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202-231
f RE III STATE OF ALASKA • MAY C 2 3 EIV 2012 E D ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® 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. 5/3/2012 202 - 231 312 - 105 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 12/14/2002 50 029 - 20135 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/18/2002 PBU F -08A 2308' FSL, 2396' FEL, Sec. 02, T11 N, R13E, UM 8. KB (ft above MSL): 54.80' 15. Field / Pool(s): Top of Productive Horizon: 1203' FNL, 1152' FEL, Sec. 10, T11 N, R13E, UM GL (ft above MSL): 34.92' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil P001 620' FNL, 36' FEL, Sec. 10, T11 N, R13E, UM 11085' 8881' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x 651960 y 5973828 Zone ASP4 12750' 9043' ADL 028280 & 028281 TPI: x 648488 y 5970246 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 649591 y 5970851 Zone ASP4 None 18. Directional Survey 0 Yes 181 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 MIXTVD: MWD, GR, ROP, RES, MCNL 11066' 8865' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 30" 157.53# Conductor Surface 80' Surface 80' 36" 135 sx Arctic Set 13 -3/8" 72# N -80 Surface 2700' _Surface 2700' 18 -1/2" 3697 sx Permafrost II 9 -5/8" 40# / 47# , L - 80 / N - 80 Surface 10087' Surface 8174' 12 -1/4" 1650 sx Howco Liaht. 200 sx Class 'G' 7" 29# N -80 9559' 11066' 7866' 8865' 8 -1/2" 752 sx Class 'G' 3 - 3/16" x 2 - 7/8" 6.2# / 6.16# L -80 10429' 12740' 8404' 9043' 3 -3/4" 125 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4-1/2", 12.6#, 13C R80 / L -80 9546 / 10435' - 10447' 9488', 10435' / 7826', 8408' MD TVD MD TVD 7 ", 26#, N -80 9520' - 9596' y 26. ACID, FRACTURE U CEMENT SQUEEZE, ETC. f JUN S f ' ,f` t��L, DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 11085' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 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. None R MAY 25 ZOO �` VtF101)9114 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 60,1 ��/' ubmit Original Onl 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. • FORMATION TESTS • NAME MD TVD Well Tested? ❑ Yes IS No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 25N 11098' 8892' None 25P 11110' 8902' 23P 11160' 8945' 22P 11193' 8970' 21P 11226' 8992' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the • - ' +ing is t ue a r ct to the best of my knowledge. Signed: Joe Lastufka J ' Title: Drilling Technologist Date: 5/9--// PBU F O8A 202 -231 312 -105 Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Ron Phillips, 564 -5913 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • F -08A, Well History (Pre Rig Sidetrack) Date Summary 04/14/12 T /I /O = 2150/1400/200. Conduct PJSM. Cycled SSV and SV. Performed LTT on Swab valve (passed). Rigged up lubricator and tested against Swab valve to 200 -300 psi. low for 5 min. (passed), and 3500 psi. high for 5 min. (passed). Set 4" CIW H -TWC # 279 at 115" using one 1' extension. Rigged down lubricator and attached pulling tool. Rigged up lubricator and tested against swab valve to 200 -300 psi. low for 5 min. (passed) and 3500 psi. high for 5 min. (passed). Torqued all flanges to API specs (see log). Shell tested tree to 200 -300 psi. low for 5 min. (passed) and 5000 psi. high for 5 min. (passed). Pulled 4" CIW H -TWC # 279. Bled off pressure to 0 psi. and rigged down lubricator. Attached tree cap and pressure tested to 500 psi. (passed). Numbered and marked flange studs. All charted tests in field charted test folder. 04/16/12 TAG 3- 3/16" X 2 -7/8" XO @ 11,122' SLM /11,101' MD w/ 2.75" CENT & S. BAILER - NO SAMPLE DRIFTED W/ 2.70" CENT, 5' X 2.625 ", 3 -1/2" GR & 10' X 2.70" DMY WS - UNABLE TO PASS 11.087' SLM. DRIFTED W/ 10' X 2.70" DUMMY WHIPSTOCK - UNABLE TO PASS 11,082' SLM. 04/18/12 T /I /O= 1990/140/250. Temp= S /I. MIT IA (PASSED) to 3000 psi (CTD Prep) Pumped 8 bbls 60*F crude down IA to reach test pressure. 1st 15min lost 116 psi. 2nd 15 min lost 46 psi for a total loss of 162 psi in 30 min. 04/19/12 Mit -OA (FAILED) to 2000 psi. CTD. Pressured up OA with .21 bbls 60* crude. Lost 460 psi in first 7 min. Repressured OA several times. Lost pressure rapidly. Bled IAP, bled back -7 bbls. Tags hung. Valve positions upon departure: SV WV SSV= closed. MV IA OA= open FWHP's 2350/90/100 04/21/12 T /I /O =SSV /200/200, Temp =SI. PPPOT -T (PASS), pre CTD. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (standard), unable to reach 3 due to grading braces, all the rest moved freely (2.5 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 04/23/12 RAN 2.75" CENT., 2.5" LIB, S/D 10,422' SLM (impressioin of tbg. stub). DRIFTED W/ 2.75" CENT TO X- OVER @ 11,095' SLM (11,101' MD). DRIFTED W/ 17' (2.70 max od) BAKER DUMMY WHIPSTOCK TO 11,062' SLM (stopped due to dog leg). DRIFTED W/ 18.5' (2.625" max od) DUMMY WHIPSTOCK TO 11,067' SLM (stopped due to dog leg). DRIFTED W/ 12.5' (2.625" max od) DUMMY WHIPSTOCK TO 11,064' SLM (stopped due to dog leg). 04/24/12 DRIFTED W/ 10' x 3.70" DUMMY WHIPSTOCK TO 9,600' SLM (no problems) 04/29/12 T /1 /O= 2300/240/200 ( Load and Kill) Rig to tree cap. Pump 10 bbls neat meth followed by 294 hhls 2% KCL then 38 bbls diesel down TBG for load and kill. RDMO.FWHP=0/40/200 Swab = closed / ssv =open / master =open / IA and OA open to gauges. Operator notified. 04/29/12 T /1 /O= Vac /80/0 Conducted PJSM; P.T. (charted) SN (barrier) to 300 psi /3500 psi (passed); Removed tree cap, SN & SSV used as barriers; Installed lubricator & P.T. (charted) to 300 psi /3500 psi (passed); Set 4" CIW TWC #260 @ 114" w/1 -1' ext used.; P.T. (charted) TWC to 300 psi /3500 psi (passed), Charted tests downloaded into U- drive; Pre Nordic 2. 04/29/12 T /l /O = vac /vac /200. Temp = SI. Bleed IAP and OAP to 0 psi. (Pre Nordic #2). IAP on vac. Bled OAP to bleed trailer from 200 psi to 0 psi in 30 min. Start 15 min stabilization IAP increased 1 psi, OAP increased 10 psi. 2nd, 15 min test IAP increased 1 psi, OAP increased 5 psi. Final WHPs T /I /O = vac /2/15. Job complete. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 1230 Page 1 of 1 • • With Arneric a • ALASKA - BP ` erasion Summary Report Common Well Name: F -08 1 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 4/30/2012 1 End Date: IX3 -011 MW -C: (2,062,333.00 ) i Project: Prudhoe Bay Site: PB F Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 3/24/1974 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °20'11.829 "9 Long: 0148 °46'01.316'W Active Datum: ORIG KELLY BUSHING @54.80ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth Phase ' Description of Operations (hr) (ft) 4/30/2012 j 06:00 - 09:00 3.00 MOB P 1 PRE I BEGIN RON EVENT FOR NORDIC 2 AT 06:00 ON 4/30/2012. STAGE RIG ON DS15 -09 WHILE MAKING FINAL PREPARATIONS FOR RIG MOVE. 09:00 - 17:00 8.00 MOB P PRE MOVE RIG 12 MILES FROM DS 15 TO F PAD. 17:00 - 19:00 2.00 MOB P PRE STAGE RIG ON F PAD. CREWS COMPLETE I CHANGEOUT. FINALIZE RIG MAT PLACEMENT AROUND F -08 WELL. I 19 - I IPDATF AOGCC REPRESENTATIVE BOB NOBLE WITH INTENTION TO TEST BOPE AT 01:00 5/1/2012. MR. NOBLE WAIVES STATE'S RIGHT TO WITNESS BOP TEST I UNLESS TESTING BEGINS AFTER 6 AM ON � 5/1/2012. 1 19:0 - 20:00 1.00 MOB P PRE 1 DHD ON LOCATION TO BLEED DOWN OA. I 1 PRESSURE BLEEDS FROM 200 PSI TO 0 PSI IN SECONDS. MONITOR BUILD UP. PRESSURE GAINS 12 PSI IN FINAL 15 MIN OF ! I 1 30 MIN PERIOD. 20:00 - 21:00 1.00 I MOB ( P 1 T PRE ; HOLD PJSM AND SPOT RIG OVER F -08 WELL. - ALL TREE AND WELLHEAD VALVES I CONFIRMED CLOSED. - WELLWORK TRANSFER PERMIT OPEN WITH PAD OPERATOR. - TBG = TWC, IA = 31 PSI, OA = 32 PSI ' - F PAD OPERATOR DECLINES WITNESS FOR PULLING RIG OVER WELL. 21:00 - 22:00 1.00 RIGU P PRE ACCEPT RIG AT 21:00 ON 4/30/2012. SHORE UP CELLAR AREA. SPOT CUTTINGS BOX_ 22:00 - 23:00 1.00 RIGU 1 P PRE GENERAL RIG UP OPERATIONS. TAKE ' CONTROL OF SSV WITH PANEL IN SLB OPS ( CAB. FUNCTION TEST (VALVE CLOSES WITH PROPER 4.5" STEM EXPOSED). OPEN AND j I CLOSE SWAB VALVE TO CONFIRM 23 ' CORRECT TURNS TO FUNCTION. ' 23:00 - 00:00 1.00 BOPSUR P PRE PRESSURE TEST SWAB CAP AGAINST CLOSED SWAB VALVE AND SSV TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS, SEE ATTACHED CHART). DOUBLE BARRIERS ESTABLISHED FOR I I BREAKING CONTAINMENT TO NIPPLE UP I BOPS. I I I ■ REMOVE TREE CAP AT SWAB CAP FLANGE. Printed 5/14/2012 1:13:38PM North Aoloica - AKA - BP Page 2 Operation Summary Report Common Well Name: F -08 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 4/30/2012 End Date: X3 -011 MW -C: (2,062,333.00 ) Project: Prudhoe Bay Site: PB F Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 3/24/1974 12:OO:OOAM Rig Release: Rig Contractor: NORDIC CALISTA 1 UWI: / Lat: 070 °20'11.829 "9 Long: 10148°46'01.316'W Active Datum: ORIG KELLY BUSHING @54.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/1/2012 00:00 - 01:30 1.50 BOPSUR P PRE SET BOP STACK ON CAMERON 4 -1/8" TREE. NIPPLE UP BOPS TO SWAB FLANGE WITH FOLLOWING STACK CONFIGURATION: - 7- 1/16" HYDRIL GK ANNULAR PREVENTER - TOT BLIND -SHEAR RAMS - TOT 2 -3/8" COMBI PIPE SLIP /RAMS - MUD CROSS WITH 2- 1/16" MANUAL GATE VALVES + 4- 1/16" HCR VALVES ON BOTH CHOKE AND KILL LINES . - TOT 2 -3/8" X 3-1/2" VB RAMS - TOT 2 -3/8" COMBI PIPE SLIP /RAMS. SPOT SATELLITE CAMP AND AUXILLARY EQUIPMENT. RIG UP FLOWBACK TANK AND HARDLINE. 01:30 - 02:00 0.50 BOPSUR P PRE RIG UP GOOSENECK. 02:00 - 03:00 1.00 BOPSUR P PRE INSTALL LUBRICATOR AND PACKOFF 'ASSEMBLY. RIG UP INJECTOR. 03:00 - 08:00 5.00 BOPSUR P PRE PULL NEW 2 -3/8" COIL FROM REEL HOUSE OVER TO RIG FLOOR AND SECURE IN INJECTOR. !GET SHELL TEST ON BOPS. : BEGIN BOP TEST. TEST WITNESS WAS I WAIVED BY BOB NOBLE WITH AOGCC. 08:00 - 11:30 3.50 BOPSUR P { PRE CONTINUE PRESSURE TEST BOPS. TEST ALL CHOKE VALVES. TEST ANNULAR PREVENTER, BLIND /SHEAR, UPPER AND LOWER PIPE SLIP RAMS AND VBR RAMS. NO FAILURES. TES T 2 TIW VALVES. +- 11:30 - 12:00 0.50 BOPSUR P PRE PERFORM RIG EVAC EXERCISE WITH HIGH LEVEL H2S ALARM. ALL PERSONNEL MUSTER AT THE PRIMARY MUSTER POINT AND ARE ACCOUNTED FOR IN2MIN. CONDUCT AAR FOLLOWING THE DRILL. 12:00 - 13:00 1.00 BOPSUR P PRE I PICK UP INJECTOR AND TEST THE E -LINE, DOESN'T PASS. TROUBLESHOOT IN REEL. UNHOOK CABLE _ ' FROM BULKHEAD, STILL DOESN'T TEST. 13:00 - 14:30 1.50 BOPSUR N PRE DISCUSS WITH SLB CTS MANAGEMENT IN DEADHORSE. BAD SPOT IN CABLE IS SUSPECTED CLOSE TO THE BULKHEAD. DECIDE TO BREAK DOWN THE REMAINING E -LINE IRON IN THE REEL TO EXPOSE AS MUCH ELINE AS POSSIBLE TO FIND THE BAD SPOT. PJSM FOR WORKING INSIDE REEL. EXPOSE 3 FT OF WIRE IN THE REEL AND CUT _ IT OFF. RE -TEST IS GOOD. 14:30 - 20:00 5.50 BOPSUR N PRE PUMP BACKWARDS TO FILL REEL AND PUSH SLACK TOWARDS REEL, NEED ANOTHER 2 -3 FT OF CABLE TO MAKE UP BULKHEAD. GET REQUIRED CABLE AND MU BULKHEAD AGAIN. CONDUCTIVITY TEST AND CABLE GOOD. 20:00 - 21:30 1.50 BOPSUR P PRE PJSM, MAKE UP BAKER SLIM CONNECTOR. PULL TEST SAME. PRESSURE TEST CONNECTOR TO 250/3500 PSI. 21:30 - 22:00 0.50 BOPSUR P PRE PRESSURE TEST INNER REEL VALVE AND PACK -OFF TO 250/3500 PSI, GOOD TEST Printed 5/14/2012 1:13:38PM • * North America - ALASKA - BP Page 3 ' Operation Summary Report Common Well Name: F -08 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 4/30/2012 End Date: X3 -011 MW -C: (2,062,333.00 ) Project: Prudhoe Bay I Site: PB F Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 3/24/1974 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °20'11.829 "9 Long: 0148°46'01.316'W Active Datum: ORIG KELLY BUSHING @54.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ; Phase Description of Operations (hr) (ft) 22:30 - 23:00 0.50 BOPSUR P PRE PUMP SLACK FORWARD @3.8BPM MEG TEST E -LINE, GOOD _ 23:00 - 00:00 1.00 BOPSUR P ! PRE INSTALL BHI DUAL FLAPPER CHECK VALVE AND PRESSURE TEST SAME TO 250/3500 PSI 5/2/2012 00:00 - 02:00 2.00 BOPSUR P PRE PJSM WITH VAVLE CREW TO PULL TWC. MU LUBRICATOR AND PRESSURE TEST !SAME TO 250/3500 PSI AGAINST CLOSED SWAB, SSV AND MASTER 02:00 - 03:00 1.00 BOPSUR P PRE OPEN SWAB, SSV AND MASTER VALVES. PULL TWC, WELL ON VAC TWC RECOVERED MISSING 0-RING, LIKELY LOST DOWNHOLE DUE TO VAC. CLOSE MASTER AND SWAB. _ 03:00 - 04:20 1.33 BOPSUR P PRE RIG UP TO BULLHEAD FILL STACK WITH MEOH, STAB INJECTOR, TEST QTS TO 250/3500 PSI. OPEN MASTER AND SWAB 04:20 - 05:30 1.17 BOPSUR P PRE BULLHEAD WELL WITH 8.4 PPG KCL, 2.5 BPM DOWN COIL, 2 BPM DOWN KILL LINE FOR 4.5 BPM TOTAL PUMP RATE AT 2200 PSI AND 290 BBLS PUMPED 0 5:30 - 07:00 1.50 ! BOPSUR P PRE ,FLOW CHECK WELL FOR 30 MIN. FILL WELL ACROSS TOP AND ASSESS LOSS RATE. ABOUT 20 -25 BBUHR. 07:00 - 08:20 1.33 j BOPSUR P PRE DISCUSS WITH CTD SUPT AND ODE. DECISION IS MADE TO INCLUDE JARS IN THE DRIFT RUN DUE TO LOST 0-RING WHEN PULLING TWC. 08:20 - 08:30 0.17 STWHIP P WEXIT JARS ON LOCATION. PJSM FOR M/U DRIFT BHA. 08:30 - 09:00 0.50 STWHIP P WEXIT j M/U BHA #1 - WHIPSTOCK DRIFT WITH JARS, 2 -3/8" COILTRAK. BHA OAL = 64.34 FT. 09:00 - 11:40 2.67 STWHIP P WEXIT RIH WITH BHA #1. UP WT AT 10400 FT IS 42K. 11:40 - 13:00 1.33 STWHIP P WEXIT TIE IN DEPTH FROM 10535 FT. CORRECT -38 FT. LOG ANOTHER GR PEAK AT 10850 FT TO CONFIRM, ZERO CORRECTION. 13:00 - 13:25 0.42 STWHIP P ! WEXIT ! CONTINUE RIH WITH WHIPSTOCK DRIFT. SLOW DOWN AND ZERO DWOB AT 11090 FT, LOOK FOR A TAG. TAG AT 11104 FT WITH PRESSURE INCREASE. 6K ON DWOB. PICK UPWITH SLIGHT OVERPULL TO 11050 FT AND TRY AGAIN. ZERO DWOB AND RIH 10 FT /MIN FROM 11050 ! FT. INCREASE IN DWOB OF LESS THAN 100 LB DOWN TO 11101 FT, STOP THERE SO AS NOT TO TAG THE XO AGAIN. 13:25 - 15:30 2.08 STWHIP P WEXIT PICK UP OFF BOTTOM AND FLOW CHECK FOR 5 MIN. FLOW CHECK IS GOOD. POOH. 15:30 - 18:00 2.50 STWHIP P j ! WEXIT UD WHIPSTOCK DRIFT AND JARS. M/U BHA #2 - WHIPSTOCK AND 2 -3/8" 1 COI - Printed 5/14/2012 1:13:38PM North America - ALASKA - BP Page 4ef Operation Summary Report Common Well Name: F -08 ' AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 4/30/2012 1 End Date: 'X3 -011 MW -C: (2,062,333.00 ) Project: Prudhoe Bay Site: PB F Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 3/24/1974 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °20'11.829 "9 Long: [ 0148°46'01.316'W Active Datum: ORIG KELLY BUSHING @54.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (ft) 18:00 - 21:00 3.00 STWHIP P WEXIT RIH WITH WHIPSTOCK AT 75 FPM SLOWING DOWN TO 10 FPM AT ALL JEWELRY. 13 BPH LOSSES WHILE PUMPING AT 0.45 ;BPM THROUGH OPEN EDC. IAP= 5 PSI, OAP = 215 PSI 21:00 - 21:15 0.25 STWHIP P WEXIT ORIENT WHIPSTOCK FACE TO 62 ROHS AT ;10,050' MD. PUW AT 10,300' MD = 45K 21:15 - 21:45 0.50 STWHIP P j WEXIT iTIE -IN AT 10,900' MD WITH A ( -38') I CORRECTION 21:45 - 22:00 0.25 STWHIP P WEXIT 1 RIH TO SETTING DEPTH OF 11085' MD TOP _ OF WHIPSTOCK. VERIFY WS ORIENTATION OF 62 DEG ROHS. SET TRIPS ON PUMP TO 4000 PSI, CLOSE • EDC WHIPSTOCK SET AT 3400 PSI AND WOB OF 3K ALONG WITH FULL RETURNS CONFIRMED SET. 22:00 - 22:10 0.17 STWHIP P WEXIT PULL UP OUR OF WS, FLOW CHECK WELL FOR 5 MIN, CLOSE EDC. 22:10 - 00:00 1.83 STWHIP P WEXIT POH AT 80 FPM WHILE CIRCULATING 1.5 BPM 'AT 2050 PSI TO 3200' MD. 5/3/2012 00:00 - 00:30 0.50 STWHIP P WEXIT POOH FROM 3200' MD TO 67'MD TOTAL OF 2 BBLS LOST TO FORMATION DURING POH. 00:30 - 01:15 0.75 STWHIP P j WEXIT PJSM WHILE FLOW CHECKING WELL ! UNSTAB INJECTOR AND SLOWLY COME UP PTO CONNECTOR SINCE SLIMHOLE BHA 1 LAY DOWN WS RUNNING BHA 01:00 - 01:30 0.50 STMILL P WEXIT RIG EVAC DRILL ALL HANDS ACCOUNTED FOR INCLUDING 4 TRUCK DRIVERS AND BTT REPS. FOLLOW WITH AAR 01:45 - 02:15 0.50 STMILL P WEXIT PICK UP WINDOW MILLING BHA #3 WITH HC 2.74" WINDOW MILL, HC 2.74" STRING REAMER, STRAIGHT MOTOR, 2 JTS CSH, COILTRAK. VERIFY GUAGE ON MILL AND REAMER, 2.75" L 1 1 GO, 2.74" NO -GO. 102:15 - 02:30 0.25 STMILL P 1 WEXIT , STAB INJECTOR AND TEST QTS TO 250/3500 PSI. 02:30 - 07:30 5.00 1 STMILL P i WEXIT RIH TO TIE -IN DEPTH —10,900' SWAP WELL TO MUD THROUGH OPEN EDC. 07:30 - 08:00 0.50 STMILL P WEXIT GET SPP AT 11080 FT AFTER WELL IS SWAPPED TO MUD. 08:00 - 08:30 0.50 STMILL P WEXIT TAG WHIPSTOCK AND START MII I INC-1 WINDOW. TIME MILL THE FIRST 1 FT. 08:30 - 08:40 ! 0.17 STMILL P WEXIT CONTINUE MILLING WINDOW FROM A PINCH POINT OF 11085.5 FT. 08:40 - 09:00 I 0.33 STMILL P WEXIT 1 STALL AT THE END OF A TIME STEP AT 11085.9 FT. CLEAN PICKUP, START 0.2 FT HIGHER UP. 09:00 - 10:00 1.00 STMILL P WEXIT MILLING WINDOW AT 11086.0 FT. DWOB = 1.86KLBS. CIRC PRESSURE = 3020 PSI. ! _ _ BLEED IA FROM 750 PSI TO 120 PSI. 10:00 - 11:00 1.00 STMILL P WEXIT MILL WINDOW AT 11086.6 FT. DWOB = i 3.09KLBS. CIRC PRESSURE = 3259 PSI. 11:00 - 12:15 1.25 STMILL P WEXIT � MILL WINDOW AT 11087.1 FT. DWOB = I ! 2.90KLBS. CIRC PRESSURE = 3333 PSI. Printed 5/14/2012 1:13:38PM • North America - ALASKA - BP Page 5 ' Operation Summary Report . Common Well Name: F -08 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 4/30/2012 End Date: ;X3 -011 MW -C: (2,062,333.00 ) Project: Prudhoe Bay Site: PB F Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 3/24/1974 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °20'11.829 "9 Long: 0148°4601.316'W Active Datum: ORIG KELLY BUSHING @54.80ft (above Mean Sea Level) Date From - To j Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:15 - 13:05 0.83 STMILL P WEXIT ; MILL WINDOW AT 11088.0 FT. DWOB = 1.11 KLBS. CIRC PRESSURE = 3164 PSI. 13:05 - 14:50 1.75 STMILL P WEXIT , MILL WINDOW AT 11088.91 FT. DWOB = 1.30 KLBS. CIRC PRESSURE = 3060 PSI. 14:50 - 15:30 0.67 STMILL P WEXIT MILL WINDOW AT 11090.4 FT. DWOB = 1.40KLBS. CIRC PRESSURE = 3090 PSI. 15:30 - 16:30 1.00 STMILL P WEXIT LIKELY CASING EXIT AT 11090.8 FT. CONTINUE TIME MILLING ANOTHER 1 FT TO ALLOW THE STRING REAMER TO WORK. 16:30 - 18:30 2.00 STMILL P WEXIT MILL RATHOLE AT 5 -10 FT /HR WITH 2K DWOB TO 11101' MD. ! SAMPLE FROM 11091 FT IS 25% FORMATION. 18:30 - 20:00 1.50 STMILL P WEXIT iDRESS WINDOW BY BACKREAMING UP (THROUGH WIDOW FOLLOWED BY 3 PASSES AT 1 FPM WHILE CIRCULATING. 20:00 - 20:30 0.50 STMILL P WEXIT DRY DRIFT WINDOW 20:30 - 20:45 0.25 STMILL P WEXIT FLOW CHECK WELL, NO FLOW 20:45 - 23:00 2.25 STMILL P WEXIT POH WITH WINDOW MILLING BHA AT 70 FPM _ ! _ PUMPING 3BPM @ 3710 PSI WITH EDC OPEN. 23:00 - 23:20 0.33 STMILL P WEXIT FLOW CHECK AT 500' MD PRIOR TO PULLING BHA THROUGH STACK. 23:20 - 00:00 0.67 STMILL P WEXIT PJSM, LD MILLING BHA, MINIMAL WEARON MILLS, WINDOW MILL AND STRINGMILL GUAGED AT 2.74 G0,2.73 NO -GO. 5/4/2012 00:00 - 01:00 1.00 STWHIP P WEXIT LAY DOWN MILLING BHA AND GAUGE. WINDOW MILL GAUGED AT 2.73, STRING MILL AT 2.74, MINIMAL WEAR 01:00 - 01:45 0.75 DRILL P PROD1 PJSM, SIMULATE CIRCULATING OUT KICK THROUGH MUD GAS SEPARATOR USING THE SUPERCHOKE, PUMPED 1 BPM WHILE PERFORMING DRILL. AAR HELD TO DISCUSS EFFICIENCY FOR WHEN THIS OPERATION MIGHT BE NEEDED AT COLDER TEMPS 01:45 - 04:00 t 2.25 DRILL P PROD1 1 PJSM, CUT AND SLIP DRILLING LINE, 50', HOLD AAR 04:00 - 05:00 1.00 DRILL P PROD1 I PJSM, MU BUILD SECTION BHA #4 WITH 1.6 DEG MOTOR AND 2.7" X 3" HCC BIT 05:00 - 06:00 1.00 DRILL P PROD1 RIH WITH BUILD BHA 06:00 - 06:30 0.50 DRILL P PROD1 CONTINUE RIH WITH BUILD BHA. 06:30 - 07:10 0.67 DRILL P PROD1 CONTINUE RIH WITH 1.6 DEG BUILD ASSEMBLY. - -- - - - - - - -- - - - -- - -- - - - -- - -- - - -- - 07:10 - 07:40 0.50 DRILL P PROD1 •TIE IN DEPTH FROM 10900 FT. CORRECT -38 FT. PASS THROUGH WINDOW AT 60R ORIENTATION. 07:40 - 12:30 4.83 DRILL P PROD1 START DRILLING SLOWLY FROM 11101 FT. AVERAGE ROP IS 20 -40 FT/HR WITH 1 -2K DWOB. DRILL AT 45R INITIALLY TO GAIN SEPARATION FROM PARENT WELL. 12:30 - 13:10 ! 0.67 DRILL P ! PROD1 CONTINUE DRILLING PAST 11230 FT. PUMP 20 BBLS HI-VIS PILL. DRILL TO 11250 FT. Printed 5/14/2012 1:13:38PM WELLI-EAD = 13-5/8" Kiz EV OY PJC D•FT F-08B SAIIINOTES:WB.L ANGLE > 70 11315% ACTUATOR= BAKER C 20 CO i4 t I Be: ELEv _ 34.9 " ICUCTOR —1 joi .4 lli, 2072 . 1-19-5/8' HES CEMENTER 1 2700' 94 #, H-40, 4 t KOP= k S 2097` H4-1/2" FES X NV, 13 =3.813" 1 ,... M3x Angle = 94" © 1145V D= 19.124" i Datum ND= 11053' 9-5/8" CSG, 40#, 615' I 2106' H9-5/8" PBR (121 2135' —19-5/8 HOWCO FO CEMB4TER Datum 1 VD --'. 8800' SS L-80 HY PRI.. • • 563 X0 TO TC11 , • 2660' H9-5nr HOWCO FO CEMENTER • 19-5/8* TEBACK CSG, 40#, L-80 TC1, 13= 8.835" . --I 2129' I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" 1 2700' 2 3795 3769 22 MMG DMY RK 0 11/21(11 • II 1 1 7638 6493 40 MMG DMY 1 RK 0 11/21/11 19-5/8" HOWCO FO CEMENTER 1 4212' 9425' — 14-1/2" HES X NP, D = 3.813' I MINIMUM ID = 178" @ 9446' 9439' 1-13.70 DEPLOY SLV, ID = 3.00' 1 MILLED OUT ALUMINUM BUSHING iri lli 1 94.45' H3-1/2" X 3 LNR X0, ID = 2.70" 1 DEPLOYMENT SLEEVE 9446' I 3 DEPLOY SLV, ID = 2.25" ALUMINUM BUSHNG @9452' (MILLED DUD 1 7" TBG STUB (TAGGE) 07/08/07) H 9520' 1 II 9488' H 9-518" X 4-1/2" BKR S-3 PKR, ID =3.875' 1 I 9512' H 4-lir HES X NP, 13= 3.813" 1 BEHIND 9 = 1 '4-1/2' TBG, 12.64.13CR-80 VAM TOP, — 1 533' H4-1/2" HES XN MP, D 3.725" CT LINER 1 9546' . .0152 bpf, ID = 3.958" 9546' H4-1/2" HES WLEG, ID = 3.958" r TBG, 264 , N-80 AB-TC-4S, .0383 bpf, 13 = 6.276' --1 9559' i :1' c. 9559' H9-5/8" X 7" BOT LTPw / 40' FBA &I-IGR, ID =1 I I 1 9-5/8' CSG, 47#, N-80 Burr, RD = 8.681" H 10087' 10435' HT` X 4-1/2. OTIS VvD FKR, ID = 4.0' 1 13-3/16' LM R STUB (07/09/07) H 10435' 1 BEHIND 10441' 714-1/2" 011S X NP, 13 = 3.813 1 2 CT U NER I i 10445' 1— 4-1/2" OTIS XN NV, ID= 3_800" (MLLEJ 12/04/02) 17 MARKER JOINT 1-1 11040' 1 10447' H4-1/2 W/LEG, 1) = 3.958' I M LLOUT VOIDOW (F-08A) 11086' - 11074' I pig , i1V 1 7" L14 29#, N-80 BUTT, .0371 bpf, D = 6.184 I-1 11066' . Al Ok- I A; 1161 PA_LOUT MEOW (07-08/3) 11086 - 11091' Ab P ow , 3-3/16" WFIPSTOCK (05/02/12) —1 11085' --,........ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, D = 2.80" H 11101' 1-- PERFORATION StifiNAARY REF LOG: SWS ECM_ ON 05/13/12 ANGLEAT TOP PERF: 90* (§) 12455' Note: Refer to Production DB for historical pert data SIZE 1 SW IYIERVAL Opn/Sqz DATE — 1.56" 6 12455- 12655 CI 05/14/12 MID --1 12663' 1 iv [2-3/8" LNR, 4.7#, L-80 STL, _0039 bpf, ID = 1.995" 1-1 12701' 1 611111 DATE REV BY COMMENTS DATE REV BY COIVMENTS FRUDHOE BAY UMT 09/08/78 IMTIAL COMPLETION WELL: F-08B 12/20/02 NORDIC 1 CTD SIDETRACK (F-08A) FERMT No: 120400 , 07/14/07 N2ES RWO AR No: 50-029-20135-02 05/15/12 NORDIC 2 CTD SIDETRACK (F-08B) SEC 2, T11N, R13E, 2570' Ft'L & 2403' FWL 05/18112 PJC DRLG HO ODRRECTIONS 05/19/12 PJC DRLG DRAFT CORRECT/DNS L BP Exploration (Alaska) • • McMains, Stephen E (DOA) From: Lastufka, Joseph N (Northern Solutions) (Joseph.Lastufka @bp.com] Sent: Thursday, May 31, 2012 10:36 AM To: McMains, Stephen E (DOA) Subject: 10 -407 for F -08A FIT ; lo; 1 Steve, There is a correction for the y coordinate for the surface location. It should be 5974230, not 5973828. This changes the Surface Location to 2570' FNL, 2877' FEL. Please let me know if you have any questions. Thanks! Joe � DJUN t 1 �tl?Z ' • • , ' , Y ( i , , — J c ' C � ' N C ' SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader 1 BP Exploration (Alaska), Inc. Q - P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F -08A Sundry Number: 312 -105 Dear Mr. McMullen: F : $:)MAR y 8 ZOIL 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, 11' , Cathy . Foerster Chair DATED this day of March, 2012. Encl. • I • E i EIVED r' • STATE OF ALASKA Z2� ,�CT ALASKA OIL AND GAS CONSERVATION COMMISSI N C� ' 1 2012 APPLICATION FOR SUNDRY APPROV L -- 20 AAC 25.280 ` 41d5 .a ! 3 Goa Coe.,. Carr rksian I 1. Type of Request: ! \tnChorage ❑ Abandon ® Plug for Redrill r ❑ Perforate New Pool ❑ Repair Well ❑ Chaige Approved Program ____.�) ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension __ ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development / ❑ Exploratory 202 - 231 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 20135 - 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 F -08A Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028280 & 028281 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): 12750' ' 9043' ' 12707' 9042' 11890' 12278' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 30" 80' 80' Surface 2700' 13 -3/8" 2700' 2700' 4930 2670 Intermediate 10087' 9 -5/8" 10087' 8174' 6870 4760 Production Liner 1507' 7" 9559 - 11066' 7866' - 8865' 8160 7020 . Liner 2377' 3- 3/16" x 2 -7/8" 10429' - 12740' 8404' - 9043' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11290' - 12694' 9023' - 9042' 4-1/2", 12.6# / 7 ", 26# 13Cr80 / L - 80 / N - 80 10435- 10447 ' ssza - 9596 Packers and SSSV Type: 9 -5/8" x 4 -1/2" Baker 'S -3' packer Packers and SSSV 9488' / 7826' 7" x 4" Otis WD Packer MD (ft) and TVD (ft): 10435' / 8408' 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: April 1, 2012 ❑ 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 Ron Phillips, 564 -5913 Printed Name Jo' ! r em ,. Title Engineering Team Leader • Prepared By Name /Number: Signature 4., r Phone 564 - 44711 Date 3 4 Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval•. Notify Commission so that a representative may witness 3f 2_406 L�fr Sundry Number: ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance -$ 3s� ps;, 4 .3e/0 7' , ,.l Other: ® / 2_& AA C.- ZS 1 / 2 ■'V Subsequent Form Required: /D .-4/107 APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date 3 - 1 2 — / Z Fo 10-40 vi 01/ f f e n Submit In Duplicate 3.2-z-(2.- /-ti A • i To: Alaska Oil & Gas Conservation Commission From: Ron Phillips by CTD Engineer Date: March 13, 2012 Re: F -08A Sundry Approval Sundry approval is requested to plug the F -08A perforations with a 3- 3/16" Baker ✓ Packer Whipstock as part of drilling the F -08B coiled tubing sidetrack. History of F -08A. F -08A is a CST completed in Dec 2002 in Zone 2A above the MHO /HOT (did not tag the HOT). Upon completion, the well struggled to flow despite two N2 lifts. The well finally went on production after an HCI wash and the installation of a gas lift straddle. The sidetrack produced fulltime until late 2005 when it was shut -in for a tubing leak. In July 2007, a RWO was completed which replaced the tubing and the Thermocase section of the 9 -5/8" casing. The 5 -3/4" CTD liner deployment sleeve was also cut off and removed before running the downsized 4 -1/2" tubing. The well was POP'ed and remained fulltime for -2 years. In mid 2009, F -08A began cycling for high GOR. In July 2010 a CIBP was set at 11890' to isolate the current perfs, and 100' of perfs were added in the first half of the lateral. The well would not flow. An additional 60' of perfs were shot in Feb 2011. The well produced for a couple months before being shut -in for high GOR. End -of -life adperfs (25') were shot in the heel in April 2011, but they were unsuccessful. F -08A is currently shut -in for high GOR. The most recent calliper from 11/19/12 showed the tubing and casing (4 -1/2 ", 7" and 3- 3/16") to be in good condition, with a maximum wall penetration of 19% recorded at 11,010', 10,667' and 10,438'. All sidetrack screening pressure tests passed. Reason for sidetrack. F -08A is no longer a competitive producer, and there are no remaining wellwork options. The proposed sidetrack will access reserves in a Zone 2A target in Southwestern F -pad. Proposed plan for F -08A. The existing perforations will be isolated by setting a 3- 3/16" packer whipstock set pre -rig. The primary cement job for the liner will cover the whipstock by 650'. The sidetrack, F -08B, will exit the existing 3- 3/16" liner and kick off and land in the Ivishak Zone 2A. This sidetrack will be completed with a cemented and perforated 2 -3/8" L- 80 liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. 74 e or,/ 602 4. C/ �.a J o� Iv ewer , Q"'a ‘c-f/.57, 1 Gv /. eci /'U � f oluie ��� �1rif god 6,011 /1 ew �cr�S a,_ dv f - Me tt Cam' / / y ,� lec�ly�y° wgtq c T4f Pe/Il `t P i Ttie- Ate ,1a r /k-'4f er ' o (0 ,, v. 4 kA r N eeaff tPoO 5C,10 L � % ,1�o✓ /0/ /I�1�/v✓ / lyfrido, 14,y wel� TO Q IION / / /0 r ►'� COW'f, �✓'om rl' / O ' ? O The i A ./.2/// . • • Pre -Rig Work: (scheduled to begin April 1 2012) 1. F MIT- IA to 3,000 psi (passed 11/21/12), MIT -OA to 2,000 psi (failed 11/21/12). 2. W Function LDS; PPPOT- T to 5,000 psi. 3. S Drift for 3- 3/16" packer whipstock (2.56" x 9.25') to 11,101'. 4. EP Set 3- 3/16" packer whipstock at 11,085' MD (orientate 90 °). 5. V PT MV, SV, WV. !� P7 -� ts orsL 6. 0 Blind and bleed lines to zero, remove wellhouse and level pad. 7. V Set 4" CIW TWC 24 hrs prior to rig arrival. Rig Sidetrack Operations: (Scheduled to begin on May 1 2012 using Nordic Rig 1) ri/ 1. MIRU Nordic Rig 1. 2. NU 7- 1/16" CT Drilling BOPE and test. 3. Mill 2.80" single string window in the 3- 3/16" liner at 11,085'. 4. Drill Build: 3" OH, 305' (35 deg /100 planned). 5. Drill Lateral in Z2A: 3" OH, 1,590' (12 deg /100 planned) with resistivity. 6. Run 2 -3/8" L -80 liner leaving TOL -9,520' MD. 7. Pump primary cement leaving TOC at 10,435' MD, 10.6 bbls of 15.8 ppg Class G cement planned. 8. Perform cleanout/log run with mill and motor. P eAd 9. Perform a logging run with MCNL /GR /CCL. en) 10. Test liner lap to 2,400 psi. 11. Perforate well (- 500'). 12. Freeze protect well with diesel to 2,500' TVD. 13. Set BPV. ND 7- 1/16" BOPE stack. 14. Freeze protect tree and PT tree cap to 3,500 psi. 15. RDMO Nordic 1. Post Rig: 1. Re- install wellhouse, flowline and pull BPV. 2. Set 4 -1/2" liner top packer if needed with skickline, and test to 2,400 psi. Ron Phillips CTD Engineer 564 -5913 CC: Well File Sondra Stewman/Terrie Hubble TREE. . 