpm with 1170 psi. Losses at 372 bph. Increase pump rate to 350 gpm with 1170 psi. Losses at 384 bph. Resume pumping at 126 gpm. Begin to gain volume. Increase pump rate at 21 to 42 gpm increments. Work up to 355 gpm with 15 bph losses. Drill ahead to 9914' at 355 gpm with 1245 psi. Rotate at 120 rpm with 18k torque. WOB 12k. Watering mud back to 10.9 ppg on the fly with losses falling from 85 bph to 15 bph. Pumping nut-plug sweeps as needed for bit balling. Up weight 265k, down 150k, RT 190k. 19/28/2007 100:00 - 07:30 I 7.501 DRILL I P I I INT1 Continue to directional drill ahead to 10212' MD, 8223' TVD. Up weight 265k, down 155k, RT 195k. Rotate at 120 rpm with 14-18k torque off bottom, 17k on bottom. WOB 26k. Pump at 426 gpm with 1600 psi off bottom, 1700 psi on bottom. SPR's both pumps at 10912'/2300 hours, 30/380, 45/460. Mud weight in and out 11.0 ppg. Calculated ECD 11.57, actual 11.75. Directional drill ahead to 10379' MD, 8318' TVD. Pump at 450 gpm with 1700 psi off bottom, 1760 psi on bottom. Rotate at 90 to 120 rpm with 19-21 k off bottom, 14-16k on bottom. WOB 25 to 35k. Up weight 285k, down 155k, RT 195k. Mud weight in and out 11.1 ppg. Calulated ECD 11.77 ppg, actual 11.85 ppg. Printed: 10/30/2007 11:30:51 AM ~ ~ BP EXPLORATION Page 16 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date From - To Hours Task Code NPT Spud Date: Start: 8/23/2007 End: Rig Release: 10/23/2007 Rig Number: 2ES Phase 9/28/2007 00:00 - 07:30 7.50 DRILL P INT1 07:30 - 09:30 2.00 DRILL N DFAL INT1 09:30 - 10:00 0.50 DRILL N DFAL INT1 10:00 - 17:00 7.00 DRILL N DFAL INT1 17:00 - 20:30 I 3.501 DRILL I N I DFAL I INT1 20:30 - 00:00 I 3.501 BOPSUF~P I I INT1 19/29/2007 100:00 - 03:00 I 3.001 BOPSUF~ P I I INT1 03:00 - 07:30 I 4.501 DRILL I N I DFAL I INT1 07:30 - 11:30 I 4.001 DRILL I N I DFAL I INT1 11:30 - 13:30 I 2.001 DRILL I P I I INT1 13:30 - 18:30 5.00 DRILL N DFAL INT1 18:30 - 20:00 1.50 DRILL N DFAL INT1 20:00 - 00:00 I 4.001 DRILL I P ( I INT1 19/30/2007 100:00 - 00:00 I 24.001 DRILL I P I I INT1 Description of Operations Losses since midnight 175 bbls for an average of 29 bph. Circulate and trouble shoot MWD problems. Electrical short in tool. Not receiving data to surface. Circulate bottoms up at 450 gpm with 1820 psi. Mud weight in and out 11.1 ppg. Monitor well. Well breathing. Gain 186 bbls in 30 minutes. POOH to 9436'. Pump dry job. Remove blower hose. Continue to POOH to 834'. Net gain of 131 bbls while pulling out of hole. Monitor well. Static loss of 2 bph. PJSM. Stand back HWDP and jars. Break CCV and Ball Catcher. Retrieve balls and lay down. LD flex collars. Flush BHA with fresh water. Break and LD stabilizer, float sub and bit. Housing sleeve wheels and bit balled up with clay and one nozzle plugged. Plug into tool, down load and tum off. Break and LD HOC, MWD tools and Geo-Pilot. Clear and clean floor. PJSM. PU test joint. Pull wear ring. Install test plug and fill stack. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpushers Bruce Simonson/Wayne Stout. PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpushers Bruce Simonson/Wayne Stout. PJSM. PU and RIH with BHA to 80'. Plug in and upload MWD. PU BHA to 1 stand of HWDP. Make up top drive. Surface test MWD at 350 gpm wtih 180 psi and 400 gpm with 253 psi. Tests OK. Continue to PU BHA to 834'. RIH to top of window at 4434'. Make up top drive. Fill pipe and test MWD. Test OK. Unable to send command to Geo-Pilot. No differential pressure. Bring rate up to 500 gpm with 646 psi. Signal good. PJSM. Cut and slip 87' of drilling line. PJSM. Inspect draworks, brakes and Elmago Splines. PJSM. Service top drive and crown. SPR's both pumps at 1145 hours/10472', 30/390, 45/500. RIH to 10192' at 50 fpm. Fill pipe and move annulus every 10 stands. Lost 174 bbls to 10192'. Break circulation. Stage pumps up to 425 gpm. Wash and ream to 10379'. Drill ahead to 10472' MD. Pump at 350 gpm with 1580 psi. WOB 25k. Rotate at 120 rpm with 17-19k torque. Up weight 275k, down 150k, RT 198k. Losing up to 400 bph. Lost 1050 bbls up to midnight. Mud weight in and out 11.1 ppg. ECD 11.63 ppg. Directional drill ahead to 10472' MD. Pump at 300 to 425 gpm with 1690 psi off bottom, 1740 psi on bottom. Rotate at 80 to 120 rpm with 20-30k torque off bottom, 15-22k on bottom. WOB 25-34k. Up weight 295k, down 150k, RT 198k. Mud weight in and out 11.1 ppg. ECD 11.75 ppg. SPR's at 10503'/1100 hours both pumps 30/370, 45/490. Continue to directional drill ahead to interval TD of 10987'. MD, 8720' TVD at top of Sag. Pump at 380 gpm with 1590 psi off Printed: 10/30/2007 11:30:51 AM • BP EXPLORATION Page 17 of 32 Operations Sumllnary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours -Task Code NPT Phase Description of Qperations 9/30/2007 00:00 - 00:00 24.00 DRILL P INT1 bottom, 1620 psi on bottom. Rotate at 120 rpm with 17-19k torque on bottom, 21-25k off bottom. WOB 25-35k. Up weight 325k, down 155k, RT 203k. Control drill last 2 singles down to Sag river marker. Stop drilling as per Geologist at 10987'. Circulate up samples. Mud weight in and out 11.1 ppg. ECD 11.64 ppg. SPR's both pumps at 10849'/1700 hours, 30/400, 45/510. 10/1/2007 00:00 - 01:00 1.00 DRILL P INT1 Circulate up samples from 10987' MD as per Geologist. Circulate at 385 gpm with 1600 psi. Up weight 330k, down 160k, RT 200k. TD called at 10987' MD, 8720 TVD. Mud weight in and out 11.2 ppg. ECD 11.7 ppg. 01:00 - 03:00 2.00 DRILL P INT1 PJSM. POOH to top of HRZ at 9598' MD. Up weight 330k, down 160k. Pull at 50 fpm. Tight spot at 9765' with 40k overpull. Go down and work through. Wiped clean. Gained 285 bbls on trip out. 03:00 - 04:00 1.00 DRILL P INT1 RIH to 10900'. One tight spot at 10260'. Pul- up and work through with no problems. Wash down last stand at 400 gpm with 1700 psi. Gained 26 bbls RIH. A total gain of 311 bbls during wiper trip. 04:00 - 06:30 2.50 DRILL P INT1 Circulate BU and pump weighted sweep surface to surface at 386 gpm with 1720 psi. Gas cut mud back on 2nd BU. Gas cut to 10.4 ppg regular balance scale, 11.2 ppg pressure scale. Mud weight in 11.2 ppg. Gas cleaned up from 70% to 2-3%. 06:30 - 15:30 9.00 DRILL P INT1 POH for 7" liner. Work minor tight spots at 10894, 10165'. Pulls ', to 50klbs. Work and rotate thru tight spot at 10120'. Wipe thru X4 and cleaned up - no pump. POH above top HRZ to 9220'. Up weight 225k, down 145k. Pump pill. Continue to POOH to 834' for 7" liner. Remove blower hose. 15:30 - 20:00 4.50 DRILL P INT1 PJSM. Lay down HWDP, jars and flex collars. Flush MWD tools. Download MWD. Two sets of Geo-Pilot sleave rollers were packed off as well as one side of bit guage pads. Break bit. LD remaining BHA. Clear and clean floor. 20:00 - 00:00 4.00 CASE P LNR1 PJSM. Pick up and rig up liner running equipment. Make up shoe track and landing baffle. Fill and check floats - OK. Run 7", 26#, L-80, BTC-M liner to 1230'. Optimum torque 9k ft/Ibs. Baker-lok float equipment. Use Best-Of-Life 2000 on BTC-M connections. 10/2/2007 00:00 - 09:00 9.00 CASE P LNR1 PJSM. Continue to run 7", 26#, L-80, BTC-M liner, 85 joints. PU and MU ES cementer. Run 10 joints BTC-M. Rig up torque turn equipment. Switch to 7", 26#, L-80, TC-II liner using Jet-Cube Seal Guard dope. Continue to run in hole to window at 80-90 fpm. Fill liner. Run into open hole at 60-70 fpm. RIH to 6607'. Rig down and lay down tongs. Change out handling equipment. Pick up liner running tool and prepare to RIH on drill pipe. Up weight 195k, down 135k. Make up top drive and pump 1000 strokes at 225 gpm with 336 psi. Pick up 10' pup and RIH. 09:00 - 14:30 5.50 CASE P LNR1 PJSM. RIH to 10968' at 40 fpm, filling every 5 stands. Up weight 195k, down 135k. Make up top drive and break circulation at 200 gpm with 600 psi. No returns. Lost 365 bbls on liner run. 14:30 - 15:30 1.00 CASE P LNR1 Make up cement head and single. Wash and work liner to 10987', Stage pump up to 126 gpm with 25 psi. Increase to 225 Printed: 10/30/2007 11:30:51 AM • -BP EXPLORATION Page 18 of 32 Operations: Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date 10/2/2007 From - To I Hours. I .Task (.Coded NPT I Phase Description of Operations 14:30 - 15:30 1.00 CASE P LNR1 15:30 - 16:00 0.50 CEMT P LNR 16:00 - 17:30 1.50 CEMT P LNR 17:30 - 18:50 1.33 CEMT P LNR 18:50 - 20:00 I 1.171 CEMT I P CIP at 2000 hours. 20:00 - 21:00 I 1.001 CEMT I P 21:00 - 00:00 I 3.001 CEMT I P LNR gpm with 350 psi. No returns. 1 Hold PJSM with crew and all service personnel. 1 Batch up cement slurries. Leave pipe parked on bottom. 1 Line up to cement truck. Pump 5 bbls water. Pressure test lines to 4500 psi - OK. Displace water out wash down line with Mudpush II. Line up on dril pipe and pump 40 bbls 11.8 ppg Mudpush II. Follow with 82 bbls of 12.0 ppg Litecrete lead cement. Follow with 35 bbls of 15.8 ppg Class G, Gasblok tail cement. Pump slurries at 5 bpm. Shut down. 1 Kick out 1st stage plug with 5 bbls water. Swap over to rig pumps. Pump mud at 5 bpm. At 100 strokes with 264 psi and 3% returns. Latch up wiper plug at 952 strokes (67 bbls) with 1375 psi and 9% returns. Continue to displace, at 2000 strokes with 675 psi and 12% returns, 3000 strokes with 955 psi and 14% returns, 4000 strokes with 1184 psi and 10% returns indicating good lift. Bump plug with 4518 strokes (321 bbls) and pressure to 2500 psi. Slack pipe to 60k and verify set. Bleed off and check floats. Floats holding. Pressure up to 3600 psi and attempt to open ES Cementer without success. Line up cement truck and pump up to 3870 psi and open ES Cementer. Swap back to rig. LNR1 LNR1 10/3/2007 100:00 - 07:30 I 7.501 CEMT I P LNR1 07:30 - 08:30 1.00 CEMT N CEMT LNR1 08:30 - 09:00 0.50 CEMT P LNR1 09:00 - 11:00 2.00 CEMT P LNR1 Circulate bottoms up times 2 at 450 gpm with 1750 psi. Returns at 17% at start and improving to 45% at finish. Overboard Mudpush II contaminated mud, Got back 215 bbls mud from well breathing. Wait on cement compressive strength of 500 psi. Pump 10 bbls every 30 minutes at 2 bpm with 475 psi. Well still breathing back mud. Saw trace of cement back to surface. Wait on 1st stage compresive strength of 500 psi. Move mud every 30 minutes, pumping 10 bbls at 2 bpm. Well breathing on every pump cycle. Trace of cement back with flow. Circulated one bottoms up at 450 gpm with 1650 psi. Well breathing back, total of 300 bbls back between cement jobs. Pump failure on cement truck. Shut down for repairs. PJSM with crew and service personnel for 2nd stage cement Pump 5 bbls water. Pressure test lines to 4500 psi. F-ush water from line with Mudpush II through wash down line. Pump 40 bbls 11.8 ppg Mudpush II at 5 bpm. Follow with 110 bbls of 12.0 ppg LightCrete tail cement with 2 ppb CemNET at 5 bpm. Drop plug and kick out with 5 bbls water. Switch over to rig pumps and displace cement with mud at 5 bpm. Latch up wiper plug at 929 strokes (66 bbls). Bump plug with 2705 strokes (192 bbls). Pressue up to 2200 psi and close ES Cementer. Bleed off. Check floats - OK. CIP at 1010 hours. Rotate 15 turns to the right. Pressure up to 1000 psi. Pickup 6' and watch for pressure drop. At pressure drop kick in pumps Printed: 10/30/2007 11:30:51 AM ', • . BP EXPLORATION Page 19 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 10/3/2007 09:00 - 11:00 2.00 CEMT P LNR1 circulate 40 bbls at 450 gpm. Slow pumps to 84 gpm set down 50k to set packer. Pick up off liner top. Set rotary at 15 rpm. ', Slack off and confirm packer set. Pick up 30' increase flow rate to 630 gpm with 2000 psi. Circulate 2 bottoms up while staying off liner top with liner running tool. 11:00 - 12:00 1.00 CEMT P LNR1 Break out and lay down cement head and manifold. Stab in safety valve. Clear floor. Pump slug. Pull and LD first joint of 5" DP. Blow down. 12:00 - 14:00 2.00 CEMT P LNR1 PJSM. Adjust draworks brakes. Service top drive. Locate and tighten leaking hydraulic fittings on Iron Roughneck. 14:00 - 18:00 4.00 CEMT P LNR1 POOH and lay down 5" drill pipe, 10' pup and liner running tool. Recover all of liner running tool. Clear and clean floor. 18:00 - 19:00 1.00 DRILL N RREP PROD1 Inspect top drive rail system frame work. Found 3 of 4 bolts broken. 19:00 - 00:00 5.00 DRILL N RREP PROD1 Remove lower end of block links from top drive. Disassemble cage guard and related components to access broken rail frame bolts. Inspect other bolts - OK. 10/4/2007 00:00 - 22:30 22.50 DRILL N RREP PROD1 PJSM. Continue working on top drive, drive rail system. Top drive sheared off bolts on top drive main frame. Disassemble top drive. Remove cage and remove sheared studs. Install new studs and reassemble top drive. Torque studs. Assemble drive cage guard. Weld mounting flange on cage. Remount components and re-wire electrical. Reconnect hydraulic lines. Re-pin block links. Inspect torque tube rail, guide bolts and re-torque. Power up system and function test. Clear and clean floor. 22:30 - 00:00 1.50 DRILL P PROD1 Make up mule shoe. RIH with 5" DP from derrick. 10/5/2007 00:00 - 01:30 1.50 DRILL P PROD1 PJSM. R1H with 5" DP stands from derrick to 4032'. 01:30 - 04:00 2.50 DRILL P PROD1 PJSM. POOH laying down 5" DP to 2083'. 04:00 - 04:30 0.50 DRILL P PROD1 PJSM. RIH with remaining 5" DP stands. 04:30 - 05:30 1.00 DRILL P PROD1 PJSM. Perform stripping drill. Take turns on choke and working pipe. 05:30 - 11:00 5.50 DRILL P PROD1 POOH laying down remaining 5" DP. 11:00 - 13:30 2.50 BOPSU P PROD1 Change out top drive saver sub, gripper blocks and stabbing guides. Replace guide plate bolts and nuts. Adjust foot. Re-position kelly hose safety clamp. 13:30 - 15:30 2.00 BOPSU P PROD1 PJSM. Pick up and make up test joint. MU wear ring puller. Pull wear ring. Install test plug. Fill stack and check for leaks - OK. 15:30 - 17:30 2.00 BOPSU P PROD1 PJSM. Test rams and saver sub with 4" test joint to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witnessed by WSL Bill Decker and Toolpusher Cleve Coyne. Blow down and rig down. Install wear ring. 17:30 - 20:00 2.50 DRILL P PROD1 PJSM. Make up mule shoe. RIH picking up 4" DP singles to 4200'. 20:00 - 22:00 2.00 DRILL P PROD1 PJSM. Pump slug. POOH with 4" DP stands. LD Mule Shoe. Clear floor. 22:00 - 23:30 1.50 DRILL P PROD1 PJSM. PU clean out BHA up beaverslide. Test mud pump #2 to 3500 psi. 23:30 - 00:00 0.50 DRILL P PROD1 PJSM. Pick up drill collar. Make up float sub. 10/6/2007 00:00 - 01:00 1.00 DRILL P PROD1 PJSM. PU bit, bit sub and make up to drill collar with float sub. Pick up remaining drill collars, HWDP and Jars. RIH to 372'. 01:00 - 07:30 6.50 DRILL P PROD1 PJSM. RIH picking. up 4" DP to 7290'. Pdnted: 10/30/2007 11:30:51 AM • ', BP EXPLORATION Page 20 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: j Event Name: REENTER+COMPLETE Start: 8/23/2007 End: 'Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of pperations ,10/6/2007 07:30 - 08:00 0.50 DRILL P PROD1 PJSM. Test liner lap to 3500 psi for 10 minutes. Test OK. ' 08:00 - 11:30 3.50 DRILL P PROD1 Wash and ream to 7527. Drill ES Cementer at 752T. Pump at 250 gpm with 920 psi. WOB 15-18k. Rotate at 40 rpm with 4-8k torque. Up weight 155k, down 110k, RT 130k. Blow down top drive. 11:30 - 15:30 4.00 DRILL P PROD1 PJSM. RIH to 10473'. Tag plug. Pick up and make up top drive. Up weight 235k, down 115k, RT 150k. Circulate at 290 gpm with 1546 psi. Rotate at 26 rpm with 12-13k torque off bottom, 9-11k on bottom. WOB 18k. Drill up cement plug to 10504'. Continue to wash and ream to 10743'. Top drive break hanging up. Top drive will not spin out of stand. 15:30 - 17:00 1.50 DRILL N SFAL PROD1 Top drive brake actuator valve failure. Remove old valve and install new valve. Function test - OK. 17:00 - 17:30 0.50 DRILL P PROD1 Continue to wash and ream to top of plug at baffle adapter. Tag at 10901'. 17:30 - 19:30 2.00 DRILL P PROD1 Circulate tube pill for metal to metal torque surface to surface at 370 gpm with 2440 psi. Cement and rubber in returns. 19:30 - 20:00 0.50 DRILL P PROD1 PJSM. Pressure test casing/liner to 3500 psi for 30 minutes. Test OK. Blow down kill line. Recored data for FIT correlation. 20:00 - 22:30 2.50 DRILL P PROD1 Drill up baffle adapter, cement, float collar and cement to 10977', 10' above float shoe. Pump at 250 gpm with 1500 psi. Rotate at 20-60 rpm with 9-11 k torque on bottom, 12-13k torque off bottom. WOB 5-25k. Up weight 245k, down 120k, RT 150k. 22:30 - 00:00 1.50 DRILL P PROD1 PJSM. Pump 50 bbls fresh water spacer, 45 bbls hi-vis sweep with tube for metal to metal torque followed by new 8.4 ppg Flo-Pro mud to displace well. Pump surface to surface until 8.4 ppg mud all the way around. Reciprocate and rotate pipe during displacement. Up weight 165k, down 140k, RT 155k. Torque reduced from 13k to 4.6k at 85 rpm. Shut down and break out stand. 10/7/2007 00:00 - 01:00 1.00 DRILL P PROD1 PJSM. Cut and slip 105' of drilling line. 01:00 - 02:00 1.00 DRILL P PROD1 Service and tube top drive. Inspect brakes, Elamgo Spline and draworks. 02:00 - 06:00 4.00 DR-LL P PROD1 POOH to 373'. 06:00 - 08:00 2.00 DRILL P PROD1 PJSM. Stand back HWDP. Lay down bit and collars. Clear and clean floor. PU 6-1/8" build section BHA. 08:00 - 10:00 2.00 DRILL P PROD1 PJSM. Make up 6-1 /8" BHA. 10:00 - 12:30 2.50 DRILL P PROD1 PU 4" drill pipe and RIH to 2810'. Up and down weight 60k. 12:30 - 16:00 3.50 DRILL P PROD1 PJSM. RIH to 4303'. Tag top of liner. Up weight 95k, down 90k. Rotate and slide through. Continue to RIH to 10977', filling every 30 stands. Remove air slips and install blower hose. 16:00 - 18:00 2.00 DRILL P PROD1 Make up top drive. Circulate at 250 gpm with 1690 psi. Line up high side and tag shoe at 10986'. Drill out remaining shoe track and 21' of new hole to 11008'. Up weight 195k, down 140k. 18:00 - 19:30 1.50 DRILL P PROD1 Circulate bottoms up at 250 gpm with 1750 psi. SPR's both pumps at 11008'/2000 hours, 30/610, 45/750. Mud weight in and out 8.4 ppg. 19:30 - 20:00 0.50 DRILL P PROD1 PJSM. Perform FIT to 10.0 ppg EMW with 725 psi. Test OK. 20:00 - 00:00 4.00 DRILL P PROD1 Directional drill ahead to 11081' MD, 8765' TVD. Pump at 250 gpm with 1844 psi on bottom, 1726 psi off bottom.. Up weight 195k, down 140k. WOB 15-18k. AST 4.62 10/8/2007 00:00 - 13:00 13.00 DRILL P PROD1 PJSM. Directional drill ahead in 6-118" production hole to Printed: 10/30/2007 11:30:51 AM ' • i BP EXPLORATION Page 21_of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT .Phase Description of Operations 10/8/2007 00:00 - 13:00 13.00 DRILL P PROD1 11268' MD, 8762' TVD. Pump at 250 to 275 gpm with 1780 psi 13:00 - 14:00 1.00 DRILL P I PROD1 14:00 - 16:00 2.00 DRILL P 16:00 - 00:00 8.001 DRILL I N I SFAL I PROD1 10/9/2007 100:00 - 02:30 I 2.501 DRILL I N I SFAL I PROD1 02:30 - 03:00 0.50 DRILL P 03:00 - 12:00 9.00 DRILL P 12:00 - 14:30 I 2.501 DRILL I P 14:30 - 15:30 I 1.001 DRILL I P 15:30 - 16:00 I 0.501 DRILL I P 16:00. - 17:00 I 1.00 I DRILL I P 17:00 - 20:30 I 3.501 DRILL I P 20:30 - 21:00 0.50 DRILL P 21:00 - 21:30 0.