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e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q-a - L b. L Well History File Identifier Page Count from Scanned File: h!o (CO"", does ;ncl"de 7' sheet) Page Count Matches Number in SCaring preparation: V YES ~ Date: 1/3 loG If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided III II 111111111 1111I RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NofType: D Poor Quality Originals: D Other: NOTES: Date¡/a/Óh Date 1/"" 106 ~ x 30 = /PO Datel ;,/ ó (p BY: ~ Project Proofing BY: ~ Scanning Preparation BY: ~ Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 11111111111 II III III OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: 151 NlP "' 111111111111111I 151 rnf + .5 = TOTAL PAGES hs- (Count does not include cover sheet) 151 ntP 11111111/111111111/ NO 151 w¡p NO 151 III II 111111I111111I III II 111111I11 1111I 151 Quality Checked 11111111111I 1111111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18,2012 as,D3 -1 (Pi \A- ow sovom.:p.D\AuG 8 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 -- H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 1 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 I-1-14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18/2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 1-1-21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 - NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H -35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25. »0 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 9/19/2011 203 - 161 311 - 218 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 11/17/2003 50 029 - 20104 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/24/2003 PBU H-04A 873' FNL, 1265' FEL, SEC. 21, T11 N, R13E, UM 8. KB (ft above MSL): 64,4 1 5. Field / Pool (s ): Top of Productive Horizon: 1789' FSL, 3893' FWL, SEC. 15, T11 N, R13E, UM GL (ft above MSL): 39.72' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 3068' FSL, 2834' FWL, SEC. 15, T11 N, R13E, UM 11351' 8645' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 643315 y- 5959915 Zone ASP4 13410' 9036' ADL 028284 TPI: x- 648415 y- 5962676 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 647329 Y 5963935 Zone- ASP4 NA 18. Directional Survey: 0 Yes 18:1 No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all Togs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: SGRC, GR, EWR, Memory CNL, MGR, CCL, CNL 11322' 8621' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 30" Conductor Surface_ 100' Surface 100' 36" 300 sx Permafrost II 18 -5/8" 96.5# K -55 Surface 2316' _Surface 2316 24" 4800 sx Permafrost II 134 68# / 47# K -55 / N Surface 10012' Surface 7625' 12 -1/4" 740 sx 'G'. 200 sx 'G'. 2170 sx PF II 7" 29# N -80 9517' 11322' 7251' 8621' 8 -1/2" 1140 sx Class 'G' 3-1/2x 7 t3/1s° 88 #! 2#/ L -80 10790' 13410' 8207' 9036' 4-' x3-314" 157 sx Class 'G' 24. Open to production or injection? ❑ Yes c". No 25, TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 5 -1/2 ", 17 #, L -80 9431' 9431' / 7188' MD TVD MD TVD 4 -1/2 ", 12.6#, L -80 9431' - 11322' (Below K/O) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. JAN c ) 12 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11351' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ■0 No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RECEIVED RBDMS OCT 17 2011 OCT 0 7 2011 a ka U & Gas - Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSAL n ? Submit Original O 9IY �ncinCorag��e )., I - .2 G7-a d %At. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 42N 11442' 8713' None Top CGL / Zone 3 11512' 8774' Base CGL / Zone 2C 11630' 8864' 25N 12072' 8960' 25P 12096' 8968' 22P 12270' 9033' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. �/ Signed: Terrie Hubble I R *kL. Title: Drilling Technologist Date: lJV 1 PBU H 203 - 161 311 - 218 Prepared By Name/Number Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Mark Staudinger, 564-5733 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029- 20123-00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only H -04A, Well History (Pre Rig Sidetrack) Date Summary 07/14/11 WELL SHUT IN ON ARRIVAL. TAGGED LINER TOP PKR AT 10,783' SLM W/ 3.80" CENT & S- BAILER. MADE 3 ATTEMPTS TO PULL LTP @ 10,783' SLM (3 HRS), NO MOVEMENT. 07/15/11 PULLED KB LINER TOP PACKER cA 10,779' SLM (all intact). DRIFTED W/ 2.70" x 20' DMY WHIPSTOCK & SAT DOWN AT 11,320' SLM. HAD TO JAR FREE, APPEARS TO HAVE STOPPED DUE TO DOG LEGS. WHIPSTOCK SETTING DEPTH AT 11,351'. HAD TO RIG DOWN DUE TO GC -2 SHUT DOWN. WELL LEFT S /I, JOB INCOMPLETE. 07/25/11 WELL S/I ON ARRIVAL. DRIFT BAKER DUMMY WHIPSTOCK (2.625 OD, 22' 3" LENGTH) TO 11,378' SLM. RESTRICTION @ 11,363' SLM WHERE TOOLS OCCASIONALLY HANG UP. UNABLE TO REACH TARGET DEPTH OF 11,460' SLM. WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS. 07/28/11 T /I /O =SSV /550/0 +, Temp =Sl. PPPOT -T (PASS), pre CTD. PPPOT -T: Stung into test port (100 psi), bled to 0 psi. Functioned LDS, all moved freely (2.5 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 07/30/11 WELL S/I ON ARRIVAL. R/U SLICKLINE. CURRENTLY RIH W/ 2' 1 -7/8" STEM, 2.80" SWAGE. 07/31/11 DRIFT W/ 2' 1 -7/8" STEM, 2.80" SWAGE TO XN- NIPPLE @ 11,294' SLM/11,304' MD. DRIFT W/ 3 1/2" GR, 3 1/2" BAIT SUB, BAKER DMY WS (2.70" x 18') DRIFT TO 11,358' SLM/11,368' MD (unable to pass due to dog leg). WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 08/09/11 RIH w/ 2.63" DMY Whipstock Drift._ Drifted without issues to 11,608', 148' deeper than requested. POOH. RDMO. Job Complete. 08/18/11 T /I /0= 2400/550/0 Conduct PJSM. Conduct Pre -CTD Torque & test for Nordic 1. 08/25/11 T /I /O =na /500/0 Load and Kill, wait for scaffolding, pressure test line. 08/26/11 T /I /0= 2350/500/0 Load and Kill. (CTD prep) Pumped 5 bbl meth spear followed by 376 bbls 1% kcl and 58 bbls 60/40 meth to freeze protect. Bleed IA pressure to 0. Rig off tree cap. IA pressured back up to 350 psi continue bleeding. DHD on location to take over job on bleeding IA to 0 psi. Open SSV for DHD. Upon opening SSV, TP was at 790 psi. Notify Fullbore PE. DHD on well at LRS departure. FWHP= 790/80/0 08/26/11 T /I /O = 790/110/0. Temp = SI. Bleed WHPs to 0 psi. (CTD prep). Tubing FL @ 2900' (70 bbls). IA FL @ 90'. Wellhouse and flowline have been removed, drilling scaffold #9 in place. Cellar is 50" deep, cannot access OA for FL shot. OAP taken from tree gauge. Bled IAP from 110 psi to 35 psi in 4 hrs 25 min (gas /fluid slugs). Monitored for 30 min. Final WHPs = 1110/50/0. 08/27/11 T /I /0= 1650/57/30 Temp =SI Load & Kill (CTD prep) Pumped 380 bbls of 110° 2% kcl down TBG, cap w /60 bbls of 60/40 meth H2o. Bled OAP off, monitor well head psi's for 30 min. Final Whp's= vac/90 /0 Page 1 of 1 Nora America' - ALASKA - SP Page 1 ate' Operation Summary Report Common Well Name: H -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 I End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 I Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To Hrs Task Code I NPT 1, NPT Depth Phase ' Description of Operations (hr) I (ft) - 8/29/2011 14:00 - 19:00 ; 5.00 MOB N I RREP PRE PJSM. 4 I i I INSTALL SCOPING RAM IN DERRICK. RIG MOVE FROM K -PAD TO H -PAD. 19:00 - 19:30 0.50 '— MOB P PRE PREP AND SECURE CELLAR AND BOP STACK I i FOR RIG MOVE. 19:30 20:00 0.50 MOB P PRE I PJSM TO MOVE RIG OFF WELL. ■ 20:00 20:30 0.50 MOB , P PRE MOVE RIG OFF WELL. CREW CHANGE. 20:30 - 21:00 I 0.50 MOB P 1 PRE PJSM TO MOVE RIG TO H -PAD. 21:00 - 00:00 3.00 I- MOB P PRE MOVE RIG FROM K -PAD TO H -PAD. 8/30/2011 1 00:00 - 08:30 8.50 MOB P PRE FINISH RIG MOVE FROM K -PAD TO H -PAD. I SPOT RIG ON H -PAD OUT OF THE WAY. 08:30 - 00:00 15.50 MOB N RREP 1 PRE !WAIT FOR INDEPENDENT INVESTIGATION ' CREW TO PERFORM INVESTIGATION ON ' PUMP OVER PRESSURE, POP OFF SHEARING AND LINE PARTING DOWN STREAM OF POP OFF. I FINISHED SCOPING DOWN DERRICK RAM. j REMOVED CATWALK RAM. SPOTTED CUTTINGS BOX. TESTED MUD PUMP CHECK VALVES TO 500 j PSI FOR 30 MINUTES. UNLOADED TRAILERS. CLEAN RIG. 8/31/2011 00:00 - 00:00 24.00 ' MOB N RREP PRE :INDEPENDENT INVESTIGATION. CLEAN RIG AND CHANGE OUT TOTCO SYSTEM. DISASSEMBLED MANUAL CHOKE FOR INSPECTION. WAIT ON ORDERS FROM TOWN. 9/1/2011 00:00 00:00 24.00 MOB N. RREP PRE WAIT ON ORDERS FROM TOWN. CLEAN RIG. REPAIR AIR REGULATOR. - --- SPOTTED NORDIC RIG 2 WELDING SHOP. 9/2/2011 00:00 - 05:00 5.00 MOB N RREP' I PRE WAIT ON ORDERS FROM TOWN. CLEAN RIG. MEASURE AND REMOVE POP OFF LINES. 9/3/2011 00:00 - 00:00 24.00 MOB N RREP I PRE WORK ON FABRICATING AND INSTALLING NEW POP OFF LINES ON RIG PUMPS #1 AND - - -- - - - - -- - #2. SEALING UP AND CLEANING RIG. 9/4/2011 00:00 00:00 1 24.00 MOB N RREP PRE FABRICATING AND INSTALLING NEW POP OFF LINES. PAINTING INSIDE OF RIG AND OUTSIDE OF WELDING SHOP. 9/5/2011 00:00 - 14:00 14.00 MOB N ' RREP PRE FABRICATING AND INSTALLING NEW POP OFF LINES. INSTALL PIPE CLAMPS ON 2" ' j HARDLINE IN PIPE SHED. PAINTING INSIDE OF RIG. 14:00 - 00:00 } 10.00 MOB — N RREP - -- — , PRE INSTALL RUBBER ON PIPE SHED DOOR. X- RAYING WELDS ON POP OFF LINES BEFORE INSTALLATION. 9/6/2011 00:00 - 05:00 5.00 MOB N RREP PRE FABRICATING NEW POP OFF LINES. 1 X- RAYING WELDS ON POP OFF LINES 4 1 BEFORE INSTALLATION. 05:00 18:00 13.00 MOB N RREP PRE 1 WELD FAILED AND HAD TO BE REWELDED. i _ AT 18:00 WE HAVE 5 WELDS LEFT TO XRAY 18:00 - 00:00 6.00 MOB N RREP PRE CONTINUING WITH XRAY OF WELDS BEFORE INSTALLATION ONTO RIG. Printed 9/26/2011 11:40:43AM North America - ALASKA - ; BP Page Operation Summary Report Common Well Name: H -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 I End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA IUWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/7/2011 00:00 - 06:00 6.00 MOB N RREP PRE XRAY WELDS FOR DOWNSTREAM PIPING FROM PUMP PRESSURE RELIEF POP -OFF VALVES 06:00 - 00:00 18.00 MOB N RREP PRE CONTINUE TO XRAY WELDS ON DOWNSTREAM NG TWO WELDS FAIL INSPECTION. RE -W , RE -XRAY. INSTALL PIPING ON PUMP ONE. HYDRO -TEST TO 5000 PSI. PASSED. ALL PIPING PASSED AND ON LOCATION AT MIDNIGHT. PRE INSTALL 9/8/2011 00:00 - 02:00 2.00 MOB N RREP i TALL PIPING. PRESSURE TEST TO 5000 J PSI. GOOD TEST. 02:00 - 06:00 4.00 MOB N RREP PRE INSTALL, WELD SUPPORT BRACKETS FOR PIPING. ' — - - - - - -- 06:00 - 19:00 13.00 MOB N RREP PRE CONTINUED WELDING BRACKETS TO PRESSURE RELIEF LINES FOR MUDPUMPS 1 AND2. WELLS GROUP PREPARED H-04B FOR RIG: GREASED & TESTED TREE VALVES AND SET TWO -WAY CHECK VALVE. 19:00 - 21:00 2.00 MOB N ' RREP PRE CONDUCTED MEETING WITH NORDIC, SLB, AND BP REPRESENTATIVES REGARDING IMPROVED PROCESS FOR OPERATING PUMPS ON RIGS AND AVOIDING ACCIDENTAL OVER- PRESSURING OF POP -OFF VALVES. - SLB SUBMITTED COURSE OF ACTION FOR TESTING AND IMPROVING OPERATOR COMPETENCY. - TEAM AGREED ON IMPORTANCE FOR DECREASING DISTRACTIONS FOR COIL TUBING OPERATOR AND IMPROVING AND INCREASING COMMUNICATIONS BETWEEN COIL OPERATOR AND NORDIC DRILLER WHEN ASSIGNING, UTILIZING, AND SETTING TRIPS FOR PUMPS. - THE USE OF AN ENGINEERING CONTROL AS A REMINDER TO EITHER NOT USE OR TO QUESTION PUMP TRIPS WAS AGREED UPON AND WILL BE IMPLEMENTED ON BOTH RIGS. CALLED IN TO BP CTD LEAD WITH MEETING CONCLUSIONS AND AGREEMENT BY ALL PARTIES THAT NORDIC 1 AND 2 HAD A PLAN TO SAFELY RETURN TO WORK. PERMISSION GRANTED TO RETURN TO WORK. AOGCC GIVEN 24 -HOUR NOTICE FOR BOP TEST ON 1 NORDIC 1. 21:00 - 00:00 3.00 MOB N RREP PRE BEGIN WARMING UP MOVING SYSTEM ON RIG. BEGIN RIG PREP FOR MOVE. MOVE SATELLITE CAMP, WELDING SHOP OUT OF MOVE ROUTE. BEGIN LAYING MATBOARDS 1 DOWN ACROSS UTILIDOR AREA. 9/9/2011 00:00 - 01:00 1.00 MOB N RREP PRE COMPLETE LAYING DOWN MATTING BOARDS. PJSM ON RIG MOVE. IDENTIFY PERSONNEL PLACEMENT, DUTIES. 01:00 - 03:00 2.00 MOB P PRE MOVE RIG OVER H-04B. RIG ACCEPT 0300 HRS. 03:00 - 06:00 3.00 BOPSUR P PRE STAGE WELDING SHOP. NU BOP. RU HARDLINE TO TIGER TANK, PRESSURE TEST. 06:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE, PJSM AND CONTINUE 06:30 - 10:0 3.50 BOPSUR P PRE ; NU SPACER SPOOL, BOP'S, LUBRICATOR 1AND DRIP PAN ON RIG FLOOR Printed 9/26/2011 11:40:43AM North America - ALASKA - BP Page 3 a Operation Summary Report Common Well Name: H -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 8/29/2011 End Date: 1X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To 1 Hrs Task Code NPT I NPT Depth I Phase Description of Operations (hr) I (ft) 10:00 - 10:40 0.67 BOPSUR P PRE NU COMPLETE FLUID PACK STACK AND !SHELL TEST FOR REEL BLOW DOWN i LOU GRIMALDE WAIVED WITNESSING THE BOP TEST 10:40 - 11:00 0.33 RIGU P PRE , PJSM TO BLOW DOWN THE REEL 11:00 - 11:45 0.75 RIGU P PRE PREP TO PU INJECTOR AND MU TO LUBRICATOR 11:45 12:45 1.00 BOPSUR N RREP PRE KR VALVE ACCUMULATOR ON THE KOOMEY 'WAS REPLACED DURING SUMMER MAINTENANCE AND HAS A LEAK. REPLACE 12:45 - 14:00 1.25 RIGU P PRE LINE UP TO PUMP 1 VOLUME OF FRESH WATER THEN 30 BBLS OF INHIBITED WATER AND 5 BBLS OF NEAT METHANOL ■ LINES ARE FLUID PACKED, SHUT IN AND PT, GOOD PT CTS SERVICE QUALITY COACH IS HERE ASSESSING MATT LINK ON HIS PUMPING SKILLS [COOL DOWN N2 - - — 14:00 - 14:30 0.50 RIGU P PRE TALL FLUIDS HAVE BEEN PUMPED, LINE UP TO PUMP N2 AT 1800 SCF /MIN ',COMMENCE PUMPING N2 INTO CT REEL AT — 1,800PSI CIRC PRESSURE. RECEIVED GOOD INDICATION FOR N2 HAVING CLEARED COIL WITH 33BBLS BLOWN DOWN (MEASURED ON "OUT' MM). ISOLATE N2 PUMP AND RIG DOWN. 14:30 - 15:00 0.50 RIGU P ' PRE N2 DOWN ON PUMP ALLOW COIL PRESSURE _ 1 TO BLEED OFF 15:00 - 15:15 0.25 RIGU P PRE HOLD AAR FOR PUMPING OPS AND PJSM FOR UNSTABBING COIL FROM INJECTOR I I HEAD. 15:15 - 15:40 0.42 RIGU P PRE II INJECTOR HEAD FROM RISER AND PICK UP. • CUT OFF NOZZLE, SMOOTH WELDING SEAM AND INSTALL NIGHT CAP. ' INSTALL GRAPPEL CONNECTOR TO UNSTAB COIL. 15:40 - 17:30 1.83 RIGU P PRE PULL OIL BACK TO REEL AND SECURE. 17:30 - 17:40 0.17 RIGU P PRE ;REEL SECURED, PREP TO PULL REEL IRON 1 17:40 - 18:00 0.33 MOB P PRE PERFORM RIG EVAC DRILL WITH DAY CREW 118:00 - 18:15 0.25 RIGU P PRE ' CREW CHANGE 18:15 - 21:30 3.25 RIGU P PRE PREPPING FOR REEL SWAP 21:30 - 00:00 2.50 RIGU P PRE PJSM FOR REEL SWAP. DROP REEL. I TROUBLE GETTING TRUCK TO RELEASE FROM PINTLE IN ORDER TO DROP TRAILER AND PU OTHER TRAILER. RESOLVED. PU NEW TRAILER, SPOT REEL UNDER REELHOUSE. PU, PLACE AND SECURE NEW REEL. ORIENT REEL FOR NEXT OP ERATION. 9/10/2011 00:00 00:30 0.50 RIGU P PRE ORIENTING AND SECURING REEL. STAGE HARD IRON. 00:30 - 01:00 0.50 RIGU ' P PRE RIG EVACUATION DRILL. CREW RESPONSE TIME 2 MIN TO REACH PRE - DETERMINED RIG , 1 4 EVAC SITE. CONDUCT AAR. Printed 9/26/2011 11:40:43AM North America - ALASKA - BP Page 4 Operation Summary Report Common Well Name: H -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay r Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To Hrs ! Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 04:00 3.00 RIGU P PRE PJSM ON PULLING COIL ACROSS. INSTALL GRAPPLE, PULL TEST. PULL ACROSS. STAB INTO INJECTOR. REMOVE GRAPPLE, SET INJECTOR OFF TO SIDE. BEGIN MU INNER REEL IRON, INSTALL PRESSURE BULKHEAD, TEST E -LINE. 04:00 - 06:00 2.00 BOPSUR N HMAN O BOP PRE PREP TO CONDUCT BOP TEST. AOGCC INSPECTOR LOU GRIMALDI WAIVED WITNESS. VISUAL INSPECTION OF EQUIPMENT, BEGIN TEST OF VALVES. 06:00 - 07:00 1.00 BOPSUR N HMAN PRE CREW CHANGE, PJSM TO CONTINUE _TESTING BOPE 07:00 - 10:00 3.00 BOPSUR N RREP PRE PRIOR TO TESTING CHOKE VALVE #11 THE VALVE WAS FUNCTIONED AND A GRINDING WAS NOTICED. PULLED VALVE TO INSPECT AND THE PLATE INSIDE IS SCARRED, DUE TO THE PLATE BEING INSTALLED UPSIDE -DOWN 'AFTER BEING REBUILT IN TOWN. VALVE 1 WAS REBUILT AND TESTED GOOD. 10:00 - 11:00 1.00 BOPSUR N HMAN PRE PT REBUILT VALVE CHOKE VALVE 11:00 - 13:25 2.42 BOPSUR P PRE CONTINUE TESTING BOPE 1 13:25 - 17:00 3.58 BOPSUR P PRE KICK WHILE DRILLING DRILL W/ PACK -OFF FAILURE AFTER SHUT IN. CONTINUE BOP TEST 17:00 - 17:25 0.42 BOPSUR P PRE I BOP TEST COMPLETED BOP'S FUNCTION TESTED FROM BOTH 'STATIONS DRAW DOWN TEST SYSTEM PRESSURE = 3100 PSI 12000 PSI AFTER SHUT IN 19 SEC FOR 1ST 200 PSI TO 2200 PSI + 108 SEC TO FULL SYSTEM RECOVERY 17:25 - 20:30 3.08 RIGU P PRE PREP FLOOR TO CHANGE PACK OFF, MU CTC AND BHI UQC. CONDUCT PULL TEST TO 35K. PULL TEST FAILED. CUT OFF CTC. PREP COIL, RE- INSTALL CTC. CONDUCT PULL TEST TO 35K. GOOD TEST. MU BHI UQC. TEST ELECTRICAL. 20:30 - 23:45 3.25 RIGU P PRE PRESSURE TEST QTS. PRESSURE TEST INNER REEL IRON. FLUID PACK REEL, PUMP SLACK FORWARD. PRESSURE TEST PACKOFFS AND INNER REEL VALVE. POP OFF FROM LUBRICATOR, PRESSURE TEST UQC. INSTALL DOUBLE CHECK VALVES. PRESSURE TEST. 23:45 00:00 0.25 BOPSUR P PRE MOBILIZE LUBRICATOR TO RIG FLOOR 9/11/2011 00:00 00:30 0.50 BOPSUR P PRE MOBILIZE LUBRICATOR TO RIG FLOOR. 00:30 02:00 1.50 BOPSUR P PRE ' NU LUBRICATOR. PRESSURE TEST LUBRICATOR TO 250 LOW, 3500 HIGH. GOOD TEST. Printed 9/26/2011 11:40:43AM North America - ALASKA - BP Page 5 afi Operation Summary Report Common Well Name: H -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 'I Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date I From - To Hrs Task Code I NPT NPT Depth Phase , Description of Operations (hr) (ft) 02:00 - 04 :45 ! 2.75 BOPSUR P I PRE PULL TWC. UNABLE TO PU TWC PULLING TOOL WITH TWC ON IT PAST SWAB VALVE DUE TO "J" STYLE PLUG AND LUBRICATOR CONFIGURATION. CLOSE MASTER VALVE. WELLS GROUP POLICY CALLS FOR CLOSING SSV IN CONJUNCTION WITH INDEPENDENTLY TESTED MASTER VALVE. CONSULTED WITH DWOP, REQUIRES TWO INDEPENDENT BARRIERS FOR OPERATION. CRACK MASTER, NO PRESSURE ON WELL. CONSULT WITH TOWN. DECISION IS TO USE WELLS GROUP SOP TO CLOSE SSV AND I MASTER. ND LUBRICATOR, NO TWC. 1PULLING TOOL PACKED OFF WITH VERY HARD GREASE. CLEAN TOOL. 04:45 - 06:00 1.25 BOPSUR P PRE MU NOZZLE ASSEMBLY. MU TO INJECTOR, PT QTS. RIH, CIRCULATE ABOVE TWC TO CLEAN ABOVE TWC. BREAK OFF FROM ' LUBRICATOR AND STAND BACK INJECTOR. 06:00 - 08:00 2.00 BOPSUR P PRE I MU LUBRICATOR AND PRESSURE TEST. RIH, RETRIEVE TWC. 150 PSI ON WELL. CLOSE MASTER, SSV. ND LUBRICATOR. 08:00 - 08:20 0.33 BOPSUR P PRE ORDER 50 BBLS HI -VIS PILL TO 08:20 - 08:45 0.42 BOPSUR P PRE I GOOD TEST AGAINST MASTER, BLEED OFF AND CLOSE SSV FOR LEAK TIGHT TEST 08:45 - 09:00 0.25 BOPSUR N SFAL I PRE GOOD LTT, PU LUBRICATOR AND TWC RETRIEVED BUT LEFT ONE OF THE LARGE SEALS IN THE WELL. CALL ODE AND SUCK OUT STACK. CALL OUT FOR VENTURI JUNK 1 BASKET BHA WHILE SUCKING OUT STACK - - - - - -- - - -- --- - - - - -- - - -- - -- -- - 09:00 - 10:00 1.00 BOPSUR N UFAL PRE SUCKED OUT STACK AND SAW 1 PIECE OF WIRE STICKING OUT OF THE FLUID ON TOP OF THE SWAB VALVE. FRAYED THE END OF A 30' CHUNK OF ELINE AND LOWERED IT INTO THE STACK AND RETRIEVED -1/3 OF ITHE MISSING SEAL. TRIED TWISTING AND TURNING THE ELINE ON TOP OF THE SWAB AGAIN TO SEE IF WE COULD GRAB ANYMORE BUT DID NOT GET ANYMORE. FUNCTIONED THE BOP RAMS TO SEE IF IT WAS IN ONE OF THE CAVITIES AND THEY WERE CLEAN. WO VENTURI JUNK BASKET IBHA 10:00 - 11:30 1.50 BOPSUR N SFAL PRE WO TOOLS AND PT NIGHT CAP 11 :30 11:45 0.25 BOPSUR N SFAL PRE 1 TOOLS ON LOCATION, LOAD ON RIGH THEN HOLD PJSM FOR VENTURI BHA 11:45 12:05 0.33 BOPSUR N SFAL PRE PJSM TO OPEN UP WELL AND BH KILL WELL 12:05 - 12:20 0.25 BOPSUR N SFAL PRE OPEN SWAB AND MASTER, WHP AT 140 PSI. CRACK CHOKE TAKING RETURNS TO TIGER TANK TO SEE IF WE HAVE GAS OR FLUID AND IF WHP BLEEDS OFF 12:20 - 12:30 0.17 BOPSUR N SFAL PRE GAS CAP ON WELL WITH SLIGHT BLEED OFF, LINE UP TO KILL WELL 5 BBLS NEAT METH FOLLOWED BY 375 BBLS OF KCL 6.1 BPM @1735 WHP - Printed 9/26/2011 11:40:43AM Nora America ALASKA - BP Page 6 toPM Operation Summary Report Common Well Name: H -04 1 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 12:55 0.42 BOPSUR . N SFAL r PRE 70 BBLS INTO KILL MOTORMAN NEEDS US TO REDUCE OUR RATE TO INVESTIGATE WHY GEN #1 IS GETTING HOT. CIRCULATED 30 BBLS AT REDUCED RATE (3.0 BPM) SHUT DOWN PUMPS, GEN #1 TURBO ON MOTOR IS TURNING CHERRY RED 12:55 - 13:10 0.25 BOPSUR N SFAL PRE AFTER TOOLPUSHER CONFIRMED THAT BOTH GENERATRORS WERE OPERATING WITHIN PARAMETERS HE WANTED TO BRING PUMPS BACKUP TO RATE AGAIN, ZERO BBL COUNTERS RIG GENERATORS OPERATING AT 41% POWER AT 6 BPM 13:10 13:30 0.33 BOPSUR N RREP PRE SLOW DOWN PUMP RATES TP WANTS TO REDUCE RATE TO DROP GEN #1, TURBO GETTING HOT. MM CALLED FOR ESD TO BE ACTIVATED TO SHUT DOWN RIG. THE CTS FS SHUT DOWN THE PUMPS AND THE ESD WAS ACTIVATED. I CALLED OUT FOR THE DRILLER TO SHUT IN THE WELL BUT DID NOT GET A RESPONSE, THE CTS FS REPEATED THE ORDER AND HE DID NOT GET A RESPONSE EITHER AND THEN HE CALLED FOR HIS , HAND TO SECURE THE WELL BY CLOSING THE SWAB AND MASTER VALVES. THE WELL WAS SECURED AND I LEFT THE OPS CAB TO GO TO THE MOTOR ROOM TO SEE WHAT HAPPENED. AFTER ACCESSING THE SITUATION I MADE CALLS TO 5300 TO REPORT THE FIRE AND THE DISCHARGE OF A FIRE EXTINGUISHER. I THEN CALLED KEN MILLER WHO CALLED THE ADW SAFETY OFFICER AND THEN I CALLED THE GC2 OTL. INCIDENT REPORT: 2011 -IR- 3940535 13:30 - 21:00 7.50 BOPSUR N RREP PRE INVESTIGATE GENERATOR PROBLEMS. MAKE AREA SAFE. ON STANDBY WHILE WAITING ON PARTS. THE FIRE CHIEF AND BP SAFETY OFFICER ARRIVED ON LOCATION AND ASSESSED THE SITUATION. 21:00 - 23:30 2.50 BOPSUR N , RREP PRE CHECK VALVE LINE -UPS, INSPECT TREE, INSPECT CHOKE MANIFOLD. LINE UP TO PUMP 50/50 METHANOL FOR FREEZE PROTECT. PUMP ACROSS TOP WITH VALVES CLOSED UNTIL RETURNS ARE ESTABLISHED WITH METHANOL RETURNS THROUGH CHOKE TO TIGER TANK. OPEN UP SWAB AND MASTER, NO PRESSURE ON WELL. RETURNS AT 20 BBLS. BULLHEAD 60 BBLS METHANOL AT 3 BPM, 1160 -1185 PSI, TO FREEZE PROTECT TO 2500'. FINAL CIRCULATING PRESSURE AT 1140 PSI, IA AT 70 PSI. DOWN ON PUMPS, CLOSE VALVES. 23:30 - 00:00 0.50 BOPSUR N RREP PRE ON STANDBY WHILE WAITING FOR PART FOR GENERATOR. 9/12/2011 00:00 - 04:30 4.50 BOPSUR N RREP PRE WAIT ON GENERATOR PARTS . 04:30 - 04:35 0.08 BOPSUR N RREP PRE LINE UP TO PUMP. OPEN UP WELL. NO PRESSURE ON WELL. BRING ON PUMPS TO 2.P BPM, 280 PSI. 11 BBLS TO GET 1 RETURNS. LOSS RATE OF 2.2 BPH. SECURE WELL Printed 9/26/2011 11:40:43AM Page 7 eta North America - ALASKA - BP Operation Summary Report Common Well Name: H -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth Phase Description of Operations 04:35 - 06:00 1.42 BOPSUR N RREP PRE 1 , WAIT ON GENERATOR PARTS 06:00 - 09:00 3.00 BOPSUR N RREP PRE CONTINUE WAITING ON GENERATOR PARTS 09:00 - 14:00 5.00 BOPSUR N RREP PRE WELL WORK SHUT DOWN FOR ENGINE ROOM FIRE INVESTIGATION 14:00 - 14:20 0.33 BOPSUR N RREP PRE RAISED CT INJECTOR HEAD ON FEET IN !PREPARATION FOR SLICKLINE TO RIG UP. 14:20 - 16:00 1.67 BOPSUR N RREP PRE WAITING FOR SL TO ARRIVE ON PAD. 16:00 - 16:10 0.17 BOPSUR N RREP PRE SL MOVE IN ON PAD. 16:10 - 17:00 0.83 BOPSUR N RREP PRE I REMOVE RIG'S OUTSIDE STAIRS. -L- - -- — - - � -- - -- - 17:00 - 18:00 1.00 BOPSUR N RREP PRE HOLD PJSM AND LIFT SLB LIFTING W /LINE GEAR UP TO RIG FLOOR. 18:00 - 22:00 4.00 BOPSUR N RREP PRE ORDER OUT FLUIDS TO KILL WELL. HOLD MEETING WITH SLB, DRILLER, CTD DRILLER TO DISCUSS PLAN FORWARD. CREW I CHANGE OUT AT 2000, CONDUCT RIG BRIEF OF PAST EVENTS. 22:00 - 00:00 2.00 BOPSUR N RREP PRE FLUID ON LOCATION. LINE UP TRUCK WHILE PREPARATION FOR WELL KILL. 400 PSI TRAPPED PRESSURE BETWEEN SWAB AND CHOKE. BLEED TO TIGER TANK. BEGIN LINE UP FOR WELL KILL. ATTEMPT TO PRESSURE TEST NIGHT CAP AGAINST SWAB. FAILED. 1 GREASE CREW ALREADY ON LOCATION, CALLED OVER FOR SERVICE. SERVICE BOTH SWAB AND MASTER. TEST VALVES, GOOD. 9/13/2011 1 00:00 - 03:15 3.25 BOPSUR yl N RREP PRE ; OPEN UP WELL. 450PSI ON WELL. ' BULLHEADED KILL WELL WITH 5BBLS NEAT IAHEAD. BRING PUMP UP TO 4.25BPM. INITIAL IA PRESSURE 130PSI, TBG PRESSURE 540PSI. FLUID CAUGHT 15BBLS IN. MAINTAIN 4.25BPM, ICP 1210PSI, MAX 2100PSI, FCP 1230 PSI. FINAL IA AT 581 PSI. 480 BBLS PUMPED TOTAL DUE TO LOWER PUMP RATE. MONITOR WELL. WELL DEAD. PUMP ACROSS TOP, TOOK 12BBLS TO FILL. FLUID LOSSES I AT 11 BPH. PUMP ACRSS TOP TO KEEP HOLE FULL. 03:15 - 03:45 I 0.50 BOPSUR N RREP PRE [PJSM WITH SLB ON MOBILIZING AND MU OF LUBRICATOR AND JUNK BASKET BHA. 03:45 04:15 0.50 BOPSUR N RREP I - . � PRE � MOBILIZE SLB JUNK BASKET BHA TO RIG _ I I FLOOR. 04:15 - 06:00 1.75 BOPSUR N RREP PRE PRESSURE TEST MASTER AND SWAB VALVES. RU LUBRICATOR. PRRESSURE TEST I LUBRICATOR ASSEMBLY AND QTS. 06:00 - 09:00 3.00 BOPSUR N RREP PRE DO SLB CREW CHANGE, HOLD PJSM AND MU SLICKLINE TOOLSTRING #1 CAN 4.5" OD JUNK BASKET. 09:00 - 09:40 0.67 BOPSUR N RREP PRE FILL LUBRICATOR WITH FLUID AND SUCCESSFULLY PRESSURE TEST TO 300PSV5MIN AND 3,500PSV5MIN. 09:40 - 11:00 1.33 BOPSUR N RREP PRE OPEN SWAB VALVE AND MV - NO WHP. I FILL UP WELL WITH 24BBLS WHICH EQUALS A LOSS -RATE OF 5.3BBLS/HR (WELL WAS S/I BETWEEN 05:10AM AND 09:40AM). CIRCULATE ACROSS MUDCROSS. Printed 9/26/2011 11:40:43AM North America - ALASKA - BP Page g er Operation Summary Report Common Well Name: H -04 I AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:30 1.50 BOPSUR N RREP PRE RIG WITH JNUK BASKET TO 5 V2" X 4 1/2" TBG XOVER, WHILST CIRCULATING ACROSS MUCROSS. 286BBLS PVT @ 11:00HRS. 12:30 - 13:00 0.50 j BOPSUR N RREP PRE SLICKLINE OOH. CLOSE MV AND PRESSURE -TEST TO 300PSV65MIN AND 3,500PSV5MIN. 269BBL PVT @ 12:30HRS, INDICATING — 0.2BPM LOSS - RATE. 13:00 - 13:20 0.33 BOPSUR N RREP i PRE CLOSE SWAB VALVE AND PRESSURE -TEST TO 300PSV5MIN AND 3,500PSV5MIN. 13:20 - 13:30 0.17 BOPSUR N RREP PRE BLEED OFF PRESSURE, POP LUBRICATOR. '; BREAK OUT JNUK BASKET. JUNK BASKET EMPTY, NO REMAINING PARTS OFF THE TWC VALVE'S SEAL RING RECOVERED. 13:30 - 14:00 0.50 BOPSUR N RREP PRE M/U SLICKLINE TS#2 C/W WIRE -BRUSH AND 4.54" OD GAUGE" RING. STAB ON LUBRICATOR AND PRESSURE -TEST IN SITU SUB TO 300PSV5MIN AND 3,500PSV5MIN. 14:00 16:00 2.00 BOPSUR N RREP PRE I OPEN UP SWAB VALVE AND MV AND RIG WITH WIRE -BRUSH AND GAUGE RING TO LCLEAN X- NIPPLE PROFILE @ 9,363FT. 16:00 - 16:30 0.50 BOPSUR N RREP PRE 1 SLICKLINE TS #2 OOH. 239BBL PVT @ 16:00HRS, INDICATING -- 0.25BPM LOSS -RATE. CLOSE MASTER VALVE AND PRESSURE -TEST TO 300PSV5MIN AND 3,500PSV5MIN. 16:30 - 17:00 0.50 BOPSUR N RREP PRE CLOSE SWAB VALVE AND PRESSURE -TEST TO 300PSV5MIN AND 3,500PSV5MIN. 17:00 - 17:40 0.67 BOPSUR N RREP PRE POP LUBRICATOR AND B/OUT WIRE- BRUSH. FIND FAIR -SIZED PIECE OF THE LOST SEAL -RING IN WIRE- BRUSH. DECIDE TO MODIFY THE WIRE -BRUSH SLIGHTLY (1 7/8" BODY TO ALLOW FOR LONGER WIRES) AND RE -RUN BRUSH IN ATTEMPT TO RECOVER REMAINING PIECES OF SEAL -RING. 17:40 - 18:00 0.33 BOPSUR N RREP PRE ! M/U SLICKLINE TS#3 C/W WIRE -BRUSH AND 14.54" OF GAUGE RING. STAB ON LUBRICATOR AND PRESSURE -TEST IN -SITU _ j SUB TO 300PSV5MIN AND 3,500PSV5MIN. 18:00 - 20:30 2.50 BOPSUR N RREP PRE 1 OPEN UP SWAB VALVE AND MV AND RERUN WIRE -BRUSH AND GAUGE RING TO CLEAN TBG. KEEP TBG FLUID - FILLED BY PUMPING 'ACROSS MUDCROSS WITH CHARGE PUMP AT LOW RATE. 20:30 - 21:30 1.00 BOPSUR N RREP PRE BRUSH BHA AT SURFACE. FLUID LEVEL, RETURNS TO SHAKERS. 