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202-035
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. d 0:1- 035 Well History File Identifier In ,e Project Well History File COI Page - r Organizing \,1,1\1.1 RESCAN 0 TwO-Sided ~ D\G)ìALDATA W DiskeUes. No. 0 Other. NolType r. , Rescan Needed QVERS\ZED (scannab\e) 0 Maps: 0 Other items scannable by large scanner Color items: 0 / Grayscale items: OVERSIZED (Non-scannable) 0 poor Quality Originals: Other: 0 Logs of varioUs kinds BEVERLY ROBIN VINCENT SHER ~INO"/ 0 Other " t DATE 1'~ tJl/e< Vv\ r 0 NOTES: B'(: I , BY: -1- )( 30 '" ,~O V\1r .. + 1--: '" TOTAL PAGES ;;;!J- DA'E411~OLf' VVI,P . I DATE,.1f I':; OtftSI ¡ Project Proofing BEVERL'( ROBIN VINCENT SHER'I(i.í;;;;;:)¡INOI Scanning preparation BEVERLY ROBIN VINCENT SHER"/~~ I/I/INO'( B'(' production Scanning Stage 1 PAGE coUNTfROM SCANNED FILE: ''Ât1 - / PAGE COUNT MATCHES NUMBER IN SCAN~ARA-¡ION: ¥ YEf. ..-~ Nr BEVERL'/ Roel" VINCEN' S"ER,~WINO/ DATE~ 1wldt"" A. \ r Stage 2 If NO IN STAGE 1, PAGElS) DISCREPANCIES WERE FOUND: - VE¡' .. -- .,0 B'l: ISf 6"< BEVERL'{ ROBIN VINCEtH SHER'lL MARIA WINDt OA TE 11 ,- If. " 15G"""" " G"""C" " ,~, °"'''' U'.'" spCC''''- A"""''''' " ",OU,"co "'. ~, ,,_ou"" "G' ..'" DUE TO aLl/lllT~ . GP./I'ISCA\.E OR COLOR 1'-'/lCES) I I I I ,I ReScan ned 1"..1"" ,."f , "" I'."'" . 'I .'W "".,.; '.' ,"'''''''' ""..,,,1,,,,,;1) III ,\ \. ISf RESCANNEO BY: BE"'RL" ROBIN VINCENT SHER'IL MARIA WINDt DATE: Quality Checked \""",,'\ , \1 General Notes or Comments about this file: 12I\OI02ReI/3t10Tsr.anned v.pd STATE OF ALASKA ALASKA OIL *D GAS CONSERVATION COMMIS WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 9/16/2010 202 - 035 310 - 251 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 03/09/2002 50 029 - 20818 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 03/11/2002 PBU 18 -10B 4907' FSL, 371' FEL, SEC 24, T11 N, R14E, UM 8, KB (ft above MSL): 45.03 15. Field / Pool(s): Top of Productive Horizon: 4299' FSL, 1286' FEL, SEC 14, T11 N, R14E, UM GL (ft above MSL): 15.23 Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 4458' FSL, 4548' FEL, SEC 13, T11 N, R14E, UM 12253' 8612' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x 691373 y 5961488 Zone ASP4 14107' 8690' ADL 028307 TPI: x- 685062 y- 5966001 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 685368 Y 5967528 Zone- ASP4 N/A 18. Directional Survey: ❑ Yes ONO 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): Submit electronic and printed information per 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill /Lateral Top Window MD/TVD: MWD, GR, ROP 1 12218' 8596' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. b DE TOP - BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91. 0 u 7' Surf ce 79' 1 75# Pole 9- /" 7# 0 rf ce 10800' Surfa 2' 12 -1/4" 500 1 Bbl P' 29# L -8 ' 12218'1 8' 8 -1/2" 350 s 'G' 3 -1/2" x 3- 3/16" 8.81# x 6.2# L-80 11 97'1 1410 ' 1 8690' 1 3-3/4" ' x 2 -7 /8" x 6.16# 24. Open to production or injection? ❑ Yes ® No 25 TUBING RECORD If Yes, list each interval open SIZE DEPTH SET MD PACKER SET MD / TVD (MD +TVD of Top & Bottom; Perforation Size and Number): None 4 -1/2 ", 12.6 #, L -80 12064' 12050' / 8516' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED - W ou 12245' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithW" gilm- or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laborat 250.071. None DEC I � zp1Q .' 14gk8 it & Gat L003. COitXtM>RE�O� RRDMS 4 201 '` ch0t& 9 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 2 •/3 -/D Submit Original Only / 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? [I Y No Permafrost Top If yes, list intervals and fo ns tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 1 B 12420' 8643' None Formation at Total Depth (Name): 31. List of Attachments: Summary of Well work, Summary of Daily Drilling Reports and a Well Schematic Diagram. 32. 1 hereby certify that the foregoi is true and correct to the best of my knowledge. Signed: Sond ' Stewman�.; -- Title: Drilling Technologist Date: _ E PBU 18 -10B 202 -035 310 -251 Prepared By Name/Number. Sondra Stewman, 564 -4750 Well Number Permit No. / Approval No. Drilling Engineer: Cody Hinchman, 564 -4468 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain), Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only TREE = 6" McEV OY WELLHEAD= CNV SAFETY ES: WELL ANGLE >70 °@12300'. ACTUATOR = AXELSON J M D D RA O 1 8. 1 OC * * *ORIG,18 -10A & 18 -10B NOT SHOWN * ** KB. ELEV = 45.0' BF. ELEV = NA 2T 5 -1/2" X 4 -1/2" HGRXO, ID = 3.958" KOP = 1950' Max Angle = 95" @ 13396' 2207' 4 -1/2" CAMCO TRCF -4A TRSSSV Datum MD = 12438' ® W/ CURVED FLAPPER, ID = 3.812" Datum TV D = 8600' SS LOCKED OUT & HYDRAULICS OPENED NOTE: NOT FULLY STROKED OPEN 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 2534' GAS LIFT MANDRELS Minimum ID =1.78" 11954 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3612 13309 52 MMG DOME RK 16 10/07/10 BKR DEPLOYMENT SLV L 2 7089 5497 51 MMG SO RK 20 10/07/10 3 9647 7015 52 MMG DMY RK 0 07/01 /95 TOP OF 7" BKR TIEBK SLV, ID = 7.50" 10649 4 10610 7633 48 MMG DMY RK 0 02/23/02 9 -5/8" X 7" BKR H PKR, ID = 6:188" 10660' 9 -5/8" X 7" BKR HMC HGR, ID = 6.184" 10665' 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 10800' 9 -5/8" SIDETRACK WINDOW (18 -10A) 10800' - 10850' 11947 3.70" BKR DEPLOYMENT SLV, ID 11954 = 2.250" 3 -3/4" OD BKR DEPLOYMENT SLV, ID = 3.000" 12005' 3.00" BKR DEPLOYMENT SLV, ID 12015 3 -1/2" XN NIP, ID = 2.750" 3 -1/2" X 3- 3/16" XO, ID = 2.786" j 12016' 12039 4 -1/2" HES X NIP, ID = 3.813" 12050' 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" 4 -1/2" TBG, 12.6 #, L-80_0152 bpf, ID = 3.958" 12064' 12064' EOT- 4 -1/2" TP WAS BACKED OFF WHILE MILLING XN NIP ON 02/27/02 7" LNR MILLOUT WINDOW (18 -10B) 12219' - 12226' 7" LNR, 29 #, L -80 NSCC, .0371 bpf, ID = 6.184" 13120 / 3- 3/16" MILLOUT WINDOW (18 -10C) 12253'-12258 3- 3/16" WHIPSTOCK (08/29/10) 12245' RA TAG (09/16/10) 12256' l 3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.786" 12269' \\ �\ PERFORATION SUMMARY \ REF LOG: SLB MEM GR/CCL/CNL on 09/28/10 \� ANGLE AT TOP PERF: 90° @ 12900' Note: Refer to Production DB for historical perf data PBTD 14448 SIZE SPF INTERVAL Opn /Sqz DATE 1.56 6 12900 - 13140 O 09/29/10 2 -3/8" LNR, 6.2 #, L -80 STL, .0076 bpf, ID = 2.786" 14486' 1.56 6 13250 - 13490 O 09/29/10 1.56 6 13530 - 13750 O 09/29/10 1.56 6 13850 - 14000 O 09/29/10 1.56 6 14240 - 14415 O 09/29/10 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/24/82 ORIGINAL COMPLETION 10/23/10 RCT /AGR GLV CJO (10/05/10) WELL: 18 -10C 07/01/95 N2ES RIG SIDETRACK (18 -10A) 10/26/10 RCT /PJC TRSSSV NOTE PERMIT No: R L101120 03/13/02 CTD SIDETRACK (18 -108) API No: 50- 029 - 20818 -03 -00 09129/10 NORDIC1 CTD SIDETRACK (18 -10C) SEC 24, T11 N, R14E 370' SNL & 372' WEL 09/29/10 PJC DRLG HO CORRECTIONS 10/19/10 ? /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 18 -1013, Well History (Pre Rig Sidetrack) Date Summary 07/05/10 T /IA/OA= SSV /1500/0 Temp =Sl W/H repair Unable to bleed WHP to 0 psi due to no Alemite. Adjusted all G/N on both spools no leaks detected. 07/16/10 ** *WELL S/I ON ARRIVAL * * *(ctd screen) DRIFT W/ 2.25" CENTRALIZER & 1 -3/4" SAMPLE BAILER TO 12740' SLM, DEVIATE OUT, NO SAMPLE RECOVERED PDS M/U 24 ARM CALIPER TO TS 07/16/10 ( Assist S -Line ) Load diesel / Arrive on location / Standby for S -Line / ( WSR continued on 07 -17 -10 ) 07/17/10 (WSR continued from 07- 16 -10) Assist S -Line / Load TBG & IA (CTD screening). Loaded IA w/ 2 bbls neat meth and 294 bbls crude. Loaded TBG w/ 3 bbls neat meth, 290 bbls of 2% KCL and 40 bbls DSL. S. Line RIH to set TP / Reloaded TBG with 11 bbls diesel to achieve test press of 2500 Psi. Held 2500 Psi for 15 Minutes per S -Line with a 90 Psi Loss. Bleed TBG to 260 Psi. / RDMO / * *Tags hung, FW P's= 260/460/40 S -Line on well @ departure. IA and OA open to gauges. Operator notified. / 07/17/10 * * *CONT FROM 7 -17 -10 WSR * * *(ctd screen) LOG TUBING WITH 24 arm PDS CALIPER FROM DEVIATION @ 12709' SLM TO SURFACE SET 4 1/2" SLIPSTOP C -SUB @ 3995' SLM PULL RK -OGLV FROM STA #1 @ 3595' SLM/ 3612' MD LRS -LOAD IA W/ 290 BBLS CRUDE SET RK -DGLV IN STA #1 @ 3612' MD PULLED C -SUB FROM 3995' SLM LRS -LOAD TBG W/ 290 BBLS KCL & 40 BBLS DIESEL SET 2.81" C.A.T STANDING VALVE (4 1/2" G -FISH NECK, 28" OAL) @ 11967' SLM / 11997' MD LRS TEST PLUG TO 2500 psi, PASS 07/18/10 * * *CONT JOB FROM 7- 17- 10 * * *(ctd- screen) RIG DOWN S/L UNIT *" *WELL LEFT S /I, DSO NOTIFIED * ** 07/28/10 T /I /O= 150/750/0 MIT IA to 3000 psi.PASSED MIT OA to 2000 psi. PASSED Pumped 9.2 bbls crude down IA to bring pressure up to 3000 psi. Lost 80 psi in 1st 15 minutes. Lost 20 psi in 2nd 15 minutes. Bleed IA pressure down to 560 psi. Pumped 4.6 bbls crude down OA to bring pressure up to 2000 psi. Lost 120 psi in 1st 15 minutes. Lost 40 psi in 2nd 15 minutes. Bleed OA pressure down to 500 psi. FWHP= 150/560/500 Master, IA, and OA open. Swab, Wing, and SSV closed. 08/13/10 T /I /O= SSV/780 /550, Temp =Sl. PPPOT-T (PASS), CTD screen. PPPOT -T: Opened SBS, bled test void to 0 psi (gas). Removed 1 " plug, installed Alemite fitting. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi, removed Alemite fitting and internal check. Re- installed Alemite fitting. PT void to 5000 psi, no external leaks, bled void to 0 psi. Functioned LDS, all moved freely (2.5 "). 08/18/10 ** *WELL S/I ON ARRIVAL * ** RIG SWCP #4515 TO PULL 45KB LTP. ** *CONTINUED ON 8 -19 -10 WSR * ** 08/19/10 ** *CONTINUED FROM 8 -18 -10 WSR ** *(pre sdtrk) PULLED 4 1/2" KB LTTP FROM 11921' SLM PULLED 4 1/2" BKR LINER TOP PACKER FROM 11 936' SLM/11997' SLM. DRIFT TO 2 7/8" XO W/ 10'x 2 5/8" STEM, 2.66" CENT, S- BAILER TO 12243' SLM/ 12269' MD. ** *WELL LEFT S/I OPER NOTIFIED * ** Page 1 of 3 18 -1013, Well History (Pre Rig Sidetrack) Date Summary 08/25/10 T /I /O = 2100/1050/480. Temp =Sl. Tbg FL (for E- line). IA & OA are fluid packed. Tbg FL @ 7400' (between sta #2 & sta #3, 113 bbls). Integral installed on IA. SV,WV,SSV= Closed. MV =Open. IA,OA =OTG. NOVP. 08/26/10 ** *WELL S/I ON ARRIVAL * ** ATTEMPT DOUBLE BARRIER TEST. FAILED. CALLED FOR GREASE CREW. * *WSR CONTINUED ON 8/27/10) * ** 08/27/10 ** *JOB CONTINUED FROM 8 -26 * ** (drift dummy whip stock) RAN 3.5 GR, 10' X 2.7 DMY WHIPSTOCK, SD @ 12,217, UNABLE TO WORK PAST RAN 2.70 "CENT, SD @ 12237'SLM/12269'MD RAN 2.70" CENT, XO, 2.50" LIB, SD @ 12237, GOOD PICTURE RAN 20 X 2.70" DUMMY WHIP STOCK SD @ 11,987' SLM WORK DOWN TO 12,235' SLM RAN 10 X 2.70 DUMMY WHIP STOCK SD @ 12,217' SLM, UNABLE TO WORK PAST ** *WELL LEFT SHUT IN * * * * ** 08/28/10 TWO= 2100/1020/520. Assist E -line. (CTD prep) Arrive on location. Standby for E -line. Rig up and PT surface line. ** *WSR continued on 08- 29- 2010 * ** 08/28/10 ** *WELL SI ON ARRIVAL ( ELINE WHIPSTOCK) INITIAL T /I /O = 2000/1050/525 RIG UP ELINE AND LRS. ARM AND ORIENT WHIPSTOCK SETTING TOOL. ** *JOB IN PROGRESS AND CONTINUED ON 29 AUG 2010 * ** 08/29/10 ** *WSR continued from 08- 28- 2010 * ** T /I /O = 2100/1020/520. Assist E -line. MIT -T * *FAILED ** to 1000 psi. to test Whipstock. (CTD prep). Speared into Tbg with 2 bbls of Neat followed by 294 bbls of 1 %KCL and capped with 48 bbls of Diesel. Pumped 4.5 bbls of dsl down TBG to reach test pressure. 15 min TP lost 500 psi. 30 min TP lost 220 psi. Total loss of 720 psi in 30 mins. 120 psi left on TBG at time of rig down. On departure TBG had decreased to 20 psi. DSO notified of well status and tree valve positions as follows: SV,WV= closed SSV,MV= open. IA and OA open to gauges. FWHP= 20/1140/40. ** *Job Complete * ** 08/29/10 ** *CONTINUED FROM 28 AUG 2010 * ** LRS LOAD /KILL WITH 294 BBL 1% KCL. PUMP FREEZE PROTECT 35 BBL DIESEL. SET WHIPSTOCK WITH TOP OF WHIPSTOCK AT 12247 FT. ORIENTED 33 DEG RIGHT OF HIGH SIDE. PULLED 2500 LB TO RELEASE SETTING TOOL. FINAL T /I /O = 0/1200/300. WELL LEFT IN CONTROL OF LRS FOR PRESSURE TESTING. ** *JOB COMPLETE * ** 09/06/10 TWO = 0/1000/0 Pressure tested down on master & wing to 300 psi (passed) and 3500 psi (passed). Pressure tested down on SSV & wing to 300 psi (passed) and 3500 psi (passed). Rigged up lubricator and tested to 300 psi (passed) and 3500 psi (passed) Set 5 1/8" FMC ISA BPV @ 108" w/ 1 -2' ext. Torqued all tree flange nuts to spec. (see log) Rigged up lubricator with pulling tool and tested to 300 psi. (passed) and 3500 psi (passed) Pulled 5 1/8" FMC ISA BPV. Rigged up lubricator to set TTP. Tested lubricator to 300 psi. (passed) and 3500 psi. (passed) Set 5 1/8" FMC ISA TTP. Rigged up lubricator to pull TTP. Pressure tested entire tree to 300 psi (passed) and 5000 psi (passed) Pulled 5 1/8" FMC ISA TTP. Tested swab valve from topside to 3500 psi (failed) valve lost 250 psi in 5 minutes. 09/08/10 TWO = SSV /1060/Vac. Temp = SI. Bleed IAP to 0 psi (Pre -CTD). No AL, flowline, well house or scaffold. Unable to get TBGP (well is LOTO & has no WH scaffold). IA FL @ surface. Bled IAP from 1060 psi to 170 psi (unable to bleed below 140 psi, see log for details), (to BT, 27 bbls fluid) in 2.5 hours. Monitor for 30 min. IAP increased 30 psi to 200 psi. OAP unchanged through job. FWHP's = SSV /200/Vac. Job Incomplete. SV = ?. WV, SSV = Locked out. MV = C. IA, OA = OTG. NOVP. 09/09/10 T /I /O = SSV /350 /Vac. Temp = SI. Bleed IAP to 0 psi Monitoring OA (Pre -CTD). No AL, flowline, well house or scaffold. IAP increased 150 psi overnight. IA FL =near surface. Bled IAP from 350 psi to 250 psi (see log for details), (to BT, 11.5 bbls fluid) in 3 hours. IAP increased 10 psi during 30 min monitor. OAP unchanged through job. FWHP's =SSV /260 /Vac SV = ?. WV, SSV = Locked out. MV = C. IA, OA = OTG. NOVP. * *Job incomplete ** Page 2 of 3 18 -1013, Well History (Pre Rig Sidetrack) Date Summary 09/10/10 T /I /O= SSW360Nac Temp =Sl MIT -IA w/ diesel to 3000 psi (Eval IA integrity) IAP increased 100 psi overnight. IA FL dropped to 640' (34 bbls). IA FL too deep to continue job w /tri -plex - job cancelled. SV =C. WV, SSV= LOCKED OUT. IA, OA =OTG. NOVP * *Job incomplete ** 09/10/10 TWO = SSV /500Nac. Temp = SI. Bleed IAP to 0 psi (Pre -CTD). No AL, flowline, wellhouse or scaffold. IA FL @ 114' (6 bbls). Bled IAP from 500 psi to 35 psi (to BT, gas /fluid, 1.875 bbls) in 8.5 hours. Monitor for 30 min. IAP increased 35 psi to 70 psi. FWHP's = SSV/70Nac. Job Incomplete. SV = ?. WV, SSV = Locked Out. MV = C. IA, OA = OTG. NOVP. 09/10/10 TWO= 40 /320/Vac Temp= SI MIT -IA PASSED to 3000 psi (CTD) Pressured up IA to 3000 psi with 51.3 bbls crude. 