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Home My WebLink About201-184 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. 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., ban .: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 7/4/2010 201 -184 310 -153 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 11/02/2001 50 029 - 22462 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T. D. Reached: 14. Well Name and Number: Surface: 11/05/2001 PBU 15 -32A 1676' FNL, 333' FWL, SEC. 22, T11 N, R14E, UM 8. KB (ft above MSL): 68.05' 15. Field / Pool(s): Top of Productive Horizon: 1941' FNL, 650' FWL, SEC. 22, T11 N, RUE, UM GL (ft above MSQ: 33.3' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 3722' FNL, 2133' FWL, SEC. 22, T11 N, R1 4E, UM 8690' 8645' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 676277 y- 5959812 Zone- ASP4 11535' 8912' ADL 028306 TPI: x - 676601 y - 5959555 Zone ASP4 11. SSSV Depth (MD +TVD): 17. land Use Permit: Total Depth: x 678129 Y 5957810 Zone ASP4 N/A 18. Directional Survey: ® Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): Submit electronic and printed information per 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: MWD, GR, CNL 1 10365' 8848' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD k8-1 OLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91. H -40 114' 34' 114' -260 sx Arctic Set 13-3/8" 35' 117 rm fr ' 7 ' 9 -5/8" 47# L -80 2' 8327' 32' 8319' -1/4" 610 sx I 7" 26# L -80 / 13Cr 8165' 9649' 8161' 1' /2" 2 0 sx Class ' ' 4 -1/2" 1 L-80 1 9417' 10365'_ Liner n w/ 15-32A 2-3/8" 4.43# 1 L -80 1 8765' 1115361 8703' 1 12' 1 3" 1221 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#, 13Cr80 8621' 8092'/8089' MD TVD MD TVD 3 -1/2 ", 9.2 #, L -80 8703'- 8768' A703'/ 8655' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. NOV �U t� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED U t 8740' Set CIBP 8690' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize litholog f r water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory C 250.071. None 11 A 3 0 2010 RBDMS JUL S 0 1010 Alaska (0 & ION Cat'j. CowN ssion Anchorage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE / !a Sub it Original Only 29. GEOLOGIC MARKERS (List all formations and ma1W encountered): 30. MATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 1 B 8962' 8824' None Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing i true and correct to the best of my knowledge. 0 �/ • l� Signed: Terrie Hubble Title: Drilling Technologist Date: 9 PBU 15 - 32A 201 - 184 310 - 153 Prepared By Name✓Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Sean McLaughlin, 564 -4387 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 15 -32A, Well History (Pre Rig Sidetrack) Date Summary 5/18/2010 WELL S/I ON ARRIVAL. CURRENTLY PUMPING DIESEL FOR MIT -IA. 5/19/2010 PUMPED 19 BBLS TO REACH TEST PRESSURE OF 3000 #'s. MIT -IA PASSED (see log). DRIFTED TO TOP OF 31/2" XO @ 8722' SLM (8709 MD), W/ 20'x 3.70" WHIPSTOCK. RAN PDS 40 ARM CALIPER PER PROGRAM. LOGGED UP FROM 8721' SLM @ 50 FPM TO 7850' SLM. WELL LEFT S/I PIN DEPARTURE. 5/20/2010 WELL SHUT IN ON ARRIVAL. INITIAL T /1 /0= 2250/1100/140 SET BAKER 3 -1/2" CIBP. MIDDLE ELEMEN SET DEPTH = 8740'. 5/21/2010 RIH WITH WHIPSTOCK. CORRELATED TO SWS MCNL DATED 7 NOV 2001, SE BAKER GEN2 TT WHIPSTOCK TOP AT 8673'. ORIENTATION OF FACE 166 DEGREES WITH 2 PIP TAGS LOCATED 8683'. TAGGED AFTER SET WITH GOOD SURFACE INDICATION. OAL 17.53' AND MOD 3.625 ". FINAL T /1 /0= 0/900/140. JOB COMPLETE. WELL LEFT SI UPON DEPARTURE. 5/27/2010 T /IA/1O= SI/1100/150 Temp =Sl PPPOT-T (PASS) PPPOT -IC (PASS) (Pre CTD) PPPOT -T : RU 2 HP BT onto THA 0+ psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "ET style" all functioned with no problems. PPPOT -IC : RU 2 HP bleed tools onto IC test void 50 psi bled to 0 psi , flush void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bleed void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "ET style" all moved with no problems. 6/13/2010 T /I /O = 200/1080/175 Torqued tree to API specs. Tested tree to 5k. Tree passed pressure test. Pulled CIW H TWC thru tree for Pre CTD. Tagged @ 102" w/ 1 -2' ext. Post tree test and torque. No problems. 6/13/2010 T/I/O= MV/1100/180. Temp =Sl. Bleed WHP's to 0 psi (pre -CTD). No AL. IA FL @ surface. OA FL @ 280'(-20 bbls). Bled OAP from 180 psi to 2 psi in 2 hrs (all gas). IAP decreased 10 psi. Out of time. Monitored 30 mins. OA FL inconclusive. OAP increased to 10 psi. MV is locked out, no well house or flowline. Well Support has moved a drilling scaffold in place. Final T /I/O= MV/1090/10. 6/14/2010 T /1 /0= 110/1090/60. Temp =Sl. Bleed WHP's to 0 psi (pre -CTD). No AL. T & IA FL's @ surface. OA FL near surface. OAP increased 50 psi overnight. Bled TP from 110 psi to 0 psi in 50 mins (fluid), monitored during IAP bleed. Bled IAP from 1090 psi to 0 psi in 7 hrs, 30 mins (fluid /gas). Monitored 30 mins. IAP increased 1 psi. Bled OAP from 60 psi to 2 psi in 2 hrs, SI when FTS. Monitored 30 mins during continuing IAP bleed. OAP increased 20 psi. Final T /1 /0= 0/1/30. 6/17/2010 T /1 /0= 10/110/60. Temp =S1. WHP's (pre -CTD). No AL. TP increased 10 psi, IAP increased 109 psi, OAP increased 30 psi since 06/14/10. 6/21/2010 T/1/0=10/200/80. Temp = SI. WHPs. (pre CTD). No AL. TP unchanged, IAP increased 90 psi, OAP increased 20 psi from 06 -17 monitor. 6/22/2010 T /I /O = 10/200/80. Temp = SI. Bleed WHPs to 0 psi. (pre CTD). T FL near surface. IA FL near surface. OA FL near surface. Bled IAP from 200 psi to 0 psi in 1 hr 30 min. TP decreased 5 psi. Bled TP from 5 psi to 0 psi in < 1 min. Bled OAP from 80 psi to 0 psi in 1 hr. IAP increased 10 psi. Bled IAP from 10 psi to 0 psi in 10 min. Monitored 30 min. IAP increased 10 psi & OAP increased 40 psi. Final WHPs = 0 410/40. 6/24/2010 T /1 /0= 5/50/60. Temp =Sl. WHP's. (Pre -CTD). TP increased 5 psi, IAP increased 40 psi & OAP increased 20 psi in 2 days. Job Complete. 6/25/2010 T /I /O = 5/90/60. Temp = SI. WHPs (pre -CTD). IAP increased 40 psi overnight. 6/26/2010 T /I /O = 5/90/60. Temp = SI. WHPs (pre -CTD). No change in pressures overnight. 6/28/2010 T /1 /0 = 5/145/75. Temp =Sl. Bleed WHPs to 0 psi (pre CTD). No AL. Flowline disconnected, no WH. IAP increased 50 psi, OAP increased 10 psi since 6/26/10. TBG FL @ surface. IA FL near surface. OA FL near surface. Bled TP to 0 psi ,1 min, fluid. Bled IAP from 140 psi to 0 psi in 2 hr, all gas. Monitor IAP during OAP bleed. Bled OAP from 75 psi to 5 psi in 3 hr, fluid to surface. Bled 7.75 bbls from OA. During OA bleed, IAP increased 5 psi. Re -bled IAP to 0 psi in 5 min. Monitor for 30 min. IAP increased 5 psi, OAP increased 35 psi. Job incomDlete. Final WHPs =O +/5/40. Page 1 of 2 15 -32A, Well History (Pre Rig Sidetrack) Date Summary 6/29/2010 T /1 /0= 5/15/40. Temp =Sl. Bleed WHP's to 0 psi. (Pre -CTD). T, IA & OA FL's @ Surface. Bled OAP from 40 psi to 20 psi in 2 hours 30 minutes (bled back 109 gallons of fluid), OAP increased 20 psi back up to 40 psi in 5 minutes. IAP increased 5 psi to 20 psi during OA bleed. Bled IAP from 20 psi to 0 psi in 20 minutes. Monitor for 30 minutes during rig down. No change in TP during bleed or monitor, IAP increased to 5 psi in 30 minutes & OAP remained @ 40 psi during IA bleed & 30 minute monitor. Final WHPs= 5/5/40. Job incomplete. 6/29/2010 T /1 /0= 20/20/0 temp =S /I Load OA (CTD Prep) Pumped 250 bls 9.8# Brine down OA. PE & DSO notified upon departure. FWP= 60/60/0 6/30/2010 T /I /O = 30 /36NAC. Temp =S1. Bleed WHPs to 0 psi (pre CTD). Tubing pressure increased 10 psi, IAP increased 16 psi overnight. Tubing FL @ surface. IA FL near surface. Bled tubing pressure from 30 psi to 0 psi in 15 min, fluid. Bled IAP from 36 psi to 0 psi in 30 min, all gas. Monitor tubing pressure during IAP bleed. Bled IAP from 36 psi to 0 psiin 30 min. Monitor Tubing pressure & IAP for 30 min. Tubing pressure remained @ 0 psi, IAP increased 5 psi. Re -bled IAP to 0 psi in 2 min. Monitor IAP for 30 min. IAP increased 2 psi, re -bled IAP in 1 min. Job complete. Final WHPs= O /ONAC. 7/2/2010 TIO= vac /35 /vac. SI. Bleed WHPs to 0 psi (pre -CTD). Well house, flow line AL line all removed. Bled IAP to 0 psi in 30 mins (all gas). Monitor for 30 mins, IAP increased to 0 +. Final WHPs= vac /0+ /vac. Job Complete. Page 2 of 2 Pam 1 of 1 O Rap it Common Well Name: 15-32 AFE No Event Type: MOBILIZATION (MOB) Start Date: 7/3/2010 End Date: 7/4/2010 X3- 00WO2 -C (547,512.00 ) I Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 9/17/2001 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 1976' SNL, 333' EWL, SEC 22, T11 N, R14E UM Active Datum: 70.5 @70.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/3/2010 08:00 14:00 6.00 MOB P PRE SET THE RIG DOWN AFTER BACKING OFF WELL _ TO REPLACE HARDLINE ON PUMP #1 14:00 14:15 0.25 MOB P PRE PJSM TO MOVE RIG OVER TO 15 -32B 14:15 _ 15:00 0.75 MOB P PRE MOVE RIG TO 15 -32B 15:00 15:30 0.50 MOB P PRE PJSM TO SPOT RIG OVER 15 -32B 15:30 16:30 1.00 MOB P PRE SPOT RIG OVER WELL 15 -32B RIG ACCEPTED 16:30 18:00 1.50 MOB P PRE REMOVE TREE CAP & NU BOPE ONTO WELL HEAD _ 18:00 19:45 1.75 MOB P PRE LEVEL RIG 19:45 20:00 0.25 MOB P PRE . PJSM TO FINISH NU OF BOPE 20:00 22:15 2.25 BOPSUR P PRE FINISH NU BOPE 22:15 22:30 0.25 BOPSUR P PRE PJSM TO PT BOPE 22:30 00:00 1.50 ( BOPSUR P PRE PT BOPE AS PER NORDIC PROCEDURE & AOGCC _ REGULATIONS 7/4/2010 00:00 06:00 6.00 P PRE - P BOPE 06:00 06:20 0.33 BOPSUR P PRE CREW CHANGE & PJSM TO CONTINUE BOP TEST 06:20 08:15 1.92 ° BOPSUR P PRE CONTINUE BOP TEST 08:15 08:30 0.25 BOPSUR P PRE PJSM TO PU INJECTOR TO PT PACKOFF AND INNER REEL VALVE 08:30 09:00 0.50 BOPSUR_ P. PRE PT PACKOFF & INNER REEL VALVE 09:00 09:30 0.50 BOPSUR P PRE PUMP SLACK MANAGEMENT 09:30 09:45 0.25 BOPSUR P PRE PJSM TO CUT PIPE TO LOOK FOR WIRE 09:45 10:20 0.58 BOPSUR P PRE CUT PIPE TO FIND WIRE 10:20 10:55 0.58 BOPSUR P PRE PREP TO MU SLB CTC 10:55 11:10 0.25 BOPSUR P PRE PULL TEST CTC TO 42K 11:10 11:20 0.17 BOPSUR P PRE MOVE INJECTOR OVER BUNG HOLE TO PUMP _ SLACK FORWARD 11:20 11:30 0.17 BOPSUR P PRE MEG TEST WIRE 11:30 12:00 0.50 BOPSUR N SFAL PRE WIRE NOT TESTING, SUSPECT PIG TAIL FROM REEL TO NEW SHACK IS THE PROBLEM. BHI INVESTIGATING 12:00 12:30 0.50 BOPSUR P PRE FOUND BAD CONNECTION, MU UQC AND TERMINATE WIRE IN FLOW SUB i Printed 7/6/2010 10:12:02AM NaM America ALAS,KP, - BP r�tiisn Su�rnmary R�pdrt; Common Well Name: 15-32 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- 00W02 -C (1,285,456.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 9/17/2001 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 1976' SNL, 333' EWL, SEC 22, T11N, R14E _ UM Active Datum: 70.5 @70.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/4/2010 12:30 12:50 0.33 STWHIP P WEXIT PJSM TO PT BHI UCQ & FLOW SUB AND MU WINDOW MILLING BHA _ 12:50 13:15 0.42 STWHIP P WEXIT PT BHI TOOLS 13:15 13:40 0.42 STWHIP P WEXIT MOVE INJECTOR OVER BUNG HOLE TO PUMP SLACK FORWARD WHILE MAKING UP WINDOW BHA_ 13:40 14:00 0.33 STWHIP P WEXIT SLACKED PUMPED FORWARD AND BHA IS MADE UP, SHUTDOWN PUMP TO PU INJECTOR AND MAKE UP TO BHA 14:00 15:40 1.67 STWHIP P WEXIT RIH WITH WINDOW BHA AT MIN RATE TO 2500' THE INCREASE RATE TO DISPLACE FP FROM WELL 15:40 15:45 0.08 STWHIP P WEXIT STOP AND FLOW CHECK WELL FOR GAS, NO FLOW 15:45 16:10 0.42 STWHIP P WEXIT TIE IN FROM 8450' 16:10 16:15 0.08 STWHIP P WEXIT CORRECT DEPTH -3' AND RIH WT CK AT 8600'= 40K 16:15 16:30 0.25 STWHIP P WEXIT TAG WS AT 8688.5' PU 1WAND BRING PUMP ONLINE AT 2.5 BPM I SWAP TO GEOVIS 16:30 16:40 0.17 STWHIP P WEXIT START TIME MILLING FIRST 1' @ 1 FPH C 16:40 17:30 0.83 STWHIP N DFAL WEXIT PU OFF BOTTOM, MWD NOT WORKING NO COMMS TO MWD AND WO A FUNCTIONING DISCONNECT WE NEED TO POOH SLB MECHANIC HERE TO LISTEN TO INJECTOR BECAUSE THERE WAS A LITTLE CHATTER WHILE WE WERE RIH 17:30 19:15 1.75 STWHIP N DFAL WEXIT POOH FROM 8400' PJSM WITH CREW TO LD MILLING BHA WHEN 15 MIN UTES FROM SURFACE 19:15 20:15 1.00 STWHIP N DFAL WEXIT LID BHA & TROUBLESHOOT MWD TOOLS _ SWAP OUT MWD TOOLS 20:15 22:30 2.25 STWHIP N DFAL WEXIT RIH WITH NEW TOOLS TO 8,450' LOG TIE IN FROM 8,450' TO 8,490' 4 CORRECTION UP WT 37K CONTINUE TO RIH & TAG TOWS @ 8,690' 22:30 00:00 1.50 STWHIP P WEXIT MILL WINDOW PU TO 8,680' BRING PUMPS UP TO RATE FS 2,850 PSI @ 2.5 BPM RIH & TAG TOWS WITH PUMPS ON @ 8,689.3' TIME MILL THE FIRST 1' @ 1 FPH & 50 -100 PSI MTR WK, .5K - 1.5K WOB 7/5/2010 15:50 16:35 0.75 DRILL P PROD1 PU BHA _ TEST TOOL 16:35 17:10 0.58 DRILL P PROD1 RIH 2' AND TAGGED Printed 7/6/2010 10:12:50AM TREE = 4 1/16" CIW SAFETYES: WELL ANGLE> 70° @ 9015' WELLHEAD = FMC ACTUATOR = BAKER C - � *" *4 - 1 12 OME TBG & 7" LNR ` ** KB. ELEV 70.5' PJC DRAFT BF. R EV = NA KOP = 8149' Max Angle = 97° @ 10350' 2008' 4 -1/2" X NIP, ID = 3.813" Datum MD = 8989' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TV DEV TYPE J LATCH PORT DATE 20" CONDUCTOR, 91.5 #, H-40,19.124" 114 4 3029 3028 1 MMG RK 16 07/20/10 3 5031 5029 1 MMG RK 20 07/20/10 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 3530 2 6861 6859 0 MMG RK 0 04/11/08 1 7981 7979 5 MMG RK 0 04/11/08 M inimum ID = 2.387" @ 8754' $062' 4 - 1 — /2 - 7 NIP, ID — =3 - 813 - 1 - 3/16" X 2 -718" CROSSOVER 8092' 9 -5/8" X 4 -1/2" BKR S -3 PKR, ID = 3.875" $127' 4 -112" X NIP, ID = 3.813" TOP OF 7" LNR 8165' 8165 9 -5/8" X 7" TIEBACK SLV 8173 9 -5/8" X 7" TIW LTP w / LNR HGR, ID 9 -5/8" CSG, 47 #, L -80 NSCC, ID = 8.681" 8327' 8592 TOP OF 2 -7/8 3 -1/2" DEPLOY SLEEVE, ID= 3.000" " LNR 8592' 8604' 3 -1/2" PUP JT, ID = 2.992" $614 3 -1/2" OTIS X NIP, ID = 2.812" 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, 8621' 8621' — F - 1/ - 2 -- w — LEG, ID = 3.958" .0152 bpf, ID = 3.958" 3 -1/2" LNR, 9.3 #, L -80 STL, .0087 bpf, ID = 2.992" 8657' 8657' 3 -1/2" XO TO 3- 3/16 ", ID = 2.786" 7" LNR, 26 #, L -80 NSCC XO TO 13CR NSCC 8665' 7" LNR, 26 #, 13CR NSCC, .0383 bpf, ID = 6.276" $689' MILLOUT WINDOW (15 -32B) 8690'- 8695' 7" GEN II WHIPSTOCK (07/04/10) 8689' I h4 PERFORATION SUMMARY REF LOG: BHI MWD /GR ON 11/04/01 ANGLE AT TOP PERF: 96° @ 9317' Note: Refer to Production DB for historical perf data 8754' 3- 3/16" XO TO 2 -7/8 ", SIZE SPF INTERVAL Opn /Sqz DATE ID = 2.387" 2" 6 9317-9437 O 07/18/10 2" 6 9537-9797 O 07/18/10 2" 6 10017 - 10137 O 07118/10 2" 6 10317 - 10527 O 07/18/10 2" 6 10637 - 10677 O 07/18/10 2" 6 10757 - 10787 O 07/18/10 2" 6 10837 - 10877 O 07/18/10 3-3/16" LNR, 6.2 #, L -80 TCII, 8754' 2" 6 10927 - 11237 O 07/18/10 1.0076 bpf, ID = 2.80" 2" 6 11287 - 11307 O 07/18/10 pBTp 11584' 2" 6 11387 - 11477 O 07/18/10 2 -7/8" LNR, 6.5 #, L -80 STL, .0058 bpf, ID = 2.441" 11624' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/28/94 D9 ORIGINAL COMPLETION 07/27/10 PJC DRAWING CORRECTIONS WELL: 15 -32B 11/08/01 NORDIC 1 CTD SIDETRACK (15 -32A) 07/28/10 MK/PJC MIN ID CORRECTIONS PERMIT No: 2100620 04/11/08 D16 RWO API No: 50- 029 - 22462 -02 07/18/10 NORDIC 2 CTD SIDETRACK (15 -32B) SEC 22, T11 N, R1 4E, 1676' FNL & 333' FWL 07/26/10 PJC DRLG DRAFT CORRECTIONS 07/26/10 1 DAV /PJC GLV C/O (07/20/10) BP Exploration (Alaska) • • ~~Q~~ OCR Q~Q~~{Q /,~.~~.~~o~,~a John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. } ~,,,~ ~„ . °~tl i~ , ~ ~ ~ ~~:~3 P.O. Box 196612 ~ ©~ "' Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-32A Sundry Number: 310-153 Dear Mr. McMullen: 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 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. DATED this ~~day of May, 2010. Encl. U STATE OF ALASKA ~~C~1~f...~~e~~YL " ,~'1~1 ALASK~L AND GAS CONSERVATION COMMIS•N S/~'/O 5 APPLICATION FOR SUNDRY APPROVAL MAY 14 2010 20 AAC 25.280 ,,,_e._ ~.~ ~ ,~__,~,..... r~vnmiaslort 1. Type of Request: Aitd19~ ^ Abandon ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-184 3. Address: ^ Service ^ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22462-01-00 7. If perforating, closest approach in pool(s) opened 6y this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 15-32A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028306 ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (tt): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11535' - 8912' 11498' - 8908' 10460' None Casin Len Size MD ND Burst Colla e Structural Conductor 114' 114' 14 47 Surface 13-3/ " 530' 3 2 ' 4 0 227 Intermediate 8295' - / " 8327' 1 687 47 Production liner 1484' 7" 8165' - 9' 1 1' - 51' 7 4 1 Liner 948' 4-1/2" 9417' - 1 8872' - 84 ' 8430 7 00 Liner 7 ' - / " 7 1 112 117 Perforation Depth MD (ft): Perforation Depth TVD (tt): Tubing Size: Tubing Grade: Tubing MD (ft): 9120' - 9400' (Above Plug) 8866' - 8873' 4-1/2", 12.6# & 3-1/2", 9.2# 13Cr80 & L-80 8621' i3< 8703' - 8768' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'S-3' packer; Packers and SSSV 8092' / 8089' 7" x 4-1/2" Baker'S-3' packer MD (ft) and TVD (ft): 8703' / 8655' ' 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: June 1, 2010 ^ Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ~/ Abandoned ^ WAG ^ SPLUG ('~ Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLau hlin 564-4387 Printed Name n cMul en Title Engineering Team Leader Prepared By Name/Number. ' ~U /~ Terrie Hubble, 564-4628 Signature ,. ; Phone 564-4711 Date Commission Use Onl Conditions of approval: N tity Commission so that a representative may witness 31 ~ ~, I Sundry Number: ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance -~ 3S©o p s ~, ~ e ~ Other: Subsequent Form Required: l U - ~ O APPROVED BY ~ /D ~~ ~ Approved By: COMMISSIONER THE COMMISSION Date Form 10-4C4?~~1~p~(p A ry qo,~ ~ ~ %~ Submit In Duplicate ~~ MAT ~i 1 L a `(~ ~ ~'-'° v ~~ ~~~~~ To: Alaska Oil & Gas Conserva~ Commission • From: Sean McLaughlin ~~ CTD Engineer Date: May 11, 2010 Re: 15-32A Sundry Approval Sundry approval is requested for well 15-32A. 15-32A was drilled and completed as a tiny tool CTD sidetrack in November 2001. The well was a toe horizontal extension of the parent well (15-32) that was completed with -650' of 4-1/2" slotted liner which is now cemented behind the 2-3/8" liner. 