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205-164
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC Y-11C PRUDHOE BAY UNIT Y-11C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 Y-11C 50-029-20513-03-00 205-164-0 W SPT 8789 2051640 2197 403 415 416 415 23 62 74 77 4YRTST P Lou Laubenstein 5/14/2022 Standad 4-year 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-11C Inspection Date: Tubing OA Packer Depth 139 2503 2472 2463IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220516085930 BBL Pumped:6.3 BBL Returned:6.3 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 15:16:01 -08'00' MEMORANDA • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,May 18,2018 Jim Rr P.I.Supervisor lC J' ,KJ SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. l6 Y-11C FROM: Bob Noble PRUDHOE BAY UNIT Y-11C Petroleum Inspector Src: Inspector Reviewed By:+� P.I.Suprv. p2---- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Y-11CAPI Well Number 50-029-20513-03-00 Inspector Name: Bob Noble Permit Number: 205-164-0 Inspection Date: 5/12/2018 Insp Num: mitRCN180512144301 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I Y-11C 'Type Inj W "!TVD 8789 Tubing 599 594 600 ' 598 - PTD 2051640 Type Test SPT Test psi 2197 IA 9 2500 - 2482 2476 BBL Pumped: 6.2 BBL Returned: 3.5 OA 101 278 - 282 - 321 Interval 4YRTST P/F P Notes: some JUN 0 1 2018 Friday,May 18,2018 Page 1 of I Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~j - ~ ~ ~.- Well History File Identifier Organizing (done> ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIIII II II III IN RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~iskettes, No. I ^ Maps: ~Greyscale Items: l ~~ ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: g ~ ^ Other:: /s/ Project Proofing III IIIIII VIII II III BY: Maria Date: ~ /s/ , i P ti S ~ 30 = + ~ =TOTAL PAGES ~ V repara on cann ng x I (Count does not include cover sheet) ~ BY: Maria Date: ~ ~ 55 / / 1 R /sl i Production Scanning Stage 1 Page Count from Scanned File: (Count does include cov sheet) Pa e Count Matches Number in Scanning Preparation: YES NO 9 BY: Maria Date: a.~~,$'/D ~ /s/ I Stage 1 if NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I iI ~I II I II II I (III R.s~:~ ~ iuiuiiuiiamu BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I II -7-~ 10/6/2005 Well History File Cover Page.doc • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 20, 2010 9011 5r444 34" Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ��* �' ' " ;,� asiatl L : >e... 333 West 7 Avenue Anchorage, Alaska 99501 bc Subject: Corrosion Inhibitor Treatments of GPB Y Pad Dear Mr. Maunder, 1 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 14.5 2.0 0.3 NA 1.70 8/4/2010 Y -08A 1880560 50029205720100 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 - 11C 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 • MEMORANDUM To: Jim Regg r / P.I. Supervisor ~~~ ~` Z~ !~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y-11 C PRUDHOE BAY UNIT Y-1 ] C Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .~ Comm Well Name: pRUDHOE BAY UNIT Y-11C Insp Num: mitCS100711170705 Rel Insp Num: API Well Number: 50-029-20513-03-00 Permit Number: 205-164-0 Inspector Name: Chuck Scheve Inspection Date: x/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WCII Y-11C '" Type Inj. ~' TVD 8789 ~ IA 40 3960 3960 3940 - 3940 ' P.T.D 2051640 TypeTest SPT Test psi 2197 - OA ao ao so so so Interval aYRTST p~ P ~ Tubing looo looo looo tooo looo Notes: pre-test pressures observed and found stable. ' ._.,. .. Wednesday, July 14, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test r Email to:jim.regg~alaska.gov; phcebe_brooks~alaska.gov; tom.maunder@alaska.gov; doa.aogcc.pnidhce.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT 1 PAD: Prudhoe Bay /PBU / Y pad DATE: 07/08!10 OPERATOR REP: Jerry Murphy AOGCC REP: Jeff Jones Packer h Pretest Initial 15 Min. 30 Min. WTI Y-11C T I '. W TVD 8,789' T 1,000 1,000 1,000 1,000 Interval 4 P.T.D. 2051640 T test P Test 219725 ~ 3,960 3,960 3,940 P/F P Notes: MIT-IA to 4000 for 4 y~r /pre MI for U1C OA 4t1 80 80 80 Well T In'_ TVD T 1,000 Interval P.T.D. T test Test 3,940 P/F Notes: Extended additrorral 15 mirrs for stabilizatiar OA 90 Well T Iri . TVD Tu ' Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD T ~ Interval P.T.D. T test Test P/F Notes: OA Well T I ~. TVD T Interval P.T.D. T test Test P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D =Drilling Waste M =Annulus AAorator"urg G =Gas P =Standard Pressure Test I =Industrial Wastewater R = Interval Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D = DtiFerential Temperature Test ~gr-~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (descrilx: in notes) MIT Report Form BFL 11127/07 MIT PBU Y-11 07-08-10.x1s ~ ~~ ~ar.. ~~ o~ DATA SUBMITTAL CQMPLIANCE REPORT 2/6/2008 Permit to Drill 2051640 Well Name/No. PRUDHOE BAY UNIT Y-11C MD 15868 TVD 9060 REQUIRED INFORMATION Completion Date 12/25/2005 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20513-03-00 Completion Status WAGIN Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES / ABI, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No og Sonic 5 Col 1 I"!, Log Injection Profile Blu 1 I,~ D Asc Directional Survey ~t 15355 LIS Verification C Lis 15355 Induction/Resistivity D C Lis 15400 Induction/Resistivity Well Cores/Samples Information: Current Status WAGIN Directional Survey Yes -~~ (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 7300 10735 Case 3/3/2006 Ultrasonic Imager Tool - Rev 1 GR/CCL/USIT - B 22-Dec-2005 10470 14195 Case 6/20/2007 Mem Injection Profile, GR, CCL, Temp, Pres, Spin 1- Jun-2007 0 0 1/17/2006 DEFINITIVE SURVEY 7070 15827 Open 8/23/2007 LIS Veri, GR, ROP, FET 7070 15827 Open 8/23/2007 LIS Veri, GR, ROP, FET 7070 15827 Open 9/12/2007 LIS Veri, GR, ROP, FET w/Graphics PDF and EMF Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~N Daily History Received? ~ N Chips Received? ~Y~-N-' Formation Tops ~/ N Analysis ~4Pd~ Received? s Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051640 Well Name/No. PRUDHOE BAY UNIT Y-11C MD 15868 TVD 9060 Completion Date 12!25!2005 Compliance Reviewed By: Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20513-03-00 Completion Status WAGIN Current Status WAG{N UIC Y Date: ~Ll ~ -~- ~-~_~__l~~ 8 To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : Y-11CI August 15, 2007 AK-MW-4064799 Y-11 CI: Digital Log Images: 50-029-20513-03 1 CD Rom 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 .~~ ,~ .~ ~~ ate: ~. r R ~~~~:a ~~ ,.. ,_ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ aos - t~~(~ ~ ~~a~ try WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: Y-1 lA August 7, 2007 AK-MW-4064799 1 LDWG formatted CD rom with verification listing. API#: 50-029-20513-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURl~1ING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ ~~'~; ~~ Date: ^ ~ ;_' es w i Y 'w~v.°' ,}{?~. i~viri9i'i1J`v°i(i~I BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 i Signed: UZC205 =-1(oy ~ t S3S~~ os/1 a/o7 .. Schlumber~er Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wpu L,ti ~ 1 ,... new.- ..~:.... N0.4306 Company: State of Alaska Alaska Oi18 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n..a., e~ r_~_- nn L3-12 11695062 PRODUCTION PROFILE 06/06/07 GNI-03 11637128 PRESS/TEMP SURVEY Ofi106/07 Y-11C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 05-30 11801067 LDL 06/01/07 1 13-29L1 11686753 LDL 05/28/07 1 Y-05A 11628778 MEMORY INJECTION PROFILE 05/28/07 1 L5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROF/IPROF 06105/07 1 Y-35A 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFILE 06/13107 1 01-07A 11626098 PRODUCTION PROFILE 05128107 1 13-29L1 11686753 LDL 05/28!07 1 04-24 11773112 PRODUCTION LOG 05119107 1 12-19 11637343 LDL 06/13/07 1 G-23A 11638639 LDL 06103107 1 14-OSA 11813055 PPROF W/RST BORAX 06/11/07 1 K-12A 11745224 MEMORY PROD PROFILE 06102/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/08/07 1 3-41IK-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04/21/07 1 W-17A 40012333 OH EDIT MWDILWD 09/19/05 2 1 • ccs-•vc rev ~•~v~~cc uvc nGa+Glr 1 0^ J~V Ir119V AIYU RCI VR1711Y~7 V19C liVrT CAlir7 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 --- - -- - 900 E Benson Blvd. ~' Anchorage, Alaska 99508 T Date Delivered: ;T ~~ ~~~tr~ i7 '` Y f ~ - l Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: STATE OF ALASKA ALAS AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~G~~~~ FEe o $ 2oas Alas#ia O! ~ Gaa Cons. Cffnxni~iOQ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/25/2005 12. Permit to Drill Number 205-164 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11 /20/2005 13. API Number 50- 029-20513-03-00 4a. Location of Well (Governmental Section): Surtace: ' ' 7. Date T.D. Reached 12/12/2005 14. Well Name and Number: PBU Y-11C 1433 FNL, 313 FEL, SEC. 33, T11N, R13E, UM Top of Productive Horizon: 4860' FNL, 4277' FEL, SEC. 33, T11N, R13E, UM 8. KB Elevation (ft): 79 9 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 2314' FNL, 2160' FEL, SEC. 04, T10N, R13E, UM 9. Plug Back Depth (MD+TVD) 14227 + 9040 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 644504 y- 5948816 Zone- A SP4 10. Total Depth (MD+TVD) 15868 + 9060 Ft 16. Property Designation: ADL 047471 _ TPI: x-__640614__ y-_ 59_45315 Zone- ~ASP4 Total Depth: x- 642789 Y- 5942623 Zone- ASP4 11 • Depth where SSSV set None MD 17. Land Use Permit: ----- ------ ~~~~---------------- f P i f t 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ckness o erma ros 20. Th 1900' (Approx.) 21. Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES / ABI, USIT 2. ASING, LINER AND EMENTING ECORD CiASING ETTINp EPiH MD ET71N0 EPTH TVD HOLE OUNT :- SIZE WT. PER FT. GRADE OP TTOM OP TTOM .SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" cu ds Concrete 13-3/8" 72# L-80 Surface 2662' Surface 2662' 17-1/2" 301 cu ft Permafrost II 9-5/8" 47# L-80 Surface 7488' Surtace 6804' 12-1/4" 1320 cu ft Class'G' 130 cu ft PF 7" 26# L-80 7321' 10900' 6661' 8887' 8-1/2" 19 cu ft Class'G' 4-1/2" 12.6# L-80 10784' 14313' 8819' 9047' 6-1/8° 13 cu ft Class'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING' RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10789' 10732' MD TVD MD TVD 13550' - 13570' 9026' - 9024' 13980' - 14000' 9025' - 9026' 13600' - 13620' 9020' - 9019' 14040' - 14060' 9029' - 9030' 25. ACID, FRACTURE, CEMENT SQUEEZE, .ETC. 13640' - 13660' 9017' - 9016' 14090' - 14110' 9032' - 9033' 13890' 13910' 9020' 9020' 141 03 ' 9 ' ' ' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 40 - 14160 9 4 - 035 13940' - 13960' 9022' - 9023' 14180' - 14200' 9036' - 9038' 2200' Freeze Protect w/ 151 Bbls of Diesel 26. PRODUCTION TEST Date First Production: January 8, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Pr@SS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submlt core chips; if none, state "none". ( ~ ~ c~ ~~ ~„""',N ~~~~~ ~~~ F I" ~' ~ ~ 2000 ~ ~u~r~e ~ None ~,~, ( .~G Form 10-407 Revised 12/2 ONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER 29' .'OFMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10920' 8899' None Shublik A 10961' 8922' Shublik B 11031' 8957' Shublik C 11078' 8977 Sadlerochit 11180' 9006' HOT 12425' 9057' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date ~"Vl~~p PBU Y-11 C 205-164 Prepared By Name/Number. Teiiie Hubble, 564-4628 Well Number Permit No. / A royal No. Dolling Engineer: JefiCut/er, 564-4134 INSTRUCTIONS GeNeaa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of 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. ITEM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one 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). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12!2003 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: Y-11 Common Name: Y-11 Test Date j Test Type ~ Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure ~eak Off Pressure (BHP) EMW - - -- 11/19/2005 FIT 7,488.0 (ft) 6,806.0 (ft) 11.10 (ppg) 320 (psi) 4,244 (psi) 12.01 (ppg) 11/26/2005 FIT 10,900.0 (ft) 8,887.0 (ft) 8.40 (ppg) 740 (psi) 4,618 (psi) 10.00 (ppg) Printed: 12/27/2005 8:35:12 AM BP EXPLORATION Operations Summary Report Legal Well Name: Y-11 Common Well Name: Y-11 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To I Hours Task 'i Code NPT 11 /15/2005 16:00 - 20:00 I 4.00 MOB ~ P 20:00 - 00:00 4.00 MOB P 11/16/2005 00:00 - 02:00 2.00 MOB P 02:00 - 13:00 11.00 MOB P 13:00 - 17:30 4.50 MOB P 17:30 - 21:00 3.50 MOB P 21:00 - 21:30 0.50 MOB P 21:30 - 00:00 2.50 DHB P 11/17/2005 100:00 - 03:30 I 3.501 KILL I P 03:30 - 04:00 I 0.501 DHB I P 04:00 - 06:30 2.50 WHSUR P 06:30 - 09:00 2.50 BOPSU P 09:00 - 10:00 1.00 BOPSU P 10:00 - 14:30 4.50 BOPSU N SFAL 14:30 - 21:00 I 6.501 BOPSUR P 21:00 - 23:00 2.00 BOPSU N SFAL 23:00 - 00:00 1.00 WHSUR P 11/18/2005 00:00 - 00:30 0.50 WHSUR P 00:30 - 02:00 1.50 BOPSU N SFAL 02:00 - 03:30 I 1.501 PULL I P 03:30 - 05:00 I 1.501 PULL I N I WAIT 05:00 - 06:00 I 1.001 PULL I P 06:00 - 07:00 I 1.001 PULL I P 07:00 - 14:00 I 7.001 PULL I P 14:00 - 15:00 1.00 PULL P 15:00 - 16:00 1.00 CLEAN P 16:00 - 18:30 2.50 CLEAN P 18:30 - 22:30 4.00 DHB P 22:30 - 23:30 1.00 DHB P 23:30 - 00:00 0.50 STWHIP P 11/19/2005 00:00 - 04:30 4.50 STWHIP P Page 1 of 15 Spud Date: 10/24/1980 Start: 11/14/2005 End: 12/25/2005 Rig Release: 12/25/2005 Rig Number: i Phase ; Description of Operations PRE Move camp, shop and pits. Bridle derrick. Lay down pipe shed chute. Lay derrick down. Move substructure module off well. PRE Start moving shop, pits, and camp to Y Pad. PRE Move camp, pits, and shop to Y-Pad. PRE Move rig to Y-Pad. PRE Spot sub over well. Spot pits and install new flowline. PRE Raise derrick. Bridle down. Rig up floor. Berm and set cuttings pit. Take on water. Accept rig ~ 2100 hrs 11/16/2005. DECOMP Pre Spud meeting with crew, mud engineer, toolpush, co. man. DECOMP NU second valve on tbg head.0 psi IA, 0 psi OA.i Pulled BPV w/ lubricator. 0 psi TP. RU lines to circ well. DECOMP RU lines to circ. Test lines to 1,500 psi. Rev diesel out of tubing - 3 bpm - 280 psi. Switch lines. Circ down tubing -circ out freeze protect diesel. Pumped soap pill and displaced well with clean seawater. Observe well -Static. DECOMP Dry rod TWCV. Test from below to 1,000 psi. Held. RD circ lines. DECOMP ND Tree and adaptor - remove from cellar. DECOMP NU BOP's. DECOMP RU to test BOP's with 4 1/2" test joint. DECOMP Attempt to test BOP's. TWCV leaking. Pulled TWCV and set new TWCV w/ lubricator and extension. DECOMP Test BOP's as per BP policy to 250 psi low and 4,000 psi high. Annular to 250 psi low / 3,500 high. Upper IBOP failed low pressure test. Test witness waived byJeff Jones w/ AOGCC. Test witnessed by Mike Whiteley - BP and Ronnie Dalton and Charile Henley -Nabors. DECOMP Remove upper IBOP. DECOMP RU lubricator and extension. Pulled TWCV. DECOMP RD DSM lubricator. DECOMP Install upper hyd IBOP and TIW valve. Test upper IBOP to 250 psi low and 4,000 psi high. Blow down TD. RD test equipment. DECOMP MU double grapple spear (3.947" grapples). BOLDS. Attemp to spear tubing. Bottom grapple going in tbg pup 3". Made several attempts. DECOMP Wait on smaller grapple from Baker fishing tool. Rev circ 100 bbls warm water down annulus. DECOMP Re-engage tubing with 3.885" grapples. Pull hanger to floor with approx 50 klbs over calc wt - 160 klbs. DECOMP LD tbg hanger and spear. Clear floor. RU 4.5" tubing handling tools. DECOMP POOH laying down 4.5" 12.6# L80 NSCT tubing - 181 jts + 32.45' piece. DECOMP RD tubing handling tools. Set wear ring. DECOMP PJSM - RU SWS. MU tools. DECOMP Ran 8.5" O.D gage ring / GR / CCL. Tagged tubing stump C~3 7,615'. Ran GR / CCI log to 7,050'. POOH. DECOMP Ran and set 9 5/8" EZSV plug C~ 7,524'. POOH RD SWS. DECOMP Test 9 5/8" csg /EZSV plug to 4,000 psi for 30 min. Held. WEXIT Pull tools to rig floor. RU to PU whipstock BHA. WEXIT MU Whipstock /Window mill BHA. PU window mills, HWDP, MWD tools, UBHO sub. Orient, upload MWD, surface test tools. PU 9 5/8" whipstock, B.S., 6 1/8" DC's, 5" HWDP. Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Operations Summary Report Legal Well Name: Y-11 Common Well Name: Y-11 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To .Hours ~' Task ~~ Code ~ NPT ~!~ __ - - - -- I 1.00 STWHIP P 2.00 STWHIP P 11/19/2005 00:00 - 04:30 4.5~ STWHIP P WEXIT 04:30 - 10:30 6.00 STWHIP P WEXIT 10:30-11:00 0.50 STWHIP P 11:00 - 12:00 1.00 STWHIP P 12:00 - 13:30 I 1.501 STWHIPI P 13:30 - 22:30 I 9.00 I STWHIPI P 22:30 - 23:00 I 0.501 STWHIPI P 23:00 - 23:30 I 0.501 STWHIPI P 23:30 - 00:00 I 0.501 STWHIPI P 11 /20/2005 00:00 - 01:00 01:00 - 04:00 04:00 - 07:00 1.00 STWHIP P 3.00 STWHIP P 3.00 STWHIP P 07:00 - 08:00 08:00 - 10:00 10:00 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 19:00 19:00 - 00:00 11 /21 /2005 00:00 - 01:00 01:00 - 03:00 03:00 - 05:30 05:30 - 00:00 11 /22/2005 00:00 - 00:00 11/23/2005 00:00-05:30 4.00 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 2.501 DRILL I P Start: 11 /14/2005 Rig Release: 12/25/2005 Rig Number: t Page 2 of 15 Spud Date: 10/24/1980 End: 12/25/2005 Phase I Description of Operations WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT INT1 5.001 DRILL N RREP INTi 1.00 DRILL N RREP I NTi 2.00 DRILL P I NT1 2.50 DRILL N RREP I NT1 18.50 DRILL P I NTi 24.00 DRILL P I NT1 5.50 DRILL P I NT1 Change handling tools. RIH with whipstock /window mills picking up 4" DP to 7,400'. Fill pipe every 3,000'. Service top drive and install blower hose. Fill pipe. Orient to 15 deg RHS. Stand back one stand. PU 3 singles. Break circ. Tag C~J 7,509'. UP 180k, DN 150K, Set 20k down and set bottom trip anchor. PU and confirm set. Set 40k down and shear whipstock lug. PU to confirm free. Displace well to 11.1 ppg LSND mud - 500 gpm C~ 2,260 psi. SPR's. Mill window in 9 5/8" csg from 7,488' TOW to 7,505' BOW and 20' new hole to 7517'. 500 gpm C~3 2,500 psi, RPM 100, WOB 5 -12K, TQ 8 -10K, UP 165K, DN 145K, ROT 155K. Pump super sweep around. Recover total 215 Ibs metal cuttings. Work mills thru window - no problems. Pull mill up to 7,440'. Performed FIT to 12.0 ppg EMW with 11.1 ppg mud - 6806' TVD, surface pressure 320 psi. Pump dry job. Remove blower hose. Blow down surface equipment. MW 11.1 ppg in, 11.1 ppg out. Cut and slip drilling line. POOH to BHA. Pulled BHA. Stand back HWDP. LD DC's, bumper sub, UBHO sub. Download /Upload MWD/ LWD. LD MWD and window mills. String mill full gauge. Pull wear ring. Flush out stack and mud cross valves. Functioned all rams. Installed wear ring. PJSM. MU 8.5" drilling BHA. PDC bit, 7" motor - 1.22 deg, MWD. Orient. PU NM flex collars. Surface test MWD. RIH w/ HWDP and jars. RIH picking up 4" DP to 5,094'. Fill DP every 3,000'. RIH to 7,428'. Service top drive. Install blower hose. Orient 10 deg RHS. Slide thru window f/ 7,488' to 7,513' pumps off. Wash to bottom @ 7,517'. Dir drill 8.5" intermediate hole f/ 7,517' to 7,623'. AST = 1.28 hrs, ART = 0.32 hrs. UP 160K, DN 135K, RT 150K, TQ 6k off, TO 8k on, 75 RPM. Lost power from #2 generator. Trouble shoot #2 Generator. MW 11.1 ppg in & out. Pull bit up into 9 5/8" csg. Repair #2 generator -replace exciter card. RIH and orient. Dir drill from 7,623' to 7,739'. Run base line ECD's -Lost power from #2 Generator. MW 11.1 ppg in & out. Pull bit into 9 5/8" csg. Trouble shoot #2 generator. Clean exciter brushes. Dir drill f/ 7,739' to 8,846'. AST = 5.94 hrs, ART = 9.65 hrs. UP 170K, DN 135k, ROT 150k, RPM 95, WOB 8 -12K, 492 gpm @ 3,280 / 3,480 psi, TO 7 off, 8k on. ECD = 11.87 ppg. Dir drill f/ 8,846' to 10,414'. UP 195K, DN 140k, RT 165K, TO off 8.5 K, TO on 10.5k, 490 gpm 3,720psi / 3,990 psi. RPM 90. ECD = 11.81 Ppg. Dir. drill f/ 10,414' to 10, 660'. UP 215K, DN 140k, RT 168K, TO 10K off, 11.5K on, 480 gpm Q 3,720 psi / 3,900 psi. RPM 90, ECD = 11. 7 ppg. No problems. Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Operations Summary Report Legal Well Name: Y-11 Common Well Name: Y-11 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date ~ From - To ~ Hours Task Code f NPT ~! - - - Start: 11 /14/2005 Rig Release: 12/25/2005 Rig Number: Phase 11/23/2005 05:30 - 06:00 0.50 DRILL P INT1 06:00 - 08:30 2.50 DRILL P INT1 08:30 - 11:00 2.50 DRILL N RREP INTi 11:00 - 13:00 I 2.001 DRILL I P I I INTi 13:00 - 15:00 2.00 DRILL P INTi 15:00 - 17:30 2.50 DRILL P INTi 17:30 - 18:30 1.00 DRILL P INT1 18:30 - 19:00 0.50 DRILL P INT1 19:00 - 21:00 2.00 DRILL P INT1 21:00 - 22:30 { 1.50 {DRILL ~ P ~ ~ INT1 22:30 - 23:30 1.00 DRILL N RREP INTi 23:30 - 00:00 0.50 DRILL P INT1 11/24/2005 100:00 - 01:00 I 1.001 DRILL I P I I INT1 01:00 - 03:00 2.00 DRILL P INT1 03:00 - 05:00 2.00 DRILL P INTi 05:00 - 07:30 2.50 DRILL P INT1 07:30 - 11:00 3.50 DRILL P INT1 11:00 - 13:30 I 2.501 CASE I P I I LNR1 13:30 - 17:30 4.00 CASE P LNR1 17:30 - 19:00 1.50 CASE P LNR1 19:00 - 21:30 2.50 CASE P LNR1 21:30 - 22:00 0.50 CASE P LNR1 22:00 - 00:00 2.00 CASE P LNR1 11/25/2005 00:00 - 04:30 4.50 CASE P LNR1 04:30 - 05:30 1.00 CEMT P LNR1 05:30 - 07:00 1.50 CEMT P LNR1 Page 3 of 15 Spud Date: 10/24/1980 End: 12/25/2005 Description of Operations Change swab in #1 pump. Circ pumping 270 gpm. Dir. drill f/ 10,660' to 10,807'. MW 11.1 ppg in, 11.2 ppg out. Trouble shoot #2 generator -load share failure. Rotate & recipicate -pump 270 gpm / 1,450 psi. Dir. drill f/ 10,807' to 10,900'. ART = hrs, AST = hrs. UP 215K DN 135K, 170 K, RPM 90- 480 gpm @ 3,740 psi / 3,890 psi. ECD = 11.8 ppg. Circ for samples - 480 gpm 3,670 psi. - MW 11.1 ppg in & out. POOH f/ 10,900' to 7,428'. Intermittant drag 25k to 50k over string weight. Cut drilling line. Service crown and drawworks. Service top drive. RIH f/ 7,428' to 10,880' - 15K drag @ 7,550', 30k drag @ 9,700'. Hole O.K. Wash 20' to bottom. Rotate, recipicate and stage pumps up. Circ and conditon mud and hole for 7" liner. Rotate 90 RPM / Recipicate. Pump hi vis sweep around @ 480 gpm @ 3,950 psi. Replace swab in #1 pump. Trouble shoot #2 generator -change out AC module - circ w / one pump 947 psi 190 gpm. Circ hole clean @ 420 gpm @ 3,250 psi. Rotate 90 RPM / recipicate Still have generator load share problem. Circ @ reduced pump rate. Spot 230 bbls liner running pill. Monitor well. Slug DP. Blow down. MW 11.1 ppg in & 11.2 ppg out. UP 220K, DN 135K, RT 170K, TO off 12,500. Initial ECD 11.9 ppg, Final ECD 11.66 PPg• POOH f{ 10,900' to 7,615' @ 60 fpm. Intermitant drag 20K - 30K over string weight. No problems. Dropped 2 3/8" rabbit. Mad pass log f/ 7610' to7110' @ 300 fUhr. Remove top drive blower hose. POOH to run 7' liner from 7110 to 803' @ 90 fpm. L/D HWDP, jars & flex collars. Flush BHA with fresh water. Down load tools & LiD mud motor. Clear and clean rig floor. Blind rams closed. PJSM. R/U casing equip. PJSM with all personell. M/U float equip and check floats. RIH with 7" 26# L-80 BTC-M liner to 3554'. M/U liner hanger/packer, pup and 1 stand of drill pipe. Circ liner volume @ 8 bpm @ 1080 psi. UWT = 108K, DWT = 105K. RIH with liner on drill pipe from 3693' to 7" window @ 7426'. Circ drill pipe and liner volume @ 8 bpm @ 1080 psi. UWT = 180K, DWT = 120K. RIH from 7426' to 10880' and M/U cement head. Fill pipe. Attempt to break circ. Hole packed off (800 psi) @ 10,885'. Work pipe pulling 340K -unable to move pipe down. LD 1 jt DP and work pipe up to 10,810'. Established circ -stage pumps up to 4 bpm @ 825 psi. Wash liner to bottom @ 10,900'. Stage pumps up to 7 bpm @ 2,000 psi. Full returns. PJSM. Circ @ 7 bpm - 2,950 psi. Schlumberger cemented. Pumped 5 water. Test lines to 4,500 psi. Pumped 38.5 bbls Mud push II spacer @ 12.0 ppg and 39 bbls Class "G" @ 15.8 ppg. Schlumberger displace @ 6.9 BPM Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Operations Summary Report Legal Well Name: Y-11 Common Well Name: Y-11 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Start: 11 /14/2005 Rig Release: 12/25/2005 Rig Number: - Date From - To Hours Task Code NPT ~ Phase 11/25/2005 105:30 - 07:00 ~ 1.501 CEMT ~ ~LNR1 07:00 - 08:00 1.00 CEMT P 08:00 - 08:30 0.50 CEMT P 08:30 - 12:00 3.50 CEMT P 12:00 - 18:00 6.00 BOPSU P 18:00 - 20:30 2.50 DRILL P 20:30 - 21:30 1.00 CASE P 21:30 - 00:00 2.50 DRILL P 11/26/2005 00:00 - 01:00 1.00 DRILL P 01:00 - 03:00 2.00 DRILL P 03:00 - 03:30 0.50 DR1LL P 03:30 - 06:30 3.00 DRILL P 06:30 - 08:30 2.00 DRILL P 08:30 - 09:00 0.50 DRILL P 09:00 - 10:30 1.50 DRILL P 10:30 - 14:00 3.50 DRILL P 14:00 - 14:30 0.50 DRILL P 14:30 - 15:00 15:00 - 11 /27/2005 00:00 - 03:30 0.501 DRILL I P 0.00 DRILL P 3.50 DRILL P 03:30 - 06:00 LNR1 LNR1 LNR1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 2.501 DRILL N DPRB PROD1 Page 4 of 15 Spud Date: 10/24/1980 End: 12/25/2005 Description of Operations w/ mud. Full returns. Bumped plug to 3,600 psi. CIP @ 0638 hrs. Set hanger. Shoe @ 10,900'. Floats held. Released setting tool. Pressure to 1,000 psi and stung out. Circ 500 gpm. Set packer w/ 65k down. Rotate on pkr w/ 60k. CBU @ 7,321' - 500 gpm @ 3,550 psi. MW 11.1 ppg in & out. No cement circ to surface. Blow down surface equipment. L.D. cementing head. Clear rig floor. POOH with running tool. L.D. running tool. Pull wear ring. R.U. BOP test equipment. Test BOP's with 4" test as per BP policy to 250 psi low and 4,000 psi high. Annular to 250 psi low and 4,000 psi high. Witness waived by Winton with AOGCC. Test witnessed by Jim Willingham - BP and Cleve Coyne - nabors. All rams were functioned. RD test equipment. Blow down. Install wear ring. PJSM. Change out wash pipe & packing -test. Test 7" liner & 9 5/8" csg to 4,000 psi against blinds for 30 min - Held. Bleed off and blow down. PJSM. M.U. 6 1/8" drilling BHA. Orient tools, upload, and surface test. Finish making up 6 1/8" BHA - NM flex collars, jars, HWDP. RIH w/ 6 1/8" BHA picking up 47 jts 4" DP. Fill pipe. Float not holding. Circ -slug drill pipe. RIH picking up total 174 jts 4" DP. At 05:00 MWD hand knocked over electrical transformer with his pick up truck. Investigated by Herb Williams, Cleve Coyne, MWD supervisor and Jim Willingham. RIH to 10,574'. Install blower hose. Wash down f/ 10,574' to landing collar @ 10,815'. Drill out plugs and L.C. @ 10,815', good cement, float collar @ 10,857', good cement to 10,896'. WOB 5k, RPM 40, 250 gpm @ 2,200 psi., UP 200K, DN 125k, RT 155k. Displace well to 8.4 ppg Flo-pro. 1380 psi @ 265 gpm. Clean troughs, possum bellies, and shakers. SPR's. Drill shoe @ 10,900' and 21' new hole to 10,921'. Circ 10 min. Pull up to 10,884'. Perform FIT to 10.0 ppg EMW. Mud w- 8.4 ppg, Surface press 740 psi., TVD 8887. Lost 30 psi in 10 min. Dir drill from 10,921' to Dir drill from 11,104' to 11,149'. Flow show increase. Gas breaking out @ surface. No pit gain. Check for flow. Shut well in. SIDPP 170 psi. SICP 70 psi. in 15 min. Attempt to circ thru choke and mud gas seperator. Pressure up to 800 psi. No returns -string plugged or packed off. Bleed off DP &csg .Check for flow.Open hydril. Check for flow. Fluid level 20' below flow line. Pull DP free w/ 40K over string wt. and rotate. Attempt to break circ, move pipe f/ 11,139' to 11,050. Unable to circ. Packed off. Pulled up into 7" csg -slight swabbing. Had 40K drag f/ 10,938' to 7" shoe @ 10,900'. Pulled up into 7" @ 10, 760'. Had 40k drag in csg / Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 11 /27/2005 ~ 03:30 - 06:00 06:00 - 07:30 07:00 - 08:30 08:30 - 11:00 11:00 - 17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 22:30 22:30 - 00:00 11/28/2005 X00:00-01:00 Page 5 of 15 Y-11 Y-11 Spud Date: 10/24/1980 REENTER+COMPLETE Start: 11/14/2005 End: 12/25/2005 NABOBS ALASKA DRILLING I Rig Release: 12/25/2005 NABOBS 2ES Rig Number: Hours I Task Code 2.50 DRILL N 1.50 DRILL P 1.50 DRILL P 2.50 DRILL N 6.50 DRILL P 0.50 DRILL P 1.00 DRILL P 0.50 DRILL P 3.00 DRILL N 1.501 DRILL N 1.001 DRILL N 01:00 -04:00 3.00 DRILL N 04:00 - 07:00 3.00 DRILL N 07:00 - 09:00 2.00 DRILL N 09:00 - 10:30 1.50 DRILL P 10:30 - 12:00 1.50 DRILL N 12:00 - 13:00 1.00 DRILL N 13:00 - 18:00 5.00 DRILL N 18:00 - 18:30 I 0.501 DRILL I N 18:30 - 19:30 1.00 DRILL N 19:30 - 21:30 2.00 DRILL N 21:30 - 23:00 1.50 DRILL P 23:00 - 00:00 1.00 DRILL N 11 /29/2005 00:00 - 05:00 5.00 DRILL N NPT Phase ~ ~, Description of Operations __ DPRB PROD1 packing off. Work pipe /rotate / Establish circ 300 gpm C~ 1,635 psi. Notifyed AOGCC that well was shut in. PROD1 Pump high vis sweep and CBU. H2S gas alarm sounded. Shut in well and evacuate rig. Check well for pressure, open bleed line to pits. Open annular preventor. Check atmosphere with hand held gas detector at bell nipple, methane reading 4%, H2s reading 0. Notify AOGCC that well was shut in. PROD1 Gas breaking out in bell nipple while circulating. When pumps are shut down there is no flow. CBU, shut down pumps and monitor well for 15 min, well is stable. DPRB PROD1 Ream to bottom. Pump C~3 300 gpm ~ 1680 psi. WOB 5/10K. Torque = 5500K. RPM = 45/65. UWT = 180K, DWT = 150K, RWT = 165K. As soon as bit entered open hole well started packing off. Work down 10' below shoe to 10910' and pull back to casing Xs 4. Ream to bottom at 11149' without diffaculty. Well stable. PROD1 Drill from 11149' to 11507'. ART = 2.18 hrs, AST = 1.54 hrs.UWT = 185K, DWT = 150K, RWT = 165K. Torque = 7K off, 9K on C~3 70 rpm. Pump @ 300 gpm C~3 1750/2100 psi. PROD1 Circ for wiper trip to 7" shoe. Monitor well. MW = 8.4 ppg in & out. PROD1 Wiper trip -POOH to 7" shoe ~ 10,900' .Had 40K drag f/ 10,980' to 10,920'. PROD1 Service top drive and attempt to locate oil leak. DPRB PROD1 Start RIH -tagged up @ 10,920' w/ 40K down. Pulled up into 7" csg and broke circ. Wash and ream f/ 10,900' to 10,902'. Motor stalling and packing off. Washed and reamed down to 10,923' - packed off -work pipe back up into 7" csg w/ 60k over. Had 40K drag in 7" csg. Rotate /move pipe and establish circ. Pump Hi vis sweep and continue washing & reaming from 10,900' to 10,915'. Heavy shale over shakers. Unable to clean hole up f/ 10,900' to 10,915'. Packing off, pulling 80k over string wt, jar up and down to get free. DPRB PROD1 Pump sweepout bit. Drop dart and open circ sub. Circ hole clean 500 gpm @ 1,850 psi. DPRB PROD1 Pump 50 bbl high vis sweep. Circ hole clean 500 gpm C~ 1,850 psi. Monitor well. Slug DP. MW 8.4 ppg in & out. DPRB PROD1 POOH to 4,509' -stand back 69 stands. DPRB PROD1 PJSM. POOH laying down 4" DP. DPRB PROD1 LD BHA -down load MW D. PROD1 Clear floor. Service top drive. Change oil in T.D. Investigate oil leak on top drive. DPRB PRODi Wait on 7" cement retainer / Halliburtion hand. DPRB PRODi M.U. 7" EZSV retainer /setting tool on DP. DPRB PROD1 RIH w/ 7" cement retainer on DP to 10,840' - 120 ft/min. Encountered 10K down drag of 10K @ 8,470' and 8,590'. DPRB PROD1 Attempt to break circ @ 10,840'. Pressure DP to 2,250 psi. DP plugged. Pipe moves free. UP i90K, DN 140K. DPRB PROD1 Wait on orders. Mud wt in pits 8.4 ppg. DPRB PROD1 POOH wet to 7,294'. PROD1 Cut & Slip drilling line. Adjust brakes. DPRB PROD1 POOH wet with 7" retainer to 5,241'. DPRB PROD1 POOH from 5241' wet with 7" cement retainer. Retainer and Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Operations Sumrnary Report Page 6 of 15 Legal Well Name: Y-11 Common Well Name: Y-11 Spud Date: 10/24/1980 Event Name: REENTER+COMPLETE Start: 11/14/2005 End: 12/25/2005 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 12/25/2005 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 11/29/2005 00:00 - 05:00 5.00 DRILL N DPRB PROD1 bottom 2 joints of drill pipe plugged with cuttings. Clean out same and L/D retainer. Clear & clean rig floor. 05:00 - 06:00 1.00 DRILL P PRODi P/U clean out assy. Roller cone bit, 7" csg scraper, bit sub, float sub, 9 HWDP, Jars, 3 HWDP, XO, length = 411.56 06:00 - 12:00 6.00 DRILL P PROD1 RIH w/clean out assy, fill pipe and break circ every 2000' in 9 12:00 - 15:00 I 3.001 DRILL I P I I PROD1 15:00 - 19:00 4.001 DRILL P PROD1 19:00 - 22:30 3.50 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 11/30/2005 00:00 - 03:00 3.00 DRILL P PROD1 03:00 - 06:00 3.00 DRILL P PROD1 06:00 - 13:30 7.50 DRILL N RREP PRODi 13:30 - 14:30 1.00 DRILL N PROD1 14:30 - 15:00 0.50 DRILL N PROD1 15:00 - 17:00 2.00 DRILL N PROD1 17:00 - 20:30 3.50 DRILL N PROD1 20:30 - 00:00 I 3.501 DRILL I N I I PRODi 12/1/2005 100:00 - 01:00 I 1.001 DRILL I P I I PROD1 01:00 - 05:00 4.00 DRILL N DFAL PROD1 05:00 - 07:30 2.50 DRILL N DFAL PROD1 07:30 - 11:00 3.50 DRILL N DFAL PROD1 11:00 - 15:30 4.50 DRILL N DFAL PROD1 15:30 - 20:00 4.50 DRILL P PROD1 20:00 - 00:00 4.001 DRILL P PROD1 5/8" casing. Fill pipe and break circ every 1000' in 7" casing. RIH to 9931'. Install top drive blower hose. Ream from 9931' to 10900'. UWT = 170K, DWT = 145K, RWT = 155K. Pump @ 550 gpm @ 2200 psi. Torque = 5500 @ 80 rpm. Heavy sand returns on shakers. Pump 50 bbl high vis sweep weighted to 9.5 ppg. Condition mud with black products. Rotate and reciprocate. Pump 550 gpm @ 2300 psi. Rotating @ 80 rpm. Mud weight in and out = 8.5 PPg• Pump dry job. POH from 10900' to 411'. Stand back 5 HWDP and jars. L/D BHA. Clear and clean rig floor. M/U bit, mud motor and MW D to 362', upload, pulse check @ 250 gpm @ 720 psi. P/U drill pipe from pipe shed. RIH, fill pipe and test MWD @ 3000' intervals. RIH to 3291'. Repair Elmago spline engagement split ring assy and stop dogs. Clear and clean area. RIH from 3291' to 5996', fill pipe. Flow test MWD :unable to pump up surveys or tool faces. RIH, from 5996' to 10759'. fill pipe at 3000' intervals. Remove air slips. Install top drive blower hose. Wash from 10759' to 10900'. Pump @ 325 gpm @ 1950 psi. Torque = 5500 @ 40 rpm. UWT = 190K, DWT = 145K, RWT = 165K. Wash and ream from 7" shoe @ 10900' to 10902' inches at a time. Hole packing off. Wash and ream to 10920 in 2' increments. Hole packed off, Jar pipe free with 300K. Pull into casing, wash and ream down to 10930, started taking weight. Pull into casing. With pumps off attemped to work pipe down into old hole. Taking weight past 10925'. Orient and work pipe, hole in good shape. Unable to get into old hole without MWD working. Pull into casing. CBU and mix dry job. CBU @ 325 gpm @ 1950 psi. Flow check well. Drop dart and shear pump out sub. Pump dry job. Mud weight in & out = 8.9 PPg• POH from 10900' to BHA @ 362'. BHA : L/D jars, down load MWD tool. L/D MWD & mud motor. Clear and clean rig floor. M/U bit, mud motor, float sub, stb, new jars &MWD. Change orfice in HM-HOC. Upload MWD. RIH with BHA to 462' & pulse check. RIH fill pipe and break circ @ 3000' intervals. RIH to 10764'. Wash and ream from 10764' to 10925'. Hole in good shape. No problem @ shoe. Wash and ream from 10925' to 11507'. Pump @ 325 gpm @ 2000 psi. Drill from 11507' to 11634'. UWT = 205K, DWT = 135K, RWT = 165K. Torque = 10K off bottom, 11 K on @ 70 rpm. WOB = 7K. Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Operations Summary Report Page 7 of 15 Legal Well Name: Y-11 Common Well Name: Y-11 Spud Date: 10/24/1980 Event Name: REENTER+COMPLETE Start: 11/14/2005 End: 12/25/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2005 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours ~ Task ~ Code' NPT ~! Phase 12/1/2005 120:00 - 00:00 ~ 4.00 DRILL ~ P PRODi 12/2/2005 100:00 - 19:30 19.501 DRILL ~ P I PROD1 19:30 - 21:30 2.00 DRILL P PRODi 21:30 - 23:30 2.00 DRILL P PRODi 23:30 - 00:00 0.50 DRILL P PRODi 12/3/2005 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 02:30 I 2.001 DRILL I P I I PROD1 02:30 - 06:00 I 3.501 DRILL I P I I PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 00:00 17.50 DRILL P PROD1 12!412005 ~ 00:00 - 02:30 ~ 2.50 ~ DRILL ~ P ~ ~ PROD1 02:30 - 03:00 0.50 DRILL N DPRB PRODi 03:00 -04:30 1.50 DRILL N DPRB PROD1 04:30 - 06:00 ~ 1.50 ~ DRILL N DPRB PRODi 06:00 - 07:00 1.00 DRILL N DPRB PROD1 07:00 - 10:00 3.00 DRILL N DPRB PROD1 10:00 - 11:00 i.00 DRILL N DPRB PROD1 11:00 - 11:30 0.50 DRILL N DPRB PROD1 11:30 - 14:30 3.00 DRILL N DPRB PROD1 14:30 - 15:30 1.00 DRILL N DPRB PROD1 15:30 - 17:00 1.50 DRILL N DPRB PROD1 17:00 - 18:00 1.00 DRILL N DPRB PROD1 18:00 - 20:30 2.50 DRILL N DPRB PROD1 20:30 - 00:00 I 3.501 DRILL I N I DPRB I PROD1 12/5/2005 00:00 - 02:30 2.50 DRILL N DPRB PROD1 02:30 - 05:30 3.00 DRILL N DPRB PROD1 Description of Operations Pump @340 gpm @ 2320 psi off bottom & 2490 psi on. AST = .55, ART = 1.01 firs. Drill from 11634' to 12533'. UWT = 205K, DWT = 135K, RWT = 165K, Pump @ 344 gpm @ 2540 off bottom, 2640 on. Torque = 8/10K on bottom, 8.5K off @ 80 rpm. WOB = 7/12K. AST = 6.07 hrs. ART = 5.36 hrs. Pump high vis sweep &circ until clean. Rotate & reciprocate. POH from 12533' to 7" casing shoe @ 10900'. Max over pull 40K. Hole in good shape. POH to 8334'. (Will P/U enough drill pipe to TD well) Service top drive. Lube rig & top drive. Function all BOP rams, annular preventor & HCR valves. RIH P/U drill pipe from 8334' to 7" shoe @ 10900'. Monitor well, stable. RIH, tag bridge @ 10932'. Orient high side and attempt to slide tfirough. No success. Ream area from shoe @ 10900' to 10993'. Hole in good shape, not tight. Wash and ream until we can trip through without pumps on. RIH to 10984'. Tag bridge, wash and ream to 11058'. RIH from 11058' to 12533'. Hole in good shape. Drilling from 12533' to 13325'. AST = 10.3 hrs, ART = 10.79 hrs. Torque = 7K off bottom, 8K on @ 80 rpm. Pump @340 gpm @ 2500 psi. UWT = 195K, DWT = 135K, RWT = 160K. Drill from 13325' to 13450'. AST = .07, ART = .87. At 13429' started losing mud. Inital losses = 180 bph while pumping, static = 40 bph, dropping to 140 bph pumping and 35 static. Circ & mix LCM. Monitor losses. POH from 13450' to 7" shoe @ 10900'. Over pull of 30/40K from 13450' to 12550'. Mud weight in and out = 9+ ppg. Mix 140 bbl LCM pill @ 30 ppb. Keep hole full. Monitor well. Slip and cut drill line & adjust brakes. Static loss rate = 36 bph. Total mud lost to well = 492 bbl. Service top drive & tube rig. Static loss rate = 48 bph. Mix 80 ppb LCM pill. Drop dart and open circ sub, spot 95 bbls of 80 ppb LCM pill. Blow down top drive. POH from 10900' to 10122'. annulus over balanced. Mix and pump dry job. Blow down top drive. POH from 10122' to 7260'. Mud weight in and out = 8.7 ppg. Perform MAD pass from 7260' to 7130' @ 200 fph. POH from 7130' to 1991'. POH L/D 51 joints of drill pipe to BHA @ 367'. Rack back HWDP & jars. Flush MWD with water. Down load, pull pulsar, L/D MWD, mud motor & bit. Clear & clean rig floor. P/U insert bit, 1 drill collar, 2 stabilizers, HWDP & jars. RIH to 7517'. RIH with insert bit, 1 drill collar, 2 stbs, jars &HWDP to 7" shoe @ 10900'. Fill pipe @ 3000' intervals. Install top drive blower hose. Loss rate = 10 bph. Wash, ream &RIH from 7" shoe @ 10900' to bottom @ 13450'. Area below shoe in good shape. Tight spots @ 10960', 11150', 12055', 12260', 12340, 12470', 12825;, 12947',13094' Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: Y-11 Common W ell Name: Y-11 Spud Date: 10/24/1980 Event Nam e: REENTE R+COM PLET E Start : 11/14/2005 End: 12/25/2005 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/25/2005 Rig Name: NABOB S 2ES Rig Number: Date From - To ' Hours I Task ~ i Code NPT Phase i t Description of Operations 12/5/2005 02:30 - 05:30 3.00 DRILL N DPRB PROD1 & 13340'. Loss rate = 35 bph. 05:30 - 08:30 3.00 DRILL P PROD1 Drill from 13450' to 13571'. ART = 2.22 hrs. Pump 50 bbl LCM pill @ 80 ppb @ 13571'. UWT = 190K, DWT = 130K, RWT = 160K. Torque off bottom = 9K, on bottom 14K @ 100 rpm. 08:30 - 10:30 2.00 DRILL N DPRB PROD1 CBU @ 13571'. Pump @ 325 gpm @ 1350 psi. Spot 50 bbl LCM pill @ 80 ppb. Monitor well. Mud weight in = 8.7 ppg, Mud weight out = 8.9 ppg. 10:30 - 16:00 5.50 DRILL N DPRB PRODi POH from 13571' to 227'. Had 40 to 60K over pulls @ 12850'. to 12400', 12250' to 12000'. 16:00 - 17:00 1.00 DRILL N DPRB PROD1 BHA : L/D drill collar, stab & subs. Clear & clean rig floor. 17:00 - 19:00 2.00 DRILL N DPRB PROD1 P/U bit, mud motor, MWD & stab. Upload, RIH with BHA to 458'. Pulse check MWD. 19:00 - 22:30 3.50 DRILL N DPRB PROD1 RIH to 10831', fill pipe @ 3000' intervals. 22:30 - 23:00 0.50 DRILL P PROD1 Service top drive. 23:00 - 00:00 1.00 DRILL N DPRB PROD1 RIH past 7" shoe without problem. Tight spot @ 11570', wash to 11768'. Pump @ 300 gpm @ 1680 psi. HWT = 210K, DWT = 135K. Loss rate = 10 bph. 12!612005 00:00 - 01:30 1.50 DRILL N DPRB PROD1 RIH from i 1768' to 13571'. Wash through tight spots @ 11290' & 13050'. Loss rate 10 BPH. 01:30 - 00:00 22.50 DRILL P PRODi Drill from 13571' to 14042". ART = 4.38 hrs, AST = 7.36 hrs.Pump @ 304 gpm @ 2050 psi / 2,175 psi. Torque off bottom = 8.5 K, on 9.5k UWT = 200K, DWT = 125K, RWT = 160K. Loss rate 6 - 15 BPH. Lost 251 bbls last 24 hrs. Total loss 1,394 bbls. ECD = 9.72 ppg. Slow /difficult sliding -pump tube pills. 12/7/2005 00:00 - 00:00 24.00 DRILL P PROD1 Drill from 14,042' - 14,762'. ART= 10.81 hrs, AST = 5.41 hrs. UP 200K, DN 120K, RT 160K. TO on 12.5K, off 9.5K. RPM 95. 304 gpm @ 2,230 / 2,336 psi. Loss rate 20 bph. String in LCM while drilling. ECD = 9.91 ppg. Lost 386 bbls last 24 hrs. Total mud loss 1,780 bbls. 12/8/2005 00:00 - 03:00 3.00 DRILL P PROD1 Drill f/ 14,762' to 14,870'. ART = 2.89 hrs. AST = 0 hrs. UP 205K, DN 115K, RT 160k. TO on 13K, off 11K. 304 gpm @ 2250 psi / 2350 psi. Loss rate 23 BPH drilling. String in LCM - Mix II /Safe carb 250. 