4" CM/ V�ELLHEAD - 5/8" McEVOY SAMIN OTES: WELL ANGLE > 70° @ 11295'. * ** I ACTUATOR = OTIS F-08A 4- 1 /WiROMETBG* ** KB. ELEV = 54.8' BF. ELEV = 34.92' I KOP = 3200' ►j k Max Angle = 94° @ 11575' 30" CONDUCTOR, --I 80' 0 > 2072' H9 -5/8" HES CEMENTER I � Datum MD = 11053' �i k 157.53 #, ID = ? t 2097' I -14 -1/2" HES X NIP, ID = 3.813" I Datum TVD = 8800' SS i 19 -5/8" CSG, 40 #, L -80 HY DRIL 563 XO TO TC11 H 615' 1 2106' H9-5/8" PBRI • 0- I 2135' H 9 -5/8" HOWCO FO CEMENTER I 19 -5/8" CSG, 40 #, L -80 TCII, ID = 8.835" I-1 2129' • 2660' H 9 -5/8" HOWCO FO CEMENTER I 113 -3/8" CSG, 72 #, N -80 BUTT, ID = 12.347" I-1 2700' I 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3795 3769 22 MMG DMY RK 0 11/21/11 19-5/8" HOWCO FO CEMENTER I-{ 4212' ( • 0 1 7638 6493 40 MMG DMY RK 0 11/21/11 Minimum ID = 2.372 "@ 11101' ' 1 I 9425' H4 -1/2" HES X NIP, ID = 3.813" 1 3- 3/16" X 2 -7/8" XO a -I 9488' H 9-518'x4-1/2" BKR S -3 PKR, ID = 3.875" I 17" TBG STUB (TAGGED 07/04/07) 1-1 9512' 1 • ( 9512' H4 -1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, —I 9545' • • I 9533' J -J4 -1/2" HES XN NIP, ID = 3.725" .0152 bpf, ID = 3.958" 17" TBG, 26 #, N -80, .0383 bpf, ID = 6.276" H 9596' 9546' I--I4 -1/2" HES WLEG, ID = 3.958" I 9559' 1-17" PBR, ID = ? 19 -5/8" CSG, 47 #, N -80 BUTT, ID = 8.681" I--1 10087' PERFORATION SUMMARY 9599' _I-17" BOT PKR w / BOT HGR, ID = ? I REF LOG: SWS MEMORY CNL /GR OF 12/19/02 ANGLE AT TOP PERF: 71° @ 11290' ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 10435' H3- 3/16" LNR STUB (07/09/07) 1 1.56" 6 11290 - 11295 0 04/03/11 1.56" 6 11295 - 11315 0 04/02/11 I 10435' 1-17" X 4 -1/2" OTIS WD PKR, ID = 4.0" I 2" 6 11340 - 11365 0 07/15/10 g 2" 6 11415 - 11440 0 07/15/10 10441' —14 -1/2" OTIS X NIP, ID = 3.813" I BEHIND 2" 6 11470 11500 0 02/03/11 i I 10445' 114-1/2" OTIS XN NIP, ID = 3.800" CT LINER 2" 6 11582 - 11612 0 02/03/11 2" 6 11660 - 11685 0 07/15/10 (MILLED 12/04/02) 2" 6 11800 - 11825 0 07/15/10 10447' H4 -1/2" W /LEG I 2" 4 12000 - 12182 C 12/20/02 2" 4 12380 - 12694 C 12/20/02 • � � I 11040' H 7" MARKER JOINT I • MILLOUT WINDOW (F -08A) 11066' - 11074' I I TOP OF CEMENT H 10760' ♦ t4 t � $1? 5 TOP OF WHIPSTOCK 11053' ♦;v W S H �. 11101' —13-3/16" X 2 -7/8" XO, ID = 2.372" I (BAKER MOD K BRIDGE PLUG H 11275' 12278' FISH- FASDRILL DEBRIS 1 7" LNR, 29 #, N -80 BUTT, .0371 bpf, ID = 6.184"1-1 11303' A/ ` (PUSHED TO BTM 09/13/07) 3- 3/16" LNR, 6.2 #, L -80, 11101' PBTD --I 12705' .0076 bpf, ID = 2.80" 12-7/8" HES CIBP (07/15/10) H 11890' I ' I2 -7/8" LNR, 6.16 #, L -80 STL, .0547 bpf, ID = 2.372" H 12740' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/08/76 ORIGINAL COMPLETION 07/28/10 HJW /PJC PERF/ CIBP (07/15/10) WELL: F -08A 12/21/02 DAC /KK CTD SIDETRACK (F -08A) 02/12/11 LLVPJC ADPERFS (02/03/11) PERMIT No: ® 2022310 07/14/07 N2ES RWO 04/04/11 RRD /PJC ADPERF (04/02- 03/11) API No: 50- 029 - 20135 -01 ll 02/08/07 CJN/PAG PULL BKR IBP/ GL MANDREL 11/28/11 DLW /JMD GLV C/0 (11/21/11) SEC 2, T11N, R13E, 2570' FNL & 2403' FWL f: 04/06/07 ALH/PJC ARROW PATCH PULLED (02/07/07) ' 01/15/08 JCM/ PJC DRLG DRAFT CORRECTIONS I BP Exploration (Alaska) 61 NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM V12 /1' V14 I HON a,rwlar 1 7111 a" 5000 psi ROP's ID . 7.08" V15 V71 ' /17 1 /18" 5000 Wi, RX -08 Transducers ® IIlll M ORB 1 # V2 1 V1 V ...IN 0I ia w r t typical ,. No BOP I OT ', OASS age for Z coiled 1 �' tubing tlrlllnq Zi �. T O MI... MI... � •. I 71116" 5000 pal, RXL6 111 ii V17 HCR � IC �' ix OK , To Poor Boy Gas Buster Mc ._. I V19 V19 ' 'S ;T7;., AP ]1116 "5000 psi. RX.]G I 3.00 "5000 psi HCR I 1 „ M +r - ■ a rdl te 2.1 Mr 0000 psi CHECK VALVE Manual Choke ighlM1211111 Ica — 71/16 Cameron FOV Gate r •, ^ Valve x 5000 pal 1`r lir— MEOH /Diesel ` f — P Line CoFlex Hose cli Mil Mr 7. - 1/4 Turn Halco 10W0o To Production Tree or Cross Over • I I e r •ress e transducers CoPIex Hose CV11 11 11 CV12 To Coiled Tubing °.., Bleed Off Inner Reel Valve w _ j �_ CV Cement Line In !1 1 Ground Level Tie -in .0 -e', CVO CV2 T Stand Pipe — _ — _ — — Manual Choke _ — _..,,_„•• r - - -_ - -- _ p = Pressure Transducers 0 I, I = 1 i CV9 Motion 11 CV17 V a _ IUI. cvt I� �► Nov u cva — { ,,,,;,,,,,,.rr.,..,a Tiger Tank Mud Pump 2 m O — Baker MP In F ro1 8 MP 2 t – _ M11I Choke • • CV14 = to Pits I Rig Floor i Mud Pump #1 0 CV16 Reverse Ci . ' n • '„- Cir CT while 00' _ = _ aM . . a CID O _ — To Manifold CV15 1 Jun - 2010 ■ aaversa Oir.sul.Hnn lino / err wile MN CoFlex Hose • Page 1 of l Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art o teve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 • uis checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and V operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 3/21/2012 STATE OF ALASKA s • ALASKA* AND GAS CONSERVATION COMMISSICIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ - 202 -2310 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 20135 -01 -00 8. Property Designation (Lease Number) : r 9. Well Name and Number: ADLO- 028281 , PBU F -08A 10. Field /Pool(s): a PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12750 feet Plugs (measured) 11890 feet true vertical 9042.69 feet Junk (measured) 12278 feet Effective Depth measured 12707 feet Packer (measured) 9488 9599 10435 feet true vertical 9042.23 feet (true vertical) 7826 7888 8408 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 30" 20 - 101 20 - 101 Surface 2681' 13- 3/8 "72# N -80 19 - 2700 19 - 2700 4930 2670 Production 2111' 9 -5/8" 40# L -80 18 - 2129 18 - 2129 5750 3090 Production 7958' 9 -5/8" 47# N -80 2129 - 10087 2129 - 8174 6870 4760 Liner 1515' 7" 29# N -80 9559 - 11074 7866 - 8871 8160 7020 Liner 690' 3- 3/16" 6.2# L -80 10435 - 11125 8408 - 8916 Liner 1615' 2 -7/8" 6.16# L -80 11125 - 12740 8916 - 9043 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 17 - 9545 17 - 7858 7" 26# N -80 9512 - 9596 7839 - 7887 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Packer 9488 7826 7" BOT Packer 9599 7888 4 -1/2" Otis WD Packer 10435 8408 12. Stimulation or cement squeeze summary: Intervals treated (measured): RECEiVEU `►' ` % APR i 3 }1 Treatment descriptions including volumes used and final pressure: ri '' a 2 .?!r1 13. Representative Daily AverAkakflaireprfhisiltm.Rate ��� Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 751 12,747 49 - rj " ' tor eg 6 1,183 Subsequent to operation: 410 25,926 75 1,070 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil „ El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSPO SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na e Jo• Lastul ilk i Title Data Manager Signatu - INAui \ Phone 564 -4091 Date 4/12/2011 Form 10 -404 Revised 10/ 0 '1 /3 4 ReDMS APR 13 7"' f /� A / Submit Original Only F -08A 202 -231 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F -08A 12/20/02 PER 12,000. 12,182. 9,030.7 9,035.23 F -08A 12/20/02 PER 12,380. 12,694. 9,040.23 9,042.12 F -08A 7/13/10 APF 11,800. 11,825. 9,028.18 9,027.14 F -08A 7/13/10 BPS 11,890. 12,694. 9,026.04 9,042.12 F -08A 7/14/10 APF 11,660. 11,685. 9,028.04 9,028.4 F -08A 7/14/10 APF 11,415. 11,440. 9,030.3 9,029.08 F -08A 7/15/10 APF 11,340. 11,365. 9,032.68 9,032.82 F -08A 2/2/11 APF 11,470. 11,500. 9,029.14 9,030.28 F -08A 2/2/11 APF 11,582. 11,612. 9,030.15 9,028.32 F -08A 4/2/11 APF 11,295. 11,315. 9,024.81 9,029.66 F -08A 4/3/11 APF 11,290. 11,295. 9,023.24 9,024.81 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • F -08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/1/2011 IT /I /0= 2200/1620/360, Temp =S /I, Assist E -line Load and Kill (Perforating) Pumped 10 bbl Neat Meth spear followed by 293 bbls 1% KCL w/ Safe Lube down Tbg to load I and Kill for E -line. Capped w/ 40 bbls Crude for freeze protect. Rigged off E -line PIS, SB for E -line. Pumped additional 26 bbls crude to assist E -line down hole. FWHP's= 800/1400/400. E -line on well upon departure. 4/1/2011 ** *WELL SHUT -IN ON ARRIVAL * ** SSV OPEN, INTIAL T /I /O 2400/1600/350 MADE DRIFT RUN WITH UPCT AND TWO WEIGHT BARS. ABLE TO REACH 111333'. ATTEMPTED TO RUN 2" - 10' PERF GUN. UNABLE TO REACH DEPTH. 1TRIED PUMPING UP TO 2.5 BPM, COULD NOT GET PAST 11281'. LAY DOWN UNIT FOR NIGHT, OUT OF HOURS, PLAN IS TO PERFORATE THE 25' IN 3 RUNS WITH 1- 11/16" GUNS TOMORROW. ** *JOB IN PROGRESS AND CONTINUED ON 4/2/11 WSR * ** 4/2/2011 1 ** *CONTINUED FROM PREVIOUS DAY * ** WELL SHUT -IN ON ARRIVAL, SSV CLOSED, INITIAL T /I /O 1100/1400/350 KILLED WELL WITH 225 BBLS CRUDE, RAN 1.56" HSD 6SPF 60 DEGREE PHASED PJ 1606 GUNS IN 10' SECTIONS. PERFORATED 11295'- 11315' DEPTH !CORRECTED TO SLB MEMORY CNL DATED 19- DEC -02. ALL SHOTS FIRED, !LAID UNIT DOWN FOR NIGHT. WELL SHUT -IN AND SECURE FOR NIGHT, DSO NOTIFIED OF CONDITION AND TO NOT FLOW WELL. ** *JOB IN PROGRESS AND CONTINUED ON 4/3/11 WSR * ** 4/2/2011 T /I /0= 1100/1400/350. (Assist E -Line w/ perforating) Spear into tbg w/ 3 bbls neat 1 ;meth followed by 220 bbls crude. Cap w/ 5 bbls neat meth. Standby for E -Line to I RIH. FWHP = 0/1400/400. IA & OA OTG. E -Line still on well upon LRS departure. 9 • • 4/3/201 ** *CONTINUED FROM PREVIOUS DAY* * WELL SHUT —IN ON ARRIVAL, SSV CLOSED, INITIAL T /I /O 0/1400/350 I RAN 1.56" HSD 6SPF 60 DEGREE PHASED PJ 1606 GUN, PERFORATED 11290'- 11295' DEPTH CORRECTED TO SLB MEMORY CNL DATED 19— DEC -02. ALL SHOTS FIRED. HAND OVER WITH DSO, DSO TO POP WELL AFTER SLB DEPARTURE. FINAL TWO 0/1400/350. 1 ** *JOB COMPLETE * ** � a FLUIDS PUMPED BBLS 293 1% KCL W/ SAFE LUBE 286 CRUDE 21 METH 3 DIESEL 613 TOTAL TREE = 4" CM/ SAFETY : WELL ANGLE > 70° @ 11295'. * ** I WELLHEACI *-5/8" McEVOY • ACTUATOR= OTIS F -08A 4 CH E TBG * ** KB. ELEV = 54.8' BF, ELEV = 34.92' , , I KOP = 3200' ! � j Max Angle = 94° @ 11575' 30" CONDUCTOR, — 80' 2072' H9-5/8" HES CEMENTER I ■ Datum MD = 11053' 157.53 #, ID = ? .1 ■ ., 2097' 1-14-1/2" HES X NIP, ID = 3.813" I Datum TV D = 8800' SS - • 2106' 4 ' 9 -5/8" CSG, 40 #, L -80 HYDRIL 563 XO TO TC11 H 615' H9 -5/8" PBRI • • 2135' H9 -5/8" HOWCO FO CEMENTER I 19 -5/8" CSG, 40 #, L -80 TCII, ID = 8.835" f-I 2129' • • 2660' H 9 -5/8" HOWCO FO CEMENTER I 113 -3/8" CSG, 72 #, N-80 BUTT, ID = 12.347" H 2700' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3795 3769 22 MMG DOME RK 16 08/23/07 I9 -5/8" HOWCO FO CEMENTER H 4212' I 1 7638 6493 40 MMG SO RK 20 08/23/07 Minimum ID = 2.372 "@ 11101' ' • I 9425' J- I4 -1/2" HES X NIP, ID = 3.813" I 3- 3/16" X 2 -7/8" XO 9488' 1 — I 9-5/8" X 4 -1/2" BKR S -3 PKR, ID = 3.875" 17" TBG STUB (TAGGED 07/04/07) H 9512' I • • I 9512' H4 -112" HES X NIP, D = 3.813" I 4 -1/2" TBG, 12.6 #, 13C R-80 VA TOP, — 9545' I I I 9533' H4 -1/2" HES XN NIP, ID = 3.725" I .0152 bpf, ID = 3.958" 17" TBG, 26 #, N-80, .0383 bpf, ID = 6.276" H 9596' I 9546' I - 14 - 1/2" HES WLEG, ID = 3.958" I 6 - 1 9559' I-17" PER, ID = ? 9 -5/8" CSG, 47 #, N-80 BUTT, ID = 8.681" H 10087' I PERFORATION SUMMARY 9599' H 7" BOT PKR w / BOT HGR, ID = ? I REF LOG: SWS MEMORY CNL/GR OF 12/19/02 ANGLE AT TOP PERF: 71° @ 11290' ■ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 10435' H3-3/16" LNR STUB (07/09/07) I 1.56" 6 11290 - 11295 0 04/03/11 1.56" 6 11295 - 11315 0 04/02/11 10435' H 7" X 4 -1/2" OTIS WD PKR, ID = 4.0" I 2" 6 11340 - 11365 0 07/15/10 1 1 2" 6 11415 - 11440 0 07/15/10 1 OTIS X NIP, ID = 3.813" I BEHIND 2" 6 11470 11500 0 02/03/11 I I 10445' I — 4 -1/2" OTIS XN NIP, ID = 3.800" CT LINER 2" 6 11582 - 11612 0 02/03/11 2" 6 11660 - 11685 0 07/15/10 (MILLED 12/04/02) 2" 6 11800 - 11825 0 07/15/10 10447' I W /LEG' 2" 4 12000 - 12182 C 12/20/02 2" 4 12380 - 12694 C 12/20/02 ' 'a I 11040' I-17" MARKER JOINT I a • MILLOUT WINDOW F -08A 11066' - 11074' I TOP OF CEMENT I 10760' ' • 14,4 *� ( ) I TOP OF WHIPSTOCK H I v • •• • •, 11101' — 3 X 2 -718" XO, ID = 2.372" I BAKER MOD K BRIDGE PLUG H 11275' -'� +' 12278' — FISH- FASDRILL DEBRIS 7" LNR, 29 #, N -80 BUTT, .0371 bpf, ID = 6.184" I - 1 11303' )/ (PUSHED TO BTM 09/13/07) 3- 3/16" LNR, 6.2 #, L -80, 11101' PBTD -I 12705' 1 .0076 bpf, ID = 2.80" I2 -7/8" HES CIBP (07/15/10) I—I 11890' I •• 'v I2 -7/8" LNR, 6.16 #, L -80 STL, .0547 bpf, ID = 2.372" H 12740' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/08/76 ORIGINAL COMPLETION 07/28/10 HJW /PJC PERF/ CIBP (07/15/10) WELL: F -08A 12/21/02 DAC /KK CTD SIDETRACK (F -08A) 02/12/11 LLVPJC ADPERFS (02/03/11) PERMIT No: 2022310 07/14/07 N2ES RWO 04/04/11 RRD /PJC ADPERF (04/02- 03/11) API No: 50- 029 - 20135 -01 02/08 /07 CJN/PAG PULL BKR IBP / GL MANDREL SEC 2, T11N, R13E, 2570' FNL & 2403' FWL 04/06/07 ALHJPJC ARROW PATCH PULLED (02/07/07) 01/15/08 JCM/ PJC DRLG DRAFT CORRECTIONS I BP Exploration (Alaska) STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI4 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ -•- 202 -2310 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 ' 50- 029 - 20135 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028281 a PBU F -08A 10. Field /Pool(s): j . PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12750 feet Plugs (measured) 11890 feet (7/13/10) true vertical 9042.69 feet Junk (measured) 12278 feet (9/13/07) Effective Depth measured 12707 feet Packer (measured) 9488 10435 feet true vertical 9042.23 feet (true vertical) 7826 8408 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 30" SURFACE - 80 SURFACE - 80 Surface 2700' 13 -3/8" 72# N -80 SURFACE - 2700 SURFACE - 2700 4930 2670 Production 7981' 9 -5/8" 47# N -80 2106 - 10087 2106 - 8174 6870 4760 Liner 1507' 7 "26# N -80 9559 - 11066 7866 - 8865 8160 7020 Liner 2377' 3- 3/16 "X2- 7/8 "L -80 10363 - 12740 8359 - 9043 13450 13890 Tieback 2098' 9 -5/8" 40# L -80 SURFACE - 2129 SURFACE - 2129 5750 3090 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR80 SURFACE - 9545 SURFACE - 7858 7 "26# N -80 9512 -9596 7839 -7887 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" X 4 -1/2" BKR S -3 PKR 9488 7826 7" X 4 -1/2" OTIS WD PKR 10435 8408 • C i 4 12. Stimulation or cement squeeze summary: -7F. B 0 9 all Intervals treated (measured): 2011 .r= 'r,1 ON i ;1. arcs. C :- :tssron Treatment descriptions including volumes used and final pressure: fi AiKftej, ;Ale 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 673 46,750 74 568 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development eg " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil c, 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na = •e Lastu Title Data Manager Signat = ligg'L1 Phone 564 -4091 Date 2/8/2011 VI A,2 Form 10-404 Revised 10/2010 RBDMS FEB 0 9 ' -/O .`/ Submit Original Only i F -08A 202 -231 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F -08A 12/20/02 PER 12,000. 12,182. 9,030.7 9,035.23 F -08A 12/20/02 PER 12,380. 12,694. 9,040.23 9,042.12 F -08A 7/13/10 APF 11,800. 11,825. 9,028.18 9,027.14 F -08A 7/13/10 BPS 11,890. 12,694. 9,026.04 9,042.12 F -08A 7/14/10 APF 11,415. 11,440. 9,030.3 9,029.08 F -08A 7/14/10 APF 11,660. 11,685. 9,028.04 9,028.4 F -08A 7/15/10 APF 11,340. 11,365. 9,032.68 9,032.82 F -08A 2/2/11 APF 7 11,470. 11,500. 9,029.14 9,030.28 F -08A 2/2/11 APF 7 11,582. 11,612. 9,030.15 9,028.32 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • F -08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY rs 2/1/2011 i CTU #9 Job Scope = Drift/Tie in Log RIH w/ Memory Logging TS/2.35" JSN, tag high @ 11333' CTM (need 11700'), `POOH. RIH w/ Memory Logging TS/2.25" JSN to 11700' CTM. Log OOH, paint flag, log up to 10300' CTM. POOH, RIH with 2" x 30' of PJ HMX pert gun. * ** **Job Continued on 2/2/2011 2/2/2011 CTU #9 Job Scope = Add Perf RIH with 2" PJ2006 HMX Perf gun, Shoot from 11582 - 11612, pooh RIH w / run #2 lw/ 2" PJ2006 HMX Perf gun top shot 11470' & bottom shot 11500' .At surface guns fired, ball recovered. RDMO. Move from F -08 to F -01. * *JOB COMPLETE ** FLUIDS PUMPED BBLS 159 60/40 METH 159 TOTAL TREE = 4 CNV SAFETY : WELL> 70° @ 11295'. *** 4 -1/2" WELLHEAD McEVOY 1 CHROME TBG*** I 08A ACTUATOR = OTIS F - KB. ELEV = 54.8' BF. ELEV = 34.92' 0 I KOP = 3200' �� Max Angle = 94° @ 11575' 30" CONDUCTOR, -1 80' 4" 2072' H9-5/8" HES CEMENTER I Datum MD = 11053' 157.53 #, ID = ? % 2097' 1-14-1/2" HES X NIP, ID = 3.813" I Datum TVD = 8800' SS lc 19 -5/8" CSG, 40 #, L -80 HYDRIL 563 X0 TO TC11 I-I 615' , 2106' 1-19-5/8" PBRI • 2135' H9-5/8" HOWCO FO CEMENTER 1 9 -5/8" CSG, 40 #, L -80 TCII, ID = 8.835" I-1 2129' 1 2660' H 9 -5/8" HOWCO FO CEMENTER I 13 -3/8" CSG, 72 #, N-80 BUTT, ID = 12.347" I-1 2700' I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3795 3769 22 MMG I9 -5/8" HOWCO FO CEMENTER 1-1 4212' I • M �) 1 7638 6493 40 MMG DOME RK 20 08/23/07 Minimum ID = 2.372 "@ 11101' , ' I 9425' 1-14-1/2" HES X NIP, ID = 3.813" I 3- 3/16" X 2 -7/8" XO x --I 9488' H9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 17" TBG STUB (TAGGED 07/04/07) H 9512' I 1 1 1 9512' , -I 4 -1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, -1 9545' 1 1 I 9533' H4 -1/2" HES XN NIP, ID = 3.725" I .0152 bpf, ID = 3.958" s- 9546' H4 -1/2" HES WLEG, ID = 3.958" I 17" TBG, 26 #, N-80, .0383 bpf, ID = 6.276" I 9596' 9559' 1-17" PBR, ID = ?I 19 -5/8" CSG, 47 #, N-80 BUTT, ID = 8.681" H 10087' L 9599' HT BOT PKR w / BOT HGR, 1D = ? PERFORATION SUMMARY REF LOG: SWS MEMORY CNL /GR OF 12/19/02 • ANGLE AT TOP PERF: 87° @ 11340' Note: Refer to Production DB for historical pert data 10435' H3-3/16" LNR STUB (07/09/07) I SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11340 - 11365 0 07/15/10 2" 6 11415 11440 0 07/15/10 I I� 10435' 7" X 4-1/2" OTIS WD PKR, ID = 4.0" I ��� 2" 6 11660 - 11685 0 07/15/10 10441' 3.813" 2" 6 11800 - 11825 0 07/15/10 � 4 -1/2" OTIS X NIP ID _ BEHIND 2" 4 12000 - 12182 C 12/20/02 I 10445' I- 4 -1/2" OTIS XN NIP, ID = 3.800" CT LINER 2" 4 12380 - 12694 C 12/20/02 (MILLED 12/04/02) 10447' H 4 -1 /2" W /LEG I TOP OF CEMENT I 10760' * * 0 * 1 11040' H 7" MARKER JOINT I • TOP OF WHIPSTOCK 1 11053' ( .4� ',, MILLOUT WINDOW (F -08A) 11066' - 11074' I �•� �• 1110 —1 3- 3/16" X 2 -7/8" XO, ID = 2.372" I BAKER MOD K BRIDGE PLUG H 11275' .4.4.6.* ••••••• k " ` 12278' - FISH- FASDRILL DEBRIS 7" LNR, 29 #, N -80 BUTT, .0371 bpf, ID = 6.184" I--I 11303' )/ (PUSHED TO BTM 09/13/07) 3- 3/16" LNR, 6.2 #, L -80, 11101' PBTD -I 12705' I .0076 bpf, ID = 2.80" 12-7/8" HES CIBP (07 /15/10) I1 11890' I 41h. 2 -7/8" LNR, 6.16 #, L -80 STL, .0547 bpf, ID = 2.372" I-I 12740' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/08/76 ORIGINAL COMPLETION 07/28/10 HJW /PJC PERF/ CIBP (07/15/10) WELL: F -08A 12/21/02 DAC /KK CTD SIDETRACK (F -08A) PERMIT No: 2022310 07/14/07 N2ES RWO API No: 50- 029 - 20135 -01 02/08/07 CJN/PAG PULL BKR IBP / GL MANDREL SEC 2, T11 N, R13E, 2570' FNL & 2403' FWL 04/06/07 ALH/PJC ARROW PATCH PULLED (02/07/07) 01/15/08 JCM/ PJC DRLG DRAFT CORRECTIONS 1 BP Exploration (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS JUL 1 9 2Q1C! 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ & ,_ IA Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ AQCPA~~aA* Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ~ Exploratory ^ 202-2310 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-20135-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number ~ ADLO-028 81 '' PBU F-08A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12750 feet Plugs (measured) 11890' 7/13/10 feet true vertical 9042.69 feet Junk (measured) 12278' 9/13/07 feet Effective Depth measured 12707 feet Packer (measured) 9488 10435 true vertical 9042.23 feet (true vertical) 7826 8408 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" SURFACE - 80 SURFACE - 80 Surface 2700 13-3/8" 72# N-80 SURFACE - 2700 SURFACE - 2700 4930 2670 Production 7981 9-5/8"47# N-80 2106 - 10087 2106 - 8174 6870 4760 Liner 1507 7"26# N-80 9559 - 11066 7866 - 8865 8160 7020 Liner 2377 3-3/16"X2-7/8" L-80 10363 - 12470 8359 - 9043 13450 13890 Tieback 2098 9-5/8" 40# L-80 SURFACE - 2129 SURFACE - 2129 5750 3090 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR80 SURFACE - 9545 SURFACE - 7858 7" 26# N-80 9512' - 9596' 7839' - 7887' Packers and SSSV (type, measured and true vertical depth) 9-5/8"X4-1/2" BKR S-3 PKR 9488 7826 7"X4-1/2" OTIS WD PKR 10435 8408 12. Stimulation or cement squeeze summary: Intervals treated (measured): g~ {~ (1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/16/2010 vain w-•rvv rycviacu ~icvva~~~~ ~~~ ~ O ~~~ // ~ ~/ /~ vuvnm vnyniai vnry F-08A 202-231 PERF ATTA(_HMFNT LJ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F-08A 12/20/02 PER 12,000. 12,182. 9,030.7 9,035.23 F-08A 12/20/02 PER 12,380. 12,694. 9,040.23 9,042.12 F-08A 7/13/10 APF 11,800. 11,825. 9,028.18 9,027.14 F-08A 7/13/10 BPS 11,890. 12,694. 9,026.04 9,042.12 F-08A 7/14/10 APF 11,660. 11,685. 9,028.04 9,028.4 F-08A 7/14/10 APF 11,800. 11,825. 9,028.18 9,027.14 F-08A 7/15/10 APF ~ 11,340. 11,365. 9,032.68 9,032.82 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • . F-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 7/6/2010 "** WELL SHUT IN ON ARRIVAL *'"" (Pre Coil adperf) DRIFT TO DEV. W/2.23" CENT @ 11,335' SLM (no sample) E HUNG UP @ 11,264', 11,250', AND 11,200' SLM *""WELL S/I ON DEPARTURE, DSO NOTIFIED OF STATUS**" ', 7/12/2010iCTU #8 w 1.75" ct Job scope depth log set CIBP & perforate.Road from Z-38 to ~ F08 MIRU «<Job in progress»> ~ ~ 7/13/2010~CTU #8 w 1.75" ct Job scope depth log set CIBP & perforate. «<InterAct is publishing»>RIH with SLB GR/CCL log. Log from 12100 to 10250 ft. Paint flag ~ at 11,900. POOH. RIH with HES 2 7/8"CIBP. Set plug at 11,890 ft. RIH w / 25' ' of 2" 6 spf-60 deg-PJ2006 HMX 6.5grm guns. ToP shot 11800' bottom shot 11825."**JOB CONTINUED*"* 7/14/2010!CTU #8 w / 1.75" ct Job scope Perforating. «<InterAct is publishing»>At surface with gun run #1 all shots fired & recovered 1/2" ball. Wittiness weekly i BOP test. Good BOP test. Cut 150' of coil for pipe management .RIH with gun ~ i ~ run #2. Perforate interval #2 (11660-11685 ft) . At surface,confirm guns fired, recover 1 2" ball. RIH with gun run #3. Perforate interval #3 (11800- j 11825)«<Job in progress»> ~ _ _ __ _ _ ~~ 7/14/2010~CTU #8 w / 1.75" ct Job scope Perforating. «<InterAct is publishing»>At ':surface with gun run #1 all shots fired & recovered 1/2" ball. Wittiness weekly BOP test. Good BOP test. Cut 150' of coil for pipe management .RIH with gun 'run #2) 2" 6spf-60-deg-PJ2006 HMX guns.. Perforate interval #2 (11660- ~ 11685 ft) . At surface,confirm guns fired, recovered 1/2" ball. RIH with gun run #3 )( 2" 6spf-60-deg-PJ2006 HMX guns.. Perforate interval #3 (11800-11825) 'At surface confirmed guns fired and recovered 1/2" ball )RIH w /gun run #4( 2" 6spf-60-deg-PJ2006 HMX guns.. «<Job in progress»> ~ _ ~ ~__ .~ 7/15/2010 CTU #8 w / 1.75" ct Job scope Perforating. «<InterAct is publishing»> RIH w ~! gun run #4( 2" 6spf-60-deg-PJ2006 HMX guns..Perforating interval top shot 11340' bottom shot 11365'. At surface confirmed all shots fired and recovered 1/2" ball. «<Job is complete»> FLUIDS PUMPED BBLS 313 1% KCL W/SAFELUBE 38 60/40 METH 1 DIESEL 352 Total TREE _ 4" CNV WELLHEAdS-5/8" McEVOY ACTUATOR OTIS KB. ELEV = 54.8' BF. ELEV = 34.92' KOP = 3200' Max Angle = 94° @ 11575' 30" CONDUCTOR, 80' Datum MD = 11053' 157.53#, ID = ? Datum TV D = 8800' SS 9-5/8" CSG, 40#, L-80 HYDRIL 563 XO TO TC11 615' 9-5/8" CSG, 40#, L-80 TCII, ID = 8.835" 2129 13-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" 270( 9-5/8" HOWCO FO CEMENTER ~ 4212' Minimum ID = 2.372"@ 11101' 3-3/16" X 2-7/$" XO 7" TBG STUB (TAGGED 07/04/07} 9512' 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 7" TBG, 26#, N-80, .0383 bpf, ID = 6.276" 9-5/8" CSG, 47#, N-80 BUTT, ID = 8.681" PERFORATION SUMMARY REF LOG: SWS MEMORY CNUGR OF 12/19/02 ANGLE AT TOP PERF: 89° @ 12000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12000 - 12182 O 12/20/02 2" 4 12380 - 12694 0 12120/02 (TOP OF CEMENT I OF WHIPSTOCK I-I 11053' BAKER MOD K BRIDGE PLUG 7" LNR, 29#, N-80 BUTT, .0371 bpf, ID = 6.184" F-08A 3-3116" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" SAFETY :WELL > 70° @ 11295'. *** 4-1 /2" CHROM G'`** 2072' -j 9-5/8" HES CEMENTER 2097' 4-1/2" HES X NIP, ID = 3.813" 2106' 9-5/8" PBR 2135' 9-5/8° HOWCO FO CEMENTER 2660' 9-5/8" HOWCO FO CEMENTER GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3795 7638 3769 6493 22 40 MMG MMG DOME SO RK RK 16 20 08(23107 08!23!07 9425' ~-~4-1/2" HES X NIP, ID = 3.813" 9488' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9512' 4-1/2" HES X NIP, ID = 3.813" 9533' 4-1/2" HES XN NIP, ID = 3.725" 9$~' --~4-1/2" HES WLEG, ID = 3.958" 9559' 7° PBRiD = ? 95~ 7" BOT PKR w / BOT HGR, ID = ? 10435' -j 3-3(16" LNR STUB (07!09107} 10435' 7" X 4-112" OTIS WD PKR, ID = 4.0" 10441' -~4-1/2" OTIS X NIP, ID = 3.813" BEHIND 10445' 4-1l2" OTIS XN NIP, ID = 3.800" CT LINER (MILLED 12!04/02) 1044T 4-112" W/LEG 11040' -{7"MARKER JOINT MILLOUT WINDOW (F-08A) 11066' - 11074' 11101' 3-3/16" X 2-7/8" XO, ID = 2.372" 12278' FISH- FASDRILL DEBRIS (PUSHED TO BTM 09/13/07} 11101' PBTD 12705' 2-7/8" LNR, 6.16#, L-80 STL, .0547 bpf, ID = 2.372" DATE REV BY COMMENTS DATE REV BY COMMENTS 09/08/76 ORIGINAL COMPLETION 12!21/02 DAC/KK CTDSIDETRACK(F-08A) 07!14/07 N2ES RWO 02/08(07 CJN/PAG PULL BKR IBPi GL MANDREL 04106/07 ALWPJC ARROW PATCH PULLED (02/07/07) 01/15108 JCNU PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: F-08A PERMIT No: 2022310 API No: 50-029-20135-01 SEC 2, T11 N, R13E, 2570' FNL & 2403' FWL BP Exploration (Alaska) OS/05/09 ~~a~~~~~~~~~~ NO. 5329 ~laska Data F~ Consulting Services ~~ r., . ~, ~~y ~ Company: State of Alaska ?_525 Gambell Street, Suite 400 '' +>>'~~ f~:~:~:+cs« -~,. ~J ~, •- ;i _ U~~~` Alaska Oil & Gas 1'ons Comm slnchorage, AK s95oa-za3a Attn: Christine M~3hnken f~'9~n~: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 951501 lNell Job # Log Description Date BL Color CD ~ P~ P-21 ~ AWJI-00039 MEM PROD PROFILE - 07/14/09 1 1 P2-12 AXWS-00013 PRODUCTION PROFILE - - 07/12l09 1 1 C-36A AY1M-00017 IBP SET RECORD W/CROSSFLOW G Y 07/08/09 1 ~ ~ VV-45 AXBD-00035 MEM TEMP & PRESS SURVEY ~ c~ 07/09/09 1 1 H-13A B2NJ-00009 MCNL _ L G/ C 06/17/09 1 1 F-08A AY1M-00028 RST G 07/01/09 1 1 01-95 AY3J-00038 CH EDIT P C TBG PUNCH/JEWELRY LOG 07/10/09 1 _.._._ ~ -- O c // ~A GACC A~`ILAIA\R/l C11!!C ~C /~CII'fT oV t~~A~~~ ~~w ~ _.._ __-_-_" _ -_ ___.""""~~.".".~..~.~..........v..rvv• ~ ~r~v~~ ~v. BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petro4echnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 F_. Benson Bivd. Anchorage, AK 99503-2838 i ~ U as a il & Gas Con~ (', 1. Operations Performed: AnchoraHe o Abandon ~ Repair Well o Plug Perforations o Stimulate ORe-Enter Suspen ed Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 202-231 - 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20135-01-00 7. KB Elevation (ft): 54.80' , 9. Well Name and Number: PBU F-oSA - 8. Property Designation: 10. Field I Pool(s): ADL 028281 - Prudhoe Bay Field / Prudhoe Bay Pool . 11. Present well condition summary Total depth: measured 12750 . feet true vertical 9043 ( feet Plugs (measured) 11900 Effective depth: measured 12707 feet Junk (measured) None true vertical 9042 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 30" 80' 80' Surface 2700' 13-318" 2700' 2700' 4930 2670 Intermediate Production 7981' 9-5/8" 2106' - 10087' 2106' - 8174' 6870 4760 Liner 1507' 7" 9559' - 11066' 7866' - 8865' 8160 7020 Liner 2377' 3-3/16" x 2-7/8" 1 0363' - 12740' 8359' - 9043' 13450 13890 Tieback 2098' 9-5/8" 2129' 2129' 5750 3090 SCANNED AUG 2 02007 Perforation Depth MD (ft): 12000' - 12694' Perforation Depth TVD (ft): 9031' - 9042' 4-1/2",12.6# 13Cr80 9546' Tubing Size (size, grade, and measured depth): ll. I -80 R. ' _ 1 nA.d7' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' packer; 9488'; 7" x 4" Otis WD Packer 10427' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut 3-3/16" Liner at 10429'. Cut and pull 7" tubing. Pull 9-5/8" x 10-3/4" casing. Run new 9-518",40#, L-80 tieback. Cement tieback with 142 Bbls Class 'G' (797 cu ft /681 sx). Pull 3-3/16" Liner from cut at -10429'. Run new Chrome Tubing. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Shane Gagliardi, 564-5251 307 -047 Printed Name Terrie Hubble Title Technical Assistant Signature /ff7 ^ f\ ì f? . ~ Phone 564-4628 o o/D9~ Prepared By Name/Number: Date '17 Terrie Hubble, 564-4628 . STATE OF ALASKA . ~RECEIVED ALASKA OIL AND GAS CONSERVATION COM SIONIt-c r; REPORT OF SUNDRY WELL OPERATIONS ~(~ AUG 0 9 2007 AI k 0 ion Form 10-404 Revised 04/2006 Submit Original Only ORIGINAL RBDMS 8FL AUG 1 6 2007 Digi~al Wellfile . . Page 1 of 2 Well: F-08 Well Events for SurfaceWell - F-08 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC1 -> F -> F-08 Date Range: 03/Feb/2007 to 22/Jun/2007 Data Source(s): AWGRS Events Source Well Date Description AWGRS F-08A 06/22/2007 T/I/0==0/0/20 Temp==SI CMIT TxIA INCOMPLETE to 3000 psi (Pre-Rig Sliding Over Well) - Pressured up IA from 0 psi to 2500 psi w/9 bbls diesel. OAP increased from 20 psi to 300 psi. Monitor pressures for 20 min OAP increased to 500 psi. lAP decreased 110 psi to 2390 psi. Bleed OAP to 70 psi in 3 min. OAP increased 60 psi to 130 psi in 5 min post bleed. Bled all pressures to 0 psi. Job Canceled for 2 ES site prep work (per rig rep). Normal all valves, tag well & notify operator & 2ES rep. Final WHP's==O/O/O AWGRS F-08A 06/22/2007 PULLED BPV AFTER THE RIG MOVED ON THE WELL AWGRS F-08A 06/17/2007 T/I/O == 0/0/0. MIT OA PASSED to 500 psi. Pumped 3.5 bbls crude to achieve test pressure. Lost 40 psi in the 1st 15 min and 0 psi in the 2nd 15 min, for a total loss of 40 psi in 30 min. Bled OA back to 0 psi. Final WHP's == 0/0/0. AWGRS F-08A OS/21/2007 set bpv / pre rig AWGR~ F-08A 05/18/2007 T/I/O == 5/6/4. S1. Hardline rigged-up on TBG & IA to F-38 flowline from circ-out. Bleed WHPs to 0 psi (pre-RWO). Bleed WHPs to bleed trailer to 0 psi (3 hrs). Final WHPs == Vac/Vac/O. AWGRS F-08A 05/16/2007 ***WSR continues from 5/15/07*** Bleed pressures to zero. Final WHP== 0/0/0. A wGRS F-08A 05/15/2007 T/I/O == 1060/1020/1040. Pre RWO Circ Out. Pump 10 bbls neat, 969 bbls 1 % KCL, and 141 bbls diesel into the IA. Take TBG returns through jumper to F-38's flowline. U-Tube Tx IA. Freeze protect F-38's flowline with WOA neat/crude recipe and flush it with 12 bbls diesel. ***WSR continues on 5/16/07*** AWGR~ F-08A 05/13/2007 T/I/O== 1060/1060/1060. Temp== S1. Monitor (Eval High OAP). AL spool dropped. Unable to access cellar to get OAP. Need confined space permit. AWGJ3,S F-08A 04/06/2007 T/I/0==300/250/0 Assist E-Line - Stuck in Hole (Pre RWO) Pumped 7 bbls 120* crude down TBG to help free up E-Line. FWP==2220/2220/0 A WGRS F-08A 04/06/2007 ***CONTINUED FROM APRIL 5, 2007*** AT SURFACE WITH CHe. BECAME STUCK ACROSS MASTER/SWAB VALVES IN TREE. REQUIRED PUMPING FROM LRS TO FREE TOOL. LOWER CHEMICAL TUBE IN CUTTER FOUND TO BE DAMAGED FROM CHEMICAL REACTION CAUSED DURING FIRING SEQUENCE. JOB COMPLETE. **** WELL LEFT SHUT-IN ***** AWGRS F-08A 04/05/2007 ***CONTINUED FROM APRIL 5, 2007*** UNABLE TO GET TO DEPTH WITH CHEM CUTTER, STAND-BY FOR DECISION. POOH WITH CHEM CUTTER. RIH WITH STRING SHOT. FIRE SECOND STRING SHOT WITH GR FOR CORRELATION AT 9466' - 9478'. RIH WITH CHEM CUTTER, CUT 7" TBG AT 9488', POOH. AT SURFACE WITH CHEM CUTTER BUT UNABLE TO PICK UP INTO LUBRICATOR, HUNG UP INSIDE WELLHEAD. ***CONTINUE JOB ON APRIL 6,2007 WSR*** AWGRS F-08A 04/04/2007 WHP: 0/0/0 RIH WITH 2.5" SUPER CUTTER. CUT 3 1/16" LNR AT 10429' RIH WITH TBG PUNCHER, SHOT INTERVAL: 9449'-9451' RIH WITH 2 X 12' STRINGSHOT, SHOT INTERVAL 9478'-9490' ***CON'T ON 05/04/07*** 8 WGRS F-08A 04/03/2007 CTU # 9, 16167' 1. 