15-32A had a 22 ft patch set over GLM #1 in December 2001 immediately following the sidetrack. The well came online and again developed T x IA communication in the summer of 2006 and was subsequently SI. Doyon 16 completed the RWO that replaced the corroded 4-1/2" x 3-1/2" tubing string with a 4-1/2" 13-Cr tubing string in April 2008. A total of 530' of adperfs were shot with the wellwork platform in July 2008 following the RWO. The 1~ 250' (10,730'-10,980' MD) were Z16 adperfs and were located just above the sidetrack's initial perfs. The remaining 280' (9,120'-9,400' MD) were Z1 A/1 B and were shot through 2 strings of pipe to re-access the parent wellbore's reserves. The adperfs brought in very little oil and consequently high GOR. A CIBP was set at -10,460' MD on 5/14/09 to help reduce the gas rates. There was no significant change in the well's GOR. The next couple of cycle attempts were unsuccessful due to high GOR. REASON FOR SIDETRACK: 15-32A has been SI for high GOR since late July 2009. There is no GSO or any other viable intervention options left to pursue. With such a low on-time and poor cycle performance, there is very little remaining value associated with this well. A CTD sidetrack is an attractive means to increase ontime to -100% while also boosting rate and access to reserves. The proposed plan for 15-32A is to drill a through tubing sidetrack with the a Coiled Tubing Drilling rig on or around June 10. 2010. The existing perforations will be isolated by a CIBP and the primary cement job. The sidetrack, 15-326, will exit the existing 7" liner and kick off in Z2 and target Zone 1 A reserves. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (scheduled to begin June 1, 2010) ,j /~cv/. 1. S Dummy GLV's 2, G~ 2. S Drift for 4-1/2" X 7" Thru tubing whipstock to 8703' MD (CO /iv/ 3. S Caliper 7" liner ~~~~~ we// 4. D MIT-IA - 3000 psi 5. E Set 3-1/2" CIBP at 8715' ' 6. D MIT-Tubing 2000 psi ' 7. E Set whipstock at 8680' MD 8. W AC-LDS; AC-PPPOT- T 9. W PT tree (MV,SV,WV), 10. O Bleed gas lift and production flowlines down to zero and blind flange 11. O Remove S-Riser, Remove wellhouse, level pad Rig Work: (scheduled to begin on June 10, 2010) 1. MIRU and test BOPE to 250 osi low and 3500 ~` wil ~~~ n ~G~ lad GX~ sc~~r/• twrf /~fi, ~rfr~~'e,:~~: i~~"~' J/j~C) 2. Mill 3.8" window at 8680' and 10' of rathole. 3. Drill Build: 4.125" OH, 405' (38 deg/100 planned) 4. Drill Lateral: 4.125" OH, 2515' (12 deg/100 planned) 5. Run 3-1/2" x 3-3/16" x 2-7/8" solid L-80 liner leaving TOL at 8580' 6. Pump primary cement leaving TOC at 8580', 31 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNVGR/CCL log 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions (1400') 10. Freeze protect well, Set BPV, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's Sean Mclaughlin CTD Engineer 564-4387 CC: Well File Sondra StewmanlTerrie Hubble 12EE = 41116" CMJ M1~.HEAD = - FMC • 15 -3 2A 1CTUATOR= BAKERC \B, ELEV - 68.05' 3F. ELEV = NA COP = 8149' Aax Angie = 98° ~ 9585' ~tum MD = 9105' )atum TV 0 = 8800' SS 20" CONDUCTOR, 91.5#, H-40, 19.124" 114' 13-3/8" CSG, 68#, L-80, ID = 12.415" 3530' Minimum ID = 1.920" ~ 8880' 2-3/8" LINER PIN *"" 2.3~PLOY SLV ~ 8728' ELM (37' HIGHER TVA\I A M.1 TI~t t V IS1111/~A TCC\ #°M •ln 2008' 4-1/2" X NIP ID = 3.813" ST MD TVD DEV TYPE VLV LATCH PORT OWTE 4 3029 3028 1 NMG DMY RK 0 08/09/09 5031 5029 1 MMG DMY RK 0 06/09/09 2 6861 6859 0 MMG DMY RK 0 04/11/08 1 7981 7979 5 MMG DMY RK 0 04/11/08 8062' 4-1/2" X NIP, 10 = 3.813" y 8092' ~-19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9-518" X 7" TIEBACK SLV, ID = ? 8165' 8127' 4-1/2" X NIP, ID = 3.813 X 7" TNV LTP w / LNR HGR, ID = 6.276" 8173' 9-5/8" CSG, 47#, L-80 NSCC, ID = 8.681" H 8327' 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 8621' 1.0152 bpf, ID = 3.958" 7" LNR, 26#, L-SO XO TO 13-CR NSCC 8665' TOP OF 2-3/8" LNR 8728' ELM 3-1/2" TBG, 9.2#, L-80 NSCT, 8788' .0087 bpf, ID = 2.992" TOP OF CEMENT 8792' OF 4-112" LNR ~-~ 9417' 8621' --~4-1/2" WLEG, ID= 3.958" 8703' T' X 4-112" BKR S-3 PKR, ID = 3.875" 8708' 4-1/2" X 3-1/2" XO, ID = 2.992" 8728' ELM 2.70" BKR DEPLOY SLV, ID= 2.250" 8740' 3-1/2" OTIS X NIP, ID = 2.813" (BEHIND CT LNR) 8757' 3-1/2" PKR SWN NIP, ID = 2.76" (BEHIND CT LNR) 8768' 3-1/2" WLEG, ID = 2.992" (BEHIND CT LNR) 9417' H T' X 41 /2" TNV SS PKR, ID = 3.96" 9464' ~4-1/2" PORTEDJT(41.55') BHNDCTLNR 7" LNR, 26#, 13CR NSCC, .0383 bpf, ID = 6.276" REF LOG: BHI MUVD/GR ON 11 /04/01 A NGLE AT TOP PERF: 83° ~ 912(Y Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 1-9/16" 6 9120 -9400 O 07/15/08 SLT D 9630 - 10342 S 11 /06/01 1-11 /16" 4 11000 - 111 ~ C 11 /08/01 1-11116" 4 11150 - 11230 C 11 /08/01 1-11 /16" 4 11290 - 11440 C 11 /08/01 10460' ~-~ 2-3/8" CIBP (05/12/09) PBTD~~ 11498' 2-3/8" LNR, 4.7#, L-80, STL, .0039 bpf, ID = 1.995" 11535' DATE REV BY COMMENTS DATE REV BY CON~NTS 04/28/94 DB ORIGINAL COMPLETION 06/03/09 TAR/TLH _ CIBP SET (05/12/09) 11/08/01 NORDIC 1 CTD SIDETRACK "A" 06/09/09 SWGTLH GLV GO 04/11/08 D76 RWO 04/15/08 KJB/SV GLV GO 05/08/08 AJW/PJC DRLG DRAFT CORRECTIONS 08/05/08 DMSfTLH ADPERF (07/15/08) PRUDHOE BAY UNIT WELL: 15-32A PERMIT No: 2011840 API No: 50-029-22462-01 SEC 22, 711 N, R14E, 1676' FNL & 333' FWL BP Exploration (Alaska) 9649' 5' E = 41 /16" CNV _:HE/'~ _ - FMC # 15 3 2 B ~*' " ' 'vv ~ mss. .r ~..~.~ nwv~~ ~ ~ v V av ~ .~ fUATOR = BAKER C 2-3/ EPLOYSLV ~ 8728' ELM (37' HIGHER - ~ ------ THAN 1 /01 TALLY INDICATES) *'" 7" ELEV = 68.05' P mposed C TD srlei?ack r•uornuG i niv ioeonei ~*** ELEV = NA ' _ __ 8149' Angle = 98_~ 9585' - 2008' 4-1/2" X NIP, ID = 3.813" ~m MD = 9105' ~m TVD = 8800' SS 20" CONDUCTOR, 91.5#, H-40, 19.124" 114' 13-3/8" CSG, 68#, L-80, ID = 12.415" 3530 Minimum ID = 2.5" ~ 8570' Bore of KB packer I9-518" X 7" TIEBACK SLV, ID = ? ~ 8165' 3" X 7" TNV LTP w /LNR HGR, ID = 6.276" 8173' 9-518" CSG, 47#, L-80 NSCC, ID = 8.681" 8327' 41/2" TBG, 12.6#, 13CR-80 VAMTOP, 8621' .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 XO TO 13-CR NSCC 8665' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3029 3028 1 MMG DMY RK 0 06/09/09 5031 5029 1 MMG OMY RK 0 06/09/09 2 6861 6859 0 MMG DMY RK 0 04/11 /08 1 7981 7979 5 MMG DMY RK 0 04/11 /08 8062' 4-1/2" X NIP, ID = 3.813" 8092' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8127' 4-112" X NIP, ID = 3.813" 8570' I--141/2" KB LTP 8580' 3.7" BOT dply SLV 8580' TOC TSGR 8,300' 8621' 4-1/2"WLEG,ID=3.958" gCGL 8,645' -8630 3-112" x 3-3/16" XO -9200 3-3/16" x 2-7/8" XO 14-1/2" x 7" WS I 3 5 deg -1/2" CIBP H 8715' TOP OF2-318" LNR 8728' ELM 3-1/2" TBG, 9.2#, L-80 NSCT, 8768' .0087 bpf, ID = 2.992" TOP OF CEMENT 8792' TOP OF 4-1/2" LNR 9417' 11600' H Planned TD ~ 8703' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8708' 4-1/2" X 3-1/2" XO, ID = 2.992" 8728' ELM 2.70" BKR DEPLOY SLV, ID = 2.250" 8740' 3-1/2" OTIS X NIP, ID = 2.813" (BEHIND CT LNR) 8757' 3-1/2" PKR SWN NIP, ID = 2.76" (BEHIND CT LNR) 8768' 3-1/2" WLEG, ID = 2.992" (BEHIND CT LNR) 9417' -j T' X 4-1 /2" TNV SS PKR, ID = 3.96" 9464' 4-1/2" PORTED JT (41.55') BHND CT LNR 7" LNR, 26#, 13CR NSCC, .0383 bpf, ID = 6.276" ~ 9649' 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 10365' PERFORATION SUMMARY REF LOG: BHI MWD/GR ON 11 /04/01 A NGLE A T TOP PERF: 83° ~ 9120' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 1-9/16" 6 9120 - 9400 O 07/15/08 SLT D 9630 - 10342 S 11 /06/01 1-11 !16" 4 11000 - 11100 C 11 /08101 1-11 /16" 4 11150 - 11230 C 11 /08/01 1-11!16" r 4 11290 - 11440 ~ i 11/08/01 ~ 10460' ~-{ 2-318" CIBP (05/12/09) PBTD ~--{ 11498' LNR, 4.7#, L-80, STL, .0039 bpf, ID = 1.995" I--I 11535' DATE REV BY COMMENTS DATE REV BY COMMENTS 04!28/94 D9 ORIGINAL COMPLETION 06/03/09 TAR/TLH CIBP SET (05/12/09) 11108/01 NORDIC 1 CTD SIDETRACK "A" 06/09/09 SWC/TLH GLV GO 04/11/08 D16 RWO 04/15/08 KJB/SV GLV GO 05/08/08 AJW/PJC DRLG DRAFT CORRECTIONS 08/05/08 DMS/TLH ADPERF (07/15!08) PRUDHOE BAY UNfT WELL: 15-32A PERMIT No: 1011840 API No: 50-029-22462-02 SEC 22, T11 N, R14E, 1676' FNL & 333' FWL ~ Exploration (Alaska) • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 • ~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, ~o~-t~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Date' 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-016 2042570 50029206960200 NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-O6A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-116 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11(9!2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-37B 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-426 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-45B 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-488 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-49B 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 ALASKA OIL AND GAS CONSERVATION COMMI`"ION REPa~,,,.' OF SUNDRY WELL OPER~I(ONS MAY 1 9 lU(~8 1. Operations Performed: A~56t8 ®ii ~ ~8S ~OnS• ~Cn1 ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate U^ Re-Enter~~Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-184' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22462-01-00 7. KB Elevation (ft): 68 05' 9. Well Name and Number: PBU 15-32A - 8. Property Designation: 10. Field /Pool(s): ADL 028306 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11535' ~ feet true vertical 8912' ~ feet Plugs (measured) None Effective depth: measured 11498' feet Junk (measured) None true vertical 8908' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 114' 114' 1490 470 Surface 3495' 13-3/8" 3530' 3529' 4930 2270 Intermediate 8295' 9-518" 8327' 8319' 6870 4760 Production Liner 1484' 7" 8165' - 9649' 8161' - 8851' 7240 5410 Liner 948' 4-1/2" 9417' - 10365' 8872' - 8848' 8430 7500 Liner 2770' 2-3/8" 8765' - 11535' 8703' - 8912' 11200 11780 Perforation Depth MD (ft): 11000' - 11440' Perforation Depth TVD (ft): 8868' - 8904' 4-1/2", 12.6#; 13Cr80; 8621'; Tubing Size (size, grade, and measured depth): 4.1 /9" 17 F# x ~-1 / " U 7# I -RO ' - ' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; 8092'; ' 7" x 4-1/2" Baker'S-3' packer 8703 12. Stimulation or cement squeeze summary: MAY ~ 0 2008 Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 372 18,227 3 1,300 1,693 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 NIA Printed Name Terrie Hubble Title Drilling Technologist _ )1 Prepared By Name/Number: V ~ Signature Phone 564-4628 Date Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 Submit Original Only - S ~. MAY ~ ~ 1006 ~~ ~ ( ~ ~~~IGINAL ssion TRFF= 4-1HB" CM/ WELLHEAD = FMC ACTUATOR= BAKERC KB. ELEV = 68.05' BF. ELEV -_ NA KOP= 8149' Max Angle = 98° @ 9585' Datum MD = 9105' Datum 8800' SS TVD= 20" CONDUCTOR, 91.5#, H-40, 19.124" ~', 13-3/8" CSG, 68#, L-80, ID = 12.415" ~ 3530' Minimum ID =1.920" @ 8880' 2-3/8" LINER PIN 9-518" X 7" TIEBACK SLV, ID = ? ~--~ 8165, 9-5/8" X 7" TMJ LTP w /LNR HGR, ID = 6.276" 8173' 9-5/8" CSG, 47#, L-80 NSCC, ID = 8.681" 8327' 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 8621' .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 XO TO 13-CR NSCC 8665' TOP OF 2-3/8" LNR ~-{ $728' ELM 3-1/2" TBG, 9.2#, L-80 NSCT, - j 8768. 0087 bpf, ID = 2.992" TOP OF CEME~ 8792' TOP OF4-1/2" LNR 9417' SAF'- ~ NOTES: WELL ANGLE > 70° @ 9015' 15 32A ***~~~" DEPLOYSLV @ 8728' ELM (37' HIGHER ~ THAN 11 /16/01 TALLY INDICATES) *** 7" CHROME LNR (PARTIAL}*** 2008' 4-1/2" X NIP, ID = 3.813 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3029 3028 1 MMG DOME RK 15 04/15/08 3 5031 5029 1 MMG SO RK 20 04/15/08 2 6861 6859 0 MMG DMY RK 0 04/11/08 1 7981 7979 5 MMG DMY RK 0 04/11/08 8062' --~ 4-1/2" X NIP, ID = 3.813" $092' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8127' 4-1/2" X NIP, ID = 3.813" 8621' --~4-1/2" WLEG, ID=3.958" 8703' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8708' 4-1/2" X 3-1/2" XO, ID = 2.992" '28' ELM -12.70" BKR DEPLOY SLV, ID = 2.250" 8740' 3-1/2" OTIS X NIP, ID = 2.813" (BEHIND CT LNR) $757' 3-112" PKR SWN NIP, ID = 2.76" (BEHIND CT LNR) $76$' 3-1/2" WLEG, ID = 2.992" (BEHIND CT LNR) 9417' ~-i 7" X 4-1 /2" TM/ SS PKR, ID = 3.96" )4-1/2" PORTED JT (41.55') BHND CT LNR ~ 7" LNR, 26#, 13CR NSCC, .0383 bpf, ID = 6.276" ~-) 9649' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 10365' PERFORATION SUMMARY REF LOG: BHI MWD/GR ON 11/04/01 ANGLE AT TOP PERF: 86° @ 11000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 1-11/16" 4 11000 - 11100 O 11/08/01 1-11/16" 4 11150 - 11230 O 11108!01 1-11/16" 4 11290 - 11440 O 11/08/01 SLTD 9830 - 10342 S 11/06/01 PBTDI-~ 11 2-3/8" LNR, 4.7#, L-80, STL, .0039 bpf, ID = 1.995" ~-~ 11535' ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 04/28/94 D9 ORIGINAL COMPLETION 04!20/08 ?/PJC DRLG DRAFT CORRECTIONS 11!08/01 NORDIC 1 CTD SIDETRACK "A" 05!08/08 AJW/PJC DRLG DRAFT CORRECTIONS 04!11/08 D16 RWO 04/13/08 SWC/PJC SET WRP & JUNK CATCHER 04/15/08 KJB/SV GLV C/O 04/17/08 CJN/PJC PULL JNK CATCHER/ WRP PRUDHOE BAY UNIT WELL: 15-32A PERM(f No: x2011840 API No: 50-029-22462-01 SEC 22, T11 N, R14E, 1676' FNL & 333' FWL BP Exploration (Alaska) Well History -15-32A, Pre-Rig Workover Date Summary 3/20/2008 T/I/O=SSV/200/200, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test void to check pressure (50 psi), bled to 0 psi. Pumped through void until clean fluid returns achieved. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely, no sign of bent or broken pins. PPPOT-IC: Stung into test void to check pressure (100 psi), bled to 0 psi. Pumped through void until clean fluid returns achieved. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 20 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely, no sign of bent or broken pins. 3/23/2008 MASTER WAS FOUND SHUT ON ARRIVAL. RAN 3.840" CENT. TAG TOP OF TRSSSV @ 2220' SLM, 2215' MD. RAN 3.840" CENT. & FLAPPER CHECKER SD @ SAME DEPTH. PICK UP CLEANLY, CONFIRMED TRSSSV IS ~ LOCKED OPEN. TAGGED TOP OF HES 4 1/2"_PATCH W/ 3.805" CENT @ 2988' SLM, 2984' ELM. RAN 4" GS, UNABLE TO LATCH HES PATCH, SLIPPING OUT. TOOL CAME BACK SHEARD. c 3/24/2008 ATTEMPTED TO LATCH/PULL HES RCP PATCH AT 2987'SLM W/ 4" GS (slipping out). RIH 3.50" LIB TO PATCH AT 2987' (OD of fish neck is corroded but ID of fish neck looks ok). RIH W/ 3.70" RELEASEABLE SPEAR (2.80" GRAPPLE) TO PATCH AT 2987' (not latching up). RIH W/ 2.30" CENT, 2.25" LIB TO 8711'SLM, TAGGED IBP (OOH W/CLEAN PIC OF IBP). RIH W/ 3.70" RELEASEABLE SPEAR (2.80" GRAPPLE Spread to 2.90") TO PATCH AT 2987'. LATCHED PATCH & JARRED 1 HR BEFORE POOH W/ ADDITIONAL 450 LBS WEIGHT.. 3/25/2008 JAR FOR 6 HOURS IN ATTEMPT TO RETRIEVE HES PATCH FROM TRSV Cc~ 9215' MD. PULLED OUT_ ~E_ ROPE SOCKET RETRIEVED ALL WIRE & TOOLSTRING FROM WELL. 3/26/2008 JARRED 9 HRS ATTEMPTING TO PULL HES RCP PATCH THRU SSSV NIPPLE AT 2195' SLM. 3/27/2008 PULL SPEAR FROM PATCH AT 2193'SLM TO INSPECT CONDITION (5 MISSING TIPS). DRIFTED TO &THRU PATCH AT 2193'SLM W/2.25" CENT/BRUSH (NO OBSTRUCTIONS) NOTE: HES RCP PATCH LEFT IN SSSV (OAL: 26.68' /STRIPPED OUT 4" G FISH NECK). FISH: 5 PIECES OF GRAPPLE TIPS LOST DOWN HOLE _ .936" WIDE x .805" x 1.725" 3/31/2008 ~RULLED RCP PATCH FROM 2201' BLM (SSSV NIPPLE) (all elements & slips recovered). RAN 3.84" NOGG, FLAPPER CHECKER TO 2222' BLM, (DRIFTED IN/OUT OF TRSV OK). 4/1/2008 T/I/0=50/170/460. Temp=S1. TBG & IA FL (assist SL). TBG FL @ surface, IA FL @ 126' (6.7 bbls). 4/1/2008 TAGGED IBP @ 8741' BLM W/ 2.50 LIB. HAD TO DROP DAP SLEEVE TO COME BACK THROUGH (locked out trsssv). RAN 4 1/2" GS TO 2220' BLM, (recoved dap tool). RAN 3.84 NOGO, TO 2213' SLM. RAN 4 1/2" PERMANENT LOCK OUT TOOL TO 2213' SLM (locked out trdp w/ Irs assistance). RIH W/ 3.84 NOGO, 5' 1 1/2" PRONG FLAPPER CHECKER IN PROGRESS. 4/1/2008 T/I/O = 50/140/425 -Assist slickline lock out SSSV, Freeze Protect Flow Line on well #47 (Pre-RWO) Pumped 5 bbls neat methanol spear and 94 bbls crude to attempt to free up SSL -hung upon SSSV valve. DAP tool ran and freed SSL. Pumped 5 bbls crude to lock out SSSV. 4/2/2008 T/I/0= 150/150/450 Temp= S/I CMIT TxIA to 3500 psi. -In Progress- (Pre RWO) Pumped 85 bbls 100'F crude down IA, RD IA and RU to Tbg. 4/2/2008 Freeze protect hardline and 15-47 flowline w/10 bbls neat meth. FWP's = 150/150/440. Casing valves open to guages, hardline loop shut in, tags hung, DSO notified of well status. 4/2/2008 RAN 3.84 NOGG, 5' 1 1/2 STEM, FLAPPER CHECKER @ 2213'SLM (trssv locked out pins good). PULLED 2 1/8 BAKER IBP @ 8712'SLM. DRIFT W/ WFD DMY WRP 3.7" TO 8732' SLM. TAG XN-NIPPLE @ 8732' SLM (8757' MD), PUH 22' FLAG WIRE. SET 3 1/2" WRP @ 8735' MD. SET 3 1/2" JUNK CATCHER @ 8705'SLM (122" OAL 2.7" OD). 4/3/2008 Temp= S/I CMIT TxIA FAILED to 3500 psi. (Pre RWO) Pumped 270 bbls crude down the Tbg to establish LLR o' 5 bpm @ 1200 psi for 68 bbls without change. Called off job to be replaced with LRS 46. Final WHP's= 60/80/450 "Annulus casing valves open on departure" 4/3/2008 PULLED 3 1/2' JUNK BASKET FROM 8705' SLM. PULLED 3 1/2" WRP FROM 8710' SLM. TAG TOP OF LINER W/ 2.5" LIB @ 8733' SLM. `~ Well History - 15-32A, Pre-Rig Workover Date Summary 4/4/2008 SET 3.5" WRP @ 8722' MD (Irs cmit to 3500 pass). SET JUNK CATCHER 122" OAL 2.70 MAX OD @ 8720'SLM. ~(. P OF JUNK BASKET IN 3 1/2" TBG W/ 2.5" LIB 4/4/2008 T/I/0=0/0/450 Temp = SI Circ-Out (Pre-RWO) Standby for hardline crew to rig up reverse out skid, and fluid to arrive on location. 4/4/2008 T/I/O = 100/100/450 Temp = S/I - CMIT Tx IA PASSED to 3500 psi (Pre RWO) Pressured up T/I to 3500 psi with 15 bbls 90"F crude. T/I lost 180/160 psi in 1st 15 mins and 80/80 psi in 2nd 15 mins for a total loss of 260/240 psi in 30 mins. Bled WHP's. Bled back ~ 12 bbls fluid. FWHP's = 200/120/450 ~~~ Casing valves open to guages, tags hung, DSO notified of well status. 