1st 15 min IA lost 120 psi, 2nd 15 min IA lost 30 psi with a total loss of 150 psi in 30 min test. Bled back 17 bbls crude. Final WHP's= 60/500/0 "Valves are SV,WV,SSV,MV= closed, IA and OA open on departure" 09/11/10 T /1 /0= 0/0/0. Pressure tested down on Master & SSV to 500 psi. 5 min. to verify barriers (passed). Rigged up lubricator and tested to 300 psi. 5 min. (passed) and 3500 psi. 5 min. (passed). Set 5 1/8" FMC ISA BPV #537 @ 108" w/ 1 -2' ext. Pressure tested tree cap to 500 psi. (passed), upon completion. 09/11/10 T /I /O= SSW90Nac. Temp =S1. Bleed IAP to 0 psi. (pre -CTD). IA has integral installed. IA FL near surface. Bled IAP to 40 psi in 7 hr (fluid /gas) (see log). No Montior, IAP =40 psi @ 16:30. 1 bbl return. Final W HPs= BPW40Nac. 09/12/10 T /I /O= BPW80Nac. Temp =Sl. Bleed IAP to 0 psi, Monitor OAP (pre -CTD). No AL. IA FL @ 330' (18 bbls). Bled IAP from 80 psi to 13 psi in 8 hrs (all gas), the pressure increased periodically throughout the bleed. IA FL @ 110'. Monitored 30 mins, IAP increased 22 psi. ** Well has been demobed for Drilling. IA integral installed. Final T /I /O= BPW35Nac. ** Job is Complete ** ** Nordic 1 is in control of wellhead upon departure ** 09/12/10 T /I /O= BPV /80Nac. Temp =Sl. Bleed IAP to 0 psi, Monitor OAP (pre -CTD). No AL. IA FL @ 330'(18 bbls). Bled IAP from 80 psi to 13 psi in 8 hrs (all gas), the pressure increased periodically throughout the bleed. IA FL @ 110'. Monitored 30 mins, IAP increased 22 psi. ** Well has been demobed for Drilling. IA integral installed. Final T /I /O= BPW35Nac. ** Job is Complete ** ** Nordic 1 is in control of wellhead upon departure ** 09/14/10 T /1 /0= 60/0/0. Pulled 5" FMC ISA BPV #537, Nordic 1 to move on well. Rigged up lubricator and pressure tested to 300psi. (passed) and 3500psi. (passed). Used 4 -5' ext., tagged @ 76" Page 3 of 3 North America - ALASKA - BP Page - at - Operation Summary Report Common Well Name: 18 -10 AFE No Event Type: MOBILIZATION (MOB) Start Date: 9/12/2010 End Date: X3- OOXC5 -C (467,337.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 3/17/2002 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: A ctive Datum: 2 : 10 5/31/1996 08:46 @ (abov Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/12/2010 16:00 - 00:00 8.00 MOB P PRE MOVE RIG OFF C PAD & ONTO TWIN TOWERS ROAD. TURN RIGHT ONTO WEST DOCK ROAD. 9/13/2010 00:00 - 02:00 2.00 MOB P PRE MOVE RIG DOWN WEST DOCK ROAD. STOP RIG ON WEST DOCK ROAD — 5MILES FROM DS 18 TURN OFF. RIG HAS FLAT TIRE. 02:00 - 14:00 12.00 MOB N RREP PRE PUT RIG MATS DOWN. REMOVE ODS STAIR CASE. REMOVE STEERING ARM. REMOVE CONNECTOR ARM. REMOVE TIRE. INSTALL " NEW TIRE. AIR UP NEW TIRE. INSTALL CONNECTOR & STEERING ARM. 14:00 17:00 3.00 MOB P PRE CONTINUE MOVING TO DS 18 17:00 - 18:30 1.50 MOB P PRE MOBILIZE RIG OVER WELL AND SPOT ON WELL 118:30 23:30 5.00 BOPSUR P PRE RIG ACCEPT AT 1830' - COMPLETE RIG PREPARATION FOR NU BOP NU BOP POSITION SATELLITE CAMP POSITION TIGER TANK, RU HARD LINES TAKE ON RIG WATER INSPECT LINES PREPARE FLOOR FOR BOP TEST 23:30 - 00:00 0.50 BOPSUR P PRE T EST BOP TO 250 PSI LOW. 3500 PSI HIGH WITH 2" TEST JOINT 9/14/2010 00:00 - 07:05 7.08 BOPSUR P WEXIT TEST BOP TO 250 PSI LOW, 3500 PSI HIGH WITH 2" TEST JOINT Q� - TEST VARIABLE COMBIE RAMS WITH 2 3/8" Ivv'' TEST JOINT f - AOGCC REP CHUCK SCHEVE WAIVED WITNESS TO TEST TOOLPUSHER BRIAN PEDERSON AND WSL ROB O'NEAL WITNESSED TEST - BOPE TEST 250PSV350OPSI - PASSED CONCURRENT OPS: TAKE ON FLUID TO PITS, STAGE TRUCK TO DISPLACE FREEZE PROTECT FROM WELL PU NEW 2" COIL 1 07:05 - 09:00 1.92 BOPSUR P WEXIT INSTALL GRAPPLE CONNECTOR IN CT. RD HARDLING OUT OF WAY OF LOADER. INSTALL LANDING ON STAIRS. RU HARDLINE. PRESSURE TEST HARDLINE. Printed 10/14/2010 12:51:06PM No rth Acnerlc� - ALASKA - BP; Fage``1 of 1Q• Operation Summary Report Common Well Name: 18 -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/14/2010 End Date: 9/25/2010 X3- OOXC5 -C (1,585,726.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 3/17/2002 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active D 21 : 10 5/31/1 08:46 @45.03ft (above M Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/14/2010 09:00 - 09:15 0.25 BOPSUR P WEXIT PJSM WITH DSM. 09:15 - 09:30 0.25 BOPSUR P WEXIT RU DSM. STAB ONTO WELL. 09:30 - 09:50 0.33 BOPSUR P WEXIT PRESSURE TEST DSM LUBRICATOR. 250PSV3500PSI - PASS. 09:50 - 10:20 0.50 BOPSUR P WEXIT PULL BPV. 10:20 10:50 0.50 BOPSUR P WEXIT RD DSM, BPV RECOVERED. WHP — 100PS1. 10:50 - 11:05 0.25 RIGU P WEXIT PJSM REGARDING PULLING COIL ACROSS & STABBING PIPE. 11:05 - 12:30 1.42 RIGU P WEXIT PULL TEST GRAPPLE CONNECTOR. REMOVE SHIPPING BAR. PULL COIL ACROSS & STAB INTO INJECTOR. BOOT E -LINE, FILL LINE WITH SEAWATER TREATED WITH KCL. 12:30 15:00 2.50 EVAL P WEXIT PRESSURE TEST INNER REEL; LEAK BY. INSPECT, FIND MISSING O -RING ON PLUG VALVE. REPAIR O -RING. RE -TEST TO 4000 PSI, GOOD TEST. CHANGE PACKOFFS IN INJECTOR HEAD AND PRESSURE TEST INNER REEL AND PACKOFFS TO 4000 PSI, GOOD TEST. 15:00 17:15 2.25 RIGU P WEXIT - PUMP SLACK WITH NO MOVEMENT. REHEAD CTC MEG LINE AND CONDUCT PULL TEST. PRESSURE TEST CTC AND UQC, GOOD TEST. PUMP SLACK FORWARD. BREAK OFF INJECTOR, STAND BACK AND SECURE WELL CAP. 17:15 18:30 1.25 EVAL P WEXIT ATTEMPT TO BLEED OFF PRESSURE FROM WELL BEFORE DISPLACEMENT. BLEED OFF SUCCESSFUL. MONITOR WELLHEAD PRESSURE, CLIMBED TO 140 PSI OVER 45 MINUTE PERIOD. DISCUSS MITIGATION ACTIONS, CONSULT WITH TOWN ENGINEER. DECIDE TO BULLHEAD 1.5X TUBING VOLUME. 18:30 - 20:00 1.50 BOPSUR P WEXIT MOBILIZE METHANOL TO TREAT HYDRATES I DURING BULLHEAD OPERATIONS. PREP, RU NOZZLE BHA FOR BULLHEAD OPERATION. BLEED WELLHEAD PRESSURE TO BLEED TANK. RU COIL. 20:00 20:30 0.50 EVAL P WEXIT CIRCULATE KCL THROUGH REEL. PRESSURE TEST INNER REEL, COIL AND LUBRICATOR CONNECTION TO 250 PIS LOW, 3500 PSI HIGH ON SLB CHART. GOOD TEST. 20:30 22:30 2.00 EVAL P WEXIT ATTEMPT TO RIH WITH COIL. CANNOT PASS BY SWAB VALVE WITH THREE ATTEMPTS. RE- MEASURE STACK, ENSURE IT IS SWAB VALVE STACKING OUT ON. PULL BACK INJECTOR, STRAIGHTEN COIL MEMORY (NEWCOIL). RE- PRESSURE TEST AGAINST LUBRICATOR CONNECTION TO 250 PSI LOW, 3500 PSI HIGH. BLEED OFF TO 1000 PSI. Printed 10/14/2010 12:55:25PM orth America - ALAS - BP Fa IE Operation Summary Report Common Well Name: 18 -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/14/2010 End Date: 9/25/2010 X3- OOXC5 -C (1,585,726.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 3/17/2002 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA I UWI: Active Datum : 10 5/31/1996 08:46 @45.03ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 122:30 - 00:00 1.50 KILLW P WEXIT RIH WITH COIL THROUGH PACKOFF ASSEMBLY WITH CLOSED CHOKE, MAINTAINING 1000 PSI SHUT -IN PRESSURE PRESSURE INCREASED TO 1500 PSI; BLEED TO TIGER TANK, MAINTAINING LESS THAN 100 PSI BACK PRESSURE - SOME GAS NOTICED DURING BLEED OFF CONTINUE TO RIH HOLDING 1000 PSI BACK PRESSURE - IA AND OA AT 0 PSI 9/15/2010 00:00 06:00 6.00 EVAL P WEXIT RIH WITH NOZZLE BHA WHILE DISPLACING THROUGH CHOKE INTO TIGER TANK, MAINTAINING 1000 PSI OF BACK PRESSURE AND SEEING 60 PSI OF PRESSURE GOING TO TIGER TANK. CONTINUE RIH THIS WAY TO 9600' WHILE MONITORING WELL PRESSURE - CLOSE CHOKE, BREAK OVER AND BEGIN BULLHEAD OPERATIONS AT 9900' PUMPING AT .9 BPM, 1800 -2000 PSI -TAG WHIPSTOCK AT 12,243' COIL MEASUREMENT PU, ESTABLISH PARAMETERS: CIRC PRESSURE 1750 PSI AT .9 BPM WITH 59 BBLS KCL BULLHEADED INTO FORMATION - CRACK CHOKE, CONTINUE TO PUMP 420 BBLS KCL FOR TWO BOTTOMS UP AT 1.2 -1.8 BPM, 2600 -3280 PSI AND DISPLACE FREEZE PROTECT TO TIGER TANK - SWAP TO 8.5 PPG GEOVIS MUD DISPLACE AT 2.35 BPM, 3700 PSI HOLDING 430 PSI BACKPRESSURE SHUT DOWN PUMPING, MONITOR WELL - IA AT 12 PSI, OA AT 0 PSI MW IN 8.5 PPG, MW OUT 8.4 PPG 06:00 08:00 2.00 EVAL P WEXIT CONTINUE CIRCULATING WELL WITH 8.56 PPG GEOVIS MUD. FLOW CHECK WELL FOR 30 MINUTES AND VENT RESIDUAL SURFACE GAS TO TIGER TANK NO -FLOW OBSERVED 08:00 - 10:20 2.33 EVAL P WEXIT POOH 10:20 11:50 1.50 EVAL P WEXIT TAG UP AND FLOW CHECK AT SURFACE MEG ELINE(GOOD) M U WINDOW MILLING BHA WITH 2.74" MILL AND STRING REAMER 11:50 - 14:20 2.50 EVAL P WEXIT RIH 14:20 15:30 1.17 EVAL P WEXIT LOG TIE IN FROM 11 590' TO 11760'. CORRECTED -2° Printed 10/14/2010 12:55:25PM = arth America°=�°tiLASKA Page 3 of � a i s�umrna Re r ot � .:, ©per ,ton. ry. p ; Common Well Name: 18 -10 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/14/2010 End Date: 9/25/2010 X3- OOXC5 -C (1,585,726.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 3/17/2002 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 21 : 10 5/31/1996 08:46 @45.03ft (abo Mean Sea Lev Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 00:00 8.50 STWHIP P WEXIT BEGIN MILLING WINDOW AT 12252 1.55/1.58 BPM 2930 PSI FS 8.56/8.59 PPG PVT = 166 BBLS ECD = 9.35 PPG WINDOW MILL EXIT AT 12,257.8' - 1.1 TO 1.2 WOB, 1.2 TO 1.3 BPM, 3110 TO 3280 PSI ON, 8.53 PPG MW IN, 8.56 MW OUT, PVT 165 BBLS, ECD 9.37 PPG CONTINUE DRILLING RATHOLE TO 12,267.98' - 0.8 TO 1.7 WOB, 1.57 BPM, 3200 PSI ON, 8.57 PPG MW IN, 8.58 PPG MW OUT, PVT 165 BBLS, ECD 9.8 PPG - REAM THROUGH WINDOW X3, MAKE DRY RUN THROUGH WITH NO PROBLEMS 9/16/2010 00:00 - 02:15 2.25 STWHIP P WEXIT MONITOR WELL. POH TO BHA. CONDUCT FLOW CHECK AT 7000'. CONTINUE TO POH. TAG AT SURFACE. 02:15 - 02:45 0.50 STWHIP P WEXIT BREAK INJECTOR HEAD, LD MILLING BHA. MILL AND UPPER STRING MILL IN GAUGE. 02:45 - 03:45 1.00 DRILL P PROD1 CLEAR AND CLEAN RIG FLOOR. MU 3" BI- CENTER DRILLING BHA. INSPECT COIL CONNECTOR. FLOW CHECK WELL. 03:45 06:00 2.25 DRILL P PROD1 RIH WITH 3" DRILLING BHA. CONDUCT TIE -IN AT 11,670'; -3' CORRECTION . CONTINUE TO RIH. _. 06:00 09:40 3.67 DRILL P PROD1 BEGIN DRILLING BUILD SECTION FROM 12257' 1.59/1.63 BPM 3102 PSI FREE SPIN 8.56/8.60 PPG SWAPPING MUD ECD = 9.40 PPG 09:40 - 09:50 0.17 DRILL P PROD1 WIPER TRIP TO WINDOW FROM 12400' 09:50 12:10 2.33 DRILL P PROD1 CONTINUE DRILLING BUILD SECTION FROM 12400' 12:10 - 12:30 0.33 DRILL P PROD1 WIPER TRIP TO WINDOW FROM 12550' 12:30 15:00 2.50 DRILL P PROD1 CONTINUE DRILLING BUILD SECTION FROM 12550' 15:00 15:30 0.50 DRILL P PROD1 WIPER TRIP TO WINDOW FROM 12685' AFTER ROP SLOWED 15:30 - 15:45 0.25 DRILL P PROD1 TIE -IN LOG FROM 12270'. CORRECT + 2'. 15:45 - 18:00 2.25 DRILL P PROD1 WIPER TO BOTTOM TO RESUME DRILLING BUILD 18:00 - 20:00 2.00 DRILL P PROD1 CONTINUE DRILLING BUILD SECTION FROM 12257 TO 12875' 1.58 / 1.74 BPM 3035 PSI FREE SPIN 8.57 / 8.62 PPG ECD = 9.53 PPG COLLECT SAMPLES FOR GEO EVERY 50' 20:00 - 20:30 0.50 DRILL P PROD1 WIPER TRIP TO WINDOW. 20:30 - 20:50 0.33 DRILL P PROD1 OPEN ECD, PUMP 10 BBL HI-VIS SWEEP TO COINCIDE WITH BIT AT WINDOW. 20:50 00:00 3.17 DRILL P PROD1 POH CIRCULATING HI-VIS SWEEP TO SURFACE AT 2.1 BPM IN, 1.9 BPM OUT, 8.54 PPGMW IN, 8.62 PPG MW OUT, 3070 PSI 9/17/2010 1 00:00 00:20 0.33 DRILL P PROD1 POH TO BHA 00:20 - 01:30 1.17 DRILL P PROD1 BREAK OUT INJECTOR HEAD, POH WITH BHA. CHANGE OUT BIT ONTO SAME BHA. BIT GRADE 5- 3- RO- A- X -1 -BT -BHA Printed 10/14/2010 12:55:25PM • • ~~al~~ 0~ p~Q~S~(Q /.E......E.~~o~a.o. John McMullen ;;~~~~ ~.; J Engineering Team Leader ~- ~ X13 BP Exploration (Alaska), Inc. ~ V P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18- l OB Sundry Number: 310-251 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ~'~ Daniel T. Seamount, Jr. j Chair DATED this ~ Sday of August, 2010. Encl. STATE OF ALASKA f,p~ ALASK~ AND GAS CONSERVATION COMMIS~1 v' ~~~~ APPLICATION FOR SUNDRY APPROVAL ~/~ 20 AAC 25.280 ti~ ~~ 1. Type of Request: ^ Abandon ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development • ^ Exploratory 202-035 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20818-02-00• 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-108 Spacing Exception Required? ^ Yes ®No r 9. Property Designation: 10. Field /Pool(s): ADL 028302 • Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14107' 8690' • 14107' 8690' None None Casin Len th Size MD TVD Burst Colla e Structural Conductor 7g' 7 ' 149 47 Surface 2534' 1 -3/8" 2534' 2497' 493 2670 Intermediate 1080 ' 9-5/ " 10800' 77 2' 870 4760 Production Liner 157 ' 7" 10648' - 1221 7658' - 8 816 702 Liner 2110' 3-1 /2" x 3-3/16" x 2-7/8" 11997' - 14107' 490' - 8690' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12929' - 14105' 8717' - 8691' 4-1/2", 12.6# L-80 12064' Packers and SSSV Type: 9-5/8" x 7" BKR H Packer, 7" x 4-1/2" BKR S-3 Packer Packers and SSSV 10660' / 7666' MD (ft) and TVD (ft): 12050' / 8516' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 21, 2010 ^ Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: 13 212 ~f p ^ Gas ^ GINJ ^ GSTOR ^ Abandoned ~ W b ^ WAG ^ SPLUG ®Suspended Commission Representative: . / K 2.~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Cod Hirschman, 564-4468 Printed Name ~ I Title Engineering Team Leader Prepared By Name/Number: Signat a Phone 564-4711 Dat~ ~'~ ~ Elizabeth Barker, 564-4628 Commission Use Onl Conditions of approval: otify Commission so that a representative may witness ~' O .~~ Sundry Number: ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ ~ ~~~~ t ~' ~ ' " ~.:.