Alaska Logo
Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
Loading...
HomeMy WebLinkAbout202-031�ytt 202031 Up Date: 3/28/2019 30 52 9 Transmittal Number: 93660 0 '6E EIVED BPXA WELL DATA TRANSMITTAL MAN Z 9 X�20�19+ Enclosed is one disc containing the information listed below. A O G V V If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall&bD.com. SW Name I API Date Com an Descri tion 03-09 1500292036200 3/27/2019 BPXA COMPOSITED GYROSCOPIC SURVEY X-09 1500292045500 3/6/2019 BPXA OMPOSITED GYROSCOPIC SURVEY IX -09A 1500292045501 3/6/2019 BPXA OMPOSITED GYROSCOPIC SURVEY X -09B 500292045502 3/6/2019 BPXA OMPOSITED GYROSCOPIC SURVEY Please Sign andR-et-ulln, one co of this transmittal to. GANCPDC9bp365 omnicrosoftcom Thank you, JWer Xendaff Subsurface Information Management Alaska Oil & Gas Conservation Commission Department of Natural Resources ConocoPhillips Alaska, Inc. ExxonMobil, Alaska Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, September 11, 2017 5:55 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC1 Field O&M IL; AK, OPS GC3 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Boman,Wade; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer X-09B (PTD#2020310) OA over NOL- OA Repressurization Rate Manageable by Bleeds All, Producer X-09B(PTD#2020310)was reported to have sustained outer annulus pressure above NOL. This well just finished diagnostics(OART outer annulus repressurization test)on 9/9/17 and on investigation this well is still OPERABLE, subject to maintaining NOL's by manageable bleeds. The Well Integrity team will continue to monitor the well to assess well barriers. Please report any NOL excursions. Plan Forward/Work Completed: 1. Downhole Diagnostics:Thermal cycle well while performing OA repressurization test-Complete 2. Wellhead: Positive Pressure Packoff Test—Inner Casing/energize secondary seals -Pass 3. Well Integrity Engineer:Additional diagnostics as required Please reply if in conflict with proposed plan, Thanks, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 SCANNED HP 1 2 2U Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, September 1, 2017 12:41 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Field O&M TL;AK, OPS GC3 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Boman,Wade; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Tempel, Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer X-09B (PTD#2020310) Sustained outer annulus pressure above NOL Attachments: X-09B.pdf All, Producer X-09B (PTD#2020310)was reported to have sustained outer annulus pressure above NOL on 8/31/17. The pressures were reported to be TBG/IA/OA= 360/1810/1030psi. The well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Downhole Diagnostics:Thermal cycle well while performing OA repressurization test 2. Wellhead: Positive Pressure Packoff Test—Inner Casing/energize secondary seals 3. Well Integrity Engineer:Additional diagnostics as required Please reply if in conflict with proposed plan, Joshua Stephens Well Integrity Engineer SCANP ZQ'! Office: 907-659-8110 ate" Cell: 907-341-9068 1rro 1 Irr"-'e Project Well History File Cov~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. 40d.- 03 L Well History File Identifier Organizing {done} RESCAN o Two-Sided """1111111111111 DIGITAL DATA / Diskettes, No. ~ o Rescan Needed '" 1111111111 111111 OVERSIZED (Scannable) 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: o Maps: o Other, Norrype o Other items scannable by large scanner OVERSIZED (Non-Scannable) NOTES: o Logs of various kinds BY: ~~eINDY o Other DATE: VV(;f 1111111111111111111 DATE4/Bi./1; ~ + ~ = TOTAL PAGES 60 DATE#lÓlfl~ vvr£ BY: BEVERLY ROBIN VINCENT SHERYL~INDY Project Proofing BY: .~ ~-'-ÐINDY Scanning Preparation -L x 30 = 30 Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: s, ~ ~AGE COUNT MATCHES NUMBER IN SCANNING PREPARATIO':kL YES BY: IJJÛ.t DATE: (~Ø~SI Stage ;"q, ~F NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUNL' /YES B': íV BEVERLY ROBIN VINCENT SHERYL MAR~ WINDY DATEO ¿f.~/Ð+ IS! (SCANNING ~]:PLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS ï i7/ ( DUE TO QUALITY . GRAYSCALE OR COLOR IMAGES) NO 1111111111111111111 ReScanned (i¡¡dill/dual p,Tq~ (spod,rl ,1t!O!Hionj5cð"f)i!lq cnmplntod) 1111111111111111111 RESCANNED B~< BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: 151 General Notes or Comments about this file: Quality Checked (done) 1111111111111111111 1211 Ol02Rev3NOTScanned. wpd · ...-..: ·:·'>"':T"} ; ·t, j ;'~:3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn. : Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13,2006 RE: MWD Formation Evaluation Logs: X-08A, X-09B, X-31 L1 & Z-llA. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 X-08A: c903 - / I'? tf t4¿/L/9 Digital Log Images: 50-029-20463-01 1 CD Rom X-09B: {JD d -031 tt: 14L/L/~ Digital Log Images: 50-029-20455-02 1 CD Rom X-31 Ll: ;;08- - 6"7- 3 "it l'tft./'-It-j Digital Log Images: 50-029-20435-60 1 CD Rom Z-llA: QD~ -D3 ( .sf 1 / /L/L/j- Digital Log Images: 50-029-22053-01 1 CD Rom SCANNED FFB {} 1 2007 :) e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corum. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 dOd-DBI February 17,2006 1'~'1~ \ RE: MWD Formation Evaluation Logs X-09B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 X-09B: LAS Data & Digital Log Images: 50-029-20455-02 1 CD Rom f' tÎJ: ~ :>/ g'ðfoCt . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFìche\CvrPgs _ Inserts\Microfilm _ Marker.doc ~... v'  tj Ij \,{ DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 ~ >J,u.,¿ J~~~~Á- API No. 50-029-20455-02-00 BP EXPLORATION (ALASKA) INC Operator Well Name/No. PRUDHOE BAY UNIT X-09B 2020310 Permit to Dri UIC N 1-01L Current Status 1-01L Completion Status -' 3/26/2002 Completion Date ./" 9023 TVD 4417 ~ MD REQUIRED INFORMATION ,-Ne-' Y ~ L.,/' Master Well Data Maint Directional Survey (data taken from Logs Portion of No Samples No Mud Log DATA INFORMATION Types Electric or Other Logs Run: Well Log Information j Electr Dataset Number 11340 Log/ Data Type Õ -l I Comments ROP, DGR, EWR ROP, DGR, EWR OH CH Received - - ~¡¡se \ 12/6/2002 Ca I 12/6/2002 \ se ~""'-- C se( se, nterval Stop 14345 14345 14417 14417 14417 Start 9950 9950 9990 0024 0024 Run No 1 1 1 Log Log Scale Media 25 25 Name 11750 11750 11750 Digital Med/Frmt D Rpt ED t·g- Asc ED c... Ð""'" Pdf ED '- D- Pdf Sample Set Number Interval Stop Well Cores/Samples Information: Comments Received Sent Start Name ADDITIONAL INFORMATION Well Cored? Y fro ) (lyN QN Daily History Received? Formation Tops , Y I N '(l.bI.---' Chips Received? Analysis Received? Comments: ~MV{ Date: Compliance Reviewed By: ,.;""""., ,-:;, (}VO d. - D?:;; J WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas ConselVation Corom, Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 09, 2003 RE: MWD Formation Evaluation Logs: X-09B, AK-MW-22045 X-09B: Digital Log Images 50-029-20455-02 1 CD Rom t I,'SD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed ~ &~=- Date: (c; t IlP03 RECEIVED MAY 13 2003 Alaska Or¡ & Gas Cons. Commiøeton Anchorage . . ¿;; 0ë3 -03 / 1/840 ~ WELL WG TRANSMITTAL To: State.of Alaska Alaska Oil and Gas C.onservation Corom. Attn.: Lisa Weépie , 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 03, 2002 RE: MWD Formation Evaluation Logs X-09B, AK-MW-22045 1 LDWG formatted Disc with verification listing. ~I#: 50-029-20455-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF TIm TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Expl.oration (Alaska) Inc. Petro- T echnica1 Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~~ RECEIVED DEC 06 2002 Alaska Œi & Gas Cons. Commission Anchorage ·~ ,~, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well !mail o Gas o Suspended o Abandoned o Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-031 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20455-02 4. Location of well at surface lOCA\'Ø&$ ç·""-:~7~~·:'-~-"-' 9. Unit or Lease Name 453' SNL, 372' WEL, SEC. 07, T10N, R14E, UM ',¡r"p, '''¡10f1& . I .?~. ;)~~ Y7 Prudhoe Bay Unit At top of productive interval ¡ ~~it ' 704' SNL, 2844' EWL, SEC. 17, T10N, R14E, UM ¡ '2£...1) Su -c:;:-; ,;;:: I 10. Well Number At total depth ! v~W AI 1 ß.H.~~, l X-09B 2827' SNL, 3167' EWL, SEC. 17, T10N, R14E, UM ~,~'>. 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 68.78' ADL 047475 12. Date Spudded 113. Date T.D. Reached 114. Date Camp., Susp., or Aband. ì 15. Water depth, if offshore 16. No. of Completions 3/15/2002 3/23/2002 3/26/2002 N/A MSL One 17. Total Depth (MD+TVD)r 18. Plug Back Depth (MD+TVD)r 19. Directional Survey r 20. Depth where SSSV se~121. Thickness of Permafrost 14417 9023 FT 14417 9023 FT !m Yes 0 No (Nipple) 2215' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" X 30" Surface 110' 36" 8.5 cu vds Concrete 13-3/8" 72# L-80 Surface 2671' 17-1/2" 3720 cu ft Permafrost 9-5/8" 47# L-80 Surface 9991' 12-1/4" 1689 cu ft Class 'G' 130 cu ft PF 7" 26# L-80 9801' 11792' 8-1/2" 464 cu ft Class 'G' 4-1/2" 12.6# L-80 11634' 14417' 6-1/8" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 11649' 11592' MD TVD MD TVD 11782'-11814' 8851' - 8869' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. 12089' - 12750' 8950' - 8991' 13478' - 14376' 9002' - 9024' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 151 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 29, 2002 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BSL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 4/29/2002 6 TEST PERIOD 4642 10131 3664 1300 2182 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChIRS.," ~">Oj n 11-..... ~. ,," ¡¡ I; - ! '\ L\ ~ ,',,,, J No core samples were taken. n I t\ ,", I Î \~i ¡ 11 ....- _oj ~{~~as!'a 011 &. Cons. LUnìÜH~~iU¡ AnGhora~e Form 10-407 Rev. 07-01-80 B 5 FL MAY -.J I 2002 f Submit In Duplicate R DM B ~ ~ ~ " \ 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 11781' 8851' Shublik 11814' 8869' Sadlerochit 12250' 8957' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date OS.;t3·0 X-09B Well Number 202-031 Permit No. / A roval No. Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 4,716 (psi 12.00 (ppg) (psi 12.00 (ppg) 4,600 (psi) 10.00 (ppg) ) ) - Printed: 4/1/2002 11:15:53 AM 472 (psi (psi) 735 (psi) 10.80 (ppg) (ppg) 8.40 (ppg) 9,991.0 (ft) 7,564,0 (ft) (ft) (ft) 11,807.0 (ft) 8,857.0 (ft) C' ~ ' _.,.~ " ? 3/13/2002 FIT 3/18/2002 FIT 3/19/2002 FIT ,"-" ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Start: 3/9/2002 Rig Release: 3/26/2002 Rig Number: Spud Date: 6/1/1980 End: 3/26/2002 3/8/2002 14:00 - 00:00 10.00 MOB P PRE RIG DOWN. MOVE PUMP AND PIT MODULE. RIG DOWN. LOWER DERRICK. START MOVING RIG UNIT AT 21 :30 HRS 3/9/2002 00:00 - 14:00 14.00 MOB P PRE MOVE RIG UNIT TO WELL X-09B. MOVE PUMP/ PIT MODULE AND CAMP TO X PAD. RIG UP. SPOT PITS, CAMP, MECHANIC SHOP AND CUTTINGS BOX. RIG UP. 14:00 - 15:00 1.00 BOPSU DECOMP ACCEPT RIG AT 14:00 HRS INSTALL SECONDRY VALVE ON ANNULUS. 15:00 - 16:00 1.00 BOPSU DECOMP PRE-SPUD AND SAFETY MEETING WITH ALL PERSONNEL. 16:00 - 19:00 3.00 BOPSU P DECOMP PULL BACK PRESSURE VALVE. RECEIVE SEA WATER. SEA WATER TRUCKS DELAYED DUE TO WORK LOAD. 19:00 - 21 :30 2.50 BOPSU DECOMP SAFETY STAND DOWN WITH ALL RIG PERSONNEL AND PEAK DRIVERS. 21 :30 - 00:00 2.50 BOPSU DECOMP DISPLACE FREEZE PROTECT WITH SEA WATER WHILE OFF LOADING VAC TRUCKS. 3/10/2002 00:00 - 02:30 2.50 BOPSU DECOMP DISPLACE FREEZE PROTECT AND CIRCULATE WELL WITH SEA WATER AT 3 BPM. 02:30 - 03:00 0.50 BOPSU DECOMP RIG DOWN CIRCULATING LINES. 03:00 - 03:30 0.50 BOPSU DECOMP INSTALL TWO WAY CHECK VALVE AND TEST TO 1000 PSI. 03:30 - 05:00 1.50 BOPSU DECOMP SAFETY STAND DOWN WITH DRILLING CREW. 05:00 - 07:00 2.00 BOPSU DECOMP NIPPLE DOWN TREE AND ADAPTOR FLANGE. 07:00 - 10:00 3.00 BOPSU DECOMP NIPPLE UP BOP. 10:00 - 10:30 0.50 BOPSU DECOMP RIG UP TO TEST BOP. 10:30 - 15:00 4.50 BOPSU DECOMP TEST BOP AND RELATED EQUIPMENT. 250 PSI LOW, 3500 PSI HIGH. NOTE: JOHN CRISP OF AOGCC WAIVED WITNESSING TEST 15:00 - 16:00 1.00 BOPSU DECOMP RIG UP DSM LlBRICATOR. PULL TWC. 16:00 - 17:30 1.50 PULL DECOMP PULL TUBING HANGER. PROBLEMS BACKING OUT LOCK DOWN SCREWS. 17:30 - 18:30 1.00 PULL P DECOMP UNSEAT HANGER. WORK STRING. 40K OVER PULL. PULL TUBING HANGER TO FLOOR AND LAY DOWN SAME. 18:30 - 19:30 1.00 PULL P DECOMP RIG UP 4 1/2" TUBING EQUIPMENT AND CONTROL LINE SPOOLER. PJSM. 19:30 - 22:00 2.50 PULL P DECOMP POH. LAY DOWN 41/2" 12.6# BTC TUBING. NORM INSPECT TREE, TUBING HANGER AND FIRST 10 JOINTS. 