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Home My WebLink About207-105MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Y-07A PRUDHOE BAY UNIT Y-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/15/2024 Y-07A 50-029-20560-01-00 207-105-0 W SPT 8701 2071050 2175 476 481 480 480 21 20 20 20 4YRTST P Brian Bixby 7/6/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT Y-07A Inspection Date: Tubing OA Packer Depth 29 2508 2453 2438IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240707132322 BBL Pumped:7.4 BBL Returned:6.1 Thursday, August 15, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 99 99 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 15:15:45 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector Well Name PRUDHOE BAY UNIT Y -07A Insp Num: mitRCN200721134548 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 12, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC Y -07A PRUDHOE BAY UNIT Y -07A Sre: Inspector Reviewed By: P.I. Supryy Comm API Well Number 50-029-20560-01-00 Inspector Name: Bob Noble Permit Number: 207-105-0 Inspection Date: 7/20/2020 Packer Depth Well Y -07A ,Type Inj W- TVD 8701 Tubing PTD ! 2071050 - Type Test l SPT ITest psi 2175 IA BBL Pumped: 6.8 BBL Returned: 6 OA Interval --4YRTSTP/F P —_.— Notes: Pretest Initial 15 Min 30 Min 45 Min 60 Min 754 757 756 756 I 264 2529 2486 - 2472 ` IS 15 15 15 Wednesday, August 12, 2020 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,July 20,2016 Jim Regg P.I.Supervisor Re,,i 7'z Z II SUBJECT: Mechanical Integrity Tests 4 BP EXPLORATION(ALASKA)INC. Y-07A FROM: Matt Herrera PRUDHOE BAY UNIT Y-07A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,9 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Y-07A API Well Number 50-029-20560-01-00 Inspector Name: Matt Herrera Permit Number: 207-105-0 Inspection Date: 7/16/2016 Insp Num: mitMFH160716185546 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Y-07A Type Inj W-TVD 8701 - Tubing 497 518 - 516 . 515 • PTD 2071050 • 'Type Test SPT Test psi 2175 - IA 326 2503 2469 • 2452 - Interval 4YRTST P/F P ✓ OA 11 11 11 11 - Notes: 2500 PSI test pressure per Operator - SCANNED MAY 1. 9 017 Wednesday,July 20,2016 Page 1 of 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 20, 2010 JAN % 4 ra11 Mr. Tom Maunder+; -. Alaska Oil and Gas Conservation Commission 333 West 7 Avenue .:in, Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Y Pad Dear Mr. Maunder, ao7-fas-- Enclosed please find multiple copies of a spreadsheet with a list of wells from Y Pad 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, Jerry Murphy, 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 -404) Date: 12 /20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # _ cement pumped cement date inhibitor sealant date ft bbls ft na gal Y -01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y - 02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y -03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y - 04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y -05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y -06A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y -07A 2071050 50029205600100 Y -08A 1880560 50029205720100 14.5 2.0 0.3 NA 1.70 8/4/2010 NA 4 NA 15.30 8/5/2010 Y -09A 1970830 50029205790100 19 1.5 3.6 NA 17.00 8/4/2010 Y -10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y -11 C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y -13 1811120 50029206340000 NA 0.4 NA 3.40 4/15/2010 Y -14B 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y -16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y -18 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y - 19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y - 20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y - 21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y -22A 1881150 50029215580100 NA 0.5 _ NA 3.40 8/4/2010 Y - 23B 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y - 25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y - 26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y -27 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y - 28 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y - 29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 Y - 30 1910150 50029221350000 NA _ 0.5 NA 2.60 4/13/2010 Y -31 1910560 50029221610000 _ NA 0.5 NA 3.40 4/12/2010 Y - 32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y -33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y - 34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y -35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y - 36 1931310, 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y - 37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 • ,; ~; nF,`~F ~ a1' ~r ~M' fly" x ~ .~ ~,"'~, MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDERTHIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~ih~~mU~~~~~ Alaska Data & Consulting Services NO. 5020 2525 Gambell Street, Suite 400 Com an State of Alaska Anchorage, AK 99503-2838 P y' ATTN: Beth .. Alaska Oil & Gas Cons Comm I- ~, r .,PSi,r t. ~.. ~ .,ti , ~ ~ ~< ~ ~ i,l+.~.~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 4-20/M-35 Job # 12014059 Lo Descri lion STATIC SURVEY/PERF Date BL Color C W-18 11968978 PRODUCTION PROFILE 12/11/08 1 1 Y-07A 12103704 INJECTION PROFILE ~ 12/20/08 1 1 P2-35 12031533 SCMT ~ ~ 12/18/08 ~ 1 M-16 12111931 _ SCMT 12/18/08 1 1 P2-15A P2 1 40015006 OH MWD/LWD EDIT ~ ~ ~ 12/19/08 1 1 - 5APB3 40015006 ` OH MWD/LWD EDIT a 04/01/07 2 1 P2-15AP62 40015006 _ ~ OH MWD/LWD EDIT °~~ a ~ 03/27/07 2 1 P2-15APB1 40015006 - f~ OH MWD/LWD EDIT ~_ 03/24/07 2 1 W-31A 40017846 ( OH MWD/LWD EDIT _' ~ 03/22/07 2 1 W'29 11549353 CH EDIT (USIT) 09/27/08 Q 1 H-05A AXBD-00002 MCNL 12/18/06 1 11/20/08 1 1 - -----~ ---••- ..~. ~ vnwnvu VrvC I:UPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ Alaska Data & Consulting Services 900 E. Benson Blvd. 2525 Gambell Street, Suite 400 Anchorage, Alaska 99508 1 Anchorage, AK 99503-2838 J ATTN: Beth Date Delivered: Received by: 12/29/08 u DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2071050 Well Name/No. PRUDHOE BAY UNIT Y-07A MD 14730 TVD 91$5 Completion Date 5/10/2008 REQUIRED INFORMATION Mud Log No Samples No Directional Su Yes -- - - -- ------ DATA INFORMATION Types Electric or Other Logs Run: DIR / GR /PWD, USIT, DIR / GR /PWD, USIT, DIR 1 GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name og Sonic Cog Cement Evaluation C Pds 15992 Cement Evaluation ~D C L 16216 ti /R i I d ti it as i n on uc es v y s Las 16218 Induction/Resistivity ~Pi LIS Verification D C Lis 16291 LIS Verification i, t ifi ti LIS Ve r ca on vED C Li 16 V i s i 292 er fication LIS ~g Cement Evaluation ~D C Pds 16315 Cement Evaluation ~g Temperature C Pds 16323 Temperature I i ~ to r /.r,~1~1 igw~t/ .,~~ Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20560-01-00 Completion Status WAGIN Current Status WAGIN (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 5 Col 1 200 2590 Case 2/22/2008 USIT w/Plug, USIT-D, GR, CCL 18-Dec-2008 5 Col 28 14562 Case 3/4/2008 CBL, SCMT, GR, CCL 3- Feb-2007 28 14562 Case 3/4/2008 CBL, SCMT, GR, CCL 3- Feb-2007 1821 12745 Open 4/11/2008 P61 RPM, GR, ROP, RPD, RPS, RPX 9254 14730 Open 5/5/2008 EWR, GR, ROP, RPS, RPX 1823 14743 Open 5/21/2008 LIS Veri, GR, ROP, RPS, FET, RPM, RPD, RPX 1823 14743 Open 5/21!2008 LIS Veri, GR, ROP, RPS, FET, RPM, RPD, RPX 1823 12755 Open 5/21/2008 P61 LIS Veri, GR, ROP, RPS, FET, RPM, RPD, RPX 1823 12755 Open 5/21/2008 PB1 LIS Veri, GR, ROP, RPS, FET, RPM, RPD, • RPX 5 Col 14000 14600 Case 5/23/2008 CBL, SCMT-CB, GR, CCL 2-May-2008 14000 14600 -Case 5/23/2008 CBL, SCMT-CB, GR, CCL 2-May-2008 5 Blu 14000 14600 Case 5/23/2008 Temp, Pres, GR, CCL 2- May-2008 14000 14600 Case 5/23/2008 Temp, Pres, GR, CCL 2- 92 44&v^v°- £~ese 5fz3/zAAB--- May-2008 -EI's'oFefi~rF~;-6vc= J DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2071050 Well Name/No. PRUDHOE BAY UNIT Y-07A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20560-01-00 MD 14730 TVD 9185 Completion Date 5!10/2008 Completion Status WAGIN Current Status WAGIN U!C Y og Induction/Resistivity 25 Col 2052 14730 6/19/2008 MD ROP, DGR, EWR ~ ~,Lrog Induction/Resistivity 25 Col 2052 9183 6/19/2008 I TVD ROP, DGR, EWR ~VJcog ~r Induction/Resistivity 25 Col 2052 12745 6/19/2008 PB1 MD ROP, DGR, EWR i~-Cog Induction/Resistivity 25 Col 2052 12745 6/19/2008 P61 MD ROP, DGR, EWR Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y'/ N ~ Chips Received? ll_](J..P/--/ Analysis y1.P~ Received? Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~'-`~' Formation Tops l.~?~' N Date: J • MEMORANDUM n To: Jim Regg I~~~ 6~_~(~`O P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Monday, August 18, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y-07A PRUDHOE BAY UNIT Y-07A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~- Comm Well Name• PRUDHOE BAY UNIT Y-07A Insp Num: mitCS08081113154s Rel Insp Num: API Well Number: so-oz9-2osbo-0I-oo Permit Number: 207-toy-0 Inspector Name' Chuck Scheve Inspection Date: 8/8/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y-o7A Type Inj. ~' TVD slot IA azo zaoo zs7o zs7o p.T, zo7loso TypeTest SPT Test psi zl7s.zs pA o 0 0 0 Interval INITAL p~F P / Tubing Into tsto Into tsto Notes: Monday, August 18, 2008 Page 1 of 1 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, July 21, 2008 11:38 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU Y-07A / PTD # 207-105 Hi Art, Please reference the following well: Well Name: PBU Y-07A Permit #: 207-105 API #: 50-029-20560-01-00 Top Perf MD: 14545' Bottom Perf MD: 14585' This well began Injection on July 19, 2008 Method of Operations is: Produced Water No test data for Injection Wells 7/22/2008 t - ~ STATE OF ALASKA - -Old ALASKA IL AND GAS CONSERVATION COM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~ ~~~ JUN ~ ~ 2008 t ~~~ ~ ~~~5 ~ol~~. Cofn;~ISSiDra 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,oa zoAAC za„o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1b. Well Class:~fgC~~!_l;•~~0 ^ Development ~Q xploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 5/10/2008 ~' 12. Permit to Drill Number 207-105 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/27/2007 13. API Number 50-029-20560-01-00' 4a. Location of Well (Governmental Section): Surface: 1341' FNL 18' FW S 7. Date T.D. Reached 1/31/2008 ~ 14. Well Name and Number: PBU Y-07A ' , 1 L, EC. 34, T11 N, R13E, UM Top of Productive Horizon: 4279' FSL, 2720' FEL, SEC. 29, T11 N, R13E, UM 8. KB (ft above MSL): 79.58' ~ Ground (ft MSL): 49.96' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4347' FSL, 2792' FEL, SEC. 29, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 14644' 9111' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 644933 y- 5948917 Zone- ASP4 10. Total Depth (MD+TVD) 14730' 9185' 16. Property Designation: ADL 02828 ~7 +~?d!' TPI: x- 636697 y- 5954384 Zone- ASP4 Total Depth: x- 636624 y- 5954450 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 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): DIR / GR /PWD, USIT, DIR / GR /PWD, USIT, DIR / GR / RES `///YdOi+l ~v~Do?Oicff.L~ o?O/9~Ty0 22. CASING, LINER AND CEMENTING RECORD CASING tSETTING DEPTH MD; SETTING DEPTH ND HOLE AMOUNT Wi. PAR FT. GRgDE -TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2 20' Surface 2020' 17-1/2" 3720 cu ft Permafrost II 9-5/8" 47# L-80 28' 9302' 28' 5792' 12-1/4" 3264 cu ft LiteCrete 784 cu ft 'G' 7" 26# L-80 9106' 14397' 5706' 8904' 8-1/2" 811 cu ft LiteCrete 188 cu ft 'G' 4-1/2" 12.6# L-80 14221' 14729' 8760' 9184' 6-1/8" 95 cu ft Class'G' 23. Open to production or inject ion? ®Yes ^ No 24. TuewG RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7I8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 14226' 14149' MD TVD MD TVD 'l~il tvc.. 14545' - 14585' 9027 - 9061' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED Freeze Protect w/ 152 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac 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. ?__ ~~~H~~-r: ~li~i~ wJir_.... None S'!C~-D Form 10-407 Revised 02/2007 ~ I ~ ~ ! ~ ' I I 'O~I~TINUED ON REVERSE SIDE /' `~~ ' ' `~~ ~ : ~' ~- ~~ & ~ ~~ Jllk. 2 ~ X006 `~{~~ (~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 4 5338' 4055' None WS2 8166' 5295' CM3 9223' 5758' Top HRZ 12158' 7215' Base HRZ 12580' 7474' Miluveach 12602' 7490' Sag River 14412' 8917' Shublik A 14443' 8942' Sadlerochit 14542' 9025' HOT 14596' 9070' 45S6 /Zone 4Bu 14602' 9076' OWC 14618' 9089' Formation at Total Depth (Name): Sadlerochit /Zone 46 14602' 9076' 30. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is tru e and correct to the best of my knowledge. ~ Signed Terrie Rubble / ~ Title Drilling Technologist Date /' 8/t',~ 8 PBU Y-07A 207-105 Prepared By Name/Number. Terrie Hubble, 564-4628 DriliingEngineer: ,/ohnROSe, 564-5271 Well Number Permit No. / A royal No. INSTRUCTIONS GeNeRA~: 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 26: 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 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: Y-07 Common Name: Y-07 Test Date `Test Type '; Test Depth (TMD) Test Depth (TVD) ~ AMW Surface Pressure Leak Off Pressure (BHP) EMW 12/27/2007 FIT 2,020.0 (ft) 2,020.0 (ft) 9.30 (ppg) 350 (psi) 1,326 (psi) 12.64 (ppg) 1/9/2008 FIT 9,325.0 (ft) 5,801.0 (ft) 9.00 (ppg) 1,050 (psi) 3,762 (psi) 12.48 (ppg) 1/31/2008 LOT 14,397.0 (ft) 8,904.0 (ft) 8.40 (ppg) 900 (psi) 4,785 (psi) 10.35 (ppg) Printed: 3/27/2008 1:59:15 PI s ~ BP EXPLORATION Page 1 of 28 Operations Summary. Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date 'From - To ~', Hours ~ Task Code NPT .Phase ' Description of Operations 12/14/2007 12:00 - 00:00 12.00 MOB P PRE Rig released from 02-09C on 12/14/07 at 12:00 hours. Rig down and prepared to move. Moved shop, pit module and camp to Y-Pad (ETA on Y-Pad -24:00 hrs). 12/15/2007 12:00 - 23:00 11,00 RIGU P PRE Continue to mobilize rig f/DS02 and RU rig-up on Y-07Ai location. 23:00 - 00:00 1.00 WHSUR P DECOMP Rigged-up on well. Take on seawater. Commence well operations as follows: 1. Noted well pressures / OA = 200 psi, IA = 75 psi. 2. Rigged-up to bleed off pressure. Accept riq at 23:00 hrs on 12/15/2007,, 3. Held pre-spud meeting at tour change meeting at 23:30 hours. 4. Mobilized DSM to pull BPV. 12/16/2007 00:00 - 01:00 1.00 WHSUR P DECOMP Bleed IA (75 psi) and OA (200 psi) to zero. 01:00 - 03:00 2.00 WHSUR P DECOMP PU & RU DSM lubricator test to 500 si and ull BPV. LD lubricatior. 03:00 - 06:00 3.00 KILL P DECOMP PJSM, RU circulation lines to OA and top of tree to cuttings tank. Reverse circulate through the tubing cut and circulate out diesel until clean seawater returns at surface (5.5 bpm at 500 psi). While monitor well for 1 hour to confirm well "dead", ressure tested the OA to 2000 si f/30 minutes ood test . 06:00 - 07:30 1.50 BOPSU P DECOMP Blow down lines and remove from tree and dry rod in TWC (Cameron). Hook lines back ua and test TWC from above and below to 1000 si ood tests . 07:30 - 10:30 3.00 BOPSU P DECOMP PJSM, ND tree/adapter flange & removed from cellar. Functioned all LDS & thread hanger XO in by hand (7" IJ4S threads). 10:30 - 14:00 3.50 BOPSU P DECOMP NU BOP stack, CO outside lower mud cross vavle and install secondary annulus valve. 14:00 - 15:00 1.00 BOPSU P DECOMP RU 4-1/2" & 5" test joints & other BOP testing equipment. 15:00 - 00:00 9.00 BOPSU P DECOMP Be in testin BOP's & all related valves to 250 psi low / 4000 psi high, hydril to 2500 psi. Tests witnessed by WSL's D. Maskell, J. Rose & C. Kobuck and by NAD TP's C. Henley & B. Simonson. Test witness waived by AOGCC J. Crisp. 12/17/2007 00:00 - 03:30 3.50 BOPSU P DECOMP Continue BOP test (250 low/4000 high - 2500 on the bag). Testing witnessed by WSL J. Rose and NAD TP Bruce Simonson (witness waived by AOGCC). 03:30 - 05:00 1.50 BOPSU P DECOMP PJSM w/DSM, pull TWC w/lubricator (tested lubricator to 500 psi). 05:00 - 06:30 1.50 PULL P DECOMP PJSM, PU & RU tubing equipment, MU landing jt & floor valve, steam wellhead in preparation to pull 4-1/2" tubing from pre-rig cut at 2616' MD (Cameron & Camco on location). 06:30 - 09:00 2.50 PULL P DECOMP BOLDS, pull hanger free at 90K, free up 55K, pull hanger to rig floor, break-out landing joint & hanger, re-hang rig tongs, LD 4 joints of tubing, well started to flow from tubing. 09:00 - 09:30 0.50 PULL P DECOMP Install floor valve & shut-in well, initial SICP = 15 psi. MU top drive, line up to open bleeder & observed once fluid packed. SIDPP = 10 psi, SICP went to 0 psi. Clean pits (suck diesel out w/vac truck) while monitor shut in pressures. 09:30 - 12:00 2.50 PULL P DECOMP PJSM, circulate 255 bbls seawater taking returns through the choke at 5 bpm / 410 psi holding 200 psi back-preasure (overboard all returns to the cuttings tank). Open choke and bleeder, monitor well 15 minutes, open rams, blow down top Printed: 3/27/2008 1:59:21 PM BP EXPLORATION Page 2 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From --To ~ Hours Task Code NPT Phase ~ Description of Operations 12/17/2007 09:30 - 12:00 2.50 PULL P DECOMP drive and choke lines. Well dead. 12:00 - 16:00 4.00 PULL P DECOMP LD 4-1/2", 12.6 #, L-80 tubing from 1824', clean & clear rig floor(pulled 62 joints - SSSV & 10.95' cut joint). 16:00 - 17:00 1.00 BOPSU P DECOMP PJSM, MU 5" test joint & install test plug, test lower pipe rams 250 low/4000 psi hi has final ortion of BOP testin re uirements. 17:00 - 20:30 3.50 CLEAN P DECOMP 9-5/8" clean-out run, MU 8-1/2" bit, bit sub & 9-5/8" scraper on 5" DP and RIH to top tubing stub at 2610'. 20:30 - 22:00 1.50 CLEAN P DECOMP Circulate BU w/seawater the surface to surface with 30 bbl HVS at 410 gpm ~ 250 psi. Saw some debris on the initial BU. Well cleaned-up with return of the HVS. 22:00 - 23:00 1.00 BOPSU P DECOMP LD 2 joints DP and rack back 1 stand in the derrick, MU storm packer and set 32' below RKB, tested the oacker to 1000 psi. f/10 minutes (charted), blow down kill line. 23:00 - 00:00 1.00 BOPSU P DECOMP Begin ND process to swap the existing tubing spool for a full spacer spool (need full bore spacer spool to pull the 9-5/8" casing). 12/18/2007 00:00 - 06:00 6.00 BOPSU P DECOMP Split stack and ND. Remove secondary annulus valve. Remove tubing spool from cellar. Bring in spacer spool and install. Set stack and NU. Clean up cellar. 06:00 - 07:00 1.00 BOPSU P DECOMP PJSM. Make up retrieving tool and TIW valve. Screw into storm packer. Open TIW. Close pipe rams and body test breaks to ~~~ 2000 psi - OK. 07:00 - 09:00 2.00 DHB P DECOMP Pull RTTS. Break and lay down single and RTTS. POOH. Break and lay down bit, bit sub and scraper. 09:00 - 17:00 8.00 EVAL P DECOMP PJSM. Spot and rig up E-Llne. Make up tools. RIH with EZSV. Set at 2560' WLM. POOH with wireline. Test EZSV to 2500 si for 10 minutes - OK. Make up USIT/CCUGR, RIH to 2550' and log up. POOH and rig down E-Line. Top of cement at 2204'. 17:00 - 20:00 3.00 STCTPL P DECOMP PJSM. Make up 9-5/8" casing cutter. RIH to 2140'. Make up blower hose and top drive. 20:00 - 22:30 2.50 STCTPL N WAIT DECOMP Waiting on LRS, to displace arctic pack with diesel. 22:30 - 23:30 1.00 STCTPL P DECOMP Pump at 150 gpm with 430 psi. Open knives on cutter and check for collar. Set cutters on depth at 2140'. Cut 9-5/8" casin .Shut down, close Hydril and open OA. Stage pressure up to 750 psi to break circulation. Returns to cuttings tank. Shut down. 23:30 - 00:00 0.50 STCTPL P DECOMP Lay down single. Blow down top drive. Rig up head pin, cement hose and LRS. PJSM for displacement of arctic pack. 12/19/2007 00:00 - 05:30 5.50 STCTPL P DECOMP PJSM. Pressure test LRS lines to 4000 psi. Displace drill pipe with 34 bbls of treated diesel. Shut down, close Hydril, open annulus and pump 105 bbls of diesel. Pump at .5 to 2 bpm with 300 to 2150 psi. Pump last 20 bbls of treated diesel. Shut down, swap over to rig pumps and pump heated seawater at 100 gpm with 2550 psi. Bleed off, rig down and blow down. 05:30 - 07:30 2.00 STCTPL P DECOMP PJSM. POOH with casing cutter. 07:30 - 08:30 1.00 STCTPL P DECOMP PU and MU 9-5/8" s ear and sin le. 08:30 - 09:00 0.50 STCTPL P DECOMP Engage hanger, confirm latch. Back out lock down screws. MU top drive. Unseat hanger with 110k up. Pull to 185k. 09:00 - 10:00 1.00 STCTPL P DECOMP Break circulation. Close Hydril, pump through OA at 400 gpm with 900 psi for 2 bottoms up. Open bag, blow down lines. 10:00 - 19:30 9.50 STCTPL P DECOMP Pull han er to ri floor with 135k. Rig up false bowl and casing equipment. Release spear and lay down. Blow down top drive. Printed: 3/27/2008 1:59:21 PM BP EXPLORATION Page 3 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES `Date From - To Hours Task 'Code' NPT Phase Description of Operations 12/19/2007 10:00 - 19:30 9.50 STCTPL P DECOMP Break and lay down hanger. Pull and lay down 9-5/8" casing for '. Recovered 54 full joints, 1 cut joint at 8' and 19:30 - 21:30 2.00 STCTPL P 21:30 - 23:00 1.50 BOPSU P 23:00 - 00:00 I 1.00 I CLEAN I P 12/20/2007 100:00 - 03:30 I 3.501 CLEAN I P 03:30 - 04:30 I 1.001 CLEAN I P 04:30 - 08:00 I 3.501 CLEAN I P 08:00 - 11:00 I 3.001 CLEAN I P 11:00 - 14:00 3.00 CLEAN P 14:00 - 14:30 0.50 CLEAN P 14:30 - 16:30 2.00 CLEAN P 16:30 - 17:30 1.00 CLEAN P 17:30 - 19:00 1.50 CLEAN P 19:00 - 20:00 1.00 CLEAN P 20:00 - 22:30 2.50 CLEAN P 22:30 - 23:30 1.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 12/21/2007 00:00 - 03:00 3.00 CLEAN P 03:00 - 08:30 I 5.501 CLEAN I P 08:30 - 09:30 I 1.001 CLEAN 1 P 09:30 - 10:30 1.00 CLEAN P 10:30 - 14:00 3.50 CLEAN P 14:00 - 17:30 I 3.501 CLEAN I P 17:30 - 18:00 0.50 ~ CLEAN P hanger. DECOMP Rig down casing equipment. Clear and clean floor. DECOMP Make up 5" test joint. Install test plug. Test spacer witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. RD test equipment. DECOMP Pick up mill and scraper BHA to rig floor. Service break 9-5/8" spear assembly and lay down. DECOMP PU and MU 13-3/8" scraper/mill BHA_. PU 9 drill collars and 11 HWDP. Tag tight spot at 613'. DECOMP Drift through with 25k down and 25k over. Install blower hose. Wash and ream through tight spot. Free torque 2k, max torque 6k at 35 rpm. Remove blower hose. Blow down top drive. Cement and scale back on BU. DECOMP Continue to PU HWDP. Tag tight spot at 796'. Wash and ream throught tight spot. Cement back at BU. Continue picking up HWDP and washing throught tight spots at 827' and 846' to 867'. Torque 3-10k at 60 rpm. Pump at 625 gpm with 550 psi. WOB 1 k. Some metal shavings back to surface. DECOMP Lay down single of HWDP and POOH. Break and LD scraper, double pin XO and upper mill. Lay down Flex joint, lower mill and starter mill in pipe shed. DECOMP Wait on tools. Clear and clean floor. DECOMP PU 11-7/16" saved a and jars to rig floor. Prep tools. DECOMP Make up BHA to 946'. DECOMP RIH to 2139' with no roblems. Up weight 110k, down 115k. DECOMP Circulate hot seawater surface to surface. Pump at 500 gpm with 500 psi. DECOMP POOH to 946' with no problems. DECOMP POOH with BHA. Lay down 11-7/16" swedge. Make up 12" stabilizer. Clear floor. RIH with stabilizer BHA to 945'. DECOMP RIH to 2139' with no problems. Up weight 110k, down 115k. DECOMP POOH to 945'. DECOMP POOH with BHA. Lay down 12" stabilizer. PU 12-1/8" swedge. RIH with BHA to 944'. DECOMP RIH with HWDP. Run past previous tight spots with no problem. Hit tight spot at 1131'. Work swedge through till smooth. RIH and work throught tight spots at 1161'-1167', 1275', 1469' and 1548'. RIH to 2139'. DECOMP Circulate hot seawater surface to surface at 625 gpm with 710 psi. DECOMP POOH to 944'. DECOMP POOH with swedge BHA. Lay down 12-1/8" swedge, XO and bull nose. Bring up tools for mill run. Make up double pin XO and bull nose with 12-1/8" mill BHA to 959'. DECOMP RIH and tag at 1137'. Ream and mill tight snots at 1137', 1162-1185', 1277', 1471', 1534', 1548', 1563', 1709-1716' and 1836', then running to bottom at 2139'. Pump at 310 gpm with 185 psi. Torque at 1.5k to 6k rotating at 75 rpm. WOB 1 k. Up weight 110k, down 115k. DECOMP POOH to 959'. Printetl: 3/27/2008 1:59:21 PM BP EXPLORATION Page 4 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~, From - To Hours Task 'Code `NPT Phase 12/21/2007 18:00 - 20:30 2.501 CLEAN P 20:30 - 00:00 I 3.501 CLEAN I P 12/22/2007 100:00 - 18:00 I 18.001 CLEAN I P 18:00 - 19:00 1.00 CLEAN P 19:00 - 00:00 5.00 CLEAN P Description of Operations DECOMP POOH with 12-1/8" mill BHA. Change out with 12-1/4" mill BHA and RIH, tagging at 675'. DECOMP Ream and mill ti ht s ots at 675'-691', 776'-788', 806'-809', 848'-853', 861'-863', 869'-874', 942'-947', 953-961' and 971'-975'. Pumping at 325 gpm with 175 psi. Rotate at 50-85 rpm with 3-7k torque on, 1.5k torque off. WOB 1-3k. DECOMP Ream and mill ti ht s ots at 971'-1008', 1016'-1021', 1027'-1028', 1033-1035', 1043'-1047', 1101'-1103', 1116'-1125', 1133'-1143', 1146-1183', 1190'-1194' and 1212'-1215'. Pumping at 325 gpm with 180 psi. Torque 2-8k at 50 rpm. WOB 1-3k. Up weight 110k, down 115k, RT 100k. Work through each tight spot with no rotary using 2k or less down drag. Added safe tube to reduce pipe chatter. DECOMP Service top drive. DECOMP Continue milling in 13-3/8" casing, with 12-1/4" watermellon 12/23/2007 100:00 - 09:00 I 9.001 CLEAN I P 09:00 - 09:30 I 0.501 CLEAN I P 09:30 - 10:30 1.00 CLEAN P 10:30 - 14:30 4.00 CLEAN P 14:30 - 15:30 I 1.001 CLEAN I P 15:30 - 16:00 0.50 CLEAN P 16:00 - 16:30 0.50 CLEAN P 16:30 - 20:30 4.00 CLEAN P 20:30 - 21:30 I 1.001 CLEAN I P 21:30 - 22:30 1.00 CLEAN P 22:30 - 00:00 1.50 CLEAN P ~ 12/24/2007 ~ 00:00 - 00:30 ~ 0.50 CLEAN ~ P 00:30 - 01:00 I 0.501 DHB I P mill, workin throu h ti ht s ots at 1272'-1277', 1283'-1292', 1313'-1318' and 1328'-1330'. Continue to pump at 325 gpm with 175 psi. Torque 3-5k at 90 rpm. WOB 1-3k. Up weight 105k, down 100k, RT 100k. DECOMP Milling through 13-3/8" casing with 12-1/4" watermellon mill, workin through tight spots at 1337'-1340', 1361'-1369', 1389'-1392', 1429'-1441', 1467'-1480', 1499'-1503', 1506'-1508', 1517'-1521' and 1545'. Pumping at 325 gpm with 155 psi. Torque 2-7k at 90 rpm. WOB 1-3k. Up weight 100k, down 105k, RT 103k. Pumping tubes and sweeps as needed. DECOMP Pump sweep at 1545', pumping at 330 gpm with 150 psi. Install rubbers and blow down top drive. DECOMP PJSM. POOH to 947'. DECOMP PJSM. Rack back drill collars, HWDP and jars. Inspect mill. Mill 1/32" under au e. Cutting structure was in good shape. Brea c bull nose and mill. LD beaver slide. Clean and clear floor. PU new 12-1/4"__watermellon mill, make up with bull nose to jars. RIH with HWDP and drill collars to 947'. DECOMP PJSM. Cut and slip 90' of drilling line. Inspect brakes, chains and hoses. Lube Elmago splines. DECOMP Service top drive. DECOMP RIH to 1481' and to u . DECOMP Ream casin from 1481'-1485' and 1530'-1569'. Pump at 325 gpm with 135 psi. Torque 3-8k at 90 rpm. Wash and ream from 1569'-2139' at 90 rpm with short areas easily reaming clean, at 2-3k torque. DECOMP Pump hi-vis sweep at 650 gpm with 575 psi. Pump hi-vis spacer and displace well with hot seawater. DECOMP Blow down top drive. Remove blower hose. POOH to 947'. DECOMP Stand back HWDP and drill collars. Break and lay down jars and bumper sub. Break bull nose and lay down mill. Mill in gauge with no wear. Clear and clean floor. Bring EZSV up beaver slide. DECOMP PJSM. Lay mill down beaver slide. Blow down choke and kill lines. Clear and clean floor. WEXIT PJSM. PU a stand of drill pipe. Make up EZSV running tool and 13-3/8" EZSV. Pnntetl: 3/27/2008 1:59:'Ll PM BP EXPLORATION Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Event Name: REENTER+COMPLETE Start: 12/1/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Page 5 of 28 ~ Spud Date: 4/22/1981 End: 2/6/2008 Date From - To Hoiars Task ,Code NPT Phase Description of Operations 12/24/2007 01:00 - 02:30 1.50 DHB P WEXIT PJSM. RIH with 13-3/8" EZSV to 2055',at 60 fpm as per Halliburton Rep. Make up top drive and pump at 125 gpm with 85 psi. Circulate 1 drill pipe volume. Bleed off. 02:30 - 03:00 0.50 DHB P WEXIT Pull u and soot top of EZSV at 2050'. Rotate pipe 35 turns to the right. Pick up 15k over. Wait 1 minute. Pick up in 3 stages to 60k over and set EZSV. Pick up 10' and rotate 20 turns to the right. Shut down, slack off and set 25k down on plug. Set verified. Rack back 1 stand. Make up top drive. 03:00 - 03:30 0.50 DHB P WEXIT PJSM. Test 13-3/8" casing and EZSV to 2000 psi for 30 03:30 - 05:00 1.50 DHB P WEXIT 05:00 - 09:00 4.00 BOPSU N HMAN WEXIT 09:00 - 12:00 I 3.00 I BOPSUR N I HMAN I W EXIT 12:00 - 18:00 6.00 BOPSU P 18:00 - 20:30 2.50 CLEAN P 20:30 - 23:00 2.50 CLEAN P 23:00 - 23:30 0.50 CLEAN P 23:30 - 00:00 0.50 CLEAN P 12/25/2007 00:00 - 02:00 2.00 CLEAN P 02:00 - 02:30 0.50 STWHIP P 02:30 - 06:00 3.50 STWHIP P 06:00 - 07:00 1.00 STWHIP P 07:00 - 09:00 2.00 STWHIP P 09:00 - 09:30 I 0.501 STWHIPI P 09:30 - 10:00 0.50 STWHIP P 10:00 - 12:00 2.00 STWHIP P 12:00 - 14:30 I 2.501 STWHIPI P minutes - OK. Bleed off. Break out and blow down top drive and kill line. PJSM. POOH with EZSV running tool and lay down. PJSM. Clear and clean floor. Remove mousehole. Remove riser. Nipple down stack and spacer spool. Set stack back. Remove spool from cellar and bring in new spacer spool. Casing head in good shape. Set spacer spool on stack and check wear ring measurements. All ok. PJSM. NU stack and spacer spool. Install mousehole, riser and turnbuckles. Run in test plug. Fill stack and check for leaks. Fill choke. Clear and clean cellar. Test BOPE to 250 psi low, 4000 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 Bill Decker and Toolpusher Cleve Coyne. Pull test plug. Install wear ring. Blow down. PJSM. Pick up and MU motor, bit, float sub, flex stabilizer, 1 stand of drill collars, jar and HWDP to 816' for drift run. PJSM. PU drill pipe and RIH. Tag rough spots at 1118', 1128'-1163', 1928' and 1518'. Drifted through all with 15k down drag. Tap EZSV at 2050'. POOH to 816'. Stand back HWDP. Lay down jars. PJSM. Lay down drift run BHA. Break bit. LD motor. Clear and clean floor. Blow down kill lines. PJSM. Pick whipstock BHA up beaverslide.. PJSM. PU bumper sub, XO and UBHO. Make up window mill. Orient mill to UBHO. Verify gyro will seat. Lay down. Pick up whipstock slide and run in hole. Pick up mill/UBHO assembly and tie into slide. RIH with drill collars and HWDP to 962'. PJSM. RIH to 2017'. PJSM. Rig up gyro sheaves and tool. PU single. RIH with gyro to 1983'. Work pipe and orient whipstock slide. Tag UBHO with gyro tool on seat. POOH with gyro. Verify punch. Whipstock slide oriented to 313 degrees. Tie gyro in derrick and secure lines. PJSM. Pick up drill pipe single. Slack off and set whipstock anchor down on EZSV with 35k. Set anchor and shear o a the same time. Lay down 2 drill pipe singles. PJSM. POOH to 962'. PJSM. POOH with HWDP and drill collars. Break mill, bit sub, XO and UBHO sub. Lay down bumper sub. Clear and clean floor. PJSM. Make up window mill, lower mill, flex joint, upper mill, WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Nrinced: 3iziizous i:ba:zi rnn BP EXPLORATION Page 6 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date I' From - To 'Hours Task .Code NPT Phase ~ Description of Operations 12/25/2007 12:00 - 14:30 2.50 STWHIP P WEXIT float sub, drill collars and HWDP to 946'. 14:30 - 16:00 1.50 STWHIP P WEXIT RIH picking up drill pipe to 1983'. Install blower hose. Make up stand and tag top of whipstock at 2020'. 16:00 - 17:00 1.00 STWHIP P WEXIT Pump 40 bbl hi-vis spacer and displace well with 290 bbls 9.3 ppg LSND milling fluid. Pump at 650 gpm with 450 psi. Up weight 110k, down 112k, RT 112k. 17:00 - 23:00 6.00 STWHIP P WEXIT Mill 12-1/4" window in 13-3/8" casing from TOW at 2020' to 2024'. Pump at 650 gpm with 470 psi. Rotate at 75-90 rpm with torque 10-16k. WOB 5-15k. With WOB at 13k and torque of 12-14k there was a loud cracking noise and the pipe had a ? ~ •_ ~ ~ ~ 1 sudden and severe bounce. The torque went to the free torque of 1200 and the pump pressure dropped 50 psi. Pull up out of ~ , '~~ window and run back through with no torque or drag. Tag up at 2024' with 2k WOB and experience severe bounce with no torque. Pull up immediately. 23:00 - 00:00 1.00 STWHIP N DFAL WEXIT Monitor well while mixing dryjob. Pump dryjob. Blow down top drive. Remove blower hose and POOH to 1323'. Mud weight in and out 9.3 ppg. 12/26/2007 00:00 - 00:30 0.50 STWHIP N DFAL WEXIT PJSM. POOH to 946'. 00:30 - 04:00 3.50 STWHIP N DFAL WEXIT PJSM. Rack back HWDP and drill collars. PU and inspect upper mill, lower mill parted at the base. Left window mill and fishin neck in hole at 5.13'. Break out mills and float sub. Clear and clean floor. Lay mills down beaverslide. 04:00 - 05:00 1.00 STWHIP N DFAL WEXIT PJSM. Service top drive. Inspect brakes and draworks. Lube Elmago Splines. 05:00 - 06:00 1.00 STWHIP N DFAL WEXIT PU bumper sub and jars for fishing run. 06:00 - 07:00 1.00 FISH N DFAL WEXIT PJSM. MU spear on a stand of HWDP and RIH to 646'. 07:00 - 07:30 0.50 FISH N DFAL WEXIT PJSM. RIH to 1969'. PU stand. MU top drive. Establish circulation at 200 gpm with 400 psi. Up weight 85k, down 85k. Slack off to top of fish at 2019'. Shut off pump. Slack off 10k down. Engauge fish. PU 100k and break fish free at 105k. 07:30 - 08:30 1.00 FISH N DFAL WEXIT PJSM. POOH to 646'. Rack back HWDP. Remove bushings and pull fish to rig floor. 08:30 - 10:30 2.00 FISH N DFAL WEXIT PJSM. Release grapple from fish. LD fish and spear. Clear and clean floor. 10:30 - 13:00 2.50 STWHIP N DFAL WEXIT PJSM. MU window mill and upper mill. Pick up 1 stand HWDP, Make up drill collars and HWDP to 967'. 13:00 - 14:00 1.00 STWHIP N DFAL WEXIT RIH to 2018'. 14:00 - 00:00 10.00 STWHIP P WEXIT Fill pipe. Up weight 110k, down 112k, RT 112k. Ream to 2024'. Free torque 1 k, torque on 2-5k at 90 rpm. Pump at 625 gpm with 430 psi. WOB 1-2k. Mill window to 2043'. Torque 1-8k at 90 rpm. WOB 2-7k. Pump at 630 gpm with 460 psi. 12/27/2007 00:00 - 04:00 4.00 STWHIP P WEXIT Mill from the middle of the 12-1/4" window plus 20' of new_ formation to 2052'. Work window -clean. Total steel recovered - 730 Lbs. 04:00 - 05:30 1.50 STWHIP P WEXIT Circulate "Super Sweep". Mud wt. in and out 9.3 ppg. 05:30 - 06:00 0.50 STWHIP P WEXIT Perform FIT to 12.6 . EMW w/ 350 psi. @ surface 06:00 - 07:00 1.00 STWHIP P WEXIT PJSM. POOH to 967'. Rack back HWDP. 07:00 - 09:00 2.00 STWHIP P WEXIT PJSM. Lay down drill collars. Stand back HWDP. Inspect window mill and upper mill - in gauge. Clear and clean floor. 09:00 - 10:30 1.50 STWHIP P WEXIT Pick up running tool, run in and pull wear ring. Make up stack flushing tool. Flush stack at 800 gpm with 170 psi. Function all BOPE. Blow down choke and kill lines and top drive. Lay down Printed: 3iz~/zoos i:5a:n rnn BP EXPLORATION Page 7 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task 'Code NPT Phase Description of Operations 12/27/2007 09:00 - 10:30 1.50 STWHIP P WEXIT Baker tools. Run wear ring in. Lay down running tool. 10:30 - 11:30 1.00 STWHIP P WEXIT PJSM. Pick tools for 12-1/4" BHA up beaverslide. 11:30 - 12:30 1.00 STWHIP P WEXIT Service and tube rig. 12:30 - 16:30 4.00 STWHIP P WEXIT PJSM. MU bit, float sub and Geoflex. MU MWD tools, stabilizer, pulser, float sub and UBHO. Scribe offset and upload MWD. Pick up flex drill collars and XO. MU drilling jar and HWDP to 845'. 16:30 - 17:00 0.50 STWHIP P WEXIT RIH to 1977'. Drift tight spot at 1855'. Install blower hose and fill pipe. Pass through window to 2047'. Kick on pumps to break gels. 17:00 - 20:30 3.50 DRILL P INTi PJSM. Pull back to 2038', break out single. Rig up and run E-line gyro. Orient bit to 321 degrees. POOH with E-line, hang back tool. Make single back up and RIH to 2047'. 20:30 - 00:00 3.50 DRILL P INT1 Wash to 2052'. Drill ahead to 2105'. Break off a double. Run a gyro survey. Pumping at 600 gpm with 920 psi. Torque off bottom 1-2k, on bottom 2-4k at 35 rpm. WOB 3-7k. Drill ahead to 2167' MD. AST-1.32, ART-1.00. Mud weight in and out 9.3 ppg. Up, down and RT weight 95k. ECD 9.63. Establish baseline ECD at 9.5 ppg at 750 gpm with 1300 psi and 800 gpm with 1465 psi. Rotate at 80 rpm with 2k free torque. 12/28/2007 00:00 - 17:30 17.50 DRILL P INT1 Directional drill ahead to 3140' MD, 3000' TVD. Pumping at 750 gpm with 1350 psi off bottom, 1550 psi on bottom.Torque off bottom 3-4k, on bottom 4-6k at 90 RPM. WOB 10-30k. Mud weight in and out 9.3 ppg. Up weight 105k, down 100k, RT 105k. Rigged down SS E-line and Gyro Data tools. Continue to drill ahead to end of build section at 3771' MD, 3372' TVD. Pump at 750 gpm with 1500 psi off bottom, 1680 psi on bottom. Torque 4-5k off bottom, 5-7k on bottom at 90 rpm. WOB 15-25k. Up weight 115k, down 103k, RT 112k. Mud weight in and out 9.3 ppg. AST 2.16, ART 1.66. ECD 9.76. 17:30 - 18:30 1.00 DRILL P INT1 Circulate hi-vis sweep at 755 gpm with 1500 psi. Increase in cuttings minimal. In and out weight 9.3 ppg. 18:30 - 21:00 2.50 DRILL P INT1 PJSM. POOH to 2080'. Up weight 125k, down 100k. Hole swabbing at times. Slow down pull rate. Hole fill at calculated. Wipe every stand with 30-40k over, up to 2450' MD. Wipe clean then no problems. 21:00 - 22:00 1.00 DRILL P INT1 MAD pass from 2080' to 1820' at 300 fph max pulling speed. 22:00 - 22:30 0.50 DRILL P INT1 POOH to 845'. Flush BHA with fresh water. 22:30 - 00:00 1.50 DRILL P INT1 PJSM. Rack back HWDP. Lay down jars. Break UBHO sub. PU and plug into MWD tool and down load. 12/29/2007 00:00 - 02:30 2.50 DRILL P INT1 PJSM. Download MWD. Lay down MWD tools, motor and bit. Clear and clean floor. 02:30 - 08:30 6.00 DRILL P INT1 PJSM. PU Geo-Pilot 12-1/4" BHA. Make up Geo-Pilot, DM and bit. Upload MWD. PU jars, CCV and HWDP to 851'. 08:30 - 10:00 1.50 DRILL P INT1 PJSM. Pick up drill pipe to 1983'. MU ghost reamer at 1225'. 10:00 - 11:30 1.50 DRILL P INTi PJSM. Cut and slip 258' of drilling line. Service top drive, draworks and crown. 11:30 - 12:00 0.50 DRILL P INT1 Fill pipe at 250 gpm with 200 psi. Install blower hose. Up, down and RT weight 100k. 12:00 - 13:30 1.50 DRILL N SFAL INT1 Repairs made to rig rod washer system. 13:30 - 14:30 1.00 DRILL P INT1 PJSM. PU remaining drill pipe to 2550'. 14:30 - 16:30 2.00 DRILL P INT1 PJSM. RIH to 3096'. Make up top drive. Pump at 200 gpm with Printed: 3/27/2008 1:59:21 PM B'P EXPLORATION Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To Hours Task Code NPT 12/29/2007 14:30 - 16:30 2.00 DRILL P Start: 12/1 /2007 Rig Release: 2/6/2008 Rig Number: 2ES Page 8 of 28 ~ Spud Date: 4/22/1981 End: 2/6/2008 Phase Description of Operations INT1 275 psi. Rotate at 30 rpm. Up weight 115k, down 100k. Tr 16:30 - 18:00 1.50 DRILL N DPRB INT1 18:00 - 19:00 1.00 DRILL N DPRB INTi 19:00 - 21:00 2.00 DRILL N SFAL INT1 21:00 - 00:00 3.00 DRILL P INTi 12/30/2007 100:00 - 21:30 21.501 DRILL P INT1 21:30 - 23:00 I 1.501 DRILL I P I I INT1 23:00 - 00:00 I 1.001 DRILL I P I I INT1 12/31/2007 (00:00 - 03:30 3.50 ~ DRILL ~ P ~ ~ INTi 03:30 - 04:00 I 0.501 DRILL I P I I INT1 04:00 - 05:00 I 1.001 DRILL I P I I INT1 05:00 - 00:00 ~ 19.00 ~ DRILL ~ P ~ ~ INT1 PJSM. POOH to 1229'. Break and LD ghost reamer. PJSM. RIH to 1979'. Make up top drive and fill pipe at 200 gpm with 300 psi. RIH to 3040' and hang up. Unable to work through. Make up top drive and work through area with 220 gpm and 480 psi. Rotate and pump the rest of the way to bottom. Kick pumps up to 775 gpm with 1494 psi. Rotate at 90 rpm with 4-5k torque off bottom. Geo-Pilot not responding to signals. Troubleshoot SS Geo-Pilot system. Signal acctuator not sending signals. Trouble was loose wire connection. Directional drill ahead to 4034' MD, 3487' TVD. Pump at 810 gpm with 1650 psi off bottom, 1680 psi on bottom. Torque 5-6k off bottom, 6-8k on bottom at 150 rpm. Up weight 115k, down 100k, RT 110k. WOB 30-32k. Mud weight in 9.3 ppg, out 9.4 ppg. ART 2.22. ECD 9.7 Directional drill ahead to 5343' MD, 4055'TVD. Pumping at 810 gpm with 1860 psi off bottom, 1860 psi on bottom. Torque 9k off bottom, 9-13k on bottom at 150 rpm. WOB 25-30k. Up weight 130k, down 105k, RT 115k. Mud weight in and out 9.4+ ppg. ECD 9.96 Continue to drill ahead to 6132' MD, 4401' ND. Pump at 830 gpm with 2000 psi off bottom, 2025 psi on bottom. Torque 10-12k off bottom, 11-15k on bottom at 150 rpm. WOB 25-30k. Control drill coal seams at 5293' MD, 5409' MD, 5568' MD and 5998' MD with no problems. Up weight 155k, down 105k, RT 125k. Mud weight in 9.3 ppg, out 9.4 ppg. ART 15.03 PJSM. Pump weighted sweep surface to surface at 820 gpm with 1990 psi. Riciprocate and rotate at 150 rpm with 10-11 k torque. Blow down TD and Geo-Pilot skid. Mud weight in/out 9.4 ppg. ECD before shutting down 9.77. PJSM. POOH to 5093' MD. Up weight 165k, down 105k. Overpulls of 20-50k but wiping clean. Hole taking correct displacement. No swabbing. POOH to 3675' MD. Pulling tight at 4995' MD, 45k overpull. Pump and backream out to 3678' MD. Pump at 830 gpm with 1780 psi. Rotate at 120 rpm with 7-12k torque. Circulate 1.5 times BU at 830 gpm with 1730 psi. Torque 6k at 155 rpm. PJSM. RIH to 6040'. Taking weight at 5340, 50k down. Wipe clean. Drag 10-15k higher in section not backreamed. Make up top drive, wash to bottom at 800 gpm. Directional drill ahead to 6240' MD, 4468' TVD. Pump at 822 gpm with 2170 psi. Torque 12-15k at 150 rpm. WOB 15-25k. Mud weight in and out 9.3 ppg. Continue to drill ahead to 8021' MD, 5232' TVD. Pump at 825 gpm with 2280 psi off and on bottom. Torque 14-17k off bottom, 19-23k on bottom at 135-155 rpm. WOB 20-30k. Up weight 200k, down 105k, RT 140k. Mud weight in 9.3 ppg, out Printed: 3/27/2008 1:59:21 PM ~ ~ BP EXPLORATION Page 9 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code ' NPT Phase Description of Operations 12/31/2007 05:00 - 00:00 19.00 DRILL P INT1 9.4 ppg. ART 14.28. ECD 9.84 1/1/2008 00:00 - 02:30 2.50 DRILL P INT1 Drill ahead to 8211' MD, 5314' TVD. Pump at 826 gpm with 02:30 - 03:30 ~ 1.00 ~ DRILL ~ N SFAL INTi 03:30 - 12:00 ~ 8.50 ~ DRILL ~ P 12:00 - 16:30 I 4.501 DRILL I P 16:30 - 20:00 I 3.501 DRILL I P 20:00 - 00:00 ~ 4.00 ~ DRILL ~ P 1/2/2008 ~ 00:00 - 01:30 ~ 1.50 ~ DRILL ~ P 01:30 - 02:30 I 1.001 DRILL I P 02:30 - 12:00 I 9.501 DRILL I P 12:00 - 13:00 I 1.001 DRILL I P 13:00 - 14:00 I 1.001 DRILL I P 14:00 - 14:30 0.50 DRILL P 14:30 - 16:00 1.50 DRILL P 16:00 - 16:30 0.50 DRILL P 16:30 - 18:00 1.50 DRILL P 18:00 - 18:30 0.50 DRILL P 18:30 - 21:00 2.50 BOPSU P INTi INT1 INTi INT1 INT1 INT1 INTi INT1 INTi INTi INT1 INT1 INTi INT1 INTi 2300 psi. WOB 17-20k. Torque 18-22k at 135 rpm. Mud weight in 9.2 ppg, out 9.3+ppg. Circulate, rotate and reciprocate while repairing pop-off. Pop Off went out because of too large an orfice on Geo-Pilot skid. - Changed to smaller orfice. Drill ahead to 8964' MD, 5642' TVD. Pump at 805 gpm with 2440 psi. Torque 20-24k at 135 rpm. WOB 25-30k. Mud weight in 9.3 ppg, out 9.4 ppg. AECD 9.98 ppg. CECD 9.7 ppg. Drill to TD C~3 9305' MD. 5793' TVD. Pump at 780 gpm with 2318 psi. Torque on 22-24k, off 21-21k ~ 132 rpm. WOB 20k, Up 217k, DN 110k. Mud weight in 9.5 ppg, out 9.5+ppg. Circulate bottoms up at TD of 9305'. 17-19k tt-Ibs l~ 140 rpm. 810 gpm at 2400 psi. Circulate weighted sweep of 11.8 ppg surface to surface. Shakers clean. 9.5 ppg in and out. Monitor well -static. Backreaming out of hole to 6485' MD. ', 18-20k ft-Ibs C~ 150 rpm. Pump at 800 gpm at 2100 psi. Backream from 6,485'to 6,160'. -800 gpm ~ 2175 psi, 15-18 KfUlbs C~3 145 RPM -Pull 50K over, no forward progress -Carpe chunks of coal coming over s akerc -CECD 9.7 ppg, AECD 10.1 ppg Run back in hole to 6370', Circ bottoms up -807 gpm 02188 psi, 13-14 Kft/Ibs ~ 150 RPM -Cuttings decreased by 75% after bottoms up, AECD 9.9 ppg -Attempted to pump out of hole from 6,370' to 6,160', pulling 30K over Backream out of hole from 6130' to 2074'. -810 GPM ~ 2,180 psi, 13-14 Kft/Ibs ~ 150 RPM. -TO = 10-18k ft-Ibs. Attempt to pull BHA through window, pull 50k over at 2052'. Turn string, try again - no go. Establish circ C~? 750 gpm, PU to tight spot w/15k over ratchet string. Break free and pull through window C~ 2020' w/ 105k up /90k dn. PJSM. Rack back stand, drop ball, open circ sub. -est circ rate to 800 gpm ~ 450 psi. -Bring rotary to 165 rpm, TO 2k. -CBU, pump dry job. Monitor well -static. PJSM. POH from 1979'to 846'. LD single HWDP. PJSM. Rack back HWDP & LD BHA #16 to float. Download MWD. LD remaining BHA #16. Pull wear ring and install test plug. Clean and clear rig floor. PJSM. C/O top rams to 9-5/8" and test to 250/4000 psi. Good test. Printed: 3/27/2008 1:59:21 PM • BP EXPLORATION Page 10 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From- To Hours Task Code NPT Phase ~ Description of Operations 1/2/2008 18:30 - 21:00 2.50 BOPSU P INT1 Witness of test waived by AOGCC rep Lou Gramaldi. Test witnessed by WSL Joey LeBlanc and NTP Jon Castle. 21:00 - 22:30 1.50 CASE P INT1 PJSM. PU 9-5/8" XO's and csg tools up beaverslide. 22:30 - 00:00 1.50 CASE P INT1 Rig up 9-5/8" csg equipment. 1/3/2008 00:00 - 02:30 2.50 CASE P INT1 Continue RU 9-5/8" csg equipment. 02:30 - 03:00 0.50 CASE P INT1 PJSM w/crew, Nabors Csg, HES, and Baker. 03:00 - 04:30 1.50 CASE P INT1 PU 9-5/8" 47# BTC-M shoe track, Baker-LOK joints 1-4. -Test floats - ok 04:30 - 08:30 4.00 CASE P INT1 RIH w/ 9-5/8" L-80 47# BTC-M casing from 168' to 1881'. -Make up to mark, average TO 10,000 ft-Ibs. -Install 1 straight blade centralizer per joint. 08:30 - 09:00 0.50 CASE N RREP INT1 Set 9-5/8" casing collar on riser while RIH and bent riser. POH and pulled Riser out of BOPE, causing a 10 gallon spill in cellar. 09:00 - 11:00 2.00 CASE N SFAL INT1 Franks tool leaking. PJSM. Remove Franks tool & rebuild (change out slide and valve). 11:00 - 12:00 1.00 CASE N RREP INT1 PJSM. Remove Riser, remove turn buckles. 12:00 - 16:00 4.00 CASE N RREP INTi Jack up front of substructure, lay down 3x12's, set down substructure. Change out air boots, install riser, rig up power tongs. 16:00 - 18:00 2.00 CASE P INT1 PJSM. RIH w/ 9-5/8" L-80 BTC-M csg to 1963'. -Replaced jt #48 due to galled threads and collar on jt #47. -Continue RIH to 2042'. 18:00 - 19:00 1.00 CASE P INT1 Establish circ ~ 261 gpm and 338 psi. Begin blending mud from 9.4 ppg to clean 9.2 ppg. 19:00 - 00:00 5.00 CASE P INT1 PJSM. Continue RIH w/ 9-5/8" csg to 4026' -Jt #55, 56, and 57 were hanging on window, slack off 80k dn, rotate jt #57 1/4 turn, slack off, and break free. - Continue RIH to 4026' w/ no issues. -Fill csg every jt, circulate every 13 jts @ 5 bpm, 360 psi. 1/4/2008 00:00 - 10:00 10.00 CASE P INTi Continue to RIH w/ 9-5/8" 47# L-80 BTC-M csg to 6783'. -Fill csg every jt, circ every 13 jts C~ 5 bpm. 06:00 - 14:00 8.00 CASE P INTi PU 9-5/8" BTC-M to Hydril XO, Continue to RIH w/ 9-5/8" 47# L-80 H dril 563 from 6783' to 9305'. -Fill csg every jt, circ every 13 jts @ 5 bpm. -PU BOT external cs ckr and HES ES Cementer ~ 7310'. -Est circ on bottom C~? 215 gpm, 501 psi. -PU wt 420k, SO 160k 14:00 - 15:30 1.50 CASE P INTi Circ and condition hole @ 215 gpm, 500 psi. 15:30 - 16:00 0.50 CEMT P INT1 PJSM. L/D Franks tool, blow down top drive, XO and M/U cement head. 16:00 - 16:30 0.50 CEMT P INTi Circ C~ 215 gpm, 450 psi. -Reciprocate Pipe 20' strokes. 16:30 - 18:00 1.50 CEMT N WAIT INTi Connection to SLB computer not working, Wait on SLB to troubleshoot. 18:00 - 20:00 2.00 CEMT N WAIT INT1 Wait on SLB Pump Truck. Bearing locked up in pump truck on location. Bring new truck to location. 20:00 - 00:00 4.00 CEMT P INT1 PJSM. Switch to SLB pumps. -Pump 5 bbls fresh water to cmt head. Drop bottom wiper plug. -Test lines to 4000 psi. -Load top plug. -Pump 50 bbls 10.5 ppg Mud Push II -Pump 575 bbls 11.5 ppg LiteCrete Printed: 3/27/2008 1:59:21 PM • BP EXPLORATION Page 11 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase I' Description of Operations 1/4/2008 20:00 - 00:00 4.00 CEMT P INT1 -Drop top plug w/ 5 bbls water, switch over and displace w/ rig pumps. 1/5/2008 00:00 - 02:00 2.00 CEMT P INT1 Continue to displace 1st stage cmt job w/ rig pumps. -Reci rocate i e 20' stroke for first 473 bbls of displacement. -Bump plug w/ 686 bbls 9.4 ppg mud. -Pressure up to 1400 psi, hold for 3 minutes. -Bleed pressure and check floats -holding. - 01:20 CIP -Load closing plug for ES cementer. 02:00 - 04:00 2.00 CEMT P INT1 Pressure u too en ECP sheared o en and inflated ~ 1900 psi. Switch to SLB pumps, pressure up to 3150 psi and open ES Cementer. Circulate out cement in annulus ~ 9 bpm, 400 psi. -115 bbls cmt contaminated mud back to surface after circulatin out annulus. Pressure up backside and csg to 2000 psi for 10 minutes to test ECP - ok. Bleed off. 04:00 - 06:00 2.00 CEMT P INT1 Pump 2nd stage cement job. Pump 5 bbls water followed by 28.6 bbls of 11.5 ppg MudPush II spacer, and 138 bbls 15.8 ppg class G slurry. Drop Closing plug, switch to rig pumps and displace w/ 146 bbls 9.4 ppg mud ~ 8 bpm, 600 psi. Bump plug ~ 700 psi, continue pressuring up to 1620 psi, positive indication ES Cementer shut. CIP ~ 05:25. 30 bbls cmt back to surface. 06:00 - 07:00 1.00 CASE P INT1 Flush and Drain BOPE. UD cmt head and slips. 07:00 - 11:00 4.00 WHSUR P INTi N/D BOP and spacer spool, set 9-5/8" emergency slips w/ 150k over. Suck fluid out of 9-5/8" jt. Rig up Wach's cutter and cut 9-5/8" csg. UD 16.73' of 9-5/8" jt. 11:00 - 12:00 1.00 WHSUR P INT1 Remove riser, split and remove spacer spool, stand back BOP's. 12:00 - 17:30 5.50 WHSUR P INT1 PJSM. Jack up rig to open back doors, bring tubing spool in, lower doors, lower rig. Install tubing spool. Test packoff and flange to 3800 psi for 30 minutes -good test. N/U BOPE. 17:30 - 23:00 5.50 WHSUR N HMAN INTi PJSM. Blow water and steam lines down in pits and water line on sub. Move pit module out, move sub foward, level sub, spot pits, plug pits in. 23:00 - 23:30 0.50 WHSUR P INTi PJSM. Install riser, put turn buckles on. 23:30 - 00:00 0.50 WHSUR P INTi PJSM. Change out rams from 9-5/8" to 3-1/2" x 6" variables. 1/6/2008 00:00 - 01:30 1.50 WHSUR P INT1 Finish nipple up and change rams to 3-1/2" x 6" variable. 01:30 - 03:30 2.00 WHSUR P INT1 Pull wear ring, install test plug, rig up BOP test equipment. -Plumb water line from brine tank to test pump. 03:30 - 10:30 7.00 WHSUR P INT1 Test BOPE 250psi/2500 psi Annular and 250psi/4000 psi Rams. -5" test joint for rams. -Witness of test waived by AOGCC rep John Crisp. -Test witnessed by NTP Jon Castle and WSL Joey LeBlanc and Chris Kobuck. -Pull test plug, install wear ring, rig down test equipment, and blow down surface equipment. 10:30 - 12:00 1.50 DRILL P INT2 PJSM. PU BHA # 17 to rig floor and prep. MU Geo Pilot -bit and flex DC. 12:00 - 15:30 3.50 DRILL P INT2 PJSM. MU BHA # 17, up load MWD tools. Printed: 3/27/2008 1:59:21 PM ~ ~ BP EXPLORATION Page 12 of 28 Operations Summary Report. Legal Well Name: Y-07 Common W ell Name: Y-07 Spud Date: 4/22/1981 Event Nam e: REENTE R+COM PLET E Start : 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To ~ Hours Task .Code NPT I Phase Description of Operations __ _- 1/6/2008 15:30 - 16:30 1.00 DRILL P INT2 PJSM. Cut and slip 130' of drill line. 16:30 - 17:30 1.00 DRILL P INT2 PJSM. Service top drive, drawworks, crown, and turn kelly hose. 17:30 - 20:00 2.50 DRILL P INT2 PJSM. PU 5" DP singles from 836' to 1955'. -Ta cement, CBU ~ 500 m, 1200 si. -Close circ sub. -Picked up 8-3/8" ghost reamer ~ 1212'. 20:00 - 20:30 0.50 DRILL P INT2 PJSM. Test casin to 4000 si. -Pressure u to 4000 si, sudden) bled to 2000 si. Held for 10 minutes, then bled to 0 psi. -Closing plug blew down off seat into ES Cementer body. 20:30 - 00:00 3.50 DRILL P INT2 Begin drilling out plug w/ 5-25k WOB, 40-80 rpm, 250-450 gpm. Drill from 1983' to 1986.5'. 1/7/2008 00:00 - 01:30 1.50 DRILL P INT2 Continue to drill out plug in ES cementer from 1986' to 2000'. -450 gpm C~ 1020 psi, 80 rpm @ 1.5-3k ft-Ibs TO, 5-10k WOB. -Push bottom section of plug downhole to 2006'. 01:30 - 02:00 0.50 DRILL P INT2 Test ca_sinq to 4000 psi for 30 minutes and chart. Good test.. 02:00 - 03:30 1.50 DRILL N RREP INT2 Adjust top drive rails, top drive leaking. 03:30 - 04:30 1.00 DRILL N RREP INT2 Ream and push ES cementer debris down from 2006' to 2072'. Blow down top drive and remove blower hose. 04:30 - 05:00 0.50 DRILL N RREP INT2 POH from 2072' to 843'. 05:00 - 07:30 2.50 DRILL N RREP INT2 POH from 843' to surface. -Lay down circ sub & float sub, flush BHA w/ water. -Plug in and turn off MWD, Lay down MWD. -Break out bit and lay down geo pilot. -Clean and clear rig floor. 07:30 - 12:00 4.50 DRILL N RREP INT2 Be in re air of faile -Remove bails, saver sub, and hydraulic IBOP. -Drain oil, disconnect hydraulic hoses. 