4/4/2008 INITIAL WHP'S= 0/0/450. JET CUT 3.5" TUBING @ 8669', 10' FROM TOP OF JOINT. FINAL WHP'S= 0/0/450. JOB COMPLETE, WELL LEFT S/I. 4/5/2008 T/I/O 10/0/25 Set 4" ciw bpv thru tree (pre rig work). Job Complete. 4/5/2008 Circ-Out, Load OA with 9.8 brine (Pre RWO) Pumped 5 bbls neat meth followed by 901 bbls 1 % KCL down Tbg up IA, taking returns to the flowline of well #47. Freeze protected Tbg/IA with 150 bbls diesel, pumped down IA, taking returns up Tbg to flowline. U-Tubed TxIA to put freeze protect in Tbg. Freeze Protected Flowline (well 47) with 5 bbls neat meth and 25 bbls crude. Freeze protected surface lines with diesel upon departure. Loaded OA with 3 bbls neat meth and 262 bbls 9.8 # brine, freeze protected with 12 bbls diesel. Bled WHP's ""Wellhead valves checked for position and tags hung upon departure"" FWP's=0/0/vac 4/6/2008 T/I/0= 0/0/0 Pulled 4 1/16" CIW BPV# END404 through tree for Doyon 16 to start work. 102". Set VR Plug to pull 3 1/8" FMC I/A off front of tree for rig. VR tag on well head. 2 .... BP EXPLORATION Page 1 of 5 OAerations Summary Report Legal Well Name: 15-32 Common Well Name: 15-32A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task 'Code NPT 4/5/2008 06:00 - 12:00 6.00 MOB N WAIT Start: 4/6/2008 Rig Release: 4/11/2008 Rig Number: Spud Date: 9/17/2001 End: 4/18/2008 Phase ` Description of Operations PRE Stand-by for Wellhouse and Flowline removal and Pad Prep for 15-32A. Clean Rig and perform Rig Maintenance as needed. 12:00 - 16:30 4.50 MOB N WAIT PRE Continue to stand-by for 15-32A to be ready. Continue Rig housekeeping in motor room and as needed in other locations. Clean Windwalls. Complete work-orders and address concerns from Rig Safety Audit. Remove snow from around rig in preparation for moving off of 15-49. 16:30 - 17:00 0.50 MOB N WAIT PRE Clean and clear Rig Floor. Review Rig Move Checklist and prepare Rig for moving off of 15-49. 17:00 - 17:30 0.50 MOB N WAIT PRE Move Rig off of 15-49 and stage parallel to well row. 17:30 - 00:00 6.50 MOB N WAIT PRE Continue to stand-by for 15-32A. Continue general housekeeping and maintenance. Weld mounting brackets for new communications equipment antennas on back of rig. 4/6/2008 00:00 - 12:00 12.00 MOB N WAIT PRE Stand-by for 15-32A pad preparation. General housekeeping and maintenance on rig while waiting. 12:00 - 16:00 4.00 MOB P PRE Move rig from 15-49A to 15-32A. Wait on DSM to place VR plug in the IA valve facing the rig. Check IA and well is on slight vacuum. DSM pulled rig-side bullplugged flange on the IA valve, installed VR plug, and removed the valve. DSM installed the bull-plugged flange with a Whitey valve and plug. Danny Moffett was at wellsite and said that they would ensure that DSM SOP for pre-rig work for D-16 would include the removal of the proper valves before D-16 moves on. Connect all lines to circulating manifold. Install 2-nd valve on the IA and the OA valves and connect lines to them with the OA vented to the Slop Tank. Center rig over well and take on fluid to the Pits. Accept Rig at 1600-hours. 16:00 - 17:00 1.00 WHSUR P DECOMP P/U DSM lubricator and M/U to tree. Test lubricator to 500-psi. .Pull BPV and no pressure under valve. IA still on slight 17:00 - 18:30 1.50 KILL P DECOMP 18:30 - 22:00 3.50 KILL P DECOMP 22:00 - 22:30 0.50 KILL P DECOMP 22:30 - 23:30 1.00 KILL P DECOMP vacuum. Finish R/U lines, then hold Pre-Spud PJSM with crew, Vac truck drivers, day and night WSLs and WSL of the future. Reverse Circulate out ~30-bbls Diesel Freeze Protection in Tubing, displacing with 8.4-ppg 1 % KCI brine. Mud Pump #1 pumping at 6-bpm / 580-psi. Took 12-bbls pumped before seeing returns. Swap over and pump 20-bbl Hi Vis sweep the long way to get -118-bbls Diesel Freeze Protection out of the Annulus. Pumping at 5-bpm / 300-psi. Did not get sweep back at surface when estimated (6900 stks) so continued to circulate another bottoms up. No sweep back but did see increasing amounts of sand coming across shakers. Flow check by monitoring gas buster outlet -Static. Drain Tree and FMC tech Installed TWC. , Test TWC below to 1,000-psi and hold for 10 charted minutes. 0o es . est from above to 3,500-psi again and hold for 10 cnartea minutes. c.;ooa i est. 23:30 - 00:00 0.50 KILL P DECOMP Blow down all lines in cellar. R/D cellar circulating manifold. 4/7/2008 00:00 - 01:30 1.50 WHSUR P DECOMP N/D Production Tree. Inspect Tubing hanger threads and check with 4-1/2" NSCT XO. Screwed into the hanger for 6-1/2 turns by hand. 01:30 - 03:30 2.00 BOPSU P DECOMP N/U BOP stack, Choke & Kill Lines. 03:30 - 04:00 0.50 BOPSU P DECOMP R/U to test BOPs. 04:00 - 08:30 4.50 BOPSU P DECOMP Test BOPs per BP & AOGCC procedures. Low pressure test YfI11i60: 4/Ll/CUUi3 I:IL:4/ YM BP EXPLORATION `Operations Summary Report Legal Well Name: 15-32 Common Well Name: 15-32A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task i Code i NPT 4/7/2008 ~ 04:00 - 08:30 ~ 4.50 ~ BOPSU Fj P 08:30 - 09:00 0.50 PULL P 09:00 - 10:30 1.50 PULL P 10:30 - 11:30 ~ 1.00 i PULL ~ P 11:30 - 12:30 1.00 ~ PULL ~ P 12:30 - 14:00 I 1.501 PULL I P 14:00 - 14:30 ~ 0.50 ~ PULL ~ P 14:30 - 16:30 2.00 PULL P 16:30 - 17:00 0.50 PULL P 17:00 - 19:00 2.00 PULL P 19:00 - 22:30 3.50 PULL P 22:30 - 23:00 0.501 PULL P 23:00 - 00:00 ~ 1.00 ~ WHSUR ~ P 4/8/2008 ~ 00:00 - 01:00 ~ 1.00 ~ WHSUR ~ P 01:00 - 01:30 0.50 WHSUR P 01:30 - 02:00 0.50 CLEAN P 02:00 - 04:00 2.00 CLEAN P 04:00 - 05:00 I 1.001 CLEAN I P 05:00 - 12:30 7.50 CLEAN P 12:30 - 16:00 3.50 CLEAN P Page 2 of 5 i Spud Date: 9/17/2001 Start: 4/6/2008 End: 4/18/2008 Rig Release: 4/11/2008 Rig Number: Phase Description of Operations DECOMP to 250-psi & High Pressure test to 3,500-psi. Hold all tests for 5 charted minutes. Test Annular Preventer, Pipe Rams, Blind Shear Rams, IBOPs, TIW & Dart valves, all Choke Manifold valves, Choke & Kill Line manual & HCR valves, and Accumulator. Test with 4-1/2" and 3-1/2" test jts. AOGCC rep Lou Grimaldi waived witness of BOP test at 2100-hrs. All tests witnessed by BP WSLs and DDI TPs. Called DSM at 0600-hours and were told that two rigs were ahead of Doyon 16 for their services. DECOMP Clear and clean Rig Floor. DECOMP Wait on DSM. Bring Schlumberger Camco spooler to Rig Floor. Finish loading and strapping Drill Pipe into the Pipe Shed. DECOMP P/U and install lubricator extension. P/U and M/U DSM lubricator to extension. Test Lubricator to 500-psi. DECOMP P/U Landing Joint and screw into hanger 7-1/2 turns. Connect IA valves to Slop Tank via high pressure hose and leave valves in open position. Check OA and no pressure on OA. Hold PJSM for pulling the hanger to the floor. MU Top Drive to Landing Joint. BOLDSs. Pull on Hanger and it breaks_free at 125,000-Ibs, then dro s to 120,000-Ibs, ullin Basil u hole. DECOMP Circulate Bottoms Up 10-BPM, with initial circulating pressure of 680-psi and FCP of 760-psi. DECOMP B/O and UD landing joint. Slowdown the Top-Drive. Changeout the elevators. Restrain and cut the single 1/4" SS control line. M/U the control line to the Camco spooler. DECOMP POH and UD 4-1/2" tubing through the Pipe Shed. DECOMP R/D Control Line spooler and move out to load on Schlum/Camco truck. DECOMP Continue to pull and UD 4.5" Completion from 6,400' to 4,700'. DECOMP R/U 3-1/2" Handling Equipment and Pull and UD 3-1/2" Tubing from 4,700' to Cut 't. Holes in Tbg jts #133, 134, 136, 149, 154, 155, 169, 175, 177 and 206. Pin ends on most jts were eroded. Thick yellow and orange scale below last GLM C~3 -8,059'. Recovered 32-S/S bands, 94-jts 4-1/2" NSCT Tbg, 145-jts 3-1/2" NSCT Tbg, 1-SSSV, 4-GEMS, 1-X NippleCut, 1-Cut Jt. Cut Jt length=10.78 and cut was flared to a 4" OD. DECOMP R/D 3-1/2" Handling Equipment. Clear and Clean Rig Floor, Change out to 4" Elevators, drain BOP stack. DECOMP P/U single of drill pipe from pipe shed and pull Pack-Off, broke free at 90,000# up weight. M/U new Pack-Off. DECOMP RIH with new 9-5/8" Pack-off. Screw in with Top Drive and install per FMC tech. Test Pack-off to 5000-psi and hold for 30-minutes. Service Top Drive. DECOMP Install Wear Ring. DECOMP P/U six 4-3/4" DC from pipe shed and stand back in Derrick. DECOMP P/U and M/U 3-1/2" Tubing stub Dress-off BHA -Dress-off Shoe, Wash Pipe, Internal Mill, 2-Boot Baskets, Bumper Sub, and 6-DCs. RIH on DCs to 216' md. DECOMP P/U and RIH w/ 11-jts of 4" DP from shed to space out the 9-5/8" casing scraper above the 7" liner top C~ 8,173' md. DECOMP RIH Dress-off BHA on DP from Derrick. 54-joints RIH at 0620-hours. 72 at 0650-hrs. DECOMP Obtain drilling parameters at 8670' D-16 MD: P/U wt 164K, S/O Nrinted: aizvzuue 1:7L:4/ NM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 15-32 15-32A WORKOVER DOYON DRILLING INC. DOYON 16 Date From - To Hours Task Code -NPT 4/8/2008 12:30 - 16:00 3.50 ~ CLEAN ~ P 16:00 - 17:00 ~ 1.00 ~ CLEAN ~ P 17:00 - 19:00 2.001 CLEAN ~ P 19:00 - 20:00 ~ 1.00 ~ CLEAN ~ P 20:00 - 21:00 1.001 CLEAN ~ P 21:00 - 22:00 ~ 1.00 ~ CLEAN ~ P 22:00 - 00:00 2.00 CLEAN P 4/9/2008 00:00 - 00:30 0.50 CLEAN P 00:30 - 01:30 1.00 CLEAN P 01:30 - 03:00 1.50 CLEAN P 03:00 - 04:00 ~ 1.00 ~ CLEAN ~ P 04:00 - 07:30 ~ 3.50 ~ CLEAN ~ P Page3of5~ Spud Date: 9/17/2001 Start: 4/6/2008 End: 4/18/2008 Rig Release: 4/11 /2008 Rig Number: Phase Description of Operations DECOMP wt 166K, Rot wt at 60-RPM 169K, 3-BPM at 210-psi. Continue RIH to to stub at 8692' D-16 MD. Put 2K-Ibs WOB and see torque range from 2-5K-Ib-ft. Try two more times and do not gain any depth. Suspect that SBR may be spinning and call ADW engineer to discuss options. Baker fisherman calls Baker and jointly decide to continue with dress-off. Use various weights on bit as well as various pump rates and RPMs, but did not make any progress. Call ADW engineering to discuss options, when Baker lead fishing expert arrives at rig. Decide to pump a sweep and the POH and S/B DP and DCs to examine the dress-off BHA. Total depth is 8,692', Doyon 16 DP MD. DECOMP Pump sweep at 9-BPM and 1400-psi. Recovered about 5-gallons of sand and oily debris across the shakers. Monitor well; no flow or losses. Pump dry job and blow down Top Drive. DECOMP POH standing back 4" HT-38 drill pipe in derrick. Make several passes with 9-5/8" Scraper from 8,050' to 8,100' to cover the intended packer setting depth of 8,080'. DECOMP POOH with dress off assembly. Examination of mill showed that only 3" of the tubing stub was swallowed. The inner mill was untouched. Discuss results with ADW. Decide to P/U and RIH with spear and attempt to release K-Anchor. DECOMP Clear and clean rig floor. Gather Baker fishing tools for BHA #2. DECOMP P/U BHA #2 Bowen Type "C" Dimension Spear. BHA consisting of spear with 3.001 "grapple, bumper sub, jars, pump out sub, x/o sub, (2) stands of 4-3/4" drill collars. Total length of BHA #2- 219.19' DECOMP RIH with BHA #2 on 4" HT-38 drill pipe from derrick. DECOMP Continue to RIH with BHA #2 on 4" HT-38 drill pipe from derrick. DECOMP PJSM. Slip and cut 98' of drill line. Inspect brakes and linkage. Inspect Dyna-Matic. DECOMP Establish fishing parameters of Up Wt- 165,000 Ibs and Down Wt- 167,000 Ibs. P/U 2 single of 4" HT-38 drill pipe from pipe shed and RIH. Tag top of tubing stub at 8692'. Continue to RIH and "No Go out at 8704'. Pump at 3 bpm with 1700 psi. P/U to 200,000 Ibs to hit with jars. Dead lift to 225,000 Ibs. Repeat once more to set grapple. S/O to 180,000 Ibs and rotate right at 5 rpm with 3000 ft-Ibs torque. Worked 1-1/2 to 2 rotations in work string and grapple would appear to slip yet latch up without any left hand rotation. Continue to work on releasing K-Anchor this way for several cycles. Grapple continued to appear to slip. Attempt to set grapple with up weight to 215,000 Ibs and hit with jars. Dead pull to 225,000 lbs. Last hit with jars at 215,000 Ibs grapple pulled free. Attempt to S/O and latch back to fish. Attempt twice to reset grapple with left had rotation. Could not get any overpull. S/O to No Go at 8703'. Lost 1' to 1-1/2' of hole. DECOMP Drop ball to open circulating sub with 3 bpm with 1100 psi. Open circ sub with 2400 psi. CBU at 12 bpm with 1790 psi. Bottoms up had trace amount of gas and cleared up immediately. DECOMP Blow down top drive and L/D 2 singles of 4" HT-38 drill pipe not rnncea: viz uzwe i:icvi rm ....~ BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: 15-32 Common Well Name: 15-32A 'Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date. From- To Hours Task Code NPT 4/9/2008 04:00 - 07:30 3.50 CLEAN P 07:30 - 09:00 1.50 CLEAN P 09:00 - 09:30 0.50 CLEAN P 09:30 - 11:00 1.50 CLEAN P 11:00 - 11:30 0.50 CLEAN P 11:30 - 12:30 1.00 CLEAN P 12:30 - 13:30 1.00 CLEAN P 13:30 - 14:00 0.50 CLEAN P 14:00 - 20:00 6.00 CLEAN P 20:00 - 20:30 ~ 0.50 ~ CLEAN ~ P 20:30 - 21:30 1.00 CLEAN P 21:30 - 22:30 1.00 CLEAN P 22:30 - 00:00 ~ 1.50 ~ CLEAN ~ P 4/10/2008 00:00 - 02:00 ~ 2.00 CLEAN ~ P 02:00 - 03:30 ~ 1.50 ~ CLEAN P 03:30 - 06:00 ~ 2.50 ~ CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30 - 08:00 1.50 BUNCO 08:00 - 08:30 I 0.50 Spud Date: 9/17/2001 Start: 4/6/2008 End: 4/18/2008 Rig Release: 4/11/2008 Rig Number: Phase i Description of Operations DECOMP in string. POOH standing back 4" HT-38 drill pipe in derrick. DECOMP freak out and UD fish: 20.65' cut joint of 3-1/2" tubing; 9.74' long 3-1/2" tubing pup joint; and Baker KBH-22 Seal assembly attached to 3-1/2" x 4-1/2" XO, overall length to top of seals 2.30'. Total overall length of fish to top of seals = 32.69'. DECOMP P/U and M/U BHA #3: 5-3/4" RCJB with 6" OD head, Bumper Sub, and 6-ea 4-3/4" Drill Colars. DECOMP RIH BHA #3 on DP from Derrick to clean off the top of the packer at 8,725' Doyon 16 RKB. DECOMP Rig crew convened in DogHouse for Safety meeting with Steve Rossberg, ADW Manager, Allen Graff, ADW NS HSE. DECOMP Continue RIH to Hoover off the top of the packer at 8725'. DECOMP Get parameters: P/U wt 164K, S/O wt 168K, Drop ball and chase down at 5-BPM, 860-psi. Pressure increased to 1050-psi when the ball got on seat. Continue RIH and lightly tag at 8725', P/U 6' and increase pump rate to 10-BPM with an initial circ pressure of 2650-psi and a final circ pressure at bottoms up of 2890-psi. DECOMP Well dead. Mix and pump dry job. Blow down Top Drive. DECOMP POH and UD Drillpipe through Pipe Shed. 15-joints UD at 1430-hours. 39-jts C~ 1500-hrs. 90-jts @ 1600-hrs. 135-jts 1700. DECOMP POH with BHA #3 (RCJB). UD 6 drill collars, bumper sub, x/o sub, and RCJB. RCJB recovered- 2 pieces of CMT, 1 piece of rubber element, and 4 of 8 slip segments from the K-Anchor ratchet latch ring. DECOMP Evalutate results from RCJB. Clear and clean rig floor. DECOMP R/U 7' lubricator from annular to rig floor. Gather SWS slickline tools and equipment. R/U SWS slickline. DECOMP R/U SWS with 3.5" magnet and 4.958" brush. RIH and stack out at 8710' SLM. POOH. No recovery. DECOMP R/U SWS with 2.3" magnet and 2.992" brush. RIH and stack out at 8710' SLM. POOH. No recovery. Small amount of damage on magnet showing signs of obstruction. DECOMP P/U and run 2.5 Ib lead impression block to 8710' SLM. POOH. Sign on impression block showed damage on one side from possible slip segment standing up on side of X/O. Also light impression of slip teeth from another slip segment laying flat slip teeth up across X/O. DECOMP P/U center spear with 2.7" bell guide. Total length of spear assembly- 42" made up of 6" bell guide and 36" spear. RIH to 8712' SLM. Bell guide hanging up at 4.5" x 3.5" X/O. Work spear assembly through X/O to 8718' SLM where spear hung up. Work spear assembly loose with 4 hits from hydraulic jars. Spear assembly worked free, but unable to read spang jars topping out. POOH with spear assembly. Spang jars jammed up with 2 cups of sand fill. Call ADW Engineer and decide to POH and R/D Schlumberger slickline and RIH with the new 4-1 2" om letion strin . DECOMP R/D Schlumberger slickline equipment. RUNCMP R/U Doyon Casing torque-turn equipment. Check computer interface and hydraulic tongs. RUNCMP PJSM with rig crew, Doyon Casing personnel, Toolpusher and rrintea: nrnauus i:iz:4i rnn BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: 1 5-32 Common W ell Name: 1 5-32A Spud Date: 9/17/2001 Event Nam e: WORKO VER Start : 4/6/2008 End: 4/18/2008 Contractor Name: DOYON DRILLIN G INC . Rig Release: 4/11/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Cade N PT Phase Description. of Operations 4/10/2008 08:00 - 08:30 0.50 BUNCO RUNCMP WSL. Check the WLEG to ensure smooth entry in the muleshoe. 08:30 - 20:30 12.00 BUNCO RUNCMP RIH with 199 joints of new 4-1/2", 12.6-Ib, 13Cr-80, VamTo completion. Using Jet Lube Seal Guard pipe dope and a stabbing guide; torque all connections to optimum torque of 4,440-Ib-ft. The only connection that will be Bakerloked on the Rig Floor is between the first X-nipple assembly and the Baker packer assembly. Changed out 2 joints due to incorrect make up. Replaced bad joints with 2 spare joints. 20:30 - 21:00 0.50 BUNCO RUNCMP P/U and M/U TBG Hanger. Blank off control line ports 21:00 - 21:30 0.50 BUNCO RUNCMP RIH with TBG Hanger and land in TBG spool. Land and RILDS. Final Pick Up Wt- 135,000 Ibs and Final Down Wt- 140,000 lbs. 21:30 - 22:00 0.50 BUNCO RUNCMP R/U to reverse circulate and displace the well to new 8.4 ppg 1 %KCI Brine. PJSM with CH2MHill and Rig Team. Discuss displacement procedures and concerns. Assign jobs to rig personnel. Make sure that it is understood that the job could be stopped at any time without any adverse problems. 22:00 - 00:00 2.00 BUNCO RUNCMP Displace with new 120 deg F, 8.4 ppg 1%KCI brine at 3 bpm with 130 psi. Pump 130 bbls of non inhibited brine followed by 450 bbls of brine treated with EC-1124A corrosion inhibitor. 