~~,~ ¢ 00 ~vsL BaP .s,~ 35 T/-~s -f- ~ `r","` % ' S ~- Other: ~ Z S ~ U ~ S ~ ~ ., .1 .,,c/ J ' ~ ':~~.. _ s ~a~ te - vaVt~nissio r "ii~~l~'~t.;)n~t Subsequent Form Required: ~ (~ - ~/ O ~' 7 APPROVED BY ~ ~~~j" Approved By: COMMISSIONER THE COMMISSION Date ;;,,,,~~ Form 10-403 Revis d10 /' ~_ ~~~~G~ Submit In Duplicate DAIf1S AUG ~" 6 ~'~'' ~ g- i~-z o p,s~ ~ . ,~, ,~ ORIGIN~~. ~=j~D -° • • To: Alaska Oil & Gas Conservation Commission From: Cody Hinchman b p CTD Engineer Date: August 16, 2010 Re: 18-lOB Sundry Approval Sundry approval is requested to abandon the 18-lOB well by setting a packer whipstock above the exisitng perforations. The history of 18-lOB. Well 18-lOB was sidetracked in March 2002 after well 18-10A gassed out. The well is a Zone lA horizontal in the northwest area of DS 18. It was completed with 1176' of 2-7/8" slotted liner. After several years at a sustained production rate the rate leveled out and the GOR increased until it exceeded MGOR. The well became a swing well and on-time declined. In 2009, the well was shut-in most of the year due to high GOR and competition from its twin well 18-09B. Well 18-lOB was brought back on in December 2009 and had to be shut-in shortly after on March 1, 2010 due to the GOR increasing and the oil rate falling off. The well has remained shut-in since March 1, 2010. Sinee the well has a slotted liner, the gas shut-off options are limited. The well has a passing MIT-T, MIT-IA and MIT-OA. The reason for side track is well 18-lOB is no longer a competitive producer due to a high GOR. Because of the slotted liner completion, there are no remaining wellwork options. This well will be utilized to access Zone lA reserves in the upstructure portion of DS 18. The proposed plan for 18-lOB is to drill a thru-tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig on or around September 10, 2010. The existing perforations will be isolated by a 3-3/16" packer whipstock and the / primary 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: (scheduled to begin August 21, 2010). j/t,s tvtll CB/I~f9P~ty ~"®d"~f 4~~' 1. S DummyGLV's / 6p MsLP/f td G0~• f~{vrt`y Tit /t re o~01 2. S Pu114-1/2" KB LTP at 11,997' MD. ~ Q ~~, ro q//aW ; t fi ~pc4vl~-A"bvr w~ r~ f 3. S Dummy WS drift to 12,270' MD. ~ov~k of +hM~`4S ~0~ ~7 a 4o v e 60 Al ~F~y~ 4. E Set 3-3/16" Baker packer whipstock 30° ROHS at 1 ,250 MD. . ~~q;~~ f tortlil ~~'+tr ~;~; tf 5. F PT packer whipstock to 1000 psi for 30 min. ~ ~~kovti,. ~.,~f. ~jc~,d~,1r~ 6. W AC-LDS; AC-PPPOT-T to 5000 psi. ~n.~ fatr~~k~"{ Jv 4 Ae~.t 7. V PT MV, SV, WV gdvQ~l7rif[0~ (p cMti"6h ~//~/ 8. D Bleed gas lift and production flowlines down to zero and blind flange. ~~ 1~,,~,-pfd ~t~~ ~;~ 9. O Remove wellhouse, level pad. p~rT;o~ m,~ r{~ ~~o/ wglt mil! ~4r Qll~ U1~ ~f/~ P~,9- Rig Work: (scheduled to begin on Sept 10, 2010) ___1.. MIRU and test BOPE to 250 psi low and 3500 2. Swap the well to Geo-Vis. Mi112.8" window at 12,250' and 10' of rathole. 3. Drill Build: 3.0" OH, 570' (25°/100). 4. Drill Lateral: 3.0" OH, 1820' (12°/100). 5. Run 2-3/8" solid/slotted Bonzai completion leaving TOL at 11,980' MD. 6. Pump primary cement leaving TOC at TOL (11,980'), 5.4 bbls of 15.8 ppg liner cmt planned. 7. Test liner lap to 2,000 psi. 8. Cleanout run. 9. Run MCNL/GR/CCL log. 10. Set LTP. 11. Freeze protect well, set BPV and RDMO. -~T'~ Post-Rig Work: • • 1. Re-install wellhouse and FL's. 2. Run generic GLV's. 3. RU test separator, flow test well. 4. RU PBGL Cody Hinchman CTD Engineer 564-4468 CC: Well File Sondra Stewman/Terrie Hubble _, TREE= 6'MCEYOY LHEAD = MCEVOY ACTUATOR = A?tE1.SON KB. ELEV = aS.tY BF. ELEV = NA KOP = 1950' . Max!®'..._. -37 13092' .....~ .._._..._._ alum M1D = 1 50' abHfi T = 8600' Minimum ID'2.30"~ ~zeei~ MILLED 8KR LANQIN©CQLLAR TOP OF 7" BKR T~K SLV. ID = 7.50" 10649' 9•$18" X 7" BKR H PKR, ~ = 9.188" 10660' 9.5/13' X 7" BKR HhIC NGR, ~ = 0.184' 106' a5/8" csG, a7r, u80, ~ = 8.981" 10600' 6112" BKR KB LNR TOP PKR, D = 2.5~" 1199r OD BKR DEPI.OYF>B:NT SLV, ID = 3.000" 1?A05' 3.112" X 3.3119" LNR XO. b = 2.789' 1~o1r OF BAKER WHIPSTOCK J-j 1221y' RA PAi' TAG 722M' PERFORATION SUMMARY REF L00: SLTD LNR R~ TO PDTD ~ 14106' ANl9LE AT TOP PERF: 88 Q 12929' Nota: Referto Production DB for historical f data SIZE SPF INTERVAL DATE 2-718" 4 12929 -14105 0 03M 3102 - ~ v ~ ~t 1 T RI[J I t!: t#tLL AIR~Lt ! RU' ~7L]W'. ' TOP 2 ATD .ITS OF 2-TA" LNR II~D C61T DRLD OUT TO 2.]0", SO OPEN PBiFS IWE !i0'i CVr1C/`TCA ~ M'~.40~ ~'iaOl~ 2r $• 1rr' X 4112" HGR X0, ID = 3.955' • 2207' 41 CY CAMICO TRCF-4A TRSSSV CURVED FLAPPER, tD = 3.812" LOCKED OUT 8 HYDR1s1JLICS OPENED OAS LET AAAM1DRH.S ST MD TYD DEV TYPE VLY TCH PORT DATE 1 3612 3309 52 CA- S4 RK 20 01 C211D7 2 7089 5497 51 CA-AMMO DMfY RK 0 01/29/07 3 9847 701 S S2 CA-MNIO DMY RK 0 07/01195 4 1061 D 7632 .48 CA-kNMFCi DMY RK 0 02!23102 4112' 784.12.9/. L-80..01$2 bpf, ID = 3.9$8" ~ 9.518" SIDETRACK WINDOW f;'1~1t9A~ 10800' -10850' I kl" BKR SEAL ASSY, ~ = 2.390" 'ill" XN Nom, ~ = 2.750" 1l2"HESXNP,O=3.813" X 41(2" BKR S•3 PKR, D = 3.875" )T • 4112" TP WAS BAgCED OFF NEE ABLLNIG XN NBti ON 02127AD2 7" LNR MILLOUT WF+IDOW R'16-4B^) 12219' -12226' LNR, 9.2ar, 1-80, .0079 bpf, D = 2.789" 3-3/1e" X 2-7/8" LNR X0, b = 2.377" LANONG COLLAR. ML'D TD 2.30" ~ STOP OF 2-718" SLTD LNR ~ ~ ~\ t 1 ~~ '`` 14166' FBTD • ~ ~ k ~ ~ BTM2-718"SLTDLNR 14105' ~ 2-718" LNR. 0.5/. 6 x..0098 bpf. 67 = 2.377" 1410r DATE REV BY COMMENTS DATE REV BY _ COMMENTS 7th ~IQIIIiI CiDlLEI't011 09126!05 DAVIPJC OI.V C~ BiA'It119i R1ti f~ETR~t 6-1 0112/107 AVAAO OLV CIO B7M71B2 trTO i6fETRIEO[ 6-1Bm 09109/117 JRPISV _ _ TRSSSV LOCK OUT (08120A7) 10120A1 CHMAK CORRECTIONS 02104/10 JLWIPJC 9-SAB' CSO CORRECTION 03128A2 CH/TP CORRECTIDN's O6fl3A3 CMO/fLP KBELEYATIONCORRECTION PRUDFtOE BAY UNT iNELL' 18-108 PERMIT No: 202-0350 APl No: 50-029-20818-02 TREE= 6" McEVOY WE1_.LHEAD ` McEVOY ACTUATOR = AXELSON KB. E1EV = 45.0' BF. ELEV = NA KOP = 1950' Max Angle = 97 @ 13092' Datum MD = 12350' Datum TV D = 8600' SS . ~ ~ _ ~ O ~ TO~ L~TS OF 2 7/8 LNR HAD C~MT DRLD Proposed CTD Sidetrack OUT TO 2.30", SO OPEN PERFS ARE NOT EXPECTED FROM 12929' -12994'. 27' ~~ 5-1 /2" X 4-1 /2" HGR XO, ID = 3.958" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2534' 2207' 4-1/2" CAMCO TRCF-4A TRSSSV W/ CURVED FLAPPER, ID = 3.812" LOCKED OUT & HYDRAULICS OPENED GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =1.75" @ 11970 1 3612 3309 52 CA-MMG SO RK 20 01/21/07 BKR LTP SEAL 2 3 7089 9647 5497 7015 51 52 CA-MMG CA-MMG DMY DMY RK RK 0 0 01/21/07 07/01/95 4 10610 7632 48 CA-MMG DMY RK 0 02/23/02 TOP OF 7" BKR TIEBK SLV, ID = 7.50" ~ 10649' 9-5/8" X 7" BKR H PKR, ID = 6.188" 10660' 9-5/8" X 7" BKR HMC HGR, ID = 6.184" 10665' 9-5/8" SIDETRACK WINDOW (18-10A) 10800' - 10850' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10800' TSGR 11540' 11970' 4.5" BKR KB LNR TOP PKR ID = 1.75" 59~ " " ' 11980' TOL 2-3/8" 4-1/2 BKR KB LNR TOP PKR, ID = 2.560 (PULL) 11997 Pull LTP " " ' 12005' 3.00" BKR SEAL ASSY, ID = 2.390" (PULL) OD BKR DEPLOYMENT SLV, ID = 3.000 3-3/4 12005 12015' 3-1/2" XN NIP, ID = 2.750" 3-1 /2" X 3-3/16" LNR XO ID = 2 786" 12017' , . 12039' 4-1/2" HES X NIP, ID = 3.813" 12050' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" TBG 12 6# L-80 0152 b f ID = 3 958" 12050' 12064' EOT - 4-1/2" TP WAS BACKED OFF . , , . p , , . WHILE MILLING XN NIP ON 02/27/02 RA PIP TAG 12224' 7" LNR MILLOUT WINDOW (18-10B) 12219' - 12226' 3-3/16" monobore pkr w hipstock 12250' 7" LNR, 29#, L-80, NSCC ID = 6.184" 12514' PERFORATION SUMMARY REF LOG: SLTD LNR REF TO PBTD @ 14106' ANGLE AT TOP PERF: 88 @ 12929' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 12929 - 14105 O 03/13/02 bottom of cmt 13,000' o ~~ I 63 -------------------~ 2-3/8" LNR, 4.7#, L-80, ID = 1.995" I ~ 12269' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" ` 12270' 3-3/16" X 2-7/8" LNR XO, ID = 2.377" 1 1 \ ~ \ ~ 1 ~ 1 ~ 1 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.377" 14107' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/24/82 ORIGINAL COMPLETION 09!26/05 DAV/PJC GLV C/O 07/01/95 RIG SIDETRACK (18-10A) 01/21/07 DAV/PAG GLV C/O 03/13/02 CTD SIDETRACK (18-106) 09/01/07 JRP/SV TRSSSV LOCK OUT (08/20/07) 10/20/01 CWKAK CORRECTIONS 02/04/10 JLW/PJC 9-5/8" CSG CORRECTION 03/28/02 CWTP CORRECTIONS 08/03/10 MSE PROPOSED CTD SIDETRACK 06/13/03 CMO/TLP KB ELEVATION CORRECTION PRUDHOE BAY UNfT WELL: 18-10C PERMfT No: API No: 50-029-20818-03 SEC 24, T11 N, R14E 370' SNL & 372' WEL BP Exploration (Alaska) NORDIC-CALISTA RIG 1 CHOKE / REEVCIRCULATION MANIFOLD DIAGRAM Vts -- •-- V74 7-1116" 5000 psi BOP's ID = 7.06" V76 V71 TranaWrcxa ,t ;~ POOR BOY ~ V V2 Vl V 16 DEGASSER rr~n: IYpcr BOP cWW1eWn aulin VB vto vn HCR IC To Poor Boy Gas Buatw V4 5 V7 V1S l.w' ww pi RCR V9 Manual Ctaka YCS YEOH mw{al P Lkw CoFwi How ~MWlal ~ - t/4 Turn Hak:o SWACO IOWOG Pre re IransOucers -1 j _ CYll CY12 To Co11eU Tubkg Bkwtl Otl Yttter Rwl Vales CV33 i ~ Camwtl Lkw h Ground Uwl TIO-M CY30 CV3 CV2 Mkvd Ql9 Motbn CY77 CV1 CVS Tyar Tank Yud Pump 2 O CV/4 Mud Pump n O O D CV75 1 Jun-2010 Y Inr woo i, lu« ~~ Y( OK uua c~o.s 7 LI{' ww W . Pl-S{ sae w,~a Tor ris ~-Inr {ooo p.i cllEClc vuvE Y~ ror ris 1 In{ C~nrm FOV Ga4 vrY. { ww y.l •--- To Proouciion Tree or Cross Over CoFk>< How T Stets Pipa Yarwal Ctgka Pnaeura Transtluwrs N From Bales ~ YP 1 It YP 2 Cltoka KIII to Ptls Ltlw Rig Favor Rawrw CtlcWal LMIa C4 CT To YentloW CoFwc Nona Page 1 of 1 l~ J Subject: FW: INTENT PLUG for RE-DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10-403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 farm is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2. On the Form 10-403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10-403 with a check in the "Plug far Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-407, he wilt check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve will also change the status on the 10-407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file://F:~Daily_Document Record~Procedures Instructions~FW INTENT PLUG for RE-D... 8/18/2010 09/28/07 Schlumd~rger Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~~~ Nor/ o ~ za~~ Well .leh ~ Inn 110crrinfinn NO.4440 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~fe of e+..~..~ rn 15-06A 11661158 MCNL it L 06/21/07 1 F-26B 11216200 MCNL >t! <./ ~ 06/06/06 1 P2-11A 11285926 MCNL ~ 04/19/06 1 1 C-316 11745223 MCNL ~<,/ 05/31/07 1 1 E-03A 11628773 MCNL ~ ~C/ 05/09/07 1 1 K-12A 11745224 MCNL Q .. 06/02/07 1 1 18-108 11485771 MCNL ''~ / </'~(0 11/08/06 1 1 C-086 11209599 MCNL --~~~ ~ ~ JrL 04/22/06 1 1 D-30B 11628774 MCNL L ~' 05/10/07 1 1 ~~-r.vr '+vr"~v ~r~~vv~ ~~cv Glr ~ o~ JIV1\II~V NI~Y nGl VRIY11717 VIYC VVr'r CAlif1 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 i ~ r' ~' j, 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~~°~ itti ~~~~~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 1).- fÌ- ýi À ~!j 1..( DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020350 Well Name/No. PRUDHOE BAY UNIT 18-10B Operator BP EXPLORATION (ALASKA) INC ,".. I ) 1/ ~,: 1. 1 /'¡ ')~'- ...~ ð fJ.L I API No. 50-029-20818-02-00 MD 14107 " TVD 8690 .--- Completion Date 3/13/2002 ---- Completion Status 1-01L Current Status 1-01L UIC N -- - -.- -- -- ----------- ---- - ---- --- - ----- __n_____- - ----- .. - - - ----- - - ----- - - -- - -- ----- ----- ------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~., - -- - - --- --- .. - --------- ------- - - --------- - -- -- - - - - ------- .. - -- - --- - - - - - - ---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Logl Electr Data Digital Dataset Type Med/Frmt Number Name - - .. -- - .. - ---- - - -- -.. Rpt LIS Verification '~E'ó D (~1475 LIS Verification .--/'ED C Asc /.:J'19ì 1 LIS Verification ? ED C Pdf '? 11971 Rate of Penetration , /11971 (EO C Pdf Gamma Ray ------ - --._- Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments - - - -- ---- 12118 14075 Case 1/14/2003 -- ---.- --- ------ 25 25 12118 14075 Case 1/14/2003 12118 14107 Open 6/2/2003 12216 14107 Open 6/2/2003 MWD - ROP, NGP - MD 12216 8645 Open 6/2/2003 MWD - NGP - TVD Final Final - ---~-==--------- ----- ---- --- ---- --------- -------- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y rN.-' Daily History Received? GJ.¡N (j)N ~._-'" Chips Received? -Y-71I;J-- Formation Tops AnalysIs Received? --¥-t1'J - - - - -------- .. -- -- .. -- - ------ ----------- - -- .. - --- ---- - - ~- -- -- - ----- ------ ------- Comments: ~omPIi~n~~ -~e:i~=~:;-~--~~--:~_~11__u- - - - - --- ---------- --- -- - - - - - - - ---- - --- --- ------ - --- --- -------- - --- --- - ------ Date: --- - j,~ A-t-:J~-' r~!~~ :~-;-- ÔOd-O~ ) fr-//9r/ \\'ELL LOG TRANSl\lITTAL To: State of Alaska Alaska Oil and Gas Conservation Conm1. Attn.: Lisa Weepie 333 West 7th Avenue. Suite 100 Anchorage, Alaska 9950 I April l-l, 2003 RE: MWD Formation Evaluation Logs: I8-10B. AK -lVI\V - 22044 18-108: Digital Log Images 50-029-20818-02 I CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRo\.NSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 995 18 RECEIVED JUN 02 2003 . ~ \ - '- ~ . Date: .. Signed: ',""rJl)-t- fY\.. -1=:y,-~ Ala.a Oil & Gas Cons. CoI11ßU8)f1 And1cnge BP Exploration (Alaska) Inc. Petro-techrucaJ Data Center. LR2-1 900 E. Benson Bivd. Anchorage, Alaska 99508 ~tlJ. - 03:;- '~~~ f~\ ~ ~Od-035 1147S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn,: Lisa Weepie 333 West 7111 Avenue, Suite 100 J\nchorage, AJaska January 10, 2003 RE: MWD Formation Evaluation Logs 18-10B, AK-MW-22044 1 LDWG fOffilatted Disc with verification listing. API#: 50-029-20818-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Ann: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 995 18 BP Exploration (AJaska) Inc. Petro- T echnicaJ Data Center LR2-1 900 E. Benson Blvd, Anchorage, AJaska 99508 Date: Si~- /c (11(0 RECEíVE,[~r~ 'A" . v ~ 1 ~, "'''''' 'J . I Ll;I~-' Alaska o.~ & Gas I ,".,', . \AlI.o;. .....ommt-n AnchOf'lcJe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ,"' ".. . 4907' NSL, 371' WEL, SEC. 24, T11 N, R14E, UM . -::,' '. - At top of productive interval ',' -, '.," -' 4276' NSL, 1347' WEL, SEC. 14, T11N, R14E, UM ,.,.,::",,:L}--~'_L- At total depth " '" ::,' . 535' NSL, 940' WEL, SEC. 11, T11N, R14E, UM .'_"-:'~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 45.03' ADL 028302 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/9/2002 3/11/2002 3/13/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 14107 8690 FT 14107 8690 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP Classification of Service Well 7. Permit Number 202-035 8. API Number 50- 029-20818-02 ~ ~OC/i:,:-i{j.a~ 9. Unit or Lease Name . ~.~ ~ Prudhoe Bay Unit V~ 1D. Well Number 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 18-108 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2207' MD 1900' (Approx.) 