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 off bottom, 2030 psi on bottom. WOB 15-25k. Up weight 195k, down 135k. Mud weight in and out 8.4 ppg. PJSM. POOH to 10941'. Pump out at 255 gpm with 1920 psi. Drop ball, pump down at 84 gpm with 823 psi. Seat ball with 2000 psi. Hold then bump up pressure to open CCV at 2515 psi. Pump sweep surface to surface at 400 gpm with 1600 psi. Up weight 200k, down 140k. Mud weight in and out 8.4+. Drop ball. Pump down at 84 gpm with 620 psi. Close CCV at 2480 psi. PJSM. Trouble shoot top drive. Having problems spinning in and out. Found brake pad shattered. Pieces of brake pad stalling the top drive traction motor. Change out pads and rebuild calipers. Inspect rotor. Clean up parts and begin re-assemble. PJSM. Continue re-assembly of top drive. Finish assembly and function test. Test OK. Prepare to RIH and drill ahead. Clear floor. RIH to 11268'. Directional drill ahead to 11353' MD, 8750' TVD. Pump at 275 gpm @ 2040/2090 psi on bottom. WOB 20 to 25k. Up weight 190k, down 135k. AST= 6.57, ADT= 6.57, Jar Hrs.= 28.50 SPR 1&2 30SPM@740 psi, 45 SPM@ 880 psi, MD= 11284 @04:30 Mud weight in and out 8.4+ ppg. SPR's both pumps at 0330 hours/11268', 30/740, 45/880. Drilling from 11353' to 11370' @ 272 GPM -2040 psi On, 2090 psi Off -Up Wt. 190k, Down Wt. 135k -SPR's @ 11320' -0#1-30= 780/45= 900 -#2-30= 760/45= 890 -Mud Wt.= 8.4 -AST= 1.64 Pump out of Hole from 11370' to 10941' -Up Wt. 190k -Down Wt. 135k -262 SPM @ 1818 psi Drop Ball and pump down 2 bpm @ 756 psi to seat ball -Hold 2000 psi for 1 min. -Open Circ. Sub @ 2218 psi Circ. B/U @ 402 GPm -1558 psi remove blower hose -Pump slug and install stripping rubbers and air slips -Blow Down Top Drive PJSM/ POH from 10941' to 357' - Monitor well for 10 min. Drop Ball to close circ. sub - Flush BHA w/ fresh water -Blow Down Top Drive PJSM/ Rack Back HWDP, Jars, and 1 Std. Flex Collars Printed: 10/30/2007 11:30:51 AM ', BP EXPLORATION Page 22 of 32 -Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 10/9/2007 21:00 - 21:30 0.50 DRILL P PROD1 -Break down Circ. Sub and retrieve 4 balls 21:30 - 22:00 0.50 DRILL P PROD1 Plug in and download MWD 22:00 - 23:00 1.00 DRILL P PROD1 PJSM/ Cont. LD BHA, TM & DM, BRK Bit, LD Motor -Clean and Clear Floor 23:00 - 00:00 1.00 DRILL P PROD1 PJSM/ P/U Motor and Bit -M/U BHA 10/10/2007 00:00 - 02:00 2.00 DRILL P PROD1 P/U BHA -RIH to 406' -Shallow Hole test 203 gpm / 610 psi -Good Test 02:00 - 04:30 2.50 DRILL P PROD1 RIH and Fill every 30 stands -3216' 203 gpm / 920 psi -6019' attempted to fill and unable to circulate -Pumped 2.7bbls (47 stks) / 2500 psi no circulation -worked and rotated pipe to clear, unsuccessful 04:30 - 05:00 0.50 DRILL N DPRB PROD1 Attempt to unplug drill string -Dropped ball to attempt to open circ. sub 05:00 - 05:30 0.50 DRILL N DPRB PROD1 Serviced Top Drive 05:30 - 06:00 0.50 DRILL N DPRB PROD1 PJSM, Attempt to open circ. sub, unsuccessful 06:00 - 09:30 3.50 DRILL N DPRB PROD1 PJSM, POH From 6019' to 406' -MWT= 8.4 in & out 09:30 - 12:00 2.50 DRILL N DPRB PROD1 PJSM, STD HWDP Back, Remove Nukes, STD Collars Back -LID plugged pulser on MWD (tool was plugged with formation cuttings) -UD Nukes -1 Jet Plugged in Bit 12:00 - 14:00 2.00 DRILL N DPRB PROD1 -MWD personnel working on MWD Collar to remove pulser (unsuccessful) -Changed Out MWD Collar 14:00 - 15:00 1.00 DRILL N DPRB PROD1 PJSM, Rescribe Tool -P/U Nuke tool and new TM Collar from pipe shed 15:00 - 15:30 0.50 DRILL N DPRB PROD1 Upload MWD 15:30 - 16:00 0.50 DRILL N DPRB PROD1 P/U STD of Flex and install XO to 4" -Surface Test MWD @ 201 gpm 528 psi (Good Test) 16:00 - 17:00 1.00 DRILL N DPRB PROD1 PJSM, Load Nukes -P/U BHA to 406' -Change out handling equipment 17:00 - 17:30 0.50 DRILL N DPRB PROD1 Drop Ball and cycle the circ sub @ 2 bpm -1898 psi to open and 1711 psi to close -Confirmed closed 17:30 - 19:00 1.50 DRILL N DPRB PROD1 PJSM, RIH from 406' to 6019' Filling every 20 stands -1st Fill = 201 gpm / 758 psi -Checked MWD (good) -Fill @4432' = 201 gpm / 1222 psi 19:00 - 20:30 1.50 DRILL P PROD1 RIH to 10972' -Installed blower hose -Up Wt. 195k Down Wt. 135k 20:30 - 21:00 0.50 DRILL P PROD1 RIH from 10972' to 11346' -No issues running through open hole - Est. Circ. @ 274 gpm, 2050 psi -Shut down pump and slack off to bottom, Orient MWD -MWT In 8.4+ / 8.5 Out adding 5 bph of H2O 21:00 - 00:00 3.00 DRILL P PROD1 Drilling from 11370' to 11454' @ 277 gpm with 2029 psi off btm Printed: 10/30/2007 11:30:51 AM ~~ ! i BP EXPLORATION. Page 23 of 32 Operations Summally Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 10/10/2007 21:00 - 00:00 3.00 DRILL P PROD1 and 2280 psi on btm - 10-15k WOB - Up Wt. 205k /Down Wt. 120k - MWT 8.4+ In and Out adding 5 bph H2O 10/11/2007 00:00 - 12:00 12.00 DRILL P PROD1 Continue drilling from 11459' to 11812' -MWT. 8.5 In & Out -250 gpm / 1770 Off Bottom and 2070 psi On Bottom -Torque 4-5k off Bottom and 7-8k on Bottom -Up Wt. 180k Down Wt. 130k -70 RPM -WOB 5k / 10k -Hole started taking fluid @ 11620' -Total losses of 223 bbls 12:00 - 23:30 11.50 DRILL P PROD1 Continue drilling from 11812' to 12268' -MWT 8.5 In & Out -260 gpm / 1869 off Bottom and 2147 psi on Bottom -Torque 4-5k off Bottom and 7-8k on Bottom -Up Wt. 180k Down Wt. 132k -WOB 5k / 10k -Total loss since 12:00 hrs = 338 bbls 23:30 - 00:00 0.50 DRILL N DPRB PROD1 -Lost all returns @ 12268' -P/U pipe above zone -Keep hole failed on back side with trip tank returns @ 15% -Static losses @ 150-180 bph -Total losses of 108 bbls 10/12/2007 00:00 - 01:00 1.00 DRILL N DPRB PROD1 -Trip out of hole to the shoe @ 10972' -no problems pulling through openhole -Static losses @ 110 bph -MWT 8.5 -Loss of 88 bbls 01:00 - 06:00 5.00 DRILL N DPRB PROD1 Monitor Well -Open circ sub -Drop ball to close off BHA -Clean out pit -Build Form-A-Set sweep 06:00 - 06:30 0.50 DRILL N DPRB PROD1 PJSM, RIH from 10972' to 12268' 06:30 - 07:30 1.00 DRILL N DPRB PROD1 PJSM, Mix Form-A-Set -Break Circ. -Spot Form-A-Set @ 228 gpm 917 psi -Spot outside pipe and shut down ,bleed off -Up Wt. 210k Down Wt. 145k 07:30 - 08:30 1.00 DRILL N DPRB PROD1 PJSM, POH from 12268' to 10691' -Up Wt. 210k Down Wt. 145k -No problems, good hole -Blow Down Top Drive 08:30 - 09:00 0.50 DRILL N DPRB PROD1 Static loss @ 72 bph -Continued monitoring hole 09:00 - 09:30 0.50 DRILL N DPRB PROD1 Attempt circ. BUS @ 208 gpm 694 psi -No retums, shut down, blow down Top Drive -Circ. over TOH w/ trip tank 26% returns -Static toss of 9 bbls 09:30 - 10:00 0.50 DRILL P PROD1 PJSM w/ Halliburton Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 24 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date I From.- To I Hours I Task I Code I NPT I Phase I Description of Operations 10/12/2007 109:30 - 10:00 0.50 DRILL P I PROD1 -Load 9 5/8" RTTS in pipe shed 10:00 - 10:30 0.50 DRILL P 10:30 - 12:00 1.50 BOPSU P 12:00 - 16:30 1 4.501 BOPSUF~P 16:30 - 18:00 I 1.501 BOPSUFIP 18:00 - 20:00 2.00 DRILL P 20:00 - 21:00 1.00 DRILL P 21:00 - 22:00 1.00 DRILL P 22:00 - 23:00 1.00 DRILL N PROD1 PJSM, P/U Halliburton RTTS M/U and P/U single from pipe shed -RIH 37' set 9' below base of flange -Set RTTS, remove wear ring -Test to 1000 psi above, Good test -Losses of 1008 bbls this Tour PROD1 PJSM, M/U test plug -RIH and fill choke PROD1 PJSM, testing BOP's 250 low / 3500 psi high -Test 4" and 4 1/2" joint -Witness by BP WSL Blair Neufeld ,Nabors Tool Pusher Jon Castle and Jeff Jones of AOGCC -Rig Down and Blow Down Testing Equip. -Install Wear Ring PROD1 PJSM, P/U RTTS Running Tool -Screw into RTTS & Pull -UD RTTS -Hole was on vacuum, 70 bbls to fill PROD1 Mix and Spot Magna-Fiber LCM pill -5 bpm @ 730 psi PROD1 PROD1 DPRB PROD1 23:00 - 00:00 I 1.001 DRILL N I DPRB I PROD1 10/13/2007 00:00 - 00:30 0.50 DRILL N 00:30 - 01:00 0.50 DRILL N 01:00 - 03:00 I 2.001 DRILL I P PROD1 03:00 - 06:00 I 3.00 I DRILL I N I DPRB I PROD1 Cut & Slip 88' of drill line Rig Service, Lubricate Rig and Top Drive Circ. Mud -Circulate and Condition -Static losses less than 10 bbl hr. Break circulation -100% returns @ 6 bpm -Dropped ball and closed circ. sub -Opened BHA -Circ. 6 bpm, verified MWD pulsing -No losses -Circulation with circ. sub open 6 bpm 850 psi -Circulation with circ. sub closed 6 bpm 1530 psi RIH, No problems until 12152' took 40K Washed down from 12092'-12265' -240 gal min @ 1630 psi and 30 rpm -Torque 7k -Full returns -Up Wt. 190K Down Wt. 160 -240 gpm @ 1500 psi -Lost 1/2 returns when tagged bottom Drill from 12268' - 12357' -Control drilled @ 50 fph -60-70 rpm / torque 7k on / 9k off -Started 65-75 % losses when drilling began -No losses when not circulating, lost 320 bbls over last 2 hours while drilling Drop ball open circ sub -34 spm @ 560 psi before / 34 spm @ 430 psi after -Pumped down at 2 bpm @ 660 psi -Open at 2125 psi DPRB PROD1 DPRB PROD1 Printed: 10/30!2007 11:30:51 AM BP EXPLORATION Page 25 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations ',,10/13/2007 03:00 - 06:00 3.00 DRILL N DPRB PROD1 -Verify sub is open 2 bpm @ 440 psi -Drop BHA shut off ball -Verify BHA is shut off by pumping 6 bpm 06:00 - 07:00 1.00 DRILL N DPRB PROD1 Pump Magna-Fiber pill -Spot in open hole -5 bpm @ 900 psi 07:00 - 08:00 1.00 DRILL N DPRB PROD1 POOH, from 12356' to 10972' -No problems pulling out of hole -Monitor well -MWT in & out 8.5 08:00 - 09:30 1.50 DRILL N DPRB PROD1 Circ. 6 bpm @ 880 psi -Losses reduced from 120 bph to 15 bph while pumping over 30 min. -Drop ball, close CCV & open BHA -242 gpm @ 1465 psi 09:30 - 10:30 1.00 DRILL N DPRB PROD1 RIH, from 10972' to 12186' -Wash Down from 12186' to 12356' -Losses begin @ 12270 - 180 bph -Decision to switch from Flo-pro to sea water 10:30 - 12:30 2.00 DRILL P PROD1 Drilling from 12356' to 12405' -Up Wt. 190k Down Wt. 130k -RPM 30 torque 7k off / 8k on -WOB 6k -238 gpm @ 1500 ! 1670 psi 12:30 - 14:30 2.00 DRILL P PROD1 Circ. mud @ 2 bpm, 625 psi -Screen Down Blinding Off with LCM 14:30 - 00:00 9.50 DRILL P PROD1 Drilling from 12436' to 12697' -Up Wt. 200k Down Wt. 130k -ROT 160 -Torque off 7-8k on 8-9k -Mud Wt. in & out 8.5 vis 30 -Fluid Loss for Tour = 1129 bbls 10/14/2007 00:00 - 12:00 12.00 DRILL P PROD1 Drilling from 12697' to 13056' -Up Wt. 205k Down Wt. 125k RtWt 160 -270 GPM 1010 psi OFF / 1100psi ON -RPM 70 Torque off 7-8k on 8-9k -Mud Wt. in & out 8.5 Seawater -Loss Rate of 120 bph -loss since midnight 1475 bbls Sliding Difficult, pumping lube pills to help 12:00 - 15:00 3.00 DRILL P PROD1 Drilling from 13056' - 13141 Losing Pump Pressure / lost a total of 400 psi since 03:00 hrs -Up Wt. 210k Down Wt. 125k RtWt 160 -270 GPM 975 psi OFF / 1050 psi ON -RPM 50 Torque off 7-8k on 8-11 k -Mud Wt. in & out 8.5 Seawater -Loss Rate of 120 bph Sliding Difficult, pumping tube pills to help 15:00 - 15:30 0.50 DRILL N DFAL PROD1 Test Surface Equipment, O.K. Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 26 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 10/14/2007 15:30 - 19:30 4.00 DRILL N DFAL PROD1 POH looking for washout 19:30 - 22:30 I 3.001 DRILL I N 22:30 - 23:00 I 0.501 DRILL I P 23:00 - 00:00 I 1.00 I DRILL I P 110/15/2007 100:00 - 03:30 I 3.501 DRILL I P 03:30 - 05:00 I 1.501 DRILL ( P 05:00 - 12:00 I 7.001 DRILL I P 12:00 - 21:00 I 9.001 DRILL I P -Found washout in 68 stands off bottom -Washout approximately 1" in length by 1/4" wide, position laterally in slip area of the joint of 4" drill pipe -L/D Down washed out joint and pump 270 gpm / 1250 psi (expected pressure) DFAL PROD1 RIH - 13040' no issues running in -Fill @ 8824' 270 gpm / 1330 psi -Fill @ 10972' 270 gpm / 1500 psi PROD1 Precautionary ream 100' to bottom -30 rpm 7-9 k Torque -270 gpm 1750 psi PROD1 Drilling from 13141 - 13151 -Up Wt. 210k Down Wt. 125k RtWt 160 -270 GPM 1740 psi Off / 1920 psi On -RPM 60 Torque off 7-8k on 8-11 k -Mud Wt. in & out 8.5 Seawater -Loss Rate of 120 bph PROD1 PROD1 PROD1 PROD1 21:00 - 21:30 I 0.501 DRILL I N I DFAL I PROD1 21:30 - 00:00 I 2.501 DRILL I P I I PROD1 110/16/2007 100:00 - 05:30 I 5.501 DRILL I N I DFAL I PROD1 05:30 - 08:00 I 2.501 DRILL I N I DFAL I PROD1 Seawater Lost for the last 12 hours = 1030 bbls Drilling from 13151' - 13304' -Up Wt. 210k Down Wt. 125k RtWt 160 -270 GPM 1500 psi Off / 1630 psi On -RPM 60 Torque off 7-8k on 8-11 k -Mud Wt. in & out 8.5 Seawater -Loss Rate of 120 bph HES/ Sperry Sun MWD Struggling with detection -Mad pass from 13304' - 13211' @ 300 fph Drilling from 13304' - 13343' -Up Wt. 210k Down Wt. 125k RtWt 160 -270 GPM 1400 psi Off / 1550 psi On -RPM 70 Torque off 7k on 10k -Total Losses this tour 1650 bbl seawater Drilling from 13343' - 13410' -Loss of 450 psi over last 8 hours -Unable to get MWD detection the majority of the time -Unable to effectively slide to correct for inclination -Up Wt. 215k Down Wt. 120k RtWt 160 -300 GPM 1550 psi Off / 1750 psi On -RPM 75 Torque off 6-7k on 7-8k PJSM, POH from 13410'-13280' , no problems -Looking for wash out -Monitor Hole ,Hole is static when not circulating -Mud Wt 8.5 in & out PJSM, Mad pass from 13280' - 12450' -RPM 30 Torque off 6-7k -84 GPM @ 280 psi 280' fph -Losses 50 bbls -Total Losses this tour 1376 bbls POH, From 12463' - 406' -Changed out handling equipment -Losses of 85-95 bph while POH POH, From 406' - 171' Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 27 of 32 Operations Sumimary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 10/16/2007 05:30 - 08:00 2.50 DRILL N DFAL PROD1 -PJSM, L/D Nukes -POH from 171' - 0' -Clear Floor -Wash out in circ. sub 08:00 - 09:00 1.00 DRILL N DFAL PROD1 PJSM, M/U BHA to 108' 09:00 - 12:00 3.00 DRILL N DFAL PROD1 Download MWD, C/0 Nuke Tool &MWD -Upload MWD -Losses this tour 1020 bbls of seawater 12:00 - 15:00 3.00 DRILL N DFAL PROD1 PJSM, Upload MWD, MWD and motor could not communicate -UD MWD & Nukes, Check plugs in motor -P/U MWD& Nukes, Upload MWD -L/D MWD Tools & Motor, (due to communication issue) 15:00 - 18:30 3.50 DRILL N DFAL PROD1 PJSM, P/U new motor, bit, new DM, DRG, Nukes, TM -Upload MWD -Shallow Test MWD (Good Test) 250 gpm @ 930 psi -Load Nukes -RIH to 389' and change out handling equipment 18:30 - 20:00 1.50 DRILL N DFAL PROD1 PJSM, RIH from 389' - 4322' -Fill @ 3199' 250 gpm @ 1140 psi ,MWD unable to communicate -4322' 250 gpm @ 1180 psi ,MWD unable to communicate 20:00 - 21:30 1.50 DRILL N DFAL PROD1 Trouble shoot communication issue with MWD. -Resolved conflict and toot is operational 21:30 - 00:00 2.50 DRILL N DFAL PROD1 RIH from 4322' - 10113' -Up Wt. 170k /Down Wt. 140k -Fill @ 6002' 300 gpm @ 1760 psi ,Checking MWD communication -Fill @ 8807' 300 gpm @ 1940 psi ,Checking MWD communication -Losses this tour 936 bbls of seawater 10/17/2007 00:00 - 00:30 0.50 DRILL N DFAL PROD1 RIH, 10113' - 10953' (shoe) 00:30 - 01:00 0.50 DRILL P PROD1 Service Top Drive, Draw works, and Crown Section 01:00 - 03:30 2.50 DRILL N DFAL PROD1 RIH from 10953' - 13000' -Taking 2 MWD survey check shots -No issues running in the hole 03:30 - 04:00 0.50 DRILL N DFAL PROD1 Precautionary wash and ream from 13000' - 13410' -Bench mark surveys @ 13019' , 13206' , 13410' -260 gpm @ 1800 psi -30 rpm Torque 7400 ft/Ibs 04:00 - 12:00 8.00 DRILL P PROD1 Drill ahead 13410' - 13598' -Up Wt. 200k /Down Wt. 125k -ROT 160k -RPM 70 267 gpm @ 1800psi / 1950psi -Torque 8k off / 10k on -WOB 10k -Total losses this tour 1330 bbl of seawater 12:00 - 18:30 6.50 DRILL P PROD1 Drill ahead 13598' - 13900' -Up Wt. 215k /Down Wt. 130k -ROT 160k -RPM 70 270 gpm @ 1740psi / 1970psi -Torque 8-9k off / 9-11 k on -WOB 10k - 12k -Mud Wt. In & Out 8.5 Printed: 10/30/2007 11:30:51 AM • a BP EXPLORATION Page 28 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 10/17/2007 12:00 - 18:30 6.50 DRILL P PROD1 18:30 - 20:30 2.00 DRILL P PROD1 Circ. 30 bbls Hi-Vis Sweep -RPM 80 275 gpm @ 1770psi -Torque 8-9k -Monitor Well 20:30 - 23:00 2.50 DRILL P PROD1 PJSM, POH from 13900' - 10955' -From 13900'- 13400' intermittent 25-50k overpull -From 13400' - 12850' intermittent 25-40k overpull -No trouble after 12850' 23:00 - 00:00 1.00 DRILL P PROD1 PJSM, Cut & Slip drilling line -Total losses this tour 1373 bbls of seawater 10/18/2007 00:00 - 00:30 0.50 DRILL P PROD1 Service Top Drive, Draw Works, and Crown Section 00:30 - 02:00 1.50 DRILL P PROD1 RIH 10900' - 13900' -Precautionary reamed 13700' - 13900' -RPM 30 Torque 9200 ft/Ibs ~ -240 gpm @ 1940 psi -Drilled an extra 12' of hole to 13912' to fit pipe tally -RPM 65 Torque 8700 off / 9700 ft/Ibs on -270 gpm @ 1940 psi off / 2060 psi on 02:00 - 04:30 2.50 DRILL P PROD1 Pump High-Vis sweep surface to surface -Pumped until shakers cleared up -290 gpm @ 2130 psi 04:30 - 05:30 1.00 DRILL P PROD1 Pump and spot High-Vis / Lube liner running pill -270 gpm @ 1900 psi -Monitor Well 05:30 - 07:30 2.00 DRILL P PROD1 POH, 13912' - 10861' -Up Wt. 190k /Down Wt 140k -75 bph losses while tripping 07:30 - 08:30 1.00 DRILL P PROD1 Circ. 290 gpm @ 1800 psi -ROT & Recip. from 10861' - 10790' -Drop ball & open Circ. sub 08:30 - 11:00 2.50 DRILL P PROD1 POH, 10861' - 4694' -Place Circ. sub @ 4303' -Losses of 75 bph 11:00 - 12:00 1.00 DRILL P PROD1 Pump High-Visc. sweep around -400 gpm @ 600 psi -Clean up 7" liner top -Up Wt. 100 /Down Wt. 95 -70 bph losses -Total losses for this tour of 1090 bbls of seawater 12:00 - 14:00 2.00 DRILL P PROD1 PJSM, POH 4694' - 389' 14:00 - 16:30 2.50 DRILL P PROD1 PJSM, L/D BHA, C/O Elevators, Lay tools down beaver slide -Clean up rig floor 16:30 - 17:00 0.50 CASE P RUNPRD PJSM, Rig up to run 4 1/2" liner 17:00 - 21:30 4.50 CASE P RUNPRD PJSM, Run 4 1/2" L-80 IBT-M 12.6# to 3106' -P/U Hanger -Torque average 2500 ft/Ibs -Change out elevators -RIH 1 Stand drill pipe to 3231' -Dump 5 gals. of pal-mix into the top of liner -Let set up for half an hour 21:30 - 22:00 0.50 CASE P RUNPRD Circ. 1 liner volume - 210 gpm @ 100 psi Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 29 of 82 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES :Date. From. - To Hours. Task Code NPT Phase Description of Operations 10/18/2007 21:30 - 22:00 0.50 CASE P RUNPRD - Liner wt = 40k + blocks 22:00 - 00:00 2.00 CASE P RUNPRD PJSM, RIH from 3231' - 6415' -Filling every 10 stands -Up Wt. 105k / Down Wt. 100k -Total losses for this tour of 830 bbls of seawater 10/19/2007 00:00 - 04:00 4.00 CASE P RUNPRD RIH with 4 1/2" liner to 10901 -Lost Rate @ 40 - 100 bph RIH 04:00 - 05:00 1.00 CASE P RUNPRD Circulate at the Shoe 10987' -4 bpm / 300 psi PUW 175k /SOW 135k 05:00 - 06:00 1.00 CASE P RUNPRD Run liner into open hole from 10987' - 13912' TOL @ 10,813' -71 joints of 4 1/2" 12.6#/ft L-80 IBT -mod -Best-o-life pipe dope -No problems running in the hole, a few bobbles caused by Differential sticking 06:00 - 07:30 1.50 CEMT C RUNPRD Break circulation staging up to 5 bpm -5 bpm / 845 psi -Unable to reciprocate due to sticky hole -PJSM with Dowell Schlumberger personnel -PJSM with Nabors Rig Crew personnel 07:30 - 11:00 3.50 CEMT C RUNPRD Start Cement Job -Pump 5 bbls of water to charge lines and Test to 4700 psi, Good Test -Pump 40 bbls of 11.6 ppg MudPush II w/2 ppb CemNet -Pump 131 bbls of 15.8 class "G" Cement slurry with 2 ppb of CemNet -Flush lines through tee on floor -Rig pumped 60 bbls of PerF Pill, Chased with seawater -Latched up and Bumped on strokes, Increased pressure to 4000 psi to set hanger, PU t/180k, Set Down to 90k, Pick up and sat back down rotating with 15 rpm to confirm packer is set -Bleed off & Checked Floats, O.K. -Pressure uo to 900 psi and pull out of hanger -Pump @ 450 gpm @ 3040 psi -Circulated 27 bbls of cement back to surface -CIP @ 09:50 11:00 - 11:30 0.50 CEMT C RUNPRD Rig Down Cement head and clear floor of cementing and casing running equipment 11:30 - 12:30 1.00 CEMT P RUNPRD Slip and cut drilling line 12:30 - 13:30 1.00 CEMT C RUNPRD Circulate clean seawater around -489 gpm / 2100 psi 13:30 - 18:00 4.50 CASE P RUNPRD POH with 4" Drill pipe -Lay Down Running Tool 18:00 - 18:30 0.50 CASE P RUNPRD Service the TDS, Draw works and Crown 18:30 - 21:00 2.50 PERFO C OTHCMP PJSM with Nabors Rig personnel and Schlumberger Perf. Tech's -Ready Rig floor to Pick up Schlumberger TPC Perf Guns -Load Guns and 2 7/8" Pac Pipe into Pipe Shed 21:00 - 21:30 0.50 CASE P RUNPRD Test Liner Lap and Liner to 3500 psi for 30 mi, Good Test -Recorded Test on chart 21:30 - 00:00 2.50 PERFO P OTHCMP Pick up 2.88" 6SPPF 2906PJ & PJ OMEGA pert guns -Space out guns with 2 7/8" Pac Pipe 10/20/2007 00:00 - 02:30 2.50 PERFO C OTHCMP Pick up 2.88" 6SPPF 2906PJ & PJ OMEGA pert guns Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 30 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date -From - To Hours Task Code NPT Phase Description of Operations 10/20/2007 00:00 - 02:30 2.50 PERFO C OTHCMP -Space out guns with 2 7/8" Pac Pipe -78 guns picked up -1323' fo Loaded Guns -1115' of Blanks ', -2439' of total gun length 02:30 - 07:00 4.50 PERFO C OTHCMP RIH with perforating guns on 4" Drill pipe -Tag Plugs @on top of Landing Collar @ 13818 -Tag 6 feet high including Wiper Plugs -PUW - 193k SOW- 137k 07:00 - 08:00 1.00 PERFO X WAIT OTHCMP Consulted with Anchorage Rig team. -Change in Perforation Depth of 4 feet shallower than plan -Plan Shot Depth @ 13822', Actua! Shot depth 13818' 08:00 - 09:00 1.00 PERFO C OTHCMP PJSM with Schlumberger Perf Tech's and Nabors Rig Crew -Close Bag -Perform Firing Sequence -Positive indictation shots fired -Monitor well, 8 bph loss rate 09:00 - 10:00 1.00 PERFO P OTHCMP POH with 32 stands of Drill pipe -Loss rate Of 6 bph -Ready Floor to Lay Down Drill pipe 10:00 - 16:30 6.50 PERFO P OTHCMP Laydown drill pipe -Loss rate @ 4 bph 16:30 - 18:00 1.50 PERFO N OTHCMP Repair Iron Roughneck -Hydraulic Leak 18:00 - 19:30 1.50 PERFO P OTHCMP Finish Laying down 4" Drill Pipe from hole 19:30 - 00:00 4.50 PERFO C OTHCMP Lay Down 2 7/8" Pac Drill Pipe and Perforating Guns 10/21/2007 00:00 - 04:00 4.00 PERFO C OTHCMP Finish laydown 2 7/8" Pac Drill pipe and 2 7/8 Perf Guns -All Shots fire -No Junk left in hole Perf intervals, -11,398 - 11746', -12,581 - 12816', -12,921' - 13,021 -13,066 - 13,126' -13,186' - 13,274' -13,326 - 13818' 04:00 - 05:30 1.50 PERFO P OTHCMP RIH with 63 stands Drill Pipe from Derrick 05:30 - 10:30 5.00 PERFO P OTHCMP Lay Down 4" Drill Pipe 10:30 - 13:30 3.00 RUNCO RUNCMP Pull wear Bushing, Change out to longer bales, Bring tubing running equipment to the rig floor, R/U Power Tongs and handling equipment Rig up Stabbing board, Prepare Pipe Shed 13:30 - 14:00 0.50 RUNCO RUNCMP PJSM with Nabors drilling crew, Nabors casing hands and Baker Gompletion specialist 14:00 - 00:00 10.00 RUNCO RUNCMP Run 4 1/2" 12.6# Cr-80 Vam Top Tubing Completion Assembly -BakerLok Connections below packer -Jet Lube Seal Guard thread Compound -Avg Make Torque = 4400 ft/Ibs PUW - 95k SOW - 90k @ 7" Liner top 10/22/2007 00:00 - 05:00 5.00 RUNCO RUNCMP Run 4 1/2" 12.6# Cr-80 Vam Top Tubing Completion Assembly -Jet Lube Seal Guard thread Compound -Avg Make Torque = 4400 ft/Ibs Tagged @ 10825' Printed: 10130/2007 11:30:51 AM • BP EXPLORATION. Page 31 of 32 .Operations Summary :Report Legal Well Name: 14-02 Common Well Name: 14-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hotars Task' Code. NPT Phase Description of Operations 10/22/2007 00:00 - 05:00 5.00 RUNCO RUNCMP PUW - 180k SOW - 90k 05:00 - 07:30 2.50 RUNCO RUNCMP L/D 3 Joints, Make Up Space out Pups, Run 1 full joint, Rig Down Tubing running equipment, M/U Hanger and Landing Land in tubing spool with 8' of swallow from TOL to WLEG, Land with 60k on hanger, RILDS, Back out Landing joint 07:30 - 09:30 I 2.00 ~ RU Completion as follows 4.5" WLEG 9CR -4.5" TCII Tubing Pup -XN Nipple w/RHC-M plug (3.725" bore) 4.5" 12.6# 13Cr-80 XO pup Vam Top box x TCII pin 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin Baker S-3 7"x 4.5" Packer TCII Box x Pin 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-112" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 20 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #1 4.5"x1" KBG2-1 R 9Cr w/DV RK latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 37 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #2 4.5"x 1" KBG2-1 R 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 40 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #3 4.5"x 1" KBG2-1 R 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 36 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #4 4.5"x 1" KBG2-1 R 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 44 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM # 5 4.5"x 1" KBG2-1 R 9Cr w/ DCR Shear & RKP 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 22 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 50 jts (#194-242) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing Space Out PUPS 9.79', 9.75', 7.92', 5.8', 3.84' 1 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin Cameron Tubing Hanger 13.625" x 4.5" TCII Box x Pin RUNCMP Rig up and reverse in 182 bbls of corrision inhibited seawater followed by 168 bbls of clean seawater -3 bpm / 110 psi Printed: 10/30/2007 11:30:51 AM • • BP EXPLORATION Page 32 of 32 Operations Summary Report Legal Well Name: 14-02 Common Well Name: 1 4-02 Spud Date: Event Name: REENTER+COMPLETE Start: 8/23/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/23/2007 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To .Hours Task Code NPT Phase' Description of Operations 10/22/2007 07:30 - 09:30 2.00 RUNCO RUNCMP -Stab Landing joint and drop 2 1/4" ball and rod -Lay down Landing joint 09:30 - 13:30 4.00 RUNCO RUNCMP Close Blind rams and pressure up to 3500 psi on tubing -Set packer, held pressure for 10 min -Pressure test tubing to 3500 psi for 30 minutes, good test -Test tubing annulus to 3500 psi for 30 minutes, good test -Bleed annulus off and then tubing, Bring pressure up on tubing annulus and shear DCR shear valve in #5 GLM -Sheared @ 2300 psi Pump Both ways to confirm good shear Charted all tests 13:30 - 14:00 I 0.50 14:00 - 16:00 I 2.00 BOPSU~P 16:00 - 20:30 4.50 WHSUR P 20:30 - 22:00 I 1.501 WHSUR I P 22:00 - 00:00 I 2.00 WHSUR I P .10/23/2007 100:00 - 01:30 I 1.501 WHSUR I P 01:30 - 02:30 I 1.001 WHSUR I P RUNCMP ~ Install TWC and pressure test to 1000 psi for 10 min -Blow down lines RUNCMP Nipple down BOP's and set back on stump -Secure BOP's for rig move RUNCMP Nipple up Adaptor flange and tree -Test Flange to 5000psi for 30 min, good test -Test Tree to 5000 psi, good test RUNCMP PJSM with DSM and Rig Crew -R/U DSM Lubricator and test to 250 psi f/5min -Pull TWC RUNCMP PJSM with Little Red and Rig Crew -R/U to Pump Freeze Protect Diesel -Pump 151 bbls at 3 bpm / 700 psi RUNCMP U-tube Diesel -Rig Down Little Red RUNCMP R/U DSM install BPV -Test from below for 1000 psi 02:30 - 04:00 1.50 RIGD P RUNCMP -Remove secondary annulus valve -Secure Well -Prepare RDMO -Release Rig at 04:00 Printed: 10/30/2007 11:30:51 AM BP EXPLORATION Page 1 of 1' .Leak-Off Test Summary Legal Name: 14-02 Common Name: 14-02 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 9/17/2007 FIT 4,455.0 (ft) 4,320.0 (ft) 9.50 (ppg) 680 (psi) 2,812 (psi) 12.53 (ppg) 10/7/2007 FIT 11,008.0 (ft) 8,732.0 (ft) 8.40 (ppg) 725 (psi) 4,535 (psi) 10.00 (ppg) • Printed: 10/30/2007 11:36:49 AM -' ~ • Sperry Drilling Services Survey Report Company:- $P Amoco Date: 11/f9/2007 Time: 16:42:38 Page: l Field: Prudhoe $ay Co-ordinate(NE) Reference: Well: 14-02, True North Site: PB DS 14 Vertical (TVD) Reference: 41.22k28.5; 69.7 Well: 14-02 Section (VS) Reference:. WeII (O.OON,O.OOE;1 05.76Azi) Wellpath: 14-02C SurveyGalculationMethod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: WeII Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 14-02 Slot Name: 14-02 Well Position: +N/-S -524.22 ft Northing: 5939078.39 ft Latitude: 70 14 21.189 N +E/-W 1082.67 ft Easting : 675244.90 ft Longitude: 148 35 5.256 W Position Uncertainty: 0.00 ft Wellpath: 14-02C Drilled From: 14-02 500292031803 Tie-on Depth: 4455.00 ft Current Datum: 41.22+28.5; Height 69.72 ft Above System Da tum: Mean Sea Level Magnetic Data: 10/14/2007 Declination: 23.59 deg Field Strength: 57659 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 27. 61 0.00 0.00 105.76 Survey Program for Definitive Wellpath Date: 11/12/2007 Validated: Yes Version: 24 Actual From To Survey Toolcode Tool Name ft ft 96.72 4446.72 14-02 GYD CT CMS (96 .72-4746.7 GYD-CT-CMS Gyrodata cont.casing m/s 4455.00 13855.51 14-02C MWD+IFR+MS ( 4455.00-138 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Incl Azim TVD . Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 27.61 0.00 0.00 27.61 -42.11 0.00 0.00 5939078.39 675244.90 TIE LINE 96.72 0.41 123.80 96.72 27.00 -0.14 0.21 5939078.26 675245.11 GYD-CT-CMS 196.72 0.32 101.56 196.72 127.00 -0.39 0.78 5939078.02 675245.69 GYD-CT-CMS 296.72 0.44 227.96 296.72 227.00 -0.71 0.76 5939077.70 675245.68 GYD-CT-CMS 396.72 0.38 114.22 396.71 326.99 -1.10 0.78 5939077.31 675245.71 GYD-CT-CMS 496.72 0.45 232.37 496.71 426.99 -1.47 0.77 5939076.93 675245.71 GYD-CT-CMS 596.72 0.52 198.63 596.71 526.99 -2.14 0.32 5939076.25 675245.27 GYD-CT-CMS 696.72 0.32 94.84 696.71 626.99 -2.60 0.45 5939075.80 675245.41 GYD-CT-CMS 796.72 0.47 218.48 796.71 726.99 -2.94 0.47 5939075.46 675245.44 GYD-CT-CMS 896.72 0.38 117.33 896.71 826.99 -3.42 0.51 5939074.99 675245.49 GYD-CT-CMS 996.72 0.52 216.64 996.70 926.98 -3.93 0.54 5939074.47 675245.53 GYD-CT-CMS 1096.72 0.13 34.26 1096.70 1026.98 -4.20 0.33 5939074.20 675245.33 GYD-CT-CMS 1196.72 0.55 192.84 1196.70 1126.98 -4.58 0.29 5939073.82 675245.29 GYD-CT-CMS 1296.72 0.75 204.38 1296.69 1226.97 -5.64 -0.09 5939072.75 675244.94 GYD-CT-CMS 1396.72 0.61 168.67 1396.69 1326.97 -6.76 -0.26 5939071.63 675244.80 GYD-CT-CMS 1496.72 0.57 168.42 1496.68 1426.96 -7.77 -0.05 5939070.62 675245.03 GYD-CT-CMS 1596.72 0.71 225.12 1596.68 1526.96 -8.69 -0.39 5939069.69 675244.71 GYD-CT-CMS 1696.72 0.06 243.25 1696.67 1626.95 -9.15 -0.88 5939069.22 675244.24 GYD-CT-CMS 1796.72 0.05 266.49 1796.67 1726.95 -9.18 -0.97 5939069.19 675244.15 GYD-CT-CMS 1896.72 0.59 228.06 1896.67 1826.95 -9.53 -1.39 5939068.83 675243.73 GYD-CT-CMS 1996.72 0.57 224.47 1996.67 1926.95 -10.23 -2.12 5939068.12 675243.01 GYD-CT-CMS 2096.72 0.53 210.97 2096.66 2026.94 -10.98 -2.71 5939067.35 675242.45 GYD-CT-CMS 2196.72 0.58 189.25 2196.66 2126.94 -11.87 -3.03 5939066.45 675242.15 GYD-CT-CMS 2296.72 0.52 113.29 2296.66 2226.94 -12.55 -2.69 5939065.78 675242.50 GYD-CT-CMS 2396.72 0.76 177.14 2396.65 2326.93 -13.39 -2.24 5939064.95 675242.97 GYD-CT-CMS 2496.72 0.76 183.88 2496.64 2426.92 -14.72 -2.26 5939063.62 675242.99 GYD-CT-CMS 2596.72 0.73 191.81 2596.63 2526.91 -16.00 -2.43 5939062.34 675242.84 GYD-CT-CMS 2696.72 0.86 186.88 2696.62 2626.90 -17.37 -2.65 5939060.96 675242.65 GYD-CT-CMS 2796.72 1.34 187.29 2796.60 2726.88 -19.28 -2.89 5939059.05 675242.46 GYD-CT-CMS ~ • • Sperry Drilling Services Survey Report Company> BP AmOCO Date: 11/i9/2007 Tirne: 16:42:38 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Welly 14-02, True North Site: PB DS 14 Vertical (TVI)) Reference: 41 .22+28.5; 69.7 Well: 14-02- Section (VS)Reference; Well (O.OON,O.OOE,105.76Azi) Wellpath: 14-A2C Survey CalculationMeth~d: Mi nimum Curvature Ub: Oracle Survey MD Incl Azim TVD `Sys TVD N/S E/W MapN MapE Tool ft deg deg.: ft ft ft ft ft ft 2896.72 2.74 334.00 2896.57 2826.85 -18.29 -4.09 5939060.01 675241.24 GYD-CT-CMS 2996.72 6.05 347.92 2996.27 2926.55 -10.98 -6.24 5939067.26 675238.92 GYD-CT-CMS 3096.72 8.70 345.24 3095.43 3025.71 1.48 -9.27 5939079.66 675235.60 GYD-CT-CMS 3196.72 10.61 335.83 3194.02 3124.30 17.20 -14.97 5939095.24 675229.54 GYD-CT-CMS 3296.72 12.22 333.12 3292.04 3222.32 35.04 -23.52 5939112.87 675220.57 GYD-CT-CMS 3396.72 14.12 334.08 3389.40 3319.68 55.45 -33.64 5939133.04 675209.98 GYD-CT-CMS 3496.72 16.42 334.48 3485.86 3416.14 79.18 -45.06 5939156.50 675198.01 GYD-CT-CMS 3521.72 17.09 334.84 3509.80 3440.08 85.69 -48.14 5939162.94 675194.78 GYD-CT-CMS 3546.72 17.76 335.04 3533.66 3463.94 92.48 -51.32 5939169.64 675191.45 GYD-CT-CMS 3571.72 18.24 335.44 3557.43 3487.71 99.49 -54.55 5939176.58 675188.06 GYD-CT-CMS 3596.72 18.96 335.91 3581.13 3511.41 106.76 -57.83 5939183.77 675184.60 GYD-CT-CMS 3621.72 19.52 336.05 3604.73 3535.01 114.28 -61.19 5939191.21 675181.08 GYD-CT-CMS 3646.72 20.04 336.57 3628.25 3558.53 122.03 -64.59 5939198.88 675177.50 GYD-CT-CMS 3671.72 20.89 337.00 3651.68 3581.96 130.06 -68.03 5939206.83 675173.87 GYD-CT-CMS 3696.72 21.45 337.18 3674.99 3605.27 138.38 -71.55 5939215.06 675170.16 GYD-CT-CMS 3721.72 22.10 337.70 3698.21 3628.49 146.94 -75.10 5939223.54 675166.41 GYD-CT-CMS 3746.72 22.67 338.12 3721.32 3651.60 155.77 -78.68 5939232.27 675162.62 GYD-CT-CMS 3771.72 22.97 338.34 3744.36 3674.64 164.77 -82.28 5939241.19 675158.82 GYD-CT-CMS 3796.72 23.44 338.67 3767.34 3697.62 173.94 -85.89 5939250.27 675155.00 GYD-CT-CMS 3821.72 23.96 339.11 3790.23 3720.51 183.31 -89.51 5939259.56 675151.16 GYD-CT-CMS 3846.72 24.38 339.45 3813.04 3743.32 192.88 -93.13 5939269.05 675147.32 GYD-CT-CMS 3871.72 25.15 339.68 3835.74 3766.02 202.70 -96.78 5939278.77 675143.44 GYD-CT-CMS 3896.72 25.78 339.76 3858.31 3788.59 212.78 -100.51 5939288.76 675139.48 GYD-CT-CMS 3921.72 26.56 339.83 3880.75 3811.03 223.13 -104.32 5939299.02 675135.43 GYD-CT-CMS 3946.72 27.38 339.77 3903.03 3833.31 233.77 -108.23 5939309.56 675131.27 GYD-CT-CMS 3971.72 28.04 339.95 3925.16 3855.44 244.68 -112.24 5939320.38 675127.02 GYD-CT-CMS 3996.72 28.83 340.28 3947.15 3877.43 255.88 -116.28 5939331.48 675122.71 GYD-CT-CMS 4021.72 29.47 340.51 3968.98 3899.26 267.35 -120.37 5939342.85 675118.36 GYD-CT-CMS 4046.72 29.94 340.66 3990.70 3920.98 279.03 -124.49 5939354.44 675113.97 GYD-CT-CMS 4071.72 30.95 341.00 4012.25 3942.53 291.00 -128.65 5939366.30 675109.53 GYD•CT-CMS 4096.72 31.64 341.14 4033.61 3963.89 303.28 -132.86 5939378.48 675105.04 GYD-CT-CMS 4121.72 32.10 341.26 4054.84 3985.12 315.78 -137.11 5939390.87 675100.49 GYD-CT-CMS 4146.72 32.98 341.38 4075.92 4006.20 328.52 -141.42 5939403.51 675095.89 GYD-CT-CMS 4171.72 33.78 341.42 4096.79 4027.07 341.55 -145.81 5939416.44 675091.20 GYD-CT-CMS 4196.72 34.55 341.63 4117.48 4047.76 354.87 -150.26 5939429.65 675086.45 GYD-CT-CMS 4221.72 35.56 341.70 4137.94 4068.22 368.50 -154.77 5939443.17 675081.61 GYD-CT-CMS 4246.72 36.09 341.77 4158.21 4088.49 382.39 -159.36 5939456.95 675076.71 GYD-CT-CMS 4271.72 36.87 341.98 4178.32 4108.60 396.52 -163.98 5939470.96 675071.76 GYD-CT-CMS 4296.72 37.47 342,02 4198.24 4128.52 410.88 -168.65 5939485.22 675066.76 GYD-CT-CMS 4321.72 37.90 342.15 4218.02 4148.30 425.43 -173.35 5939499.64 675061.72 GYD-CT-CMS 4346.72 38.65 342.42 4237.65 4167.93 440.18 -178.06 5939514.28 675056.67 GYD-CT-CMS 4371.72 39.33 342.54 4257.08 4187.36 455.18 -182.80 5939529.17 675051.58 GYD-CT-CMS 4396.72 40.16 342.79 4276.30 4206.58 470.44 -187.56 5939544.31 675046.47 GYD-CT-CMS 4421.72 40.98 343.06 4295.29 4225.57 485.98 -192.33 5939559.74 675041.34 GYD-CT-CMS 4446.72 41.76 343.20 4314.05 4244.33 501.79 -197.13 5939575.43 675036.17 GYD-CT-CMS 4455.00 42.03 343.20 4320.22 4250.50 507.08 -198.73 5939580.68 675034.45 MWD+IFR+MS 4496.87 42.17 345.56 4351.28 4281.56 534.11 -206.28 5939607.53 675026.27 MWD+IFR+MS 4582.50 42.42 343.20 4414.63 4344.91 589.60 -221.80 5939662.64 675009.47 MWD+IFR+MS 4677.35 37.89 345.56 4487.11 4417.39 648.47 -238.32 5939721.10 674991.59 MWD+IFR+MS 4772.64 37.22 354.77 4562.71 4492.99 705.55 -248.25 5939777.93 674980.33 MWD+IFR+MS 4834.00 36.03 3.28 4611.99 4542.27 742.07 -248.91 5939814.43 674978.83 MWD+IFR+MS 4928.41 33.17 13.33 4689.75 .4620.03 794.98 -241.36 5939867.49 674985.15 MWD+IFR+MS ~' • • Sperry Drilling Services Survey Report Company: $P Amoco Date: 11/1'9/2007 Time: 16 :42:38 Page: 3 Feldc Pru dhoe Bay Co-ordinate(NE) Reference: Welf: 14-02, True North 'Site; PB DS`14 Vertica l (TVD) Reference: 41.22 +28.5; 69.7 Well: 14-02 Section (VS)13eference: Well ( O.OON,O.OOE,105.76Azi) Wellpath: 14-02C Survey Calculation Method:: Minim um Gurvatu re Db: Oracfe Survey MD Incl Azim TVD Sys TVD N/S E/W MapN ' MapE Viol ft deg deg ft ft ft ft ft ft 4960.45 31.90 16.06 4716.77 4647.05 811.64 -236.99 5939884.25 674989.12 MWD+IFR+MS 5054.14 31.36 17.85 4796.54 4726.82 858.64 -222.67 5939931.57 675002.34 MWD+IFR+MS 5149.93 29.63 22.54 4879.09 4809.37 904.24 -205.95 5939977.54 675018.00 MWD+IFR+MS 5244.74 29.95 29.69 4961.40 4891.68 946.46 -185.24 5940020.23 675037.72 MWD+IFR+MS 5340.55 29.89 35.37 5044.45 4974.73 986.72 -159.57 5940061.07 675062.45 MWD+IFR+MS 5434.33 29.13 43.53 5126.10 5056.38 1022.33 -130.31 5940097.35 675090.87 MWD+IFR+MS 5529.01 29.52 51.33 5208.68 5138.96 1053.63 -96.21 5940129.43 675124.23 MWD+IFR+MS 5631.78 30.72 56.51 5297.59 5227.87 1083.94 -54.55 5940160.70 675165.18 MWD+IFR+MS 5726.86 32.82 62.45 5378.44 5308.72 1109.27 -11.43 5940187.02 675207.69 MWD+IFR+MS 5819.66 33.06 70.37 5456.35 5386.63 1129.41 34.73 5940208.23 675253.37 MWD+IFR+MS 5914.25 35.91 77.59 5534.35 5464,63 1144.05 86.15 5940224.06 675304.43 MWD+IFR+MS 6007.29 38.04 83.40 5608.70 5538,98 1153.21 141.30 5940234.50 675359.35 MWD+IFR+MS 6103.41 41.93 88.24 5682.35 5612,63 1157.60 202.86 5940240.32 675420.78 MWD+IFR+MS 6198.29 45.18 93.76 5751.12 5681.40 1156.37 268.16 5940240.61 675486.09 MWD+IFR+MS 6293.09 48.15 97.87 5816.19 5746.47 1149.33 336.72 5940235.16 675554.79 MWD+IFR+MS 6386.59 48.98 102.83 5878.09 5808.37 1136.72 405.63 5940224.16 675623.97 MWD+IFR+MS 6481.52 50.91 108.23 5939.20 5869.48 1117.24 475.57 5940206.30 675694.35 MWD+IFR+MS 6576.24 54.75 109.68 5996.42 5926.70 1092.70 546.93 5940183.44 675766.25 MWD+IFR+MS 6669.94 54.75 109.81 6050.50 5980.78 1066.85 618.96 5940159.27 675838.85 MWD+IFR+MS 6764.69 53.97 110.07 6105.71 6035.99 1040.59 691.34 5940134.70 675911.82 MWD+IFR+MS 6860.03 54.57 108.69 6161.38 6091.66 1014.91 764.35 5940110.73 675985.40 MWD+IFR+MS 6955.28 54.50 105.70 6216.66 6146.94 991.98 838.45 5940089.53 676060.01 MWD+IFR+MS 7049.31 54.59 104.44 6271.20 6201.48 972.07 912.40 5940071.34 676134.40 MWD+IFR+MS 7143.80 53.96 106.08 6326.38 6256.66 951.88 986.40 5940052.88 676208.85 MWD+IFR+MS 7237.71 53.48 105.22 6381.95 6312.23 931.46 1059.30 5940034.16 676282.20 MWD+IFR+MS 7330.92 53.20 104.77 6437.60 6367.88 912.11 1131.53 5940016.50 676354.85 MWD+iFR+MS 7424.82 52.97 102.17 6494.00 6424.28 894.63 1204.52 5940000.71 676428.23 MWD+IFR+MS 7520.91 52.80 102.60 6551.99 6482.27 878.19 1279.37 5939986.02 676503.43 MWD+IFR+MS 7613.98 52.37 103.59 6608.53 6538.81 861.45 1351.36 5939970.96 676575.79 MWD+IFR+MS 7708.37 52.63 106.33 6666.00 6596.28 842.12 1423.70 5939953.31 676648.55 MWD+IFR+MS 7802.82 54.36 106.62 6722.19 6652.47 820.58 1496.50 5939933.48 676721.82 MWD+IFR+MS 7896.41 53.83 107.38 6777.07 6707.35 798.42 1568.99 5939913.01 676794.81 MWD+IFR+MS 7991.45 54.90 107.62 6832.45 6762.73 775.19 1642.66 5939891.50 676868.99 MWD+IFR+MS 8085.00 54.51 106.46 6886.50 6816.78 752.82 1715.66 5939870.83 676942.48 MWD+IFR+MS 8179.86 53.59 107.44 6942.19 6872.47 730.44 1789.11 5939850.16 677016.43 MWD+IFR+MS 8273.72 52.85 106.08 6998.39 6928.67 708.75 1861.09 5939830.16 677088.89 MWD+IFR+MS 8367.91 52.85 106.49 7055.27 6985.55 687.70 1933.15 5939810.79 677161.42 MWD+IFR+MS 8460.84 52.79 106.14 7111.43 7041.71 666.90 2004.21 5939791.65 677232.94 MWD+IFR+MS 8554.34 53.89 104.27 7167.26 7097.54 647.24 2076.59 5939773.68 677305.75 MWD+IFR+MS 8650.09 52.89 104.94 7224.36 7154.64 627.86 2150.96 5939756.04 677380.55 MWD+IFR+MS 8744.84 52.22 107.81 7281.97 7212.25 606.67 2223.13 5939736.53 677453.18 MWD+IFR+MS 8838.27 52.28 112.38 7339.19 7269.47 581.30 2292.47 5939712.78 677523.09 MWD+IFR+MS 8932.59 50.56 118.48 7398.04 7328.32 549.71 2359.02 5939682.74 677590.35 MWD+IFR+MS 9028.80 48.98 124.27 7460.21 7390.49 511.53 2421.70 5939646.04 677653.90 MWD+IFR+MS 9120.66 49.36 129.48 7520.29 7450.57 469.84 2477.26 5939605.65 677710.41 MWD+IFR+MS 9216.38 49.55 135.44 7582.55 7512.83 420.78 2530.88 5939557.85 677765.15 MWD+IFR+MS 9312.00 50.53 138.23 7643.97 7574.25 367.32 2581.00 5939505.58 677816.50 MWD+IFR+MS 9407.42 49.35 141.24 7705.39 7635.67 311.62 2628.20 5939450.99 677864.98 MWD+IFR+MS 9501.50 51.73 144.44 7765.18 7695.46 253.72 2672.04 5939394.13 677910.14 MWD+IFR+MS 9596.10 50.53 147.82 7824.56 7754.84 192.60 2713.09 5939333.98 677952.60 MWD+IFR+MS 9691.27 51.61 145.18 7884.37 7814.65 130.88 2753.95 5939273.23 677994.89 MWD+IFR+MS 9785.61 50.46 141.72 7943.70 7873.98 71.96 2797.61 5939215.35 678039.90 MWD+IFR+MS 9879.18 50.04 142.30 8003.53 7933.81 15.26 2841.89 5939159.70 678085.48 MWD+IFR+MS .