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205-137
• 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. ~- ~ ~ ~ Well History File Identifier Organizing (done) RE CAN Color Items: ~Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ Project Proofing BY: Maria Scanning Preparation BY: Maria Date: p~~ ~/ Date: / t III II~II~lltlllll) Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: a/ ~ ~ g /s/ ~~ Stage 1 !f NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II ~I I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: Isl Comments about this file: ~.~.,aea iuuiuiuiiuuii DIGITAL DATA Diskettes, No. ^ Other, No/Type: Re,~a~~eeaea uuumniuuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other.: ,~iiiiiiifiimiuii P wtP / ~ x 30 = _~ + _~ =TOTAL PAGES (Count does not include cover sheet) Date: ~.~ /s/ a.. ~,~~~~~ iiiiummimm 101612005 Wetl History File Cover Page.doc STATE OF ALASKA ALASKA OILLND GAS CONSERVATION COMMISIt WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 IN 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. 9/12/2011 205 - 137 311 - 242 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 10/16/2005 50 029 - 20371 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 10/23/2005 PBU C -10A 775' FNL, 1222' FEL, SEC. 19, T11 N, R14E, UM 8. KB (ft above MSL): 62.32' 15. Field / Pool(s): Top of Productive Horizon: 4582' FNL, 1666' FWL, SEC. 20, T11 N, R14E, UM GL (ft above MSL): 32.55' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 5182' FNL, 2952' FWL, SEC. 20, T11 N, R14E, UM 11311' 9040' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 664143 y - 5960439 Zone- ASP4 12360' 9026' ADL 028305 TPI: x- 667127 y- 5956697 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 668428 y- 5956126 Zone- ASP4 N/A 18. Directional Survey: ❑ Yes ®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- DriII/Lateral Top Window MD/TVD: MWD DIR / GR /RES / PWD, MWD DIR / GR / RES / ABI, DEN / NEU 8505' 6743' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE ToP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 12.9 cu ft Permafrost 13 -3/8" 72# L -80 Surface 2666' Surface 2666' 17 -1/2" 4492 cu ft Arcticset 9-5/8" 47# L -80 Surface 8505' Surface 6743' 12 -1/4" 1589 cu ft Class 'G'. 130 cu ft AS 1 7" 26# L -80 8328' 10400' 6642' 8403' 8 -1/2" 197 cu ft Class 'G' 4 -1/2" 12.6# L -80 10225' 12360' 8235' 9026' 6-1/8" 310 cu ft Class 'G' 24. Open to production or injection? ❑ Yes ® 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): 4 -1/2 ", 12.6#, 13Cr80 10233' 10178' / 8190' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED *) ring;, 11308' Set Whipstock t`iL 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 IN No Sidewall Core(s) Acquired? ❑ Yes IN 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 R ECEIVED ED RBDMS SEP 2 6 20 / EP 2 3 20 � ' Make Oil 81 Gds CWIS. C orntnt - Submit Original Only Form 10-407 Revised 12/2009 CONTINU ON REVERSE $$ S g y ,L 'Z ;Moorage G� / 29. ,GEOLOGIC MARKERS (List all formations and markellcountered): 30. F`IATION 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. Top HRZ 9481' 7520' None Base HRZ 9682' 7714' Sag River 10408' 8411' Shublik 10441' 8443' Sadlerochit 10522' 8521' Top CGL 10711' 8699' Base CGL 10797' 8780' 23SB / Zone 2B 10845' 8823' 22TS 10930' 8893' 21 TS / Zone 2A 11015' 8950' Zone 1B 11149' 9016' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoii�ng iistrue and correct to the best of my knowledge. O�l l Signed: Terrie Hubble � 1 IAie , Title: Drilling Technologist Date: 1 1 PBU C -10A 205 -137 311 -242 Prepared By Name/Number: Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Zach Sayers, 564 -5790 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 1 a: 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 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 • • C -10A, Well History (Pre Rig Sidetrack) Date Summary 06/23/11 T /I /0= 2270/890/0 Temp =S /I Assist SSL w/ MIT -IA to 3000 psi PASSED / MIT -OA to 2000 psi PASSED Previously pumped 325 bbls crude down IA while SSL RIH to set DMY. Pumped additional 5.2 bbls crude down IA after DMY set to reach 3000 psi MIT -IA, On 2nd test, 1st 15 min IA lost 20 psi, 30 min IA lost 10 psi for a total loss of 30 psi. Pass. Bled down IA to 300 psi (16 bbls) / MIT -OA- Pressured up w/ 3.9 bbls crude. On 3rd test, OA lost 160 psi in 1st 15 min & 30 psi in 2nd 15 min. Total loss of 190 psi in 30 min. Pass. Bled OAP ( -1.4 bbls). Pad - Op & PE notified. FWP= 2450/0/380 06/23/11 LRS PUMPED 325 BBLS OF CRUDE DOWN THE IA. SET 1 1/2" RK/DGLV IN STA# 3 @ 5,533' MD. LRS PERFORMED A MIT -IA TO 3,000 PSI. (test passed) PULLED 4 1/2" SSCS FROM 5,591' SLM. (empty) SSV NORMALED UP TO PANEL AND LEFT WELL SHUT -IN. 08/11/11 MIRU. Liquid pack wellbore. RIH w/ 3.80" D331 mill on LH milling assy to XN nipple,Al,l nipple, PU thru XN back reaming, dry run thru XN to 11430', POOH. 08/12/11 OOH & RD 3.8" milling assembly, MU Dummy WS drift assembly, PT'd & TESTED PUMP KICK OUT, 3.7" OD x 25.5', RIH to 11450', clean. POH. FP w/ 38 bbls McOH. RDMO. Job complete. 08/15/11 T /I /O = 10/0/0 Conduct PJSM. Verified Barriers. Set 6" CIW J TWC @ 108" w/ 1 -2' ext. Torqued all tree flanges to spec. Shell tested tree against TWC to 300 psi low and 5000 psi high for 5 mins. ea. (passed) Pulled 6" CIW J TWC. Tested tree cap connection against swab valve to 300 psi low and 3500 psi high for 5 mins. ea. (passed) Lubricator was tested to 300 psi low and 3500 psi high each time it was installed. All charted tests in Field Charted Tests folder. Job Complete. 08/28/11 T /I /O= SSVNACNAC. Temp= SI. WHPs (Pre RIG). No AL. Wellhouse, flowline, and scaffolding removed. 08/29/11 T /I /0= 2320NacNac. Temp =SI. WHP's (pre -CTD). No AL. Drilling scaffold in place. Some minor subsidence around wellhead noted. MV left closed as per FO. 08/30/11 T/I/O= 0/0/0; Conduct PJSM; Set 6" CIW "J" TWC for Nordic 2 pre -rig; (see log); MV approved as a barrier. 08/30/11 T /I /O= 2400/0/0 Temp= SI Load tubing (pre CTD) Pump 258 bbls of 140 °F 1% KCL down tubing to load and kill well. Pump 45 bbls hot diesel down tubing for freeze protect. FWHP 0/0/0 Page 1 of 1 • • • North America - ALASKA - BP Page 1 = Operation Summary Report Common Well Name: C -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: IX3- 010P7 -C (1,898,705.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292037100 Active Datum: C -10A: @62.32ft (above Mean Sea Level) Date From - To Hrs Task ' Code NPT NPT Depth Phase I Description of Operations (hr) (ft) 8/31/2011 00:00 - 06:00 6.00 MOB ' P PRE CONTINUE TO CLEAN UP RIG . CONTINUE TO MOVE RIG EQUIPMENT TO C -10 PAD. 06:00 - 06:30 0.50 MOB P PRE I CREW CHANGE. DISCUSS RIG STATUS. MAKE EQUIPMENT CHECKS AND RIG ROUNDS. 06:30 - 18:00 11.50 MOB P PRE !HOLD PJSM WITH TRUCK DRIVERS AND SECURITY. MOVE SATELLITE TRAILER AND MAN CAMP 1 FROM PAD 10 TO C -PAD. CONTINUE TO LOAD OUT MICS EQUIPMENT FROM PAD 10. CONTINUE SMALL RIG MAINTENANCE PROJECTS WHILE WAITING ON SECURITY ESCORT. 18:00 - 19:00 1.00 MOB + P PRE CREW CHANGE, DISCUSS ONGOING OPERATIONS WHILE WAITING ON SECURITY ESCORT. 1 19:00 - 19:30 ! 0.50 MOB P PRE HOLD PJSM WITH SECURITY AND CREW. 19:30 - 00:00 4.50 MOB P PRE ' JACKUP RIG MOVE TO C -PAD. 'TRAVELING ON WEST DOCK RD. CURRENTLY 1.5 MILES FROM K -PAD RD. 9/1/2011 00:00 - 05:00 5.00 MOB P PRE MOVE RIG TO C -PAD. 05:00 - 05:30 0.50 MOB P PRE SPOT RIG IN CENTER OF C -PAD. SET RIG DOWN. 05:30 - 06:00 0.50 MOB P i PRE SET RIG STAIRS DOWN. R/U SATTELITE POWER TO RIG. RIG ON STANBY WAITING FOR ORDERS TO REURN TO WORK- ' MUD PUMP POP VALVE LINE INVESTIGATION. 06:00 - 06:30 0.50 MOB N RREP PRE CREW CHANGE. DISCUSS RIG OPS AND STATUS AFTER MOVE. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. 06:30 18:00 11.50 MOB N RREP PRE MEASURE AND RECORD PUMP POP OFF [VALVES IN PUMP ROOM 1 AND 2. PERFORM POST MAINTENANCE RIG AUDIT WITH D &C DRILLING HSE ADVISOR. CONTINUE TO CLEAN AND PAINT INTERIOR l I AREAS OF RIG. 18:00 00:00 6.00 MOB N RREP PRE CREW CHANGE OUT. DISCUSS RIG OPS. MAKE EQUIPMENT CHECKS. CLEAN AND PAINT IN PUMP ROOM. CLEAN AND ORGANIZE IN REELHOUSE. QUADCO CHANGED OUT PRESSURE SENSOR ON HYDRAULIC CHOKE. 9/2/2011 00:00 - 06:00 6.00 MOB N RREP PRE RIG ON STANDBY WAITING FOR ORDERS TO RETURN TO WORK - MUD PUMP POP VALVE LINE INVESTIGATION. CONTINUE TO CLEAN REELHOUSE. PAINT MP ROOM STAIRS. PAINT MIX ROOM CEILING, CENTRIFUGE FEED PUMP LINES. PREP SHAKER FOR PAINT. 06:00 - 06:30 0.50 MOB N RREP PRE CREW CHANGE. DISCUSS RIG PROJECT STATUS. MAKE EQUIPMENT CHECKS AND RIG ROUNDS. ASSIGN TASKS AND I COMPLETE PERMITS AS REQUIRED. Printed 9/19/2011 9:31:25AM orth America - ALASKA - BP Page 2 02 Operation Summary Report Common Well Name: C -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010P7 -C (1,898,705.00 ) Project: Prudhoe Bay Site: PB C Pad - I Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM I Rig Release: Rig Contractor: NORDIC CALISTA ! UWI: 500292037100 Active Datum: C -10A: @62.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth 1 Phase ! Description of Operations (hr) (ft) 06:30 - 18:00 11.50 MOB 1 N ' RREP PRE I CONTINUE TO CLEAN RIG INTERIOR. PAINT FLOOR SECTIONS. SO &R INVESTIGATION TEAM INSPECTED PUMP PRESSURE RELIEF LINES. 18:00 - 00:00 r 6.00 MOB N RREP PRE CREW CHANGE. DISCUSS RIG PROJECT STATUS. MAKE EQUIPMENT CHECKS AND RIG ROUNDS. � CONTINUE PAINTING ON RIG FLOOR . PAINTING IN PIT AREA. IPAINT CHOKE MANIFOLD ROOM. 9/3/2011 00:00 - 06:00 6.00 MOB N 1 RREP ! PRE RIG ON STANDBY WAITING FOR ORDERS TO RETURN TO WORK- MUD PUMP POP VALVE LINE INVESTIGATION. CONTINUE PAINTING ON RIG FLOOR . PAINTING IN PIT AREA. 06:00 06:30 0.50 MOB N RREP. PAINT CHOKE MANIFOLD ROOM. N - MANIFOLD PRE CREW CHANGE. DISCUSS PROJECTS AND RIG STATUS. MAKE OUTSIDE CHECKS AND i ROUNDS. 06:30 18:00 11.50 MOB 1 N 1 RREP PRE 1CONTINUE TO CLEAN AND PAINT RIG INTERIOR. CONTINUE TO SOURCE 3" IRON AND WELDERS FOR POP OFF LINE 1REPLACEMENT. 118:00 18:30 0.50 MOB N I RREP PRE I CREW CHANGE. DISCUSS PROJECTS AND RIG EQUIPMENT STATUS. -- - -- - -- - - - -rt - - -- -- - -- 18:30 PRE 00:00 5.50 MOB N RREP CONTINUE TO CLEAN AND PAINT RIG INTERIOR. i I I CONTINUE PAINTING IN CHOKE ROOM. PREP ACCUMULATOR AREA FOR PAINT. I _ PAINT ON RIG FLOOR. y 9/4/2011 00:00 - 06:00 6.00 MOB N RREP PRE CONTINUE TO CLEAN AND PAINT RIG INTERIOR. PREP RIG FLOOR FOR PAINT. I PAINT IN CHOKE ROOM. PREP ACCUMULATOR FLOOR FOR PAINT. 06:00 - 06:30 0.50 MOB N RREP PRE CREW CHANGE. DISCUSS OPS RIG STATUS 1 I AND PROJCTS. MAKE EQUIPMENT CHECKS I 1 AND OUTSIDE ROUNDS. ORIENT PEAK WELDER. DISCUSS HSE REQUIREMENTS WHILE WORKING ON RIG. REVIEW POP OFF LINE PROJECT DETAILS. f 06:30 - 18:00 11.50 MOB N RREP PRE 1 AND PAINT AROUND RIG. PEAK WELDER FABRICATING PREESURE RELIEF LINES IN DEADHORSE. INSTALL COIL REEL. MU HARDLINE AND t ELECTRICAL CONNECTIONS. 18:00 - 18:30 0.50 1 MOB N RREP PRE NEW RIG CREW CHANGE OUT. DISCUSS RIG OPS, STATIS AND PROJECTS. MAKE EQUIPMENT CHECKS. REVIEW PREVIOUS WORK COMPLETED ALONG WITH ONGOING WORK. DISCUSS SAFETY EXPECTATIONS. Printed 9/19/2011 9:31:25AM • nrth America - ALASKA BP Page TOW Operation Summary Report Common Well Name: C -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: 'X3- 010P7 -C (1,898,705.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292037100 Active Datum: C -10A: @62.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) MOB N (ft) 18:30 00:00 � .50 "_- - 5 1- RREP � PRE CONTINUE TO CLEAN AND PAINT RIG INTERIOR. M/U CTB GRAPPLE TO PULL COIL ACROSS. HEAD UP CTB ENCODER. TEST AND CONFIRM STRIPPER AND CHAIN LUBE ARE WORKING. PAINT U -TUBE LINES ON MGS. PREP RIG FLOOR FOR PAINT. ASSEMBLE ELEVATORS AND SLIPS. 9/5/2011 00:00 06:00 6.00 MOB N RREP PRE CONTINUE TO CLEAN AND PAINT RIG INTERIOR. PAINT U -TUBE LINES ON MGS. PREP RIG FLOOR FOR PAINT. ASSEMBLE AND PAINT PIPE ELEVATORS AND SLIPS. INSTALL NEW SCREWS ON SHAKER DECK RUBBER. P/U TOOLS AND CLEANUP WORK AREA @ 05 :30. PRE - -- - - I -- , 06:00 - 18:00 12.00 MOB N RREP CREW CHANGE. DISCUSS RIG AND PROJECT STATUS. MAKE OUTSIDE ROUNDS AND EQUIPMENT CHECKS. CONTINUE TO REASSEMBLE HANDLING EQUIPMENT AND TOOLS. CONTINUE TO REMOVE OLD PAINT. CLEAN AND REPAINT INTERIOR EQUIPMENT OF RIG. INSPECT CHOKE LINE BELOW RIG FLOOR. INSPECT MISC HANDLING EQUIPMENT. REVIEW PESSURE RELIEF LINE WITH ADW HSE REPRESENTATIVES. 18:00 18:30 0.50 MOB N RREP PRE CREW CHANGE. DISCUSS ONGOING OPERATIONS. DISCUSS SAFETY EXPECTATIONS TO WELDER WORKING ON MUD PUMP RELEIF LINES. MOB ' N RREP ' -- - - - - -- -- - - - -- -- -- - - -- 18:30 - 00:00 ! 5.50 PRE CONTINUE TO CLEAN AND PAINT RIG INTERIOR. PREP RIG FLOOR FOR PAINT. PAINT WALL BEHIND MGS. ENCLOSE ROOF AROUND MGS. WELDERS FABRICATING NEW MUD PUMP RELEIF LINES. 9/6/2011 00:00 - 06:00 6.00 MOB N RREP PRE WELDERS FABRICATING 3" MUD PUMP RELEIF LINES. CONTINUE TO CLEAN AND PAINT RIG INTERIOR. ENCLOSE ROOF AROUND MGS. PREP RIG FLOOR FOR PAINT. 06:00 06:30 0.50 MOB N RREP PRE CREW CHANGE. REVIEW RIG AND PROJECT STATUS WITH NIGHT CREW. MAKE EQUIPMENT CHECKS. MAKE OUTSIDE ROUNDS. 06:30 - 18:00 11.50 t MOB N RREP PRE CONTINUE TO FABRICATE PRESSURE RELIEF VALVE LINES ONSITE AND OFFSITE. CONTINUE PREPPING PORTIONS OF RIG INTERIOR FOR PAINT. INSTALL MOST OF POP OFF LINE FOR PUMP #1 Printed 9/19/2011 9:31:25AM orth Americas - ALASKA - BP Page 4 sift Aeration Summary Report Common Well Name: C -10 j AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010P7 -C (1,898,705.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292037100 Active Datum: C -1 OA: @62.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 00:00 6.00 MOB P PRE CONTINUE TO WORK ON #1 & #2 PUMP POP OFF LINES. CONTINUE PREPPING PORTIONS OF RIG INTERIOR FOR PAINT WORKING ON CRITICAL ITEMS LIST GENERATED BY NORDIC SUPERINTENDANTS. }FINISH UP PLYWOOD ROOFING. 9/7/2011 00:00 06:00 6.00 MOB N RREP PRE CONTINUE TO FABRICATE POP OFF LINES FOR # 1 & #2 PUMPS AT PEAK WELDING SHOP AND IN THE NORDIC WELDING SHOP. WORK ON CRITICAL LIST AND PREP AREAS FOR PAINTING. 06:00 - 06:30 0.50 MOB N RREP PRE CREW CHANGE. DISCUSS RIG OPS AND STATUS. MAKE EQUIPMENT CHECKS AND !OUTSIDE ROUNDS. 06:30 00:00 17.50 MOB N RREP { PRE !CONTINUE TO PREP AND PAINT RIG FLOOR AREA. CONTINUE TO FAB PUMP #2 POP OFF LINE. PJSM TO PREP PITS FOR POP OFF LINE PENETRATION. X -RAY NORDIC 1 LINE COMPONENTS. REMOVE AND CLOSE OLD LINE ENTRY POINT IN PIT #2. PENETRATE BOTTOM OF PIT #1 FOR BOTH POP OFF LINES. INSTALL 2ND PIECE OF #1 PUMP POP OFF IN 1 PUMP ROOM #2 AND PITS. X -RAY LINE COMPONENTS ON END OF PAD. 9/8/2011 00:00 - 06:00 6.00 MOB N RREP PRE CONTINUE TO WELD, INSPECT AND INSTALL POP OFF LINES. - INSTALLING POP OFF LINE ON # 2 PUMP. - CLEANING AND PAINTING VARIOUS SECTIONS OF THE RIG. - COMPLETING ITEMS ON CRITICAL LIST. 06:00 06:30 0.50 MOB N RREP PRE CREW CHANGE. DISCUSS PROJECT STATUS AND OTHER INFO. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. ISSURE PERMITS FOR CONFINED SPACE AND HOT WORK. 06:30 - 19:00 12.50 MOB N RREP PRE CONTINUE TO INSTALL PUMP #2 POP OFF LINE. I WORK ON CLOSING AND REINFORCING PENETRATION THROUGH BTM OF PIT #1. WORK WITH SLB TO WRITE PUMP OPERATION PROCEDURE. CLEAN UP AND PAINT NEW METAL IN PIT #1. RU TO PRESSURE TEST POP OFF LINES. Printed 9/19/2011 9:31:25AM Page 5 ailia orth America = ALASKA - BP Aeration Summary Report Common Well Name: C -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: 1X3- 010P7 -C (1,898,705.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292037100 Active Datum: C -10A: @62.32ft (above Mean Sea Level) Date From - To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) ' (ft) 19:00 - 21:00 2.00 MOB N RREP PRE CONDUCTED MEETING CONCERNING RIG GOING BACK TO WORK. - ATTENDEES INCLUDED (5) BP WSL, NORDIC TOOLPUSHERS AND TOUR PUSHERS SCHLUMBERGER OPERATORS (2) AND SCHLUMBERGER MANAGERS (2) - NORDIC SUPERINTENDANT (MEETING 1 FACILITATOR). - ALL ATTENDEES WERE FROM NORDIC 1 'AND NORDIC2 RIGS. - MEETING ADDRESSED ADJUSTMENTS MADE, (BOTH ADMINISTRATIVE AND ENGINEERING), THAT WILL ENABLE US TO OPERATE MUD PUMPS IN A RESPONSIBLE MANNER. THESE ADJUSTMENTS INCLUDED: - SETTING HI PRESSURE TRIPS. THIS WORK IS IN PROGRESS AND WILL ALLOW FOR TRIPS TO BE SET ON BOTH PUMPS SIMULTANEOUSLY, WHETHER ONE IS IN USE OR NOT. APPROXIMATE TIME TO COMPLETION ... 5 DAYS. - PUMP START UP "GUIDELINE" GENERATED BY NORDIC. - SCHLUMBERGER PROCEDURE # 713. - SCHLUMBERGER MANAGEMENT TO BE PRESENT DURING PUMP OPERATIONS TO ASSESS SKILL LEVELS OF OPERATORS. 1 - COVER OVER NON TRIP PROTECTED RHEOSTAT TO PREVENT NON INTENTIONAL OPERATION. - WILL CAPTURE EVERY TIME A PRESSURE RELIEF VALVE IS FUNCTIONED AND EXPLAIN WHY. 1 - AGREEMENT MADE TO USE BETTER COMMUNICATIONS WHEN BRINGING ON A PUMP SO AS TO KEEP THE FOCUS LEVEL OF THE ENTIRE TEAM UP. - KEEP DISTRACTIONS TO THE OPERATOR AT A MINIMUM DURING OPERATIONS. 21:00 - 00:00 3.00 MOB N RREP PRE I CONTINUE TO PRESSURE TEST POP OFF I LINE(S). 250 / 5000 PSI. - ALL TESTS SUCCESSFUL. 9/9/2011 00:00 - 02:00 2.00 MOB P PRE REMOVE SCAFFOLDING FROM AROUND WELL. 1- SPOT MATTING BOARDS. 02:00 - 02:30 0.50 MOB P PRE !PJSM ON MOVING RIG OVER WELL. - EMPHASIS ON GOOD COMMUNICATION AND TASK DELEGATION. - PAD OPERATOR NOTIFIED AND ;WITNESSING. 02:30 - 04:00 1.50 i MOB P PRE MOVE ;I • _.: AND CENTER UP AND LEVEL SAME. - RIG ACCEPTED @ 04:00 HRS. 04:00 - 06:00 2.00 BOPSUR P PRE PJSM. pEGIIU ITU BOPF 06:00 - 06:30 0.50 BOPSUR P PRE CREW CHANGE. DISCUSS RIG STATUS AND i OPS. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. CONTINUE TO NU BOPS. Printed 9/19/2011 9:31:25AM oft America - ALASKA - BP Page 6 aide peration Summa Re ort P rY P Common Well Name: C -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010P7 -C (1,898,705.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM I Rig Release: Rig Contractor: NORDIC CALISTA ' UWI: 500292037100 Active Datum: C -10A: @62.32ft (above Mean Sea Level) Date i From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 10:30 4.00 BOPSUR P PRE CONTINUE TO NU BOPS. UPDATE AOGCC REGARDING BOP TEST TIME FRAME. 110:30 - 14:30 4.00 RIGU P { PRE PULL AND STAB COIL INTO INJECTOR. I CONTINUE TO SPOT EQUIPMENT AND RIG UP WELLSITE. 1 SPOT FLOW BACK TANK. MU AND TEST HARDLINE TO 3500 PSI. 14:30 - 15:30 1.00 RIGU P PRE' HOLD COMBO RIG EVACUATION/ H2S DRILL. DEBRIEF WITH AAR DOCUMENTATION. 15:30 - 19:00 r 3.50 BOPSUR P PRE ATTEMPT TO PERFORM BOP BODY TEST. 250 / 4500 PSI. - VALVE #3 ON MUD MANIFOLD LEAKING. - REPLACE PADDLE AND SEAT. - GLEANED HAND CHOKE SEALS AND !GREASED. BOPE FUNCTION TESTED USING REMOTE 4 I IN OPS CAB. 19:00 - 22:00 3.00 BOPSUR P PRE HANG INJECTOR SERVICE LOOP - INSTALL "T' ON MUD GAS SEPARATOR U I TUBE LINE. 22:00 00:00 2.00 BOPSUR P 1 PRE ; R PRELIMINARY TEST ON BOPE. 1 r 9/10/2011 100:00 - 01:00 1.00 BOPSUR • P PRE • COMPLETE PRELIMINARY BOPE TEST. 01:00 - 05:00 4.00 BOPSUR P PRE CONDUCT FULL BOPE TEST AS PER AOGCC REGS. - TESTING DONE @ 250 / 3500 PSI / 5 MIN ..k EACH ON ALL COMPONENTS. 'e - OPERATION OF BOPE DURING TEST DONE WITH DRILLERS CONSOLE REMOTE. 05:00 - 06:00 1.00 BOPSUR P PRE I CONDUCT RIG EVACUATION, H2S , COMBINATION DRILL. I - AAR CONDUCTED POST DRILL, PERSONAL , REPORTED TO SATELLITE CAMP. 06:00 - 06:30 0.50 BOPSUR P , PRE I CREW CHANGE. DISCUSS RIG AND OPS STATUS. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. ISSUE PERMITS. 106:30 10:30 4.00 BOPSUR �, P PRE CONTINUE TO PERFORM BOP TEST. TEST COMPLETED AS PER PERMIT TO DRILL, 1 AOGCC REGULATIONS, AND BP ADWOP POLICIES. NO FAILURES NOTED. TEST RESULTS TRANSMITTED TO AOGCC IN —_ — ANCHORAGE. 10:30 13:30 3.00 BOPSUR P . A 1 WEXIT 1 HOLD PJSM. RU DSM LUBRICATOR. PT TO 250 AND 4000 PSI FOR 5 MIN. ENGAGE AND PULL TWC. NOTE 1660 PSI WHP. SHUT IN WELL. BLEED GAS TO FLOW BACK TANK. RD LUBRICATOR AND REMOVE ' FROM RIG. I LOAD PIS WTH 2% SLICK KCL W/ SAFE -LUBE. 13:30 17:15 3.75 BOPSUR P WEXIT I HOLD PJSM. RU TO PUMP ELINE SLACK IN REEL. FILL REEL WITH KCL. PRESSURE TEST INNER REEL VALVE TO 300 ; AND 3500 PSI. PRESSURE TEST PACKOFFS TO 300 AND 3500 PSI. 17:15 - 18:00 0.75 BOPSUR P WEXIT REVERSE CIRCULATE E -LINE BACK INTO I COIL. ' 18:00 - 20:30 2.50 BOPSUR P WEXIT PJSM. CUT OFF 225' OF COIL. Printed 9/19/2011 9:31:25AM orth America = Americ ALASKA - BP P 7 Operation Summary Report Common Well Name: C -10 — AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: .X3- 010P7 -C (1,898,705.00 ) Project: Prudhoe Bay I Site: PB C Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292037100 Active Datum: C -10A: @62.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 21:30 1.00 j KILLW N SFAL WEXIT TROUBLE SHOOT INJECTOR, CHANGE OUT ENCODER. 21:30 - 00:00 2.50 KILLW P WEXIT INSTALL COIL TBG CONNECTOR. PULL TEST TO 35K. 1- PUMP WIRE FORWARD TO ALLOW BAKER ,TO HEAD UP. - – � BAKER HEADING UP. 9/11/2011 00:00 - 01:00 1.00 KILLW P WEXIT FINISH REHEADING (BAKER) ;= PRESSURE TEST © 3800 PSI, OK. - TEST CHECKS, GOOD TEST. - SECURE INJECTOR. 01:00 01:30 0.50 KILLW P WEXIT PJSM W/ REGARD TO BULLHEAD KILL. I- DOUBLE CHECK VALVE ALIGNMENT. - PRESSURE UP AGAINST SWAB VALVE, 1700 PSI. I - OPEN SWAB AND MASTER VALVE, 33 TURNS EACH. 01:30 - 02:30 1.00 KILLW P WEXIT BRING ON PUMP @ 2 BPM / 1650 PSI. - WALK AROUND, MAKE SURE EVERYTHING j GOOD. ' I- BRING PUMPS UP TO 6 BPM, BULL HEADING DOWN 4 1/2" TBG. - PUMPING 8.4 PPG 2% KCL W/ SAFE LUBE. - 50 BBLS AWAY / 1450 PSI, 100 BBLS AWAY / 1150 PSI. - 150 BBLS AWAY / 500 PSI, 200 BBLS AWAY / 600 PSI. - 250 BBLS AWAY / 750 PSI, 300 BBLS AWAY / 825 PSI. 1- @ 180 BBLS AWAY / 150 PSI, PRESSURE BEGAN CLIMBING AS FLUID HIT PERFS. 02:30 03:00 0.50 KILLW P WEXIT 1MONITOR WELL / 30 MIN / WELL ON VACUUM. ' 03:00 - 03:15 0.25 KILLW P WEXIT AAR ON WELL KILL. - PJSM FOR BRINGING BAKER TOOLS TO ' FLOOR AND MAKING UP. 03:15 - 04:00 0.75 KILLW P WEXIT 1 BRING UP WHIPSTOCK SETTING TOOLS. l i - AFTER (1) HOUR, FILL HOLE, 42 BBLS TO FILL. 04:00 - 06:00 2.00 KILLW N RREP WEXIT TROUBLE SHOOT "IN" MICRO MOTION METER. 06:00 - 06:30 0.50 KILLW P WEXIT CREW CHANGE. DISCUSS RIG STAUS AND 'CURRENT OPS. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. CONTINUE TO WORK ON MICROMOTION IN. 06:30 - 12:00 5.50 KILLW P WEXIT CONTINUE TO FILL AND MONITOR HOLE. . TAKING UP TO 120 BPH. RATE TOO HIGH TO SET WHIPSTOCK/PACKER ASSEMBLY. 1 DISCUSS WITH TOWN. ' CALL FOR LCM FROM MI. ORDER 250 BBLS USED FLOPRO FROM MI. 1 CONTINUE TO PUMP 60 BPH IN TO WELL. 12:00 - 13:00 1.00 KILLW P WEXIT MIX 50 BBLS 20 PPB (2PPB g -SEAL, 6 PPB MIX II COARSE, 6 PPBMIX II MEDIUM, 3 PPB – - 1 NUT PLUG FINE, 3 PPB SAFE CARB 40) Printed 9/19/2011 9:31:25AM orth America - ALASKA - BP Page sit Aeration Summary Report Common Well Name: C -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: X3- 010P7 -C (1,898,705.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292037100 Active Datum: C -1 OA: @62.32ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 1 (ft) 13:00 14:30 1.50 KILLW P H WEXIT PUMP 10 BBLS LCM. CHASE WITH 175 BBLS 2% KCL. 550 PSI WHP AT 3.3 BPM. ' REDUCE RATE TO 0.5 BPM WITH 165 BBLS TOTAL PUMPED. 110 PSI WHP AT 0.5 BPM. PUMP 175 BBLS TOTAL. 14:30 15:00 0.50 KILLW P WEXIT CIRCULATE ACROSS THE WELL. PVT AT START: 184 BBLS @ 1436 HRS. 180 BBLS @ 1441 HRS. 15:00 - 16:45 1.75 KILLW P WEXIT a PUMP ADDITIONAL 40 BBLS LCM. 2.95 BPM AT 2050 PSI. I WITH 170 BBLS PUMPED, REDUCE RATE TO 1 BPM. WHP: 1580 PSI. !WITH 193 BBLS PUMPED, REDUCE RATE TO 0.5 BPM. WHP: 1930 PSI. WITH 210 BBLS PUMPED, WHP: 2550 PSI. SHUT DN PUMP. BLEED WELLHEAD. 16:45 17:15 0.50 KILLW P WEXIT I CIRCULATE ACROSS TOP OF WELL. PVT 360 BBLS AT 1652 HRS. 358 BBLS AT 1703 HRS. LOSS RATE <15 BPH. 17:15 - 19:00 1.75 STWHIP P WEXIT 1 MU WHIPSTOCK ON INTEQ TOOLS. 