75" CTU, *Continued from 04/02/07* Continue trip in hole, Set FasDrill @ 11900' CTM ( Pre-Jet cut). POOH and perform CMIT-TxIA to 3000 psi Pass. RDMO. Notified Pad Operator of well status ***Job Completed*** Final T/I/O==O/O/O. £o.WGRS F-08A 04/02/2007 CTU #9 w/1617' 1.75" CT. Drift to 12000'. Circ-Jet with 2% KCL (11850'-11950'). Set a FasDrill @11900' (Pre Jet Cut) and do CMIT-TxIA to 3000 psi. CTU#9 backed into well house, Wells Operations supervisor informed, GPB HSE advisor informed, MCC security was informed. HSE advisor and Security came to Pad for investigation. Finished up rigging up and RIH with drift run with 2.2" Nozzle. ~et from 11400' to 12000'. TOOH to pick up FasDril1. ****Continue on 04/03/07*** AWGRS F-08A 04/02/2007 T/I/0==110/0/20. Temp==S1. T,I,O FL (CTU). TBG FL @ 1080'. IA FL near surface. OA FL near surface. AWGRS F-08A 03/20/2007 ***JOB CONTINUED FROM 19MAR2007*** RU & LOG SCMT FROM 10450 - 11075 FT. FOUND TOC AT 10450 FT. CABLE STUCK IN FLOW TUBES AT 820 FT. CLOSE BOPS, FIX CABLE, POOH. LARGE AMOUNTS OF PARAFFIN FOUND ON THE WIRE AND TOOL. CANCELLED JOB AND RDMO. ***JOB INCOMPLETE*** AWGRS F-08A 02/17/2007 T/I/O== 0/0/0 Visual to check out well head for External checks on well head flange. Tubing spool has external check Casing spool has external check not known if internal are pulled A W_GK$ F-08A 02/09/2007 ***CONTINUE FROM 2/8/07*** DRIFTED TO 2 7/8" XO @ 11,126' SLM W/ 2.69" CENT. 2' STEM, 2.69" CENT ***WELL LEFT SI NOTIFY PAD OP*** 8 WGRS F-08A 02/09/2007 T/I/0==140jVAC/0+ Temp==SI AL dropped TBG & IA FLs (Pre-RWO). TBG FL @ 1200' (45 bbls). http://digitalwellfile.bpweb.bp .comIW ellEvents/Home/Defaul t.aspx 8/7 12007 Digit,al Wellfile AY'lGRS F-08A 02/08/2007 AWÇ¿8.S F-08A 02/07/2007 AWGRS F-08A 02/06/2007 A~YGgS F-08A 02/05/2007 AWGRS F-08A 02/05/2007 AWGRS F-08A 02/05/2007 í\ IN ~ß~ F-08A 02/05/2007 AWGBS F-08A 02/04/2007 AWGRS F-08A 02/04/2007 AWGRS F-08A 02/03/2007 . . Page 2 of 2 IA FL @ 1086' (28 bbls). ****CONT. FROM 2/7/07**** PULLED LOWER ANCHOR FROM 2036' SLM RAN IBP EQ. SLEEVE TO 10820' SLM, PRESSURE CAME UP 50 PSI ON TBG. RAN 2" SB W/ EQ. SLEEVE, LATCH IBP @ 10820' SLM, RECOVERED IBP W/ ALL RUBBERS ****CONT. ON 2/9/07 WSR**** *** OFF WEATHER HOLD, CONT' TO FISH OUT STRADDLE*** LATCHED BAITED SPEAR, FISHED OUT REMAINING SECTION OF UPPER STRADDLE FROM 4010' SLM RAN WFD PULLING TOOL & LATCH BOTTOM ANCHOR @ 4037' SLM. JAR FOR 20 MIN. PULLED FREE, CURRENTLY POOH W/ LOWER ANCHOR ****CONT. ON 2/8/07 WSR**** ****CONT. FROM 2/05/07**** PULLED WEATHERFORD PKR FROM SSSV NIPPLE, RECOVERED ONLY 46" OF UPPER POGLM ASSY. RAN 5-1/2" GS BAITED SPEAR (3.078 GRAPPLE), SAT DOWN @ 4020 SLM. DID NOT LATCH, JARRED DOWN FEW TIMES TO PLANT, SHEARED GS AND LEFT SPEAR IN HOLE LAYED DOWN EQUIP DUE TO HIGH WINDS ***CONT ON 02/07/07**** **** WELL SHUT IN ON ARRIVAL *** RUN IGS IMPACT MEMORY TOOL TO EVALUATE SPRING JARS VS OIL JARS. PULLED WEATHERFORD POGLM @ 4020' SLM AND MOVED UP TO SSSV NIPPLE. ATTEMPTING TO WORK THROUGH. ****CONT. ON 1/6/07 WSR**** T/I/0==BPV/8/5. Temp==S1. WHP's (post-PPPOT, pre rig). lAP increased 8 psi overnight. OAP increased 5 psi overnight. Unable to get TBGP due to BPV in hole. SET BPV , WELLHEAD REPAIR, BPV WAS PULLED AFTER THE WELLHEAD WORK WAS COPLETED Repaired stud bolts isssues on THA x TS (5). Tested Apadpter flange -passed. T/I/O == 50/0+/0+. Temp == S/1. AL spool dropped. Bleed WHPs (pre-PPPOT, pre-Rig). From yesterday TBGP increased 20 psi, lAP and OAP unchanged, Bled TBGP to tank from 50 psi to 0 psi in 2 hrs. Maintained open bleed on TBG and IA for Cameron's TBG and IC hanger PPPOTs. FWHPs == 0/0/0. T/I/0==5/0/0, PPPOT-T (PASS), PPPOT-IC (PASS). RWO prep. McEvoy 2 step, Casing head: 13 3/8" x 13 5/8" 5m w/ (1) 3" McEvoy model C OA valve. Tubing head: 135/8" 5m x 13 5/8" 5m w/ (1) 3" McEvoy model C IA valve. Tubing head adapter: 13 5/8" 5m x 7" 5m 4 seal. Tree: 7" Cameron w/ Otis actuator. PPPOT-T: Opened test void bleeder screw to bleed void to o psi (fluid/gas). Removed internal check and installed external Alemite check valve. Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, no change in pressure after 30 min PASS. Functioned all LDS, all moved freely no signs of bent or broken pins. PPPOT-IC: Open test void bleeder screw to bleed void to 0 psi (fluid), remove internal check and install external Alemite check valve. Function LDS previously backed out, the rest moved freely with no sign of bent or broken pins. pumped through void until returns were achieved. Pressured void to 3500 psi for 30 min test, lost 200 psi in 30 min PASS. T/I/O == 800/30/30. Temp == S/r. AL spool dropped. IA FL Bleed WHPs to 0 psi (pre-PPPOT). Initial TBG FL @ 3375'. Bled TBGP to production from 800 psi to 350 psi in 2 hrs, Bled TBGP to tank from 350 psi to 30 psi in 3.25 hrs. Post 30 min monitor TBGP unchanged. TBG FL unchanged during bleed. Bled lAP to tank from 30 psi to 0 psi in 30 min. Post 30 min monitor lAP increased to 0+. Bled OAP to tank from 30 psi to 0 psi in 20 min. Post 30 min monitor OAP unchanged. FWHPs == 30/0+/0. http://digitalwellfile.bpweb.bp .comIW ellEvents/Horne/Default.aspx 8/7/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I . . F-08  F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES 6/22/2007 7/11/2007 2ES Spud Date: 3/24/1974 End: 7/6/2007 Start: Rig Release: Rig Number: 6/22/2007 14:00 - 16:00 2.00 MOB P PRE Move Rig Off of F-09 and clean up around cellar Attempt to test IA / Tubing with Little Red Services Unable to Test Tubing/lA, Communication between IA and OA 16:00 - 22:30 6.50 MOB P PRE Prepare pad for rig on F-08a I -Unable to prep site due to rig sitting in front of F-08 I (Accept Rig @ 21 :00 Hrs, Back up 6 Hrs for Site Prep) 22:30 - 00:00 1.50 MOB P PRE Spot mats, Lay Herculite and spot Rig over F-08 6/23/2007 00:00 - 03:00 3.00 MOB ,P PRE Spot Pits, Spot Cutting Tank, Hook up Interconnects and service Lines 03:00 . 03:30 0.50 WHSUR P DECOMP Pre Spud meeting 03:30 - 04:30 1.00 I WHSUR P DECOMP Install Secondary Annulus valves, Run Lines to Tiger Tank 04:30 - 05:30 1.00 WHSUR P DECOMP Pull BPV with Drill Site Maintenance 05:30 - 07:30 2.00 WHSUR P DECOMP Displace Diesel From Tubing and IA -apx 160 bbls of and 130 bbls of Seawater 107:30 - 09:30 I -4 bpm / 350 psi 2.00 WHSI DECOMP Dry Rod TWC -Test from above to 3500 psi for 10 min, Good Test 2.50 I WHSUR P -Test from below to 1000 psi for 10 min, Good Test 09:30 - 12:00 DECOMP Nipple Down Tree and Adaptor Flange 12:00 - 15:00 3.00 BOPSU P DECOMP Nipple up spacer spool and BOP's 15:00 - 21 :00 6.00 BOPSU P DECOMP PJSM on Testing BOP's I -Test BOPE with 7" test joint, 250 low, 3500 psi high, holding each test for 5 min. Tested Annular to 250 Low and 2500 High Tested Hyd. & Manual choke to 250 low, 1500 high Performed Koomey Test Tested Gas alarms & PVT. Test witnessed by BP WSL Dave Newlon, NAD TP Jon Castle, Witness of test waived by Bob Noble, AOGCC. -During Test Lower Ram Bonnet seal start to leak 21 :00 - 21 :30 0.50 BOPSU DECOMP PJSM on changing Ram Bonnet Seal 21 :30 - 00:00 I -Change Seal 2.50 BOPSU DECOMP Finish Testing Bope's 6/24/2007 00:00 - 01 :00 1.00 BOPSU DECOMP Finish Testing Lower IBOP and Upper IBOP Valve Test witnessed by BP WSL Dave Newlon, NAD TP Jon Castle, 01 :00 - 02:00 02:00 - 04:00 1.00 DHB 2.00 PULL Witness of test waived by Bob Noble, AOGCC. DECOMP Rig up DSM lubricator and Pull TWC DECOMP PJSM on Pull Tubing Make up landing joint and 7" IJ4S crossover -screw in to 7" hanger P P Back out lock down screws Pull up to 300k 2x Pull up to 315k and pipe came free PUW = 265k Pull Hanger up to Rig floor And Remove Control Line from Hanger Back out of Landing Joint, Well out of Balance Screw back in to Landing joint and pump weighted pill Printed: 7/24/2007 5:05:56 PM . . BP Operations Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/22/2007 7/11/2007 2ES Spud Date: 3/24/1974 End: 7/6/2007 Task Code 6/24/2007 04:00 - 05:00 1.00 PULL P IDECOMP Lay Down Hanger and Landing Joint -Make up crossover, surface safety valve and circ. head 05:00 - 06:00 1.00 PULL P , DECOMP Circulate 100 bbls of clean seawater 5 bpm @ 230 psi 06:00 - 13:00 7.00 PULL P DECOMP Pull and Lay down 7" TC4S 26# Tubing with control lines from surface to SSSV @ 2043' -20 40k Overpulls, -Pull 125k overpull to get SSSV through collapse Thermo Case @ +1- 80' RKB -Control line balled up in places, -2 clamp pieces, 1 clamp pin and 3 centralizers blades missing Recovered 100 bands 2 partial bands 45 full clamps and 6 partial clamps 13:00 - 14:00 1.00 PULL P DECOMP Rig Down Spooler and clear floor of third party gear 14:00 - 21 :00 7.00 PULL P : DECOMP Pull and Lay down 220 jts 7" TC4S 26# Tubing 21 :00 - 21 :30 0.50 PULL P DECOMP Diesel 1 Seawater flowing over tubing, Circ. Diesel/ Dirty Seawater out 21 :30 - 22:30 1.00 PULL P DECOMP Finish Pulling and Laying down 7" TC4S 26# Tubing - 237 joints laid down and 1 cut joint 32.12' 22:30 - 23:30 1.00 PULL P DECOMP Rig Down Tubular handling equipment -Clean and clear Rig Floor 23:30 - 00:00 0.50 BOPSUR P DECOMP PJSM, Change Top Set of Rams to 103/4" 6/25/2007 00:00 - 01 :00 1.00 BOPSU~ P DECOMP Change out Top Rams to 10 3/4" 01 :00 - 02:00 1.00 BOPSU P DECOMP After draining stack we discovered 3 pieces of control line, 2 BOPSUJ N SS bands and 1 piece of centralizer band stuck in the bottom of Annular Rubber and in the Ram cavities 02:00 - 05:00 3.00 SFAL DECOMP Install Test Plug and Run In LOS -Unable to get Plug to Seat, Run in all of the LOS -Attempt to test Lower Rams 2x, Low Pressure Bleeding oft -BOLDS, Pull Test plug to Rig floor, No Visable Damage to plug -Change Plugs and retest, No Go 05:00 - 06:00 1.00 BOPSU N SFAL DECOMP Wait on Cameron to bring New Test Plug 06:00 - 09:30 3.50 BOPSU P DECOMP M/U New Test Plug, Test Lower Rams with 4" test joint -250 psi low /3500 psi high -Test Annular to 250 low /3500 high -Test 4" Surface safety valve and dart valve -Pull Test Plug and Install wear bushing 09:30 - 13:30 4.00 FISH P DECOMP M/U 8.375" Swedge BHA, Tag @ 44' -Attempt to Swedge with 1 stand of DC's, No Go -Pick 9 Dc's and 8 1/4" Swedge -Swedge Thermo Case from 44' - 46' 13:30 - 14:00 0.50 FISH N DPRB DECOMP Consult with the Anchorage Rig Team and revise Plan Forward --Change of plan to set Fas Drill Plug instead of RBP. 14:00 - 14:30 0.50 FISH P DECOMP Change out swedge to 8.00" 14:30 - 16:30 2.00 FISH P DECOMP RIH with 8.00" Swedge and swedge from 46 - 82' -Work throrough 4x, backream 2x @ 25 rpm / 6k Ran in to 209', O.K. 16:30 - 17:30 1.00 FISH P DECOMP POH and UD Swedge, Stand Back Collars and clear floor 17:30 - 18:30 1.00 FISH P DECOMP Inspect Derrick and Draw Works 18:30 - 20:30 2.00 CLEAN P DECOMP Make up Wash Sub and RIH picking up 4" Drill Pipe 20:30 - 21 :00 0.50 CLEAN P DECOMP Wash from @2613" => 2716' -500 gpm / 600 psi Printed: 7/24/2007 5:05:56 PM . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES k Start: Rig Release: Rig Number: 6/22/2007 7/11/2007 2ES Spud Date: 3/24/1974 End: 7/6/2007 6/25/2007 20:30 - 21 :00 0.50 CLEAN P DECOMP -70 rpm / 700 fVbs 21 :00 - 22:00 1.00 CLEAN P DECOMP Slip and Cut Drilling Line 22:00 - 23:00 1.00 CLEAN P DECOMP . POH with Wash tool, monitor well, static 8.5 ppg in / out 23:00 - 00:00 1.00 DHB P DECOMP PJSM with Schlumberger SWS and NAD rig Crew I -Spot Wireline Truck -R/U Sheaves and Wireline Equipment I Run HES Fas Drill Plug (OD 7.75") Sat Down @ 2057', Pulled 6/26/2007 00:00 - 02:00 2.00 DHB P DECOMP up easy, plug hung, work down, Pulled up easy and plug came up, RIH easy and plug sat down again @ 2057' -POH for Gauge ring 02:00 - 03:00 1.00 DHB N DPRB DECOMP Unable to get a proper size gauge ring. -Only sizes available 8.05" & 6 .75", Need 7.75" to 8.00" Rig down SWS and ready floor for wiper trip 03:00 - 05:00 2.00 FISH C DECOMP Make Up 8.00" Swedge BHA and RIH to 2730' 05:00 - 05:30 0.50 FISH C DECOMP Circ @ 500 gpm I 580 psi 05:30 - 06:00 0.50 FISH C DECOMP POH to 2076 06:00 - 06:30 0.50 FISH C DECOMP Wash From 2030 - 2076 500 gpm / 580 psi Monitor hole, static 8.5 ppg seawater inlout 06:30 - 08:00 1.50 FISH C DECOMP POH and Lay Down Swedge BHA 08:00 - 10:00 2.00 FISH P DECOMP Rig SWS, Make Up9 5/8" 3 strand String Shot -RIH and shoot @ 2106' - 2118' -POH and R/U to run Inflatable Bridge Plug 10:00 - 11 :00 1.00 DHB P DECOMP RIH with IBP, Set @ 2633', Element @ 2644' 11 :00 - 14:30 3.50 DHB !P I DECOMP Inflate Packer and test to 1000 psi for 10 minutes, Good Test 14:30 - 15:00 0.50 DHB f DECOMP POH with Running tool and Rig Down SWS wireline 15:00 - 16:00 1.00 DHB P DECOMP Dump Sand Down on top of IBP 16:00 - 16:30 0.50 BOPSU P DECOMP Pull Wear Bushing 16:30 - 22:30 6.00 BOPSU P DECOMP N/D BOP, -Remove Tubing Spool -Install slip handles and wire up casing slips / seal assembly -N/U spacer Spool and BOP's -N/U HCR valve on Kill line -Install riser and turnbuckles 22:30 - 23:00 0.50 BOPSU P DECOMP Test Spool flanges and BOP Body Test to 1000psi -Pressure bleeding off to OA (13318 x Thermo Case /10 3/4 annulus) 23:00 - 00:00 1.00 CASE P DECOMP M/U Spear assembly and spear 9 5/8" x 11 3/4" Thermo Case -Back out Lock Down Screws -Pull out of PBR 1.001 CASE I -Pulled @ 227,000 to 242,000 6/27/2007 00:00 - 01 :00 P DECOMP POH with Spear assembly and 9 5/8" x 11 3/4" Thermo Case -Pulled @ 227,000 to 242,000 Free Wt. 140,000 Remove Seal and slip assembly from 9 5/8" Pup joint Thermo Case Split at top seam and Collapsed Set Slips and Remove 10' Pup Joint, -Threads on Thermo Case Are 9 5/8" Hydril Triple Seal/ not BTC 01 :00 - 05:30 4.50 CASE N ¡WAIT DECOMP Mobilize tool service to retrieve Triple Seal Pup Joint or Crossover from Cold Storage Pad -Unable to Find any Crossovers or Pup joints to get back to 9 5/8" Triple Seal Threads, Printed: 7/24/2007 5:05:56 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/22/2007 7/11/2007 2ES Spud Date: 3/24/1974 End: 7/6/2007 Shorten Spear (UD all Subs Except 9.625 Grapple and Lift Sub) -Lay Down 2 Joints of 9 518" ThermoCase II with Spear 07:00 - 09:00 2.00 CASE P DECOMP Rig Up Little Red pumping, PT line to 3500 psi -Rev Circ.1 0 bbls of Heated diesel (120 deg) down 13318 x 10 3/4" annulus -Pack off in the ThermoCase failed -Rig Down Little Red and blow down lines -Let wellbore fluids Equalize 09:00 - 10:30 1.50 CASE P DECaMP Engage Spear in third joint of ThermoCase -Pull to Rig Floor and Lay Down Final Joint of ThermoCase -RID Spear And CIO to 10 3/4" Handling equip. 10:30 - 15:30 5.00 CASE P DECOMP UD 45 joints of 10 3/4" 55.5# N-80 Seal Lock Casing -Lay Down 2 Joints of 9 5/8" 47# N-80 BTC csg -Lay Down 9 5/8 PBR Seal assembly -No Problems Breaking out, Normal breakout torque 15:30 - 17:00 1.50 CASE P DECOMP R/D Casing Handling Equipment and clean Floor 17:00 - 17:30 0.50 CASE P DECOMP Pressure Test 133/8" csg, 133/8" Shoe, PBR and 9 518" down to IBP @ 2644' Test to 1000 psi, Good Test 17:30 - 18:30 1.00 BOPSU P DECOMP Change Upper Rams to 9 518" Rams 18:30 - 19:30 1.00 BOPSU P DECaMP R/U and Test Door Seals to 250 psi Low and 3500 psi High, -Test held for 5 minutes for each test, Good Test 19:30 - 22:30 3.00 CLEAN P DECOMP Pick up 13 3/8 and 9 5/8" Casing Scraper BHA -Spaceout 13 3/8" scraper 477' back of bit 22:30 - 00:00 1.50 CLEAN P DECaMP RIH from 765' to 2595' -Tagged up @ 2146' and work down (FOC ?), -35 k to get through, PIU and RIH without issues -Tagged PBR @ 2116', sat 25k down PUW - 85k SOW - 85k 6/28/2007 00:00 - 00:30 0.50 CLEAN P DECOMP Rig up to Circulate Heated Diesel to Clean out Residual Arctic Pack in Well 00:30 - 01 :30 1.00 CLEAN N WAIT DECOMP Wait On Little Red Pumping Services arrival 01 :30 - 03:00 1.50 CLEAN P DECOMP Pump 90 bbls of 105 deg Diesel @ 2 bpm -ICP @ 2 bpm = 400 psi -FCP @ 2 bpm = 1200 psi Taking Returns to Open Top Tiger Tank, Returns are Clabbered Arctic Pack and Diesel : 03:00 - 06:30 3.50 CLEAN P DECOMP Displace Diesel with 90 bbls of heated (105 deg) Seawater with Safe Surf 0 -Circ @ 5 bpm, @ 81 bbls away the line plugged going to the Open top Tiger Tank, Shut in and Bleed off both sides, Bled to Cutting Tank, Line up to take returns to cutting tank, Returns thick and clabber, pump rate @ 1 bpm till Seawater returns Displace Seawater with 9.8 Brine -Circ @ 5 bpm,Thick Intermittent returns 06:30 - 09:30 3.00 CLEAN P DECOMP POH -Lay Down Casing Scrapers and XO's 09:30 - 11 :00 1.50 EVAL P DECOMP PreJob with Schlumberger wireline crew and NAD rig crew -R/U SWS and make up Tools Printed: 7/24/2007 5:05:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 3/24/1974 End: 7/6/2007 6/22/2007 7/11/2007 2ES DECOMP Run logging tools to 2550' I -Perform USIT Log from 2550 - Top of 9 5/8" PBR @ 2116' Log shows cement to top of PBR 13:30 - 14:00 0.50 EVAL P DECOMP RID SWS and clear floor 14:00 - 15:00 1.00 FISH N WAIT DECOMP Wait on IBP retrieving tool from Baker Fishing 15:00 - 16:30 1.50 FISH P DECOMP M/U Oversize guide and Sure Catch overshot -RIH to top of sand @ 2620' 16:30 - 18:00 1.50 FISH P DECOMP Displace 9.8 ppg Brine with Seawater -400 gpm I 700 psi -Washing down to IBP 18:00 - 19:30 1.50 FISH P DECOMP Tag IBP @ 2645', sat down with 5k, wait 5 min, pull up, no joy, sat 10k down, pull up, no joy - unable to Latch on to tool, 19:30 - 20:30 1.00 FISH P DECOMP POH to PIU Rev Circ. basket. -UD Latch Fishing assembly 20:30 - 21 :30 1.00 FISH N DPRB DECOMP M/U Reverse circulating basket 21 :30 - 22:00 0.50 FISH N DPRB DECOMP RIH to 2551' 22:00 - 22:30 0.50 FISH N DPRB DECOMP Wash Down to Top of IBP @ 2645' 22:30 - 00:00 1.50 FISH N DPRB DECOMP Tag IBP, Circ. @ 330 gpm 13100 psi -Lots Of Sand coming back - PUW = 75k I SOW = 70k Monitor well, 8.5 Seawater in and out 6/29/2007 00:00 - 01 :00 1.00 FISH X DPRB DECOMP POH with Reverse circulating Boot Basket -Monitor well 8.5 seawater in lout 01 :00 - 02:00 1.00 FISH X DPRB DECOMP Breakout Boot basket ***apx. one cup of misc. rubber in basket, no metal Lay Down Boot Basket and Crossovers Clean I Clear Floor 02:00 - 05:00 3.00 FISH X DPRB DECOMP PreJob Meeting with Schlumberger slick line crew and NAD rig Crew -Set 9 5/8 Shooting nipple in stack -R/U SWS Sheaves, Lubricator and BOP's -Test 1000 psi -Pick up Retrieving tool 05:00 - 08:30 3.50 FISH X DPRB DECOMP Run in Schlumberger Slick Line attemt to retrieve IBP set in the 9 5/8" casing @ 2645' -Run #1, Lead Impression Block, tag PBR -Run # 2 IBP Pulling tool, unable to latch on -Run #3, Lead Impression block, No Solid impression -Run #4, RIH wlbailer, 1/2 gal sand back 08:30 - 09:00 0.50 FISH X DPRB DECOMP RID Schlumberger Lubricator, BOP's and 9.625 Shooting Nipple 09:00 - 10:30 1.50 FISH X DPRB DECOMP Pick up 8.125 x 7.75 Wash Pipe and RIH to clean off top of IBP @ 2649' 10:30 - 12:00 1.50 FISH X DPRB DECOMP Reverse Circ 20 bbl Hi-Vis Sweep@ 250 gpm 1500 psi -Lots of Rubber back and a small amount of sand 12:00 - 14:00 2.00 FISH X DPRB DECOMP POH and UD Wash Pipe -Clear & Clean Rig Floor 14:00 - 15:00 1.00 FISH X DPRB DECOMP Rig up with Schlumberger Slick line -Set Shooting Nipple in stack, P/U Lubricator & SWS BOP's 15:00 - 21:30 6.50 FISH X DPRB DECOMP Run in Schlumberger Slick Line attempt to retrieve IBP set in the 9 5/8" casing @ 2645' -Run #1, Lead Impression Block, no indent Printed: 7/24/2007 5:05:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 6/22/2007 Rig Release: 7/11/2007 Rig Number: 2ES Spud Date: 3/24/1974 End: 7/6/2007 Unable to get over IBP Fish Neck Rig Down SWS Slick line Make 5.75 Cutlip guide and 1.75" Overshot -RIH RIH with Cut Lip And 1.75" Overshot RIH to 2585, -Wash Down over IBP Fishing neck @ 2649', @ 168 gpm / 75 psi -Washed over and pull up, sheared pins, 5k to shear -PUW - 70k I SOW 70k -Deflate IBP for 1/2 hour -Slack off below previous setting depth DECOMP POH with IBP -Retrieved IBP, -IBP Intact no missing pieces -Fishing Neck appears to be damage, unable to release overshot Make up HES Retrievable Bridge plug and running tools RIH with RBP to 2600' - PUW=73 k SOW=73k Set HES Retrievable Bridge Plug -Set Down 20k to confirm set -pull 1 stand and test to 1000 psi for 10 min Dump 2000 Ibs of sand down Drill Pipe on top of Plug Displace Seawater from well to 9.8 ppg Brine -6 bpm @ 170 psi POH and Lay Down HES running tools Test 133/8" Casing to 3000 psi, Chart for 10 minutes, Good test Test BOP's to 250 low and 3500 high -All tests held for 5 minutes and charted -Test Witness by BP WSL; B.Neufeld, D. Newlon and NAD TP; R. Dalton, W. Stout -Witness of test waived by AOGCC John Crisp DECOMP Make up PBR Polish Mill BHA and RIH to 2071' DECOMP Wash down to Top Of PBR @ 2117' -Wash and Polish 95/8" Seal Bore Receptacle -6 bpm / 200 psi, Rotate @ 15 rpm -PUW=75k I SOW=75k -Tag Top @ 2117' Tag Bottom @ 2132' Work Through 4 x -Circ. Hi-Vis Sweep Around @ 10 bpm 1500 psi DECOMP POH with Polishing Mill BHA and Lay Down BHA 6.50 FISH 21 :30 - 23:00 1.50 FISH X DPRB DECOMP 23:00 - 00:00 1.00 FISH X DPRB DECOMP 6/30/2007 00:00 - 01 :00 1.00 FISH X DPRB DECOMP 01 :00 - 02:00 1.00 FISH X DPRB DECOMP 02:00 - 03:30 1.50 FISH P 03:30 - 04:30 1.00 DHB P DECOMP 04:30 - 06:00 1.50 DHB P DECOMP 06:00 - 08:00 2.00 DHB P DECOMP 08:00 - 12:00 4.00 DHB P DECOMP 12:00 - 14:00 2.00 DHB P DECOMP 14:00 - 15:00 1.00 DHB P DECOMP 15:00 - 15:30 0.50 CASE P DECOMP 15:30 - 20:30 5.00 CASE P DECOMP 20:30 - 21 :30 21 :30 - 22:30 1.00 CLEAN P 1.00 CLEAN P 22:30 - 23:30 1.00 CLEAN P -Run #2 IBP Pulling tool, unable to latch on -Run #3 4.5" Lead Impression block, Impression on side of block -Run #4 IBP Pulling tool, unable to latch on -Run #5 5.5" Lead Impression block, Indent on side of block -Run #6 IBP Pulling tool with Bell Guide pin for jar up, unable to latch on -Run #7 IBP Pulling tool with Bell Guide pin for jar up without centralizer, unable to latch on Printed: 7/24/2007 5:05:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/22/2007 7/11/2007 2ES Spud Date: 3/24/1974 End: 7/6/2007 6/30/2007 23:30 - 00:00 I P TIEB1 Start Rigging up to run casing 0.50 ¡CASE -Change out to Long Bales 7/1/2007 00:00 - 02:00 2.00 CASE P TIEB1 PreJob with NAD Casing Crew And NAD rig Crew Rig up to run casing -Set up False Bowl and Slips, Rig up Elevators, Power Tongs and Rig Tongs -M/U Safety Valves and Pick up Pup Joints 02:00 - 08:00 6.00 CASE P TIEB1 Make up 9 5/8" Seal Assembly, Baffle Plate, Pup Joints and HES ES cementer Run 9518 #40 L-80 TCII and Hydril 563 Casing -1 centralizer per joint, 50 cetralizers total -Jet Lube Seal Guard on TCII and Hydril 563 threads -No Plug in Baffle plate Torque TCII to 12,600 It.lbs Hydril 563 -13,000 It.lbs 08:00 - 09:00 1.00 CASE P TIEB1 Make up XO & Cement Head -Rig Down False Bowl, Power Tongs and casing running equip. 09:00 - 10:00 1.00 CASE P TIEB1 Tag No Go on SBR, Unsting from PBR, -Drop Bottom Plug, Pump Down Plug to Baffle Seat, -Plug Bumped @ calculated strokes, -125k PUW I 82k SOW 10:00 - 10:30 0.50. CASE P TIEB1 Attempt to Test Casing to 2000 psi, Failed I Pressure bleeding off with returns in the annulus I I -Open Bleeder and sting in to PBR to unseat plug -Re-Ianded plug -Attempt to pull out of PBR, no go, pulled max of 200,000 -Attempt to test casing to 2000 psi, -Test Failed, Rapid bleed off with returns in annulus 10:30 - 12:00 1.50 CASE N DFAL TIEB1 Consulted with Anchorage Rig Team on Plan Forward 12:00 - 13:30 1.50 DHB N DFAL TIEB1 Remove Cement head, XO's, CIO Bales I -Rig Up False Table and Tubular Running equipment 13:30 - 14:30 1.00 DHB N !DFAL TIEB1 P/U RBP and Running Tools -Make RBP BHA 14:30 - 17:30 3.00 DHB N DFAL TIEB1 RIH with RBP and set @ 2050', POOH 17:30 - 18:30 1.00 DHB N DFAL TIEB1 Make XO's and Circulating Head Pin -Test 9 5/8 casing against RBP @ 2050' -Charted for 30 min, Good Test, -Rig Down Cement head and XO's 18:30 - 21 :00 2.50 DHB N DFAL TIEB1 RIU False Table & Bowl-RIH to 2050 and release RBP -POH with RBP -UD Tools and Tubular handling Equipment Clear Floor of RBP Running Equipment 21 :00 - 22:00 1.00 CASE P TIEB1 Install Long Bales, MIU Cement Head and Cementing Lines 22:00 - 23:00 1.00 CEMT P TIEB1 Pick up to 100k, Start pumping @ 2 bbllmin, -ES Cementer sheared @ 3600 psi -Estabilish Circulation @ 6 bpm I 260 psi -CBU before we got clean brine back -Pre Job Safety Mtg. with Schlumberger Cementing crew, Veco 123:00 - 00:00 Truck Drivers and NAD Rig Crew 1.00 CEMT P TIEB1 Start Cement Job -Pump 3 bbls fresh water to cement head through wash up line to flow line, test lines to 4500 psi. Clear lines with brine alter testing. -Pump 20 bbls 9.8 ppg brine. Printed: 7/24/2007 5:05:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 6/22/2007 Rig Release: 7/11/2007 Rig Number: 2ES Spud Date: 3/24/1974 End: 7/6/2007 P and pump 142 bbls (670 sx) of 15.8 ppg class "G" tail with at 5 bpm, closing plug and kick out with 5 bbls water to clear lines. -Displace Cement with 9.8 Brine 7/2/2007 00:00 - 01 :00 1.00 CEMT P TIEB1 Displace Cement with 160 bbls 9.8 ppg brine. (Total displ volume = 165 bbls). Slow down pump rate to 1 BPM as plug approaches the ES cementer 1-19 bbls of Cement back to Surface ,-Bump plug, close cementer @ 1600 psi,Pressure up to 2000 psi and hold for 5 min. -Bleed pressure and check floats, Cementer Holding -Break out cementing equipment BOPsu1 P CIP @ 00:45 7-2-2007 01 :00 - 02:30 1.50 TIEB1 Flush Stack -Flush & Blow down lines to cutting tank I -Rig Down Cement Head and Long Bales -Prepare floor to Nipple Down 02:30 - 04:00 1.50 BOPsu1 P TIEB1 Nipple Down Stack, Spacer Spool, & Riser Prepare Cellar for Cutting Casing Bopsuip Raise BOP's 4' 04:00 - 06:30 2.50 TIEB1 Set casing slips with 75,000 hanging weight I Cut 9 5/8" casing with WACHS Cutter UD Cut Joint BOPSU~ P UD Spacer Spool 06:30 - 12:30 6.00 TIEB1 NIU Tubing Spool, Test Flange and Packoff seals to 2400 psi NIU BOP's, Set Riser, Mousehole and Turnbuckles 12:30 - 14:00 1.50 BOPSU~P TIEB1 Changeout Pipe Rams from 9 5/8 to 3.5 x 6 variables 14:00 - 15:00 1.00 BOPSU P TIEB1 M/U 4" Test Joint, Install Test plug I Test Top set Pipe Rams 250 low 3500 high, Test Charted & Held for 5 min. Witness of test Waived by AOGCC John Crisp Pulled Test Plug I Install wear Bushing 15:00 - 16:30 1.50 CLEAN P DECOMP M/U Cleanout BHA & RIH to 2040' 16:30 - 17:00 0.50 CLEAN P DECOMP Test 9 5/8" csg to 2200 psi for 15 min, Good Test 17:00 - 20:00 3.00 CLEAN P DECOMP Tag of Cement @ 2064', Drill Cement, Plugs & ES Cementer @ 2074' 6 bpm / 200 psi 50 rpm 11200 ftIlbs 75k PUW 75k SOW Drill firm Cement to Baffle Collar @ 2116' RIH down to 2544, Wash sand to 2548' 20:00 - 20:30 0.50 CLEAN P DECOMP Pump Hi-Vis sweep around@ 10 bpm / 500 psi 20:30 - 22:00 1.50 CLEAN P DECOMP POH with cleanout assembly, Break Bit and UD Boot Baskets 22:00 - 00:00 2.00 CLEAN P DECOMP Make up Reverse Circulating basket and RIH to 2548' 7/3/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP Circulate down with Reverse Circ. Basket washing Sand & Junk from 2548 -2580 -290 gpm / 3000 psi 20 rpm 11800 ft. lb. -75k Up and Down WI. Pump Hi-vis sweep, sweep brought up small pieces of aluminum, rubber and sand 01 :00 - 03:30 2.50 CLEAN P DECOMP POH and UD Cleanout BHA -Recovered the majority of junk and all of the bigger pieces ie; cone, cement ring and bigger chunks of baffle plate cement Printed: 7/24/2007 5:05:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/22/2007 7/11/2007 2ES Spud Date: 3/24/1974 End: 7/6/2007 7/3/2007 01 :00 - 03:30 2.50 CLEAN P DECOMP Clear Floor and UD Excess tools and Equipment 03:30 - 04:00 0.50 CLEAN P DECOMP I Rig up to Test Casing, Close Blind Rams and Line up to pump I through Kill Line -Tested 95/8" csg to 3500 psi for 10 min, Good Test Bleed Off and Line up BOP stack 04:00 - 05:00 1.00 CLEAN P DECOMP Pick up HES RBP retrieving tool and RIH 05:00 - 05:30 0.50 DHB P DECOMP Wash Down thru sand from 2568' to RBP. Pump HI-Vis sweep around and latch up on plug. Confirm latch up. 05:30 - 07:30 2.00 DHB P DECOMP POH with RBP and LD same. 07:30 - 08:30 1.00 CLEAN P DECOMP MU Rev circ JB, bumper sub, oil jars, boot baskets & DC's. 08:30 - 15:00 6.50 CLEAN P DECOMP Run stands down to 2700'. PJ8M. Continue in hole Picking up singles to 9642'. 15:00 - 15:30 0.50 CLEAN P DECOMP Drop ball and wash down to 7" stub at 9512' DPM. Pump at 200 gpm with 580 psi. Pump ball down on seat and circ at 300 gpm with 3000 psi. Work down to top of tubing stub. 15:30 - 17:00 1 .50 CLEAN P DECOMP Circulate BU at 300 gpm with 3000 psi. Pump dry job. 17:00 - 19:30 2.50 CLEAN P DECOMP POOH to 2183'. 19:30 - 20:00 0.50 CLEAN P DECOMP Spot 110 deg seawater from 2183' to surface. Pump at 250 ! gpm with 1900 psi. Pump dry job. 20:00 - 21 :00 1.00 CLEAN P DECOMP POOH to 315'. Change out handling equipment. 