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201-148
• 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg S N ED AUG 1 7 20 2 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 � 1-1 Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A 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, L 4 14 - 9 - Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) A -Pad Date: 04/15/2012 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 A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A -03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A -04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 1 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 , A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 _ NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU A -25A Oper. Rep: Jack Winslow PTD No.: 2011480 Oper. Phone: 659 -5766 Location Verified? No - Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 11/22/01 Date AOGCC Notified: Sundry No.: Well Completion Rpt - Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing SSV closed - Photos Taken? Yes ✓ IA 1050 by Operator OA 10 Condition of Wellhead: Well house in place, full tree with closed SSV, flow line removed and blinded. Condition of OK Surrounding Surface Location: Follow Up Actions Bleed IA pressure and monitor. Well bore diagram indicates open hole has been P&A'd. Needed: Attachments: None REVIEWED BY: Insp. Supry Comm Il i PLB 08/2010 2010- 0911_Suspend_PBU_A- 25A_cs.xls , # STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1 b. 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. 7/23/2011 . 201 - 148 311 -008 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 11/16/2001 , 50 - 029 - 20764 - - 4a. Location of Well (Govemmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/18/2001 , PBU A -25A 2651' FNL, 1703' FEL, Sec. 35, T11 N, R13E, UM 8. KB (ft above MSL): 79 98' 15. Field / Pool(s): Top of Productive Horizon: N/A GL (ft above MSL): 50.48' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 3799' FSL, 3819' FWL, Sec. 25, T11N, R13E, UM 8179' 6058' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 653697 y- 5947780 Zone- ASP4 13092' 9138' ADL 028286 TPI: x- y- Zone- 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 659081 y- 5954344 Zone- ASP4 N/A 18. Directional Survey: ❑ Yes El 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 logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, GR, RES, DEN, NEU 12109' 8599' 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. 10' 36" 8 cu vds Concrete 13 -3/8" 72# L -80 Surface 3152' Surface 2768' 17 -1/2" 4365 cu ft Permafrost 9-5/8" . 47# L -80 Surface 11958' Surface 8481' 12 -1/4" 1610 cu ft Class 'G' 7" 26# IJ4S 11486' 12109' 8131' 8599' 8 -1/2" 420 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): None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ECEI !v . • , DEPTH INNTTEERRVAL (MD4 Set EZSV UNT AND KIND OF MATERIAL USED SEP 0 7 20P 8179' Set Whipstock • Alitskn 0ii & AAR futile f`.Iran'rerjjegj 27. Al ,�� PRODUCTION TEST • ;, , -tM4 Date First Production: • •` �' "' Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A 1 Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® 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. nil None 8 R SEP 0 8101 '.), 3 4 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only J 29. GEOLOGIC MARKERS (List all formations and marks countered): 30. - TION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadierochit 12109' 8599' None Zone 4A 12309' 8738' Zone 3 12393' 8786' Zone 2C 12536' 8862' Zone 2B 12632' 8905' Zone 2A 12940' 9055' Formation at Total Depth (Name): • 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing i true and correct to the best of my knowledge. CR/ Signed: Terrie Hubble Title: Drilling Technologist Date: / 07( 1 PBU A - 25A 201 - 148 311 - 008 Prepared By Name/Number Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Jesse Rosenbaum, 564 -5155 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • A -25A, Well History (Pre Rig Sidetrack) Date Summary 3/22/2011 T /I /0= 450/240/60 CMIT -TxIA PASSED to 3000 psi (Pre Rig). Pumped 11.3 bbls DSL down the TBG to pressure up the TBG & IA to 3000/3000 psi. TBG /IA lost 20/20 psi in 15 minutes and 20/20 psi in the second 15 minutes for a total 30 minute loss of 40/40 psi. Attempted 2nd test without needing to repressure TBG /IA. TBG /IA lost 20/20 psi in the 1st 15 mins and 20/0 psi in the 2nd 15 mins. Monitored for additional 15 mins with a 0/0 psi loss observed on the TBG /IA. Bled TBG /IA (12 bbls fluid). Unable to perform MIT -OA due to scaffolding. FWHPs= 60/100/40 3/28/2011 T /I /0= SI /100/20 Temp =Sl PPPOT-T (PASS) PPPOT -IC (PASS) (Pre RIG) PPPOT -T: RU 1 HP BT onto THA 50 psi psi bled to 0 psi, flushed void until clean returns achieved. Pressure void to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, cycle and torque LDS "Standard" all were in good working and visual condition. RD all test equipment. PPPOT -IC: RU 1 HP BT onto IC test void 0 psi, verified with SBS. Pressure IC to 3500 psi for 30 minute test, 3400/ 15 minutes, 3400/ 30 minutes. Bled void to 0 psi. Cycle LDS "Standard" (1) LDS @ 1:00 position was tight but moving all others were in good working and visual condition. RD all test equipment. 3/28/2011 T /I /O= SSV /110/20. Temp= SI. MIT -OA to 2000 psi ** *PASS * ** (Pre -rig). No AL or flowline. OA FL @ surface. Pumped .83 bbls of diesel into OA to achieve test pressure. During 1st 15 mins, OAP lost 40 psi. During second 15 mins, OAP lost 10 psi for a total of 50 psi during 30 min test. Bled OAP from 1960 psi to 20 psi to slop tank in 30 mins (1.33 bbls fluid). Job Complete. Final WHPs= SSV /110/20. 7/3/2011 T /I /O = SSV /60/100. Temp = SI. Bleed IA and OA to 0 psi (Pre Rig). Flowline removed. IA FL @ 84', OA FL @ surface. Bled OAP to slop trailer from 100 psi to 0 psi in 10 minutes, Bled IAP to slop trailer from 60 psi to 0 psi in 20 minutes. Monitor for 30 minutes. OAP remained @ 0 psi, IAP increased 2 psi. Final WHPs = SSV /2/0. 7/3/2011 T /I /0= SSV /4/6. Temp= SI. WHPs (Post IA and OA bleed). Flowline removed. Integral installed on IA. Temporary scaffolding built, but not inspected. IAP increased 2 psi and OAP increased 6 psi overnight. 7/7/2011 T /I /0= 50/0 + /0 +. Temp= SI. WHPs (SU well). No AL or flowline.BPV crew in control of well on departure. 7/8/2011 T /I /O= 0/0/0; Set CIW "H" BPV #149 thru tree for Doyon 25 pre -rig and install 3 -1/8" CIW HWO gate valve onto existing I/A valve (piggyback) Page 1 of 1 i • North America ALASKA - BP Page 1 ate' Operat Summary Report Common Well Name: A -25 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 7/7/2011 End Date: 8/9/2011 X3- 00Y3D -C (2,997,508.00 ) Project: Prudhoe Bay I Site: PB A Pad Rig Name /No.: DOYON 25 1 Spud Date/Time: 11/16/2001 12:00:OOAM I Rig Release: 8/9/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292076400 Active Datum: A -25B @90.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/14/2011 00:00 - 12:00 12.00 MOB P PRE FINISH SECURING LINES IN DERRICK AFTER LAYING DOWN. SKID PIPE SHED COMPLEX AWAY FROM SUB IN PREPARATION FOR RIG MOVE. CONT MAINTENANCE ITEMS - WELDING LAYDOWN MACHINE STABILIZER AND PIT TO SUB WEATHER STRIPPING. [ 12:00 - 20:00 8.00 r MOB P PRE COMPLETE RIG MAINTENANCE ITEMS AND PREP CASING SHED COMPLEX AND PIPE SHED COMPLEX FOR RIG MOVE. LOWER SUSPENSION AND PIN IN PLACE. 20:00 - 00:00 4.00 MOB P PRE PJSM. HOOK UP PEAK SOWS TO CASING AND PIPE SHED MODULES. BEGIN RIG MOVE ' FROM K PAD TO A PAD. 7/15/2011 00:00 - 12:00 12.00 MOB P PRE USE PEAK SOWS TO MOVE TWO MODULES I AT A TIME FROM K PAD TO A PAD. SPOT ALL SIX MODULES IN STAGING AREA ON A PAD. 12:00 - 20:00 8.00 MOB P PRE I CONTINUE MOVING MODULES TO STAGING - i — AREA ONAPAD. 20:00 - 00:00 4.00 MOB P PRE ALL MODULES AT A PAD. SPOT PUMP, PITS, AND POWER COMPLEXES NEXT TO WELL A -25. BEGIN LAYING RIG MATS AROUND WELLHOUSE IN PREPARATION FOR MOVING THE SUB OVER THE WELL. 7/16/2011 00:00 - 04:00 4.00 MOB P PRE CONTINUE LAYING RIG MATS IN PREPARATION FOR THE DRILLING SUB. 04:00 - 05:00 1.00 RIGU P PRE , MOVE DRILLING SUB OVER RIG MATS TO , WELL A -25. 105:00 - 07:30 2.50 RIGU N RREP PRE HYDRAULIC LINE FAILURE ON MOVING SYSTEM OF THE RIG SUB COMPLEX. CLEAN UP HYDRAULIC FUILD AND REPAIR HOSE. 07:30 - 11:00 3.50 RIGU P PRE CONTINUE MOVING SUB AND SPOT OVER + ,WELL A -25. 11:00 - 16:00 5.00 RIGU P PRE USE STOMPERS TO MANEUVER PIPE SHED COMPLEX IN POSITION NEXT TO SUB. SIMOPS: MOVE RIG MATS WITH LOADER TO r PREP FOR SPOTTING OTHER MODULES. 16:00 - 20:00 4.00 RIGU P PRE MOVE CASING SHED COMPLEX AND SPOT ' INTO POSITION NEXT TO DRILL PIPE COMPLEX. 20:00 - 00:00 4.00 RIGU P PRE PJSM. RAISE DERRICK AND SKID RIG FLOOR. INSTALL HANDRAILS AND LOWER ISTAIRWAYS ON CSG SHED AND SUB. 7/17/2011 00:00 - 12:00 ! 12.00 RIGU P PRE I SHIM SUB, PIPE SHED, AND CASING SHED MODULES. SPOT AND SHIM PITS, PUMP, AND POWER COMPLEXES. R/U LINES, RAISE CATTLE CHUTE AND SECURE. - SPOT 500 BBLS BLEED DOWN TANK, CHOKE SKID, AND HARDLINE. 12:00 - 21:30 9.50 RIGU P PRE TAKE UP SLACK ON DRLG LINE, UNPIN TOPDRIVE FROM DERRICK, R/U BRIDAL LINES, AND PERFORM DERRICK INSPECTION. SCOPE DERRICK UP, R/D BRIDAL LINES, AND LOWER C- SECTION. R/U AND INSTALL UPPER CATTLE CHUTE. Printed 9/6/2011 9:11:45AM orth America - ALASKA - BP Page 2 oil* pleration Summary Report Common Well Name: A -25 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/7/2011 End Date: 8/9/2011 X3- 00Y3D -C (2,997,508.00 ) Project: Prudhoe Bay Site: PB A Pad Rig Name /No.: DOYON 25 Spud Date/Time: 11/16/2001 12:00:OOAM Rig Release: 8/9/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292076400 Active Datum: A -25B @90.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 22:30 1.00 RIGU P PRE - TAKE ON 8.5 PPG SEAWATER TO THE MUD PITS. - INSTALL C- SECTION CUSHIONS AND LOWER INTO PLACE RIG ACCEPT 21:30 HRS ON 7/17/2011. 22:30 - 00:00 1.50 RIGU P PRE - RU AND PRESSURE TEST OA VALVE TO 500 PSI FOR 5 MIN. GOOD TEST. - INSTALL 2ND WORKING VALVE ON OA. - RU FOR PRESSURE TESTING IA AND OA. 7/18/2011 00:00 - 04:30 4.50 RIGU P PRE FINISH RIGGING UP LINES TO WELLHEAD TO PERFORM MIT USING INJECTION PUMP. MIT OA TO 250 PSI FOR 5 MIN AND 2000 PSI FOR 30 MIN - TEST PASSED - WTL APPROVAL TO CONTINUE OPERATIONS 6.4 BBLS TO REACH TEST PRESSURE - LOST 50 PSI IN FIRST 15 MIN LOST 15 PSI IN SECOND 15 MIN - 6.4 BBLS RETURNED MIT T X IA TO 250 PSI FOR 5 MIN AND 2000 PSI FOR 30 MIN - TEST PASSED - WTL APPROVAL TO CONTINUE OPERATIONS - 7.2 BBLS TO REACH TEST PRESSURE - LOST 42 PSI IN FIRST 15 MIN - LOST 14 PSI IN SECOND 15 MIN - 7.2 BBLS RETURNED 04:30 - 05:00 0.50 RIGU P PRE ' R/D TEST EQUIPMENT AND BLOW DOWN LINES. 05:00 - 05:30 0.50 RIGU P PRE R/U LONG BAILS AND CALIBRATE BLOCK 05:30 06:30 1.00 WHSUR P DECOMP HEIGHT. ACTIVATE ZONE MANAGEMENT. } ZONE IPJSM. PICK UP LUBRICATOR TO RIG FLOOR. - R/U AND TEST TO 250 PSI FOR 5 MIN AND 3500 PSI FOR 5 MIN. GOOD TEST. PULL BPV - R/D LUBRICATOR i t -- — --- - - -- -- - 06:30 - 07:00 0.50 WHSUR P DECOMP R/U TO DISPACE FREEZE PROTECT FROM WELL. 07:00 - 08:00 1.00 WHSUR P DECOMP TEST EMERGENCY SHUTDOWN SYSTEM ON RIG. 08:00 10:00 2.00 WHSUR - SYSTEM FUNCTIONED PROPERLY P DECOMP PJSM FOR DISPLACING FREEZE PROTECT. 1 - PUMP 62 BBLS 8.4 PPG SEAWATER DOWN IA AND DISPLACE FREEZE PROTECT TO 500 BBL OPEN TOP TANK. - R/U AND PUMP 205 BBLS SEAWATER DOWN TUBING, TAKING RETURNS TO OPEN TOP TANK. 34 BBLS OF DIESEL RETURNED FROM TBG, 118 BBLS OF DIESEL RETURNED FROM IA. - TOTAL VOLUME PUMPED 267 BBLS, TOTAL VOLUME RETURNED 267 BBLS. - MONITOR WELL FOR 10 MIN - STATIC. 10:00 - 12:00 2.00 WHSUR P DECOMP DRY ROD IN TWC AND TEST FROM ABOVE TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MIN - GOOD TEST. TEST FROM BELOW TO 250 PSI LOW / 2000 PSI HIGH FOR 5 MIN - GOOD TEST. - R/D TEST EQUIPMENT AND B/D LINES. 12:00 - 18:00 1 6.00 WHSUR P DECOMP R/D CIRC LINES, VALVES, AND FITTINGS. NIPPLE DOWN TREE AND ADAPTER FLANGE. UD TREE IN 4 PIECES. Printed 9/6/2011 9:11:45AM , orth America W ALASKA - BP Pagel 3 tde' Aeration Summary Report Common Well Name: A -25 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/7/2011 End Date: 8/9/2011 X3- 00Y3D -C (2,997,508.00 ) Project: Prudhoe Bay ; Site: PB A Pad Rig Name /No.: DOYON 25 Spud Date/Time: 11/16/2001 12:00:OOAM Rig Release: 8/9/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292076400 Active Datum: A -25B @90.32ft (above Mean Sea Level) Date From - To Hrs Task 1 Code NPT NPT Depth Phase I Description of Operations (hr) = (ft) 18:00 - 00:00 T 6.00 BOPSUR P DECOMP ! PJSM. BEGIN N/U BOPE. P/U 1.5, 2', AND 14' I HIGH PRESSURE RISER SECTIONS TO RIG FLOOR UP BEAVER SLIDE. N/U HIGH PRESSURE RISER SECTIONS. R/U CHOKE HOSE, MOVE FLOW LINE BOX, BELL NIPPLE, AND STACK INTO PLACE. 7/19/2011 00:00 - 04:00 4.00 BOPSUR P DECOMP NIPPLE UP BOPE, TORQUE ALL FLANGES ON HIGH PRESSURE RISER. R/U FOR BOP TEST. OPEN BOP DOORS AND PERFORM VISUAL INSPECTION OF PIPE RAMS AND ANNULAR ELEMENTS AS PER SOP FOR HIGH GOR WELLS. CLOSE DOORS. - INSPECTION WITNESSED BY BP WSL GARRET STAUDINGER AND TOURPUSHER JOHN NEWMAN. 04:00 - 04:30 0.50 BOPSUR P DECOMP RIG UP TO TEST BOPE. 04:30 - 05:00 0.50 BOPSUR P DECOMP PERFORM KICK WHILE DRILLING DRILL (D2). 05:00 - 09:30 4.50 BOPSUR P DECOMP TFST ROPF TO.250 PSI LOW, 3500 PSI HIGH AS PER AOGCC AND BP POLICY. TEST ANNULAR PREVENTER TO 250 PSI LOW, 3500 PSI HIGH. EACH TEST 5 CHARTED MINUTES. TEST THE UPPER VARIABLES AND LOWER, VARIABLES WITH 4 IN AND 4 1/2 IN TEST JOINTS. TEST THE ANNULAR PREVENTER / t'" WITH 4 IN TEST JOINT. NO FAILED TESTS. ft5 TEST WITNESS WAIVED BY JOHN CRISP WITH AOGCC. TEST WITNESSED BY WSL MIKE DINGER AND TOOLPUSHER MIKE MEADOWS. PERFORMED ACCUMULATOR TEST: SYSTEM PRESSURE 3,000 PSI, PRESSURE AFTER CLOSING ALL RAMS AND ANNULAR PREVENTER 1,775 PSI. RECOVERED 1ST 200 PSI 35 SECONDS. 6 NITROGEN BOTTLES, AVERAGE PRESSURE = 2,450 -PSI. CLOSING TIMES: - ANNULAR PREVENTER: 23 SEC. - TOP RAMS: 18 SEC. - BOTTOM RAMS: 16 SEC. I - BLIND SHEARS: 16 SEC. - HCR KILL: 2 SEC. 10:00 0.50 BOPSUR - HCR CHOKE: 2 SEC. 09:30 - t P ; DECOMP OPEN BLIND RAM DOORS AND INSPECT CONDITION OF RAM SEALS - SEALS GOOD. 10:00 - 10:30 0.50 BOPSUR P DECOMP TEST BLIND RAMS TO 250 PSI LOW, 3500 PSI I HIGH FOR 5 MIN. 10:30 - 12:00 1.50 WHSUR P DECOMP PICK UP DUTCH RISER, DSM LUBRICATOR, AND M/U TWC RETRIEVING TOOL TO [ LUBRICATOR. 12:00 - 14:30 2.50 WHSUR P DECOMP I TEST LUBRICATOR TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH - ' . PASS. PULL TWC, MONITOR WELL - STATIC. - UD LUBRICATOR AND DUTCH RISER. Printed 9/6/2011 9:11:45AM orth America - ALASKA - BP Page 4 peratton Summary Report Common Well Name: A -25 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/7/2011 End Date: 8/9/2011 X3- 00Y3D -C (2,997,508.00 ) Project: Prudhoe Bay Site: PB A Pad Rig Name /No.: DOYON 25 Spud Date/Time: 11/16/2001 12:00:OOAM 1Rig Release: 8/9/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292076400 Active Datum: A -25B @90.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) 1 114:30 - 18:00 3.50 PULL P DECOMP; M/U LANDING JOINT W/ FOSV. RIH AND M/U TO TBG HANGER W/ 7 TURNS TO RIGHT. - PULL TBG HANGER FREE AT 69K UP, NO OVERPULL. - MONITOR WELL FOR 10 MIN - STATIC - PULL HANGER ABOVE ROTARY TABLE AND L/D HANGER AND LANDING JOINT. - R/U CIRC HOSES TO TAKE RETURNS FROM IA TO 500 BBL OPEN TOP TANK, M/U CEMENT !HOSE ON STUMP, CLOSE ANNULAR. 18:00 - 19:00 1.00 PULL P DECOMPCIRCULATE LONG WAY AT 250 GPM / 450 PSI, TAKING RETURNS TO OPEN TOP TANK. PUMP 40 BBL SOAP PILL AND CHASE WITH 305 BBLS SEAWATER. - MW 8.4+ IN / 8.4+ OUT - MONITOR WELL FOR 10 MIN - STATIC 19:00 - 20:00 1.00 PULL P DECOMP RIG DOWN CIRC LINES, CLEAR AND CLEAN RIG FLOOR. 20:00 - 00:00 4.00 PULL P DECOMP 1 PJSM. LAY DOWN 4.5 ", 12.6#, L -80 TBG FROM T _ 3311' TO 320'. HOLE TAKING PROPER FILL. 7/20/2011 00:00 - 01:00 1.00 PULL P DECOMP LAY DOWN 4.5" 12.6# L -80 TBG. y _ - TOTAL OF 79 JOINTS, 1 PUP, AND 1 WLEG LAVED DOWN. 01:00 - 02:30 1.50 PULL P DECOMP R/D 4 -1/2" HANDLING EQUIPMENT. - R/D LONG BAILS 02:30 - 03:30 ! 1.00 CLEAN P WEXIT R/U TO RUN N. : ■ - R/U SHORT BAILS AND POWER ELVATORS - P/U CLEANOUT TOOLS TO RIG FLOOR - LOAD PIPE SHED W/ 4" HWDP, 5" HWDP, 'AND 6-1/2" DCS 03:30 - 04:00 0.50 BOPSUR P WEXIT INSTALL WEAR BUSHING. 