23. CASING SIZE WT. PER FT. GRADE 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 3.1'2" x 3-3116 88111 x 6.2# L-80 x 2-718" x 6.1611 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 79' 30" 1975# Poleset Surface 2534' 17-1/2" 2120 sx Fondu, 400 sx PF 'C' Surface 10800' 12-1/4" 500 sx 'G', 51 Bbls PF 'C' 10648' 12218' 8-1/2" 350 sx Class 'G' 11997' 14107' 3-3/4" 37 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8", Slotted Liner MD 12929' - 14105' TVD ~ TVD 8717'-8691,RECr:IVED APR 1 6 200~ MlkaOil&GasCona.Commission Ardmgc 27. Date First Production March 25, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF AMOUNT PULLED 25. TUBING RECORD DEPTH SET (MD) 12064' PACKER SET (MD) 12050' SIZE 4-1/2", 12.6#, L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH WATER-BBL CHOKE SIZE GAS-OIL RATIO WATER-BBL OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. Form 10-407 Rev. 07-01-80 , . , t( tt U M S L1~ L ¡\PR 2 0 20CC () \.: Submit In Duplicate 29. Marker Name Geologic Marker,s Measured Depth 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 1 B 12420' 8662' RECE\VED APR 1 6 200Z A\a1ÞOi\&GasCQnl.CQmm\ss\on AJdDtI\P 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ Title Technical Assistant 18-10B 202-035 Well Number Permit No. I Approval No. Date {J{.I(p.O~ Prepared By Name/Number: Sandra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection. water injection. steam injection. air injection, salt water disposal. water supply for injection. observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given In other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16. and in item 24 show the producing intervals for only the interval reported in item 27, Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF. KB. etc.), ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain, ITEM 28: If no cores taken, indicate 'none', Form 10-407 Rev. 07-01-80 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-1 0 18-10B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Activity Code NPT Phase 3/6/2002 10:00 - 00:00 14,00 MOB P IpRE 3/7/2002 00:00 - 10:00 10.00 MOB P PRE 10:00 - 10:30 0.50 MOB P PRE 10:30 - 10:45 0.25 MOB P PRE 10:45 .. 11 :00 I 0.25 MOB P PRE 11 :00 - 13:00 2,00 MOB P PRE 13,00 - 14:00 1.00 BOPSUR P DECOMP 14:00 - 19:00 5.00 BOPSUR P DECOMP 19:00 - 19:30 0.50 PXA P DECOMP 19:30 - 20:00 0.50 PXA P DECOMP 20:00 - 21 :00 1.00 PXA P DECOMP 21 :00 - 22:30 1.50 BOPSUR P DECOMP 22:30 - 23:30 1.00 BOPSUR P DECOMP 23:30 - 00:00 0.50 PXA N SFAL DECOMP 3/8/2002 00:00 - 03:00 3.00 PXA N SFAL DECOMP 03:00 - 03:45 0.75 PXA P DECOMP 03:45 - 06:00 2.25 PXA P DECOMP 06:00 - 07:30 1.50 PXA P DECOMP 07:30 - 08:00 0.50 PXA P DECOMP 08'00 - 08:30 0.50 PXA P DECOMP 08.30 - 08'55 0 42 PXA P DECOMP 08.55 - 09.35 0.67 PXA P DECOMP Page 1 of 8 Start: Rig Release: Rig Number: Spud Date: 3/7/2002 End: 3/7/2002 Description of Operations Move Rig to OS 18-10B. 26 miles via K pad and West Dock road, Derrick up. Good weather, 8F, 10 MPH. Move Rig to OS 18-10B. Position rig in front of well. SIWHP = 0 psi. Flowline = 0 PSI. N/D tree cap. SAFETY MEETING, Review procedure and hazards to back rig over well. Position rig over well. ACCEPT RIG AT 11 :00 HRS, 03/07/2002. General rig up. spot trailers, generator. berm and spot tanks. N/U BOP stack. Perform Initial BOPE Pressure 1 function test. AOGCC witness waived by Lou Grimaldi. Observe electrical fault @ BOP panel. Suspend BOP test. Safety meeting prior to begining operations, R/U for cutting CT. Meanwhile take on KCL water in pits. Cut 200' of CT for fatigue management & changeout packoff. Install OS CTC & pull test to 35klbs. Meanwhile rectify electrical fault @ BOP panel. Complete testing BOPE. Foward report to AOGCC. Meanwhile fill & circulate CT. Open up well. WHP = 0 psi. PT inner reel valve to 500 psi & 3500 psi - OK. PT CTC to 3500 pSI - OK. Dowell computers crash and locks-up. W.O. computer repair. Rectify Dowell computer (printer software) problem. Meanwhile circulate CT. M/U cement stinger BHA#l, Stab injector on well. RIH with BHA #1 with on/off returns. Well drinking. Pumped 58bbls total before getting any returns. Wt check @ 12200', up = 40k, down = 14k, Tag whipstock @ 12245' & stack 5k. Held OK, Reset depth to 12214'. Order more 2% KCL water. PUH to 12204' & flag CT. PUH thru tailpipe to 11988' - no bobbles. Atempt to fill hole - getting 3.3/0.6bpm (high injectivity). Load 300 bbls. 2% KCL water in rig pits. SAFETY MEETING. Review cement job procedure and hazards with crews. Press test cement line with 4000 psi. Pump 10 bbls, 13.8 ppg, G CMT with 8% dry blended Bentonite. 2.7 bpm, 850 psi Pump 25 bbls, 13.8 ppg CMT with 16 ppb Aggregate. 22 bpm, 700 pSI Pump 13 5 bbls, neat 13 8 ppg CMT 2 7 bpm, Pump 10 bbls, water behind. 28 bpm, 1100 pSI, 1 bpm returns. Close choke. Bullhead 2 8 bpm with 150 psi WHP, Displace CMT with rig pump against closed choke. 29 bpm, 250 WHP, 10 bbls GMT out nozzle. 1.3 bpm, 700 WHP, 20 bbls CMT out nozzle. 1 3 bpm, 1000 WHP, 25 bbls CMT out nozzle. 1 1 bpm, 1400 WHP, 30 bbls GMT out nozzle. Open choke slowly Hold 1500 WHP. Lay in rest of CMT at 1 /1. WGTOC at 11,200 ft. Pull to Pr,nlea 311812002 14843 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-1 0 18-10B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Activity Code NPT Phase 3/8/2002 08:55 - 09:35 09:35 - 10:45 0.67 PXA 1 . 17 PXA P P DECaMP DECaMP 10:45 - 13:00 2,25 PXA P DECaMP 13:00 - 13:30 0.50 PXA P DECaMP 13:30 - 14:00 0.50 STWHIP P WEXIT 14:00 - 16:30 2.50 STWHIP P WEXIT 16:30 - 18:15 1,75 STWHIP P WEXIT 18:15 - 19:35 1,33 STWHIP P WEXIT 19:35 - 19:50 0.25 STWHIP P WEXIT 19:50 - 22:55 3,08 STWHIP P WEXIT 22:55 - 23:00 0.08 STWHIP P WEXIT 23:00 - 00:00 1,00 STWHIP P WEXIT 3/9/2002 00:00 - 00:45 0.75 STWHIP P WEXIT 00:45 - 00:50 0,08 STWHIP P WEXIT 00:50 - 02:20 1.50 STWHIP P WEXIT 02:20 - 02:55 0.58 STWHIP P WEXIT 02'55 - 03:10 0.25 STWHIP P WEXIT 03.10-03'50 0 67 STWHIP P WEXIT 03:50 - 03:55 0.08 STWHIP P WEXIT 03:55 - 05:45 1.83 STWHIP P WEXIT 05'45 - 08: 15 2 50 STWHIP P WEXIT 08.15 - 08:30 0 25 STWHIP P WEXIT 08.30 - 08:45 0 25 DRILL P PROD 1 Page 2 of 8 Start: Rig Release: Rig Number: Spud Date: 3/7/2002 End: 3/7/2002 Description of Operations 11.000 ft. Closed choke, Squeezed 2 bbls CMT away at 1800 WHP. Held 10 min, Good steady WHP. 33 bbls CMT below Whipstock. Cleanout 15.5 bbls CMT with 31 bbls Biozan water. Found CMT top at 11.700 ft, Cleanout with Biozan at 2.0 bpm, full returns. Cleanout to pinch point on whipstock. 12,219 ft. Circ, out contaminated CMT at 3.6 bpm. full returns. POOH while chasing contaminated CMT to surface. 3.1 bpm. full returns. LlO cementing BHA. Jet Stack with side jetting nozzle. M/U BHA #2 with 3.80" HC Diamond Speed Mill. 3.80" string reamer, straight motor, circ sub. 2 jts PH6 tubing, Hyd Discon and CTC, Total length = 87.4 ft, RIH with milling BHA. Correct to pinch point on whipstock at 12,218 ft, [-25' CTD] Flag CT at 12,218 ft. Start milling window at 12,218.0 ft. 2.7 bpm, 1500 psi, full returns. Milling at 12,219,1 ft. 2.7 bpm, 1500 psi, 2500 WOB. Mill to 12220' with 2,7/2,7bpm, 1480-1670psi. 2500 WOB. 2' milled. WOB occasionally creeping above 3k, Wt check, 35k up wt & 1400psi free spin, WOB falls below 3k after resuming milling. Mill to 12221.8' with 2.7/2.7bpm. 1500-1650psi, 2.5k WOB. 3.8' milled. Good motor work, but it takes time for wt to mil off. Wt check, 40k up wt & 1400psi free spin. Mill to 12222.1' with 2.7/2.7bpm, 1480-1500psi, 2k-3k WOB, 4.1' milled. Slow milling progress (29#, 7" csg). Mill to 12222.5' with 2,6/2.6bpm, 1500psi, 2k-3k WOB, 4.5' milled. WOB builds above 3k. Wt check, 41k up wt & 1450psi free spin. Pump down 5 bbls of biozan sweep. Mill to 12223.8' with 2,6/2.6bpm, 1680psi, 2k-3k WOB. 5.8' milled. Mill center pt should be crossing csg. Mill to 12224.3' with 2.6/2.6bpm. 1700psi, 2k-3k WOB. 6.3' milled. Motor stall. Wt check. 41 k up wt & 1450psi free spin. Had 2 more stalls on mill resumption. Continue milling to 12226' with 2.6/2,6bpm, 1480psi. 1.5k-2.5k WOB. 8' milled. Rap picking up to 15fph. Observed Btm of window @ 12225 7'. Slowly backream & pump down 6 bbls of blozan sweep. Mill 10' of formation to 12236'. Backream window area & made multiple dry passes. No motor work. Window looks clean. Meanwhile swap well to flo-pro mud. Window = 12219' to 12226' . POOH with milling BHA #2. Continue to swap well to re-conditioned FloPro. UO milling BHA. Diamond speed mill 1 stnng reamer both In gauge. PRE-SPUD MEETING 1 SAFETY MEETING. Review well plan with troups Review hazards and procedure to M/U BHA Pr,nlE-d 3/18/2002 1 ~8 43 PM BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Name: 18-1 0 Common Well Name: 18-108 Spud Date: 3/7/2002 Event Name: REENTER+COMPLETE Start: 3/7/2002 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 3/9/2002 08:45 - 09:30 0.75 DRILL P PROD1 M/U MWD BHA #3 with new DS49 Bit #2 and 1.04 bend motor. Held kick while trip drill. 09:30 - 11 :50 2.33 DRILL P PROD1 RIH with BHA #3. Shallow test Sperry tools. OK. RIH. 11:50-13:00 1.17 DRILL P PROD1 Tag TD at 12,246 ft, correct depth to 12,236 ft. [-10 ft CTD]. Up Wt. = 38K, Dwn Wt = 12K. Pick up to 12,130 ft. Log down with GR. Unable to get good tie-in with MWD GR thru 7" liner/cement. 13:00 - 13:15 0.25 DRILL P PROD1 Orient TF to high side. 13:15-15:30 2.25 DRILL P PROD1 RIH. Tag TD at 12254', correct to 12236' [-18' CTD, total corr. = -28 ft]. Drill build section. TF = 20R, 2.6/2,6 bpm, 3400 pSI, Drilled to 12320 ft. 15:30 -16:15 0,75 DRILL P PROD1 Drilling build section. TF = 60R. 2,6/2.6 bpm, 3400 psi. Drilled to 12,350 ft. 16:15 - 17:30 1.25 DRILL P PROD1 Log tie-in across RA marker at 12.217' logging up, Pull to TSAD and log up across TSAD. add 6 ft to CTD to correct to BHCS/GR TSAD. NOTE: Corrected depth for RA tag is 12,226 ft BKB. per geologist. Will use this depth for future tie-ins, 17:30 - 17:45 0.25 DRILL P PROD1 RIH. Tag corrected TD at 12,355 ft. 17:45 - 18:15 0.50 DRILL P PROD1 Drilling build section. TF = 70R. 2.6/2.6 bpm, 3400 psi. Drilled to 12387 ft. 18:15 - 18:55 0.67 DRILL P PROD1 Orient TF around to 60R. 18:55 - 19:30 0.58 DRILL P PROD1 Drill to 12433' with 60R TF, 2.6/2.6bpm, 3300/3650psi & 79fph ave ROP. 19:30 - 20:10 0,67 DRILL P PROD1 Drill to 12489' with 75-80R TF, 2,6/2.6bpm, 3300/3650psi & 84fph ave ROP. 20:10 - 20:15 0,08 DRILL P PROD1 Drill to 12500' with 75-80R TF, 2.6/2.6bpm, 3300/3650psi & 132fph ave ROP, 20: 15 - 20:30 0,25 DRILL P PROD1 Wiper to the window - hole OK, 20:30 - 20:50 0.33 DRILL P PROD1 Drill to 12530' with 80R TF, 2.6/2.6bpm, 3300/3700psi & 90fph ave ROP. 20:50 - 21 :00 0.17 DRILL P PROD1 Drill to 12543' with 80R TF, 2.6/2.6bpm, 3300/3700psi & 78fph ave ROP. 21 :00 - 21 :20 0.33 DRILL P PROD1 Drill to 12582' with 80R TF, 2.6/2.6bpm, 3300/3700psi & 117fph ave ROP. Meanwhile held HSE Stand-Down meeting with Nordic night crew & MI mud Engr. DS crew already covered during Schlumberger's general safety meeting. 21 :20 - 21 :50 0.50 DRILL P PROD1 Orient TF to 70R. 21'50 - 22'20 0 50 DRILL P PROD 1 Drill to 12607' with 70-80R TF, 2.6/2.6bpm, 3300/3800psi & 50fph ave ROP 22:20 - 22:45 0.42 DRILL P PROD 1 Drill to 12628' with lOR TF, 2.6/2.6bpm, 3300/3800psi & 45fph ave ROP. Wt stacking & acting like fault crossing. 22:45 - 23'05 0 33 DRILL P PROD 1 Orient 1 click & drill to 12652' with 90-100R TF. 2 6/2 6bpm. 3300/3800psi & 120fph ave ROP. 23 05 - 23.40 0.58 DRILL P PROD1 Wiper to the wmdow - hole OK. 23.40 - 00'00 0 33 DRILL P PROD 1 Drill to 12670' with 90R TF. 2.6/2.6bpm. 3300/3700psi & 25fph ave ROP. Wt stacking. 0.8% drill solids m mud. Call for 450bbls fresh mud. 3/10/2002 00:00 - 01 :50 1.83 DRILL P PROD 1 Drill to 12752' with 90R TF, 2.6/2 6bpm, 3300/3600psi & 54fph ave ROP. Wt stacking & ratty drillmg thru various shale streaks. Hole not sticky. 01:50 - 02:15 042 DRILL P PROD1 Wiper to the window - hole OK. Printed 3/18/2002 1 4643 PM ) ) BP EXPLORATION Operations Summary Report Page 4 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-1 0 18-10B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 3/7/2002 Spud Date: 3/7/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 3/10/2002 02: 15 - 02:40 0.42 DRILL P PROD 1 Log & tie-into RA PIP tag (+8' correction) 02:40 - 02:55 0.25 DRILL P PROD 1 RBIH smoothly to btm. 02:55 - 03:00 0.08 DRILL P PROD1 Drill to 12762' with 90R TF, 2.6/2,6bpm, 3300/3700psi & 57fph ave ROP, Wt stacking. 03:00 - 03:20 0,33 DRILL P PROD1 Orient TF to 60R. 03:20 - 04: 15 0,92 DRILL P PROD1 Drill to 12800' with 90R TF, 2,6/2.6bpm, 3300/3700psi & 53fph ave ROP, Clean PIUs, but stll drilling ratty, Suspect shaley interval between Zones 1 B & 1A. 04: 15 - 04:30 0,25 DRILL P PROD1 Orient TF to 90L. 04:30 - 05:00 0.50 DRILL P PROD1 Dnll to 12830' with 90L TF, 2.6/2.6bpm, 3300/3600psi & 75fph ave ROP. Seems to be drilling better. 05:00 - 05:30 0.50 DRILL P PROD 1 Orient & drill to 12872' with 90L TF. 2.6/2.6bpm, 3300/3600psi & 95fph ave ROP 05:30 - 06:20 0.83 DRILL P PROD1 Orient 2 clicks & drill to 12887' with 45L TF. 2.6/2.6bpm, 3300/3600psi & 55fph ave ROP, Wt stacking, 06:20 - 06:45 0.42 DRILL P PROD1 Orient 2 clicks & drilled to 12900', 2.6 I 2.6 bpm, 3400 psi. TF = 5L 06:45 - 07:30 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH to TD. 07:30 - 08:00 0.50 DRILL P PROD1 Drilling. TF = 10L. 2.6 I 2,6 bpm. 3400 psi. 60 fph. Drilled to 12,925 ft. 08:00 - 08: 15 0.25 DRILL P PROD1 Orient around. 08: 15 - 10: 15 2.00 DRILL P PROD 1 Drilling. TF = 10L, 2,6 1 2,6 bpm. 3400 psi, Stacking wt, Ip Drilled to 12970 ft. 10:15 - 12:30 2.25 DRILL PROD1 Drilling. TF = 10L, 2.6 1 2,6 bpm. 3400 psi, Swap to new FloPro. Landed well at 12,980 ft, 8673 ft TVDSS. Drilled to 13,043 ft. 12:30 - 13:00 0.50 DRILL P PROD1 Drilling. TF = 2R. 2.6 1 2.6 bpm, 3300 psi. Drilled to 13.075 ft. 13:00 - 13:45 0.75 DRILL P PROD 1 Wiper trip to window. Clean hole. RIH. 13:45 -16:30 2.75 DRILL P PROD 1 Drilling, TF = 40R-120R. 2,6/2.6 bpm. 3300 psi. 100 fph, Drilled to 13,250 ft, Ip Finally drilling in 50-60 API sand. 16:30 - 17:30 1.00 DRILL PROD1 Wiper trip to window, Clean hole, RIH. 17:30 - 18:30 1.00 DRILL P PROD1 Drilling. TF = 95R. 2.6/2.6 bpm, 3400 psi, 80 fph, Drilled to 13,315ft. 18:30 - 18:45 0.25 DRILL P PROD1 Orient TF to 60R. 18:45 - 19:05 0.33 DRILL P PROD1 Drill to 13335' with 50R TF, 2.6/2.6bpm, 3300/3550psi & 60fph ave ROP, 19:05 - 19:20 0.25 DRILL P PROD 1 Orient 2 clicks & drill to 13358' with 90R TF, 2.6/2.6bpm, 3300/3700psi & 92fph ave ROP. 19'20 - 19:50 0 50 DRILL P PROD1 Drill to 13400' with 90R TF, 2.6/2.6bpm, 3300/3700psi & 84fph ave ROP Geologist wants to undulate through the cleaner upper half of Zone 1A. 19:50 - 20:20 0.50 DRILL P PROD1 Wiper tnp to window. Hole clean 20:20 - 21 :00 0.67 DRILL P PROD1 Log & tie-into RA PIP tag (+21' correction) 21 :00 - 21 :30 0.50 DRILL P PROD1 RBIH smoothly to btm. 21.30 - 22'00 0 50 DRILL P PROD 1 Onent TF to HS. 22.00 - 22.20 0.33 DRILL P PROD1 Drill to 13447' with HS TF. 2.6/2.6bpm, 3300/3550psi & 80fph ave ROP. 22'20 - 23.20 1 00 DRILL P PROD 1 Onent & drill to 13504' with 90R TF, 2 6/2.6bpm, 3200/3500psi & 82fph ave ROP. 23 20 - 23 30 0 17 DRILL P PROD 1 Orient TF to LS 23'30 - 00:00 0 50 DRILL P PROD 1 Drill to 13535' with LS TF. 2.6/2.6bpm, 3300/3550psi & 90fph ave ROP. Pr,nlea 3/18/2002 1 ~8 ~3 PM BP EXPLORATION Page 5 of 8 Operations Summary Report Legal Well Name: 1 8-1 0 Common Well Name: 18-10B Spud Date: 3/7/2002 Event Name: REENTER+COMPLETE Start: 3/7/2002 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 3/11/2002 00:00 - 00:10 0.17 DRILL P PROD1 Continue drilling to 13550' with LS TF, 2.6/2.6bpm, 3300/3550psi & 90fph ave ROP. 00: 1 0 - 00:45 0.58 DRILL P PROD1 Wiper trip to window. Hole clean, 00:45 - 01 :00 0.25 DRILL P PROD 1 Log & tie-into RA PIP tag (+6' correction) 01 :00 - 01 :30 0,50 DRILL P PROD1 RBIH. Set down in shale @ 12685'. Work thru, RIH to TD. 01 :30 - 01 :50 0,33 DRILL P PROD1 Orient TF to 90R. 01 :50 - 02:00 0.17 DRILL P PROD1 Drill to 13561' @ 90R TF, 2,6/2.6bpm, 3200/3450psi & 66fph ave ROP, 02:00 - 02: 1 0 0,17 DRILL P PROD1 Orient 1 click & drill to 13578' @ 100R TF. 2,6/2,6bpm. 3200/3450psi & 102fph ave ROP. 02: 1 0 - 02:50 0,67 DRILL P PROD1 Orient & geodrill to 13607' @ 100R TF, 2.6/2.6bpm, 3200/3450psi & 116fph ave ROP. Break into clean (27api) sand @13545' (8650ftvd), Suspect Zone 1 B, 02:50 - 03:00 0.17 DRILL P PROD 1 Drill to 13620' @ 100R TF, 2.6/2.6bpm, 3200/3450psi & 78fph ave ROP. Geologist wants 86 degs incl to re-enter Zone 1A, 03:00 - 03:05 0.08 DRILL P PROD1 Orient TF to 160R. 03:05 - 03 25 0.33 DRILL P PROD1 Drill to 13651' @ 160R TF, 2,6/2.6bpm, 3200/3450psi & 93fph ave ROP. Re-entered Zone-1 A @ 13635'. 