12:00 - 00:00 12.00 DRILL N RREP INT2 PJSM. Continue top drive repair. -Remove gripper, pull bearings, remove rotary manifold, pull quill out of rotary manifold. -Change out seals. -Stab quill back into rotary manifold. 1/8/2008 00:00 - 01:00 1.00 DRILL N RREP INT2 Begin to assemble Top Drive. -Mechanic timed out on working hours and sent to bed at 00:00 hrs. 01:00 - 07:00 6.00 DRILL N RREP INT2 Clean and Service rig while waiting on mechanic. 07:00 - 18:00 11.00 DRILL N RREP INT2 PJSM. Assemble Top Drive. -Connect handler sensors, install bearing and race, hook up hydraulic lines, install grabber assembly. -Install gripper, lower and upper IBOP valves. -Hook up hoses, install bales, test top drive - ok 18:00 - 21:30 3.50 DRILL N RREP INT2 PJSM. Make up BHA #18. -MU bit, geopilot, and MWD tools. -Up load MWD. -RIH w/ HWDP to 836'. -Shallow pulse test MWD @ 285'. 21:30 - 22:00 0.50 DRILL N RREP INT2 PJSM. RIH from 836' to 2072' with stands. -PU ghost reamer ~ 1219'. -MU TO = 31 k ft-Ibs. 22:00 - 00:00 2.00 DRILL P INT2 PJSM. Single in w/DP from 2072' to 3489'. -Fill pipe C~ 3489' with 450 gpm ~ 1200 psi. Printed: 3/27/ZWS 1:59:21 F'M • BP EXPLORATION Page 13 of 28 Operations Summary Report Legal Well Name: Y-07 Common W ell Name: Y-07 Spud Date: 4/22/1981 Event Nam e: REENTE R+COM PLET E Start : 12/1/2007 End: 2/6/2008 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 2/6/2008 Rig Name: NABOB S 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/9/2008 00:00 - 02:30 2.50 DRILL P INT2 Continue to RIH w/singles on 5" DP from 3489' to 5758'. -MU DP to 31 k ft-Ibs. 02:30 - 04:30 2.00 DRILL P INT2 RIH w/stands on 5" DP from 5758' to 9158'. -Check connections to 31 k ft-Ibs - ok. -Fill pipe every 3000'. 04:30 - 05:00 0.50 DRILL P INT2 Install blower hose on top drive. 05:00 - 05:30 0.50 DRILL P INT2 RIH and to HES Baffle Collar at 9211'. -Circulate ~ 450 gpm, 1650 psi. 05:30 - 06:30 1.00 DRILL P INT2 Pressure test casin 9-5/8" cs to 4000 si, held for 30 min. 06:30 - 12:00 5.50 DRILL P INT2 Drill out Float equip. from 9211' to 9273' -Landing Collar was C~3 9213' and Float Collar was ~ 9255' -Up Wt. 225k, Down Wt. 100k, ROT 145k C~ 40 rpm -504 gpm C~ 2050psi -TO 18k off/ 20k on 12:00 - 13:00 1.00 DRILL P INT2 Drill Float equip. from 9273' to 9300' -500 gpm @ 2050 psi -Up Wt. 225k /Down Wt. 100k ROT 145K -WOB 8k RPM 60 -TO 21 k 13:00 - 13:30 0.50 DRILL P INT2 Drill Rat Hole & 20' from 9300' to 9325' -500 gpm ~ 2050 psi 13:30 - 15:00 1.50 DRILL P INT2 PJSM, Displace to 9.0 LSND from 9.3 LSND 15:00 - 15:30 0.50 DRILL P INT2 PJSM FIT to 12. 1 50 si -MWT In & Out 9.0 -Est ECD Base Line - 9.94 ppg 15:30 - 00:00 8.50 DRILL P INT2 Drill from 9325' to 10194' -UP Wt 180k Down Wt. 120k ROT 145k -WOB 15k RPM 140k -560 gpm ~ 2150 psi -TO 14k off / 17k on -MW in 9.0 ppg, MW out 9.1 ppg 1/10/2008 00:00 - 12:00 12.00 DRILL P INT2 Continue drilling from 10194' to 11232'. -531 gpm ~ 2180 psi off / 2300 psi on. -140 RPM, 17k WOB -10k ft-Ibs TO off / 13k ft-Ibs TO on -195k Up Wt, 135k Dn Wt, 162k ROT -MW in = 9.0+, MW out = 9.2 ppg -CECD = 10.36 ppg, AECD = 10.45 ppg 12:00 - 16:30 4.50 DRILL P INT2 Drilling from 11232' to 11610'. -200k UP Wt, 145k Dn Wt, 170k Rot -140 rpm, 16k WOB -550 gpm C~ 2090 psi off, 2140 psi on -TO off = 9k ft-Ibs, TO on = 11-12k ft-Ibs 16:30 - 17:30 1.00 DRILL P INT2 Circulate and condition mud. -Reduce ECD from 10.86 ppg to 10.26 ppg. 17:30 - 22:00 4.50 DRILL P INT2 Drill from 11610' to 11800' -205k Up Wt, 140k Dn Wt, 170k Rot -140 rpm, 15k WOB ~ -475 gpm C~3 2090 psi off, 2400 psi on -TO off = 11-12k ft-Ibs, TO on = 13-14k ft-Ibs. -Add 16.0 ppg spike fluid to raise MW to 11.0 ppg 22:00 - 22:30 0.50 DRILL N SFAL INT2 PJSM. Geo-skid washed out with 450 psi loss. Change out Geo-skid. Printed: 3/27/2008 1:59:21 PM BP EXPLORATION Page 14 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To i Hours Task Code NPT Phase Description of Operations ~___~ 1/10/2008 122:30 - 00:00 I 1.501 DRILL I P 1/11/2008 100:00 - 06:00 I 6.001 DRILL I P 06:00 - 12:00 6.001 DRILL P 12:00 - 17:00 I 5.001 DRILL I P 17:00 - 19:30 2.501 DRILL ~ P 19:30 - 20:00 ~ 0.50 ~ DRILL ~ P INT2 INT2 INT2 INT2 INT2 Drilling from 11800' to 11870'. -205k Up Wt, 140k Dn Wt, 170k Rot -140 rpm, 15k WOB -425 gpm ~ 2084 psi off, 2200 psi on -TO off = 11-12k ft-Ibs, TO on = 13-14k ft-Ibs -Hole started breathing ~ 11800' -Total losses = 21 bbls Continue drilling from 11870' to 12206'. -210k Up Wt, 145k Dn Wt, 170k Rot -140 rpm, 17-18k WOB -450 gpm C~ 2160 psi off, 2350 psi on -TO off = 12-13k ft-Ibs, TO on = 13-14k ft-Ibs -BOP = 60 fph -MW in = 11.0 ppg, MW out = 11.0+ ppg -CECD = 12.04 ppg, AECD = 12.25 ppg Continue drilling from 12206' to 12330'. -210k Up Wt, 145k Dn Wt, 170k Rot. -120 rpm, 35 WOB -510 gpm l~ 2590 psi off, 2660 psi on -TO off = 10k ft-Ibs, TO on = 10k ft-Ibs -BOP seemed erratic and slow/ dropping to less than 10' an hour -MW in = 11.0 ppg, MW out = 11.0+ ppg Total losses = 21 bbls Continue drilling from 12330' to 12398'. -215k Up Wt, 150 Dn Wt, 175k Rot -140 rpm, 23k WOB -500 gpm C~ 2540 psi off, 2620 psi on -TO off = 13k ft-Ibs, TO on = 14k ft-Ibs -Varied WOB and RPM combinations to improve BOP, no success. ROP varied between 15' - 60' an hour, mostly on the lower end. -MW in = 11.0 ppg, MW out = 11.0+ POH wet from 12398' to 9300'. -25-40k overpulls from 12400' to 11250' -40k overpull C~ 11780'. -POH for bit check. Pump dry job, blow down top drive, remove blower hose from top drive. POH from 9300' to 3680' L/D Drill Pipe from 3680' to 2166' L/D Drill pipe 2166' to top BHA @ 836' Stand back HWDP & jars, lay down circ sub & ball catcher, stand back flex DC's, lay down stabilizer and float sub, flush MWD tools w/fresh water. Break bit, download MWD, laydown TM collar, laydown MWD assembly, laydown geopilot, swap out mud pulsers. PU new geo-pilot, MWD assembly, MU bit and TM collar, upload MWD. MU float sub and stabilizer, RIH w/stand of flex DC's. Shallow hole test MWD ~ 430 gpm, 800 psi - ok. MU circ sub and ball catcher, PU HWDP and jars to 836'. PU DP from 836' to 3680'. INT2 20:00 - 22:30 2.50 DRILL P INT2 22:30 - 00:00 1.50 DRILL P INT2 1/12/2008 00:00 - 01:30 1.50 DRILL P INT2 01:30 - 04:30 3.00 DRILL P INT2 04:30 - 07:30 3.001 DRILL P INT2 07:30 - 11:00 ~ 3.501 DRILL ~ P ~ ~ INT2 PnntOtl: 3/27/2008 1:5y:L1 PM BP EXPLORATION Page 15 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To ~ Hours I Task Code I', NPT Phase Description of Operations 1/12/2008 107:30 - 11:00 3.501 DRILL P INT2 -MU ghost reamer ~ 2450' 11:00 - 12:30 1.50 DRILL P INT2 12:30 - 13:30 1.00 DRILL P INT2 13:30 - 15:30 2.00 DRILL P INT2 15:30 - 17:00 1.50 DRILL P INT2 17:00 - 19:00 2.00 DRILL P INT2 19:00 - 22:30 3.50 DRILL P INT2 22:30 - 00:00 I 1.501 DRILL I P I I INT2 1/13/2008 100:00 - 03:30 I 3.501 DRILL I P I I INT2 03:30 - 07:30 4.00 DRILL N DPRB INT2 07:30 - 08:30 1.00 DRILL N DPRB INT2 08:30 - 10:00 1.50 DRILL N DPRB INT2 10:00 - 12:00 2.00 DRILL N DPRB INT2 12:00 - 18:00 6.00 DRILL N DPRB INT2 18:00 - 18:30 0.50 DRILL N DPRB INT2 18:30 - 20:30 2.00 DRILL P INT2 -Fill pipe and test MWD - ok -Blow down top drive PJSM. Slip and cut 102' of drill line. Service Top Drive. RIH from 3680' to 9251'. -Fill C~? 6513' CBU at 9251' at 450 gpm C~ 1900 psi. -Break in geo-pilot ~ 10, 20, and 40 rpm (5 min each) -Blow down top drive and geo-skid RIH from 9251' to 12170'. -Tag fill C~ 12170', pulling 40k over. Break circulation and work string. Hole packing off. -Rotate 60 rpm while staging pumps to 430 gpm ~ 2200 psi. -Wash and ream from 12170' to 12398' -Periodic packoffs and overpull. Work string down to 12398'. Drilling from 12398' to 12462'. -235k Up Wt, 135k Dn Wt, 180k Rot -135 rpm, 10k WOB -500 gpm ~ 2500 psi off, 2610 psi on -TO off = 16k ft-Ibs, TO on = 17k ft-Ibs -MW in = 11.1 ppg, MW out = 11.1 ppg Drill ahead from 12462' to 12602'. -500 gpm C~ 2580 psi / 2680 psi -BOP ranging from 40 to 100 fph -WOB 10-15k -Up Wt. 235k /Down Wt. 140k /ROT 182k -TO 14-17k on / 14-16k off -Intermittent MWD failures -Troubleshooting detection errors while drilling ahead -At 12600', begin losing mud. -Complete losses at full drilling rate, No losses static. Begin mixing 45 bbl LCM pill - 40 ppb -Rotate and Reciprocate while pumping 2 bpm ~ 350 psi -Mobilize mud plant for more 11.0 ppg mud -Spot pill C~ 12600' POH from 12600' to 12083' (above LCM Pill) -275k Up Wt. Begin pumping C~3 2 bpm / 350 psi -Increase rate to 4 bpm / 660 psi -Monitor Losses +-33% at all rates -Total Losses of 650 bbls Reciproate pipe and pump 10 bbls every 30 min. -Waiting on mud from plant Reciprocate pipe and pump 10 bbl every 30 min. -Waiting on mud from plant RIH from 12083' to 12600' Drill from 12600' to 12628' -375 gpm C~ 1380 psi -Up Wt. 250k /Down Wt. 140k ROT 185k -RPM 110-130 WOB 15k -BOP 20 fph -Losses of 420 boh while drilling Printed: 3/27/2008 1:59:21 PM ~ r BP EXPLORATION Page 16 of 28` Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ Frorn - To ~ Hours Task Code NPT Phase Description of Operations 1/13/2008 20:30 - 22:00 1.50 DRILL N DPRB INT2 POH from 12628' to 12083' -Pump out of hole at 2 bpm ~ 325 psi -Backream due to swabbing -Waiting on mud from plant 22:00 - 00:00 2.00 DRILL N DPRB INT2 Reciprocate while waiting on mud from plant -1 1/14/2008 00:00 - 01:00 1.00 DRILL N DPRB INT2 RIH to bottom at 12628'. -More mud (290 bbls) arrived on location ~ 00:00. -No problems while RIH 01:00 - 02:30 1.50 DRILL P INT2 Drill ahead from 12628' to 12642'. -260k Up Wt, 140k Dn Wt, 196 Rot -14-15k TO off, 16-17k TO on -130 rpm, 20-30k WOB -350-375 gpm, 1400-1500 psi on -BOP ranging from 15 fph to 80 fph -Ave ROP of -20 fph -Lost 571 bbls in 1.5 hrs 02:30 - 04:00 1.50 DRILL N DPRB INT2 Drop ball to shear open CCV. -Pump ball ~ 125 gpm, 473 psi -Ball seated, pressure up to 1890 psi, shear open, fcp = 386 psi ~ 125 gpm -Drop ball to shut off BHA, pump 25 bbl mud spacer, pump 90 bbl pill of 80 ppb LCM, pump 5 bbl mud spacer, pump 30 bbl Cemnet+ pill. 04:00 - 04:30 0.50 DRILL N DPRB INT2 Displace DP with 11.0 ppg mud at 250 gpm, 630 psi. -Returns im roved short) after LCM turned the corner. 04:30 - 05:30 1.00 DRILL N DPRB INT2 Shut off pump and monitor wellbore. -Well a eared to be breathin back. -35 b 05:30 - 10:00 4.50 DRILL N DPRB INT2 POH to shoe to 9251'. -Pump out of hole from 12642' to 10855' (swabbing). -Pump dry job and POH slow. II till r -225k Up Wt, Max Up = 300k @ 12550' (wiped clean) -Monitor well at shoe -gained 1 bbl in 15 min. 10:00 - 14:00 4.00 DRILL N DPRB INT2 Circulate @ 565 gpm, 1230 psi w/CCV open. -LCM blinding screens, stop pumping & monitor breathing. -Gain 14 bbls in 30 mins while changing screens. -Drop CCV closing ball, pump on seat, shear close ~ 1890 psi. -Est Loss Rate: Circ ~ 450 gpm, 1590 psi = 370 bph losses -Circ ~ 220 gpm, 610 psi = 50 bph losses -CBU at 225 gpm, 625 psi, 30 rpm, recip pipe -Blow down top drive and geo skid 14:00 - 15:30 1.50 DRILL N DPRB INT2 RIH from 9251' to 12645'. 15:30 - 18:00 2.50 DRILL P INT2 Drill ahead to 12745'. -265k Up Wt, 140k Dn Wt, 190k Rot -125 rpm, 15k WOB -525 gpm C~ 2300 psi off, 2360 psi on -TO off = 23k ft-Ibs, TO on = 25k ft-Ibs -Eosin mud at 400 b h while drillin . 18:00 - 20:00 2.00 DRILL N DPRB INT2 Pump out of hole from 12745' to 11894' ~ 2 bpm, 320 psi. -Rotate at 45 rpm (swabbing) -25% return flow with pumps off, diminish to 11 Printed: 3/27/2008 1:59:21 PM ~ ~ BP EXPLORATION Page 17 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase 1/14/2008 18:00 - 20:00 2.00 DRILL N DPRB INT2 20:00 - 00:00 4.00 DRILL N DPRB INT2 1/15/2008 100:00 - 04:15 I 4.251 DRILL I N I DPRB I INT2 04:15 - 05:00 0.751 DRILL N DPRB ~ INT2 05:00 - 05:45 I 0.751 DRILL I N I DPRB I INT2 05:45 - 06:30 I 0.751 DRILL I N I DPRB I INT2 06:30 - 10:00 3.50 ~ DRILL ~ N ~ DPRB ~ INT2 10:00 - 11:00 1.001 DRILL N DPRB INT2 11:00 - 12:00 1.00 DRILL N DPRB INT2 12:00 - 15:00 3.00 DRILL N DPRB INT2 15:00 - 18:30 ~ 3.501 DRILL ~ N ~ DPRB ~ INT2 18:30 - 20:00 1.50 DRILL N DPRB INT2 20:00 - 00:00 4.00 DRILL N DPRB INT2 1/16/2008 00:00 - 02:00 2.00 DRILL N DPRB INT2 02:00 - 06:00 4.00 DRILL N DPRB INT2 06:00 - 10:00 4.00 DRILL N FLUD INT2 10:00 - 14:00 ~ 4.00 ~ DRILL N ~ DPRB ~ INT2 Description of Operations -Blow down top drive and geo-skid Work pipe and monitor well while mixing 100 bbl Form-A-Squeeze LCM Pill. -Problems mixing pill -would not mix -additive layering on top of fresh water. Troubleshoot. -Well flowing back - 11 % to 0 over 3 hours. -35 bbls first hour, 30 bbls second hr, 15 bbls third hr, down to 0 flow -Total losses for day = 2026 bbls. _ Continue mixing 100 bbl Form-A-Squeeze pill in pit. -Cycle between pill pit and pit #3 while gradually adding barite and sacks of Form-A-Squeeze. -MI Lead on location to supervise mixing of pill. -After pill mixed, agitate for 30 minutes to ensure consistency Pump 100 bbl Form-A-Squeeze LCM pill C~1 4 bpm, 495 psi. -Chase w/ 96 bbls mud -Form-A-Squeeze Pill C~ bit Monitor Well -breathing back w/diminishing returns. -45 bbls back in 1 hour. Close annular preventer. Commence squeezing -50 bbls mud and 50 bbls Form-a-Squeeze to loss zone leaving -50 bbls of pill in the open hole down to loss zone at 12600'. Pump at 3 bpm @ 400 psi. Start with 3.5 bbl increments, waiting 15 minutes before next squeeze. Pumping 3 bpm ~ -400 psi. No pressure build-up noted or change in squeeze pressure. Pump 5 bbls every 30 minutes with no appreciable change in squeeze pressure. Well holds - 150 psi of back pressure when waiting between squeezes with well shut in. Squeezed a total of 35.5 bbls away to formation with no indication of a squeeze forming downhole. Monitor well. Blow down kill line. Pump dry job. Blow down top drive. Remove TIW valve. POOH to 9251'. Well breathing while pulling. Up weight 290k. Stage pumps up to 300 gpm with 340 bph losses. Bring pumps up to 500 gpm with 460 bph losses. Shut down and monitor flowback. Flow decreasing from 26% to 9% over 30 min. Well flowed back 44 bbls of mud. Discuss situation with town. Pump dry job. Blow down top drive. POOH to 2827'. Well not taking correct disolacement. Well still breathin . POOH laying down drill pipe to 843'. Lay down BHA from 843'. Download MWD then flush with fresh water. Lay down MWD. Break bit. LD Geo-Pilot. Clear and clean floor. Pick up LCM, BHA to 651'. RIH with 5" drill pipe to shoe at 9302'. PJSM. MI mud plant had problems with Gunk mix. Rig preparing for contingency to mix Gunk pill at rig. Stop preperations for mixing on rig. Mud plant finished pill. Loading out pill. Waiting on pill. RIH to 12549'. Install TIW valve 2 stands down. Fill pipe. Up weight 275k, down 135k. Break circulation at 2 bpm with 450 Printed: 3/27/2008 1:59:21 PM ~ r BP EXPLORATION Page 18 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase.. Description of Operations 1/16/2008 10:00 - 14:00 4.00 DRILL N DPRB INT2 psi. Reciprocate pipe. Hold PJSM. 14:00 - 16:00 2.00 DRILL N DPRB INT2 Prime up cement truck. Pump 5 bbls LVT. Pressure test lines to 3500 psi. Leak in line. Find leak. All lines good. Pump 10 bbls LVT and switch to Gunk pill. Pump Gunk pill at 4 bpm with 50% returns, pill weighing 10.4 ppg. With 20 s away pressure at 850 psi, 120 bbls away 1000 psi. Returns increased to 60%, density to 10.7 ppg. With 147.5 bbls away pressure at 1020 psi. Switch to rig pumps and chase LVT to end of pipe at 3 bpm with 1030 psi. Shut in annulus. Pump mud at 4 bpm with 880 psi. Displace LVT and 50 bbls of Gunk out of drill pipe. Start pumping down back side at 4 bpm. Annulus pressure climbing. Slowed pump rate as pressure climbed. Decreased pumps to final pumping rate of .7 bbls per minute on both sides until pressure climbed to 550 psi and spiked to 600 psi, shut down. Approximately 50-52 bbls of Gunk and the 15 bbls of LVT left in drill i e. 16:00 - 19:30 3.50 DRILL N STUC INT2 Pull one stand of drill pipe with 125k overpull. Attempt to circulate. Pressure u to 1500 si, no o. Work stand with rotation. No going down. Pulling 190k over with 460k. Attempt to circulate once again. Pressure broke over at 1800 psi, with no returns. Pump 85 bbls of mud to clear pipe of any Gunk pill and LVT with pressures between 1800 and 3300. No longer able to rotate ull u o down or establish returns. 19:30 - 00:00 4.50 DRILL N STUC INT2 Pull 400k wait 30 minutes, put 70k down and wait 30 minutes with no change in pipe movement. Waiting on SWS. Baker fishing hand arrived on location. Attempt to reset Jars. Work pipe from 425k up to 70k down while trapping left hand torque in string. Still uable to cock and activate Jars; Attempt pipe movement as per Baker rep with no success. 1/17/2008 00:00 - 04:00 4.00 DRILL N STUC INT2 Waiting on E-line unit for free point and backoff. 04:00 - 07:30 3.50 DRILL N STUC INT2 RU E-line unit. 07:30 - 16:30 9.00 DRILL N STUC INT2 RIH with E-Line Freepoint Tool. Make baseline calibrations at 2000'. Run torque sequence at 9200', pipe 100% free. RIH to 10025' and repeat sequence, 100% free. 10721 -pipe 80% free. Repeat at 11725' -pipe stuck. 11585' -pipe stuck. 11265' - pipe 66% free, 11500' -pipe 56% free, 11600' -pipe 11 free, 11555' -pipe 33% free. POH with Freepoint. 16:30 - 21:30 5.00 DRILL N STUC INT2 Make up and RIH with string shot. PJSM. Work 4-1/2 left hand turns in string. Hold with rig tongs. RIH with E-line to 10994'. Fire strin ack off. POOH with E-line to 9200'. Release torque. Work 8-1/2 left hand turns into string and release. Work another 8-1/2 left hand turns into string. String backed off and 2082'. POOH with E-line. 21:30 - 22:30 1.00 DRILL N STUC INT2 Lay down E-line assembly. Pick up one joint of DP. Make up string at 2082' with 31 k torque. Work torque down. Lay down joint of DP. Make up E-line assembly. 22:30 - 00:00 1.50 DRILL N STUC INT2 RIH with strip shot assembl #2 to 9200'. 1/18/2008 00:00 - 04:00 4.00 DRILL N STUC INT2 RIH with E-line to 9200'. Make up stuffing box. Pull 225k and set slips. Work and hold 18k torque. RIH with E-line to 10718'. Fire string shot. Release for ue, pull u 350k. Pipe not free. POOH with E-line. Break and lay down string shot assembly. Make up top drive, pull 300k, not free. Reciprocate and work 18k LH torque into drill string. Pull 230k, go down pull up to Printed: 3!2712008 1:5921 PM ~ ~ BP-EXPLORATION Page 19 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABORS 2ES Rig Number: 2ES I , Code NPT Phase Description of Operations Date 'From - To Hours Task 1/18/2008 00:00 - 04:00 4.00 DRILL N STUC INT2 250k, pipe came free. 04:00 - 09:00 5.00 DRILL N STUC INT2 Circulate bottoms up. Pump nut plug sweep for marker. Marker back indicatin backoff below 10100'. Continue to circu at~l e an~c condition mud at 450 gpm with 850 psi. Increase pumps to 550 gpm with 1200 psi, no losses or breathing. Pump dry job. Blow down top drive. Up weight 200k, down 120k. 09:00 - 11:30 2.50 DRILL N STUC INT2 POH to 5300'. Check connections from 2000' to 2200'. Redope and torque. 11:30 - 12:30 1.00 DRILL N STUC INT2 PJSM. Service crown. Cut drilling line. Inspect and service draworks and Elmago Spline. Check brushes. 12:30 - 13:30 1.00 DRILL N STUC INT2 Service top drive. 13:30 - 16:30 3.00 DRILL N STUC INT2 POH from 5300'. Recoverd DP from 10733'. Clean floor. 16:30 - 17:30 1.00 STKOH N STUC INT2 Pick up and rig up 3-1/2" tubing equipment. 17:30 - 19:00 1.50 STKOH N STUC INT2 Replace hose on BOP stack to hydraulic kill valve. 19:00 - 21:00 2.00 STKOH N STUC INT2 PJSM. Make up 3-1/2" NSCT, 9.2#, L-80 mule shoe and tubing stinger to 1027'. Rig down tubing equipment. CO elevators. 21:00 - 00:00 3.00 STKOH N STUC INT2 RIH with 3-1/2" stinger on 5" drill pipe to 7448', checking make up torque on each connection. 1/19/2008 00:00 - 02:00 2.00 STKOH N STUC INT2 RIH with 3-1/2" stinger on 5" drill pipe to 10.287'. 02:00 - 04:30 2.50 STKOH N STUC INT2 Circ & cond mud for cement'ob. 04:30 - 05:00 0.50 STKOH N STUC INT2 Pull up to 10200'. Spot 20 bbl viscous pill at 11.0 ppg from 10200-9900' to help support cement plug. 05:00 - 05:30 0.50 STKOH N STUC INT2 RU cementers. Prepare to lay in balanced cement plug from 9900' to 9100' (200' inside 9 5/8 casing). 05:30 - 06:00 0.50 STKOH N STUC INT2 PJSM Nabors, BP, CH2M Hill for cement job. 06:00 - 07:00 1.00 STKOH N STUC INT2 Pump 5 bbls water. PT lines to 4500 psi. Pump 45 bbls water followed by 70 bbls (395 sx) Class G cement at 17.0 ppg at 2 bpm - 400 psi. Pump 15 bbls water behind cement to balance. 07:00 - 07:30 0.50 STKOH N STUC INT2 Switch to rig. Displace cement with rig pumps at 550 gpm. Pump 110 bbls at 550 gpm C~ 1900 psi. Slow rate for final 23 bbls of displacement to 2 bpm. 133 bbls total displacement. CIP at 07:30 hrs. 07:30 - 08:30 1.00 STKOH N STUC INT2 RD cmt line and break off head pin. Pull up slowly out of cement plug (40-30 fpm). Pull up from 9900' to 8600'. 08:30 - 11:30 3.00 STKOH N STUC INT2 Break Circ and CBU at 550 gpm. NQ losses noted. Install foams ball in DP and followed by 50 bbls of 50 ppb nutplug to clear cement out of pipe. Pump at 550 gpm. 11:30 - 15:00 3.50 STKOH N STUC INT2 PJSM. POOH to 1027'. Pull air slips. Clear and clean floor. 15:00 - 18:30 3.50 STKOH N STUC INT2 PJSM. Rig up tubing handling equipment. POOH laying down 3-1/2" tubing stinger. Clean and clear floor. 18:30 - 00:00 5.50 STKOH N STUC INT2 PJSM. Pull wear ring. Make up test joint. Install test plug. Fill stack and choke manifold. Test BOPE to 250 psi low, 4000 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 Toolpusher Bruce Simonson. 1/20/2008 00:00 - 06:00 6.00 STKOH N STUC INT2 PJSM. Test ROPE 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 Toolpusher Bruce Simonson. Trouble with lower IBOP. Change out. System aired up no test. Purge lines tested OK. Rig down from BOP test. Pull test plug. Run in wear ring. Prepare to pick up BHA. Printed: 3/27/2008 1:59:21 PM BP EXPLORATION Page 20 of 28 .Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES .Date From - To Hours Task Code NPT Spud Date: 4/22/1981 Start: 12/1/2007 End: 2/6/2008 Rig Release: 2/6/2008 Rig Number: 2ES Phase '~ Description of Operations 1/20/2008 06:00 - 06:30 0.50 STKOH N STUC INT2 Suspected ice build up due to temperature fluctuations. Inspect and clear derrick. 06:30 - 11:00 4.50 STKOH N STUC INT2 Bring 8-1/2" BHA tools up beaverslide. PJSM. PU Geo-Pilot. Make up bit and BHA to 78'. Plug in and upload MWD. PU to 2nd stand of HWDP. Make up top drive and surface test MWD at 550 gpm with 1500 psi. Test - OK. Test Geo-Pilot with command -good test. PU jars and remaining BHA to 821'. 11:00 - 14:00 3.00 STKOH N STUC INT2 PJSM. Pick up drill pipe to 2242'. PU and MU ghost reamer. Continue to PU drill pipe to 3854'. 14:00 - 17:30 3.50 STKOH N STUC INT2 RIH to 8860'. Install blower hose. Fill pipe. Pump at 410 gpm with 1580 psi. Up weight 200k, down 100k, RT 135k. Free torque 14k at 45 rpm. 17:30 - 20:30 3.00 STKOH N STUC IINT2 20:30 - 00:00 ~ 3.50 ~ STKOH ~ N ~ STUC ~ INT2 1/21/2008 100:00 - 01:00 1.001 STKOH ~ N ~ STUC ~ INT2 01:00 - 02:00 1.00 STKOH N STUC INT2 02:00 - 03:00 1.00 STKOH N STUC INT2 03:00 - 04:00 1.00 STKOH N 04:00 - 04:15 0.25 STKOH N 04:15 - 00:00 19.75 STKOH N 1/22/2008 ~ 00:00 - 09:00 ~ 9.00 ~ STKOH ~ N STUC INT2 STUC INT2 STUC INT2 STUC IINT2 09:00 - 10:00 1.00 STKOH ~ N ~ STUC ~ I NT2 10:00 - 16:00 6.00 STKOH N STUC IINT2 RIH and tag cement stringer at 9038'. Pump at 450 gpm with 1825 psi. Work through stringers and taa cement at 9094'. Drill cement to 9320' with 16-17k torque at 100 rpm. WOB 10k. Time drill and kick off to 9363'. Pump at 400 gpm with 1430 psi. Torque 17k at 140 rpm. WOB 3-4k. ART - 3.27 Mud weight in and out 10.8 ppg. Directional drill ahead to 9398' MD, 5836' TVD. Pump at 500 gpm with 2050 psi. Torque 16-20k at 140 rpm. Up weight 250k, down 100k, RT 200k. PJSM. Pull up inside shoe to 9236'. Clean pits for displacement. PJSM. Displace 10.8 ppg mud. Pump hi-vis spacer followed by 8.8 ppg LSND mud. Pump at 500 gpm with 2050 psi. Rotate at 110 rpm with 17k torque to start and 6.5k after. Break out and blow down top drive. Clean out shaker possum bellies and troughs. Establish baseline ECD of 9.54 ppg. Get slow pump rates. Directional drill ahead to 10000' MD, 6130' TVD. Pump at 550 gpm with 2020 psi off bottom 2060 psi on bottom. Rotate at 140 rpm with 9k torque off bottom, 11k on bottom. WOB 4-15k. Up weight 175k, down 130k, RT 150k. Mud weight in and out 9.0 PPg• Continue to drill ahead to 11275' MD, 6772' TVD. Pump at 575 gpm with 2350 psi off bottom, 2485 psi on bottom. Rotate at 140 rpm with 8k torque off bottom, 12k on bottom. WOB 15-18k. Up weight 190k, down 135k, RT 160k. Mud weight 9.1 ppg in and out. ART - 14.95. Well breathing back 15 bbls on connections. Drill ahead to 11976' MD. Pumping at 575 gpm with 2590 psi off bottom, 2620 psi on bottom. Rotate at 140 rpm with 10k off bottom, 15k on bottom. WOB 15-18k. Up weight 210k, down 130k, RT 165k. Mud weight in and out 9.2 ppg. ECD 10.53 ppg. Well breathing back 5-7 bbls on connections.. Displace system to 10.7 ppg LSND, with shale stabilization (black product). Decrease pump rate to 420 gpm wtih 1861 psi. Rotate and a reciprocate pipe. Continue to drill ahead to 12438' MD at 425 gpm with 1800 psi off bottom, 1860 psi on bottom. Torque 15k off bottom, 16k on bottom at 145 rpm. Up weight 210k, down 130k, RT 167k. Mud weight in and out 10.7 ppg. Well breathing at 24% flow back Printed: 3/27/2008 1:59:21 PM BP EXPLORATION Page 21 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1 /2007 End: 2/6/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To ~ Hours ~ Task .Code NPT Phase Description of Operations. 1/22/2008 10:00 - 16:00 6.00 STKOH N STUC INT2 with a 20 bbl gain in 10 minutes. Flow back diminishing each shut down. 16:00 - 16:30 0.50 STKOH N STUC INT2 Replace leaking fitting on top drive. 16:30 - 00:00 7.50 STKOH N STUC INT2 Continue to drill ahead to 12724' MD, 7244' TVD. Pump at 425 gpm with 1850 psi off bottom, 2125 psi on bottom. Torque 13k off bottom, 17k on bottom at 145 rpm. WOB 12-18k. Mud weight in and out 10.7 ppg. Up weight 225k, down 130k, RT 175k. ECD 11.83. Well continuing to breath back at 23-26% flow durin shut downs diminishin each time. 1/23/2008 00:00 - 00:15 0.25 STKOH N STUC INT2 Continue drilling ahead to last wellbore total depth of 12745' MD. 00:15 - 06:30 6.25 DRILL P INT2 Drill ahead to 13109' MD, 7865' TVD. Pump at 421 gpm with 2175 psi. Torque 16k at 140 rpm. WOB 14-18k. Up weight 227k, down 137k, RT 176k. Mud weight in and out 10.7 ppg. ECD 11.95. 06:30 - 07:30 1.00 DRILL N WAIT INT2 Weather elevated to Phase III. Decision made to shut down. Circulate sweep surface to surface at 421 gpm with 2018 psi. Rotate and reciprocate. Pump survey. Mud weight in and out 10.7 ppg. Up weight 275k, down 130k. 07:30 - 10:30 3.00 DRILL N WAIT INT2 PJSM. POOH to 9145' into 9-5/8" shoe. No problems. 10:30 - 00:00 13.50 DRILL N WAIT INT2 Waiting on weather. Blizzard conditions. High winds and blowing snow. Phase III over entire field. Circulate over the top with no losses. 1/24/2008 00:00 - 05:00 5.00 DRILL N WAIT INT2 Continue to wait on weather after ullin u i - shoe. Working on cleaning up yard, digging out pickups and loaders. Received camp water and rig fuel. 05:00 - 09:00 4.00 DRILL P INT2 PJSM. Cut and slip 102' of drilling line. Service top drive and draworks. Turn kelly hose. 09:00 - 10:00 1.00 DRILL P INT2 Circulate bottoms up at 425 gpm with 1745 psi. 10:00 - 12:00 2.00 DRILL P INT2 PJSM. Loosen clamps and hammer unions on stand pipe. Turn gooseneck. Re-adjust kelly hose again. 12:00 - 13:00 1.00 DRILL N RREP INT2 PJSM. Try again to adjust kelly hose. Tighten clamps and upper stand pipe. Function test - OK. 13:00 - 15:00 2.00 DRILL P INT2 PJSM. RIH to 12070'. 15:00 - 16:00 1.00 DRILL P INT2 Circulate BU at 420 gpm with 1970 psi. Rotate at 80 rpm with 16k torque. Up weight 227k, down 127k, RT 165k. Blow down. 16:00 - 20:30 4.50 DRILL P INT2 RIH to 12860'. Ti ht hole. Wash and ream to 13 16". Packing off with overpulls of 20-30k. Up weight 275k, down 125k, RT 165k. RIH with last stand to bottom. 20:30 - 00:00 3.50 DRILL P INT2 Drill ahead to 13274' MD, 7982' TVD. Pump at 421 gpm with 1990 psi off bottom 2100 psi on bottom. Torque 15k off bottom, 17k on bottom at 140 rpm. WOB 14-18k. Up weight 240k, down 135k, RT 180k. Mud weight in and out 10.7 ppg. ART - 2.73. Well breathing on connections. ECD 11.99. 1/25/2008 00:00 - 20:30 20.50 DRILL P INT2 Directional drill ahead to 13525' MD, 8198' TVD. Pump at 421 gpm with 1930 psi off bottom, 2025 psi on bottom. Torque 17k off bottom, 19k on bottom at 140 rpm. WOB 16-22k. Up weight 245k, down 150k, RT 189k. Mud weight in 10.7 ppg, out 10.8 ppg. ECD 11.65. Flow check on last connection, 68 bbls back in 10 minutes. Flow diminishing from 37% to 24%. Coninue drillin ahead to interval TD of 14398' MD 8904' TV ,. Pump at 455 gpm with 2245 psi off bottom, 2300 psi on Printed: 3/27/2008 1:59:21 PM • BP`EXPLORATION Page 22 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task ~ Code NPT Phase Description of Operations 1/25/2008 00:00 - 20:30 20.50 DRILL P INT2 bottom. Rotate at 140 rpm with 18k torque off bottom, 23k on bottom. WOB 15-22k. Mud weight in and out 10.7 ppg. ART - 16.76. ECD 11.67. Up weight 275k, down 150k, RT 200k. Control drill from 14360' to TD. Spotted reverse drilling break. Gammas ike evident at 14398' MD. 20:30 - 00:00 3.50 DRILL P INT2 Circulate up samples at 450 gpm with 2350 psi. Samples confirm TD as per Geologist. Pump weighted sweep surface to surface until clean. Up weight 280k, down 150k, RT 200k. 1/26/2008 00:00 - 02:00 2.00 DRILL P INT2 Pump and spot liner running pill in open hole. Shut down and prepare to POOH for 7" liner run. 02:00 - 08:00 6.00 DRILL P INT2 Perform flow check, got back 15 bbls in 5 minutes. Diminishing from 29% to 24%. Mud weight in and out 10.7 ppg. POOH to 11500'. Hole in good shape. Continue to POOH to 9238', no problems. Total flow back for trip, 98 bbls. 08:00 - 09:30 1.50 DRILL P INT2 PJSM. Attempt to open CCV sub with no success. Circulate BU at 500 gpm with 2250 psi. Rotate and reciprocate. Pump dry job. Monitor well for 10 minutes, OK. 09:30 - 11:30 2.00 DRILL P INT2 PJSM. POOH to 5367'. 11:30 - 15:00 3.50 DRILL P INT2 PJSM. POOH laying down 5" drillpipe to 828'. 15:00 - 20:00 5.00 DRILL P INT2 PJSM. LD BHA to flex collars. Make up top drive, flush MWD and Geo-Pilot skid. Blow down. Pick up to CCV, plugged with cement. Plug in MWD and download. Lay down remaining BHA. Break bit. Clear and clean floor. 20:00 - 20:30 0.50 DRILL P INT2 Lay BHA down beaver slide. Pump out stack. 20:30 - 22:00 1.50 BOPSU P INT2 Pick up test joint. Remove wear ring and install test plug. PJSM. Change out top rams from 3-1/2"x6" variables to 7". PU 7" test joint an run in. i stac , c ec or ea s, 22:00 - 00:00 2.00 BOPSU P INT2 PJSM. Test 7" rams to 250 psi low, 4000 psi high as per AOGCC. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle. Collar leaking on high test. Replace seal ring. Test again, OK. Blow down and rig down. Lay down test joint and plug. Run in wear ring. 1/27/2008 00:00 - 01:30 1.50 CASE P INT2 PJSM. Pick up and rig up liner running tools. 01:30 - 10:30 9.00 CASE P INT2 PJSM. Run 7", 26#, L-80, Rotatable BTC-M liner to 14397'. Run torque rings in each joint. Torque to 14,000 fUlbs. Fill on the fly, top off every 10 joints. Running in at 80-90 fpm. PU hanger, pup and DP single and 1 stand out of derrick. Losses 24 bbls. 10:30 - 11:30 1.00 CASE P INT2 Circulate one liner volume. Stage pumps up to 210 gpm with 390 psi. Stage over 20 minutes. Losses 83 bbls while circulating. Up weight 120k, down 100k. 11:30 - 14:00 2.50 CASE P INT2 PJSM. Run liner in hole on 5" drill pipe to 9275'. Make up top drive. 14:00 - 15:00 1.00 CASE P INT2 Stage pumps up to 210 gpm with 500 psi. Circulate a bottoms up and reciprocate pipe. Up weight 177k, down 110k. 15:00 - 17:30 2.50 CASE P INT2 PJSM. RIH to 12013' filling every 10 stands. Make up top drive and establish circulation at 210 gpm with 470 psi. Up weight 215k, down 110k. Wash from 11918' to 12107'. Blow down top drive. RIH to 13740'. 17:30 - 00:00 6.50 CASE P INT2 Take 25k down weight at 13740'. Unable to work through. Kick in pumps staging up to 5 bpm. Pump and rotate down to 13806'. Hole packing off and stalling out. Wash and ream to Printed: 3/27/2008 1:59:21 PM BP EXPLORATION Page 23 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To ILL Nours Task Code NPT Phase Description of Operations 1/27/2008 17:30 - 00:00 6.50 CASE P INT2 14278'. Up weight 310k, down 110k, RT 185k. 1/28/2008 00:00 - 04:00 4.00 CASE P INT2 PJSM. Wash and rotate to 14398'. Pump at 250 gpm with 940 psi. Torque 22-25k at 70 rpm. Up weight 375k, down 160k, RT 200k. Hole packing off and rotary stalling. Tag up and spot liner 1' off bottom. 04:00 - 04:30 0.50 CEMT P INT2 Rig up cement head. 04:30 - 05:30 1.00 CEMT P INT2 Stage pumps up to 210 gpm with 810 psi. Circulate bottoms up. Prepare to cement liner. 05:30 - 08:05 2.58 CEMT P INT2 PJSM. Pump 5 bbls water, test lines to 4500 psi, OK. Pump 5 bbls of 11.3 ppg Mudpush II and chase water down flowline. Divert Mudpush II down hole and pump remaining 25 bbls at 5 bpm with 700 psi. Follow with 144.5 bbls of 11.7 ppg LiteCRETE lead, staging up to 5 bpm with 820 psi. Follow with 37.5 bbls of 15.8, Class G tail slurry also staging up to 5 bpm at 800 psi. Kick plug out with 5 bbls water and switch over to rig pumps. Latched up liner wiper plug with 151 bbls of mud away and 1000 psi. Continue to displace cement at 5 bpm with 780 psi. Observe good lift with pressure climbing to 1000 psi on up to 1350 psi, finally bumping at 2780 psi with 349 bbls of mud away. Bumped on strokes. 08:05 - 08:30 0.421 CEMT I P CIP at 0805 hours. INT2 Bum ressure u to 3000 si and hold for 5 minutes. PU to 275k, slack off to 125k liner set. Bump up pressure to 4000 psi to release running tool, hold for 2 minutes. Bleed off and pick up. Running tool not released. Slack off to 100k. Pressure up to 4200 psi, bleed off. Pick up again without releasing. Slack off to 80k. Pressure up again to 4200 psi, tool free. Release dogs and slack off to 45k and set packer. Rotate and check set. Check floats. Bring pressure up to 1000 psi and slowly un-sting from packer while maintaining pressure. Confirm pressure drop and increase pump rate to circulate out hole. INT2 Circulate 2 bottoms up at 550 gpm with 2350 psi. Losses of 135 bblc while circulating. Ao~roximately 15 bbls of cement 08:30 - 10:00 1.50 CEMT P 10:00 - 12:30 2.50 CEMT P 12:30 - 14:00 1.50 CEMT P 14:00 - 17:00 3.00 CEMT P 17:00 - 20:30 3.50 CEMT P 20:30 - 21:00 0.50 BOPSU~ P 21:00 - 21:30 0.50 BOPSU P 21:30 - 00:00 2.50 BOPSU P INT2 Monitor well while circulating over the top, well breathed back 74 bbls. Hold PJSM to LD cement head. INT2 Lay down cement head. Rig down manifold and clear floor. LD Geo-Pilot skid. Flush stack with retarder pill. Blow down choke and kill lines. Opened up TIW. Mud flowing over top of drill pipe, well out of balance. Make up top drive. INT2 Circulate while laying tools down beaver slide. Pump at 365 gpm with 725 psi. Cement returns to surface at 350 bbls away. Shut down, line up trucks outside. Continue to pump until system cleaned up. Another 10 bbls cement to surface. Shut down and line back up to pits. Circulate and treat for cement contamination. Pump dry job and blow down. INT2 PJSM. POOH to liner running tool. Break out running tool and lay down. Tool in good shape. INT2 Clear and clean floor. Blow down choke and kill lines. INT2 PU test joint and pull wear ring. Install test plug. INT2 PJSM. Change top rams back to 3-1/2"x 6" variables. Change out washpipe pac ing on t e top drive while changirig rams. Printetl: 3/27/2008 1:59:21 PM • BP EXPLORATION Page 24 of 2$ Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task ~ Code NPT Phase Description of Operations 1/29/2008 00:00 - 03:00 3.00 BOPSU~ P INT2 Test rams to 250 psi low, 4000 psi high as per AOGCC. Test 03:00 - 04:30 1.50 CASE N DFAL INT2 04:30 - 12:00 7.50 CASE N DFAL INT2 12:00 - 15:00 3.00 CASE N DFAL INT2 15:00 - 16:30 1.50 CASE N DFAL INT2 16:30 - 17:00 0.50 CASE N DFAL INT2 17:00 - 19:00 2.00 CASE P INT2 19:00 - 20:00 1.00 CASE P INT2 20:00 - 22:30 2.50 CASE N DFAL INT2 22:30 - 00:00 1.50 CASE N DFAL INT2 1/30/2008 00:00 - 01:00 1.00 CASE N DFAL INT2 01:00 - 01:30 0.50 CASE N DFAL INT2 01:30 - 08:00 6.50 CASE N DFAL INT2 08:00 - 11:00 3.00 CASE N DFAL INT2 Hydril to 250 psi low, 2500 psi high. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher John Castle. PJSM. Pick up and MU BHA for clean out run. Run in with bit, polish mill, dress mill and 9-5/8" casing scraper. PJSM. RIH with clean out BHA on 5" drill pipe from 127' to 7775'. - Filling every 30 stands - Take weight ~ 4469', 5-10k Ibs - Break circ @ 4751', 270 gpm ~ 350 psi, take weight 5-10k - Break circ ~ 5790', Pump 20 minutes ~ 470 gpm, 1150 psi - Wash and Ream from 5790' to 7775'. 160k Up, 90k Dn, 120k Rot. Pump C 490 gpm, 1400 psi. Rotate ~ 30rpm, TO = 5-7k ft-Ibs. PJSM. Wash and ream from 7775' to 9181'. - Pump ~ 502 gpm, 1505 psi - Quarter sized chunks of hard cement to surface. - Rotate C~ 30 rpm, TQ off = 8-10k, TO on = 12-15k, 20k WOB - Up Wt 175k, Dn Wt 90k, Rot Wt 120k. - Go down to 9181', polish mill in TOL, set down 10k, pick up. - Bring up rotary to 50 rpm, TQ = 14k, pump ~ 5 bpm while running in liner top. - Set down 10k, dress and polish TBR and liner top. - Pump high vis weighted sweep. Circulate sweep ~ 585 gpm, 1987 psi - Rotate and reciprocate C~? 100 rpm, 14k TO down to TOL - Chunks of cement to surface. - CBU until clean as per mud engineer. - Pump slug ~ 242 gpm, 509 psi. - Remove blower hose, blow down top drive. PJSM. Rack back 2 stands 5" DP to 9000'. PJSM. Slip and cut 100' of drilling line, adjust brakes, inspect top drive and drawworks. Service Rig. - Lubricate top drive, grease clutches, clean Baylor brake splines. - Clean and clear rig floor. - Install rubbers and air slips. PJSM. POH from 9000' to 100'. - Up Wt 210k, Dn Wt 105k. PJSM. LD singles and BHA. Break bit. Clean and clear rig floor. Clean and clear rig floor. PJSM. PU Baker Liner Top Packer with Seal Assembly and 2 joints of 5" DP to 108'. PJSM. RIH w/packer to 9077'. - Slow running speed due to mud running over the top of DP Wash into liner top, Slack off to NO-GO ring on packer assembly, pressure increase to 500 psi. -Pick up until pressure decrease. -Drop ball, pump down ~ 126 gpm, 340 psi. -Prior to ball seat, slow pumps to 84 gpm, 240 psi. Nnntea: siziiwuu i:oa:zi rnn ,~ • BP EXPLORATION Page 25 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task 'Code NPT Phase Description of Operations 1/30/2008 08:00 - 11:00 3.00 CASE N DFAL INT2 -Seat ball and slack off to No-Go ring. -Pressure up to 4000 psi. Hydraulic pusher set ~ 2390 psi, HR tool released C~ 3380 psi. Hold for 2 min Cam? 4000 psi. -Test annulus to 3000 gsi -held ok. -Pick up and shear ball out of seat ~ 5000 psi. -Test 9-5/8" casing and 7" liner lap to 4000 psi for 10 min -held ok. -Liner to now @ 9106'. 11:00 - 11:30 0.50 CASE N DFAL INT2 Pump dry job. Install rubbers and air slips. 11:30 - 14:30 3.00 CASE N DFAL INT2 PJSM. POH 9105' to 451'. Remove air slips. 14:30 - 16:00 1.50 CASE N DFAL INT2 PJSM. LD 14 jts 5" DP. LD running tool. Clean and clear rig floor. 16:00 - 17:00 1.00 DRILL P PROD1 PJSM. PU 6-1/8" BHA components up beaverslide. Change out handling equipment. 17:00 - 18:00 1.00 DRILL P PROD1 PJSM. Make up BHA to TM collar, scribe motor to DM collar, pick up plug in. 18:00 - 19:00 1.00 DRILL P PROD1 Upload MWD. 19:00 - 19:30 0.50 DRILL P PROD1 PU remaining BHA and 1 jt 4" DP. 19:30 - 20:30 1.00 DRILL P PROD1 PJSM. Shallow test MWD @ 250 gpm, 1140 psi -good test. -Break out top drive crossover and blow down. 20:30 - 00:00 3.50 DRILL P PROD1 PJSM. Pick up 4" DP from 381' to 6174'. -Filling pipe every 60 jts and testing MWD each fill -good tests. 1/31/2008 00:00 - 04:30 4.50 DRILL P PROD1 RIH on 5" DP to 14200' -Fill every 20 stands 04:30 - 05:00 0.50 DRILL P PROD1 Break circulation ~ 250 gpm, 2300 psi. -RIH and tag at 14337'. -Landing collar expected ~ 14300', it blew down to float collar located ~ 14340'. 05:00 - 06:00 1.00 DRILL P PROD1 Ri u and test 7" Liner to 4000 si for 30 minutes -Good Test. Test witnessed by NTP Jon Castle and BP WSL Chris Kobuck. 06:00 - 08:30 2.50 DRILL P PROD1 PJSM, Drill out float equip. from 14340' to 14387' -Up Wt. 325k /Down Wt. 120k /ROT Wt. 140k -255 gpm @ 2330psi / RPM 8 -TO 15k 08:30 - 12:00 3.50 DRILL P PROD1 PJSM, Displace mud from LSND to 8.4ppg Flo-Pro -Up Wt. 250k /Down Wt. 150k /ROT Wt. 165k -260 gpm C~3 1600psi / RPM 40 -TO 12k -Clean out under shakers 12:00 - 13:30 1.50 DRILL P PROD1 Tag Cement @ 14390' and drill out shoe track -Exit shoe ~ 14403' and drill 20' of new hole to 14423' -Up Wt. 285k /Down Wt. 155k /ROT Wt. 185k -TO off 10-12k / TO on 12-15k -WOB 12-15k ~ 100 RPM 13:30 - 15:30 2.00 DRILL P PROD1 Pump Steel tube sweep inside casing -316 gpm ~ 1887 psi /RPM 60 -Circulate Surf to Surf 15:30 - 16:00 0.50 DRILL P PROD1 PJSM, Perform LOT to EMW of 10.34ppg(~ 900 psi -Blow own i ine 16:00 - 21:30 5.50 DRILL P PROD1 Drill ahead from 14423' to 14730' -Up Wt. 225k /Down Wt. 150k /ROT Wt. 190k -328 gpm C~ 2031 psi off / 2323 psi on /RPM 110 Printed: 3/27/2008 1:59:21 PM • BP EXPLORATION Page 26 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task I Code NPT Phase Description of Operations 1/31/2008 116:00 - 21:30 I 5.501 DRILL I P 21:30 - 23:00 I 1.501 DRILL I P 23:00 - 23:30 ~ 0.50 ~ DRILL ~ P 23:30 - 00:00 0.501 DRILL P 2/1/2008 00:00 - 02:15 2.25 DRILL P 02:15 - 03:00 0.75 DRILL P 03:00 - 04:30 I 1.501 DRILL I P 04:30 - 07:00 2.50 DRILL P 07:00 - 08:00 1.00 DRILL P 08:00 - 10:00 2.00 DRILL P 10:00 - 13:00 3.00 DRILL P 13:00 - 15:30 2.50 DRILL P 15:30 - 17:00 1.50 CASE P 17:00 - 18:00 1.00 CASE P 18:00 - 19:30 1.50 CASE P 19:30 - 20:00 0.50 CASE P 20:00 - 21:30 1.50 CASE P 21:30 - 00:00 2.50 CASE P 2/2/2008 100:00 - 06:00 6.001 CASE P PROD1 -TO 14-15k off / TO 15-15k on / WOB 10-15k -Mud Wt. In & Out 8.4 ppg -TD set C~ 14730 as er Geo PROD1 PJSM, Circ. Btms up -326 gpm ~ 1943 psi /RPM 100 -Rotate and Recip. PROD1 POH from 14730' to 14387' -Up Wt. 240k /Down Wt. 160k -RIH from 14387' to 14730' -No problems, good hole PROD1 Circ. Hi Vis. weighted sweep surf to surf -318 gpm C~? 1963 psi -Saw Increase in cuttings and Metal shavings -Rotate and Recip PROD1 Pump out of hole from 14730' to 14376' - 310 gpm / 2250 psi PROD1 Dropped Ball to open CCV -pumped downn ~ 2 bpm / 620 psi -CCV opened l~ 2230 psi PROD1 Dropped Ball to close BHA -500 gpm C~ 1990 psi -Rotate and Recip pipe -100 rpm, 12k ft-Ibs TO -Pump Dry Job -Monitor well - MW in = 8.4+ppg, MW out = 8.4+ ppg PROD1 PJSM. POH 14376' to 9290' (CCV ~ liner top) PROD1 CBU ~ 7" liner top - 580 gpm. PROD1 PJSM. POH to 6269', racking back 5" DP -Change out handling equipment PROD1 PJSM. Rack back 38 stands 4" DP in derrick. -Lay down 72 jts 4" DP to 381' -Close CCV, flush BHA w/fresh water. -Break out and blow down TD. PROD1 PJSM. Lay down BHA. RUNPRD Clean and clear rig floor. Function BOPE. RUNPRD PJSM. Pick up and rig up casing running tools. RUNPRD PJSM. Pick up 475' of 4.5" 12.6" L-80 IBT-M Production Liner. -Pick up liner hanger and liner top packer. -Pick up 3 jts 4" DP to 625' RUNPRD Circulate liner volume at 5 bpm. RUNPRD PJSM. RIH w/ 4" DP singles from 625' to 2370' RUNPRD PJSM. RIH from 2370'to 6209' on 4" stands. -Fill pipe every 20 stands C~3 5 bpm. -160 psi ~ 2463' -220 psi ~ 4333' -290 psi @ 6209' RUNPRD RIH from 6209' to 7" casing shoe ~ 14326' -Cross over from 4" to 5" DP ~ 8804'. -No issues entering 7" liner top ~ 9106'. -Fill pipe every 20 stands and circulating down. -340 psi C~ 8099', 430 psi ~ 9984', 550 psi ~ 11871', 640 psi ~ 13760', 665' C~ 14326'. Printed: 3/27/2008 1:59:21 PM BP EXPLORATION Page 27 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES ~ ' From - To Hours Task Code NPT ~~ Phase Description of Operations Date -_ 2/2/2008 06:00 - 07:00 1.00 CASE P RUNPRD Circulate 250 bbls. @ 7" shoe at 5 bpm, 660 psi. -150k Dn Wt, 215k Up Wt 07:00 - 08:00 1.00 CASE P RUNPRD RIH from 14326' to 14705'. -Make up cement head and single. -Ta bottom ~ 14730'. -Break circulation ~ 5 bpm, 830 psi 08:00 - 10:00 2.00 CEMT P RUNPRD PJSM. Switch to SLB pumps. -Pump 5 bbl water through tee and test lines to 4000 psi. -Pump 20 bbl 12.0 ppg Mud Push -Pump 17 bbl 15.8 ppg Class G Tail Cement -Pump 5 bbls water through tee and blow down SLB lines. -Switch to rig pumps, drop plug and displace with 15 bbl pert pill followed by 8.5 ppg Flo Pro mud. -Reci rocate 8-10' throu h cement 'ob - 230k U 16 n; -Full returns throu hout cement 'ob. -Bump plug w/217 bbls, pressure up to 3000 psi to set hanger, slack off to verify set -good. -Bleed pressure and check floats -good. -Rotate 20 turns right to release running tool. -Pressure up to 1000 psi and pick up to expose pack-off and dog subs, circulate 40 bbls C~3 575 gpm, 2900 psi. -Shut down pumps, set down 35k to set packer, rotate down to verify set -good. -Pull out from tie back receptacle -CIP C~ 0930 hrs 10:00 - 12:00 2.00 CEMT P RUNPRD CBU 2x C~ 590 gpm, 2500 psi. -5 bbls cement back to surface. -Blow down surface equipment. 12:00 - 13:00 1.00 CEMT P RUNPRD PJSM. Lay down cement head and 2 jts 5" DP. Flush out BOPE. 13:00 - 14:30 1.50 CEMT P RUNPRD PJSM. Displace well over to sea water ~ 525 gpm, 2300 psi. 14:30 - 16:00 1.50 CEMT P RUNPRD PJSM. Cut and slip 116' drilling line. Service drawworks, crown, and top drive. 16:00 - 00:00 8.00 CEMT P RUNPRD PJSM. POH 1x1 from 14166'to 6238', laying down DP. 2/3/2008 00:00 - 05:30 5.50 CEMT P RUNPRD Continue laying down DP and running tool. -Clean and clear rig floor. 05:30 - 06:30 1.00 CEMT P RUNPRD PJSM. Rig up and Pressure test casing to 4000 psi for 30 minutes. Test witnessed by BP WSL Mark Staudinger and NTP Jon Castle. 06:30 - 07:30 1.00 EVAL P OTHCMP PJSM. Rig up SLB wireline. 07:30 - 14:30 7.00 EVAL P OTHCMP RIH with E-Line to 14572'. -Lo u to surface with SCMT/GR tool. 14:30 - 15:30 1.00 EVAL P OTHCMP PJSM. Rig down wire line unit. 15:30 - 16:30 1.00 BUNCO RUNCMP PJSM. Service drawworks, crown, and top drive. Adjust brakes. 16:30 - 17:00 0.50 BUNCO RUNCMP PJSM. Pull wear ring. 17:00 - 18:00 1.00 BUNCO RUNCMP PJSM. Pick up and rig up completion running tools. 18:00 - 00:00 6.00 BUNCO RUNCMP PJSM. Pick up 4.5" 12.6# TCII L-80 completion to 2149' -Top 5 threads on pin end of every jt of tubing is rough. Every pin end needs to be cleaned, dressed, and re-doped for connection to make up correctly. 2/4/2008 00:00 - 16:00 16.00 BUNCO RUNCMP Continue to RIH w/ 4-1/2" 12.6# L-80 TCII completion from 2149' to 14212'. -Rough threads on pin end still causing each joint to be Printed: 3/27/2008 1:59:21 PM • BP EXPLORATION Page 28 of 28 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: 2/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/6/2008 Rig Name: NABOBS 2ES Rig Number: 2ES ~ ~ Date. From - To Hours Task Code NPT Phase ~ Description of Operations 2/4/2008 00:00 - 16:00 16.00 BUNCO RUNCMP cleaned, dressed, and re-doped. -Tag liner too (~ 1421 ~' - 8 ft higher than expected. -Rotate WLEG 180 deg and work into TBR. RIH length of TBR (11.5') and tag bottom of TBR. Pick up 5' to determine space o t,, -PUW = 160k Ibs, SOW = 95k lbs. 16:00 - 00:00 8.00 BUNCO SFAL RUNCMP 8 hours of trouble time are charged to the tubing run on this well as the condition of the TC-II threads required additional time to clean, dress and re-dope (top 5 threads "rough" on pin end of all joints). Atypical run rate for this tubing would be in the 22 jt/hr range versus the 12 jt/hr range that was the case for this completion. 2/5/2008 00:00 - 02:00 2.00 BUNCO RUNCMP Space out 4-1/2" completion, make up tbg hanger w/TWC installed and landing joint, land tubing, lay down landing jt. Run in lock down screws. 02:00 - 03:30 1.50 BUNCO RUNCMP Test TWC above and below to 1000 psi for 5 minutes -good test. -Blow down surface equipment -Clean and clear rig floor -Flush out BOP stack 03:30 - 05:30 2.00 BOPSU P RUNCMP PJSM. Nipple down BOPE. 05:30 - 08:30 3.00 WHSUR P RUNCMP PJSM. Raise rig, open cellar, and bring tree and adapter flange into cellar. -Close up cellar, steam tree and adapter -Install blanking flange to tree -Nipple up tree and adapter -Y-Pad Operator verified orientation 08:30 - 10:30 2.00 WHSUR P RUNCMP Test Adapter Flange to 5000 psi for 30 minutes (Cameron). Test tree to 5000 psi for 10 minutes -good test. Rig down. 10:30 - 11:30 1.00 WHSUR P RUNCMP Rig up circ and U-tube equipment to annulus. 11:30 - 13:30 2.00 WHSUR P RUNCMP PJSM. Rig up DSM, test lubricator to 500 psi, pull TWC, rig down DSM. 13:30 - 14:00 0.50 WHSUR P RUNCMP PJSM. Rig up to reverse circulate corrosion inhibited seawater. 14:00 - 18:30 4.50 WHSUR P RUNCMP PJSM. Reverse circulate 215 bbls clean seawater, followed by 426 bbls seawater w/corrosion inhibitor at 3 bpm. 18:30 - 00:00 5.50 WHSUR P RUNCMP PJSM. Rig up Hot Oil, pump 152 bbls diesel down annulus ~ 84 gpm, 150 psi. Allow to U-tube through tree. 2/6/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP Drop ball and rod. Rig up Hot Oil for pressure testing. 01:00 - 03:00 2.00 WHSUR P RUNCMP Pressure up tubing to 4000 psi to set packer and test for 30 minutes. -Bleed pressure to 2000 si ressure u IA to 4000 si nd 0 or 30 minutes. Good test. -Test witnessed by BPWSL Mark Staudinger and NTP Jon Castle. 03:00 - 05:00 2.00 WHSUR P RUNCMP Rig down Hot Oil. Install BPV. Secure well w/flanges, bull plugs w/needle valves and pressure gauges. -Release rig from operations Y-07Ai on 2/6/08 ~ 05:00 hrs. Printed: 3/27/2008 1:59:21 PM • Y-07A Well History -Post Rig Sidetrack Date Summary 2/19/2008 Pulled BPV. T/I/O =VAC/0/0 2/25/2008 PULLED BALUROD FROM 14,186' SLM. PULLED 4-1/2" RHC FROM AT 14,195' SLM. TAGGED BTM AT 14,469' MD W/ 3-3/8" DUMMY GUN (SAMPLE OF MUD/CLAY). RAN PDS MEM GR/CCL. LOGGED FROM 14,450' SLM UP TO 14,000' SLM, GOOD DATA. WELL S/I ON DEPARTURE, NOTIFIED DSO. 4/4/2008 Continue RIH with 2.50" OD JSN. Dry tag top of fill at 14504' ctmd. Perform FCO with gel sweeps to hard tag at 14544' ctmd; unable to work past this depth. POOH and call for motor and mill. While POOH, inspect a bad section of the coil and find pipe wall thickness below minimums, decide to abort job. Pull to surface, freeze protect well, and blow down reel. RDMO. Road unit to shop for reel swap. Job incomplete, failed to achieve objective depth. 4/18/2008 MIRU CTU. Perform BOP test. Begin milling / FCO in the morning. 4/19/2008 RIH with 2-7/8" WFD MHA and 3.65" OD 5 blade cowboy mill to 14,493' CTMD. Dry tagged lightly, picked up and began milling from 14,493' to 14,629' (14,617' with weight back) making frequent Geovis XT gel sweeps. Hard spot at 14,629' making little to no progress. We appear to be on the 4.5" Baker landing collar at 14643.78' per tubing tally Chase OOH at 80% to inspect MHA and shut down for the day. Inspect MHA and mill, confer with APE on plan forward. Mill shows signs of wear from hard milling on metal. APE wants to do some diagnostics with slickline and E line before we mill any further. Well is freeze protected to 2000' with 60/40 meth water. Pad operator notified of well conditions. RD coil unit. Job Complete. 4/21/2008 WORKED 3 3/8" DUMMY GUN, S-BLR THRU TIGHT SPOTS FROM 3500' TO 4100' SLM. UNABLE TO WORK D.GUN PAST 14,588' SLM (small sample of what appears to be scale). TAGGED HARD BTM C«~ 14614' SLM W/ 2.50" x 5' DD-BLR (1/4 cup metal shavings & scale). CURRENTLY RIH W/SLB MEMORY GR/CCL. 4/22/2008 LOGGED SLB MEMORY GR/CCL FROM 14,614' SLM TO 13,834' SLM, GOOD DATA. WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR. 4/25/2008 T/I/O = 160NAC/20. Temp = SI. IA FL (pre E-line). IA FL @ 48' (3 Bbls). 