04:00 - 07:30 3.50 CLEAN P WEXIT PJSM. M/U CLEANOUT BHA AS PER BOT REP. 8 -1/2" USED MILL TOOTH BIT, BOOT BASKETS (2), WATERMELON MILL, DRILL COLLARS, 5" HWDP, 4" HWDP. 07:30 - 08:30 1.00 CLEAN N RREP WEXIT CALIBRATE THRESHHOLD FOR LINK TILT TO ENABLE TOP DRIVE ZONE MANAGEMENT 09:30 1.00 CLEAN P SYSTEM. 08:30 - ; WEXIT CONTINUE M/U CLEANOUT BHA. 109:30 10:30 1.00 CLEAN P WEXIT 'HOLD H2S / RIG EVAC DRILL. SHUT WELL IN. PERFORM AAR. 1 10:30 - 11:00 0.50 CLEAN P WEXIT STRAP DRILLPIPE IN A & B TUBS TO BE PICKED UP. R/U TO CUT AND SLIP DRILL LINE. 11:00 - 14:00 3.00 T CLEAN P WEXIT I CUT AND SLIP 86' OF DRILL LINE, CALIBRATE BLOCK HEIGHT ON TOTCO & AMPHION SYSTEMS, CLEAR AND CLEAN RIG FLOOR. 14:00 - 00:00 10.00 CLEAN P WEXIT PJSM. RIH W/ CLEANOUT ASSY ON DOUBLES FROM THE PIPESHED TO 7026' MD. FILL PIPE EVERY 20 STANDS AND STRAP DRILLPIPE WHILE RIH. HOLE GIVING PROPER DISPLACEMENT. P/U = 144K, S/O = 119K 7/21/2011 00:00 - 02:00 2.00 CLEAN P r WEXIT RIH WITH CLEANOUT ASSEMBLY ON DOUBLES FROM PIPESHED TO 7660'. I- STRAP PIPE ON TRIP IN 02:00 03:30 1.50 CLEAN N RREP WEXIT CONTINUE TROUBLESHOOTING PIPE TUB CONVEYOR IN PIPESHED. Printed 9/6/2011 9:11:45AM Page 5 e> 6f oft America • ALASKA - BP Aeration Summary Repo rt Common Well Name: A -25 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/7/2011 End Date: 8/9/2011 X3- 00Y3D -C (2,997,508.00 ) Project: Prudhoe Bay Site: PB A Pad Rig Name /No.: DOYON 25 Spud Date/Time: 11/16/2001 12:00:OOAM Rig Release: 8/9/2011 Rig Contractor: DOYON DRILLING INC. 1 UWI: 500292076400 Active Datum: A -25B @90.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT l NPT Depth I Phase Description of Operations (hr) 03:30 - 04:00 0.50 CLEAN P (ft) WEXIT SERVICE TOP DRIVE, BLOCKS, DRAWWORKS, CATHEADS, AND IRON ROUGHNECK. 04:00 - 06:00 2.00 CLEAN P WEXIT !CONTINUE RIH WITH CLEANOUT ASSEMBLY TO 8,227' MD. HOLE TAKING PROPER DISPLACEMENT. 06:00 - 07:30 1.50 CLEAN P WEXIT M/U TOPDRIVE. ROTATE AND RECIPROCATE 60' STROKES WHILE CIRCULATING 30 BBL 8.4 PPG HIGH VIS SOAP PILL. PUMP PILL AROUND TO SURFACE. 1- CIRC AT 590 GPM / 2,565 PSI 07 :30 - 08:30 1.00 CLEAN P WEXIT P/U DOUBLE FROM PIPESHED AND RIH TO 8,295'. I- ROTATE AND RECIPROCATE 60' STROKES, CBU - 590 GPM / 2,250 PSI 08:30 09:00 0.50 CLEAN P WEXIT OBTAIN SLOW PUMP RATES - MONITOR WELL FOR 10 MIN - STATIC - MW8.5IN /8.5OUT 09:00 - 19:00 10.00 CLEAN P WEXIT POOH ON ELEVATORS TO 6,785'. MONITOR WELL FOR 10 MIN - STATIC. MW 8.5 IN / 8.5 OUT. PUMP DRY JOB. CONTINUE POOH ON ELEVATORS TO BHA. I- STAND BACK HWDP AND DRILL COLLARS - UD BOOT BASKETS (EMPTY) UD WATERMELON MILL - IN GAUGE 1 19:00 22:00 3.00 EVAL P WEXIT PJSM. R/U SLB ELINE - P/U EZSV, WIRELINE SHEAVES, AND TOOLS. - INSTALL SHEAVE IN ELEVATORS AND ON RIG FLOOR - P/U WIRELINE THROUGH WINDOW IN WALL, M/U TOOLSTRING 22:00 - 00:00 2.00 EVAL P WEXIT RIH WITH EZSV ON WIRFI INF TO A3nn' Fl Mn STARTED MONITORING OA AT 22:30 HRS AS PER PACK -OFF CHANGE OUT SOP. 7/22/2011 00:00 - 01:00 1.00 EVAL P WEXIT TIE INTO GR/CCL OF A -25A PDC LOG. E -LINE DEPTH CORRECTION OF -22'. - SET EZSV AT 8,193' ELMD. i - TAG TOP OF EZSV WITH WIRELINE TOOLS l TO CONFIRM SET. ' 01:00 - 02:30 1.50 EVAL P WEXIT POH WITH WIRELINE TO SURFACE. 02:30 - 03:00 0.50 EVAL P WEXIT R/D WIRELINE SHEAVES AND TOOLS. R/U TO PRESSURE TEST CSG. 03:00 - 04:00 1.00 EVAL P WEXIT PRESSURE TEST 9 -5/8 CSG AND EZSV TO 250 PSI FOR 5 MIN AND 3500 PSI FOR 30 MIN - TEST PASSED - WTL APPROVAL TO CONTINUE OPERATIONS - 7.6 BBLS TO REACH TEST PRESSURE - LOST 18 PSI IN FIRST 15 MIN - LOST 16 PSI IN SECOND 15 MIN - LOST 7 PSI IN THIRD 15 MIN - 7.6 BBLS RETURNED 04:00 - 05:30 1.50 STWHIP P WEXIT PERFORM AAR ON WIRELINE. PJSM FOR I WINDOW MILLING BHA. R/U TO P/U IWHIPSTOCKASSEMBLY. 05:30 - 10:30 5.00 STWHIP P I WEXIT PJSM. M/U WHIPSTOCK BHA WITH MII 1 S MWD, HWDP, AND DRILL COLLARS. Printed 9/6/2011 9:11:45AM orth America - ALASKA - BP Page 6 abtfl • Aeration Summary Report Common Well Name: A -25 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 7/7/2011 End Date: 8/9/2011 X3- 00Y3D -C (2,997,508.00 ) Project: Prudhoe Bay Site: PB A Pad Rig Name /No.: DOYON 25 Spud Date/Time: 11/16/2001 12:00:OOAM Rig Release: 8/9/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292076400 Active Datum: A -25B @90.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:00 0.50 STWHIP P WEXIT SHALLOW PULSE TEST MWD @ 510 GPM / 11200 PSI. ' GOOD DETECTION. 1 11:00 - 17:30 6.50 STWHIP P WEXIT CONTINUE RIH WITH WHIPSTOCK ASSEMBLY TO 8150. - HOLE GIVING PROPER DISPLACEMENT. 17:30 - 18:30 1.00 STWHIP P WEXIT M/U TOPDRIVE. OBTAIN SLOW PUMP RATES. - CIRC AT 510 GPM / 2225 PSI, P/U = 166K, S/O =129K - ORIENT WHIPSTOCK FACE TO 47 DEG LOHS ; - TAG EZSV AT 8200' MD. - SET BOTTOM TRIP ANCHOR WITH 12K DOWN - P/U 15K OVER TO CONFIRM SET - S/O 38K TO SHEAR OFF WHIPSTOCK TOP OF WS SET AT 8179' MD - ----- - - - - -- 18:30 - 19:00 0.50 STWHIP P WEXIT t ST W AND BACK 3 STANDS TO 7942' MD. 19:00 - 20:30 1.50 STWHIP P WEXIT 1 RTTS TO DRILLPIPE. RIH 1 STAND AND SET RTTS. - 21 TURNS TO LEFT TO RELEASE FROM I TOOL. 20:30 - 21:00 0.50 STWHIP P WEXIT PRESSURE TEST RTTS TO 250 PSI LOW / 2000 PSI HIGH FOR 5 MIN EACH - GOOD TEST 21:: - 1 00 - 23:30 2.50 STWHIP r P WEXIT DRAIN STACK. R/U AND PULL WEAR RING. 23 :30 - 00:00 0.50 STWHIP P WEXIT ,PULL 9 -5/8" PACKOFF THROUGH STAr { PULLED FREE WITH 21 K OVERPULL. 7/23/2011 00:00 - 02:00 2.00 STWHIP P WEXIT I INSTALL NEW 9 -5/8" PACKOFF THROUGH STACK PER CAMERON REP. ' - RUN IN AND TORQUE LDS - TEST PACK -OFF VOID TO 250 PSI LOW / 5 MIN AND 3500 PSI HIGH / 30 MIN - GOOD TEST 02:00 03:00 1.00 STWHIP P WEXIT I R/U RTTS PULLING TOOL AND RUN IN ON STAND. - INSTALL TIW ON DP - ENGAGE INTO RTTS WITH 21 TURNS TO RIGHT - CLOSE ANNULAR, RELEASE RTTS SLIPS AND ELEMENTS - 0 PSI ON CHOKE, OPEN CHOKE AND VERIFY NO FLOW - OPEN ANNULAR, PULL RTTS 03:00 - 03:30 0.50 STWHIP P WEXIT ; UD RTTS AND RUNNING TOOL. 03:30 - 08:30 5.00 STWHIP P WEXIT PJSM. RIH WITH 3 STANDS TO TOP OF WHIPSTOCK. DISPLACE 8.5 PPG SEAWATER TO 9.9 PPG LSND. - PUMP 30 BBLS SPACER, DISPLACE WELL @ 330 GPM / 900 PSI. A LOT OF PARAFIN IN RETURNS. - MONITOR WELL FOR 10 MIN - STATIC. MW 9.9IN/9.9OUT - OBTAIN SLOW PUMP RATES Printed 9/6/2011 9:11:45AM , • Oath America - ALASKA - BP Page 7 o> A eration Summary Report Common Well Name: A -25 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/7/2011 1 End Date: 8/9/2011 X3- 00Y3D -C (2,997,508.00 ) ' L Project: Prudhoe Bay 7Site: PB A Pad Rig Name /No.: DOYON 25 'Spud Date/Time: 11/16/2001 12:00:OOAM Rig Release: 8/9/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292076400 Active Datum: A -25B ©90.32ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (ft) 08:30 - 18:00 WEXIT MILL WINDOW FROM 8179' TO 8196' AS PER ' BOT REP. .6 - 500 GPM / 2150 PSI - 100 RPM / 6 -8K TQ � - 5 -12K WOB rv' ! - P/U 175K, S/O 135K PIj7 TOW = 8179' 1 BOW = 8196' HEAVY TAR AND PARAFIN BLINDING SHAKER ' SCREENS CAUSING DELAYS DURING 1 MILLING. 18:00 - 19:30 1.50 STWHIP P I WEXIT DRILL 29' OF NEW FORMATION TO 8216' MD ' - 500 GPM / 2200 PSI - 100 RPM / 5-7K TQ P/U CLEAN AND SLIDE THROUGH WINDOW ',WITH NO ISSUES 19:30 - 22:00 2.50 STWHIP P WEXIT PUMP 40 BBL SUPER SWEEP AND 1.5 BU @ 500 GPM / 2200 PSI - NO INCREASE IN METAL CUTTINGS SEEN SAT SURFACE TOTAL METAL RECOVERED 300 LBS 1- - MONITOR WELL - STATIC. MW 9.9 IN / 9.9 OUT 122:00 - 23:30 1.50 STWHIP P WEXIT PJSM. PERFORM LOT TO 12.8 PPG EMW WITH 940 PSI AT 6066' TVD AND 9.9 PPG MW. - 3.5 BBLS TO REACH LEAK OFF PRESSURE, j 2 BBLS RETURNED 123:30 - 00:00 0.50 STWHIP P WEXIT R/D TEST EQUIPMENT WHILE MONITORING WELL - STATIC. 7/24/2011 00:00 - 05:00 5.00 STWHIP P WEXIT PJSM. PUMP DRY JOB. POOH ON ELEVATORS WITH WINDOW MILLING ASSEMBLY. - HOLE TAKING PROPER DISPLACEMENT. 05:00 4.00 STWHIP P WEXIT I LAY DOWN MILLING BHA PER BAKER REP ! 09:00 - 10:00 1.00 STWHIP P WEXIT CLEAN AND CLEAR RIG FLOOR. LAY DOWN STRING MILLS AND PILOT MILLS. - ALL 3 STRING MILS IN GAUGE 1 - WINDOW PILOT MILL 1/4" UNDER GAUGE 10 :00 - 10:30 1 0.50 STWHIP P WEXIT SERVICE IRON DERRICKMAN, TOP DRIVE, I AND BLOCKS. 1- 10:30 - 11:00 0.50 STWHIP P WEXIT PULL WEAR RING. 11:00 - 12:30 1.50 STWHIP P WEXIT I FLUSH OUT BOP STACK. FUNCTION RAMS AND FLUSH. 12:30 - 13:00 0.50 STWHIP P WEXIT I INSTALL WEAR RING. 13:00 - 13:30 0.50 STWHIP P WEXIT PJSM FOR M/U DRILLING BHA AND PICKING I UP REMAINING DOUBLE FROM PIPESHED. 13:30 - 17:30 4.00 STWHIP P WEXIT P/U BHA TO 112', UPLOAD BHA, SHALLOW PULSE TEST MWD @ 550 GPM / 1030 PSI. CONTINUE M/U BHA TO 644'. 1 17:30 - 00:00 6.50 STWHIP P WEXIT I RIH WITH DRILLING BHA ON DOUBLES FROM PIPESHED TO 3172' 11- STRAP DOUBLES ON TRIP IN HOLE GIVING PROPER DISPLACEMENT ! 7/25/2011 00:00 - 03:00 3.00 STWHIP P WEXIT CONTINUE RIH WITH DRILLING BHA ON DOUBLES TO 4728' MD. - STRAP DOUBLES ON TRIP IN 103:00 - 06:30 3.50 STWHIP P WEXIT IRIH WITH DRILLING BHA ON STANDS FROM DERRICK. - HOLE GIVING PROPER DISPLACEMENT Printed 9/6/2011 9:11:45AM TREE _. 4- 1/16" CM/ SAFETY : WARNING: RADIO TRANSMITTER IN • WELLHEAD = McEVOY 0 WEATHNITORING SHACK MUST BE TURNED 'ACTUATOR = BAKER C A -2 5 B OFF BEFORE ANY WELL WORK INVOLVING KB. ELEV = 87.68' PJC DRAFT EXPLOSIVES CAN BEGIN. CONTACT PAD OPER. BF. ELEV = 51.98' 1 I ' KOP = 1100' Max Angle ,= 54° @ 4553' Datum MD = 1130T ' I 2190' 1-14-1/2" HES X NIP, ID = 3.813" I Datum TVD= 8800' SS 2987' H9 -5/8" DV COLLAR I 120" CONDUCTOR, ID = ? I 110' GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I 3152' ST MD D DEV TYPE VLV LATCH PORT DATE 5 4249 3488 48 MMG DCR RKP 0 08/06/11 4 6606 4993 47 MMG DMY RK 0 08/06/11 3 7757 5795 50 MMG DMY RK 0 08/06/11 9 -5/8" X 7" BKR ZXPN LTP w / 10' TIBBACK, --I 8052' 2 8663 6393 42 KBG2 DMY BK 0 08/06/11 & FLEX LOCK LNR H�RJD = 6 18' 1 9362 6991 19 KBG2 DMY BK 0 08/06/11 9 -5/8" WHIPSTOCK (07/22/11) I-1 8179' fl 9-5/8" CSG, 47 #, L -80 BTC, ID = 8.681" ( I -8179 19 -5/8" EZSV (TAGGED 07/22/11) I--1 8200' y MILLOUT WINDOW (A -25B) 8079' - 8196' l_2 M 1 inimum ID = 3.725" @ 10821' 4 -1/2" HES XN NIPPLE ' 1 10682' H4-1/2" HES X NIP, ID = 3.813" I I 10710' 1-17" X 4-1/2" HES TNT PKR, ID = 3.856" 1 10745' I- I4 -1/2" HES X NIP, ID = 3.813" 10821' H4-1/2" HES XN NIP, ID = 3.725" I 10826' H7" X 5" BKR HRD-E ZXPN LTP, ID = 4.21" I 'TOP OF 4-1/2" PROD LNR H 10826' 10834' H4 -112" WLEG, ID= 3.958" I 4 -1/2" TBG, 12.6 #, 13CR -85 VAM TOP, 10834' I I -{ ELMD TT NOT LOGGED 0152 bpf, ID = 3.958" 10842' 1-1 7" X 5" BKR FLEX LOCK HGR, ID = 4.19" I 1 7" LNR, 26 #, L -80 VAM TOP HC XO TO BTC H 10861' I "' 10852' 1-15" X 4 -1/2" XO, ID = 3.90" I 17" LNR, 26 #, L -80 BTC, ID = 6.276" 1-1 10983' 1 A • PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I PBTD I-1 11520' 4-1/2" LNR, 12.6 #, 13CR -85 VAM TOP, 11608' • • • • • • • .0152 bpf, ID = 3.958" _••• •• • DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/23/82 NIES ORIGINAL COMPLETION WELL: A -25B 07/16/89 N1 ES RWO PERMIT No: 2110030 11/22/01 D16 SUSPENDED ST (A -25A) API No: 50- 029 - 20764 -02 08/09/11 D25 SIDETRACK (A -25B) SEC 35, T11 N, R12E, 2628' FSL & 1703' FEL 08/13/11 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 02/03/11 Schlumberger NO. 5688 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I Well Job # Log Description Date BL Color CD F -12 BMSA -00003 RST / -J1 '1-- 01/05/11 1 9( /di 1 H -01A AWJI -00117 MCNL J 9' / 1 0 10/15/10 1 0l()"ier 1 J -20B B5JN -00073 CH EDIT PDC -GR (PLUG SET) 4(19 $ `- (') 11/05/10 0 �( 1 A -25A BCZ2 -00027 CH EDIT PDC -GR GRICC r .•••• 11/06/10 ■ 1 W -220 BG4H -00025 CH EDIT USIT I 1 D -33 BD88 -00061 MCNL ' PQ ' - rSAIr I 13-37 BBKA -00056 USIT (2 re, 09/18/10 r 1 1 03 -20A 11503603 PRODUCTION LOG I i 6 472 11/19/06 1 AO,- /4 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 t a q FEB 0 7 2011 Alaska Oil & Gas Cons. Commission Anchaage q .,.... • • lf [E If AELns---u SEAN PARNELL, GOVERNOR 4 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIHSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 ? � Anchorage, AK 99519 -6612 S > NE M �' ' " ' (� Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A -25A Sundry Number: 311 -008 Dear Mr. Egbejimba: 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, • . f Daniel -T. Seamount, Jr. Chair DATED this / day of January, 2011. Encl. STATE OF ALASKA Pi'l ( ` ALASKA AND GAS CONSERVATION COMMISSI• l ,Z J- 7-/I APPLIC FOR SUNDRY APPROVAL `P e l( 20 AAC 25.280 1 41/ 1. Type of Request: ❑ 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. '151 Development ❑ Exploratory 201 -148 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20764 -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 A -25A Spacing Exception Required? ❑ Yes ■= No 9. Property Designation: 10. Field / Pool(s): ADL 028286 - 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): 13092' - 9138' - 11883' ` 8424' • None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 3152' 13 -3/8" 3152' 2768' 4930 2670 Intermediate 11958' 9 -5/8" 11958' 8481' 6870 4760 Production Liner 623' 7" 11486' - 12109' , 8131' - 8599' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 4 -1/2 ", 12.6# (Kill String) L -80 3310' Packers and SSSV Type: None Packers and SSSV None MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ■ Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory . ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 11, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jesse Rosenbaum, 564 -5155 Printed Name John Egbejimba Title Engineering Team Leader Prepared By Name/Number: Signature t( . 6friSa.. Phone 564 -5859 Date 1/6 f 11 Elizabeth Barker, 564 -4628 Commission Use Only Conditions of approval: N.tify Commission so that a representative may witness l r ^ Q Sundry Number l V ❑ Plug Integrity l'. BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 7Ie 351),0 Other: �� " �Sv �v,s1 2r/— ` ' E iV i'''t /4 / ,, /o /t f l4 «.,t..,t Cyrea /`.` Za .4�4c. Z S i Z A 0 6 2011 J Subsequent Form Required: /6 — d 7 ° ' fl l n C9,3 CMS. Clr,InIiSSiO 1 lncf>!ne 4 /0,.... ' - APPROVED BY --, Approved By COMMISSIONER THE COMMISSION Date 1 4/ Form 10-403 Revis d 01/RaDM JAKig ORIGINAL 2 Submit In Duplicate • • b P Ggt. A -25A Sundry Request Well Type: Suspended Sidetrack Current Status: This well is currently plugged with a 4 -1/2" L -80 tubing kill string set to 3,311'. The well was sidetracked and subsequently suspended in November of 2001. Request: Pull current kill string and set EZSV on February 1 2011 in preparation for sidetrack to restore production. Well History: The A -25 parent was drilled July '82 and completed for production in February '83 in the 27P and 26P intervals of Zone 2C. In August 1987, perforations were added in the 25P and 24P intervals of Zone 2B. All of these zones have been commingled with each other at one time or another in the life of the well. The well was shut -in December '97 due to tubing integrity issues. Prior to being shut -in, the well began to experience production decline coincident with increasing GOR and increasing watercut. At the time watercut was seen to increase, the 26P was isolated behind a straddle packer. Watercut again increased in late '96 at a time when A -35i injection was significantly diminished. The increased watercut at that time may have been due to the 26P leaking across the straddle packer. Logging in late '96 indicated potential resaturation in the 26P behind the packer and holes were punched through the tubing after attempts to open the packer failed. Following the hole punch operation, the well immediately went to high watercut and was shut -in late '97. A -25A was identified as a sidetrack candidate to target bypassed oil reserves between the expanding gas cap and the HOT in early 2001. The reserves estimates centered largely on the 24P and 22P based on detailed mapping of the HOT /shale wedge play and offset well data from new sidetrack B -19A. The well was drilled in November 2001, and approximately 1,000' of section were drilled with minimal issues. However, real time formation evaluation / resistivity data indicated that there were few remaining reserves associated with the target interval. Resistivity and I neutron data showed the well had a gas -water contact in Subzone 2C. Furthermore the 22N was HOT bearing due to the markers being encountered approximately 22' deep of prognosis. A -25A was not completed due to gas on water in the target location. The well was suspended with a cement plug laid in the 7" production liner from 11,883'- 13,092' MD. 4 -1/2" tubing without a production packer was run to 3311' MD and the well has been used to test new wireline tools for the last 10 years. Scope of Work: The pre -rig work will include verifying tubular and wellhead integrity. With a rig on the well, ✓ operations will include pulling the kill string from 3,311' and a 9 -5/8" EZSV will be set in position for milling the window at 4-/- 8,210' MD. Preparations will be made for sidetracking. ( 90 VC; " A -25A Sundry Application 1 1/4/2011 • • Pre -Rig Operations: 1. W Pressure Test (to verify Abandonment & Barriers) MIT - OA to 2000 psi . CMIT -TxIA to 3,000psi • PPPOT -T to 5,000psi PPPOT -IC to 3,500psi Function test tubing and casing LDS. Back out to ensure full movement. 