03:25 - 03:35 0.17 DRILL P PROO1 Orient TF to 1 OOR. 03:35 - 04:05 0.50 DRILL P PROD 1 Drill to 13682' @ 85R TF, 2,6/2.6bpm, 3200/3450psi & 62fph ave ROP. 04:05 - 04:20 0.25 DRILL P PROD 1 Drill to 13700' @ 90R TF, 2,6/2,6bpm, 3200/3450psi & 72fph ave ROP. 04:20 - 05:35 1.25 DRILL P PROD 1 Wiper trip to window. Hole clean. 05:35 - 05:50 0.25 DRILL P PROD1 Drill to 13719' @ 90R TF, 2.6/2.6bpm, 3200/3450psi & 70fph ave ROP. 05:50 - 06:00 0.17 DRILL P PROD1 Orient TF to HS. 06:00 - 06:20 0.33 DRILL P PRODl Drill to 13750' @ HS TF, 2.6/2.6bpm, 3200/3650psi & 120fph ave ROP. 06:20 - 06:25 0.08 DRILL P PROD1 Orient TF to 90R. 06:25 - 07:30 1.08 DRILL P PROD1 Drill to 13,850 ft, 90R TF. 2.6/2.6 bpm, 3300 psi. 100 fph. 07:30 - 08:30 1.00 DRILL P PROD1 Wiper trip to window. 08:30 - 08:45 0.25 DRILL P PROD 1 Tied-in with RA tag, Added 14 ft CTD. 08:45 - 09:30 0.75 DRILL P PROD1 Wiper trip back to TD. Clean hole. 09:30 - 09:45 0.25 DRILL P PROD1 Orient TF to 40R. 09:45 - 11 :50 2.08 DRILL P PROD1 Drilling, TF = 40-90R. 2.6/2.6 bpm, 3400 psi, ROP = 110 fph. Stacking wt. Drilled to 13,980'. 11 50 - 13'40 1.83 DRILL P PROD1 Wiper trip to window. Clean hole. RIH to TD. 13.40-16'00 2.33 DRILL P PROD 1 Drilling, TF = 11 OR. 2.6/2.6 bpm, 3400 psi, ROP = 80 fph, Stacking wt. Drilled to TD of 14,100 ft. 16 00 - 17.00 1.00 DRILL P PROD1 Wiper tnp to window. Clean hole 17:00-17.30 0.50 DRILL P PROD 1 Log tie-In with RA tag at 12,226 ft. Added 17ft to CTD. 17:30 - 18'30 1.00 DRILL P PROD 1 RBIH & tag TD @ 14107' (8645.41ftvd) -final TD. 18.30-21:20 2.83 DRILL P PROD1 POOH laying in new FloPro in open hole. Paint EOP flag @ 10000'. Meanwhile strap & prep the 2-7/8" perforated ST-L liner & tubulators. 21 20 - 22.30 1 17 DRILL P PROD 1 PJSM. UD dnlllng BHA#3. 22 30 - 23:30 1,00 CASE P COMP I R/U to run Bonzai completion liner. 23:30 - 00.00 0.50 CASE P COMP Safety mtg reo liner. 3/12/2002 0000 - 03:00 300 CASE P COMP M/U 36 jts 2-7/8" 6 16# L-80 STL perf Inr w/guide shoe & turbos, 1 jt 2-ì/8 6 16# L-80 STL solid Inr, dlverter collar & perf Pr,ntea 3/1812002 '46 4j PM BP EXPLORATION Operations Summary Report Page 6 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-1 0 18-10B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 S ta rt: Rig Release: Rig Number: 3/7/2002 Spud Date: 3/7/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 3/12/2002 00:00 - 03:00 3,00 CASE P COMP 4' pup/jt. float collar. 10' pup/jt & latch collar, 19 jts 2-7/8" 6.16# L-80 STL solid Inr & turbos Xlover to 8 jts 3-3/16" 6.2# L-80 TClllnr. 03:00 - 04: 15 1.25 CASE P COMP MU "XN" Nipple, Baker Deployment Sub & CTLRT. Install Baker CTC. Pull test to 35k & pressure test to 3500 psi - OK. 04: 15 - 07:00 2,75 CASE P COMP RIH with liner on CT. See flag at 12148', Correct to 12111'. P/U 36k, RIH thru window & set down in shale @ 12310'. Work thru. Continue RIH with slight bobbles to TD tagged @ 14088' CTD. P/U @ 41 k & retag TD @ same depth. Liner at TD & set down 10k Ibs down on CTLRT. 07:00 - 07:45 0.75 CASE P COMP Circ. 5/8" steel ball to release from liner. Ball on seat at 44 bbls, Released at 4200 psi. Pick up liner free at 32K, Sat dwn wt. 07'45 - 09:30 1.75 CASE P COMP Circ. well to 2% KCL water. Recover FloPro and return to MI to recondition, 2.6 1 2.6 bpm. 1600 psi. Rig up DS cementers. Batch mix cement. At wt at 0900 09:30 - 09:45 0.25 CEMT P COMP SAFETY MEETING. Review cementing procedure and hazards with crew. 09:45 - 11: 1 0 1.42 CEMT P COMP Press test cement line. Pump 5 bbls water. Stage 7.5 bbls. 15.8 ppg G CMT. Stop pump. Clean lines. Insert dart. Displace Dart with 1 bbl. Check, dart gone. displace with 10 bbls Biozan and KCL water. 3,0 I 3.0 bpm. 1800 psi. Dart on wiper plug at 58.7 bbls, sheared at 3000 psi, Wiper plug landed at 64.2 bbls. held 1500 psi steady. Floats holding. Stung out of top of liner and circ, at liner top. CMT job went very well. Full returns. 11: 10- 13:30 2.33 CEMT P COMP POOH. 1.8 bpm, 450 psi. Full returns. 13:30 - 14.00 0.50 CEMT P COMP LlO BKR CTLRT BHA. 14:00-14:15 0.25 CEMT P COMP SAFETY MEETING. Review procedure and hazards of running CSH workstring, 14:15-14:45 0.50 CEMT P COMP M/U 2,30" diamond parabolic mill. 2.125 motor, circ sub, hyd discon, 2.125 upldwn jars, check valves, XO. 14:45 - 16:45 2.00 CEMT P COMP Pick up 72 Jts. CSH workstring. 16:45 - 17: 15 0.50 CEMT P COMP M/U BKR hyd discon, non-rot jt, CTC. BHA = 2334 ft. 17:15-18:50 1.58 CEMT P COMP RIH with milling BHA #4. 0.5 bpm, 380 psi. 18:50 - 21 :00 2.17 CEMT P COMP Stop at 11900', make -34' correction. Standby on cement. 21 : 00 - 2 1 : 50 0.83 CEMT P COMP HSE Safety stand down. Discuss YTD HSE statistics with both Nordic and SWS oncoming crews. 21'50 - 22'20 0.50 CEMT P COMP Checked with SWS lab, cement compressive strength at 2030 psi at 20:50 PM. Make PT of liner lap cement. Brought pressure up to 2200 psi on WH, bleed off to 1200 psi in 3 minutes Kicked pumps back on, ablt to inject KCL Into formation at 1800 psi WHP and 0.5 bpm. The more we pump, the better the Injectlvlty gets SI pumping Liner lap appears to be leaking. 22.20 - 22.40 0.33 CEMT P COMP RIH to mill cement. Weight check 32klbs at 12700'. 22.40 - 00 00 1.33 CEMT P COMP Tag up at 12853', PU at 31klbs. Kick on pumps, 1.7/1 7/2000 pSI free Spin. Begin milling Start milling at 12849.8' (COIl stretch). Pumping 40 bbls KCL. 10 bbls gel sweep, alternating. Made it to 12852,9' at midnight 3/13/2002 00,00 - 01 40 1 67 CEMT P COMP 12852 9', Continue milling operations Seeing drilling breaks corresponding to float eq spacing. Depth shift to correct to Pr,ntea 3/18/;;'002 1 4843 PM BP EXPLORATION Operations Summary Report Page 7 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-1 0 18-10B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 3/7/2002 Spud Date: 3/7/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 3/13/2002 00:00 - 01 :40 1.67 CEMT P COMP liner tally is +29.8'. We will not make a correction at this point. Continue milling, pumping 40 bbls of KCL and 10 bbls of gel sweep. 01 :40 - 01:45 0.08 CEMT P COMP 12867', broke through the baffle plate. No cement encountered below. Depth shift a consistent +30' throughout milling of divert/float eq. Continue RIH, tag up at 12897', with depth correction this is consistent with top of the first open predrilled joint. 01:45 - 02:45 1.00 CEMT P COMP Mill cement In liner fr/12897'-12950', Mill stringers below this, ROP improved the deeper we got. Last stringer at 13020'. Continue RIH, Pumping sweeps every 40 bbls. 02:45 - 03: 15 0,50 CEMT P COMP 13500', Pump 30 bbl of 2# biozan sweep. followed by 10 bbl spacer of used KCL, followed by 100 bbls of fresh 2% KCL. Continue RIH. No additional cement observed in liner below 13020'. 03:15 - 03:50 0.58 CEMT P COMP Made it to bottom. Tagged up at 14074', which is consistent with the 30' correction that we needed to be on depth at float eq. Circulate bio sweep to bit. 03:50 - 04:40 0.83 CEMT P COMP Circulate clean KCL out of bit, POOH, circulating at 1.6 bpm, POOH at 60 fpm. Leave slotted liner with clean 2% KCL inside. 04:40 - 06:45 2.08 CEMT P COMP POOH with milling BHA, 06:45 - 07:00 0 25 CEMT P COMP SAFETY MEETING. Review procedure and hazards of standing back CSH workstring. 07:00 - 08:30 1.50 CEMT P COMP Standback 37 stands of CSH workstring. 08:30 - 08:45 0.25 CEMT P COMP UO milling BHA. Mill in gauge, 50% wear In center. 08:45 - 09:00 0,25 CEMT P COMP SAFETY MEETING. Review procedure and hazards for M/U of Baker Liner top Pkr 09:00 - 09:45 0.75 CEMT P COMP M/U Baker seal Assy, KB Packer, running tool, hyd discon,1 jt 2-3/16, CV, CTC. Total length = 50.54 ft. 09:45 - 12:20 2.58 CEMT P COMP RIH with Baker 4.5" KB Liner Top Packer BHA. RIH at 80 fpm, 0.2 bpm. 12:20 - 14:15 1.92 CEMT P COMP Up wt at 11900 ft = 37K, Dwn wt, = 14K. Stung Seal Assy into deployment sleeve at 12022' CTD, Set down 10K at 12029.3' CTD, Sting out with seal assy. and pump 5/8" AL Ball. Circ. 2 bpm, 800 psi. Ball on seat at 52.9 bbls. RIH. Set down 10K at 12029.3' CTD. Pick up 1.9 ft off bottom. Set slips with 2500 PSI. Pull 5K over to energize element. Stack 10K at 12027.4 ft. Seal Assy 1.9 ft off landing profile. Press test packer with 2200 psi for 30min. Good test. Lost 15 psi In 30 min 14: 1 5 - 1 5: 30 1 25 CEMT P COMP Press up to 3400 pSI and release from KB Packer. POOH with running tools. Top of 4-1/2" KB Packer at 11,997.4 ft BKB. Clean rig pitS while POOH. 15:30 - 16.00 0.50 DEMOB P COMP Freeze protect 4-1/2" tubing with MEOH from 2000 ft to surface 16'00-16:30 0 50 CEMT P COMP UO Baker BHA 16'30 - 19.00 2 50 RIGD N WAIT POST Wait on DS Nitrogen pumper Last minute engine problems 19'00 - 19'40 0.67 RIGD P POST Safety meeting prior to blowing down cOil with N2. 19:40 - 21 :00 1.33 RIGD P POST PT hardlines to 3000 psi, Blow down cOil with N2 21.00 - 22,00 1 00 RIGD P POST CTP bled down to 0 psi, Pop off injector, stand back same Pr,nlsa 3/18/2002 146 4j PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/13/2002 18-1 0 18-10B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT Phase 21 :00 - 22:00 1.00 RIGD P POST 22:00 - 23:00 1.00 DEMOB P POST 23:00 - 00:00 1.00 DEMOB P POST Page 8 of 8 Start: Rig Release: Rig Number: Spud Date: 3/7/2002 End: 3/7/2002 Description of Operations Begin rig down stack. prepare to move off well. Begin movement of rig camp and flatbed trailor to C-28. Continue rigging down BOP stack in prepartation of rig move. Release rig at 23:00, BOP stack rigged down. tree cap on and tested, Continue prep to move rig from DS 18 to C pad in the WOA. Pr,nteo 3/18/2002 14843 PM AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 18-108 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,191.00' MD Window / Kickoff Survey 12,216.00' MD (if applicable) Projected Survey: 14,107.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachmentts) é) Cb>- °35 19-Mar-02 RECEIVED t.1 ~ ~ .'") C ~{)O2 I ,("\, \ L --\.! Alaska Oil & Gas Cons. Commission Anchorage DEFINITIVE North Slope Alaska BPXA PBU_EOA DS 18, Slot 18-10 18-10B Job No. AKMW22044, Surveyed: 11 March, 2002 SURVEY REPORT 19 March, 2002 Your Ref: API 5002920818 Surface Coordinates: 5961488.32 N, 691373.25 E (700 17' 57.6753" H, 148026' 59.9899" W) Kelly Bushing: 45.03ft above Mean Sea Level 5pa.,..,y-sur-, CAILL'NG SEAVlc:es A Halliburton Company Survey Ref: svy11149 Sperry-Sun Drilling Services . Survey Report for 18-108 DEF'N Your Ref: AP/5002920818 TIVE Job No. AKMW22044, Surveyed: 11 March, 2002 BPXA North Slope Alaska PBU - EOA DS 18 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12191.00 61 500 326.100 8538.27 8583.30 4464,74 N 6155.24 W 5965794.86 N 685106.30 E 2595.1 7 Tre On Point 12216,00 60 730 326 200 8550.34 8595.37 4482.92 N 6167.43 W 5965812,72 N 685093.65 E 3.100 2609.29 Window Pornl 12239 42 63 630 327.330 8561.27 8606,30 4500.25 N 6178,78 W 5965829.75 N 685081.87 E 13 097 2622.81 12254 23 65 040 328.660 8567.69 8612,72 4511.57 N 6185,85 W 5965840.89 N 685074,51 E 12496 2631 74 12286 39 68.820 329 060 8580.29 8625.32 4536.89 N 6201.15 W 5965865,81 N 685058.57 E 11.809 2651 87 12314.34 71810 330,460 8589 70 8634.73 4559.62 N 6214.40 W 5965888.20 N 685044,75 E 11 691 267007 12357.92 74 970 333 630 8602 16 8647. 19 4596.50 N 6233.96 W 5965924.57 N 685024,25 E 10.057 2700 13 1 2411. 77 77.520 341 010 8614 98 8660,01 4644,73 N 6254.10 W 5965972.27 N 685002.89 E 14.127 274094 12462 86 79 :l60 345,580 8625.22 8670,25 4692,66 N 6268.4 7 W 5966019.82 N 684987.30 E 9.474 2783 05 12502 77 80 770 350.150 8632.11 8677.14 4731.08 N 6276.73 W 5966058.02 N 684978.07 E 11.819 281 7 70 12553.78 81 030 354.550 8640.18 8685.21 4780.99 N 6283.43 W 5966107.74 N 684970,1 ° E 8.532 2863.83 12584 20 80 680 356.480 8645.02 8690,05 4810,93 N 6285.78 W 5966137.61 N 684966,99 E 6.369 2891.96 1261894 83 060 0.870 8649.93 8694.96 4845.30 N 6286.57 W 5966171,94 N 684965,32 E 14.262 2924.78 12654.58 84 020 4.920 8653.94 8698.97 4880.66 N 6284.78 W 5966207.34 N 684966.21 E 11.608 2959 27 12694 11 84 81 0 8.260 8657.79 8702.82 4919.73 N 6280,27 W 5966246.52 N 684969.73 E 8.643 2998 08 12732.29 85 1 70 11 .600 8661 . 