1 I - MAKE UP INJECTOR TO WELL. - PERFROM PRE TRIP FLUIDS CHECK. ; W - TEST QTS, GOOD TEST. 19:00 - 22:15 3.25 STHIP P WEXIT ! RIH W/ WHIPSTOCK SETTING BHA. I- RIH @ 70 FPM, PUMPING .4 BPM OF 8.4 PPG KCL. ' W 11,000', 28K DOWN T, 41K UP WT. 22:15 - 00:00 1.75 STWHIP P WEXIT LOG TIE IN FROM 11,050' - 11.250', SUBTRACT 25' CORRECTION. 1 - RIH TO 11,380' & LOG UP (CCL). COLLAR LOCATED @ 11,305'. 9/12/2011 00:00 - 01:00 1.00 STWHIP P WEXIT I PROGRAM CALLS FOR TOP OF WHIPSTOCK © 11,300', COLLAR @ 11,305'. 1- ATTEMPT TO ESTABLISH COMMUNICATION WITH TOWN ENGINEER(S) - CONSULT WITH SUPERINTENDANT KEN MILLER. - OK GIVEN TO CONSULT DD AND I GEOLOGIST IN FIELD TO ADJUST DEPTH. I - MAKE DECISION TO SET TOP OF WHIPSTOCK (a 11,308'. RIH TO 11,350' & PULL UP TO 11,323.64' & j PARK. TF 90R. 01:00 - 01:45 0.75 STWHIP 1 P WEXIT I SHUT DOWN PUMP, CLOSE EDC. TF 90R. I - BRING ON PUMP AND PRESSURE UP COIL TO 1800 PSI & OBSERVE SET. - RELEASED FROM WHIPSTOCK, POOH TO I 11,300'. HOLE FULL. - PERFORM 10 MINUTE FLOW CHECK, WELL ' STABLE, HOLE STAYING FULL. 01 :45 - 04:00 ! 2.25 STWHIP P WEXIT PJSM. POOH W/ WHIPSTOCK SETTING RHA - NO LOSS OR GAIN ON WAY OUT, TAKING RIGHT AMOUNT OF FLUID. 04:00 - 06:00 2.00 STWHIP P WEXIT PJSM. FLOW CHECK, 10 MIN, WELL STABLE. - BREAK OFF INJECTOR, LAY DOWN WHIPSTOCK SETTING TOOL. - AAR ON LAYING DOWN BHA. PJSM ON PICKING UP WINDOW MILLING BHA. - PICK UP WINDOW MILLING BHA. Printed 9/19/2011 9:31:25AM orth America - ALASKA i BP Page 9 vie Aeration Summary Report Common Well Name: C -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/29/2011 End Date: 1X3- 010P7 -C (1,898,705.00 ) I Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/17/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292037100 Active Datum: C -10A: ©62.32ft (above Mean Sea Level) Date From - To Hrs Task I Code ' NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 06:30 ' 0.50 STWHIP P ' WEXIT !CREW CHANGE. DISCUSS RIG STATUS AND OPS WITH NIGT CREW. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. CONTINUE T O PU WINDOW MILLING BHA. 06:30 - 10:15 3.75 STWHIP , P r WEXIT [STAB COIL. TEST TOOLS. GET ON WELL. PT LUBRICATOR CONNECTION. RUN IN HOLE. 110:15 13:15 1 3.00 STWHIP P 1 WEXIT I LOG GR TIE IN FROM 11,045' TO 11150'. SUBTRACT 10' CORRECTION. I I .RIH. TAG WHIPSTOCK AT 11,310'. ! PU AND DISPLACE COIL TO NEW FLOVIS MUD. ACQUIRE SLOW PUMP RATES. c , _ e,. 1 13:15 - 16:00 2.75 STWHIP P WEXIT ; MILL WINDOW AS PER WELLPLAN. -�T� ` 1 MILL INITIAL 1' SLOWLY INCREASING WOB C► AO gj 1 FROM 11,311.3'. y I 12.52 BPM IN/OUT AT 2100 PSI FS. 100 -12 =150 PSI MTR WORK. Pt") t " ) DHWOB: 2.2.5K# MILL AHEAD AT 0.1' AS WEIGHT AND DRILL }�-- 'ALLOWS. I ( MILL TO11,315'. 16:00 - 18:00 2.00 STWHIP P WEXIT CONTINUE TO MILL AHEAD AS PRESCRIBED IN PROGRAM. I - 2 - 2.5K WOB, 300 - 400 DIFFERENTIAL IPRESSURE, @ 11,316.5'. 18:00 - 22:15 1 4.25 STWHIP P WEXIT 1 CONTINUE MILLING WINDOW, MILLING 1 /10TH OF A FOOT EVERY 5 - 6 MIN. 1- 2.5 BPM / 1900 PSI FREE SPIN, 2K WOB, 200 I - 300 PSI MOTOR WORK. - @ 11,321' WITH 1' OF FORMATION MILLED. ,- CALLING TOW @ 11,311', BOW @ 11,320'. 22:15 00:00 1.75 STWHIP P WEXIT MILL FORMATION @ 10 - 15 FPH TO 11,332'. 1 9/13/2011 00:00 - 00:15 0.25 STWHIP P WEXIT FLOW CHECK PRIOR TO POOH, WELL STABLE. 00:15 - 02:30 2.25 STWHIP P WEXIT :OPEN EDC, POOH W/ WINDOW MILLING BHA. 02:30 - 02:45 0.25 STWHIP P WEXIT PJSM FOR LAYING DOWN BHA. 02:45 - 03:00 0.25 STWHIP P WEXIT 1 AT SURFACE, FLOW CHECK, WELL STABLE. - NO LOSSES OR GAINS DURING TRIP OR WHILE MILLING WINDOW. 03:00 - 05:00 2.00 STWHIP P WEXIT POP OFF WELL, STAND BACK INJECTOR. - LAY DOWN WINDOW MILLING BHA, GAUGE MILLS, IN GAUGE, (3.80 "). - CHECK TORQUE ON TREE BOLTS, GOOD. - PICK UP LATERAL SECTION BHA W/ RESISTIVITY TOOL. - 1.1 DEG AKO MTR WITH HYCALOG RAPTOR I BIT. 05:00 - 06:00 1.00 DRILL P PROD1 IRIH W/ LATERAL SECTION BHA @ 95 FPM, PUMPING .35 BPM. 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS RIG STATUS AND OPS. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. I CONTINUE TO RIH WITH LATERAL BHA. 06:30 - 07:30 1.00 DRILL P PROD1 CONTINUE TO RIH. ' CIRC AT 985 PSI AT 0.32 BPM. 07:30 - 08:00 0.50 DRILL P ! PROD1 LOG GR TIE IN FROM 11050'. SUBTRACT 11' CORRECTION. CONTINUE TO RUN IN HOLE. Printed 9/19/2011 9:31:25AM TREE= • 6" CMJ WELLHEAD = 13 -5/8" 5M FMC • SAFETY: * * *4 -1 /2" CHROME TBG*** ACTUATOR = OTIS C 10 A KB. ELEV = 61.97' BF. ELEV = 34.97' KOP = 3100' Max Angle = 92 @"1130'9' 1 1 I 2190' I -1/2" HES X NIP, ID = 3.813" I Datum MD = 11546' Datum TVD = 8800' SS —1 2585' H 9 -5/8" DV I 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2666' 1 ' GAS LIFT MANDRELS M ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3008 3008 6 MMG DMY RK 0 06/23/11 3 5533 5013 53 MMG DMY RK 0 06/23/11 2 7876 6393 55 MMG DMY RK 0 10/28/05 Minimum ID = 3.80" @ 10220' 1 9792 7820 16 KGB2 DMY BK 0 10/28/05 4 -1/2" MILLED HES XN NIPPLE 8328' H 9 -5/8" X 7" BKR ZXP LTP w /TIEBACK SLV, ID = 6.30" I 1 8345' H 9 -5/8" X 7" BKR HMC LNR HNGR, ID = 6.23" I MILLOUT 9 -5/8" WINDOW TOP OF WHIPSTOCK H 8506' I 8505' - 8522' ( 9 -5/8" CSG, 47 #, N-80, ID = 8.681" H -8522 10158' H 4 -1/2" HES X NIP, ID = 3.813" I ., 10178' H 7" x 4-1/Z' BKR S -3 PKR, ID = 3.875" I 19 -5/8" EZSV H 8527' I 10201' H 4 -1 /2" HES X NIP, ID = 3.813" I I `► 10220' - 4 -1/2" HES XN NIP, v MILLED TO 3.80" (08/11 /11) N.- 10233' H 4 -1/2" WLEG, ID= 3.958" I 10225' I- 7" X 5" BKR ZXP LTP w / TIEBACK SLV, ID = 4.40" 1 I J I ELMD TT NOT LOGGED 1 10243' I 7" X 5" BKR HMC LNR ♦ HNGR, ID = 4.410" 14 -1/2" TBG, 12.6 #, 13CR80 TCII, .0152 bpf, ID = 3.958" H 10233' 10250' 115" X 4 -1/2" XO, ID = 3.950" PERFORATION SUMMARY REF LOG: LWD SPERRY SUN ON 10/24/05 ANGLE AT TOP PERF: 39° @ 10915' Note: Refer to R DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE ` 3 -3/8" 6 10915 - 10925 0 04/18/10 7" LNR, 26 #, L -80 BTC-M, -I 10400' 2 -1/2" 4 11500 - 12260 0 10/26/05 .0383 bpf, ID = 6.276" 0p O r \ \3a8' I PBTD 11 12274' ' . 4 % - ∎ 14-1/2" LNR, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" I-I 12360' , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/10/79 ORIGINAL COMPLETION 04/20/10 JMF /SV ADD PERF (04/18/10) WELL: C-10A 03/24/90 RWO 06/25/11 SWC/ PJC PULL WRP/ GLV C/O (6/20 -23/11 PERMIT No: 2051370 10/29/05 N2ES SIDETRACK (C -10A) 08/14/11 PBS/ PJC MILL XN (08/11/11) API No: 50- 029 - 20371 -01 11/02/05 KSB/TLH GLV C/O 775' SNL & 1222' WEL, Sec. 19, T11N, R14E 12/04/05 MJA /TLH DRLG DRAFT CORRECTIONS 04/20/10 SWC /SV SET WRP(04 /15/10) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August22, 2011 ,,,,�';s Mr. Tom Maunder AUG 3 Alaska Oil and Gas Conservation Commissio ��$ 333 West 7 Avenue Anchorage, Alaska 99501 Ancimmgs Cam ssron Subject: Corrosion Inhibitor Treatments of GPB C -Pad aos- (37 Dear Mr. Maunder, / O P Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 r 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 > C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -318 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C-41A 2041880 500292238501 Sealed NA NA NA NA NA C-42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 I • • r nsEA sir : iii SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM11IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. r P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C -10A Sundry Number: 311 -242 Dear Mr. McMullen: NED AU 6 0 lc 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, e )"7 Daniel T. Seamount, Jr. Chair DATED this 't day of August, 2011. Encl. ; ? 1 , I I STATE OF ALASKA • '` r - \ i ) ALASKA. AND GAS CONSERVATION COMMISSION , i, .201 . APPLICATION FOR SUNDRY APPROVAL , r - �'�%/ 20 AAC 25.280 a:4' }:. . . ; t --,. -4 , -:1,=11,ssio 1. Type of Request: t , g ,� )C ❑ Abandon ® Plug for Redrill - ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ 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 - 205 - 137- 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 r 50 029 - 20371 - 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 C -10A- Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028305 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12360 - 9026 - 12274 - 9022 - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2666' 13 -3/8" 2666' 2666' 4930 2670 Intermediate Production 8505' 9 -5/8" 8505' 6743' 6870 4760 Liner 2072' 7" 8328' - 10400' 6642' - 8403' 7240 5410 Liner 2135' 4 -1/2" 10225' - 12360' 8235' - 9026' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10915' - 12260' 8881' - 9022' 4 - 1/2 ", 12.6# 13CR80 10233' Packers and SSSV Type: 7" x 4 - 1/2" BKR S - Packer Packers and SSSV 10178' MD / 8190' TVD MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sk El Detailed Operations Program ❑ Exploratory - ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 8, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG _ 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Zach Sayers, 564 -5790 Printed Name Joh ,A ,m Title Engineering Team Leader Prepared By Name /Number: Signature � Phone 564 - 4711 Datt j (- r ( Elizabeth Barker, 564 -5674 Commission Use Only Condition of approval: Notify Commission so that a representative may witness �) l Sundry Number: ❑ Plug Integrity 'BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0- 3 So o , t3 7f 'Ts t Other: ' �i v� ^�'� / 1 p A14, ptIK3 Plat: . .._ ac-/ / Ac t Zo .9,#c Zs /IL Cu..) Subsequent Form Required: / 0 • T 07 APPROVED BY 4 / I / gi Approved By: COMMISSIONER THE COMMISSION Date Form 10 -403 Re�l9e ft 6}162 n �� £ yet Submit In Duplicate ►��U y V ;JI I Ir1r e G INAL . 11 °0 • • To: Alaska Oil & Gas Conservation Commission bp From: Zach Sa Y ers CTD Engineer Date: August 3, 2011 Re: C -10A Sundry Approval Sundry approval is requested to plug the C -10A perforations as part of drilling the C -10B coiled tubing sidetrack. History of C -10A. C -10A was rotary sidetracked in Oct 2005 to Zone 1B/2A above the HOT with 760' of perfs. By mid 2008 the well reached MGOR due to a high gas rate and was shut -in for the summertime. The well was POP'ed in late 2008 and remained online until April 2009 when it was shut -in for a tree C /O. The well was POP'ed & placed on a cycle schedule of month on / month off, which lasted -1 year. A RST -sigma log was run Dec 2009. Based on the log results, 10' of a Z2B oil lens was shot and all of the open perforations were isolated with a WRP in April 2010. This wellwork job provided - 3 months of competitive fulltime production before the well started cycling again. The well is currently shut -in, and the WRP was pulled during CTD screening work in June 2011. Reason for sidetrack. C -10A is no longer a competitive well due to high GOR and has no remaining wellwork options. The proposed sidetrack will access a target above the MHO /HOT in south - eastern C -pad. Proposed plan for C -10B is to drill a through tubing sidetrack with the SLB /Nordic 2 Coiled Tubing Drilling rig on or around September 1 2011. The existing perforations will be isolated by the primary cement job for the liner. The sidetrack, C -10B, will exit the existing 4 - %" liner and kick off in the HOT and land in Z2A and Z1 B. This sidetrack will be completed with a 3- 3/16" x 2 -7/8" liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. pod 7 I Col Cvt wc, /fo. L'e y err /e fv5 rq /sect ftoIG404. d�,r C1 fir Pl + (4te 6?/e4' ! fwk„✓ ovf ,e. „ 1 f 404. /10 %GIq 9e k4 I4 ./►. 14( P q fro•. rti /s (Orr' 71 / e4 plevl /toe'',) • Pre -Rig Work: (scheduled to begin August 8 ', 2011) 1. F MIT- IA to 3,000 psi, MIT -OA to 2,000 psi) Passed 06/23/11 2. W Cycle LDS; PPPOT- T to 5,000 psi Passed 06/22/11 3. C Mill XN nipple at 10,220' to 3.80" 4. C Dummy WS Drift to 11,400'. 5. V PT MV, SV, WV. Bleed wellhead pressures down to zero. 6. 0 Bleed production flow and GL lines down to zero and blind flange 7. 0 Remove wellhouse, level pad 8. V Set TWC (Cameron 6 -3/8" Type J profile) 24 hrs prior to rig arrival Rig Work: (scheduled to begin September 1 2011) (y( 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Set 4 - 1/2" KB Packer Whipstock at 11,300' MD 3. Mill 3.80" window at 11,300' and 10' of rathole. Swap the well to Power -Pro SF. 4. Drill Lateral: 4.125" OH, 2,708' (12 deg /100 planned) with resistivity 5. Run 3- 3/16" x 2 -7/8" L -80 liner leaving TOL at 10,850' MD. 6. Pump primary cement leaving TOC at 10,850' MD, 38 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and run MCNUGR /CCL log. AI Ad 8. Test liner lap to 2,400 psi. erP 9. Perforate liner per asset instructions ( -800') 10. Set 4 -W liner top packer, and test to 2,400 psi 11. Freeze protect well, set BPV, RDMO Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Generic GLV's 3. Test separator Zach Sayers CTD Engineer 564 -5790 CC: Well File Sondra Stewman/Terrie Hubble TREE= . 6" CIW - _WELLHEAD = 13 -5/8" 5M FMC • SAFETY : * * *4 -112" CHROME TBG* ** ACTUATOR = C - p A KB. ELEV = 61.971.97 ' BF. ELEV = 34.97' KOP = 3100' Max Angle = 92 @ 11309' 1 1 2190' I- I4 -1/2" HES X NIP, ID = 3.813" 1 Datum MD = 11546' Datum TVD = 8800' SS _ --I 2585' H9 -5/8" DV' 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2666' I , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3008 3008 6 MMG DMY RK 0 06/23/11 3 5533 5013 53 MMG DMY RK 0 06/23/11 2 7876 6393 55 MMG DMY RK 0 10/28/05 Minimum ID = 3.725" @ 10220' 1 9792 7820 16 _ KGB2 DMY BK 0 10/28/05 4 -1/2" HES XN NIPPLE 8328' I 19 -5/8" X 7" BKR ZXP LTP w /TIEBACK SLV, ID = 6.30" I I 8345' H 9 -5/8" X 7" BKR HMC LNR HNGR, ID = 6.23" I MILLOUT 9 -5/8" WINDOW 1 TOP OF WHIPSTOCK I1 8506' 1 8505' - 8522' T • 10158' 114-1/2" HES X NIP, ID = 3.813" I y , A >. ,1. _ 1 0178' 7" x 4 -1/2" BKR S -3 PKR, ID = 3.875" 19-5/8" EZSV I--{ 8527' I : . <., �� 'TOP OF CEMENT (09/24/05) I1 -8527' 1 10201' 1-14-1/2" HES X NIP, ID = 3.813" 4 1 1 1 1 1 1 1 1 � � ;� 10220' I- I4 -1/2" HES XN NIP, ID = 3.725" 111111 1 , 10225' I 7 "X5 " BKR ZXPLTPw/ _. ►/// ,� ►11111 v , TIEBACK SLV, ID = 4.40" ► 1 9 -5/8" CSG, 47 #, N -80, ID = 8.681" I-1 10831' ► 1 1 1 1 1 1 1 1 1 1 1 10233' I-14 -_1/2 WLEG, 10 " 11111 III N� , I H ELMD TT NOT LOGGED I 1�(1�t e■ 10243' ( X 5" BKR HMC LNR ' .�,.. I HNGR, ID = 4.410" 111 �jIj1/11/11,_ 10250' I- 5 " X 4 -1/2" X0, � 1111' , , ID = 3.950" 17" LNR, 29 #, L -80 , ID = 6.184" I 12060' tAttitittV 14 -1/2" TBG, 12.6 #, 13CR80 TCII, .0152 bpf, ID = 3.958" I-I 10233' I PERFORATION SUMMARY ` REF LOG: LWD SPERRY SUN ON 10/24/05 7" LNR, 26 #, L -80 BTC-M, H 10400' 1 ANGLE AT TOP PERF: 39° @ 10915' .0383 bpf, ID = 6.276" Note: Refer to Production DB for historical pert data ` SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 10915 - 10925 0 04/18/10 2 -1/2" 4 11500 - 12260 0 10/26/05 PBTD H 12274' X 4, 1 ∎∎ • I4 -1/2" LNR, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" I-I 12360' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/10/79 ORIGINAL COMPLETION 04/20/10 JMF /SV ADD PERF (04 /18/10) WELL: C-10A 03/24/90 RWO 06/25/11 SWC/ PJC PULL WRP/ GLV C/0 (6/20 -23/11 PERMIT No: '2051370 10/29/05 N2ES SIDETRACK (C -10A) API No: 50- 029 - 20371 -01 11/02/05 KSB/TLH GLV C/0 775' SNL & 1222' WEL, Sec. 19, T11 N, R14E 12/04/05 MJA /TLH DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 04/20/10 SWC /SV SET WRP (04/15/10) - TREE = 6" CIW WELLHEAD = 13 -5/8" 5M FMC •C -1 0 B SAFETY S: ***4-1/2" CHROME TBG* ** ACTUATOR = OTIS KB. ELEV = 61.97' Proposed CTD Sidetrack BF. ELEV = 34.97' - KOP = 3100' Max Annggle e = 9 2 @ 11309' I I 2190' I -14- 1 /2 " HES X NIP, ID= 3.813" I 9 Datum MD = 11546' Datum TVD = 8800' SS 2585' I -1 9 -5/8" DV I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2666' I ! , GAS LIFT MANDRELS POI ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3008 3008 6 MMG DMY RK 0 06/23/11 3 5533 5013 53 MMG DMY RK 0 06/23/11 2 7876 6393 55 MMG DMY RK 0 10/28/05 Minimum ID = 3.725" @ 10220' 1 9792 7820 16 KGB2 DMY BK 0 10/28/05 4 -1/2" HES XN NIPPLE A 8328' H9-5/8" X 7" BKR ZXP LTP w /TIEBACK SLV, ID = 6.30" I 8345' H 9 -5/8" X 7" BKR HMC LNR HNGR, ID = 6.23" I MILLOUT 9 -5/8" WINDOW 8505' - 8522' TOP OF WHIPSTOCK H 8506' I 10158' 1-14-1/2" HES X NIP, ID = 3.813" I 10178' 1-17" x 4-1/2" BKR S -3 PKR, ID = 3.875" I 9 -5/8" EZSV H 8527' I TOP OF CEMENT (09/24/05) H -8527' I ‘II 10201' I-14-1/2" HES X NIP, ID = 3.813" I � 10220' 1-14-1/2" HES XN NIP, ID = 3.725" I 10225' I- 7" X 5" BKR ZXP LTP w / 4i N TIEBACK SLV, ID = 4.40" 10233' H4 -1/2" WLEG, ID= 3.958" I t 10243' I— 7" X 5" BKR HMC LNR ■ N HNGR, ID = 4.410" 10250' 1- 5" X 4 -1/2" XO, ID = 3.950" 3.7" deployment sleeve / 4.5" KB LTP .. TOL /TOC -10,850' 2 -7/8" 4.7# L -80 liner aybe slotted or cmtd 4 -1/2" TBG, 12.6 #, 13CR80 TCII, .0152 bpf, ID = 3.958" IH 10233' 7" LNR, 26 #, L -80 BTC-M, 10400' PERFORATION SUMMARY .0383 bpf, ID = 6.276" REF LOG: LW() SPERRY SUN ON 10/24/05 ANGLE AT TOP PERF: 39° @ 10915' 3- 3/16" x 2 -7/8" XO @ --12,050' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 4.5" whipstock @ 11,300' 3 -3/8" 6 10915 - 10925 0 04/18/10 93 degrees 2 -112" 4 11500 - 12260 0 10/26/05 FBTD I 12274' � AO 4 -1/2" LNR, 12.64, L -80 IBT, .0152 bpf, ID = 3.958" H 12360' IT @ -14,008' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/10/79 ORIGINAL COMPLETION 04/20/10 JMF /SV ADD PERF (04/18/10) WELL: C-10A 03/24/90 RWO 06/25/11 SWC/ PJC PULL WRP/ GLV C/O (6/20 -23/11 PERMIT No: 2051370 10/29/05 N2ES SIDETRACK (C -10A) API No: 50- 029 - 20371 -01 11/02/05 KSB /TLH GLV C/O 775' SNL & 1222' WEL, Sec. 19, T11N, R14E 12/04/05 MJA /TLH DRLG DRAFT CORRECTIONS 04/20/10 SWC /SV SET WRP (04/15/10) BP Exploration (Alaska) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM '.14.11111111.111r Cho a Panel Standpipe 2" Circulation Line �► • • • aMM11 L= C A Driller Gauge •�• , M 10 1 • 10. a M anual Choke • CIRCULATING MANIFOLD _ MM ; 9 MM 20 V r MM 22 041110 •le• SLB Transducer M1 .11 MM ,_ 6 . - .. ., PVT Sensor • a 7 -1118" Skpsi ROPE ♦ . ••.•� MM 7 .• Baker Choke Blind Shears • MMS MM 21 GAS BUSTER 2 -318" Combi • t • Kill Line TOT PIS Rev Cir Line 1.1 !. j 1 O MM14 � , -_s_ I_ • -r- sk v p /liss Is IL..' Coiled Tubing ti _ _ 2-3/8" - 3 -1(2" VBR ram 1 Ba er Choke 2 -318" Combi • • TOT MM 1 -..• MP1 in • �• MM 13 E ,- I ii a Y- Kill Line I• Outlet F- Cement Line to Ground Mud - tin my ' Pd.. •s In ,,,, Tranducers COILED TUBING Choke Line CIRCULATING SYSTEM Cellar — _ OP • MIMMII *•• L I r 4 0 Area HP 14 - -- - To Inner Reel Outlets Valve —`.` HP 0 r HP7 - HP 4 Moti HP3 I , HP 2 HP 1 J — 94 HP 1i 4 tl cement line N2 ( SLB NORDIC'S 2 I Circulate Manifold CHOKE MANIFOLD in Cellar , I -0L - HP 11 N2 TriFlow � t� � CM 85 Gauge M j A.' -1 '•� C HOKE I INF f r r Test Pump Inlet = - „ „r , „ , 0 CM3 Ai 11 HDI Gauge CM18 II - Flow fl HCR - c r,. rr = _ = ;• - 4Way Block CM14 CM1 CM8 — To PITS C 2 Intel C C C.. 1 3 Baker Choke Line r■on, from wal HCR j zi II Baker Choke Line PAKFR CHOKE LINE CM13 - , ■ , CM7 ® _ Baker Choke Line CM2 — CM19 • — Micro Use for CM 28 CM 29 Motion Blowing CM20 — Back MM CM4 — CM21 I M i — —__Iis .i.nnRV GI (WV — —_ CM 30 CHOKE LINE C M 75 CM10 C __ Tiger Tank CM 25 Outside c Page 1 of 2 Schwartz, Guy L (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 04, 2011 8:56 AM n To: Schwartz, Guy L (DOA) / -' Subject: FW: C -1 OA Sundry / C -10B PTD . 7 Attachments: C -10B prop.pdf; C- 10A.PDF Sorry, I did not copy you earlier. From: Maunder, Thomas E (DOA) Sent: Wednesday, August 03, 2011 2:20 PM To: 'Sayers, Zach Y Subject: RE: C -10A Sundry / C -10B PTD Zach, Steve Davies and I have spoken about the situation. It is appropriate to submit the sundry and the permit to drill for the sidetrack (C -10B). If the situation changes and you set the slotted liner, then we can settle any naming issue. Tom Maunder, PE AOGCC From: Sayers, Zach 3 [mailto:Zach.Sayers @ bp.com] Sent: Wednesday, August 03, 2011 2:15 PM To: Maunder, Thomas E (DOA) Subject: RE: C -10A Sundry / C -10B PTD Correct, I am writing them today. Zach Sayers Drilling Engineer From: Maunder, Thomas E (DOA) jmailto:tom.maunder @alaska.gov] Sent: Wednesday, August 03, 2011 1:46 PM To: Sayers, Zach J Subject: RE: C -10A Sundry / C -10B PTD OK. If I understand correctly, you have not submitted either the sundry or permit application. Tom From: Sayers, Zach 3 [mailto:Zach.Sayers @bp.com] Sent: Wednesday, August 03, 2011 1:43 PM To: Maunder, Thomas E (DOA) Subject: RE: C -10A Sundry / C -10B PTD Drilling conditions when crossing the Fault #2 area will be used to make the final completion decision. Any evidence of a fault crossing when drilling outside the HOT (losses, change in log character, drilling change, etc.) will require a solid and cemented completion. 8/4/2011 • Page 2 of 2 Zach Sayers Drilling Engineer From: Maunder, Thomas E (DOA) [mailtoaom.maunder @alaska.gov] Sent: Wednesday, August 03, 2011 11:59 AM To: Sayers, Zach 3 Cc: McMullen, John C Subject: RE: C -10A Sundry / C -10B PTD Zach, What will the basis be for the decision solid versus cemented? Tom From: Sayers, Zach 3 [mailto:Zach.Sayers @bp.com] Sent: Wednesday, August 03, 2011 11:30 AM To: Maunder, Thomas E (DOA) Cc: McMullen, John C Subject: C -10A Sundry / C -10B PTD Mr. Maunder, As we discussed BP coil tubing drilling has a well, C -10B, on the schedule for September 1st, 2011. This well has a 50/50 contingency to run a slotted liner instead of a solid and cemented liner. There are open perf above the sidetrack point that will be abandoned by cement as of the solid liner cement job; however, these perforations will remain open if a slotted liner is run. Please see the attached schematic for reference. My plan was to submit a sundry for abandonment and a permit to drill a sidetrack for the solid and cemented liner decision; however my understanding is that if we go with the slotted liner contingency, this will change the well classification to a lateral making a sundry unnecessary and the naming convention different on the permit. Please advice on how to proceed with permitting. Thank you, Zach Sayers Drilling Engineer, Coil Tubing Drilling Alaska Drilling & Wells (907) 564 -5790 — Direct (907) 575 -5189 cell 8/4/2011 ~~~~ STATE OF ALASKA APR ASKA~ AND GAS CONSERVATION COMMIS ~ 0 ~ORT OF SUNDRY WELL OPERATIONS 1. Operations ~ ~ ell ^ Plug Perforations ^ Stimulate ^ Other ^ Performed: Alter Ca(Q 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. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 205-1370 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-20371 -01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028305 \ PBU C-10A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12360 feet Plugs (measured) 10995' 4/15/10 feet true vertical 9025.51 feet Junk (measured) None feet Effective Depth measured 12274 feet Packer (measured) 10178 true vertical 9022 feet (true vertical) 8190 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20:" SURFACE - 110 SURFACE - 110 Surface 2666 13-3/8" 72# L-80 SURFACE - 2666 SURFACE - 2666 4930 2670 Intermediate Production 8505 9-5/8" 47# L-80 SURFACE - 8505 SURFACE - 6743 6870 4760 Liner 2072 7"26# L-80 8328 - 10400 6642 - 8403 7240 5410 Liner 2135 4-1/2"12.6# L-80 10225 - 12360 8235 - 9026 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR80 SURFACE - 10233 SURFACE - 8242 Packers and SSSV (type, measured and true vertical depth) 7"x4-1/2"BKR S-3 PKR ..,".,10178 8190 12. Stimulation or cement squeeze summary: Intervals treated (measured): ; ~~ ~ `r E .