4/11/2008 00:00 - 01:30 1.50 BUNCO RUNCMP Continue to displace with new 120 deg F, 8.4 ppg 1%KCI brine at 3 bpm with 130 psi. Pump 130 bbls of non inhibited brine followed by 450 bbls of brine treated with EC-1124A corrosion inhibitor. 01:30 - 02:00 0.50 BUNCO RUNCMP Drop ball and rod. Allow to reach RHC seat. 02:00 - 03:00 1.00 BUNCO RUNCMP R/U and pressure up tubing to 3500 psi and set PKR. Hold tubing test or 30 c arte minutes. oo test. 03:00 - 03:30 0.50 BUNCO RUNCMP Bleed pressure o tubing and hold 1700 psi. Test PKR by pressuring up on IA to 3500 psi and hold for 30 minute charted test. Good test. 03:30 - 04:00 0.50 BUNCO RUNCMP Bleed pressure off tubing to shear DCR valve with 2500 psi differential pressure. Pump through sheared DCR valve to confirm communication. Pump long at 3 bpm with 230 psi. Reverse circulate at 3 bpm with 210 psi. 04:00 - 04:30 0.50 BOPSU RUNCMP R/U and set TWC. Test TWC to 1000 psi from above and below for 10 charted minutes. Good tests. 04:30 - 07:00 2.50 BOPSU RUNCMP PJSM. N/D BOPE 07:00 - 08:30 1.50 WHSUR RUNCMP N/U Adaptor Flange and Tree. Test Adaptor Flange neck seal to 5,000-psi. 08:30 - 10:30 2.00 WHSUR RUNCMP R/U to test tree, fill tree with diesel and stroke valves. Test tree to 5,000-psi for good, solid test. 10:30 - 15:00 4.50 BUNCO RUNCMP Test surface lines to 3,500-psi. P/U DSM lubricator, test to 500-psi, and pull TWC. DSM gage showed 1500-psi under TWC, but the IA showed 0-psi. Replaced the DSM gage with a rig gage and pressure was 0-psi. Open both bleeds and well is dead. R/U Lil Red and test their lines to 3,500-psi. Pump 150-Bbls of diesel freeze protect fluid, 3-BPM at 500-psi. Allow to U-tube for 1-hour. 15:00 - 15:30 0.50 BUNCO RUNCMP R/D Lil Red. Lower bridle lines out of Derrick. 15:30 - 17:00 1.50 BUNCO RUNCMP Install BPV. Test BPV to 1000 psi from below for 30 charted minutes. Good Test. Bleed of pressure and R/D. 17:00 - 18:00 1.00 BUNCO RUNCMP Secure well and cellar. Release rig at 18:00 hours. rnrneu: vi<u<~~o ~.ic.vi nvi l::>-jLA ~t" IV ffLVlliY+V) LlaSSlllt:u as rrUUlt:1ll VVt:ll ~--- Subject: 15-32A (PTD #201;;40) Classified as Problem Well \<qq 6 ( ¡d()<., From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sat, 03 lun 2006 21 :23 :25 -0800 T.o: "GPB, FS3 DS Ops Lead" <GPBFS3DSOpsLead@BP.com>, "Rossberg, RSteven" <Steven.Rossberg@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, uGPB, wens Opt Eng" <ÇJPBW ellsOptEng@BP .com>, jim _regg@admin.state.ak.us, wîri.ton _ aubert@admin.state.akus, "NSU, ADW WL & Completion Bupervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "¡{urz, John" <john.kurz@BP.com>, "GPB, Optinúzation Engr" <GPBOptimizationEngr@BP:com>, "Çahalane, Ted W" <Ted.Cahalane@BP.com>, uGPB, FS3 Area Mgr"· <GPBFS3TL@BP .com> ~C:"NSU,ADW Welllntegcity Engineer" <NSUADWWellInte~tyEngineer@BP.com>, !.'MCCOLLUM, CODY o (VECO)" <Cody.MtCollum@BP.comr-, "Aus~ Paul A"·· k:Palll.A.Austin@BP.com>, "Derrick, George (Mackie) M" <derrgm@BP~com>, "Wi1so~ RonaldD (VECO)".c <Ronald. Wilson@BP.com> .1-- ð; l All, Well 15-32A (PTD #2011840) has sustained casing pressure on the IA and has been classified as a Problem Well. Wellhead pressures on 6/1/06 were 2430/2300/450 psi. A TIFL failed on 6/1/06. We are currently evaluating secure options - there is a patch in the well. Attached is a wellbore schematic. Please call if you have any questions. 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.eom 5CN~NED JUN 272006 «15-32A.pdf» . .... . .m.....____ ___ Content-Description: 15-32A.pdf 15-32A.pdf Content-Type: application/octet-stream· Content-Encoding: base64 . .. .. .. .....-.-.-....------ JA scf L 300ps:. ;\..CVl{ P <...\. 1/1 uiP 2'1J' ~" {fò7Cfs; 33 ¡ ::-i-c ölL ~ CJJ tr:f-z- 1 of 1 6/9/2006 10: 13 AM TREE = 4-1f16" MCEVOY WB-LHEAO = FMC ~"_~.~_~~'.Y_"'_"~'_"_""'____''''''-"",."""~",·",,,,,,,,,,,,~,,,,,-·,,,,,,_.,,,,,,,,,,,,,_··_~....W"A"~..._"""'.. ACTUA TOR = BAKER C -'<8. EL8T=-----~68~5' ·-BF~ãêr~··--·---····-----·--·---··-ÑÃ· KOP~··----_·~-·--·--814i --..-_""''''''''''''_..._'''...."._......--~'''...,.....,.".....''''__..._v_~~....'W'#'_,____ Ma~~ngle =__~~@.~.~85~ Datum MO = 9105' O~Tüm n.Tõ~----..-8¿3ÖÕ:sS .- 15-32A SAÆ'-....-i0TES: *** 7" CHROME LNR (PARTIAL)*** TR55SV @ 2215' RE-LOCKED OUT ON 03/07/05. WELL DEV > 70° @ 9015' I) ~ 2215' 1-1 4-111" CA- TRDP-4A TRSSSV, 10 = 3.812" ~ ~ GAS LIFT fv1Þ.NDRELS 3530' Z ST 1\t1D NO DEV TYÆ VLV LA TCH PORT: DATE' L 2991 2990 1 TE- TPD DV T-2 0 06/04/94 2984' 2 4988 4987 1 TE- TPD DV T-2 0 04/27/94 Z Z 3 6755 6753 TE- TPD DV T-2 0 04/27/94: 4 8049 8046 5 TE- TPD DV T-2 0 . 04/27/94 ! 13-3/8" CSG. 68#, L-80, ID = 12.415" 1-1 HES PA TCH, RCP PKRS, BTM @ 3006' -i MIN ID:: 2.35",4" GS FN, STRADDLES GLM #1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 3966' \ ~ ~ 9-5/8" CSG, 47#, L-80, ID:: 8.681" 1-1 8327' I~l - I 7" LNR, 26#, XO FROM L-80 TO 13-CR, ID = 6.276" 1-1 8665' J-x f z Minimum ID = 1.920" @ 8768' TOP OF 2-3/8" LIN ER I TOP OF 2-3/8" 4.7# LNR, ID = 1.920" l-i 3-1/2" TBG, 9.3#, L-80 NSCT, .0087 bpf, ID:: 2.992" 1-1 I TOP OF 4-1/2" LNR l-i 14-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" -I TOPOF 4-1/2" LNR- SLOTIED l-i /7" LNR, 26#, 13CRlL-80 NSCC, .0383 bpf, ID= 6.276" 1-1 I BTM OF 4-1/2" SLOTIED LNR l-i I I R ~I tl Z--/ ~ ~ ; I ~ ~: I .... .... I I I 8768' 8767' 9417' 9630' 9630' 9649' 10342' 3966' 1-1 4-1/2" x 3-1/2" XO, ID = 2.992" 1 8164' H TOP OF TIVV TIEBACK SLV I 8173' l-i 9-5/8" x 7" TrN LNR TOP PKRlHGR, ID :: 6.276" 8649' H 3-1/2" OTIS X NIP, ID:: 2.813" , 8700' 1-1 3-1/2" x 4-1/2" XO 1 8703' 1-1 7" x 4-111" BAKER SABL-3 PKR, ID = 3.875" 8708' 1-1 4-1/2" X 3-1/2" XO, ID = 2.992" 1 8740' 1-1 3-1/2" 011S X NIP, 10 = 2.813" 1 8757' 1-1 3-1/2" PARKERSWN NIP, ID = 2.75" 8765' 1-1 2.70" BKR DEPLOYMENT SLV, ID = 2.250" 8768' l-i 3-1/2" WLEG 8792' l-i TOP OF cl\trr 9417' 9464' 1-i7" X 4-1/2" TrN SS HORIZONTAL PKR, ID= 3.96" 1-14-1/2" PORTED JT (41.55') BHND CT LNR 1 14-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, 10 = 3.958" 1-1 10365' ~ORATlONSUMMARY REF LOG: BHI MWD/GR ON 11/04/01 ANGLE AT TOP ÆRF: 86 @ 11000' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 1-11/16" 4 11000 -11100 0 11/08/01 1-11/16" 4 11150-11230 0 11/08/01 1-11/16" 4 11290-11440 0 11/08/01 DA TE REV BY COMMENTS 04/28/94 ORIGINAL COM PLEfION 11/08/01 CTD SIDEfRACK 11/28/01 CH/TP CORRECTIONS 12115/01 DDWfKAK PATCH 02120/03 /TLH WAIVER SAFETY NOTE 06/05/03 CMOfTLP MAX ANGLE I 2-3/8" LNR, 4.7#, L-80, STL, .0039 bpf,!D= 1.92" Ii 11535' I DA TE REV BY COMtv1ENTS 09/12/03 CMOlTLP DATUM MD & ÆRF ANGLE 09/22/03 TJP/TLP WAIVEH. CANCB..ED 03/09/05 MGSITLH TRSSSV LOCKED OUT PRUDHOE BAY UNIT WB..L: 15-32A PERrviff No: 2011840 API No: 50-029-22462-01 SEC 22, T11 N, R14E, 1976' SNL & 333' EWL BP Exploration (Alaska) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marker.doc - '" " . 10 ,~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2011840 Well Name/No. PRUDHOE BAY UNIT 15-32A Operator BP EXPLORATION (ALASKA) INC Sf! ~¿ .:( /lfrl'v).. Ó fJ J API No. 50-029-22462-01-00 MD 11535 ..JI TVD 8919 ,/' Completion Date 11/9/2001 ,,/' Completion Status 1-01L Current Status 1-01L UIC N -- ----. -~- REQUIRED INFORMATION Mud Log No Samples No Directional surve~. -- .Wtr-'V J...£J-. .-. -- -- -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~ Logl Data Type -:-ED i ØD I Electr Digital Dataset MedlFrmt Number D C:.-:1 0548 Name Log Log Run Scale Media No 1 1 Interval OH / Start Stop CH Received 10260 11537 Open 2/5/2002 Comments ...-+D568 - -, , i ---- -- , j C 8410 11486 Case 12n/2001 Well CoreslSamples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORM~ON Well Cored? Y ~ Chips Received~~ Analysis ~ Received? Daily History Received? ~N '\ G1/N Formation Tops -- -------- - ----- --~ --------- Comments: N ~ 1- (r-. I\ V)!) f/V\ \ fV7~:v....e~ 1-V¡I.llwJì f\ltu..'l-rr-- .MCNl. }G;rz/CCL-. 7fUúv Àà~ I Ú7 'f?..jMW D M ~ ~ ìvÒ (~).)'-,¡ - Jt ~~ ')- ~ yt-l'^- c~ Compliance Reviewed By: ~ Date: ~ ~ I'U' tL ~) - ----: - -- -- t STATE OF ALASKA ( ALASKA UIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-184 3. Address 8. API Number . . P.O. Box 196612, Anchorage, Alaska 99519-6612 , r. ~ - - - ...", l' 50-029-22462-01 4. Location of well at surface "--"'-""'æ 9. Unit or Lease Name 1676' SNL, 333' EWL, SEC. 22, T11N, R14E, UM ; '::":':';~:~:~-:~:¡'; it, -', Prudhoe Bay Unit At top of productive interval . ~;1DI;"'~ 1940' SNL, 648' EWL, SEC. 22, T11 N, R14E, UM ./.' ( .:~"'\"~- . . ------------ I -'~-4- '-" ~ 10. Well Number At total depth . -.,' ,- ..- 1 " ..".. ~..,' \ "'-""",." ,: ' ~-^W'\~","I'.', 15-32A .- ." -- c I 3739' SNL, 2120' EWL, SEC. 22, T11N, R14E, UM ',..n - _dDn.- --- 1, 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool RKB = 68.05' ADL 028306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 11/2/2001 11/5/2001 11/9/2001 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11535 8919 FT 11498' 8915 FT 181 Yes DNo (Nipple) 2215' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, CNL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PUllED 20" 91.5# H-40 34' 114' 30" 260 sx Arctic Set (Approx.) 13-3/8" 68# L-80 35' 3530' 16" 1170 sx PF 'E', 375 sx Class 'G' 9-5/8" 47# L-80 32' 8327' 12-1/4" 610 sx Class IG1 7" 26# L-80 / 13Cr 8165' 9649' 8-1/2" 280 sx Class 'G' 4-1/2" 12.6# L-80 9417' 103651 6" Uncemented Slotted Liner Cemented Over) 2-3/8" 4.43# L-80 8765' 11535' 3" 221 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 x 8768' 8703' MD TVD MD TVD 3-1/2",9.2#, L-80 11 000' - 11100' 8876' - 8883' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11150' - 11230' 8890' - 8899' 11290' - 11440' 8906' - 8911' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 25 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 29, 2001 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-Bel GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-Bel GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED No core samples were taken. FEB 0 ~, 2002 Alaska Oil & Gas Cons. Comnrissìon Anchorage Form 10-407 Rev. 07-01-80 - ---""\",,,'~\"n)jl':"l '"", '. ':. " ( '\.1 \i, ",.-i, \1 ' ~ il ,I 'il J, I " I ,'I, ~, :!t--.)¡I,¡I,m",\,r:\:\!!,,~~, 1",.../ ¡ \; ~",,) Ii ¡I, 'Ò ' " . ,.~. RBDMS BFl Submit In Duplicate ÆB I I 2002 l, \/ -~ "'-"' 30. Formation Tests Marker Name Geologic Markers Measured Depth True Vertical Depth Include interval tested, pressure data, aU fluids recovered and gravity, GOR, and time of each phase. 129. 8962' 8824' Zone 1 B RECEIVED FEB 0 6 2002 Alaska Oil & Gas Coos. Commission Anchorage 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 Hubb!e ~). t\;J} 'k-\, , ~ Title Technical Assistant I "'" ~ -- -- 15-32A 201-184 Well Number Permit No. I Approval No. Date D 'Â.-Q5 ..O~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERA!-: 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. waler injection, steam injection, air injection, salt waler 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. I.EM 16 AND 24: If this well is completed lor separate production !Tom more than one interval (multiple completion). so stale in item 16. and in item 24 shoW the producing intelVals for only the intelVai reported in item 27 - submtt a separate form for each additional intelVal 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.). \1.11 23: Attached supplemental records lor this well should shOW the details of any multiple stage cementing and the location of the cementing too\. I1EM 27: Method of Operation: Flowing, Gas LiII, Rod pump, Hydraulic pump, submersible, Water Injection, Gas Injection, Shut-In, Other-explain. 'TEM 28: If no cores taken, indicate 'none'. r')ntr..1r.~ {:; i j, ~ t \""'" i~ ¡u\' nt\ í \ l\fU. V ¡ . f ., ~ \i- Form 10-407 Rev. 07-01.80 BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: 15-32 Common Well Name: 15-32A Spud Date: 9/17/2001 Event Name: REENTER+COMPLETE Start: 9/17/2001 End: 11/9/2001 Contractor Name: NORDIC CALISTA Rig Release: 11/9/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/16/2001 11:30 -14:30 3.00 CONS N WAIT POST Begin Rig Standby for next well (WOO) 14:30 - 15:00 0.50 CONS N WAIT POST Move rig off well and set down on C Pad extension 15:00 - 18:00 3.00 CONS N WAIT POST Install corrosion pump line in mud pits 18:00 - 18:30 0.50 CONS N WAIT POST Crew change/safety mtg 18:30 - 00:00 5.50 CONS N WAIT POST CARRIED OUT GENERAL HOUSEKEEPING & MAINTENANCE WHILE WOO FOR NEXT LOCATIONIWELL. 9/17/2001 00:00 - 08:00 8.00 MOB N DPRB PRE WOO (L2-18 diagnostics and 15-32 prep) on C Pad extension. Perform general maintenance and cleaning 08:00 - 08:30 0.50 MOB P PRE Safety mtg re: derrick down move to 15-32 08:30 - 12:00 3.50 MOB P PRE Start rig move rate. Pull CT from injector, remove gooseneck, set injector in box 12:00 - 12:30 0.50 MOB P PRE Safety mtg/crew change 12:30 - 00:00 11.50 MOB N WAIT PRE Standby WOW. Wind gusts to 21 mph (next step is to lay down wind walls). Meanwhile perform general housekeeping & mantenance. Replaced gasket on boiler #2 valve. Installed safety cables on outside lights & painted post for wind tarps. 9/18/2001 00:00 - 06:30 6.50 MOB N WAIT PRE STANDBY WOW TO LAY DOWN WIND WALLS. WIND SPEED: STEADY/GUST = +/-15/>20 MPH. FOGGY WEATHER WITH VERY POOR VISIBILITY. MEANWHILE SERVICED CENTRIFUGE. 06:30 - 06:45 0.25 MOB P PRE Resume RD, wind laying down. Crew change/safety mtg 06:45 - 10:00 3.25 MOB P PRE Lay down windwalls, scope down derrick, lay down derrick 10:00 -19:00 9.00 MOB P PRE Move from C Pad to DS 15 19:00 - 00:00 5.00 MOB N WAIT PRE STANDBY, WOW, WIND TO HIGH TO RAISE WIND WALLS. END WOW AT 00:00 HRS., 09-19-01. Raise mast and windwalls. 9/19/2001 00:00 - 07:00 7.00 MOB P PRE RAISE MAST AND WINDWALLS. PREP TO MOVE RIG OVER WELL. 07:00 - 09:00 2.00 MOB P PRE MOVE RIG AND SPOT OVER WELL 15-32A. 09:00 - 12:00 3.00 BOPSUF P DECOMP ACCEPT RIG AT 09:00 HRS, 09/19/2001. N/U BOP STACK. SECURE FLOWLINE AND BLEED TO ZERO PSI. 12:00 - 14:00 2.00 BOPSUF N SFAL DECOMP PRESSURE TEST BOPE. SWAB AND MASTER LEAKING. CALL FOR GREASE CREW. CO NT. GENERAL RIG UP. RIU BERMS, SPOT TANKS AND EQUIP. R/U HARDLINE TO FLOWBACK TANK AND PRESS TEST. 14:00 - 18:00 4.00 BOPSUF P DECOMP PRESS TEST BOPE. AOGCC TEST WITNESS WAIVED BY CHUCK SCHEVE. SEND TEST REPORT TO AOGCC. 18:00 -19:00 1.00 KILL P DECOMP WAIT ON FLUIDS. RU HB&R. 19:00 - 21:30 2.50 KILL P DECOMP INSTALL AND ACTIVATE SSSV CONTROL PANEL. (TO KEEP TBG RET VALVE OPEN DURING IA DISPLACEMENT) 21 :30 - 22:00 0.50 KILL P DECOMP HOLD PRE JOB MTG WITH ALL HANDS REGARDING LOADING IA. 22:00 - 23:45 1.75 KILL P DECOMP BEGIN DISPLACING IA WITH SEAWATER. 1200 PSI IA PRESSURE. PUMP AT 5.7 BPM/1600 PSI. PUMP 300 BBLS SEA WATER. CHASE WITH 110 BBLS 60/40 MEOH FOR FP. 23:45 - 00:00 0.25 KILL P DECOMP RD HB&R. 9/20/2001 00:00 - 01 :00 1.00 KILL P DECOMP PUMP FLO PRO DN TBG AT 5 BPM. ISITP:1350 PSI. BULLHEAD AT 5 BPM & 1600 PSI PUMP PRESSURE. 240 BBLS AWAY. (' ( Printed: 11/13/2001 4:31 :05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/20/2001 9/21/2001 f ( BP EXPLORATION Operations Summary Report 15-32 15-32A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date 01 :00 - 02:00 From - To Hours Activity Code NPT DECaMP 02:00 - 05:15 05:15 - 06:00 06:00 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00 -11:00 11 :00 - 11 :45 11:45-12:10 12:10 - 14:00 14:00 - 14:30 14:30 - 21 :30 21 :30 - 22:00 22:00 - 22:15 22:15 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 01 :00 01:00 - 01:45 1.00 KILL 3.25 KILL 0.75 KILL 2.50 KILL 1.00 KILL 0.50 FISH 1.00 FISH 0.75 FISH 0.42 FISH 1.83 FISH 0.50 FISH 7.00 FISH 0.50 FISH 0.25 FISH 0.25 FISH 1.00 FISH 0.50 FISH 1.00 FISH 0.75 FISH P N P P P P P P P P P N N N N N N P P Phase WAIT DECaMP DECaMP DECaMP DECaMP DECaMP DECaMP DECaMP DECaMP DECOMP DECaMP DFAL DECaMP DECaMP DECaMP DECaMP DECaMP DECaMP DECOMP DECaMP Page 2 of 9 Start: 9/17/2001 Rig Release: 11/9/2001 Rig Number: Spud Date: 9/17/2001 End: 11/9/2001 Description of Operations SHUT IN PUMP. MONITOR WELL. IA: 850 PSI. SITP:450 PSI. ATTEMPT TO BLEED IA: LOTS OF GAS. WAIT ON ADDITIONAL KILL FLUIDS AND HARDLINE CREW, TO RU FLOW BACK LINE FROM IA TO TIGER TANK. BLEED IA USING 1/2" HOSE IN MEAN TIME. BLEED IA & TBG TO 200 PSI. RU HARD LINE TO TIGER TANK LINE. BLEED IA. BLEED TBG. BOTH PRESSURED BACK UP TO +/-100 PSI IN 10 MINUTES. BLEED AGAIN. SLPOWLY PRESSURED BACK UP TO 200 PSI IN 10 MINUTES. BULLHEAD 2% KCL DOWN TBG. 5 BPM, 2250 PSI. 350 BBLS. BULLHEAD 2# BIOZAN DOWN TBG. 5 BPM, 2200 PSI. 150 BBLS. SIWHP = 170 PSI. lAP = 300 PSI. BLEED GAS OFF INNER ANN. WHILE PUMPING 4 BPM DOWN TBG. PUMP 60 BBLS. SIWHP = 0 PSI, lAP = 260 PSI. M/U BKR CT CONNECTOR, PULL TEST 50K, FILL COIL WITH BIOZAN, PRESS TEST 3500 PSI. M/U BKR FISHING TOOLS: 4" GS SPEAR, HYD DISC, DAILEY FISH JARS, 4 WT BARS, BOWEN ACCEL, CHECK VLVS, CTC. BHA = 38.45 FT. RIH TO 2150 FT. UP WT = 4K, DWN WT = 1.6K. RIH TO TOP OF FISH AT 2245 FT. LATCH ONTO BAITED FISH, FISH = 41/2" AVA TBG PATCH, = 25 FT LONG. PULL 8K, 10K, 12K, 14K, 20K, 25K, 30K, 35K, 40K, PULLED FREE AT 42K. [38K OVERPULL]. NO JARRING ACTION, JUST STRAIGHT PULLS. CIRC AT 0.5 BPM AND PULL AT 20 FPM. UP WT = 5K. 1 K EXTRA WT. POOH AT 30 FPM, PUMP 0.5 BPM. WHP SLOWLY INCREASING. SI WELL AND PARK BHA AT 50 FT. BULLHEAD DOWN TBG AT 3.0 BPM AT 1700 PSI. SIWHP = 0 PSI. RECOVERED BKR FISHING BHA AND 4.5" PRT. LOWER 2.5" OF 8 COLLETS SHEARED OFF AT GS FISHING PROFILE [SAME THING OCCURED DURING SLlCKLINE FISHING OPERATION]. TOTAL OF 20 OF 2" LONG X 1/2" WIDE BY 1/8" THICK FINGERS LEFT IN WELL NOW. PROBABLY LAYING IN HORIZONTAL 7" LINER. WAIT ON BKR MACHINE SHOP FOR NEW 4 1/2" PRT. BLEED IA TO 100 PSI. MONITOR WELL. NO FLOW. HOLD PRE JOB MTG BEFORE PU BHA. MU NEW PRT TOOL WITH JARS, ACCEL, & WT BARS. RIH. 0.6# DN, 3.7K# UP WT. TAG FISH 2973'. LATCH FISH. JAR UP 10K# OVER. THEN STRAIGHT PULL 25K# REPEAT SEVERAL TIMES. POPPED FREE. EITHER PULLED OFF OR CAME FREE. POOH TO SSSV TO "CHECK" FOR FISH. NO OVERPULL AT SSSV, BUT UNABLE TO GO DOWN EITHER. CONTINUE TO POOH. FILL HOLE ACROSS TOP AT SURFACE. MONITOR WELL BEFORE REMOVING Printed: 11/13/2001 4:31 :05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/21/2001 10/31/2001 11/1/2001 {' ( ( BP EXPLORATION Operations Summary Report 15-32 15-32A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 01:00 - 01:45 From - To Hours Activity Code NPT DECOMP 01 :45 - 02:30 02:30 - 03:30 03:30 - 04:30 04:30 - 05:00 05:00 - 08:00 08:00 - 09:20 09:20 - 10:30 10:30 - 11 :30 11 :30 - 12:00 00:00 - 06:00 06:00 - 13:00 13:00 - 15:00 15:00 - 18:30 18:30 - 00:00 00:00 - 02:15 02:15 - 06:00 06:00 - 07:00 07:00 - 09:30 09:30 - 10:30 10:30 - 11 :00 11:00 -12:45 12:45 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 15:45 0.75 FISH P 0.75 FISH 1.00 FISH P P 1.00 FISH 0.50 FISH 3.00 FISH P P P 1.33 RIGD P 1.17 RIGD 1.00 RIGD 0.50 RIGD P P P 6.00 MOB 7.00 RIGU 2.00 RIGU 3.50 RIGU N 5.50 BOPSUF P 2.25 BOPSUF P 3.75 RIGU P 1.00 RIGU 2.50 RIGU P P 1.00 RIGU 0.50 RIGU P P 1.75 KILL P 0.75 KILL P 0.