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Home My WebLink About202-161 ) Image Project Well History File Cover Page ') XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ;;¿O:J.... - J G L Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~can Needed I1111IIII111111111 RESCAN ~olor Items: ~reYSCale Items: 0 Poor Quality Originals: DI~AL DATA \.d'Diskettes, No. I 0 Other, NofType: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: BY: Helen ~ 0 Other:: 1 f I if) Date J 0 :Jif lilf Isl Vl1r , , 1111111111111111111 DatejÓ :J-Cf ~ Isl m~ I . BY: Helen (Maria) Project Proofing Scanning Preparation I x 30 =30 + ~() = TOTAL PAGES 6"7) (Count does 11. at íntilud.~ cover S¥7fk.. ) .. P. Date: 10 ~ b If Isl VVJ I i 1111111111111111111 BY: Helen (Maria 2- Production Scanning Stage 1 Page Count from Scanned File: ~t) J (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ 1 ' Helen l~vlar~ .) Date: II, i D D't Isl If NO in stage 1 page(s) discrepancies were found: YES NO NO BY: \4tP Stage 1 BY: Helen Maria Date: Isl Scanning is complete at this point unless rescanning is required. 1II1III111111111111 ReScanned 1111111111111111111 BY: Helen Maria Date: /sl Comments about this file: Quality Checked IIIII1I1I1111111111 8/24/2004 Well History File Cover Page.doc • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION D 0 3 Z009 WELL COMPLETION OR RECOMPLETION REPORT A si0n 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Plugged ® Abandoned ❑ Suspended 1b. We ass: 20AAC 25.105 20AAC 25.110 ® Development A 19 tory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/9/2009 202 -161 309 -302 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 09/01/2002 50- 029 - 20466 -02 -00 , a. Location of Well (Governmental Section): . Date T.D. Reached: !�. Well Name and Number: � Surface: 09/03/2002 PBU E -09B 243' FNL, 500' FEL, SEC. 06, T11 N, R1 4E, UM . KB (ft above MSL): 65.01' . Field / Pool(s): Top of Productive Horizon: 1020' FNL, 4480' FWL, SEC. 05, T11 N, R1 4E, UM GL (ft above MSL): 30.16' Prudhoe Bay Field / Prudhoe Bay Total Depth: Plug Back Depth (MD +TVD): Oil Pool 1663' FNL, 849' FWL, SEC. 04, T11 N, R14E, UM 12687' 8883' 4b. Location of Well (State Base Plane Coordinates, NAD 27): iq. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 664447 y- 5976820 Zone- ASP4 12725' 8883' ADL 028303 TPI: x- 669445 y- 5976154 Zone- ASP4 1M1 -.SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 671110 y- 5975550 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, CCL, Memory CNL 1 10680' 8747' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TvD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 0" Insulated Conduct r Surface 110' Surface 110' 36" 11.8 cu d Ar i et 13 - 3 / 8 " 7 2671' 71' 1- 7 r i t l -5/8" 47# L- Surface 10213' Surfa 8386' 12 -1/4" 14 ft Class'G' 130 cu Arctics t 7" 29# L- 717' 10558' 79 8' 8 -1 /2" 253 cu ft Class'G' 15# 1 1 784 1 8 747' 6 286 cu ft Cl ass'G' 3-1/2"x3-3/16'x2 / 6.2# i 6.16n 1 L-80 110103 8298' 1 8882' 1 3-3/4" 1140 cu ft Class ' ' 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#, L -80 9542' 9495'/ 7802' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD ) AMOUNT AND KIND OF MATERIAL USED 10613' Set Whipstock c� bo JZ i/• 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 (CORK): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewali Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None I -UDAIS 1 4) q Form 10-407 Revised 07/2009 CONTINUED O R E SUVA Original Only 29. GEOLOGIC MARKERS (List all formations and maW encountered): 30. RMATION 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. 21TS 10723' 8772' None Zone 1 B 10850' 8829' Zone 1 A 10960' 8873' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Terrie Hubble 1 Title: Drilling Technologist Date: PBU E -09B 202 -161 309 -302 Prepared ByName/Number. TerrieHi ble, 564 -4628 Well Number Permit No. /Approval No. Drilling Engineer: Cody Hinchman, 564 -4468 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 - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123 -00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only E -0913, Well History (Pre Rig Sidetrack) Date Summary 9/3/2009 WELL S/I ON ARRIVAL. RAN 2.70" x 20' DMY WHIPSTOCK, UNABLE TO GET P A SS ED 10,616' SLM. 9/4/2009 RAN 2.70" CENT., 2.50" S.BAILER, DRIFT TO 10,723' SLM, NO PROBLEMS. (empty). DRIFT W/ 2.70 x 10' DMY WHIPSTOCK, UNABLE TO PASS 10 616' SLM WELL LEFT S /I, PAD OP NOTIFIED. 9/21/2009 WELL SHUT IN ON ARRIVAL. INITIAL T /1 /0= 2400/300/0 SWAB, SSV, WING = CLOSED, MASTER OPEN, IA / OA = OTG. RIG UP ELINE TO SET BAKER WHIPSTOCK, COULD NOT SET WHIPSTOCK DUE TO BAD WPST. POOH AND TROUBLE SHOOT. AT SURFACE IT WAS REALIZED THAT THE WRONG WHIPSTOCK WAS RUN ON FIRST ATTEMPT. RIH WITH NEW CORRECT WHIPSTOCK AND NEW TOOL STRING. 9/22/2009 ATTEMPT TO SET BAKER WHIPSTOCK. DOWN HOLE MOTOR ISSUES PREVENT SUCCESSFUL ORIENTATION. POOH. MOTOR BEGINS WORKING AT 4,000'. CONT. POOH. WAIT 7 HOURS ON WIND TO RECOVER TOOL. DECIDE TO MAKE ANOTHER ATTEMPT. RUN BACK IN HOLE WITH SAME TOOL. AT SETTING DEPTH 10624 AND MOTOR IS WORKING FINE. STILL UNABLE TO GET TOOL ORIENTED DUE TO DOGLEG. PULL UP TO 10555 AND TOOL ORIENTS CORRECTLY. RIH TO SET DEPTH AND TOOL ROTATES OUT OF DESIRED ORIENTATION. CONTINUE TO WORK AT DIFFERENT SPEEDS, DEPTHS, AND ORIENTATION. 9/23/2009 CONTINUE TO TRY AND ORIENTATE WHIPSTOCK INTO POSITION, ABLE TO ORIENTATE TOOL ABOVE 10570', WHEN TOOL DROPS BELOW 10575 TOOL WILL FLOP PLUS OR MINUS 40 DEG. NOT ABLE TO SET OUTSIDE OF A 20 DEG WINDOW. POOH AND CHANGE TOOL STRING TO INCLUDE ADDITIONAL CENTRALIZER. RIH, TOWS SET AT 10619.7', 159.2 DEGREES RIGHT OF HIGH SIDE. DSO NOTIFIED OF VALVE POSITIONS. SWAB, SSV, WING = CLOSED, MASTER OPEN IA / OA = OTG. WELL SHUT IN ON DEPARTURE. FINAL T /I /O = 2400/320/0 JOB COMPLETE. 10/6/2009 T /1 /0= 2400/350/0. Pulled 4- 1/16" CIW H TWC # 278 thru tree, pre CTD. Torqued, pressure tested and serviced tree. Used 1 -2' ext. Tagged @ 106 ". No problems. 10/6/2009 T /1 /0= 2350/0/0 Set 4 1/16 TWC # 278 thru tree. Torqued all flanges to API specs. PTed all tree valves to 5k, all valves passed. SVC tree with 601. No problems. 10/18/2009 T /1 /0= 2360/350/0 MIT -TBG (Post CTD) Bled TBG pressure from 2360 psi to 1980 psi in 60 min. S/I and monitor. TBG came up from 1980 to 2000 in 30 min. Clean up, MO. Job canceled per PE. Pad -Op notified upon departure. FWHP's = 2010/350/0 SV, WV, SSV & MV = S /I, IA & OA = Open. 10/19/2009 T /1 /0= 2040/350/0. Temp= SI. Bleed TP to 0 psi (CTD). No wellhouse, F/L or AL. WV blinded. T FL @ 9553' (146 bbl). Bled TP to production using well E -102 from 2040 psi to 510 psi in 1.5 hr. Unable to monitor due to shift change. Final WHPs= 510/350/0. SV, WV, MV = C. SSV = O. IA, OA = OTG. NOVP. 10/20/2009 T /1/0= 510/350/vac. Temp =Sl. Bleed WHPs to 0 psi (CTD). No Well house, F/L or AL. WV blinded. T FL @ 9553'(146 bbls). Bled TP to tank from 510 psi to 5 psi in 4 hours (all gas). Monitored for 30 min, TP unchanged, T FL unchanged. Bled IAP from 350 psi to 0+ psi in 1.5 hours (all gas). Monitored for 30 min. IAP unchanged. Final WHPs =5/0+ /vac. SV, WV, MV = C. SSV = O. IA, OA = OTG. NOVP. 10/27/2009 T /1 /0= 1800/200/0 Temp = SI Load tubing/ MIT Inconclusive (CTD Prep complete) Test pressure increased due to high starting pressure per PE. TBG pressure up to 2800 psi with 3 bblls 60/40 and 50 bbls crude. T lost 100 psi in first 15 minutes and 50 psi in second 15 minutes. For a total of 200 psi in 30 minutes. Monitored additional 15 minutes and tbg lost 20 psi. Let sit for 30 minutes. Attempted to bleed down initially getting gas and swaping to fluid. Stopped bleeding leaving pressure on well per PE. FWHP's = 2600/200/0 VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV open, Master closed, IA open, OA open - Well SI. 10/30/2009 T /l /O = 2590/230/VAC. Temp = SI. Bleed TP to 500 psi (pre psi test packer and whipstock). No AL. Tbg FL ® 5882'(90 bbls). Bled TP from 2590 psi to 440 psi in 2 hrs 20 mins. IAP decreased 30 psi. Monitored for 30 mins. TP increased 90 psi & IAP increased 10 psi. Final WHPs = 530/210/VAC. SV, WV, MV = Closed (PO informed of MV position, MV flagged). SSV = Open. IA & OA = OTG. NOVP. Page 1 of 2 E -0913, Well History (Pre Rig Sidetrack) Date Summary 10/30/2009 T /1 /0= 10/220/10. Temp =Sl. TBG FL pre TP bleed (pre psi test packer and whipstock). Flowline disconnected. TBG FL incunclusive. Note: Rig scafold in place. SV, WV = closed. MV, SSV = open. IA, OA = OTG. NOVP. 10/31/2009 T /I /O = 920/230/Vac. Temp = SI. Bleed TP to 0 psi (for FB lube & bleed to psi test packer & whipstock). No AL, flowline or wellhouse. Rig scaffold on well. TP increased 390 psi to 920 psi since night shift bleed. TBG FL @ 5433'(83 bbis). Bled TP from 920 psi to 30 psi (to OT) in 3.5 hours (TP does not want to bleed down). During bleed IAP decreased 10 psi to 220 psi. Final TBG FL @ 5040' (TBG inflowed 393') (See log for details). Monitor for 30 min. TP increased 40 psi to 70 psi. FW HP's 70 /220/Vac. SV, WV, MV = C. SSV = O. IA, OA = OTG. NOVP. 11/1/2009 WELL S/I ON ARRIVAL. CURRENTLY RIGGING UP SWCP 4516 TO SET 3 -1/2" XXN PLUG @ 10,113' MD. 11/2/2009 T /I /O = 100 /240NAC. Temp= SI. WHPs (pre -CTD). No AL. Wellhouse & flowline have been removed. Drilling scaffolding on wellhead. OT tank on location. T FL @ 6500' (between Sta 2 & 3, 99 bbis). IA FL @ surface. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 11/2/2009 T /I /O = 110 /240NAC. Temp = SI. Bleed TP to 0 psi, then monitor every hour for BUR (pre -CTD). No AL. Tbg FL @ 6500' (between Sta #2 & #3, 100 bbls). Bled TP from 110 psi to 0 psi in 2 hrs 15 min. Monitored for a total of 4 hrs and TP increased 4 psi for an average of 1 psi /hr. Final WHPs = 4 /240NAC. SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. NOVP. 11/2/2009 BRUSHED 3 -1/2" XN NIPPLE @ 10,097' SLM (10,113' MD) W/ 3 -1/2" BLB, 2.70" G -RING. S 3 -1/2 XXN PLUG (4x3/16" -4x 1/8" ports, oal = 23 ") AT 10,097' SLM (10,113' MD). BLED TUBING FROM 900 PSI TO 70 PSI IN 6 HOURS (Holding solid on departure). WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS (T /IA/OA = 70/150/0). 11/5/2009 T /1 /0 = 0/160/0 Temp =Sl Assist Slickline, Load Tbg (CTD). Spot unit, currently standing by for slickline to rig up. 11/5/2009 T /1 /0= unknown. Bleed WHP's to 0 psi. (pre CTD). No AL. Tree has been preped fo rig, there is no platform or flowline on well. No Drilling scaffold to access tubing string. Snow removal in progress @ 16:00. Will need bleed tank to bleed tbg from last known tbg FL. 11/6/2009 Assist Slickline (CTD). Pumped 105 bbls crude down Tbg to load prior to slickline pulling plug. Pressured up Tbg with an additional 1 bbl crude post slickline pulling plug to verify Tbg fluid packed and whipstock in place. Bled pressure back, bled aprox 3 bbls crude. Final WHPs 0/250/0 Slickline on well at time of departure. 11/6/2009 WELL S/I ON ARRIVAL. LRS LOADED TUBING W/ 105 BBLS CRUDE. RAN 2.68" CENT, XX EQ PRONG TO 10,095' SLM (10,113' MD). PULLED 3 -1/2" XXN PLUG FROM 10,095' SLM (10,113' MD). LRS PRESSURE UP TBG TO 550 PSI AGAINST WHIPSTOCK AND HOLD FOR 10 MIN. BLED TBG & IA PRESSURE TO 0 PSI. WELL LEFT S /l, TURN OVER TO PAD OP. Page 2 of 2 BP EXPLORATION Page 1 a=!- Operations Summary Report Legal Well Name: E -09 Common Well Name: E -09 Spud Date: 5/4/1980 Event Name: REENTER +COMPLETE Start: 11/7/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/7/2009 13:30 - 00:00 10.50 MOB P PRE MOVE RIG FROM DS 18 -11A TO E -09C 11/8/2009 00:00 - 00:30 0.50 MOB P PRE MOVE RIG FROM 18 -11A TO E -09C 00:30 - 16:30 16.00 MOB N PRE TIRE RUPTURED ON THE DRILLER'S SIDE REAR, INNER TIRE. RIG IS LOCATED ON K PAD ROAD 300 YARDS FROM THE E PAD ENTRANCE. C/O TIRE. C/O STEERING LINK BUSHING. WARM UP DRIVE SYSTEM 16:30 - 19:30 3.00 MOB N PRE WAIT ON SECURITY. 19:30 - 20:30 1.00 MOB N PRE SAFETY MEETING, RE: MOVE TO E- PAD COMPLETE MOVE TO E -PAD & LINE UP ON THE WELL SAFETY MEETING, RE: MOVE OVER THE WELL BACK OVER THE WELL 20:30 - 00:00 3.50 RIGU N PRE ..,.... "ACCEPT RIG @ 20:30 " * *. SPOT CUTTING BOX, SPOT SAT CAMP, SPOT TIGER TANK & RU HARDLINE, NU BOP 11/9/2009 00:00 - 01:00 1.00 BOPSUF P PRE NU BOP. REBUILD BOP KILL LINE VALVE 01:00 - 08:30 7.50 BOPSUF P PRE PRESSURE TEST BOPE. WITNESS WAIVED BY BOB NOBEL, AOGCC TEST VALVES TO 3500 PSI, ANNULAR TO 2500 PSI. 08:30 - 14:45 6.25 STWHIP P WEXIT CIRCULATE MEOH FROM CT. RU AND PUMP SLACK INTO CT.@ 2.7 bpm 4600 psi. CUT 330" OF CT. INSTALL CTC & PULL TEST TO 30k. Head up Baker. 14:45 - 15:00 0.25 RIGU P PRE PJSM FOR PICKING UP OF LUBRICATOR AND PULLING BPV. 15:00 -16:15 1.25 RIGU P PRE PU LUBRICATOR. TEST LUBRICATOR TO 1000 PSI. PULL BPV. CLOSE MASTER. LD LUBRICATOR 16:15 -16:40 0.42 STWHIP P WEXIT SAFETY MEETING, RE: PU MILLING BHA 16:40 - 18:00 1.33 STWHIP P WEXIT PU WINDOW MILLING BHA W/ COIL TRAK, 2 -1/8" EXTREME MOTOR, 2.74" DIAMOND STRING MILL, & 2.74" WINDOW MILL. OAL= 47.65' OPEN EDC, PUMP 1.5 BPM FOR 40 BBLS TO PUMP SLACK FORWARD. 18:00 - 19:30 1.50 STWHIP P WEXIT RIH TO 6180' 19:30 - 20:15 0.75 STWHIP N HMAN WEXIT POH FOR 2.7" SPIRAL CENTRALIZER & 2 JTS 2 -1/6" CSH 20:15 - 20:30 0.25 STWHIP N HMAN WEXIT SAFETY MEETING, RE: BHA CHANGE 20:30 - 21:30 1.00 STWHIP N HMAN WEXIT L/D COILTRAK PU 2.7" SPIRAL CENTRALIZER & 2 JTS 2- 1/16" CSH PU COILTRAK 21:30 - 22:40 1.17 STWHIP N HMAN WEXIT RIH WINDOW MILLING BHA TO 6180'. 22:40 - 23:30 0.83 STWHIP P WEXIT RIH 23:30 - 00:00 0.50 STWHIP P WEXIT LOG TIE -IN 11/10/2009 00:00 - 00:20 0.33 STWHIP P WEXIT LOG TIE -IN, -9' CORRECTION 5AeCA RIH, DRY TAG TOWS @ 10610', PU 20', 09cc FS = 2330 PSI @ 1.61 BPM BEGIN TIME MILLING 01:00 - 02:10 1.17 STWHIP P WEXIT GAS IN THE RETURNS PUH, OPEN EDC, CIRCULATE OUT GAS @ 2.2 BPM. PUMP 140 BBL TO CLEAN UP GAS (120 BBL CALC. HOLE VOL) Printed: 11/19/2009 11:37:31 AM TREE _ 4" 5M C1W WELLHEAD = 13 -5/8" MCEVOY SAFET ES: >70 @ 10955' ACTUATOR = BAKER E ®p C KB. ELEV = 65.01' \ BF. ELEV = 30.76' KOP= 10680' DRLG DRAFT Max Angle = 95 @13075' 2083' 4 -1/2" OTIS SSSV NIP, ID = 3.813" Datum MD = 10939' Datum TV D = 8800' SS 2620' 9 -5/8" DV PKR 13 -3/8" CSG,72 #, L -80, ID = 12.347" 2671' GAS LIFT MANDRELS STI MD I TVD DEV !ME E VLV LATCH PORT DATE Minimum ID = `1. " �� 3 1 4384 1 419 8 36 R DMY RM 0 06/12/07 2 8264 6805 44 R DMY RM 0 06/12/07 SELIT BUSHING MILLED OUT 1 9413 7671 37 R DMY RA 0 09/08/02 9452 2-318" DEPLOYMENT SLV, ID = 3.00" 9483 4 -1 /2" OTIS X NIP, ID = 3.813" 9495 4 -1/2" TM/ HBBP PKR, ID = 4.32" 9519 4 -1/2" OTIS X NIP, ID = 3.813" 9530 4 -1/2" OTIS XN NIP, ID = 3.80" (MILLED 08/29/02) 4 -1/2" TBG, 12.6 #, L-80_0152 bpf, ID = 3.953" 9542' 9542' 4 1!2" WLEG, ID = 3.958" TOP OF 5" LNR 9553 ELMD TT NOT LOGGED TOP OFT ' LNR 9717' 9 -5/8" CSG, 47 #, L -80, ID = 8.68" 10213' 10103 4" BKR DEPLOYMENT SLV, ID = 3.00" 3 -1/2" LNR, 8.81 #, L-80,.0087 bpf, ID = 2.992" 10608' 10113' 3 1/2" HES XN NIP, ID = 2.750" MILL OUT WINDOW 10558'- 10569' 7" LNR, 29 #, L-80,.0371 bpf, ID = 6.184" 10569' i 3- 3/16" mnobore w hipstock 10613' MILL OUT WINDOW 10607'- 10612' F ;ToTwINDOW 10681'- 10688' 10608' 3 -1/2" X 3- 1/16" XO, ID = 2.800" 5" LNR, 15 #, 13 -CR, .0188 bpf, ID = 4.408" 10688` PERFORATION SUMMARY REF LOG: MEM GR/CCL /MNCL ON 11/21/09 P s 9L A NGLE AT TOP PERF: 90 @ 11450' 1 f Qzke✓ Note: Refer to Production DB for historical perf data Q / y -! /- p SIZE SPF INTERVAL Opn /Sqz DATE 1.56 6 11450 - 11630 O 11/21109 1.56 6 11810- 12020 O 11/21/09 1.56 6 12160 - 12280 O 11/21/09 1.56 6 12400 - 12860 O 11/21/09 1.56 6 12900 - 12960 O 11121/09 PBTD 13202' 1.56 6 13050 - 13190 O 11/21/09 2 -3/8" LNR, 4.7 #, L -80, .0039bpf, ID = 1.99" 1 13217' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/80 ORIGINAL COMPLETION WELL: E -09C 01/13/95 DFF SIDETRACK(E -09A) PERMIT No: 09/08/02 DAC /KK CTD SIDETRACK (E -09B) API No: 50- 029 - 20466 -03 11/22109 NORDIC1 CTD SIDETRACK (E -09C) SEC 6, T11 N, R14E, 243.18' FNL & 500.01' FEL 11/25/09 1 SV DRLG HO CORRECTIONS BP Exploration (Alaska) • • ~h~ ~ - ~ ~ ~ ~` ~;,~.~. ~ ~~~~ ~._ ~~ ,~_~~ ~.