~ {~ 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: 674 40246 30 1420 Subsequent to operation: 1740 26137 72 1205 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 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 Preble Title Data Management Engineer Signature Phone 564-4944 Date 4/28/2010 `(• 30 • to , y/~, C-10A 205-137 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-10A 10/26/05 PER 11,500. 12,260. 9,025.55 9,021.73 C-10A 4/15/10 BPS / ~ 10,995. 10,996. 8,937.94 8,938.57 C-10A 4/18/10 APF ~/ 10,915. 10,925. 8,881.11 8,888.82 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 • C-l0A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY I 4/15/2010""WELL S/I ON ARRIVAL*'""(adperf) DRIFT W/ 3.695" DMY WRP SPECIAL CLEARANCE DRIFT @ STOP DUE TO ? DEV @ 11085' SLM ¢ l 'TAG XN NIPPLE W/ 3.75" G-RING @ 1019T SLM/ 10220 MD ~ TAG XN NIPPLE AGAIN W/ XN LOCATOR ABOVE E-FIRE TOOLS @ 10213' 3 SLM =SET 4 1/2" SPECIAL CLEARANCE WRP ~ 10995' MD / 10932' SLM CURRENTLY ON STBY FOR GREASECREW I**"CONTINUED ON 4/16/10 WSR*** 4/16/2010 "**WSR CONTINUED FROM 4/15/10**"(profile mod) RIG DOWN SLICKLINE UNIT "**JOB COMPLETE, WELL LEFT S/I, PAD OP NOTIFIED*"'" 4/17/2010E***"WELL SHUT-IN ON ARRIVAL****(E-LINE JEWELRY LOG &PERF) [INITIAL T/I/O = 2000/1400/0 PSI RIG UP E-LINE ~****CONTINUED ON 18-APR-2010 WSR'"*** 4/18/2010****LOG CONTINUED FROM 17-APR-2010""**(E-LINE JEWELRY LOG & PERF) IJEWELRI( LOG FROM 10970'-9750' 36.5" PENE, 0.37" EH, 22.7 GMS. CORRELATED TO SWS RST LOG DATED 12/28/2009. FINAL T/I/0=2400/1400/0 *""*JOB COMPLETE""* FLUIDS PUMPED BBLS 1 DIESEL 1 Total TREE = 6" CNV 'iIVELL+1EFtD = 13-518" 5M FMC ACTUATOR = OTIS KB. ELEV = 61.97' BF. ELEV = 34.97' KOP = - 3140' Max Angle = 92 @ 11309' Datum MD = 11546' datum TVD = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" 2666' Minimum ID - 3.725" @ 10220' 4-1/2" HES XN NIPPLE TOP OF WHIPSTOCK ~-~ 8506' 9-5/8" F2SV TOP OF CEMEM (09/24/05) 9-518" CSG, 47#, N-80, ID = 8.681" ~-~ 10$31' ~ 7" LNR, 29#, L-80 , ID = 6.184" ~ 2190' '-j4-1/2" HES X NIP, ~ = 3.813" 2585' 9-518" DV GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3008 3008 6 MMG DOME RK 16 11/02/05 3 5533 5013 53 MMG SO RK 20 11 /02/05 2 7876 6393 55 MMG DMY RK 0 10/28/05 1 9792 7820 16 KGB2 DMY BK 0 10/28105 8328' 9-518" X 7" BKR ZXP LTP w JTEEBACK SLV, ID = 6.30" $345' 9-518" X 7" BKR HMC LNR HNGR, ID = 6.23" I MILLOtJf 9-5/8" WINDOW 8505' - 8522' ~ 10158' --~4-112" HES X NIP, ID = 3.813" 10178' 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 10201' 4-112" HES X NIP, ID = 3.813" 10220' 4-112" HES XN NIP, ID = 3.725" 10225 ~" x 5" BKR zx,,,,,,,,,,,,,,,,,,,,, ' PLTPw/ TIEBACK SLV, ID = 4.40" 10233' 4-1/2" WLEG, ID = 3.958 ~~~ELMD TT NOT LOGGED 10243' 7" X 5" BKR HMC LNR HNGR, ID = 4.410" 10250' S" x 4-112" Xo, ~ ID - 3.950" (4-112" TBG, 12.6#, 13CR80 TCII, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: LWD SPERRY SUN ON 10!24/05 ANGLE AT TOP PERF: 39° @ 10915' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 10915 - 10925 O 04/18/10 2-112" 4 11500 - 12260 C 10/26/05 7" LNR, 26#, L-80 BTGM, 10400' .0383 bpf, ID = 6.276" 4-112" WFD SPECIAL CLEARANCE WRP (04/15/10) 10995' PBTD 12274' 4-1/2" LNR, 12.6#, L-80 IBT, .0152 bpf, ID = 3.958" 12360_ DATE REV BY COMMENTS DATE REV BY COMMENTS 08/10/79 ORIGINAL COM PL.ETION 04/20/10 JMF/SV ADD PERF (04118/10) 03/24/90 RWO 10/29!05 N2ES SIDETRACK{C-10A) 11/02/05 KSB/TLH GLV C/O 12/04!05 MJA/TLH DRLG DRAFT CORRECTIONS 04/20/10 SWC/SV SET WRP (04/15/10) PRUDHOE BAY UNff WELL: G10A PERMIT No: 2051370 API No: 50-029-20371-01 775' SNL & 1222' WEL, Sec. 19, T11N, R14E BP Exploration (Alaska) S S: ***4-112" CHROME TBG"** G -10A Sch~anUer~r Alaska Data 8 Consulting Services 2525 Gambell Street, Suke 400 Anchorage, AK 99503-2938 ATTN: Beth Well Job # NO. 5463 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 09-45 AP30-00077 CROSSFLOW CHECK 01/29/10 1 1 V-217 C-10A V-227 82NJ-00051 B3S0-00038 09AKA0146 MEMORY INJ PROFILE RST OH MWDA-WD EDIT 01/27/10 12/28/09 11/12/09 1 1 2 1 1 1 rvCMCIr' 1 O r JRirvIrvV NIVU rIC l UrvrvlrvV VIYC l.VY1 CRlin I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. o~rosi I n Alaska Data 8 Consulting Services 2525 Gambell Street, Sude 400 Anchorage, AK 99503-2838 `~ er WELL LOG TRANSMITTAL To: State of Alaska February 13, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : C-l0A AK-MW-3992155 C-10A: Digital Log Images: 50-029-20371-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~, .e .~ Date ,) ,~; J~~ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~~~ MAR ~ ~ 200 ~S--i3~ ~ /s9~9 ~~ ~~,. ;~~ y _,. :: . ~ '~ y:d'~~, `:. ~ ~ J ~ -, ~ ~~ ,a ~' ~~~ ~' ~ ~ • • WELL LOG TRANSMITTAL To: State of Alaska February 11,2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: C-l0A AK-MW-399215 1 LDWG formatted CD rom with verification listing. API# : 5 0-029-203 71-0 l PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~~ ~~ ~_ ,\ Date: ~~ ~ 'i;~;'~ Signed: ~IVEEt~ MAR ~ 9 2008 SOS ~~ ~~~~C~ ,~~" -~.: ` r V~. ,;~:..,~,.~ ,~ r „d..,,w„~„ .; a b' N~ ~ ~,~~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051370 Well Name/No. PRUDHOE BAY UNIT C-10A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20371-01-00 MD 12360 TVD 9026 Completion Date 10/28/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Su y _ Yes - DATA INFORMATION Types Electric or Other Log s Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D D Asc ~ __ __ Directional Survey /J .ED D Asc Directional Survey ,ED C Las 15436 See Notes Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? 'F'TRt-- Analysis ~-I'IQ~ Received? Comments: Compliance Reviewed By: (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 8500 12360 Open 11/17/2005 Definitive 8500 12360 Open 11/17/2005 MWD 10776 11383 Open 9/17/2007 Field Data, LAS - FNC, GR, NCN, NPHI, RHOB w/EMF Graphics Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? "-'"''' Formation Tops ~/ N Date: Date 09-14-2007 Transmittal Number:92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have anv questions, please contact Uou~las llortcri at the Y11~.; at ~b4-4y ~ ~ Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: u~C 06-066 ~ ~~ yah 06-06BPB1 ~ a~-~~ ~ ~ c~a~ 13-31A -tsSCao~ I(o~ '~ r5~2'~ 14-11 A `~ ao5=(a6 ~S~b 14-11 APBs 14-21A uzcao~ -+o~ ~ +5 x/31 15-39A do(o-o~~ ~ ~Qy3a 16-06B acx.-o ~t ¢ ~ sy;33 16-14B c~o(o`003 " ~55/3y c-o36 aos as~r ~ ~~s C-10Aaas-tai •+5~a~ J-17C ~ o~s2 ~ +5'`33 NGI-07A u'z~acX.-,aL ~' IS~l3tl ~' ,t ji Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 3 ~,~~ ~ ~ ~~ g -,-, ~~ g~' `;fit ~ ~~1°.~ s a,j'if ti~i cC~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 STATE OF ALASKA ALASKA LAND GAS CONSERVATION COMM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~CIV~~ ~~~ 0 2005 >tVlaska Oil & Gas Cons. Commission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.tos 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/28/2005 12. Permit to Drill Number 205-137 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/16/2005 13. API Number 50-029-20371-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/23/2005 14. Well Name and Number: PBU C-10A 775 FNL, 1222 FEL, SEC. 19, T11N, R14E, UM Top of Productive Horizon: 4582' FNL, 1666' FWL, SEC. 20, T11N, R14E, UM 8. KB Elevation (ft): 62.32' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 5i 82' FNL, 2952' FWL, SEC. 20, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 12274 + 9022 Ft 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 664143 y- 5960439 Zone- ASP4 10. Total Depth (MD+TVD) 12360 + 9026 Ft 16. Property Designation: ADL 028305 TPI: x- 667127 y- 5956697 Zone- ASP4 Total Depth: x- 668428 Y- 5956126 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: --- ------ --~---- ----------- i f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL Permafrost 20. Th ckness o 1900' (Approx.) 21. Logs Run: MWD DIR / GR /RES / PWD, MWD DIR / GR /RES / ABI, DEN / NEU 2. CASING, LINER AND CEMENTING RECORD CASING ETTINQ EPTH MD ETTING EPiH TVD' HOLE AMOUNT $IZE 'WT. PER FT. GRADE OP TTOM OP" TTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surtace 110' 36" 12.9 cu ft Permafrost 13-3/8" 72# L-80 Surtace 2666' Surtace 2666' 17-1/2" 492 cu ft Arcticset 9-5/8" 47# L-80 Surface 8505' Surface 6743' 12-1/4" 1589 cu ft Class'G', 130 cu ft AS I 7" 26# L-80 .8328' 10400' 6642' 8403' 8-1/2" 197 cu ft Class'G' 4-1 /2" 12.6# L-80 10225' 12360' 8235' 9026' 6-1 /8" 310 cu ft Class 'G' 23. Perforations open to Produc tion (MD +TV D of Top and " " 24.' Tus-wG RECORD BOttOm Interval, Size and Number; if none, Stat@ none ): SIZE DEPTH SET (MD) PACKER $ET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 10233' 10178' MD TVD MD TVD 11500' - 12260' 9026 - 9022' 'L j, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED Freeze Protect w/ 151 Bbls of Diesel 26. PRODUCTION TEST Date First Production: November 5, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 11/13/2005 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 526 GAS-McF 2,245 WATER-BBL 17 CHOKE SIZE 176° GAS-OIL RATIO 4,265 Flow Tubing Press. 46 Casing Pressure 1,220 CALCULATED 24-HOUR RATE OIL-BBL 3,158 GAS-MCF 13,469 WATER-BBL 104 OIL GRAVITY-API (CORK) 30.7 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, as or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". / G~D~ ~ ~ ~ ~ ~,//1 ~~f. ~~ " ~ d~t~/ ~d~ a ~ ~ YJJ None ~ ~ ~ ~ ~ ~~ D~(, ~ ~ 2~0~~ ~w.~'7 Form 10-407 Revised 12/2003 a',.,,~' ?~ a,~ ~Gfl/~1T~fVUED GN REVERSE SIDE i 28. r GEOLOGIC MARKERS 29' RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD ND and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top IiRZ 9481' 7520' None Base HRZ 9682' 7714' Sag River 10408' 8411' Shublik 10441' 8443' Sadlerochit 10522' 8521' Top CGL 10711' 8699' Base CGL 10797' 8780' 23S6 /Zone 2B 10845' 8823' 22TS 10930' 8893' 21TS /Zone 2A 11015' 8950' Zone 1 B 11149' 9016' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' ~ l Signed Terrie Hubble Title Technical Assistant Date 3~~ PBU C-10A 205-137 Prepared By Name/Number Terrie Hubble, 564-4628 Well Number Permit No. /A royal No. Oril~ingEngineer: JeffCuNer, 564-4134 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 ail test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 10/31/2005 11:39:58 AM BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: C-10 Common Well Name: C-10 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To ' Hours Task ~i Code NPT - - + - - _- 10/11 /2005 ~ 04:00 - 12:00 ~ 8.00 ~ MOB ~ P Spud Date: 7/17/1979 Start: 10/10/2005 End: 10/28/2005 Rig Release: 10/28/2005 Rig Number: Phase PRE 12:00 - 13:00 1.00 MOB P PRE 13:00 - 15:30 2.50 MOB N WAIT PRE 15:30 - 16:00 0.50 MOB P PRE 16:00 - 00:00 8.00 MOB P PRE 10/12/2005 00:00 - 06:00 6.00 RIGU P PRE 06:00 - 06:30 0.50 WHSUR P DECO 06:30 - 07:00 0.50 WHSUR P DECO 07:00 - 09:00 2.00 WHSUR P DECO 09:00 - 09:30 0.50 WHSUR P DECO 09:30 - 11:30 2.00 WHSUR P DECO 11:30 - 12:00 I 0.501 W HSUR I P I I DECO 12:00 - 12:30 0.50 WHSUR P DECO 12:30 - 14:00 1.50 WHSUR P DECO 14:00 - 16:00 2.00 BOPSU~ P DECO 16:00 - 20:00 4.00 BOPSU N RREP DECO 20:00 - 00:00 4.00 BOPSU P DECO 10/13/2005 00:00 - 02:00 ~ 2.00 ~ BOPSUFj P ~ ~ DECO 02:00 - 02:30 0.50 RIGU N 02:30 - 03:30 1.00 PULL P 03:30 - 04:30 1.00 PULL P 04:30 - 05:30 1.00 PULL P 05:30 - 08:00 2.50 PULL P 08:00 - 08:30 0.50 PULL P 08:30 - 12:00 3.50 PULL P 12:00 - 14:30 2.50 PULL P Description of Operations Rig down floor. Rig down top drive. Bridle derrick. Lower cattle chute. Open cellar door. Move camp, pits, and shop to C-Pad. Move rig off J-17C. Stage rig C~? end of pad. Wait on weather to lay derrick over - 35 mph to 50 mph wind gusts. Lay derrick over. Move substructure module from J-Pad to C-Pad. Spot and level sub. Lay herculite. Raise derrick and cattle chute. Spot pits, shop camp, cuttings pit. Berm cuttings pit.Bridle down. R.U. top drive. Hang bridle. Hook up interconnect. RU floor, gatronics, check gas alarms. Take on sea water. Berm cellar and close windwalls around cellar. Accept rig C~3 0600 hrs 10-12-2005. MP Pre spud and saftey meeting -Tool pusher, Co. Rep., crew. MP Install second annulus valve. No pressure on 9 5/8" csg MP RU lubricator. Pull BPV. Trouble pulling BPV. Ice on pulling tool. Steam plug. Pull BPV. RD lubricator and clear floor. MP RU circ lines. Test lines to 3,500 psi. MP Reverse circ out diesel. Flip lines pump DN TBG & displace well to 8.5 PPG SW. Verify well is dead. 0 Psi on TBG. 0 PSI on TBG ANN. MP Install TWC. Test from below to 1000 psi. Blow down all surface equipment. MP Rig down circ lines. MP ND Tree and adaptor flange. Check Tbg hanger threads and function lock down screws. MP NU BOP's. MP Change out 3 1/8" 5M manual choke line valve. MP RU test equip. Test all BOPE as per BP policy to 250 psi / 3,500 psi high w/ 3 1/2" & 4 1/2' test jts. No leaks. Test witnessed by Mike Whiteley - Co. Rep., Jim Henson -Tool pusher. MP Test all BOPE as per BP policy to 250 psi low and 3,500 psi high w/ 3 1/2" & 4 1/2" test jts. Test witnessed by Mike Whiteley - Co Rep., Jim Henson -Tool .pusher. RD test jt. Blow down. Reposition sub base over well. RU lubricator and extension. Pulled TWCV. RD lubricator. MU DP in tbg hanger. BOLDS. Pulled tbg hanger to floor. Pipe was free -string wt 100K. LD hanger. Well stable. RU handling tools /spooler. PJSM. POOH laying down total 55 jts 4 1/2" tubing. R/D control line spooler. R/U 3 1/2" TBG Equipment. UD 3 1!2" TBG Fl7057' Tl2350' UD 3 1/2"TBG F/2350' -Clear Floorof all handling equipment - 221 total 3 1/2" tbg -cut off piece 11.50'. 14:30 - 16:00 1.50 BOPSU P DECOMP M/U test Jt - RIH W /test plug, test top & bottom rams, test hydril 250 / 3500 PSI, pull test plug, run wear ring, UD test Jt. Test witnessed by John Rall - wellsite leader. 16:00 - 22:30 6.50 DHB P DECOMP PJSM. R/U wire line, RIH W/ 8.51" GR / JB to 9,000', POH, UD GR/JB, M/U & RIH W / 9 5/8" EZSV plug & CCL, set C~3 8,522' wire line depth, POH & R/D wireline. Printed: 10/31/2005 11:40:05 AM HMAN DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: C-10 Common W ell Name: C-10 Spud Date: 7/17/1979 Event Nam e: REENTE R+COM PLET E Start : 10/10/2005 End: 10/28/2005 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 10/28/2005 Rig Name: NABOB S 2ES Rig Number: Date , From - To Hours I' Task ~ Code NPT I Phase ~ Description of Operations 10/13/2005 22:30 - 23:30 1.00 DHB P DECOMP Test 9 5/8" csg to 3,500 PSI F/ 30 min. Held. Blow Down 23:30 - 00:00 0.50 STWHIP P WEXIT RU to PU window mill BHA / whipstock -tools to rig floor. 10/14/2005 00:00 - 03:00 3.00 STWHIP P WEXIT M.U. window milling BHA to 119'. Orient tools. Upload MWD. Shallow test @ 500 gpm. PU 9 5/8" whipstock. Orient UBHO sub. 03:00 - 04:30 1.50 STWHIP P WEXIT PU BHA - B.S., DC's, HWDP. 04:30 - 12:00 7.50 STWHIP P WEXIT RIH w/ whipstock /mill BHA picking up 4" DP. 12:00 - 12:30 0.50 STWHIP P WEXIT Service top drive, connect blower hose. 12:30 - 13:00 0.50 STWHIP P WEXIT Orient whipstock to 84 L. Tag plug @ 8,527'. Set BTM anchor - shear @ i8K and over puff 10K -Shear off Whipstock w 1 35K. 13:00 - 14:00 1.00 STWHIP P WEXIT Displace well W/ 10.2 PPG LSND mud, 504 GPM @ 2200 PSI. Take SPR's. 14:00 - 23:30 9.50 STWHIP P WEXIT Mill window in 9 5/8" csg f/ 8505 - 8522' and new hole to 8,527'.. UP 190K. DN 130K. RT 150K. TO off 7K, TO on 9K - 10.5K. Lube pump down on Top Drive. 23:30 - 00:00 0.50 STWHIP N RREP WEXIT Pull 1 stand DP to 8,452'. Trouble shoot Top Drive tube pump / motor. 10/15/2005 00:00 - 03:00 3.00 STWHIP N RREP WEXIT Service top drive. Replace lube pump & motor 03:00 - 03:30 0.50 STWHIP P WEXIT Mill open hole f/ 8,527 - 8,529'. Lube pump on TD failed. Rack back one stand in derrick. 03:30 - 04:30 1.00 STWHIP P WEXIT Cut and slip drilling line. 04:30 - 06:00 1.50 STWHIP N RREP WEXIT Trouble shoot electrical problem /repair tube pump motor on Top Drive. Remove cooling fan circuit. 06:00 - 07:00 1.00 STWHIP P WEXIT Milling open hole, F/8529' T18534 - 20' new hole. Recovered 225 LBS metal total - 9 5/8" window f/ 8,505' - 8,522'. 07:00 - 08:30. 1.50 STWHIP P WEXIT Circ Super Sweep, 500 GPM, 2370 PSI, worked window. 08:30 - 09:00 0.50 STWHIP P WEXIT Performed F.I.T. w/ 10.2 PPG mud to12.0 PPG EMW. 650 psi surface pressure. 09:00 -09:30 0.50 STWHIP P WEXIT Pumped Dry Job, Blow down surface equip. Remove blower hose. 09:30 - 10:30 1.00 STWHIP P WEXIT POOH f/ 8,534' to 6,645'. 10:30 - 12:00 1.50 STWHIP N RREP WEXIT Replace Draw works traction mtr brushes. 12:00 - 14:30 2.50 STWHIP P WEXIT POOH f/ 6,645' to 1,042'. 14:30 - 17:00 2.50 STWHIP P WEXIT C/O Elevators, Stand back HWDP f/ 1,042' to 373' L/D BHA f/ 373'. Down load MWD tools. Window mill 1/4" under gage, string mill full gage. Clear floor. 17:00 - 17:30 0.50 STWHIP P WEXIT Service Wear Ring 17:30 - 18:30 1.00 STWHIP P WEXIT Flush stack & surface equipment. Function blinds, upper & lower pipe rams. Clean drip pan. Blow down suface equip. 18:30 - 21:30 3.00 STWHIP P WEXIT M/U BHA 4o 75', Orient, upload MWD tools. Shallow test. Finish PU BHA. Change elevators. 21:30 - 00:00 2.50 STWHIP P WEXIT RIH PU DP f/ 817' to 3,156', fill pipe every 3000'. 10/16/2005 00:00 - 02:00 2.00 STWHIP P WEXIT RIH picking up 4" DP to 5,581'. 02:00 - 03:00 1.00 STWHIP P WEXIT RIH to 8,385'. 03:00 -03:30 0.50 STWHIP P WEXIT Service Top Drive. Connect blower hose. 03:30 - 04:00 0.50 STWHIP P WEXIT Orient 85L high side, SPR's, slide thru window@/8,505' - 8,522'. Tagg btm @ 8,534'. 04:00 - 11:30 7.50 DRILL P INTi Dir. Drill from 8,534' to 8,664' . AST= 3.74 hr, ART= 1.64 hr. Up 160K, DN 125K, RT 125K, TO 7K off, 9K ON - 3,050 psi @ 545 gpm. 11:30 - 12:30 1.00 N RREP INT1 Replace gasket on oil line by turbo. 12:30 - 13:00 0.50 DRILL P INTi Dir drill from 8,864' - 8,880'. AST=O hr, ART= .34 hr. Printed: 10/31/2005 11:40:05 AM BP EXPLORATION Operations Summary Report Page 3 of 7 Legal Well Name: C-10 Common Well Name: C-10 Spud Date: 7/17/1979 Event Name: REENTER+COMPLETE Start: 10/10/2005 End: 10/28/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/28/2005 Rig Name: NABORS 2ES Rig Number: Date From - To I Hours Task Code !! NPT I Phase ~~ Description of Operations 10/16/2005 13:00 - 14:00 1.00 DRILL N RREP INTi Weld crack on suction manifold #2 mud pump. 14:00 - 00:00 10.00 DRILL P INT1 Dir. drill f/ 8,880' - 9,032'. AST2.37 hr, ART= 3.2 hr, UP 165K 10/17/2005 ~ 00:00 - 00:00 ~ 24.00 ~ DRILL ~ P ~ ~ INT1 10/18/2005 00:00 - 01:30 1.50 DRILL P INT1 01:30 - 02:30 1.00 DRILL P INTi 02:30 - 03:30 1:00 DRILL P INT1 03:30 - 04:00 0.50 DRILL P INT1 04:00 - 04:30 0.50 DRILL P INT1 04:30 - 07:00 2.50 DRILL P INT1 07:00 - 11:30 4.50 DRILL P INT1 11:30 - 14:30 3.00 DRILL P INT1 14:30 - 15:30 1.00 CASE P LNR1 15:30 - 18:30 3.00 CASE P LNR1 18:30 - 19:30 1.00 CASE P LNR1 19:30 - 23:30 4.00 CASE P LNR1 23:30 - 00:00 0.50 CASE P LNR1 10/19/2005 00:00 - 01:00 1.00 CASE P LNR1 01:00 - 02:00 1.00 CASE P LNR1 02:00 - 03:30 1.50 CASE P LNR1 03:30 - 05:00 1.50 CASE P LNR1 05:00 - 05:30 0.50 CASE P LNR1 05:30 - 09:30 4.00 CASE P LNR1 09:30 - 11:30 2.00 DRILL P PROD1 11:30 - 14:00 2.50 DRILL N WAIT PROD1 14:00 - 15:00 1.00 DRILL P PROD1 15:00 - 19:00 4.00 DRILL P PROD1 DN 130K, RT 145K, TO off 6k, TO on 7k. 3,270 psi @ 540 gpm. Dir drill f/ 9,032' - 10,400' .ART= 11.08 hrs, AST= 3.37 hrs. Up 205K, 150k DN, 175K Rot, TO on 11.K, TO off 9k, 515 gpm @ 3,600 psi. Circ for samples for geologist - 10,400' TD. Pump hi vis sweep around and circ clean for wiper trip. 500 gpm - 3,500 psi. Observe well. Static. Wiper trip -POOH f/ 10,400' - 8,477'. No problems. Cut and slip drilling line. Inspect drawworks and brakes. Service top drive. RIH to 10,345'. No problems. Break circ and stage pumps up. Washed to btm @ 10,400'. No fill. Hole in good shape. Pump hi vis sweep around. Circ hole clean. Spot liner running pill. Pump dry job. 500 gpm 3,500 psi. UP 205K, DN 150K, RT 175K, TO off 10.5k. Blow down surface equipment. Monitor well, static. Drop drill pipe drift. POH from 10400' to 817'. UD BHA. Down load MWD tools. Clear rig floor. R/U to run 7"liner. P/U float equipment, check floats held. RIH with 7" 26# BTC-M liner to 2048'. M/U liner hanger and 10' pup and 1 stand of drill pipe to 2187'. Circ liner volume @ 5 bpm @ 250 psi. RIH from 2178' to 9 5/8" window @ 8505'. Break circ @ 930' intervals. Circ drill pipe volume @ 5 bpm @ 750 psi. Blow down top drive. RIH from 8505' to 10376'. Fill pipe & tag bottom @ 10400'. Stage pumps up to 6 bpm @ 1200 psi. PJSM with drill crew, Schlumberger & WSL. Mix cement. Pump 5 bbl of water, test lines to 4000 psi. Pump 30 bbl of mudpush @ 12 ppg followed by 35 bbl , 170 sx, class "G" cement @ 15.8 ppg. Wash lines through "T" on rig floor, drop wiper dart, displace with 160 bbl mud. Bump plug to 3500 psi, CIP @ 03:00. Set hanger, bleed off pressure, floats held. Release from liner, pressure up to 1000 psi and unsling. Pump 500 strokes @ 220 spm, slow pump and set down 50K to set packer, rotate down on packer, good surface indication. CBU, 12 bpm @ 3000 psi. No cement to surface. L/D cement head. Service top drive. POH for 6 1/8" drilling assy. UD liner running tool, clear rig floor. P/U 6 1/8" BHA, Hughes MXI8HDX bit, orient & upload MWD. Stop operations for Nabors management to discuss work issues with drill crews. P/U BHA, RIH with 1 stand of drill pipe & shallow test MWD tools. 275 gpm @ 1770 psi. Blow down top drive. RIH from 456' to 10313', fill pipe and check MWD tools @ 3000' intervals. Printed: 10/31/2005 11:40:05 AM BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: C-10 Common W eil Name: C-10 Spud Date:. 7/17/1979 Event Nam e: REENTE R+COM PLET E Start : 10/10/2005 End: 10/28/2005 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 10/28/2005 Rig Name: NABOB S 2ES Rig Number: ' ~ ~ I Date From - To Hours Task Code NPT Phase Description of Operations 10/19/2005 19:00 - 20:00 1.00 DRILL P PROD1 Test 7" casing & liner top packer, stage pump up to 3500 psi @ 1/2 bbl min, chart and hold for 30 min, OK. Blow down lines. 20:00 - 23:00 3.00 DRILL P PROD1 Drill float equipment and cement to 10395'. 23:00 - 00:00 1.00 DRILL P PROD1 Displace well to 8.4 ppg FloPro mud, pump @ 300 gpm @ 2400 psi. 10/20/2005 00:00 - 01:30 1.50 DRILL P PROD1 Displace well to 8.4 ppg FloPro mud @ 300 gpm @ 2200 psi. Take SPRs. 01:30 - 02:30 1.00 DRILL P PROD1 Drill cement & shoe @ 10400'. Drill 20' new formation to 10420'. Circulate. 02:30 - 03:00 0.50 DRILL P ~ PROD1 Perform F.I.T. to 10.0 ppg mud weight. OMW = 8.4 ppg, TVD = 8405'. Pressure up to 700 psi, bled off to 650 psi and held steady. EMW = 9.9 ppg. 03:00 - 00:00 21.00 DRILL P PROD1 Drilling 6 1/8" hole from 10420' to 11104'. AST = 8.97, ART = 6.60. UWT = 195K, DWT = 145K, RWT = 170K. Torque off bottom = 5K, on = 7K @ 60 rpm. Pump @ 277 gpm @ 185 psi. WOB = 15/20K. 10/21/2005 00:00 - 06:30 6.50 DRILL P PROD1 Drill 6 1/8" hole from 11104' to 11384'. UWT = 195K, DWT = 145K, RWT = 175K. WOB = 10K. Pump @ 277 gpm @ 1850 psi. Torque = 5K off bottom, 7K on. 06:30 - 08:00 1.50 DRILL P PROD1 Pump high vis sweep, circulate up sample for geologist. Pump @ 275 gpm @ 1960 psi. 08:00 - 08:30 0.50 DRILL P PROD1 POH from 11384' to 7" shoe @ 10400'. Hole in good shape. 08:30 - 09:00 0.50 DRILL P PROD1 Drop dart and open circ sub. Pump dry job. Blow down top drive. 09:00 - 13:00 4.00 DRILL P PROD1 POH from 10400' to 363'. Stand back drill collars & HWDP. 13:00 - 15:00 2.00 DRILL P PROD1 Flush MWD tools. L/D mud motor, clear rig floor. 15:00 - 18:30 3.50 DRILL P PROD1 PJSM. M/U BHA, orient, upload & surface test MWD. Install nukes. 18:30 - 22:30 4.00 DRILL P PROD1 RIH to 10388'. Fill pipe and test MWD @ 3000' intervals. 22:30 - 23:00 0.50 DRILL P PROD1 Service top drive and crown. Install top drive blower hose. 23:00 - 23:30 0.50 DRILL P PROD1 RIH from 10388' to 11384', wash down 70'. 