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN N 0.75 CLEAN N Phase DECOMP DECOMP DECOMP DECOMP DECOMP COMP COMP COMP COMP PRE PRE PRE RREP PRE DECOMP DECOMP PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP RREP DECOMP RREP DECOMP Page 3 of 9 Start: 9/17/2001 Rig Release: 11/9/2001 Rig Number: Spud Date: 9/17/2001 End: 11/9/2001 Description of Operations INJECTOR. NO RECOVERY. SCARRING ON DOGS ON PRT. LOOKS LIKE TOOL SLIPPED OFF. SHEAR SCREWS STILL INTACT. RIH FOR SECOND TRY. 6K# UP, 3K# DN WT AT 2900'. TAG FISH AT 2977'. STRAIGHT PULL TO 28K#. PRT SLIPPED. REPEAT SEVERAL TIMES. UNABLE TO KEEP A BITE ON FISH. POOH. STAND BACK BHA. WAIT ON ORDERS FROM TOWN. DECIDE TO STOP RIG FISHING OPERATIONS AND MOVE TO DS 15-41B. FREEZE PROTECT 41/2" LINER TO 1800 FT WITH 28 BBLS MEOH. EMPTY AND CLEAN RIG PITS. N/D BOPE. N/U TREE CAP AND PRESS TEST WITH 4000 PSI. RELEASED NORDIC 1 ON 15-32AAT 12:00 HRS, 09-21-01 41/2" TBG FREEZE PROTECTED TO 1800 FT WITH MEOH. MOVE RIG TO 15-41 B FOR CTD SIDETRACK. MOVE NORDIC 1 FROM DS 5 TO DS 15-32A. SPOT NEAR WELL. RAISE MAST & WIND WALLS. SPOT RIG OVER WELL. NU BOPS. BEGIN REEL CHANGEOUT. PROBLEM WITH HYDRAULICS ON REEL STAND. CONTINUE RU INJECTOR & GOOSENECK. Remove and load out used reel Accept rig at operating rate at 1830 hrs 10/31/01. Begin BOPE test. Witness waived by AOGCC. Fill pits wI KGI. Spot flowback tank, slop tank DS welder and mechanics work on fixing reel drive motor pins. Set replacement spool in reel house at 2300 hrs Fin test BOPE. Hook up hardline to reel Prep reel. Pull CT to injector and stab. Spot Sperry and MI shacks Install slip connector. PRESSURE & PULL TEST SAME. DISPLACE COIL TO WATER. PUMP DART. COIL VOLUME 40.7 BBLS. INSTALL WELD ON CONNECTOR. TEST SAME. COMPLETE RU OF FLOW BACK HARDLINE. TEST SAME TO 4000 PSI. ISITP: 60 PSI. ISICP: 150 PSI. BULL HEAD WELL AT 5 BPM USING BOTH RIG PUMPS.1800 PSI WHP WHILE PUMPING 2%KCI. MONITOR WELL FOR FLOW. BLEED GAS OFF IA. WELL APPEARS TO BE DEAD. MU 2.8" PARABOLIC DSM ON INTEO 2.375" MTR. RIH WITH MILLING ASSY. LUBRICATOR LEAKING. STOP AND REPLACE O-RING SEAL AT FLOOR. STILL LEAKING. POOH TO REPAIR SAME. (FROM 3000') Printed: 11/13/2001 4:31 :05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/1/2001 11/2/2001 11/3/2001 ( ( BP EXPLORATION Operations Summary Report 15-32 1 5-32A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 15:45 - 16:15 16:45 - 17:00 17:00 - 17:45 17:45 - 18:15 18:15 - 18:40 18:40 - 19:00 19:00 - 20:20 20:20 - 20:55 20:55 - 21 :30 21 :30 - 22:45 22:45 - 23:00 23:00 - 00:00 00:00 - 00:35 00:35- 00:45 00:45 - 01 :30 01 :30 - 03:30 03:30 - 03:45 03:45 - 04:10 04:10 - 05:00 05:00 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 16:00 16:00 - 00:00 00:00 - 00:50 00:50 - 01 :00 01 :00 - 01 :55 01 :55 - 03:50 03:50 - 04:40 Phase 0.50 CLEAN N 0.25 CLEAN N 0.75 CLEAN P 0.50 CLEAN P RREP DECOMP RREP DECOMP DECOMP DECOMP 0.42 CLEAN P DECOMP 0.33 CLEAN P DECOMP 1.33 CLEAN P DECOMP 0.58 CLEAN P 0.58 CLEAN P DECOMP DECOMP 1.25 CLEAN P DECOMP 0.25 CLEAN P 1.00 DRILL P 0.58 DRILL P 0.17 DRILL P 0.75 DRILL N DECOMP PROD1 PROD1 PROD1 DFAL PROD1 2.00 DRILL 0.25 DRILL P P PROD1 PROD1 0.42 DRILL P PROD1 0.83 DRILL N DFAL PROD1 2.00 DRILL 2.00 DRILL 0.50 DRILL 1.50 DRILL N N N N DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 0.50 DRILL 0.50 DRILL 4.00 DRILL 8.00 DRILL N N N N DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 0.83 DRILL 0.17 DRILL 0.92 DRILL 1.92 DRILL 0.83 DRILL N N N N P DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 Page 4 of 9 Start: 9/17/2001 Rig Release: 11/9/2001 Rig Number: Spud Date: 9/17/2001 End: 11/9/2001 Description of Operations OFF WELL. CHANGE OUT LUBRICATOR O-RING. RIH WITH MILL ASSY. (AT 3000 FT) CONTINUE TO RIH. TAG SWN NIPPLE AT 8794'. CORRECT TO PROGRAM DEPTH OF 8757'. BEGIN MILLING SAME. 1.6 BPM@1750 PSI. 21 K# UP, 15K# DN. THROUGH SAME. MAKE UP PASS. VERY SMOOTH. CONTINUE TO RIH. Looking for packoff bushing at 10342' and guide shoe at 10363' DPM Tag hard btm at 10311.8' CTD several times 22.6k, 1.7/1800 full returns. Begin milling from here. Mill thru it (1' thick) to 10322' in 10 min. Backream clean. RIH 14.5k Tag at 10335.1'. Work to get thru it (1' thick) in 15 min, then ease in hole slow looking for float equipment drilling/milling 0.8'/min wI 200 psi diff and no wt to 10370'. Must have been float equipment back there. . . muse, muse Wiper to 10300' while circ 15 bbl bio sweep to mill Wiper to EOT chasing sweep at max rate. Some fine sand in returns POOH for drlg assy. Get jewelry log and find that SWN nipple should be at 8792' ELMD (not 8757', which is DPM). Therefore, TD is probably 10400-407' LD milling BHA MU drilling BHA (new Sperry MWD) Fin MU drilling BHA RIH w/ drilling BHA #2 to 500' SHT MWD and troubleshoot pulses-have weak pulses, but good detection Continue RIH Begin tie-in at 10040'. Not getting pulses. Begin displacement to Flo Pro mud RIH reaming and tag TD at 10403' CTD. Circ mud to bit while checking pulses 1.1/1.0 @ 1920 psi. Spud and drill to 10407' CTD trying to get a signal PUH and backream 20'/min displacing to mud while Sperry troubleshoots. Clean thru float equipment 1.6/1.5 2800 POOH to changeout MWD pulser Change out mwd sonde & pulser. RIH with second set of Sperry slim tools Shallow test mwd tools with various flow rates etc. Unable to establish any pulses at all. Notify Baker Inteq they will need to mobilze. POOH LD mwd tools. RD Sperry MWD equipment. Wait on Baker hands and equipment. Unit arrive @ 1800 hrs, first personnel 1945 hrs. Begin RU @ 2130 hrs Fin RU BHI MWD. Check well for press and on a vac Safety mtg re: BHA MU drilling BHA RIH w/ drilling BHA #3. Set down at GLM #2 at 5020' CTD Begin tie-in at 10030' PVT 272. Log to 10070' 1.5/1.4 2550 140L Printed: 11/13/2001 4:31 :05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/3/2001 11/4/2001 ( ( BP EXPLORATION Operations Summary Report 15-32 1 5-32A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Activity Code NPT Phase 04:40 - 04:55 04:55 - 05:30 05:30 - 06:05 06:05 - 08:00 08:00 - 10:00 10:00 - 11 :00 11 :00 - 11 :30 11 :30 - 12:45 12:45 - 13:15 13:15 - 15:00 15:00 - 16:30 16:30 - 16:45 16:45 -17:15 17:15 - 17:30 17:30 - 18:30 18:30 -19:15 19:15 - 20:05 20:05 - 20:35 20:35 - 21 :50 21 :50 - 22:45 22:45 - 23:15 23:15 - 23:35 23:35 - 00:00 00:00 - 02:45 02:45 - 04:00 04:00 - 04:15 04:15 - 05:50 05:50 - 07:15 07:15 - 07:45 07:45 - 08:00 08:00 - 09:30 09:30 - 09:45 09:45 - 10:00 10:00 -10:15 10:15 - 12:30 12:30 - 12:45 12:45 - 14:00 14:00 - 14:25 14:25 - 15:20 15:20 - 15:30 15:30 - 16:00 16:00 - 18:00 18:00 - 19:15 0.25 DRILL 0.58 DRILL 0.58 DRILL 1.92 DRILL 2.00 DRILL 1.00 DRILL 0.50 DRILL 1.25 DRILL 0.50 DRILL 1.75 DRILL 1.50 DRILL 0.25 DRILL 0.50 DRILL 0.25 DRILL 1.00 DRILL 0.75 DRILL 0.83 DRILL 0.50 DRILL 1.25 DRILL 0.92 DRILL 0.50 DRILL 0.33 DRILL 0.42 DRILL 2.75 DRILL 1.25 DRILL 0.25 DRILL 1.58 DRILL 1.42 DRILL 0.50 DRILL 0.25 DRILL 1.50 DRILL 0.25 DRILL 0.25 DRILL 0.25 DRILL 2.25 DRILL 0.25 DRILL 1.25 DRILL 0.42 DRILL 0.92 DRILL 0.17 DRILL 0.50 DRILL 2.00 DRILL 1.25 DRILL P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 5 of 9 Start: 9/17/2001 Rig Release: 11/9/2001 Rig Number: Spud Date: 9/17/2001 End: 11/9/2001 Description of Operations No corr, RIH and tag TD at 10402.4'. PUH Log down from 10365'-TD 1.5/1.4 2500 140L Orient around. Add 5 gal Safe-scav oxygen scavenger to mud system as initial treatment Plan to add 3 gals per day for rest of well. Drilling 30'/hr from 10402' 1.6/1.5 2600 115R PVT 271 Drilling at 10480'. 1.6/3000/120R PVT:267 Drilling ahead. 1.6/2900 90R PVT:263 bbls. Inc dropping. Slow ROP in shale. Orient around to 45R Drill to 10560'. Formation improving after drilling a lot of shale. PVT:260 bbls. Short trip to 10,000'. Hole & liner smooth. Log GR section from 10270' to 10400'. Drill ahead. 1.7/3100/90R PVT:255 bbls ROP:50-70 fph Orient to 90L Drill ahead Orient to 90R Drill ahead to 10716' 1.7/3100/90R Wiper to 10000', clean Drilling 1.7/3100/121R. Geo's want to hold 88 deg PVT 251 100' wiper from 10771'. Orient around Drilling 1.6/2860 to 10850' Not sliding real well. Wiper to EOT at 8800' RIH Begin tie-in at 10030' 1.6/2880/180L Add 7.0', RIH to TD at 10854' Drilling from 10854' 1.7/2970/90R. Make several50-10Q' wipers after stacking/sticking. Drill to 10950' PVT 236 Wiper to 9800' prior to TF change 1.6/3000 Tag TD, 22.5k, 9.5k Orient to left side Drilling (spud and PU) 1.7/3050/115L to 11000' Wiper to EOT PVT 228 Log GR tie in from 10020'. Begin cleaning pits for mud swap. Add 7' correction. RIH. Drill ahead. 1.6/31 00/90R. Wt x-fer very poor until new mud got to bit Drill to 11075' Orient to begin drop as per geologist Need to get into next sand below. TF:160L Drill to 11110'. INC:84 deg. Orient to begin hold. TF: 80L. Drill ahead to 11160'. See shale on gr. Orient around to 10R to level off. Drill ahead to 11178' @ 1.6/3100/1 OR. Take on rest of new mud. Wiper trip to 9500'. RBIH. Tag-up @ 10410' (shale). Work thru & cont RIH to btm. Orient TF to 100L Attempt to drill ahead @ 1.7/3500/105L. No progress. Decide to POOH to changeout Smith experimental bit POOH BHA#3. Bit was trashed. Pilot portion was cored back to jet Shoulder Printed: 11/13/2001 4:31 :05 PM BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: 15-32 Common Well Name: 15-32A Spud Date: 9/17/2001 Event Name: REENTER+COMPLETE Start: 9/17/2001 End: 11/9/2001 Contractor Name: NORDIC CALISTA Rig Release: 11/9/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/4/2001 18:00 -19:15 1.25 DRILL P PROD1 cutters on one blade had fallen out. Put on a used HC bit that has several runs in same formation and new motor 19:15 - 21 :00 1.75 DRILL P PROD1 RIH w/ BHA #4 (1.15 deg motor) 21 :00 - 22:05 1.08 DRILL P PROD1 Log tie-in at 10030' and had no corr. Precautionary ream to TD at 11180' CTD 22:05 - 22:25 0.33 DRILL P PROD1 Orient around. PVT 226 22:25 - 00:00 1.58 DRILL P PROD1 Drilling from 11180' 1.7/3000 95L holding 82 deg. Penetration rate slowed down at 11230' and GR later showed a 170+ API shale 11/5/2001 00:00 - 01 :30 1.50 DRILL P PROD1 Drilling in a 170API shale at 11240' 1.7/3000/90L 83.5 deg 8828' TVD 01:30 - 03:15 1.75 DRILL P PROD1 Got out of hot shale at 11292' and P rate picked up. Drill to 11308' 03:15 - 03:45 0.50 DRILL P PROD1 Orient to high side to level out. Then got sticky and hard to make hole due to TF change. Wipe and spud 03:45 - 04:05 0.33 DRILL P PROD1 Drill to 11338' 1.6/2940/1 OL 04:05 - 06:10 2.08 DRILL P PROD1 Wiper to EOT prior to TF change, clean. RIH and set down at 10422' (shale). RIH. Set down at 10502'. RIH 06:10 - 06:12 0.03 DRILL P PROD1 Tag TD at 11336' CTD. Orient around to 90R Geologist wants 86-87degs hold. 06:12 - 06:27 0.25 DRILL P PROD1 Drilled to 11342' with 80R TF, 1.7 /1.6bpm, 2800/3300psi & 16fph ROP. 06:27 - 06:34 0.12 DRILL P PROD1 Orient 1 click and Drill to 11361' with 95R TF, 1.7 /1.6bpm, 2800/3300psi & 163fph ROP. Drilling 50API sand. Good wt transfer. 06:34 - 07:15 0.68 DRILL P PROD1 Orient 1 click & drill to 11411' with 120R TF, 1.7 /1.6bpm, 2800/3300psi & 73fph ROP. Getting sticky. 07:15 - 08:00 0.75 DRILL P PROD1 Wiper trip to 10000'. 08:00 - 08:30 0.50 DRILL P PROD1 Log GR tie in from 10020'. Add 20' to CTD. 08:30 - 09:06 0.60 DRILL P PROD1 RBIH smoothly & tag btm @ 11424'. 09:06 - 09:15 0.15 DRILL P PROD1 Drilled to 11440' with 11 OR TF, 1.5/1.5bpm, 2700/3100psi & 107fph ROP. 09:15 - 09:40 0,42 DRILL P PROD1 Drilled to 11445' with 120R TF, 1.5/1.5bpm, 2700/3100psi & 12fph ROP. Seems to be scheming shale roof. 09:40 - 10:00 0.33 DRILL P PROD1 Orient around to 90R 10:00 - 10:12 0.20 DRILL P PROD1 Drilled to 11455' with 60R TF, 1.6/1.5bpm, 3000/3200psi & 50fph ave ROP. Drilling ratty. 10:12 -10:40 0,47 DRILL P PROD1 Orient 2 clicks & drill to 11460' with 100R TF, 1.6/1.5bpm, 3000/3200psi & 10fph ave ROP. Stacking. 10:40 -10:52 0.20 DRILL P PROD1 Short trip to 11000'. 10:52 - 11 :09 0.28 DRILL P PROD1 Drilled to 11464' with 90R TF, 1.6/1.5bpm, 2800/31500psi & 14fph ROP. Inclination = 87 degs. 11:09 -12:00 0.85 DRILL P PROD1 Orient 2 clicks & drill to 11480' with 95R TF, 1.6/1.5bpm, 3000/3200psi & 15fph ROP. Still drilling shale. Geologist wants 83-84 degs inclination to get out of shale. 12:00 - 12:15 0.25 DRILL P PROD1 Orient around to 140R 12:15-13:30 1.25 DRILL P PROD1 Drilled to 11487' with 144R TF, 1.6/1.5bpm, 3000/3200psi & 7fph ave ROP. Not enough wt to drill thru shale. Call for 60 bbls fresh mud with 6% lubetex to see if that does help. 13:30 - 13:35 0.08 DRILL P PROD1 Wiper trip to shoe. RBIH & set down at 11270' (shale), RIH to btm. 13:35 - 14:30 0.92 DRILL P PROD1 Attempt drill, still stacking. Had to reboot MWD surface computers. ( ( Printed: 11/13/2001 4:31 :05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/5/2001 11/6/2001 ( (' BP EXPLORATION Operations Summary Report 1 5-32 1 5-32A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Activity Code NPT Phase 14:30 - 15:45 15:45 -16:20 16:20 - 17:30 17:30 -19:00 19:00 -19:45 19:45-21:10 21:10-21:30 21:30 - 22:15 22:15 - 23:30 23:30 - 00:00 00:00 - 01 :00 01:00 - 02:10 02:10 - 02:20 02:20 - 03:00 03:00 - 06:00 06:00 - 06:20 06:20 - 07:00 07:00 - 12:45 12:45 - 14:15 14:15 -15:15 15:15 -15:45 15:45 -18:00 18:00 -18:20 18:20 -18:50 18:50 -19:50 19:50 - 20:35 1.25 DRILL 0.58 DRILL 1.17 DRILL 1.50 DRILL 0.75 DRILL 1.42 DRILL 0.33 DRILL 0.75 DRILL 1.25 DRILL 0.50 DRILL 1.00 DRILL 1.17 DRILL 0.17 CASE 0.67 CASE 3.00 CASE 0.33 CASE 0.67 CASE 5.75 CASE 1.50 CASE 1.00 CASE 0.50 CASE 2.25 CASE 0.33 CASE 0.50 CEMT 1.00 CEMT 0.75 CEMT N P P P P P P P P P P P P P P P P P P P P P P P P P SFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP CaMP COMP CaMP CaMP COMP CaMP CaMP COMP CaMP CaMP CaMP Page 7 of 9 Start: 9/17/2001 Rig Release: 11/9/2001 Rig Number: Spud Date: 9/17/2001 End: 11/9/2001 Description of Operations W.O. MWD surface computers. Drilled to 11497' with 111 RTF, 1.6/1.5bpm, 3000/3300psi & 15fph ave ROP. Start pumping 55 bbls fresh mud with 6% lubetex. Occasional drilling take offs & stops. New mud @ the bit. Take off & drill to 11524' with 100R TF, 1.6 /1.5bpm, 3000/3300psi & 50fph ave ROP. Drilled to 11531' with 115R TF, 1.6/1.5bpm, 30PO/3100psi & 15fph ave ROP. Weight stacking. Slow wipe btm 70' of hole to get wt to btm Drill and can't make hole at 11531' CTD. Got motor diff and getting to btm. CT has 25% wear at this spot. AK Airlines calls saying Goldstreak package with revised well map can be picked up. . . . Wiper to 9750' while Energy Center video crew does their thing in ops cab and wo geo's to decide if they want to continue. Will require a trip to cut CT (fatigue) and a mud swap to get 150' more hole which wouldn't be enough 1A sand (not even into it yet) to produce. Will live wI a 1 B producer Log tie-in at 10030' Add 14.0', RIH. Set down in shale at 11250' and work 10 min to get thru Tag TD at 11535' CTD/8851 , TVD. Backream OOH Flag at 8600' EOP. POOH for liner POOH for liner LD drilling BHA Safety mtg re: liner RU to run liner MU 84 jts 2-3/8" 4.7# L-80 STL liner w/ float equipment Crew chglsafety mtg Fin MU liner M/U Baker slickstick. Strap, drift & M/U 89 jts of 1" CSH workstring. Stung into O-ring flapper & space out with CSH pups. Pressure test seals in O-ring sub to 500 psi - OK. Install CTLRT with 17' stinger below O-ring seal assy. RIH liner BHA (OAL - 2775") with CT smoothly & tag btm @11536'. Check Up wt without pumps @ 28k & with pumps 24.5k. Load 5/8" steel ball. Displace with flopro @ 1.3/1.2bpm & 4100psi. Slow rate to 0.8/0.7bpm & 2600 psi @ 33 bbls away. Meanwhile RIU DS cementers. No pressure ramp up after pumping 50bbls (Coil Vol = 41.7bbls). SD pumps, P/U & confirm liner release with 21 k up wt. Suspect premature release & shearing of ball seat due to high pressures (4100 psi) while displacing ball to seat. Liner was set to release @ 3000 psi & ball seat shear @ 3750 psi. Swap well to KCI @ 1.3/1.2bpm & 3650psi. Crew change & Safety mtg re: cmt Batch-up cement slurry. PT DS @ 4400 psi. DS load CT wI 45 bbls 15.8 ppg G cement wI latex 1.2/3800 Displace cement w/2% KCI water 0.8/3800 and under displ by 2 bbls. Unsting at 20.8k, retag. Had 33 bbls (out MM total, but needs calibration-est more like 40 bbls) annular returns after Printed: 11/13/2001 4:31 :05 PM BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: 1 5-32 Common Well Name: 15-32A Spud Date: 9/17/2001 Event Name: REENTER+COMPLETE Start: 9/17/2001 End: 11/9/2001 Contractor Name: NORDIC CALISTA Rig Release: 11/9/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/6/2001 19:50 - 20:35 0.75 CEMT P CaMP cement around shoe 20:35 - 23:45 3.17 CEMT P CaMP Pump 27 bbls Biozan to CT 1.3/3800 and displace with KCI. Jet from PBD DOH and dumped 80 bbls cement contaminated fluid w/ density as high as 11.5 ppg (yup, a lot more than normal) 23:45 - 00:00 0.25 CEMT P CaMP RU to standback CSH 11/7/2001 00:00 - 01 :30 1.50 CEMT P CaMP LD 1 single and pup. Stand back 44 CSH doubles 01 :30 - 02:45 1.25 EVAL P CaMP RU CNL tools 02:45 - 03:00 0.25 EVAL P COMP Safety mtg re: source 03:00 - 04:45 1.75 EVAL P CaMP MU 45 CSH doubles 04:45 - 05:50 1.08 EVAL P CaMP RIH w/ CT 05:50 - 07:30 1.67 EVAL P CaMP Begin logging down from 8400' at 30'/min 07:30 - 09:30 2.00 EVAL P CaMP Tag bottom at 11492' CTM uncorrected (Should be 11497' based on tally). Spot 15 bbls of high viscosity flo pro mud. Log up at 30 fpm. Clean pickup off bottom. 