9 5/8" packoff will be changed out 2 F Circulate the well to seawater. Freeze - protect the IA and tubing with diesel to - 2,200'. 3. D Bleed all pressures to zero. Set BPV. Secure well. 4. V Set BPV. Secure well. 5. O Remove the well house. If necessary, level the pad. Install impermeable cellar liner Rip Operations - Sundry Notice: 1. MI / RU rig 2. MIT - OA 2000 psi for 30 minutes (begin monitoring OA). 3. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. 4. Set TWC and test to 1,000 psi from below and above.✓ 5. Nipple down tree & tubing adapter. 6. Nipple up and test BOPE to 3,500psi high/ 250psi low. Pull TWC. 7. R/U & pull 4 -1/2" tubing (kill string) from 3311'. 8. R/U & Run 9 -5/8" casing scraper to 8300' 9. RIH with HES EZSV bridge plug + GR /CCL on E -line and set at -8200' MD, as required to avoid cutting a casing collar while milling the window. Test CSG to 3,500 psi. POOH. 10. P/U and RIH with 9-%" Baker bottom -trip anchor whip stock assembly. Orient whipstock and set on EZSV bridge plug. Shear off of whip stock. 11. Hang off milling BHA on storm packer to change out 9 5/8" pack -off. 12. Change out and test 9 -5/8" pack -off through the BOP stack. . 13. Retrieve storm packer. 14. Displace the well to 9.1 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. End of Sundry Notice Well Control: Equipment will be installed that is capable of handling maximum potential surface pressures. (Schematics are attached.) Independent gas and H2S detectors will be installed. ■ 5000 psi working pressure pipe rams (2) ■ Blind /shear rams ■ Annular preventer Based upon the calculations below, BOP equipment will be tested to 3500 psi. Current Well Bore: • Maximum anticipated BHP: 3280 psi at 8,800 TVD • Maximum surface pressure: 2400 psi at (Based on a full column of gas at 0.1 psi /ft) Drilling Engineer Jesse Rosenbaum (907) 564 -5155 A -25A Sundry Application 2 1/4/2011 TREE =' ' 6" CM/ WELLHEAD = McEVOY III UATOR = OTIS P 2 5A SAFETY :WARNING: RADIO TRANSMTTER IN ACT KB UAT = 87 68' WEATHER MONITORING SHACK MUST BE TURNED OFF BF. ELEV = 51.98' BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR A -25A HAS KOP= 1100' CMT PLUG FROM TD TO 11883'. Max Angle = 58 (iii 10000' Datum MD = Datum TVD= 8800' SS ' ' I 2425' H 4-1/T HES X NIP, ID = 3.813" 113 -3/8" CSG, 721, L -80, ID = 12.347" H 3152' 141/2' TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 3310' ( / " I 3311' H4 -1/2" WLEG Minimum ID = 3.813" @ 2425' 4 -1/2" HES X NIPPLE GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE ITOP OF 7" BOT HGR TIEBACK SLV H 11486' 111 4 111'1 I 11883' H TOP OF MIT P&A PLUG I •••••••• 11•1111•1 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 11957' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11111111111111111 7" MLLOUT WINDOW ••••••• 11111110 12109' - 12121' •••■••••1♦ 11111111111. ••••••••••••. 11111111111111, `•••••••••••••■ ITOP OF WHIPSTOCK I 12109' 4.14111111111111111111111111.1. '4404444•40.4 . 1 1 * 1. •111111111•111, `11111111111114, 7" CIBP 12127' `1•11111111111. *111111111111. x/1•111/11/111. `1111111111111♦ `.1111111111111. PERFORATION SUMMARY W� � ` 1 � �1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 �� , 1111111111111 `1111111111111 REF LOG: 1'x'1 rfl 4...4.000W 111114 `1111111111111 . 1.4.4.4.4 `1111111111111. ANGLE AT TOP PERF: Wav av •.•••••••••••••■ •••••� 4111111111111♦ Note: Refer to Production DB for historical perf data I 1'1 •111111111111 11• 4 `1111111111111. SIZE SPF INTERVAL OpnlSgz DATE I 1.1.1 • 4'4440000.44 11111•111111. ..iao..� , ,;1.1.1.1.1./ i `14111111111111111111111111 1 111111, 41111111111 1111 • , _, `1111111 '1'1'1'1'1'1'1' 4. 111111.. 4 . 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 6.125" P& A'd OPEN HOLE —I 13092' 4 SIDETRACK TD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ► • 1 • 1 17" LNR, 26#, L -80, 1D = 6.276" I—{ 12817' • DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/23/82 ORIGINAL COMPLETION 05/24/01 RN/TP CORRECTIONS WELL: A -25A 07/13/89 RWO 11/22/01 s RIG SIDETRACK (P & A'D) PERMIT No: 201 -1480 04/09 /97 TBG PUNCH 12/29/01 CH/TP CORRECTIONS AR No: 50-029-20764-01 02/06/01 SIS-MH CONVERTED TO CANVAS 2651' SNL & 1703' WEL, Sec. 35, T11 N, R 13E 03/05/01 SIS-LG FINAL BP Exploration (Alaska) A A Lj%ZK)% SEAN PARNELL, GOVERNOR AIIASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSE RQATION C011I0II ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Gary Preble Data Management Engineer BP Exploration (Alaska), Inc. v P.O. Box 196612 �"� Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A -25A Sundry Number: 310 -319 Dear Mr. Preble: 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. incerely, Daniel T. Seamount, Jr. ti Chair DATED this ? day of November, 2010. Encl. 0 by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 September 16, 2010 � SEP 2 0 2010 Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission CrWim"on 333 West 7 Avenue A_Ot1S Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well A -25A (PTD #2011480) Suspended Well Inspection Report (10 -404) Application for Renewal of Existing Suspension (10 -403) Dear Mr. Seamount, BP Exploration (Alaska) Inc. (BPXA) completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well A -25A on 9/11/10. Enclosed is a Report of Sundry Well Operations (10 -404) with attachments documenting the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). Recent well events from this well indicate that this well is mechanically sound. Specific attachments include: • Suspended Well Site Inspection form documenting the well pressures and site condition • Wellbore diagram illustrating the current configuration of the well • Pad map and aerial photo showing well location and other wells within one- , quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Prudhoe Bay Unit well A -25A was suspended on 11122/01. It is located on a pad with active wells and /or service wells. Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10- 403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay Unit well A -25A is mechanically sound and secure and will meet the requirements for renewal of suspended status. • If you require any additional information, please contact me at 564 -5637, Torin Roschinger /Jerry Murphy at 659 -5102 or Chris Stone 564 -5518. Sincerely, R. Steven Rossberg BPXA, Wells Operations Manager Attachments: Report of Sundry Operations (Form 10 -404) with attachments: Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Pictures of wellhead and location Application for Sundry Approval (Form 10 -403) with attachment: Technical Justification Cc: Roschinger /Murphy Harry Engel Mike Bill Chris Stone Laurie Derrick Gary Preble Y STATE OF ALASKA 9 ALAS4L AND GAS CONSERVATION COMMISSI0 0(,w 10 p APPLICATION FOR SUNDRY APPROVALS '�; 20 AAC 25.280 `�' 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: RENEW SUSPENSION 21 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development p]_ Exploratory ❑ 201 -1480 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20764 -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 A -25A Spacing Exception Required? Yes ❑ No ❑ . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028286 - PRUDHOE BAY Field / PRUDHOE 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): 13092 - 9137.92 11883. 8423.85 _ 11883' TOC NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE 110 SURFACE 110 Surface 3152 13 -3/8" 72# L -80 SURFACE 3152 SURFACE 2768 4930 2670 Intermediate 11958 9 -5/8" 47# L -80 SURFACE 11958 SURFACE 8481 6870 4760 Production 623 7" 26# L -80 11486 12109 8131 8599 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE- - 4 -1/2" 12.6# L -80 SURFACE 3310 KILL STRING Packers and SSSV TVDe: NONE Packers and SSSV MD and TVD (ft): 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 21- Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/28/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended _ ❑Q 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name A l Gary E3ble4 Title Data Management Engineer Signature Phone Date q 564 -4944 Y alld Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY (�A Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 �, l ct Plug Integrity /❑ BOP Test ❑ j Mechanical Integrity Test ❑ Location Clearance ❑ ' Other: ,�. A I � P 1 / 4 c G ... +.. a��yo✓o ✓ c.f� �il ZG Z S. l / i � f C K 1 2010 Subsequent Form Required: �� -(-� �� ».� Anchemp APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: f Bones Ho 0 3 ,ORIGINAL % zy • ia Submit • nD Form 10-403 Revised 1/2010 Prudhoe Bay Oil Pool well A -25A Technical Justification for Application for Renewal of Suspension Status September 16, 2010 Well Status Prudhoe Bay well A -25A (PTD # 2011480) was suspended on 11/20/2001 after drilling found a gas on top of water contact in the targeted production interval. On that date, the sidetrack hole was plugged with cement from TD to 11,883' MD. The well has a 4- 1/2" kill string to 3,311' MD and has been used for testing wireline technologies. The well is mechanically sound as indicated by a passing pressure test of the cement plug to 3000 psi on 11/21/01. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe, and not a threat to public health. The strata through which the well was drilled is neither abnormally geo- pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe Bay Unit well A -25A is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. During the inspection it was discovered the well sign is missing. A new sign will be ordered and placed at the well. The well pressure readings are TWO = SSV /1050/10. The inner annulus pressure was bled to less than 300 psi on 9/12/10 and is stable. t?/ X,4 3ov p s 4- Request BPXA requests approval for renewal of the existing suspension status for A -25A. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. } TREE _ 6" CIW WELLHEAD = McEVOY # SAF ES: WARNING: RADIO TRANSMITTER IN ACTUATOR = OTIS A-25A WEATHER MONITORING SHACK MUST BE TURNED OFF KB. ELEV 87.68' BEFOREANY WELL WORK INVOLVING EXPLOSIVES BF. ELEV = 51.98' CAN BEGIN. CONTACT PAD OPERATOR. A -25A HAS KOP - 1100' CMT PLUG FROM TD TO 11883'. Max Angle = 58 @ 10000' Datum MD Datum TV D = 8800' SS 2425' 4 -1 /2" HES X NIP, ID = 3.813" 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 3152' 4 -1/2" TBG, 12.6 #, L-80_0152 bpf, ID = 3310' 3311' 4 -1/2" WLEG Minimum ID = 3.813" @ 2425' GAS LIFT MANDRELS 4 -1/2" HES X NIPPLE ST MD TVD DEV TYPE I VLV LATCHI PORT DATE TOP OF 7" BOT HGR TIEBACK SLV 11486' 11883' — i TOP OF CMT P & A PLUG 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 11957' 7" MILLOUT WINDOW 12109'- 12121' TOP OF WHIPSTOCK 12109' 7 CIBP 12127' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 6.125" P & A'd OPEN HOLE 13092' SIDETRACK TD 7" LNR, 26 #, L -80, ID = 6.276 ", 1281r DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/23/82 ORIGINAL COMPLETION 05/24/01 RN /TP CORRECTIONS WELL: A -25A 07/13/89 RWO 11/22101 RIG SIDETRACK (P &A'D) PERMIT No: 201 -1480 04/09197 TBG PUNCH 12/29/01 CH/TP CORRECTIONS API No: 50- 029 - 20764 -01 02106/01 SIS-MH CONVERTED TO CANVAS 2651' SNL & 1703' WEL, Sec. 35, T11 N, R 13E 03/05/01 SIS -LG I FINAL BP Exploration (Alas4.a) TREE= OW , PROPOSED TRANSMITTER WELLHEAD= McEVOY ACTUATOR = OTIS A -2 5 B SAFETY yVEATHER MONITORING SHACK MUST UU E URNED OFF KB. ELEV = 87.68' BEFORE ANY WELL WORK INVOLVING EXPLOSIVES BF. ELEV = 51.98' CAN BEGIN. CONTACT PAD OPERATOR A -25A HAS KOP = 1100' CMT PLUG FROM TD TO 11883'. Max Angle = 38 @10000' Datum MO = Datum _ TVD _ — 8800' 8800' SS I —2000 H4-1/2" HES X NIP, ID = 3.813" 13 -3/8" CSG, 72 #, L -80, ID = 12347' H 3152' I 17" x 9 -5/8" Casing hanger / Packer —I 8050' I • p GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 '3500 50 Minimum ID = 3.813" @ 2000' 2 '5000 52 4 -1/2" HES X NIPPLE 3 '5800 48 4 '6400 46 5 '7000 46 TOP OF WHIPSTOCK — 8200' - 7" CIBP — TOP OF 7" BOT HGR TIEBACK SLV H 11486' I IS 1111 " ' ', 11 19 -5 /8" CSG, 47 #, L -80, ID = 8.681" H 11957' I--I ► 1 1 111111 1 1111 1 1 11 11111111 111111111 111♦ 1 11 1: : : : :: : : : : ::: : 11. 11 111111 111111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ♦ 1 1.. 1. ♦1111111. . 1 11 � 1 � 11 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11 " � �, co - 10, 700' H 4-1/2" x 7" PKR ■■■ XXXX I 4 -1/2" TBG, 12.6# PERFORATION SUMMARY 4 13 -CR, ID = 3.833" 411111 REF LOG: 11 —10,800 I-I4 -1/2" x 7" Liner Hanger I ANGLE AT TOPPERF: �� 4 • ■ Note: Refer to Production DB for historical perf data i. vvvv, SIZE SFF INTERVAL Opn/Sqz DATE 1eeff$ 10970' H 7" LNR, 26#, L -80, ID = 6.151" 1 WAS . 1 � 11 � 1 �111111 1 N I 11 11111111 ►11111 I 11111. ►1111111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11111111 11111111' 1 1V0 ► 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 1 1.1A .14AA 7" LNR, 26#, L -80, ID = 6.276" I—I 12817' 14.5 ", 12.6#, 13-Cr, ID 3.95" — 11600' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/23/82 ORIGINAL COMPLETION 05/24/01 RN/TP CORRECTIONS WELL: A -25 07/13/89 RWO 11/22/01 RIG SIDETRACK (P & A'D) PERMIT No: XXX -XXXX 04/09/97 TBG PUNCH 12/29/01 CH/TP CORRECTIONS API No: 50- 029 -20764 02/06/01 SIS-MH CONVERTED TO CANVAS 2651' SNL & 1703' WEL, Sec. 35, T11 N, R 13E 03/05/01 SIS-LG FINAL BP Exploration (Alaska) DOYON DRILLING -- RIG 25 8i "'H °Noe 1 A -4 -A 1 ANNULAR I 111 1 41 II. " 4.Ie Tlf 1411 4 1 . - 211Plar l irillri b die 1711' 2 UPPER PIPE RAM I- i irkell • 4314A , ici,11-0 A 410 • 000 A 0 .-;(14 lo . ,01.p. g iiii 7' II' ' ii-b—aitosi i.a...-...61 _ii....a! ..in-ta........a.—iimaia a 3 BLIND/SHEAR RAMS iiri rT" , 1 — .MIAMI o 7 6 5 4 3 2 1 I 4 LOWER PIPE RAMS OM 5 CHOKE 1 / • N. 0 4 • 6 KILL 7 AU XILIARY I — , - ----..: -- - ----- 1 0 ,„ 0 W - - ''''' 8 BY-PASS 1 [x 0 I S 11 u j 111•■ 11 1 - — ..... _ I. „.... • Ili P IPF ' V1112 - ' : = • - .C _ , ., , ..r . .. ,: 0 i: BLIND SHE AR- IN= 1 somm■Iii*:. '") . ! .1■1■1 . N ' e I 0 JI46- 1 - AeklirCiy - '' _PI" ilioip PHI ' A BR - = = = PIP: il • -- — = = ( .4_ _ .....r: w • ) I 1 i • I I I. " ® : GM MEI EAU KT .5,i1 PR/..: I , &/ , '711 -, :' I ,. : Hit mu.. 0 0 ANNULAR 011E um ° I I I a llidl:: HP• : 4.,.. LIPRE PIP: RANI 0 0 0 0 ..a.A...A. . - - ... 112111,111 rm., It rER VV. I SR W... i Ral MS, 21-1/ 4 ' v 20111,11 1 L AS BLIND SHEAR RAM 0 I f= fO , Ir," L 'LOA TOA' ;'.' POTTLE 0 2, C. c: /.1,11L/LI - f OR 4 SO I ALE MO ...... ...... ZOE U [=^ ,U) 4;1' 15 TO TON PO' T 1 IT i 0 LOWE PIP RAM 0 0 a psi LI Q1 4 IWI 221 ATFO r.- *RR Ro•-• Mg5 41 0 1 A \ A? ( '7' 7 1i 0 0 0 0 CM!) MD Min ffiVE 1 1 0 o , Jo DRFRTER I INF E ... __ 2 " ] 1 a AUXILLIARYIRAM 0 l' ) DIV11,1FR 21 2000 PRI ME .