~ ~ • Sperry Drilling Services Survey Report Companye BP Amoco Date: 11/19/2007 Time: 16:42-38. Page: 4 .Field: ' Pru dhoe Bay Co-ordinate(NE) Reference: Well: 14-02, True North Site: PB DS 14 Vertica l (TVI)) Reference: 41 .22+28.5; 69.7 Well: 14-02 Section (VS) Reference6 WeR (O.OON;O.OOE,105.76Azi) Wellpath: 14-02C Survey Calculation Method: Mi nimum Curvatu re Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN ~'IapE Tool ft ' deg deg ft h ft ft ft ft 9970.87 50.36 144.57 8062.23 7992.51 -41.31 2883.85 5939104.12 678128.74 MWD+IFR+MS 10065.99 51.00 145.78 8122.50 8052.78 -101.72 2925.87 5939044.71 678172.15 MWD+IFR+MS 10160.54 50.39 146.68 8182.40 8112.68 -162.53 2966.54 5938984.86 678214.22 MWD+IFR+MS 10253.25 51.56 145.76 8240.77 8171.05 -222.39 3006.59 5938925.95 678255.65 MWD+IFR+MS 10346.66 49.64 146.08 8300.06 8230.34 -282.17 3047.03 5938867.13 678297.47 MWD+IFR+MS 10440.01 49.72 144.60 8360.46 8290.74 -340.71 3087.51 5938809.55 678339.29 MWD+IFR+MS 10534.45 50.01 145.82 8421.34 8351.62 -400.01 3128.70 5938751.24 678381.85 MWD+IFR+MS 10628.47 48.49 146.27 8482.71 8412.99 -459.08 3168.49 5938693.10 678422.99 MWD+IFR+MS 10721.83 47.77 146.09 8545.02 8475.30 -516.84 3207.18 5938636.26 678463.02 MWD+IFR+MS 10816.86 48.13 145.89 8608.67 8538.95 -575.34 3246.65 5938578.71 678503.83 MWD+IFR+MS 10942.92 49.68 147.67 8691.53 8621.81 -654.81 3298.68 5938500.47 678557.69 MWD+IFR+MS 11023.28 58.56 146.83 8738.59 8668.87 -709.50 3333.89 5938446.61 678594.16 MWD+IFR+MS 11054.00 65.23 146.51 8753.05 8683.33 -732.13 3348.77 5938424.34 678609.56 MWD+IFR+MS 11085.11 71.56 144.69 8764.50 8694.78 -755.98 3365.11 5938400.88 678626.45 MWD+IFR+MS 11115.13 78.35 143.10 8772.29 8702.57 -779.38 3382.19 5938377.88 678644.07 MWD+IFR+MS 11146.14 85.07 144.22 8776.76 8707.04 -804.09 3400.36 5938353.61 678662.81 MWD+IFR+MS 11178.36 92.62 142.88 8777.41 8707.69 -829.98 3419.48 5938328.17 678682.53 MWD+IFR+MS 11208.36 100.02 144.69 8774.10 8704.38 -854.02 3437.09 5938304.55 678700.69 MWD+IFR+MS 11239.72 105.55 148.54 8767.17 8697.45 -879.53 3453.92 5938279.43 678718.10 MWD+IFR+MS 11270.99 102.11 146.08 8759.69 8689.97 -905.08 3470.32 5938254.28 678735.09 MWD+IFR+MS 11301.68 99.84 140.65 8753.84 8684.12 -929.24 3488.29 5938230.54 678753.62 MWD+IFR+MS 11361.93 98.99 142.12 8743.99 8674.27 -975.68 3525.38 5938184.98 678791.78 MWD+IFR+MS 11392.23 96.98 139.27 8739.78 8670.06 -998.89 3544.39 5938162.21 678811.32 MWD+IFR+MS 11423.87 95.87 136.50 8736.24 8666.52 -1022.21 3565.47 5938139.39 678832.94 MWD+IFR+MS 11455.04 96.86 140.28 8732.78 8663.06 -1045.37 3586.04 5938116.72 678854.04 MWD+IFR+MS 11485.83 98.61 141.59 8728.64 8658.92 -1069.06 3605.27 5938093.49 678873.81 MWD+IFR+MS 11517.01 96.37 140.62 8724.57 8654.85 -1093.12 3624.68 5938069.89 678893.77 MWD+lFR+MS 11548.88 93.64 139.20 8721.79 8652.07 -1117.40 3645.12 5938046.09 678914.77 MWD+IFR+MS 11579.15 92.96 136.14 8720.05 8650.33 -1139.74 3665.47 5938024.23 678935.63 MWD+IFR+MS 11611.70 91.91 132.67 8718.66 8648.94 -1162.49 3688.70 5938002.03 678959.38 MWD+IFR+MS 11643.20 90.80 128.45 8717.92 8648.20 -1182.96 3712.62 5937982.12 678983.77 MWD+IFR+MS 11673.56 90.12 125.38 8717.68 8647.96 -1201.19 3736.89 5937964.45 679008.45 MWD+IFR+MS 11705.52 88.52 122.14 8718.06 8648.34 -1218.95 3763.45 5937947.32 679035.42 MWD+IFR+MS 11736.68 87.59 119.55 8719.11 8649.39 -1234.92 3790.19 5937931.98 679062.52 MWD+IFR+MS 11767.00 87.90 115.78 8720.31 8650.59 -1248.98 3817.01 5937918.55 679089.66 MWD+IFR+MS 11798.00 88.09 114.34 8721.39 8651.67 -1262.10 3845.08 5937906.08 679118.02 MWD+IFR+MS 11828.72 89.26 112.46 8722.10 8652.38 -1274.30 3873.26 5937894.54 679146.48 MWD+IFR+MS 11860.54 89.32 106.18 8722.50 8652.78 -1284.82 3903.27 5937884.72 679176.73 MWD+IFR+MS 11890.98 87.34 104.89 8723.38 8653.66 -1292.97 3932.59 5937877.26 679206.22 MWD+IFR+MS 11921.35 87.22 104.67 8724.82 8655.10 -1300.71 3961.92 5937870.20 679235.72 MWD+IFR+MS 11952,12 88.40 104.12 8726.00 8656.28 -1308.35 3991.70 5937863.26 679265.67 MWD+IFR+MS 11995,62 89.44 103.93 8726.82 8657.10 -1318.89 4033.89 5937853.70 679308.10 MWD+IFR+MS 12015.02 89.44 103.98 8727.01 8657.29 -1323.57 4052.72 5937849.46 679327.03 MWD+IFR+MS 12045.16 89.44 104.36 8727.30 8657.58 -1330.95 4081.94 5937842.76 679356.41 MWD+IFR+MS 12076.84 90.56 103.99 8727.30 8657.58 -1338.71 4112.66 5937835.72 679387.29 MWD+IFR+MS 12107.42 90.68 103.58 8726.97 8657.25 -1345.99 4142.36 5937829.13 679417.15 MWD+IFR+MS 12138.94 90.99 103.75 8726.51 8656.79 -1353.44 4172.98 5937822.40 679447.94 MWD+IFR+MS 12171.04 91.11 103.82 8725.93 8656.21 -1361.08 4204.15 5937815.48 679479.28 MWD+IFR+MS 12202.38 91.92 104.20 8725.10 8655.38 -1368.67 4234.55 5937808.60 679509.84 MWD+IFR+MS 12231.55 92.41 104.43 8724.00 8654.28 -1375.88 4262.79 5937802.05 679538.24 MWD+IFR+MS 12323.78 94.45 104.99 8718.48 8648.76 -1399.25 4351.83 5937780:76 679627.80 MWD+IFR+MS 12417.08 95.51 103.79 8710.38 8640.66 -1422.35 4441.86 5937759.76 679718.33 MWD+IFR+MS i ' ~ ~ • Sperry Drilling Services Survey Report Company: BP Amoco Date: 11/l9/2007 Time: 16:42:38 Yage: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 14-02, True North Site: PB DS 14 Vertical (TVD) Reference: 41.22+28.5; 69.7 We11: 14-02 SecGon(VS) Reference: Well (O.OON,0.40E;105.76Azi) Wellpath: 14=02C Survey Calculation Method: Minimum Curvature. Db: Oracle Survey MD Incl Azm ft deg deg, 12509.62 91.98 101.73 12602.95 89.38 101.76 12635.30 88.95 102.10 12664.99 87.53 101.84 12695.44 88.15 101.45 12790.51 89.88 101.06 12849.45 90.25 101.76 12884.61 90.68 101.92 12977.81 92.72 101.96 13070.61 93.09 100.69 13132.35 93.15 99.49 13164.99 92.78 99.50 13258.26 91.54 98.72 13305.84 91.73 98.48 13350.21 91.23 98.07 13427.66 89.69 95.83 13462.86 89.75 96.18 13492.63 88.77 95.17 13521.29 88.33 96.38 13568.29 88.02 95.01 13614.91 89.38 97.03 13707.38 89.88 97.86 13798.19 89.07 97.55 13855.51 88.70 98.44 13912.00 88.70 98.44 TVl) SysTVD N/S ft ft fC 8704.33 8634.61 -1442.74 8703.23 8633.51 -1461.73 8703.70 8633.98 -1468.42 8704.61 8634.89 -1474.58 8705.76 8636.04 -1480.72 8707.39 8637.67 -1499.27 8707.32 8637.60 -1510.93 8707.04 8637.32 -1518.14 8704.27 8634.55 -1537.42 8699.57 8629.85 -1555.62 8696.21 8626.49 -1566.42 8694.52 8624.80 -1571.79 8691.01 8621.29 -1586.55 8689.65 8619.93 -1593.66 8688.50 8618.78 -1600.04 8687.88 8618.16 -1609.42 8688.05 8618.33 -1613.10 8688.44 8618.72 -1616.04 8689.16 8619.44 -1618.92 8690.66 8620.94 -1623.59 8691.72 8622.00 -1628.47 8692.32 8622.60 -1640.45 8693.15 8623.43 -1652.63 8694,26 8624.54 -1660.60 8695.54 8625.82 -1668.89 E/W MapN MapE Tool ft ft 'ft 4531.90 5937741.47 679808.82 MWD+IFR+MS 4623.27 5937724.60 679900.59 MWD+IFR+MS 4654.91 5937718.65 679932.38 MWD+IFR+MS 4683.94 5937713.18 679961.55 MWD+IFR+MS 4713.75 5937707.73 679991.48 MWD+IFR+MS 4806.97 5937691.35 680085.11 MWD+IFR+MS 4864.74 5937681.04 680143.13 MWD+IFR+MS 4899.16 5937674.63 680177.70 MWD+IFR+MS 4990.29 5937657.48 680269.25 MWD+IFR+MS 5081.17 5937641.40 680360.52 MWD+IFR+MS 5141.86 5937632.01 680421.45 MWD+IFR+MS 5174.01 5937627.38 680453.71 MWD+IFR+MS 5266.04 5937614.77 680546.05 MWD+IFR+MS 5313.06 5937608.75 680593.22 MWD+IFR+MS 5356.96 5937603.39 680637.25 MWD+IFR+MS 5433.83 5937595.81 680714.31 MWD+IFR+MS 5468.83 5937592.94 680749.39 MWD+IFR+MS 5498.46 5937590.69 680779.07 MWD+IFR+MS 5526.96 5937588.47 680807.64 MWD+IFR+MS 5573.70 5937584.90 680854.47 MWD+IFR+MS 5620.05 5937581.09 680900.92 MWD+IFR+MS 5711.74 5937571.24 680992.85 MWD+IFR+MS 5801.72 5937561.16 681083.09 MWD+IFR+MS 5858.47 5937554.51 .681140.01 MWD+IFR+MS 5914.34 5937547.53 681196.05 PROJECTED to TD Date 1 1-09-2007 Transmittal Number:92919 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: ~5-10C '3~'~° ~ c" l ,--~ -;. G2ZA _~?.0 T.- ~-.j'~.~Ym.~.'~ ~ 5~_~s~ P2 ~15}~I'B3__ a ~.~c _~~ ~ ~~~--~- .! u =~`~ ~ Please`Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 (/ FiT on i4-02C ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) ,.-- Sent: Wednesday, September 19, 2007 10:33 AM ~ ~ ~ ' , ` To: 'McVey, Adrienne' Subject: RE: FIT on 14-02C Adrienne, Thanks for the information. It appears that the leak off was only slightly less than you planned although this was a LOT rather than a FIT. The regulatory requirement at 20 AAC 25.030 (f) is to demonstrate [by FIT or LOT] that the integrity of the casing shoe is sufficient to contain wellbore pressures ... (to allow drilling to the next casing point]. Call or message with any questions. Good luck with the forward operations. Tom Maunder, PE AOGCC From: McVey, Adrienne [mailto:Adrienne.McVey@bp.com] Sent: Wednesday, September 19, 2007 10:12 AM To: Maunder, Thomas E (DOA) Subject: FIT on 14-02C Tom, I'm the drilling engineer for PBU 14-02C (Permit No. 207-115). We planned a 12.6 FIT. We performed the test at 4320' TVD (4455' MD), but got leakoff at 680 psi, which equates to a 12.53 ppg LOT. Our planned maximum mud weight for this hole section is 11.6 ppg. Please call with any questions. Thanks, Adrienne McVey GPB Rotary Drilling 907-564-4184 (office) 907-748-9865 (cell) adrienne. mcvey@bp.com 9/i 9/2007 i • o Q ~ ~ ~ SARAH rALIN, GOVERNOR ~~ OI~ ~D a7rta 333 W 7 h AVEN a C011TSIriRQATIOI~T COA'II~iI5SIOIQ . t UE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PMONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-02C BP Exploration Alaska, Inc. Permit No: 207-115 Surface Location: 1262' FNL, 1228' FEL, SEC. 09, T10N, R14E, UM Bottomhole Location: 2935' FNL, 4536' FWL, SEC. 10, T10N, R14E, UM Dear Mr. Hobbs: 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 y. required test, contact the Commission's petroleum field inspector at (9 ) 65j9-3607 (pager). n~K. Norm2 C it DATED this da st, 2007 cc: Department of ish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK,-, IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1c. Specify if well is proposed~ehOtB~B ^ Coalbed Methane ^ Gas Hydrate ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 14-02C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13758 TVD 8684 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1262' FNL 1228' FEL SEC T10N R14E 09 UM 7. Property Designation: ADL 028312 Pool , , , . , , Top of Productive Horizon: 1962' FNL, 2100' FWL, SEC. 10, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 31, 2007 Total Depth: 2935' FNL, 4536' FWL, SEC. 10, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 17,900' 4b. Location of Well (State Base Plane Coordinates): Surface: x-675245 y-5939078 Zone-ASP4 10. KB Elevation Plan (Height above GL): 67.6 feet 15. Distance to Nearest Well Within Pool: 325' 16. Deviated Wells: Kickoff Depth: 4500 feet Maximum Hole An le: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3215 Surface: 2344 18. Casin "Pr ram: cificatio ns To - Se irr De th - Bo om uantit of Cement c.f. or sa k Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 12-1/4" 9-5/8" 47# L-80 TC-II 1961' Surface Surface 2000' 2000' 672 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-M 6649' 4350' 4248' 10999' 8708' 697 sx LiteCrete 91 sx Class'G' 6-1l8" 4-1/2" 12. L-80 IBT 2904' 1 4 ' 629' 1375 ' 8684' n ment Slott d Lin r 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11755 Total Depth TVD (ft): 9129 Plugs (measured): 11422 Effective Depth MD (ft): 11576 Effective Depth TVD (ft): 9012 Junk (measured): None asing Length Size Cement Volume MD TVD Conductor /Structural 120' 20" 675 sx Arcticset I I 120' 120' Surface 2732' 13-3/8" 5904 sx Permafrost II 2732' 2732' Intermediate 9366' 9-5/8" 1000 sx Class'G' 9366' 7760' Pr c ion Liner 2543' 7" 445 sx Class 'G' 9072' - 11615' 7549' - 9037' Perforation Depth MD (ft): 11494' - 11576' Perforation Depth TVD (ft): 8960' - 9012' 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 fore in is tfue and correct. Contact Ron Phillips, 564-5913 Printed Name Greg Hobb Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~ ~ Phone 564-4191 Date ~ e ~' : '~ Terrie Hubble, 56a-4628 Commission Use Onl Permit To Drill Number: o~~ O API Number: 50-029-20318-03-00 Permit Appr v Irk Date: ~ 1 See cover letter for other re uirements Conditions of Approva-: If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: ~.,/ ~~(''~ ~' T? ~ ~ ~~~ Samples Req'd: ^ Yes 1~ No Mud Log Req'd: ^ Yes L+7 No ~..! (~, 17~J HZS Measures: ~Y No rectional Survey Req'd: Yes ^ No Other: APP VED BY THE COMMISSION Date ~ Q ,COMMISSIONER ,~: , ~3~ ~'t~',a `~ I ~J~7 ~~I~~ka Jil & Gas Cons. ~SSIQf Form 10-401 Revised 1212005 r / ~~ ~"~~ Submit In Duplicate ('1f11ne~~ ~ , v Well Name: 14-02C Planned Well Summary Horz. Well 14-02C ~ Type Sidetrack Objective Sag River Producer FE Number PBD4P2623 API Number: 50-029-20318-03 Surface Northin Eastin Offsets TRS Location 5,939,079 675,245 4,018' FSL / 4,052 FWL 10N, 14E, 9 Target Northin Eastin TVD Offsets TRS Location 5,938,457 678,590 -8,708 3,317' FSL / 2,100'FWL 10N, 14E, 10 Bottom Northin Eastin TVD Offsets TRS Location 5,937,543 681,050 -8,684 2,345' FSL / 4,536' FWL 10N, 14E, 10 Planned TD: 13,758 MD / 8,684' TVD S ud Date: 8/31/07 Ri Nabors 2ES Directional - Sperry wP-o7 BFE: 39.1' RKB: 67.6' Maximum Hole An le: 92.7° in the tanned horizontal roduction section Close Approach Wells: All wells except the 15-23A pass major risk close approach criteria. The center to center distance is 325'. Both the 15-23A and the 14-02B have very poor tool codes, so re-gyroing both should clear up the close approach issues. Surve Pro ram: MWD Standard / IFR / MS Nearest Pro ert Line: 17,900 to the Unit bounda to the South Nearest Well within Pool: 13-23A is 325' awa from tanned well in horizontal roduction section. 14-02C Drilling Program Page 2 • • Formation Markers 14-02C (Based on Dir wp-07) Estimated Formation To s Estimated Pore Press. Formation TVDss (TVD rkb ~ 67.6 MD rkb 67.6 (ppg EMW / Psi UG4 4387 4455 4630 UG3 4573 4641 4865 UG1 5237 5305 5633 WS2 5758 5826 6287 WS1 6051 6119 6757 CM3 6269 6337 7129 CM2 6701 6769 7866 CM1 7289 7357 8865 THRZ 7765 7833 9609 BHRZ 7918 7986 9847 TKNG 7958 8026 9910 LCU 8396 8464 10592 TJB 8469 8537 10706 TJA 8564 8632 10859 TSGR 8640 8708 10999 7.07 / 3200 TSHU 8666 8734 11056 7.05 / 3200 Casing/Tubing Program Hole Size Csg / Tbg O.D. Wt/Ft Grade Conn Length Top MD /TVD rkb Bottom MD / TVDrkb 12-1/4" 9-5/8" 47# L-80 TC-II 1961' Surface 2000' / 2000' 8-1 /2" 7" 26# L-80 BTC-M 6649' 4350' / 4248' 10999' / 8708' 6-1/8" 4-1/2" 12.6# L-80 IBT slotted LNR 2904' 10849' / 8629' 13753' / 8684' Tubing 4-1/2" 12.6# 13CR-80 Vam Top 10810' Surface 10849' / 8629' Mud Program Hole Section /operation: Mill window in the 9-5/8" casing to 200' prior to THRZ 9409 M D T e Densit PV YP MBT API FL H LSND 9.2 - 9.6 15-25 22-30 <15 5-7 9 - 10 Hole Section / o eration: 200' rior to THRZ 9409' MD to Int. TD 10,999' MD T e Densit PV YP MBT API FL H LSND 11.6 15-22 26-30 <15 4-6 9 - 10 Hole Section / o eration: Drillin 6-'/a" roduction hole to TD 13,753' MD T e Densit PV YP LSRV API FL H MBT Flo-Pro SF 8.4-8.5 8 - 12 22 - 28 >20,000 6 - 8 9.0 - 9.5 <3 Logging Program Hole Section: Required Sensors /Service 9-5/8" C&P: USIT/GR run to find TOC for cut and ull and condition of cs down to KOP 8-1/2" intermediate: MWD Dir/GR/Res/PWD and near bit amma ra 6-1/4" roduction: MWD Dir/GR/Res/ABI/Az Dens/Neu/Stratasteer and near bit amma 14-02C Drilling Permit Page 3 • • Cement Program Casin Strin 9-5/8", 47#, L-80, TC-II Cut and ull Slurry Design Basis: Tail slurry: 2,000' of 9-5/8" x 13-3/8" annulus up to surface with 0% excess. Mud Push II: 30 bbls at 11.8 pp Tail Slur : Slurry Type 15.8 pp Class `G' liner slurry ry Mix method Batch mix Slur Volume 140 bbls /786 cf / 672 sx Class `G'/ 15.8 / 1.17 cf/sk. Casin Strin 7", 26#, L-80, BTC-M Drillin liner Slurry Design Basis: Tail slurry: 1,000' of 7" x 8-1/2" annulus with 40% excess, plus ~86' of 7", 26#, shoe tract. Tail TOC C~ 9,999' MD. Lead Slurry: 5,649' of 7" x 8-1/2" annulus with 40% excess. Lead TOC to --4,350' MD, at 7" x 9-5/8" liner han er. Mud Push II: 30 bbls at 11.8 L d Sl Slur T e 12.0 Lite Crete slur ea urry: Mix method Batch Mix Slur Volume 201 bbl / 1129 cf / 697 sx Litecrete/ 12.0 / 1.62 cf/sk Tail Slur : Slur T e 15.8 Class `G' liner slur ry Mix method Batch mix Slur Volume 19 bbls / 106 cf / 91 sx Class `G'/ 15.8 / 1.17 cf/sk. Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. Wells 14-01 and 14-03 are the closest wells at 119 to the North and South respectively. Close Approach Shut-in Wells: All wells pass major risk close approach criteria except 13-23A which is an Ivishak injector 325' ctr-ctr away in the horizontal production zone. The well 13-23A should pass major anti-collision after both ,walls 13-23A and 14-02B are re-gyroed. The 13-23A well will be shut in when we drill the 14-02C production zone past this close approach interval. They both currently have poor tool codes with huge error ellipses. Hydrogen Sulfide DS 14 is designated an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Date of Well Name H2S Level Readino #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) 14-01 No Data 14-03 50 m 2/13/06 13-23A In'ector No Data 14-26 30 m 8/31 /05 14-07 300 m 4/12/07 14-06,14-07,14-22,14-31, 14-37 and 14-41 all have H2S readings between 100 and 300ppm 14-02C Drilling Permit Page 4 • Faults A tight drilling polygon should keep us out of the seismically mapped faults. There is only one planned fault crossing at 12,900' MD with an estimated throw of 10-20' West. A number of faults are located in the near vicinity of the proposed well. The coordinates for these faults will be provided in the directional plan details. The risk of fault and fracture associated lost circulation is considered low. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams, blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: Well Interval: 8-1/2" intermediate interval to TSGR Maximum antici ated BHP: 3,215 si at 8,707' tvd Maximum surface ressure: 2,344 si based u on BHP and a full column of as from TD ~ 0.10 si/ft Calculated kick tolerance: 159 bbls with 12.6 EMW FIT Planned BOPE test ressure: 250 si low / 3,500 si hi h -14 da test c cle Drillin o erations Well Interval: 6-1/8" horizontal roduction interval in Sa River Maximum antici ated BHP: 3,206 si at 8,684' tvd. Maximum surface pressure: 2,338 pSl (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.0 EMW FIT Planned BOPE test ressure: 250 si low / 3,500 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.8 seawater / 7.1 Diesel BOPE and drilling fluid system schematics are currently on file with the AOGCC. Dis osal Annular No annular injection in this well. In~ection: Cuttings Cuttings generated from drilling operations are to be hauled to the Grind and Inject Handlin station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for Handlin injection. All Class I wastes are to be hauled to Pad 3 for dis osal. 14-02C Drilling Permit Page 5 • C Dr~g Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control The cretaceous in this area is over pressured to 9.5 ppg. This section of the well will start at a 9.2 ppg .and weight up to 11.6 ppg prior to drilling the HRZ and Kingak shales. The Sag River in this fault block is expected to be under-pressured at 7.1 ppg EMW. This pressure is estimated based on offset well pressures. This well section will be drilled with 8.5 ppg mud in the reservoir section. There is a drilling hard line 50' past TD that can not be crossed or there is a good chance of crossing into the Kingak. II. Lost Circulation/Breathing The risk of fault- and fracture-associated lost circulation is considered low. Statasteer geosteering will be used to minimize the risk of drilling out of zone. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 159 bbls with 11.6 ppg mud, 12.6 ppg FIT, and an 8.4 ppg pore pressure at the top of the Sag River. This FIT should prove up adequate formation strength for expected ECD's. B. The Kick Tolerance for the production hole section is infinite with 8.5 ppg mud, 10.0 ppg FIT, and an 7.1 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. C. Integrity Testing Test Point Test De th Test e EMW Ib/ al 9-5/8" KOP 20-ft from the 9-5/8" KOP FIT 12.6 minimum 7" shoe 20-ft from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. Stuck pipe in the Kingak has been a problem on DS 14. At 146 degrees AZI and 60 degrees Inc an 11.6 ppg mud should prevent Kingak stability problems. VI. Hydrogen Sulfide DS 14 is designated as an H2S site since 14-06,14-07,14-22,14-31, 14-37 and 14-41 all have H2S readings between 100 and 300ppm. Standard Operating Procedures for H2S precautions should be followed at all times. VII. Faults A tight drilling polygon should keep us out of the mapped faults. There is only one planned fault crossing at 12,900' MD with an estimated throw of 10-20' West. VIII. Anti-Collision Issues All wells should pass major anti-collision close approach criteria after 13-23A and 14-02B are re-gyroed. The 13-23A well is 325' ctr-ctr at 12,392' planned MD. 14-02C Drilling Permit Page 6 • • 14-02C Operations Summary Pre-Riq Operations: 1. Replace all live gas lift valves with dummy valves and fluid pack as necessary for CT P&A. 2. Remove tubing tail plug from 11,405'. 3. RIH with slick line and drift the tbg to 7,500' MD, below the proposed cutting depth. 4. RIH with coil tubing and P&A the 14-02B well bore (215 deg F and 3286psi at TD). Lay in ~40 bbls of 15.8 ppg cement, leaving TOC in the 4-1/2" tbg at 9,500' MD. Cement volume calculated on the following parameters: Cement Calculations: 11,576'- 11,435' 7"LNR, 29#, 13-CR-80, 0.0371 bpf ~ 5.24 bbls 11, 435' - 9, 500' 4-1 /2" tbg, 12.6#, 13-CR-80, 0.0152 bpf 29.45 bbls Total cement 40 bbls, including 5 bbls for squeezing. 5. RU E-line and RIH. Cut the 4-1/2" 13 CR-80 tbg at 7,000' MD with an appropriate jet cutter. 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' MD with diesel. 7. Function all lock down screws, repair or replace as needed. 8. CMIT TxIA to 3500psi, MIT OA to 2000psi, PPPOT (T and IC) needed within 45 days of drilling rig moving on well. 9. Bleed casing and annulus pressures to zero. 10. Set a BPV in the tubing hanger. Secure the well. 11. Remove the well house, level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MI / RU Nabors rig 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Set and test TWC from above and below. 3. Nipple down tree and adaptor. Nipple up and test BOPE 250psi low and 3,500 psi high. Pull TWC. 4. Rig up, back out tockdown screws, pull hanger. 5. Pull and lay down 4-1 /2" tubing from the cut at 7,000'. (the deeper cut is to recover Cr tbg) 6. MU/PU mill assembly. RIH to -6,900' picking up drill pipe, and circulate the well bore. 7. RU e-line, run USIT. Corrosion and cement mode from 5,000' to surface. 8. Determine the depth of the 9-5/8" cut based on USIT interpretation (2,000). 9. RIH with HES 9 5/8" EZSV bridge plug on E-line and set at --4,522' md, as required to avoid cutting a casing collar while milling the window. POH. R/D E-line. 10. String shot 9 s/8" casing at back off point (2,000' or where USIT indicates TOC) to ease break out. RD a-line. 11. Change out to 9 5/e" rams, and test rams. 12. RU a Baker 9 5/e" cutting assembly. RIH picking up DP. Cut the 9 5/a" casing per Baker representative instructions. Cut ~4' above the string shot casing collar. POOH, VD assembly. 13. BOLDS, RU casing spear assembly, and unseat the 9 5/8". Circulate the Arctic Pack from the annulus with warm diesel followed by seawater and detergent sweeps. Pull the 9 5/8" casing from the cut. 14. RU wash over assembly, and 13 3/" casing scraper. 15. RIH, clean out the 13 3/" casing, and the 9 5/e" casing stub, POOH, L/D the assembly. 16. RU BKR back-off assembly, RIH, and back off the 9-5/8" casing joint. POOH, UD assembly. 17. RU casing spear assembly, RIH, recover cut stub. POOH. ~O~-~ 18. RU 9 5/8" HES ES Cementer on screw in sub and RIH w/ new 9-5/8", TC-II casing. 19. Install spool, Nipple up BOPE, and test. 20. Shear open ES cementer and cement 9 5/8" x 13'/" annulus to surface. 21. PU 4" DP and mill tooth bit. Make clean out run through the ES Cementer. 22. Pressure-test the 9 5/" casing to 3,500 psi for 30 minutes. Record test. 23. Change BOP rams back to VBR's and test rams. 24. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on EZSV bridge plug. Shear off of whip stock. 25. Dis lace the well to 9.2 LSND based millin fluid. i 26. Mill window in 9-5/8" casing at ± 4,500 MD, plus approximately 20' from mid window. Circulate well "6tL bore clean. 14-02C Drilling Permit Page 7 ~ ~ 27. Pull up into 9 5/8" casing and conduct an FIT to 12.6 ppg EMW. POOH. (Mud wt. should be weight up to 11.6 ppg before drilling to HRZ) 28. M/U 8-1/2" Dir/GR/RES/PWD assembly. 29. RIH to window. Drill ahead per directional plan to the 7" casing point at 10,999'. 30. Circulate the well bore clean. Short trip, circulate the well bore. POOH, UD assembly. 31. Change out to 7" rams and test. 32. RU / MU 166 joints of 7" liner. 33. RIH to bottom on drill pipe, circulate and condition the hole. 34. Cement the entire 7" liner through the 8-1/2" hole and back 150' into the 9-5/8" casing at 4,350'. Set the hanger and packer. Displace cement with mud. 35. Circulate bottoms up, POOH. UD liner running tool. 36. As a Contingency (No money in AFE for Scab liner): a. Scab liner will be run, if USIT results show leaks, or pitting in below the 13-3/8" shoe. b. Run 7" scab liner up to the 13 3/8" shoe or where USIT show appropriate. c. Sting in and establish seal. P/U to expose ports. d. Cement the entire length of the 7" scab liner, bury the seal. 37. Change out to variable rams and test. 38. Pick up drill pipe and stand back. 39. MU 6-1/8" cleanout assembly with DIR/GR/RES and an insert bit. 40. RIH to 7" liner landing collar. Test for 30 minutes, and record. Drill out of the cement and float equipment to shoe. 41. Displace to 8.5 ppg Flo Pro drilling fluid. 42. Drill out of the 7" shoe plus 20' of new formation. Pull up into the shoe and conduct FIT to 10.0 ppg mud EMW. 43. Drill 373' to the landing in the Sag River formation at 11,372' MD. 44. CBU, POOH for 6-1/8" horizontal BHA with a PDC bit, and GR/Res/Azimuth density. Strata steer processing will also be utilized through this section. 45. RIH to the bottom, drill ahead 2,381' to planned TD at 13,758'. 46. CBU, Short trip, circulate and condition the hole for running the 4 1/2" slotted liner. POOH, UD excess drill pipe. Clear the floor of unnecessary equipment. 47. RU, MU 2,253' of 4 1/2" slotted liner plus 651' of blank 4 1/2" 12.6#, L-80, IBT-M liner for overlap into the 7" liner. 48. RIH to shoe, circulate string. RIH to bottom, circulate and condition the hole. 49. Release, set packer, circulate bottoms up. 50. POOH. UD liner running tool. 51. RU, test BOPE if needed. 52. Test casing and liner. 53. R/U 10,849' of 4-1/2" 13CR, Vam Top completion tubing. 54. RIH, space and land the completion tubing into the 4-1/2" liner top, Run in lock down screws . 55. Reverse circulate to seawater and corrosion inhibitor. 56. Drop ball and Rod, set packer. 57. Test tubing and annulus separately to 3500 psi each, record the test. 58. Install and test TWC. 59. Nipple down BOPE. 60. Nipple up tree and adaptor flange, test tree to 5,000 psi. Pull TWC. 61. Reverse in diesel freeze protect to -2,200' U-tube. Install BPV. 62. Secure well. Release rig. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Perform static pressure survey. 3. Install we11 house and instrumentation. 14-02C Drilling Permit Page 8 TREE _. GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 68' BF. ELEV = KOP = 3195' Max Angle = __ 59 @ 9974' Datum MD = 11348'. batum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" ~ 14-02B Minimum ID = 3.725" @ 11422' 4-1/2" HES XN NIPPLE TOP OF 7" LNR 9-5/8" CSG, 47#, N-80, ID = 8.681" I-I 9366' PERFORATION SUMMARY REF LOG: BRCS ON 01/16/94 ANGLE AT TOP PERF: 53 @ 11348' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11348 - 11352 S 01 /23/94 3-3/8" 4 11494 - 11510 C 02/17/00 3-318" 4 11515 - 11521 C 11 /25/99 3-3/8" 4 11526 - 11532 C 11 /25/99 3-3/8" 4 11556 - 11576 C 02/04/94 4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" I--I 11435' PBTD I-I 11576' 7" LNR, 29#, 13-CR/L-80, .0371 bpf, ID = 6.184" TD SAFETY NOTES: CHROME 4-1 /2" TBG & 7" LNR 2216' I-I 4-1/2" CAM TRDP4A SC, ID = 3.813" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 3235 3232 12 MMGM RK 2 6026 5442 46 MMGM RK 3 7875 6711 47 MMGM RK 4 8777 7338 45 MMGM RK 5 9007 7501 44 MMGM RK 9-5/8" MILLOUT WINDOW @ 9366 I 4-1/2" HES X NIP, ID = 3.81" I 10594' 7" X 4-1/2" BKR SABL-3 PKR W/4-1/2" BKR KBH-22 ANCR SEAL ASSY 11385' 7" X 4-1/2" BKR SABL-3 PKR W/4-1/2" BKR ANCHOR SEAL ASSY 11405' 4-1/2" HES X NIP, ID = 3.81" 11422' 4-1/2" HES XN NIP, ID = 3.725" 11422' 4-1/2" PXN TTP (07/16/06) 11435' 4-1/2" WLEG 11428' ELMD TT LOGGED (02/30/94) DATE REV BY COMMENTS DATE REV BY COMMENTS 11178 ORIGINAL COMPLETION 01/27/94 LAST WORKOVER 06/28/02 JB/KAK TRSV CORRECTION 05/31/06 DTM WELLHEAD CORRECTION 07/16/06 CJWPJC SET PXN TTP PRUDHOE BAY UNIT WELL: 14-028 PERMff No: 1932000 API No: 50-029-20318-02 SEC 9, T10N, R14E, 1556.49' FEL & 593.53' FNL BP Exploration (Alaska) 14-02C Proposed 2,000 HES ES Cementer 2,732 13-3/8",728, N-80, ID=12.347" 4,350 9-5/8" X T' Baker LNR hanger 4,500- 9-5/8" window 4,519 4,522 EZSV GBP 7,000 4117' Tubing cut 9,500 Top of Cement 10,775 4117', 'X' Landing Nipple, ID=3.813" 10,795 7" X 41/7'Baker S-3 PKR 10,815 41/7"X' Landing Nipple, ID=3.813" 10,835 41/2",'XN' Landing Nipple, ID=3.725" 10,849 41/2",12.8#, CR-80 TBG 10,849 T' X 41/2" Baker LNR hanger 10,999 T',268, L-80 LNR W~LHEAD = GRAY ACTIWTOR = AXEtSON KB. ELEV = 68' BF. E1EV KOP = 4500' Max Angle = 37 Q 11172' Datum MD = Datum TVD = 8800' SS ~ 41/7',12.8#, sbtted IBT LNR ~~ DATE REV BY COMMENTS DATE REV BY COMMENTS 11/78 ORIGINAL COMPLETION 01/27/94 LAST WORItOV62 02/02/02 RNITP CORRECTIONS 06/28/02 JB/KAK TRSV CORRECTION 05/31/06 DTM WELLHEADCORR6CTION 07/18/07 RLP Updated BP 6cploration (Alaska) SAFETY NOTES: CHROME4-112"TBG PRUDHOE BAY UNIT WELL: 14028 PERMIT No: 1932000 API No: 50-029-20318-OZ SEC 9, T10N, R14E, 1556.49' FEL 8593.53' FNL COMPANY DETAILS REFERENCE INFORMATION BP Amino 1 ('o-ordinate IN E) Refenncc Well Centre: H-02. True Nonh tU Venical(TVD)Reference ~:U2 I.&1994 W:0067.MI I<ulation Mahal: Minimum Cunaturc Section (VS)Rcfarcncc Slut-U2 (U.UUN.O.UUE) Errur Svstem: ISCK'SA :1lcasureJ Depth Reference: i : U2 I•% 1994 UU:UU 67bU Scan Methud: Tr v C'vlinder Nonh Calculation Method: Minimum Cunaturc Enor Surface Elliptical ~ C'using TARGET DETAILS Name TVD +Ni-S +E;-W Northing Eastine Shape Id-026pu1}' 8673.6(1 -537.94 3(163.611 1938612A0 67832(100 Polygon I4-02B TS 8681.60 -1590.01 5364.91 >937613.77 68(1645A3 Point I4-112B T9 8683.60 -1671101 5768.47 5937543.18 681010.'_8 Point 14-U2B T7 869161) -1$511.01 11119.13 5937641.7_' 680398.40 Paint 14-026 T1 8702611 -698.86 3331100 5938457.32 678190.05 Point 14-U2B T6 8713.60 -149(1(1(1 4112 28 59;7694.85 679830.31 Point 14-028 T3 Rce I 87''3.60 -10110.110 3533A0 19381610(1 678799.99 Paint 14-028 T3 Rcv 2 8722.60 -1042.00 3164.00 5938119.73 678831.95 Point 14-028 T4 Rev I 8722.60 -1390.1111 3927.73 593788(1.27 679301.33 Point 14-1I3B TS Rcv I 8722.6(1 -1420.1111 4288.47 5937758.70 679164.96 Point 14-1128 T4 872260 -1290.011 3927.73 5937880.27 679201.32 Point W-112B"f5 8727.60 -14211.1111 4288.47 5937758.70 679164.96 Poinl 14-1126 "f3 8733.611 - I I1111L(IU 3533.(1(1 5938161.110 678799 ~)9 Point c L Q CASING DETAILS No. TVD MD Name Size I 8707.60 10999. 23 7" 7A110 2 8683. 58 13753. 0(1 41/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 4454.60 4630.46 UG4 2 4640.60 4864.54 UG3 3 >304.60 5633.39 UG I q 5835.60 6386.98 W S3 5 6118.60 6757.12 WSI 6 6336.60 7129.11 C'M3 7 6768.60 7866.27 C'M'_ S 7356.60 8863.>7 C'M I 9 7833.60 9608.77 THRL. 10 7985.60 9847.31 61182 11 8025.60 990951 TKNG 12 8463.00 1(159^_.11 LCU 13 8536.60 10705 92 TJB 14 863161) 10858.90 TJA IS 8707.60 10999.23 TSGR 16 8733.60 11056.37 "fSHU SURVEY PROGRAM Fm Depth To Survey: Plan Tool Plan: 14-03C' wpU7 (W-(12.PIan 14-02C) (/ 13717.7? Planned: I4-U2(' wp07 V44 M~\'D~ IFR ~ MS C'rcatcd By: Sperry Drilling Date: Ri I!20U7 R'ELL DETAILS Name ~N.-S ~E.-N' Noshing Easting Latitude Longitude Slut IJ-U2 -524.06 10%270 593907%.55 675'_44.93 7U"1421.191N I4%"35'U5215W 02 Scc MD Inc Azi TVD +N;-S +E;-W DLcg TFatt VScc Target I 45tIU.00 43.11 34117 4317.72 139.71 -21W." 11.00 1100 -346.21 2 452000 43.37 344.61 437229 112.81 -208.24 12.00 85.011 -313.76 3 6173.09 14.1'_ 105.94 6010.75 110142 137.18 4.110 131.65 209.70 4 8679A4 14.12 105.94 7245.45 632.11 2178.67 0.110 0.(10 1916.84 5 9469.79 5(1.0(1 146.110 7743A2 281.00 2668.00 4.011 109.77 2483.51 6 9473.30 50,(18 146.07 7745.03 283.411 2669.07 4All 33.10 2484.98 7 1075133 SU.llB 146.07 8565.74 -530.57 3216.63 Q(IU 0.00 323729 8 111999_'3 60.(10 146.011 8707.60 -698.86 3331100 4.U(I -0.36 3393.00 14-028 TI 9 1101923 60.00 146A0 8717.60 -713.23 3339.69 1101( 0.110 34116.29 10 11169.19 95,99 145.62 874828 -832.55 3430]9 24.00 -0.64 3517.38 II 11397.53 95.99 145.62 8724.46 -1019.97 3549,113 11.1111 0.00 3692.68 12 11424.24 92.00 146.(10 8722.60 -1042.110 3564.00 I S.UII 174.54 3713.19 14-036 T3 Rcv 2 13 11(,116.61 89.47 118.76 8720.22 -1163.74 3697.44 15.011 -95,04 3875.22 14 11853.81 89.47 118.76 8722.53 -1282.66 3914.14 ILUII 0.00 4116.44 IS 11869.25 911.00 118A(I 8722.60 -1290.110 3927.73 6.00 -54.79 413154 14-02B T4 Rcv I 16 12045.15 8>.47 IU7.46 8723.42 -1357.87 41189.73 6.011 -92.89 43U6A2 17 12164.43 89.47 107.46 8724.52 -1393.66 42113.51 11.00 0.00 4425_'6 18 12253A1 93.(111 IOZ00 8722.60 -1420.00 4388.47 4.00 -7.41 451420 14-026 TS Rc. I 19 13294.05 9144 107.45 872103 -1432.03 4327.26 4.110 163.80 4554.80 2U 12338.98 91 A4 107.41 8719.90 -1445511 4370.111 0.110 O.OU 4599.70 21 12526.75 92.411 101100 8713.60 -1490.00 4552 2R 4.00 -82.53 4787.07 14-026 T6 22 12598.45 92.73 97.15 8710.39 -1500.68 4623.09 4.UU -83.39 4858.06 23 12964.115 92.73 97.15 8693.00 -046.12 4985.44 110(1 (100 5218.75 24 12997.99 92.110 96.00 8691611 -1550.111 5019.13 4.00 -122.34 5252.19 14-02BT7 25 12999.84 91.94 96A4 8691.54 -1550211 5021197 4.00 149A4 5254.01 26 13241.45 91.94 96.04 8683.37 -1575.6(1 5261.111 0.00 0.00 5491.73 27 13346.33 90.00 99.76 8681.60 -1590.(11 >364.95 4A0 117.45 5595.49 14-02B T8 2R 13385.17 89.71 101.29 8681.70 -1597.10 1403.13 4.00 100.85 5634.14 29 13757.72 89.71 101 29 8683.60 -1670.111 5768A7 0.00 0.00 6005.34 14-02B T9 HALLIBURTON la - - ~ ~ CMI ~ rt Dn4'~I 0 10751.33' MD. 8565.7 '"fVD ~ ~ ~' - ~ Start Dir X47/IOII' .11019 23' MD, IZ6TVD I ', 000. I End DI :10999 23' MD. 8707 6' VD _ ~ ' ~1 % ~ ' End v I 1169.19' MD, 8748 8' TVD ' rt Dir 11?1100' : 11397.53 MU, R724.46'l'VD ) Sa ' '~ ~ - - ~~ -- ~ ~ ~ I / ' End Dir : 116(16.61' M .8730.22' TVD ~ ~ - ~ I I - - - ~ J ' ~ ~ I %~ I ~ Start Dtr 6'?'1 W' . I 1853.81' MD, 8722.53'7 D ' ~ I - - -- /. i End Dir : 12 45.15' MD, 8723.42' "fVD . '_t.l. ~ TKN(i - - - - - '- .Start Dir •',rl(N)' :12164.43' MD, 8 4.52'TVD I ~ ~~.. I I I 10000 i ~ End it :12'_94.05' MD, 872 Lll ' TVU :. 