22:00 - 22:30 0.50 PULL P DECOMP LAY DOWN SSSV. RIG DOWN CONTROL LINE SPOOLER. 22:30 - 00:00 1.50 PULL P DECOMP POH LAY DOWN 41/2" TUBING. 3/11/2002 00:00 - 06:00 6.00 PULL P DECOMP POH LAY DOWN 41/2" TUBING. TOTAL OF 236 JTS AND 12.75' CUT OFF STUB. 06:00 - 07:30 1.50 PULL P DECOMP RIG DOWN TUBING HANDLING EQUIPMENT AND CLEAN FLOOR. 07:30 - 09:30 2,00 CLEAN P DECOMP MAKE UP 8 1/2" MILLING BHA. 09:30 - 10:30 1.00 CLEAN P DECOMP PICK UP 5" DRILL PIPE AND RIH TO 1788'. 10:30-11:30 1,00 CLEAN P DECOMP MAKE UP RTTS PACKER AND RIH TO 33'. 11 :30 - 12:00 0.50 CLEAN P DECOMP SET RTTS PACKER AND TEST TO 1500 PSI. 12:00 - 13:30 1.50 BOPSU P DECOMP NIPPLE DOWN BOP. 13:30 - 23:30 10.00 BOPSU P DECOMP REMOVE TUBING SPOOL. PROBLEMS REMOVING LOCK DOWN SCREW. CHAGE OUT 13 5/8" x 9 5/8' CASING PACK OFF AN DTEST TO 5000 PSI. INSTALL TUBING SPOOL. Printed: 4/1/2002 11 :16:01 AM ,~ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Start: 3/9/2002 Rig Release: 3/26/2002 Rig Number: Spud Date: 6/1/1980 End: 3/26/2002 NIPPLE UP BOP. NIPPLE UP BOP. TEST UPPER PIPE RAMS AND BOTTOM FLANGE TO 250 PSI LOW AND 5000 PSI HIGH, TEST LOWER PIPE RAMS, ANNULAR, LOWER KELLY COCK AND TIW TO 250 PSI LOW AND 3500 PSI HIGH. 05:00 - 05:30 DECOMP INSTALL WEAR BUSHING. 05:30 - 08:00 DECOMP PULL RTTS PACKER AND LAY DOWN SAME. 08:00 -15:30 DECOMP PICK UP 5" DRILL PIPE AND RIH WITH MILL BHA TO 41/2" TUBING STUMP AT 10070' 15:30 - 16:30 1.00 BOPSU DECOMP CIRCULATE BOTTOMS UP AT 586 GPM. 16:30 - 19:00 2.50 BOPSU DECOMP POH WITH 5" DRILL PIPE TO 4134' 19:00 - 20:00 1.00 BOPSU DECOMP SLIP AND CUT DRILLING LINE. 20:00 - 20:30 0.50 BOPSU DECOMP SERVICE TOP DRIVE. 20:30 - 21 :30 1.00 BOPSU DECOMP POH TO BHA. 21 :30 - 22:00 0.50 BOPSU DECOMP POH MILL BHA. 22:00 - 22:30 0.50 BOPSU DECOMP RIG UP SCHLUMBERGER E-LlNE UNIT. PJSM WITH RIG CREW, SCHLUMBERGER CREW AND HALLlBUTRON BRIDGE PLUG TECH. 22:30 - 00:00 DECOMP RIH WITH 9 5/8" EZSV BRIDGE PLUG ON E-LlNE. 3/13/2002 00:00 - 02:00 DECOMP RIH WITH 9 5/8" EZSV BRIDGE PLUG ON E-LlNE AND SET AT 10010'. GOOD INDICATION THAT BRIDGE PLUG SET BUT UNABLE TO RELEASE TOOLS. 02:00 - 02:30 DFAL DECOMP INSTALL "T" BAR TO WIRELlNE, PULL UP WITH BLOCKS AND PULL OUT OF ROPE SOCKET 02:30 - 04:00 DECOMP POH WITH WIRE LINE AND RIG DOWN SCHLUMBERGER. 04:00 - 06:00 DFAL DECOMP MAKE UP FISHING BHA WITH 3 3/8" OVER SHOT GRAPPLE AND 81/8" GUIDE. 06:00 - 09:00 DFAL DECOMP RIH WITH 5" DRILL PIPE TO 9994'. 09:00 - 10:00 DFAL DECOMP ENGAGE FISH. PULL E-LlNE TOOLS FREE FROM BRIDGE PLUG. 10:00 - 11 :00 DECOMP TEST 9 5/8" CASING TO 3500 PSI FOR 30 MINUTES. 11 :00 - 14:00 DFAL DECOMP POH WITH OVERSHOT AND E-LlNE TOOLS. 14:00 - 15:00 DFAL DECOMP POH WITH FISHING BHA. 15:00 - 16:30 DFAL DECOMP LAY DOWN FISH, CLEAR RIG FLOOR. 16:30 - 19:30 WEXIT MAKE UP 8 1/2" MILLING ASSEMBLY, MWD AND WHIPSTOCK. PJSM. 19:30 - 20:00 0.50 STWHIP P WEXIT SURFACE TEST MWD. 20:00 - 00:00 4.00 STWHIP P WEXIT RIH WHIPSTOCK AND MILLING BHA ON 5" DRILL PIPE TO 7992'. 3/14/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT RIH WHIPSTOCK AND MILLING BHA ON 5" DRILL PIPE TO 9960'. 01 :30 - 02:30 1.00 STWHIP P WEXIT ORIENT WHIPSTOCK 85 DEG RIGHT OF HIGH SIDE. TAG UP ON EZSV AT 10013'. SET WHIPSTOCK BOTTOM ANCHOR WITH 25,000 LBS. SHEAR PIN ON WHIPSTOCK WITH 45,000 LBS. 02:30 - 04:00 1.50 STWHIP P WEXIT CIRCULATE AND DISPLACE SEA WATER WITH LSND 10.8 PPG MUD. 04:00 - 18:30 14.50 STWHIP P WEXIT MILL 81/2" WINDOW FROM 9991' TO 10024' 18:30 - 19:30 1.00 STWHIP P WEXIT CIRCULATE AND PUMP LOW VIS SWEEP AROUND. WORK MILLS ACROSS WINDOW. 19:30 - 20:30 1.00 STWHIP P WEXIT PERFORM FIT TO 12.0 PPG EMW WITH 472 PSI. 20:30 - 23:00 2.50 STWHIP P WEXIT SLIP AND CUT DRILLING LINE. Printed: 4/112002 11:16:01 AM .~ .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Start: 3/9/2002 Rig Release: 3/26/2002 Rig Number: Spud Date: 6/1/1980 End: 3/26/2002 3/15/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT POH TO MILLING BHA. 01 :30 - 03:00 1.50 STWHIP P WEXIT LAY DOWN MILLING BHA. UPPER MILL FULL GAGE. 03:00 - 04:00 1.00 STWHIP P WEXIT CLEAN FLOOR. 04:00 - 04:30 0.50 STWHIP P WEXIT PULL WEAR BUSHING, WASH WELL HEAD AND BOP WITH JETTING TOOL. 04:30 - 05:00 0.50 DRILL P INT1 RUN TEST PLUG AND TEST JOINT. 05:00 - 06:30 1.50 DRILL P INT1 TEST BOP AND ASSOCIATED EQUIPMENT 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES. CHOKE MANIFOLD TESTED WHILE POH. NOTE: TEST WITNESS WAIVED BY JEFF JONS OF AOGCC. 06:30 - 07:00 0.50 DRILL P INT1 PULL TEST PLUG AND TEST JOINT. INSTALL WEAR BUSHING. 07:00 - 08:30 1.50 DRILL P INT1 MAKE UP 8 1/2" DRILLING BHA WITH MUD MOTOR AND MWD. 08:30 - 09:30 1.00 DRILL P INT1 UP LOAD MWD. 09:30 - 10:30 1.00 DRILL P INT1 MAKE UP BHA. 10:30 - 11 :00 0.50 DRILL P INT1 SHALLOW TEST MWD. OK. 11:00 -13:00 2.00 DRILL P INT1 PICK UP 5" DRILL PIPE AND RIH TO 2793' 13:00 - 15:30 2.50 DRILL P INT1 RIH WITH 5" DRILL PIPE TO 9933' 15:30 - 16:30 1.00 DRILL P INT1 ORIENT TOOLS ABOVE WINDOW. WORK BIT THROUGH WINDOW WITH NO PROBLEMS, 16:30 - 00:00 7.50 DRILL P INT1 DRILL 81/2" DIRECTIONAL HOLE FROM 10024' TO 10339' SLIDING TIME-4 HRS ROTATING TIME-0.5 HRS 3/16/2002 00:00 - 09:00 9.00 DRILL P INT1 DRILL 81/2" DIRECTIONAL HOLE FROM 10339' to 10871' SLIDING TIME-3.7 HRS ROTATING TIME-2,3 HRS 09:00 - 10:30 1.50 DRILL P INT1 CIRCULATE BOTTOMS UP. MONITOR WELL, STATIC. 10:30 -11:30 1.00 DRILL P INT1 POH SHORT TRIP TO 9 5/8" CASING WINDOW. NO PROBLEMS. TAKE SURVEY CHECK SHOTS AT 10464', 10433', 10370' AND 10399'. 11 :30 - 12:00 0.50 DRILL P INT1 RIH TO BOTTOM NO PROBLEMS. 12:00 - 00:00 12.00 DRILL P INT1 DRILL 81/2" DIRECTIONAL HOLE FROM 10871' TO 11716' SLIDING TIME-1.5 HRS ROTATING TIME-5,8 HRS 3/17/2002 00:00 - 02:30 2.50 DRILL P INT1 DRILL 81/2" DIRECTIONAL HOLE FROM 11716' TO 11792' SLIDING TIME-0.7 HRS ROTATING TIME-0.6 HRS LOST 60% RETURNS WHILE CIRCULATING. 02:30 - 03:30 1.00 DRILL P INT1 MONITOR WELL. STATIC LOSS RATE 10 BPH. MIX LCM PILL 03:30 - 05:00 1.50 DRILL P INT1 SPOT 40 BBL LCM PILL WITH 30 LBS I BBL LCM ON BOTTOM. LOSS RATE WHILE SPOTTING PILL 3.5 BBU MIN. LOST 100 BBL WHILE CIRCULATING. WHEN LCM PILL GOT TO BOTTOM LOSS SLOWED THEN STOPPED. 05:00 - 06:00 1.00 DRILL P INT1 POH TO 9 5/8" CASING WINDOW. 06:00 - 07:00 1.00 DRILL P INT1 SLIP AND CUT DRILLING LINE. 07:00 - 08:00 1.00 DRILL P INT1 SERVICE TOP DRIVE. 08:00 - 09:00 1.00 DRILL P INT1 RIH TO BOTTOM. 09:00 - 11 :30 2.50 DRILL P INT1 CIRCULATE AND SPOT LINER RUNNING PILL. SLOW LOSSES WHILE CIRCULATING. TOTAL LOSS 140 BBL. 11 :30 - 13:00 1.50 DRILL P INT1 POH TO CASING WINDOW. SLM. DROP RABBIT. Printed: 4/112002 11 :16:01 AM ,/'"'""-0.., ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Start: 3/9/2002 Rig Release: 3/26/2002 Rig Number: Spud Date: 6/1/1980 End: 3/26/2002 3/17/2002 13:00 - 13:30 0.50 DRILL P INT1 PUMP DRY JOB. BLOW DOWN SURFACE LINES. 13:30 - 19:00 5.50 DRILL P INT1 POH TO BHA. 19:00 - 22:00 3.00 DRILL P INT1 LAY DOWN BHA. 22:00 - 23:00 1.00 DRILL P INT1 CLEAR RIG FLOOR. 23:00 - 00:00 1.00 CASE P INT1 RIG UP TO RUN 7" LINER. 3/18/2002 00:00 - 00:30 0.50 CASE P INT1 MAKE UP FLOATS AND SHOE TRACK. CHECK FLOATS. 00:30 - 04:00 3.50 CASE P INT1 RUN 7" LINER, 26# L-80 BTC-MOD. TOTAL 48 JOINTS, 04:00 - 04:30 0.50 CASE P INT1 MAKE UP BAKER 7" X 9 5/8" HYD LINER HANGER AND ZXP LINER TOP PACKER. 04:30 - 05:00 0.50 CASE P INT1 CIRCULATE LINER VOLUME. 05:00 - 10:30 5.50 CASE P INT1 RUN LINER ON 5" DRILL PIPE TO 9895' FILL EVERY 10 STANDS. 10:30 - 11 :00 0.50 CASE P INT1 MAKE UP CEMENTING HEAD AND LAY DOWN ON JOINT. 11 :00 - 11 :30 0.50 CASE P INT1 CIRCULATE DRILL PIPE VOLUME. 11 :30 - 12:30 1,00 CASE P INT1 RUN LINER ON 5" DRILL PIPE TO 11680'. 12:30 - 13:00 0,50 CASE P INT1 CIRCULATE AND WASH LINER TO 11792'. 13:00 - 14:30 1.50 CASE P INT1 CIRCULATE AND CONDITION MUD. 14:30 - 16:00 1,50 CEMT P INT1 PJSM WITH ALL PERSONNEL. TEST LINES TO 4000 PSI. PUMP 35 BBL ALPHA SPACER. MIX AND PUMP 82.7 BBL (376 SX) 15.8 PPG WITH 0.2% CFR-3, 0.4% HALARD-344 AND 0.18% HR-5. DROP PLUG AND DISPLACE WITH 241 BBL MUD. BUMP PLUG. LOST 20 BBL MUD DURING JOB, CEMENT IN PLACE AT 16:00 HRS. 16:00 - 16:30 0.50 CASE P INT1 SET LINER HANGER. RELEASE FROM LINER HANGER. SET ZXP LINER TOP PACKER WITH 75K DOWN WEIGHT. 16:30 - 17:30 1.00 CASE P INT1 CIRCULATE BOTTUMS UP, NO CEMENT RETURNS BUT CLEAR INCREASE OF PH IN MUD. 17:30 - 18:00 0.50 CASE P INT1 LAY DOWN CEMENT HEAD. 18:00 - 22:00 4.00 CASE P INT1 POH 5" DRILL PIPE IN STANDS. 22:00 - 23:30 1,50 CASE P INT1 POH. LAY DOWN EXCESS 5" DRILL PIPE. LAY DOWN BAKER LINER HANGER RUNNING TOOL. 23:30 - 00:00 0.50 CASE P INT1 RIG DOWN LINER RUNNING TOOLS AND CLEAR FLOOR. 3/19/2002 00:00 - 00:30 0,50 CASE P INT1 PRESSURE TEST CSG TO 3,500 PSI- OKAY. 00:30 - 02:30 2.00 DRILL P INT1 PU BHA, SET MTR AT 1.5 DEG, ORIENT MTR. 02:30 - 03:30 1.00 DRILL P INT1 SURFACE TEST MWD - OKAY. 03:30 - 04:00 0.50 DRILL P INT1 CONTINUE PU BHA. 04:00 - 04:30 0.50 DRILL P INT1 C/O ELEVATORS, SHALLOW TEST MWD -OKAY. 04:30 - 09:00 4.50 DRILL P INT1 PU 144 JTS OF 4" DP (4,479'), TO TO WELL. 09:00 - 09:30 0.50 DRILL P INT1 C/O ELEVATORS TO 5", FILL PIPE, CHECK MWD AT 4,731'- OKAY. 09:30 - 11 :00 1.50 DRILL P INT1 RIH WI 5" DP TO 9,777', FILL PIPE, CHK MWD-OKAY. 11 :00 - 12:00 1.00 DRILL P INT1 CUT AND SLIP 91' OF DL. 12:00 - 12:30 0.50 DRILL P INT1 SERVICE TO. 12:30 - 13:30 1.00 DRILL P INT1 RIH TO 11,670' (UWT=205K, DWT=140K AT TOP OF WINDOW). 13:30 - 15:30 2.00 DRILL P INT1 TAGGED LC AT 11,703', DRILL SHOE TRACK FROM 11,703' - 11,779', WITH 100 SPM AND 1,750 PSI. 15:30 - 19:00 3.50 DRILL P INT1 DISPLACE WELLBORE TO 8.4PPG QUICKDRIL MUD AT 6 BPM. 19:00 - 20:00 1.00 DRILL P INT1 DRILL FLOAT SHOE TO 11,787, PLUS 20' OF NEW FM, TO 11,807', (UWT=220K, DWT=180K, ROT= 200K). 20:00 - 20:30 0.50 DRILL P INT1 PERFORM FIT TO 10.0 PPG EMW, WI 735 PSI SURFACE PRESS. Printed: 4/1/2002 11:16:01 AM /---.. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Start: 3/9/2002 Rig Release: 3/26/2002 Rig Number: Spud Date: 6/1/1980 End: 3/26/2002 3/19/2002 20:30 - 00:00 3.50 DRILL P INT1 DRILL AHEAD TO 11,872', W/1 ,5 DEG MTR. ART=.9, AST=2.2. 3/20/2002 00:00 - 00:00 24.00 DRILL P INT1 DRILL 6-1/8" HOLE W/1.5 DEG MTR. AST=10.5, ART=4.9. 3/21/2002 00:00 - 00:00 24.00 DRILL P INT1 DRILL 6-1/8" HOLE W/1.5 DEG MTR. AST=6.4, ART=8.6. 3/22/2002 00:00 - 00:00 24.00 DRILL P INT1 DRILL 6-1/8" HOLE W/1.5 DEG MTR. AST=3.5, ART=10.3. 3/23/2002 00:00 - 05:00 5.00 DRILL P INT1 DRILL 6-1/8" HOLE W/1,5 DEG MTR. AST=O.O, ART=5.0. 05:00 - 08:00 3.00 DRILL P INT1 CIRC SWEEP AT 6.5 BPM WHILE RECIPROCATING PIPE. 08:00 - 09:30 1.50 DRILL P INT1 SHORT TRIP TO 7" CSG SHOE AT 11,749' - NO PROBLEMS. 09:30 - 10:30 1,00 DRILL P INT1 SERVICE TO. 10:30-11:30 1.00 DRILL P INT1 RIH TO TO. - NO PROBLEMS. 11 :30 - 14:30 3.00 DRILL P INT1 CIRC SWEEP AT 6.5 BPM WHILE RECIPROCATING PIPE. SPOT 130 BBL LINER RUNNING PILL IN OPEN HOLE. PUMP SLUG, MONITOR WELL - OKAY. 14:30 - 17:00 2.50 DRILL P INT1 POOH TO 11,844', LAYING DOWN 84 JTS OF 5" DP. PRESS TEST CHOKE MANIFOLD TO 250/3,500 PSI, FOR 5/5 MIN-OKAY. 17:00 - 21 :00 4.00 DRILL P INT1 POOH TO 4,479' WI 5" DP, (WET STRING), AND STAND BACK IN DERRICK.. 21 :00 - 21 :30 0.50 DRILL P INT1 CIO TO 4" HANDLING EQUIPMENT. 21 :30 - 23:30 2.00 DRILL P INT1 POOH TO BHA. 23:30 - 00:00 0,50 DRILL P INT1 LD BHA. 3/24/2002 00:00 - 02:00 2.00 DRILL P INT1 CONT. LD BHA, DOWNLOAD MWD DATA. CLEAN RIG FLOOR. 02:00 - 04:30 2.50 DRILL P INT1 PULL WB, RU TEST EQUIP. TEST BOPE - BLIND RAMS, UPPER AND LOWER PIPE RAMS, ANNULAR, FLOOR VALVES, TO, TO 250-3,500 PSI, FOR 5/5 MIN- OKAY. 04:30 - 05:00 0.50 DRILL P INT1 RD TEST EQUIP., INSTALL WB. 05:00 - 07:30 2.50 DRILL P INT1 C/O GRABBER DIES IN TO. RU LINER HANDLING EQUIP, 07:30 - 10:00 2.50 CASE P PROD1 RUN 79 JTS (2,750.52') OF 4,5" 12,6 LB/FT, L-80, IBT-M SLOTTED/SOLID LINER, WI 27 CENTS ON THE SOLID JTS. THREAD LOCKED BTM 3 JTS, 10:00-11:00 1.00 CASE P PROD1 MU BOT 7" X 5" HMC LINER HNGR AND 'ZXP' LINER TOP PKR. 11 :00 - 14:30 3.50 CASE P PROD1 RIH WI 4" DP TO 7,271. 14:30 - 15:00 0.50 CASE P PROD1 CIO TO 5" HANDLING TOOLS. 15:00 - 15:30 0.50 CASE P PROD1 RIH W/5" DP TO 9,801'. 15:30 - 16:00 0.50 CASE P PROD1 CIRC ONE DP VOLUME AT 3 BPM, 580 PSI. 16:00 - 17:00 1.00 CASE P PROD1 CONT. RIH WITH 5" DP TO TD OF 14,417'. 