1 3 8706,16 4957.19 N 6273.71 W 5966284.13 N 684975.33 E 8765 3035,89 12774,02 87010 14.580 8663.97 8709,00 4997,74 N 6264.28 W 5966324.90 N 684983.72 E 8.378 3077.46 12803 34 88,070 15 640 8665.23 8710.26 5026.02 N 6256.65 W 5966353.37 N 684990,63 E 5 110 3106,75 12840 47 86 1 30 11 770 8667.11 8712,14 5062.03 N 6247.86 W 5966389.60 N 684998,50 E 11.647 3143.80 12875 38 85870 8080 8669.55 8714,58 5096,33 N 6241.86 W 5966424.04 N 685003,63 E 10.571 317842 1289959 88 330 8.960 8670.77 8715.80 5120.24 N 6238.28 W 5966448.03 N 685006.60 E 10.790 3202.39 12941 .95 87 800 5970 8672.20 8717,23 5162.21 N 6232.78 W 5966490.13 N 685011,03 E 7165 3244 25 1 2977 14 89 300 358 940 8673 10 8718,13 5197.34 N 6231.27 W 5966525,28 N 685011.64 E 20 420 3278 43 13007,67 91 670 355 780 8672.84 8717,87 5227.83 N 6232.68 W 5966555.72 N 685009.45 E 12 937 3307 35 13039.97 91410 350 330 8671.97 8717.00 5259.87 N 6236.58 W 5966587.65 N 685004.74 E 16 886 333707 1 3092 44 97.210 350 1 50 8668.03 8713,06 5311.41 N 6245.45 W 5966638.95 N 684994,56 E 11.059 3384 1 8 13121 99 96 420 353 320 8664.52 8709.55 5340.44 N 6249.66 W 5966667.87 N 684989.61 E 10.982 341092 1 31 56 39 92.810 355 780 8661.75 8706.78 5374,57 N 6252.92 W 5966701.90 N 684985,49 E 1 2 685 3442 83 1318794 91 850 357 890 8660.4 7 8705.50 5406,04 N 6254,66 W 5966733.32 N 684982,94 E 7.342 3472,60 1.3224 12 90 440 1 050 8659.75 8704.78 5442,21 N 6254.99 W 5966769.47 N 684981,69 E 9.562 3507.28 - ---------------- 19 March. 2002 - 14:06 Page 2 0'4 DrillQ/lest 2.00,08.005 s¡iérry-Sun Drilling Servicës' it Survey Report for 18.10B Your Ref: API 5002920818 Job No. AKMW22044, Surveyed: 11 March, 2002 BPXA North Slope Alaska PBU - EOA DS 18 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlng. Northing. Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 13275 22 89.030 4.210 8659.98 8705,01 5493.25 N 6252.65 W 5966820.55 N 684982.73 E 6.771 3556 98 13303.32 88 680 6.320 8660.54 8705.57 5521.22 N 6250.07 W 5966848.58 N 684984,60 E 7.610 3584.58 13331 .98 90 090 8.430 8660.85 8705.88 5549.64 N 6246.39 W 5966877.08 N 684987,55 E 8854 3612.92 13360.95 90 790 10.540 8660.63 8705.66 5578.21 N 6241.62 W 5966905.76 N 684991.60 E 7.673 3641.70 13411 97 90 970 14.580 8659.84 8704.87 5627.99 N 6230,53 W 5966955.81 N 685001.41 E 7925 3692 61 1344331 94 1 30 14 230 8658.45 8703.48 5658.31 N 6222,74 W 5966986.32 N 685008.43 E 10.144 372390 1347679 94 660 15.460 8655,88 8700.91 5690.58 N 6214,19 W 5967018.80 N 685016.16 E 3.990 3757.27 13509 27 93.870 20.030 8653.4 7 8698.50 5721.42 N 6204,32 W 5967049.88 N 685025.24 E 14.240 3789 64 1357517 90 530 23.020 8650.94 8695.97 5782.66 N 6180.16 W 5967111.72 N 685047,83 E 6.800 3855 1 7 1361194 89.650 29.000 8650.88 8695,91 5815.69 N 6164.04 W 5967145.15 N 685063,10 E 16.438 3891.36 13656.37 85 340 27.420 8652.82 8697.85 5854.80 N 6143.07 W 5967184.77 N 685083,07 E 10,330 3934.73 13691.95 85 600 30.230 8655,63 8700,66 5885.87 N 6125.97 W 5967216.27 N 685099.37 E 7,907 3969 31 1372301 86 220 32.510 8657.85 8702.88 5912.32 N 6109.84 W 5967243,12 N 685114.82 E 7.589 3999 19 13751.97 88 1 50 30.580 8659.27 8704,30 5936.97 N 6094.71 W 5967268.15 N 685129.32 E 9.419 4027.05 13785,03 87.800 36.210 8660.44 8705.47 5964.54 N 6076.53 W 5967296,17 N 685146.79 E 17.052 405857 13827.77 91.320 40.250 8660.77 8705.80 5998.10 N 6050.09 W 5967330.40 N 685172,36 E 12.536 4098 11 13850.22 92 110 42.180 8660.10 8705,13 6014.98 N 6035,31 W 596734 7 .65 N 685186,71 E 9.286 411841 1 3881 .70 92 020 41.830 8658.96 8703,99 6038.36 N 6014.26 W 5967371,55 N 685207,17 E 1 147 414669 1391524 91 850 42.180 8657.83 8702.86 6063,27 N 5991.82 W 5967397.03 N 685228,96 E 1.160 4176.81 13953.44 95.270 41.480 8655.46 8700.49 6091.67 N 5966.40 W 5967426.07 N 685253,65 E 9.138 4211 13 13979.64 95.620 45.350 8652.97 8698.00 6110.61 N 5948.48 W 5967445.46 N 685271,08 E 14.765 4234 27 14012.20 95.540 50,800 8649,80 8694,83 6132.26 N 5924.38 W 5967467.71 N 685294.62 E 16,661 4261 72 1404499 R3 080 51 850 8647.34 8692,37 6152.69 N 5898.85 W 5967488.78 N 685319.62 E 8 153 428R 40 1407579 91.320 52.910 8646.16 8691,19 6171.47 N 5874.48 W 5967508,18 N 685343,51 E 6.669 431318 1410700 9 1 320 52,910 8645.44 8690.4 7 6190,29 N 5849.59 W 5967527.63 N 685367,91 E 0.000 4338 12 Projected Survey --------------------- - - --- 19 March, 2002 - 14:06 Page 3 of4 DrillQuest 2,00,08.005 Sperry-Sun Drilling Services Survey Report for 18-10B Your Ref: API 5002920818 Job No. AKMW22044, Surveyed: 11 March, 2002 . North Slope Alaska BPXA PBU EOA DS 18 All data is in Feet (US) unless otherwise stated, Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26,533" (08-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 16.0000 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14107.00ft., The Bottom Hole Displacement is 8516,89ft., in lhe Direction of 316.6210 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12191.00 12216.00 14107.00 8583.30 8595.37 8690.4 7 4464.74 N 4482.92 N 6190.29 N 6155.24 W 6167.43 W 5849.59 W Tie On Point Window Point Projected Survey Survey tool program for 18-10B From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 000 0.00 14107.00 8690.47 MWD Magnetic (18-108) - - ----- -- ---- - - 19 March, 2002 - 14:06 Page 4 of 4 DrillQuest 2,00,08,005 ~~~~E :F !Æ~fÆ2Æ~~fÆ ALASIiA OIL AND GAS CONSERVATION COMMISSION I I /' / / / TONY KNOWLES, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 18-10B BP Exploration (Alaska), Inc. Penn it No: 202-035 Sur Loc: 4907' NSL, 371' WEL, Sec. 24, Tll N, R14E, UM Btmhole Loc. 517' NSL, 1028' WEL, Sec. 11, TIIN, R14E, OM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redri II does not exempt you from obtaining additional pemlits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit 18-10B. Blo\vout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (I. .1 I L'" - J..r-/ l)" .f 1'l.A\,t.-/'{ tY -u t Lj' ~ ~ 6 ~ Cammy Cfechsli Taylor Chair BY ORDER OF THE COMJ\lDSSION DA TED thisJJ1i day of Month, 2002 jjcÆnc losures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASKA STATE OF ALASKA ,~AND GAS CONSERVATION COMt\ PERMIT TO DRILL 20 AAC 25.005 piON ~J6A '-IIS/oL h- ;).{ C5 j/lq I (I/'::J}u l. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4907' NSL, 371' WEL, SEC. 24, T11N, R14E, UM At top of productive interval 3702' NSL, 1013' WEL, SEC. 14, T11N, R14E, UM At total depth 517' NSL, 1028' WEL, SEC. 11, T11 N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028307,517' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 12580' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casino Weiqht Grade Couplinq Lenqth 3-3/4" 3-1/2" x 3.3'16" 8.81#)(6.2" L-80 ST-L 1560' 1b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas B"Single Zoneß~ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 45.03' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool OZ~;D~ ADL 028302 ..61.::> 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 18-10B 9. Approximate spud date 03/10/02 ./ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14100' M D I 8649' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 960 Maximum surface 2280 psig, At total depth (TVD) 8800' I 3337 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD TVD./ (include staqe data) 12540' 8673' 14100' 8649' 67 cu ft Class 'G' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 x 2-718" X 6.16# RF~FIVFn 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 13780 feet 8718 feet 13729 feet 8718 feet Length Plugs (measured) FEB 1 4 2002 Junk (measured) Alaska Oil & Gas Cons. Commission An~ Size Cemented MD TVD 79' 20" 2534' 13-3/8" 1 0800' 9-5/8" 1866' 7" 1474' 4-1/2" 1975# Poleset 2120 sx Fondu, 400 sx PF 'C' 500 sx 'G', 51 bbls PF 'C' 350 sx Class 'G' 200 sx Class 'G' 79' 2534' 10800' 10648' - 12514' 12301' - 13775' 79' 2534' 7762' 7658' - 8709' 8638' - 8718' Perforation depth: measured 12630' - 12700', 12780' - 12810',12865' - 12950', 12970' - 13060',13080' - 13280', 13305' - 13717' true vertical 8727' - 8730',8729' - 8728',8728' - 8729',8730' - 8732',8732' - 8725', 8725' - 8719' 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contacr Engineer Name,'Number: Ted Stagg. 564-4694 21. I hereby certify that the f~g~9,iS true and correct to the best of my knowledge Signed Ted Stagg ....J!-({~, J¿";1/ Title CT Drilling Engineer V / Commission Use Only Permit Number API Number A~oval.Q'1~ See cover letter '2..D'Z. ,- () 35 50- 029-20818-02 ~ }V¡ U?- for other requirements Conditions of Approval: Samples Required 0 Ves BNo Mud Log Recuired 0 Yes liI No Hydrogen Sulfide Measures rg¡ Yes 0 No Directional Survey Required 161 Yes 0 No Required Working Pressure for BOPE D2K 0 3K D4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other:oTg1n¡¡tsig~~~E fc ~ÇCC f~/. \t4(jlt J . by order of "Î () . Approved By Cammy Oechsh r- C?~~iSS!One~ "the commission Date I'" f "1, ().~ Form 10-401 Rev. 12-01-85 (, I :' !: ( I, t ", ~ i\ L Sub It In TrnlicMe J \.J ('" \ t.J \ \ \' !~:.;\ Prepared By Name/Number: Date c+¡, 3ß ¿.. BP DS 18-10b CTD Sidetrack Summary of Operations: /./ A CTD through tubing sidetrack is planned for DS 18-1 Oa. The coil sidetrack, 18-10b, will exit the 4 1/2" liner in the Ivishak Zone 1 B formation and target Zone 1 A/1 B. /' Existing Zone 1 A/1 B perfs will be isolated with the cast iron packer used as a base for the whipstock tray. A whipstock tray will be installed into the packer after pressure testing to 2000 psi."'Window milling will be done by drilling coil. One small fault will be crossed near the heel of the 18-1 Ob sidetrack but lost circulation is not expected. DS18-10b will be completed with a fully cemented 33/16" x 2 7/8" liner. The top of the cemented liner will be placed approx. 40 ft above the window in Zone 1. A liner top packer is planned as a lap seal from primary cement is unlikely with the 40 ft lap. The liner lap is limited to 40"feet to leave room for a future coil sidetrack that would be initiated through the single string of 4 Y2" between 12,514' and the 18-1 Ob liner top at 12,540'. Phase 1: Prep work. Planned for Feb. 25 to March 8. ~/ 1. Service coil to set a whipstock packer/bridge plug at 12,596 and test to 2000 psi. 2. Service coil to install whipstock tray. Phase 2: Mill window, Drill and Complete sidetrack: Planned for March 10,2002. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Maximum hole angle will be 96 degrees. ~ Mud Program: . Phase 1 &2: Seawater . Phase 3: Mill with seawater/biozan, drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: ./ . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: The production liner will be a 3 Y2" ST-L x 3 3/16" TC II x 2 7/8" ST-L solid liner from TD to approx. 12,540'MD (8670'ss). The X-O between 3 3/16" x 2 7/8" wi~be at 12,640' MD (8683'ss). Only the top joint will be 3 Y2". Liner cement volume will a minimum of 12 bbls. ;",{ ~,~ Well Control: . BOP diagram is attached. ./ . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 96 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 all of the open hole section. Memory CNL will be run inside the liner. Hazards . ./ DS 18 has no production with H2S in excess of 100 ppm. The closest wells to 18-10 have measured H2S readings of 16 ppm and 10 ppm. May lose circulation if the frac wing from 18-10a is drilled into. . . If Kavik is penetrated while drilling Z1 A then a plug back may be required. Reservoir Pressure Res. press. is estimated to be 3337 psi at 8800'ss (7.3 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2280 psi. ./ TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MO = DatumTVD= 6" McEVOY McEVOY AXELSON 46' NA 1950' 93 @ 13101' 13043' 8688' SS 18-108 Proposed CTO Sidetrac ( SAF ), NOTES: WELL ANGLE> 70 DEG @ 12379' & > 90 L @ 12729'. 13-3/8" CSG. 72#, L-80. ID = 12.347"1-i 2534' ~ Minimum 10 = 3.725" @ 1207311 4-1/2" HES XN NIPPLE I TOP OF 7" BKR TIEBK SL V. ID = 7,50" l-i 10649' I l I 9-5/8" X 7" BKR H PKR. ID = 6.188" 1--1 10660' I --9 I 9-5/8" X 7" BKR HMC HGR. ID = 6184" l-i 10665' ¡-----.. 9-5/8" CSG, 47#, ID = 8.681" l-i 10800' I I 4-112" TBG.12,6#, L-80, .0152 bpf, ID = 3.958" l-i 12050' I I 4-1/2" TIP, 12.6#, L-80. .0152 bpf. ID = 3.958" l-i 12095' I I TOPOFBKRTIEBACKSLV.ID=5.250" l-i 12301' I I 7" X 4-12" BKR HYFLO HGR. ID = 4.375" l-i 12314' I DATE 10/24/82 07/01/95 01/09/01 02/01/01 10/20/01 18-10A ÆRFORATION SUMMARY REF LOG: TCP ÆRF REF TO PBTD @ 13729' ANGLE AT TOP PERF: 85 @ 12630' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 12630 - 12700 P&A proposed 2-3/4" 4 12780 - 12810 P&A proposed 2-3/4" 4 12865 - 12950 P&A proposed 2-3/4" 4 12970 - 13060 P&A proposed 2-3/4" 4 13080 - 13280 P&A proposed 2-3/4" 4 13305 - 13717 P&A proposed I I :8: :8: I I , L ~ 0 L J /' ~ 27' 1-i5-1/2" X 4-1/2" HGR XO, ID = 3.958"1 2207' 1- 4-1/2" CAMCO TRCF-4A TRSSSV WI CURVED FLAPÆR, ID = 3,812" ~ ST MD TVD 1 3612 3309 2 7089 5497 3 9647 7015 4 10610 7632 J ~ GAS LIFT MANDRELS DEV lYPE VLV L TCH 52 CA-MMG DOME RK 51 CA-MMG DOME RK 52 CA-MMG DV RK 48 CA-MMG S/O RK PORT DATE 16 09/11/96 16 09/11/96 0 07/01/95 24 08/03/97 9-5/8" SIDETRACK WINDOW 10800' - 10850' (SECTION MILL) NOTE: PRE-SDTRK WELLBORE HAS BEEN P&A'DAND IS NOT SHOWN BELOW 9-5/8" MILLOUT WINDOW. I 12039' 1-i4-1/2" HES X NIP. ID = 3.813" I I 12050' I-iT' X 4-112" BKR S-3 PKR. ID = 3,875" I 12073' 1-i4-1/2" HES XN NIP, ID = 3.725" I 12096' 1-i4-1/2" WLEG. ID = 4.00" I I 12308' I-iT' X 4-1/2" BAKER H PKR. ID = 4.438" I 7" LNR SIDETRACK WINDOW 12514' - 12564' (SECTION MILL) 12540' 1-1 Top of 3-3/16" Liner I 7"LNR.29#, L-80, ID=6.184" 1--1 13120' ~ v" I 4-1/2" LNR. 12.6#, L-80, .0152 bpf, ID = 3.958" l-i COMMENTS 0 RIG INA L COMPLETION RIG SIDETRACK SIS-151 CONVERTED TO CANV AS SIS-LG REVISION CHlKA K CORRECTIONS DATE REV BY REV BY COMMENTS 1-i3-3/16"x 2-7/8" X-over 14100' 1--12-7/8" crnted and perf'ed liner ./ ') ~ 12580' I-iAnchor/Mechanical whipstock 13730' l-i PBTD Bkr insert LC PRUDHOE BA Y UNrr WELL: 18-10A ÆRMrr No: 195-0600 API No: 50-029-20818-01 370' SNL & 372' WEL, Sec 24, T11N, R14E BP Exploration (Alaska) ,,......... ~, ; bp -':¡;¡~~~ BP Amoco Baker Hughes INTEQ Planning Report lB.. BAKER HUGHES l~n':..Q I--~:i~~~)~:--~~::~~~~~~-- -- _U_--- ------ ----n ,----- ------ -- --------- __m ---- ------------ ----- - - ----------- ---- ------- -- U- ------ - -- ~~~e~ - ----- - --l Site: PB DS 18 I Well: 18-10 l~l'lIpa!.~~lan#2 !8-10B I Field: Prudhoe Bay North Slope UNITED STATES I\lap S)stem:US State Plane Coordinate System 1927 I\lap Zone: Alaska, Zone 4 Gl'O Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre S)!i Datum: Mean Sea Level Geomagnetic l\Iodel: BGGM2001 --- '--------------'-----.--'----------------'-----,------.--------- ---- --.----- -. - ----- --. -. .-- Date: 1/31/2002 Time: 09:39:30 Co-ordinate(NE) Reference: Well: 18-10, True North Vertical (T\'D) Reference: System: Mean Sea Level I Section (\'S) Reference: Well (O,OON,O.00E,16.00Azi) , ----- -- ------ ----- ---~~~'~)' Calculation J\I~ho~_--~i~~~~~_g~~tur~_______~b: O~~c_~~___1 ---- -- -----.- ------. ----- ---.------- --------- -----.