5/2/2008 INITIAL WHP= T/IA/OA = 40/0/0. RIH W/ SCMT. TIGHT SPOT @ 3700-4100'. POOH, ADDED ROLLERS TO TOOLSTRING TO GET PAST RESTRICTION. CEMENT IN AREA OF INTEREST 14545'-14585' NOT GOOD. PE DECIDED NOT TO PERF PENDING FURTHER REVIEW OF LOG. RIGGED DOWN. FINAL WHP= T/IA/OA: 50/0/0. WELL LEFT SHUT IN. 5/9/2008 INITIAL T/I/0=100/0/0 RU E-LINE FOR DRIFT AND TAG WITH 10' 2 7/8" DUMMY GUN. 5/10/2008 CONTINUE RIH WITH 10' DUMMY GUN FOR TEMP SURVEY /DRIFT AND TAG. 2 RUNS -PERFORATE WITH 2.88" POWERJET OMEGA 6 SPF FROM 14545'-14585'. FINAL T/I/O = 0/0/0. WELL LEFT SHUT-IN, JOB COMPLETED. Page 1 of 1 ,~ Sperry Drilling Services Survey Report Company°: BP AmoCO - _ Date. 2/14/2008 ~hlml 14:42:02 Yage: 1 ii Field: Prudhoe Bay Site: PB Y Pad Co-ordinate(NE) Keference: Well: Y-07, True North Vertical (TVD) liefcren~e. Y-07A: 79.6 I Well: Y-07 Section (VS) Referen ce: Well (O.OON,O.OOE,306.45Azi) Wellpath: Y-07APB1 Survey Calculation Method: Minimum Curvatu re llb: Oracle Survey NID Iucl Azim TVA S ys TVD N/5 E/W Map1l~ 14IapE Tool ft deg deg ft ft ft ft ft ft -._ _ 29.62 0.00 0.00 - 29.62 _ -49.96 0.00 0.00 5948916.58 644932.60 TIE LINE 92.78 0.92 170.11 92.78 13.20 -0.50 0.09 5948916.08 644932.70 BOSS-GYRO 192.78 0.92 188.69 192.76 113.18 -2.08 0.10 5948914.50 644932.74 BOSS-GYRO 292.78 0.88 190.60 292.75 213.17 -3.63 -0.16 5948912.95 644932.51 BOSS-GYRO 392.78 0.92 194.39 392.74 313.16 -5.16 -0.50 5948911.41 644932.20 BOSS-GYRO 492.78 0.88 194.79 492.73 413.15 -6.68 -0.90 5948909.88 644931.83 BOSS-GYRO 592.78 0.62 190.89 592.72 513.14 -7.96 -1.19 5948908.60 644931.56 BOSS-GYRO 692.78 0.40 167.61 692.72 613.14 -8.83 -1.22 5948907.73 644931.55 BOSS-GYRO 792.78 0.38 131.81 792.71 713.13 -9.39 -0.90 5948907.17 644931.88 BOSS-GYRO 892.78 0.38 116.81 892.71 813.13 -9.76 -0.36 5948906.81 644932.43 BOSS-GYRO 992.78 0.47 93.31 992.71 913.13 -9.94 0.35 5948906.65 644933.14 BOSS-GYRO 1092.78 0.50 71.80 1092.70 1013.12 -9.82 1.17 5948906.78 644933.96 BOSS-GYRO 1192.78 0.32 76.80 1192.70 1113.12 -9.62 1.86 5948906.99 644934.65 BOSS-GYRO 1292.78 0.28 349.30 1292.70 1213.12 -9.32 2.09 5948907.30 644934.87 BOSS-GYRO 1392.78 0.32 326.11 1392.70 1313.12 -8.85 1.89 5948907.77 644934.66 BOSS-GYRO 1492.78 0.15 166.61 1492.70 1413.12 -8.74 1.76 5948907.87 644934.53 BOSS-GYRO 1592.78 0.35 171.81 1592.70 1513.12 -9.17 1.83 5948907.44 644934.61 BOSS-GYRO 1692.78 0.60 171.70 1692.69 1613.11 -9.99 1.95 5948906.63 644934.75 BOSS-GYRO 1792.78 0.80 169.11 1792.69 1713.11 -11.20 2.16 5948905.43 644934.98 BOSS-GYRO 1892.78 0.57 188.60 1892.68 1813.10 -12.38 2.22 5948904.25 644935.06 BOSS-GYRO 1992.78 0.60 189.29 1992.67 1913.09 -13.38 2.06 5948903.24 644934.92 BOSS-GYRO 2020.00 1.34 319.04 2019.89 1940.31 -13.28 1.83 5948903.33 644934.68 MWD+IFR+MS 2044.00 2.99 323.21 2043.87 1964.29 -12.57 1.27 5948904.04 644934.11 MWD+IFR+MS 2073.00 4.58 317.97 2072.81 1993.23 -11.10 0.04 5948905.48 644932.85 MWD+IFR+MS 2173.00 6.72 318.57 2172.32 2092.74 -3.75 -6.50 5948912.70 644926.17 MWD+IFR+MS 2220.97 7.85 316.25 2219.90 2140.32 0.72 -10.63 5948917.09 644921.96 MWD+IFR+MS 2251.79 9.62 319.75 2250.36 2170.78 4.21 -13.75 5948920.52 644918.78 MWD+IFR+MS 2282.44 11.71 316.76 2280.48 2200.90 8.43 -17.53 5948924.67 644914.91 MWD+IFR+MS 2313.50 13.92 315.93 2310.77 2231.19 13.41 -22.29 5948929.55 644910.06 MWD+IFR+MS 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 Well: Y-07 Slot Name: Y-07 Well Position: +N/-S 430.33 ft Northing: 5948916.58 ft Latitude: 70 16 4.268 N +E/-W -2808.44 ft Easting : 644932.60 ft Longitude: 148 49 40.738 W Position Uncertainty: 0.00 ft Wellpath: Y-07APB1 Drilled From: Y-07 500292056070 Tie-on Depth: 1992.78 ft Current Datum: Y-07A: Height 79.58 ft Above System Datum: Mean Sea Level Magnetic Data: 12/20/2007 Declination: 23.39 deg Field Strength: 57656 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 29.62 0.00 0.00 306.45 Survey Program for Definitive Wellpath Date: 2/14/2008 Validated: Yes Version: 13 Actual From To Survey Toolcode Tool Name ft ft 92.78 12617.95 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 2020.00 12617.35 Y-07APB1 MWD-IFR-MS Sperry (20 MWD+IFR+MS MWD +IFR + Multi Station ' • Sperry Drilling Services Survey Report Company: BRAmoCO Field: Prudhoe Bay Sites PB Y Pad I «'ell: Y-07 ~~ Welipath: Y-07APB1 Survcr' I NID [ncl ft deg zim deg VD ft ys'PVD ft llate: 2/14/2008 Timc: 14:42:02 Yagc: 2 Co-ordinate(NF) Iicference: Well: Y-07, True North Vertical (1'VU) Reference: Y-07A: 79.6 Section (VS) Reference: Well (O.OON,O.OOE,306.45Azi) Sarver Calculation 111cthod: Minimum Curvature Db: Oracle N/S E/W blapN AIapE Tool ft ' ft ft ft 2408.16 17.35 313.74 2401.91 2322.33 31.35 -40.41 5948947.15 644891.59 MWD+IFR+MS 2501.88 20.83 316.54 2490.47 2410.89 53.12 -61.98 5948968.49 644869.61 MWD+IFR+MS 2596.15 25.40 320.92 2577.15 2497.57 80.99 -86.27 5948995.89 644844.80 MWD+IFR+MS 2628.52 26.98 322.03 2606.20 2526.62 92.17 -95.16 5949006.90 644835.69 MWD+IFR+MS 2659.74 28.56 322.55 2633.82 2554.24 103.68 -104.06 5949018.23 644826.57 MWD+IFR+MS 2691.00 31.04 322.46 2660.94 2581.36 116.00 -113.51 5949030.37 644816.88 MWD+IFR+MS 2785.19 35.36 320.84 2739.74 2660.16 156.41 -145.54 5949070.15 644784.09 MWD+IFR+MS 2878.05 39.19 319.32 2813.62 2734.04 199.51 -181.64 5949112.54 644747.16 MWD+IFR+MS 2972.30 41.94 317.42 2885.22 2805.64 245.30 -222.37 5949157.53 644705.56 MWD+IFR+MS 3067.30 43.80 316.25 2954.84 2875.26 292.43 -266.59 5949203.80 644660.45 MWD+IFR+MS 3159.43 47.32 316.28 3019.34 2939.76 339.95 -312.06 5949250.43 644614.08 MWD+IFR+MS 3256.58 49.97 315.64 3083.52 3003.94 392.36 -362.76 5949301.85 644562.39 MWD+IFR+MS 3350.21 52.45 312.37 3142.18 3062.60 443.02 -415.26 5949351.49 644508.92 MWD+IFR+MS 3444.19 53.49 308.67 3198.79 3119.21 491.74 -472.28 5949399.09 644450.97 MWD+IFR+MS 3539.08 55.00 304.96 3254.25 3174.67 537.85 -533.93 5949444.01 644388.46 MWD+IFR+MS 3633.97 58.85 304.63 3306.02 3226.44 583.21 -599.21 5949488.10 644322.32 MWD+IFR+MS 3729.71 61.95 306.37 3353.31 3273.73 631.56 -666.96 5949535.13 644253.65 MWD+IFR+MS 3779.76 62.05 308.05 3376.81 3297.23 658.28 -702.15 5949561.17 644217.96 MWD+IFR+MS 3835.59 63.73 308.13 3402.25 3322.67 688.94 -741.27 5949591.06 644178.26 MWD+IFR+MS 3931.25 64.76 306.69 3443.82 3364.24 741.27 -809.70 5949642.07 644108.84 MWD+IFR+MS 4023.75 64.35 305.66 3483.56 3403.98 790.57 -877.12 5949690.06 644040.49 MWD+IFR+MS 4117.87 64.55 303.79 3524.16 3444.58 838.94 -946.91 5949737.07 643969.78 MWD+IFR+MS 4213.55 64.70 303.42 3565.16 3485.58 886.79 -1018.91 5949783.52 643896.88 MWD+IFR+MS 4307.76 64.66 303.86 3605.45 3525.87 933.96 -1089.81 5949829.32 643825.09 MWD+IFR+MS 4401.69 64.42 305.00 3645.83 3566.25 981.91 -1159.76 5949875.91 643754.24 MWD+IFR+MS 4495.80 64.27 305.91 3686.58 3607.00 1031.12 -1228.86 5949923.77 643684.21 MWD+IFR+MS 4589.03 63.82 307.17 3727.38 3647.80 1081.02 -1296.21 5949972.37 643615.92 MWD+IFR+MS 4683.18 63.93 308.17 3768.84 3689.26 1132.68 -1363.12 5950022.72 643548.03 MWD+IFR+MS 4778.11 63.93 309.47 3810.56 3730.98 1186.13 -1429.55 5950074.88 643480.58 MWD+IFR+MS 4870.43 64.01 310.18 3851.07 3771.49 1239.26 -1493.26 5950126.77 643415.87 MWD+IFR+MS 4966.28 64.10 309.26 3893.01 3813.43 1294.34 -1559.56 5950180.56 643348.53 MWD+IFR+MS 5061.83 64.14 307.88 3934.72 3855.14 1347.94 -1626.77 5950232.84 643280.31 MWD+IFR+MS 5155.85 64.23 306.09 3975.66 3896.08 1398.85 -1694.37 5950282.44 643211.74 MWD+IFR+MS 5250.99 63.96 305.62 4017.23 3937.65 1448.98 -1763.74 5950331.22 643141.43 MWD+IFR+MS 5345.34 63.93 305.50 4058.67 3979.09 1498.27 -1832.69 5950379.18 643071.54 MWD+IFR+MS 5440.65 63.85 305.39 4100.62 4021.04 1547.90 -1902.41 5950427.45 643000.88 MWD+IFR+MS 5534.37 65.24 306.78 4140.90 4061.32 1597.75 -1970.79 5950475.97 642931.56 MWD+IFR+MS 5627.46 64.97 305.75 4180.08 4100.50 1647.69 -2038.87 5950524.59 642862.54 MWD+IFR+MS 5721.79 64.57 304.17 4220.29 4140.71 1696.59 -2108.80 5950572.13 642791.69 MWD+IFR+MS 5816.41 64.09 302.86 4261.28 4181.70 1743.68 -2179.90 5950617.83 642719.70 MWD+IFR+MS 5911.51 63.18 301.67 4303.52 4223.94 1789.17 -2251.95 5950661.92 642646.80 MWD+IFR+MS 6006.65 63.89 302.99 4345.92 4266.34 1834.72 -2323.91 5950706.07 642573.97 MWD+IFR+MS 6101.50 63.32 304.44 4388.09 4308.51 1881.87 -2394.58 5950751.86 642502.41 MWD+IFR+MS 6195.20 62.99 307.72 4430.41 4350.83 1931.09 -2462.14 5950799.77 642433.93 MWD+IFR+MS 6288.70 64.29 309.09 4471.92 4392.34 1983.14 -2527.78 5950850.53 642367.30 MWD+IFR+MS 6383.83 64.48 308.07 4513.05 4433.47 2036.63 -2594.84 5950902.72 642299.23 MWD+IFR+MS 6477.40 64.08 305.90 4553.66 4474.08 2087.34 -2662.17 5950952.12 642230.94 MWD+IFR+MS 6571.69 63.11 305.39 4595.59 4516.01 2136.56 -2730.80 5951000.01 642161.38 MWD+IFR+MS 6666.43 63.60 303.42 4638.08 4558.50 2184.40 -2800.66 5951046.49 642090.62 MWD+IFR+MS 6762.04 64.64 302.06 4679.82 4600.24 2230.92 -2873.01 5951091.60 642017.39 MWD+IFR+MS 6856.81 64.61 301.66 4720.43 4640.85 2276.12 -2945.74 5951135.39 641943.81 MWD+IFR+MS 6951.09 64.28 302.78 4761.10 4681.52 2321.46 -3017.70 5951179.34 641871.00 MWD+IFR+MS .~ • Sperry Drilling Services Survey Report Company: BP AmoCO I)atc: 2/14/2008 Time: 14:42:02 Page: 3 Ticld: Pru dhoe Bay Co-ord inatc(NE)Re ference: Well: Y-07, True North Site: PB Y Pad Vertical (TVDj Refe rence: Y- 07A: 79.6 Nell: Y-07 Section (VS) Referen ce: Well (O.OON,O.OOE,306.45Azi) Wcllpath: Y-07APB1 Survey Calculation Method: M inimum Curvatu re Db: Oracle Survey MD Incl Arim TVD Sys TVD N/S IJ/VV NIapN MapF. Tool ft deg deg ft ft ft ft ft ft 7045.34 63.32 306.34 4802.72 4723.14 2369.41 -3087.33 5951225.94 641800.46 MWD+IFR+MS 7140.05 63.73 306.99 4844.95 4765.37 2420.04 -3155.33 5951275.24 641731.50 MWD+IFR+MS 7235.29 64.28 307.00 4886.69 4807.11 2471.55 -3223.70 5951325.42 641662.16 MWD+IFR+MS 7330.05 64.77 307.94 4927.45 4847.87 2523.59 -3291.60 5951376.14 641593.28 MWD+IFR+MS 7424.14 64.37 307.60 4967.85 4888.27 2575.64 -3358.77 5951426.88 641525.12 MWD+IFR+MS 7519.72 63.89 307.88 5009.56 4929.98 2628.28 -3426.78 5951478.20 641456.12 MWD+IFR+MS 7612.78 63.95 306.72 5050.47 4970.89 2678.93 -3493.27 5951527.55 641388.67 MWD+IFR+MS 7706.35 63.89 307.04 5091.60 5012.02 2729.37 -3560.49 5951576.68 641320.49 MWD+IFR+MS 7801.79 63.33 306.54 5134.03 5054.45 2780.57 -3628.96 5951626.55 641251.06 MWD+IFR+MS 7895.59 63.33 306.88 5176.13 5096.55 2830.67 -3696.15 5951675.35 641182.92 MWD+IFR+MS 7989.98 63.88 306.97 5218.09 5138.51 2881.47 -3763.74 5951724.83 641114.37 MWD+IFR+MS 8083.40 64.09 305.49 5259.07 5179.49 2931.08 -3831.46 5951773.13 641045.71 MWD+IFR+MS 8179.14 64.02 305.19 5300.95 5221.37 2980.88 -3901.69 5951821.56 640974.54 MWD+IFR+MS 8273.24 63.83 305.42 5342.31 5262.73 3029.73 -3970.67 5951869.07 640904.64 MWD+IFR+MS 8366.90 64.36 307.38 5383.24 5303.66 3079.72 -4038.47 5951917.75 640835.89 MWD+IFR+MS 8461.50 64.01 306.99 5424.43 5344.85 3131.19 -4106.32 5951967.90 640767.07 MWD+IFR+MS 8556.21 64.06 306.18 5465.90 5386.32 3181.94 -4174.69 5952017.32 640697.74 MWD+IFR+MS 8650.44 63.80 306.18 5507.31 5427.73 3231.91 -4243.01 5952065.96 640628.48 MWD+IFR+MS 8744.07 64.10 305.88 5548.43 5468.85 3281.39 -4311.04 5952114.11 640559.51 MWD+IFR+MS 8838.24 64.65 305.59 5589.15 5509.57 3330.98 -4379.96 5952162.36 640489.66 MWD+IFR+MS 8932.44 63.93 305.36 5630.02 5550.44 3380.23 -4449.08 5952210.27 640419.61 MWD+IFR+MS 9028.15 63.75 305.85 5672.22 5592.64 3430.25 -4518.92 5952258.93 640348.82 MWD+IFR+MS 9122.20 64.08 306.03 5713.57 5633.99 3479.83 -4587.31 5952307.18 640279.49 MWD+IFR+MS 9216.20 64.18 306.90 5754.59 5675.01 3530.09 -4655.33 5952356.12 640210.52 MWD+IFR+MS 9274.70 64.30 306.60 5780.01 5700.43 3561.62 -4697.55 5952386.83 640167.71 MWD+IFR+MS 9312.93 64.20 303.56 5796.62 5717.04 3581.40 -4725.72 5952406.07 640139.16 MWD+IFR+MS 9406.62 63.18 304.66 5838.15 5758.57 3628.50 -4795.26 5952451.81 640068.74 MWD+IFR+MS 9500.46 63.03 304.91 5880.60 5801.02 3676.24 -4863.99 5952498.22 639999.10 MWD+IFR+MS 9594.04 65.16 310.00 5921.50 5841.92 3727.43 -4930.76 5952548.11 639931.37 MWD+IFR+MS 9688.89 65.95 309.14 5960.75 5881.17 3782.44 -4997.32 5952601.82 639863.76 MWD+IFR+MS 9781.96 64.01 306.58 6000.12 5920.54 3834.20 -5063.89 5952652.28 639796.22 MWD+IFR+MS 9877.59 65.50 302.36 6040.92 5961.34 3883.12 -5135.18 5952699.82 639724.00 MWD+IFR+MS 9972.21 63.88 301.34 6081.37 6001.79 3928.26 -5207.83 5952743.55 639650.50 MWD+IFR+MS 10066.59 63.67 302.61 6123.07 6043.49 3973.09 -5279.65 5952786.99 639577.84 MWD+IFR+MS 10162.04 63.64 303.90 6165.43 6085.85 4020.00 -5351.18 5952832.50 639505.43 MWD+IFR+MS 10256.45 63.90 302.91 6207.16 6127.58 4066.62 -5421.88 5952877.75 639433.85 MWD+IFR+MS 10352.46 63.74 306.13 6249.53 6169.95 4115.44 -5492.85 5952925.19 639361.95 MWD+IFR+MS 10445.66 63.08 308.57 6291.25 6211.67 4165.99 -5559.10 5952974.45 639294.75 MWD+IFR+MS 10538.29 58.01 307.51 6336.79 6257.21 4215.69 -5622.59 5953022.92 639230.32 MWD+IFR+MS 10631.62 55.23 303.39 6388.15 6308.57 4260.91 -5686.03 5953066.90 639166.03 MWD+IFR+MS 10727.17 50.51 303.53 6445.81 6366.23 4302.89 -5749.56 5953107.66 639101.70 MWD+IFR+MS 10821.63 45.64 303.23 6508.90 6429.32 4341.56 -5808.23 5953145.18 639042.31 MWD+IFR+MS 10916.76 43.75 305.98 6576.53 6496.95 4379.52 -5863.30 5953182.07 638986.52 MWD+IFR+MS 11011.31 41.88 306.62 6645.88 6566.30 4417.56 -5915.09 5953219.10 638934.01 MWD+IFR+MS 11105.02 42.56 302.30 6715.30 6635.72 4453.16 -5966.99 5953253.69 638881.43 MWD+IFR+MS 11200.08 45.06 301.03 6783.89 6704.31 4487.69 -6023.01 5953287.13 638824.77 MWD+IFR+MS 11294.80 43.34 304.99 6851.81 6772.23 4523.61 -6078.38 5953321.99 638768.72 MWD+IFR+MS 11388.65 41.67 308.42 6921.00 6841.42 4561.48 -6129.21 5953358.86 638717.17 MWD+IFR+MS 11482.48 42.68 305.70 6990.55 6910.97 4599.42 -6179.49 5953395.83 638666.18 MWD+IFR+MS 11576.93 43.25 308.20 7059.67 6980.09 4638.12 -6230.92 5953433.53 638614.02 MWD+IFR+MS 11676.03 43.14 307.12 7131.91 7052.33 4679.56 -6284.61 5953473.92 638559.54 MWD+IFR+MS 11767.55 43.25 306.43 7198.64 7119.06 4717.06 -6334.79 5953510.45 638508.65 MWD+IFR+MS 11861.54 43.23 307.63 7267,11 7187.53 4755.84 -6386.19 5953548.23 638456.52 MWD+IFR+MS :~•~ i • Sperry Drilling Services Survey Report -`Company: BP AmoCO llatr. 2114{2008 Time: 14:42:02 Page: 4 Field: Prudhoe Bay Co-ordinateiNE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical 11'VI)) Reference: Y-07A: 79.6 Well: Y-07 Section(VS)Kefercnce: Well (O.OON,O.OOE,306.45Azi) Wegpath: Sarvev Y-07APB1 Survey Calculation 3lcthod: Minimum Curvature T)b: Oracle MI) Incl Azim TVD Sys'TVD N/S E/W NiapN MapE Tool ft deg deg ft ft ft ft ft ft 11956.21 45.34 308.81 7334.88 7255.30 4796.74 -6438.11 5953588.12 638403.82 MWD+IFR+MS 12050.17 42.32 304.54 7402.67 7323.09 4835.64 -6490.23 5953626.00 638350.97 MWD+IFR+MS 12145.53 42.85 301.93 7472.88 7393.30 4870.99 -6544.20 5953660.30 638296.34 MWD+IFR+MS 12240.88 44.63 301.78 7541.77 7462.19 4905.78 -6600.19 5953694.01 638239.69 MWD+IFR+MS 12334.64 45.01 302.20 7608.28 7528.70 4940.79 -6656.24 5953727.93 638182.98 MWD+IFR+MS 12429.76 46.09 302.82 7674.89 7595.31 4977.29 -6713.50 5953763.32 638125.03 MWD+IFR+MS 12523.64 46.33 302.76 7739.85 7660.27 5013.99 -6770.47 5953798.91 638067.37 MWD+IFR+MS 12617.35 46.50 302.41 7804.46 7724.88 5050.55 -6827.67 5953834.36 638009.48 MWD+IFR+MS 12745.00 46.50 302.41 7892.33 7812.75 5100.17 -6905.84 5953882.47 637930.38 BLIND ,, i r Sperry Drilling Services Survey Report ~~~ Compan}~: BP AmOCO llate: 2/14/2008 Time: 14:42:55 Page: 1 Field: Prudhoe Bay Co-ordinatc(NE) Refere^ce: Well: Y-07, True North Site: PB Y Pad Vertical t'f VD) Reference: Y-07A: 79.6 Well: Y-07 Section (VS)12eference: Well (O.OON,O.OOE,306.14Azi) Wellpath: Y-07A Survey CalculationMetbod: Minimum Curvature llb: Oracle Survey -- j n~II) Incl Azim TVD Sys TVD N/S E/W D~IapN DIapE Tool ft deg deg ft ft ft ft ft ft _-- - 29.62 0.00 0.00 29.62 -49.96 0.00 0.00 5948916.58 644932.60 TIE LINE 92.78 0.92 170.11 92.78 13.20 -0.50 0.09 5948916.08 644932.70 BOSS-GYRO 192.78 0.92 188.69 192.76 113.18 -2.08 0.10 5948914.50 644932.74 BOSS-GYRO 292.78 0.88 190.60 292.75 213.17 -3.63 -0.16 5948912.95 644932.51 BOSS-GYRO 392.78 0.92 194.39 392.74 313.16 -5.16 -0.50 5948911.41 644932.20 BOSS-GYRO 492.78 0.88 194.79 492.73 413.15 -6.68 -0.90 5948909.88 644931.83 BOSS-GYRO 592.78 0.62 190.89 592.72 513.14 -7.96 -1.19 5948908.60 644931.56 BOSS-GYRO 692.78 0.40 167.61 692.72 613.14 -8.83 -1.22 5948907.73 644931.55 BOSS-GYRO 792.78 0.38 131.81 792.71 713.13 -9.39 -0.90 5948907.17 644931.88 BOSS-GYRO 892.78 0.38 116.81 892.71 813.13 -9.76 -0.36 5948906.81 644932.43 BOSS-GYRO 992.78 0.47 93.31 992.71 913.13 -9.94 0.35 5948906.65 644933.14 BOSS-GYRO 1092.78 0.50 71.80 1092.70 1013.12 -9.82 1.17 5948906.78 644933.96 BOSS-GYRO 1192.78 0.32 76.80 1192.70 1113.12 -9.62 1.86 5948906.99 644934.65 BOSS-GYRO 1292.78 0.28 349.30 1292.70 1213.12 -9.32 2.09 5948907.30 644934.87 BOSS-GYRO 1392.78 0.32 326.11 1392.70 1313.12 -8.85 1.89 5948907.77 644934.66 BOSS-GYRO 1492.78 0.15 166.61 1492.70 1413.12 -8.74 1.76 5948907.87 644934.53 BOSS-GYRO 1592.78 0.35 171.81 1592.70 1513.12 -9.17 1.83 5948907.44 644934.61 BOSS-GYRO 1692.78 0.60 171.70 1692.69 1613.11 -9.99 1.95 5948906.63 644934.75 BOSS-GYRO 1792.78 0.80 169.11 1792.69 1713.11 -11.20 2.16 5948905.43 644934.98 BOSS-GYRO 1892.78 0.57 188.60 1892.68 1813.10 -12.38 2.22 5948904.25 644935.06 BOSS-GYRO 1992.78 0.60 189.29 1992.67 1913.09 -13.38 2.06 5948903.24 644934.92 BOSS-GYRO 2020.00 1.34 319.04 2019.89 1940.31 -13.28 1.83 5948903.33 644934.68 MWD+IFR+MS 2044.00 2.99 323.21 2043.87 1964.29 -12.57 1.27 5948904.04 644934.11 MWD+IFR+MS 2073.00 4.58 317.97 2072.81 1993.23 -11.10 0.04 5948905.48 644932.85 MWD+IFR+MS 2173.00 6.72 318.57 2172.32 2092.74 -3.75 -6.50 5948912.70 644926.17 MWD+IFR+MS 2220.97 7.85 316.25 2219.90 2140.32 0.72 -10.63 5948917.09 644921.96 MWD+IFR+MS 2251.79 9.62 319.75 2250.36 2170.78 4.21 -13.75 5948920.52 644918.78 MWD+IFR+MS 2282.44 11.71 316.76 2280.48 2200.90 8.43 -17.53 5948924.67 644914.91 MWD+IFR+MS 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 Well: Y-07 Slot Name: Y-07 Well Position: +N/-S 430.33 ft Northing: 5948916.58 ft Latitude: 70 16 4.268 N +E/-W -2808.44 ft Easting : 644932.60 ft Longitude: 148 49 40.738 W Position Uncertainty: 0.00 ft Wellpath: Y-07A Drilled From: Y-07AP61 500292056001 Tie-on Depth: 9301.12 ft Current Datum: Y-07A: Height 79.58 ft Above System Datum: Mean Sea Level Magnetic Data: 12/20/2007 Declination: 23.35 deg Field Strength: 57658 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 29.62 0.00 0.00 306.14 Survey Program for Definitive Wellpath Date: 2/14/2008 Validated: Yes Version: 5 Actual From To Survey Toolcode Tool Name ft ft 92.78 12617.95 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 2020.00 12617.35 Y-07AP61 MWD-IFR-MS Sperry (20 MWD+IFR+MS MWD +IFR + Multi Station 12617.95 14657.85 Y-07A MWD-IFR-MS (9398.59-1465 MWD+IFR+MS MWD +IFR + Multi Station Sperry Drilling Services Survey Report I Company: BP Amoeo Field: Prudhoe Bay Site: PB Y Pad ~-Nell: Y-07 Wellpath: Y-07A Survey Date: 2/14/2008 Time: 14:42:55 Page: 2 Co-ordiuate(NE) Refemncc: Well: Y-07, True North Vertical (TVD) Re1'ereuce: Y-07A: 79.6 Section (VSj Reference: Well (O.OON,O.OOE,306.14Azi) Survey Calculation blet6od: Minimum Curvature llb: Oracle DID Incl Azim TVD Sys 1'VD N/S E/W MapN MapE Tool ~ ft deg deg ft ft ft ft ft ft 2313.50 13.92 315.93 2310.77 2231.19 13.41 -22.29 5948929.55 644910.06 MWD+IFR+MS 2408.16 17.35 313.74 2401.91 2322.33 31.35 -40.41 5948947.15 644891.59 MWD+IFR+MS 2501.88 20.83 316.54 2490.47 2410.89 53.12 -61.98 5948968.49 644869.61 MWD+IFR+MS 2596.15 25.40 320.92 2577.15 2497.57 80.99 -86.27 5948995.89 644844.80 MWD+IFR+MS 2628.52 26.98 322.03 2606.20 2526.62 92.17 -95.16 5949006.90 644835.69 MWD+IFR+MS 2659.74 28.56 322.55 2633.82 2554.24 103.68 -104.06 5949018.23 644826.57 MWD+IFR+MS 2691.00 31.04 322.46 2660.94 2581.36 116.00 -113.51 5949030.37 644816.88 MWD+IFR+MS 2785.19 35.36 320.84 2739.74 2660.16 156.41 -145.54 5949070.15 644784.09 MWD+IFR+MS 2878.05 39.19 319.32 2813.62 2734.04 199.51 -181.64 5949112.54 644747.16 MWD+IFR+MS 2972.30 41.94 317.42 2885.22 2805.64 245.30 -222.37 5949157.53 644705.56 MWD+IFR+MS 3067.30 43.80 316.25 2954.84 2875.26 292.43 -266.59 5949203.80 644660.45 MWD+IFR+MS 3159.43 47.32 316.28 3019.34 2939.76 339.95 -312.06 5949250.43 644614.08 MWD+IFR+MS 3256.58 49.97 315.64 3083.52 3003.94 392.36 -362.76 5949301.85 644562.39 MWD+IFR+MS 3350.21 52.45 312.37 3142.18 3062.60 443.02 -415.26 5949351.49 644508.92 MWD+IFR+MS 3444.19 53.49 308.67 3198.79 3119.21 491.74 -472.28 5949399.09 644450.97 MWD+IFR+MS 3539.08 55.00 304.96 3254.25 3174.67 537.85 -533.93 5949444.01 644388.46 MWD+IFR+MS 3633.97 58.85 304.63 3306.02 3226.44 583.21 -599.21 5949488.10 644322.32 MWD+IFR+MS 3729.71 61.95 306.37 3353.31 3273.73 631.56 -666.96 5949535.13 644253.65 MWD+IFR+MS 3779.76 62.05 308.05 3376.81 3297.23 658.28 -702.15 5949561.17 644217.96 MWD+IFR+MS 3835.59 63.73 308.13 3402.25 3322.67 688.94 -741.27 5949591.06 644178.26 MWD+IFR+MS 3931.25 64.76 306.69 3443.82 3364.24 741.27 -809.70 5949642.07 644108.84 MWD+IFR+MS 4023.75 64.35 305.66 3483.56 3403.98 790.57 -877.12 5949690.06 644040.49 MWD+IFR+MS 4117.87 64.55 303.79 3524.16 3444.58 838.94 -946.91 5949737.07 643969.78 MWD+IFR+MS 4213.55 64.70 303.42 3565.16 3485.58 886.79 -1018.91 5949783.52 643896.88 MWD+IFR+MS 4307.76 64.66 303.86 3605.45 3525.87 933.96 -1089.81 5949829.32 643825.09 MWD+IFR+MS 4401.69 64.42 305.00 3645.83 3566.25 981.91 -1159.76 5949875.91 643754.24 MWD+IFR+MS 4495.80 64.27 305.91 3686.58 3607.00 1031.12 -1228.86 5949923.77 643684.21 MWD+IFR+MS 4589.03 63.82 307.17 3727.38 3647.80 1081.02 -1296.21 5949972.37 643615.92 MWD+IFR+MS 4683.18 63.93 308.17 3768.84 3689.26 1132.68 -1363.12 5950022.72 643548.03 MWD+IFR+MS 4778.11 63.93 309.47 3810.56 3730.98 1186.13 -1429.55 5950074.88 643480.58 MWD+IFR+MS 4870.43 64.01 310.18 3851.07 3771.49 1239.26 -1493.26 5950126.77 643415.87 MWD+IFR+MS 4966.28 64.10 309.26 3893.01 3813.43 1294.34 -1559.56 5950180.56 643348.53 MWD+IFR+MS 5061.83 64.14 307.88 3934.72 3855.14 1347.94 -1626.77 5950232.84 643280.31 MWD+IFR+MS 5155.85 64.23 306.09 3975.66 3896.08 1398.85 -1694.37 5950282.44 643211.74 MWD+IFR+MS 5250.99 63.96 305.62 4017.23 3937.65 1448.98 -1763.74 5950331.22 643141.43 MWD+IFR+MS 5345.34 63.93 305.50 4058.67 3979.09 1498.27 -1832.69 5950379.18 643071.54 MWD+IFR+MS 5440.65 63.85 305.39 4100.62 4021.04 1547.90 -1902.41 5950427.45 643000.88 MWD+IFR+MS 5534.37 65.24 306.78 4140.90 4061.32 1597.75 -1970.79 5950475.97 642931.56 MWD+IFR+MS 5627.46 64.97 305.75 4180.08 4100.50 1647.69 -2038.87 5950524.59 642862.54 MWD+IFR+MS 5721.79 64.57 304.17 4220.29 4140.71 1696.59 -2108.80 5950572.13 642791.69 MWD+IFR+MS 5816.41 64.09 302.86 4261.28 4181.70 1743.68 -2179.90 5950617.83 642719.70 MWD+IFR+MS 5911.51 63.18 301.67 4303.52 4223.94 1789.17 -2251.95 5950661.92 642646.80 MWD+IFR+MS 6006.65 63.89 302.99 4345.92 4266.34 1834.72 -2323.91 5950706.07 642573.97 MWD+IFR+MS 6101.50 63.32 304.44 4388.09 4308.51 1881.87 -2394.58 5950751.86 642502.41 MWD+IFR+MS 6195.20 62.99 307.72 4430.41 4350.83 1931.09 -2462.14 5950799.77 642433.93 MWD+IFR+MS 6288.70 64.29 309.09 4471.92 4392.34 1983.14 -2527.78 5950850.53 642367.30 MWD+IFR+MS 6383.83 64.48 308.07 4513.05 4433.47 2036.63 -2594.84 5950902.72 642299.23 MWD+IFR+MS 6477.40 64.08 305.90 4553.66 4474.08 2087.34 -2662.17 5950952.12 642230.94 MWD+IFR+MS 6571.69 63.11 305.39 4595.59 4516.01 2136.56 -2730.80 5951000.01 642161.38 MWD+IFR+MS 6666.43 63.60 303.42 4638.08 4558.50 2184.40 -2800.66 5951046.49 642090.62 MWD+IFR+MS 6762.04 64.64 302.06 4679.82 4600.24 2230.92 -2873.01 5951091.60 642017.39 MWD+IFR+MS 6856.81 64.61 301.66 4720.43 4640.85 2276.12 -2945.74 5951135.39 641943.81 MWD+IFR+MS ~~ ~ • Sperry Drilling Services Survey Report ,` Company: BP AmoCO Field: Prudhoe Bay ~~ Sitr. PB Y Pad Well: Y-07 Wellpath: Y-07A Survev MD Incl ft d'eg im deg D ft s TVD ft Date: 2/14/2008 Time: 14:42:55 Page: 3 Co-ordinatc~NN:) Reference: Well: Y-07, True North ~~ Vertical ITVll) Reference: Y-07A: 79.6 ~ Section (VS) Reference: Well (QOON,O.OOE,306.14Azi) Survev Calculation Method: Minimum Curvature Db: Oracle ` __ -- N/S' E/W MapN MapE Tool ft ft ft ft __ 6951.09 - -- 64.28 - - 302.78 4761.10 4681.52 2321.46 _ -3017.70 5951179.34 641871.00 MWD+IFR+MS 7045.34 63.32 306.34 4802.72 4723.14 2369.41 -3087.33 5951225.94 641800.46 MWD+IFR+MS 7140.05 63.73 306.99 4844.95 4765.37 2420.04 -3155.33 5951275.24 641731.50 MWD+IFR+MS 7235.29 64.28 307.00 4886.69 4807.11 2471.55 -3223.70 5951325.42 641662.16 MWD+IFR+MS 7330.05 64.77 307.94 4927.45 4847.87 2523.59 -3291.60 5951376.14 641593.28 MWD+IFR+MS 7424.14 64.37 307.60 4967.85 4888.27 2575.64 -3358.77 5951426.88 641525.12 MWD+IFR+MS 7519.72 63.89 307.88 5009.56 4929.98 2628.28 -3426.78 5951478.20 641456.12 MWD+IFR+MS 7612.78 63.95 306.72 5050.47 4970.89 2678.93 -3493.27 5951527.55 641388.67 MWD+IFR+MS 7706.35 63.89 307.04 5091.60 5012.02 2729.37 -3560.49 5951576.68 641320.49 MWD+IFR+MS 7801.79 63.33 306.54 5134.03 5054.45 2780.57 -3628.96 5951626.55 641251.06 MWD+IFR+MS 7895.59 63.33 306.88 5176.13 5096.55 2830.67 -3696.15 5951675.35 641182.92 MWD+IFR+MS 7989.98 63.88 306.97 5218.09 5138.51 2881.47 -3763.74 5951724.83 641114.37 MWD+IFR+MS 8083.40 64.09 305.49 5259.07 5179.49 2931.08 -3831.46 5951773.13 641045.71 MWD+IFR+MS 8179.14 64.02 305.19 5300.95 5221.37 2980.88 -3901.69 5951821.56 640974.54 MWD+IFR+MS 8273.24 63.83 305.42 5342.31 5262.73 3029.73 -3970.67 5951869.07 640904.64 MWD+IFR+MS 8366.90 64.36 307.38 5383.24 5303.66 3079.72 -4038.47 5951917.75 640835.89 MWD+IFR+MS 8461.50 64.01 306.99 5424.43 5344.85 3131.19 -4106.32 5951967.90 640767.07 MWD+IFR+MS 8556.21 64.06 306.18 5465.90 5386.32 3181.94 -4174.69 5952017.32 640697.74 MWD+IFR+MS 8650.44 63.80 306.18 5507.31 5427.73 3231.91 -4243.01 5952065.96 640628.48 MWD+IFR+MS 8744.07 64.10 305.88 5548.43 5468.85 3281.39 -4311.04 5952114.11 640559.51 MWD+IFR+MS 8838.24 64.65 305.59 5589.15 5509.57 3330.98 -4379.96 5952162.36 640489.66 MWD+IFR+MS 8932.44 63.93 305.36 5630.02 5550.44 3380.23 -4449.08 5952210.27 640419.61 MWD+IFR+MS 9028.15 63.75 305.85 5672.22 5592.64 3430.25 -4518.92 5952258.93 640348.82 MWD+IFR+MS 9122.20 64.08 306.03 5713.57 5633.99 3479.83 -4587.31 5952307.18 640279.49 MWD+IFR+MS 9216.20 64.18 306.90 5754.59 5675.01 3530.09 -4655.33 5952356.12 640210.52 MWD+IFR+MS 9274.70 64.30 306.60 5780.01 5700.43 3561.62 -4697.55 5952386.83 640167.71 MWD+IFR+MS 9398.59 61.45 300.81 5836.53 5756.95 3622.82 -4789.17 5952446.25 640074.93 MWD+IFR+MS 9493.20 59.46 296.80 5883.19 5803.61 3662.49 -4861.26 5952484.52 640002.10 MWD+IFR+MS 9588.24 60.16 295.23 5930.99 5851.41 3698.51 -4935.08 5952519.11 639927.60 MWD+IFR+MS 9682.32 60.50 296.13 5977.56 5897.98 3733.94 -5008.75 5952553.11 639853.27 MWD+IFR+MS 9776.45 60.60 295.35 6023.84 5944.26 3769.54 -5082.58 5952587.28 639778.77 MWD+IFR+MS 9868.78 61.04 295.06 6068.85 5989.27 3803.86 -5155.52 5952620.19 639705.19 MWD+IFR+MS 9962.27 60.45 295.82 6114.54 6034.96 3838.90 -5229.18 5952653.80 639630.88 MWD+IFR+MS 10055.50 60.24 295.43 6160.67 6081.09 3873.94 -5302.23 5952687.43 639557.18 MWD+IFR+MS 10151.64 60.11 296.15 6208.49 6128.91 3910.23 -5377.32 5952722.26 639481.40 MWD+IFR+MS 10246.44 59.98 296.94 6255.82 6176.24 3946.93 -5450.80 5952757.54 639407.24 MWD+IFR+MS 10340.55 59.90 297.63 6302.96 6223.38 3984.27 -5523.19 5952793.47 639334.15 MWD+IFR+MS 10436.02 59.53 298.30 6351.11 6271.53 4022.93 -5596.01 5952830.72 639260.61 MWD+IFR+MS 10529.88 59.60 298.90 6398.66 6319.08 4061.67 -5667.06 5952868.08 639188.83 MWD+IFR+MS 10625.75 59.46 298.72 6447.27 6367.69 4101.49 -5739.46 5952906.50 639115.68 MWD+IFR+MS 10719.30 59.66 297.95 6494.67 6415.09 4139.77 -5810.45 5952943.40 639043.97 MWD+IFR+MS 10811.60 60.17 297.76 6540.94 6461.36 4177.08 -5881.06 5952979.35 638972.66 MWD+IFR+MS 10905.15 59.89 296.19 6587.67 6508.09 4213.84 -5953.28 5953014.71 638899.75 MWD+IFR+MS 11000.88 60.09 294.35 6635.55 6555.97 4249.23 -6028.24 5953048.64 638824.13 MWD+IFR+MS 11095.43 60.51 294.13 6682.40 6602.82 4282.95 -6103.13 5953080.91 638748.61 MWD+IFR+MS 11190.51 59.82 294.80 6729.70 6650.12 4317.10 -6178.20 5953113.61 638672.90 MWD+IFR+MS 11285.71 59.81 295.81 6777.57 6697.99 4352.27 -6252.60 5953147.34 638597.85 MWD+IFR+MS 11381.01 59.82 296.28 6825.48 6745.90 4388.44 -6326.61 5953182.07 638523.16 MWD+IFR+MS 11473.76 60.10 296.27 6871.92 6792.34 4423.99 -6398.60 5953216.22 638450.50 MWD+IFR+MS 11569.03 59.61 296.56 6919.76 6840.18 4460.64 -6472.39 5953251.44 638376.03 MWD+lFR+MS 11662.74 60.09 298.17 6966.83 6887.25 4497.89 -6544.35 5953287.29 638303.37 MWD+IFR+MS 11756.56 60.46 298.02 7013.35 6933.77 4536.25 -6616.22 5953324.27 638230.78 MWD+IFR+MS 11840.49 60.02 296.46 7055.01 6975.43 4569.60 -6681.00 5953356.36 638165.37 MWD+IFR+MS ,`' ` • • Sperry Drilling Services Survey Report Company: BP AmoCO Datc: 2/14/2008 Time: 14:42:55 Page: 4 Field: Pru dhoe Bay Co-ordinate(NE) Re ference: Well: Y-07, Tr ue North Site: PB Y Pad Vertical (TVDj Refe rence: Y -07A: 79.6 Well: Y-07 Section (VS) Referen ce: Well (O.OON,O. OOE,306.14Azi) Wdlpath: Y-07A Survey Calculation b~iethod: M inimum Curv atu re llb: Oracle Survey MD Ind Azim TVD SysTVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft it 11947. 30 - 60. 25 296. 39 7108. 20 - 7028. - 62 4610.83 __ -6763.94 5953395 .98 638081. 65 MWD+IFR+MS 12042. 32 59. 54 296. 13 7155. 86 7076. 28 4647.20 -6837.66 5953430 .92 638007. 26 MWD+IFR+MS 12137. 14 58. 86 296. 54 7204. 41 7124. 83 4683.33 -6910.66 5953465 .63 637933. 59 MWD+IFR+MS 12229. 75 57. 52 297. 83 7253. 22 7173. 64 4719.27 -6980.66 5953500 .22 637862. 91 MWD+IFR+MS 12326. 95 54. 31 300. 92 7307. 70 7228. 12 4758.71 -7050.81 5953538 .30 637792. 02 MWD+IFR+MS 12419. 19 49. 63 303. 11 7364. 51 7284. 93 4797.18 -7112.42 5953575 .57 637729. 69 MWD+IFR+MS 12513. 59 46. 38 305. 57 7427. 67 7348. 09 4836.71 -7170.35 5953613 .98 637671. 00 MWD+IFR+MS 12608. 82 43. 43 308. 81 7495. 12 7415. 54 4877.29 -7223.92 5953653 .52 637616. 67 MWD+IFR+MS 12703. 12 43. 50 310. 30 7563. 57 7483. 99 4918.60 -7273.93 5953693 .85 637565. 88 MWD+IFR+MS 12797. 43 43. 23 310. 20 7632. 13 7552. 55 4960.44 -7323.35 5953734 .73 637515. 66 MWD+IFR+MS 12890. 31 43. 67 310. 35 7699. 56 7619. 98 5001.74 -7372.09 5953775 .08 637466. 15 MWD+IFR+MS 12985. 25 44. 15 309. 53 7767. 96 7688. 38 5044.00 -7422.57 5953816 .36 637414. 86 MWD+IFR+MS 13079. 56 43. 64 308. 68 7835. 92 7756. 34 5085.25 -7473.31 5953856 .62 637363. 34 MWD+IFR+MS 13174. 01 41. 00 310. 39 7905. 75 7826. 17 5125.70 -7522.36 5953896 .12 637313. 53 MWD+IFR+MS 13267. 49 37. 64 308. 85 7978. 06 7898. 48 5163.49 -7567.96 5953933 .02 637267. 21 MWD+IFR+MS 13361. 86 34. 50 307. 37 8054. 33 7974. 75 5197.79 -7611.65 5953966 .47 637222. 87 MWD+IFR+MS 13456. 21 34. 58 308. 74 8132. 05 8052. 47 5230.77 -7653.77 5953998 .63 637180. 12 MWD+IFR+MS 13550. 68 34. 58 309. 78 8209. 83 8130. 25 5264.70 -7695.29 5954031 .75 637137. 97 MWD+IFR+MS 13644. 76 34. 27 311. 49 8287. 44 8207. 86 5299.33 -7735.65 5954065 .59 637096. 95 MWD+IFR+MS 13739. 43 35. 31 313. 26 8365. 18 8285. 60 5335.74 -7775.54 5954101 .23 637056. 37 MWD+IFR+MS 13833. 42 35. 95 311. 15 8441. 58 8362. 00 5372.51 -7816.10 5954137 .21 637015. 11 MWD+IFR+MS 13927. 60 34. 82 308. 72 8518. 37 8438. 79 5407.53 -7857.89 5954171 .41 636972. 65 MWD+IFR+MS 14022. 37 34. 26 305. 99 8596. 44 8516. 86 5440.13 -7900.59 5954203 .18 636929. 34 MWD+IFR+MS 14117. 06 34. 16 309. 20 8674. 75 8595. 17 5472.59 -7942.76 5954234 .83 636886. 55 MWD+IFR+MS 14211. 31 35. 21 309. 13 8752. 25 8672. 67 5506.47 -7984.35 5954267 .89 636844. 33 MWD+IFR+MS 14306. 53 35. 00 310. 29 8830. 15 8750. 57 5541.45 -8026.47 5954302 .05 636801. 54 MWD+IFR+MS 14366. 83 34. 98 311. 68 8879. 55 8799. 97 5564.13 -8052.57 5954324 .22 636775. 01 MWD+IFR+MS 14407. 76 35. 00 311. 44 8913. 08 8833. 50 5579.70 -8070.13 5954339 .45 636757. 15 MWD+IFR+MS 14502. 98 33. 15 310. 36 8991. 95 8912. 37 5614.63 -8110.45 5954373 .60 636716. 18 MWD+IFR+MS 14598. 03 31. 69 311. 67 9072. 19 8992. 61 5648.06 -8148.90 5954406 .28 636677. 09 MWD+IFR+MS 14657. 85 31. 45 314. 55 9123. 16 9043. 58 5669.46 -8171.76 5954427 .23 636653. 83 MWD+IFR+MS 14730. 00 31. 45 314. 55 9184. 71 9105. 13 5695.87 -8198.59 5954453 .12 636626. 50 BLIND TRE~-''= J 4-1/16" CIW tLLHEAD = MCEVOY ACTUATOR = BAKER C KB. ELEV - 86.78' BF. ELEV = 51.46' KOP = 2044' Max Angle = 85° @ 5534' Datum MD = 14367' Datum TV D = 8800' SS 20" INSULATED CONDUCTOR, ID = ? Minimum ID = 3.725" @ 14214' 4-1/2" HES XN NlPPLE I9-5/8" CSG, 47#,L-80 HYDRIL 563 XO TO L-80 BTGM ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" PERFORATION SUMMARY REF LOG: SWS SCMT ON 02/03/08 ANGLE AT TOP PERF: 33° @ 14545' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 7_7/R" F 1dFdF _ 1dFRF_ (1 !1F/1n/nR S NOTES: 1985, E-~ 9-5/8" HES CEMENTER 1993 9-5/8" BKR EXTERNAL CSG PKR ID = 8.881" MILLOUT WINDOW (Y-07A) 2020' - 2044' I 2200 4-112" HES X NIP, ID = 3.813" Y-07A 9-5/8" CSG, 47#, L-80 BTGM, ID = 8.681" ~4-1/2" 7BG, 12.6#, L-80 TCII, .0152bpf, ID = 3.958" T' LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" ~PBBTD 4-1/2" LNR, 12.6#, L-80 IBT-M, .0152bpf, ID = 3.958 9106' N 9-5/8" X 7" BKR HR ZXP w / HD LNR TOP PKR & 11' TIEBACK ASSY, ID = 7.50" 9125' 7" XO PUP, ID = 8.276 9130 9-5/8" X 7" ZXP w / HD LTP & 11' TIEBK ASSY, ID = 7.50 9153 9-5/8" X 7" BKR FLEX-LOCK LNR HGR, ID = 8.30" 14118 ~ 4-1 /2" HES X NIP, ID = 3.813" 14149 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 14183 4-1/2" HES X NIP, ID = 3.813" 14214' ~- 4-112" HES XN NIP, ID = 3.725" 14421' 7" X 5" BKR C2 ZXP LTP w / 11.5' TIEBK, ID = 4.410" 14226 4-1/2" WLEG, ID = 3.958" 14238 7" X 5" BKR FLIX-LOCK LNR HGR, ID = 4.430" 14248' 5" X 4-1/2" XO, ID = 3.958" 14544- 4-1/2" MARKERJOINTI DATE REV BY COMMENTS DATE REV BY COMMENTS 12/05/85 N1 ES ORIGINAL COMPLETION 02/06/08 N2 ES SIDETRACK (Y -07A) 05/10/08 JKD/SV INffIAL PERFORATIONS 08/10/08 JGR/PJC DRLG DRAFT CORRRECTIONS PRUDHOE BAY UNIT WELL: Y-07A PERMfI' No: x2071050 API No: 50-029-20560-01 SEC 34, T11 N, R13E,1341' FNL & 118' FWL BP Exploration (Alaska) • • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 06, 2008 10:16 AM To: 'Schmoyer, AI' Cc: Rose, John G (FAIRWEATHER); Hobbs, Greg S (ANC) Subject: RE: PBU Y-07 (181-018) and Y-07A (207-105) -- Again A!, Sorry we haven't been able to hook up. Thanks for the reply and assessment. I agree with your conclusions. Bottom line, when all available information is/was considered, sufficient isolation was determined to allow completion of the well. Call or message with any questions. Tom Maunder, PE AOGCC From: Schmoyer, AI [mailto:Al.Schmoyer@bp.com] Sent: Wednesday, August 06, 2008 10:05 AM To: Maunder, Thomas E (DOA) Cc: Rose, John G (FAIRWEATHER); Hobbs, Greg S (ANC) Subject: RE: PBU Y-07 (181-018) and Y-07A (207-105) -- Again Tom, We are in agreement that the cement outside the 4.5" liner is not as good as expected given the "best practices" and operations. Our observations as we reviewed the 5-2-2008 SCMT log: . cement bond improved significantly over that shown on the 2-3-2008 SCMT log • there is up-hole isolation with >100' strong cement bond across the Shublik and Sag • there is ~15' (14,598'-14,613') acceptable bond/compressive strength across the HOT/tar-mat In general the cement quality is not ideal, probably better than it looks on the log, good enough so that we really can't do anything about it (sqz cement). The reservoir section is thin and the standoff from the HOT is ~10'. The cement bond should provide near well injection containment across the Tar-mat. The tar mat is going to provide injection cantainment as the flood moves out into the matrix. Hope that helps. Call if you have any further questions, Alk From: Hobbs, Greg S (ANC) Sent: Thursday, Juiy 31, 2008 2:17 PM To: Schmoyer, AI Cc: Rose, John G (FAIRWEATHER); Maunder, Thomas E (DOA) Subject: FW: PBU Y-07 (181-018) and Y-07A (207-105) -- Again AI- Could you provide feedback on Y-07 to Tom? Thanks! Greg 8/6/2008 • • Page 2 of 2 From: Maunder, Thomas E (DOA) (mailto:tom.maunder@alaska.gov] Sent: Thursday, July 31, 2008 11:41 AM To: Hobbs, Greg S (ANC) Subject: RE: PBU Y-07 (181-018) and Y-07A (207-105) -- Again Greg, Would you forward to the production engineer responsible for Y-07A? The SCMT log from 2/3/08 portrays a pessimistic picture of the cement quality outside the 4-1/2" liner. I would have expected better quality cement given the operations summary. It appears that best practices were employed. According to the post-rig work summary, another SCMT was run May 2 and it is noted "Cement in area of interest 14545 - 14585 not good. PE decided not to pert pending further review of log." I would agree that section is not the best quality of the interval logged. On May 10, perforations were shot 14545 -14585. I am curious what the assessment of the "bond" is over the 4/1/2" liner? The presentation from 5/2 in general indicates better quality than the 2/3 log. Thanks in advance. 1 look forward to the reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, July 31, 2008 10:50 AM To: Hobbs, Greg S (ANC); 'Rose, John G (FAIRWEATHER)'; Elmore, Gary O (Schlumberger); 'Hubble, Terrie L' Cc: Engel, Harry R; Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA); Christine Mahnken Subject: PBU Y-07 (181-018) and Y-07A (207-105) All, I am reviewing the completion report for Y-07A. As part of the review for injection wells, I also examine the "bond logs". In the AOGCC file 1 found a USIT dated 12/18/07 and a SCMT dated 2/3/08. The well name on both logs is Y-07A. The name on the 12/18/07 log is incorrect. This log is of the 9-5/8" casing set in the well in 1981, a portion of which was cut and pulled shortly after this log was run. Window milling to begin Y-07A was not commenced until late on 12/25/07. The correct well name for USIT log is Y-07. The convention employed by AOGCC is that the new well or redrill is not "spudded" until new formation is drilled beyond the window. It would be appreciated that those responsible for logging operations such as this would be informed of this. It is not necessary to send renamed copies of the USIT log. I will make the necessary correction. Thanks in advance for you attention to naming matters. Call or message with any questions. Tom Maunder, PE AOGCC 8/6/2008 • WELL LOG TRANSMdTTAL To: State of Alaska June 4, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: Y-07A+PB 1 AK-MW-5355473 Y-07A+PB 1: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-029-20560-01,70 g 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-029-20560-01,70 g Digital Log Images: 1 CD Rom 50-029-20560-01,70 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 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 t; tgl ( `~ ! ;~' Signed: _ ~„/ ~r ~~ 05/13/08 ~~ll~~m~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth well .~nh ~ NO. 4702 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I ~_ MPS-11 12017492 CEMENT & CORROSION LOG ~~~-(~~ f/ 04/22/08 VVIVI 1 VV 1 1-21/K-25 12061694 o PRODUCTION LOG ~~~ +' rr~r~ ~ ,_~~j~ 04/18/08 1 1 GNI-04 12057606 - STEP RATE INJECTIVI'i r I t5 i USG / ~jCF 04/23/08 1 1 L-220 11975763 USIT 04/22/08 1 1 MPS-31 11962598 USIT C _ 05/03/08 1 1 X-17 12034894 USIT - f • /~ 33~. 05/03/08 1 1 04-47 11978458 MEM LDL ~`j~-(--(f 3 05/01/08 1 1 Y-07A 11966254 TEMP & PRESS LOG aV~-- f 05/02/08 1 1 L5-36 11975768 PRODUCTION PROFILE W/FSI -U f 04/28/08 1 1 Z-112 40016350 OH MWD/LWD EDIT ~}- 02/15/08 2 1 Z-112 PB 40016350 OH MWD/LWD EDIT '~- ~ 02/11/08 2 1 Y-07A 11962781 CH EDIT PDC GR fSCMT) 'M~ /(~~ ~(o ~~-( 02/03/08 1 L2-16 11975760 RST ~, L~~=~_--~~-')~ ~1 ~~ ~ ~ 03/31/08 1 1 L2-33 11998999 , ~ RST I - 04/01/08 1 1 L1-14 11999000 RST ~ ,-~ 04/02/08 1 1 D-266 40016518 OH MWD/LWD EDIT - rv' 02/21/08 1 1 PI FASF Art KN(111VI Cr1RC oo rno7 ev cIr_~ u~Ir_ n~In nrrl L,.ILL. ....~ ........ ~.,,.. .~.. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. _n Anchorage, Alaska 99508 Date Delivered ~, y,,, ~~a`~j +~ _ ~ t i,_B i' Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 ;" Anchorage, AK 99503-2838 ; ATTN: Beth ~ Received by: / I~ 05/13/08 ~~i~l~m~~s~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII .Inh it NO. 4702 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 1(10 Anchorage, AK 99501 1 .... n.. MPS-11 12017492 ~" - CEMENT & CORROSION LOG 7fj~-(/'~ // 04/22/08 IiVIVf 1 VV 1 1-21/K-25 12061694 0 PRODUCTION LOG `~O _a~ ~ ,,~~~ 04/18/08 1 1 GNI-04 12057606 STEP RATE INJECTIVI'1 r I tS t USG / ~jcf 04/23/08 1 1 L-220 11975763 USIT - 04/22/08 1 1 MPS-31 11962598 USIT C 05/03/08 1 1 X-17 12034894 USIT - / • /(o ~ ~ 05/03/08 1 1 04-47 11978458 MEM LDL ~`jL(-6 ~ 05/01/08 1 1 Y-07A 11966254 TEMP & PRESS LOG aU~-- / 05/02/08 1 1 L5-36 11975768 PRODUCTION PROFILE W/FSI •-p /' 04/28/08 1 1 Z-112 40016350 OH MWD/LWD EDIT "~- 02/15/08 2 1 Z-112 PB 40016350 OH MWD/LWD EDIT p"~ - ~~ 02/11/08 2 1 Y-07A 11962781 CH EDIT PDC GR fSCMTt ~~ /vim ~Coc3OCf 02/03/08 1 L2-16 11975760 RST -~ ~'~T~~-~"~ ~~ ~~.~~ 03/31/08 1 1 L2-33 11998999 RST 1 - 04/01/08 1 1 Li-14 11999000 RST ~ ~ 04/02/08 1 1 D-266 40016518 OH MWD/LWD EDIT `~j' 02/21/08 1 1 PI FASF nCKnlntnn Gnr_c oc rnuT cv ~~n. ur.~n e.~n ~~r~ ~.,.~~.~.+ ....~ ..,...., ~..... -_ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 -- Date Delivered: --- ~"I f ~ ,' I i._ o t Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 ;" Anchorage, AK 99503-2838 j ATTN: Beth ~ ~, Received by: ~~ 05/20/08 d~i~i~mb~s~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII .Inh ~F NO. 4712 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ .... n., MPB-04A 12021150 MEM PROD PROFILE ~y 04/17/08 1~ 1 MPG-13 12021151 MEM INJECTION PROFILE G 04/18/08 1 1 Z-26A 11978454 MEM GLS ap(p-p 04/23/08 1 1 Z-29 11978453 MEM GLS - 04/22/08 1 1 Y-36 12005204 MEM GLS L/ 02/12/08 1 1 4-14A/S-37 12031471 _ PRODUCTION PROFILE W/FSI 04/12/08 1 1 Y-07A 11966254 SCMT / 05/02/08 1 1 02-01 B 11966257 LDL ~ (p 05/10/08 1 1 X-16A 11975771 USIT L- L 05/14/08 1 1 07-26 12061688 USIT - 05/16/08 1 1 05-34 11966251 USIT - 04/13/08 1 1 OS-23A 118966257 USIT / 05/13/08 1 1 S-33 11962596 USIT 04/15/08 1 1 V-223 12061688 CH EDIT PDC GR (USIT ~j - ` 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT 'fib _ 03/03/08 2 1 4-14A/S-37 40016545 OH MWD/LWD EDIT p'~.-U l ( 02/18/08 2 1 05-226 11628800 MCNL 10/22/07 1 1 05-136 12021140 MCNL ~ 01/31!08 1 1 Z-10 12066520 RST (~L 04/10/08 1 1 D-10 11975766 RST 04/25/08 1 1 . __ -„~ ..,,....,. .. ~~.,.~,~ ..~„~.. . ., . vwnn..a r+iw nc ~ vnwnv~a vrvc ~.vr r cN~.n i v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~-===r 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ;,n li' ~. `"fll l~ ,, ; Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~\ WELL LOG TRANSMITTAL To: State of Alaska May 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: Y-07A PB1 AK-MW-5355473 1 LDWG formatted CD rom with verification listing. API#: 50-029-20560-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~~=~ ~~ ,,; ~ Date: `~ - ~ - Signed: ~e~--dos ~ 1~,~ ~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska May 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: Y-07A AK-MW-5355473 1 LDWG formatted CD rom with verification listing. API#: 50-029-20560-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~~ - - ;~- ,; Date: ~~; - ~ - ~ Signed: ~o`~-e~6a9 ~ Date 04-30-2008 Transmittal Number:92964 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 slivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: i-13B ~~ - ~~{rc ~1 ~c7~ -O1A) aU~--(O~ (~ a l ~'~"/~ Please Sig an nd 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 ":~ ~ ~ Date 04-11-2008 - Transmittal Number:92955 ~ ; +~> #~ BF~A WELL DATA TRANSMITTAL Enclosed are the tti~itci~ials listed' below. (SPXA FIELD LOG DATA) ~t you nave any questions, please contact llouglas llortch at the YllC; at 564-4y /3 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 05-136 ~U~-- l~l4~ '~ ~~a13 C-35B c~OCo -(~Ll ~! (0 2 ~ 5 - l - APB1 ~'~-~~ ~~(oal (o 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 99519-6612 o2/2s/os Schlambergr NO. 4612 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Aurora,GNI,Pt.Mac,Milne Pt,Endicott Well Joh # Inn rlacrrinfinn rhfn QI r~..i... rn 15-25A 12014000 LDL / ..(~Co 'm 02/20/08 1 1 A-12A 11963077 MCNL sf 3 01/19/08 1 1 GNI-04 12031448 TEMP SURVEY (REVISED) a(j~- ~ (0 01/22/08 1 1 P2-32 11968730 USIT '- ~ 02/13/08 1 1 17-02 11996384 USIT /~Q - ~' 02117/08 1 1 Y-07A 11962781 SCMT '}-1 ~ ~ 02/03/08 1 1 P2-58 12031456 USIT /9O - ~/ 02/25/08 1 1 MPH-12 12005205 MEM INJ PROFILE ~ _ j~-p It '~ 02/15/08 1 1 4-14/R-34 11975755 USIT Vet? ~ 02/25/08 1 1 S-126 11968731 JEWELRY/PERF/SBHP ~. M' ~ 02/15/08 1 1 rLG/iJG MNNYVVYLCVVG RG~.GIr'1 6T JIb NInIV NIVV KtIUKIVI1Vl7 VIVO I.VYY tAl;fi IIJ: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ Ki Anchorage, Alaska 99508 Date Delivered: ~ ~j ,~~ ` ,' fl(1fY ~~~..~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: .~ oz/zo/os • ~~~~~~~~~~~ NO. 4590 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 4Q0 Alaska Oil & 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,Endicott,Borealis,Polaris,Lisburne WPII .Inh $ Inn r)ocr•ri n4inn r1~4n RI r'nlnr ! fl 18-32A 11968923 SCMT [ - ~ 02!12/08 1 MPE-12 11978438 MEM INJ PROFILE UIC~--a(~~ - t~(o 02108108 1 4-14/R-34 11996383 USIT ~ 02112/08 1 V-07 40016096 OH MWDILWD EDIT '~ - G [ L!c 12/04/07 2 1 L1-14 11626482 RST ~ ~-- [ / S"9Y3 05/09/07 1 1 L2-18A 11657124 RST ~ 05/10/07 1 1 L2-33 11626484 RST ( (p - ( 'nj G [ 05111107 1 1 G-31A 11962778 RST - vS ~( ~~ 01/01/08 1 1 V-111 11978439 MEM GLS 02/10/08 1 W-216 12031441 __ CH EDIT PDC GR (USIT) 9 01/11/08 1 W-214 40016055 OH MWD/LWD EDIT U=, _ ( 11115107 2 1 Y-07A 11962576 USIT `~ 12118/07 1 C-356 11978432 _ MEM DDL - / 01102108 1 rcar+~c Al.nrvVVVLCUbt KtlalYl t3T 51hNI1Vli AIVU KtI,VKIVIry(aµU~~..I;UYY tAGrt IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 I ~ ~'(~(yt Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: !~ ~ 1 , j t ~,, , * ~ , ' i 1 ) ,r ~ ; ALASSA OIL A1~TD GAS COI~TSER~ATIOl~T COMl-IISSIOIQ Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-07A BP Exploration Alaska Inc. Permit No: 207-105 (revised) Surface Location: 1341' FNL, 118' FWL, SEC. 34, T11N, R13E, UM Bottomhole Location: 4331' FSL, 2786' FEL, SEC. 29, T11N, R13E, UM Dear Mr. Hobbs: Enclosed is the revised approved application for permit to drill the above referenced service well. This revision was necessary due to moving the bottomhole location. All requirements contained in the Commission's letter of August 8, 2007 apply. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cath P. Foerster Commissioner DATED this ~' day of January, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~; ALAS~IL AND GAS CONSERVATION COMM N PERMIT TO DRILL ~1~-~ 20 AAC 25.005 R~~~~ Revised: / /0 hange BHL 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify~llB~i ~ ~@ ~~~ ®ft109i I ^Coalbed Methane ~~Irates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU Y-07A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14683 TVD 9138 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1341' FNL 118' FWL T11N SEC 34 R13E UM 7. Property Designation: ADL 028288 Pool , , . , , , Top of Productive Horizon: 4275' FSL, 2719' FEL, SEC. 29, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: In Progress Total Depth: 4331' FSL, 2786' FEL, SEC. 29, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 20,187' 4b. Location of Well (State Base Plane Coordinates): Surface: x-644933 y-5948917 Zone-ASP4 10. KB Elevation Plan (Height above GL): 78.46 feet 15. Distance to Nearest Well Within Pool: 1,550' 16. Deviated Wells: Kickoff Depth: 2105 feet Maximum Hole An le: 64 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3900 Surface: 3018 18. Casin Pro ram: ecfi bo ns To - Se in De th - Bo om uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 5239' 9155' 5727' 14394' 8901' 741 cu ft LiteCrete 191 cu ft Class'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 389' 14294' 8820' 14683' 9138' 82 cu ft Class'G' 19. PRESE NT WELL CONDITION SUMMARY tTo be completed for Redrill and Reentry Operations) Total Depth MD (ft): 11275 to~/z,/os~ Total Depth TVD (ft): 6772 Plugs (measured): None Effective Depth MD (ft): 11275 Effective Depth TVD (ft): 6772 Junk (measured): None Casing : Length ize Cement Volume MD TV Conductor /Structural 110' 20" x 30" 8 cu ds Concrete 110' 110' Surface 2685' 13-3/8" 3720 cu ft Permafrost II 2020' TOW 2685' Intermediate Pro uction 9305' 9-5/8" 32 8 cu ft LiteCrete 775 cu ft'G' 930 ' 5793' Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 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 Rep esentative: Date: 22. I hereby certify that the foreg i ue and correct. Contact John Rose, 564-5271 Printed Name Greg Hobb Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date / Z.~ d Terrie Hubble, 564-4628 Commission Use On Permit To Drill Number: 207-105 API Number: 50-029-20560-01-00 Permit Ap I See cover letter for Date: ~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed metJhane, gas hydrates, or gas contained shales: ~~~~ ClCt~nfLn~ ~~1G~~-4'~~ OS~ Samples Req'd: ^ es t]~ No Mud Log Req'd: ,^,/Yes ~No y ~ HZS Measures: I~es ^ No Directional Survey Req'd: L10 Yes ^ No `~ ~ O P~ 1 ~~ ~ ~S~' W Other: V l~1 v~C~.~ C O ~~ C'G"~cO hS ~ v~ G~ CfJ ~ ~ ps~~ ~r Q APPROVED BY THE COMMISSION Date Q ,COMMISSIONER Form 10-401 Revised 12/2005 O ~' ~i A' /~ ~~ ~ ~ ~ Submit In Duplicate. t • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: John Rose, ODE ' ~ -" Date: January 22, 2008 Re: Y-07ai Sidetrack Permit to Drill The Y-07Ai rotary sidetrack is currently being drilled by Nabors 2ES as approved by the Permit to Drill #207-105. As down-hole problems developed in the 8-1/2" hole at 12,745' MD, the well has now been sidetracked on a new directional plan which includes a new BHL which is greater than the 500' limit as allowed under AOGCC regulations. Therefore, the attached data details a new drilling plan and is submitted as required for a new drilling permit. The following outline details the work done to date on this well under the current PTD (#207-105): 1. Accepted on well at 23:00 hours on 12/15/07. 2. De-completed the well under the authorization of Sundry Number 306-001. 3. Began work under the Permit to Drill #207-105 on 12/24/07 at 03:30 hours. 4. Set whipstock and milled window a 12-1/4" window in the 13-3/8" casing from 2020' - 2043' MD. 5. Drilled 12-1/4" hole to 9305' MD (top Colville) and ran and fully cement back to surface a string of 47# 9-5/8" casing. 6. Drilled 8-1/2" hole to 12,745' MD. 7. Lost "fish" while working lost circulation problem. 8. Plugged well back into the 9-5/8" casing shoe at 9305' MD. 9. Drilled out of 9-5/8" casing with an 8-1/2" BHA and sidetracked well at 9327' MD on directional plan wp21A which includes the BHL change which dictates the need for a new Permit to Drill. The path-forward drilling plans for this sidetrack include the following: 1. Drill the current 8-1/2" hole to the new top Sag target at 14,394' MD and run and fully cement a 26# 7" drilling liner to TD to include a 150' liner lap into the 9-5/8" casing shoe. 2. Drill a 6-1/8" production hole interval to the planned final well TD at 14,683' and run and fully cement a 12.6# 4-1/2" production liner to TD to include 100' liner lap into the 7" drilling liner. 3. Confirm cement quality /isolation by running SCMT logs. 4. Perforate well. 5. Run a 12.6# carbon 4-1/2" completion string. In our "system", the original 8-1/2" hole which was drilled and plugged will be call PB#1 and our new sidetracked 8-1/2" hole/well will keep the Y-07Ai name. Please note the follow drilling and completion summary as provided below and do not hesitate to call if additional information is required. Y-07ai Sidetrack "Revised" Page 1 Well Name: Y-O7ai Drill and Complete Plan Summary (01/21/08 Revision) T e of Well service / roducer / in'ector : Ivishak Injector Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface Location 644,933 5,948,917 0 11 N 13E 34 3940 5162 TSAD 636,698 5,954,381 8935 11 N 13E 29 4276 2719 BHL 636,630 5,954,435 9060 11 N 13E 29 4331 2786 AFE Number: PBD 4P2572 API Number: 50-029-20560-01 Estimated Start Date: 12/15/07 O eratin da s: 50 Ri Nabors 2ES TMD 14,683' TVD rkb: 9138' RKB/GL 28.5'/49.96' RTE 78.46' Well Design: USH Zone 4 Injector 4-~/z", L-80 Com letion Current Status: Rotary Sidetrack General Well Information: Estimated BHP: 3177 psi at 8935' TVDss Estimated BHT: 231 deg F at 8800' TVDss Y-07ai Sidetrack "Revised" Page 2 Formation Markers: Est. Formation To s Uncertain Commercial Hydrocarbon Beartn Est. Pore Press. Est. Pore Press. FOYmatiOn (TVDss) (feet) (Yes/No) (Psi) (ppg EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are required from surface to TD for all new wells KOP @ 2150 MD -2070 SSTVD NA NA SV4 -2309 +/- 10' SV3 -2892 +/- 10' SV2 -3116 +/- TO' SVl -3462 +/- 20' UG4 -3977 +/- 50' UG3 -4196 +/- 50' UGl -4769 +/- 50' WS2 -5224 +/- 50' WSl -5470 +/- 50' CM3 -5676 +/- 50' CM2 -6137 +/- 50' CMl -6823 +/- 50' THRZ -7139 +/- 50' LCU / BHRZ / TKNG -7385 +/- 50' TJF -7898 +/- 50' TJE -8030 +/- 50' TJD -8326 +/- 50' TJC -8515 +/- 50' TJB -8654 +/- 25' TSGR -8823 +/-25' Yes 3128 6.3 TSHU -8849 +/-25' 31a0 6.: TSAD -8935 +/-25' Yes 3177 6.8 POWC -8955 +/- 20' Yes 3186 6.8 To HOT -8975 +/- 20'. 