17:00 - 18:30 1.50 CASE P PROD1 CIRC AT 3 BPM, DROP SETTING BALL. PRESSURE UP TO 1,600 PSI AND SET HNGR. SET DOWN WEIGHT TO VERIFY SETTING. PRESSURE UP TO 2,500 PSI, BLEED OFF AND RELEASE FROM HNGR. SET DOWN 70K, AND SET ZXP PKR. PU CLEAR OF LINER TOP, PRESSURE UP TO 3,800 PSI AND BLOW OUT BALL SEAT. 18:30 - 21 :30 3.00 CASE P PROD1 DISPLACE WELL TO CLEAN SEAWATER AT 9 BPM AND 1,025 PSI. 21 :30 - 00:00 2.50 CASE P PROD1 POOH TO 7,874' LAYING DOWN 5" DP. 3/25/2002 00:00 - 03:00 3.00 CASE P PROD1 CONTINUE POOH TO 4,527'. 03:00 - 04:00 1,00 CASE P PROD1 CUT AND SLIP DL. 04:00 - 05:00 1.00 CASE P PROD1 SERVICE TD. 05:00 - 09:00 4.00 CASE P PROD1 CONTINUE POOH, LAYING DOWN 4" DP AND HANGER RUNNING TOOL. 09:00 - 10:00 1.00 RUNCO COMP PULL WB. RU 4-1/2" TBG HANDLING EQUIP, Printed: 4/1/2002 11 :16:01 AM · . ,~ ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Start: 3/9/2002 Rig Release: 3/26/2002 Rig Number: Spud Date: 6/1/1980 End: 3/26/2002 23:00 - 23:30 COMP 23:30 - 00:00 COMP 3/26/2002 00:00 - 04:30 COMP 04:30 - 07:00 COMP 07:00 - 07:30 0.50 WHSUR P COMP 07:30 - 09:00 1.50 WHSUR P COMP 09:00 - 10:00 1.00 WHSUR P COMP 10:00 - 14:30 4.50 WHSUR P COMP 14:30 - 15:00 0.50 WHSUR P COMP 15:00 - 16:30 1.50 WHSUR N COMP 16:30 - 17:30 1.00 WHSUR N COMP 17:30 - 18:30 1.00 WHSUR N COMP 18:30 - 19:00 0,50 WHSUR N COMP 19:00 - 20:30 1,50 WHSUR P COMP 20:30 - 21 :30 1.00 WHSUR P COMP 21 :30 - 23:00 1.50 WHSUR P COMP 23:00 - 00:00 1.00 WHSUR P COMP PJSM, RUN 285 JTS OF 4.5", 12.6#, L-80, IBT-M TBG. TAG UP AT 11,648.7'. UWT = 150K, DWT = 115K. SPACE OUT W/2,78' + 9.70' PUP JTS. PUIMU TBG HANGER AND LAND SAME. RUN IN LOCK DOWN SCREWS. RU LINES, AND CIRCULATE TBG AT 3 BPM WITH CORROSION INHIB. DROP BALL & ROD, PRESSURE UP ON TBG TO 3,500 PSI, SET PKR, HELD PRESSURE FOR 30 MIN - OKAY. (NOTE: HOSE TO RECORDER LEAKED, BUT GUAGE PRESSURE HELD). BLED TBG PRESSURE TO 1500 PSI, PRESSURED UP ANNULUS TO 3,500 PSI AND HELD FOR 30 MIN - OKAY. BLED TBG PRESSURE AND SHEARED RP (SET FOR 2,500 PSI). INSTALL TWC AND PRESSURE TEST TO 2,500 PSI. RD SURFACE EQUIP, CLEAN RIG FLOOR. ND BOPE. NU ADAPTER FLANGE AND TREE. ORIENTATION OF TREE OFF APPROXIMATELY 15 DEG DUE TO 2 HOLE CONFIGURATION OF FLANGE AND TREE. PRESSURE TEST FAILED. ACTUATOR VALVE LEAKING AT THE BONNET. ND TREE, AND REMOVE FROM CELLAR. WAIT ON REPLACEMENT TREE. NU TREE AND TEST ADAPTOR FLANGE TO 5,000 PSI - OKAY. PRESSURE TEST TREE TO 5,000 PSI, FOR 30 MIN - OKAY. PULL TWC WI LUBRICATOR. TWC FROZE IN PLACE, UNABLE TO PULL. WARM UP PROFILE W/ STEAM AND PULL. RD LUBRICATOR. RU TO PUMP DIESEL FREEZE PROTECT. TEST LINES AND PUMP 151 BBLS OF 90 DEG DIESEL, AT 2.5 BPM AND 700 PSI. U-TUBE SAME SET BPV AND TEST TO 2,500 PSI- OKAY. BLOW DOWN PRESSURE. RELEASE RIG AT 00:00 HRS 3/27102. Printed: 4/112002 11:16:01 AM ,-... ~, X-09B Prudhoe Bay Unit 50-029-20455-02 202-031 Rig Accept: Rig Spud: Rig Release: Drillin Ri : 03/09/02 03/15/02 03/26/02 Nabors 2ES PRE-RIG WORK 02/13/02 MITOA PASSEDI BLED IA. RUN 3.8 CENT WI 4-1/2" EO DEVICE TO PLUG @ 11,233' WLMD -- PULL41/2 XX PLUG FROM 11,233' WLM -- DRIFT WI 2.25" CENT AND SAMPLE BAILER TO 12,175' WLM. 02/21/02 MU 3" BALL DROP NZL. RIG UP HOT OIL TO FLUID PACK IA. 02/22/02 CaN'T LOADING IA WI FW & DIESEL. KILL WELL WI FW. RIH. PUMP 23 BBLS 15.8 PPG CL "G" CMT. COULD NOT BUILD 500 PSI SOZ. PUMPED 2 BBLS FW OUT NOZZLE, LEFT CMT PLUG IN LINER. PUH TO SAFETY. MIX 2ND BATCH CEMENT. PUMP 21 BBL NEAT 15.8 PPG. ACHIEVE 2000 PSI SOZ AND HOLD F/30-MIN. CONTAMINATE CEMENT TO 11190' CTM W/PARTIALL Y PLUGGED NOZZLE. POOH TO SWAP NOZZLES. BALL WAS SEATED ON COLD-ROLL CONNECTOR, SWAP COLD-ROLLS AND RBIH W/3" JSN. JET WASH W/1-FOR-1 RETURNS TO 11190' W/3 PASSES HOLDING 300 PSI WHP. JET WASH GLMS/SSSV NIPPLE ON WAY OOH. FP TO 2500' W/DIESEL. RDMO - LEFT WELL SI & FP. 02/24/02 DRIFT TBG WI 3.625 CENT & SAMPLE BAILER TO 11,102' WLMD. OOH WI NO SAMPLE -- PIT TBG TO 3200 PSI, GOOD TEST. RDMO. WELL TO REMAIN SHUT IN. 02125/02 ATTEMPTED TO CUT TBG. RAN IN HOLE WITH JET CUTTER TO CUT AT 10050'. TRIED TO TIE INTO LOG BUT COULD NOT GET DOWN PAST GAS LIFT MANDREL ATN 11141'. PULL OUT OF THE HOLE AND WILL RUN JEWELRY LOG TOMORROW. 02126/02 RIH W 1 11/16" PBMS (GR-CCL) TO PERFORM JEWELRY LOG FOR TIE IN TO PREVIOUS LOG. DEPTH FOR TIE IN NOT ACHIEVED. TAGGED 11104' SO TIED INTO PIPE TALLY INSTEAD WITH DRILLING ENGINEERS AGREEMENT. RAN LOG OVER GLM'S TO 9100'. RIH WITH 3 7/16" JET CUTTER. TIED INTO PIPE TALLY AND CUT 4.5" TUBING AT 10060' (CUT DEPTH MOVED DOWN 10' FROM REQUESTED DEPTH TO GET BELOW COLLAR. GOOD CUT INDICATION. NOTIFY PAD OPERATOR OF WELL STATUS. RIG DOWN AND LEAVE WELL SHUT IN. 03/03/02 INSTALL LUCKY TUBES ON CASING HANGER (RWO PREP). 03/04/02 CIRCULATE OUT TUBING & IA WITH 720 BBLS OF SEAWATER, FREEZE PROTECT WITH 170 BBLS OF DIESEL. U- TUBE, BLEED TUBING & IA TO ZERO. r--, ~ aod-03; 31-Mar-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well X-09B Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,895.97' MD 9,991.00' MD 14,417.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~EclElvS JJ).) 0 I, i\ ,. ~OU& 4 2002 ~~ DEFINITIVE ) North Slope Alaska BPXA PBU_WOA X Pad, Slot X-09 X-09B Job No. AKZZ22045, Surveyed: 23 March, 2002 SURVEY REPORT 29 March, 2002 W) Your Ref: API 500292045502 Surface Coordinates: 5939668.00 N, 665523.00 E (70014' 29.1481" N, 148039'47.4166" Kelly Bushing: 68. 78ft above Mean Sea Level ) Survey Ref: svy11158 Sf::M!!..........y-......, SEAVICSS A Halliburton Company (I) DEFINITIVE Sperry-Sun Drilling Services Survey Report for X-098 Your Ref: API 500292045502 Job No. AKZZ22045, Surveyed: 23 March, 2002 BPXA PBU_WOA X Pad Comment Vertical Section Dogleg Rate (0/100ft) Global Coordinates Northlngs Eastings (ft) (ft) Coordinates Eastlngs (ft) local Northings (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Azim. North Slope Alaska ncl Measured Depth (ft) ) Tie On Point AK-6 BP__IFR-AK Window Point 4048.19 4105.84 4141,28 4160.69 4174.51 0.313 9.754 11.335 11.327 668892.79 E 668940.54 E 668966.74 E 668978.67 E 668986.15 E 5935913.35 N 5935859.86 N 5935826.69 N 5935808.30 N 5935795.10 N 3286.53 E 3333.10 E 3358.57 E 3370.09 E 3377,28 E 3827.73 S 3882.26 S 3916.00 S 3934.65 S 3948.00 S 7493.93 7556.29 7594.77 7616.42 7632.36 7425.15 7487,51 7525.99 7547,64 7563.58 39,310 139.690 146.370 150.260 153.220 48.950 49.030 46.440 44.310 42.880 9895.97 9991.00 0048. 19 0079.00 0101.00 4199.88 4221.94 4241.04 4256.81 4278.62 11.332 10.243 9.904 4.511 8.798 668997.62 E 669005.26 E 669010.24 E 669013.51 E 669016.66 E 5935770.69 N 5935749.23 N 5935730.52 N 5935714.98 N 5935693.37 N 3388.20 E 3395.37 E 3399.95 E 3402.87 E 3405.54 E 3972.67 S 3994.28 S 4013.10 S 4028.70 S 4050.38 S 7662.70 7690.18 7714.98 7736.14 7765.44 7593.92 7621.40 7646.20 7667.36 7696.66 159.120 164.280 168.470 170.290 175.660 40.470 38.880 37.130 36.650 36.820 10141,61 10177,31 10208,78 10235.23 10271.78 4297.32 4314.29 4335.16 4353.67 4369.62 6.730 7.852 9.151 6.151 7.019 669017.92 E 669018.02 E 669016.53 E 669013.82 E 669010.56 E 5935674.70 N 5935657.67 N 5935636.58 N 5935617.73 N 5935601.41 N 3406.40 E 3406.13 E 3404.17 E 3401.05 E 3397.43 E 4069.07 S 4086.10 S 4107.16 S 4125.94 S 4142.18 S 7790.29 7812,68 7840,16 7864.75 7886.24 7721.51 7743,90 7771.38 7795.97 7817.46 179,100 182.720 187.880 191.000 194.110 37.140 37.410 37.810 37.710 37.820 10302.89 10331.02 10365.70 10396.80 10423.98 ) 4425.33 4484.52 4547.94 4615.59 4681.82 3.076 3,830 4.400 2.344 0.595 668996.46 E 668981.78 E 668970.87 E 668964.06 E 668958.96 E 5935544.17 N 5935483.37 N 5935418.68 N 5935350.12 N 5935283.14 N 3382.08 E 3366.07 E 3353.74 E 3345.42 E 3338.85 E 4199.10 S 4259.56 S 4324.00 S 4392.40 S 4459.25 S 7958.72 8028.09 8095.59 8163.02 8227.23 7889.94 7959.31 8026.81 8094.24 8158.45 196.020 193.720 188.000 185.900 185.320 40.430 43.660 44.780 46.470 46.110 10517.42 10610,84 10704.99 10801.40 10894.33 4750.65 4812.88 4879.89 4945,84 5010.03 0.856 0.916 0.563 0.718 0.704 668953.49 E 668948.30 E 668943.37 E 668938.83 E 668934.47 E 5935213.51 N 5935150.54 N 5935082.79 N 5935016.14 N 5934951.28 N 3331.85 E 3325.28 E 3318.86 E 3312.86 E 3307.08 E 4528.74 S 4591.58 S 4659.21 S 4725.74 S 4790.49 S 8295.09 8357.89 8426,63 8495.35 8563.79 8226.31 8289.11 8357.85 8426.57 8495.01 186.180 185.760 185.080 185.230 184.970 45.550 44.790 44.530 43.850 43.210 10991.71 11080.80 11177.44 11273.28 11367.67 5072.98 5136.17 5199.93 5246.77 5282.37 0.907 1.956 2.447 6.197 7.497 668930.66 E 668926.46 E 668921.37 E 668916.82 E 668912.78 E 5934887.71 N 5934823.86 N 5934759.36 N 5934711.90 N 5934675.78 N 3301.87 E 3296.28 E 3289.77 E 3284.18 E 3279.35 E 4853.96 S 4917.70 S 4982.08 S 5029.42 S 5065.45 S 8632.49 8700.47 8764.75 8807.39 8835.97 8563.71 8631.69 8695.97 8738.61 8767,19 184.410 185.610 185,930 187.490 187.780 42.450 44.080 46.300 50.090 53.550 11461.35 11554.71 11645.92 11709.89 11756.14 2.00.08.005 DriflQuest Page 20f5 13:03 29 March, 2002 If) Sperry-Sun Drilling Services Survey Report for X-09B Your Ref: API 500292045502 Job No. AKZZ22045, Surveyed: 23 March, 2002 BPXA PBU_WOA X Pad Comment Vertical Section Dogleg Rate (0/100ft) Coordinates Eastlngs (ft) Globa Northlngs (ft) Coordinates Eastlngs (ft) local Northlngs (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Azim. North Slope Alaska Incl Measured Depth (ft) ) 5304.77 5329.68 5356.36 5386.56 5413.70 4.986 6.295 14.408 9.292 10.116 668910.15 E 668907.14 E 668903.83 E 668899.78 E 668896.07 E 5934653.04 N 5934627.76 N 5934600.65 N 5934569.95 N 5934542.35 N 3276.22 E 3272.66 E 3268.75 E 3264.03 E 3259.71 E 5088.12 S 5113.33 S 5140.36 S 5170.96 S 5198.47 S 8852.45 8869.68 8885.98 8901.74 8914.07 8783,67 8800.90 8817.20 8832.96 8845.29 187.940 188.120 188.320 189.210 188.660 54.950 56.880 61 .460 64.590 67.630 11784.34 11815.09 11846.90 11881.65 11912.11 5443.44 5475,17 5505.21 5532.54 5566.18 13.250 9.529 14.149 11.427 11.219 668892,19 E 668888.28 E 668884.98 E 668882.10 E 668878.81 E 5934512.13 N 5934479.90 N 5934449.44 N 5934421.72 N 5934387.64 N 3255.17 E 3250.55 E 3246.59 E 3243.10 E 3239.06 E 5228.61 S 5260.74 S 5291.12 S 5318.77 S 5352.77 S 8925.29 8934.90 8941.81 8946.20 8949.52 8856.51 8866.12 8873.03 8877.42 8880.74 188.4 70 187.900 186.960 187.430 186.110 71.930 75,110 79.460 82.650 86.280 11944.59 11978.45 12009.87 12038.08 12072.49 5596.81 5626.98 5720.28 5751.54 5782.26 16.746 4.381 1.885 7.106 1.973 668877.48 E 668877.76 E 668879.27 E 668879.79 E 668880.45 E 5934356.75 N 5934326.48 N 5934232.92 N 5934201.58 N 5934170.79 N 3237.05 E 3236.67 E 3236.12 E 3235.96 E 3235.94 E 5383.62 S 5413.89 S 5507.46 S 5538.81 S 5569.60 S 8950.96 8951.73 8955.20 8957.42 8960.35 8882,18 8882.95 8886.42 8888.64 8891.57 181.360 180.080 180.590 180.020 180.040 88.370 88.720 87.030 84.870 84.260 12103.45 12133.73 12227.37 12258.80 12289.73 5809,65 5903.68 6001.49 6091.89 6186.77 2.255 0.991 0.494 0.833 2,015 668881.15 E 668884.33 E 668888,38 E 668892.87 E 668897.91 E 5934143.35 N 5934049.22 N 5933951.36 N 5933860.99 N 5933766.18 N 3236.03 E 3237.14 E 3239.05 E 3241.55 E 3244.51 E 5597.05 S 5691.23 S 5789.16 S 5879.60 S 5974.50 S 8963.01 8971.14 8978.65 8984.94 8989.53 8894.23 8902.36 8909.87 8916.16 8920.75 179.570 179.080 178.690 178.140 178.290 84.670 85.470 85.760 86.280 88.190 12317.31 12411.85 12510.08 12600.78 12695.84 ) 6279.43 6373.4 7 6466.98 6558.18 6655.46 1.411 0.686 1.059 0.496 1.062 668903.58 E 668910.72 E 668919.07 E 668927.61 E 668937.14 E 5933673.64 N 5933579.87 N 5933486.73 N 5933395.92 N 5933299.11 N 3248.15 E 3253.23 E 3259.53 E 3266.08 E 3273.47 E 6067.14 S 6161.05 S 6254.35 S 6345.32 S 6442.32 S 8991.86 8993.44 8994.57 8995.29 8995.53 8923.08 8924.66 8925.79 8926.51 8926.75 177.210 176,600 175.670 176.100 175.180 88.930 89.140 89.480 89.620 90.090 12788.58 12882.64 12976.16 13067.37 13164.65 6702.15 6749.17 6783.42 6814.64 6842.86 0.228 1.225 2.251 1.333 3.867 668942.05 E 668946.78 E 668950.32 E 668953.82 E 668957,08 E 5933252.68 N 5933205.89 N 5933171.83 N 5933140.80 N 5933112.76 N 3277.36 E 3281.06 E 3283.86 E 3286.67 E 3289.32 E 6488.84 S 6535.73 S 6569.86 S 6600.96 S 6629.07 S 8995.43 8995.15 8994.85 8994.50 8994.36 8926.65 8926.37 8926.07 8925.72 8925.58 175.260 175.710 174,940 174.700 174.540 90.160 90.520 90.480 90.820 89.740 13211.34 13258.37 13292.62 13323.85 13352,08 DrillQuest 2.00.08.005 Page 30f5 13:03 29 March, 2002 f) Sperry-Sun Drilling Services Survey Report for X-09B Your Ref: API 500292045502 Job No. AKZZ22045, Surveyed: 23 March, 2002 BPXA PBU_WOA X Pad Comment Vertical Section Dogleg Rate (0/100ft) Coordinates Eastings (ft) Globa Northlngs (ft) Coordinates Eastings (ft) Loca Northings (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Azim. North