21:30 - 22:30 1.00 BOPSUR N RREP PRE PRESSURE -TEST AGAINST CLOSED MASTER AND SWAB. GOOD TEST. POP OFF SLB i WIRELINE LUBRICATOR. 22:30 - 22:45 0.25 BOPSUR N I RREP PRE OPEN VALVES, NO PRESSURE ON WELL. BEGIN TO CIRCULATE TO FILL HOLE AND ESTABLISH LOSS -RATE, GAS ON LEL. SHUT IN TO LINE UP TO TIGER TANK. CIRCULATE AND CATCH RETURNS AT 19BBLS WITH NO SHOW ON LEL. CONTINUE CIRCULATING ACROSS TOP, LINE UP TO PITS, NO LEL. 22:45 - 23:40 I 0.92 BOPSUR N RREP PRE RIH WITH 2.70" DRIFT BHA ON WIRELINE I WHILE PUMPING AT 0.25BPM ACROSS TOP. RIG TO 11,550FT WITH NO PROBLEMS. Printed 9/26/2011 11:40:43AM North America - ALASKA BP Page 9 efeS Operation Summary Report Common Well Name: H -04 — AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) 1 .. Project: Prudhoe Bay ' Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 23:40 - 00:00 0.33 BOPSUR N RREP PRE POH WITH DRIFT ASSEMBLY 9/14/2011 00:00 - 00:30 0.50 BOPSUR N ' RREP PRE POH WITH BRIFTASSEMBLY. 00:30 01:40 1.17 BOPSUR N RREP PRE TEST MASTER AND SWAB VALVE. GOOD TESTS. 01:40 02:50 1.17 BOPSUR N RREP PRE LINE UP TO PUMP FREEZE PROTECT. OPEN VALVES, NO PRESSURE ON WELL. PUMP 50/50 MEATHANOL DOWN ON TOP OF KCL FLUID PACK AT 3.4BPM AGAINST CLOSED CHOKE. CATCH FLUID AT 15BBLS IN. CONTINUE TO PUMP AT 3.25BPM, ICP 450PSI N CO UE , FCP 1080PSI AT 5OBBLS AWAY. SLOWLY BEGIN TO STAGE DOWN ON PUMPS FOR LAST 1 OBBLS. 60BBLS 50/50 METHANOL PUMPED, FINAL RATE 1.50 BPM, FCP 750PSI. DOWN ON PUMPS. MONITOR WELL, NO I PRESSURE ON WELL AND NO FLOW. 02:50 - 04:15 1.42 BOPSUR N RREP PRE CLOSE MASTER AND SWAB AND PT. LD DRIFT BHA, MU 5 -1/2" XX PLUG BHA. MU - - -- ------ - - - - -- LUBRICATOR. PT QTS. GOOD TEST. 04:15 - 06:00 1.75 BOPSUR N RREP PRE I OPEN VALVES. NO PRESSURE ON WELL. RIG WITH 5-1/2" XX PLUG BHA TO 5900FT (AS OF 0515HRS). 06:00 - 08:00 2.00 BOPSUR N RREP PRE SET PLUG IN X- NIPPLE PROFILE @ 9,381 FT SLICKLINE MEASUREMENT. RECEIVED CLEAR INDICATION (WEIGHT LOSS ON 1 WEIGHT INDICATOR), THAT PLUG WAS SET SUCCESSFULLY. POOH INTO LUBRICATOR. 08:00 - 08:45 0.75 BOPSUR N RREP PRE 1 LINE UP AND FLUID -PACK THE TBG ABOVE THE PLUG WITH 22BBLS OF 50/50 METHANOL. PRESSURE -TEST PLUG TO 200PSV5MIN AND 3,500PSV5MIN - ACHIEVE 08:45 - 09:15 0.50 BOPSUR N + RREP GOOD TEST. PRE CLOSE MASTER VALVE AND PERFORM PRESSURE -TEST TO 200PSV5MIN AND 3,500PSV5MIN - ACHIEVE GOOD TEST. WELL NOW HAS 2 PROVEN BARRIERS.CLOSE SWAB VALVE. MEANWHILE INVESTIGATION TEAM ARRIVES AT RIG TO START "PRIMARY INVESTIGATION. 09:15 - 09:45 0.50 BOPSUR N RREP PRE TEST SWAB VALVE TO 200PSV5MIN AND 3,500PSV5MIN - ACHIEVE GOOD TEST. 109:45 11:15 1.50 BOPSUR N RREP PRE HOLD PJSM AND RIG DOWN SLICKLINE EQUIPMENT. LEAVE WELL WITH TRASHCAP 13:15 2.00 BOPSUR N RREP_ ON RISER. 11:15 - ! PRE IFREEZE- PROTECT CIL WITH 866LS OF NEAT 1METHANOL. 13:15 RREP 18:00 4.75 BOPSUR N PRE HALT OPERATIONS WHILST WAITING FOR GENERATOR #1 - REPAIR AND OUTCOME OF INVESTIGATION. 6.00 BOPSUR N RREP t 18:00 - 00:00 PRE CONDUCT CREW CHANGE. REFINE AND UPDATE BOP - TESTING PROCEDURE. 9/15/2011 00:00 06:00 6.00 BOPSUR j N RREP PRE WORK ON UPDATING BOP - TESTING PROCEDURE. REPLACE BLUE WINCH. 06:00 - 00:00 18.00 BOPSUR N RREP PRE GENERATOR TURBO FIRE INVESTIGATION. RESULTS PENDING. WAITING ON ORDERS TO RESUME WORK. Printed 9/26/2011 11:40:43AM North America - ALASKA - BP Page 10> Operation Summary Report Common Well Name: H-04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay , Site: PB H Pad Rig Name /No.: NORDIC 1 I Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 @64.40ft (above Mean Sea Level) Date From - To Hrs Task I Code NPT • NPT Depth I Phase Description of Operations 9/16/2011 00:00 - 07:00 7.00 BOPSUB N RREP (ft) PRE CONTINUE TO WAIT ON APPROVAL TO GO BACK TO WORK BASED ON INVESTIGATION FINDINGS. 07:00 - 08:00 1.00 BOPSUB N PRE BODY TEST ON BOP, WAITING ON AOGCC TO !COMMENCE TEST. 08:00 - 09:30 1.50 BOPSUB N PRE ;COMMENCE BOPE TEST..., SWAB VALVE APPEARS TO BE LEAKING. 09:30 11:00 1.50 BOPSUB N SFAL PRE CALL FOR GREASE CREW. 11:00 - 12:30 1.50 BOPSUB N SFAL PRE GREASE SWAB AND MASTER VALVES. 12:30 - 14:00 1.50 BOPSUB N PRE ATTEMPT TO TEST, SWAB VALVE LEAKING. - ATTEMPT TO TEST AGAINST MASTER VALVE. 14:00 - 14:30 0.50 BOPSUB N PRE GREASE PACK BOTH VALVES. 14:30 - 16:00 1.50 BOPSUB N PRE I CANNOT ACHIEVE ANY GOOD TESTS. - CALL OUT FOR CREW TO SET TWO WAY 16:30 0.50 BOPSUB N SFAL 'CHECK J OB SAFETY MEETING ON PICKING UP . 16:00 - PRE I I PRE JOB AND TOOLS. 16:30 - 17:30 1.00 BOPSUB N SFAL PRE I PICK UP LUBRICATOR AND TOOLS. 17:30 - 18:30 1.00 BOPSUB N SFAL PRE 1 PRESSURE TEST LUBRICATOR, PRESSURE TEST TWO WAY CHECK VALVE. { 250 / 3500 PSI, 5 MIN EACH. 18:30 20:00 1.50 BOPSUB N PRE j R/D LUBRICATOR, FILL TREE, CONDUCT FULL BODY TEST. - 250 / 3500 PSI, OK. NOTIFY AOGCC REP JEFF JONES. 20:00 - 00:00 4.00 BOPSUB N PRE RESUME TESTING BOPE AS PER AOGCC. 9/17/2011 00:00 - 11:00 11.00 BOPSUR N PRE CONTINUE TO TEST BOPE. - TEST ALL CHOKE VALVES AND MUD CROSS VALVE 250 - 3500 PSV - TEST COMBI RAMS AND BLIND SHEARS @ 250 - 3500 PSI. - TEST ANNULAR PREVENTOR @ 250 - 2500 PSI. 5 MIN STABALIZED EACH. - (1) FAILURE, KILL LINE SIDE CHECK VALVE, REBUILT SAME. - STATE AOGCC INSPECTOR. JEFF JONES ' WITNESSED FIRST HALF OF TEST. - PERFORMED DRAWDOWN TEST ON ACCUMULATOR. - ALL FUNCTIONS PERFORMED FROM NORDIC DRILLER'S REMOTE CONTROL I PANEL. 11 :00 - 14:30 3.50 BOPSUR N PRE I PICK UP INJECTOR, PRESSURE TEST INNER REEL VALVE AND PACKOFFS. - 250 / 3500 PSI, 5 MIN EACH. 1 - STAND BACK INJECTOR. 14:30 - 17:00 2.50 BOPSUR N PRE 1 PJSM WITH VALVE CREW. - PICK UP LUBRICATOR & MAKE UP TO WELL. - PRESSURE TEST LUBRICATOR, 250 / 3500 PSI, 5 MIN EACH, OK. - PULL TWO WAY CHECK, NO PRESSURE j BELOW TWO WAY CHECK. - UD LUBRICATOR AND VALVE SHOP TOOLS. - SENT 0 RING PIECES W/ VALVE CREW FOR EVALUATION. - VALVE CREW REPORTED VIRTUALLY 100% RECOVERY ON 0 RING. Printed 9/26/2011 11:40:43AM North America - ALASKA - BP Page 11 eddit Operation Summary Report Common Well Name: H -04 ` i AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay I Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 ©64.40ft (above Mean Sea Level) Date From - To I Hrs Task I Code NPT I NPT Depth Phase I Description of Operations (hr) 1 (ft) 17:00 - 18:30 1 1.50 FISH N I WEXIT CLEAR AND CLEAN RIG FLOOR. CONDUCT CREW CHANGEOUT. BAKER HAND ON LOCATION. RU TO PRESSURE TEST CHECK VALVES. 118:30 - 20:30 2.00 FISH N WEXIT PRESSURE TEST CHECK VALVES. FAILED. REPLACE CHECK VALVES. PRESSURE TEST GOOD. MU NIGHTCAP, PT. PJSM ON BHA MU , WHILE PRESSURE TESTING. GOOD TEST. OPEN VALVES, MONITOR WELL. STATIC. 20:30 - 21:30 I 1.00 FISH N WEXIT MU PLUG RETRIEVAL BHA: 4 -1/2" XX PRONG, 5' GS SPEAR, DUAL JARS, XO, BLIND SUB, ; DPS, EDC, POWERCOMMS, WEAR SUB, LQC, 1 UQC, CTC. MU TO IN JECTOR. PT QTS. 21:30 - 23:30 2.00 FISH N I WEXIT PJSM ON RUNNING IN HOLE WHILE PT QTS. 1 1 ITESTTRIPS ON BOTH PUMPS. RIH WITH RETRIEVAL BHA. ERRATIC MM READINGS WHILE RIH. WEIGHT CHECK AT 9200' 25K. 23:30 - 00:00 0.50 FISH 1 N fi WEXIT OPEN EDC. CIRCULATE BU TO GET 8.4 PPG 1 I KCL ALL THE WAY AROUND. HOLD PJSM ON I I PULLING PLUG, BULLHEAD OPERATIONS, I PULLING UP HOLE TO AVOID SWABBING I ! WHILE CIRCULATING. 9/18/2011 00:00 01:30 I I- 1.50 FISH N WEXIT CIRCULATE BU TO GET 8.4 PPG KCL ALL THE 1 'WAY AROUND. CONFIRMED GAS RETURNS TO TIGER TANK, MONITOR DOWN STREAM 1 AND WELLHEAD PRESSURE. FULL DENSITY ' AT 210 BBLS, 8.4 PPG IN AND OUT. 1 i CONTINUE TO TAKE RETURNS TO TIGER , I TANK FOR ADDITIONAL 15 BBLS. TAKE 4 11RE TURNS TO PITS, CLEAN. 01:30 - 03:15 1.75 FISH i N WEXIT I WAITING ON TRUCK TO ARRIVE WITH ,ADDITIONAL KCL BEFORE PULLING PLUG AND BEGINNING BULLHEAD OPS. CONTINUE TO CIRCULATE WHILE WAITING. CONDUCT I PJSM ON BULLHEADING, POH WITH PLUG HOLDING BACKPRESSURE TO PREVENT SWABBING. OBTAIN AND RECORD SLOW — PUMP RATES. 03:15 - 05:00 ! 1.75 FISH 1 N WEXIT 1 KCL ON LOCATION, LINE UP TRUCK TO RIG. CLOSE EDC. RIH FROM 9300'. TAG AT 9376' COIL TUBING DEPTH. SET DOWN 2.5K. PU 1 10' PUW 25K. COME ON LINE WITH PUMPS I DOWN BACKSIDE, STAGE UP TO 4 BPM, ICP 1 1260 PSI, FCP 1180 WITH 110 BBLS AWAY. 1 DOWN ON PUMPS. MONITOR WELL. NO ' I PRESSURE. LOSSES ESTABLISHED AT 6 BPH. 05:00 - 09:00 4.00 FISH N ' WEXIT I LINE UP THROUGH CHOKE. POH AT 20 FPM, 1 BPM IN, .6 BPM OUT, HOLDING 250 -260 PSI. I INCREASE PULLING UP HOLE TO 50 FPM, I I I 1.15 BPM IN, .63 BPM OUT, 280 PSI BACK PRESSURE. 60 BBLS LOST DURING POH. CONDUCT AAR OF LATCHING INTO PLUG, BULLHEADING OPERATION WHILE POH. ■ 1 09:00 - 10:00 1.00 1 FISH N WEXIT PJSM. MONITOR WELL, 15 MINUTES, WELL STABLE. FILL HOLE, 3 BBLS TO FILL. - RESIDUAL GAS IN LUBRICATOR, FLUSH ' OUT SAME. - UD BHA, PLUG RETRIEVED, LAY DOWN lb 1 SAME. Printed 9/26/2011 11:40:43AM North America ALASKA - BP Page 12 etEg Operation Summary Report Common Well Name: 1404 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:OOAM Rig Release: Rig Contractor NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 ©64.40ft (above Mean Sea Level) Date From - To I Hrs Task I Code I NPT NPT Depth I Phase Description of Operations (hr) ( ft) 10:00 - 10:30 0.50 STWHIP N WEXIT M/U NIGHT CAP, PT AGAINST MASTER VALVE, NO VISIBLE LEAKS, OK. - FILL HOLE ACROSS THE TOP. DETERMINE 4 I LOSS RATE, 12 - 15 BBLS / HR. 10:30 - 12:00 1.50 STWHIP j N WEXIT P/U INJECTOR. PRESSURE TEST COIL CONNECTOR, 250 / 4000 PSI, GOOD. - M/U BAKER DUAL CHECK VALVES, TEST, NO GOOD. i- RETEST W / TEST PUMP, GOOD. BREAK DOWN CHECKS, EXAMINE AND CLEAN GREASE OFF 0 RINGS. M/U BAKER DUAL CHECK VALVES, TEST @ 250 / 3500 PSI, 5 MIN EACH, GOOD. 12:00 - 13:30 1.50 STWHIP P WEXIT PJSM. M/U BAKER WHIPSTOCK BHA. - WHIPSTOCK SCRIBED TO THE HOT. '- P/U INJECTOR, M/U TO WELL. - FILL PITS, TAKE PHYSICAL MEASUREMENT AS WELL AS PVT. 13:30 - 16:30 3.00 STWHIP P WEXIT RIH W/ BAKER WHIPSTOCK ASSEMBLY ON 2" COIL. PUMPING .8 BPM / 350 PSI, RUNNING IN @ 70 FPM. 16:30 - 19:30 3.00 STWHIP P WEXIT ;LOGGING DOWN (GAMMA) F/ 11,140' @ 100' / HR - LOG TO 11,393.7ft - TIE IN AND CORRECT DEPTH WITH - 26.5'_ 19:30 - 19:50 0.33 STWHIP P WEXIT I PUH TO 11 250' AND PERFORM CCL -LOG. OBSERVE GAS IN RETURN E TO TIGER TANK. PU AND CLOSE EDC. ' 19:50 - 20:20 0.50 STWHIP P WEXIT ,SFT WHIPSTOCK WITH 11 5nFA ROHS TOWS AT11,351FT. 20:20 - 22:00 1.67 STWHIP P WEXIT PICK UP HOLE TO 11,349', CIRCULATE BOTTOMS UP TO CIRCULATE GAS OUT OF WELL. CALL ENGINEER TO DISCUSS DISPLACING TO MUD. CALL OUT MUD FROM PLANT. 22:00 - 00:00 2.00 STWHIP P WEXIT CONTINUE PUMPING KCL TO CIRCULATE I GAS OUT WELL. TOTAL VOLUME KCL CIRCULATED: 700BBLS. 9/19/2011 00:00 - 03:10 3.17 STWHIP P WEXIT COMMENCE PUMPING BU WITH 8.6PPG QUIK- DRILL. STILL OBSERVE 120 - 60 ON LEL WHEN ATTEMPTING TO FLOW CHECK AND CIRCULATE ACROSS SHAKERS. LINE UP TO TIGER TANK. 03:10 - 04:00 0.83 STWHIP P WEXIT GET SLOW PUMP - RATES, FILL GAS BUSTER, CLOSE IN AGAINST CHOKE, HOLD 150- 200PSI BACK PRESSURE AND FLOW THROUGH GAS IBUSTER. RETURNS ARE GOOD BUT DENSITY OF MUD "IN" IS 8.5PPG, WHILST MUD "OUT" IS ONLY 7.37PPG TO 7.60PPG FOR 5OBBLS. PUMP AT 10.5BPM WITH 165PSI WHP. Printed 9/26/2011 11:40:43AM North America - ALASKA - BP Page 1340 Operation Summary Report Common Well Name: H -04 — AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 ©64.40ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (ft) 04:00 - 05:00 1.00 STWHIP P WEXIT LINE UP WELL TO TIGER TANK AND FULLY OPEN UP. CLOSE IN PUMPS AND PERFORM FLOWCHECK - WELL APPEARS TO SHOW SMALLEST TRICKLE. ROUTE WELL TO MUD PITS - AGAIN OBSERVE MINUTE FLOW. START PUMPING AGAIN @ APPROX 2BPM, ■ GAS PICKED UP BY LEL. IA = 713 (STEADILY INCREASING) 05:00 06:30 1.50 STWHIP P WEXIT PU WITH COIL TO ABOVE LINER TOP @ 10,793FT. CIRCULATE BOTTOMS UP FROM 10,780'. - CIRCULATING THRU GAS BUSTER ... 5 PPM H2S, TAKE RETURNS OUTSIDE. 06:30 08:30 2.00 STWHIP P WEXIT - SHUT IN CHOKE, HOLD 150 - 200 PSI BACK PRESSURE WHILE CIRCULATING. - TAKE RETURNS INSIDE, PUMPING 2.2 BPM / :3400 PSI, 8.6 PPG MUD. ' - GETTING BACK 2 - 2.1 BPM / WT CAME BACK TO 8.6 PPG AFTER PUMPING 25 BBLS. - PUMPED REMAINDER OF BOTTOMS UP. (BTMS UP IS 205 BBLS) - SHUT DOWN PUMP, SHUT IN CHOKE W/ 190 PSI & OBSERVE. 08:30 - 12:30 4.00 STWHIP P WEXIT PRESSURE BLED TO 90 PSI. OPEN WELL & MONITOR. - WELL STABLE, CIRC BTMS UP @ 2.2 BPM / 3300 PSI W/ OPEN CHOKE. - PUMPED 150 BBLS AND OBSERVED DENSITY OUT SLOWLY DROPPING. - WENT BELOW 7 PPG AND THEN A SMALL GAS BLURP. - CLOSED CHOKE / HOLD 250 PSI BACK PRESSURE. - CONTINUE TO PUMP ANOTHER 25 BBLS UNTIL IT CLEANED UP. - 8.6 PPG BACK, (GAS FREE), PUMPED 200 BBLS TOTAL. - MONITOR WELL, WELL STABLE. CHOKE OPEN. - CIRCULATE BOTTOMS UP, (205 BBLS), 2.2 BPM / 3150 PSI, W/ CHOKE FULLY OPEN. - MOVED BHA DEPTH TO 10,750' W / PUMPING. - 8.6 PPG MUD BACK THROUGHOUT CIRCULATION. - NO GAS, SHUT DOWN, MONITOR WELL. BLED VA F 900 PSI TO 175, ALL FLUID. - WELL STABLE. 12:30 - 13:00 0.50 STWHIP P WEXIT PRRF TEST WHIPSTOCK PACKER na 11,351'. - LINE AND PUMP DOWN COIL, PRESSURE TO 2350 PSI. - 5.7 BBLS PUMPED, SHUT DOWN AND OBSERVE PRESSURE DROP TO 600 PSI IN 5 MINUTES. - TEST FAILED. (LINER LAP @ 10,793') - BLEED OFF ALL PRESSURE. 13:00 - 15:30 2.50 STWHIP P WEXIT r POOH W/ WHIPSTOCK RUNNING ASSEMBLY. FLOW CHECK WELL, WELL STABLE. Printed 9/26/2011 11:40:43AM North America,- ALASKA - BP Page 14 Operation Summary Report Common Well Name: H -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010G9 -C: (2,530,972.00 ) Project: Prudhoe Bay I Site: PB H Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 8/19/1971 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292010400 Active Datum: 6 : 04 8/19/1971 00:00 ©64.40ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase I Description of Operations (hr) (ft) ' 15:30 - 16 :30 1.00 STWHIP P WEXIT PJSM. BREAK OFF WELL, L/D WHIPSTOCK BHA. - PJSM. M/U WINDOW MILLING BHA. BOP DRILL W/ PICKING UP BHA. - AAR DONE ON ALL ACTIVITIES. WELL FLUID I LEVEL STATIC THROUGHOUT. 16:30 - 19:45 3.25 STWHIP P WEXIT RIH W/ WINDOW MILLING ASSEMBLY ON 2" , COIL. LOG TIE -IN ON TRIP IN. BEGIN TO SEE ERRATIC READINGS ON MICROMOTION. LINE UP THROUGH GAS BUSTER. VARIATIONS IN DENSITY COMING BACK. CLOSE,IN TO HOLD —150 PSI BACK PRESSURE. COMPLETE TIE -IN WITH -26' 1 CORRECTION. 19:45 - 21:30 1.75 STWHIP P WEXIT DENSITY LEVELED OUT AT 8.6 PPG BOTH IN AND OUT AFTER 50 BBLS OF CIRCULATION. COMPLETE CIRCULATION OF BOTTOMS UP 1 WITH 8.6 PPG IN AND OUT. 21:30 - 21:45 ! 0.25 STWHIP P WEXIT CLOSE EDC. DRY TAG WHIPSTOCK AT 1 11,352'. PU WHILE LINING UP BACK TO SHAKERS. COME ON WITH PUMPS, ADJUST CHOKE TO HOLD 150 PSI. MW IN AND OUT 8.6 PPG, 1.49 BPM IN, 1.49 BPM OUT, PVT 302 BBLS, FREE SPIN 2800 PSI. 21:45 - 00:00 2.25 STWHIP P WEXIT TAG TOP OF WHIPSTOCK WITH PUMPS ON aa AT 11351.6'. BEGIN MILLING OPERATIONS '���.! PER BAKER REP. FREE SPIN 2800 PSI AT 1.5 1 BPM. MILL AT 1.5 BPM, 2840 PSI, .7 -2.0 K 1 / WOB. 9/20/2011 00:00 - 06:00 ! 6.00 STWHIP P WEXIT MILL WINDOW PER WELL PLAN AND BAKER REP. - 2460 -2840 PSI, 1.5 BPM, .2 -2.0 K WOB - TIME MILL AT 1 FPH AT 11,357.2'. INDICATIONS INTO OPEN HOLE AT 11,358.2'. MILL INTO FORMATION AT 1 FPH. - GEO SAMPLES FROM BOTTOMS UP AT 11,362' REVEAL FORMATION HAS BEEN DRILLED INTO MW IN AND OUT 8.6 PPG WITH 150 PSI OF BACK PRESSURE WHILE MILLING. LOST 3 BBLS TO WELL DURING MILLING OPERATIONS, NO GAS SEEN AT SURFACE. 06:00 - 08:00 2.00 STWHIP P WEXIT TOW @11,351', BOW @11,357' DRILLED TO 11,367'. - REAMED AND BACK REAMED WINDOW - DRY DRIFT WINDOW, SMOOTH, NO ISSUES. - PULL UP TO 11,335', OPEN EDC & FLOW CHECK,15 MINUTES, WELL STATIC. 08:00 - 09:30 r 1.50 STWHIP N DPRB 11,333.98 WEXIT PJSM. CIRCULATE BOTTOMS UP, CHOKE FULL OPEN. - 2.6 BPM / 3550 PSI. 146 BBLS PUMPED, OUT DENSITY DROPPING. - 151 PUMPED, LEL ALARM, ROUTE THRU 1 GAS SEPARATOR. - HOLD 100- 150 PSI BACK PRESSURE W/ CIRCULATING. - 205 BBLS PUMPED, 8.5 - 8.6 PPG COMING BACK, GAS FREE. Printed 9/26/2011 11:40:43AM TREE WELLH EAD = MCEVOY 6" ��, H -04A I WELLHEAD SAFETY NOTES ACTUATOR = OTIS , K1'3. - ELEV = 64.44' BF. ELEV = 45' I 2000' I 5 -1/2" CAMCO "BAL -O" SSSV _KO P = 2600' LAND NIP, ID = 4.562" Max Angle = 95° @ 12798' --I 2244' H 9 -5/8" DV PKR I Datum MD = 11617' Datum TVD = 8800' SS - --I 2293' H 13 -5/8" X 9 -5/8" XO, ID 8.861" I 1 13 -3/8" CSG, 68 #, K -55, ID = 12.415" H 2293' GAS LIFT MANDRELS I18 -518" CSG, 96 #, K -55, ID = 17.655" I—I 2316' IA ■ ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3018 2940 18 CA DMY RM v 0 09/07/11 y 1 5511 4677 54 CA DMY RM r 0 09/07/11 Minimum ID = 2.377" @ 12425' I 9363' H5 -1/2" OTIS X NIP, ID= 4.562" I 2 -7/8" STL LNR I 9363' I— I5 -1/2" XX PLUG (09/14/11) I i 9415' , —I TBG SEAL ASSY I II 9431' 1-19-5/8" X 5-1/2" BKR HB PKR, ID = 4.00" I I5 -1/2" TBG,17 #, L -80, .0232 bpf, ID = 4.892" H 9431' I / I 9431' I-- 15 -1/2" X 4 -1/2" XO, ID = 3.958" TOP OF 7" LNR I—I 9462' l 9517' I—I TIW HGR, TM/ PKR W/ TB 1 19 -5/8" CSG, 47 #, N-80, ID = 8.681" H 10012' I—A 10789' H BKR LOCATOR SUB, ID = 2.390" I I TOP OF 2 -7/8" LNR H 10793' (10790'CnI) 1 `'I 10793' H 3 -1/2" BKR DEPLOY SLV, ID = 3.00" I I 10802' (-13 -1 /2" X NIP, ID = 2.813" I 4 4 ►0 j' 11270' --I TUBING PUNCH IN STRADDLE I 3 -1/2" LNR, 8.81 #, L -80 STL, —I 11315' 1 ►; 1 11304' (11301' CnI) I— HOWCO XN NIP .0087 bpf, ID = 2.992" 4 % w /RA MARKER, ID = 2.75" 1 '`. 11315' H3 -1/2" X 3- 3/16" XO, ID = 2.786" I I TOP OF WHIPSTOCK I 11325' 4, IRA PIP TAG h 11332' I � 4 MILLOUT WINDOW (H -04A) 11325' - 11333' I 'MARKER JOINT H 11510' I • I RADIOACTIVE COLLAR I—I 11675' elm I 3 I 12406' I -I 3- 3/16" X 2 -7/8 XO, ID = 2.441" I 1 4-1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" H 11740' 1- -' ` 12450' H 2 -7/8" CIBP(02/01/09) I 7" LNR, 26 #, N-80, SEALLOCK, 12008' / ' 1 ' 1 ' 1 ' 1 ' 1 ' 1 ' 1 ' 0371 bpf, ID = 6.184" ................ PERFORATION SUMMARY REF LOG: MCNL /CCL /GR ON 11/27/03 3- 3/16" LNR, 6.2 #, L -80 TCII, 12406' �iiii TIE -IN LOG: GEOLOGY PDC LOG .0076 bpf, ID = 2.80" •"" ANGLE AT TOP PERF: 76° @ 12042' ' Note: Refer to Production DB for historical pert data 1 , SIZE SPF INTERVAL Opn /Sqz DATE y ` 2" 6 12042 - 12067 O 02/02/09 I2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.377" I-1 13410' 2" 6 12306 - 12356 O 09/19/06 2" 6 12490 - 12560 C 09/19/06 2" 4 13030 - 13150 C 11/27/03 -- 1 - 1) � Oc ()"p "-j5 I 2" 4 13180 - 13296 C 11/27/03 \ W pS+OCk--- 2" 4 13320 - 13360 C 11/27/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/18/77 ORIGINAL COMPLETION 11/14/09 DAV /PJC GLV C/O (11/11/09) WELL: H-04A 01/13/90 RWO 07/29/10 JKD /PJC CIBP SET (02/01/09) PERMIT No: 2031610 11/28/03 TM NITLP CTD SIDETRACK 07/29/11 TA/ PJC PULL KB LTP (7/15/11) API No: 50- 029 - 20104 -01 02/06/09 GLM/SV SET CIBP /ADPERF (02/02/09) 09/20/11 MSS/ PJC GLV C/O (09/07/11) SEC 21, T11 N, R13E, 872.91' FNL & 1265' FEL 03/27/09 JLJ /PJC GLV C/O (03/21/09) 09/20/11 BSE/ PJC SET XX PLUG (09/14/11) 09/09/09 CJN/TLH GLV C/O (07/30 & 08/04/09) BP Exploration (Alaska) • • LirrUV; sulf[E u[p SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader j� [ BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H -04A Sundry Number: 311 -218 Dear Mr. McMullen: Ni ����0)1 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, I Dan' - Seamount, Jr. Chair DATED this' day of July, 2011. Encl. /Ant Gii STATE OF ALASKA (/ ��k 0'1 loiiL •" f ALASKA "'AND GAS CONSERVATION COMMISS � Fe PVED APPLICATION FOR SUNDRY APPROVAL 4% .11a 20 AAC 25.280 ' i, J'-- 9 ; ?Ill' 1. Type of Request: ❑ Abandon ® Plug for Redrill . ❑ Perforate New Pool ❑ Repair Well ❑ Change *SAG G Ifid trtkkr Griff6. GgtilMI9 SiOl1 ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension Air nt aigo ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. _∎ Development . ❑ Exploratory 203 -161 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20104 -01 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU H-04A Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028284 ' Prudhoe Bay Field / Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13410 " 9009 • 13376 9008 12450 None Casing Length Size MD / ND Burst Collapse Structural Conductor 100' 30" 100' 100' Surface 2316' 18 -5/8" 2316' 2316' 930 870 Intermediate 10012' 13 -3/8" x 9 -5/8" 10012' 7625" 3450 1950 Production Liner 1805' 7" 9517' - 11322' 7251' - 8621' 7240 5410 Liner 2626' 3 -1 x 3- 3/16" x tare" 10784' - 13410' 8207' - 9036' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12042' - 12450' , 8952' - 9050' 5 17#x4 12/6# ( L - 80 9431' / 11325' Packers and SSSV Type: 9-5/8" x 5 -1/2" BKR HB Packer Packers and SSSV 9431' / 7188' MD (ft) and ND (ft): 1 12. Attachments: 13. Well Class after proposed work: . ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory IN Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Jul 1 0 011 Oil , T , i '/ ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: e: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned ❑ WAG ❑ SPLUG ® Suspended • Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Staudinger, 564 -5733 Printed Name Jo 1 M en Title L19ineering Team Leader �- _ ��/ I Eliza b Prepared h Barker, 564 5674 Signature Phone 564 -4711 Date Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 2j t ' 1 I Sundry Number: ✓✓ Or ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Subsequent Form Required: I 0 01/ APPROVED BY Approved By: / 1 COMMISSIONER THE COMMISSION Date 06"."-// Form 10-403 Revised 01/2010 &RIGINACBDMS JUL 1 S uSu � bmit In Duplicate ii • • • To: Alaska Oil & Gas Conservation Commission From: Mark Staudinger b p CTD Engineer Date: July 5, 2011 Re: H -04A Sundry Approval Sundry approval is requested fo well H -04A. Well H -04A is a horizontal CST drilled in Nov 2003 and completed in Zone 2B)with 276' of perforations. Oil rate rapidly declined with/ sharply increasing gas rates reaching marginal GOR within one year. A July 2004 PLT/Borax log did not indicate any cement channels, leaks, or point source entries. A SCMT log run later in Sept 2006 also showed good liner cement outside the window. H -04A produced only intermittently during the next 5 years, with long shut -in periods despite two sets of perfs added in the lateral section in 2006. Each time the well was brought on, production decreased quickly with a fast rise in GOR. In Feb 2009, a CIBP was set at 12449' MD over most of the lateral section and 25' were shot in a Z2C oil lens. Production remained unchanged. A PLT run in July 2010 indicated all production was from the Z2C lens adperfs and the LTP as still holding. H -04A is currently shut -in for high GOR. REASON FOR SIDETRACK H -04A is no longer a competitive producer, and there are no remaining wellwork options. The proposed sidetrack will access reserves in a -.30 acre target in northeastern H -pad. The proposed plan for H -04B is to drill a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around August 1, 2011. The existing perforations will be isolated by a packer whipstock, as well as the primary cement job. e sidetrack, H -04A, will exit the existing 3- 3/16" liner and kick off in Ivishak and land in zone Z2 2I31 The following describes work planned and is submitted as an attachment to Form 10 -403. A chematic diagram of the proposed sidetrack is attached for reference. Pre -Rig Work: (scheduled to begin July 10, 2011) 1. W MIT -IA to 2500 psi; MIT -OA to 1200 psi. 2. S Pull LTP 3. E Dummy Baker 3- 3/16" PackerWS drift 4. E Set Baker 3- 3/16" Packer WS at 11,444' 5. W PPPOT -T to 5,000 psi, function LDS 6. F Load & Kill well. Freeze protect to 2,500' TVD. 7. V PT Tree (MV, SV, WV) 8. V Set BPV - 24 hrs prior to rig arrival T(tii,s to- q.03 0,frovAt • • • Rig Work: (scheduled to begin on August 1, 2011) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Mill 2.74" window at 11,444' and 10' of rathole. Swap the well to Quick Drill -n. 3. Drill Build: 3.0" OH, 250' (22 deg /100 planned) with resistivity 4. Drill Lateral: 3.0" OH, 3080' (12 deg /100 planned) with resistivity 5. Run 2 -3/8" solid liner leaving TOL at 10,700' 6. Pump primary cement leaving TOC at 11,170', 14.7 bbls of 15.8 ppg Class "G" liner cmt planned 7. Cleanout liner and MCNL /GR/CCL log 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions (-800') 10. Run LTP if failed liner lap test 11. Freeze protect well, RDMO Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Kick off well with N2 3. Run Generic GLV's as needed Mark Staudinger CTD Engineer 564 -5733 CC: Well File Sondra Stewman/Terrie Hubble TREE = , 6" CM/ SAFETY NO I WF,RLHEAD= MCEVOY • H -04A • ACTUATOR = OTIS KB. ELEV = 64.44' ' BF. ELEV = 45' I 2000' I- 1 5 -1/2" CAMCO "BA L-0" SSSV KOP = 2600' 0 1J • NIP, ID = 4.562" • Max Angle = 95° @ 12798' 2244' I DV PKR Datum MD = 11617' Datum TVD = 8800' SS 2293' 1-113-5/8" X 9 -5/8" XO I 113 -3/8" CSG, 68 #, K -55, ID = 12.415" I—I 2293' GAS LIFT MANDRELS ST MD 11/D DEV TYPE VLV LATCH PORT DATE 118 -5/8" CSG, 96 #, K -55, ID = 17.655" H 2316' I--� 2 3018 2940 18 CA DMY RM • 0 11 /11/09 1 5511 4677 54 CA DMY RM ' 0 11/11/09 Minimum ID = 2.377" @ 12425' I 9363' I— I5 -1/2" OTIS X NIP, ID = 4.562" I 2 - 7/8" STL LNR I I I 9415' HTBG SEAL ASSY I Z1 ►Z4 9431' I - 19 - 5/8" X 5 -1/2" BKR HB PKR, ID = 4.00" I I5 -1/2" TBG,17 #, L -80, .0232 bpf, ID = 4.892" I-1 9431' I 9431' H5-1/2" X 4 -1/2" XO I 9517' I-I TM/ HGR TM/ PKR W/ TB I TOP OF 7" LNR i—I 9462' 10784' I KB LTP, ID = 2.56" I 19 -5/8" CSG, 47 #, N-80, ID = 8.681" H 10012' I 10789' I--I BKR LOCATOR SUB, ID = 2.390" I I O F (10790'Cni) I % � i I 10793' H3 -112" BKR DEPLOY SLV, ID = 3.00" I 0 I 10802' H3-1/2" X NIP, ID = 2.813" I 1A �' 11270' I-I TUBING PUNCH IN STRADDLE I 3 -1/2" LNR 8.81 #, L -80 STL, —I 11315' I � � � ;' 11304' (11301' Cnl) I— HOWCO XN NIP .0087 bpf, ID = 2.992" 1 1 • � � w /RA MARKER, ID = 2.75" �, ,. 11315' I — I3 - 1/2" X 3- 3/16" XO, ID = 2.786" I TOP OF WHIPSTOCK H 11325' I � ,.. ' RA PIP TAG I—I 11332' i ', . O MILLOUT WINDOW (H -04A) 11325' - 11333' I MARKER JOINT H 11510' I �' �' ( I 12406' —I3- 3/16" X 2 -7/8 XO, ID = 2.441" I I RADIOACTIVE COLLAR I-1 11675' elm i 3 14 -1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" I 11740' =' '= ` 12450' I 12-7/8" CIBP (02101/09) I 7" LNR, 26 #, N -80, SEALLOCK, 12008' YO .