03:00 - 05:00 2.00 DRILL P PROD1 Circ btms up 1.5X for bit trip. Spot 45 bbls LCM pill - 20 Ibs/bbl. Loss rate 20 BPH. Inital ECD = 9.91 ppg, Final ECD = 9.90 pP9• 05:00 - 05:30 0.50 DRILL P PROD1 Monitor well. Static loss rate 0 bph. Blow down TD. Mud wt in & of 8.8 ppg. 05:30 - 06:00 0.50 DRILL P PROD1 POOH to 13,600'. 06:00 - 07:00 1.00 DRILL P PROD1 Mad pass log f/ 13,600' to 13,400'. 300 FPH. 07:00 - 08:00 1.00 DRILL P PROD1 POOH f/ 13,400' to 10,900'. 25K overpull f/ 13,100' to 12,700', 30k overpull f/ 11,120' to 10,970'. 08:00 - 08:30 0.50 DRILL P PROD1 Monitor well. Drop dart and open Circ sub. Slug pipe. Blow down topdrive. 08:30 - 12:00 3.50 DRILL P PROD1 POOH with DP. 12:00 - 14:00 2.00 DRILL P PROD1 Pull BHA. Down load. Break bit. L.D. MWD /motor. Loss rate 10 BPH tripping out. 14:00 - 19:00 5.00 BOPSU P PROD1 Pull wear ring set test plug and rig up to test. Test BOP's as per BP policy to 250 psi low and 4,000 psi high. Test witness waived by Jeff Jones w/ AOGGC. Test witnessed by John Rall - WSL, Charlie Henley - toolpusher. All rams were functioned. 19:00 - 20:30 1.50 DRILL P PROD1 MU new bit. PU MWD. Orient. PU LWD's and upload. RIH w/ Printed: 12/27!2005 8:35:18 AM BP EXPLORATION Operations Summary Report Legal Well Name: Y-11 Common Well Name: Y-11 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To j Hours Task Code ~ NPT ~~ 12/8/2005 19:00 - 20:30 1.50 DRILL P 20:30 - 22:00 1.50 DRILL P Start: 11 /14/2005 Rig Release: 12/25/2005 Rig Number: Phase PROD1 PROD1 22:00 - 23:00 1.00 DRILL N HMAN PROD1 23:00 - 23:30 0.50 DRILL N HMAN PROD1 23:30 - 00:00 I 0.501 DRILL I N I HMAN I PROD1 12/9(2005 00:00 - 01:00 1.00 DRILL N HMAN PROD1 01:00 - 02:00 1.00 DRILL N HMAN PROD1 02:00 - 07:00 I 5.00 f DRILL I P I I PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 09:30 0.50 DRILL P PROD1 09:30 - 10:00 0.50 DRILL P PROD1 10:00 - 12:30 2.50 DRILL P PROD1 12:30 - 13:30 I 1.001 DRILL I P I I PROD1 13:30 - 14:00 0.50 DRILL P 14:00 - 16:00 2.00 DRILL P 16:00 - 17:30 1.50 DRILL P 17:30 - 18:30 1.00 DRILL P 18:30 - 22:30 4.00 DRILL P 22:30 - 23:30 1.00 DRILL P 23:30 - 00:00 0.50 DRILL P 12/10!2005 100:00 - 02:00 I 2.001 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 02:00 - 03:00 1.00 DRILL P PROD1 03:00 - 03:30 0.50 DRILL N DFAL PROD1 03:30 - 04:00 0.50 DRILL N DFAL PROD1 04:00 - 08:00 4.00 DRILL N DFAL PRODi 08:00 - 09:30 1.50 DRILL N DFAL PROD1 09:30 - 11:30 I 2.00 DRILL I N I DFAL (PROD1 11:30 - 16:00 4.50 DRILL N DFAL PROD1 16:00 - 17:00 1.00 DRILL P PROD1 17:00 - 18:30 I 1.501 DRILL I N I DFAL I PROD1 Page 9 of 15 Spud Date: 10/24/1980 End: 12/25/2005 Description of Operations BHA to 400' and shallow test. RIH picking up 51 jts 4" DP. Fill pipe. Pressure up to 2,500 psi. Pipe plugged. POOH wet to 555'. RIH to 1,972'. L.D 3 jts 4" DP that had cement fall out when rattled w/ hammer on rig floor. Drop dart and shear circ sub. Circ @ 514 gals - 522 psi to clean out and clear DP. Lost 326 bbs mud last 24 hrs. Total mud losses 2,106 bbls. POOH wet to BHA. L.D. 3 singles. Pull and stand back BHA to TM HOC. Baffle and pulser not plugged. Shallow test MWD - O.K. RIH w/ BHA. RIH w/drilling BHA to 10,479". Fill every 3,000". Loss rate 10 BPH. Cut drilling line. Service top drive. RIH to 7' shoe @ 10,900'. Pump EMI tube pill in csg. RIH to 10,935'. Tight spot. Wash and ream tight hole f/ 10,935' to 10,963'. Packing off. Gas to surface. UP 185k, DN 140k, RT 160k, TO 6-8k. Circ gas out thru choke /mud gas seperator - DP 525 psi @ 30 SPM, CSG 0 psi. Open annular. Observe well. Blow down. Wash and ream tight hole f/ 10,906' to 11,506'. Work tight spots @ 10,900' - 10,906', 10,960' - 10,970', 10,995' - 11,000', 11,210 - 11,491'. Hole packed off @ 11,506'. MW in 8.7 ppg, MW out 8.8 ppg. POOH f/ 11,506'to 10,900'. CBU @ 10,900' - 300 gpm @ 1,770 psi. Wash and ream f/ 10,900'to 11,786'. 300 gpm @ 1,750 psi. Shale over shakers. UP 185K, DN 140K, RT 160k, TO 7k. Loss rate 20 BPH. RIH f/ 11,786' to 13,562'. Fill every 10 stands. Hole packed off @ 13,580' after filling pipe. Wash and ream f/ 13,562' to 13,655'. - 283 gpm @ 1,980 psi. UP 185k DN 135k, RT 160K, TO 8k. Losses last 24 hrs 394 bbls. Total losses to hole 2,500 bbls. Wash and ream tight hole f/ 13,655' to 13,706'. Pump hi vis LCM pill. 290 gpm @ 2,100 psi. Drill string partially plugged. 180 gpm - 3,200 psi. Surge pipe. Unable to clear drill string. POOH f/ 13,706' to 10,852'. No problems. Circ -Surge pipe -attempt to unplug drill string. No success. Drop dart. Open circ sub. Slug DP. Blow down. POOH to unplug BHA. Hole taking 15 BPH mud. POOH w/ BHA. Stator twisted off motor. Break bit and lay down motor.. Down load MWD and change out pulser. PJSM. MU MWD and motor. Change out motor stabilizer sleeve. MU bit, orient, and up load LWD's. MU BHA. RIH to 10,900'. Fill pipe every 3,000'. Loss rate 8 BPH. Lubricate rig. Service top drive. Install blower hose. Fitl pipe. Orient to high side. Wash and ream fl 10,900' to 11,134' 275 gpm @ 1,570 psi. Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 'From - To --~ - 12/10/2005 18:30 - 19:30 19:30 - 22:30 22:30 - 00:00 Y-11 Y-11 REENTER+COMPLETE NABORS ALASKA DRILLING NABORS2ES Hours I' Task Code I NPT II - ~ _' - C 1.00 DRILL ~ DFAL 3.00 DRILL P 1.501 DRILL I P 12/11/2005 ~ 00:00 - 00:00 ~ 24.00 ~ DRILL ~ P 12/12/2005 100:00 - 13:00 I 13.001 DRILL I P 13:00 - 14:30 I 1.501 LCR I N I DPRB 14:30 - 18:00 I 3.501 DRILL I P 18:00 - 20:00 1 2.001 DRILL I P 20:00 - 00:00 4.00 DRILL P 12/13/2005 00:00 - 01:00 1.00 DRILL P 01:00 - 02:00 1.00 DRILL P 02:00 - 02:30 0.50 DRILL P 02:30 - 05:30 3.00 DRILL P 05:30 - 06:30 1.00 DRILL N DPRB 06:30 - 11:30 5.00 DRILL N DPRB 11:30 - 13:30 2.00 DRILL N DPRB 13:30 - 14:30 1.00 DRILL N DPRB 14:30 - 19:00 4.50 DRILL N DPRB 19:00 - 20:00 1.00 DRILL P 20:00 - 00:00 4.00 DRILL N DPRB 12!14/2005 ~ 00:00 - 03:00 ~ 3.00 ~ DRILL ~ N ~ DPRB Page 10 of 15 Spud Date: 10/24/1980 Start: 11 J14f2005 End: 12/25/2005 I Rig Release: 12/25/2005 Rig Number: Phase Description of Operations PROD1 RIH f/ 11,143' to 13,715'. Tagged up w/ 40K C~3 13,715'. PROD1 Wash and ream tight hole f/ 13,655' to 13,749'. RIH to 14,250 - tight. Wash and ream tight hole f/ 14,215' to 14,280' and 14,620' to 14,660'. Wash to bottom. Pump 50 bbls hi vis sweep. Loss rate 25 BPH. String in LCM -safe Garb, micha, mix II. PROD1 Drill f/ 14,870' to 14,896'. AST = 0 hrs, ART = 1.41 hrs. UP 195K, DN 125k, RT 160k, TO off 9K , TQ on 11k, 95 RPM,ECD = 9.91 ppg. Loss rate 25 BPH. Lost 420 bbls last 24 hrs. Cumulative mud loss 2,920 bbls. PROD1 Drill f/ 14,896' to 15,410'. UP 200K, DN 115K, RT 160K, 95 RPM, TQ off 10.5K, TO on 12k, 304 gpm ~ 2180psi off / 2311 psi on. ECD = 9.90 ppg. Loss rate 25 BPH. Lost 748 bbls last 24 hrs. Total mud loss 3,668 bbls. PRODi Drill f/ 15,410' to 15,764'. Loss rate increased Q 15,757'. Lost all returns @ 15,764'. ART = 7.8 hrs, AST = 0.78hrs. UP 200K, DN 115K, RT 160K, TO Off 10K, TO on 13k. 300 gpm @ 2,200 psi 12,360 psi on btm. ECD = 9.89 ppg. Loss rate 25 bbls / hr. PROD1 Circ C~ 15,764'. Mix and pump 50 bbls LCM pill - 20 Ibs/bbl. Loss rate 250 bbls / hr. Slowed to 112 BPH. PROD1 Drill f/ 15,764' to 15,868' TD. ART = 2.05 hrs. Pump 25 bbls hi vis LCM pill. Loss rate 78 BPH. UP 215K, DN 115k, RT 160k, TO off 10K, TO on 12k. ECD = 9.99 ppg. PROD1 Pump sweep around and Circ hole clean. CBU 2X. Pump 50 bbls LCM pillout bit - 20 PPB. Monitor well -static. MW in 8.7 ppg, MW out 8.7+ ppg. PROD1 Wiper trip -POOH wet to 12,436'. Intermtent overpull f/ 13,500' to 12,438' - 30K over string wt. Loss rate 15 BPH. PROD1 POOH f/ 12,436' to 10,850'. Had 40K drag C~? 11,036' & 10,945'. PROD1 Cut drilling line. PROD1 Service crown and top drive. Static loss rate 15 BPH. PROD1 RIH. Tagg up Q 10,946'. Unable to ream past 10,946'. Orient and slide w/ pump past ledge @ 10,946'. Back ream and ream hole from 10,947' to 11,020'. Unable to get by ledge @ 10,946' without orienting and sliding with pumps. Slug DP. PRODi POOH f/ 10,852' to 9,916'. RIH f/ 9,916' to 10,852' -Talk to town. (MW 8.7 ppg in & out). PROD1 POOH to change BHA. LD 8 jts bent DP. STDs # 119, 120,121,123, and 125. PROD1 POOH w/ BHA. Down load LWD's. LD motor & MWD. PROD1 MU Clean out BHA. 6 1/8" hole opener, bit sub, NM Flex DC, stab, 2x flex DC, 3 HWDP, Jars, 2 HWDP, xo. PROD1 RIH to 10,900'. Fill pipe every 3,000'. No mud losses. PROD1 Lubricate rig .Service top drive. PROD1 Wash from 10,900' to 10,946' w/ hole opener. Tagged up at 10,946'. 3 hrs to wash and ream from 10,946' to 10,988' w/ 15k - 25k wt on hole opener. Unable to clean up hole. Unable to get down without reaming. Circ w/full returns. UP 190K, DN 145k, RT 165k, TO off 6k, TO 9k - 300 gpm @ 1,300 psi. Lost 201 bbls mud last 24 hrs. Total losses to well 5,223 bbls. PROD1 Wash and ream w/ hole opener from 10,988' to 11,000'. Hole started taking mud @ 95 BPH and hole opener washing down Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: Y-11 Common W ell Name: Y-11 Spud Date: 10/24/1980 Event Nam e: REENTE R+COM PLET E Start : 1 1 11 4/2005 End: 12!2512005 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/25/2005 Rig Name: NABOB S 2ES Rig Number: Date From - To Hours Task Code NPT I, Phase ' Description of Operations 12/14/2005 00:00 - 03:00 3.00 DRILL N DPRB PROD1 easy. Hole bridged over @ 11,000'. Wash and ream from 11,000' to 11,750'. String in LCM -Loss rate 65 BPH. 282 gpm @ 1,316 psi. UP 200K, DN i25k, RT 160K, TO off 6.5k. 03:00 - 05:00 2.00 DRILL N DPRB PROD1 RIH from 11,750' to 13,650' -stopped @ 13,650' w/ 50K down. 05:00 - 16:00 11.00 DRILL N DPRB PROD1 Break circ. Wash and ream f/ 13,630' to 1,3660'. Hole packing off -pump high vis f LCM pill w/ 50 PPB. Continue reaming fl 13,660' to 15,075'. Tight area f/ 14,870' to 14,900'. Wash f/ 15,075' to 15,636'. Ream f/ 15,764' to 15,783'. Wash f/ 15,783' to 15,868' TD. 6' iill on bottom. 300 gpm @ 2130 psi. RPM 100. UP 200K, DN 115K RT 168K, TO off 10 - 11 K. TO off 8.5K. 16:00 - 20:00 4.00 DRILL N DPRB PROD1 Circ and conditon mud and hole. Pump 50 bbls hi vis /LCM pill around and CBU 2X. Rotate 100 RPM / recipicate. Pump 50 bbls hi vis weep around (bottoms up 3X). 300 gpm @ 2010 psi, TO off 10k, RPM 100, UP 200K, DN 115K, RT 168k.Loss rate 65 BPH. MW in 8.7 ppg. MW out 8.8 ppg. 20:00 - 23:00 3.00 DRILL N DPRB PROD1 Wiper trip -POOH wet f/ 15,868' to 7" shoe @ 10,900'. No problems. 23:00 - 23:30 0.50 DRILL P PROD1 Lubricate rig. Service top drive. Function pipe rams. 23:30 - 00:00 0.50 DRILL N DPRB PROD1 RIH. Tagg up @ 10,946'. Wash and ream from 10,946' to 10,963'. UP 200K, DN 120K, RT 165K, 250 gpm @ 1100 psi, TQ 6 - 9.5 K. Lossing 65 BPH. Lost 1,024 bbls mud last 24 hrs. Cumulative lost mud 6,247 bbls 12/15/2005 00:00 - 02:30 2.50 DRILL N DPRB PROD1 Wash /Ream @ 10,963'. Unable to get hole opener deeper than 10,963'. UP 190k, DN 120k, RT 165k, TO 6.5 - 9.5K, 250 gpm @ 1,100 psi. Loss rate 30 BPH. 02:30 - 04:00 1.50 DRILL N DPRB PROD1 Circ bottoms up 2X @ 487 gpm 2,300 psi to clean up 9 5/8" csg. Loss rate 30 BPH. Observe well. Slug DP. Drop 2 3/8" O.D. rabbit. MW in & out 8.7 ppg. 04:00 - 09:30 5.50 DRILL P PROD1 POOH to run 4.5" production liner. L.D. 23 jts bent joints DP. 09:30 - 12:30 3.00 DRILL P PROD1 POOH laying down 48 jts DP and BHA. Clear and clean rig floor. 12:30 - 13:30 1.00 CASE P RUNPRD PJSM. Rig up handling tools to run 4.5" production liner. 13:30 - 19:00 5.50 CASE P RUNPRD PU float joints. Shoe joint bent 15' above shoe. Clear floats. Ran 120 jts 4.5" 12.6# L80 IBT-M liner. Loss rate 30 BPH. 19:00 - 20:00 1.00 CASE P RUNPRD MU liner hanger and liner top packer. UP 90K, DN 85k. 20:00 - 20:30 0.50 CASE P RUNPRD Circ liner volume 5 BPM @ 300 psi. 20:30 - 23:00 2.50 CASE P RUNPRD RIH w/ 4.5" liner on 4" DP to 10,895'. Fill every 10 stands. 23:00 - 00:00 1.00 CASE P RUNPRD Circ liner & DP volume @ 10,900'. Stage pumps to 6 BPM @ 840 psi. Loss rate 40 BPH. Lost 519 bbls mud last 24 hrs. Cumulative losses 6,766 bbls. 12/16/2005 00:00 - 03:30 3.50 CASE P RUNPRD Wash down f/ 10,900' to 10,962'. Tagged up @ 10,962'. Attempt to work liner by ledge @ 10, 962'. Set 25 - 30k on shoe, turn pipe in 1!4 round increments, shake pipe down and spud, vary pump rate. Unable to get past 10,962'. 03:30 - OS:30 5.00 CASE N DPRB RUNPRD Pulled up to work torque down string. Unable to get past 10,936'. Loss rate 20 BPH. UP i65K, DN 135K, 675 psi @ 4 BPM. 08:30 - 09:00 0.50 CASE N DPRB RUNPRD Monitor well. Static. Slug DP. Blow down top drive. MW in & out 8.7 ppg. 09:00 - 10:00 1.00 CASE N DPRB RUNPRD POOH w/ DP to 8,081'. 10:00 - 11:30 1.50 CASE P RUNPRD Cut drilling line. Adjust brakes & rollers. 11:30 - 12:30 1.00 CASE P RUNPRD Lubricate rig. Service top drive. Change oil & filter in top drive. Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: Y-11 Common Well Name: Y-11 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To Hours ; Task , Code~NPT 12/16/2005 12:30 - 14:00 1.50 CASE N DPRB 14:00 - 15:00 1.00 CASE N DPRB 15:00 - 21:00 6.00 CASE N DPRB 21:00 - 00:00 3.00 CLEAN N DPRB 12/17/2005 00:00 - 06:00 6.00 CLEAN N ,DPRB 06:00 - 17:30 I 11.501 CLEAN I N I DPRB 17:30 - 21:00 I 3.501 CLEAN I N I STUC 21:00 - 00:00 I 3.001 CLEAN I N I STUC 12/18/2005 ~ 00:00 - 04:30 4.50 CLEAN I N i STUC 04:30 - 18:00 13.50 CLEAN I N I STUC Spud Date: 10/24/1980 Start: 1 1 /1 412005 End: 12/25/2005 I Rig Release: 12/25/2005 Rig Number: Phase Description of Operations RUNPRD POOH w/ DP to 4.5" liner top packer /hanger.. RUNPRD PJSM. RU handling tools. Lay down Iliner top packer /hanger. RUNPRD POOH laying down 120 jts 4.5" i2.6# L80 IBTM finer. Bottom of float shoe busted out and left in hole. Clear rig floor. CLEAN M.U. Clean out BHA -orient - 6 1/8" insert bit, 4.75"OD x 1.5 deg motor, float sub, MW D, 3- 4 314" NMFDC's, circ sub, 3jts - 3.5" HWDP, jars, 2jts - 3.5" HWDP, 6 1/8"O.D. roller reamer, 3jts - 3.5" HWDP. Shallow test MWD. Loss rate 20 BPH. Lost 115 bbls mud last 24 hrs. Cumulative mud loss 6,881 bbls. CLEAN RIH w/ Clean out BHA to 10, 900' -Pick up 63 jts 4" DP -fill DP every 3,000'. Loss rate 40 BPH. Install blower hose. Orient to high side. CLEAN Circulate down in OH oriented highside. Passed by trouble spots at 10936' and 10962'. Orient highside. Circ down to 11000' & took weight. PU & work stand. Work minor tight spots at 11000', 10985', 10970', 10930'. RIH from 11000 to 11012' with pump off. Continue washing down each stand and then pick back up and run each stand back down with no pump to 12,126'. Ream with motor (slide) & RIH f/ 12,126' to 14,870' - 260gpm @ 2,000 psi. Hard spot @ 14,870'. Pump 260 gpm @ 2,000 psi and ream down w/ motor (slide) to 14,890' in 5' increments. PU twice to 14,880' and ream with motor back down to 14,890'. PU from 14,890' (215 UP, 130 DN) and pulled up to 65k over. Attempt to go down, Attempt to rotate - no success. Pulled up to -100K over string wt and moved pipe up to 14,843' -then partially packed off - 1400 psi 3 BPM. CLEAN Attempt to work pipe back down with 10 - 12K torque and 70k -80K down. Jars will not trip down. No success. No pipe movement. Bit @ 14,843'. Partially packed off - 1,400 psi Q 3 BPM. Loss rate 120 BPH. Discuss situation with ODE & Baker fishing. CLEAN Work pipe and jar up @ 350K and pull to max 400K w/ 14k torque. Work pipe down w/ 80K and 14k torque to cock jars. No movement. Bit Q 14,843'. Partially packed off - 1,050 psi C~3 2 BPM. Loss rate 57 BPH. Lost 1,106 bbls last 24 hrs. Cumulative mud lost 7,987 bbls. CLEAN Work pipe jar up ~ 350K (135K over string wt) and pull to 400K w/ 14k torque. Work pipe down w/ 80K and 14K torque.Partially packed off - 2 BPM Q 1,050 psi. Loss rate 57 BPH. Contact SWS at 03:00 to come to location to attempt a backoff. Jars were functioning on upstroke -not working on downstroke. CLEAN PJSM. RU Schlumberger E line to run string shot and attempt to back off DP. Run string shot and pump down at 3 bpm from 8000'. Tool stopped at 10890'. Hole angle approx 54 deg and depth is approx 7" shoe depth. PU string weight to 175 klbs and then 200 klbs and got down to 10898. Increase pump to 4 bpm (max recommended by SWS) and try at 225, 250, 275 klbs hookload with no success going down further. Increase hook load to 325 klbs Qars still functioning). Able to pump tool down to 11600'. Pick up to 11300' and try again -got Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Page 13 of 15 Operations Summary Report. Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To Y-11 Y-11 Spud Date: 10/24/1980 REENTER+COMPLETE Start: 11/14/2005 End: 12/25/2005 NABORS ALASKA DRILLING I Rig Release: 12/25!2005 NABORS 2ES Rig Number: Hours I~' Task Code NPT Phase Description of Operations 12/18/2005 04:30 - 18:00 13.50 CLEAN N STUC CLEAN down to 11770' (hole angle 88-90 deg). No further progress with repeated attempts pulling up hole and pumping down again. POH with string shot. 18:00 - 20:30 2.50 CLEAN N STUC CLEAN MU SWS tools - 1.79" Swetech colliding tool to cut 4" DP. 20:30 - 23:30 3.00 CLEAN N STUC CLEAN RIH w/ 1.79" OD DP cutting tool to 14,424' pumping 5 BPM C~3 2,100 psi.(w/ 135K over pull on DP). Tools stopped in DP XO sub ~ 14,414' and pressured up to 3,500 psi. Pulled 5,500 Ibs on W.L. -tool hung up. Slack off to string wt. Attempt to fire cutter several times - no success. Picked up to trip jars and tool came free. Pulled up to 14,365'. Attempt to fire cutter - no success. Tool failure. Static loss rate i6 - 20 BPH. Daily mud loss 806 bbls. Cumulative mud losses 8,793 bbls. 12/19/2005 00:00 - 02:00 2.00 CLEAN N STUC CLEAN POOH w/ wire line tools. Break lubricator. Trouble shoot tools, change out CCL and detenator. Re-arm cutter. MU lubricator. 02:00 - 03:30 1.50 CLEAN N STUC CLEAN RIH w. 1.79" OD DP cutter to 14,325'. Pumped tools down C~ 5 BPM - 2,100 psi. Fired cutter @ 14,305' (wire line measurement) w/ 225K up on DP. No indication on weight indicator DP parted. 03:30 - 04:30 1.00 CLEAN N STUC CLEAN POOH w/ wire line tools. Pull up to 350 K and set slips (pipe not parted). Break lubricator. Cutter fired. LD wire line tools. Left one bow spring off centralizer in DP (2' x 3/8" x 1/8" ). 04:30 - 06:00 1.50 CLEAN N STUC CLEAN RD lubricator, swivel, grease head, and 5" DP. PU 4" HT40 DP. Jar up @ 375K on pipe and work torque down - DP parted and is free. 8K torque, UP 205K, DN 140K, RT 165K. Circ ~ 1,200 psi 250 gpm.Static loss rate 16 - 20 BPH. 06:00 - 08:30 2.50 CLEAN N DPRB CLEAN Pump hi vis sweep around. -finish rigging down SWS. 08:30 - 09:30 1.00 CLEAN N DPRB CLEAN Break and L.D. TIW valve, xo, 5" DP pups. PU two single of 4" HT-40. Slug DP. MW in & out 8.7 ppg. 09:30 - 15:00 5.50 CLEAN N DPRB CLEAN POOH f/ 14,305' to 10,843' wet. No problems. UP 215k. RIH w/ 2 stds and tagged up @ 10,948'. Unable to pass w/ 25k down wt. Wash downf! 10,948' to 11,040'. Shut down pumps. POOH. f/ 11,040' to 10,761'. RIH no pump f/ 10,761' to 11,041'. Pump 1 BPM & RIH f/ 11,040' to 11,415' No obstructions. POOH f/ 11,415' to 10,761. 15:00 - 16:30 1.50 CLEAN N DPRB CLEAN Inspect crown -derrick -Top Drive - drawworks, -brakes. 16:30 - 17:30 1.00 CLEAN P CLEAN Service Top Drive. 17:30 - 18:30 1.00 CLEAN P CLEAN Cut drilling line. MW 8.7 ppg in & out. 18:30 - 00:00 5.50 CLEAN P CLEAN POOH w/ DP to run 4.5" production liner (SLM). Left BHA 429.59') and 3 jts + 18.00' piece (102') 4" 14# HT-40 DP in hole. Top of fish ~ 14,303'. Loss rate 20 BPH. Lost 590 bbls mud last 24 hrs. Cumulative mud loss 9,383 bbls. 12!20/2005 00:00 - 01:00 1.00 CASE N DPRB RUNPRD Clean and clear rig floor. 01:00 - 01:30 0.50 CASE N DPRB RUNPRD PJSM. RU to run 4.5" liner. 01:30 - 08:00 6.50 CASE N DPRB RUNPRD MU 4.5" shoe track and check floats. Ran 83 jts 4.5" 12.6# L80 IBT-M liner. Make up 4.5" liner hanger /packer assy, RIH to 3536' filling pipe every 5 joints. Loss rate 20 BPH. 08:00 - 08:30 0.50 CASE N DPRB RUNPRD Circ liner volume @ 3 bpm C~3 190 psi. 08:30 - 14:30 6.00 CASE N DPRB RUNPRD RIH with liner on drill pipe from 3536' to 10821' C~3 120 fpm. SLM & drop 2" drift on all joints. Fill pipe @ 10 stand intervals. Static losses = 0 since 08:30 hrs. Mud weight in and out = 8.7 PP9~ 14:30 - 16:30 2.00 CASE N DPRB RUNPRD POH from 10821' to 7083'. 16:30 - 18:30 2.00 CASE N DPRB RUNPRD RIH from 7083' to 10822'. Drift &SLM. Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: Y-11 Common W ell Name: Y-11 Spud Date: 10/24/1980 Event Nam e: REENTE R+COM PLET E Start : 11/14/2005 End: 12/25/2005 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/25/2005 Rig Name: NABOB S 2ES Rig Number: Date I From - To ~~ Hours Task ~ Code' NPT I Phase ~ I Description of Operations 12/20/2005 18:30 - 19:30 1.00 CASE N DPRB RUNPRD Circ liner and drill pipe volume, stage pump up to 6 bpm @ 810 psi. 19:30 - 00:00 4.50 CASE P RUNPRD RIH from 10822' to 13447'. Wash and work through tight spots @ 10946', 10970', 11070', 11400'. Mud weight in and out = 8.7 PPg• 12/21/2005. 00:00 - 02:00 2.00 CASE P RUNPRD RIH with 4.5" 12.6# L-80 IBT-M liner on drill pipe. Wash down from 13447' to TOP OF FISH @ 14314' SLM. 02:00 - 03:00 1.00 CEMT P RUNPRD Circ, stage pump up to 6 bpm @ 1300 psi. Make up cement head. Circ & cond. UWT = 205K, DWT = 140K. 03:00 - 05:00 2.00 CEMT P RUNPRD Hold PJSM with drill crew, Veco, Schlumberger cement crew, M.I. and WSL. Batch mix cement. 05:00 - 06:00 1.00 CEMT P RUNPRD Cement 4.5" liner. Pump 5 bbl water, test lines to 4500 psi. Pump 20 bbl of CW100 preflush. Pump 25 bbl of mudpush XL spacer @ 9.5 ppg. Pump 127 bbls (585 sx) class G GasBlok "Expando" cement with LCM @ 15.8 ppg. 06:00 - 06:45 0.75 CEMT P RUNPRD Displace with 55 bbls lithium hypochlorite bleach followed by mud. Slow to 3 bpm & PU liner wiper plug on schedule. Continue displacing and bump liner wiper plug at calc displacement of 161.8 bbls total. Reciprocated 5-10' until 85 bbls in to displacement, then getting sticky -park string. Bump plug and pressure up to 4500 psi to set hanger. Release off hanger & verify same. CIP at 06:30 hrs. Hold 1000 psi on string and pull up to expose setting dogs. Set liner top packer with 35 klbs down weight. 06:45 - 08:30 1.75 CEMT P RUNPRD CBU @ 500 gpm @ 2600 psi until clean. Had +- 50 bbls of cement returned. 08:30 - 16:30 8.00 CEMT P RUNPRD Clean pits, take on seawater. 16:30 - 18:00 1.50 CEMT P RUNPRD Displace well to seawater, pump at 13 bpm @ 2530 psi. Blow down surface equip. 18:00 - 19:00 1.00 CEMT P RUNPRD Service top drive, adjust brakes. 19:00 - 00:00 5.00 CEMT P RUNPRD POH, L/D 2800' of drill pipe while cleaning strung out LCM from mud system. Take on clean seawater. 12/22/2005 00:00 - 01:00 1.00 CEMT P RUNPRD RIH with drill pipe from derrick, 8123' to 10720'. 01:00 - 02:30 1.50 CEMT P RUNPRD Pump 110 gallons of Safe-Surf-O (soap pill) and displace to clean seawater, pump @ 525 gpm @ 2600 psi. 02:30 - 06:00 3.50 CEMT P RUNPRD POH from 10720', L/D liner running tool. Clear & clean rig floor. 06:00 - 08:00 2.00 EVAL P OTHCMP PJSM. R/U SWS, M/U & surface test tools. 08:00 - 13:30 5.50 EVAL P OTHCMP RIH with USIT log. Log from 11000' to 7200'. POH, L/D tools. 13:30 - 14:30 1.00 EVAL P OTHCMP Test 4.5" liner and lap to 4000 psi for 30 min, OK. 14:30 - 20:00 5.50 BOPSU P OTHCMP Pull wear bushing. R/U and test BOPE to 250 psi low and 4000 high. Witness of test waived by AOGCC rep John Crisp. Test witnessed by rig supervisors C.Coyne & J.Henson & Co. reps D. Maskell & J. Willingham. 20:00 - 21:00 1.00 PERFO P OTHCMP PJSM. R/U Schlumberger and pert gun handling equip. 21:00 - 22:00 1.00 PERFO P OTHCMP RIH with 2.5" Powerjet Omega pert guns @ 4 SPF, RIH to 672'. 22:00 - 00:00 2.00 PERFO P OTHCMP Change handling equipment and RIH with pert guns P/U 2 7/8" PAC drill pipe to 2532'. 12/23/2005 00:00 - 01:00 1.00 PERFO P OTHCMP RIH with 2 1/2" 4 spf Power Jet Omega pert guns, P/U 2 7/8" PAC drill pipe from 2532' to 3541'. 01:00 - 05:00 4.00 PERFO P OTHCMP RIH with 4" pipe from derrick to 14200'. 05:00 - 06:00 1.00 PERFO P OTHCMP P/U single of drill pipe and tag 4.5" landing collar @ 14226'. Printed: 12/27/2005 8:35:18 AM BP EXPLORATION Operations Summary Report Lega{ Well Name: Y-11 Common Well Name: Y-11 Event Name: REENTER+COMPLETE Start: 11/14/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/25/2005 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To Hours I Task ~ Code - -t 1 12/23/2005 ~ 05:00 - 06:00 t 1.001 PERFOB~ P 06:00 - 06:30 0.501 PERFOB P 06:30 - 07:30 1.00 PERFOB~ P 07:30 - 08:30 1.00 PERFO P 08:30 - 09:00 0.50 PERFO P 09:00 - 19:00 10.00 PERFO P 19:00 -23:00 4.00 PERFO P 23x00 - 00:00 1.00 PERFO P 12/24/2005 00:00 - 01:00 1.00 BUNCO 01:00 - 02:30 1.50 BUNCO 02:30 - 12:00 9.50 BUNCO 12:00 - 15:00 I 3.00 15:00 - 16:00 l 1.001 RU 16:00 - 18:00 2.00 BOPSUF~ P 18:00 - 21:00 3.00 BOPSU~{P 21:00-00:00 ~ 3.00iWHSURP 12/25/2005 00:00 - 01:30 1.50 WHSUR P 01:30 - 04:00 2.50 WHSUR P 04:00 - 06:30 I 2.501 WHSUR I P 06:30 - 07:00 0.50 WHSUR P 07:00 - 09:00 2.00 WHSUR P NPT ~I Phase 1 Page 15 of 15 Spud Date: 10/24/1980 End: 12/25/2005 Description of Operations OTHCMP Space out bottom shot to 14200'. PJSM. R/U shot detection device and initiate firing sequence. Fire guns, bleed off pressure and open well. Observe shot. Perf intervals = 13550-13570, 13600-13620, 13640-13660, 13890-13910, 13940-13960, 13980-14000, 14040-14060, 1 4090-1 41 1 0, 14140-14160, 14180-14200. Total perfs = 200'. OTHCMP POH from 14200' to 13451'. Monitor well, static loss rate = 13 bph. OTHCMP Service top drive. OTHCMP PJSM. Slip and cut 106' of drill line. Inspect brakes & drawworks. OTHCMP Pump dry job, blow down surface equip. OTHCMP POH LDDP from 13451' to 3541'. Change out handling equip and rig up power tongs. UD 2 7/8" PAC drill pipe from 3541' to 672'. OTHCMP PJSM. Change handling equip, POH UD firing head and shot guns from 672', all guns fired. OTHCMP P/U mule shoe and RIH with 9 stands of drill pipe left in derrick, POH LDDP. RUNCMP M/U test joint & pull wear ring. RUNCMP PJSM. R/U to run 4.5" tubing. RUNCMP Run 4.5" 12.6# L-80 TCII completion. Baker Lock connections below packer. Torque =3850 ft pounds. Use Jet Lube Seal Guard pipe dope. RUNCMP Tag up on no-go C~3 10790'. UD 3 joints of tubing. P/U 4 space out pups and install. Run all pups 1 joint down from surface. Change elevators & M/U landing joint & tubing hanger. Flush well head profile, drain BOP stack. Land hanger & RILDS. Close annular preventor and test metal seal on hanger to 1000 psi, OK. UD landing joint and clear rig floor. RUNCMP Dry rod TWC valve in & test from above to 1000 psi, OK. Install tubing monitoring gauge on tubing annulus. RUNCMP PJSM. N/D BOPE. Clean hanger neck/profile. RUNCMP PJSM. N/U 7 1116" X 5000 psi production tree. R/U DSM lubricator and pull TWC. RUNCMP R/U circ lines and pump 100 bbls of clean seawater followed by 400 bbls of inhibited seawater down annulus @ 3 bpm. RUNCMP Displace well with 400 bbl of clean inhibited seawater. RUNCMP R/U LRHOS. Test lines to 4500 psi. Pump diesel freeze protect to 2200'. Allow diesel to U-tube from annulus to tubing. RUNCMP Drop ball & rod, pressure up on tubing to 4000 psi to set packer. Hold for 30 min, OK. Bleed tubing down to 1000 psi. Pressure up on annulus to 4000 psi to test packer, hold for 30 min, OK. RUNCMP Install BPV. RUNCMP Blow down all circ lines, R/D LRHOS. Remove secondary annulus valve. Secure well. Clean cellar area. Release rig C~ 09:00 hrs. 12(25!2005 Printed: 12/27/2005 8:35:18 AM ;~ Halliburton Global ~:~.. ~ __ ~~ .. ~~ Company: BP Amoco Date:: 1!9/2006 Tim. 14:51 43 Ps~ge: Co-ordinate(NL++') Reference: Well. Y-11. True North Picl~l: Prudhoe Bay Site: PB:YPad Vertical (TVl))Reference: Y-11C:79.9 Well: Y=11 Section (VS) ltef'erc nce: Well (O.OON,O.OOE 1 70.OOAzi) Wellpath: Y-11 C Survey Calculation Method:- Minimum Curvature Db: -0racle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plan e 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 Well: Y-11 Slot Name: Y-11 Well Position: +N/-S 338.18 ft Northing: 5948816.00 ft Latitude: 70 16 3.360 N +E/-W -3238.96 ft Easting : 644504.00 ft Longitude: 148 49 53.268 W Position Uncertainty: 0.00 ft Wellpath: Y-11C Drilled From: Y-11A 95 ft 7492 500292051303 Tie-on Depth: . Current Datum: Y-11G: Height 79.90 ft Above System Datum: Mean Sea Level Magnetic Data: 1 1/18/2005 Declination: 24.65 deg Field Strength: 57597 nT Mag Dip Angle: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28. 50 0.00 0.00 170.00 Survey Program for Definitive Wellpath Date: 1/9/2006 Validated: Yes Version: 5 Actual From To Survey Toolcode Tool Name ft ft 95 95 5292 92 1 : Sperry-Sun BOSS gyro multi (92.95-529B6S~$O~YRO Sperry-Sun BOSS gyro mu ltishot . . 95 7492.95 5392 Y-11A (5392.95-10487.9 5) (1) BOSS-GYRO Sperry-Sun BOSS gyro multishot . 7563.37 15831.01 Y-11C IIFR+SAG (7563. 37-15831.01) MWD+IFR+MS MWD +IFR + Multi Station Survey MD Incl Azim TVD Sys TVD N/S EIW MapN MapE Tool ft deg deg ft ft ft ft ft ft 00 50 0 28 0.00 28.50 -51.40 0.00 0.00 5948816.00 644504.00 TIE LINE . . 68 95 0 92 00 257 92.95 13.05 -0.09 -0.37 5948815.91 644503.63 BOSS-GYRO . . 60 95 0 192 . 245 50 192.94 113.04 -0.44 -1.43 5948815.54 644502.58 BOSS-GYRO . . 57 95 0 292 . 255.89 292.94 213.04 -0.78 -2.39 5948815.18 644501.63 BOSS-GYRO . . 392.95 0.45 248.00 392.93 313.03 -1.04 -3.23 5948814.89 644500.79 BOSS-GYRO 45 95 0 492 251.89 492.93 413.03 -1.31 -3.97 5948814.61 644500.06 BOSS-GYRO . . 63 95 0 592 89 255 592.93 513.03 -1.57 -4.88 5948814.34 644499.15 BOSS-GYRO . . 47 95 0 692 . 251.79 692.92 613.02 -1.83 -5.80 5948814.06 644498.24 BOSS-GYRO . . 35 95 0 792 240.00 792.92 713.02 -2.11 -6.45 5948813.76 644497.59 BOSS-GYRO . . 892.95 0.27 266.10 892.92 813.02 -2.28 -6.95 5948813.59 644497.09 BOSS-GYRO 40 95 0 992 2$8.30 992.92 913.02 -2.19 -7.52 5948813.67 644496.52 BOSS-GYRO . . 22 95 0 1092 279.90 1092.91 1013.01 -2.04 -8.04 5948813.80 644496.00 BOSS-GYRO . . 95 0.30 1192 245.60 1192.91 1113.01 -2.12 -8.47 5948813.72 644495.58 BOSS-GYRO . 37 95 0 1292 254.60 1292.91 1213.01 -2.31 -9.02 5948813.51 644495.03 BOSS-GYRO . . 1392.95 0.27 261.50 1392.91 1313.01 -2.43 -9.56 5948813.38 644494.49 BOSS-GYRO 30 95 0 1492 251.10 1492.91 1413.01 -2.55 -10.04 5948813.25 644494.01 BOSS-GYRO . . 30 95 0 1592 247.39 1592.91 1513.01 -2.74 -10.53 5948813.06 644493.52 BOSS-GYRO . . 30 95 0 1692 248.29 1692.91 1613.01 -2.94 -11.02 5948812.85 644493.04 BOSS-GYRO . . 33 95 0 1792 259.50 1792.90 1713.00 -3.09 -11.54 5948812.69 644492.52 BOSS-GYRO . . 1892.95 0.50 262.00 1892.90 1813.00 -3.20 -12.26 5948812.57 644491.81 BOSS-GYRO 95 0.55 ' 1992 267.10 1992.90 1913.00 -3.28 -13.17 5948812.46 644490.90 BOSS-GYRO . 43 95 0 2092 237.10 2092.89 2012.99 -3.51 -13.96 5948812.22 644490.11 BOSS-GYRO . . 37 95 0 2192 266.39 2192.89 2112.99 -3.74 -14.60 5948811.98 644489.47 BOSS-GYRO . . 23 95 0 2292 272.50 2292.89 2212.99 -3.75 -15.12 5948811.96 644488.95 BOSS-GYRO . . 2392.95 0.17 248.29 2392.89 2312.99 -3.79 -15.46 5948811.91 644488.61 BOSS-GYRO 12 95 0 2492 144.31 2492.89 2412.99 -3.93 -15.54 5948811.77 644488.54 BOSS-GYRO . . 95 0.05 2592 269.39 2592.89 2512.99 -4.02 -15.52 5948811.68 644488.56 BOSS-GYRO . 2692.95 0.18 247.10 2692.89 2612.99 -4.08 -15.71 5948811.62 644488.37 BOSS-GYRO Halliburton Global Company: BP Amoco Date: 1/9/2006 Time: 14 :51:43 page: 2 .Field': Prudhoe Bay 'Co-ord inate(NE)Reference: Well; Y-11, True No rth Site: PB ' Y Pad Vertica l (TVD) Reference: Y-11 C; 79.9 Well; Y-1 1 Section (VS) Reference: Well ( QOON,O.OOE 1 70:OOAzi) Wellpath: Y-1 1C Survey Calculation Method: Minimum Curvature Dh: Oracle: Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft fit ft 2792 95 15 2 205.29 2792.86 2712.96 -5.84 -16.66 5948809.84 644487.46 BOSS-GYRO . 2892.95 . 6.05 180.50 2892.59 2812.69 -12.81 -17.50 5948802.86 644486.75 BOSS-GYRO ~ 2992 95 8 88 198.19 2991.75 2911.85 -25.41 -19.96 5948790.21 644484.53 BOSS-GYRO ~ . 95 3092 . 12.43 203.39 3090.01 3010.11 -42.63 -26.64 5948772.87 644478.18 BOSS-GYRO . 95 3192 14 07 204.19 3187.35 3107.45 -63.60 -35.90 5948751.73 644469.33 BOSS-GYRO . 3292 95 . 10 16 206.10 3283.90 3204.00 -87.14 -46.98 5948727.98 644458.70 BOSS-GYRO . 3392.95 . 18.63 206.29 3379.33 3299.43 -113.92 -60.16 5948700.96 644446.05 BOSS-GYRO 95 3492 20 50 207.00 3473.55 3393.65 -143.84 -75.18 5948670.75 644431.60 BOSS-GYRO . 3592 95 . 23 33 209.19 3566.32 3486.42 -176.74 -92.79 5948637.53 644414.62 BOSS-GYRO . 3692 95 . 92 25 210.00 3657.22 3577.32 -212.96 -113.38 5948600.92 644394.74 BOSS-GYRO . 3792 95 . 62 28 211.00 3746.10 3666.20 -252.42 -136.65 5948561.02 644372.23 BOSS-GYRO . 3892.95 . 32.38 212.69 3832.24 3752.34 -295.50 -163.46 5948517.44 644346.26 BOSS-GYRO 95 3992 78 33 212.89 3916.03 3836.13 -341.38 -193.02 5948471.00 644317.59 BOSS-GYRO . 95 4092 . 97 33 212.60 3999.06 3919.16 -388.27 -223.16 5948423.55 644288.35 BOSS-GYRO . 4192 95 . 87 33 213.00 4082.04 4002.14 -435.17 -253.39 5948376.08 644259.03 BOSS-GYRO . 95 4292 . 98 33 213.60 4165.02 4085.12 -481.82 -284.03 5948328.86 644229.29 BOSS-GYRO . 4392.95 . 34.17 214.29 4247.85 4167.95 -528.30 -315.32 5948281.79 644198.90 BOSS-GYRO 95 4492 50 34 214.79 4330.42 4250.52 -574.76 -347.30 5948234.73 644167.82 BOSS-GYRO . 95 4592 . 34 78 215.69 4412.70 4332.80 -621.18 -380.10 5948187.69 644135.92 BOSS-GYRO . 95 4692 . 42 35 216.19 4494.51 4414.61 -667.73 -413.85 5948140.50 644103.08 BOSS-GYRO . 95 4792 . 35.33 216.79 4576.05 4496.15 -714.27 -448.28 5948093.31 644069.55 BOSS-GYRO . 4892.95 35.55 216.69 4657.52 4577.62 -760.74 -482.96 5948046.19 644035.77 BOSS-GYRO 95 4992 37 35 217.00 4738.98 4659.08 -807.17 -517.75 5947999.10 644001.88 BOSS-GYRO . 95 5092 . 03 35 217.19 4820.69 4740.79 -853.15 -552.52 5947952.47 643968.00 BOSS-GYRO . 95 5192 . 34 63 219.60 4902.78 4822.88 -897.91 -587.98 5947907.04 643933.41 BOSS-GYRO . 5292 95 . 34 42 219.60 4985.17 4905.27 -941.58 -624.10 5947862.69 643898.13 BOSS-GYRO ~ . 5392.95 . 34.27 219.19 5067.73 4987.83 -985.17 -659.91 5947818.42 643863.17 BOSS-GYRO 95 5492 02 34 219.29 5150.49 5070.59 -1028.65 -695.42 5947774.27 643828.51 BOSS-GYRO . 95 5592 . 33.78 218.89 5233.50 5153.60 -1071.93 -730.58 5947730.32 643794.18 BOSS-GYRO . 95 5692 07 33 223.19 5316.97 5237.07 -1113.47 -766.72 5947688.10 643758.86 BOSS-GYRO . 5742 95 . 97 31 228.69 5359.14 5279.24 -1132.16 -786.00 5947669.05 643739.94 BOSS-GYRO . 5792.95 . 32.22 233.69 5401.50 5321.60 -1148.79 -806.69 5947652.02 643719.57 BOSS-GYRO 95 5842 02 33 234.50 5443.62 5363.72 -1164.60 -828.52 5947635.80 643698.05 BOSS-GYRO . 5892 95 . 33 32 234.79 5485.47 5405.57 -1180.43 -850.83 5947619.55 643676.05 BOSS-GYRO . 95 5992 . 15 34 234.50 5568.63 5488.73 -1212.56 -896.13 5947586.55 643631.38 BOSS-GYRO . 95 6092 . 34 53 234.29 5651.20 5571.30 -1245.41 -941.99 5947552.84 643586.16 BOSS-GYRO . 6192.95 . 35.15 234.10 5733.27 5653.37 -1278.83 -988.32 5947518.53 643540.48 BOSS-GYRO i 95 6292 90 35 234.10 5814.66 5734.76 -1312.90 -1035.39 5947483.57 643494.08 BOSS-GYRO ~ . 6392 95 . 03 36 234.10 5895.60 5815.70 -1347.34 -1082.96 5947448.23 643447.18 BOSS-GYRO . 6492 95 . 13 36 233.29 5976.42 5896.52 -1382.20 -1130.42 5947412.46 643400.41 BOSS-GYRO . 95 6592 . 97 35 232.79 6057.27 5977.37 -1417.59 -1177.44 5947376.18 643354.07 BOSS-GYRO . 6692.95 . 35.62 232.19 6138.38 6058.48 -1453.20 -1223.84 5947339.69 643308.37 BOSS-GYRO 6792 95 08 35 231.50 6219.94 6140.04 -1488.94 -1269.34 5947303.08 643263.58 BOSS-GYRO . 95 6892 . 34 95 231.19 6301.84 6221.94 -1524.78 -1314.14 5947266.39 643219.47 BOSS-GYRO . 95 6992 . 33 80 231.10 6384.38 6304.48 -1560.20 -1358.11 5947230.14 643176.19 BOSS-GYRO . 95 7092 . 32.85 231.19 6467.93 6388.03 -1594.67 -1400.89 5947194.86 643134.08 BOSS-GYRO . 7192.95 32.25 230.79 6552.23 6472.33 -1628.53 -1442.70 5947160.20 643092.93 BOSS-GYRO 95 7292 31 53 230.60 6637.13 6557.23 -1662.00 -1483.58 5947125.96 643052.71 BOSS-GYRO . 7392 95 . 30 95 230.10 6722.63 6642.73 -1695.09 -1523.51 5947092.11 643013.42 BOSS-GYRO . 7492 95 . 15 30 229.89 6808.75 6728.85 -1727.76 -1562.45 5947058.70 642975.12 BOSS-GYRO . 37 7563 . 34 69 231.69 6868.18 6788.28 -1751.59 -1591.71 5947034.31 642946.32 MWD+IFR+MS . 7655.51 . 39.51 233.41 6941.65 6861.75 -1785.34 -1635.85 5946999.73 642902.85 MWD+IFR+MS Halliburton Global Company:. BP Amoco Date:. 1/9/2006' Time: 1.4 :51:43 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Wells Y-11, True No rth Site: PB Y Pad Vertica l (TVD) Reference: Y-11G: 79.9 Well: Y<1 1 Section (VS) Reference: Welt (O.OON;O.OOE,1 70.OOAzi) Wellpath: Y-1 1C Survey Calculation Method:. Minimum Curvature Db; Oracle. Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool- ft deg deg ft ft ft ft ft ft -~ 18 7751 43.14 231.80 7013.48 6933.58 -1823.72 -1686.01 5946960.39 642853.44 MWD+IFR+MS . 54 7845 45.63 231.38 7080.91 7001.01 -1864.73 -1737.72 5946918.40 642802.53 MWD+IFR+MS . 02 7939 49.08 234.12 7144.24 7064.34 -1906.30 -1792.46 5946875.79 642748.60 MWD+IFR+MS . 57 8032 52.43 233.56 7203.42 7123.52 -1949.05 -1850.94 5946831.93 642690.95 MWD+IFR+MS . 8125.79 54.10 234.28 7259.17 7179.27 -1993.04 -1911.32 5946786.80 642631.44 MWD+IFR+MS 44 8220 53.92 233.71 7314.79 7234.89 -2038.06 -1973.27 5946740.60 642570.36 MWD+IFR+MS . 63 8313 54.83 235.99 7369.08 7289.18 -2081.65 -2035.20 5946695.82 642509.28 MWD+IFR+MS . 58 8406 73 54 236.11 7422.68 7342.78 -2124.06 -2098.19 5946652.22 642447.12 MWD+IFR+MS . 70 8500 . 34 54 235.35 7477.29 7397.39 -2167.22 -2161.54 5946607.85 642384.62 MWD+IFR+MS . 8593.30 . 54.26 235.48 7531.33 7451.43 -2209.91 -2223.45 5946563.99 642323.54 MWD+IFR+MS 40 8682 54 82 236.97 7583.02 7503.12 -2250.25 -2283.78 5946522.50 642264.01 MWD+IFR+MS . 8781 02 . 00 55 237.93 7639.71 7559.81 -2293.67 -2351.80 5946477,79 642196.84 MWD+IFR+MS . 01 8874 . 55.20 235.25 7692.92 7613.02 -2335.66 -2415.45 5946434.59 642134.01 MWD+IFR+MS . 82 8966 54.47 232.65 7746.38 7666.48 -2380.29 -2476.79 5946388.78 642073.55 MWD+IFR+MS . 9059.52 53.80 231.98 7800.69 7720.79 -2426.22 -2536.24 5946341.73 642014.99 MWD+IFR+MS 9152 70 83 53 232.03 7855.70 7775.80 -2472.51 -2595.51 5946294.31 641956.63 MWD+IFR+MS . 9246 39 . 53.97 231.97 7910.91 7831.01 -2519.12 -2655.16 5946246.57 641897.89 MWD+IFR+MS . 24 9337 53.97 234.80 7964.35 7884.45 -2562.93 -2714.12 5946201.64 641839.78 MWD+IFR+MS . 61 9431 53.94 234.72 8019.88 7939.98 -2606.96 -2776.44 5946156.43 641778.32 MWD+IFR+MS . 9523.54 54.05 234.43 8073.92 7994.02 -2650.07 -2837.04 5946112.17 641.718.56 MWD+IFR+MS 16 9617 53.43 235.75 8129.30 8049.40 -2693.27 -2898.94 5946067.79 641657.51 MWD+IFR+MS . 9710 20 36 53 236.01 8184.78 8104.88 -2735.16 -2960.78 5946024.72 641596.50 MWD+IFR+MS . 78 9803 . 53 01 235.92 8240.85 8160.95 -2777.09 -3022.86 5945981.60 641535.23 MWD+IFR+MS . 86 9896 . 79 52 235.49 8297.00 8217.10 -2818.92 -3084.19 5945938.61 641474.72 MWD+IFR+MS . 9991.44 . 53.90 236.20 8353.46 8273.56 -2861.52 -3146.98 5945894.82 641412.76 MWD+IFR+MS 83 10082 91 53 235.94 8407.30 8327.40 -2902.74 -3208.26 5945852.43 641352.30 MWD+IFR+MS . 20 10177 . 99 53 235.89 8462.84 8382.94 -2945.50 -3271.45 5945808.47 641289.95 MWD+IFR+MS . 88 10270 . 91 53 235.93 8517.97 8438.07 -2987.95 -3334.17 5945764.83 641228.05 MWD+IFR+MS . 10364 43 . 53.59 235.71 8573.29 8493.39 -3030.33 -3396.58 5945721.26 641166.47 MWD+IFR+MS . 10457.77 53.98 234.49 8628.43 8548.53 -3073.42 -3458.34 5945677.00 641105.55 MWD+IFR+MS 87 10551 53.85 234.47 8683.86 8603.96 -3117.60 -3520.24 5945631.64 641044.52 MWD+IFR+MS . 47 10643 54.46 235.03 8737.50 8657.60 -3160.46 -3580.88 5945587.63 640984.72 MWD+IFR+MS . 10736 52 28 54 235.15 8791.70 8711.80 -3203.74 -3642.90 5945543.17 640923.55 MWD+IFR+MS . 37 10829 . 54.28 235.10 8845.91 8766.01 -3246.84 -3704.74 5945498.89 640862.55 MWD+IFR+MS . 10914.62 54.12 235.05 8895.78 8815.88 -3286.43 -3761.43 5945458.23 640806.63 MWD+IFR+MS 10946 19 55.55 234.29 8913.96 8834.06 -3301.35 -3782.49 5945442.90 640785.87 MWD+IFR+MS . 10976 58 58.44 233.85 8930.51 8850.61 -3316.31 -3803.12 5945427.56 640765.53 MWD+IFR+MS . 11008.28 61.10 233.72 8946.47 8866.57 -3332.49 -3825.21 5945410.96 640743.75 MWD+IFR+MS 05 11038 63.79 234.13 8960.24 8880.34 -3348.03 -3846.55 5945395.01 640722.72 MWD+IFR+MS . 11068.14 66.79 233.37 8972.82 8892.92 -3364.19 -3868.59 5945378.43 640701.00 MWD+IFR+MS 24 11101 70.64 233.61 8984.83 8904.93 -3382.53 -3893.37 5945359.61 640676.57 MWD+IFR+MS . 65 11131 73.75 234.15 8994.13 8914.23 -3399.60 -3916.76 5945342.10 640653.52 MWD+IFR+MS . 71 11162 76.87 235.14 9002.01 8922.11 -3416.98 -3941.26 5945324.26 640629.36 MWD+IFR+MS . 04 11193 79.64 235.67 9008.18 8928.28 -3433.84 -3965.70 5945306.93 640605.25 MWD+IFR+MS . 11224.51 81.58 235.56 9013.31 8933.41 -3451.37 -3991.32 5945288.91 640579.97 MWD+IFR+MS I 11255.26 82.76 236.30 9017.50 8937.60 -3468.44 -4016.56 5945271.37 640555.07 MWD+IFR+MS i 51 11285 18 85 235.73 9020.68 8940.78 -3485.25 -4041.50 5945254.08 640530.46 MWD+IFR+MS . 11318 60 . 86.85 236.04 9022.98 8943.08 -3503.76 -4068.83 5945235.05 640503.49 MWD+IFR+MS ' . ~ 07 11349 87.16 236.08 9024.57 8944.67 -3520.75 -4094.07 5945217.58 640478.58 MWD+IFR+MS . 11379.43 87.29 236.11 9026.04 8946.14 -3537.67 -4119.24 5945200.18 640453.74 MWD+IFR+MS 11413 88 88.02 237.16 9027.45 8947.55 -3556.60 -4147.99 5945180.71 640425.36 MWD+IFR+MS . 