Slope Alaska Incl Measured Depth (ft) ) 6936,69 7029.41 7059.36 7122,95 7187.17 5.108 1.520 4.815 9.453 3.194 668968.51 E 668981.39 E 668986.27 E 669000.70 E 669019.49 E 5933019.58 N 5932927.66 N 5932898.03 N 5932835.50 N 5932772.74 N 3298.70 E 3309.56 E 3313.79 E 3326.84 E 3344.24 E 6722.47 S 6814.65 S 6844.38 S 6907.21 S 6970.37 S 8998.70 9006.93 9009.46 9013.77 9016.49 8929.92 8938.15 8940.68 8944.99 8947.71 173.990 172.570 171.240 165.300 163,890 84.970 84.890 85.480 86.850 88.400 13446.08 13539,27 13569.40 13633.75 13699.32 7214.77 7305.53 7397,80 7488.05 7580.31 1,531 0.380 1.373 0.419 3.153 669028.02 E 669056.64 E 669086.36 E 669115.98 E 669147,27 E 5932745.81 N 5932657.31 N 5932567.38 N 5932479.48 N 5932389.71 N 3352.18 E 3378.86 E 3406.60 E 3434.28 E 3463.59 E 6997.48 S 7086.59 S 7177.15S 7265.67 S 7356.11 S 9017.29 9019.77 9023.08 9027.03 9028.45 8948.51 8950.99 8954,30 8958.25 8959.67 163.460 163.210 162.730 162.540 161,550 88.350 88.600 87.390 87.730 90.560 13727.58 13820.63 13915,40 14008.24 14103.33 7671.04 7762.11 7802.35 7883.16 0.091 0.753 2.166 0.000 669178.89 E 669211.11 E 669225.87 E 669256.17 E 5932301.51 N 5932213.03 N 5932173.98 N 5932095.62 N 3493.26 E 3523.53 E 3537.43 E 3566.00 E 7444.98 S 7534.15 S 7573,51 S 7652.52 S 9027.47 9026.04 9025.14 9023.11 8958,69 8957.26 8956.36 8954.33 161.520 160.980 160.120 160.120 90.640 91 .100 91 .380 91 .380 14197.03 14291.21 14332.96 14417.00 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference Northings and Eastings are relative to Well Reference ) (11-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an.Azimuth of 175.990° (True). Magnetic Declination at Surface is 26.381 ° 2.00.08.005 DrilfQuest Based upon Minimum Curvature type calculations, at a Measured Depth of 14417.00ft. The Bottom Hole Displacement is 8442.60ft.. in the Direction of 155.015° (True). Page 40f5 13:03 29 March, 2002 ) ) e BPXA PBU_WOA X Pad Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for X-098 Your Ref: API 500292045502 Job No. AKZZ22045, Surveyed: 23 March, 2002 North Slope Alaska Comments Measured Sta on Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9895.97 7493.93 3827,73 S 3286.53 E Tie On Point 9991.00 7556.29 3882.26 S 3333.10 E Window Point 14417,00 9023.11 7652.52 S 3566.00 E Projected Survey Survey tool program for X-09B Fro m To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 9895.97 7493.93 AK-1 BP _HG - BP High Accuracy Gyro (X-09) 9895.97 7493.93 14417.00 9023.11 AK-6 BP JFR-AK (X-09B) -.-.--- 29 March, 2002 - 13:03 Page 50f5 ,.-..., AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~ 31-Mar-02 Re: Distribution of Survey Data for Well X-09B MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,895.97' MD 9,991.00' MD 14,417.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) REceIVED APi? 4 2002 AlaicaOU&GasCons ('.I\Ithw:.._. Ancholagê VVI''''llIIðIOn ô{Qc;' /)31 ) North Slope Alaska BPXA PBU_WOA X Pad, Slot X-09 X-09B MWD Job No. AKMW22045, Surveyed: 23 March, 2002 "-.' SURVEY REPORT 29 March, 2002 148039' 47.4166" Your Ref: API 500292045502 Surface Coordinates: 5939668.00 N, 665523.00 E (70014' 29.1481" N, Kelly Bushing: 68. 78ft above Mean Sea Level ) Survey Ref: svy11159 W) !SI::JI!!!r'Ir"Y-!5l.Jr1 SERVICES A Halliburton Company ) ) Sperry-Sun Drilling Services e Survey Report for X-09B MWD Your Ref: API 500292045502 Job No. AKMW22045, Surveyed: 23 March, 2002 BPXA North Slope Alaska PBU WOA X Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9895.97 48.950 139.310 7425,15 7493.93 3827.73 S 3286.53 E 5935913.35 N 668892.79 E 4048.19 Tie On Point MWD Magnetic ,"-. 9991.00 49.030 139.690 7487.51 7556.29 3882.26 S 3333.10 E 5935859.86 N 668940.54 E 0.313 4105.84 Window Point 10048.19 46.440 158,130 7526.15 7594.93 3918.13 S 3354.90 E 5935824.48 N 668963.12 E 24.234 4143.15 10079.00 44,310 150.260 7547.81 7616.59 3937.85 S 3364.40 E 5935804.97 N 668973.05 E 19.440 4163.48 10101.00 42.880 153.220 7563.75 7632.53 3951.21 S 3371.59 E 5935791.78 N 668980.53 E 11.327 4177.31 10141.61 40.4 70 157.280 7594,08 7662.86 3975.71 S 3382.91 E 5935767.53 N 668992.38 E 8,909 4202.54 10177.31 38.880 164.640 7621.57 7690.35 3997.21 S 3390.35 E 5935746.20 N 669000.30 E 13.888 4224.51 10208.78 37.130 168.860 7646.37 7715.15 4016.06 S 3394.81 E 5935727.45 N 669005.17 E 9.952 4243.63 10235.23 36.650 170.860 7667.53 7736.31 4031.68 S 3397.60 E 5935711.89 N 669008.31 E 4.888 4259.41 10271.78 36.820 175.990 7696.83 7765.61 4053.39 S 3400.10 E 5935690.25 N 669011.28 E 8.406 4281.23 10302.89 37.140 179.480 7721.68 7790.46 4072.08 S 3400.84 E 5935671.58 N 669012.43 E 6.825 4299.93 10331,02 37.410 182.720 7744.07 7812.85 4089.11 S 3400.51 E 5935654.54 N 669012.47 E 7.041 4316,90 10365.70 37.810 188.220 7771.55 7840.33 4110.16 S 3398.49 E 5935633.46 N 669010.92 E 9.745 4337,75 10396.80 37.710 191.280 7796.14 7864.92 4128.92 S 3395.27 E 5935614.63 N 669008.11 E 6.033 4356.24 10423.98 37.820 194.550 7817.63 7886.41 4145.14 S 3391.55 E 5935598.33 N 669004.74 E 7,378 4372.16 10517.42 40.430 196.520 7890.11 7958.89 4201.93 S 3375.73 E 5935541.21 N 668990.18 E 3.094 4427.71 10610.84 43.660 194.260 7959,48 8028.26 4262.24 S 3359.17 E 5935480.54 N 668974.94 E 3,818 4486.72 10704.99 44.780 188.450 8026.98 8095.76 4326.57 S 3346.28 E 5935415.95 N 668963.48 E 4.464 4549.99 10801.40 46.470 186.170 8094.41 8163.19 4394.91 S 3337.54 E 5935347.43 N 668956,23 E 2.435 4617.55 10894.33 46.110 185,850 8158.63 8227.41 4461.72 S 3330.50 E 5935280.49 N 668950.67 E 0.460 4683.70 10991.71 45.550 186.710 8226.48 8295.26 4531.15 S 3322.87 E 5935210.91 N 668944.55 E 0.856 4752.42 11080.80 44.790 186.310 8289.29 8358.07 4593.92 S 3315.70 E 5935147.99 N 668938.77 E 0.911 4814.54 11177.44 44.530 185.640 8358.03 8426.81 4661.48 S 3308.63 E 5935080.29 N 668933.18 E 0.557 4881.44 11273.28 43.850 185.840 8426.75 8495.53 4727.95 S 3301.95 E 5935013.69 N 668927.96 E 0.724 4947.28 11367.67 43.210 185.600 8495.18 8563.96 4792.63 S 3295.47 E 5934948.88 N 668922.91 E 0.700 5011.35 11461.35 42.450 185.030 8563.88 8632.66 4856.04 S 3289.57 'E 5934885.36 N 668918.40 E 0.911 5074.20 11554.71 44080 186.130 8631.87 8700.65 4919.72 S 3283.34 E 5934821.56 N 668913.57 E 1.924 5137.28 11645.92 46.300 186.460 8696.14 8764.92 4984.04 S 3276.24 E 5934757.10 N 668907.88 E 2.447 5200.94 11709.89 50090 188.040 8738.78 8807.56 5031.32 S 3270.20 E 5934709.69 N 668902.89 E 6.204 5247.69 11756.14 53,550 187.780 8767,36 8836.14 5067.33 S 3265.20 E 5934673.59 N 668898.68 E 7.494 5283.26 _0·· ... <___ 29 March, 2002 - 13:03 Page 2 0'5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services f) Survey Report for X-09B MWD Your Ref: API 500292045502 Job No. AKMW22045, Surveyed: 23 March, 2002 BPXA North Slope Alaska PBU_WOA X Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth locI. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11784.34 54.950 187.690 8783.84 8852.62 5090.01 S 3262.12 E 5934650.85 N 668896.10 E 4.971 5305.67 ) 11815.09 56.880 188.790 8801,07 8869.85 5115.21 S 3258.47 E 5934625.57 N 668893.00 E 6.940 5330.55 11846.90 61.460 189.010 8817.37 8886,15 5142.19 S 3254.24 E 5934598.51 N 668889.37 E 14.410 5357.17 11881.65 64.590 190.000 8833,13 8901.91 5172.73 S 3249.13 E 5934567.86 N 668884.92 E 9.358 5387.28 11912.11 67.630 188.990 8845.47 8914.25 5200.19 S 3244.54 E 5934540.30 N 668880.93 E 10.430 5414.35 11944.59 71.930 188.980 8856.69 8925.47 5230.29 S 3239.78 E 5934510.11 N 668876.84 E 13.239 5444.05 11978.45 75.110 188.080 8866.29 8935.07 5262.40 S 3234.96 E 5934477.90 N 668872.73 E 9.731 5475.74 12009.87 79.460 187.360 8873.21 8941 .99 5292.76 S 3230.85 E 5934447.46 N 668869.28 E 14.024 5505.74 12038.08 82.650 187.870 8877.59 8946.37 5320.38 S 3227.16 E 5934419.76 N 668866.20 E 11.448 5533.03 12072.49 86.280 186.560 8880.91 8949.69 5354.35 S 3222.86 E 5934385.71 N 668862.64 E 11 .209 5566.62 12103.45 88.370 181.850 8882,36 8951.14 5385.18 S 3220.59 E 5934354.83 N 668861.06 E 16.628 5597.22 12133.73 88.720 180.720 8883.13 8951.91 5415.44 S 3219.91 E 5934324.56 N 668861.04 E 3.906 5627.36 12227.37 87.030 181.330 8886.60 8955.38 5509.00 S 3218.24 E 5934230.99 N 668861.42 E 1.919 5720,57 12258.80 84.870 180.720 8888.82 8957.60 5540.35 S 3217.68 E 5934199.64 N 668861.55 E 7,140 5751.80 12289.73 84.260 180.780 8891,75 8960.53 5571.13 S 3217.27 E 5934168.85 N 668861.82 E 1,982 5782.48 12317.31 84.670 180.250 8894.41 8963.19 5598.58 S 3217.03 E 5934141.40 N 668862.18 E 2.422 5809.85 12411.85 85.4 70 179.900 8902.53 8971.31 5692.77 S 3216.90 E 5934047.23 N 668864.13 E 0.923 5903.80 12510.08 85.760 179.700 8910.04 8978,82 5790.71 S 3217.25 E 5933949.32 N 668866.62 E 0.358 6001.52 ) 12600.78 86.280 179.160 8916.34 8985.12 5881.19 S 3218.15 E 5933858.89 N 668869.50 E 0.825 6091.84 12695.84 88.190 179.060 8920.92 8989.70 5976.12 S 3219.62 E 5933764.01 N 668873.06 E 2,012 6186.64 12788.58 88.930 177.850 8923.25 8992.03 6068.80 S 3222.12 E 5933671.41 N 668877.60 E 1.529 6279.27 12882.64 89.140 177.300 8924,84 8993.62 6162.76 S 3226.10 E 5933577.56 N 668883.64 E 0.626 6373.28 12976.16 89.480 176.250 8925.97 8994.75 6256.12 S 3231.36 E 5933484.33 N 668890.95 E 1.180 6466.78 13067.37 89.620 176.510 8926.68 8995.46 6347.15 S 3237.12 E 5933393.46 N 668898.70 E 0,324 6557.98 13164.65 90090 175.840 8926.93 8995.71 6444.21 S 3243.61 E 5933296.56 N 668907.32 E 0.841 6655.26 13211.34 90.160 175.870 8926.83 8995.61 6490.78 S 3246.98 E 5933250.08 N 668911.72 E 0.163 6701.95 13258,37 90.520 176.360 8926.55 8995.33 6537.70 S 3250.17 E 5933203.24 N 668915.94 E 1,293 6748.98 13292.62 90.480 175.650 8926.25 8995,03 6571.87 S 3252.56 E 5933169.13 N 668919.07 E 2.076 6783.23 13323.85 90.820 175.430 8925,89 8994,67 6603.00 S 3254.98 E 5933138.06 N 668922.18 E 1.297 6814.46 13352.08 89740 175.300 8925.76 8994.54 6631.14 S 3257.27 E 5933109.98 N 668925.08 E 3.853 6842.68 29 March, 2002 - 13:03 Page 3 of5 DrillQuest 2.00.08.005 · (I Sperry-Sun Drilling Services Survey Report for X-09S MWD Your Ref: API 500292045502 Job No. AKMW22045, Surveyed: 23 March, 2002 BPXA PBU WOA X Pad Vertical Section Dogleg Rate (0/100ft) Global Coordinates Northlngs Eastings (ft) (ft) Coordinates Eastings (ft) Local Northlngs (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Azim. North Slope Alaska Incl Measured Depth (ft) ) Comment 6936.54 7029.31 7059.27 7122,95 7187,30 5.114 1.595 5.058 9.498 3.050 668935.31 E 668947.11 E 668951.68 E 668965.51 E 668983.64 E 5933016.67 N 5932924.60 N 5932894.93 N 5932832.26 N 5932769.31 N 3265.45 E 3275.22 E 3279.14 E 3291.59 E 3308.33 E 6724.65 S 6816.96 S 6846.72 S 6909.68 S 6973.02 S 8998.87 9007.11 9009.64 9013,94 9016.66 8930.09 8938.33 8940.86 8945.16 8947.88 174.700 173.210 171.800 165.830 164.565 84,970 84.890 85.480 86.850 88.400 13446.08 13539.27 13569.40 13633.75 13699.32 '-- 7214.97 7306.01 7398.58 7489.08 7581.61 1.058 0.365 1.385 0.557 3.114 668991.82 E 669019.18 E 669047.61 E 669076,16 E 669106.41 E 5932742.27 N 5932653.37 N 5932563.03 N 5932474.77 N 5932384.64 N 3315.91 E 3341.31 E 3367.76 E 3394.36 E 3422.62 E 7000.23 S 7089.71 S 7180.65 S 7269.51 S 7360.28 S 9017.46 9019.94 9023.26 9027.21 9028.63 8948.68 8951.16 8954.48 8958,43 8959.85 164.270 164.040 163.530 163.140 162.270 88.350 88.600 87.390 87.730 90.560 13727.58 13820.63 13915.40 14008.24 14103.33 7672.73 7764,32 7804.73 7885.82 0.583 0,761 3.536 0.000 669136.47 E 669166.70 E 669180.79 E 669210.14 E 5932295.90 N 5932206.72 N 5932167.43 N 5932088.71 N 3450.73 E 3479.00 E 3492.22 E 3519.83 E 7449.66 S 7539.49 S 7579.08 S 7658.42 S 9027.65 9026.22 9025.31 9023.29 8958.87 8957.44 8956.53 8954.51 162.810 162.260 160.810 160.810 90.640 91.100 91.380 91.380 14197.03 14291.21 14332.96 14417.00 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North Vertical depths are relative to Well Reference Northings and Eastings are relative to Well Reference ) Magnetic Declination at Surface is 26.381° (11-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an DrillQllest 2.00.08.005 (True) Based upon Minimum Curvature type calculations, at a Measured Depth of 14417.00ft. The Bottom Hole Displacement is 8428.56ft.. in the Direction of 155.316° (True). 