23:30 - 00:00 0.50 DRILL P PROD1 MAD pass up from 11384' to 11319' @ 150 fph. 10/22/2005 00:00 - 05:00 5.00 DRILL P PROD1 MAD pass, log up from 11319' to 10870' @ 150 fph. Rotating @ 15 rpm, pump @ 260 gpm @ 1600 psi. Survey every stand for Casandra. 05:00 - 05:30 0.50 DRILL P PROD1 RIH from 10870' to bottom @ 11384'. Survey check shot. 05:30 - 00:00 18.50 DRILL P PROD1 Drill 6 1/8" hole from 11384' to 12009'. ART = 2.52 hrs, AST = 4.15 hrs. UWT = 195K, DWT = 135K, RWT = 165K. Torque = 6K off bottom, 8K on @ 25 rpm. Pump @ 275 gpm @ 1760/1950 psi. 10/23/2005 00:00 - 14:00 14.00 DRILL P PROD1 Drill 6 1/8" hole from 12009' to 12360'. AST = 3.87 hrs, ART = 2.85 hrs. Pump @ 275 gpm @ 1780/1920 psi. WOB = 5/10K. Torque = 7K otf bottom, SK on @ 80 rpm. UWT = 200K, DWT = 135K, RWT = 165K. Sliding, need left hand turn, difficult to slide and turn. Mix sweeps & beads. 14:00 - 16:00 2.00 DRILL P PROD1 Circ high vis sweep around, pump @ 275 gpm @ 1840 psi. 16:00 - 17:00 1.00 DRILL P PROD1 Short trip, POH from 12360' to 11350'. RIH, hole in good shape. 17:00 - 18:00 1.00 DRILL P PROD1 Pump high vis sweep and circ sweep up into 7 casing, spot liner running pill. 18:00 - 19:00 1.00 DRILL P PROD1 POH from bottom @ 12360' to 7" casing @ 10400'. 19:00 - 20:00 1.00 DRILL P PRODi Drop dart and open circ sub. CBU @ 462 gpm @ 1250 psi. Pump dry job, blow down top drive. Printed: 1073112005 11:40:05 AM BP EXPLORATION Operations Summary Report Legal Well Name: C-10 Common Well Name: C-10 Event Name: REENTER+COMPLETE Start: 10/10/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/28/2005 Rig Name: NABOBS 2ES Rig Number: Date From - To HoursTTask ;Code NPT I' 10/23/2005 20:00 - 21:00 1.00 DRILL P 21:00 - 21:30 0.50 DRILL P 21:30 - 00:00. 2.50 DRILL P 10/24/2005 00:00 - 01:30 1.50 DRILL P 01:30 - 05:30 4.00 DRILL P 05:30 - 06:00 0.50 CASE P 06:00 - 10:00 4.00 CASE P 10:00 - 15:30 I 5.50 {CASE I P 15:30 - 16:00 0.50 CASE P 16:00 - 17:00 1.00 CASE P 17:00 - 19:00 2.00 CEMT P 19:00 - 20:30 1.50 ~ CEMT ~ P 20:30 - 21:30 1.00 CEMT P 21:30 - 23:00. 1.50 CEMT P 23:00 - 00:00 I 1.001 CEMT I P 10/25/2005 100:00 - 04:30 I 4.501 CEMT I P 04:30 - 11:00 I 6.501 BOPSUFi P 11:00 - 12:00 1.00 TIEBAC P 12:00 - 13:00 1.00 PERFO P 13:00 - 16:00 I 3.001 PERFOBI P 16:00 - 20:30 I 4.501 PERFOB P 20:30 - 23:30 I 3.001 PERFOBI N 23:30 - 00:00 0.50 PERFO N 10/26/2005 00:00 - 04:30 4.50 PERFO N Phase PROD1 PROD1 PROD1 PROD1 PROD1 RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD PROD1 OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP DFAL OTHCMP DFAL OTHCMP DFAL OTHCMP Page 5 of 7 Spud Date: 7!17/1979 End: 10/28/2005 Description of Operations Slip and cut 98' drill line. Inspect drawworks. Service top drive POH from 10400' to 4317' for 4.5" liner. POH from 4317' to BHA @ 392'. PJSM. L/D HWDP, Jars & flex collars. PJSM. Remove sources from nukes. Flush MW D tools. Blow down top drive. Down load MWD. Break bit & UD mud motor. R/U to run 4.5" 11.6# L-80 LT & C production liner. PJSM. M/U shoe track, fill pipe and check floats, OK. RIH w/liner to 2155'. Fill pipe every 5 joints. Circ liner volume. Liner weight = 52K. RIH w/liner on drill pipe to 7" shoe @ 10400'. Fill pipe @ 930' intervals. Circ liner & drill pipe volume. Pump @ 5 bpm @ 580 psi. RIH to 12337'. M/U cement head. Break circ @ 2 bpm @ 550 psi, tag bottom @ 12360'. Stage pumps up to 6 bpm @ 1100 psi, reciprocate pipe & batch mix cement. UWT = 180K, DWT = 145K. Pump 5 bbl H2O, test lines to 4500 psi. Pump 15 bbls CW 100, 25 bbls MudPush XL spacer @ 10 ppg, followed by 55.2 bbls (265 sx) class "G" premium GasBlock cement @ 15.8 ppg. Wash lines up through "T" with pert pill. Drop wiper plug, pump remaining 40 bbls pert pill & displace w/mud. Total disp = 132 bbl. Bump plug w/4000 psi & set hanger. CIP @ 20:00 hrs. Bleed off pressure and check floats held, OK. Rotate and release from finer hanger. Pressure up to 1000 psi w/rig pump & unsting. Circ 30 bbl @ 11.5 bpm, slow pump & slack off 50K while rotating down to set packer X2. CBU @ 11.5 bpm @ 2300 psi. Trace of cement in returns. Displace well to seawater @ 11.5 bpm @ 2900 psi. Pump dry job. Blow down surface equipment, L/D cement head, clear rig floor. Clean shaker possum bellys and flow line. POH from 10225'. L/D liner running tool, pup jt, & XO. Clear rig floor. PJSM. M/U test joint, pull wear ring, install test plug & test BOPE to 250 low test & 3500 psi high, OK. R/D test equip, blow down lines & install wear ring. Test witnessed by John Crisp with AOGCC, Tool pusher &WSL Dick Maskell. R/U & test casing to 3500 psi for 30 min, OK. Blow down lines. R/U handling equip for 2 1/2" pert guns. PJSM with drill crew,perf crew &WSL. M/U perf guns and firing head to 789'. RIH P/U 2 7/8" PAC drill pipe to 2132'. Change out handling .equip. R1H from 2132' to 4.5" landing collar @ 12273'. Tag up and put perf guns on depth @ 12260'. UWT = 180K, DWT = 145K. PJSM. Break circ, Close annular preventor and pressure up on perf guns as per E-Fire procedure to fire ,guns, no success. Attempt to fire guns 4 times. R/U & reverse circ &circ. Attempt to fire guns w/100 psi higher pressure, no success. R/D & blow down lines. POH with perf guns from 12260'. POH with live perf guns from 12260' to 2132'. Printed: 10/31/2005 11:40:05 AM • BP EXPLORATION Operations Summary Report Legal Well Name: C-10 Common Well Name: C-10 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To Hours Task __II Code ' NPT 04:30 - 05:00 ~ 0.50 PERFOtf 10/26/2005 N DFAL 05:00 - 06:00 1.00 PERFO N 06:00 - 10:30 4.50 PERFO N 10:30 - 15:30 I 5.001 PERFOBI N 15:30 - 16:30 I 1.001 PERFOBI P 16:30 - 17:00 I 0.501 PERFOBI P 17:00 - 18:00 1.00 PERFO P 18:00 - 18:30 0.50 PERFO P 18:30 - 00:00 5.50 PERFO P 10/27/2005 00:00 - 01:30 1.50 PERFO P 01:30 - 03:30 2.00 PERFO~ P 03:30 - 07:30 4.00 PERFO P 07:30 - 11:00 I 3.501 PERFOB, P 11:00 - 11:30 0.50 11:30 - 14:00 2.50 14:00 - 00:00 I 10.00 10/28/2005 100:00 - 03:00 I 3.00 03:00 - 05:00 I 2.00 05:00 - 09:30 I 4.50 09:30 - 11:00 I 1.50 11:00 - 12:00 ~ 1.00 ~ BOPSUp P 12:00 - 14:00 2.00 BOPSU P 14:00 - 17:00 3.00 BOPSU 17:00 - 18:30 1.50 BOPSU P 18:30 - 21:30 3.00 BUNCO 21:30 - 22:00 0.50 22:00 - 23:00 1.00 DFAL DFAL DFAL Start: 10/10/2005 Rig Release: 10/28/2005 Rig Number: Page 6 of 7 Spud Date: 7/17/1979 End: 10/28/2005 Phase Description of Operations OTHCMP PJSM. Change out handling equip. R/U power tongs for 2 7/8" PAC pipe. OTHCMP POH with 2 7/8" PAC pipe to pert guns, 2133' to 790'. OTHCMP PJSM with drill crew, Schl pert crew & WSL. Bleed and break out firing head, dry. P/U 40 'and break top gun, dry, guns not flooded. UD firing head & down load. M/U new firing head, change out handling equipment. OTHCMP RIH @ 90 fpm from 2133' to L.C. @ 12273'. Put guns on depth, bottom shot @ 12260'. UWT = 180K, DWT = 145K. OTHCMP PJSM. Break circ. Close annular preventor. Pressure up on guns as per E-Fire procedure. Bleed off pressure & open annular preventor, fire guns. Good surface indication guns fired. Lost 3 bbl seawater to well. POH from 12260' to 11440'. OTHCMP Monitor well, static losses 7 bph. Pump dry job, blow down top drive. OTHCMP Slip and cut 76' drill line, service drawworks. OTHCMP Service top drive. OTHCMP POH LDDP from 11440' to 3348'. Well taking 7 bph. OTHCMP POH LDDP from 3348' to 2133'. OTHCMP C/O handling equipment. R/U power tongs & POH UD 2 7/8" PAC drill pipe to 790'. OTHCMP PJSM. C/O handling equipment. Pull firing head to rig floor. Break & UD disconnect & firing head. L/D shot guns. Clear & clean rig floor. OTHCMP M/U mule shoe, RIH with 32 stands of 4" drill pipe from derrick. POH LDDP. RUNCMP M/U test joint & pull wear ring. UD same. RUNCMP PJSM. Remove top drive saver sub. R/U to run 4.5" .chrome completion. RUNCMP M/U tail pipe/packer assy &RIH with 4.5" 12.6# 13Cr-80 Vam Top completion. Losses to well have slowed to 1 bph. Total seawater lost to well = 125 bbl. RUNCMP RIH with 4.5" 12.6# 13Cr-80 Vam Top completion, tag up on no-go @ 10230'. RUNCMP Space out, P/U 2 pup joints and place 1 joint down from hanger. Ran 238 joints of 4.5" 12.6# 13Cr-80 Vam Top tubing. M/U landing joint and land tubing, RILDS. RUNCMP R/U circ lines and reverse 156 bbl clean seawater. Pump 323 bbl inhibited seawater and displace w/161 bbl clean seawater @ 3 bpm @ 160psi. RUNCMP Drop 1 7/8" ball & rod, test tubing to 3500 psi for 30 min, OK. Bleed pressure to 1500 psi. Test annulus to 3500 psi for 30 min, OK. Bleed off tubing and pressure up annulus and shear DCR shear valve. RUNCMP Dry rod TWC valve .Test from below to 1000 psi. Blow down surface equipment. RUNCMP N/D BOPE. RUNCMP Install adaptor flange and tree. Test void & tree to 5000 psi. RUNCMP R/U DSM & pull TWC with lubricator. R/D DSM. RUNCMP R/U LRHOS, pressure test lines. Pump 151 bbl diesel freeze protect down annulus and U-tube. RUNCMP Dry rod BPV in & test from below to 1000 psi. RUNCMP Blow down lines and R/D LRHOS. Printed: 10/31/2005 11:40:05 AM Printed: 10/31/2005 11:40:05 AM Halliburton Sperry-Sun North Slope Alaska BPXA C-10A Job No. AKZZ3992155, Surveyed: 23 October, 2005 Survey Report 31 October, 2005 Your Ref.• API 500292037101 Surface Coordinates: 5960439.00 N, 664143.00E (70° 17' 53.6928" N, 148° 40' 14.3394" Y1~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 62.32ft above Mean Sea Level ~ ~ t ~-.~ ~ ~ ~ ~ ~ '~ ~ c ~ ~ Survey Ref: svy4684 A HaillburtanCOmpany • Halliburton Sperry-Sun Survey Report for C-10A Your Ref.' API 500292037101 Job No. AKZZ3992155, Surveyed: 23 October, 2005 North Slope Alaska Measured True 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) (°/100ft) 8500.35 54.530 145.650 6677.75 6740.07 3052.31 S 2304.41E 5957437.76 N 666513.53E 3799.56 Tie On Point MW D+I I FR+MS 8505.00 54.480 145.160 6680.45 6742.77 3055.42 S 2306.56E 5957434.69 N 666515.74E 8.646 3803.30 Window Point 8540.75 54.080 141.000 6701.33 6763.65 3078.62 S 2323.98E 5957411.88 N 666533.67E 9.513 3832.11 8569.37 53.900 139.000 6718.15 6780.47 3096.35 S 2338.86E 5957394.47 N 666548.94E 5.688 3855.22 8600.08 52.440 138.650 6736.56 6798.88 3114.86 S 2355.04E 5957376.33 N 666565.52E 4.841 3879.78 8633.79 50.230 137.880 6757.62 6819.94 3134.50 S 2372.56E 5957357.07 N 666583.46E 6.794 3906.08 8664.70 48.630 137.310 6777.72 6840.04 3151.83 S 2388.39E 5957340.08 N 666599.67E 5.362 3929.55 8692.80 46.860 138.570 6796.62 6858.94 3167.27 S 2402.33E 5957324.95 N 666613.94E 7.120 3950.34 8726.14 45.360 137.570 6819.73 6882.05 3185.15 S 2418.38E 5957307.43 N 666630.38E 4.991 3974.36 8756.48 43.740 137.240 6841.35 6903.67 3200.82 S 2432.79E 5957292.08 N 666645.12E 5.394 3995.64 8786.76 42.350 137.620 6863.48 6925.80 3216.04 S 2446.77E 5957277.17 N 666659.43E 4.670 4016.30 8818.67 41.440 138.670 6887.23 6949.55 3231.91 S 2460.99E 5957261.62 N 666673.99E 3.600 4037.60 8851.00 40.480 140.010 6911.65 6973.97 3247.98 S 2474.80E 5957245.85 N 666688.15E 4.025 4058.77 8879.97 39.440 142.130 6933.86 6996.18 3262.45 S 2486.49E 5957231.64 N 666700.16E 5.914 4077.31 8936.08 37.780 144.080 6977.70 7040.02 3290.44 S 2507.52E 5957204.11 N 666721.79E 3.668 4112.08 8974.17 37.270 145.200 7007.91 7070.23 3309.36 S 2520.94E 5957185.49 N 666735.63E 2.236 4135.04 9004.88 36.450 145.030 7032.48 7094.80 3324.47 S 2531.48E 5957170.61 N 666746.49E 2.691 4153.25 9037.85 35.710 145.070 7059.13 7121.45 3340.39 S 2542.60E 5957154.94 N 666757.96E 2.246 4172.44 9065.81 34.170 144.580 7082.05 7144.37 3353.48 S 2551.83E 5957142.06 N 666767.46E 5.599 4188.28 9096.59 32.750 144.730 7107.72 7170.04 3367.32 S 2561.64E 5957128.43 N 666777.58E 4.621 4205.08 9128.00 31.070 143.910 7134.39 7196.71 3380.81 S 2571.32E 5957115.16 N 666787.55E 5.524 4221.52 9158.84 29.340 142.550 7161.04 7223.36 3393.24 S 2580.61E 5957102.94 N 666797.11E 6.032 4236.92 9189.90 27.520 142.840 7188.35 7250.67 3405.00 S 2589.57E 5957091.38 N 666806.32E 5.876 4251.62 9220.68 25.800 143.540 7215.86 7278.18 3416.05 S 2597.85E 5957080.50 N 666814.84E 5.680 4265.34 9251.51 24.660 144.020 7243.75 7306.07 3426.65 S 2605.61E 5957070.07 N 666822.83E 3.757 4278.37 9286.01 23.290 144.180 7275.27 7337.59 3438.01 S 2613.83E 5957058.90 N 666831.30E 3.975 4292.26 9313.37 22.920 145.280 7300.44 7362.76 3446.77 S 2620.03E 5957050.27 N 666837.69E 2.078 4302.88 9343.68 22.440 144.100 7328.40 7390.72 3456.31 S 2626.79E 5957040.89 N 666844.65E 2.182 4314.45 9375.34 20.940 142.420 7357.82 7420.14 3465.69 S 2633.78E 5957031.66 N 666851.85E 5.127 4326.06 9406.64 19.230 140.710 7387.21 7449.53 3474.11 S 2640.46E 5957023.39 N 666858.71E 5.776 4336.76 9437.86 17.960 140.770 7416.80 7479.12 3481.82 S 2646.76E 5957015.82 N 666865.17E 4.068 4346.69. 9484.84 16.330 141.430 7461.70 7524.02 3492.60 S 2655.45E 5957005.24 N 666874.11E 3.494 4360.49 9531.47 15.790 141.480 7506.51 7568.83 3502.69 S 2663.49E 5956995.33 N 666882.36E 1.158 4373.34 9579.66 15.720 141.790 7552.88 7615.20 3512.95 S 2671.61E 5956985.25 N 666890.71E 0.227 4386.37 9625.46 16.170 142.380 7596.92 7659.24 3522.87 S 2679.35E 5956975.49 N 666898.65E 1.044 4398.89 BPXA • • 31 October, 2005 - 14:49 Page 2 of 5 DrillQuest 3.03.06.008 IHalliburton Sperry-Sun Survey Report for C-10A Your Ref.• API 500292037101 Job No. AKZZ3992155, Surveyed: 23 October, 2005 North Slope Alaska Measured Depth (ft) 9672.71 9718.45 9811.72 9905.46 9998.91 10093.85 10187.23 10281.93 10336.18 10426.79 10501.44 10548.83 10594.16 10642.80 10687.24 Incl. 16.000 15.620 16.550 16.620 16.390 16.180 16.210 16.120 15.560 15.480 15.820 17.830 19.650 19.660 19.580 True Azim 142.690 142.870 144.730 145.500 145.570 145.160 143.640 142.710 142.070 143.030 143:230 139.500 137.170 137.300 137.150 Sub-Sea Depth (ft) 7642.32 7686.33 7775.95 7865.79 7955.39 8046.52 8136.20 8227.15 8279.34 8366.65 8438.53 8483.89 8526.82 8572.62 8614.48 Vertical Depth (ft) 7704.64 7748.65 7838.27 7928.11 8017.71 8108.84 8198.52 8289.47 8341.66 8428.97 8500.85 8546.21 8589.14 8634.94 8676.80 10736 .74 18.800 138 .970 8661.23 8723 .55 10780 .52 20.460 139 .760 8702. 47 8764 .79 10812 .86 24.890 138 .550 8732. 30 8794 .62 10844 .62 29.270 136 .500 8760. 57 8822 .89 10875 .21 33.550 134 .870 8786. 67 8848 .99 10906 .91 37.680 132 .980 8812. 44 8874 .76 10937 .59 42.120 131 .400 8835. 97 8898 .29 10966 .51 46.270 129 .560 8856. 70 8919 .02 11000 .64 51.340 128 .900 8879. 17 8941 .49 11029 .92 54.540 127 .630 8896. 82 8959 .14 Local Coordinates Northings Eastings (ft) (ft) 3533.26 S 2687.31 E 3543.19 S 2694.85 E 3564.04 S 2710.10 E 3585.99 S 2725.40 E 3607.88 S 2740.42 E 3629.79 S 2755.55 E 3650.96 S 2770.71 E 3672.06 S 2786.52 E 3683.80 S 2795.55 E 3703.04 S 2810.29 E 3719.15 S 2822.38 E 3729.85 S 2830.96 E 3740.71 S 2840.64 E 3752.72 S 2851.75 E 3763.68 S 2861.89 E 3775.77 S 2872.76 E 3786.94 S 2882.34 E 3796.36 S 2890.50 E 3807.01 S 2900.27 E 3818.40 S 2911.42 E Global Coordinates Northings Eastings (ft) (ft) 5956965.28 N 666906 .84 E 5956955.52 N 666914 .59 E 5956935.00 N 666930 .30 E 5956913.39 N 666946 .07 E 5956891.84 N 666961 .57 E 5956870.27 N 666977 .18 E 5956849.43 N 666992 .80 E 5956828.67 N 667009 .06 E 5956817.14 N 667018 .35 E 5956798.22 N 667033 .50 E 5956782.38 N 667045 .94 E 5956771.88 N 667054 .75 E 5956761.23 N 667064 .67 E 5956749.46 N 667076 .04 E 5956738.73 N 667086 .41 E 5956726.87 N 667097 .55 E 5956715.92 N 667107 .37 E 5956706.68 N 667115 .73 E 5956696.25 N 667125 .73 E 5956685.10 N 667137 .12 E Dogleg Vertical Rate Section Comment (°/100ft) 0.403 4411.91 0.838 4424.29 1.140 4449.92 0.246 4476.36 0.247 4502.58 0.252 452$.87 0.455 4554.66 0.289 4580.84 1.081 4595.57 0.297 4619.67 0.461 4639.67 4.812 4653.33 4.341 4667.88 0.092 4684.24 0.213 4699.16 1.986 4715.42 3.840 4730.11 13.773 4742.56 14.099 4757.01 14.263 4772.95 3831 .19 S 2924. 72E 5956672.61 N 667150.70E 13.482 4791.38 3844. 39 S 2939. 30E 5956659.72 N 667165.57E 14.843 4811.00 3857 .47 S 2954. 64E 5956646.99 N 667181.19E 15.018 4831.05 3873 .70 S 2974. 53E 5956631.19 N 667201.43E 14.926 4856.52 3888 .16 S 2992. 88E 5956617.13 N 667220.09E 11.464 4879.65 11059.89 57.640 126.990 8913.53 8975.85 3903.24 S 3012.66E 5956602.50 N 667240.20 E 11091.18 61.500 126.140 8929.38 8991.70 3919.30 S 3034.33E 5956586.91 N 667262.21 E 11125.39 66.310 126.620 8944.42 9006.74 3937.52 S 3059.05E 5956569.23 N 667287.33 E 11153.28 70.570 126.470 8954.67 9016.99 3952.96 S 3079.89E 5956554.25 N 667308.49 E 11183:97 75.150 125.620 8963.71 9026.03 3970.21 S 3103.60E 5956537.52 N 667332.57 E 11215.66 79.700 124.190 8970.61 9032.93 3987.90 S 3128.96E 5956520.39 N 667358.31 E 11246.00 83.450 122.860 8975.05 9037.37 4004.47 S 3153.97E 5956504.37 N 667383.68 E 11277.90 87.900 122.650 8977.46 9039.78 4021.68 S 3180.72E 5956487.75 N 667410.80 E 11309.01 92.720 120.670 8977.29 9039.61 4038.00 S 3207.19E 5956472.01 N 667437.62 E 11337.69 95.380 114.140 8975.26 9037.58 4051.16 S 3232.57E 5956459.41 N 667463.28 E 10.494 12.556 14.117 15.282 15.156 15.018 13.098 13.965 16.749 24.530 4904.20 4930.78 4961.02 4986.57 5015.42 5045.72 5074.97 5105.87 5135.95 5162.98 BPXA • C7 31 October, 2005 - 14:49 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for C-10A Your Ref: API 500292037101 Job No. AKZZ3992155, Surveyed: 23 October, 2005 North Slope Alaska BPXA Measured True 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) (°/100ft) 11365.05 94.940 111.690 8972.80 9035.12 4061.77 S 3257.66E 5956449.35 N 667488.60E 9.062 5187.97 11412.43 94.450 109.400 8968.92 9031.24 4078.34 S 3301.88E 5956433.75 N 667533.17E 4.927 5230.46 11458.46 93.640 108.120 8965.68 9028.00 4093.11 S 3345.35E 5956419.94 N 667576.96E 3.285 5271.14 11505.21 93.030 109.020 8962.96 9025.28 4107.97 S 3389.59E 5956406.04 N 667621.51E 2.323 5312.41 11550.59 92.590 107.870 8960.73 9023.05 4122.31 S 3432.59E 5956392.65 N 667664.81E 2.710 5352.44 11597.85 91.170 107.370 8959.18 9021.50 4136.61 S 3477.61E 5956379.33 N 667710.13E 3.185 5393.84 • 11644.62 90.620 107.210 8958.45 9020.77 4150.51 S 3522.26E 5956366.41 N 667755.07E 1.225 5434.70 11674.82 88.770 108.750 8958.61 9020.93 4159.83 S 3550.98E 5956357.72 N 667783.99E 7.970 5461.26 11705.70 87.840 109.230 8959.53 9021.85 4169.87 S 3580.17E 5956348.32 N 667813.39E 3.389 5488.66 11736.09 89.440 111.810 8960.25 9022.57 4180.52 S 3608.62E 5956338.29 N 667842.07E 9.987 5515.99 11785.46 90.310 115.600 8960.36 9022.68 4200.37 S 3653.81E 5956319.44 N 667887.69E 7.876 5561.53 11831.49 89.690 116.920 8960.36 9022.68 4220.73 S 3695.09E 5956299.98 N 667929.40E 3.168 5604.74 11876.37 89.010 117.310 8960.86 9023.18 4241.19 S 3735.04E 5956280.41 N 667969.78E 1.747 5647.10 11924.26 90.620 117.150 8961.02 9023.34 4263.10 S 3777.62E 5956259.43 N 668012.83E 3.378 5692.33 11970.79 92.160 116.860 8959.89 9022.21 4284.22 S 3819.06E 5956239.22 N 668054.72E 3.368 5736.21 12018.40 91.910 112.640 8958.20 9020.52 4304.13 S 3862.26E 5956220.25 N 668098.35E 8.874 5780.42 12052.20 91.230 109.760 8957.27 9019.59 4316.35 S 3893.76E 5956208.73 N 668130.11E 8.752 5810.99 12083.61 91.050 108.410 8956.65 9018.97 4326.62 S 3923.43E 5956199.11 N 668160.00E 4.335 5838.89 12112.22 89.510 108.450 8956.51 9018.83 4335.66 S 3950.57E 5956190.66 N 668187.33E 5.385 5864.16 12157.19 89.260 108.610 8956.99 9019.31 4349.95 S 3993.21E 5956177.30 N 668230.27E 0.660 5903.91 12205.74 88.520 107.040 8957.93 9020.25 4364.81 S 4039.42E 5956163.46 N 668276.79E 3.574 5946.54 12251.31 88.390 106.030 8959.16 9021.48 4377.78 S 4083.09E 5956151.45 N 668320.73E 2.234 5986.04 12297.07 87.900 105.770 8960.64 9022.96 4390.31 S 4127.08E 5956139.88 N 668364.98E 1.212 6025.45 12312.32 87.650 105.350 8961.23 9023.55 4394.39 S 4141.75E 5956136.12 N 668379.75E 3.203 6038.53 12360.00 87.650 105.350 8963.19 9025.51 4407.01 S 4187.70E 5956124.51 N 668425.95E 0.000 6079.35 Projected Survey All data is in Feet (US Su rvey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Refe rence . Northings and Eastings are relative to Well Reference . Global Northi ngs and Eastings are relati ve to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 1 00 feet (US Survey). Vertical Sect ion is from Well Reference and calculated along an Azimuth of 136.400° (True). Based upon Minimum Cu rvature type calculations, at a Measured Depth of 12360.OOft., The Bottom Hole Displacement is 6079. 35ft., in the Direction of 136.462° (True). 31 October, 2005 - 14:49 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for C-10A Your Ref.• API 500292037101 Job No. AKZZ3992155, Surveyed: 23 October, 2005 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 8500.35 6740.07 3052.31 S 2304.41E Tie On Point 8505.00 6742.77 3055.42 S 2306.56E Window Point 12360.00 9025.51 4407.01 S 4187.70E Projected Survey BPXA • Survey tool program for C-1OA From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 8500.35 6740.07 To Measured Vertical Depth Depth (ft) (ft) 8500:35 6740.07 12360.00 9025.51 Survey Tool Description BP Conventional Gyro - GYD-CT-CMS (C-10) MWD+IIFR+MS (C-10A} • 31 October, 2005 - 14:49 Page 5 of 5 DrillQuest 3.03.06.008 TREE = 6" CM/ WELLHEAD = 13-518" 5M FMC ACTUATOR = _~~ KB ELEV = OTIS _ ~. 6L9T BF. ELEV = 34.97' KOP = . . ~ 3100' ~,~ ~. -_... -.m. . Max Angle = 92 @ 11309' -Datum MD = 11546' Datum TV D = 8800' SS • _~ ~ C -1 flA 13-3/8" CSG, 72#, L-80, ID = 12.347" 2666' Minimum ID = 3.725" ~ 10220' 4-1/2" HES XN NIPPLE TOP OF WHIPSTOCK `?`?°? 9-5/8" EZSV TOP OF CEMENT (09!24/05) 9-5/8" CSG, 47#, N-80, ID = 8.681" ~-~ 10831' 2585' 9-5-L /8" DV I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3008 3008 6 MMG DOME RK 16 11!02/05 3 5533 5013 53 MMG SO RK 20 11!02/05 2 7876 6393 55 MMG DMY RK 0 10/28/05 1 9792 7820 16 KGB2 DMY BK 0 10/28/05 8328' 9-5/8" X 7" BKR ZXP LTP w /TIEBACK SLV, ID = 6.30" 8345' 9-518" X 7" BKR HMC LNR HNGR, ID = 6.23" MiLLOUT 9-5/8" WINDOW 8505' - 8522' 10158' -i4-1/2" HES X NIP, ID = 3.813" 1017$' 7" x 4-112" BKR S-3 PKR, ID = 3.875"' 10201' - 4-112" HES X NIP, iD = 3.813" 10220' 4-1/2" HES XN NIP, ID = 3.725" 10225' 7" X 5" BKR ZXP LTP w / TIEBACK SLV, ID = 4.40" 10233' 4-1/2" WLEG, ID = 3.958" -~--~ ELMD TT NOT LOGGED ,. 10243' 7" X 5" BKR HMC LNR HNGR, ID = 4.410" 10250' S" X 4-112" xo, ID = 3.950" 7" LNR, 29#, L-80 , ID = 6.184" ~-~ 12060' ~ rUtinnnnnnra / 4-1/2" TBG, 12.6#, 13CR80 TCII, .0152 bpf, ID = 3.958" 10233' PERFORATION SUMMARY RLt:. i_~,: CBL%4:h~ o€ 3 . ;%t ANGLE AT TOP PERF: 93 @ 11500' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 11500 - 12260 O 10126/05 S NOTES: ***4-1 /2" CHROMETBCd`** 2190' I-~4-1/2" HES X NIP; lD = 3.813" 7" LNR, 26#, L-80 BTGM, ~ 10400' .0383 bpf, ID = 6.276" PBTD 12274' 4-1i2" LNR, 12.6#, L-80 IBT, .0152 bpf, ID = 3.958" 12360' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/10/79 ORIGINAL COMPLETION 03/24/90 RWO __ __ ___ 10129(05 CRM SIDETRACK (G10A) 11/02105 " GLV C/O 11109/05 i ' DRLG DRAFT CORRECTIONS PRUDHOE BAY UNfT WELL: G10A PERMff No: 2051370 AP1 No: 50-029-20371-01 775' SNL & 1222' WEL, Sec. 19, T11 N, R14E BP F~cploration {Alaska) • ~ 02-Nov-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C-10A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,500.35' MD Window /Kickoff Survey: 8,505.00' MD (if applicable) Projected Survey: 12,360.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~~ ~~~ 4~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~, Ub~`~~~ ~r~/~ CJ • 02-Nov-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C-10A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,500.35' MD Window /Kickoff Survey: 8,505.00' MD (if applicable) Projected Survey: 12,360.