71 11443 83 88 237.28 9028.27 8948.37 -3572.74 -4173.06 5945164.09 640400.61 MWD+IFR+MS . ~ 11475.83 . 89.26 237.19 9028.81 8948.91 -3590.12 -4200.06 5945146.19 640373.95 MWD+iFR+MS ~. - -- -- Halliburton Global Company: BP Amoco Dater 1/9/2006 Time: 14 :51:43 Page: 4 Field• Pru dhoe Bay Co-ordinate(NE) Reference: WeIF Y-11, True No rth Site: PB Y Pad Vertica l (TVD) References Y-110:: 79.9 Well: Y-1 1 Section (VSJReference: Well (O.OON,O.OOE,170;OOAzi)- Wellpath• Y-1 10 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool. 1 ft deg deg ft ft ft ft ft ft 36 11504 51 89 236.96 9029.11 8949.21 -3605.63 -4224.01 5945130.23 640350.30 MWD+IFR+MS . 11535.60 . 89.61 237.89 9029.35 8949.45 -3622.45 -4250.33 5945112.91 640324.31 MWD+IFR+MS 65 11564 89 58 237.09 9029.56 8949.66 -3638.06 -4274.83 5945096.83 640300.12 MWD+IFR+MS . 98 11597 . 88.63 234.63 9030.08 8950.18 -3656.76 -4302.41 5945077.60 640272.90 MWD+IFR+MS . 56 11627 53 87 233.18 9031.07 8951.17 -3674.18 -4326.30 5945059.73 640249.36 MWD+IFR+MS . 11658 16 . 27 87 230.70 9032.46 8952.56 -3693.02 -4350.36 5945040.43 640225.66 MWD+IFR+MS . 11689.89 . 88.70 228.64 9033.57 8953.67 -3713.54 -4374.54 5945019.45 640201.89 MWD+fFR+MS 37 11720 69 89 226.82 9034.00 8954.10 -3734.04 -4397.09 5944998.53 640179.73 MWD+IFR+MS . 16 11750 . 90 37 224.05 9033.99 8954.09 -3754.94 -4418.31 5944977.22 640158.92 MWD+IFR+MS . 95 11781 . 26 89 221.25 9034.09 8954.19 -3778.32 -4439.84 5944953.44 640137.84 MWD+IFR+MS . 48 11810 . 04 87 220.34 9035.01 8955.11 -3799.91 -4458.47 5944931.50 640119.63 MWD+IFR+MS . 11841.62 . 86.78 219.09 9036.69 8956.79 -3823.83 -4478.34 5944907.21 640100.22 MWD+IFR+MS 51 11873 89 86 217 93 9038.45 8958.55 -3848.74 -4498.17 5944881.92 640080.88 MWD+IFR+MS . 57 11906 . 87 28 . 215 13 9040.13 8960.23 -3875.27 -4517.82 5944855.02 640061.74 MWD+IFR+MS . 49 11935 . 87 96 . 212.78 9041.33 8961.43 -3899.24 -4533.96 5944830.75 640046.07 MWD+fFR+MS . 12 11967 . 96 87 210.02 9042.46 8962.56 -3926.21 -4550.42 5944803.46 640030.13 MWD+IFR+MS . 12000.17 . 88.43 207.42 9043.50 8963.60 -3955.18 -4566.30 5944774.20 640014.81 MWD+IFR+MS 47 12027 88 70 205.33 9044.18 8964.28 -3979.63 -4578.42 5944749.52 640003.16 MWD+IFR+MS . 64 12060 . 88 38 202.77 9045.03 8965.13 -4009.91 -4591.93 5944718.99 639990.24 MWD+IFR+MS . 13 12091 . 38 88 201 03 9045.89 8965.99 -4038.19 -4603.30 5944690.50 639979.41 MWD+IFR+MS . 98 12120 . 87.83 . 198.77 9046.88 8966.98 -4066.24 -4613.45 5944662.27 639969.80 MWD+IFR+MS . 12153.16 87.83 195.35 9048.10 8968.20 -4096.97 -4622.89 5944631.36 639960.96 MWD+IFR+MS 49 12181 17 86 13 193 9049.58 8969.68 -4124.39 -4629.85 5944603.81 639954.53 MWD+IFR+MS . 72 12212 . 86 23 . 189.77 9051.65 8971.75 -4154.93 -4636.03 5944573.16 639948.93 MWD+IFR+MS . 80 12244 . 53 86 186.34 9053.68 8973.78 -4186.63 -4640.52 5944541.39 639945.06 MWD+IFR+MS . 75 12276 . 03 87 180.03 9055.47 8975.57 -4218.46 -4642.29 5944509.53 639943.90 MWD+IFR+MS . 12306.55 . 88.14 176.04 9056.73 8976.83 -4248.21 -4641.27 5944479.81 639945.49 MWD+IFR+MS 70 12338 07 89 173.63 9057.51 8977.61 -4280.22 -4638.37 5944447.86 639949.00 MWD+IFR+MS . 69 12369 . 90.29 169.36 9057.68 8977.78 -4310.86 -4633.79 5944417.32 639954.17 MWD+IFR+MS . 77 12399 72 90 168.95 9057.42 8977.52 -4340.40 -4628.13 5944387.89 639960.39 MWD+IFR+MS . 85 12430 . 72 90 168.44 9057.03 8977.13 -4370.87 -4622.04 5944357.54 639967.07 MWD+IFR+MS . 12462.30 . 87.96 168.17 9057.39 8977.49 -4401.67 -4615.66 5944326.88 639974.03 MWD+IFR+MS 91 12493 01 88 168.32 9058.50 8978.60 -4432.59 -4609.23 5944296.09 639981.06 MWD+IFR+MS . 37 12513 . 88.26 168.06 9059.14 8979.24 -4451.63 -4605.25 5944277.13 639985.40 MWD+IFR+MS . 62 12544 87.95 165.99 9060.17 8980.27 -4482.06 -4598.24 5944246.84 639993.00 MWD+IFR+MS . 12575 87 87 39 163.57 9061.44 8981.54 -4512.19 -4590.04 5944216.88 640001.77 MWD+IFR+MS . 12606.61 . 87.08 160.95 9062.92 8983.02 -4541.43 -4580.68 5944187.82 640011.68 MWD+IFR+MS 1 49 12638 52 87 157.69 9064.42 8984.52 -4571.22 -4569.44 5944158.26 640023.50 MWD+IFR+MS . 64 12669 . 87 88 155.94 9065.68 8985.78 -4599.83 -4557.19 5944129.89 640036.30 MWD+IFR+MS . 40 12700 . 37 89 154.58 9066.41 8986.51 -4627.76 -4544.32 5944102.22 640049.70 MWD+IFR+MS . 12732 12 . 90 23 153.21 9066.52 8986.62 -4656.24 -4530.36 5944074.01 640064.20 MWD+IFR+MS . 12761.74 . 90.55 151.22 9066.32 8986.42 -4682.45 -4516.55 5944048.08 640078.50 MWD+IFR+MS 26 12793 90 42 148.42 9066.06 8986.16 -4709.69 -4500.71 5944021.15 640094.86 MWD+IFR+MS . 47 12824 . 50 89 146.39 9066.08 8986.18 -4735.98 -4483.90 5943995.18 640112.18 MWD+IFR+MS . 75 12855 . 89.19 144.12 9066.43 8986.53 -4761.68 -4466.07 5943969.83 640130.49 MWD+IFR+MS . 71 12886 89.49 141.40 9066.79 8986.89 -4786.32 -4447.34 5943945.55 640149.69 MWD+IFR+MS . 12918.20 90.11 139.08 9066.90 8987.00 -4810.53 -4427.20 5943921.74 640170.29 MWD+IFR+MS 28 12949 91.60 136.66 9066.44 8986.54 -4833.57 -4406.36 5943899.10 640191.57 MWD+IFR+MS . 12980 05 92 39 134.60 9065.37 8985.47 -4855.56 -4384.86 5943877.54 640213.49 MWD+IFR+MS . 28 13009 . 92.95 131.81 9064.00 8984.10 -4875.54 -4363.58 5943857.97 640235.15 MWD+IFR+MS . 64 13042 93.08 131.32 9062.25 8982.35 -4897.65 -4338.65 5943836.35 640260.49 MWD+IFR+MS . 13072.69 93.20 131.52 9060.60 8980.70 -4917.50 -4316.15 5943816.94 - 640283.37 - MWD+IFR+MSi L- _ _ - Halliburton Global Company: BP Amoco Field: Prudhoe Bay Date: Co-ord 1/9/2006 inate(NE) Ref Time: 14 erence: WeIL 151:43 Y-11, True No Page: 5 rth PB Site: Y Pad Vertical (TVD) Reference: Y-11 C: 79.9 .. Well: Y-1 1 Section (VS)Referen ce: Well (O.OON,O:OOE,1 70;OOAzi) Wellpath: Y-1 1 C Survey Calculation Method: Minimum Curvature Db: Oracle Survey r MD Incl Azim TVD Sys TVD N/S E/VV MapN MapE Tool ~ ft deg deg ft ft ft ft ft ft ~ 10 13105 31 94 131.22 9058.48 8978.58 -4938.87 -4291.88 5943796.03 640308.04 MWD+IFR+MS ~ . 53 13135 . 94.44 128.38 9056.16 8976.26 -4958.29 -4268.57 5943777.07 640331.72 MWD+IFR+MS . 13167 15 93 57 126.83 9053.95 8974.05 -4977.54 -4243.58 5943758.30 640357.07 MWD+IFR+MS . 17 13199 . 44 93 127.18 9051.99 8972.09 -4996.77 -4218.06 5943739.56 640382.95 MWD+IFR+MS . 13229.61 . 93.39 126.24 9050.18 8970.28 -5014.94 -4193.70 5943721.87 640407.65 MWD+IFR+MS 45 13261 51 93 125.69 9048.26 8968.36 -5033.60 -4167.98 5943703.70 640433.73 MWD+IFR+MS . 12 13294 . 93 63 126.22 9046.23 8966.33 -5052.75 -4141.58 5943685.07 640460.48 MWD+IFR+MS . 52 13324 . 93 69 123.87 9044.29 8964.39 -5070.17 -4116.75 5943668.13 640485.65 MWD+IFR+MS . 11 13355 . 64 93 123.83 9042.33 8962.43 -5087.17 -4091.40 5943651.62 640511.32 MWD+IFR+MS . 13387.23 . 93.88 123.31 9040.23 8960.33 -5104.89 -4064.69 5943634.41 640538.36 MWD+IFR+MS 05 13432 93 52 124.45 9037.33 8957.43 -5129.83 -4027.56 5943610.20 640575.96 MWD+IFR+MS . 90 13476 . 94 61 124.55 9034.16. 8954.26 -5155.17 -3990.69 5943585.58 640613.30 MWD+IFR+MS . 13521 90 . 96.48 124.88 9029.81 8949.91 -5180.67 -3953.87 5943560.78 640650.60 MWD+IFR+MS . 03 13566 15 98 124.46 9024.19 8944.29 -5205.57 -3917.88 5943536.58 640687.07 MWD+IFR+MS . 13593.74 . 95.62 123.86 9020.87 8940.97 -5221.01 -3895.12 5943521.58 640710.12 MWD+IFR+MS 19 13624 76 93 120.05 9018.38 8938.48 -5237.07 -3869.37 5943506.02 640736.16 MWD+IFR+MS . 67 13656 . 92 55 118.85 9016.59 8936.69 -5253.02 -3841.13 5943490.62 640764.70 MWD+IFR+MS . 13686 05 . 43 90 117.73 9015.83 8935.93 -5266.93 -3815.27 5943477.20 640790.82 MWD+IFR+MS . 13718 28 . 88 64 118.25 9016.09 8936.19 -5282.06 -3786.81 5943462.63 640819.56 MWD+IFR+MS . 13750.45 . 87.47 116.97 9017.18 8937.28 -5296.96 -3758.32 5943448.28 640848.33 MWD+IFR+MS 13780 26 87.70 117.98 9018.43 8938.53 -5310.70 -3731.90 5943435.05 640875.01 MWD+fFR+MS . 13811 34 77 88 119.64 9019.39 8939.49 -5325.67 -3704.68 5943420.61 640902.51 MWD+IFR+MS . 10 13842 . 05 90 121.10 9019.71 8939.81 -5341.22 -3678.15 5943405.57 640929.34 MWD+IFR+MS . 07 13873 . 04 90 121.53 9019.68 8939.78 -5357.32 -3651.69 5943389.98 640956.10 MWD+IFR+MS . 13905.75 . 88.27 120.83 9020.17 8940.27 -5374.23 -3623.73 5943373.61 640984.37 MWD+IFR+MS 13935 06 44 86 120.75 9021.52 8941.62 -5389.22 -3598.58 5943359.11 641009.80 MWD+IFR+MS . 13966 70 . 85 79 119.16 9023.66 8943.76 -5404.98 -3571.23 5943343.88 641037.45 MWD+IFR+MS . 23 13998 . 42 85 116.92 9026.08 8946.18 -5419.76 -3543.49 5943329.63 641065.47 MWD+IFR+MS . 31 14030 . 11 86 116.58 9028.45 8948.55 -5434.16 -3514.92 5943315.79 641094.31 MWD+IFR+MS . 14060.35 . 86.78 115.28 9030.31 8950.41 -5447.27 -3487.96 5943303.20 641121.51 MWD+IFR+MS 14092 00 57 34 114.39 9031.93 8952.03 -5460.54 -3459.27 5943290.48 641150.45 MWD+IFR+MS . 14123 59 . 40 87 113.14 9033.38 8953.48 -5473.26 -3430.39 5943278.32 641179.56 MWD+IFR+MS . 14153 12 . 86.95 112.24 9034.84 8954.94 -5484.64 -3403.18 5943267.47 641206.99 MWD+IFR+MS . 14186 65 70 85 112.76 9036.99 8957.09 -5497.44 -3372.27 5943255.26 641238.14 MWD+IFR+MS . 14217.56 . 85.91 112.15 9039.25 8959.35 -5509.22 -3343.78 5943244.03 641266.85 MWD+IFR+MS 90 14247 85.42 111.15 9041.54 8961.64 -5520.38 -3315.66 5943233.41 641295.17 MWD+IFR+MS . 81 14279 85.74 111.75 9044.00 8964.10 -5532.01 -3286.05 5943222.35 641325.00 MWD+IFR+MS . 14311.05 85.18 113.06 9046.48 8966.58 -5543.88 -3257.26 5943211.04 641354.01 MWD+IFR+MS 77 14341 84.86 113.63 9049.14 8969.24 -5556.01 -3229.16 5943199.45 641382.33 MWD+IFR+MS . 14372.76 86.77 113.06 9051.40 8971.50 -5568.26 -3200.78 5943187.75 641410.94 MWD+IFR+MS 14403 06 88.76 112.56 9052.59 8972.69 -5579.99 -3172.87 5943176.56 641439.06 MWD+IFR+MS . 14435 06 91.14 110.82 9052.61 8972.71 -5591.82 -3143.14 5943165.30 641469.01 MWD+IFR+MS . 82 14467 93.11 110.69 9051.40 8971.50 -5603.42 -3112.53 5943154.29 641499.84 MWD+IFR+MS . 14496 97 44 93 109.49 9049.73 8969.83 -5613.42 -3085.20 5943144.83 641527.35 MWD+IFR+MS . 14527.91 . 93.24 110.15 9047.93 8968.03 -5623.89 -3056.14 5943134.91 641556.61 MWD+IFR+MS 14573.00 93.19 110.52 9045.40 8965.50 -5639.53 -3013.93 5943120.08 641599.11 MWD+IFR+MS 14621 34 93.01 110.36 9042.79 8962.89 -5656.39 -2968.70 5943104.10 641644.65 MWD+IFR+MS . 58 14669 92.94 110.63 9040.28 8960.38 -5673.26 -2923.57 5943088.10 641690.09 MWD+IFR+MS . 26 14715 93.14 109.83 9037.86 8957.96 -5689.03 -2880.77 5943073.15 641733.18 MWD+fFR+MS I . 14760.94 92.84 110.32 9035.48 8955.58 -5704.69 -2837.93 5943058.32 641776.32 MWD+IFR+MS 14808.46 92.68 112.00 9033.19 8953.29 -5721.82 -2793.66 5943042.04 641820.90 MWD+IFR+MS 81 14856 92.84 111.95 9030.86 8950.96 -5739.89 -2748.88 5943024.84 641866.02 MWD+IFR+MS . 14889.04 92.99 112.68 9029.22 8949.32 -5752.12 -2719.10 5943013.19 641896_02 MWD+IFR+MS ~ Halliburton Global Company: BP Amoco Date: 1/9/2006 Time: 14:51:43 Page: 6 Field: Prud hoe Bay Co-ordinate(NE)Reference: Well; Y-11,-True No rth Site: PB Y Pad Vertical (TVD) Reference: Y-11 G' 79.9 Well: Y-11 Section (V5) Reference: Well (O.OON;O.OOE,1 70.OOAzi) Wel{path: Y-11 C Survey Calculation Method: Minimum Curvature Db: Oracle. Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool. ft deg deg ft ft ft ft ft ft -, 14920.13 10 93 111.23 9027.57 8947.67 -5763.72 -2690.31 5943002.14 641925.03 MWD+IFR+MS 14950.06 . 92.99 112.66 9025.98 8946.08 -5774.89 -2662.59 5942991.50 641952.96 MWD+IFR+MS 02 14981 86 91 111.53 9024.67 8944.77 -5786.53 -2633.93 5942980.42 641981.83 MWD+IFR+MS . 71 15011 . 91.51 113.49 9023.77 8943.87 -5798.27 -2605.59 5942969.23 642010.39 MWD+IFR+MS . 15042 57 90 89 113.52 9023.12 8943.22 -5810.58 -2577.29 5942957.47 642038.91 MWD+IFR+MS . 12 15074 . 89 90 113.78 9022.63 8942.73 -5823.23 -2548.40 5942945.37 642068.04 MWD+IFR+MS . 15105.86 . 90.89 113.07 9022.14 8942.24 -5835.85 -2519.28 5942933.32 642097.40 MWD+IFR+MS 15137 99 40 90 114.12 9021.78 8941.88 -5848.71 -2489.84 5942921.02 642127.08 MWD+IFR+MS . 98 15169 . 65 90 113.23 9021.48 8941.58 -5861.55 -2460.54 5942908.75 642156.61 MWD+IFR+MS . 11 15200 . 20 90 113.82 9021.26 8941.36 -5873.58 -2432.92 5942897.25 642184.46 MWD+IFR+MS . 15245 82 . 97 89 114.04 9021.19 8941.29 -5892.12 -2391.13 5942879.52 642226.59 MWD+IFR+MS . 15293.49 . 89.41 114.46 9021.45 8941.55 -5911.70 -2347.67 5942860.78 642270.42 MWD+IFR+MS 17 15342 98 88 115.08 9022.14 8942.24 -5932.09 -2303.48 5942841.24 642314.99 MWD+IFR+MS . 66 15386 . 24 88 114.98 9023.21 8943.31 -5950.91 -2263.18 5942823.20 642355.64 MWD+IFR+MS . 29 15432 . 41 88 113.41 9024.55 8944.65 -5969.60 -2221.57 5942805.31 642397.59 MWD+IFR+MS . 75 15479 . 41 88 114.30 9025.87 8945.97 -5988.79 -2178.18 5942786.96 642441.34 MWD+IFR+MS . 15527.06 . 88.35 114.89 9027.20 8947.30 -6008.47 -2135.18 5942768.11 642484.71 MWD+IFR+MS 15573 66 25 87 116.02 9028.99 8949.09 -6028.48 -2093.14 5942748.91 642527.12 MWD+IFR+MS . 88 15635 . 07 86 115.28 9032.62 8952.72 -6055.37 -2037.15 5942723.10 642583.62 MWD+IFR+MS . 43 15666 . 84 84 115.94 9035.04 8955.14 -6068.53 -2009.69 5942710.47 642611.32 MWD+IFR+MS . 50 15759 . 82.97 117.12 9044.92 8965.02 -6109.87 -1926.89 5942670.74 842694.89 MWD+IFR+MS . 15831.01 81.23 118.18 9054.75 8974.85 -6142.73 -1864.15 5942639.08 642758.24 MWD+IFR+MS 15868.00 81.23 118.18 9060.39 8980.49 -6160.00 -1831.93 5942622.44 642790.79 PROJECTED to TD TREE = 6" CNV WELLH~AD= GRAY ACTUATOR= OTIS KB. ELEV = 85.4' BF. ELEV - 51.4' KOP = 3050' Max Angle = 98 @ 13566' Datum MD = 10888' Datum TV D = 8800' SS TBG~GiNAL P&A' WELLBORE NOT S OWN ON THIS ~ 1 1 ~ DIAGRAM BELOW THE 9-5/8" CSG WINDOW. ORIGINAL 9- 518" CSG TD = 8604' 27' 7" X 4-112" XO, ID = 3.958" 2207' 4-1/2" HES X NIP, ID = 3.813" 13-3f8" CSG, 72#, L-80, iD =12.347" ~-~ 2660` Minimum ID = 3.725" @ 11OQ2' 4-1f2" HES XN NfPPLE WHIPSTOCK (11119/05) ~ 750g' 9-5t8" EZSV PLUG (11/18/05) 7524` TOPOFTBG STUB (11/12/05) ~--~ 7615, TOP OF CEMENT (11110!05) 9350` 4-112" TBG, 12.6#, L-80, iD = 3.958" ~ 9448' 9-518" CSG, 47#, L-80, ID = 8.681" 9Q.2Q' 7" LNR, 26#, L-80, NSCC, 1D = 6.276" ~-1! 4-112" LNR, 12.6#, L-80, ID = 3.958" --C PERFORATION SUMMARY REF LOG: MWD GR/RESISTNfTY ON 12/13/05 ANGLE AT TOP PERF: 98 @ 13550' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2-1 /2" 4 13550 - 13570 O 12!23!05 2-112" 4 13600 - 13620 O 12!23105 2-1/2" 4 13640 - 13660 O 12!23(05 2-1/2" 4 13890 - 13910 O 12/23!05 2-1/2" 4 13940 - 13960 O 12!23105 2-1/2" 4 13980 - 14000 O 12!23105 2-1/2" 4 14040 - 14060 O 12/23/05 2-1/2" 4 14090 - 14110 O 12!23!05 2-112" 4 14140 - 14160 O 12/23/05 2-112" 4 14180 - 14200 O 12/23!05 4-112" TBG, 12.6#, L-80 - j 107E TCII, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 STGM, .0383 bpf, ID = 6.276" PBTD 14227' 4-112" LNR, 12.6#, L-80 IB7-M, 14313' .0152 bpf, ID = 3.958" 10711, ~--~4-1/2" HES X NIP, ID = 3.813" 10732' 7" X 4-1/2" BKR S3 PKR, ID = 3.875" 10755' 4-1 /2" HES X NIP, ID = 3.813" 10776' 4-1/2" HES X NIP, ID = 3.813" 10784' 7" X 5" BKR ZXP LNR TOP PKR w /TIEBACK SLV, ID = 4.40" 10789` 4-1/2" WLEG, ID = 3.958" EL''~9C} TT NC? ( LJCGED 10806' 7" X 5" BKR FLEX-LOCK LNR HNGR, ID = 4.43" 10816' 5" X 4-112" XO, ID = 3.95" 11002` 4-112" HES XN NIP, ID - 3.725" DATE REV BY COMMENTS DATE REV BY COMMENTS 12/18/80 BIXBY ORIGINAL COMPLETION 10/07191 RWO 10/16/95 M DO SIDETRACK (Y-11 B) 12!27/05 N2ES SIDETRACK(Y-11C) 01/03/06 ~~??=LH DRLG DRAFT CORRECTIONS PRUDHOE BAY UNft' WELL: Y-11C PERMIT Na: 2051640 API No: 50-029-20513-03 SEC 33, T11N, R13E, 1433' SNL & 313' WEL BP Exploration (Alaska} 7321' ~ 9-5/8" X 7" BKR G2 ZXP LNR TOP PKR w f I TIEBACK SLV & HMC LNR HNGR, ID = 6.30" MILLOl1T WINDOW (Y-11C) ~` 7488' - 7505' • 13-Jan-06 A(~GCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well Y-11 C Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF fifes. Tie-on Survey: 7,492.95' MD Window /Kickoff Survey: 15,831.01 ' MD (if applicable} Projected Survey: 15,868.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) MEMORANDUM • To: JimRegg ~;~~~ Z~~1~~C~ P.T. Supervisor FROiVt: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, February 01, 2006 StiBJECT: Mechanical Integrity Tests BP EXPLORATION (r1LASKA) INC Y-11 C PRUDHOE BAY UNIT Y-11C Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv , ~`. "-- Comm Weli Name: PRUDHOE BAY UNIT Y-I1C Insp Num: mitCS060131143418 Rel Insp Num API Well Number Permit Number: 50-029-20513-03-00 205-164-0 Inspector Name: Chuck Scheve Inspection Date: 1/31/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y_Ilc ;Type Inj. w I TVD ~ i sass ~ IA i Sao zs2a ' I zaso zaso ! ~r ~ p T ~ 2oslbao jTypeTest ~ SPT ! Test psi ~ _ 2197 j OA ~~ o o ( o j o ~ j Interval IrrITAZ. P/F P o Tubing's llso ~ luo ~ use ~ use Notes Wednesday, February Ol, 2006 Page 1 of 1 ~~ ~ ~, w ~ ,r~r ,~ i; ,~ i, {~ ~ 3~ . ~ ,~'°'~ s, ~~ ~' °s~~ ~'~'~~ ~ FRANK H. MURKOWSKI, GOVERNOR ~~~~ ~~~~++ ~~rr~ ~~~ ~~~~rr ~LL>•-7~ OII/ ~ ~iti•a7 333 W. T" AVENUE, SUITE 100 CONSERQA'1'IO1~T COMnIIS5IOK ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Dave Wesley FAx (907) 276-7642 Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU Y-11 C BP Exploration (Alaska), Inc. Permit No: 205-164 Surface Location: 1433' FNL, 313' FEL, SEC. 33, Tl 1N, R13E, UM Bottomhole Location: 2355' FNL, 1725' FEL, SEC. 04, TlON, R13E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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. Please provide at least twenty- four (24} hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this day of November, 2005 cc: Department of Fish & Game, Habitat Section wio encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO r,ISSION PERMIT TO DRILL 20 AAC 25.005 ~G~ to i~ 1 z©~ s ~~~ ~~ -.- ~,.1P ,sn u Vii: `~~ bj L) ., C~~,1 ~.x, ~~~~~~~~oQ~ ia. Type of work ~ Drill ®RedriH ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Oil Itc~lt~lne ^ Stratigraphic Test ®Service ^ Development Gas ^ Single one 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number PBU Y-11C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15739 TVD 9060 12. Field / Pool(s): Prudho® Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1433' FNL 313' FEL SEC T11 N 33 R13E UM 7. Property Designation: ADL 047471 Pool , , . , , , Top of Productive Horizon: 5278' FNL, 4433' FEL, SEC. 33, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud November 0 005 Total Depth: 2355' FNL, 1725' FEL, SEC. 04, T10N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 8750' 4b. Location of Well (State Base Plane Coordinates): Surface: x-644504 y- 5948816 Zone- ASP4 10. KB Elevation (Height above GL): 85' feet 15. Distance to Nearest Well Within Pool Y-21 A is 60' away 16. Deviated Wells: Kickoff Depth: 7500 feet Maximum Hole Angle: 96 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA 35) Downhole: 3845 Surface: 386 1s. a ng Program: Size Specifications Setting Depth To Bottom uan o ement 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 3532' 7350' 6686' 10882' 8910' 198 cu ft Class'G' i 6-1/8" 4-1/2" 12.6# L-80 IBT-M 4956' 10782' 8849' 15738' 9060' 89 cu ft Class'G' ~" 19. PRESENT WELL CONDITI ON SUMMARY (To be completed for Aedrill AND Re-entry Operations) Total Depth MD (ft}: 10869 Total Depth TVD (ft): 9047 Plugs (measured): None Effective Depth MD (ft): 10782 Effective Depth ND (ft): 9036 Junk (measured): None Casin Len h Size Cement Volume MD TVD n r i i 0' 20" x 30" cu ds Concrete 110' 110' 2662' 13-3/8" 301 cu ft Permafrost II 2662' 2662' 8604' 9-518" 1320 cu ft Class 'G', 130 cu ft PF 8604' 7837' r i 1281' 7" 57 cu ft Class 'G' 8329' -9610' 7574' - 8783' Liner 1430' 4-112" 35 cu ft Class 'G' 943' - 10869' 8651' - 9047' Perforation Depth MD (ft): 10000' - 10680' Perforation Depth TVD (ft): 8966' - 9025' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jeff Cutler, 564-4134 Printed Name ave Wesle Title Senior Drilling Engineer Prepared By NameMumber. Si nature ~C Phone 564-5153 Date ~3r~s ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ~ ~ _ /~"E ~ API Number: 50- 029-20513-03-00 Permit Approval Date: ~ See cover letter for other requirements Conditions of Approval: Samples Required n. Yes~No Mud Log Required ^ Yes~No Hydrogen Sulfid ~ Measure ~ T Yes ^ No Directional Surrey Required Yes ^ No ... Other: '~~ v ~° ~ e" f' ~ '~-~7 tj c~ J iii . /~ ~.~ (,~* 4v1~ ~.. ~ ! ~ ~.~ !.i ~: ~ ~aC` Y`+°e ;-sit, APPROVED BY A roved B . THE COMMISSION Date Form 10-401 R ed O6 04 Submit In Duplicate • • Well Name: Y-11C Planned Well Summary Horizontal Well Y-11 C Well Sidetrack Target Zone 4 Type In'ector Objective AFE Number: PBD4P2368 Surface Northin Eastin Offsets TRS Location 5,948,816 644,504 1433' FNL 1313' FEL 11 N, 13E, 33 API Number: 50-029-20513-03 T t Northin Eastin Offsets TRS arge ' ' L ti 5944895 640467 FS 2 L / 847 FWL 11 N, 13E, 33 oca ons 5943430 640965 ~ 1472 FNL / 1313 FWL 10N, 13E, 4 Bottom Northin Eastin Offsets TRS Location 5942590 643225 2355' FNL ! 