~,~; ~~ ~` ~ ~ _ ~ SEAN PARNELL, GOVERNOR - ~ ~~ ~ ~ ~ ~ ra~t~-7~ ~~ t'~1ty Vra47 333 W. 7th AVENUE, SUITE 100 COlYSERQATIOlY COAII-'IIS5141~T ANCHORAGE, ALASKA 99501-35 ~ PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-09B 1~ t Sundry Number: 309-302 , ~ ~~ y a 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ 1~ Chair DATED this ~ day of September 2009 ~: ~~=;~~~~,; :~G_ ~'~~s~? Encl. y.,. ~ t~ ~ " ~ `4 ~ 4`" , ~k d~.~ c ,^'` ~~.~ d r~ STATE OF ALASKA ~- ~~e~~~' ~~~ ALA~OIL AND GAS CONSERVATION COMII~ION ~~ ,-; 9''~ ~ APPLICATION FOR SUNDRY APPROVAL " k'_` .:- 20 AAC 25280 1. Type of Request: ~ Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension `: ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. .~ Development ^ Exploratory 202-161 3. Address ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20466-02-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU E-09B - Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028303 65.01 Prudhoe Bay Field / Prudhoe Bay Oil Pool 12~ PRESENT WELL CONDITION SlJM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12725 - 8883 12687 - 8883- None Unknown in n h iz M u C I Structur I n 1' 2"x ' 11' 110' Surfa 2671' 1-3/8" 2671' 2671' 4930 2 7 Intermediate 1 1' -/" 1 1' 3' 6 7 47 in r 841' 7" 9717' - 1 798 '- 8 5' 7240 5410 Lin r 1127' 5" 5 3' - 1 6 0' 7849' - 8747' 290 7250 i er 2' " -7/ " 1 1 3' - 1 725' - 8' 1 1 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11590' - 12680' 8912' - 8883' 4-1/2", 12.6# L-80 9542' Packers and SSSV Type: 4-1/2" TIW HBBP packer Packers and SSSV MD (ft): 9495' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for _f 16. Well Status after proposed work: Commencin O erations: September 15, 2009 ,, ~ Oil - ^ Gas ^ Plugged IJ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Cody Hinchman, 56a-a468 Printed Name Jo ull ~ Title Engineering Team Leader ~ Prepared By Name/Number Signature ~~ ~-~ Phone 564-4711 Date~ ~ ~'~ ~' Sondra Stewman, 564-4750 Commission Use Onl ~-~' Sundry Number:~~ ~ Conditions of approvat: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form quired: 1 ~ ~- !' '~~ ; -~ APPROVED BY ~ ~ ~ A roved B. COMMISSIONER THE COMMISSION Date Form 10-403 Revise 06/2006 Submit In Duplicate ORIGINAL ~~- ~~~~~:~ w ~~~i~o~ • • To: Tom Maunder Petroleum Engineer ~~ Alaska Oil & Gas Conservation Commission From: Cody Hinchman CTD Engineer Date: August 25, 2009 Re: E-09C Sundry Approval Sundry approval is requested to abandon all perforations on well E-096 prior to a CTD sidetrack. Due to high GOR, well E-09B has had no significant on-time since 2005. Well History: E-09B was drilled as a horizontal CST in the western area of K-pad targeting the Z1 AB sands. The well was completed in December 2002 and was twinned with E-08A, which was sidetracked at the same time. It was expected that these two wells would be similar in rates and pressures and that they could flow together. E-09B " could not compete and was shut in to allow the twin to produce in HP. The well under performed compared to what was expected. It was thought that this might have been a result of the well having an excessively long shut-in time post drilling. An acid stimulation job was completed in October . 2003 in an attempt to clean up any flow pro or drilling fluids that never had a chance to flow. No appreciable difference was noticed in the production. In May 2004, 140' of Z1A add perfs were shot in an attempt to increase production rates. These perforations proved to be ineffective and added little vafue. In May 2005, 35' of end of life Z1 B add perfs were shot in the _ heel of the well to access any remaining value. These perforations provided a brief oil buzz but quickly declined to the wells normal rates within a one month period. At the wells most recent production rates, the GOR is well above marginal allowing no on-time for the well. In June 2007, the well was CTD screened. A slickline drift with a roller stem made it to 11,124' SLM with no problems and an empty sample bailer. While pulling station #2 at 8,264' MD, three kick springs were noted to be lost downhole. Their depth and location are unknown. A caliper on 6/11/07 found all tubulars in good condition with no significant wall penetrations. On 6/12/07, an MIT-OA passed to 2000 psi and an MIT-IA passed to 3000 psi. In June 2009, the well received another CTD screen. It passed an MIT-T to 3000 psi, an MIT-IA to 3000 psi, and an MIT-OA to 2000 psi. A PPPOT-T passed to 5000 psi and a PPPOT-IC passed to 3500 psi. A slickline drift reached 10,965' SLM and attempted to fish the three kick springs left in the hole. They were unsuccessful and . never encountered the kick springs. On their final run in hole, a swage was run to deviation too ensure the kick springs were pushed below the kick off point for the sidetrack. To determine whether or not this would be a tiny tools ST, an SCMT was run on 7/2/09. It found the cement up to the liner top at approximately 10,130' MD, eliminating the possibilities of a big coil ST. Reason for Sundry: The sands encountered in E-09B were poorer than anticipated along the wellpath which resulted in an exceedingly thin target zone. All producible sands have been accessed up to 25' tvd below the GOC identified at 8,775' tvd in 2002. At current operating conditions the well is uncompetitive and has had no significant on-time since 2005 due to high GOR. With gas so close to open perforations and no available gas shut off options it has - been determined that this well is ready for sidetrack. Pre-Rig Work Summary: (The pre CTD work is slated to begin about September 15, 2009.) L~1~~ 1. PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi ~ ~ Ca 2. Function LDS 3. 4. PPPOT-T Dummy all GLM's ~ j~~ 5. Drift with Baker dummy 3-3/16" WS and tag cross-over at 10~36'. 7 ~ " ' ~~~~ 6. ~e ~- . Tts~l- ~~ Set Baker 3 3/16 Packer WS with top at 10624 7. MIT-IA to 3000 psi, OA to 2000 psi. 8. Set BPV 9. Bleed T, IA, gas lift and production flowlines down to zero and blind flange. 10. Remove S-Riser, Remove wellhouse, level pad. ! ~ Rig Sidetrack Operations: (Scheduled to begin on November 15, 2009 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Pull BPV. 4. Mill a 2.74" window at 10624'. 5. Drill build/turn section of the E-09C lateral with 2.70"x3.0" bicenter bit and land well. 6. Drill lateral section to 13,300' MD. 7. Run and cement a 2-3/8" L-80 solid liner string. 8. Make a cleanout run with mill and motor. 9. Make a logging run with a SWS GR-CNL logging tool. 10. Make a perforating run with 1.56" OD perf guns. 11. Set LTP if needed. 12. Circulate well to KWF brine. FP well to 2000' with diesel. 13. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well Cody Hinchman CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble ~ ~ r; = . ~T kQ 71/D OE71/ 7'YP~ 1/l.jf 11w7~#i Ii~T ~+l'IE 2 1 ffi84 94/3 89E16 '7!B74 ~4 37 A~6t ~t D`ift DAY' tdul iil4 d 12A!}T tF 91~1910Z 1:2HM, D~ 3.96~ P t3F5' I.I+ff# P~F7'12+R ~ ~ ~..._~___~.~..---~~~~~,_--, ~' ~519' 4.1f1' 7~Mlt}I~ RCR ~= i AEI~ b~ill'M~XFt~,D•3.84~' 'g53p' dv4d~' 9~ ~ @~!. IDa 9.8ti. {~iIL~DR1~9/t!'l) ~SAf~I'P' t~It7iE ~~{'j' -f~?tA1dE~~~9.~8' 1T N[Xf LOdf~ ~ !4IX ~ {tiBdt2K ~GROEROYlY~ETSCi/, ~ ~~.tIQ' ~3~t,~1" tl~ B.~iN. l..BQ, A~O7 d{#, ~= 29~!" a'uat, 2~ Ga~ os7f bpr, r-$s_~sar ~' LFIF~ 1.~iil,1~CR. A188hp~, ~adAtfB" 1 9553' I 71[lM~~lAR1( F~ L4C~t II~tC~~DOJ~. {~N49-Q~'~IFI2 AJ~t~E ATTOP F~E3~ 8Fi ~ it1997" NiStlt~ I~tfeltloPtad~n~ ~ fiar h~foiirs~i tx~td sl~Bs r a c~ar ~ esryaa t. ~ttFrtta ? $ 108~}-t!~T9 (7 E4Fd3t~0~ ~ +i t 19~ft • t 1~09tF O (C5~J44 i' 4 t i1iffi - 44t9t} O dl6F~n10 2 d 4 f21EF - t 123C- {} FL~~'I!!4d ~' +1 1 t923 - f 13~ tI f~lTl~t10 ~ a ~ ~s~aa = t i~m ~ c~~-r~a ~ a ~ aoeu ~ ~z~au o c~xnx-a ?' +I t?bl#~ a f~~fF {7 SiB~ftlT~62 Y~IC~T~"`~'" ~L~~ ~ ~08l19~~G9 - X ~~ ~ 95t ~' ~lk~4A{i~D ~NC`a ~90~ ~~~~~ ~ ~ ~A ~LIl~JG Tl[S~tS - YI~.L Nflf N(}~I? ~ w tPV~U~ SEl' - ~IIfC3' det;P~" F~'~Ilf[Y SfiSSf t~ iO~ a~,a i~• 3~3l18' WRB~'iR. L,8F4, .~DTB Mf. D= 2.86tP .$ CY4iE ~f 81t G~O~R~TS O~t7~ i~Y BY ~dii~t~'S IffiJd~ ~IJ~LCA7W Ogi2T~i17 fiCT7~S'k/ s'~9~E~ l?9Kf O4kE~,3 ~ C!C ~09A C O~B127d(~ 6~YTLt~1 ~PI.Ed4-(~.t~ ~aoaa~oa ~-~~ac e~as~cx~~o~ us~,m n~ ~~ru~v 5fi27•29dUd AQ~F3~S [k5~'11d05 Yli~~fF~IC lt~l~lS 08~I227JOT 08 i~l1LF! f~1f~CK} Ofl~42-tf1 S~H 111$lt8' ~--~-Yl2'X~t/t18*3~(t3.Da2Sittf' MLL illFf !1l~~i1t 1SI8$t' =11f1iB8B r 2lii' BAIt lf~lT it~it: tsEl~ P~iklr tJ~: ~EF2f dt#F AF1N~: SU-~Fl9~3dM88-fF! ~ 8,1'! ttf, itt~€, Zd3_t8" l~1L8 fifltlQt"F~ ~ 6oplor~Yt.int~ [~~ka} ~ ~ Page 1 of 1 Schwartz, Guy L (DOA) From: Hinchman, Cody [Cody.Hinchman@bp.com] Sent: Thursday, September 03, 2009 12:53 PM To: Schwartz, Guy L (DOA) Subject: RE: E-098 P& A(PTD 202-161) Guy, I would like to verify that the Whipstock/Packer combo will be pressure tested to 2000 psi in order to isolate the perfs, prior to the E-09C CTD sidetrack. The projected path of E-09C will have a close approach to the K-19A wellbore (119' Ctr - Ctr). The K-19A wellbore wi!! cross the E-09 wellbore at a measured depth of 11,575' in K-19A. All perforations below 10,960' MD in well K-19A are currently isolated by a CIBP. Due to the CIBP the HSE risk of ~n intersection af the two wellbores is minimal. I apologize this was not mentioned in the P& A sundry request and that t was not able to answer your questions right away. This is my first well as a new challenger here and I am working under the gu+dance of Greg Sarber. Cody Hinchman CTD Drilling Engineer BPXA Office: 907-564-446$ Cell: 303-319-5472 Cody.Hinchman@bp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, September 03, 2009 10:49 AM To: Hinchman, Cody Cc: Maunder, Thomas E (DOA) Subject: E-09B P& A(PTD 202-161) Cody, t was reviewing the P& A sundry request for E-096 and see we are using a Whipstock/Packer combo to isolate the perfs and set up for the CTD sidetrack. You do not rnention pressure testing the WS/packer in the procedure. Can you verify that this will be done and to what pressure?? A state witnessed test won't be required assuming the packer/whipstock holds as the liner will be fully cemented above this anyway. Also, in reviewing the Anti-collision data I saw that K-19A wellbore comes very close (115' Ctr-Ctr) to the projected path of E-09C. Looking at the Traveling cylinder though it looks even closer.... 24 feet !!! Am I reading this carrectly??? Is this wellbore abandoned already?? Any mitigation concerns? Thanks in advance, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 9/3/2009 o~i2oios SC~l~b~t'g~ , , ~ ~ ~~~~~ ~~-ys Alaska Data & Consultin Services 9 .~r,~5,; Company: State of Alaska 2525 Gambell Street, Suite 400 ; ~~ ~` ~ ?_ _~ ~.. ,; - Alaska Oil & Gas Cons Comm Anchorage,AK 99503-2838 ~ ~~4~ ~""'" ~ Attn: ChristinenAahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 4-04A/T-30 AYTO-00023 PRODUCTION PROFILE O6/30/09 1 1 L3-31 AXBD-00030 MEM INJECTION PROFILE / 07/01/09 1 1 G-31 B ANHY-00100 LDL ( 07/07/09 1 1 Z-32BL7 AV1H-00018 SBHP RVEY 07/02/09 1 1 14-10 AY3J-00033 PRODUCTION PROFILE (~ d 07/01/09 1 y A-20 AV1H-00021 SBHP SURVEY - 07/07/09 1 1 01-30 AY3J-00034 LDL 07/04/09 1 1 M-26A BOCV-00021 PRODU TION LOG 07/1y09 1 1 06-23C AXBD-00031 MEMORY PROD PROFILE - 07/03/09 1 1 L3-31 BOCV-00019 PRODUCTION LOG (~, - 07/09/09 1 1 L2-20 AYKP-00031 LDL / 07/10/09 1 1 E-09B B04C-00064 SCMT • - 07/01/09 1 1 04-33 QY3J-00036 USlT ( p7/Q7/ag ~ ' WGI-07 BOCV-00020 USIT 07/11/09 1 1 1-31/M-21 B14B-00063 PRODUCTION PROFIL~- O6/16/09 1 1 ~ L3-02 AZCM-00028 RST ~ 06/15/09 1 1 1-31/M-21 814B-00063 RST ' 06/17/09 1 1 18-18B ANHY-00097 RST a- 06/09/09 1 9 ~I CACC Al~Il1JA\ll/1 C~1/~C f1C f~CI~1T ~V G~IA~~~ ~~~ ~ "' ~~~~.~ "~~~.. . ~ . ~..w.....v ~..v ~ ~r ~ v~ ~~~~~~~a v~~~ vvr ~ G./'~v1 ~ ~ V. BP Expioration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. ,,~~.,~-~-_~ `.` 1~,.•~ _% Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm _ Marker. doc ) STATE OF ALASKA ) RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO;JS I 2 2005' 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ŒJ ExploratoryD Stimulat~'ðka Oil & G.as ConS.~A~sion . 0 AnfhoranA. 0 Waiver Ime "Btmnslon Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1610 6. API Number 50-029-20466-02-00 1 . Operations Performed: Abandon D Alter CasingD Change Approved Program 0 Repair Well 0 PluQ PerforationsD Pull Tubing D Perforate New PoolD Operation Shutdown D Perforate [KJ P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 65.01 8. Property Designation: ADL-028303 11. Present Well Condition Summary: Stratigraphic 0 Service 0 9. Well Name and Number: E-09B 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 12725 feet true vertical 8882.4 feet Effective Depth measured 12687 feet true vertical 8882.8 feet Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 35 115 35.0 115.0 1490 470 SURFACE 2637 13-3/8" 72# L-80 34 - 2671 34.0 - 2670.9 4930 2670 PRODUCTION 10180 9-5/8" 47# L-80 33 - 10213 33.0 - 8386.5 6870 4760 LINER 964 7" 29# L-80 9717 . 10681 7983.4 - 8747.4 8160 7020 LINER 1128 5" 15# 13CR80 9553 - 10681 7849.4 - 8747.4 8290 7250 LINER 505 3-1/2" 8.81# L-80 10103 - 10608 8297.8 - 8696.4 9840 9760 LINER 128 3-3/16" 6.2# L-80 10608 - 10736 8696.4 - 8779.2 LINER 1989 2-7/8" 6.16# L-80 10736 - 12725 8779.2 - 8882.4 11820 11270 Measured depth: 10937-10952,10959-10979,11040-11090, 11165-11190, 11210-11235, 11323-11363, 11590-11970,12060-12360, 12570-12680 True vertical depth: 8864-8870, 8873-8880, 8901-8914, 8921-8921, 8920-8920, 8919-8918, 8912-8886, 8882-8873, 8877-8883 TubinQ ( size, qrade, and measured depth): 4-1/2" 12.6# L-80 @ 31 ,S(~~ÑNEDI JUt 1 ~]; 2005 Packers & SSSV (type & measured depth): 9-5/8" DV Packer 4-1/2" TIW HBBP Packer 4-1/2" Otis SSV Nipple @ 2620 @ 9495 @ 2083 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft JUL I 3 2005 13 Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN 0 0 Subsequent to operation: 1056 20010 13 0 1074 14. Attachments: ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD Development Œl Service D Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne Schnorr Printed Name _ ~dne ~~~n:,rr ~ D f) Signature "1/Jt..I'~~--- ~~ Title Petroleum Engineer Phone 564-5174 Date 7/8/05 Form 10-404 Revised 4/2004 ('" ~ ii ::.~") ¡ (-. ¡ ì\ I ~' 1 ~ ! ····1 " I \ 1 ¡I,.. .,j,.'~" - ) ') E-098 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/15/05 ***WELL WAS SHUT-IN UPON ARRIVAL***. TAG @ 11060' SLM. WITH 2 1/8" DUMMY GUN. STOPPED DUE TO DEVIATION.. ***WELL LEFT SHUT-IN***. ***TURN WELL OVER TO DSO*** OS/21/05 PERFORATED FROM 10937' - 10952' AND 109591 - 10979' USING 2" HSD 2006 PJ HMX GUNS. SAT DOWN DUE TO DEVIATION AT 11,080 ON LAST PASS. WELL LEFT SHUT IN. *** JOB COMPLETE *** FLUIDS PUMPED BBLS o NO FLUIDS PUMPED o TOTAL Page 1 TREE = 4" 5M CrN WELLHEAD = 13-5/8" MCEVOY A CTUA TOR = SA KER kï3·.~·EL§j·";"""· ,. '''''" ,,0 '0" ",.." ""65'~'Ö'1'~' SF. ELEV = 30.76' KOP = " , '1Ó6sÖi Max Angle = 97 @11711' bïiiiUmMÖ';;';" ".. .... .... .. '10939; .....NW~·...