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 iJ ~ ^ ~ / / , Date ~ f ty~~~3 Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~, iZ 1 -l )1 I ~`i ~~ • P, 1 ~ ~ ~ 7 ~ ~ ~ ~ 9 ~ ~ ryh~- Y ~ ~ 41 J q~ ~y ~ ,~ `' j3 ,~~ ; ~~.~ Jy yg ~~ ~ J7~^+ ~ ~ f °ai ,~ )~7 ~ ~i i /~ yy°°' ALASKA OIL A11TD GAS COI~TSERQA'TI011T COril-IISSIOIQ Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 r FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: PBU C- l0A BP Exploration (Alaska) Inc. Permit No: 205-137 Surface Location: 775' FNL, 1222' FEL, SEC. 19, T11N, R14E, UM Bottomhole Location: 5141' FNL, 2955' FWL, SEC. 20, Tl 1N, R14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petrol m field inspector at (907) 659- 3607 (pager). K. DATED this day of September, 2005 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. t,~t~r~, ~ 1 ~~ f v-~os STATE OF ALASKA ~ ALASKA\OL AND GAS CONSERVATI N ~ 1 O COaSION PERMIT TO DRILL 20 AAC 25.005 - 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 ~ 11. Well Name and Number: PBU C-10A Q,/~ os 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD 12356 ~ TVD 9028 12. Field / Paol(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: . , 775' FNL 1222' FEL SEC 19 T11N R14E UM 7. Property Designation: ~ ADL 028305 Pool , , . , , , Top of Productive Horizon: 4482' FNL, 1557' FWL, SEC. 20, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 10, 2005 Total Depth: 5141' FNL, 2955' FWL, SEC. 20, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 31,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664143 ~ y- 5960439 ~ Zone- ASP4 10. KB Elevation (Height above GL): 70.8' feet 15. Distance to Nearest Well Within Pool C-12A offset 800' at 10671' MD 16. Deviated,Wells: Kickoff Depth: 8500 -feet Maximum Hole Angle: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3200 ~ Surface: 2304 ' 1 asing rogram: Size Spec cations Setting Depth To $ottom uanttty o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 2041' 8350' 6664' 10391' 8406' 197 cu ft Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2065' 10291' 8311' 12356' 9028' 99 cu ft Class'G' 19. PRESENT W ELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 12060 Total Depth TVD (ft): 9217 Plugs (measured): N/A Effective Depth MD (ft): 12017 Effective Depth TVD (ft): 9186 Junk (measured): N/A Casing Len th Size Cement Voiume MD TVD r r C n for 110' 20" x 30" 12.9 cu ds Permafrost Concrete 110' 110' 2666' 13-3/8" 492 cu ft Arcticset 2666' 2666' r Pr d ti 10831' 9-5/8" 1589 cu ft Class 'G', 130 cu ft AS I 10831' 8381' 1744' 7" 20 cu ft Class 'G' 10316' - 12060' 8019' - 9217' Perforation Depth MD (ft): 11620' - 11818' Perforation Depth TVD (ft): 8911' - 9047' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission. Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jeff Cutler, 564-4134 Printed Name ve Wesley Title Senior Drilling Engineer i Prepared By Name/Number. Si nature ,! ~~~ Phone 5645153 Date ~ /.S~~S Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ~~ ° / ~'7 API Number: 50- 029-20371-01-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples quired ^ Yes ~No Mud Log Required ^ Yes ~No Hydr en (fide Measures j~Yes ^ No Directional Survey Required. ,Yes ^ No Other: ~-~~ S ~~ ~ ~~ ~ D ~~ ~ ~ ~, ~~ ~ ~' s s C ~~ C I ~ ~ ~.l ~e~-°vL~.~~ t3~ 1~ ~ ~ ~d fe sf ~~ cc~d r~~ u ~~ ~~~~ ~ro v' APPROVED BY ~~ A roved THE COMMISSION Date ~l. Form 10-4 is 20 ~ r ubmit n Duplicate ~ • Well Name: C-10A Planned Well Summary Horizontal Well C-10A Well Sidetrack Target Zone 2 Type Producer Objective AFE Number: PBD4P2401 API Number: 50-029-20371-01 Surface Northin Eastin Offsets TRS Location 5,960,439 664,143 775' FNL / 1222' FEL 11 N, 14E, 19 Target Northin Eastin Offsets TRS Location 5,.956,795 667,016 798' FSL / 1557' FWL 11 N, 14E, 20 Bottom Northin Eastin Offsets TRS Location 5,956,167 668,430 138' FSL / 2955' FWL 11 N, 14E, 20 Planned KOP: 8,500' and / 6,752' tvd Planned TD: 12,356' and / 9,028' tvd Ri Nabor E CBE: 42.26' RTE: 70.8' Directional Program A roved Well tan: Wp03 Exit oint: 8,500' and / 6,752' tvd Maximum Hole Inclination: ~92° in the tanned 6 1/8" roduction section. C-25 is the only close approach issue with this well. Gyro surveys will be run Proximity Issues: in the C-10 parent well bore pre-rig to reduce directional uncertainty. After gyro surveys are run another proximity scan will be conducted and Wp04 will be enerated with corrected surve s. Survey Program: Standard MWD. Nearest Well within ool: Well C-12A, with center-to-center distance of 800' C~ TSAD, 10,671' md. Nearest Pro ert Line 31,500' North to unit bounda C-10A Sidetrack Page 1 ~ • Longing Program Hole Section: Required Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR/Res/PWD throu hout the interval 6 1/8" production: Real time MWD Dir/GR/Res/ABI throughout the interval. Pick up Den/Neu after - landing to log lateral section, MAD pass to 100' above PGOC prior to drilling lateral. Two sam le catchers. Cased Hole: None Planned O en Hole: None tanned Mud Program Hole Section / o eration: Mill window in the 9 5/8" casin T e Densi Viscosit PV YP API FL HTHP H LSND 10.5 ~ 50 - 60 15 - 22 30 - 40 <6.0 <11 9.0 - 9.5 Hole Sectio .o eration: Drillin 8 1/2" interval from 8528 to section TD T e Densit ~ Viscosit PV YP API FL HTHP H LSND 10.5 10.7` 42-52 18-25 22-28 <5.0 <11 9.0-9.5 ~~_.~ Hole Section / o eration: Drillin 6 1/8" roduction interval T e Densi LSRV PV YP API FL LSRV H FloPro SF 8.4 - 8.6 ~ >25,000 8 -15 24 - 30 4 - 6 >25,000 9.0 - 9.5 Casina /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8 1/2" 7" 26.0# L-80 BTC-M 2,041' 8,350' / 6,664' 10,391' / 8,406' 6 1/8" 4'/z" Solid 12.6# L-80 IBT-M 2,065' 10,291' / 8,311' 12,356' / 9,028' Tubin 41h" 12.6# 13-Cr VamTo 10,295' Surface 10,295' / 8,311' N©T~f. This It is p ned ' h the ~nimu al , 100' f' r lap, a T' I be at .near e n to of the g Riv ,but the nned plat' ,the ker to ' ' die w' mo t I' ely ex ed the ' li as AA 5.41 b) but fees n . A v to 20 C 5.4 . b} al 'ng a cker inject' zone nc f 300' r ue ed. ~ ~ ~, p~- Cementing Program Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner Slurry Design Basis: Lead slurry: None planned. Tail slurry: 1,000' of 7" X 8-1/2" annulus with 40% excess, 85' of 7", 26# shoe track. Pre-Flush None tanned Fl id S /V l S acer 35 bbls MudPUSH at 12.0 s u equence o ume: Lead Slur None tanned ,~'~~ -~-~ Tail Slur 35 bbl / 197 cf 170 s Class `G', 15.8 .16 sk. ~- :~f C-10A Sidetrack Page 2 • • Casin Strin 4'h", 12.6#, L-80, IBT-M Production Liner Lead slurry: none planned Slurry Design Basis: Tail slurry: 1965' of 4-~/z" X 6-%a" annulus with 40% excess, plus 85' of 4-'/z", " ' " " ' " 12.6# shoe track, plus 100 of 7 X 4-1/z liner lap, plus 200 of 7 X 4 drill pipe annulus. Pre-Flush 5 bbls CW 100 Fl id S /V l S acer 20 bbls MudPUSH at 9.6 u s equence ume: o Lead Slur None tanned Tail Slur 53.8 bbl / 298.7 ft / 255 s Class `G', 15.8 .17 /sk. ~' Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" Casin Bride lu to surface 30 min recorded 3,500 si surface 9 5/8" Casin window 20' new formation be and FIT 12.0 EMW 7" Casin Float a ui ment to surface 30 min recorded 3,500 si surface 7" Casin shoe 20' new formation be and FIT 10.0 EMW 4 ~/z" roduction liner Float a ui ment to surface 30 min recorded 3,500 si surface Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum antici ated BHP: 3,100 si at 8,406' TVD. Maximum surface ressure: 2,2 - Si (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: fini with 12.0 EMW FIT Planned BOPS test ressure: si low / 3,500 si hi h - 7 da test c cle Pre drillin hase ROPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams drilling liner. while running 2,041' of 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This confi uration rovides two sets of em to able rams, rather than one. Well Interval: 6 1/8" roduction interval Maximum antici ated BHP: 3,200 si at 8,964' TVD Maximum surface ressure: 2 4 SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: fini with 10.0 p EMW FIT. Planned BOPE test ressure: si low / 3,500 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.4 seawater / 6.8 Diesel BPXA requests a variance to the provisions of 20 AAC 25.035. (e){10)C regarding the function pressure % test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exceut when the routine use of BOP ram type equipment may have tximpromised their effectiveness. (Example would be when pipe rams are .inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity o€ the BOP equipment. C-10A Sidetrack Page 3 ~ ~ Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Formation MD TVDbkb TVDss Comments CM1 7626 6253 6190 Above KOP in original weltbore THRZ 9448 7506 7443 TJD 10004 8037 7974 TJB 10207 8231 8168 Sa River 10391 8406 8343 Possible Hydrocarbons TSAD 10511 8521 8458 Possible Hydrocarbons TCGL 10687 8687 8624 Possible Hydrocarbons BCGL 10775 8771 8708 Possible Hydrocarbons 23SB 10815 8808 8745 Possible Hydrocarbons 22TS 10904 8885 8822 Possible Hydrocarbons, est. pore pressure 3200 psi 21TS 10990 8947 8884 Possible Hydrocarbons TZ1 B 11180 9030 8967 Possible Hydrocarbons HOT 11210 9035 8972 BSAD 9096 9033 Below TD TD Criteria: I TD as per directional plan unless drilling conditions deteriorate to the point further progress is unfeasible Oaerations Summar Current Condition: / SI since early 2005. / 4-1/2" X 3-1/2"completion. / 03/08/05 Weatherford WRP set at 10,316' MD. / 02/22/05: Caliper 4.5" 51 jts 0-40%, 8 jts 40-72%; 3.5" 298 0-40%, 15 jts 40-85%, hole in pup above GLM #5 012976' and & hole in jt above btm stradl pkr @ 11,772' md, DGLV in sta #5 & OA tracking /A with approximately a 100 psi per day rise. / 4-1/2"Otis SSSV set at 2,125' MD $COpe * Notify the field AOGCC representative with intent to plug and abandon Pre-Rig Operations: 1. Replace all live Gas Lift valves with Dummy valves and fluid pack as necessary for CT P&A. 2. R/U SL, pull WRP set at 10,316', drift to tbg tail at 11,784'. 3. R/U a-line and run gyro surveys to 12,017'. iQ~Q fG.9~p ~.~ ~. zi~~' C-10A Sidetrack Page 4 s ~ 4. RIH with CT and P&A the C-10 well bore. Pump 30 bbls of 15.8 ppg Class G cement, calculated on: 234' of 7", 29# liner from 11,783' to 12,017' and 1783' of 3-'/z", 9.2# tubing from 11,783' to top of cement at 70,000'. Attempt to squeeze ~5-6 bbls of cement into the open perfs 5. RIH with the appropriate jet cutter and cut the 3-'/z" tubing at --9,300' MD. 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' MD with diesel. 7. Test the 9 5/" pack-off and tubing hanger seals to 5,OOOpsi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 8. Bleed casing and annulus pressures to zero. 9. Set a BPV. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displa a well to seawater. Set BPV. 3. Nipple down tree. Nipple up and test BOPE to ,5 si. - 4. Pull 4-~/2" X 3-~/z" tubing from the cut at ~9,300j. D, 4-'/z" X 3-'h" XO at 2,267. 5. R/U E-line. M/U 8.5" gauge ring /junk basket / CCL. RIH and tag tubing stump. POH. 6. RIH with HES EZSV on E-line. Set bridge plug at 8,524', as required to avoid cutting a casing collar while milling the window. POH. R/D E-line. 7. Pressure-test the 9 5/a" casing to 3,500 psi for 30 minutes. Record test. 8. U and RIH with 9-S/a" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 10.5 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. ~ ~IuS 1b ~~ I10. Mill window in 9-5/8" casing at ± 8,500' MD, plus approximately 20' beyond middle of window. Circulate ~~Iro~i~-~ - well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POH. 12. M/U 8~/z" Dir/GR/Res assembly. RIH, kick off and drill the 8-'/z" intermediate section to the top of the ' Sag River, per directional proposal. Circulate well clean, short trip to window. POH. 13. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 14. M/U 6-'/8" Dir1GR/Res assembly with 'l$" insert bit. RIH to the landing collar. 15. Test the 9 5/8" casing X 7" liner to 0 si for 30 minutes. Record the test. ~` 16. Drill out the 7" liner float equipm d cement to the shoe. 17. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead through Zone 3 and the 15° dogleg build section. 19. POH and PU a 6-%e" PDC bit with a DIR/GR/Res/ Den/Neu assembly. ~ 20. RIH and drill ahead to TD 21. Circulate well bore clean, POH to shoe, circulate, if hole hole conditions indicate it is necessary RIH to TD for a short trip. POH mad passing as required for Den/Neu log data. 22. Run and cement 4-'/z", 12.6#, L-80 solid production liner. POH. / 23. RIH with 2-7/8" pert guns and perforate ±400'. 24. R/U and run a 4-~/z", 12.6#, 13-Cr, VamTop completion, stinging into the 4-~/2" liner tie back sleeve. ~- 25. Set a TWC. 26. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 27. Pull TWC, freeze protect to 2,200' TVD. 28. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. /~ 29. Set BPV, secure well 30. Rig down and move off. Post-Riq Operations: 1. MIRU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. C-10A Sidetrack Page 5 ~ ~ Job 1: Move In / Rig Up /Test ROPE Planned Job Time Planned Job Cost 54 hours $176,000 Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - C-33 is 74' to the North and will not require shut-in for the rig to move onto C-10, check the spacing and alert the pad operator prior to moving onto the well. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the C-10 well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the C-10 well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. - C-Pad is not designated as a H2S site. Standard Operating Procedures for H2S precautions ~ should beTolTowed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading C-33 No Data C-27 10 ppm C-09 No Data C-12 No Data The maximum level recorded of H2S on the pad was 10 ppm in well C-26 on 10/22/2000. ~ - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Job 2: De-complete Well __ Planned Job Time Planned Job Cost 49 hours $170,000 Reference RP :• "De-completions" RP Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. C-10A Sidetrack Page 6 • - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a 13-5/8" FMC. Check with FMC to ensure all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - There is a 4-~/z" Otis HXO BVN SSSV set at 2125'. Historical well files show the SSSV was run with a dual encapsulated control line. 28 rubber and 3 stainless steel bands were initially run on the control line. - Run GR/CCL Log from the bridge plug setting depth to surface after setting the EZSV. Job 3: Run Whiu Stock Planned Job Time Planned Job Cost 38 hours $238,000 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - The 9-5/8" casing was cemented with 1382 sxs (1589 ft3) 15.8 ppg Class G cement. Calculated cement top in gauge hole is 5,757', cement is expected behind the 9-5/8" casing at the KOP. - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Job 5: Drill 8-1/2" Intermediate Hole Interval Planned Job Time Planned Job Cost 76 hours $407,000 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - Tie MWD - GR back to PDC log from parent wellbore. - For this well, the HRZ will require a mud weight of 10.5 ppg. Maintain mud weight at 10.5 ppg, after milling window to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: I worst-case scenario of 7.1 ppg pore pressure at the Sag River depth, a fracture gradient 12. ppg at the 9-5/8" casing window, and 10.5 ppg mud in the hole, the kick tolerance is i finite: - The above kick tole nce is based on an FIT of 12.0 ppg EMW, if this is not reached contact the ODE C-10A Sidetrack Page 7 ~ ~ Job 6: Run and Cement 7" Intermediate Casing Planned Job Time Planned Job Cost 24 hours $145,000 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab/surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Job 7: Drill 6 1/8" Production Hole Interval Planned Job Time Planned Job Cost 119 hours $675,500 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - The geologic polygon is designed to land the well in the HOT in Zone 2A, then geosteer to 5' above the HOT. - C-10A is expected to cross a single, small fault at 10,975' to 11,125' MD, 8850' to 8950' TVD. ' - The throw is estimated at X10', losses are not expected. Job 9: Run 4~h" Production Liner Planned Job Time Planned Job Cost 18 hours $178,000 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4'/z", 12.6#, L-80, IBT-M solid liner throughout the production interval. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be ~680psi over balanced to the Ivishak Zone 2 formation. Minimize the time the pipe is left stationary while running the liner. C-10A Sidetrack Page 8 • • - Sufficient 4-~/z" liner will be run to extend 100' back up into the 7" liner shoe. - Ensure the 4-~h" liner top packer is set prior to POH. Job 10: DPC Perforate Well Planned Job Time Planned Job Cost 30 hours $229,000 Hazards and Contingencies - The production interval of the well will be DPC perforated prior to running the completion. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with pert guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach tag the landing collar due to cement/fill. Reference RPs • DPC Perforating RP • Schlumberger DPC Perforating Guidelines Job 12: Run 4 ~h" 13-Cr Completion Planned Job Time Planned Job Cost 24 hours $436,000 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 Asia at 100° F. - The completion, as designed, will be to run a 4'/2", 12.6#, 13-Cr, VamTop production tubing string, stinging into the 4'/i" liner tieback sleeve. Job 13: ND/NU/Release Rig Planned Job Time Planned Job Cost 12.0 hours $44,000 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off of C-10A. However, C-33 is 74' to the North. This is the closest neighboring well. Care should be taken while moving off from the well. Spotters should be employed at all times. C-10A Sidetrack Page 9 ~ it 6500 I ~ ' ' - 85W' ! 700 I 19 ', I i 7500 =~- ~_ ! ~- L a c 800 _ Ii' j ~ F i-~~ I kI~.Fl~:kt:NCl: INP(1kh1A'IIUN SUR\'fY PRlki1GU1 N'ellpath: (C-111, Plan C'-IOA) C'uoNiiure IN:1~:1 Re&nnce: \\.II Centm: C-IU.'I rue Nunh Ucpth h'm Ueprh Io Sia. ~y/Phn -I.~,~I Crmled dy' Tray lakabosky ~aka10(ubp.cuBkle: 9;112005 VMical ITVU) R.icmiw'e: ?N 5 ~ 36.9] 41.;] Sav7iun (VSl keknncr Sbr-IU (I1.WN.U.WP1 x5U1.W 12i 56.21 PLnuxai: C-IOA upUI VIE Mw UIhK-hfS Checked: Dale: Mraxural 0.prh kcfcnik~c: 2x.5 - 3; 97 61,1 i ('alcuhtion MnhrW: hliniruum ('unuture Rea'iewed: Dale N'I~:LL UI:'1 AILS CASING DETAILS rv:a~~e .. N;-s n-w wnhmE li;~ung ulinmc L oogaale slur No. TVD MD Name Size c-lu 31xv1 lea2.i; swdwa9.W 6641;1.W nrl]'s1.691N 14x°;o' 1;.1v1w ul 1 8406.47 10390.88 7" 7.000 TARGET DETAILS 2 9028.47 12356.0(1 41/2" 4.500 Name TVD +N/-S +Ei-W Northing Easting Shape ' - ~ ~ - ~ ~ C-IOA Faultl 8923.47 -3948.96 2231.44 5956540.00 666460.00 Polygon 6752.56'TVD ~ I ~ ~~ ~ - ~ ~ C-l0A T2 9028.47 -4174.46 3441.89 5956341.00 667675AU Point ' j -- - ~ i C-IOA T3 9028.47 -4364.92 4192.96 595G16ZU0 66843000 Point i i C-IOA Faultl 9028 47 -4584.38 3157.85 5955925.00 66740000 Polygon 1 - I I I C-IOA Fault4 9028 47 4135A8 3882.89 5956390.00 668115.00 Polygon 1' MD. 67Cy134'TV ~ ~ _ I C-IOA Fauh 3 9028.47 4492.27 3519.97 5956025.00 667760.00 Polygon ~ ~ C-l0A TI 9038.47 -4031.48 3169.93 5956478.00 667400.0(1 Point . ~ i ~ C-lUA Poly 9038.47 -3739.09 3156.31 595G77UAU 667380.00 Polygon i I I II II I SECTION DETAILS r :9437.28' MD, 7496:42 I TVD I I I Scc MD Inc Azi TVD +N.-S +E/-W DLcg TFacc VScc Target I 850UAU 53.82 145.31 G752S6 -3042.53 2298.87 OAO 0.00 3786,75 ', . ; __ -_ _. 2 8520.00 54.06 142.35 6764.34 -3055.58 2308.41 12AU -85.00 3802.77 ' ~ , 3 9437.29 17.38 144? I 7496.42 -3475.18 2626.29 4A0 179.07 4325.58 4 10488.88 1738 144.21 8500.00 -3730.00 2810AU OAU 0.0(1 4636.61 5 10540.96 18.89 137.39 8549.49 -3742.52 2820.26 SAO -57.83 4652.75 6 10782.74 18.89 137.39 8778.25 -3800.13 2873?6 (lAU 0.00 4731.02 7 11273.18 92.00 124.911 91138.47 -4031.48 3169.93 =-15A0 -13A2 5103.37 C-IOATI i I 8 11315.81 92.32 118.51 9036.86 -4053.85 3206.15 15.00 -87.04 5144.61 , 9 11465.81 92.32 118.51 903(1.80 -4125.39 3337.86 O.OU OAO 5287.44 ' ~ ~ IU 11580.93 90.00 112A0 9028.47 -4174.46 3441.89 6A0 -109.51 5394.89 C-IOA T2 ~ ~ ~ ~ ~ II 11723.53 90.00 103.44 9028.47 -4217.83 3577.60 6.00 -90.00 SS2U.19 I ~ ~. ~ ~ _ ~. I 12 12356.23 9UA0 103.44 9028.47 4364.92 4192.96 0.00 0.0(1 6052.56 C-IOA T3 I I St:vt Uir i I W :10488.88' D, 85(IOTVD ~ . ~~~_ ~~ i C'UMI'ANY U67NL5 y.~,1~; nP Amara ~ j ~1{~ Calculmwn Al shat: hlirtimun ('un'enrc "MI"r hmrt Syuam: ISC'w'SA Sun Mnlaal: Trey Cylirxkr Nonh 1!mn SUrf ec: I:Ili~al ~ ('a~vg \\aminx MctIW: Kuk. Bawl a C z s ~~ C'UMPANY UEI AILS aP Amocu (u4ulatioi M1lMal. Minis um(Wanvc I~nur Sv~tem: IS('NSA S.an M1I Thal: l rer ('YlinJvr Nunh I:mrt Surfu~e: ClUpiul ~ (Twig N':uning hivThoa: Rulce newt RFtCRCNC 1 INFURM1I,\ 1'IUN ('orrNil I (N/I1R 1 N II( vc: ('-10. Ime Norrh V.ni. Il'IM1 U1R1 n %.S 1i 47 fi1.i7 kvixnt\Sl Rvfin~uv. 11or Ill 111 lNlN.II.WC1 hluvur.J Ikpill ReYereu~o'. 2N.5 ~ \J Y7 fi147 ('el.ulutiam Al th.vl: M1lu~iu~um ('un-enee SURVIiY PR(IURAM PiUn: C-IOA wp03 (C-IOiPlan C-IOA) Ihpth tm Uep h I S vyrl'Iur fool CreattA By: Troy lekubosky IjakalU(abp cuBpe: 9i 1312W5 XSIXI IXI 1'35fi.3 IW ~vd: ('-IUA nTXlJ V16 AIN'U~ItR-MS Cheekel: Dme: N'CLL Ull.\ILS Nude - W-S ~V-N' Nonhmg I~uaing Letitak Longinxle Sla C'~IU 11 tl5.11 ILb?Ji SYWiJ91X1 (.fi411i W ]U°17'S3.6Y3N 14tl'4U'14319W' 1U TARGET DETAILS Name TVD +N/-S +E/-W Noshing Easting Shapc - C-IOA T2 9028.47 -4174.46 3441.89 5956341 AO 667675.00 Point - C-IUA T3 9028.47 -4364.92 4192.96 5956167A0 668430.00 Point - - ~ -- C'-IUA TI 9038.47 -4031.48 3169.93 5956478AU 667400.00 Point ~ - - FORMATION TOP DETAILS ~: '~ : i i ~ ~ ~ - No. TVDPath MDPath Formation ' '. ~ ~I i :. ~ I 7506.47 9447.82 THRZ I _ ' 2 7719.47 9671.01 LCU I - - 3 8037.47 10004.22 TJD 4 8231.47 102(17.51 T16 - __ - ~ 5 8406.47 10390.88 TSGR 6 8521.47 10511.42 TSAD ' ' ~ 7 8687.47 10686.79 TCGL '~ . ', '.. ~. ':. ! ~ - i L '1 8808.47 10815.18 B3SB 1.25'TVD ~ 10 8885.47 10904.54 22TS ' II 8947.47 10989.87 21TS End Dir : 11315.8 ' MD, 9036.86' TVD 12 9030.47 I 1 180.25 TZIB / _ 11 9035.47 11210.01 HOT /, Stnn Dir 6i I '; 11465.81' MD, 9030 C-IUA T2 .8' VD _ End Ir : 11723.5T MD, 902 8. T TVD - : IUA Fault 4. - - ~ - ~~ ~ ~ T lh 12356 23' t Dc MD 9 8 4 - - T TVA _ . - -- - I ':: ~I. f - ; . . p p : C- I llA T3 . PIanC=IUA- . , . I-I---~~ -tOAFault 7 ' - - : ~ ~ { ~ C-IOA_wp U3 _ ~, I~ , ~ . _ ! - -a : ~ - 41/2.' - ~- - . ~ - --- ' -- _ I E CASING DETAILS '. i, '~: I I i No. TVD MD Name Size ' - - - - I 8406.47 10390.88 7" 7AOU - - 2 9028.47 12356.00 4 I/2" 4.500 SECTION DETAILS I Scc MD Inc Azi TVD +N/-S +E./-W DLeg TFacc VScc Target I 8511(1.(10 53.82 145.31 675256 -3042.53 2298.87 OAO 0.00 3786.75 i ': I i . 90 0 _ - ~ - 3 9437.29 17.38 14411 7496.42 -3475.18 2626.29 4.UU 179.07 4325.58 , I _. ~ ..