-. ..,-. c MD CM IY H, 7()11.Z. CON TR( 1 Pi AREL 4" OIVER7 ER f I 0 9 ) f x ) T it C Iv / TROGEN A4PIT: Ifi 1 1 ' 1 1 1 STATE OF ALASKA • ALASKA L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Q Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ WELL 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ '- 201 -1480 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 X50- 029 - 20764 -01 -00 8. Property Designation (Lease Number) : \ 9. Well Name and Number: ADLO- 028286 PBU A -25A 10. Field /Pool(s): \ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13092 feet Plugs (measured) 11883' TOC feet true vertical 9137.92 feet Junk (measured) None feet Effective Depth measured 11883 feet Packer (measured) true vertical 8423.85 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 3152 13 -3/8" 72# L -80 SURFACE - 3152 SURFACE - 2768 4930 2670 Intermediate 11958 9 -5/8" 47# L -80 SURFACE - 11958 SURFACE - 8481 6870 4760 Production 623 7" 26# L -80 11486 - 12109 8131 - 8599 7240 5410 Liner Liner Perforation depth: Measured depth: NONE- True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 3310 SURFACE - 2866 Packers and SSSV (type, measured and true vertical depth) NONE NCB' q 2 `��a 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9EP 2 Treatment descriptions including volumes used and final pressure: /A ,... & W COMM"'Ift Anr4mp 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ - Development Service ❑ Daily Report of Well Operations X 16. Well Status after we SUSPENDED Oil El Gas 0 WDSPL LJ GSTOR ❑ WAG ❑ GINJ ❑ WINJ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564 -4944 Date �' D 7 Lug 7 4- /o.21r• /e Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT A -25A Field /Pool: PRUDHOE BAY / PRUDHOE OIL Permit # (PTD): 2011480 API Number: 50029207640100 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 11/22/2001 Surface Location: Section: 35 Twsp: 11N Range: 13E Nearest active pad or road: PRUDHOE BAY A -PAD Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Clean & dry Location cleanup needed: No' Pits condition: Good - clean water Surrounding area condition: Good Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: No Samples taken: No Access road condition: Good Photographs taken (# and description): (2) weilhouse & pits Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Well description, condition: McEvoy wellhead; CiW tree - good condition Cellar description, condition, fluids: Dry Rat Hole: None Wellhouse or protective barriers: Wellhouse Well identification sign: None Tubing Pressure (or casing if no tubing): SSV Annulus pressures: IA: 1050 psi OA: 10 psi XA 9 0 s °l !t /0 3 a ° p S Wellhead Photos taken (# and description): (2) wellhead & tree Work Required: Ordered wellhouse sign / Operator Rep (name and signature): Torin Roschinger d�-�� AOGCC Inspector: Chuck Scheve Other Observers: Jack Winslow Inspection Date: 9/11/2010 AOGCC Notice Date: 9/8/2010 Time of arrival: 8:10 AM Time of Departure: 8:20 AM Site access method: Truck TRFF = 6" CM/ WELLHEAD = McEVOY A -25A SAFETY NOTES: WARNING: RADIO TRANSMITTER IN ACTUATOR = OTIS WEATHER MONITORING SHACK MUST BE TURNED OFF KB. R EV = 87.68' BEFORE ANY WELL WORK INVOLVING EXPLOSIVES BF. ELEV = 51.98, CAN BEGIN. CONTACT PAD OPERATOP, A -25A HAS KOP = 1100' CMT PLUG FROM TD TO 11883'. Max Angle = 58 @ 10000' Datum MD = Datum TV = 8800' SS —F - 2 - 4 - 25 - ' - 144-1/2' HES X NIP, ID = 3.813" 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 3152' 4 -1/2" TBG, 12.6 #, L-80_0152 bpf, ID = 3.958" 3310 3311' 4 -1/2" WLEG Minimum ID = 3.813" @ 2425' 4 -1/2" HES X NIPPLE GAS LIFT MANDRELS ST MD TVD DEV TYPE I VLV LATCH PORT DATE TOP OF 7" BOT HGR TIEBACK SLV 11486' 11883' TOP O F CMT P&A PLUG 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 11957' 7" MILLOUT WINDOW 12109'- 12121' T OF WHIPSTOCK 12109' 7 CIBP 12127' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 6.125" P& A'd OPEN HOLE 1 - 1 - 13092' SIDETRACK TD 7" LNR, 26 #, L -80, ID = 6.276" 12817' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/23/82 ORIGINAL COMPLETION 05/24/01 RN/TP CORRECTIONS WELL: A -25A 07/13/89 RWO 11/22101 RIG SIDETRACK (P &A'D) PERMIT No: 201 -1480 04/09/97 TBG PUNCH 12/29/01 CH/TP CORRECTIONS API No: 50- 029 - 20764 -01 02/06/01 SIS-MH CONVERTED TO CANVAS 2651' SNL & 1703' WEL, Sec. 35, T11 N, R 13E 03/05/01 SIS-LG FINAL SP Exploration (Alaska) 516' ►' v? 0 Enter /Exit L� 13 - U (! 35 34 11 Alk- 00 33 �. O 10 41 9 7 43 / 6 i 40 3 5 f 4 55 - Methanol Tank 3 92 29 2 r ' O 28 52 27 Enter /Exit i 26 � -- 25 ❑_ N T 24 14 23 t 32 15 22 31 42 16 38 21 37 f,__ 17 30 20 s L 18 --j L 19 i 967' -- - ►j WELL PRODUCER ■ or WELL INJECTOR A DATE : 01/06/2009 SCALE : 1" = 300' MAP DATE : 2007 PBU - A PAD WELL SLOT W /CONDUCTOR ,-Y bs14495.dgn X � fC O 0 O . CL A Q. — Q 7 Q N op yr c ' I ' � t �►rrrrr r , L , :r Yr r t ti 4. k ry 4 u a _ , I I , w F W " y , f 31 :^ i t y 0 0 A-25A (PTD #2011480) TIO Plot Well Tbg 1A OA IA OOA 1 4tf1 OOOA On ---------------- 09/25/10 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker. doc Permit to Drill 2011480 MD -- 13092 cÀ>~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Well Name/No. PRUDHOE BAY UNIT A-25A Operator BP EXPLORATION (ALASKA) INC ) lI.4..d. l t. qJ Iv ~ ð ~ ( API No. 50-029-20764-01-00 UIC N REQUIRED INFORMATION TVD Completion Date 11/22/2001 -- Completion Status SUSP Current Status SUSP Þ«r- Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: 9138 " I I i YED ! )lED I fED i C Pdt C Pdt C Pdt '4 1987 /41987 ¡f 1987 iÆD (ÉD C Pdt C Pdt -11987 -11987 (data taken from Logs Portion of Master Well Data Maint) -'.0 Log Log Run Interval OH/ Scale Media No Start Stop CH Received 1 12074 13035 Case 12/6/2002 1 12074 13035 Case 12/6/2002 3 12080 13090 Open 6/2/2003 25 Final 12109 13092 Open 6/2/2003 25 Final 12109 9137 Open 6/2/2003 25 Final 12109 13092 Open 6/2/2003 25 Final 12109 9137 Open 6/2/2003 25 Final 12109 13092 Open 6/2/2003 25 Final 12109 9137 Open 6/2/2003 Comments --- ------ - Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ¡ Rpt 'L.I$V~rîfìç~t¡()I'l j-eö 0 ~36 :L.iáV~t¡fib~tib "f kD C Asc íA 1987 ÚSVèiïfiqåtiöH rED C Pdt ./11987 MWD-ROP, DGR, EWR- MD MWD-DGR, EWR-TVD MWD-DGR, CTN, SLD-MD MWD-DGR, CTN, SLD- TVD . I MWD-DGR, CTN, SLD-MD ! MWD-DGR, CTN, SLD- TVD --.- Well Cores/Samples Information: , ---_u ---- ----- Name ADDITIONAL INFORMATION Well Cored? Y / ~ Chips Received? -y""ffl- Analysis Received? -v /ÞI -_.- -- --- --- Interval Start Stop Sample Set Number Comments Comments: Sent Received Daily History Received? g: Formation Tops DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2011480 Well Name/No. PRUDHOE BAY UNIT A-25A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20764-01-00 MD 13092 TVD 9138 Completion Date 11/22/2001 Completion Status SUSP Current Status SUSP UIC N Compliance Reviewed By: ~ Date: 3 }~~.1 ~- ----.. Ii \t /' ~ 30\ - \ t-\3 } \9 8~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn. : Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage, Alaska 99501 May 14, 2003 RE: MWD Formation Evaluation Logs: A-25 A, AK-MM-11181 A-25A: Digital Log Images 50-029-20764-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~ ~:, ~~" a~ Date: r:,~2; \:!~;I, ,po...",~ t""" ~. Ii', û' .¡;"" :.;"',;;:, ¡"''""", ¡r' \" !.' 1',1,"""" H " (i~.",~~ tL~". Ü ';5' lb."", ~L",,~¡i !~ ITl1 l'. ,") c'.: .,":: vi t), r,] \.1 c:. ,:.. ,,' ~~~~~ , !{ " \1" \ ¿;<Ol-Ir.¡~ l133~ WELL LOG TRANSMITf AL To: State of Alaska Alaska Oil and Gas Conservation COmtn. Attn.: Lisa Weepie 333 West 7tl1 Avenue, Suite 100 Anchorage, Alaska December 04, 2002 RE: MWD Formation Evaluation Logs A-25 A, AK-M1v1-11181 1 LDWG formatted Disc with verification listing. API#: 50-029-20764-01 PLEASE ACKNOWLEDGE RtCEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: s ign~/ ....Qz RfJ ~ ..-/ RECE\VED DEC 06 2002 Alaska Oli & Gas Cons. Commission Anchorage " ',' (" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well DOil 0 Gas 181 Suspended 0 Abandoned 0 Service 2. Name of Operator . i.OcA t~~ 7. Permit Number BP Exploration (Alaska) Inc. ~~ao 201-148 301-327 3. Address s~fft[' ':, 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 .5 (.) ~l-u J?Û .r!.H..~~ 50- 029-20764-01 4. Location of well at surface i"\ ~;hv:,',~'-~~'¡ ,_. 9. Unit or Lease Name 26511 SNL, 1703' WEL, SEC. 35, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval .~ ..JJ..:2Z, 61 ) NIA ' -__I 4 ~ -:; ,:'r1 ,\ 10. Well Number At total depth r ' ." ¡ """ .¡ 37991 NSL, 3819' EWL, SEC. 25, T11N, R13E, UM ,.::::;.,,~.::J A-25A 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field 1 Prudhoe Bay Pool 79.98' ADL 028286 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 11/16/2001 11/18/2001 11/22/2001 NIA MSL Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13092 9138 FT 11883 8424 FT 181 Yes DNo NIA MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" X 30" Insulated Conductor Surface 110' 36" a cu Vds Concrete 13-3/8" 72# L-80 Surface 3152' 17-1/2" 14365 cu ft Permafrost 9-518" 47# L-80 Surface 11958' 12-1/4" 1610 cu ft Class 'G' 7" 26# IJ4S 11486' 12109' 8-1/2" 420 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 3310' N/A MD TVD MD TVD (Kill String) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11883' Suspension Plug #1: 32.7 Bbls Class 'G' 2000' Freeze Protect with 160 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production NI A (Dry Hole) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECE\VED DEC ~8 2001 A'aska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 UK I (J IN AlBBOMS BFL Submit In Duplicate 1J DEC 3 0 2001 CJI ( (' 29. Marker Name Geologic Markers Measured True Vertical Depth Depth 12109' 8599' 12309' 8738' 12393' 8786' 12536' 8862' 12632' 8905' 12940' 9055' 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sadlerochit Zone 4A Zone 3 Zone 2C Zone 28 Zone 2A 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the fore oing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date \~.~ 7.ó! A-25A Well Number 201-148 301-327 Permit No. / A roval No. Prepared By Name/Number: Terrie Hubble, 564.4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1 : Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none', Form 10-407 Rev. 07-01-80 Legal Name: A-25A Common Name: A-25A Test Date 11/14/2001 "" TêsfType . " FIT , , ~ , , , ..' ',' ,~ " 'Test Depth (TMI» 12,097.0 (ft) BP EXPLORATION ,:' "'.. ""~' ::~ , , '", " 1.~eak~9ff1est Summa , ~ , ~ test- Depth (WD) 8,580.0 (ft) AMW 8.40 (ppg) Surface Pressure 670 (psi) Leak Off Pressure (BHP) 4,414 (psi) Page 1 of 1 EMW 9.90 (ppg) '-"0 ,~, Printed: 11/27/2001 4:58:43 PM (' f" \. BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: A-25A Common Well Name: A-25A Spud Date: 11/16/2001 Event Name: ORIG DRILLING Start: 11/7/2001 End: 11/22/2001 Contractor Name: DOYON Rig Release: 11/22/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/612001 20:00 - 00:00 4.00 MOB P DECOMP MOVED IN FROM A-02i, SPOTTED RIG. 11/7/2001 00:00 - 03:00 3.00 MOB P DECOMP HELD PJSM. SHIMMED AND LEVELED RIG. CLOSED CELLAR WALLS, SECURED STAIRS AND STEPS. INSTALLED BOARDS AROUND WELL. N I U 2nd IA VALVE. SPOTTED SLOP TANK, SPOTTED AND HOOKED UP TIGER TANK. DSM INSTALLED HARDLINE FROM A-25 TO A-26. 03:00 - 05:30 2.50 RIGU P DECOMP TOOK ON SEAWATER. R I U CIRCULATING LINES. PRESSURE TESTED HARDLINE. ACCEPTED RIG @ 0300 HRS 11 I 07 I 2001. 05:30 - 06:30 1.00 WHSUR P DECOMP HELD PJSM. R I U DSM LUBRICATOR, PULLED BPV, RID DSM LUBRICATOR. 06:30 - 07:30 1.00 CLEAN P DECOMP HELD PJSM. M / U TREE CAP, R / U CIRCULATING LINE TO TREE CAP. 07:30 - 10:00 2.50 CLEAN P DECOMP OPENED WELL AND CIRCULATED OUT FREEZE PROTECT FROM WELL. PUMPED DOWN TUBING, TOOK RETURNS OFF OF 9-5/8" x 4-1/2" IA DOWN HARDLINE TO WELL A-26 FLOWLINE. PUMP RATE 8.5 BPM, SPP 1,000 PSI. 10:00 - 11 :00 1.00 CLEAN P DECOMP ALLOWED IA AND TUBING TO EQUALIZE. VACUUM OUT AND BROKE DOWN HARDLINE. 11 :00 - 12:30 1.50 WHSUR P DECOMP HELD PJSM. SET TWC. R I U AND TESTED TWC TO 1,000 PSI. OK. 12:30 - 14:00 1.50 WHSUR P DECOMP BLED DOWN AND PLUGGED OFF CONTROL LINES. N I 0 PRODUCTION TREE. 14:00 - 14:30 0.50 WHSUR P DECOMP CLEANED HANGER, M I U CROSS OVER AND CHECKED THREADS. 14:30 - 20:30 6.00 BOPSUF P DECOMP HELD PJSM. N I U BOPE. CHANGED OUT TOP PIPE RAMS TO 4-1/2" x 7" VARIABLES. 20:30 - 23:00 2.50 BOPSUF P DECOMP R I U TEST JOINT AND EQUIPMENT. TESTED BOPS. TESTED UPPER PIPE RAMS, BLIND RAMS, CHOKE MANIFOLD, MANIFOLD VALVES, HCR, KILL LINE, CHOKE LINE AND VALVES, TIW, DART AND ALL FLOOR VALVES TO 3,500 PSI HIGH 1250 PSI LOW. TESTED ANNULAR TO 3,500 PSI HIGH 1250 PSI LOW. HIGH PRESSURE TESTS HELD FOR 10 MIN, LOW PRESSURE TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD wI NO LEAKS OR PRESSURE LOSS. UNABLE TO TEST LOWER PIPE RAMS DUE TO HEIGHT OF TUBING HANGER AND TWC. WITNESSING OF TEST WAIVED BY JOHN CRISP wI AOGCC. 23:00 - 00:00 1.00 PULL P DECOMP HELD PJSM. BLEW DOWN CHOKE MANIFOLD, CLEANED RIG FLOOR, R I U POWER TONGS, P I U DSM LUBRICATOR. 11/8/2001 00:00 - 01 :00 1.00 WHSUR P DECOMP HELD PJSM. PULLED TWC, RID DSM LUBRICATOR. 01:00 - 01:30 0.50 PULL P DECOMP MADE UP BAKER SPEAR wI PACK OFF, XO, 1 JOINT 5" DP. 01 :30 - 02:00 0.50 PULL P DECOMP LOWERED SPEAR THROUGH TUBING HANGER AND ENGAGED GRAPPLES. BACKED OUT LOS. OBSERVED 0 PSI ON IA. PULLED UP ON TUBING STRING TO 80,000#, HANGER CAME FREE. PULLED TUBING HANGER TO FLOOR, STRING WEIGHT 75,000#. 02:00 - 02:30 0.50 PULL P DECOMP BROKE OUT LID 5" DP AND BAKER SPEAR. DISCONNECTED AND PLUGGED CONTROL LINES. BROKE Printed: 11/27/2001 4: 13 :36 PM ( ('" BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: A-25A Common Well Name: A-25A Spud Date: 11/16/2001 Event Name: ORIG DRILLING Start: 11/7/2001 End: 11/22/2001 Contractor Name: DOYON Rig Release: 11/22/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/8/2001 02:00 - 02:30 0.50 PULL P DECOMP OUT AND LID TUBING HANGER. 02:30 - 03:30 1.00 PULL P DECOMP R / U 4-1/2" TUBING HANDLING EQUIPMENT AND CAMCO SPOOLING EQUIPMENT TO SPOOL UP CONTROL LINES. 03:30 - 07:30 4.00 PULL P DECOMP POOH, BROKE OUT AND LID 50 JTS 4-1/2" 12.6# TUBING. 07:30 - 08:00 0.50 PULL P DECOMP L /0 SSSV ASSEMBLY. RID CAMCO CONTROL LINE SPOOL AND EQUIPMENT. 08:00 - 09:30 1.50 PULL P DECOMP POOH, LID 4-1/2" TUBING. 09:30 - 10:30 1.00 PULL P DECaMP SPILL DRILL, REPLACE FLOWLINE AIR BOOT. 10:30 - 13:00 2.50 PULL P DECOMP POOH, LID TUBING. LID TOTAL 157 JOINTS 4-1/2" 12.6# TUBING, 1 SSSV ASSEMBLY, 1 GLM ASSEMBLY, 1 CUT JOINT - 20.25'. 13:00 -13:30 0.50 BOPSUF P DECaMP M I U TEST JOINT AND PLUG. SET TEST PLUG IN WELLHEAD. 13:30 - 14:00 0.50 BOPSUF P DECOMP CLOSED LOWER PIPE RAMS. TESTED LOWER PIPE RAMS TO 3,500 PSI HIGH 1250 PSI LOW. HIGH PRESSURE TEST HELD FOR 10 MIN, LOW PRESSURE TEST HELD FOR 5 MIN. PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. 14:00 - 14:30 0.50 BOPSUf; P DECOMP BROKE OUT AND L / 0 TEST PLUG. RAN AND SET WEAR BUSHING. 14:30 - 17:00 2.50 PULL P DECOMP LID 3-1/2" KELLY ASSEMBLY AND BUSHINGS. PI U AND M I U 5-1/4" KELLY ASSEMBLY AND BUSHINGS. 17:00 - 17:30 0.50 PULL P DECOMP PRESSURE TESTED KELLY, KELLY COCK VALVE, TIW VALVE AND STANDPIPE TO 3,500 PSI HIGH f/10 MINUTES, 250 PSI LOW f/5 MINUTES. PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. 17:30 - 20:00 2.50 PULL P DECOMP HELD PJSM. MADE UP FISHING BHA-8-3/8" CUT LIP GUIDE, OVERSHOT wI 4-1/2" BASKET GRAPPLE - OVERSHOT EXTENSION - TOP SUB - BUMPER SUB - 6-1/4" OIL JARS - XO - 9-6" D.C. - XO - ACCELERATOR JARS. BHA LENGTH 312.10'. TOP OF FISH 6,300'. 20:00 - 00:00 4.00 PULL P DECOMP RIH PICKED UP 5" DRILL PIPE. TALLIED AND DRIFTED ( 110 JTS IN AT 0000 HRS) 11/9/2001 00:00 - 04:30 4.50 PULL P DECOMP HELD PJSM. TALLIED, DRIFTED AND PI U 5" DP AND RIH TO 6,283' 04:30 - 05:00 0.50 PULL P DECOMP PI U KELLY. BROKE CIRCULATION, PUMP RATE 2 BPM, SPP 300 PSI. STRING WEIGHT UP 150,000#, STRING WEIGHT DOWN 95,000#. TAGGED TOP FISH AT 6,307'. SWALLOWED FISH, PUMP PRESSURE INCREASED TO 500 PSI, SHUT DOWN PUMPS AND FULLY ENGAGED TUBING STUMP WITH OVERSHOT AND GRAPPLE. PULLED UP ON DRILL STRING TO 185,000#, ALLOWED JARS TO BLEED OFF. PULLED UP TO 250,000#, FISH BEGAN TO MOVE, STRING WEIGHT DECREASED TO 225,000#. BROKE OFF KELLY AND RACK BACK. POOH 30' AND L /0 1 JT OF DP. 05:00 - 07:30 2.50 PULL P DECaMP CIRCULATED BOTTOMS UP. PUMP RATE 5 BPM, SPP 1,000 PSI. CIRCULATED BACK PERF PILL AND SLIGHT AMOUNT OF GAS. CIRCULATED UNTIL RETURNS OVER SHAKERS WERE CLEAN. 07:30 - 08:00 0.50 PULL P DECOMP MONITORED WELL, BLEW DOWN KELLY, P I U 1 JT OF 5" DP. 08:00 - 12:00 4.00 PULL P DECOMP POOH wI 5" DP TO FISHING BHA. Printed: 11/27/2001 4:13:36 PM ( ~: BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: A-25A Common Well Name: A-25A Spud Date: 11/16/2001 Event Name: ORIG DRILLING Start: 11/7/2001 End: 11/22/2001 Contractor Name: DOYON Rig Release: 11/22/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1119/2001 12:00 - 12:30 0.50 PULL P DECOMP SET BACK 6" DC, LID JARS, BROKE OUT AND LID OVERSHOT. 12:30 - 13:00 0.50 PULL P DECOMP HELD PJSM. R I U TUBING EQUIPMENT. 13:00 -18:00 5.00 PULL P DECOMP POOH, LID 125 JTS 4-1/2" 12.6# TUBING, 3 - GLM ASSEMBLIES, X NIPPLE ASSEMBLY AND SBR OVERSHOT. 18:00 -19:00 1.00 PULL P DECOMP RID AND CLEANED TUBING EQUIPMENT, CLEANED RIG FLOOR, R I U HOSES TO STRIP-O-MATIC SLID OVER HOLE 19:00 - 19:30 0.50 PULL P DECOMP MADE UP OVERSHOT BHA, 83/8" GUIDE, 81/8" OVERSHOT DRESSED WITH 5 318" GRAPPLE, 8 1/8" EXT TOP SUB, 6 1/4" BUMPER SUB, 61/4" OIL JARS, XO, 9 X 6 1/2" DC, XO, 61/4" ACCELERATOR. BHA LENGTH 312.10'. 