�. •v /r .0371 bpf, ID = 6.184" VI ". ������.41 ` PERFORATION SUMMARY REF LOG: MCNUCCL /GR ON 11/27/03 3- 3/16" LNR, 6.2 #, L -80 TCII, —I 12406' I .inni. TIE -IN LOG: GEOLOGY PDC LOG .0076 bpf, ID = 2.80" ``;� ANGLE AT TOP PERF: 76° @ 12042' Note: Refer to R DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 12042 - 12067 0 02/02/09 I2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.377"1-1 13410' 2" 6 12306 - 12356 0 09/19/06 2" 6 12490 - 12560 C 09/19/06 2" 4 13030 - 13150 C 11/27/03 2" 4 13180 - 13296 C 11/27/03 2" 4 13320 - 13360 C 11/27/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/18/77 ORIGINAL COMPLETION 02/06/09 GLM/SV SET CIBP /ADPERF (02/02/09) WELL: H-04A 01/13/90 RWO 03/27/09 JLJ /PJC GLV C/O (03/21/09) PERMIT No: F 2031610 11/28/03 TMNITLP CTD SIDETRACK 09/09/09 CJN/TLH GLV C/O (07/30 & 08/04/09) API No: 50- 029 - 20104 -01 05/29/06 CO /DTM PERF CORRECTION (6/13/2004) 11/14/09 DAV /PJC GLV C/O (11/11/09) SEC 21, T11N, R13E, 872.91' FNL & 1265' FEL 06/26/08 PJC LNR CORRECTIONS 07/29/10 JKD /PJC CIBP SET (02/01/09) 10/16/08 JNA /PJC GLV C/O (09/12/08) BP Exploration (Alaska) TREE _ 6" OW • H _0 4 B SAFETY NO• I W 3_L'HEAD = MCEVOY ACTUATOR= OTIS Proposed CTD Sidetrack KB. ELEV = 64.44' BF. ELEV = 45' 2000' I— I 5 -1/2" CAMCO "BAL -O" SSSV KOP = 2600' O LAND NIP, ID = 4.562" Max Angle = 95° @ 12798' —I 2244' H DV PKR I Datum MD = 11617' Datum TVD = 8800' SS —I 2293' I -113 -5/8" X 9 -5/8" XO I 13 -3/8" CSG, 68 #, K -55, ID = 12.415" H 2293' GAS LIFT MANDRELS , 18 -5/8" CSG, 96 #, K -55, ID = 17.655" H 2316' I- 2 D E 30 8 2940 18 CA DMY LATCH PORT CA H 1 DATE /11 09 1 5511 4677 54 CA DMY RM 0 11111 /09 Minimum ID = 2.377" @ 12425' 9363' I 1/2" OTIS X NIP, ID = 4.562" 2 -7/8" STL LNR i—j (. I y 9415' HTBG SEAL ASSY I 2 E 9431' 1-19-5/8" X 5 -1/2" BKR HB PKR, ID = 4.00" I 5 -1/2" TBG,17 #, L -80, .0232 bpf, ID = 4.892" H 9431' I 9431' I —I5 -1/2" X 4 -1/2" XO I TOP OF 7" LNR H 9462' H--C, L--I 9517' H TM/ HGR, TNV PKR W/ TB TOL --10,700' c ) 3.7" deployment sleeve / 4.5" KB LTP 9 -5/8" CSG, 47 #, N -80, ID = 8.681" I-) 10012' I A ■ TSGR 11,170' TOC below 11,170' if possible ► ► . o ■ 2 -3/8" 4.7# L -80 liner ► 4 ' ,,\ -- ( �-, ` 3 -3/16 pkr whipstock @ 11,444' 14,825' - TD 38 degrees 3 3 14 -1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" I-I 11740' II C. Al 7" LNR, 26 #, N -80, SEA LLOCK, —I 12008' . . o r...... .0371 bpf, ID = 6.184" t .... ... A ` PERFORATION SUMMARY i REF LOG: MCNL /CCL /GR ON 11/27/03 3- 3/16" LNR, 6.2 #, L -80 TCII, --I 12406' I Alm.,, LOG: GEOLOGY PDC LOG .0076 bpf, ID = 2.80" ' ANGLE AT TOP PERF: 76° @ 12042' — 12406' H3-3/16" X 2 -7/8 XO, ID ` .441" I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 12042 - 12067 0 02/02/09 12 -7/8" LNR, 6.164, L -80 STL, .0058 bpf, ID = 2.377"1—I 13410' 2" 6 12306 - 12356 0 09/19/06 2" 6 12490 - 12560 C 09/19/06 2" 4 13030 - 13150 C 11/27/03 2" 4 13180 - 13296 C 11/27/03 2" 4 13320 - 13360 C 11/27/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/18/77 ORIGINAL COMPLETION 02/06/09 GLM/SV SET CIBP /ADPERF (02/02/09) WELL: H -04A 01/13/90 RWO 03/27/09 JLJ /PJC GLV C/O (03/21/09) PERMIT No: 2031610 11/28/03 TM N/TLP CTD SIDETRACK 09/09/09 CJN/TLH GLV C/O (07/30 & 08/04/09) API No: 50- 029 - 20104 -01 05/29/06 CO /DTM PERF CORRECTION (6/13/2004) 11/14/09 DAV /PJC GLV C/O (11/11/09) SEC 21, T11N, R13E, 872.91' FNL & 1265' FEL 06/26/08 PJC LNR CORRECTIONS 07/29/10 JKD /PJC CIBP SET (02/01 /09) 10/16/08 JNA /PJC GLV C/O (09/12/08) _ BP Exploration (Alaska) NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM • V12 I s °lit V14 NIL I I 7 -1/16" 5000 psi BOP's ID = 7.06" IMIll V15 V17 e Je tire 00 w. ax I mem Transducers FOOR BOY - - - rEGASSER V V2 V1 V 16 �- •.... • 110- I' n. Vac OOP _ .w ra tubing aruurro IN r i i 11 I 2tna - ssso w. Rx�a , i V17 '----- To Poor Boy Gas Buster ' HCR � IC: IK OK IP ..... ...... ..,. I ', 2tnr MOO w,wt -n >.ar saso wHCR >! I IIIM 14 1 • II — — r — f a -tna• MnLVE OD w CHECK I all v Manual Choke • — ��•II 2 tCameron e Cameron FOV Gate rim 0065.. soon w EOH /Diesel . r . ' FP Line • r , , CoFlex Hose . =. _.. 1/4 Turn Halco 10WOG To Production Tree or Cross Over • I A T e transducers I CoFlex Hose CV11 11 It CV12 To Coiled Tubing Bleed Off Inner Reel Valve w- — a - Cv13 Cement Line In _ Ground Level Tie -in / CV1O _ CV3 CV2 r T Stand Pipe �- - - - - -- �- . -_ _- - -. - 1.1 A Manual Choke -- - r NW -- - - Pressure Transducers i _ i — I a r cvs Moaoe III 1� cvn 1 / • =7414. - AMA all•Ils Alas " CV1 cva V Tiger Tank Mud Pump 2 t • — . i. _ = In From O ■ 9. 91 — — Baker MP 1 8 MP 2 Choke • • CV14 to Pits Rig Floor t Mud Pump #1 41 CV16 Reverse Cir O C Cu hi CT we ••' 0 MINN ► ". ..-... mrv- ...,,......P..�- �..._,...,.m.- ter_- _........,,- • • — To Manifold CV15 1-Jun-2010 4 17..,.06.. ri..,u.u n.,. I rtrty CoFlex Hose Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS ( IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve J D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 7/7/2011 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMON ~~~`f~ ~-~-~ ~~~ ~~ ?~1(l~ REPORT OF SUNDRY WELL OPERATIONS Alaska iii ~ « ~ ~nr~s. ~amfnissi®~, 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ AnCi~orage Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory 203-1610 - 3. Address: P.O. Box 196612 StratlgraphlC ~~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20104-01-00 7. KB Elevation (ft): 9. Well Name and Number: 64.4 KB - PBU H-04A - 8. Property Designation: 10. Field/Pool(s): ADLO-028284 - . ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: ' Total Depth measured 13410 - feet Plugs (measured) 12250 2/1/09 Junk (measured) None true vertical 9008.7 - feet ;;fi~tt Effective Depth measured 12250 fe~ J`~`~4u'~'~l° - ~~~~ ~ e~ A 1~~j true vertical 9001 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 19 - 99 19 - 99 1490 470 Production 2276 13-3/8"68# K-55 17 - 2293 17 - 2293 3450 1950 Surface 2298 18-5/8" 96.5# K-55 18 - 2316 18 - 2316 930 870 Liner 1091 3-3/16" 6.2# L-80 11315 - 12406 8611 - 9023 8520 7660 Liner 1004 2-7/8" 6.16# L-80 12406 - 13410 9023 - 9009 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: ,_ _ _ Tubing: (size, grade, and measured depth) 5-1 /2" 17# L-80 17 -9430 4-1/2" 12.6# L-80 9430 - 11740 Packers and SSSV (type and measured depth) 9-5/8" DV Packer 2244 5-1/2" Baker HB Packer 9431 7" TIW Packer 9517 3-1/2" Baker KB Top Packer 10784 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 463 27510 69 1769 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory I~~ Development #~~° • Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas WAG ~ GINJ r WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 2/5/2009 Form 10-404 ReNised 04/2006 ', ~ ~ `• ' ' S' ~ , , ~~~. F ~~ ~' ~QQQ ,~j a~ Submit Original Only ~` ~P H-04A 203-1610 PERF OTTO[_HMFNT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-04A 11/27/03 PER 13,030. 13,150. 9,014.9 9,012.78 H-04A 11/27/03 PER 13,180. 13,296. 9,013.01 9,008.94 H-04A 11/27/03 PER 13,320. 13,360. 9,008.31 9,007.92 H-04A 9/16/06 APF 12,490. 12,560. 9,021.44 9,019.97 H-04A 9/18/06 APF 12,486. 12,556. 9,021.61 9,019.97 H-04A 9/19/06 APF 12,304. 12,354. 9,014.05 9,021.55 H-04A 8/23/08 BPS 9,353. 13,360. 7,124.12 9,007.92 H-04A 9/23/08 BPP 9,353. 13,360. 7,124.12 9,007.92 H-04A 2/1/09 BPS 12,250. 12,252. 9,000.82 9,001.43 H-04A 2/2/09 APF 12,042. 12,067. 8,924.84 8,931.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE u n H-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/30/2009 CTU #9 w/1.75" CT. Job Scone: Drift /Caliper Loa/ Set CIBP /Perforate. MIRU CTU. Performed weekly BOP Test. M/U tool string w/ 2.25" JSN. Go to Weather Standby. *** Job Continued on WSR 01/31/09 *** 1/31/2009 CTU #9 w/1.75" CT. Job Objective: Drft /Caliper Log. ""* Continued from WSR 1/30/09 *** <InterACT publishing> M/U BHA #1 with 2.25" JSN. Load well with 10 bbls of 60/40 meth and 410 bbls of 2% KCI. Freeze protect top of well with 30 bbls of 60/40 meth. Drift to 12,520' CTM and POOH. M/U BHA #2 with PDS memory caliper. Unable to RIH initally due to BHA tagging in the tree. `Reconfigure toolstring. "'"'' Job Continued on WSR 2/1/09 **" 2/1/2009€CTU #9 w/1.75" CT. Job scope: Caliper Log, Set CIBP . *"* Continued from WSR ;01/31/09 *'* <InterACT publishing> Work through problems with caliper tools not testing at surface. MU and RIH with PDS 24 arm caliper tools. Flag pipe and log Ifrom 12450' ctmd to surface per SOP. At surface noticed some piece of metal ;shavings on logging tool. Good data recovered on Caliper and GR with poor ',quality Data on CCL. Depth tied into SLB Memory CBL dated 17-Sept-2006 (-35' correction). M/U and RIH Baker 2 7/8 CIBP. Correct depth at flag and.set CIBP with center of element at 12450' corrected depth per SOP. Top of plug at 1 ~r„~,~_~ *** Job Continued on WSR 02/02/09 *** 2/2/2009~CTU #9 w/1.75" CT. Job scope: Adperf. *"* Continued from WSR 02/01/09 *** I <InterACT publishing> Makeup and RIH BHA #4 w/25' of 2.00" pert guns. RIH and tag top of CIBP for depth control (-38' correction to bottom shot). Perforate from 12042' to 12067' with 2.00" guns loaded with 2006PJ charges, 6spf. POOH. ~At surface, all shots fired. Freeze protect well with 50 bbls of 60/40 meth. M/U tree cap and pressure tested. to 3600 psi, ok. Well handed over to Pad Operator. Final W HP = 0/400/200. **" Job Completed**" FLUIDS PUMPED BBLS 111 60/40 METH 410 2% KCL 521 Total • • ~~_ :-~: ~.. MICROFILMED 03101 /2008 DO NOT PLACE .~ ~~ ,: ti ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm_Marker.doc H-04A (PTD #2031610) Internal Waiver Cancellation - Nonnal Well . . All, An internal waiver was issued for IAxOA communication on well H-04A (PTD #2031610) on 08/10/05. The well passed an MITIA on 12/16/04 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1, 2007, well H-04A will be Operable, with pressure limits of 2000 psi on the IA and 1000 psi on the OA. The well is reclassified as a Normal well. Please remove all waive red well signs and the laminated copy of the waiver from the wellhouse. Thank you - Jack L. Winslow (for Andrea Hughes) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 SCANNED MAY 1 6 2007 I of I 5/1112007 2:40 PM 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA _ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS o o o RECEIVED OCT I 9 2006 P.O. Box 196612 Anchorage, AK 99519·6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate 0 WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 3. Address: Exploratory Service 203-1610 6. API Number: 50-029-20104-01-00 9. Well Name and Number: 64.4 KB PBU H-04A 8. Property Designation: ADLO-028284 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Total Depth measured true vertical 13410 9008.7 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 13376 feet true vertical 9008.05 feet Casing Length Size MD TVD Conductor 80 20" 91.5# H-40 19 - 99 19 - 99 Production 2276 13·3/8" 68# K-55 17 - 2293 17 - 2292.99 Surface 2298 18-5/8" 96.5# K-55 18 - 2316 18 - 2315.99 Liner 1091 3-3/16" 6.2# L-80 11315 - 12406 8610.53 - 9022.75 Liner 1004 2-7/8" 6.16# L-80 12406 - 13410 9022.75 - 9008.7 Burst 1490 3450 930 8520 13450 Collapse 470 1950 870 7660 13890 Perforation depth: Measured depth: 13030 - 13150 True Vertical depth: 9014.9 - 9012.78 13180·13296 9013.01 ·9008.94 13320 . 13360 9008.31 - 9007.92 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 9431' - 11751' Packers and SSSV (type and measured depth) 9-5/8" DV Packer 5·1/2" Baker HB Packer 7" TIW Packer 3-1/2" Baker KB Top Packer 2244 9421 9517 10784 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~,~f" 1\, M"~I:.:~) \";\¡,;'" ~.'ì:t"¡¡;¡"r.,· Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Wat~-8þl Casing Pressure 27027 248 0 25582 265 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 602 753 Tubing pressure 1456 1387 Service x Contact Gary Preble WINJ WDSPL Signature Title Data Engineer Phone 564·4944 Date 10/16/2006 Submit Original Only .. . . '" H-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY from 9-16-06 to MU memory SCMT logging tools. RIH. Log liner from 13,340' . 10,600'. POOH wI memory Data was bad due to error while programing tools. Rerun tools and log again. Good data on second run. *** Job in progress *** 9/18/2006 *** Job continued 9-17 -06 12,486' - 12,556' in three runs. Depths tied into SWS jewelery log dated 7-29-06. MU PDS memory and RIH for tie in fog for second set of perfs. *** Job in progress *** continued 9-18-06 Run memory fog. with perforating run #4..Shoot interval 12329'· 12354'. POOH. RIH with perforating run #5. Shoot interval 12304' - 12329'. POOH. Rig up N2 pumpers. *** Job in *** up N2 unit. wI 2.25" N2 lift operations. RIH pumping 750 N2 to 8500' ctm. Shut down N2 pumping and monitor well flow. Initial test: 4280 bpd water, 150 bpd oil, 3.6 mmscf gas, FL temp = 42*. POOH and monitor well. Final Test Separator results: 00 bpd water, 1500 bpd oil, 5.0 mmscf, FL temp = 76*. Secured well and notified operator of status. ***JOB COMPLETE*** FLUIDS PUMPED I Gallons I ~~~~ ~~TAL P. E·:: C. '~':\,'. I~.;:-:' ß '~.. f;, / f,C:: ~r. ~y Ii'"\' . \ . rL 11 \MI IL, II.j OCT J1. 0 20GB 1 0/06/06 Sc~lumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth c903 -/~I ,~~ Qill~ Ha,.~ COOf;, Gommi~~Jo17l NO. 3982 fl .h.... ,nOÇ~ 11,,,r~') Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL 3-29/J-32 11414759 SBHP SURVEY 09/04/06 1 L4-10 11285941 MEM PROD PROFILE 09/15/06 1 L2-21A 11421023 LDL 09/11/06 1 C-18A 11285934 MEM PROD & INJECTION 07/29/06 1 Y-24 N/A INJECTION PROFILE 09/03/06 1 Z-31 11414379 INJECTION PROFILE 09/04/06 1 S-27B 11285940 MEM PROD PROFILE 09/14/06 1 P-13 11414277 INJECTION PROFILE 09/03/06 1 X-33 11421024 LDL 09/12/06 1 Z-19A N/A MDT 09/08/06 A-17 11414381 USIT 09/07/06 X-01 11422961 USIT 09/09/06 H-04A 11285942 SCMT 09/17/06 15-39A 11212888 SCMT 09/16/06 C-09A 11209608 MCNL 06/16/06 C-18A 11285934 MCNL 07/29/06 Z-14B 40013765 OH EDIT OF MWD/LWD 07131/06 Color CD :( 1 1 1 1 1 ( Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCANNED OCT 3 1 2005 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well IP2-22 ,'",1- -8':'/9 IP2-16 I~~ - I;..J~ P2-36 ' C¡'? - I (~D P2-50B 'i"1,"'; - O'7G 16.03 : ~ I - (, ¡I P2-36 I "ì 1- - I (~b 4·18/5·30 i -1¡L,( - 1/ 6 1-33B/L-24 I G 'íç - ;::) -<;":5- 04-41A Ic;-r-î\"'~ 15-D9A C¡ 3 - I.~"'i< 09-17 -:t--~ -r~:z..L,( 16-D9A 'i I - ('?-K 16-11 i "i<.'ì - I I oS 17-02 I~{' - o "TO NK-38A /)(~i..1 -fJ4/ R-35 ¡ t1.~- / 1i- D-D9A I C¡C; - eJ.7<.,- L5·16 i ";(1- - n \C::\ K-D8A ~;~~-i4() H -D4A c¡f).::¡ .- / {, I Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Job# 11136744 11058238 N/A N/A 11076454 11051061 10564459 10889175 N/A N/A 11076460 11051089 11058249 N/A 10687734 11212863 11221576 11212864 11054182 10715365 11 t, n Ii ! i ./1/ / j , .f. , f I l!., \ / l/-- V(_/' RECE\VED JUN 0 8 2006 . &SiCn .:.J2S1<,a Oil &. GdS C<;1ìS. ecmml ,Anc\'llCrage Loa DescriDtion GL5 WFL LDL LDL INJECTION PROFILE GLS/LDL PSP GLS SCMT LDL OIL PHASE BOTTOM HOLE SAMPLE INJECTION PROFILE PRODUCTION LOG W/DEFT LDL SENSA MEMORY LDL MDT USIT USIT USIT MCNL ~ ì'.~...¡q::::l MCNL';:;' I'~ <./"1 ~ Date 11/13f05 08/18/05 07/13/05 07/16/05 07/28/05 06/15/05 04/18/03 10/12/04 07118/05 02/02/05 08/18/05 08/18/05 09/14/05 10/17/05 02/27/05 OS/26/06 OS/27/06 OS/28/06 06/06/05 11/27/03 06/01/06 NO. 3828 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ;;¡.D?J-l {PJ BL 1 1 1 1 1 1 1 Color CD e 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth e e To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 WELL LOG TRANSMITTAL ~/)D~)·- )[1)( Februmy 17, 2006 \(j50~ RE: MWD Formation Evaluation Logs H-04A, 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 H-04A: LAS Data & Digital Log hnages: 50-029-20104-01 1 CD Rom f G:Jo1ÆYì )1~X?(Œo RE: PBU H-04A e ~e1't~3ù v:." Suh.iect: RE: PBU £-1-04/\ From: "NSU, ADW Well Integrity Engineer" <J'\SUADWWelIlntcgrityEngineer@BP.com> Dutc: Sat, 28 .Ian 2006 10:33 :07 -OC)()O To: James Regg <.jim_regg@admin.state.ak.us>, "GPB, GC2 Well pad Lead" <GPBGC2W cllpadLcad@ßP.com> CC: ";\ISlJ, ADW Well Integrity Engineer" <NSUADWWelllntegrityEnginecr@BP.com> Hi Jim, H-04A (PTD #2031610) has a notice of lowered MAASP with limits set at 1500 psi on the IA and 1000 psi on the OA. The casing bursts are 3450 psi on the lA, and 2566 psi on the OA. I calculate that the MAASP limits are 34% and 39% respectively. I've included a copy of the wellbore schematic and an electronic copy of the notice. Please let us know if you have any other questions. Hi Bob, Please have the operator double check that this notice is posted near the wellhead with these operational limits. Thanks, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: ( 907 ) 659 - 51 0 2 Pager: (907) 659-5100 xl154 ,'j(.l\N?\Œ~·,,' r -----Original Message----- From: James Regg [t.J:I:9:UtC?:j~rf1:......:r:~s.:9.(¡î)9:9~1.?:l!::'§,!:9.:!:~:éi~::l.1§] Sent: Thursday, January 26, 2006 8:20 AM To: NSU, ADW Drlg ges Toolpusher; NSU, ADW Well Integrity Engineer Subject: Re: PBU H-04A My fault; I meant to send this to the well integrity group; should have checked email address closer.\ Jim Regg NSU, ADW Drlg ges Toolpusher wrote: Jim, We have not been to H-Pad w/9ES. During that time we were on V-pad. Thanks Kelly Cozby 9ES Toolpusher -----Original Message----- From: James Regg [t.J:I:2~?:~_!:?:j~'T:....E~9.9.'i.Y~0:9.:~1.~l!::§t:~l!:~:9:~:_\l§] Sent: Wednesday, January 25, 2006 3:35 PM To: NSU, ADW Drlg ges Toolpusher Cc: Winton GAubert Subject: PBU H-04A Inspector noted while witnessing safety valve test on PBU H-04A (PTD 2031610) that the MAASP exceeds 45% of the surface casing burst rating; inspection date was 1/21/06. By MAASP, we are assuming this means a waiver pressure for the OA (note - we do not have a copy of any waiver for H-04A). High OA pressure (>45%) was reported by Joe Anders previously (see attached) and noted that a 10-403 would not be submittted since the work to repair would be completed before paperwork 10f2 1/30/2006 9:34 AM RE: PBU H-04A could be prepared. e e According to the inspection report, there was no pressure on the OA at the time of safety valve test. Please review the waiver pressure (MAASP?) assigned by BPXA for PGBU H-04A and make sure it complies with CO 492 requirements. Jim Regg AOGCC > Content-Description: H-04A.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: H-04A Lowered lAP 08-10-05 H-04A Lowered lAP 08-10-05 .pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 1/30/20069:34 AM TREE = 6" CN\! WELLHEAD = MCEVOY ._-- ACTUA TOR = OTIS KB. ELEV '" 64.44' BF. ELEV = 45' KOP = 2600' !\I!ax Angle'" 94.6 @ 12798' DatumMD= 11617' Datum NO '" 8800' SS e 13-3/8" CSG, 68#, K-55, ID = 12.415" 118-5/8" CSG, 96#, K-55, ID = 17.655" I Minimum ID :::: 2.377" @ 12425' 2-7/8" STllNR 15-1/2" TBG,17#, L-80, .0232 bpf, ID = 4.892" I 9431' I TOP OF 7" LNR I 9462' 19-5/8" CSG, 47#, N-80, ID '" 8.681" I 10012' I TOP OF 3-1/2" X 3-3/16" X 2-7/8" LNR I 10793' (10790'cnl) I TOP OF WHIPSTOCK I IRA PIP TAG I I MARKER JOINT H I ECLIPSE TBG PA TCH I RADIOACTIVECOLLAR I 14-1/2" TBG,12.6#, L-80, .0152 bpf, ID = 3.958" I I PBTD H 7" LNR, 26#, N-80, SEALLOCK, -j .0371 bpf, ID = 6.184" PERFORA TION SUMMARY REF LOG: MCNL/CCL/GR ON 11/27/03 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 91 @ 13030' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 13030 - 13150 C 11/27/03 2" 4 13180 - 13296 C 11/27/03 2" 413320-13360 C 11/27/03 H-04 SAF TES:***NO COMMUNICA TION ISSUES. LOWER THE IA TION PRESSURE OPERATING LIMITS: MAX 1AP= 1500 PSI; MAX OAP= 1000 PSI (08/10/05 WANER)··· . GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 3018 2940 18 CA DOME RM 16 10/26/04 1 5511 4677 54 CA SO RM 20 10/26/04 9363' 9415' 9431' 9431' 9517' 12008' -19-5/8" X 5-1/2" BKR HB PKR, ID'" 4.00" -15-1/2" X 4-1/2" XO I -1 TN\! HGR, TIW PKR W/ TB I 13-112" X 3-3/16" X 2-7/8" LNRCl\rrED& PERFED H 13410' ~ : ~~H-::~"--~-+--~~_:+~~::~==--l 11/10/03 MSE PROPOSEDCTDSI 10/19/05 RPHlPJC WANER SAFETY NOTE (8/10/05) 11/28/03 TMNlTLP NORDIC-1 CTDSIDETRACK 03/17/04 A TD/TLP CI\1T TO SURF AT ORJG COMPL 07/31/04 BMcL/TL DELETE PBTD@ 13376' PRUDHOE BA Y UNIT WELL: H-04A PERMIT No: 2031610 API No: 50-029-20104-01 SEC21, T11N, R13E, 872.91' FNL & 1265' FEL BP Exploration (Alaska) "';''''''''''_'_''''--~'''¿-..~~..-...-",."",....,¡¡;;-......."",,,,,,,,,,-.,........= Vis/rilmllon: (y; / P.~fJ ()pØroll)( OS / Pa~j F.rlgìnt~';H \VOE o:=_~~.. A/~¡)ar Date · · · and TIm rnaxirnurn al!owable annulus surface prcssuréon the IA has beel1lowered lö 150U psi. 111(1 n,ilxírnurn allowable annulus surlaCfj pressure on the OA rérnait1S àt Woo psi. If these pressured are ext:eeded, the v/ell shQuld bé shut in immedlatély and the WIE should be notified. Operating Limits Max lAP d 1500 psi Max OAP = 1000 psi pG~:Ñ-OFAêTÎott'"C=~~-~=O- ==. Any deviation from this )olico mllst be pr(j-approvod by he Wells Grollp 10 Operations Manager. · · Tubing (S·1iZ 17# Um) Bursl '" 7740 psi Production CasinD (13-:)iß" 68i1 K-55) Bursl '" 3450 psi, 45% =1522 psi Surlm;o Casing (18·5/8" 8611 K'55) Burst", 2250 psi, 45% '" 1012 psi rObjeciive 01 Ihis nollce is 10 ìnlÖrrn Operations 01 a revised IA MAASP due lojoinls oJ K·55 pipe ill 1110 Produc;llon and Sufac;e Casings. AOGCO regualtions rèquire notification when annulus þresstJl'Os èxceed 45% or burst arid Ihe standard MAASP is higher than this value,Therß is no known communication belwf!én annuli. -iMPÛRTANTcONSf5ERA TIOtfšTëOMMifÑTS: MIT-T Pa!>sed 10 2500 psi 2/26/04 fAX OA COMMUÑfcATION?·· ~~ MI T -11\ Pa¡,iwd (tJ 2ì60 psi .' 1211 6/04 ~YES xx -_mi4Ò .. îiJßïNèYXïA C'Õ~1MÜÑïcA TiON? REASON FOR NOTICE: PrP,SSllr(~s: Flowing 81 lower the IA Operating Pressure Tubing 1032 2250 psi psi lar Annulus 1550 11300 psi psi Oulor Annulus 200 760 psi psi Produclion Data 03/17/03: 732 BOPD, 27 BWPD, 23.915 MMCFD, 0 MMCFD AL. WEI..I..: ,:":=...~,~~.='~.::'.'~~:::===~~ H-04A WELL TYPE¡: Prodli¢ét- to. OperatingPrt!SSUr!!~__====~ N,l\Ufª1 pl6w DATE: 00-10-05 H-04 Flowing after failed test. e e ~tPt1 \tZ4\O~:' Subject: H-04 Flowing after failed test. From: "GPB, GC2 AreaMgr';<GPBGC2TL@BP.com> Dute: J\1on, 23 Jan 2006 15:04:31-0900 , f~t~~:;1~~;;¿. >'~~f~l~~~~: K.@BP.COIn' C2WellpadLea M":i:I-?03 -1'=.,1 John Below you will see a secuence of events for state testing of well H-04, we have a well flowing that by the procedure should be shut in today they tried to get out there and fix it this morning were not able to get there. Jeff Jones with AOGCC is aware on the situation and we will get out to it as soon as we can. I have been the loop on this from beginning, and agree with the below. We have the well entered in the defeated safety log. If you have any question let me know. Thanks H-04 was State Tested on 1/21/06 by Rich Vincent (BP) / Jeff Jones (AOGCC). 1.) The P. Pilot Low Trip was set at 550psi and tripped at 580psi 2.) The SSV did trip, but took longer than the required 2- minutes to go fully closed. 3.) The SSV did hold Differential Pressure. Downstream of the SSV was depressured to 150Opsi. 4.) When the SSV was reopened the Shut In Pressure was at 2200psi. 5.) H-04 was left in service and the grease crew came out to flush the hydraulic lines of any solids. 6.) Work Request was written to install a Quick Dump at the wellhead if need be. 7.) Control Tech went out to verify the return line from H-04 to H-52 Hydraulic Skid was adequate. They did find some ice in this line and purged it out. 8.) WOA was in Phase 2 at this time and was considering going to Phase 3. 9.) The decision to leave H-04 was made by GC-2 Well Pad Lead (Rich Vincent) & GC-2 Area Manager Bruce Robinson, because if this well was Shut In there was no way to freeze protect this well, as the pump truck had a flat tire and once this was repaired they were going to stage the tanker in a warehouse, do to the upcoming Phase 2 / 3 weather. 10.) A call has been made to the AOGCC Rep, Jeff Jones to make him aware of the situation. 11.) The P. Pilot did what it was supposed to do, as well as the SSV, in holding Differential Pressure. The SSV was slow in closing, which will be addressed, as soon as weather allows. 12.) If the H-04 was Shut In and the Flowline was not able to be Freeze Protected, do to the weather conditions, this Flowline could Freeze and Rupture causing potential risk to employees and environment, as we are in Phase 3 at the present time are to remain in this phase for most of the day and evening. Bruce W Robinson GC-2 Area Manager (907) 659-4902 Pager 4236-521 5CANNEL FEU :\; ¡j 10f2 1/24/2006 8:38 AM H-04 Flowing after failed test. 20f2 e H-04 Flowing ufter fuiled test. e 1/24/2006 8:38 AM [Fwd: H-04 Flowing after failed test.] e e Subject: [FWd: H-04 Flowing after failed test.] From: JeffJdnes <jeffjones@admin.state.ak.us> Date: MOTÏ;23Jan 200617:46:15 -0900 ,',',.. '..'}' ......'....'.... , " " To: James Regg <jitj-í.:iregg@admin.1)tate.ak.lÏs>" . ..... ..... ... . Hi Jim, This is FYI, the SSV on H-04 took well over 4 minutes to close and this is why it has not been repaired or shut in (yet). Thanks, Jeff Content-Type: message/rfc822 Flowing ufter fuiled test. Content-Encoding: 7bit 1 of 1 1/24/2006 8:39 AM J-.g ~ ~>- DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031610 Well Name/No. PRUDHOE BAY UNIT H-04A Operator BP EXPLORATION (ALASKA) INC S"CA.¿ /7 Ala \J Aù-uJ APrNo. 50-029-20104-01-00 MD 13410_ TVD 9009" Completion Date 11/28/2003 ./ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~--,-------- DATA INFORMATION Types Electric or Other Logs Run: SGRC, GR, EWR, Memory CNL, MGR, CCL, CNL Well Log Information: Logl Electr Data Digital Dataset Type MedlFrmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH 1 Start Stop CH . Received Comments ---_.~---,---~".."_."---_._..- ~ Directional Survey 11300 13410 Open 12/22/2003 At LIS Verification 11211 13352 Open 8/5/2004 MWD,GR, ROP, FET, RPD, RPM,RPS,RPX DSN#12613 ~D Lis 12613 I nduction/Resistivity 11211 13352 Open 8/5/2004 MWD,GR, ROP, FET, RPD, RPM,RPS,RPX ~ Production Blu 9284 13366 Case 1 0/15/2004 MEMORY PPROF & IPROF LOG MEMORY GRlCCUSTP Æ'o9 Gamma Ray 25 Blu 9284 13366 Case 1 0/15/2004 PPROF/IPROF/JEWELRY LOG/MEMORY ¥C GRlCCUSTP Pds 12753 Leak 10701 13367 Case 1 0/15/2004 . ...199 12753 Leak Blu 10701 13367 Case 1 0/15/2004 MEMORY BORAXLOG, MEMORY GR/CCLlCNL --~._--~--_. Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2031610 MD 13410 TVD 9009 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? 'r 1 t~ ' Analysis Received? ~ Comments: ~-'._._~~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Well Name/No. PRUDHOE BAY UNIT H-04A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20104-01-00 Completion Date 11/28/2003 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? tN 7!J/N Formation Tops ~ Date: 3>. J.~ ~-{o . . Problem Well> 45% Notification: H-04A (PTD #2031610) . Prb..:tt 20 3 -16 I Subject: Problem Well > 45<.~otification: H-04A (PTD #2031610) . From: "NSU, ADW We]} Integrity Engineer" <NSUADWWelHntegrityEnginecr@BP.com> Date: Sun, 14 Nov 200422:04:26 -0900 To: "AOGCC Jim Regg (E-mai1)..<jim_regg@admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWelUntegrityEngincer@BP.com>, "Mielke, Robert L." <robcrt.mielke@BP.com>, "Warren, Mike (Orbis)" <WarrenM@BP.com>, "GPB, GC2 Area Mgr" <GPBGC2TL@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWeIlOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "GPB, Ops Mgr" <GPBOpsMgr@BP.com>, "G,PB,Well Pads HYQ" <GPBWe1lPadsHPYQ@BP.com>, "GPB, Fld Ops Lead" <GPBFldOpsLead@BP.com>, "Jacobsen,.Rosanne M" <JacobsRM@BP.com>, "Engel, Harry R" <EngelHR@BP.com> All, Well H-04A (PTD #2031610) has sustained casing pressure on the IA that exceeds 45% of the production casing burst pressure. The well has been classified as a Problem well. Wellhead pressures on 11/13/04 were T/I/O = 2230/1680/30. The burst pressure of the 13-3/8" K-55 production casing is 3450 psi, 45% = 1552 psi. The plan forward for this well is as follows: 1. SL: Set TTP, Pull Generics, Run DGLV's 2. FB: MITIA to 2760 psi (80% of PC burst) 3. SL: Pull TTP if MITIA passes Note Rule 5 of Conservation Order 492 states: "Unless well conditions require the operator to take emergency corrective action before AOGCC approval can be obtained, the operator shall submit in an Application for Sundry Approvals (Form 10-403) a proposal for corrective action." The TTP and gas lift valve work is scheduled as soon as weather conditions permit (currently have high winds/phase 2 driving conditions). We are not planning to submit a 10-403 as this work will be completed before it could be prepared, submitted and approved. Attached is a wellbore schematic. Please call if you have any questions. «H-04A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWellIntegrityEngineer@bp.com Content-Description: H-04A.pdf H-04A.pd Content-Type: application/octet-stream Content-Encoding: base64 ~/ 1t)~-404- ìbll~feJ J4e- ~It:.::> ~\~) -:> JJùh¡:'c~~ ì'F- df... > (Oùù pSl JX~ III IS(tYt- 1 of 1 11/15/20049:21 AM TREE = 6" CNV WELLHEAD = MCEVOY ACTUA TOR = OTIS . c "..~>< KB. ELEV = 64.44' BF. ELEV = 45' KOP = 2600' Max Angle = 94.6 @ 12798' -.. - >- DatumMD= 11617' . "" .... Datum TVD = 8800' SS . 113-3/8" CSG, 68#, K-55, 10= 12.415" H 2293' 118-518" CSG, 96#, K-55, ID = 17.655" H 2316' Minimum ID = 2.377" @ 12425' 2-7/8" STL LNR H -04A l . 11 - -~ (' 1---1 ~ 15-1/2" TBG,17#, L-80, .0232 bpf, 10=4.892" H 9431" ::8:, L_mmmm. ~ [TOP OF 7" LNR H 9462' .---... 9-5/8" CSG, 47#, N-80, 10 = 8.681" H 10012' ~ TOPOF3-1/2" x 3-3/16" X 2-7/8" LNR H 10793' (10790'cnl) t L í ì ::8:" I ~OTES: 2000' H 5-1/2" CAMeO SSSV LANO NIP, 10 = 4.562" 1 I TOP OF WHIPSTOCK H 11325' ~ IRA PIP TAG H 11332' I---- I MARKER JOINT H 11510' h-... I ECLIPSE TBG PATCH H 11650' ¡....---:::] j RADIOACTIVE COLLAR H 11675'elm ~-~ ¡ 4-1/2"TBG,12.6#,L-80,.0152bpf,ID=3.958" H 11740' I ~ :8 PBTD H 11960' ~OOOOOOOO 17" LNR, 26#, N-80, SEALLOCK, 1-1 12008' ~~ .0371 bpf, 10=6.184" PERFORA TION SUMMARY REF LOG: MCNLlCCL/GR ON 11/27/03 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 91 @ 13030' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 13030 - 13150 0 11/27/03 2" 4 13180 - 13296 0 11/27/03 2" 4 13320 - 13360 0 11/27/03 OA TE REV BY COMMENTS 02/18/77 ORIGINAL COMPLETION 01/13/90 RWO 11/10/03 M SE PROPOSED CTD SIDETRACK 11/28/03 TMNlTLP NORDIC-1 CTD SIDETRACK 02/26/04 RMHlTLP GL V C/O 03/17/04 A TDITLP GMT TO SURF AT ORIG COMPL 2244' H OV PKR I 2293' Ii 13-518" X 9-518" XO I ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 2 3018 2940 18 CA DOME RM 16 10/26/04 1 5511 4677 54 CA SO RM 20 10/26/04 9363' H 5-1/2" OTIS X NIP, 10 = 4.562" I 9415' HTBG SEAL ASSY I 9431' H 9-5/8" X 5-1/2" BKR HB PKR, 10 = 4.00" I 9431' H 5-1/2" X 4-1/2" XO I 9517' H TNV HGR, TNV PKR W/ TB I 10784' H BAKER KB LNR TOP PKR I 10793' H BTM DEPLOY SLEEVE, 6' LONG, 10 = 3.00" 10802' H3-1/2" X NIP, 10 = 2.813'" -i 11270' HTUBING PUNCH IN STRAODLE I 111304' (11301' cnl) 11XN NIP(2.813" PROFILE, I 2.75" NOGO) W/ RA MARKER 11315' H3-1/2" X 3-3116" XO I 1 MILLOUT WINDOW 11325' - 11333' 12406' H3-3/16" X 2-718 XO I 13-112" X 3-3/16" X 2-7/8" LNR CMTED & ÆRFED H 13410' ¡----: OA TE REV BY COMMENTS 07/31/04 BMcL/TLF DELETE PBTD @ 13376' 10/26/04 BMcLITLP GL V C/O PRUDHOE BAY UNrr WELL: H-04A ÆRMrrNo: 2031610 API No: 50-029-20104-01 SEC 21, T11 N, R13E, 872.91' FNL & 1265' FEL BP Exploration (Alaska) e e ;/t):3--!f¿( / 2~(3 WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs H-04A, 1 LDWG fOlmatted Disc with verification listing. PûPI#: 50-029-20104-01 July 29, 2004 AK-MW-2771368 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO mE ATTENTION OF: Speny-Sun 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 Dare ?3ff ~/: ,þ.1 SignC~. ~~ ~ //' refcL '?(o~(o <I: .. STATE OF ALASKA . RECEIV· 'E·· D ALASKAWL AND GAS CONSERVATION COMMISSION - . WELL COMPLETION OR RECOMPLETION REPORT AND LO~vjAY 1 1 2004 AraN1sôff:&o~~so~f.'f!o?Rr&§~\\ction 1b. Well Q\M$mrage 1m Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-161 13. API Number 50- 029-201 04-01-00 14. Well Name and Number: A. .~ No. of Completions 1a. Well Status: 1m Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 873' SNL, 1265' WEL, SEC. 21, T11N, R13E, UM Top of Productive Horizon: 2034' NSL, 3500' EWL, SEC. 15, T11N, R13E, UM Total Depth: 2987' NSL, 2912' EWL, SEC. 15, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 643315 y- 5959915 Zone- ASP4 TPI: x- 648016 y- 5962914 Zone- ASP4 Total Depth: x- 647409 y- 5963855 Zone- ASP4 18. Directional Survey 1m Yes 0 No One Other 5. Date Comp., Susp., or Aband. 11/28/2003 6. Date Spudded 11/17/2003 7. Date T.D. Re¡Jched 11/24/2003 8. KB Elevation (ft): KBE = 64.4' PBU H-04A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 9. Plug Back Depth (MD+ TVD) 13376 + 9008 10. Total Depth (MD+TVD) 13410 + 9009 11. Depth where SSSV set (Nipple) 2000' MD 19. Water depth, if offshore N/A MSL Ft Ft 16. Property Designation: ADL 028284 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: SGRC, GR, EWR, Memory CNL, MGR, CCL, CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE Top BOTTOM Top BOTTOM SIZE CEMENTING RECORD PUllED 30" Conductor Surface 100' Surface 100' 36" 300 sx Permafrost II 18-5/8" 96.5# K-55 Surface 2316' Surface 2316' 24" 4800 sx Permafrost II 13-3/8" x 9-5/8" 68# /47# K-55 I N-80 Surface 10012' Surface 7618' 12-1/4" 740 sx 'G', 200 sx 'G', 2170 sx PF II 7" 29# N-80 9517' 11322' 7244' 8616' 8-1/2" 1140 sx Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 8.81# /6.2# /6.16# L-80 10784' 13410' 8199' 9009' 4-1/8-x3-3/4" 157 sx Class 'G' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl 101 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 13030' - 13150' 9015' - 9013' 13180' - 13296' 9013' - 9009' 13320' - 13360' 9008' - 9008' 26. Date First Production: April 9, 2004 Date of Test Hours Tested PRODUCTION FOR 5/1/2004 4 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 1,900 54 24-HoUR RATE Oll-Bsl 604 TUBING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, L-80 9431' 4-1/2", 12.6#,L-80 9431'-11751' , 25. FRACTURE, CEMENT SQUEEZE, ETC. 24. PACKER SET (MD) 9431' 11740' DEPTH INTERVAL (MD) 2000' AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH GAs-McF 3,622 GAs-McF 21,734 CHOKE SIZE I GAS-Oil RATIO 55° 35,967 Oil GRAVITY-API (CORR) 25.9 WATER-Bsl 6 WATER-Bsl 36 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 OR 1 G \ NALRBDMSBfL MAY 1 ~ "1M!, CONTINUED ON REVERSE SIDE (9 f 28. e GEOLOGIC MARKERS NAME MD TVD 42N 11442' 8709' Top CGL 11512' 8772' Base CGL 11630' 8855' 25N 12072' 8933' 25P 12096' 8942' 22P 12270' 9006' 29. e FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEIVED MAY 11 2004- Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Surveys, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble ~ ~~._ Title Technical Assistant Date ()S-/O"'OL( PBU H-04A 203-161 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Alistair Sherwood, 564-4378 Permit No. I Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 IG\NAL e e Well: Field: API: Permit: Date H-04A Prudhoe Bay Unit 50-029-20104-01 203-161 Accept: Spud: Release: Rig: 11/14/03 11/17/03 11/28/03 Nordic #1 POST RIG WORK 12/19/03 ATTEMPT TO SET 5-112" TBG STOP SAT DOWN @ 2752 SLM. OBSTRUCTION APPEARS TO BE LOSS CONTROL MATERIAL, DRIFTED THROUGH WI 2.25 CENT AND SB, SAMPLE BAILER FULL OF WHAT APPEARS TO BE FLOW PRO. 12/20/03 DRIFT TBG WI 5-1/2" FBB AND 4.56" GR. FROM SURFACE TO 5600' SLM. SET AND PULL 5-1/2" SLlP- STOP CATCHER 5531' SLM. AFTER GLV C/O. CIO DGLV TO LGLV IN STA# 2 @ 3004' SLM. 1500 TRO 1/4 PORT. C/O DGLV TO OGLV IN STA # 1 @ 5499' SLM. 5/16 OGLV. PULL CATCHER SUB. 02/25/04 SET 5.5 WIDDON CATCHER @ 8430 SLM. PULLED 5/16 ORFICE WI RM LATCH FROM STA # 1 @ 5496'SLM. PULLED 1.5" LGLV, 1/4, RM FROM STA # 2 @ 3003'SLM. SET 1.5" DGLV (RA LATCH) IN STA # 2 @ 3003'SLM. ATTEMPT TO SET DGLV IN STA #1 @ 5496'SLM. LOST CAM LOCK FROM RA LATCH IN HOLE. 02/26/04 RIH W/5.5"OM1 WIT' EXT AND POCKET POKER TO STA #1 @5103'SLM (POCKET LOOKS GOOD). SET 1.5" DGLV (RM LATCH) IN STA # 1 @5103'SLM. PULL WIDDON C-SUB FROM 8430'SLM (CAM FROM RA LATCH IN C-SUB). TURN WELL OVER TO PAD OPERATOR. 04/07/04 DRIFT COIL W-1-1/4" BALL, OK. PERFORM WEEKLY BOP TEST TO 4000 PSI, OK. MU 2" OD JSN AND RIH. 04/08/04 CONTINUE RIH. TAGGED AT 13,256 CTM AND TRIED TO WORK DOWN. ULTIMATELY REACHED 13,287 CTM BUT LOOKED LIKE COIL WAS LOCKING UP AND/OR GETTING DIFFERENTIALLY STUCK. TAGS WERE INCONSISTENT ON WAY DOWN AND HAD TO KICK ON PUMP EACH TIME TO PUH. CIRCULATED BU AND PERFORMED PRE-ACID INJECTIVITY TEST. 0.9 BPM @ 1300 PSI. (0.66 BPD/PSI), 0.4 BPM @ 945 PSI. STIMULATED WITH 60 BBLS 7.4% HCL WHILE MAKING UPIDN PASSES. INJECTIVITY AT END OF ACID STAGE 1.8 BPM @ 460 PSI. (2.34 BPD/PSI). OVER DISPLACED W/60 BBLS 2% KCL. FINAL INJECTIVITY 1.8 BPM @ 462 PSI (2.33 BPD/PSI). POOH AND CHANGE PACKOFFS, RBIH AND START CONTINUOUS N2 LIFT, WELL DID NOT COME AROUND. POOH, ALLOW WELL TO LOAD UP AND RBIH W/N2 AT 1000 SCF/MIN. 04/09/04 RIH JETTING W/N2 AT 1000 SCFIMIN WITH STOPS AT 2500',2900',3500',4000',5331' CTM. SD N2, OBSERVED WELL AND POOH WHILE MONITORING WELL AT PAD SEPARATOR. WELL FLOWING STRONG. INSTANTANEOUS RATES AT END OF LIFT: 60 DEG CHOKE, 4.5 MMSCF/DAY GAS. 4000 BOPD, 500 BWPD, WHP=390 PSI. WHT=106 DEG F. CONTACT PAD OPERATOR WITH FINAL FLOWING PARAMETERS. CONTACT PCC WITH WELL STATUS. WELL LEFT FLOWING TO PAD SEPARATOR. H-04A t (' ~ -:..~ e TREE" 6" CIW W8.LHEAD = fllCEVOY A CTUð. fõR':; . OTIS Kä REV = ^--- 64:44; BF.ECÊV = 45' -KOP " ^^^ ... -^^26ö¡¡7 '~;;ix ,'\'i;Úë ·:"-¡¡¿·:i¡;;~ 1 iï"Ùi¡;· ·D¡;tl~~iï'¡;ïD·:'--····"·"· '·--'-'6'1 i Datum TVD = 8800' SS 113-318" CSG, 68#, K-55, ID = 12.415" H 118-518" CSG, 96#, K-55, ID = 17 .655" H 2293' 2316' Minimum ID = 2.377" @ 12425' I 2-718" STL LNR í :g \ jl 15-1/2" TBG,17#, L-80, .0232 bpf, 0 =4.892" H 9431' TOPOF7"LNR H 9462' . ~ I )( ~~ 1- --l L ì :;g I ~ 9-5/8"CSG,47#,N-80,ID=8.681"H 10012' ~ ~ TOPOF 3-1/2" X3-3I16"X 2-718" LNR H 10793' (10790'cnl) t . SAÆTY NOTES: 2000' H5-1/2"CI\MCOSSSV LAND NIP, 0=4.562" HOJ FKR H 13-518" X 9-5/8" XO 2244' 2293' .. ST MD TVD 2 3018 2940 1 5511 4677 GAS LIFT flMNDR8.S DEV TYPE VLV LATŒi PORT DATE 18 CI\ O\I1Y RA - 02/26/04 54 CI\ O\I1Y RM - 02/26/04 9363' H5-1/2" OTIS X NIP, 0 =4.562" 9415' HTBG SEAL ASSY I 9431' 9431' 9517' H9-5/8" X5-1/2" BKR HB PKR, ID =4.00" 1 H5-1/2" X4-1/2" XO I 1-11lW H3R, llW FKRW/TB I 10784' HBAKER KB LNRTOP FKR I 10793' H BTM DER.OY SLEBI E, 6' LONG, ID " 3.00" 10802' H3-1/2"XNIP, ID=2.813" I 11270' HWBNGPUNCHIN STRADDLE I 111304' (11301' cnl) HXNNIP(2.813"PROFlE, I \2.75" NOGO) WI RA flMRKER 11315' H3-1/2" X 3-3116" XO I I MlLOUTWINDOW 11325' - 11333' 12406' H3-3/16" X2-7/8XO 1 1 TOP OF WHIFSTOCK H 11325' IRA PIPTAG H 11332' flMRKERJOINT H 11510' ~ ECLlPSETBGPATCH H 11650' ~ i RAaOACTIVECOLLAR H 11675' elm ~-~ i 14-112"TBG,12.6#,L-80,.0152bPf,0=3.958" H 11740' r-z :8: I PBTD H 11960' 1 '7"LN".#,N-eo,SEALLOCK H 12008' I ~ .0371bpf,ID=6.184" I' PERFORATION SUI\t1f1MRY REF LOG: fllCNUCQ/GR ON 11/27/03 TIE-IN LOG: GEOLOGY PDC LOG ANGLEA TTOP PERF: 91 @ 13030' J\bte: Refer to A-oductbn DB for historical perf data SIZE S~ INTERVAL Opn/Sqz DATE 2" 4 13030-13150 0 11/27/03 2" 4 13180 - 13296 0 11/27/03 2" 4 13320-13380 0 11/27/03 13-1/2" X3-3I16"X 2-718" LNRCMf'ED& PERFED H 13410' - DA lE RBI BY COMMEN1S DATE REV BY 02118/77 ORIGINAL COMPLETION 01/13190 RWO 11/10/03 M SE PROPOSED CTD SIDETRACK 11/28/03 TMN/TLP NORaC-1 CTD SIDETRACK 02126104 RMH/lLP GLV 00 03117/04 A TD/lLP CMf TO SURF AT ORlG COMPL COMMENTS PRUDI-OE BAY UNIT WELL: H-04A PERf\,11T J\b: 2031610 API J\b: 50-029-20104-01 SEC 21, T11N, R13E, 872.91' FNL & 1265' FEL BP Exploration (Alaska) · STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CCL, CNL CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 100' 36" Surface 2316' 24" Surface 10012' 12-1/4" 9517' 11322' 8-1/2" 10784' 13410' 4-1/8" x 3-314" o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 873' SNL, 1265' WEL, SEC. 21, T11N, R13E, UM Top of Productive Horizon: 2034' NSL, 3500' EWL, SEC. 15, T11N, R13E, UM Total Depth: 2987' NSL, 2912' EWL, SEC. 15, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 643315 y- 5959915 Zone- ASP4 TPI: x- 648016 Y- 5962914 Zone- ASP4 Total Depth: x- 647409 Y- 5963855 Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: SGRC, GR, EWR, Memory CNL, MGR, 22. CASING SIZE 30" 18-5/8" GRADE WT. PER FT. Conductor 96.5# 68# 147# 29# K-55 K-55 I N-80 N-80 L-80 13-3/8" x 9-518" 7" 8.81# /6.2# /6.16# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 13030'-13150' 9015'-9013' 13180' -13296' 9013' - 9009' 13320' - 13360' 9008' - 9008' One Other 5. Date Comp., Susp., or Aband. 11/28/2003 6. Date Spudded 11/17/2003 7. Date T.D. Reached 11/24/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 64.4' 9. Plug Back Depth (MD+ TVD) 13376 + 9008 Ft 10. Total Depth (MD+ TVD) 13410 + 9009 Ft 11. Depth where SSSV set (Nipple) 2000' MD 19. Water depth, if offshore N/A MSL 1 b. Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-161 13. API Number 50- 029-201 04-01-00 14. Well Number PBU H-04A 15. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028284 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RecoRD 300 sx Permafrost II 4800 sx Permafrost II 740 sx 'G', 200 sx 'G', 2170 sx PF II 1140 sx Class 'G' 157 sx Class 'G' SIZE 5-1/2", 17#, L-80 4-1/2", 12.6#, L-80 AMOUNT PULLED . 3-1/2" x 3-3/16- x 2-7/8" DEPTH SET (MD) 9431' 9431'-11751' PACKER SET (MD) 9431' 11740' 25. PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL-BBL GAs-McF WATER-BBL DEPTH INTERVAL (MD) 2000' AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH GAs-McF W A TER-BBL 26. Date First Production: Not on Production Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE""" 27. CORE DATA ~~~~~~~~~~~~p~~ :;t~~~~,Y~ia~~~~~~:~~ctures, apparent dips and presence of oil, gas or water (attach s~t! œ rveD')' None ¡ ;l~:;:A ¡ ~at.. JAM \I JAN 062004 I :;.~ 0 ~ I GIN i~ L G I' Alaska Oil & ;::h;~::~ COIl'l11issio" OIL -BBL Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 28. GEOLOGIC MARKERS. 29. .RMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 42N 11442' 8709' None Top CGL 11512' 8772' Base CGL 11630' 8855' 25N 12072' 8933' 25P 12096' 8942' 22P 12270' 9006' RECEIVEr} JAN 0 6 2004 Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble '11.M.lR, ~ Title Technical Assistant Date 0 I· D (P °DL{ PBU H-04A 203-161 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number P . N I A Drilling Engineer: Alistair Sherwood, 564-4378 ermlt o. pproval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 O~\G\N!\l- ..." .. BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-04 H-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Page 1 of 16 Start: Rig Release: Rig Number: Spud Date: 8/19/1971 End: 11/28/2003 11/14/2003 11/28/2003 N1 Date From - To Hours Task I Code I NPT I:h.~.~~_.u. -"------... PRE Move Nordic 1 from S pad to H pad. 11 Mile derrick down rig move. Rig move started at 2100 hrs, 11/13/2003. Arrive on H pad. The pad prep is still in progress. Stage rig down the pad from the well. Held PJSM with repect to raising the derrick and wind walls. Raise derrick. Scope derrick up. Raise wind walls. P/U injecter. Install gooseneck. Wait on pad preparation. Rig on Standby. Need to pull the wellhouse, grade and level pad. Bleed the flowline and remove the S riser and install the WH platform. Pad prep complete. PJSM prior to moving the rig over the well. Move rig over well. ACCEPT RIG ON H-04A AT 1600 HRS, 11/14/2003. N/U BOPE. RIU tanks, trailers, hardline to cuttings and divert tanks. Load rig pits with 2% KCL water with 1/2 PPB Biozan. Perform BOPE function and pressure test. Witness waived by AOGCC inspector. Send report information to AOGCC. Continue BOPE pressure I function testing. Had to replace Blind rams rubber horseshoe 2 times to get good test. Send test report to AOGCC. MIU CT connecter. Pull test. Check injecter head. Clean chains. Fill coil, PT new swivel joint and standing iron. Pump dart. Landed at 58.8 (Was 58.3 last time it was pumpted) Checked, and found an ice plug in dart catcher with no dart. Stab back on, pump to 70 bbls with no recovery. Pump another 10 bbls, with no bump. Found dart hung up in the CTC. No debris in front of dart. Disconnect CTC, remove dart. ID of WF CTC=1.0", Need 1.125" for dart. No debris, no problems with coil. Reconnect CTC, PT to 3500 psi. WEXIT Check WHP. Gauge reads 0 psi. Check with needle valve. There are a couple of psi of gas on tree. Can't bleed it off. Need to bullhead well dead with KCL in pits. On line with 2 pumps, pumping 7 bpm at 1000 psi. Final pump pressure was 1470 psi at 6.7 bpm. Pumped a total of 300 bbls. Well quickly went on a vac. Well is dead. Safety meeting prior to picking up WS BHA. Make up Whipstock BHA. RIH with WS BHA. IAP=230 psi, OAP=260 psi. Hold PJSM for changing out boilers. Can't pump thru WF BHA. Consult with WF hand. The ported sub was left out of the BHA. Can't drop a ball on seat wlo being able to pump if we need to disconnect. POOH to install ported sub. Tag up at surface. Stand back the injector. Swap out non ported sub for ported sub. Stab back on tree. Check circulation. Can pump down the coil and get returns. RIH with the whipstock. Tag up 3 times in the stack. Finally popped thru. Continue RIH. Stop at 11000', SI the choke line, pump down the coil to establish injectivity prior to setting the whipstock tray. --..- -.-----.....-.---.. 11/14/2003 00:00 - 06:30 6.50 MOB P 06:30 - 07: 15 0.75 MOB P PRE 07:15 - 12:00 4.75 MOB P PRE 12:00 - 15:00 3.00 MOB N WAIT PRE 15:00 - 15:30 0.50 MOB P PRE 15:30 - 16:00 0.50 MOB P PRE 16:00 -18:00 2.00 RIGU P PRE 18:00 - 21 :00 3.00 RIGU P PRE 21 :00 - 00:00 3.00 BOPSUR P PRE 11/15/2003 00:00 - 03:30 3.50 BOPSURP PRE 03:30 - 06:00 2.50 WHIP P WEXIT 06:00 - 09:15 3.25 WHIP P WEXIT 09:15 - 10:20 1.08 KILL P 10:20 - 10:40 0.33 WHIP P WEXIT 10:40 -11:10 0.50 WHIP P WEXIT 11: 1 0 - 11 :20 0.17 WHIP P WEXIT 11 :20 - 11 :40 0.33 WHIP P WEXIT 11:40 -12:15 0.58 WHIP N HMAN WEXIT 12:15-13:00 0.75 WHIP N HMAN WEXIT 13:00 -14:50 1.83 WHIP P WEXIT 14:50 - 15:05 0.25 WHIP P WEXIT Description of Operations .---.... -.---- Printed: 12/1/2003 9:57:52 AM ..,. .. Page 2 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: H-04 Common Well Name: H-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I F~~~ - To __.H~~~~ I Tas~. - Code NPTl Phase 11/15/2003 14:50 - 15:05 15:05 - 15:30 0.25 WHIP P 0.42 WHIP P WEXIT WEXIT 15:30 - 15:40 0.17 WHIP P WEXIT 15:40 -17:15 1.58 WHIP P WEXIT 17:15-17:50 0.58 WHIP P WEXIT 17:50 - 19:00 1.17 ZONISO P WEXIT 19:00 - 21 :30 2.50 ZONISO P WEXIT 21:30 - 21:45 0.25 ZONISO P WEXIT 21 :45 - 22:00 0.25 ZONISO P WEXIT 22:00 - 00:00 2.00 ZONISO P WEXIT Start: Rig Release: Rig Number: I I I Spud Date: 8/19/1971 End: 11/28/2003 11/14/2003 11/28/2003 N1 Description of Operations ...----.- Injectivity at 1 bpm is CTP=2170 psi, WHP=1974 psi. RIH to set WS. RIH at 9 fpm. WS anchor was set by eline at 11336'. Tag up at 11343' CTM. Stack 5 klbs. PU clean. No overpulls. RIH 20 fpm. No overpull. RIH 25 fpm. Set down 10 klbs. Got 5 klbs overpull. Should take 15 klbs to shear stud. Set down again to confirm that it is set. Got 15 klbs overpull. Could be set. Tag again and set down 10 klbs. PU got 15 klbs overpull? Possibly pinching on WS tray, but want to be sure. Tag again at 35 fpm. Set down with 15 klbs. PU at 12K Ibs overpull. Set down again, PU at 15 klbs. Set down again at 60 fpm, set down 15 klbs. PU with a 15 klbs overpull. Set down again, got 16 klbs overpull. Set down again, got 12 klbs overpull. Should be set. POOH to check. WS top at 11321.9' RA tag at 11329.2' RA tag 7.25' down from top of whipstock. WS tray orientation is 30 R of high side. Check Injectivity at 1 bpm. CTP=1912 psi, WHP=1750 psi. POH with WS setting tool pumping to ensure the well is clean. Getting diesel back in returns? Junking fluid. Where did diesel come from? IAP=328 psi, OAP=383 psi. Stand back injector. Rig down WS setting tool. WS stud sheared properly, tray left in hole. Lay down WF equipment. Make up cementing BHA. RIH with BHA #2 with cementing nozzle. Circ. while RIH. Clean returns. At 2000 hrs, the Rig loader had 1 quart engine oil leak to ice on the pad, due to cold weather conditions. [-27F, 10 MPH, -50F chill factor]. Reported leak to BP Enviromental and CTD manager. The rig crew cleaned up the leak completely. IR #679675 was submitted for approval. Tag whipstock at 11,348 ft. Correct [-26 ft CTD] to top of whipstock depth of 11,322'. lAP = 380 psi, OAP = 420 psi. Close choke and perform injectivity test. Pump 0.5 bpm, WHP = 1410 psi, Pump press = 1580 psi. No change in lAP or OAP. Pump 1.0 bpm, WHP = 1700 psi, Pump press = 1880 psi. Pump 1.5 bpm, WHP = 1960 psi, Pump press = 2350 psi. lAP = 410 psi, OAP = 450 psi. No comunication to IA. SAFETY MEETING. Review procedure, hazards and mitigation for pumping HCL acid to perfs. Circ. KCL water while prep to pump. Warm up pump line with rig KCL water. Press test pump line with 4000 psi. Nozzle set at 11,270' at top of tubing punch. Pump 15% HCL acid, 2.7 bpm, 1200 psi, Pump 12 bbls. Displace with rig water. Use SWS pump to displace acid to perfs. Circ. 2 bpm at 720 psi. Slow pump to 1.5 bpm. Close Printed: 12/1/2003 9:57:52 AM .... .. Page 3 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: H-04 Common Well Name: H-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 ! I' , Date ¡From - To , Hours I Task Code Start: Rig Release: Rig Number: NPT ' Phase 11/14/2003 11/28/2003 N1 Spud Date: 8/19/1971 End: 11/28/2003 .'---.. '---.." ...---- ----.-- --.-.--. 11/15/2003 22:00 - 00:00 2.00 ZONISO P -----....----.... ....-..... ...-.. .-----......--- Description of Operations WEXIT choke at 40 bbls displacement. Slow pump to 1.0 bpm with acid at nozzle. Squeeze 12 bbls acid to perfs. 1.0 bpm, 1750 psi SIWHP. Squeeze press = 1600 psi with 12 bbls acid to perfs. Over displace acid to perfs with 50 bbls water. RIH to flush out any acid to top of whipstock. Squeeze pressure fell to 500 psi at 1.0 bpm with water going to perfs. Pump 1.5 bpm at 900 psi SIWHP. Open choke at 50 bbl over displacement. Circ at 0.5 bpm. Injection pressure dropped a total of 1060 psi at 1.5 bpm, from the acid job. WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for pumping Cement. WEXIT Batch mix cement. Cement at wt at 0045 hrs. WEXIT Stage 5 bbls water ahead. Stage 15.8 PPG, G Cement with Latex, Pump total of 17.2 bbls cement. Stage 5 bbls water behind to clear lines. WEXIT Displace cement with Rig pump with KCL water. Displace at 2.6 bpm, 1000 psi. Lay in 17.2 bbls cement at 1.1 bpm from top of whipstock at 11,322 ft. to WCTOC of 10190'. Pull to safety of 10,000'. Close choke. Squeeze cement away at 1.0 bpm.. 3 bbls SQZD = 650 psi WHP. 4 bbls SQZD = 1200 psi WHP. Slow pump to 0.5 bpm. 6 bbls SQZD = 1450 psi. Stop pump at 7 bbls SQZD. SIWHP = 1500 psi. CMT in place at 0240 hrs. WHP fell to 1250 psi in 5 min. SQZ 1/2 bbl, Wait 5 min. SQZ 1/2 bbl, wait 5 min. Final SQZ vol of 9 BBLS held 1400 psi with very slow leakoff. Open choke at 0310 hrs. WEXIT Circ. Biozan water and clean out cement in 4-1/2" liner at 2.6 bpm to 11,260 ft. Found cement top at 10,900 ft and cleaned out to 11,260 ft. Circ. out contaminated cement to cuttings tank. WEXIT Chase contaminated cement while POH. 3.1 bpm, 1420 psi, Pull at 60 fpm. Dump contaminated cement returns to cuttings tank. Flag CT at 8000 ft EOP for depth control with milling BHA. Tag up at surface, lay down cementing BHA, and install swizzle stick nozzle. Circulate KCL, washing stack with swizzle stick nozzle to remove any cement that may be there. 