-- - , 4 10488.88 17.38 144.21 8500.00 -3730.00 2810.00 O.UO 0.00 4636.G1 ' ~ 5 1(1540.96 18.89 137.39 8549.49 -3742.52 2820.26 5.0(1 -57.83 4652.75 ' ~ ' 6 10782.74 18.89 137.39 877815 -38(10.13 2873.26 0A0 0.00 4731.02 ~ 7 11273.18 92.00 124.90 9038.47 -4031.48 3169.93 15.00 -13.02 5103.37 C-IOA TI ~ C- (C-l U) 8 11315.81 92.32 118.51 9036.86 -4053.85 3206.15 IS.UU -87.04 5144.61 9 11465.81 92.32 118.51 9030.80 -4125.39 3337.86 UAU 0.00 5287.44 10 11580.93 90.00 112.00 9028.47 -4174.46 3441.89 6A0 -109.51 5394.89 C-10A T2 ',(IUU 2400 28(10 3200 3600 11 11723.53 90.00 103.44 9028.47 -4217.83 3577.60 6.00 -90.00 5520.19 12 1235613 90A0 IU3.44 9028.47 -4364.92 4192.96 OAO 0.00 6052.56 C-IUA T3 Wcst(-1/East(+) [4UOIUin] 2 8520.110 54.06 142.35 6764.34 -3055.58 2308.41 12.00 -55.00 3802.77 Sperry-sun BP Planning Report Company: BP AmOCO Date: 9/13/2005 Time: 17:57x14 Page: i Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: C-10, True North Site: PB C Pad Vertical (TVD) Reference: 28.5 + 34.97 63.5 " Well: C-10 Section (VS) Reference: Well{O.OON,O.OOE,136.15Azi) Wellpath: Plan C,10A Survey Calculation Method: - Minimum Curvature Db: Oracle Plan: C-10A wp03 Date Composed: 6/3/2005 Version: 16 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB C Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5957218.72 ft Latitude: 70 17 22.367 N From: Map Fasting: 662550.03 ft Longitude: 148 41 2.797 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft G»d Convergence: 1.24 deg Well: C-10 Slot Name: 10 C-10 Well Position: +N/-S 3185.31 ft Northing: 5960439.00 ft ~ Latitude: 70 17 53.693 N +E/-W 1662.34 ft Fasting : 664143.00 ft ' Longitude: 148 40 14.339 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name. ft ft in in 10390.88 8406.47 7.000 8.500 7" 12356.00 9028.47 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg ; deg. 0.00 CM1 0.00 0.00 9447.82 7506.47 THRZ 0.00 0.00 9671.01 7719.47 LCU 0.00 0.00 10004.22 8037.47 TJ D 0.00 0.00 10207.51 8231.47 TJB 0.00 0.00 10390.88 8406.47 TSGR 0.00 0.00 10511.42 8521.47 TSAD 0.00 0.00 10686.79 8687.47 TCGL 0.00 0.00 10775.58 8771.47 BCGL 0.00 0.00 10815.18 8808.47 23S6 0.00 0.00 10904.54 8885.47 22TS 0.00 0.00 10989.87 8947.47 21TS 0.00 0.00 11180.25 9030.47 TZ1 B 0.00 0.00 11210.01 9035.47 HOT 0.00 0.00 0.00 BSAD 0.00 0.00 Targets Map Map. <-- Latitude --> <-- Longitude --> Name Description TVD _ +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft - ft ft ft C-10A Fault 1 8923.47 -3948.96 2231.44 5956540.00 666460.00 70 17 14.852 N 148 39 9.326 W -Polygon 1 8923.47 -3948.96 2231.44 5956540.00 666460.00 70 17 14.852 N 148 39 9.326 W -Polygon 2 8923.47 -3876.59 2948.24 5956628.00 667175.00 70 17 15.561 N 148 38 48.441 W -Polygon 3 8923.47 -3900.81 3232.80 5956610.00 667460.00 70 17 15.322 N 148 38 40.150 W -Polygon 4 8923.47 -3876.59 2948.24 5956628.00 667175.00 70 17 15.561 N 148 38 48.441 W C-10A T2 9028.47 -4174.46 3441.89 5956341.00 667675.00 70 17 12.630 N 148 38 34.062 W C-10A T3 9028.47 -4364.92 4192.96 5956167.00 668430.00 70 17 10.753 N 148 38 12.183 W C-10A Fault 2 9028.47 -4584.38 3157.85 5955925.00 667400.00 70 17 8.599 N 148 38 42.343 W Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/13/2005 Time: 17157:14 Page: 2 Field: Prudhoe Bay Co-ordinate(NEJ Reference: Well: C-10, True: North Site: PB C Pad Vertical. ('I'YD) Reference: 28.5 +'34.97 63.5 WeU: C-10 Section (VS) Reference: Well (O.pON,0.00E,136.15Azi ) VKellpatht° Plan C,10A Survey Calculation Method: Minimum Gurvature, Db: Oracle Targets Map Map'- <-= Latitude -> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg. Min Sec Deg Min Sec Dip.: Dir. ft ft ft ft ft -Polygon 1 9028.47 -4584.38 3157.85 5955925.00 667400.00 70 17 8.599 N 148 38 42.343 W -Polygon 2 9028.47 -4389.22 3382.18 5956125.00 667620.00 70 17 10.518 N 148 38 35.805 W C-10A Fault 4 9028.47 -4135.08 3882.89 5956390.00 668115.00 70 17 13.015 N 148 38 21.214 W -Polygon 1 9028.47 -4135.08 3882.89 5956390.00 668115.00 70 17 13.015 N 148 38 21.214 W -Polygon 2 9028.47 -3999.47 4085.91 5956530.00 668315.00 70 17 14.347 N 148 38 15.296 W C-10A Fault 3 9028.47 -4492.27 3519.97 5956025.00 667760.00 70 17 9.504 N 148 38 31.792 W -Polygon 1 9028.47 -4492.27 3519.97 5956025.00 667760.00 70 17 9.504 N 148 38 31.792 W -Polygon 2 9028.47 -4528.81 3819.27 5955995.00 668060.00 70 17 9.143 N 148 38 23.073 W -Polygon 3 9028.47 -4602.32 4207.78 . 5955930.00 668450.00 70 17 8.418 N 148 38 11.756 W -Polygon 4 9028.47 -4528.81 3819.27 5955995.00 668060.00 70 17 9.143 N 148 38 23.073 W C-10A T1 9038.47 -4031.48 3169.93 5956478.00 667400.00 70 17 14.037 N 148 38 41.984 W C-10A Poly 9038.47 -3739.09 3156.31 5956770.00 667380.00 70 17 16.913 N 148 38 42.377 W -Polygon 1 9038.47 -3739.09 3156.31 5956770.00 667380.00 70 17 16.913 N 148 38 42.377 W -Polygon 2 9038.47 -4227.99 3785.83 5956295.00 668020.00 70 17 12.101 N 148 38 24.043 W -Polygon 3 9038.47 -4343.02 4243.46 5956190.00 668480.00 70 17 10.968 N 148 38 10.712 W -Polygon 4 9038.47 -4462.70 4455.91 5956075.00 668695.00 70 17 9.790 N 148 38 4.525 W -Polygon 5 9038.47 -4527.47 4444.49 5956010.00 668685.00 70 17 9.153 N 148 38 4.858 W -Polygon 6 9038.47 -4478.54 4265.50 5956055.00 668505.00 70 17 9.635 N 148 38 10.072 W -Polygon 7 9038.47 -4328.38 3573.57 5956190.00 667810.00 70 17 11.115 N 148 38 30.228 W -Polygon 8 9038.47 -3975.12 2971.10 5956530.00 667200.00 70 17 14.592 N 148 38 47.776 W Plan Section Information MD Incl' Azim TVD +N/-5 +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8500.00 53.82 145.31 6752.56 -3042.53 2298.87 0.00 0.00 0.00 0.00 8520.00 54.06 142.35 6764.34 -3055.58 2308.41 12.00 1.23 -14.77 -85.00 9437.29 17.38 144.21 7496.42 -3475.18 2626.29 4.00 -4.00 0.20 179.07 10488.88 17.38 144.21 8500.00 -3730.00 2810.00 0.00 0.00 0.00 0.00 10540.96 18.89 137.39 8549.49 -3742.52 2820.26 5.00 2.90 -13.10 -57.83 10782.74 18.89 137.39 8778.25 -3800.13 2873.26 0.00 0.00 0.00 0.00 11273.18 92.00 124.90 9038.47 -4031.48 3169.93 15.00 14.91 -2.55 -13.02 C-10A T1 11315.81 92.32 118.51 9036.86 -4053.85 3206.15 15.00 0.74 -14.99 -87.04 11465.81 92.32 118.51 9030.80 -4125.39 3337.86 0.00 0.00 0.00 0.00 11580.93 90.00 112.00 9028.47 -4174.46 3441.89 6.00 -2.01 -5.65 -109.51 C-10A T2 11723.53 90.00 103.44 9028.47 -4217.83 3577.60 6.00 0.00 -6.00 -90.00 12356.23 90.00 103.44 9028.47 -4364.92 4192.96 0.00 0.00 0.00 0.00 C-10A T3 Survey MD Incl Azim TVD ' Sys TVI) N/S E/W DLS. MapN MapE TooUComm t ft deg deg ft ft ft ft deg/100ft ft< ft 8500.00 53.82 145.31 6752.56 6689.09 -3042.53 2298.87 0.00 5957447.61 666507.61 Start Dir 12/10 8520.00 54.06 142.35 6764.34 6700.87 -3055.58 2308.41 12.00 5957434.78 666517.44 Start Dir 4/100 8600.00 50.86 142.42 6813.08 6749.61 -3105.82 2347.13 4.00 5957385.40 666557.24 MWD+IFR+MS 8700.00 46.86 142.51 6878.85 6815.38 -3165.53 2393.00 4.00 5957326.71 666604.40 MWD+IFR+MS 8800.00 42.86 142.62 6949.72 6886.25 -3221.53 2435.87 4.00 5957271.66 666648.48 MWD+IFR+MS 8900.00 38.86 142.74 7025.33 6961.86 -3273.55 2475.53 4.00 5957220.53 666689.27 MWD+IFR+MS 9000.00 34.86 142.89 7105.32 7041.85 -3321.33 2511.79 4.00 5957173.55 666726.55 MWD+IFR+MS 9100.00 30.87 143.07 7189.30 7125.83 -3364.64 2544.46 4.00 5957130.97 666760.16 MWD+IFR+MS 9200.00 26.87 143.29 7276.86 7213.39 -3403.28 2573.39 4.00 5957092.98 666789.93 MWD+IFR+MS 9300.00 22.87 143.59 7367.57 7304.10 -3437.04 2598.44 4.00 5957059.77 666815.71 MWD+IFR+MS 9400.00 18.87 144.01 7460.99 7397.52 -3465.78 2619.49 4.00 5957031.50 666837.38 MWD+IFR+MS 9437.29 17.38 144.21 7496.42 7432.95 -3475.18 2626.29 4.00 5957022.25 666844.38 End Dir :9437 9447.82 17.38 144.21 7506.47 7443.00 -3477.73 2628.13 0.00 5957019.75 666846.28 THRZ 9500.00 17.38 144.21 7556.27 7492.80 -3490.37 2637.25 0.00 5957007.30 666855.67 MWD+IFR+MS Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/13/2005 TSme: 17:57:14 Page:. 3 .Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: C-10 True North Site: PB C Pad Vertical (TVD) Reference: 28.5 +34.97 63.5 Well: C-1 0 Section (VS) Reference: Well (O,OON,O OOE,136.15Azi) Wellpath: ' Plan C-10A Survey Calculation Method: Minimum Curvature - Dh:.Oracle Survey MI) Incl Azim TVD: SysThD N/S E1W DLS MapN MapE, TooUComme t ft deg deg ft ft ft ft deg/100ft ft ', ft 9600. 00 17.38 144.21 7651.70 7588.23 -3514.60 2654.72 0.00 5956983.46 666873.66 MWD+IFR+MS 9671. 01 17.38 144.21 7719.47 7656.00 -3531.81 2667.12 0.00 5956966.53 666886.44 LCU 9700. 00 17.38 144.21 7747.14 7683.67 -3538.84 2672.19 0.00 5956959.62 666891.65 MWD+IFR+MS 9800. 00 17.38 144.21 7842.57 7779.10 -3563.07 2689.65 0.00 5956935.77 666909.65 MWD+IFR+MS 9900. 00 17.38 144.21 7938.01 7874.54 -3587.30 2707.12 0.00 5956911.93 666927.64 MWD+IFR+MS 10000. 00 17.38 144.21 8033.44 7969.97 -3611.53 2724.59 0.00 5956888.09 666945.63 MWD+IFR+MS 10004. 22 17.38 144.21 8037.47 7974.00 -3612.56 2725.33 0.00 5956887.08 666946.39 TJD 10100. 00 17.38 144.21 8128.87 8065.40 -3635.77 2742.06 0.00 5956864.24 666963.63 MWD+IFR+MS 10200. 00 17.38 144.21 8224.31 8160.84 -3660.00 2759.53 0.00 5956840.40 666981.62 MWD+IFR+MS 10207. 51 17.38 144.21 8231.47 8168.00 -3661.82 2760.84 0.00 5956838.61 666982.97 TJB 10300. 00 17.38 144.21 8319.74 8256.27 -3684.23 2777.00 0.00 5956816.56 666999.61 MWD+IFR+MS 10390. 88 17.38 144.21 8406.47 8343.00 -3706.25 2792.88 0.00 5956794.89 667015.97 7" 10400. 00 17.38 144.21 8415.18 8351.71 -3708.46 2794.47 0.00 5956792.71 667017.61 MWD+IFR+MS 10488. 88 17.38 144.21 8500.00 8436.53 -3730.00 2810.00 0.00 5956771.52 667033.60 Start Dir 5/100 10500. 00 17.68 142.66 8510.60 8447.13 -3732.69 2812.00 5.00 5956768.88 667035.65 MWD+IFR+MS 10511. 42 18.01 141.12 8521.47 8458.00 -3735.44 2814.15 5.00 5956766.17 667037.87 TSAD 10540. 96 18.89 137.39 8549.49 8486.02 -3742.52 2820.26 5.00 5956759.23 667044.13 End Dir :1054 10600. 00 18.89 137.39 8605.35 8541.88 -3756.59 2833.20 0.00 5956745.45 667057.37 MWD+IFR+MS 10686. 79 18.89 137.39 8687.47 8624.00 -3777.27 2852.23 0.00 5956725.19 667076.85 TCGL 10700. 00 18.89 137.39 8699.97 8636.50 -3780.42 2855.12 0.00 5956722.11 667079.81 MWD+IFR+MS 10775. 58 18.89 137.39 8771.47 8708.00 -3798.43 2871.69 0.00 5956704.46 667096.76 BCGL 10782. 74 18.89 137.39 8778.25 8714.78 -3800.13 2873.26 0.00 5956702.79 667098.37 Start Dir 15/10 10800. 00 21.42 135.79 8794.45 8730.98 -3804.45 2877.35 15.00 5956698.56 667102.55 MWD+IFR+MS 10815. 18 23.66 134.66 8808.47 8745.00 -3808.58 2881.45 15.00 5956694.53 667106.74 23S6 10900. 00 36.24 130.78 8881.82 8818.35 -3837.03 2912.67 15.00 5956666.77 667138.57 MWD+IFR+MS 10904. 54 36.91 130.64 8885.47 8822.00 -3838.80 2914.72 15.00 5956665.05 667140.66 22TS 10954. 66 44.38 129.33 8923.47 8860.00 -3859.74 2939.73 15.00 5956644.66 667166.13 C-10A Fault 1 10989. 87 49.64 128.61 8947.47 8884.00 -3875.93 2959.76 15.00 5956628.91 667186.50 21TS 11000. 00 51.15 128.42 8953.93 8890.46 -3880.79 2965.86 15.00 5956624.19 667192.71 MWD+IFR+MS 11100. 00 66.10 126.90 9005.85 8942.38 -3932.73 3033.31 15.00 5956573.73 667261.27 MWD+IFR+MS 11171. 07 76.73 126.04 9028.47 8965.00 -3972.71 3087.41 15.00 5956534.95 667316.23 C-10A Fault 2 11180. 25 78.10 125.93 9030.47 8967.00 -3977.97 3094.66 15.00 5956529.85 667323.59 TZ1B 11200. 00 81.05 125.71 9034.04 8970.57 -3989.33 3110.41 15.00 5956518.83 667339.58 MWD+IFR+MS 11210. 01 82.55 125.59 9035.47 8972.00 -3995.11 3118.46 15.00 5956513.24 667347.75 HOT 11273. 18 92.00 124.90 9038.47 8975.00 -4031.48 3169.93 15.00 5956478.00 667400.00 C-10A T1 11300. 00 92.20 120.88 9037.49 8974.02 -4046.03 3192.43 15.00 5956463.94 667422.82 MWD+IFR+MS 11315. 81 92.32 118.51 9036.86 8973.39 -4053.85 3206.15 15.00 5956456.42 667436.70 End Dir :1131 11400. 00 92.32 118.51 9033.46 8969.99 -4094.01 3280.08 0.00 5956417.90 667511.48 MWD+IFR+MS 11465. 81 92.32 118.51 9030.80 8967.33 -4125.39 3337.86 0.00 5956387.78 667569.93 Start Dir 6/100 11500. 00 91.63 116.57 9029.62 8966.15 -4141.19 3368.15 6.00 5956372.65 667600.56 MWD+IFR+MS 11580. 93 90.00 112.00 9028.47 8965.00 -4174.46 3441.89 6.00 5956341.00 667675.00 C-10A T2 11600. 00 90.00 110.86 9028.47 8965.00 -4181.43 3459.64 6.00 5956334.42 667692.90 MWD+IFR+MS 11700. 00 90.00 104.86 9028.47 8965.00 -4212.08 3554.78 6.00 5956305.86 667788.68 MWD+IFR+MS 11723. 53 90.00 103.44 9028.47 8965.00 -4217.83 3577.60 6.00 5956300.61 667811.62 End Dir :1172 11800. 00 90.00 103.44 9028.47 8965.00 -4235.61 3651.97 0.00 5956284.46 667886.36 MWD+IFR+MS 11900. 00 90.00 103.44 9028.47 8965.00 -4258.86 3749.23 0.00 5956263.34 667984.10 MWD+IFR+MS 12000. 00 90.00 103.44 9028.47 8965.00 -4282.11 3846.49 0.00 5956242.22 668081.83 MWD+IFR+MS 12100. 00 90.00 103.44 9028.47 8965.00 -4305.35 3943.75 0.00 5956221.11 668179.57 MWD+IFR+MS 12200. 00 90.00 103.44 9028.47 8965.00 -4328.60 4041.01 0.00 5956199.99 668277.31 MWD+IFR+MS 12300. 00 90.00 103.44 9028.47 8965.00 -4351.85 4138.27 0.00 5956178.87 668375.05 MWD+IFR+MS 12356. 00 90.00 103.44 9028.47 8965.00 -4364.87 4192.74 0.00 5956167.05 668429.78 4 1 /2" ~ 12356. 23 90.00 103.44 9028.47 ~ 8965.00 -4364.92 4192.96 0.00 5956167.00 668430.00 C-10A T3 TREE =~ 6" Clw WELLHEAD = 13-5/8" 5M FMC ACTUATOR = OTIS KB. ELEV = 61.97' BF. ELEV = 34.97' KOP = 3100' Max Angle = 57 @ 8200' Datum MD = 11546' Datum TVD = 8800' SS NOTES: CMT SQZ DONE BETWEEN C ~ 1 0 ~ S DLE PKRS ON 5/29/98. ® 2125' 4-1/2" SSSV, OTIS LANDING NIP ID = 3.813" 2267' 4-1/2" X 3-1/2" XO, ID = 2.992" 2585' 9-5/8" DV GAS LIFT MANDRELS l I~~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 226T 13-3/8" CSG, 72#, L-80, ID = 12.347'° ~ 266 Minimum ID = 2.75" @ 11669' 3-1 /2" OTIS XA SLIDING SLV 9-518" X 7" BOT LNR HGR /TIEBACK SLV ~-j 1031 f 9-5/8" CSG, 47#, N-80, ID = 8.681" 10831' 11567' --~ 7" MARKER JOINT 11598' 3-1/2" OTIS X NIP, MILLED-OUT TO 2.85" ID 11624' 7 " X 3-1/2" 7M/ HBBP-R PKR, ID = 4.00" I I 11669' 3-1/2" OTIS XA SLIDING SLV, ID = 2.75" 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 11675' 11675' 3-1/2" BLAST JTS (90' ), ID = 2.992" 11774' 7 " X 3-1/2" TNV HBBP PKR ID = 4.00" 11781' 3-1/2" OTIS X NIP, ID = 2.75" 11784' 3-1/2" OTIS WLEG, ID = 2.87" PERFORATION SUMMARY 11783' ELMD TT REF LOG: CBUGR on 8/9/79 ANGLE AT TOP PERF: 48 @ 11620' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11620 - 11625 S 05/29/98 3-1/8" 4 11654 - 11706 S 05/29/98 3-1/8" 4 11716 - 11728 S 05/29/98 3-1/8" 4 11734 - 11748 S 05/29/98 3-1/8" 4 11756 - 11772 O 06/10/98 3-3/8" 4 11786 - 11818 O 06/10/98 PBTD I-1 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2989 2926 6 MERLA DMY RA 0 02/22/05 4 4990 4608 49 MERLA DMY RA 0 02/22/05 3 6991 5813 55 MERLA DMY RA 0 06/08/98 2 8993 6998 49 MERLA DMY RA 0 06/08/98 1 10212 7879 42 MERLA DMY RA 0 06/08/98 10233' 3-1/2" OTIS X NIP, MILLED-OUT TO 2.85" ID 10242' TNV SBR SEAL ASSY 10257' 9-5/8" X 3-1 /2" PKR, TNV HBBP-R, ID = 4.00" 10316' WEATHERFORD WRP SET 3!8/05 12017' 12060' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/10/79 ORIGINAL COMPLETION 03/24/90 RWO 07/27/01 CWKAK CORRECTIONS 03/02/05 MS/TLH GLV GO (02/22/05) 05/22/05 DAGPJC WRP CORRECTION (SET 3/8/05) PRUDHOE BAY UNIT WELL: G10 ' PERMff No: 79-0350 API No: 50-029-20371-00 775' SNL & 1222' WEL, Sec. 19, T11 N, R14E BP 6cploration (Alaska) TREE =' 6" CNV WELLHEAD = 13-5/8" 5M FMC ACTUATOR = OTIS KB. ELEV = 61.97' BF. ELEV = 34.97' KOP = 3100' Max Angle = 57 @ 8200' Datum MD = 11546' Datum ND = 8800' SS C -10 Proposed NOTES: CMT Soz DONE BETWEEN S DLE PKRS ON 5/29/98. De-com alete 2585' I-I 9-5/8^ DV 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2666' Minimum ID = 2.75" @ 11669' 3-1 /2" OTIS XA SLIDING SLV -9024' 9-5/8" EZSV, w ireline set Top of P&A cement 10,000' 9-5/8" X 7" BOT LNR HGR /TIEBACK SLV 10316' 9-5/8" CSG, 47#, N-80, ID = 8.681" 10831' PERFORATION SUMMARY REF LOG: CBL/GR on 8/9/79 ANGLE AT TOP PERF: 48 @ 11620' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11620 - 11625 S 05/29/98 3-1/8" 4 11654 - 11706 S 05/29/98 3-1/8" 4 11716 - 11728 S 05/29/98 3-1/8" 4 11734 - 11748 S 05/29/98 3-1/8" 4 11756 - 11772 O 06/10/98 3-3/8" 4 11786 - 11818 O 06/10/98 PBTD 12017' 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 12060' 9300' Jet cut in 3-1/2" tbg f • ~ 10233' 3-1/2" OTIS X NIP, MILLED-OUT TO 2.85" ID • - 10242' TNV SBR SEAL ASSY ., • 10257 9-5/8" X 3-1/2" PKR, TNV HBBP-R, ID = 4.00" 1 r ,~ •, 11624' 7 " X 3-1 /2" TNV HBBP-R PKR, ID = 4.00" 11669' 3-1/2" OTIS XA SLIDING SLV, ID = 2.75" .• ' ~ ~ 11774' 7 " X 3-1 /2" TM/ HBBP PKR, ID = 4.00" . •`~ 11784' 3-1/2" OTIS WLEG, ID = 2.87" DATE REV BY COMMENTS DATE REV BY COMMENTS 08/10/79 ORIGINAL COMPLETION 03/24/90 RWO 07/27/01 CWKAK CORRECTIONS 03/02/05 MS/TLH GLV GO (02/22/05) 05122!05 DAGPJC WRP CORRECTION (SET 3/8/05) PRUDHOE BAY UNff WELL: G10 PERMff No: 79-0350 API No: 50-029-20371-00 775' SNL & 1222' WEL, Sec. 19, 711 N, R14E BP Exploration (Alaska) TREE = s° clw WELLHEAD = 13-5/8" 5M FMC ACTUATOR = OTIS KB. ELEV = 61.97' BF. ELEV = 34.97 KOP = 3100' Max Angle = 57 @ 8200' Datum MD = 11546' Datum TVD = 8800' SS +C-10 Proposed Completion 2585' 9-5/8" DV 13-3/8" CSG, 72#, L-80, ID = 12.347" 2666' Minimum ID = 3.725" @ 10,274' 4-1 /2" XN NIPPLE 8500' 9 5/8" Window 10,294' 4-1/2" 12.6# 13cr80 VamTop tbg 8800' Chemical cut in 3-1/2" tbg 10242' TNV SBR SEAL ASSY 10257' 9-5/8" X 3-1/2" PKR, TNV HBBP-R, ID = 4.00" 9-5/8" X 7" BOT LNR HGR /TIEBACK SLV 10316' 9-5/8" CSG, 47#, N-80, ID = 8.681" 10831' PERFORATION SUMMARY REF LOG: CBUGR on 8/9/79 ANGLE AT TOP PERF: Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE PBTD 12017' 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 12060' NOTES: CMT SQZ DONE BETWEEN S DLE PKRS ON 5/29/98. 8350' -Top of 7" Liner 10214' 7" x 4 1/2" Baker S3 Packer 10234' 4 1/2" X Nipple (3.813" ID) 10254' 4 1/2" X Nipple (3.813" ID) 10274' 4 1/2" XN Nipple (3.725" ID) 10,294' 4 1/2" WLEG <' 10294' 4 1/2" Hanger /liner top packer 10390' 7" 26# L-80 (6.276" ID) 4 1/2" 12.6# L-80 Liner PBTD 12,356' 11624' 7 " X 3-1/2" TNV HBBP-R PKR, ID = 4.00" 11669' 3-1/2" OTIS XA SLIDING SLV, ID = 2.75" 11774' 7 " X 3-1 /2" TM! HBBP PKR, ID = 4.00" 11784' 3-1/2" OTIS WLEG, ID = 2.87" DATE REV BY COMMENTS DATE REV BY COMMENTS 08/10/79 ORIGINAL COMPLETION 03/24/90 RWO 07/27/01 CWKAK CORRECTIONS 03/02/05 MSlTLH GLV GO (02/22/05) 05/22/05 DAGPJC WRP CORRECTION (SET 3/8/05) 06/20/05 JNC Proposed Completion PRUDHOE BAY UNIT WELL: G10A PERMfr No: 79-0350 API No: 50-029-20371-01 775' SNL & 1222' WEL, Sec. 19, T11 N, R14E BP Exploration (Alaska) • C-10A IFE DRILLING & COMPLETION FLUIDS PROPOSAL MiSWAC~~ IFE F = BP C-10A Ivishak Zone 2A Producer Nabors 2ES Name Signature Date Originator: Mark Fairbanks Reviewed by: Mark Dick Customer Approval: Jeff Cutler Version: 1.0 August 7, 2005 Location North Slope Alaska Confidential 1 9/812005 i C-10A Well Summary Well C-10A is a two string horizontal sidetrack producer targeting zone 2A. A 10.5 Ib/gal LSND fluid will be used to mill a window in the existing 9 5/8" casing at 9,000' MD. This density will be held while drilling through the HRZ/Kingak. The 8.5" intermediate interval will TD at _10,555' MD where a 7.0" liner will then be run and cemented. An 8.4 Ib/gal Fl_oPt~o SF (Solids Free) Reservoir Drill-In Fluid (RDF) will then be used to drill a 6.125" production hole to the Zone 2A target TD of --12,430' MD. A 4'/z" production liner will run and cemented with 150' lap into the 7.0" liner. The maximum inclination for this well is 92° in the production zone. After reviewing the "C" Pad Data Sheet M-I SWACO offers the following recommendations. _ ~~ IFE Benchmark and Goals _-- 1FE Benchmarks No Stuck Pi e No Mud Related HSE Issues Casin /Liner to Bottom Minimum 400' of erfs in horizontal well in Zone 2A Casing and Fluid Summary Casing Size (in Hole Size in) Casing Program Depth MD (ft) TYD (ft) Interval Length ft) Mud System Mud Weight (Ib/ al Pore Press. 7.0 8.5 10,555 8,469 1,555 LSND 10.5- 10.7 n/a 4.5 6.125 12,430 9,028 1,875 FI_oPROSF 8.4 7.0 Estimated Costs Estimated Drilling Fluid Related Costs Depth Interval (ft) Product Costs ($) Engineering Costs (days) ($) Interval Cost ($) Cumulative Cost (a) Decompletion $10,000 $5,680 (4) $15,680 $15,680 Kick-off @ --9,000 -10,555 $85,000 $7,100 (5) $92,100 $107,780 10,555 - 12,430 $119,000 $7,100 (5) $126,100 $233,880 Completion $10,000 $5,680 (4) $15,680 $249,560 P10 P50 P90 Total Fluid and Engineering Cost $187,170 $249,560 $436,730 GWSI (Drilling only $218,200 P10: Assumes using recycled fluid from a previous well P50: Assumes using all new fluids Location North Slope Alaska Confidential 2 9/8/2005 • • C-10A Directional Profile r n m 0 m .Y r m m 2 r Formation Markers Formation Tops(TVDss) and Estimated Pore Pressures Esl. Formulion To s Uncerlninly Commercial H_vdroc•nrbon Benr•in Esl. Pore Press. Est. Pore Prec.c. Formation (TVDss) (Jeer) (Yes/Nn) (Psi) (ppg EMGG'/ NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells LCU -7610 TJD -7872 TJB -8 l 85 No TSGR -8368 Yes TSAD -8483 20' Yes TCGL -892 20' Yes BCGL -8665 20' Yes 23SB -8745 20' Yes 22TS -8814 20' Yes 3200 21TS -8875 20' Yes TZ1B -8967 20' Yes HOT -8972 10' BSAD -9033 20' No Location North Slope Alaska Confidential 3 918/2005 • C-40A Milling/ Intermediate Interval - 8.5 " Drilling Fluid System LSND Key Products Poly Pac Supreme, Duo-Vls, Caustic, Resinex, Barite, Asphasol Supreme, Lube 776 Solids Control Shakers, Desander, Mud Cleaner, Centrifuge, Solids Control Van Removing metal cuttings Potential Problems Adequate hole cleaning Hole integrity and condition for liner and cement. Excessive Tor ue and dra . Balance ROP, ECD to obtain adequate hole cleaning and minimize any LC Interval Objectives Maintain Wellbore stability through HRZ/Kingak section Maintain proper fluid Theology & lubricant concentration to achieve directional re uirements Milling /Intermediate Interval Fluid Properties Plastic Yield API Fluid Depth MD Mud Wt. Funnel Viscosity. Point Loss HTHP (ft) (Ib/gaq Viscosity (cp) (Ib/100ft2} (ml/30min) {ml/30min) pH MBT Milling @ -9,000 10.5 50 - 60 15 - 22 30 - 40 <6.0 <11 9.0-9.5 <20.0 -9,000- 10,555 10.5-10.7 42 - 52 18 - 25 22 - 28 <5.0 <11 9.0-9.5 <20.0 LSND Mud Formulation: 10.5 Ib/gal Fresh water 0.94 bbl MECT WS1 0.03 Ib/bbl Soda Ash 0.2 Ib/bbl M-I Gel 10 Ib/bbl Poly Pac Supreme 1.0 Ib/bbl Duo-Vls 1.75 Ib/bbl Barite -100.0 Ib/bbl EMI 776 2.0% v/v Resinex 4.0 Ib/bbl Asphasol Supreme 4.0 Ib/bbl Sea water to LSND Displacement Recommendations After decompletion operations are completed displace the seawater to a 10.5 Ib/gal LSND prior to milling a window in the existing 9 5/8" casing. / Clean the rig pits and flush all surface lines prior to taking on the LSND fluid delivered from the M-I SWACO Mud Plant. Have vacuum trucks ready to haul-off displaced fluid prior to beginning the displacement to LSND. / It is suggested to initially receive the minimum volume mud necessary for milling so as to allow room in the pits for another load of low viscosity mud in order to reduce the active viscosity for optimal drilling the section to TD. / Mix up 40-50 bbl high vis spacer in the pill pit using 3.0 ppb Duo-Vls and water. / An optional 40 - 60 bbl lubricant spacer containing 10% by volume Steel Lube EP can be pumped behind the water and ahead of the high viscosity spacer. This spacer can be incorporated into the LSDN system. Location North Slope Alaska Confidential 4 9/8/2005 ~I r ~ C-1 OA / Pump the 10.5 Ib/gal LSND at >500 gal/min while rotating the drill pipe to ensure minimal interface and a good displacement. / Monitor the shakers for the spacers. Discard the spacers and any contaminated LSND fluid as needed. Milling Operations - Use the 10.5 Ib/gal LSND to mill a window in the casing. If any cement is encountered, treat with Bi-Garb and/or citric acid. A sweep containing 0.125-0.25 Ib/bbl `Super Sweep' can be used to sweep the hole of metal cuttings while milling the window. Intermediate Interval Operations - The 10.5 Ib/gal LSND used to mill the window will also be used to drill the intermediate interval. Since the window will exit into the HRZ the fluid will be initially have all the "black products" and weight material in it necessary for drilling the HRZ/Kingak sections. It is also recommended to use hot water to mix the LSND system. - Drill ahead using Resinex and Asphasol Supreme UI materials to control fluid losses. Duo-Vis will be used to maintain rheology. Water, Tannathin and Spersene CF may also be used to adjust and fine-tune