19:30 - 21:30 2.00 PULL P DECOMP RIH wI BHA ON 5" DP OUT OF DERRICK TO 6,314' 21 :30 - 00:00 2.50 PULL P DECOMP CONTINUED TO RIH wI BHA PICKING UP 5" DRILL PIPE TO 8,216' AT 0000 HOURS 11/10/2001 00:00 - 02:30 2.50 PULL P DECOMP HELD PJSM. RIH wI BHA, P I U & DRIFTED 5" DP FROM PIPE SHED. 02:30 - 03:30 1.00 PULL P DECOMP LOADED PIPE SHED wI 5" DP 03:30 - 05:00 1.50 PULL P DECOMP RIH wI BHA TO 11,283'. PI U & DRIFTED 5" DP FROM PIPE SHED. 05:00 - 06:30 1.50 PULL P DECOMP HELD PJSM. SLIPPED AND CUT DRILLING LINE. 06:30 - 07:00 0.50 PULL P DECOMP RIH wI BHA ON 5" DP TO 11,394' 07:00 - 07:30 0.50 PULL P DECOMP PI U KELLY, BROKE CIRCULATION, PUMP RATE 4 BPM, SPP 150 PSI. STRING WEIGHT UP 320,000#, STRING WEIGHT DOWN 125,000#, STRING WEIGHT ROTATING 188,000#, TORQUE 380 AMPS. SWALLOWED FISH, PUMP PRESSURE INCREASED TO 500 PSI. SHUT DOWN PUMPS. FULLY ENGAGED FISH. PULLED UP TO 350,000#, BLED OFF JARS. SLACKED OFF TO 210,000#. ROTATED DRILL STRING TO THE RIGHT 18 TURNS, RELEASED K ANCHOR. 07:30 - 09:30 2.00 PULL P DECOMP CIRCULATED TO CLEAN UP THE HOLE. PUMP RATE 6 BPM, SPP 200 PSI. CIRCULATED BACK PERF PILL, NO GAS. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. 09:30 - 15:00 5.50 PULL P DECOMP POOH wI 5" DP TO BHA. 15:00 - 15:30 0.50 PULL P DECOMP BROKE OUT AND SET BACK BHA. 15:30 - 16:00 0.50 PULL P DECOMP BROKE OUT AND LID FISH AND OVERSHOT. 100% RECOVERY OF K ANCHOR. 16:00 - 17:00 1.00 PULL P DECOMP HELD PJSM. MADE UP FISHING BHA-3-1/4" SPEAR wI 4.01" GRAPPLE, XO, STOP SUB - BUMPER SUB - 6-1/4" OIL JARS - XO - 9-6" D.C. - XO - ACCELERATOR JARS - PUMP OUT SUB. BHA LENGTH 311.58', SPEAR SPACED OUT 28.5" FROM MIDDLE OF GRAPPLE TO STOP SUB TO CATCH SHIFTING SLEEVE IN PACKER. 17:00 - 21:30 4.50 PULL P DECOMP RIH wI BHA ON 5" DP TO 11,390'. 21 :30 - 22:00 0.50 PULL P DECOMP PI U KELLY, STRING WEIGHT UP 300,000#, STRING WEIGHT DOWN 135,000#. BROKE CIRCULATION, PUMP RATE 4 BPM, SPP 300 PSI. ENGAGED TIW PACKER wI SPEAR AT 11,444'. PUMP PRESSURE INCREASED TO 500 PSI, SHUT DOWN PUMP. PULLED 30,000# OVER TO 330,000#, BLED OFF JARS, PICKED BACK UP 30,000# OVER TO 330,000# HELD FOR 10 MIN, PICKED UP 80,000# OVER TO 380,000#, SLACKED OFF TO 200,000#, PULLED Printed: 11/27/2001 4:13:36 PM ( ( \ BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: A-25A Common Well Name: A-25A Spud Date: 11/16/2001 Event Name: ORIG DRILLING Start: 11/7/2001 End: 11/22/2001 Contractor Name: DOYON Rig Release: 11/22/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/10/2001 21 :30 - 22:00 0.50 PULL P DECOMP 100,000# OVER TO 400,000#, NO PACKER MOVEMENT. 22:00 - 23:00 1.00 PULL P DECOMP BEGAN JARRING ON PACKER wI 50,000# OVER AT 350,000#, WORKED UP TO 100,000# OVER AT 400,000# FOR 45 MIN, PACKER CAME FREE, PULLED UP 30', 75,000# - 50,000# DRAG. 23:00 - 00:00 1.00 PULL P DECOMP PUMPED AND CIRCULATED HI VIS SWEEP, PUMP RATE 7 BPM, SPP 500 PSI. 11/11/2001 00:00 - 01 :00 1.00 PULL P DECOMP HELD PJSM. PUMPED AND CIRCULATED HI VIS SWEEP, PUMP RATE 7 BPM, SPP 500 PSI. 01:00 - 01:30 0.50 PULL P DECOMP MONITORED WELL, BLEW DOWN KELLY. 01 :30 - 09:00 7.50 PULL P DECOMP POOH wI 5" DP TO BHA. FIRST 11 STANDS OUT OF THE HOLE AVERAGE DRAG 50,000#, FROM THAT POINT TO SURFACE AVERAGE DRAG 25,000#. 09:00 - 09:30 0.50 PULL P DECOMP LID ACCELERATOR JARS, STOOD DRILL COLLARS IN DERRICK. 09:30 - 10:30 1.00 PULL P DECOMP HELD PJSM. BROKE OUT SPEAR FROM PACKER. BROKE OUT AND LID SPEAR, BUMPER SUB AND OIL JARS. 10:30 -11:00 0.50 PULL P DECOMP BROKE OUT AND LID TIW PACKER. RECOVERED PACKER w/1 0% OF PACKER RUBBER ELEMENT AND 2 OF 5 BOTTOM SLIPS DOGS. 11 :00 - 11 :30 0.50 PULL P DECOMP HELD PJSM. R I U TUBING TONGS AND EQUIPMENT. 11 :30 - 13:30 2.00 PULL P DECOMP BROKE OUT AND LID 4-1/2" TUBING. RECOVERED 24 JOINTS AND 1 CUT JOINT. TOTAL TUBING RECOVERED 801.20'. 13:30 - 14:00 0.50 PULL P DECOMP RID TUBING TONGS AND EQUIPMENT, CLEANED FLOOR. 14:00 - 14:30 0.50 STWHIP P WEXIT R I U TO RUN CLEAN OUT ASSEMBLY. 14:30 - 16:00 1.50 STWHIP P WEXIT M / U USED HTC 6-1/8" ATJ-4 BIT, SER#Y20JF TO CLEAN OUT BHA. PI U 13 JTS 3-1/2" HWDP, 9 - 4-3/4" DC. 16:00 - 20:30 4.50 STWHIP P WEXIT RIH wI CLEAN OUT BHA ON 5" DP.TO 12,155', PICKED UP 4 JOINTS FROM PIPE SHEAD 20:30 - 21 :00 0.50 STWHIP P WEXIT M / U KELLY, BROKE CIRCULATION, TAGGED TOP OF LINER AT 11,493' BIT AT 12,178'. PUMP RATE 6 BPM, SPP 1,100 PSI 21 :00 - 22:00 1.00 STWHIP P WEXIT CIRCULATED BOTTOMS UP TRACE OF GAS, OIL AND SOME SAND ACROSS SHAKER. PUMP RATE 6 BPM, SPP 1,100 PSI 22:00 - 00:00 2.00 STWHIP P WEXIT HELD PJSM, PUMPED 20 BBL DIRT MAG, 50 BBL BARCARB PILL, DISPLACED HOLE TO QUICKDRILL MUD, TOOK SEAWATER RETURNS DOWN HARDLINE TO WELL # A-26. PUMP RATE 6 BPM, SPP 1,200 PSI. 11/12/2001 00:00 - 02:00 2.00 STWHIP P WEXIT HELD PJSM. CONTINUED TO DISPLACE HOLE TO QUIKDRIL MUD, TOOK SEAWATER RETURNS DOWN HARDLINE TO A-26 FLOWLINE. PUMP RATE 6 BPM, SPP 1,200 PSI. CLEANED MUD PITS. 02:00 - 04:30 2.50 STWHIP P WEXIT CIRCULATED COMPLETE MUD SYSTEM, RAN AND CHECKED SOLIDS CONTROL EQUIPMENT. 04:30 - 05:00 0.50 STWHIP P WEXIT MONITORED WELL. RACKED BACK AND BLEW DOWN KELL Y. 05:00 - 07:30 2.50 STWHIP P WEXIT HELD PJSM. POOH, BROKE OUT AND L / 0 60 JOINTS OF 5"DP. 07:30 - 12:00 4.50 STWHIP P WEXIT POOH, RACKED DP IN DERRICK. 12:00 - 13:30 1.50 STWHIP P WEXIT HELD PJSM. BROKE OUT AND LID 9 - 6" DC 13:30 - 14:00 0.50 STWHIP P WEXIT POOH wI REMAINING BHA, BROKE OUT AND LID 9-5/8" & Printed: 11/27/2001 4:13:36 PM ¡' ( ( BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: A-25A Common Well Name: A-25A Spud Date: 11/16/2001 Event Name: ORIG DRILLING Start: 11/7/2001 End: 11/22/2001 Contractor Name: DOYON Rig Release: 11/22/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/12/2001 13:30 - 14:00 0.50 STWHIP P WEXIT 7" CASING SCRAPER. 14:00 -15:30 1.50 STWHIP P WEXIT HELD PJSM. R / U SCHLUMBERGER SHEEVES AND EQUIPMENT. 15:30 -17:30 2.00 STWHIP P WEXIT RIH wI 6.10" GAUGE RING AND JUNK BASKET ON SCHLUMBERGER E-LINE. TAGGED UP AT 11,483', COULD NOT WORK THROUGH, GAUGE RING HANGING UP. POOH w/ GAUGE RING AND JUNK BASKET. 17:30 - 21:00 3.50 STWHIP P WEXIT RIH wI 5.9" GAUGE RING AND JUNK BASKET ON SCHLUMBERGER E-LINE TO 12,178', POOH WITH GAUGE RINGIJUNK BASKET. RECOVERED + 1- 1 GALLON OF CMT CUTTINGISAND IN JUNK BASKET. 21 :00 - 22:00 1.00 STWHIP P WEXIT M / U 7" E-LINE SET HALLIBURTON CIBP. 22:00 - 00:00 2.00 STWHIP P WEXIT RIH wI 7" CIBP ON SCHLUMBERGER E-LINE. CORRELATED wI CASING COLLAR LOCATOR. SET CIBP AT 12,112'. POOH WITH E-LINE AT REPORT TIME. 11/13/2001 00:00 - 00:30 0.50 STWHIP P WEXIT SCHLUMBERGER POOH E-LINE AND CIBP SETTING TOOL 00:30 - 01 :30 1.00 STWHIP P WEXIT RIGGED DOWN SCHLUMBERGER 01 :30 - 02:00 0.50 STWHIP P WEXIT PRESSURE TESTED CIBP & CASING TO 3000 PSI CHARTED 30 MIN 02:00 - 03:00 1.00 STWHIP P WEXIT CUT BRACE IN CELLAR TO ADJUST MOUSE HOLE. WELDED IN MUD BUCKET CONNECTION THROUGH LINE IN RIG FLOOR 03:00 - 09:00 6.00 STWHIP P WEXIT MADE UP WHIPSTOCK BHA ( PRESSURE TESTED MWD, PUMP RATE 250 GPM PLUSE PRESSURE 600 PSI TO 700 PSI) RIH PICKED UP 60 JTS 3 1/2" DP FROM SHED. 09:00 - 14:30 5.50 STWHIP P WEXIT RIH WITH 5" DP OUT OF DERRICK FILL DP EVERY 20 STD RUN TO 11,400' BROKE CIRCULATION 14:30 -15:00 0.50 STWHIP P WEXIT SLIP AND CUT DRILLING LINE 60' 15:00 - 15:30 0.50 STWHIP N DPRB WEXIT CONTINUE RIH, TOOK WEIGHT AT 11,531', ATEMPTED TO WORK PAST 15:30 -18:30 3.00 STWHIP N DPRB WEXIT RACK ONE STAND, PU AND WASH ( 2 ) TWO SINGLES DOWN FROM 11490' TO 11531' ( UNABLE TO WASH PAST) LAID ( 2) TWO SINGLES, PICKED UP KELLY ROTATED AND WASHED TO 11534', RACK KELLY BACK 18:30 -19:30 1.00 STWHIP P WEXIT RIH TO 12069' 19:30 - 20:00 0.50 STWHIP P WEXIT PICKED UP KELLY, ORIENTATED @ 48* RIGHT, WASH DOWN TAG CIBP AT 12,127', SET WHIPSTOCK, TOP @ 12,109' BOTTOM @ 12,121' 20:00 - 00:00 4.00 STWHIP P WEXIT TOOK SLOW PUMP RATE AT 50-40-30 SPM, MILLED WINDOW FROM 12,109' TO 12,117' AT REPORT TIME 11/14/2001 00:00 - 06:30 6.50 STWHIP P WEXIT FINISHED MILLING SIDETRACK WINDOW, DRILL FROM BOTTOM OF WINDOW AT 12,121' TO 12134' (TOP OF WINDOW 12109'-12,121' ) 06:30 - 07:00 0.50 STWHIP P WEXIT WASH AND REAM WINDOW 07:00 - 09:30 2.50 STWHIP P WEXIT CIRCULATE AND CONDITIONED MUD, PUMPED HI VIS PILL 09:30 - 11 :00 1.50 STWHIP P WEXIT PREFORMED FIT, 12,079' , MUD WT 8.4 PPG EST MUD WT 9.9 PPG SURFACE PRESSURE 670 PSI CHARTED 15 MIN, BLED BACK 3 BBL 11 :00 - 11 :30 0.50 STWHIP P WEXIT PUMPED DRY JOB, BLOW KELLY DOWN, SET KELLY BACK 11 :30 - 12:00 0.50 STWHIP P WEXIT DP STILL OUT OF BALANCE, PUMPED SECOND DRY JOB 12:00 - 16:00 4.00 STWHIP P WEXIT POOH TO 2831' l Printed: 11/27/2001 4:13:36 PM BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: A-25A Common Well Name: A-25A Spud Date: 11/16/2001 Event Name: ORIG DRILLING Start: 11/7/2001 End: 11/22/2001 Contractor Name: DOYON Rig Release: 11/22/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/14/2001 16:00 - 16:30 0.50 STWHIP P WEXIT CLEAN RIG FLOOR, PUMPED SLUG 16:30 -17:30 1.00 STWHIP P WEXIT LAID DOWN 39 JTS 31/2" DRILL PIPE 17:30 -19:30 2.00 STWHIP P WEXIT FINISH POOH STOOD REMAINING 31/2" DP AND HWDP IN DERRICK, LAID DOWN 9 X 4 3/4" DRILL COLLARS AND SIDETRACK BHA 19:30 - 22:30 3.00 STWHIP P WEXIT WEEKLY BOPE PRESSURE TEST, LOW 250 PSI AND HIGH 3500 PSI, ALL TESTED GOOD (NOTE!! TESTED MANIFOLD WHILE POOH) 22:30 - 00:00 1.50 STWHIP P WEXIT MAKING UP MWD DIRECTIONAL BHAAT REPORT TIME 11/15/2001 00:00 - 01 :00 1.00 STWHIP P WEXIT CONTINUE MAKE UP DIRECTIONAL BHA 01 :00 - 03:00 2.00 STWHIP P WEXIT UPLOAD AND TEST MWD 03:00 - 03:30 0.50 STWHIP P WEXIT LOAD SOURCE IN MWD 03:30 - 13:00 9.50 STWHIP P WEXIT RIH TO 12084' 13:00 - 17:30 4.50 STWHIP N HMAN WEXIT ORIENT TOOL FACE 50* RIGHT, ATTEMPT TO EXIT WINDOW, MAX WT ON BIT 25,000 LB (DRILLERS MEASURE BIT DEPTH 12114) 17:30 - 18:30 1.00 STWHIP N HMAN WEXIT DROPPED PBL BALL, PUMPED SLUG 18:30 - 00:00 5.50 STWHIP N HMAN WEXIT PJSM, POOH TO BHA @ REPORT TIME 11/16/2001 00:00 - 05:00 5.00 STWHIP N HMAN WEXIT POOH WITH MWD BHA, ( FOUND HANG OFF SUB 11 .29' NOT INCLUDED IN BHA MEASURMENT) (THE BIT WAS ACTUALL Y IN OPEN HOLE, NOT ON THE SLIDE) (BIT DEPTH 12,125') 05:00 - 07:00 2.00 STWHIP N HMAN WEXIT MADE UP SAME MWD BHA AND ORIENTATED 07:00 - 08:00 1.00 STWHIP N HMAN WEXIT UPLOAD MWD 08:00 - 08:30 0.50 STWHIP N HMAN WEXIT MADE UP PBL SUB AND TEST MWD 08:30 - 09:00 0.50 STWHIP N HMAN WEXIT LOAD SOURCE 09:00 - 18:30 9.50 STWHIP N HMAN WEXIT RIH TO 12,031 18:30 - 19:00 0.50 STWHIP N HMAN WEXIT ORIENTATE TOOL FACE 19:00 - 20:00 1.00 STWHIP P WEXIT REAMED UNDER GAGE HOLE FROM 12,121' TO 12,134' 20:00 - 00:00 4.00 STWHIP P WEXIT SLIDE DRILL 61/8" HOLE FROM 12,134' TO 12,235' AT - - REPORT TIME 11/17/2001 00:00 - 08:30 8.50 STWHIP P WEXIT DIRECTIONALL Y DRILLED 61/8" HOLE FROM 12235' TO 12,304' ( PUMPED HI VIS PILL) 08:30 - 09:30 1.00 STWHIP P WEXIT WIPER TRIP TO 12,121' 09:30 - 00:00 14.50 STWHIP P WEXIT DRIECTIONALLY DRILLED 61/8" HOLE TO 12,712' AT REPORT TIME 11/18/2001 00:00 - 21 :00 21.00 STWHIP P WEXIT DIRECTIONAL DRILLED 6 1/8" HOLE TO TO AT 13,092, 21 :00 - 23:30 2.50 STWHIP P WEXIT CIRCULATED FOR LINER, PUMPED HI VIS PILL 23:30 - 00:00 0.50 STWHIP P WEXIT WIPER TRIP OUT TO 12,130' 11/19/2001 00:00 - 01 :30 1.50 STWHIP P WEXIT RIH FROM 12130' TO TO AT 13092, (HOLE IN GOOD . ---:>0- CONDITION) 01 :30 - 03:00 1.50 STWHIP P WEXIT CIRCULATE CONDITION HOLE FOR LINER 03:00 - 04:00 1.00 STWHIP P WEXIT BLOW KELLY DOWN, POOH PBL AT TOP OF LINER ( 11493' ) 04:00 - 07:30 3.50 STWHIP P WEXIT CROPPED BALL OPEN PBL, CIRCULATED HI VIS PILL, DROPPED BALL CLOSE PBL, PUMPED DRY JOB 07:30 - 15:00 7.50 STWHIP P WEXIT POOH TO MWD 15:00 -16:30 1.50 STWHIP P WEXIT DOWN LOAD MWD 16:30 - 17:30 1.00 STWHIP P WEXIT FINISH POOH LAID DOWN BHA 17:30 - 18:00 0.50 STWHIP P WEXIT CLEAN RIG FLOOR 18:00 - 19:30 1.50 STWHIP P WEXIT SLIP AND CUT DRILLING LINE 115' 19:30 - 21:30 2.00 STWHIP C WEXIT LAID DOWN 20 JT 3 1/2" HWDP 21 :30 - 00:00 2.50 STWHIP C WEXIT MADE UP 3112 MIXING SUB ON 31/2" DP RIH 7 STD OUT ( ( Printed: 11/27/2001 4:13:36 PM BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: A-25A Common Well Name: A-25A Spud Date: 11/16/2001 Event Name: ORIG DRILLING Start: 11/7/2001 End: 11/22/2001 Contractor Name: DOYON Rig Release: 11/22/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/19/2001 21 :30 - 00:00 2.50 STWHIP C WEXIT OF DERRICK PICKED UP 36 JTS FROM SHED CONTINUE RIH WITH 5" DRILL PIPE AT REPORT TIME 11/20/2001 00:00 - 05:30 5.50 STWHIP C WEXIT CONTINUE IN HOLE W/3 1/2" X 51/2" STRING TO 13,092' TO P&A WELLBORE. 05:30 - 09:00 3.50 STWHIP C WEXIT MIU TIW VALVE/HEADPIN & CMT LINE. CIRC & CONDITION MUD. PJSM ON CEMENT JOB. 09:00 - 10:00 1.00 STWHIP C WEXIT PT LINES TO 3000 PSI, OK. PUMP 10 BBLS WATER AHEAD, 32.7 BBLS CEMENT, & 3 BBLS WATER. PREMIUM CEMENT, 15.8 PPG, .35% HALAD-344, .5% UCS, & .09% HR-5. 4 HR THICKENING TIME @ 135 DEG. 10:00 - 11 :30 1.50 STWHIP C WEXIT POOH 10 STDS, (WET). 11:30-12:30 1.00 STWHIP C WEXIT REVERSE CIRCULATE 3500 STKS @ 12,140'. CEMENT IN RETURNS. 12:30 - 13:00 0.50 STWHIP C WEXIT PJSM. PT LINES TO 3000 PSI, OK. 13:00 -14:00 1.00 STWHIP C WEXIT PUMP 5 BBLS WATER AHEAD, 22 BBLS PREMIUM CEMENT, 3 BBLS WATER BEHIND & DISPLACE. 14:00 - 14:30 0.50 STWHIP C WEXIT POOH 7 STDS TO 11,470', (DRY). 14:30 - 15:30 1.00 STWHIP C WEXIT REV CIRCULATE 3500 STROKES, NO CEMENT BACK. 15:30 -16:00 0.50 STWHIP C WEXIT POOH 5 STDS TO 10,995'. 16:00 - 20:30 4.50 STWHIP C WEXIT CIRCULATE @ 10,995' & WOC. 20:30 - 21 :30 1.00 STWHIP C WEXIT LID 24 JTS DP. 21 :30 - 00:00 2.50 STWHIP C WEXIT WAIT ON CEMENT, CLEAN & FLUSH LINES, 2" DEMCO VALVES. 11/21/2001 00:00 - 00:30 0.50 STWHIP C WEXIT PRESSURE TEST CASING & P&A CEMENT PLUG TO 3000 PSI FI 20 MINUTES, ROCK SOLID. AOGCC REP LOU GRIMALDI WITNESSED PT & TAG UP OF CEMENT PLUG. 00:30 - 03:00 2.50 STWHIP C WEXIT RIH F/1 0,232' TO 11,883'. HARD TAG @ 11,883' & SET DOWN 15K. PICK UP WI NO OVERPULL. 03:00 - 04:00 1.00 STWHIP C WEXIT BREAK CIRCULATION, MIX & PUMP DRY JOB. 04:00 - 18:00 14.00 STWHIP C WEXIT POOH LAYING DOWN 5" & 31/2" DP. BREAK DOWN KELLY & INSPECT DRILLING LINE. 18:00 - 18:30 0.50 REST C POST PULL WEAR BUSHING. 18:30 - 23:30 5.00 REST C POST RIG UP EQUIPMENT TO RUN KILL STRING. LOAD TUBING IN PIPESHED, DRIFT & STRAP SAME. PJSM ON PICKING UP TUBING. 23:30 - 00:00 0.50 REST C POST MIU WIRELINEGUIDE & PICK UP & RIH WI KILL STRING. 11/22/2001 00:00 - 05:00 5.00 REST C POST CONTINUE TO RIH WI KILL STRING. RAN A TOTAL OF 79 FULL JTS OF 41/2" L-80 B-GRADE AIB MOD 12.6# BTC TUBING. X-NIPPLE @ 2425' & WIRELINE GUIDE @ 3310', NO OTHER JEWELRY. 05:00 - 07:00 2.00 REST C POST INSTALL 2 WAY CHECK IN TUBING HANGER, MIU TBG HANGER & LAND SAME. RILDS & LID LANDING JOINT. 07:00 - 11 :00 4.00 REST C POST NID BOPE. 11 :00 - 15:00 4.00 REST C POST NIU & TEST TREE, 5000 PSI, OK. CLEANING PITS. 15:00 - 18:00 3.00 REST C POST PUMP 160 BBLS DIESEL DOWN 9 5/8" ANNULUS & ALLOW TO U-TUBE, FREEZE PROTECTING TUBING & CASING TO 2000'. 18:00 - 19:00 1.00 REST C POST LID 5" KELLY. REMOVE SECONDARY ANNULUS VALVE, SECURE WELL. RIG RELEASED @ 1900 HRS, 11/22/2001. ( ( Printed: 11/27/2001 4:13:36 PM ,I " '\ { 1 O-Dec-O 1 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well A-25A dOJ- '4 't Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,092.38' MD Window / Kickoff Survey 12,109.00' MD Projected Survey: 13,092.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) R,. E""C,'E-m\/ED ~ ", """ ,,""" i D,r-r '.'l' 1 1)001 ..... \./ I ,- A~a$ka Oil 8: Gas Cons, Cùmm185ion .~I"¡(;oorage ", DEFINITIVE ~ North Slope Alaska Alaska Drilling & Wells PBU_WOA A Pad, Slot A-25 A-25A Job No. AKMM11181, Surveyed: 18 November, 2001 SURVEY REPORT 10 December, 2001 Your Ref: API 500292076401 Surface Coordinates: 5947780.00 N, 653697.00 E (7.0° 15' 51.3816" N, 148045' 26.3383" W) Kelly Bushing: 80.08ft above Mean Sea Level -............ RECEIVED DEC 2 8 2001 Alaska Oil & Gas Cons. Commission Anchorage spe...,..y-suf'1 D A Halliburton Company Survey Ref: svy11039 '""" . .' Sperry-Sun Drilling Services Survey Report for A-25A Your Ref: API 500292076401 Job No. AKMM11181, Surveyed: 18 November, 2001 DEFINITIVE. Alaska Drilling & Wells North Slope Alaska PBU - WOA A Pad Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12092.38 37.603 49.892 8505.28 8585.36 6231.75 N 4726.43 E 5954106.93 N 658295.23 E 6032.40 Tie On Point . MWD Magnetic 0",-"" 12109.00 37.290 49.840 8518.47 8598.55 6238.26 N 4734.15 E 5954113.60 N 658302.82 E 1.890 6041.42 Window Point 12142.47 39.350 55.890 8544.74 8624.82 6250.76 N 4750.70 E 5954126.43 N 658319.10 E 12.781 6060.39 12174.34 42.070 61.070 8568.90 8648.98 6261.59 N 4768.41 E 5954137.63 N 658336.60 E 13.604 6080.13 12208.18 45.060 66.020 8593.43 8673.51 6271.95 N 4789.29 E 5954148.41 N 658357.26 E 13.400 6102.82 12238.49 48.030 70.020 8614.28 8694.36 6280.16 N 4809.69 E 5954157.04 N 658377.49 E 13.700 6124.57 12269.54 51.330 73.760 8634.37 8714.45 6287.50 N 4832.19E 5954164.83 N 658399.83 E 14.043 6148.15 12301.84 54.500 77.330 8653.85 8733.93 6293.91 N 4857.13 E 5954171.75 N 658424.64 E 13.191 6173.90 12332.84 54.990 75.400 8671.74 8751.82 6299.88 N 4881.73 E 5954178.22 N 658449.11 E 5.324 6199.21 12365.00 54.610 74.020 8690.28 8770.36 6306.81 N 4907.08 E 5954185.67 N 658474.31 E 3.700 6225.4 7 12398.00 56.280 74.790 8709.00 8789.08 6314.11 N 4933.26 E 5954193.51 N 658500.33 E 5.413 6252.63 12427.20 57.400 76.460 8724.97 8805.05 6320.18 N 4956.94 E 5954200.05 N 658523.88 E 6.135 6277.07 12460.42 56.640 76.210 8743.05 8823.13 6326.76 N 4984.01 E 5954207.19 N 658550.82 E 2.373 6304.93 12493.21 58.310 75.620 8760.68 8840.76 6333.49 N 5010.83 E 5954214.46 N 658577.49 E 5.314 6332.58 12525.13 61.810 74.630 8776.61 8856.69 6340.60 N 5037.56 E 5954222.11 N 658604.07 E 11.289 6360.22 12557.47 63.660 76.600 8791.43 8871.51 6347.73 N 5065.40 E 5954229.81 N 658631.76 E 7.876 6388.96 12589.67 62.810 76.530 8805.93 8886.01' 6354.41 N 5093.36 E 5954237.06 N 658659.58 E 2.647 6417.71 12619.71 63.120 74.770 8819.58 8899.66 6361.04 N 5119.28 E 5954244.22 N 658685.36 E 5.320 6444.46 12651.38 62.790 75.040 8833.98 8914.06 6368.39 N 5146.52 E 5954252.12 N 658712.44 E 1.289 6472.65 "-' 12683.13 62.480 74.280 8848.58 8928.66 6375.85 N 5173.71 E 5954260.14 N 658739.47 E 2.339 6500.83 12715.39 62.680 74.380 8863.43 8943.51 6383.58 N 5201.28 E 5954268.43 N 658766.88 E 0.678 6529.44 12747.38 61.220 73.360 8878.48 8958.56 6391.43 N 5228.40 E 5954276.83 N 658793.84 E 5.362 6557.64 12779.74 60.940 74.300 8894.12 8974.20 6399.31 N 5255.60 E 5954285.27 N 658820.87 E 2.686 6585.93 12810.18 60.430 74.710 8909.03 8989.11 6406.40 N 5281.18 E 5954292.88 N 658846.30 E 2.046 6612.45 12839.52 59.390 78.830 8923.74 9003.82 6412.22 N 5305.88 E 5954299.19 N 658870.88 E 12.655 6637.83 12873.08 59.420 77.480 8940.82 9020.90 6418.15 N 5334.16 E 5954305.70 N 658899.02 E 3.464 6666.70 12904.91 59.090 79.400 8957.10 9037.18 6423.63 N 5360.95 E 5954311.73 N 658925.71 E 5.287 6694.05 12936.60 58.160 79.250 8973.60 9053.68 6428.64 N 5387.54 E 5954317.28 N 658952.19 E 2.962 6721.07 12967.50 58.220 79.100 8989.88 9069.96 6433.57 N 5413.33 E 5954322.74 N 658977.87 E 0.456 6747.31 12997.60 56.870 80.000 9006.04 9086.12 6438.18 N 5438.31 E 5954327.86 N 659002.75 E 5.146 6772.68 ---... ,..,.. _u .. ------- ._u.u_------------,-, 10 December, 2001-11:02 Page 2 of 4 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for A-25A Your Ref: API 600292076401 Job No. AKMM11181, Surveyed: 18 November, 2001 North Slope Alaska Measured Depth (ft) Azlm. Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Depth Northings Eastlngs Northings Eastlngs Rate (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9022.99 9103.07 6442.74 N 5463.77 E 5954332.93 N 659028.11 E 1.100 9057.89 9137.97 6452.22 N 5515.93 E 5954343.47 N 659080.07 E 0.000 Incl. 13028.53 13092.00 56.640 56.640 79.700 79.700 ~ All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.446° (18-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 76.710° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13092.00ft., The Bottom Hole Displacement is 8488.62ft., in the Direction of 40.527° (True). Comments -~ Measured Depth (ft) Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 12092.38 12109.00 13092.00 8585.36 8598.55 9137.97 6231.75 N 6238.26 N 6452.22 N 4726.43 E 4734.15 E 5515.93 E Tie On Point Window Point Projected Survey . ------ ------ 10 December, 2001 - 11 :02 Page 3 of 4 . Alaska Drilling & Wells PBU_WOA A Pad Vertical Section 6798.50 6851.44 Comment Projected Survey Drll/Quest 2.00.08.005 ~ North Slope Alaska Sperry-Sun Drilling Services Survey Report for A.25A Your Ref: API 500292076401 Job No. AKMM11181, Surveyed: 18 November, 2001 . Alaska Drilling & Wells PBU WOA A Pad Survey tool program for A-25A -~ From Measured Vertical Depth Depth (ft) (ft) 0.00 12092.38 0.00 8585.36 "'-" To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 12092.38 13092.00 8585.36 AK-1 BP _HG (A-25 Gyrodata) 9137.97 MWD Magnetic (A-25A) 10 December, 2001 - 11:02 -- ----,---.--,--- '-h,____---,---u DrillQuest 2.00.08.005 Page 4 of 4 !) ,- ( ( 'II( \, MEMORANDUM State of Alas ka Alaska Oil and Gas Conservation Commission TO: Cammy a.Taylor Cß~ Chair ~ THRU: Tom Maunder Mì-'rq~\ P.I. Supervisor ~O=>d \ DATE: November 20, 2001 SUBJECT: Plug & Abandonement A-25A BPX, A pad Prudhoe Bay Field Prudhoe Bay Unit PTO #201-148 FROM: Lou Grimaldi Petroleum Inspector NON- ~ Township: 11N Drilling Rig: Doyon 16 Range: 13E Rig Elevation: 28 Meridian: Umiat Total Depth: 13092 Section: 35 Lease No.: 35 Operator Rep.: Paul Haynes Casina Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet CasinalTublna Data: Conductor: 0.0. Shoe@ Surface: 133/8 0.0. Shoe@ 3152 Intermediate: 9 5/8 0.0. Shoe@ 11957 Production: 7 0.0. Shoe@ 12817 Liner: 0.0. Shoe@ Tubing: 0.0. Tail@ TVDe Plua Founded on Bottom PluaainaData: TOD of Cement Mud Weight Pressure (bottom UD) of Cement Deoth Verified? above plug Test Applied Annulus Bottom 13092 11883 D.P.Taa 15K 3000 "OK" TVDe Plua Open Hole Perforation Annulus Casing Stub Surface The plug was pressure tested to 3000 psi first with no leakage observed. The rig then tripped in the hole to 11883 and tagged the cement. 15K was set down on the plug twice which appeared firm, no sticking was observed when the Drillpipe was picked up. The top of cement was considerably deeper than anticipated, this could be attributed to a washout in the hole. The top of the milled window was at 12109 leaving approximately 226 feet of cement above the window. Founded on: Bottom Bridge plug Balanced Retainer Verified? Orillpipe tag Wireline tag C.T. Tag No cc: Attachments: Well diagram Distribution: orig - Well File c - Operator c - ONRIOOG c - Database c - Rpt File c - Inspector Rev.:5/28/00 by loR.G. P and A BPX A-25A 11-20-01 LG.xls 11/26/01 ;¡ rl/20/01 10: 36 FAX 907 564 5('" .. ---"- '-f - ~ ß ~ 13-318. CSG, 72#. L-80, It)::: 12.347. TOP OF r LNR 9-5/8. CSG, 47#. L-80, D = 8.681M 1" CIS P 17. RTNR 4.1/2- TaG, 12.6#,l-80, 0.0152 bpf. ID = 3.958 17" LNR, 26#, L-80 U4S, 0.0383 bpf, Ð::: 6,2761 BP EXPLORATION ~OO4 Ii I~ A.25A, Proposed. T I A 3152' 1148~ 11957' 12127' H 125251 ( 125421 127741 1281T 4.5", Kill String at 3000' MD with an "X" Nipple at 2500' !:!' 'We 1/ g~'3 í~¡¿tj To'p of Cement Plug = 12,009' MD Test plug to 3000 psi & Tag with DP Top of Window = 12,109' MD 8,580' TVD 6.125" Hole TD = 13,092' MD = 9,138' TVO v\J\'ú () ,-" ' \ \\~I~ \, . -::J It< \. ~ ~;y ~ " STATE OF ALASKA l ALASKL .JIL AND GAS CONSERVATION COM~..~SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: 0 Abandon III Suspend DI Plugging 0 Time Extension 0 Perforate 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other 0 Change Approved Program 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate At total depth 37951 NSL, 3898' EWL, SEC. 25, T11 N, R13E, UM (As Planned) 12. Present well condition summary Total depth: measured 13092 feet Plugs (measured) true vertical 9138 feet Effective depth: measured 12109 feet true vertical 8580 feet 14. Estimated date for commencing operation November 20, 2001 16. If proposal was verbally approvedlrô1YtIJ Tom Maunder W /" \ 11/19/2001 Name of approver Date Approved Contact Engineer Name/Number: Skip Coyner, 564-4395 17. I hereby certify that the foregoing I tru_e~~ rect to the best of my knowledge Signed Brian Robertson W Title Senior Drilling Engineer " """"",""", ,:', " :"',' ",,:,øø~mÎs~i~n;,;Û$~:p~IYq ",;',: Conditions of Approval: Notify commiSSio"O rep~ sentative may witness Plug integrity BOP Test - Location clearance - Mechanical Integrity Test ---A- 'g' ~segYl:}Qt form required 10- L-\D ~ uti mal \)Ignec tSY A roved b order of the Commission Camm De Form 1 0-403 Rev. 06/15/88 I GIN A L 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 26511 SNL, 17031 WEL, SEC. 35, T11N, R13E, UM At top of productive interval 3766' NSL, 3767' EWL, SEC. 25, T11 N, R13E, UM (As Planned) At effective depth Casing Structural Conductor Surface Intermediate Production Liner Length Size 110' 3105' 11911' 20" X 30" 13-3/8" 9-5/8" 1331' 7" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments IS! Description Summary of Proposal c-' ,~ 5. Type of well: IS! Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) Plan RTE = 79.98' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-25A 9. Permit Number 201-148 10. API Number 50- 029-20764-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Set CIBP at 12127' MD for sidetrack operation Junk (measured) Cemented MD TVD 8 cu yds Concrete 110' 1101 4365 cu ft Permafrost 3152' 2768' 1610 cu ft Class 'G', 130 cu ft PF 'C' 119581 8476' 420 cu ft Class 'G' 11486' - 12109' 8127' - 8580' RECEIVED NOV 2 0 2001 Alaska 011 & Gas Cons. Commission Anchorage 0 Detailed Operations Program 15. Status of well classifications as: 0 Oil 0 Gas IS! Suspended 0 BOP Sketch Service Prepared By Name/Number: Sondra Stewman, 564-4750 Date ':, ";':, , ,'q" ' Approval No. ;S:) l- 3~ 7 Commissioner Date I Submit I ( .. To: From: Date: Subject: (' ( bp GI6L,,~. Doyon 16, Company Men Skip Coyner, Sr. Drlg/WO Engineer 11/20/2001 A-25A, Abandonment - Suspension A-25A sidetrack will be plugged back and suspended as follows: . Sidetrack TD: 13092' MD, 9138' TVD . Hole size: 6.125" . Formation at TD: HOT . Whipstock/window: 12109' MD, 8580' TVD . Formation at window: Ivishak - T/Zone 4 1. File a Sundry Notice with the AOGCC. Notify the AOGCC field representative 24 hours before tagging and testing the final cement plug. 2. RIH with open-ended drill pipe to + 13,090'. Circulate bottoms up to cool the hole. 3. Cement Plug #1: 13090' - 12400' + 30% excess in open hole. RU Halliburton and test lines to 3000 psi. Pump 10 bbl of fresh water followed by: 160 sx (32.8 bbl) of class "0" cement + 0.35% Halad-344 + 0.5% ues + 0.09% HR-5 + 5.0 gps fresh water Displace with 3 bbl fresh water followed by mud. Under-displace + 2 bbl. 4. Pull 10 stands and reverse circulate 150% of the drill pipe volume. Watch for seepage and slow the pump rate if necessary. Watch for cement returns on bottoms up. After reversing out, POOH 5 more stands and wac until the surface samples start to set up. 5. After the initial set of the surface samples, RIH and tag plug #1 with the pump idling. Tag with 2-5,000# only. Pull a tool joint up to the drill floor and prepare for plug #2. . .,¡ ( (" 6. Cement Plug #2: 12400' - 11900' + 30% excess in open hole. RU Halliburton and test lines to 3000 psi. Pump 6.5 bbl of fresh water followed by: 106 sx (21.7 bbl) of class "G" cement + 0.35% Halad-344 + 0.5% DeS + 0.09% HR-5 + 5.0 gps fresh water Displace with 2 bbl fresh water followed by mud. Under-displace + 2 bbl. 7. Pull 7 stands and reverse circulate 150% of the drill pipe volume. Watch for cement returns. Watch for losses/seepage and reduce the pump rate if needed. 8. POOH 3 more stands, circulate and wac. After the initial set of the surface samples, pressure test Plug #2 to 3000 psi for 30 minutes. RIH and tag Plug #2 with 10,000# - no rotation, pump idling. Call the AOGCC to witness the tag and test. The minimum allowable TOC is 12009' MD. IfTOC is below 12009', another cement plug must be set. Once the cement plug is tagged and tested, LDDP. 9. Pick up + 3000' of 4-1/2" kill/freeze-protect tubing. Run a WLEG on bottom and an "X" nipple at + 2500'. Pick up the tubing hanger and landing joint. Land the tubing. RILDS. 10. Set a BPV. ND BOP's and NU the tree. Replace the BPV with a TWC and test the tree to 3000 psi for 30 minutes. Test the casing and tubing hanger to 3000 psi for 30 minutes. Replace the TWC with a BPV. Freeze protect with diesel to + 2500'. 11. RD Doyon 16. 12. Move to Y -24i. Re: A-25A, GPB, Sidetrack (' Subject: Re: A-25A, GPB, Sidetrack dO \ - \ ~,~ Date: Mon, 19 Nov 2001 13: 11:48 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Coyner, Vern M" <CoynerVM@BP.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> { Skip, Per our discussion, the regulation that applies is 20 MC 25.112 (b) (1) for segregating cased and uncased portions of the wellbore. Your plan to put cement a minimum of 100' above the whipstock will satisfy the regulations. Since you plan on suspending the well, I recommend you plan to make a bit trip and tag the cement plug, then pressure test. You indicated your casing has previously tested to 3000 psi, so with a competent cement plug there shouldn't be a problem. Please note that I will need a sundry notice regarding this plan and also have your rig supervisor get in touch with the North Slope Inspector to possibly witness the tag. You have approval to proceed. Tom Maunder, PE Sr. Petroleum Engineer AOGCC "Coyner, Vern M" wrote: > We have finished drilling the sidetrack and we are considering plugging the > sidetrack portion of the well and temporan1y abandoning the well. If so, > we plan to fill the 6. 125" sidetrack hole with cement and cover the > whipstock. FYI the whipstock is set at 12109' MO right at the top of zone > 4. TO is 13092' MD. > How much fill do we need above the whipstock to satisfy the AOGCC? > Do we need a clap above that? > > Skip Coyner > Orlg/WO Engr > (907) 564-4395 > (907) 440-0191 L..........................................................................,...............................................................................,............,..".......................,.........................................................................................,....,...................................,.............................................."............................,..........,......,......................................................,......................,................,.. ., ,. ," : Tom Maunder <tom_maunder@admin.state.ak.us> . Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 11/20/01 4:57 AM 113-3/8" CSG, 72#, L-80, 10 = 12.347" I TOPOF 7" LNR I 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 17" CIBP 17" RTNR \ A-25A, Current Con~Llon 3152' 11486' 11957' 12127' 1-1 12525' I Top of Window = 12,109' MD 8,580' TVD , , , , , , , , , , , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , ' , "- , ' , ' , ' , ' , ' , " , I , I " I , I " I , I " I 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958'1~ 12542' I I PBTD 17" LNR, 26#, L-80 U4S, 0.0383 bpf, 10 = 6.276'1 12774' 12817' 6.125" Hole TD = 13,092' MD = 9,138' TVD '-. 113-3/8" CSG. 72#. L-80, 10 = 12.347" I TOPOF 7" LNR I 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 17" clap 17" RTNR 14-1/2" TBG, 12.6#. L-80, 0.0152 bpf, 10 = 3.958'1-1 17" LNR, 26#, L-80 1J4S, 0.0383 bpf, 10 = 6.276'1 PBTDI A-25A, 3152" 11486" 11957" 12127" 1-1 12525" 12542" 12774" 12817" Proposed ,;:',::,;'::-!' ..:',':: ;"1 -"alA 4.5", Kill String at 3000' MD with an "X" Nipple at 2500' Top of Cement Plug = 12,009' MD Test plug to 3000 psi & Tag with DP Top of Window - 12,109' MD 8,580' TVD ':-.. "'1']1-'" ,'! 