29 March, 2002 75.9900 Page 4 0'5 Azimuth of 13:03 ) ) - e BPXA PBU_WOA X Pad DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for X-09B MWD Your Ref: API 500292045502 Job No. AKMW22045, Surveyed: 23 March, 2002 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9895,97 7493.93 3827.73 S 3286.53 E Tie On Point 9991.00 7556.29 3882.26 S 3333.10 E Window Point 14417.00 9023.29 7658.42 S 3519.83 E Projected Survey Survey tool program for X-09B MWD Fro m To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 9895.97 7493.93 AK-1 BP _HG - BP High Accuracy Gyro (X-09) 9895.97 7493.93 14417.00 9023.29 MWD Magnetic (X-09B MWD) 29 March, 2002 - 13:03 Page 5 of 5 ~ ~ ~¥IÆ¥Œ ffi)~ IÆ~IÆ~[K\IÆ AI1ASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit X-09B BP Exploration (Alaska), Inc. Pennit No: 202-031 Sur Loc: 453' SNL, 372' WEL, Sec. 07, TlON, R14E, UM Btmhole Loc. 2793' SNL, 2083' WEL, Sec. 17, T10N, R14E, UM Dear Mr. Robertson: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit X-09B. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~D4tv/. Þ1/ Cammy Oechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 15th day of February, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. WC1A z.11 slo'Z- Ir ").ll,\ ðM t-f 1/110 J Cl/ .' ~ STATE OF ALASKA ALASKA OIL ,\lD GAS CONSERVATION COMMISf~ PERMIT TO DRILL 20 AAC 25.005 1a. Type of work 0 Drill II Redrill 1b. Type of well [J Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 453' SNL, 372' WEL, SEC. 07, T10N, R14E, UM At top of productive interval 610' SNL, 2412' WEL, SEC. 17, T10N, R14E, UM At total depth 2793' SNL, 2083' WEL, SEC. 17, T10N, R14E, UM [J Exploratory Dßtratigraphic Test II Development Oil [J Service [J Development Gas üT Single Zone /.b [J Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan RKB = 70.38' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 047475 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number X-09B 9. Approximate spud ,te 03/01/02 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14417' MD / 9040' TVD o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 56 Maximum surface 2412 psig, At total depth (TVD) 8880' / 3300 psig Setting Depth Too Bo tom MD TVD MD TVD 9850' 7465' 11847' 8875' 11700' 8794' 14417' 9040' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well ADL 028314', 2083' MD I X·23 is 1027' away at 11285' MD 16. To be completed for deviated wells Kick Off Depth 10000' MD Maximum Hole Angle 18. CasinfJ Program Specifications Ize Casina Weiaht Grade Couolina 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 NSCT Quantitv of Cement (include staae data) 376 cu ft Class 'G' ./ Slotted Liner Lenath 1997' 2717' Hole 8-1/2" 6-1/8" I ...... v r:: .LJ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical FES 0 5 2002 12446 feet 8976 feet 12442 feet 8976 feet Length Plugs (measured) Alaska Oil & Gas Cons. Commission Anchorage Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Sidetrack Liner Size Cemented MD TVD 8.5 cu yds Concrete 3720 cu ft Permafrost 1689 cu ft Class 'G', 130 cu ft PF 110' 2671' 11871' 110' 2671' 8772' 110' 20" x 30" 13-3/8" 2671' 9-5/8" 11871' 631' 7" 1104' 2-7/8" 8469' - 8853' 8444' - 8976' 454 cu ft Class 'G' None 11377' - 12008' 11338' - 12442' Perforation depth: measured 12040' - 12060', 12140' - 12160', 12330' - 12350', 12405' - 12425' true vertical 8871' - 8880', 8908' - 8914', 8955' - 8959', 8969' - 8973' [J BOP Sketch [J Diverter Sketch II Drilling Program [J Refraction Analysis [J Seabed Report 0 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 II Filing Fee [J Property Plat II Drilling Fluid Program 0 Time vs Depth Plot Contact Engineer Name/Number: Dave Wesley, 564-5773 21. I hereby certify that the foregoing i~ rue apd corr t to the best of my knowledge Signed Brian Robertson ~V/O~rs¡ Title Senior Drilling Engineer Date 7./'+/01.- Pe""' ~u~~ _,.,-:z./~IO':~~5.02 ~ ~AoI(~I.g{:l!' :~=;=:men=;\;: Conditions of Approval: Samples Required 0 Yes BI No Mud Log Required 0 Yes B( No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required KI Yes 0 No Required Working Pressure Jor BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU OtheP.~"'~Pf 'f<) "Y;OO fk. v.J~ C.., lJIdü by order of Commissioner the commission 20. Attachments Date 9·).S.. Õ..:L- Approved Bv Form 10-401 Rev. 12-01-85 Submit In Triplicate ORIGINAL 1""""' r'\ I Well Name: IX-098 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: X = 665,523.00 Y = 5,939,668.00 Estimated 453' FNL , 372' FEL Sec. 7, T10N, R14E Umiat Target Location: X = 668,900.00 Y = 5,934,305.00 TVDss 8880 Sadlerochit Zone 1A 610' FNL, 2412' FEL Sec. 17, T10N, R14E Umiat Bottom Hole Location: X = 669,285.00 Y = 5,932,130.00 TVDss 8965 2793'FNL,2083'FEL Sec. 17, T10N, R14E Umiat AFE Number: 4P1860 I Estimated Start Date: 103/01/02 I ~ 14,417' I 1 TVD: 19,040' 1 Rig: I Nabors 2ES ,/" I Operating days to complete: 120.00 I BF/MS: 140.38' I I RKB: 170.38' 1 Well Design (conventional, slimhole, etc.): 1 Horizontal Sidetrack I Objective: I Zone 48, Sadlerochit C IT b' P asmaJ u ma roaram Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDrrVD MDrrVD 81/2" 7" 26.0# L-80 BTCM -1997' 9850' / 7465' 11847' /8875' 61/8" 4 Y2" 12.6# L-80 NSCT -2717' 11700' / 8794' 14417'/ 9040' TubinQ 4 Y2" 12.6# L-80 NSCT -11700' GL 11700'/ 8794' Directional KOP: 110,000' MD Maximum Hole Angle: -56.0° in original well bore from -6200' MD to -8100' MD. -45.0° through reservoir section of planned sidetrack from 9847' MD to TD at 10337' MD. Close Approach Well: There is one close approach issue: The closest well to the X-09B is X-23 with a center-to-center distance of 1027' and allowable deviation of 1027' at the planned depth of 11,285' MD. This well passes 1 :200 minor risk, but fails major risk criteria. It will not require shut in while drillinq. Survey Program: Standard MWD Surveys from kick-off to TD. X-09B Sidetrack Page 1 ~ LSND PV 15 -19 LSND PV 15-19 Lo ram 8 1/2" Intermediate: Drilling: Open Hole: Cased Hole: ~ Sample Catchers - None MWD Dir/GRI- Real time GR throu None None hout entire interval 61/8" Production: Sample Catchers - Two, at Company man call out Drilling: MWD Dir/GRlRes- Real time GR/RES throughout entire interval; Open Hole: None Cased Hole: None c p ement rogram I Casing Size I 7" Intermediate Liner I I Basis: Lead: None Tail: Based on 80' of 7" shoe track, 1847' of 8 1/2" open hole with 30% excess, 150' of 7" x 9 5/8" liner lap, and 200' of 9 5/8" x 4" DP annulus volume. Tail TOC: -9850' MD 7465'TVD Liner toP. I Fluid Sequence & Volumes: Pre 10 bbls Water Flush Spacer 30 bbls Alpha Spacer at 11 .5 ppg Lead None / ./ Tail 67 bbl I 376 ft;j I 316 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 1900 Casing Size 14 1/2" Production Liner (IF I REQUIRED FOR SOLID LINER) Basis: Lead: None Tail: Based on 80' of 4-1/2" shoe track, 2570' of 61/8" open hole with 30% excess, 150' of 4 %" x7" liner lap, and 200' of 7" x 4" DP annulus volume. Tail TOC: -11697' MD (8793'TVD) - Liner top. Fluid Sequence & Volumes: Pre 10 bbls KCI Water Flush Spacer 20 bbls Alpha Spacer at 9.6 ppg Lead None / ./ Tail 64 bbl I 359 ft~ I 302 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 2250 X-09B Sidetrack Page 2 ,---........ ,~ Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. / BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- · Maximum anticipated BHP: /3300 psi @ 8880' TVDss - Z4B · Maximum surface pressure: 2412 psi @ surface (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 3500 psi 8.6 ppg seawater /7.2 ppg Diesel · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at D8-04. Any metal cuttings will be sent to the North 810pe Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to D8-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Formation Markers Formation Tops (Wp#4) MD TVDss Comments CM2 6700 CM1 7300 THRZ 10408 7780 JKU 10678 7980 SAG RIVER 11837 8795 TSHU/SHUBLlK 11867 8810 TSADfTZ4B 12151 8880 Estimated Pore Pressure 3300 psi (-7.2ppg EMW) TZ4A Below TD TD Criteria: Proposed MO, which is just up-dip of the limit of the Light Oil Column (LOC). / X-09B Sidetrack Page 3 ~. ,-, Sidetrack and Complete Procedure Summary Ria Operations: I 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace ~II to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull and lay down 4 1/2" tubing from tubing cut and above. 5. P/U milling assembly and 4" drill pipe. RIH and drift to tubing cut. POOH and stand back BHA. 6. MU bridge plug. RIH and set at 10,020' MD. 7. Pressure Test well bore to 3500 psi for 30 minutes. 8. RIH with 9 5/8" Baker whip stock assembly. Orient whip stock as desired and set on bridge plug. Mill window in 9 5/8" ca~g at 10,000' MD. Drilllmill 20' new formation, pull up into 9 5/8" casing and conduct FIT to 12.0 ppg EMW; POOH. 9. RIH with 8-112" dnlling assembly (with MWp/GR) to whip stock. Kick-off and drill the 8-1/2" intermediate sectionpTop Sag -11,847' MD (-8875' TVD). 10. Run and cement 7", 26# intermediate drilling liner to -150' back into window. POOH. 11.)'!ake up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES). Test the 7" casing to 3500 psi for 30 minutes. /' 12. Drill 6-1/8" production section as per directional plan to an estimated TD of 14,417' MD (-9040' TVD). / 13. Run a 4 W', 12.6# slotted production liner throughout the 6-1/8" well bore. Displace well to clean seawater above liner top. POOH. ,,/ 14. Run the 41/2",12.6# L-80 completion, tying into the 4-1/2" liner top. 15. Drop Ball and Rod to set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect the well to -2200' and secure the well. 18. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod I RHC plug from IX' nipple below the production packer and install gas lift valves. Estimated Start Date: March 01, 2002 X-09B Sidetrack Page 4 .'~, ,..,...--., Job 1: MIRU Hazards and Contingencies / ~ No wells will require shut-in for the rig move onto X-09A. X-31 is 34' to the West, and X-08 is 111' to the East. These are the '0 closest neighboring wells. ~ X-Pad is designated as an Hß site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: X-31 20 ppm X-10 60 ppm X-08 20 ppm 14-44 39 j?pm The maximum level recorded of H2S on the pad was 210 ppm, in 08/1996. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP's .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-comDlete Well Hazards and Contingencies ~ The perforated intervals and lower section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ The tubing hanger is listed as a 7" X 12" McEvoy, requiring a 7" IJ4S landing joint connection. Verify the hanger type and connection. Be prepared with spear to remove. Reference RP's .:. "De-completions" RP Job 3: Run WhiDstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP's .:. "Whip stock Sidetracks" RP Job 5: Drill 8%" Intermediate Hole Hazards and Contingencies ~ The well will kick-off in the Colville (CM1) Mudstone and drill the HRZ, Kingak shale, and into the Sag River formation. Previous X Pad wells drilled the Kingak with 9.8 to 10.2 ppg mud weights. X-09B Sidetrack Page 5 ,,.--......,. ~ / Maintain mud weight at 10.5 ppg, minimally, to 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ Nearby well X-33 experienced problems with sticking and lost circulation while running 7" casing. The interval was drilled with 9.8 ppg mud weight. The 7" became 'stuck' in the upper Kingak at 8361' tvd. Had to pull the casing and condition the hole prior to re-running. ~ KICK TOLERANCE: In the worst case scenario of 9.5 ppg pore pressure at the Sag River depth, a fracture gradient of 10.9 ppg at the 9 5/8" casing window, and 10.5 ppg mud in the hole, the kick tolerance is 76.6 bbls. ).- One close approach issue exists with X-23. The well fails major risk criteria, but passes 1 :200 minor risk criteria. The closest point is at 11,285' MD, with a center-to-center separation of 1027'. Reference RP's .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "lubricants for Torque and Drag Management" RP TD Criteria: The onsite geologist will be needed throughout the intermediate hole section for correlation of formation markers and selection of interval TD. Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP's .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies ~ It will be necessary to Geo-steer this interval of the well to avoid exposure to areas of high water saturation. The entire interval will be placed in upper Zone 4B. ./ ~ There is one anticipated fault crossing while drilling this horizontal section of X-09B. This fault has an estimated throw of +1- 15 feet. It is expected at approximately 13,400' MD, which will be about half way through the production interval. Based upon previous experience encountering this fault while drilling the original well bore, no significant losses are expected. However, all precautions showed be taken and lost circulation procedures should be followed. ).