the rheologies. Barite to maintain density and caustic to control pH. - Control ROP to <100 ft/hr. and maintain pump rate @ -500 gal/min while drilling through the HRZ. - Adjust rheology, ROP, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. See Virtual Hydraulics Modeling enclosure. - Pump high viscosity weighted sweeps (>2.5 Ib/gal over mud weight), monitor cuttings and ECD to avoid packing off the annulus and ensure good hole cleaning. - Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily cleanup or if there is any excess of torque, drag, pick-up or slack-off weights pump a second high viscosity sweep and circulate bottoms up again. Monitor cuttings across the solids control equipment and circulate at least three bottoms up if necessary prior to POOH. (Note- M-I Swaco recommends performing a short trip to the window to clean up the HRZ prior to running the drilling liner. Experience has shown this to be the best practice for this section. - Adjust rheology (YP 20 - 22) prior to running the casing as required in the cementing program. Once the casing in on bottom the YP may be lowered even further if required. Intermediate Interval Drilling Concerns - Hole Cleaning: The maximum hole angle during this interval is 48°. Fluid properties should be monitored and adjusted if necessary to maintain adequate hole cleaning parameters. Effective average ROP's above 100 ft/hr. and/or prolonged instantaneous penetration rates of >150 ft/hrs should be avoided while drilling this interval since much of it will be in the HRLKingak. - Wellbore Stability: Monitor hole conditions closely and inspect cuttings for indications of wellbore instability. - Hole Stability through the HRLKingak: Experience has indicated that the best way to drill through the HRZ is to have the required mud density prior to entering the formation and use shale inhibitors to maintain wellbore stability. This is accomplished with the additions of 4.0 Ib/bbl Asphasol Supreme/Soltex and 4.0 Ib/bbl Resinex which will be included in the original milling fluid along with an additional fluids received from the mud plant. - Drill Solids Build up: Maintain an aggressive solids control program as described in the following section, Location North Slope Alaska Confidential 5 9/8/2005 • r C-1 OA use the solids control van and do not let the Low Gravity Solids (LGS) exceed 70 Ib/bbl. - Lubricity: The fluid will be mixed with 2% v/v Lube 776. If additional lubricant is required add additional Steel Lube EP in 0.5% increments. Consult with the M-I SWACO Project Engineer before increasing the concentration of lubricant. - Lost Circulation. The risk for lost circulation while drilling this interval is low; however a full inventory of loss circulation material should be on location as a precaution. Recommended Intermediate Interval Solids Control Equipment Shaker Screens 210/170's or as needed to control mud loss over shakers while drillin . De-sander Use as needed to control sand content (<_0.5%) Mud Cleaner/De-sitter As needed to control sand/silt, will het downstream a ui ment. Centrifu a Run as needed to control drill solids %, as well as mud wei ht. Solids Control Van Use the solids control van to minimize LGS Shakers • Inspect decking rubbers, c/o as necessary. • Install XR Magnum screens (140 - 175 mesh). Ensure screens are properly tensioned, per M-I Swaco's best practice suggestions. Spray down new screens with fresh water before operating the shakers. • Set counterweights to 95% (8 G's) for optimum performance. • As fluid shears, screen up as necessary to higher mesh screen sizes. • Ensure jacking system on ALSII or equivalent shakers enables the fluid to flow to the center of the screens, adjust and lock as necessary. De-Silter • Ensure cuttings trough bypasses shakers, and goes into cuttings ditch. Failure to do so will allow small particles to enter right back into system through the flow line shakers (84 - 110 mesh screens). • Install 3/8" Apexes. • Ensure that Feet of Head gauge is available at the De-Silter, not the pump. • Ensure that De-Silter feed pump can achieve 95' of head. CRITICAL! • Monitor discard, change apexes as necessary to improve solids content in mud. Discard should be 2 - 3 ppg over feed weight. Centrifuge • Intermediate intervals require a greater through put during most operations, which require the centrifuge to run at a lower speed (2,500 rpm). This setting allows the centrifuge to process more fluid and discharge more cuttings. The only draw back of the lower rpm's, is the cut point is reduce from 3 - 6 micron cut, to approximately 6 - 10 micron. M-I SWACO recommends and stands behind the suggestion to run the centrifuge at the lower speeds during the upper sections of hole. • Refer to mud man for solids information to determine speed and feed rate of centrifuge. • Use to lower LGS. • Continual processing at low feed rates will yield better results than shutting centrifuge down and starting it up. Slow feed rate down to maintain an acceptable weight if needed. M-I SWACO will have a complete inventory of shaker screens to use during this interval. Location North Slope Alaska Confidential 6 9/8/2005 • • C-10A Mi ~ -,_ A ~ WD 9050 ft Operates: BP ~~/•~,~ TVD: 7098 ft Wel Nana: C-t0A Sna Shot 8'S"hole at window VIRTUAL HYDRAULICS• Bi sae: as in. LDCatbn: Peu 4" drill pipe o~~.~Y1 _ wBV"r..~ Date: 9f/2005 Cotrrtry: US G 1vD/NDf eomet I) Csg/ ry H Dia (~n) Depth (ft) 0 Angl 30 60 e 90 10. Density 4 10.6 10. (Ib/gal) 8 11.0 71 2 0 P 1 V, 0 YP 37 , LS 30 Y P 40 0 AV 2 (ft/m VJ 50 in) 0 75 0 Hole ~ Cl G ean F Ind P 0 Pressure Loss (% ) 2S m 76 10 0 19 jj I! ~ tooB i {;. j ~ 2D00 v ~~ EC ~.; I i i aooo ~ j 5000 f ^.: ~ ' ESD ~ soon I' ~' 7000 L P aooo ' ~ E + t , i 9000 7~ s.6~s 10000 ! Drill String Bit ~nnu us DRILLING FLUID Water-Based Mud Mud weigh los agal Teat Terry 85 °F SYSTEM DATA Fbw Rate 500 gaartl ROP 100ftR1r RPM 90 rpm WCB 25Kb TFA S94 it' PRESSURE LOSS (psi) Mo~'ed Power law Drit String 1592 MDtorMIWD 3501450 Bi 698 s10ru'Off 100 AmuWa 154 Surface Equya 2T U-Tube Press 43 Total System 3412 FSD ECD +Cut CsgSloe 1058 1098 11.10 TD 1058 11A0 11.11 VRDH -VSSlm27.t F#s-C-iMI.00B Location North Slope Alaska Confidential ~ 918/2005 M Location North Slope Alaska Confidential 8 9!812005 • • C-10A Intermediate Interval Hole Cleaning Hole Cleaning ~ ooo - -- . r -~~ __ _-- I f ROP 50. ftlhr - ~~ ble Cleaning Poor H 1 ~` ROP 100. ftlh ,_ I - __ ROP 150. ftlh 750 0 i - ROP 200. ft/h ft/h ROP 250 . i . ROP 300. ft/h x ~ C t71 Fair Hode Cleaning C ~ 0.500 - m V I I m O S Good Hole Cleaning I ~ I _ . _ . ~~ i 0.250 _... - - Very Gdod Hole Clean~ng i 4 0.0 46 ~: 0.0 480.0 500.0 52 0.0 540.0 560.0 VIRTUAL NrnRwu Flow Rate (gal/min) ucs® ti1118WACO Modeled at 10.5 Ib/gal and 100 rpm Hole Cleaning Summary - 8.5" Hole ROP DP RPM Pum GPM Fluid Wei ht Hole Cleanin Condition 100 60 525 10.5 Good 150 60 525 10.5 Good/Fair 200 60 525 10.5 Fair 200 100 525 10.5 Fair 200 60 550 10.5 Fair 250 100 550 10.5 Fair/Poor In all cases where hole cleaning is rated as, fair to very poor, extra precautions must be made to keep the wellbore clean. 1. Extra time spent should be spent on circulation prior to connections and trips. 2. Adjust rheology if possible to help with hole cleaning. 3. Weighted high viscosity sweeps may help. 4. Maximized rpm while drilling and circulating will generally aid with hole cleaning. 5. Observe and chart pickup and slack off weights during each connection. Location North Slope Alaska Confidential 9 918/2005 • C-1 OA Lost Circulation Decision Tree Risk for loss circulation is low thru this interval; however have adequate Lost Circulation Material (LCM) on location. Follow the LCM Decision Tree when encountering lost circulation. Be sure to cycle open the PBL or circulation sub (if present) when pumping a lost circulation pill containing coarse lost circulation material. Lost Circulation Flow Chart-Intermediate Interval I Losses I Seepage I I Partial I I Severe I ~ Total 10-20 bbl/hr static 20.60 bbllhr static BO-200 bbllhr static >200 bbllhr Treat Active System Drill across teak as noted DNII across fault as noted Y with 10 sx/hr Mix 0 and below below. ' r L ss s Treat Aedve System a losses era fault relat- Mlt I t with 10 axlM MGt II and ed, dNll across fault as Pump 100 ppb LCM pill dNll BCfeas fault aE noted belOW. thro PBL sub (volume to pump NI FORMABET pill t0 noted below, be baaed upon loss rete): allow POM (volume will be N 20 ppb M•I Seal (F) based Upon loss rate). Dynamic Y 20 ppb Md Saal (M) Treat Acdve System with Losses <30 30 ppb Mix II S sx/hr Mix II bbllhr 20 ppb Md Seal 10 ppb Nut Plug (F) POH, PU Dumb BHA N Y Y Plan to pump 50 to BO bbl D amts yn DNII D amk tl" Pum 40 b LCM ll p pp W DNII Y Dynamic DOB2C Pill as per Dowell Losses <30 Ahead Losses <30 Dr ill Mru Dit (volume will be Ahead Losses <30 recdmmendaden when bbllhr bbllhr c ad bases upon loss rate): bbllhr back on bottom. ZO ppb Mlx II N N ZO ppb Md Seel N Increase T reatment to Pump 35 ppb LCM pill mru ba (volume will be A second pill may bs requketl Plan t0 pump 8 aec0nd 50 f 0 sx/hr Mix II bases upon loss rah): Y Dynamic based upon aucuas I impact of to BO bbl D062C pill it Losses <30 flreL M MI FORMd18ET pill wal massWe losses COntlnue. 20 ppb Mix 11 be cusiderod'd fibrous LCM 76 ppb Md Seal bbllhr has eta. aRect Dynamic Y DNII Y Dynamic Pump 100 ppb LCM pill thro PBL sub I} all attempts are UnsUCeess- Losses <30 Ahead Losses <30 (volume b be baaed upon loss rate): ful, pump MI FORN,ABET pill to bbllhr bbllhr ZO ppb M-1 Seal (F) allow POH (volume will be 20 ppb M-1 Saal (M) based upon IosSBS and suc- h 30 ppb Mlx II Cass of inWel Pills) N 20 ppb M-I Seal 70 ppb Nut Plug (F) mp 36 ppb LCM pill thru (volume will ba based A second pill may ee nquiretl POH, PU Dumb BHA on bas rah): based upon success I impsd of first An MI FORM-ABET pill will ppb Mix 11 be considered if flbroua LCM A second pOt may M requirW ppb Md Seal has little effect. baaed upon sucuaa / knpset of first An MI FORYd18ET pia will plan t0 Um 30 to 50 bbl P P M consldered'rf fibrous LCM D062C pill as per nu little eRect Dowell recommendation U dynamic loss is still >30 bbyhr a decision will be when back on bottom. made if addklonal LCM treatments are to be made. Note: If losses are fault related, drill across fault 7 to 1.5 times the length of the throw before treating losses. Estimated fault throws are listed in the well plan. Location Notch Slope Alaska Confidential 10 9/8/2005 • • C-10A Production Interval - 6.125" Drilling Fluid System FLOPRO SF Reservoir Drill-in Fluid Key Products Fro-vas PLUS, K~A-GARD, Lubetex, KCI Solids Control- Shakers, Mud cleaner, Centrifuge Lithologic instability near the wellbore. Potentiat Problems Torque and drag. Hole cleaning. Lost Circulation from low ressure zone or faults Interval Objectives Maintain adequate hole cleaning Use lubricants to maintain acce table for ue/Bra Burin build Production Interval Mud Properties Plastic LSRV API Fluid Depth MD Mud Wt. Viscosity Yield Point Low Shear Rate Loss (ft) (Ib/gal) (cP) (Ib/100ftZ) Viscosity (cP) (ml/30min) pH -10,555 - 12,430 8.4 8 -15 24 - 30 >25,000 7 - 9 9.0 - 9.5 Production Interval Fluid Formulation (for new fluid) Fresh Water Greencide Fro-V~s PLUS Caustic Potash KLA-GARD Conqor 404 Sodium Metabisulfite Lubetex Base Fluid 5 gal/100 bbls 2.0 Ib/bbl 0.25 Ib/bbl 6.0 Ib/bbl 0.8 Ib/bbl 0.07 Iblbbl" 4.0% v/v * added at the well site Mud to FLOPRO SF Displacement Recommendations / Clean the rig pits and flush all surface lines prior to taking on the F~oPRO SF fluid delivered from the M-I Mud Plant. Have vacuum trucks ready to haul-off displaced fluid prior to beginning the displacement to FLOPRO SF. / Mix up 50-60 bbl high vis spacer in the pill pit using 3.0 ppb FLO-Vis PLUS and water. / Drill-out the remaining cement treating any Ca++ contamination with Bicarb, SAPP, and Desco CF while maintaining the YP at 15 - 20. / Pump 100 bbls water from the rig brine tanks followed by the high viscosity spacer. / An optional 40-60 bbl lubricant spacer containing 10% by volume Steel Lube EP can be pumped behind the water and ahead of the high viscosity spacer. This spacer should be captured and discarded with the other spacers. / Pump the 8.4 Ib/gal F~oPRO SF at rates >250 gal/min while rotating the drill pipe to ensure minimal interface and a good displacement. / Monitor the shakers for the spacers. Discard the spacers and any contaminated FLOPRO SF drill-in fluid as Location North Slope Alaska Confidential 11 9/8/2005 / • C-10A needed to ensure the quality of the FLOPRO SF system. Production Interval Operations - An 8.4 Ib/gal F~oPRO SF will be used to drill the production interval. Use hot water to mix the FLOPRO SF system and have the fluid delivered to the rig site with a temperature of >95° F. - Drill ahead using FLO-Vis P~us/Water to adjust rheologies. Record the LSRV (Low Shear Rate Viscosity) and maintain an aggressive solids control program. - Due to the directional nature of the well, 4 % lubricant (Lubetex) is recommended. - Adjust rheology, ROP, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. See Virtual Hydraulics Modeling enclosure. - Ensure that the flow rate is at least 280 gpm to ensure adequate hole cleaning is being achieved. Pump a weighted sweeps (>2.5 Ib/gal over mud weight), monitor cuttings and ECD to avoid packing off the annulus and ensure good hole cleaning. - Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily cleanup or if there is any excess of torque, drag, pick-up or slack-off weights pump a weighted sweeps (>2.5 Ib/gal over existing fluid weight). Monitor cuttings across the solids control equipment and circulate at least three bottoms up if necessary prior to POOH. - Note- the final dry job prior to pulling out of the hole should be made from salt to minimize the amount of solids in the wellbore. - Maintain adequate rheologies prior to running the slotted production liner in to the well. Production Interval Concerns / ECD Control: Maintain a minimal ECD by maintaining adequate fluid properties to provide the best possible hole cleaning. Maintain mud weights as low as possible and ensure that rheology is optimized to reduce ECD's to a manageable level while drilling. Monitor for any fluid losses and flow back closely. / Hole Cleaning: Drilled formations may change the rheology of the mud - be prepared to treat the mud should this occur. Adjust rheology and drilling criteria to match the hole cleaning needs„ ROP's above 200 ft/hr. should be carefully monitored due to the modeled poor hole cleaning that will occur at these rates. Due to the high LSVR of the Ft_oPRO 5F system, high viscosity sweeps are not required. if sweeps are pumped they should be weighted sweeps (>2.5 Ib/gal over existing fluid weight). / Whole Mud Treatments: Whole mud dilutions are recommended if the MBT nears or exceeds 6 Ib/bbl. It is also important to maintain the drill solids content below 3% to reduce the possibility of any formation damage that may occur. / Lubricity: The F~oPRO SF will be ordered with 4% Lubetex. Add additional Lubetex if necessary. Maintain the required lubricant concentration through out the well while monitoring toque and drag indicators. Only if it becomes necessary, treat the casing/liner with Steel Lube EP in the form of a `Cube Sweep'. This `Cube Sweep' should be circulated inside the casing/liner only and the returning sweep caught: on the surface and properly disposed. The concentration for this sweep should be 8-12% EMI-920. If necessary this step can be repeated. / Lost Circulation: It is recommended to follow the Lost Circulation Decision Tree and have an adequate amount of lost circulation material on location. This well will be completed with a cemented liner. Fluid Location North Slope Alaska Confidential 12 9/8/2005 • ~ C-10A rheology should be maintained as not to increase the ECD. / Corrosion: As part of the `Corrosion Mitigation Program' maintain an adequate amount of Conqor 404 (corrosion inhibitor) and Sodium metabisulfite (oxygen scavenger) in the system at all times. Maintain a minimum of 5000 ppm concentration of Conqor 404 and <2.0 of dissolved oxygen. Report the test results on the Daily Mud Report. / Sliding: If additional lubricity is required for sliding, sweep the hole with a pill containing addition lubricant such as Lubetex and polymer beads. Alternatively, a pill containing Lubetex and Nut Plug (as allowed by MWD tools) to minimize clay to metal sticking has proven successful. Recommended Production Interval Solids Control Equipment Shakers • Inspect decking rubbers, c/o as necessary. • Install XR Magnum screens (200 - 250 mesh) as soon as possible. Ensure screens are properly tensioned, per M-I Swaco's best practice suggestions. Spray down new screens with fresh water before operating the shakers. • Set counterweights to 90% (7.8 G's) for optimum performance. • As fluid shears, screen up as necessary to higher mesh screen sizes. 200 mesh is optimum to reduce sand sized particles. • Ensure jacking system on ALSII or equivalent shakers enables the fluid to flow to the center of the screens, adjust and lock as necessary. De-Silter • Ensure cuttings trough bypasses shakers, and goes into cuttings ditch. Failure to do so will allow small particles to enter right back into system through the flow line shakers (84-110 mesh screens). • Install 3/8" Apexes. • Ensure that Feet of Head gauge is available at the De-Silter, not the pump. • Ensure that De-Silter feed pump can achieve 95' of head. CRITICAL! • Monitor discard, change apexes as necessary to improve solids content in mud. Discard should be 2 - 3 ppg over feed weight. Centrifuge • With the relatively low ROP seen in past Zone 2A wells the Solids Control Van should not be needed. • This additional piece or equipment has proven to be extremely valuable to reduce solids build up in the system. • Production intervals generally call fora "high-speed" centrifuge, which is rotating at approximately 3,200 rpm's. This allows the centrifuge to make the 3 - 6 micron cut, and eliminate a percentage of the "ultra fine" cuttings from the fluid. Through put must be decreased while running the centrifuge at 3,200 rpm's, since there is a greater risk of "packing off' the centrifuge back drive and auger. Swaco would also suggest installation of amp meter on the back drive motor which will allow the operators to monitor the feed rates by knowing how much torque the back drive motor is receiving while trying to discharge the cuttings. • Refer to mud man for solids information to determine speed and feed rate of centrifuge. • Continual processing at low feed rates will yield better results than shutting centrifuge down and starting it up. Slow feed rate down to maintain an acceptable weight if needed. • Run the centrifuge system all the time including while tripping. M-1 SWACO will have a complete inventory of shaker screens to use during this interval. Location North Slope Alaska Confidential 13 9/8/2005 • • t~-10A, Mi SWACQ VIRTUAL HYDRAULICS" S ~ ~ ~ areatua r.,,. -wrp. w..~..1 Geometry Depth Angle r4DirvDrcl c:gin Dia N~1 (I) o ~ ~ easo s Ism i e iosss 7.aa OA69 627 I 12430 6718 9028 6.125" hole at TD 4" drill pipe Density (Ib/gal) PV, YP, LSYP Pressure Loss (% ) zs m 7s tos Drill SVing BI An us DRILLING FLUID FLOPRO NT Mud WefgM BAS dgal Test Tenp 85°F SYSTEM DATA Fbw Rate 260 gathrin ROP 150fLfir RPM 90 rpm WOB 25 K b TFA S94 kt' PRESSURE LOSS (psi) ModMied Power Law Dril Strttg 445 Motw~MWD 302 /188 B! 151 Bt OrMDff 100 Annulus 300 SurfaeeEqup 6 U-Tube Press 95 Total System 1786 ESD ECD +Cut CsgBrae 8S2 8.91 9.12 TD 8S2 9.16 936 VRDH -Vrsim27.i f9s-C40AI.MDB MD: 12430 ft ~~, Operator: BP TVD: 9029 ft I Wel Nana: C-10A BI Sae: 6.125 in. Location: PBU Date: 9f/2005 Courrtry: US AV (ft/min) Hole Clean Ind ~ 2:o sm ~ K3 G F P s Location North Slope Alaska Confidential 14 9/8/2005 • C-10A Production Interval Hole Cleaning 4.0" DP Hole Cleaning Modeled at 8.4 Ib/gal with 100 RPM Hole Cleaning Summary - 6.125" Hole ROP DP RPM Pum GPM Fluid Wei ht Hole Cleanin Condition 100 60 275 8.4 Good 150 60 275 8.4 Good/Fair 200 60 275 8.4 Good 200 80 275 8.4 Good/Fair 200 80 300 8.4 Good 225 60 325 8.4 Fair Although the modeling shows relatively good hole cleaning, in cases where drill rates are sustained at >250 ft/hr. extra precautions should be made to keep the wellbore clean. 1. Extra time should be spent on circulation prior to connections and trips. 2. Adjust rheology if possible to help with hole cleaning. 3. Weighted high viscosity sweeps may help but should not be used as a primary cleaning strategy. 4. Maximized rpm while drilling and circulating will generally aid with hole cleaning. 