6.125" Hole TD = 13,092' MD = 9,138' TVD ( (: ~ 1r fA\ 1f Œ (ffi ~ fA\ ~ fA\ ~ [\ fA\ ALAS KA. 0 IL AND GAS CONSERVATION COltDlISSION TONY KNOWLES, GOVERNOR 333 W. ? AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit A-25A BP Exploration (Alaska) Inc. Permit No: 201-148 Sur Loc: 2651' SNL, 1703' WEL, SEC. 35,TIIN, R13E, UM Btmhole Loc. 3795' NSL, 3898' EWL, SEC. 25, T11N, R13E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit A-25A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ju£¿[1 Jt1, t-!e,¿,(/-xxr Julie M. Heusser Commissioner BY ORDER OF THE ÇOMMISSION DA TED this e~ t'~ day of August, 2001 jjc/Enclosures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMI~SION PERMIT TO DRILL 20 AAC 25.005 ~ç ~ C::., 1 a. Type of work 0 Drill II Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan ATE = 79.98' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028286 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2651' SNL, 1703' WEL, SEC. 35, T11 N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3766' NSL, 3767' EWL, SEC. 25, T11 N, R13E, UM A-25A Number 2S1 00302630-277 At total depth 9. Approximate spud date 3795' NSL, 3898' EWL, SEC. 25, T11 N, R13E, UM 08/20/01 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028310.1381' MD C-05A is 1021' away aI13053' 2560 13114' MD / 9023' TVD 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12100' MD Maximum Hole Angle 63 Maximum surface 2430 psig, At total depth (TVD) 8498' / 3280 psig 18. Casing Program Specifications Setting Depth Quantitv of Cement Size Too Bot 'Om Hole Casino Weicht Grade CouDlina Lenath MD TVD MD TVD (include staae data) 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1735' 11379' 8051' 131141 9105' 348 cu ft Class 'G' n r- ..r"'\ r- ~ \ II'"""""""" .'L\JI::I V CLI 19. To be completed for Redrill, Re-entry, and Deepen Operations. JUL 1 9 2001 Present well condition summary Total depth: measured 12817 feet Plugs (measured) true vertical 9190 feet Alaska Oil & Gas Cons. Commission Effective depth: measured 12774 feet Junk (measured) Anchorage true vertical 9152 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' Surface 3105' 13-3/8" 4365 cu ft Permafrost 3152' 2768' Intermediate 11911' 9-5/8" 1610 cu ft Class 'G', 130 cu ft PF 'C' 11958' 8476' Production Liner 1331' 7" 420 cu ft Class 'G' 114861 - 12817' 8127' - 9190' Perforation depth: measured Open: 12509' - 12522', 12546' - 12554', 12563' - 12600' Sqzd: 12460' - 12509' true vertical Open: 8922' - 8933', 8954' - 8961', 89681 - 9000; Sqzd: 8881' - 8922' 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Scott, Ko/stad, 564-5347 Prepared By Name/Number: Terrie Hubble, 564-4628 21, I hereby certify that the foregoing is:~nd correct to the best of my knowl~ge , Date , f I~J 0 , Signed Dan Stone c:::--:-7 -~. Title Senior Drilling Engineer '::,:,:,,:;:\':(;': ¡,'~ii: :;:!>":,!::'::!':"::;!,,:::":',:'::,::,:': ii', ';,;:::.": ::1'",,1 '::::\¡'¡ i:i:'::::"I';::!I!J,:: :<:: t!;¡\,::'}:':çØô1ml¡~.iQn:::¡~~.¡:ø~I"j~~:\i¡:"i!1¡¡::,:!;i:,:'!¡i:i¡l;i:);iii:¡i\:;!;::;i:!, i::' :'!:¡::,:: ;:::i!::¡' :i::1 :::':;';:,1', ;,,:',1 '.':'i'I::'!:':::.,:':!;';,!:: :i,i,'r:)',',:i:;,:::::',¡:::' ::,i ::', ,..,',', I,";'; ," ,', ",', I, Permit Nu.Jber API Number AP~Y$ij' Date See cover letter 20/ - )/f( 50- 029-20764-01 5?¡ 'n I for other reQuirements Conditions of Approval: Samples Required DYes ENo Mud Log Required DYes ~No Hydrogen Sulfide Measures J8I Yes DNo Directional Survey Required BYes 0 No Required Working Pressure for BOPE D2K D3K D4K D5K D10K D15K ~.5KPSi~ Other: by order of Date ?/RI OJ Approved By ORIGINAL SIGNED BY Commissioner the commission Form 10-401 Rev. 12-01-85 J. M. Heusser IJRIG Submit In Triplicate INAL ( (' I Well Name: IA-25A Drill and Complete Plan Summary l!ïPe of Well (service 1 producer 1 injectorU Producer Surface Location: X = 653,697 Y = 5,947,780 2,628' F8L 1,703' FEL T 11 N, R 13E, 8 35 Umiat KOP Location: Target X = 659,030 Y = 5,954,310 3,766' F8L 1,512'FEL T11N,R13E,825 Umiat Bottom Hole Location: X = 659,160 Y = 5,954,342 3,795' F8L 1,381' FEL T 11 N, R 13E, 825 Umiat ~ Nabors 7E8 l.Qperating~s to complete: 116.5 I AFE Number: 4P1629 I Estimated Start Date: 18/20/2001 I Top Edge Cellar/MSL: 50.48' I RT: I MD: 113,114' I I TVD: 19,105' 1 179098' I I Well Design (conventional, slimhole, etc.>.J Conventional Sidetrack ~ective: I Ivishak Zone 2 Mud Program: 6-1/8" Production hole: QuickDrii N Interval Density Viscosity VP PV Tauo pH (ppg) (seconds) (lb/1 OOfe) Milling 8.3 - 8.5 50 - 70 35 5-8 4-8 8.5 - 9.0 Production 8.3 -8.5 45 - 60 20 - 25 5-8 4-8 8.5 - 9.0 Di rectional: KOP: 1-12,100' MO Maximum Hole Angle: 63° Close Approach Wells: C-05A: 1,021' center to center distance at 13,053' in A-25A 0-21 : 1,468' center to center distance at 12,400' in A-25A A-25A Permit to Drill Page 1 ( Lo ram: ( Drilling: MWD / GR / DEN / NEU Open Hole: None Cased Hole: None Formation Markers: Formation To s MDbkb SGR SHB TSAO Zone 4 Zone 3 Zone 2C PGOC 25P 24P 22P 22P Base HOT TO 12,248' 12,389' 12,542' 12,631 ' 12,720' 12,775' 12,886' 12,964' 12,968' 13,114' TVDss 8,395' 8,425' 8,498' 8,612' 8,695' 8,765' 8,805' 8,845' 8,870' 8,920' 8,955' 8,957' -9,000' Comments 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW,3280 si, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint 7.43 EMW, 10' vertical uncertaint TO ma va based on HOT de tho Casin lTubin Pro ram: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tb O.D. MDITVD MDITVD bkb 6-1/8" 4 Y2" 12.6# L-80 18TM 1,735' 11,379' / 13,114' / 8,051' 9,105' Tubing 4 Y2" 12.6# 13 Cr- Vam 11 ,379' Surface 11 ,379' / 80 Ace 8,051' Cement Calculations: Casin Basis: Size 4 Y2" Liner Lead: None Lead TOG: NI A Tail: Based on a fully cemented liner with 50% excess, 82' shoe track, 614' of 4 Y2" x 7" annulus, 107' of 4 Y2" x 9 5/8" annulus, and 200' of cement in the 4" OP x 9 5/8" annulus. Tail TOG: 11,379' MO, 8,051' TVObkb Total Cement Volume: Lead N/A Tail 62 bbls I 348 ft I 293 sks of Halliburton Premium 'G' with latex at 15.6 and 1.19 dIsk. Testin Test De th 20' MD minimum from the top of the window A-25A Permit to Drill Test T e EMW FIT 9.0 ppg Page 2 ( (' Well Control: For production hole drilling, well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3,500 psi. BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Max. anticipated BHP (SAD): . Max. surface pressure (SAD): . Planned BOP test pressure: Planned completion fluid: 3,280 psi (7.43 ppg) @ 8,498' TVOss - Ivishak Sands 2,430 psi @ surface (Based on BHP and a full column of gas from TO @ 0.10 psi/ft) 3,500 psi sea water /2,200' of 6.8 ppg Diesel . Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S . A Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Highest level of H2S recently measured on A Pad: Closest surface location measured recently: Recent data from nearest BHL: 200 ppm from A-43, 6/6/00. 50 ppm from A-26, 2/2/00. 10 ppm from B-17, 5/15/00. DRilliNG CLOSE APPROACH: . C-05A and 0-21 pass BP risk based close approach guidelines. Disposal: . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. A-25A Permit to Drill Page 3 ~~ 'K' ~ ( ( DRILL AND COMPLETE PROCEDURE SUMMARY Pre-RiQ Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. Rig up slickline, drift and tag. 2. RU eline. There are two 19' blast joints above the lower packer. The 10 of the blast joints is 3.985". Set an EZSV cement retainer in the middle of the bottom blast joint at 12,523' (use the sliding sleeve type EZSV, not the poppet type spring loaded valve that will not hold pressure from above). Note: The EZSV must be set below the sliding sleeve and tubing punch to prevent cement from getting around the outside of the tubing above. 3. RU coil tubing to P&A the perlorations in the 24P middle zone 2 (12,546' - 12,554' and 12,563' - 12,600'). The estimated reservoir pressure in A-25 is -3,280 psi (at -8,498' TVDss this is equal to 7.43 ppg EMW). Perlorm a cement down squeeze through the squeeze packer using 15.8 ppg class 'G' cement. Use adequate cement volume to fill the 7" liner from PBTD at 12,774' MD to the tubing tail at 12,542', fill the 4 %" tubing to 12,523', plus squeeze 5 bbls into the perlorations. Estimated minimum cement volume required is -15 barrels (9 bbls 7" liner volume, 0.3 bbls tubing volume, and 5 bbls squeezed into the perlorations). After unstinging from the retainer, squeeze a viscous flo-pro pill through the tubing punch at 12,396' and into the perlorations from 12,509' - 12,522'. The lowest tubing cut will be made at 12,250'. 4. RU E-line. Make two tubing cuts in the 4 %" tubing at :t 12,250' in the middle of a joint (this cut can be a jet or chemical cut), and 11,410' just above the tubing seal assembly and 'X' nipple (this cut will be fished and a chemical cut is required) . 5. Test the 9-5/8" packoff and tubing hanger seals. 6. Bleed casing and annulus pressures to zero. 7. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover , form. Ria Operations: Q, ~ \\ \æ\." '\-cc-"Ç).~ ~ <Ù~. '\-C Ç\~ , 1. MIRU Nabors 7ES. 2. Circulate out freeze protection and displace well to sea water. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4 %" tubing from cut above the packer. 5. Fish and recover seal assembly. 6. RIH and attempt to retrieve the TIW HBBP-R packer. If unable to retrieve, mill the production packer. If milling is necessary, fish and recover packer and tubing tail pipe. 7. MU window milling BHA and drift down to the BP setting depth. Set BP on E-line (set as needed to avoid cutting casing collar). 8. Pressure test liner to 3,500 psi to evaluate possible casing leak. 9. RIH with 7" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Displace well to milling fluid. Mill window in 7" liner at :t 12,100' MD. 10. Perlorm FIT test. POOH. 11. Pick up 6 1/8" drilling BHA. 12. Drill 6 1/8" hole to HOT. 13. Run and cement a 4 %", 12.6#, L-80 solid production liner to TO. The 4 %" liner top will be brought above the old production packer location. Leave perl pill in liner, displace well to clean sea water above liner top. POOH. 14. Test the 4-1/2", 7", and 9 5/8" casing from the 4-1/2" landing collar to surlace to 3,500 psi for 30 minutes. 15. Run 4-1/2", 12.6#, 13Cr gas lift completion tying into the 4-1/2" liner top. 16. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. Shear RP valve. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to 2,200'. 19. Rig down and move off. Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 2. Install gas lift valves. 3. Perlorate. A-25A Permit to Drill Page 4 { ( Job 1: MIRU Hazards and Contingencies ~ Well A-24 and A-26 are located 109.5' and 111.0' from A-25 respectively. These wells should not require the well houses to be removed and therefore will not need to be shut In. Reference RPs .:. "Drilling/Work over Close Proximity Surface and Subsurface Wells Procedure" Operational Specifics . Job 2: Decomplete Well Hazards and Contingencies ~ The GaR of A-25 was increasing prior to shutting the well in. There is a potential for trapped gas under the production packer. Monitor flow closely while retrieving or milling the packer. ~ Based on a leak detect log run May 25th, 1998, there is a possible casing leak in the 9 5/8" casing. The leak is most likely a packer leak or a leak in the seal assembly above the upper packer. Reference RPs .:. Operational Specifics . .", """mm....""...,."""""..""""""""""""""",, ,......."....,.,..'""".~ .""'."""""mm"m""""""',"m"m",""".,.......~..:~"."", ",...",,~......."" .,"""""""".."." """'""'",""""".""",,, Job 3: Run Whipstock Hazards and Contingencies ~ Cement is expected behind the casing at the window depth. The 7" liner was fully cemented and cement was seen on a cleanout run. Reference RPs .:. Operational Specifics . Job 6: Drillina Production Hole Hazards and Contingencies ~ No mapped faults along the A-25A well path. ~ Differential sticking will be a problem if the drill string or casing is left stationary for an extended period of time across the Ivishak Sands. ~ The kick tolerance for the 6 1/8" production section would be infinite assuming an influx from the Ivishak formation at -13,066' MD. This is a worst case scenario based on a 8.3 ppg pore pressure gradient, a fracture gradient of 9.0 ppg at the window, and 8.5 ppg mud in the hole. A-25A Permit to Drill Page 5 ( ( þ;> There are two close approach wells for the A-25A well trajectory. See center to center distance in Directional section above. Reference RPs .:. Operational Specifics . Job 7: Install 4 Y2" Production Liner Hazards and Contingencies þ;> Differential sticking could be a problem in the Ivishak sands. Minimize the time the pipe is left stationary while running the liner. > Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight to set the packer. Check with Baker for the maximum down weight. If the stinger is pulled out of the liner top prior to setting the packer, POOH to remove the stinger prior to setting the packer. Reference RPs .:. Operational Specifics . Job 8: Run Completion Hazards and Contingencies > Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs .:. OperaüonalSpecifics . , """",,#,. Job 9: ND/NU/Release Ria Hazards and Contingencies > See hazards related to the MIRU in Job 1. Reference RPs .:. OperaüonalSpecifics . """'"' ,~....""'~"..-.,-"'"."",..,,,.,,.. ",...,...... ..""""",......, "",",¡"..,.~.".,.......¡""""""""""""",."""""""¡",-"",...,,""">on..--.....,..".."",.,."",, .",..,"""""'~..""...,,¡;_...,,.. A-25A Permit to Drill Page 6 ( ( TREE: S- CIW WEllHEAD: McevOY ACTUATOR: OllS KB. ElEV c 87.68' BF, ElEV = 51.98' SSSV lANDING NIPPLEf J. 019' I (CAMCO )(3.813" 10) @ 13-318", 72 111ft. L-80, BTRS. 13152'1 FOC GAS UFT MANDRELS (OllS WI RA LATCH) N" MO(BKB) lVDss 3670' 010' 7863' 836' 0,060' 153' 1.387' 969' KOP:500' MAX ANGLE: 58-/10,000' 4-1r¿a, 12.6I1ft. L-80, ABlBTRS TUBING TUBING 10: 3.956" . CAPACITY: ,01522 BBLJFT 4 1r¿a "X" NIPPLE (OllS) (3.613"10) , .111ÆÆJ )11 ,423' I, 111,429' I TUBING SEAL ASSY. - ì 9QO¡ 9.5/8" llW PACKER ( HBBP-R)(4.750"10) 4 1/2'", 12.6#1ft. L-80 TAILPIPE MARKER JOINT ' TOP OF I I 7" UNER 11,486' 112,065' I 112396' I Tubing Punch 2 1" shots 9-5/8", 47111ft, L-80. BTAS 111,957' I - TS& IL \\ ~ 10 \ , ~ 112:529' I 112,540' , 112.5421 I 112,542' I PERFORATION SUMMAR REF LOG: SWS - BHCS - 8-18- SIZE SPF INTERV AL 97£ 'Sfll: 12,460- 3318" 6 12.511' 3318" 6 12,546 - 5" 4 12,554' 5" 4 12,563 - 5" 4 12,600' 12,509 - 12,522' 12,546 - 12,554' 12.563 - SOZDI6-15-89 4 112" -XN" NIPPLE (OllS) (3.725"10) . 4112" TBG TAIL (OTIS )(WLEG ) (ELMO) " " OPENISTAOL OPEN/7-13-8 " > -: .' NOTE: 1-11/16"CENTRAUZEO E-UNE TOOLS STICKING IN WLEG. 1800 LBS PULL REQUIRED TO PULL FREE. '.' ~ $ :: ,~ l' . W ÄRNING: RADIO TRANSMITIER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE Am WELL WORK INVOLVING EXPLOSIVES CAN BEGIN! CONT. CTPADOP R OR. 11?774'\- , :lltm~t*41{ If? R17' I - , PBTD 7" ,261f1ft, L-80. 1J4S DATE REV. BY COMMENTS 8-23-82 INITIAL COMPLETION 7-16-89 FH RWO 11-22-90 A. TEEL PUT ON MAC . 512M3: Ml.~1,=SS REVISED 4/9/97 K. Bardwell Tubing Punch PRUDHOE BAY UNIT WELL: A-25 (32-2S-11..::1ID API NO: SO-029- 20764 EC 3S'TN 11N'RGE13 BP Explor"""';""""'" 'I'I!~_I......\ ""~."".. ,hlu'vl\q,l I,' TREE: 6"CIW WELLHEAD: McEvoy 133/8", 72 lIft, L-80 I 3,152' 4-1/2" 'X' Landing Nipple 9 5/8" x 7" Baker 'S-3' Packer 4-1/2" 'X' Landing Nipple 4-1/2" 'XN' Landing Nipple, 3.75" 10 7"Liner Top at I +/-11,486' I 9-5/8",47 #Ift, L80, BTC 111,957' I Window Milled from Whipstock Top of Window at +1- 12,100' MD Bridge Plug set at +1-12, 117'MD Otis XA Sliding Sleeve 112,487' I EZSV I TOC at +1-12,523' MD 7" TIW HBBP packer 112,529' I 7" 26#/ft L-80 IJ4S 112,817' I ( A-25A Proposed Completion GL Elevation = 50.48 Nabors 7ES RKB = 79.98' 4-1/2" 12.6# 13 Cr-80, Yam Ace Tubing 4-1/2" x 1-1/2" Cameo 'MMG' Gas Lift Mandrels with handling pups installed above and below. J , ,'-. GAS LIFT MANDRELS M) Size Valve Type 1 ' 1-1/2" RP Shear I 1-1/2" DV 2 I 1-1/2" DV 3 I 1-1/2" DV 4 5 (or 1 jt above 1-1/2" DV packer) +/-11,379' BAKER 95/8" X 7" XO to 4 1/2" ZXP Liner Top Packer and Hydraulic Liner Hanger PRUDHOE BAY UNIT WELL: A-25A API #: 50-029-20764-01 4-1/2" 12.6 lIft, L-80, IBT-M 113,114 I I ~ Date Revised by C 0 ;"")" ^ n + ~ I ,.;. ..."..... I 07/17/01 SRK Proposed completion '-'l North Slope Alaska Alaska Drilling & Wells PBU- WOA A Pad, Slot A-25A A -25A WPO2 Revised: 17 July, 2001 '-"0 PROPOSAL REPORT 17 July, 2001 Surface Coordinates: 5947780.00 N. 653697.00 E (70° 15' 51.3816" N. 148° 45' 26.3383" W) Surface Coordinates relative to Project H Reference: 947780.00 N. 153697.00 E (Grid) Surface Coordinates relative to Structure Reference: 1645.04 N, 221.86 E (True) Kelly Bushing: 81.98ft above Mean Sea Level ~~ , - ,- ~~ "I~ ,....... ',' ~-~ '."-,' ::r"'~ H! D alL;LtNG.5EA VI C:::155 " "',,~nCocnpany Proposal Ref: pro 10876 ~Y-!5L.lj1 North Slope Alaska lum..i..tNGA=:=:' Alaska Drilling & Wells ;S::::: 0 LO C\I II ~ (J c: ~ 9125 Q) Ct! (J (j) ~~..~ -_.^^^~^^^ I Proposal Data for A-25A I I ' Vertical Origin: Well ¡ Horizontal Origin: Well I Measurement UnitSt: i North Reference: True North I Dogleg severity: Degrees per 100 feet (US) Vertical Section Azi7tiØØ4° Vertical Section DeW.