- The Southern end of the polygon is to be considered a Hard Line. Beyond the polygon is a bounding fault, which should not be crossed. Reference RP's .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" X-09B Sidetrack Page 6 ,r----" ,/,,\ .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4%" Production Liner Hazards and Contingencies / ).> The base case completion design is to run a 4 W' slotted liner throughout the horizontal interval. Contingencies exist to run either a Solid / Slotted (Bonzai) 4 W' liner completion, or a fully Solid and Cemented 4 W' liner completion. The log data acquired will dictate the design, depending upon the extent of the water saturation encountered. ).> Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ).> Sufficient 4 W' liner will need to be run to extend -150' back up into the 7" intermediate liner, set at -11847' MD. Reference RP's .:. "Running and Cementing a Liner Conventionally" RP .:. "Combination Solid - Slotted Production Liners" RP Job 12: Run ComDletion Hazards and Contingencies ).> Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP's .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease RiQ Hazards and Contingencies ).> Though there are no close proximity surface issues, identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig about the pad and while positioning on the hole. Reference RP's .:. "Freeze Protecting an Inner Annulus" RP X-09B Sidetrack Page 7 SURVEY PROGRAM Plan: X-09B wp04 (X-09/Plan X-09B) Depth Fm Depth To SurveylPJan Tool Created By: Ken Allen Date: 11/19/2001 10000.00 14417.37 Planned: X-098 wp04 VI MWD Checked: Date_ Reviewed: Date:_ - - WELL DETAILS N~ fNf-S IE/-W Northing Easting Latitude U'Ingitude Slot 904.34 59396(18.00 6' ,00 70014'29.l48N 148~39'47.417W 09 REFERENCE INFORMATION Co-ordinatc (NÆ) Reference: Well o..-ntrc: X-09, Tzu¡,: North Vertical (IVO) Refen."UCC: 74.88' 74.88 Scçtion (VS) Rcfl-'I\."UCC: Slot - 09 (O.OON,O.OOE) Measured Depth Reference: 74.88' 74.88 Calculation Method: Minimum Curvature aJMPANY DETAILS BP Amoco Minimum Curvature ISCWSA Tr.iv Cylinder North EllipticaJ+ C:a..¡ing Rules8ased bp Calculation Method: ErrorSy:.1em: Scan Method: Error Surface: Warning Method: All TVD depths are ssTVD plus 74.88' for RKBE ) Target X-09B TA X-09B TB X-09B TC X-09B TD VSee 4937.49 4952.21 5221.29 5779.93 6063.41 6291.13 6307.03 6361.20 6949.56 6998.31 6998.38 7110.47 7201.89 7578.78 8425,20 Shap' Point Point Point Point Polygon TFaee 0.00 85.00 ¡ 18.23 0.00 0.00 -0.01 0.00 -101.24 0.00 126.15 59.36 0.00 -90.27 -79.89 0.00 Basting 6(18900.65 6(18865.74 6(18850.77 M,9285.91 668785.64 DLeg 0.00 12.00 8.00 0.00 4.00 10.00 0.00 6.00 0.00 6.00 6.00 0.00 6.00 6.00 0.00 TARGET DETAILS +N/-S +Ef·W Northing 4305.4 3515.41 3280.41 2130.4: 4365.3' +E/-W 3335.70 3345.16 3422,05 3338.31 3295.82 3261.70 3259,31 3253.39 321 1.90 3207.07 3207.06 3192.64 3186.94 3264.69 3596.75 SECTION DETAILS 259. 207.1 18(,.' 596: 145.' +N/-S -3885.31 -3897.11 -4158.38 -4815.66 -5149.20 -5417.14 -5435.84 -5498.55 -6168.76 -6224.94 -6225.03 -6355.78 -6459.57 -6839,64 -7618.88 5435. 6224.' 6459. 7618. 5373. lVD 8954.1 8994.: 9014.1 9039.1 8989.1 TVD 7563.48 7576.56 7864.11 8600.00 8875.00 8954.18 8954.88 8957.62 8991.08 8994.88 8994.89 9006.05 9014.88 9033.21 9039,88 Nmœ X-098 Polygol 139.70 ]42.86 ] 87.26 ]87.26 ]87.26 187.26 187.26 183.54 183,54 186.29 186,29 186,29 180.00 156.92 ]56.92 Azi 1ne 49.03 49.28 42.00 42.00 59.44 87.88 87.88 87.15 87.15 85.15 85.15 85.15 85.15 89.55 89.55 MD 10000.00 10020.00 10421.28 11411.52 11847.57 1213 1.95 12150,81 12213.87 12886.20 12942.73 12942.81 13074.83 13179.21 13570.31 14417.37 See 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 .. ..;;,'*' , '.....J'I4< ., , " /' .Þ~ -' #;T " ~ , .I ;' ;' .rI " ;' -I I ~ l l Size 9.625 7.000 4.500 CASING DETAILS No. TVD MD Name ¡ 7563.48 0000.00 95/8' 2 8874.88 ¡ 847.34 7" 3 9039.88 4417.36 41/2' \liD, 7563.48'TVD II) 7j.76.56'TVD LOI 7864, 0000' 00' ~ : 650 7000 7500 E TVD 1 : FORMATION TOP DETAILS Formation THRZ JKU TSGR TSHU TSADrrZ4B MDPath 10408.86 10677.98 11837.56 11867.60 12150.81 TVDPath 7854.88 8054.88 8869.88 8884.88 8954.88 No. 1 2 3 4 5 ~ ¢: o Ë '" p. ¿; ~ .~ :> 2 ¡.. 8000 9039.88' TVD I' 8,99L9ª"TYJ) ,4.89' TVD .,83',MD" 90Q6.0~ m"" ',.""'m"""" EndDir : n4:;1n 1.1,iun jon11;-£i;'TVD 18'TVD 8954.88'TVD Start Dir6110Q': 1288( .'II 'iJ?' · Œ"¡'j.'lh~ II 895 'M 000 O'TVD Dir : 1213L95'MD, Dir 61100': 12150.8 " 1 ~OOO ! i ......, i I i 8500 9000 I 9500 I 9000 8500 T 8000 7500 [500ft/in] 54.73 7000 Vertical Section a 6500 T 6000 5500 5000 Datc: 11119/200 Datc_ Date_ Plan: X..()9B wp04 (X-09/Plan X..09B) Created By: Ken Allen Checked: Tool MWD SURVEY PROGRAM Depth Fm Depth To Sl.I!'Vey/Plan 10000.00 14417.17 Planned; X-09ß wp04 VI REFERENCE INFORMATION Co·ordiuate (NÆ) Refeænœ: Well Cen1.æ: X-09, Trw North Vertical (lVD) Reference: 74.88' 74.88 Section (VS) Reference: Slot - 09 (O.OON,O.()()E~ Measured Depth Reference: 74.88' 74.88 Calculation Method: Minimmn Curvature a>MPANY DETAILS BP Amoco CalculatiOl1 M"ihod: Minimmn Curvature ErrorSystem: ISCWSA Scan Mclbod: Trav Cylinder North Error Surfucc; Elliptical + Casing Waminl!, Method: Rules Based bp MD, 7563.48'TVD No. TVD MD Name Size MD,7576.56'TVD 1 7563.48 10000.00 95/8" 9.625 2 8874,88 11847.34 7" 7.000 3 9039.88 14417.36 41/2" 4.500 MD, 7864.11' TVD . FORMATION TOP DETAILS No. TVDPath MDPath F onnation 1 7854.88 10408.86 THRZ 2 8054.88 10677,98 JKU 3 8869.88 11837.56 TSGR 4 8884.88 11867.60 TSHU 5 8954.88 12150,81 TSADrrZ4B - (X-09L1 Slot 09 Longitude 148"39'47.417W Latitude 70014'29.148N TARGET DEI AILS +N/·S +EI·W Northing 4305.41 3515.40 3280.40 2130.45 4365.39 WELL DETAILS Basting 665523.00 Northing 5939668.00 +r:J·W 904.: Name +N/·S X-09 2230.9' CASING DETAILS ) Targe X-09B TA X-09B TB X-09B TC X-09B TD VSee 4937.49 4952,21 5221.29 5779.93 6063.4 1 6291.13 6307.03 6361.20 6949.56 6998.31 6998.38 7110.47 7201.89 7578.78 8425.20 Shapl Point Point Point Point Polygo TFaee 0.00 85.00 18.23 0.00 0.00 -0.01 0.00 -101.24 0.00 126.15 59.36 0.00 -90.27 -79.89 0.00 &sting 668900.65 668865.74 668850.77 669285.91 668785.64 DLeg 0.00 2.00 8.00 0.00 4.00 0.00 0.00 6.00 0.00 6.00 6.00 0.00 6.00 6.00 0.00 32593 3207.0 3186.9 3596.7 3145.6 SECTION DETAILS +E/-W 3335.70 3345.16 3422.05 3338.3 1 3295.82 3261.70 3259.3 1 3253.39 3211.90 3207.07 3207.06 3192.64 3186.94 3264.69 3596.75 ·5435.84 _6224.94 ·6459.57 -7618.88 -5373.34 +N/-S -3885.31 -3897.11 -4158.38 -4815.66 -5149.20 -5417.14 -5435.84 -5498.55 -6168.76 -6224.94 -6225.03 -6355.78 -6459.57 -6839.64 -7618.88 !VD :954.1 994.1 014.1 039.1 989.1 TVD 7563.48 7576.56 7864.11 8600.00 8875.00 8954.18 8954.88 8957.62 8991.08 8994.88 8994.89 9006.05 9014.88 9033.21 9039.88 N~ X·09ßTA X·09BTB X-09BPolyg( 139.70 142.86 187.26 187.26 187,26 187,26 187.26 183,54 183.54 186.29 186.29 186.29 180.00 156.92 156.92 Azi Ine 49.03 49.28 42.00 42.00 59.44 87.88 87.88 87.15 87,15 85,15 85.15 85.15 85,15 89.55 89.55 MD 10000.00 10020.00 10421.28 11411.52 11847.57 12131.95 12150.81 12213.87 12886.20 12942.73 12942.81 13074.83 13179.21 13570.31 14417.37 See X-09 (X-09) 9033.21' TVD All TVD depths are ssTVD plus 74.88' for RKBE wp04 14417.37' MD, 9039.88' TVD 3600 4200 W est( - )/East( +) [600ft/in] I 2 3 4 5 6 7 8 9 10 11 12 13 14 15 4800 3000 -780 E ¢: o o ~ + ~ ~ j¡' :; o '" ,r--.., ./""' \ BP Amoco Planning Report - Geographic Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 Site: PB X Pad TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5937417.97 ft 664667.65 ft Latitude: 70 14 Longitude: 148 40 North Reference: Grid Convergence: 7.207 N 13.706 W True 1.25 deg Well: X-09 Slot Name: 09 X-09 Surface Position: +N/-S 2230.97 ft Northing: 5939668.00 ft Latitude: 70 14 29.148 N +E/-W 904.34 ft Easting : 665523.00 ft Longitude: 148 39 47.417 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 2230.97 ft Northing: 5939668.00 ft Latitude: 70 14 29.148 N +E/-W 904.34 ft Easting : 665523.00 ft Longitude: 148 39 47.417 W Measured Depth: 34.50 ft Inclination: 0.00 deg Vertical Depth: 34.50 ft Azimuth: 0.00 deg Wellpath: Plan X-09B Drilled From: X-09 Tie-on Depth: 10250.00 ft Current Datum: 74.88' Height 74.88 ft Above System Datum: Mean Sea Level Magnetic Data: 8/6/2001 Declination: 26.58 deg Field Strength: 57492 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction .~ i ft ft ft deg I-- I 0.00 0.00 0.00 154.73 Plan: X-09B wp04 Date Composed: 11/19/2001 I Version: 1 I Principal: Yes Tied-to: From: Definitive Path Plan Section Information 110000.00 49,03 139.70 7563.48 -3885.31 3335.70 0.00 0.00 0.00 0.00 10020.00 49.28 142.86 7576.56 -3897.11 3345.16 12.00 1.26 15.78 85.00 . 10421.28 42.00 187.26 7864.11 -4158.38 3422.05 8.00 -1.81 11.07 118.23 11411.52 42,00 187.26 8600.00 -4815,66 3338.31 0.00 0.00 0.00 0.00 11847.57 59.44 187.26 8875.00 -5149.20 3295.82 4.00 4.00 0.00 0.00 12131.95 87.88 187.26 8954.18 -5417.14 3261.70 10.00 10.00 0.00 -0.01 12150.81 87.88 187.26 8954.88 -5435.84 3259.31 0.00 0.00 0.00 0.00 X-09B TA 12213.87 87.15 183.54 8957.62 -5498.55 3253,39 6.00 -1.16 -5.89 -101.24 12886.20 87.15 183.54 8991.08 -6168.76 3211.90 0,00 0.00 0.00 0.00 12942.73 85.15 186.29 8994.88 -6224.94 3207.07 6.00 -3.53 4,86 126.15 X-09B TB 12942.81 85.15 186.29 8994.89 -6225.03 3207,06 6.00 1.01 1.71 59.36 13074.83 85.15 186.29 9006.05 -6355.78 3192.64 0.00 0,00 0.00 0.00 13179.21 85.15 180.00 9014.88 -6459.57 3186.94 6.00 0.00 -6.03 -90.27 X-09B TC 13570.31 89.55 156.92 9033.21 -6839.64 3264.69 6.00 1.12 -5.90 -79,89 14417.37 89.55 156.92 9039.88 -7618.88 3596.75 0.00 0.00 0.00 0,00 X-09B TO Section 1 : Start ".........., ~, BP Amoco Planning Report - Geographic 10050.00 48.18 145.70 7596.35 -3915.41 3358.33 4974.37 8.00 -3.67 9.46 118,23 10100,00 46.51 150.64 7630.24 -3946.62 3377.73 5010.88 8.00 -3.34 9.89 116.36 10150.00 45.06 155.84 7665.12 -3978.59 3393.87 5046.68 8.00 -2,89 10.41 113.01 10200.00 43.86 161.29 7700,82 -4011.15 3406.67 5081.59 8.00 -2.40 10,90 109.38 10250.00 42.93 166.96 7737.16 -4044.16 3416.07 5115.46 8.00 -1.86 11.33 105.49 10300.00 42.29 172.79 7773.98 -4077.46 3422.03 5148.10 8.00 -1.28 11.67 101.37 10350.00 41.95 178.74 7811.08 -4110.87 3424.51 5179.38 8.00 -0.68 11,89 97.07 10400.00 41.92 184.72 7848.29 -4144.23 3423.50 5209.12 8.00 -0.06 11.97 92.66 10421.28 42.00 187.26 7864.11 -4158.38 3422.05 5221.29 7,98 0.38 11.92 88.23 Section 3 : Start 10500.00 42.00 187.26 7922.61 -4210.63 3415.39 5265,70 0.00 0.00 0.00 180,00 10600.00 42.00 187.26 7996.92 -4277.01 3406.94 5322.12 0.00 0.00 0.00 180.00 10700.00 42.00 187.26 8071.24 -4343.38 3398.48 5378.53 0.00 0.00 0,00 180.00 10800.00 42.00 187.26 8145.55 -4409.76 3390.03 5434.95 0.00 0,00 0.00 180.00 10900.00 42.00 187.26 8219.87 -4476.14 3381.57 5491.36 0.00 0.00 0.00 180,00 11000.00 42.00 187.26 8294.18 -4542.51 3373.11 5547.78 0.00 0.00 0.00 180.00 11100.00 42.00 187.26 8368.50 -4608.89 3364.66 5604.19 0.00 0.00 0.00 180.00 11200.00 42.00 187.26 8442.81 -4675.27 3356.20 5660.60 0.00 0.00 0.00 180.00 11300.00 42.00 187.26 8517.13 -4741.64 3347.75 5717.02 0.00 0.00 0.00 180.00 11400.00 42.00 187.26 8591.44 -4808.02 3339.29 5773.43 0.00 0.00 0.00 180.00 11411.52 42.00 187.26 8600,00 -4815.66 3338.31 5779.92 0.00 0.00 0.00 180.00 Section 4 : Start 11500.00 45.54 187.26 8663.88 -4876.37 3330.58 5831.52 4.00 4.00 0.00 0.00 11600.00 49.54 187.26 8731.38 -4949.53 3321.26 5893.70 4.00 4.00 0.00 0.00 11700.00 53.54 187.26 8793.56 -5027.19 3311.36 5959.71 4.00 4.00 0.00 0.00 11800.00 57.54 187.26 8850.14 -5108.97 3300.94 6029.21 4.00 4.00 0.00 0.00 11847.57 59.44 187.26 8875.00 -5149.20 3295.82 6063.40 4.00 4.00 0.00 0,00 Section 5 : Start 11850,00 59.68 187.26 8876.23 -5151.28 3295.56 6065.17 10.00 10.00 0.00 -0.01 11900.00 64.68 187.26 8899.56 -5195.13 3289.97 6102.44 10.00 10.00 0.00 -0.01 11950.00 69.68 187.26 8918.94 -5240.84 3284.15 6141.29 10.00 10.00 0.00 -0.01 12000.00 74.68 187.26 8934.23 -5288.04 3278.14 6181.41 10.00 10.00 0.00 -0.01 12050.00 79.68 187.26 8945.32 -5336.39 3271.98 6222.50 10.00 10.00 0.00 -0.01 12100,00 84.68 187.26 8952.12 -5385.51 3265.72 6264.25 10.00 10.00 0.00 -0.01 12131.95 87.88 187.26 8954.18 -5417.14 3261.70 6291.13 10.01 10.01 0.01 0.08 Section 6 : Start ,,,.........., ~, BP Amoco Planning Report - Geographic Section 9: Start 13200.00 85.37 178.77 9016.60 -6480,29 3187.16 7220.72 6.00 -5.93 -79.89 13250.00 85.91 175.81 9020.40 -6530.08 3189.52 7266.75 6.00 -5.92 -79.79 13300,00 86.46 172.85 9023.73 -6579.72 3194.45 7313.74 6.00 -5.91 -79.56 13350.00 87.01 169.90 9026.58 -6629.07 3201.94 7361.57 6.00 -5.90 -79.37 13400,00 87.58 166.95 9028.94 -6677.99 3211,96 7410.08 6.00 -5.90 -79.20 13450.00 88.15 164,00 9030.80 -6726.35 3224.49 7459.17 6.00 -5.89 -79.06 13500.00 88.73 161.06 9032.16 -6774.03 3239.49 7508.68 6.00 -5.89 -78.95 13550.00 89.31 158.11 9033.01 -6820.87 3256.92 7558.49 6,00 -5.89 -78.87 13570.31 89.55 156.92 9033.21 -6839.64 3264.69 7578,77 6,00 -5.88 -78.67 Section 14: Start 13600.00 89.55 156.92 9033.44 -6866.95 3276.33 7608.44 0.00 0.00 0.00 0.00 13700.00 89.55 156.92 9034.23 -6958.95 3315.53 7708.37 0.00 0.00 0.00 0.00 13800.00 89.55 156.92 9035.01 -7050.94 3354.73 7808.29 0.00 0.00 0.00 0.00 13900.00 89.55 156.92 9035.80 -7142.93 3393.93 7908.21 0,00 0.00 0,00 0.00 14000.00 89.55 156.92 9036.58 -7234.92 3433.13 8008.14 0.00 0.00 0.00 0.00 14100.00 89,55 156.92 9037,37 -7326.92 3472.33 8108.06 0.00 0.00 0.00 0.00 14200.00 89.55 156.92 9038.16 -7418.91 3511.53 8207.98 0.00 0.00 0.00 0.00 14300.00 89.55 156.92 9038.94 -7510.90 3550.73 8307.91 0.00 0.00 0.00 0.00 14400,00 89,55 156.92 9039.73 -7602.90 3589.93 8407.83 0.00 0.00 0.00 0.00 14417.37 89.55 156.92 9039.88 -7618.88 3596.75 8425.20 0.00 0.00 0.00 0.00 .