· Datum TVD = 8800' SS ) E-09B e - - ~ .., 113-3/8" CSG,72#, L-80, ID = 12.347" l-i 2671' ~ Minimum ID = 2.372" @ 10737' TOP OF 2-7/8" TUBING L I I Z Z ~ ~ 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.953" l-i I TOP OF 5" LNR l-i I TOP OF 7" LNR l-i 9542' 9553' I -.,"" - 9717' I I 9-5/8" CSG, 47#, L-80, ID = 8.68" l-i 10213' ~ g '1 ~ ~ 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.992" l-i 10608' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" l-i 10898' 15" LNR, 15#, 13-CR, .0188 bpf, ID=4.408" l-i 11995' SI ')v NOTES: 5" CHROME LNR 2083' 1-i4-1/2" OTIS SSSV NIP, ID = 3.813" 1 2620' 1-19-5/8" DV PKR 1 ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH 3 4384 4198 36 MER DOME RA 2 8264 6805 44 MER SO RA 1 9413 7671 37 MER DMY RA PORT DATE 16 09/13/02 20 09/13/02 o 09/08/02 9483' 1-i4-1/2" OTIS X NIP, ID = 3.813" 1 9495' 1-14-1/2" TrN HSSP PKR, ID = 4.32" I 9519' 1-i4-1/2" OTIS X NIP, ID = 3.813" 1 9530' 1-i4-1/2" OTIS XN NIP, ID = 3.725" 1 9542' 1-i4-1/2" WLEG, ID = 3.958" I l-i ELMD TT NOT LOGGED I 10103' 1-i4" BKR DEPLOYMENT SLV, ID = 3.00" 10113' 1-13-1/2" HES XN NIP, ID = 2.750" 1 10608' l-i 3-1/2" x 3-1/16" XO, 10 = 2.800" 1 MILL OUT WINDOW 10681' - 10688' l-i 3-3/16" X 2-7/8" XO, ID = 2.380" 1 PBTD l-i 12687' I ÆRFORA TION SUMMARY REF LOG: MEM GR/CCL/MNCL ON 09/07/02 ANGLE AT TOP PERF: 65 @ 10937' 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" l-i 10735' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I--{ 12725' SEE PAGE 2 DATE 05/80 01/13/95 09/08/02 10/07/02 09/17/03 10/13/03 REV BY COMMENTS ORIGINAL COM PLETION DFF SIDETRACK (E-09A) DAC/KK CTD SIDETRACK (E-09B) THlKA K PERF CORRECTION CMO/TLP DATUM MD CORRECTION A NY /TLP TOP PERF CORRECTION DA TE REV SY COMMENTS 02/04/04 CMO/TLP PERF CORRECTION 5/27-28/0L SJMcN/KK ADEPRFS OS/21/05 WJHlPJC PERFORATIONS PRUDHOE SA Y UNIT WELL: E-09B PERMIT No: "2021610 API No: 50-029-20466-02 SEC 6, T11 N, R14E, 243.18' FNL & 500.01' FEL BP Exploration (Alaska) TREE = 4" 5M CrN WELLHEAD = 13-5/8" MCEVOY ACTUATOR = SAKER "KffËLE\ï;;'" , , , '" "'" '" 65:01; SF. ELÊV"~~--" 30,76' kÖp'~'''''' " '" ,,', ",,, '1Ò6ä6~ Max A'r;'gie = 97 '@1"1'71F 'ÖaÚÚnMÖ~' "" " "" '1'6939; Datum TV D = ~-88öÓ"sS ") E-09B SA' 'y NOTES: 5" CHROME LNR ) (I) - - - - ~ ~ Minimum ID = 2.372" @ 10737' TOP OF 2-7/8" TUBING L I Z I Z ~ ~ PERFORA TION SUMMA RY REF LOG: MEM GR/CCL/MNCL ON 09/07/02 A NGLE AT TOP PERF: 65 @ 10937' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 10937 - 10952 0 OS/21/05 2" 6 10959 - 10979 0 OS/21/05 2" 4 11040 - 11090 0 OS/28/04 2" 4 11165 - 11190 0 OS/28/04 2" 4 11210-11235 0 OS/27/04 2" 4 11323 - 11363 0 OS/27/04 2" 4 11590 - 11970 0 09/07/02 2" 4 12060 - 12360 0 09/07/02 2" 4 12570 - 12680 0 09/07/02 I I I .41 ,~ .. ~ ~ Ii. DATE 05/80 01/13/95 09/08/02 10/07/02 09/17/03 10/13/03 REV BY COMMENTS ORIGINAL COMPLETION DFF SIDETRACK (E-09A) DAC/KK CTD SIDETRACK (E-09B) THlKA K PERF CORRECTION CMO/TLP DATUM MD CORRECTION A NY /TLP TOP PERF CORRECTION OA TE REV BY COMMENTS 02/04/04 CMO/TLP PERF CORRECTION 5/27-28/0L BJMcN/KK ADEPRFS OS/21/05 WJHlPJC PERFORATIONS PRUDHOE SA Y UNIT WELL: E-09B PERMrr No: "2021610 API No: 50-029-20466-02 SEC 6, T11N, R14E, 243.18' FNL & 500.01' FEL BP Exploration (Alaska) (j D ~ ÀJJÇZ)~' DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021610 Well Name/No. PRUDHOE BAY UNIT E-09B Operator BP EXPLORATION (ALASKA) INC f¡{~d;o-~~o~~ MD 12725 ~-----//TVD 8882 ,/ Completion Date 9/812002 ~/~/ Completion Status 1-01l Current Status 1-01l UIC N REQUIRED INFORMATION Mud log No Samples No Directional surve~e~i '---. =>- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset !1P~_~~rmt Number Name ~-. LIS Verification c.er--ø..---- ~Survey" ~ MWD, GR, CCl, Memory CNl (data taken from logs Portion of Master Well Data Maint) Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments 10395 12681 Case 3/17/2003 10563 12725 Open 10/2/2002 1 0563 12725 Open 10/2/2002 ~ Directional Survey A Directional Survey log is required to be submitted. This record automatically created from Permit to Drill Module on: 8/1/2002. An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 8/1/2002. c~og- G-j\,eutron Blu 9980 12674 Case 1/10/2003 ..-/ G v?-./ K- 0 y; 12681 ~17/2003 ....-EO D ff635 -kID 'v<eriflcation'. -- 10395 ~. ~sing collar locator Blu 9980 12674 Case 1/10/2003 '~ ~ ¿)3amma Ray Blu 9980 12674 Case 1/10/2003 ~ 11472 Neutron 1 9980 12674 Case 1/10/2003 ~ C Ase tOO7 LIS Verification 1,2 10412 12725 Open 6/2/2003 C Pdf 2007 Rate of Penetration 25 Final 10692 12725 Open 6/2/2003 MWD-ROP, DGR - MD LED C Pdf 2007 Gamma Ray 25 Final 10692 8817 Open 6/2/2003 MWD- DGR - TVD --------- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permitto Drill 2021610 MD 12725 TVD 8882 Well Cored? ADDITIONAL INFORMATION y&J Chips Received? ~ Analysis Received? ~.._--~~ Comments: ---- YIN Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Well Name/No. PRUDHOE BAY UNIT E-09B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20466-02-00 Completion Date 9/8/2002 Completion Status 1-01L Daily History Received? Formation Tops ! l-o Current Status 1-01L ~N t!YN Date: UIC N ~. JV1 O~~i '~ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 65.01 8. Property Designation: ADL-0028303 11. Present Well Condition Summary: Total Depth Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate I!J 4. Current Well Class: Stimulate 0 OtherO WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1610 Development Œ:I Stratigraphic D 9. Well Name and Number: E-09B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D 6. API Number 50-029-20466-02-00 measured 12725 feet Plugs (measured) None Effective Depth true vertical 8882.4 feet Junk (measured) None measured 12687 feet true vertical 8882.8 feet Casing Conductor Liner Liner Liner Li ner Liner Production Surface Length 80 1128 959 505 128 1989 10185 2641 Perforation deDth: Size 20" 91.5# H-40 5" 15# 13CR80 7" 29# L-80 3-1/2" 9.3# L-80 3-3/16" 6.2# L.80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 35 115 35.0 115.0 1490 470 9553 - 10681 7849.4 - 8747.4 8290 7250 9722 - 10681 7987.5 - 8747.4 8160 7020 10103 - 10608 8297.8 - 8696.4 10160 10530 10608 - 10736 8696.4 - 8779.2 10736 - 12725 8779.2 - 8882.4 13450 13890 33 - 10218 33.0 - 8390.5 6870 4760 34 - 2675 34.0 - 2674.9 4930 2670 Measured depth: 11040 -11090,11165 -11190,11210 -11235,11323 -11363,11590 -11970,12060 -12360,12570 -12680 True vertical depth: 8901.02 - 8914.24,8921.35 - 8921.14,8920.49 - 8919.72,8918.72 - 8917.53,8912.02 - 8885.95,8882.03 - 88~~~12 8877.29 - 8882.84 ^ Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 31 9542 Packers & SSSV (type & measured depth): 4-1/2" TIW HBBP Packer 9-5/8" DV Packer @ 9495 @ 2625 12. Stimulation or cement squeeze summary: Intervals treated (measured): a~DMS BFL Treatment descriptions including volumes used and final pressur~:u-' Representative Daily Average Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - MJ6 1'1 200\ Oil-Bbl Tubing Pressure 255 171 11.3 9.1 0 0 432 490 232 294 15. Well Class after proposed work: EXDloratorvD DeveloDment [X] Service 0 16. Well Status after proposed work: OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: NIA Daily Report of Well Operations - ! 17. I hereby certify that the foreqoinq is true and correct to the best of my knowledqe. Contact Garry Catron Printed Name Garry Catron Signature 9j~ ~ Form 1 0-404 Revise~ 4/2004 Title Production Technical Assistant 564-4657 Date 8/6/04 O~\G\NJXre -) ) E-098 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/26/04 MIRU CTU #5. MU/RIH W/2 11811 MHAlPDS MEM GR/CCL IN CARRIER. BEGIN UP PASS FROM 11,4001. CONTINUED ON 05/27104 WSR. 05/27104 CONTINUED FROM 05/26/04 WSR. LOG MEM GR/CCL FROM 114001-106501, FLAG CT @ 11190'. MU/RIH WIGUN #1: 201 OF 2'" 4 SPF. TIE INTO FLAG. SHOOT INTERVAL 11343'. 113631. MU/RIH WI GUN #2: 201 OF 211. TIE INTO FLAG. SHOOT INTERVAL 113231- 113431. MU/RIH WI GUN #3: 251 OF 211. TIE INTO FLAG. SHOOT INTERVAL 112101- 112351. POOH. CUT 1001 PIPE. MU/RIH WI DOWELL DEPTHLOG HYDRAULIC CCL & PDS MEM GR/CCL. LOG SWS HYDRAULIC CCL WI REPEAT PASS FROM 112501-106501, PUMPING @ 1.2 BPM. LOG MEMORY GR/CCL AND REPEAT (3RD PASS) HYD CCL FROM 112801-106501. PAINT FLAG @ 11000'. POOH. CONTINUED ON 05/28/04 WSR. 05/28/04 CONTINUED FROM 05/27104 WSR. INTERPRET TIE-IN LOGS. MU/RIH WI GUN #4, 251 OF 211 4 SPF. SHOOT INTERVAL 111651-111901. POOH. MU/RIH WI GUN #5, 251 OF 211 4 SPF. SHOOT INTERVAL 110651-110901. POOH. MU/RIH WI GUN #6, 251 OF 211 4 SPF. SHOOT INTERVAL 110401-110651. WELL OPENED TO LP WHILE POOH, BUT DOES NOT APPEAR TO FLOW. DSO TO RU PBGL. CUT 1001 PIPE. RDMO. FLUIDS PUMPED BBLS 387 260 647 Methonal/W ater 1 % KCL TOTAL Page 1 TREE = 4" 5M CrN W8.LHEAD = 13-518" IVCBI OY A CTUA. TOR = BAKER KB. ELEV = 65.01' B'f.E["EV = mmmn~ 'ï<0þ-;--__mnmm1oäsOï ï\Í1ax'''Angle = 97 @11711' oãiüm-rŸ1D = -"--"1 093'9' DatumTVD = ~"-8ãÖõ'SS 113-3/8" CSG,72#, L-80, ID = 12.347" H 2671' Minimum ID = 2.372" @ 10737' TOP OF 2-7/8" TUBING I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" l-i 1 TOP OF 5" LNR 1-1 TOP OF T' LNR l-i ) 9542' 9553' 9717' 9-5/8" CSG, 47#, L-80, D = 8.68" 1-1 10213' 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.992" 1-1 10608' IT' LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 10898' 15"LNR, 15#,13-CR, .0188bpf,ID=4.408" H 11995' I PERFORA 110N SlJv1Iv\A.RY REFLOG: rvEM GRlCa.../rvf\JCL ON 09/07/02 ANGLEATTOPPERF: 71 @ 11040' Note: Refer to A'oduction œ for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 2" 4 11040 - 11090 0 OS/28/04 2" 4 11165 - 11190 0 OS/28/04 2" 4 11210-11235 0 OS/27/04 2" 4 11323- 11363 0 OS/27/04 2" 4 11590- 11970 0 09/07/02 2" 4 12060 - 12360 0 09/07/02 2" 4 12570 - 12680 0 09/07/02 DATE 05180 01113/95 09/08/02 1 0/07/02 09/17/03 10/13/03 COtvTv1ENTS ORIGINAL COM PLETION I:FF SlDErRACK (E-09A) DAC/KK CTDSIŒTRACK(E-09B) THIKAK ÆRF CORRECTION CMOrrLP DA lUM MD CORREe110N ANyrrLP TOP PERF CORRECTION REV BY ) E-09B SAÆTYNOTES:S" CHROMELNR 8 2083' H4-1/2" 011S SSSV NIP, D = 3.813" I - - - 2620' H 9-5/8" DV PKR I r-J ~ GAS LIFT Iv\A.NDR8.S ST tv[) TVD DEV 1Y PE VL V LA TCH 3 4384 4198 36 rveR OOrvE RA 2 8264 6805 44 rvER SO RA 1 9413 7671 37 rvER DMY RA PORT DATE 16 09/13102 20 09/13102 0 09108/02 L . :8: I ~ 9483' H4-1/2" 011S X NIP, ID = 3.813" 1 9495' H4-1/2"TIWHBBPPKR,ID=4.32" I 9519' H4-1/2"011SXNIP, ID=3.813" I ! 1 9530' H4-1/2" 0118 XN NIP, ID = 3:725" I 9542' H4-1/2"WLEG, ID= 3.958" I H ELMD IT NOT LOGGED I 11 '"I . I I 10103' 1-14" BKR DEPLOYrvENT SLV ,ID = 3.00" I 1 10113' H3-1/2" HES XN NIP, D = 2.750" I 1 10608' H3-1/2"X 3-1/16"XO,ID= 2.800" I MLL OUT WINDOW 10681' - 10688' H3-3/16"X 2-7/8" XO, D =2.380" I PBlD H 12687' I 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" H 10735' I 12-718" LNR, 6.16#, L-80, .0058 bpf, D =2.441" H 12725' I DA TE RBI BY COMMENTS 02104104 CWOIlLP PERF CORRECTION ;/27-2810¿BJrv\:;I\VKK AŒPRFS FRLDHOE BA Y UI\IT WELL: E-09B PERMIT No: 2021610 AA No: 50-029-20466-02 SEe 6, T11 N, R14E, 243.18' FNL & 500.01' F8. BP Exploration (Alaska) ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Repair Well 0 PluQ PerforationsD Pull TubingD Perforate New Pool 0 Operation Shutdown 0 Perforate 0 4. Current Well Class: Stimulate 00 OtherD WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1610 Name: SP Exploration (Alaska), Inc. 65.01 8. Property Designation: ADL-0028303 11. Present Well Condition Summary: Development I]] Stratigraphic 0 9. Well Name and Number: E-09B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExPloratoryD Service D 6. API Number 50-029-20466-02-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 12725 feet true vertical 8882.4 feet Effective Depth measured 12687 feet true vertical 8882.8 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 35 115 35.0 - 115.0 1490 470 Liner 1128 5" 15# 13CR80 9553 - 10681 7849.4 - 8747.4 8290 7250 Liner 959 7" 29# L-80 9722 - 10681 7987.5 - 8747.4 8160 7020 Liner 505 3-1/2" 9.3# L-80 10103 - 10608 8297.8 - 8696.4 10160 10530 Liner 128 3-3/16" 6.2# L-80 10608 - 10736 8696.4 - 8779.2 Li ner 1989 2-7/8" 6.16# L-80 10736 - 12725 8779.2 - 8882.4 13450 13890 Production 10185 9-5/8" 47# L-80 33 - 10218 33.0 - 8390.5 6870 4760 Surface 2641 13-3/8" 72# L-80 34 - 2675 34.0 - 2674.9 4930 2670 Perforation depth: Measured depth: 11590 - 11970, 12060 - 12360, 12570 -12680 True vertical depth: 8912.02 - 8885.95,8882.03 - 8873.12,8877.29 - 8882.84 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 Packers & SSSV (type & measured depth): 4-1/2" TIW HBBP Packer 9-5/8" DV Packer @ 31 9542 @ 9495 @ 2625 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 9.7 0 520 AU6 i it ~ßBt 13 512 18.3 23 535 Tubing Pressure 348 502 Prior to well operation: Subsequent to operation: Oil-Bbl 184 Copies of Logs and Surveys run - 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] Service D 14. Attachments: Daily Report of Well Operations. 2S. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )d~~ Form 10-404 Revised 4/2004 WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: NIA Title Production Technical Assistant Signature OK\G\N^t:ne 564-4657 Date 8/6/04 ~ ' ) ) E-09B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/11/03 DRIFTED W/ 2.25 CENT W/ 1 3/4 BAILER TOOLS STOPPED FALLING @ 10797' WLM DUE TO DEVIATION. (PRE CT-ACID) ***LEFT WELL SHUT IN*** 10/14/03 CTU #9, ACID TREAT; MIRU DS CTU #9. MU AND RIH 1.9" CRC, 1 3/4" CHECKS, 1 3/4" STINGERS, 1 3/4" NOZZLE. LOAD WELL WITH FILTERED KCL. FILTERS PLUGGED, FOUND WATER TO BE CONTAMINATED. CONr ON WSR 10/15/03... 10/15/03 CTU #9, ACID TREAT; CONr FROM WSR 10/14/03... CONTINUE RIH WITH 1 3/4" NOZZLE. PERFS PLUGGING. BEGIN TAKING RETURNS TO TANK WHILE RIH. CIRC METH OUT OF COIL. DRY TAGGED TD AT 126961 CTMD. PU @ 126891 CTMD. PUH JET WASHING PERFS WITH KCL IN AN ATTEMPT TO CLEAN PERFS AND CIRC OUT BAD WATER. WASH PERFS AND CIRC BOTTOMS UP. PRE-ACID INJECTION RATE 1 BPM @ 1450 PSIG WHP, 1.5 BPM @ 1650 PSIG WHP. WASHED PERFS WITH 73 BBLS OF 12/10 HCUXYLENE ACID. POST TREATMENT INJECTION RATE 1 BPM @ 140 PSIG WHP, 1.5 BPM @ 250 PSIG WHP. OVER FLUSH ACID WITH100 BBLS OF 2% KCL. POST-OVERFLUSH INJECTION RATE 1 BPM @ 320 PSIG WHP. POOH. NOTIFIED PAD OPERATOR TO POP WELL AS SOON AS POSSIBLE. RD DS CTU #9. *** JOB COMPLETE *** FLUIDS PUMPED BBLS 57 73 509 639 60/40 Methonal 12/10 HCUXylene Acid 2% KCL TOTAL Page 1 ) )90d-jÚ/ Jou07- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: E-09B, E-09B: Digital Log Images: 50-029-20466-02 May 22, 2003 AK-MW-22148 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: -;GÅ~~'-C~ ~~~(\{\~ BP Exploration (Alaska) Inc. Petro-technical Data Center LRZ-l 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED JUN 0 2 2003 PJasks (Ii; & Gas Cons. Commis5ion .Anchofttge ') ) aL8--/~)/ I / to ~~I5~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 13, 2003 RE: MWD Formation Evaluation Logs E-09Xv () AK-MW-22148 1 LDWG formatted Disc with verification listing. API#: 50-029-20466-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: s~úÚl~ RECEIVED 1 MAR 1 ~ 2003 Alaeø OtJ & Gas Cons. CornmiJion ~ Scblllmbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well E-09B aOCll\-IIo' E-08A ~O~-O~~ NK-27 J q .t1- oa ) Job# Log Description Date 22465 MCNL 22401 MCNL 22485 RST 09/07/02 08/27/02 10/22/02 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 JAN 1 0 2003 Alaeka œ & Gas Cons. CommIaeion AnGbc;rtg; Blueline 01/06/03 NO. 2644 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints ~ CD .~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth ReceiV~ cJJoop-J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well II Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 243' SNL, 500' WEL, SEC. 06, T11N, R14E, UM At top of productive interval 1021' SNL, 4479' EWL, SEC. 05, T11N, R14E, UM At total depth 1663' SNL, 849' EWL, SEC. 04, T11 N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 65.01' ADL 028303 12. Date Spudded.. 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 9/1/2002 9/3/2002 9/8/2002 " 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12725 8882 FT 12687 8883 FT II Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, CCL, Memory CNL Classification of Service Well 7. Permit Number 202-161 8. API Number 50- 029-20466-02 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number E-09B 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2083' MD 1900' (Approx.) - /D~ß6'A,Ð 71'W~ ~ 7"7 ' 'JÝ./) 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 2011 X 3011 Insulated Conductor Surface 110' 3611 11.8 cu yds Arcticset 13-3/811 72# L-80 Surface 2671' 17-1/211 2790 cu ft Arcticset II 9-5/811 47# L-80 Surface 10213' 12-1/411 1455 cu ft Class 'G', 130 cu ft AS 711 29# L-80 9717' 10558' 8-1/211 ~53 cu ft Class 'G' 511 15# 13Cr80 9553' 10680' 611 286 cu ft Class 'G' 3-3/16" x 2-7/8" 6.2#/6.16# L-80 10103' 12725' 3-3/411 140 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) 211 Gun Diameter, 4 spf MD TVD 11590' - 11970' 8681' - 8886' 12060' - 12360' 8882' - 8873' 12570' - 12680' 8877' - 8878' AMOUNT PULLED SIZE 4-1/211, 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 9542' PACKER SET (MD) 9495' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with MeOH 27. Date First Production September 19, 2002 Date of Test Hours Tested 9/19/2002 8 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 898 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SU'\t'E(t\ 'J t D No core samples were taken. OIL-BBL GAs-McF 18,327 GAs-McF WATER-BBL 72 WATER-BBL CHOKE SIZE 176/64 OIL GRAVITY-API (CORR) GAS-OIL RATIO 20,420 nrT 14 OC1 0 A 2002 l\~mm\ßS\on O\~& GasQons. vv Þ.