3195 6.8 Well TD Criteria (ie ??ft TVD, ??ft Rathole, etc.) Drill to planned T.D. of 14,227'. Must have sufficient rathole to perforate entire Ivishak section above HO/T top. Comments Ugnu is not hydrocarbon bearing in this area. Casing/Tubing Program: (NOTE: 9-5/8" casing currently cemented to surface f/9305' MD.) Hole Size Csg/ Tbg O.D. WUFt Grade Connection Length (ft) Top MD/TVD RTE ft Btm MD/TVD RTE ft 12-Ya" 9-5/8" 47 L-80 HYDRIL 563 2490 GL 2490/2479 12-'/a" 9-5/8" 47 L-80 BTC-M 6815 2490/2479 9305/5793 8-1 /2" 7" 26 L-80 BTC-M 5239 9155/5727 14,394/8901 6-%" 4-'/z" 12.6 L-80 IBT-M 389 14,294/8820 14,683/9138 Tubin 4-Ih" 12.6 L-80 TC-II 14,300 GL 14,300/8825 Y-07ai Sidetrack "Revised" Page 3 Directional• Directional Plan: Sperry wp21A (Ref Elev: 78.46' MD) KOP: 2105' MD, begin 4/100 build Close Approach Wells: All Wells pass Major Risk Scan, reference wp21 anti-collision report Survey Program: MWD+IFR=MS (2150'), MWD +IFR + MS (14,683') Maximum Hole Angle: 64 degrees f/3712'-9310' MD Distance to Nearest Property Line: 20,187' Distance to Nearest Well in Pool: None within'/4 mile - H-37 is at 2457' at TSAD / Y-23B is 1550' at TSAD / U-09A is 1833' at TSAD Mud Program: 12-'/a" Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH Funn Vis FL Millin Fluid 9.3 16-30 30 9 - 10 50-150 < 8.0 KOP-CM3 9.3-9.6 15-25 22-30 9 - 10 <8.0 8-1/2" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 9305'-12,165' CM3-THRZ 9.0-9.3 8-16 18-24 9 -10 4 - 7 < 15 THRZ-TSAG 10.7 12-20 18-24 9 - 10 HTHP < 10 < 15 6-'/e" Production Hole Mud Pro erties FloPro-SF Interval Densit PV YP PH API Filtrate MBT to Final Well TD 8.4-8.6 8-12 22-28 9 - 9.5 6 - 8 cc's <3 Survey and Logging Program: 12-'/a" Hole Section: Surface Gyro until MW D surveys are clean. MWD/LWD: Dir/GR/PWD O en Hole: None Cased hole: USIT (possible run in conjunction w/7" USIT work) 8-1/2" Hole Section: Sample as required by well site Geolo ist MWD /LWD: DIR/GR/PWD O en Hole: None Cased Hole: USIT 6-'/e" Hole Section: Sample as required by well site Geologist MWD /LWD: DIR/GR/RES O en Hole: None Cased Hole: None NOTE: The Primary Depth Control Log (PDCL) for Y-07A is the Schlumberger Y-07 Jewelry Log GR dated 01/12/06. All MWD logs are to be tied-in and depth shifted to this PDCL. Sufficient gamma ray character for definitive tie-in above the window is to be recorded and printed on field and final logs. Y-07ai Sidetrack "Revised" Page 4 • Cement Calculations: (NOTE: The cement numbers are "ACTUAL" for the 9-5/8" casing which is currently run and cemented on this well at 9305' MD.) Casing Size Intermediate Casing - 9 5/", 47 Ib/ft, L-80, BTC & Hydril 563 - (2 Stage Cement Job) (12-1/4" Hole 1St Stage Lead: None. Tail: Open hole volume + 40% excess from the 9-5/8" casing shoe to the ES cementer at 2100' MD (50' Inside 13-3/8"Window w/ECP ~ust below ES Cementer , + 80' shoe track. Fluid Sequence and Volume: ES Cementer at 2100' MD for 2" Stage Cement Job Wash None S acer 50 bbls of MudPush II wei hted to 10.5 ACTUAL PUMPED Lead None Tail 575 bbls (1167 sks) 11.50 Ib/gal LiteCRETE - 2.77 cuft/sk (ACTUAL PUMPED Tem BHST = 80° F, BHCT ~80° F 2" Stage Lead: None. Tail: Cased hole volume (72# 13-3/8") f/ES Cementer (21000' MD) to surface plus 20 bbls excess cement. TOC at Surface. Fluid Sequence and Volume: ES Cementer at 2100' MD for 2" Stage Cement Job Wash None S acer 29 bbls of MudPush II wei hted to 11.5 ACTUAL PUMPED Lead None Tail 138 bbls 665 sks 15.8 G cement -1.16 cuft/sx ACTUAL PUMPED Tem BHST = 50° F, BHCT ~80° F Casin Size Intermediate Casin - 7", 26 Ib/ft, L-80, BTC-M -Sin le Sta a 8-1/2" Hole Basis Lead: Open hole volume f/13,394 MD to 9305' MD + 40% excess plus 150' liner lap into 9-5/8" casing. Estimated TOC 9155' MD. Tail: Open hole volume f/14,394' MD to 13,394' MD + 40% excess + 80' shoe track. TOC 1000' above 7" shoe. Fluid Sequence and None Volume: Wash None 3 acer 30 bbl of MudPush II S acer wei hted to 11.3-Ib/ al Lead 132 bbl 288 sks 11.7.0 LiteCRETE - 2.57 cuft/sk Tail 34 bbl (166 sks) 15.8 pp4 Class G cement + Latex - 1.16 cuft/sk Temq I BHST = 180° F. BHCT = 100° F Casin Size Production Liner - 4-'h", 12.6 Ib/ft, L-80, IBT-M -Sin le Sta a 6-1/8" Hole Basis Lead: Open hole volume + 30% excess + 150' of liner lap + 80' shoe track + 200' of 7" x 4" DP annulus volume. TOC at liner top (13,839' MD) I Fluid Sequence and Wash None I Volume: 3 acer 20 bbls of Mud ush II Wei hted to 13.0 Tail bbls sks 15.8 Ib/ al Class G Cement + Latex - 1.17 cuft/sk '~ re Kati "Wl ~ Temp BHST = 231 ° F fr m SOR, BHCT 160° F (est.) Y-07ai Sidetrack "Revised" Page 5 Surface and Anti-Collision Issues: With the Y-31 & Y-24 wells being 33.9' & 35.7' respectively, no surface shut-in's will be required to move onto this well. Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require sub-surface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. Well Control The surface, intermediate and production hole sections will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This BOP equipment is capable of handling maximum potential surface pressures which in this case exceed 3000 psi. NOTES: 1. ROPE and drilling fluid system schematics are on file with the AOGCC. 2. When pipe rams are changed, full ram tests are required. 1St Intermediate Section Kfck Tolerance and Intearitv Testina • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 2509 psi - CM3 (8.5 ppg EMW C~3 5676' TVDss) • Maximum surface pressure: 1941 psi -Based on a full column of gas C~ 0.10 psi/ft • Planned BOP test pressure: 4000 psi/250 psi Rams and 2500 psi/250 psi Annular • 9-5/8" Casing Test: 3500 psi surface pressure test • Integrity Test -12-1/4" hole: FIT 20' - 50' from 9 5/8' shoe • Kick Tolerance: 25.1 bbl KT with a 9.3 ppg mud and a minimum 12.0 ppg FIT • (NOTE: Actual FIT of 12.6 ppg when drilled out of the 13-3/8" window.) 2"d Intermediate Section Kick Tolerance and Intearitv Testina • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 3900 psi -Top Sag River (8.5 ppg EMW C~ 8823' TVDss) • Maximum surface pressure: 3018 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 4000 psi/250 psi Rams and 2500 psi/250 psi Annular • 7" Casing Test: 4000 psi surface pressure test • Integrity Test - 8-1/2" hole: FIT 20' - 50' from 9 5/" shoe • Kick Tolerance: 85.1 bbl KT with a 11.0 ppg mud and a minimum 11.5 ppg FIT • (NOTE: Actual FIT to 12.5 ppg when drilled out of the 9-5/8" casing.) Production Section Kick Tolerance and Intearitv Testina • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 3177 psi - Ivishak 42P (6.8 ppg C 8835' TVDss) • Maximum surface pressure: 2293 psi -Based on a full column of gas C~ 0.10 psi/ft • Planned BOP test pressure: 4000 psi/250 psi Rams and 2500 psi/250 psi Annular • 4'/2" Liner Test: 4000 psi surface pressure test • Integrity Test - 6-'/e" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with a minimum 8.9 ppg FIT (NOTE: A 10.5 ppg FIT is required to provide sufficient integrity for ECD management issues.) • Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Y-07ai Sidetrack "Revised" Page 6 Y-07Ai Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: Normal pore pressures (8.5 ppg) are expected throughout both intermediate hole sections from the window in the 13-3/8" window at 2150' MD to the 7" casing point into the top of the Sag at 13,955' MD. The Ivishak is expected to be pressured at 6.8 ppg EMW. (NOTE: There is the possibility of encountering Cretaceous injection pressures in the 9.0 ppg range as high as the top of the SV1 at 3908' TMD but more probable when drilling the various sands of the Ugnu and West Sak formations as we drill to the 12-1/4" TD into the top of the Colville formation. As our plan is to drill this interval with a minimum 9.3 ppg mud, no effects of this cretaceous injection activity should be problematic.) II. Hydrates and Shallow gas: No gas hydrates or shallow gas is anticipated, however, follow good drilling practices in the regards at all times. III. Lost Circulation /Breathing: Lost circulation while drilling the 12-1/4" surface hole and during the 9-5/8" cement job is of concern. Well breathing problems are a possibility in the intermediate hole after weighting-up the mud to 11.0 ppg for the HRZ. And while this well has be directionally designed to avoid lost circulation in the reservoir section, the possibility for lost circulation is still a possibility. Follow the RP guidelines for dealing with Lost Circulation related issues as/if it occurs. IV. Kick Tolerance /Integrity Testing: Surface Section Kick Tolerance and Integrity Testing • Integrity Test -12-1/4" hole: FIT 20' - 50' from 9 S/e" shoe Kick Tolerance: 25.1 bbl KT with a 9.3 ppg mud and a minimum 12.0 ppg FIT. However, a full LOT for this casing test will be performed to provide valuable data to assist the planning for the 9-5/8" casing cement job. Intermediate Section Kick Tolerance and Integrity Testing • Integrity Test - 8-1/2" hole: FIT 20' - 50' from 9 5/8" shoe • Kick Tolerance: 85.1 bbl KT with a 11.0 ppg mud and a minimum 11.5 ppg FIT. However, a 12.5 ppg FIT will be targeted to support the ECD management objectives of this interval of the well. Production Section Kick Tolerance and Integrity Testing • Integrity Test - 6-%" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with a minimum 8.9 ppg FIT. However, a 10.5 ppg FIT will be targeted to support the ECD management objectives of this interval of the well. V. Stuck Pipe There will be slight differential sticking tendencies across upper sands in the 12-1/4" hole while drilling and running the 9- 5/8" surface casing. Follow good drilling practices and keep all pipe moving to minimize the potential for sticking. Also, all efforts to insure effective hole cleaning is being achieved should be of priority while drilling the large diameter top-hole section of this well. With the upper sands behind casing when drilling with the 11.0 ppg mud in the intermediate hole, differential sticking will be minimized, however, still of concern. Differential sticking will also be of concern while drilling the "depleted" reservoir section of the well. VI. Hydrogen Sulfide Y-Pad is not designated as an HzS site, however Standard Operating Procedures for HzS precautions should be followed at all times as H2S levels greater than 100 ppm have been recorded on Y-30 (02/28/2004). VII. Faults Based upon the directional design of this well, there are two fault intersects. The first fault intersect is in the JF-JD of the Kingak formation at -14,207' MD. While this fault intersect is not expected to be troublesome, wellbore stability issues should be of concern while drilling this fault. CONSULT THE Y-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Y-07ai Sidetrack "Revised" Page 7 Y-07Ai Operations Summary (NOTE: As the drilling of this well is currently in progress, all work down through Step #26 under "Rig Operations" have been completed.) Pre-Rig Work: - . ~ T~n~_!,C ana' - SZ 714' nr i i OQ' /_ e r e ~ ~_i~4~+i ihinn.- S2 70~~2'~,(2 G:n7' nr i i ~ 4_1~7~+~i°ih°iT'n~`n~- 52~7~8 ~nn~ nr in `°°T^`3~' e r Cvnnnn Binh ~mn /Cni ~nn~n\ _.~ RRI ~ Tn+~,I nnrr~nn+ vnli imn of ~4 RRI C v. ~~~ dp-: ~IEk~~~f+ A_i /4" +~ Shinn Ton 4. r nrr 7. ~~~6at the 4-1,/~" +~ Shinn .,+ _ ~ann~ nnn AA A RRI C\ i' /_ irRRQ~oC~ 7' /_ 1 G.` RRI C\ C l Tn(' . i~mlee~ nA IA 4 TRr_' +n ~~_4/u" '°r v r~ nonL_nff +n ~ +hn a_~/Q" nonL_nff +n ~ inn n ~ CYF1 c c:r - ~'°° P "°°-P ' nnnr+nrl /nnnlC\ . Ria Operations: G• Cn+ O_~/4" n+nr m nrnLnr hnln~.~ +hn ~~, nllhnor! 7 nll I ~anllhn., r+ + ~. g. D~ III O_~/Q" n+nr n nn+ "hrno Lc" ~ ~irn m nonLnr n rl n ~ DI i n I Cc r ~ ~ viv z~~} t " Q - /4' ~ et `~ ~~n' .+nr! +nn+ +n ~~nn nni/Qn mini +nn D B Q ~~ ~_o__ r - ccitrr .iI ~i ~--F. With i=-i~ne, r l ve - u-~ .~v - ^ I ICIT Inn +n rln+nrmi u - r -o c~. ~ nn Tn!'` nn ~_~/lZ~~ nnninn r n rnn~ ~Itn ~nA nn » r R~+Lnr rnnrnnnn4~+i~in inn+r~ in+innn Dnnu oni-I I /n onnnm hhi . +hn n. ~+ "+ O 1 e QG~ . n nnninn n+~ ~h _ 9 1 Q~° rf r n • ee n n n Y-07ai Sidetrack "Revised" Page 8 ,,. . ~;,:,,. D~u~-~pn ~/nn~;,~$~;;T;~ed ~~ ea~ef mag~aetis-ir~terferense. • ~ , OepaeptEy. 4 C(`D\ /nlnrc; TH€ ° ~/4" !'`eClAlr` \A/I~ RC C~ nnl CI IDC DDn\/InCn RV \/CT(`n ~~' ~v" ~1TQCTT-v1T[PTfOt v v 1 v C 1 v G~ nnln eC.~\/T~Cn Rv renncDnnl Tn uenln TuC r~clnl~ Inl Tuc r~IIDDCnIT vCTrn rnclnln SP~IO~. ~E-~-SO--W-IL~ i4L~8 DDn-,~-~v `/~~TH~D R I n.~" °~D ~R ^ ~I~-O,cTASSE-MI~L~( F^ D~~ 9nclnlr~ eTDlnl/-. ~~~~/€V€R, Tkl€~A~-~~61=1€A-~€Q~Nf€P~T cDnnn TuC Tn~ n~c r~u~~~~~ (` CDnnl I ID \A/1~ RCvc~nvi\:vE~~€LrT n~~~Pnnl 1A/ulr`u \n/I~~~n~l I~€TH€ TQBIPI~ c~t=vvL Anl n erv~ °.,D-rE~~-FL~I-V~ €~- . . 9A nAl I th., SZ_i /O" rl rillinn nc.onmhl~i ~.~i+h nID//~D/D\n/n onr! D14J +n +hn hnrlinn nnlhr O L:• Drnon~ ire +nc~+ ~~~nllhnrn +n iIAAA nc~i fnr 4!1 mini ~+no rnn~ ~irnrf fnr C!'`n m~norrmm~n+\ n s , ~I~~} NOTE: The original 8-1/2" hole was drilled to 12,745' MD (in Step #27 as indicated above) prior to running into Kingak fault related lost circulation problems where the drillpipe became stuck and the well was plugged back into the 9-5/8" casing with cement in preparation for a sidetrack out of the existing casing shoe at 9305' MD. The path-forward operational plans are as indicated below. 1. Sidetrack new 8-1/2" hole from below the current 9-5/8" casing at 9305'. (NOTE: The actual KOP for our current 8-1/2" hole was at 9327' MD.) 2. Continue drilling 8-1/2" per wp21A to a planned TD in the top of the Sag at 14,394' MD. 3. Run a 7", 26#, L-80, BTC-M drilling liner to provide a 150' lap into the 9-5/8" casing and fully cement the liner back to the lap. Set hanger /liner top packer and displace cement with mud. POOH laying down the un-needed portion of the 5" DP (5" drill-pipe will be run inside the 9-5/8" casing to the top of the 7" liner). 4. MU 6-1/8" drilling BHA and RIH picking up enough 4" DP to TD the well at 14,683' MD. 5. Clean-out the 7" liner to the top of the landing collar and pressure test wellbore to 4000 psi for 30 minutes. 6. Drill out shoe track. Swap over to 8.4ppg FloPro mud. 7. Drill at least 20' (not more than 50') of formation and perform FIT to 10.5 ppg (8.9 ppg f/KT -10.5 ppg f/ECD management). 8. Drill the 6-1/8" interval as per directional plan to the final well TD of 14,226' MD. 9. Condition well bore for the 4-1/2", 12.6#, L-80 IBT-M solid, cement liner. POOH racking back DP. LD drilling assembly. 10. Run and cement a 4-'/2" solid production liner extending the liner lap 100' into the 7" drilling liner. Set liner top packer and displace well to clean seawater above the liner top. POOH. (Note: A perf pill will be left in the 4-1/2"liner.) 11. After cement reaches 1000 psi compressive strength, pressure test well to 4000 psi for 30 minutes and chart. 12. RU E-line and run USIT log (SCMT log) the 4-1/2" and 7" liners to confirm cement bond/injection zone isolation. Also, consider running a USIT log back to surface if the cement quality on the 9-5/8" casing is of interest. 13. RIH with DPC or E-line perf guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and perf guns. 14. Run the 4-1/2", 12.6#, L-80 TC-II completion tying into the 4-1/2" liner top. 15. Reverse in "inhibited" seawater and diesel freeze protection into the annulus (freeze protect to 2000' TVD w/diesel and spot inhibited brine below the diesel to the top of the production packer). Y-07ai Sidetrack "Revised" Page 9 i 16. With the annulus shut-in, bull-head the tubing side with diesel freeze protect to 2000' TVD. (NOTE: With reservoir pressure at 6.8 ppg, the diesel freeze protection will not place the well into an under- balanced condition.) 17. Drop ball & rod and set the production packer and individually test the tubing to 4000 psi and annulus to 4,000 psi for 30 minutes each. 18. Set and test TWC. 19. ND BOPE. NU and test the tree to 5,000 psi. (NOTE: ANEW OR REFURBISHED 4" TREE WILL BE NEEDED FOR THIS WELL. ALSO, AS THE ORIENTATION OF THE TREE IS IMPORTANT, CONFIRM THE ORIENTATION OF THAT TREE WITH THE Y-PAD OPERATOR.) 20. Pull TWC and install BPV. 21. Secure the well. RDMO. Post-Rig Work: 22. Install wellhouse and flowlines. (NOTE: An "S" Riser modifications will be required.) 23. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. Y-07ai Sidetrack "Revised" Page 10 TREE WELLHEAD = ACTUATOR = KB. ELEV...- BF. ELEV - 51.46' KOP = Max Angle = Datum MD = Datu m TV D = 'A Y-07AI ~ Proposed Completion 13-3/8" CIBP - --2180' 9-5/8" Mechanical Cut - --2185' Calc TOC - 2200` 9-5/8" CIBP - -2550' - Jet Cut TBG - - 2600' 9-5/8" DV Sub - ~ 2600` ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" 2685 Calc TOC (zero excess) - 5,286` - -11,240` MD 4-1/2" X Nipple ID = 3.813" "-14,250' MD BKR 7" x 4-1/2" S3 PKR _14,270` MD 4-1/2" X Nipple ID = 3.813" 14,290` MD 4-1/2" XN Nipple ID = 3.725" -14,300` MD 4-1/2" WLEG // --14,294` MD -BKR HGR & LTP w/TB sleeve -14,394` MD - 7", 26#, L-80, BTC-M -4-1/2", 12.6#, L-80, IBT-M - 14,683` MD TOC - -8,500' ~ 8524' 4-1 /2"SLIDING SLEEVE ID = 3.813" 8587' 4-1 /2" TBG SEAL ASSY !' - " 2' 9-5 /8' z 4-1 /2" TIW HBBP PKR, ID = 4-1/2"TBG, 12.6#,L-80, 0.0152 bpf, ID=3.958" 1 -- 8602, I 2' 4-1/2"X3-1/2"XO TOP OF 3-1/2"TBG TA IL 8602' 647' 3-1 /2" OTIS X NIP, ID = 2.75" " 8 80' 3-1 /2" OTIS XN NIP, ID = 2.fi35" TOP OF 7 LNR 8 ' 8713' 3-1 l2" SHEA ROUT SUB TBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992' 8773 8713' 3-1 /2' WLEG 869 ELMD TT LOGGED 09/25/90 9-5/8"CS G, 47#,L-80, ID=8.681" 9787• a11~ 1n' ~ MA RKER JO INT DATE REV BY COMMENTS DATE REV BY COMMENTS 12/05/85 ORIGINAL COMPLETION 06/24/01 RN/TP CORRECTIONS 06/28/03 JRC/KK CORRECTIONS 07/25/07 JGR Proposed Completion PRUDHOE BAY UNIT WELL: Y-07 PERMrf No: 1810180 API No: 50-029-20560-02 SEC 34, T11 N, R13E,1341' SNL & 118' EWL BP Exploration (Alaska) -2200' MD HES 4-1/2" X Nipple ID = 3.813" 9-5/8" ES Cementer at -2100' MD f9-5/8" ES Cementer at 2106' MD --2020' MD -Top of Window in 13-3/8" Casing 4-1/2", 12.6#, L-80, TC-II TBG /~/ -9155` MD -BKR HGR &LTP w/TB sleave 9305' MD - 9-5/8", 47#, L-80, Casing ~~ ~ (Hydril 553 f/surf to 2490' MD /BTC to 9305' MD) • Plan: Y-07A wp21.A Sperry Drilling Services Proposal Report -Geographic 19 January, 2008 BP Amoco Prudhoe Bay PB Y Pad Y-07 Y-07A contingency Local Coordinate Origin: Centered on Well Y-07 Viewing Datum: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet HALUBURTON ---- 8perry Oriliing Service: Total Depth : 14682.81' [v1D, 9138.46' TVD b~ 6800 HALLIBURTON Y-07 ' Y-07A New T3 TD Rev2 ' ~ Y-07A wp_ A Sperry Grilling Services ~~ Y-07A Faulr 2 'Y-07A wp21 Dnllels Target -H r' ~ ~ Y-07A New Geo Poly Project: Prudhoe Bay ' ~ Site: PB Y Pad 4-1'2"i "End Dir :133'_6.71' MD, 8026.2' TVD Well: Y-07 6000 ' Wellbore: Y-07A contingenc Plan: Y-07A wp21.A 5600 ~ Stan Dir 4°! 100' :13110.69' MD, 7858.97TVD _ - 7~~ ' . Y-07A New 72 deeper - - ,~ - - " I 5200 ' ' - ' ~N'C ~ ~ ~ i , _ - _ ' Y-07A Fault I ~ i _ P I 1 1 To HOT ~ ' ~ ' i - ~_' _ _ _ _ _ y'-O7 Rig Sun eys Y-b7A ' i , i 1 I ~ I _ _ _ _ _ _ _ _ _ _ - Fnd Dir :12009.43' MD, 7495.49' TV D 4800 ~~ ' ' , ~i ' ' ~ ' _ 7SHU ~ i ' ~ I I - ~ Y-07A New T I Shallower Rev2 ' - -- ' ~ i i ' ~ I 1 ----- -- TSGR ~ ; 1 i r i r Stan Dir 4°/100' :121 31.78' MD, 720(1.58TVD 4400 1 1 1 I TJB ~ ~ I ~ ~ ~ TIC ~ ' I r ~ ~ T1D ~ ' ' ' I ' WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name TVD +WS +FJ-W Nonhing EasBrg Shapa Y-07A New T7 Shalbwar Rev2 7278.46 4740.00 -7014.78 5953520 29 637828.40 Point Y-07A New T2 deeper 7963.46 5154.34 -7561.34 5953924 00 837274.00 Point V-07A Fauk 1 8100.46 5044.86 -7127.34 5953823 00 637710.00 Polygon Y-07A New Geo Poty 8188.00 5444.25 -8278.95 5954200.00 636550.00 Polygon Y-07A vry21 Drillels Target 8188.00 5544.97 -0188.01 5954302.46 838838.98 Polygon Y-07A Fauk 2 8098.46 6246.25 -7853.10 5955010.00 836961.00 Polygon V-07A New T3 TD Rev2 8138.18 5677.69 -0185.43 5954435.00 638830.170 Point W ELL DETAILS: Y-07 Ground Level: 0.00 +N/_S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5948916.58 644932.60 70°16'4.268N 148°49'40.738W TIE ' ~ r ' End Dir :9513.42' MD, .5890.89' ND ~ ~ ` r TIF ' ' ' LCUrBHRZ/TIQ9G 1 1 9 5/8" Start Dlr 4"~ 100' :9310' MD, 5795.30'71'0 1 ~ ~ I i. THRZ ~ CMI CM2 ~ Sran Uu 2"/IOU' :9300' MD, 5790.99TVD : 150° LT TP C °o 0 0 3 O 2400 FORMATION TOP DETAILS No. TVDPatlt MDPath Fomulbn 1 4847.48 7145.73 UGt 2 5302.48 8182.58 W S2 3 5548.48 8744.15 WS1 2000 4 5754.48 9215.82 CM3 5 8215.48 10182.30 CM2 8 8901.48 11533.77 CMt 7 7217.48 12184.175 THRZ 8 7483.48 12584.70 LCU/BHRZ/n(NG 1600 9 7878.48 13285.12 TJF 10 8108.48 13427.00 TJE 11 8404.48 13787.89 TJD 12 8593.48 14018.33 TJC 13 8732.48 14187.80 TJB 10 8801.48 14393.&5 TSGR ITS 15 8827.48 14425.55 TSHU 18 8013.48 14530.41 TSAD 17 9033.48 14554.78 POWC 18 8053.48 14579.18 Top HOT Srm MD Inc Aa ND T"' 8300.00 84.23 304.58 5780.99 2 8310.00 84.05 304.18 5785.36 3 8513.42 58.99 296.19 5890.69 4 12131.78 59.99 296.48 7200.58 5 12278.72 55.00 300.00 7278.46 B 0 12808.43 43.52 308.94 7485 49 7 13110.89 43.52 308.94 7858.97 B 13248.70 38.00 309.00 7963.46 B 13326.71 34.80 309.55 8026.20 f0 11882.81 34.80 309.55 9138.46 400 DDI=6.45 ' CO MPANY DETAILS: BP Amoco Calcula0on Method: Minimum Curvature Error System: ISCWSA Scan Method: Travelling CyliMer Error Surface: Elliptical Conic W aming Method: Rules Based SECTION DETAILS +W-S +E/-W DLag TFace 1571.58 3718.03 0.00 0.00 3579.68 3723.44 2.00 -150.00 3670.89 3877.82 4.00 -121.80 4682.28 -0907.12 0.00 0.00 4740.00 -7014.78 4.00 150.25 4!380.77 -7222.83 4.00 152.30 5097.70 -7401.32 0.00 0.00 5154.34 -7581.34 4.00 170.61 5183,67 -7507.22 4.00 174.20 5677.68 -8185.43 0.00 0.00 VSec Target 5818.71 5825.70 8104.25 8339.48 8480.45 Y-07A New T7 Shalbwe 8711.48 9058.25 9148.20 Y-07A New T2 deeper 8192.47 9968.93 V-07A New T3 TD Rev2 Co-ordinate (WE) Reference: Web Y-07, True Nonh n @ 79.468 (Nabors TES (49.98*28.5)) Vertical (ND) Reference: Y-07A p la th ReferenceY Measured De 178+28 TES (49 5)) 07A 78 48N N b w a p ors . . - n @ . ( a Cakula8on Method: Minimum Curvature SURVEY PROGRAM Date: 2008-01-19700:00:00 Validated: Yes Version: 36.000 pepth From DepM To Survey/Plan Tool 91.66 1992.78 Copy of BOSS-GYR02 2020.00 9300.00 MWD+IFR+MS '~. 9300.00 14682.32 Y-07Awp21.A tv1WD+IFR+MS CASING DETAILS No TVD MD Name Size 1 5790.99 9300.00 95/8' 9-518 3600 ,.., 2 8901.46 14393.85 7° 7 3 9138.46 14682.81 4-1 /2' 4-1/2 O 3200 2800 0 °o c-p 7 v 2400 1600 • 12W 800 400 () `. n "' -000 -8400 -8000 -7600 -7200 -6800 -6400 -6000 -5600 -5200 ~t800 X400 -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 400 800 West(-)/East(+) (1000 fl/in) Project: Prudhoe Bay ~ SECTION DETAILS Site: PB Y Pad ~ HALL 1 B U R TO N Sec MD Inc Azi TVD +WS +E/-W DLeg TFace VSec Target ~ , Well: Y-07 • 1 9300.00 64.23 304.59 5790.99 3574.58 -4716.03 0.00 0.00 5916.71 ~ reUbore: Y-07A contingenc 111~ sPerry Drilling Services 3 9513.42 59.99 296.9 5890.89 3670.89 -4877.92 4.00 -12.80 6104.25 Ian: Y-07A wp21 A 4 12131.78 59.99 296.49 7200.58 4682.28 -6907.12 0.00 0.00 8339.46 . 5 12276.72 55.00 300.00 7278.46 4740.00 -7014.78 4.00 150.25 (3460.45 Y-07A New T1 Shallow 6 12609.43 43.52 308.94 7495.49 4880.77 -7222.83 4.00 152.30 8711.48 COMPANY DETAILS: BP Amoco 7 13110.69 43.52 308.94 7858.97 5097.70 -7491.32 0.00 0.00 9056.25 8 13248.70 38.00 309.00 7963.46 5154.34 -7561.34 4.00 179.61 9146.20 Y-07A New T2 deeper CakulaGon Methotl: Minimum Curvature 9 13326.71 34.90 309.55 6026.20 5183.67 -7597.22 4.00 174.20 9192.47 600 Error System: ISCW SA 10 14682.81 34.90 309.55 9138.46 5677.69 -8195.43 0.00 0.00 9966.93 Y-07A New T3 TD Rev Scan Method: Travelling Cylinder Error Surface: Elliptical Conic W ELLBORE TARGET DETAILS (MAP CO-ORDINATES) Warning Mefhotl: Rules Based 1200 Name TVD +W-S +E/-W Nonhing Eatting Shape Y-07A New Tt Shallower Rev2 7278.46 4740.00 -7014.78 5953520.29 637828.40 Point 2 deeper 1 12 DDI=6.45 00.46 5044.96 8 Y 07A Fault 1 7.34 5953823.00 637710.00 Polygon -7 1800 Y-07A New Geo Poly 8188.00 5444.25 -8279.95 5954200.00 636550.00 Polygon Y-07A wp21 Driller's Target 8188.00 5544.97 -8168.01 5954302.46 636639.98 Polygon Y-07A Fault 2 9098.46 6246.25 -7853.40 5955010.00 636961.00 Polygon Y-07A New T3 TO Rev2 9138.46 5677.69 -8195.43 5954435.00 636630.00 Point WELL DE-I'AIIS: Y-07 Ground Level: 0.00 - \' -S +g/-W Nonhln_ Eating Latittllde Longitude Slot O.UO 0.00 5948916.95 6449]2.80 70°16'4.?68N 148°49'40.738W C_ O O t a m O c~ r H REFERENCE INFORMATION Co-0rdinate (WE) Reference: Well Y-07, True North Vertical (ND) Reference: Y-07A plan @ 78.46f1(Nabors 7ES (49.96+28.5)) Start Dir 2°/100' :9300' MD, 5790.99'ND :150° LT TF Measured Depth Reference: Y-07A plan @ 78.46f1(Nabors 7ES (49.96+28.5)) Calculation Method: Minimum Curvature \ Start Dir 4°/100' :9310' MD, 5795.36'ND End Dir :9513.42' M0, 5890.89' ND Y-07/Y-07 CASING DETAILS ND MD Name Size 6600 5790.99 9300.00 9518' 9-518 8901.46 14393.85 7' 7 3 9138.46 14682.81 41/2' 4-1/2 7200 FORMATION TOP DETAILS --- No. TVDParti MDP~h Form~bn 7600 1 4847.48 7145.73 UG1 2 5302.46 8182.59 WS2 3 5549.46 8744.15 WSt 4 5754.48 9215.92 CM3 5 8215.48 10192.30 CM2 8 6901.46 11533.77 CM1 640D 7 7217.48 12164.95 THRZ 8 7493.48 12564.70 LCU43MRZITKNG 9 7976.46 13265.12 TJF 10 8108.48 13427.00 TJE 11 9404.48 13787.89 TJD 9000 12 8593.48 14019.33 TJC 13 8732.46 14187.80 TJB 14 8901.46 14393.85 TSGR 15 8927.46 14425.55 TSHU 18 9013.46 14530.41 TSAD 9600 17 9033.46 14554.79 POWC 19 8053.48 74579.18 Top HOT -600 0 600 1200 1800 2400 3000 3600 4200 1200 1800 Start Dir 4°1100' :12131.78' MD, 7200.58'ND 5400 9 518" 6000 CM2 Y-07A New T1 Shallower Rev2 6600 End Dir :12609.43' MD, 7495.49' ND CM1 ------ ,~~ ----- 7200 THRZ------ --------- , - - _ - - " Start Dir 4°I100' :13110.69' MD, 7858.9TND LCU/BHRZ/TKNG - - - - - - ' - Y-07A New T2 deeper - " 7800 Y-07(Rig Surveys Y-07A _ _ _ _ _ TJF - - - - _ _ _ _ ~ - - -- End Dir :13326.71' MD, 8026.2' ND TJE - - - _ _ _ - - - 7" Y-07A New T3 TD Rev2 8400 ---- _ - TJD----- - ___ TJC--- -__-- ---- _ -~~ i,- _-4-1/2" 9000 _ TJB - - - " ' " " ~ - " " , Total Depth :14682.81' MD, 9138.46' ND TSGR -' " TSHU TSAD / 9600 POWC Top HOT Y-071Y-07A wp21.A 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 Vertical Section at 306.14° (1500 ft/in) c rD N _~ ~i v m s 0 0 c~ CI C~ Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate ieference: Well Y-07 Company: BP Amoco TVD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Project: Prudhoe Bay MD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49:96+28.5)) Site: PB Y Pad North Reference: True Well: Y-07 Survey Calculation Method: Minimum Curvature Wellbore: Y-07A contingency. Design: Y-07A wp21.A Project Prudhoe Bay, NorEh Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Weli Y-07, Y-07 Well Position +N/-S 0.00 ft Northing: 5,948,916.58 ft Latitude: 70° 16' 04.268" N +E/-W 0.00 ft Easting: 644,932.60ft Longitude: 148° 49' 40.738" W Position Uncertainty O.OO ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore Y-07A contingency Magnetics Model Name Sample Date Declination Dip Angie Field Strength BGGM2007 1/16/2008 23.34 80.88 57,656 Design Y-07A wp21.A Audit Notes: Version: 36 Phase: PLAN Tie On Depth: 9,300.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction 0.00 0.00 0.00 306.14 Pian Summary Measured Dogleg Build Tum Depth inclination Azimuth TVD TYDSS +NIS +EI-W Rate Rate Rate TFO (ft) (°) {°) (ft) (g) (ft) (ft) (°HOOft) (°/100ft) (°/100ft) (°) 9,300.00 64.23 304.59 5,790.99 5,712.54 3,574.58 -4,716.03 0.00 0.00 0.00 0.00 9,310.00 64.05 304.48 5,795.36 5,716.90 3,579.68 -4,723.44 2.00 -1.73 -1.11 -150.00 9,513.42 59.99 296.49 5,890.89 5,812.43 3,670.89 -4,877.92 4.00 -2.00 -3.93 -121.80 12,131.78 59.99 296.49 7,200.58 7,122.12 4,682.28 -6,907.12 0.00 0.00 0.00 0.00 12,276.72 55.00 300.00 7,278.46 7,200.00 4,740.00 -7,014.78 4.00 -3.44 2.42 150.25 12,609.43 43.52 308.94 7,495.49 7,417.03 4,880.77 -7,222.83 4.00 -3.45 2.69 152.30 13,110.69 43.52 308.94 7,858.97 7,780.51 5,097.70 -7,491.32 0.00 0.00 0.00 0.00 13,248.70 38.00 309.00 7,963.46 7,885.00 5,154.34 -7,561.34 4.00 -4.00 0.04 179.61 13,326.71 34.90 309.55 8,026.20 7,947.74 5,183.67 -7,597.22 4.00 -3.98 0.71 174.20 14,682.81 34.90 309.55 9,138.46 9,060.00 5,677.69 -8,195.43 0.00 0.00 0.00 0.00 1/19/2008 10:17:11AM Page 2 of 10 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: w,.. .._, .Sperry EDM .11 Local Co-ordinate Reference: Well Y-07 Company: BP Amoco ND Reference; Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Project: Prudhoe Bay MD Reference: Y-07A plan @ 78:46ft (Nabors 7ES (49.96+28.5)) Site: PB Y Pad North Reference: True Weil Y-07 Survey Calculation Method: Minimum Curvature Weilbore: Y-07A contingency Design: Y-07A wp21.A Planned Survey Y-07A wp21.A Map Map MD Incl Azimuth ND (ft) TVDSS +N/-S +E/-W Northing Fasting DLSEV Vert Section {ft) {°) 1°) (ft) {ft) (ft) {ft) (ft) (°HOOft) (ft) 0.00 0.00 0.00 0.00 -78.46 0.00 0.00 5,948,916.58 644,932.60 0.00 0.00 100.00 0.92 171.64 99.99 21.53 -0.92 0.16 5,948,915.66 644,932.78 0.92 -0.67 200.00 0.92 188.84 199.98 121.52 -2.51 0.13 5,948,914.08 644,932.78 0.27 -1.59 300.00 0.88 190.93 299.97 221.51 -4.05 -0.13 5,948,912.53 644,932.55 0.05 -2.28 400.00 0.92 194.42 399.96 321.50 -5.59 -0.48 5,948,910.99 644,932.23 0.06 -2.90 500.00 0.86 194.56 499.95 421.49 -7.10 -0.88 5,948,908.47 644,931.86 0.06 -3.48 600.00 0.60 189.63 599.94 521.48 -8.34 -1.16 5,948,908.22 644,931.60 0.27 -3.98 700.00 0.39 164.90 699.93 621.47 -9.18 -1.16 5,948,907.38 644,931.62 0.29 -4.48 800.00 0.38 130.57 799.93 721.47 -9.72 -0.81 5,948,906.85 644,931.98 0.23 -5.08 900.00 0.38 114.48 899.93 821.47 -10.08 -0.25 5,948,906.50 644,932.54 0.11 -5.74 1,000.00 0.47 91.45 999.93 921.47 -10.23 0.47 5,948,906.36 644,933.27 0.19 -6.41 1,100.00 0.48 72.07 1,099.92 1021.46 -10.09 1.29 5,948,906.51 644,934.09 0.16 -7.00 1,200.00 0.30 72.27 1,199.92 1121.46 -9.90 1.95 5,948,906.72 644,934.74 0.19 -7.42 1,300.00 0.28 347.16 1,299.92 1221.46 -9.57 2.13 5,948,907.05 644,934.91 0.39 -7.36 1,400.00 0.28 325.22 1,399.92 1321.46 -9.10 1.91 5,948,907.52 644,934.69 0.11 -6.91 1,500.00 0.17 167.52 1,499.92 1421.46 -9.06 1.82 5,948,907.56 644,934.59 0.44 -6.81 1,600.00 0.37 171.80 1,599.92 1521.46 -9.52 1.89 5,948,907.10 644,934.68 0.21 -7.14 1,700.00 0.62 171.42 1,699.91 1621.45 -10.37 2.02 5,948,906.25 644,934.82 0.25 -7.75 1,800.00 0.78 170.28 1,799.90 1721.44 -11.60 2.23 5,948,905.02 644,935.05 0.16 -8.64 1,900.00 0.57 188.66 1,899.90 1821.44 -12.75 2.26 5,948,903.88 644,935.10 0.30 -9.34 2,000.00 0.35 241.33 1,999.89 1921.43 -13.73 2.08 5,948,902.89 644,934.95 0.46 -9.78 2,100.00 5.16 318.18 2,099.71 2021.25 -9.70 -1.44 5,948,906.85 644,931.34 5.09 -4.56 2,200.00 7.35 317.18 2,199.11 2120.65 -1.60 -8.68 5,948,914.81 644,923.96 2.20 6.06 2,300.00 12.96 316.26 2,297.63 2219.17 10.84 -20.07 5,948,927.03 644,912.33 5.61 22.60 2,400.00 17.05 313.89 2,394.11 2315.65 29.38 -38.62 5,948,945.21 644,893.42 4.14 48.52 2,500.00 20.76 316.49 2,488.71 2410.25 52.33 -61.47 5,948,967.71 644,870.14 3.80 80.50 2,600.00 25.59 321.06 2,580.62 2502.16 81.98 -87.26 5,948,996.86 644,843.78 5.15 118.82 2,700.00 31.45 322.29 2,668.64 2580.18 119.40 -116.32 5,949,033.71 644,814.02 5.89 164.35 2,800.00 35.97 320.58 2,751.77 2673.31 162.79 -150.96 5,949,076.42 644,778.55 4.62 217.92. 2,900.00 39.83 318.86 2,830.56 2752.10 209.76 -190.74 5,949,122.62 644,737.87 4.00 277.75 3,000.00 42.48 317.07 2,905.73 2827.27 258.66 -234.96 5,949,170.65 644,692.72 2.90 342.30 3,100.00 45.05 316.26 2,978.19 2899.73 308.66 -282.37 5,949,219.72 644,644.36 2.63 410.07 3,200.00 48.43. 316.01 3,046.55 2968.09 361.34 -332.86 5,949,271.42 644,592.87 3.38 481.92 3,300.00 51.11 314.10 3,111.11 3032.65 415.70 -386.47 5,949,324.73 644,538.23 3.05 557.27 3,400.00 52.99 310.40 3,172.34 3093.88 468.90 -444.93 5,949,376.79 644,478.76 3.47 635.86 3,500.00 54.36 306.47 3,231.65 3153.19 518.93 -507.99 5,949,425.59 644,414.75 3.45 716.28 3,600.00 57.47 304.74 3,288.10 3209.64 566.48 -575.44 5,949,471.83 644,346.41 3.42 798.80 3,700.00 60.99 305.84 3,339.12 3260.66 615.87 -645.83 5,949,519.86 644,275.09 3.64 884.77 3,800.00 62.66 308.08 3,386.20 3307.74 669.03 -716.22 5,949,571.65 644,203.68 2.59 972.97 3,900.00 64.42 307.16 3,430.41 3351.95 724.01 -787.09 5,949,625.25 644,131.78 1.95 1,062.63 4,000.00 64.45 305.93 3,473.30 3394.84 777.74 -859.70 5,949,677.57 644,058.15 1.11 1,152.96 4,100.00 64.51 304.14 3,516.47 3438.01 829.62 -933.48 5,949,728.01 643,983.39 1.61 1,243.14 4,200.00 64.68 303.47 3,559.36 3480.91 879.73 -1,008.64 5,949,776.66 643,907.28 0.63 1,333.39 4,300.00 64.66 303.82 3,602.13 3523.67 929.75 -1,083.94 5,949,825.22 643,831.05 0.32 1,423.70 4,400.00 64.42 304.98 3,645.10 3566.64 980.73 -1,158.46 5,949,874.75 643,755.56 1.07 1,513.95 4,500.00 64.25 305.97 3,688.40 3609.94 1,033.04 -1,231.88 5,949,925.63 643,681.16 0.91 1,604.08 4,600.00 63.83 307.29 3,732.22 3653.76 1,086.68 -1,304.00 5,949,977.87 643,608.02 1.26 1,693.96 4,700.00 63.93 308.40 3,776.23 3697.77 1,141.74 -1,374.93 5,950,031.55 643,536.05 1.00 1,783.72 4,800.00 63.95 309.64 3,820.17 3741.71 1,198.35 -1,444.67 5,950,086.81 643,465.24 1.11 1,873.42 1/19/200810:17:11AM Page 3 of 10 COMPASS 2003. f 18uild 48 Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Y-07 Company: BP Amoco TVD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) ~~ Project: Prudhoe Bay MD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Site: PB Y Pad North Reference: True Well: Y-07 Survey Calculation Method: Minimum Curvature Wellbore: Y-07A contingency Design; Y-07A wp21.A Planned Survey Y-07A wp21.A Map Map MD tncl Azimuth TVD (ft) TVDSS +N1-S +E/•W Northing Easting DLS~V Vart Section lft) (°) (°) (ft) lft) lft) lft) ln) (°/10t?Pt) lft) 4,900.00 64.04 309.90 3,864.02 3785.56 1,256.06 -1,513.57 5,950,143.17 643,395.25 0.25 1,963.10 5,000.00 64.11 308.77 3,907.73 3829.27 1,313.13 -1,583.08 5,950,198.89 643,324.65 1.01 2,052.89 5,100.00 64.17 307.15 3,951.35 3872.89 1,368.55 -1,653.97 5,950,252.93 643,252.72 1.46. 2,142.83 5,200.00 64.10 305.87 3,994.90 3916.44 1,421.89 -1,726.48 5,950,304.86 643,179.20 1.15 2,232.85 5,300.00 63.94 305.56 4,038.75 3960.29 1,474.30 -1,799.49 5,950,355.85 643,105.19 0.32 2,322.72 5,400.00 63.88 305.44 4,082.71 4004.25 1,526.45 -1,872.62 5,950,406.58 643,031.08 0.12 2,412.53 5,500.00 64.73 306.27 4,126.36 4047.90 1,578.91 -1,945.72 5,950,457.61 642,957.00 1.13 2,502.49 5,600.00 65.05 306.05 4,168.48 4090.02 1,632.80 -2,018.66 5,950,510.09 642,883.03 0.38 2,593.19 5,700.00 64.66 304.54 4,210.95 4132.49 1,685.18 -2,092.50 5,950,561.03 642,808.20 1.43 2,683.71 5,800.00 64.17 303.09 4,254.12 4175.66 1,735.34 -2,167.47 5,950,609.74 642,732.29 1.39 2,773.83 5,900.00 63.29 301.82 4,298.33 4219.87 1,783.46 -2,243.16 5,950,656:38 642,655.69 1.44 2,863.34 6,000.00 63.84 302.90 4,342.99 4264.53 1,831.17 -2,318.85 5,950,702.62 642,579.10 1.12 2,952.60 6,100.00 63.33 304.42 4,387.41 4308.95 1,880.81 -2,393.43 5,950,750.82 642,503.59 1.45 3,042.11 6,200.00 63.06 307.79 4,432.58 4354.12 1,933.41 -2,465.47 5,950,802.02 642,430.55 3.02 3,131.31 6,300.00 64.31 308.97 4,476.82 4398.36 1,989.25 -2,535.64 5,950,856.49 642,359.32 1.64 3,220.91 6,400.00 64.41 307.70 4,520.03 4441.57 2,045.29 -2,606.30 5,950,911.15 642,287.60 1.15 3,311.02 6,500.00 63.85 305.78 4,563.58 4485.12 2,098.93 -2,678.58 5,950,963.39 642,214.31 1.81 3,401.03 6,600.00 63.25 304.80 4,608.36 4529.90 2,150.78 -2,751.42 5,951,013.83 642,140.49 1.06 3,490.43 6,700.00 63.96 302.94 4,652.91 4574.45 2,200.58 -2,825.82 5,951,062.18 642,065.16 1.81 3,579.88 6,800.00 64.63 301.90 4,696.08 4617.62 2,248.78 -2,902.06 5,951,108.90 641,988.00 1.15 3,669.88 6,900.00 64.46 302.17 4,739.00 4660.54 2,296.43 -2,978.79 5,951,155.06 641,910.38 0.30 3,759.95 7,000.00 63.77 304.62 4,782.52 4704.06 2,345.55 -3,054.23 5,951,202.72 641,834.01 2.31 3,849.84 7,100.00 63.56 306.72 4,827.16 4748.71 2,398.21 -3,126.57 5,951,253.97 641,760.68 1.89 3,939.32 7,145.73 63.76 306.99 4,847.46 4769..00 2,422.80 -3,159.36 5,951,277.92 641,727.42 0.70 3,980.30 UG1 7,200.00 64.08 307.00 4,871.32 4792.86 2,452.13 -3,198.29 5,951,306.49 641,687.94 0.58 4,029.04 7,300.00 64.61 307.64 4,914.60 4836.14 2,506.64 -3,270.08 5,951,359.61 641,615.11 0.79 4,119.17 7,400.00 64.47 307.69 4,957.43 4878.97 2,562.04 -3,341.48 5,951,413.62 641,542.67 0.15 4,209.49 7,500.00 63.99 307.82 5,000.89 4922.43 2,617.10 -3,412.74 5,951,467.30 641,470.37 0.50 4,299.52 7,600.00 63.94 306.88 5,044.85 4966.39 2,671.75 -3,484.02 5,951,520.55 641,398.05 0.85 4,389.31 7,700.00 63.89 307.02 5,088.81 5010.35 2,725.63 -3,555.89 5,951,573.04 641,325.16 0.13 4,479.13 7,800.00 63.34 .306.55 5,133.22 5054.76 2,779.31 -3,627.62 5,951,625.32 641,252.42 0.69 4,568.72 7,900.00 63.36 306.88 5,178.10 5099.65 2,832.73 -3,699.26 5,951,677.35 641,179.77 0.30 4,658.07 8,000.00 63.90 306.81 5,222.50 5144.04 2,886.56 -3,770.89 5,951,729.79 641,107.12 0.55 4,747.67 8,100.00 64.08 305.44 5,266.32 5187.86 2,939.44 -3,843.58 5,951,781.26 641,033.44 1.25 4,837.56 8,182.58 64.01 305.20 5,302.46 5224.00 2,982.36 -3,904.17 5,951,823.00 640,972.03 0.27 4,911.80 WS2 8,200.00 63.98 305.24 5,310.10 5231.64 2,991.39 -3,916.96 5,951,831.78 640,959.07 0.30 4,927.45 8,300.00 63.98 305.98 5,354.08 5275.62 3,043.45 -3,990.14 5,951,882.41 640,884.91 0.67 5,017.25 8,400.00 64.24 307.24 5,397.59 5319.13 3,097.50 -4,062.15 5,951,935.06 640,811.88 1.16 5,107.28 8,500.00 64.03 306.66 5,441.29 5362.83 3,151.63 -4,133.97 5,951,987.80 640,739.03 0.56 5,197.22 8,600.00 63.94 306.18 5,485.09 5406.63 3,204.87 -4,206.41 5,952,039.63 640,665.59 0.44 5,287.11 8,700.00 63.96 306.02 5,529.13 5450.67 3,257.82 -4,278.92 5,952,091.17 640,592.08 0.14 5,376.90 8,744.15 64.10 305.88 5,548.46 5470.00 3,281.13 -4,311.05 5,952,113.85 640,559.51 0.43 5,416.59 WSi 8,800.00 64.43 305.71 5,572.71 5494.25 3,310.55 -4,351.86 5,952,142.48 640,518.15 0.65 5,466.90 8,900.00 64.18 305.44 5,615.82 5537.36 3,363.03 -4,425.25 5,952,193.54 640,443.76 0.35 5,557.12 1/19/2008 10:17:11AM Page 4 of 10 COMPASS 2003.11 Build 48 • Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: WeIl7Y-07 _ Company: BP Amoco TVD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Project: Prudhoe Bay MD Reference: Y-07A plan @ 78.46ft (Nabors 7ES. (49.96+28.5)) Site: PB Y Pad North Reference: True Well: Y-07 Survey Calculation Method: Minimum Curvature Weltbore: Y-07A contingency Design: Y-07A wp21.A Planned Survey Y-07A wp21.A MD Incl Azimuth TVD (fti TYDSS +N/•S (ft) (°) (°) (ft) (ft) 9,000.00 63.80 305.71 5,659.78 5581.32 3,415.18 9,100.00 64.00 305.99 5,703.85 5625.39 3,467.79 9,200.00 64.16 306.75 5,747.53 5669.07 3,521.05 9,215.92 64.18 306.90 5,754.46 5676.00 3,529.64 CM3 9,300.00 64.23 304.59 5,790.99 5712,54 3,574.58 Start Dir 2°/100' :9300' MD, 5790.99TVD :150° LT TF - 9 5/8° 9,310.00 64.05 304.48 5,795.36 5716.90 3,579.68 Start Dir 4°/100' :931 0' MD, 5795.36'TVD 9,315.42 63.94 304.27 5,797.73 5719.27 3,582.43 End Dir :9513.42' MD, 5890.89' TVD 9,400.00 62.20 301.02 5,836.05 5757.59 3,623.11 9,500.00 60.24 297.04 5,884.21 5805.75 3,665.65 9,513.42 59.99 296.49 5,890.89 5812.43 3,670.89 9,600.00 59.99 296.49 5,934.20 5855.74 3,704.33 9,700.00 59.99 296.49 5,984.22 5905.76 3,742.96 9,800.00 59.99 296.49 6,034.24 5955.78 3,781.59 9,900.00 59.99 296.49 6,084.26 6005.80 3,820.22 10,000.00 59.99 296.49 6,134.28 6055.82 3,858.84 10,100.00 59.99 296.49 6,184.30. 6105.84 3, 897.47 10,162.30 59.99 296.49 6,215.46 6137.00 3,921.53 CM2 10,200.00 59.99 296.49 6,234.32 6155.86 3,936.10 10,300.00 59.99 296.49 6,284.34 6205.88 3,974.72 10,400.00 59.99 296.49 6,334.35 6255.89 4,013.35 10,500.00 59.99 296.49 6,384.37 6305.91 4,051.98 10,600.00 59.99 296.49 6,434:39 6355.93 4,090.60 10,700.00 59.99 296.49 6,484.41 6405.95 4,129.23 10,800.00 59.99 296.49 6,534.43 6455.97 4,167.86 10,900.00 59.99 296.49 6,584.45 6505.99 4,206.48 11,000.00 59.99 296.49 6,634.47 6556.01 4,245.11 11,100.00 59.99 286.49 6,684.49 6606.03 4,283.74 11,200.00 59.99 296.49 6,734.51 6656.05 4,322.36 11,300.00 59.99 296.49 6,784.53 6706.07 4,360.99 11,400.00 59.99 296.49 6,834.55 6756.09 4,399.62 11,500.00 59.99 296.49 6,884.57 6806.11 4,438.24 11,533.77 59.99 296.49 6,901.46 6823.00 4,451.29 CM1 11,600.00 59.99 296.49 6,934.59 6856.13 4,476.87 11,700.00 59.99 296.49 6,984.61 6906.15 4,515.50 11,800.00 59.99 296.49 7,034.63 6956.17 4,554.12 11,900.00 59.99 296.49 7,084.64 7006.19 4,592.75 12,000.00 59.99 296.49 7,134.66 7056.20 4,631.38 12,100.00 59.99 296.49 7,184.68 7106.22 4,670.00 Map Map +EI.1N Northing Easting DLSEY Vert Section (ft) (ft) (fU (°l100h) (ft) -4,498.39 5,952,244,26 640,369.64 .0.44 5,646.94 -4,571.12 5,952,295.46 640,295.91 0.32 5,736.70 -4,643.61 5,952,347.31 640,222.41 0:70 5,826.66 -4,655.08 5,952,355.67 640,210.78 0.84 5,840.98 -4,716.03 5,952,399.43 640,148.98 2.47 5,916.71 -4,723.44 5,952,404.38 640,141.47 2.00 5,925.70 -4,727.46 5,952,407.06 640,137.40 4.00 5,930.57 -4,790.94 5,952,446.51 640,073.16 4.00 6,005.82 -4,867.53 5,952,487.56 639,995.77 4.00 6,092.77 -4,877.92 5,952,492.60 639,985.28 4.01 6,104.25 -4,945.02 5,952,524.74 639,917.56 0.00 6,178.16 -5,022.52 5,952,561.87 639,839.33 0.00 6,263.53 -5,100.02 5,952,598.99 639,761.11 0.00 6,348.89 -5,177.52 5,952,636.12 639,682.89 0.00 6,434.26 -5,255.01 5,952,673.24 639,604.67 0.00 6,519.63 -5,332.51 5,952,710.37 639,526.45 0.00 6,604.99 -5,380.80 5,952,733.49 639,477.71 0.00 6,658.18 -5,410.01 5,952,747.49 639,448.22 0.00 6,690.36 -5,487.51 5,952,784.61 639,370.00 0.00 6,775.73 -5,565.01 5,952,821.74 639,291.78 0.00 6,861.09 -5,642.51 5,952,858.86 639,213.56 0.00 6,946.46 -5,720.01 5,952,895.99 639,135.34 0.00 7,031.83 -5,797.50 5,952,933.11 639,057.11 0.00 7,117.19 -5,875.00 5,952,970.24 638,978.89 0.00 7,202.56 -5,952.50 5,953,007.36 638,900.67 0.00 7,287.93 -6,030.00 5,953,044.49 638,822.45 0.00 7,373.29 -6,107.50 5,953,081.61 638,744.23 0.00 7,458.66 -6,185.00 5,953,118.74 638,666.00 0.00 7,544.03 -6,262.50 5,953,155.86 638,587.78 0.00 7,629.39 -6,340.00 5,953,192.98 638,509.56 0.00 7,714.76 -6,417.49 5,953,230.11 638,431.34 0.00 7,800.13 -6,443.67 5,953,242.65 638,404.92 0.00 7,828.96 -6,494.99 5,953,267.23 638,353.12 0.00 7,885.49 -6,572.49 5,953,304.36 638,274.89 0.00 7,970.86 -6,649.99 5,953,341.48 638,196.67 0.00 8,056.23 -6,727.49 5,953,378.61 638,118.45 0.00 8,141.60 -6,804.99 5,953,415.73 638,040.23 0.00 8,226.96 -6,882.49 5,953,452.86 637,962.00 0.00 8,312.33 1/19/2008 10:17:11AM Page 5 of 10 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: .Spent' EDM .11 Local Co-ordinate Reference: Well Y-07 Company: BP Amoco TVD Reference: Y-07A plan @ 78:46ft (Nabors 7ES (49.96+28.5)) Project: Prudhoe Bay MD Reference: Y-07A plan @ 78:46ft (Nabors 7ES (49.96+28.5)) Site: PB Y Pad North Reference: True Well: Y-07 Survey Calculation Method: Minimum Curvature Wellbore: Y-07A contingency Design: Y-07A wp21.A Planned Survey Y-07A wp21.A Map Map MD incl Azimuth TVD (ft) TVDSS +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) tft) lft) (ft) (ft) (ft! (°/t00ft) (ft) 12,131.78 59.99 296.49 7,200.58 7122.12 4,682.28 -6,907.12 5,953,464.66 637,937.14 .0.00 8,339.46 Start Dir 4°1100' : 1213 1.78' MD, 7 200.58'TVD 12,164.95 58.84 297.26 7,217.46 7139.00 4,695.19 -6,932.59 5,953,477.07 637,911.43 4.00 8,367.64 THRZ 12,200.00 57.63 298.09 7,235.91 7157.45 4,709.03 -6,958.97 5,953,490.40 637,884.79 3.99 8,397.11 12,276.72 55.00 300.00 7,278.46 7200.00 4,740.00 -7,014.78 5,953,520.29 637,828.40 4.00 8,460.45 Y-07A New T1 Shallower Rev2 12,300.00 54.18 300.53 7,291.95 7213.49 4,749.56 -7,031.17 5,953,529.54 637,811.83 3.99 8,479.32 12,400.00 50.67 302.96 7,352.93 7274.47 4,791.22 -7,098.56 5,953,569.88 637,743.65 4.00 8,558.32 12,500.00 47.22 305.64 7,418.61 7340.15 4,833.66 -7,160.86 5,953,611.11 637,680.55 4.00 8,633.66 12,564.70 45.02 307.54 7,463.46 7385.00 4,861.45 -7,198.31 5,953,638.17 637,642.58 4.00 8,680.29 LCUIBHRZ/TKNG 12,600.00 43.83 308.64 7,488.67 7410.21 4,876.69 -7,217.76 5,953,653.03 637,622.84 4.00 8,704.98 12,609.43 43.52 308.94 7,495.49 7417.03 4,880.77 -7,222.83 5,953,657.01 637,617.69 4.00 8,711.48 End Dir :12609.43' MD, 7495.49' TVD 12,700.00 43.52 308.94 7,561.16 7482.70 4,919.96 -7,271.34 5,953,695.26 637,568.44 0.00 8,773.78 12,800.00 43.52 308.94 7,633.68 7555.22 4,963.24 -7,324.90 5,953,737.50 637,514.06 0.00 8,842.56 12,900.00 43.52 308.94 7,706.19 7627.73 5,006.52 -7,378.47 5,953,779.74 637,459.68 0.00 8,911.33 13,000.00 43.52 308.94 7,778.70 7700.24 5,049.80 -7,432.03 5,953,821.97 637,405.30 0.00 8,980.11 13,100.00 43.52 308.94 7,851.22 7772.76 5,093.07 -7,485.59 5,953,864.21 637,350.91 0.00 9,048.89 13,110.69 43.52 308.94 7,858.97 7780.51 5,097.70 -7,491.32 5;953,868.72 637,345.10 0.00 9,056.25 Start Dir 4°/100' : 1311 0.69' MD, 7858.97'TVD 13,200.00 39.95 308.98 7,925.60 7847.14 5,135.07 -7,537.54 5,953,905.19 637,298.17 4.00 9,115.61 13,248.70 38.00 309.00 7,963.46 7885.00 5,154.34 -7,561.34 5,953,924.00 637,274.00 4.00 9,146.20 Y-07A New T2 deeper 13,265.12 37.35 309.11 7,976.46 7898.00 5,160.67 -7,569.14 5,953,930.17 637,266.09 4.00 9,156.23 TJF 13,300.00 35.96 309.35 8,004.44 7925.98 5,173.83 -7,585.27 5,953,943.03 637,249.71 3.99 9,177.02 13,326.71 34.90 309.55 8,026.20 7947.74 5,183.67 -7,597.22 5,953,952.63 637,237.57 4.01 9,192.47 End Dir :13326.71' MO, 8026.2' TVD 13,400.00 34.90 309.55 8,086.32 8007.86 5,210.37 -7,629.55 5,953,978.70 637,204.73 0.00 9,234.33 13,417.24 34.90 309.55 8,100.46 8022.00 5,216.65 -7,637.16 5,953,984.83 637,197.00 0.00 9,244.18 Y-07A Fault 1 13,427.00 34.90 309.55 8,108.46 8030.00 5,220.21 -7,641.46 5,953,988.30 637,192.63 0.00 9,249.75 TJE 13,500.00 34.90 309.55 8,168.34 8089.88 5,246.80 -7,673.66 5,954,014.27 637,159.93 0.00 9,291.44 13,523.98 34.90 309.55 8,188.00 8109.54 5,255.53 -7,684.24 5,954,022.80 637,149.19 0.00 9,305.13 Y-07A New Geo Poly - Y-07A wp21 Driiler's Ta rget 13,600.00 34.90 309.55 8,250.35 8171.89 5,283.23 -7,717.78 5,954,049.84 637,115.13 0.00 9,348.55 13,700.00 34.90 309.55 8,332.37 8253.91 5,319.66 -7,761.89 5,954,085.41 637,070.32 0.00 9,405.66 1/19/2008 10:17:11AM Page 6 of 10 COMPASS 2003.11 Build 48 • Halliburton Company Compass Proposal Report -Geographic Database: .Spent' EDM .11 Local Co-ordinate Reference: Well Y-07 Company: BP Amoco TVD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Project: Prudhoe Bay MD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Site: PB Y Pad North Reference; True Well: Y-07 Survey Calculation Method: Minimum Curvature Wellbore: Y-07A contingency Design: Y-07A wp21.A Planned Survey Y-07A wp21.A Map Map MD Incl Azimuth TVD (ft) TVDSS +NI-S +E/-W Northing Easting pL$~V Vert Section (fU (°) (°) (ftl (ftl (ft) (ft) (ft) (°/100ft) fft1 13,787.89 34.90 309.55 8,404.46 8326.00 5,351.68 -7,800.66 5,954,116.67 637,030.95 0.00 .9,455.85 TJD 13,800.00 34.90 309.55 8,414.39 8335.93 5,356.09 -7,806.00 5,954,120.98 637,025.52 0.00 9,462.77 13,900.00 34.90 309.55 8,496.41 8417.95 5,392.52 -7,850.12 5,954,156.55 636,980.72 0.00 9,519.87 14,000.00 34.90 309.55 8,578.43 8499.97 5,428.94 -7,894.23 5,954,192.12 636,935.92 0.00 9,576.98 14,018.33 34.90 309.55 8,593.46 8515.00 5,435.62 -7,902.31 5,954,198.64 636,927.70 0.00 9,587.45 TJC 14,100.00 34.90 309.55 8,660.45 8581.99 5,465.37 -7,938.34 5,954,227.69.. 636,891.11 0.00 9,634.09 14,187.80 34.90 309.55 8,732.46 8654.00 5,497.36 -7,977.07 5,954,258.92 636,851.78 0.00 9,684.24 TJB 14,200.00 34.90 309.55 8,742.46 8664.00 5,501.80 -7,982.45 5,954,263.26 636,846.31 0.00 9,691.20 14,300.00 34.90 309.55 8,824.48 8746.02 5,538.23 -8,026.57 5,954,298.83 636,801.51 0.00 9,748.31 14,393.85 34.90 309.55 8,901.46 8823.00 5,572.42 -8,067.97 5,954,332.22 636,759.46 0.00 9,801.91 TSGR - 7" 14,400.00 34.90 309.55 8,906.50 8828.04 5,574.66 -8,070.68 5,954,334.40 636,756.71 0.00 9,805.42 14,425.55 34.90 309.55 8,927.46 8849.00 5,583.97 -8,081.95 5,954,343.49 636,745.26 0.00 9,820.01 TSHU 14,500.00 34.90 309.55 8,988.52 8910.06 5,611.09 -8,114.79 5,954,369.97 636,711.90 0.00 9,862.53 14,530.41 34.90 309.55 9,013.46 8935.00 5,622.17 -8,128.20 5,954,380.79 636,698.28 0.00 9,879.89 TSAD 14,554.79 34.90 309.55 9,033.46 8955.00 5,631.05 -8,138.96 5,954,389.46 636,687.36 0.00 9,893.82 POWC 14,579.18 34.90 309.55 9,053.46 8975.00 5,639.93 -8,149.72 5,954,398.14 636,676.43 0.00 9,907.74 Top HOT 14,600.00 34.90 309.55 9,070.54 8992.08 5,647.52 -8,158.90 5,954,405.54 636,667.10 0.00 9,919.64 14,634.04 34.90 309.55 9,098.46 9020.00 5,659.92 -8,173.92 5,954,417.65 636,651.85 0.00 9,939.08 Y-07A Fault 2 14,682.00 34.90 309.55 9,137.79 9059.33 5,677.39 -8,195.07 5,954,434.71 636,630.36 0.00 9,966.46 Total Depth : 14682.81' MD, 9138.46' ND 14,682.81 34.90 309.55 9,138.46 9060.00 5,677.69 -8,195.43 5,954,435.00 636,630.00 0.00 9,966.93 4-1/2" - Y-07A New T3 TD Rev2 1/19/2008 10:17:11AM Page 7 of 10 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 t.ocat Co-ordinate Reference; Well Y-07 Company: BP Amoco TVD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Project: Prudhoe Bay MD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)). Site: PB Y Pad North Ref®rence: True Well: Y-07 Survey Calculation Method: Minimum Curvature Wellbore: Y-07A contingency Design: Y-07A wp21.A Geologic Targets Y-07A contingency TVD TVDSS Target Name +N/-S +E!-W Northing East)ng (ft) (ft) -Shape ft ft (ft) (ft} 8,100.46 Y-07A Fault 1 5,044.96 -7,127.34 5,953,823.00 637,710.00 - Polygon Point 1 0.00 0.00 5,953,823.00 637,710.00 Point 2 1.15 304.10 5,953,830.00 638,014.00 Point 3 56.19 562.23 5,953,890.00 638,271.00 Point 4 1.15 304.10 5,953,830.00 638,014.00 7,278.46 Y-07A New T1 Shallower Rev2 4,740.00 -7,014.78 5,953,520.29 637,828.40 - Point 8,188.00 Y-07Awp21 Driller'sTarget 5,544.97 -8,188.01 5,954,302.46 636,639.98 - Polygon Point 1 0.00 0.00 5,954,302.46 636,639.98 Point 2 0.93 9.73 5,954,303.58 636,649.69 Point 3 2.58 20.15 5,954,305.43 636,660.08 Point 4 4.72 30.95 5,954,307.77 636,670.83 Point 5 6.84 41.73 5,954,310.10 636,681.57 Point 6 8.98 52.53 5,954,312.45 636,692.32 Point 7 11.11 63.31 5,954,314.79 636,703.06 Point 8 13.25 74.09 5,954,317.13 636,713.80 Point 9 15.49 84.86 5,954,319.58 636,724.52 Point 10 17.85 95.55 5,954,322.14 636,735.16 Point 11 20.31 106.10 5,954,324.81 636,745.66 Point 12 23.11 116.28 5,954,327.80 636,755.78 Point 13 26.14 125.95 5,954,331.02 636,765.39 Point 14 29.54 134.79 5,954,334.59 636,774.17 Point 15 33.42 142.34 5,954,338.61 636,781.64 Point 16 37.67 148.30 5,954,342.98 636,787.52 Point 17 42.08 152.73 5,954,347.47 636,791.86 Point 18 45.05 154.77 5,954,350.48 636,793.84 Point 19 50.60 157.54 5,954,356.08 636,796.50 Point 20 57.52 159.31 5,954,363.03 636,798.14 Point 21 65.80 159.42 5,954,371.31 636,798.09 Point 22 75.04 158.26 5,954,380.53 636,796.75 Point 23 84.93 155.67 5,954,390.36 636,793.97 Point 24 95.11 152.31 5,954,400.48 636,790.42 Point 25 105.43 148.56 5,954,410.72 636,786.47 Point 26 115.76 144.42 5,954,420.97 636,782.13 Point 27 126.11 140.22 5,954,431.24 636,777.74 Point 28 136.41 135.88 5,954,441.45 636,773.20 Point 29 146.71 131.54 5,954,451.66 636,768.66 Point 30 157.00 127.20 5,954,461.87 636,764.12 Point 31 166.96 122.65 5,954,471.74 636,759.38 Point 32 175.97 117.69 5,954,480.65 636,754.25 Point 33 178.19 116.15 5,954,482.84 636,752.67 Point 34 185.82 108.65 5,954,490.32 636,745.02 Point 35 189.85 98.05 5,954,494.15 636,734.35 Point 36 190.25 85.52 5,954,494.31 636,721.81 Point 37 188.75 72.31 5,954,492.55 636,708.64 Point 38 186.70 59.00 5,954,490.25 636,695.37 Point 39 184.43 45.71 5,954,487.72 636,682.13 Point 40 181.95 32.51 5,954,484.99 636,668.98 Point 41 179.21 19.55 5,954,482.00 636,656.07 Point 42 175.51 7.43 5,954,478.07 636,644.03 Point 43 170.56 -3.13 5,954,472.92 636,633.57 Point 44 164.33 -11.40 5,954,466.53 636,625.42 Point 45 163.54 -12.11 5,954,465.72 636,624.72 Point 46 156.40 -17.57 5,954,458.48 636,619.40 Point 47 146.91 -22.00 5,954,448.91 636,615.16 Point 48 135.24 -24.92 5 954 437.18 636 612.46 1/19/2008 10:17:11AM Page 8 of 10 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: .Spent' EDM .11 Local Co-ordinate Reference: Well Y-07 Company: BP Amoco TVD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49:96+28.5)) Project: Prudhoe Bay MD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Site: PB Y Pad North Reference: True Well: Y-07 Survey Calculation Method: Minimum Curvature Wellbore: Y-07A contingency Design: Y-07A wp21.A Point 49 122.04 -26.44 5,954,423.96 636,611.20 Point 50 108.01 -26.96 5,954,409.92 636,610.95 Point 51 93.61 -26.89 5,954,395.53 636,611.29 Point 52 79.08 -26.55 5,954,381.01 636,611.91 Point 53 64.52 -26.10 5,954,366.46 636,612.64 Point 54 49.98 -25.49 5,954,351.94 636,613.53 Point 55 35.55 -24.70 5,954,337:53 636,614.60 Point 56 21.75 -23.09 5,954,323.76 636,616.48 Point 57 9.85 -19.58 5,954,311.93 636,620.22 Point 58 2.31 -12.60 5,954,304.53 636,627.34 Point 59 0.05 -2.83 5,954,302.46 636,637.15 Point 60 0.00 0.00 5,954,302.46 636,639.98 7,963.46 Y-07A New T2 deeper 5,154.34 -7,561.34 5,953,924.00 637,274.00 - Point 9,098.46 Y-07A Fault 2 6,246.25 -7,853.40 5,955,010.00 636,961.00 - Polygon Point 1 0.00 0.00 0.00 0.00 Point 2 -692.13 360.77 0.00 0.00 Point 3 -838.33 681.04 0.00 0.00 Point 4 -692.13 360.77 0.00 0.00 9,138.46 Y-07A New T3 TD Rev2 5,677.69 -8,195.43 5,954,435.00 636,630.00 - Point 8,188.00 Y-07A New Geo Poly 5,444.25 -8,279.95 5,954,200.00 636,550.00 - Polygon Point 1 0.00 0.00 5,954,200.00 636,550.00 Point 2 77.48 391.59 5,954,285.00 636,940.00 Point 3 395.14 257.67 5,954,600.00 636,800.00 Point 4 350.35 -13.26 5,954,550.00 636,530.00 Point 5 0.00 0.00 5,954,200.00 636,550.00 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter tft) tft) ("j ("I 9,300.00 5,790.99 9-5/8 12-1/4 14,393.85 8,901.46 7 8-1/2 14,682.81 9,138.46 4-112 6-118 1/19/2008 10:17:11AM Page 9 of 10 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Y-07 Company: BP Amoco TVD Reference: Y-07A plan @ 78.46ft (Nabors 7ES (49.96+28.5)) Project: Prudhoe Bay MD Reference: Y-07A plan @ 78:46ft (Nabors 7ES (49.96+28.5)) Site: PB Y Pad North Reference: True Well: Y-07 Survey Calculation Method: Minimum Curvature Weilbore: Y-07A contingency Design: Y-07A wp21.A Prognosed Formation Intersection Points Measured Depth Inclination Azimuth TVD TVDSS +N/-E {ft) +E/-W (ft) (ft) (°I (°) tft) (ft) Narne 7,145.73 63.76 306.99 4,847.46 2,422.80 -3,159.36 UG1 8,182.58 64.01 305.20 5,302.46 2,982.36 -3,904.17 WS2 8,744.15 64.10 305.88 5,548.46 3,281.13 -4,311.05 WS1 9,215.92 64.18 306.90 5,754.46 3,529.64 -4,655.08 CM3 10,162.30 59.99 296.49 6,215.46 3,921.53 -5,380.80 CM2 11,533.77 59.99 296.49 6,901.46 4,451.29 -6,443.67 CM1 12,164.95 58.84 297.26 7,217.46 4,695.19 -6,932.59 THRZ 12,564.70 45.02 307.54 7,463.46 4,861.45 -7,198.31 LCU/BHRZ/TKNG 13,265.12 37.35 309.11 7,976.46 5,160.67 -7,569.14 TJF 13,427.00 34.90 309.55 8,108.46 5,220.21 -7,641.46 TJE 13,787.89 34.90 309.55 8,404,46 5,351.68 -7,800.66 TJD 14,018.33 34.90 309.55 8,593.46 5,435.62 -7,902.31 TJC 14,187.80 34.90 309.55 8,732.46 5,497.36 -7,977.07 TJB 14,393.85 34.90 309.55 8,901.46 5,572.42 -8,067.97 TSGR 14,425.55 34.90 309.55 8,927.46 5,583.97 -8,081.95 TSHU 14,530.41 34.90 309.55 9,013.46 5,622.17 -8,128.20 TSAR 14,554.79 34.90 309.55 9,033.46 5,631.05 -8,138.96 POWC 14,579.18 34.90 309.55 9,053.46 5,639.93 -8,149.72 Top HOT Plan Annotations Measured Vertical Local. Coordinates Depth Depth +~N/-S +E/-W Comment {fU {ftl {~) (ft) 9,300.00 5,790.99 3,574,58 -4,716.03 Start Dir 2°/100' :9300' MD, 5790.99'TVD :150° LT TF 9,310.00 5,795.36 3,579.68 -4,723.44 Start Dir 4°/100' :9310' MD, 5795.36'TVD 9,315.42 5,797.73 3,582.43 -4,727.46 End Dir :9513.42' MD, 5890.89' TVD 12,131.78 7,200.58 4,682.28 -6,907.12 Start Dir 4°/100' :12131.78' MD, 7200.58'TVD 12,609.43 7,495.49 4,880.77 -7,222.83 End Dir :12609.43' MD, 7495.49' TVD 13,110.69 7,858.97 5,097.70 -7,491.31 Start Dir 4°/100' :13110.69' MD, 7858.97'TVD 13,326.71 8,026.21 5,183.67 -7,597.22 End Dir :13326.71' MD, 8026.2' TVD 14,682.00 9,137.79 5,677.39 -8,195.07 Total Depth :14682.81' MD, 9138.46' TVD 1/19/2008 10:17:11AM Page 10 of 10 COMPASS 2003.11 Build 48 REFERENCE INFORMATION gNTI-COLL ISION SE'f'CINGS Coordinate (NIE) Reference: Well Centre. Y-07, True NorN VerticallND1 Reference: Y-07A plan 78.48 $eCtiM (VSI Reference: Sbt-10 OON,e.OOE) 111(Cr olation \lethod:.'11D p Intrrval: 25.00 " ' Maaaured OepNi Referanu: Y-07A plan 7e <e Uepih Range From: 9300-00 0: 14682.68 1 C]kWaBan Method: MiWmum CYMNre 5laximum Range: 1665A2 Reference: Plan: Y'-07:1 ep21.,\ '~ P'rom Colour 'fu h1D _ 0 250 - Y~v ly i.,I. U.:..: w.