----------- PB DS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: I' PO!iition Uncertaint): 0,00 ft Ground Level: 0,00 ft - ------ -------.-- Site: 5959213.15 ft 691583.44 ft Latitude: Longitude: North Reference: Grid COß\'ergl'nce: 70 17 35.252 N 148 26 55.555 W True 1.46 ~g--_. _. ------_: ----.-- ------ -.-- -'-------"----- - .. -- - -,- -- - --- ------------ _._-- ---- -- --- Well: Slot Name: 10 ---------1 18-10 18-1 0 Well Position: +N/-S 2280,04 ft Northing: 5961488.44 ft Latitude: 70 17 57.676 N _!Ositi~n~~~~tain_t),;E/~~15~:~_t_~~!itin~: 6913~3,28_f~____~:n~~tud~:__- ___1~~_~:___S9,~8~__~__- ------ - ---- J 1\';e"p~ih~Plan#218-ï-OB --------- - -- ----D~iïi~d- Fro';;~------ -18~1-ÕA- ------------------------ ---- 500292081802 Tie-on Depth: 12580.00 ft II Current Datum: 21: 105/31/199608:46 Height 45,03 ft Abo\l' S)stl'm Datum: Mean Sea Level l\Iagnetic Data: 1/31/2002 Declination: 26.57 deg Field Strength: 57514 nT !\lag Dip Angle: 80,83 deg '-l'rtical Section: Depth From (T\'D) +N/-S +E/-W Direction i I ft ft ----~- ----______deg_-- - _--n ----- -----------______1 ----=--==~O_~~-~=---=-~=-----~--- - --_O.O~---- 16,00 ----- ------- -------- ------------_J ---------- ------ --- ---------------- -------. -.---_ø.--.-- .,--.-----.- - --.- - ----.--------.---- I Plan: Plan #2 Identical to Lamar's Plan #2 Principal: Yes Date Composed: \' l'rsion: Tied-to: 1/31/2002 1 From: Definitive Path - -- - --____1 ---------.--------.--.---- --- - -. ------. __n- . --- -- -.- ----- ---.- -. -. - -.- .-..---- .-------.------- ---- ------- Targets 1------ --- ---- - ------ ,-- - ---- --- ---,----- ------------------- -- -- " - ... ---- - ---- - -- ------------- - ----------. --. - - -- . --- -- ...- .. . --- ---- Name Description TVD ft 8680,00 !\lap !\lap +N/-S +E/-W Northing Eastlng ft ft ft ft ----- 5222,01 -6217.58 5966550,12 685025,10 <-- Latitude ---> <--- Longitude --> : Deg I\lIn Sl'C Dl'g I\lIn Sl'C --.----- 0.00 0.00 0,00 0.00 0.00 6164.75 -5918.44 5967500,12 685300,12 70 18 58.284 N 4806.00 -6498,09 5966127.13 684755.29 70 18 44,916 N 4806.00 -6498,09 5966127,13 684755,29 70 18 44,916 N 6139.24 -6173.49 5967468.12 685045,81 70 18 58,031 N 6180.71 -5838.30 5967518.11 685379,82 70 18 58.441 N 4829.03 -6145.87 5966159.12 685106,79 70 18 45,145 N 70 18 49,009 N 148 30 1.370 W 148 29 52.665 W ' 18-10B T2.1 18-10B T2,2 8645.00 18-10B Polygon2.1 -Polygon 1 -Polygon 2 -Polygon 3 1___- __--~~~I~on ~--------- 148 30 9.543 W 148 30 9.543 W 148 30 0.106 W 148 29 50.327 W 148 29 59.269 W .- ------.---- --. - -.-.------ -- .-'----- --.------------ --.--.-- ---___.._0__- I --______1 Annotation 1- - - ~Ù) T"D i- ---~---_.._--~--- ----------- -- ------ ---- 1112575.00 8675.77 TIP ,12580.00 8676.48 KOP , 1259000 8677.77 1 I 12636.98 8680.50 2 '12886.98 8669.81 3 13113.49 8660.56 4 1341349 8670.10 5 1370709 8679.41 6 13830.12 867402 7 1410000 8649.15 TD ----------- -----.-.---- --.-- --..-. __0 --- ----- ------- - - ---I - --- --_u_- ------ ---------- -------- - ---- - - --- -- ---_oj , - - - - - ..- . ---- .- - - - -- ---. - --- --.---.--.- ----- - --- ------- - ----- - ------ -- l'~iI. BAKER HUGHES l~ fLQ BP Amoco Baker Hughes INTEQ Planning Report ..~..~~ , if ur:) 'JI~" ----------------- ----- --.--- --"_____n__- -------- .-------.-----.-- - ."---- ..-- ._--. 1- c~~~-~~)~:- BP Ä~-~~~--- -- _n------- -- -- --- - ---- -------- Field: Prudhoe Bay I Site: PB DS 18 Well: 18-10 ,-~~~~~-~~:__~~n!~~~1_~~___-------- ------- - ----------- -- .-- Plan Section Information Date: 1/31/2002 Time: 09:39:30 Co-ordinate(NE) Reference: Well: 18-10. True North Vertical (T\'D) Reference: System: Mean Sea Level Section (\'S) Reference: Well (0.00N,O.00E,16.00Azi) S~~e~~~~~~~~~!~on l\Iet~~~___~~~i~~~ ~u~~~~r~____~~- ~~~~~-- - _I Page: 2 ------. --------- --- --.--".--.--..--- [~~D"=~_~_;~--=-_T;~..~.. +~(~- +}t"-- 12575.00 81,60 330,90 8675.77 4763.74 -6346.62 ; 12580,00 81.91 330,71 8676.48 4768.06 -6349.03 112590,00 83.33 332.13 8677,77 4776,77 -6353.77 12636.98 90.00 338,76 8680,50 4819.38 -6373,23 12886.98 94,59 28.61 8669.81 5060,80 -6357.86 :13113.49 90,00 1,79 8660.56 5277.18 -6299.17 113413.49 86.48 37.64 8670,10 5554,87 -6199.77 , 13707.09 90,00 2.56 8679.41 5826.16 -6100.59 , 13830.12 95.00 16.47 8674.02 5947,05 -6080.36 12~_1~0.~~_-- ~~~~ ---~_:?~_~~9~~- ---~~_0~_-_593~ ~3__- DLS Build Turn TFO Target ' - ~~~/200ft d:~/1_0~ft ~~~/_~O~-----~~~-- ---------- -- -- --- ___I 0.00 0,00 0.00 0.00 I 7.25 6.20 -3.80 328.75 20,00 14,17 14.24 45,00 : 20,00 14.21 14,11 45,00 20.00 1,84 19,94 84,00 12,00 -2,03 -11,84 261,00 12,00 -1.17 11.95 96.00 12.00 1.20 -11,95 275.00 12,00 4,06 11.31 70,00 12.00 0.11 12.05 88,00 -- -----1 ---.--- --- ------- Sun-e) 1--- -~~j)- - ------i;;~~ - - -'~J:~-- -- -S-S~\~D ---- - - Ñ~S' - -- -- --E~\"--- - - --~i~pÑ- -- - -- - --~-Î~rÈ------d~~~~~~-- -~S------'T~~ -- -- -T~ol--- -- ,-- - --------- --.. -- ------- - - - -------------------- ---- ----------- --- ______h -- -- - n_- -- -- - ---- --On --- ______n_____- -----... --- -- ------------ - - -- ---- - --- - - __n --- ------. - -- --- -. - J 81.60 330.90 8675,77 4763.74 -6346,62 5966088,74 684907.78 0.00 2829.84 0.00 TIP I 81,91 330,71 8676.48 4768.06 -6349.03 5966093,00 684905.26 7.25 2833,33 328.75 KOP , 83.33 332,13 8677,77 4776,77 -6353,77 5966101,58 684900,29 20,00 2840,39 45,00 1 84,74 333,55 8678.81 4785,62 -6358.31 5966110.31 68489553 20.00 2847.64 45,00 MWD 88.29 337.08 8680,33 4808.29 -6368,73 5966132.70 684884.54 20.00 2866,56 44.85 MWD 12575.00 12580.00 12590.00 12600.00 12625,00 44.64 2 84.00 MWD 84.01 MWD 84,05 MWD 84.14 MWO 4819,38 -6373,23 5966143,68 684879,76 20,00 2875,99 4831,62 -6377.67 5966155.80 684875.01 20,00 2886.53 4855,63 -6384,63 5966179.62 684867.44 20.00 2907,69 4880,14 -6389.48 5966204,00 684861.97 20,00 2929.91 4904,98 -6392.18 5966228.76 684858,64 20.00 2953.04 12636,98 90,00 338,76 8680.50 12650.00 90.27 341.35 8680.47 12675.00 90.79 346,33 8680,24 12700,00 91,31 351,30 8679,78 12725.00 91,81 356.28 8679.10 4929,95 -6392,72 5966253,71 684857.46 20,00 2976,90 4954.86 -6391.09 5966278,65 684858.46 20,00 3001,30 4979,53 -6387.30 5966303.41 684861,62 20.00 3026.05 5003,77 -6381,38 5966327,78 684866,92 20.00 3050,98 5027,38 -6373,38 5966351,60 684874,31 20,00 3075,89 84.28 MWD 84.46 MWO 84,68 MWO 84.94 MWD 85.24 MWD 1.26 8678,20 6.24 8677.10 11,22 8675.78 16,21 8674,28 21,21 8672.60 12750,00 92.30 12775.00 92.78 12800.00 93.23 12825.00 93,66 12850,00 94,06 5050.20 -6363.36 5966374.66 684883,75 20.00 3100,59 85,58 MWO 5060,80 -6357,86 5966385.40 684888,97 20,00 3112,29 85.95 3 5072.28 -6351.80 5966397,03 684894.74 12,00 3125,00 261.00 MWD 5094,77 -6341.04 5966419,78 684904.92 12.00 3149,58 260.88 MWD 5117,80 -6331.45 5966443.05 684913,92 12,00 3174,36 260.67 MWD 26,21 8670.75 28,61 8669,81 27.06 8668.79 24,09 8667,00 21,13 8665.42 12875,00 94.43 12886.98 94,59 12900.00 94.35 12925.00 93.87 12950,00 93,37 5141.31 -6323,06 5966466,76 684921.71 12.00 3199.27 260.48 MWD 5165.23 -6315,89 5966490.86 684928,27 12.00 3224,24 260,32 MWD 5189,50 -6309,96 5966515.26 684933.58 12,00 3249,20 260.18 MWD 5214.04 -6305.30 5966539,92 684937.62 12,00 3274,09 260.07 MWO 5238,81 -6301.90 5966564,76 684940.38 12,00 3298.82 259.99 MWD 12975.00 92.87 13000.00 92.37 13025.00 91.85 13050.00 91,33 13075,00 90.81 18,16 8664,06 15,20 8662,92 12.25 8662,00 9,29 8661,30 6,34 8660,84 5263.71 -6299.78 5966589.71 684941,86 12.00 3323.35 259.94 MWD 5277,18 -6299.17 5966603,19 684942.13 12,00 3336.47 259.91 4 5288,69 -6298.68 5966614.70 684942.33 12.00 3347.66 96.00 MWD 5313.60 -6296.65 5966639.66 684943.73 12.00 3372.17 96.00 MWD 5338.37 -6293.33 5966664.51 684946.42 12.00 3396.90 95.98 MWD 13100.00 90.28 13113.49 90.00 13125.00 89.86 13150.00 8954 13175.00 89,23 3.38 8660.60 1,79 8660.56 3.16 8660,58 6.15 8660.71 9.13 8660.98 95,95 MWD 95.90 MWD 95.84 MWD 95.76 MWD 95.66 MWD 5362.94 -6288.72 5966689.18 684950.40 12.00 3421.78 538723 -6282.84 5966713.61 684955.65 12.00 3446.75 5411.18 -627571 5966737.73 684962.18 12.00 3471.74 5434,72 -6267.33 5966761.48 684969.95 12.00 3496.67 5457.79 -6257.75 5966784 78 68497894 12.00 3521.49 12.11 8661.38 1 5 1 0 8661 .92 18 08 8662.59 21.07 8663.39 2406 8664.32 13200.00 88.92 13225.00 8861 13250.00 88.31 13275.00 88.01 13300.00 8772 5480.32 -6246.98 5966807.58 68498913 12.00 3546.12 550225 -6235.04 5966829.81 685000.50 12.00 357049 5523.53 -622199 5966851.41 685013.01 12.00 3594.54 5544.09 -620784 5966872 32 685026.63 12.00 3618.21 5554 87 -6199.77 5966883.30 685034.42 12.00 3630.79 95.55 MWD 95.42 MWD 95.28 MWD 95.13 MWD 94.96 5 27.05 8665.38 30.04 8666.56 33.03 8667.87 36.02 8669.28 37.64 8670.10 13325.00 87.43 13350,00 87.15 13375.00 86.88 13400.00 86.62 13413.49 86.48 . -. - -- - - - -- -- - - -. . - - - - -. - - - -- . - .. .- - - - -- ---- --- - --- .~~J fol.. . ;. J U[J "¡P't'f"õi 1- -- Compan) : BP Amoco Field: Prudhoe Bay Site: PB OS 18 Well: 18-10 I -~~~~~~t~: _.P~a~~? 18-10B BP Amoco Baker Hughes INTEQ Planning Report I'~ii. BAKIII! HUGHES [:"IIEQ -~-- .---.--. ------ .--- ---- Date: 1/31/2002 Time: 09:39:30 Co-ordinate(NE) Reference: Well: 18-10. True North Vertical (T\'D) Reference: System: Mean Sea Level Section (\'S) Reference: Well (0.00N.0.00E.16.00Azi) - ----- -- - __--_S~r~er~~I_~~~t~o_~- ~1~t_h_~.~:_- - -- _~i~i_~~~ g~':Y_~t~~ ------ _.!>~~-,~~~~~e- ____I Page: 3 Sun'e) :-~-iD---lncl---- ---~.\zi~---SŠi\TI---------N/S- ---.. -Ë:ïw" ------ -~-'-;;Ñ--" -" ----~ï~pi:-- ----DlS" 0- -- -- V5-- -- ---T-FO---- --]=;;-01---1 1---- -1-3~~25.-00- -8~e:0--__-- ::~26 86~0.79 5:64~05-"----6~~2'-ai --S96:-a-gÚ5S-- 68;~41.Õ9-~~1g~~~_ft_--3~-1-.5£ ----2~;~OÕ-- MWÕ----' 13450.00 86,87 33.27 8672.22 5584.55 -6178.64 5966913,51 685054,79 12,00 3665.15 275,08 MWO 13475.00 87.15 30.28 8673,52 5605.77 -6165.49 5966935,06 685067,39 12.00 3689.18 275.25 MWO 13500.00 87.43 27.29 8674,70 5627,66 -6153.47 5966957,24 685078.85 12.00 3713,53 275.41 MWO 13525,00 87,73 24,30 8675,76 5650,15 -6142,60 5966980,00 685089.14 12,00 3738,14 275.55 MWO 13550.00 88.03 13575,00 88,33 13600.00 88.64 13625.00 88,96 13650,00 89,27 13675.00 89.59 13700.00 89.91 13707 09 90.00 13725.00 90.73 13750.00 91,76 13775,00 92.78 13800.00 93,79 13825.00 94.80 13830.12 95.00 13850.00 95.08 13875.00 95,17 13900.00 95.24 13925.00 95.30 13950.00 95.34 13975,00 95,37 14000,00 95.38 14025.00 95,38 14050.00 95.37 14075.00 95.34 i- ~~ ~ ?0:0~__--~5.:29 21.31 8676.68 18.32 8677.48 15,34 8678,14 12.36 8678.66 9.37 8679,05 6.39 8679,30 3.41 8679.41 2.56 8679.41 4.58 8679,30 7.40 8678.75 10.22 8677.76 13.05 8676,33 15,89 8674.46 16.47 8674.02 18.86 8672.27 21,87 8670,04 24,88 8667.77 27.90 8665.48 30,91 8663,16 33,92 8660,83 36,93 8658.49 39,95 8656.14 42,96 8653.80 45.97 8651.47 48,99 8649.15 .--- - - -. - - - - -. - - - - -.- 5673.17 -6132.92 5967003.26 685098,23 12.00 3762.94 275,68 MWO 5696,68 -6124.45 5967026,97 685106,10 12,00 3787,87 275,79 MWO 5720.60 -6117,22 5967051,07 685112.73 12,00 3812.86 275,88 MWO 5744.86 -6111,23 5967075.48 685118.09 12.00 3837,83 275.96 MWO 5769.41 -6106,52 5967100,13 685122.17 12.00 3862,72 276,02 MWO 5794.17 -6103,10 5967124,97 685124.97 12.00 3887.47 276.07 MWO 5819,07 -6100,96 5967149.92 685126.46 12,00 3912,00 276,10 MWO 5826,16 -6100.59 5967157,01 685126,65 12.00 3918.91 276,11 6 5844.03 -6099.48 5967174,90 685127,31 12,00 3936,39 70.00 MWO 5868,88 -6096,87 5967199.81 685129.29 12.00 3961.01 70.01 MWO 5893.56 -6093.05 5967224,59 685132.48 12.00 3985.79 5918.01 -6088,01 5967249,15 685136.89 12,00 4010.67 5942,14 -6081.79 5967273.43 685142.50 12.00 4035.59 5947.05 -6080.36 5967278,37 685143.80 12.00 4040.69 5965.91 -6074,36 5967297,38 685149,32 12,00 4060.48 5989,25 -6065,69 5967320.93 685157.39 12,00 4085.31 6012,10 -6055.81 5967344,03 685166.68 12,00 4110.00 6034.40 -6044.75 5967366.60 685177.17 12.00 4134.48 6056,08 -6032,53 5967388.58 685188.83 12,00 4158,69 6077,09 -6019,19 5967409.93 685201.64 12,00 4182,56 70,07 MWO 70.19 MWO 70,35 MWO 70,56 7 88.00 MWO 88.21 MWO 88.48 MWO 88.75 MWO 89,03 MWO 89,31 MWO 6097,37 -6004.76 5967430,57 685215.54 12.00 4206,03 6116,87 -5989,29 5967450.44 685230.51 12,00 4229.04 6135,52 -5972,81 5967469.51 685246.50 12.00 4251.51 6153.28 -5955,38 5967487,71 685263.48 12.00 4273,39 6170,10 -5937,04 5967504.99 685281,39 12.00 4294.61 89.59 MWO 89,87 MWO 90.15 MWO 90.44 MWO 90.72 TO -.. ----.---.- . - ------------.- ---.--- ----- -. ---- ---- ------ ---.. -- .-----. ---. BP Amoco WlLL"ATH DnAlLI "un ,..". ~DDn2G1I1D2 '.N.~:.~:.':::~ ....,OA UIIO.oo Ref. D.I~~ :It 110 1'11.tlH a... v.s .,:.:~: o.':t.~ ~:!~ :::--rt.D ¡:¡EFE¡:¡E'~CE 'N~OR"'AT'O'~ c~ ~~~~:~(/;~5: ~:~:::~~~ ~,~I;~<;;;r~~~]~~s:~. LT~"::I N.:.n.h .s~I.)n '\' ='1 R-:JI~rÍ"I1'=-~ Slül"O 10 Ij/)N û orJE' "~eJ~IJrp.:f DiI~'I~ Re t1II?I1 ~ 21 1£' 513''''='9600 41j 4~ (13 C 31.t:'JI31.C'" ".~'::'I.ho-j ~4,nlrnl_,m CLlf'.. EJIIJ'e ....... DLAI nu. I UJnoo 1'.'0 UGH 1815." 471.114 """12 OOG G,GO 2.1584 I U!08000 I.,. 1,107' "7"'" 471"08 ..s.-DJ 7.2'5 n.ln iUJ..11,J I U!oIO 00 u.n U2.. J 1177 n ..n.. n .eJ.SJ 77 20 oa &5 00 lec JtII .. IleU" 8000 UI r. 'U050 61'1 J8 ...In.,u moo &!ooo un." I ..u.... .....51 2... ...... 1œa.80 "''''5'''.'' 1000 MOO 1I1Z.Z8 . U""''' eoO'J I PI .NOH ..nr,', ..28817 U.oa :NlOO 133447 r UA'1- ...1 .'r'. IUO to 1S'5" n "'M 7F n.oa .. DO seJO.7. . 1:l1D708 80M :lse In... HZ..'. -8tOOSI 1a,OG 27too :JIIL81 . UUO.U ''500 ,...' "'.02 !!INrO! -808OJI U.OO ,aoo 80110". 10U,10000 .'21 .,.. ."'11 .UO'O "UOJ u.oo "00 .uN., liD a..al.8.lo. ..n.77 nn, 00 riP 117. AI 12110 00 t(OP 1171.n 12110.00 1 "'O.lD 121,... 2 ......, 12'" I' 1 ..10"1 U1UAl . "70.1Q U.UAI I .lnA, U70701 . 117..01 una 12 7 '''''.11 1.'00 00 TO I,!-".~ ,;, '8 ".~ r¡; ,.,,:.c:-.""V"";:' !ltfo.:' .~:' ~:;:;, (I 6,;'1 ~ ':JrI !ll!14! ~~.' t...... '! ~,' iU (:WI ~II.": q.('Jf.." +I:.to.... f~ 8151) 8201 825(j 83(1) - C 8350 ~ 8400 It) -8450 ,J: .. B'85()1) Q - 8550 fa U :e 8600 GI > 8650 GI 28700 t- 8750 --- --- 0 LIp .&.. BAKlR HUCHlS ---- ------ -~--- I~TI!Q 6300 6200 6100 6000 5900 -C-5800 ~ 5700 0 .... 5600 - £5U10 ,J: 1:: 5400 0 ~5300 . i 5200 :s :5100 5000 4900 4800 4700 4(,00 -' , . I . '1"", ........,,~ - -!..!... .... ~ l~j'11¿L1"A)I- -, -' , I 1 ':T~. 10 f 1ð-10"EEsl)' .. LEc,Elm L2.Z~ IL2.~~' '8.101'".10, UI.1(1 PS.1(1A) 1J:01.1(J t1~ 1rJAP811 ,,,.'01'8- '('ÞF'B?, Plilnltl 18--10'3 PI;:." rr2 T 1\ M A '-;-' 1 '6,_'CIB T12: /lzim'Jlhs 10 True North Mag'leuc North: 26.57' --- ---- P'a~ P'3~ 1'2 I 18-10fP'ar) t2 18.1('B) CrE 31~.j BV 8rll p(II.!,".I; I --I [D;~ 1L2.