\as\(a AndtoraQe G~ RBDMS 8Fl Form 10-407 Rev. 07-01-80 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 21TS 107231 8772' Zone 1 B 10850' 8829' Zone 1 A 10960' 8873' R~t!ffVED OCT 0 4 2002 Alaska 011 & Gas Cons, Commtssíoli AnChorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the f~Oi~9 is tru. ,. e and correct to the best of my knowledge Signed Terrie Hubble "lQAA.t0 ~- T~le Technical Assistant Date JO' D^I.O;;2.. E-09B 202-161 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Alistair Sherwood, 564-4378 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) Legal Well Name: Common Well Name: Event Name: .Contractor Name: Rig Name: E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N 1 Spud Date: 5/4/1980 End: Date From/To. Hours Task. CödeNPT PéScri ptiØr((jfQþ~rØtiÖr1s 8/29/2002 1.00 MOB DECOMP 00:00 - 01 :00 01 :00 - 03:30 03:30 - 13:00 13:00 - 13:50 2.50 RIGU 9.50 BOPSUR 0.83 CLEAN P DECOMP DECOMP DECOMP 13:50 - 14:10 14:10 - 15:40 0.33 CLEAN P 1.50 CLEAN P DECOMP DECOMP 15:40 - 16:20 0.67 CLEAN P DECOMP 16:20 - 18:00 18:00 - 20:00 1.67 CLEAN P 2.00 CLEAN P DECOMP DECOMP 20:00 - 22:25 2.42 CLEAN P DECOMP 22:25 - 23:15 0.83 CLEAN P DECOMP 23:15 - 23:30 0.25 EVAL P WEXIT 23:30 - 00:00 0.50 EVAL P WEXIT 8/30/2002 00:00 - 02: 15 2.25 EVAL P WEXIT 02:15 - 03:00 0.75 EVAL P WEXIT 03:00 - 05:00 2.00 EVAL P WEXIT 05:00 - 05:45 0.75 EVAL P WEXIT 05:45 - 06: 15 0.50 STWHIP P WEXIT 06:15 - 07:15 1.00 STWHIP WEXIT 07:15 - 09:30 2.25 STWHIP P WEXIT 09:30 - 10:15 0.75 STWHIP N DPRB WEXIT 10:15 -10:30 10:30 - 11 :00 0.25 STWHIP N 0.50 STWHIP N DPRB WEXIT DPRB WEXIT Move rig to E-09A, position rig over well. Rig accept at 01 :00 08/29/2002. NU BOPE, position cuttings tank, call out grease crew. PT BOPE. Lou Grimaldi from AOGCC here to witness test. BOP test completed, all passed ok. MU Baker CTC, PT to 3500 psi, Pull test to 20klbs. Pre job safety meeting. Discuss hazards unique to this well. Open master and swab valves. Well has swapped out since load and kill yesterday. WHP=750 psi. IA=OA=O psi. Try bleeding to flowback tank. All gas. Rig up to bullhead gas away with bio water in pits. Kill well with 250 bbls. Well on vac at finish of kill. RU Baker milling BHA #1. 3.80" DSM, 3.80" string reamer, motor, 2 jts PH6, MHA. RIH with BHA #1 to mill XN nipple at 9530'. 9500', Weight check up=34klbs. Dry tag top of XN nipple @ 9530'. Make -11 correction to get on depth. Kick on pumps. Free spin= 1500psi. LEL alarm in pits, divert returns to choke. Pit vol=322bbls @ 18:25. IA=300psi. Seeing 300-500psi motor work. Mill down thru nipple, backream up thru, mill down, backream up. Run thru nipple dry, come back up thru nipple dry. No bobbles. Down thru it again dry, no bobles. RIH to 10700'. Spot high vis pill. POOH. Stand back injector, LD milling assembly, prep rig floor for eline. PJSM, discuss rigging up SWS eline. PU Eline tools: GR/CCL and 3.625" dummy whipstock drift RIH for 3.625" whipstock drift and GR/CCL Jewelry log. Set down with 3.625" drift (18') & GR/CCL(16.7') @ 10,670 3x, attempt to work past, no progress. Sart losing ground, last set down 10605. Set down depth varies with RIH speed, believe we may have some dogleg below the 7" window that is preventing this tool from getting down. The whipstock will be 5' shorter than the drift and approx. 300lbs heavier. If it is a dogleg issue we may have a better chance at getting the whipstock down. CCL shows all jewelry is where it should be. POH, discuss situation with A. Sherwood. Plan to try running the whipstock on next run. LD drift assembly. Safety meeting prior to picking up whipstock. Make up SWS setting tool and Baker whipstock. RIH with Baker 5" Retrievable monobore whipstock on SWS setting tool with POS tool and CCL. Hang up at SSSV nipple, can't get thru. POOH, check whipstock. No obvious marks. Grind protection pad for anchor to smooth champher slightly. RIH, still tagging up on SSSV nipple. Tag a couple of times lightly, then POOH. Consult with Baker, and BP town. Baker is modifiing a new bottom nose to have a more rounded profile to it. Attach new bottom nose to whipstock. RIH with Baker whipstock on Schlumberger wireline setting eq. Can't get past SSSV nipple again. Same problem at same depth. Printed: 9/9/2002 12:22:50 PM ) ) BPEXPLORATION Cl)pEj~~ti()~$$t;lrnm~ryREjpô~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N1 Spud Date: 5/4/1980 End: HoUrs Task CÖde...NPT Oè$~riptiÖrtöfOÞørC3tiþns 8/30/2002 11 :00 - 13:25 2.42 STWHIP N DPRB WEXIT 13:25 - 14:30 1.08 STWHIP N DPRB WEXIT 14:30 - 16:00 1.50 STWHIP N DPRB WEXIT 16:00 - 16:30 0.50 STWHIP P WEXIT 16:30 - 17:40 1.17 STWHIP P WEXIT 17:40 -18:15 0.58 STWHIP P WEXIT 18:15 - 18:30 0.25 STWHIP P WEXIT 18:30 - 20:25 1.92 STWHIP P WEXIT 20:25 - 22: 1 0 1.75 STWHIP P WEXIT 22:10 - 22:35 0.42 STWHIP P WEXIT 22:35 - 23:30 0.92 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 8/31/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 03:00 2.00 STWHIP P WEXIT 03:00 - 04:30 1.50 STWHIP P WEXIT 04:30 - 05:00 0.50 STWHIP P WEXIT 05:00 - 05:30 0.50 STWHIP P WEXIT 05:30 - 06:30 1.00 STWHIP P WEXIT 06:30 - 08:45 2.25 STWHIP P WEXIT 08:45 - 10:00 1.25 STWHIP P WEXIT Tag up at surface, no obvious problem with whipstock. Need to do something different. Call Baker and order 5" permananet (old style) whipstock. Wait for new whipstock from Deadhorse. Baker back on location. MU whipstock on catwalk. Scribe WS to POS tool and calibrate. Disconnect and make tools up vertically. Check scribe marks. RIH with Baker WS on SWS eline. Slipped thru SSSV nipple with no bobble at all on weight. Continue RIH. Log Whipstock into position. Set whipstock with top at 10680', TF=17L. RA tag at 10689'. POOH with WS setting BHA. Rig down SWS setting BHA. Safety meeting prior to PU P&A BHA. PU Cementing BHA: Baker Coil Connector,XO, Dowel Hyd Disconnect, Dowell Burst Disc Circ Sub, XO, BPX 2 jts 2-3/8" PH6, XO, 13/16" ball drop Cementing Nozzle (4x 0.25" side jets, 4x 0.1875"down jets, 3/4" center down jet). Postition injector on well. Cementers on location @ 19:30. RIH with cementing nozzle. Pre job in ops cab prior to pumping cement with cementers and rig crew. Tag Whipstock, depth correct to eline setting depth of 10680' (subtract 8'). PU and flag pipe at 10670'md. Test to make sure we can bullhead fluid, 0.5bpm at 1500psi whp. Call A. sherwood to discuss, decide to PT dowelllines to 4000psi. Good test. Start pumping 5bbls Fresh water, 30bb115.8ppg neat cement, 5bbl Fresh water. Start bullheading cement with 1500psi whp at 0.5bpm. Pressure went to 1900psi when cement hit top perfs. Open choke and POH holding 500psi on the choke. Start laying in cement 1: 1, pull up to safety. Hold 1000psi with chokes closed, WHP bled down to 800psi in 6-8min., circulate 0.2bpm to get WHP back up to 1000psi. Slowly pushing cement away to the perfs (less than 0.1 bpm). Hold 1000psi WHP while at safety for an additional 60minutes. Started POH with 7bbls of cement below whipstock, pushed away an additional 4.3 bbls to perfs while holding 1000psi at safety. Prepare to drop ball. Cement thickening time= 4hrs 50min. Drop 13/16" ball for ball drop nozzle to cleanout cement. RIH circulating at 70fpm, 3.5bpm/2475psi circ press. Cleanout down to whipstock tray at 10680'. POH circulating to 9500', rbih to whipstock tray 100fpm, 3.5bpm/2338psi. Repeat. 3up/3down passes total to clean above whipstock. POH, Prejob on jetting stack clean while pooh. Jet stack with swizzle stick. LD cementing nozzle, PU Milling assembly (in .8" HC DSM DP0261 + 3.8" STRING MILL) RIH with BHA #3, Window milling BHA. Hughes DSM-Baker String reamer-BHI motor-Baker MHA. 4700', Continue RIH. Tour crew change OAP=O psi, IAP=125 psi. Still no compressive strength on SWS cementers UCA. Cement to 1000 psi compressive strength according to SWS UCA. RIH. weight check at 10600'=46klbs. Tag top ofWS. Printed: 9/9/2002 12:22:50 PM ) ') BI?EXPLORATION r4>p~~Ci~iQr)SSll.rpI11ØrY~~P()1"t Legal Well Name: E-09 Common Well Name: E-09 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 HdÜl"s Task Code NRT 8/31/2002 08:45 - 10:00 1.25 STWHIP P WEXIT 10:00 - 11 :00 1.00 STWHIP P WEXIT 11 :00 - 12:00 1.00 STWHIP P WEXIT 12:00 - 13:00 1.00 STWHIP P WEXIT 13:00 - 14:00 1.00 STWHIP P WEXIT 14:00 - 15:00 1.00 STWHIP P WEXIT 15:00 - 16:00 1.00 STWHIP P WEXIT 16:00 - 17:00 1.00 STWHIP P WEXIT 17:00 - 18:00 1.00 STWHIP P WEXIT 18:00 - 18:20 0.33 STWHIP P WEXIT 18:20 - 19:15 0.92 STWHIP P WEXIT Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N1 Spud Date: 5/4/1980 End: DßSctiptionofOperatjÞns 19:15 - 21:25 2.17 STWHIP P WEXIT 21 :25 - 22:45 1.33 STWHIP P WEXIT 22:45 - 00:00 1.25 STWHIP P WEXIT 9/1/2002 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 01 :00 0.50 STWHIP P WEXIT 01 :00 - 01 :15 0.25 STWHIP P WEXIT 01:15 - 02:30 1.25 STWHIP P WEXIT Make -6.5' correction to 10680.5'. Paint yellow flag at window start depth. Begin window milling. 2.5 bpm, 1950 psi free spin. 10681', Update at 10:00, milling ahead. 600 Ibs weight on bit, 150 psi motor work. 1 for 1 returns. Pit vol=182 bbls. 10682.2', Update at 11 :00, Milling ahead. 2700 Ibs weight on bit, 210 psi motor work. Pit Vol=181 bbls. 10682.9', Update at 12:00, Milling ahead. 4400 Ibs weight on bit, 200 psi motor work. Pit vol=182 bbls. Milling is going as expected, getting good metal on ditch magnets. 10683.4', Update at 13:00, Milling ahead. 3850 Ibs weight on bit, 190 psi motor work. Pit Vol=182 bbls. 10684.1', Update at 14:00, Milling ahead. 4300 Ibs weight on bit, 270 psi motor work. Pit vol=183 bbls. 10685.9', Update at 15:00, Milling ahead. 4050 Ibs weight on bit, 150 psi motor work. Pit vol= 183 bbls. 10687.0', Update at 16:00, Milling ahead. 4400 Ibs weight on bit, 120 psi motor work. Pit vol= 185 bbls. 10687.6', Update at 17:00, Milling ahead. 3500 Ibs weight on bit, 190 psi motor work. Pit vol= 185 bbls. 10688.6', Update at 18:00, Milling ahead. 4400 Ibs weight on bit, 380 psi motor work. Pit vol=184 bbls. 10689.0', Formation sample examined by Geo contains 20% pebbly chert cuttings. This is the bad kind of chert. The good news is that we at least have a partial window. Continuing to mill ahead. We have cut 8.5' of window so far. Window will be 9.0' if the mill stays on the tray all the way. Drilling break, ROP increasing. Belive we are milling formation. Sample from 10692' shows 90% of the cutttings are formation. 30% Chert/70% Sand. 10693', Update at 19:00, Milling ahead, ROP increasing. 5362 Ibs weight on bit, 206 psi motor work. Pit vol=182 bbls. Pump high vis sweep. Pill on bottom at 10695'md. Mil to 10,698.4'. Start backreaming up through the window at O.1fpm. See slight motor work where the string reamer enters the bottom of the window at 10687.7'. Back ream up thru the window, no motor work except at the bottom of the window. Run back down thru the window at 0.6fpm to TO at 10698.2'. Back reem up thru the window a 2nd time. RIH dry, no bobbles. Back reem out of the hole one last time. Looks clean. TOW=10680.5, BOW=10687.7 Poh with window milling assembly Continue poh with window milling assembly. PreJob to discuss directional plan with DO, Geo and Co. rep. Stand back injector. LD window milling assembly. Mill 00=3.8" ,String reamer 00=3.8" PJSM wI Nordic, Sperry, Baker, Schlumberger hands. Do not get complacent with safety. Discuss plan forward with build assembly. Changeout Baker coil tubing connector for OS CTC. Pull test(50K) and PT (3800psi) CTC. Good test. Pressure test OS MHA. Printed: 9/9/2002 12:22:50 PM ) ) BPE~PLORATION .Opèråtiól1$..5urQ~a:tY.R~p()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N1 Spud Date: 5/4/1980 End: Datè FrÖm..Td HoUrs Task CÖdè NPT [)ésêriþtìÖn.dfQþ~r~tiÖh$ 9/1/2002 02:30 - 03:25 0.92 STWHIP P WEXIT 03:25 - 05: 15 1.83 STWHIP P WEXIT 05:15 - 05:45 0.50 STWHIP P WEXIT 05:45 - 06:05 0.33 STWHIP P WEXIT 06:05 - 06:30 0.42 STWHIP N DFAL WEXIT 06:30 - 07:45 1.25 DRILL P PROD1 07:45 - 09:30 1.75 DRILL P PROD1 09:30 - 10:35 1.08 DRILL P PROD1 10:35 - 11 :00 0.42 DRILL P PROD1 11 :00 - 11: 15 0.25 DRILL P PROD1 11:15-12:00 0.75 DRILL P PROD1 12:00 - 12:10 0.17 DRILL P PROD1 12:10 - 13:35 1.42 DRILL P PROD1 13:35 - 13:55 0.33 DRILL P PROD1 13:55 - 15:55 2.00 DRILL P PROD1 15:55 - 16:00 0.08 DRILL P PROD1 16:00 - 17:30 1.50 DRILL P PROD1 17:30 - 19:05 1.58 DRILL P PROD1 19:05 - 19:50 0.75 DRILL P PROD1 19:50 - 21 :40 1.83 DRILL P PROD1 21:40 - 22:15 0.58 DRILL P PROD1 22:15 - 22:40 0.42 DRILL P PROD1 22:40 - 23:50 1.17 DRILL P PROD1 23:50 - 00:00 0.17 DRILL P PROD1 9/2/2002 00:00 - 01 :00 1.00 DRILL P PROD1 PU build assembly RIH with build assembly, 1.37deg motor, new DS49 (srl#1 03861). Shallow hole test MWD. Good test. Tie in near GR at 10,400. Subtract 4'. RIH past whipstock, on bobbles in window. Work with MWD. Not getting pulses. Orient 1 time, and it started working. 10701', Begin drilling. Still have 2# bio in the hole. Free spin 2.7 bpm @ 2730 psi. Drilling ahead 2.7/2.7/3100 psi. Started mud swap to used flo pro system. Annular pressures at begining of day tour; OA=O psi, IA=125 psi. Hard drilling, slow ROP, lots of stalls. 10740', Mud swap completed, now drilling with new flo pro mud. ROP still slow - 35 fph. Not as many stalls as before. 2.7/2.7/3400 psi. 10795', ROP=24 fph. Pit vol=292 bbls. 2.7/2.7/3580, Geo reports last sample at 10700' was nearly 100% chert. The sample from 10750' was about 50% chert. Free spin with flo pro=3300 psi. 10818', Drilling break. ROP up to 70 fph. 2.7/2.7/3670 psi. Pit vol=291 bbls, WOB=2700 psi. 10850', Wiper trip to the shoe. Up wt=36klbs, slick to shoe and back to TD. Resume drilling. 2.7/2.7/3900, Pit vol=291 bbls. ROP=100 fph. Orient to 70L. Resume drilling. 11000', Wiper trip to shoe. Clean PU at 36klbs. Smooth to shoe and back. Resume drilling. Free spin 3450 psi. 2.7/2.7/3950 psi. 286 bbls pit vol. Minor losses while drilling. About 1.5 bbls/hour TF=83L. 11081 " 1 00' wiper trip off bottom. Resume drilling. 11155', Well is landed as per Geo at 8855', 5' deep to original plan. ROP has been slow for this last 80'. POOH to change bits and adjust motor bend. Clean PU off bottom at 36klbs. No problems coming up in open hole, or at window. OA=Opsi, IA=350psi at beginning of night tower. Stand back injector. LD build assembly. Inspect bit: broken cutters + some matrix gone. Change out bit for new DS49 (srl#103862) inspect motor: loose. Replace motor change motor bend to 1.04deg. MWD/orientor working well, run the same ones. Stab injector. RIH with lateral assembly. 1.04deg BHI HP motor, new Hycalog DS49, Sperry hydraulic orientor, Sperry MWD. Tie-in to PIP tag at 10688.9 pulling back up thru window. No correction. Continue RIH. Orienting, getting 2 for 3 clicks. Free spin= 3200psi. Pit vol= 277bbls. Tag bottom at 11160'. 2.5/2.5/3520psi 79L. Slow ROP, stalling. 11188' 3940psi/2. 7/2.7 82L. Pit Vol= 274bbls Drilling. 11200'md 3650psi/2.7/2.7 Pit Vol=274. 67L, Inc=90.4 Printed: 9/9/2002 12:22:50 PM ) ) Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N1 Spud Date: 5/4/1980 End: Date FrórTf~To Flours Task Code NPT DëscriþìipHofQperätioh\s 9/2/2002 01 :00 - 02:30 1.50 DRILL P PROD1 02:30 - 03: 15 0.75 DRILL P PROD1 03: 15 - 04:05 0.83 DRILL P PROD1 04:05 - 05:30 1.42 DRILL P PROD1 05:30 - 05:45 0.25 DRILL P PROD1 05:45 - 06:20 0.58 DRILL P PROD1 06:20 - 06:35 0.25 DRILL P PROD1 06:35 - 07:20 0.75 DRILL P PROD1 07:20 - 07:45 0.42 DRILL P PROD1 07:45 - 08:30 0.75 DRILL P PROD1 08:30 - 09: 15 0.75 DRILL P PROD1 09: 15 - 09:30 0.25 DRILL P PROD1 09:30 - 10:00 0.50 DRILL P PROD1 10:00 - 12:00 2.00 DRILL P PROD1 12:00 - 12:45 0.75 DRILL P PROD1 12:45 - 13:35 0.83 DRILL P PROD1 13:35 - 13:55 0.33 DRILL P PROD1 13:55 - 14:25 0.50 DRILL P PROD1 14:25 - 14:35 0.17 DRILL P PROD1 14:35 - 14:38 0.05 DRILL P PROD1 14:38 - 14:40 0.03 DRILL P PROD1 14:40 - 15:25 0.75 DRILL P PROD1 15:25 - 15:50 0.42 DRILL P PROD1 15:50 -16:35 0.75 DRILL P PROD1 16:35 - 16:45 0.17 DRILL P PROD1 16:45 - 17:00 0.25 DRILL P PROD1 17:00 - 18:15 1.25 DRILL P PROD1 Drilling. Still slow ROP. 11215'md 3455psi/2.5/2.5 94R Inc=90.8 Send lube tex pill from the pits. Find faster drilling at 10228'md for a short time. Drilling is inconsistent, ratty GR. Saw no improvement in drillability with the lube-tex pill on bottom. Short trip back to window. Drilling. 