11/16/2003 00:00 - 00: 15 0.25 ZONISO P 00: 15 - 00:45 00:45 - 01 :50 0.50 ZONISO P 1.08 ZONISO P 01 :50 - 03:10 1.33 ZONISO P 03:10 - 03:50 0.67 ZONISO P 03:50 - 06:30 2.67 ZONISO P 06:30 - 07:00 0.50 ZONISO P WEXIT 07:00 - 08:00 1.00 ZONISO P WEXIT 08:00 - 08:15 0.25 STWHIP P WEXIT 08:15 - 08:30 0.25 STWHIP P WEXIT 08:30 - 09:00 0.50 STWHIP P WEXIT 09:00 -11:10 2.17 STWHIP P WEXIT 11:10 -11:25 0.25 STWHIP P WEXIT PU WF BHA components from pickup truck. Break off swizzle stick nozzle. Hold PJSM prior to picking up milling BHA. Make up milling BHA. HCC DSM, HCC DSR, WF motor, WF MHA, 2 Jts of PH6. RIH to mill window for dual string exit thru 4.5" production tubing and 7" liner. Tie into EOP flag at 8000'. Make a -33' correction. Continue RIH. Weight check at 11150'=44klbs. Check with SWS lab. Cement compressive strength is at 1000 psi now. Free spin 2.5 bpm 1200 psi. RIH weight=18000 Ibs. Printed: 12/1/2003 9:57:52 AM . . Page 4 of 16 BP EXPLORATION Operations Summary Report Date H-04 H-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Task I Code I NPT ! Start: Rig Release: Rig Number: Phase 11/14/2003 11/28/2003 N1 Spud Date: 8/19/1971 End: 11/28/2003 WEXIT Tag top of cement at 11262'. Begin milling contaminated cement at 100 fph. Broke thru, made it to 11291' easily. Cement may be still green. PU, RIH dry and tagged up on cement at 11292'. Cement appears to have some compressive strength, but is not hard yet. Don't want to exit the 4-112" until the cement is hard. Pick up hole, wait on cement 1 hour, and circulate bottoms up to get cement back to surface. Caught bottoms up sample. Driller reports the cement returns are solid cuttings, not liquid. Tag up at 11929', seemed a little harder, but still able to push thru it to 11310' at 350 fph. Pick up hole, wait on cement another hour. Tag up @ 11310', we seem to have harder cement now. Plan to mill cement, then rezero depth when we get to the pinchpoint on the WS. Milling cement at 2.5/2.5/1520 psi, 30 fph. Now we are talking! WEXIT Tag top of WS, reset depth to E-line measured depth of top of WS of 11321.9'. Made+9.7' correction. Begin milling window. Note - For this WF whipstock the pinch point is at the top of whipstock. 11323.5', 1.6' into window. IAP=620 psi, OAP=674 psi. 11325.6', 3.7' into window. IAP=629 psi, OAP=684 psi. Pit vol=284 bbls. 2.56/2.61/1600 psi. Pump 10 bbls of 2# biozan. Getting steel shavings back on ditch magnets. 11326.1',4.2' into window. ROP has slowed down. Probably starting on the 7" casing. 11326.9',5.0' into window. ROP continues to be slow. Getting good metal returns on magnets. 11327.5',5.6' into window. ROP continues to be slow. IAP=660 psi, OAP=714 psi. Pits=284 bbls. 11328.2', 6.3' into window. ROP continues to be slow. IAP=680 psi, OAP=730 psi. Pits=284 bbls. 11329.0', 7.1' into window. ROP continues to be slow. IAP=680 psi, OAP=730 psi. Pits=283 bbls. Pick up and back ream thru window. Clean pickup and window. Up wt = 47K, Free spin = 1400 psi, Back ream pilot hole in cement up to 11,250 ft. Ream down. Dwn wt = 15.5K, Bled down lAP to 200 psi and OAP to 90 psi. 11329.3', 7.4' into window, 2.4K WOB, 400 psi motor work. 11329.8', 7.9' into window, 2.2K WOB. Stalled, Pickup and back ream, clean window, REam down, stalled at 11329.5' with no WOB. Ream down and stalled again. 11330.3'. Bottom of window at 11,330'. Less motor work, more WOB, Faster ROP. Milling formation at 15 FPH, 2.5K WOB, 300 psi motor work. Window top at 11,322 ft, bottom at 11,330 ft. Milled formation to 11,340 ft. Backream thru window. Clean window. No motor work. WEXIT Ream window area 4 times. Clean window. Ran down thru window with no pump. Clean. WEXIT Circ. well to FloPro, 460 bbls reconditioned and 120 bbls new, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/16/2003 11 :10 - 11 :25 0.25 STWHIP P 11 :25 - 12:30 1.08 STWHIP P WEXIT 12:30 - 12:45 0.25 STWHIP P WEXIT 12:45 - 13:45 1.00 STWHIP P WEXIT 13:45 - 14:10 0.42 STWHIP P WEXIT 14:10-15:00 0.83 STWHIP P 15:00 - 16:00 1.00 STWHIP P WEXIT 16:00 -16:10 0.17 STWHIP P WEXIT 16:10-16:20 0.17 STWHIP P WEXIT 16:20 - 17:00 0.67 STWHIP P WEXIT 17:00 - 18:00 1.00 STWHIP P WEXIT 18:00 - 19:15 1.25 STWHIP P WEXIT 19:15 - 20:30 1.25 STWHIP P WEXIT 20:30 - 21 :30 1.00 STWHIP P WEXIT 21 :30 - 22:10 0.67 STWHIP P WEXIT 22:10 - 23:30 1.33 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 11/17/2003 00:00 - 00:45 0.75 STWHIP P 00:45 - 01 :30 0.75 STWHIP P Description of Operations Printed: 12/1/2003 9:57:52 AM / ~. - BP EXPLORATION Operations Summary Report While RIH, Hold Kick while tripping drill. Good response from all hands. RIH thru window with pumps down. Tag bottom on depth with pumps down at 11342'. PU, kick on pumps. Orient to 30R. Tag bottom 11340', Begin drilling. Pit vol=314 bbls. IAP=177, OAP=95 psi. Difficult getting started drilling. 11347', Very slow ROP. Very stally and hard to get drilling. Possibly junk in the hole? Orient to 60R, continue trying to drill. Seem to be able to make a little better ROP at this tool face. Getting 20-60 fph. PROD1 11375', Orient 1 click. PROD1 Resume drilling. ROP seems to be improving slowly. We probably did have junk in the hole at the start. ROP was very slow and grabby. Free spin=3200 psi at 2.9 bpm. Drilling at 2.9/2.9/3300 psi. Pit vol=308 bbls. ROP=60-75 fph. 11388', Orient to straight down. Resume drilling 50-60 fph. Not exactly setting any speed records. 11463', Orient to 80R. ROP has improved, and we are now averaging 90 fph. Free spin = 3200 psi at 2.9 bpm. Resume drilling at 80R. ROP up over 100 fph. Definate zone 4 drilling. The ROP has been slowly trending up all day since we started drilling below the shoe. 11495', Orient around to 30R. Drill ahead. 2.9/2.9/3250 psi. Pit vol=308 bbls. 11520'. ROP slowing way down. Zone 3. Several stalls. Drilled to 11,525'. Very slow ROP. Log GR tie-in with RA tag to , Added 8 ft to CTD. Present TD = 11,533'. RA tag at 11,332 ft. Top of window at 11325', Bottom of window at 11333'. POH for new bit and motor. C/O motor, bit and add shock sub. 3.2 deg Air Drilling motor [180 RPM), 3.75" HCC Tri-cone bit and Sperry shock sub. BHA length = 71.94 ft. RIH with BHA #5, 3.2 Deg, ADM motor and HCC Tri-Cone Legal Well Name: H-04 Common Well Name: H-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To I Hours: Task' Code NPT Phase 11/17/2003 00:45 - 01 :30 0.75 STWHIP P WEXIT 01 :30 - 03:30 2.00 STWHIP P WEXIT 03:30 - 04:30 1.00 STWHIP P WEXIT 04:30 - 04:45 0.25 DRILL P PROD1 04:45 - 05:15 0.50 DRILL P PROD1 05:15 - 07:15 2.00 DRILL P PROD1 07:15 - 07:35 0.33 DRILL P PROD1 07:35 - 08:50 1.25 DRILL P PROD1 08:50 - 10:45 1.92 DRILL P PROD1 10:45 - 10:50 10:50 - 11 :35 0.08 DRILL P 0.75 DRILL P 11:35-11:45 0.17 DRILL P PROD1 11:45 -14:10 2.42 DRILL P PROD1 14:10 -15:30 1.33 DRILL P PROD1 15:30 - 15:55 0.42 DRILL P PROD1 15:55 - 16:35 0.67 DRILL P PROD1 16:35 -18:10 1.58 DRILL P PROD1 18:10 -19:30 1.33 DRILL P PROD1 19:30 - 21:15 1.75 DRILL P PROD1 21:15-23:00 1.75 DRILL P PROD1 23:00 - 23:45 0.75 DRILL P PROD1 23:45 - 00:00 0.25 DRILL P PROD1 Page 5 of 16 Start: Rig Release: Rig Number: I Spud Date: 8/19/1971 End: 11/28/2003 11/14/2003 11/28/2003 N1 Description of Operations from last well. 2.5 bpm, 2000 psi, full returns. POH slow while circ well to FloPro. Flag CT at 11,000 ft EOP. 2.5 BPM, 2000 psi. UO window milling BHA. Diamond Window Mill was worn across the face and in gauge. Diamond string reamer was 3.79" gauge. M/U new DS CTC. Pull test and press test. PRE-SPUD MEETING. Reviewed well program, hazards and mitigation with crew. Reviewed procedure for M/U Build BHA. M/U Build MWD BHA #4 with 4.125" HCC Bi-center bit and 3.06 deg motor. BHA = 66.5 ft. RIH with Build MWD BHA #4. Shallow test tools. Good test. RIH. Stop at EOP flag, make -23' correction. Continue RIH. Printed: 12/1/2003 9:57:52 AM . . Page 6 of 16 BP EXPLORATION Operations Summary Report H-04 H-04 REENTER+COMPLETE Start: 11/14/2003 NORDIC CALISTA Rig Release: 11/28/2003 NORDIC 1 Rig Number: N1 Fr~m - ~~.: H~urs . ~:Sk !~~de! ~PT_Phase 1.__._ PROD1 3.75" bit. PROD1 RIH with Build MWD BHA #5 with 3-2 deg ADM and 3.75" HCC tri-cone bit. Correct to CT flag at 11100'. [-16 ft CTD]. RIH to TD. Try to Orient TF to 65R. Could not get clicks on bottom, pull to just below window. Still not getting clicks, pulled above window and got 1/2 clicks. Orient and RIH. Drilling Z3 with Tri-cone bit. 2.8/2.8 bpm, 3100 - 3200 psi, 15 FPH, 70R. Drilled to 11550'. Drilling Z3 with Tri-cone bit. 2.8/2.8 bpm, 3100 - 3200 psi, 15 FPH, 70R. Drilled to 11565'. PU orient 1 click. Very difficult to get clicks. Finally managed to get one after multiple attempts. Drilling Zone 3. 2.7/2.7/3100 psi. Free spin 3030 psi. Pit vol=277 bbls. IAP=500 psi, OAP=557 psi. Was drilling 10 fph in pyritic interval in Z3, ROP improved to 20-30 ROP in non pyritic interval in Z3. See Remarks section for more observations on how the combination of the Baker ADM slow RPM motor worked with the Hughes STX20 tricone bit. PROD1 11598', Pick up to orient 2 clicks. It was difficult to get clicks again. Got our clicks, then could not RIH past 11545' (spike on GR, possibly a shale?). Avoid setting down with full rate to avoid sidetracking, or developing a lip. Finally had to orient all the way around to 90R to get thru, then fight it in the high dogleg below 11545' to get the additional clicks needed. PROD1 Resume drilling. Need to be very carefull about the interval at 11545', it is in the high dog leg section of the well, and we do not want to have problems and possibly sidetrack there. PROD1 11623', Returns went to O. Drilled into a loss zone. Pumping 2.6/0/3200, Lost 10 bbls into the formation, then started to get slight returns of 2.7/0.3. Pickup slow and try to reestablish returns. PROD1 Resume drilling, due to slow ROP, there are very little cuttings in wellbore. Resume drilling and attempt to generate cuttings to plug up loss zone. Losses back to 100%. Call for a truck of mud asap. PROD1 11625', Returns starting to come back slow. Pit vol=208 bbls, ROP=25 fph. 2.6/1.7/3200 . PROD1 11631', DD needs to orient to 45R. This isn't going to help our losses, but with a high dogleg motor we can't drill additional hole without orienting. Can't get any clicks near bottom. Managed to pull up and get them near the casing shoe after a great amount of messing about. Only getting 1 out of 10 clicks. It makes it very difficult to orient. The orienter in a big bind has trouble getting clicks. PROD1 Drilling build, 2.8/2.2 bpm, 3100 - 3300 psi, 20 fph, 85R TF, Drilled to 11,636'. Drilled into Zone 2 per GEO. 7 Hrs drilling, 103 ft of Zone 3 drilled. PROD1 POH for bi-center bit, new motor, new orienter and to LlO Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/17/2003 23:45-00:00 11/18/2003 00:00 - 02:00 0.25 DRILL P 2.00 DRILL P 02:00 - 03:45 1.75 DRILL P PROD1 03:45 - 05:00 1.25 DRILL P PROD1 05:00 - 06:00 1.00 DRILL P PROD1 06:00 - 06:40 0.67 DRILL P PROD1 06:40 - 08:50 2.17 DRILL P PROD1 08:50 - 10:30 1.67 DRILL P 10:30 - 11 :50 1.33 DRILL P 11 :50 - 12:00 0.17 DRILL P 12:00 - 12:10 0.17 DRILL P 12:10-12:25 0.25 DRILL P 12:25 - 15:30 3.08 DRILL P 15:30 - 16:45 1.25 DRILL P 16:45 - 18:40 1.92 DRILL P Spud Date: 8/19/1971 End: 11/28/2003 Description of Operations .----..-.. ..---.---.... Printed: 12/1/2003 9:57:52 AM ,/ -- ~ .. Page 7 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: H-04 Common Well Name: H-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours I Task I Code NPT Start: Rig Release: Rig Number: Phase Spud Date: 8/19/1971 End: 11/28/2003 11/14/2003 11/28/2003 N1 Description of Operations 11118/2003 16:45 - 18:40 18:40 - 19:00 ___0" _____.___ "____ _.___... ____..... .--.-..... .----...- ..-----.. ____no 19:00 - 19:30 19:30 - 21:45 21 :45 - 22:50 22:50 - 23:10 23:10 - 00:00 11/19/2003 00:00 - 00:50 00:50 - 02:25 02:25 - 03: 15 03:15 - 06:00 06:00 - 09:00 09:00 - 09:30 09:30 - 15:30 15:30 - 15:45 15:45 - 16:30 16:30 - 18:30 18:30 - 18:45 18:45 - 19:00 19:00 - 19:30 19:30 - 20:05 20:05 - 20:45 20:45 - 21:10 21:10 - 21:25 1.92 DRILL P 0.33 DRILL P 0.50 DRILL P 2.25 DRILL P 1.08 DRILL N 0.33 DRILL N 0.83 DRILL N 0.83 DRILL N 1.58 DRILL N 0.83 DRILL N 2.75 DRILL N 3.00 DRILL N 0.50 DRILL N 6.00 DRILL N 0.25 DRILL N 0.75 DRILL N 2.00 DRILL N 0.25 DRILL P 0.25 DRILL N 0.50 DRILL P 0.58 DRILL P 0.67 DRILL P 0.42 DRILL P 0.25 DRILL P PROD1 shock sub. PROD1 OOH. PJSM. LlO shock sub, ADM motor, orienter & bit. Bit grades 4-4-1/8 undergauage. PROD1 M/U new BHI HP motor with 3.06deg bend, orienter & rebuilt HCC 3-3/4" x 4-1/8" bicenter bit. M/U MWD tool & scribe BHA. M/U MHA & P/U injector. PROD1 RIH with BHA #6. SHT - OK. RIH. Subtract 27.8' from CTD @ flag. Continue RIH clean thru window & tag tight hole @ 11550'. P/U with 20k O/Pul1. PVT = 260bbls. IAP/OAP = 219/269psi. DPRB PROD1 Ream & backream tight hole with 1 OR TF 2.6/2.3bpm, 3000/3200psi & 25fpm ave ROP. Olpull (up to 40k) @ 11580', 11590' & 11618'. Tag hard @ 11623' (hi-DLS area). Backream & ream 3x till no O/pulls. RREP PROD1 Park bit @ 11599' to investigate smoke from power park. Observe bearing of power-park traction motor smoking. Callout DS Mechanics. RREP PROD1 PUH to 9300', into 5-1/2" tbg to troubleshoot power pack motor bearings. RREP PROD1 DS Mechanics inspect power pack. Decide to swap out motor. Call for crane, spare motor & rig electrician. RREP PROD1 POOH drilling BHA#6. RREP PROD1 OOH. PJSM. LlO BHA. Bit pass thru diameter worn from 3-3/4" to 3.68". RREP PROD1 Decouple & disconnect power pack traction motor & prep for C/O. Meanwhile W.O. on crane. RREP PROD1 Spot Peak crane. Prep traction motor for lift. Complete lift plan. RREP PROD1 SAFETY MEETING. Review lift plan, hazards and mitigation with personnel. RREP PROD1 Pick traction motor with crane. Set in new traction motor with crane. No problems. Rig up traction motor and test. RREP PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U MWD BHA. RREP PROD1 M/U MWD Build BHA #7 with 3.06 deg motor and 3.75" HYC DS49 bit. RREP PROD1 RIH with BHA #7, Shallow test tools. Subtract 33' from CTD @ flag. Continue RIH clean thru window to 11600'. PROD1 Up wt @ 11600 = 40k & run-in wt = 20k. Tight hole from 11600'. Ream in hole & tag TD @ 11627'. PUH to 11600' & retag @ same depth. Correct CTD to 11636'. DPRB PROD1 Backream & ream hole 2x from TD to 11600' till no motor work. PVT = 213bbls, IAP/OAP = 181/238psi. PROD1 PUH to 11530', orient 2 clicks & ream to btm. PUH to 11550', orient 3 clicks & ream to btm. TF @ 20L. PROD1 Drill to 11679' with 30R TF, 2.5/2.45bpm, 3000/3300psi & 75fph ave ROP. TF walking right. PROD1 Orient on btm - not getting clicks. PUH to 11470' & orient TF to 20R. RBIH. PROD1 Drill to 11730' with 30R TF, 2.5/2.5bpm, 3000/3300psi & 120fph ave ROP. PROD1 Orient 2 clicks & drill to 11745' with 50R TF, 2.5/2.5bpm, Printed: 12/1/2003 9:57:52 AM . . BP EXPLORATION Operations Summary Report Page 8 of 16 Legal Well Name: H-04 Common Well Name: H-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To I Hours Task I Code I NPT I 11/19/2003 21:10 - 21:25 21 :25 - 21 :45 ".--- -._- 21 :45 - 23:40 23:40 - 00:00 11/20/2003 00:00 - 01 :40 01:40 - 03:40 03:40 - 04:30 04:30 - 05:45 05:45 - 07:30 07:30 - 07:45 07:45 - 08:20 08:20 - 08:45 08:45 - 09:30 09:30 - 09:45 09:45 - 10:10 10:10 -10:30 10:30 - 12:40 12:40 - 13:15 13:15 -14:30 14:30 - 15:10 15:10 - 16:15 16:15 -18:00 18:00 - 18:45 18:45 -19:10 19:10-20:40 20:40 - 21 :10 Start: Rig Release: Rig Number: Phase I Spud Date: 8/19/1971 End: 11/28/2003 11/14/2003 11/28/2003 N1 Description of Operations -·-_0---··· "____ ...___ "_ _..__n __. __u 0.25 DRILL P 0.33 DRILL P PROD1 3000/3350psi & 60fph ave ROP. PROD1 Orient 2 clicks & drill to 11760' with 95R TF, 2.5/2.5bpm, 3000/3200psi & 45fph ave ROP. Land well with +1-87degs @ the bit. Geo wants 8848'-8850'vd @ 11900'. PROD1 POOH for lateral BHA. Paint EOP flag @ 11200'. PROD1 OOH. PJSM. SIB injector. LlO BHA. Observe metal shavings in orienter swivel- will C/O. Bit grades 1-3-1. PROD1 M/U new BHI HP motor with 1.37deg bend, orienter & HYC 3-3/4" x 4-1/4" bicenter bit. M/U MWD/RES tool & scribe BHA. Initialize EWR tool. M/U MHA & P/U injector. PROD1 RIH with BHA #8. SHT - OK. RIH. Add 128' to CTD @ flag?? DS depth tracking system faulty - showing running speed even with CT brakes on. Using Sperry depth system. Meanwhile call out DS Tech to rectify depth tracking problem. Continue RIH clean thru window. PROD1 Log down memory RES MAD pass @ 10fpm. See RA PIP tag 3' off @ 11329'. Continue logging thru hi-DLS area (11550' - 11650') without problems. Tag TD @ 11762'. Add 3' to CTD & correct TD to 11765'. PROD1 PUH to 11520', orient several times & managed to get TF to 90R. RBIH. PVT = 140bbls PROD1 Drill with 90-1 OOR TF, 2.5/2.4bpm, 2900/31 OOpsi. Drilled to 11850'. Call for one truck load of new mud. PROD1 Orient TF to 90L. PROD1 Drilling lateral, 2.8/2.7 bpm, 3100 - 3500 psi, 90L, 88 deg incl, 80 fph, Drilled to 11876'. PROD1 Orient TF to 100L. PROD1 Drilling lateral, 2.8/2.7 bpm, 3100 - 3500 psi, 90L, 88 deg incl, 80 fph, Drilled to 11894'. Mud losses went to 0.5 bpm at 11,880 ft. PROD1 Wiper trip. Clean hole. RIH. PROD1 Drilling lateral, 2.6 I 2.4 bpm, 3000 - 3500 psi, 90L, 88 deg incl, 60 fph, Drilled to 11920'. PROD1 Orient TF to 145L. PROD1 Drilling lateral, 2.6/2.2 bpm, 3000 - 3500 psi, 130L, 81 deg incl, 60 fph, Drilled to 12002'. PROD1 Orient TF to 140R. PROD1 Drilling lateral, 2.7/2.3 bpm, 3000 - 3500 psi, 140R, 78 deg incl, 40 fph, Drilled to 12050'. PROD1 Wiper trip to window. Clean hole. RIH. Drop pump to 1.0 bpm from 11700-11600 ft. PROD1 Drilling lateral, 2.7/2.3 bpm, 3000 - 3500 psi, 140R, 73 deg incl, 40 fph, Drilled to 12,075'. PROD1 Drilling lateral, 2.7/2.3 bpm, 3000 - 3500 psi, 90R, 70 deg incl, 40 fph, Drilled to 12,120'. PROD1 Drilling lateral, 2.7/2.3 bpm, 3100 - 3250 psi, 105R, 67 deg incl, 25 fph, Drilled to 12,135'. PROD1 Reorient TF to 11 OR due to loss of reactive torque. PVT = 133bbls, IAP/OAP = 433/476psi. PROD1 Drill to 12200' with 115L TF, 2.7/2.5bpm, 3000/3250psi & 35fph ave ROP. Add 220bbls of fresh flopro mud to system. PROD1 Wiper trip clean to window. Up wt = 39k. 1.92 DRILL P 0.33 DRILL P 1.67 DRILL P 2.00 DRILL P 0.83 DRILL P 1.25 DRILL P 1.75 DRILL P 0.25 DRILL P 0.58 DRILL P 0.42 DRILL P 0.75 DRILL P 0.25 DRILL P 0.42 DRILL P 0.33 DRILL P 2.17 DRILL P 0.58 DRILL P 1.25 DRILL P 0.67 DRILL P 1.08 DRILL P 1.75 DRILL P 0.75 DRILL P 0.42 DRILL P 1.50 DRILL P 0.50 DRILL P Printed: 12/1/2003 9:57:52 AM // --. .... .. Page 9 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-04 H-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: I Phase ¡ 11/14/2003 11/28/2003 N1 Spud Date: 8/19/1971 End: 11/28/2003 Date From - To i Hours Task ¡Code· NPT ··_·_._n_._. ..--.----. .... .-.- .-...---.-.-.-. ....-.-.. .-----...---.--.- 11/20/2003 21:10-21:40 0.50 DRILL P PROD1 21 :40 - 22:05 0.42 DRILL P PROD1 22:05 - 23:15 1.17 DRILL P PROD1 23:15 - 00:00 0.75 DRILL N DFAL PROD1 11/21/2003 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 01 :00 - 02:00 1.00 DRILL N DFAL PROD1 02:00 - 02:40 0.67 DRILL N DFAL PROD1 02:40 - 03:20 0.67 DRILL N DFAL PROD1 03:20 - 03:45 0.42 DRILL N DFAL PROD1 03:45 - 04:15 0.50 DRILL N DFAL PROD1 04:15 - 06:30 2.25 DRILL N DFAL PROD1 06:30 - 07:00 0.50 DRILL N DFAL PROD1 07:00 - 08:45 1.75 DRILL P PROD1 08:45 - 11 :00 2.25 DRILL P PROD1 11 :00 - 11 :45 0.75 DRILL P PROD1 11 :45 - 12:30 0.75 DRILL P PROD1 12:30 - 12:50 0.33 DRILL P PROD1 12:50 - 14:15 1.42 DRILL P PROD1 14:15 - 14:40 0.42 DRILL P PROD1 14:40 - 15:30 0.83 DRILL P PROD1 15:30 - 17:55 2.42 DRILL P PROD1 17:55 - 19:15 1.33 DRILL P PROD1 19:15 - 00:00 4.75 BOPSURP PROD1 11/22/2003 00:00 - 01 :30 1.50 DRILL P PROD1 01:30 - 04:15 2.75 DRILL P PROD1 04:15 - 04:50 0.58 DRILL P PROD1 04:50 - 05:00 0.17 DRILL P PROD1 05:00 - 05: 15 0.25 DRILL P PROD1 Description of Operations Log up GR & tie into RA PIP tag. Add 7' to CTD. RBIH clean to btm tagged @ 12204'. Run-in wt 18k. PVT = 297bbls. Orient on btm - not getting clicks. PUH to 12050' & orient - still not getting clicks. PUH to 11480' & orient without luck- suspect orienter has failed. POOH for orienter. Paint EOP flag @ 11200'. Continue POOH BHA#8. OOH. PJSM. SIB injector. UO BHA. Observe nothing amiss with orienter - will still C/O. Check bit - grades 3-2-1. Download resistivity memory data. M/U same BHI HP 1.37deg bend motor with a new orienter & new HYC 3-3/4" x 4-1/4" bicenter bit. M/U MWD/RES tool & check BHA scribe. Initialize EWR tool. M/U MHA & P/U injector. RIH with BHA #9. SHT orienter - not getting clicks. POOH for orienter. OOH. SIB injector. C/O orienter. M/U MHA & P/U injector. RIH with BHA #9. SHT orienter - OK. Subtract 45.6' to CTD @ flag. Continue RIH clean thru window. RIH to TD. Orient TF to high side. Drilling lateral, 2.6/2.2 bpm, 2900 - 3200 psi, 10L, 65 deg incl, 30 fph, Drill to 12,238'. Stacked wt, pick up with overpull. Back ream 100 ft. Ream down. Drilling lateral, 2.6/2.4 bpm, 2900 - 3200 psi, 60L, 65 deg incl, 40 fph, Drill to 12,308'. Drilling lateral, 2.6 I 2.4 bpm, 2900 - 3200 psi, 60L, 65 deg incl, 40 fph, Drill to 12,342'. Wiper trip to window. Clean trip. RIH. Orient TF to high side. Drilling lateral, 2.6/2.4 bpm, 2900 - 3200 psi, OL, 88 deg incl, 60 fph, Drill to 12,390'. Orient TF to 100L. Drilling lateral, 2.8/2.5 bpm, 3000 - 3300 psi, 100L, 91 deg incl, 20 fph, Drill to 12,405'. POH for bit and motor change. Flag CT at 11,200 ft EOP. OOH. PJSM. SIB injector. Download resistivity memory data. UO BHA. Bit grades 4-4-1 with slightly rung pilot & slots between blades packed with cuttings. SI MV & SW. Perform weekly BOPE pressure/function test. PT inner reel valve to 3500 psi. AOGCC test witness waived by Chuck Scheve. M/U BHI HP motor with 1.04deg bend, new orienter & new HYC 3-3/4" DS49 bit. MIU MWDIRES tool & scribe BHA. Initialize EWR tool. M/U MHA & P/U injector. RIH with BHA #10. SHT - OK. RIH. Subtract 37' from CTD @ the flag. Continue RIH clean thru window. Tag TD @ 12405'. Orient & drill to 12426' with 90R TF, 2.7/2.5bpm, 3000/3350psi & 35fph ave ROP. Orient TF to 80L. Drill to 12443' with 70-90L TF, 2.7/2.5bpm, 3000/3350psi & 65fph ave ROP. PVT = 312bbls. lAP = 208psi, OAP = 244psi. Printed: 12/1/2003 9:57:52 AM . . Page 10 of 16 BP EXPLORATION Operations Summary Report MWD quit pulsing. Cycle pumps & troubleshoot MWD pulses - no luck. POOH for MWD. Flag CT at 11,200' EOP. POH. CIO Sperry RES I MWD probes. Bit, motor and orienter were OK. RIH with RES I MWD BHA #11 with 1.04 deg motor and DS49 bit. Correct -34 ft at CT flag. RIH to 12,430 ft. Ream shales from 12,430-12350 ft. Up down 3 times, 10-20K overpul/s. Tag TD at 12441 ft and correct to 12,443 ft. Drilling, 2.5/2.0 bpm, 3800 - 4100 psi, 15L, 90 deg incl, Slow ROP. Drilled to 12477'. Drilling a sticky shale, stacking wt and overpulls. Had major positive RES shift from 2 to 8 Ohm's between last RES tool and this one. Will require MAD Pass at some point for valid RES log of well. Orient TF to 90L. Drilling, 2.6/2.4 bpm, 3000 - 3400 psi, 93 deg incl, 90L TF, Drilled up out of sticky shale. Drilled to 12,552'. Drilling, 2.6/2.5 bpm, 3000 - 3400 psi, 91 deg incl, 60L TF, Drilled up out of sticky shale. Drilled to 12,600'. Wiper trip clean to window. Up wt = 42k. Log up GR & tie into RA PIP tag. Add 12' to CTD. RBIH clean to 12590'. Ratty hole on btm. Tagged TD @ 12609'. Run-in wt 16k. PUH - pulling 47k. Backream & ream 2x to 12550'. Orient TF to 10R. Drill to 12615' with HS TF, 2.6/2.2bpm, 3150/3250psi & 45fph ave ROP. PVT = 319bbls. lAP = 264psi, OAP = 306psÎ. Still drilling thru claystone. Orient & drill to 12670' with 60-90R TF, 2.6/2.2bpm, 3150/3350psi & 50fph ave ROP. Wipe up hole to 12580' & orient TF around to 30R. Lost 50bbls of mud in 2hrs. Add aditional 50bbls into system. PVT = 303bbls. Drill to 12701' with 30-80R TF, 2.7/2.3bpm, 3150/3450psi & 40fph ave ROP. MWD quit pulsing. Cycle pump to get pulses back - MWD pulsing intermittently & freespin jump to 3650psi @ 2.7bpm. Suspect bit or equalizer jet plugging. DFAL PROD1 Continue cycling pumps & manage to get back (twice than normal - 40psi) MWD pulses. Meanwhile backream & ream thru shale intervals (12410' -12490',12565' -12635' & 12640'- 12700'). Orient TF to 110R. MWD still pulsing intermittently. Freespin drop to 3230psi @ 2.7bpm. Drill to 12710' with numerous stalls, 110R TF, 2.7/2.2bpm, 3250/3450psi & 35fph ave ROP. Drill to 12729' with 90R TF, 2.7/2.2bpm, 3150/3450psi & 25fph ave ROP. MWD pulses almost back to normal. Orient & drill to 12745' with 110R TF, 2.7/2.2bpm, 3150/3450psi & 45fph ave ROP. Orient & drill to 12760' with 110R TF, 2.7/2.2bpm, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-04 H-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To ' Hours Task 'Code NPT Phase -.-....- .._--. 11/22/2003 05:00 - 05:15 0.25 DRILL P PROD1 05:15 - 06:00 0.75 DRILL P PROD1 06:00 - 08:40 2.67 DRILL N DFAL PROD1 08:40 - 10:30 1.83 DRILL N DFAL PROD1 10:30 - 13:00 2.50 DRILL N DFAL PROD1 13:00 - 13:30 0.50 DRILL N DFAL PROD1 13:30 - 15:45 2.25 DRILL P PROD1 15:45 - 16:00 0.25 DRILL P PROD1 16:00 -17:15 1.25 DRILL P PROD1 17:15 - 18:15 1.00 DRILL P PROD1 18:15-18:50 0.58 DRILL P PROD1 18:50 - 19:10 0.33 DRILL P PROD1 19:10 -19:45 0.58 DRILL P PROD1 19:45 - 20:00 0.25 DRILL P PROD1 20:00 - 20:05 0.08 DRILL P PROD1 20:05 - 20:10 0.08 DRILL P PROD1 20:10 - 21 :25 1.25 DRILL P PROD1 21 :25 - 21 :55 0.50 DRILL P PROD1 21 :55 - 22:55 1.00 DRILL P PROD1 22:55 - 23:20 0.42 DRILL N 23:20 - 23:40 0.33 DRILL P PROD1 23:40 - 00:00 0.33 DRILL P PROD1 11/23/2003 00:00 - 01:1 0 1.17 DRILL P PROD1 01:10-01:45 0.58 DRILL P PROD1 01 :45 - 02:30 0.75 DRILL P PROD1 Start: 11/14/2003 Rig Release: 11/28/2003 Rig Number: N1 Spud Date: 8/19/1971 End: 11/28/2003 Description of Operations ----.---- ..-..----- Printed: 12/1/2003 9:57:52 AM ~/ --~ ~ .. Page 11 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-04 H-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 . . Date From - To ; Hours Task ¡ , Phase Code! NPT ' __...____.