~ ,~, BP Amoco Planning Report - Geographic 10000.00 49.03 139.70 7563.48 -3885.31 3335.70 5935857.13 668942.97 70 13 50.929 N 148 38 10.498 W 10020.00 49.28 142.86 7576.56 -3897.11 3345.16 5935845.54 668952.68 70 13 50.813 N 148 38 10,223 W 10050.00 48,18 145.70 7596.35 -3915.41 3358.33 5935827.54 668966.25 70 13 50.633 N 148 38 9.841 W 10100.00 46.51 150.64 7630.24 -3946.62 3377.73 5935796.76 668986.33 70 13 50.326 N 148 38 9.277 W 10150.00 45.06 155.84 7665.12 -3978.59 3393.87 5935765.16 669003.16 70 13 50.011 N 148 38 8.809 W 10200.00 43.86 161.29 7700.82 -4011.15 3406.67 5935732.89 669016.68 70 13 49.691 N 148 38 8.437 W 10250.00 42.93 166.96 7737.16 -4044.16 3416,07 5935700.09 669026.80 70 13 49.366 N 148 38 8.164 W 10300.00 42.29 172.79 7773.98 -4077.46 3422,03 5935666.94 669033.49 70 13 49.039 N 148 38 7.992 W 10350.00 41.95 178.74 7811.08 -4110.87 3424.51 5935633.60 669036.70 70 13 48.710 N 148 38 7.920 W 10400.00 41.92 184.72 7848.29 -4144.23 3423.50 5935600.22 669036.42 70 13 48.382 N 148 38 7.950 W 10421.28 42.00 187.26 7864.11 -4158.38 3422.05 5935586.04 669035.29 70 13 48.243 N 148 38 7.992 W 10500.00 42.00 187.26 7922.61 -4210.63 3415.39 5935533.66 669029.78 70 13 47.729 N 148 38 8.186 W 10600.00 42.00 187.26 7996.92 -4277.01 3406.94 5935467.12 669022.78 70 13 47.076 N 148 38 8.433 W 10700.00 42.00 187.26 8071.24 -4343.38 3398.48 5935400.58 669015.79 70 13 46.423 N 148 38 8.679 W 10800.00 42,00 187.26 8145.55 -4409.76 3390.03 5935334,04 669008.79 70 13 45.771 N 148 38 8.926 W 10900.00 42.00 187.26 8219.87 -4476.14 3381.57 5935267.50 669001.80 70 13 45.118 N 148 38 9.172 W 11000.00 42.00 187.26 8294.18 -4542.51 3373.11 5935200.95 668994.80 70 13 44.465 N 148 38 9.419 W 11100.00 42.00 187.26 8368.50 -4608.89 3364.66 5935134.41 668987.80 70 13 43.812 N 148 38 9.666 W 11200.00 42.00 187.26 8442.81 -4675.27 3356.20 5935067.87 668980.81 70 13 43.160 N 148 38 9.912 W 11300.00 42.00 187.26 8517.13 -4741.64 3347.75 5935001.33 668973.81 70 13 42.507 N 148 38 10.159 W 11400.00 42.00 187.26 8591.44 -4808.02 3339.29 5934934,79 668966.82 70 13 41.854 N 148 38 10.405 W 11411.52 42.00 187.26 8600.00 -4815.66 3338,31 5934927.13 668966.00 70 13 41,779 N 148 38 10.434 W 11500.00 45.54 187.26 8663.88 -4876.37 3330.58 5934866.27 668959.61 70 13 41.182 N 148 38 10.659 W 11600.00 49.54 187.26 8731.38 -4949.53 3321.26 5934792.92 668951.89 70 13 40.462 N 148 38 10.931 W 11700.00 53.54 187,26 8793.56 -5027.19 3311.36 5934715.07 668943.71 70 13 39.699 N 148 38 11.219 W 11800.00 57,54 187,26 8850.14 -5108.97 3300.94 5934633.09 668935.09 70 13 38.894 N 148 38 11.523 W 11847.57 59.44 187.26 8875.00 -5149.20 3295.82 5934592.76 668930,85 70 13 38.499 N 148 38 11.672 W 11850.00 59,68 187.26 8876.23 -5151.28 3295.56 5934590.68 668930.63 70 13 38.478 N 148 38 11.680 W 11900.00 64.68 187.26 8899.56 -5195.13 3289.97 5934546.71 668926.01 70 13 38.047 N 148 38 11.843 W 11950.00 69.68 187.26 8918.94 -5240.84 3284.15 5934500.90 668921.19 70 13 37.597 N 148 38 12.012 W 12000.00 74.68 187.26 8934.23 -5288.04 3278.14 5934453.57 668916.22 70 13 37.133 N 148 38 12.188 W 12050.00 79,68 187.26 8945.32 -5336.39 3271.98 5934405.10 668911.13 70 13 36.658 N 148 38 12.367 W 12100.00 84.68 187.26 8952.12 -5385,51 3265.72 5934355.86 668905.95 70 13 36.175 N 148 38 12.549 W 12131.95 87.88 187.26 8954.18 -5417.14 3261.70 5934324.15 668902.62 70 13 35,864 N 148 38 12.667 W 12150.81 87.88 187.26 8954.88 -5435.84 3259.31 5934305.41 668900.64 70 13 35.680 N 148 38 12.736 W 12200,00 87.31 184.36 8956.95 -5484.73 3254.33 5934256.42 668896.74 70 13 35.199 N 148 38 12.882 W 12213.87 87.15 183.54 8957.62 -5498.55 3253.39 5934242.59 668896.10 70 13 35.063 N 148 38 12.909 W 12300.00 87.15 183.54 8961.90 -5584.41 3248.08 5934156.64 668892.68 70 13 34.219 N 148 38 13.065 W 12400.00 87.15 183.54 8966.87 -5684.10 3241.91 5934056.85 668888.70 70 13 33.238 N 148 38 13.245 W 12500.00 87.15 183.54 8971.85 -5783.78 3235.74 5933957.06 668884.73 70 13 32.258 N 148 38 13.425 W 12600.00 87.15 183.54 8976.82 -5883.47 3229.58 5933857.27 668880.75 70 13 31.277 N 148 38 13.606 W 12700.00 87.15 183.54 8981.79 -5983.15 3223.41 5933757.48 668876.77 70 13 30.297 N 148 38 13.786 W 12800.00 87.15 183.54 8986.76 -6082.84 3217.24 5933657.69 668872.80 70 13 29.317 N 148 38 13.966 W 12886.20 87,15 183.54 8991.08 -6168.76 3211.90 5933571.67 668869.34 70 13 28.472 N 148 38 14.123 W 112900.00 86.66 184.21 8991.82 -6182.51 3210.97 5933557.91 668868.71 70 13 28.336 N 148 38 14.150 W 12942.73 85.15 186.29 8994.88 -6224.94 3207.07 5933515.40 668865.75 70 13 27.919 N 148 38 14.264 W 12942.81 85,15 186.29 8994.89 -6225.03 3207.06 5933515.31 668865.74 70 13 27.918 N 148 38 14.264 W 13000.00 85.15 186.29 8999.73 -6281.67 3200.82 5933458.55 668860.74 70 13 27.361 N 148 38 14.446 W 13074.83 85.15 186.29 9006.05 -6355.78 3192.64 5933384.29 668854.19 70 13 26.632 N 148 38 14.684 W 13100.00 85.14 184.77 9008.18 -6380.74 3190,22 5933359,28 668852.32 70 13 26.387 N 148 38 14.755 W 13150.00 85.14 181.76 9012.41 -6430.48 3187.38 5933309.50 668850.58 70 13 25.898 N 148 38 14.838 W 13179.21 85.15 180.00 9014.88 -6459.57 3186,94 5933280.40 668850.77 70 13 25.612 N 148 38 14.851 W 13200.00 85.37 178.77 9016.60 -6480.29 3187.16 5933259.70 668851.45 70 13 25.408 N 148 38 14.845 W ,..-...... /-\ BP Amoco Planning Report - Geographic 13250.00 85.91 175.81 9020.40 -6530.08 3189.52 5933209.97 668854.90 70 13 24.918 N 148 38 14.777 W 13300.00 86.46 172.85 9023.73 -6579.72 3194.45 5933160.46 668860.92 70 13 24.430 N 148 38 14.635 W 13350.00 87.01 169.90 9026.58 -6629.07 3201.94 5933111.29 668869.49 70 13 23.945 N 148 38 14.418 W 13400,00 87.58 166.95 9028.94 -6677.99 3211.96 5933062.60 668880.58 70 13 23.463 N 148 38 14.127 W 13450.00 88.15 164.00 9030.80 -6726.35 3224.49 5933014.53 668894.17 70 13 22.988 N 148 38 13.764 W 13500.00 88.73 161.06 9032.16 -6774.03 3239.49 5932967.20 668910.21 70 13 22.519 N 148 38 13.329 W 13550,00 89.31 158.11 9033.01 -6820.87 3256.92 5932920.75 668928.67 70 13 22.058 N 148 38 12.823 W 13570.31 89.55 156.92 9033.21 -6839.64 3264.69 5932902.16 668936.85 70 13 21.873 N 148 38 12.598 W 13600,00 89.55 156.92 9033.44 -6866.95 3276.33 5932875.11 668949.08 70 13 21.605 N 148 38 12.260 W 13700.00 89.55 156.92 9034.23 -6958.95 3315.53 5932784.01 668990.29 70 13 20.700 N 148 38 11.123 W 13800.00 89.55 156.92 9035.01 -7050.94 3354.73 5932692.90 669031.50 70 13 19.795 N 148 38 9.985 W 13900.00 89.55 156.92 9035.80 -7142.93 3393.93 5932601.80 669072. 70 70 13 18.890 N 148 38 8.848 W 14000.00 89.55 156.92 9036.58 -7234.92 3433.13 5932510.70 669113.91 70 13 17.985 N 148 38 7.711 W 14100.00 89.55 156,92 9037.37 -7326.92 3472,33 5932419.59 669155.12 70 13 17.080 N 148 38 6.574 W 14200.00 89.55 156.92 9038.16 -7418.91 3511.53 5932328.49 669196.33 70 13 16.175 N 148 38 5.436 W 14300.00 89.55 156.92 9038.94 -7510.90 3550.73 5932237.38 669237.54 70 13 15,270 N 148 38 4.299 W 14400.00 89.55 156.92 9039.73 -7602.90 3589.93 5932146.28 669278.74 70 13 14.365 N 148 38 3.162 W 14417.37 89.55 156.92 9039.88 -7618.88 3596.75 5932130.45 669285.91 70 13 14,208 N 148 38 2.964 W TREE = 6" CrN ,WELLHEAD= MCEVOY "~~~'~~""~~'''~''~,,"'''''~''m',",~ ACTUA TOR= OTIS ^"m",_.".'-'"">'y'",,,,~~~==^ KB. ELEV = 72.81' ~m~~~~~~,_~ 8F. ELEV = 40.38 KOP= ·.·.w.·.·.·.·.mu.~«.w=·"·.·@m@w.-.·.·.~_~.~_~~,~·,·",·.·.·.·w Max Angle = Datum MD = _._-=~~~~~~-~~. Datum lVDss= 19 5/8" DV Packer H 113-3/8" 72#, L80, BTRS Casing H 2671' 141/2" 12.6# L-80 Tubing OTIS "XA" Sliding Sleeve H 11236' Tubing Seal Assembly H 11308' Baker SAB Packer; 3.813" 1.0. -i 11327' ITOPOF 2-7/8" LinerH 11338' TOP OF 7" Liner -i 11377' 19-5/8" 47#, L80, BTRS Csg -i 11871' ~ Á-09A Pre Rig 2578' 1 Top of Whipstock -i 12006' I Top of cement plug -i 12210' I Fish - 15' tailpipe covered w I cement 1 7" 29#, L80, BRTS Liner PBTD H 13466' -i 13528' 1 I 1 I~ DATE REV BY COMMENTS 01/17102 DEW A-oposed A-e Rig CTU Cement P&A; Tubing cut. .~ 2200' -j 41/2" X Landing Nipple, ID=3.813 o o o o 1 A-e-rig tubing cut H 10,050' H 11,200' I ",,' A-e-rig CTU Cement P&A; TOC 11371' -i4-1/2" OTIS 'X' NIP, ID=3.813 1 11401' -i4-1/2" OTIS 'XN'; ID=3.725 11403' -i4-1/2" TBG TAIL, 1D=3.9581 12442' 1-127/8" shoe 1 12446' 1-1 Sidetrack TD PRUDHOE BA Y UNrr WELL: X-09B ÆRMrr No: API No: 50-029-20455 Sec. 7, T10N, R14E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 TREE = 6" CrN WELLHEAO= MCEVOY ~'·Á'~~.·.,,~.·.·m"'·"·~~~,=NMNN~" ACTUA TOR= OTIS KB. ELEV = 74.88 ·_~_·>A·~"'~>m,wm·W···'~'·W"_'W,",~.wN=__.v______~A BF. ELEV = 40.38 M=.·.W,"'=M'~~'m~~·.y,'W.'·.'·W,"W."""N KOP = 10,000 Ma'xÃngíê-;89 .if~@1·357Õ 'Datum M'D';- 12f50' 'W~".W_WNNN=mm'~~~.~" Datum TVDss= 8880' 195/8" DV Packer l-i /"- X-09LProposed Con~letion 1 Top of Whip-stock H 10,000' I I Bridge Rug H 10,020' I~ I Pre-rig tubing cut -i 10,050' 1 1 OTIS "XA" Sliding Sleeve H 11236' ITubing Seal Assembly -i 11308' 1 Baker SAB Packer; 3.813" 1.0. H 11327' TOPOF 2-7/8" Liner -i 11338' I TOP OF 7" Liner H 11377' 19-5/8" 47#, L80, BTRS Csg H 11871' ~ .(.1((" ID Top of Whipstock H 12006' 1 113-3/8" 72#, L80, BTRS Casing H 14 1/2" 12.6# L-80 Tubing. I Baker 'ZXP Liner top pkr; 'HMC' Liner hanger I-J 9850' Top of cement plug H 12210' I Fish - 15' tailpipe covered w I cement 7" 29#, L80, BRTS Liner 1 PBTO H 13466' H 13528' 2200' -i 41/2" X Landing Nipple, 10=3.813 2578' o o ST MD 5 3625 4 5769 3 8047 2 9848 1 11193 o o GAS LIFT MANDRELS TVO OEV TYÆ SIZE L TCH 3400 9° OTIS 4112 RA 5000 54° OTIS 4 1/2 RA 6350 50° OTIS 4 1/2 RA 7500 42° OTIS 4 1/2 RA 8500 42° OTIS 4 1/2 RA COMMENTS 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 4 1/2 X 1 2671' Baker 5" X 7" Tie Back Sleeve; 'ZXP Liner top packer; 'HMC' Liner hanger H 7" 26#, L-80 BTCM Liner = 14417' 1-14-1/2" 12.6# L-80 Slotted Liner 11371' H4-1/2" OTIS 'X' NIP, 10=3.813 1 ~ 1 11401' -i4-1/2" OTIS 'XN'; 10=3.725 11403' H4-1/2" TBG TAIL, 10=3.9581 12442' H27/8" shoe 1 1 12446' H Sidetrack TO DATE REV BY COMMENTS 01/17102 DEW Proposed Sidetrack w I a Slotted liner Completion PRUDHOE SA Y UNIT WELL: X-09B ÆRMIT No: API No: 50-029-20455 Sec. 7, T10N, R14E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 X-09B Kick Tolerance ,~ Page 1 of 2 /"'-'-0/, 1/29/2002 1 :08 PM KICK TOLERANCE CALCULATOR For Vertical, Deviated or Horizontal Wells Well: Version 6.0, December 2000 Kick Zone Parameters: Input Error Messages: 1 Openhole Size? (inch) 2 Measured Depth? (H) 3 Vertical Depth? (H) 4 Horizontal Length (>87 deg) ? (H) 5 Tangent Angle Above Horizontal? (deg) 6 Min Pore Pressure Gradient? (ppg) 7 Max Pore Pressure Gradient? (ppg) 8 Kick Zone Temperature? (deg.F) Weak Point Parameters: 9 Measured Depth? (ft) 10 Vertical Depth? (H) 11 Section Angle «87 deg) ? (deg) 12 Min Fracture Gradient / EMW ? (ppg) 13 Max Fracture Gradient / EMW (ppg) 14 Weak Point Temperature? (deg.F) Other Parameters: 15 Drill Collar OD ? (inch) 16 Drill Collar Length ? (H) 17 Drillpipe OD ? (inch) 18 Surface Pressure Safety Factor? (psi) 19 Mud Weight in Hole? (ppg) Annular Capacity Around BHA: (bbl/ft) 0.02592 Annular Capacity Around DP: (bbl/ft) 0.05464 At Min Fracture Gradient: Comments: Circulating MAASP (psi) 7 Gas Gradient at Weak Point (psi/ft) 0.0706 For Min Pore Pressure: Max Allowable Gas Height: (ft) 2919 Extends above weak point Kick Tolerance: (bbl) Infinite For Max Pore Pressure: Max Allowable Gas Height: (ft) 983 Kick Tolerance: (bbl) 76.6 At Max Fracture Gradient: Circulating MAASP (psi) 440 Gas Gradient at Weak Point (psi/H) 0.0757 For Min Pore Pressure: Max Allowable Gas Height: (ft) 3873 Extends above weak point Kick Tolerance: (bbl) Infinite For Max Pore Pressure: Max Allowable Gas Height: (H) 1916 Extends above weak point Kick Tolerance: (bbl) Infinite Units (UK/US): ~ ,,.