1725' FEL 10 N, 13 E, 4 Planned KOP: 7,500' and 16,815' tvd Planned TD: 15,739' and ! 9,060' tvd Ri Nabors 2ES ~ CBE: 51.39' RTE: 79.9' Directional Program A roved Well Ian: W 03 Exit oint: 7,500' and / 6,815' tvd Maximum Hole Inclination: ~96° in the tanned 6 1 /8" roduction section. Proximi Issues: Y-21A passes 1/200 minor risk. All other wells ass major risk criteria. Survey Program: Standard MWD/IIFR/MS. Nearest Well within ool: Well Y-11C, wp03 asses underneath Y-21A with 60' of vertical standoff Nearest Pro ert Line 8,750' Y-11 C Sidetrack Page 1 • • Logging Program Hote Section: Required Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR/PWD throu hout the interval 6 1/8" roduction: Re a MWD Dir/GR/Res/ABt throu hout the interval. Sam les at 50' intervals. Cased Hole: IT in the 7" intermediate liner O en Hole: "tanned Mud Program Hote Section /operation: Mill window in the 9 5!8" casing at 7,500' and to 100' above THRZ. T e Densit Viscosit PV YP API FL H LSND 9.0-9.3 50-60 15-22 30-40 <6.0 9.0-9.5 Hole Section /operation: Drilling 8 1/2" interval from --100 above THRZ to section TD T e Den Viscosit PV YP API FL H LSND 11.1 42-52 18-25 22-28 <5.0 9.0-9.5 Hole Section / o eration: Drillin 6 1/8" production interval T e Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.6 >25,000 8 - 15 24 - 30 4 - 6 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and ! tvd 8 1/2" 7" 26.0# L-80 BTC-M 3,532' 7350' / 6,6$6' 10,882' / 8,910' 6 1/8" 4'/z" 12.6# L-80 IBT-M 4,956' 10,782/ 8,849' 15,738' / 9,060 Tubin 4'/z" 12.6# L-80 TC-II 10,782' Surface 10,782/ 8,849' Nv ~ t; ~ nis wen is p~annea wnn the minimum a~wwea, i vo' uner iap, the ~- snoe wtn de iocatea near the top of the Sag River, but with the planned completion, the packer to injection zone distance will exceed the -~ 200' limit as per 20 AAC 25.412 (b). A variance to 20 AAC 25.412 (b) is requested allowing a packer to injection zone distance of greater than 200' is requested Cementing Program Casin Strin 7", 26#, L-80, BTC-M intermediate liner Slurry Design Basis: Lead slurry: None planned. Tail slurry: 1,000' of 7" X 8-1/2" annulus with 40% excess, plus 85' of 7", 26# shoe track. Pre-Flush None tanned Fl id S /V l S acer 35bbls MudPUSH at 12.0 u s equence ume: o Lead Slur None tanned Tail Slur 35.0 bbl / 197.6 cf / 6 sxs Class 'G', 15.8 .1rrcf/sk. ,~. Casin Strin 4 1/2", 12.6#, L-80, IBT-M solid production liner Slurry Design Basis: Lead slurry: none planned ° , Tail slur :4,856 of 4 1/2 X 6 1/8 annulus with 40% excess, lus 85 of 4 Y-11 C Sidetrack Page 2 • • 112", 12.6# shoe track, plus 100' of 7" X 4 ~/z" liner lap, plus 200' of 7" X 4" drill i e annulus. Pre-Flush 25bbls CW 100 Fl id S l /V S acer 35bbls MudPUSH at 9.6 u s equence o ume: Lead Slur None tanned Tail Slur 122.7 bbl J 689 cf 589 x Class `G', 15.8 , 1. cf/sk. Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 518" casin Bride lu to surface 30 min recorded 4,000 si surface 9 5/8" casin window 20' new formation be and FIT 12.0 EMW 7" casin Float a ui ment to surface 30 min recorded 4,000 si surface 7" casin shoe 20' new formation be and FIT 10.0 EMW 4'h" roduction liner Float a ui ment to surface 30 min recorded 4,000 si surface Well Control r r Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. l BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum anticipated BHP: 3,845 psi at 8,910' TVD. Maximum surface pressure: 2, SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: nfin' with 12.0 ppg EMW FIT Planned ROPE test pressure: 0 psi low 14,000 psi high - 7 day test cycle (Pre drilling phase) BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams drilling liner. while running 3,535' of 7" liner. In the event of a kick the rig will follow the current best practice of picking up a joint of drill pipe crossed over to casing thread and running in the hole placing the drill pipe across all rams. This configuration provides two sets of employable rams, rather than one. Well Interval: 6 1/8" roduction interval Maximum antici ated BHP: 3,386 psi at 8,945' TVDss. Maximum surface ressure: 2, SI (based upon BHP and a full column of as from TD @ 0.10 psi/ft) Calculated kick tolerance: I fin' with 10.0 EMW FIT. Planned BOPE test ressure: si low ! 4,000 si hi h -14 da test c cle Drillin o erations Planned com letion fluid: 8.4 seawater / 7.1 p Diesel BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)G regarding the function pressure test requirement after the use of BOP ram type equipment for other than weN control or equivalent purposes, excebt when the routine use of BOP ram-type. equipment may have compromised their effectiveness. (Example wouk! be when pipe rams are inadvertently closed on a tool joint during routine. operations.) The. activities associated withthis reques# willnot compromise the integrity of the BOP equipment: Y-11 C Sidetrack Page 3 • • Disposal Annular In'ection: No annular injection in this well Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Area of Review Dist. to nearest property line, ft.: 8,750' Dist. to nearest well within pool, ft: 60' (w 3 asses underneath Y-21 A w/ 60' vertical standoff) Wells within 1!4 mi. of this injection well @ top reservoir & along well path to BHL Well Name Dist, Ft. Annulus Inte rit Comments Y-21 900' abandoned '~ lib o70 Y-21A 60' SI TxIA, FTS. TTP •~ 14 Sv37 Y-29 1000' abandoned ~ i g o l 7 ~} Y-29A 1120' No well rote it issue. ~' l 4 G o91 Well Status @ Com letion Cemented liner, erfd with tubin for injection DNR Land Use Permit No. NIA Geologic Prognosis Est. Formation To s Uncertain Commercial Hydrocarbo n Bearin Est. Pore Press. Est. Pore Press. Formation (TVDss) (eet) (YeslNo) (Psi) ( EMW) CM2 (Y-11Ci KOP is ~ -6733' SSTVD) 6220 +/- 20' No 2187 6.8 CMl 7040 +/- 20' No 2548 7.0 THRZ 7310 +/- 20' No 2666 7.0 BHRZ (JKU) 7585 +1- 30' No 2787 7.1 TJG 7640 +/- 30' No 2812 7.1 TJF 7990 +/- 30' No 2966 7.1 TJE 8080 +/- 30' No 3005 7.2 TJD 8380 +/- 30' No 3137 7.2 TJC $550 +/- 15' No 3212 7.2 TJB 8690 +!- 15' No 3274 7.2 TJA 8760 +/- 15' No 3304 7.3 TSGR 8830 +/- 15' Yes 3335 7.3 TSHA 8850 +/- 15' No 3344 7.3 TSHB 8890 +/- 15' No 3362. 7.3 TSHC 8910 +/- 15' No 3370 7.3 Y-11 C Sidetrack Page 4 • ~ TSAD 8935 +/- 15' Yes 3381 7.3 To HOT $980 +/- 10' TSAD at 1st well crest 8940 +/- 10' 3384 7.3 TSAD at 2nd well crest 8945 +1- 10' 3386 7.3 TD Criteria: BHL was located on basis of 1500' of standoff from Y-09A to avoid premature breakthrough of MI. If well is drilled to plan it will TD in a position to support production at Y-09A, Y-29A, Y-21 A, P-04L1 and a future offset to Y-21. This is the best case for ultimate recovery and maximum economic benefit. However, in the event of excessive problems in trying to reach TD, a shallower BHL would likely provide some reservoir benefit as the five aforementioned wells occur relatively uniformly through the reservoir from point-of-entry to TD. Note : 2 most recent wells in the area i.e Y-146 ST'ed in 2001 used 8.6 ppg mud to TD & Y-20A ST'ed in 2001 used 11.3 ppg mud when drilled 8-1/2" hole section & 8.4 - 8.5 mud when drillin 6.125" hole section to TD. Oaerations Summar Current Condition: / Sl since June 2003. / 4-1/2'; 12.6#, L-80, NSCT tubing, WLEG C~? 9449' MD. / 7" X 4-1/2"Baker S-3 packer at 9385. / 04/23/05: Functioned all LDS on casing head and tubing spool, all good. Tested casing hanger and tbg hanger voids and seals to 4000 PSI I30 Minutes. / 04/23/05: MIT ON WELL Y-11 Gray 'BP Big Bore Original' SM Wellhead with 71/i6 x 6 3/8 Bore tree. ~ PPPOT-T (PASSED) Initial void pressure @ zero. / 4-112" HES `X' Nipple set at 2,021' MD Scope * Notify the field AOGCC representative with intent to plug and abandon Pre-Rig Work: 1. Rig up slickline, drift 4-1/2" tubing as deep as possible. 2. Fluid pack tubing and inner annulus. 3. P&A perfs from the PBTD to 9,350' MD (100'MD above tubing tail). RIH with coil to PBTD C«2 10,782' MD. Lay in 22 bbls of cement to 9,350' MD. Obtain squeeze on cement with 5 additional bbls. POH with coil. 4. Rig up slickline, tag TOC. 5. RU E-line. Chemical cut the tubing in the middle of a joint no higher than 7,600' MD. 6. Fluid pack T X IA with seawater, test IA to 4000 psi. 7. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect with diesel to 2,200' MD. 8. Test the 9-5/8" pack-off and tubing hanger seals to 5000 psi. 9. Function all lock-down screws. Repair or replace as needed. 10. Bleed casing and annulus pressures to zero. 11. Set a BPV in tubing hanger. Secure well. 12. Remove the well house. 13. If necessary, level the pad. Please provide total well preparation cost on the handover form. Rig Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. Y-11 C Sidetrack Page 5 • • 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from pre-rig tubing cut at 7,600' MD. 5. RU a-line. Run GR/JB for 9-5/8", 47# casing with CCL to just above top of tubing stub. 6. RIH with CIBP on a-line. Set CIBP to avoid cutting a casing collar during window milling operations. 7. Test casin to 4000 psi against bridge plug. 8. 9-5 8" a er• bottom trip whipstock assembly. RIH, orient whipstock with MWD and set on CIBP. 9. Swap over to 9.0 ppg LSND milling and drilling fluid. 10. Mill window in 9-5/8" casing at 7,500' MD (top of window) plus 20' past middle of window. Perform .~~' FIT to 12.0 ppg EMW. POH. ~-j~~, t~ '~Jt 11. MU B-1/2" drilling assembly with Dir/GR/PWD/IFR/Caz. RIH. 12. Orient BHA with MWD to kick off and drill ahead. ~'-(''!'r°V~~~t.... ;~. Atrill8 X50' MD'( t100eabove he tolp oflthe HRZ) we ghtupgo 11.1 ppg with spike fluid from the MI plant. 15. Drill ahead to casing point at Top Sag River, estimated depth of 10,882' MD. 16. Run and cement a 7" drilling liner with 150' of liner lap in the 9-5/8". Displace cement with mud. ~" POH. 17. MU 6-118" BHA with Dir/GR/RES/ABI/IFR/Caz and RIH to the landing collar. 18. Pressure test 7" liner to 4000 psi for 30 minutes. ~ 19. Drill shoe track. Swap over to 8.5 ppg Flo-Pro SF mud and drill 20' of new formation. Perform FIT to 10.0 ppg EMW. 20. Drill the 6-1/8" production interval building at 11 °/100' to horizontal, targeting Z4 Ivishak. Drill ahead to j an estimated TD of 15,738' ~ 21. RU E-line. RIH and run IT~og from 7" shoe to top of 7" liner. Quality cement bond required by ~' AOGCC to allow water inj ion. 22. Run and cement a 4-1/2" liner with 100' liner lap in the 7" drilling liner. Displace cement with perf pill ~ and mud. 23. Release from liner, displace well to clean seawater. 24. Pressure test 4-112" liner to 4,000 psi for 30 mins. 25. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. Expected interval is near ~- well TD. 26. POH. LD DP and perf guns. 27. Run 4-1/2", 12.6#, L-80 TC-II completion, tag up on tie-back sleeve and space out tubing. / 28. Land tubing, RILDS. Set TWC 29. ND BOPE and NU the tree. Test tree to 5000 psi. Pull TWC 30. Reverse circulate in sufficient diesel to freeze protect the well to 2200' TVD, allow to U-tube. 31. Drop rod and ball. Pressure up on tbg and set the packer. 32. Test tubing to 4,000 psi for 30 minutes. Test annulus to 4,000 psi for 30 min. Record each test. ~ 33. Set and test TWC. 34. Secure the well. 35. RDMO Post-Riq Work• 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. Phase 1: Move In /Riq Up /Test BOPE Planned Phase lime Planned Phase Cost 55.9hours $342,400 includes re-ri costs Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Y-11 C Sidetrack Page 6 CJ • Issues and Potential Hazards - No wells will require shut-in for the rig move onto Y-11. However, Y-20 is 35' to the West and Y-37 is 38' to the East. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MIlRU operations, the Y-11 well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During NDINU BOPE operations, the Y-11 B well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. - Y-Pad is of esignated as an H2S site. Standard Operating Procedures for H2S precautions should b wed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading Y-20A 10 ppm Y-09A 10 ppm Y-37A 70 ppm Y-146 20 ppm The maximum level recorded of H2S on the pad was 120 ppm in well Y-30L1 on 02/08/2004. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 47.3 hours $152,600 Reference RP • "De-completions" RP Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a Gray BP original. Check with Cameron to ensure all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has an "X" Nipple at 2021' MD, there are no control lines to contend with during decompletion. Y-11 C Sidetrack Page 7 • ~ - Run GR/CCL Log from the bridge plug setting depth to surface after setting the EZSV. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 29.8 hours $209,200 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - Unable to determine 9-5/8" cement data from historical records. - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Phase 5: Drill 8 1/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 105.1 hours $523,250 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - Primary Depth Control Log (PDCL) is the SWS Y-11A OH resistivity log. All Y-11Ci MWDlLWD logs need to be tied in and depth shifted to the PDCL. Record a minimum of 200' of LWD logs above the window to provide PDCL tie-in. - For this well, the Kingak will require a mud weight of 11.1 ppg. Maintain mud weight at 11.1 ppg, minimally, from 100' above the HRZ to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure, the SOR is estimating 7.3 ppg max, at the Sag River depth, a fracture gradien f 12.0 ppg at the 9 5/8" casing window, and 11.1 ppg mud in the hole, the kick tolerance is ' fini - The above kick tolerance is based on an FIT of 12. pg EMW, if this is not reached contact the ODE. - One fault crossing has been identified in the intermediate section at 10,485' with an estimated throw of 15-20'. After crossing the fault it may be necessary to circulate samples up to allow the geologist to depth correlate for the 7" casing pick. Y-11 C Sidetrack Page 8 • • Phase 6: Run and Cement 7" Intermediate Casing Planned Phase Time Planned Phase Cost 25.9 hours $297,000 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab 1 surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Phase 7: Drill 6 1!8" Production Hole Interval Planned Phase Time Planned Phase Cost 229.9 hours $1,284,500 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - The geologic polygon is bounded on the North by a fault, the Eastern polygon line is set up to maintain 1,500' standoff from Y-09a producer - Y-11 Ci crosses two small faults, #1 C~ 12,870" MD and #2 @ 15,240' MD, in the production section both are poorly imaged on 3D seismic and show little continuity. The risk of lost circulation is considered low for both faults. Phase 8: Run USIT Log in 7" Intermediate Liner Planned Phase Time Planned Phase Cost 16.1 hours $63,200 Reference RP • "Wireline Pressure Control SOP Issues and Potential Hazards - 50' of good cement is required to demonstrate injection fluid isolation. Y-11 C Sidetrack Page 9 • • Phase 9: Run 4~/2" Production Liner Planned Phase Time Planned Phase Cost 60 hours $392,500 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4'/z", 12.6#, L-80 solid liner throughout the production interval. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be 500 psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4 ~/2" liner will be run to extend 100' back up into the 7" liner shoe. - Ensure the 4'/z" liner top packer is set prior to POH. Job 10: DPC Perforate Well Planned Job Time Planned Job Cost 31.9 hours $130,600 Hazards and Contingencies - The production interval of the well will be DPC perforated prior to running the completion. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with pert guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach tag the landing collar due to cement/fill. Reference RPs • DPC Perforating RP • Schlumberger DPC Perforating Guidelines Phase 12: Run 4'1z", 12.6#, L-80, TC-11 Completion Planned Phase Time Planned Phase Cost 28.8 hours $320,500 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 Asia at 100° F. Y-11C Sidetrack Page 10 • • - The completion, as designed, will be to run a 4~/2", 12.6#, L-80, TC-II production tubing string, stinging into the 4'/z" liner tieback sleeve. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 6.0 hours $40,600 Reference RP •: "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig to move off of Y-11. However, Y-20 is 35' to the West and Y-37 is 38' to the East. These are the closest neighboring wells care should be taken while moving off of the well. Spotters should be employed at all times. Y-11 C Sidetrack Page 11 CUMI'.\NY DI~I,V LS kFYI:k1:N('1~: INFUkhL\TIUN SUk\FY rktk~k:\hl Plan: Y-IlC wpll3 tY-11 B. Plan Y-11 CI nl\ by ('alcuWn MNuJM Iml(un nlrt (n.~N INI: kf till(' 1'Im lme Nunh \'m I11\Dlkf I.i4~ %5 ]440 ti \'Slkf SI IIWNU hIL II Ihplhlm lxrlh to SwsyYWI I,xJ 11\ 4 i14% %I ISIi%74 YW I Y II ' CrealCd ey'. Di@iwl Buti tis ('lien! l)se DI'3:?_.?IXIi a Yrr r S tull: ISI K'S \ I ( I I sl i4~ '%s rV WI nl J D h k r ~ w1% rvlw . ~ ( 1 h1ND Irk A1S C'hecked' Dlt: u yr ; Scan MCrhuJ: 1Tes'('ylilNcr N°NI ceum .yl c cnrxe . _ ('akulari,~n hh•OxXI: hLninluni l'unanlre I~nor Surtlln•: I~:Ilipuwl ~ l'avmg Reviewed: Dale: K'amine M1IcNxN. kale. Uv.eJ N'LLL Ulil:\ILS Naaic N -1 ~ I~. ~N Nurhing I~vsnnE Lermxk L.mglnxk Slol \-Iln 1i%.sl -1~i4.1' 541%%I h.il 6115111.5% 'll'Ih'111.1(r!N IlN'14'Si.1KIW II IARUY:f U1~:1.\ILS Na~nc J\U ~N/-S ~1~:-w Northing lavnp Shalr.~ ~ ~ ~~ ~ i ~ ~ ~ ~ ~ ~ ~ l I I ~ ~ ~ I I ~ Y Ill'11 'NII4wl -li]I.%] lY h_l 544 ?]111X1 h11uw..III I t ' ' i ' I ~ ~ I i I ~ ' Y IIC 13 w114 w1 511]%1 161154 s'i1.1,inIX1 (+NW 511 I Y nL a ~In iwl uw1 n luln snr~lw%I 61 wlo r - r 600 ~ . v ncl+ wl Iwl 5x50] 1oa6.16 s41 4uy%I 611 Wll P I - I I I I ~ I . - : - ~ ~ ti nc)h wI54w nlol_n 114]46 $411swm w_ sm r-n ~ _ I I I ', Y IIr'I' wl vwl -k,IJ.'] -0111_? $~Nil'_i.W WWwul Y°rm ~ - I ' i I i SECTION DETAILS i ~ ~ _ i ! I I ~ I Sec MD Inc A~i TVD +N/-S +Ei-W DLeg TFnee VSec Target ~ , - ~ + ~ ~ . ~ i . 1 7498.110 30.11 229.91 6813.12 -1729.39 -1564.37 0.00 OAII 906.23 ~ ~ ~ ~ 2 7518.00 32.49 2311A5 6830.21 -1736.04 -1572.35 12.00 7.00 908.88 . I ~ ~ i ~ - ~ i ~ I ~ 3 804LU9 53.28 233.98 7211.44 -1951.17 -1853.38 4.0(1 7.93 985.09 660 ~ 4 1(1893.17 53.28 233.98 8916.67 -3295.60 -3702.46 0.00 Q.00 1422.10 ' ~ I ~ ari D'v 12100'; 749 MD, 6813.~2'1'VD ' ~' - 5 112110.61 86.90 230.00 9(119.90 -3471.87 -3926.23 IIAU -7.15 148729 Y-IIC'TI ' ~ ' - ~ ~, - 6 11627.97 86.79 182A1 91144.84 -3843.16 -411L112 ~Fl.UO -91.511 1745.69 ' ~ - ~ ~. ~, ~ ~ ~ 7 121011.83 86.79 182.91 9071.33 -4314.66 -4135.112 IIAU U.l1U 2162.88 ', Slam Dv 4II W':~75 R'MD, fix3Q21'TVD ~ } -- ~ I ~ 8 12404.01 90.00 I65.lIU 9(179.90 -4614.77 -41(1312 6.00 -80.17 2448.31 Y-IIC T2 { J ---~ ~ I ~ 9 12807.9? 96.10 141.50 91158.13 -4972.35 -392315 6A0 -75A1 2848.44 4 ~q0°'. ~ I lU 131179.95 y6.10 141.511 9029.24 -5184A4 -3754.86 0.0(1 0.(IU 3111.46 I ~ I I 13255.611 90.00 138.00 9019.90 -5317.82 -3641.59 4.00 -1511.06 3280.98 Y-IIC T3 [ ! 12 13438.56 85.68 132.09 9026.811 -5447.12 -3512.51 4A0 -12616 3453.32 ' A8° End Dm : 041.09' MD, 7211.44' TVD ~ - 13 13704.86 85.68 132.09 9046.87 -5625.10 -3315.44 OA0 0.110 3696.91 ' - - ~ - ~ ~ 14 14049.14 90.00 119.011 9059.90 -5824.57 -3036.16 4.00 -72.114 3995.71 Y-IIC'T4 7200 ~ IS 14473.111 94.18 10355 9044.35 -5974.35 -264L59 4.1111 -75.53 4298.22 ' R ~ ~ - - ~ '. '. - I ~ ~ IG 14687.25 94.18 1112.55 9038.74 -61120.79 -2433.02 0.00 1L011 4428.45 I ~, ~ - ~ - ~ ~ - ~ ~ - I - ! ~ ~, ~~ '~ I7 14792.61 911A0 1112.110 9024.90 -6043.17 -233(1.17 4.00 -172.45 449220 Y-IIC TS ~ II - ~ I ~ ~ ~ 18 1487(,.04 87.78 99.51 9026.51 -6058-74 -2248.23 4.OU -13L6(, 4540.94 1 . i _ _ _ '. 19 15738.79 87.78 99.51 9059.90 -6201.11 -1397.96 0A0 0.011 SU29.31 Y-IIC' T6 L _ 1 ~ ' ~ I I CASING DETAILS L I Q d,~ i i i ~ 'i ~ I I No. TVD MD Name Sizc ~ I 'I ~ 'I ~ it I ~ I I I 8909.90 10881.86 7" 7.(1011 78011 ' vouo ' ' I I 2 9059.87 15738.00 41/2" 4.50(1 i I I Stan DirIGIW' : IU893. TMD. R91fi 6TTVD I I I I i . I t ~ End oir : 11627.v7• MD, vOd~i.R4~ TVD - - I I I ~,. I i ~~ FORMATION TOP DETAILS I SIUn DQ 6/I(IU' Izla).R MD, y071.33TVD ~ Nu. TVDPath MDPath Fonnatiou 'I I ~ ~ End Dar : 12%07.91' MD 9058 13,TVD I .. ~ I I . 1 89119.90 10881.86 TSGR .. ~ I - - Stan Dir 4,l :13079.9~Mp 9029241'} ~ - I ' ' 840 End Dlr :134385( MD, 902 R TVD - i (~D - - ' i - - -1 -! - i .Stan Dir4.100'--: 1 704.X1+' bID. 9U46.87"fVD __ -___- - . . ~ I - - I ~ ~ ~ ~ I ~ :End Dlr 14473.0 1 ~~ 1 D. 9(N-1.35' TVA ~ I~ _ _ . ._ _. . ~ ~. ~'- 1(Y II)' I - - I-p I _ - _ ~ SWn Dir:4 )U': 146$7>>Md, 902!