\ y.rn tY.~•.wr?I.r.n w.t 250 -~_._.. 5UU - yam., o-,.,aruu .e•r~wr - y-„~wrsw,.,,Y--w .~i~. ,w~ 500 750 _ 750 1000 = i P,,~'iii"~i":~~ni~~wr..,w.~ 1000 .._ 1250 - Yarvw~Y'+- ~ ~ 1250 1500 iY~t ~r.\4~~~w.l - Y _ ;"""""'w'N:""'w° Y-07 (Rig Surveys Y-07A -Neil) 1500 1750 - Y:~~~V.uatW;. k~ti 0 1750 2000 2000 2050 I~I',.~ur ~,.~.•,w,r _ ~ 2050 -- 2100 =~w+"-_~UI._.,`°~w,~ 33 0 2100 2200 -- 41io>`~:ek~;,c,.w„ 97 2200 2300 - -- - r•~ awn 2300 --`-" 2400 - ;:;; ;-;;;~I•G~i':tt."~`w~ 2400 2500 - y.-,.Y-.,el.v,.,,wv 2500 2600 - y-.r n~..,f. atm~~ a,a - -f rr- si ~ 600 -- 2700 ,~rw iY_vw, >.I„o, a,.k 00 2800 = r-~~h=;;"a~l.a 96 2 0 2900 - Y-tu iY-rulll. M.~.~~Rut Y-,.,N.,,~a,.t ~ ui r 290 0 31100 Y-ai al,i.,~am - - - r.crY..~rntih,,~xuc 000 311111 - „IY„L.L,,,, a~,. v:,,~,Y.,,~~.t„o, a„~ 00 32;11 3 "II 3500 - ;-:8a~~'w~~~`a,w 3S 0 3750 375 4000 900 4200 9200 4300 94 4300 4400 4900 4500 0 270 4600 4600 4700 4700 5000 5000 5500 55 ~-- 1)000 60 6500 65 7000 7 8000 00 9000 0110 9_500 25 950 9750 240 97 20 9800 00 -- 9900 900 10000 10000 10500 10500 11000 11000 11500 11500 12000 21 50 12000 12500 _ 12500 13000 13000 ---- 14000 5 14000 15000 18 15000 U WELL DETAILS Name +N/-S •i3.'-\\' Northing Fasting Latitude Longitude Slot conmANroernn.% 1'-t l7 430.33 -2808. iJ 594891658 644932.60 70`16'04268N 148"49'40 738W N A aP Ntxw n (-u1cW~u.nt Melh~d' Minimum Curv-uWre I~nur Sya7an: I.G' WSA 4:m MelMrl. TmY l-yliMcr North terror swr cY. G3lipucW+Cal®g TravrllinR ('ylinder Azimuth (I'FO+AZI) ~degl vs Centre m Centre Separation 125fUinl W'aminX MiOad-. RWu nrut SL'R\~EY PRUGRAAI Depth Fm Depth To Sun~er/Plan Tool 9300.00 14682.68 Planned: Y-Wq wp21.A V38 MWD+IFR+MS WFLLPATH DETAILS Y-O7q conWgency Para{ 1Vcllpath Rig Stwn. \'-U7A -Neil rw ua MD: 9J0U.u0 Rig: Ref. Datum: Y-07A plan 7N.46R V.Sxfion Origin Origio Starting Angle -tN/-S +FJ-W From TVD 311fi.14" 0.(MI I1.IN1 2%.511 10 -0 0 to ~ t to 21 SF('TR)N UI~:1'AII.S See MI) In A[i TVU +N'-S +1?--W Ul.c-g 7Tace VSrc Targn From Colour To M 0 250 250 500 500 750 750 - - 1000 1000 t25o 1250 1500 1500 1750 1750 2000 2000 2050 2050 --~ 200 ~lo0 2 00 2200 2300 2300 2400 2400 --- 2500 2500 2600 2600 2700 2700 2800 '_800 2900 '900 3000 3100 31 3250 325 ~ 3500 3500 3750 3750 4000 4000 4200 4200 - -~ 4300 4300 4400 4400 4500 4soo aeoo 4voo a7oo 5000 5000 90 5500 5500 -~- 6000 6000 6500 6500 7000 7000 8000 8000 9000 9000 9500 9500 9750 9750 .__ 9800 I UU II soo I 11000 I 11500 I: 12000 I: 12500 I: 13000 I~ 14000 I: 15000 0 1 97fX/.00 (r4.?3 i03.3Y 57YI.W ii74.9U -f7I6.04 O.W II.W i91G')1 Y31LL00 64.03 3114.4% 5795.]6 35811A11 ~7?iAi '.W -IiO.W 59=5.90 3 951358 i~9H '_')6.41 51{90.97 1671 _'N -01178.05 4.W -I?1.79 61045% 4 1?I31.611 59.99 '_96.4'1 TJ70.56 46%'_.?i -6'N1711N II.W 0.011 %339.4? i I_?76.18 ii.W 71NI.IXI 7?7N.46 47iY!/g -7111 i.78 3.1X1 150.?0 %460.43 Y+17A Nca~ TI Shalluu~aRn~- G 1?li(19.'_/ Oi.i2 708!M 7495.49 48%11.75 -T~~.Nl 4.011 li'_l0 N711.4% 7 131III.i6 33.3'_ 311%.94 7%%.97 51197.6N -7491.3'_ O.W 0.W 9056.'_4 % IS'4%.i6 38.IXI 3U9.W TM3.46 it i4.i'_ -75GI.ii 4.W 179.60 9146.19 Ya1~A N~~x'l''J.~ePa 9 17L'G.57 34.90 7[1955 811:b?0 5183.65 -7597.?? 3.W 174.'_1 919'_47 10 14683.66 34.W 309.55 9138.46 %77.67 4t19i 44 O.W O.W 9966.9? y{IAA Ncu'T3 TU Rn^ Travelling Cylinder Azimuth (TFO+qyi) [deg] vs Centre to Centre Separazion [IORiin] I• Halliburton Company Anticollision Report 1..~I Company: BP Amoco Date: 1/19/2008 Time: 11:09:52 Page:: 1 .Field: P-udhoe Bay Reference Site: PB YPad Co-ordinste(NEp Reference: Well: Y=07, True North Reference Well: Y-07 Verticat(TVD) Reference: Y-07A plan 78:5 Reference Wellpath: Y-07A contingency Db: Oracle GLOBAL SCAN APPLIED: All weftpaths within 200'+ 100/1000 of reference -There are Itl;fAlle"Soeells in thistitirdiipal Plan & PLANNED PROGRAM Interpolation Meth od: MD I nterval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9300.00 to 14682.68 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1665.42 ft - --- - -~__ Error Surface: Ellipse + Casing -- -- Survey Program for Definitive Wellpath -_~--- -- _~--- : Date: 1/17/2008 Validated: No Version: 0 ' Planned From To Survey Toolcode Tool Name ' ft ft 91.66 1992.78 1 : Sperry•Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 2013.00 9300.00 Rig Surveys Y-07A (2013.00-126 MWD+IFR+MS MWD +IFR + Multi Station. 9300.00 14682.68 Planned: Y-07A wp21.A V38 MWD+IFR+MS MWD +IFR + Mufti Station ~ Casing Points MD TVD Diameter Hole Size .Name ~ ft ft in - in 9300.00 5791.00 9.625 12.250 9 5/8" 114393.85 8901.57 7.000 8.500 7" i 14682.67 9138.46 4.500 6.750 4 1/2" ~~I Summary i <- - Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable I Site Well Wellpath MD MD Distance. Area Deviation Waraing ft ft ft ft ft' PB U Pad U-09 U-09 V1 Out of range PB U Pad U-10 Plan U-10A V1 Plan: U- 14580.07 13150.00 671.40 344.35 327.05 Pass: Major Risk PB Y Pad Y-04 Y-04 V1 Out of range PB Y Pad Y-05A Y-05A V1 Out of range PB Y Pad Y-05 Y-05 V1 Out of range PB Y Pad Y-06 Y-06 V1 Out of range PB Y Pad Y-06 Y-06A V6 Out of range PB Y Pad Y-06 Y-O6AP61 V4 Out of range PB Y Pad Y-07 Plan Y-07A V10 Plan: Y 9392.08 9400.00 2.13 289.14 -287.01 FAIL: Major Risk PB Y Pad Y-07 Rig Surveys Y-07A - Ne 9325.00 9325.00 0.20 258.19 -257.99 FAIL: Major Risk PB Y Pad Y-07 Y-07 V1 Out of range PB Y Pad Y-08A Y-OSA V1 Out of range PB Y Pad Y-08 Y-08 V1 Out of range PB Y Pad Y-09APB1 Y-09APBt V2 Out of range PB Y Pad Y-09A Y-09A V2 Out of range PB Y Pad Y-09 Y-09 V1 Out of range PB Y Pad Y-10 Y-10 V1 Out of range PB Y Pad Y-10 Y-10A V3 Out of range PB Y Pad Y-11 Y-11 V7 Out of range PB Y Pad Y-11 Y-11A V1 Out of range PB Y Pad Y-11 Y-11 B V3 Out of range PB Y Pad Y-11 Y-116P61 V4 Out of range PB Y Pad Y-11 Y-11C V5 Out of range PB Y Pad Y-19 Y-19 V1 Out of range PB Y Pad Y-21A Y-21A V1 Out of range PB Y Pad Y-21 Y-21 V1 Out of range PB Y Pad Y-22 Plan Y-22B V5 Out of range PB Y Pad Y-22 Y-22 V1 Out of range PB Y Pad Y-22 Y-22A VO Out of range PB Y Pad Y-23 Y-23 V7 Out of range PB Y Pad Y-23 Y-23A V4 Out of range PB Y Pad Y-23 Y-23AP61 V1 Out of range PB Y Pad Y-23 Y-23AP62 V1 Out of range PB Y Pad Y-23 Y-236 V7 13978.37 14050.00 1446.47 303.96 1142.51 Pass: Major Risk PB Y Pad Y-24 Y-24 V2 Out of range PB Y Pad Y-25 Y-25 V1 Out of range PB Y Pad Y-28 Y-28 V1 Out of range PB Y Pad Y-29A Y-29A V2 Out of range PB Y Pad Y-29 Y-29 V1 Out of range PB Y Pad Y-30 Y-30 V3 Out of range PB Y Pad Y-30 Y-30L1 V3 Out of range Halliburton Company Anticollision Report Company: BP Amoco Date: 1/19/2008 Time: 11:09;52 Page: 2 Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) .Reference: WeIIC Y-07, True North Reference Well: Y-07 Vertical (TVD) Reference: Y-07A pl an 78.5 Reference Wellpathd Y-07A contingency Db: -0raCle Summary < O ffset Wellpath -> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning j I ft ft ft ft ft_ PB Y Pad Y-31 Y-31 V4 Out of range PB Y Pad Y-32 Y-32 V7 Out of range PB Y Pad Y-32 Y-32L1 V2 i Out of range PB Y Pad Y-33 Y-33 V1 Out of range PB Y Pad Y-34A Y-34A V3 Out of range PB Y Pad Y-34 Y-34 V1 Out of range PB Y Pad Y-37 Y-37 V1 Out of range PB Y Pad Y-37 Y-37A V8 Out of range PB Y Pad Y-37 Y-37APB1 V3 .Out of range Site: PB U Pa d Well: U-10 Rale Assigned: Major Risk Wellpath: Plan U-1 0A V1 Plan: U-10A wp03 V35 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go AlMwable i MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/IISI)istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 14460.64 8956.35 11800.00 8313.54 54.46 43.61 357 47 - - 8.500 - 1650.55 267.51 1383.04 Pass 14469.60 8963.70 11825.00 8332.68 54.49 43.68 357 47 8.500 1628.53 268.48 1360.04 Pass 14478.55 8971.04 11850.00 8351.82 54.51 43.75 357 48 8.500 1606.54 269.48 1337.06 Pass 14487.51 8978.39 11875.00 8370.95 54.54 43.82 358 48 8.500 1584.59 270.49 1314.10 Pass 14496.46 8985.73 11900.00 8390.09 54.56 43.89 358 48 8.500 1562.69 271.53 1291.16 Pass 14505.42 8993.08 11925.00 8409.23 54.59 43.96 358 49 8.500 1540.82 272.59 1268.23 Pass 14514.37 9000.42 11950.00 8428.37 54.61 44.03 358 49 8.500 1519.00 273.67 1245.33 Pass 14523.33 9007.77 11975.00 8447.51 54.64 44.10 359 49 8.500 1497.22 274.77 1222.45 Pass 14532.28 9015.11 12000.00 8466.65 54.66 44.17 359 50 8.500 1475.50 275.90 1199.60 Pass 14541.24 9022.46 12025.00 8485.79 54.69 44.24 -1 50 8.500 1453.82 277.05 1176.77 Pass 14550.20 9029.80 12050.00 8504.93 54.71 44.31 0 50 8.500 1432.19 278.22 1153.97 Pass 14559.15 9037.15 12075.00 8524.07 54.74 44.38 0 51 8.500 1410.62 279.42 1131.20 Pass 14568.11 9044.49 12100.00 8543.21 54.76 44.45 1 51 8.500 1389.11 280.65 1108.46 Pass 14577.06 9051.84 12125.00 8562.35 54.79 44.52 1 51 8.500 1367.66 281.91 1085.75 Pass 14586.02 9059.18 12150.00 8581.49 54.81 44.59 1 52 8.500 1346.27 283.19 1063.08 Pass 14594.97 9066.53 12175.00 8600.62 54.84 44.66 2 52 8.500 1324.94 284.50 1040.44 Pass 14595.41 9066.88 13125.00 9049.29 54.84 48.68 37 88 6.125 672.74 344.34 328.41 Pass 14580.07 9054.30 13150.00 9047.99 54.79 48.82 39 89 6.125 671.40 344.35 327.05 Pass 14564.74 9041.73 13175.00 9046.71 54.75 48.96 40 91 6.125 672.05 344.10 327.95 Pass 14549.47 9029.20 13200.00 9045.44 54.71 49.10 42 93 6.125 674.70 343.60 331.10 Pass 14534.30 9016.76 13225.00 9044.20 54.67 49.24 44 94 6.125 679.31 342.86 336.45 Pass 14519.29 9004.45 13250.00 9042.97 54.62 49.37 45 96 6.125 685.83 342.38 343.45 Pass 14504.48 8992.31 13275.00 9041.78 54.58 49.50 47 97 6.125 694.21 341.75 352.46 Pass 14489.92 8980.37 13300.00 9040.62 54.54 49.63 48 99 6.125 704.37 340.96 363.42 Pass 14475.66 8968.67 13325.00 9039.50 54.50 49.75 50 100 6.125 716.22 340.04 376.18 Pass 14461.75 8957.26 13350.00 9038.41 54.47 49.87 51 101 6.125 729.65 339.04 390.61 Pass 14448.22 8946.16 13375.00 9037.37 54.43 49.99 52 102 6.125 744.56 337.99 406.57 Pass 14435.12 8935.42 13400.00 9036.38 54.39 50.10 53 104 6.125 760.84 336.94 423.90 Pass 14422.50 8925.07 13425.00 9035.43 54.36 50.20 54 104 6.125 778.37 335.91 442.46 Pass 14410.39 8915.14 13450.00 9034.54 54.32 50.30 55 105 6.125 797.04 334.93 462.11 Pass 14398.84 8905.66 13475.00 9033.70 54.29 50.39 56 106 6.125 816.74 334.09 482.65 Pass 14387.70 8896.53 13500.00 9032.91 54.26 50.47 56 107 6.125 837.14 333.25 503.90 Pass 14376.59 8887.42 13525.00 9032.12 54.23 50.56 57 107 6.125 857.68 332.41 525.27 Pass 14365.48 8878.30 13550.00 9031.33 54.20 50.64 57 108 6.125 878.30 331.58 546.72 Pass 14354.37 8869.19 13575.00 9030.53 54.17 50.72 58 108 6.125 899.01 330.76 568.25 Pass 14343.26 8860.08 13600.00 9029.74 54.14 50.81 58 109 6.125 919.79 329.95 589.84 Pass 14332.15 8850.96 13625.00 9028.95 54.11 50.89 59 109 6.125 940.65 329.16 611.49 Pass 14321.04 8841:85 13650.00 9028.16 54.08 50.98 59 .110 6.125 961.58 328.38 633.20 Pass 14309.93 8832.74 13675.00 9027.36 54.05 51.06 60 110 6.125 982.58 327.62 654.96 Pass REFERENCE WFORMATION .ANTI-COLL ISION SETTINGS Cocnflnah (N/EI ftahnxica: Wall Centre: Y-07. True NwM verooal (TVOlftaroranoa~. Y-07A pua, 7a.46 Section (V51 Rahranca: Slot-10 OON U.OOE Inter olatiun AlelhodcMU Y ' Interval: 25.00 Meawratl Deptllftahnr¢e: Y-07A phn 7e de rmn: 9300.00 Uepth Range F To: 14682.68 CakWatron MeawE: Minimum CurvaWre Maximum Range: 1665.42 Reference: Ylan: 1'-07A wp2l.A - reLU~w.\ ~~n.~;.w~~i~a'"w° From Coluur 'fo MD - w..r.k:.:~" U 250 - V+u iY ix 1. \I.rn w.~ ,r..r.l.., x,a 250 500 - n.VB~. M.i.,'w ~ ..... ,w, 500 750 9'ini w"°w., 750 1000 :~+Pxi"n?'~.~Iwi~...w.~w„ _ 1000 1250 _ _ : " ; : ~ 1250 1500 I ~ r ! .: - ~ ' Y-07 (Rig Sur veys Y-071- tieiq 15U0 1750 _ ;:I I h I I ~!">G;.." w , 0 175U 2000 _ .on-Ilnre i:..i.~rwa 2000 2050 - Y.11 i,'.I n-r.wl."w,~ - v.w~r.lwr el.,~~ w,, 2050 2100 - Y.-~Arc.a,u.ae~~ w,r 33 - - U 2100 2200 ,r -- `)~ 22UU -- 2300 = v~°v3°1M:"'~'w~° 230U ---- 2400 - ;;;r`s~•„.;:5"';`wx 24U0 2500 _ - °~ti;~'I,"'~:.w,. 2500 2600 - r;,;Y;;'F~:;;:x;a 600 2700 - r~-"~;Y"'a",'1"~{.",';:,.r UO 2800 = rsows~;M':;;:l~~k 96 \ 2 0 -- 2900 'M".°; x~ .,r 30 - ;~ ;YI ,~ 290 R 3000 , ;' ~,. ~,, ,L,.•, e,.l' \ - ~ `I I ). M.~.. Ni.r. ~~I,'»1. M.ior N..k ,, Y ,,~, M.,. ei., , ~ ~ ~ 3000 ~ UO 3100 3250 ,. L, , k„ ~ 3 0 3500 ", Ih ~ 35 0 3750 _ ." \ 375 4000 40U ~ 4200 42U0 4300 94 a3a x400 44U0 4500 0 27 4G1N) 46U0 4700 47011 5000 5o0U 5500 55U ~ 6000 60U 6500 65 7000 7 0 8000 00 -- 9000 000 9500 zs - 950 9750 zoo y7 '-" 9800 OU '- 9900 900 10000 IUUUU 10500 IUSUU - 11000 IIUUO 11500 11500 12000 zl ~ 12000 12500 so 125U0 13000 13000 - 14000 5 14000 15000 Ig ISUUO 0 WELL DETAILS Name +Nr-S +E,'-W Northing Easting Latitude Longitude Slot ITIMrnNYDl:rnn.s }•~7 430.33 -2808A4 59x891658 64493'_.60 70°I6'04.268N Ii8'49'a0.738W NA Nr nm,wn l'uluula6nn MCIh,YI: MilWnwnl'un alurc 1'.mrt Sv.l.rn: IS1'WSA 4;u1 M Ylael. Tra,' ('ylua4r hk,rth rrr,n swfaee: ewpue,I+raanr Travelling Cylinder Azimuth (TFO+AZq ~deg~ vs Ceo[re to Centre Separation ~25ftlin~ WerninB Mcasel: RW~+aad SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 9300.00 14682.68 Plauued: Y-07A wp21.A V38 MWD+IFR+MS WELLPATR DETAILS Y-07A contingency Parent Wellpath: Rig Surveys Y-07A -Neil Tk oo MD: 93W.W Rig: Ref. Datum: Y-07A plan 78.46R V.Sect)on OrrBiu Ongm Starting Altgk +N/-S +E/-W From TVD SIK,.l4" ILW U.W 28.50 16 0 0 10 ~ 110 " SIA'TN)N I)IiTAILS Sec MU Inc Azi M) +N:-S +1-W DLeg TFace VSec Tarry From Colour To M 0 250 250 500 500 750 750 ------ 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 2050 zoso --- zloo 2100 2zoo 2200 2300 2300 2400 2400 - 2500 2500 2600 2600 2700 2700 2800 2800 2900 '900 3000 3100 31 3250 325 0- 3500 3500 3750 3750 4000 4000 4200 4200 4300 4300 4400 x400 4500 4500 4600 4600 4700 5000 5000 90 5500 5500 + 6000 6000 6500 6500 7000 7000 - - 8000 8000 9000 9000 9500 9500 9750 9750 9800 98 l'~- 9900 0o Inn fbsoo 1 11000 I 11500 1 12000 1 Izsoo 1 13000 _.-. I 14000 I Isooo 0 1 93(q.W W?3 1U4.iY x791.1%1 5574.W -1716.04 U.W I1.UU 591 G.91 H11 U.W 64.05 104.4% i795.3G liBU.W -aT_735 ?.W -IiU.UU iH'_i.~Al 3 951358 i9.'r) 2H6.49 5%X1.97 7671.'_% 3878.n5 4.W -1'_1.79 61n358 4 1'_131.611 iH: rl '_96.x9 7111.56 4682._'5 L9UZUN o.W unu Nn9,a~ 5 I??76.58 35.1%1 3UII.W 7278.46 4719.HN -71113.7% 4.W IiU.'_II N3f~1134 t'-07n Ncw TI Siwlluxa Rn' 6 1'_WI')_'9 455? 111%94 7415A9 48%11.75 -7~"%1 4.W li'_.lU 87113% 7 131 IU.i6 43.x2 1118,94 78>8.97 5119268 -749L1'_ O.W U.UII W156. _'4 8 11'_3X.56 iB.W 1119.110 7961.46 5154.3'_ -7561.35 4.W 17H.W HI3G.19 Y-07A Ncx'T'_dctipu H 133'_6.57 14.W lU9.i5 8U'_6_'0 51%7.65 -7597.?2 4.W 174.21 919?17 IU 1368'_.6% 13:AI LIH.55 `)13%.46 %77.67 -81Hi.44 U.W OAU 9966.9'_ Ya17A Ncv~T7 TD Ret2 Travelling Cylinder Azimuth (TFO+pZI) [deg] vs Crntre to Centre Separazion [IOWin] • Halliburton Company Anticollision Report Company: BP Amoco Date: 1/19/2008 Time: 11:09:52 Page: 1 Field: Prudhoe Bay Reference Site: PB Y' Pad.. Co-ordinate(NE) Reference: WeIL Y-07, True North Reference Well: Y-07 Vertical(TVD) Reference: Y-07A plan 785 Reference Wellpath: Y-07A contingency Db: OraCle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1<i!@ipl'iceells in thisRte~Jpal Plan & PLANNED PROGRAM Interpolation Meth od: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9300.00 to 14682.68 ft Scan Method: Trav Cylinder North Maximum Radius: 1665.42 ft Error Surface: Ellipse + Casing Survey Program for Defmitive Wellpath Date: 1/17/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 91.66 1992.78 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 2013.00 9300.00 Rig Surveys Y-07A (2013.00-126 MWD+IFR+MS MWD +IFR + Multi Station 9300.00 14682.68 Planned: Y-07A wp21.A V38 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TV D Diameter Hole Size. Name ft ft in in 9300.00 5791.00 9.625 12.250 9 5/8" 14393.85 8901.57 7.000 8.500 7" 14682.67 9138.46 4.500 6.750 41/2" 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 U Pad U-09 U-09 V1 Out of range PB U Pad U-10 Plan U-10A V1 Plan: U- 14580.07 13150.00 671.40 344.35 327.05 Pass: Major Risk PB Y Pad Y-04 Y-04 V1 Out of range PB Y Pad Y-05A Y-05A V1 Out of range PB Y Pad Y-05 Y-05 V1 Out of range PB Y Pad Y-06 Y-06 V1 Out of range PB Y Pad Y-06 Y-06A V6 Out of range PB Y Pad Y-O6 Y-06AP61 V4 Out of range PB Y Pad Y-07 Plan Y-07A V10 Plan: Y 9392.08 9400.00 2.13 289.14 -287.01 FAIL: Major Risk PB Y Pad Y-07 Rig Surveys Y-07A - Ne 9325.00 9325.00 0.20 258.19 -257.99 FAIL: Major Risk PB Y Pad Y-07 Y-07 V1 Out of range PB Y Pad Y-08A Y-08A V1 Out of range PB Y Pad Y-08 Y-08 V1 Out of range PB Y Pad Y-09AP61 Y-09AP61 V2 Out of range PB Y Pad Y-09A Y-09A V2 Out of range PB Y Pad Y-09 Y-09 V1 Out of range PB Y Pad Y-10 Y-10 V1 Out of range PB Y Pad Y-10 Y-10A V3 Out of range PB Y Pad Y-11 Y-11 V7 Out of range PB Y Pad Y-11 Y-11A V1 Out of range PB Y Pad Y-11 Y-11 B V3 Out of range PB Y Pad Y-11 Y-11 BP61 V4 Out of range PB Y Pad Y-11 Y-11 C V5 Out of range PB Y Pad Y-19 Y-19 V1 Out of range PB Y Pad Y-21A Y-21A V1 Out of range PB Y Pad Y-21 Y-21 V1 Out of range PB Y Pad Y-22 Plan Y-22B V5 Out of range PB Y Pad Y-22 Y-22 V1 Out of range PB Y Pad Y-22 Y-22A VO Out of range PB Y Pad Y-23 Y-23 V7 Out of range PB Y Pad Y-23 Y-23A V4 Out of range PB Y Pad Y-23 Y-23APB1 V1 Out of range PB Y Pad Y-23 Y-23APB2 V1 Out of range PB Y Pad Y-23 Y-236 V7 13978.37 14050.00 1446.47 303.96 1142.51 Pass: Major Risk PB Y Pad Y-24 Y-24 V2 Out of range PB Y Pad Y-25 Y-25 V1 Out of range PB Y Pad Y-28 Y-28 V1 Out of range PB Y Pad Y-29A Y-29A V2 Out of range PB Y Pad Y-29 Y-29 V1 Out of range PB Y Pad Y-30 Y-30 V3 Out of range PB Y Pad Y-30 Y-30L1 V3 Out of range Halliburton Company Anticollision Report Companys BP Amaco Date: 1/19/2008. Time: 11:09:52 Page: Z Field: Prudhoe Ba y_ Reference Site: PB Y Pad Co-ordinate(NE) Reference: Well: Y-07, True North Reference. Well: Y-07 Vertical (T'YD) Reference: Y-07A plan 78.5 Reference Wellpath: Y-07A contingency Db: Oracle Summary <-------- =-- OffsetWelipath ------ -- > Reference .. Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft= ft ft PB Y Pad Y-31 Y-31 V4 Out of range PB Y Pad Y-32 Y-32 V7 Out of range PB Y Pad Y-32 Y-32L1 V2 Out of range PB Y Pad Y-33 Y-33 V1 Out of range PB Y Pad Y-34A Y-34A V3 Out of range PB Y Pad Y-34 Y-34 V1 Out of range PB Y Pad Y-37 Y-37 V1 Out of range PB Y Pad Y-37 Y-37A V8 Out of range PB Y Pad Y-37 Y-37APB1 V3 Out of range Site: PB U Pad Well: U-10 Rule Assigned: Major Risk Wellpath: Plan U-1 0A V1 Plan: U-10A wp03 V35 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 Casiag/IISDistance Area. Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 14460.64 8956. 35 11800.00 8313.54 54.46 43.61 357 47 8.500 1650.55 267.51 1383.04 Pass 14469.60 8963. 70 11825.00 8332.68 54.49 43.68 357 47 8.500 1628.53 268.48 1360.04 Pass 14478.55 8971. 04 11850.00 8351.82 54.51 43.75 357 48 8.500 1606.54 269.48 1337.06 Pass 14487.51 8978. 39 11875.00 8370.95 54.54 43.82 358 48 8.500 1584.59 270.49 1314.10 Pass 14496.46 8985. 73 11900.00 8390.09 54.56 43.89 358 48 8.500 1562.69 271.53 1291.16 Pass 14505.42 8993 .08 11925.00 8409.23 54.59 43.96 358 49 8.500 1540.82 272.59 1268.23 Pass 14514.37 9000 .42 11950.00 8428.37 54.61 44.03 358 49 8.500 1519.00 273.67 1245.33 Pass 14523.33 9007 .77 11975.00 8447.51 54.64 44.10 359 49 8.500 1497.22 274.77 1222.45 Pass 14532.28 9015 .11 12000.00 8466.65 54.66 44.17 359 50 8.500 1475.50 275.90 1199.60 Pass 14541.24 9022 .46 12025.00 8485.79 54.69 44.24 -1 50 8.500 1453.82 277.05 1176.77 Pass 14550.20 9029 .80 12050.00 8504.93 54.71 44.31 0 50 8.500 1432.19 278.22 1153.97 Pass 14559.15 9037 .15 12075.00 8524.07 54.74 44.38 0 51 8.500 1410.62 279.42 1131.20 Pass 14568.11 9044 .49 12100.00 8543.21 54.76 44.45 1 51 8.500 1389.11 280.65 1108.46 Pass 14577.06 9051 .84 12125.00 8562.35 54.79 44.52 1 51 8.500 1367.66 281.91 1085.75 Pass 14586.02 9059 .18 12150.00 8581.49 54.81 44.59 1 52 8.500 1346.27 283.19 1063.08 Pass 14594.97 9066 .53 12175.00 8600.62 54.84 44.66 2 52 8.500 1324.94 284.50 1040.44 Pass 14595.41 9066 .88 13125.00 9049.29 54.84 48.68 37 88 6.125 672.74 344.34 328.41 Pass 14580.07 9054 .30 13150.00 9047.99 54.79 48.82 39 89 6.125 671.40 344.35 327.05 Pass 14564.74 9041 .73 13175.00 9046.71 54.75 48.96 40 91 6.125 672.05 344.10 327.95 Pass 14549.47 9029 .20 13200.00 9045.44 54.71 49.10 42 93 6.125 674.70 343.60 331.10 Pass 14534.30 9016 .76 13225.00 9044.20 54.67 49.24 44 94 6.125 679.31 342.86 336.45 Pass 14519.29 9004 .45 13250.00 9042.97 54.62 49.37 45 96 6.125 685.83 342.38 343.45 Pass 14504.48 8992 .31 13275.00 9041.78 54.58 49.50 47 97 6.125 694.21 341.75 352.46 Pass 14489.92 8980 .37 13300.00 9040.62 54.54 49.63 48 99 6.125 704.37 340.96 363.42 Pass 14475.66 8968 .67 13325.00 9039.50 54.50 49.75 50 100 6.125 716.22 340.04 376.18 Pass 14461.75 8957 .26 13350.00 9038.41 54.47 49.87 51 101 6.125 729.65 339.04 390.61 Pass 14448.22 8946 .16 13375.00 9037.37 54.43 49.99 52 102 6.125 744.56 337.99 406.57 Pass 14435.12 8935 .42 13400.00 9036.38 54.39 50.10 53 104 6.125 760.84 336.94 423.90 Pass 14422.50 8925 .07 13425.00 9035.43 54.36 50.20 54 104 6.125 778.37 335.91 442.46 Pass 14410.39 8915 .14 13450.00 9034.54 54.32 50.30 55 105 6.125 797.04 334.93 462.11 Pass 14398.84 8905 .66 13475.00 9033.70 54.29 50.39 56 106 6.125 816.74 334.09 482.65 Pass 14387.70 8896 .53 13500.00 9032.91 54.26 50.47 56 107 6.125 837.14 333.25 503.90 Pass 14376.59 8887 .42 13525.00 9032.12 54.23 50.56 57 107 6.125 857.68 332.41 525.27 Pass 14365.48 8878 .30 13550.00 9031.33 54.20 50.64 57 108 6.125 878.30 331.58 546.72 Pass 14354.37 8869 .19 13575.00 9030.53 54.17 50.72 58 108 6.125 899.01 330.76 568.25 Pass 14343.26 8860 .08 13600.00 9029.74 54.14 50.81 58 109 6.125 919.79 329.95 589.84 Pass 14332.15 8850 .96 13625.00 9028.95 54.11 50.89 59 109 6.125 940.65 329.16 611.49 Pass 14321.04 8841 .85 13650.00 9028.16 54.08 50.98 59 110 6.125 961.58 328.38 633.20 Pass 14309.93 8832 .74 13675.00 9027.36 54.05 51.06 60 110 6.125 982.58 327.62 654.96 Pass Halliburton Company Anticollision Report Company: BP Amoco Date: 1/19!2008 Time: 11:09:52 Page: 3 Field: ' Prutlhoe Bay. .:Reference Site: PB Y Pad Co-ordinate(1VE) Reference: `.' Weill Y-07, True North Reference Well: Y-07 VerticaL(TVD) Reference: Y-07A plan 78.5 Reference Welipath: Y-07A contingency Db: Oracle Site: PB U Pad Well: U-10 Rule Ass igned: Major Risk Wellpath: Plan U-10A V1 Plan: U-10A wp03 V35 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/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 14298.82 8823.63 13700. 00 9026.57 54.02 51.15 60 111 6.125 1003.63 326.87 676.77 Pass 14287.74 8814.54 13725. 00 9025.85 53.99 51.24 61 111 6.125 1024.73 326.13 698.60 Pass 14276.88 8805.63 13750. 00 9025.57 53.96 51.33 61 112 6.125 1045.80 325.36 720.44 Pass 14266.28 8796.94 13775. 00 9025.80 53.93 51.43 62 112 6.125 1066.85 324.57 742.28 Pass 14255.98 8788.49 13800. 00 9026.57 53.90 51.53 62 113 6.125 1087.87 323.73 764.14 Pass 14245.98 8780.29 13825. 00 9027.86 53.87 51.64 63 113 6.125 1108.87 322.86 786.01 Pass 14236.30 8772.35 13850. 00 9029.68 53.85 51.75 63 114 6.125 1129.84 321.94 807.90 Pass 14226.90 8764.64 13875. 00 9031.99 53.82 51.86 64 114 6.125 1150.79 320.99 829.80 Pass 14217.58 8756.99 13900. 00 9034.41 53.80 51.97 64 115 6.125 1171.80 320.04 851.76 Pass 14208.25 8749.34 13925. 00 9036.83 53.77 52.08 65 115 6.125 1192.89 319.10 873.79 Pass 14198.92 8741.69 13950. 00 9039.25 53.74 52.19 65 115 6.125 1214.06 318.18 895.88 Pass 14189.59 8734.04 13975. 00 9041.67 53.72 52.30 65 116 6.125 1235.30 317.27 918.03 Pass 14180.27 8726.39 14000. 00 9044.09 53.69 52.41 66 116 6.125 1256.61 316.38 940.23 Pass 14170.94 8718.74 14025. 00 9046.51 53.67 52.52 66 117 6.125 1277.98 315.51 962.48 Pass 14161.61 8711.09 14050. 00 9048.93 53.64 52.63 67 117 6.125 1299.42 314.65 984.77 Pass 14152.28 8703.44 14075. 00 9051.35 53.62 52.74 67 117 6.125 1320.91 313.81 1007.11 Pass 14142.96 8695.79 14100. 00 9053.77 53.59 52.85 67 118 6.125 1342.47 312.98 1029.49 Pass 14133.63 8688.14 14125. 00 9056.19 53.57 52.96 68 118 6.125 1364.07 312.17 1051.90 Pass 14124.30 8680.49 14150. 00 9058.61 53.54 53.07 68 119 6.125 1385.73 311.38 1074.36 Pass 14114.97 8672.84 14175. 00 9061.02 53.52 53.18 68 119 6.125 1407.44 310.60 1096.84 Pass 14105.65 8665.19 14200 .00 9063.44 53.49 53.29 69 119 6.125 1429.19 309.83 1119.36 Pass 14096.32 8657.54 14225 .00 9065.86 53.47 53.40 69 120 1450.99 309.09 1141.91 Pass 14089.74 8652.14 14242 .64 9067.57 53.45 53.48 69 120 1466.40 308.57 1157.83 Pass Site: PB Y Pad Well: Y-07 Rule Assigned: Major Risk Welipath: Plan Y-07A V10 Plan: Y-07A WP 14.0 V64 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Co Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/EISflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9317.17 5798.50 9325 .00 5799.42 40.64 44.31 182 238 7.000 1.94 253.58 -251.64 FAIL 9342.18 5809.61 9350 .00 5810.38 40.64 44.44 165 222 7.000 1.16 209.05 -207.90 FAIL 9367.16 5820.90 9375 .00 5821.34 40.64 44.57 78 135 7.000 0.70 219.46 -218.76 FAIL 9392.08 5832.36 9400 .00 5832.30 40.64 44.69 29 88 7.000 2.13 289.14 -287.01 FAIL 9416.93 5843.99 9425 .00 5843.26 40.62 44.79 19 79 7.000 4.24 283.83 -279.59 FAIL 9441.71 5855.77 9450 .00 5854.22 40.58 44.89 14 75 7.000 6.80 279.39 -272.59 FAIL 9466.38 5867.69 9475 .00 5865.18 40.55 44.97 11 73 7.000 9.80 276.24 -266.44 FAIL 9490.95 5879.73 9500 .00 5876.14 40.52 45.05 9 72 7.000 13.23 273.88 -260.65 FAIL 9515.42 5891.89 9525 .00 5887.10 40.48 45.12 8 71 7.000 17.08 272.01 -254.93 FAIL 9540.09 5904.23 9550 .00 5898.06 40.52 45.29 7 70 7.000 21.11 271.24 -250.13 FAIL 9564.76 5916.57 9575 .00 5909.02 40.56 45.45 6 70 7.000 25.15 270.87 -245.72 FAIL 9589.43 5928.92 9600 .00 5919.98 40.60 45.62 6 69 7.000 29.18 270.75 -241.56 FAIL 9614.10 5941.26 9625 .00 5930.93 40.64 45.79 5 69 7.000 33.22 270.79 -237.56 FAIL 9638.77 5953.60 9650 .00 5941.89 40.68 45.96 5 69 7.000 37.26 270.94 -233.68 FAIL 9663.44 5965.94 9675 .00 5952.85 40.73 46.12 5 69 7.000 41.30 271.17 -229.87 FAIL 9688.12 5978.28 9700 .00 5963.81 40.77 46.29 5 68 7.000 45.34 271.46 -226.11 FAIL 9712.79 5990.62 9725 .00 5974.77 40.81 46.46 5 68 7.000 49.38 271.80 -222.41 FAIL 9737.46 6002.96 9750 .00 5985.73 40.86 46.62 5 68 7.000 53.43 272.17 -218.74 FAIL 9762.13 6015.30 9775 .00 5996.69 40.90 46.79 5 68 7.000 57.47 272.57 -215.11 FAIL 9786.80 6027.64 9800 .00 6007.65 40.94 46.96 4 68 7.000 61.51 273.00 -211.49 FAIL 9811.47 6039.98 9825 .00 6018.61 40.99 47.12 4 68 7.000 65.55 273.45 -207.89 FAIL Halliburton Company Anticollision Report Compsnyc BP Amoco Date: 1/1.9/2008 Time: :11:09:52 Pave: 4 Fields Prudhoe Bay ; Reference Site: ` PB Y Pad Co-ordinate(NE) Reference: Well: Y-07, True North Reference Well: Y-07 Ve rtical {TVD) Reference: Y-07A plan 78.5 Reference Wellpath: Y-07A contingency Db: Oracle Site: PB Y Pad Well: Y-07 Rule Ass igned: Major Risk Wellpath: Plan Y-07A V10 Plan: Y-07A WP 14. 0 V64 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MI) TV D Ref' Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft_ ft ft ft ft ft deg deg in ft` ' ft ft 9836.14 6052.32 9850.00 6029. 57 41. 04 47. 29 4 68 7.000 69.59 273.91 -204.32 FAIL 9860.81 6064.67 9875.00 6040. 53 41. 08 47. 46 4 68 7.000 73.63 274.39 -200.75 FAIL 9885.48 6077.01 9900.00 6051. 49 41. 13 47. 63 4 68 7.000 77.68 274.88 -197.20 FAIL 9910.15 6089.35 9925.00 6062. 45 41. 18 47. 79 4 68 7.000 81.72 275.38 -193.66 FAIL 9934.83 6101.69 9950.00 6073. 41 41. 23 47. 96 4 68 7.000 85.76 275.89 -190.13 FAIL 9959.50 6114.03 9975.00 6084. 36 41. 28 48. 13 4 68 7.000 89.80 276.41 -186.61 FAIL 9984.17 6126.37 10000.00 6095. 32 41. 33 48. 29 4 68 7.000 93.85 276.94 -183.09 FAIL 10008,84 6138.71 10025.00 6106. 28 41. 38 48. 46 4 68 7.000 97.89 277.47 -179.58 FAIL 10033.51 6151.05 10050.00 6117. 24 41. 43 48. 63 4 67 7.000 101.93 278.01 -176.08 FAIL 10058.18 6163.39 10075.00 6128. 20 41. 48 48. 80 4 67 7.000 105.97 278.56 -172.59 FAIL 10082.85 6175.73 10100.00 6139. 16 41. 53 48. 96 4 67 7.000 110.01 279.11 -169.10 FAIL 10107.52 6188.07 10125.00 6150. 12 41. 59 49. 13 4 67 7.000 114.06 279.67 -165.61 FAIL 10132.19 6200.41 10150.00 6161. 08 41. 64 49. 30 4 67 7.000 118.10 280.23 -162.13 FAIL 10156.86 6212.76 10175.00 6172. 04 41. 69 49. 46 4 67 7.000 122.14 280.80 -158.66 FAIL 10181.54 6225.10 10200.00 6183. 00 41. 75 49. 63 4 67 7.000 126.18 281.37 -155.18 FAIL 10206.21 6237.44 10225.00 6193. 96 41. 80 49. 80 4 67 7.000 130.23 281.94 -151.71 FAIL 10230.88 6249.78 10250.00 6204. 92 41. 86 49. 97 4 67 7.000 134.27 282.52 -148.25 FAIL 10255.55 6262.12 10275.00 6215. 88 41. 92 50. 13 4 67 7.000 138.31 283.10 -144.79 FAIL 10280.22 6274.46 10300.00 6226. 84 41. 97 50. 30 4 67 7.000 142.35 283.68 -141.33 FAIL 10304.89 6286.80 10325.00 6237. 79 42 .03 50. 47 4 67 7.000 146.40 284.27 -137.87 FAIL 10329.56 6299.14 10350.00 6248. 75 42 .09 50. 63 4 67 7.000 150.44 284.86 -134.42 FAIL 10354.25 6311.49 10375.00 6259. 88 42. 15 50. 78 4 67 7.000 154.39 285.52 -131.13 FAIL 10378.96 6323.85 10400.00 6271. 39 42. 21 50. 93 4 67 7.000 158.11 286.44 -128.33 FAIL 10403.70 6336.23 10425.00 6283. 29 42 .27 51. 05 4 68 7.000 161.61 287.54 -125.93 FAIL 10428.46 6348.61 10450.00 6295. 56 42 .33 51. 18 5 68 7.000 164.89 288.87 -123.98 FAIL 10453.22 6361.00 10475.00 6308. 22 42 .39 51. 30 5 69 7.000 167.96 290.41 -122.45 FAIL 10477.98 6373.39 10500.00 6321. 24 42 .45 51. 42 6 69 7.000 170.82 292.13 -121.31 FAIL 10502.74 6385.77 10525.00 6334. 64 42. 51 51. 54 7 70 7.000 173.50 294.01 -120.51 FAIL 10527.48 6398.14 10550.00 6348. 40 42. 57 51. 66 7 71 7.000 175.99 296.03 -120.04 FAIL 10552.20 6410.51 10575.00 6362. 52 42 .64 51. 78 8 72 7.000 178.32 298.18 -119.86 FAIL 10576.89 6422.86 10600.00 6377. 00 42 .70 51. 89 9 73 7.000 180.50 300.43 -119.93 FAIL 10601.54 6435.19 10625.00 6391. 83 42 .76 52. 00 11 74 7.000 182.55 302.73 -120.18 FAIL 10626.15 6447.50 10650.00 6407. 01 42 .83 52. 11 12 75 7.000 184.48 305.08 -120.60 FAIL 10650.70 6459.78 10675.00 6422. 53 42 .89 52 .22 13 77 7.000 186.33 307.45 -121.12 FAIL 10675.19 6472.03 10700.00 6438. 39 42 .96 52. 33 15 78 7.000 188.12 309.81 -121.69 FAIL 10699.62 6484.25 10725.00 6454. 59 43 .02 52. 43 16 80 7.000 189.87 312.09 -122.22 FAIL 10723.97 6496.43 10750.00 6471. 11 43 .09 52. 53 18 81 7.000 191.60 314.29 -122.68 FAIL 10748.25 6508.58 10775.00 6487. 96 43 .16 52. 63 19 83 7.000 193.36 316.35 -123.00 FAIL 10772.43 6520.67 10800.00 6505. 12 43 .22 52 .73 21 85 7.000 195.16 318.25 -123.09 FAIL 10796.51 6532.72 10825.00 6522. 60 43 .29 52. 83 23 87 7.000 197.05 319.92 -122.87 FAIL 10820.49 6544.71 10850.00 6540. 38 43 .35 52. 92 25 89 7.000 199.05 321.33 -122.28 FAIL 10844.42 6556.68 10875.00 6558. 32 43 .42 53. 03 27 91 7.000 201.24 322.48 -121.24 FAIL 10868.35 6568.65 10900.00 6576. 25 43 .49 53. 14 29 92 7.000 203.67 323.31 -119.64 FAIL 10892.27 6580.62 10925.00 6594. 18 43 .56 53 .27 31 94 7.000 206.32 323.88 -117.56 FAIL 10916.20 6592.59 10950.00 6612. 11 43 .63 53 .40 33 96 7.000 209.19 324.17 -114.98 FAIL 10940.13 6604.56 10975.00 6630. 04 43 .69 53 .53 34 98 7.000 212.27 324.20 -111.92 FAIL 10964.06 6616.53 11000.00 6647. 98 43 .76 53. 66 36 100 7.000 215.55 323.98 -108.43 FAIL 10987.98 6628.50 11025:00 6665. 91 43 .83 53 .79 38 101 7.000 219.02 323.54 -104.52 FAIL 11011.91 6640.47 11050.00 6683. 84 43 .90 53 .92 39 103 7.000 222.67 322.92 -100.24 FAIL 11035.84 6652.44 11075.00 6701. 77 43 .97 54 .05 41 105 7.000 226.49 322.11 -95.62 FAIL 11059.77 6664.40 11100.00 6719. 70 44 .05 54 .18 43 106 7.000 230.48 321.16 -90.68 FAIL ~~ Halliburton Company Anticollision Report C~ Company: BP Amoco Date: 1/1.9/2008 Time: 11:09:52 - Page: 5 Fields Prudhoe Bay Reference Site: PB Y Pad Co=ordinate(NE) Reference: Well: Y-07, True Nort h Reference Well:: Y-07 Vertical (TVD) Reference: Y-07A plan.78: 5. Reference Wellpath: Y-07A contingency Db: Oracle Site: PB Y Pad Well: Y-07 Rule Ass igned: Ma jor Risk Wellpath: Plan Y-07A V10 Plan: Y-07A WP 14 .0 V64 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD_ ft TVD ft' MD ft TVD ft Ref ft Offset ft TFO+AZi deg TFO-HS deg Casing/HSDistance in ft Area - ft Deviation ft 'Warning 11083. 69 6676.37 11125.00 6737.63 44. 12 54.31 44 108 7.000 234.62 320.07 -85. 44 FAIL 11107. 62 6688.34 11150.00 6755.57 44. 19 54.44 45 109 7.000 238.92 318.86 -79. 95 FAIL 11131. 55 6700.31 11175.00 6773.50 44 .26 54.57 47 110 7.000 243.35 317.56 -74. 21 FAIL 11155. 48 6712.28 11200.00 6791.43 44 .34 54.70 48 112 7.000 247.91 316.18 -68. 27 FAIL 11179. 40 6724.25 11225.00 6809.36 44 .41 54.83 49 113 7.000 252.60 314.73 -62. 13 FAIL 11203. 33 6736.22 11250.00 6827.29 44 .48 54.96 51 114 7.000 257.41 313.22 -55. 81 FAIL 11227. 26 6748.19 11275.00 fi845.23 44. 56 55.09 52 115 7.000 262.33 311.67 -49. 35 FAIL 11251. 19 6760.16 11300.00 6863.16 44 .63 55.22 53 116 7.000 267.35 310.09 -42. 74 FAIL 11275. 12 6772.13 11325.00 6881.09 44 .71 55.35 54 118 7.000 272.48 308.49 -36. 01 FAIL 11299. 04 6784.09 11350.00 6899.02 44 .78 55.48 55 119 7.000 277.70 306.87 -29. 17 FAIL 11322. 97 6796.06 11375.00 6916.95 44 .86 55.61 56 120 7.000 283.01 305.25 -22. 24 FAIL 11346. 90 6808.03 11400.00 6934.88 44 .94 55.75 57 121 7.000 288.40 303.62 -15. 22 FAIL 11370. 83 6820.00 11425.00 6952.82 45 .01 55.88 58 121 7.000 293.87 302.00 -8. 13 FAIL 11394. 75 6831.97 11450.00 6970.75 45 .09 56.01 59 122 7.000 299.42 300.38 -0. 96 FAIL 11418. 68 6843.94 11475.00 6988.68 45 .17 56.14 60 123 7.000 305.04 298.79 6. 25 Pass 11442. 61 6855.91 11500.00 7006.61 45 .25 56.27 61 124 7.000 310.72 297.20 13. 52 Pass 11466. 54 6867.88 11525.00 7024.54 45 .33 56.40 61 125 7.000 316.47 295.64 20. 83 Pass 11490. 46 6879.85 11550.00 7042.48 45 .40 56.53 62 126 7.000 322.28 294.10 28. 18 Pass 11514. 39 6891.82 11575.00 7060.41 45 .48 56.66 63 126 7.000 328.15 292.59 35. 56 Pass 11538. 32 6903.78 11600.00 7078.34 45 .56 56.79 64 127 7.000 334.07 291.10 42. 97 Pass 11562. 25 6915.75 11625.00 7096.27 45 .64 56.92 64 128 7.000 340.04 289.64 50. 41 Pass 11586. 17 6927.72 11650.00 7114.20 45 .72 57.05 65 128 7.000 346.06 288.21 57. 86 Pass 11610. 10 6939.69 11675.00 7132.13 45 .81 57.18 66 129 7.000 352.13 286.80 65. 33 Pass 11634. 03 6951.66 11700.00 7150.07 45 .89 57.31 66 130 7.000 358.24 285.43 72. 81 Pass 11657. 96 6963.63 11725.00 7168.00 45 .97 57.44 67 130 7.000 364.39 284.09 80. 30 Pass 11681. 88 6975.60 11750.00 7185.93 46 .05 57.57 67 131 7.000 370.59 282.78 87. 81 Pass 11705. 81 6987.57 11775.00 7203.86 46 .13 57.70 68 132 7.000 376.81 281.50 95. 32 Pass 11729. 74 6999.54 11800.00 7221.79 46 .22 57.83 69 132 7.000 383.08 280.25 102. 83 Pass 11753. 67 7011.51 11825.00 7239.73 46 .30 57.96 69 133 7.000 389.38 279.03 110. 34 Pass 11777. 60 7023.48 11850.00 7257.66 46 .39 58.10 70 133 7.000 395.71 277.85 117. 86 Pass 11801. 52 7035.44 11875.00 7275.59 46 .47 58.23 70 134 7.000 402.07 276.69 125. 38 Pass 11825. 45 7047.41 11900.00 7293.52 46 .55 58.36 71 134 7.000 408.46 275.56 132. 90 Pass 11849. 38 7059.38 11925.00 7311.45 46 .64 58.49 71 135 7.000 414.88 274.47 140. 42 Pass 11873. 31 7071.35 11950.00 7329.38 46 .73 58.62 71 135 7.000 421.33 273.40 147. 93 Pass 11897. 23 7083.32 11975.00 7347.32 46 .81 58.75 72 135 7.000 427.80 272.36 155. 44 Pass 11921. 16 7095.29 12000.00 7365.25 46 .90 58.88 72 136 7.000 434.29 271.35 162. 95 Pass 11945. 09 7107.26 12025.00 7383.18 46 .98 59.01 73 136 7.000 440.81 270.37 170. 45 Pass 11969. 02 7119.23 12050.00 7401.11 47 .07 59.14 73 137 7.000 447.36 269.41 177. 95 Pass 11992. 94 7131.20 12075.00 7419.04 47 .16 59.27 74 137 7,000 453.92 268.48 185. 44 Pass 12016. 87 7143.17 12100.00 7436.98 47 .25 59.40 74 137 7,000 460.50 267.58 192. 92 Pass 12040. 80 7155.13 12125.00 7454.91 47 .33 59.53 74 138 7,000 467.10 266.70 200. 40 Pass 12064. 73 7167.10 12150.00 7472.84 47 .42 59.66 75 138 7.000 473.73 265.85 207. 88 Pass 12088. 65 7179.07 12175.00 7490.77 47 .51 59.80 75 139 7.000 480.36 265.02 215. 35 Pass 12112. 58 7191.04 12200.00 7508.70 47 .60 59.93 75 139 7.000 487.02 264.21 222. 81 Pass 12139. 02 7204.28 12225.00 7526.63 47 .71 60.08 76 139 7.000 493.68 263.65 230. 03 Pass 12175. 50 7223.02 12250.00 7544.57 47 .91 60.33 76 139 7.000 499.95 264.00 235. 95 Pass 12212. 47 7242.70 12275.00 7562.50 48 .10 60.57 77 139 7.000 505.62 264.34 241. 28 Pass 12249. 90 7263.33 12300.00 7580.43 48 .28 60.80 78 139 7.000 510.69 264.59 246. 10 Pass 12287. 65 .7284.84 12325.00 7598.36 48 .45 61.02 79 138 7.000 515.13 264.84 250. 29 Pass 12325. 56 7307.16 12350.00 7616:29 48 .59 61.21 79 138 7.000 518.95 264.93 254. 03 Pass 12363. 79 7330.38 12375.00 7634.23 48 .74 61.40 80 138 7.000 522.15 265.02 257. 12 Pass Halliburton Company Anticollision Report Company: BP Amoco Date: 1/1912008. Time: 11:09:52 Page: 6 Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: Well: Y-07, True North Reference Well: Y-07 Vertical (TVD) Reference: Y-07A plan 78,5 Reference Wellpath: Y-07A contingency Db: Oracle. Site: PB Y Pad Well: Y-07 Rule Assigned: Major Risk Wellpath: Plan Y-07A V10 Plan: Y-07A WP 14 .0 V64 Inter-Site Error: 0.00 ft Reference Otfset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref t7ffset TFO+AZf TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg.. ..deg in ft ft ft 12402.28 7354.47 12400.00 7652.16 48. 88 61.58 80 137 7.000 524. 70 265.17 259.53 Pass 12440.99 7379.39 12425.00 7670.09 48. 99 61.75 81 137 7.000 526. 61 265.08 261.53 Pass 12479.86 7405.11 12450.00 7688.02 49 .11 61.91 81 136 7.000 527. 86 265.07 262.80 Pass 12518.83 7431.57 12475.00 7705.95 49 .21 62.05 82 136 7.000 528. 46 264.94 263.52 Pass 12557.85 7458.72 12500.00 7723.88 49 .30 62.19 82 135 7.000 528. 40 264.69 263.71 Pass 12596.85 7486.50 12525.00 7741.82 49 .38 62.31 83 134 7.000 527. 68 264.53 263.15 Pass 12626.28 7507.80 12550.00 7759.75 49 .46 62.44 83 134 7.000 526. 45 264.51 261.94 Pass 12651.23 7525.90 12575.00 7777.68 49 .53 62.57 83 134 7.000 525. 18 264.52 260.66 Pass 12676.18 7543.99 12600.00 7795.61 49 .60 62.70 83 134 7.000 523. 92 264.53 259.39 Pass 12701.13 7562.08 12625.00 7813.54 49 .67 62.83 83 134 7.000 522. 66 264.54 258.12 Pass 12726.09 7580.18 12650.00 7831.48 49 .74 62.96 83 134 7.000 521. 40 264.55 256.85 Pass 12751.04 7598.27 12675.00 7849.41 49 .82 63.09 83 135 7.000 520. 15 264.57 255.58 Pass 12775.99 7616.36 12700.00 7867.34 49 .89 63.23 84 135 7.000 518. 89 264.57 254.32 Pass 12800.94 7634.46 12725.00 7885.27 49 .97 63.36 84 135 7.000 517. 64 264.58 253.06 Pass 12825.89 7652.55 12750.00 7903.20 50 .05 63.49 84 135 7.000 516. 38 264.58 251.81 Pass 12850.85 7670.64 12775.00 7921.14 50 .12 63.62 84 135 7'000 515 .13 264.58 250.56 Pass 12875.80 7688.74 12800.00 7939.07 50 .20 63.75 84 135 7.000 513 .88 264.57 249.31 Pass 12900.75 7706.83 12825.00 7957.00 50 .28 63.88 84 135 7.000 512 .64 264.56 248.08 Pass 12925.70 7724.93 12850.00 7974.93 50 .35 64.02 84 135 7.000 511 .39 264.55 246.84 Pass 12950.65 7743.02 12875.00 7992.86 50 .43 64.15 84 135 7.000 510 .15 264.53 245.62 Pass 12975.60 7761.11 12900.00 8010.79 50 .51 64.28 84 135 7.000 508 .90 264.51 244.39 Pass 13000.56 7779.21 12925.00 8028.73 50 .59 64.41 84 136 7.000 507 .66 264.49 243.18 Pass 13025.51 7797.30 12950.00 8046.66 50 .66 64.54 85 136 7.000 506 .43 264.46 241.97 Pass 13050.46 7815.39 12975.00 8064.59 50 .74 64.67 85 136 7.000 505 .19 264.43 240.76 Pass 13075.41 7833.49 13000.00 8082.52 50 .82 64.81 85 136 7.000 503 .95 264.39 239.56 Pass 13100.36 7851.58 13025.00 8100.45 50 .90 64.94 85 136 7.000 502 .72 264.35 238.37 Pass 13130.34 7873.41 13050.00 8118.39 50 .99 65.07 85 136 7.000 501 .41 264.20 237.21 Pass 13163.74 7898.21 13075.00 8136.32 51 .08 65.20 85 136 7.000 499 .72 264.13 235.59 Pass 13197.07 7923.47 13100.00 8154.25 51 .18 65.34 85 136 7.000 497 .61 264.26 233.35 Pass 13230.30 7949.14 13125.00 8172.18 51 .26 65.47 85 136 7.000 495 .08 264.55 230.52 Pass 13263.80 7975.52 13150.00 8190.11 51 .34 65.60 85 136 7.000 492 .12 265.03 227.10 Pass 13297.64 8002.64 13175.00 8208.04 51 .41 65.73 85 136 7.000 488 .72 265.68 223.03 Pass 13330.00 8029.02 13200.00 8225.98 51 .48 65.87 85 135 7.000 484 .86 266.55 218.31 Pass 13354.63 8049.22 13225.00 8243.91 51 .54 66.00 85 135 7.000 480 .84 267.73 213.11 Pass 13379.25 8069.41 13250.00 8261.84 51 .59 66.13 84 135 7.000 476 .83 268.93 207.90 Pass 13403.88 8089.61 13275.00 8279.77 51 .65 66.26 84 135 7.000 472 .83 270.14 202.68 Pass 13428.50 8109.81 13300.00 8297.70 51 .72 66.39 84 134 7.000 468 .82 271.38 197.44 Pass 13453.13 8130.00 13325.00 8315.64 51 .78 66.53 84 134 7.000 464 .83 272.64 192.19 Pass 13477.75 8150.20 13350.00 8333.57 51 .84 66.66 84 134 7.000 460 .84 273.91 186.93 Pass 13502.38 8170.40 13375.00 8351.50 51 .90 66.79 83 134 7.000 456 .86 275.20 181.66 Pass 13527.00 8190.60 13400.00 8369.43 51 .97 66.92 83 134 7.000 452 .88 276.50 176.37 Pass 13551.63 8210.79 13425.00 8387.36 52 .03 67.05 83 133 7.000 448 .91 277.82 171.08 Pass 13576.25 8230.99 13450.00 8405.29 52 .09 67.18 83 133 7.000 444 .94 279.16 165.78 Pass 13600.88 8251.19 13475.00 8423.23 52 .16 67.32 83 133 7.000 440 .98 280.52 160.47 Pass 13625.50 8271.38 13500.00 8441.16 52 .22 67.45 82 133 7.000 437 .03 281.89 155.14 Pass 13650.13 8291.58 13525.00 8459.09 52 .29 67.58 82 133 7.000 433 .09 283.28 149.80 Pass 13674.75 8311.78 13550.00 8477.02 52 .35 67.71 82 132 7.000 429 .15 284.69 144.46 Pass 13699.38 8331.97 13575.00 8494.95 52 .41 67.84 82 132 7.000 425 .22 286.12 139.10 Pass 13724.00 8352.17 13600.00 8512.89 52 .48 67.98 81 132 7.000 421 .29 287.57 133.73 Pass 13748.63 8372.37 13625.00 8530.82 52 .54 68.11 81 132 7.000 417 .38 289.04 128.34 Pass 13773.25 8392.56 13650.00 8548.75 52 .61 68.24 81 131 7.000 413 .47 290.52 122.95 Pass i • Halliburton Company Anticollision Report Company: BP Amoco Date: 1/19!2008 Time: 11:09:52 Page: 7 Field: Prudhoe Bay : Reference Site: PB Y Pad Go-ordinate(NE) Reference: Well: Y-07, True Nort h Reference Well: Y-07 Vertical (TVD) Reference: Y-07A plan 78.5 Reference Wellpath: Y-07A confingenCy Db: Oracle Site: PB Y Pad Well: Y-07 Rule Ass igned: Major Risk Wellpath: Plan Y-0 7A V10 Plan: Y-07A WP 14. 0 V64 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Anus Ctr-Gtr' No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casmg/HSDistance Area ' Deviation Warning __ft ft ft ft ft ft deg deg in ft ft ft 13797.87 8412.76 13675.00 8566.68 52. 67 68. 37 81 131 7.000 409.57 292.03 117.54 Pass 13822.50 8432.96 13700.00 8584.61 52. 74 68. 51 80 131 7.000 405.68 293.56 112.13 Pass 13847.12 8453.15 13725.00 8602.54 52. 80 68. 64 80 131 7.000 401.80 295.11 106.70 Pass 13871.75 8473.35 13750.00 8620.48 52. 87 68. 77 80 130 7.000 397.93 296.67 101.25 Pass 13896.37 8493.55 13775.00 8638.41 52. 93 68. 90 80 130 7.000 394.06 298.27 95.80 Pass 13921.00 8513.74 13800.00 8656.34 53. 00 69. 03 79 130 7.000 390.21 299.88 90.33 Pass 13945.62 8533.94 13825.00 8674.27 53. 06 69. 17 79 129 7.000 386.37 301.51 84.85 Pass 13970.25 8554.14 13850.00 8692.20 53. 13 69. 30 79 129 7.000 382.53 303.17 79.36 Pass 13994.87 8574.34 13875.00 8710.14 53. 19 69. 43 78 129 7.000 378.71 304.85 73.85 Pass 14019.50 8594.53 13900.00 8728.07 53. 26 69. 56 78 129 7.000 374.89 306.56 68.34 Pass 14044.12 8614.73 13925.00 8746.00 53. 33 89. 69 78 128 7.000 371.09 308.28 62.81 Pass 14068.75 8634.93 13950.00 8763.93 53. 39 69. 83 77 128 7.000 367.30 310.04 57.26 Pass 14093.37 8655.12 13975.00 8781.86 53. 46 69. 96 77 128 7.000 363.52 311.81 51.71 Pass 14118.00 8675.32 14000.00 8799.79 53. 53 70. 09 77 127 7.000 359.75 313.61 46.14 Pass 14142.62 8695.52 14025.00 8817.73 53. 59 70. 22 76 127 7.000 356.00 315.44 40.56 Pass 14167.25 8715.71 14050.00 8835.66 53. 66 70. 36 76 127 7.000 352.26 317.29 34.97 Pass 14191.87 8735.91 14075.00 8853.59 53. 73 70. 49 76 126 7.000 348.53 319.16 29.36 Pass 14216.50 8756.11 14100.00 8871.52 53. 79 70. 62 75 126 7.000 344.81 321.07 23.74 Pass 14241.12 8776.30 14125.00 8889.45 53. 86 70. 75 75 125 4.500 341.11 322.89 18.22 Pass 14265.75 8796.50 14150.00 8907.39 53. 93 70. 88 75 125 4.500 337.42 324.85 12.58 Pass 14290.37 8816.70 14175.00 8925.32 53. 99 71. 02 74 125 4.500 333.75 326.83 6.92 Pass 14314.99 8836.89 14200.00 8943.25 54. 06 71. 15 74 124 4.500 330.10 328.84 1.26 Pass 14339.62 8857.09 14225.00 8961.18 54. 13 71. 28 73 124 4.500 326.46 330.87 -4.42 FAIL 14364.24 8877.29 14250.00 8979.11 54. 20 71. 41 73 123 4.500 322.83 332.94 -10.10 FAIL 14388.87 8897.48 14275.00 8997.04 54. 26 71. 55 73 123 4.500 319.23 335.03 -15.80 FAIL 14413.49 8917.68 14300.00 9014.98 54. 33 71. 68 72 123 4.500 315.64 337.07 -21.43 FAIL 14438.12 8937.88 14325.00 9032.91 54. 40 71. 81 72 122 4.500 312.07 339.22 -27.15 FAIL 14462.74 8958.08 14350.00 9050.84 54. 47 71. 94 71 122 4.500 308.52 341.39 -32.87 FAIL 14487.37 8978.27 14375.00 9068.77 54. 54 72. 07 71 121 4.500 304.99 343.59 -38.60 FAIL 14511.99 8998.47 14400.00 9086.70 54. 60 72. 21 70 121 4.500 301.48 345.81 -44.34 FAIL 14536.62 9018.67 14425.00 9104.64 54. 67 72. 34 70 120 4.500 297.99 348.07 -50.08 FAIL 14554.23 9033.11 14442.88 9117.46 54. 72 72. 43 69 120 4.500 295.50 349.69 -54.19 FAIL Site: PB Y Pad Well: Y-07 Rule Ass igned: Major Risk Wellpath: Rig Surveys Y-07A -Neil V8 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/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft' 9300.00 5791.00 9300.00 5791.00 40. 61 40. 61 305 0 9.625 0.00 181.89 -181.89 FAIL 9325.00 5801.96 9325.00 5801.89 40. 64 40. 75 237 293 7.000 0.20 258.19 -257.99 FAIL 9350.00 5813.12 9350.00 5812.87 40. 64 40. 87 299 356 7.000 0.28 89.38 -89.10 FAIL 9374.98 5824.48 9375.00 5823.97 40. 64 40. 99 350 48 7.000 0.86 216.59 -215.74 FAIL 9399.93 5836.02 9400.00 5835.17 40. 64 41. 09 3 62 7.000 2.02 248.59 -246.57 FAIL 9424.82 5847.72 9425.00 5846.45 40. 61 41. 18 7 67 7.000 3.70 257.48 -253.79 FAIL 9449.65 5859.58 9450.00 5857.74 40. 57 41. 26 8 69 7.000 5.82 259.95 -254.13 FAIL 9474.39 5871.59 9475.00 5869.06 40. 54 41 .33 8 70 7.000 8.39 260.62 -252.23 FAIL 9499.04 5883.73 9500.00 5880.39 40. 51 41 .39 7 70 7.000 11.41 260.64 -249.24 FAIL 9523.64 5896.01 9525.00 5891.62 40. 49 41 .49 7 70 7.000 15.09 260.54 -245.44 FAIL 9548.26 5908.32 9550.00 5902.64 40. 53 41 .64 7 70 7.000 19.43 260.86 -241.42 FAIL 9572.77 5920.58 9575.00 5913.43 40 .57 41 .80 7 70 7.000 24.35 261.25 -236.90 FA-L Halliburton Company Anticollision Report • Company; BP Amoco Date: 1/19/2008 , Time: 11:09:52 Page: R Field: Prudhoe Bay Reference Sites PB Y Pad Co-ordinate(NE) Reference: Well: Y-07, True Nort h Reference Well: Y-07 Vertical (1'VD) References: Y-07A plan 78.5 .Reference Wellpath: Y-07A contingency Db: OraCle Site: PB Y Pad Well: Y-07 Rule Assigned: Major Risk Wellpath: Rig S urveys Y-07A - Neil V8 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TV D MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area' Deviation Warning ft ft ft ft ft ft deg deg. in ft ft ft 9597.17 5932. 78 9600.00 5924.00 40. 61 41. 95 7 70 7.000 29.83 261.68 -231.85 FAIL 9621.53 5944. 97 9625.00 5934.44 40. 65 42. 10 6 70 7.000 35.45 261.93 -226.48 FAIL 9645.90 5957. 16 9650.00 5944.80 40. 70 42. 26 6 70 7.000 41.03 261.97 -220.94 FAIL 9670.27 5969. 35 9675.00 5955.08 40. 74 42. 41 6 69 7.000 46.57 261.87 -215.31 FAIL 9694.66 5981. 55 9700.00 5965.30 40. 78 42. 57 5 69 7.000 52.04 261.71 -209.67 FAIL 9719.12 5993. 79 9725.00 5975.69 40. 82 42. 72 5 69 7.000 57.22 261.76 -204.54 FAIL 9743.64 6006. 06 9750.00 5986.28 40. 87 42. 88 5 68 7.000 62.07 262.02 -199.95 FAIL 9768.23 6018. 36 9775.00 5997.08 40. 91 43. 03 5 68 7.000 66.58 262.44 -195.86 FAIL 9792.88 6030. 68 9800.00 6007.98 40. 96 43. 19 5 68 7.000 70.76 262.84 -192.08 FAIL 9817.58 6043. 04 9825.00 6018.76 41. 00 43. 35 4 68 7.000 74.62 262.81 -188.20 FAIL 9842.31 6055. 41 9850.00 6029.38 41. 05 43. 51 4 67 7.000 78.16 262.37 -184.21 FAIL 9867.08 6067. 80 9875.00 6039.84 41. 10 43. 66 3 67 7.000 81.41 261.53 -180.12 FAIL 9891.87 6080. 20 9900.00 6050.28 41. 14 43. 82 2 66 7.000 84.42 260.55 -176.13 FAIL 9916.69 6092. 62 9925.00 6060.88 41. 19 43. 98 2 65 7.000 87.26 259.79 -172.53 FAIL 9941.53 6105. 04 9950.00 6071.66 41. 24 44. 13 1 65 7.000 89.93 259.23 -169.30 FAIL 9966.40 6117. 48 9975.00 6082.60 41. 29 44. 29 1 64 7.000 92.43 258.86 -166.42 FAIL 9991.26 6129. 92 10000.00 6093.62 41. 34 44. 45 0 64 7.000 94.93 258.63 -163.70 FAIL 10016.12 6142. 35 10025.00 6104.66 41. 39 44. 60 0 63 7.000 97.54 258.55 -161.01 FAIL 10040.97 6154. 78 10050.00 6115.72 41. 45 44. 75 0 63 7.000 100.25 258.59 -158.35 FAIL 10065.81 6167. 21 10075.00 6126.81 41. 50 44. 91 0 63 7.000 103.06 258.77 -155.71 FAIL 10090.64 6179. 63 10100.00 6137.90 41. 55 45. 06 -1 63 7.000 105.98 259.04 -153.06 FAIL 10115.45 6192. 04 10125.00 6148.99 41. 60 45 .22 359 63 7.000 109.02 259.41 -150.39 FAIL 10140.25 6204. 45 10150.00 6160.09 41. 66 45 .37 359 63 7.000 112.17 259.87 -147.71 FAIL 10165.04 6216. 85 10175.00 6171.19 41. 71 45 .53 359 63 7.000 115.40 260.40 -145.00 FAIL 10189.84 6229. 25 10200.00 6182.26 41. 77 45. 69 359 63 7.000 118.58 260.86 -142.28 FAIL 10214.64 6241. 66 10225.00 6193.30 41. 82 45. 84 359 63 7.000 121.69 261.25 -139.56 FAIL 10239.46 6254. 07 10250.00 6204.32 41. 88 46. 00 359 63 7.000 124.73 261.57 -136.84 FAIL 10264.27 6266. 48 10275.00 6215.33 41. 94 46. 16 359 62 7.000 127.79 261.90 -134.10 FAIL 10289.05 6278. 88 10300.00 6226.35 41. 99 46 .31 359 62 7.000 131.11 262.40 -131.29 FAIL 10313.79 6291. 25 10325.00 6237.39 42. 05 46 .47 359 62 7.000 134.70 263.09 -128.40 FAIL 10338.49 6303. 61 10350.00 6248.44 42. 11 46 .63 359 63 7.000 138.55 263.95 -125.40 FAIL 10363.15 6315. 