09:30 - 10:20 0.83 EVAL P CaMP Log up to 8400', POOH with coil to top of CS hydril. 10:20 -10:40 0.33 EVAL P COMP Tag up at surface with CTC, stand back injector. 10:40 -12:15 1.58 EVAL P CaMP Pull and standback CS hydrill. 12:15 -12:30 0.25 EVAL P CaMP Safety meeting prior to laying down memory CNL. (Radioactive logging source) 12:30 - 12:45 0.25 EVAL P CaMP Lay down memory tool. 12:45 - 13:10 0.42 EVAL P CaMP Wait on Schlumberger to download Memory tool and confirm no gas in perfs prior to picking up perf guns. Log shows possible gas under run just above upper perfs. Fax log to town for decision on shooting upper zone. Also got confirmation from SWS lab that cement was at 2000psi compressive strength at 15:00 hours. 13:10 -13:45 0.58 EVAL P CaMP PT liner lap. Pressure up to 2000 psi. Bled down to 900 psi in 15 minutes. Repeat test, confirming that all valves are double blocked. Same thing appear to have a leaking liner lap. 13:45 -14:15 0.50 PERF P CaMP Safety meeting prior to picking up perf guns. 14:15 -17:30 3.25 PERF P CaMP Pick up SWS perforating guns. Hold kick drill with safety joint on gun #3. 17:30 -19:30 2.00 PERF P CaMP Make up CS Hydril. (38 Stands). 19:30 - 21:10 1.67 PERF P CaMP RIH wI CT 21 :10 - 23:35 2.42 PERF N SFAL CaMP Tag at 11498.3' CTD, corr to 11497.6'. PUH 23.2k. Park at set depth. Load CT w/12 bbls Flo Pro mud. Load 1/2" aluminum ball. Displace w/ KCI to seat and no indication of on seat. Load 1/2" steel ball and chase with KCI. No indication 23:35 - 00:00 0.42 PERF N SFAL COMP POOH filling from BS 11/8/2001 00:00 - 01 :00 1.00 PERF N SFAL COMP POOH wI perf guns 01 :00 - 02:45 1.75 PERF N SFAL CaMP Standback CSH 02:45 - 04:00 1.25 PERF N SFAL CaMP Check firing head. Guns didn't fire and neither ball was found. Check upper BHA, lower BHA. Check ball drop port. Load a foam pig into ball drop and circ a coil volume at high rate (2.5 bpm) to catcher (41.8 bbls). Found the 1/2" aluminum, the 1/2" steel, parts of the pig, two small chunks of cement and, gulp, a 5/8" steel ball (probably from the liner release tool) 04:00 - 05:30 1.50 PERF N SFAL CaMP Load another foam pig and do it again (41.6 bbls)-recover pieces of pig. Load a 1/2" steel ball and circ at normal displ rate (w/ CSH on CT) of 1.4 bpm and ball landed at 50 bbls 05:30 - 07:00 1.50 PERF N SFAL CaMP Blow back reel w/ air. RD inner reel hardline to find out where (' ( Printed: 11/13/2001 4:31:05PM BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: 1 5-32 Common Well Name: 15-32A Spud Date: 9/17/2001 Event Name: REENTER+COMPLETE Start: 9/17/2001 End: 11/9/2001 Contractor Name: NORDIC CALISTA Rig Release: 11/9/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/8/2001 05:30 - 07:00 1.50 PERF N SFAL CaMP the 5/8" ball was hiding for so long 07:00 - 07:20 0.33 PERF N SFAL CaMP Pre tour safety meeting. 07:20 - 07:35 0.25 PERF N SFAL CaMP Pressure test hardline after inspecting to 4500 psi. PT passed ok. No problems or hang ups observed during inspection of hardline. 07:35 - 08:00 0.42 PERF N SFAL CaMP Inspect CTC to ensure that there are no hang ups inside of it. 08:00 - 10:00 2.00 PERF N SFAL CaMP RU dart catcher. Pump at 3.5 bpm for 1.5 coil volumes to ensure that coil is clean of dart debris. No debris found in coil connecter. Blow back coil, cut off old CTC. Run 1 stand on top of perf guns in hole to get them off the rig floor. Weld on new CTC. Pull test CTC to 40 klbs, PT to 10:00 - 10:15 0.25 PERF N SFAL CaMP Safety meeting prior to running CS hydrill work string. 10:15-11:15 1.00 PERF N SFAL CaMP RIH with 39 stands of CS hydrill. 11: 15 - 11 :45 0.50 PERF N SFAL CaMP Make up injector. 11 :45 - 13:35 1.83 PERF N SFAL CaMP RIH with perforating BHA on coil. 13:35 - 14:20 0.75 PERF P CaMP Tag up, correct depth to PBTD. Made +1' correction to get on depth. Pull up to shooting depth with gun bottom nose at 11441'. Circulate new double slick KCL down coil. Saw 900 psi pressure drop while swapping over to double slick. Pump 5 bbls high vis flo pro mud. 14:20 - 14:50 0.50 PERF P COMP Drop 1/2" ball to fire guns. Confirmed ball rolling after dropping ball. Chase ball with 9 bbls of high vis fJo pro mud. Follow mud with extra slick KCL. Pump at 1.7 bpm, 4000 psi CTP. Landed ball at 33 bbls away. (Coil vol + CS hydril = 43 bbls). Circ press 800 psi, guns fired at 3200 psi. Firing head pinned for 2500 psi over. Good indication of guns firing. 14:50 - 16:15 1.42 PERF P CaMP POOH with coil. Filling down the backside. Holding 250 psi on well with choke. 16:15 -17:15 1.00 PERF P CaMP Tag up at surface, stand back injector. 17:15 -18:00 0.75 PERF P CaMP Pull 1" CS hydrill work string. Stand back same. 18:00 - 18:15 0.25 PERF P CaMP Shut down for crew change. 18:15 - 18:35 0.33 PERF P CaMP Resume pulling pipe. 18:35 -18:45 0.17 PERF P CaMP Safety mtg re: perf guns 18:45 - 20:20 1.58 PERF P CaMP LD perf guns-all shots fired. Kick drill w/ safety jt Perforated 11000-11100', 11150-11230', 11290-11440' w/4 spf w/1-11/16" guns 20:20 - 21 :45 1.42 RIGD P CaMP RU nozzle assy. RIH pumping MeOH. POOH freeze protecting from 2000' w/ 25 bbls MeOH (neat) 21 :45 - 22:45 1.00 RIGD P CaMP DOH. SI swab. Blow down lines w/ air 22:45 - 00:00 1.25 RIGD P CaMP ND BOPE 11/9/2001 00:00 - 00:45 0.75 RIGD P CaMP NU tree cap and test RREL @ 0045 hrs for move to 15-16 15-32A = 8 days 6.25 hrs (' ( Printed: 11/13/2001 4:31:05PM .-"tII... : : bp ~ ( BP Amoco Baker Hughes INTEQ Survey Report ( Riï. BAIŒ8. HI.JC .. S --------- -'---.---'---- INTEQ Compny: BP Amoco Field: Prudhoe Bay Site: PB DS 15 WeD: 15-32 WeUpatlt: 15-32A Date: 1/212002 TIme: 15:57:26 Page: I Co-ordiaate(NE) Refereace: Well: 15-32. True North Vertical (TVD) Reference: 46: 32 41211994 00:00 68.0 Sectloa (VS) Refereace: Well (0.00N,0.00E,170.00Azi) Sarvey Catc.latloa Metltod: Minimum Curvature Db: Oracle Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Eastlng: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: 70 17 35.236 N Longitude: 148 34 21.213 W North Reference: True Grid Convergence: 1 .34 deg Site: Well: 15-32 Slot Name: 32 15-32 Well Position: +N/-S 975.72 ft Northing: 5959812.81 ft Latitude: 70 17 44.833 N +EI-W 2.92 ft Eastlng : 676277.02 ft Longitude: 148 34 21.128W Position Uncertainty: 0.00 ft Wellpath: 15-32A 500292246201 Current Datum: 46: 324/2/1994 00:00 Magnetic Data: 917/2001 Field Strength: 57502 nT Vertical Section: Depth From (TVD) ft 0.00 Survey: MWD Drilled From: 15-32 TIe-on Depth: 10365.00 ft Height 68.05 ft Above System Datum: Mean Sea Level Declination: 26.64 deg Mag DIp Angle: 80.81 deg +N/-S +EI-W DIrection ft ft deg 0.00 0.00 170.00 Start Date: 111512001 Engineer: Tied-to: From: Definitive Path Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Annotation MD ft 10365.00 11535.00 TVD ft 8855.10 8919.19 KOP TD Survey MD Incl Azlm TVD SSTVD N/S EIW MapN MapE DLS VS ft deg deg ft ft ft ft ft ft deg/100ft ft 10365.00 90.80 126.40 8855.10 8787.05 -1008.28 1490.02 5958839.82 677700.18 0.00 1251.70 10400.34 89.65 119.80 8854.96 8786.91 -1027.57 1519.61 5958821.23 677820.21 18.96 1275.84 10431.46 87.54 124.37 8855.72 8787.67 -1044.09 1545.96 5958805.34 677846.94 16.17 1296.68 10464.69 87.28 130.35 8857.23 8789.18 -1064.23 1572.33 5958785.83 677873.77 17.99 1321.09 10494.96 88.86 134.57 8858.25 8700.20 -1084.64 1594.64 5958765.94 677896.56 14.88 1345.07 10524.71 89.47 140.55 8858.68 8790.63 -1106.59 1614.71 5958744.47 677917.13 20.20 1370.17 10557.54 88.51 148.28 8859.26 8791.21 -1133.26 1633.80 5958718.26 677936.84 23.72 1399.75 10594.67 86.13 153.20 8861.00 8792.95 -1165.60 1651.92 5958686.35 677955.71 14.71 1434.75 10624.79 87.54 148.28 8862,66 8794.61 -1191.83 1666.61 5958660.47 677971.02 16.97 1463.13 10664.47 89.56 149.34 8863.66 8795.61 -1225.76 1687.15 5958627.04 677992.35 5.75 1500.11 10694.82 90.44 156.37 8863.66 8795.61 -1252.75 1700.99 5958600.38 678006.81 23.34 1529.1 0 10730.42 87.89 162.69 8864.18 8796.13 -1286.08 1713.43 5958567.35 678020.03 19.14 1564.08 10765.37 83.67 161.99 8866.75 8798.70 -1319.29 1724.01 5958534.41 678031.38 12.24 1598.61 10802.57 86.57 174,30 8869.93 8801.88 -1355.49 1731.60 5958498.40 678039.82 33.88 1635.58 10835.18 88.59 181.33 8871.31 8803.26 -1388.02 1732.84 5958465.90 678041.82 22.41 1667.84 10866.50 88.86 186.25 8872.01 8803.96 -1419.26 1730.77 5958434.63 678040.48 15.73 1698.24 10898.60 90.88 187,30 8872.08 8804.03 -1451,13 1726.98 5958402.68 678037.44 7.09 1728.97 10931.13 89.21 198.55 8872.05 8804.00 -1482.79 1719.72 5958370.86 678030.92 34.96 1758.88 ..'.~ ..'1ot, : : O¡:-) ---...,' ( ( BP Amoco Baker Hughes INTEQ Survey Report lBii8 BAKD NUGI8 S ._-- ___eo_. ----- INTEQ Compaay: BP Amoco FIeld: Prudhoe Bay Site: PB OS 15 WeD: 15-32 WeUpatla: 15-32A Date: 11212002 TIme: 15:57:26 Page: 2 Co-ordlaate(NE) Reference: Well: 15-32, True North Vertical (1VD) Refere.ce: 46: 324/2/1994 00:00 68.0 Sectloa (VS) Refereace: Well (0.OON,0.00E,170.00Azi) S.rvey Calc.laöoa Metllod: Minimum Curvature Db: Oracle Survey MD lael AzIm TV» SS TV» NIS EIW MapN MapE DLS VS ft deg deg ft ft ft ft ft ft deg/ 1 00ft ft 10963.85 86.92 199.26 8873.16 8805.11 -1513.72 1709.12 5958339.69 678021.06 7.33 1787.51 10998.61 85.69 192.58 8875.40 8807.35 -1547.06 1699.61 5958306.14 678012.33 19.50 1818.69 11028.49 86.40 188.36 8877.46 8809,41 -1576.36 1694.20 5958276.72 678007.61 14.29 1846.61 11065.81 86.13 184.14 8879.90 8811.85 -1613.37 1690.14 5958239.63 678004.42 11.31 1882.35 11098.94 82.44 182.03 8883.19 8815.14 -1646.28 1688.37 5958206.69 678003.42 12.81 1914.46 11136.06 81.30 176.76 8888.45 8820.40 -1683.02 1688.75 5958169.98 678004.67 14.39 1950.70 11167.72 84.29 175.70 8892.42 8824.37 -1714.35 1690.82 5958138.70 678007.47 10.01 1981.92 11200.82 83.67 169.37 8895.89 8827.84 -1746.97 1695.09 5958106.19 678012.50 19.11 2014.78 11236.24 83.06 164.45 8899.99 8831.94 -1781.23 1703.06 5958072.13 678021.27 13.90 2049.90 11269.02 83.50 158.12 8903.83 8835.78 -1812.05 1713.50 5958041.57 678032.43 19.22 2082.07 11299.00 83.14 153.20 8907.32 8839.27 -1839.17 1725.77 5958014.74 678045.33 16.34 2110.91 11337.22 89.74 151.09 8909.69 8841.64 -1872.88 1743.58 5957981.47 678063.93 18.13 2147.19 11379.60 89.65 158.12 8909.91 8841.86 -1911.14 1761.74 5957943.65 678082.98 16.59 2188.02 11415.95 88,28 165.16 8910.57 8842.52 -1945.61 1773,18 5957909.45 678095.23 19.73 2223.96 11450.65 87.28 166.21 8911.92 8843.87 -1979.20 1781.76 5957876.07 678104.59 4.18 2258.53 11483.20 85.08 172.19 8914.09 8846.04 -2011.09 1787.84 5957844.34 678111.42 19.54 2290.99 11508.25 84.11 177.46 8916.45 8848.40 -2035.92 1790.09 5957819.57 678114.25 21.30 2315.83 11535.00 84.11 177.46 8919.19 8851.14 -2062.50 1791.27 5957793.03 678116.05 0.00 2342.22 WELLPATH DETAILS Ref. V.Section Angle 170.00' Origin +N/-S 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E) Reference. Well Centre: 15-32, True North Vert'cal (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot. 32 (O.OON,O.OOE) Measured Depth Reference: 46. 324/2/199400:00 6B.05 Calculation Method. Minimum Curvature ANNOTATIONS we -", -CIW"'"CO NO MD Ao="',oo 8787051036500 KOP 885114 1153500 ill B200 B250 B300 B350 .... I:: ~B400 Q ¡nB450 .... ;B500 a. ~8550 ~B600 ¡B650 :> ~8700 ~ ~B750 BBOO BB50 B900 8950 LEGEND T Azimuths to True North Well path (1S-3211S-32A) Magnetic North: 26.64" Created By, ad) Potn" Date 1/212002 Field Stre 02nT Dip ,BI' Date: 9/7/2001 Model: BGGM2001 , I", I I ':' 'I ,I: '. '. ' i "; I. , ' I " " ::' : .:, -900 ,. " f I ': ' " . , " -"", , I, ' , . , --. " , ' , -":' " . , -1100 , . , " , ' ' ., ~ -1200, ':' ," I: I -lOUI " '" ,"m, I' ,",": , . , ' "" , ,- , , -1400 : "'. , ': : ','", ' , ' ..,., "" , , I , - '" I ' . ' , , 'I I, , I .. --:-"': ' ~ ,'d ... Id --, " ' . .:" ::-.1700 I,' !, ,: I' " , ::¡ " ,," ,', :'.. , ' : : " , : " ' , , , " , , " " "--1900 , ',' 'I" ,I . , , " ", I, ,. lID I I "I. "I , : . 'I.-é -=- ~_:, , .' : -2000 " i :) I , ~ " ' : , I -~~ , . , :, - ,: ': , 'I: , '" .: -2200' 'littih' "":',', ,,', ' :. "f -2300 , : , " I " , -;¿4UU " :' '1:1: '¡v-c-;, ,:1,'1' ., ' , '" , . : L.~L~:""'::""'II': ,ii, ,Ll ~, ~~O "T ~ ' , . ' .. , ., I :1 700 BOO 900 1000 1 1700 1750 1BOO 1B50 1900 1950 2000 2050 2100 2150 2200 2250 2300 Vertical Section at 170.00. - Well: Field: API: Permit: (' ( 10/31/01 11/02101 11/09/01 Nordic #1 ------.----------- POST RIG WORK 11/18/01 DRIFT WI DUMMY PATCH (3.805" 00 X 23.73' LONG). TIGHT SPOT @ 2229' SLM. PASS THRU TO 3500' SLM. NO MORE PROBLEMS. RDMO. 15-32A Prudhoe Bay Unit 50-029-22462-01 201-184 Rig Accept: Rig Spud: Rig Release: Drilling.B!g: 12/15/01 SET 4.5" HALLIBURTON PATCH @ 2984.5 FT TO 3006.5 FT [CENTER OF PKR ELEMENTS). DID NOT TAG TO/ STICKY THROUGH THE SSSV @ 2215 FT. POOH, RDMO. (: ~ , I.- I ! I DftIrr", - "',""""""" II I I ----"'-.--"-----'..'--'- i)'¡,~~:-?i1:".., :-.. - .. M -< :~~. ::: -- -:~----'-n --"-'-----'- Transmittal Form To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 1 00 Anchorage, AK 99501 I~~'. ,-". - ". M -'. &I. I:~..".. . BAKER HUGHES I Canada GEOSciences Centre I I I I :-.. ... .. M -. 'i.~-...;;;~;;;--"";;---;-ñ- ,~-,,-.. ::;"~~"'~ ~ :' ... j ¡ ij g ¡ : ;1 ¡¡I '¡ ¡ H i~ ~ : ¡HI : :~1:> j j H!~ -~--- ¡ ~ ~¡ ~ ~ : :1 i~ ! : ;¡. , a¡.~ ~ : ~~:t .: : :: =; \ : :: h ., . ..:. ; : ,:!:i , : ~:-; i: .Bi : : ~:,.. -~"- ¡ : ::1 if Ë ¡ ~H¡ ~ : ,.::U " : .~ ~~ a : ~I ~~ ~ : .: ¡- : : 1!:~ i : ~îiî ¡ : ~! ¡¡~ . . " '" _..~,,- ¡ ¡ ;(,;¡ I : ~ ~,¡ i : ~i~ rj ¡ ~',I ~~ ~ ¡ iU~ ¡ : :1: :.~ 1 : ~i ¡ i j @!~, :'.-;:,:" ~. ; r ~.~~~! .'~ ~" .: Baker Atlas Attention: Lisa Weepie Reference: 15-32A Prudhoe Bay Unit ao/-I'lL! , . -... ... Contains the rollo\\'iní!: ...' ::;,~'" ,,=,:'."'."~'.:"""'7"~' .'.' .,V.,. ".' ~~'!!!!-~!,__!~_~L I LD\\'C; format disk .I listin~ ..." I, ~ct lïlnls (2 films: IGR :\10 and 11"\'D) ", I set prints (2 prints: IGR :\10 and IT\'D) ¡¡; !I II II ~ r ¡ I ¡ ¡ LAC:16535 ,""""" ..\'.."'1 """I ".............," "" "-....: ;-"" ""I"'.' X~,I"~l ':""" , """"'1"1 ,ce"---;,;---'- -_.---- -..---.-- -....-.-- -- ------- -- ------ :r--=-=: --===:::== /..--- .--...---- - ..-..- : .~=--=-- ,~,.=-~::::: ==-:::: i -1----' ,--------.----------- .-I=~= --,. ---- --'----- --t- ,,:--' .:~!..::J Sent By: Iuliana Craiciu ~ ¿J), <', Received By QCJ ~ Date: FA~e~IVE Date: FEB 0 $ 2002 Alaska Oil ~GJ3_Comm' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RE'NdtirIlANGn OR FAXING YOUR COpy FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 " """I '------.-" ,---~~~.--~ >",:. ~,:' ,"'I 'I""" ,...,.."::::,:!;~:~~~~':,!::~!......- ..,,""":::10-1,. ..... ScblllDbepgeli Alaska Data & Consultlng Services 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie -- Well - Job # Log Description INJECTION PROFILE 21460 RST-SIGMA 21194 RST-SIGMA 21470 MCNL 21481 RST-SIGMA 21479 MCNL 21469 RST-SIGMA 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 DEC 0 7 2001 . . . . Anchorage Date 11/22/01 10/23/01 04/05/01 10/29/01 11/09/01 11/07/01 10/25/01 Blueline 12/05/01 NO. 1663 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay,Niakuk Sepia Color Prints CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received b~ { ~ , ~u~uŒ lID~ ~~~~[}{~ I~, / TONY KNOWLES, GOVERNOR AlAS IiA 0 IL AND GAS COl\TSERVATI ON COMMISSION 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood . CT. Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 15-32A BP Exploration (Alaska) Inc. Permit N9i ,~01-184 ~Sur Lo¿:~~' SNL, 333' EWL, Sec. 22, T11N, R14E, UM Btmhole Loc. 4132' SNL, 2044' EWL, Sec. 22, T11N, R14E, UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 15-32A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (1lA....,_.~ ~ é~~;- ~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 17th day of September 2001 cc: Department ofFish & Game, Habitat Section wloencl. Department of Environmental Conservation wlo encl. ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 f;~# k ~ øt/:j ~) 9)1<1-/0 J 1 a. Type of work 0 Drill 0 Redrill 1 b. Type of well 0 Exploratory ~atigraPhiC Test II Development Oil 0 Re-Entry II Deepen 0 Service 0 Development Gas Sin"gle Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. RKB = 68.05' Prudhoe Bay Field I Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028306 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) " 1~' SNL, 333' EWL, SEC. 22, T11 N, R14E, UM Prudhoe Bay Unit ~ t"1 At top of productive interval 8. Well Number 1774' SNL, 356' EWL, SEC. 22, T11N, R14E, UM 15-32A Number 2S1 00302630-277 At total depth 9. Approximate spud date 4132' SNL, 2044' EWL, SEC. 22, T11N, R14E, UM 09/17/01 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028309, 1147' MD No Close Approach 2560 11900' MD / 8810' TVDss 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10365' MD Maximum Hole Angle 91 Maximum surface 2295 psig, At total depth (TVD) 8800' / 3450 psig 18. Casing Program Specifications Setting Depth ¡tv of Cement t ;j7P. Te 10 Bottom Hole C:::¡sina Weiaht Grade Couolina Lenath MD TVD MD TVD (include staae data) 3" 2-3/8" 4.7# L-80 ST-L 3200' 8700' 8581' 11900' 8810' 181 sx Class 'G' f'""\ r r"'\ r ~ \\ I r" 11'"'"\ r'L..