{.7~1'T D - _-- . _ .. I I End it ' 148 604' MD I' '9026.5 'D . j{ _t urd Dc ' 9059.9' TV 1573tt~ DI TSKiI~ ; J I ' ~ I - -Y _ - -. i - - 9000 I I - - }'-1.16.11'-1 )~ i ~ - __ __ p _ __ __ °~I I ° I ~ ~ __ I Ii ~ P OOb _ _ _ I _. __ - -11C Y 'w 3 - ~ . I I ~ I ~ ~ t f 1 _ ~ _. _ _ -, - - - _ - I - - - - T - -- 4 1; 2" - , _ ~' i i - I .. 600 1200 1800 24011 30110 3600 42011 480(1 5400 6000 Vertical Section at 155.00° [6001Uin] -16UU- (DMPANY nY.-I AILS BI' Anun~ M Nub. hr - (~ a1un~ M h~~d: lra (vlilwk N.xth x surt.e. I:IhP[x~al - (uving y hleduvl. Rule. lixvvl i CASING DETAILS End D ir :8041.09' D, 7211.44 ' TVD - - I ' ~ ~ ~ No. TVD MD Name Sizc - ~ ~ : I 8909.90 10881.86 7 " 7.000 - I - . ~ I ~ ~ ~, ~, - _ 9059.87 15738.00 4 l/2" 4.500 ~I ~'~~, i, TARGET DETAILS Na me TVD +N!-S +E.-W Northing East ing Shape _ Y-l IC'TI 9019.90 -3471.87 -3926.23 5945'_70.00 640645 A1 Point ' Y-I IC T3 9019.90 -531282 -3641.59 5943430.00 640965 A2 Poiltt 8916.6TTVD Y-l IC TS 9024.90 -6043.17 -233(1.17 5942730A0 642290.02 Point Y-l IC' T4 9059.9(1 -5824.57 -3036.16 5942')35.00 641580. 02 Point Y-I IC T6 9059.90 - 6201.11 -1397.96 5942590.(10 643225. 01 Point 4'TVD Y-IIC T2 9079.90 -4614.77 -4103.22 5944124.00 640490.01 Point SECTION DETAILS '1.33'TVD Scc MD Inc Azi TVD +N/-S +E,'-W DLeg TFace VSec Target I 7498A0 30.11 229.91 6813.12 -1T!9.39 -1564.37 0.00 0A0 906.23 7518.00 32.49 230.45 6830.21 -1736.04 -1572.35 12.00 7A0 908.88 3 8041.09 53 ?8 233.98 7211.44 -1951.17 -1853.38 4.00 7.93 985A9 3 10893.17 53 ?8 233.98 8916.67 -3295.60 -3702.46 0.00 UAO 1422.10 ~-I ~ 5 11200.61 86.90 230.00 9019 A(1 -347L87 -3926.23 11.00 -7.15 1487.29 Y-lIC TI 6 11627.97 86.79 182.91 9043.84 -3843.16 -4111.0'_ I L00 -91.5(1 1745.69 7 12100.83 86.79 182.91 9071.33 -4314.66 -4135A2 O.UU OA(1 2162.88 - 8 12404.01 90.00 165.00 9079.90 -4614.77 -4103.22 6.00 -8(1.17 2448.31 Y-IIC T2 ' 9 12807.9? 96.10 141.50 9058.13 -4972.35 -3923.25 6.00 -75A1 2848.44 VD IU 13079.95 96.10 141.50 9029?4 -5184.04 -3754.86 Q.00 OA0 31IL46 II 132>5.60 90.00 138.00 9019.90 -5317.82 -3641.5) 4.00 -ISO.U6 3280.58 Y-IIC T3 I2 13438.56 85.68 132.09 9026.80 -5447.12 -3512.51 4.00 -126.26 3452.32 13 13704.86 85.68 I32.U9 9046.87 -5625.10 -3315.44 O.UU O.UO 3696.91 VD 14 15 14049.14 14473.01 90.00 94.18 119.00 102.55 9059.90 9044.35 -5824.57 -5974.35 -3036.16 4.00 -2641.59 4.00 -72.04 -75.53 3995.71 4298 ?2 Y-I IC T4 IG 14687.25 94.18 102.55 9(128.74 -60211.79 -2433.02 0.00 0.00 4428.45 8TTVp 9046 17 14792.61 90.00 102.00 9024.90 -6043.17 -2330.17 4.OU -172.45 4492.20 Y-l IC TS . 18 14876.04 87.78 )9.51 902(1.51 -6058.74 -2248.23 4.00 -131.66 4540.94 . I ' ~~ I9 15738.79 87.78 99.51 9059.90 -6201.11 -1397.96 0.011 0.0(1 5029.31 Y-l IC T6 RLFLRLN('1: INFURh1A 1IUN SURVEY PNDtilte\M Plan: Y-I IC wP031Y-I lB. Plun Y-11 C) I'n-~~Ninate IN'LI N.knm~r W.N ('cove \'-I l ls, l me N~~nh Ihp1h Fiu Iklnh lu SuncyPlmt l uul ('rcatnl B}'. Digital Buiinexx Clirnl User Date: 3:2?-'INIS \'i7t 'I(I\nlNf I.i4- x.s 7Y 411 Si 1V11Nr 51 II (0-WN,OIXII.1 "%J4A 1X1 ISItA 74 1'Immnl: Y'-IIC O7N13 VI4 hIW U-IPN~hIS ('hocked: Dale: Mzas rl n p I R f I i9 %.5 "19.4f1 ( kulvlion Me levl. hlioinlum C n-anm WI~:LL UI~ IAILS Nm1x N.-1 ~I:-W N~vthing I:mung Lau11x4 Longlnxk Slur Yd 16 (Y- IBI' ~ ~ Y-nn uxsl -323v.n >wxxla.73 r.uAl3sx 7u'I h'u3.3nJN ux'Ja531wIW n FORMATION TOP DETAILS Stan rl2/IW':7498'MD;681 12TVD ~ Nn. TVDPath MDPath Fortnatiat ~_~ 700 I 8909.90 10881.86 TSGR Y-IIA(Y-IIA) StartDir4:l `: 75t8'MD.6830.21'T D 1 ~ /' I c R`, -401 x L s 5 I I ~ ~i ', 1ir4/IOQ':13079.95'M t -axoo -aoou -3zoo -24ou -ufou -xoo D soo Wcsq-)iEast(+) [BUOILin] Sperry-Sun BP Planning Report Company: $P Amoco bate: 3/22/2005 Time: 10:37:34 Page: I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-11 B, Tnae North Site: PB Y Pad Vertical (TVD) Reference: 51`.39 + 28.5 79.9 Well: Y-11 B Section (VS) Reference: Well. (OAON;O:OOE,155.OOAzi) Wellpath: Plan Y-11 C Survey Calculation Method: Minimum Curvature Db: Oracle Plan: Y-11C wp03 Date Composed: 3/1/2005 Version: 19 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: bggm2004 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-11 B Slot Name: 11 Y-11 B Well Position: +N/-S 338.51 ft Northing: 5948816.33 ft Latitude: 70 16 3.364 N +E/-W -3239.37 ft Easting : 644503.58 ft Longitude: 148 49 53.280 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 10881.86 8909.90 7.000 8.500 7" 15738.00 9059.87 4.500 6.125 4 1 /2" Formations MD, TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 10881.86 8909.90 TSGR 0.00 0.00 Targets Map Map <-- Latitude --> <- .Longitude -> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft Y-11 C T1 9019.90 -3471.87 -3926.23 5945270.00 640645.01 70 15 29.208 N 148 51 47.509 W Y-11 C T3 9019.90 -5317.82 -3641.59 5943430.00 640965.02 70 15 11.054 N 148 51 39.201 W Y-11 C T5 9024.90 -6043.17 -2330.17 5942730.00 642290.02 70 15 3.925 N 148 51 1.050 W Y-11 C T4 9059.90 -5824.57 -3036.16 5942935.00 641580.02 70 15 6.073 N 148 51 21.585 W Y-11 C T6 9059.90 -6201.11 -1397.96 5942590.00 643225.01 70 15 2.374 N 148 50 33.937 W Y-11C T2 9079.90 -4614.77 X103.22 5944124.00 640490.01 70 15 17.966 N 148 51 52.639 W Plan Section Information MD Incl Azim TVD' +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft degl100ft deg/1 OOft, deg/100fk ' .deg 7498.00 30.11 229.91 6813.12 -1729.39 -1564.37 0.00 0.00 0.00 0.00 7518.00 32.49 230.45 6830.21 -1736.04 -1572.35 12.00 11.92 2.72 7.00 8041.09 53.28 233.98 7211.44 -1951.17 -1853.38 4.00 3.97 0.67 7.93 10893.17 53.28 233.98 8916.67 -3295.60 -3702.46 0.00 0.00 0.00 0.00 11200.61 86.90 230.00 9019.90 -3471.87 -3926.23 11.00 10.94 -1.29 -7.15 Y-11CT1 11627.97 86.79 182.91 9044.84 -3843.16 -4111.02 11.00 -0.03 -11.02 -91.50 12100.83 86.79 182.91 9071.33 -4314.66 -4135.02 0.00 0.00 0.00 0.00 12404.01 90.00 165.00 9079.90 -4614.77 -4103.22 6.00 1.06 -5.91 -80.17 Y-11 C T2 Sperry-Sun BP Planning Report ~~ ~~ Company; BP Amoco Dater 3/22/2005 Time: 10:37:34 Page: 2 Field: Prudhoe Bay Co-ordin~te(NE) Reference: WeIC Y-11B,Tnte North Site: PB Y Pad Vertical (TVD) Reference: 51:39 + 28.5 79.9 Well:. Y-11B SecHon(VS)Reference: Well (O.OON,O. OOE,155c00Azi) Wellpaths Plan Y-11 C Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO ` Target ; ft deg. deg ft ft ft deg/100ft deg/100ff deg/100ft deg 12807.92 96.10 141.50 9058.13 -4972.35 -3923.25 6.00 1.51 -5.82 -75.01 13079.95 96.10 141.50 9029.24 -5184.04 -3754.86 0.00 0.00 0.00 0.00 13255.60 90.00 138.00 9019.90 -5317.82 -3641.59 4.00 -3.47 -1.99 -150.06 Y-11C T3 13438.56 85.68 132.09 9026.80 -5447.12 -3512.51 4.00 -2.36 -3.23 -126.26 13704.86 85.68 132.09 9046.87 -5625.10 -3315.44 0.00 0.00 0.00 0.00 14049.14 90.00 119.00 9059.90 -5824.57 -3036.16 4.00 1.26 -3.80 -72.04 Y-11CT4 14473.01 94.18 102.55 9044.35 -5974.35 -2641.59 4.00 0.99 -3.88 -75.53 14687.25 94.18 102.55 9028.74 -6020.79 -2433.02 0.00 0.00 0.00 0.00 14792.61 90.00 102.00 9024.90 -6043.17 -2330.17 4.00 -3.97 -0.53 -172.45 Y-11C T5 14876.04 87.78 99.51 9026.51 -6058.74 -2248.23 4.00 -2.66 -2.99 -131.66 15738.79 87.78 99.51 9059.90 -6201.11 -1397.96 0.00 0.00 0.00 0.00 Y-11C T6 Survey MD Incl Azim TVD Sys TVD N/S E/W DLS MapN MapE Tool/Comute t ft deg deg ft ft ft ft deg/100ft ft ft 7498.00 30.11 229.91 6813.12 6733.22 -1729.39 -1564.37 0.00 5947057.36 642972.81 Start Dir 12/10 7500.00 30.34 229.97 6814.84 6734.94 -1730.04 -1565.14 12.00 5947056.70 642972.05 MWD+IFR+MS 7518.00 32.49 230.45 6830.21 6750.31 -1736.04 -1572.35 12.00 5947050.56 642964.96 Start Dir 4/100 7600.00 35.74 231.23 6898.09 6818.19 -1765.07 -1608.02 4.00 5947020.85 642929.86 MWD+IFR+MS 7700.00 39.71 232.02 6977.17 6897.27 -1803.03 -1655.99 4.00 5946981.98 642882.63 MWD+IFR+MS 7800.00 43.69 232.69 7051.82 6971.92 -1843.63 -1708.66 4.00 5946940.38 642830.76 MWD+IFR+MS 7900.00 47.66 233.27 7121.68 7041.78 -1886.68 -1765.78 4.00 5946896.24 642774.48 MWD+IFR+MS 8000.00 51.64 233.79 7186.40 7106.50 -1931.97 -1827.06 4.00 5946849.79 642714.08 MWD+IFR+MS 8041.09 53.28 233.98 7211.44 7131.54 -1951.17 -1853.38 4.00 5946830.09 642688.14 End Dir :8041 8100.00 53.28 233.98 7246.66 7166.76 -1978.94 -1891.57 0.00 5946801.59 642650.49 MWD+IFR+MS 8200.00 53.28 233.98 7306.45 7226.55 -2026.08 -1956.40 0.00 5946753.22 642586.58 MWD+IFR+MS 8300.00 53.28 233.98 7366.24 7286.34 -2073.22 -2021.24 0.00 5946704.85 642522.67 MWD+IFR+MS ^8400.00 53.28 233.98 7426.03 7346.13 -2120.36 -2086.07 0.00 5946656.48 642458.75 MWD+IFR+MS 8500.00 53.28 233.98 7485.81 7405.91 -2167.50 -2150.90 0.00 5946608.11 642394.84 MWD+IFR+MS 8600.00 53.28 233.98 7545.60 7465.70 -2214.64 -2215.73 0.00 5946559.74 642330.93 MWD+IFR+MS x8700.00 53.28 233.98 7605.39 7525.49 -2261.77 -2280.57 0.00 5946511.37 642267.02 MWD+IFR+MS 8800.00 53.28 233.98 7665.18 7585.28 -2308.91 -2345.40 0.00 5946463.00 642203.11 MWD+IFR+MS 8900.00 53.28 233.98 7724.97 7645.07 -2356.05 -2410.23 0.00 5946414.63 642139.20 MWD+IFR+MS 9000.00 53.28 233.98 7784.76 7704.86 -2403.19 -2475.06 0.00 5946366.26 642075.29 MWD+IFR+MS 9100.00 53.28 233.98 7844.55 7764.65 -2450.33 -2539.90 0.00 5946317.89 642011.38 MWD+IFR+MS 9200.00 53.28 233.98 7904.34 7824.44 -2497.47 -2604.73 0.00 5946269.52 641947.47 MWD+IFR+MS 9300.00 53.28 233.98 7964.13 7884.23 -2544.60 -2669.56 0.00 5946221.15 641883.56 MWD+IFR+MS 9400.00 53.28 233.98 8023.91 7944.01 -2591.74 -2734.40 0.00 5946172.78 641819.65 MWD+IFR+MS 9500.00 53.28 233.98 8083.70 8003.80 -2638.88 -2799.23 0.00 5946124.40 641755.74 MWD+IFR+MS 9600.00 53.28 233.98 8143.49 8063.59 -2686.02 -2864.06 0.00 5946076.03 641691.82 MWD+IFR+MS 9700.00 53.28 233.98 8203.28 8123.38 -2733.16 -2928.89 0.00 5946027.66 641627.91 MWD+IFR+MS 9800.00 53.28 233.98 8263.07 8183.17 -2780.30 -2993.73 0.00 5945979.29 641564.00 MWD+IFR+MS 9900.00 53.28 233.98 8322.86 8242.96 -2827.44 -3058.56 0.00 5945930.92 641500.09 MWD+IFR+MS 10000.00 53.28 233.98 8382.65 8302.75 -2874.57 -3123.39 0.00 5945882.55 641436.18 MWD+IFR+MS 10100.00 53.28 233.98 8442.44 8362.54 -2921.71 -3188.22 0.00 5945834.18 641372.27 MWD+IFR+MS 10200.00 53.28 233.98 8502.23 8422.33 -2968.85 -3253.06 0.00 5945785.81 641308.36 MWD+IFR+MS 10300.00 53.28 233.98 8562.01 8482.11 -3015.99 -3317.89 0.00 5945737.44 641244.45 MWD+IFR+MS 10400.00 53.28 233.98 8621.80 8541.90 -3063.13 -3382.72 0.00 5945689.07 641180.54 MWD+IFR+MS 10500.00 53.28 233.98 8681.59 8601.69 -3110.27 -3447.55 0.00 5945640.70 641116.63 MWD+IFR+MS 10600.00 53.28 233.98 8741.38 8661.48 -3157.40 -3512.39 0.00 5945592.33 641052.72 MWD+IFR+MS 10700.00 53.28 233.98 8801.17 8721.27 -3204.54 -3577.22 0.00 5945543.96 640988.81 MWD+IFR+MS 10800.00 53.28 233.98 8860.96 8781.06 -3251.68 -3642.05 0.00 5945495.59 640924.90 MWD+IFR+MS 10881.86 53.28 233.98 8909.90 8830.00 -3290.27 -3695.12 0.00 5945455.99 640872.58 7" 10893.17 53.28 233.98 8916.67 8836.77 -3295.60 -3702.46 0.00 5945450.52 640865.35 Start Dir 11/10 10900.00 54.03 233.86 8920.71 8840.81 -3298.84 -3706.90 11.00 5945447.19 640860.97 MWD+IFR+MS Sperry-Sun BP Planning Report Company: BP Amoco Date: 3/22/2005 Time: 10:37:34 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference:' W eIL Y-11 B, Tnie North Site: PB Y Pad Vertical (TVD) Reference: b1.39 + 28.579:9 WeQ: Y-1 1B' Sectio n (VS) Reference: Well (t).OON,O. OOE,155.OOAzi) Wellpathr Plan Y-11 G Survey Calculation Method: Minimum Curvature I)b: Oracle Survey Mb Incl Azim TVD Sys TVl) N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft ' deg/100ft ft ft 11000.00 64.95 232.38 8971.41 8891.51 -3350.51 -3775.67 11.00 5945394.21 640793.21 MWD+IFR+MS 11100.00 75.89 231.13 9004.87 8924.97 -3408.77 -3849.53 11.00 5945334.55 640720.49 MWD+IFR+MS 11200.00 86.83 230.01 9019.87 8939.97 -3471.48 -3925.77 11.00 5945270.40 640645.47 MWD+IFR+MS 11300.00 86.67 219.05 9025.49 8945.59 -3542.51 -3995.71 10.94 5945198.04 640576.91 MWD+IFR+MS 11400.00 86.56 208.03 9031.41 8951.51 -3625.58 -4050.79 11.00 5945113.94 640523.44 MWD+IFR+MS 11500.00 86.58 197.01 9037.41 8957.51 -3717.65 -4088.97 11.00 5945021.16 640487.04 MWD+IFR+MS 11600.00 86.73 186.00 9043.26 8963.36 -3815.32 -4108.85 11.00 5944923.13 640469.04 MWD+IFR+MS 11627.97 86.79 182.91 9044.84 8964.94 -3843.16 -4111.02 11.00 5944895.26 640467.41 End Dir :1162 11700.00 86.79 182.91 9048.88 8968.98 -3914.98 -4114.67 0.00 5944823.39 640465.13 MWD+IFR+MS 11800.00 86.79 182.91 9054.48 8974.58 X014.69 -4119.75 0.00 5944723.60 640461.97 MWD+IFR+MS 11900.00 86.79 182.91 9060.08 8980.18 -4114.41 -4124.83 0.00 5944623.82 640458.80 MWD+IFR+MS 12000.00 86.79 182.91 9065.69 8985.79 -4214.12 -4129.90 0.00 5944524.03 640455.64 MWD+IFR+MS 12100.00 86.79 182.91 9071.29 8991.39 -4313.84 -4134.98 0.00 5944424.25 640452.48 MWD+IFR+MS 12100.83 86.79 182.91 9071.33 8991.43 -4314.66 -4135.02 0.00 5944423.42 640452.46 Start Dir 6/100 12200.00 87.82 177.05 9076.00 8996.10 -4413.68 -4134.99 6.00 5944324.43 640454.39 MWD+IFR+MS 12300.00 88.88 171.14 9078.88 8998.98 -4513.06 -4124.71 6.00 5944225.27 640466.58 MWD+IFR+MS 12400.00 89.96 165.24 9079.90 9000.00 -4610.89 -4104.25 6.00 5944127.86 640488.91 MWD+IFR+MS 12404.01 90.00 165.00 9079.90 9000.00 -4614.77 -4103.22 6.00 5944124.00 640490.01 Y-11 C T2 12500.00 91.49 159.44 9078.65 8998.75 -4706.13 -4073.92 6.00 5944033.23 640521.06 MWD+IFR+MS 12600.00 93.02 153.63 9074.71 8994.81 -4797.75 -4034.15 6.00 5943942.40 640562.58 MWD+IFR+MS 12700.00 94.53 147.81 9068.13 8988.23 -4884.74 -3985.37 6.00 5943856.36 640613.01 MWD+IFR+MS 12800.00 95.98 141.96 9058.96 8979.06 -4966.16 -3928.13 6.00 5943776.06 640671.80 MWD+IFR+MS 12807.92 96.10 141.50 9058.13 8978.23 -4972.35 -3923.25 6.00 5943769.97 640676.80 End Dir :1280 12900.00 96.10 141.50 9048.35 8968.45 -5044.00 -3866.25 0.00 5943699.43 640735.16 MWD+IFR+MS 13000.00 96.10 141.50 9037.73 8957.83 -5121.82 -3804.35 0.00 5943622.82 640798.53 MWD+IFR+MS 13079.95 96.10 141.50 9029.24 8949.34 -5184.04 -3754.86 0.00 5943561.57 640849.20 Start Dir 4/100 13100.00 95.40 141.10 9027.23 8947.33 -5199.61 -3742.39 4.00 5943546.24 640861.97 MWD+IFR+MS 13200.00 91.93 139.10 9020.84 8940.94 -5276.15 -3678.39 4.00 5943470.95 640927.43 MWD+IFR+MS 13255.60 90.00 138.00 9019.90 8940.00 -5317.82 -3641.59 4.00 5943430.00 640965.02 Y-11 C T3 13300.00 88.95 136.57 9020.31 8940.41 -5350.43 -3611.47 4.00 5943397.97 640995.75 MWD+IFR+MS 13400.00 86.59 133.34 9024.20 8944.30 -5421.02 -3540.77 4.00 5943328.76 641067.79 MWD+IFR+MS 13438.56 85.68 132.09 9026.80 8946.90 -5447.12 -3512.51 4.00 5943303.21 641096.55 End Dir :1343 13500.00 85.68 132.09 9031.43 8951.53 -5488.18 -3467.04 0.00 5943263.03 641142.79 MWD+IFR+MS 13600.00 85.68 132.09 9038.97 8959.07 -5555.02 -3393.04 0.00 5943197.63 641218.05 MWD+IFR+MS 13700.00 85.68 132.09 9046.50 8966.60 -5621.85 -3319.04 0.00 5943132.23 641293.32 MWD+IFR+MS 13704.86 85.68 132.09 9046.87 8966.97 -5625.10 -3315.44 0.00 5943129.05 641296.98 Start Dir 4/100 13800.00 86.86 128.46 9053.06 8973.16 -5686.46 -3243.02 4.00 5943069.10 641370.56 MWD+IFR+MS 13900.00 88.11 124.66 9057.44 8977.54 -5745.96 -3162.79 4.00 5943011.16 641451.91 MWD+IFR+MS 14000.00 89.38 120.86 9059.63 8979.73 -5800.05 -3078.74 4.00 5942958.69 641536.98 MWD+IFR+MS 14049.14 90.00 119.00 9059.90 8980.00 -5824.57 -3036.16 4.00 5942935.00 641580.02 Y-11 C T4 14100.00 90.51 117.03 9059.67 8979.77 -5848.46 -2991.26 4.00 5942911.98 641625.36 MWD+IFR+MS 14200.00 91.50 113.16 9057.92 8978.02 -5890.85 -2900.73 4.00 5942871.33 641716.68 MWD+IFR+MS 14300.00 92.49 109.28 9054.43 8974.53 -5927.01 -2807.58 4.00 5942836.97 641810.50 MWD+IFR+MS 14400.00 93.47 105.39 9049.22 8969.32 -5956.76 -2712.27 4.00 5942809.06 641906.35 MWD+IFR+MS 14473.01 94.18 102.55 9044.35 8964.45 -5974.35 -2641.59 4.00 5942792.83 641977.35 End Dir :1447 14500.00 94.18 102.55 9042.38 8962.48 -5980.20 -2615.32 0.00 5942787.48 642003.74 MWD+IFR+MS 14600.00 94.18 102.55 9035.10 8955.20 -6001.88 -2517.97 0.00 5942767.68 642101.48 MWD+IFR+MS 14687.25 94.18 102.55 9028.74 8948.84 -6020.79 -2433.02 0.00 5942750.40 642186.76 Start Dir 4/100 14700.00 93.67 102.49 9027.87 8947.97 -6023.55 -2420.61 4.00 5942747.88 642199.22 MWD+IFR+MS 14792.61 90.00 102.00 9024.90 8945.00 -6043.17 -2330.17 4.00 5942730.00 642290.02 Y-11 C T5 14800.00 89.80 101.78 9024.91 8945.01 -6044.70 -2322.94 4.00 5942728.62 642297.28 MWD+IFR+MS 14876.04 87.78 99.51 9026.51 8946.61 -6058.74 -2248.23 4.00 5942716.02 642372.23 End Dir :1487 • Sperry-Sun BP Planning Report Company: BP Amoco Date: 3/22/2005 ' lime: 10:37:34 Page:` 4 'Field: Prudhoe Bay Co-ordinate(NE)Reference: Well: Y-11 B,.True North Site: PB Y Pad Vertical (TVD) Reference: 51.39 + 28.5 79:9 Well: Y-116 Section (VS) Reference: Well (Q.OON,O.OOE,155.OOAzi) Wellpath: Plan Y-11 G Survey Calculation Met6odt Minimum Curvature Db::Oracle Survey MD Tncl Azim TVD Sys TVI) N/S E/W DLS MapN MapE TooUComme t ft deg. deg ft ft ft ft .. deg/100ft ft' ft 14900.00 87.78 99.51 9027.44 8947.54 -6062.69 -2224.62 0.00 5942712.52 642395.92 MWD+IFR+MS 15000.00 87.78 99.51 9031.31 8951.41 -6079.19 -2126.06 0.00 5942697.91 642494.76 MWD+IFR+MS 15100.00 87.78 99.51 9035.18 8955.28 -6095.69 -2027.51 0.00 5942683.31 642593.61 MWD+IFR+MS 15200.00 87.78 99.51 9039.05 8959.15 -6112.20 -1928.96 0.00 5942668.70 642692.45 MWD+IFR+MS 15300.00 87.78 99.51 9042.92 8963.02 -6128.70 -1830.40 0.00 5942654.09 642791.29 MWD+IFR+MS 15400.00 87.78 99.51 9046.79 8966.89 -6145.20 -1731.85 0.00 5942639.49 642890.14 MWD+IFR+MS 15500.00 87.78 99.51 9050.66 8970.76 -6161.70 -1633.30 0.00 5942624.88 642988.98 MWD+IFR+MS 15600.00 87.78 99.51 9054.53 8974.63 -6178.20 -1534.75 0.00 5942610.28 643087.83 MWD+IFR+MS 15700.00 87.78 99.51 9058.40 8978.50 -6194.71 -1436.19 0.00 5942595.67 643186.67 MWD+IFR+MS 15738.00 87.78 99.51 9059.87 8979.97 -6200.98 -1398.74 0.00 5942590.12 643224.23 41/2" 15738.79 87.78 99.51 9059.90 8980.00 -6201.11 -1397.96 0.00 5942590.00 643225.01 Y-11 C T6 TREE = 6" CW WELLH D= GRAY ACTUATOR= OT1S KB. ELEV = 85.4' BF. ELEV = 51.4' KOP = 3050' Max Angie = 86 @ 10291' Datum MD = 9762' Datum TV D = 8800' SS SA NOTES= OLD P&A'D WELLBORE NOT SHOWN ^ -11 B ON THIS DIAGRAM BELOW THE 9-58" CSG. WINDOW 2021' I--14-1/2" HES 'X' NIP, ~=3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2660' Minimum ID = 3.725" @ 9429' 4-1/2" HES XN NIPPLE I TM/ TBR 6.31' POLISH BORE, ID = 5.25" 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 7" X 4-1/2" TM/ S-6 PKR/HGR ID = 3.878" 9439 F 9448' 9449' PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 82 @ 10000' Note' Refer to Production DB for historical nerf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 6 10000' -10080' O 10/16/95 2-3/4" 6 10110' -10130' O 10/16/95 2-3/4' 6 10330' -10410' O 10/16/95 2-3/4" 6 10430' -10450' O 10/16/95 2-3/4" 6 10580' -10680' O 10/16/95 9-5l8" CSG, 47#, L-80, ID = 8.681" I~ 9420' ~~ I-I 10782' ( 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 12/18/80 BIXBY ORIGINAL COMPLETION 11/01/01 WB/TP SURF LOC CORRECTION 10/16/95 MDO SIDETRACK COMPLETION 02/24/02 AF/KAK WELL NAME CORRECTION 03/04/01 SIS-QAA CONVERTED TO CANVAS 03/12/01 SIS-MD FINAL 07/03/01 CH/KAK CORRECTIONS PRUDHOE BAY UNIT WELL: Y-11BP61 PERMIT No: 195-1110 API No: 50-029-20513-70 SEC 33, T11 N, R13E, .1433' SNL & 3'I 3' WEL BP 6cploration (Alaska) 8329' ~ 9-5/8" X 7" BKR ZXP PKR W/ HMC HGR, ID = 6.375" 9374' 4-1/2" HES X NIP, ID = 3.813" 9385' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9408' 4-1/2" HES X NIP, ID = 3.813" 9429' 4-1/2" HES XN NIP, ID = 3.725" 9449' 4-1/2" WLEG, ID = 3.958" 9452' ELMD TT LOGGED 11/26/95 CAM FROM SWS TRACTOR TOOL LOST IN V ICINITY OF XN NIP ON 06/18/99. (SEE DRAWING IN WELL FILE) ' 9-5l8" MILLOUT SECTION WINDOW 8604' - 8654' I 9610' 7" LNR, 26#, L80, NSCC, .0383 bpf, ID = 6.276" r Y-11 Ci ro osed C letion p p TREE = 6" CNV 2200` X-Nip ID = 3.813 2660` 13-3/8", 72#, L-80 4-1/2", 12.6#, L-80, TCII 7350` 7500` 7530` Cut 7600` 8329` 7350` 9-5/8" X 7" Baker HMC Liner Hanger with ZXP and C-2 running tool Top of window approx. 7500` 10673' - 7 X 41/2" Baker S-3 Packer 10 3 ` - 7" X 5" XO to 4-1/2" Baker Flex-Lock Liner Hanger wit ZXP & C-2 running tool ~, 10882` - 7", 26#, L-80, BTC-M 4-1 /2", 12.6#, L-80, I BT-M Top of 7" Liner 8604` 9-5/8", 47#, L-80 9350` ~ Top of P&A Cement 9610`/ - ~• ~~ L 7" 29#, L-80 10869` 4.5", 12.6#, L-80 _n • ~ s WELLHEAD = GRAY ACTUATOR = OTIS KB. E1EV = 85.4' BF. E1.E1/ = 51.4' KOP = 3050' Max Angle = 96.1@12807' Datum MD = Datum ND = Tubing Tail: -10` Pup Joint -X Nipple (3.813) -20' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 15738` Date Rev By Comments PRUDHOE BAY UNIT 04-14-05 MJM Proposed Completion WELL: Y 11 Ci 04-20-05 MJM Cement P&A to 9350`MD API N0:50-029-20513-?? Permit NO: GPB Rotary Drilling -''~ a 22G0` ''2660' 1 7350` 7500` ~: ~r ...r ~ ~rc~ ~a~e~ ~~~ ~~c~n ~ ~ X-Nip ID = 3.1313 4-112", 12.6#, L-80, TC11 ~:w~~ ~t i~ra~ = r~~,a~, ;~~:Ti_~^, T. ~~=. _. ' iii BF c1t~1 ,1 1' ~~~I' - _ .