94 10375.00 6259.53 42. 17 46 .78 359 63 7.000 142.64 264.95 -122.32 FAIL 10387.77 6328. 26 10400.00 6270.69 42. 23 46 .93 0 63 7.000 146.90 266.10 -119.21 FAIL 10412.36 6340. 56 10425.00 6281.92 42. 29 47 .08 0 63 7.000 151.33 267.39 -116.06 FAIL 10436.91 6352. 84 10450.00 6293.22 42. 35 47 .23 0 64 7.000 155.94 268.79 -112.85 FAIL 10461.48 6365. 13 10475.00 6304.90 42. 41 47 .38 1 64 7.000 160.35 270.41 -110.06 FAIL 10486.09 6377. 44 10500.00 6317.10 42. 47 47 .52 1 65 7.000 164.37 272.30 -107.93 FAIL 10510.73 6389. 76 10525.00 6329.82 42. 53 47 .67 2 66 7.000 168.02 274.44 -106.42 FAIL 10535.38 6402. 09 10550.00 6343.02 42. 59 47 .81 3 67 7.000 171.30 276.77 -105.47 FAIL 10560.07 6414. 45 10575.00 6356.54 42. 66 47 .95 4 67 7.000 174.13 279.09 -104.96 FAIL 10584.81 6426. 82 10600.00 6370.33 42. 72 48 .09 5 68 7.000 176.50 281.39 -104.89 FAIL 10609.58 6439. 21 10625.00 6384.38 42. 78 48 .23 6 69 7.000 178.41 283.67 -105.26 FAIL 10634.35 6451. 60 10650.00 6398.75 42. 85 48 .37 7 70 7.000 179.94 285.98 -106.04 FAIL 10659.07 6463. 97 10675.00 6413.55 42. 92 48 .50 8 71 7.000 181.31 288.46 -107.15 FAIL 10683.73 6476. 30 10700.00 6428.78 42. 98 48 .63 9 73 7.000 182.56 291.09 -108.53 FAIL 10708.31 6488. 60 10725.00 6444.43 43. 05 48 .76 10 74 7.000 183.72 293.83 -110.10 FAIL 10732.81 6500. 85 10750.00 6460.51 43. 11 48 .88 12 75 7.000 184.81 296.60 -111.79 FAIL 10757.20 6513. 06 10775.00 6477.01 43. 18 49 .00 14 77 7.000 185.83 299.38 -113.55 FAIL 10781.49 6525 .20 10800.00 6493.93 43 .25 49 .12 15 79 7.000 186.83 302.12 -115.29 FAIL 10805.65 6537 .29 10825.00 6511.26 43 .31 49 .23 17 81 7.000 187.85 304.75 -116.90 FAIL 10829.71 6549 .33 10850.00 6528.84 43 .38 49 .34 19 83 7.000 189.14 307.15 -118.01 FAIL i Halliburton Company Anticollision Report Company: BP Amoco Date: 1/19/2008 Tune: 11:09:52 Page: 9 Field:. Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: Well: Y-07, True North Reference Well: Y-07 Vertical (TVD) Reference: Y-07A plan 78.5 Reference Wellpath: Y-OZA contingency Db: Oracle Site: PB Y Pad Well: Y-07 Rule Assigned: Major Risk Wellpath: Rig Surveys Y-07A - Neil V8 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Co Allowable MD TV D MD TVD Ref- Offset ` TFO+AZI TFO-HS Casng/HSflistance Area - Deviation Warning ft ft ft ft ft_ ft deg deg in ft ft ft 10853.70 6561. 32 10875.00 6546.57 43.45 49. 45 21 85 7.000 190.84 309.26 -118.42 FAIL 10877.60 6573. 28 10900.00 6564.46 43.52 49. 56 23 87 7.000 192.97 311.04 -118.07 FAIL 10901.41 6585. 19 10925.00 6582.49 43.58 49. 67 26 89 7.000 195.53 312.47 -116.94 FAIL 10925.15 6597. 07 10950.00 6600.67 43.65 49. 77 28 91 7.000 198.42 313.54 -115.11 FAIL 10948.83 6608. 91 10975.00 6619.00 43.72 49. 88 30 93 7.000 201.61 314.24 -112.63 FAIL 10972.43 6620. 72 11000.00 6637.48 43.79 49. 98 32 95 7.000 205.10 314.57 -109.47 FAIL 10995.99 6632. 50 11025.00 6656.07 43.86 50. 09 34 97 7.000 208.86 314.56 -105.70 FAIL 11019.60 6644. 31 11050.00 6674.63 43.93 50. 19 36 99 7.000 212.57 314.23 -101.66 FAIL 11043.27 6656. 15 11075.00 6693.14 44.00 50. 30 38 101 7.000 216.20 313.63 -97.43 FAIL 11067.01 6668. 03 11100.00 6711.60 44.07 50. 40 40 103 7.000 219.72 312.78 -93.06 FAIL 11090.82 6679. 94 11125.00 6729.95 44.14 50. 51 41 105 7.000 223.18 311.75 -88.57 FAIL 11114.71 6691. 89 11150.00 6748.11 44.21 50. 63 43 107 7.000 226.68 310.59 -83.91 FAIL 11138.70 6703. 89 11175.00 6766.08 44.28 50. 74 45 108 7.000 230.20 309.35 -79.15 FAIL 11162.84 6715. 96 11200.08 6783.89 44.36 50. 85 46 110 7.000 233.72 308.05 -74.33 FAIL 11186.83 6727. 97 11225.00 6801.57 44.43 50. 96 47 111 7.000 237.44 306.67 -69.23 FAIL 11210.83 6739. 97 11250.00 6819.44 44.51 51. 07 49 112 7.000 241.66 305.17 -63.51 FAIL 11234.73 6751. 93 11275.00 6837.45 44.58 51. 19 50 114 7.000 246.37 303.57 -57.20 FAIL 11258.55 6763. 84 11300.00 6855.59 44.66 51. 30 51 115 7.000 251.56 301.88 -50.32 FAIL 11282.27 6775. 71 11325.00 6873.87 44.73 51. 40 53 116 7.000 257.20 300.12 -42.92 FAIL 11305.90 6787. 53 11350.00 6892.28 44.80 51. 50 54 117 7.000 263.26 298.30 -35.04 FAIL 11329.43 6799. 30 11375.00 6910.83 44.88 51. 61 55 119 7.000 269.74 296.45 -26.71 FAIL 11352.88 6811. 02 11400.00 6929.47 44.96 51. 71 56 120 7.000 276.58 294.58 -18.00 FAIL 11376.37 6822. 77 11425.00 6948.08 45.03 51. 82 57 121 7.000 283.37 292.73 -9.36 FAIL 11399.93 6834. 56 11450.00 6966.60 45.11 51. 92 58 122 7.000 290.02 290.91 -0.89 FAIL 11423.55 6846. 38 11475.00 6985.04 45.18 52. 03 59 123 7.000 296.53 289.12 7.41 Pass 11447.23 6858. 22 11500.00 7003.42 45.26 52. 14 60 124 7.000 302.97 287.38 15.59 Pass 11470.89 6870. 06 11525.00 7021.74 45.34 52. 24 61 124 7.000 309.61 285.74 23.87 Pass 11494.55 6881. 89 11550.00 7040.02 45.42 52. 35 62 125 7.000 316.46 284.20 32.26 Pass 11518.19 6893. 72 11575.00 7058.26 45.50 52. 46 62 126 7.000 323.51 282.78 40.73 Pass 11541.83 6905. 54 11600.00 7076.47 45.58 52. 57 63 127 7.000 330.65 281.43 49.22 Pass 11565.47 6917. 37 11625.00 7094.70 45.65 52. 68 64 127 7.000 337.78 280.10 57.68 Pass 11589.13 6929. 20 11650.00 7112.93 45.73 52. 79 64 128 7.000 344.89 278.78 66.11 Pass 11612.80 6941. 04 11675.00 7131.16 45.81 52. 90 65 129 7.000 351.98 277.47 74.51 Pass 11636.48 6952. 89 11700.00 7149.40 45.90 53. 01 66 129 7.000 359.05 276.19 82.86 Pass 11660.17 6964. 74 11725.00 7167.63 45.98 53. 12 66 130 7.000 366.11 274.94 91.17 Pass 11683.87 6976. 59 11750.00 7185.85 46.06 53. 23 67 130 7.000 373.15 273.71 99.44 Pass 11707.59 6988. 46 11775.00 7204.06 46.14 53. 34 67 131 7.000 380.19 272.51 107.68 Pass 11731.29 7000. 31 11800.00 7222.27 46.22 53. 45 68 131 7.000 387.30 271.36 115.94 Pass 11754.98 7012. 16 11825.00 7240.49 46.31 53. 56 68 132 7.000 394.52 270.28 124.25 Pass 11778.66 7024. 01 11850.00 7258.70 46.39 53. 67 69 132 7.000 401.85 269.25 132.60 Pass 11802.33 7035. 85 11875.00 7276.89 46.47 53. 78 69 133 7.000 409.26 268.29 140.97 Pass 11826.04 7047. 71 11900:00 7294.93 46.56 53. 89 70 133 7.000 416.65 267.47 149.18 Pass 11849.79 7059. 59 11925.00 7312.81 46.64 54. 00 70 134 7.000 424.00 266.79 157.21 Pass 11873.59 7071. 50 11950.00 7330.51 46.73 54. 11 70 134 7.000 431.30 266.25 165.05 Pass 11897.42 7083. 41 11975.00 7348.16 46.81 54. 23 71 134 7.000 438.55 265.74 172.81 Pass 11921.21 7095. 32 12000.00 7366.04 46.90 54. 34 71 135 7.000 445.76 265.06 180.70 Pass 11944.97 7107. 20 12025.00 7384.17 46.98 54. 45 71 135 7.000 452.92 264.20 188.72 Pass 11968.67 7119. 06 12050.00 7402.54 47.07 54. 56 72 135 7.000 460.05 263.16 196.89 Pass 11992.37 7130. 91 12075.00 7421.01 47.16 54. 66 72 136 7.000 467.09 262.02 205.07 Pass 12016.11 7142. 78 12100.00 7439.43 47.24 54. 77 73 136 7.000 473.97 260.88 213.10 Pass 12039.89. 7154. 68 12125.00 7457.82 47.33 54. 88 73 137 7.000 480.70 259.72 220.98 Pass • Halliburton Company Anticollision Report Company: BP Amoco Date: 1/19/2008 Time: 11:09:52 Pale: 10 :Field: Prudhoe Bay Reference Site: PB YPad Co-ordinate(NE) Reference: ` Well: Y-07, True. North Reference Well: Y-07 Vertical (TVD) Reference: Y-07A plan 78:5.. Reference Wellpath: Y-07A contingency 4b: Oracle Site: PB Y Pad Well: Y-07 Rule Assigned: Major Risk Wellpath: Rig Surveys Y-07A -Neil V8 Inter-Site Error: 0.00 ft Reference Affset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.H5 Casing/HSflistance Area Deviation Warning , ft ft ft ft ft ft deg deg in ft ft: ft 12063.70 7166.59 12150.00 7476.16 47.42 54.99 74 137 7.000 487.27 258.55 228.72 Pass 12087.56 7178.53 12175.00 7494.39 47.51 55.10 74 138 7.000 493.72 257.43 236.29 Pass 12111.49 7190.49 12200.00 7512.49 47.60 55.22 75 138 7.000 500.05 256.39 243.66 Pass 12137.51 7203.52 12225.00 7530.44 47.70 55.35 75 138 7.000 506.25 255.60 250.65 Pass 12174.55 7222.52 12250.00 7548.26 47.91 55.57 76 138 7.000 511.95 255.79 256.16 Pass 12212.08 7242.49 12275.00 7566.02 48.10 55.79 76 138 7.000 517.00 256.01 261.00 Pass 12250.05 7263.42 12300.00 7583.76 48.28 56.00 77 138 7.000 521.44 256.15 265.29 Pass 12288.30 7285.22 12325.00 7601.46 48.45 56.19 78 138 7.000 525.24 256.33 268.91 Pass 12326.67 7307.82 12350.00 7619.12 48.60 56.37 79 137 7.000 528.39 256.36 272.04 Pass 12365.33 7331.33 12375.00 7636.70 48.74 56.54 79 137 7.000 530.86 256.46 274.40 Pass 12404.22 7355.70 12400.00 7654.18 48.88 56.71 80 137 7.000 532.63 256.65 275.98 Pass 12443.28 7380.89 12425.00 7671.58 49.00 56.86 80 136 7.000 533.68 256.66 277.02 Pass 12482.43 7406.83 12450.00 7688.92 49.12 57.00 81 135 7.000 534.04 256.80 277.24 Pass 12521.60 7433.48 12475.00 7706.23 49.22 57.13 81 135 7.000 533.70 256.81 276.90 Pass 12560.74 7460.76 12500.00 7723.52 49.30 57.25 82 134 7.000 532.68 256.74 275.95 Pass 12599.77 7488.60 12525.00 7740.79 49.39 57.36 82 133 7.000 530.98 256.77 274.21 Pass 12628.10 7509.12 12550.00 7758.05 49.46 57.48 82 133 7.000 528.77 256.93 271.84 Pass 12652.99 7527.18 12575.00 7775.29 49.53 57.60 82 133 7.000 526.51 257.10 269.41 Pass 12677.88 7545.22 12600.00 7792.51 49.60 57.72 82 133 7.000 524.22 257.27 266.95 Pass 12695.15 7557.75 12617.35 7804.46 49.65 57.80 82 133 7.000 522.61 257.38 265.23 Pass Site: PB Y Pad Well: Y-23 Rule Assigned: Major Risk Wellpath: Y-236 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 TF0.HS Casing/IISi)istance :Area. Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13500.81 8169.12 13025.00 9042.27 51.90 40.30 153 204 4.500 1665.35 198.93 1466.42 Pass 13512.31 8178.55 13050.00 9042.58 51.93 40.39 154 204 4.500 1657.07 201.53 1455.54 Pass 13523.95 8188.09 13075.00 9042.78 51.96 40.49 155 205 4.500 1648.49 204.13 1444.36 Pass 13535.53 8197.59 13100.00 9042.85 51.99 40.59 155 206 4.500 1639.96 206.74 1433.23 Pass 13546.96 8206.97 13125.00 9042.78 52.02 40.70 156 207 4.500 1631.71 209.39 1422.32 Pass 13558.27 8216.24 13150.00 9042.55 52.05 40.80 157 207 4.500 1623.64 212.05 1411.59 Pass 13569.68 8225.60 13175.00 9042.23 52.08 40.90 158 208 4.500 1615.35 214.71 1400.64 Pass 13581.48 8235.27 13200.00 9041.99 52.11 41.00 158 209 4.500 1606.56 217.33 1389.23 Pass 13593.22 8244.90 13225.00 9041.37 52.14 41.11 159 209 4.500 1597.19 219.92 1377.27 Pass 13604.66 8254.29 13250.00 9040.19 52.17 41.22 160 210 4.500 1587.30 222.51 1364.79 Pass 13615.97 8263.56 13275.00 9038.69 52.20 41.33 160 211 4.500 1577.12 225.09 1352.03 Pass 13627.19 8272.77 13300.00 9036.95 52.23 41.44 161 212 4.500 1566.76 227.68 1339.09 Pass 13638.39 8281.95 13325.00 9035.16 52.26 41.55 162 212 4.500 1556.56 230.28 1326.29 Pass 13649.56 8291.11 13350.00 9033.34 52.28 41.67 163 213 4.500 1546.60 232.89 1313.71 Pass 13660.66 8300.22 13375.00 9031.44 52.31 41.78 163 214 4.500 1536.87 235.53 1301.34 Pass 13671.74 8309.30 13400.00 9029.53 52.34 41.89 164 215 4.500 1527,45 238.19 1289.25 Pass 13682.91 8318.47 13425.00 9027.81 52.37 42.09 165 215 4.500 1518.59 240.88 1277.71 Pass 13694.19 8327.72 13450.00 9026.29 52.40 42.12 166 216 4.500 1510.33 243.58 1266.75 Pass 13705.57 8337.05 13475.00 9024.99 52.43 42.24 166 217 4.500 1502.66 246.30 1256.37 Pass 13717.00 8346.43 13500.00 9023.79 52.46 42.35 167 218 4.500 1495.46 249.02 1246.44 Pass 13728.43 8355.81 13525.00 9022.59 52.49 42.47 168 219 4.500 1488.52 251.75 1236.78 Pass 13739.86 8365.18 13550.00 9021.37 52.52 42.58 169 219 4.500 1481.86 254.47 1227.39 Pass 13751.30 8374.56 13575.00 9020.15 52.55 42.70 170 220 4.500 1475.48 257.19 1218.29 Pass 13762.96 8384.12 13600.00 9019.26 52.58 42.81 171 221 4.500 1469.72 259.90 1209.82 Pass 13774.92 8393.93 13625.00 9018.83 52.61 42.93 171 222 4.500 1464.71 262.59 1202.11 Pass • Halliburton Company Anticollision Report .Company: BP Amoco Date: 1/49!2008- Time: 11:09:52 Page: 11 Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: WeI L Y-07, True North Reference Well: Y-07 Vertical (TVD) Reference: Y-07A p lan 78: 5 Reference Wellpath: Y-07A contingency Db: Oracle Site: PB Y Pad Well: Y-23 Rule Assigned: Major Risk Wellpath: Y-23B V7 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr ' No-Go Allowable MD ft TVD ft MD ft TVD ft Ref ft Offset ft TFO+AZI deg TFO-HS deg Casing/H~istance in ft Area ft Deviation ft Warning 13787.17 8403. 98 13650. 00 9018.86 52.64 43.05 172 223 4.500 1460.45 265. 27 1195. 18 Pass 13799.69 8414. 25 13675. 00 9019.29 52.68 43.16 173 224 4.500 1456.89 267. 92 1188. 97 Pass 13812.27 8424. 57 13700. 00 9019.81 52.71 43.28 174 224 4.500 1453.70 270. 55 1183. 15 Pass 13824.89 8434. 92 13725. 00 9020.37 52.74 43.40 175 225 4.500 1450.82 273. 15 1177. 67 Pass 13837.54 8445. 29 13750. 00 9020.96 52.78 43.52 176 226 4.500 1448.26 275. 73 1172. 54 Pass 13850.16 8455. 65 13775. 00 9021.57 52.81 43.64 176 227 4.500 1446.11 278. 27 1167. 84 Pass 13862.65 8465. 89 13800. 00 9022.11 52.84 43.76 177 228 4.500 1444.55 280. 79 1163. 76 Pass 13874.88 8475. 92 13825. 00 9022.37 52.88 43.87 178 229 4.500 1443.24 283. 29 1159 .95 Pass 13886.85 8485. 74 13850. 09 9022.20 52.91 43.99 179 229 4.500 1441.99 285 .76 1156 .22 Pass 13898.54 8495. 33 13875. 00 9021.81 52.94 44.11 180 230 4.500 1441.01 288 .19 1152 .82 Pass 13910.20 8504. 89 13900 .00 9021.38 52.97 44.22 181 231 4.500 1440.49 290 .58 1149 .91 Pass 13921.78 8514. 39 13925. 00 9020.91 53.00 44.34 182 232 4.500 1440.44 292. 93 1147. 50 Pass 13933.29 8523. 82 13950. 00 9020.41 53.03 44.46 183 233 4.500 1440.84 295. 24 1145. 60 Pass 13944.70 8533. 18 13975. 00 9019.83 53.06 44.57 183 234 4.500 1441.66 297. 50 1144. 16 Pass 13956.02 8542. 47 14000. 00 9019.17 53.09 44.69 184 235 4.500 1442.87 299 .71 1143. 17 Pass 13967.24 8551. 67 14025. 00 9018.42 53.12 44.81 185 236 4.500 1444.48 301 .86 1142 .61 Pass 13978.37 8560. 80 14050. 00 9017.61 53.15 44.92 186 237 4.500 1446.47 303 .96 1142 .51 Pass 13989.55 8569. 97 14075. 00 9016.84 53.18 45.04 187 237 4.500 1448.83 306 .01 1142 .83 Pass 14000.77 8579 .17 14100. 00 9016.13 53.21 45.15 188 238 4.500 1451.55 307 .99 1143 .56 Pass 14012.05 8588 .42 14125. 00 9015.48 53.24 45.27 189 239 4.500 1454.63 309 .91 1144 .72 Pass 14023.34 8597 .68 14150 .00 9014.86 53.27 45.39 190 240 4.500 1458.05 311 .77 1146 .28 Pass 14034.52 8606 .85 14175 .00 9014.11 53.30 45.50 190 241 4.500 1461.80 313 .57 1148 .23 Pass 14045.58 8615 .93 14200 .00 9013.24 53.33 45.62 191 242 4.500 1465.88 315 .31 1150 .57 Pass 14056.53 8624. 90 14225. 00 9012.24 53.36 45.73 192 243 4.500 1470.29 316. 99 1153. 30 Pass 14067.43 8633. 85 14250. 00 9011.20 53.39 45.85 193 243 4.500 1475.04 318 .61 1156. 43 Pass 14078.42 8642. 86 14275. 00 9010.25 53.42 45.97 194 244 4.500 1480.14 320 .17 1159 .97 Pass 14089.49 8651. 94 14300. 00 9009.40 53.45 46.08 195 245 4.500 1485.57 321 .66 1163 .91 Pass 14100.63 8661. 08 14325. 00 9008.64 53.48 46.20 196 246 4.500 1491.34 323 .09 1168 .25 Pass 14111.77 8670. 21 14350. 00 9007.88 53.51 46.32 196 247 4.500 1497.47 324 .46 1173 .01 Pass 14122.85 8679. 30 14375. 00 9007.10 53.54 46.44 197 248 4.500 1503.97 325 .77 1178 .20 Pass 14133.87 8688 .34 14400. 00 9006.27 53.57 46.56 198 248 4.500 1510.84 327 .01 1183 .83 Pass 14144.88 8697 .37 14425 .00 9005.45 53.60 46.67 199 249 4.500 1518.06 328 .20 1189 .86 Pass 14156.32 8706 .75 14450. 00 9005.05 53.63 46.79 200 250 4.500 1525.45 329 .33 1196 .12 Pass 14168.23 8716 .52 14475 .00 9005.13 53.66 46.91 200 251 4.500 1532.97 330 .40 1202 .57 Pass 14180.28 8726 .41 14500 .00 9005.35 53.69 47.03 201 252 4.500 1540.74 331 .41 1209 .32 Pass 14192.40 8736. 35 14525. 00 9005.64 53.73 47.16 202 252 4.500 1548.73 332 .38 1216. 35 Pass 14204.58 8746. 33 14550. 00 9005.89 53.76 47.28 203 253 4.500 1556.77 333 .30 1223 .47 Pass 14216.80 8756. 36 14575. 00 9006.12 53.79 47.40 203 254 4.500 1564.82 334 .16 1230 .65 Pass 14229.08 8766. 43 14600. 00 9006.30 53.83 47.52 204 255 4.500 1572.88 334 .98 1237 .90 Pass 14241.34 8776. 48 14625. 00 9006.41 53.86 47.65 205 255 4.500 1581.05 335 .75 1245 .30 Pass 14253.45 8786. 42 14650. 00 9006.35 53.89 47.77 206 256 4.500 1589.48 336 .48 1253 .01 Pass 14265.42 8796 .23 14675. 00 9006.14 53.93 47.90 206 257 4.500 1598.19 337 .15 1261 .04 Pass 14277.24 8805 .93 14700 .00 9005.76 53.96 48.02 207 257 4.500 1607.16 337 .78 1269 .39 Pass 14289.10 8815 .65 14725 .00 9005.41 53.99 48.15 208 258 4.500 1616.38 338 .36 1278 .02 Pass 14301.16 8825 .54 14750 .00 9005.29 54.02 48.27 208 259 4.500 1625.82 338 .90 1286 .91 Pass 14313.42 8835 ,60 14775 .00 9005.39 54.06 48.40 209 260 4.500 1635.45 339 .40 1296 .05 Pass 14325.87 8845, 81 14800. 00 9005.71 54.09 48.51 210 260 4.500 1645.29 339 .82 1305 .48 Pass 14338.37 8856. 07 14825. 00 9006.08 54.13 48.58 210 261 4.500 1655.34 340 .07. 1315 .28 Pass TRANSMITTAL LETTER CHECKLIST WELL NAME _ ~~l/• Y-O,7A ~~ ~ ~1ZS~C,~ PTD# o?O~~OSD Development y Service Exploratory Strati ra hic Test g p Non-Conventional Well FIELD: ~~"y~~pfc ~x~.. POOL: P~,,~ h.0 tt ~C~. ~`t Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing (If last two digits in API number well permit No. ,API No. 50- - 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 i SAMPLE n no greater than 30' sample intervals from below the permafrost or from where samples are first caught and ] 0' sample intervals throw h tar et zones. Non-Conventional Well please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Comnanv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/1(/2008 ^^ m o- m 0 ~ ~ ~ ~ , O .Q ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ C Q ~ ~ ~ ~ Qy ~ ~ ~ g. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ m ~ , , V' ` Q 1 ~ p ~ ~ l6 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ C ~ ~ ~ ~ C ~ L ~ • > O C C ~ r. Y. 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Thanks - jr Well Name: Y-07Ai CMT VOL ID bbls/ft Footage Volume 9-5/8" - 47# 8.681 0.0732 0 7" -26# 6.276 0.0383 0 4-1/2" - 12.6# 3.958 0.0152 80 1 4" DP 3.24 0.01 0 9-5/8" x 4" 0.0577 0 7" x 4-1/2" 0.0186 100 2 8-1/2" x 7" 0.0224 0 6-1/8" x 4-1/2" 0.0168 289 5 7" x 4" 0.0321 200 6 9-5/8" x 7" 0.0256 0 40% Excess 0.3 0 30% Excess 0.3 1 Total Cement (bbls) 16bbls 15.8 "G" bbls 1 16 16bbls cf 5.6 16 89cf sxs 4.83 16 76sxs Other Blends sxs/bbl cf/sxs 10.7 DeepCrete 1.55 3.62- 12.0 LiteCrete 3.47 1.61 5.5867 11.5 LiteCrete 2.02 2.77 5.5954 10.7 ASL 1.26 4.44 5.5944 15.8 "G" 4.83 1.17 5.6511 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 28, 2008 8:42 AM To: Rose, John G (FAIRWEATHER) Cc: Hobbs, Greg S (ANC); NSU, ADW Drlg Rig 2es Subject: RE: Y-07Ai Plug Back (PTD #207-105) John, et al, I am reviewing the permit right now. I would expect to move it to the Commissioners later this morning. You may continue the operations underway. Call or message with any questions. Tom Maunder, PE 1 /28/2008 Y-07Ai Plug Back (PTD #207 ~) Page 2 of 4 AOGCC From: Rose, John G {FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Monday, January 28, 2008 8;22 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S {ANC); NSU, ADW Drk,J Rig 2es Subject: RE: Y-07Ai Piug Back {PTD #207-105) Tom, We have re-drilled our Y-07Ai 8-1/2" hole from the 9-5/8" shoe at 9305' MD to the new top Sag target (wp21.A) at 14,398' MD and we are currently cementing our 7" drilling liner at that depth. Our path-forward plan for this well is to drill the 6-1/8" hole as detailed in the request for a Drilling Permit as submitted to your office last week. As we should be ready to drill out of our 7" shoe in the next 24-36 hours, have you had a chance to review the permit request and/or is there any additional information required by your office? Thanks - jr From: Rose, John G (FAIRWEATHER) Sent: Friday, January 18, 2008 1:17 PM To: 'Maunder, Thomas E (DOA)' Cc: Hobbs, Gnrg S (ANC); NSU, ADW Dtig Rig 2es Subject: RE: Y-07Ai Plug Back (PTD #207-105) Tom, In an effort to get over and around some the complex Kingak geology in the area of our current well-path, the BHL will be moved to the west and MAY exceed the 500' rule which will require a new drilling permit. When the final directional plan for our sidetrack is complete, I will initiate that new PTD process if the movement of our BHL exceeds 500' and I am assuming that process will not interfere with ongoing rig operations. Please advise if you have any concerns or require additional information. Thanks - JR m: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Se :Friday, January 18, 2008 12:02 PM To: R , John G (FAIRWEATHER) Ce: Hob Greg 5 {ANC); NSU, ADW Drk,I Rig 2es Subject: -07Ai Plug Back (PTD #207-105) Provided there are zones that require isolation in t interval, setting the plug off bo will meet the regulatory uirement. Good luck, Tom Maunder, PE AOGCC From: Rose, John G (FAiRWEA ) [ma :John.G.Rose@bp.com] Sent: Friday, January 18, 200 1:53 AM To: Maunder, Thomas E (D ) Cc: Hobbs, Greg S (AN ,NSU, ADW Drlg Rig 2es Subject: RE: Y-07A' ug Back (PTD #207-105) Tom, 1din~ on where to top of drillpipe is based upon our final back-o ork, we may or may not cement from the the stub back into the shoe as there is a current plan out there whe we may spot a 700' (off-bottom) it plug from 500' below the 9-5/8" shoe to 200' above the shoe. In any se, we can only cement what we 1/28/2008 Y-07Ai Plug Back (PTD #207 ~) Page 1 of 2 • Maunder, Thomas E (DOA) From: Rose, John G (FA{RWEATHER} [John.G.Rose@bp.com] . Sent: Friday, January 18, 2008 12:05 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); NSU, ADW Drlg Rig 2es Subject: RE: Y-07Ai Plug Baek (PTD #207-105) There are no zones which require isolation. Thanks again. jr From: Maunder, Thomas E (DOA) [mailto:tom.maunder@a{aska.gov] Sent: Friday, January 18, 2008 12:02 PM To: Rase, John G (FAIRWEATHER) Cc: Hobbs, Greg S (ANC); NSU, ADW Dry Rig 2es Subject: RE: Y-07Ai P{ug Back (PTD #207-I05} Provided there are no zones that require isolation in that interval, setting the plug off bottom will meet the regulatory requirement. Good luck, Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER} [mailto:John.G.Rose@bp.com] Sent: Friday, January 18, 2008 11:53 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); NSU, ADW Drlg Rig 2es Subject: RE: Y-07Ai Plug Back (PTD #207-105} Tom, Depending on where to top of drillpipe is based upon our final back-off work, we may or may not cement from the top of the stub back into the shoe as there is a current plan out there where we may spot a 700' (off-bottom) cement plug from 500' below the 9-5/8" shoe to 200' above the shoe. In any case, we can only cement what we can get to above the 5" dri0pipe stub and we haven't quite landed on a full cement column from the stub versus an off-bottom cement plug. Hope this answers your question. Thanks again. - JR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@a{aska.gov] Sent: Friday, January 18, 2008 11:31 AM To: Rose, John G (FAIRWEATHER} Cc: Hobbs, Greg S (ANC) Subject: RE: Y-07A{ Plug Baek (PTD #207-105} John, Thanks for the update. Based on the depths you give, 12745' should be well above any of the pay zones. Will you be cementing the entire remaining 8-1/2" hole back to the shoe? Look forward to your reply, Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) [mai{to:John.G.Rose@bp.com] 1/18/2008 Y-07Ai Plug Back (PTD #207 ~} Page 2 of 2 • Serrt: Friday, January 18, 200$ 10:45 AM To: Maunder, Thomas E (DOA) Ce: Hobbs, Greg S (ANC); NSU, ADW Drfg Rig 2es Subject: Y-07Af Plug Back (PTD #207-105} Tom, Ta follow upon my phone message to your office, please note the following details as they relate to our current operations on the Y-07Ai Ivishak sidetrack: 1. 9-518" casing was run and cemented to surface into the top of the Colville at 9305' MD per the original weilplan. 2. 8-1/2" hole was then being drilled targeting a top Sag casing point for the intermediate drifting finer with a planned TD of 14,142' MD. 3. At 12,600' MD in the 8-112" hole we encountered a fault in the Kingak and lost circulation problems developed. 4. The 8-1/2" hate was drilled with fosses to a final TD of 12,745' in an effort to get across the fault to a{low us to deal with the fault related mud losses. 5. In an effort to stop the fosses, we RlH with open-ended 5" drittpipe to 12,549' TMD to spat a gunk squeeze. burning that process the losses were stopped, but the dritfpipe became stuck. 7. fn the last 24 hours we ran afree-paint and have backed-off the driNpipe at 10,718' MD (that back-off depth has not been confirmed as we are currently TOH with the 5" drillpipe). 8. The current plan forward has us backing-up the weft (most tfkefy to the 9-5/8" shoe), setting a cement K4 plug and re-drifting the interval. 9. After TD'ing the next 8-1/2" hole into the top of the Sag, we wilt be back on our weltplan which includes running a 7" drifting finer (150' lap back into the 9-518" easing) and tufty cerr~nting the liner with a single stage cement job. As our new directional plan does not change the BHt by 500', is there any other information you need to regards to this plan as it relates to our current PTD? Thanks - JR John G. Rose BPX -Drilling Consularnt pf~ce 907/56q-5271 CeA y07/748-5223 F,9 I 90?/564-4040 Flonte 907/243-8813 1/18/2008 • • Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs@bp.com] Sent: Tuesday, December 1$, 2007 6:32 AM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drag Rig 2es Subject: FW: Y-07 (181-018) Fluid Ba#ance Issue Tom- ~"~~. ~ `~. +~--~~~~ Information from the rig regarding my last e-mail. Looks like they have operations in hand- Thanks! Greg Page 1 of 2 From: Rose, ]ohn G (FAIRWEATHER) Sent: Monday, December 17, 2007 9:35 PM To: Hobbs, Greg S (ANC) Cc: NSU, ADW Drlg Rig 2es; Pettier, Travis M Subject: RE: Y-07 (181-018) Fluid Balance Issue Just to confirm, John Grisp gave us the OK to test the BOP breaks to 2000 psi after the NU after installing the spacer spool, however, he would like us to test the BOP's to 4000 psi after we pull the 9-5/8" casing using a test plug in the casing spool profile which Cameron has indicated we can do. However, if we can't for some reason get a test using the test plug in the casing spool, Dick had a good idea that we could certainly test to 3500 psi against the well at some point forward as we already have 2 - 3500 psi CMIT's T x IA already done and we could consider bumping that test to 4000 psi if needed. Bottom-line we have a good path-forward with a couple of options in terms of satisfying our permits fora 4000 psi BOP test. Let us know if you need any clarification. Thanks - jr om: Hobbs, Greg S {ANC} Sen . onday, December 17, 2007 3:29 PM To: Maun homas E (DOA) Cc: NSU, ADW Dr 2es; Peltier, Travis M Subject: RE: Y-07 {181- Fluid Balance Issue Tom, Dick called from the rig and the well is dead and the ulled. The next step is to run aclean-out run in the 9 5/8" and hang an RTTS in the well and split the s and larger ID spool in place to pull the 9 5/8" hanger. The well plan required testing this break to psi. Dick is con ed about the force of this test on the RTTS and the current 9 5/8" hanger. Give this break and test will prove he barrier while the well is drilled to the Colvillle section, and that are no known hydrocarbon zones between kick-off point and the intermediate TD, we wo i e to test the break to 2,500 psi with your permission. Thanks foyt~hr€consideration- reg From: Maunder, Thomas E (DOA) [mai#toaom.maunder@alaska.gov] 1J28/20Q8 Maunder, Thomas E (D4A) From: Hobbs, Greg S {ANC) [Greg.Hobbs@bp.com] Sent: Monday, December 17, 2007 3:29 PM To: Maunder, Thomas E {DOA) Cc: NSU, ADW Dr1g Rig 2es; Pettier, Travis M Subject: RE: Y-07 (181-018)(Fluid Balance Issue Tom, ~" ~~ ~ `~~-~OS> Page 1 of 2 Dick called from the rig and the well is dead and the tubing pulled. The next step is to run aclean-out run in the 9 5/8" and hang an RTTS in the well and split the stack and put a larger ID spool in place to pull the 9 5/8" hanger. The well plan required testing this break to 4000 psi. Dick is concerned about the force of this test on the RTTS and the current 9 5/8" hanger. Given that this break and test will prove up the barrier while the well is drilled to the Colvillle section, and that there are no known hydrocarbon zones between the kick-off point and the intermediate TD, we would like to test the break to 2,500 psi with your permission. Thanks for the consideration- Greg From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Monday, December 17, 2007 12:31 PM To: Hobbs, Greg S (ANC) Cc: Schultz, Mikel; NSU, ADW Drlg Rig 2es; AOGCC North Slope Office Subject: RE: Y-07 (181-018) Fluid Balance Issue Greg, Thanks for the information. Appears the diesel must have got strung out. Might be a function of the shallow cut. Maybe a lesson learned for future shallow cuts. Your plan forward is acceptable. There is no need to re-test the 4-1/2" rams after the tubing is laid down. Call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Monday, December 17, 2007 12:04 PM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel; NSU, ADW Drlg Rig 2es Subject: RE: Y-07 (181-018) Fluid Balance Issue Tom- This morning, while pulling 2600' of 4.5" tubing from well Y-07AI, slight flow was noted up the tubing after four joints were pulled. A valve was stabbed in the tubing, and the 4.5" rams were closed. Initially, there was 20 psi on the 9 518" gauge and 0 psi on the tubing. This then became 0 psi on the 9 5/8" and 10 psi on the tubing. We are still getting diesel in returns, so it appears to be a fluid balance issue. Dick Maskell is circulating the well as we speak, and forward plans are to insure the well is stable, pull the tubing, and run a 9 5/8" plug above the tubing stub per the well plan. Greg 1/28/2008 From: Maunder, Thomas E {DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 17, 2007 11:49 AM To: Hobbs, Greg S {ANC) Subject: Y-07 (181-018) Fluid Balance Issue Greg, 1 received your voice message. 'T'hanks in advance. Tom Maunder, 1'E AOGCC Could you please respond to this message with a written summary. Page 2 of 2 1!28/2008 ~-07Ai Wellplan Changes (P207-105) Page 1 of~ ~ ~~~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, November 15, 2007 9:35 AM To: 'Rose, John G (FAIRWEATHER)' Subject: RE: Y-07Ai Wellplan Changes (PTD# 207-105) Good luck with the operations. Tom From: Rose, ]ohn G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Thursday, November 15, 2007 9:33 AM To: Maunder, Thomas E (DOA) Subject: RE: Y-07Ai Wellp{an Changes (PTD# 207-105) Correct. The gross cement volumes will remain the same in that full cementation from casing shoe to surface for the 9-5i8" casing and from the liner shoe to the liner top for the 7" liner (using the same excess volume factors for both jobs) remains the objective of both cement jobs. Thanks - jr From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Thursday, November 15, 2007 9:10 AM To: Rose, John G (FAIRWEATHER) Cc: Hobbs, Greg S (ANC} Subject: RE: Y-07Ai Wellplan Changes (PTD# 207-105) John, It does not appear that the revisions will adversely effect the planned well construction and in the cementing operations are planned to give you slightly lighter hydrostatic columns. I presume that the gross pumping volumes will still be the same. Look forward to your reply. Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com) Sent: Thursday, November 15, 2007 7:02 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: Y-07Ai Wellplan Changes (PTD# 207-i05) Tom, As the Y-07Ai RST is our next planned well for Nabors 2ES with a planned spud date of ~12i15107, please note the attached document to review the changes to the Wellplan which have been made since the PTD was issued by your office. If you have any questions or concerns or require additional infarmation on any of these Wellplan changes, please advise. Thanks - JR «Y--07Ai Wellplan Changes. doc» ~lohn G. Rose BPX -Drilling Consultant 11115/2007 Tom, As the Y-07Ai RST is our next planned well for Nabors 2ES with a planned spud date of 72/15/07, please be advised of the following fisted weltplan changes that have been made since the PTD has been approved for this well: Wellpian Chance KOP 9-5/8" casing wt/ft 9-5/8" intermediate casing connections to 2650' MD 1st stage 9-5/8" cement sluny(s)" 2nd stage 9-5/8" cement job (ES cementer &ECP)" Pressure test for 9-518" casing ~ole sire out of 9-5/8" shoe " cement job" OriainaF Wellolan 2150' MD 40# TC-i I 11.5 LiteCRETE lead + 15.8 G tail 10.7 ppg DeepCRETE to surface 3500 psi 8-3/4" 12.0 LiteCRETE + 15.8 tail Current Welinlan 2039' MD 47# Hydril 563 All 11.5 ppg LiteCRETE 15.8 ppg G to surface 4000 psi 8-1/2" 11.7 ppg LiteCRETE + 15.8 ppg tail Reason f/Chanoe better shale f/LOT no ECP f/40# pipe both gas-tight connections lower density f/better lift + no need f/15.8 ppg tail w/ECP, 15.5 G to surface injector well requirement using 47# 9-5/8" casing lower density f/better lift NOTE: The cement jobs on both the 9-5/8" casing and 7" liner are designed to fully cement both strings of pipe, i.e., the 9-5/8" casing will be fully cemented back to surface and the 7" liner will be fully cemented back to the top of the liner lap. If you have any questions or concerns or require additional information on any of these weltplan changes, please advise. Thanks - JR a ~ o ~ SARAH PALIN, GOVERNOR ~r ~-7~~~T Duj ~D a7[~a 333 W. 7th AVENUE, SUITE 100 C~l~-7~RQ,•~~Qi~ C011~/i15SIO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (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 Y-07A BP Exploration Alaska Inc. Permit No: 207-105 Surface Location: 1341' FNL, 118' FWL, SEC. 34, T11N, R13E, UM Bottomhole Location: 4183' FSL, 2049' FEL, SEC. 29, T11N, R13E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this ~ day of August, 2007 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ALAS~IL AND GAS CONSERVATION COMMI N PERMIT TO DRILL ~~'~ 20 AAC 25.005 ~~ ,. `i l :_. ~i3iltmlSSiO~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is proposed fay--. ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU Y-07A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14227' TVD 9119 ' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1341' FNL 34 118' FWL SEC T11N R13E UM` 7. Property Designation:~aL ADL 028288 s`~$7 Pool 3.~ , , , . , , Top of Productive Horizon: 2948' FSL, 420' FEL, SEC. 29, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 5, 2007 Total Depth: 4183' FSL, 2049' FEL, SEC. 29, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 20,267' , 4b. Location of Well (State Base Plane Coordinates): Surface: x-644933 ~ y-5948917 ~ Zone-ASP4 10. KB Elevation Plan (Height above GL): 78.46 .feet 15. Distance to Nearest Well Within Pool: 1,720' r 16. Deviated Wells: Kickoff Depth: 2150 ' feet Maximum Hole An le: 64 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3900 ~ Surface: 3018 . 18. asin ' Pr `ram: S` " cfi bo ns ° To - Settin De` h -Bo ttom uanti of Dement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 12-1/4" 9-5/8" 40# L-80 TC-II 2650' Surface Surface 2650' ~ 2643' ~ See Below 12-1 /4" 9-5/8" 40# L-80 BTC-M 6285' 2650' 2643' 8935' ~ 5815' - 2251 cu ft ~iteCrete, 522 cu ft'G', 1207 cu ft DeepCrete 8-3/4" 7" 2 L-80 BTC-M 161' 8785' 5742' 13946' 890 ' ' cu ft Lite ret 213 cu ft la 6-1 /8" 4-1 /2" 12.6# L-80 IBT-M 387' 13846' 8837' 14226' 9118' 90 cu ft Class 'G' 19. PRESE NT WELL CON©ITION SUMMARY (To be completed for Redrill :and Re-entry Operations) Total Depth MD (ft): 10075 Total Depth TVD (ft): Plugs (measured): 9684 None Effective Depth MD (ft): 9906 Effective Depth TVD (ft): 9519 Junk (measured): None Casing Length:. ize Cement Volume MD D Conductor /Structural 110' 2 " x 0" 8 cu ds Concrete 110' 110' Surface 2685' 13-3/8" 3720 cu ft Permafrost 11 2685' 2685' Intermediate 9187' 9-5/8" 1271 cu ft Class'G' 130 cu ft PF'C' 9187' 8818' Prod ti n Liner 1380' 7" 4 5 cu ft Class'G' 8683' - 10063' 8331' - 9673' Perforation Depth MD (ft): 9288' - 9442' Perforation Depth TVD (ft): 8915' - 9065' 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 foregoin is true and correct. Contact John Rose, 564-5271 Printed Name Greg, o bs Title Senior Drilling Engineer ~, Prepared By Name/Number Si nature ` 1'!! Phone 564-4191 Date > ~~~ ~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~7''~0~ API Number: 50-029-20560-01-00 Permit A proval See cover letter for Date: other re uirements Conditions of Approval: ~: If box is ciihecked, well may not be used to explore for, test, or produce coalbed meths ,gas hydrates, or gas contained shales: ,..,/ 1`~ ~~ ~' t.S~ 4~~Z:. ti~ C-' ` v ~ ~ t ~ ~,.' , l ~ '"~ Sam les Re d: [~ Lt7 yr p q' ^ lles No Mud Log Req'd: ^ ,Yes No ~ m~,; ~1.L~ ~, H S Measures: es ^ No irectional Surve Re d: Yes ^ No Y q' .~~t ~_ '~? "~~5~ ~ Other: ~, ~ ~~ ~`~`~C~ ~1~L~ ~..~+r\. i;:~..<e~ `A'~ ~~ls . l/ ~~'~1~..c~. ~ . ~ ~ APPROVED BY THE COMMISSION Date ~ ~Q ,COMMISSIONER Form 10-401 Revised 12!2005 ~ ~ [~/ ~ ~ Submit In Duplicate ~R1G0NA~ _~,/ ~h,~~8.s.~t • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: John Rose, ODE Date: July 25, 2007 Re: Y-07ai Sidetrack Permit to Drill LJ by The Y-07ai rotary sidetrack is scheduled to be drilled by Nabors 7ES with an estimated spud date for the sidetrack of ~11/05/07. The basic sidetrack plan is to perform a whipstock departure from the parent well (Y-07i) from the 13-3/8" casing at 2150' MD with a 12-1/4" BHA and drill into the top of the Colville at 8935' MD and run and fully cement a 9-5/8" casing string to surface. An 8-1/2" hole will then be drilled to the top of the Sag River formation at 13,955' MD where a 7" drilling liner will be run and fully cemented back to the 9-5/8" lap. A 6-1/8" injection hole will then be drilled into Zone 4 of the Ivishak to 14,14_3' MD where a 4-1/2" injection liner will be run and fully cement back into the 7" lap. This well will then be completed with a 4-1/2" carbon completion. A Sundry Approval (306-001) for the P&A work on the Y-07i parent well was approved by your office on 01/03/06 and while the P&A plan has not changed, the sidetrack plan has been ,~ "revised" from the plan as outlined in the original Sundry request. Please note the follow drilling and completion summary as provided below and do not hesitate to call if additional information is required. Well Name: Y-07ai Drill and Complete Plan Summary (7/25/07) T e of Well service / roducer / in'ector : Ivishak Injector Tar et X Y Z TVDss Townshi Ran a Section FSL. FEL Surface Location 644,933 - 5,948,917 - 0 11 N - 13E - 34 - 3940 ~ 5162 - Intermediate Tar et 639,025 5,953,095 6710 11 N 13E 29 2948 420 BHL 637,370 5,954,300 8970 11 N 13E 29 4183 2049 AFE Number: PBD 4P2572 API Number: 50-029-20560-01 Estimated Start Date: 11/05/07 O eratin da s: 29 Rig: Nabors 7ES TMD 14,227' TVD rkb: 9119' ~ RKB/GL 28.5'/49.96' RTE 78.46' Well Design: USH Zone 4 Injector 4-~/z", L-80 Com letion Current Status: Rotary Sidetrack General Well Information: Estimated BHP: 3177 psi at 8935' TVDss Estimated BHT: 231 deg F at 8800' TVDss Y-07ai Sidetrack Page 1 • Formation Markers: • Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation (TVDss) (feet) (Yes/No) (Psi) (ppg EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells KOP @ 2150 MD (-2070 SSTVD) NA NA SV4 -2309 +/- 10' SV3 -2892 +/- 10' SV2 -3116 +/- 10' SVl -3462 +/- 20' UC4 -3977 +/- 50' UG3 -4196 +/- 50' UGl -4769 +/- 50' WS2 -5224 +/- 50' WSl -5470 +/- 50' CM3 -5676 +/- 50' CM2 -6137 +/- 50' CMl -6823 +/- 50' THRZ -7139 +/- 50' LCU / BHRZ / TKNG -7385 +/- 50' TJF -7898 +/- 50' TJE -8030 +/- 50' TJD -8326 +/- 50' TJC -8515 +/- 50' TJB -8654 +/- 25' TSGR -8823 +/-25' Yes 3128 6.8 TSHU -8849 +/-25' 3 L40 6.8 TSAD -8935 +/-25' Yes 3177 6.8 POWC -8955 +/- 20' Yes 3186 6.8 To HOT -8975 +/- 20' 3195 6.8 Well TD Criteria (ie ??ft TVD, ??ft Rathole, etc.) Drill to planned T.D. of 14,227'. Must have sufficient rathole to perforate entire Ivishak section above HO/T top. Comments Ugnu is not hydrocarbon bearing in this area. Casing/Tubing Program: Hole Size Csg/ Tbg O.D. WUFt Grade Connection Length (ft) Top MD/TVD RTE ft Btm MDlTVD RTE ft 12-1/a" 9-5/8" 40 L-80 TC-II 2650 GL 2650/2643 12-'/a" 9-5/8" 40 L-80 BTC-M 6285 ~ 2650/2643 8935/5815 ' 8-3/4" 7" 26 L-80 BTC-M 5161 8785/5742 13,946/8903 f' 6-%a" 4-'/z" 12.6 L-80 IBT-M 380 13,846/8837 14,226/9118 Tubin 4-t/z" 12.6 L-80 TC-II 13,796 GL 13,846/8837 Directional: Directional Plan: Schlumber er Feasibilit Stud P7 Ref Elev: 63.3' MD KOP: 2150' MD, be in 4/100 build Close A roach Wells: All Wells ass Ma'or Risk Scan, reference P7 anti-collision re ort Surve Pro ram: G rodata cont. cs m/s 2150' , MWD + tFR + MS 14,227' Maximum Hole An le: 64 de rees f/3807'-5407' MD Distance to Nearest Property Line: 20,267' Distance to Nearest Well in Pool: None within'/a mile / H-37 is at 1720' at to Ivishak Y-07ai Sidetrack Page 2 • • Mud Pro ram: 12-'/a" Surface Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH Funn Vis FL 2052'-8935 KOP-CM3 9.3 f 25-50 20 - 50 9.0 - 9.5 50-150 < 8.0 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Density PV YP PH API Filtrate MBT 8935'-11,753' CM3-THRZ 9.3 8-14 18-24 9.0-9.5 4 - 7 < 15 11,753'-13,946' THRZ-TSAG 11.0 12-20 18-24 9.0-9.5 HTHP < 10 < 15 6-'/8" Production Hole Mud Pro erties FloPro-SF Interval Density PV YP PH API Filtrate MBT 13,946'-14,226' Final Well TD 8.4-8.6 _ 8-12 22-28 8.5-9.0 < 10 <3 Surve and Lo in Pro ram: 12-'/a" Hole Section: Surface Gyro until MWD surreys are clean. MWD /LWD: Dir/GR/PWD O en Hole: None Cased hole: USIT (possible run in conjunction w/7" USIT work) 8-3/a" Hole Section: Sample as required by well site Geologist MWD /LWD: DIR/GR/PWD - O en Hole: None Cased Hole: USIT 6-'/8" Hole Section: Sample as required by well site Geologist MWD /LWD: DIR/GR/RES O en Hole: None Cased Hole: None NOTE: The Primary Depth Control Log (PDCL) for Y-07A is the Schlumberger Y-07 Jewelry Log GR dated 01/12/06. All MWD logs are to be tied-in and depth shifted to this PDCL. Sufficient gamma ray character for definitive tie-in above the window is to be recorded and rinted on field and final to s. Cement Calculations: Casin Size Surface Casin - 9 5/e", 40 Ib/ft, L-80, BTC-M & TC-II - 2 Sta a Cement Job 12-1/4" Hole 15 Stage Lead: Open hole volume + 40% from 7816' to 2650' MD (ES Cementer). Tail: Open hole volume + 40% excess + 80' shoe track. TOC 500' TVD above shoe to 7816' MD. Fluid Sequence and Volume: ES Cementer at 2650' MD for 2" Stage Cement Job Wash None S acer 100 bbls of MudPush II wei hted to 10.0 Lead 401 bbls 810 sks 11.5 LiteCRETE - 2.77 cuft/sx Tail 93 bbls 454 sks 15.8 Ib/ al Class G - 1.15 cuft/sk Temp BHST ~ 80° F, BHCT ~80° F 2" Stage Lead: None. Tail: Open hole volume + 40% excess f/ES Cementer (2650' MD) to 13-3/8" window at 2150' MD plus 13-3/8' x 9-5/8" annular volume to surface lus 50 bbls excess cement. TOC at Surface. Fluid Sequence and Volume: ES Cementer at 2650' MD for 2" Stage Cement Job Y-07ai Sidetrack Page 3 r • Wash None S acer 100 bbls of MudPush II wei hted to 10.0 Lead None Tail 215 bbls 325 sks 10.7 Ib/ al Dee CRETE cement - 3.7 cuft/sx Tem BHST ~ 50° F, BHCT ~70° F Casin Size Intermediate Casin - 7", 26 Ib/ft, L-80, BTC-M -Sin le Sta a 8-3/4" Hole Basis Lead: Open hole volume + 30% excess plus 150' liner lap into 9-5/8" casing. Estimated TOC 8785' MD. Tail: O en hole volume + 30% excess + 80' shoe track. TOC 1000' above 7" shoe. Fluid Sequence and None Volume: Wash None S acer 70 bbl of MUDPUSH XL S acer wei hted to 11.5-Ib/ al Lead 144 bbl 315 sks 12.0 LiteCRETE + Latex - 2.55 cuft/sk Tail 38 bbl 184 sks 15.8 Class G cement + Latex - 1.16 cuft/sk Temp BHST = 175° F. BHCT ~ 100° F Casin Size Production Liner - 4-~h", 12.6 Ib/ft, L-80, IBT-M -Sin le Sta a 6-1/8" Hole Basis Lead: Open hole volume + 30% excess + 150' of liner lap + 80' shoe track + 200' of 7" x 4" DP annulus volume. TOC at liner top (13,839' MD) Fluid Sequence and Wash None Volume: S acer 20 bbls of Mud ush II Wei hted to 11 Tail 16 bbls 75 sks 15.8 Ib/ al Class G Cement + Silica + Latex - 1.2 cuft/sk Temp BHST ~ 231 ° F from SOR. BHCT 160° F (est.) Surface and Anti-Collision Issues: • With the Y-31 & Y-24 wells being 33.9' & 35.7' respectively, no surface shut-in's will be required to move onto this well. • Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require sub-surface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. Y-07ai Sidetrack Page 4 • • Well Control The surface, intermediate and production hole sections will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This BOP equipment is capable of handling maximum potential surface pressures which in this case exceed 3000 psi. NOTES: 1. BOPE and drilling fluid system schematics are on file with the AOGCC. 2. When pipe rams are changed, full ram tests are required. Surface Section • ROPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 2509 psi - CM3 (8.5 ppg EMW Q 5676' TVDss) • Maximum surface pressure: 1941 psi -Based on a full column of gas C~ 0.10 psi/ft • Planned BOP test pressure: 4000 psi/250 psi Rams and 2500 psi/250 psi Annular • 9-5/8" Casing Test: 3500 psi surface pressure test • Integrity Test -12-1/4" hole: FIT 20' - 50' from 9 5/8" shoe • Kick Tolerance: 25.1 bbl KT with a 9.3 ppg mud and a 12.0 ppg FIT/LOT Intermediate Section Kick Tolerance and Intearitv Testin • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 3900 psi -Top Sag River (8.5 ppg EMW ~ 8823' TVDss) • Maximum surface pressure: ~ 3018 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 4000 psi/250 psi Rams and 2500 psi/250 psi Annular • 7" Casing Test: 4000 psi surface pressure test • Integrity Test - 8-3/4" hole: FIT 20' - 50' from 9 5/s" shoe • Kick Tolerance: 85.1 bbl KT with a 11.0 ppg mud and a 11.5 ppg FIT/LOT Production Section Kick Tolerance and Intearitv Testing • BOPE: Hydril, 13-5/8", 5000 psi j • Maximum anticipated BHP: 3177 psi - Ivishak 42P (6.8 ppg C~ 8835' TVDss) • Maximum surface pressure: 2293 psi -Based on a full column of gas C~ 0.10 psi/ft • Planned BOP test pressure: 4000 psi/250 psi Rams and 2500 psi/250 psi Annular • 4'/z" Liner Test: 4000 psi surface pressure test • Integrity Test - 6-'/e" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with 8.9 ppg FIT/LOT • Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Y-07ai Sidetrack Page 5 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control /Reservoir Pressures: Normal pore pressures (8.5 ppg) are expected throughout surface and intermediate hole drilling ~ operations. The Ivishak is expected to be pressured at 6.8 ppg EMW. II. Hydrates and Shallow gas: No gas hydrates or shallow gas is anticipated, however, follow good drilling practices in the regards at all times. - III. Lost Circulation /Breathing: Lost circulation while drilling the 12-1/4" surface hole and during the 9-5/8" cement job is of concern. Well breathing problems are a possibility in the intermediate hole after weighting-up the mud to 11.0 ppg for the HRZ. And while this well has be directionally designed to avoid lost circulation in the reservoir section, the possibility for lost circulation is still a possibility. Follow the RP guidelines for dealing with Lost Circulation related issues as/if it occurs. IV. Kick Tolerance /Integrity Testing: Surface Section Kick Tolerance and Integrity Testing • Integrity Test -12-1/4" hole: FIT 20' - 50' from 9 5/a" shoe • Kick Tolerance: 25.1 bbl KT with a 9.3 ppg mud and a 12.0 ppg FIT/LOT Intermediate Section Kick Tolerance and Integrity Testing • Integrity Test - 8-3/4" hole: FIT 20' - 50' from 9 5/8" shoe • Kick Tolerance: 85.1 bbl KT with a 11.0 ppg mud and a 11.5 ppg FIT/LOT Production Section Kick Tolerance and Integrity Testing • Integrity Test - 6-'/" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with 8.9 ppg FIT/LOT V. Stuck Pipe There will be slight differential sticking tendencies across upper sands in the 12-1/4" hole while drilling and running the 9-5/8" surface casing. Follow good drilling practices and keep all pipe moving to minimize the potential for sticking. Also, all efforts to insure effective hole cleaning is being achieved should be of priority while drilling the large diameter top-hole section of this well. With the upper sands behind casing when drilling with the 11.0 ppg mud in the intermediate hole, differential sticking will be minimized, however, still of concern. Differential sticking will also be of concern while drilling the "depleted" reservoir section of the well. VI. Hydrogen Sulfide Y-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times as H2S levels greater than 100 ppm have been recorded on Y-19 (03/00). ~ VII. Faults Based upon the directional design of this well, there are two fault intersects. The first fault intersect is in the JF-JD of the Kingak formation at 12,910' MD. While this fault intersect is not expected to be troublesome, wellbore stability issues should be of concern while drilling this fault. The second fault will be seen at 14,205' MD while drilling the reservoir section of the well. The possibility of lost circulation should be of primary concern when drilling this fault. CONSULT THE Y-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Y-07ai Sidetrack Page 6 Y-07Ai Operations Summary Pre-Riq Work: 1. Rig up slickline. Pull PXN plug from profile at 8680' MD. 2. Drift 4-1/2" x 3-1/2" tubing through WLEG. Tag and record PBTD below WLEG. 3. Rl~ E-line. ~^^oL~eri ~ Inn frnm +hn ~nii ~r_ +n o,~rF~nn (DONE - 01/12/06) 4. Fluid pack the tubing and inner annulus. 5. P&A perfs in 7" liner from the PBTD up to just above the production packer. RIH with coil to PBTD (9,906' MD). Lay in 52 bbls of cement to 8,500' MD (Above top of production packer). Wash down to confirm TOC is <_ 8,500'. POH with coil. a. Cement Calculations: • 7" liner = 9,906' - 8,713' or 1,193' (44.4 BBLS) • 3-1/2" tubing = 8,713' - 8,602' or 111' (~1 BBLS) • 4-1/2" tubing = 8,602' - 8,500' or 102' (~1.6 BBLS) • Excess volume (Squeeze) _ ~5 BBLS • Total cement volume of 52 BBLS 6. Rig up slickline, drift 4-1/2" tubing. Tag & record TOC. 7. Jet cut the 4-1/2" tubing at ~ 2,600' MD. 8. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi for 30 minutes. 9. Circulate the well to sea water through the cut. Freeze protect the IA and tubing with diesel to 2,200'. 10. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 11. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 12. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MIRU Nabors 7ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC and test f/below to 1000 psi to confirm barriers. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from the pre-rig cut 2,600'. Spool up SSSV control lines. 5. MU 9-5/8" casing scraper assembly. RIH picking up 5" DP to 2,600' & circulate wellbore. 6. RU E-Line and seta 9-5/8" CIBP on DP & set 2,550' and test to 3500 psi/30 minutes. 7. With E-line, run USIT log to determine TOC on 9-5/8" casing. 8. MU a Baker 9-5/8" casing cutting assembly. RIH to ~2,185'md and cut the 9-5/8" casing per USIT log results and per Baker representative instructions. POOH and L/D assembly. 9. CO to 9-5/8" Rams. 10. MU a 9-5/8" casing spear assembly and unseat the casing. Circulate the Arctic Pack from the annulus with warm diesel followed by sea water and detergent sweeps. Pull the 9-5/8" casing from the cut at 2,185'. 11. RU a-line. Run Gauge Ring /Junk basket and Gamma Ray tool for 13-3/8", 72# casing with CCL to casing stub ~ 2,185'. `~~12. RIH with 13-3/8" EZSV on drillpipe. Set EZSV at --2,180 to avoid cutting a casing collar during window (_ ~,°~' milling operations. RD a-line. ~>~, 13. C/O to variable Rams. 14. Close rams and pressure test the 13-3/8" casing and bridge plug to 2,000 psi for 30 minutes. 15. PU 13-3/8" whipstock and bottom trip anchor with a 12-1/4" window milling assembly. BHA will contain a UBHO sub and G/MWD tool for whipstock orientation. RIH on 5" DP to EZSV. Orient and set the whi sp tock. Swap well ovel~,to 9.3 pp milling fluid. 16. Mill a window in the 13-3/8" casing at ±2,150' MD plus 20' from mid window. Pe orm to ppg. POOH for Drilling BHA. (Note: Verify that the mud weight is 9.3 ppg prior to cutting the window.) 17. MU the 12-1/4" drilling assembly with DIR/GR/PWD and RIH. Kick-off and drill 12-1/4" interval to 9- 5/8" casing point into the top of the Colville 8935' MD. Short trip and condition wellbore for 9-5/8" ~h~y casing. POOH. The G/MWD surveys will be used until clear of magnetic interference. ~' ,.~~ 18. Run and cement 9-5/8", 40#, L-80, TC-II & BTC casing back surface (2 stage cement job). ~~(C~~. 19. MU an 8-3/4" clean-out assembly and drill-out/clean-out the 9-5/8" casing down to the float collar. POOH. 20. MU the 8-3/4" drilling assembly with DIR/GR/PWD and RIH to the landing collar. Y-07ai Sidetrack Page 7 21. Pressure test wellbore to 3500 psi for 30 minutes. 