21 :00 - 22:00 1.00 CLEAN P DECOMP Service break RCJB and lay down. Clean and lay down boot baskets. Clear and clean floor. Recovered several pieces of control line, S8 bands and centralizer from boot baskets. 22:00 - 23:30 1.50 CLEAN P DECOMP PU and MU 5-1/2" RCJB BHA to 240'. Change out handling equipment. 23:30 - 00:00 0.50 CLEAN P DECOMP RIH to 1264'. 7/4/2007 00:00 - 02:30 2.50 CLEAN P DECOMP RIH to 9387'. 02:30 - 03:30 1.00 CLEAN P DECOMP PJSM. Cut and slip 100' of drilling line. Inspect draworks, traction motor brushes, brakes. Lube elmago splines. Service draworks. 03:30 - 04:30 1.00 CLEAN P DECOMP Inspect and service top drive and crown. 04:30 - 05:00 0.50 CLEAN P DECOMP Test casing to 3500 psi for 30 minutes. Just passed as per MIT guidelines. 05:00 - 06:00 1.00 CLEAN P DECOMP Pick up drilll pipe singles and RIH. Tag 7" casing stump at 9512'. Up weight 193k, down 130k, RT 153k. 06:00 - 09:30 3.50 CLEAN P DECOMP Wash and ream at 9512'. Pump at 260 gpm with 775 psi. Free torque 6k at 20 rpm. Max torque at 10k. WOB 2-5k. Unable to get inside stump. Layed down single. Install blower hose. Drop RCJB ball. Pick up single and wash to 9559' at 400 gpm with 2500 psi. Rotate at 30 rpm with max torque of 10k. Obstruction at 9559'. Pump dry job. Remove blower hose. 09:30 - 14:00 4.50 CLEAN P DECOMP POOH to 240'. Change out handling equipment. 14:00 - 15:00 1.00 CLEAN P DECOMP Stand back drill collars. Check and lay down reverse junk basket. Empty and clean boot baskets. Recoverd small piece of S8 banding. 15:00 - 16:00 1.00 CLEAN P DECOMP Re-test casing to 3500 psi for 30 minutes to verify good test. Just passed as per MIT guidelines. 16:00 - 17:00 1.00 CLEAN P DECOMP PU and MU Rope Spear BHA to 235'. Change out handling equipment. 17:00 - 19:30 2.50 CLEAN P DECOMP RIH to 9475'. Install blower hose. 19:30 - 22:00 2.50 CLEAN P DECOMP Break circulation at 170 gpm with 450 psi. Up weight 183k, down 138k, RT 152k at 20 rpm. RIH and tag obstruction at Printed: 7/24/2007 5:05:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/22/2007 7/11/2007 2ES Spud Date: 3/24/1974 End: 7/6/2007 7/4/2007 9538'. Work through one single with 4-6k torque. Break out top drive. Continue to RIH with singles to 10382' working up 30' every 120' run in. Do not tag up as per Baker rep. Pump dry job. Seawater weight in and out 8.5 ppg. 22:00 - 00:00 2.00 CLEAN P DECOMP POOH to 4343'. 7/5/2007 i 00:00 - 02:00 I 2.00 CLEAN P DECOMP PJSM. Continue POOH to 235'. Change out handling I I , equipment. I 02:00 - 03:30 1.50 CLEAN P DECOMP PJSM. Lay down intensifier and circ sub. Stand back drill collars. Break and lay down rope spear from BHA #12. Recovered 1/2 of a centralizer band from spear and several small pieces of metal in the boot basket. Pick up and make up RCJB for BHA #13. Make up rest of BHA to 235'. CO handling I , equipment. i 03:30 - 06:00 2.50 CLEAN P DECOMP RIH to 9512'. Unable to get into 7" stump. 06:00 - 08:00 2.00 CLEAN P DECOMP Make up top drive. Reverse circulate at 250 gpm with 775 psi. ! Torque 5k at 20 rpm. Unable to work down. Break out top drive. I Drop ball. MU top drive. Install blower hose. Wash and ream at 400 gpm with 2525 psi. Torque 8k at 20 rpm. WOB 2-10k. Up weight 190k, down 130k, RT 152k. Unable to wash past 9517'. 108:00 - 11 :30 3.50 CLEAN P DECOMP POOH to 237'. ì 11 :30 - 15:00 3.50 CLEAN P DECOMP Lay down intensifier. Rack back drill collars. LD RCJB. All the inside fingers of RCJB were broken off. Broken fingers could indicate mill has cut a finger in 7" tubing. Clean and LD boot baskets. PU double mill BHA #14 to rig floor. Make up boot baskets, watermelon mill, magnet and 3-1/8" convex mill. Make up rest of BHA to 247'. Change out handling equipment. 15:00 - 17:30 2.50 CLEAN P DECOMP RIH to 9487'. Install blower hose. 17:30 - 19:30 2.00 CLEAN P DECOMP Break circulation at 250 gpm with 1320 psi. Up weight 185k, down 130k, RT 150k. Torque 4-7k with 40 rpm. Tag at 9512' and work down with 10k to 9517'. Could not work down any more. Pump dry job. Remove blower hose. 19:30 - 22:30 3.00 CLEAN P DECOMP POOH to 247'. Change out handling equipment. 22:30 - 00:00 1.50 CLEAN P DECOMP Lay down boot baskets and mills. Clean boot baskets. Negligible amount of material in baskets. Clear floor. PU washpipe BHA #15 to rig floor. 7/6/2007 100:00 - 02:00 2.00 CLEAN P DECOMP PJSM. Finish picking up Baker tools. Make up washpipe shoe and extensions. Make up boot baskets, jars, bumper sub and drill collars to 313'. 02:00 - 04:30 2.50 CLEAN P DECOMP RIH to 9460'. Install blower hose. 04:30 - 06:00 1.50 CLEAN P DECOMP Wash down to 9500'. Up weight 195k, down weight 135k, RT 160k. Torque 8k at 50 rpm. Pump at 340 gpm with 970 psi. Wash down and tag at 9512'. Wash over 7" stump with 2-5k WOB, rotate at 50 rpm with 6-9k torque. Continue to wash down to coupling at 9519.5'. Pump sweep surface to surface. Work washpipe over stump. Shut down rotary and work washpipe down to 9519.5' with no problems. Ramp pumps up to 500 gpm with 2000 psi. 06:00 - 10:00 4.00 CLEAN P DECOMP Remove blower hose. POOH to 313'. Change out handling equipment. 10:00 - 12:00 2.00 CLEAN P DECOMP Lay down and clean boot basket. Negligible material in basket. Lay down washpipe BHA #14. Make up overshot BHA #15 to 320'. Change out handling equipment. 12:00 - 14:30 2.50 CLEAN P DECOMP RIH to 8253'. Printed: 7/24/2007 5:05:56 PM , . . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/22/2007 7/11/2007 2ES Spud Date: 3/24/1974 End: 7/6/2007 7/6/2007 14:30 - 15:30 1.00 CLEAN P DECOMP Cut and slip 108' of drilling line. Service and inspect brakes and traction motor brushes. Lube elmago splines. Adjust brakes. 15:30 - 16:00 0.50 CLEAN P DECOMP RIH to 9512'. Up weight 200k, down 135k. 16:00 - 18:00 2.00 CLEAN P DECOMP Swallow stump to 9520'. Jar on 7" casing and PBR. Start jarring at 275k, pull to 300k. Increase to 300k jar, pull to 350k. Increase to 350k jar, pull to 400k. No movement. Release overshot. 18:00 - 20:00 2.00 CLEAN P DECOMP PJSM. Inspect derrick, top drive and draworks after jarring 3.50 I CLEAN operations. 20:00 - 23:30 P DECOMP POOH to 320'. Change out handling equipment. 23:30 - 00:00 0.50 i CLEAN P DECOMP POOH with BHA #15. Lay down intensifier. Stand back drill i collars. 7/7/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP PJSM. Break out shoe and change grapple. Make up BHA #16. PU/MU washpipe extensions and shoe. MU drill collars and intensifier to 331 '. Change out handling equipment. 01 :30 - 04:30 3.00 CLEAN P DECaMP PJSM. RIH to 9512'. 04:30 - 08:30 4.00 CLEAN P DECOMP Install blower hose. Make up top drive. Establish circulation at 335 gpm with 900 psi. Up weight 195k, down 135k, RT 160k. Free Torque 5k at 50 rpm. Work down to collar at 9519'. Mill on collar pumping at 335 gpm with 1050 psi. WOB 5-12k. Torque 5-11 k at 50 rpm. Reduce pump rate to 228 gpm with 555 psi. Mill down to 9521'. Pull one stand. Pump dry job. Remove blower hose. Install air slips. 08:30 - 13:00 4.50 CLEAN P DECOMP POOH to 331'. 13:00 - 14:00 1.00 CLEAN P DECOMP PJSM. POOH with BHA #16. LD intensifier. Stand back drill collars. Lay down mill shoe and washpipe extensions. Make up cut lip and lay down jar assembly. 14:00 - 22:30 8.50 BOPSU P DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test both 4" and 4-1/2" test joints. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL's Dick Maskell and Mitch Skinner, and Toolpusher's Cleve Coyne and Bruce Simonson. Rig down. Clear and clean floor. 22:30 - 23:30 1.00 CLEAN P DECOMP PJSM. Pick up tools for BHA #17. Make up overshot. Check I torque on baker tools. Run in bumper sub, jars, drill collars and I intensifier to 320'. Change out handling equipment. i 23:30 - 00:00 0.50 CLEAN P DECaMP RIH to 1719'. 7/8/2007 00:00 - 02:00 2.00 CLEAN P DECOMP RIH to 9467'. Make up top drive. 02:00 - 04:00 2.00 CLEAN P DECOMP PJSM. Cut and slip 57' of drilling line. Service top drive, crown and draworks. 04:00 - 04:30 0.50 I CLEAN P DECOMP Pick up stand and establish parameters. Up weight 195k, down 135k, RT 160k. Free torque 4.5k at 30 rpm. Pumps at 110 gpm with 95 psi. Up weight 190k, down 140k. Rotate at 20 rpm and work over 7" stump at 9512'. Pick back up turn off pump and rotary. Slack off and engage fish to 9520'. Pick up and verify with 200k, kick on pumps and pressure up to 600 psi. Kick off pumps. Pull up and break fish loose with 225k. Pull and rack back one stand. Purnp dry job with 200 gpm and 380 psi. Install air slips. 04:30 - 07:30 3.00 CLEAN P DECOMP PJSM. POOH to 320'. Change out handling equipment. 07:30 - 10:00 2.50 CLEAN P DECOMP PJSM. POOH with BHA #17. Lay down intensifier. Stand back drill collars. Pick up and verify fish. PJSM. Break out grapple. Lay down 7" tubing fish and rest of BHA. Strap on 7" stump at Printed: 7/24/2007 5:05:56 PM .. . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 6/22/2007 Rig Release: 7/11/2007 Rig Number: 2ES Spud Date: 3/24/1974 End: 7/6/2007 ours Task 7/8/2007 07:30 - 10:00 2.50 CLEAN P DECOMP 7.57'. Clear and clean floor. 10:00 - 11 :30 1.50 CLEAN P DECOMP Pick 3-1/4" spear and 4" grapple assembly up beaverslide. 11 :30 - 12:30 1.00 CLEAN P DECOMP PJSM. Due to condition of 7" stump pulled from hole it was decided to test the casing. Casing tested to 3500 psi for 30 minutes. Test OK. Bleed off and blow down lines. 12:30 - 13:30 1.00 CLEAN P DECOMP PJSM. Make up BHA #18 with 3-1/4" spear and 4" grapple to 223'. 13:30 - 16:30 3.00 CLEAN P DECOMP RIH to 9520' and work through top of 7" tubing with no problems. RIH to 10307'. 16:30 - 17:00 0.50 CLEAN P DECOMP Break circulation at 350 gpm with 2100 psi. Up weight 190k, down 140k. Wash down and tag at 10385'. Engage fish to 10389' with 10k down. Pick up free at 190k. Back down to 130k with pumps off. Fish believed to be on. Pump dry job. 17:00 - 20:30 3.50 CLEAN P DECOMP POOH easy. Pull through tight spot at 9605' with 20k over. Continue to 223'. 20:30 - 00:00 3.50 CLEAN P DECOMP PJSM. Break and lay down intensifier and circ sub. Stand back drill collars. Pull up with tubing fish on. A 2' long, 2" wide finger of 7" casing was wedged between the grapple and the fish holding the fish on. Approximately 1 gallon of junk, including banding, cement, tubing and control line recovered from between the 5-3/4" sleeve and the 3-3/4" sleeve. Disengage spear and break off. Lay down jar and bumper sub. Change out elevators. POOH with fish. Break and lay down fish, jars and bumper sub. Clear and clean floor. RIH with 4-3/4" drill collars, pull and lay down. Fish length at 66.85'. 7/9/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP PJSM. Lay down remaining drill collars. Clear floor. Change out handling equipment. 01 :00 - 03:30 2.50 CLEAN P DECOMP PJSM. Pick up single and XO sub. Make up overshot BHA #19 and RIH to 1284'. Change out handling equipment. Install airslips. 03:30 - 06:30 3.00 CLEAN P DECOMP PJSM. RIH to 10448'. Tag 3-3/16" stump. Rack a stand back. PU space out pup. Make up top drive. Up weight 215k, down 135k. 06:30 - 08:30 2.00 CLEAN P DECOMP Establish circulation at 198 gpm with 484 psi. Slack off, tag bottom. Circulate bottoms up. With pumps on, up weight 210k, down 140k. PJSM with SWS. Spot unit and pick tools up beaverslide. 08:30 - 10:30 2.00 CLEAN P DECOMP Rig up slickline sheaves and drift tool. Tool at 2.145" OD. 10:30 - 12:00 1.50 CLEAN P DECOMP RIH with slickline drift to 11134'. No problems getting into top of liner. Tool stopped at possible crossover point from 3-3/16" to 2-7/8". 12:00 - 13:30 1.50 CLEAN P DECOMP POOH with slickline. Rig down and lay down SWS equipment. 13:30 - 14:30 1.00 CLEAN P DECOMP Pump hi-vis sweep surface to surface at 500 gpm with 2200 psi. 14:30 - 17:00 2.50 CLEAN P DECOMP PJSM. Lay down drill pipe to 8500'. 17:00 - 20:30 3.50 CLEAN N RREP DECOMP Repair leaking hydraulic line on iron roughneck. 20:30 - 00:00 3.50 CLEAN P DECOMP Continue to POOH and LD drill pipe to 3152'. 7/10/2007 00:00 - 03:00 3.00 CLEAN P DECOMP Continue to lay down drill pipe to 1284'. 03:00 - 05:00 2.00 CLEAN P DECOMP Lay down drill collars. Break and LD Jar, bumper sub, boot baskets and XO's. Lower down beaverslide. Clear floor. 05:00 - 07:00 2.00 CLEAN P DECOMP Continue to LD DP and overshot guide. Pull wear ring. Clear and clean floor. 07:00 - 10:00 3.00 RUNCO P RUNCMP PJSM. Change out bails. Make up XO's for landing joint. PJSM. Printed: 7/24/2007 5:05:56 PM -. . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 WORKOVER Start: 6/22/2007 NABORS ALASKA DRILLING I Rig Release: 7/11/2007 NABORS 2ES Rig Number: 2ES 3.00 RUNl:~~o/j~~~[:~!!' 8';'g"p œ,;,g 'q";pmoot to ';g floo' aod ';g"P 14.00 RUNCO~P I RUNCMP I PJSM. PU tail pipe assembly and packer. RIH with 4-1/2", :' 12.6#, 13Cr-80, Vam Top completion to 9545.90'. Run a total i of 223 joints. Up weight 132k, down 112k. Make up joint #223. f' Pull airslips and rubbers. Rig down compensator. Change out i elevators. Pick up landing joint and make up hanger. 1.50 RUNCO P RUNCMP PJSM. Run tubing tailpipe assembly into top of 7" liner. Land , 4-1/2" tubing. RILOS. Back out landing joint. Clear and clean t' floor. Rig up to reverse circulate. 3.50 RUNCO P RUNCMP PJSM. Reverse circulate 146 bbls of clean seawater at 125 gpm with 150 psi. Follow with 306 bbls of corrosion inhibited seawater. Chase with 204 bbls of clean sewater. 1.50 RUNCOIP RUNCMP Run in landing joint. Drop ball and rod down to RHC plug and XN nipple. Lay down landing joint. Pressure up tubing and set packer with 2400 psi, continue to pressure up to 3500 psi to test tubing for 30 minutes. Test OK. Bleed pressure to 1500 psi. Pressure up annulus to 3500 psi and hold for 30 minutes. Test OK. Bleed off tubing and annulus. Pump up annulus to 2500 psi and shear OCR valve. Pump both ways to verify good shear. RUNCMP PJSM. Install TWC and test from above and below to 1000 psi for 5 minutes each side. Bleed off and blow down all surface equipment. Rig down cellar lines and ready tools for BOP NO. Prep pits for rig move. RUNCMP PJSM. Pull mouse hole and riser. Nipple down BOP stack and extension spool. Bring adapter flange and tree into cellar. RUNCMP PJSM. Install adapter flange and tree. Call out pad operator to verify orientation. NU tree and adapter. RUNCMP Test packoff and void to 5000 psi for 10 minutes. Test OK. Line up test pump and test tree to 5000 psi for 30 minutes. Test OK. ,RUNCMP Pull TWC with DSM lubricator. RUNCMP PJSM. Rig up circulating lines to annulus and top of tree to cuttings tank. Tie in LRS. Pressure test lines to 2000 psi. Pump 156 bbls diesel for freeze protection at 2 bpm. Shut in LRS. Line up and u-tube well. Suck back diesel lines. RUNCMP Rig down circulating lines. Dry rod BPV and test from below to 1000 psi. Test OK. Rig down LRS Remove all circulating lines and secondary annulus valve. Install all flanges, plugs, manifolds and gauges. Secure tree. Prep pits and cellar for rig move. Spud Date: 3/24/1974 End: 7/6/2007 7/10/2007 07:00 - 10:00 10:00 - 00:00 7/11/2007 00:00 - 01 :30 01 :30 - 05:00 05:00 - 06:30 06:30 - 08:30 08:30 - 11 :00 11 :00 - 15:30 15:30 - 17:30 17:30 - 18:30 18:30 - 21 :30 21 :30 - 22:00 22:00 - 00:00 2.00 BOPSU P 2.50 BOPSU P 4.50 WHSUR P 2.00 WHSUR P 1.00 WHSUR P 3.00 WHSUR P 0.50 WHSUR P 2.00 RIGD P POST Rig released at midnight. Printed: 7/24/2007 5:05:56 PM F-08A DRLG DRAF~ '. 9-5/8" eSG, 40#, l-80 Tvll, ID'" 8.835", 0,0758 bpI 2106' 2700' Minimum ID =2,372"@ 11101' 3-3/16" X 2·7/8" XO 9519' 9599' 9546' 10087' 10160' 11053' 11215' 11303' PERFORA TION SlIMI\/!.A. RY REF lOG: SWS MWORY CNl/GR OF 12-19-02 ANGLE AT TOP ÆRF: 89@ 12000' Note: Refer to Produotion DB for historIcal perf data DATE 2" 4, 12000 - 12182 12/20/02 2" 4 12380 - 12694 12/20/02 I SURF ACE H ES11MA TED TOP OF GEJ\.1ENT I 209T 4-1/2" HES X NIP, ID'" 3.813" GA S LIFT MA NDRElS lYÆ VlV LAT MMG OCR RKP M1\AG DMY RK RT OA TE o 07108107 o 07/08/07 -19-5/8" HES ES Cementer -19-5/8" PBRI 3-3/16" LNR, 6..2#, l-80, .0076 bpf, 10'" 2.80" PRUDHOE BA Y UNrr WELL F-OM PERMrr No: 112022310 APi No: 50-029-20135-01 sEC 2, T11 N. R13E, 2570' SNl & 2877' \NEt BP Exploration {Ataska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth E)Oa -''d3/ 05/15/07 NO. 4024 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . Well Job# Loa DescriDtion Date BL Color CD L3-22 11638627 PRODUCTION PROFILE 04/14/07 1 L3-30 11637115 PRODUCTION PROFILE 03/19/07 1 L4-10 11660529 MEM PROD PROFILE 04/04/07 1 L3-12 11686732 PRODUCTION PROFILE 04/08/07 1 02-29C N/A EMIT & CALIPER IMAGE 04/17/07 1 DS 02-36 11637141 MULTI-FINGER CALlPE 03/14/07 1 F-16A N/A SCMT 02/12/07 1 X-21A 11660531 MEM CBL 04/07/07 1 F-08A 11676934 SCMT 03/20/07 1 A-30A 11628762 MEM CBL 03/13/07 1 03-36A 11637326 USIT (CORROSION) 04/12/07 1 03-36A 11637326 USIT (CEMENT) 04/12/07 1 DS 17-05 11594492 USIT 04/24/07 1 DS 03-01 11630462 USIT 03/11/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE ø)f;r ..~çJ;1~: BP Exploration (Alaska) Inc. 5\¡ANNI:LJ MAY Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~1¡\'( .1\. 6 zuu1 \~ . 1 7 2007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-2 38 ATTN: Beth Received by: ---- . . SARAH PALIN, GOVERNOR AI.ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F -08A Sundry Number: 307 -04 7 !ÀO~-d31 scANNED FES 1 2 2007 Dear Mr. Hobbs: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this '& day of February, 2007 Enc!. eft 101 STATE OF ALASKA ~f. 0 ALA Oil AND GAS CONSERVATION cOMZ;~~h:),"'1-RECEIVE . APPLICATION FOR SUNDRY APPROVAL JÔ~\I 3 1 2007 20 MC 25.280 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program o Suspend 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate ~A"iI" 'li'1h1i6w Gons. COmmiSSiOn o Stimulate 0 Re-Enter S&~HtiJWWell o Waiver 0 Other t?· ......... Total Depth MD (ft): 12750 Casino Structural Conductor Surface Intermediate Production Liner 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028281 { 54.80' Prudhoe Bay Field / Prudhoe Bay Pool . .... . . 'A'!".. I ..... .... ......... .iT; .W.·iÇj7[.. ../r...///iii{D. Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9043 I 12707 9042 10804 None Lenoth Size MD TVD Burst Collanse 4. Current Well Class: ~ Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 202-231 , 6. API Number: 50-029-20135-01-00 ' 8. Well Name and Number: PBU F-08A r , Liner 80' 30" 80' 80' 2700' 13-3/8" 2700' 2700' 4930 2670 10087' 9-5/8" x 103/4" 10087' 8174' 6870 47RO 1507' 7" 95sg¡;'- 11066' 7866' - 8865' 8160 7020 2377' 3-3/16" x 2-7/8" 10363' - 12740' 8359' - 9043' 13450 13890 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 12000' - 12694' 9031' - 9042' Packers and SSSV Type: 7" x 4" Otis WD Packer, 7" Otis SSSV Nip 13. Attachments: ~ Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for Commencina Ocerations: 17. Verbal Approval: Commission Representative: / 18. I hereby certify that the foregOing is true and correct to the best of my knowledge. Printed Name Greg Ho~~~t?, Title Senior Drilling Engineer {fI/ IT / j/ ,i .' Prepared By Name/Number: Signature.;tV JUII/' Phone 564-;µ;3~1¡tll Date //Jb/1/- Sondra Stewman, 564-4750 . Y ~IJ Commission Use Onlv ' t Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~BOP Test 0 Mechanical Integrity Test 0 Location Clearance Tubing Size: Tubing Grade: Tubing MD (ft): 7",26# & 4-1/2", 12.6# N-80 & L-80 9596' & 10435' -10447' Packers and SSSV MD (ft): 10435' I 2043' 14. Well Class after proposed work: o Exploratory ~ Development 0 Service February 20,2007 Date: 16. Well Status after proposed work: ~ Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact Shane Gagliardi, 564-5251 I Sundry NumberðQ7-047 Other: Subsequent Fonn Required: '-\~ 7 Accroved Bv: .-.j / ~~COMMISSIONER Form 10-403 Revised 06/2006 V \..../ APPROVED BY THE COMMISSION Date ~... ¡¡> ~ ðr- ORIGINAL W"'^OQug 8Ft "'(n. . M..m .. !,.. .SN~mi~ In Duplicate J ~j zOO! . . Obp GL-~AY To: Tom Maunder - AOGCC Date: January 29, 2007 From: Shane Gagliardi - BPXA GPB Rotary Drilling Subject: F-08A Application for Sundry Approval Approval is requested for the proposed rig work over of PBU well F-08A. The parent well (F-08) was drilled in 1976. It was initially perforated in Z2B/Z2C sands. The parent produced 38.5 Mmbo (SLP) prior to sidetrack. Little wellwork was done on the well, with the exception of a GSO in 1987 and a return to a 26P lens in 1998. The sidetrack decision was made once gas was being produced from the upper part of the 22P. The current well was drilled in December 2002. Upon completion, there was real difficulty putting the well on production (POP) despite two N2 lifts. POP difficulties led to suspicion that reservoir damage was also contributing to difficulties getting F-08A online. The well finally went on production after an HCL wash and the installation of a gas lift straddle. Since the well was POP in May 2003, it has been an outstanding low GOR producer. Before the tubing leak developed the well was producing to the HP with no gas lift assistance. The first evidence of IAxOA communication occurred during May 2003. After POP, IAxOA communication was minor and manageable by bleeds, but TIO plots show clear IAxOA tracking. The plan is to replace the existing Thermocase wI 9-%" premium thread casing and cement to surface. During this operation, the 7" tubing wI the Arrow Pac patch will be pulled and replaced with 4-%" premium thread tubing. With all pertinent tubulars replaced and integrity restored, the well will be placed back on production. Estimated Spud Date: 2/20107 Shane Gagliardi Ops Drilling Engineer Office: 564-5251 Mobile: 632-6789 03-36 Application for Sundry . . 1. Current Well Information Well Name: API Number: PTD: Well Type: Current Status: BHP: BHT: Mechanical Condition: Tubing: TD I PBTD: Kick Off Point: Max Dogleg (to tbg cut): Max Angle (to tbg cut): Tubing Spool: Tubing Hanger: Tbg. Head Adapter: Tree: BPV Profile: SSSV: Control line: Control line bands: Control Line clamps: Perforations: Tubing Fluids: Annulus Fluids: PPPOT - IC: PPPOT - T: MITT MITIA MITOA: F-08A 50-029-20135-01 2022310 Producer The well is completed with 7" N-80 tubing and is currently secured with an 'ISP' set at 10,804' md (12/8/05) in the 3-3/16" liner. 3,175 psi @ 8800' TVDss Ivishak 210 of @ 8800' TVDss 7", 26#, N-80 TC4S tubing with 7" x 2-%" Weatherford Arrow Pac patch system at -4,012' md. IBP set at 10,804' md (12/8/05) 12,740' md/12,705' md (CTD sidetrack) 2,700' I 11,053' md 6.6°/100' @ 6,692' md 55.75° at 9,525' md McEvoy 13-%" x 13-%" 5M McEvoy 12" x 7", wi 7" IJ4S Top and Bottom CIW 13-%" x 7-1/16" 5M 6" CIW 5M 6-%" J profile 7" Otis SSSV Nipple @ 2,043' md 2 x W' Stainless Steel -38 (one per joint down to 2,043") NIA See schematic for perforation details. Seawater I Diesel Seawater I Diesel Unknown PASSED 1/18/2006 I 5,000 psi T x IA Communication FAILED 3/9/2006 I 3,000 psi(LLR too small); IAxOA communication. FAILED 3/9/2006 I 3,000 psi 2. Materials Required for Workover Operations Casing Repair: :52,100' 9-%",40#, L-80 Liner, TC-II wi HES ES Cementer. 1 9-%" Seal Assembly (Re-use existing if possible) Completion: -9,600' 4-%",12.6#, 13Cr-80 Tubing, Vam Top 1 Baker, 7" x 4-%" S-3 9 Cr Packer 1 6" x 4-1/2" WLEG 1 Baker, 9-%" x 4-W' S-3 9Cr Packer 3 4-%" 'X' Nipples, 3.813" ID, chrome 1 4-%" 'XN' Nipple, 3.75" ID, chrome 2 4-%" x 1-W' MMG 9Cr GLMs (1 w/DGLV, 1 wi Shear) CID 67901 1 McEvoy 13-%" x 4-1/16" adapter flange, 5M F-GSA RWO AFE # PBD4P9260 Page 2 . . CID 282293 1 McEvoy Tubing hanger, 4-%" TC-II top / VAM TOP bottom threads McEvoy 13-%" x 13-%" 5M Tubing Spool with 9-%" YBT secondary pack-off. McEvoy 9-%" Emergency Slips 4-1/16" 5M Carbon CIW Tree CID 67883 CID 67919 CID 67640 CID 69517 3. Short Scope Well F-08A is a GD well that is currently shut-in for IA x OA communication. Due to 11-%" x 9-%" Thermocase in the OA the well cannot sustain a sufficient pressure test in order to obtain a waiver. Therefore, the requested RWO is required to return the well to production. The primary objective of the RWO will be to remove the Thermocase from the well and replace it with 9- %" casing in order to mitigate current IA x OA communication. 4. Hazards and Contingencies 4.3 HYDROGEN SULFIDE ( Reference SOP: Hydrogen Sulfide) · F-pad is considered an H2S pad; standard operating procedures for H2S precautions should be reviewed and followed at all times. 4.2 WELL CONTROL PRESSURES · Max. anticipated BHP: · Max. anticipated surface pressure: · Planned completion fluid: 3,175 psi (7.0 ppg EMW) @ 8800' tvd - Ivishak 2,295 psi (BHP + full gas column at 0.1 psi/ft) 8.45 ppg sea water / 6.8 ppg diesel 4.3 SIMOPS (Reference SOP: DrillingIWorkover Close Proximity Surface and Subsurface Wells) · There are three (3) wells in relatively close proximity: - F-38 is -35' to S; - F-36 is -68' to S; - F-20 is -70' to N F-08A RWO AFE # PBD4P9260 Page 3 . . 5. Casing I Tubing Program 5.1 Present CasinglTubing Program: Casingrrubing Wt/Ft Grade Conn Top Bottom 13-%" 72 NT -80 BTC Surface 2,700' 11-3,4" x 9-%" - ThermoCase BTC Surface 147' 10-%" 55.5 N-80 BTC 147' 2,022' 9-%" 47 N-80 BTC 2,022' 2,106' (PBR) 9-%' 47 N-80 BTC 2,106' 10,087' 7" 29 N-80 BTC 9,556' 11,053' T.O.W. 3-3/16" Liner 6.2 L-80 10,363' 11,101 ' 2-%" Liner 6.16 L-80 11,101' 12,740' 7" Tubing 26 N-80 TC4S Surface 9,596' 5.2 Proposed CasinglTubing Program: 9-%" Tie-back 40.0 L-80 TC-II Surface -2,106' 4-112" Tubing 12.6 13Cr-80 Vam Top Surface -9,600' 6. Pre I Post RWO Work 6.1 Pre-Rig Work Request: Check the tubing and IC casing hanger lock down screws for movement. Completely back out 0 1. and check each LDS for breakage. PPPOT T & IC. NOTE: Well is currently SECURED with a IBP. 0 2. RU Service Coil. RIH wi SSSV insert retrieving tool. POOH and LD insert. Records indicate that this has been done -12/4/02. RIH with Arrowpack retrieving tool. Retrieve upper packer and GLM. LD upper assembly. 0 3. RIH with Arrowpack retrieving tool. Retrieve anchor packer. LD anchor packer. RDMO Service Coil. S 4. PulllBP @ 10,804' ELM. E 5. Run SCMT in 3-1/16" liner from 1 0,450' to 11, 075'. E 6. Set Fast Drill Plug @ 10,804' md. vr E 7. RIH wi Chem Cutter. Cut 3-3/16" liner @ 10,440' md. E 8. RIH wi 5-%" Chem cutter. Cut 7" tbg @ -9,500' md. 0 8. Set BPV and level pad as necessary. 6.2 Post-Rig Work: 0 1. Install flow line and re-set wellhouse & retrieve BPV. S 2. Retrieve ball & rod. Pull RHC body. Run GLV's. S 3. Drill Fast Drill plug @ 10,804' md wi service coil. F-oSA AWO AFE # PBD4P9260 Page 4 . . 7. F -08A RWO Detailed Operations * NOTIFY AOGCC REPRESENTATIVE 24 HOURS PRIOR TO WITNESS BOP TESTING * 7.1 Note tubing and annular pressures (trapped gas). Bleed-off as required prior to MIRU. MIRU 7ES. RU to the tree to circulate out the diesel freeze protection. Pull BPV with lubricator. Confirm the amount of diesel used to freeze protect on the handover form. Circulate out the diesel freeze protection and displace with hot 120 of seawater. Note - Increased focus on Barrier Policy Guidelines has prompted changes in the way barriers are confirmed. Refer to attached Well Barrier Policy Guidelines prior to removing the tree or BOP stack. 7.2 Have Wellhead Crew / Valve Crew set TWC; test below to 1,000 psi /10 min. and above to 3,500 psi / 10 min. Chart, notate and sign. ND tree and adapter flange. Send tree and adapter in for inspection and/or repairs as needed. The adapter and tree will not be re-used on this well. NORM test all well head and completion equipment. Reference 'Decomoletion' RP for details. 7.3 NU BOPE. Have 3-%" x 6" and 4-%" x 7" variables rams installed. Test the BOPE to 250 psi low / 3,500 psi high. Test the annular to 250 psi low 12,500 psi high. Have Wellhead Crew / Valve Crew pull the TWC with lubricator. 7.4 PU landing joint or spear and recover the tubing hanger. Pull and lay down the tubing hanger. Send in the hanger for inspection. Inspect all completion equipment for NORM. Reference: RP 'Decomoletion '. Pull and lay down the 7" L-80 tubing down to the cut. Do not exceed 80% of the 7" tubing tensile rating (Yield at 100% is 604,000 Ibs). NOTE: Estimated string weight in seawater down to the cut point at 9,500' is -214,547# + the blocks, etc. There are dual X" stainless steel control lines and 48 stainless steel bands (one per joint) to the SSSV @ 2,043'. NOTE - Tubing is not planned to be salvaged unless the condition of the pipe warrants consideration for future use. 7.5 RIH w/ spear on drill pipe. Spear Baker C-2 liner tie back sleeve wI an ITCO spear and 3.952" grapple. POOH w/7T of 5-%" (10 = 4.0") x 3-W x 3-3/16" liner. 7.6 RIH with Dress Off / Casing Scraper to top of tubing cut at -9,500' md: · 6" x 4-1/2" 1.0. Shoe · Dressing Mill & Extension · 9-%" 47# casing scraper · Junk baskets · 7" 29# casing scraper · Junk baskets · Drill Collars · Jars RIH to 7" x 4-W OTIS WO packer @ 10,435' with 6" x 4-1/2" 10 shoe, dressing mill and extension with 9-%" 47# casing scraper, junk baskets, 7" 29# scraper, collars and jars. Establish string weights and slowly work pipe until returns and junk baskets are clean. Reverse circulate the wellbore clean with heated seawater and hi-vis sweeps as required. This run is designed as a scraper / gauge run; if excessive rotation or clean out is necessary, a designated clean out/mill run will be necessary. POOH 7.7 RIH w/ string shot; locate and fire across 9-%" seal stem. POOH and RID SWS. 7.8 RIH with 9-%" HES RBP on Drillpipe; set RBP at -2,300' md. Release from RBP and turn well over to 1200 9.8 ppg NaCI brine. Monitor IA and OA pressures while turning well over to warm brine. Pressure test to 2,500 psi for 15 minutes. Bleed off lAP and OAP as required. POOH. 7.9 Run one joint of 7" through stack and dump -2,200# of 20/40 mesh river sand (-50 ft) on top of RBP. LD joint. F-08A RWO AFE # PBD4P9260 Page 5 . . 