~' DJ'" 1'3 I<'O('~ Magnsllc Field ~~'-:"r" ., .r Strength. 57514nT '-, J." ., '0 "- Dip A'lgle: 80.83" Dale: 1/31/2002 Model BGGM21J01 '18- '~J 18-IMPB; ,: -. - - "- " ìj-:::: ~1'" : '': ,: 1'.'1(I"';'~':~.'~:' 1 -~ E '11:..1 ..I.' ~'~., ,:. r-:; r .~rJ .. :rr f.,_~~::-'H..I}-~-;; !~.-;t,:, '~:r. ':::T ;r.:' -7500 .7400 -7300 .7200 -7100.7000 -6900 -6800 -6700 -6600 -6500 -6400 -6300 -6200 -6100 -6000 -5900 -5!!00 .5700 -5600 .5500 - 5400 -5300 -5200 -5100 -WOO -4900 West(-)/East(+) [100ft/in] IT I J' ,~ÜPI ,-- --+ <~il"_" ----- __n~;';-;',I 8800 8850 89(1) I~ 10 l'ð- HrIl-"B1.!1 I-'-li. ,it¡ 1 ~-.!Q"PB'II~ ;~8_.1CJB F'~¡"~"'1JJL- 'TI :~"OI'(l.IQ~11 '11 . - ~, I .,--. - fl':9f'J \. ~. :-6-1 LL '-PI;,,!? 1&,'1('BI L_IQ.J --+ f-_'~- H'B ¡ 221 2600 2650 2700 2750 2800 2850 2300 2950 3000 3050 3100 3151) 320(1 3250 3300 33503400 3450 3500 3550 3600 3650 3700 3750 3800 2.850 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 MOO 4450 451)0 Vertical Section at 16.00° [50ft/in] ----. --.1ß-U2.002 - ---9;39 AM . J . ~ ," . 35 CTD BOP Detail " / I I I I t=C ~" 9 I Blind/Shear 1"- t=f= @ I 2 318" PlpelSlip HCR J I [@]~ )h~IIffi1lil~Î 7-1/16" 10, 5000 psi working pressure J l Ram Type Dual Gate BOF': TOT 1= ~ 2"@'" 1= : I 3 1/2" Combi Pipe/Slip I / Manual over Hydraulic c ~ I ' ~ 1= 2 3/8" X 3 1/2" VBR seal rams xo Spool as necessæy \ (~ Single I I 2 flanged gate valves Manual Master Valve ~ (optional depending ~ on RU) I I I IL THA ) ,ublng - @- ~ 7" Annulus r spool =, - I J --~ @ ~ 9 5/8" Annulus /UI I ~ Methanol Injection ðJL.ð Otis 7" WLA Quick I' Connect - I I r ..1 1-1/16" 10, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold MOJ 5/21/01 o~ -- CT Injector Head I 1 -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ - 7" Riser , I I " Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure .' I '~ire resistant Kelly Hose to Flange by Hammer up 114 Tur' Valve on OS Hardline to Standp' / manifold / I 204443 DATE 01/17/ü2 CHECK NO. 00204443 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 00 ,11602 CK011602~ PYMT :OMMENTS: HANDLING INST: Per~it to Drill ~ee S/H - Terrie HubJle X4628 100.00 b RECEIVED 12;'IDb FE8 1 4 20l/ Alaska Oil & Gas Con~. (,;OJTn1ISSlc.r Ao~ "TTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE, TOT~L .. 100.00 ---.1 00. 00 BP EXPLORATION, (ALASKA) INC. P.o. BOX 196612 ANCHORAGE. ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H2O 4 4 4 3 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 4'i'2 00204443 >AY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 01/17/02 AMOUNT $100.00 ïo The JRDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 V 1I~ - ," " ~ or It. C, .;~,,~f) ~, ~ ,Ie' . III 20 L, L, L, :1111 1:0 L, ¡. 20 :18 g 51: 008 L, ~ ~ 9111 ) TRANSIVIlT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ¡?/ld /f~/() 6> CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL ~' EXPLORATION INJECTION \\TELL INJECTION \\TELL REDRILL \VELL NAME CHECK 'VIlA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL¿R D~OSAL ~NO ANNULAR DISPOSAL <--J YES ANNULAR DISPOSAL THIS 'VELL "CLUE" The permit is for a new wellbore segment of existing well --J Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 MC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <--J YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. /J t'q..;;'j t( WELL PERMIT CHECKLIST COMPANY ß//X WELL~AME /8-10 15 PROGRAM: Exp - Dev ~ Redrll ,/ Serv - Wellbore seg - Ann. disposal para req - FIELD & POOL ~L/O/S() INITCLASS ~~/ /f)/L GEOLAREA ~l?) UNIT# I)//(~~Ç{) ON/OFFSHORE 0/1- ADMINISTRATION 1, Permit fee attached. . , . . , , . . . , , . . . , , . . , . , , N ~ . /' / . / . / ,/)- 2, Lease number appropriate.~. . . , . , , , , , , , , , . , . . ~N~..:5tL-1.. r~ ¿..;:... /6 I!!A h(;Y"'O-t ~ -fz;¡p- .~Oa'. <-e~.::f-e.. V4f" u.... /l7::>L 0 z..g'3D"7.1' 3, Unique well name and number. .. . , . . . , . . , , . . . . . " --r: ~ V'¡"" -1 DL- ¿")~ 3ðz ..db 4, Well located in a defined pool., . . . . . . . . . . . , . . . , I N 5, Well located proper distance from drilling unit boundary, , . , 'N 6. Well located proper distance from other wells.. , . , , . , , , )N 7. Sufficient acreage available in drilling unit.. . , . , . , , , . . - - ') N 8. If deviated, is wellbore plat included.. , . . , . . . . . . . . . ' 'N 9, Operator only affected party.. . . , , , . . , . , , , . , . . , ' N 10. Operator has appropriate bond in force. . . , , , . . . , , , . 'N 11. Permit can be issued without conservation order. . . . . . . , ) N AP~ DATE 12, Permit can be issued without administrative approval., . . , , N ß~ l.. I ç, o'V13. Can permit be approved before 15-day wait., , , . , . . . , , Y N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . , , , , , ¥ N ,-J/4 15. Surface casing protects all known USDWs. . , . . . . . . . . v---N-- 16. CMT vol adequate to circulate on conductor & surf csg, , . . . ¥ -N- " 17. CMT vol adequate to tie-in long string to surf csg. . . , . . . . Y @ 18, CMT will cover all known productive horizons. , . . , . . . , , éi/ N Ad""q l(.,~-i< e,.-l ('P S ç C.ë oA.-L -r' ~L,t . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . &, N C 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . &/ NeT Ou.. 21. If a re-drill, has a 10-403 for abandonment been approved. , , Y N 22, Adequate wellbore separation proposed.. . . . . , , . . , . . W N 23. If diverter required, does it meet regulations. . . . , . , . . . -~ ¡4J/A 24. Drilling fluid program schematic & equip list adequate. , . . , (ý) N 25. BOPEs, do they meet regulation, , . . . . . . . . , , . . . . @ N d 26. BOPE press rating appropriate; test to 3500 psig. @ N S.i . ('..TDU ì3 0 PG ks,t fMS5.U '\....f' . /'IztY;p : l.l to f' y'. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . iSi2 N 28. Work will occur without operation shutdown. . , , . . . . , . , IiJ N 29. Is presence of H2S gas probable.. . . . . . . . . . . . , . . . ~ N ~~lr.;',-I..-" 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y (N) ~.-.S t.4 ~,,-f ¿:¡ -I AC; / f - 31. Data presented on potential overpressure zones. . . . . . . g . t/ 32. Seismic anal~~is of shallo~ gas zones. . . , . . , . . . , . . -Ai A N AP~ DATE 33. Seabed condition survey (If off-shore). . . . . . . . . . ~ Y N /?JV z.. . IS- 01., 34. Contact name/phone for weekly progress reports {expklfatory only} Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . Y N ' J.. . APPR DATE (B) will not contaminate freshwater; or cause drilling waste. '. Y N No (1,.{/I., ,-{ L-{(a I,' dAf ~"t'\() S'1.. ( ¥'Y~ ljlq ê J to surface; ) I :/ . (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25,252 or 20 MC 25.412, Y N GEOLOGY: ENGI~~RING: UIC/Annular: COMMISSION: RPC- TE~'M~r1s COT SFD~- WGA ~t:,k DTS 02./15 ItS) <- JMH .:l I\. i H ,}/IS J LJ 2-- APPR DATE \þJGI\ 7. lS/O'- /ß1)r¡ ~ IS" GEOLOGY Com mentsll nstructions: G: \geology\permits\checklist. doc 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 me and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Specry-Sun Dri 11 ing Ser-;.Tices LIS Scan Utility dQ]-(ßS 1)'-115 $P.e\'ision: 3 S LisLib SRe~ision: <:I: $ Thu Jan 09 15:25:48 2003 Reel Header Ser':ice name. . . . . . . . . . . . . LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 ' 01 ' 09 Origin. . . . . . . . . . . . . . . . . . . STS Eeel !Tame................ U1IKnOWH Continuation Uumber...... 01 pre",Tious Reel Name....... UlJKI'Jû\^IT'J Corm~nts................ .STS LIS 1JJ:r.- it ing Librar:/. Sc ientific Technical Ser.'ices Tape Headec Ser-,'ice name. . . . . . . . . . . . . LISTPE Date. . . . . . . . . . . . . . . . . . . . .03,' 01 09 Or ig in. . . . . . . . . . . . . . . . . . . STS Tape Name................ m,JKNOWN Continuation Number..... .01 pre'"Tious Tape Name....... Ul'WNOWH Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Ser,:ices Ph~/s ica 1 EOF Comment Record T.~.PE HE.~.DEP. Prudhoe Ba::l l-IWD .'n;D LOGS # WELL IJ:~.J'lE: .; P I rIUl.lEER: OPERJ:..TOR : LOGGIIJG COHP';.JlY: T;'.PE CRE.;'TIOI1 DATE: # JOB D.;TA 18-10B 500292081802 BP Exploration (~laska) Inc. Sperry-Sun Drilling Ser:ices 09-J;'JT-03 JOB !,jlJ1.1BER.: LOGGHIG EIIGINEEP.: OPEK~TOR WITnESS: i-fwD RUl r 1 A K -l.IW - 2 2 0 .J. oJ B. J;'.HU R. \II]HITLOW , # SUEF'.r..CE LOC';'TIOlJ SECTION: TOWNSHIP: Rh.NGE: FIlL: FSL: FEL: FWL: ELE\l.;TIOI'J (FT FFOH KELL Y BUSHHIG: DEREICK FLOOR: GF.OUlJD LE'JEL: 2<1 1ll-1 l.J.E 4907 371 HSL 0) <:1:5.03 .00 .00 # V,JELL CAS nlG FECOP.D 1ST STRIITG 2HD STRIrJG OPEIJ HOLE C.:"SHJG DRILLERS BIT SIZE (HI I SIZE ITIT) DEPTH 1FT) 3.750 oJ.SOO 12216.0 3 ED STRING PRODUCTION STRIl~ # P.El-L~Er:S : 1. '='.LL DEPTHS '='.P.E HEASURED DEPTH ([.ID) mTLESS OTHEE~\1ISE NOTED. THESE DEPTHS .:"F.E BIT DEPTHS. 2. J...LL VERTIC;'.L DEPTHS .::'.P.E TRUE 'IERTIC;'.L DEPTH - SUBS E.::'. (TVDSS) . 3. [,fWD EUE 1 Cor.¡PRISED DIRECTIorJ.;L II'JITH LJ.r..TUP~::'.L G.::'J.ll'L::'. RÞ.Y (PCG) UTILIZING SCIlJTILLÞ.TIOlJ DETECTORS. .J. DEPTH SHIFTIlTG,' CORRECTIûl! OF Hv'JD D.::'.1'.::'. VIl';'S vJ;'.J'./ED PEP. E-I:-LlI..IL FRaN D. SCHNORR, BP E:':PLORA1'IOlT (;'.L;'.SY~::'.), IITC., D.::'.TED .J 1 02, 5. UWD RUlT 1 HEPRESENTS t'oJELL 18-10B vJITH .::'.PI#: 50-029-20818-02. THIS WELL RE~CHED A TOTAL DEPTH (TD) OF 14107'HD 8645'TVDSS. SHOP = SUOOTHED K::'.TE OF PEHETP3...TIOU \ljHILE DRILLIITG. SGRD = S[,¡OOTHED N;'.TUK;L Ga,n,r;.. R:"Y. $ File Header Service name............ .STSLIB.OOl Serf ice Sub Le':el I'Tame. . . Version Humber.......... .1.0.0 Date of Generation...... .03,01,09 Haximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HE.~.DER FILE l1UllBEF.: EDITED [.1ERGED H\¡\1D Depth shifted and DEPTH Il'JCREHEI!T: # F I L E S Ul-'ll'IÞ. R '¡' PBU TOOL CODE Gp. ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 12118.0 12240.5 STOP DEPTH 14075.5 14107.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT mTSHIFTED DEPTH --------- B.l..SELIIJE DEPTH $ If HERGED PBU 11WD $ DAT;'. SOURCE TOOL CODE BIT RUN HO HERGE TOP 1 12118.0 HERGE BASE 14107.0 # EE['L:"PKS : 1.JERGED ['L::'.Il'T PASS. $ If Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........... . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spac i ng. . . . . . . . . . . . . . . . . . . . . 60 . 1111 [,Ia:{ frames per record............. Undefined Absent value..................... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-t~pe...O Harne Ser?ice Order Units Size ITsam Rep Code Offset Channel D EP'r FT 4 1 68 (I 1 Rap HWD FT'H .J. 1 68 .cl 2 GR LßvD Þ.P1 .J. 1 68 8 3 First Last 1,1 ame Sel.-\' ice Unit l'.lin Uax l,Jean [Isam peading Peading DEPT FT 12118 1-1107 13112.5 39~9 12118 1410~ Rap HWD FTIH 0.08 329.92 88.-;'699 373.J. 122.clO.5 1.cl10-;' GR I.fWD API 13.52 867.18 ó3.0061 3881 12118 1-l0ì5.5 First Reading For Entire File......... .12118 Last Reading For Entire File.......... .1~107 File Trailer Service name............ .STSLIB.001 Service Sub Le\,'el Name... Version Number.......... .1.0.0 Date of Generation...... .03,'01,09 Haxirnum Physical Eecord. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.OO2 Ph/sical EOF file Header Sep,rice name............ .STSL1B.002 Service Sub Le\'el llame... Version Number.......... .1.0.0 Date of Generation...... .03;01,09 Maximum Physical Record. .65535 File Type... ....,....... .LO Pre~,rious File !lame. . . . . . . STSLIB. 001 Comment Record FILE HEÞ.DER FILE NUHBER: P ß..!¡J HW D Curves and log BIT RUN nm'IBER: DEPTH INCREMENT: # FILE Sm,IHARY VEnOOF. TOOL CODE STÞ.RT DEPTH GR 12118.0 ROP 12240.5 $ 2 header data for each bit run in separate files. 1 .5000 STOP DEPTH 1.J075.5 14107.0 =# LOG HE¿~DER D';'.T.:::'¿ DATE LOGGED: SOFTWARE SURF¿::'¿CE SOFTW.::'.EE \,'ERSION: DOv\1NHOLE SOFTW.;RE VERSION: DÞ.TA TYPE (HElIORY OR RE.r..L-1'IHE) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BO'T'TOl-l LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCL IN.~TIOl.J (DEG BINIHUH .;I'TGLE: 1.L~~Il.H.n'1 .;,['IGLE: # TOOL STRIHG (TOP TO BOTTOH) VENDOR TOOL CODE TOOL TYPE l\JGP $ NA1'UR;'L GÞJ.ll.L:'~ PEOBE # BOREHOLE .;I'JD CASIlJG D.~T~~ OPEr,J HOLE BIT SIZE (IN): DRILLEE I S CP~.SIl' G DEPTH (FT): # BOREHOLE CONDITIOnS [.100 TYPE: VIVO OEI:1SIT"i (LB/G): MUD VISCOSITY (S): BUD PH: HUD CHLORIDES (PPH): FLUID LOSS (C3): RESISTIVITY (OHHI-l) Þ.1' TEHPEP~~.TUR£ (DEGF) HUD ~~T HE.:;SURED TEHPEP~~TURE (1,11'): HUD .":..1' I.L;Z CIP.CUL;'~TING TEP.I.IPEK:'~TURE: UUD FILTRATE ~;:'.T liT: HUD C.;KE .;:.~ l' 1-11': # NEUTRON TOOL HÞ.TRIX: l-L~TP.IZ. DENSITY: HOLE CORRECTION (Hn: # TOOL ST.:..JJDOFF (IIJ): EWR FREQUENCY (HZ): =# REHAPKS: $ # Data Format Specification Record Data Record T}~e..................O Data Specification Block 1'~~e.....O Logging Direction................ .00vffi Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1HI Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-t~~e...O 11 -1 L:'.R - I) 2 Insite l-Iemor~.' 1.J.107.0 12216.0 1410,.0 63.6 95.6 TOOL I TUI,IBER 126583 3.750 1206.J..0 Flo Pro 8.60 .0 8.5 19000 7.8 .000 .000 .000 .000 .0 150.0 .0 .0 Harne Service Order Units Size Usam Rep Code Offset Channel DEPT F1' 4: 1 68 0 1 ROP [.1WD0 10 FT H 4 1 68 4 2 GR [.!WOO 1 0 API .J 1 68 8 3 First Last lIame Service Unit Hin l'lax [.Iea n lIsam P.eading P.eadin9 DEPT FT 12118 14107 13112.5 39"79 12118 1-110-:' ROP HWDOI0 FT..H 0.08 329.92 88."7'699 373..,1 122.J.0.5 1.:.1107 GR HWDO 1 0 t'. PI 13.52 867.18 63.0061 3881 12118 1.Jûì5.5 First Reading For Entire File......... .12118 Last Reading For Entire File.......... .14107 File Trailer Service name............ .STSLIB.002 Ser,rice Sub Level I.Tame... \.fersion Number. . . . . . . . . . .1.0.0 Date of Generation...... .03 01,'09 Haximum Ph:/sical P.ecord.. 65535 F i 1 e Type... . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Ph~'s ical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03 '01 '09 Or ig in. . . . . . . . . . . . . . . . . . . STS Tape lJame. . . . . . . . . . . . . . . . Ul'J¥l'TOWlT Continuation Number..... .01 Hext Tape Name. . . . . . . . . . . UN¥.lJOil'm COIT~ents................ .STS LIS Writing Library. Scient ific Technical Sec.~ices Peel Trailer Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 01. 09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . . U1TKHOWlT Continuation Number..... .01 Next Reel Name. . . . . . . . . . . UIJY1JOWl'T Comments................ .STS LIS Wri ting Librar~'. Scientific Technical Ser~ices Ph:/sical EOF Phj'S ical EOF End Of LIS File