5. Observe and chart pickup and slack off weights during each connection. Location North Slope Alaska Confidential 15 9/8/2005 VIRTUAL Flow Rate (gal/min) ~ - HYDRAULICS • • C-40A Lost Circulation Decision Tree Although the risk for loss circulation is low, be sure to have adequate Lost Circulation Material (LCM) on location. Follow the LCM Decision Tree when encountering lost circulation. Be sure to cycle open the PBL or circulation sub (if present) when pumping a lost circulation pill containing coarse lost circulation material. Since a slotted liner is being utilized in this completion, careful consideration should be taken before pumping any LCM. Discuss the type and size of any LCM pumped with the Project Engineer before pumping. Lost Circulation Flow Chart Losses Production Interval Seepage Partial/Severe 10-20 bbl/hr static 20•>60 bbUhr static If fault related, drill across V fault related, drill across faun as noted bebw. fault ~ noted below. Pump SO ppb LCM pill Pump 60 ppb LCM pill thru bit (volume wal be mru PBL (volume will W based upon Iona rata): based upon loss rate): 20 ppb Safe-Garb 70 15 ppb Safe~CarD 40 70 ppD Sah-Garb 20 20 ppb Safa-Garb 40 15 ppb Safetam 250 v r A second pill may be ro0ulrad Dased upon suedes / bnpset of flrsL Dynamic D,)n Losses <30 AMad bbghr N Y Dynant~ Ddu Pump SO ppb LCM pal cad LOSasf <30 Mru PBL (volume will be bbVhr based upon loss rats): 35 ppb Safa-Garb 10 15 ppb Safe-Garb 20 30 ppb Safe-Garb 40 Contact Drllang/Asset Engineer Prbr Evaluate Pumping seawater Dynamic Y Drill Losses <90 Ahead Dbllhr N ontact DdlVng/Aaset ngMeer prior Pump 95 ppb LCM pill thru Dlt (volume will be baaetl upon loss rate): 20 ppb Safa-Garb 40 p sewnd pill may De regWred based upon aueusa / Impact of flret. M MI FORM-M4ET pN wYl IF dynamic loss is sea >30 bbOhr a decision will ba M corlslderad V t6reua LCY has little efheL made if additional LCM treatments are to be made. Note: If losses are fault related, drill across fault 1 to 1.5 times the length of the throw befor Estimated fault throws are listed in the well plan. Location North Slope Alaska Confidential 16 9/8/2005 • • C-1 OA Completion Program A cemented production liner will be used in completing this interval. Seawater will serve as the completion fluid to displace the mud out of the 7.0" liner once the liner has been run. A high viscosity pert pill will be used to bump the plug followed by the seawater. HSE Issues Handling of Drilling Fluid Products Health and Safety - Drilling crews should be instructed in the proper procedures for handling fluid products. - Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. - PPE must be in good working order and be utilized as recommended by the PPE charts. - Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans), as much as possible in order to minimize inventory of partial units. - Ensure all MSDS sheets are up to date and readily available for workers to access for information. Environmental - Ensure that all product stored outside is protected from the weather. - Do not store partial units (sacks) outside if possible. - When transferring fluids and/or cuttings from the rig to tanks, ensure all hoses are properly secured. Perform a transfer checklist as needed in order to avoid spills. o ~ c~ o a Location North Slope Alaska Confidential 17 9/8/2005 • C-10A PPE Chart Product Function Health Flammabilit Reactivit PPE SPHASOL Shale Inhibitor 1 1 0 J BIOBAN BP Biocide *2 0 0 J BROMIDE 8~ NaBr brine Densifier 1 0 0 F CAUSTIC SODA Ikalinit control 3 0 1 X CAUSTIC POTASH Ikalinit control 3 0 1 X ITRIC ACID H Ad~uster 1 0 0 E ONCOR 404 orrosion Inhibitor 1 1 0 J DEFORM X Defoamer 1 1 0 J DESCO CF Dispersant 1 1 0 E DUAL-FLO Modified Starch 1 1 0 E DUOVIS iscosifier 1 1 0 E D-D CWT Fluids Additive 2 1 0 J FLOVIS iscosifier 1 1 0 E FLO LOBE Lubricant 1 1 0 J G-SEAL ra hite loss circulation 1 1 0 E ELEX Bentonite Extender 1 1 0 E GREEN CIDE 25G Biocide 3 0 0 J KLA-GARD hale Control 0 1 0 J LUBETEX Lubricant 1 1 0 J MI BAR ei htin A ent *1 1 0 E MI GEL iscosifier *1 1 0 E MI SEAL F, M, C Loss circulation material *1 1 0 E MIX II F, M, C Loss circulation material *1 1 0 E NUT PLUG Loss circulation material *1 1 0 E POLY PAC iscosifier, Fluid Loss Control *1 1 0 E POTASSIUM CHLORIDE hale Inhibitor, Densifier 1 0 0 E AFE CARB F, M, C Brid in & wei htin a ent *1 0 0 E SAFEKLEEN urfactant 1 1 0 J ALT (NACL) 8~ Brine olution Densifier 1 0 0 E SAPP Dispersant *1 0 0 E ODA ASH alcium recipitation 1 1 0 E ODIUM BICARB Ikalinit control 1 0 0 E SODIUM Meta Bisulfate x en Scaven er 1 1 0 J PERSENE CF Dis ersant 1 1 0 E CONCOR 404 Corrosion Inhibitor 1 1 0 J DEFORM X Defoamer 1 1 0 J DUAL FLO Fluids loss reducer 1 1 0 E DESCO CF Dispersant 1 1 0 E GREEN CIDE 25G iocide 3 0 0 J A ~ m O 0 6 Location North Slope Alaska Confidential 18 9/8/2005 • • C-1 OA HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIs) HAZARD RATINGS 4 -Severe hazard 3 -Serious hazard 2 -Moderate hazard 1 -Slight hazard 0 -Minimal hazard • An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIs PERSONAL PROTECTIVE EQUIPMENT INDEX A -Safety Glasses B -Safety Glasses, Gloves C -Safety Glasses, Gloves, Synthetic Apron D -Face Shield, Gloves, Synthetic Apron E -Safety Glasses, Gloves, Dust Respirator F -Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G -Safety Glasses, Gloves, Vapor Respirator H -Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator -Safety Glasses, Gloves, Dust and Vapor Respirator J -Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K -Air Line Hood or Mask, Gloves, Full Suit, Boots X -Consult your supervisor for special handling directions A 0 m O 0 Location North Slope Alaska Confidential 19 9/8/2005 • • TERRY L RUBBLE ss-eilz5z 223 BP EXPLORATION AK INC , PO BOX 196612 MB 7-5 'Mastercard Check" .ANCHORAGE, AK 99519-6612 DATE r PAY TO THE r.~, ORDER OF - $ C.V First National Bank-Alas a Anchorage AK( 99501 MEMO ~ i ~ (~ ~ ~: L 2 5 2 0 0 0 6 0 ~: 9 9 L 4 ~~~ 6 2 2 3 ••~ i 5 5 6.11• 0 2.2 3 • . ~ TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LEJTTER WELL NAME ~"/ ~'~ PTD# ~ aS' / ~ ~~_ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIS 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 well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\trans m ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT C-10A Program DEV Well bore seg ^ PTD#:2051370 Company BP EXPLORATION~ALASKA) INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mitfee attached - - - - - - - - - - - Yes - - - - - - 2 Lease number appropriate - - - - - - - Yes - - - - - - - - - - - 3 Uniquewell_nameandnumbe[ --------------- ----- --- ------- ----Yes- ----- -------------- ----------------- ------- --- -- ---------- ---- -- - 4 Well locatedin_a_definedpool___________________________ ____.-_-._-Yes_ __-_--PRl1DH0El~AY,_P_RUDHOEOIL-640150____-__--______.-__---_---.__.___--_--_..- 5 Well located proper distance from drilling anitboundary_ . , _ - - . _ - .. _ -Yes - _ - - _ _ .Governed by CO 341 D: no restrictions as to well spacing except That no_pay open closer than 500' to _ - . _ _ . 6 Well located proper distance from other wells__________________ ______,-__.Yes_ _.._externalboundary,which is 31,500'away,_-_-__-___.-______.__..___-___-____-.___-- 7 Sufficient acreageayailablein_drillingun~____________________ ____________Yes_ ____-___--__--____-_..-_...___.___.-__.__-.__- --------------------------- 8 If deviated, is.wellborep1at-included - - Yes - - - - - - - - - - - - - 9 Ope[atoronlyaffectedparty--------------------------- ------------Yes- ------------------------ 10 Operatorhas_appropriate-bond in force -------------------- ------- -- Yes- ------ -...------------ ---------- -- -- - ------------- ---------- --- 11 Pe[miteanbeissuedwithoutconservationorder-__-___-__-___ _______-____Yes- --_...__.______________________--_-_--_-.._--__-.___.-__--.__-.-__.. Appr Date 12 Pe[mitcanbeissuedwithoutadministrative_approval_____________ ____________Yes. ___.-__--_-_.__--___--__.-_--__-----_-.-_-.__--__--__..__.-__---___-.-__ SFD 9!21!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorizedby_InjectionOrde[#(put10# in_comments)-(For_NA.- ___--------------------------------------------------------------- ----- 15 All wells within1/4_mileareaofreyiewjdentified(FOrsenricewe!!only)--- ------------ NA _ __-___-__--.___.____._--.___--__--__--___-__-- ---------------------------- 16 Pre-produced injector: duration of pre production less than 3 months_(For service well only) NA_ 17 ACMP-Finding of Consistency_hasbeenissuedforthisproject__.___-_ ____-_-..-NA-- __--__Redril_lof existing well-------------____.----------._-__-..__.-__--__--__-_-. Engineering 18 Conductor string_provided - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - 19 Surface casing_p_rotectsallkvown USDWs - - - NA- - - - - - - - - - - - 20 CMT_vol-adeguate_tocirculate-onconductor&surf-csg_.__..__--_ _-.-_._.-. NA._ ___.__-__________________________________ ________-.._---_-.____--__. 21 CMT_vol_adequate_totie-in long string to su_rfcsg - - - - - - - NA- - - - - - - - - - - - - - 22 CMT,willcoyer_allknow_n-productiyehorizons__________________ _-._.-.-...Yes- __.-__Adequateexcess,__---.__--__-___-__-------.-_-.__--__..__--__-___--.-_-. 23 CasiogdesignsadequaleforC,.T.,B&.permafCost--------------- ------------Yes- ------------------------------------------------------------------. 24 Adequate tankage_or reserve pit - - - - - - - - - - Yes - - Nabo[s 2E$, - - - - - - - - - - - - 25 Ifa_re-d[ill,has.a10-403 for abandonment been app.roved-___-____ _--___..__. Yes_ -__..-918/2006,-________________________._-..__--__.-_-..--_-.__.___.. _._ 26 Adequatewellboreseparationproposed-------- -- -------- ------------Yes- ---------------------- ------------- --- ------------- -------------- --- 27 If_diverterrequired,doesitmeetregulatigns______.-__.-_-.__ -___----_-. NA_- __.-__Sidetrack____________________.__..__..________.-__.__..-_-.___--.-__.- Appr Date 28 f)rillingfluid.programsehematic&e0.uiplistadequate_-_._.__ ____._-._Ye5- _____MaxMN!-10,7_ppg.__________.__-__...-_______________________________ WGA 912212005 29 BOPEs,dotheymeetregulation_-__.__.______.____--- ------------Yes_ ____._-__.-_-_______.-__.-___-.-_-.-_-.-_..___--_-.-_..-.-_--_.__..-_- 30 BOPE_pressratingapp[opriafe;festto_(putpsigipcomments)_-_--_ ________.___Yes_ ____.Testt_03500.psi._MSP2304psi_____________ ___________________________________ 31 Choke_manifoldcompliesw/API_RP-53(May84)---------------- -----------Yes- -------------------------------------------------------.-------------- 32 Work willoccu[withoratoperationshutdow.n__--___,_________ _______ ____Yes. __.___..__.______._____.__._______.-_-----_--__--__..__..-_._-_-.--___ 33 Is presence- of H2S gas. probable - - - - - - N~- - - NOt an H2S pad. - - - - - - - - - - - - - 34 Mechanical condition of wells within AOR verified (Forservice well only) _ _ _ - _ NA_ - _ Geology 35 Permit can be issued wlo hydrogen, sulfide measures - - - - -- - - - - - - - - - - - - - - No- _ _ - _ - - H2S has been detected at C-Pad. _Operations_plan calls-for_H2S standard operating procedures._ . - . - . _ - . 38 Data_plesented on potential overpressure zones- - - - - - - - - - - - - - - - - - - - - -Yes - . _ _ - . Will be drilled from KOP_t4 tl$ag_with 10.5 to 10.7 ppg mud. Expected reservoir-pressure is.6.9 ppg EMW;_ - - Appr Date 37 Seismic analysis of shallow gas zones_ _ - - - _ - _ .. _ - _ _ - - . - _ - .. NA_ - _ _ _ - _ will be drilled with-8.4 to 8,6_ppg mud-- - - - - - - - - - - - -- - - - --------------------------- SFD 9!21!2005 38 Seabed condition survey-(ifoff-share) - - - - - - NA - - - - - - - - - - - - - - - - - 39 -Conta-ctnam_elphonefpr_weeklyprogresslepo[ts[expl4ratoryonly]_____ ____________NA__ _______-__-.___..__.__.__--__--.__-..-_.-__..__--__..__--__-.__-._.-- Geologic Engineering Date Date: Date Commissioner: mmi Commissioner: ~~~~ er 9 6 ~~ ~ Z ~~ f Pages Laos- i37 in the appendix have not been microfilmed. • Well History File APPENDIX • Information of detailed nature that is not particularly germane io 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. ~~AN~E~ MAR ~ ~ ?_Q0 • C-lOA,txt Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib $Revision: 4 $ wed Jan 30 11:59:48 2008 Reel Header service name .............LISTPE Date . ...................08/01/30 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/01/30 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name......,UNKNOWN Comments .................STS LIS Writing Library. • Scientific Technical services scientific Technical services Physical EOF TAPEeHEADER rd ~ ~ I~E~ MAR ~. 9 2008 Prudhoe say MWD/MAD LOGS WELL NAME: C-l0A API NUMBER: 500292037101 OPERATOR: BP Exploratio n Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 30-JAN-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 Job NUMBER: Mw-000399215 MW-000399215 MW-000399215 LOGGING ENGINEER: A. SHANAHAN A. SHANAHAN A. SHANAHAN OPERATOR WITNESS: J. BALL J. RALL J. RALL MWD RUN 4 MAD RUN 4 JOB NUMBER: Mw-000399215 Mw-000399215 LOGGING ENGINEER: C.A. DEMOSKI C.A. DEMOSKI OPERATOR WITNESS: D. MASKELL D. MASKELL SURFACE LOCATION SECTION: 9 TOWNSHIP: 11N RANGE: 14E FNL: FSL: 775 FEL: FWL: 1222 Page 1 ~a~=t3~ `~ ~5~~ C-lOA.txt ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 62.32 GROUND LEVEL: 33.82 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8505.0 2ND STRING 8.500 9.625 8505.0 3RD STRING 6.125 7.000 10400.0 PRODUCTION STRING 6.125 7.000 10400.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 8505' MD/6742'TVD, IN THE C-10 WELLBORE. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL WINDOW AND IS NOT PRESENTED ON THE LOGS. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). MWD RUNS 1-2 ALSO INCLUDED DRILLSTRING DYNAMICS (DDS). MWD RUNS 3-4 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUN 4 ALSO INCLUDED AZIMUTHAL LITHO- DENSITY (ALD) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). MAD PASS DATA WERE ACQUIRED OVER A PORTION OF MWD RUN 3 INTERVAL PRIOR TO DRILLING. POROSI DATA WERE MERGED WITH MWD RUN 4 DATA. MAD PASS GAMMA AND RESISTIVITY DATA PRESENTED SEPARATELY. 4, DEPTH SHIFTING WAIVED AS PER INSTRUCTIONS RELIEVED FROM DOUG DORTCH (SAIL/BP ON 16 NOVEMBER 2007, AS AUTHORIZED BY DOUG STONER (BP). MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-4 REPRESENT WELL C-10A WITH API# 50-029-20371-O1. THIS WELL REACH A TOTAL DEPTH (TD) OF 12,360' MD/9026'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP Page 2 • C-lOA.txt SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 2500-3000 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS FET RPX ROP NPHI NCNT FCNT PEF RHOB DRHO 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8496.0 8500.0 8500.0 8500.0 8500.0 8500.0 8505.0 10782.0 10782.0 10782.0 10798.0 10798.0 10798.0 BASELINE CURVE FOR SHIFTS: STOP DEPTH 12294.5 12301.5 12301.5 12301.5 12301.5 12301.5 12360.0 12266.0 12266.0 12266.0 12283.0 12283.0 12283.0 Page 3 • CURVE SHIFT DATA BASELINE DEPTH 10865.0 10874.5 10884.5 10924.5 10930.5 10996.0 11014.0 11058.0 11067.5 11071.0 11090.0 11093.5 11150.0 11153.0 11231.0 11234.5 C-lOA.txt (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- GR 10859.5 10869.5 10881.0 10920.5 10925.5 10991.0 11009.5 11053.0 11061.5 11066.0 11084.0 11088.0 11143.5 11147.5 11226.0 11229.0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 8505.0 2 8533.0 3 10400.0 4 11384.0 REMARKS: MERGED MAIN PASS. MERGE BASE 8533.0 10400.0 11384.0 12360.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ................... .-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD G/CC 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Page 4 • C-lOA.txt Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8496 12360 10428 7729 8496 12360 FCNT MWD CNTS 312 1192 595.623 2969 10782 12266 NCNT MWD CNTS 21570 37796 29025.1 2969 10782 12266 RHOB MwD G/CC 2.072 2.9 2.35154 2971 10798 12283 DRHO MWD G/CC -0.029 0.459 0.0814561 2971 10798 12283 RPD MwD OHMM 0.43 2000 43.7391 7604 8500 12301.5 RPM MWD OHMM 0.42 1940.22 26.4428 7604 8500 12301.5 RPS MWD OHMM 0.37 1942.01 19.3821 7604 8500 12301.5 RPX MWD OHMM 0.33 2000 16.8413 7604 8500 12301.5 FET MWD HOUR 0.37 52.63 2.837 7604 8500 12301.5 GR MwD API 12.19 528.06 92.3807 7598 8496 12294.5 PEF MWD G/cc 1.31 5.43 2.23371 2971 10798 12283 ROP MWD FT/H 0.4 282.95 84.1774 7711 8505 12360 NPHI MwD PU-S 14.97 35.4 25.2719 2969 10782 12266 First Reading For Entire File..........8496 Last Reading For Entire File...........12360 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/01/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLI6.001 comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10809.5 11323.0 FET 10816.5 11330.0 RPx 10816.5 11330.0 RPS 10816.5 11330.0 RPM 10816.5 11330.0 RPD 10816.5 11330.0 RAT 10875.0 11389.0 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE Page 5 • MWD 4 1 REMARKS: MERGED MAD PASS. C-lOA.txt 10782.0 11389.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 RPD MAD OHMM 4 1 68 8 3 RPM MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPX MAD OHMM 4 1 68 20 6 FET MAD HOUR 4 1 68 24 7 GR MAD API 4 1 68 28 8 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 10809.5 11389 11099.3 1160 10809.5 11389 RAT MAD FT/H -1.5 160.62 111.046 1029 10875 11389 RPD MAD OHMM 5.19 58.59 20.3258 1028 10816.5 11330 RPM MAD OHMM 4.76 43.68 17.003 1028 10816.5 11330 RPS MAD OHMM 4.52 35.43 14.3742 1028 10816.5 11330 RPX MAD OHMM 3.68 31.46 13.6618 1028 10816.5 11330 FET MAD HOUR 18.22 38.2 27.9445 1028 10816.5 11330 GR MAD API 13.29 170.18 35.7966 1028 10809.5 11323 First Reading For Entire File..........10809 Last Reading For Entire File...........11389 File Trailer Service name... .......sTSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/O1/30 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number...........1.0.0 Page 6 • • C-lOA.txt Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8505.0 8533.0 LOG HEADER DATA DATE LOGGED: 15-OCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8533.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 54.5 MAXIMUM ANGLE: 54.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8505.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 62.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 1200 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 134.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 7 • C-lOA.txt Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8505 8533 8519 57 8505 8533 ROP MWDO10 FT/H 0.62 16.07 4.57228 57 8505 8533 First Reading For Entire File..........8505 Last Reading For Entire File...........8533 File Trailer service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8496.0 10363.0 RPS 8500.0 10355.5 Page 8 • C-lOA.txt RPX 8500.0 10355.5 RPD 8500.0 10355.5 FET 8500.0 10355.5 RPM 8500.0 10355.5 ROP 8533.5 10400.0 LOG HEADER DATA DATE LOGGED: 18-OCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10400.0 TOP LOG INTERVAL (FT): 8496.0 BOTTOM LOG INTERVAL (FT): 10363.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 15.6 MAXIMUM ANGLE: 54.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8505.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 43.0 MUD PH: g,3 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUR E (MT): 1.020 70.0 MUD AT MAX CIRCULATING TER MPERATURE: .503 149.0 MUD FILTRATE AT MT: .980 70.0 MUD CAKE AT MT: 1.200 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Page 9 • • C-lOA.txt Absent value .... ..................-999 Depth Units. .. .. ..... Datum Specificat ion Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 6$ 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8496 10400 9448 3809 8496 10400 RPD MWD020 OHMM 0.51 2000 7.22405 3712 8500 10355.5 RPM MWD020 OHMM 0.5 1940.22 3.91485 3712 8500 10355.5 RPS MWD020 OHMM 0.52 1763.34 2.77702 3712 8500 10355.5 RPX MWD020 OHMM 0.51 1621.75 2.61902 3712 8500 10355.5 FET MWD020 HOUR 0.37 52.54 2.0243 3712 8500 10355.5 GR MWD020 API 40.9 414.63 147.463 3735 8496 10363 ROP MWD020 FT/H 2.8 282.95 91.4077 3734 8533.5 10400 First Reading For Entire File..........8496 Last Reading For Entire File...........10400 File Trailer Service name... .......STSLIB.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY Page 10 r C-lOA.txt VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 10356.0 11329.0 FET 10356.0 11329.0 RPX 10356.0 11329.0 RPM 10356.0 11329.0 RPD 10356.0 11329.0 GR 10363.5 11322.0 ROP 10400.5 11384.0 LOG HEADER DATA DATE LOGGED: 21-OCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11384.0 TOP LOG INTERVAL (FT): 10363.0 BOTTOM LOG INTERVAL (FT): 11323.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 15.4 MAXIMUM ANGLE: 92,7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10400.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 46.0 MUD PH: $,9 MUD CHLORIDES (PPM): 2700 FLUID LO55 (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.100 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .672 125.5 MUD FILTRATE AT MT: .950 74.0 MUD CAKE AT MT: 1.200 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Page 11 C-lOA.txt Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 SCRC MWD030 API 4 1 68 24 7 RoP MwD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10356 113$4 10870 2057 10356 11384 RPD MWD030 OHMM 0.43 2000 142.91 1947 10356 11329 RPM MWD030 OHMM 0.42 1785.04 82.3628 1947 10356 11329 RPS MWD030 OHMM 0.37 1942.01 57.7605 1947 10356 11329 RPX MWD030 OHMM 0.33 2000 48.7515 1947 10356 11329 FET MwD030 HOUR 0.65 52.63 3.93046 1947 10356 11329 SCRC MWD030 API 12.19 528.06 43.8074 1918 10363.5 11322 ROP MWD030 FT/H 1 235.31 70.0541 1968 10400.5 11384 First Reading For Entire File..........10356 Last Reading For Entire File...........11384 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 Page 12 • C-lOA.tXt DE PTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 10782.0 12266.0 NPHI 10782.0 12266.0 NCNT 10782.0 12266.0 DRHO 10798.0 12283.0 PEF 10798.0 12283.0 RHOB 10798.0 12283.0 GR 11322.5 12294.5 RPM 11329.5 12301.5 RPX 11329.5 12301.5 FET 11329.5 12301.5 RPD 11329.5 12301.5 RPS 11329.5 12301.5 ROP 11384.5 12360.0 LOG HEADER DATA DATE LOGGED: 23-OCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT); 12360.0 TOP LOG INTERVAL (FT): 10782.0 BOTTOM LOG INTERVAL (FT): 12295.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.7 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 130908 ALD Azimuthal Litho-Den 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10400.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 46.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 2500 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .500 89.0 MUD AT MAX CIRCULATING TERMPERATURE: .333 137.0 MUD FILTRATE AT MT: 1.000 78.0 MUD CAKE AT MT: 1.250 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Page 13 • TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: C-lOA.txt Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Di rection .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CC 4 1 68 12 4 DRHO MwD040 G/cc 4 1 68 16 5 RPD MwD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MwD040 API 4 1 68 40 11 PEF MWD040 G/CC 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MwD040 Pu-s 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10782 12360 11571 3157 10782 12360 FCNT MWD040 CNTS 312 1192 595.623 2969 10782 12266 NCNT MWD040 CNTS 21570 37796 29025.1 2969 10782 12266 RHOB MWD040 G/CC 2.072 2.9 2.35154 2971 10798 12283 DRHO MWD040 G/CC -0.029 0.459 0.0814561 2971 10798 12283 RPD MWD040 OHMM 6.76 24.65 14.1552 1945 11329.5 12301.5 RPM MWD040 OHMM 6.02 24 13.4595 1945 11329.5 12301.5 RPS MWD040 OHMM 5.48 22.36 12.6548 1945 11329.5 12301.5 RPX MWD040 OHMM 5.62 21.1 12.0412 1945 11329.5 12301.5 FET MWD040 HOUR 0.65 24.32 3.29345 1945 11329.5 12301.5 GR MWD040 API 15.05 139.05 34.5052 1945 11322.5 12294.5 PEF MWD040 G/CC 1.31 5.43 2.23371 2971 10798 12283 ROP MWD040 FT/H 0.4 195.31 86.9102 1952 11384.5 12360 NPHI MwD040 Pu-S 14.97 35.4 25.2719 2969 10782 12266 First Reading For Entire File..........10782 Last Reading For Entire File...........12360 File Trailer Service name... .......STSLIB.006 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Page 14 C-lOA.txt Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EoF File Header Service name... .......STSLIB.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10809.5 RPM 10816.5 FET 10816.5 RPx 10816.5 RPS 10816.5 RPD 10816.5 RAT 10875.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD STOP DEPTH 11323.0 11330.0 11330.0 11330.0 11330.0 11330.0 11389.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuthal Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): Page 15 23-OCT-05 Insite 6.02 Memory 12360.0 10782.0 11323.0 87.7 95.4 TOOL NUMBER 087225 1844674407370955 130908 1050894 6.125 10400.0 • C-lOA.txt BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 46.0 MUD PH: $,5 MUD CHLORIDES (PPM): 2500 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .500 89.0 MUD AT MAX CIRCULATING TERMPERATURE: .333 137.0 MUD FILTRATE AT MT: 1.000 78.0 MUD CAKE AT MT: 1.250 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MAD041 OHMM 4 1 68 4 2 RPM MAD041 OHMM 4 1 68 8 3 RPS MAD041 OHMM 4 1 68 12 4 RPX MAD041 OHMM 4 1 68 16 5 FET MAD041 HOUR 4 1 68 20 6 GR MAD041 API 4 1 68 24 7 RAT MAD041 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10809.5 11389 11099.3 1160 10809.5 11389 RPD MAD041 OHMM 5.19 58.59 20.3258 1028 10816.5 11330 RPM MAD041 OHMM 4.76 43.68 17.003 1028 10816.5 11330 RPS MAD041 OHMM 4.52 35.43 14.3742 1028 10816.5 11330 RPX MAD041 OHMM 3.68 31.46 13.6618 1028 10816.5 11330 FET MAD041 HOUR 18.22 38.2 27.9445 1028 10816.5 11330 GR MAD041 API 13.29 170.18 35.7966 1028 10809.5 11323 RAT MAD041 FT/H -1.5 160.62 111.046 1029 10875 11389 First Reading For Entire File..........10809.5 Last Reading For Entire File...........11389 Page 16 • C-lOA.txt File Trailer Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/01/30 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/01/30 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/01/30 Ori9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library Physical EoF Physical EOF End Of LIS File • scientific Technical services scientific Technical Services Page 17