~~,~0' ..u n i f ~.J ____- _ - . _ _-- -- - -- Sturn (~:J 735Q' 9-5/8" X 7" Baker HMC Liner Hanger -x Nipple (3.R13"> with I~XP and C-2 running tool -~o' Pup Joint j -XN Nipple (3J~5") -10' Pup Joint -WL~G ~ Top of window approx. 7500` 10673' - 7 X 4-112" Baker S-3 Packer i 10782`:-7" X 5"X~ to 4-112" Baker Fiex-Lock Liner Hanger ~ ~ ~^rith ZXP & C-2 running tool 7530` - ,,, Cut ~7t~00' ~ 10882` - 7", 26#, L-80, BTC-Pvl 11,000` - ~-112" X Nipple (3.813" ID) 8329` ~~ ~ 4-1/2", 12.6#x, L-80, IBT-M Top of 7'` Liner \ ;~ 8604` 9-5/8", 47#, L-SO 9350' Top of P&A Cer~rent 15733' i 9610. 7", 29#, L-80 ', 10869' 4.5", 12.6#, L-80 gate Rem ~y ~--~- Commer~t~ ~ - ~ PRl.~~3I-~b~~ 5,,~`f L7~lT c~~ i ~ n~ ~~.~„~r E -~~,~~,~<< c~,~„ ~c~t;on tlt/E~,$~,,: Y-1 °l ~i o~ o os ___ ti~_~r~,9 ,~rr,~ ,r ~~rn tc~ ~~tio~ti~rr~ ___..-----_.-__.~. -- ~'a~'! N(~:~~-0~~-2fl513-?? 1a4~~tnit NQ: ~ _. .__ _-- ~P~ rotary Drilling ~~~ -10' Pup Joirat -X Nipple (3.513") -20' Pup Joint -Packer -2~J' Pup .Join' ' • ~ TERRIE L RUBBLE; ss-sii252 234 BP EXPLORATION AK LNC "Mastercard Check" PO BOX 196612 MB 7-5 AN£HORAGE, AK 99519-$612 oaTE ~®~`"~S PAY TO THE - - ~/ $. ~( j( / ~ ~Q ORDER OF /~'J~ vv t l.J~ , First National' Bank Alaska Anchorage AK 99501 MEMO ~ : ~ ~ ~ , ~:~25200060~:99L4~~~6227~~~L55611' 0234 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# " " CHECK WHAT ADD-ONS CLUE APPLIES (OPTIONS) ent of lb LTI ore segm ermit is for a new wel The MU p LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as ! last two (2) digits a function of .the original API number stated i are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (pj~ records, data and logs acquired for the pilot ~ ~ hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - i 70/80) from records, data and logs acquired for well (name on permit). t to full b SPACING ` jec The permit is approved su EXCEPTION compliance with 20 AAC 25.055. Approval to ~ perforate and produce/infect is contingent ~ upon issuance of a conservation order approving a spacing exception. ~ i Com an Name assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL-640150 _ Well Name: PRUDHOE BAY UNIT Y-11C -Program SER _ Well bore seg PTD#:2051640 Company BP EXPLORATION ALASKA) INC Initial Class/Type SER I WAGIN GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 Permit.fee attached - - - Yes _ - - - - - - - 2 Lease number appropriate - - - - Yes - - - ~ 1 3 Uniquewell_nameandnumber________________--__--_--__ _____-.--Yes,----- .--------------------------_-- 4 Well located in a-defined-pool___________________________- --..-__Yes--_.-- ____ - - 5 Well located proper distance from drilling unit_boundary- _ Yes - - . - - . . - -- - 6 Well located pr_operdistancefromotherwells_____________________ _____- -Yes,_____ _--_--_---________--________-------_____-___________--_-__-__-_-_--_ 7 Sufficient acreageayail_ablein-drilling unit____------------------ ------ Yes--_.-- __________-__________--____-___----_-__ - - 8 If deviated, is-wellboreplat_included------------------------- ------ Yes--- -- -____ - - - - 9 Operator only affected party_-_____-__-__---------- ---- Yes_--_-- --- - -- - 10 Ope[atorhas-appropriate_bondinforce ------- - -- ---- - --- ----Yes-- -- - --- -------- -- - -- -- ---- --- --- --- -- -------- -- - 11 Permit-can be issued withoutconserYationorder____-_____________ _________Yes___--_ _----___-_--__--_-_-_______--_______-._______--.__--___-.._--- Appr Date 12 Permit. can be issued without administ[alive-appr_oval_______________ _______ _Yes-_____ _---- __-______-__.--._--___---__-_____-.--_____ RPC 11!1/2005 13 Can permit be approved before 15-day wait Yes 14 Well ocated within area and_strata authorized by Injection Orde[ # (put-10# in-co mments)_(Fpr. Yes _ _ _ _ _ _ _ AIQ3 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells within 114-mile area of review identified (For sevice well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ - _ - _ Y-21, Y-21A, Y _29, Y-29A_ . - - - _ _ _ _ _ _ _ _ ... _ _ - _ _ - - _ _ . 16 Pre-produced injector. duration ofpre-production Less than- 3 months-(Forservice well-only) NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ --------------- 17 ACMP_Fintling of Consistency-has been issued_forthis project- . - - - _ - - _ . N_A- - - - - - - -- Engineering 18 Conductor string.P-rovided - - - ~ - - - 19 Surface casingprotects all-known- U$DWs - NA - - - - - - - - 20 CMT_vol_adequate-tocirculate_onconductor_&surf-csg___________ _________ NA_____-- --_--______---_--___ 21 CMT_voladequate_totie-in long string to surfcs-g-.---------------- - --_- NA_----. ------ ------------- ---- ----- ------.--------,--------------___ -- 22 CMT-will coverall known-productive horizons- Yes - Adequate excess. 23 Casing designs adequate for-C,T,B&-permafrost__________________ _ ______ Yes-__- _ ____---.--_--_______- -_.._____._-...____-_--_._-___--------________ 24 Adequatelan_kage-or reserve pit---------------------------- --- Yes_____ -Nabors-2ES,__----.._____- 25 Ifa_re-drill,has-a-10-403forabandonment been approved_----------- ---------Yes___--- -"._._______-__.--______-----____- __--_--____--_.-_-_____-----.-._ _ 26 Adequatewellboreseparation_proposed.---------~ -- --- - - - -- --Yes --- --- - ~--------.._ ---- -- - --- -- -- ---- -- -- ------ -- 27 If_diverterrequired,doesitmeetregulations______________________ ________ NA_____ -Sidetrack.---_____--______--__-___ -__-----_____-_,_-________----______ Appr Date X 28 Drillingfiuid.programschematic&equiplistadequate_ _--.--_----- -------- Yes_-_-.- -Max MW-11.1-ppg.__________-____---_-_____.---____-_---_-.-__-- WGA 111212005 29 BQPEs,.dotheymeetregulation____________________________ _______-Yes--____ __------__________---__-_____-_._ - - 30 BOPE_pressratingappropriate;testto-(pu_tpsigincomments)___________ _________Yes__--- -Test to 4000 psi.-M$P3386p&i,___--_--________.-_-____-_-_--_--________-_-_- - 31 Choke-manifold oomplies w/APL RP-5$ GMay 84) - - - - Yes - - 32 Work willoccurwithoutoperationshutdown______________________ _________Yes-____ _------______-_----_.__-____-__--__-__ _--.________---_________-_- - 33 Is presence-of H2S gas. probable -Yes 120-Ppm onpad.- - - - - - - - - - - - 34 Mechanical condition of wells within AOR ver(fied (For service well only) Yes - - - . -Records reviewed of all AOR wells. _ - _ - . - _ - Geology 35 Permit can be issued wlohvdrogen-sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - - No_ _ _ _ - _ _ - - . - _ - _ _ _ _ _ _ 36 Data-presentedon_potential overpressure zones____------- ------ ------- -NA-_--.__ ___--.___-________-.._ -------- Appr Date 37 Seismic_analysis ofshallow gas-zones- - . _ _ - - NA_ - - RPC 11/1/2005 38 Seabed condition survey_(if off-shore) - - - _ - _ _ _ - _ - - - _ _ - N_A_ _ - 39 Contact nam_elphone for.weekly progress_reports [exploratory only]- NA- - Geologic Engineering Public Commissioner: Date: Commissioner: Date Co er Date ~~~,.; I~ y as-- 1~ ,~,~~,. • • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efforl has been made io chronologically organize this category of information. i Y11CO12122005SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 02 14:17:55 2007 Reel Header Service name .............LISTPE Date . ...................07/08/02 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/08/02 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments ............., ..STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 1 W-0004064799 C. COCHRAN D. MASKELL MWD RUN 5 W-0004064799 J. PANTER J. RALL scientific Technical services scientific Technical Services Y-11C 500292051303 BP Exploration (Alaska) Sperry Drilling Services 02-AUG-07 MWD RUN 2 w-0004064799 C. COCHRAN D. MASKELL MWD RUN 6 w-0004064799 J. PANTER J. RALL 33 11N 13E 1433 313 Page 1 MWD RUN 3 W-0004064799 C. COCHRAN D. MASKELL MWD RUN 8 W-0004064799 J. PANTER J. RALL uz.C 86S - ~~Y '~ ~53~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Y11CO121220055SN.txt 79.90 51.39 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 7488.0 2ND STRING 6.125 7.000 10900.0 3RD STRING PRODUCTION STRING REMARKS: C 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 WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE Y-11A WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 7488'MD/6804'TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. ONLY SROP DATA ARE PRESENTED FOR MWD RUN 1. 4. MWD RUN 2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. UPHOLE MAD SGRC TIE-IN DATA WERE ACQUIRED WHILE POOH AFTER MWD RUNS 2 AND 5. THESE DATA WERE MERGED WITH RUN 2 MWD DATA. 5. MWD RUNS 3,5,6,8 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER OPEN-HOLE GAMMA RAY LOG RUN IN Y-11A ON 7 DECEMBER 1980. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 20 JUNE 2007, QUOTING AUTHORIZA- TION FROM COLE ABEL (BP GEOSCIENTIST). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THE SHIFTED SGRC LOG IS CONSIDERED THE PDC LOG FOR Y-11C. 7. MWD RUNS 1-3,5,6,8 REPRESENT WELL Y-11C WITH API#: 50-029-20513-03. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15868'MD/9060'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW Page 2 • Y11CO121220055SN.txt 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.......07/08/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7070.5 15820.5 ROP 7495.0 15875.5 RPD 10887.0 15827.0 RPx 10887.0 15827.0 RPM 10887.0 15827.0 RPS 10887.0 15827.0 FET 10887.0 15827.0 BASELINE CURVE FO R SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 7070.5 7064.5 7080.0 7074.0 7082.0 7076.5 7089.0 7082.5 7091.0 7085.0 7095.0 7088.0 7097.0 7090.0 7111.0 7103.0 7115.0 7108.5 7124.5 7118.0 7133.0 7124.5 7137.5 7128.5 7143.5 7135.5 7162.0 7153.0 7166.0 7157.5 7177.5 7168.5 7207.5 7198.0 7216.5 7206.5 7224.0 7214.0 7319.5 7308.5 7337.5 7327.5 7420.0 7411.0 7437.5 7428.5 Page 3 • Y11C012122005SSN.txt 7454.0 7446.5 7460.5 7452.0 7474.0 7468.0 7497.0 7490.0 15875.5 15868.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 7488.0 7517.0 MWD 2 7517.0 10900.0 MwD 3 10900.0 11507.0 MwD 5 11507.0 13449.0 MwD 6 13449.0 14870.0 MwD 8 14870.0 15868.5 REMARKS: MERGED MAIN PASS. 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 HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7070.5 15875.5 11473 17611 7070.5 15875.5 RPD MWD OHMM 0.67 2000 17.6881 9881 10887 15827 RPM MWD OHMM 0.17 2000 14.6357 9881 10887 15827 RPS MWD OHMM 0.93 2000 12.7771 9881 10887 15827 RPX MWD OHMM 0.78 1844.45 10.1896 9881 10887 15827 FET MWD HOUR 0.47 100.94 5.79522 9881 10887 15827 GR MWD API 19.14 584.02 86.031 17501 7070.5 15820.5 ROP MWD FT/H 0.33 4016.1 83.8547 16762 7495 15875.5 First Reading For Entire File..........7070.5 Last Reading For Entire File...........15875. File Trailer Service name... .......STSLIB.001 Service sub Level Name... Page 4 Y11C012122005SSN.txt Version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 7488.0 7517.0 LOG HEADER DATA DATE LOGGED: 19-Nov-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7517.0 TOP LOG INTERVAL (FT): 7488.0 BOTTOM LOG INTERVAL (FT): 7517.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 7488.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 11.10 MUD VISCOSITY (S): 55.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 950 FLUID LOSS (C3): 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O Page 5 • • Y11C0121220055SN.txt MUD AT MAX CIRCULATING TERMPERATURE: .000 123.0 MUD FILTRATE AT MT: .000 .0 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 Loping Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7488 7517 7502.5 59 7488 7517 ROP MWDO10 FT/H 1 12 3.33051 59 7488 7517 First Reading For Entire File..........7488 Last Reading For Entire File...........7517 File Trailer Service name... .......sTSLI6.002 service Sub Level Name.., version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSL2B.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type ................Lo Page 6 ~- Y11C01212200555N.txt Previous File Name.......STSL26.002 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 7064.5 10870.0 ROP 7517.5. 10900.0 LOG HEADER DATA DATE LOGGED: 24-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10900.0 TOP LOG INTERVAL (FT): 7517.0 BOTTOM LOG INTERVAL (FT): 10900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.7 MAXIMUM ANGLE: 55.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 622535 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 7488.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 11.10 MUD VISCOSITY (S): 46.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 1150 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 178.2 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 7 • Yl1CO12122005SSN.txt Data Format specification Record. Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value........... .........-999 Depth. Units. .. .. ..... Datum Specification Block sub-type...0 Name service Order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7064.5 10900 8982.25 7672 7064.5 10900 GR MWD020 API 36.01 384.6 133.73 7612 7064.5 10$70 ROP MWD020 FT/H 0.33 4016.1 95.4669 6766 7517.5 10900 First Reading For Entire File..........7064.5 Last Reading For Entire File...........10900 File Trailer service name... .......sTSLI6.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSL2B.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10870.5 11455.5 Page 8 • Y11CO12122005SSN.txt RPD 10880.0 11462.5 RPM 10880.0 11462.5 RPX 10880.0 11462.5 RPS 10880.0 11462.5 FET 10880.0 11462.5 RoP 10900.5 11507.0 LOG HEADER DATA DATE LOGGED: 27-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11507.0 TOP LOG INTERVAL (FT): 10900.0 BOTTOM LOG INTERVAL (FT): 11507.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 54.1 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10900.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (5): 51.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): 7.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.150 69.0 MUD AT MAX CIRCULATING TER MPERATURE: .420 199.0 MUD FILTRATE AT MT: 1.450 69.0 MUD CAKE AT MT: 1.350 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing .....................60 .lIN Page 9 • Y11C012122005SSN.txt Max frames per record ..... .. ......undefined Absent value ... ........... .. ......-999 Depth units. .. . . ..... Datum Specifica tion Block sub-type...0 Name service order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MwD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MwD030 HOUR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MwD030 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10870.5 11507 11188.8 1274 10870.5 11507 RPD MWD030 OHMM 0.67 2000 103.728 1166 10880 11462.5 RPM MwD030 OHMM 0.17 2000 79.5437 1166 10880 11462.5 RPS MWD030 OHMM 0.93 2000 66.2157 1166 10880 11462.5 RPX MwD030 OHMM 0.78 1844.45 48.4404 1166 10880 11462.5 FET MWD030 HOUR 0.47 74.77 4.74389 1166 10880 11462.5 GR MWD030 API 19.6 584.02 98.651 1171 10870.5 11455.5 ROP MWD030 FT/H 1.11 190.18 70.9094 1214 10900.5 11507 First Reading For Entire File..........10870.5 Last Reading For Entire File...........11507 File Trailer Service name... .......STSLIB.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/08/02 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.......07/08/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.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 Page 10 U Y11C012122005SSN.txt FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11456.0 13393.5 RPS 11463.0 13400.5 FET 11463.0 13400.5 RPM 11463.0 13400.5 RPX 11463.0 13400.5 RPD 11463.0 13400.5 ROP 11507.5 13449.0 LOG HEADER DATA DATE LOGGED: 04-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13449.0 TOP LOG INTERVAL (FT): 11507.0 BOTTOM LOG INTERVAL (FT): 13449.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10900.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 45.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 37000 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .120 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 176.0 MUD FILTRATE AT MT: .140 70.0 MUD CAKE AT MT: .170 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Dat a Format Specification Record Data Record Type... ........ ..0 Data specification Block Type,.. ..0 Logging Direction ............... ..Down Page 11 • • Y11C012122005SSN.txt 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 °HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11456 13449 12452.5 3987 11456 13449 RPD MwD050 OHMM 3.15 15.03 6.65187 3876 11463 13400.5 RPM MwD050 OHMM 2.88 16.52 6.44585 3876 11463 13400.5 RPS MWD050 OHMM 2.69 18.11 6.19422 3876 11463 13400.5 RPX MWD050 OHMM 2.45 15.94 5.47678 3876 11463 13400.5 FET MWD050 HOUR 0.47 98.96 3.69297 3876 11463 13400.5 GR MwD050 API 19..14 189.19 41.3638 3876 11456 13393.5. ROP MWD050 FT/H 0.61 505.51 105.749 3884 11507.5 13449 First Reading For Entire File.. .........11456 Last Reading For Entire File...........13449 File. Trailer Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.005 comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. Page 12 • Y11C0121220055SN.txt BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13394.0 FET 13401.0 RPX 13401.0 RPS 13401.0 RPM 13401.0 RPD 13401.0 ROP 13449.5 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 14815.5 14823.0 14823.0 14823.0 14823.0 14823.0 14870.0 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: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Page 13 08-DEC-05 Incite 66.37 Memory 14870.0 13.449.0 14870.0 84.9 98.2 TOOL NUMBER 156435 153663 6.125 10900.0 Lignosulfanate 8.80 52.0 9.1 30000 5.2 .130. 68.0 .050 192.0 .210 68.0 .300 68.0 • • Y11C012122005SSN.txt Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD 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 HOUR 4 1 68 20 6 GR MwD060 API 4 1 68 24 7 ROP MwD060 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 13394 14870 14132 2953 13394 14870 RPD MwD060 OHMM 1.68 11.26 5.75613 2845 13401 14823 RPM MWD060 OHMM 1.56 12.24 5.56151 2845 13401 14823 RPS MWD060 OHMM 1.45 11.97 5.23506 2845 13401 14823 RPX MWD060 OHMM 1.25 8.93 4.82419 2845 13401 14823 FET MwD060 HOUR 0.52 100.94 9.37563 2845 13401 14823 GR MwD060 API 20.58 167.9 44.8885 2844 13394 14815.5 ROP MWD060 FT/H 0.48 347.06 56.0848 2842 13449.5 14870 First Reading For Entire File..........13394 Last Reading For Entire File...........14870 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.006 Comment Record FILE HEADER Page 14 • • Yl1CO1212200555N.txt FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14816.0 15813.5 RPX 14823.5 15820.0 RPD 14823.5 15820.0 FET 14823.5 15820.0 RPM 14823.5 15820.0 RPS 14823.5 15820.0 RoP 14870.5 15868.5 LOG HEADER DATA DATE LOGGED: 12-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 15868.0 TOP LOG INTERVAL (FT): 14870.0 BOTTOM LOG INTERVAL (FT): 15868.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.2 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10900.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 52.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .310 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .120 189.0 MUD FILTRATE AT MT: .270 70.0 MUD CAKE AT MT: .330 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 15 Y11C012122005SSN.txt 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 MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MwD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14816 15868.5 15342.3 2106 14816 15868.5 RPD MWD080 OHMM 1.38 11.28 5.8526 1994 14823.5 15820 RPM MWD080 OHMM 1.16 12.05 5.54706 1994 14823.5 15820 RPS MWD080 OHMM 1.07 10.18 5.08526 1994 14823.5 15820 RPX MWD080 OHMM 0.97 9.73 4.63854 1994 14823.5 15820 FET MWD080 HOUR 0.91 70.25 5.38796 1994 14823.5 15820 GR MWD080 API 22.12 159.73 42.1079 1996 14816 15813.5 ROP MWD080 FT/H 8.64 494.19 51.6974 1997 14870.5 15868.5 First Reading For Entire File..........14816 Last Reading For Entire File...........15868 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/08/02 origin ...................sTS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Page 16 scientific Technical Services Y11CO12122005SSN.txt Reel Trailer Service name .............LiSTPE Date . ...................07/08/02 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File writing Library. Scientific Technical Services Page 17