7.10 Confirm no gas pressure in 13-%" x 9-%" annulus. Set RTTS. NO BOPE and set back. NO McEvoy 13-%" x 13-%" tubing spool wI secondary pack-off bushing. Install handles on slips to ensure that the slips stay together and come out on the first collar of the 9-%" casing. NU spacer spool/ BOPE and test. 7.11 RIH with spear and packoff. Spear 9-%" casing. BOLDS and pull slips w/ primary pack-off to floor unseating seals from PBR @ 2,106' md. a. If 9-% intermediate casing cannot be pulled from PBR, RU Baker mechanical cutter. Cut in the middle of the second joint above the PBR. At this point the back off tool and screw in sub method will be used. NOTE: Upper 3 joints of the production casing are Thermocase II. Below the Thermocase the string crosses over to 10-0/4" to -2,200' before the string crosses back to 9-%" for -100' before the cut / seal assembly. 7.12 Establish circulation up the 13-%" x 10-0/4" annulus. NOTE: Records indicate that Arctic Pack has been flushed with diesel (8/14103). Take returns to closed tiger tank with gas-vent baffle in place. If able to establish circulation, pump hot 9.8 ppg NaCI brine to clean up annulus. Pump heated diesel into the 13-%" x 10-0/4" annulus. Allow diesel to soak for minimum of 30 mins. Circulate annulus clean with heated 9.8 ppg NaCI brine. 7.13 Monitor 13-%" x 10-%" annulus for possible gas break-out. Consider keeping return line from 13-%" x 10-0/4" annulus open through choke, to minimize chance of gas build-up. 7.14 Confirm no gas Dressure in annulus. POOH with Thermocase II x 10-%" x 9-%" casing down to seals. Be aware of trapped pressure when breaking out the Thermocase. Note on the morning report the overall condition of the casing. Send in 9-%" seal assembly to be inspected for the 9-%" tieback job. Caliper 00 of seal assembly to determine proper 00 of dressing mill for the PBR. 7.15 RIH with dressing mill and 13-%" scraper to top of PBR. Consider staging in to help remove the Arctic Pack. Clean well bore with hot 9.8 ppg NaCI brine alternating with heated diesel (if needed) until clean. If needed, pump a Safe-Surf-O (mixed in fresh water) pill. 7.16 Obtain PU, SO, and rotating parameters. Dress off PBR as per Baker fishing rep. Circulate annulus clean with clean heated 9.8 ppg NaCI brine. 7.17 Clear floor and R/U to run to run 9-%" tie-back string. RIH with the following 9-%" casing assembly: · 9-%" Baker seal assembly (re-used) with handling pup if needed · 9-%" HES baffle plate · 9-%" pup joint · 9-%" Halliburton BTC ES-Cementer set to shear at 3,300 psi (6 shear pins) ('Bakerlok' all connection below ES cementer); · 9-%" pup joint (if needed) · -10'-30' 9-%", 40#/ft, L-80, TC-II casing pup, re-thread pin end BTC. NOTE: size this pup to enable cementing head to be at a reasonable working height on the rig floor when casing is made up downhole AND to ensure a connection is NOT across pack-off setting depth/rough cut depth in wellhead. ('Bakerlok' this joint into the ES cementer) · 9-%", 40#/ft, L-80 TC-II casing (make-up torque = 12,600 ft-Ibs). Torque-turn TC-II connection to ensure proper make-up. Place one free floating centralizer per joint of casing (above the ES cementer) except the last joint at the wellhead. · 9-%" BTC pin x 9-%" TC-II pin cross-over for cementing head. Take all the normal precautions while running the premium casing: clean threads if contaminated, use a stabbing guide, single joint compensator, properly dope and hand-start each pin. Use Jet Lube Seal Guard thread compound and torque turn each connection. Casing should arrive on F-oSA RWO AFE # PBD4P9260 Page 6 . . ¡location with the proper thread dope. Confirm type of thread co~pound prior to RIH. "Use "Jet Lube Seal Guard" Thread Compound on TC-II connection** **Clean casing threads before applying new Jet Lube Seal Guard** **Optimum 9-%", 40# TC-II Make-up Torque is 12600 ft-Ibs** 9-%" 40# L-80 TC-II Collapse Burst Tensile ID Make-up Torque 100% 3,090 psi 5,750 psi 916,0001b 8.835" ID 12,600 ft-Ib opt 13,600 ft-Ib max 80% 2,472 psi 4,600 psi 732,800 Ib 8.679" drift 11,600 ft-Ib min 7.18 Obtain PU and SO weights. RU circulating head and establish circulation. Sting into PBR while pumping to verify that the seal assembly is on depth. Shut down pumps and mark pipe. Space out seal assembly ±2' from being fully inserted. Unsting from PBR and pump bottom plug to baffle adapter. 7.19 Pressure test casing to 2,000 psi for 30 minutes on chart. Bleed off pressure and sting back into PBR. Pressure up and shear open ES cementer. 7.20 MIRU Schlumberger cementers. Make up HES cementing head to 9-%" casing. Returns will be taken through the side outlet valve(s). PT cementing lines to 4,500 psi. Open cementers to the 9-%" casing. Establish circulation with 50 bbls warm 9.8 ppg brine. Have cementers ready to pump immediately after pumping the brine. DO NOT USE FRESH WATER! 7.21 Pump 15.8 ppg Class G cement w/ 'GasBlok'; thickening time of 6 hours at 80° F BHST. NOTE: Cement volume to be determined based on annular volume of new 13-%" x 9-%" tieback string, plus 15 bbls. Drop ES-Cementer closing plug. Switch to rig pump and displace to ES-Cementer with 9.8 ppg brine at 5 - 6 BPM. Keep pump pressure under 3,000 psi while displacing cement. 7.22 Slow pumps to % bpm as plug approaches ES cementer. Bump plug and close ES-Cementer. Overdisplace cement if needed to bump plug. Shut-down pumping. Verify cement returns from 9-%" x 13-%" annulus. Grab samples of cement to check setting up progress and for UCA analysis. 7.23 Check for flow up 9-%" casing. If no flow, then break out cementing equipment. Flush side outlet valve(s) with diesel to remove cement. Time is of the essence for changing the spool piece, setting the wellhead slips and packoff. Ensure all personnel and equipment are aware of the scope of work and are available for the wellhead work. 7.24 As soon as possible after cementing, break stack and set McEvoy 9-%" slips/packoff per McEvoy wellhead specialist. Slack off and set string weight on slips. RILDS and make cut on 9-%" with Wachs cutter. LD 9-%" casing. Set back BOP stack. Remove spacer spool and NU McEvoy spool w/ secondary seal. 7.25 NU BOPE. Test casing hanger flange and pack-off seals to 2,400 psi (80% of new L-80 9-%" 40#/ft casing). After 6 hrs WOC, test BOPE to 3,500 psi. Do not pressure test against the casing. Cement UCA must be 1,000 psi or higher before RIH. Verify UCA results with Schlumberger lab. 7.26 RIH with 8-W' bit, boot baskets, 9-%" scraper on drill collars and jars. Place boot baskets below scraper in BHA. Drill up ES-Cementer closing plug and remaining cement in 9-%" casing down to the baffle adapter. Test 9-%" casing to 3,500 psi for 30 charted minutes. Continue RIH and drill up baffle adapter. Control drill while drilling out cement, plugs, and ES cementer in order to minimize debris size on top of sand plug. Seawater can now be used. Pump 20 bbl sweeps as needed to clean hole. Wash down to sand on top of RBP. CBU with final hi-vis sweep. POOH. 7.27 RIH with reverse circulating junk basket to top of RBP and circulate clean. POOH. 7.28 RIH with RBP retrieving tool and reverse off of RBP. Latch and unseat RBP. Circulate bottoms up and POOH with RBP. 7.29 Clear floor and RIU to run 4-%", 12.6#/ft, 13Cr-80 Vam Top tubing with Baker 9-%" x 4-W' S-3 packer and tailpipe. Rabbit the tubing and jewelry before RIH. See the attached 'Proposed Completion F-08A RWO AFE # PBD4P9260 Page 7 . . Schematic'. See RP Handlinq and Runninq 13 Chrome and Como/etion Desiqn and Runninq. Take all the normal precautions while preparing and running 13Cr tubing: · Use Torque-Turn' services for all tubing connections; · Rabbit the tubing and jewelry before RIH; · Ensure threads are clean of any contamination prior to applying thread compound; · Use a stabbing guide; · Use on Iv 'Jet Lube Seal Guard' thread compound · Confirm thread compound used prior to RIH; tubing should arrive on location with same; · Properly dope each pin w/ Jet Lube Seal Guard onlv; · Hand start each pin. Run completion string as follows: · 6" x 4-1/2" 9Cr VAM TOP Unique Machine Overshot · 10' 4-%,'12.6# 13Cr-80 VAM TOP pup · 4-%" "XN" nipple, 9Cr, 3.75" 10 · 10' 4-%" 12.6# 13Cr-80 VAM TOP pup · 10' 4-%" 12.6# 13Cr-80 VAM TOP pup · 4-%" "X" nipple, 9Cr, 3.813" 10 with RHC sleeve installed · 10' 4-%" 12.6# 13Cr-80 VAM TOP pup · 10' 4-%" 12.6# 13Cr-80 VAM TOP pup · Baker 9-%" x 4-%" Chrome 8-3 permanent packer -9,536' md · 10' 4-%" 12.6# 13Cr-80 VAM TOP pup · 1 joint, 4-%" 12.6# 13Cr-80 Vam Top tubing · 10' 4-%" 12.6# 13Cr-80 VAM TOP pup · 4-%" "X" nipple, 9Cr, 3.813" 10 · 10' 4-%" 12.6# 13Cr-80 pup · -43 jts 4-%" 12.6# 13Cr-80 VAM TOP tubing · 10' 4-%" 12.6# 13Cr-80 pup · 4-%" x 1-1/2" GLM #1, MMG w/ DGLV @ -7,654' md /6,500 tvd · 10' 4-%" 12.6# 13Cr-80 pup · - 91 jts 4-%" 12.6# 13Cr-80 VAM TOP tubing · 10' 4-%" 12.6# 13Cr-80 pup · 4-%" x 1-1/2" GLM #2, MMG w/2,500 psi OCR shear valve @ -3,800' md /3,750' tvd · 10' 4-%" 12.6# 13Cr-80 pup · -37 jts 4-%" 12.6# 13Cr-80 VAM TOP tubing · 10' 4-%" 12.6# 13Cr-80 pup · 4-%" "X" nipple, 9Cr, 3.813" 10 at -2,200' md · 10' 4-%" 12.6# 13Cr-80 pup F-08A RWO AFE # PBD4P9260 Page 8 . . · - 51 jts 4-%,'12.6# 13Cr-80 VAM TOP tubing · 4-%,'12.6# 13Cr-80 VAM TOP space out pups · 1 jt 4- %" 13Cr V AM TOP tubing · McEvoy 5-seaI12" x 4.5" Tubing hanger wITC-1I x VAM TOP Pn x Pn cross-over pup bucked on. "Use "Jet Lube Seal Guard" Thread Compound** **Clean tubing threads before applying new Jet Lube Seal Guard** "Optimum VAM TOP Make-up Torque is 4440 ft-Ibs** ** Optimum VAM TOP Make-up Torque is 4500 ft-Ibs **Baker-Loc ALL tailpipe connections** 4-%" 12.6# Collapse, Burst, Tensile, MAKE-UP TOROUE VALUES 13Cr-80 psi psi Ib ID V AM-TOP 100% 7,500 psi 8,430 psi 288,0001b 3.958" 10 4,440 ft-Ib opt 4,880 ft-Ib max 80% 6,000 psi 6,744 psi 230,000 Ib 3.833" Drift 4,000 ft-Ib min 7.30 Rig LRS hot-oil unit and heat all seawater to 120 of. Reverse circulate the well with 150 bbl of seawater and 525 bbl seawater w/ corrosion inhibitor at 3 BPM. 7.31 Land the tubing hanger and RILDS. Lay down landing joint. Test tubing hanger packoff to 5,000 psi. 7.32 Drop the ball & rod and set the packer. Increase the pressure and test the tubing to 3,500 psi for 30 minutes. Bleed off the tubing to 1,500 psi. Test the IA to 3,500 psi for 30 minutes. Bleed off the tubing and shear the OCR valve. Chart, notate and sign all pressure tests. 7.33 Have Wellhead Crew / Valve Crew set TWC and test below to 1,000 psi /10 min. and above to 3,500 psi /10 min. NO BOPE and NU adapter flange and tree. Test to 5,000 psi. 7.34 RU lubricator and pull TWC. RU hot oil pump and freeze protect the tubing and IA to -2,000' with:t 140 bbl of diesel. 7.35 Install BPV and test to 1,000 psi. Secure the tree and cellar. 7.36 RDMO. I * COMPLETE POST-RIG INSPECTION WITH PAD OPERATOR PRIOR TO RIG MOVING OFF THE WELL * I F-08A RWO AFE # PBD4P9260 Page 9 .fREE = ... ELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = . 6"CIW McEVOY OTIS 54.79' 34.92' 3200' 94 @ 11575' 11053' 8800' SS F-08A NOTES: INCLINATION EXCEEDS 70° @ 11295'. PROD CSG INCLUDES THERMOCASE II, PUBLISHED COLLAPSE 2070 PSI 19-5/8" X 11-3/4" CSG, THERMOCASE II I 110-3/4" CSG, 55.5#, N-80, ID = 9.953" I 19-5/8" CSG, 47#, N-80, ID = 8.681" I 113-3/8" CSG, 72#, N-80, ID = 12.347" I Minimum ID =2.372"@ 11101' 3-3/16" X 2-7/8" XO 17" TBG, 26#. N-80, .0383 bpf, ID = 6.276" 9596' 19-5/8" CSG, 47#, N-80. ID = 8.681" I 10087' I TOP OF CEMENT I 10760' I TOP OF WHIPSTOCK H 11053' I I BAKER MOD K BRIDGE PLUG I 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 11275' 11303' ÆRFORA TION SUMMARY REF LOG: SWS MEMORY CNUGR OF 12-19-02 ANGLEATTOPÆRF: 89 @ 12000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 4 12000 - 12182 C 12/20/02 2" 4 12380 - 12694 C 12/20/02 DATE 09/08/76 12/21/02 04/17/03 OS/27/03 11/09/05 12/02/05 REV BY COMMENTS ORIGINAL COM PLETION DAC/KK CTD SIDETRACK (F-08A) PlNElTLH TBG PUNCH BJM'TLP GLV C/O, PATCH DTRlPJC GL V C/O ???/TLH GLV C/O (11/25/05) DATE 12/08/05 01/21/06 05/11/06 . 7" ARROW PAC PATCH (WFO) W/2-7/8" SFO - 1C1 GLM -iTBG PUNCH,S HOLES (04/17103) I -i 7" 40' PBR I -i 7" PKR, LNR HGR I -15-3/4" BKR C-2 LNR TIE BACK SLV, ID = 4.0" -i3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" , -i3-1/2" HES XN NIP, ID = 2.750" I -i3-1/2" X 3-3/16" XO, ID = 2.800" I -i7" X 4-1/2" OTIS WD PKR, ID = 4.0" (B8-iIND LNR) -i4-1/2" OTIS X NIP, ID = 3.813" (B8-iIND LNR) I 4-1/2" OTIS XN NIP, ID = 3.800" (MILLED 12/04/02) (B8-iIND LNR) 10447' -14-1/2" W/LEG (B8-iIND LNR) I 10804' ELMD -f2-1/8" BKR IBP (12/8/05) I MILLOUT WINDOW 11066' - 11074' -f 3-3/16" X 2-7/8" XO, ID = 2.372" I 3-3/16" LNR, 6.2#, L-BO, .0076 bpf, ID = 2.80" 12-7/8" LNR, 6.16#. L-80, .0547 bpf, ID = 2.372" I REV BY COMMENTS DFRlPJC SET BKR IBP @ 10804' JKS/PAG SSSV INSERT PULLED (12/03/02) RUvVTLH THERMOCASE CORRECTION PRUDHOE BA Y UNIT WELL: F-08A ÆRMIT No: ~02231 0 AA No: 50-029-20135-01 SEC 2, T11 N, R13E, 2570' SNL & 2877' WEL BP Exploration (Alaska) ;fREE = 1>. ELLHEAO = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MO = Datum NO = ~08A Pre-Rig 6" CrN fv1cEVOY OTIS 54.79' 34.92' 3200' 94 @ 11575' 11053' 8800' SS I 9-5/8" X 11-3/4" CSG, THERMOCASE" I 110-3/4" CSG, 55.5#, N-80, 10 = 9.953" I 19-5/8" CSG, 47#, N-80, 10 = 8.681" I 113-3/8" CSG, 72#, N-80, 10 = 12.347" I Minimum ID = 2.372"@ 11101' 3-3/16" X 2-7/8" XO 9516' 9596' ICHEM CUT 7" TBG W/5-3/4" CUTTER 17" TBG, 26#, N-80, .0383 bpf, 10 = 6.276" 19-5/8" CSG, 47#, N-80, 10 = 8.681" I 10087' I TOP OF CEMENT I a-evnJr33'161FJ3W 2-3'8Q.J1lffi MILLOUT WINDOW 11066' - 11074' I 7" LNR, 29#, N-80, .0371 bpf, 10 = 6.184" I DATE 09/08/76 12/21/02 04/17103 OS/27/03 11/09/05 12/02/05 11303' PERFORA TION SUMMARY REF LOG: SWS MEMORY CNUGR OF 12-19-02 ANGLEATTOPPERF: 89 @ 12000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz OA TE 2" 4 12000 - 12182 C 12/20/02 2" 4 12380 - 12694 C 12/20/02 REV BY COMM8\lTS ORIGINAL COM PLETION DAC/KK CTD SIDETRACK (F-08A) FWElTLH TBG A.JNCH BJIINTLP GLV C/O, PATCH OTRIPJC GL V C/O ???/TLH GLV C/O (11/25/05) DATE 12/08/05 01/21/06 05/11/06 NOTES: INCLINATION EXCEEDS 700 @ 11295'. PROD CSG INCLUDES THERMOCASE II, PUBLISHED COLLAPSE: 2070 PSI . -19-5/8" X 10-3/4" XO I - 10-3/4" X 9-5/8" XO I - 7" OTIS SSSV NIP, 10= 3.813" I -19-5/8" PBRI 4030' I- TBG A.JNCH, 5 HOLES (04/17/03) I - 7" 40' PBR I -i 7" A<R, LNR HGR I - 3-3/16" X 2-7/8" XO, 10 = 2.372" I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.80" 12-7/8" LNR, 6.16#, L-80, .0547 bpf, 10 = 2.372" I REV BY COMMENTS OFRlPJC SEr BKR IBP @ 10804' JKS/PAG SSSV INSERT A.JLLBJ (12/03/02) RUvVTLH THERMOCASE CORRECTION PRUDHOE BAY UNIT WELL: F-08A ÆRMIT No: ~022310 API No: 50-029-20135-01 SEC 2, T11 N, R13E, 2570' SNL & 2877' WEL BP Exploration (Alaska) F-O'A Proposed Com~tion I SURFACEH ESTIMATED TOP OF CEMENT I W8...LHEAO ~ ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max An le- Datum MD = Datum NO = 4-1/16" erN fvtEVOY 54.79' 34.92' 3200' 11575' 11053' 8800' SS 19-5/8" CSG, 40#, L-80 9-5/8" CSG, 40#, L-80 TC-II, ID = 8.835", 0.0758 bpf 113-3/8" CSG, 72#, N-80, ID = 12.347" I Minimum ID =2.372"@ 11101' 3-3/16" X 2-7/8" XO 17" TBG, 26#, N-80, .0383 bpi, 10 = 6.276" 17" A<R, LNR HGR 4-1/2"TBG, 12.6#, 13CR80VAMTOP, ID = 3.958",0.0152 bpf 19-5/8" CSG, 47#, N-80, ID = 8.681" I I TOP OF CEMENT I Ii -1884 I 2106' 2700' 9546' 9599' 9600' 10087' 10760' I TOP OF WHIPSTOCK H 11053' I 1 BAKER MOD K BRIDGE PLUG 11275' 17" LNR, 29#, N-80, .0371 bpf, ID=6.184" 11303' ÆRFORA TION SUMMARY REF LOG: SWS MEMORY CNUGR OF 12-19-02 ANGLEATTOPÆRF: 89 @ 12000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 4 12000 - 12182 C 12/20/02 2" 4 12380 - 12694 C 12/20/02 DATE 09/08/76 12/21/02 04/17/03 OS/27/03 11/09/05 12/02/05 REV BY COMMENTS ORIGINAL COM PLETION DAC/KK CTD SIDETRACK (F-08A) FWE/TLH TBG PUNCH BJM'TLP GLV C/O, PATCH DTRlPJC GL V C/O ???/TLH GLV C/O (11/25/05) DATE 12/08/05 01/21/06 05/11/06 -2100 -f4-1/2"HESXNIP,ID=3.813" I GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DCK DMY DATE ST MD lVD 1 7654 6500 2 3806 3750 -14-1/2" HES X NIP. 10 = 3.813" I -i 9-5/8" X 4-1/2" BAKER S-3 A<R, ID = 4.0" -i 7" 40' PBR I -i4-1/2" HES X NIP, 10 = 3.813" -14-1/2" HES XN NIP, 10 = 3.75" -f4-1/2" x 6" WLEG I 10435' 10441' 10445' --i 7" X 4-1/2" OTIS WD A<R, ID = 4.0" (BB-IIND LNR) -14-1/2" OTIS X NIP, ID = 3.813" (BB-IIND LNR) I 4-1/2" OTIS XN NIP, ID = 3.800" (MILLED 12/04/02) (BB-IIND LNR) -14-1/2" W/LEG (BB-IIND LNR) I MILLOUT WINDOW 11066' - 11074' -i 3-3/16" X 2-7/8" XO, ID = 2.372" I PBTD -1 12705' I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" 12-7/8" LNR, 6.16#, L-80, .0547 bpf, ID = 2.372" I REV BY COMMENTS DFRlPJC SET BKR IBP @ 10804' JKS/PAG SSSV INSERT PULLED (12/03/02) RLI'vVTLH THERMOCASE CORRECTION PRUDHOE BA Y UNIT we.L: F-08A ÆRMIT No: ~02231 0 API No: 50-029-20135-01 SEC 2, T11 N, R13E, 2570' SNL & 2877' We. BP Exploration (Alaska) RE: PBU F-08A Workover . . Tom, Thanks for the input. In the attached program revision, the below mentioned issues have been addressed in the following manner: 1. The BOP will be dressed w/ 3-1/2" x 6" and 4-1/2" x 7" variables tested to 4" and 7". 2. Well will have to set an RTTS as mentioned in our phone conversation to ND the BOP and remove the stack. That step is now listed in 7.10. So the barriers will be the deep fast drill, kill weight fluid and the RTTS. We have committed ourselves to two tested mechanical barriers; kill weight fluid does not count if a tested mechanical can be achieved. 3. The way this particular pack-off works, the secondary seal will be removed when the tubing spool is removed; the primary seal rides out with the slips. So, that part of what was step 7.15 has been omitted and explained is better detail in the respective parts of the program. Please note the additional change that was made in what is now step 7.6 concerning the mill/scraper run. The intention is a only as gauge run; should excessive rotation be necessary, separate runs will be required. Any other questions, let me know. Thank s , Shane Shane Gagliardi Operations Drilling Engineer 907-564-5251 (Office) 907-632-6789 (Cell) -----Original Message----- From: Thomas Maunder Sent: Thursday, February 01, To: Gagliardi, Shane T Subject: PBU F-08A Workover Shane, As noted in our call, I am reviewing the proposed workover procedure for the well and have a couple of questions. 1. In step 7.3, you specify having 4" x 6" VBRs in the stack. There is no mention of 7" rams. A set of 7" rams is needed since you will be pulling -9500' of 7" tubing. 2. In step 7.7 you plan to ND the BOP to remove the 9-5/8" casing spool. It appears that you will have 3 barriers with the deep FAS drill, kill weight fluid and the TWC. This is the first time I've a TWC used in 9-5/8" casing. 3. It would appear that pulling the 9-5/8" packoff (step 7.15) should occur prior to unseating engaging the spear to unseat the seals from the PBR. please discuss with your colleague regarding 2 and 3. The issue in 1 is ] of2 2/2/2007 ] 0:32 AM RE: PBV F-08A Work over . . pretty clear cut. Call or message with any questions. Tom Maunder, PE AOGCC Content-Description: F-08A RWO Program Rev l.ZIP F-08A RWO Program Rev l.ZIP Content-Type: applicationlx-zip-compressed Content-Encoding: base64 20f2 2/2/200710:32 AM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc F-08A (PTD #2022310) Classified as Problem Well e Suhject: F-08A (PTD #2(22310) Classi fied as Problcm Well From: "NSLJ. AD\-\' Well Integrity Engineer" <NSLADWWclllntcgrityEngineer@;BP.com> Date: Sun, 13 No\' 2005 20:55:40 -0900 To: "Schmoyer, AI" <SchmoyAL@BP.eom>, "GPB, GCI Area Mgr" <GPBGCITL@BP.eom>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUAD\VWcIlOpcrationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@?BP.com>, "AOGCC Jim Rcgg (E-mail)..<jim_Jegg@}admin.statc.ak.us>. "AOGCC \Vinton Aubert (E-mail)..<winton_.aubcrt@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&ComplctionSupcrvisor@BP.com>, "Kurz, John" <~john.kurz@BP.com>, "GPB, GCI Wcllpad Lead" <GPBGCI WellpadLead@BP.com>, "GPB, Optimization Engr" <GPBOptll1lizationEngr@ßP.com>, "GPB, Prod Controllers" <0 PBProdControllers@BP.com> cc: "Hughes, Andrea (VECO)" <hugha4(~:~}BP.com>, "NSlJ, ADW Well Integrity Engineer" <NSUADWWelHntcgrityEngincer@BP.com>. "Reeves, Donald F" ·<RccvcsDf@BP.com>, "Frazier, Nicholas B" <fraznb@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com> e rze.t(i \1-\' ~ö& All, Well F-08A (PTD #2022310) has sustained casing pressure on the IA and has been classified as a Problem well. Wellhead pressures on 11/11/05 were 2200/2050/1080. A TIFL Failed on 11/11/05 due to IA repressurization. The plan forward for this well is as follows: 1. DHD: Isolate the gas lift line 2. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «F-08A. pdt» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com ~Ç·'·I·· \>.1<\.."" "\;.--,~ ' , ':~ !~¡¡\Mf"""¡ ";- " , ".,) ~"'.' 'H....'._ r From: Hughes, Andrea (VECO) Sent: Saturday, November 12, 2005 7:58 PM To: NSU, ADW Well Integrity Engineer Subject: F-08 New Problem Well Joe- F-08 has been found with sustained casing pressure on the IA and needs to be classified as a Problem Well. The TIO's on 11/11/05 were 2200/2050/1080. The well is a natural flow producer with a connected gas lift line that is twinned with F-38. A TIFL failed on BUR today and the gas lift line is suspect. I have notified Well Services to drop and blind the GL T line and then DHD will perform another TIFL. 10f2 12/13/2005 10:14 AM F-08A (PTD #2022310) Classified as Problem Well e e Thanks- Andrea Hughes Well Integrity Engineer Office: (907) 659-5525 Pager: (907) 659-5100 x1242 Content-Description: F-08A.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 12/13/2005 10:14 AM TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max A!::..~e = Datum MD = DatumlVO = 6" CNV McEVOY OTIS 54.79' e F-OS FETY NOTES: INCLINATION EXCEEDS 70° @ 11295'. 94 @ 11575' 11053' 8800' SS I BAKER MOD K BRIDGE PLUG I 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" . 19-5/8" CSG, 47#, N-80, ID = 8.681" 110-3/4" CSG, 55.5#, N-80, 10 = 9.953" I 113-3/8" CSG. 72#, N-80, ID= 12.347" I 1" ARROW PAC PA TCH (WFO) W/2-7/8" SFO - 1C1 GLM Minimum ID = 2.372"@ 11101' 3-3/16" X 2-7/8" XO GAS LIFT MANDRELS OEV TY Æ V LA TCH PORT OA TE 28 SFO-1 C1 BK 0 11/09/05 17" TBG, 26#, N-80, .0383 bpf, 10 = 6.276" I 9596' -1TBG PUNCH, 5 HOLES (04/17/03) -17" 40' PBR I H 7" PKR, LNR HGR I 19-5/8" CSG, 47#, N-80, 10=8.681" I 10087' I TOP OF CEMENT I 10760' -15-3/4" BKR G-2 LNR TIE BACK SL V, !D - 4.0" -13-3/4" BKR DEPLOYMENT SLV, 10 - 3.00" 1 -13-1/2" HES XN NIP,!D - 2.750" I -13-1/2" X 3-3/16" XO, !O - 2.800" I -17" X 4-112" OTIS WD PKR, 10 = 4.0" (BEH!ND LNR) -14-1/2" OTIS X NIP, 10 = 3.813" (BEHIND LNR) I 4-1/2" OTIS XN NIP, 10 = 3.800" (MILLED 12/04/02) (BEHIND LNR) -14-1/2" W/LEG (BEHIND LNR) I ITOPOFWHIPSTOCK H 11053' I -13-3/16" X 2-7/8" XO. 10 = 2.372" 1 11275' 11303' PBTO -- 12705' J PERFORA T!ON SUMrv1ARY REF LOG: SWS MEMORY CNL/GR OF 12-19-02 ANGLEATTOPPERF: 89 @ 12000' Note: Refer to Production DB for historical perf data SPF INTERV AL Opn/Sqz DA TE 2" 4 12000 - 12182 0 12/20102 2" 4 12380 - 12694 0 12/20/02 3-3/16" LNR, 6.2#. L-80, .0076 bpf. 10 = 2.80" 12-718" LNR, 6.16#, L-80, .0547 bpf, 10 = 2.372" I DATE 09108/76 12/21/02 04/17/03 OS/27/03 11/09/05 REV BY COMMENTS OR!GINAL COMPLETION DAC/KK cm S!DETRACK (F-08A) PlNEJTLH TBG PUNCH BJMlTLP GL V C/O. PATCH DTRlPJC GL V C/O DATE REV BY COMMENTS PRUDHOE SA Y UNfT WELL: F-08A PERMfT No: "2022310 API No: 50-029-20135-01 SEC 2, T11 N. R13E, 2570' SNL & 2871' WEL BP Exploration (Alaska) ) ) ,: (:~~(, (\~ ",~,,¡' ~ 1. \'}ùJ Ç)\.,\ 't WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23, 2004 RE: MWD Formation Evaluation Logs: F-08A, AK.-MW-22195 F-08A: Digital Log Images 50-029-20135-01 -# J J.3 .> 3 SCANNEO 11I011 II <) 2' oq' ¡;;; QP ~ '"'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 K.alish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: } ~J~ v ME> 1- 1LJ (J/L¡ Signed: ^ ~:^ -,.t) l. ~( , .e-. ~ò J~ oL~ ~ç-' DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2022310 Well Name/No. PRUDHOE BAY UNIT F-08A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20135-01-00 10980 12750 Open 1/9/2003 25 1-5 11071 12750 Open 2/26/2004 Rap, DGR, EWR - Horizontal Presentation - MWD 25 1-5 11071 12750 Open 2/26/2004 Rap, DGR, EWR - Horizontal Presentation - MWD 1-5 11071 12750 Open 2/26/2004 Rap, DGR, EWR - Horizontal Presentation - MWD 1-5 11071 12750 Open 2/26/2004 Rap, DGR, EWR - Horizontal Presentation - MWD Sample Set Sent Received Number Comments / MD 12750 -'//./ TVD 9043 /' Completion Date 12/20/2002 /.ø" Completion Status 1-01L ~-------~~-_.~--~ ~~------ REQUIRED INFORMATION Mud Log No Samples No ---~---._--_.~ ------------~--~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: MWD, GR, Rap, RES, Memory CNL Log/ Data Digital ~__~_ed/Fr~t ~ .(j g/ íe" ,Rpt Electr Dataset Number Name c./Neutron 0'1696 ~e(ifi~dliulI . ð1549 Neutron Lt1š Verification CD \(. i: uJ K l.f /to Y; Log Log Run Scale Media No Blu 1 1 1 <F(pt ~êctional SUNey fED C Pdf r12426 Rate of Penetration ED C Pdf 12426 Induction/Resistivity U' / ED C Lis 12426 Rate of Penetration / ED C Lis "'12426 Induction/Resistivity --.-- Well Cores/Samples Information: Name Interval Start Stop P'. I .-> Y1 Vl..-Ò. /LI ~ ~ Â. Current Status 1-01L UIC N Directional SUNey ,~ ~~.J (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments 10138 12692 Case 2/28/2003 10655 12718 Open 4/17/2003 10138 12692 Case 2/28/2003 10655 12718 Open 4/17/2003 '~/ DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permitto Drill 2022310 Well Name/No. PRUDHOE BAY UNIT F-08A MD 12750 TVD 9043 Completion Date 12/20/2002 ADDITIONAL INFORMATION Well Cored? Y /@ Chips Received? ~ Analysis Received? ~- -------------- ----~--~--- Comments: --_._~_.- ¡~ Compliance Reviewed By: Operatof.,..BP EXPLORATION (ALASKA) INC Completion Status 1-01L API No. 50-029-20135-01-00 Current Status 1-01L UIC N Daily History Received? fYvN I....:..J ~/N Formation Tops Date: ~' ~ 7 J~~J_~:';--< -~ , ') ) f)Œ)-83 \ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23,2004 RE: MWD Fonnation Evaluation Logs: F-08A, AK-MW-22195 F-08A: Digital Log Images 50-029-20135-01 1 CD Rom JåLleY Lo 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 Date: '\ Sign~~~(~ RECEIVED FJ:~p 2 6 ?f\/î4 ._~.J .....l.iv .;'\J.aska OJ! & Gas Cons. Commision A.nrh«age ~~b\\\~ " ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 05/13/03, Put on Production ) ) 1. Status of Well Ia Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2710' NSL, 2877' WEL, SEC. 02, T11 N, R13E, UM At top of productive interval 1203' SNL, 1153' WEL, SEC. 10, T11 N, R13E, UM X = 648487, Y = 5970247 10. Well Number At total depth 621' SNL, 37' WEL, SEC. 10, T11 N, R13E, UM X = 649591, Y = 5970851 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 54.8' ADL 028281 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 12/14/2002 12/18/2002 12/20/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12750 9043 FT 12707 9042 FT Ia Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, RES, Memory CNL Classification of Service Well 7. Permit Number 202-231 8. API Number 50- 029-20135-01 9. Unit or Lease Name X = 651959, Y = 5974230 Prudhoe Bay Unit F-08A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2043' MD 1900' (Approx.) 7" 3-3/16" x 2-7/8" WT. PER FT. 157.53# 72# 47# x 55.5# 29# 6.2# /6.16# GRADE Conductor N-80 N-80 N-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 80' 36" Surface 2700' 18-1/2" Surface 10087' 12-1/4" 9559' 11066' 8-1/2" 10363' 12740' 3-3/4" CEMENTING RECORD 135 sx Arcticset 3697 sx Permafrost II 1650 sx Howco Light, 200 sx Class 'G' 752 sx Class 'G' 125 sx Class 'G' AMOUNT PUllED 23. CASING SIZE 30" 13-3/8" 9-5/8" x 10-3/4" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 12000' - 12182' 9031' - 9035' 12380' - 12694' 9040' - 9042' 25. TUBING RECORD SIZE DEPTH SET (MD) 7",26#, N-80 9596' 4-1/2", 12.6#, L-80 10435' - 10447' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH (By Rig) 4030' - 4031' Tubing Punched for Gas Lift Straddle PACKER SET (MD) N/A 10435' MD TVD 27. Date First Production April 20, 2003 Date of Test Hours Tested 5/8/2003 4 Flow Tubing Casing Pressure CALCULATED Press. 188 24-HoUR RATE PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR Oll-BBl TEST PERIOD 1,837 Oll-BBl GAs-McF 2,800 GAs-McF WATER-BBl 603 WATER-BBl CHOKE SIZE 90° GAS-Oil RATIO 1,524 Oil GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RBDMS BFL MAY 1 ~, RECEIVED No core samples were taken. -~ (j;F ' . ~~1.. MAY 142003 --»2"-' 0 RIG NA- \~,,"', ')<.¡ ',',,",,;.c:'- ,~:,~~'''-~;.;:¡" '''.''; Aiasi{a OH & Gas Cons. Comf'l1ißeiÐn ,- ~ .~ Andtorage \~ Form 10-407 Rev. 07-01-80 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 25N 11098' 8892' 25P 11110' 8902' 23P 11160' 8945' 22P 11193' 8970' 21P 11226' 8992' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ J.Ai.J¿, ~ ~ Title Technical Assistant Date 05 -/3-03 F-08A Well Number 202-231 Permit No. / Approval No. Prepared By Name/Number: Terrie Hubble, 564-4628 Drilling Engineer: Thomas McCarty, 564-5278 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10.407 Rev. 07-01-80 ) ) Well: Field: API: Permit: Date F-08A Prudhoe Bay Unit 50-029-20135-01 202-231 Accept: Spud: Release: Rig: 12/11/02 12/14/02 12/20/02 Nordic #1 POST RIG WORK 01/15/03 N2 LIFT: RIH PUMPING 700 SCFM N2. STOP @ 3000',4000',5000' (WAIT FOR FLUID TO SURFACE). INCREASE N2 RATE TO 100 SCF/MIN AT 7200 FT. TOTAL OF 518 BBLS PRODUCED. JOB IN PROGRESS. 