èPtion: Vertical Section Orr¡m N,O.OO E easured Inet. Azim. Vertical Northings Eastings Vertical Dogleg, Depth Depth Section Rate I I i 12100.00 37.383 49.497 8584.93 6213.60N 4774.25E 6303.30 I 12430.92 63.229 77.207 8796.85 6314.37 N 5001.03 E 6549.08 10.000 I 12964.04 63.229 77.207 9036.98 6419.77 N 5465.19 E 7024.31 0.000 I 13114.04 63.229 77.207 9104.54 6449.43 N 5595.79 E 7158.02 0.000 i PBU_WOA A Pad I DrillQuest' A-25A WPO2 A-25A Geo Poly 9036.98 TVD, 6419.77 N, 5465.19 E 6500 C/) C) c: ~ t 0 Z -, 6250. ST @ 10.oo0/1O0ft-50° RTF: 12100.00ft MD, 8584.93ft TVD 8375 4750 5000 Scale: 1 inch = 250ft 8625 Tu@ 10.000/1O0ft-50° RTF: 12100.00ft MD, 8584.93ft TVD ............... ...... ............... 00" .......00 ..n...n.. .n.. .n..nn. .--.. ..... .n. ----.. .......n. TZ4A 8693.98ft TVD End Dir, Start Sail @ 63.229°: 12430.92ftMD,8796.85ftTVD .........,..". "0000 '00_.'" ./:. ........... ,..' "00' noon .... ..n".... 0000.. 00'00"""'" 00'00"'" ........... no_. , TZ3 8776.98ft TVD 8875 .... 'n.', n,."" ..'\............. n ...n nn - 'n","""","'" nn. ...,. ,n,...... .n n:t¿ë'äii46. 98ft'fVti ~~~ ~ ~ ~~~ ~~~~~~ ~ ~~~ ~~ ~~\ ~~~ ~ ~~~~ ~ ~ ~~~ ~ ~~~~~ ~n~~~~~~' .~~~ ~~~~~~~~~~ ~ ~~~~ ~~~~~ ~ ~~~~~ ~~~~ ~ ~!!.f!.~~~~~~~~~~~~ty9~p 8926. 98ft TVD ..... ............. .......\. .......... ..... ......... ..... ......... ..... ..... .... ........... .............. ........24P 8951. 98ft TVD --....n.......n...........\..... n....,"----, ..----.un .,", ....... --'0000,,'--""". .....--.....................22P 900 1. 98ft TVD .............................. .............,... ...............HOIT 9038.98ft TVD A-2SA Geo Poly 22P base 9036.98ft TVD 9036.981"lD, 6419.77 N, 5465.19 E 4'".c?t 7' \ 41/2" liner ~~\ 13114.04ft MD 9104.54ft TVD 6375 Scale: 1 inch = 250ft 6875 7125 7375 Section Azimuth: 73.984° (True North) Vertical Section 6625 5250 Eastings 5500 5750 Reference is True North bp I I ~ Current Well Properties Well: , Horizontal Coordinates: I Ref. Global Coordinates: I Ref. Structure Reference: i Ref. Geographical Coordinates: I RKB Elevation: I II' North Reference: Units : i A-25A 5947780.00 N. 653697.00 E I 1645,04 N. 221.86 E I 70" 15' 51,3816" N. 148> 45' 26,3383" W I I ! I I I I I --- J 81.98ft above Mean Sea Level 81.98ft above Structure Reference True North Feet (US) ~,,--,--- ,--- ,---, ( , Sperry-Sun Drilling Se~vices Proposal Data - A-25A - A-25A 161.!u ly,20lJ1~1 0: 13 ;.1::. Dill/Quest Sperry-Sun Drilling Services . Proposal Report for A-25A WP02 Revised: 17 July, 2001 Alaska Drilling & Wells North Slope Alaska PBU- WOA A Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth lnel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/1 OOft) 12100.00 37.383 49.497 8502.95 8584.93 6213.60 N 4774.25 E 5954089.77 N 658343.41 E 6303.30 ST @ 10.00°/1000 - 50° R TF : 12100.000 MD, 8584.93ft TVD 12200.00 44.434 60.368 8578.57 8660.55 6250.72 N 4827.89 E 5954127.97 N 658396.29 E 10.000 6365.11 12248.37 48.154 64.649 8612.00 8693.98 6266.81 N 4858.91 E 5954144.70 N 658426.97 E 10.000 6399.36 TZ4A --. 12300.00 52.279 68.692 8645.04 8727.02 6282.48 N 4895.34 E 5954161.10 N 658463.07 E 10.000 6438.69 12389.32 59.691 74.717 8695.00 8776.98 6305.52 N 4965.58 E 5954185.58 N 658532.83 E 10.000 6512.57 TZ3 12400.00 60.595 75.372 8700.32 8782.30 6307.91 N 4974.53 E 5954188.15 N 658541.73 E 10.000 6521.83 12430.92 63.229 77.207 8714.87 8796.85 6314.37 N 5001.03 E 5954195.15 N 658568.08 E 10.000 6549.08 End Dir, Start Sail @ 63.229° : 12430.92ftM 0 ,8796.85ftTVD 12500.00 63.229 77.207 8745.99 8827.97 6328.03 N 5061.17 E 5954210.03 N 658627.94 E 0.000 6610.66 12542.21 63.229 77.207 8765.00 8846.98 6336.38 N 5097.92 E 5954219.12 N 658664.51 E 0.000 6648.29 Z2C 12600.00 63.229 77.207 8791.03 8873.01 6347.80 N 5148.24 E 5954231.57 N 658714.58 E 0.000 6699.80 12631.01 63.229 77.207 8805.00 8886.98 6353.93 N 5175.24 E 5954238.25 N 658741.45 E 0.000 6727.45 PGOC 12700.00 63.229 77.207 8836.07 8918.05 6367.57 N 5235.31 E 5954253.12 N 658801.23 E 0.000 6788.94 12719.82 63.229 77.207 8845.00 8926.98 6371 .49 N 5252.56 E 5954257.39 N 658818.40 E 0.000 6806.61 25P 12775.32 63.229 77.207 8870.00 8951.98 6382.46 N 5300.88 E 5954269.34 N 658866.49 E 0.000 6856.09 24P 12800.00 63.229 77.207 8881.11 8963.09 6387.34 N 5322.37 E 5954274.66 N 658887.87 E 0.000 6878.09 12886.33 63.229 77.207 8920.00 9001.98 6404.41 N 5397.53 E 5954293.26 N 658962.67 E 0.000 6955.04 22P 12900.00 63.229 77.207 8926.16 9008.14 6407.11 N 5409.44 E 5954296.20 N 658974.51 E 0.000 6967.23 12964.04 63.229 77.207 8955.00 9036.98 6419.77 N 5465.19 E 5954310.00 N 659030.00 E 0.000 7024.31 22P base Target - A-25A Goo Poly, Current Tar~ 12968.48 63.229 77.207 8957.00 9038.98 6420.65 N 5469.06 E 5954310.96 N 659033.85 E 0.000 7028.27 HOlT .-~, 13000.00 63.229 77.207 8971.20 9053.18 6426.88 N 5496.50 E 5954317.75 N 659061.16 E 0.000 7056.37 13100.00 63.229 77.207 9016.24 9098.22 6446.65 N 5583.57 E 5954339.29 N 659147.80 E 0.000 7145.51 13114.04 63.229 77.207 9022.56 9104.54 6449.43 N 5595.79 E 5954342.31 N 659159.96 E 0.000 7158.02 Total Depth: 13114.04ftMD,91 04.54ftTVD 4 112Q Liner 17 July, 2001 - 11:39 Page 2 of 4 Dri//Quesf 2.00.09.003 ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSNUTTALLETTER CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPME/NT.. REDRILL / EXPLORATION INJECTION WELL INJECTION WELL REDRILL WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL~AL ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL f\-dS A "CLUE" The permit is for a new wellbore segment of existing well . Permit No, , API No. . ' Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The. permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. ' ( ( DATE 07/06/01 CHECK NO. 00193318 H 19331~ DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 0/0201 CKO7020iE PYMT OMMENTS: HANDL NG INST: lüü.üü 100.00 Per it to Drill ee 8tH - Terrie Hub Ie X4628 or Sandra ate man X4750 \1- ';).. c¡)i 'HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ' ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK 017 ASHLAND AN AFFILIAte OF NATIONAL CITY BANK CLEVELAND. .oHIO No~H 1 9.3318 CONSOLIDATED COMMERCIAL ACCOUNT ,', ", '"',',, ..' ,.. Oi\iEHl!NDR ED & 00/ 1 Od~**,~*************.**4f*:J**t*********** U~ D~LLAR ,.. ..' 56~389 412 PAY , ',,'" " ',,', '" DATÈ,i ":AMOUNT <:i~/db/Ol+:\.,.j!I" '. .'.'. ~1()~{~ NQTVALIOAFTER:'120, DAYS ", TD The ORDER Of .' .. , ,',,', . , . , ,ALAEi~A O:rL~~f!G~S .., CONSERVATIONC:OMMISSTON 333>WESiF 7'tHÄVEN~E "', ",,;;....'. SUITE 100 ANCHORAGE AK 99501 , ,.. , , " " '" rr............,...'..'......','.W.;....';...'.1!.~.'. '..~.'~.-.-.{' '~~"~."" .. ,." -,', III ~ Ii ~ ~ ~ a III I: 0'" ~ 2 0 ~ a Ii 5 I: 0 0 a ...... ~ Ii III WELL PERMIT CHECKLIST COMPANY ... Ç1PROGRAM: exp - dev - redrll FIELD & POOL rÇ ë/ð/{ c r'"1 INIT CLASS GE L AREA ~/ ¿) ADMINISTRATION 1. Pennitfee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. .. . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available- in drilling unit.. . . . . . . . . . . Y No 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Pennit can be issued without conservation order. . . . . . . . Y N 12. Pennit can-be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ~i: ~~::;E~:t~:;~:t=o~~~~~~ ¿ ~~rt ~go: 0: -: 0: : ~ ~"( ~\~ \c ~~\7~"', ~\\. 17. CMT vol adequate totia-in long string to surf csg. . . . . . . . N j ù 18. CMT will cover all known productive horizons. . . . . '. . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N ~ ... ~ ~!: ~;E~I~!!1 ~~£!~~~:r~:~~~.t ~e~ ~~p~o. ~~.d:. : :. ~ J t~~~~ ~ ~ 23. If diverter required, does it meet regulations. . . . . . . . . . ~ 24. Drilling .fluid program schematic & equip list adequate. . . . . N . 25. BOPEs, do they meet regulation. . . . . . "1:. rt',.^. . . . N '-1'" ("t""\ ,~ ... \ - <:\ ('b., ~. \. ~~ ". ~l ~~ . 26. BOPE press rating appropriate; test to .;;::::A.J\,J psig. N ~~C; v ~~~ """'- c:7- ~ ~ ~~\ F:;CJ.ili-\ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . ~- . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . .. Y N 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . '1/ N AP R ....9AT9I. 33. Seabed condition survey (if off-shore). . . . . . . . . . . . ./Y N ~ ~ 34. Contact name/phone for weekly progress reports {exploratory 0y.,yj Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. - (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; .. .. (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOL Y: ENGINEERING:. UIC/Annular COMMISSION: ~þ WM ~ . 8~s--r1Tfnr- JM~ serv well bore seg _ann. disposal para req - 0 1/.6 ~ ð ON/OFF SHORE /1AJ UNIT# c 0 Z 0 -I :E :::u ( ~~~ ENGINEERING - -I m - '~ \~ (:~\ Z -I ::J: - GEOLOGY APPR DATE Y N Y N en :Þ :xl m » ( Com mentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process. but is part of the history file. . To improve the readability of the Well History file and to simpltfy finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically. . organize this category of information. SCANNEr, NO\} ;i ') ~ 0/-/'1'( 1/ '33~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 04 15:16:22 2002 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. .... ........ ..UNKNOWN Continuation Number.. ....01 Previous Reel Name... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Tape Header Service name........ .... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name..... ....... ....UNKNOWN Continuation Number.. ....01 Previous Tape Name... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA A-25A 500292076401 BP Exploration Sperry Sun 04-DEC-02 (Alaska) JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-11181 T. MCGUIRE T. ABBOTT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 llN 13E 2628 1703 MSL 0) 80.08 78.58 51. 98 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 12109.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) UNLESS OTHERWISE NOTED. 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET THE WHIPSTOCK, SCANNED NO\! fì... 0 200J1 \.J 0 .9. ) ) WITH THE TOP OF THE WHIPSTOCK SET AT 12109' MD / 8598' TVD. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTRO- MAGNETIC WAVE RESISTIVITY (EWRP4), STABILIZED LITHO- DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). NO PROGRESS WAS MADE ON THIS RUN, SO NO MWD DATA WAS PRESENTED 5. MWD RUN 300 WAS DIRECTIONAL WITH DGR, EWRP4, SLD, AND CTN. ALL MWD DATA FOR THE WELL WAS COLLECTED AND PRESENTED ON MWD RUN 3. 6. MWD DATA IS DEPTH-SHIFTED TO TIE-IN TO THE PARENT WELL GAMMA RAY (SCHLUMBERGER LOG, 8/18/1982) PER THE 11/29/2001 E-MAIL FROM D. SCHNORR (BP EXPLORATION). ALL HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 7. MWD RUN 3 REPRESENTS WELL A-25A WITH API # 50-029-20764-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13092'MD / 9137'TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME (RESISTIVITY) RESISTIVITY (EXTRA RESISTIVITY RESISTIVITY RESISTIVITY (DEEP TNPS = SMOOTHED SNP2 = SMOOTHED METHOD) SBD2 = SMOOTHED SC02 = SMOOTHED METHOD) COMPENSATED THERMAL NEUTRON POROSITY NEAR PHOTOELECTRIC (RAPID SAMPLE BULK DENSITY (RAPID SAMPLE METHOD) STAND OFF CORRECTION (RADID SAMPLE COMPENSATED NEUTRON POROSITY PROCESSING PARAMETERS: MATRIX: FIXED HOLE SIZE: MUD WEIGHT: MUD SALINITY: WATER SALINITY: SANDSTONE 6.125" F/ TNPS 8.7 ppg F/ TNPS 1,100 ppm 20,000 ppm $ File Header Service name.. ........ ...STSLIB.001 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation.......02/12/04 Maximum Physical Record..65535 File Type................ LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # 1 clipped curves; all bit runs merged. .5000 FILE SUMMARY PBU TOOL CODE PEF DRHO RHOB GR FET RPD RPM RPS RPX NCNT NPHI FCNT ROP $ START DEPTH 12070.0 12070.0 12070.0 12074.0 12082.0 12082.0 12082.0 12082.0 12082.0 12099.0 12099.0 12099.0 12122.0 ) STOP DEPTH 13013.5 13013.5 13013.5 13035.0 13042.0 13042.0 13042.0 13042.0 13042.0 12998.0 12998.0 12998.0 13080.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 12099.0 13080.0 $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE # REMARKS: GR 12109.5 13090.5 BIT RUN NO MERGE TOP 3 12080.0 MERGED MAIN PASS. $ MERGE BASE 13090.5 # Data Format Specification Record Data Record Type......... ....... ..0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point.... ........ ..Undefined Frame Spacing... ........ ........ ..60 .1IN Max frames per record............ .Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 RHOB MWD G/CC 4 1 68 32 9 DRHO MWD G/CC 4 1 68 36 10 PEF MWD B/E 4 1 68 40 11 NPHI MWD PU 4 1 68 44 12 NCNT MWD CP30 4 1 68 48 13 FCNT MWD CP30 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12070 13080 12575 2021 12070 13080 ROP MWD FT/H 0.47 501. 42 45.3253 1917 12122 13080 GR MWD API 11.73 284.51 33.1227 1923 12074 13035 RPX MWD OHMM 2.04 1100.89 20.8462 1921 12082 13042 RPS MWD OHMM 1. 93 1693.75 26.6269 1921 12082 13042 RPM MWD OHMM 0.28 2000 55.9918 1921 12082 13042 RPD MWD OHMM 0.74 2000 56.5252 1921 12082 13042 FET MWD HR 0.7335 5.4192 2.01356 1921 12082 13042 RHOB MWD G/CC 0.473 2.847 2.30522 1850 12070 13013.5 DRHO MWD G/CC -1.733 0.172 0.0205211 1850 12070 13013.5 PEF MWD B/E 1. 07 14.98 2.59797 1888 12070 13013.5 NPHI MWD NCNT MWD FCNT MWD PU CP30 CP30 7.43 713.15 12 33.26 1476.77 72 .15 First Reading For Entire File..........12070 Last Reading For Entire File.. ...... ...13080 File Trailer Service name.. ......... ..STSLIB.001 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation..... ..02/12/04 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number.... ... ... .1.0.0 Date of Generation...... .02/12/04 Maximum Physical Record. .65535 File Type................ LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF DRHO RHOB GR FET RPD RPM RPS RPX NCNT NPHI FCNT ROP $ 2 21. 8874 1799 1008.24 1799 24.7105 1799 ) 12099 12099 12099 12998 12998 12998 header data for each bit run in separate files. 3 .5000 START DEPTH 12080.0 12080.5 12080.5 12084.5 12092.5 12092.5 12092.5 12092.5 12092.5 12109.5 12109.5 12109.5 12132.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 STOP DEPTH 13024.0 13024.0 13024.0 13045.5 13052.5 13052.5 13052.5 13052.5 13052.5 13008.5 13008.5 13008.5 13090.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 18-NOV-01 Insite 6.02 Memory 13092.0 12132.0 37.6 63.1 TOOL NUMBER 135134 112439 113413 130910 ) ) $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 12109.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S)~ MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Based Water 8.60 48.0 8.2 1100 .1 1. 200 .700 1. 800 1. 400 75.0 132.8 75.0 75.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction..... ..... ...... . Down Optical log depth units.... ...... .Feet Data Reference Point. ..... ....... . Undefined Frame Spacing. ...... ............ ..60 .1IN Max frames per record...... .... ...Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 RHOB MWD030 G/CC 4 1 68 32 9 DRHO MWD030 G/CC 4 1 68 36 10 PEF MWD030 B/E 4 1 68 40 11 NPHI MWD030 PU 4 1 68 44 12 NCNT MWD030 CP30 4 1 68 48 13 FCNT MWD030 CP30 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12080 13090.5 12585.3 2022 12080 13090.5 ROP MWD030 FT/H 0.47 501. 42 45.3253 1917 12132.5 13090.5 GR MWD030 API 11.73 284.51 33.1227 1923 12084.5 13045.5 RPX MWD030 OHMM 2.04 1100.89 20.8462 1921 12092.5 13052.5 RPS MWD030 OHMM 1. 93 1693.75 26.6269 1921 12092.5 13052.5 RPM MWD030 OHMM 0.28 2000 55.9918 1921 12092.5 13052.5 RPD MWD030 OHMM 0.74 2000 56.5252 1921 12092.5 13052.5 FET MWD030 HR 0.7335 5.4192 2.01356 1921 12092.5 13052.5 RHOB MWD030 G/CC 0.473 2.847 2.30522 1850 12080.5 13024 DRHO MWD030 G/CC -1.733 0.172 0.0205211 1850 12080.5 13024 PEF MWD030 B/E 1. 07 14.98 2.60289 1889 12080 13024 NPHI MWD030 PU 7.43 33.26 21. 8874 1799 12109.5 13008.5 NCNT MWD030 CP30 713 .15 1476.77 1008.24 1799 12109.5 13008.5 FCNT MWD030 CP30 12 72 .15 24.7105 1799 12109.5 13008.5 First Reading For Entire File. ..., "" .12080 Last Reading For Entire File... ...,.. ..13090.5 File Trailer Service name. """"'" .STSLIB.002 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation.... ...02/12/04 Maximum Physical Record..65535 File Type. "'" """ '" .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name.. ""'" '" .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. ... .......... ..UNKNOWN Continuation Number.. ....01 Next Tape Name...... ... ..UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. """"" ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name...... ....,. '" . UNKNOWN Continuation Number. "" .01 Next Reel Name....... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