1, I ~ ~ ~ ~~ ' ~ i / I ," Sw Dir 4:'i IOII' :12338.98 ), 8719,9'TVD :. ~~ ~ / ! j % End Dir : 12598.45' M .8710.39' TVD ---{ ~' lCT ~ ~~ ~ / ~ Sdart D 4'?, 1110' ~ 13241 45' MD, 683.3TTVD ~- ' - ~ a - Total Ucpth :1375 73' MD, 8683.6' TVD ~30p0 "~'~ - -Plan 14-(12C' T` 00 ~ o °oee 1_000 ~41i2" 14-02Cwp07 Stan Dir 42~ 100' : 2964.05' MD R693'TVD End Dir 12999.84' MD, 8691.54' 'D I End Dir : 13385.17 M , 8681.7 TVD 1000 '_(IOU 30110 4000 5000 6000 71100 Vertical Section at IU6.15' ~ IIIIIIAL inJ C OMPANY DETAILS REFERENCE INFORMATION BP Amaeo -urJinate IN. E) Rekrence: Well ('r-nrre: 1-t-U2, True Nunh r Vcnical ITVD) Reference: 5: OZ Ir8 1994 W:W 6260 CulculaGun AlethoJ: Minimum Cunamre Section l\'S)Rclcrence: Slur-02 IO.WNA.WE) Ertor Svsrem: IS('WSA MeusureJ Depth Reference: _5:02 L%:1994 W:W 6260 Sean M1lethuJ: Trav ('ylinJcr Nunh (':dculation McthoJ: Minimum Cunature Error Surface Elliptical ~ ('acing \1'arning McthuJ: Rules BascJ HALLIBURTON Sperry Grilling Bervicas I8I SU FORMATION TOP DETAILS No. TVDPath MDPath Funn:Jiun 1 4451.60 4630.46 UG4 2 4640.611 4864.54 UG3 ~ 3 5304.60 5633.39 UGI 4 5835.60 628698 W'S_ S 6118.60 6757.12 WSI 6 6336.60 7129.11 CM3 7 6768.60 7866.27 CM2 8 7356.60 886457 CMI 9 7832.60 9608.77 THRZ IU 7985.60 981731 BHRZ Il 8025.60 990955 TKNG 12 8463.60 10592.15 LCU 13 8536.60 111705.92 TJB 14 8631.60 111858.9(1 T1A 15 8707.60 10999.23 TSGR 16 8733.60 111116.17 TSHU ' ~ ~ '4 SE('TION DETAILS Sec MD Inc Azi TVD i N.-S i Ei-W DLcg TFace VSec Target I 15W.W 43.11 141.17 4357.72 539.71 -?0422 UAU UAU -316.25 45ZOAO 43.37 344.65 4372.29 552ri1 -20834 IZ.00 85.00 -353.76 3 6573.09 54.12 105.94 6010.75 110142 537.18 4UU 135.65 209.70 4 8679.94 54.12 105.94 7245.15 632.55 2178.67 0.W O.UO 1916.84 5 9469.79 SQ.UO 11600 7743.42 2ri5A0 2668.00 4.00 109.77 2483.51 6 917_'30 SQUB 116.117 7741.(13 ?83.40 2669.07 4.00 33.10 2481.98 7 1075133 50.Uri 146.07 x161.74 -530.57 3216.63 0.00 0.00 3237.29 8 10999.'_3 60.00 146.00 8702(0 -h98.8(r 333U.W 4.00 -0.36 3393.W I4(12B TI 9 11019.'3 60.00 146.011 %71260 -713.22 3339.69 OAO 0.00 3406.29 IU 11169.19 95.94 14162 874ri.28 -832.55 3420.79 24(10 -U.G4 3517.38 11 11397.53 95.99 115.62 %7?1.16 -IU 19.97 3549.03 O.UO O.W 3692.68 12 1142421 92.00 116.00 8732.60 -1042.W 356•f.W IS_OU 171.54 3713.19 14-028 T3 Roc2 13 11606.61 89.17 IIR.76 8720_'2 -1163.74 3697.44 ISAO -95.04 3875.22 14 11853.81 %9.47 II8.7h %72?.53 -I28Z(rh 3914.14 0.00 0.W 1116.14 U II%6935 90.00 II%011 %722.6(1 -I?AQW 3927.73 6.00 -54.79 413154 Il-02B T1 Rcv I 16 13011.15 89.17 107.16 8723.12 -1357.ri7 40%9.73 6.W -92.89 1306.02 17 I?161.13 %9.17 IU7.16 %721.5? -1393.66 4207.51 O.W O.W 1125.26 IR 12'_53.11 93A0 IU7.lNl %T_2.6U -142U.W 428RA7 4.00 -7.11 1514.20 14-0_'B TS Rcv I 19 12291.05 9111 107.45 %721.03 -1432.03 132736 1.00 Ih3.%U 4551.80 20 1233%.98 91.14 IOZ45 8719.90 -141550 4370.10 0.00 O.W 4599.70 21 1'526.75 92.10 IW.W %713.60 -149U.W 4552?8 4.00 -8253 4787.07 14-026 T6 ~2 1259x.15 92.73 97.11 ri71U.39 -I SIN/.firi 1623.09 1.00 -83.39 485S.W 23 I_"161.15 92.73 9215 8693.IN1 -1516.12 19%5.44 0.00 ILW 5218.75 21 12947.99 92.00 9h.W rih9 LhU -155U.uI iU 19.13 4W -122.34 S?52.19 14-02B T7 2i 1_'999.%1 9191 96.01 %1,91.51 -1550.20 5020.97 1.UU 119.11 5251.01 26 1321115 9191 96.W %fi8337 -1575.60 i2h 1.10 0.00 QW 5491.73 27 13316.33 90.00 99.76 x681.60 -1590.01 53(+1.95 4.OU I17A5 ;195.49 14-026 T8 28 13385.17 89.71 IUI.29 rib%1.70 -1597.10 5103.13 400 IW.85 5631.11 39 13757.7? 8991 IUI39 %683.60 -1670.01 5768.47 U.W O.W 600534 U-02B T9 SURVEY PROGRAM Drprh Fin Depth Tu Sun-ep Plan foul Plan: 14-02C wp07 (14-0L Plan 14-020 1 1i00.ou 11757.72 I'IanncJ: W-U2('rcp117 V14 AIND~IFR'MS CrcatcJ By: SIx:m Dulling Data: %~ I;2007 HELL DETAILS - - Name ~N~-S iE~-W Northing Fasting LatituJe LungituJe Slot .. _ _ I1-02 -524.06 108_'.70 5939078.55 h75214Y3 7U"14'21.191N 148'35'U5355N' UZ TARGET DETAILS _ Name TVD +N.'-S +E~-W Northing Fasting Shape ~ ~~ 14-026 poly 8673.611 -5.17.94 3063.60 5938612.00 678320.0(1 Polygon '~ "''' '~ ~ I4-U'_B T8 8681.60 -1590.0 1 5364.95 5937613.77 6811645.03 Point ' - - - ~ 14-026 T9 8683.60 -1670.0 1 5768A7 5937543.18 68105(128 Point + ~ I4-(128 T7 869160 -1550.11 1 SU 19.13 5937645.72 680298A0 Point 14-028 TI 870260 -698.86 3330.011 5938457.3? 6785911.115 Point 14-026"f6 8713.60 -1490.00 4552.28 5937694.85 6798311.31 Point 14-02B T3 Rev I 8722.60 -11)00.00 3533.00 5938161.1)0 678799.99 Point '. - 14036 T3 Rcv 3 8722.60 -1042.00 3564.011 59381 19.73 67883 I AS Point 14-UZB T4 Rev 1 8723.60 -1290.00 3927.73 5937880.27 679201.32 Point 14(126 T5 Rcv l 8722.60 -142(1.011 4288.47 5937758.70 67956496 Point 14-(126 T4 872260 -1290.00 3927.73 593788(1.27 679201.32 Point - ~ ~ ~ - 14-026 T5 8727.60 -1420.00 4288.47 5937758,70 679564.96 Point - ~ ~ I 14-1128 T3 8733.60 -1000.18) 3533.00 5938161.00 678799A9 Point ' ' ~ ~ ~ - ~ - - ~ - ~ ~ - CASING DETAILS 1.75' VU No. TVD MD Name . ~ I 8702611 10999 23 7" . 2 8683.58 13753 AU 4112" Start Dir4?/ U0 OU' :8679:94" MD; 7245.4 'TVD VD PTV 7500 End Uir : 9472.3 ' MD, 7 45.03' TVD - ~I ~ ! - + I 800 ~ ~ - - - St Uir 43'100 ': 111751.33'-M ,856 5.74'TVD I .,_~ . , - ~ , ~ l4-(126 T3 Rev 1 I-t-U26'f3 Ret j I 141 i S[a Dir4:'/IUO': 123 - - End Dir : l2 t 2721 3628 1535 544'_ 6350 Siu 7.0(10 4.5110 Trl • S err -Sun P Y BP Planning Report Company: BP Amoco Date: 8/1/2007 Time: 13:37:15 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 1402, True North Site: PB DS 14 Vertical (TVD) Reference: 5:02 1/8/1994 00:00 67 ,6 Well: 14-02 Section (VS) Reference: Well (O.OON,O.OOE,106.1 5Azi) Wellpath: Plan 14-02C Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 14-02C wp07 Date Composed: 5/5/2006 Version: 44 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 14 TR-10-14 UNITED STATES :North Slope Site Position: Northing: 5939577.43 ft Latitude: 70 14 26.346 N From: Map Easting: 674150.48 ft Longitude: 148 35 36.726 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergenc e: 1.32 deg Well: 14-02 Slot Name: 02 14-02 Well Position: +N/-S -524.06 ft Northing: 5939078.55 ft Latitude: 70 14 21.191 N +E/-W 1082.70 ft Easting : 675244.93 ft Longitude: 148 35 5.255 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 10999.23 8707.60 7.000 8.500 7" 13753.00 8683.58 4.500 6.750 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 SV1 0.00 0.00 4630.46 4454.60 UG4 0.00 0.00 4864.54 4640.60 UG3 0.00 0.00 5633.39 5304.60 UG1 0.00 0.00 6286.98 5825.60 WS2 0.00 0.00 6757.12 6118.60 WS1 0.00 0.00 7129.11 6336.60 CM3 0.00 0.00 7866.27 6768.60 CM2 0.00 0.00 8864.57 7356.60 CM1 0.00 0.00 9608.77 7832.60 THRZ 0.00 0.00 9847.21 7985.60 BHRZ 0.00 0.00 9909.55 8025.60 TKNG 0.00 0.00 10592.15 8463.60 LCU 0.00 0.00 10705.92 8536.60 TJB 0.00 0.00 10858.90 8631.60 TJA 0.00 0.00 10999.23 8707.60 TSGR 0.00 0.00 11056.37 8733.60 TSHU 0.00 0.00 Targets Map Map <--- Latitude ----> <--- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 14-026 poly 8673.60 -537.94 3063.60 5938612.00 678320.00 70 14 15.894 N 148 33 36.212 W -Polygon 1 8673.60 -537.94 3063.60 5938612.00 678320.00 70 14 15.894 N 148 33 36.212 W -Polygon 2 8673.60 -1679.19 3746.30 5937487.00 679029.00 70 14 4.667 N 148 33 16.386 W -Polygon 3 8673.60 -1975.10 4469.67 5937208.00 679759.00 70 14 1.753 N 148 32 55.370 W -Polygon 4 8673.60 -1970.03 5025.97 5937226.00 680315.00 70 14 1.799 N 148 32 39.204 W -Polygon 5 8673.60 -2139.92 5363.13 5937064.00 680656.00 70 14 0.126 N 148 32 29.410 W -Polygon 6 8673.60 -2087.40 5943.55 5937130.00 681235.00 70 14 0.638 N 148 32 12.542 W -Polygon 7 8673.60 -1028.55 5578.04 5938180.00 680845.00 70 14 11.055 N 148 32 23.141 W -Polygon 8 8673.60 -1206.05 4349.50 5937974.00 679621.00 70 14 9.317 N 148 32 58.849 W S err -Sun P Y BP Planning Report Company:. BP AmOCO Date: 8/1/2007 Time: 13:37:15 Pager Z Field: PrudhoeBay Co-ordinate(NE) Reference: WeIL 14-02, True North Site: PB DS 14 Vertical (TVD) Reference: 5:02 1!8/1994 00:00 67.6 Well: 14-02 Section (VS) Reference: Well (O.OON,O.OOE,106:15Azi} Wellpath: Plan 14-02C Survey Calculation Method: Minimum Curvature. Dhr Oracle Targets Map Map <_-- Latitude --> <-- Longitude ---~ Name Description TVD +N/-S +E/-W Northing Fasting Deg Miu Sec Deg Min Sec Dip. Dir. ft ft ft ft ft -Polygon 9 8673.60 -1061.01 4091.79 5938113.00 679360.00 70 14 10.745 N 148 33 6.336 W -Polygon 10 8673.60 -560.58 3693.28 5938604.00 678950.00 70 14 15.669 N 148 33 17.911 W -Polygon 11 8673.60 -537.94 3063.60 5938612.00 678320.00 70 14 15.894 N 148 33 36.212 W 14-02B T8 8681.60 -1590.01 5364.95 5937613.77 680645.03 70 14 5.534 N 148 32 29.346 W 14-026 T9 8683.60 -1670.01 5768.47 5937543.18 681050.28 70 14 4.745 N 148 32 17.621 W 14-02B T7 8691.60 -1550.01 5019.13 5937645.72 680298.40 70 14 5.930 N 148 32 39.394 W 14-02B T1 8707.60 -698.86 3330.00 5938457.32 678590.05 70 14 14.310 N 148 33 28.471 W 14-026 T6 8713.60 -1490.00 4552.28 5937694.85 679830.31 70 14 6.523 N 148 32 52.961 W 14-026 T3 Rev 1 8722.60 -1000.00 3533.00 5938161.00 678799.99 70 14 11.348 N 148 33 22.575 W 14-026 T3 Rev 2 8722.60 -1042.00 3564.00 5938119.73 678831.95 70 14 10.934 N 148 33 21.675 W 14-026 T4 Rev 1 8722.60 -1290.00 3927.73 5937880.27 679201.32 70 14 8.494 N 148 33 11.108 W 14-026 T5 Rev 1 8722.60 -1420.00 4288.47 5937758.70 679564.96 70 14 7.213 N 148 33 0.626 W 14-026 T4 8727.60 -1290.00 3927.73 5937880.27 679201.32 70 14 8.494 N 148 33 11.108 W 14-02B T5 8727.60 -1420.00 4288.47 5937758.70 679564.96 70 14 7.213 N 148 33 0.626 W 14-026 T3 8733.60 -1000.00 3533.00 5938161.00 678799.99 70 14 11.348 N 148 33 22.575 W Plan Section Information MD Incl Atim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft ..deg 4500.00 43.11 341.17 4357.72 539.71 -204.22 0.00 0.00 0.00 0.00 4520.00 43.37 344.65 4372.29 552.81 -208.24 12.00 1.31 17.41 85.00 6573.09 54.12 105.94 6010.75 1101.42 537.18 4.00 0.52 5.91 135.65 8679.94 54.12 105.94 7245.45 632.55 2178.67 0.00 0.00 0.00 0.00 9469.79 50.00 146.00 7743.42 285.00 2668.00 4.00 -0.52 5.07 109.77 9472.30 50.08 146.07 7745.03 283.40 2669.07 4.00 3.35 2.85 33.10 10751.33 50.08 146.07 8565.74 -530.57 3216.63 0.00 0.00 0.00 0.00 10999.23 60.00 146.00 8707.60 -698.86 3330.00 4.00 4.00 -0.03 -0.36 14-026 T1 11019.23 60.00 146.00 8717.60 -713.22 3339.69 0.00 0.00 0.00 0.00 11169.19 95.99 145.62 8748.28 -832.55 3420.79 24.00 24.00 -0.25 -0.64 11397.53 95.99 145.62 8724.46 -1019.97 3549.03 0.00 0.00 0.00 0.00 11424.24 92.00 146.00 8722.60 -1042.00 3564.00 15.00 -14.93 1.43 174.54 14-026 T3 Rev 2 11606.61 89.47 118.76 8720.22 -1163.74 3697.44 15.00 -1.39 -14.94 -95.04 11853.81 89.47 118.76 8722.53 -1282.66 3914.14 0.00 0.00 0.00 0.00 11869.25 90.00 118.00 8722.60 -1290.00 3927.73 6.00 3.46 -4.90 -54.79 14-028 T4 Rev 1 12045.15 89.47 107.46 8723.42 -1357.87 4089.73 6.00 -0.30 -5.99 -92.89 12164.43 89.47 107.46 8724.52 -1393.66 4203.51 0.00 0.00 0.00 0.00 12253.41 93.00 107.00 8722.60 -1420.00 4288.47 4.00 3.97 -0.52 -7.41 14-026 T5 Rev 1 12294.05 91.44 107.45 8721.03 -1432.03 4327.26 4.00 -3.84 1.12 163.80 12338.98 91.44 107.45 8719.90 -1445.50 4370.10 0.00 0.00 0.00 0.00 12526.75 92.40 100.00 8713.60 -1490.00 4552.28 4.00 0.51 -3.97 -82.53 14-026 T6 12598.45 92.73 97.15 8710.39 -1500.68 4623.09 4.00 0.46 -3.98 -83.39 12964.05 92.73 97.15 8693.00 -1546.12 4985.44 0.00 0.00 0.00 0.00 12997.99 92.00 96.00 8691.60 -1550.01 5019.13 4.00 -2.14 -3.38 -122.34 14-026 T7 12999.84 91.94 96.04 8691.54 -1550.20 5020.97 4.00 -3.44 2.03 149.44 13241.45 91.94 96.04 8683.37 -1575.60 5261.10 0.00 0.00 0.00 0.00 13346.33 90.00 99.76 8681.60 -1590.01 5364.95 4.00 -1.85 3.55 117.45 14-02B T8 13385.17 89.71 101.29 8681.70 -1597.10 5403.13 4.00 -0.75 3.93 100.85 13757.72 89.71 101.29 8683.60 -1670.01 5768.47 0.00 0.00 0.00 0.00 14-026 T9 S er -Sun P rY BP Planning Report Company: BP Amoco Date: 8/1!2007 Time: 13:37:15 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 14-02, True North Site: PB DS 14 Vertical (TVD) Reference:. .5:02 1/8/1994 00:00 67.6 Well: 14-02 Section (VS) Reference: Well (O.OON,O.OOE,106.15Azi), Wellpath: Plan 14-02C Survey Calculation Method: Minimum Curvature Dh: Oracle Survey MD ft 4500.00 4520.00 4600.00 4630.46 4700.00 4800.00 4864.54 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5633.39 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6286.98 6300.00 6400.00 6500.00 6573.09 6600.00 6700.00 6757.12 6800.00 6900.00 7000.00 7100.00 7129.11 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7866.27 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8679.94 8700.00 Inc! deg Azim deg TVD ft Sys TVD ft VS ft N/S ft E/W ft DLS deg/100ft MapN ft 43.11 341.17 4357 .72 4290.12 -346 .25 539.71 -204. 22 0.00 5939613. 34 43.37 344.65 4372 .29 4304.69 -353 .76 552.81 -208. 24 12.00 5939626. 33 41.13 348.05 4431 .51 4363.91 -380 .51 605.05 -220. 97 4.00 5939678. 26 40.30 349.43 4454 .60 4387.00 -389 .65 624.53 -224. 85 4.00 5939697. 64 38.49 352.74 4508 .35 4440.75 X08 .36 668.11 -231. 71 4.00 5939741. 05 36.05 357.99 4587 .94 4520.34 -429 .90 728.41 -236. 67 4.00 5939801. 22 34.61 1.70 4640 .60 4573.00 -440 .39 765.72 -236. 80 4.00 5939838 .51 33.87 3.85 4669 .91 4602.31 -445 .01 785.65 -235. 84 4.00 5939858. 45 32.00 10.36 4753. 86 4686.26 -453 .62 839.54 -229. 20 4.00 5939912. 48 30.50 17.51 4839. 38 4771.78 -455 .69 889.83 -216. 80 4.00 5939963. 04 29.42 25.23 4926. 05 4858.45 -451 .21 936.27 -198. 69 4.00 5940009. 89 28.81 33.36 5013 .44 4945.84 -440 .20 978.64 -174. 96 4.00 5940052. 79 28.71 41.67 5101. 14 5033.54 -422 .72 1016.72 -145. 73 4.00 5940091. 54 29.11 49.91 5188. 72 5121.12 -398 .84 1050.34 -111. 14 4.00 5940125. 95 29.99 57.82 5275 .74 5208.14 -368 .69 1079.32 -71. 36 4.00 5940155. 85 30.39 60.36 5304 .60 5237.00 -357 .25 1087.94 -56. 96 4.00 5940164. 81 31.33 65.23 5361 .79 5294.19 -332 .41 1103.54 -26. 58 4.00 5940181. 10 33.05 72.01 5446 .45 5378.85 -290 .18 1122.86 22. 98 4.00 5940201. 57 35.10 78.14 5529 .30 5461.70 -242 .21 1137.20 77. 07 4.00 5940217. 16 37.44 83.63 5609 .94 5542.34 -188 .72 1146.48 135. 44 4.00 5940227. 80 40.00 88.55 5687 .97 5620.37 -129 .99 1150.67 197. 80 4.00 5940233. 43 42.74 92.95 5763 .03 5695.43 -66 .29 1149.73 263. 84 4.00 5940234. 03 45.26 96.42 5825 .60 5758.00 -7 .08 1144.76 324. 04 4.00 5940230. 46 45.64 96.91 5834 .73 5767.13 2 .07 1143.68 333. 25 4.00 5940229. 59 48.67 100.48 5902 .74 5835.14 74 .74 1132.55 405. 69 4.00 5940220. 15 51.79 103.74 5966 .72 5899.12 151 .39 1116.38 480. 80 4.00 5940205. 73 54.12 105.94 6010 .75 5943.15 209 .70 1101.42 537. 18 4.00 5940192. 09 54.12 105.94 6026 .52 5958.92 231 .50 1095.43 558. 14 0.00 5940186. 59 54.12 105.94 6085 .12 6017.52 312 .53 1073.18 636. 06 0.00 5940166. 15 54.12 105.94 6118 .60 6051.00 358 .82 1060.47 680. 56 0.00 5940154. 48 54.12 105.94 6143 .73 6076.13 393 .56 1050.93 713. 97 0.00 5940145 .72 54.12 105.94 6202 .33 6134.73 474 .59 1028.67 791. 88 0.00 5940125. 28 54.12 105.94 6260. 93 6193.33 555 .61 1006.42 869. 79 0.00 5940104 .84 54.12 105.94 6319. 54 6251.94 636 .64 984.16 947. 71 0.00 5940084. 41 54.12 105.94 6336. 60 6269.00 660 .23 977.68 970. 39 0.00 5940078. 46 54.12 105.94 6378. 14 6310.54 717 .67 961.91 1025. 62 0.00 5940063. 97 54.12 105.94 6436. 75 6369.15 798 .70 939.65 1103. 53 0.00 5940043. 54 54.12 105.94 6495. 35 6427.75 879 .73 917.40 1181. 44 0.00 5940023. 10 54.12 105.94 6553. 95 6486.35 960 .75 895.14 1259. 35 0.00 5940002. 66 54.12 105.94 6612. 56 6544.96 1041 .78 872.89 1337. 27 0.00 5939982. 23 54.12 105.94 6671. 16 6603.56 1122 .81 850.63 1415. 18 0.00 5939961. 79 54.12 105.94 6729. 77 6662.17 1203 .84 828.38 1493. 09 0.00 5939941. 35 54.12 105.94 6768. 60 6701.00 1257 .53 813.63 1544. 72 0.00 5939927. 81 54.12 105.94 6788. 37 6720.77 1284 .86 806.12 1571. 00 0.00 5939920. 92 54.12 105.94 6846. 97 6779.37 1365 .89 783.87 1648. 92 0.00 5939900. 48 54.12 105.94 6905. 58 6837.98 1446 .92 761.61 1726. 83 0.00 5939880. 04 54.12 105.94 6964. 18 6896.58 1527 .95 739.36 1804. 74 0.00 5939859. 61 54.12 105.94 7022. 78 6955.18 1608 .98 717.10 1882. 65 0.00 5939839. 17 54.12 105.94 7081. 39 7013.79 1690 .00 694.85 1960. 56 0.00 5939818. 73 54.12 105.94 7139. 99 7072.39 1771 .03 672.59 2038. 48 0.00 5939798. 30 54.12 105.94 7198. 60 7131.00 1852 .06 650.34 2116. 39 0.00 5939777. 86 54.12 105.94 7245 .45 7177.85 1916 .84 632.55 2178. 67 0.00 5939761. 52 53.86 106.88 7257 .24 7189.64 1933 .06 627.96 2194. 24 4.00 5939757. 30 MapE TooUC ft 675028.23 Start Dir ' 675023.90 Start Dir 675009.97 MWD+IFI 675005.64 UG4 674997.77 MWD+IFI 674991.40 MWD+IFI 674990.41 UG3 674990.91 MWD+IFI 674996.29 MWD+IFI 675007.52 MWD+IF''~ 675024.55 MWD+IFI 675047.28 MWD+IFI 675075.61 MWD+IFI 675109.41 MWD+IFI 675148.50 MWD+IFI 675162.70 UG1 675192.70 MWD+IFI 675241.80 MWD+IFI 675295.54 MWD+IFI 675353.67 MWD+IFI 675415.91 MWD+IFI 675481.96 MWD+IFI 675542.25 WS2 675551.49 MWD+IFI 675624.16 MWD+IFI 675699.62 MWD+IFI 675756.33 End Dir 675777.42 MWD+IFI 675855.83 MWD+IFI 675900.61 WS1 675934.23 MWD+IFI 676012.63 MWD+IFI 676091.04 MWD+IFI 676169.44 MWD+IFI 676192.27 CM3 676247.84 MWD+IFI 676326.25 MWD+IFI 676404.65 MWD+IFI 676483.05 MWD+IFI 676561.46 MWD+IFI 676639.86 MWD+IFI 676718.26 MWD+IFI 676770.22 CM2 676796.67 MWD+IFI 676875.07 MWD+IFI 676953.47 MWD+IFI 677031.88 MWD+IFI 677110.28 MWD+IFI 677188.68 MWD+IFI 677267.09 MWD+IFI 677345.49 MWD+IFI 677408.17 Start Dir 677423.83 MWD+IFI S err -Sun P Y BP Planning Report Company: BP Amoco Date: 8/1/2007 Time: 13`.37:15 Page: 4 Field: Prudhoe Bay Co-ordiuate(NE) Reference: Well: 14-02, True North Site: PB DS 14 Vertical (TVD) Reference: 5:02.1/8/1994 00:00 67.6 Well: 14-02 Section(VS)Reference: Well (O.OON,O.OOE,106.15Azi) Wellpath: Plan 14-02C Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft 8800.00 8864.57 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 9469.79 9472.30 9500.00 9600.00 9608.77 9700.00 9800.00 9847.21 9900.00 9909.55 10000.00 10100.00 10200.00 10300.00 10400.00 10500.00 10592.15 10600.00 10700.00 10705.92 10751.33 10800.00 10858.90 10900.00 10933.79 10999.23 11000.00 11019.23 11029.62 11040.97 11056.37 11100.00 11169.19 11172.44 11200.00 11219.55 11300.00 11397.53 11400.00 11424.24 11500.00 11600.00 11606.61 11633.96 Incl .deg Azim deg TVD ft Sys TVD ft VS ft N/S ft E/W ft DLS deg/100ft MapN ft 52 .63 111.63 7317.10 7249 .50 2013 .02 601 .58 2269 .85 4.00 5939732.69 51 .95 114.78 7356.60 7289 .00 2063 .70 581 .47 2316 .78 4.00 5939713.67 51 .60 116.53 7378.53 7310 .93 2091 .15 569 .42 2341 .88 4.00 5939702.21 50 .79 121.55 7441.22 7373 .62 2167 .08 531 .63 2409 .98 4.00 5939666.02 50 .19 126.68 7504.86 7437 .26 2240 .42 488 .40 2473 .82 4.00 5939624.28 49 .82 131.88 7569.16 7501 .56 2310 .83 439 .93 2533 .08 4.00 5939577.21 49 .69 137.12 7633.80 7566 .20 2377 .96 386 .47 2587 .49 4.00 5939525.03 49 .79 142.36 7698.45 7630 .85 2441 .48 328 .27 2636 .77 4.00 5939468.00 50 .00 146.00 7743.42 7675 .82 2483 .51 285 .00 2668 .00 4.00 5939425.47 50 .08 146.07 7745.03 7677 .43 2484 .98 283 .40 2669 .07 4.00 5939423.90 50 .08 146.07 7762.81 7695 .21 2501 .28 265 .77 2680 .93 0.00 5939406.55 50 .08 146.07 7826.97 7759 .37 2560 .10 202 .13 2723 .74 0.00 5939343.92 50 .08 146.07 7832.60 7765 .00 2565 .26 196 .55 2727 .50 0.00 5939338.43 50 .08 146.07 7891.14 7823 .54 2618 .92 138 .50 2766 .55 0.00 5939281.30 50 .08 146.07 7955.30 7887 .70 2677 .74 74 .86 2809 .36 0.00 5939218.68 50 .08 146.07 7985.60 7918 .00 2705 .51 44 .81 2829. 