22. Drill shoe track. Ensure good 9.0-9.3 ppg mud throughout system and drill 20' of new formation. Perform FIT to 11.5 ppg. 23. Continue drilling 8-3/4" interval holding inclination ~63° and then dropping to ~40° by the THRZ ~: Formation at 11,753' MD. The mud weight will be increased to 11.0 ppg before drilling into the THRZ. Drill ahead holding hole angle and azimuth to the 7" casing point 13,946' MD. Short trip and condition hole for 7" liner run. POOH racking back as much 5" drill pipe as possible to limit the amount of time before running 7" liner. 24. Run a 7", 26#, L-80, BTC-M drilling liner to provide a 150' lap into the 9-5/8" casing and fully cement the liner back to the lap. Set hanger /liner top packer and displace cement with mud. POOH laying down the un-needed portion of the 5" DP (5" drill-pipe will be run inside the 9-5/8" casing to the top of the 7" liner). 25. MU 6-1/8" drilling BHA and RIH picking up enough 4" DP to TD the well at 14,226' MD. 26. Clean-out the 7" liner to the top of the landing collar and pressure test wellbore to 4000 psi for 30 minutes. 27. Drill out shoe track. Swap over to 8.4ppg FloPro mud. 28. Drill at least 20' (not more than 50') of formation and perform FIT to 8.9 ppg. 29. Drill the 6-1/8" interval as per directional plan to the final well TD of 14,226' MD. `~ 30. Condition well bore for the 4-1/2", 12.6#, L-80 IBT-M solid, cement liner. POOH racking back DP. LD drilling assembly. 31. Run and cement a 4-'/z" solid production liner extending the liner lap 100' into the 7" drilling liner. Set liner top packer and displace well to clean seawater above the liner top. POOH. (Note: A pen` pill will be left in the 4-1/2"liner.) 32. After cement reaches 1000 psi compressive strength, pressure test well to 4000 psi for 30 minutes and chart. 33. RU E-line and run USIT log on 7" liner cement job to confirm injection zone isolation. Also, consider running this USIT log back to surface if the cement quality on the 9-5/8" casing is of interest. 34. RIH with DPC or E-line perf guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and pert guns. 35. Run the 4-1/2", 12.6#, L-80 TC-II completion tying into the 4-1/2" liner top. 36. Reverse in inhibited seawater and diesel freeze protection into the annulus (freeze protect to 2200' MD w/diesel and spot inhibited brine below the diesel to the top of the production packer). 37. With the annulus shut-in, bull-head the tubing side with diesel freeze protect to 2200' MD. (NOTE: With reservoir pressure at 6.8 ppg, the diesel freeze protection will not place the well into an under- balanced condition.) 38. Drop ball & rod and set the production packer and individually test the tubing to 4000 psi and annulus to 4,000 psi for 30 minutes each. 39. Set and test TWC. 40. ND BOPE. NU and test the tree to 5,000 psi. (Confirm tree orientation w/Pad engineer.) 41. Pull TWC and install BPV. 42. Secure the well. RDMO. Post-Rig Work: 43. Install wellhouse and flowlines. No "S" Riser modifications should be required. 44. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. Y-07ai Sidetrack Page 8 - - - ' . ~__ . _ r ` . ~ _ _ . - F, F- o = -' < G vi i ~ a _ . 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A ~6 ~x ", [u!/UOUZ I ] (+lyuoN!(-141no5 rl 3 Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/11/2006 Timer 16:31:56 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-07, True North ~ Site: PB Y Pad Vertical (TVD) Reference: 28.5+51.46 80.0 Well: Y-07 Section (VS) Reference: Well (O.OON,O.OOE,306.55Azi) Wellpath: Plan Y-07A Survey Calculation Method: Minimum Curvature ~ Dhc Oracle Plan: Y-07A wp07 Date Composed: 8/9/2005 Version: 34 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: bggm2005 Site: PB Y Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5948541.48 ft Latitude: 70 16 0.041 N From: Map Easting: 647748.73 ft Longitude: 148 48 18.991 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.12 deg Well: Y-07 Slot Name: Y-07 Well Position: +N/-S 430.33 ft Northing: 5948916.58 ft % Latitude: 70 16 4.268 N +E/-W -2808.44 ft Easting : 644932.60 ft ~ Longitude: 148 49 40.738 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 5056.30 4049.96 9.625 12.250 9 5/8" 13954.64 8909.96 7.000 8.750 7" 14226.00 9118.41 4.500 6.125 4 1 /2" Formations MD ft TVD ft Formations Lithology Dip Angle deg Dip Direction deg 3011.09 2969.96 SV3 0.00 0.00 3275.14 3179.96 SV2 0.00 0.00 3903.21 3539.96 SV1 0.00 0.00 5056.30 4049.96 UG4 0.00 0.00 5540.82 4264.96 UG3 0.00 0.00 6822.23 4849.96 UG1 0.00 0.00 7566.73 5189.96 UG_MA (top SB) 0.00 0.00 9165.22 5919.96 SB_OBF_base (base SB) 0.00 0.00 11722.07 7194.96 THRZ 0.00 0.00 11806.69 7259.96 LCU / BHRZ / TMLV 0.00 0.00 12171.19 7539.96 TKNG 0.00 0.00 12704.92 7949.96 TJF 0.00 0.00 12874.15 8079.96 TJE 0.00 0.00 13225.64 8349.96 TJ D 0.00 0.00 13446.94 8519.96 TJC 0.00 0.00 13629.19 8659.96 TJB 0.00 0.00 13850.50 8829.96 TJA 0.00 0.00 13954.64 8909.96 TSGR 0.00 0.00 13993.69 8939.96 TSHU 0.00 0.00 14084.82 9009.96 TEIL 0.00 0.00 14091.33 9014.96 TSAD 0.00 0.00 14117.36 9034.96 POWC 0.00 0.00 14143.40 9054.96 Top HOT 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 Y-07A T1 6789.96 4291.70 -5826.50 5953094.98 639025.00 70 16 46.455 N 148 52 30.429 W -Plan hit target Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/11/2006 Time: 16:31:56 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical (TVD) Reference: 28.5+51.46 80.0 Well: Y-07 Section (VS) Reference: Well (O.OON,O.OOE,306.55Azi) Wetlpath: Plan Y-07A Survey Calculation Method: Minimum Curvature Db: Oracle 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 Y-07A T2 9049.96 5528.43 -7458.12 5954299.98 637370.00 70 16 58.604 N 148 53 17.984 W -Plan hit target Plan Section Information MD ft Incl deg Azim deg TVD ft +N/-S ft +E/-W ft DLS deg/100ft Build deg/100ft Turn deg/100ft TFO Target deg 2150 .00 0. 89 211.23 2149.88 -15. 25 1 .19 0.00 0.00 0.00 0.00 2170 .00 1. 92 99.45 2169.88 -15. 44 1 .44 12.00 5.13 -558.91 228.00 2270 .00 3. 07 355.14 2269.82 -13. 05 2 .87 4.00 1.15 -104.31 228.00 3807 .38 63. 75 313.00 3497.58 553. 58 -559 .91 4.00 3.95 -2.74 316.78 5407 .38 63. 75 313.00 4205.24 1532. 24 -1609 .40 0.00 0.00 0.00 0.00 5632 .69 62. 83 302.96 4306.72 1655. 93 -1767 .71 4.00 -0.41 -4.46 -98.12 10973 .84 62. 83 302.96 6745.92 4241. 17 -5754 .53 0.00 0.00 0.00 0.00 11072 .21 64. 00 307.16 6789.96 4291. 70 -5826 .50 4.00 1.19 4.27 73.60 Y-07A T1 11676 .96 39. 81 307.16 7160.31 4577. 06 -6202 .98 4.00 -4.00 0.00 -180.00 14136 .89 39. 81 307.16 9049.96 5528. 43 -7458 .12 0.00 0.00 0.00 0.00 Y-07A 72 14226 .89 39. 81 307.16 9119.10 5563. 24 -7504 .04 0.00 0.00 0.00 0.00 Survey MD ft 2150.00 2170.00 2200.00 2270.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3011.09 3100.00 3200.00 3275.14 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3807.38 3900.00 3903.21 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 Incl Azim deg deg 0.89 211.23 1.92 99.45 1.43 60.85 3.07 355.14 4.03 343.35 7.72 327.64 11.62 322.23 15.57 319.52 19.54 317.89 23.52 316.79 27.51 316.00 31.50 315.39 31.94 315.34 35.49 314.91 39.48 314.51 42.48 314.26 43.48 314.18 47.47 313.89 51.47 313.64 55.46 313.41 59.46 313.20 63.46 313.01 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 63.75 313.00 TVD ft Sys TVD ft VS ft N/S ft E!W ft DLS deg/1OOft MapN ft 2149.88 2069. 92 -10. 04 -15.25 1 .19 0.00 5948901 .36 2169.88 2089. 92 -10. 35 -15.44 1. 44 12.00 5948901 .17 2199.87 2119. 91 -10. 96 -15.34 2. 27 4.00 5948901 .29 2269.82 2189. 86 -10. 08 -13.05 2. 87 4.00 5948903 .59 2299.76 2219. 80 -8. 70 -11.24 2 .50 4.00 5948905 .39 2399.22 2319. 26 0. 38 -2.19 -2 .10 4.00 5948914 .35 2497.78 2417. 82 16. 36 11.45 -11. 87 4.00 5948927 .80 2594.96 2515. 00 39. 15 29.63 -26. 77 4.00 5948945 .69 2690.28 2610. 32 68. 65 52.26 -46. 70 4.00 5948967 .93 2783.29 2703. 33 104. 70 79.23 -71. 59 4.00 5948994 .41 2873.51 2793. 55 147. 14 110.40 -101. 31 4.00 5949025 .00 2960.53 2880. 57 195. 75 145.63 -135 .71 4.00 5949059 .56 2969.96 2890. 00 201. 51 149.78 -139. 81 4.00 5949063 .63 3043.91 2963. 95 250. 31 184.74 -174. 63 4.00 5949097 .91 3123.24 3043. 28 310. 54 227.54 -217. 88 4.00 5949139 .87 3179.96 3100. 00 359. 35 262.01 -253. 10 4.00 5949173 .65 3198.14 3118. 18 376. 15 273.82 -265. 24 4.00 5949185 .23 3268.25 3188. 29 446. 82 323.37 -316. 49 4.00 5949233 .77 3333.23 3253. 27 522. 21 375.92 -371. 37 4.00 5949285 .26 3392.75 3312. 79 601. 95 431.24 -429. 62 4.00 5949339 .44 3446.52 3366. 56 685. 65 489.05 -490. 96 4.00 5949396 .05 3494.30 3414. 34 772. 90 549.07 -555. 08 4.00 5949454 .82 3497.58 3417. 62 779. 47 553.58 -559. 91 4.00 5949459 .23 3538.54 3458. 58 862. 01 610.23 -620. 66 0.00 5949514 .70 3539.96 3460. 00 864. 87 612.19 -622. 77 0.00 5949516 .62 3582.77 3502. 81 951. 13 671.40 -686. 26 0.00 5949574 .59 3627.00 3547. 04 1040. 25 732.56 -751. 85 0.00 5949634 .48 3671.23 3591. 27 1129. 37 793.73 -817. 44 0.00 5949694 .36 3715.46 3635. 50 1218. 49 854.90 -883. 04 0.00 5949754 .25 3759.69 3679. 73 1307. 61 916.06 -948. 63 0.00 5949814 .14 3803.92 3723. 96 1396. 73 977.23 -1014. 22 0.00 5949874 .03 3848.14 3768. 18 1485. 85 1038.40 -1079. 82 0.00 5949933 .92 3892.37 3812. 41 1574. 97 1099.56 -1145. 41 0.00 5949993 .80 3936.60 3856. 64 1664. 09 1160.73 -1211. 00 0.00 5950053 .69 MapE TooUCoi ft 644934.09 Start Dir 1 644934.34 Start Dir 4/ 644935.16 MWD+IFR 644935.72 MWD+IFR 644935.32 MWD+IFR 644930.54 MWD+IFR 644920.51 MWD+IFR 644905.27 MWD+IFR 644884.90 MWD+IFR 644859.50 MWD+IFR 644829.19 MWD+IFR 644794.12 MWD+IFR 644789.94 SV3 644754.46 MWD+IFR 644710.40 MWD+IFR 644674.53 SV2 644662.16 MWD+IFR 644609.97 MWD+IFR 644554.09 MWD+IFR 644494.79 MWD+IFR 644432.36 MWD+IFR 644367.10 MWD+IFR 644362.18 End Dir 644300.35 MWD+IFR 644298.21 SV1 644233.60 MWD+IFR 644166.84 MWD+IFR 644100.09 MWD+IFR 644033.34 MWD+IFR 643966.58 MWD+IFR 643899.83 MWD+IFR 643833.07 MWD+IFR 643766.32 MWD+IFR 643699.57 MWD+IFR Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/11/2006 Time: 16:31;56 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical (TVD) Reference: 28:5+51.46 80.0 Well: Y-07 Section (VS) Reference: Well (O.OON,O.OOE,306.55Azi) Wellpath: Plan Y-07A 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 4900.00 63.75 313.00 3980.83 3900.87 1753.21 1221.90 -1276.60 0.00 5950113.58 643632.81 MWD+IFR 5000.00 63.75 313.00 4025.06 3945.10 1842.33 1283.06 -1342.19 0.00 5950173.47 643566.06 MWD+IFR 5056.30 63.75 313.00 4049.96 3970.00 1892.51 1317.50 -1379.12 0.00 5950207.18 643528.48 9 5/8" 5100.00 63.75 313.00 4069.29 3989.33 1931.45 1344.23 -1407.78 0.00 5950233.35 643499.31 MWD+IFR 5200.00 63.75 313.00 4113.52 4033.56 2020.57 1405.40 -1473.37 0.00 5950293.24 643432.55 MWD+IFR 5300.00 63.75 313.00 4157.75 4077.79 2109.69 1466.56 -1538.97 0.00 5950353.13 643365.80 MWD+IFR 5400.00 63.75 313.00 4201.98 4122.02 2198.81 1527.73 -1604.56 0.00 5950413.02 643299.05 MWD+IFR 5407.38 63.75 313.00 4205.24 4125.28 2205.39 1532.24 -1609.40 0.00 5950417.44 643294.12 Start Dir 4/ i 5500.00 63.28 308.89 4246.55 4166.59 2288.02 1586.56 -1672.00 4.00 5950470.54 643230.50 MWD+IFR 5540.82 63.12 307.07 4264.96 4185.00 2324.44 1608.98 -1700.71 4.00 5950492.40 643201.36 UG3 5600.00 62.92 304.43 4291.82 4211.86 2377.17 1639.79 -1743.51 4.00 5950522.38 643157.98 MWD+IFR 5632.69 62.83 302.96 4306.72 4226.76 2406.22 1655.93 -1767.71 4.00 5950538.04 643133.47 End Dir 5700.00 62.83 302.96 4337.46 4257.50 2465.99 1688.51 -1817.95 0.00 5950569.65 643082.61 MWD+IFR 5800.00 62.83 302.96 4383.13 4303.17 2554.78 1736.91 -1892.60 0.00 5950616.60 643007.06 MWD+IFR 5900.00 62.83 302.96 4428.80 4348.84 2643.57 1785.32 -1967.24 0.00 5950663.56 642931.50 MWD+IFR 6000.00 62.83 302.96 4474.47 4394,51 2732.35 1833.72 -2041.88 0.00 5950710.51 642855.95 MWD+IFR 6100.00 62.83 302.96 4520.13 4440.17 2821.14 1882.12 -2116.53 0.00 5950757.46 642780.39 MWD+IFR 6200.00 62.83 302.96 4565.80 4485.84 2909.93 1930.52 -2191.17 0.00 5950804.41 642704.83 MWD+IFR 6300.00 62.83 302.96 4611.47 4531.51 2998.72 1978.93 -2265.81 0.00 5950851.37 642629.28 MWD+IFR 6400.00 62.83 302.96 4657.14 4577.18 3087.51 2027.33 -2340.46 0.00 5950898.32 642553.72 MWD+IFR 6500.00 62.83 302.96 4702.81 4622.85 3176.30 2075.73 -2415.10 0.00 5950945.27 642478.17 MWD+IFR 6600.00 62.83 302.96 4748.47 4668.51 3265.09 2124.13 -2489.75 0.00 5950992.22 642402.61 MWD+IFR 6700.00 62.83 302.96 4794.14 4714.18 3353.87 2172.53 -2564.39 0.00 5951039.18 642327.06 MWD+IFR 6800.00 62.83 302.96 4839.81 4759.85 3442.66 2220.94 -2639.03 0.00 5951086.13 642251.50 MWD+IFR 6822.23 62.83 302.96 4849.96 4770.00 3462.40 2231.70 -2655.62 0.00 5951096.56 642234.71 UG1 6900.00 62.83 302.96 4885.48 4805.52 3531.45 2269.34 -2713.68 0.00 5951133.08 642175.94 MWD+IFR 7000.00 62.83 302.96 4931.15 4851.19 3620.24 2317.74 -2788.32 0.00 5951180.03 642100.39 MWD+IFR 7100.00 62.83 302.96 4976.81 4896.85 3709.03 2366.14 -2862.96 0.00 5951226.99 642024.83 MWD+IFR 7200.00 62.83 302.96 5022.48 4942.52 3797.82 2414.55 -2937.61 0.00 5951273.94 641949.28 MWD+IFR 7300.00 62.83 302.96 5068.15 4988.19 3886.60 2462.95 -3012.25 0.00 5951320.89 641873.72 MWD+IFR 7400.00 62.83 302.96 5113.82 5033.86 3975.39 2511.35 -3086.89 0.00 5951367.84 641798.16 MWD+IFR 7500.00 62.83 302.96 5159.49 5079.53 4064.18 2559.75 -3161.54 0.00 5951414.80 641722.61 MWD+IFR 7566.73 62.83 302.96 5189.96 5110.00 4123.43 2592.05 -3211.35 0.00 5951446.13 641672.19 UG_MA (t ~ 7600.00 62.83 302.96 5205.15 5125.19 4152.97 2608.16 -3236.18 0.00 5951461.75 641647.05 MWD+IFR 7700.00 62.83 302.96 5250.82 5170.86 4241.76 2656.56 -3310.82 0.00 5951508.70 641571.50 MWD+IFR i 7800.00 62.83 302.96 5296.49 5216.53 4330.55 2704.96 -3385.47 0.00 5951555.65 641495.94 MWD+IFR i 7900.00 62.83 302.96 5342.16 5262.20 4419.33 2753.36 -3460.11 0.00 5951602.61 641420.39 MWD+IFR 8000.00 62.83 302.96 5387.83 5307.87 4508.12 2801.77 -3534.75 0.00 5951649.56 641344.83 MWD+IFR 8100.00 62.83 302.96 5433.49 5353.53 4596.91 2850.17 -3609.40 0.00 5951696.51 641269.27 MWD+IFR 8200.00 62.83 302.96 5479.16 5399.20 4685.70 2898.57 -3684.04 0.00 5951743.46 641193.72 MWD+IFR 8300.00 62.83 302.96 5524.83 5444.87 4774.49 2946.97 -3758.68 0.00 5951790.42 641118.16 MWD+IFR I 8400.00 62.83 302.96 5570.50 5490.54 4863.28 2995.37 -3833.33 0.00 5951837.37 641042.61 MWD+IFR I 8500.00 62.83 302.96 5616.17 5536.21 4952.07 3043.78 -3907.97 0.00 5951884.32 640967.05 MWD+IFR I 8600.00 62.83 302.96 5661.83 5581.87 5040.85 3092.18 -3982.61 0.00 5951931.28 640891.50 MWD+IFR 8700.00 62.83 302.96 5707.50 5627.54 5129.64 3140.58 -4057.26 0.00 5951978.23 640815.94 MWD+IFR I 8800.00 62.83 302.96 5753.17 5673.21 5218.43 3188.98 -4131.90 0.00 5952025.18 640740.38 MWD+IFR 8900.00 62.83 302.96 5798.84 5718.88 5307.22 3237.39 -4206.54 0.00 5952072.13 640664.83 MWD+IFR 9000.00 62.83 302.96 5844.51 5764.55 5396.01 3285.79 -4281.19 0.00 5952119.09 640589.27 MWD+IFR 9100.00 62.83 302.96 5890.17 5810.21 5484.80 3334.19 -4355.83 0.00 5952166.04 640513.72 MWD+IFR 9165.22 62.83 302.96 5919.96 5840.00 5542.71 3365.76 -4404.52 0.00 5952196.66 640464.44 SB_OBF_ z 9200.00 62.83 302.96 5935.84 5855.88 5573.58 3382.59 -4430.48 0.00 5952212.99 640438.16 MWD+IFR 9300.00 62.83 302.96 5981.51 5901.55 5662.37 3431.00 -4505.12 0.00 5952259.94 640362.60 MWD+IFR S S S (be Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/11/2006 Time: 16:31;56 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical (TVD) Reference: 28.5+51.46 80.0 Well: Y-07 Section (VS) Reference: Well (O.OON,O.OOE,306.55Azi) Wellpath: Plan Y-07A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooVCo ft deg deg ft ft ft ft ft deg/100ft ft ft 9400. 00 62. 83 302.96 6027.18 5947 .22 5751.16 3479. 40 -4579. 76 0.00 5952306 .90 640287.05 MWD+IFR 9500. 00 62. 83 302.96 6072.85 5992 .89 5839.95 3527. 80 -4654. 41 0.00 5952353 .85 640211.49 MWD+IFR 9600. 00 62. 83 302.96 6118.51 6038 .55 5928.74 3576. 20 -4729. 05 0.00 5952400 .80 640135.94 MWD+IFR 9700. 00 62. 83 302.96 6164.18 6084 .22 6017.53 3624. 60 -4803 .69 0.00 5952447 .75 640060.38 MWD+IFR 9800. 00 62. 83 302.96 6209.85 6129 .89 6106.32 3673. 01 -4878 .34 0.00 5952494 .71 639984.83 MWD+IFR 9900. 00 62. 83 302.96 6255.52 6175 .56 6195.10 3721. 41 -4952 .98 0.00 5952541 .66 639909.27 MWD+IFR 10000. 00 62. 83 302.96 6301.19 6221 .23 6283.89 3769. 81 -5027. 62 0.00 5952588 .61 639833.71 MWD+IFR 10100. 00 62. 83 302.96 6346.86 6266 .90 6372.68 3818. 21 -5102. 27 0.00 5952635 .56 639758.16 MWD+IFR 10200. 00 62. 83 302.96 6392.52 6312 .56 6461.47 3866. 62 -5176. 91 0.00 5952682 .52 639682.60 MWD+IFR 10300. 00 62. 83 302.96 6438.19 6358 .23 6550.26 3915. 02 -5251. 55 0.00 5952729 .47 639607.05 MWD+IFR 10400. 00 62. 83 302.96 6483.86 6403 .90 6639.05 3963. 42 -5326. 20 0.00 5952776 .42 639531.49 MWD+IFR 10500. 00 62. 83 302.96 6529.53 6449 .57 6727.83 4011. 82 -5400. 84 0.00 5952823 .37 639455.94 MWD+IFR 10600. 00 62. 83 302.96 6575.20 6495 .24 6816.62 4060. 23 -5475. 48 0.00 5952870 .33 639380.38 MWD+IFR 10700. 00 62. 83 302.96 6620.86 6540 .90 6905.41 4108. 63 -5550. 13 0.00 5952917 .28 639304.82 MWD+IFR 10800. 00 62. 83 302.96 6666.53 6586 .57 6994.20 4157. 03 -5624 .77 0.00 5952964 .23 639229.27 MWD+IFR 10900. 00 62. 83 302.96 6712.20 6632 .24 7082.99 4205. 43 -5699 .41 0.00 5953011 .18 639153.71 MWD+IFR 10973. 84 62. 83 302.96 6745.92 6665 .96 7148.55 4241. 17 -5754. 53 0.00 5953045 .86 639097.92 Start Dir 4/ i 11000. 00 63. 13 304.09 6757.81 6677 .85 7171.82 4254. 04 -5773. 96 4.00 5953058 .35 639078.25 MWD+IFR 11072. 21 64. 00 307.16 6789.96 6710 .00 7236.46 4291. 70 -5826. 50 4.00 5953094 .98 639025.00 Y-07A T1 11100. 00 62. 89 307.16 6802.39 6722 .43 7261.32 4306. 72 -5846. 31 4.00 5953109 .62 639004.90 MWD+IFR 11200. 00 58. 89 307.16 6851.03 6771 .07 7348.66 4359. 48 -5915. 92 4.00 5953161 .03 638934.29 MWD+IFR 11300. 00 54. 89 307.16 6905.64 6825 .68 7432.40 4410. 07 -5982. 66 4.00 5953210 .32 638866.60 MWD+IFR 11400. 00 50. 89 307.16 6965.97 6886 .01 7512.12 4458. 23 -6046. 20 4.00 5953257 .24 638802.15 MWD+IFR 11500. 00 46. 89 307.16 7031.71 6951 .75 7587.45 4503. 73 -6106. 23 4.00 5953301 .58 638741.25 MWD+IFR 11600. 00 42. 89 307.16 7102.54 7022 .58 7658.00 4546. 36 -6162. 46 4.00 5953343 .10 638684.22 MWD+IFR 11676. 96 39. 81 307.16 7160.31 7080 .35 7708.84 4577. 06 -6202. 98 4.00 5953373 .02 638643.12 End Dir : 11 11700. 00 39. 81 307.16 7178.01 7098 .05 7723.59 4585. 97 -6214. 73 0.00 5953381 .71 638631.20 MWD+IFR 11722. 07 39. 81 307.16 7194.96 7115 .00 7737.72 4594. 51 -6226. 00 0.00 5953390 .02 638619.78 THRZ 11800. 00 39. 81 307.16 7254.82 7174 .86 7787.61 4624. 65 -6265. 76 0.00 5953419 .39 638579.44 MWD+IFR 11806. 69 39. 81 307.16 7259.96 7180 .00 7791.89 4627. 24 -6269. 17 0.00 5953421 .91 638575.98 LCU / BH - 11900. 00 39. 81 307.16 7331.64 7251 .68 7851.63 4663. 32 -6316. 78 0.00 5953457 .07 638527.69 MWD+IFR 12000. 00 39. 81 307.16 7408.46 7328 .50 7915.65 4702. 00 -6367. 80 0.00 5953494 .75 638475.94 MWD+IFR 12100. 00 39. 81 307.16 7485.28 7405 .32 7979.67 4740. 67 -6418. 83 0.00 5953532 .44 638424.18 MWD+IFR 12171. 19 39. 81 307.16 7539.96 7460 .00 8025.24 4768. 20 -6455. 15 0.00 5953559 .26 638387.34 TKNG 12200. 00 39. 81 307.16 7562.09 7482 .13 8043.69 4779. 35 -6469. 85 0.00 5953570 .12 638372.43 MWD+IFR 12300. 00 39. 81 307.16 7638.91 7558 .95 8107.71 4818. 02 -6520. 87 0.00 5953607 .80 638320.67 MWD+IFR 12400. 00 39. 81 307.16 7715.73 7635 .77 8171.73 4856. 70 -6571. 90 0.00 5953645. 48 638268.92 MWD+IFR 12500. 00 39. 81 307.16 7792.55 7712 .59 8235.75 4895. 37 -6622. 92 0.00 5953683 .16 638217.16 MWD+IFR 12600. 00 39. 81 307.16 7869.36 7789 .40 8299.77 4934. 05 -6673. 94 0.00 5953720 .85 638165.41 MWD+IFR 12700. 00 39. 81 307.16 7946.18 7866 .22 8363.79 4972. 72 -6724. 97 0.00 5953758 .53 638113.65 MWD+IFR 12704. 92 39. 81 307.16 7949.96 7870 .00 8366.94 4974. 62 -6727. 48 0.00 5953760 .38 638111.11 TJF 12800. 00 39. 81 307.16 8023.00 7943 .04 8427.81 5011. 40 -6775. 99 0.00 5953796 .21 638061.90 MWD+IFR 12874. 15 39. 81 307.16 8079.96 8000 .00 8475.29 5040. 07 -6813. 83 0.00 5953824 .15 638023.52 TJ E 12900. 00 39. 81 307.16 8099.81 8019 .85 8491.83 5050. 07 -6827. 01 0.00 5953833 .89 638010.14 MWD+IFR i 13000. 00 39. 81 307.16 8176.63 8096 .67 8555.86 5088. 74 -6878. 04 0.00 5953871 .58 637958.39 MWD+-FR ', 13100. 00 39. 81 307.16 8253.45 8173 .49 8619.88 5127. 42 -6929. 06 0.00 5953909. 26 637906.64 MWD+IFR I 13200. 00 39. 81 307.16 8330.27 8250 .31 8683.90 5166. 09 -6980. 08 0.00 5953946. 94 637854.88 MWD+IFR 13225. 64 39. 81 307.16 8349.96 8270 .00 8700.31 5176. 01 -6993. 17 0.00 5953956. 60 637841.61 TJD 13300. 00 39. 81 307.16 8407.08 8327 .12 8747.92 5204. 77 -7031. 11 0.00 5953984. 62 637803.13 MWD+IFR 13400. 00 39. 81 307.16 8483.90 8403 .94 8811.94 5243. 44 -7082. 13 0.00 5954022 .30 637751.37 MWD+IFR 13446. 94 39. 81 307.16 8519.96 8440 .00 8841.99 5261. 60 -7106. 08 0.00 5954039 .99 637727.08 TJC 13500. 00 39. 81 307.16 8560.72 8480 .76 8875.96 5282. 12 -7133. 15 0.00 5954059 .99 637699.62 MWD+IFR 13600. 00 39. 81 307.16 8637.53 8557 .57 8939.98 5320. 79 -7184. 18 0.00 5954097 .67 637647.86 MWD+IFR TM S Company: BP Amoco Field: Prudhoe Bay Site: PB Y Pad Well: Y-07 Wellpath: Plan Y-07A Survey MD Incl Azim ft deg deg 13629.19 39.81 307.16 13700.00 39.81 307.16 13800.00 39.81 307.16 13850.50 39.81 307.16 13900.00 39.81 307.16 13954.64 39.81 307.16 13993.69 39.81 307.16 14000.00 39.81 307.16 14084.82 39.81 307.16 14091.33 39.81 307.16 14100.00 39.81 307.16 14117.36 39.81 307.16 14136.89 39.81 307.16 14143.40 39.81 307.16 14200.00 39.81 307.16 14226.00 39.81 307.16 14226.89 ~ 39.81 307.16 Sperry-Sun BP Planning Report Date: 9/11/2006 Time: 16:31:56 Page: 5 Co-ordinate(NE) Reference: W eII: Y-07, True North Vertical (TVD) Reference: 28.5+51.46 80.0 Section (VS) Reference: Well (O.OON,O.OOE,306.55Azi) Survey Calculation Method: Minimum Curvature Db: Oracle TVD Sys TVD ft ft 8659.96 8580.00 8714.35 8634.39 8791.17 8711.21 8829.96 8750.00 8867.99 8788.03 8909.96 8830.00 8939.96 8860.00 8944.80 8864.84 9009.96 8930.00 9014.96 8935.00 9021.62 8941.66 9034.96 8955.00 9049.96 8970.00 9054.96 8975.00 9098.44 9018.48 9118.41 9038.45 9119.10 ~ 9039.14 VS N/S ft ft 8958.67 5332.08 9004.00 5359.47 9068.02 5398.14 9100.35 5417.67 9132.04 5436.82 9167.02 5457.95 9192.02 5473.05 9196.06 5475.49 9250.36 5508.29 9254.53 5510.81 9260.08 5514.17 9271.20 5520.88 9283.70 5528.43 9287.87 5530.95 9324.10 5552.84 9340.75 5562.90 9341.32 5563.24 E/W DLS MapN ft deg/100ft ft -7199.07 0.00 5954108.67 -7235.20 0.00 5954135.35 -7286.22 0.00 5954173.03 -7311.99 0.00 5954192.06 -7337.25 0.00 5954210.71 -7365.13 0.00 5954231.30 -7385.05 0.00 5954246.02 -7388.27 0.00 5954248.40 -7431.55 0.00 5954280.36 -7434.87 0.00 5954282.81 -7439.29 0.00 5954286.08 -7448.15 0.00 5954292.62 -7458.12 0.00 5954299.98 -7461.44 0.00 5954302.43 -7490.32 0.00 5954323.76 -7503.58 0.00 5954333.56 -7504.04 0.00 5954333.89 MapE Tuol/Coi ft 637632.75 TJ B 637596.11 MWD+IFR 637544.35 MWD+IFR 637518.22 TJA 637492.60 MWD+IFR 637464.32 7" 637444.11 TSHU 637440.84 MWD+IFR 637396.95 TEIL 637393.58 TSAD 637389.09 MWD+IFR 637380.10 POWC 637370.00 Y-07A T2 637366.63 Top HOT 637337.34 MWD+IFR 637323.88 41/2" 637323.42 MWD+IFR S Sperry-Sun Anticollision Report Company: BP Amoco Date: 9/11/2006 Timer 16:24:30 Page: i Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: WeIL' Y-07, True North Reference Well: Y-07 Vertical (T VD) Reference: 28.5+51.46 80.0 Reference Wellpath: Plan Y-07A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Ti~i@sadls in this fiZh7lcipal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 20.00 ft Error Model: ISCWSA Ellipse Depth Range: 2150.00 to 14226.89 ft Scan Method: Trav Cylinder North Maximum Radius: 1619.84 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/9/2005 Validated: No Version: 8 Planned From To Survey Toolcode Tool N ame ft ft 93.16 2150.00 1 : Speny-Sun BOSS gyro multi (93.16-10068~EQT-CMS Gyrodata cont.casing m/s 2150.00 14226.89 Planned: Y-07A wp07 V34 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 5056.30 4049.96 9.625 12.250 9 5/8" 13954.64 8909.96 7.000 8.750 7" 14226.00 9118.41 4.500 6.125 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 H Pad H-10 Plan H-10B V1 Plan: H- 14200.11 12540.00 327.93 320.99 6.94 Pass: Major Risk PB H Pad H-37 H-37A V1 Out of range PB H Pad H-37 Plan H-37B VO Plan: H- 14194.98 12700.00 334.48 327.17 7.31 Pass: Major Risk PB U Pad U-09 Plan U-09B VO Plan: U- 14198.10 13020.00 538.44 605.07 -66.63 FAIL: Major Risk PB U Pad U-10 Plan U-10A V1 Plan: U- 14193.26 13720.00 609.58 390.23 219.35 Pass: Major Risk PB Y Pad Y-04 Y-04 V1 2297.79 2300.00 348.15 35.40 312.75 Pass: Major Risk PB Y Pad Y-05A Y-05A V1 2317.09 2320.00 222.66 35.33 187.33 Pass: Major Risk PB Y Pad Y-05 Y-05 V1 2317.09 2320.00 222.66 35.33 187.33 Pass: Major Risk PB Y Pad Y-06 Y-06 V1 2299.78 2300.00 119.44 34.52 84.93 Pass: Major Risk PB Y Pad Y-06 Y-06A V5 2299.78 2300.00 119.44 34.36 85.08 Pass: Major Risk PB Y Pad Y-06 Y-06APB1 V3 2299.78 2300.00 119.44 34.52 84.93 Pass: Major Risk PB Y Pad Y-07 Y-07 V1 2160.00 2160.00 0.11 0.80 -0.69 FAIL: NOERRORS PB Y Pad Y-08A Y-08A V1 2155.50 2160.00 90.60 39.22 51.38 Pass: Major Risk PB Y Pad Y-08 Y-08 V1 2155.50 2160.00 90.62 39.05 51.57 Pass: Major Risk PB Y Pad Y-09AP61 Y-09AP61 V2 2795.15 2780.00 207.03 41.88 165.14 Pass: Major Risk PB Y Pad Y-09A Y-09A V2 2795.15 2780.00 207.03 41.88 165.14 Pass: Major Risk PB Y Pad Y-09 Y-09 V1 2795.15 2780.00 207.03 41.88 165.14 Pass: Major Risk PB Y Pad Y-10 Y-10 V1 2910.81 2880.00 288.37 43.19 245.18 Pass: Major Risk PB Y Pad Y-10 Y-10A V2 2910.81 2880.00 288.37 43.19 245.18 Pass: Major Risk PB Y Pad Y-11 Y-11 V7 2984.44 2920.00 404.25 44.22 360.03 Pass: Major Risk PB Y Pad Y-11 Y-11A V1 2984.44 2920.00 404.25 44.22 360.03 Pass: Major Risk PB Y Pad Y-11 Y-11 B V3 2984.44 2920.00 404.25 44.22 360.03 Pass: Major Risk PB Y Pad Y-11 Y-11 BP61 V4 2984.44 2920.00 404.25 44.22 360.03 Pass: Major Risk PB Y Pad Y-11 Y-11C V5 2984.44 2920.00 404.25 44.22 360.03 Pass: Major Risk PB Y Pad Y-12 Y-12 V1 3190.65 3120.00 490.74 50.16 440.58 Pass: Major Risk PB Y Pad Y-19 Y-19 V1 3302.90 3240.00 513.01 57.28 455.73 Pass: Major Risk PB Y Pad Y-21A Y-21A V1 2916.53 2880.00 331.41 45.11 286.30 Pass: Major Risk PB Y Pad Y-21 Y-21 V1 2916.53 2880.00 331.41 45.32 286.09 Pass: Major Risk PB Y Pad Y-22 Plan Y-226 V5 2155.89 2300.00 859.77 47.75 812.02 Pass: Major Risk P8 Y Pad Y-22 Y-22 V1 2155.89 2300.00 859.77 47.86 811.91 Pass: Major Risk PB Y Pad Y-22 Y-22A VO 2155.89 2300.00 859.77 47.86 811.91 Pass: Major Risk PB Y Pad Y-23 Y-23 V3 4871.73 4520.00 220.09 113.07 107.02 Pass: Major Risk PB Y Pad Y-23 Y-23A V4 4871.73 4520.00 220.09 113.07 107.02 Pass: Major Risk PB Y Pad Y-23 Y-23AP61 V1 4871.73 4520.00 220.09 113.07 107.02 Pass: Major Risk PB Y Pad Y-23 Y-23APB2 V1 4871.73 4520.00 220.09 113.07 107.02 Pass: Major Risk PB Y Pad Y-23 Y-236 V7 4871.73 4520.00 220.09 113.07 107.02 Pass: Major Risk PB Y Pad Y-24 Y-24 V2 2158.29 2260.00 514.18 33.81 480.38 Pass: Major Risk PB Y Pad Y-25 Y-25 V1 2886.92 2860.00 261.26 41.82 219.44 Pass: Major Risk PB Y Pad Y-26 Y-26 V1 3191.04 3080.00 542.60 50.40 492.20 Pass: Major Risk PB Y Pad Y-26 Y-26A V2 3191.04 3080.00 542.60 50.40 492.20 Pass: Major Risk PB Y Pad Y-28 Y-28 V1 2281.38 2280.00 254.02 31.50 222.52 Pass: Major Risk PB Y Pad Y-29A Y-29A V2 2793.53 2780.00 163.94 37.52 126.43 Pass: Major Risk Sperry-Sun Anticollision Report Company: BP Amoco Dater 9/11/2006 Time: .16:24:30 Page:. 2 Field:. Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reterence: Well: Y-07, True North Reference Well: Y-07 Vertical (TVD) Reference: 28.5+51 ,46 80.0 Reference Wellpath: Plan Y-07A Db: Oracle 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 Y Pad Y-29 Y-29 V1 2793.53 2780.00 163.94 37.52 126.43 Pass: Major Risk PB Y Pad Y-30 Y-30 V3 2583.98 2580.00 65.38 32.69 32.69 Pass: Major Risk PB Y Pad Y-30 Y-30L1 V3 2583.98 2580.00 65.38 32.69 32.69 Pass: Major Risk PB Y Pad Y-31 Y-31 V1 2359.95 2360.00 42.06 33.24 8.82 Pass: Major Risk PB Y Pad Y-32 Y-32 V7 2171.76 2180.00 161.87 38.72 123.14 Pass: Major Risk PB Y Pad Y-32 Y-32L1 V2 2171.76 2180.00 161.87 38.72 123.14 Pass: Major Risk PB Y Pad Y-33 Y-33 V1 2319.52 2320.00 145.43 29.16 116.27 Pass: Major Risk PB Y Pad Y-34A Y-34A V3 2298.87 2300.00 404.23 29.55 374.67 Pass: Major Risk PB Y Pad Y-34 Y-34 V1 2298.87 2300.00 404.23 29.55 374.67 Pass: Major Risk PB Y Pad Y-37 Y-37 V1 2155.45 2160.00 383.94 30.88 353.06 Pass: Major Risk P8 Y Pad Y-37 Y-37A V8 2155.45 2160.00 383.94 30.90 353.04 Pass: Major Risk PB Y Pad Y-37 Y-37AP61 V3 2155.45 2160.00 383.94 30.90 353.04 Pass: Major Risk Site: PB H Pad Well: H-10 Rule Assigned: Major Risk Wellpath: Plan H-106 V1 Plan: H-106 wp01 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+A ZI TFO-HS Casing/HSflistance Area Deviation Wa rning ft ft ft ft ft ft deg deg ir- ft ft ft 13224.13 8348 .80 10760.00 8300.57 63.83 31 .45 34 .49 87.33 8.500 1619.26 275.94 1343.32 Pass 13237.24 8358 .87 10780.00 8314.14 63.89 31 .53 34 .67 87.51 8.500 1604.95 276.07 1328.87 Pass 13250.35 8368 .95 10800.00 8327.72 63.95 31 .61 34 .84 87.68 8.500 1590.65 276.20 1314.45 Pass 13263.47 8379 .02 10820.00 8341.29 64.01 31 .69 35 .02 87.86 8.500 1576.37 276.32 1300.05 Pass 13276.58 8389 .09 10840.00 8354.86 64.07 31 .77 35 .20 88.04 8.500 1562.11 276.44 1285.67 Pass 13289.69 8399 .17 10860.00 8368.43 64.14 31 .85 35 .38 88.22 8.500 1547.86 276.55 1271.31 Pass 13302.81 8409 .24 10880.00 8382.00 64.20 31 .93 35 .57 88.41 8.500 1533.63 276.66 1256.97 Pass 13315.92 8419 .31 10900.00 8395.58 64.26 32 .01 35 .76 88.60 8.500 1519.41 276.76 1242.65 Pass 13329.03 8429 .38 10920.00 8409.15 64.32 32 .09 35 .96 88.80 8.500 1505.21 276.85 1228.36 Pass 13342.15 8439 .46 10940.00 8422.72 64.38 32 .17 36 .16 89.00 8.500 1491.03 276.94 1214.09 Pass 13355.26 8449 .53 10960.00 8436.29 64.44 32 .25 36 .36 89.20 8.500 1476.87 277.02 1199.85 Pass 13368.37 8459 .60 10980.00 8449.87 64.51 32 .33 36 .57 89.40 8.500 1462.73 277.09 1185.64 Pass 13381.48 8469 .68 11000.00 8463.44 64.57 32 .41 36 .78 89.61 8.500 1448.61 277.16 1171.45 Pass 13394.60 8479 .75 11020.00 8477.01 64.63 32 .49 36 .99 89.83 8.500 1434.50 277.22 1157.29 Pass 13407.71 8489 .82 11040.00 8490.58 64.69 32 .57 37 .21 90.05 8.500 1420.42 277.27 1143.15 Pass 13420.82 8499 .90 11060.00 8504.16 64.75 32 .64 37 .43 90.27 8.500 1406.36 277.31 1129.05 Pass 13433.94 8509 .97 11080.00 8517.73 64.82 32 .72 37 .66 90.50 8.500 1392.32 277.34 1114.97 Pass 13447.05 8520 .04 11100.00 8531.30 64.88 32 .80 37 .89 90.73 8.500 1378.30 277.37 1100.93 Pass 13460.16 8530 .11 11120.00 8544.87 64.94 32 .88 38 .13 90.97 8.500 1364.30 277.39 1086.91 Pass 13473.27 8540 .19 11140.00 8558.45 65.00 32 .96 38 .37 91.21 8.500 1350.33 277.40 1072.93 Pass 13486.39 8550 .26 11160.00 8572.02 65.06 33 .04 38 .62 91.46 8.500 1336.38 277.40 1058.99 Pass 13499.50 8560 .33 11180.00 8585.59 65.13 33 .12 38 .87 91.71 8.500 1322.46 277.39 1045.08 Pass 13512.61 8570 .41 11200.00 8599.16 65.19 33 .20 39 .13 91.97 8.500 1308.57 277.37 1031.20 Pass 13525.73 8580 .48 11220.00 8612.74 65.25 33 .28 39 .39 92.23 8.500 1294.70 277.34 1017.36 Pass 13538.84 8590 .55 11240.00 8626.31 65.31 33 .36 39 .66 92.50 8.500 1280.86 277.30 1003.56 Pass 13551.95 8600 .63 11260.00 8639.88 65.37 33 .44 39 .94 92.77 8.500 1267.05 277.25 989.80 Pass 13565.07 8610 .70 11280.00 8653.45 65.44 33 .52 40 .22 93.05 8.500 1253.27 277.19 976.08 Pass 13578.18 8620 .77 11300.00 8667.03 65.50 33 .60 40 .50 93.34 8.500 1239.52 277.12 962.40 Pass 13591.29 8630 .84 11320.00 8680.60 65.56 33 .68 40 .80 93.63 8.500 1225.80 277.03 948.77 Pass 13604.40 8640 .92 11340.00 8694.17 65.62 33 .76 41 .10 93.93 8.500 1212.11 276.94 935.17 Pass 13617.52 8650 .99 11360.00 8707.74 65.68 33 .84 41 .40 94.24 8.500 1198.46 276.83 921.63 Pass 13630.63 8661 .06 11380.00 8721.32 65.75 33 .92 41 .72 94.56 8.500 1184.84 276.71 908.13 Pass 13643.74 8671 .14 11400.00 8734.89 65.81 34 .00 42 .04 94.88 8.500 1171.26 276.58 894.68 Pass 13656.86 8681 .21 11420.00 8748.46 65.87 34 .07 42 .37 95.21 8.500 1157.72 276.44 881.28 Pass 13669.97 8691 .28 11440.00 8762.03 65.93 34 .15 42 .70 95.54 8.500 1144.22 276.28 867.94 Pass 13683.08 8701 .36 11460.00 8775.61 65.99 34 .23 43 .05 95.89 8.500 1130.75 276.11 854.65 Pass uJ:u ur l'.v LS ANTI-COLLISION SETTINGS (tMll'.dN1' UGI AILX SVNVIi I' I'RIXiNAAi hanu N-S I:,.\\' NruXhnlg rann^_ LinruJ Lun_nWe tilor I11';vlux'.r IhMh Hru Ik'Mh to Srery.l'lan "l rxd In4rpolafion A7cIhoJ:MD Imm~'al. 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'J -; GIN IU 111X1 IrIXI 'IiJI ?_' Y-07ai (WP-07) TMD Inc Az TVD 2150.00 0.89 211.23 2149.88 2170.00 1.92 99.45 2169.88 2200.00 1.43 60.85 2199.87 2270.00 3.07 355.14 2269.82 2300.00 4.03 343.35 2299.76 2400.00 7.72 327.64 2399.22 2500.00 11.62 322.23 2497.78 2600.00 15.57 319.52 2594.96 2700.00 19.54 317.89 2690.28 2800.00 23.52 316.79 2783.29 2900.00 27.51 316.00 2873.51 3000.00 31.50 315.39 2960.53 3011.09 31.94 315.34 2969.96 3100.00 35.49 314.91 3043.91 3200.00 39.48 314.51 3123.24 3275.14 42.48 314.26 3179.96 3300.00 43.48 314.18 3198.14 3400.00 47.47 313.89 3268.25 3500.00 51.47 313.64 3333.23 3600.00 55.46 313.41 3392.75 3700.00 59.46 313.20 3446.52 3800.00 63.46 313.01 3494.30 3807.38 63.75 313.00 3497.58 3900.00 63.75 313.00 3538.54 3903.21 63.75 313.00 3539.96 4000.00 63.75 313.00 3582.77 4100.00 63.75 313.00 3627.00 4200.00 63.75 313.00 3671.23 4300.00 63.75 313.00 3715.46 4400.00 63.75 313.00 3759.69 4500.00 63.75 313.00 3803.92 4600.00 63.75 313.00 3848.14 4700.00 63.75 313.00 3892.37 4800.00 63.75 313.00 3936.60 4900.00 63.75 313.00 3980.83 5000.00 63.75 313.00 4025.06 5056.30 63.75 313.00 4049.96 5100.00 63.75 313.00 4069.29 5200.00 63.75 313.00 4113.52 5300.00 63.75 313.00 4157.75 5400.00 63.75 313.00 4201.98 5407.38 63.75 313.00 4205.24 5500.00 63.28 308.89 4246.55 5540.82 63.12 307.07 4264.96 5600.00 62.92 304.43 4291.82 5632.69 62.83 302.96 4306.72 5700.00 62.83 302.96 4337.46 5800.00 62.83 302.96 4383.13 5900.00 62.83 302.96 4428.80 6000.00 62.83 302.96 4474.47 Y-07ai wp-07.x1s • • 6100.00 62.83 302.96 4520.13 6200.00 62.83 302.96 4565.80 6300.00 62.83 302.96 4611.47 6400.00 62.83 302.96 4657.14 6500.00 62.83 302.96 4702.81 6600.00 62.83 302.96 4748.47 6700.00 62.83 302.96 4794.14 6800.00 62.83 302.96 4839.81 6822.23 62.83 302.96 4849.96 6900.00 62.83 302.96 4885.48 7000.00 62.83 302.96 4931.15 7100.00 62.83 302.96 4976.81 7200.00 62.83 302.96 5022.48 7300.00 62.83 302.96 5068.15 7400.00 62.83 302.96 5113.82 7500.00 62.83 302.96 5159.49 7566.73 62.83 302.96 5189.96 7600.00 62.83 302.96 5205.15 7700.00 62.83 302.96 5250.82 7800.00 62.83 302.96 5296.49 7900.00 62.83 302.96 5342.16 8000.00 62.83 302.96 5387.83 8100.00 62.83 302.96 5433.49 8200.00 62.83 302.96 5479.16 8300.00 62.83 302.96 5524.83 8400.00 62.83 302.96 5570.50 8500.00 62.83 302.96 5616.17 8600.00 62.83 302.96 5661.83 8700.00 62.83 302.96 5707.50 8800.00 62.83 302.96 5753.17 8900.00 62.83 302.96 5798.84 9000.00 62.83 302.96 5844.51 9100.00 62.83 302.96 5890.17 9165.22 62.83 302.96 5919.96 9200.00 62.83 302.96 5935.84 9300.00 62.83 302.96 5981.51 9400.00 62.83 302.96 6027.18 9500.00 62.83 302.96 6072.85 9600.00 62.83 302.96 6118.51 9700.00 62.83 302.96 6164.18 9800.00 62.83 302.96 6209.85 9900.00 62.83 302.96 6255.52 10000.00 62.83 302.96 6301.19 10100.00 62.83 302.96 6346.86 10200.00 62.83 302.96 6392.52 10300.00 62.83 302.96 6438.19 10400.00 62.83 302.96 6483.86 10500.00 62.83 302.96 6529.53 10600.00 62.83 302.96 6575.20 10700.00 62.83 302.96 6620.86 10800.00 62.83 302.96 6666.53 10900.00 62.83 302.96 6712.20 Y-07ai wp-07.x1s w n 10973.84 62.83 302.96 6745.92 11000.00 63.13 304.09 6757.81 11072.21 64.00 307.16 6789.96 11100.00 62.89 307.16 6802.39 11200.00 58.89 307.16 6851.03 11300.00 54.89 307.16 6905.64 11400.00 50.89 307.16 6965.97 11500.00 46.89 307.16 7031.71 11600.00 42.89 307.16 7102.54 11676.96 39.81 307.16 7160.31 11700.00 39.81 307.16 7178.01 11722.07 39.81 307.16 7194.96 11800.00 39.81 307.16 7254.82 11806.69 39.81 307.16 7259.96 11900.00 39.81 307.16 7331.64 12000.00 39.81 307.16 7408.46 12100.00 39.81 307.16 7485.28 12171.19 39.81 307.16 7539.96 12200.00 39.81 307.16 7562.09 12300.00 39.81 307.16 7638.91 12400.00 39.81 307.16 7715.73 12500.00 39.81 307.16 7792.55 12600.00 39.81 307.16 7869.36 12700.00 39.81 307.16 7946.18 12704.92 39.81 307.16 7949.96 12800.00 39.81 307.16 8023.00 12874.15 39.81 307.16 8079.96 12900.00 39.81 307.16 8099.81 13000.00 39.81 307.16 8176.63. 13100.00 39.81 307.16 8253.45 13200.00 39.81 307.16 8330.27 13225.64 39.81 307.16 8349.96 13300.00 39.81 307.16 8407.08 13400.00 39.81 307.16 8483.90 13446.94 39.81 307.16 8519.96 13500.00 39.81 307.16 8560.72 13600.00 39.81 307.16 8637.53 13629.19 39.81 307.16 8659.96 13700.00 39.81 307.16 8714.35 13800.00 39.81 307.16 8791.17 13850.50 39.81 307.16 8829.96 13900.00 39.81 307.16 8867.99 13954.64 39.81 307.16 8909.96 13993.69 39.81 307.16 8939.96 14000:00 39.81 307.16 8944.80 14084.82 39.81 307.16 9009.96 14091.33 39.81 307.16. 9014.96 14100.00 39.81 307.16 9021.62 14117.36 39.81 307.16 9034.96 14136.89 39.81 307.16 9049.96 14143.40 39.81 307.16 9054.96 14200.00 39.81 307.16 9098.44 • Y-07ai wp-07.x1s 14226.00 39.81 307.16 9118.41 14226.89 39.81 307.16 9119.10 • Y-07ai wp-07.x1s = ti" CNV 1NELLHEAD = GRAY ACTUATOR = OTIS KB. ELEV = 86.76' BF. ELEV = 51.46' KOP = 3100' Max Angle = 25 @ 5100' Datum MD = 9258' Datum TV D = 8800' SS ~~07i S NOTES: Current 20" Conductor -110' - 2134' 4-1/2" OTIS SSSV NIP, ID = 3.813" 2,200` - Calc TOC 2600' 9-5/8" DV Pkr 13-3/8" CSG, 72#, L-80, ID = 12.347" (~ 2685' Calc TOC (zero excess) - -5,286`` Minimum ID = 2.635" @ 8680' 3-1/2" OTIS XN NIPPLE I I 8524' ~J 4-1/2" SLIDING SLEEV E ID = 3.813" 4-1l2" TBG SEAL ASSY I 9-5/8" x 4-1 /2" TNV HBBP PKR, ID = 4.0" 4-1/2" X 3-1/2" XO PXN Plug Installed (10/31/05) 8647' 3-1/2" OTIS X NIP, ID = 2.75" TOP OF 7" LNR 8683' 8680° 3-1/2" OTIS XN NIP, ID = 2.635" 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 8713' 871'3' 3-1/2"SHEAROUTSUB 8713' 3-1/2" WLEG 8698' ELMD TT LOGGED 09/25/90 9-5/8" CSG, 47#, L-80, ID = 8.681" 9187' PERFORATION SUMMARY REF LOG: BHCS ON 05/14/81 ANGLE AT TOP PERF: 14 @ 9288' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 9288 - 9314 O 12/05/86 2-1/8" 4 9398 - 9442 O 12/05/86 PBTD --~ 9906, 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10075' 9310' H MA RKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 12/05/85 ORIGINAL COMPLETION 08/24/01 RNrTP CORRECTIONS 06/28/03 JRCJKK CORRECTIONS 11 /06/05 WTS/TL SET PXN PLUG (10/31 /05) PRUDHOE BAY UNrr WELL: Y-07 PERMrr No: x1810180 API No: 50-029-20580-00 SEC 34, T11N, R13E,1341' SNL & 118' EWL BP 6cploration (Alaska) EE = 6" CM/ WELLHEAD = GRAY ACTUATOR = OTIS KB. ELEV = 86.76' BF. ELEV = 51.46' KOP = 3100' Max Angle = 25 @ 5100' Datum MD = 9258' Datum TV D = 8800' SS Jet Cut TBG - --2600' MD 13-3/8" CSG, 72#, L-80, ID = 12.347" 2685' Minimum ID = 2.635" @ 8680' 3-1/2" OTIS XN NIPPLE Calc TOC (zero excess) - _5,286' - TOC - --8,500' ~ 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" ~ 8602' TOP OF 3-1/2" TBG TAIL 8602' TOP OF 7" LNR 8683' 3-1/2" TBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" 8713' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9187' PERFORATION SUMMARY REF LOG: BHCS ON 05/14/81 A NGLE AT TOP PERF: 14 @ 9288' Note: Refer to Production DB for historical oerf data S-ZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 2-1/8" 4 4 9288 - 9314' 9398 - 9442' O O 12/05/86 12/05/86 PBTD 9906' 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 10075' Y-07 Pre-Rig 2134' ~J4-1/2" OTIS SSSV NIP, ID = 3.813" -2,200` - Calc TOC 2600' 9-5/8" DV PKR 8524' ~4-1/2" SLIDING SLEEVE ID = 3.813" 8587' 4-1/2" TBG SEAL ASSY 8602' 9-5/8" x 4-1/2" TM/ HBBP PKR, ID = 4.0" 8602' 4-1/2" X 3-1/2" XO $647' 3-1/2" OTIS X NIP, ID = 2.75" 8680' 3-1 /2" OTIS XN NIP, ID = 2.635" 8713' 3-1/2" SHEAROUT SUB 8713' 3-v2° wLEc 8698' ELMD TT LOGGED 09/25/90 ~' 9310' H MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 12/05/85 ORIGINAL COMPLETION 06/24/01 RN~TP CORRECTIONS 06/28/03 JRGKK CORRECTIONS 12/12/05 KWA Pre-Rig w ork PRUDHOE BAY UNrr WELL: Y-07 PERMrr No: 1810180 API No: 50-029-20560-00 SEC 34, T11 N, R13E,1341' SNL & 118' EWL BP Exploration (Alaska) TRFF Y-07AI DATE REV BY COMMENTS DATE REV BY COMMENTS 12/05/85 ORIGINAL COMPLETION 06/24/01 RN/TP CORRECTIONS 06/28/03 JRGKK CORRECTIONS 12/07/05 KWA Proposed Completion PRUDHOE BAY UNff WELL: Y-07 PERMff No: 1810180 API No: 50-029-20560-00 SEC 34, T11N, R13E,1341' SNL & 118' EWL BP 6cploration (Alaska) KB: ~~ - Pre-Sidertack ~~G - Y-07AI Proposed Completion -2200' MD HES 4-1/2" X Nipple ID = 3.813" ~ -2150` MD -Top of Window in 13-3/8" Casing ~9-5/8" ES Cementer at 2650' MD ~ 4-1/2", 12.6#, L-80, TC-II TBG 13-3/8"CIBP - -2180' 9-5/8" Mechanical Cut - -2185' Calc TOC - "-2200` 9-5/8" CIBP - -2550' - Jet Cut TBG - -" 2600' - 9-5/8" DV Sub - _ 2600` 13-3/8" CSG, 72#, L-80, ID = 12.347" 2685 / Calc TOC (zero excess) - -"5,286' - / -8785` MD -BKR HGR &LTP w/TB sleave I -8935` MD - 9-5/8", 40#, L-80, Casing ~ ~ (TC-II f/surf to 2650' MD /BTC (/2650' - 8935' MD) -13,786` MD 4-1/2" X Nipple ID = 3.813" --13,796' MD BKR 7" x 4-1/2" S3 PKR -13,816' MD 4-1/2" X Nipple ID = 3.813" 13,836' MD 4-1/2" XN Nipple ID = 3.725" -13,846' MD 4-1/2" WLEG /~ "-13,846' MD -BKR HGR &LTP wlTB sleeve -13,946` MD - 7", 26#, L-80, BTC-M ~ -4-1/2", 12.6#, L-80, IBT-M - -14,227` MD I TOP OF 7" LNR I 9-5/8" CSG. 47#. L-80. ID = 8.881" TOC - -8,500' J - J~4-112' SLIDING SLEEVE ID = 3.013" I 4-112" TBG SEAL ASSV • 9-SIB" x 4-112" TIW HBBP PKR, ID = 4.0" 4-1 /2' X 3-7 /2" XO • 3-i/2" OTIS X NIP, ID = 2.75' • 3-1 /2" OTIS XN NIP, ID = 2.635" • 3-112" SHEA RO UT SUB • 3-112"WLEG • ELMD TT LOGGED 09/25/90 MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 12/05/85 ORIGINAL COMPLETION 06/24/01 RN/TP CORRECTIONS 06/28/03 JRGKK CORRECTIONS 07/25/07 JGR Proposed Completion PRUDHOE BAY UNfT WELL: Y-07 PERMff No: x1810180 API No: 50-029-20560-02 SEC 34, T11 N, R13E,1341' SNL & 118' EWL BP 6Lploration (Alaska) Y-07Ai PTD • • Maunder, Thomas E (DOA) Page 1 of 1 From: Rose, John G (FAIRWEATHER) [John.G.Rose@bp.com] Sent: Tuesday, July 31, 2447 14:08 AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L; Hobbs, Greg S (ANC) Subject: Y-07Ai PTD Attachments; Y-47A wp07 NEW.pdf Tom, Per our conversation today, please note the attached directional plan that has the correct casing program for the planned Y-07Ai sidetrack. The directional program that was previously submitted with the Drilling Permit application is correct in terms of the directional data and the anti-collision work, but it shows an early iteration of the directional plan where the 9-5/8" casing string was positioned at a shallower setting depth. Thanks for your help and let me know if t can be of further help. - jr «Y-07A wp47 NEW.pdf» John G. Rose BP-Alaska Drilling Group Office 907/564-5271 Ce/! 907/748-5223 Fax 9071564-4040 7/31 /2007 -- Start Dir 12/IOU''. 2150' MD, 2149.88TVD SV4 8` Start Dir 41100' _ 2170' MD. 2169.88'TVD t6, End Dir 3807.38' MD, 349758' TVD • O 0 6 0 u IN 2 t-" FORMATION TOP DETAILS No. TVDPath MDPath Formation I 238896 2389.65 SV4 2 297196 3013.45 SV3 3 319596 3296.99 SVZ 4 3541.96 3907.73 SVI 5 4056 96 5072.13 UG4 6 4275 96 5565 I I UG3 7 4848.96 6820.04 UGI B 5303 96 7816.36 WS2 9 5549.96 8355.03 WSI 10 5755.96 8806.11 CM3 11 6216.96 9815.57 CM2 12 6902.96 11295.32 CMI 13 7218 96 11753 3I THRZ 14 7464 96 12073.55 LCU / BHRZ / TKNG IS 7977.96 12741.37 T1F 16 8109.96 12913.21 TJE 17 8405.96 13298.54 T1D IS 8594.96 13544.58 TJC' 19 8733.96 13725.53 TJB 20 8902.96 13945.53 TSGR 21 89289E 13979.37 TSHI! 22 9014.96 14091.33 TSAD 23 9054.96 14143.40 'Top HOT u iHVl.l' I'K~x~w..~. NI%n Y-~ %~\ ~.i - - ~]~I'Ivl Y-IiiAi IhVlh hin Ih'Vlh I.~ xm..^I'Iwi livil ~namJ HY lirlc l' Ilulllburu`n i)alc v/IS/21)(k~ 2150 OU IJ22n tlv i•lenn~rl Y-u]n .vlxil VSJ MWI/~IhR~M.~ C:hcc Avd I)u(c Itc. mw °J Uac W h:l.l. 111:1 All ti Nn m. -N-~ -u' N,~nlcnµ I~.ualelµ ..ac me. I~r FmJ. xl.~i v.i i~ J111 t. -3XUtl 1J 5/J %Y In Sx WJV t2 m1 ]II`I(~14 ](~%N IJN'J`Ylll ]~%W N?. IAksn~'I UI-:rAll.ti ram. IVII N-~ t.-W Nunhmµ ~.a Unµ xhep. Y-u9A ll ~J%v vl~ J2vl'~~ -Sx2n to 5v5mvY V% itvu25 UU 1'uin: Y-U]A r2 11iJ~/I 'i2x J+ -iJSx l1 liJ2vv vx nr]1]U Ue Y°in~ tiEC"PION DET.41L5 Sec MD Inc Azl "PVD -N/-S ~E/-W DLeg TFace VSec Target 1 2150.00 0.89 211.23 2149.88 -15.25 1.19 000 OW -10.04 2170.00 1.92 99.45 216988 -15.44 L44 12.00 228.00 -10.35 Stan Dtr 4/I W''S4O738'MD, 42U524TVD 3 2270.00 3.07 355.14 2269.82 -13.05 287 4.00 228.00 -10.08 69' MD. 43U6.72'1VD ' End Dir 5632 4 3807.38 63.75 313.00 3497 58 553 58 -55991 4.00 316 78 779.47 . 5 5407.38 63.75 313.00 4205.24 1532.24 -160940 0.00 0.00 2205.39 _ 6 5632.69 62.83 302.96 4306.72 1655.93 -1767.71 400 -98.12 2406.22 ' 7 10973.84 62.83 302.96 6745.92 4241.17 -5754.53 0.00 0.00 7148.55 ' 8 11072.21 6400 307.16 6789.96 429L70 -5826.50 400 73.60 723646 Y-07A T1 '~ ~~/ ~ 9 11676.96 39.81 307.16 7160.31 457706 -6202.98 400 -180.00 7708.84 10 14136.89 39.81 307.16 9049 96 5528.43 -7458.12 0.00 0.00 9283.70 Y-07A T2 - LG:1 -!.- I1 14226.89 39.81 307.16 911910 886324 -750404 000 0.00 934132 - 700 ' - --- REFFRF:NC'L INtt>kMAI'I(1N ' ~ - ~ ~ ..a Jmely (N L~.l kclelw.:e Welllulu° Y-U].Imc NVNi `, -~ V IfIVD)R1 2XS~SI JG]Y4 I - W52' ~~ )a; fV%IRI SI -(U WN,000I.I M ~ vn J i XIXNI W S I - C amr uanM thuJ: Mm mu I ula '--r-- -~'--' -' ~ ----- . - (' ~/ 3 CASING DETAILS ~ - No TVD MD Name Slze -- I 5814 96 8935.30 9 5/8" 9.625 - - - _ - - - 8909.96 13954.64 7" 7.000 . . _ _ __.. - CM2 - - z 9118.41 14226.00 4 1/2" 4.500 - -- 118100 _. _:__:..,.-. _' .. ~ '.-'. - --;- _ Start Dlr 4/100'' 111973.8T MD. 6745.92TVD _ _ 11 hr 0 CM1' P End Dir ' 11676.96' htD. 7160.31' TVD _ _ TiB TSGR 41/2„ T AD _.- Top iQT _r Total ~pth '. 14226.N9'MD, 9P I~I -0 UO 3000 4000 5000 6000 7000 8000 9000 Vertical Section at 306.55° [10(X)tt/in] C'UMNANY UETAILA aY Amuw ~alwlnnm Mwhud. Mwiwuw l.'un nwa Frtw 5).¢m. IAIW'SA 4ai McIAuJ 7'ra+ C\ImJcr NuM f:rt.n lurrwc t:IhpUVal - C++wA Wuning McthoJ. Rules BnrnJ Total Depth '. 14226.89' MD, 9l 19.1' TVD 4 I/2' _07A T2 v.rrµkacl. ;N l~`tcmn u~ln .cla kr rw n~Knn~ ~.:~~ -,~ ..,,,~ . ~- . ~.,~~ - . 1 .1 urJinnclNk.l Relnm+c W.Ilimu~ Y-U: Irv. Nu1Ui 1)cl,~h km IklnU l.. ~m~.. I'Ibr I~.~1 _~~uI~J N\ 1.~i+.' liulhnwiul~ ~/au. •,:1 ~~.~tln \ VcrUwI1TVU)Re(ermcc:2b 55106 ]9 v~~. Sw'n~w lVppSl Rcrwwa alul-IU WN)`WI-~ :I)U itl~ IJ226 nv Ylnnncd Y-Utn ~+pU]Y7. MWU~IkR-A1J l,'L+~uAcJ I)aLL Mu+wallwl:n .x cMeOwJ Mwunum(l'ui~aw~c" - t\'I-:I.I. Uk: !'All ~ Nnm. ~rv-s ~...w N~.~mntl I~.n,nntl Lw1wc. - ~ ~, .w. Y-llt J1117~ -2MUtl VV 59JA91G 5tl (WdY 11 (.U ]U`I(iUJ 26bN IVA'4Y'JU t7b1\' N/. '. ARlil~~l Uk:I AILS N.m+ 1'Vll N-S ~I~.-W NuOhinM I-xaUnu Shay. V-u]A'I' 1 L]A9 Y6 1291 t0 -SA26 50 5957094 9A 6)9025110 Pwoi 1-utn'I: 914)96 552A d7 -td5A 12 S95d2999A 4PJtUW Yuiw SECTION DETAILS Sec MD Inc Azl TVD +N/-S +E/-W DLeg TFace VSec Target I 2150.00 0.89 211.23 2149.88 -15.25 1.19 0.00 0.00 -10.04 2 2170 00 1.92 99.45 '_ 169.88 -1 S 44 1.44 12.00 228 00 -10.35 3 2270.00 3.07 355.14 2269.82 -13.05 2.87 4.00 228.00 -10.08 4 3807.38 63 75 313.00 3497.58 553.58 -559.91 4.00 316.78 779.47 5 5407 38 63 75 313.00 4205 24 153224 -1609.40 0.00 0 W ^_205.39 6 5632.69 62 83 302.96 4306.72 1655.93 -1767 71 4.00 -98.12 '_406.22 7 10973.84 62.83 302.96 6745.92 4241.17 -5754 S3 0.00 O.W 7148.55 8 11072.21 (14.00 307.16 6789.96 4291.70 -5826.50 4.00 73.60 7236.46 Y-07A T1 9 1 1676 96 39.81 307 16 7160.31 4577.06 -6202.98 4.00 -180 00 7708.84 10 14136.89 39.81 307.16 9049.96 5528.43 -7458.12 0.00 0.00 9283.70 Y-07A T2 Il 14226.89 39.81 307.16 9119.10 5563.24 -7504.04 0.00 0.00 9341.32 CASING DETAll.S No 1'VU MD Name Slze 1 5814.96 8935.30 9 S/8" 9.625 8909.96 !3954.64 7" 7.000 3 9118.41 14226.00 41/2" 4.500 8000 End Der - 11676.96' MD. 7160.31' TVD 75001 Start Dlr 4/100' 10973 84' MD, 6745.92'TVD -- ~ 7 0 =~'-07A T1 4067 -~- 6500 ,'I _. L O z s 0 N FORMATION TOP DETAILS u. TVDPath MDPath Fom7ahon I 2388.96 2389.65 SV4 2 2971.96 3013.45 SV3 3 3195.96 3296.99 SVZ 4 3541.96 3907.73 SVI 5 4056.96 5072.13 UG4 6 4275 96 5565.11 UG3 7 4848 96 6820.04 UG I 8 5303.96 7816.36 WS2 9 55499ti 8355.03 WSI 10 5755.96 8806.11 CM3 11 6216.96 9815.57 CM2 12 6902 96 11295.32 CM I 13 7218.96 11753.31 THRZ 14 7464.96 12073.55 LCU / BHRZ / TKNG 15 7977.96 12741.37 T1F 16 8109 96 12913.21 TJE 17 8405.96 13298.54 T1D l8 8594.96 13544.58 TJC 19 8733.96 13725.53 TJB 20 8902.96 13945.53 TSGR 21 8928.96 13979.37 TSHU 22 9014.96 14091.33 TSAD 23 9054.96 14143.40 Top HOT Dir 5632 69' MD, 4306.72' TVD Start Dv 4/ I W' - 5407 38' MD, 4205.24'TVD End Dlr 3807 38' MD, 3497.58' TVD Start Dv 4/1 W' ' 2170' MD, 2169 88'TVD *+- *-~' ~ / Stan Dv 12/100'' 2150' MD, 2149.88'TVD -4067 -3050 -2034 -1017 0 I West(-1/East!+)1t~1 Halliburton Company Survey Report Company: BP Amoco Date: 9/15/2006 Time: 13:31:34 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical (TVD) Reference: 28.5+51.46 80.0 Well: Y-07 Sectioe (VS) Reference: Welt (O.OON,O.OpE, 306.55Azi) Wellpath: Plan Y-07A Survey Calculation Method: 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) Coordiuate System: Well Centre ', Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 _ - Site: PB Y Pad _ _ - TR-11-13 ' !, UNITED STATES :North Slope ! Site Position: Northing: 5948541.48 ft Latitude: 70 16 0.041 N From: Map Easting: 647748.73 ft Lougitude: 148 48 18.991 W Position Uncertainty: 0.00 ft North Reference: True ', Grouud Level: 0.00 ft Grid Convergence: 1.12 deg l Well: Y-07 Slot Name: Y-07 ' Surface Position: +N/-S 430.33 ft Northing: 5948916.58 ft Latitude: 70 16 4.268 N +E/-W -2808.44 ft Easting : 644932.60 ft Longitude: 148 49 40.738 W Position Uncertainty: 0.00 ft !, Reference Poiut: +N/-S 430.33 ft Northing: 5948916.58 ft Latitude: 70 16 4.268 N +E/-W -2808.44 ft Easting : 644932.60 ft Lougitude: 148 49 40.738 W Measured Depth: 28.50 ft Iuclinatiou: 0.00 deg Vertical Depth: L 28.50 ft Azimuth : 0.00 deg - _ _ Wellpath: Plan Y-07A Drilled From: - Y-07 - - -I ', Tie-on Depth: 2150.00 ft Current Datum: 28.5+51.46 Height 79.96 ft Above System Datum: Mean Sea Level Magnetic Data: 8/9/2005 Declination: 24.75 deg Field Strength: 57595 uT Mag Dip Angle: 80.85 deg I Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg - 28.50 0.00 0.00 306.55 Survey Program for Definitive Wellpath ' Date: 8/9/2005 Validated: No Version: 8 Planued From To Survey Toolcode Tool Name ! ft ft _ 93.16 2150.00 1 : Sperry-Sun BOSS gyro multi GYD-CT-CMS Gyrodata cont.casing m/s 2150.00 14226.89 Planned: Y-07A wp07 V34 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Iucl Azim TVD +N/-S +E/-W _ VS DLS Build Taru TooUComment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 28.50 0.00 0.00 28.50 ~ 0.00 0.00 0.00 0.00 0.00 0.00 TIE LINE 128.50 0.91 176.65 128.49 -1.07 0.15 -0.76 0.91 0.91 0.00 GYD-CT-CMS 228.50 0.91 189.35 228.48 -2.65 0.02 -1.59 0.20 0.00 12.69 GYD-CT-CMS 328.50 0.89 191.98 328.47 -4.18 -0.26 -2.28 0.04 -0.01. 2.63 GYD-CT-CMS ', 428.50 0.91 194.53 428.46 -5.72 -0.64 -2.90 0.04 0.01 2.55 GYD-CT-CMS ~ 528.50 0.79 193.71 528.44 -7.20 -1.02 -3.47 0.12 -0.12 -0.82 GYD-CT-CMS 628.50 0.53 184.88 628.44 -8.32 -1.24 -3.96 0.27 -0.25 -8.83 GYD-CT-CMS !, 728.50 0.38 155.55 728.43 -9.07 -1.14 -4.48 0.28 -0.16 -29.33 GYD-CT-CMS !, 50 0.38 126.52 828.43 ! 828 -9.55 -0.72 -5.11 0.19 0.00 -29.03 GYD-CT-CMS . ! 928.50 0.40 107.36 928.43 -9.87 -0.13 -5.77 0.13 0.03 -19.16 GYD-CT-CMS ~ 1028.50 0.47 85.43 1028.43 -9.95 0.64 -6.44 0.18 0.07 -21.93 GYD-CT-CMS ~ 1128.50 0.44 73.10 1128.42 -9.75 1.45 -6.97 0.10 -0.04 -12.34 GYD-CT-CMS 1228.50 0.23 51.72 1228.42 -9.57 2.01 -7.32 0.23 -0.20 -21.38 GYD-CT-CMS 1328.50 0.29 340.42 1328.42 ' -9.16 2.04 -7.10 0.31 0.06 -71.30 GYD-CT-CMS ~ i 1428.50 0.16 319.38 1428.42 -8.74 1.80 -6.65 0.15 -0.13 -21.04 GYD-CT-CMS ! 1528.50 0.22 169.52 1528.42 -8.87 1.79 -6.72 0.37 0.06 -149.85 GYD-CT-CMS 1628.50 0.44 171.76 1628.42 -9.43 1.87 -7.12 0.22 0.22 2.23 GYD-CT-CMS 1728.50 0.67 170.61 1728.41 -10.39 2.02 -7.81 0.23 0.23 -1.15 GYD-CT-CMS ! 'I 1828.50 0.71 174.54 1828.40 -11.67 2.23 -8.74 0.06 0.04 3.93 GYD-CT-CMS Halliburton Company Survey Report Company: BP Amoco Date: 9/15!2006 Time: 13:31:34 Page: 2 FieM: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical (TVD) Reference: 28. 