___u· 11/23/2003 01 :45 - 02:30 0.75 DRILL P PROD1 02:30 - 03:45 1.25 DRILL P PROD1 03:45 - 05:15 1.50 DRILL N DPRB PROD1 05:15 - 05:20 0.08 DRILL P PROD1 05:20 - 06:00 0.67 DRILL P PROD1 06:00 - 07:20 1.33 DRILL P PROD1 07:20 - 08:20 1.00 DRILL P PROD1 08:20 - 08:40 0.33 DRILL P PROD1 08:40 - 08:50 08:50 - 11 :00 0.17 DRILL P 2.17 DRILL P PROD1 PROD1 11:00-13:15 PROD1 2.25 DRILL P 13:15 - 14:50 1.58 DRILL N DPRB PROD1 14:50 - 15:20 15:20 - 15:50 15:50 - 18:00 PROD1 DPRB PROD1 DPRB PROD1 0.50 DRILL P 0.50 DRILL N 2.17 DRILL N 18:00 - 18:20 0.33 DRILL N DPRB PROD1 18:20 - 19:00 0.67 DRILL P PROD1 19:00 - 19:20 0.33 DRILL P PROD1 19:20 - 19:40 0.33 DRILL P PROD1 19:40 - 19:55 0.25 DRILL P PROD1 19:55 - 20:10 0.25 DRILL P PROD1 20:10 - 20:20 0.17 DRILL P PROD1 20:20 - 21 :35 1.25 DRILL P PROD1 21 :35 - 21 :50 0.25 DRILL P PROD1 21 :50 - 23:00 1.17 DRILL P PROD1 Start: 11/14/2003 Rig Release: 11/28/2003 Rig Number: N1 Spud Date: 8/19/1971 End: 11/28/2003 Description of Operations 3150/3450psi & 35fph ave ROP. Wiper trip clean to window. Very ratty across shale intervals. Ream & backream 3x from 12000' to TD & cleanout shale intervals. Orient TF to 120L. Orient & drill to 12780' with 115L TF, 2.7/2.2bpm, 3150/3450psi & 35fph ave ROP. Bring up mud system to 10ppb Kla-Gard. Drilling, 2.6/2.3 bpm, 3150 - 3500 psi, 92 deg, 60 fph, 10L, Drilled to 12,808'. Orient TF to 11 OL. Drilling, 2.6/2.3 bpm, 3150 - 3500 psi, 93 deg, 60 fph, 10L, Drilled to 12,822'. Getting too close to gas cap, so told to hold level at 90 deg by Geo. Orient TF to low side. Drilling, 2.6 I 2.2 bpm, 3000 - 3500 psi, 93 deg, 20 fph, 160L, Drilled to 12,861'. Drilling break at 12861 ft. ROP increased and mud loss increased [2.6/2.0 bpm]. Drilling, 2.6/1.8 bpm, 3000 - 3500 psi, 91 deg, 40 fph, 90L, Drilled to 12,920' Mud loss stayed at 2.5 11.8 bpm. Wiper trip to window. Back ream tight shales from 12700 - 12400'. 20K overpull and stack wt. Stuck pipe at 12,435 ft. Work 20K up and down. Work free after 20 min. Pull to window - OK. Log tie-in with RA tag at 11,332 ft. Added 9 ft to CTD. Pull up to 11100 ft. Stop and check SWS power pack. RIH clean to 12,300 ft. Slow down to 11 fpm and ream down. Dwn WT = 16K, Up wt = 40K. First motor work at 12450 ft. Ream shales. 12480-12400'. Ream down 50 ft, back ream. Ream down 50 ft, Back ream. Reaming with very little motor work. Just drag from BHA. Ream down in 50 ft increments. Cleaned hole to 12630 ft. Reaming shales from 12630 - 12700 ft. Very little motor work. 2.5/2.1 bpm. Ream to 12,720 ft. RIH to TD of 12,925 ft. Drill to 12949' with 90L TF, 2.7/2.1 bpm, 3100/3600 psi, 40fph ave ROP & 2k WOB. Orient 1 click & drill to 12952' with 90L TF, 2.7/2.1 bpm, 3120/3500 psi, 11fph ave ROP & 2k WOB. Orient 1 more click. Drill to 12959' with 70L TF, 2.7/2.0bpm, 3120/3500psi, 20fph ave ROP & 1k WOB. PVT = 212bbls. Orient & drill to 12962' with 80L TF, 2.7/1.8bpm, 3120/3500psi, 11 fph ave ROP & 4k WOB. Orient & drill to 12968' with 45-70L TF, 2.7/1.8bpm, 3120/3500psi, 33fph ave ROP & 6k WOB. Orient & drill to 12984' with 15L TF, 2.7/1.8bpm, 3120/3350psi, 74fph ave ROP & 6k WOB. Orient & drill to 13011' with 10L TF, 2.7/1.6bpm, 3130/3450psi, 21fph ave ROP & 12k WOB. Orient & drill to 13013' with 60R TF, 2.7/1.6bpm, 3130/3450psi & 9fph ave ROP. Drill into hard spot @ 13013'. Wiper trip with 41 k up wt. Pull up to 60K across shale intervals Printed: 12/1/2003 9:57:52 AM . . Page 12 of 16 BP EXPLORATION Operations Summary Report PROD1 & had motor work @ 12620'. Reduce pump, RBIH & backream clean. Continue wiping. Slight packing off from 12430' to 12400'. Wipe clean to to window. Returns improving from 12370'. RBIH with 16k run-in wt. MM partially plugged with cuttings. Cleanout MM. RIH relatively clean to btm. Orient TF to 35L. Drill to 13047' with 80-90L TF, 2.7/1.8bpm, 3150/3450 psi, 65fph ave ROP & 3k WOB. Orient & drill to 13086' with 50-70L TF, 2.7/1.8bpm, 3200/3450 psi, 70fph ave ROP & 5k WOB. Orient & drill to 13118' with 45L TF, 2.7/1.8bpm, 3200/3450 psi, 1 OOfph ave ROP & 1 Ok WOB. OrientTF to 11 OL. Drill to 13148' with 90-110L TF, 2.6/1.5bpm, 3150/3400 psi, 60fph ave ROP & 6k WOB. Orient & drill to 13165' with 75L TF, 2.6/1.5bpm, 3150/3400 psi, 60fph ave ROP & 3k WOB. Wiper trip fairly clean to window with few bobbles across shale intervals. RBIH & set down @ 12605'. Work past tight spot & ream in hole to 12800'. Backream & ream shale interval from 12800' to 12400'. RBIH to btm. Drilling, 2.6/1.8 bpm, 3100 - 3800 psi, 60R TF, 60 FPH, 90 deg. Drilled to 13,232 ft. Drilling, 2.6/1.8 bpm, 3100 - 3800 psi, 90R TF, 60 FPH, 93 deg. Drilled to 13,290 ft. Drilling, 2.6/1.8 bpm, 3100 - 3800 psi, 120R TF, 60 FPH, 93 deg. Drilled to 13,310 ft. Wiper trip to window. Back ream shales at 15 fpm, Shales in good condition. Pull to window. RIH. Went thru shales with out picking up. Good condition. RIH. Orient TF to 90R. Drilling, 2.6/1.8 bpm, 3100 - 3800 psi, 100R TF, 60 FPH, 91 deg. Drilled to 13,328 ft. Orient to 100R TF. Drilling, 2.6/1.6 bpm, 3000 - 3800 psi, 120R TF, 60 FPH, 90 deg. Drilled to 13,400 ft. Geo called TD for well @ 13,400 ft. Wiper trip to window. Ream up thru shales, OK. Did not stop coil. Shales in good condition. Log tie-in at RA tag at 11,332 ft. Added 14 ft to CTD. RIH to 11,600 ft. Log MAD pass down from 11,600 - 12,500 ft at 10 fpm, 2.4 I 1.8 bpm, 2900 psi. RIH clean and tag TD at 13410'. POOH to run Liner. Paint CT EOP flags @ 10600' & 8500'. Hole condition - good. Losses reduce to 0.25bpm from 5000'. OOH. SIB injector. PJSM. LlO BHA. Bit grades 6-6-0.20" undergauge. Review OH gauge with ANC & decide to make a clean out run to open up undergauge hole to 3.75". Download resistivity data & initialize MWDIDIR tools. Meanwhile SWS install 2 RA pip tags in 3-1/2" XN nipple for Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-04 H-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours: Task Code NPT Phase __.. ___....__._n_.___ 11/23/2003 21 :50 - 23:00 1.17 DRILL P 23:00 - 23:50 0.83 DRILL P PROD1 23:50 - 00:00 0.17 DRILL P PROD1 11/24/2003 00:00 - 00:50 0.83 DRILL P PROD1 00:50 - 01:40 0.83 DRILL P PROD1 01 :40 - 02:00 0.33 DRILL P PROD1 02:00 - 02: 15 0.25 DRILL P PROD1 02:15 - 03:10 0.92 DRILL P PROD1 03: 1 0 - 03:30 0.33 DRILL P PROD1 03:30 - 05:15 1.75 DRILL P PROD1 05: 15 - 06:00 0.75 DRILL P PROD1 06:00 - 08:00 2.00 DRILL P PROD1 08:00 - 09:30 1.50 DRILL P PROD1 09:30 - 10:00 0.50 DRILL P PROD1 10:00 - 12:00 2.00 DRILL P PROD1 12:00 - 12:15 0.25 DRILL P PROD1 12:15 - 12:35 0.33 DRILL P PROD1 12:35 - 12:55 0.33 DRILL P PROD1 12:55 - 15:00 2.08 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00 - 16:40 0.67 DRILL P PROD1 16:40 - 18:00 1.33 DRILL P PROD1 18:00 - 18:40 0.67 DRILL P PROD1 18:40 - 21 :50 3.17 DRILL P PROD1 21 :50 - 22:30 0.67 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 Start: 11/14/2003 Rig Release: 11/28/2003 Rig Number: N1 Spud Date: 8/19/1971 End: 11/28/2003 Description of Operations _________.___ _____no __ .. .. -.- .-......--- Printed: 12/1/2003 9:57:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ..... .. Page 13 of 16 BP EXPLORATION Operations Summary Report H-04 H-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To I Hours Task· Code NPT ;. Phase ! Date 11/24/2003 22:30 - 00:00 11/25/2003 00:00 - 00:45 00:45 - 01:1 0 01:1 0 - 01 :30 01 :30 - 03:35 03:35 - 05:30 05:30 - 05:50 05:50 - 06:00 06:00 - 07:15 07:15 - 07:25 07:25 - 07:40 07:40 - 07:50 07:50 - 10:30 10:30 - 13:00 13:00 - 13:50 13:50 - 14:50 14:50-15:15 15:15 -17:30 17:30 - 18:30 18:30 - 19:00 19:00 - 19:30 19:30 - 23:15 23:15 - 23:30 23:30 - 00:00 11/26/2003 00:00 - 00: 1 0 00:10 - 01 :00 01 :00 - 01 :40 01 :40 - 02:00 02:00 - 02:30 02:30 - 02:45 02:45 - 05:15 05:15-06:15 06:15 - 08:30 1.50 DRILL P 0.75 DRILL N 0.42 DRILL N 0.33 DRILL N 2.08 DRILL N 1.92 DRILL N 0.33 DRILL N 0.17 DRILL N 1.25 DRILL N 0.17 DRILL N 0.25 DRILL N 0.17 DRILL N 2.67 DRILL N 2.50 DRILL P 0.83 DRILL P 1.00 DRILL P 0.42 DRILL P 2.25 DRILL P 1.00 DRILL P 0.50 CASE P 0.50 CASE P 3.75 CASE P 0.25 CASE P 0.50 CASE P 0.17 CASE P 0.83 CASE N 0.67 CASE P 0.33 CASE P 0.50 CASE P 0.25 CASE P 2.50 CASE P 1.00 CASE P 2.25 CASE P n_ _u._._on___. PROD1 DPRB PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP COMP WAIT COMP COMP COMP COMP COMP COMP COMP COMP Start: Rig Release: Rig Number: Spud Date: 8/19/1971 End: 11/28/2003 11/14/2003 11/28/2003 N1 Description of Operations .--......-.--.--- completion liner. Well bore static losses @ 0.20bpm. M/U new BHI HP motor with 1.04deg bend, orienter & new HYC 3-3/4" DS-49 bit. M/U MWD tool & scribe BHA. M/U MHA & P/U injector. RIH with BHA #12. Attempt to SHT orienter - getting hi circ presure of 3900psi @ 1.85bpm. POOH to inspect BHA. OOH. SIB injector. Inspect BHA - found spring & pieces of hinge pin (from check valve) on top of MWD pulser. C/O MWD pulser & check valve. M/U MHA & P/U injector. RIH with BHA #12. SHT orienter - OK. Subtract 36' from CTD @ flag. Continue RIH clean thru window. Log up GR & tie into RA PIP tag. Add 8' to CTD. RIH clean to 11750'. Note that returns always bounce back to almost 1: 1 whenever RIH from 11550' to 11700' (Could be thief zone area). RIH clean to 12700 ft. Shales in good condition. Continue RIH clean to 13050 ft. Stack wt I motor work. Orient TF to 70L. RIH clean to 13210 ft. Stack wt. Orient TF to 70R. RIH clean to 13225 ft. Motor work for 1 ft, Ream down, very little motor work until 13,310 ft. Ream at 4 fpm with 90R TF. Several stalls from 13,310 - 13350'. Reaming 3.75" hole from 13,350 - 13362 ft. Many stalls at 13,362 ft. Have same TF, 1.04 deg motor and DS49 bit that hole was drilled with. Very slow reaming, tag bottom and stall motor. 2.6/1.8 bpm, 2900 I 3900 psi. Reamed to 13,370 ft. Reaming, 2.7/1.9 bpm, 2900 - 3900 psi, Still in original hole. Several stalls. Reaming better at 13,380 ft. 1.5 fpm, zero WOB. Clean out hole and tag TD at 13,405 ft CTD. Tied-in TD was 13,410 ft. Wiper trip to window. Clean hole. Back ream shales at 15 fpm, shales in good condition. Log up GR & tie into RA PIP tag. Add 7' to CTD - confirms TD is where we tagged. POOH to run Liner. Paint CT EOP flags @ 10600' & 8500'. OOH. SIB injector. PJSM. UO clean out BHA. Bit grades 1-1-1. RU to run liner. PU Baker tools and jewelry to rig floor. PJSM for running liner. Run 2 7/8" x 3 3/16" x 31/2" liner. MU injector. Install Baker CTC. Pull test to 33,000 Ibs. PT to 3,500 psi. Continue to PT CTC. Wait on XO for dart catcher. MU dart catcher to CT. Pump CT wiper dart. Retrieve dart. Lots of solids I gunk behind dart. Pump 10 bbls to try and clean up returns from coil. Pump 2nd CT wiper dart. Dart hit at 60.5 bbls Retrieve dart and fewer solids. Pump 10 bbls and returns cleaned up. MU injector. Run liner. Work liner in hole from 12,530' to TD. Drop 5/8" steel ball and circulate ball to disconnect from liner. Tried several techniques to released from liner with no success Printed: 12/1/2003 9:57:52 AM ~ .. Page 14 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: H-04 Common Well Name: H-04 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: _~:_t:. I ~ro~~ ~O ! Hours - Task ! Code NPT; Phase 11/26/2003 08:30 - 10:28 1.97 CASE N DFAL COMP 10:28 - 11 :50 1.37 CASE N DFAL COMP 11 :50 - 13:55 2.08 CASE N DFAL COMP 13:55-14:15 0.33 CASE N DFAL COMP 14:15-15:20 1.08 CASE N DFAL COMP 15:20 - 15:30 0.17 CASE N DFAL COMP 15:30 - 18:30 3.00 CASE P COMP 18:30 - 19:00 0.50 CASE N WAIT COMP 19:00 - 20:00 1.00 CASE P COMP 20:00 - 20:30 0.50 CASE P COMP 20:30 - 21 :00 0.50 CASE P COMP 21 :00 - 22:15 1.25 CEMT P COMP 22:15 - 00:00 1.75 CASE P COMP 11/27/2003 00:00 - 00:30 0.50 CASE P COMP 00:30 - 01 :15 0.75 CASE P COMP 01:15 - 01:30 0.25 EVAL P COMP 01 :30 - 02:00 0.50 EVAL P COMP 02:00 - 04:20 2.33 EVAL P COMP 04:20 - 04:30 0.17 EVAL P COMP 04:30 - 05:50 1.33 EVAL P COMP 05:50 - 06:50 1.00 EVAL P COMP 06:50 - 07:45 0.92 EVAL P COMP 07:45 - 09:00 1.25 EVAL P COMP 09:00 - 10:45 1.75 EVAL P COMP 10:45 - 11 :00 0.25 EVAL P COMP 11:00-11:40 0.67 EVAL P COMP 11 :40 - 13:25 1.75 EVAL P COMP 11/14/2003 11/28/2003 N1 Spud Date: 8/19/1971 End: 11/28/2003 Description of Operations POOH with Liner while keeping hole full, Pulled cleaned after 12150ft. Change out Bakers CTLRT, 5/8" Ball was on seat, PU and installed CTLRT and make up Injector head RIH with Liner L = 2626.30 ft Tagged bottom and corrected 13400' to 13410' , Cir and established losses Dropped 5/8" AI ball and displaced with Flo-Pro Reduced Qp from 1.9 bpm to 0.3 bpm at 40 bbl pumped behind the ball. Ball on seat @ 54.8bbls. Pressure up to 3300psi & release CTLRT. P/U @ 27k & confirm release. Displace well to 2% KCI at 3.0/2.3bpm & 14000psi. Circulate at reduced rate and wait on cementers. RU cementers. Mix 30 bbls biozan pill in pill pit. Hold PJSM for cement job. Batch mix cement. Cement up to weight at 20:50. Pump 2 bbls of water. Pressure test cement lines to 4,200 psi. Pump 32 bbls 15.8 ppg gas block cement at 2 bpm. Shut down and wash up lines. Load and launch CT wiper dart. Displace cement with 30 bbls KCI wI biozan. Switch to KCI. Displace with KCI at 2.12 11.4 bpm. Cement at shoe. Zero out micro motion meter. Continue displacement at 2.07 11.46 I 670 psi and slowly climbing. Slow rate to 1.5 bpm 2.5 bbls before calculated dart latch. 1.5/1.07 I 550 psi. Observe dart latch at 62 bbls into displacement. Shear plug at 3,450 psi. Continue displacement at 2.07 /1.25 11800 psi. Returns decreasing to 2.12 I .84/2,080 psi at 9.5 bbls of cement out shoe. Slow rate to 1 bpm a few bbls before calculated plug bump. Bump plug to 1,600 psi on calculated volume. 20.6 bbls of cement out of shoe. CIP at 22:10. Bleed off pressure and check floats. Pressure up to 500 psi. Unsting from liner. Lay in biozan replacing voidage only. POOH. POOH. Stand back injector. LD CTLRT. PU logging tool to rig floor. PJSM for PU cleanout I logging BHA. PU mill, motor, and logging tool. Load RA source. PU 86 joints 1 1/4" CSH. MU injector. RIH to 10,680'. Log down at 60 fpm pumping .53 bpm to to PBTD tagged @ 13404.7' Log up @ 60fpm from PBTD to 10680'. Meanwhile lay-in 150k perf pill in liner. POOH from 10680'. OOH. PJSM. SIB injector. UD 10 jts & RIB 38 stands of 1-1/4" CSH. PJSM for UD SWS source & logging tool. UD MCNUGR/CCL logging tool. Check for data quality - good. Line up to test liner lap. Compressive strength of cement @ 1600psi - W.O.C to get to 2000psi. Meanwhile download MCNUCCUGR data & fax to ANC Geo. Logged PBTD @ 13379' & TOL @ 10790'. Geo okays perf picks. Load perf guns into pipe shed. Printed: 12/1/2003 9:57:52 AM ..... .. Page 15 of 16 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-04 H-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date I I From - To Hours I Task ¡Code NPT! Phase 11/27/2003 13:25 - 14:00 0.58 EVAL P COMP 14:00 - 14:15 0.25 PERF P COMP 14:15-15:10 0.92 PERF P COMP 15:10 -16:10 1.00 PERF P COMP 16:10 - 18:20 2.17 PERF P COMP 18:20 - 19:15 0.92 PERF P COMP 19:15 - 21:30 2.25 PERF P COMP 21 :30 - 22:00 0.50 PERF P COMP 22:00 - 22:15 0.25 PERF P COMP 22:15 - 00:00 1.75 PERF P COMP 11/28/2003 00:00 - 00:15 0.25 PERF P COMP 00:15 - 00:30 0.25 PERF P COMP 00:30 - 01:45 1.25 PERF P COMP 01 :45 - 02:00 0.25 PERF P COMP 02:00 - 02:15 0.25 CASE P COMP 02: 15 - 02:45 0.50 CASE P COMP 02:45 - 04:40 1.92 CASE P COMP 04:40 - 06:20 1.67 CASE P COMP 06:20 - 06:40 0.33 CASE P COMP 06:40 - 08: 10 1.50 CASE P COMP 08: 10 - 08:20 0.17 CASE P COMP 08:20 - 08:45 0.42 CASE P COMP 08:45 - 09: 15 0.50 CASE P COMP 09: 15 - 09:40 0.42 RIGD P COMP 09:40 - 12:30 2.83 RIGD P COMP 12:30 - 14:30 2.00 RIGD P COMP 14:30 - 14:50 0.33 RIGD P COMP Start: Rig Release: Rig Number: Spud Date: 8/19/1971 End: 11/28/2003 11/14/2003 11/28/2003 N1 Description of Operations ---.---... Compressive strength of cement @ 2000psi. Fill hole with 5bbls of KCL. WHP/IAP/OAP @ 4011881225 psi @ onset of test. Staged up WHP in 500 psi intervals. PT @ 1500 psi with an injectivity of 4.6bpm & no change in IAP/OAP. Review forward plan with ANC & decide to set a L TP after perforating. PJSM on perforation job. M/U 16jts of 2" HSD 4spf PJ guns & blanks with CBF firing system. M/U 38 doubles of 1-1/4" CHS tbg. MIU injector. RIH with perforating BHA#15 circ perf pill @ min rate. Wt check @ 10700' = 33k. Tag PBTD @ 13398'. Pull to P/U wt & corect CTD to 13379' (PBTD as per MCNL log). Load 5/8" steel ball. Blow ball into CT with 10bbls perf pill behind. Position guns for btm shot @ 13360'. Chase ball to seat @ 2.4bpm/3000psi. Move guns down 2' to allow for pipe movement when firing guns. Ball on seat. Start moving guns at 2 fpm. Pressure up to 3,875 psi and fire guns. Perforated interval = 13030' - 13150', 13180' - 13296' & 13320' - 13360'. POOH. Stand back injector. Well control drill. PJSM for LD CSH. LD 76 joints of 1 1/4" CSH. LD CSH. PJSM for LD perf guns. LD perf guns. Unload perf guns from pipe shed. PJSM for PU Baker packer. MU liner top packer, Baker disconnect and check valves, 2 joints PH6. RIH pumping minimum rate to 10,685'. PU 37,500 Ibs. SO= 18,900Ibs. SO pumping .5 bpm, 73 psi. Sting into deployment sleeve no-go. PU 2'. Flag pipe. Unsting from sleeve. Establish circulation. Drop 5/8" aluminum ball. Pump down ball at 1.5 bpm, 4,80 psi. Slow rate prior to ball seating. Ball on seat. SO and sting into deployment sleeve. Set down 1 OK. PU 2'. On depth wI flag. Pressure up to 2,400 psi and set packer. PU to verify slips are set. SO 10K. Bleed CT pressure to 300 psi. PIT est L TP via annulus to 2000psi for 15mins - OK. Pressure down CT to 3800psi to hydraulically release from L TP. P/U from L TP @ 36k. POOH with L TP setting tool to 2000'. Getting back gas bubbles & lots of cement contaminated KCL. SID pumps & flowcheck well - stable. Will flush well & FP with a nozzle BHA. Continue POOH with L TP setting tool. UD L TP running tool BHA. M/U FP nozzle BHA. MIU injector. RIH nozzle BHA to 10750'. Pump down 30bbls of bio sweep. POOH with nozzle flushing wellbore @ 3.0bpm & 100fpm. Circ out gas bubble @ 8000'. Continue POOH to 2000'. POOH freeze protecting with 60/40 MeOH. SI master valve (34-1/2 turns). Printed: 12/1/2003 9:57:52 AM ... .. BP EXPLORATION Operations Summary Report Legal Well Name: H-04 Common Well Name: H-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To Hours Task Code NPT: Phase ___L____. 11/28/2003 14:50 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 18:00 0.17 RIGD P 1.00 RIGD P 0.50 RIGD P 1.50 RIGD P POST POST POST POST Page 16 of 16 Start: 11/14/2003 Rig Release: 11/28/2003 Rig Number: N 1 Spud Date: 8/19/1971 End: 11/28/2003 Description of Operations PJSM. PIT N2 lines - OK. Blow down CT with N2. Meanwhile clean out pits & tanks. RD injector. PJSM for ND. Nipple down BOP. Nipple up & pressure test tree cap. Rig Released at 18:00 hrs on 11/28/2003. Printed: 12/1/2003 9:57:52 AM . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITVE Re: Distribution of Survey Data for Well H-04 A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,300.00' MD 11,325.00' MD 13,410.00' MD (if applicable) . &-03 "l ~\ 19-Dec-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager AUachment(s) '~~~\~,~ RECEIVED DEC 22 2003 ßJri,~k~ 00 & Gas Cons. Commissfon A.nchOI"l.ge Survey Ref: svy4138 spe....,....,y-sul'l ffRTL L. I jij.ïi!.... . 5 ïæ Ä v··re: Ës A Halliburton Company Surface Coordinates relative to Project H Reference: 959915.21 N, 143315.00 E (Grid) Surface Coordinates relative to Structure Reference: 2305.31 N, 1994.77 E (True) Kelly Bushing Elevation: 64.40ft above Mean Sea Level Kelly Bushing Elevation: 64.40ft above Project V Reference Kelly Bushing Elevation: 64.40ft above Structure Reference . Your Ref: API 500292010401 Surface Coordinates: 5959915.21 N, 643315.00 E (70017' 52.7327" N, 148050' 21.7119" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 18 December, 2003 Survey Report Job No. AKMW0002771368, Surveyed: 24 November, 2003 . North Slope Alaska BPXA PBU_ WOA H Pad H-04A Halliburton Sperry-Sun Halliburton Sperry-Sun Survey Report for PBU_ WOA H Pad - H-04A Your Ref: API 500292010401 Job No. AKMW0002771368, Surveyed: 24 November, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11300.00 33.750 115.000 8533.65 8598.05 2705.59 N 5223.23 E 5962719.91 N 648485.69 E -1484.38 Tie On Point MWD Magnetic 11325.00 33.600 115.000 8554.46 8618.86 2699.73 N 5235.80 E 5962714.29 N 648498.36 E 0.600 -1497.14 Window Point 11350.78 40.700 122.040 8575.00 8639.40 2692.24 N 5249.41 E 5962707.07 N 648512.11 E 32.064 -1511.82 11381.41 47.140 131 .270 8597.07 8661.47 2679.51 N 5266.35 E 5962694.66 N 648529.29 E 29.606 -1532.61 . 11411.39 37.890 141.030 8619.17 8683.57 2665.06 N 5280.44 E 5962680.48 N 648543.66 E 37.822 -1552.78 11441.75 29.000 151.260 8644.50 8708.90 2651.32 N 5289.87 E 5962666.93 N 648553.35 E 34.586 -1569.30 11471.88 24.320 168.670 8671.46 8735.86 2638.81 N 5294.61 E 5962654.50 N 648558.33 E 30.076 -1581.77 11501.87 28.460 191.570 8698.39 8762.79 2625.71 N 5294.39 E 5962641.41 N 648558.36 E 36.382 -1591.36 11532.78 33.660 200.560 8724.87 8789.27 2610.46 N 5289.90 E 5962626.07 N 648554.16 E 22.504 -1599.69 11562.55 46.610 212.540 8747.62 8812.02 2593.51 N 5281.14 E 5962608.97 N 648545.72 E 50.485 -1606.41 11592.88 54.010 234.920 8767.12 8831.52 2577.03 N 5265.02 E 5962592.17 N 648529.92 E 61.553 -1607.88 11625.27 47.750 261.710 8787.77 8852.17 2567.66 N 5242.17 E 5962582.37 N 648507.25 E 66.699 -1599.55 11657.40 56.560 266.640 8807.47 8871.87 2565.15 N 5216.96 E 5962579.38 N 648482.09 E 29.964 -1584.55 11701.64 71.720 277.040 8826.76 8891.16 2566.65 N 5177.37 E 5962580.13 N 648442.48 E 40.213 -1556.94 11739.51 85.290 286.020 8834.30 8898.70 2574.11 N 5141.14 E 5962586.90 N 648406.12 E 42.674 -1527.16 11775.23 86.080 301.880 8837.00 8901.40 2588.53 N 5108.70 E 5962600.69 N 648373.40 E 44.329 -1494.73 11811.98 86.170 310.870 8839.49 8903.89 2610.25 N 5079.21 E 5962621.85 N 648343.50 E 24.408 -1458.86 11846.23 87.580 318.090 8841.36 8905.76 2634.20 N 5054.82 E 5962645.33 N 648318.67 E 21.447 -1424.75 11876.03 89.690 311.220 8842.07 8906.47 2655.12 N 5033.64 E 5962665.84 N 648297.10 E 24.109 -1395.02 11907.04 89.250 306.110 8842.36 8906.76 2674.49 N 5009.44 E 5962684.74 N 648272.53 E 16.539 -1364.44 11941.00 85.990 305.930 8843.77 8908.17 2694.44 N 4982.00 E 5962704.17 N 648244.71 E 9.614 -1331.25 . 11971.79 81.850 303.120 8847.03 8911.43 2711.79 N 4956.79 E 5962721.03 N 648219.17 E 16.221 -1301.48 12001.41 79.560 296.240 8851.82 8916.22 2726.26 N 4931.41 E 5962735.02 N 648193.52 E 24.189 -1273.75 12033.23 76.830 307.520 8858.35 8922.75 2742.67 N 4905.00 E 5962750.92 N 648166.81 E 35.739 -1243.89 12063.72 72.250 308.580 8866.48 8930.88 2760.77 N 4881.87 E 5962768.58 N 648143.33 E 15.390 -1214.95 12094.23 69.250 312.280 8876.54 8940.94 2779.44 N 4859.94 E 5962786.82 N 648121.05 E 15.090 -1186.41 12124.63 67.930 315.270 8887.64 8952.04 2799.01 N 4839.51 E 5962806.00 N 648100.25 E 10.134 -1158.19 12152.92 67.050 318.970 8898.47 8962.87 2818.16 N 4821.73 E 5962824.81 N 648082.11 E 12.476 -1132.07 12172.38 65.730 324.440 8906.27 8970.67 2832.14 N 4810.68 E 5962838.58 N 648070.79 E 26.632 -1114.28 12202.02 64.850 325.140 8918.66 8983.06 2854.14 N 4795.15 E 5962860.28 N 648054.85 E 3.663 -1087.54 18 December, 2003 -19:44 Page 2 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA H Pad - H-04A Your Ref: API 500292010401 Job No. AKMW0002771368, Surveyed: 24 November, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (tt) (tt) (tt) (tt) (tt) (tt) (tt) (0/100tt) 12237.47 69.780 326.020 8932.33 8996.73 2881.12 N 4776.67 E 5962886.89 N 648035.86 E 14.094 -1055.13 12267.86 75.240 329.370 8941 .46 9005.86 2905.61 N 4761.20 E 5962911.09 N 648019.93 E 20.814 -1026.58 12299.69 78.150 334.480 8948.79 9013.19 2932.93 N 4746.64 E 5962938.13 N 648004.84 E 18.100 -996.53 12330.60 81.320 342.230 8954.30 9018.70 2961.18 N 4735.44 E 5962966.15 N 647993.11 E 26.714 -968.04 12363.00 85.990 341 .350 8957.88 9022.28 2991.76 N 4725.38 E 5962996.54 N 647982.47 E 14.664 -938.59 . 12391.63 91.370 341.180 8958.54 9022.94 3018.85 N 4716.19 E 5963023.45 N 647972.76 E 18.801 -912.30 12421.74 88.720 343.120 8958.52 9022.92 3047.51 N 4706.96 E 5963051.93 N 647962.99 E 10.907 -884.83 12451.15 90.930 341.000 8958.61 9023.01 3075.49 N 4697.90 E 5963079.73 N 647953.40 E 10.413 -857.98 12473.09 93.040 337.300 8957.85 9022.25 3095.97 N 4690.10 E 5963100.06 N 647945.21 E 19.404 -837.53 12524.65 91.190 332.370 8955.95 9020.35 3142.59 N 4668.20 E 5963146.25 N 647922.42 E 10.206 -788.23 12559.43 90.040 328.670 8955.57 9019.97 3172.86 N 4651.09 E 5963176.19 N 647904.73 E 11.140 -754.29 12592.73 90.750 325.320 8955.34 9019.74 3200.78 N 4632.95 E 5963203.76 N 647886.07 E 10.283 -721.41 12622.61 92.330 324.970 8954.54 9018.94 3225.29 N 4615.88 E 5963227.94 N 647868.53 E 5.416 -691. 77 12652.17 90.220 327.430 8953.88 9018.28 3249.85 N 4599.44 E 5963252.18 N 647851.63 E 10.962 -662.52 12682.39 92.780 329.900 8953.09 9017.49 3275.64 N 4583.74 E 5963277.67 N 647835.43 E 11.769 -632.84 12709.97 92.160 332.720 8951.90 9016.30 3299.81 N 4570.51 E 5963301.58 N 647821.75 E 10.460 -606.03 12738.25 92.780 338.530 8950.68 9015.08 3325.54 N 4558.85 E 5963327.08 N 647809.61 E 20.642 -579.11 12768.63 90.040 338.010 8949.93 9014.33 3353.75 N 4547.61 E 5963355.07 N 647797.83 E 9.180 -550.63 12798.30 94.630 338.710 8948.73 9013.13 3381.30 N 4536.68 E 5963382.41 N 647786.37 E 15.649 -522.84 12828.75 94.010 338.710 8946.43 9010.83 3409.59 N 4525.66 E 5963410.48 N 647774.81 E 2.036 -494.44 12861.48 89.960 334.660 8945.30 9009.70 3439.61 N 4512.71 E 5963440.26 N 647761.30 E 17.492 -463.46 12891.86 88.280 332.190 8945.76 9010.16 3466.78 N 4499.13 E 5963467.16 N 647747.20 E 9.832 -434.19 . 