58 0.00 5939189.11 50 .08 146.07 8019.47 7951 .87 2736 .55 11 .22 2852 .17 0.00 5939156.06 50 .08 146.07 8025.60 7958 .00 2742 .17 5 .14 2856. 26 0.00 5939150.07 50 .08 146.07 8083.64 8016 .04 2795 .37 -52 .42 2894. 98 0.00 5939093.43 50 .08 146.07 8147.80 8080 .20 2854 .19 -116 .06 2937. 79 0.00 5939030.81 50 .08 146.07 8211.97 8144 .37 2913 .01 -179 .70 2980. 60 0.00 5938968.19 50 .08 146.07 8276.14 8208 .54 2971 .83 -243 .34 3023. 41 0.00 5938905.56 50 .08 146.07 8340.30 8272 .70 3030 .65 -306 .98 3066. 22 0.00 5938842.94 50 .08 146.07 8404.47 8336 .87 3089 .47 -370 .62 3109. 03 0.00 5938780.32 50 .08 146.07 8463.60 8396 .00 3143 .67 -429 .27 3148. 49 0.00 5938722.61 50 .08 146.07 8468.63 8401 .03 3148 .29 -434 .26 3151. 84 0.00 5938717.69 50 .08 146.07 8532.80 8465 .20 3207 .10 -497 .90 3194. 65 0.00 5938655.07 50 .08 146.07 8536.60 8469 .00 3210 .59 -501 .67 3197. 19 0.00 5938651.36 50 .08 146.07 8565.74 8498 .14 3237 .29 -530 .57 3216. 63 0.00 5938622.93 52 .03 146.06 8596.33 8528 .73 3266 .33 -561 .97 3237. 76 4.00 5938592.02 54 .39 146.04 8631.60 8564 .00 3302 .51 -601 .10 3264. 10 4.00 5938553.52 56. 03 146.03 8655.05 8587 .45 3328 .41 -629 .09 3282. 96 4.00 5938525.98 57. 38 146.02 8673.60 8606 .00 3350 .09 -652 .51 3298. 75 4.00 5938502.93 60. 00 146.00 8707.60 8640 .00 3393 .00 -698 .86 3330. 00 4.00 5938457.32 60. 00 146.00 8707.99 8640 .39 3393 .51 -699 .41 3330. 37 0.00 5938456.78 60. 00 146.00 8717.60 8650 .00 3406 .29 -713 .22 3339. 69 0.00 5938443.19 62. 49 145.97 8722.60 8655 .00 3413. 29 -720 .77 3344. 78 24.00 5938435.76 65. 22 145.94 8727.60 8660. 00 3421. 12 -729 .21 3350. 49 24.00 5938427.46 68. 91 145.89 8733.60 8666. 00 3432. 02 -740 .96 3358. 44 24.00 5938415.90 79. 38 145.78 8745.50 8677. 90 3464. 26 -775 .63 3381. 97 24.00 5938381.78 95. 99 145.62 8748.28 8680. 68 3517. 38 -832 .55 3420. 79 24.00 5938325.79 95. 99 145.62 8747.94 8680. 34 3519. 88 -835 .21 3422. 62 0.00 5938323.17 95. 99 145.62 8745.07 8677. 47 3541. 04 -857 .83 3438. 10 0.00 5938300.91 95. 99 145.62 8743.03 8675. 43 3556. 04 -873 .88 3449. 07 0.00 5938285.13 95. 99 145.62 8734.64 8667. 04 3617. 81 -939 .91 3494. 26 0.00 5938220.17 95. 99 145.62 8724.46 8656. 86 3692. 68 -1019 .97 3549. 03 0.00 5938141.41 95. 62 145.65 8724.21 8656. 61 3694. 58 -1022 .00 3550. 42 15.00 5938139.42 92. 00 146.00 8722.60 8655. 00 3713. 19 -1042. 00 3564. 00 15.00 5938119.73 90. 97 134.68 8720.63 8653. 03 3775. 73 -1100 .21 3612. 26 15.00 5938062.67 89. 56 119.74 8720.17 8652. 57 3868. 78 -1160. 51 3691. 67 15.00 5938004.23 89. 47 118.76 8720.22 8652. 62 3875. 22 -1163. 74 3697. 44 15.00 5938001.14 89. 47 118.76 8720.48 8652. 88 3901. 91 -1176. 90 3721. 41 0.00 5937988.54 MapE TooUCo e ft 677500.03 MWD+IFR S 677547.42 CM1 677572.78 MWD+IFR S 677641.74 MWD+IFR S 677706.56 MWD+IFR S 677766.94 MWD+IFR S 677822.57 MWD+IFR S 677873.19 MWD+IFR S 677905.41 MWD+IFR S 677906.52 End Dir : 2 677918.78 MWD+IFR S 677963.06 MWD+IFR S 677966.94 THRZ 678007.33 MWD+IFR S 678051.61 MWD+IFR S 678072.51 BHRZ 678095.88 MWD+IFR S 678100.11 TKNG 678140.16 MWD+IFR S 678184.43 MWD+IFR S 678228.71 MWD+IFR S 678272.98 MWD+IFR S 678317.26 MWD+IFR S 678361.53 MWD+IFR S 678402.33 LCU 678405.81 MWD+IFR S 678450.08 MWD+IFR S 678452.70 TJ B 678472.81 Start Dir 4/ 0 678494.66 MWD+IFR S 678521.91 TJA 678541.41 MWD+IFR S 678557.74 14-026 pol 678590.05 14-026 T1 678590.44 MWD+IFR S 678600.07 Start Dir 2 0 678605.34 14-026 T3 v 1 678611.24 14-02B T4 678619.46 14-028 T3 678643.79 MWD+IFR S 678683.92 MWD+IFR S 678685.81 End Dir : 11 7 678701.81 MWD+IFR S 678713.16 Start Dir 7/ 0 678759.86 MWD+IFR S 678816.47 MWD+IFR S 678817.91 MWD+IFR S 678831.95 14-026 T3 v 2 678881.55 MWD+IFR S 678962.33 MWD+IFR S 678968.18 MWD+IFR S 678992.45 End Dir : 11 3 S err -Sun P Y BP Planning Report Company: BP Amoco Date: 8/1/2007 Time: .13:37:15 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 14-02, True North Site: PB DS 14 Vertical (TVD) Reference: 5:02 1/8/1994 00:00 67.6 Well: 14-02 Section (VS) Reference: Well (O.OON,O.OOE,106:15Azi) Wellpath: Plan 14-02C Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 11700.00 89.47 118.76 8721.09 8653.49 3966.35 -1208.67 3779.31 0.00 5937958.13 679051.06 MWD+IFR 11800.00 89.47 118.76 8722.03 8654.43 4063.93 -1256.78 3866.97 0.00 5937912.07 679139.81 MWD+IFR 11800.87 89.47 118.76 8722.03 8654.43 4064.78 -1257.20 3867.73 0.00 5937911.67 679140.58 Start Dir 6/ ~ 11853.81 89.47 118.76 8722.53 8654.93 4116.44 -1282.66 3914.14 0.00 5937887.29 679187.57 MWD+IFR 11869.25 90.00 118.00 8722.60 8655.00 4131.54 -1290.00 3927.73 6.00 5937880.27 679201.32 14-026 T4 11900.00 89.91 116.16 8722.62 8655.02 4161.72 -1304.00 3955.10 6.00 5937866.92 679229.01 MWD+IFR 12000.00 89.61 110.17 8723.05 8655.45 4260.93 -1343.31 4047.00 6.00 5937829.75 679321.79 MWD+IFR 12041.30 89.48 107.69 8723.38 8655.78 4302.17 -1356.71 4086.06 6.00 5937817.27 679361.15 End Dir : 1" 12045.15 89.47 107.46 8723.42 8655.82 4306.02 -1357.87 4089.73 6.00 5937816.19 679364.85 MWD+IFR 12100.00 89.47 107.46 8723.92 8656.32 4360.86 -1374.33 4142.05 0.00 5937800.96 679417.53 MWD+IFR 12160.37 89.47 107.46 8724.48 8656.88 4421.21 -1392.44 4199.64 0.00 5937784.19 679475.52 Start Dir 4/ i 12164.43 89.47 107.46 8724.52 8656.92 4425.26 -1393.66 4203.51 0.00 5937783.06 679479.42 MWD+IFR 12200.00 90.88 107.28 8724.41 8656.81 4460.83 -1404.28 4237.46 4.00 5937773.24 679513.61 MWD+IFR 12253.41 93.00 107.00 8722.60 8655.00 4514.20 -1420.00 4288.47 4.00 5937758.70 679564.96 14-02B T5 12254.70 92.95 107.01 8722.53 8654.93 4515.48 -1420.38 4289.70 4.00 5937758.35 679566.20 End Dir : 1 12294.05 91.44 107.45 8721.03 8653.43 4554.80 -1432.03 4327.26 4.00 5937747.58 679604.02 MWD+IFR 12300.00 91.44 107.45 8720.88 8653.28 4560.74 -1433.81 4332.93 0.00 5937745.93 679609.73 MWD+IFR 12338.08 91.44 107.45 8719.92 8652.32 4598.80 -1445.23 4369.24 0.00 5937735.36 679646.30 Start Dir 4/ i 12338.98 91.44 107.45 8719.90 8652.30 4599.70 -1445.50 4370.10 0.00 5937735.11 679647.15 MWD+IFR 12400.00 91.75 105.03 8718.20 8650.60 4660.69 -1462.56 4428.66 4.00 5937719.41 679706.09 MWD+IFR 12500.00 92.27 101.06 8714.69 8647.09 4760.46 -1485.12 4526.00 4.00 5937699.13 679803.92 MWD+IFR 12526.75 92.40 100.00 8713.60 8646.00 4787.07 -1490.00 4552.28 4.00 5937694.85 679830.31 14-026 T6 12593.90 92.71 97.33 8710.61 8643.01 4853.57 -1500.11 4618.58 4.00 5937686.29 679896.83 End Dir : 1" 12598.45 92.73 97.15 8710.39 8642.79 4858.06 -1500.68 4623.09 4.00 5937685.82 679901.35 MWD+IFR 12600.00 92.73 97.15 8710.32 8642.72 4859.59 -1500.87 4624.63 0.00 5937685.67 679902.89 MWD+IFR 12700.00 92.73 97.15 8705.56 8637.96 4958.25 -1513.30 4723.74 0.00 5937675.55 680002.26 MWD+IFR 12800.00 92.73 97.15 8700.80 8633.20 5056.90 -1525.73 4822.85 0.00 5937665.43 680101.62 MWD+IFR 12900.00 92.73 97.15 8696.05 8628.45 5155.56 -1538.16 4921.96 0.00 5937655.30 680200.99 MWD+IFR 12959.50 92.73 97.15 8693.22 8625.62 5214.26 -1545.56 4980.93 0.00 5937649.28 680260.11 Start Dir 4/ i 12964.05 92.73 97.15 8693.00 8625.40 5218.75 -1546.12 4985.44 .0.00 5937648.82 680264.63 MWD+IFR 12995.30 92.06 96.09 8691.70 8624.10 5249.54 -1549.72 5016.46 4.00 5937645.94 680295.72 End Dir : 1' 12997.99 92.00 96.00 8691.60 8624.00 5252.19 -1550.01 5019.13 4.00 5937645.72 680298.40 14-026 T7 13000.00 91.94 96.04 8691.53 8623.93 5254.17 -1550.22 5021.13 3.68 5937645.56 680300.40 MWD+IFR 13100.00 91.94 96.04 8688.15 8620.55 5352.56 -1560.73 5120.52 0.00 5937637.36 680400.00 MWD+IFR 13200.00 91.94 96.04 8684.77 8617.17 5450.95 -1571.24 5219.90 0.00 5937629.16 680499.60 MWD+IFR 13236.90 91.94 96.04 8683.53 8615.93 5487.26 -1575.12 5256.58 0.00 5937626.14 680536.35 Start Dir 4/ i 13241.45 91.94 96.04 8683.37 8615.77 5491.73 -1575.60 5261.10 0.00 5937625.76 680540.88 MWD+IFR 13300.00 90.86 98.12 8681.95 8614.35 5549.53 -1582.81 5319.18 4.00 5937619.91 680599.11 MWD+IFR 13346.33 90.00 99.76 8681.60 8614.00 5595.49 -1590.01 5364.95 4.00 5937613.77 680645.03 14-026 T8 13380.62 89.74 101.11 8681.68 8614.08 5629.61 -1596.22 5398.67 4.00 5937608.35 680678.89 End Dir : 1 13385.17 89.71 101.29 8681.70 8614.10 5634.14 -1597.10 5403.13 4.00 5937607.57 680683.37 MWD+IFR 13400.00 89.71 101.29 8681.77 8614.17 5648.92 -1600.00 5417.68 0.00 5937605.01 680697.97 MWD+IFR 13500.00 89.71 101.29 8682.29 8614.69 5748.56 -1619.57 5515.74 0.00 5937587.72 680796.46 MWD+IFR 13600.00 89.71 101.29 8682.80 8615.20 5848.20 -1639.14 5613.81 0.00 5937570.44 680894.95 MWD+IFR 13700.00 89.71 101.29 8683.31 8615.71 5947.84 -1658.71 5711.87 0.00 5937553.16 680993.44 MWD+IFR 13753.00 89.71 101.29 8683.58 8615.98 6000.65 -1669.08 5763.85 0.00 5937543.99 681045.63 41/2" 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L O ~_ II~1~ ~N Q ' ~ N J - C _ _ - ~ T N U L. b+0 - _ _ Q ~ ~ C ~ ^d W v ' _ >ao ~ - x ~ ~~ F ~= o ~a~ c~~: ~ ~ o _ - M N aQa °~ = ° N a ~ ~ C/~ ce z i . a ~ ~O ~ N O ~n O ~n O v'i O ~ O N v~ ~C r ~ ~ ~ r • S err -Sun p Y Anticollision Report Company: BP Amoco Date: 8/1/2007 Time: 13:48:54 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 14 Co-ordinate(NE) Reference: Well: 14-02, True North Reference Well: 14-02 Vertical (TVD) Reference: 5:02 1/8/1994 00:00 67:6. Reference Wellpath: Plan 14-02C Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are TIAfaY~~n~atils in this tl2litlcipal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 4500.00 to 13757.72 ft Scan Method: Trav Cylinder North Maximum Radius: 1573.21 ft Error Surface: Ellipse + Casing Survey Program for DeSnitive Wellpath Date: 2/8/2006 Validated: No Version: 6 Planned From To Survey Toolcode Tool N ame ft ft 551.60 4500.00 1 : Camera based gyro multisho (551.60-1185~~((4j`(RO-MS Camera based gyro multishot 4500.00 13757.72 Planned: 14-02C wp07 V44 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 10999.23 8707.60 7.000 8.500 7" 13753.00 8683.58 4.500 6.750 4 1 /2" Summary <----_~-~~_~_ Offset Wellpath ------ ----> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 06 06-06 06-066 V4 Out of range PB DS 06 06-12 Plan 6-126 V1 Plan: 6- 13502.20 12871.79 349.58 376.79 -27.21 FAIL: Major Risk PB DS 06 06-19 Plan 06-19A V0 Plan: 0 Out of range PB DS 13 13-23A 13-23A V7 12391.64 12400.00 325.04 1500.00 -1174.96 FAIL: Major Risk PB DS 13 13-26 Plan 13-26A V0 Plan: 1 11457.05 15393.76 93.95 311.41 -217.46 FAIL: Major Risk PB DS 14 14-01 14-01 V1 4526.15 4300.00 600.52 127.45 473.07 Pass: Major Risk PB DS 14 14-01A 14-01A V1 4526.15 4300.00 600.52 127.45 473.07 Pass: Major Risk PB DS 14 14-02 14-02 V1 4594.38 4600.00 4.14 0.82 3.32 Pass: NOERRORS PB DS 14 14-02 14-02A V1 4500.00 4500.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-02A 14-02A V1 4500.00 4500.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-026 14-026 V4 4500.00 4500.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-03 14-03 V1 4528.42 4500.00 718.51 173.03 545.47 Pass: Major Risk PB DS 14 14-03A 14-03A V1 4528.42 4500.00 718.51 173.03 545.47 Pass: Major Risk PB DS 14 14-07 14-07 V1 13145.23 11100.00 1355.83 1056.59 299.24 Pass: Major Risk PB DS 14 14-12 14-12 V1 9806.54 8600.00 654.12 214.78 439.35 Pass: Major Risk PB DS 14 14-13 14-13 V1 9175.42 8300.00 737.47 194.03 543.44 Pass: Major Risk PB DS 14 14-14 14-14 V1 13693.12 10500.00 1018.88 875.69 143.19 Pass: Major Risk PB DS 14 14-16 14-16 V1 7117.69 6500.00 600.51 135.33 465.18 Pass: Major Risk PB DS 14 14-16A 14-16A V3 7117.69 6500.00 600.51 135.33 465.18 Pass: Major Risk PB DS 14 14-20 14-20 V1 4512.33 4900.00 978.51 102.34 876.17 Pass: Major Risk PB DS 14 14-26 14-26 V8 12784.43 10500.00 958.25 928.07 30.18 Pass: Major Risk PB DS 14 14-35 14-35 V1 5512.23 5200.00 123.95 83.25 40.70 Pass: Major Risk PB DS 14 14-41 14-41 V1 5642.99 5200.00 519.96 81.03 438.93 Pass: Major Risk PB DS 14 14-43 14-43 V1 5661.92 5300.00 128.89 83.57 45.31 Pass: Major Risk Site: PB DS 06 Well: 06-12 Rule Assigned: Major Risk Wellpath: Plan 6-12B V1 Plan: 6-12B wp02 V9 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-H S Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13667.71 8683.14 12700.00 8797.18 43.79 76.29 208.39 107.11 6.125 394.82 376.63 18.19 Pass 13571.36 8682.65 12800.00 8784.56 43.23 76.42 207.68 106.40 6.125 368.46 376.67 -8.21 FAIL 13502.20 8682.30 12871.79 8775.50 42.82 76.52 207.11 105.82 6.125 349.58 376.79 -27.21 FAIL Site: PB DS 13 Well: 13-23A Rule Assigned: Major Ris k Wellpath: 13-23A V7 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSI)istance Area Deviation Warning Alaska Department of Natural Resources Land Administration System Page 1 of 2 .; ,. ` ~ ,:ra .fir . ~ r~.~, "~I~ts ~~~~..°o~ders S~a~~ch State Galains N~u~~ bus __...~_ l1 File Type ADL_. File Number: 28312 ~ PrintableC...ase File_Summary See Township, Range, Section and Acreage? ~` Yes r= NO ~ New Search LAS Menus ~ Case Abstract ~ Case Detail ~ Lar-d Abstract ~. File: :1llL 2531? ~~'~' 5earrh for Status Plat Updates ;~~ of ORi?9i200? Cz~sto~~acr~: OOOl OT 7~ BP EXPLOR~I~TION (ALASKA) INC PO BOX 1966I2/900_E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case Type; 7s~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Statzrs Date: 08/19/1965 Totul Acres: 2560.000 Date Initiatecl.~ 05/28/1965 Office of Primary Responsibility : DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtyp e. ~iS NORT H SLOPE Last Transaction: AA-NRB ASSIGNMENTAPPROVED _1lerfclian: U 7<nv~tshij~.~ OION Ru~t~r: 014E Secllon: 03 Scc(ir~~l ~~C/•c's: 640 Search Plats a1c~~ricli~u~: U 7u1rf7shrj~: OION XanLre~ 0141.; S'e~ctinrr: 04 S't~c~iurr:-acres: (140 llericli~rn: U 7ulc~l,~hij~: OION Rarage: 014E ,S'crc~iun: 09 .S'e~~liun.-Icf•e.~': 6-~0 ~1leric~iuri: U Trnti~~rc6u1~: OION Range: 014E Scctic~r~.~ l0 S'c°cur~n,~lcr~rs: 640 Leal Description 0~-28-1965 * * * ,SALE NOTICE LEGAL DESCRIPTION CI ~-133 TION, R14E, UM 3, 4, 9, 10 2560. DO ~t1t, ~ CaSE' t11~f11i"'~/ Last updated on 08/29/2007. http://www. dnr. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28312&... 8/29/2007 • • TRANSMITTAL LETTER CHECKLIST WELL NAME f'.8•~ I'~'Oo?G PTD# v~~ ~//S~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK. ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full. compliance with 20 AAC EXCEPTION 25.055. 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. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or 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 (Company Name) has designed and implemented a water well testing program to provide baseline data on water. quality and quantity. ~Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7!1312007 I~ ~J • ^^ ~ ~ I , , , N. 3. c. ~, ua o. , O ~ ~, ~ m , y 3 O, ~ , ~ t ~ ~ v' N' ~~ ' c, ~ cca `~ , W cn ~ ~ ~ ~ ~ c O~ O ~ w N O ~ N O C E O ~ ~ ~ c. N. ~, a uroi ~ a °~' 3 ~ ' ~ , ~ . ~ M, , , m. ~ ~, ~ a m c c?. ~ c a, . a n N, ~, ; N ~ ' v ~ ~ ~ rn a . 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N, N N N, N~ N~ N N a N N~ N~ VD N N N N~ Vl, N N a ~ O N~ N ~ V N ~ , z , , ~~ ~;~,~; ~-,~-~ ~~, r~; ~ , ~, , , , z,z,z , , , z z z ~ ; z; ~-~; z~ ~- ~- ~; , , ~ ~-~ ~- , , z ~- ~ z' ~~ ~ Z~~~ `/ ` \ ~ .t ~ , ~ ~ ~ „ s. ,i I , , , , ; , , , , , , , , ~ ~ ~ p' - E. °, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . c- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ma ~ ~ ~ O o ~ O, ~ J ~ ~ ~ p ~~ ~ ~ ~ ~ -O. ~ ~ ~ N. ~ ~ Z~ ~ ~ c~00' W i ~ ro, ~° f6 '~ ~ ro' N, Q N' m ° a ~ a ~ ~ i ~ , o. x O 2 ~ ~ o c. o, m, ~ ~ ,t a ~ ~ c l ~, °, u, ~ ~ 1 \ ~ ~ ~ ~ ~, ~ ~ ~ ~, a ' ~ v' o, Q' ~ ~ ~~ y°yS ~ °, ~ c, ~ ~ ro~ ~ o ~, ' ro~ ~, rn~ ~ ~~ ~ ~ ~ ~ ~ ~,~ N ~ a, ~ -O. ~N, U' ~ ~ ~~ U. N ~, ~ ~~ ~ ~~ ~ N~ M, 4-~ N. C' ~ O, } ~ ~ °i 3, .C ~ O. ~~ 3 a N ~ M. ~ ~~ ~~ N, ,N, Q ~ c O, ~ ~ a ~ 3 , ~~ •O. `, ~ N~ M W -~ ~, p -O. `p, N' p •O ro, N. a ~ O, C. p, m. p. O. m ' , L. ' ' N• _, N, O .. , N a C C 2 Q ~ ~ o d ~ N ~ ,~, ~ a° C U ~ •O• o a U~ ro~ ~ m. N ~ ~~ O O' a' 3 0. ~ O. ~ ~, 7. .. (~ 'a ro' d ~ . L~ N, c' _, O. dj, d, o m, .O, 3~ • rn ~~ ro, >' N °' T (0' ~' O N .N ~ ~ s' o, ro, ro, c c, o p' N c :?. a Y o, ro, ~ ro cf ro ~ E ~, Q. ~ %, ~ ~ a T o, Y w o, ro, ro U• U• N. a m >T ~, d d ~ Q ~~ , ~~ ro ro, ~, Z, ~, , ~, m 4 p, O a C a a °' ~ ro ro, c ~, . m. a ro' ~, a ~ ~ r' v ro ro' , ~ ° a. E. v. ~, m, , •~, ~ ~ a~, ~, . •- a~ ri ~~ y ~ ° rn m ° ~ a 3, ° ' .~ d , ~' m' >' ` ' L j o o ~ O °' ~°' c' v v; ro' m' . a' ~, 3 3; ~ m, ~~ .., o, N :'4, ~, '~, .-, o ~ ° ~ ~ o u~ n 'a a y ~ co o, 3 o a i , o L Z U O a ~~ o~ ~ ~, m ~~ °~ ~ ~~ ° o ~~ ~, p ro~ ~~ o' c ~ po a ar a o. c' ~ a o, a~ ~,~ v~ o' E' ~, ro, a~ E' o~ m c, w ( v~ ~ a °~ °~ ~, . 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N, O. ~, c ~ ~~ ~~ Y' ~~ N• L• '~, ro ~: ~, m, ~ N ~.~, ~ Y >, a~; ° aroi, 'c, ~' ~' ~' ~ ~;lS;~; i ~; o ~ " ; n a O O; d ai a;a; ~ U ~ ~' . ro, o ¢;a;z' o ~; ~; ~; U;cn U U ~; U m v; U a f6 a, a' = w ~ Q ~ O; p L; m m U °' °: a ~; ~';~' m. a m o; -i; a o; 'a cn tn;U D (ti U c -, - , , _ , , , , , , , , ; -, , ; , , , , , w ~ O N M V ~ (O I~ W O O N M V ~ O h W Q1 O N M I to CO f~ 00 O V O ~ __ _ N M ~t LL~ M _.__.____.__ h W O) ~ ~ _ N N N _ N N N_ N__N N __ -__ N M M M M_ M .JII -_ __._ M _- _ M - M M M _-. _ U I I ~ ~ O r O h O .. ~ C "' N +O'' N +'' N U C Q' ~ W d ~ ~ H Q N W i C • Q M M 0~ O O O N ~ N •C I ~ ~ ~ Q ^ ~ •~ ~~ (~ L.a ~ ~ a s a a U a ~ w a a W -- O ~ a U as • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically . organize this calegory of information. 14-02c.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Aug 13 10:29:13 2008 Reel Header Service name .............LISTPE Date.. . .................08/08/13 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/08/13 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: Mw0005043421 LOGGING ENGINEER: GEOFFREY SAM OPERATOR WITNESS: BILL DECKER MWD RUN 4 JOB NUMBER: MW0005043421 LOGGING ENGINEER: GEOFFREY SAM OPERATOR WITNESS: DICK MASKELL MWD RUN 7 JOB NUMBER: MW0005043421 LOGGING ENGINEER: GEOFFERY SAM OPERATOR WITNESS: BILL DECKER SURFACE LOCATION SECTION: writing Library. scientific Technical services 14-02C 500292031803 BP Exploration (Alaska) Inc. Sperry Drilling Services 13-AUG-08 MWD RUN 2 MWD RUN 3 Mw0005043421 Mw0005043421 GEOFFREY SAM GEOFFREY SAM BILL DECKER BILL DECKER MWD RUN 5 MWD RUN 6 Mw0005043421 Mw0005043421 GEOFFREY SAM GEOFFREY SAM DICK MASKELL DICK MASKELL MWD RUN 9 Mw0005043421 GEOFFREY SAM BLAIR NEUFEL 9 Page 1 MWD RUN 10 MW0005043421 GEOFFREY SAM JOHN ROSE ~o~--~r5~ ~168~09 i 14-02c.tapx TOWNSHIP: lON RANGE: 14E FNL: FSL: 4018 FEL: FWL: 4052 ELEVATION (FT FROM MSL O) KELLY BUSHING: 69,72 DERRICK FLOOR: GROUND LEVEL: 41.22 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 4455.0 2ND STRING 6.125 7.000 10987.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THE PURPOSE OF MWD RUN 1 (DIRECTIONAL ONLY) WAS TO POSITION THE WHIP- STOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. THE TOP OF THE WHIPSTOCK WAS AT 4455'MD/4320'TVD. ONLY SROP DATA ARE PRESENTED. 4. MWD RUNS 2-10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). UPHOLE MAD TIE-IN SGRC DATA WERE MERGED WITH RUN 2 MWD DATA. MWD RUNS 2-6 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 2,4-6 ALSO INCLUDED GEOPILOT ROTARY STEERABLE BHA (GP). MWD RUNS 9,10 ALSO INCLUDED COMPENSATED THERMAL NEUTRON (CTN) AND AZIMUTH- AL LITHO-DENSITY (ALD). MWD RUNS 7,10 INCLUDED AT-BIT INCLINATION (ABI). GABI (GAMMA/AT-BIT INCLINATION) WAS INCLUDED ON MWD RUN 9. NO DATA WERE ACQUIRED ON MWD RUN 8. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 4 AUGUST 2008, QUOTING AUTHORIZATION FROM PRIYA MARAJ (BP). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-7,9,10 REPRESENT WELL 14-02C WITH API# 50-029-20318-03. THIS WELL REACHED A TOTAL DEPTH OF 13912'MD/8697'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. Page 2 ~ ~ 14-02c.tapx SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED-HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.4-8.8 PPG MUD SALINITY: 3800-18000 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......sTSLI6.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX FET RPM RPD 1 and clipped curves; all bit runs merged. .5000 START DEPTH 4189.0 4450.0 4450.0 4450.0 4450.0 STOP DEPTH 13849.0 13856.0 13856.0 13856.0 13856.0 Page 3 i ~ 14-02c.tapx RPS 4450.0 13856.0 ROP 4455.5 13912.0 FCNT 11277.5 13821.0 NPHI 11277.5 13821.0 NCNT 11277.5 13821.0 PEF 11292.0 13836.5 DRHO 11292.0 13836.5 RHOB 11292.0 13836.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 4455.5 4493.0 MwD 2 4493.0 4576.0 MwD 3 4576.0 5565.0 MwD 4 5565.0 8958.0 MwD 5 8958.0 10379.0 MwD 6 10379.0 10987.0 MWD 7 10987.0 11369.0 MwD 9 11369.0 13411.0 MwD 10 13411.0 13912.0 REMARKS: MERGED MAIN PASS. Data Format specific ation Record Data Record Type. .. ...... 0 Data specificatio n Block Type. .... ....0 Loging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Po int .......... ....undefined Frame Spacing.... ... ........ ....60 .lIN Max frames per re cord ......... ....undefined Absent value ..... ............. ....-999 Depth Units. .. .. . .... Datum specification Block sub- type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU-s 4 1 68 52 14 First Last Page 4 ~ ~ 14-02c.tapx Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 4189 13912 9050.5 19447 4189 13912 FCNT MWD CP30 255.04 2078.66 577.865 5088 11277.5 13821 NCNT MWD CP30 17609.6 41971.3 26695.7 5088 11277.5 13821 RHOB MWD G/CC 2.031 3.233 2.39102 5090 11292 13836.5 DRHO MWD G/CC -0.319 0.708 0.0898044 5090 11292 13836.5 RPD MWD OHMM 0.58 2000 14.2747 18813 4450 13856 RPM MWD OHMM 0.65 2000 13.8178 18813 4450 13856 RPS MWD OHMM 0.63 2000 8.2899 18813 4450 13856 RPX MWD OHMM 0.66 2000 7.16664 18813 4450 13856 FET MWD HR 0.25 165.06 4.22407 18813 4450 13856 GR MWD API 9.75 563.26 103.213 19321 4189 13849 PEF MWD B/E 1.1 7.23 2.22087 5090 11292 13836.5 ROP MWD FPH 0.04 856.53 99.5127 18854 4455.5 13912 NPHI MWD PU-s 8.58 37.07 23.6732 5088 11277.5 13821 First Reading For Entire File..........4189 Last Reading For Entire File...........13912 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4455.5 4493.0 LOG HEADER DATA DATE LOGGED: 17-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4493.0 Page 5 14-02c.tapx TOP LOG INTERVAL (FT): 4455.0 BOTTOM LOG INTERVAL (FT): 4493.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: ,Q MAXIMUM ANGLE: ,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4455.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 54.0 MUD PH: g,7 MUD CHLORIDES (PPM): 2200 FLUID LOSS (C3): ,Q RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 79.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MwD010 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4455.5 4493 4474.25 76 4455.5 4493 ROP MwD010 FPH 0.04 19.99 8.45053 76 4455.5 4493 Page 6 • 14-02c.tapx First Reading For Entire File..........4455.5 Last Reading For Entire File...........4493 File Trailer Service name... .....,.STSLIB.002 Service sub Level Name.,. version Number. ........1.0.0 Date of Generation.....,.08/08/13 Maximum Physical Record,.65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .....,.STSLIB.003 Service Sub Level~Name.,. version Number.. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type. ..........,.LO Previous File Name.....,.5T5LI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4189.0 4536.0 RPS 4450.0 4523.0 RPD 4450.0 4523.0 FET 4450.0 4523.0 RPM 4450.0 4523.0 RPX 4450.0 4523.0 ROP 4493.5 4576.0 LOG HEADER DATA DATE LOGGED: 18-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4576.0 TOP LOG INTERVAL (FT): 4493.0 BOTTOM LOG INTERVAL (FT): 4576.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.2 MAXIMUM ANGLE: 42.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 245697 EWR4 ELECTROMAG. RESIS. 4 81390 Page 7 14-02c.tapx BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 • 8.500 4455.0 Fresh water Gel 9.50 52.0 9.7 2200 8.0 1.120 75.0 .980 87.0 .930 75.0 1.250 75.0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MwD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MwD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4189 4576 4382.5 775 4189 4576 RPD MWD020 OHMM 0.97 2000 168.514 147 4450 4523 RPM MWD020 OHMM 1.99 2000 154.512 147 4450 4523 RPS MWD020 OHMM 1.42 1704.84 26.8848 147 4450 4523 RPX MWD020 OHMM 0.68 1703.68 26.1814 147 4450 4523 FET MwD020 HR 0.91 27.65 15.1349 147 4450 4523 GR MWD020 API 15.57 96.98 50.2142 695 4189 4536 Page 8 14-02c.tapx ROP MWD020 FPH 3.01 411.73 144.593 166 4493.5 First Reading For Entire File..........4189 Last Reading For Entire File...........4576 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/08/13 Maximum Physical Record..65535 File Type. .LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSL26.004 service sub Level~Name... version Number. ........1.0.0 Date of Generation.... .08/08/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4523.5 5508.5 RPX 4523.5 5508.5 RPS 4523.5 5508.5 RPM 4523.5 5508.5 RPD 4523.5 5508.5 GR 4536.5 5521.5 ROP 4576.5 5565.0 LOG HEADER DATA DATE LOGGED: 20-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5565.0 TOP LOG INTERVAL (FT): 4576.0 BOTTOM LOG INTERVAL (FT): 5565.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 29.1 MAXIMUM ANGLE: 42.4 TOOL STRING (TOP TO BOTTOM) Page 9 4576 • ~ 14-02c.tapx VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 245697 EWR4 ELECTROMAG. RESIS. 4 81390 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT); 4455.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): g,70 MUD VISCOSITY (S): 53.0 MUD PH: g,7 MUD CHLORIDES (PPM): 2200 FLUID LOSS (C3): 5,7 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.120 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.010 84.0 MUD FILTRATE AT MT: .930 75.0 MUD CAKE AT MT: 1.250 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4523.5 5565 5044.25 2084 4523.5 RPD MWD030 OHMM 1.03 42.69 4.09985 1971 4523.5 RPM MWD030 OHMM 1.03 25.78 3.90434 1971 4523.5 RPS MWD030 OHMM 1.03 26 3.85828 1971 4523.5 Page 10 Last Reading 5565 5508.5 5508.5 5508.5 • 14-02c.tapx RPx MwD030 OHMM 1.03 22.82 3.83213 1971 4523.5 5508.5 FET MwD030 HR 0.25 17.7 1.87168 1971 4523.5 5508.5 GR MWD030 API 9.75 135.42 67.2537 1971 4536.5 5521.5 ROP MWD030 FPH 0.43 500.05 148.884 1978 4576.5 5565 First Reading For Entire File..........4523.5 Last Reading For Entire File...........5565 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type. .. .........LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 5509.0 8904.5 FET 5509.0 8904.5 RPS 5509.0 8904.5 RPx 5509.0 8904,5 RPD 5509.0 8904.5 GR 5522.0 8918.0 ROP 5565.5 8958.0 LOG HEADER DATA DATE LOGGED: 22-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8958.0 TOP LOG INTERVAL (FT): 5565.0 BOTTOM LOG INTERVAL (FT): 8958.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.7 Page 11 MAXIMUM ANGLE: 14-02c.tapx 54.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD040 RPM MWD040 RPS MWD040 RPX MWD040 FET MWD040 GR MWD040 ROP MWD040 TOOL NUMBER 245697 81390 8.500 4455.0 Fresh water Gel 9.70 61.0 9.5 600 7.0 1.120 1.010 .930 1.250 units size Nsam Rep Code offset FT 4 1 68 0 OHMM 4 1 68 4 OHMM 4 1 68 8 OHMM 4 1 68 12 OHMM 4 1 68 16 HR 4 1 68 20 API 4 1 68 24 FPH 4 1 68 28 Channel 1 3 4 5 6 8 75.0 84.0 75.0 75.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5509 8958 7233.5 6899 5509 8958 Page 12 ~ ~ 14-02c.tapx RPD MWD040 OHMM 0.8 11.1 3.19917 6792 5509 8904.5 RPM MWD040 OHMM 0.77 12.54 3.14684 6792 5509 8904.5 RPS MWD040 OHMM 0.77 17.76 3.06993 6792 5509 8904.5 RPX MWD040 OHMM 0.79 24.86 3.06248 6792 5509 8904.5 FET MWD040 HR 0.26 12.69 0.823014 6792 5509 8904.5 GR MWD040 API 20.25 279.82 95.566 6793 5522 8918 ROP MWD040 FPH 7.26 512.52 136.982 6786 5565.5 8958 First Reading For Entire File..........5509 Last Reading For Entire File...........8958 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/08/13 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.005 comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8905.0 10318.5 FET 8905.0 10318.5 RPD 8905.0 10318.5 RPX 8905.0 10318.5 RPS 8905.0 10318.5 GR 8918.5 10331.5 ROP 8988.5 10379.0 LOG HEADER DATA DATE LOGGED: 28-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10379.0 TOP LOG INTERVAL (FT): 8958.0 BOTTOM LOG INTERVAL (FT): 10379.0 Page 13 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 14-02c.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN); EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Di rection .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 49.0 51.6 TOOL NUMBER 245697 81390 8.500 4455.0 Fresh water Gel 11.10 55.0 9.5 1000 4.4 1.150 72.0 .640 134.6 .900 72.0 1.350 72.0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 Page 14 14-02c.tapx First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8905 10379 9642 2949 8905 10379 RPD MwD050 OHMM 0.65 10.41 2.94207 2828 8905 10318.5 RPM MWD050 OHMM 0.65 10.82 2.95636 2828 8905 10318.5 RPS MWD050 OHMM 0.63 9.26 2.72118 2828 8905 10318.5 RPX MWD050 OHMM 0.66 9.95 2.70808 2828 8905 10318.5 FET MwD050 HR 0.44 103.15 6.01549 2828 8905 10318.5 GR MWD050 API 73.45 406.94 172.419 2827 8918.5 10331.5 ROP MWD050 FPH 1.43 200.33 73.2137 2782 8988.5 10379 First Reading For Entire File..........8905 Last Reading For Entire File...........10379 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 oate of Generation.... .08/08/13 Maximum Physical Record..65535 File Type. .LO Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 10319.0 10943.0 FET 10319.0 10943.0 RPD 10319.0 10943.0 RPM 10319.0 10943.0 RPS 10319.0 10943.0 GR 10332.0 10950.5 ROP 10379.5 10987.0 LOG HEADER DATA DATE LOGGED: 30-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 15 TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 14-02c.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 10987.0 10379.0 10987.0 48.2 51.6 TOOL NUMBER 245697 228272 8.500 4455.0 Fresh water Gel 11.10 47.0 9.5 900 3.8 1.150 72.0 .640 135.4 .900 72.0 1.350 72.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HR 4 1 68 20 6 GR MwD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 Page 16 i 14-02c.tapx • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10319 10987 10653 1337 10319 10987 RPD MWD060 OHMM 1.59 7.52 2.69623 1249 10319 10943 RPM MWD060 OHMM 1.67 7.59 2.7391 1249 10319 10943 RPS MWD060 OHMM 1.64 6.51 2.46797 1249 10319 10943 RPX MWD060 OHMM 1.67 6.78 2.44196 1249 10319 10943 FET MWD060 HR 1.03 44.13 5.78162 1249 10319 10943 GR MWD060 API 71.05 147.05 125.496 1238 10332 10950.5 ROP MWD060 FPH 2.65 290 34.2968 1216 10379.5 10987 First Reading For Entire File..........10319 Last Reading For Entire File...........10987 File Trailer Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.008 Physical EOF File Header Service name... .......STSLI6.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.007 comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10943.5 11315.0 RPx 10943.5 11315.0 RPS 10943.5 11315.0 FET 10943.5 11315.0 RPD 10943.5 11315.0 GR 10951.0 11308.0 ROP 10987.5 11369.0 LOG HEADER DATA DATE LOGGED: 09-OCT-07 SOFTWARE Page 17 • 14-02c.tapx SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11369.0 TOP LOG INTERVAL (FT): 10987.0 BOTTOM LOG INTERVAL (FT): 11369.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.6 MAXIMUM ANGLE: 105.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10987.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 50.0 MUD PH: g,7 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 10.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.600 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .670 171.0 MUD FILTRATE AT MT: .690 68.0 MUD CAKE AT MT: 1.350 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN); TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service order DEPT RPD MWD070 RPM MWD070 RPS MWD070 RPX MWD070 Units Size Nsam FT 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 Rep Code offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 Page 18 • 14-02c.tapx FET MWD070 HR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 RoP MWD070 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10943.5 11369 11156.3 852 10943.5 11369 RPD MWD070 OHMM 0.58 2000 190.244 744 10943.5 11315 RPM MWD070 OHMM 1.87 2000 191.216 744 10943.5 11315 RPS MWD070 OHMM 1.62 2000 84.4607 744 10943.5 11315 RPX MWD070 OHMM 1.16 2000 60.432 744 10943.5 11315 FET MWD070 HR 2.76 165.06 26.0881 744 10943.5 11315 GR MWD070 API 54.29 563.26 178.574 715 10951 11308 ROP MWD070 FPH 0.64 164.67 20.0455 764 10987.5 11369 First Reading For Entire File..........10943.5 Last Reading For Entire File...........11369 File Trailer service name... .......STSLI6.008 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.009 Physical EOF File Header Service name... .......STSLI6.009 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......sTSLI6.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY .5000 VENDOR TOOL CODE START DEPTH NPHI 11277.5 FCNT 11277.5 NCNT 11277.5 PEF 11292.0 RHOB 11292.0 DRHO 11292.0 GR 11308.5 RPM 11315.5 RPS 11315.5 header data for each bit run in separate files. 9 STOP DEPTH 13318.5 13318.5 13318.5 13333.5 13333.5 13333.5 13346.5 13355.0 13355.0 Page 19 14-02c.tapx RPD 11315.5 13355.0 RPX 11315.5 13355.0 FET 11315.5 13353.5 ROP 11369.5 13411.0 LOG HEADER DATA DATE LOGGED: 15-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13411.0 TOP LOG INTERVAL (FT): 11369.0 BOTTOM LOG INTERVAL (FT): 13411.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87,2 MAXIMUM ANGLE: 99.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 CTN COMP THERMAL NEUTRON 231708 EWR4 Electromag Resis. 4 228502 ALD Azimuthal Litho-Dens 179170 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10987.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 49.0 MUD PH: g,5 MUD CHLORIDES (PPM): 3800 FLUID LOSS (C3): 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.710 70.5 MUD AT MAX CIRCULATING TERMPERATURE: .850 149.0 MUD FILTRATE AT MT: 1.310 72.6 MUD CAKE AT MT: 1.260 66.5 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Page 20 • M f 14-02c.tapx d ax ram es per recor .... ... ......undefin ed Absent value ... .......... .........-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FONT MwD090 cP30 4 1 68 4 2 NCNT MWD090 CP30 4 1 68 8 3 RHOB MWD090 G/CC 4 1 68 12 4 DRHO MWD090 G/CC 4 1 68 16 5 RPD MwD090 OHMM 4 1 68 20 6 RPM MWD090 OHMM 4 1 68 24 7 RPS MwD090 OHMM 4 1 68 28 8 RPx MwD090 OHMM 4 1 68 32 9 FET MWD090 HR 4 1 68 36 10 GR MwD090 API 4 1 68 40 11 PEF MwD090 B/E 4 1 68 44 12 ROP MwD090 FPH 4 1 68 48 13 NPHI MwD090 PU-S 4 1 68 52 14 First Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 11277.5 13411 12344.3 4268 11277.5 13411 FONT MWD090 CP30 255.04 2078.66 572.663 4083 11277.5 13318.5 NCNT MwD090 cP30 17609.6 41971.3 26316.5 4083 11277.5 13318.5 RHOB MwD090 G/cc 2.031 3.233 2.3909 4084 11292 13333.5 DRHO MWD090 G/CC -0.319 0.708 0.0885115 4084 11292 13333.5 RPD MWD090 OHMM 4.01 71.54 11.8867 4080 11315.5 13355 RPM MWD090 OHMM 3.35 67.28 10.9507 4080 11315.5 13355 RPS MWD090 OHMM 3.12 76.47 10.2601 4080 11315.5 13355 RPx MWD090 OHMM 2.84 79.23 9.63019 4080 11315.5 13355 FET MwD090 HR 0.53 37.63 4.50618 4077 11315.5 13353.5 GR MwD090 API 42.62 538.58 83.2283 4077 11308.5 13346.5 PEF MwD090 B/E 1.1 7.23 2.23596 4084 11292 13333.5 ROP MwD090 FPH 0.27 856.53 72.8354 4084 11369.5 13411 NPHI MwD090 PU-S 8.58 37.07 23.5953 4083 11277.5 13318.5 First Reading For Entire File..........11277.5 Last Reading For Entire File....... .....13411 File Trailer service name... .......STSLI6.009 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.010 Physical EOF File Header Service name... .......STSLIB.O10 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/13 Page 21 14-02c.tapx Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FONT 13319.0 13821.0 NPHI 13319.0 13821.0 NCNT 13319.0 13821.0 DRHO 13334.0 13836.5 RHOS 13334.0 13836.5 PEF 13334.0 13836.5 GR 13347.0 13849.0 FET 13354.0 13856.0 RPM 13355.5 13856.0 RPX 13355.5 13856.0 RPS 13355.5 13856.0 RPD 13355.5 13856.0 ROP 13411.5 13912.0 LOG HEADER DATA DATE LOGGED: 18-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT): 13912.0 TOP LOG INTERVAL (FT): 13411.0 BOTTOM LOG INTERVAL (FT): 13912.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: $$,Q MAXIMUM ANGLE: 92,7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232605 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 223565 ALD Azimuthal Litho-Dens 231387 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10987.0 BOREHOLE CONDITIONS MUD TYPE: Sea Water MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 34.0 MUD PH: 7,2 MUD CHLORIDES (PPM): 16000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) Page 22 • 14-02c.tapx MUD AT MEASURED TEMPERATURE (MT): .340 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .160 152.0 MUD FILTRATE AT MT: .340 70.0 MUD CAKE AT MT: .340 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block rype.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD100 CP30 4 1 68 4 2 NCNT MWD100 CP30 4 1 68 8 3 RHOB MwD100 G/CC 4 1 68 12 4 DRHO MWD100 G/CC 4 1 68 16 5 RPD MWD100 OHMM 4 1 68 20 6 RPM MWD100 OHMM 4 1 68 24 7 RPS MWD100 OHMM 4 1 68 28 8 RPX MWD100 OHMM 4 1 68 32 9 FET MWD100 HR 4 1 68 36 10 GR MWD100 API 4 1 68 40 11 PEF MWD100 B/E 4 1 68 44 12 ROP MWD100 FPH 4 1 68 48 13 NPHI MwD100 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13319 13912 13615.5 1187 13319 13912 FCNT MWD100 CP30 391.74 728.99 599 1005 13319 13821 NCNT MWD100 CP30 21454.6 31307.7 28236.1 1005 13319 13821 RHOB MWD100 G/CC 2.267 2.535 2.39151 1006 13334 13836.5 DRHO MWD100 G/CC -0.043 0.59 0.0950533 1006 13334 13836.5 RPD MwD100 OHMM 6.16 17.99 12.2176 1002 13355.5 13856 RPM MWD100 OHMM 4.19 16.85 9.4291 1002 13355.5 13856 RPS MWD100 OHMM 3.9 15.21 8.05587 1002 13355.5 13856 RPX MWD100 OHMM 3.82 14.32 7.64753 1002 13355.5 13856 FET MWD100 HR 0.69 38.67 5.91959 1005 13354 13856 GR MWD100 API 50.54 91.81 67.4174 1005 13347 13849 PEF MWD100 B/E 1.66 4.7 2.1596 1006 13334 13836.5 ROP MWD100 FPH 3.13 244.44 69.2137 1002 13411.5 13912 NPHI MWD100 PU-s 21.03 28.15 23.9897 1005 13319 13821 Page 23