01/16/03 CONTINUE N2 LIFT. RIH TO 9200. VARY N2 RATES FROM 700 TO 1000 SCF/MIN. POH TO CHANGE OUT NOZZLES. RIH TO PERFS, JET 30 BBLS OF 1% KCL FROM 12000' - 12694' & CHASE OOH PUMPING N2 @ 1000 SCF. PARK @ 4000' ESTABLISH FLOW TO SURFACE. PCC SHUT CHOKE W/O NOTICE (LOST FLOW). RIH TO 8000'. POOH @ 150'/MIN PUMPING N2 @ 1200 SCF (ATTEMPT TO SWAB IN WELL). TOTAL RETURNS FOR THE JOB: 1100 BBLS (99% WATER WI TRACE OF OIL AND SOLIDS). WELL TURNED OVER TO APC TEST SEP. 01/17/03 T/I/O=501010 FL FOR WELL TESTING FLOW BACK. TBG FL AT 1800'. 01/21/03 FREEZE PROTECT TUBING W/80 BBLS 60/40 MEOH. 02104/03 T/I/O=50/12010 (FOR WIRE LINE) TBG FL @ 510', IA FL @ NEAR SURFACE. 03/24/03 MIRU CTU # 5, WITH TEST SEPARATOR. ATTEMPT LOAD/KILL WI FILTERED SW. WELL TOO TIGHT. SD ALLOW WHP TO BLEED DOWN. WELL BORE FLUID PACKED. PERFORM INJ. TEST @ SURFACE. - 1 BPM @ -2200 PSI. RIH WI 2" JS NOZZLE. PERFORM INJ TEST @ 11997' CTM (JUST ABOVE PERFS) 1.6 BPM @ 1750 PSI. RIH & TAG TD @ 12728' CTM. JET 79 BBLS OF 12% HCL BETWEEN 11970' - 12718. INITIAL TREATING 1835 PSI WHP/1.7 BPM, FINAL TREATING 568 PSI WHP/2.0 BPM. JET PERFS WI FILTERED SW. PUMPIJET 219 BBL OVERLFUSH SW. POST INJ TEST @ 11970': 1.6 BPM @ 700 PSI WHP. POOH FOR N2 LIFT. 03/25/03 POOH FOR N2 LIFT. BEGIN N2 @ 1000 SCF/M @ 2000'. MAKE STOPS AT 3000',3500',4000',4500',5557', 6300',7000',7500',8000',8500'. ATTEMPTED TO FLOW WELL W/O N2. WELL DIED. STAND BY FOR MORE N2. RESUME N2 @ 1000 SCF/M WHILE PULLING UP HOLE TO 7000'. PULL UP TO 6700'. MAKE STOPS @ 7300'. TOTAL FLUID RETURNED: 1264 BBLS. 03/26/03 PUMP N2 @ 1000 SCF/M. STOP @ 8100',9000' & 9800'. 1717 BBLS FLUID RECOVERED. SD N2. POOH. RDMO. 04/04/03 T/I/O=401010+ FL FOR EL. TBG FL AT 1300' (48 BBLS). IA FL AT 155' (4 BBLS). OA FL NS. 04/05/03 T/I/O: 401010 MITIA PASSED TO 3000 PSI, MITOA FAILED TO 3000 PSI. (EVAL FOR TUBING PUNCH) IA FL @ 150' (4 BBLS). FIRST ENERGY PRESSURE IA UP TO 3000 PSI (12 BBLS CRUDE). IN FIRST 15 MIN IA LOST 140 PSI. IN SECOND 15 MIN IA LOST 60 PSI FOR A TOTAL OF 200 PSI IN 30 MIN. SECOND TEST (.4 BBLS) IA LOST 40 PSI IN 15 MIN AND A TOTAL OF 60 PSI IN 30 MIN. BLED IA BACK TO 500 PSI. WHP'S: 40/50010. F-08A, Coil Tubing Drilling, Pos. ]illing Work Page 2 ) MITOA FAILED TO 3000 PSI. FIRST ENERGY PRESSURED OA UP TO 3000 PSI, IN ABOUT 1 MIN THERE WAS A POP NOISE THAT CAME FROM THE CELLAR AND OA PRESSURE DROPPED TO 2260 PSI. MONITORED SITUATION FOR ABOUT FIVE MIN WITH NO INDICATIONS OF ANY PROBLEM. OA HELD THE 2260 PSI. CAME BACK ON WITH PUMP AND WHEN OA PRESSURE GOT UP TO 2900 PSI THERE WERE MORE POPPING AND CRACKING NOISES COMING FROM THE CELLAR. IMMEDIATELY SHUT DOWN PUMPING AND BLED OA BACK TO 0 PSI. IA PRESSURE INCREASED FROM 500 PSI TO 700 PSI WHILE PRESSURING UP OA. DID NOT SEE ANY INDICATION OF IA X OA COMM. CELLAR ICE HAS A MOUND (LOOKING AT TREE THE MOUND IS TO THE RIGHT AND SLlGHL TY IN FRONT OF TREE) IN IT WITH A COUPLE OF LARGE CRACKS THAT APPEAR TO BE NEW. TAGGED OA "DO NOT PUT PRESSURE ON OA". FINAL WHP'S = 40/600/0. LOAD TBG W/ 50 BBLS CRUDE. MITIA @ 3000 PSI (PASSED). MITOA @ 3000 PSI (FAILED). 04/06/03 /1/0=40/520/0+. MONITOR WHP'S. (POST MITIA, MITOA). lAP DECREASED 80 PSI FROM YESTERDAY. 04/07/03 T/1/0=SI/500/0+. MONITOR WHP'S. (POST MITIA, MITOA). lAP DECREASED 20 PSI FROM YESTERDAY. THE CELLAR STILL HAS ICE IN IT, MAY NEED TO HAVE THE WATER VAC'ED OUT SO THAT THE ICE CAN CONTINUE TO MELT. 04/08/03 TI0=40/550/220 MONITOR WHP'S (POST MIT lA, OA). 04/16/03 T/I/O = 0+/500/180. T AND IA FLS FOR E-LlNE. TUBING FL NEAR SURFACE; IA FL @ SURFACE. 04/17/03 T/I/0=50/520/150 (PREP FOR E-LlNE) RAN A JUMPER HOSE FROM TBG TO IA TO EQUALIZE PRESSURE, PRESSURE EQUALIZED AT 50 PSI. AFTER 30 MINS. FINAL WHP'S 50/50/150. PUNCH TUBING FROM 4030'-4031' (TWO FEET BELOW COLLAR AT 4028'). DEPTH REFERENCED TO SSSV AT 2043' DD. IA LIQUID PACKED PRIOR TO JOB, CONFIRM HOLES WITH GAS LIFT JUMPER. PAD OPERATOR NOTIFIED WELL LEFT SHUT IN. 04/18/03 T/I/0=50/580/200 (POST TBG PUNCH) IA FL @ 720'. ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ACID STIMULATION 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - Stimulate _X Alter casing - 5. Type of Well: Development _X Plugging - Perforate - Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 55 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number (asp's 651958,597423:\ F-08A 9. Permit number / approval number (asp's 648487,5970247) 202-231 10. API number 50-029-20135-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool Packers & SSSV (type & measured depth) 7" - 40' Packer Seal Assembly. 7" x 4-1/2" Otis WD PKR (behind liner) @ 10435'. 7" Otis SSSV Nipple @ 2043' MD. 13. Stimulation or cement squeeze summary Intervals treated (measur~d) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl SHUT-IN Exploratory- Stratigraphic- Service- 2570' FNL,2877'FEL,Sec.02, T11N, R13E,UM At top of productive interval 1203' FNL, 1153' FEL, Sec. 10,T11N,R13E, UM At effective depth 635'FNL, 78'FEL,Sec. 10,T11N,R13E,UM At total depth 621'FNL,36'FEL,Sec. 10,T11N, R13E,UM 12. Present well condition summary Total depth: measured true vertical (asp's 649550,5970836) (asp's 649591,5970851) 12750 feet 9043 feet Plugs (measured) Effective depth: measured 12707 feet Junk (measured) true vertical 9042 feet Length Size Cemented Measured Depth 80' 30.00 135 sx ArcticSet 115' 2665' 13-3/8" 3697 sx Permafrost II 2700' 10052' 9-5/8" x 10-3/4" 1650 Howco Lite, 200 sx 1 0087' Class 'G' 1507' 7" 752 sx Class 'G' 9559' - 11066' 2377' 3-3/16" x 2-7/8" 125 sx Class 'G' 10363' - 12740' Casing Conductor Surface Production Liner SideTrack Liner Perforation depth: measured Open Perfs 12000'-12182', 12380'-12694'. true vertical Open Perfs 9031'-9035', 9040'-9042'. Tubing (size, grade, and measured depth) 7",26#, L-80 @ 9596' MD. Prior to well operation 02/15/2003 Subsequent to operation 04/07/2003 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil _X Gas - 17. I hereby certify that the foregoing i rue and correct to the best of my knowledge. Æ--4-~ DeWayne R. Schnorr SHUT-IN 16. Status of well classification as: Suspended - Title: Technical Assistant MDMS fjf ~ Form 10-404 Rev 06/15/88 . ri ;1 ':If~ ORIG,NA- NAY True Vertical Depth 115' 2700' 8176' 7866' - 8866' 8359' - 9043' Casing Pressure Tubing Pressure Service Date April 07. 2003 Prepared by DeWayne R. Schnorr 564-5174 "~ SUBMIT IN DUPLICATE ') F-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/24/2003 CTD: ACID TREATMENT; N2 LIFT 03/25/2003 CTD: ACID TREATMENT; N2 LIFT 03/26/2003 CTD: ACID TREATMENT; N2 LIFT 03/24/03 03/25/03 EVENT SUMMARY MIRU CTU # 5, WITH TEST SEPARATOR. ATTEMPT LOAD/KILL W/ FILTERED SW. WELL TOO TIGHT. SD ALLOW WHP TO BLEED DOWN. WELL BORE FLUID PACKED. PERFORM INJ. TEST @ SURFACE. - 1 BPM @ -2200 PSI. RIH W/2" JS NOZZLE. PERFORM INJTEST @ 11997' CTM (JUST ABOVE PERFS) 1.6 BPM @ 1750 PSI. RIH & TAG TD @ 12728' CTM. JET 79 BBLS OF 12% HCL BETWEEN 11970' - 12718. INITIAL TREATING 1835 PSI WHP/1.7 BPM, FINAL TREATING 568 PSI WHP/2.0 BPM. JET PERFS WI FILTERED SW. PUMP/JET 219 BBL OVERLFUSH SW. POST INJ TEST@ 11970' = 1.6 BPM @ 700 PSI WHP. POOH FOR N2 LIFT. POOH FOR N2 LIFT. BEGIN N2 @ 1000 SCF/M @ 2000'. MAKE STOPS AT 3000" 3500', 4000', 4500', 5557', 6300', 7000', 7500', 8000', 8500'. ATTEMPTED TO FLOW WELL W/O N2. WELL DIED. STAND BY FOR MORE N2. SAFETY STAND DOWN DUE TO FIRE IN DEADHORSE. RESUME N2 @ 1000 SCF/M WHILE PULLING UP HOLE TO 7000'. PULL UP TO 6700'. MAKE STOPS @ 7300'. TOTAL FLUID RETURNED= 1264 BBLS. 03/26/03 PUMP N2 @ 1000 SCF/M. STOP @ 8100',9000' & 98001.1717 BBLS FLUID RECOVERED. SD N2. POOH. RDMO. BBLS 81 472 79 333 965 Fluids Pumped METHANOL WATER SALTWATER 120/0 hel ACID (ACID TITRATION -12.2%, IRON < 50 PPM). 14000 GALS N2 TOTAL Page 1 ') WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska To: April 07, 2003 RE: MWD Fonnation Evaluation Logs F-08^ AK-MW-22195 1 LDWG fonnatted Disc with verification listing. ~I#: 50-029-20135-01 c9C8-~81 I' t;,q 10 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 Date: BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed~~~ RECEIVED ApR ..-; H." !; Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well F-08A cJD¡J,. rl~ ( J-01B ~ ~-~t)} WGI-01 I - O...~ I W-17 I X"... ûq~ F-44 I 1- 00 <x' F-21 J ~q- 0 SCtJ F-21 ..jI D.S. 9-01 I 7 tJ ,. 0 7 i(J Job # Log Description 23017 MCNL 23015 MCNL LDL TEMPERATURE PROFILE 23055 RST-SIGMA LDL PRODUCTION PROFILE PRODUCTION PROFILE/DEFT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED B 28 ""1"\1'>--' FE iVv;; Ala~ or; & Gas Cons. v)ftYf.~~ '-\:,ch~e NO. 2684 Company: 02/26/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Sepia Prints CD 12/19/02 1 11/23/02 1 02/04/03 1 02/14/03 1 01/21/03 1 02/18/03 1 02/18/03 1 02/24/03 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN:~. Re~edbY:~ . ~ ,.~'?" uf)O<2{J~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well II Oil 0 Gas 0 Suspended 0 Abandoned_,., 0. Service ~1'Tfi\rf~, 2. Name of Operator ; :,:'::'n:::::.":':;~jf;,f¡ ."~, 7. Permit Number BP Exploration (Alaska) Inc. i ,/~.!~i.§.:E...~ ~ ' ~; 202-231 3. A~.~~:x 196612, Anchorage, Alaska 99519-6612 t~j 1;. . 8. :O~~n;~r35-01 4. Location of well at surface 9. Unit or Lease Name 2710' NSL, 2877' WEL, SEC. 02, T11N, R13E, UM X = 651959, Y = 5974230 Prudhoe Bay Unit At top of productive interval ~ 1203' SNL, 1153' WEL, SEC. 10, T11N, R13E, UM X = 648487, Y = 5970247 10. Well Number ' , At total depth fb:lt '64§50Q~-.SNL, 37' WEL, SEC. 10, T11N, R13E, UM X = 649591, Y = 5970851 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 KBE = 54.8' ADL 028281 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 12/14/2002 ' 12/18/2002 ' 12/20/2002 ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12750 9043 FT 12707 9042 FT II Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, RES, Memory CNL Classification of Service Well F-08A 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2043' MD 1900' (Approx.) "V4.Jt.Kè:I.~ /~ tf) S-3 '/110 'l5fßS""~~ rvð 7" 3-3/16" x 2-7/8" WT. PER FT. 157.53# 72# 47# x 55.5# 29# 6.2# /6.16# GRADE Conductor N-80 N-80 N-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 80' 36" Surface 2700' 18-1/2" Surface 10087' 12-1/4" 9559' 11066' 8-1/2" 10363' 12740' 3-3/4" CEMENTING RECORD 135 sx Arcticset 3697 sx Permafrost II 1650 sx Howco LiQht, 200 sx Class 'G' 752 sx Class 'G' 125 sx Class 'G' AMOUNT PULLED 23. CASING SIZE 30" 13-3/8" 9-5/8" x 10-3/4" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 12000' -12182' 9031' - 9035' 12380' - 12694' 9040' - 9042' 25. TUBING RECORD SIZE DEPTH SET (MD) 7",26#, N-80 9596' 4-1/2", 12.6#, L-80 10435' - 10447' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH PACKER SET (MD) N/A 10435' MD TVD .27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE '8. CORE DATA Itl ~"'" l'" Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit colé.c~¡p~ OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) No core samples were taken. Form 10-407 Rev. 07-01-80 RBDMS BFl Submit In Duplicate ) ) 29. Geologic Markers Marker Name Measured Depth 25N 11098' 25P 11110' 23P 11160' 22P 11193' 21P 11226' 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8892' 8902' 8945' 8970' 8992' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~4ftÅt. J ~ Title Technical Assistant Date o-;;¡. I Q .03 F-08A 202-231 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Thomas McCarty, 564-5278 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 E)ate Frorn~Tö HoUrs Task Code NPT Phase PRE 12/10/2002 00:00 - 01 :45 01 :45 - 07:00 07:00 - 09:30 09:30 - 11 :00 11:00 -14:15 14:15 -19:30 19:30 - 00:00 12/11/2002 00:00 - 08:00 08:00 - 10:00 10:00 - 16:00 16:00 - 18:30 18:30 - 18:45 18:45 - 19:30 19:30 - 22:30 22:30 - 00:00 12/12/2002 00:00 - 03:30 03:30 - 05:00 05:00 - 07:30 07:30 -10:15 10:15 - 10:30 1.75 MOB P 5.25 MOB N WAIT PRE 2.50 MOB N WAIT PRE 1.50 MOB N WAIT PRE 3.25 MOB N WAIT PRE 5.25 MOB N WAIT PRE 4.50 MOB N RREP PRE 8.00 MOB N RREP PRE 2.00 MOB 6.00 MOB N N RREP PRE RREP PRE 2.50 MOB 0.25 MOB N P RREP PRE PRE 0.75 MOB P 3.00 BOPSURP 1.50 BOPSUR P 3.50 BOPSUR P 1.50 KILL P 2.50 KILL P 2.75 KILL P 0.25 REMCM-P PRE DECaMP DECaMP DECaMP DECaMP DECaMP DECaMP DECaMP Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: P$$qtiþtiQD.,.öfQp~t$tiQÄ$ Finish rig move from K-20 to F Pad. Set rig down at entrance to Pad Rig arrived with a non fixable flat on outside rear tire on off drillers side. WO well prep. E-line unit is leaving Pad and support equipment is being removed. Wellhouse is still on well I&E on location to disconnect electrical Prep injector and install gooseneck Remove wellhouse Prep reel. Pull CT to floor Shoot grade and level location Stab CT, load out used injector chains MIRU Little Red. Safety mtg re: load/kill RU to tree cap. PT 3000 psi. Liquid pack well with 900 bbls 1 % KCI water. 8 BPM, 1650 psi pump press. Nordic decides to replace flat tire before moving over well. Inspect & observe crack on flat tire rim. Source for spare rim from Price-pad & replacement tire from Doyon. Dismantle flat tire & rim. Continue dismantling flat tire & rim. Attempt to install spare rim with new tire. Threads were damaged on wheel bearing locking nut. Chase threads at machine shop. Return to rig. Attempt to make up locking nut, unable to make up fully. Back out and check threads, OK. Make up wheel bearing lock nut fully after adjusting tire/ wheel. Field crew bled down flowline to 0 psi. Re-install rig stairwell that was removed to pull tire. SAFETY MEETING. Pre-rig move meeting with all DS / Nordic personnel. Back rig over well & set down. Accept rig @ 19:30 hrs, on 12/11/02. N/U BOPE. Spot trailers & tanks. Prep for BOP testing. Grease crew pump open SSV & grease tree valves. Check WHP = 175psi. Perform initial BOPE pressure/function test. AOGCC test witness waived by Jeff Jones. Meanwhile fill rig pits with 2% KCL water. Finish BOP test with the exception of the inner reel valve. Check WHP = 200psi. Mobilize 600bls KCL water & HB&R pump for well kill. P/U injector & service pack off. Cut coil. Install Baker CTC. Pull test to 35klbs. Install dart catcher. Load wiper dart. Launch, chase & fill CT with 2% KCL. Dart hit @ 57bbls. Press test inner reel valve & CTC to 3500psi - OK. Meanwhile R/U HB&R hardlines to BOP 2" bleed line. SIWHP = 300 psi. Bullhead kill well with HB&R with 1 % KCL water at 5.7 BPM and 950 psi. At 500 bbls away, 5.6 bpm and 1000 psi. Pumped total of 706 bbls. Well dead. SAFETY MEETING. Review BHA M/U procedure, hazards and Printed: 12/26/2002 10:14:33 AM ) ") Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/12/2002 10:15 -10:30 10:30 - 11 :00 11 :00 - 12:30 12:30 - 12:45 12:45 - 14:30 14:30 - 16:10 16:10 -17:20 F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: Hours 0.25 REMCM-P 0.50 REMCM-P DECOMP DECOMP 1.50 REMCM-P DECOMP 0.25 REMCM-P DECOMP 1.75 REMCM-P DECOMP 1.67 REMCM-N HMAN DECOMP 1.17 REMCM-P DECOMP 17:20 - 20:30 3.17 REMCM-P DECOMP 20:30 - 21 :00 0.50 REMCM-P DECOMP 21 : 00 - 21 : 15 0.25 REMCM-P DECOMP 21 :15 - 21 :45 0.50 REMCM-P DECOMP 21 :45 - 23:00 12/13/2002 00:00 - 01 :00 23:00 - 00:00 01:00 - 01:15 01:15 - 01:40 01 :40 - 03:25 1.25 REMCM-P DECOMP 1.00 REMCM-P DECOMP 1.00 REMCM-P DECOMP 0.25 REMCM-P DECOMP 0.42 REMCMtp 1.75 REMCM-P DECOMP DECOMP mitigation. M/U Cement nozzle BHA #1. 2.90" Nozzle with 0.625" hole. Total length = 38.65'. RIH with BHA #1. Check injecter head chains while RIH. New Chains and Coil. Both look good. SAFETY MEETING. Review cementing procedure, hazards and mitigation with crews. RIH. Tag Whipstock at 11,121', This is 70 ft deep based on CT measured depth, but we have new Coil which may account for larger than normal depth correction. Correct depth to 11 051ft. [Pinch Point]. Pick up 10ft and flag CT at 11,041'. 47K up wt. 23K down wt. Circ 0.3 bpm with no returns. Tag Whipstock again at 11,051'. Same depth, so whipstock is not moving downhole. Rig water not hot enough to mix cement. Heat from 45F up to 65F for cementers. Communication error. Press test Cement line to 4000 psi. Circ. 24 bbls KCL water at 3.0 bpm, no returns. Cement at wt at 16:20 hrs. Stage 15.8 PPG, Class G CMT at 2 bpm. Pump total of 22 bbls CMT. Stage 5 bbls water. Displace with rig pumps with 2% KCL water at 3.0 bpm, 1270 psi, No Returns. Displace cement with 25 bbls and close choke. Bullhead last 10 bbls of KCL water in CT and First 20 bbls of CMT. Only 15 psi WHP. Lay in last 2 bbls CMT and pull to safety of 10,600'. Cement in Place at 17: 1 0 hrs. Possible top of cement at 10950' [nozzle depth with cement displaced]. No SOZ pressure seen. SIWHP = 15 psi, with no fluid returns. Fluid level = ?? Wait on Cement. Meanwhile Cementers return to base to mobilize more cement/additives for 2nd job. R/U DS Cementers Held PJSM. Review cementing procedure, HA & HM with crews. RBIH circulating @ 2.5bpm/1750psi with no apparent indication of fluid level catch-up. Tagged up @ 10685'. P/U clean @ 40k. Wash down @ 2.7bpm/1950psi from 10685' & stacked out @ 10696'. Take gassy returns to tiger tank. Having clean PIUs. Continue washing @ 10696' with 3.0bpm/2350psi - no progress. Still getting gassy returns. Review forward plan with town & decide to POOH & run GR/CCL log for depth correlation. Total fluid pumped away into tiger tank = 256bbls. POOH cement nozzle BHA #1 circ @ 1.5bpm. Flag CT EOP @ 10600'. Compressive strength of cement @ 23:05 - 250psi. Continue POOH cement nozzle BHA #1. Pumped total of 139bbls while POOH bringing total fluid pumped away into tiger tank = 395bbls. Observed cement sheath on 200' of CT & BHA. . OOH. SID pumps & observe well - stable & no gas. UD cement nozzle BHA #1. P/U memory GR/CCL logging BHA #2. RIH with BHA #2 to 10200' circ @ 0.5bpm & getting 1 :1. Suck out a total of 300bbls of fluid from tiger tank. Seems like we did Printed: 12/26/2002 10:14:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 ') Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: Date FrOIi'l~:To 'Hours Task Code NPT [)esþriptiOJlqf .Qper~ti~ris 12/13/2002 01 :40 - 03:25 1.75 REMCM-P DECOMP 03:25 - 03:50 0.42 REMCM-P DECOMP 03:50 - 04:10 0.33 REMCM-P DECOMP 04:10 - 06:30 2.33 REMCM-P DECOMP 06:30 - 07:00 0.50 REMCM-P DECOMP 07:00 - 07:15 0.25 REMCM-P DECOMP 07:15 - 07:45 0.50 REMCM-P DECOMP 07:45 - 09:40 1.92 REMCM-P DECOMP 09:40 - 11 :00 1.33 REMCM-P DECOMP 11 :00 - 11:45 0.75 REMCM-P DECOMP 11 :45 - 12:45 1.00 REMCM-P DECOMP 12:45 - 16:00 3.25 REMCM-P DECOMP 16:00 - 16:30 0.50 REMCM-P DECOMP 16:30 - 18:45 2.25 CASE P DECOMP 18:45 - 20:25 1.67 CASE P DECOMP 20:25 - 20:45 0.33 CASE P DECOMP 20:45 - 21 :00 0.25 CASE P DECOMP 21:00-21:15 0.25 STWHIP P WEXIT not loose fluid into the perfs while circulating out the gas cut KCL into the tiger tank. The difference between total fulid pumped into & sucked out from the tiger tank may be due to gas expansion. Log down from 10200' @ 30fpm circ @ 0.5bpm & getting 1: 1. See flag @ 10666.9' (46.1' deeper). Continue logging & tag up @ 10733' (37' deeper). Log up from 10733' @ 30fpm circ @ 0.5bpm & getting 1 :1. Log up to 10200'. POOH logging BHA #2 circ @ 1.0bpm & getting 1 :1. OOH. Layout SWS memory logging tools. Good Data. Tied-in PBTD = 10,685' vs CTD of previous run of 10,696', This indicates that the whipstock is on depth and not 70' deep. That depth error is from first RIH with new coil [mill scale, rust, etc]. SAFETY MEETING. Review procedure, hazards and mitigation for BHA M/U. M/U 3.80" parabolic mill BHA with straight motor, 1 jt PH6 and MHA. BHA #3 Length = 51'. RIH with milling BHA #3. Full returns while RIH. Tag CMT at 10,740' CTD and correct depth to 10,685' per SWS tie-in log. [-55' CTD]. Mill Cement bridge from 10685 - 10690'. RIH at 6 fpm, 2.7 bpm with full returns. Tagged cement at 10,835'. Milled soft cement to 10872'. Circ. Biozan sweep and continue milling CMT. Milled green cement at 3 fpm from 10,835 -10,930'. Milling green cement at 3 fpm, 2.7 bpm, full returns. Milled down to 10,965'. Back ream up to 10,660', clean. Ream down at 2.9 bpm, 2850 psi, Ream down clean to 10966'. Milling green cement at 2.5 fph, 2.9 bpm, 3150 psi. Milled to 11,037'. Stalled 4 times at same depth. Must be pinch point on whipstock. Circ. Biozan sweep at 3.0 bpm. Full returns. Back ream up to 10,650'. 3.0 bpm, full returns. Ream down to 11,037' CTD. Ream up to 10500' at 3 bpm. Slow to 2 bpm while pulling thru tailpipe. Pull from 10,400' at 3.0 bpm. pull at 80% to get any CMT out of the well. At surface, LlO mill and motor, M/U 5.937" OD BKR string stabilizer and ported nozzle. BHA #4 - Drift for Liner entry guide and possible Liner top Packer. RIH with BHA #4 - 5.937" drift. Drift went thru SSSV nipple at 2043' with no wt loss. RIH with drift. Circ. at 2.7 bpm, 1950 psi. Full returns. Circ. in 300 bbls clean KCL water and dump cement contaminated KCL water. Bled down OAP from 700 to 10 psi. lAP = 5 psi. RIH thru 7" Liner PBR at 9556' with no wt loss. Lig htly Tag top of 4-1/2" Otis Packer at 1 0481' CTD, correct depth = 10435' [-46' CTD] POH with drift. Circ. at 2.7 bpm, 1900 psi. Tag @ surface. Function/Pressure test Nordic-1 mud pump #1 with newly replaced fluid end. LID tubing drift BHA #4. Held pre-operations & pre-spud safety meeting. Reviewed well Printed: 12/26/2002 10: 14:33 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 HÒ,Ürs' Task COde NPT Phase 0.25 STWHIP P 0.75 STWHIP P WEXIT WEXIT 12/13/2002 21 :00 - 21: 15 21 :15 - 22:00 22:00 - 00:00 2.00 STWHIP P WEXIT 12/14/2002 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 00:40 0.17 STWHIP P WEXIT 00:40 - 02:00 1.33 STWHIP P WEXIT 02:00 - 02:30 0.50 STWHIP P WEXIT 02:30 - 04:30 2.00 STWHII1 P WEXIT 04:30 - 05:00 0.50 STWHIP P WEXIT 05:00 - 05:30 0.50 STWHIP P WEXIT 05:30 - 06:30 1.00 STWHIP P WEXIT 06:30 - 07:30 1.00 STWHIP P WEXIT 07:30 - 08:30 1.00 STWHIP P WEXIT 08:30 - 09:30 1.00 STWHIP P WEXIT 09:30 - 10:30 1.00 STWHIP P WEXIT 10:30 - 13:30 3.00 STWHIP P WEXIT 13:30 - 14:00 0.50 STWHIP P WEXIT 14:00 - 14:45 0.75 DRILL P PROD1 14:45 - 15:15 0.50 DRILL P PROD1 15:15 - 16:30 1.25 DRILL P PROD1 16:30 - 19:00 2.50 DRILL P PROD1 Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: , De$çriptìÒnQfØp~r~tiQr\s plan / hazards & window milling BHA M/U procedures. M/U window milling BHA #5 with Baker X-treme straight motor, string reamer, HCC DSM, 2 jts of 2-3/8" PH6 tbg & MHA. Stab injector on well. RIH with window milling BHA #5 circ 2# Biozan KCL water at 0.2 bpm, 200 psi & taking wellbore returns to tiger tank. Wt check @ 11000' : Up = 46.5k & Run-in = 19k. RIH & tag @ 11081'. Bring on pumps & circ @ 2.5 bpm/1770 psi. Recheck up wt - 48k & Run-in wt - 16k. Continue RIH & tag whipstock pinch point at 11095' CTD. O/Pulled to 70k. Ease-in & stall 2x @ 11091.3'. O/pull to 58k & 73k. Ease-in from 11090.5' with 2.9bpm/1900psi & see 200psi motor work @ 11090.7'. Assume we're at pinch point which is 4.6' from TOWS. Correct depth to 11052.6' (11048' + 4.6') & flag CT. Time-milled window to 11054' @ 0.1'/6mins with 2.9/ 2.9bpm, 1900/2200psi, 1k WOB. Continue milling to 11054.5' with 2.9/2.9bpm, 1900/2200psi, 1k WOB. P/U clean & establish freespin @ 2.8bpm/2160psi. Milled to 11055.5' with 2.8/ 2.8bpm, 2160/2670psi, 2k WOB. P/U clean & establish freespin @ 2.8bpm/2170psi. Continue milling to 11056'. Milling with 2.9/2.9bpm, 2170/2800psi, 2k WOB. Milled to 11057'. Milling with 2.9/2.9bpm, 2170/2650psi, 1 k WOB. Milled to 11058'. Milling with 2.8/2.8bpm, 2170/2350psi, 2k WOB. Milled to 11 059'. Milling with 2.8/2.8bpm, 2170/2750psi, 3k WOB. Milled to 11060'. Back ream window clean. 42K up wt. Milling with 2.8/2.8bpm, 2170/2750psi, 3k WOB. Milled to 11061'. Exit window at 11061'. Milling formation. 20 fph, 2200/2600 psi, 4K WOB, Milled to 11,071'. Swap well to FloPro. Back Ream window from 11050-11065'. Ream down across window. 1 FPM. 2.8/2.8 bpm, 2250/2400 psi. Ream window up/ down at 3 fpm. Ream window up/down at 10 fpm. Run down thru window clean with no pump. Back ream. POH with window milling BHA. Circ. out of hole while chasing FloPro to surface. Window top at 11,053', Window bottom at 11,061 '. UO Milling BHA. Cut off 25 ft of CT for fatigue management. M/U DS CTC. Pull test and press test. SAFETY MEETING. Pre-Spud meeting with all contractor personnel. Review well plan, concerns and safety issues. PJSM, Review BHA M/U procedure, hazards and M/U MWD BHA #6 with used Smith M09 Bit #2 and 2.58 deg bend motor. RIH with BHA #6. Shallow test Sperry tools at 3000 ft, OK. RIH. Set down @ top of packer. P/U & run thru. RIH to 11000'. Printed: 12/26/2002 10:14:33 AM ) ) BP".,'.EXPI..Q(=RA+IGN Qp~r~~iQ~.$..'..,$IJ""'.rtI~!t'Y...~'~.!Þør-t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: Datë Frorrl,"'..Td Houts 12/14/2002 16:30 - 19:00 2.50 DRILL P 19:00 - 19:25 0.42 DRILL P 19:25 - 20:10 0.75 DRILL P 20: 10 - 20:30 0.33 DRILL P 20:30 - 20:45 0.25 DRILL P 20:45 - 22:30 1.75 DRILL P PRODl PRODl PRODl PRODl PRODl PRODl 22:30 - 23: 1 0 0.67 DRILL P PRODl 23: 1 0 - 23:30 0.33 DRILL P PRODl 23:30 - 23:45 0.25 DRILL P PRODl 23:45 - 00:00 0.25 DRILL N SFAL PRODl 12/15/2002 00:00 - 00:50 0.83 DRILL P PRODl 00:50 - 01 :05 0.25 DRILL P PRODl 01 :05 - 01 :50 0.75 DRILL P PRODl 01 :50 - 02: 1 0 0.33 DRILL P PRODl 02:10 - 02:30 0.33 DRILL P PRODl 02:30 - 03:05 0.58 DRILL P PRODl 03:05 - 03:20 0.25 DRILL P PRODl 03:20 - 03:45 0.42 DRILL P PRODl 03:45 - 04:15 0.50 DRILL P PRODl 04:15 - 05:00 0.75 DRILL P PRODl 05:00 - 08:00 3.00 DRILL P PRODl 08:00 - 10:30 2.50 DRILL P PRODl 10:30 - 12:45 2.25 DRILL P PRODl 12:45 - 14:15 1.50 DRILL P PRODl 14:15 - 14:30 0.25 DRILL P PRODl 14:30 - 15:30 1.00 DRILL P PRODl 15:30 - 17:30 2.00 DRILL N DFAL PRODl 17:30 - 18:20 0.83 DRILL N DFAL PRODl 18:20 - 20:55 2.58 DRILL N DFAL PRODl Orient TF to LS. RIH & tag TD @ 11114'. Correct CTD to 11071'. Orient TF to 170R. Begin drilling build section with 150-140R TF, 2.7/2.7bpm, 3100/3380psi & 50fph ave ROP. Drill to 11100'. Drill to 11120' with 110R TF, 2.7/2.7bpm, 3100/3350psi & 50fph ave ROP. Saw RA pip tag @ 11080' (22' deeper). Wiper trip clean to window. PUH to 10690' for tie-in log. Log GR & tie-into Geology PDC log. Subtract 9' from CTD. RBIH & tag TD @ 11112'. Relog & saw RA pip tag @ 11071'. Corrected depths are: TOWS = 11061', TOW = 11066', RA Pip Tag = 11071', BOW =11074 '. Orient TF to 90R. Drill to 11144' with 55R TF, 2.7/2.7bpm, 3100/3500psi & 90fph ave ROP. Orient & drill to 11150' with 45R TF, 2.7/2.7bpm, 3100/3500psi & 60fph ave ROP. PUH while Sperry reboot surface computers. Orient & drill to 11189' with 30R TF, 2.7/2.7bpm, 3100/3500psi & 55fph ave ROP. Take off-btm sUNey & orient TF to 80R. Drill to 11230' with 60-70R TF, 2.7/2.7bpm, 3100/3400psi & 55fph ave ROP. Drill to 11270' with 30R TF, 2.7/2.7bpm, 3100/3400psi & 100fph ave ROP. Wiper clean to window. RBIH. Drill to 11350' with 15-20R TF, 2.7/2.7bpm, 3100/3400psi & 150fph ave ROP. Land well @ 11347'. Orient TF to 90R. Drill to 11420' with 80R TF, 2.6/2.6bpm, 3000/3350psi & 150fph ave ROP. Wiper clean to window. RBIH. Orient & drill to 11465' with 100-120R TF, 2.6/2.6bpm, 3000/3350psi & 60fph ave ROP. Stacking wt with no Motor Work. Decide to POOH for lateral BHA. POOH chasing btms up samples. Paint EOP flag @ 10900'. M/U BHA #7. Bit #3, New HYC DS49, new 1.37 deg motor, MWD and Resistivity tool. Test Resistivity tool at surface. RIH with BHA #7. Shallow test tools, OK. RIH. Tag TD at 11521'. Correct depth to 11,467' [-54']. Log up with Resistivity 1 GR at 300 FPH. 2.8 1 2.8 BPM, 2900 psi. Tied-in at RA tag [-2 ft CTD]. RIH to TD. Clean trip to TD. Orient TF to 80R. Unable to orient in build section on bottom. Pull to just below window. No Clicks. Pull into 7" liner. Try to orient, 0 clicks out of 8 trys. Orienter not working. POH to change out orienter. C/O orienter and reduce Sperry bleed sub orifice size to 14/32". RIH with BHA #8. 1.37 deg motor and Bit #4, re-run DS49 bit. SHT tools @ 3500' - OK. RIH & tag up @ top of pkr. Orient (getting 1 for 1) & run thru. RIH & tag TD @ 11518'. Correct CTD to 11465'. Printed: 12/26/2002 10:14:33 AM ') ) Legal Well Name: F-08 Common Well Name: F-08 Spud Date: 3/24/1974 Event Name: REENTER+COMPLETE Start: 12/10/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 12/20/2002 Rig Name: NORDIC 1 Rig Number: N1 IDaté Frorir~ To Hours Phase ,DØ~criptfol1 pf Qperations' 12/15/2002 20:55 - 21 :00 0.08 DRILL P PROD1 Orient TF to 11 OR. 21 :00 - 21 :10 0.17 DRILL P PROD1 Drill to 11488' with 100R TF, 2.5/2.5bpm, 3000/3350psi & 150fph ave ROP. 21:10 - 22:00 0.83 DRILL P PROD1 Attemt to orient TF to 60R - getting 3 out of 12 clicks in hi-DLS area. PUH to 11220' & retry - no success. MWD quit pulsing. 22:00 - 00:00 2.00 DRILL N DFAL PROD1 POOH for MWD. Review forward plan with town & decide to C/O MWD, LlO EWR & RBIH to drill with Dir/GR MWD only. 12116/2002 00:00 - 01 :15 1.25 DRILL N DFAL PROD1 OOH. C/O MWD & LlO EWR tool. Check bit - OK with one chip cutter probably from tagging up on top of pkr. 01 :15 - 03:30 2.25 DRILL N DFAL PROD1 RIH BHA #9 with 1.37 deg motor & re-run DS49 bit. SHT tools @ 3500' - OK. RIH & tag TD @ 11543'. Correct CTD to 11488'. 03:30 - 03:45 0.25 DRILL P PROD1 MAD pass from 11465' to 11488'. 03:45 - 04:05 0.33 DRILL P PROD1 Orient TF to 75R. 04:05 - 04:30 0.42 DRILL P PROD1 Drill to 11536' with 60-90R TF, 2.7/2.7bpm, 3200/3650psi & 150fph ave ROP. TF flopping to 1 OOR. 04:30 - 05:20 0.83 DRILL P PROD1 Orient & reorient TF to 60R. TF flopping to 100R. 05:20 - 05:45 0.42 DRILL P PROD1 Drill to 11573' with 50R TF, 2.7/2.7bpm, 3200/3450psi & 90fph ave ROP. 05:45 - 06:20 0.58 DRILL P PROD1 Orient & drill to 11612' with 90R TF, 2.7/2.7bpm, 3200/3450psi & 90fph ave ROP. Stacking & sticky. 06:20 - 07: 15 0.92 DRILL P PROD1 Wiper trip to window. RIH. Ream down from 11500' at 10 FPM. Clean hole. 07: 15 - 07:30 0.25 DRILL P PROD1 Orient TF. 07:30 - 08:45 1.25 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3600 psi, 90R, 90 deg incl, Drilled to 11,685'. 08:45 - 09:30 0.75 DRILL P PROD1 Orient TF around to 80R. TF fell down to 140R. Orient around again. 09:30 - 10:00 0.50 DRILL P PROD1 Drilling, 2.6 / 2.6 bpm, 3000 - 3600 psi, 80R, 90 deg incl, Drilled to 11,709'. 10:00 - 10:30 0.50 DRILL P PROD1 Orient TF to left side. 10:30 - 11 :00 0.50 DRILL P PROD1 Drilling, 2.6 / 2.6 bpm, 3000 - 3600 psi, 70L, 90 deg incl, Drilled to 11,732'. 11 :00 - 12:00 1.00 DRILL P PROD1 Wiper trip to window. RIH clean. 12:00-13:10 1.17 DRILL P PROD1 Drilling, 2.6 12.6 bpm, 3000 - 3600 psi, 70L, 90 deg incl, Drilled to 11,786'. 13:10 -13:45 0.58 DRILL P PROD1 Orient TF to 80 R. 13:45 - 15:00 1.25 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 3200 - 3800 psi, 90R, 92 deg incl, Drilled to 11,860'. 15:00 - 15:30 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. 15:30 - 15:45 0.25 DRILL P PROD1 Log tie-in. Added 4 ft to CTD. 15:45 - 16:20 0.58 DRILL P PROD1 RIH to TD. Clean to 11,863'. 16:20 - 17:20 1.00 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 3200 - 3800 psi, 90R, 90 deg incl, Drilled to 11,900'. 17:20 - 18:30 1.17 DRILL P PROD1 POH for 1.0 deg. motor. POH into csg @ 10904'. 18:30 - 19:00 0.50 DRILL N RREP PROD1 Fix leak in reel hardline & P/test OK. 19:00 - 20:45 1.75 DRILL P PROD1 Continue POOH. 20:45 - 21 :30 0.75 DRILL P PROD1 OOH. Check bit - 5/5/1. OK C/O bit & reset motor bend to 1.04 deg. 21 :30 - 23:50 2.33 DRILL P PROD1 RIH BHA #10 with 1.04 deg motor & a used D849 bit. RIH & tag TD @ 11909'. Correct CTD to 11900'. 23:50 - 00:00 0.17 DRILL P PROD1 PUH & orient - pulling heavy 50-60k. 12/17/2002 00:00 - 00:30 0.50 DRILL P PROD1 Continue orienting TF to 11 OL. Printed: 12/26/2002 10:14:33 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: Date FrOm.-.,To HOUrs TâSk COde NPT PhaSe q~$Gri þtiOhþf@p~ratiOh$ 12/17/2002 00:30 - 01 :20 0.83 DRill P PROD1 Drill to 11947' with 90l TF, 2.7/2.7bpm, 3200/3580psi & 40fph ave ROP. Stacking wt & pulling heavy. Start swapping well to new flopro mud with 6 ppb klagard & 4% lubetex. 01 :20 - 01:40 0.33 DRill P PROD1 Drill to 11973' with 70l TF, 2.7/2.7bpm, 3200/3580psi & 100fph ave ROP. 01 :40 - 01 :50 0.17 DRill P PROD1 Orient TF to 20L. 01 :50 - 02:00 0.17 DRill P PROD1 Drill to 12000' with 20l TF, 2.7/2.7bpm, 3200/3580psi & 110fph ave ROP. New mud out of bit. Getting clean PIUs & better wt transfer. 02:00 - 02: 15 0.25 DRill P PROD1 Orient TF to 90L. 02:15 - 03:00 0.75 DRill P PROD1 Drill to 12050' with 20l TF, 2.7/2.7bpm, 3200/3580psi & 120fph ave ROP. 03:00 - 04:00 1.00 DRill P PROD1 Wiper clean to window & RBIH. 04:00 - 04:20 0.33 DRill P PROD1 Orient & drill to 12077' with 80l TF, 2.7/2.7bpm, 3200/3580psi & 80fph ave ROP. 04:20 - 05:30 1.17 DRill P PROD1 Orient & drill to 12170' with 60-30l TF, 2.7/2.7bpm, 3000/3250psi & 120fph ave ROP. Have new mud all way round. 05:30 - 06:00 0.50 DRill P PROD1 Orient TF to 60L. 06:00 - 06:30 0.50 DRill P PROD1 Drill to 12201' with 90l TF, 2.7/2.7bpm, 3000/3300psi & 100fph ave ROP. 06:30 - 07:20 0.83 DRill P PROD1 Wiper clean to window. 07:20 - 08: 10 0.83 DRill P PROD1 log Tie-in at RA tag. Added 2 ft to CTD. 08: 10 - 09:20 1.17 DRill P PROD1 RIH to TD. Clean hole. Circ. 20 min. chasing 12,200 sample to surface. No traces of HOT seen in Geo. samples. 09:20 - 11 :30 2.17 DRill P PROD1 Drilling, 3125 - 3800 psi, 2.7/2.7 bpm, 90R TF, 120 FPH, Drilled to 12,350'. 11:30-14:10 2.67 DRill P PROD1 Wiper trip to window at 20 FPM. Circ. 3 Geo. samples to surface while tripping. 2.8/2.8 bpm, 3200 psi. Clean hole. RIH clean to TD. No traces of HOT seen in Geo. samples. 14:10 -15:45 1.58 DRill P PROD1 Drilling, 3125 - 3800 psi, 2.7/2.7 bpm, 90R TF, 100 FPH, 89 deg Incl. Drilled to 12,450'. 15:45 - 16:40 0.92 DRill P PROD1 Drilling, 3200 - 3800 psi, 2.7/2.7 bpm, 90R TF, 90 FPH, 90 deg Incl. Drilled to 12,500'. 16:40 - 18:30 1.83 DRill P PROD1 Wiper trip to window at 20 FPM. Circ. 3 Geo. samples to surface while tripping. 2.8/2.8 bpm, 3200 psi. Clean hole. RIH clean to TD. No traces of HOT seen in Geo. samples. 18:30 - 20:55 2.42 DRill C PROD1 12500', Drilling, 2.7/2.7/3480 psi. Free spin 3100 psi. TF 70l, IAP=39, OAP=350 psi. ROP50-70 fph. Good weight on bit at start of interval of 11 klbs. Down to 500 Ibs weight on bit at end of interval. 20:55 - 22:50 1.92 DRill C PROD1 12650', Wiper trip to shoe. Pickup at 42 klbs, Fairly ratty for first 100', then smotthed out. Pulling at 20 fpm to allow time for samples to reach surface. Clean all the way to the shoe. RIH at 20 fpm. Clean to bottom. 22:50 - 00:00 1.17 DRill C PROD1 Resume drilling. 2.6/2.5/3500. Pit vol=203 bbls. TF=90R. Midnight depth was 12720'. 12/18/2002 00:00 - 00:40 0.67 DRill C PROD1 12720', Continuing to drill lateral section. 00:40 - 01 :35 0.92 DRill P PROD1 12750'. This is well TD according to Geo. Wiper trip to shoe for tie in log. 01 :35 - 01 :50 0.25 DRill P PROD1 log final tie in pass over Gamma marker near window. Make -2' correction. Printed: 12/26/2002 10:14:33 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Dåte Frorn.;Tö Hours TaSk Code NPT Phase 12/18/2002 01 :50 - 02:35 0.75 DRILL P PROD1 02:35 - 02:45 0.17 DRILL P PROD1 02:45 - 06:00 3.25 DRILL P PROD1 06:00 - 06:45 0.75 DRILL P PROD1 06:45 - 07:45 1.00 CASE P COMP 07:45 - 08:15 0.50 CASE P COMP 08:15 -11:00 2.75 CASE P COMP 11 :00 - 12:30 1.50 CASE P COMP 12:30 - 13:15 0.75 CASE P COMP 13:15 -15:00 1.75 CASE P COMP 15:00 - 15:40 0.67 CASE P COMP 15:40 - 16:20 0.67 CASE P COMP 16:20 - 20:10 3.83 CASE P COMP 20: 1 0 - 20:45 0.58 CASE P COMP 20:45 - 21 :15 0.50 CEMT P COMP 21 : 15 - 21 : 30 21 :30 - 22:55 0.25 CEMT P 1.42 CEMT P COMP COMP Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: péscriþtton .of..QÞ~rÇitiqri$ Run back to bottom. Tag up on bottom at 12748'. Drill 2 more feet. TD well at 12750'. 12750', POOH to run liner. Clean PU off bottom at 42 klbs. Clean in open hole. Paint EOP flags at 10300', and 8600'. Tag up at surface. Rig down drilling BHA. Rig up floor I pipe shed to run liner. SAFETY MEETING. Review procedure, hazards and mitigation for running liner. M/U 55jts of 2-7/8", 6.16#, L-80, STL Liner. Stop atjt#40 and fill liner. Run remaining 2-7/8" Liner. M/U 23 jts of 3-3/16",6.2#, L-80, TCII Liner. M/U 3..5" HALCO XN Nipple, No-Go = 2.75". M/U 2,3.5" STL pups, M/U BKR Deployment sub and Baker C-2 Liner Tie Back Sleeve for 6' seal assembly and Baker 5.75" Fluted Entry Guide [4.00" ID]. M/U Baker CTLRT and CTC. RIH with 2-7/8" /3-3/16" Liner on BKR CTLRT. Total length = 2388 ft. Ran down thru window with no wt loss. Up Wt. = 55K, Dwn Wt. = 20K. Sat down twice at 12570'. RIH and sat down at 12720', 4 times. Sat down at 12735', 5 times. Work down to final corrected TD of 12,750', [12,755' CTD]. Liner landed on bottom. PBTD = 12,716'. Insert 5/8" steel ball to release from liner. Displace with FloPro at 2.3 bpm, slow to 1 bpm at 36 bbls. Ball on seat at 46.5 bbls. Sheared at 3800 psi. Pick up free at 36K. Stack back weight on liner top. Circulate well to 2% KCL water with double friction reducer. 3.0 bpm at 2400 psi. Full returns with FloPro in open hole. 95% returns with KCL water in open hole. 3.3 bpm I 3.1 bpm with KCL water, 1900 psi. Well completely swapped to KCL. 172 bbls in pits. Release all Vac trucks, MIRU DS cementers. Rig up same. Current IAP=12 psi, OAP=171 bbls. Circulating at minimum rate to keep hole full and minimize losses. 0.3 bpm in, 0.2 bpm returns. Safety meeting prior to pumping cement job. Attended by rig SWS and Nordic crews, SWS cementers, Peak Vac truck driver, SWS team leader, BP Co Man. Note simultanious operations occuring on the rig. Nordic changing tire on off driller side rear tire. Not in conflict with cementing operations. Continue to circulate while cementers batch up. Cement up to weight, down on pumps. Pump 4 bbls water to warm cementers lines. PT to 4000 psi. All ok. On line with cement. Pump cement into coil at 2.5 bpm, 1300 psi, returns 2.2 bpm. Pump 25.4 bbls thru MM. Drop dart. Chase with water. Catch fluid, displace cement at 2.9/2.6/1823. Pump 20 bbls water, swap to bio and pump 30 bbls. Swap back to water. Land dart at 58.1 (coil vol=59.5). Landed liner wiper plug at 14.8 bbls (Calculated volume=15.12 bbls). Bump plug to 2000 psi. Check floats, ok. Unsting from seals at pickup Printed: 12/26/2002 10: 14:33 AM ) ) BPE~PLORATION øÞê:r~ti.~,.Q$'SUIl1I"f1'.ê¡I.,.ry.'..,.R~þgr't Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: phase D~sçriptj()n bfQperatiÞJl$ 12/18/2002 21 :30 - 22:55 1.42 CEMT P COMP weight of 33klbs. Circulate bio to deployment tool. Pump at 1.7 in, 1.7 out. Pitvol=168 bbls. Pumped 25.4 bbls cement thru MM, Got 21.8 bbls behind pipe. Lost 3.6 bbls to the formation. Estimated cement top behind pipe = 10760'. Cement type, as per proceedure. 15.8 Ib/g, Class G, Additives; 0.4% 0065, 0.2% 0800, 0.2 g/sk 0047, 2.0 G/sk 0600G. Cement thickening time=4:56 hours. 22:55 - 00:00 1.08 CEMT P COMP POOH with Baker CTLRT. 12/19/2002 00:00 - 00:40 0.67 CEMT P COMP Continue POH with Baker CTLRT. 00:40 - 01 :20 0.67 CEMT P COMP Lay down Baker CTLRT. All recovered OK. 01 :20 - 07:00 5.67 BOPSUR P COMP Weekly BOP pressure test. Witness waived by State of Alaska AOGCC, John Spaulding. Sent test report to AOGCC. 07:00 - 07:45 0.75 CEMT P COMP Prep rig floor to run SWS Memory CNL/GR with motor and mill. 07:45 - 08:00 0.25 CASE P COMP SAFETY MEETING. Review procedure, hazards and mitigation to M/U BHA with CNL source. 08:00 - 08:30 0.50 CASE P COMP M/U 2.30" mill, 2.13" motor, SWS CNL/GR inside carrier, BKR circ sub, Hyd. Oisc. and XO. 08:30 - 09:30 1.00 CASE P COMP RIH with 39 stds of 1-1/4" CSH workstring. M/U OS MHA. 09:30 - 11 :00 1.50 CASE P COMP RIH with SWS MCNL and motor/mill BHA. OS CMT UCA sample in lab at 2000 psi at 11 :00 hrs. 11 :00 - 13:00 2.00 CASE P COMP Log down with MCNL/GR from 10,200' at 30 fpm. Circ. 0.7 bpm at 1350 psi. Circ. 25 BBL high Vis FloPro perf pill to mill while logging down. Tag PBTO of 12715' twice at 12,751' CTO. 13:00 - 14:45 1.75 CASE P COMP Log up with MCNL at 30 fpm while laying in HV FloPro perf pill. 0.30 bpm at 850 psi. Stop logging at 10,200 ft. 14:45 - 16:30 1.75 CASE P COMP POH with BHA. Circ. 1.2 bpm at 1700 psi. 16:30 - 18:30 2.00 CASE P COMP Stand back CSH workstring. Wet string. 18:30-19:15 0.75 CASE P COMP Continue standing back CSH. 19:15 -19:35 0.33 CASE P COMP Safety meeting prior to laying down MCNL tool. Attended by rig SWS and Nordic crews, MCNL crew. BP Co Man, Tool pusher, SWS lab tech. 19:35 - 20:00 0.42 CASE P COMP Lay down MCNL tool, motor, mill. All recovered properly, mill in gauge at 2.30". 20:00 - 20:30 0.50 CASE P COMP Pressure test liner lap to 2000 psi. Held fine with no pressure loss for 1/2 hour. Good cement job on liner lap. 20:30 - 21 :20 0.83 PERF P COMP Fax MCNL log to town Geo. PBTO was 12706', 9' shy of expected. Need to layout 1 gun to perforate to PBTO. Geo gave ok to perf. No gas in perf interval. 21 :20 - 21 :50 0.50 PERF P COMP Safety meeting prior to picking up perf guns. 21 :50 - 23:30 1.67 PERF P COMP Pickup SWS perf guns. Run three guns, hold trip drill. Continue running perf guns. 23:30 - 00:00 0.50 PERF P COMP Pickup 28 stands/56 joints of CSH. 12/20/2002 00:00 - 00:15 0.25 PERF P COMP Continue RIH with CS hydril work string. 00: 15 - 00:25 0.17 PERF P COMP Make up injector 00:25 - 01 :55 1.50 PERF P COMP RIH with perf guns conveyed on coiled tubing. 01 :55 - 02:40 0.75 PERF P COMP Tag up at 12776', make a correction to ELM tag from memory log of 12705' on up weight. Retag to confirm depth. PU into Printed: 12/26/2002 10:14:33 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-08 F-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date 'Task Code NPT Phase Frbrti,:..'.Tb 12/20/2002 01 :55 - 02:40 0.75 PERF P COMP 02:40 - 04:20 1.67 PERF P COMP 04:20 - 04:45 0.42 PERF P COMP 04:45 - 05:30 0.75 PERF P COMP 05:30 - 05:45 0.25 PERF P COMP 05:45 - 06:00 0.25 PERF P COMP 06:00 - 06: 15 0.25 PERF P COMP 06: 15 - 09:45 3.50 PERF P COMP 09:45 - 11 :30 1.75 RIGD P COMP 11 :30 - 11 :45 0.25 RIGD P COMP 11 :45 - 13:00 1.25 RIGD P COMP 13:00 - 14:30 1.50 RIGD P COMP 14:30 - 00:00 9.50 RIGD P COMP Start: 12/10/2002 Rig Release: 12/20/2002 Rig Number: N1 Spud Date: 3/24/1974 End: P$$qriþt¡óÒ...,df'..c>þ$rêtiÒr1§ ball drop depth. Pump flopro perf pill. Drop 5/8" ball to fire. Chase perf pill with KCL. Roll back to perf depth of 12694.4'. Circulate ball to firing head at 2.6 bpm 3600 psi. Slow pump rate to 1 bpm, 450 psi at 47 bbls away. Ball on seat at 51.9 bbls away (coil + CSH vol=62.25 bbal). Good indication of fire at 3400 psi. Perforated 12000'-12182', and 12380'-12694' with 2" Powerjet guns at 4 spf and 60 deg phasing. POH pumping 1 bpm to keep the hole full. Tag up at top of CSH. Stand back injector. Stand back CS hydril work string. Safety meeting prior to laying out perf guns. Shut down for crew change. Fill the hole. Safety meeting with on coming crew re perforating guns. Lay down SWS perf guns. All shots fired. Recovered all guns. Remove perf guns from pipe shed. RIH to 2000 ft and freeze protect 7" tubing with MEOH. Lay in MEOH at 50% up to 100ft. Circ. last 200' at 100% MEOH. POH. Close Master Valve and Swab Valve. SIWHP = 0 psi, lAP = 10 psi, OAP = 10 psi. SAFETY MEETING. Review procedure, hazards and mitigation for pumping N2 and bleeding down coil pressure. Pump N2 and displace KCL water from coil. Bleed down coil. N/D BOPE and hardline to tanks. Clean rig pits. RELEASED RIG AT 14:30 HRS, 12-20-2002. TOTAL TIME ON WELL WAS 8 DAYS, 19 HRS. Held Safety Meeting. Moved rig off of well. Held pre-rig move meeting with security, tool service, Nordic and Schlumberger, BP and moved rig to Point Mac. Printed: 12/26/2002 10:14:33 AM ) AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well F-08A Dear Dear Sir/Madam: Enclosed are two survey hard copies. ) 31-Dec-02 Tie-on Survey: 10,980.00' MD Window / Kickoff Survey 11,053.00' MD (if applicable) Projected Survey: 12,750.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECE\VED JAN 0 9 2003 A1IIØ Q¡ & GaS Cons. eommiIIiIR AI\dØI9Ø a~-d31 D~t:'\ -V: Sperry-Sun Drilling Services North Slope Alaska BPXA PBU- WOA F Pad F-OBA '--- Job No. AKMW22195, Surveyed: 18 December, 2002 Survey Report 2 January, 2003 Your Ref: 500292013501 Surface Coordinates: 5974230.00 N, 651959.00 E (70020' 11.8289" N, 148046' 01.3159" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '~. Surface Coordinates relative to Project H Reference: 974230.00 N, 151959.00 E (Grid) Surface Coordinates relative to Structure Reference: 1681.02 N, 1033.41 E (True) Kelly Bushing: 54.80ft above Mean Sea Level Elevation relative to Project V Reference: 54. 80ft Elevation relative to Structure Reference: 54.80ft spe"-'''-'V-SUI! c,R,U";,,LING, Se;RVIc;:es A Halliburton Company Survey Ref: svy11418 Sperry-Sun Drilling Services Survey Report for PBU- WOA F Pad - F-08A Your Ref: 500292013501 Job No. AKMW22195, Surveyed: 18 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) 10980.00 40.000 246.150 8743.50 8798.30 3906.06 S 3435.35 W 5970255.13 N 648603.51 E -5166.63 Tie-On Point MWD Magnetic - 11053.00 39.100 246.330 8799.79 8854.59 - 3924.79 S 3477.89 W 5970235.54 N 648561.35 E 1.243 -5210.78 Winow Point 11112.07 27.140 269.970 8849.37 8904.17 3932.34 S 3508.66 W 5970227.37 N 648530.74 E 29.486 -5238.69 11140.40 29.960 291.000 8874.32 8929.12 3929.80 S 3521.76 W 5970229.65 N 648517.59 E 36.661 -5246.73 11164.50 38.310 297.530 8894.26 8949.06 3924.18 S 3534.03 W 5970235.02 N 648505.21 E 37.794 -5252.08 ~ 11194.07 45.810 310.050 8916.24 8971.04 3913.08 S 3550.33 W 5970245.78 N 648488.70 E 37.956 -5256.77 11224.00 50.750 320.800 8936.18 8990.98 3897.16 S 3565.90 W 5970261.38 N 648472.80 E 31 .443 -5257.69 11247.87 57.530 326.610 8950.16 9004.96 3881.56 S 3577.30 W 5970276.74 N 648461.09 E 34.563 -5255.73 11294.67 72.510 336.130 8969.91 9024.71 3844.39 S 3597.35 W 5970313.50 N 648440.29 E 36.894 -5245.75 11324.45 82.380 335.780 8976.37 9031 .17 3817.88 S 3609.18 W 5970339.77 N 648427.92 E 33.163 -5236.80 11358.92 91.540 342.470 8978.20 9033.00 3785.77 S 3621.42 W 5970371.63 N 648415.04 E 32.878 -5224.41 11390.00 93.300 356.390 8976.88 9031.68 3755.32 S 3627.10 W 5970401.96 N 648408.74 E 45.1 03 -5208.26 11439.75 92.600 17.540 8974.29 9029.09 3706.28 S 3621.11 W 5970451.10 N 648413.74 E 42.479 -5170.99 11463.96 88.110 24.940 8974.14 9028.94 3683.74 S 3612.35 W 5970473.82 N 648422.04 E 35.745 -5149.40 11497.70 87.670 29.700 8975.39 9030.19 3653.79 S 3596.88 W 5970504.07 N 648436.90 E 14.158 -5117.86 11542.22 89.070 41.330 8976.66 9031 .46 3617.63 S 3571.07 W 5970540.75 N 648461.97 E 26.301 -5074.49 11575.47 93.920 44.150 8975.79 9030.59 3593.23 S 3548.52 W 5970565.60 N 648484.02 E 16.870 -5041 .40 11607.72 93.300 55.420 8973.75 9028.55 3572.48 S 3523.98 W 5970586.84 N 648508.13 E 34.929 -5009.29 11646.88 88.900 60.530 8973.00 9027.80 3551.73 S 3490.81 W 5970608.26 N 648540.88 E 17.216 -4970.75 11681.55 89.250 67.760 8973.56 9028.36 3536.63 S 3459.63 W 5970624.00 N 648571.74 E 20.875 -4937.47 11711.40 89.250 72.870 8973.95 9028.75 3526.58 S 3431.54 W 5970634.61 N 648599.63 E 17.117 -4909.87 11741 .65 89.340 67.580 8974.32 9029.12 3516.35 S 3403.08 W 5970645.42 N 648627.87 E 17.489 -4881.88 .~ 11772.35 91 .190 61 .770 8974.18 9028.98 3503.22 S 3375.35 W 5970659.10 N 648655.33 E 19.860 -4852.48 11814.55 92.600 72.870 8972.78 9027.58 3486.98 S 3336.49 W 5970676.13 N 648693.85 E 26.500 -4812.74 11849.38 91.370 82.210 8971.57 9026.37 3479.48 S 3302.54 W 5970684.31 N 648727.64 E 27.031 -4782.49 11887.05 89.690 90.840 8971.22 9026.02 3477.20 S 3264.98 W 5970687.35 N 648765.15 E 23.338 -4753.05 11932.27 86.780 88.730 8972.62 9027.42 3477.03 S 3219.79 W 5970688.44 N 648810.33 E 7.947 -4719.36 11965.45 86.340 86.180 8974.61 9029.41 3475.56 S 3186.70 W 5970690.58 N 648843.38 E 7.785 -4693.79 12001.65 89.520 80.970 8975.92 9030.72 3471.51 S 3150.77 W 5970695.35 N 648879.22 E 16.852 -4664.38 12039.67 89.050 76.180 8976.39 9031 .19 3463.98 S 3113.52 W 5970703.64 N 648916.31 E 12.658 -4631.65 2 January, 2003 - 14:14 Page2of4 DrillQuest 3.03.02.004 Sperry-Sun DrÎ//Îng ServÎces Survey Report for PBU- WOA F Pad - F-08A Your Ref: 500292013501 Job No. AKMW22195, Surveyed: 18 December, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (It) (It) (It) (It) (It) 12070.67 86.960 72.520 8977.47 9032.27 3455.63 S 3083.69 W 5970712.59 N 648945.96 E 12104.27 87.220 68.110 8979.18 9033.98 3444.33 S 3052.11 W 5970724.53 N 648977.31 E 12137.88 88.280 59.650 8980.50 9035.30 3429.56 S 3021.98 W 5970739.91 N 649007.14 E 12187.30 92.330 60.710 8980.24 9035.04 3404.99 S 2979.11 W 5970765.35 N 649049.49 E 12217.72 91.540 63.000 8979.21 9034.01 3390.65 S 2952.31 W 5970780.23 N 649076.00 E 12250.55 89.160 66.520 8979.01 9033.81 3376.65 S 2922.62 W 5970794.82 N 649105.40 E 12281.00 86.200 68.830 8980.24 9035.04 3365.09 S 2894.48 W 5970806.94 N 649133.30 E 12317.17 86.430 73.920 8982.57 9037.37 3353.57 S 2860.29 W 5970819.16 N 649167.26 E 12352.60 87.490 80.440 8984.45 9039.25 3345.73 S 2825.81 W 5970827.70 N 649201.57 E 12381.50 88.460 83.090 8985.47 9040.27 3341.59 S 2797.23 W 5970832.41 N 649230.06 E 12423.20 88.630 92.600 8986.53 9041.33 3340.02 S 2755.62 W 5970834.82 N 649271.63 E 12459.20 90.040 102.290 8986.95 9041.75 3344.68 S 2719.97W 5970830.89 N 649307.37 E 12491.05 90.400 102.120 8986.83 9041.63 3351.42 S 2688.84 W 5970824.79 N 649338.63 E 12523.88 89.430 100.000 8986.87 9041.67 3357.71 S 2656.62 W 5970819.14 N 649370.97 E 12553.67 90.400 94.010 8986.92 9041. 72 3361.35 S 2627.06 W 5970816.11 N 649400.59 E 12593.38 90.400 88.550 8986.64 9041 .44 3362.23 S 2587.38 W 5970816.03 N 649440.28 E 12625.38 89.250 85.550 8986.74 9041 .54 3360.59 S 2555.43 W 5970818.32 N 649472.19 E 12658.38 89.600 79.780 8987.07 9041 .87 3356.37 S 2522.71 W 5970823.20 N 649504.82 E 12690.17 89.600 74.810 8987.29 9042.09 3349.39 S 2491.71 W 5970830.81 N 649535.67 E 12728.60 89.340 70.930 8987.65 9042.45 3338.07 S 2455.00 W 5970842.87 N 649572.15 E 12750.00 89.340 70.930 8987.90 9042.70 3331.08 S 2434.77 W 5970850.27 N 649592.23 E 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 48.000° (True). Magnetic Declination at Surface is 25.994°(12-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 12750.00ft., The Bottom Hole Displacement is 4126.04ft., in the Direction of 216.164° (True). 2 January, 2003 - 14: 14 Page30f4 BPXA Dogleg Vertical Rate Section Comment (°/1 OOft) 13.589 -4603.90 13.131 -4572.86 25.348 -4540.59 8.471 -4492.29 7.959 -4462.78 ~/ 12.942 -4431.35 12.326 -4402.71 14.058 -4369.58 18.618 -4338.71 9.759 -4314.70 22.802 -4282.73 27.198 -4259.36 1.250 -4240.73 7.101 -4221.00 20.369 -4201.47 13.749 -4172.57 10.040 -4147.72 17.516 -4120.59 15.633 -4092.88 10.118 -4058.02 0.000 -4038.31 Projected Survey .~ DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU- WOA F Pad - F-08A Your Ref: 500292013501 Job No. AKMW22195, Surveyed: 18 December, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10980.00 11053.00 12750.00 8798.30 8854.59 9042.70 3906.06 S 3924.79 S 3331.08 S 3435.35 W 3477.89 W 2434.77 W Tie-On Point Winow Point Projected Survey '"-' Survey tool program for F-OBA From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 10980.00 0.00 10980.00 8798.30 12750.00 8798.30 AK-4 BP _CM - BP Conventional Magnetic(F-08) 9042.70 MWD Magnetic(F-08A) '~ 2 January, 2003 - 14: 14 Page 4 of 4 DrillQuest 3.03.02.004 .) ~ 1T !A\1f Œ ffiJ !A\£)[\ TONY KNOWLES, GOVERNOR AI,ASIiA..OILAND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BPExploration (Alaska), Inc. PO Box 196612 Plnchorage,AJ( 99519 Re: Prudhoe Bay Unit F -08A BP Exploration (Alaska), Inc. Permit No: 202-231 Surface Location: 2570' SNL, 2877' WEL, Sec. 02, TI1N, R13E, UM Bottomhole Location: 550' SNL, 139' WEL, Sec. 10, T11N, R13E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~._.,/-' /ð'- ~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 9~ day of December, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. RE: F -08A Pemùt ) ') Subject: RE: F-08A Permit Date: Mon, 9 Dec 2002 17:42:03 -0600 From: "McCarty, Thomas M" <McCartTM@BP.com> To: "'Winton Aubert'" <Winton_Aubert@admin.state.ak.us> CC: "McCarty, Thomas M" <McCartTM@BP.com> Winton, Just to follow up on my phone message. Nordic 1 will release from well K-20B this afternoon or early this evening 12/09. And will move to F-Pad tonight. Optimally I would like to fax the rig a copy of the permit this afternoon. Oftentimes the communications link goes down during the move and continues to be down during most of the rig up. So, getting the permit to the rig before they move off of K pad would allow them to have a copy when the inspector comes out for the BOPE test. I appreciate your help, especially with our rapidly and ever changing schedules. Thank You 223-7156 Thomas McCarty Coiled Tubing Drilling Engineer, Alaska Drilling & Wells BP Exploration (Alaska) Inc. -----Original Message----- From: Winton Aubert [mailto:Winton Aubert@admin.state.ak.us] Sent: Thursday, December 05, 2002 3:07 PM To: McCarty, Thomas M Subject: Re: F-08A Permit Thomas, The F-08 Sundry was approved on 12/3/02. The Commissioners have the F-08A APD. Winton "McCarty, Thomas M" wrote: > Winton: > > It looks like we need the permit by 12/10 for well F-08 and the permit asap. > The K-20B well is moving along quicker than estimated. > > Thanks, please let me know if I can help out in any way. > > 223-7156 > > Thomas McCarty > Coiled Tubing Drilling Engineer, Alaska Drilling & Wells > BP Exploration (Alaska) Inc. F -08A Permit ) ') Subject: F -08A Permit Date: Thu, 5 Dec 2002 17:52:26 -0600 From: "McCarty, Thomas M" <McCartTM@BP.com> To: "'winton - aubert@admin.state.ak.us'" <winton - aubert@admin.state.ak.us> cc: "Hubble, Tenie L" <HubbleTL@BP.com> Winton: It looks like we need the permit by 12/10 for well F-08 and the permit asap. The K-20B well is moving along quicker than estimated. Thanks, please let me know if I can help out in any way. 223-7156 Thomas McCarty Coiled Tubing Drilling Engineer, Alaska Drilling & Wells BP Exploration (Alaska) Inc. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2570' SNL, 2877' WEL, SEC. 02, T11 N, R13E, UM At top of productive interval 1117' SNL, 864' WEL, SEC. 10, T11N, R13E, UM At total depth 550' SNL, 139' WEL, SEC. 10, T11 N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well 1" ADL 028280,139' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11040' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Hole Casina Weiqht Grade CouDlina 3-3/4" 3-3116" x 2-7/8" 6.2#/6.16# L-80 ST-L j2/'i/O'1.- ALASKA , STATE OF ALASKA )". AND GAS CONSERVATION COMf\ )sION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool KBE = 54.79' Prudhoe Bay Field 1 Prudhoe 6. Property Designation Bay Pool ADL 028281 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /" F-08A 9. Approximate spud dat~ 12/15/02 /' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12500' MD 1 8973' TVD 17. Anticipated pressure {see.20 AAC 25.035 (e) (2)} 900 Maximum surface 2134 P;ig, At total depth (TVD) 8800' 1 3190 psig Setting Depth T OD Bo~tom Quantitv of Cement Lenath MD TVD MD TVD (include staqe data) 2100' 10400' 8384' 12500' 8973' 100 sx Class 'G' /" 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Open: 11092' - 11102' , 11204' - 11246' Sqzd: 11030' -11061', 11080' -11101',11127'-11137',11152' -11168' true vertical Open: 8885' - 8893' , 8973' - 9006' Sqzd: 8836' - 8861' , 8876' - 8892' , 8912' - 8920' , 8932' - 8945' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 5ê4 ~'WJ .:1 '10 - gos- , Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Thomas w.ccartyE ...2;0 C( "":7(' F . Title , C:r Drilling Engine~r " ;'." ,.,>~U$eOn~. :,' Permit Number API Number APZOY21 Date See cover letter 2-0<., - .z 3 / 50- 029-20135-01 Ç2 C¡!r:?~ for other reauirements Conditions of Approval: Samples Required 0 Yes œ No Mud Log equired 0 Yes iii No Hydrogen Sulfide Measures iii Yes 0 No Directional Survey Required HI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: 'n ~+ -g.ot)E 1-0 ~~OO (Jç ø . ~ by order of f -- ! Approved By ORIGINAL SI~NED BY Commissioner the commission Date I/J/oq O;? Form 10-401 Rev. 12-01-85 M L. am ' ~ ~ ~ Submit I Triplicate ~ ~ L Casing Structural Conductor Surface Intermediate Production Liner Packer Tail Pipe Perforation depth: measured 20. Attachments 11305 feet 9053 feet 11270 feet 9026 feet Length TVD Plugs (measured) Junk (measured) Size Cemented MD 80' 2700' 30" 13-3/8" 135 sx Arctic Set 3697 sx Perma Frost II 100' 2700' 100' 10087' 9-5/8" x 10-3/4" 1650 sx Howco Light, 200 sx Class 'G' 1744' 7" 752 sx Class 'G' 12' 4-1/2" NIA 10087' 8176' 9559' - 11303' 7866' - 9052' 10435' - 10447' 8408' - 8416' Date (2-/;"'/' 2- ) ") BP , F-08A CTD Sidetrack Summary of Operations: /' A CTD through tubing lateral is planned for F-08. The coiled tubing sidetrack, F-08A, will exit the 7" liner in zone 2 and target Zone 2A. Prior to CTD sidetracking the well, a whipstock will be set and cemented in place. After the window is milled in the 7" liner, approximately 1460' of 3-3/4" open hole is planned to access the Zone 2A target. The well will be completed with a solid, cemented and perforated liner. ~ Phase 1: Prep work. Planned for December 6, 2002. 1. Install mechanical whipstock in 7" liner. 2. Cement past whipstock. 3. Mill window with service coil, time permitting. / Phase 2: Mill window, Drill and Complete sidetrack: Planned for December 15,2002. Drilling coil will be used to mill the window in the 7" liner if service coil could not mill the window in Phase 1. Drilling coil will then drill and complete the directional hole as per attached plan. Maximum hole angle is planned for 90 degrees. The lateral will be completed with a 2 7/8" x 33/16" solid --. cemented and perforated liner. Resistivity and MCNL logs will be run in addition to MWD gamma ray. Mud Program: . Phase 1: Sea water and 2ppb Biozan . Phase 2: Drill with Flo-Pro (8.6 - 8.7 ppg) / Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: /' The production liner will be 2 7/8" ST-L solid liner from TD to approx. 11100' MD,where it will be crossed over to 3 3/16" liner. Desired top of 33/16" liner will be at approx. 10,400'md. The liner will be cemented in place and perforations will be made in the target zone. Use of the 3-3/16" liner will preserve future sidetrack options. Well Control: . BOP diagram is attached. - . Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. / . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is approx. 90deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray will be run over the entire open hole section. Resistivity will be run in the open hole. Memory CNL is planned to be run in the cased hole after cementing. H~a~s / . F-Pad is not an H2S pad. Offsets have all measured less than 20ppm. . Lost circulation risk is considered low based on fault orientation and regional history. Reservoir Pressure Res. press. is estimated to be 3190 at 8800'ss ( 7.0 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2134 psi. TREE =. W8...LHEA 0 = ACTUA TOR = KB. 8...EV = BF. 8...EV = KOP= Max Angle = Datum MO = DatumTVO= 6"CIW McEVOY OTIS 54.79' 34.92' 3200' 56 @ 9600' 11053' 8800' SS ) ~FE) JOTES F -08a proQ.Qse(1 1 TOP OF 7" LNR 1-1 9559' ~ 7" TBG, 26#, N-80, AB TC-4S, - 9596' 0.0383 bpf, 10 = 6.276" I 19-5/8" CSG, 47#, N-80, ID = 8.681" l-i 10087' ~ I TOP OF 3 3/16" Liner 1-1 10400' I DATE REV BY COMMENTS 11/07/02 MSE ffi()R)SED em ST 19-518"CSG,47#, N-80, ID=8.681" H 149' r l10-3/4" CSG, 55.5#, N-80, ID = 9.953" 1-1 2022' ~ 113-3/8" CSG, 72#, N-80, 10 = 12.347" H 2700' Minimum 10 = 3.725"@ 10445' OTIS XN NIPPLE 1 TOP OF cement 1-1 10700' ÆRFORA TION SUMMARY REF LOG: SWS BHCS 04/19/74 ANGLEATTOPÆRF: 39 @ 11030' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 11030-11061 S 09/05/87 4" 4 11080-11101 S 09/05/87 4" 4 11127-11137 S 09/05/87 4" 4 11152-11168 S 09/05/87 3-3/8" 4 11204-11246 0 10/01/87 2-7/8" 6 11092-11102 0 09/01/98 1 PBTD 1-1 11270' 1 17" LNR, 29#, N-80, BTC, 0.0371 bpf, D=6.184" H 11303' DATE 09/08176 02115/01 03/05101 08/13/01 11/06/02 REV BY COMMENTS ORIGINAL COMPLETION SIS-MH CONVERTED TO CANVAS SIS-MD FINAL RNIKAK CORRECTIONS MSE ADD DRLG DETALS 149' 1-19-5/8" X 10-3/4" XOI I 2022' 1-110-34" X 9-5/8" XOI . ~ 2043' 1-17" OTIS SSSV NIPW/INSERT, 10 = 3.813" I I ~ r ~ GAS LIFT MANDR8...S ST MD TVO DEV TYPE VLV LATCH R)RT DATE 2106' 1-19 5/8" PBR 1 ,---l 9556' H 7" 40' PBR 1 H 9599' 1-17" PACKER, LINER HANGER 1 .. 