11265'md 3600psi/2.8/2.8 Pit Vol=273 79R, Inc=90.8 Drilling. 11292'md 3960psi/2. 7/2. 7 Pit Vol=270 Orient to 64 R Drilling.. 11353'md 3950psi/2.7/2.7 New reconditioned mud on bottom. 11370', Pick up to orient. Get 3 clicks. Resume drilling. Free spin=3500 psi. 2.7/2.7/3800, TF90R, getting huge reactive, up to 180 deg. ROP=90 fph. Mud swap in progress to 2nd used system. Start of tour annulus pressure check; OA=O psi, IA=135 psi. * - Note Bit from last run graded at 3-3-BT-NA-I-BHA. 11430', Wiper trip to shoe. Clean PU off bottom, no problems in build section. Log tie in pass up across RA tag in whipstock. Subtract 1 ft CTD. RIH. Ream shale from 11260-11330 ft. RIH to TO. Drilling, 2.6 1 2.6 bpm, 3380-4000 psi, 92 deg incl, Drilled to 11,457'. Orient TF. Drilling, 2.6/2.6 bpm, 3380-4000 psi, 11558', Slow drilling in Zone 1 shaley sands. Pump 6% lubetex pill to see if it increased weight transfer or ROP. No improvement. 11597', Wiper trip to shoe. Clean PU off bottom. 11305' Small amount of motor work, and 1000# overpull. 11285', significant motor work and 4k# overpull. 11275', set down, took siginificant motor work, then fell thru. This is same clay that gave us problems on way OOH. Ream/backream. 2 time until clean. Confer with town about directional plan ahead. To achieve what the Geo requests, we must drill a build of 95 deg for the next 400'. Orient 45L. Resume drilling. 3400 psi free spin. 2.612.6/3800 psi. Pit vol=265 bbls. Orient 2 more clicks. Resume drilling. 11670', orient to 90L. Resume drilling. 11721', Orient to 90R. Pit Vol=260 bbls. Resume drilling. 11750', Wiper trip to shoe. Clean PU off bottom. Had to ream back down thru 11300'. Same shale observed on previous runs. Worked it a couple of times until it cleaned up. Still not too bad, but seems to be getting a bit worse on each trip. Call Printed: 9/9/2002 12:22:50 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BP .EXPLORATION Qpêrøtiøn~.....$LJml'ñâryiRepørt E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 9/2/2002 17:00 -18:15 Fl"orn;..To Hours Task Code NPT Phase PROD1 Date 18:15 - 18:41 18:41 - 20:05 20:05 - 21 :05 9/3/2002 21 :05 - 21 :16 21:16 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 01 :40 01 :40 - 03:05 03:05 - 05:00 05:00 - 05:10 05:10 - 06:30 06:30 - 07:50 07:50 - 08:10 08: 1 0 - 08:45 08:45 - 09:00 09:00 - 09:50 09:50 -10:10 10:10 - 12:10 12:10 -13:00 13:00 - 13:30 13:30 -14:15 14:15 - 14:40 14:40 - 14:55 1.25 DRILL P 0.43 DRILL P 1.40 DRILL P 1.00 DRILL P 0.18 DRILL P 2.23 DRILL P 0.50 DRILL P 1.50 DRILL P 0.17 DRILL P 1.42 DRILL P 1.92 DRILL P 0.17 DRILL P 1.33 DRILL P 1.33 DRILL P 0.33 DRILL P 0.58 DRILL P 0.25 DRILL P 0.83 DRILL P 0.33 DRILL P 2.00 DRILL P 0.83 DRILL C 0.50 DRILL C 0.75 DRILL C 0.42 DRILL C 0.25 DRILL C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N1 Spud Date: 5/4/1980 End: driller to add 4 more drums of claygard. Up to 14#/bbl, which is max+. Resume drilling. Pit volume=254 bbls. We continue to loose mud at about 1.5 to 2 bbls/hr. Start of tour annulus pressure check; OA=O psi, IA=325 psi. 11823'md, difficulty holding TF. PU off bottom. Clean pickup. Resume drilling. Free spin=3450, 2.7/2.7/3900. Drill to 11913'md. Short trip back to window. We have been fighting reactive torque in the 60-80API "Sand". Backream thru shale from 11280-11312'. See motor work and lose wt at 11280 as we run back in hole. Orient to 105R. Resume Drilling. Drill to 12070. Wiper to window. Wiper to window. Tie in to PIP tag, add 7'. 430bbls new mud on location(8.6ppg, 10ppb KlaGard, 3%Lube Tex). Made 742ft on last reconditioned mud system, started acting like the previous system: drill off quickly and sticky PU. Also saw some differential sticking. New mud going down hole at 01 :00. Tag bottom, PU. Orient to 56L. Free spin=3250. Resume drilling. 12084'md 2.6/2.6/3850 New Mud on bottom at 12,084. Drill to 12225'md. Wiper to window. Set down at 11318' going back into the hole, work thru. Does not seem to be getting any worse at this point. On Bottom, Orient 90R Drilling smoother with new mud on bottom. Free spin= 3400. 12,292',2.8/2.8/3890 Pit Vol= 241. Difficulty holding TF. 12375', Short trip to window. Begain adding an additional 4#/bbl of claygard to new system. Pit vol=235 bbls. OA=150 psi, IA=140 psi. 400# motor work and weight bobbles pulling thru shale at 11350'-11250'. Not terrible, but consistent difficulty with this shale. Geo reports that he is seeing continuous shale sluffing in his samples. The shale content is lower today than yesterday. * Mud has 3% lubtex, 14 #/bbl claygard. We are going to add salt to bring mud weight up to 9.2 #/g. RIH and tag up at 11330'. Having to work it to clean it up. Finish wiper trip in hole with no problems. Orient to 120R. Plan forward is to drill at 90.5-91 deg. Resume drilling. Free spin=3400 psi. 2.7/2.7/3850 psi. Pit vol=231 bbls. 12420', Orient to 75R. Resume drilling. Drill pass original plan TD of 12470'. 12550', Wiper trip to shoe. Clean PU off bottom at 36klbs. Same motor work and weight at the shale at 11295'. Log tie in pass over RA tag. Make a +8' correction. Continue wiper trip in hole. Fairly clean thru shale at 11350-11250. Resume drilling. 3550 psi free spin. 2.6/2.6/3720, pit vol=234 bbls. 12590', orient around to 50R. Printed: 9/9/2002 12:22:50 PM ) ) Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N1 Spud Date: 5/4/1980 End: Datè FrÖh1-"TÖ Hours Task lqesÓriptiþhöf Qþ~rati<:>hs 9/3/2002 14:55 - 15:45 15:45 - 15:55 15:55 - 17:45 17:45 - 20:00 0.83 DRILL C 0.17 DRILL C 1.83 DRILL C 2.25 DRILL P PROD1 PROD1 PROD1 PROD1 20:00 - 23:05 3.08 DRILL P PROD1 23:05 - 00:00 0.92 DRILL P PROD1 9/4/2002 00:00 - 00:45 0.75 CASE P COMP 00:45 - 01 :30 0.75 CASE P COMP 01 :30 - 01 :45 0.25 CASE P COMP 01 :45 - 07:30 5.75 CASE P COMP 07:30 - 09:30 2.00 CASE P COMP 09:30 - 12:00 2.50 CASE P COMP 12:00 - 14:00 2.00 CASE N DPRB COMP 14:00 - 14:30 0.50 CASE N DPRB COMP 14:30 - 14:45 0.25 CASE N DPRB COMP 14:45 - 15:15 0.50 CASE N DPRB COMP 15:15 - 18:00 2.75 CASE N DPRB COMP 18:00 -18:15 0.25 CASE N DPRB COMP 18:15 -19:00 0.75 CASE N DPRB COMP 19:00 - 21:15 2.25 CASE N DPRB COMP 21 :15 - 00:00 2.75 CASE N DPRB COMP 9/5/2002 00:00-01:10 1.17 CASE N DPRB COMP 01 :10 - 03:45 2.58 CASE N DPRB COMP Resume drilling. Pit vol=233 bbls. 12650', orient to Resume drilling. Pit vol=229 bbls. TD well at 12722. Wiper back to window for final tie-in. Saw a small bobble at the bottom of the shale at 11328', otherwise it looks to be in good shape. The increased mud wt (9.2ppg) and 14pb Kia gard seems to be doing its job. Corrected TD=12725'md Pull out of hole. 30fpm in OH, shale still in good shape. Slight overpull above window in 5", possibly cuttings settled down. Cont POH. LD drilling assembly. Hycalog DS49 was in very good condition. One small chip from back reaming cutters. Put on Baker Coil Connector. Pull Test to 30K. Good test. Pressure test to 3500psi. Good test. RU and Circulate around used coil dart at 2.6bpm. CT vol= 55.6 bbls. PJSM on running liner. Discuss plan forward, emphasize good stance and hand placement while picking up and running liner RIH with TIW taper float shoe, Baker float collar, Baker latch collar, 62joints 2-7/8" STL + 4 joints 3-3/16" + 17 Joints of 3-1/2" + 3-1/2" HES XN nipple, Baker Deployment sub (4"GS profile). M/U Coil. RI H liner with CT to 10600'. Check up wt - 40k, down wt - 19k. RIH smoothly @ 50 fpm thru window. Set down @ 11925', 11987' & 12051'. P/U & continue RIH. Set down hard in shale @ 12468'. OA = 0 psi. IA = 75 psi. Work shales several times & attempt to run past 12468' without progress. Prepare & pump 27bbls of 7.5% lubetex pill out of shoe. Work on hard spot - no luck. Hitting solid @ 12468'. Having good wt transfer with clean PIUs & very minimal O/pull - could be hitting on a ledge. Gave up & decide to POOH for a cleanout run. POOH liner completion assy. No O/pulls across upper shales. Hole to 12468' looks good. Stand back injector. UD CTLRT. PJSM on racking back liner. Pump down 11 bbls 9.9ppg hi-wt slug. UD 5 jts of 3-1/2" STL Inr & rack back 6 stds of remaining 3-1/2" STL, 2 stds of 3-3/16" TCII & 14 stds of 2-7/8" STL Inr. Crew change & PJSM. Cont... LD liner. PU Cleanout assembly. Change CTC. BH11.04deg HP motor, used DS49, Sperry MWD, Sperry 20deg orientor RIH with cleanout assembly. Tie in to PIP tag, Cont RIH. Set down at 11310', sticky PU 15K overpull. Backream up thru shale. Run back to 11290' see motor work in shale area (11260-11330). PU 15K overpull seeing motor work as we pick up. Short trip. RBIH set down 11268'md, motor work, PU with overpull. Losing ground. Continue cleaning up this area. Having trouble getting past 11268'. Finally get through shale after working at it. Lose wt and see motor work in shale at 11515', cont RIH. Set down in shale at 11710'-11730md work Printed: 9/9/2002 12:22:50 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N1 Spud Date: 5/4/1980 End: Datè Fr'drn-To Hours Task COde... NPT [)è$Cr'iption:of .pþer?1tipr\s 9/5/2002 01:10 - 03:45 2.58 CASE N DPRB COMP 03:45 - 04:05 04:05 - 05:05 0.33 CASE N 1.00 CASE N DPRB COMP DPRB COMP 05:05 - 07:30 2.42 CASE N DPRB COMP 07:30 - 07:50 0.33 CASE N DPRB COMP 07:50 - 12:20 4.50 CASE N DPRB COMP 12:20 - 14:15 1.92 CASE N DPRB COMP 14:15 -15:20 1.08 CASE N DPRB COMP 15:20 - 16:25 1.08 CASE N DPRB COMP 16:25 - 16:55 0.50 CASE N DPRB COMP 16:55 - 18:50 1.92 CASE N DPRB COMP 18:50 - 19:30 0.67 CASE N DPRB COMP 19:30 - 23:00 3.50 CASE N DPRB COMP 23:00 - 23:40 0.67 CASE N DPRB COMP 23:40 - 00:00 0.33 CASE N DPRB COMP 9/6/2002 00:00 - 01:10 1.17 CASE N DPRB COMP 01:10 - 01:30 0.33 CASE N DPRB COMP 01 :30 - 01 :55 0.42 CASE P COMP 01 :55 - 03:25 1.50 CASE P COMP 03:25 - 03:45 0.33 CEMT P COMP 03:45 - 04:20 0.58 CEMT P COMP 04:20 - 05: 15 0.92 CEMT P COMP thru it. RIH to 12380' set down in shale. Work this area. Work to 12420. Progress slowing. Short trip to 12050'md. Lose weight at 12380', PU, 10K overpull. Work the area down to 12420'. Tough going. Make it down to 12445'. PU,25K overpull. Perhaps the mud system has reached its useful life. We have drilled 641' on this new mud but have really battled the shales this evening. Wiper to window, need to move some solids. Call for new mud (9.3ppg, 14ppb klagard, 6%lubetex). RBIH to btm. Continue RIH past 12445' & set down @ 12495'. P/U & RBIH fairly clean to 12643'. Decide to call it good & plan with a TO of 12406'. Wiper to window with < 10k Olpull & minimal motor work. RBIH smoothly to 12406'. Continue wiping hole to window and back again to 12406' while waiting on new mud. Hole looks relatively clean. New mud arrive location. Start pumping down new 9.3 ppg, 14ppb klagard, 6% lubetex flopro mud. Meanwhile continue to wipe hole. Pump new mud around bit. PUH with minimal Olpull & motor work to 11700'. Change of plan - decide to RBIH to original TO of 12725' or any hold-up depth beyond 12406'. Have new mud all round wellbore. RBIH with 20k running wt. Set down @ 11300'. P/U clean & continue RIH clean with +/-17k running wt to TO tagged @ 12714'. POOH cleanout BHA#7. Saw slight motor work across 11260'- 11330' shales. PUH to 10720'. Tie in to RA PIP tag (+15' correction). Continue POOH to run Liner. Flag CT @ 7800' EOP & 9800' EOP. LD Cleanout BHA MU Liner with 8 drill collars on top. Change out Baker CTC. Pull test to 30K. Pressure test to 3055psi. RIH with liner; Total BHA length= 2867.5' Total liner length=2622.5' RIH with liner. Slow down to 75fpm above window. See flag above window, 14.5' deep. Slack off=20K PU=45K. Set down at 11952'md work past. RIH to TO at 12725' with very little resistance. Drop ball to release. Shear CTLRT ball seat a 2725psi. PU off bottom= 54K, PU after ball seat sheared out= 31 K. Release confirmed. Circulate around KCL brine weighted to 9.3ppg. PJSM prior to pumping cement Allow cementers to batch mix and PT lines with 2bbls fresh water. PT looks good. Cement up to weight at 04:10. Line up cementers Cement on line. 2.91/2.0/1800psi. Shut down with 25bbls out, line up 9.3 KCL brine to displace and launch dart. Shut down, 0.1 bbl out and check for dart, dart has left. Cont pumping 1400/2.9/2.8. Zero out rate at 72.7bbls pumped (cement at Printed: 9/9/2002 12:22:50 PM ) ) BPE)<f?LCJRATION .C1:).Âerä~i~IÎ$.....$ul11~~ry....~~..~~..1"t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N 1 Spud Date: 5/4/1980 End: Hours Task Code NPT DèscriþtiÒri()f9þ~r~tiöt1~ 9/6/2002 04:20 - 05: 15 0.92 CEMT P COMP 05: 15 - 07:05 1.83 CASE P COMP 07:05 - 07:30 0.42 CASE P COMP 07:30 - 07:45 0.25 CASE P COMP 07:45 - 09:00 1.25 CASE P COMP 09:00 - 14:45 5.75 BOPSURP COMP 14:45 -15:00 0.25 EVAL P COMP 15:00 - 17:30 2.50 EVAL P COMP 17:30 - 18:45 1.25 EVAL P COMP 18:45 - 23:00 4.25 EVAL P COMP 23:00 - 00:00 1.00 EVAL P COMP 9/7/2002 00:00 - 00:10 0.17 EVAL P COMP 00: 10 - 00:25 0.25 EVAL P COMP 00:25 - 02:10 1.75 EVAL P COMP 02:10 - 02:20 0.17 EVAL COMP 02:20 - 03:00 0.67 EVAL COMP 03:00 - 03:40 0.67 EVAL P COMP 03:40 - 04:15 0.58 EVAL P COMP 04:15 - 04:45 0.50 PERF P COMP 04:45 - 05:00 0.25 PERF P COMP 05:00 - 06:00 1.00 PERF P COMP 06:00 - 06: 15 0.25 PERF P COMP 06:15 - 08:50 2.58 PERF P COMP 08:50 - 10:45 1.92 PERF P COMP 10:45 - 11: 15 0.50 PERF P COMP shoe). 2600/2.8/2.6. Slow down to see dart latch, see press spike at 81.4bbls (0.3bbl off calculated). Press up to 3400psi to shear out LWP. Continue pumping 2.5/2.4/2800. See wiper latch up at 98bbls, right on calculated volume. Press up to 2900psi, bleed down, check floats. Floats held. Press up to 1000psi and unsting from liner top. PU wt 34K as expected. Circulate at liner top briefly and POH. POH with CTLRT and drill collars. Tag up @ surface. Stand back injector. PJSM for LID cementing BHA. LID CTLRT & drill collars. PJSM. Perform weekly BOPE pressure test. AOGCC test witness waived by Chuck Scheve. PJSM on P/U logging & liner cleanout assy. Discuss positioning. Rig floor is slippery from rain. P/U logging & liner cleanout assy with 2-1/8" motor, 2.3" D331 mill & newly-improved carrier for CCLlGR/CNL tools. P/U 44 stands of 1-1/4" CSH & M/U injector. RIH logging & liner cleanout BHA#9. IA=250psi, OA=Opsi. Start logging down from 10,OOO'md (100' above liner top), 380psi/0.3/0.730ft/min. Tag PBTD at 12704'. Expected the latch collar to be at 12689'. No difficulty at all RIH inside liner. Start displacing liner with 150K LSRV flo pro perf pill. Start logging, POH while laying in pill. Log up to 10,OOO'md POH with MCNL. POH with MCNL, cleanout motor/mill PJSM on laying down MCNL tools and 88 joints CS Hydril SIB 88 joints 1.25" CS Hydril PJSM on laying down RA source from MCNL LD last joint of CS Hydril, MCNL, motor and mill. Pressure test liner lap to 2200psi, lost 160psi over 30min test. Good test. Finsh downloading MCNL data. Discuss MCNL results with townlslope geo. Everything looks good. Corrected PBTD = 12687' & TOL = 10101'. GOC field pick @ 10884'. Geo confirms to perforate as per plan. Wait on schlumberger to finish organizing guns in pipe shed PJSM, discuss plan forward for PU guns. Post signs, nobody in cellar while guns are above ground. MU 2-3/8" PH6 safety joint. PU perf guns. PJSM after crew change. Discuss plan forward for PU reaminder of guns. Insure signs are posted, nobody in cellar while guns are above ground. 2-3/8" PH6 safety joint on catwalk. Rig floor is slippery when wet. Continue P/U perf guns. P/U 26 stands of 1-1/4" CSH & M/U injector. RIH with perforating BHA#10. RIH & tag PBTD @ 12705'. Pull to P/U wt (35k) & correct depth to 12687'. PUH to 12677' to drop ball. Load 5/8" steel ball. Blow ball in to CT and circ down while positioning guns for bottom shot at 12680'. Chase ball to seat slowing to 1 bpm, 690psi @ 45bbls. Ball on seat after 53 bbls away. Printed: 9/9/2002 12:22:50 PM ) ) BPEXPLORATION c>p~~atiônsSQrnl'11~l)lR.eport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-09 E-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/29/2002 Rig Release: 9/8/2002 Rig Number: N1 Spud Date: 5/4/1980 End: Date FrOm HOurs Tâšk Code NPT Phase De$cription....