--.. P'-'JT THIS NOTICE IN THE DOGHOUSE X-09B Rig site Summary of Drilling Hazards ./ ./ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is on X-10 @ 210 ppm, (August 1996). ./ NORM test all retrieved well head and completion equipment. ./ One well fails to pass major risk criteria. X-23, with a center-center distance of 1027' at the planned depth of 11,285', is the closest point. The first failure point is at a MD of 10,245' in the drilling well, with a center-center distance of 1142'. This well passes 1 :200 minor risk criteria and will not require shut in while drilling. ./ Lost circulation may also be experienced while drilling. Though not expected to be a problem, potential lost circulation demands awareness. The SSD lost circulation tree should be followed if lost fluid returns are encountered. ./ Differential sticking may be encountered in this depleted reservoir. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE X- PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. X-09B ,,-..., /'"'. H 204437 DATE 01/17/02 CHECK NO. 00204437 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 011602 CK011602D PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it to Drill ee S/H - Terrie Hub Ie X4628 X--DC(ß fHE ATIACHED CHECK IS IN PAYMENT FDR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100. 00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CllY BANK CLEVELAND, OHIO No. H20 4 4 3 7 CONSOLIDATED COMMERCIAL ACCOUNT 56·389 4i2 00204437 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 01/17/02 I I AMOUNT $100. 001 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 NOT VALID AFTER 120 DAYS Q ...~" ! , " t'>f \\ ,'.; n Aj1.t . t,.{ \ '" .......~¥ ~t. "'It.. I~ II- 20 l¡ l¡ ~ ? II- I: 0 l¡ ;¡. 20 :Hil1 5 I: 00 B l¡ l¡ ¡. g II- ... ,-....., ...--.. TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSNDTTAL LETTER WELL NAME $(1 X ,-09 /t \\.. ... CHECK 1 CHECK WHAT APPLIES STANDARD LETTER ADD-ONS (OPTIONS) "CLUE" DEVELOPMENT MULTI LATERAL The permit is for a new well bore segment of existing weD --'--' Permit No, API No. . (If api number last two (2) Production should continue to be reported as a function .of / digits are between 60-(9) the original API number stated above. DEVELOPMENT PILOT HOLE (PH) In accordance with 20 AAC 25.005(t), all records, data and REDRlLL logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from / records, data and logs acquired for well (name on permit). EXPLORATION ANNULAR ~SAL Annular disposal has not been requested. . . INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . L-> YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . REDRILL THIS WELL DISPOSAL INTO OTHER Please note that an disposal of fluids generated... . ANNULUS L-> YES + SPACING EXCEPTION Enclosed is the approved application for permUto.driil the above referenced well. The permit is approved. subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates Ann. disposal para req _ ON/OFF SHORE Or) 7,~~ Serv _ Wellbore seg UNIT# 0, ) = l.4tl. ç; M. ...,i,C - - ~vð'r ~ .v.J 7- 'Z.11J(f -c,n, ~ROGRAM: Exp - GEOL AREA - "7 - - ~ - ,-e-e... ... - /17::. C '" '- - - ( ( - - ( ( - - ( ( ( - - j ~ - 'f4?Ñi?..¿ Af,q tit 1. Permit fee attached. . . . 2. Lease number appropriate. . . 3. Unique well name and number. . 4. Well located in a defined pool.. . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells.. . . . 7. Sufficient acreage available in drilling unit.. . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . 11. Permit can be issued without conservation order. . . 12. Permit can be issued without administrative approval 13. Can permit be approved before 15-day wait. FIELD & POOL ADMINISTRATION . . psig. Conductor string provided . . . . . . . . Surface casing protects all known USDWs. . . . . CMT vol adequate to circulate on conductor & surf csg CMT vol adequate to tie-in long string to surf csg. , CMT will cover all known productive horizons. . . . . Casing designs adequate for C, T, B & permafrost. . Adequate tankage or reserve pit.. . . . . . . . . . . . . . If a re-drill, has a 10-403 for abandonment been approved. Adequate wellbore separation proposed.. . . . . . . If diverter required, does it meet regulations . . . . . Drilling fluid program schematic & equip list adequate BOPEs, do they meet regulation . . . . . . . . BOPE press rating appropriate; test to 2¡ç 00 Choke manifold complies w/API RP-53 (May 84) Work will occur without operation shutdown. Is presence of H2S gas probable. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Aߣ DATE ~()Z- ENGINEERING APPR DATE W4+_JdiJj..J2l- !±± Permit can be issued w/o hydrogen sulfide measures. Data presented on potential overpressure zones , .. ... Seismic anal~~is of shallo~ gas zones. . . . . . . .~. ... fk Seabed condItion survey (If off-shore). . . . . . . . . .. . Contact name/phone for weekly progress reports [ex/? atory only] 30. 31. 32. ~Z DATE 33. .!:.:.!.!.:f~z.-.- 34. ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; (B) will not contaminate freshwater; or cause drilling waste to surface; (C) will not impair mechanical integrity of the well used for disposal (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION TEM~ '-(('1 WGA ~qk- ) ( oSQ. Y N Ilk Û«KU(a Y N - Y N Y N - Y N DATE - APPR Comments/Instructions: COT DTS 02! ,q./o z... JMH ð11lH+ c/ lro/CY2- RP~ðr , SF~ G:\geology\permits\checklist.doc r-' ~ 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 effort has been made to chronologically organize this category of information. ,......", ,~, ó<òa~ 03/ ¡/3 L/ a Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Man Dec 02 14:17:07 2002 Reel Header Service name.............LISTPE Date.................... .02/12/02 Origin.................. .STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name........ .....LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/02 Origin.................. .STS Tape Name................ UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA X-09B 500292045502 BP Exploration (Alaska), Inc. Sperry Sun 02-DEC-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AKMW22045 N. HERNANDEZ FERGUSON MWD RUN 3 AKMW22045 D. HAWKINS RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 7 10N HE 453 372 MSL 0) .00 68.78 40.28 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 9800.0 11792.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) r"', ---, UTILIZING GEIGER-MUELLER TUBE X-09A AT TOP OF WHIPSTOCK SET AT DRILLED INTO FORMATION TO 10024' PRESENTED AS PART OF MWD RUN 2 DATA. DETECTORS. WELL KICKS OFF FROM 10000' MD, 7562' TVD. MWD RUN 1 MD, 7578' TVD. THIS DATA 4. MWD RUN 2 WAS DIRECTIONAL WITH DGR. 5. MWD RUN 3 WAS DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4(EWR4). RESISTIVITY TOOL FAILED AT SENSOR DEPTH 13842' MD, 9020' TVD. DECISION WAS MADE TO DRILL TO TD WITHOUT GATHERING RESISTIVITY DATA. 6. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER 4/9/2002 E-MAIL FROM Do SCHNORR (BP EXPLORATION). 7. MWD RUNS 2-3 REPRESENT WELL X-09B WITH API # 50-029-20455-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14417'MD / 9023'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) SEXP = SMOOTHED PHASE SHALLOW SPACING) SESP = SMOOTHED PHASE SPACING) SEMP = SMOOTHED PHASE SPACING) SEDP = SMOOTHED PHASE SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ SHIFT DERIVED RESISTIVITY (EXTRA SHIFT DERIVED RESISTIVITY (SHALLOW SHIFT DERIVED RESISTIVITY (MEDIUM SHIFT DERIVED RESISTIVITY (DEEP File Header Service name.......... ...STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/12/02 Maximum Physical Record..65535 File Type............... .LO Previous File Name.. .....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM RPS RPX FET $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9990.0 9991.5 11780.5 11780.5 11780.5 11780.5 11780.5 STOP DEPTH 14345.5 14417.0 13842.0 13842.0 13842.0 13842.0 13842.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE ~ ~ PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 9990.0 11 792.0 MERGE BASE 11 792.0 14417.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units............... . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9990 14417 12203.5 8855 9990 14417 ROP MWD FT/H 0.09 2684.54 87.925 8852 9991.5 14417 GR MWD API 17.56 615.35 103.063 8500 9990 14345.5 RPX MWD OHMM 0.33 2000 51. 9988 4124 11780.5 13842 RPS MWD OHMM 0.53 2000 60.6041 4124 11780.5 13842 RPM MWD OHMM 1. 25 2000 59.5392 4124 11780.5 13842 RPD MWD OHMM 1. 41 2000 151.212 4124 11780.5 13842 FET MWD HR 0.45 68.85 2.55982 4124 11780.5 13842 First Reading For Entire File..........9990 Last Reading For Entire File...........14417 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/12/02 Maximum Physical Record. .65535 File Type............... .LO 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.......02/12/02 Maximum Physical Record..65535 Fi 1 e 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: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 .5000 START DEPTH 9990.0 9991. 5 STOP DEPTH 11739.5 11 792.0 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep Code I 68 1 68 1 68 17-MAR-02 Insite Memory 11 792.0 10024.0 11 792.0 36.7 50.1 TOOL NUMBER PB00026M6 8.500 9800.0 LSND 10.80 50.0 9.5 800 15.3 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 ~ .0 168.8 .0 .0 ~ ,~ First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9990 11 792 10891 3605 9990 11 792 ROP MWD020 FT/H 0.09 280.07 107.95 3602 9991.5 11792 GR MWD020 API 37.43 383.83 146.443 3500 9990 11739.5 First Reading For Entire Fi1e..........9990 Last Reading For Entire File...........11792 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......02/l2/02 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.......02/12/02 Maximum Physical Record..65535 Fi I e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 11740.0 11780.5 11780.5 11780.5 11780.5 11780.5 11792.5 STOP DEPTH 14345.5 13842.0 13842.0 13842.0 13842.0 13842.0 14417.0 # 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: 23-MAR-02 Insite Jv!emory 14417.0 11792.0 14417.0 55.0 91. 4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB00084JvI4 PB00084M4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 11 792.0 ,~ ~ # 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: LSND 8.40 50.0 9.4 1300 9.0 2.000 1.100 3.000 3.300 68.0 150.3 68.0 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type. ....0 Logging Direction.................Down Optical log depth units..... ......Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni t.s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11740 14417 13078.5 5355 11740 14417 ROP MWD030 FT/H 0.2 2684.54 74.186 5250 11792.5 14417 GR MWD030 API 17.56 615.35 72.6975 5000 11740 14345.5 RPX MWD030 OHMM 0.33 2000 51. 9988 4124 11780.5 13842 RPS MWD030 OHMM 0.53 2000 60.6041 4124 11780.5 13842 RPM MWD030 OHMM 1. 25 2000 59.5392 4124 11780.5 13842 RPD MWD030 OHMM 1. 41 2000 151.212 4124 11780.5 13842 FET MWD030 HR 0.45 68.85 2.55982 4124 11780.5 13842 First Reading For Entire Fi1e..........11740 Last Reading For Entire Fi1e...........14417 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/12/02 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.004 ,,--... ~........\ Physical EOF Tape Trailer Service name.............LISTPE Date.....................02/12/02 Origin.................. .STS Tape Name................UNKNOWN Continuation Number. .....01 Next Tape Name...........UNKNOWN Comments......... ........STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/02 Origin.................. .STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name.. .........UNKNOWN Comments...... ...........STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File