10400' 1-1 Baker 5 1/2" C2 tie back setting I sleeve fluted to set in 7" 10410' - 31/2" XN, 2.75" No go 1 ~ 1r -' 1 I 10445' 1 ~i {}~~lrt~ I H" 1 1-14-1/2" OTIS XN NIP, ID nilled to = 3.80" 1 I., 1 11100' H3-3/16 x 2-7/8 X-over 1 I 11400' 1-12 7/8" marker joint 1 ~ 12450/1 1 3-3/16" X 2-7/8" cmt'ed and perfedl-1 12500' 1 11040' H Mechanical Whipstock 11275' H BAKER MOD K BRIDGE R.UG I PRUDHOE BAY UNrr W8...L: F-08 PERMrr No: API No: 50-029-20135-01 Sec.2,T11N,R13E BP Exploration (Alaska) TREE = 6" crw W8..LHEAD = M:; EVOY ÄCn~T<jR = '"'' OTIS KB. ELEV :::"'54.79" ï3F. ELEV;;';. j.{g2' 'ROP"::' "'" ' '32C>'Öi' ... . .. .~,.h'~.~_..~.~,,,~.~. ~ .... M~ ,~,~~~"~,.,., ,..,5~@..~Oq, Datum MD ::: 11053' Datum TVD = 8800' SS ) G-u--iCU 19-518" CSG, 47#. N-80, 10= 8.681" H 149' 110-3/4" CSG, 55.5#, N-80, 10= 9.953" H 2022' ~ ~ 113-318" CSG, 72#,N-80, 10 = 12.347" H 2700' r----M Minimum ID = 3.725"@ 1 0445' OTIS XN NIPPLE [TOP OF 7" LNRI-i 9559' h 17" TBG, 26#, N-80, 0.0383 bpf, 10= 6.276" H 9596' ~ ~ ~I 9-5/8" CSG,47#, N-80, 10= 8.681" H 10087' .~ PERFORA 1lON SLMMA. RY RS= LOG: SWS BHCS 04/19/74 ANGLE AT TOP PERF: 39@ 11030' Note: Refer fD Production œ for historical perf data SIZE 8FT IN1ERVAL Opn/Sqz DATE ~ 4" 4 11030-11061 S 09/05/87 \¡ 4" 4 11080-11101 S 09/05/87 4" 4 11127-11137 S 09/05/87 4" 4 11152-11168 S 09/05/87 3-318" 4 11204-11246 0 10/01187 2-718" 6 11092-11102 0 09/01198 I PBTD H 11270' 17" Lf'R, 29#, N-80, 0.0371 bpf, ID= 6.184" H 11303' DATE 09/00/76 02/15/01 03/05/01 00/13/01 ~ BY COMM:NTS ORIGINAL COMRETlON SIS-MH CONVERTED TO CANVAS SIS-MD FNAL ~KAK COR~IONS F-08 1 1 .---1 ~ ~) ~TES 149' H9-5I8" X 10-3/4" XO 2022' H 10-34" X 9-518" XO 1 2043' H7" OTIS SSSV NIPW/INSERr, 10= 3.813" I GAS LIFT MANDRELS ST MD TVD ŒV 1YÆ VLV LATa; FORr DATE J---i 9556' 1-i7" PBR 1 , r i I r J DATE ~ BY COMM:NTS ~ 10435' 10441' 10445' 10447' 11020' 1-17" x 4-1/2" 011S WD PKR, 10 = 4.0" 1 1---14-1/2" OTIS X NIP, ID = 3.813"1 H4-1/2" OTISXNNIP, ID= 3.725" I H4-1/2" W/LEG I H MA. RKER JOINT I PRLD -()E BA Y LNIT WELL: F-08 PERMIf No: 74-0110 AA No: 50-029-20135-00 Sec. 2, T11N, R13E BP Exploration (Alas ka) . ._-_._-~--~~--~-- ---. ~-_.~--. --------~ T !¡\M Azimuths to True North Plan: Plan #8 (F-08/Plan#8 F-08A) Magnetic North: 26.02° Created By: Brij Potnis Date: 11/1/2002 BP Amoco LEGEND F-08 (F-08) Plan#8 F-08A Plan #8 < f\ Magnetic Field Strength: 57534nT Dip Angle: 80.83° Date: 11/7/2002 Model: BGGM2002 Contact Information. é WELLPATH DETAILS PI.n". ,-G8A 800212013501 ¡l"'TFQ Bak.$r rl'., ,I ,- ,!, I: f., .'" P....nt W.llp.th: Tie on MD: RII' lI.f. D.tum: ..08 10880.00 I : 08 31241117400:00 TVO '--./ V.Sectlon Angl. 48.00' O+'IJ ~ ~~,.~ ::::~D 0.00 -2800 0.00 0.00 REFERENCE INFORMATION ':'ç .~ri¡~,t~ (~ 'E) P"f:>r",n~",. Well Centre: F-08, True North t~:,:' .'. ~ L:.: :~, ~::: ~:: :: ~r~t~~~ ro~g3N~g~0~~)~ Measured Depth Reference: 8: 08 3/24/1974 00:00 54.80 Calculation Method: Minimum Curvature 81!CTION DETAIL8 TVO +I!I.W DL.. TF.C8 V"o Target 1 10880.00 40.00 240.15 8743.80 .3808.08 .3435.35 0.00 0.00 -5188.83 Z 11040.00 30.S7 248.27 8788.88 .3821.82 .3470.41 1.08 173.11 .5203.02 3 11080,00 38.80 248.77 8805.23 .3828.33 .3482.02 8.00 120.00 .5214.87 : H~:g:~: :g:!i ::::! I::::!! ::!:;:l! ::~:~:;: 1;:gg 1::gg ~¡!::i! ~ ~:~:g::: ::::l :~::g ::;t:: :~::g:;: ::::::~: ~::gg -:tgg ~;::~~ 8 12800.00 88.88 88.13 8873.38 .3280.08 .2538.72 12.00 288.52 ...we8.07 --~-------_._- ~ ~---------~-- -- ANNOTATIONS - -3200 C ¡¡ -3300 Õ 0 -3400 "I'" - +-3500 ' - .c 1:: -3600 0 iÇ -3700 - . :c -3800 .. g -3900 en -4000 -.-I MD AnnoblUon +E1-W Shape ~:fngon7.1 :~:~ :~~:ii :~~i:~ ~~~r 8743.80 10180.00 TIP 8788.88 11040.00 KOP 8805.23 11080.00 1 8885.00 11330.28 2 8888.00 11380.28 3 8188.00 11780.28 4 8888.88 12080.28 5 8871.08 12380.28 8 8173.38 12800.00 TO --~~----~--~-_.~-~- 8400 8450 8500 8550 - C .- 8600 ~ 8650 - = 8700 a. & 8750 'i 8800 U t= 8850 CD ~ 8900 ~ 8950 9000 9050 9100 9150 Vertical Section at 48.00° [50ft/in] - -~~~---------- 11/7/2002 3:511 PM "'.. BAKER HUGHES ) BP ) Baker Hughes INTEQ Planning Report ..-. .- . I ~ L LQ Company: BP Amoco Field: Prudhoe Bay Site: PB F Pad Well: F-08 Wellpath: Plan#8 F-08A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: PB F Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: F-08 F-08 Well Position: Well: Date: 1117/2002 Time: 15:55:16 Co-ordinate(NE) Reference: Well: F-08, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,48.00Azi) Sun'ey Calculation Method: Minimum Curvature Db: Page: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 5972527.29 ft 650960.70 ft Latitude: Longitude: North Reference: Grid Convergence: 70 19 55.283 N 148 46 31.468 W True 1.15 deg Slot Name: 08 70 20 11.829 N 148 46 1.316 W +N/-S 1682.40 ft Northing: 5974230.00 ft +E/-W 1032.44 ft Easting: 651959.00 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan#8 F-08A 500292013501 Current Datum: 8: 083/24/197400:00 Magnetic Data: 11/7/2002 Field Strength: 57534 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Name Description Dip. Dir. F-08A Polygon7.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8965.00 F-08A T7.1 F-08A T7.2 8980.00 Annotation l\ID TVD ft ft 10980.00 8743.50 TIP 11040.00 8789.68 KOP 11060.00 8805.23 1 11330.26 8965.00 2 11380.26 8965.00 3 11780.26 8965.00 4 12080.26 8966.59 5 12380.26 8971.06 6 12500.00 8973.39 TD Height 54.80 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 F-08 10980.00 ft Mean Sea Level 26.02 deg 80.83 deg Direction deg 48.00 +N/-S ft 0.00 Map Map <-- Latitude --> <-- Longitude --> +N/-S +E/-W Northing Eastiog Deg Min See Deg Min See ft ft ft ft -3840.13 -3747.86 5970315.00 648290.00 70 19 34.052 N 148 47 50.716 W -3840.13 -3747.86 5970315.00 648290.00 70 19 34.052 N 148 47 50.716 W -4228.12 -3605.68 5969930.00 648440.00 70 19 30.237 N 148 47 46.561 W -4041.62 -2936.72 5970130.00 649104.99 70 19 32.074 N 148 47 27.037 W -3682.57 -2391.29 5970500.00 649643.00 70 19 35.607 N 148 47 11.119 W -2958.89 -2069.54 5971230.00 649949.99 70 19 42.726 N 148 47 1.733 W -2849.41 -2042.31 5971340.00 649975.00 70 19 43.802 N 148 47 0.939 W -3209.91 -3009.88 5970960.00 649015.00 70 19 40.254 N 148 47 29.182 W -3481.29 -3685.57 5970675.00 648345.00 70 19 37.582 N 148 47 48.903 W -3673.63 -3079.30 5970495.00 648955.00 70 19 35.693 N 148 47 31.203 W -3075.33 -2246.94 5971110.00 649775.00 70 19 41.580 N 148 47 6.911 W Company: BP Amoco Field: Prudhoe Bay Site: PB F Pad Well: F-08 WeUpath: Plan#8 F-08A ) BP ) Baker Hughes INTEQ Planning Repôrt Plan: Plan #8 Kick off in Zone2 to avoid Zone3 drilling Principal: Yes Plan Section Information MD ft 10980.00 11040.00 11060.00 11330.26 11380.26 11780.26 12080.26 12380.26 12500.00 loel deg 40.00 39.37 38.50 90.00 90.00 90.00 89.41 88.94 88.85 Survey l\ID ft 10980.00 11000.00 11025.00 11040.00 11050.00 loci deg 40.00 39.79 39.53 39.37 38.93 Azim deg 246.15 246.27 248.77 15.00 35.50 83.50 47.50 83.50 69.13 Azirn deg 246.15 246.19 246.24 246.27 247.51 TVD ft 8743.50 8789.68 8805.23 8965.00 8965.00 8965.00 8966.59 8971.06 8973.39 +N/-S ft -3906.06 -3921.52 -3926.33 -3775.15 -3730.17 -3533.04 -3410.68 -3288.34 -3260.09 r~.. BAlCER HUGHES t, L LQ Date: 1117/2002 Time: 15:55:16 Co-ordinate(NE) Reference: Well: F-08, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,48.00Azi) SUn'ey Calculation Method: Minimum Curvature Db: Oracle Date Composed: Version: Tied-to: 11/7/2002 2 From: Definitive Path Page: 2 SSTVD ft 8743.50 8758.85 8778.09 8789.68 8797.43 N/S ft -3906.06 -3911.25 -3917.68 -3921.52 -3924.00 +E/-W ft -3435.35 -3470.41 -3482.02 -3547.63 -3526.42 -3191.75 -2923.23 -2654.74 -2538.72 TFO deg 0.00 173.11 120.00 119.83 90.00 90.00 -91.00 91.00 269.52 Target TFO deg 0.00 TIP 173.11 MWD 173.08 MWD 173.04 KOP 120.00 MWD Tool 11060.00 38.50 248.77 8805.23 -3926.33 -3482.02 5970234.22 648557.51 -5214.87 / 9.00 119.04 1 11075.00 35.76 257.99 8817.20 -3928.93 -3490.66 5970231.44 648548.92 -5223.04 41.29 119.83 MWD 11100.00 33.03 275.67 8837.88 -3929.78 -3504.63 5970230.31 648534.98 -5233.98 41.29 112.47 MWD 11125.00 33.06 294.66 8858.89 -3926.25 -3517.64 5970233.57 648521.90 -5241.29 41.29 97.84 MWD 11150.00 35.83 312.30 8879.56 -3918.46 -3529.28 5970241.12 648510.10 -5244.73 41.29 81.88 MWD DLS Build Turn deg/10OO deg/100ft deg/100ft 0.00 0.00 0.00 1.06 -1.05 0.20 9.00 -4.37 12.52 41.29 19.06 46.70 41.00 0.00 41.00 12.00 0.00 12.00 12.00 -0.20 -12.00 12.00 -0.16 12.00 12.00 -0.07 -12.01 E/W ft -3435.35 -3447.08 -3461.68 -3470.41 -3476.21 VS ft -5166.63 -5178.82 -5193.97 -5203.02 -5209.00 DLS deg/100ft 0.00 1.06 1.06 1.06 9.00 MapN ft 5970255.42 5970250.00 5970243.27 5970239.26 5970236.66 l\IapE ft 648603.76 648592.13 648577.66 648569.02 648563.27 11175.00 40.79 326.96 8899.21 -3906.66 -3539.17 5970252.72 648499.97 -5244.18 41.29 11200.00 47.23 338.60 8917.21 -3891.23 -3546.99 5970267.99 648491.84 -5239.67 41.29 11225.00 54.62 347.90 8932.98 -3872.67 -3552.49 5970286.43 648485.97 -5231.34 41.29 11250.00 62.61 355.58 8946.00 -3851.58 -3555.49 5970307.45 648482.54 -5219.46 41.29 11275.00 70.95 2.20 8955.86 -3828.65 -3555.89 5970330.37 648481.67 -5204.41 41.29 11300.00 79.51 11325.00 88.17 11330.26 90.00 11350.00 90.00 11375.00 90.00 11380.26 90.00 11400.00 90.00 11425.00 90.00 11450.00 90.00 11475.00 90.00 11500.00 90.00 11525.00 90.00 11550.00 90.00 11575.00 90.00 11600.00 90.00 11625.00 90.00 11650.00 90.00 11675.00 90.00 11700.00 90.00 11725.00 90.00 11750.00 90.00 11775.00 90.00 11780.26 90.00 8.18 8962.23 -3804.61 -3553.69 5970354.45 648483.39 -5186.68 41.29 13.83 8964.92 -3780.24 -3548.94 5970378.90 648487.65 -5166.85 41.29 15.00 8965.00 -3775.15 -3547.63 5970384.02 648488.85 -5162.47 41.29 23.09 8965.00 -3756.51 -3541.19 5970402.79 648494.91 -5145.21 41.00 33.34 8965.00 -3734.51 -3529.39 5970425.02 648506.26 -5121.72 41.00 35.50 8965.00 -3730.17 -3526.42 5970429.42 648509.15 -5116.61 41.00 37.87 8965.00 -3714.34 -3514.63 5970445.48 648520.62 -5097.25 12.00 40.87 8965.00 -3695.01 -3498.77 5970465.12 648536.08 -5072.54 12.00 43.87 8965.00 -3676.55 -3481.92 5970483.93 648552.54 -5047.66 12.00 46.87 8965.00 -3658.98 -3464.13 5970501.85 648569.97 -5022.69 12.00 49.87 8965.00 -3642.38 -3445.45 5970518.83 648588.31 -4997.70 12.00 52.87 8965.00 -3626.77 -3425.92 5970534.82 648607.52 -4972.74 12.00 55.87 8965.00 -3612.21 -3405.61 5970549.79 648627.53 -4947.90 12.00 58.87 8965.00 -3598.73 -3384.56 5970563.70 648648.31 -4923.24 12.00 61.87 8965.00 -3586.37 -3362.83 5970576.49 648669.78 -4898.82 12.00 64.87 8965.00 -3575.17 -3340.48 5970588.15 648691.89 -4874.71 12.00 67.87 8965.00 -3565.15 -3317.58 5970598.63 648714.58 -4850.99 12.00 70.87 8965.00 -3556.34 -3294.19 5970607.91 648737.79 -4827.71 12.00 73.87 8965.00 -3548.77 -3270.36 5970615.96 648761.45 -4804.94 12.00 76.87 8965.00 -3542.45 -3246.18 5970622.76 648785.51 -4782.74 12.00 79.87 8965.00 -3537.41 -3221.69 5970628.30 648809.88 -4761.18 12.00 82.87 8965.00 -3533.66 -3196.98 5970632.55 648834.51 -4740.30 12.00 83.50 8965.00 -3533.04 -3191.75 5970633.28 648839.72 -4736.00 12.00 67.29 MWD 55.76 MWD 47.36 MWD 41.47 MWD 37.46 MWD 34.84 MWD 33.31 MWD 32.70 2 90.00 MWD 90.00 MWD 90.00 3 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 4 Company: BP Amoco Field: Prudhoe Bay Site: PB F Pad Well: F-08 WeUpath: Plan#8 F-08A Survey l\-ID loci ft deg 11800.00 89.96 11825.00 89.91 11850.00 89.85 11875.00 89.80 11900.00 89.75 11925.00 89.70 11950.00 89.65 11975.00 89.60 12000.00 89.56 12025.00 89.51 12050.00 89.46 12075.00 89.42 12080.26 89.41 12100.00 89.37 12125.00 89.32 12150.00 89.27 12175.00 89.23 12200.00 89.18 12225.00 89.14 12250.00 89.10 12275.00 89.06 12300.00 89.03 12325.00 89.00 12350.00 88.97 12375.00 88.94 12380.26 88.94 12400.00 88.92 12425.00 88.90 12450.00 88.88 12475.00 88.86 12500.00 88.85 ) BP) Baker Hughes INTEQ Planning Repórt ßI.. BAKU! NUGIIIS -.. ... ... o- J :'\ r Lf) Date: 1117/2002 Time: 15:55:16 Co-ordinate(NE) Reference: Well: F-08. True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N.0.00E,48.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Page: 3 Azirn SSTVD N/S E/W MapN l\lapE VS DLS TFO deg ft ft ft ft ft ft deg/100ft deg 81.13 8965.01 -3530.40 -3172.20 5970636.31 648859.22 -4719.70 12.00 269.00 MWD 78.13 8965.04 -3525.90 -3147.61 5970641.31 648883.71 -4698.41 12.00 269.00 MWD 75.13 8965.09 -3520.12 -3123.29 5970647.58 648907.91 -4676.47 12.00 269.00 MWD 72.13 8965.16 -3513.08 -3099.30 5970655.11 648931.74 -4653.94 12.00 269.01 MWD 69.13 8965.26 -3504.79 -3075.72 5970663.87 648955.15 -4630.87 12.00 269.02 MWD 66.13 8965.38 -3495.27 -3052.60 5970673.85 648978.07 -4607.32 12.00 269.03 MWD 63.13 8965.52 -3484.57 -3030.02 5970685.01 649000.43 -4583.37 12.00 269.05 MWD Tool 60.13 8965.68 -3472.69 -3008.02 5970697.33 649022.18 -4559.08 12.00 269.06 MWD 57.13 8965.87 -3459.68 -2986.68 5970710.77 649043.26 -4534.51 12.00 269.08 MWD 54.14 8966.07 -3445.57 -2966.04 5970725.29 649063.60 -4509.74 12.00 269.10 MWD 51.14 8966.29 -3430.40 -2946.18 5970740.86 649083.15 -4484.82 12.00 269.13 MWD 48.14 8966.54 -3414.21 -2927.13 5970757.43 649101.86 -4459.84 12.00 269.16 MWD 47.50 8966.59 -3410.68 -2923.23 5970761.04 649105.69 -4454.57 12.00 269.18 5 49.87 8966.80 -3397.65 -2908.41 5970774.37 649120.25 -4434.84 12.00 91.00 MWD 52.87 8967.09 -3382.05 -2888.88 5970790.36 649139.45 -4409.89 12.00 90.97 MWD 55.87 8967.39 -3367.49 -2868.57 5970805.33 649159.47 -4385.05 12.00 90.94 MWD 58.87 8967.72 -3354.01 -2847.52 5970819.23 649180.24 -4360.39 12.00 90.90 MWD 61.87 8968.07 -3341.65 -2825.79 5970832.02 649201.71 -4335.97 12.00 64.87 8968.43 -3330.45 -2803.45 5970843.68 649223.82 -4311.87 12.00 67.87 8968.82 -3320.43 -2780.55 5970854.15 649246.51 -4288.15 12.00 70.87 8969.22 -3311.63 -2757.15 5970863.43 649269.72 -4264.88 12.00 73.87 8969.63 -3304.06 -2733.33 5970871.48 649293.38 -4242.11 12.00 90.86 MWD 90.82 MWD 90.78 MWD 90.73 MWD 90.68 MWD 76.87 8970.06 -3297.75 -2709.15 5970878.28 649317.42 -4219.92 12.00 90.63 MWD 79.87 8970.51 -3292.71 -2684.67 5970883.81 649341.80 -4198.35 12.00 90.58 MWD 82.87 8970.96 -3288.96 -2659.96 5970888.06 649366.42 -4177.48 12.00 90.53 MWD 83.50 8971.06 -3288.34 -2654.74 5970888.79 649371.63 -4173.18 12.00 90.48 6 81.14 8971.43 -3285.70 -2635.18 5970891.82 649391.13 -4156.88 12.00 269.52 MWD 78.13 8971.91 -3281.20 -2610.60 5970896.82 649415.62 -4135.60 12.00 269.56 MWD 75.13 8972.39 -3275.43 -2586.28 5970903.08 649439.81 -4113.67 12.00 269.62 MWD 72.13 8972.89 -3268.38 -2562.30 5970910.61 649463.64 -4091.14 12.00 269.68 MWD 69.13 8973.39 -3260.09 -2538.72 5970919.38 649487.04 -4068.07 12.00 269.74 TD ') BOP- Tree NOK'S;>IC 2- Well I F - (,{~ A r . Rig Floor I I~ r mID ~ I, KB Elevation ~ I I Lubncator 10 = '5 375" with 6" OtiS LJnions f. .J1W~~~~L.J i,ï 1116" 5000 psi BOP's, 10 = ì.06" ! 3" 5000 psi I, I I I.. 17 1/16' 5000 PSI. R);-46 I ,,' ;:$nru;~:':~ I, I " ,,: ,: TO,.,' <;'~ I. . I I rai~ .... ~ J],I, ~£I I I ~1~d}~~,,'1 . L-J I Choke Line I ~ , f, T 1111. . I ;I['~~~~I~ IZ1116"5DOOpsl RX-24 1III Wi I. I IP'~~~J II I ¡ 1116" 5000 psi IRX-46 or "'.:...:..:....:.:.1 ..- 41116' 5000 psi lRX-39 ~ ¡~t I ~';'I""'I"ili':"i";)""'O"'" ~ ,~IQ~ ~.:'r, ~,: ,", ',~ ~ C,,,.,,,..."""11'''' """"'''''), '1--.810.... '~~ : ~.: '-"', : if!' :- ;:--t, '~~~",~^'~^^,J ,:, -......- R;..~;(t -'-" ~2 I. ssv I ~~ø~~#¡J . ~ '?i:: ...... ..¡:¡ ";'~ JIll""" '.~ ~ 'Z' '8 :fi~.. .~æ;~ [:~~i;.¥i~~:::~1u'-'] ~:'r:.;~-~p...;~,,~ ~f.ki:~~;~~~~1~~ ~: .;it~f~I}t'..~:.~~1"X:..( ..I. . ')j ;.;!~ {~F.,:''}NJ~~~ '~'::'.,::;;! '~:~'Iißitii4t:if:fii¡fkf. ~':' [~rii~ 1.1/4 Turn L T Valve I I @[ I t L-J . I Swab Valve I Tree Size I I Master Valve I I Base Flange I I Page 1 WELL NO. .;F-lli', I 0-1 ':-13) ; OTIS PACKE R TAIL. )E ASSEMBLY AS RUN AFTE R PERFORATING: NOV. 5,1976 \' "WO" PACKER WI 5.69 0.0. RfTRACTOR !1 I ' r \ ' ~~lJ $ ^O^PTER SUB WI 41/2" 1275#- 3' PUP JOI NT 8 4 1/2" 12.75 # --..- ~ x-tJlrr:..E 'Iv,' 3.813 1.0. ri 4 1/2" 12.75# --.-----.--+ 3' Pur) JUINT 8 41/2" 12.75* -_.. --. XN-IIIF PLE WI 3 ~13 I L' I~ 8 / II . # 4 I 2 12. (5 - 3.725 ---- .'--+1 NO GO ~ WIRELlNE f¡E-ErrCRY ,/) G'JIDE ---// / LENGTH . DEPTH (FT. BKe /-----.----- I 10,435' f / 4.08' T - -- -----,----- 2.27' .~-------IJ---- -------f---- 3.04 ' ~-------t----- 1.30' (------{----- ~ 0.57' \- -- - -~-- --- 10,441 10,445' 10,447 ' H 207132 DATE INVOICE I CREDIT MEMO 9/20/02 INV# 091602B -..... f.~' .; =,,, (. ~'" ..,/'.."<' , \ ''', --.. ,.' _.~~) r THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ GROSS FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 8 P r;"'.. "f'" fIll. hi III/ft.,! <¡""I' f""l' (Is, hi, . t' ( . "" 1",' ,j.. ':.. ";', . R i).Jr.. 11iI',' 11ft.' .11"" ~II..., ."" TO THE ALASKA OIL & GAS CONSERVATION COMMISSION ORDER 333 W. 7th AVE. STE. 100 OF ANCHORAGE, AK 99501 DATE SEPT. 20, 2002 118 20 ? ~ j 2,,8 1:0 It ~ 20 is., 51: OOB It It ~ g,,8 DATE 9/20/02 CHECK NO, H207132 VENDOR DISCOUNT NET H -' ~tCl'lt, Ofc o' '£ Ð ~oo.,Q 2 ?OQ2 A. êi8 Ðoll "1I'Chora ~ CoIlJ/11l rle . 1Bslon No. H 207132 CONSOLIDATED COMMERCIAL ACCOUNT """/ AMOUNT ****$100.00**** 1J~::I:~:~::::.:~~!.\!~;,:~.::t~~ Rev: 07/10/02 C\jody\templates ") /' TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE "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(f), 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). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ,WELL PERMIT CHECKLIST COMPANY ßfJ Y WELL NAME/Au F-(")? A PROGRAM: Exp - Dev.)L Redrll...2L Re-Enter - Serv - Wellbore seg - FIELD & POOL 't::9ó)5ð INIT CLASS Oe..o /-d,7 GEOL AREA Ÿló UNIT# //C.sc ON/OFF SHORE ON ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ry: 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 N 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. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . .. . \::¡) N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_,' ,Ý;(~. A. (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. Y/ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . '¥-~'-N- 16. Surface casing protects all known USDWs. . . . . . . . . . . -¥-N- IlL.. 17. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥--N- NfH 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . '¥---N- 19. CMT will cover all known productive horizons. . . . . . . .. . t N ~~: ~~:~~a~:~~~~~;~~i~:~~~~ ;¡t:: ~ ~ :~r~~froo~t..: : : : : : ' ..' ~ CTð lÁ. 22. If a re-drill, has a 10-403 for abandonment been approved. . . ~ N i L{ ; (0'- . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . ~ N 24. If diverter required, does it meet regulations. . . . . . . . . . rlY N AVk ¡/J/J;, I 0. 7 25. Drilling fluid program sChem, atic & equip list adequate. . . . . . ., N ¿lJ1.Jt/¡£ 'I'i, '^"", 1J ' ýJ PC:¡ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N D' ~/j ,'. APPR DATE 27. BOPE press rating appropriate; test to ~5'OO psig. N JI/1tS { ¿J -:J¥' P ~ . ¡,V'.A I I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~ i Z- 1.//0 l- 29. Work will occur without operation shutdown. . . . . . . . . . . , N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~" _l/L. 31. Mechanical condition of wells within AOR verified. . . . . . . . ~ /'4" 32. Permit can be issued wlo hydrogen sulfide measures. . . . . ~~ ~ S/' ~Õ:5"'v ¡). 33. Data presented on potential overpressure zones. . . . . . . . ~ 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y , ~ /t ~, A" 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RP~ TEM JDH JBR APPR DATE ÚL- ~L (Service Well Only) GEOLOGY APPR DATE ht"" /2../'¡k,z. -(Éxploratory Only) Rev: 10/15/02 ') COMMISSIONER: COT ~/t; /0 ';).- DTS í<J, fO?- Commentsllnstructions: SFD- WGA /' MJW MLB /~/ t;/-:i. G:\geology\permits\checklist.doc ) ) 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 simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically organize this category of information. ') Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 04 08:32:05 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS ) a~-¿;;3J //to/6 Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22195 B. JAHN R. WHITLOW JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 5 AK-MW-22195 B. JAHN R. WHITLOW # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: F-08A 500292013501 BP Exploration Sperry Sun 04-APR-03 MWDRUN 3 AK-MW-22195 B. JAHN R. WHITLOW 2 11N 13E 2570 2877 54.79 .00 (Alaska) Inc. MWDRUN 4 AK-MW-22195 B. JAHN R. WHITLOW ) ) GROUND LEVEL: .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 11040.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS - SUBSEA (TVDSS). 3. WELL KICKED OFF FROM F-08 WITH TOP OF WHIPSTOCK SET AT ABOUT 11070' MD, 8814' TVDSS. 4. MWD RUN 1 WAS DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 2 WAS DIRECTIONAL WITH GM, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). NO FOOTAGE WAS DRILLED. A MAD PASS WAS PERFORMED WHILE POOH ACROSS THE MWD RUN 1 INTERVAL, THE EWR4 DATA ARE INCLUDED WITH THE RUN 3 DATA. 6. MWD RUN 3 WAS DIRECTIONAL WITH GM, EWR4. 7. MWD RUNS 4-5 WERE DIRECTIONAL WITH GM. 8. DIGITAL AND LOG DATA ARE DEPTH SHIFTED TO THE PDC GR LOG, (SCHLUMBERGER LOG RUN 12/19/2002) PER 03/03/2003 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER AND RUN INFORMATION DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 8. MWD RUNS 1-5 REPRESENT WELL F-08A WITH API # 50-029-20135-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12750'MD / 8988'TVDSS. SROP = SMOOTHED SGRC = SMOOTHED SEXP = SMOOTHED SESP = SMOOTHED SEMP = SMOOTHED SEDP = SMOOTHED SFXE = SMOOTHED $ RATE OF PENETRATION WHILE DRILLING. GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) FORMATION EXPOSURE TIME File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 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: # FILE SUMMARY 1 clipped curves¡ all bit runs merged. .5000 PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ ) ) START DEPTH 10655.5 11057.5 11057.5 11057.5 11057.5 11057.5 11071.5 STOP DEPTH 12718.5 11458.5 11458.5 11458.5 11458.5 11458.5 12746.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE 10655.5 10656.0 10663.5 10666.5 10681.0 10697.5 10703.0 11037.0 11059.5 11067.5 11079.5 11083.0 11100.5 11104.5 11109.5 11112.5 11130.5 11143.5 11161.0 11164.5 11167.0 11169.0 11172.0 11187.5 11189.0 11192.0 11207.5 11211.5 11219.5 11224.5 11226.5 11228.5 11236.5 11238.5 11241.5 11253.0 11266.0 11269.5 11277.5 11284.0 11326.0 11349.5 11366.0 11375.0 11398.0 11410.0 11426.0 11450.0 11463.5 11527.0 DEPTH GR 10654.0 10654.5 10662.0 10665.5 10680.0 10696.5 10702.5 11036.0 11059.0 11066.0 11079.5 11081.5 11100.5 11104.0 11108.5 11111.5 11129.5 11142.5 11160.0 11164.0 11166.0 11168.0 11170.5 11186.5 11187.5 11190.5 11207.0 11210.5 11218.5 11224.0 11226.5 11227.5 11236.5 11238.5 11240.5 11252.0 11266.5 11270.5 11277.5 11283.5 11326.0 11350.0 11366.5 11373.5 11400.5 11411.0 11423.5 11449.0 11462.5 11524.0 ') 11560.0 11591.0 11618.5 11664.0 11669.0 11672.5 11680.5 11683.0 11710.0 11724.0 11729.0 11764.0 11785.0 11854.0 11891.5 11903.5 11913.5 11944.0 11951.5 12273.5 12276.0 12377.0 12480.5 12556.0 12570.0 12746.0 $ 11558.0 11589.0 11615.0 11661.0 11665.5 11669.5 11679.0 11680.5 11708.5 11727.5 11731.5 11767.5 11785.0 11853.5 11891.0 11903.0 11916.0 11946.5 11952.0 12276.5 12279.5 12380.0 12485.0 12560.0 12574.5 12750.5 # MERGED DATA PBU TOOL MWD MWD MWD MWD $ SOURCE CODE MERGE TOP 10654.0 11057.0 11439.5 11874.5 MERGE BASE 11467.5 11489.0 11901.0 12750.5 BIT RUN NO 1 3 4 5 # REMARKS: MERGED MAIN PASS. $ # 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 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 HOUR 4 1 68 28 8 ) First Last ) Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10655.5 12746 11700.8 4182 10655.5 12746 ROP MWD FT/H 2.06 798.03 104.019 3350 11071.5 12746 GR MWD API 17.86 236.42 40.1092 3476 10655.5 12718.5 RPX MWD OHMM 3.5 27.27 7.95111 803 11057.5 11458.5 RPS MWD OHMM 3.98 31.72 9.29707 803 11057.5 11458.5 RPM MWD OHMM 4.09 35.97 9.96916 803 11057.5 11458.5 RPD MWD OHMM 5.23 48.31 12.1121 803 11057.5 11458.5 FET MWD HOUR 8.54 19.37 12.7452 803 11057.5 11458.5 First Reading For Entire File........ ..10655.5 Last Reading For Entire File.... ..... ..12746 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 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...... .03/04/04 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10654.0 ROP 11062.0 $ 2 header data for each bit run in separate files. 1 .5000 STOP DEPTH 11435.0 11467.5 # 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: 15-DEC-02 Insite 4.3 Memory 11465.0 10653.0 11465.0 40.0 92.6 ) # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ..... ......0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O TOOL NUMBER 74165 3.750 11040.0 Flo Pro 8.60 65.0 9.0 22000 .1 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 ) .0 137.9 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10654 11467.5 11060.8 1628 10654 11467.5 ROP MWD010 FT/H 1.31 798.03 117.225 812 11062 11467.5 GR MWD010 API 17.86 236.42 52.7774 913 10654 11435 First Reading For Entire File......... .10654 Last Reading For Entire File......... ..11467.5 ') File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ 3 ) header data for each bit run in separate files. 3 .5000 START DEPTH 11057.0 11057.0 11057.0 11057.0 11057.0 11424.0 11465.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11457.5 11457.5 11457.5 11457.5 11457.5 11445.0 11489.0 15-DEC-02 Insite 4.3 Memory 11490.0 11465.0 11490.0 88.1 88.1 TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 82758 125631 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11040.0 ) # 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: Flo Pro 8.60 65.0 9.0 22000 .1 .180 .090 .250 .500 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............ .... . Down Optical log depth units.......... .Feet . Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order 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 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR Min 11057 11.57 33.69 3.5 3.98 4.09 5.23 8.54 Max 11489 659.47 56.05 27.27 31.72 35.97 48.31 19.37 Mean 11273 197.717 43.0742 7.93544 9.2746 9.94855 12.0969 12.7636 Nsam 865 48 43 802 802 802 802 802 First Reading For Entire File........ ..11057 Last Reading For Entire File......... ..11489 ) 70.0 141.0 70.0 70.0 First Reading 11057 11465.5 11424 11057 11057 11057 11057 11057 Last Reading 11489 11489 11445 11457.5 11457.5 11457.5 11457.5 11457.5 ') ) File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.... ...... .STSLIB.004 physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type.. .. .. .. .. .. .. .. LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11439.5 ROP 11489.5 $ 4 header data for each bit run in separate files. 4 .5000 STOP DEPTH 11874.5 11901.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 16-DEC-02 Insite 4.3 Memory 11901.0 11490.0 11901.0 87.7 93.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 74165 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11040.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): Flo Pro 8.60 65.0 ) ') 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: 9.0 22000 .1 .000 .000 .000 .000 .0 141.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing.......... ......... ..60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . : . . . . . . . . . . . . . -999 Depth 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 MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11439.5 11901 11670.3 924 11439.5 11901 ROP MWD040 FT/H 3.17 530.39 97.521 824 11489.5 11901 GR MWD040 API 20.95 107.33 42.1667 871 11439.5 11874.5 First Reading For Entire File........ ..11439.5 Last Reading For Entire File....... ....11901 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/04/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header ) Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 ) header data for each bit run in separate files. 5 .5000 START DEPTH 11874.5 11901.5 STOP DEPTH 12723.0 12750.5 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 18-DEC-02 Insite 4.3 Memory 12750.0 11901.0 12750.0 86.2 92.3 TOOL NUMBER 74165 3.750 11040.0 Flo Pro 8.60 65.0 9.0 22000 .1 .000 .000 .000 .000 .0 159.0 .0 .0 ') ) 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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11874.5 12750.5 12312.5 1753 11874.5 12750.5 ROP MWD050 FT/H 2.32 483.28 97.4442 1699 11901.5 12750.5 GR MWD050 API 22.22 104.83 32.2588 1698 11874.5 12723 First Reading For Entire File........ ..11874.5 Last Reading For Entire File.......... .12750.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/04/04 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 Da t e. . . . . . . . . . . . . . . . . . . . . 03 1 041 04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name......... ..... ..UNKNOWN Continuation Number.... ..01 Next Reel Name......... ..UNKNOWN ) Comments............... ..STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ) Scientific Technical Services