()fqþèr~tiÓh$ 9/7/2002 11: 15 - 11 :20 0.08 PERF P COMP Pressure up to 2950 psi & observe firing head fire guns. Perf Intervals: 11590-11970', 12060-12360' & 12570-12680'. Total of 790' 11 :20 - 13:30 2.17 PERF P COMP POOH with perf guns at 38fpm monitoring well. 13:30 - 13:45 0.25 PERF P COMP Rack back injector & R/U to LID 1-1/4" CSH. 13:45 - 14:00 0.25 PERF P COMP PJSM for LID 1-1/4" CSH. 14:00 - 15:30 1.50 PERF P COMP LID 52 jts of 1-1/4" CS Hydril tubing work string. Fill hole with 3 bbls of KCL water. R/U for LID perf guns. 15:30 - 15:45 0.25 PERF P COMP PJSM on handling perf guns. Discuss posibility of trapped pressures etc. Re-emphasize good communication and wearing face shields/goggles while LID blanks. 15:45 - 18:00 2.25 PERF P COMP LID 40 perf guns & confirm all shots fired. 18:00 - 18:15 0.25 PERF P COMP PJSM after crew change. Discuss plan forward for LID reaminder of guns. Rediscuss posibility of trapped pressures etc. 18:15 -19:30 1.25 PERF P COMP Continue LID perf guns. ASF! 19:30 - 20:50 1.33 CASE P COMP LD remaining 1-1/4" CS Hydril that is stood back, prior to rig move. Toolpusher gave 24 hr notice to AOGCC for BOPE test on R-31. 20:50 - 22:30 1.67 CASE P COMP Stab injector, Freeze protect well to 2200' with 50/50 MeOH 22:30 - 00:00 1.50 RIGD P COMP Blown down CT with N2. Empty Pits. 9/8/2002 00:00 - 00:05 0.08 RIGD P COMP Continue blowing down CT reel. Empty pits. Clean cuttings tank. 00:05 - 00:15 0.17 RIGD P COMP Stand back injector. Cut coil connector 00:15 - 00:30 0.25 RIGD P COMP PJSM on setting injector in pipe bay for rig move. Discuss plan forward, good communication and responsibilities. 00:30 - 01 :45 1.25 RIGD P COMP Unstab CT and spool end of CT onto reel. 01 :45 - 02:40 0.92 RIGD P COMP Remove gooseneck and set injector into pipe bay. 02:40 - 05:00 2.33 RIGD P COMP N/D BOPE. N/U tree cap and PT. RD tank berms. Place cap on well, PT tree. Release Rig at 02:00 9/8/02. Time on well: 10days, 1 Hr. (Rig release backed out time spent racking back injector, unstabbing CT and spooling it on to reel for reel change out.) Printed: 9/9/2002 12:22:50 PM ¿;¿ oa- / to I 30-Sep-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well E-09B Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,563.00' MD Window / Kickoff Survey 10,680.00' MD (if applicable) Projected Survey: 12,725.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ¡-'i' ~I\.i ~~'!!J.U ~, A,,,,. l,-...~.., " \.,( ,Ii.- .þJ~ska Ò~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU- WOA E Pad E-09B ~ Job No. AKMW22148, Surveyed: 3 September, 2002 Survey Report 30 September, 2002 Your Ref: API 500292046602 Surface Coordinates: 5976820.00 N, 664447.00 E (70020' 34.7058" N, 148039' 55.0050" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~J Surface Coordinates relative to Project H Reference: 976820.00 N, 164447.00 E (Grid) Surface Coordinates relative to Structure Reference: 3615.24 N, 1987.81 E(True) Kelly Bushing: 65.01ft above Mean Sea Level Elevation relative to Project V Reference: 65.01ft Elevation relative to Structure Reference: 65.01ft spe""""Y-SUI! O"A'la:.;..;.1. N G, .,sefAv"lEe ? A Halliburton Company Survey Ref: svy11329 Sperry-Sun Drilling Services Survey Report for PBU- WOA E Pad - E-09B Your Ref: API 500292046602 Job No. AKMW22148, Surveyed: 3 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10563.00 37.900 105.480 8596.85 8661.86 740.51 S 4758.92 E 5976184.06 N 669221.02 E 4803.53 Tie On Point 10680.00 49.330 88.490 8681.71 8746.72 748.99 S 4838.44 E 5976177.33 N 669300.71 E 13.927 4882.92 Window Point 10701.41 54.100 88.500 8694.97 8759.98 748.55 S 4855.24 E 5976178.14 N 669317.49 E 22.279 4899.19 10731.49 57.970 94.200 8711.78 8776.79 749.16 S 4880.16 E 5976178.07 N 669342.42 E 20.304 4923.60 10760.46 62.030 99.000 8726.27 8791.28 752.07 S 4905.06 E 5976175.71 N 669367.38 E 20.052 4948. 52 .~ 10808.86 66.300 109.540 8747.40 8812.41 762.85 S 4947.17 E 5976165.86 N 669409.71 E 21.482 4991.98 10843.86 67.580 114.620 8761.12 8826.13 774.96 S 4977.00 E 5976154.41 N 669439.80 E 13.845 5023.76 10877.06 66.430 120.610 8774.10 8839.11 789.11 S 5004.06 E 5976140.85 N 669467.17 E 16.964 5053.32 10907.81 64.670 125.720 8786.83 8851.84 804.41 S 5027.49 E 5976126.07 N 669490.92 E 16.172 5079.59 1 0940.44 65.730 119.200 8800.53 8865.54 820.29 S 5052.47 E 5976110.74 N 669516.25 E 18.425 5107.50 10974.41 68.720 113.560 8813.69 8878.70 834.18 S 5080.52 E 5976097.47 N 669544.59 E 17.655 5137.95 11002.08 70.220 108.100 8823.40 8888.41 843.38 S 5104.73 E 5976088.80 N 669569.00 E 19.257 5163.61 11031.81 70.660 102.280 8833.36 8898.37 850.72 S 5131.75 E 5976082.06 N 669596.17 E 18.505 5191.59 11066.26 74.450 97.530 8843.69 8908.70 856.36 S 5164.11 E 5976077.13 N 669628.65 E 17.145 5224.39 11107.29 81.590 94.000 8852.21 8917.22 860.37 S 5204.01 E 5976074.00 N 669668.63 E 19.327 5264.17 11143.86 87.310 92.940 8855.74 8920.75 862.57 S 5240.33 E 5976072.59 N 669704.99 E 15.905 5300.05 11173.46 90.310 90.120 8856.36 8921.37 863.36 S 5269.90 E 5976072.45 N 669734.57 E 13.908 5329.05 11207.76 92.330 87.130 8855.57 8920.58 862.54 S 5304.18 E 5976074.03 N 669768.82 E 10.518 5362.26 11236.71 91.190 91.530 8854.68 8919.69 862.20 S 5333.11 E 5976075.00 N 669797.74 E 15.693 5390.37 11271.33 90.310 95.060 8854.22 8919.23 864.19 S 5367.66 E 5976073.77 N 669832.33 E 10.508 5424.49 11303.16 90.480 98.410 8854.00 8919.01 867.92 S 5399.27 E 5976070.73 N 669864.00 E 10.538 5456.12 11338.26 91.810 101.930 8853.30 8918.31 874.11 S 5433.80 E 5976065.29 N 669898.67 E 10.718 5491.17 11369.24 91.810 105.980 8852.32 8917.33 881.58 S 5463.84 E 5976058.49 N 669928.87 E 13.066 5522.12 ~ 11403.16 91.630 109.860 8851.31 8916.32 892.01 S 5496.10 E 5976048.77 N 669961.34 E 11 .446 5555.89 11441.36 92.810 107.370 8849.83 8914.84 904.19 S 5532.27 E 5976037.38 N 669997.77 E 7.209 5593.88 11478.79 92.420 1 02.460 8848.12 8913.13 913.81 S 5568.39 E 5976028.56 N 670034.10 E 13.145 5631.24 11513.43 91 .190 102.110 8847.03 8912.04 921.18 S 5602.22 E 5976021.93 N 670068.08 E 3.692 5665.86 11545.76 90.660 98.940 8846.50 8911.51 927.09 S 5634.00 E 5976016.73 N 670099.98 E 9.940 5698.15 11573.54 88.810 97.880 8846.63 8911.64 931.15 S 5661.48 E 5976013.27 N 670127.54 E 7.675 5725.84 11611.88 88.190 95.410 8847.64 8912.65 935.58 S 5699.54 E 5976009.67 N 670165.69 E 6.640 5763.92 11646.13 92.420 94.880 8847.45 8912.46 938.65 S 5733.65 E 5976007.35 N 670199.86 E 12.447 5797.84 11677.24 95.150 92.940 8845.40 8910.41 940.77 S 5764.61 E 5976005.91 N 670230.86 E 10.757 5828.49 11710.63 96.920 91 .360 8841 .89 8906.90 942.02 S 5797.79 E 5976005.39 N 670264.06 E 7.088 5861.10 11744.11 96.120 94.350 8838.09 8903.10 943.67 S 5831.01 E 5976004.46 N 670297.31 E 9.189 5893.84 11783.43 94.710 98.410 8834.38 8899.39 948.02 S 5869.90 E 5976000.97 N 670336.28 E 10.887 5932.72 30 September, 2002 - 17:22 Page2of4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA E Pad - E-09B Your Ref: API 500292046602 Job No. AKMW22148, Surveyed: 3 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11818.66 95.070 103.340 8831 .37 8896.38 954.64 S 5904.36 E 5975995.11 N 670370.88 E 13.980 5967.78 11867.56 94.010 109.330 8827.50 8892.51 968.35 S 5951.12 E 5975982.43 N 670417.93 E 12.402 6016.42 11899.99 94.450 113.380 8825.10 8890.11 980.12 S 5981.23 E 5975971.32 N 670448.29 E 12.528 6048.41 11938.63 93.660 116.910 8822.37 8887.38 996.50 S 6016.12 E 5975955.71 N 670483.53 E 9.339 6086.09 11969.04 91 .630 116.380 8820.97 8885.98 1010.12 S 6043.27 E 5975942.69 N 670510.97 E 6.899 6115.61 '~ 12004.38 93.570 113.030 8819.36 8884.37 1024.88 S 6075.33 E 5975928.64 N 670543.35 E 10.945 6150.17 12037.63 92.250 109.510 8817.67 8882.68 1036.92 S 6106.27 E 5975917.28 N 670574.55 E 11 .293 6183.03 12075.36 90.310 105.980 8816.83 8881.84 1048.41 S 6142.19 E 5975906.58 N 670610.71 E 10.673 6220.61 12104.66 90.750 103.520 8816.56 8881.57 1055.87 S 6170.52 E 5975899.74 N 670639.20 E 8.529 6249.89 12142.26 90.570 100.170 8816.13 8881 .14 1063.59 8 6207.31 E 5975892.83 N 670676.15 E 8.922 6287.48 12173.61 90.480 102.110 8815.84 8880.85 1069.64 S 6238.07 E 5975887.45 N 670707.03 E 6.195 6318.81 12207.66 92.380 106.250 8814.99 8880.00 1077.98 S 6271.06 E 5975879.84 N 670740.20 E 13.374 6352.83 12241.99 92.070 110.040 8813.66 8878.67 1088.66 S 6303.66 E 5975869.88 N 670773.02 E 11.068 6386.99 12276.71 92.160 113.380 8812.37 8877.38 1101.49 8 6335.89 E 5975857.76 N 670805.53 E 9.617 6421.28 12308.18 93.130 117.090 8810.92 8875.93 1114.89 S 6364.32 E 5975844.98 N 670834.24 E 12.173 6452.00 12344.21 93.300 120.080 8808.90 8873.91 1132.10S 6395.90 E 5975828.47 N 670866.20 E 8.299 6486.64 12380.13 91.370 122.900 8807.44 8872.45 1150.85S 6426.50 E 5975810.40 N 670897.20 E 9.508 6520.68 12411.93 89.780 126.780 8807.12 8872.13 1169.01S 6452.60 E 5975792.82 N 670923.69 E 13.185 6550.19 12440.08 89.520 131.360 8807.29 8872.30 1186.75 S 6474.44 E 5975775.56 N 670945.92 E 16.296 6575.47 12480.63 88.620 134.220 8807.95 8872.96 1214.298 6504.20 E 5975748.68 N 670976.27 E 7.393 6610.65 12516.96 87.580 139.990 8809.15 8874.16 1240.88 S 6528.90 E 5975722.64 N 671001.55 E 16.129 6640.70 12552.93 86.430 143.870 8811.03 8876.04 1269.15 S 6551.04 E 5975694.86 N 671024.31 E 11 .236 6668.64 12580.18 84.490 146.340 8813.19 8878.20 1291.438 6566.58 E 5975672.93 N 671040.33 E 11.503 6688.79 '~/ 12611.58 85.900 148.100 8815.82 8880.83 1317.738 6583.52 E 5975647.01 N 671057.84 E 7.167 6711.21 12642.24 88.630 151.800 8817.28 8882.29 1344.23 S 6598.85 E 5975620.85 N 671073.75 E 14.985 6732.11 12673.51 89.520 155.500 8817.79 8882.80 1372.25 S 6612.73 E 5975593.14 N 671088.24 E 12.168 6751.93 12702.61 90.800 158.100 8817.71 8882.72 1398.99 8 6624.19 E 5975566.66 N 671100.29 E 9.959 6769.12 12725.00 90.800 158.100 8817.40 8882.41 1419.768 6632.54 E 5975546.07 N 671109.09 E 0.000 6781.93 Projected Survey 30 September, 2002 - 17:22 Page 3 of 4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA E Pad - E-09B Your Ref: API 500292046602 Job No. AKMW22148, Surveyed: 3 September, 2002 BPXA North Slope Alaska All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 103.000° (True). Magnetic Declination at Surface is 26.159°(31-Aug-02) ~ Based upon Minimum Curvature type calculations, at a Measured Depth of 12725.00ft., The Bottom Hole Displacement is 6782.80ft., in the Direction of 102.082° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10563.00 10680.00 12725.00 8661.86 8746.72 8882.41 740.51 S 748.99 S 1419.76 S 4758.92 E 4838.44 E 6632.54 E Tie On Point Window Point Projected Survey Survey tool proqram for E-098 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) ~ Survey Tool Description 0.00 10504.71 0.00 8616.04 10504.71 12725.00 8616.04 AK-1 BP _HG - BP High Accuracy Gyro(E-09) 8882.41 MWD Magnetic(E-09APB1) 30 September, 2002 - 17:22 Page 4 of 4 DrillQuest 3.03.02.002 1 ~~~~~ Œ~ ~~~~æ~ ;/ AI,ASIiA OIL AND GAS CONSERVATION COMMISSION í TONY KNOWLES, GOVERNOR 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 E-09B BP Exploration (Alaska), Inc. Permit No: 202-161 Surface Location: 243' SNL, 500' WEL, Sec. 06, TIIN, RI4E, UM Bottomhole Location: 1382' SNL, 709' EWL, Sec. 04, TIIN, RI4E, UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above development well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, CßA ~.~ camm~hSli Taylor Chair BY ORDER <;>~ THE COMMISSION DATED thislØ:: day of August, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA \ ) AND GAS CONSERVATION COMM. )¡ON PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill II Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (OF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65.01' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028303 4. Location of well at surface 7. Unit or Property Name 243' SNL, 500' WEL, SEC. 06, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number / 959' SNL, 4513' EWL, SEC. 05, T11 N, R14E, UM E-09B / At total depth 9. Approximate spud date 1382' SNL, 709' EWL, SEC. 04, T11 N, R14E, UM 09/15/02 // 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 028304,709' MD No Close Approach 2560 12470' MD / 8822' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} Kick Off Depth 10650' MD Maximum Hole Angle 920 Maximum surface 2644 psig, At total depth (TVD) 8800' / 3700 psig 18. Casin~ Program Specifications Setting Depth Size T OD Botom Quantitv of Cement Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (include staae data) 3-3/4" 3-3116" x 2-7/S" 6.2#/6.16# L-80 TCII / STL 2370' 10100' 8295' 12470' 8822' 168 cu ft Class 'G' t' 'I '~<:Æ-~ ~"Io l... ~g(ll~ 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 11995 feet 8878 feet 11906 feet 8880 feet Length Plugs (measured) Junk (measured) \& Size Cemented MD TVD 110' 20" x 30" 2671' 13-3/8" 10213' 9-5/8" 841' 7" 2442' 5" 11.8 cu yds Arcticset 2790 cu ft Arcticset II 1455 cu ft Class 'G', 130 cu ft AS 110' 2671' 10213' 110' 2671' 8386' 253 cu ft Class 'G' 286 cu ft Class 'G' 9717' - 10558' 9553' - 11995' 7983' - 8658' 7849' - 8878' true vertical 11036' -11076', 11130' -11240', 11450' -11590', 11660' -11780', 11830' -11900' 8898' - 8900', 8899' - 8895', 8882' - 8881', 8881' - 8882', 8881' - 8881' Perforation depth: measured 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid PrQgram 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. Is~:~:Y :: ::~: fOßß!?~~nJ~;;:rhe b~::f ~~ ::::n~ineer Date 1!~t!ÒL , .'.,'> .... .,.'....' ., ..~$SionUstt.øraIY)i.L,..~';;:,;:',.. ' Permit Number API Number Ap,gr,vE:1IR~e See cover letter /t?'- -I-t< I 50- 029-20466-02 '0 , , ~) (f\, for other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other:TeSt- ßtjPE..~ -SS'OO pC,', Onglna' SIgned By Cammy Qechsli T aytor Commissioner Approved By Form 10-401 Rev. 12-01-85 by order of the commission Date 8 \ l D(~ Submit In Triplicate ") ) BP GPB E-09B CrD Sidetrack Summarv of Operations: / A CrD thru-tubing sidetrack is planned for E-09A. Using a mechanical whipstock the 1400' coil sidetrack, E-09B, will exit the 5" liner in the Ivishak Zone 2B formation and drilled to a Zone 1 A/1 B target. E-09B heads west, down a fairly undisturbed fault bounded corridor. To minimize the lost circulation risk the well will be steared down the middle to maximize fault offset. Upon compl~n of drilling operations the 3%" OH will be cased with 2*" & 3-3/16" solid liner. Assuming a TD of 12,470, (-8821' tvdss) and a liner top placement of 10,100', (-8295' tvdss), 20bbls be used to cement the liner in place before it's selectively perforated. Phase 1: Prep work. Planned to start August 10, 2002. // 1. With e-line, run & set 5" monobore whipstock at 1 0,675'md with a highside orientation /' ith service coil P&A the open perfs by squeezing 35 bbls of 15.8ppg past the whipstock. 35bbls takes account of 1300' of 5" liner, (25bbls volume) and that as much as 10bbls could be squeezed behind pipe. Any excess above the whipstock will be washed out. Phase 2: Mill window, Drill and Complete sidetrack: Planned for September 15, 2002. 1. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Maximum hole angle will be 92 degrees. Mud Program: . Phase 1 &2: Seawater and 8.6 ppg Flo-Pro / . Phase 3: Mill and drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: /' The production liner will be a 3-3/16" TC II x 2-7/8" ST-L solid linerfrom TD at 12,470' to approx. 10,100', (- 8295'tvdss). The X-O betwe~ 3-3/16" x 2-7/8" will be placed at 10,705' MD (-8697'tvdss). Liner cement will be a minimum of 30 bbls of 15.8 ppg latex cement. Well Control: . BOP diagram is attached. .,/ . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional / . See attached directional plan. Max. planned hole angle is 92 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . MWD, Gamma Ray & Resistivity will be run in the open hole section. A Memory GR/CCUCNL log will be run inside the liner upon completion of the cementing operations. Hazards . The concentration of H2S in E-pad well process streams is <10ppm. The well will be steared down a fault bounded corridor. Lost circulation of tip-out fractures is a risk. . Reservoir Pressure Res. press. is estimated to be 3700 psi at -8800'tvdss (8.1 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2644 psi. TREÐ= Wa.LHEAD = ~ .. ... .. .... .. ACTUA TOR = KB. ELEV = BF.ËlEV = KOP= Max Ãï,gië' ;;, , . .. .... Datum MD = ,..<.. ,~,.~" , , '" ." DatumTVD = 4" 5M CrN 13-5/8" MCEVOY . .. ... .. ...... . BAKER 65.01' 30.76' 3200' 95 @ 11300i .................. .. .......... 10914' 8800' SS ) E-09A 8 - - 13-3/8" CSG,72#, L-80, ID = 12.347" 1-1 2671' I 4 Minimum ID = 2.205" @ 11114' 2-7/8" XN NIPPLE L I :8: I 1 :8:---1 J t J I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.953" 1-1 9542' 1 1 TOP OF 5" LINER 1-1 9553' 1 I . II I TOP OF 7" LINER 1-1 9717' 1 . I I 9-5/8" CSG, 47#, L-80, ID = 8.68" 1-1 1 0213' ~ lilt.. ÆRFORA TION SUMMARY REF LOG: SWS MWD GR 01/5/95; ATLAS STP 02/09/95 ANGLE AT TOPÆRF: 82 @ 11036' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11036' -11056' 0 02/15/95 3-3/8" 4 11056' -11076' 0 02/14/95 3-3/8" 4 11130' -11240' 0 01/14/95 3-3/8" 4 11450' -11590' 0 01/14/95 3-3/8" 4 11660' -11780' 0 01/14/95 3-3/8" 4 11830' -11900' 0 01/14/95 7" LNR, 29#, L-80, 0.0371 bpI, D; 6.184" H 10898' I I TOP OF 2-7/8" TBG 1-1 1 2-7/8" TBG, L-80#, 0.0188 bpf, ID = 4.408" 1-1 11122' I SA FE'T'( NOTES ) 2083' 1-14-1/2" OTIS SSSV NIP, ID = 3.813" 1 =-1 2620' 1-19-5/8" DV PKR 1 ~ GAS LIFT MANDRELS ST MD TVD DEV 1YÆ VLV LATCH PORT DATE 3 4384 4198 36 MER RA 2 8264 6805 44 MER RA 1 9413 7671 37 MER RA 9483' 1-14-1/2" OTIS X NIP, ID = 3.813" 1 9495' 1-14-1/2" TIW HBBP PKR, ID = 4.32" 1 9519' 1-14-1/2" OTIS X NIP, ID = 3.813" 1 9530' 1-14-1/2" OTIS XN NIP, ID = 3.725" 1 9542' 1-14-1/2" WLEG, ID = 3.958" 1 9548' 1-1 ELMD TT LOGGED 02/09/95 1 MILLOUT WINDOW IN 7" @ 10569' 10558' - 10569' DATE REV BY COMMENTS 05/80 ORIGINAL COMPLETION 01/13/95 DFF SÐETRACK COMPLETION 01/29/01 SIS-QAA CONVERTED TO CANVAS 02127/01 SIS-LG FINAL 07/18/01 RN/TP CORRECTIONS DATE REV BY COMMENTS PBTD 1-1 11906' 1 1 5" LNR, 15#, 13CR, 0.0188 bpf, ID = 4.408" 1-1 11995' 1 PRUDHOE BAY UNIT WELL: E-09A PERMIT No: 94-1480 API No: 50-029-20466-01 Sec. 6, T11N, R14E BP Exploration (Alaska) TREE:&: WELLHEAD = ÄCTuATÖR~. KB. ELEV = È3f. ElE\¡ ~... KOP= ....... ....., ""..... < . Max Angle = ........ .. ............... Datum MD = Dàtum ïVb' = . 4" 5M erN 13-5/8" MCEV OY .. . BÄKER 65.01' 3Ö.76' 3200' 95 @.11300' . . .. . .. . ... . . . .. ... . 10914' 88ÖÖ'.SS ) 13-3/8" CSG,72#, L-80, 10 = 12.347" 1-1 2671' 1 Minimum ID = 2.205" @ 11114' 2-7/8" XN NIPPLE 1 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.953" 1-1 9542' 1 I TOP OF 5" LINER 1-1 9553' 1 TOPOF7" LINER 1-1 9717' 1 I 9-5/8" CSG, 47#, L-80,ID = 8.68" 1-1 10213' ~ ÆRFORA TION SUMMARY REF LOG: SWS tv1WD GR01/5/95; ATI.AS STP02/09/95 ANGLEATTOPÆRF: 82 @ 11036' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 6 11036' -11056' 0 02/15/95 3-3/8" 4 11056' -11076' 0 02/14/95 3-3/8" 4 11130' -11240' 0 01/14/95 3-3/8" 4 11450' -11590' 0 01/14/95 3-3/8" 4 11660' -11780' 0 01/14/95 3-3/8" 4 11830' -11900' 0 01/14/95 I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 1-1 I TOP OF 2-7/8" TBG 1-1 r 2-7/8"TBG,L-80#,O.0188bpf,ID=4.408" 1-1 11122' I 5" LNR, 15#, 13CR, 0.0188 bpf, ID = 4.408" 1-1 11995' 1 DATE REV BY COMMENTS 05/80 ORIGINAL COMPLETION 01/13/95 OFF SIDETRACK COMPLETION 01129/01 SIS-OAA CONVERTED TO CANVAS 02127/01 SIS-LG FINAL 07/18/01 RNITP CORRECTIONS E-098 Proposed CTD Sidetrack (I) - - 4 L . :8: I I :8:-1 t J ... . I SAFElY NO. TES ) 2083' 1-14-1/2" OTIS SSSV NIP, ID = 3.813" 1 =-i 2620' 1-19-5/8" DV PKR I ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 3 4384 4198 36 MER RA 2 8264 6805 44 MER RA 1 9413 7671 37 MER RA 9483' 1-14-1/2" OTIS X NIP, ID = 3.813" 1 9495' 1-14-1/2" TIVV HBBPPKR, ID = 4.32" 1 9519' 1-14-1/2" OTIS X NIP,ID = 3.813" 1 9530' 1-14-1/2" OTIS XN NIP, ID = 3.725" 1 9542' - 4-1/2" WLEG, ID = 3.958" 1 9548' - ELMD TT LOGGED 02/09/95 1 I I 10100' 1-1 Top of 3-3/16" Liner .. i 10100' 1-1 Top of Cement I 10580' 1-1 Toe I MILLOUT WINDOW IN 7" @ 10569' 10558' - 10569' 1-1 Mechanical Whipstock 1-13-3/16 x 2-7/8 X-over I 3-3/16" X 2-7/8" cnt'ed and perfedl-l 12470' 1 --l 11080' 1-15" BAKERPKR,ID=2.500" 1 11114' 1-12-7/8" XN NIP, ID = 2.205" 1 11122' H2-7/8" WLEG ID = 2.441" 1 OA TE REV BY COMMENTS PRUDHOE BAY UNIT WELL: E-09A PERMIT No: 94-1480 API No: 50-029-20466-01 Sec. 6, T11N, R14E BP Exploration (Alas ka) --~----~-- --~-bþ - ;. INTRQ J'~ . M'- I '\;"'1 ..... .., :::: ~700 . , ~B. .! ... . . ........-. i. ~'J\N~~I ; ...-:~c:8" ~. .. .u. _n_Cþ.- ----~- 'm Ì4l '[K,1ëÄ-K~1MÍL '> --' i--- _f...._nL__~ --- , u;Qmill,1J - . fE-~ ¡ ...m i.... i i -- ~ --- ------- BP Amoco W8LLPATH D8TAlL. ,.,../111-11.. 100282_102 P.rent W.IIp.thl T'. on MDI '.otIAP'1 10150.00 Nordic 1 'oO.A 8S.01ft o.'M!: ~~~ ::::';t,D 0.00 0.00 1Va' R.f. D.t.m. Y.hat'on Ani'. 103.00' REFERENCE INFORMATION Co-ordinate ~IE) Reference' Well Centre: E-09, True North \'~~~~I~~:' ..~~.: ~:::::~:~:. ~Yc;1t~~ ~e~~~~~)el Measured Deptn Reference: E-09A 65.01 Calculation Method: Minimum Curvature alcnoN DITAtL8 tVO 1 10183.00 31.80 101." 8'''''1 2 10810.00 ".18 n.18 8881.84 3 10870.00 CT.78 13.41 88'8.1' 4 10882.01 81.00 111.08 ""'02 IS 111118.81 eo.oo 81.00 8Ise.22 8 "1120.00 80.00 78.30 81"'21 7 111SO.OO 82.31 10S.11 "St." . 117so.oo n.ti 81.80 "U84 8 12no.oo 81.U 112.21 "3O.OT 1012410.00 81.81 88.20 8811." +EJ..W DL8. TFac8 .740..' .'88.82 0.00 0.00 .7".88 ..18.25 13.83 307.84 ==" :=::1 4:= ~= 4".34 8147.10 12.00 311Me .8'4.07 8410.31 12.00 270.00 -812.13 8837." 12.00 88.00 -1".3' 8831.88 12.00 -80.00 .1014.17 122...7 12.00 80.00 .1 U8.23 "'3.80 12.00 -88.00 V8ec T.f.et ~H! i~fi ANNOTATION. TVD MD AIIftobltlOll ....... 101n.00 TIP .U1," 108".00 KOP .878.t. 10870.00 t .7...01 101...08 I ...8.21 11 U...I , ."8.21 11120.00 . ...1M 11110.00 . ."S," 11780.00 8 .130.07 11170.00 7 '111". 11.70.00 TO TARGET DETAILS TVO +N/.s +EJ-W Shape E-09Bmøo~,1 aaJ.~ .~~:= ~~:~ ~ lil!h =.~ -j~:~! ~:~ 51 ---_.._~---- -- - - ~~~---- -~--------~-~~-----~-----~ :5 8550 Q, & 8600 "i 8650 U 1: 8700 .. > 8750 .. ! 8800 8850 8900 8950 9000 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 ------------~-~-_._- LEGEND - ê:g~ ¡ê:8~k) -- E-09 (E-09APB1) K-19A (K-19A) Plan#6 E-09B ~- Plan #6 T ^M é Azimuths to True North Plan: Plan #6 (E-09JPlan#6 E-09B) Magnetic North: 26.410 Created By: Brij Potnis Date: 4/5/2002 Magnetic Field r- . . Strength: 57507nT Contact Information. Dip Angle: 80.830 Direct: (907) 267-6613 Date: 4/5/2002 E-mail: brij.potnis@inteq.com Model: BGGM2001 Baker Hughes INTEQ: (907) 267-6600 -------- -.,,' ~- . ! I. ! : 'i i . i : . : : Ii' Iii,. :, I ,i Ii i, i : I i I ¡ : ,: I' : 5600 5700 5800 5900 61 DO 6200 6300 6400 6500 6600 6800 6900 71 DO 7200 730 West(-)/East(+) [100ft/in] , 5000 5100 52'00 5300 5400 n-- .¡ u~ -t, ... i/;' '.~ u ~ .~- . ..¡--- ..- +- -. - ! u . ¡ - ~... : "".,.",/' - .. -.. - - - - . - :-, F-O!,i~:_nQA . : . - ~ - --- I n- m -- --- - -- -- I~"-¡ !,,-'I r:L~~S21 , 1 u .i i .. tn- . ..- - i ¡ . : . T : i .. . ..--. ~ i' 1I -I i.1 -- T_(I~~J:~=Ü: . . .. .. u ¡ ..,..... 6650 5250 5300 '1/5/2002 12:53 PM ) ) .. BP Baker Hughes INTEQ Planning Report INTEQ COlnp~ny: Fiêld; Site: Well: W~lIpatlt: Field: Date: 4/5/2002 . . TiiDe:.12:54:50 . Ç~f9,~~àte(~)~~r~Il~: .\!V~lt:..~:'QQ~T~~N~~ Y~J1i~~"ffm~1,{e'er~~ce: Sy~t~IJ1:M~~p~~~,~~y~! .;.. . S~oÌJ.(VS};BefereJlce: .. . .' . WeJt;(~.);ogN;q.OQE,;t03,()()ki) ,~urvey.ÇalculatioD'M-ethod; MinimumCÙrvature. . Db~ rilge: 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 Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 PB E Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5973160.88 ft 662538.97 ft Latitude: Longitude: North Reference: Grid Convergence: 70 19 59.134 N 148 40 53.054 W True 1.24 deg IWell: E-09 E-09 Well Position: Slot Name: 09 70 20 34.706 N 148 39 55.005 W +N/-S 3617.17 ft Northing: 5976820.00 ft +E/-W 1987.01 ft Easting: 664447.00 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan#6 E-09B 500292046602 Current Datum: E-09A Magnetic Data: 4/5/2002 Field Strength: 57507 nT Vertical Section: Depth From (TV») ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 E-09APB1 10650.00 ft Mean Sea Level 26.41 deg 80.83 deg Direction deg 103.00 Height 65.01 ft Targets l\iJ;ap.. Map <~"';':'.Latitude...~ ~~.Long~de;C->: Name Descfiption TV». +N/-S +E/'-W Northil1g E~sting , . Deg Mio...s« DegMinSec Dip. Dir~ ft ft .ft ft ft E-09B Polygon5.1 0.00 -816.56 5136.87 5976116.37 669600.19 70 20 26.658 N 148 37 24.952 W -Polygon 1 0.00 -816.56 5136.87 5976116.37 669600.19 70 20 26.658 N 148 37 24.952 W -Polygon 2 0.00 -849.44 5961.41 5976101.59 670425.20 70 20 26.328 N 148 37 0.867 W -Polygon 3 0.00 -998.08 6358.31 5975961.70 670825.23 70 20 24.863 N 148 36 49.277 W -Polygon 4 0.00 -1230.96 6718.37 5975736.79 671190.29 70 20 22.570 N 148 36 38.766 W -Polygon 5 0.00 -1488.53 6602.76 5975476.77 671080.37 70 20 20.038 N 148 36 42.149 W -Polygon 6 0.00 -1223.80 6388.43 5975736.71 670860.30 70 20 22.643 N 148 36 48.403 W -Polygon 7 0.00 -1065.07 5756.67 5975881.53 670225.25 70 20 24.209 N 148 37 6.853 W -Polygon 8 0.00 -1025.55 5087.33 5975906.36 669555.25 70 20 24.603 N 148 37 26.403 W E-09B T5.3 8822.00 -1130.46 6433.20 5975831.00 670903.00 70 20 23.561 N 148 36 47.093 W E-09B T5.4 8822.00 -1336.48 6658.75 5975630.00 671133.00 70 20 21.533 N 148 36 40.510 W E-09B T5.2 8836.00 -926.49 5981.53 5976025.00 670447.00 70 20 25.570 N 148 37 0.281 W E-09B T5.1 8856.00 -878.74 5218.34 5976056.00 669683.00 70 20 26.046 N 148 37 22.574 W Annotation MD 1'VD ft ft , 10563.00 8596.85 TIP 10650.00 8661.54 KOP 10670.00 8675.19 1 10892.08 8799.02 2 11155.85 8856.22 3 11320.00 8856.22 4 11550.00 8851.48 5 11750.00 8843.64 6 12170.00 8830.07 7 ) BP ) .,a: Baker Hughes INTEQ Planning Report ~1'ao COlJ]pal1Y: BP.AmoCo I>atê:....4/512002, 'Tiïnei.12:54:50 :e~~: FielcJ: Prudt)Qe Bay ,. Ç~-o,~dinaw(~}l{~fereÌ1ce;" Wen:E~-O.9~_TruØN()rth Site: PB EPad Y~rijêaJ.(T~)...Rere~jtëe: ~Y~~f11::MeØp.'S~àl.;~vel Well: E~9. ~on(VS);Referençe:. ' - W~«().OQN,O.;OOE.103;OOAzi) Wëllpath: Plan#6E;'09B S"rVeY.G~lculatiol1-M:èdlod: 'Minimum'Curvature Db: Annotation MD TV» ft ft 12470.00 8821.88 TD I Plan #6 I Plan: Date Composed: 4/4/2002 Tie into E-09APB1 instead of E-09 of Plan#5 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Iuel Aiim TV» +Nl;.S +E/':W DLS ' Build TÎltt. TFO' T~rg~ ft deg deg ft .ft ft degl10Oft. d~1ØOft;;q~/JOOft peg --- 10563.00 37.90 105.48 8596.85 -740.49 4758.92 0.00 0.00 0.00 0.00 10650.00 46.18 92.19 8661.54 -748.85 4816.25 13.93 9.52 -15.27 307.84 10670.00 47.75 93.41 8675.19 -749.56 4830.85 9.00 7.83 6.08 30.00 10892.08 65.00 118.08 8799.02 -802.77 5004.83 12.00 7.77 11.11 57.50 11155.85 90.00 98.00 8856.22 -879.34 5247.10 12.00 9.48 -7.61 319.15 11320.00 90.00 78.30 8856.22 -874.07 5410.35 12.00 0.00 -12.00 270.00 11550.00 92.31 105.81 8851.48 -882.23 5637.94 12.00 1.01 11.96 85.00 11750.00 92.11 81.80 8843.64 -895.39 5835.89 12.00 -0.10 -12.01 -90.00 12170.00 91.35 132.21 8830.07 -1014.27 6224.47 12.00 -0.18 12.00 90.00 12470.00 91.68 96.20 8821.88 -1135.23 6493.50 12.00 0.11 -12.00 -89.00 Survey MD Incl Azim SSTVD N/S MapN- M:~pE VS DLS TFO Tool ft deg deg ft ft 'ft ft ft (jeg/109ft (jeg 10563.00 37.90 105.48 8596.85 -740.49 5976184.13 669220.69 4803.53 0.00 0.00 TIP 10575.00 38.94 103.38 8606.25 -742.34 5976182.43 669227.95 4810.98 13.93 307.84 MWD 10600.00 41.23 99.30 8625.38 -745.49 5976179.63 669243.79 4827.06 13.93 309.49 MWD 10625.00 43.65 95.58 8643.83 -747.66 5976177.83 669260.56 4843.84 13.93 312.61 MWD 10650.00 46.18 92.19 8661.54 -748.85 5976177.03 669278.18 4861.26 13.93 315.35 KOP 10670.00 47.75 93.41 8675.19 -749.56 4830.85 5976176.64 669292.79 4875.65 9.00 30.00 1 10675.00 48.07 94.09 8678.54 -749.81 4834.55 5976176.47 669296.50 4879.31 12.00 57.50 MWD 10700.00 49.75 97.38 8694.97 -751.69 4853.29 5976175.00 669315.28 4898.00 12.00 57.04 MWD 10725.00 51.52 100.52 8710.83 -754.71 4872.38 5976172.40 669334.42 4917.27 12.00 54.88 MWD 10750.00 53.37 103.50 8726.07 -758.84 4891.76 5976168.70 669353.89 4937.09 12.00 52.89 MWD 10775.00 55.29 106.34 8740.65 -764.07 4911.38 5976163.90 669373.61 4957.38 12.00 51.07 MWD 10800.00 57.27 109.05 8754.53 -770.39 4931.18 5976158.01 669393.55 4978.10 12.00 49.41 MWD 10825.00 59.31 111.64 8767.67 -777.79 4951.12 5976151.05 669413.64 4999.19 12.00 47.91 MWD 10850.00 61.39 114.12 8780.04 -786.24 4971.13 5976143.05 669433.83 5020.59 12.00 46.55 MWD 10875.00 63.52 116.50 8791.60 -795.72 4991.16 5976134.01 669454.07 5042.24 12.00 45.32 MWD 10892.08 65.00 118.08 8799.02 -802.77 5004.83 5976127.26 669467.89 5057.14 12.00 44.22 2 10900.00 65.72 117.39 8802.32 -806.12 5011.21 5976124.05 669474.34 5064.11 12.00 319.15 MWD 10925.00 68.01 115.29 8812.14 -816.32 5031.81 5976114.31 669495.15 5086.48 12.00 319.43 MWD 10950.00 70.33 113.25 8821.03 -825.92 5053.11 5976105.18 669516.66 5109.39 12.00 320.26 MWD 10952.89 70.60 113.02 8822.00 -826.99 5055.61 5976104.16 669519.19 5112.07 12.00 320.98 E-09B TS 10975.00 72.67 111.28 8828.96 -834.90 5075.05 5976096.68 669538.79 5132.79 12.00 321.06 MWD 11000.00 75.03 109.35 8835.92 -843.23 5097.57 5976088.85 669561.48 5156.60 12.00 321.61 MWD 11000.32 75.07 109.32 8836.00 -843.34 5097.86 5976088.75 669561.78 5156.91 12.00 322.15 E-09B 11025.00 77.41 107.46 8841.87 -850.90 5120.60 5976081.69 669584.68 5180.77 12.00 322.15 MWD 11050.00 79.80 105.61 8846.81 -857.87 5144.09 5976075.24 669608.32 5205.23 12.00 322.60 MWD 11075.00 82.20 103.79 8850.72 -864.13 5167.98 5976069.50 669632.33 5229.91 12.00 322.96 MWD 11100.00 84.61 101.99 8853.59 -869.67 5192.18 5976064.49 669656.65 5254.74 12.00 323.25 MWD 11125.00 87.02 100.20 8855.42 -874.46 5216.65 5976060.24 669681.21 5279.66 12.00 323.45 MWD 11150.00 89.43 98.42 8856.19 -878.50 5241.30 5976056.74 669705.95 5304.59 12.00 323.58 MWD 11155.85 90.00 98.00 8856.22 -879.34 5247.10 5976056.03 669711.76 5310.42 12.00 323.64 3 11175.00 90.00 95.70 8856.22 -881.62 5266.10 5976054.16 669730.81 5329.46 12.00 270.00 MWD 11200.00 90.00 92.70 8856.22 -883.46 5291.03 5976052.88 669755.77 5354.16 12.00 270.00 MWD 11225.00 90.00 89.70 8856.22 -883.98 5316.03 5976052.90 669780.77 5378.63 12.00 270.00 MWD ) BP ) C Baker Hughes INTEQ Planning Report IN'TRQ ~olIlpa~y: BÞ . Amoco Date; ... ...41saOO2 Time:...J2:þ4~SO Field: PiUdhOf) Bay Ç~~"«Iï~~~~)~ø'êtêìJ~: . VV~IJ:;I;~OØ.TrueNQrtfï Site: PRE Pad Veffi~aI(!'~).Refe~'¡Ø# S~.~~:MøØ~:Se~ ~~~è! Well: E-Q9 seetiÔQ; (V~)Jtefe..ençe: - - Well. (Q.OON,O.OGE,1~.OO~i) Wellpath: Plao#6 E~09B SurveyC3lçulåti~..~~thöd: . MioimunirCùrvature Db: ()r'acle Survey MD Iud Azim SSTVD N/S MftP~ -~p~ DLS TFO ft deg dëg ft ft ft It - d~1l)()ft -de9 11250.00 90.00 86.70 8856.22 -883.20 5976054.23 669805.73 5402.80 12.00 270.00 MWD 11275.00 90.00 83.70 8856.22 -881.11 5976056.87 669830.58 5426.60 12.00 270.00 MWD 11300.00 90.00 80.70 8856.22 -877.71 5390.69 5976060.80 669855.27 5449.97 12.00 270.00 MWD 11320.00 90.00 78.30 8856.22 ~874.07 5410.35 5976064.88 669874.85 5468.31 12.00 270.00 4 11325.00 90.05 78.90 8856.22 -873.08 5415.25 5976065.97 669879.72 5472.86 12.00 85.00 MWD 11350.00 90.31 81.89 8856.14 -868.91 5439.90 5976070.68 669904.27 5495.94 12.00 85.00 MWD 11375.00 90.57 84.88 8855.94 -866.03 5464.73 5976074.11 669929.03 5519.48 12.00 85.01 MWD 11400.00 90.83 87.87 8855.64 -864.45 5489.67 5976076.24 669953.93 5.543.43 12.00 85.03 MWD 11425.00 91.09 90.86 8855.22 -864.17 5514.67 5976077.06 669978.91 5567.72 12.00 85.07 MWD 11450.00 91.34 93.85 8854.69 -865.20 5539.64 5976076.59 670003.90 5592.28 12.00 85.12 MWD 11475.00 91.59 96.84 8854.05 -867.52 5564.52 5976074.81 670028.82 5617.05 12.00 85.18 MWD 11500.00 91.84 99.83 8853.30 -871.14 5589.24 5976071.73 670053.61 5641.95 12.00 85.26 MWD 11525.00 92.08 102.82 8852.44 -876.05 5613.74 5976067.36 670078.21 5666.92 12.00 85.35 MWD 11550.00 92.31 105.81 8851.48 -882.23 5637.94 5976061.72 670102.54 5691.90 12.00 85.45 5 11575.00 92.31 102.81 8850.48 -888.40 5662.14 5976056.08 670126.87 5716.87 12.00 270.00 MWD 11600.00 92.30 99.81 8849.47 -893.30 5686.63 5976051.72 670151.46 5741.83 12.00 269.88 MWD 11625.00 92.29 96.81 8848.47 -896.91 5711.35 5976048.65 670176.25 5766.73 12.00 269.76 MWD 11650.00 92.26 93.80 8847.48 ~899.22 5736.22 5976046.89 670201.16 5791.48 12.00 269.64 MWD 11675.00 92.24 90.80 8846.49 -900.22 5761.17 5976046.43 670226.13 5816.02 12.00 269.52 MWD 11700.00 92.20 87.80 8845.53 -899.91 5786.15 5976047.29 670251.10 5840.29 12.00 269.40 MWD 11725.00 92.16 84.80 8844.58 -898.30 5811.08 5976049.45 670275.98 5864.21 12.00 269.28 MWD 11750.00 92.11 81.80 8843.64 -895.39 5835.89 5976052.90 670300.72 5887.73 12.00 269.17 6 11775.00 92.11 84.80 8842.72 -892.47 5860.70 5976056.36 670325.46 5911.25 12.00 90.00 MWD 11800.00 92.10 87.80 8841.80 -890.86 5885.62 5976058.52 670350.34 5935.18 12.00 90.11 MWD 11825.00 92.09 90.80 8840.89 -890.55 5910.60 5976059.38 670375.30 5959.45 12.00 90.22 MWD 11850.00 92.07 93.80 8839.98 -891.56 5935.56 5976058.92 670400.28 5983.99 12.00 90.33 MWD 11875.00 92.04 96.81 8839.08 -893.86 5960.44 5976057.16 670425.20 6008.75 12.00 90.44 MWD 11900.00 92.01 99.81 8838.20 -897.47 5985.16 5976054.09 670449.99 6033.65 12.00 90.55 MWD 11925.00 91.97 102.81 8837.33 -902.37 6009.65 5976049.73 670474.58 6058.62 12.00 90.65 MWD 11950.00 91.93 105.81 8836.48 -908.55 6033.86 5976044.09 670498.92 6083.59 12.00 90.76 MWD 11975.00 91.88 108.81 8835.65 -915.98 6057.71 5976037.18 670522.93 6108.51 12.00 90.86 MWD 12000.00 91.83 111.81 8834.84 -924.65 6081.14 5976029.03 670546.54 6133.29 12.00 90.96 MWD 12025.00 91.77 114.81 8834.05 -934.54 6104.09 5976019.64 670569.70 6157.87 12.00 91.06 MWD 12050.00 91.71 117.81 8833.29 -945.62 6126.49 5976009.06 670592.33 6182.18 12.00 91.15 MWD 12075.00 91.64 120.81 8832.56 -957.85 6148.27 5975997.31 670614.38 6206.16 12.00 91.24 MWD 12100.00 91.57 123.81 8831.86 -971.21 6169.39 5975984.42 670635.78 6229.74 12.00 91.33 MWD 12125.00 91.49 126.82 8831.19 -985.65 6189.78 5975970.43 670656.48 6252.86 12.00 91.41 MWD 12150.00 91.41 129.81 8830.55 -1001.15 6209.39 5975955.37 670676.42 6275.45 12.00 91.50 MWD 12170.00 91.35 132.21 8830.07 -1014.27 6224.47 5975942.58 670691.79 6293.10 12.00 91.57 7 12175.00 91.36 131.61 8829.95 -1017.61 6228.19 5975939.33 670695.58 6297.47 12.00 271.00 MWD 12200.00 91.41 128.61 8829.35 -1033.71 6247.30 5975923.65 670715.04 6319.72 12.00 270.99 MWD 12225.00 91.45 125.61 8828.73 -1048.79 6267.23 5975909.01 670735.29 6342.53 12.00 270.91 MWD 12250.00 91.50 122.61 8828.08 -1062.80 6287.92 5975895.46 670756.28 6365.84 12.00 270.84 MWD 12275.00 91.53 119.61 8827.42 -1075.71 6309.31 5975883.02 670777.95 6389.59 12.00 270.76 MWD 12300.00 91.57 116.61 8826.75 -1087.49 6331.35 5975871.73 670800.24 6413.71 12.00 270.68 MWD 12325.00 91.60 113.61 8826.06 -1098.09 6353.98 5975861.63 670823.10 6438.14 12.00 270.60 MWD 12350.00 91.62 110.61 8825.35 -1107.49 6377.13 5975852.73 670846.44 6462.82 12.00 270.52 MWD 12375.00 91.64 107.61 8824.64 -1115.67 6400.74 5975845.07 670870.23 6487.66 12.00 270.43 MWD 12400.00 91.66 104.61 8823.92 -1122.61 6424.75 5975838.67 670894.38 6512.61 12.00 270.35 MWD 12425.00 91.67 101.61 8823.20 -1128.27 6449.08 5975833.54 670918.83 6537.60 12.00 270.26 MWD 12450.00 91.68 98.60 8822.47 -1132.66 6473.68 5975829.70 670943.52 6562.55 12.00 270.17 MWD 12470.00 91.68 96.20 8821.88 -1135.23 6493.50 5975827.56 670963.39 6582.45 12.00 270.09 TD Well # ¿"(;'fS)- DatA) ol/$/J!fJ2 All Measurements are from top of Riser 3/14/2002 from top of floor to rig mats 11181 of room under floor to rig mats L- Q) en .- a: Flanae to Flanqe Helahts 711 otis x-a .70' top of bag BAG 2.80' bttm of bag ., Blind/Shears ., middle of slips ., ..'. " /' TOTs 1.90' middle of pipes 2-3/8" pipe/slips ,./ ...,. ~ ,.--.. Mud Cross Mud Cross 1.70' middle of flow cross ----- ~ 3-1/211 pipe/slips ~ middle of blind/shears / TOTs 1.90' / ;¡.:, middle of pipe/slips 2-3/8 X 3.5 Var. pipe ,. middle of master ~'~''', ~-'~.. . .", ~m~. ~ , ìftr'\tl';J,'l.,~. ~Þir. .. -imlßfllI ~'b~~ . ~~~\.~ ¡~~I"'~'~' ;ï~'ii.;~"~ r, '..~.tu~)I,ij~'~..~ "I ~ I ='.-<' . .. ""'t'I '... ~'i: 'I , ¡ I ~ ,"' "....~ 1= i.' "I!I :. , . ~ f;i '¡ iff~~,. \;X~1,f.J. .L!> r-v,~m", ~ .~ "'~~~.. Lock down screws ~Ubing spoof adapter Tubing Spool .. Rig mats H DATE 7/12/02 CHECK NO. H207007 207007 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 7/12/02 INV# CK071002F PERMIT TO DRILL FEE ~~cA~ ,~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ PAY JULY 12, 2002 ****$100.00**** TO THE ORDER OF ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVE STE 100 ANCHORAGE, AI<. 99501 r.~.~.L{~AL!l?.l\J::~tl:.Jl.~;Dh',t.8 ...;-,....::....: :.:-....,.~.-.., ~ :. .;.<: . :.:.:.,... ":":- :':":')Z:. ..:...... ":':'. '. :.:.: 'X','. :',,1 .:.;..¡\:~~~ ~'iï'"''-:'''''~''''''''::'''''';:''''' j~~;~~ .{g~;}~;:i~~~;¡;~;;';~;;'¡:::¿;:;~ III 20 700 7111 1:0 l. ~ 2038 Ii 51: 008l. ~ ~ qlll H "-'/ ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /¿U £-09 ~ PTD# 202- /h"/ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well , Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ð f J¿ WELL NAME flit{ £"-016 PROGRAM: Exp - Dev.x.. Redrll2Š- Re-Enter - Serv - Wellbore seg- .FIELD & POOL C; ~C>I...Ç-ð INIT CLASS fJ"~J/ /--0.// GEOL AREA 9 f 0 UNIT# //C.f' (") ON/OFF SHORE.0L0 ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . ty\ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number.. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N . ;(J~ "" IJ ¿,., 8. If deviated, isweltbore plat included.. . . . . . . . . . . . . . Y N I)C' G..L!./1:!",- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . .::tJ N . (Service Well Only) 13. Wellloc. ated w/in area & strata authorized by injection order#- Y / A /, A. (Service Well Only) 14. All wells w/in y.¡ mile area of review identified. . . . . . . . .. / N / \,.. ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ N 16. Surface casing protects all known USDWs. . . . . . . . . . . l.Y N II 17. CMT vol adequate to circulate on conductor & surf csg. . . . . .¥--N- !'fit- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N - . 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N M..ecbtt...(~iA f4-CR<; <;;, , 20. Casing designs adequate for C, T, B & permafrost. . . . . . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N c;r U 22. If a re-drill, has a 1 0-403 fo~ abandonment been approved. .. ¥ b N 23. Adequate wellbore separation proposed.. . . . . . . . . . . . uc N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥-f";J- A././Æ- 25. Drilling fluid program schematic & equip list adequate. . . . . ~ N APPR DATE ~~: ~g~~spr~~:~:iïn~e:~~~~~~i:~~~te~tto' 'Š600' . . . . 'P~ig. á2~ MSP L"tlt! f~/' . j I 'GA- gIll 0" 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 1iZ N vY ~ '- 29. Work will occur without operation shutdown. . . . . . . . . .. Œ! N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥---N-l\i./Æ- 32. Permit can be issued w/o hydrogen sulfide measures. . . . . Y &þ 33. Data presented on potential overpressure zones. . . . . . . . ÃN A / /J¡ 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / r"...--, '7. 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N 36. Contact name/phone for weekly progress reports. . . . . . . . Y N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RPC§( TEM JDH.J~ ~ JBR (Service Well Only) GEOLOGY APPR DATE ~fJ/ ~/;hL '(~~ploratory Only) Rev: 07/12/02 SFD- WGA 'vJ4A- MJW G:\geology\permits\checklist.doc ) COMMISSIONER: COT DTS CJ(cl (0<- Comments/Instructions: ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special. effort has been made to chronologically organize this category of information. ) ) ~ Œ.-/0/ III "") /'- . . £~h5 t) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revislon: 4 $ Thu Mar 13 14:46:21 2003 Reel Header Service name.............LISTPE Date.....................03/03/13 Origin. . . . . . . . . . . . . . .. . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.....................03/03/13 Origin. . . . . . . . . . . . . . . . .. . STS Tape Name................ UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay M'ViJD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA E-09B 500292046602 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 13-MAR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW2214800000 J. PANTER lJ!CCARTY 1 SA MWD RUN 2 MW2214800000 J. PANTER MCCARTY 1 SA # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 6 UN HE 243 500 65.01 30.76 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 5.000 10680.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . ) ) 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS AT ABOUT 10680'MD/8682'TVDSS IN THE E-09A WELLBORE. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAl'1MA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. UFHOLE TIE-IN DATA (SGRC) ARE INCLUDED IN RUN 1. 5. LOG AND MERGED DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER WIRELINE GAMMA RAY LOG ACQUIRED IN THE E-09B WELLBORE ON 7 SEPTEMBER 2002. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. THESE DATA WERE PROVIDED BY D. SCHNORR, BP EXPLORATION (ALASKA), INC., ON 1/09/03. 6. MWD RUNS 1 & 2 REPRESENT WELL E-09B WITH API#: 50-029-20466-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12725'MD/8817'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA. RAY COMBINED. $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/13 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 10395.0 10684.0 STOP DEPTH 12681.5 12709.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 10395.0 10399.0 10403.0 10412.0 10426.0 10430.0 10432.5 10438.5 10657.0 10673.0 10679.0 10689.0 10693.0 10698.0 10701. 0 10704.0 10713.0 10720.5 10732.5 10738.0 DE PT H GR 10412.5 10416.5 10420.5 10429.0 10443.5 10447.5 10450.5 10455.5 10673.5 10689.0 10696.0 10704.5 10709.5 10713.5 10716.5 10720.0 10729.0 10737.0 10749.0 10753.5 ) ) 10739.5 10747.5 10749.5 10766.0 10769.0 10771.5 10776.5 10786.0 10794.0 10801. 5 10817.0 10823.0 10825.5 10834.5 10840.0 10845.0 10850.5 10852.5 10856.5 10869.5 10875.0 10884.5 10887.5 10897.5 10904.0 10906.0 10910.0 10941.0 10950.5 10956.5 10962.5 10971.0 10976.0 10980.5 10994.0 11001.5 11004.5 11006.0 11011.0 11014.0 11018.5 11026.5 11028.5 11035.0 11056.0 11063.5 11073.5 11076.0 11080.0 11085.0 11087.0 11105.0 11112.5 11144.0 11161.5 11183.5 11194.5 11200.5 11218.5 11236.5 11250.5 11253.0 11261.5 11266.0 11284.5 11300.0 11305.5 11311.0 11314.5 11320.0 11344.0 11354.0 11372.5 11397.5 11416.0 10755.5 10763.5 10767.0 10781. 0 10785.5 10787.5 10793.0 10801.5 10809.5 10818.0 10830.5 10837.0 10839.5 10850.5 10855.5 10860.5 10866.5 10869.5 10873.5 10885.0 10890.0 10900.5 10903.5 10914.5 10920.5 10923.0 10928.0 10958.5 10968.0 10973.5 10977.5 10987.5 10991.5 10997.0 11012.0 11018.0 11021. 5 11023.0 11028.0 11031. 5 11038.5 11045.5 11047.0 11054.0 11074.0 11081.0 11090.0 11091.5 11097.5 11103.5 11105.0 11123.5 11133.0 11166.5 11183.5 11205.0 11217 . 0 11223.0 11241.5 11261.0 11275.0 11277.0 11282.5 11286.5 11304.5 11317 .5 11323.0 11330.0 11335.5 11339.0 11363.5 11374.0 11389.0 11413.5 11433.5 ) 11426.5 11431. 5 11457.0 11464.5 11497.0 11503.5 11518.5 11550.5 11554.0 11560.0 11566.0 11577.0 11591. 0 11600.5 11615.5 11631. 0 11636.5 11658.5 11668.0 11676.5 11684.5 11686.5 11692.5 11698.0 11707.5 11731. 5 11733.5 11743.0 11750.0 11 763. 0 11774.5 11782.0 11791.5 11820.5 11842.0 11870.0 11909.5 11915.5 11924.0 11929.5 11979.5 12004.5 12016.0 12020.5 12033.5 12038.0 12044.5 12053.0 12056.5 12063.5 12079.0 12090.5 12095.5 12103.5 12109.0 12122.5 12124.5 12132.5 12141. 0 12148.5 12164.5 12186.0 12194.5 12204.0 12207.0 12219.5 12226.0 12235.0 12243.0 12248.0 12256.5 12260.0 12273.5 12280.5 12283.0 11443.5 11447.0 11473.0 11480.0 11512.5 11518.5 11533.0 11564.5 11568.5 11575.0 11581.0 11592.0 11609.0 11617.0 11630.0 11644.5 11650.0 11670.5 11678.5 11687.5 11696.0 11698.5 11704.0 11710.5 11 722.0 11744.5 11747.5 11757.0 11764.5 11776.5 11788.0 11796.5 11806.0 11835.0 11855.5 11884.0 11925.0 11931. 5 11939.5 11946.0 11993.5 12017 . 5 12027.0 12032.0 12047.0 12051. 0 12059.0 12068.0 12072.0 12079.0 12093.5 12106.5 12112.0 12120.0 12124.0 12138.5 12140.0 12149.0 12157.5 12166.5 12184.0 12204.0 12212.0 12220.0 12223.0 12234.0 12242.5 12250.0 12259.0 12265.0 12272.5 12275.0 12289.5 12295.0 12297.5 ) ) 12291.0 12299.5 12322.0 12334.0 12335.5 12337.5 12340.5 12344.0 12346.5 12356.0 12362.5 12404.0 12429.0 12441. 0 12457.0 12467.0 12476.5 12489.5 12493.5 12501. 5 12509.5 12526.0 12532.5 12564.0 12568.0 12575.5 12584.0 12587.0 12608.0 12609.0 12617.5 12642.0 12645.5 12647.0 12709.0 $ 12304.5 12310.5 12332.5 12343.5 12345.0 12347.5 12351.0 12355.0 12358.0 12369.5 12374.0 12416.5 12439.5 12453.0 12470.0 12481. 5 12493.5 12506.5 12511. 5 12518.0 12527.5 12542.5 12548.5 12578.5 12582.0 12591. 0 12599.0 12603.0 12623.5 12624.5 12633.5 12657.0 12661. 0 12663.5 12725.5 # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 10412.5 2 11157.5 MERGE BASE 11157.5 12725.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10395 12709 11552 4629 10395 12709 ROP MWD FT/H 0.44 2149.1 100.742 4051 10684 12709 GR MWD API 13.12 252.66 71. 6457 4143 10395 12681.5 First Reading For Entire File..........l0395 Last Reading For Entire File...........12709 ) File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number............. .1.0.0 Date of Generation.......03/03/13 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name............. ..STSLIB. 002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/13 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NU!'-1BER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENPOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10412.5 10700.5 STOP DEPTH 11130.0 11157.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR GM $ BOTTOM) TOOL TYPE DUAL GAMMA R.~Y Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TER}1PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 01-SEP-02 Insite 4.3 Memory 11155.0 10700.0 11155.0 54.1 81. 6 TOOL NUMBER 69706 69706 3.750 10680.0 Flo Pro 8.80 8.0 8.5 24000 6.4 .000 .000 .000 .000 .0 137.9 .0 .0 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Doí~ Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10412.5 11157.5 10785 1491 10412.5 11157.5 ROP MWD010 FT/H 3.13 1066.41 95.3093 915 10700.5 11157.5 GR MWD010 API 13.12 252.66 55.6839 1006 10412.5 11130 First Reading For Entire File..........10412.5 Last Reading For Entire File...........11157.5 File Trailer Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/13 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name..... ..... ...STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/13 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OO2 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11130.5 ROP 11158.0 $ 3 header data for each bit run in separate files. 2 .5000 STOP DEPTH 12698.0 12725.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR GM $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (1'11'): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT 1'11': MUD CAKE AT 1'11': # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O 03-SEP-02 Insìte 4.3 Memory 12725.0 11155.0 12725.0 84.5 96.9 TOOL NUMBER 69706 69706 3.750 10680.0 Fl0 Pro 8.70 7.0 8.5 23000 5.8 .000 .000 .000 .000 .0 155.5 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11130.5 12725.5 11928 3191 11130.5 12725.5 ROP HWD020 FT/H 0.44 2149.1 103.045 3136 11158 12725.5 GR MWD020 API 42.63 172.62 76.5435 3136 11130.5 12698 ) First Reading For Entire File..........11130.5 Last Reading For Entire File...........12725.5 File Trailer Service name............. STSLIB. 003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/03/13 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OO4 Physical EOF Tape Trailer Service name.............LISTPE Date.....................03/03/13 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name........... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Da te. . . . . . . . . . . . . . . . . . . . .03/03/13 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File