12923.13 87.310 329.020 8946.97 9011.37 3494.00 N 4483.79 E 5963494.08 N 647731.34 E 10.594 -403.70 12946.77 86.590 329.900 8948.23 9012.63 3514.33 N 4471.80 E 5963514.18 N 647718.96 E 4.806 -380.56 12977.89 86.700 324.080 8950.05 9014.45 3540.37 N 4454.88 E 5963539.89 N 647701.55 E 18.673 -349.89 13004.71 90.400 323.560 8950.73 9015.13 3562.01 N 4439.05 E 5963561.22 N 647685.32 E 13.931 -323.22 13034.89 90.660 320.740 8950.45 9014.85 3585.83 N 4420.54 E 5963584.69 N 647666.35 E 9.383 -293.12 13068.68 90.310 318.450 8950.16 9014.56 3611.56 N 4398.64 E 5963610.00 N 647643.97 E 6.856 -259.35 13095.52 92.160 317.390 8949.58 9013.98 3631.48 N 4380.66 E 5963629.57 N 647625.61 E 7.943 -232.52 13128.49 91.190 314.220 8948.62 9013.02 3655.10 N 4357.69 E 5963652.75 N 647602.19 E 10.051 -199.59 13163.49 89.340 310.340 8948.46 9012.86 3678.64 N 4331.80 E 5963675.79 N 647575.86 E 12.281 -164.77 13195.02 89.780 306.290 8948.70 9013.10 3698.19 N 4307.06 E 5963694.86 N 647550.76 E 12.920 -133.70 13228.28 92.250 306.990 8948.11 9012.51 3718.03 N 4280.38 E 5963714.19 N 647523.70 E 7.719 -101.10 13260.69 93.920 312.810 8946.36 9010.76 3738.78 N 4255.57 E 5963734.46 N 647498.49 E 18.656 -69.08 13294.24 92.070 320.560 8944.61 9009.01 3763.14 N 4232.60 E 5963758.38 N 647475.07 E 23.717 -35.61 18 December, 2003 -19:44 Page 3 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_ WOA H Pad - H-04A Your Ref: API 500292010401 Job No. AKMW0002771368, Surveyed: 24 November, 2003 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 13324.08 90.840 325.320 8943.85 9008.25 3786.94 N 4214.63 E 5963781.83 N 647456.65 E 13358.36 90.220 331.310 8943.53 9007.93 3816.09 N 4196.63 E 5963810.64 N 647438.10 E 13377.23 88.900 329.370 8943.68 9008.08 3832.49 N 4187.30 E 5963826.85 N 647428.45 E 13410.00 89.160 329.370 8944.23 9008.63 3860.68 N 4170.60 E 5963854.72 N 647411.22 E All data is in Feet (US Survey) 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 318.0000 (True). Magnetic Declination at Surface is 25.4050 (12-Nov-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 1341 O.OOft., The Bottom Hole Displacement is 5683.20ft., in the Direction of 47.2100 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11300.00 11325.00 13410.00 2705.59 N 2699.73 N 3860.68 N Tie On Point Window Point Projected Survey 5223.23 E 5235.80 E 4170.60 E 8598.05 8618.86 9008.63 18 December, 2003 -19:44 Page 4 of 5 Dogleg Vertical Rate Section (0/100ft) 16.470 17.566 12.435 0.793 Comment -5.90 27.81 46.24 78.37 Projected Survey BPXA . . Dril/Quest 3.03.05.005 North Slope Alaska Survey tool program for H-04A Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 11300.00 0.00 8598.05 18 December, 2003 -19:44 To Measured Vertical Depth Depth (ft) (ft) 11300.00 13410.00 8598.05 9008.63 Halliburton Sperry-Sun Survey Report for PBU_ WOA H Pad - H-04A Your Ref: API 500292010401 Job No. AKMW0002771368, Surveyed: 24 November, 2003 BPXA Survey Tool Description BP High Accuracy Gyro (H-04) MWD Magnetic (H-04A) . . Page 5 of 5 DrillQuest 3.03.05.005 WGA- 'I { 17 (1.. 00 '{¡ o Drill II Redril/ 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 873' SNL, 1265' WEL, SEC. 21, T11 N, R13E, UM Top of Productive Horizon: 1829' NSL, 3967' EWL, SEC. 15, T11N, R13E, UM Total Depth: 3047' NSL, 2861' EWL, SEC. 15, T11N, R13E, UM .. STATE OF ALASKA .. ALASKA OPÅND GAS CONSERVATION COM_SION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: ISI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 13475' TVD 8955' 55 7. Property Designation: ADL 028284 II Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU H-04A ,,/ 12. Field / Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Date:/ 11/05/03 14. Distance to Nearest Property: 22959' 9. Acres in Property: 2560 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation KBE = 15. Distance to Nearest Well Within Pool I Surface: x-643315 y-5959915 Zone-ASP4 (Height above GL): 64.4' feet H-17A is 186' away at 12076' MD 16. Deviated Wells: 17. Anticipated pressure (see 20 MC 25.035) / Kickoff Depth 11330 ft Maximum Hole Angle 900 Max. Downhole Pressure: 3200 psig. Max. Surface Pressure: 2145 psig 18. Casin~i::ogram Specifications Topsettil'l9 DepthSottom QU(~~f~i~rd:a~~~ent Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-118" x 3-314" 3-3i16" x 2-7i8" 6.2# I 6.5# L-80 TCIII 2675' 10800' 8211' 13475' 8955' 108 sx Class 'G' ~ 19. pR,E$e",'-VVELI.. CONDITION$UMMARY(Tp be completed for RedrillANPRe-entry Operation$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured).:lE. ffect. iV. e. D..e.p.th.M..D (ft):I..E. ffective Depth TVD (ft): 12020' 9214' 11960'11964'.. 9165' CernentVOI\.Irne Junk (measured): 11900' Structural Conductor 100' 30" 300 sx Permafrost II 100' 100' Surface 2316' 18-5/8" 4800 sx Permafrost II 2316' 2316' Intermediate 10012' 13-3/8" x 9-5/8" 740 sx 'G', 200 sx 'G', 2170 sx PF II 10012' 7618' Production Liner 2491' 7" 1140 sx Class 'G' 9517' - 12008' 7244' - 9204' 20. Attachments ISI Filing Fee ISI BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth rvD (ft): 8912' - 9031' ISI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report ISI Drilling Fluid Program 1SI.20 MC 25.050 Requirements Perforation Depth MD (ft): 11672' -11810' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. =::::a71;;t~da~ ~~::ne CT9;;í~~ee' I '.{I tv Ç~ommission Use Only ~~~~~o ~~ 3 - /6'/ I ~~O':;~~'04-01-OO I ~-:;' 'W~þ~.. J~;;;'::';~:~~: Conditions of Approval: Samples Required D Yes ~ No Mud Log ~q'ul~; (,J. Ie) Y"~:I;iêI;No. Hydrogen Sulfide Measures ~Yes D No Directional Survey Required ~ Yes DNo Other: '"R.st- 'gaPE to "55"'00 p~¡ . 1 7 Date: Contact Alistair Sherwood, 564-4378 Mary Endacott, 564-4388 Prepared By NameiNumber: Terrie Hubble, 564-4628 Date Appmved Byo ~t.... ~ Form 10-401 Revised 3/2001 BY ORDER OF n ~ï~ì1\r~ CHE COMMISSION Date sl'~ ~~~! e e BP H-04A CTD Sidetrack Phase 1 Operations: Non rig Prep Work: · Drift the production tubing & liner and run a calliper survey to check mechanical integrity. · Integrity pressure test OA, IA&tbg as combo, wellhead seals & Xmas tree valves. · Create & validate a circulation path behind the 4%" straddle I tailpipe assy. · Set a packer with seal assy below the open straddle perfs to accept a new straddle I WS assy. Phase 2 Operations: Nordic 1 Prep Work: Planned for Nov 5th, 03. · Install 2Ys" x 360' straddle into pkr seal. Set upper, non sealing pkr and record orientation of key slot. · Install s~ealr g anchor wi perforatable WS assy in pkr, oriented for a lowside, (180°) tray toolface. · Lay i '10 Is of neat 15.8ppg cement above the WS and allow it to gravitate out the fluid behind the stra rid 4%"x7" annuli. Phase 3 Operations: Mill window, Drill and Complete sidetrack: A single CTD milling BHA will cut a dual string window in the 4% x 7" liner at 11,330' MD (-8,559'ss) off of a W'ford WS. A minimum of 2 BHA will drill the build & lateral sections of the sidetrack as per the attached directional plan. The max hole angle will be _90°. Solid 33/16 x 2Ys" liner will complete the sidetrack, which will be cemented and selectively perforated. Mud Program: · Phase 1: Seawater/1 % KCI ~<'2 · Phase 2: Mill with seawater I %Ib biozan, drill with Solids Free Flo-Pro (8.6~P9) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: The production liner will be solid 33/16TCII x 2Ys" STL from a TD of....13;95', (-8955'ss) to 10,800'MD /' (8,211 'ss) within the tbg tailpipe. The liner will be cemented W~2 bþts with a planned TOC at 10,800' within the 4%" tailpipe."~:/./ Parent Well Casings 18%" 96#, K-55, BTC - Surface CSG 13%" 68#, K-55, Seal Lock -Intermediate to 2,300' 9%" 47#, L-80, Seal Lock - Int 2,300 - 10,012 7" 29#, N-80, Seal Lock - Production Liner Sidetrack Casings 3-3/16" 6.2#, L-80, TCII - Prod LNR 2Ys" 6.5#, L-80, STL - Prod LNR10570 OH size 23 17Y2 12\4 8Y2 Burst (psi) 2420 3450 6870 8160 Collapse (psi) 780 1950 4760 7020 4Vs 3% 8520 10570 7660 11170 Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90°. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · H-04A will be just 186' ctr-ctr away from well H-17A at 12,076'md · H-04A at TD will be 22,959' from the change of ownership boundary, (Prudhoe Bay Unit) Logging · MWD Gamma Ray will be run in the open hole section. Memory CNL will be run inside the liner. e e Hazards · H2S has never been directly measured on H04. 10-20ppm is the maximum measured on the pad. / · Two faults will likely be cut by the wellpath. The risk of a lost circulation event is considered moderate. Reservoir Pressure · Res. press. is estimated to be 3200 psiyt 8800'ss (7.0 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2145 psi. / i~d:t -AttjJ~ CdJ\f6ò{ .fòv\A"IjIß(a; lS tlkJ ~~~~.. 1~ gf+"~~ TREE = WELLHEAD = m"~~< < ACTUATOR = KB. ELEV = ,~.o,.n~~~..~..~ ~ BF. ELEV = KOP= ~ " '^~~ Max Angle = Datum MD = DatumlVD= 6" CrN MCEVOY óriS 64.44' 45' 2600' 54 @ 5200' . . . . . 11617' 8800' SS e H-04 I S~TES: . 2000' H5-1/2" CAMCO SSSV LAND NIP, ID = 4.562" 1 113-3/8" CSG, 68#, K-55, ID = 12.415" H 2293' 118-5/8" CSG, 96#, K-55, ID = 17.655" H 2316' I \ r--J I . 2293' H 13-5/8" X 9-518" Xol GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 2 3018 2940 18 OTIS RA 1 5511 4677 54 OTIS RA Minimum ID =3.725" @ 11750' 4-1/2" OTIS XN NIPPLE L 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H 9431' TOPOF7"LNR H 9517' 9363' H5-1/2" OTIS X NIP, ID = 4.562" I í i 9415' HTBG SEAL ASSY I :8: ~ 9431' H9-5/8" X 5-112" BKR A<R, ID = 4.0" I \ I 9431' H5-1/2" x 4-112" XO 1 .. I 19-518" CSG, 47#, N-80, ID = 8.681" H 10012' 1 ... .. ÆRFORA TION SUMMARY REF LOG: CBL ON 02/14/77 ANGLEATTOPÆRF: 32 @ 11649' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4" 4 11649 - 11679 S 01/18/82 2-7/8" 6 11672 - 11682 0 11/08/02 4" 4 11699-11734 S 01/18182 4" 4 11746 - 11776 S 01/18/82 5" 4 11780 - 11810 0 11/06/89 I 11510' HMARKERJOINT I ~ 11675' 11 RADIOACTIVE COLLAR ELINE I ~ MEASUREMENT I 11740' H 7" x 4-1/2" BKR A<R, ID = 4.0" I 11745' H4-1/2" OTIS X NIP, ID = 3.813" I 11750' H4-1/2" OTIS XN NIP, ID = 3.725" 1 11751' H4-1/2" OTIS TBG TAIL, 10 = 3.958" I 11751' H ELMD TT LOGGED 05/20/90 1 z z 14-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 11751' I I PBID H 11960' 17" LNR, 29#, N-80, .0371 bpf, ID = 6.184" H 12008' o -.. ~ 11900' 11 FISH - BKR TBG CONVEYED I ÆRFORA TING GUN 66" x 5" DATE 02/18/77 01/13/90 02/15/01 03/01/01 08/16/01 11/01/01 REV BY COMMENTS ORIGINAL COM PLETION RWO SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL RNlKAK CORRECTIONS WBITP SURF LOC CORRECTION DA TE REV BY COMMENTS 11/08/02 CAO/KK ADÆRF 07/14/03 CMOITLP MAXANGLECORRECTION PRUDHOE BAY UNIT WELL: H-04 PERMIT No: 1710220 API No: 50-029-20104-00 SEe 21, T11 N, R13E, 872.91' FNL & 1265' FEL BP Exploration (Alaska) TREE =, WELLHEAD = ACTUATOR = 6"CWV MCEVOY OTIS 64.44' 2600' 54 @ 5200' 11617' 8800' SS 113-3/8" CSG, 68#, K-55, 10;= 12.415" 118-5/8" CSG, 96#, K-55, 10 = Minimum ID :::: 11150' 4-1/2" OTIS XN NIPPLE 15-1/2" TBG, 17#, L-80, .0232 bpf, !D = 4.892" TOPOF7" LNR H I 9-5/8" CSG, 47#, N-80, 10 = 8.681" 2293' I \ 2316' ~ I TES: 2000' 1-15-1/2" CAMCO SSSV LAND NIP, ID = 4.562" I 2293' .. ST MD TVD 2 3018 2940 1 5511 4677 13-5/8" X 9-518" Xol GAS LIFT MANDRELS DE\! TYPE VLV LATCH OTIS RA 54 OTIS RA PORT DATE 9431' 10012' H 1-1 1-1 14-1/2" TBG, 126#, L-80, .0152 bpf, 10 = 3.958" H 11751' I PERFORATION SUMMARY REF LOG: CBL ON 02/14/77 ANGLE AT TOP PERF: 32 @ 11649' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 11649-11679 2-7/8" 6 11672 - 11682 4" 4 11699 11734 4" 4 11746-11776 5" 4 11780 - 11810 17" LNR, 29#, N-80, .0371 bpf, 10 = 6.184" DATE 02/18/77 01/13/90 02/15/01 03/01/01 08/16/01 11/01/01 REV BY COMMENTS ORIGINAL COMPLETION RWO SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL RNlKAK CORRECTIONS WB/TP SURF LOC CORRECTION ,I o 11960' 12008' DA TE REV BY COMMENTS 11/08/02 CAO/KK 07/14/03 CMOITLP MAX ANGLE CORRECTION 9363' H5-1/2"OTISXNIP, ID = 4.562" I 9415' HTBG SEAL ASSY I 9431' 1-19-5/8" X 5-112" BKR PKR, 10 = 4.0" I 9431' 1-15-1/2" X 4-1/2" XO I HMARKER I H RADIOACTIVE COLLAR ELINE I I MEASUREMENT 11740' 1-17" x 4-1/2" BKR PKR, ID = 4.0" I 11745' 1-14-1/2" OTIS X NIP, ID = 3.813" I 11750' 1-14-1/2" OTIS XN NIP, 10 = 3.725" I 11751' 1-14-1/2" OTIS TBG TAIL, ID = 3.958" I 11751' 1-1 ELMO TT LOGGED 05/20/90 I 11900' 11 FISH - BKR TBG CONVEYED I PERFORA TING GUN 66" x 5" PRUDHOE BAY UNIT WELL: H-04 PERMIT No: 1710220 API No: 50-029-20104-00 SEe 21, T11 N, R13E, 872.91' FNL & 1265' FEL Exploration (Alaska) P.rent Welll"lo.: TI. on MD: lUg: "....DMum: V .a.ction ..... 318.00' BP Amoco WEUPATH DETAI... Pt.... H-au 500282010401 .... 11300.00 8 : 04 811111871 00:00 8...4Oft ~= 0.00 ~~'-~ 0.00 :=~ 2.... Co-ordinate (N/E Reference: Well Centre: H-04, True North Vertical (NO Reference: System: Mean Sea level Section (VS Reference: Slof - 04 (O.OON.O.OOE) Measured Depth Reference: 6: 04 8/19/1971 00:00 64.40 Calculation Method: Minimum Curvat....-e 11300.00 33.75 115.00 8533.8. 11330.00 33.H 115.00 8558.82 11350.00 35.18 118.5' 8515.13 11380.00 .....75 135.aa 1805." H~~~~ ii; i::!i i.i.;;:.:7:.· 11733.18 aa.oo 278.'8 ... !~ H~i::i: :::: ~iH; i:,,!.i:!::::¡::' 1212381.1. 80.00 3311.31 ii i~ª~:ii ~~ æ:~i ;i;;:~i .. ~U~I~..aAflij :::::~: TVD MD Annobiti_ 85 11300.00 TIP 82 11330.00 KOP 13 11350.00 3 II 11390.00 4 08 11453.47 5 85 11503.47 8 11553.47 7 11733.1' . 11983.1' 1 1114.43 12121.11 10 ..23,42 12218.11 11 1154.78 12367.18 12 ::::-~: ~~::~.~: ~~ 15 .1N.78 12142.18 15 18 8854.78 13142.1' 16 17 88154.78 13312.1' 17 1. '1'4.78 13'75.00 D 8400 8450 8500 :58550 ~ 8600 an "'8650 z: .. 0.8700 GI ~ 8750 CU .!::! 8800 1:: ~ 8850 2 8900 ... 8950 9000 9050 9100 I L REFERENCE INFORMATION SECTION DETAIL' 2705.81 H88.5a H83.87 2818.31 5ii::! 280...... 2125."3 2827". ~i~i 3313.83 3$22.40 :~~I .... i! 1:':':"::::.000 ~~::::::.. ~.!,:-..5~;'~.:71 :.' ¡:,!:.~.~..: .1"...., :iffi:: ~::: 1:~ :~~~:: ',........ .7......00 -Sl1'.35 ':":,',.:'::' i;: 2!g~ ~eU1 18.00AAttØ".otTAjlS 11.82 '8.00 ~.oo +NI~ 15~~~ T."... Shøpe 2106,555166,17 Polygon 2353,335031,40 Polygon lm'~ mIH §3on ~:gr :m:~ ~:~ bp LEGEND H-04 (H-04) ~:g~~~1·W) Plan#6 H-04A Plan #6 T ^M Azimuths to True North Magnetic North: 25.50· Magnetic Field Strength: 57561nT Dip Angle: 80.83· Date: 8/15/2003 Model: bggm2003 Baker Hug?!", I~i{~~t (ffirj)~!~~r~¡~~qc()m 5223.21 :~::= ¡~!~ :~;t-:; 4848.02 5::~ 4"3.1$ ~!H! N~11M ~~;r' ,.. ... ,... -.. 6654.00 _... _... ...... Plan: Plan #6 (H-04/Plan#6 H-04A) Created By: Brij Potnis Date: 8/1512003 " ; ~~:"" -.""'. \_~) .""~,,;---/ Contact Information: é INTEQ ... C 3700 $ Ô360 Q ::'3500 - + :ë3400 '5330 Z - ~3200 -- z: '$ 3100 o en 3000 e 2900 ._~7" ?L.-~ /~.- --<-// , , , , .... .... ."' " "." .. ..... .'. .... '. . '. . .. .'. .........'.;.. .. ..-' ". ,', '.,., '. .... ..... .... .. .. ....... .. ......... ............. "... . ".', ',',".' . , : : : . , . . . . 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 West(-)/East(+) [100ft/in] \ e -1650-1600-1550-1500-1450-1400-1350-1300-1250-1200-1150-1100-1050-1000 -950 -900 -850 -700 -650 -500 -450 -400 -350 -300 -250 -200 Vertical Section at 318.00· [50ft/in] 8/15/2003 3:52 PM Company: Field: Site: Well: WeUpath: BP Amoco Prudhoe Bay PB H Pad H-04 Plan#6 H-04A e BP-GDB e Baker Hughes INTEQ Planning Report INTEQ Date: 8/15/2003 Time: 15:52:51 Page: , CooOrdinate(NE) Reference: Well: H-04, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: , Well (0.00N,0.00E,318.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle _....__. .___..._.... __ ....__ __._.... _____n___ __________.._._____....______.____.._ _.. . 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 Site: PB H Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957572.25 ft 641366.07 ft Map Zone: Coordinate System: Geomagnetic Model: Latitude: 70 17 Longitude: 148 51 North Reference: Grid Convergence: Alaska, Zone 4 Well Centre bggm2003 30.055 N 19.802 W True 1.08 deg Well: H-04 Slot Name: 04 H-04 Well Position: +N/-S 2306.08 ft Northing: 5959915.21 ft Latitude: 70 17 52.733 N +E/-W 1992.58 ft Easting : 643314.78 ft Longitude: 148 50 21.718 W Position Uncertainty: 0.00 ft Wellpath: Plan#6 H-04A 500292010401 Current Datum: 6: 048/19/1971 00:00 Magnetic Data: 8/15/2003 Field Strength: 57561 nT Vertical Section: Depth From (TVD) ft 21.40 Targets Name Description Dip. Dir. H-04A Polygon6.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 H-04A Fault 1 -Polygon 1 -Polygon 2 H-04A Fault 2 -Polygon 1 -Polygon 2 H-04A T6.1 -Plan out by 3.36 at H-04A T6.2 H-04A T6.3 H-04A T6.4 H-04A T6.5 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8844.00 8844.00 8854.00 8955.00 8955.00 8955.00 Height 64.40 ft +N/-S ft 0.00 +N/-S ft 2706.55 2706.55 3013.67 3457.73 4036.73 3899.79 3304.65 2675.14 2709.03 2353.33 2353.33 2642.48 3298.69 3298.69 3528.90 2602.04 2602.95 2741.60 3025.10 3414.07 3917.31 Drilled From: TieoOn Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +E/-W ft 5188.17 5188.17 4818.93 4612.35 4148.27 3985.62 4509.40 4737.46 5058.19 Map Map Northing Easting ft ft 5962720.00 648450.00 5962720.00 648450.00 5963020.00 648075.00 5963460.00 647860.00 5964030.00 647385.00 5963890.00 647225.00 5963305.00 647760.00 5962680.00 648000.00 5962720.00 648320.00 5962364.00 648306.00 5962364.00 648306.00 5962658.00 648559.00 5963299.00 647758.00 5963299.00 647758.00 5963532.00 647903.00 5037.40 5037.40 5295.98 4507.29 4507.29 4656.72 5161.17 5157.93 4923.77 5962615.00 648425.00 5962615.85 648421.75 5962750.00 648185.00 5963030.00 648000.00 5963415.00 647790.00 4744.13 4541.50 4115.98 5963910.00 647355.00 H-04 11300.00 ft Mean Sea Level 25.50 deg 80.83 deg Direction deg 318.00 <-- Latitude --> <-- Longitude --> Deg Min Sec Deg Min See . -...--.--.-----...---..--.---- 70 18 19.334 N 70 18 19.334 N 70 18 22.357 N 70 18 26.725 N 70 18 32.422 N 70 1831.077 N 70 18 25.220 N 70 18 19.028 N 70 18 19.359 N 70 18 15.861 N 70 18 15.861 N 70 18 18.703 N 701825.162N 70 18 25.162 N 70 18 27.425 N 70 18 18.306 N 70 18 18.315 N 70 18 19.680 N 70 18 22.470 N 70 18 26.296 N 70 18 31.248 N 148 47 50.428 W 148 47 50.428 W 148 48 1.189 W 148 48 7.206 W 148 48 20.731 W 148 48 25.477 W 148 48 10.211 W 148 48 3.572 W 148 47 54.218 W 148 47 54.832 W 148 47 54.832 W 148 47 47.286 W 148 48 10.273 W 148 48 10.273 W 148 48 5.911 W 148 4751.217 W 148 4751.312 W 148 4758.137 W 148 48 3.371 W 148 48 9.273 W 148 4821.674 W e BP-GDB I Baker Hughes INTEQ Planning Rep rt Company: BP Amoco Field: Prudhoe Bay Site: Pi:! H Pad Well: H-04 Wellpath: Plan#6 H-04Ä Annotation MD TVD ft ft 11300.00 8533.65 TIP 11330.00 8558.62 KOP 11350.00 8575.13 3 11390.00 8605.88 4 11453.47 8659.06 5 11503.47 8705.65 6 11553.47 8750.68 7 11733.18 8844.76 8 11983.18 8853.67 9 12121.19 8884.43 10 12216.19 8923.42 11 12367.16 8954.78 12 12492.16 8954.78 13 12692.16 8954.78 14 12942.16 8954.78 15 13142.16 8954.78 16 13392.16 8954.78 17 13475.00 8954.78 TO Plan: Plan #6 Identical to Lamar's Plan #6 Principal: Yes Plan Section Information MD Incl Azim TVD ft deg deg ft ..........-....--..........--.---....- .....-...-...... 11300.00 33.75 115.00 8533.65 11330.00 33.58 115.00 8558.62 11350.00 35.15 116.56 8575.13 11390.00 44.75 135.88 8605.88 11453.47 20.00 135.88 8659.07 11503.47 25.09 186.70 8705.65 11553.47 28.57 230.13 8750.68 11733.18 88.00 279.69 8844.76 11983.18 88.08 319.71 8853.67 12121.19 66.00 319.71 8884.43 12216.19 65.84 336.37 8923.42 12367.16 90.00 336.37 8954.78 12492.16 90.00 316.37 8954.78 12692.16 90.00 348.37 8954.78 12942.16 90.00 308.37 8954.78 13142.16 90.00 340.37 8954.78 13392.16 90.00 300.37 8954.78 13475.00 90.00 313.62 8954.78 +N/-S ft 2705.61 2698.58 2693.67 2678.31 2654.10 2637.27 2618.90 2604.64 2725.93 2827.89 2901.13 3035.38 3138.93 3313.83 3522.40 3682.85 3871.51 3921.25 Survey MD Incl Azim Sys TVD N/S ft deg deg ft ft ..........---..-.- .. -------....-..-....- 11300.00 33.75 115.00 8533.65 2705.61 11325.00 33.61 115.00 8554.46 2699.75 11330.00 33.58 115.00 8558.62 2698.58 11350.00 35.15 116.56 8575.13 2693.67 11375.00 40.79 129.54 8594.86 2685.23 lNTEQ Date: 8/15/2003 Time: 15:52:51 Page: 2 Co-ordinate(NE) Reference: Well: H-04, True North Vertical ({VD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,318.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle .--.-."...-....----..---.---.. Date Composed: Version: Tied-to: ._____._...u__. ..- .... -..-..---------.-.-.--.-.... ....-."'.. 8/15/2003 3 From: Definitive Path ____.___.,____".,.__._ .._..."...u.._.._._ n._ _ +E/-W DLS Build Turn ft deg/100ft deg/100ft deg/100ft .---. ----..----.-.-..- .---. .---.. -.-.-- ..---- 5223.21 0.00 0.00 5238.28 0.57 -0.57 5248.44 9.00 7.85 5268.67 39.00 24.01 5292.15 39.00 -39.00 5296.91 39.00 10.19 5286.40 39.00 6.95 5147.09 39.00 33.07 4934.45 16.00 0.03 4848.02 16.00 -16.00 4802.32 16.00 -0.16 4743.58 16.00 16.00 4674.70 16.00 0.00 4583.15 16.00 0.00 4454.69 16.00 0.00 4339.69 16.00 0.00 4183.45 16.00 0.00 4117.44 16.00 0.00 0.00 0.00 7.82 48.29 0.00 101.64 86.86 27.58 16.01 0.00 17.53 0.00 -16.00 16.00 -16.00 16.00 -16.00 16.00 TFO deg 0.00 180.00 30.00 60.00 180.00 100.00 100.00 54.00 90.60 180.00 94.00 0.00 270.00 90.00 270.00 90.00 270.00 90.00 ".__ ._n.___._____n E/W MapN MapE VS ft ft ft ft m.._...........____..____._._._.._._.._ ........_....._..._._..........._..........._ . ....... ... .........._...... 5223.21 5962719.72 648485.05 -1484.35 5235.77 5962714.11 648497.72 -1497.11 5238.28 5962712.98 648500.25 -1499.66 5248.44 5962708.27 648510.50 -1510.11 5261.21 5962700.08 648523.43 -1524.92 11390.00 44.75 135.88 8605.88 2678.31 5268.67 5962693.30 648531.02 -1535.05 11400.00 40.85 135.88 8613.21 2673.44 5273.40 5962688.52 648535.84 -1541.84 11425.00 31.10 135.88 8633.42 2662.91 5283.61 5962678.18 648546.25 -1556.50 11450.00 21.35 135.88 8655.82 2654.98 5291.29 5962670.41 648554.08 -1567.53 11453.47 20.00 135.88 8659.07 2654.10 5292.15 5962669.55 648554.95 -1568.76 11475.00 20.23 160.45 8679.31 2647.94 5295.96 5962663.46 648558.88 -1575.89 11500.00 24.29 184.08 8702.49 2638.72 5297.05 5962654.26 648560.14 -1583.47 Target DLS deg/100ft 0.00 0.57 0.57 9.00 39.00 39.00 39.00 39.00 39.00 39.00 39.00 39.00 ....________......._......n. ..-...-....---...-...... TFO Tool deg ... ___.... _m_"____.___ 0.00 TIP 180.00 MWD 180.00 KOP 30.00 3 60.00 MWD 49.74 4 180.00 MWD 180.00 MWD 180.00 MWD 180.00 5 100.00 MWD 76.89 MWD e BP-GDB e Baker Hughes INTEQ Planning Report I1';£EQ .--.-----.----- ..-.. Company: BP Amoco Hate: 8/15/2003 Time: 15:52:51 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: H-04, True North Site: PB H Pad Vertical (TVD) Reference: System: Mean Sea Level Well: H-04 Section (VS) Reference: Well (0.00N,0.00E,318.00Azi) Wellpath: Plan#6 H-04A Survey Calculation Method: Minimum Curvature Db: Oracle . . -.. . --..----------- .... u______ ______.._.____._.._.____..._ _... ..-..--.-...... Survey .... ....... ..... ...........-- ...........................- ..........--.-..----...---. MD Incl Azim Sys TVD N/S E/W MapS MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1000 deg ....- -.------.-.-.....-...... ....___m...._. 11503.47 25.09 186.70 8705.65 2637.27 5296.91 5962652.81 648560.03 -1584.45 39.00 54.96 6 11525.00 24.95 206.63 8725.19 2628.66 5294.34 5962644.16 648557.63 -1589.13 39.00 100.00 MWD 11550.00 27.93 227.60 8747.62 2619.98 5287.64 5962635.35 648551 .09 -1591.09 39.00 81.91 MWD 11553.47 28.57 230.13 8750.68 2618.90 5286.40 5962634.24 648549.87 -1591.07 39.00 63.08 7 11575.00 34.13 242.28 8769.08 2612.78 5277.08 5962627.95 648540.68 -1589.38 39.00 54.00 MWD 11600.00 41.66 252.40 8788.81 2606.99 5262.92 5962621.89 648526.63 -1584.21 39.00 43.60 MWD 11625.00 49.86 259.81 8806.25 2602.78 5245.56 5962617.35 648509.35 -1575.72 39.00 35.59 MWD 11650.00 58.42 265.58 8820.89 2600.26 5225.49 5962614.45 648489.33 -1564.16 39.00 30.40 MWD 11675.00 67.19 270.37 8832.31 2599.51 5203.29 5962613.28 648467.16 -1549.87 39.00 27.01 MWD 11700.00 76.09 274.56 8840.18 2600.55 5179.62 5962613.87 648443.47 -1533.25 39.00 24.81 MWD 11725.00 85.06 278.45 8844.27 2603.36 5155.15 5962616.20 648418.95 -1514.80 39.00 23.49 MWD 11733.18 88.00 279.69 8844.76 2604.64 5147.09 5962617.33 648410.87 -1508.45 39.00 22.85 8 11750.00 87.97 282.38 8845.35 2607.86 5130.59 5962620.24 648394.31 -1495.01 16.00 90.60 MWD 11775.00 87.94 286.38 8846.25 2614.06 5106.39 5962625.98 648370.01 -1474.21 16.00 90.51 MWD 11800.00 87.92 290.39 8847.15 2621.94 5082.69 5962633.40 648346.16 -1452.50 16.00 90.36 MWD 11825.00 87.91 294.39 8848.06 2631.46 5059.59 5962642.4 7 648322.89 -1429.97 16.00 90.22 MWD 11850.00 87.91 298.39 8848.97 2642.56 5037.21 5962653.14 648300.31 -1406.75 16.00 90.07 MWD 11875.00 87.92 302.39 8849.87 2655.20 5015.67 5962665.37 648278.52 -1382.94 16.00 89.93 MWD 11900.00 87.94 306.40 8850.78 2669.31 4995.06 5962679.08 648257.65 -1358.67 16.00 89.78 MWD 11925.00 87.97 310.40 8851.67 2684.82 4975.48 5962694.22 648237.78 -1334.04 16.00 89.64 MWD 11950.00 88.01 314.40 8852.54 2701.66 4957.04 5962710.71 648219.02 -1309.18 16.00 89.49 MWD 11975.00 88.06 318.40 8853.40 2719.76 4939.81 5962728.46 648201.45 -1284.21 16.00 89.35 MWD 11983.18 88.08 319.71 8853.67 2725.93 4934.45 5962734.53 648195.98 -1276.03 16.00 89.22 9 12000.00 85.39 319.71 8854.63 2738.74 4923.59 5962747.13 648184.88 -1259.25 16.00 180.00 MWD 12025.00 81.39 319.71 8857.51 2757.68 4907.54 5962765.76 648168.47 -1234.43 16.00 180.00 MWD 12050.00 77.39 319.71 8862.11 2776.42 4891.65 5962784.20 648152.23 -1209.87 16.00 180.00 MWD 12075.00 73.39 319.71 8868.41 2794.87 4876.01 5962802.34 648136.24 -1185.70 16.00 180.00 MWD 12100.00 69.39 319.71 8876.39 2812.94 4860.70 5962820.11 648120.58 -1162.02 16.00 180.00 MWD 12121.19 66.00 319.71 8884.43 2827.89 4848.02 5962834.82 648107.63 -1142.42 16.00 180.00 10 12125.00 65.96 320.38 8885.98 2830.56 4845.79 5962837.45 648105.34 -1138.95 16.00 94.00 MWD 12150.00 65.76 324.76 8896.21 2848.67 4831.92 5962855.29 648091.14 -1116.22 16.00 93.73 MWD 12175.00 65.69 329.14 8906.49 2867.76 4819.50 5962874.14 648078.35 -1093.71 16.00 91.94 MWD 12200.00 65.74 333.53 8916.78 2887.75 4808.57 5962893.92 648067.05 -1071.54 16.00 90.13 MWD 12216.19 65.84 336.37 8923.42 2901.13 4802.32 5962907.17 648060.54 -1057.42 16.00 88.33 11 12225.00 67.25 336.37 8926.92 2908.53 4799.08 5962914.51 648057.16 -1049.75 16.00 0.00 MWD 12250.00 71.25 336.37 8935.78 2929.95 4789.71 5962935.74 648047.39 -1027.57 16.00 0.00 MWD 12275.00 75.25 336.37 8942.98 2951.88 4780.12 5962957.48 648037.38 -1004.85 16.00 0.00 MWD 12300.00 79.25 336.37 8948.49 2974.21 4770.35 5962979.62 648027.18 -981.72 16.00 0.00 MWD 12325.00 83.25 336.37 8952.30 2996.84 4760.44 5963002.06 648016.85 -958.27 16.00 0.00 MWD 12350.00 87.25 336.37 8954.36 3019.66 4750.46 5963024.68 648006.43 -934.63 16.00 0.00 MWD 12367.16 90.00 336.37 8954.78 3035.38 4743.58 5963040.27 647999.26 -918.35 16.00 0.00 12 12375.00 90.00 335.12 8954.78 3042.53 4740.36 5963047.35 647995.90 -910.88 16.00 270.00 MWD 12400.00 90.00 331.12 8954.78 3064.82 4729.06 5963069.42 647984.18 -886.75 16.00 270.00 MWD 12425.00 90.00 327.12 8954.78 3086.27 4716.23 5963090.62 647970.94 -862.23 16.00 270.00 MWD 12450.00 90.00 323.12 8954.78 3106.77 4701.94 5963110.85 647956.26 -837.43 16.00 270.00 MWD 12475.00 90.00 319.12 8954.78 3126.23 4686.25 5963130.00 647940.20 -812.47 16.00 270.00 MWD 12492.16 90.00 316.37 8954.78 3138.93 4674.70 5963142.48 647928.42 -795.31 16.00 270.00 13 12500.00 90.00 317.62 8954.78 3144.66 4669.36 5963148.11 647922.97 -787.47 16.00 90.00 MWD 12525.00 90.00 321.62 8954.78 3163.71 4653.17 5963166.83 647906.42 -762.49 16.00 90.00 MWD 12550.00 90.00 325.62 8954.78 3183.83 4638.34 5963186.67 647891.22 -737.61 16.00 90.00 MWD 12575.00 90.00 329.62 8954.78 3204.94 4624.96 5963207.52 647877.43 -712.97 16.00 90.00 MWD 12600.00 90.00 333.62 8954.78 3226.93 4613.08 5963229.28 647865.14 -688.68 16.00 90.00 MWD 12625.00 90.00 337.62 8954.78 3249.70 4602.76 5963251.84 647854.39 -664.86 16.00 90.00 MWD e BP-GDBI Baker Hughes INTEQ Planning Rep rt J1'I!T EQ Company: BP Amoco .. Date: 8/15/2003 "fime: 15:52:51 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: H-04, True North Site: PB H Pad . Vertical ("fVD) Reference: System: Mean Sea Level Well: H-04 Section (VS) Reference: Well (0.OON,0.00E.318.00Azi) Wellpath: Plan#6 H-04A Survey Calculation :\-1ethod: Minimum Curvature Db: Oracle ..