\JL~ V œ r jJ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary SEP 1 2 ZO01 Total depth: measured 10365 feet Plugs (measured) true vertical 8855 feet Effective depth: measured 10342 feet Junk (measured) Alaska Oil & Gas Cons. Commission Anchorage true vertical 8855 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset 114' 114' Surface 3495' 13-3/8" 1170 sx PF 'E', 375 sx Class 'G' 3530' 3529' Intermediate 8295' 9-5/8" 610 sx Class 'G' 8327' 8319' Production Liner 1484' 7" 280 sx Class 'G' 8165' - 9649' 8161' - 8859' Liner 948' 4-1/2" Uncemented Slotted Liner 9417' - 10365' 8880' - 8855' Perforation depth: measured 9100' - 9120', 9150' - 9170' Slotted Liner: 9630' - 10342' true vertical 8867' - 8871', 8877' - 8880' Slotted Liner: 8861' - 8855' 20. Attachments 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: Alistair Sherwood, 564-4378 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the fOr~æng)s, tru ~d ~(>rrect Þ the best of my knOWledge. 1/t¿/o( Signed Alistair Sherwood ...;.. l'J6Jtui t~ h/h-\1fèC' . Title CT Drilling Engineer Date : ,'; ~::, '..;>': i: ':" "':' '.::, ::',:.: ,': !...:".:¡¡ >,::', : ':::: :" ':,: ,";>1/:,':::.::::::>,:,::"':: ;;!,':', : ',::::..,!,:: '1:';'<: '\': "~'qøtíd11iì~~!q~\~!sä,:():~,ly::::: :': :i,:.i:¡,:::':',:!:::»! .i':,: ii:¡:F,¡;!:-;~:~T':T;;' ~c:,~:. :.::: :..' ¡ ::: : :~'::;,' :'j;,":::: : ',' ,!!,' ',:,i', , .:', ':,':> :':::.: permi~~,~ / 8 ~ API Number ðf~T)itl ~aje See cover letter 50- 029-22462-01 for other reQuirements Conditions of Approval: Samples Required DYes IBI No Mud Log Required DYes ~No Hydrogen Sulfide Measures Ii) Yes DNo Directional Survey Required ~Yes DNo Required Working Pressure for BOPE D2K D3K D4K D5K D10K D15K ~.5K psi for CTU Other: Original Signed By by order of Date Cf, /1 ,n I Approved By Cammy Oechali Commissioner the commission Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate ( ( BPX 15-32A Sidetrack Summary of Operations: A CTO sidetrack of well 15-32A will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Please note that the arrival of the rig, and therefore the urgency of this Drilling Permit is dependant upon prep work currently being undertaken on 14-40 and the proximity of Nabours 3S on OS 15. Phase 1: Prepare Well for CTD Operations: Planned for September 13th, 2001 . Retrieve tubing patch covering GlM#1 @ 2981' using slickline. . Set plug in tailpipe nipple using slickline and perform a combo MIT on tbg & IA . Mill out fill & 4Y2"slotted liner shoe @ 10,365' using service coil. Phase 2: Drill and Complete CTD sidetrack: Planned for September 1 ¡th, 2001 . 2" coil will mill out fill & 4Y2"slotted liner shoe @ 10,365' and drill a -1,500 foot, 3" open hole sidetrack, (as per attached plan). This will be completed with a solid & cemented 2-3/8" liner which will be selectively perforated. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: . No annular injection on this well. . 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: . 2-3/8", l-80, solid liner will be run from 8,700'md (TOl, 8581' TVDss) to TO at approximately 11,900'md. Liner will be cemented from TD up to within 50' of the tailpipe, -8818' md. Approximately 37 bbls (annular volume plus 25% excess in OH) of 15.8 ppg class G cement. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray log will be run over the open hole section. . A memory CNl will be run inside the liner. Hazards . On the 12th Jan 2001, H2S was sampled at 10ppm. . The well path will cross one mapped fault -100ft into drilling. With a throw of -15-20 ft problems are not anticipated. The fault may not even be recognized while drilling. Reservoir Pressure Reservoir pressure is estimated to be 3,450 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/It) to surface is 2,295 psi. ,TREE = 4-1/16" MCEV OY ( W8..LHEAD= FMC ACTUATOR= BAKER C KB. 8..EV = 68' BF. 8..EV = KOP= 8149' Max Angle = 98 @ 9582' Datum MD = 9045' Datum lVD= 8800'SS 3530' 13-3/8" CSG, 68#, L-80 BTC, 0.1497 bpf, ID = 12.415" Minimum 10 = 2.44111 @ 2981' 4-1/2" AVA OWP RETRIEVABLE PATCH 4-112" TBG, 12.6#, L80 NSCT, 0.0152 bpf, ID = 3.958" 3966' 1 5 -3 2 . I I I 7" LNR, 26#, L-80 NSCC, 0.0383 bpf, ID = 6.276" I TOP OF 7" LNR, 26#, L-80 CR-NSCC, --i .0383 bpf, ID = 6.276" 9-5/8" CSG, 47#, L-80 NSCC, 0.0732 bpf, ID = 8.681" I 3-1/2" TBG, 9.2#, L-80 NSCT, --i 0.0087 bpf, ID = 2.992" 8768' I TOPOF 4-112" LNR I 9417' I 4-1/2" LNR, 12.6#, L-80 NSCT, 0.0152 bpf, ID=3.958" I I TOPOF 4-1/2" LNR- SLOTTED I I 7" LNR, 26#, 13CR/L-80 NSCC, 0.0383 bpf, ID=6.276" I ÆRFORA TION SUMMA RY REF LOG: MVVD GRIN/DEN on 3/20/1994 ANGLE AT TOP ÆRF: 82 @ 9100' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 1-11/16" 4 9100-9120 0 11/02/97 2-1/8" 4 9150-9170 0 05/17/96 SLOTTED 9630-10342 SLOT 04/27/94 2215' 2981' ( SAFETY NOTES: LDL 01/19/97 INDICATES LEAK @ GLM#1, AVA PATCH SETON 03/16/97. WELL EXCEEDS 90 DEG. @ 9267'. -1 4-1/2" CAMCO TRDP-4A SSSV NIP, 1D = 3.812" -i 4-1/2" A V A DWP RÐR PATCH (SET 03/16/97) {jA~ LIt- I MANUKt:L~ STA MD lVD DEV 1YÆMAN LA TCH SIZE 1 2991 2990 1 rE- TPD T-2 1.5" 2 4988 4987 1 rE- TPD T-2 1.5" 3 6755 6753 1 TE- TPD T-2 1.5" 4 8049 8046 5 TE- TPD T-2 1.5" 3966' 8164' 8173' 8649' 8700' 8703' 8708' 8740' 8757' 8768' 9417' 9464' 4-1/2" LNR-SLOTTED, 12.6#, L-80 NSCT, --1 10342' PBTDI' .0152 bpf, ID = 3.958" I x 4-1/2" LNR, 12.6#, L-80 NSCT, 0.0152 bpf, ID=3.958" I 1 0365' I I 9630' 9630' 9649' -f 10342' I DATE REV BY COMMENTS DATE REV BY COMMENTS 04/27194 ORIGINAL COMPLETION 12/18/00 SIS-isl CONVERTED TO CANVAS 02/14/01 SIS-MD FINAL 06/02101 CHIKAK CORRECTIONS 3-1/2" OTIS X NIP, ID = 2.813" I 3-1/2" X 4-1/2" XO I 7" X 4-1/2" BAKER SABL-3 PKR, ID = 3.875" I 4-1/2" X 3-1/2" XO, ID = 2.992" I -I 3-1/2" OTIS X NIP, ID = 2.813" -I 3-1/2" PARKER SWN NIP, ID = 2.75" --i 3-1/2" WLEG I 4-1/2" PORTED JOINT W/BLANK (41.55') PRUDHOE BA Y UNIT WELL: 15-32 ÆRMIT No: 94-047 API No: 50-029-22462-00 Sec. 22111 N R14E, 3444.53 Fa 2665.38 FNL BP Exploration (Alaska) . TREE == 4-1/16" MCEVOY ( 15-32A PROPOSED CTD EXTENSION W8...LHEAD== FMC ACTUA TOR== BAKER C KB. 8...EV == 68' BF. 8...EV == KOP== 8149' Max Angle = 98 @ 9582' Datum MD == 9045' Datum 1VD== 8800' SS 3530' 13-3/8" CSG, 68#, L-80 BTC, 0.1497 bpf, ID == 12.415" Minimum 10 = 2.441" @ 2981' 4-1/2" AVA OWP RETRIEVABLE PATCH 4-1/2" TBG, 12.6#, L80 NSCT, 0.0152 bpf, ID = 3.958" 3966' . I 9-5/8" CSG, 47#, L-80 NSCC, 0.0732 bpf, ID = 8.681" I 7" LNR, 26#, L-80 NSCC, 0.0383 bpf, ID = 6.276" TOP OF 7" LNR, 26#, L-80 CR-NSCC, --i .0383 bpf, ID = 6.276" 3-1/2" TBG, 9.2#, L-80 NSCT, -I 0.0087 bpf, ID = 2.992" I TOPOF 4-1/2" LNR 1 4-1/2" LNR, 12.6#, L-80 NSCT, 0.0152 bpf, ID==3.958" 1 I TOP OF 4-1/2" LNR - SLOTTED I 7" LNR, 26#, 13CRlL-80 NSCC, 0.0383 bpf, ID=6.276" I 8768' 9417' 9630' 9630' 4-112" LNR-SLOTTED, 12.6#, L-80 NSCT, 10342' .0152 bpf, ID == 3.958" 4-1/2" LNR, 12.6#, L-80 NSCT, 0.0152 bpf, ID==3.958" 1 10365' ÆRFORA TION SUMrvtARY REF LOG: MWD GRIN/DEN on 3/20/1994 ANGLEATTOPÆRF: 82 @ 9100' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 1-11/16" 4 9100-9120 0 11/02/97 2-1/8" 4 9150-9170 0 05/17/96 SLOTTED 9630-10342 SLOT 04/27/94 9649' I I I ~ 2215' --i 4-112" CAMCO TRDP.4A SSSV NIP, ID == 3,812" 2981' -I 4-1/2" AV A DWP RETR PATa-t (SET 03/16/97) ljA~ LIt- I IW\NUKtl.~ STA MD 1VD DEV TYÆ MA.N LATCH SIZE 1 2991 2990 1 TE- TPD T-2 1.5" 2 4988 4987 1 TE- TPD T-2 1.5" 3 6755 6753 1 TE- TPD T-2 1.5" 4 8049 8046 5 TE- TPD T-2 1,5" 3966' 8164' 8173' 8649' 8700' 8703' 8708' 8730' 8740' 8757' 8768' 8900' 9417' 9464' PBTD 1-1 13" Hole I ( DATE REV BY COMMENTS DATE REV BY COMMENTS 04/27194 ORIGINAL COMPLETION 12/18/00 SIS-isl CONVERTED TO CANVAS 02/14/01 SIS-MD FINAL 06/02/01 CI-V KA K CORRECTIONS 06/04/01 pcr 15-32A Proposed Extension SAFElY NOTES: LDL01119/97 INDICATES LEAK @ GLM#1. AVA PATCH SETON 03/16/97. W8...L EXCEEDS 90 DEG. @ 9267' . 3-1/2" OTIS X NIP, ID == 2.813" 1 3-112" X 4-112" XO I 7" X 4-1/2" BAKER SABL-3 PKR, ID == 3.875" I 4-112" X 3-1/2" XO, ID == 2.992" I -I Top of Proposed 2-3/8" Liner I 3-1/2" PARKER SWN NIP, ID == 2.75" 3-1/2" WLEG I Top of Cement I 7" X 4-1/2" TIW SS HORIZONTAL PKR, ID = 3.96" 4-1/2" PORTED JOINT W/BLANK (41.55') 10342' I I 2-3/8" L-80 LINER, Cemented & Perforated I 11900' PRUDHOE BA Y UNIT W8...L: 15-32A ÆRMrr No: 94-047 API No: 50-029-22462-01 Sec. 22 T11 N R14E, 3444.53 Fa. 2665.38 FNL BP Exploration (Alas ka) 0 0 N ;¡c Õi f3 0 ~ ,3 N " ro ~ do ';: ø ro C ¡¡: Õ "- c ~ 5' ðj ~ m ~ ro )j U ",,0 'Of--° ~~ t"O' øC:~OO 0'" --N"'OO Z'" LLOONN 95~ ~~:~~ ~ ô 6,j;g>£ii5 ;;;~ ~ g'~8~ s'i5 1';0 is E6, (f) :2 ~~ f-- . ~-_._-- fii ~ -----.-- 0 U 0 E <C . ;¡ .. n~ ~ ~ Ii ~~ ~ ~ :i ~ ~ H ~ 15 å ... ~ ~ '" ~ -,~ g is ~ ~~ ci ~ ;,~ g ~ g¥ ci ffi ~Uï if! ~ f¡ ~. - .>- ~" ~ 0 0 a¡ 0 0 0 ... ~ 0 0 0 0 N 0 0 co ';- - ~ m~~m ~ â~;~~;~; ~ g~8g8g88 " oogggggg ~ ~ ;;mm z . "00...' g ~ i~mm ~ m~:m m~m~ ~ m~m~ 0 ..,.,... £ m~m; ~ 88888888 ~ ~~mm 0 0 "0' 0 0 '" 0 0 N <¡J 0 0 ~ 0 0 co <¡J 0 0 .;- <¡J 0 0 I{) 0 0 '" 0 0 r- 0 0 en 0 0 0 <¡J ';- ';- ';- [UI/UOOIo] (.¡.)q:¡..lON/{-)&unog .i .. ¡ ~~ Q . . >-.'.0'.>- . ~ Q ~ . ~ . . Q ~ m~~m ........ ........ ¡~§mn N ... ~ 0 0 0 co 0 0 en N 0 0 '" N 0 0 r- N 0 0 '" N 0 0 i;J 0 0 .;- N 0 0 co N 0 0 N N 0 0 N gC' N .- g~ ~O 00 10?~ 0 -. 0 .¡. ~;;' § ~ ~ ~W 0 - 0 -. I{) . ~;;' 0 CIj ;:: GI g;t co ~ .. c õ: :s '" 0 0 N 0 0 0 0 0 0 0 en 0 0 '" 0 0 r- 0 0 '" 0 0 I{) 0 0 "0' 0 0 I{) <¡J 0 I{) N '" 0 0 co '" 0 0 0 0 0 0 0 0 0 0 I{) 0 I{) 0 I{) 0 I{) 0 I{) 0 co "0' .;- I{) I{) '" '" r- r- '" '" [U!/UOg] q;d.;'a I;~!¡:¡a^ "'an;J. '" 0 I{) '" '" 0 0 N '" ¿ (L " 0 0 m N 0 I{) '" N 0 0 '" N 0 I{) [::¡ 0 0 r- N 0 I{) '" N 0 0 '" N 0 I{) I{) N 0 0 I{) N 0 I{) "0' N 0 0 "0' N 0 I{) co N 0 0 co N 0 c~ N N gC' N N~ 0 .... ;::0 Nil) 0 .... 0 NO gO ¡;¡d ot-- g"l"" N.... g «I ~ C 0 I) 0,- en.... ~ IJ g ~ ;o'fn .,... ;!: «t .,... 0 0 N ¡;:: - 0) ~ " 0 - 0 ftI ;0' (j 0 .- :0:1:: III ê> 0 I{) '" 0 0 '" 0 I{) "~ 0 0 I{) 0 I{) ;:: 0 0 "0' 0 ¡£5 0 0 CO 0 I{) N 0 0 N 0 I{) 0 0 0 c~ 0 0 0 0 0 0 en '" 0 I{) m '" ObP ~: BP Amoco I~ Baker Hughes INTEQ Planning Report (' ... .... INTEQ 1--- : Company: BP Amoco Date: 9n/2001 Time: 16:42:12 Page: i Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-32. True North ¡Site: PB DS 15 Vertical (TVD) Reference: System: Mean Sea Level : Well: 15-32 Section (VS) Reference: Well (0.OON,O.00E.170.00Azi) ! Wellpath: Plan#2 15-32A Survey Calculation Method: Minimum Curvature Db: Oracle c_---------------------------- - --------- - ----.---." -----' - -----" ---------"--- -- - _.-------" -- --------------- --- ----- .-.------------- - "--.---------- --------_..._------- .-.------- --.---. '.-_._~ 1 ----¡ I Prudhoe Bay North Slope UNITED STATES i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 I Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ~ys Datu~:_- ~~~_~__~ea~~~~~_---_. ----------- ----_._._--- --___<?~omagnet~_~~de~____~~~M~_~01- -. --- -. - -- -.---- ,---- -.-- --- ___I j-Sit~; --PB DS-:¡-Š----_._._--------_._-------------------------_._-----.---------------------------. - ------- -.------1 , TR-11-14 I UNITED STATES: North Slope I Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N I From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W l, ,POsi,tion Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg - ---.--- -----.--.---.----- -------.-'--'---- ----------- ----- -.--.---.-.---. '---------'--------.'-"--"-'--'.-----_____.m______-----_.-... -----.-----.----------..-----------.-.-.-----.--.-------..-- --------- Field: -- ----------- .-.--------.-..--------"..---. -----,,-"--------- ---.--------.-------" --., -.-- -----.---. - . --- -'--------.'"--'--------'-------.-----'--'-----"'------"---...... u..------"--"----------.._- -----------....u_. Well: 15-32 15-32 Well Position: +N/-S +E/-W Position Uncertainty: Slot Name: 32 70 17 44.833 N 148 34 21.128W 975.72 ft Northing: 2.92 ft Easting : 0.00 ft 5959812.81 ft 676277.02 ft Latitude: Longitude: - ------ ----...-------,.--.--.----..-----u,,----"------.----..-----------'-"-'---------' '----"------__-m_-__._.-------."----..--.-.----.-..---.-.--,---------.-----------..-----.-.-----------------"--------"-----------_.-._-----_.._'----....,--- ,-.-- -- --------. --______m.___._."" -----.-.-- ------.-- _._--,--- ,,----------------. --,----- -""'--"-------'--------------'----'------" '---'---"------'---'-------.-.-'------'-'--------------.-,,-.--------.-.----.,-------.--------------.--.----.,---'-"-.----"-'-, Wellpath: Plan#215-32A Drilled From: 15-32 500292246201 Tie-on Depth: 10365.00 ft Current Datum: 46: 324/2/199400:00 Height 68.05 ft Above System Datum: Mean Sea Level Magnetic Data: 9/7/2001 Declination: 26.64 deg Field Strength: 57502 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +EI-W Direction ft ft ft deg -. - --, -...-....---.-----..------- --.------.-.---.--- --'-'-----'",,-,-,- __e. - --------.----------.---.-.---.---...-----..-.--.--------. ----------,--------,,--.------.----.-.-------.------.----..--.----.---..------...-.---.-..--.------.---.----- -.-. --.-,.,..-....-- 0.00 0.00 0,00 170.00 "... -,,-,-----. '-'------------------.'---.--.-.-----------..- ------.-.---.----.-- .----.--.-----.. .- --------'-------.---.--...---.,------.-. '---------'--_u_--..-.----.---- .----.-----.---.--------------.-.-----.---.---.-.. -- ----...----...-. --.. -..--------. ..-.. -.-_.. -. - .---..-, ,,-..---.-.. .----------- - --..,..-,- .----------- --.-. '--'------"'-..-------------.. -'-...----.-..---.---.-----------..-----..--..------------.---..-.-----.--,.-.-.- -'----'----.'------.-,---------.-----.. ----.-----.,--.. -.-..-..----.. ---_.---- Plan: Plan #2 Identical to Lamar's Plan #2 Yes Date Composed: Version: Tied-to: 9/7/2001 1 From: Definitive Path Principal: -""----"----..-....---..-.--.---....------------"--- -- ---"----"'-'-'."-'-'-'-'-"-.-'------..-. .-.------ -"'---.-...--..-,-----.----.----...----... --.'----..------.-----.-------------..---.-...-.-----.-__n______---"'--,,--.---------- Targets '¡':N~lIne,,:',Descripdon" 'TVD"':+N/~S¡+Ej-W"North¡nf{""Eåsting' DDegMinSec" "ri~g Min See ': --..- _._"._--_.--~..._-_... .~_:." -------- ,,---.---.. -.-.- - --.-.----- --- --....-- ..,--------_...~~.._._--,---- ..-. -..- .0- ---_._--~---- _.,-_."-_:_---,,~...._.- _._-----_._!t.__._._~---_..._~._._-----_._"._.- ---.-.------'.-.--... -- - -----.-.-.-------...-----.-"---- ------"------- 15-32A T2.1 8810.00 -1405.29 1790.63 5958450.00 678100.00 70 17 31.010 N 148 33 28.946 W 15-32A T2.2 8800.00 8810.00 -2004.57 1751.57 5957850.00 678075.00 5957400.00 678025.00 70 17 25.116 N 148 33 30.089 W 148 33 31.856 W 15-32A T2.3 -2453.31 1691.02 70 17 20.703 N - -'-'-"-----.'---"""-----------..-.--.--,- .----..,-,-.------,..... ,-...- -- -..--- '-'--"--.-----...-..-.----...-..--.------.-----.-----..--------.---.-----.--.----,--.-..-...---..-..-..--...- .--.-.----.---..--.-.--..------..----...---.---..-------.-'--'.--.-'---'--"'------"-.-----n-'-'--. ,--.----.---.-.---- Annotation 10326.00 10365.00 10775.00 10872.68 11072.68 11372.68 11672.68 11900.00 8787.59 8787.05 8806.20 8810.41 8806.99 8802.29 8802.24 8809.96 TIP KOP , 1 2 3 4 5 TO. Plan Section Information ---'--MD"--7",.:"Incl' '---"""~ì~'"~~è-~~TVi>~~~"7,'tN/:"s7i'"'"t~(~W",~~'~rit.S~~Build. ,'-, 'T~rQ ,- ,- .~FØ"-'" ~-;-~-~-_..~~- ---,_._!!.~_.__"__.d~~~.c~~,~-'!~-~¿~~---~~ ' ','" .:'~~~~;--,-~~!t~._;..:.'~~j£t~Ættd,~gl1pØft:,deqiiOqft_, " ~~J!~-~~---~,_._---"-_...:_~-,~-_:.._._..-,~~._...:- 10326.00 90.80 126.42 8787.59 -985.14 1458.64 0.00 0.00 0.00 0.00 10365.00 90.80 126.40 8787.05 -1008.28 1490.02 0.05 0.00 -0.05 270.00 10775.00 84.07 166.91 8806.20 -1342.93 1710.69 10.00 -1.64 9.88 100.00 10872.68 91.00 173.80 8810.41 -1439.03 1727.00 10.00 7.10 7.05 45.00 . -- ---.-- -...- ,---- -.- - --- --------..-- ...--- -----._--- ..----.--..--> .'----.-----..--,-.-..--.-.----.------..-------.---------..--.------,--.-------.- ------"'------..---------- .-----..--..-- ---..---.--..-----.---.-.--.-..--.-...--.--.-.--...-----,------..-----.-.--" .--.------ ,,--- " ObP (' , BP Amoco ~ Baker Hughes INTEQ Planning Report ( llii. .... (NT EQ ~- - .-- - .-- -. - - - - - "" I ! Compaoy: BP Amoco Date: 9n12001 Time: 16:42:12 Page: 2 ' I i Field: Prudhoe Bay Co-ordinate(NE) Refereoœ: Well: 15-32, True North I i Site: PB OS 15 Vertical (fVD) Refereoce: System: Mean Sea Level I , Well: 15-32 Seetioo (VS) Reference: Well (0.OON,O.00E,170.00Azi) I 'Wellpatb: Plan#2 15-32A Survey Calculatioo Method: Minimum Curvature Db: Oracle : I , , . ,. -- -. '- --- -.-- --, -- --- --- -' ----.-- -.--.- ---- ----- -------- - -- ----.--------- ------------------- - ------------.-- --- _._- Pian Section Information .--- -'-------------.-----..--------- - --_.,----------------------------- -,- --.- ------ '-', MD loci ADm TVD +N/-S +E/-W DLS BuDd Turn TFO Target : ft deg deg ft ft ft deg/100ft deg/100ft degl10OO deg I . .- ---'--'----,-- -- --- ---'---'-----------------------------'------. ---------.----------- -------,----------- -----.- ------- --" I 11072.68 90.94 193.80 8806.99 -1637.55 1713.81 10.00 -0.03 10.00 90.00 I I , 11372.68 90.81 163.80 8802.29 -1934.03 1720.01 10.00 -0.04 -10.00 270.00 I I 11672.68 89.21 193.76 8802.24 -2230.55 1726.33 10.00 -0.54 9.99 93.00 I I 11900.00 86.95 171.12 8809.96 -2456.04 1716.69 10.00 -0.99 -9.96 264.00 I 1- -. -,.. ._..~_.._-- --_..------- ".-,.,..-------. ------.-----_u_---.-------- ------------.-----.---...---.. . ----...--------,---.-------..---..----- --u_.- - ------.1 Survey u-- --,--------------- ------'-'- ------'.--- -- -------- - -. ----- -- -- ---.------- ---------- MD Incl Azim SSTVD N/S EJW MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/10OO ft deg ... --, ---- - .----_. -------- ---, -- ----- ..----.. ---- ------ - ,. --------- -- ---------- ----- ------- ... ------------------------ ------ -- ----- ----- - - .-____n-___- --.. ----'-------" -..