5+51.46 80.0 ~ Well: Y-07 Section (VS) Reference: Well (O.OON,O.OOE,306.55Azi) Wellpatb: Plan Y-07A Survey Cskulstion Method: Minimum Curvature Db: OraG~ Survey '~ MD Intl Azim TVD +N/-S +E/-W VS DLS Build Tam TooUComment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 1928.50 0.58 188.85 1928.40 -12.74 2.17 -9.33 0.21 -0.13 14.31 GYD-CT-CMS 2028.50 0.67 197.83 2028.39 -13.77 1.97 -9.78 0.13 0.09 8.97 GYD-CT-CMS ', 2128.50 0.87 210.53 2128.38 -14.99 1.37 -10.02 0.26 0.20 12.71 GYD-CT-CMS 2150.00 0.89 211.23 2149.88 -15.27 1.20 -10.06 0.14 0.13 3.23 Start Dir 12/100' :2150' 2170.00 1.92 99.45 2169.88 -15.46 1.45 -10.37 12.00 5.13 -558.91 Start Dir 4/100' :2170' 2228.50 1.77 20.96 2228.35 -14.77 2.74 -11.00 4.00 -0.25 -134.17 MWD+IFR+MS 2328.50 5.03 336.56 2328.17 -9.15 1.72 -6.83 3.96 3.26 -44.40 MWD+IFR+MS 2389.65 7.33 328.53 2388.96 -3.37 -1.38 -0.89 4.00 3.75 -13.13 SV4 2428.50 8.83 325.62 2427.43 1.21 -4.36 4.22 4.00 3.86 -7.49 MWD+IFR+MS ' 2528.50 12.75 321.29 2525.64 16.16 -15.60 22.15 4.00 3.92 -4.33 MWD+IFR+MS 2628.50 16.70 318.98 2622.34 35.62 -31.93 46.86 4.00 3.96 -2.31 MWD+IFR+MS 2728.50 20.68 317.54 2717.05 59.49 -53.30 78.24 4.00 3.97 -1.44 MWD+IFR+MS 2828.50 24.66 316.54 2809.30 87.67 -79.57 116.14 4.00 3.98 -0.99 MWD+IFR+MS 2928.50 28.65 315.81 2898.66 120.02 -110.64 160.36 4.00 3.99 -0.73 MWD+IFR+MS 3013.45 32.04 315.32 2971.96 150.65 -140.68 202.73 4.00 3.99 -0.58 SV3 ', 3028.50 32.64 315.25 2984.68 156.37 -146.35 210.69 4.00 3.99 -0.51 MWD+IFR+MS I 3128.50 36.63 314.79 3066.94 196.55 -186.52 266.89 4.00 3.99 -0.46 MWD+IFR+MS 3228.50 40.62 314.41 3145.05 240.37 -230.96 328.69 4.00 3.99 -0.38 MWD+IFR+MS 3296.99 43.36 314.19 3195.96 272.36 -263.75 374.09 4.00 3.99 -0.33 SV2 'i 3328.50 44.61 314.09 3218.63 287.60 -279.46 395.77 4.00 3.99 -0.30 MWD+IFR+MS 3428.50 48.61 313.82 3287.31 338.03 -331.77 467.83 4.00 3.99 -0.28 MWD+IFR+MS ', 3528.50 52.61 313.57 3350.76 391.40 -387.64 544.49 4.00 4.00 -0.25 MWD+IFR+MS i 3628.50 56.60 313.35 3408.67 447.46 -446.80 625.40 4.00 4.00 -0.22 MWD+IFR+MS 3728.50 60.60 313.15 3460.76 505.92 -508.96 710.16 4.00 4.00 -0.20 MWD+IFR+MS 3807.38 63.75 313.00 3497.58 553.56 -559.91 779.46 4.00 4.00 -0.19 End Dir :3807.38' MD, 3 i 3828.50 63.75 313.00 3506.92 566.48 -573.76 798.28 0.00 0.00 0.00 MWD+IFR+MS j 3907.73 63.75 313.00 3541.96 614.94 -625.73 868.89 0.00 0.00 0.00 SV1 ', 3928.50 63.75 313.00 3551.15 627.64 -639.35 887.40 0.00 0.00 0.00 MWD+IFR+MS I, 4028.50 63.75 313.00 3595.38 688.81 -704.95 976.52 0.00 0.00 0.00 MWD+IFR+MS ', 4128.50 63.75 313.00 3639.60 749.98 -770.54 1065.64 0.00 0.00 0.00 MWD+IFR+MS 4228.50 63.75 313.00 3683.83 811.14 -836.13 1154.76 0.00 0.00 0.00 MWD+IFR+MS 4328.50 63.75 313.00 3728.06 872.31 -901.73 1243.88 0.00 0.00 0.00 MWD+IFR+MS '~ 4428.50 63.75 313.00 3772.29 933.48 -967.32 1333.00 0.00 0.00 0.00 MWD+IFR+MS 4528.50 63.75 313.00 3816.52 994.64 -1032.91 1422.12 0.00 0.00 0.00 MWD+IFR+MS 4628.50 63.75 313.00 3860.75 1055.81 -1098.51 1511.24 0.00 0.00 0.00 MWD+IFR+MS II 4728.50 63.75 313.00 3904.98 1116.98 -1164.10 1600.36 0.00 0.00 0.00 MWD+IFR+MS 4828.50 63.75 313.00 3949.21 1178.14 -1229.69 1689.48 0.00 0:00 0.00 MWD+IFR+MS 4928.50 63.75 313.00 3993.44 1239.31 -1295.29 1778.60 0.00 0.00 0.00 MWD+IFR+MS !, 5028.50 63.75 313.00 4037.66 1300.48 -1360.88 1867.72 0.00 0.00 0.00 MWD+IFR+MS 5072.13 63.75 313.00 4056.96 1327.16 -1389.49 1906.60 0.00 0.00 0.00 UG4 5128.50 63.75 313.00 4081.89 1361.64 -1426.47 1956.84 0.00 0.00 0.00 MWD+IFR+MS ' 5228.50 63.75 313.00 4126.12 1422.81 -1492.07 2045.96 0.00 0.00 0.00 I MWD+IFR+MS 5328.50 63.75 313.00 4170.35 1483.97 -1557.66 2135.08 0.00 0.00 0.00 MWD+IFR+MS 5407.38 63.75 313.00 4205.24 1532.22 -1609.40 2205.37 0.00 0.00 0.00 Start Dir 4/100' :5407.3 5428.50 63.63 312.07 4214.60 1545.02 -1623.35 2224.20 4.00 -0.55 -4.42 MWD+IFR+MS ' ', 5528.50 63.17 307.62 4259.39 1602.30 -1691.97 2313.44 4.00 -0.47 -4.44 MWD+IFR+MS !~ i 5565.11 63.03 305.99 4275.96 1621.86 -1718.11 2346.09 4.00 -0.37 -4.47 UG3 I 5628.50 62.84 303.15 4304.81 1653.88 -1764.58 2402.49 4.00 -0.30 -4.48 MWD+IFR+MS ', 5632.69 62.83 302.96 4306.72 1655.91 -1767.71 2406.21 4.00 -0.25 -4.48 I End Dir :5632.69' MD, 4 5728.50 62.83 302.96 4350.48 1702.29 -1839.22 2491.28 0.00 0.00 0.00 MWD+IFR+MS ', 5828.50 62.83 302.96 4386.14 1750.69 -1913.87 2580.07 0.00 0.00 0.00 MWD+IFR+MS 5928.50 62.83 302.96 4441.81 1799.09 -1988.51 2668.86 0.00 0.00 0.00 MWD+IFR+MS .50 6028 62.83 302.96 4487.48 184 7.49 -2063.15 2757.64 0.00 0.00 .00 WD+IFR+MS Halliburton Company Survey Report Company: BP Amoco Date: 9/15/2006 Time: 13:31:34 Pale: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical (TVD) Reference: 28.5+51.46 80.0 Well: Y-07 Section (VS) Reference: Well (O.OON,O.OOE,306.55Azi) j Wellpath: Plan Y-07A Su rvey Cskulation Method: Minimum Curvature Db: Orade J Survey MD Ind Azim TVD +N/-S +E/-W VS DIS Buitd Tnrn Tool/Comment ~, ft deg deg ft ft ft ft deg/100ft deg/100ft degl100ft 6128.50 62.83 302.96 4533.15 1895.90 -2137.80 2846.43 0.00 0.00 0.00 MWD+IFR+MS 6228.50 62.83 302.96 4578.82 1944.30 -2212.44 2935.22 0.00 0.00 0.00 MWD+IFR+MS 6328.50 62.83 302.96 4624.48 1992.70 -2287.08 3024.01 0.00 0.00 0.00 MWD+IFR+MS 6428.50 62.83 302.96 4670.15 2041.10 -2361.73 3112.80 0.00 0.00 0.00 MWD+IFR+MS 6528.50 62.83 302.96 4715.82 2089.51 -2436.37 3201.59 0.00 0.00 0.00 MWD+IFR+MS 6628.50 62.83 302.96 4761.49 2137.91 -2511.02 3290.38 0.00 0.00 0.00 MWD+IFR+MS 6728.50 62.83 302.96 4807.16 2186.31 -2585.66 3379.16 0.00 0.00 0.00 MWD+IFR+MS 6820.04 62.83 302.96 4848.96 2230.62 -2653.99 3460.44 0.00 0.00 0.00 UG1 ~, 6828.50 62.83 302.96 4852.82 2234.71 -2660.30 3467.95 0.00 0.00 0.00 MWD+IFR+MS 6928.50 62.83 302.96 4898.49 2283.11 -2734.95 3556.74 0.00 0.00 0.00 MWD+IFR+MS 7028.50 62.83 302.96 4944.16 2331.52 -2809.59 3645.53 0.00 0.00 0.00 MWD+IFR+MS 7128.50 62.83 302.96 4989.83 2379.92 -2884.23 3734.32 0.00 0.00 0.00 MWD+IFR+MS 7228.50 62.83 302.96 5035.50 2428.32 -2958.88 3823.11 0.00 0.00 0.00 MWD+IFR+MS 7328.50 62.83 302.96 5081.17 2476.72 -3033.52 3911.89 0.00 0.00 0.00 MWD+IFR+MS 7428.50 62.83 302.96 5126.83 2525.13 -3108.16 4000.68 0.00 0.00 0.00 MWD+IFR+MS ~ 7528.50 62.83 302.96 5172.50 2573.53 -3182.81 4089.47 0.00 0.00 0.00 MWD+IFR+MS 7628.50 62.83 302.96 5218.17 2621.93 -3257.45 4178.26 0.00 0.00 0.00 MWD+IFR+MS ', 7728.50 ~ 62.83 302.96 5263.84 2670.33 -3332.09 4267.05 0.00 0.00 0.00 MWD+IFR+MS I 7816.36 62.83 302.96 5303.96 2712.86 -3397.67 4345.06 0.00 0.00 0.00 WS2 7828.50 62.83 302.96 5309.51 2718.74 -3406.74 4355.84 0.00 0.00 0.00 MWD+IFR+MS 7928.50 62.83 302.96 5355.17 2767.14 -3481.38 4444.63 0.00 0.00 0.00 MWD+IFR+MS '~ 8028.50 62.83 302.96 5400.84 2815.54 -3556.02 4533.41 0.00 0.00 0.00 MWD+IFR+MS 8128.50 62.83 302.96 5446.51 2863.94 -3630.67 4622.20 0.00 0.00 0.00 MWD+IFR+MS 8228.50 62.83 302.96 5492.18 2912.34 -3705.31 4710.99 0.00 0.00 0.00 MWD+IFR+MS 8328.50 62.83 302.96 5537.85 2960.75 -3779.95 4799.78 0.00 0.00 0.00 MWD+IFR+MS ' 8355.03 62.83 302.96 5549.96 2973.59 -3799.75 4823.33 0.00 0.00 0.00 WS1 8428.50 62.83 302.96 5583.51 3009.15 -3854.60 4888.57 0.00 0.00 0.00 MWD+IFR+MS ~!~ 8528.50 62.83 302.96 5629.18 3057.55 -3929.24 4977.36 0.00 0.00 0.00 MWD+IFR+MS 8628.50 62.83 302.96 5674.85 3105.95 -4003.88 5066.14 0.00 0.00 0.00 MWD+IFR+MS 8728.50 62.83 302.96 5720.52 3154.36 -4078.53 5154.93 0.00 0.00 0.00 MWD+IFR+MS ~~ 8806.11 62.83 302.96 5755.96 3191.92 -4136.46 5223.84 0.00 0.00 0.00 CM3 8828.50 62.83 302.96 5766.19 3202.76 -4153.17 5243.72 0.00 0.00 0.00 MWD+IFR+MS 8928.50 62.83 302.96 5811.85 3251.16 -4227.81 5332.51 0.00 0.00 0.00 MWD+IFR+MS I 8935.30 62.83 302.96 5814.96 3254.45 -4232.89 5338.55 0.00 0.00 0.00 9 5/8" 9028.50 62.83 302.96 5857.52 3299.56 -4302.46 5421.30 0.00 0.00 0.00 MWD+IFR+MS 9128.50 62.83 302.96 5903.19 3347.97 -4377.10 5510.09 0.00 0.00 0.00 MWD+IFR+MS 9228.50 62.83 302.96 5948.86 3396.37 -4451.75 5598.88 0.00 0.00 0.00 M1IW+IFR+MS 9328.50 62.83 302.96 5994.53 3444.77 X526.39 5687.66 0.00 0.00 0.00 MWD+IFR+MS 9428.50 62.83 302.96 6040.19 3493.17 -4601.03 5776.45 0.00 0.00 0.00 MWD+IFR+MS ~ 9528.50 62.83 302.96 6085.86 3541.58 -4675.68 5865.24 0.00 0.00 0.00 MWD+IFR+MS ' 9628.50 62.83 302.96 6131.53 3589.98 -4750.32 5954.03 0.00 0.00 0.00 MWD+IFR+MS 9728.50 62.83 302.96 6177.20 3638.38 -4824.96 6042.82 0.00 0.00 0.00 MWD+IFR+MS 9815.57 62.83 302.96 6216.96 3680.52 -4889.95 6120.12 0.00 0.00 0.00 CM2 9828.50 62.83 302.96 6222.87 3686.78 -4899.61 6131.61 0.00 0.00 0.00 MWD+IFR+MS 9928.50 62.83 302.96 6268.53 3735.18 -4974.25 6220.39 0.00 0.00 0.00 MWD+IFR+MS 10028.50 62.83 302.96 6314.20 3783.59 -5048.89 6309.18 0.00 0.00 0.00 MWD+IFR+MS 10128.50 62.83 302.96 6359.87 3831.99 -5123.54 6397.97 0.00 0.00 0.00 MWD+IFR+MS ', 10228.50 62.83 302.96 6405.54 3880.39 -5198.18 6486.76 0.00 0.00 0.00 MWD+IFR+MS 10328.50 62.83 302.96 6451.21 3928.79 -5272.82 6575.55 0.00 0.00 0.00 MWD+IFR+MS 10428.50 62.83 302.96 6496.87 3977.20 - 47.47 53 6664.34 0.00 0.00 0.00 MWD+IFR+MS 10528.50 62.83 302 96 6542.54 4025.60 -5422.11 6753.12 0.00 0.00 0.00 MWD+IFR+MS I '..10628.50 62.83 302.96 6588.21 4074.00 -5496.75 6841.91 0.00 0.00 0.00 MWD+IFR+MS li ~ 10728.50 62.83 302.96 6633.88 4122.40 -5571.40 6930.70 0.00 0.00 0.00 MWD+IFR+MS Halliburton Company Survey Report Company: BP Amoco Date: 9/15/2006 Time: 13:31:34 Page: 4 ~ Field: Prudhoe Bay Co-ordiuate(NE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical (TVD) Refereuce: 28. 5+51.46 80.0 WeQ: Y-07 Section (VS) Reference: Well (O.OON,O.OOE,306.55Azi) Wellpatb: Plan Y-07A Survey Calculation Metbod: Minimum Curvature Db: Orate Survey _ ', MD Intl Azim TVD +N!-S +E/-W VS DLS Build Taru TooUComment ft deg deg ft ft ft ft deg/100tt deg/100ft deg/100ft 10828.50 62.83 302.96 6679.55 4170.81 -5646.04 7019.49 0.00 0.00 0.00 MWD+IFR+MS 10928.50 62.83 302.96 6725.21 4219.21 -5720.68 7108.28 0.00 0.00 0.00 MWD+IFR+MS 10973.84 62.83 302.96 6745.92 4241.15 -5754.53 7148.54 0.00 0.00 0.00 Start Dir 4/100' :10973. 11028.50 63.46 305.31 6770.61 4268.52 -5794.89 7197.25 4.00 1.16 4.29 MWD+IFR+MS ', 11072.21 64.00 307.16 6789.96 4291.68 -5826.50 7236.44 4.00 1.23 4.25 Y-07A T1 11128.50 61.75 307.16 6815.62 4321.94 -5866.42 7286.54 4.00 -4.00 0.00 MWD+IFR+MS 11228.50 57.75 307.16 6865.99 4374.11 -5935.25 7372.90 4.00 -4.00 0.00 MWD+IFR+MS ~~ 11295.32 55.08 307.16 6902.96 4407.74 -5979.61 7428.56 4.00 -4.00 0.00 CM1 11328.50 53.75 307.16 6922.27 4424.03 -6001.11 7455.53 4.00 -4.00 0.00 MWD+IFR+MS 11428.50 49.75 307.16 6984.17 4471.46 -6063.68 7534.04 4.00 -4.00 0.00 MWD+IFR+MS 111528.50 45.75 307.16 7051.39 4516.16 -6122.66 7608.04 4.00 -4.00 0.00 MWD+IFR+MS ~, 111628.50 41.75 307.16 7123.61 4557.93 -6177.75 7677.17 4.00 -4.00 0.00 MWD+IFR+MS 11676.96 39.81 307.16 7160.31 4577.04 -6202.97 7708.82 4.00 -4.00 0.00 End Dir :11676.96' MD, ', ':11728.50 39.81 307.16 7199.90 4596.98 -6229.27 7741.82 0.00 0.00 0.00 MWD+IFR+MS ', 11753.31 39.81 307.16 7218.96 4606.57 -6241.93 7757.70 0.00 0.00 0.00 THRZ 11828.50 39.81 307.16 7276.72 4635.65 -6280.30 7805.84 0.00 0.00 0.00 MWD+IFR+MS 11928.50 39.81 307.16 7353.53 4674.33 -6331.32 7869.86 0.00 0.00 0.00 MWD+IFR+MS i 12028.50 39.81 307.16 7430.35 4713.00 -6382.34 7933.88 0.00 0.00 0.00 MWD+IFR+MS ~ 12073.55 39.81 307.16 7464.96 4730.43 -6405.33 7962.72 0.00 0.00 0.00 LCU / BHRZ / TKNG 112128.50 39.81 307.16 7507.17 4751.68 -6433.37 7997.90 0.00 0.00 0.00 MWD+IFR+MS ':12228.50 39.81 307.16 7583.99 4790.35 -6484.39 8061.92 0.00 0.00 0.00 MWD+IFR+MS ', 12328.50 39.81 307.16 7660.80 4829.03 -6535.41 8125.94 0.00 0.00 0.00 MWD+IFR+MS 12428.50 ' 39.81 307.16 7737.62 4867.70 -6586.44 8189.96 0.00 0.00 0.00 MWD+IFR+MS i 12528.50 39.81 307.16 7814.44 4906.37 -6637.46 8253.98 0.00 0.00 0.00 MWD+IFR+MS 12628.50 39.81 307.16 7891.26 4945.05 -6688.48 8318.00 0.00 0.00 0.00 MWD+IFR+MS 112728.50 39.81 307.16 7968.07 4983.72 -6739.51 8382.03 0.00 0.00 0.00 MWD+IFR+MS 1 12741.37 39.81 307.16 7977.96 4988.70 -6746.07 8390.27 0.00 0.00 0.00 TJF 12828.50 39.81 307.16 8044.89 5022.40 -6790.53 8446.05 0.00 0.00 0.00 MWD+IFR+MS 12913.21 39.81 307.16 8109.96 5055.16 -6833.75 8500.28 0.00 0.00 0.00 TJE ', 12928.50 39.81 307.16 8121.71 5061.07 -6841.55 8510.07 0.00 0.00 0.00 MWD+IFR+MS 113028.50 39.81 307.16 8198.52 5099.75 -6892.58 8574.09 0.00 0.00 0.00 MWD+IFR+MS 13128.50 39.81 307.16 8275.34 5138.42 -6943.60 8638.11 0.00 0.00 0.00 MVIID+IFR+MS ~, 113228.50 39.81 307.16 8352.16 5177.10 -6994.62 8702.13 0.00 0.00 0.00 MWD+IFR+MS ', 13298.54 39.81 307.16 8405.96 5204.18 -7030.36 8746.97 0.00 0.00 0.00 TJD ~i 13328.50 39.81 307.16 8428.98 5215.77 -7045.65 8766.15 0.00 0.00 0.00 MWD+IFR+MS ~ 13428.50 39.81 307.16 8505.79 5254.45 -7096.67 8830.17 0.00 0.00 0.00 MWD+IFR+MS 113528.50 39.81 307.16 8582.61 5293.12 -7147.69 8894.19 0.00 0.00 0.00 MWD+IFR+MS 1 113544.58 39.81 307.16 8594.96 5299.34 -7155.90 8904.48 0.00 0.00 0.00 TJC 13628.50 39.81 307.16 8659.43 5331.80 -7198.72 8958.21 0.00 0.00 0.00 MWD+IFR+MS li 13725.53 39.81 307.16 8733.96 5369.32 -7248.22 9020.33 0.00 0.00 0.00 TJB ~I 113728.50 39.81 307.16 8736.25 5370.47 -7249.74 9022.23 0.00 0.00 0.00 MWD+IFR+MS ~! 13828.50 39.81 307.16 8813.06 5409.14 -7300.76 9086.25 0.00 0.00 0.00 MWD+IFR+MS ~ 13928.50 39.81 307.16 8889.88 5447.82 -7351.79 9150.27 0.00 0.00 0.00 MWD+IFR+MS ':13945.53 39.81 307.16 8902.96 5454.40 -7360.47 9161.17 0.00 0.00 0.00 TSGR ', 13954.64 1 39.81 307.16 8909.96 5457.93 -7365.12 9167.01 0.00 0.00 0.00 7" 13979.37 39.81 307.16 8928.96 5467.49 -7377.74 9182.84 0.00 0.00 0.00 TSHU ~! 1 14028.50 39.81 307.16 8966.70 5486.49 -7402.81 9214.29 0.00 0.00 0.00 MWD+IFR+MS 14091.33 39.81 307.16 9014.96 5510.79 -7434.87 9254.52 0.00 0.00 0.00 TSAD j 14128.50 39.81 307.16 9043.51 5525.17 -7453.83 9278.31 0.00 0.00 0.00 MWD+IFR+MS 14136.89 39.81 307.16 9049.96 5528.41 -7458.11 9283.69 0.00 0.00 0.00 Y-07A T2 'i 14143.40 39.81 307.16 9054.96 5530.93 -7461.44 9287.85 0.00 0.00 0.00 Top HOT 14226.00 39.81 307.16 9118.41 5562.88 -7503.58 9340.73 0.00 0.00 0.00 41/2" 14226.89 39.81 307.16 9119.10 5563.22 -7504.04 9341.30 0.00 0.00 0.00 PROJECTED to TD - - Halliburton Company Survey Report Company: BP Amoco Date: 9/15/2006 Time: 13:31:34 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-07, True North Site: PB Y Pad Vertical (TVD) Re[erence: 28.5+51.46 80.0 Well: Y-07 Section (VS) Reference: Well (O.pON,0.00E,306.55Azi) Wellpath: Plan Y-07A Survey Calculation Method: Minimum Curvature Db: Oracle _ 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 _~ ~Y-07A T1 6789.96 4291.70 -5826.50 5953094.98 639025.00 70 16 46.455 N 148 52 30.429 W Y-07A T2 9049.96 5528.43 -7458.12 5954299.98 637370.00 70 16 58.604 N 148 53 17.984 W ', Casing Points '~ MD TVD Diameter Hole Size Name - _ ft ft in in _- _ ~ 8935.30 5814.96 9.625 12.250 9 5/8" 13954.64 8909.96 7.000 8.750 7" 114226.00 9118.41 4.500 6.125 41/2" Formations MD TVD _ _ Formations Litbology - __ Dip Angle Dip Direction ft ft deg deg '~ 2389.65 2388.96 SV4 - 0.00 0.00 3013.45 2971.96 SV3 0.00 0.00 3296.99 3195.96 SV2 0.00 0.00 3907.73 3541.96 SV1 .0.00 0.00 ', 5072.13 4056.96 UG4 II 5565.11 4275.96 UG3 0.00 0.00 ~' 6820.04 4848.96 UG1 0.00 0.00 7816.36 5303.96 WS2 0.00 0.00 ~ I 8355.03 5549.96 WS1 0.00 0.00 , 8806.11 5755.96 CM3 0.00 0.00 9815.57 6216.96 CM2 0.00 0.00 !~ 11295.32 6902.96 CM1 0.00 0.00 li 11753.31 7218.96 THRZ 0.00 0.00 12073.55 7464.96 LCU / BHRZ / TKNG 0.00 0.00 12741.37 7977.96 TJF 0.00 0.00 12913.21 8109.96 TJE 0.00 0.00 i 13298.54 8405.96 TJD 0.00 0.00 13544.58 8594.96 TJC 0.00 0.00 13725.53 8733.96 TJB 0.00 0.00 !, 13945.53 8902.96 TSGR 0.00 0.00 ~ 13979.37 8928.96 TSHU 0.00 0.00 14091.33 9014.96 TSAD 0.00 0.00 ~, 14143.40 9054.96 Top HOT 0.00 0.00 Annotation MD TVD ft ft 2150.00 2149.88 Start Dir 12/100' :2150' MD, 2149.88'ND 2170.00 2169.88 Start Dir 4/100' :2170' MD, 2169.88'ND 3807.38 3497.58 End Dir :3807.38' MD, 3497.58' ND 5407.38 4205.24 Start Dir 4/100' :5407.38' MD, 4205.24'TVD ~, ~ ~, 5632.69 4306.72 End Dir :5632.69' MD, 4306.72' ND ', 10973.84 6745.92 Start Dir 4/100' :10973.84' MD, 6745.92'ND 11676.96 7160.31 End Dir :11676.96' MD, 7160.31' ND 14226.00 9118.41 Total Depth :14226.89' MD, 9119.1' TVD _ well. ucrnu s AN'rl-COLLISION SETTINGS cuMYniJV ueTAUS sukvrv Ykl%IknM Vum ~ ' ~ '1'.-N ',xUw,% .a,,,K .~ mgrmac Xl.x )i W N ' hucrpolatlon Method:MD Inwrval IW3k1 84 ZIJII 1111 TO 14226 F D h R dYA ti;u I.ulax M God Mmwum t'unvwn Ihlx4 hin IJeI+m I. .Wrv.. Ylu IWiB i224 XY Yl:nn,J VUr:1 ..W"J+~ Iuu~. MWI)~Il~k-M~ •a JNI i1 :\ JU b -2WbJJ N 41t. ~% .Wii21x IIniN 24bN Jtl JY ro ept ange . m /17 117 Y 4 Pl en » Iscw'sn Marimwn Range - . 3. p 1619.64 Rekrence: an: u, Mcihud I m, CSlmda NuN, I~:UU, ~uRwz elUpuc+d ~ ['xwg blaming Mcdxxl kulca dnuJ 1 fi0 From Colour To MD wn I rnl I I ur '~'"" Y-°]'' rnn s 0 2150 .., nl wxuhaw v-u] `I MU 21soW 150 2150 2250 xw, 33 0 2250 3000 0 kal umwn z%s,sl w ]Y V6u 3000 3250 325 3500 „ tln~~: `N~:' i 'w i~,~~,wl~ 3500 3750 :,~,,,~ +., ~,,, ?%>, 125 3750 4000 4000 4250 4250 4500 4500 4750 Lr.°'."" loo 4750 5000 ~ IL IU (Ylul 11-IUHI Maiw WaA ~ 143]114!]Al Mqw kia4 W IL3] Y1 14!]15 M 5000 5250 ax ( n aiw 1 II l ti V~d M W Yl 5250 6000 , - l_ -W l u, al,x ~ u-lu tvlax a-lone. raal,x k..A Mn u, kul ~ Y-W lY-W i 0 _ b(]U~) 6250 l . ~ y.USA iY-USAi Meiw lLSl ~ Y O5 Y u5 M k l 30 - i. qw ,x - 1 ~ Y-I%, IY-+k,l_ Mvl•n kul k A Y W M 5 aiw ,x Y-W l - Ai. ~ Y-W /Y-WAYHII. Mui•x W.n NOI:kkOkti Y-U7lY-U]I . ~ Y-U8A I Y-IIMAi. Mai,x ILEA Y-0tl IY-U81 Main kul .. ... ___ .. '~ - V-IIYAYHI (V-In)AI'dl,. Mvim 115.1. V-I%)A lY-UYA I. M:y.n W.A ` 0 - ~ Y-UY lY-U II. Mxi.x k,.A ~ Y-IU IY-IU). MxN„ k,.+A ~"--~~ ~~ ~ Y-IUIY-IDA1~Malw ltix. -- Y-I I lY-I I1. MaYn k,al - Y-11 lY-1In 1. Mqw knA Y-I I lY-I Idl. Mq,u K,..A Y-I I fY-I IHYdII. Mul.,~ k,.~ ' 5 A .-2 -'-' Y-II IY-II[ I~MaI•u ki.l Y-1217-121- Maiw ki.A ~ Y-19 tY-I'l 1 Ma ,x k,.: ) t i . ~ Y-21A IY-21A1. MuSui ki.• w kuA V-21 Y-211 M q I . ~ Y-2 i (Y--2!A Myu, Rul Y-2!(Y-21A1 Myw k,u 2i ?IAYkI k ~ V V' M - ( i.. - - I. al,v ~ V-2i IY-23A1'd21. My.x w-. ~ 0 i ~'/ 2/ 0~ ~ Y-2i (Y-2341 Mxiw w.w - Y-2J IY-271 Malty kuA 6 \j . ~ Y-2517-_'>I. Mq•x ki.d 7.241 Y-241. Mel•x k,xl ~ V-'_4 tY-2GA1_Meiw k,sA ~ ~ _ Y 2%(Y 2X) Ma!u kl.l - Y ZYA 1 Y-24A1. Mxiw Ws. ~ V-2Y IY-2YA Mtliw kixA Y !U i Y !U) Mxi,.e k al 5 y.31 IY 3UI II M J^r ku,. `. Y-SI 1Y-311. Maiw k,..A kuA Y-32 Y-321 M / ... ( . 1 V-1217-)21.11 Mal'x knA b ~ V !517.53) Mlui k,vA ~ n /b Y-3JnY )JI, MyMaH .A ~~ 50 ^ Y-J](Y-3])Muiu, ki.rA Y-3]lY-i]A i, M.9.n ki.i ~ Y-i]1Y'-iJAI'lili Mo •x Ni.. . l flan Y-U"+.\ \_U]~ r. ixi 22 ~~ 5 : 240 12 0 ~. 100 ,~ r ,~ 125 -- -~~ ~ __. tiF.CTIUN I)t lAllk 21 ~ ~Co J l„ lu. M11 N~ IVU -Nr-S I~.-W I.u I'Fa.. v~v. % 'i~ ,~ 215eW UtlY 1 ZIJY btl 211 2 -1525 I IY UW U.W IU UJ C 150 xx ~ ? . . . I 5 \ )OW 10] 3551) 2?UY %2 JW ?28W ?g] 13. 10 U8 L ~/ 31Ni]l% 4175 \ $JU] 3g G3 ]J 31311U 3-17]58 313 W J2U52J 553 sX -sSY YI dW ll(~]tl 15322) -IdW.VU U W U W ]1 J] 22US )Y O 1 l/ ~ tb326Y 628! ] IW ]l8J 42 tli N12.Y6 JIUb.]2 W294 G]JS Y2 1655 VJ -I ]b]'/l <.W -78.12 J2J1.1) -5]SJ 53 UW UW 2JW.22 ]IJ8? tl 110]2.21 WUII !e]I6 6787.94 J2917U -Stl2(•Ni JW ].{W ]234 N~ -'I^A I' Y 116]4.9(. )981 30]16 ]IUII.JI JS]]W -420298 JW -IBU.IIU - lU 1!17684 3Y 81 3U]16 WJ9 Y6 5528)3 -])5812 VUU U3X1 r2%i ]U ,-n t; Travelling Cylinder Azimuth (TFO+AZI) [ deg) vs Centre to Centre Separation [SOft/in] II IJ224 X9 3Y bl iU]14 YI IY IIt 55432) -]SUJW UW UW rill r: Sperry-Sun Anticollision Report Company: BP Amoco Date: 9/15/2006 Time: 10:01:18 Page: 1 Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: Well: Y-07, True North Reference Well: Y-07 Vtrtical ( TVD) Reference: 28.5+51.46 80.0 Reference WellpatP~an Y-07A Db: OraGe GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - TRefe~aaec'~IGHT ~iliv:ilb-~~ tSilBlll!8~ NOT PLANNED PR I Interpolati on MethodMD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Ran ge: 2150.00 to 14226.89 ft Scan Method: Trav Cylinder North Maximum Radius9619,84 ft Error Surface: Ellipse+ Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 8935.30 5814.96 9.625 12.250 9 5/8" 13954.64 8909.96 7.000 8.750 7" 14226.00 9118.41 4.500 6.125 4 1 /2" Plan: Y-07A wp07 Date Composed: 8/9/2005 Versi on: 34 Principal: Yes Tied-to: From: Definitive Path Summary <______________________ Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distanc eArea Deviation Warning ft ft ft ft ft PB H Pad H-10 Plan H-106 V1 Plan: H- 14187.58 12500.00 346.79 319.19 27.60 Pass: Major Risk PB H Pad H-37 H-37A V1 Out of range PB H Pad H-37 Plan H-376 VO Plan: H- 14197.30 12700.00 331.20 327.63 3.58 Pass: Major Risk PB U Pad U-09 Plan U-096 VO Plan: U- 14148.49 13100.00 570.86 615.19 -44.34 FAIL: Major Risk PB U Pad U-10 Plan U-10A V1 Plan: U- 14152.57 13800.00 654.75 393.52 261.23 Pass: Major Risk PB Y Pad Y-04 Y-04 V1 2296.98 2300.00 348.13 35.39 312.74 Pass: Major Risk PB Y Pad Y-05A Y-05A V1 2291.33 2300.00 222.38 34.91 187.47 Pass: Major Risk PB Y Pad Y-05 Y-05 V1 2291.33 2300.00 222.38 34.91 187.47 Pass: Major Risk PB Y Pad Y-O6 Y-06 V1 2298.51 2300.00 119.44 34.50 84.94 Pass: Major Risk PB Y Pad Y-06 Y-06A V5 2298.51 2300.00 119.44 34.35 85.09 Pass: Major Risk PB Y Pad Y-O6 Y-06AP61 V3 2298.51 2300.00 119.44 34.50 84.94 Pass: Major Risk PB Y Pad Y-07 Y-07 V1 2193.13 2200.00 1.35 0.81 0.54 Pass: NOERRORS PB Y Pad Y-08A Y-08A V1 2184.92 2200.00 92.84 40.12 52.73 Pass: Major Risk PB Y Pad Y-08 Y-08 V1 2184.91 2200.00 92.87 39.95 52.92 Pass: Major Risk PB Y Pad Y-09APB1 Y-09AP61 V2 2805.97 2800.00 207.23 42.10 165.13 Pass: Major Risk PB Y Pad Y-09A Y-09A V2 2805.97 2800.00 207.23 42.10 165.13 Pass: Major Risk PB Y Pad Y-09 Y-09 V1 2805.97 2800.00 207.23 42.10 165.13 Pass: Major Risk PB Y Pad Y-10 Y-10 V1 2923.66 2900.00 288.74 43.39 245.35 Pass: Major Risk PB Y Pad Y-10 Y-10A V2 2923.66 2900.00 288.74 43.39 245.35 Pass: Major Risk PB Y Pad Y-11 Y-11 V7 2960.83 2900.00 404.36 43.74 360.62 Pass: Major Risk PB Y Pad Y-11 Y-11A V1 2960.83 2900.00 404.36 43.74 360.62 Pass: Major Risk PB Y Pad Y-11 Y-11 B V3 2962.56 2900.00 404.32 43.77 360.55 Pass: Major Risk PB Y Pad Y-11 Y-11 BP61 V4 2962.56 2900.00 404.32 43.77 360.55 Pass: Major Risk PB Y Pad Y-11 Y-11 C V5 2967.05 2900.00 404.24 43.86 360.37 Pass: Major Risk PB Y Pad Y-12 Y-12 V1 3169.66 3100.00 490.61 49.57 441.04 Pass: Major Risk PB Y Pad Y-19 Y-19 V1 3269.32 3200.00 512.10 56.08 456.02 Pass: Major Risk PB Y Pad Y-21A Y-21A V1 2931.77 2900.00 331.98 45.53 286.45 Pass: Major Risk PB Y Pad Y-21 Y-21 V1 2931.77 2900.00 331.98 45.74 286.24 Pass: Major Risk PB Y Pad Y-23 Y-23 V3 4845.07 4500.00 219.59 112.24 107.35 Pass: Major Risk PB Y Pad Y-23 Y-23A V4 4845.07 4500.00 219.59 112.24 107.35 Pass: Major Risk PB Y Pad Y-23 Y-23AP61 V1 4845.07 4500.00 219.59 112.24 107.35 Pass: Major Risk PB Y Pad Y-23 Y-23AP62 V1 4845.07 4500.00 219.59 112.24 107.35 Pass: Major Risk PB Y Pad Y-23 Y-23B V7 4854.00 4500.00 219.69 112.53 107.16 Pass: Major Risk PB Y Pad Y-24 Y-24 V2 2173.28 2300.00 534.32 34.06 500.26 Pass: Major Risk PB Y Pad Y-25 Y-25 V1 2924.22 2900.00 262.33 42.48 219.85 Pass: Major Risk PB Y Pad Y-26 Y-26 V1 3200.78 3100.00 543.00 50.75 492.25 Pass: Major Risk PB Y Pad Y-26 Y-26A V2 3200.78 3100.00 543.00 50.75 492.25 Pass: Major Risk PB Y Pad Y-28 Y-28 V1 2292.24 2300.00 253.99 31.47 222.52 Pass: Major Risk PB Y Pad Y-29A Y-29A V2 2804.54 2800.00 164.15 37.63 126.53 Pass: Major Risk PB Y Pad Y-29 Y-29 V1 2804.54 2800.00 164.15 37.63 126.53 Pass: Major Risk PB Y Pad Y-30 Y-30 V3 2596.29 2600.00 65.57 32.89 32.68 Pass: Major Risk PB Y Pad Y-30 Y-30L1 V3 2596.29 2600.00 65.57 32.89 32.68 Pass: Major Risk PB Y Pad Y-31 Y-31 V1 2391.39 2400.00 42.87 33.72 9.15 Pass: Major Risk PB Y Pad Y-32 Y-32 V7 2181.99 2200.00 164.90 38.97 125.93 Pass: Major Risk PB Y Pad Y-32 Y-32L1 V2 2181.99 2200.00 164.90 38.97 125.93 Pass: Major Risk PB Y Pad Y-33 Y-33 V1 2292.69 2300.00 145.33 28.66 116.66 Pass: Major Risk 2AM Sperry-Sun Anticollision Report Company: BP Amoco Date: 9/15/2006 Time: 10:01:18 Page: 2 Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Re ference: Welt: Y-07, True North Reference Welt: Y-07 Vertical (T Vb) Reference: 28.5+51.46 80.0 Reference WellpatPdan Y-07A Db: OraGe Summary <______________________ Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD DistanceArea Deviatio n Warning ft ft ft ft ft PB Y Pad Y-34A Y-34A V3 2292.84 2300.00 404.21 29.50 374.71 Pass: Major Risk PB Y Pad Y-34 Y -34 V1 2292.84 2300.00 404.21 29.50 374.71 Pass: Major Risk PB Y Pad Y-37 Y -37 V1 2184.97 2200.00 385.73 31.50 354.23 Pass: Major Risk PB Y Pad Y-37 Y -37A V8 2184.97 2200.00 385.73 31.52 354.21 Pass: Major Risk PB Y Pad Y-37 Y-37AP61 V3 2184.97 2200.00 385.73 31.52 354.21 Pass: Major Risk Site: PB H Pad Well• H-10 Rule As signed: Major Ri sk Wellpath : Plan H-106 V1 Plan: H-106 wp01 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go Allowab le MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/>$istanceArea Deviatio n Warning ft ft ft ft ft ft deg deg in ft ft ft 13253.35 8371.25 10800.00 8326.25 63.96 31.63 34.88 87.72 8.500 1587.39 276.23 1311.16 Pass 13318.92 8421.61 10900.00 8394.11 64.27 32.03 35.81 88.65 8.500 1516.17 276.78 1239.39 Pass 13384.48 8471.98 11000.00 8461.97 64.58 32.42 36.82 89.66 8.500 1445.38 277.17 1168.21 Pass 13450.05 8522.34 11100.00 8529.83 64.89 32.82 37.95 90.78 8.500 1375.10 277.37 1097.72 Pass 13515.61 8572.71 11200.00 8597.70 65.20 33.22 39.19 92.03 8.500 1305.40 277.36 1028.04 Pass 13581.17 8623.07 11300.00 8665.56 65.51 33.62 40.57 93.41 8.500 1236.38 277.10 959.28 Pass 13646.74 8673.44 11400.00 8733.42 65.82 34.01 42.11 94.95 8.500 1168.17 276.55 891.62 Pass 13712.30 8723.80 11500.00 8801.28 66.13 34.41 43.85 96.68 8.500 1100.90 275.68 825.23 Pass 13777.87 8774.17 11600.00 8869.14 66.44 34.81 45.80 98.64 6.125 1034.78 274.35 760.43 Pass 13843.43 8824.53 11700.00 8936.96 66.75 35.21 48.02 100.86 6.125 969.98 272.74 697.24 Pass 13907.25 8873.55 11800.00 8994.49 67.05 35.64 49.76 102.60 6.125 898.79 271.81 626.98 Pass 13964.96 8917.89 11900.00 9031.45 67.33 36.14 50.20 103.04 6.125 817.75 272.54 545.20 Pass 14012.63 8954.50 12000.00 9045.32 67.55 36.63 48.91 101.74 6.125 731.93 275.42 456.51 Pass 14048.62 8982.15 12100.00 9039.94 67.72 37.04 45.83 98.67 6.125 646.29 281.05 365.23 Pass 14083.36 9008.84 12200.00 9033.03 67.89 37.46 41.74 94.58 6.125 562.99 288.55 274.44 Pass 14118.10 9035.52 12300.00 9026.12 68.05 37.88 36.27 89.11 6.125 483.53 298.12 185.41 Pass 14152.84 9062.21 12400.00 9019.22 68.22 38.31 28.75 81.59 6.125 410.17 309.29 100.88 Pass 14187.58 9088.90 12500.00 9012.31 68.38 38.74 18.23 71.07 6.125 346.79 319.19 27.60 Pass Site: PB H Pad Well: H-37 Rule Assigned: Major Risk Wellpath: Plan H-376 VO Plan: H-376 wp01 V17 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/IlBistanceArea Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13371.15 8461.74 11 i 00.00 8544.90 64.52 36.11 42.29 95.13 8.500 1563.51 267.76 1295.74 Pass 13433.41 8509.57 11200.00 8598.19 64.81 36.48 42.89 95.73 8.500 1486.87 268.31 1218.56 Pass 13495.68 8557.40 11300.00 8651.48 65.11 36.86 43.55 96.39 8.500 1410.42 268.74 1141.69 Pass 13557.94 8605.22 11400.00 8704.77 65.40 37.24 44.28 97.12 8.500 1334.18 269.02 1065.16 Pass 13620.20 8653.05 11500.00 8758.06 65.70 37.62 45.11 97.95 8.500 1258.18 269.14 989.04 Pass 13682.47 8700.88 11600.00 8811.34 65.99 38.00 46.04 98.88 8.500 1182.48 269.06 913.41 Pass 13744.73 8748.71 11700.00 8864.63 66.29 38.38 47.10 99.93 6.125 1107.13 268.67 838.45 Pass 13806.99 8796.54 11800.00 8917.92 66.58 38.77 48.31 101.14 6.125 1032.21 268.13 764.08 Pass 13869.20 8844.33 11900.00 8970.97 66.87 39.16 49.69 102.53 6.125 957.69 267.33 690.36 Pass 13928.28 8889.71 12000.00 9013.19 67.15 39.58 50.51 103.35 6.125 878.31 267.42 610.89 Pass 13980.64 8929.93 12100.00 9037.61 67.40 40.03 50.13 102.97 6.125 793.51 269.29 524.23 Pass 14023.87 8963.14 12200.00 9043.15 67.61 40.46 48.16 100.99 6.125 707.33 273.65 433.68 Pass 14058.61 8989.82 12300.00 9036.27 67.77 40.84 44.78 97.62 6.125 622.08 280.87 341.21 Pass 14093.20 9016.39 12400.00 9029.23 67.94 41.24 40.35 93.18 6.125 539.66 290.50 249.16 Pass 14127.78 9042.96 12500.00 9022.18 68.10 41.64 34.36 87.20 6.125 461.61 302.68 158.93 Pass 14162.37 9069.53 12600.00 9015.14 68.26 42.05 26.09 78.93 6.125 390.57 316.47 74.10 Pass 14197.30 9096.36 12700.00 9008.37 68.43 42.43 14.52 67.36 6.125 331.20 327.63 3.58 Pass 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 n U • • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~ ©~i~ PTD# Z~ 7 ~~~ / i ra hic Test Development Service Exploratory Strat g p 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. SO- - - API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 2S.OOS(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and AP[ number (SO- - -_) from records, data and logs acquired for well SPACING The permif is approved subject to full compliance with 20 AAC EXCEPTION 25.OS5. 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 atiowed 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. SCompany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 • • ^^ ~ , , , a~ a , N y Oc Q ° m i a E C N tp M' O' , m _ D. ~ a °° ~ o H, m. '~ .E. a' c. ae m, , ~ t N ,~, s. a. m, N, , ~ ~ O ~ ~, T ~ a o a , , ~ otf _ ~ a a ~ o. , tp ~ N• ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Q. ~ U N ~ ~, ~? , c, N. ~ ~ O• O, ~ C > , ' ' r c ~ m ° °- - W d ~, ~ cfl, 4 ~ Z ~ Y, ~? M O ~ ~ V ~ ~ E, ~ ~ ~ N, O ~ ~, ~ W ~ ', ~ ~~ p ~ O ~ E~ O a O , ~ , ~ J ~ ~ _ , ~ ~ ~ , ~ uY a. 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N, ~ N, rn N. ~ Q 3, O, o, C o ~+ . ~ E w o Z O a ~, N, -°, ~ T ~ ~~ p, a, ~ 3. 3, a~ ~ ~, a~, .. o, a_ ~ ~, '~ :~ 3; o ~ ~, o a~ ~ a ~ `~ n a m ~, ~ o, 3, o' L, ~ o U o n f= a, o, ~. ~ om, , ~ m o, a~, Q, ~, ~ o, ~~ ~ o m ~~ o c' o. ~ o' u~' o o, c ~ a o, a~ y, -o, o' E' °, m E' ' o, rn c r o ~ a, Q m ~n, ° °- ° ~ a~ c . °~ ~ a t n o, ° 4 4 f0 . ° 0 ~ ~' ~' 4 of w a ~ w' v ' i ~, a °' o' ~ °i; i a m - T ~ ai p' ~, -p ~°' ' oS m' ~ c coy, ~ c ~, ~ 3 'v' ~ c °' `~ , ° °' o ~ ~° v. °, 0 0 E. . 3 `~° ~ • ~, ~ • ~- ~, a is o c Y o ~ ~~ ~~ ° `° L ~ w' u i ' ; " ~ O ~ ~, ~, .5 o. a ~ ~ p, o a~ 3, ~, v ~ a ~' ar a a~ ; m. ; o; ~; p, ~, >, a i ~ ~ a, -, a a a o ~ p, ~ a a p, N, •~'' ' :° ' c c X ° ~, ~, ai, a, ~ ° ~ o z, c c a~ _ 3~ u c ~ ° a a m' 1° o ~ o ~' . v~ °~' ~ v _ 3 ~ _ o ~n c ~ `°' a o °~ m, c i, c a m ~, ~ tJ ° °, ~' ~ 3, m. ca m. a~' o' o' o°' ~ a~, m. c ~' ~ m. ° m. ° E p m a ~', a' o o, c. c , ; ~ ~ ~ ~, •3. ~; ~ ~, ; ~; 'a, ~, a~' ~ a, ; ~ °r ~, u% - . ~ '3, N, •~, m, ° ° a a, ~ ~ ~ ~ a m E ~ a . ~, m , ~ ~ c 3, ~ c ~- I-' c `f4 H' ° N; ° `~, ? ~ . a; o n = ~ ~ ~ y m. c m - Y >, °, a~ ~, ~, ~ . c, ~ ' ' a> ~ v' a as a a~ o m ~ ' - . o ' ' t o ~ ~' ~', ' ' ~', a i p, a. a i. f6 a, -° ' - O, O. r, c i o ~ ' ' ' «, a~, °, a~, a~ o, D U = a' -~ x, ; s ; ~ ~; -, ~, O; n.; a; v ~ ¢. a z ~ ~ ~ ~ ~, ~, ¢. , ~; a, - o m, m, v, ~ , ~ ~ , ~' a, o, cn, cn; v w V a O ~ N M V ~ CO h 00 O O N M 'S ~ O~ _ _ O O O N N N N M~ N N ~ O N 00 N N N N _ O O N M M N M V M M M -- to (O M M - f~ M M M - W M U F - o o y o r-~.._ y o a~ C C O C ~ N m N ~ ~ N V O W 0 y ~ M ~ ~ ~ ` ~ ®~ ~ M O tNp f0 00 C . 00 a0 p . a ° N y ~ ~ C7 E ~ ~ ~ ~ Q~ U w a a Q Q cn ~ w G. a W H O ~ acn v Well I-listory File APPENDIX Information of detailed nature that is not • particularly germane io the Well Pen~itting Process but is part of the history file. To improve the readability of the Well History file and to simplify rending information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. y-07a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed May 14 15:33:25 2008 Reel Header Service name .............LISTPE Date . ...................08/05/14 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/05/14 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF scientific Technical services Library. Scientific Technical Services Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: Y-07A API NUMBER: 500292056001 OPERATOR: BP Explorations (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 14-MAY-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 6 JOB NUMBER: Mw0005355473 Mw0005355473 MW0005355473 LOGGING ENGINEER: GEOFFREY SAM GEOFFREY SAM OKEY OBI OPERATOR WITNESS: BILL DECKER BILL DECKER DICK MASKEL MWD RUN 7 JOB NUMBER: MW0005355473 LOGGING ENGINEER: B. YOHMAN OPERATOR WITNESS: B. DECKER SURFACE LOCATION SECTION: 34 TOWNSHIP: 11N RANGE: 13E FNL: 1341 FSL: FEL: FWL: 118 Page 1 ~o~~as r~,~r 5 i y-07a.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 79.58 GROUND LEVEL: 28.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 2020.0 2ND STRING 8.500 9.625 9305.0 3RD STRING 6.125 7.000 14398.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THE Y-07A PB1 WELLBORE EXITS THE Y-07 WELLBORE BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 2020'MD/2020'TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED WITHOUT MWD TOOLS. Y-07A EXITS Y-07A PB1 AT THE 9.625" CASING SHOE, 9305'MD/5793'TVD. THIS SIDETRACK WAS ACCOMPLISHED BY DRILLING OFF OF A CEMENT PLUG. 4. MWD RUNS 1,2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). MWD RUN 2 ALSO INCLUDED GEOPILOT ROTARY-STEERABLE BHA (GP). UPHOLE MAD SGRC TIE-IN DATA ACQUIRED WHILE POOH AFTER MWD RUN 1 WERE MERGED WITH RUN 1 MWD DATA. 5. MWD RUNS 6,7 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PWD. MWD RUN 6 ALSO INCLUDED GP. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN Y-07A ON 3 FEBRUARY 2008. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 9 MAY 2008, QUOTING AUTHORIZA- TION FROM COLE ABEL (BP). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1,2,6,7 REPRESENT WELL Y-07A WITH API#: 50-029-20560-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14730'MD/9184'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. Page 2 ~ r y-07a.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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPS FET RPM RPD RPX 1 and clipped curves; all bit runs merged. .5000 START DEPTH 1823.0 2055.5 9302.5 9302.5 9302.5 9302.5 9302.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 14684.5 14743.0 14691.5 14691.5 14691.5 14691.5 14691.5 --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 1823.0 1821.0 1837.0 1835.0 1855.0 1853.0 1891.0 1891.5 1963.0 1963.5 2010.5 2011.0 2044.5 2041.5 2047.5 2044.5 2068.5 2066.0 2093.5 2090.5 2110.5 2107.0 2151.0 2148.5 2160.0 2157.0 2193.5 2190.0 2199.5 2197.0 2209.0 2206.5 2223.0 2218.5 2232.0 2227.5 2251.5 2247.0 2265.5 2262.5 Page 3 y-07a.tapx 2286.0 2283.0 2407.5 2404.0 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MERGED MAIN PA55. y-07a.tapx MERGE TOP MERGE BASE 1821.0 3771.0 3771.0 9305.0 9305.0 14398.0 14398.0 14730.5 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 1823 14743 8283 25841 1823 14743 RPD MWD OHMM 0.62 2000 18.3538 10779 9302.5 14691.5 RPM MWD OHMM 0.76 2000 9.24671 10779 9302.5 14691.5 RPS MWD OHMM 0.46 1476.35 3.71992 10779 9302.5 14691.5 RPX MWD OHMM 0.4 1563.91 3.92566 10779 9302.5 14691.5 FET MWD HR 0.27 463.08 3.77384 10779 9302.5 14691.5 Page 10 y-07a.tapx GR MWD API 12.69 536.4 94.4775 25724 1823 ROP MWD FPH 0.31 1358.99 163.943 25376 2055.5 First Reading For Entire File..........1823 Last Reading For Entire File...........14743 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........5T5LIB.002 Physical EOF File Header service name... .......sTSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.001 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 GR 1821.0 3721.5 ROP 2052.5 3771.0 LOG HEADER DATA DATE LOGGED: 28-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3771.0 TOP LOG INTERVAL (FT): 2052.0 BOTTOM LOG INTERVAL (FT): 3771.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 4.6 MAXIMUM ANGLE: 62.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 Page 11 14684.5 14743 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): y-07a.tapx 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 Log~iny 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 12.250 2020.0 Polymer 9.30 60.0 9.5 900 8.0 .000 .0 .000 95.0 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FPH 4 1 68 8 3 First Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 1821 3771 2796 3901 1821 3771 GR MWDO10 API 13.55 111.7 60.6356 3802 1821 3721.5 ROP MWDO10 FPH 4.25 674.91 236.201 3438 2052.5 3771 First Reading For Entire File..........1821 Last Reading For Entire File...........3771 File Trailer service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Page 12 Maximum Physical Record..65535 y-07a.tapx File Type ................L0 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.......08/05/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 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 3722.0 9266.0 RoP 3771.5 9305.0 LOG HEADER DATA DATE LOGGED: 02-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9305.0 TOP LOG INTERVAL (FT): 3771.0 BOTTOM LOG INTERVAL (FT): 9305.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.0 MAXIMUM ANGLE: 65.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2020.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 50.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1100 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O Page 13 • • y-07a.tapx MUD AT MAX CIRCULATING TERMPERATURE: .000 124.0 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 GR MWD020 API 4 1 68 4 2 ROP MWD020 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3722 9305 6513.5 11167 3722 9305 GR MWD020 API 12.69 135.54 67.3249 11089 3722 9266 ROP MWD020 FPH 2.2 967.1 192.489 11068 3771.5 9305 First Reading For Entire File..........3722 Last Reading For Entire File...........9305 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Page 14 • Maximum Physical Record..65535 y-07a.tapx File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9266.5 FET 9290.0 RPD 9290.0 RPX 9290.0 RPS 9290.0 RPM 9290.0 $oP 9305.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 14361.0 14348.0 14348.0 14348.0 14348.0 14348.0 14398.0 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: Page 15 header data for each bit run in separate files. 6 .5000 4 19-7AN-08 Incite 74.11 Memory 14398.0 9305.0 14398.0 34.2 60.6 TOOL NUMBER 076571 105242 8.500 9305.0 Polymer 10.70 48.0 9.4 500 1.0 1.910 50.4 .850 122.0 1.700 52.5 1.500 59.5 i y-07a.tapx 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 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 First Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 9266.5 14398 11832.3 10264 9266.5 14398 RPD MWD060 OHMM 0.62 2000 4.72881 10117 9290 14348 RPM MWD060 OHMM 0.76 1874.5 3.70352 10117 9290 14348 RPS MWD060 OHMM 0.78 1476.35 3.05919 10117 9290 14348 RPX MWD060 OHMM 0.81 1563.91 3.06866 10117 9290 14348 FET MWD060 HR 0.27 463.08 2.66137 10117 9290 14348 GR MWD060 API 29.57 401.95 137.254 10190 9266.5 14361 ROP MWD060 FPH 0.31 1358.99 111.205 10186 9305.5 14398 First Reading For Entire File..........9266.5 Last Reading For Entire File...........14398 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLI6.005 Page 16 • Service sub Level Name... Y-07a.tapx version Number. ........1.0.0 Date of Generation.......08/05/14 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 e ach bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 14348.5 14679.0 RPD 14348.5 14679.0 RPM 14348.5 14679.0 RPS 14348.5 14679.0 RPX 14348.5 14679.0 GR 14361.5 14672.0 ROP 14398.5 14730.5 LOG HEADER DATA DATE LOGGED: 31-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14730.0 TOP LOG INTERVAL (FT): 14398.0 BOTTOM LOG INTERVAL (FT): 14730.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.5 MAXIMUM ANGLE: 35.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10852663 EWR4 Electromag Resis. 4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 14398.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 47.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): 7.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .170 55.5 MUD AT MAX CIRCULATING TERMPERATURE: .050 201.2 MUD FILTRATE AT MT: .220 54.6 MUD CAKE AT MT: .122 63.9 Page 17 i y-07a.tapx 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 n ~J Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 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 14348.5 14730.5 14539.5 765 14348.5 14730.5 RPD MWD070 OHMM 1.53 2000 236.185 662 14348.5 14679 RPM MWD070 OHMM 1.09 2000 100.627 662 14348.5 14679 RPS MWD070 OHMM 0.46 300.9 14.4734 662 14348.5 14679 RPX MWD070 OHMM 0.4 1055.48 17.5134 662 14348.5 14679 FET MWD070 HR 0.29 140.84 22.8483 662 14348.5 14679 GR MWD070 API 14.5 536.4 88.3215 622 14361.5 14672 ROP MWD070 FPH 0.74 257.96 104.996 665 14398.5 14730.5 First Reading For Entire File..........14348.5 Last Reading For Entire File...........14730.5 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Page 18 y-07a.tapx Tape Trailer service name .............LISTPE gate . ...................08/05/14 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer service name .............LISTPE gate . ...................08/05/14 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File • scientific Technical services scientific Technical services Page 19 Y • y-07apbl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed May 14 14:12:19 2008 Reel Header Service name .............LISTPE Date . ...................08/05/14 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 . ...................08/05/14 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: Y-07A PB1 API NUMBER: 500292056070 OPERATOR: BP Explorations Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 14-MAY-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 4 JOB NUMBER: Mw0005355473 MW0005355473 Mw0005355473 LOGGING ENGINEER: GEOFFREY SAM GEOFFREY SAM SHAWN POLAK OPERATOR WITNESS: BILL DECKER BILL DECKER DICK MASKELL MWD RUN 5 JOB NUMBER: Mw0005355473 LOGGING ENGINEER: OKEY OBI OPERATOR WITNESS: DICK MASKELL SURFACE LOCATION SECTION: 34 TOWNSHIP: 11N RANGE: 13E FNL: 1341 FSL: FEL: FWL: 118 Page 1 ~~-~oS ~~ 2 9 ~ • y-07apbl.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 79.58 GROUND LEVEL: 28.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 2020.0 2ND STRING 8.500 9.625 9305.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE Y-07 WELLBORE BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 2020'MD/2020'TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED WITHOUT MWD TOOLS. 4. MWD RUNS 1,2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). MWD RUN 2 ALSO INCLUDED GEOPILOT ROTARY-STEERABLE BHA (GP). UPHOLE MAD SGRC TIE-IN DATA ACQUIRED WHILE POOH AFTER MWD RUN 1 WERE MERGED WITH RUN 1 MWD DATA. 5. MWD RUNS 3-5 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GP, AND PWD. AT-BIT GAMMA (ABGT) DATA WERE APPENDED TO THE END (12705'-12741'MD, UNSHIFTED DEPTHS) OF THE MWD RUN 5 SGRC DATA TO PROVIDE A MORE COMPLETE DATASET. NO DATA WERE .ACQUIRED ON MWD RUN 3. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN Y-07A ON 3 FEBRUARY 2008. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 9 MAY 2008, QUOTING AUTHORIZA- TION FROM COLE ABEL (BP). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1,2,4,5 REPRESENT WELL Y-07A PB1 WITH API#: 50-029-20560-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12745'MD/7892'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. Page 2 • y-07apbl.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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPS FET RPM RPD RPX 1 and clipped curves; all bit runs merged. .5000 START DEPTH 1823.0 2055.5 9303.5 9303.5 9303.5 9303.5 9303.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 12755.0 12759.0 12705.5 12705.5 12705.5 12705.5 12705.5 --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 1823.0 1821.0 1837.0 1835.0 1855.0 1853.0 1891.0 1891.5 1963.0 1963.5 2010.5 2011.0 2044.5 2041.5 2047.5 2044.5 2068.5 2066.0 2093.5 2090.5 2110.5 2107.0 2151.0 2148.5 2160.0 2157.0 2193.5 2190.0 2199.5 2197.0 2209.0 2206.5 2223.0 2218.5 2232.0 2227.5 2251.5 2247.0 2265.5 2262.5 Page 3 Y-07apbl.tapx 2286.0 2283.0 2407.5 2404.0 2429.0 2426.5 2432.0 2428.5 2454.5 2451.0 2478.0 2475.0 2483.5 2481.5 2489.5 2487.0 2510.5 2507.5 2520.5 2517.5 2530.5 2527.0 2538.5 2535.5 2554.5 2551.5 2572.5 2566.5 2580.0 2576.0 2595.0 2592.5 2602.0 2598.0 2605.0 2602.5 2642.5 2641.5 2659.5 2658.0 2824.0 2821.5 2834.5 2829.0 2838.0 2833.0 2866.0 2861.5 2877.5 2873.0 2881.5 2880.0 2894.5 2890.0 2971.0 2968.0 2995.5 2989.5 3036.5 3032.5 3074.5 3072.5 3086.5 3085.0 3185.5 3182.5 3203.0 3201.0 3321.0 3318.0 3372.5 3370.5 3375.0 3372.5 3387.5 3385.5 3395.5 3392.0 3420.0 3416.5 3434.0 3429.0 3444.0 3439.0 3451.0 3445.5 3460.5 3455.5 3468.5 3464.5 3481.0 3474.5 3485.0 3480.0 3529.0 3524.5 3533.0 3528.5 3537.0 3532.5 3568.0 3563.5 3581.5 3576.5 3609.5 3603.5 3612.0 3606.5 3618.0 3612.0 3650.0 3644.0 3738.5 3731.0 3902.0 3895.5 3981.5 3975.0 4016.5 4010.5 4061.0 4052.0 4081.5 4073.5 4135.5 4130.0 Page 4 4146.0 4286.5 4343.5 4479.5 4493.5 4517.5 4527.5 4548.0 4564.5 4580.0 4663.5 4712.0 4728.0 4754.5 4794.0 4808.5 4814.0 4827.5 4957.0 4973.0 4996.0 5045.0 5066.5 5109.0 5131.0 5214.0 5228.0 5249.5 5266.5 5298.0 5335.0 5339.0 5370.5 5405.0 5540.0 5564.5 5580.0 5618.5 5657.5 5685.5 5727.5 5747.0 5765.5 5768.5 5775.5 5816.0 5835.0 5851.0 5866.0 5897.5 5942.0 5958.5 5973.0 6006.0 6061.5 6078.5 6087.5 6095.5 6142.0 6179.5 6199.5 6214.5 6222.5 4140.5 4281.0 4338.5 4474.0 4487.5 4510.0 4521.5 4541.0 4559.5 4575.0 4655.5 4702.0 4719.0 4746.0 4787.5 4802.5 4806.5 4820.5 4951.0 4964.5 4990.0 5040.0 5061.0 5103.5 5126.0 5207.0 5219.5 5242.5 5259.5 5291.5 5327.5 5334.0 5364.0 5398.0 5532.0 5556.0 5572.5 5610.0 5650.0 5677.0 5719.0 5739.0 5758.5 5761.5 5767.0 5808.5 5828.5 5843.5 5857.5 5891.5 5936.0 5952.0 5966.5 5999.5 6056.0 6070.5 6078.0 6086.5 6135.5 6172.0 6190.0 6205.0 6213.5 y-07apbl.tapx Page 5 Y-07apbl.tapx 6237.0 6228.5 6246.5 6237.5 6306.5 6298.0 6324.0 6315.5 6355.0 6345.0 6376.0 6365.5 6380.5 6371.0 6448.5 6440.0 6474.0 6463.5 6488.0 6478.0 6507.0 6499.0 6521.0 6513.0 6536.5 6528.0 6563.0 6553.0 6592.0 6584.5 6665.0 6656.0 6679.0 6670.5 6725.5 6715.5 6732.0 6720.0 6742.5 6734.5 6853.5 6842.5 6875.5 6864.0 6883.0 6871.5 6901.5 6890.5 6968.0 6956.0 6979.5 6967.0 6984.0 6973.0 7028.0 7018.0 7061.5 7052.0 7068.5 7059.0 7080.5 7071.0 7093.5 7084.0 7100.0 7089.0 7168.0 7155.5 7294.0 7282.5 7303.0 7292.0 7346.0 7334.0 7389.5 7378.0 7405.5 7395.0 7430.5 7419.0 7472.5 7462.0 7492.0 7482.5 7523.5 7510.5 7530.0 7518.0 7552.0 7539.5 7574.0 7562.0 7603.5 7591.0 7648.5 7637.5 7654.0 7642.0 7656.5 7645.5 7669.0 7658.5 7693.0 7681.5 7697.0 7685.0 7701.5 7690.0 7713.0 7701.0 7723.5 7713.0 7748.0 7735.5 7799.0 7785.5 7813.0 7800.5 7820.5 7807.5 7860.0 7848.0 7910.0 7897.5 7918.5 7907.0 Page 6 y-07apbl.tapx 7938.5 7926.5 7950.5 7939.5 7986.5 7978.5 8007.5 7996.5 8037.5 8025.5 8079.0 8067.0 8095.0 8083.0 8109.5 8097.0 8120.0 8108.0 8148.0 8134.5 8166.0 8153.5 8220.5 8210.0 8232.0 8220.5 8240.0 8226.5 8260.5 8246.5 8279.0 8266.5 8288.0 8275.5 8336.5 8322.0 8413.5 8400.0 8429.5 8415.5 8436.0 8423.0 8471.0 8457.0 8480.0 8467.0 8498.0 8486.5 8520.5 8508.5 8539.5 8525.5 8545.5 8531.0 8584.0 8570.5 8599.5 8586.5 8647.5 8633.5 8667.0 8652.5 8693.5 8680.5 8715.0 8702.0 8722.0 8707.5 8833.0 8819.0 8871.5 8857.5 8999.0 8987.0 9047.5 9034.5 9070.0 9057.0 9089.5 9076.5 9114.0 9101.0 9245.0 9231.5 9259.5 9246.0 9279.5 9266.5 9311.5 9298.0 9324.5 9311.0 9332.5 9319.0 9342.5 9328.5 12759.0 12745.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 1821.0 3771.0 MwD 2 3771.0 9305.0 MwD 4 9305.0 12399.0 MwD 5 12399.0 12745.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Page 7 • • M y-07apbl.tapx 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 1823 12759 7291 21873 1823 12759 RPD MWD OHMM 0.23 2000 7.75962 6805 9303.5 12705.5 RPM MWD OHMM 0.83 2000 4.1374 6805 9303.5 12705.5 RPS MWD OHMM 0.83 2000 4.01879 6805 9303.5 12705.5 RPX MWD OHMM 0.83 2000 3.58058 6805 9303.5 12705.5 FET MWD HR 0.26 191.78 2.84187 6805 9303.5 12705.5 GR MwD API 12.69 394.19 88.3341 21865 1823 12755 ROP MWD FPH 0.74 967.1. 177.629 21408 2055.5 12759 First Reading For Entire File..........1823 Last Reading For Entire File...........12759 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type ................L0 N2xt File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER Page 8 y-07apbl.tapx 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 GR 1821.0 3721.5 $oP 2052.5 3771.0 LOG HEADER DATA DATE LOGGED: 28-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3771.0 TOP LOG INTERVAL (FT): 2052.0 BOTTOM LOG INTERVAL (FT): 3771.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 4.6 MAXIMUM ANGLE: 62.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): .O BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 60.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 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 Page 9 • • Optical log depth units......... y Fee pbl.tapx 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 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1821 3771 2796 3901 1821 3771 GR MWDO10 API 13.55 111.7 60.6356 3802 1821 3721.5 RoP MWD010 FPH 4.25 6 74.91 236.201 3438 2052.5 3771 First Reading For Entire File..........1821 Last Reading For Entire File...........3771 File Trailer Service name... .......STSLIB.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 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 3722.0 9266.0 ROP 3771.5 9305.0 LOG HEADER DATA Page 10 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: • y-07apbl.tapx 02-JAN-08 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 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 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 Insite 74.11 Memory 9305.0 3771.0 9305.0 62.0 65.2 TOOL NUMBER 132478 12.250 .0 Fresh water Gel 9.40 50.0 9.0 1100 .0 .000 .0 .000 124.0 .000 .0 .000 .0 Name service Order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FPH 4 1 68 8 3 Page 11 i • y-07apbl.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3722 9305 6513.5 11167 3722 9305 GR MWD020 API 12.69 135.54 67.3249 11089 3722 9266 ROP MWD020 FPH 2.2 967.1 192.489 11068 3771.5 9305 First Reading For Entire File..........3722 Last Reading For Entire File...........9305 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9266.5 12358.0 FET 9290.0 12345.0 RPD 9290.0 12345.0 RPx 9290.0 12345.0 RPS 9290.0 12345.0 RPM 9290.0 12345.0 ROP 9305.5 12399.0 LOG HEADER DATA DATE LOGGED: 11-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12399.0 TOP LOG INTERVAL (FT): 9305.0 BOTTOM LOG INTERVAL (FT): 12399.0 Page 12 • BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: y-07apbl.tapx 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 • 41.7 66.0 TOOL NUMBER 132478 228272 8.500 9305.0 Fresh water Gel 10.00 56.0 9.5 750 3.5 1.800 80.0 1.080 138.0 2.000 72.0 1.600 70.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 Page 13 y-07apbl.tapx 0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9266.5 12399 10832.8 6266 9266.5 12399 RPD MWD040 OHMM 0.23 2000 8.47035 6111 9290 12345 RPM MWD040 OHMM 0.83 2000 4.43355 6111 9290 12345 RPS MWD040 OHMM 0.83 2000 4.30426 6111 9290 12345 RPX MWD040 OHMM 0.83 2000 3.81362 6111 9290 12345 FET MwD040 HR 0.26 191.78 1.85933 6111 9290 12345 GR MWD040 API 34.9 394.19 139.823 6184 9266.5 12358 ROP MWD040 FPH 1.63 463.16 127.736 6188 9305.5 12399 First Reading For Entire File..........9266.5 Last Reading For Entire File...........12399 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 12345.5 12691.5 RPD 12345.5 12691.5 RPM 12345.5 12691.5 RPS 12345.5 12691.5 RPx 12345.5 12691.5 GR 12358.5 12741.0 ROP 12399.5 12745.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Page 14 14-7AN-08 Incite 74.11 Memory e TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: y-07apbl.tapx 12745.0 12399.0 12745.0 46.1 46.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 WR4 ELECTROMAG. RESIS. 4 228272 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9305.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 11.00 MUD VISCOSITY (5): 54.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 360 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.570 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .690 145.0 MUD FILTRATE AT MT: 1.330 58.0 MUD CAKE AT MT: 1.240 62.3 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 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 15 y-07apbl.tapx • First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 12345.5 12745 12545.3 800 12345.5 12745 RPD MWD050 OHMM 1.02 5.16 1.49853 693 12345.5 12691.5 RPM MwD050 OHMM 1.03 9.12 1.52716 693 12345.5 12691.5 RPS MWD050 OHMM 1.01 9.88 1.50261 693 12345.5 12691.5 RPX MWD050 OHMM 1.02 11.88 1.52589 693 12345.5 12691.5 FET MwD050 HR 0.55 37.32 11.5061 693 12345.5 12691.5 GR MWD050 API 38.93 149.23 116.357 766 12358.5 12741 ROP MWD050 FPH 0.74 183.97 78.7374 692 12399.5 12745 First Reading For Entire File..........12345.5 Last Reading For Entire File...........12745 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/05/14 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comment5 .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/05/14 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF Library. Scientific Technical Services Library. scientific Technical services End Of LIS File Page 16 ~ • y-07apbl.tapx Page 17