-----.-.----------.... ... ---.-----....-..-....- Survey ................----...-.... ...............................-......----.... MD IDcI Azim Sys "fVD N/S E/W Map:'ll MapE VS DLS no "fool ft deg ··deg ft ft ft ft ft ft deg/1000 deg ..........-----..-....-..... .--....-------...... 12650.00 90.00 341.62 8954.78 3273.13 4594.06 5963275.10 647845.24 -641.62 16.00 90.00 MWD 12675.00 90.00 345.62 8954.78 3297.11 4587.01 5963298.94 647837.74 -619.08 16.00 90.00 MWD 12692.16 90.00 348.37 8954.78 3313.83 4583.15 5963315.59 647833.56 -604.07 16.00 90.00 14 12700.00 90.00 347.12 8954.78 3321.49 4581.49 5963323.21 647831.75 -597.27 16.00 270.00 MWD 12725.00 90.00 343.12 8954.78 3345.64 4575.07 5963347.24 647824.87 -575.02 16.00 270.00 MWD 12750.00 90.00 339.12 8954.78 3369.29 4566.98 5963370.73 647816.33 -552.03 16.00 270.00 MWD 12775.00 90.00 335.12 8954.78 3392.32 4557.26 5963393.56 647806.18 -528.42 16.00 270.00 MWD 12800.00 90.00 331.12 8954.78 3414.62 4545.96 5963415.63 647794.45 -504.29 16.00 270.00 MWD 12825.00 90.00 327.12 8954.78 3436.07 4533.13 5963436.84 647781.22 -479.76 16.00 270.00 MWD 12850.00 90.00 323.12 8954.78 3456.57 4518.83 5963457.06 647766.54 -454.96 16.00 270.00 MWD 12875.00 90.00 319.12 8954.78 3476.03 4503.14 5963476.21 647750.48 -430.00 16.00 270.00 MWD 12900.00 90.00 315.12 8954.78 3494.34 4486.13 5963494.20 647733.12 -405.01 16.00 270.00 MWD 12925.00 90.00 311.12 8954.78 3511.43 4467.89 5963510.93 647714.56 -380.10 16.00 270.00 MWD 12942.16 90.00 308.37 8954.78 3522.40 4454.69 5963521.65 647701.15 -363.12 16.00 270.00 15 12950.00 90.00 309.62 8954.78 3527.33 4448.60 5963526.46 647694.97 -355.38 16.00 90.00 MWD 12975.00 90.00 313.62 8954.78 3543.93 4429.92 5963542.70 647675.98 -330.54 16.00 90.00 MWD 13000.00 90.00 317.62 8954.78 3561.80 4412.44 5963560.23 647658.16 -305.57 16.00 90.00 MWD 13025.00 90.00 321.62 8954.78 3580.84 4396.24 5963578.96 647641.61 -280.58 16.00 90.00 MWD 13050.00 90.00 325.62 8954.78 3600.96 4381.42 5963598.80 647626.40 -255.71 16.00 90.00 MWD 13075.00 90.00 329.62 8954.78 3622.07 4368.04 5963619.64 647612.62 -231.06 16.00 90.00 MWD 13100.00 90.00 333.62 8954.78 3644.06 4356.16 5963641.40 647600.33 -206.77 16.00 90.00 MWD 13125.00 90.00 337.62 8954.78 3666.83 4345.84 5963663.97 647589.58 -182.95 16.00 90.00 MWD 13142.16 90.00 340.37 8954.78 3682.85 4339.69 5963679.87 647583.12 -166.93 16.00 90.00 16 13150.00 90.00 339.12 8954.78 3690.20 4336.98 5963687.17 647580.27 -159.65 16.00 270.00 MWD 13175.00 90.00 335.12 8954.78 3713.23 4327.26 5963710.00 647570.11 -136.03 16.00 270.00 MWD 13200.00 90.00 331.12 8954.78 3735.52 4315.95 5963732.07 647558.39 -111.90 16.00 270.00 MWD 13225.00 90.00 327.12 8954.78 3756.98 4303.12 5963753.27 647545.15 -87.38 16.00 270.00 MWD 13250.00 90.00 323.12 8954.78 3777.48 4288.83 5963773.50 647530.47 -62.57 16.00 270.00 MWD 13275.00 90.00 319.12 8954.78 3796.94 4273.14 5963792.65 647514.41 -37.62 16.00 270.00 MWD 13300.00 90.00 315.12 8954.78 3815.25 4256.13 5963810.64 647497.06 -12.62 16.00 270.00 MWD 13325.00 90.00 311.12 8954.78 3832.33 4237.88 5963827.37 647478.49 12.28 16.00 270.00 MWD 13350.00 90.00 307.12 8954.78 3848.10 4218.49 5963842.77 647458.81 36.98 16.00 270.00 MWD 13375.00 90.00 303.12 8954.78 3862.48 4198.05 5963856.75 647438.09 61.34 16.00 270.00 MWD 13392.16 90.00 300.37 8954.78 3871.51 4183.45 5963865.50 647423.33 77.82 16.00 270.00 17 13400.00 90.00 301.62 8954.78 3875.55 4176.73 5963869.40 647416.54 85.31 16.00 90.00 MWD 13425.00 90.00 305.62 8954.78 3889.39 4155.92 5963882.84 647395.46 109.52 16.00 90.00 MWD 13450.00 90.00 309.62 8954.78 3904.64 4136.12 5963897.72 647375.38 134.11 16.00 90.00 MWD 13475.00 90.00 313.62 8954.78 3921.25 4117.44 5963913.96 647356.38 158.95 16.00 90.00 TO e e All Measurements are from top of Riser 8/6/2003 . .. 10- <D en -- a: . top of bag I . Schlumberger BAG bttm of bag I I mkIdI~ of slips I Blind/Shears r' ~. I I TOTs I 23/8" combi ram/slips l ;; middle of pipes ......... .......... 0 I I 0 middle of flow cross Mud Cross Mud Cross I I middle of blind/shears I variable bore pipe 3 112-·2 718- I~ I I TOTs middle of pipe/slips I 2 3/8" combi ram/slips l/ Flow Tee p055138 DATE I I CHECK NO. 8/22/2003 055138 DATE DESCRIPTION GROSS VENDOR DISCOUNT NET INVOICE / CREDIT MEMO 8/22/2003 INV# PR082003 PERMIT TO DRILL FEE 11'D'-tA ~ECEIVED SEP 1 7 2003 Alaska Oil & Gas Cons. Comr~ss¡on Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ PAY: BPEXPlORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 TO THE ORDER OF: ALASKA plL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 "'AMOUNT August 22, 2003:***~;;**$1b6 .60·:**";;1 NOT )'AI IIJ"AFTj;R !.~O ~.ðy~ _ ...' ... .. " ~ ~. :::..:..: ·:·::.:.::?S':::::s::::::\~·::·::~~:·~· ..:. .::~~:)~~:::.:!:.~::~;.~~~~ Si ......:,.... t,<!?~' ..................;(...~............ :.:·~.~~·~.~~~···.i!.;~~!~ ,. .'.: -. .:....~;.~.._ :~..~. . ~. ~:\.~~ .. ..,fV¡¡ . . .... .......... ... ." .. ~~~:::':('::{::':\~.. .{~:iÜ;~J:~::;f::)\·;:::r··\(:·:;:G 11-055 ¡. :18"- I:OL. ¡. 20 :l8~ 51: 0 ¡. 2 'i'8~bll- H e e e . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well-, Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for we)) (name on permit). Pll..OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST Company ~ EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT H-04A PTD#: 2031610 Field & Pool PRUDHOE BAY. PRUDHOE OIL - 640150 Initial ClasslType DEV 11-01L GeoArea 890 Administration 1 Pßrmitfee attached. . . . . . . . . . . . . . . . . . . . . . . . . . . . Yßs . . . . . . . . 2 Leasß.number .appropriate. ... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . YßS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3U.nlque weltn.amß.anq oumb.er . . . . . . . . . . .. ......................... .YßS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WEtIUQcatßd In.a. d.efjr1e.d .ppol. .... . . . . . . . . . . . . . .. ....... . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 WeJUQcatßd pr.oper .dlstance. from qriJling ur1itboUr1d.ary. . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . 6 Well IQcatßd proper .dlstance from QtiJer wel!s. . . YßS . . . . . . . . . . . . . . . . . . . . . . 7S.utficier1t.acreag,e.ayail<lble indrilliog unjt. . . . . . . . . . . . . . . . . . . . . . YßS . . . . . . . . . . . . . . . . . 8 Jfdßviateq, js. weJlbQre plaUr1cJu.ded .. ...................... . . . . Yes. . . . . . . . . . . . . . . 9 .O-perator or1ly aftected party. ............................. . . . . . Yes . . . . . . . . . . . . . . . . . . . .. ........ . . . . . . . . . . . . . 10 .O-perator bas.apprppriate.b.ond lnJQrce . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . _ _ _ Yßs _ _ . . . . . . . . . . . . . . _ _ . _ . . . . _ . . . . . . . _ _ _ _ _ _ _ . . _ . . . . . . . . . . . . . . . . . . . _ _ _ . . . _ _ _ . . 11 Pßrmit c.an be lssued wjthQut conservatiOr1 Qrder . . . . . . . . . . . . . . . . . . . . . . . YßS . . . . . . . . . . . Appr Date 12 Pßrmit can be lssued wjtiJQut admir1istrative.apprpval _ . . . Yes. . . . RPC 9/17/2003 13 Can permit be approved before 15-daywait Yes 14 WeJUQcatßd wlthir1 area and.strataauthQrlzed by.lojectipo Ordßr # (putlO# in.cpmmeots) (FQr NA . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . 15 AJlwel!s.wit]1tn.1l4_roile.arEta_ofreyiewid.eotified(Fprservjc.ewellOr1ly)_ _ _ _ _. _ _.... _ _ _ NA _ _. _........... _ _ _..... _..... _ _.... _ _.... _ _ _ _ _ _.............. _ _. _ _. _ _ _ _ _.. 16 PrEt-prpdu.ced injector; ~ur<ltionof pre--pro~uctipr1 tess than:3 months (Forservlce well QnJy) . . .NA . . . . . . . . . . . _ . . . . . . . . . 17 ACMP Fïndjng of CQn.siJ>tency. h.as bee.n ,issued. fprtbis proiect . . . . . _ . . . . .NA . . . . . . . . . . . . . . . Engineering Appr Date WGA 9/17/2003 Geology Appr RPC Date 9/17/2003 Geologic Commissioner: ()ïT:5 Unit Program DEV 11650 On/Off Shore -ºn----.- D D Well bore seg Annular Disposal - - - - - - - - - - - . - - - - - - - 18 .Condu.ctor stringprQvided . . . . . . . . . . .NA . . . . . . . . . _ . . . . . . . . . . 19S.urfaœ .casir1g prQtects all.known. USDWs . . . . . . . . . . . . . . . . . . . _ . . . . . . . .NA . . . . . . . . . . . . . . . _ _ 20 .CMTv.oladeQu.atetocirc.utateoncpr1ductpr&surfC$g...... .. _ _ _. ...... NA ..... _.... ................. 21 .CMT vol adeQuateto tie-lnJQng .string to.surf ~g . . . . . . . . . . . . _ . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . 22 .CMTwil! coyeraJl kr1ow.nproductiye bQrizQn.s. . . . . _ . . . YßS. . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23 .C.asiog designs adequa.te fpr C,T, 8.&.pe!TIJafrpst . . . . . Yßs. . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . 24 Adequ<lte.tan.kage.or re_Sef"Ye pit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yßs . CTDU.. . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 Ifa.re-~rilt bas.a 10A03 fOJ <lbandonment beßO apprQved . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . 26 .Adequ<lte.wellboreseparatjo_n.proppse~.. _ . _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ . . _ _ _ . . _ . . . . Yßs _ _ _ _ _ . . _ . . . _ _ _ _ _ . _ _ _ _ _ _ . . . _ . _ _ _ _ _ . _ _ _ . . . . . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ . . . . . _ . 27 Jf.diver::ter required, dQes it me¡:¡t reguJa.tipr1s. . . _ . . . . . . . .NA . . . . . Sidetrack.. . . . . . . . . . . . . . . . .. _... ........ . . . . . . . . . . . . . . . . . . . . . . . 28 .DriUiogfJuidprQgramschematic&eq.uiplistadequatß. .... _....... Y.es..... . MaxMW8Jppg.. ............. _......... ................... 29 BOPEs,d.o.they meetreguJatipr1 . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . Yßs. . . . . . . . . . _ _ _ _ . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . 30 .BOP.E_press ra.tiog appropriate;testto.(pu.t psig tn _Commer1ts) . . . . . . . . . Yes. . . . Testt03500. psi. .MSF' 2145 psi. . . . . . _ . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . 31 .C.hokeroanifold cQmpJies. w/APt RF'-5:3 (May 84) . . . . . _ . _ . . . . . . . Yes. . _ . . . . . . . . . . . . . . _ . . . . . . . . . . . _ . . 32 WQrk will pccur withputoperation.sbutdown. . . . . . . . . . . . . . . . . . . . . . _ _ . . . . Yßs . . . . . . . . . . . . _ . _ . . . . . . . . . . _ _ _ . . . . . . . . . _ . . . . _ . . 33 Is presence Qf H2S gas. proQable. . . . . . . . . . . . . . . . . .. .... _ . _ . . . . . . . . . . No. . . . . . . . . _ _ . . . . . . . . . . . _ . . . . . . . . _ _ . . . 34 Mecha.nlcal.qmd,illoo pf WEtIlS wlthir1 AOR verified (Fpr.seryjce w¡:¡1] only). . . . . . . . . . . . . . .NA . . . . . . . . . . . . . - - - - - - - - . 35 P¡:¡rmit c.ao be lssued wlo hydrogen s.ulfide measures. ............. _........ No. . 36 .Data.preseoted on pote.ntial pve.rpres.Sl,lrezOr1es _ . . . . . . . . . . . . . . .NA 37Sßlsmic.analysjs. Qf shallow gaszpoes . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . . . _ 38Sßabe~c0r1djtjpo survey.(if off-shpre). ...... _ . . . . . . . . . . . _ _ . . .NA . . 39 . CQnta.ct r1amelp]1one.forwe¡:¡kly prpgress.reports [exploratpryonly] . . _ . . . . . . . . . . .NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date PubHc Commissioner Date 9/17/3 e e 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. / ~03-lf4 / /2 ~ (~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jul 29 08:51:34 2004 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04 / 07/ 2 9 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date. ....................04/07/29 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS II WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: II JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: II SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: II WELL CASING RECORD H-04A 500292010401 SP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 29-JUL-04 MWD RUN 1 MWD RUN 2 MWD RUN 4 MWOOO2771368 MWOO02771368 MWOO02771368 S. LATZ S. LATZ B. JAHN WHITLOW/SARB WHITLOW/ SAR WHITLot-¡ / EG MWD RUN 5 MWD RUN 7 MWD RUN 8 MWOO02771368 MWOO02771368 MWOO02771368 B. JAHN B. JAHN B. JAHN SARBER/EGBEJ SARBER/EGBEJ SARBER/EGBEJ MWD RUN 9 MWOO02771368 B. JAHN R. WHITLOW / 21 UN 13E 873 1265 MSL 0) 64.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) rC!- J 'd. 'ð/f)~J 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 4.125 4.500 11333.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 11325'MD AND THE BOTTOM WAS AT 11333'MD IN THE ORIGINAL H-04 WELLBORE. 4. MWD RUNS 1 - 4 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. TIE-IN SGRC DATA WERE ACQUIRED AFTER MWD RUN 1. THESE MAD PASS DATA WERE MERGED WITH MWD DATA FROM RUN 1. NO PROGRESS WAS MADE IN RUN 3. 5. MWD RUNS 5 - 9 COMPRISED DIRECTIONAL WITH GM AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS DATA WERE ACQUIRED OVER THE UPHOLE INTERVAL PRIOR TO DRILLING RUN 5. UNFORTUNATELY, THE EWR4 DATA ARE SUSPECT, SO THEY ARE NOT PRESENTED_ NO PROGRESS WAS MADE ON MWD RUN 6. A FINAL MAD PASS WAS RUN AFTER REACHING TD TO COMPARE WITH QUESTIONABLE EWR4 MWD DATA FROM RUNS 7 AND 8. IT WAS DECIDED TO MERGE THE RUN 9 MAD DATA WITH THE RUN 9 MWD DATA FROM 12409'MD TO 11569'MD. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG PROVIDED BY K. COONEY (SIS/BP) ON 23 JULY 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1 - 9 REPRESENT WELL H-04A WITH API#: 50-029-20104-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13410'MD/8944'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ SHIFT-DERIVED RESISTIVITY ( SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP File Header Service name. ............STSLIB.001 Service Sub Level Name._. Version Number.... . . . . . . .1. O. 0 Date of Generation.......04/07/29 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 11207.5 11339.5 11567.5 11567.5 11567.5 11567.5 11567.5 STOP DEPTH 13360.0 13405.5 13374.0 13374.0 13374.0 13374 . 0 13374.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 11211. 0 11216.5 11219.0 11227.5 11234. 5 11236.5 11247.5 11261.5 11265.5 11277.0 11280.5 11285.5 11325.0 11336.0 11340.5 11351.5 11362.5 11365.0 11373.5 11384.0 11387.0 11392.0 11403.0 11416.0 11438.0 11452.0 11453.5 11459.0 11461.5 11474.5 11484.0 11489.5 11496.0 11500.0 11508.5 11520.5 11534.5 11541.5 11583.0 11592.0 11613.0 11643.5 11676.5 11693.5 11712.0 11738.5 11755.5 11800.5 11826.0 11860.0 11908.0 11926.5 11937.0 11945.5 GR 11211.5 11216.0 11219.0 11228.0 11235.0 11236.5 11247.5 11261.5 11266.0 11277 . 5 11281.5 11286.0 11325.0 11336.0 11340.5 11355.0 11364.5 11366.0 11375.5 11385.0 11388.5 11392.5 11403.5 11417.5 11440.0 11450.5 11452.0 11458.0 11461.0 11475.0 11485.0 11489.5 11497.5 11500.0 11509.5 11519.0 11534.0 11541.0 11586.0 11593.5 11613.0 11644.5 11672.5 11692.0 11710.5 11734.5 11754.0 11799.5 11826.0 11860.0 11907.5 11927.5 11937.5 11946.0 12034.5 12044.0 12057.5 12067.0 12093.0 12107.0 12115.0 12123.5 12139.5 12150.0 12157.5 12166.5 12182.5 12196.0 12200.5 12209.0 12216.0 12231. 0 12237.5 12259.5 12311.0 12331.0 12357.5 12359.5 12362.0 12365.5 12372.0 12382.0 12396.5 12411.5 12428.5 12444.0 12461.5 12469.5 12478.0 12499.0 12524.0 12537.5 12558.5 12569.0 12583.0 12617.0 12626.5 12633.0 12637.5 12691.0 12697.0 12699.5 12714.0 12720.0 12722.5 12726.0 12744.5 12747.5 12748.5 12769.5 12775.0 12886.5 12895.5 12907.5 12929.0 12935.5 12967.0 12976.0 12993.5 12998.5 13019.0 13028.0 13033.5 13041. 5 13047.5 13070.0 13079.0 13115.0 13123.5 12034.5 12044.5 12057.0 12068.0 12094.0 12107.0 12115.5 12124.5 12140.5 12151.5 12157.5 12166.0 12181. 5 12194.0 12199.0 12206.0 12211.5 12229.0 12235.5 12258.5 12311.5 12331.0 12359.0 12360.5 12363.0 12366.5 12373.0 12383.5 12400.0 12414- 0 12433.0 12445.5 12465.5 12469.0 12478.0 12502.0 12528.5 12540.5 12561.5 12569.5 12586.0 12622.0 12627.5 12633.0 12638.5 12693.5 12697.0 12700.0 12712.0 12721.5 12724.0 12727.0 12743.5 12745.0 12747.0 12767.5 12770.0 12885.0 12895.0 12905.5 12927.5 12937.5 12968.0 12976.5 12993.0 12998.0 13017 . 5 13029.0 13032.5 13039.5 13047.0 13069.0 13079.0 13114.5 13121.5 13135.5 13147.0 13149.0 13162.5 13180.0 13191.0 13201. 0 13209.0 13230.5 13236.5 13240.0 13267.0 13284.0 13304.0 13307.0 13316.5 13326.0 13335.5 13346.5 13348.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: 13134.5 13146.5 13148.0 13162.0 13178.0 13189.5 13199.5 13206.5 13226.5 13233.5 13237.0 13269.5 13284. 5 13307.5 13309.0 13318.5 13328.0 13336.5 13349.5 13352.5 BIT RUN NO 1 2 4 5 7 8 9 MERGED MAIN PASS. $ MERGE TOP 11208.0 11533.0 11636.0 11762.0 12204.0 12410.0 12451.0 MERGE BASE 11533.0 11636.0 11 762.0 12204.0 12410.0 12451. 0 13410.0 # 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 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 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 11207.5 0.29 14.46 1. 88 2.41 2.83 4.31 0.26 Max 13405.5 1753.62 316.26 2000 304.95 91.97 96.82 153.4 Mean 12306.5 60.3858 51. 8949 9.68558 11. 0577 13.1276 16.8816 48.6328 Nsam 4397 4133 4262 3614 3614 3614 3614 3614 First Reading For Entire Fi1e..........11207.5 Last Reading For Entire Fi1e...._......13405.5 First Reading 11207.5 11339.5 11207.5 11567.5 11567.5 11567.5 11567.5 11567.5 Last Reading 13405.5 13405.5 13360 13374 13374 13374 13374 13374 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/07/29 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...........I.O.O Date of Generation.......04/07/29 Maximum Physical Record..65535 Fi 1 e Type.. . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 11208.0 11339.5 STOP DEPTH 11506.0 11533.0 # 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 GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: 17-NOV-03 Insite 4.3 Memory 11533.0 11340.0 11533.0 29.0 47.1 TOOL NUMBER 72829 4.125 11333.0 Flo Pro 8.60 65.0 9.5 21 000 6.8 .000 .000 .000 .000 .0 141.4 .0 .0 MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 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 Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Un.i t Min Max Mean Nsam Reading Reading DEPT FT 11208 11533 11370.5 651 11208 11533 ROP MWD010 FT/H 0.29 230.66 36.3677 388 11339.5 11533 GR MWD010 API 16.78 316.26 50.8278 554 11208 11506 First Reading For Entire File......... .11208 Last Reading For Entire Fi1e...........11533 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 Fi 1 e 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.......04/07/29 Maximum Physical Record..65535 Fi 1 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 ROP 3 header data for each bit run in separate files. 2 .5000 START DEPTH 11506.5 11533.5 STOP DEPTH 11602.0 11636.0 " 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 GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....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 DEPT ROP GR Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 MWD020 MWD020 Rep 68 68 68 Code 18-NOV-03 Insite 4.3 Memory 11636.0 11533.0 11636.0 33.7 54.0 TOOL NUMBER 72829 3.750 11333.0 Flo Pro 8.60 60.0 9.5 21000 7.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 .0 141. 4 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11506.5 11636 11571.3 260 11506.5 11636 ROP MWD020 FT/H 0.55 216.01 20.6456 206 11533.5 11636 GR MWD020 API 18.67 58.51 28.6319 192 11506.5 11602 First Reading For Entire File..........11506.5 Last Reading For Entire File...........11636 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number... .... ....1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 11602.5 11636.5 STOP DEPTH 11735.5 11762.0 # 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 ROTA.TING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 19-NOV-03 Insite 4.3 Memory 11762.0 11636.0 11 762.0 47.8 85.3 TOOL NUMBER 72829 3.750 11333.0 Flo Pro 8.60 65.0 9.3 21 000 7.8 .000 .000 .000 .000 .0 141.4 .0 .0 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 Units....................... Datum Specification Block sub-type...O Name DEPT ROP GR MWD040 MWD040 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Service Order Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11602.5 11762 11682.3 320 11602.5 11 762 ROP MWD040 FT/H 1. 69 174.59 109.721 252 11636.5 11762 GR MWD040 API 17.46 37.9 24.7974 267 11602.5 11735.5 First Reading For Entire File..........11602.5 Last Reading For Entire File...........11762 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name...... .......STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP 5 header data for each bit run in separate files. 5 .5000 START DEPTH 11736.0 11762.5 STOP DEPTH 12159.5 12204.0 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 GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....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 DEPT ROP MWD050 GR MWD050 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 20-NOV-03 Insite 4.3 Memory 12204.0 11762.0 12204.0 65.7 89.7 TOOL NUMBER 78012 4.125 11333.0 Flo Pro 8.60 65.0 9.2 21000 7.8 .140 .060 .150 .170 Offset o 4 8 Channel 1 60.0 162.7 60.0 60.0 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11736 12204 11970 937 11 7 36 12204 ROP MWD050 FT/H 0.45 1753.62 68.1011 884 11762.5 12204 GR MWD050 API 16.94 183.71 38.1781 848 11736 12159.5 First Reading For Entire File...._.....11736 Comment Record FILE HEADER FILE NUMBER: 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 $ Last Reading For Entire File...........12204 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/07/29 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.005 6 7 .5000 START DEPTH 12160.0 12204.5 STOP DEPTH 12366.0 12410.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: " 21-NOV-03 Insite 4.3 Memory 12410.0 12204.0 12410.0 64.9 86.0 TOOL NUMBER 78012 4.125 11333.0 Flo Pro 8.60 60.0 9.5 21500 6.0 .125 .050 .200 .155 60.0 156.6 50.0 50.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOtt (IN): EWR tREQUENCY (HZ): # REMARKS: $ # Data tormat Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........2eet Data Reference Point..............Undefined trame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...._.................-999 Depth Units..... . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD070 GR MWD070 Units tT tT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 tirst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT tT 12160 12410 12285 501 12160 12410 ROP MWD070 tT/H 0.61 81. 92 40.6832 412 12204.5 12410 GR MWD070 API 18.63 92.48 36_7034 413 12160 12366 tirst Reading tor Entire tile..........12160 Last Reading For Entire Fi1e...........12410 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 tile Type................ LO Next tile Name...........STSLIB.007 Physical EOF tile Header Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 File Type.. _............ .LO Previous tile Name.......STSLIB.006 Comment Record tILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP 7 header data for each bit run in separate files. 8 .5000 START DEPTH 12366.5 12410.5 STOP DEPTH 12405.0 12451.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL 1FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................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 DEPT ROP MWD080 GR MWD080 Code Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 22-NOV-03 Insite 4.3 Memory 12451.0 12410.0 12451.0 91. 4 91. 4 TOOL NUMBER 78012 3.750 11333.0 Fl0 Pro 8.60 60.0 9.5 21500 6.0 .130 .050 .200 .160 60.0 155.9 60.0 50.0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12366.5 12451 12408.8 170 12366.5 12451 ROP MWD080 FT/H 8.3 126.18 59.4918 82 12410.5 12451 GR MWD080 API 28.75 110.58 60.9447 78 12366.5 12405 First Reading For Entire File..........12366.5 Last Reading For Entire File...........12451 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.008 Physical EOF File Header Service name.............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 8 header data for each bit run in separate files. 9 .5000 START DEPTH 11569.0 11569.0 11569.0 11569.0 11569.0 12405.5 12451. 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): STOP DEPTH 13378.5 13378.5 13378.5 13378.5 13378.5 13364.5 13410.0 24-NOV-03 Insite 4.3 Memory 13410.0 12451. 0 13410.0 86.6 94.6 RESIS. 4 TOOL NUMBER 93091 178425 3.750 11333.0 New Flo Pro 8.60 40.0 9.3 22000 (' FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGFi MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 6.:2 .120 .050 .200 .180 60.0 153.0 60.0 60.0 # 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.....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 Vni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11569 13410 12489.5 3683 11569 13410 ROP MWD090 FT/H 0.4 1078.12 63.1186 1918 12451. 5 13410 GR MWD090 API 14.46 227.17 66.5994 1919 12405.5 13364.5 RPX MWD090 OHMM 1. 88 2000 9.69907 3620 11569 13378.5 RPS MWD090 OHMM 2.41 304.95 11. 0835 3620 11569 13378.5 RPM MWD090 OHMM 2.83 91. 97 13.1524 3620 11569 13378.5 RPD MWD090 OHMM 4.31 96.82 16.8824 3620 11569 13378.5 FET MWD090 HOUR 0.26 153.4 48.5297 3620 11569 13378.5 First Reading For Entire File..........11569 Last Reading For Entire File...........13410 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/07/29 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name.............LISTPE Date.....................04/07/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name..... ......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date........ ... .._.._.. ..04/07/29 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ............UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments...... ...........STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