--. -- - -- -......, -- 10326.00 90.80 126.42 8787.59 -985.14 1458.64 5958862.22 677758.27 0.00 1223.46 0.00 TIP 10350.00 90.80 126.42 8787.25 -999.39 1477.95 5958848.43 677777.90 0.00 1240.85 0.00 MWD 10365.00 90.80 126.40 8787.05 -1008.28 1490.02 5958839.82 677790.18 0.13 1251.70 270.00 KOP 10375.00 90.63 127.38 8786.93 -1014.28 1498.02 5958834.01 677798.31 10.00 1259.00 100.00 MWD 10400.00 90.19 129.85 8786.75 -1029.88 1517.55 5958818.87 677818.20 10.00 1277.76 100.01 MWD 10425.00 89.76 132.31 8786.76 -1046.31 1536.39 5958802.89 677837.43 10.00 1297.21 100.03 MWD 10450.00 89.32 134.77 8786.96 -1063.53 1554.51 5958786.10 677855.95 10.00 1317.31 100.03 MWD 10475.00 88.89 137.23 8787.35 -1081.51 1571.88 5958768.54 677873.72 10.00 1338.03 100.01 MWD 10500.00 88.46 139.70 8787.93 -1100.22 1588.45 5958750.23 677890.73 10.00 1359.33 99.97 MWD 10525.00 88.03 142.16 8788.70 -1119.61 1604.20 5958731.20 677906.93 10.00 1381.17 99.91 MWD 10550.00 87.60 144.63 8789.65 -1139,67 1619.09 5958711,51 677922.29 10.00 1403.50 99.84 MWD 10575.00 87.18 147.09 8790.79 -1160.33 1633.11 5958691.17 677936.78 10.00 1426.29 99.74 MWD 10600.00 86.77 149.56 8792.11 -1181.58 1646.21 5958670.24 677950.38 10.00 1449.49 99.63 MWD 10625.00 86.36 152.03 8793.61 -1203.36 1658.39 5958648.76 677963.07 10.00 1473.06 99.50 MWD 10650.00 85.95 154.50 8795.29 -1225.64 1669.61 5958626.75 677974.80 10.00 1496.94 99.35 MWD 10675.00 85.56 156.98 8797.14 -1248.37 1679.85 5958604.27 677985.58 10.00 1521.10 99.19 MWD 10700.00 85.17 159.46 8799.16 -1271.50 1689.10 5958581.36 677995.36 10.00 1545.49 99.00 MWD 10725.00 84.79 161.94 8801.35 -1295.00 1697.33 5958558.06 678004.14 10.00 1570.07 98.80 MWD 10750.00 84.42 164.42 8803.70 -1318.83 1704.53 5958534.41 678011.90 10.00 1594.78 98.59 MWD 10775.00 84.07 166.91 8806.20 -1342.93 1710.69 5958510.46 678018.62 10.00 1619.59 98.27 1 10800.00 85.84 168.68 8808.40 -1367.27 1715.95 5958486.25 678024.45 10.00 1644.47 45.00 MWD 10825.00 87.61 170.45 8809.83 -1391.81 1720.4 7 5958461.82 678029.55 10.00 1669.43 44.84 MWD 10850.00 89.39 172.21 8810.48 -1416.52 1724.24 5958437.22 678033.90 10.00 1694.41 44.74 MWD 10872.68 91.00 173.80 8810.41 -1439.03 1727.00 5958414.78 678037.18 9.99 1717.06 44.73 2 10875.00 91.00 174.03 8810.37 -1441.34 1727.25 5958412.48 678037.48 10.00 1719.37 90.00 MWD 10900.00 91.00 176.53 8809.93 -1466.25 1729.30 5958387.62 678040.12 10.00 1744.26 90.00 MWD 10925.00 91.00 179.03 8809,50 -1491.22 1730.27 5958362.68 678041.67 10.00 1769.02 90.05 MWD 10950.00 90.99 181.53 8809.06 -1516.22 1730.15 5958337.69 678042.13 10.00 1793.62 90.09 MWD 10975.00 90.98 184.03 8808.63 -1541.18 1728.93 5958312.71 678041.51 10.00 1817.99 90.13 MWD 11000.00 90.98 186,53 8808.21 -1566.07 1726.63 5958287.77 678039.79 10.00 1842.10 90.18 MWD 11025.00 90.96 189.03 8807.78 -1590.83 1723.24 5958262.94 678036.99 10.00 1865.90 90.22 MWD 11050.00 90.95 191.53 8807.36 -1615.43 1718.78 5958238.25 678033.10 10.00 1889.35 90.26 MWD 11072.68 90.94 193.80 8806.99 -1637.55 1713,81 5958216.01 678028.65 9.99 1910.27 90.30 3 11075.00 90.94 193.57 8806.95 -1639.80 1713.26 5958213,75 678028.15 10.00 1912.40 270.00 MWD 11100.00 90.94 191.07 8806.54 -1664.22 1707.93 5958189.21 678023.40 10.00 1935.52 270.00 MWD 11125.00 90.94 188.57 8806.13 -1688.85 1703.67 5958164.49 678019.71 10.00 1959.03 269.96 MWD 11150.00 90.93 186.07 8805.73 -1713.64 1700.48 5958139.63 678017.11 10.00 1982.89 269.91 MWD 11175.00 90.93 183.57 8805.32 -1738.55 1698.39 5958114.69 678015.60 10.00 2007.06 269.87 MWD 11200.00 90.92 181.07 8804.92 -1763.52 1697.37 5958089.70 678015.18 10.00 2031.48 269.83 MWD 11225.00 90.91 178.57 8804.52 -1788.52 1697.45 5958064.71 678015.84 10.00 2056.11 269.79 MWD 11250.00 90.90 176.07 8804.13 -1813.49 1698.63 5958039.78 678017.60 10.00 2080.90 269.75 MWD 11275.00 90.88 173.57 8803.74 -1838.38 1700.88 5958014.95 678020.44 10.00 2105.81 269.71 MWD 11300.00 90.87 171.07 8803.36 -1863.15 1704.23 5957990.27 678024.36 10.00 2130.78 269.67 MWD 11325.00 90.85 168.57 8802.98 -1887.75 1708.65 5957965.78 678029.36 10.00 2155.77 269.64 MWD 11350.00 90.83 166.06 8802.62 -1912.14 1714.13 5957941.53 678035.42 10.00 2180.74 269.60 MWD _.. ..- .............---.... -"---"-"".'-.--"--" -"on.....-..-------..--... ..,---...--.....----------.---... -,..." -----..",.....--, ---...---.-...---.--.--.-----.----.......-,-------.... ...-'.--.-----""--'------" -. ------....---,--.._-... "----'-.---'-"'-'--' ..__..-, --..-.....--,-..,-...-..---...-.---.......----, ~. (' ( BP Amoco ' Baker Hughes INTEQ Planning Report ..8 .... INTEQ ObP : Company: BP Amoco : Field: Prudhoe Bay i Site: PB OS 15 ! Well: 15-32 I , WeUpatb: Plan#2 15-32A l..,. -------- - .-------.------------ ----.--------------------------- Survey :---------------------- ----------------- --- ----------------------.------- ------------------'-, MD Incl Azim SSTVD NIS E/W MapN MapE DLS VS TFO Tool I ft deg deg ft ft ft ft ft deg/10OO ft deg I - --.- - - -------- ------ - -. - ------, ------- - --------------- ------------------------ --. - --- ------- -------- ---.. ..-..--- -- ---- ...J 11372.68 90.81 163.80 8802.29 -1934.03 1720.01 5957919.78 678041.80 9.99 2203.32 269.46 4 11375.00 90.80 164.03 8802.26 -1936.26 1720.65 5957917.57 678042,50 10.00 2205.63 93.00 MWD 11400.00 90.67 166.53 8801.94 -1960.43 1727.00 5957893.55 678049.41 10.00 2230.54 93.00 MWD 11425.00 90.53 169.03 8801.68 -1984.86 1732.30 5957869.25 678055.28 10.00 2255.52 93.04 MWD 11450.00 90.40 171.52 8801.47 -2009.50 1736.52 5957844.72 678060,08 10.00 2280.52 93.06 MWD ~ Date: 9n/2oo1 Time: 16:42:12 Page: 3 i Co-ørdinate(NE) Reference: Well: 15-32, True North I Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E.170.00Azi) : Survey Calculation Method: __~ini.'!1~!!1..~urvatu~~___----- D~~_9..~.!_--_..J 11475.00 90.26 174.02 8801.33 -2034.30 1739.67 5957820.00 678063,80 10.00 2305.49 93.08 MWD 11500.00 90.13 176.51 8801.24 -2059.21 1741.73 5957795.15 678066.45 10.00 2330.38 93.10 MWD 11525.00 89.99 179.01 8801.22 -2084.19 1742.70 5957770.20 678068.01 10.00 2355.15 93.10 MWD 11550.00 89.86 181.51 8801.25 -2109.19 1742.59 5957745.21 678068.48 10.00 2379.75 93.11 MWD 11575.00 89.72 184.00 8801.34 -2134.16 1741.39 5957720.22 678067.87 10.00 2404.13 93.10 MWD 11600.00 89.59 186.50 8801.49 -2159.05 1739.10 5957695.28 678066.16 10.00 2428.24 93.09 MWD 11625.00 89.45 189.00 8801.70 -2183.82 1735.73 5957670.44 678063,38 10.00 2452.05 93.08 MWD 11650.00 89.32 191.49 8801.96 -2208.42 1731.29 5957645.75 678059.51 10.00 2475.50 93.06 MWD 11672.68 89.21 193.76 8802.24 -2230.55 1726.33 5957623,51 678055.07 10.01 2496.44 92.83 5 11675.00 89.19 193.53 8802.27 -2232.80 1725.78 5957621.24 678054.58 10.00 2498.56 264.00 MWD 11700.00 88.93 191.04 8802.68 -2257.23 1720.46 5957596.70 678049.84 10.00 2521.69 264.00 MWD 11725.00 88.67 188.56 8803.21 -2281.85 1716.21 5957571.98 678046.16 10.00 2545.20 264.04 MWD 11750.00 88.41 186.07 8803.85 -2306.64 1713.03 5957547.13 678043.56 10.00 2569.06 264.10 MWD 11775.00 88.16 183.58 8804.60 -2331.54 1710.93 5957522,19 678042.05 10.00 2593.22 264.16 MWD 11800.00 87.91 181.09 8805.45 -2356.50 1709.91 5957497.21 678041.61 10.00 2617.62 264.23 MWD 11825.00 87.66 178.60 8806.42 -2381.48 1709.98 5957472.25 678042.27 10.00 2642.24 264.32 MWD 11850.00 87.42 176.11 8807.49 -2406.43 1711.13 5957447.33 678044.00 10.00 2667.01 264.42 MWD 11875.00 87.18 173.62 8808.67 -2431.30 1713.37 5957422.52 678046.82 10.01 2691.89 264.46 MWD 11900.00 86.95 171.12 8809.96 -2456.04 1716.69 5957397.87 678050,73 10.01 2716.83 264.58 TD -- -- -, ,- -..---" -----.-.. ..--..-.....,..... -....- -..-..---- --",,-----,,--------.--'-""'-------"-"----"-"-'-'-.-----"- ---..---.------...---.....--...-.-..----.------.-------------------------------.---..---------- ------.. ( 2 "CT 10,000 psi Pack-Off Lubricator /. Blind/Shear 7 1/16" Pipe/Slips Pipe/Slips 71/16" Pipe/GI¡f'$ 7 1/16" x 5.000 psi ~;' I" ... ... .... d... It 3/ II :;;) 19 ~ 'f SWAB OR MASTER VALVE CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL -/' EXPLORATION INJECTION WELL INJECTION WELL REDRILL ( f TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSNUTTALLETTER WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL~, R '~SPOSAL NO ANNULAR DISPOSAL <--J YES ANNULAR DISPOSAL THIS WELL \ý~~~ "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). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <--J YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The, permit is approved, subject to full compliance with 20 AAC 25.055~ Approval to peñora1e and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest 10 the spacing exception that may occur. /"""" " ,(' " ( ~ , DATE 07/31/01 CHECK NO. 00194714 H 194714 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 )72701 CK072701E PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it To Drill ee 5/H - Terrie Hub Ie X4628 \ ,,' ';1 '1 /") )- ì,:~ ,'-r '. v' .' ", TOTAL ~ IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 10.00 , 100.00 BP EXPLORATION, (ALASKA) INC. p.o. BOX 196612 ANCHORAGE, ALASKA 99519.6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. ,OHIO 56-389 412 No.H 194714 CONSOLIDATED COMMERCIAL ACCOUNT 00194714' PAY ONE HUNDRED 8c OO/100,*******************~*,***o§;************ US DOLLAR ,,'DATE:~ 6,¿i/31/01r "I. ~.:,,:" '.', " .'.' 1:"=: . , , AMOUNT , $1 00 - 001 To The ORDER Of ALASKA OIL AND GAS CDNSERVATIqNÇOMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE At.<. 99501 , . , ' , '. .-', \2< i> n /1. If i f 'f;~j (~. ~--¥. ~ A~~fI1~, I~ . 'D" """p.,, : III . 9 ... 7 . ... III I: 0'" . 2 0 j B 9 5 I: 0 0 B ...... . 9 III .... WELL PERMIT CHECKLIST COMPANY FIELD & POOL C INIT CLASS I ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. .. . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . .'. . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can.be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided .. . . . . . . .. . . . . . . . . . 15. Surface casing protects all known USDWs. . .. . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . .; . . . . 19. Casing. designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate weilbore separation proposed.. . . . . . ; . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . .. . . DATE 26. BOPE press rating appropriate; test to s.s;D() psig. .5l6 . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdbwn. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . .. 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . APPR DATE I 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . -..:J.b- '7' /4,0 34. Contact name/phone for weekly progress reports [explorat ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; .' (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and . E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING:.. UIC/Ann COMMISSION: ~Þ8 ¿p WM9~~ ~ ~ 1'1(jI~b A~ ~A¡¡; ./ ~ ./,0 ENGINEERING GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) PROGRAM: exp - dev - redrtl serv wellbore seg _ann. disposal para req - GEOLAREA UNIT# n //¿ 5-n ON/OFF SHORE tf)/1 N N :N N Cß . y N~ ~ ~ Q.~<'-~'Ð~ l ~\~~~t.-\:. o~",t:r\:~\)..:~\( N . N . N ~ ~ 16>~~ ~ T:~~~. Y N 1::\"-.- -\l;<: "'.~- ~ ~"-J~. . i~~~?~~~91-Ø-<:;Þ \",¡ .. "'. . y ~ \\, ';, "'" . ~ '\ "::" '\; '" '--"'" '\ ~ '<. \'1' '\t. \ ~ "':. <:<\- -.> \ \' ...... '\. ~ "" <::> ~ <:> ~ ~.,. . . , Y N JI.s I~ - €K IA-o- I S / ~/Is ù..... ~w.6 vI _~5/.sk/rf "v4. n --h I-,~$. Y ~ t:...¿¡: s-+- I1't. 4 s LJ'~./- UH?- /vrL Þ-e- ¿rl!-C 1':>'7c-/ ' ð> ,p~. IS - f5 z. .:0 IÖ V(?"11 i >( N +Á~ I- 1~1>ure.ßIiJ-vf-Æ:Ik ~ken ~ /2.. 2C(;:J/:ßl:::. Y N' , / - only] Y N ' c 0 Z ( 0 -I :e ::0 - -I- m - z -I :t- - en :Þ ( :0 m » Y N Y N Com mentsllnstructions: ( (' Well History File APPENDIX Information of detailed nature that is not , particularly gennane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special' effort has been made to chronologically. . organize this category of information. \ \ ..,.:~I,~,e::t:...l:...,~ L{ t ( **** REEL HEADER **** MWD 02/01/31 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/01/31 208288 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! Remark File Version 1.000 Extract File: ldwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10260.0000: STOP.FT 11537.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD. FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 22 TOWN.N 11N RANG. 14E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 68.05 DMF KB EKB .F 68.05 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted and are Tied-in to a Sperry Sun MWD, 25 March 1994. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Section from 10252' MD (8851' SSTVD) to 10383' MD (8787' SSTVD) was logged during a MAD pass to cover the sensor to bit offset from the original well drilling. Final Tie-in adjusts top MAD interval to 10261' MD. (5) Well 15-32A is an extension of the original well 15-32,and was kicked off @ 10365' MD (8787' SSTVD). 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration, Inc. 15-32A Prudhoe Bay Unit 2665.38' FNL, 3444.53' FEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 05-Nov-01 500292246201 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (6) Well 15-32A was drilled to 11535' MD (8851' SSTVD). The TD was adjusted to 11537' MD (8853' SSTVD) after the depth shifting to PDC. (7) The interval from 11517' MD (8849' SSTVD) to 11537' MD (8851' SSTVD) was not logged due to sensor to bit offset. (8) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS,07-11-2001). (9) A Magnetic Declination correction of 26.64 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA 1 18.97 ft. 2 18.67 ft. CURVE SHIFT DATA BASELINE, MEASURED, PAIRS=/ 10337.8, 10340.6, 10363.8, 10369.2, 10406.1, 10406.9, 10414.3, 10416.5, 10420.0, 10423.9, 10425.9, 10431.8, 10466.4, 10470.0, 10476.5, 10485.7, 10491. 3, 10506.2, 10514.2, 10529.9, 10533.7, 10535.8, 10545.5, 10573.1, 10578.5, 10591.1, 10595.0, 10678.8, 10696.7, 10706.1, 10711.8, 10784.5, 10790.1, 10803.3, 10847.6, 10861.3, 10867.0, 10890.4, 10915.0, 10918.6, 10965.2, 11009.4, 11041.2, 11067.5, 11119.3, 11123.4, 11139.6, 11146.9, 11153.4, 11167.9, 11171.4, 11179.2, 11204.0, 11207.8, 11228.1, 11240.7, 11246.4, ( 10346.3, 10349.3, 10372.1, 10377.2, 10412.4, 10414.0, 10421.2, 10423.6, 10425.9, 10429.5, 10432.5, 10436.9, 10473.9, 10476.3, 10483.6, 10492.9, 10499.9, 10513.9, 10521.0, 10533.8, 10538.1, 10542.0, 10553.6, 10579.5, 10585.4, 10599.4, 10603.2, 10687.1, 10704.1, 10715.7, 10720.6, 10793.0, 10796.4, 10808.6, 10853.6, 10866.5, 10870.0, 10893.1, 10920.1, 10923.8, 10971.7, 11013.7, 11043.6, 11069.7, 11125.2, 11127.8, 11145.8, 11152.6, 11158.5, 11173.5, 11178.5, 11185.6, 11208.2, 11213.6, 11231.3, 11243.4, 11250.4, ( DIRECTIONAL 23.43 ft. 23.13 ft. DISPLACEMENT 8.44629 8.74902 8.2959 7.99414 6.33496 7.08984 6.9375 7.08984 5.88281 5.58008 6.63672 5.12891 7.54102 6.30762 7.08984 7.24023 8.59668 7.69238 6.78711 3.9209 4.37402 6.18457 8.14453 6.48633 6.93848 8.2959 8.14453 8.2959 7.39062 9.65332 8.74902 8.44727 6.33496 5.2793 6.0332 5.12793 3.0166 2.71484 5.12793 5.12891 6.48633 4.37402 2.41309 2.2627 5.88184 4.37402 6.18457 5.73145 5.12793 5.58008 7.08887 6.33496 4.22363 5.88281 3.16797 2.71484 4.07227 t { 11257.1, 11263.5, 6.33496 11265.8, 11272.1, 6.33496 11269.7, 11276.4, 6.63672 11280.1, 11285.1, 4.97754 11291.6, 11297.9, 6.33496 11294.9, 11299.1, 4.22363 11297.9, 11303.3, 5.43066 11305.7, 11310.0, 4.22363 11319.8, 11324.2, 4.37402 11329.8, 11335.1, 5.2793 11334.1, 11340.7, 6.63672 11341.9, 11345.2, 3.31836 11433.8, 11436.8, 3.0166 11441. 8, 11443.6, 1.80957 11453.4, 11455.8, 2.41309 11469.1, 11472.1, 3.0166 11487.6, 11489.6, 1.96094 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 143 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration, Inc. 15-32A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 07-Nov-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX13 ROPS13 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 -1' I' ( ~I¡:' FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 31 Tape File Start Depth = 10260.000000 Tape File End Depth 11537.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 40 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS .MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration, Inc. 15-32A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO .MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] ('I Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 2 68 68 API F/HR 1 1 GRAX RaPS MWD MWD Total Data Records: 31 Tape File Start Depth = 10260.000000 Tape File End Depth = 11537.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 40 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/01/31 208288 01 **** REEL TRAILER **** MWD 02/01/31 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 13 2 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 10260.0000 10260.5000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 GR -999.2500 -999.2500 25.2060 62.4194 91.2049 148.0752 40.0814 33.2708 Rap -999.2500 -999.2500 -999.2500 -999.2500 24.9167 53.7589 71.3351 106.9270 I( 1 Size Length 4 4 4 4 ------- 8 {' ( 10900.0000 31.1100 94.5031 11000.0000 49.9473 39.1791 11100.0000 39.6048 119.9057 11200.0000 33.1797 79.5287 11300.0000 41.9990 95.3213 11400.0000 45.5098 135.1327 11500.0000 74.7390 26.1680 11537.0000 -999.2500 44.5580 Tape File Start Depth = 10260.000000 Tape File End Depth 11537.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 10260.0000 22.5790 -999.2500 10260.5000 22.8970 -999.2500 10300.0000 22.0580 -999.2500 10400.0000 66.5240 -999.2500 10500.0000 54.3800 25.7280 10600.0000 36.5820 16.5720 10700.0000 45.0160 67.9670 10800.0000 43.8860 105.8910 10900.0000 32.2600 85.7370 11000.0000 47.8740 66.8620 11100.0000 44.7250 123.2070 11200.0000 45.9850 87.4820 11300.0000 45.0400 102.5200 11400.0000 45.7590 135.0790 11500.0000 72.8150 87.3810 11537.0000 -999.2500 -999.2500 Tape File Start Depth = 10260.000000 Tape File End Depth 11537.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS