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Home My WebLink About203-114 ) ) 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. dO.3 - J L ~ Well History File Identifier 111111111111111111 Date: g.) 7/ D0 Isl yV j + 1I.Q:..- = TOTAL PAGES t.4 (Count does not include cover shèet) \ 11" i'() 151 V , VJ 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: Lf 7 (Count does inCIUd?er sheet) Page Count Matches Number in Scann~ng prey. ar~tion: V YES BY: JMaria ) Date: ~ I 17 ¡ ob Stage 1 If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 11111111/1111111111 RESCAN ~Ior Items: o Greyscale Items: DI~AL DATA ¡;z("Diskettes, No.1 o Other, No/Type: D Poor Quality Originals: o Other: NOTES: BY: ÇMari~ ) Date: ;;< '7>:;/0 Project Proofing BY: ~ Scanning Preparation BY: CMaria ") J x 30 = 30 Date: dv ¡ {710h BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed III 1I1I1II1 II 111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: ~ rn 151 NO Isl Wlp NO YES Isl 111I111111111111111 1111111111111111111 151 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • ,rr , ~ '• ~ 03/0112008 D0 NOT PLACE s ~_ _~;'..: ~~ ` ~x~. :.~; ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc STATE OF ALASKA ~- -.08' ~'` ~/ ~~t ~~ ALASKA~L AND GAS CONSERVATION COMMTSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~ ~ ~ ~~~~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 20AAC 25.105 2oAAC 2s.~io ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero ~q(CI~9S CUn~. ~:~rrtmisslDn 1251 Develo~~8 ,Exploratory ^ Service e f ~ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/6/2007 12. Permit to Drill Number 203-114 - 307-309 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/9/2004 ~ 13. API Number 50-029-20726-01-00 4a. Location of Well (Governmental Section): Surface: 120 ' SNL 237' EWL SEC 7. Date T.D. Reached 1/12/2004 ~ 14. Well Name and Number: PBU 15-04A , , 6 . 22, T11N, R14E, UM Top of Productive Horizon: 1298' SNL, 4002' WEL, SEC. 21, T11 N, R14E, UM 8. KB (ft above MSL): 63' Ground (ft MSL): 15. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Bay Total Depth: 133' NSL, 5136' WEL, SEC. 16, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 9808 8483 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676169 y- 5960280 Zone- ASP4 10. Total Depth (MD+TVD) 12295 8897 16. Property Designation: ADL 028306 TPI: x- 671933 y_ 5960091 Zone- ASP4 Total Depth: x- 670764 y- 5961495 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD / GR /CCL /Press, GR / CNL /CCL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 400 sx Perm fro II 13-3/8" 72# L-80 Surface 2649' Surface 2649' 17-1/2" 2000 sx Fondu 400 sx PF'C' 9-5/8" 47# L-aoisoo-ss Surface 9588' Surface 8305' 12-1/4" 500 sx Class'G' 7" 2 L-80 9270' 10460' $061' 8940' $-1 /2" 350 sx'G' (7" 26# L-80, Liner Tieback 24s1' - 9167') 4-1/2" 12.6# L-80 9159' 10438' 7977' 8940' N/A Liner Tieback 2-3/8" 4.6# L-80 9820' 12098' 8494' 8912' 3" 78 sx Class 'G' 23. Open to production or inject ion? ^ Yes ®No 24. TueING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD None 3-1/2", 9.2#, 13Cr80 9087' 9002' MD TVD MD TVD 3-1/2", 9.3#, L-80 9080' - 9202' 9112' Q (~(~q ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~'0 JHi~ ~ a~7ta'0 ® ~UUU DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 9850' Set CIBP 9808' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITV-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Core s A uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250,071. i.~~~ None jj~~ {{ (y ~ii..?i k~:`~~ ~$,_. al~~ y. ~ ~oaU r Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE / 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD WeIlTested. ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 2A / 21 TS 10188' 8809' None Zone 1 B 10275' 8883' Zone 1A / TDF 10344' 8924' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra" tewma ~' ,«_-~ Title Drilling Technologist Date f - "U~ PBU 15-04A 203-114 307-309 Prepared ey Name/luumber.~ Sondra Stewman, 564-4750 Well Number Drilling Engineer: Sean McLaughlin, 564-4387 Permit No. / A royal No. INSTRUCTIONS GeNew-~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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 29: 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 25.07E Form 10-407 Revised 02/2007 Submit Original Onty TREE = FMC GEN 2 WELLHEAD = FMC ACTUATOR= AXELSON KB. ELEV = 63' BF. ELEV = KOP = 3039' Max Angle = 93 @ 11985' Datum MD = 10240' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2649' Minimum ID =1.920" @ 9827" 3" X 2-3/8" XO 3-1/2" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" 17" TIEBACK LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, O = 2.992" ~- TOP OF 7" LNR - 9-5/8" CSG, 47#, L-80, ID = 8.681" - BAKER WHIPSTOCK (12/07/07) RA TAG PERFORATION SUMMARY REF LOG: ANGLEATTOPPERF: 70° @ 10360' Note: Refer to Production DB for histor~al perf data SIZE I SPF I INTERVAL I Opn/Sqz I DATE ~ SEE PAGE 2 FOR PERFORATION ~VFORMATION 15 -0 4A SAFETY NOTES: 3-1 /2" CHROME TBG. 2199' I~ 3-y2" HES X NIP, ID = 2.813" 2451' 9-5/8" X 7" BKR LNR TOP PKR, ID = ??? GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3354 3342 19 MMG DMY RK 0 07/30/06 3 5556 5217 34 MMG DMY RK 0 07/30/06 2 7286 6612 42 MMG DMY RK 0 01/30/04 1 8921 7798 42 MMG DMY RK 0 01/30/04 8980' ~ 3-1/2" HES X NIP, ID = 2.813" 9002' 7 X 3-1/2" PKR S-3 PROD PKR. ID = 3.875 9027' 3-1/2" HES X NIP, ID = 2.813" 9087' UNIQUE OVERSHOT 9112' 7-1/2" X 3-1/2" BKR FB-1 PKR, ID = 4.0" 9115' 3-1/2" BKR SEAL BORE EXTENSION 9124' 3-1/2" BKR CONCENTRENIC COUPLING 9125' 3-1/2" BKR SEAL BORE EXTENSION 9130' 3-112" BKR MILLOUT EXTENSION 9159' 9-518" X 4-1 /2" BKR HYFLO HGR w /TIEBACK 9~ 171' I-13-1/2" OTIS XN NIP, ID = 2.75" 9202' 3-1/2" WLEG, ID = 2.992" 9~1 ELMD TT LOGGED 12/04/90 MILLOUT W~1DOW 10194' - 10216' ' 9820' 3.0" BKR D~LOY SLV, ID = 2.250" 9827' 3" X 2-3/8" XO, ID = 1.92 9850' 2-318" BKRC~P(12/07/07) 1 9202' I 12064' I-I ~~ i4-1/2" SCAB LNR, 12.6#, L-80, .0152 bpf., ID = 3.958" ~-i 10438• 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10460' 2-3/8" LNR, 4.6#, L-80, .0036 bpf, O = 1.920" ~ 12098' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/26/82 ORIGINAL COMPLETION 05/28/07 JAFJTLH CORRECTIONS (SCAB LNRS) 12/04!90 LAST WORKOVER O6/01!07 CJAJPAG ADPERFS (05/30/07) 01/18/04 DAV/KA CTD SIDETRACK (15-04A) 12/07!07 TEL/PJC SET WHIPSTOCK/ CIBP 01/30/04 DTR/KAK GLV C/O 07130!06 DRF/PAG GLV C/O 04!29!07 SGS/TLH PERFS (04/14/07) PRUDHOE BAY UNfT WELL: 15-04A PERMff No: 2031140 API No: 50-029-20726-01 SEC 22, T11 N, R14E, 4012.86' FEL 8~ 1330.03' FNL BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: 70° @ 10360' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-9116" 6 10360 - 10380 C 05!30/07 1-11/16" 6 10526 - 10556 C 04/14/07 1-11/16" 6 10648 - 10708 G 04/14107 1-11/16" 4 10790 - 10810 C 01/15/04 1-11116" 4 10975 - 10995 C 01/15104 1-11/16" 4 11030 - 11230 C 01/15/04 1-11/16" 4 11330 - 11520 C 01!15/04 1-11/16" 4 11530 - 11930 C 01/15/04 1-11116" 4 12010 - 12061 C 01/15/04 DATE REV BY COMMENTS DATE REV BY COMMENTS 04/26/82 ORIGINAL COMPLETION 05/28/07 JAF/TLH CORRECTIONS (SCAB LNRS) 12/04/90 LAST WORKOVER 06/01/07 CJA/PAG ADPERFS(05/30/07) 01/18!04 DAV/KA CTD SIDETRACK (15-04A) 12/07/07 TEL/PJC SET WHIPSTOCK / CIBP 01/30/04 DTR/KAK GLV GO 07/30/06 DRF/PAG GLV GO 04/29!07 SGS/TLH PERFS (04/14/07) PRUDHOE BAY UNff WELL: 15-04A PERMff No: FZ031140 API No: 50-029-20726-01 SEC 22, T11 N, R14E, 4012.86' FEL & 1330.03' FNL BP Exploration (Alaska) 15-04A Digital Well File ~ • Page 1 of 2 Well: 15-04 Well History Well Date Summary 15-04A 10/25/2007 T/IA/OA= 200/600/0 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (PRE CTD ) PPPOT-T RU 2 HP bleed tools onto THA test void 100 psi bleed to 0 psi. Flushed void until clean returns achieved, cycle and re-torque LDS " ET style "all moved easily with no damage on pins. Pressured test void to 5000 psi for 30 minute test, 4900/ 15 mins, 4850/ 30 mins. Bleed test void to 0 psi RD test equipment. PPPOT-IC RU 2 HP bleed tools onto IC test void 400 psi bleed to 0 psi. Flushed void until clean returns achieved, cycle and re-torque LDS "Standard "all moved easily with no damage on pins. Pressured test void to 3500 psi fora 30 minute test, 35001 15 mins, 3450/ 30 mins. Bleed void to 0 psi, Replaced Alemite fitting on IC would not seat. RD test equipment. 15-04A 12/4/2007 ***WELL S/I ON ARIVAL*** (Pre ctd) DRIFTED 1.75" CENT INTO 2 3!8" LINER, SD @ 10218' SLM DUE TO DEVIATION ***CONTINUED ON WSR 12/05/07*** 15-04A 12/5/2007 TIO = 2370/590/40. Temp = SI. T FL (pre-ELine). No AL. T FL @ 9180'. 15-04A 12/5/2007 ***CONTINUED FROM WSR 12/04/07*** (pre-ctd) RAN 15' OF 2.625" STEM AS DUMMY WHIPSTOCK DRIFT SD @ 9820' SLM ***WELL NORMALED UP, DSO NOTIFIED OF STATUS*** 15-04A 12/6/2007 T/I/0= 2300/600/0 Assist E-line as directed (CTD screening) MIT-T to 2000 asi PASSED MIT IA to 3000 psi PASSED Loaded tubing with 5 bbls 60/40 meth spear followed by 135 bbls 70*F crude at 5 bpm . Standby while SLB runs CIBP. Pumped 7.1 bbls Crude to reach MIT T test pessure of 2000 psi. MIT-T passed on 2nd test losing 0 in 1st 15 minutes and 0 psi in 2nd 15 minutes.. Bled Tubing psi back to 0 psi. Rigged down from tubing and up to IA. Pumped 14 bbls Crude to reach MIT IA psi of 3000 psi. IA lost 80 psi in 1st 15 minutes and 40 psi in 2nd 15 minutes for a Pass. Bled IA psi down to 480 psi getting 4 bbls Crude back before returns turned to Gas. Rigged down off of IA and rig upon OA. Reached MIT OA test psi with 4.2 bbls Crude 15-04A 12/6/2007 T/1/O = 23701590/40. Temp SI. TBG, IA & OA FL (pre FB). TBG FL @ 9180' (341 bbls). IA FL @ 12' (.3 bbl). OAP FL near surface. 15-04A 12/6/2007 *''*WELL SHUT IN ON ARRIVAL*** INITIAL T/ I/ O = 2350/ 540/ 0 RUN 1: SET BAKER CIBP IN 2-3/8" AT 9850'. LRS PRESSURE TESTED TO 2000 PSI. PRESSURE TEST P RUN 2: RIH W/ BAKER THROUGH-TUBING WHIPSTOCK . ***JOB CONTINUED ON 7-DEC-2007 AWGRS*** 15-04A 12/6/2007 T/I/0= 2300/600/0 Assist E-line as directed (CTD screening) MIT-T to 2000 psi PASSED MIT IA to 3000 psi PASSED MIT-OA to 2000 psi PASSED. Loaded tubing with 5 bbls 60/40 meth spear followed by 135 bbls 70*F crude at 5 bpm .Standby while SLB runs CIBP. Pumped 7.1 bbls Crude to reach MIT T test pessure of 2000 psi. MIT-T passed on 2nd test losing 0 in 1st 15 minutes and 0 psi in 2nd 15 minutes.. Bled Tubing psi back to 0 psi. Rigged down from tubing and up to IA. Pumped 14 bbls Crude to reach MIT IA psi of 3000 psi. IA lost 80 psi in 1st 15 minutes and 40 psi in 2nd 15 minutes for a Pass. Bled IA psi down to 480 psi getting 4 bbls Crude back before returns turned to Gas. Rigged down off of IA and rig upon OA. Pumped 7 bbls Crude to reach MIT-OA psi of 2000 psi. MIT-OA passed 1st attempt, loss of 20 psi 1st 15 min, loss of 15 psi 2nd 15 min. bled back bled back 4 bbls. FWHP=0/520/0 Tags hung, casing valves open to gauges. 15-04A 12/7/2007 **'*WELL SHUT IN "*' (fish e-line tools) RETRIEVED E-LINE TOOL STRING FROM 9764' SLM TAG TOP OF WHIPSTOCK W/ 2.50" CENT. @ 9793' SLM ***WELL S/I ON DEPARTURE, TURN OVER TO DSO*** 15-04A 12/7/2007 ***CONTINUED FROM 6 DEC 07"' SET BAKER THROUGH-TUBING WHIPSTOCK IN 4-1/2" TUBING FROM 9,806' TO 9 818.95'. ITI NDI ATION OF SET, BUT UNABLE TO L G OFF I F ER KIN LINE DECISION WAS MADE TO BREAK WEAKPOINT. TOOL SCHEMATIC SENT TO PE'S. 1-3/8" FISHING NECK LOCATED AT 9776' FINAL T/I/O = 0/500/0. **'JOB COMPLETE*** 15-04A 12/9/2007 Set 41/16" CIW BPVft203 Pre Rig. Set Good. http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 12/28/2007 Digital Well File • • Page 2 of 2 15-04A 12/10/2007 T/I/O =SSV/450/20. SI. Bleed IA 8 OA to 0 psi (pre-CTD). IA FL @ 24',OA FL near surface. Bled OAP to 0 psi (40 min). Bled IA to bleed trailer,fluid/gas mix. Filled one bleed trailer max capacity (12 bbls), called to have BT vac'd-out. Continued bleed to another bleed trailer until Vac truck arrived. Had a total of 15 bbls vac'd-out of both BTs. Continue bleed to 45 psi. Changed out with day shift @ 0700 hrs. Day shift to continue IA bleed. IA all gas at 50 psi. Final WHPs =SSV/45/0. 15-04A 12/10/2007 Pulled 4" H BPV 15-04A 12/10/2007 TIll0=SSV/5410. Temp=St. Bleed fA & OA to 0 psi. (Pre-CTD). Continue from night shift. Night shift bled IAP to 25 psi, SI to go talk to CO Man &IAP increased 25 psi to 50 psi in 20 minutes. IAP increased an additional 4 psi during 10 minute change out. Bled IAP from 54 psi to 10 psi in 1 hour 45 minutes. Final WHP's=SSV/10/0. Print Date: 12/28/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 12/28/2007 BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: 15-04 Common Well Name: 15-04 Spud Date: 3/24/1982 Event Name: REENTER+COMPLETE Start: 12/10/2007 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 12/9/2007 20:00 - 00:00 4.00 MOB P PRE Move off DS7-086 and move to DS15.Had power outage as rig arrived on DS15 due to high engine temp. 12/10/2007 00:00 - 01:00 1.00 MOB P PRE Complete move to DS 15. 01:00 - 09:00 8.00 MOB N WAIT PRE Rig on standby. Wait on Bleed down of well and site prep. 09:00 - 11:00 2.00 MOB N WAIT PRE Wait on pad prep. Blade pad in front of well. Survey and blade level for rig. Installed SWS coiled tubing pipe straightener onto re-built 480 injecter head, while waiting. 11:00 - 12:00 1.00 MOB P PRE Move rig in front of well. 12:00 - 12:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing the rig over the well. 12:15 -13:00 0.75 MOB P PRE Back rig over well. Center rig over well and level rig. 13:00 - 17:30 4.50 BOPSU P PRE ACCEPT RIG AT 1300 HRS, 12/10/2007. Nipple up BOPE. Spot cuttings tank. Rig up hardline to Tiger Tank. Move in mini-camp and man camp. 17:30 - 21:00 3.50 BOPSU P PRE Pressure and function test ROPE. Test witnessed by AOGCC inspecter, Bob Noble. Send test report to AOGCC. Swab not holding. Call out grease crew Grease tree and pump open SSV. 21:00 - 00:00 3.00 BOPSU P PRE Test BOP against master. Rebuild choke valve #3. 12/11/2007 00:00 - 05:30 5.50 BOPSU P PRE Continue with BOP test 250 psi low and 3500 psi hi. 05:30 - 07:00 1.50 BOPSU P PRE PU Lubricator, PJSM, Stab lubricator and PT to 1000 psi. Pull BPV with lubricator. R/D lubricator. SIWHP = 200 psi. 07:00 - 08:30 1.50 RIGU P PRE M/U guide arch to injecter head after reel swap to 2" E-Coil and C/O to re-built injecter. 08:30 - 10:45 2.25 RIGU P PRE Align injecter, pipe straightener and guide arch. 10:45 - 11:00 0.25 RIGU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for pulling 2" E-Coil to injecter. 11:00 -12:30 1.50 RIGU P PRE Pull test grapple. Pull coil into injecter. Align and calibrate pipe straightener. 800 psi hyd. press. straightens 2", 110 coil. 12:30 - 13:15 0.75 RIGU P PRE Fill coil with 2# Biozan. Coil vol. = 40.0 bbls. Circ. across top of stack thru kill line to shaker to clean stack. Press test inner reel valve. Reverse circ thru coil at 3.2 bpm, 4150 psi. 3 times. Heard e-line zing first time for 30 sec. 13:15 - 14:00 0.75 RIGU P PRE Cut coil to find E-Line. Cut 32' of coil. 14:00 - 17:30 3.50 STWHIP P WEXIT M/U CTC and BHI UOC. E-Line tested OK. Bleed off 200 psi WHP to tiger tank. Well is dead. M/U Milling BHA #1 with 2.74" HCC diamond window mill, 2.73" reamer, BTT Xtreme motor. 2 jts 2-1/8" CSH and BHI tools. BHA OAL = 99.81'. 17:30 - 20:45 3.25 STWHIP P WEXIT RIH with 2.74" window milling BHA #1. Take retums to Tiger tank. 20:45 - 21:00 0.25 STWHIP P WEXIT Tag pinchpoint w/ pumps on at 9811'. Correct -3' to whipstock ~~i-(-rte pinch point at 9808'. Flag pipe. - ~ wm ow ru - x finer. pm, - psi, full returns, 1K WOB, 1 FPH. Printed: 12/19/2007 2:43:57 PM • • o ~ ~ ~ a SARAH PAUN, GOVERNOR <ai10-7~ O~ ~ ti0-7 333 W. 7th AVENUE, SUITE 100 CORSER~A,~`I011T COMI~IISSIOR ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 ~:c~~~~~ NOV ~ 9 2007 Anchorage, AK 99519-6612 ~,~ ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-04A Sundry Number: 307-309 Dear Mr. McLaughlin: 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 (907j 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. DATED this day of October, 2007 Encl. Sincerely. /~ ,~" STATE OF ALASKA ~ t' ALASKA OIL AND GAS CONSERVATION COMMISSION y~'f ~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 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 203-114 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20726-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 15-04A , Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028306 - 63' Prudhoe Bay Field / Prudhoe Bay Pool 12. ' PRESENT'WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured}: Junk (measured): 12295 - 8897. 12064 , 8914 - None None Casin Len th Size MD TVD Burst Colla se Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2649' 13-3/8" 2649' 2649' 4930 2670 Intermediate Production 9588' 9- /8" 9588' 8305' 6870 4760 Liner 1190' 7" 9270' - 10460' 8061' - 8940' 8160 7020 Liner Tieback 1279' 4-1/2" 9159' - 10438' 7677' - 8940' 8430 7500 Liner 2278' 2-3/8" 9820 - 12098' 8494' - 8912' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10360' - 12061' 8930' - 8914' 3-1 /2", 9.2# x 9.3#, 13Cr80 x L-80 9087, 9080' - 9202' Packers and SSSV Type: 7 x 3-1/2", S-3 Production Packer, Packers and SSSV MD (ft): 9002' 7-1/2" x 3-1/2" Baker FB-1 Packer 9112' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: October 15, 2007 ^ Oil ^ Gas ^ Plugged ®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 Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By Name/Number: 564-4750 Sondra Stewman 4 ~ C , ,/`,; Phone 56 -4387 Date (G 4 Signature - Commission. Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: ~~ APPRO~ED'BY' ~a'~ A roved B COMMISSIONER THE COMMISSION Date ~~ . . n, _, { u~~~ r Form 10-403 Revised 06/2 () Q ~ M f' '7 /~ ~~ ~~`~' ] S~u~ it I~~ticate ~RIGI AL 1`.1.~Wlr1J 1. r ~i • • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: October 4, 2007 Re: 15-04A Sundry request Sundry approval is requested for Prudhoe well 15-04A. 15-04A is a January 2004 Coil `Plus' Sidetrack completed in Z1A and Z1B. The `Plus' portion of the sidetrack included the replacement of corroded 3-1/2" L-80 tubing with 3-1/2" 13CR. Following the new completion, Z1A/Z1B was drilled and completed with a 2- 3/8" liner. The well reached marginal CTOR in June 2004. Since attaining marginal, the well has had relatively poor cycle performances with minimal healing and quick returns to marginal. In December 2004, the well had its header swapped from LP to HP -thus increasing the Flowing Tubing Pressures from 400 psi to 1000 psi -this action reduced the gas rates but maintained similar GORs. The well could not recover after being placed back in LP in November of 2005. The lack of healing potential was most apparent when the well came back at MGOR after being shut-in for over 5 months -from July to December 2006. 90 feet of Zone lA addperfs were shot on April 15, 2007 with the intention of improving 15-04A's performance of 20% uptime. These addperfs did not yield any significant improvement in 15-04A's production rates. In May 2007, there was another 20 feet of Z1B adperfs that were shot in the heal section, as an end of life intervention -these perfs brought no benefit. At present 15-04A is cycled on when excess gas capacity is available. The well's last uptime was after the 20 feet of adperfs and a 1.5 month SI period REASON FOR SIDETRACK: 15-04A currently has low rates and a high GOR therefore receiving very little on-time - 18% in the last 12 months. The "end of life" perfs shot in Zone lA in May 2007 have provided no benefits. The well currently provides minimal value to the field. Due to the low remaining value of this well and the lack of wellwork options, the well has been selected for a through tubing sidetrack. A coiled tubing sidetrack is planned on or around November 15, 2007. The sidetrack, 15-04B, will exit the existing 4-1/2" liner from a whipstock and will target the Zone lA sand. The existing perforations will be isolated by a CIBP and the liner cement job. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: The pre CTD work is slated to begin on October 15th, 2007. 1. O Passed MIT-IA, -OA Done 6/7/07 2. S Caliper inspection to 9900' 3. E Set 2-3/8" CIBP at 9850' ~~~ _~~~ 4. O PT CIBP to 2000 psi 5. E Set Baker 3-1/2" x 4-1/2" whipstock lowside at 9800'. 6. O PPPOT-IC, -T; LDS 7. O PT MV, SV, WV 8. O Blind and bleed lines, remove well house, level pad Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high 2. Mill 2.74" window at 9,800' and 10' of openhole. Swap the well to Flo-Pro. 3. Drill Build: 3" OH, 900' (20 deg/100 planned) 4. Drill Lateral: 3" OH, 1950' horizontal (10 deg/100 planned) 5. Run 2 3/8" solid liner leaving TOL at 9145' 6. Pump primary cement job to TOL, 19 bbl of 15.8 ppg cmt planned 7. Run CO assembly 8. Run MCNL/GR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate, planned 1000ft. 11. Freeze protect well, Set BPV,1tDMO Post-Rig Work 1. Pull BPV 2. Install well house. Hook up flow line. Sean McLaughlin CTD Drilling Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = FMC: GFN 2 WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 63' BF. ELEV = KOP = 3039' Max Angle = 93 (a~ 11985' Datum MD = 10240' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2649' Minimum ID =1.920" @ 9827" 3" X 2-3/8" XO ~ 3-1/2" TBG, 9.2#, 13-C R, .0087 bpf, ID = 2.992" I 17" TIEBACK LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" ~ 9202' TOP OF 7" LNR 9270' 9-5/8" CSG, 47#, L-80, ~ = 8.681" 9588' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 70° @ 10360' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-9/16" 6 10360 - 10380 O 05/30/07 1-11/16" 6 10526 - 10556 O 04/14/07 1-11/16" 6 10648 - 10708 O 04/14/07 1-11/16" 4 10790- 10810 O 01/15/04 1-11/16" 4 10975 - 10995 O 01/15/04 1-11/16" 4 11030-11230 O 01/15/04 1-11/16" 4 11330 - 11520 O 01/15/04 1-11/16" 4 11530 - 11930 O 01/15/04 1-11/16" 4 12010 - 12061 O 01/15/04 1/2" SCAB LNR, 12.6#, L-80, .0152 bpf., ~ = 3.958" ~ 10438' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10460' 15 -0 4A SAFETY NOTES: 3-1 /2" CHROME TBG. 2199' 1 3-1 /2" HES X NP, ID = 2.813" !451' 9-5/8" X 7" BKR LNR TOP PKR, ID = ??? GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3354 3342 19 MMG DMY RK 0 07/30/06 3 5556 5217 34 MMG DMY RK 0 07/30/06 2 7286 6612 42 MMG DMY RK 0 01/30/04 1 8921 7798 42 MMG DMY RK 0 01/30/04 8980' 3-1 /2" HES X N~, D = 2.813" 9002' 7X.3-112" PKR S-3 PROD PKR, ID = 3.875 9027' 3-1/2" HES X NIP, ID= 2.813" 9087' UNIQUE OV ERSHOT 9112' 7-1/2" X 3-1/2" BAKER FB-1 PKR, ~ = 4.0" 9115' 3-1/2" BAKER SEAL BORE IXTENSION 9124' 3-1/2" BAKER CONCENTRENIC COUPLING 9125' 3-1/2" BAKER SEAL BOREIXTENSION 9130' 3-1/2" BAKER MILLOUT IXTENSION 9159' 9-5/8" X 4-1/2" BKR HYFLO HNGRwlfIEBACK 9~ 171' I~ 3-1/2" OTIS XN NIP, ID = 2.75" 9202' 3-1/2" WLEG, ID= 2.992" 9189' ELMD TT LOGGED 12/04/90 Mt.LOUT WINDOW 10194' - 10216' 9820' ~ 3.0" BKR DEPLOY SLV, ID = 2.250" 9827' 3" X 2-3/8" XO, ID = 1.92" 10194' TOP OF WHIPSTOCK (1/2004) 12064' I~ PBTD 2-3/8" LNR, 4.6#, L-80, .0036 bpf, ID = 1.920" ~-~ 12098' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/26/82 ORIGINAL COMPLETION 05/28/07 JAF/TLH CORRECTIONS (SCAB LNRS) 12/04/90 LAST WORKOVER 06/01/07 CJA/PAG ADPERFS (05/30/07) 01/18/04 DAV/KA CTDSIDETRACK(15-04A) 01/30/04 DTR/KAK GLV C/O 07/30/06 DRF/PAG GLV C/O 04/29/07 SGS/TLH PERFS (04/14/07) PRUDHOE BAY UNfi' WELL: 15-04A PERMff No: 2031140 API No: 50-029-20726-01 SEC 22, T11 N, R14E, 4012.86' FEL & 1330.03' FNL BP Exploration (Alaska) TREE = FMC GEN 2 WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 63' BF. ELEV = KOP = 3039' Max Angle = 93 @ 11985' Datum MD = 10240' Datum ND = 8800' SS 15 -O ~ ~ SAFEfY OTES: 3-1 /2" CHROME TBG. Proposed CTD Sidetrack 3-1 /2" HES X NIP, ID = 2.813" 9-5/8" X 7" BKR LNR TOP PKR, ID = 13-3/8" CSG, 72#, L-80, ID = 12.347" 2649' Minimum ID =1.920" @ 9827" 3" X 2-3/8" XO 3-1 /2" TBG, 9.2#, 13-CR .0087 bpf, ID = 2.992" ~-~ 9078' ~ 7" TIEBACK LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~-j 9167' 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" ~ 9202' TOP OF 7" LNR 9270' 9-518" CSG, 47#, L-80, ID = 8.681" 9588' i3.0" BKR DEPLOY SLV, ID = 2.250" ~--~ 9820' 1 3" X 2-3/8" XO, ID = 1.92" 9827' P6iFOR4TI0N SIInMY\RY Rg LOG: ANGLE AT TOP P37F: 7G° ~ 10360' M10UTV~DOJV 10194' -10216 Note: Refer to Reduction DB for historical oerf data S¢E SPF 9JT6T/AL O m/S z O4TE 1-9116" 6 10360- 10380 O 05/30/07 1-11/16" 6 10526- 10556 O 04/14!07 1-11/16" 6 10648- 10708 O 04/14/07 1-11/16" 4 10790- 10810 O 01/15104 1-11/16" 4 10975- 10995 O 01/15/04 1-11/16" 4 11030- 11230 O 01/15/04 1-11/16" 4 11330- 11520 O 01/15/04 1-11/16" 4 11530- 119 O 01/15/04 1-11/16" 4 12010- 12061 O 01/15/04 4-1/2" SCAB LNR, 12.6#, L-80, .0152 bpf., ID = 3.958" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" LNR, 4.6#, L-80, .0036 bpf, ID = 1.920" ~~ 12098' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/26182 ORIGINAL COMPLETION 05/28/07 JAF/TLH CORRECTIONS (SCAB LNRS) 12/04190 LAST WORKOVER 06/01/07 CJA/PAG ADPERFS (05/30/07) 01118/04 DAV/KA CTD SIDETRACK (15-04A) 01/30/04 DTR/KAK GLV GO 07/30/06 DRF/PAG GLV GO 04/29/07 SGS/TLH PERFS (04/14/07) PRUDHOE BAY UNIT WELL: 15-04A PERMIT No: "2031140 API No: 50-029-20726-01 SEC 22, T11 N, R14E, 4012.86' FEL & 1330.03' FNL BP Exploration (Alaska) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3354 3342 19 MMG DMY RK 0 07/30/06 3 5556 5217 34 MMG DMY RK 0 07/30/06 2 7286 6612 42 MMG DMY RK 0 01/30/04 1 8921 7798 42 MMG DMY RK 0 01/30/04 8980' - 1 3-1/2" HES X NIP, ID = 2.813" 9002' 7 X 3-1 /2" PKR S-3 PROD PKR, ID = 3.875 9027' 3-1/2" HES X NIP, ID = 2.813" 9087' UNIQUEOVERSHOT 9112' 7-1/2" X 3-1/2" BAKER FB-1 PKR, ID = 4.0" 9115' 3-1/2" BAKER SEAL BORE IXTENSION 9124' 3-1/2"BAKERCONCENTRENICCOUPLING 9125' 3-1/2" BAKER SEAL BORE IXTENSION 9130' 3-1/2" BAKER MILLOUT IXTENSION 9159' 9-5/8" X 4-1 /2" BKR HYFLO HNGR w /TIEBACK s1a5' ~ ~~,~,~ 9145' 9171' 3-1/2" OTIS XN NIP, ID = 2.75" 9202' 3-1/2" WLEG, ID= 2.992" 9189' ELMD TT LOGGED 12/04/90 2-3/8" cmt'ed and r>erfed 12650' 9800' ~-~ Mech Whipstock 9850' 1---12-318" CIBP ' I~ PBTD ~, . \1.-\"'I::IV~D ¿-;'-O? C . STATE OF ALASKA . JU ALA Oil AND GAS CONSERVATION COM ION A N 0 7 2007 REPORT OF SUNDRY WELL OPERATIONS laska ail & Gas Co o Stimulate 0 Other 0 nChorR.g o Waiver 0 Time Extension 0 e [2] Re-enter Suspended Well 0 5. Permit to Drill Number: 203-1140 / 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 63 KB 8. Property Designation: ADLO-028306 , 11. Present Well Condition Summary: Total Depth 12295 ( feet 8897 ' feet measured true vertical Effective Depth measured 12064 " feet true vertical 8914 , feet Casing Length Size Conductor 80 20" 91.5# H-40 Surface 2649 13-3/8" 72# L-80 Production 9588 9-5/8" 47# L-80 Liner 1190 7" 26# L-80 Liner 1279 4-1/2" 12.6# L-80 Liner 3269 2-3/8" 4.6# L-80 Perforation depth: Measured depth: 10790 - 12061 True Vertical depth: 8955.81 - 8914 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 431 942 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Exploratory SenÄce 9. Well Name and Number: 6. API Number: 50-029-20726-01-00 - PBU 15-04A , 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) ~CANNED JUN 1 4 2007 MD TVD 30 - 110 30 - 110 Surface - 2649 Surface - 2649 Surface - 9588 Surface - 8305 . . 9270 10460 8061 - 8940 9159 - 10438 7977 8940 9820 - 12098 8494 - 8912 - - - - - - - - 3-1/2" 9.2# 3-1/2" 9.3# 3-1/2" Baker FB-1 Packer 3-1/2" Baker HB Packer o o 13Cr80 L-80 None None Burst 1490 5380 ,6870 7240 8430 11200 Collapse 470 2670 4760 5410 7500 11780 25 - 9087 9080' - 9202' 9002 9112 o o RBDMS 8Ft. jUN 1 3 2007 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 21377 8 0 47344 19 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 1113 394 SenÄce 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Signature Form 10-404 Revi ed 04/tj6R I GIN A L Title Data Management Engineer Phone 564-4944 WINJ WDSPL Date 6/6/2007 ~ 1,-,> Submit Original Only . . lS-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CTU#9 with 16269' of 1.5" CT.Add perfs. MU Weatherford MHA OD 1.7" and SLB CCUGR Memory log OAL = 15.7' and OD 1.5" RIH to 10500' and log from 10500' to 9800' POOH. RD Logging tools, MU 20' of 1.56" OD HSD 1606 PowerJet guns. TIH with guns.. *** Job continued on 5/30/07*** 5/30/2007 # 9, 16269' of 1 .5" CT. Add Perfs, Continued from OS/29/07. TIH with perf guns to flag, correct to 10294' RIH to 10385' PU to 10360' drop 1/2" steel ball, did not see it seat. Drop 1/2" aluminum ball and pump it down, did not see it seat. TOOH, GUNS DID NOT FIRE! Found the steel ball stuck in the lower check in the double flapper valve. MU BOT MHA and 20' 1.56" OD Perf guns and RIH to shoot 10,360' to 10,380'. Land ball on seat but have soft landing. Make several pressure ramps and guns fired. Perforated from 10,360-10,380'. POOH. Confirmed that guns fired, recovered 1/2" ball from firing head. RD CTU and notify pad operator to pop ASAP. **** JOB COMPLETE **** FLUIDS PUMPED BBLS 172 50/50 methanol 60 1 % kcl w/ 0.6% safe lube 232 TOTAL STATE OF ALASKA ;¡¿;.~? RECEIVED ALAS'RÃ OIL AND GAS CONSERVATION COMrv~ION 1r1(¡t..) APR I 9 7007 REPORT OF SUNDRY WELL OPERATIONS Stimulate 0 AlaskatOil ~as Gons. Gommissior Waiver D Time Extension [Anchorage Re-enter Suspended Well D 5. Permit to Drill Number: 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 63 KB I 8. Property Designation: ADLO-028306 I 11. Present Well Condition Summary: Total Depth measured true vertical 12295 / 8897 ' Plug Perforations 0 Perforate New Pool D Perforate 0 4. Current Well Class: Development r;; Stratigraphic Exploratory Service 203-1140 ~ 6. API Number: 50-029-20726-01-00 / 9. Well Name and Number: PBU 15-04A í 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool I feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 12064 ¡ feet true vertical 8914 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 30' - 110' 30' - 110' 1490 470 SURFACE 2649' 13-3/8" 72# L-80 surface - 2649' surface - 2649' 5380 2670 PRODUCTION 9588' 9-5/8" 47# L-80 surface - 9588' surface - 8305' 6870 4760 LINER 1190' 7" 26# L -80 9270' - 10460' 8061' - 8940' 7240 5410 LINER 1279' 4-1/2" 12.6# L-80 9159' - 10438' 7977' - 8940' 8430 7500 LINER 3269' 2-3/8" 4.6# L-80 9820' - 12098' 8494' - 8912' 11200 11780 Perforation depth: Measured depth: 10790 - 12061 - - - - True Vertical depth: 8956 - 8914 - - - - Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 15891 8 0 21485 11 0 15. Well Class after Droposed work: Exploratory Development W' 16. Well Status after proposed work: Oil r;; Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. prin:i:~~:: ~dJ// _ Form 10-404 Revts:d 04/2006 n R , h , t\I A , Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 290 402 x Contact Gary Preble 3-1/2" 9.2# 3-1/2" 9.3# 3-1/2" Baker FB-1 Packer 3-1/2" Baker HB Packer o o 13Cr80 L-80 25 - 9087 9080'-9202' 9002 9112 o o SCANNED APR 2 5 2007 Tubing pressure 1312 988 Service GINJ W DSPL WINJ Sundry Number or N/A if C.O. Exempt: Title Data Management Engineer Phone Date 4/17/2007 564-4944 RBDMS BFL APR 2 4 2007 Submit Original Only '~ '~ 15-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/13/2007 MIRU CTU #5. Drift to 11,100'. POOH. Cut 50' of pipe. RIH w. SLB Memory GR/CCL, log from @ 60 fpm 10900' to 10600' flag pipe, continue logging @ 60 fpm to 10100', POOH. ***Continue job on 4/14/2007*** 4/14/2007 CTU #5 ***Continue job from 4/13/2007*** Good data recovered from memory tools +9' correction, Perforate 10,526' - 10,556' and 10,648' - 10,708' per procedure. ***Continue job on 4/15/2006*** 4/15/2007 CTU #5 job from 4/2007*** w. some shots on gun run #3 not fired. 5 shots on the top of the 20' gun did not fire and 3 shots on the top of the lower 10' gun. MU 1.75" nozzle for lifting of well. Blow CT reel down and RIH lifting well w. N2 worked way down to 7200' flowed two wellbore volumes to tiger tank (196 bbls) turn well over to pad operator flowing @ 760 psi. Choke set @ 50 deg. *** Job Complete*** FLUIDS PUMPED BBLS 25 60/40 Methanol 25 Total / 7 I-~b DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2031140 Well Name/No. PRUDHOE BAY UNIT 15-04A Operator BP EXPLORATION (ALASKA) INC >;; J C1J~ ~~ '-1 AÞI No. 50-029-20726-01-00 MD 12295 /" TVD 8897 / Completion Date 1/17/2004"/ Completion Status 1-01l REQUIRED INFORMATION Mud log No Samples No --- DATA INFORMATION Types Electric or Other Logs Run: MWD 1 GR 1 CCl 1 Press, GR 1 CNl 1 CCl Well Log Information: Logl Data Type I Electr Digital Dataset Med/Frmt Number Log Log Scale Media Run No Name Gamma Ray ED D Pdf Directional Survey ED 0 Asc Directional Survey Rpt Directional Survey '..rôg Gamma Ray ~g Gamma Ray ,~Rpt LIS Verification _£ C Pds 13015 Gamma Ray {).cg 13015 Gamma Ray 25 Blu 25 Blu Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y 1 N Daily History Received? Chips Received? Y 1 N Formation Tops Analysis Y 1 N Received? Comments: Current Status 1-01l UIC N Directional surve~ (data taken from logs Portion of Master Well Data Maint Interval OHI Start Stop CH Received Comments 11035 11700 Open 2/4/2005 10100 12295 2/13/2004 10100 12295 2/13/2004 10100 12295 2/13/2004 10204 12295 GRlMWD 10204 12295 GR/MWD 10180 12295 LIS 8988 12071 2/28/2005 MCNUMEMORY GRlCCUCNl 8988 12071 2/28/2005 MCNUMEMORY GR/CCLlCNl . . Sample Set Number Comments Y/N (5/N Permit to Drill 2031140 MD 12295 TVD 8897 Compliance Reviewed By: _ DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Well Name/No. PRUDHOE BAY UNIT 15-04A Operator BP EXPLORATION (ALASKA) INC Completion Date 1/17/2004 Completion Status 1-01L Current Status 1-01L Date: API No. 50-029-20726-01-00 UIC N . . Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . Well N5·a;LD.S.07-03A JOj -1<{:fK-10B 'q{;-af7 D.S. 02-15A F17-l15- D.S. 18-13A Î 3·¡4¡-G-12B :&_ ¡z( -D.S. 05-26A .7 &-;3-1\ ¡f-15-04A 7q!-ð'j~ 18-02A ~-o'Ø~18-04B 1'35-015 L 1-01 IC/I;{ _ . "1O-L5-17 ~U'-' IJ? 1, ''') , - /'iH-18 .,"ð '- -_!O 2-62/Q-17 18t.-¡r"'L5_15 ~ L5-15 _~q; L5-15 \.L5-15 ¡'ð; 'E-17 '(6-/ - G-15A Job# 10715406 10715402 10715404 10715395 10715391 10715420 10715374 10621764 10708056 10913000 10900124 10703975 10900129 10708050 10563129 10672368 10913848 10703983 10679055 MCNL MCNL MCNL MCNL MCNL MCNL MCNL RST RST USIT USIT RST RST RST RST RST RST RST RST Log Description Date 06/03/04 05/16/04 05/18/04 04/16/04 03/21/04 08/19/04 01/14/04 02/23/04 03/05/04 12/25/04 11/30/04 02/17/04 12/24/04 02/07/04 11/15/03 04/16/04 09/26/04 04/09/04 02/02/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd_ Anchorage, Alaska 99508 Date Delivered: ~~t5 Blueline NO. 3354 /) cx:l3 3- /~/ ¿j 02/28/05 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 1 1 1 1 1 1 1 1 1 1 1 1 Color Prints CD 1 1 1 1 1 1 1 1 1 1 1 / 1 1 1 1 1 1 1 1 / Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 38 /" ATTN: Beth - // / Receive ~ ur~...a~ Ó . STATE OF ALASKA a ALASKA. AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG i\! ~:t~ i 22004 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CASING, LINER AND CEMENTING RECORD SETT1N$Dt;~BMÞ SI;TT1NGDEF'1:H't\ÎØ Top BO,.,.OM "I 01' BO""OM 20" 91.5# H-40 Surface 110' Surface 110' 13-3/8" 72# L-80 Surface 2649' Surface 2649' 9-5/8" 47# L-80 I SOO-95 Surface 9588' Surface 8305' 7" 29# L-80 9270' 10460' 8061' 8940' 4-1/2" 12.6# L-80 9159' 10438' 7977' 8940' 2-3/8" 4.6# L-80 9820' 12098' 8494' 8912' 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 1.56" Gun Diameter, 4 spf MD TVD 10790' -10810' 8956' - 8955' 10975' - 10995' 8951' - 8950' 11030' - 11230' 8947' - 8945' 11330' - 11520' 8945' - 8937' 11530' - 11930' 8936' - 8920' 12010' - 12061' 8917' - 8914' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oil -Bsl 132 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1206' SNL, 237' EWL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 1298' SNL, 4002' WEL, SEC. 21, T11N, R14E, UM Total Depth: 133' NSL, 5136' WEL, SEC. 16, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676169 y- 5960280 Zone- ASP4 TPI: x- 671933 y- 5960091 Zone- ASP4 Total Depth: x- 670764 y- 5961495 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD / GR / CCL / Press, GR / CNL / CCL 22. MD 26. Date First Production: February 1, 2004 Date of Test Hours Tested PRODUCTION FOR 2/9/2004 6.1 TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ........ Press. 370 24-HoUR RATE""'" Oll-Bsl 3,159 One Other 5. Date Comp., Susp., or Aband. 1/17/2004 6. Date Spudded 1/9/2004 7. Date T.D. Reached 1/12/2004 8. KB Elevation (ft): 63' 9. Plug Back Depth (MD+ TVD) 12064 + 8914 10. Total Depth (MD+TVD) 12295 + 8897 11. Depth where SSSV set (Nipple) 2199' MD 19. Water depth, if offshore N/A MSL \¡:~: . \i'; 1 bã~:~e~~::~rii n.çhJ¡\È!!ExPloratOry o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-114 13. API Number 50- 029-20726-01-00 14. Well Name and Number: PBU 15-04A 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 30" 17-1/2" 12-1/4" 8-1/2" N/A 3" 400 sx Permafrost II 2000 sx Fondu, 400 sx PF 'C' 500 sx Class 'G' 350 sx 'G' (7" 26# L-80, Liner Tieback 2451' - 9167') Liner Tieback 78 sx Class 'G' TUSING DEPTH SET (MD) 9087' 9080' - 9202' TVD SIZE 3-1/2",9.2#, 13Cr80 3-1/2",9.3#, L-80 PACKER SET (MD) 9002' 9112' ETC. AMOUNT & KIND OF MATERIAL USED Freeze Protected with 15 Bbls MeOH DEPTH INTERVAL (MD) 1700' GAs-McF 653 GAs-McF 15,668 CHOKE SIZE I GAS-Oil RATIO 82.44 4,960 Oil GRAVITY-API (CORR) W A TER-Bsl -0- WATER-Bsl -0- 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none;C:1~~e,·)'n~~e':. None !1-/j~ _.. nr., ø \11ØJt f.:_1Æ~Dj 0 D! r-! ~.! J~\ t_ ~.9~~ Form 10-407 Revised 12/2003 ~¡::; CONTINUED ON REVERSE SIDE [-, 28. GEOLOGIC MARKERS. 29. .RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 2A / 21TS 10188' 8809' None Zone 1 B 10275' 8883' Zone 1A / TDF 10344' 8924' FEB 1 2 2004 AlEda 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~.Q/\^; 0 . fuM-&- Title Technical Assistant PBU 15-04A 203-114 Well Number Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Date O~þ / t.. 0'-( Terrie Hubble, 564-4628 Dan Kara, 564-5667 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-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 elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OR\G\NAL '~ . BP EXPLORATION ·Operations Summary Report Page 1 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 12/26/2003 1/17/2004 N2 Spud Date: 3/24/1982 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations 12/26/2003 04:00 - 08:00 4.00 MOB P PRE Continue to prep for move on W pad. Move rig off of well. Hold PJSM with crews on rig. 08:00 - 09:00 1.00 MOB P PRE Measure camp height. Move rig camp to DS 15. Lay down derrick. Hold pre move mtg with Security & crews. Rig on Spine at 1500 hrs. Expected 12 hrs on Spine Rd. Plan to stop at J pad to verify rig height with CPS reps. Contact DS 15 operator, Heavy Equipment Foreman & FS 3 Control Room to discuss up-coming sim oops on pad.. 09:00 - 00:00 15.00 MOB P PRE Moblize to DS 15 0.00 0.00 0.00 0.00 0.00 0.00 12/27/2003 00:00 - 06:00 6.00 MOB P PRE Continue with rig move. 06:00 - 07:00 1.00 MOB P PRE Rig on DS 15 at 0700 hrs. Spot rig off wellhead to allow cellar access for BOP work. 07:00 - 12:00 5.00 MOB P PRE Open pipe shed. Raise derrick & windwalls. 12:00 - 15:00 3.00 MOB P PRE Begin removal of cat walk. Hold pre-lift safety mtg & review with Peak rep. Block up catwalk. Cut cat walk loose from scissor jacks. RU flow back tank on pad. 15:00 - 16:00 1.00 MOB P PRE Hold critical lift plan review with Peak, BP, and Nordic reps. Determine wind is too high to perform lift with out written exemption from Lifting guidelines. Winds at 18-20, gusting to 30 mph. Decide to postpone lift and proceed with well work. 16:00 - 18:00 2.00 BOPSURP PRE Rearrange 13 5/8" BOPS and rams inside cellar of rig. Rig accepted at 1600 hrs on 12-27-03. 18:00 - 18:30 0.50 BOPSURP PRE TL and PJSM with on coming crews. Review plan forward and simultaneous operations being conducted on the rig and well pad. 18:30 - 21 :30 3.00 BOPSURP PRE Continue reconfigure mud cross and single gate prior to pulling over well. Same time replace lower sprocket bearings on injector. 21 :30 - 22:00 0.50 MOB P PRE Move rig over well. 22:00 - 00:00 2.00 RIGU P PRE Finish work on injector. Welder attaching padeyes to catwalk for crane removal. Take on 150 deg 2% KCL water. Pull BPV. RIU rig lines to circulate and kill well. 12/28/2003 00:00 - 04:30 4.50 RIGU P PRE Finish rigging up hard line from Tiger tank and test to 2000k. Prep to kill well. 04:30 - 07:00 2.50 KILL P DECOMP Kill well down tbg taking returns from IA to Tiger Tank at 5bpm 600psi. Complete circulation. Monitor IA and tbg for flow. Well dead. Hold TL and PJSM (ND,NU) mtg in ops cab while monitoring well. 07:00 - 08:00 1.00 BOPSURP PRE Remove lines and tree cap from tree. 08:00 - 09:00 1.00 BOPSURP PRE Set BPV in tbg hanger. Test same to 1000 psi through inner annulus. 09:00 - 11 :30 2.50 BOPSURP PRE ND tree. FMC on location. 11 :30 - 00:00 12.50 BOPSURP PRE NU 13-5/8" BOPS. High winds making NU a challenge. Having to open cellar doors into wind with loader. Phase 2 driving condtions. 12/29/2003 00:00 - 06:00 6.00 BOPSURP PRE Continue with BOP nipple-up. Rearrange all ram cavities. Top .> Bottom: Annular, Blinds, Mud Cross, VBR's, Empty cavity. Printed: 1/19/2004 9:49:05 AM · "'-" - BP EXPLORATION Operations Summary Report Page 2 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 1 5-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 12/26/2003 1/17/2004 N2 Spud Date: 3/24/1982 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations -...------"--------- ----".-"--...--.--..---- ----- 12/29/2003 00:00 - 06:00 6.00 BOPSUR P PRE NU HCR's and choke/kill lines. Function test rams. Continue with prep work for Skate installation. 06:00 - 11 :00 5.00 BOPSURP PRE Body test BOP equipment. Witness waived by AOGCC J. Jones. Install 2-7/8 test joint. Test rams, annn, choke manifold, kill & choke valves 250 low, 2500/3500 high. No failures. 11 :00 - 14:30 3.50 PULL P DECaMP RU floor equipment to pull completion. Call for spooling unit & wellhead hand to convoy out (Phase 2). Convoy turned around at east guard station due to vehicles blocking Spine Rd. Convoy stuck in snow drifts on road in Deadhorse. Return to Camco shop. 14:30 - 00:00 9.50 PULL N WAIT DECaMP Phase 3 conditions declared. Standby while waiting for weather to improve. Arrange heavy equipment convoys for crews from Deadhorse and BOC. Coordinate with Nordic 1 12/30/2003 00:00 - 05:30 5.50 PULL N WAIT DECaMP Wait on Phase 3 weather. Crews able to change out with heavy equipment escort. 05:30 - 06:30 1.00 PULL N WAIT DECaMP Conditions improved to Phase 2. Call for FMC and Camco/SLB hands. Hold TL mtg with rig crews. 06:30 - 08:00 1.50 PULL P DECOMP Circulate down tbg to verify that well is full. Hold PJSM with crews. 08:00 - 09:30 1.50 PULL P DECaMP Hold PJSM with crews. RU control line spooling unit on floor. Pull BPV with DSM crew 09:30 - 11 :00 1.50 PULL P DECaMP MU 3-1/2" landing joint to tbg hanger. Back out lock down screws. Drain BOP stack. 11:00-13:00 2.00 PULL P DECaMP Pull tbg hanger to floor. 78K# up wt. Good chem cut. Break out hanger & tbg pup. LD landing jt. PU 5-1/2" elevators to latch & pull 1 jt of 5-1/2" LTC tbg. Spool control line. Note: FMC determined tubing hanger cannot be reused. New hanger is ready 13:00 - 18:00 5.00 PULL P DECaMP Continue to POOH with 3-1/2" tbg to Otis SSV. Remove and count cntlline bands. Check OA pressure and bleed off 25 psi. 18:00 - 19:00 1.00 PULL P DECaMP MU Howco 9 5/8" RTTS & SSC rih and set 54' below RKB. PT wellbore above RTTS against blinds to 2000 psi and check packoff, ok (had leaked at 3000 psi Pre RWO). Bleed off pressure. Drain stack thru IA valve 19:00 - 22:00 3.00 WHSUR P DECaMP Determine inner casing packoffs cannot be retrieved thru stack as planned (upper and lower elements). Remove drip pan on annular. ND below tubing spool and back out lock down screws on secondary packoff.Pull up BOP stackltbg spool w/ blocks w/1 Ok overpull. Find top of 9-5/8" stub flared outward to 11" (FMC believes the wrong (lower) test plug was used during the original completion since there were no marks on the recently pulled tubing hanger) and found a few burrs. Stub is also 4-6" longer than it should have been 22:00 - 00:00 2.00 WHSUR P DECaMP ND valves off tubing spool. Remove tubing spool from bottom of BOP's-no major damage seen 12/31/2003 00:00 - 01 :45 1.75 WHSUR N SFAL DECaMP WO Wachs cutting tool 01 :45 - 04:00 2.25 WHSUR N SFAL DECaMP Safety mtg re: cuUdress stub Rough cut 9-5/8" stub to remove flared portion w/ portaband. Remove secondary packoff. InstalrWach's cutting tool and cuUdress 9-5/8" stub at proper height. Pull primary packoff/inspect slips, ok 04:00 - 10:30 6.50 WHSUR P DECaMP Install new single packoff assy. Install New-Standard FMC Printed: 1/19/2004 9:49:05 AM / --~. ..... . BP EXPLORATION Operations Summary Report Page 3 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 12/26/2003 1/17/2004 N2 Spud Date: 3/24/1982 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations _n _..._. .. _._._... _..._______ 12/31/2003 04:00 - 10:30 6.50 WHSUR P DECaMP tubing spool (requires/for 4-1/2" tubing) on bottom of BOP's. Install valves on spool. NU to casing spool. Test packoffs to 3300 psi 70% of collapse. Re- install riser 10:30 - 11 :00 0.50 WHSUR P DECaMP Stab into Howco RTTS. Open SSC check for pressure - zero. Pull packer. 11 :00 - 11 :20 0.33 BOPSURP DECaMP Pressure test flange breaks on tbghead and double gate to 3500psi. Held okay. 11 :20 - 12:30 1.17 PULL P DECaMP Circulate well to warm-up annulus. 12:30 - 22:00 9.50 PULL P DECaMP Continue laying down 3 1/2" completion string. No obvious external corrosion. Found clean chemical cut in middle of the last full joint. Remove tubulars from pipeshed. NORM test tubing and other removed wellhead parts-all <5 uRem 22:00 - 22:20 0.33 CONS P DECaMP Safety mtg re: lifting 22:20 - 00:00 1.67 CONS P DECaMP Open pipeshed roof. Remove catwalk and ramp with Peak 150T crane and set on ground. Pick new skate assy and set in pipeshed on sills. Close roof. Pick catwalk and ramp and set on trailer 1/1/2004 00:00 - 08:00 8.00 CONS P DECaMP Prep skate/ramp for mating to scissor jacks Vac and clean pits 08:00 - 08:15 0.25 EVAL P DECaMP PJSM review plan forward with slickline crews. 08:15 -11:00 2.75 EVAL P DECaMP RIU 7" lubricator for wireline work. RIU wireline unit. Bring tools to floor. 11 :00 - 13:20 2.33 EVAL P DECaMP Round trip with 6" aD gauge ring/junk basket. Tagged at 9079' WLM 13:20 - 17:05 3.75 EVAL P DECaMP Round trip w/ bell guide overshot (brass pin tattle tails installed) tagged 9081' WLM. Overshot did not show indications of going over 3 1/2" tbg stub. Dress face of OS and rerun. Worked overshot a little harder this time but from surface pick-up weight indications it appears it still has not gone over tbg stub. (tbg may be laying on lowside of 41 deg inclination hole. OS has a 45 deg inside taper with 4.5" ID) Confirmed that no it did not go over tbg stub. 17:05 - 19:15 2.17 EVAL P DECaMP RIH with decentrilized 5.50" LIB to 9081'. Picture showed clean stub on nearly lowside of hole 19:15 - 20:00 0.75 EVAL P DECaMP RDMO HOWCO WL unit 20:00 - 00:00 4.00 CONS P DECaMP Function test pipe skate. Continue work on skate 1/2/2004 00:00 - 04:30 4.50 CONS C DECaMP Finalize work on pipe skate 04:30 - 16:00 11.50 CASE P CaMP Load pipeshed w/ completion tubing 16:00 - 17:30 1.50 CASE P CaMP RIU floor for running tbg. 17:30 - 18:00 0.50 CASE P CaMP Pickup overshot assy 18:00 - 18:30 0.50 CASE P CaMP TUsafety mtg re: run Chrome tbg 18:30 - 21 :00 2.50 CASE N WAIT CaMP WO XO from TS while work on skate electrical system 21 :00 - 00:00 3.00 CASE P CaMP Run 3-1/2" 9.2# 13Cr80 Vam Top tubing and accessories. Bakerlocked all connections below packer 1/3/2004 00:00 - 14:45 14.75 CASE P CaMP Continue to run 3-1/2" 9.2# 13Cr80 Vam Top tubing. 14:45 - 15:30 0.75 CASE P CaMP Install TIW on full jt. and make-up to string. Check weights 65k up/58k dwn. RIH while pumping at 3 bpm 225 psi and tagged up, setdown 8k this could be top of tbg stub. No increase in pump pressure. Rotate pipe 1 1/2 turns. RIH seen slight tag at 9080' then continued another 6' and stacked out. (Baker mule shoe overshot has a 5.9' swallow) Also increase in pressure from 225 to 560 psi. P/U off tbg stub. Line-up to reverse Printed: 1/19/2004 9:49:05 AM ..... - Page 4 of 12 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From -To Hours Task I Code NPT Phase 1/3/2004 14:45 - 15:30 0.75 CASE P CaMP 15:30 - 19:00 3.50 CASE P CaMP 19:00 - 22:00 3.00 CASE P CaMP 22:00 - 22:15 0.25 CASE P CaMP 22:15 - 00:00 1.75 CASE P CaMP 1/4/2004 00:00 - 03:00 3.00 CASE P CaMP 03:00 - 03:30 0.50 CASE P CaMP 03:30 - 08:00 4.50 BOPSUR P CaMP 08:00 - 13:00 5.00 WHSUR P CaMP 13:00 - 20:00 7.00 BOPSURP CaMP 20:00 - 20:30 0.50 BOPSURP CaMP 20:30 - 23:00 2.50 BOPSURN SFAL CaMP 23:00 - 00:00 1.00 BOPSURP CaMP 1/5/2004 00:00 - 02:45 2.75 BOPSURP CaMP 02:45 - 03:15 0.50 PULL P CaMP 03: 15 - 03:30 0.25 PULL P CaMP 03:30 - 05:00 1.50 PULL P CaMP 05:00 - 06:30 1.50 PULL P CaMP 06:30 - 13:00 6.50 PULL P CaMP 13:00 - 15:15 2.25 WHIP P WEXIT 15:15 -17:00 1.75 WHIP P WEXIT 17:00 -18:10 1.17 WHIP P WEXIT 18:10 - 20:00 1.83 WHIP P WEXIT 20:00 - 20:20 0.33 WHIP P WEXIT 20:20 - 21 :30 1.17 WHIP P WEXIT Start: Rig Release: Rig Number: Spud Date: 3/24/1982 End: 1/17/2004 12/26/2003 1/17/2004 N2 Description of Operations circulate. Reverse circulate with 140 deg 1% KCL as follows: 50 bbls, 50 bbls viscosified, 250 bbls, followed by 175 bbls 1% KCL with 25gall100bbl "Corexit" corrosion inhibitor. Retag for space out 58k, 17k. LD two jts tubing. Install space out pupslXO. Install tubing hanger. MU landing joint XO on 3-1/2 DP with TIW valve. Land tubing hanger 24.50' below RKB which leaves overshot 2.0' above bottoming out on stub. Tubing landed at 9087' BKB. RILDS. Release Nabors casing crew Safety mtg re: pump crude Install kill line to IA. Vapor test crude at 1.5 psi. FP IA by rev circ 147 bbls crude down IA at 2.0/350 taking returns thru tubing to cutting box. Final lAP 138 psi Drop 1-3/8" ball on rod to packer. Pressure tubing to 3500 psi w/IA open and hold for 30 min. Held tite w/ no returns from IA. Used portable chart recorder. Bleed off tubing to 500 psi. Pressure IA to 3500 psi and hold for 30 min with tubing at 1000 psi. Good tests. Bleed off pressures, RD equipment Back out landing jt. Set 4" TWC ND 13-5/8" BOPE N/U 13 5/8" X 4 1/8" adapater fig and 4 1/8" 5K production tree. Test same to 5K with diesel. N/U 7 1/16" 5K BOP stack. Connect HCR valves, choke/kill lines. Test BOPE. Witness waived by AOGCC Repair kill line HCR Resume BOPE test Continue BOPE test MIRU DSM lubricator. Pull TWC. RDMO DSM Safety mtg re: RU HES WL MIRU HES WL unit. Load tools to floor RIH w/ 0.108 WL and fish ball-on-rod RIH pull RHC body. Run 2.79" tapered swage and setdown at 9200' WLM. (XN nipple w/2. 75" ID at 9171 ') RIH w/2.60"x1 0' dummy whipstock tagged hard at 1 0195' WLM sticky picking up. RD slickline unit. Stab 2" coil to injector Make up Kendal connector and test. Phz 2 P/U BHA #1 RIH w/ BHA #1 (2-5/8" x 4-112" BTT WS). No wt bobbles thru stub or XN Log tie-in down from 9735'. Corr +12' to 9732' BHCS 10150' 31.3k, 21.3k. RIH to 10250', clean. PUH 30.5k to 10210' and log GR tie-in down and tie-in to PDC marker at 10188'. Corr +2'. PUH 30.5k Log tie-in down from 10200' and see top collars at 10168' within one ft, but start losing wt at 10258' and stack 1k. PUH 30.6k and park at set depth (10232.2' BOWS). Close EDC and pressure up to 3000 psi and set WS at 6R. Attempt to stack 5k to verify set and took 3.5k wt and then wt started coming back. Continue in hole to 10241.2' and WS is slipping w/ 3.5k Printed: 1/19/2004 9:49:05 AM .~ - BP EXPLORATION Operations SurnmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT ¡Phase 1/5/2004 WAIT WEXIT 21 :30 - 22:45 1.25 WHIP N 1/6/2004 22:45 - 00:00 00:00 - 00:25 00:25 - 00:50 00:50 - 04:00 DFAL WEXIT DFAL WEXIT DFAL WEXIT WAIT WEXIT 1.25 WHIP N 0.42 WHIP N 0.42 WHIP N 3.17 WHIP N 04:00 - 06:40 2.67 WHIP N WAIT WEXIT 06:40 - 07:30 0.83 WHIP N DFAL WEXIT 07:30 - 08:00 0.50 WHIP N DFAL WEXIT 08:00 - 08:30 0.50 WHIP N DFAL WEXIT 08:30 - 10:10 1.67 WHIP N DFAL WEXIT 10:10 - 10:25 0.25 WHIP N DFAL WEXIT 10:25 - 11 :00 0.58 WHIP N DFAL WEXIT 11 :00 - 12:45 1.75 WHIP N DFAL WEXIT 12:45 - 13:15 0.50 WHIP N DFAL WEXIT 13:15 - 20:00 6.75 WHIP N DFAL WEXIT 20:00 - 22:30 2.50 WHIP N DFAL WEXIT 22:30 - 00:00 1.50 WHIP N DFAL WEXIT 1/7/2004 00:00 - 00:30 0.50 WHIP N DFAL WEXIT 00:30 - 01 :30 1.00 WHIP N DFAL WEXIT 01 :30 - 02:00 0.50 WHIP N DFAL WEXIT 02:00 - 02:30 0.50 WHIP P WEXIT 02:30 - 04:30 2.00 WHIP P WEXIT 04:30 - 06:00 1.50 STWHIP P WEXIT 06:00 - 08:00 2.00 STWHIP P WEXIT 08:00 - 12:00 4.00 STWHIP P WEXIT 12:00 - 14:30 14:30 - 17:00 2.50 STWHIP P 2.50 STWHIP P WEXIT WEXIT Page 5 of 12 Start: Rig Release: Rig Number: Spud Date: 3/24/1982 End: 1/17/2004 12/26/2003 1/17/2004 N2 Description of Operations ---- -.----.-.-----..---.-- Park at 10241' (WS top at 10234') and discuss. Circ 0.4/220 Will leave WS at PBD, then run another. RIH w/ WS and start taking wt at 10254'. Stack 10k and no more movement. PUH 30k leaving WS setting on fill with top at 10247' POOH for another WS. Got btms up gas and then crude back Fin POOH. Phz 2 LD BTT setting tool and standback BHI tools. SI @ master BTT convoy to Deadhorse to mate setting tool w/ 2nd WS. Can't find their way off Pad. Send loader and he can't see either. All personnel return to rig. WOW (30-50 mph, blowing snow) BTT convoy to Deadhorse after N1 loader opened road and winds let uplvisibility improved. Re-dress setting tool with new WS. Call SWS for pip tag installation at rig. WS on location. Install riser cap and check for wellhead pressure - none. MU to BHi tools and align TF's. Wait for SWS to arrive with pip tags. Install 2 pip tags 5' below TOWS. Phz 1 MU injector to well. RIH w/ whipstock #2. (Tray angle is 2.8 deg same as WS #1) Log gr tie-in at 9732' +14' correction. RIH to 10232' check wts. 32k117k RIH to 10227'. Close EDC and orient to highside. Per Baker/Houston bring pressure up to 2k and hold 2 min. Pressure up and shear at 2950 psi. With set down wt less than 2k can see WS moving. Pushed down to 10230' and stop. Call town discuss options. TOH while discussing options with town. LD BTT setting tool. LD BHI tools WO BTT to change a 3-1/2" x 5-1/2" WS for a 4-1/2" set E-line on location 1900 hrs. MU whipstock on Eline RIH Log in and set whipstock highside with top of whipstock set at 10192'. POH LD E line tools. RD Eline. PU BHA #3. RIH 18K DN wt.Tag WS at 10182. Correct to 10,194'. Time mill at 1.7 bpm, 2400 psi FS, 2520 psi .5K WOB, Continue time milling at 6 to 10 minutes per tenth foot. 2500 psi@1.7 bpm fs. 200-300 psi mw. 2K-3.5K# WOB. Clean magnets every hour, some metal found. Mill to 10196.0' Continue time milling at 6 to 10 minutes per tenth foot. 2500 psi@1.7 bpm fs. 200-300 psi mw. 2K-3.5K# WOB. Clean magnets every hour, some metal found. Mill to 10199.0'. Revised footage needed on first run to 6.3' to contact 7" wall, as per Baker supplied drawings & data. Mill to 10200.3' as per Baker Tech recommendations. Circulate hi vis sweeps to clean hole. POOH for 2.5 deg mtr & fat radius window mill. At surface. Get off well. Unstab from coil. Blow back coil. Cut 110' coil. Re-head e-coil. Mill gauge 2.73". Wear pattern across center of mill face, generally in good condition. Printed: 1/19/2004 9:49:05 AM ..., a Page 6 of 12 BP EXPLORATION Operations Summary Report Pressure, pull & continuity test coil head. Stab coil. Get on well. RIH with 2.5 deg fixed mtr with fat radius window mill. RIH with BHA#2. Tag GLM at 8914. Oreint 150L. Rlh to 10140'. Tie - in correction +16'. RIH tag 10,196'. Mill at 1.7 bpm, 2780 psi FS, 3220 psi, 1.4K WOB, DH annular pressure 4206 psi, DH tubing pressure 5030 psi. ECD 9.34 ppg. Tagged above pinch point (probably 4-1/2"). Mill ahead and contact what should be 7" at 10200'. Time mill as per recommended schedule. Continue to stack weight. Milling window. Seen no progress little motor work. Decide to look at motor/mill. Final depth: 10200.4'. No apparent footage past previous mill run. POH At surface. Get off well. Unstab from coil. Mill worn on radius, but in gauge, plenty of cutting structure left. No wear on face, did not cross any center line. No evidence of scaring or scratches on motor housing. Order out a new fat radius and 1-step mill from HTC. Discuss options with slope team. Call town to discuss options. Decision is to RIH with straight motor, string reamer, used fat radius mill. MU assembly. RIH. Log tie in pass make a +16' correction. RIH to begin milling 7". Had a stall with string reamer at original pinch point on 4-1/2". Ease into it slowly to dress top of window at 10194.0'. Finished dressing the top of the window. RIH, and tag up at 10198.9. Wait for 30 minutes to establish a cutting pattern with new mill. Give it 15 minutes per 0.1' for first 3 tenths. Getting good drill offs. Go to 6 minutes per 0.1 '. 16:00 Update, 10199.8', 1.7/1.7/2843 psi. Free spin=2700 psi. 17:00 Update, 10201.0', 1.7/1.7/2877 psi. Getting 175 psi motor work, and good drilloffs every tenth. 19:30 Update 10203.82.1 K WOB, 1.7/1.7 @ 2,930' psi. Getting 250 psi MW. mill to 10205. Mill formation Mill @ 3240 psi, 1.7 bpm, 5k WOB, Mill to 10,216.3'. Dry tag clean. POH LD window mill and PU building assembly. RIH Tag up at 10216', Begin drilling build section of hole. Drilling at 1.55/1.6/3630 psi. ROP=20 fph. IAP=80 psi, OAP=O psi. 10255', POOH to increase motor bend. This motor is providing the expected dog legs, but we lost 5 degrees of angle from the pilot section of hole. We need a bigger bend motor to recover and land without going too deep. POOH and adjust motor from 1.9 deg to 2.6 deg. This should give us 35 deg doglegs. We need 33's to land on depth. PROD1 Lay down drilling BHA. Bit recovered at 1,1. We will re run it on the next trip in the hole. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date i From - To Hours ¡ Task Code NPT Phase -.."-- .--" -.. --"'--'-- 1/7/2004 2.50 STWHIP P WEXIT 0.50 STWHIP P WEXIT 2.00 STWHIP P WEXIT 0.17 STWHIP P WEXIT 4.33 STWHIP P WEXIT 14:30 - 17:00 17:00 - 17:30 17:30 -19:30 19:30 - 19:40 19:40 - 00:00 1/8/2004 00:00 - 02:30 2.50 STWHIP P WEXIT 02:30 - 04:30 2.00 STWHIP P WEXIT 04:30 - 05:30 1.00 STWHIP P WEXIT 05:30 - 08:00 2.50 STWHIP N DPRB WEXIT 08:00 - 09:00 1.00 STWHIP N DPRB WEXIT 09:00 - 11 :00 2.00 STWHIP N DPRB WEXIT 11 :00 - 11 :40 0.67 STWHIP N DPRB WEXIT 11 :40 - 14:00 2.33 STWHIP N DPRB WEXIT 14:00 - 16:00 2.00 STWHIP N DPRB WEXIT 16:00 - 17:00 1.00 STWHIP P WEXIT 17:00 - 19:30 2.50 STWHIP P WEXIT 19:30 - 20:30 1.00 STWHIP P WEXIT 20:30 - 00:00 3.50 STWHIP P WEXIT 1/9/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 03:00 1.50 STWHIP P WEXIT 03:00 - 04:30 1.50 STWHIP P WEXIT 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 09:45 3.75 DRILL P PROD1 09:45 - 11 :00 1.25 DRILL P PROD1 11:00-12:00 1.00 DRILL P Start: Rig Release: Rig Number: Spud Date: 3/24/1982 End: 1/17/2004 12/26/2003 1/17/2004 N2 Description of Operations --- ._---- --.--'--- Printed: 1/19/2004 9:49:05 AM .., A BP EXPLORATION Operations Summary Report Page 7 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 1 5-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 12/26/2003 Rig Release: 1/17/2004 Rig Number: N2 Spud Date: 3/24/1982 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations -_.._--_.__._.._..._.~_._.__.__. --..--.-..--------..--....--.- .--..--."-"'- 1/9/2004 12:00 - 15:00 3.00 DRILL N RREP PROD1 Cut 100' of coil and rehead. SWS preventative maintenance due to crome tubing. 15:00 - 16:45 1.75 DRILL P PROD1 RIH with BHA #7. Hughes 2.7" x 3.0" bicenter bit, BHI X-treme mud motor, Coiltrack BHA. 16:45 - 17:00 0.25 DRILL P PROD1 Log tie in pass correction +12'. 17:00 - 21:15 4.25 DRILL P PROD1 Directionally drilling 1.48/1.3 bpm, 3580 psi, FS = 3550, 1.4 K WOB, ECD 10.79, DH annular pressure 4948 psi, DH tubing pressure 5470 psi. Circulating pressure with this used mud system higher than normal. Limitiing rate due to pressure. Drill to 10340 1.49/1.43 bpm, 3812 psi, 3550 psi FS, 1 k WOB, DH annular pressure 5016 psi, DH tubing pressure 5550 psi. ECD 10.9. Drilling ahead called for mud system. Drill to 10,400. 21:15 - 21:30 0.25 DRILL P PROD1 Wiper to window.O.K. 21 :30 - 00:00 2.50 DRILL P PROD1 Directionally drill 1.5/1.5 bpm, 3940 psi, FS 3620, 1.7 K WOB, DH annular pressure 5100 spi, DH tubing [pressure 5800 psi, EDC11.0 ppg. drill to 10,500'. 1/10/2004 00:00 - 00:45 0.75 DRILL P PROD1 Continue to directionally drill build section. 1.5/1.5 bpm, 4160 psi, FS 3800 psi. 5K WOB, DH annular pressure 5140 psi, DH tubing pressure 5910 psi, 11.1 EDC, 00:45 - 01 :30 0.75 DRILL P PROD1 Continue to directionally drill. 1.55, 4025 psi, 3800 psi FS, DH annular pressure 5180 psi, DH tubing pressure 5736, 11.2 EDC. Begin mud swap with reclaimed system ( 2% L T, 1 % FL, 12 ppg KG 29000 LSRV) . Mud to bit 1.54 bpm, FS 3200 psi, Drill 1.66/1.66 bpm, 3700 psi 3300 psi, 1.7 K WOB, ECD 11.1 ppg. drill to 10,550'. 01 :30 - 03:00 1.50 DRILL P PROD1 POH. 03:00 - 04:00 1.00 DRILL P PROD1 Change bend in motor to 1.1 degree. 04:00 - 06:00 2.00 DRILL P PROD1 RIH BHA #8.Rerun bit graded 1:1 06:00 - 06:25 0.42 DRILL P PROD1 Log tie-in down from 10120' 0.3/1000 06:25 - 06:45 0.33 DRILL P PROD1 RIH to TD tagged at 10550' 06:45 - 09:15 2.50 DRILL P PROD1 Drill from 10550' 1.57/2960/80-120R in 40 api sand. Drill to 10710' 09:15 - 10:00 0.75 DRILL P PROD1 Wiper to window 10:00 - 14:00 4.00 DRILL P PROD1 Drill from 10710' to 10750' and identify markers. Drill from 10750' 1.5/2900/5R to target sand at 8898' TVD. Drill to 10885' 14:00 - 14:45 0.75 DRILL P PROD1 Wiper to window 14:45 - 17:25 2.67 DRILL P PROD1 Drill from 10885' 1.54/3000/90L and in and out of good quality sand to 11035' 17:25 - 17:50 0.42 DRILL P PROD1 Wiper to window 17:50 - 18:15 0.42 DRILL P PROD1 Log tie-in down from 10120'. Correction +5'. 18:15 - 18:35 0.33 DRILL P PROD1 Rlh tag at 11039'. 18:35 - 20:45 2.17 DRILL P PROD1 Directionally drill 1.65 /1.65 bpm, 3780 psi, 3250 psi FS, DH WOB 2.7K, DH annular pressure 4925 psi, DH tubing pressure 5713 psi, Drill to 11190'. 20:45 - 21 :40 0.92 DRILL P PROD1 Wiper to window. 0 K. 21 :40 - 23:25 1.75 DRILL P PROD1 Directionally drill 1.68/1.68 bpm, 3500 psi, 3350 psi FS, 27K DN, 14K UP, DH WOB 1 K, DH annular pressure 4910 psi, DH tubing pressure 5510 psi. 10.76 EDC. Rap 100+ ftIhr. Drill to 11340 23:25 - 00:00 0.58 DRILL P PROD1 Wiper to window. 1/11/2004 00:00 - 00:20 0.33 DRILL P PROD1 Continuation of wiper to window. OK. Tag TD at 11342. 00:20 - 01 :45 1.42 DRILL P PROD1 Directionally drill 1.66 /1.66 bpm @ 3650 psi. 3400 psi FS, WOB 1.5K, DH annular pressure 4950 psi, DH tubing pressure Printed: 1/19/2004 9:49:05 AM . . BP EXPLORATION Operations Summary Report Page 8 of 12 Legal Well Name: 1 5-04 Common Well Name: 15-04 Spud Date: 3/24/1982 Event Name: REENTER+COMPLETE Start: 12/26/2003 End: 1/17/2004 Contractor Name: NORDIC CALISTA Rig Release: 1/17/2004 Rig Name: NORDIC 2 Rig Number: N2 Date i ~ I Code NPT Phase Description of Operations From - To ¡ Hours i Task _______.._ ,W_'_n'_' ___n.__.___."_ .-.-.----.-....--.-.--.- 1/11/2004 00:20 - 01 :45 1.42 DRILL P PROD1 5610 psi, 10.7 EDC, Drill to 11490'. 01 :45 - 02:50 1.08 DRILL P PROD1 Wiper to window. No problems. 02:50 - 04:15 1.42 DRILL P PROD1 Directionally drill 1.6/1.6 bpm, at 3560 psi, 3250 psi FS, WOB 1.1 K, Rap 100+, 29 K Up wt, 13K DN wt, DH annular pressure 4940 psi, DH coil pressure 5650 psi, 10.8 ppg EDC. Drill to 11640'. 04: 15 - 05:25 1.17 DRILL P PROD1 Wiper to window. No Problems. 05:25 - 08:00 2.58 DRILL P PROD1 Directionally drill 1.6 /1.6 bpm @ 3390 psi. Find a sticky area at 11680-700' near projected fault area. Slowly losing wt transfer, but 6k is quite good considering mileage on mud. Drill to 11790' with a few 100' wipers. GR showing 30-40 api sand. Continuing slow build at 92 deg. Drill to 11800' 08:00 - 10:00 2.00 DRILL P PROD1 Wiper to window, clean. Test rig alarms. Log tie-in down from 10120', add 3.0'. RIH, clean 10:00-12:10 2.17 DRILL P PROD1 Drill from 11800' and swap to new Flo Pro mud 1.5/3000/90L continuing at 92 deg. Drill to 11950' (8867' TVD) and into 50-60 api sand 12:10 - 14:00 1.83 DRILL P PROD1 Wiper to window, clean both ways 14:00 - 16:15 2.25 DRILL P PROD1 Drill from 11950' 1.5/3000/60L and begin final push at 93.5 deg to TD. Run into a shale at 11960' and tough to make hole. Drill to 12090' and got back in sand at 12050'. Parted pipe drill 16:15-17:15 1.00 DRILL P PROD1 Wiper to window. No problems. 17:15 -17:35 0.33 DRILL P PROD1 Log tie-in down from 10122', add 5' 17:35 - 18:20 0.75 DRILL P PROD1 Wiper to TD 18:20 - 22:45 4.42 DRILL P PROD1 Directionally drill 1.6/1.6 bpm, @ 3200 psi, 3000 psi FS, 4-5K WOB, -4K surface weight, DH annulus pressure 4800 psi, DH coil pressure 5260 psi, EDC 10.4 ppg, FS 105R, Short wipers required. One set down at 12194. Drill to 12240'. 22:45 - 00:00 1.25 DRILL P PROD1 Wiper to window. No problems nothing at 12194'. 1/12/2004 00:00 - 00:45 0.75 DRILL P PROD1 Continuation of wiper to window. No probelms. 00:45 - 02:30 1.75 DRILL P PROD1 Directionally drill 1.5/1.5 bpm @ 3500 psi., 2900 psi FS, 2.4 K was, DH annular pressure 4820 psi, DH coil pressure 5770 psi, ECD 10.4 ppg, -4K surface wt, WOB 2K. Drill to 12,295' TD. TD with 1.3K WOB, -6K surface. Hard spot Call TD. 02:30 - 03:40 1.17 DRILL P PROD1 Wiper to window. 03:40 - 03:55 0.25 DRILL P PROD1 Log - in. correction +7'. 03:55 - 04:40 0.75 DRILL P PROD1 Wiper to TD. Corrected TD 12,295'. 04:40 - 05:00 0.33 DRILL P PROD1 POH to 11750'. Pin hole leak. Shut down pump and bleed off pressure. Spool pipe back. 05:00 - 06:40 1.67 DRILL P PROD1 Continue to POH with charge pump filling hole and back side shut in. 06:40 - 09:05 2.42 DRILL P PROD1 POH from window for liner 09:05 - 09:35 0.50 DRILL P PROD1 LD drilling BHA. SI swab. MIRU DS N2 Normal driving conditions 09:35 - 10:00 0.42 DRILL P PROD1 Fill CT w/ mud. Pump 10 B FW, then 5 B MeOH Safety mtg re: N2 blowdown 10:00 - 11 :30 1.50 DRILL P PROD1 Displ fluids in ECT reel w/ N2 and bleed off to flowback tank 11:30-12:45 1.25 DRILL P PROD1 Cut off CTC and install grapple connector. Pull CT to reel and secure 12:45 - 14:00 1.25 CASE P CaMP RU tools to run liner DS crew change/safety mtg re: simops 14:00 - 19:45 5.75 CASE P CaMP MU 73 jts 2-3/8" 4.7# L-80 STL liner with float equipment. Drift each connection Printed: 1/19/2004 9:49:05 AM ...... . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: Phase 12/26/2003 1/17/2004 N2 Spud Date: 3/24/1982 End: 1/17/2004 Date I I Task 'Code NPT From - To Hours -- -.. .--. .----- ______ ____._.._._n________ 1/12/2004 5.75 CASE P 3.75 CASE P CaMP CaMP 14:00 - 19:45 19:45 - 23:30 1/13/2004 23:30 - 00:00 00:00 - 03:00 0.50 CASE P 3.00 CASE P CaMP CaMP 03:00 - 03:20 0.33 CASE P CaMP 03:20 - 03:55 0.58 CASE P CaMP 03:55 - 06:40 2.75 CASE P CaMP 06:40 - 06:55 0.25 CASE P CaMP 06:55 - 07:35 0.67 CEMT P CaMP 07:35 - 08:10 0.58 CEMT P CaMP 08:10 - 08:45 0.58 CEMT P CaMP 08:45 - 10:20 1.58 CEMT P CaMP 10:20 - 10:45 0.42 CEMT P CaMP 10:45 - 18:30 7.75 BOPSURP CaMP 18:30 - 18:40 0.17 CLEAN P CaMP 18:40 - 22:00 3.33 CLEAN P CaMP 22:00 - 23:20 1.33 CLEAN P CaMP 23:20 - 00:00 0.67 CLEAN P CaMP 1/14/2004 00:00 - 01 :35 1.58 CLEAN P CaMP Page 9 of 12 Description of Operations ._~.M·_._.·_·____ Swap out E-CT for 2" e-free CT MU internal coil grapple. Pull coil to the injector stab coil. Fill coil. Pump Dart. Coil volume 39.4 bbl actual theoritical 41.3. Install weldon connector. Pull to 30K. MU liner running tool and stab injector. RIH with liner circulating at .2 bpm at 525 psi. RIH with liner. Up wt at window 30K. Set down 11,989. 12011,12023, 12041, 12103, 12105, Numerous set down at 12105 no over pulls Loosing ground to 12060 12077, 30 k up 13.6 K dn. Work back to 12105, Stack -7K and attempt to wash down. No Go. Over pull to 48K up. Pull free. Set down 12102, Unable to make forward progress. Loosing ground periodically and have to work to gain it back. Discuss with town team. Well is ramping up with high DL 14- 27. Will lose about 80' of perforations. Liner top still 220' below 9-5/8 shoe. Decided to call this TD. 12098'. Drop 5/8" ball and displace at .5 bpm at 1770 psi. Slow to .3 bpm and 1300 psi at 31 bbl into displacement. Ball on seat @ 32.2 bbl. Shear at 2725 psi. PU at 27000. MIRU DS Change over to KCL.1.4 bpm /1.1 bpm @ 2700 psi. Circ 1.0/0.9/1780 Safety mtg re: cement Batch up cement Load CT w/16 bbls 15.8 ppg G cement w/latex 1.6/1.2/3230. Load wiper dart while DS suck back lines. Check and dart was gone Displace dart w/ 30 bbls biozan followed by KCI1.9/1.2/3340. After cement exited shoe reduced rate to 1.3/0.5/3060 when annulus started packing off. Returns varied from 0.3 to 0.6 bpm. Dart latched LWP at 39.8 bbls and sheared at 4000 psi. Displace LWP at 1.25/1.0/3340 and returns gradually improved until nearly full returns when LWP bumped at calc displ to 3600 psi. Out MM showed 11.8 bbls around shoe. Bleed off CT and check floats, ok. Put 500 psi on CT and unsting at 25.5k. CIP 0845 hrs Note: TaL 9820', PBD 12064', shoe set @ TD of 12098' CTD. Est TOC 9900' (assuming 40% excess in OH) POOH diluting any cement above TaL w/ biozan and taking minimal returns LD CTLRT and load out tools Weekly BOPE test. Witness waived by AOGCC John Spalding. Repaired choke manifold valve #1 Safety mtg re: CSH MU 1.875" D331, 1-11/16" motor, MHA MU 76 jts 1" CSH RIH w/ BHA #10. Cmt is 2000 psi Tag at 9830' CTD 0.3/1000 26k, 19.1 k Start motor 0.9/2070. RIH and stall at 9831' CTD. Mill cement from 9831.0' to 9831.3' Continue milling cement at TaL from 9831.3'. Got 9.0 ppg back just before btms up. Mill to 9834.5' and broke thru. Ream thru 3 times until clean Printed: 1/19/2004 9:49:05 AM . . Page 10 of 12 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase _.~-~........... 1/14/2004 01 :35 - 02:45 1.17 CLEAN P COMP 02:45 - 04:30 1.75 CLEAN P CaMP 04:30 - 06:30 2.00 CLEAN P CaMP 06:30 - 09:30 3.00 EVAL P CaMP 09:30 - 10:45 1.25 EVAL P CaMP 10:45 - 13:25 2.67 EVAL P CaMP 13:25 - 14:30 1.08 EVAL P CaMP 14:30 - 15:00 0.50 EVAL P COMP 15:00 - 17:30 2.50 EVAL P CaMP 17:30 - 18:45 1.25 PERF P COMP 18:45 - 20:15 1.50 PERF P CaMP 20:15 - 21 :10 0.92 PERF P CaMP 21 :10 - 23:10 2.00 PERF P CaMP 23: 10 - 23:40 0.50 PERF P CaMP 23:40 - 00:00 0.33 PERF P COMP 1/15/2004 CaMP 00:00 - 00:30 0.50 PERF P 00:30 - 02:10 1.67 PERF P CaMP 02: 1 0 - 03:30 1.33 PERF P CaMP 03:30 - 03:45 0.25 PERF P CaMP 03:45 - 05:30 1.75 PERF P CaMP 05:30 - 05:45 0.25 PERF P CaMP 05:45 - 06:10 0.42 PERF P CaMP 06: 1 0 - 06:30 0.33 PERF P CaMP 06:30 - 08:00 1.50 PERF P CaMP 08:00 - 10:20 2.33 PERF P CaMP 10:20 - 11 :00 0.67 PERF P CaMP 11 :00 - 13:00 STUC CaMP 2.00 PERF N 13:00 - 15:00 STUC CaMP 2.00 PERF N Start: 12/26/2003 Rig Release: 1/17/2004 Rig Number: N2 Spud Date: 3/24/1982 End: 1/17/2004 Description of Operations RIH clean to tag at 12071' CTD. Tag 3 times and stack 5k, but had no motor work 0.9/2350 POOH Drop ball and open circ sub. Standback CSH MU CNL memory log. RIH with CS Hydril. RIH to 9000'. LOG down 60 ftlmin. Lay in Log up 30 ftlmin. Flag 6612 EOP. POH to surface. Swapped wellbore/pit fluids out for fresh KCI Test liner lap to 2000 psi for 30 min. Good test 20 psi loss. Set back injector. Stand back 1" CS Hydril. PJSM regarding picking up guns Crew XO Safety mtg re: perf guns MU 26 perf guns and blanks MU 28 stds 1" CSH RIH w/ BHA #20 (perf gun run #1) 0.25/240. Tag at 12079' CTD 28k, 16k Retag at 12078.5' and corr to 12071' ELMD PUH 28.5k to 11980' (9690.03' EOP) and flag CT (yellow). Investigate reel hydraulic leak on DS. Find crack in reel drive motor planetary gear case. Disconnect chain drive on same side. Function test, okay. Will use the other side only until repairs can be made Park at perf depth. Pump 10 bbls fresh HLSRV mud into CT 1.0/1700 Load 1/2" steel ball and displ w/ mud. Chase ball to seat w/ KCI1.5/3640. Ball on seat at 0.6/500 and sheared at 2900 psi. Went on immediate vac Perforated 11530-11930' and 12010-12061' w/1.56" SWS HSD PJ guns at 4 spf POOH 32k w/ partial returns 1.1/0.5/1000 and losing avg 0.4 bpm initially, but healing slowly Stand back 8 stds. LD 40 singles. Hole taking 3-4 bph static Safety mtg re: LD perf guns LD 26 spent perf guns and blanks Load out CSH singles. Bundle spent guns Safety mtg re: MU perf guns MU perf guns for run #2 Crew change/safety mtg Continue to MU perf guns for run #2 and 1" CS Hydril. RIH tie in to 9690' EOP flag and correct -4'. Pump 5 bbl pill Drop .5" ball. Displace with 5 bbl pill and KCL at 1.6 bpm @ 3300 psi. Ball on seat .5 bpm/509 psi. and sheared at 33.7bbls 2970 psi. Stuck Lost returns temporily. Perforated 10,790 - 10810 : 10975 - 10995 : 11030 - 11230 and 11328 - 11520' w/1.56" SWS HSD PJ guns at 4 spf. Shut down pump Pull over up to 30K, No Go. Stackout zero surface wt. No Go. Periodically pump to warm coil. Total losses 30 bbl. Circulate 6 bbl and got returns to surface. Shutin well and bullhead pressure up t01500 psi. Bleed off quick. No Go. Pressure backside and bleed back to coil numerous times with pipe in tension and then compression. Order out crude oil. Wait on crude oil. Printed: 1/19/2004 9:49:05 AM . . Page 11 of 12 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase ____..__0."_____ _._.~-_._-- 1/15/2004 1.00 PERF N STUC CaMP 15:00 - 16:00 16:00 - 18:00 2.00 PERF N STUC COMP 18:00 - 19:15 1.25 PERF N STUC CaMP 19:15 - 19:30 0.25 PERF N STUC CaMP 19:30 - 20:20 0.83 PERF N STUC CaMP 20:20 - 20:30 0.17 PERF N STUC CaMP 20:30 - 21 :40 1.17 PERF N STUC CaMP 21 :40 - 23:35 1.92 PERF N STUC CaMP 23:35 - 23:50 0.25 PERF N HMAN CaMP 23:50 - 00:00 0.17 PERF N HMAN CaMP 1/16/2004 0.58 PERF N HMAN CaMP 00:00 - 00:35 00:35 - 01 :40 1.08 PERF N STUC CaMP 01 :40 - 03:10 1.50 PERF N STUC CaMP 03:10 - 03:20 0.17 PERF N HMAN CaMP 03:20 - 04:30 1.17 PERF N HMAN CaMP 04:30 - 05:45 1.25 PERF N STUC CaMP 05:45 - 08:00 2.25 FISH N STUC CaMP 08:00 - 08:25 0.42 FISH N STUC CaMP 08:25 - 09: 15 0.83 FISH N STUC CaMP 09:15 - 11 :00 1.75 FISH N STUC CaMP 11 :00 - 11 :45 0.75 FISH N STUC CaMP 11 :45 - 12:00 0.25 FISH N STUC CaMP 12:00 - 12:10 0.17 FISH N STUC CaMP Start: Rig Release: Rig Number: 12/26/2003 1/17/2004 N2 Spud Date: 3/24/1982 End: 1/17/2004 Description of Operations -------.----..- .....---... Circulate 15 bbl crude 1.25/1.21 bpm at 2130 psi. Circulate 7 bbl crude out of fireing head and shut in well. Bull head .17 bpm at 500 psi. 2.8 bpm @ 1400 psi circulating and 1260 psi wellhead. Shut in pump Hold 20K over. Bull head .14 bpm at 740 psi .2bbl. Wait. Slack off to 1 K surface wt. Circ 0.6/0.6/500 while discuss. Crude returns periodically Will disconnect at perf guns, then fish Safety mtg re: next step Move crude transport, MIRU MeOH trailer Load out perf guns and send SWS to shop Safety mtg re: disconnect Load 5/8" steel ball and chase w/20 bbls MeOH (as precaution if disconnect pressure too high, -25F) and chase w/ fresh KCL. Let ball fall Fin circ ball to seat and sheared at 3100 psi. PUH 30k, free. POOH displacing CT to fresh KCI 0.7/3500. CTP flucuated from 2800-4300 psi at 0.6 bpm while POH Tagged up w/ CTC at normal POOH speed. Swivel parted in chains. CT backspooled over roof and CTC stopped at horsehead. Lower BHA was stuck in injector chains. Pump was shut down early and floor got wet, but had a few drips of KCI on roof. Discuss and formulate a game plan Cause was subtraction error when taking BHA length out of CT length after starting off btm Fold down gooseneck. Unstab and lift injector. Set handslips and DC on CSH Lift injector 30' exposing T J on second jt and set on hand slips. Break CSH connection and lower 1 st jt into mouse hole. Pull 1 st jt out the top of injector and LD. Set injector back. Change two gripper blocks, packoff RU CSH tools. LD first single and standback 16 Load perf gun fishing tools to floor. MU BTT fishing BHA (2" GS, jars, accel). MU 16 stds CSH. Install upper MHA Safety mtg re: pull CT to floor Lift injector w/ blocks. Pull winch line thru injector and over roof. Hook to CT stub in reelhouse after clamping off. Cut off CTC and install internal grapple. Pull CT to floor Cut off grapple assy. Cut 50' CT for chrome management. Install Kendall connector. PT 20k, 4000 psi RIH w/ BHA #14 Tag 10772.6, 16K DN, 26K UP, Jar down 10K 10 licks. No Go. Jar up 8K over 4 licks. No Go PU to 14 over hold Jar 1 OK over 6 licks pull to 53K NoGo, Slack off 6K down circulate at .8 bpm 2870 psi. Change well over to crude oil @ .8 bpm at 3000 psi. Circulate 25 crude out of fishing BHA. Shut in and bullhead 25 bbls .23 bpm at 2400 psi increase rate gradually to .7 bhm at 4000 psi. Circulate crude back to surface. Shut in well. Latch up to fish. DN wt 14K, 18K Up WT. Tag at 10772. Jar down 10K after two licks picked up to cock jars pipe free. Printed: 1/19/2004 9:49:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 12 of 12 BP EXPLORATION Operations Summary Report 15-04 15-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task iCode NPT Phase -..----..-.-- 1/16/2004 12:00 - 12:10 0.17 FISH N STUC CaMP 12:10 - 14:10 2.00 PERF P CaMP 14:10 - 14:30 0.33 PERF P CaMP 14:30 - 14:40 0.17 PERF P CaMP 14:40 - 17:00 2.33 PERF P CaMP 17:00 - 17:20 0.33 PERF P CaMP 17:20 - 18:00 0.67 PERF P CaMP 18:00 - 18:15 0.25 PERF P CaMP 18:15 - 21 :00 2.75 PERF P CaMP 21:00 - 21:15 0.25 PERF P CaMP 21:15 - 22:45 1.50 PERF P CaMP 22:45 - 00:00 1/17/2004 00:00 - 01 :45 01 :45 - 04:00 04:00 - 06:00 1.25 RIGD P CaMP 1.75 RIGD P CaMP 2.25 RIGD P CaMP 2.00 BOPSURP POST Start: 12/26/2003 Rig Release: 1/17/2004 Rig Number: N2 Spud Date: 3/24/1982 End: 1/17/2004 Description of Operations ...---.----.-...... .----.- --.-..-. RIH to 10782. POH 3500 # over up wt. Monitor well. Dead. PJSM discuss plan forward. Issues regarding pulling oil wet pipe. Standback 1" Desided to stand back CSHydril to allow oil to grain better. PJSM to LD guns. Lay down perforating guns Safety mtg after crew XO Resume LD perf guns and load out. All shots fired. No obvious damage or swelling of guns Safety mtg re: next steps/SIMOPS RU tools. LD CSH using mousehole Bullhead 15 bbls MeOH down wellbore for FP to 1700' at final 0.2 bpm @ 1900 psi WHP, 10 min 700 psi. SI swab and master 22 3/4 Install 3" side jet nozzle. Stab on injector. Displace crude from CT w/ KCI Safety mtg re: N2 PT DS N2 at 3500 psi. Displace CT w/ N2 to flowback tank and bleed down Phz 1 Pull CT to reel and secure. Open bombay doors and load out 2" reel ND BOPE. Install tree cap and test RREL @ 0600 hrs 1/17/04 Printed: 1/19/2004 9:49:05 AM ~ ObP . BP-GDB . Baker Hughes INTEQ Survey Report &03 r- , 1 i IB¡¡W IIAKDt IIUGIIIS INTEQ Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 15 15-04 15-04A Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft D~te:.. 2/10/2004 . . Time: 10:48:01 Page: CO-Qrdinate(NE) Reference: Well: 15-04, True North Vertical (TVD) Reference: 4 : 04 3/24/1982 00:0063.0 Section (VS) Reference: Well (0.00N,O.00E,320.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: 35.236 N 21.213W True 1.34 deg Well: 15-04 Slot Name: 04 15-04 Well Position: +N/-S 1445.51 ft Northing: 5960280.17 ft Latitude: 70 17 49.453 N +E/-W -94.34 ft Easting : 676168.77 ft Longitude: 148 34 23.963 W Position Uncertainty: 0.00 ft Height 63.00 ft Wellpath: 15-04A 500292072601 Current Datum: 4 : 04 3/24/1982 00:00 Magnetic Data: 6/17/2003 Field Strength: 57551 nT Vertical Section: Depth From (TVD) ft 32.00 Survey Program for Definitive Well path Date: 2/10/2004 Validated: Yes Actual From To Survey ft ft 50.00 10314.50 Gyro (50.00-10314.50) (0) 10315.10 12295.00 MWD (10192.00-12295.00) Annotation MJ) TVD ft ft 10100.00 8732.12 TIP 10192.00 8812.10 KOP 12295.00 8896.64 TD Survey: MWD Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Survey MJ) Inel Azim TVD SSTVD ft deg deg ft ft 10100.00 29.93 276.67 8732.12 8669.12 10192.00 29.31 277.13 8812.10 8749.10 10216.00 25.00 274.50 8833.45 8770.45 10246.93 32.22 271.80 8860.59 8797.59 10276.84 42.41 269.20 8884.34 8821.34 10307.47 52.40 266.60 8905.05 8842.05 10337.81 62.28 264.45 8921.40 8858.40 10367.64 72.65 257.27 8932.83 8869.83 10398.61 84.22 259.10 8939.03 8876.03 10429.21 91.23 267.15 8940.25 8877.25 10462.42 88.83 282.16 8940.23 8877.23 ~'6~f\\~ +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 15-04 10192.00 ft Mean Sea Level 25.88 deg 80.84 deg Direction deg 320.00 Version: 2 Toolcode Tool Name BOSS-GYRO MWD Sperry-Sun BOSS gyro multishot MWD - Standard f~CCE'VED rr-B 1 :: 206~ Start Date: 1/12/2004 Ala3KsOiI& Gas ConS.commitiO!1\ From: Definitive Path~ Engineer: Tied-to: N/S E/W MapN MapE VS DLS ft ft ft ft ft deg/100ft -95.54 -4096.77 5960088.63 672075.63 2560.16 0.00 -90.08 -4141.91 5960093.03 672030.38 2593.36 0.72 -88.96 -4152.80 5960093.90 672019.46 2601.22 18.64 -88.18 -4167.58 5960094.33 672004.67 2611.31 23.71 -88.07 -4185.68 5960094.01 671986.57 2623.04 34.47 -88.94 -4208.18 5960092.62 671964.10 2636.83 33.20 -90.96 -4233.61 5960090.01 671938.73 2651.64 33.10 -95.39 -4260.74 5960084.94 671911.71 2665.68 41.24 -101.58 -4290.39 5960078.06 671882.22 2680.00 37.80 -105.23 -4320.70 5960073.70 671852.00 2696.68 34.86 -102.54 -4353.71 5960075.61 671818.94 2719.96 45.77 ObP . BP-GDB . _íí. BAKIR HUGIll. Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 2/10/2004 Time: 10:48:01 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Refer.ence: Well: 15-04, True North Site: PB DS 15 Vertical (fVD) Reference: 4: 04 3/24/1982 00:00 63.0 Well: 15-04 Section (VS) Reference: Well (0.00N,0.00E,320.00Azi) Wellpath: 15-04A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 10492.73 88.46 292.07 8940.95 8877.95 -93.64 -4382.63 5960083.84 671789.82 2745.37 32.71 10524.72 86.31 304.87 8942.42 8879.42 -78.44 -4410.66 5960098.37 671761.44 2775.03 40.53 10552.26 84.40 312.72 8944.65 8881.65 -61.26 -4432.04 5960115.05 671739.67 2801.94 29.24 10587.58 87.36 318.06 8947.19 8884.19 -36.19 -4456.77 5960139.53 671714.36 2837.04 17.25 10621.81 86.50 322.75 8949.02 8886.02 -9.86 -4478.55 5960165.34 671691.97 2871.21 13.91 10653.24 87.55 327.12 8950.65 8887.65 15.83 -4496.58 5960190.59 671673.35 2902.47 14.28 10684.74 88.06 330.82 8951.86 8888.86 42.80 -4512.80 5960217.17 671656.50 2933.55 11.85 10713.48 86.71 327.44 8953.17 8890.17 67.44 -4527.53 5960241.46 671641.20 2961.90 12.65 10745.34 86.90 323.06 8954.95 8891.95 93.57 -4545.65 5960267.16 671622.47 2993.57 13.74 10777.44 89.82 324.29 8955.87 8892.87 119.41 -4564.66 5960292.55 671602.86 3025.58 9.87 10810.09 91.75 322.21 8955.42 8892.42 145.57 -4584.19 5960318.24 671582.72 3058.17 8.69 10841.21 92.33 318.03 8954.31 8891.31 169.43 -4604.13 5960341.62 671562.24 3089.27 13.55 10873.04 92.39 313.86 8953.00 8890.00 192.28 -4626.24 5960363.95 671539.60 3120.98 13.09 10909.70 91.87 311.46 8951.64 8888.64 217.10 -4653.17 5960388.13 671512.09 3157.31 6.69 10941.02 89.75 307.12 8951.20 8888.20 236.93 -4677.40 5960407.38 671487.40 3188.08 15.42 10974.29 91.96 302.52 8950.70 8887.70 255.92 -4704.71 5960425.73 671459.66 3220.17 15.34 11007.86 94.92 306.74 8948.68 8885.68 274.95 -4732.27 5960444.11 671431.66 3252.47 15.34 11032.67 94.21 310.12 8946.71 8883.71 290.32 -4751.64 5960459.02 671411.94 3276.70 13.88 11066.34 92.73 313.90 8944.67 8881.67 312.81 -4776.61 5960480.91 671386.45 3309.97 12.04 11106.53 90.40 318.95 8943.57 8880.57 341.91 -4804.29 5960509.35 671358.10 3350.05 13.83 11142.30 91.96 325.39 8942.83 8879.83 370.14 -4826.21 5960537.06 671335.52 3385.77 18.52 11180.95 88.16 323.02 8942.79 8879.79 401.48 -4848.81 5960567.86 671312.20 3424.31 11.59 11213.97 86.96 319.84 8944.20 8881.20 427.27 -4869.37 5960593.16 671291.03 3457.28 10.29 11248.45 88.16 316.13 8945.67 8882.67 452.86 -4892.43 5960618.20 671267.39 3491.70 11.30 11284.29 91.35 313.96 8945.82 8882.82 478.22 -4917.75 5960642.95 671241.48 3527.40 10.76 11316.90 91.81 313.55 8944.92 8881.92 500.76 -4941.29 5960664.94 671217.42 3559.80 1.89 11348.33 91.53 307.39 8944.01 8881.01 521.14 -4965.18 5960684.75 671193.06 3590.77 19.61 11381.30 91.35 304.44 8943.18 8880.18 540.47 -4991.87 5960703.45 671165.93 3622.74 8.96 11411.96 92.33 303.91 8942.19 8879.19 557.68 -5017.22 5960720.06 671140.18 3652.22 3.63 11445.72 94.79 310.07 8940.09 8877.09 577.94 -5044.12 5960739.69 671112.81 3685.03 19.61 11477.71 92.05 312.04 8938.19 8875.19 598.92 -5068.20 5960760.08 671088.25 3716.57 10.54 11509.24 92.21 317.41 8937.01 8874.01 621.08 -5090.58 5960781.72 671065.36 3747.93 17.03 11540.43 93.07 320.96 8935.58 8872.58 644.66 -5110.94 5960804.81 671044.46 3779.08 11.70 11571.68 92.52 327.00 8934.05 8871.05 669.89 -5129.28 5960829.60 671025.52 3810.21 19.38 11602.69 91.75 331.46 8932.90 8869.90 696.51 -5145.13 5960855.84 671009.06 3840.78 14.59 11636.81 92.73 336.73 8931.56 8868.56 727.17 -5160.02 5960886.14 670993.45 3873.84 15.70 11669.03 92.33 339.75 8930.14 8867.14 757.06 -5171.96 5960915.74 670980.83 3904.41 9.45 11701.25 92.88 344.07 8928.67 8865.67 787.65 -5181.95 5960946.08 670970.12 3934.26 13.50 11735.86 92.58 348.39 8927.02 8864.02 821.21 -5190.17 5960979.45 670961.11 3965.27 12.50 11772.51 91.32 354.16 8925.78 8862.78 857.40 -5195.73 5961015.50 670954.71 3996.56 16.11 11805.80 92.43 356.89 8924.69 8861.69 890.57 -5198.32 5961048.59 670951.34 4023.63 8.85 11837.88 91.87 352.29 8923.48 8860.48 922.48 -5201.34 5961080.41 670947.57 4050.02 14.43 11867.76 91.47 348.84 8922.61 8859.61 951.93 -5206.24 5961109.75 670941.98 4075.73 11.62 11899.17 92.67 344.40 8921.48 8858.48 982.46 -5213.50 5961140.10 670934.01 4103.79 14.63 11951.47 91.93 339.00 8919.38 8856.38 1032.06 -5229.90 5961189.29 670916.45 4152.32 10.41 11985.11 93.32 337.42 8917.83 8854.83 1063.26 -5242.38 5961220.19 670903.25 4184.24 6.25 12014.31 92.43 334.33 8916.37 8853.37 1089.87 -5254.30 5961246.52 670890.71 4212.29 11.00 12064.85 92.43 326.10 8914.22 8851.22 1133.66 -5279.36 5961289.70 670864.63 4261.94 16.27 12097.96 94.17 321.73 8912.32 8849.32 1160.37 -5298.82 5961315.94 670844.55 4294.91 14.19 12131.83 94.45 329.87 8909.77 8846.77 1188.28 -5317.79 5961343.40 670824.93 4328.48 23.98 12161.51 94.42 338.05 8907.47 8844.47 1214.84 -5330.77 5961369.65 670811.34 4357.17 27.48 12197.45 93.50 333.90 8904.98 8841.98 1247.58 -5345.36 5961402.03 670795.98 4391.64 11.80 12229.78 95.50 338.40 8902.45 8839.45 1277.05 -5358.39 5961431.19 670782.26 4422.59 15.19 ObP BP Amoco Prudhoe Bay PB DS 15 15-04 15-04A Company: Field: Site: Well: Wellpath: Survey MD ft 12260.53 Incl deg 94.98 12295.00 94.98 Azim deg 345.17 345.17 . BP-GDB . Baker Hughes INTEQ Survey Report TVD SSTVD ft ft 8899.64 8836.64 8896.64 8833.64 BíiI. B.A.KEa HUGHH INTEQ Date: 2/10/2004 Time: 10:48:01 Page: 3 Co-órdinate(NE) Reference: Well: 15-04; True North Vertical (TVD) Reference: 4: 04 3/24/1982 00:00 63.0 Section (VS) Reference: Well (0.00N,O.00E.320.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle N/S EIW MapN MapE VS DLS ft ft ft ft ft deg/1 OOft 1306.12 -5367.96 5961460.02 670772.02 4451.00 21.99 1339.32 -5376.75 5961493.00 670762.45 4482.08 0.00 BP Amoco LEGEND T Azimuths to True North Magnetic North: 25.88' Magnetic Field 51nT .84' : 6/17/2003 Model: bggm2003 Parent Wellpath: Tie on MO: WELLPATH DETAILS 15-Q4A 500292072601 15-04 10192.00 Nordic 2 4: 04 3/24/1982 00:00 63.000 We!1path: (15-04/15-04A) Created By: Bríj Potnís Data: 2/10/2004 Rig: Ref. Datum: V.Section Origin Origin Angle +N/-S +Ef·W 320.00" 0.00 0.00 Starting From TVO 32.00 1500 REFERENCE INFORMATION Co-ordlnate IN/Ej Reference: Vertical (tvD Reference: Section (VS Reference: Measured Depth Reference: Calculation Method: Well Centre: 15-04, True North System: Mean Sea Level Slot - 04 (O.OON,O.OOE) 4 : 04 3/24/1982 00:00 63.00 Minimum Curvature 1400 1300 1200 1100 ANNOTATIONS +EI_W $l>apo. NO MD Annotation ....1000 .5 == 900 e ~ 800 ..... -6300 -6200 -6100 -6000 -5900-5800 -5700 -5600 -5500 -5400 -5300 -5200 -51 00 -5000 -4900 -4800-4700 -4600-4500 -4400 -4300 -4200 -4100 -4000-3900 -3800-3700 West(-)/East(+) [100ft/in] 8669,12 10100.00 TIP 8749.08 10192.00 KOP 8833.62 12295.00 TO +,700 - :ë 600 0 Z 500 -. ..... . - 400 J:: .. ::I 0 300 7800 tfJ 200 7900 100 8000 0 ';"8100 æ 8200 -100 e e -200 "",8300 ..... ;:8400 Q. QI Q8500 ~ 8600 ¡8700 :> Ql8800 2 1-8900 9000 9100 9200 20002100220023002400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 Vertical Section at 320.00· [100ft/in] 2/10/2004 10:45 AM lID r !Æ~!Æ ~ ~~!Æ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 15-04A BP Exploration (Alaska), Inc. Permit No: 203-114 Surface Location: 1206' SNL, 237' EWL, Sec. 22, T11N, R14E, UM Bottomhole Location: 5' NSL, 5053' WEL, Sec. 16,T11N, R14E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ ~Þ1-'~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thisB day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section 1 a. Type of work 0 Drill III Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 676169, Y = 5960280 1206' SNL, 237' EWL, SEC. 22, T11N, R14E, UM At top of productive interval x = 672286, Y = 5960022 1375' SNL, 3651' WEL, SEC. 21, T11N, R14E, UM At total depth x = 670850, Y = 5961369 5' NSL, 5053' WEL, SEC. 16, T11N, R14E, UM 12. Distance to nearest property line 113. Distance to nearest well / ADL 028305, 227' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10225' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casina Weight Grade Couclina 2-3/8" 4.6# L-80 FL4S Hole 3" ~(¡A- /"/2-0./ 12--00J _ STATE OF ALASKA ALASKA (WAND GAS CONSERVATION COMMllloN PERMIT TO DRILL 20 AAC 25.005 11 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool KBE = 63' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028306 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' 15-04A 9. Approximate spud date 08/21/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 /12150' MD / 8850' TVDss o 17. Anticipated pressure {s~20 MC 25.035 (e) (2)} 94 Maximum surface 2360 psig, At total depth (TVD) 8800' / 3250 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 2150' 10000' 8591' 12150' 8850' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantity of Cement (include staae data) 74 sx Class 'G' ,/ 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 6716' 7" 946 sx Class 'G' 1190' 7" 350 sx Class 'G' 1279' 4-1/2" 145 sx Class 'G' Open: 10340' - 10360', 10360' - 10380' Sqzd: 10283' - 10318', 10324' - 10334' true vertical Open: 8951' - 8968', 8968' - 8986' Sqzd: 8901' - 8931', 8937' - 8945' III Filing Fee 0 Property Plat III BOP Sketch III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis Contact Engineer Name/Number: Dan Kara, 564-5667 Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I hereby cert"" that ;t>Õ~g~:?,d correct to the best of my knowtedge . Signed Dan Kara \ <-... Title CT Drilling Engineer Date ~ I, c¡ 10 3 ...... ..... ... . . C~ion Use. Qnly . .... ·1 API Number· . .. I APprovaZD te' I See cover letter 50- 029-20726-01 r, 1_ z.Jf 03 for other reauirements Samples Required 0 Yes I8J No Mud Log Requi ed 0 Yes 1m No Hydrogen Sulfide Measures BI Yes 0 No Directional Survey Required BJ Yes 0 No Required Working Pressure for BOPE D2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Test foPE fo ~S"oo (Hr. ~ þ / by order of :~~~0~~~..!31__ __ ... -85 . . ~~ CommiS~iî~r, A I the commission CftIUIRi. , I I, ~~,~ 0 K \ G I\\J L Casing Structural Conductor Surface Intermediate Production Liner Tieback Liner Liner Scab Liner Perforation depth: measured 20. Attachments Permit Number <..oJ'-/'/'-?I Conditions of Approval: 10460 feet 9057 feet 10454 feet 9052 feet Length Size Cemented Plugs (measured) JtJN 2 0 Junk (measured) 110' 2649' 9588' 400 sx Permafrost II 2100 sx Fondu, 400 sx PF 'C' 500 sx Class 'G' 110' 2649' 9588' 110' 2649' 8312' 20" 13-3/8" 9-5/8" 2451' - 9167' 9270' - 10460' 9159' - 10438' 2451' - 7989' 8067' - 9057' 7983' - 9037' o Diverter Sketch III Drilling Program o Seabed Report 11I20 AAC 25.050 Requirements Date ~/¥/Ò) Submit In Triplicate e e BP 15-04A RWO/CTD Sidetrack Summary of Operations: Well 15-04 is scheduled for a through tubing sidetrack with coiled tubing. Prior to CTD sidetracking, the perfs will be P&A'ed with cement and the 3-112" L-80 tubing will be replaced with 3-112" 13-Chrome tubing. The sidetrack, 15-04A, will kick off from a window milled off a mechanical whipstock. The lower Romeo Zone lA will be the target for the sidetrack. Approximately 1925' of 3" bi-center open hole is planned to access the target. The well will be completed with a solid, cemented liner. Once the liner is in place a memory GR/CCLlCNL log will be run and perforations shot. A liner top packer will be run if necessary. Pre-rig Prep work. Planned for July 10,2003 startup. 1. MIT inner annulus to 3500 psi. 2. Slickline to pull tubing patch at 4306' md. 3. Service coil tubing P&A perfs with 15 bbls Class G cement. Leave TOC at 10250'. 4. Caliper 4-112" liner 5. Chemical cut tubing at -9090' md. Nordic 2 RWO - Tubing Swap. Planned for August 21, 2003 startup. 1. RU Nordic 2 with 13-5/8" BOPE. Test stack. 2. Pull 3-112" L-80 tubing. 3. RIH with drill pipe, fish out tubing stub. 4. RIH with casing scraper run. 5. Complete well with 3-112" 9.3# 13Cr-80 tubing with new packer. Stab tailpipe into old packer. 6. PT completion. RD 13-5/8" BOPE. NU tree and 7-1116" CTD BOPE. Test. 7. Install whipstock at 10225'. 8. Continue forward with CTD window milling and open hole drilling. Nordic 2 CTD - Mill window, Drill and Complete sidetrack: 1. Mill 2.74" window from whipstock at 10225', through the 4-112" scab liner and 7" production liner. 2. Directionally drill-1925' of 3" bi-center hole to access Zone lA reserves. 3. Run 2-3/8" liner from TD up.(6l'p,OOO' md. 4. Cement liner in place with ~bþts, 15.8 ppg Class G cement. 5. Case hole log new lateral witlf"memory GR/CNLlCCL. 6. Perforate selected intervals. 7. Install liner top packer if necessary. 8. RD Nordic 2. There may be advantages to pumping the P&A cement after the tubing swap and whipstock has been set. It could be beneficial to having as much rathole as possible below the planned KOP for potential junk falling down during the tubing swap. Abandonment of the existing perforations may be done following the /' tubing swap as opposed to prior to Nordic 2 RU. In either case, the existing perforations will be isolated prior to window milling. Mud Program: · RWO: 2% KCI an~~]. Biozan for milling. · CTD: Flo-Pro (8.6~pg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. e e Casing Program: / · 2150' of 2-3/8" STL 4.6#LL~.-80 om TD up into the 4-1/2" scab liner to 10,000' md. · Cement liner in place witus, 15.8 ppg Class G cement Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. /' · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan, 1925' planned horizontal. Max. planned hole angle is approx. -94 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray will be run over the entire open hole section. · Memory CNLlCCLlGR to be run in cased hole. Hazards /' · The most recent H2S test on 15-04 was 2 ppm on 2/27/01. DS-15 is not considered an H2S pad. · Lost circulation risk is considered medium. Reservoir Pressure · Pore pressure is estimated to be 3250 psi at 8800'TVDss (7.1 ppg emw). · Maximum surface pressure with gas (0.1 psi/ft) to surface is 2360 psi / TREE = WI3..LHEAD = ACTUATOR = "KB. EL:Ëv = B F. ELEV ;;-.. KOP= Max Angle = Dab.Jm MD = Dab.JmTVD= e FMC GB'J 2 FMC AX13..S0N 63' -3039' 45 @ 8500' --- 10240' 8800' SS 5-1/2" TBG-FC, 17#, L-80, 0.0232 bpf, ID = 4.892" 1-1 73' 1 TOP OF 7' LNR-llEBACK H 2451' 113-3/8" CSG, 72#, L-80, ID = 12.347' H 2649' I Minimum ID = 1.75" @ 4306' I ECLIPSE PATCH 1 TOPOF4-112" LNR- SCAB H 17" LNR- TIEBACK, 26#, L-80, 0.0383 bpf, ID = 6.276" H 13-1/2" TBG-PC, 9.3#, L-BO, .0087 bpf, D = 2.992" H ITOPOF7" LNR H 19-5/8" CSG, 47#, L-BO, ID = 8.681" H ÆRFORA 1l0N SUMMA.RY R8' LOG: BI-CS ON 04119/82 ANGLE AT TOP PERF: 28@ 10283' Note: Refer to Production DB for historical perf data SIZE SPF IN1ERVAL Opn/Sqz DATE 3-1/8" 4 10283 -10318 S 10/13/90 3-1/8" 4 10324 - 10334 S 10/13/90 2-5/8" 6 10340 - 10380 0 02/14/91 z~ 9112' H 7-1/2" X 3-112" BAKER FB-1 PKR, D = 4.0" } I 1 9115' H 3-1/2" BAKER SEAL BOREEX1ENSION I I H 9124' 3-1/2" BAKER CONŒN1RB'JIC COUPLING ì 9125' H 3-1/2" BAKER SEAL BORE EX1ENSION I 9171' H 3-1/2" OllS XN NIP, D = 2.75" I 9202' ~ 3-1/2" TUBING TAIL,ID = 2.992" I 9189' ELMDTT LOGGBJ 12/04190 ! .. 15-04 A ~ I 4IÞ I o ~ ...J L - :8: 9159' r-1[ 9167' t-I r-' 9202' 9270' ~ r- 9588' 14-1/2"LNRSCAB, 12.6#, L-80, 0.0152 bpf,ID= 3.958" H 10438' ~ I I PBTD H 10454' I 7' LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" H 10460' ~ DATE REV BY OOWMENTS DA1E REV BY COMrvENTS 04/26/82 ORIGINAL OOrvPLETION 12/04/90 LAST WORKOVER 11/30/00 SIS-151 OON\!ERTBJ TO CAN\! AS 03/01/01 SIS-MD RNAL 06/26/01 RNlTP OORRECTIONS 01/17103 ?ITP SETTBG PA Ta-t ~AÆTY NOTES, ~ H 5-1/2"X 3-112" XO I 2225' H3-1/2" OllS FMX TRSV SSSV, I LOCKED our 02126/99, ID = 2.875" !4306'-4335'11ECLlPSEIIIPATCH, ID= 1.75" OVER GLM#2, 01/17103 GAS LIFT MANDRELS DEV TYPE VL V LATCH FORT DATE 1 CAIVCO RK 34 CA IVCO RK 34 CA IVCO RK 34 CA IVCO RK 40 CAIVCO RK 43 CAIVCO RK 44 CA IVCO RK 44 CA IVCO RK 43 CAIVCO RK 41 CA IVCO RKP 73' ST fvD TVD 1 2664 2664 2 4312 4182 3 5557 5219 4 6424 5934 5 7105 6477 6 7569 6823 7 8003 7139 8 8408 7431 9 8748 7676 10 9024 7881 PRUDHOE BA Y UNIT WELL: 15-04 PERMIT No: 1820370 AR No: 50-029-20726-00 SEC22, T11N, R14E, 4012.86' FI3.. & 1330.03' FNL BP Exploration (Alaska) TREE = FMC GEN 2 113-3/8" CSG, 7" LNR-TIEBACK H L-80, ID = 12.347" H I 7" LNR- TIEBACK, 26#, L-80, 0.0383 bpf, ID = 6.276" I TOP OF 4-1/2" LNR - SCAB 13-1/2" TBG-PC, 9.3#, L-80, .0087 bpf, ID = 2.992" - 2649' 6 ~ .. ST MO WD OEV TYÆ VLV LATCH PORT DATE H H H H H H 9099' 9102' 9111' 9112' 9117' 9158' 9159' 9159' 9189' 9189' 9189' I TOP OF T' LNR H 9210' I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9588' H ÆRFORA TION SUMMARY REF LOG: BHCS ON 04/19/82 ANGLE AT TOP ÆRF: 28 @ 10283' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-118" 4 10283 - 10318 3-1/8" 4 10324 10334 2-5/8" 6 10340 - 10380 4-1/2" LNR SCAB, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H 10438' I PBTD 1-1 10454' I I 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" H 10460' I DATE 04/26/82 12/04/90 11/30/00 03/01/01 06/26/01 01/17/03 REV BY COMMENTS ORIGINAL COMA-ETION LAST WORKOVER CONVERTED TO CANVAS FINAL CORRECTIONS SETTBG PATCH 818-lsl SIS-MD RNlTP ?ITP DATE REV BY COMMENTS SAfETY NOTES: H H 7-1/2" X 3-1/2" BAKER FB-1 PKR, ID = 4.0" I 3-1/2" SEAL BORE EXTENSION I 3-1/2" BAKER CONCENTRENIC COUA-ING 3-1/2" BAKER SEAL BORE EXTENSION 3-1/2" BAKER MILLOUT EXTENSION H 3-1/2" OTIS XN NIP, ID = 2.75" I 1,-1 3-1/2" TUBING TAIL, ID = 2.992" I .-1 ELMO "IT LOGGED 12/04/90 I I / H PRUDHOE BA Y UNrr WELL: 15-04 ÆRMrr No: 1820370 API No: 50-029-20726-00 SEe 22, T11 N, R14E, 4012.86' FEL & 1330.03' FNL SF> , Ii BP Amoco WElt.PATH DeTAILS Plan#31s.o4A 500292072601 Pannt Welipath: 15·1)4 TIe- Of! MDI 16200.00 Rig, Ref. Dabl~: 4: 04 3124/1982 00100 V.S«:tioff ADfI& 32-a.OO' o.~!: ~~~~ REFERENCE INFORMATION S-I!1:CTfON OIITAIt.5 2f,37' 2'17,98 5;~ m:ig 00.00 aW.:I:2: 00.00 302.5:2 00.03 293.52 90,03 3t9..52 :~:~~ =:~: :;:~ ~~:~~ _139.65 ..138.15 -137.:1:7 -95,09 48.52 147.54 182.74 378.36 509.74 853.88 H!44.73 1:/'13.40 i~!5 ::~~: :5:~Î &48$.94 ::~: 8849.81 ANNOl'ATIONS MD AI\Inotatiol> TIP KOÞ , · · 7 · · 10 11 TO 8250 8300 8350 ....8400 C ~ 8450 !2.8500 .c 1.8550 CII Q 8600 i U 8650 1: C118700 > ~ 8750 ¡.. 8800 ~::~¡~D "'0 33.00« 63.00 I'H....g Tl'ace ,..<get :lË 1!~ß 12,00 90.00 12.00 27;).00 ¡~I ;jg 2541.24 2556.11\ 2561..28 2657.17 292.6.48 ~!~¡:~~ 3609,57 1~;:~i 8850 8900 8950 T LEGEND Plan: Plan #3 (15-04/PJan#3 15-04A) Date: 6/17/2003 Azimuths Magnetic Magnetic Field Strength: 57551nT Dip Angle: 80.84° Date: 611712003 Modei: BGGM2002 1400 1300 1200 1100 1000 900 800 700 '+ 600 - .c 1: 500 o ~ 400 - . - ;; 300 :::II o 200 CP) 100 o -100 -200 -6000 -5900 -5800 -5700 -5600 -5500-5400 -5300 -5200 -51 00 -5000 -4900 -4800-4700-4600 -4500 -4400 -4300 -4200 -4100-4000 -3900 -3800 -3700 -3600 -3500 -3400 West(-)/East(+) [100ft/in] 2500255026002650270027502800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 3650 3700 3750 3800 3850 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 Vertical Section at 320.00" [50ft/in] 6117/2003 3:58PM ObP BP Baker Hughes INTEQ Planning Report e e -.. ..... INTEQ Site: Well: Well path: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Co-ordinate(NE) Reference: Vertical ([VD) Reference: Section (VS) Reference: Calculation Method: Well: 15-04, True North System: Mean Sea Level Well (0.00N,0.00E,320.00Azi) Minimum Curvature Db: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 --~.-..~._-------"._------ -~-"----'--'-'-"-~----------'------"-----~ ------..----------" -"-------'.- ----,-.-------.-,-.- Site: PB OS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: 35.236 N 21.213W True 1.34 deg _____.._..._~.___.,._.__~_,__._____.__ ..___'_.'n_________.__...___.,_._________.___._.......________..__.____.__~_____._.__.___._ - .--'-...--......-.---- __ ___..______.w_______,..____.___ ___.____.".__.____.___._.~._____________._~.___.___.___,____.~___,_. .----.--.----- ----------. Well: 15-04 Slot Name: 15-04 Well Position: +N/-S 1445.51 ft Northing: 5960280.17 ft Latitude: +Ef-W -94.34 ft Easting: 676168.77 ft Longitude: Position Uncertainty: 0.00 ft 04 70 17 49.453 N 148 34 23.963 W _________.,.___________n_._______ - --------_._----~-----_.._.._----.._._- -----.-..----.-.- ____..,_~_____n___.___...___________.__._._.,,_.______._..._..._ ----------....,,-------- ,..------- Wellpath: Plan#3 15-04A 500292072601 Current Datum: 4 : 04 3/24/1982 00:00 Magnetic Data: 6/17/2003 Field Strength: 57551 nT Vertical Section: Depth From (TVD) ft 0.00 Height Drilled From: 15-04 Tie-on Depth: 10200.00 ft 63.00 ft Above System Datum: Mean Sea Level Declination: 25.88 deg Mag Dip Angle: 80.84 deg +Ef-W Direction ft deg ._______...________,___...__._~__..____.__ n'" _________ 0.00 320.00 - _______..__n_._____.... +N/-S ft --------~-- 0.00 -----~-._------- --------,--_._-- .. ------------- -------..---------.--.----,,---.--------------- Targets ft ft ft .-. . 15-04A Polygon2.1 0.00 -28.69 -4329.91 5960150.00 671841.00 70 1749.159 N 148 3630.175 W -Polygon 1 0.00 -28.69 -4329.91 5960150.00 671841.00 70 17 49.159 N 1483630.175W -Polygon 2 0.00 437.67 -4637.08 5960609.00 671523.00 70 17 53.743 N 148 3639.137 W -Polygon 3 0.00 507.21 -4872.53 5960673.00 671286.00 70 17 54.426 N 148 3646.002 W -Polygon 4 0.00 678.34 -5003.57 5960841.00 671151.00 70 17 56.108 N 148 3649.825 W -Polygon 5 0.00 1512.34 -5162.07 5961671.00 670973.00 70 18 4.309 N 148 36 54.462 W -Polygon 6 0.00 1361.99 -5618.75 5961510.00 670520.00 70 18 2.827 N 148 37 7.773 W -Polygon 7 0.00 527.82 -5282.19 5960684.00 670876.00 70 17 54.626 N 148 36 57.944 W -Polygon 8 0.00 -90.47 -4681.48 5960080.00 671491.00 70 17 48.549 N 148 36 40.422 W -Polygon 9 0.00 -140.66 -4375.55 5960037.00 671798.00 70 17 48.057 N 148 36 31.503 W 15-04A Fault #1 0.00 902.40 -5429.46 5961055.00 670720.00 70 17 58.309 N 148 37 2.245 W -Polygon 1 0.00 902.40 -5429.46 5961055.00 670720.00 70 17 58.309 N 148 37 2.245 W -Polygon 2 0.00 712.55 -4798.70 5960880.00 671355.00 70 17 56.446 N 148 36 43.853 W 15-04A T3.3 8850.00 1220.24 -5289.96 5961376.00 670852.00 70 18 1 .436 N 148 3658.185 W 15-04A T2.2 8880.00 518.30 -5004.32 5960681.00 671154.00 70 17 54.534 N 148 36 49.844 W 15-04A T3.1 8886.00 143.58 -4594.96 5960316.00 671572.00 70 17 50.851 N 148 36 37.904 W ---------.......-.....----.. .. --- -----_..._.._---<-_..._.._----...._._----_."'-~-----_._-----_.. Annotation 10200.00 10225.00 10239.00 10442.35 10672.35 10822.35 8764.83 8786.64 8798.80 8886.19 8886.19 8886.19 TIP KOP 3 4 5 6 -.-.- -----.-.-.------"...---.---.--- ~-----~- .. ------- ObP e BP e ... ...... Baker Hughes INTEQ Planning Report IN'TEQ Date: 6/17/2003 Time: 15:58:40 Co-ordlnate(NE) Reference: Well: 15-04, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E,320.00Azi) Survey Calculation Method: Minimum Curvature Db: Annotation 10897.35 8886.17 7 11197.35 8886.01 8 11372.35 8885.94 9 11772.35 8872.30 10 11972.35 8859.92 11 12150.00 8849.81 TD ----------- Plan: Plan #3 Date Composed: 6/17/2003 Identical to Dan Kara's Plan #3 Version: 2 Principal: Yes Tied-to: From: Definitive Path -----------..," -------."..-,....----. ------------ ___ _______n___ - 0·.____-----------. .---------------------- Plan Section Information 10200.00 29.37 277.08 8764.83 -139.65 -4129.23 0.00 0.00 0.00 0.00 10225.00 29.11 277.07 8786.64 -138.15 -4141.35 1.04 -1.04 -0.04 181.07 10239.00 30.35 277.50 8798.80 -137.27 -4148.24 9.00 8.87 3.09 10.00 10422.35 90.00 290.52 8886.19 -95.09 -4293.81 33.00 32.53 7.10 15.00 10672.35 90.00 320.52 8886.19 48.52 -4494.97 12.00 0.00 12.00 90.00 10822.35 90.00 302.52 8886.19 147.54 -4606.81 12.00 0.00 -12.00 270.00 10897.35 90.03 293.52 8886.17 182.74 -4672.95 12.00 0.04 -12.00 270.20 11197.35 90.03 329.52 8886.01 378.36 -4893.88 12.00 0.00 12.00 90.00 11372.35 90.02 308.52 8885.94 509.74 -5008.00 12.00 0.00 -12.00 270.00 11772.35 93.66 356.42 8872.30 853.88 -5187.57 12.00 0.91 11.97 85.10 11972.35 93.34 332.38 8859.92 1044.73 -5240.87 12.00 -0.16 -12.02 270.00 12150.00 93.11 353.73 8849.81 1213.40 -5292.27 12.00 -0.13 12.02 90.00 Survey N/S E/W MapN MapE VS ft ft ft ft ft 10200.00 29.37 277.08 8764.83 -139.65 -4129.23 5960043.77 672044.21 2547.24 0.00 0.00 TIP 10225.00 29.11 277.07 8786.64 -138.15 -4141.35 5960044.99 672032.06 2556.18 1.04 181.07 KOP 10239.00 30.35 277.50 8798.80 -137.27 -4148.24 5960045.71 672025.16 2561.28 9.00 10.00 3 10250.00 33.87 279.19 8808.11 -136.42 -4154.02 5960046.43 672019.36 2565.65 33.00 15.00 MWD 10275.00 41.93 282.08 8827.83 -133.55 -4169.09 5960048.94 672004.22 2577.53 33.00 13.57 MWD 10300.00 50.04 284.18 8845.19 -129.45 -4186.58 5960052.63 671986.65 2591.92 33.00 11.29 MWD 10307.70 52.55 284.72 8850.00 -127.95 -4192.40 5960053.99 671980.79 2596.81 33.00 9.82 15-04A T 10325.00 58.18 285.83 8859.83 -124.20 -4206.12 5960057.42 671966.99 2608.50 33.00 9.48 MWD 10350.00 66.34 287.21 8871.46 -117.90 -4227.31 5960063.22 671945.65 2626.95 33.00 8.85 MWD 10375.00 74.51 288.43 8879.82 -110.70 -4249.72 5960069.90 671923.09 2646.87 33.00 8.21 MWD 10400.00 82.69 289.55 8884.76 -102.72 -4272.87 5960077.33 671899.76 2667.86 33.00 7.80 MWD 10422.35 90.00 290.52 8886.19 -95.09 -4293.81 5960084.47 671878.64 2687.17 33.00 7.58 MWD 10425.00 90.00 290.84 8886.19 -94.15 -4296.29 5960085.35 671876.15 2689.48 12.00 90.00 MWD 10442.35 90.00 292.92 8886.19 -87.69 -4312.39 5960091.43 671859.90 2704.78 12.00 90.00 4 10450.00 90.00 293.84 8886.19 -84.65 -4319.41 5960094.30 671852.81 2711.62 12.00 90.00 MWD 10475.00 90.00 296.84 8886.19 -73.95 -4342.00 5960104.47 671829.98 2734.33 12.00 90.00 MWD 10500.00 90.00 299.84 8886.19 -62.09 -4364.00 5960115.81 671807.70 2757.57 12.00 90.00 MWD 10525.00 90.00 302.84 8886.19 -49.08 -4385.35 5960128.31 671786.06 2781.25 12.00 90.00 MWD 10550.00 90.00 305.84 8886.19 -34.98 -4405.99 5960141.92 671765.09 2805.32 12.00 90.00 MWD 10575.00 90.00 308.84 8886.19 -19.82 -4425.87 5960156.61 671744.87 2829.71 12.00 90.00 MWD 10600.00 90.00 311.84 8886.19 -3.64 -4444.92 5960172.34 671725.44 2854.35 12.00 90.00 MWD 10625.00 90.00 314.84 8886.19 13.52 -4463.10 5960189.07 671706.87 2879.18 12.00 90.00 MWD 10650.00 90.00 317.84 8886.19 31.60 -4480.36 5960206.74 671689.19 2904.13 12.00 90.00 MWD 10672.35 90.00 320.52 8886.19 48.52 -4494.97 5960223.31 671674.19 2926.48 12.00 90.00 5 10675.00 90.00 320.20 8886.19 50.55 -4496.66 5960225.31 671672.45 2929.12 12.00 270.00 MWD 10700.00 90.00 317.20 8886.19 69.33 -4513.15 5960243.69 671655.52 2954.11 12.00 270.00 MWD 10725.00 90.00 314.20 8886.19 87.23 -4530.61 5960261.17 671637.65 2979.04 12.00 270.00 MWD ObP e BP e BIi. u.... Baker Hughes INTEQ Planning Report INTEQ 712003 l:R~"~ eNort/ì (TVD) Reference: ystem: ean Sea Level Section (VS) Reference: Well (0.00N,0.00E.320.00Azi) Survey Calculation Method: Minimum Curvature Db: Survey 10750.00 90.00 311.20 8886.19 104.18 -4548.98 5960277.69 671618.89 3003.83 12.00 270.00 MWD 10775.00 90.00 308.20 8886.19 120.15 -4568.21 5960293.20 671599.29 3028.43 12.00 270.00 MWD 10800.00 90.00 305.20 8886.19 135.09 -4588.25 5960307.67 671578.91 3052.76 12.00 270.00 MWD 10822.35 90.00 302.52 8886.19 147.54 -4606.81 5960319.68 671560.06 3074.23 12.00 270.00 6 10825.00 90.00 302.20 8886.19 148.96 -4609.05 5960321.05 671557.80 3076.75 12.00 270.20 MWD 10850.00 90.01 299.20 8886.18 161.72 -4630.54 5960333.30 671536.01 3100.34 12.00 270.20 MWD 10875.00 90.02 296.20 8886.18 173.35 -4652.67 5960344.40 671513.61 3123.47 12.00 270.20 MWD 10897.35 90.03 293.52 8886.17 182.74 -4672.95 5960353.32 671493.12 3143.71 12.00 270.20 7 10900.00 90.03 293.84 8886.17 183.81 -4675.37 5960354.32 671490.67 3146.08 12.00 90.00 MWD 10925.00 90.03 296.84 8886.15 194.51 -4697.97 5960364.49 671467.84 3168.79 12.00 90.00 MWD 10950.00 90.03 299.84 8886.14 206.37 -4719.97 5960375.84 671445.57 3192.03 12.00 90.00 MWD 10975.00 90.03 302.84 8886.12 219.37 -4741.32 5960388.33 671423.92 3215.71 12.00 90.00 MWD 11000.00 90.03 305.84 8886.11 233.47 -4761.96 5960401.95 671402.96 3239.78 12.00 90.01 MWD 11025.00 90.03 308.84 8886.10 248.64 -4781.83 5960416.64 671382.73 3264.17 12.00 90.01 MWD 11050.00 90.03 311.84 8886.09 264.82 -4800.89 5960432.37 671363.31 3288.81 12.00 90.01 MWD 11075.00 90.03 314.84 8886.07 281.97 -4819.07 5960449.09 671344.73 3313.64 12.00 90.01 MWD 11100.00 90.03 317.84 8886.06 300.06 -4836.32 5960466.76 671327.05 3338.59 12.00 90.01 MWD 11125.00 90.03 320.84 8886.05 319.02 -4852.61 5960485.34 671310.33 3363.58 12.00 90.01 MWD 11150.00 90.03 323.84 8886.04 338.81 -4867.88 5960504.76 671294.60 3388.56 12.00 90.01 MWD 11175.00 90.03 326.84 8886.02 359.37 -4882.10 5960524.98 671279.90 3413.45 12.00 90.02 MWD 11197.35 90.03 329.52 8886.01 378.36 -4893.88 5960543.69 671267.68 3435.57 12.00 90.02 8 11200.00 90.03 329.20 8886.01 380.64 -4895.23 5960545.94 671266.28 3438.18 12.00 270.00 MWD 11225.00 90.03 326.20 8886.00 401.77 -4908.59 5960566.75 671252.43 3462.95 12.00 270.00 MWD 11250.00 90.03 323.20 8885.99 422.17 -4923.03 5960586.80 671237.51 3487.87 12.00 270.00 MWD 11275.00 90.02 320.20 8885.98 441.79 -4938.52 5960606.05 671221.57 3512.85 12.00 270.00 MWD 11300.00 90.02 317.20 8885.97 460.57 -4955.02 5960624.44 671204.64 3537.84 12.00 270.00 MWD 11325.00 90.02 314.20 8885.96 478.46 -4972.48 5960641.92 671186.77 3562.77 12.00 269.99 MWD 11350.00 90.02 311.20 8885.95 495.42 -4990.84 5960658.43 671168.01 3587.56 12.00 269.99 MWD 11372.35 90.02 308.52 8885.94 509.74 -5008.00 5960672.35 671150.52 3609.57 12.00 269.99 9 11375.00 90.05 308.84 8885.94 511.40 -5010.07 5960673.96 671148.42 3612.16 12.00 85.10 MWD 11400.00 90.31 311.83 8885.86 527.58 -5029.12 5960689.69 671128.99 3636.80 12.00 85.10 MWD 11425.00 90.56 314.82 8885.67 544.73 -5047.31 5960706.40 671110.41 3661.63 12.00 85.11 MWD 11450.00 90.82 317.81 8885.37 562.80 -5064.57 5960724.07 671092.72 3686.57 12.00 85.13 MWD 11475.00 91.07 320.80 8884.96 581.75 -5080.87 5960742.63 671075.99 3711.57 12.00 85.17 MWD 11500.00 91.32 323.79 8884.44 601.52 -5096.16 5960762.03 671060.24 3736.54 12.00 85.22 MWD 11525.00 91.56 326.78 8883.81 622.06 -5110.39 5960782.23 671045.53 3761.42 12.00 85.28 MWD 11550.00 91.80 329.77 8883.08 643.31 -5123.53 5960803.17 671031.90 3786.15 12.00 85.35 MWD 11575.00 92.04 332.76 8882.24 665.22 -5135.54 5960824.79 671019.38 3810.65 12.00 85.44 MWD 11600.00 92.27 335.75 8881.30 687.72 -5146.39 5960847.03 671008.01 3834.86 12.00 85.54 MWD 11625.00 92.49 338.75 8880.26 710.75 -5156.05 5960869.83 670997.81 3858.71 12.00 85.66 MWD 11650.00 92.71 341.74 8879.13 734.26 -5164.49 5960893.12 670988.83 3882.14 12.00 85.78 MWD 11675.00 92.92 344.74 8877.90 758.16 -5171.68 5960916.85 670981.07 3905.08 12.00 85.92 MWD 11700.00 93.12 347.74 8876.58 782.41 -5177.62 5960940.95 670974.57 3927.47 12.00 86.06 MWD 11725.00 93.31 350.74 8875.18 806.93 -5182.28 5960965.35 670969.33 3949.25 12.00 86.22 MWD 11750.00 93.50 353.74 8873.69 831.65 -5185.65 5960989.99 670965.38 3970.36 12.00 86.39 MWD 11772.35 93.66 356.42 8872.30 853.88 -5187.57 5961012.16 670962.95 3988.61 12.00 86.57 10 11775.00 93.66 356.10 8872.13 856.51 -5187.74 5961014.79 670962.71 3990.74 12.00 270.00 MWD 11800.00 93.65 353.10 8870.54 881.35 -5190.09 5961039.56 670959.78 4011.28 12.00 269.98 MWD 11825.00 93.63 350.09 8868.95 906.03 -5193.74 5961064.15 670955.56 4032.53 12.00 269.79 MWD 11850.00 93.61 347.08 8867.37 930.48 -5198.67 5961088.48 670950.05 4054.43 12.00 269.60 MWD 11875.00 93.57 344.08 8865.80 954.64 -5204.89 5961112.49 670943.27 4076.93 12.00 269.41 MWD 11900.00 93.53 341.07 8864.26 978.45 -5212.36 5961136.11 670935.25 4099.97 12.00 269.22 MWD 11925.00 93.47 338.07 8862.73 1001.83 -5221.07 5961159.28 670925.99 4123.48 12.00 269.03 MWD ObP BP Baker Hughes INTEQ Planning Report e e Bii. IIAICD. IIUGIIIS INirEQ Company: Field: Site: Well: Wellpath: Survey BP Amoco Prudhoe Bay PB DS 15 15-04 Plan#3 15-04A Date: 61 Co-ørdina Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: ..__ __no System: Mean Sea Level Well (0.00N,0.00E,320.00Azi) Minimum Curvature Db: ..---~~ --~-~_. SSTVD ft 11950.00 93.40 335.06 8861.23 1024.72 -5230.99 5961181.93 670915.54 4147.40 12.00 268.85 MWD 11972.35 93.34 332.38 8859.92 1044.73 -5240.87 5961201.70 670905.19 4169.08 12.00 268.67 11 11975.00 93.34 332.69 8859.76 1047.07 -5242.09 5961204.01 670903.92 4171.65 12.00 90.00 MWD 12000.00 93.33 335.70 8858.31 1069.54 -5252.95 5961226.22 670892.53 4195.85 12.00 90.02 MWD 12025.00 93.32 338.70 8856.86 1092.54 -5262.62 5961248.99 670882.33 4219.68 12.00 90.19 MWD 12050.00 93.29 341.71 8855.41 1116.02 -5271.07 5961272.26 670873.33 4243.10 12.00 90.37 MWD 12075.00 93.26 344.71 8853.98 1139.92 -5278.28 5961295.98 670865.56 4266.04 12.00 90.54 MWD 12100.00 93.22 347.72 8852.57 1164.16 -5284.23 5961320.07 670859.05 4288.43 12.00 90.71 MWD 12125.00 93.17 350.72 8851.18 1188.67 -5288.90 5961344.47 670853.81 4310.21 12.00 90.88 MWD 12150.00 93.11 353.73 8849.81 1213.40 -5292.27 5961369.11 670849.85 4331.33 12.00 91.05 TD BOP-Tree Wen KB Elevation · · YT I I I ... .... Tree Size I, I . · I, Valve . I, · Base . · e e P055082 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS 6/9/2003 INV# CK0604038 PERMIT TO DRILL \$..04(1 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ .NATIONAL CITY BANK Ashland. Ohio BAY UNIT PO BOX 196612 ... ANCHORAGI;, AK99519-6612 8 '.p'.r;1). ~ 1'~··:·.JiI~"""II¡j. .1··...1· 01'''1' 1'1"· '. ....~ ". ,. l '. ,"," '1,,1' t.~~.." I·' : . ." .....~ ....: _UP .(011.. 'In'lI ....N. 'ffllO DATE June 9, 2003 . . - .. '. . . . . .. . : '". . ".".. . .. . . . .. . ." . . . . ." '. . . ALASKA OIL & GAS CONSERVATION COMMISSION ... .. " . .... . . . . ...." .. . 333 W 7TH AVENUE SUITE 106 . ANCHORAGE, AK 99501-3539 . . 1110 5 SOB 2111 I: 0 It ~ 20 :1 B ~ 5 I: 0 ~ 2 ? B ~ b III DATE I I 6/9/2003 CHECK NO. 055082 ¡ : VENDOR DISCOUNT NET H RECEIVED JUN 2 0 Z003 Alaska Oil & Gas ~ons. Commission AnchJrage No. P 055082 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 4i2 AMOUNT I *******$100.00*******1 NOT VALl02))~~~::~~.:;,:;,::\~:,;.;:;:c::~) I\;:~~:~;;;{;:;:~!:;?L1 e e TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMtTT AL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "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. HOLE 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 (SO 70/80) from records, data and logs acquired for well (name on permit). Pll..OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates 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. ~VVEllÞERJI!!!rtþHEq;~STi Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT 15-04A Program DEV Well bore seg D PTD#:2031140 Field & Pool PRUDHOEBAY,PRUDHOEOIL-640150 InitialClasslType DEV/1-0IL GeoArea 890 Unit 11650 On/OffShore ~ Annular Disposal D Administration 1 P~rmitfee attached. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . _ . . . . _ _ _ _ _ _ _ _ _ . . . _ . _ _ _ _ . . . . . . . _ _ _ _ _ _ _ . . . . . . . _ _ _ . . . . 2Leas~.numberapprORri<'lte. . . . _ _ . _ _ _ _ _ . . . . . . _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ . . . _ . .Y~s _ _ _ _ . . . . . . _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ . . . . . _ _ _ . . . . . _ _ _ _ _ _ _ _ . . . .. _ _ _ _ _ _ _ . . . . 3 .U.nlque wel'-n.am~.aod Ol!.mb.er . . . . . . . . . . _ _ . . . . . . . . _ _ _ _ . . . . . . . . _ _ . . . . .Y~s . . . _ _ . . . . . . . . . . . . _ . _ . . . . . . . _ _ _ . . . . . . . . . . . _ . _ . . . . . . . . . . _ . . . . . . . . . . . . _ . . . . . . _ 4 WellJoc<'lt~d In.a.d.efjoedpool_ . . . . _ _ _ . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . . . .Y~s _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ . . _ _ _ . _ . . . . . _ _ _ _ _ _ _ . . . _ . _ _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ . . . _ 5 WellJoc<'lt~d pr.operdlstance_ from driJIing uoitb_ouod_ary. . _ _ . _ _ _ . _ . . . . . _ _ _ _ _ _ _ _ . .Y~s _ _ _ _ _ _ . _ _ . . . . _ _ _ _ _ _ _ . _ . . . _ _ _ _ _ . _ . . . . . . . _ _ _ _ _ . . . . . . . _ _ _ . . . . . _ . . . . _ 6 WellJoc<'lt~d prpper .dlstance. from other wel]s. . . . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ . _ . . _ _ _ .Y~s _ . . . . _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ . _ _ . . _ . _ _ _ _ . _ _ . _ . . . _ _ _ _ _ . . . . . . _ _ _ _ _ _ . . . . . _ 7 .S.u{ficieotacreage.aYailable in_dJilliog unjt_ . _ _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ . .Y~s . . _ _ _ . . . . . . _ _ _ _ _ . _ . .. _. _ _ _ _ _ . . . . . . _ _ _ _ . . . . . . _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ . . . _ 8 Jf.d~viated, js weJlbore platiocJuded _ . . . . . _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ . . . _ _ .Y~s . . . . _ . _ _ _ _ _ . _ _ . . . . . _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . .. _ _ _ _ _ _ _ . . 9 .Operator pol}' affected party _ _ _ _ _ . . . . . . . _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ . . . . . _ _ _ _ .Y~s . . _ . _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ . . . _ _ _ . _ _ _ _ _ . . . . . . . _ . . . . . . _ . _ _ _ _ _ _ _ . . . . . _ _ _ _ . _ . _ 10 .Operatw has_appropriate. bond inJQrce . . . . . . . _ . _ . . . . . . . . _ . _ . _ . . . . . . . . _ . .Y~s . . . . . . . . _ . . . . . . . . . . . . _ _ . . . . . . . . . . _ _ . . . . . . . . . . . _ . . . . . . . . . . . . _ _ . . . . . . . . . _ . . . . 11 P~rmit c.ao be iSSl!.ed wjthout conserva_tioo order _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . . . . . _ _ _ _ _Y~s . . . . _ . _ _ _ _ _ . . . . . . . _ _ _....... _ _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ . . . . . . . _ . . . . . . _ _ _ . _ . . Appr Date 12 P~rmitcao be iSSl!.ed wjthout ac:tmioistratille.apprpvaL . . . . . _ _ _ _ _ _ . . . . . . . _ _ _ _ . . .Y~s . . _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ . . . . _ _ _ _ _ _ . _ . . . . .. . _ _ . . . . . . . _ _ _ _ _ _ _ _ . _ . . . . . . _ _ _ . . . . _ RPC 6/23/2003 13 Can permit be approved before 15-day wait Yes 14 WeIlJoc<'ltedwithioareaalld.strat<'lauthorizedbY.lojectiooOrd~r#(PutlO#incpmm~ots)_(For.NA...... _ _ _ _ _ _. _..... _ . _ _.. _ _.. _ _ _ _ _ _ _ _...... _ _ _ _........ _ _ _...... _ _. _.. 15 .AJlwelJs_within.1l4.roile_area.ofreyiewjd~otlfied(Forservj~.w.ellooly)............... .NA. - -............. - - -....... - -......... -............. -............ - -...... - -. e 16 PJe-produ~ecliojector; duratio.n.ofpre-productiool~ssthan_3mooths.(For_servlceweIlonJy) _. _NA _ _...... _ _. _ _ _ _ _.... _ _ _ _ _ _..... _ _ _ _ _ _ _ _...... _ _ _ _ _ _... _... _ _ _ _ _ _.... _ 17 ACMP.Fïoding.ofCon.si.$teocy_has bee.nJssued_for.this pr.oject _ _ _ _ _ . . . . . . . _ _ _ _ _ _ . .NA . _ _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ . . . . . . . _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ . . . . . _ _ _ _ . . . _ _ 18 .C.oodu.ctor strin-9_PJovided . _ _ _ _ _ _ _ . . . . _ _ _ _ . _ . . . . _ . _ _ _ _ _ _ . . . . . _ . _ _ _ _ .NA . . . _ _ _ _ _ . . . . .. _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ . . . . . _ _ _ _ . . . _ 19 _S.urfa~casiog_ PJotec.ts alLknowll USDWs . . _ _ _ _ _ . . . _ . _ _ _ _ _ _ _ . _ . . . . _ _ _ _ _ .NA . . . _ _ . . . . . . . . _ _ _ . _ . . . . _ _ _ _ _ _ _ . . . . . . . . . _ _ _ _ _ . . . . _ _ _ . . . . . _ _ _ _ _ _ . . . _ 20 .CMTv_oladequ.ate.to cifc_ulate_o_n_cood.uctor_& SUJf.q¡g . . . _ _ _ . _ . _ _ _ _ _ _ _ _ _ . .NA _ _ . . . . . . _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ . _ . . . . . . _ _ _ _ _ _ . _ . . . . _ _ _ _ _ _ . . . . _ _ _ _ _ . . . _ 21 _CMT v.ol adeql!.ate.to tie-lnJongstriog to.surf csg_ _ _ _ _ . . . . _ _ _ _ _ _ _ _ . . . . . _ . _ _ _ NA . . . _ _ _ _ _ _ . . . . . . . . _ _ _ _ . _ . . . . _ _ _ _ . . . _ . . . _ . _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ . . . _ 22 .CMT wil] coyer.all koown-Pfo_ductiye horilon_s_ _ _ . . . . _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ . . . . .Y~s _ _ _ _ . . . _ _ _ _ _ _ . . . . . . _ _ _ _ _ . . . . . _ _ _ _ _ _ . . . . . . . _ _ _ _ _ . . . . . . _ _ . _ _ _ . . _ . _ 23 .Casiog de.sigos acleQua.te fpr C,_T~ B.&.permafrpst . . _ _ _ _ _ . _ . . . .Y~s _ _ _ _ . _ _ . . _ _ _ _ _ _ _ . . . . . . _ _ _ . . _ _ _ _ _ _ _ _ _ _ . . . _ _ . _ . . . _ . _ _ _ _ _ _ _ _ . . . 24 .AdequateJan_kage_oJ fe.Serve pit _ _ _ . . . . . _ _ _ _ _ . . . . . . _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ .Y~s. . . _ _ _ _ CTDU.. . . _ . _ _ _ _ _ . . . . _ _ _ _ _ _ _ . _ . . . . . _ _ _ . . . . . . _ _ _ _ _ . . . . _ _ _ . . . . _ 25 Jf.aJe-drilL has.a_ to-403 fQr abandollment be~o apPJoved _ _ . . . . . . _ _ _ _ _ _ _ _ . . . _ _ .Y~s _ . . . . . . _ _ _ _ _ _ _ . . . . . _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ . . . . . . . _ _ _ _ . . . . . . _ _ _ _ . . _ 26 .Adequatewellboresepªr<'ltionPfoposed.... _ . . . . . . . . . _ . . . . . . . . . . . _ . _ . . . . .Y~s. _ . _ _ . . . . . . . . . . _ . . . . . . . . . _ . . . . . . . . . . . . _ . _ _ . . . . . . . . . _ . . . . . . . . . . . . . . _ _ . . . . . . . 27 Jf.djverter JeQ.uiJed, does jt meet reguJatioos_ _ _ _ _ . . . . _ _ _ _ _ _ _ . . . . . _ _ _ . . .NA . _ _ _ _ _ . Sidetrack. _ _ _ _ _ . . . . . _ . _ _ _ . . . . . . . _ _ . _ _ . _ . . . . . _ _ . . . _ _ _ _ _ _ _ _ _ . . . . _ 28 .DJilliog f]ujdprogram sc.hematic&eQ.uipJistadequ<'lte. . . . . _ _ _ _ _ _ _ . . . . . _ _ _ _ . _ . .Y~s _ _ _ _ _ _ . Max MW_8J. ppg._ _ . . . . _ _ _ _ _ _ . . . . . . _ . . _ _ _ _ _ . . . . . . . . _ . _ . . . . _ _ _ _ _ _ . . . _ 29 _BOPEs,.d.o.they meetreguJatioo . . _ _ _ _ . . . . . _ _ _ _ _ . _ . . . . _ _ _ _ _ _ . . . . . . _ _ _ .Y~s . . . . . . . _ _ _ . . . . . . _ _ _ _ . . . . _ . _ _ _ _ _ _ . . . . . . . _ _ _ _ _ _ _ . . . _ . . . _ _ _ _ _ . . . . _ _ _ _ _ . _ . _ 30 ..B.OPE.presHatiogappropriate;testto.(pu.tpSigincommeots) _ _ _ _. _..... _ _ _ _ _ _ _. .Y~s. _ _ _ _ _Testtp.3500.psJ..IIlIS~23.60psi. _ _ _ _...... _ _ _ _ _...... _ _ _ _ _ _ _ _... _ _ _ _ _ _...._ 31 .C.hoke_manifold compJies w/APIR~-53 (May 84)_ _ . . . . _ . _ _ _ _ . . . . _ . _ _ _ _ _ _ _ . . . .Y~s _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ . . . . . _ _ _ _ _ . . . . . . . _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ . _ 32 Work will occ_ur withoutoperation _shutdown. _ _ _ _ . . . . . . _ _ _ _ _ . . . . . . _ _ _ _ _ . . _ . .Y~s _ _ _ _ _ _ . . . _ . . . _ _ _ _ _ . . . . . _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . . . . . . _ _ _ . . . . _ 33 .Is presence_ Qf H2S gas. prob_able _ _ . . . . . _ _ _ _ . . . . _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ . . . No. . _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ . . . . . . . _ _ _ _ . _ . . . _ _ _ _ _ . . . . _ _ _ _ _ . . . . 34 Mecha.nlc<'lLcoodJtloo pf wells wlthio ,ð.OB. yerifiecl (fors_ervice w~1J onJy) _ _ _ _ . . . . _ _ _ _ _NA . . . . . _ _ _ _ _ _ . _ . . . _ . _ _ _ . . . . . . . _ _ _ _ _ _ . . . _ . . . _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ . . _ Engineering Appr Date WGA 6/24/2003 Geology Appr RPC Date 6/23/2003 Geologic Commissioner: DTS e 35 P~r:mitc.aobelsSl!.edw/o.hYdrogen.sulfidemeas.ures_ _ _ _ _ _. _. _ _ _ _ _ _ _ _ _..... _. No_ ...... _ _ _ _ _ _..... _ _ _ _ _ _. _... _ _.... _. _ _ _ _ _.. _.. _ _ _..... _ _ _ _ _.. 36 _D.ata.PJeseotecl Oil pote.ntial ove_rpres_sur~ .zooe.$ _ _ _ . _ . . . . _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ . . .NA . . _ _ _ _ _ _ . . . . _ _ _ _ _ . . . . . _ _ _ . . . . . . _ . _ _ _ _ _ _ . . . . . . _ _ _ _ _ . . . . _ 37 .S~i.$micanalysjs_ of shaJlow 9as_zPoes. _ _ _ _ _ . . . . . _ _ . . . . _ . _ _ _ _ . . . _ . .NA _ _ . . . . . . _ . _ _ _ _ _ . . . . . _ _ _ _ . . . . _ . _ _ _ _ _ _ _ _ _ _ . _ .. _ . . . . . . _ . _ _ _ _ . . . . . . _ _ _ _ _ . _ 38 .S~abedcoodjtioo Sl!.rvey.(if off-shpre) . _ . . . _ _ _ _ . . . . _ _ _ _ . . . . . . _ _ _ _ _ . . _ . NA _ _ _ _ _ . _ _ . . _ . _ _ . _ . . _ _ _ _ _ _ _ . . . . . _ . _ _ _ _ _ _ _ _ _ . . . _ . _ _ _ . . . . . _ _ _ _ _ . . . . . 39 _ Conta_ct l1amelpholleJor_weekly progress_reports [exploratory .ooly] _ _ _ _ _ . . . . . _ _ _ _ _ _ _NA . . . . . _ . _ _ _ _ . . . . . _ _ _ _ _ _ . . . . . _ _ _ _ _ . _ _ . . . _ _ . . . . . . _ _ _ . . . . . _ _ _ _ _ . . . . _ Date: O~ (?/fjr1(] Engineering CjiSSioner: Date ~ ~ Public /.. comm;";'ð¡~þý'1 tJ 3 e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. e e~tJ3-/IC¡ **** REEL HEADER **** MWD 05/01111 í;l1'-7 { / BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/01/12 606651 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!! !!!!!!!!!!!!!! !! !!!!!!!!!!!!!!!!! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10180.5000: STOP.FT 12295.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 22 TOWN.N IlN RANG. 14E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 63 DMF KB EKB .F 63 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE surface system. Remark File Version 1.000 Extract File: ldwg.las 1.20 : NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 15-04A Prudhoe Bay Unit 70deg 17'49.453" N, 148deg 34'23.963 W North Slope Alaska Baker Hughes INTEQ 2.375" CoilTrak - Gamma Ray 12-Jan-04 500292072601 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 e e (5) Tools run in the string included Casing Coil Locator, Electrical Disconnect and Circulating sub, a Drilling Performance Sub, (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and a Hydraulic Orienting Sub with near bit inclination sensor. (6) Data presented here is final and was depth adjusted to a PDC 14, 2004. 1/2" casing and 7" liner. (Primary Depth Control) log run by SWS on January (7) The sidetrack was drilled from milled window in 4 Top of Window. 10194 ft. MD (8759.6 ft. TVD) Bottom of window. 10204 ft. MD (8769.0 ft. TVD) (8) The interval from 12272 ft. to 12295 ft. MD (8844 was not logged due to sensor to bit offset. (9) Tied in to 15-04 at 10129 ft. MD MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 10187.5, 10188.9, 10216.9, 10218.3, 10218.7, 10220.3, 10226.1, 10226.9, 10229.9, 10231.9, 10244.4,10246, 10248.6,10250.2, 10256.4, 10258, 10261.4, 10262.8, 10277.9, 10279.5, 10288.5,10290.5, 10296.8, 10298.4, 10310.6, 10312.6, 10321.7, 10323.3, 10328.9, 10329.7, 10334.5, 10336.3, 10339.5,10341.4, 10352.2, 10353.8, 10368.9, 10369.7, 10380.1,10381.3, 10395.2, 10396.6, 10430.6,10431.2, 10447.9,10448.5, 10467.3,10468.1, 10470.5, 10471.4, 10512.4, 10512.4, 10518, 10518.6, 10523,10523.4, 10556.4, 10558.8, 10571.4, 10572.8, 10594.1, 10594.7, 10599.3, 10602.1, 10610, 10614.4, 10639.1,10641.7, 10655, 10656.6, 10704,10707.4, 10711.2, 10713.8, 10731.5, 10733.3, 10745.1,10749.1, 10765.2, 10766.2, 10780.3, 10784.5, 10793, 10796.6, 10817.4, 10821.2, 10829.2, 10832.4, 10834.1,10837.3, 10846.2, 10847.4, 10850.8, 10851.4, 10869.7, 10873.5, 10898, 10902, 10909.6,10914, 10924.4, 10929.2, 10956, 10960.8, DISPLACEMENT 1.40625 1.40527 1.60645 0.802734 2.00879 1. 60645 1.60645 1.60645 1.40527 1. 60645 2.00781 1. 60645 2.00781 1.60645 0.803711 1.80664 1. 80762 1. 60645 0.803711 1. 20508 1. 40527 0.602539 0.602539 0.803711 0.803711 o 0.602539 0.401367 2.41016 1. 40527 0.602539 2.81152 4.41797 2.61035 1. 60645 3.41309 2.61035 1. 80762 4.0166 1.00488 4.2168 3.61426 3.81543 3.21289 3.21289 1.2041 0.602539 3.81445 4.01562 4.41699 4.81934 4.81934 ft. to 8842 ft. SSTVD) e e 10964.4,10968.6, 10972.2,10976.3, 11001.6, 11003.2, 11025,11025.8, 11136.2, 11136.2, 11137.6, 11138.6, 11148.2, 11148, 11157.5, 11158.7, 11167.4, 11168.2, 11198.2, 11200, 11233, 11235, 11249.9, 11250.8, 11294.2, 11295.6, 11300,11301.2, 11307, 11308.8, 11309.8, 11311, 11411.5, 11413.9, 11493.4, 11495.6, 11525.7, 11527.9, 11528.9, 11531.6, 11855.2, 11856.6, 11858.6, 11859.4, 11861.8, 11862.8, 11878.7, 11879.9, 11894.2, 11896.4, 11921.9, 11924.9, 11925.7, 11929.3, 11930.8, 11934.8, 11934.6, 11938, 11939, 11942.2, 11947.2, 11950.8, 11955.2, 11958.5, 11972.5, 11974.9, 11984.4, 11987.4, 11990.6, 11995.6, 11996.8, 12001.4, 12004.2,12008.3, 12011.3, 12017.3, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfi1e: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU 4.21777 4.01562 1. 60645 0.803711 o 1. 00391 -0.200195 1. 20508 0.802734 1. 80762 2.00781 0.802734 1. 40527 1. 2041 1.80664 1. 20508 2.41016 2.20898 2.20801 2.61035 1. 40527 0.802734 1.00488 1.2041 2.20801 3.01172 3.61426 4.0166 3.41406 3.21289 3.61426 3.21289 2.40918 3.0127 5.01953 4.61816 4.01562 6.02344 158 records... 10 bytes 132 bytes ------------------------------------ WDFN LCC CN WN FN COUN STAT 15-04A 5.xtf 150 BP Exploration (Alaska) Inc. 15-04A Prudhoe Bay Unit North Slope Alaska e e *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 14-Jan-04 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX02 ROPA02 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 51 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10180.000000 12295.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 60 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU e e -------------------------------- WDFN LCC CN WN FN COUN STAT 15-04A.xtf 150 BP Exploration (Alaska) 15-04A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPA GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPA MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 101 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10180.250000 12295.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 110 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/01/12 606651 01 **** REEL TRAILER **** MWD 05/01/11 BHI 01 Tape Subfi1e: 4 Minimum record length: Maximum record length: Tape Subfi1e 1 is type: LIS e e 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS DEPTH 10180.0000 10180.5000 10200.0000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12295.0000 GR -999.2500 -999.2500 21.8100 41.4563 54.0053 159.7575 121. 2698 42.0445 42.8748 65.8121 87.8367 104.4600 56.6926 56.3715 62.4919 56.9477 42.2513 31.1823 29.9731 53.0479 82.3391 103.8700 88.9400 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units e e ROP -999.2500 -999.2500 -999.2500 26.2514 64.9330 18.5362 49.8587 82.3702 65.6780 93.8458 71. 0663 79.8732 128.9698 110.5694 116.9779 124.8548 143.1532 90.9179 93.9628 95.8314 62.2006 54.0600 41.8100 52.5100 10180.000000 12295.000000 0.500000 feet e e Tape Sub file 3 is type: LIS DEPTH GRAX ROPA 10180.2500 15.9400 -999.2500 10180.5000 15.2800 -999.2500 10200.0000 20.2000 -999.2500 10300.0000 34.3100 26.4100 10400.0000 53.4400 13.8300 10500.0000 158.1700 26.0200 10600.0000 122.4200 50.1000 10700.0000 40.5100 83.0500 10800.0000 52.2100 82.0200 10900.0000 62.4500 95.3300 11000.0000 90.7100 69.0500 11100.0000 104.4469 79.9800 11200.0000 45.8700 133.0500 11300.0000 57.7500 108.5700 11400.0000 60.5900 108.4800 11500.0000 59.9400 123.2400 11600.0000 41.2400 131.5600 11700.0000 32.5750 51.0100 11800.0000 32.5550 97.6200 11900.0000 55.3000 96.6200 12000.0000 99.4350 85.4000 12100.0000 186.3200 35.6700 12200.0000 74.8100 141. 3300 12295.0000 -999.2500 92.7700 Tape File Start Depth 10180.250000 Tape File End Depth 12295.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet