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Home My WebLink About203-220 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. áo 3 - ~ ~ 0 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed III 111111111111111I RESCAN DIGITAL DATA ~kettes, No. I o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: oalo 3/1 if/Oh oal03/1 Lf / f)~ ~ x 30 = ~tJ + ~ oal03/'4 lOt. o Other:: BY: ( , Maria ~ 151 WlP III II 111111 11111111 Project Proofing BY: C Maria~ mp = TOTAL PAGES t,fo (Count does not include cover sheet) 1J1A ,0 151 V rrr 151 Scanning Preparation BY: ~Maria J Production Scanning Stage 1 Page Count from Scanned File: (tJ 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY C. Ma~a ) oatoÓ /14-/ Db Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 151 NO VY1 P NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned III II 111111 11111111 BY: Maria Date: 151 Comments about this file: Quality Checked III II 1I11111 II 1I1I1 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~ION ~E~EIV'E[~ ocT ~ ~ zoo9 WELL COMPLETION OR RECOMPLETION REPORT A L 1a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Plugged ~ Abandoned ^ Suspended 20AAC 25.105 zoanc zs.»o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1b. W : ' ~ Development A11d1@~Batory ~~~~~ ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. . Date Comp., Susp., or Aband.: 10l7/2009 ' 2. Permit to Drill Number: 203-220 309-321 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 1/26/2004 N,3. API Number: ~` 50•029-20106-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 2/7/2004 4. Well Name and Number: PBU H-05A 773 FNL, 1265 FEL, SEC. 21, T11 N, R13E, UM Top of Productive Horizon: 3778' FSL, 5011' FEL, SEC. 16, T11 N, R13E, UM 8. KB (ft above MSL): 72.8g~ GL (ft above MSL): 15. Field / Pool s (): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4014' FSL, 4292' FEL, SEC. 16, T11 N, R13E, UM ~. Plug Back Depth (MD+ND): 11950' 9024' Oil Poo) 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 643313 y_ 5960015 Zone- ASP4 . Total Depth (MD+TVD): 12470' 9018' 16. Properry Designation: ADL 028284 TPI: x- 639470 y- 5964494 Zone- ASP4 Total Depth: x- 640184 Y- 59&4744 Zone- ASP4 11. SSSV Depth (MD+TVD): N!A 17. Land Use Permit: 18. Directional Survey: ~ Yes ^ No Submit electronic and rinted information r 20 AAC 25.050 ~ 9• Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List a~l logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR / R~S, DIG / G~2 / RES / NEU / DEN 22. Re-DrilULateral Top Window MD/TVD: 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETfING DEPTH ND HOLE AMOUNT GASING WT. PER FL GRADE TOP BOTfOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 0" n u r rfa 1' rf 100' 2 5 sx P rmafr II ~~ ~ rf , ~~ P r 13-3/e" x 9-5/8" 6 / 47# K-5 / N 7 2' urfa 7' 12-1l4" 87 x las 'G' A I 9-5/8" x 10-3/4" 47# / . -/ N 28' 2 ' 2' 1 2' 1-1/ " -5/ " Ti k: s Ar i I ' " 1 " 14 ' 4/" 1. 13 1 70 ' 47 ' 18' 1/ " 22 1 ss'G' 24. Open to production or injection? ^ Yes ~ No 25. TueiN~ RecoRo If Yes, list each interval open (MD+ND of Top & Bottom; Perforation Size and Number): S~ DEPTH SET MD PACKER SET MD I ND 4-U2", 12.6#, 13Cr80 10720' 10665' MD ND MD ND 26. ACID, fRACTURE, GEMENTSQUEE2E, ETC. ° ~ ` ~ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED ~t(~i`~~ t^'; ~ v `,~ ~~v a~~~c~~~~~ ' 11950' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): WA Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Fress• Casing Press: Calculated 24Hour Rate • OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: 28. CORE DATA Conventi onal Core{s) Acqu ired? ^ Yes ~ No Sidewalt Core(s} Acquired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate ~heets with this form, 'rf needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250A71. None ;ion Fortn 10-407 Revised 07/2009 ~~ „~J ~ i.,C~t~~ED ON REVERSE % // /~~ ~~ Submit Original Onty J~ ~ 1 ~~ G~~ 29. GEOLOGIC MARKERS (list al! formations and encouMered): 30. RMATION TESTS ~ NAME MD ND Well Tested? ^ Yes ~ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.07L Sag River 10855' 8548' None Shublik 10900' 8582' Sadlerochit 10953' 8622' Top CGL 11200' 8804' Base CGL 11292' 886T 26N 11402' 8938' 25N 11474' 8975' 22N 11633' 9026' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. p ~ Q~~ ~ 7 Signed: Terrie Hubble Title: Drilling Technologist Date: PBU H-05A 203-220 309-321 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Ron Phipips, 564-5913 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Muftiple completion is defined as a well producing ftom more than one pool with produdion 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 ND 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 (muftiple completion), so state in item 1, and in item 23 show the producing intervals for only the intervat 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 (e~cplain). Item 28: Provide a listing of interoals 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 07l2009 Submit Original Only • ~ H-05A, Well History (Pre Rig Sidetrack) Date Summary 09/22/09 T/I/O/00/000= SSV/0/0/0/0, Temp=Sl. PPPOT-T (PASS), pre CTD. PPPOT-T: External check installed. Stung into test port (0 psi), bled to 0 psi. Functioned LDS, all moved freely (2.5 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 09/24/09 MIRU CT. MU Baker Left Hand Motor and 3.80" OD Parabolic mill assy. RIH. Milled through XN nipple at 10.695' GTM. 10.707' MD. Backed reamed and polished out nipple. Started POOH. 09/25/09 POOH w/Baker left handed motor assy. LD Baker mill assy. MU 3.63" OD Dummy whipstock. Drifted tubing and liner to 12,100'. POOH. At surface MU IGS tools RIH to 12100'. Make several passes from 10500' to 10800', POOH from 10500' Stop at 2500' to freeze protect. Freeze protected well to 2500'. RDMO. Job complete. Page 1 of 1 ~ • BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: H-05 Common Well Name: H-05 Spud Date: 9/27/1971 Event Name: REENTER+COMPLETE Start: 10/1/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase De~cription of Operations 10/5/2009 00:00 - 02:00 2.00 MOB P PRE CONTINUE TO WAIT ON SECURITY. CLEAN UP AROUND WELL HEAD AREA. CONTINUE TO LOAD SUPPORT TRAILERS. 02:00 - 02:30 0.50 MOB P PRE PJSM REGARDING MOVING THE RIG W/ SECURITY. 02:30 - 06:00 3.50 MOB P PRE MOVE RIG FROM D PAD TO SPINE ROAD. TURN ONTO SPINE ROAD. HEAD TOWARDS GC2 ACCESS ROAD. 06:00 - 06:45 0.75 MOB P PRE CHANGE OUT CREWS AT GC2-SPINE INTERSECTION. 06:45 - 09:00 2.25 MOB P PRE CONTINUE TO MOVE TO H-PAD. 09:00 - 12:00 3.00 MOB P PRE RIG ON LOCATION AT 0900. WAIT ON RIG MATS ETC. SPOT CAME AND PREP AROUND TREE. SPOTS HERCULITE AND MATS. 12:00 - 15:00 3.00 MOB P PRE MOVE RIG OVER WELLHEAD. PREP CELLAR. SET DOWN RIG. ACCEPT RIG AT 12:30. INSTALL TREE SCAFFOLD LADDER. RU PLYWOOD OVER CELLAR HOLE. 15:00 - 19:30 4.50 PRE PJSM REGARDING NU BOPE. ND TREE CAP. NU BOPE. RU ANNULI GAUGES. FILL BOP & SHELL TEST, 250PSI/3500PSi. 19:30 - 00:00 4.50 BOPSU P PRE TIGHTEN CHOKE LINE GREY-LOC FITTING. TEST BOPE PER AOGCC REGS 250PSU3500PSI. JEFF JONES FROM AOGCC WAIVED W ITNESS TO TEST. 10/6/2009 00:00 - 03:00 3.00 BOPSU P PRE CONTINUE TO TEST BOPE PER AOGCC REGS TO 250PSI/3500PSI - PASS. 03:00 - 03:15 0.25 BOPSU P PRE PJSM REGARDING RU & PULL BPV. 03:15 - 04:45 1.50 BOPSU P PRE OPEN SWAB. OPEN SSV & INSTALL FUSEABLE. RU DSM BPV. PRESSURE TEST 250PSI/1000PSI. OPEN MASTER - VAC. PULL 4" 'H' STYLE BPV. CLOSE MASTER. RD DSM. 04:45 - 04:55 0.17 BOPSU P PRE PJSM REGARDING PU INJECTOR & STABBING ONTO WELL. 04:55 - 05:45 0.83 BOPSU P PRE PU INJECTOR & STAB ONTO WELL. FILL COIL. SI & TEST PACKOFFS & INNER REEL VALVE PER AOGCC REGS, ADW SOP, DWOP, PERMIT TO DRILL, AND WELL PLAN 250PSI/3500PSI. 05:45 - 05:55 0.17 KILL P WEXIT PJSM REGARDING MU NOZZLE BHA. 05:55 - 06:20 0.42 KILL P WEXIT MU NOZZLE BHA. STAB ONTO WELL. 06:20 - 08:45 2.42 KILL P WEXIT filH W/ NOZZLE BHA. ATTEMPT TO KILL WELL 8Y PUMPING DOWN BACKSIDE & CT, UNABLE WHP IS AT 2400PSi. RIH TO BOTTOM. CONTINUE TO RIH. REDUCE CIRC RATE TO 0.22 BPM. WHP: 720 PSI. 08:45 - 10:00 1.25 KILL P WEXIT BLEED WHP TO ZERO. NO FLOW. CIRC BTMS UP w/ KCL: 2.5 bpm in/ 2.4 bpm out at 2850 psi. Minimal losses. 10:00 - 12:40 2.67 KILL P WEXIT PULL OUT OF HOLE. CIRC AT MIN RATE. 12:40 - 12:50 0.17 KILL P WEXIT PJSM FOR LD OF NOZZLE 12:50 - 13:35 0.75 KILL P WEXIT LD NOZZLE 13:35 - 13:50 0.25 WHIP P WEXIT PJSM FOR PUMPING SLACK AND CUTTING COIL i 13:50 - 15:40 1.83 WHIP P WEXIT PUMP SLACK OUT AND CUT 382 FT OF COIL TESTED WIRE-BAD - CLEANED CORROSION OFF OF WIRE TERMINALS IN JUNCTION BOX Printed: 10/19/2009 11:0625 AM ~ . BP EXPLORATfON Page 2 of 12 Operation~ ~ummary RReport Legal Well Name: H-05 Common Well Name: H-05 Spud Date: 9/27/1971 Event Name: REENTER+COMPLETE Start: 10/1/2009 End: Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 ' Date' Fram - To Hours Task Code NPT Phase Description of Operations 10/6/2009 13:50 - 15:40 1.83 WHIP P WEXIT TESTED WIRE - GOOD 15:40 - 18:30 2.83 WHIP P WEXIT INSTALL SLB CTC AND TEST 18:30 - 19:00 0.50 WHIP P WEXIT INSTALL BHI UQC AND TEST MU WHIPSTOCK BHA 19:00 - 19:15 0.25 WHIP P WEXIT CREW CHANGE 19:15 - 21:35 2.33 WHIP P WEXIT RIH WITH WS BHA WITH EDC OPEN ~ MIN RATE AND 75 FPM 21:35 - 22:35 1.00 WHIP P WEXIT LOG FOR GR TIE IN FROM 11,680 FT TO 11,812 FT MADE -42 FT CORRECTION 22:35 - 22:55 0.33 WHIP P WEXIT RIH TO 11,910 FT AND THEN MAKE CCL LOG TO 12,080 FT. 22:55 - 23:20 0.42 WHIP P WEXIT PU TO 11,900 FT AND EVALUATE LOG BEFORE SETTING WS. PU WT = 48,500#'S TOP COLLAR C~ 11,938 FT BOTTOM COLLAR ~ 11,980 FT 23:20 - 23:30 0.17 WHIP P WEXIT RIH TO 11,966 FT WITH 30 DEG RT OF HS AND PU TO UP WT OF 48K. ZERO DHWOB CLOSE EDC AND WALK UP PUMP PRESSURE SHEARED OF ~ 2000 PSI SET DOWH WITH 4,500#'S DH WOB. / PU CLEAN / TOP OF S SH LD B BELOW TOP OF WS 23:30 - 00:00 0.50 WHIP P WEXIT OPEN EDC AND POOH AT MIN RATE DUE TO FOAMING PROBLEMS WITH KCL IN PITS 10/7/2009 00:00 - 02:00 2.00 WHIP P WEXIT CONTINUE TO POOH ~ MIN RATE 02:00 - 02:10 0.17 WHIP P WEXIT PJSM FOR LD BHA WHILE POOH 02:10 - 03:00 0.83 WHIP P WEXIT TAG UP AND FLOW CHECK WE~L LD WHIPSTOCK SETTING BHA - TOOLS LOOKED GOOD FOR A NORMAL SETTING SEND OUT BTT WS RUNNING TOOLS ' 03:00 - 03:30 0.50 STWHIP P WEXIT P WINDOW MILLING BHA WITH NEW 3.80" WINDOW ~ MILL AND STRING REAMER 03:30 - 05:45 2.25 STWHIP P WEXIT OPEN EDC AND RIH WITH WINDOW MILLING BHA. 05:45 - 06:15 0.50 STWHIP P WEXIT ~ LOG FOR GR TIE IN FROM 11,750 FT TO 11,827 ft MADE - 42 FT CORRECTION : 5- . . 5 HI P WEXIT RIH. ~ 2075 PSI FS AT 2.5 BPM IN/OUT. TAG TOWS AT 11,948.6'. TIME MILL WINDOW FROM 11,948.6' TO 11,956.4' ~ f MILL 10' OF NEW FORMATION TO 11968.4' MAKE SLOW PASSES THROUGH WINDOW WITH LITTLE TO NO MW MAKE DRY DRIFT THROUGH WINDOW - CLEAN 19:30 - 22:25 2:92 STWHIP P WEXIT BU SAMPLE HAD GOOD CUTfINGS IN IT. POOH WITH EDC OPEN ~ 4 BPM 2225 - 22:35 0.17 STWHIP P WEXIT PJSM FOR LD OF BHA WHILE POOH 22:35 - 23:10 0.58 STWHIP P WEXIT LD WINDOW MILLING BHA MILLS GAUGED AS 3.78 GO AND 3.79 NO GO 23:10 - 23:35 0.42 DRILL P PROD1 MU TURN BHA (#3) WITH 3.3 AKO, NO RESS, AND REBUILT HCC BI CENTER WITH "CHEETAH" CUTTERS. Printed: 10/19/2009 11:06:25 AM TREE= 4-1/16" WELLHEFlD = MCEVOY ACT~ATOR = OTIS KB. ELEV = 64.13' BF. ELEV - _ 44.68' KOP - 7982' Max Angle = 94 ~a 31745' Datum MD = 11301' DatumND= 8800'SS ~ ~~~.~ ~~„~F~ I 9-5/8" CSG TIEBACK W/ BOT PBR 13-3/8" CSG, 68#, K-55, ID = 12.415" 18-5/8" CSG, 96.5#, K-55, ID = 17.655" 2130' 2251' 2299' Minimum ID = 2.30" @ 11308' LINER BUSHING TOP OF 7" SCAB LNR (ESTIMATED) 6830~ - ~ SAFETY N ***4-1 /2" CHROME TBG & LNR*** 1065~ ~ 9-5/8" X 13-3/8" EST TOP OF CEMQVT 2209~ 4-1/2" HES X NIP, ID = 3.813" 2251' --~ 13-3/8" X 9-5/8" XO, ID = 8.681" GAS LIFf MANDREIS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3276 3238 28 KBG-2 DMY BK 0 11/22/06 4 5779 4929 50 KBG-2 DMY BK 0 11/22/06 3 7929 6373 47 KBG-2 DMY BK 0 02/11/04 2 9291 7371 44 KBG-2 DMY BK 0 02/11/04 1 10491 8276 41 KBG-2 DMY BK 0 02l11/04 7843~ I~ 9-5/8" X 7" BKR LNR TOP PKR 7" SCAB LNR, 26", L-80, ID = 6.276" ~~ 7830~ I 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 7982~ r 9-5/8" MILLOUT WINDOW (H-05A) 7982' - 7998' I4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" ~~ 10720, 7" LNR, 26", L-80, .0383 bpf, ID = 6.276" 10855' I3-1/2" LNR, 8.81#, L-80, STL, .0087 bpf, ID = 2.992" ~ 11353~ 4-1/2" LNR, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 11949~ 4-1/2" BKR MONOBORE WHIPSTOCK 11950~ PERFORATION SUMMARY REF LOG: SWS-MCN~ ON 10f21i09 ANGLE AT TOP PERF: 89° @ 13170' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7i8° 6 13170 - 13700 C3 10i22l09 2-7,`8" 6 13$d0 - 13979 Q 10/22/d9 10644' -14-1/2" HES X NIP, ID = 3.813" ~ 10665~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10688~ 4-1/2" HES X NIP, ID = 3.813" 10707' 4-1/2" HES XN NIP, ID = MILLm to 3.f 10713~ 4-1/2" WLEG, ID = 3.958" 10716~ 7" X 5" BKR LTP-1 10733' 5" X 4-1 /2" xo 11294~ -~ BKR KB LT PKR, ID = 2.37" ~ 11300~ 3-1/2" DEPLOYMENT SLEEVE, ID = 2.30" 11354~ 3-1/2 x 3-3/16" XO, ID = 2.80" 4-1/2" MILLOUT WINDOW (H-05B) 11949' - 11958' 12506~ ~~ 3-3/16 x 2-7/8" XO, ID = 2.377" I3-3/16" LNR, 6.2#, L-80, TCII,.0076 bpf, ID = 2.80" ~ 12505~ ~T~ 14005' 2-7/8" LNR, 6.16#, L-80, STL, .0058 bpf, ID = 2.441" -~ DATE REV BY COMMENTS DATE REV BY COMMENTS 02/18/77 ORIGINAL COMPLETION 02/18/04 SRB/KAK RIGSIDEfRACK(H-05A) 10/23/09 NORDIC2 CTD SIDETRACK (H-056) 10/25/09 SV DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: H-D5B PERMff No: ~2091000 API No: 50-029-20106-02 SEC21, T11N, R13E, 773' FNL & 1265' FEL BP F~cploration (Alaska) Change to H-OSA Sundry ~ ~ Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, September 29, 2009 1:26 PM To: 'Ron.Phillips@bp.com' Cc: Maunder, Thomas E (DOA) Subject: RE Ghanqe to H-05A (2tf3-220~ Sundry (309-321) Ron, . _._. ...._.., _ ...... I concur with your approach. The primary liner cement job will isc5l~~te""aff'~lie existing perfs anyway. No pre- squeeze of the 4'/2" liner perfs is needed. I will make the change to the P& A procedure for our records. Regards, Guy Schwartz ~,, ;,~;~~ . <<~ ,~; ~ ~ ,% `~~ ~~~~ Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Maunder, Thomas E (DOA) Sent: Tuesday, September 29, 2009 1:13 PM To: Schwartz, Guy L (DOA) Subject: FW: Change to H-05A (203-220) Sundry (309-321) From: Phillips, Ron [mailto:Ron.Phillips@bp.com] Sent: Tuesday, September 29, 2009 1:05 PM To: Maunder, Thomas E (DOA) Subject: Change to N-05A Sundry Tom, The H-05A Sundry requested permission to set a Baker Monobore whipstock and squeeze cement past it and into the open perforations. I thought since we would have open perforations above the whipstock that squeezing cement into these perforations would be the conservative approach. After the group talked it over and decided squeezing the perforations above the whipstock before drilling the well is not needed. I would like to change the plan to set a packer whipstock and cover the open perfs above the whipstock, after the H-056 sidetrack is drilled, with the primary liner cement job. Removing the down squeeze cement }ob wi11 simplify the plan and save money. Thanks, Ron Phillips Coil Tubing Drilling Engineer Alaska Drilling & Wells Office (907) 564-5913 Cell (907) 748-7868 9129/2009 • • ~~~``~ ~-I ~~ t~ ti ,,.-, ,' t x~g` ~ d~ ~p K t° ` 9~'gzr F; q'~~ r ~ ° ~ ~ 7~ ~ ~, R t ~ 2 ~ ~ ~ ~ ~ ~~ ~ ~ ~p ~ G ~ ~ ~ ~~ ~v ~ ~ ~ ~ ~~ ~ t~~ It ~ ~ ~ ~~`~ ~ ~ SEAN PARNELL, GOVERNOR ~a~~ ~:,~ ~ ~, ff~.~i @.~ ~~'-.d~ e ~ ~~-.-< p4~. ~ sw~' ~~ ~ ~ 4 L-§~ G,;~' &~, ~ _ ~ ALASBA OIL A1~TD GAS ~ 333 W. 7thAVENUE, SUITE 100 CO1~T5~RQATIOPIT COhII-IISSI01~ ; ANCHORAGE, ALASKA 99501-3539 ~` PHONE (907) 279-1433 , FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 ~~}•-~ Anchorage, AK 99519-6612 ~Q 3 ' Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBUH-05A Sundry Number: 309-321 Dear Mr. McMullen: ' ~x~~., L,'4~ ~~_ , !" " `` ~ ~~``~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair S~ DATED this ?~ day of September 2009 Encl. ~ STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM~ON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 . ~. ~' ~ t ~~~ ~/~S'~~ 1. Type of Request: ~ Abandon " ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensio-t ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 203-220~ 3. Address: ~^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20106-01-00~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU H-05A ~ Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028284 ~ 72.83' ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 12~ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12470' - 9018' - 12382' ~ 9017' _ None None Casin en th Size MD TVD Bur t Colla se Structural Conductor 1' 30" 1 0' 100' Surface 2299' 18-5/8" 2299' 2298' 930 870 Intermediate 7982' 13-3/8" x 9-5/8" 7982' 6407' 3450 1950 Production 1 9' 7" 1 8 48' 724 5410 Liner 1765' 4-1/2" 10705' - 12470' 84 5' - 9018' 8430 7500 Tieback 2227' 10-3/4" x 9-5/8" 2255' 1942' 5210 2480 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11170' - 12375' 8783' - 9017' 4-1/2", 12.6# 13Cr80 10720' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 10665' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: , Commencin O erations: September 20, 2009 ^ Oil ^ Gas ^ Plugged ~ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name J~~M ul , Title Engineering Team Leader ~^ „~ Prepared By Name/Number: Signature,o'~-~"'~ ` ,%~ ~ ~f ~ ~~ ~ ~ Phone 564-4711 Date ~ ,~,i ~~ Terrie Hubble, 564-4628 Commission Use Onl , Sundry Number: ~ , Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~ P Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~'3Sda ~s~- "~! rGS~ 'i~ Z 500 ~p SG- /`~ -~! n..-Lc.r 1 GS~' Chti`"'`/ Subsequent Form Required: ~ b- L f Q~ APPROVED BY A roved B. COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 ~ ~~ ~~ ~~~r~'~~~~ ~~~~ ~° ' ~A'~~OG ~~ ~ Submit In Duplicate ~ g ~~ d°i ~ `~~~~~ :%;~~ ~ TREE= ~ 4-1/16" WELI.HEAD= MCEVOY R~TUATOR = OTIS KB. ELEV = 64.13' BF. ELEV = 44.68' KOP = 7982' Max Angle = 94 @ 11745' Datum MD = 11301' Datum ND = 8800' SS ~ 9-5/8" CSG TIEBACK W/ BOT PBR 13-3/8" CSG, 68#, K-55, ID = 12.415" 18-5/8" CSG, 96.5#, K-55, ID = 17.655" • H~O ~ B SAF~TY N :**'4-1/2" CHROME TBG & LNR*** Planned CTD Sidetrack 2251' 2299' Minimum ID = 3.725" @ 10707' 4-1/2" HES XN NIPPLE TOPOF 7" SCAB LNR (ESTIMATm) ~--{ s$$O~ 7" SCAB LNR 26", L-80, ID = 6.276" P6~FORATION SUMMARY RFF LOG: SWS-BHCS ON 10l21/71 ANGLE AT TOP PERF: 94 @ 11770 Note: Refer to Roduction DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11600 - 11620 planned 2-7/8" 6 11770 - 11820 O 02/04/05 2-7/8" 6 11845 - 11870 O 01 /25/05 2-7/8" 4 12020 - 12375 O 02/09/04 MILLOUT WINDOW 7982' - 7998' Parent ~4-1/2" TBG, 12.6#, 13-CR .0152 bpf, ID = 3.958" ~ 7" LNR, 26", L-80, .0383 bpf, ID = 6.276" 10855~ ~ 9-5/S" X 13-3/8" EST TOP OF C~NBVT ~ 4-1/2" HES X NIP, ID = 3.813" 2251 ~ ~ 13-3/8" X 9-5/8" XO, ID = 8.681 " GAS LIFT MANDREIS ST MD N D DEV TY PE V LV LATCH PORT DATE 5 3276 3238 28 KBG-2 DMY BK 0 11/22/O6 4 5779 4929 50 KBG-2 DMY BK 0 11/22/06 3 7929 6373 47 KBG-2 DMY BK 0 02/11/04 2 9291 7371 44 KBG-2 DMY BK 0 02/11/04 1 10491 8276 41 KBG-2 DMY BK 0 02l11/04 7$43' ~-~ 9-5/S" X 7" BKR LNR TOP PKR ~9-5/8" CSG, 47#, L-80, 1~8.681" ~ 10644' 4-1/2" HES X NIP, ID = 3.813" 7 ~ 10665~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10688~ 4-1/2" HES X NIP, ID = 3.813" - I = mll to .8" 10713~ 4-1/2" WLEG, ID = 3.958" 10716~ 7" X 5" BKR LTP 17~ 5" X 4-1/2" XO 113UU~ ~~Top of Liner; Top of Cement 11310' Liner Bushing, ID = 2.3" BKR4-1/2" Mono-bore WhipstockH 11970~ 4-1/2" LNR, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 12470~ ~ A 12500' ~ 12382' ~B~ DATE REV BY COMMENTS DATE REV BY COMMENfS 02/18/77 ORIGINAL COMPLETION 11/22/O6 DAV/PAG GLV GO 02/18/04 SRBIKAK RIG SIDETRACK (H-05A) 02l27/04 RMWKA GLV GO 02/09/05 MW/TLH TBG ID CORRECTION 01/25/05 SGS/PJC PERFORATION 02/04/OS BMcL/PJ PERF/13-C LNR CORRECTION B 14100' r~ PRUDHOE BAY UNff WaL: H-056 PERMff No: R2032200 API No: 50-029-20106-01 SEC 21, T11 N, R13E, 773' FNL & 1265' FEL BP Exploratio~ (Alaska) • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ron Phillips CTD Engineer Date: September 08, 2009 Re: H-OSA Sundry Approval ~~d ~,1e PI Sundry approval is requested to abandon the H-OSA well by setting a whip stock and squeezing cement past it and into the open perforations. The history of H-OSA. H-OS was a rig sidetracked in February 2004. The difficult drilling in the top of Zone 3 and throughout Zone 21ed to a shortening of the wellbore by 300' resulting in only 355' of initial perforations. H-OSA POP'd with initial low oil rates, requiring an acid job to get the well to flow oil. Causes of the low initial production were thought to be due to the long SI time post drilling (58 days) that caused wellbore damage. First year production was disappointing. An end of life perforation job in 2005 gave the well a bit more life and H-OS continued to produce until the middle of 2007. The reason for side track is the increasing gas rate, which led to high GOR's shutting the well in, The well began to cycle with H-36A production and finally could not compete as a twinned producer with H-36A. The proposed plan for H-05B is to drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or around October 20, 2009. The existing perforations will be isolated by a cement down squeeze thru the 4- 1/2" WS. After the H-OSB well is drilled and liner is ran the liner cement will also be across the same perforations in H-OSA. 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 September 20, 2009) 1. S Dummy WS drift to 12,100' (Hit obstruction at 11,606' at 78° inclination) 2. S Dummy GLV's 3. O MIT-IA 4. C Mill XN nipple at 10,707' with LH motor to 3.80". 5. C Dummy WS drift to 12,100' . 6. O AC-LDS; AC-PPPOT-T 7. O PT MV, SV, WV 8. O Bleed gas lift and production flowlines down to zero and blind flange 9. O Remove wellhouse, level pad ~ bp 5~~-^~~~~~ 3 . g , . 7. Pump primary cement leaving TOC at TOL (11,300' ), 33 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL/GR/CCL log Rig Work: (scheduled to begin on October 15, 2009) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Set 4-1/2" Monobore WS at 11,970' at 90° Inc. 3. Down squeeze cement for P&A - 20 bbls of 15.8 ppg 4. Mi113.8" window at 11,970' and 10' of rathole. Swap the well to Gec 5. Drill Lateral: 4.25" OH, 2130' (15 deg/100 planned) with resistivity. 6 Run 3-3/16" x 2-7/8" L-801iner leavin TOL at 11 300' 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (~800') 11. Freeze protect well, RDMO ~~' ~1 ~'~r7 ~~~ft=`~,~ 1 ~~~ ~ ~~n ~ P~ ~ €~~ {~~A va 1 ,~~~y ~a~ .~~ ~ ~~~s ~ I~f ~~e~~ `~ ~nCU~ W P' ~~ ~ 6~C7~ Prdclve~ ~ welf ~o ~re~ lua tv ~,ndD~ ~r~r~~; ~ P q44- a ledr~ 1[, /~~ ~//J` ~~ ~ ~ a~~' `~ P well ~~ ~~~~~ , /~ fiG c ~ ~r~ ~~? ty . • • Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's 3. RU test separator, flow test well Ron Phillips CTD Engineer 564-5913 CC: Well File Sondra Stewman/Terrie Hubble ~_ ~ • 4-1/16" WELLH~AD = MCEVOY ALTUATOR = OTIS KB. a.EV = 64.13' BF. ELEV = 44.68' KOP = 7982' Max Angle = 94 @ 11745' ~tum MD = 11301' Datum ND = 8800' SS ~9-5/8" CSG TIEBACK W/ BOT PBR 13-3/S" CSG. 68#, K-55, ID = 12.415" 18-5/8" CSG, 96.5#, K-55, ID = 17.655" I 2130' I Minimum ID = 3.725" @ 10707' 4-1/2" HES XN NIPPLE OF 7" SCAB LNR (ESTIMAT~) H 6$30' 7" SCAB LNR, 26", L-80, ID = 6.276" ~--{ 7$3Q' P6~FORATION SUMMARY R~ LOG: SWS-BHCS ON 10/21/71 ANGLE AT TOP PERF: 94 (p~ 11770 Note: Refer to Production DB for historical perf data SQE SPF IM'~2VAL Opn/Sqz DATE 2-7lS" 6 11770 - 11820 O 02/04/OS 2-7/8" 6 11845 - 11870 0 01 /25/05 2-7/8" 4 12020 - 12375 O 02/09/04 ¢sv I-i 8018' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 10011' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 1644' ~--~4-1/2" HES X N~, ID = 3.813" ~ 10665' 7" X 4-1/2" BKR S-3 PKR ID = 3.875" 10688' 4-1/2" HES X NIP, ID = 3.813" ~07~7' 4-1/2" HES XN NIP, ID = 3.725" 10713' 4-1/2^ w~EG, ID - 3.958" 10716~ 7" X 5" BKR lNR TOP PKR 10733' -~5" X 4-1/2" XO ,~ 12382' ~~ 1!2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" H 10720' ~ 7" INR, 26", L-80, .0383 bpf, ID = 6.276" 10855' 4-1/2" LNR 12•6#, 73-CR, .0152 bpf, ID = 3.958" DATE REV BY COMMENfS DATE REV BY COMMEMS 02/18/77 ORIGINAL COMPLETION 11/22/06 DAV/PAG GLV GO 02/18/04 SRBIKA RIG SIDETRACK (F~4~05A) 02/27/04 RMWKA GLV GO 02/09/05 MW/TLH TBG ID CORRECTION 01/25/05 SGS/PJC PERFORATION 02/04/05 BMcL/PJ PERFH3-C LNRCORRECTION PRUDF~E BAY UNff WELL: 1i-05A PERMff No: R2032200 API No: 50-029-20106-01 SEC 21, T11 N, R13E, 773' FNL & 1265' F~ BP Exploration (Alaska) 1065' H 9-5l8" X 13-3/8" EST TOP OF CE~ABVT 2209' 4-1/2" HES X NIP, ID = 3.813" 2251' H 13-3/8" X 9-5/8" XO, ID = 8.681" GAS LIFf MANDR~S ST MD TVD DEV TYPE VLV LATCH PORT OATE 5 3276 3238 28 KBG-2 DMY BK 0 11/22/06 4 5779 4929 50 KBG-2 DMY BK 0 11/22/06 3 7929 6373 47 KBG-2 DMY BK 0 02/11/04 2 9291 7371 44 KBG-2 DMY BK 0 02/11/04 1 10491 8276 41 KBG-2 DMY BK 0 02/11/04 7$43' ~ 9-5/8" X 7" BKR LNR TOP PKR ~~LOUT WINDOW 7982' - 7998' l s ~ Ramirez, Darlene V (DOA) From: Foerster, Catherine P (DOA) Sent: Sunday, September 20, 2009 2:00 PM To: Ramirez, Darlene V (DOA) Subject: Re: 309-321 Approve Sent from my iPhone On Sep 18, 2009, at 10:28 AM, "Ramirez, Darlene V(DOA)" <darlene.ramirezC~alaska.gov > wrote: > «S45C-209091808520.pdf» > The message is ready to be sent with the following file or link > attachments: > > S45C-209091808520.pdf > > > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of ~le attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C-209091808520.pdf> 5ch~umberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~`f Alaska Data & Consulting Services r' 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: ` ~ ~ {,.I r. 1. f ~l~P. NO.5020 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 12/29/08 .,oo s Lo Descri tion 4-20/M-35 12014059 STATIC SURVEY/PERF Date BL Color CD W-18 11968978 PRODUCTION PROFILE _ 12/11/08 1 1 Y-07A 12103704 INJECTION PROFILE _ ~ 12/20/08 1 1 P2-35 12031533 SCMT 12/18/08 ~ 1 M-16 12111931 SCMT _ ~ L~ 12/18/08 1 1 P2-15A 40015006 OH MWD/LWD EDIT 12/19/08 1 1 P2-15AP63 40015006 OH MWD/LWD EDIT ~`~ 04/01/07 2 1 P2-15AP62 40015006 OH MWD/LWD EDIT a ~ 03/27/07 2 ~~ ~ ~ 0~ 03/24/07 2 1 P2-15APB1 40015006 OH MWD/LWD EDIT 1 W-31A 40017846 OH MWD/LWD EDIT ~- ~ 03/22!07 2 1 W-29 11549353 CH EDIT (USIT) -' ~ 09/27/08 2 1 H-O5A AXBD-00002 MCNL 12/18/06 1 11/20/08 1 1 ~ l g PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 • 12/08/08 ~~~~~m~~r~~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: BetFi wpu . r~ti ,r NO.4995 Company: State of Alaska Alaska Oil & Gas Cons Comm `~~~„~ ~~ ry -~ ?UUtt Attn: Christine Mahnken UU 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ ,,,. new...:...:.... .,_._ R-03A 4994 INJECTION PROFILE (REVISED) 10/08/08 1 1 13-23A 4994 INJECTION PROFILE 10/21/08 1 1 01-26A 4994 SCMT 11/13/08 1 1 D-29 4994 USIT 10/19/08 1 1 15-02B 4994 MEM PROD PROFILE - 11/25/08 1 1 H-05A 4994 MEM PROD & INJ PROFILE 11/20/08 1 1 E-32A 4994 SCMT - ( 11/04/08 1 1 12-17 4994 PRODUCTION LOG Q L( 11/04!08 1 1 P2-41 4994 PRODUCTION LOG - 11/07/08 1 1 1~•29/M-25 4994 PRODUCTION LOG (p _ 11/04/08 1 1 MPC-05A 4994 MEM LDL r 11/15/08 1 1 L-114A 4994 USIT = (( s 11/03/08 1 1 A-07 4994 PRODUCTION PROFILE ~ - ( ~• 11/27/08 1 1 07-18 4994 INJECTION PROFILE ~ _ - 12/02/08 1 1 15-12B 4994 MEM PROD PROFILE ~p - 11/27/pg 1 1 4-40/P-43 4994 MEM LDL (~j ` - ~ ',~ s. 11/26/08 1 1 N-14B 4994 MCNL -(~'jsv ~ 09/20/08 1 1 01-21A 4994 MCNL 09/29/08 1 1 E-29A 4994 MCNL - 09/01/08 1 1 PLEASE ACKNAWI Ffl(:F RF CFIDT RV Ct!_w ~lr nun ocr~ ~owuw~n r.w.~ i.~.,.. r..... -' BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ •I ' ~ I ~) Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 8 8 ATTN: Beth Received by: ~~ C~ ~C • ~~, -~ ~ .,. ,`", ~, Sxa may. MICROFILMED 03/0112008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_InsertsiMicrofilm_Marker.doc H-05A (PTD #2032200) Classified as Problem Well . All, Well H-05A (PTD #2032200) has been found to have sustained casing pressure on the IA. The wellhead pressures were 2070/2120/vac/0+/0+ on 11/18/06. A TIFL was conducted on 11/18/06 and determined a failure the next day due to IA pressure buildup. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: DGL Vs 3. DHD: Re- TIFL A well bore schematic has been included for reference. «H-05A.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, }lnna CDu6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 8t~NED DEC (;? 2005 Content-Description: H-05A.pdf Content-Type: application/octet-stream Content-Encoding: base64 I of 1 11/22/2006 9: 16 AM TREE = WELLHEAD = ACTUA TOR = KB. ELB! = BF. ELB! = KOP = 7 Max Angle = 94 @ 11745' DatumMD= 11301' Datum TVD = 8800' SS 19-518" CSG TIEBACK WI BOT PBR '13-3/8" CSG, 68#, K-55, 10 = 12.415" I 118-518" CSG, 96.5#, K-55, ID = 17.655" I H-05A I SAFETY A: 4-1/2" CHROME TUBING & LINER. 1065' - 9-5/8" X 13-3/8" EST TOP OF CEMENT 2209' -\4-1/2" HES X NIP, 10 = 3.813" I 2251' -113-3/8" X 9-5/8" XO, ID - 8.681" I GAS LIFT MANDRELS ST MD TVD DB! TYPE VLV LATCH PORT DATE 5 3276 3238 28 KBG-2 DOME BK 16 02/27/04 4 5779 4929 50 KBG-2 SO BK 20 02/27/04 3 7929 6373 47 KBG-2 DMY BK 0 02111/04 2 9291 7371 44 KBG-2 DMY BK 0 02/11/04 1 10491 8276 41 KBG-2 DMY BK 0 02/11/04 Minimum ID = 3.725" @ 10707' 4-112" HES XN NIPPLE 1 TOP OF 7" SCAB LNR (ESTIMA TED) I 6830' 17" SCAB LNR, 26", L-80, 10 = 6.276" I 7843' - 9-5/8" X 7" BKR LNR TOP PKR I 2-7/8" 2-7/8" 2- 7/8" PERF ORA TION SUMMARY REF LOG: SWS-BHCS ON 10/21/71 ANGLE AT TOP PERF: 94 @ 11770 Note: Refer to Production DB for historical perf data INTERVAL Opn/Sqz DATE 11770 - 11820 0 02/04/05 11845-11870 0 01/25/05 12020 - 12375 0 02/09/04 MILL OUT WINDOW 7982' - 7998' EZSV -4-1/2" HES X NIP, 10- 3.813" I - 7" X 4-112" BKR S-3 PKR, 10 = 3.875" -14-112" HES X NIP, ID= 3.813" I 6 6 4 9-5/8" CSG, 47#, L-80, ID = 8.681" I 17" LNR, 29#, N-80, ,0371 bpf, ID = 6.184" I 11650' 14-1/2" TBG, 12.6#, 13-CR. .0152 bpf, 10 = 3.958"! 1 7" LNR, 26", L-80, .0383 bpf, ID = 6.276" ! 14-1/2" LNR, 12.6#, 13-CR, .0152 bpf, 10 = 3.958'" DA TE REV BY COMMENTS 02118177 ORIGINAL COMPLETION 02118/04 SRBlKAK RIG SIDETRACK (H-05A) 02/27/04 RMH/KA GLV ClO 02/09/05 MWITLH TBG ID CORRECTION 01/25/05 SGS!PJC PERFORATION 02/04/05 BMcUPJ PERF/13-C LNR CORRECTION OA TE REV BY COMMENTS PRUDHOE SA Y UNfT WELL: H-05A PERMfT No: 2032200 API No: 50-029-20106-01 SEC 21, T11N, R13E. 773' FNL & 1265' FEL BP Exploration (Alaska) . . WELL LOG TRANS MITT AL [}05 - !;f:rD To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 I b ~f) f?:J RE: MWD Formation Evaluation Logs H-05A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 H-05A: LAS Data & Digital Log Images: 50-029-20106-01 1 CD Rom ~ ~y199 ~ II M~(L~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2032200 Well Name/No. PRUDHOE BAY UNIT H-05A Operator BP EXPLORATION (ALASKA) INC 5'¡;o.[ A6 JI'r\ ~'l API No. 50-029-20106-01-00 MD 12470 /' TVD 9018../ Completion Date 2/11/2004 -' Completion Status 1-01L Current Status 1-01L UIC N ----~~~..-_.~..- ~---_.....__.._---_.._----_._-- REQUIRED INFORMATION Mud Log No Samples No Directional surv~\ (data taken from Logs Portion of M~ata Maint ------.. DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES, DIG / GR / RES / NEU / DEN Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name , . Log Log Scale Media Run No Interval OH I Start Stop CH Received Comments ED D ' . Directional Survey 7908 12470 2/26/2004 .,Sl4f C\. ~ (.... \ i ED D ~ Ift\\ Directional Survey 7908 12470 2/26/2004 MWD I ~Pt Directional Survey 7908 12470 2/26/2004 ~Pt Directional Survey 7908 12470 2/26/2004 MWD "ED D Lis 12433 Induction/Resistivity 2-6 7795 12413 Open 2/26/2004 GR, EWR4, CNP, SLD, ROP 'ED D Lis 12433 Neutron 2-6 7795 12413 Open 2/26/2004 GR, EWR4, CNP, SLD, rI ROP ED D Lis 12433 Density 2-6 7795 12413 Open 2/26/2004 GR, EWR4, CNP, SLD, ROP . ED D Lis 12433 Rate of Penetration 2-6 7795 12413 Open 2/26/2004 GR, EWR4, CNP, SLD, ... ROP "Rpt II nd uction/Resistivity } ~ 2-6 7795 12413 Open 2/26/2004 GR, EWR4, CNP, SLD, L [5 'If 11" J ¡ ROP ~pt Neutron 2-6 7795 12413 Open 2/26/2004 GR, EWR4, CNP, SLD, I l~)if J- ROP I Ú Rpt Density 2-6 7795 12413 Open 2/26/2004 GR, EWR4, CNP, SLD, R.I, of P,"'t"';O{ ROP Rpt 2-6 7795 12413 Open 2/26/2004 GR, EWR4, CNP, SLD, I ~ ROP Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2032200 MD 12470 TVD 9018 ADDITIONAL INFORIV!:iTION Well Cored? Y AiD Chips Received? ffN- Analysis Received? YÌÑ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Well Name/No. PRUDHOE BAY UNIT H-05A Operator BP EXPLORATION (ALASKA) INC Completion Date 2/11/2004 Completion Status 1-01L Current Status 1-01L Daily History Received? @ D/N Formation Tops h Date: API No. 50-029-20106-01-00 UIC N ) 5 {~J ~-~--~ . . " .. STATE OF ALASKA I ALAS~L AND GAS CONSERVATION COMM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25,105 20AAC 25,110 21. Logs Run: DIR / GR I RES, DIG I GR / RES I NEU I DEN CASING, LINER AND CEMENTING RECORD CASING SeTTING DEPTH MD SETTINaDePTH TV!> HoLE' SIZE WT.·PI;R FT. GRADE Top BOTTOM Top BOTTOM 81ZE 30" Conductor Surface 100' Surface 100' 36" 18-5/8" 96.5# K-55 Surface 2299' Surface 2298' 24" 13-3/8" x 9-518" 68# / 47# K-55 I N-80 Surface 7982' Surface 6407' 12-1/4" 9-518" x 10-314" 47# 155.5# L-80 I N-80 28' 2255' 28' 1942' 12-1/4" 7" 26# L-80 26' 10855' 26' 8548' 8-1/2" 4-1/2" 12.6# 13Cr80 10705' 12470' 8435' 9018' 6-1/8" 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2-7/8" Gun Diameter, 4 spf MD TVD 12020' - 12375' 9023' - 9017' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 773' SNL, 1265' WEL, SEC. 21, T11N, R13E, UM Top of Productive Horizon: 3778' NSL, 5011' WEL, SEC. 16, T11 N, R13E, UM Total Depth: 4014' NSL, 4292' WEL, SEC. 16, T11N, R13E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 643313 y- 5960015 _ Zone- ASP4 TPI: x- 639470 y- 5964494 Zone- ASP4 ------~- Total Depth: x- 640184 y- 5964744 Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. MD 26. Date First Production: March 22, 2004 Date of Test Hours Tested 3/25/2004 6 Flow Tubing Casing Pressure Press. 230 1,060 One Other 5. Date Comp" Susp., or Aband. 2/11/2004 6. Date Spudded 1/26/2004 7. Date T.D. Reached 2/712004 8. KB Elevation (ft): 72.83' 9. Plug Back Depth (MD+ TVD) 12382 + 9017 10. Total Depth (MD+TVD) 12470 + 9018 11. Depth where SSSV set " (Nipple) 2209' MD 19. Water depth, if offshore NIA MSL SIZE 4-1/2", 12.6#, 13Cr80 TVD 25. 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-220 13. API Number 50- 029-201 06-01-00 14. Well Name and Number: PBU H-05A 15. Field / Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028284 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PUllED RECORD 265 sx Permafrost II 6200 sx Permafrost II 875 sx Class 'G' (& 465 sx AS I) 9-5/8" Tieback: 392 sx Arcticset I 169 sx Class 'G', 140 sx Class 'G' 225 sx Class 'G' DEPTH SET (MD) 10720' PACKER SET (MD) 10665' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-BBl GAs-McF WATER-BBl 124 746 55 PRODUCTION FOR TEST PERIOD + CALCULATED + 24-HoUR RATE Oll-BBl 495 GAs-McF 2,982 WATER-BBl 220' CHOKE SIZE I GAS-Oil RATIO 1250 6,028 Oil GRAVITY-API (CORR) 26.5 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None : ~~~ ,~' ì Form 10-407 Revised 12/2003 O~'G1~\LA,L CONTINUED ON REVERSE SIDE r..!·,t'r~ tsfL n ;-.;, _,uvd'V APR3 2U~ t<:>'V -28. . GEOLOGIC MARKERS·' 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10855' 8548' None Shublik 10900' 8582' Sadlerochit 10953' 8622' Top CGL Base CGL 11200' 8804' 11292' 8867' 26N 11402' 8938' 25N 11474' 8975' 22N 11633' 9026' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble~MI·g J ~~ Title Technical Assistant Date 03· Ô 0 ·DL( PBU H-05A 203-220 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 IGINAL Legal Name: H-05 Common Name: H-05A -------...-...--¡--.-.-.....-..-.-.-.-- Test Date' Test Type 1/24/2004 FIT 1/25/2004 FIT 2/2/2004 FIT Test Depth (TMD) (ft) 7,982.0 (ft) 10,855.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) (ft) 6,409.0 (ft) 8,548.0 (ft) AMW 11.20 (ppg) 11.20 (ppg) 8.70 (ppg) ..........-.--.....---...'............-..... Surface Pressure (psi) 432 (psi) 578 (psi) Leak Off Pressure (BHP) (psi) 4,161 (psi) 4,441 (psi) Page 1 of 1 EMW (ppg) 12.50 (ppg) 10.00 (ppg) e e Printed: 2/16/2004 9:41 :32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/13/2004 1/14/2004 1/15/2004 02:30 - 05:00 05:00 - 19:00 19:00 - 20:30 20:30 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 - 12:30 12:30 - 15:00 15:00 - 18:30 18:30 - 19:00 19:00 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 09:00 09:00 - 10:00 10:00 - 13:00 e e BP EXPLORATION Operations Summary Report 2.50 MOB P PRE H-05 H-05A REENTER+COMPLETE Start: NABORS ALASKA DRILLING I Rig Release: NABORS 2ES Rig Number: From - To j Hours! Task I Code! NPT Phase __1____._.__...___. __..~ ......._______ 14.00 MOB P 1.50 MOB P PRE PRE 3.50 RIGU P 3.00 RIGU P PRE PRE 0.50 RIGU P PRE 1.50 RIGU P PRE 1.00 KILL P 3.00 KILL P DECOMP DECOMP 0.50 WHSUR P 1.00 WHSUR P DECOMP DECOMP 2.00 WHSUR P DECOMP 2.50 BOPSURP 3.50 BOPSUR P DECOMP DECOMP 0.50 BOPSUR P 1.00 WHSUR P 1.00 PULL P DECOMP DECOMP DECOMP 1.00 PULL P DECOMP 2.00 PULL P DECOMP 1.50 PULL P DECOMP 0.50 PULL P 1.00 PULL P DECOMP DECOMP 1.00 PULL P DECOMP 1.00 PULL P DECOMP 1.00 FISH P DECOMP 3.00 FISH P DECOMP 1.00 FISH P 3.00 WHSUR P DECOMP DECOMP Page 1 of 18 1/13/2004 2/11/2004 Spud Date: 9/27/1971 End: 2/11/2004 Description of Operations .__...pn..,.,.. Rig Down Rig Floor And Can-Rig Top Drive - Bridle Up - Blow down the pits - Load out the shop - Move the pits and the cuttings tank out of the way of the Sub - Lay down Mast. Move Sub off of L2-14 and over to H-05A. Spot Sub over H-05A. Move Pits, Camp and Shop over to H-05A Raise Derrick and cattle chute. Bridle down and pin the blocks Rig up the floor and top drive. Spot the pits, camp and the shop. Pre-Spud meeting with the rig crew on tower. Accept Rig: 0300 1/14/2004 Install Secondary Annulus Valve. Pull BPV with Lubricator. 0 psi tbg. 0 psi ann Rig Up circulating lines and test surface equipment Test lines to 3,500 psi. Displace diesel out fo the wellbore with seawater - 6 bpm @ 420 psi. Dry rod in the TWC and test from below to 1,000 psi. Blow down surface equipment and rig down the circulating lines. Nipple down the tree and adapter flange. Verify the tubing hanger threads - 7" IJ4S. Function test the lock down screws. Nipple up the BOPE. Make up the test joint. Pressure test the BOPE and all related valves. 250 psi low, 3,500 psi high. The witness of the test was waived by John Spaulding of the AOGCC. Lay down the test joint. Blow down surface equipment. Rig up DSM lubricator. Pull TWC. Rig down lubricator. PJSM. Back out the lock down screws. Pull hanger to the rig floor. P/U - 150K, Max pull - 190K. Monitor the well. Static. Rig up the 5-1/2" tubing handling equipment. Rig up the control line spooling unit. PJSM. Lay down the 5-1/2" 17# tubing from -8,150' to 6,818' while spooling control lines. PJSM. Lay down the 5-1/2" 17# tubing from 6,818' to SSSV while spooling control lines. Recovered 28 rubber bands and 2 SS bands. Rig down spooling unit. PJSM. Lay down tubing. Ran into a restriction - 75K over pull. GLM @ 3,314' hung up on restriction and suspected collapsed casing @ 107' calculated based on tubing measurement Free tubing by applying Top Drive weight. Rotate tubing and try to work through restriction. Unsuccessful. RU and Pressure test the casing to 2,500 psi and hold for 30 minutes. Good test Rig down the tubing handling equipment and clear the floor. Pick up fishing tools. RIH with Fishing BHA and 5-1/2" on 4" DP to 8,150'. PU- 140K, SO - 115K. Drop tubing on bottom. Top of fish @ 3,182' POH from 3,182'. LD fishing BHA. ND BOP's and tubing spool. Weld Emergency slips to 9-5/8" Csg. Printed: 2/16/2004 9:41: 39 AM e e Page 2 of 18 BP EXPLORATION Operations Summary Report Legal Well Name: H-05 Common Well Name: H-05A Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES I I' I Date From - To ! Hours Task! Code NPT ... ._ ._ __n__ __..___h__ 1/15/2004 13:00 - 15:30 2.50 BOPSURP 15:30 - 17:00 17:00 - 20:00 1.50 FISH P 3.00 FISH P 1/16/2004 20:00 - 21 :00 1.00 FISH P 21 :00 - 23:30 2.50 CLEAN P 23:30 - 00:00 0.50 CLEAN P 00:00 - 02:30 2.50 CLEAN P 02:30 - 03:30 1.00 CLEAN P 03:30 - 04:15 0.75 FISH P 04: 15 - 05:00 0.75 FISH P 05:00 - 05:30 0.50 FISH P 05:30 - 07:30 2.00 FISH P 07:30 - 09:30 2.00 FISH N 09:30 - 12:30 3.00 FISH P 12:30 - 13:30 1.00 FISH P 13:30 - 16:00 2.50 FISH P 16:00 - 17:00 1.00 FISH P 17:00 - 20:30 3.50 FISH P 20:30 - 21 :00 0.50 FISH P 21 :00 - 23:00 2.00 FISH P 23:00 - 23:30 0.50 FISH P 23:30 - 00:00 0.50 FISH P 00:00 - 05:00 5.00 FISH P 05:00 - 05:30 0.50 FISH P 05:30 - 07:30 2.00 FISH P 07:30 - 09:00 1.50 FISH P 09:00 - 10:30 1.50 FISH P 10:30 - 12:00 1.50 FISH P 12:00 - 14:00 2.00 FISH P 14:00 - 16:30 2.50 FISH P 16:30 - 21 :00 4.50 FISH P 21 :00 - 00:00 3.00 FISH P 00:00 - 01 :30 1.50 FISH P 01 :30 - 03:00 1.50 FISH P 03:00 - 08:00 5.00 FISH P 1/17/2004 1/18/2004 1/13/2004 2/11/2004 Spud Date: 9/27/1971 End: 2/11/2004 Start: Rig Release: Rig Number: Phase DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP HMAN DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Description of Operations NU BOPE and test to 2,500 psi. Install secondary annulus valve. PJSM. MU 9-5/8" spear. Engage 9-5/8" (11-3/4" OD) Thermal Case @ 28'. Attempt to pull free @ 400K. Unsuccessful. Steam well and work pipe. Unsuccessful. LD Fishing BHA. RIH w/ Mule Shoe to 2,151' Circ Seawater from pits @ 2,151. 10.5 bpm @ 350 psi Displace well to 140 degree seawater. 6.5 bpm @ 100 psi. Circulate heated seawater - 10.5 bpm, 350 psi Blow down Top Drive. POH from 2,150'. Change out handling equipment. MU fishing spear and bumper sub. RIH on single. Pull on fish - 400K. Total gain - 11". RD spear and bumper sub. RU for swedging operations. R/U 6-5/16" Swedge. RIH on DP. Tag tight spot @ 139.5'. POH. MU 6-5/16" Swedging BHA. Tugger line hung up on Top Drive causing laceration to face of floorhand. Perform incident investigation. Swedge with 6-5/16" @ 139.5'. Work through tight spot. POH. LD 6-5/16". MU 7-5/16" swedge. RIH. Work area from 139' to 141'. Circ heated seawater - 11.5 bpm, 470 psi. Blow down top drive. POH. LD 7-5/16" swedge. PU 7-15/16" swedge. Work tight areas from 39' to 41' and 139' to 144'. RIH to 180'. POH. Change out swedge from 7-15/16" to 8-3/8". RIH Swedge tight spots between 40' to 95' and from 139' to 144'. POH. Change swedge to 8-1/2". RIH Swedge tight spot @ 40' Swedging operations w/ 8-1/2". Tight spots 40' to 45',85' to 89' and 139' to 144'. Circulate110 degree seawater. LD 8-1/2" Swedging BHA, standing back collars. Clear floor. MU 5-1/2" spear. RIH to 3,093'. PU - 80K, SO - 80K, ROT- 80K Cut and slip drilling line. Service top drive. RIH from 3,093' to 3,188', latch fish. PU - 145K, SO - 120K. POH from 3,188 to 1,793' POH from 1,793 to top of 5-1/2" fish. LD spear. RU 5-1/2" handling equipment. LD 5-1/2" tubing from 5,000' to 2,260'. Circulate 120 degree seawater. 10.5 bpm, 730 psi LD 5-1/2" tubing from 2,260' to surface. RD handling equipment. Clear floor. LD total of 206 jts + 36' cut jt. RU 9-5/8" spear. RIH and latch 9-5/8" casing @ 28'. Pull 400K. No movement. RD spear. RU 8.25" OD mechanical cutter. Work through tight spot @ 40'. Tag up at 139'. Wok pipe - unsuccessful. POH, LD cutter. MU mule shoe. RIH to 1,965'. MU DC's, Bumper Sub and 8.59" Swedge. RIH with 8.59" Swedging BHA. Work pipe @ 40' - unsuccesful. LD 8.59", PU 8.5". RIH tag @ 140'. Printed: 2/16/2004 9:41 :39 AM e e BP EXPLORATION Operations Summary Report Page 3 of 18 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-05 H-05A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 1/13/2004 2/11/2004 Spud Date: 9/27/1971 End: 2/11/2004 Date From - To Hours ; Task Code NPT Phase Description of Operations ._m____.__.__.____.._..___ -~--_.__._---- -- .._". ..... ____._n ____n___._"__________.__.._..___ ._--------- 1/18/2004 03:00 - 08:00 5.00 FISH P DECOMP Swedge @ 140' - successful. 08:00 - 09:00 1.00 FISH P DECOMP LD swege BHA. PU casing cutter and dummy run to 185'. 09:00 - 10:30 1.50 FISH P DECOMP Handle BHA, LD cutter and bumper sub. POH from 1,925'. LD mule shoe. 10:30 - 11 :30 1.00 FISH P DECOMP MU cutter, 2 stds DC, 4" single to 200'. Cut 10-3/4". 1 ,000 psi, 50 rpm, TQ - 5K, PU - 45K, SO - 45K. 11 :30 - 12:30 1.00 FISH P DECOMP Circulate and observe well. 12:30 - 13:00 0.50 FISH P DECOMP POH. LD cutter. 13:00 - 16:30 3.50 FISH P DECOMP MU 9-5/8" spear. Engage 9-5/8" x 11-3/4" Thermal casing. PU 400K. Work pipe - jar up. Circ @ 11 bpm 180 psi. Casing moved 4.7'. 16:30 - 17:00 0.50 FISH P DECOMP LD spear. MU cutter assembly. 17:00 - 18:30 1.50 FISH P DECOMP Cut thermal casing @ 58'. 18:30 - 21 :00 2.50 FISH P DECOMP POH. LD Cutter. MU Spear. Engage top of fish. Jar and work pipe to 375K. Recover 36' collapsed and split section from cut. 21 :00 - 22:00 1.00 FISH P DECOMP LD spear. MU cutter. RIH to 98'. 22:00 - 00:00 2.00 FISH P DECOMP Cut thermal casing @ 98'. LD cutter. MU spear. 1/19/2004 00:00 - 02:00 2.00 FISH P DECOMP RIH with spear. Engage fish @ 98'. Jar and work pipe to surface - 400K. LD spear. LD 39.43' section of split and collapsed thermal casing from cut. 02:00 - 03:30 1.50 FISH P DECOMP MU cutter. RIH to 143'. Attempt cut 9-5/8" x 11-3/4" thermal casing. 03:30 - 07:00 3.50 FISH P DECOMP MU spear BHA. RIH. Engage fish. POH. LD section. Joint unscrewed from 9-5/8" connection. 49.9' - pin end came out. PU -175K. 07:00 - 09:30 2.50 FISH P DECOMP MU spear. RIH to 154'. Engage fish. POH. LD 48' section with 21' of 10-3/4" cut joint. Clear floor. Redress spear. 09:30 - 10:30 1.00 FISH P DECOMP MU Spearing BHA. RIH to 201'. Latch fish. PU - 175K, pipe free. 10:30 - 11 :00 0.50 FISH P DECOMP Pressure up to 700 psi. PU and unsting. CBU @ 7 bpm. Observe Rapid flow increase. Shut in well, CSG - 100 psi. DP - 150 psi. 11:00-13:00 2.00 FISH P DECOMP Circulate out Arctic Pack through the choke - 3bpm, 400 psi. 13:00 - 17:00 4.00 FISH P DECOMP Circulate while reciprocating pipe. Initial - 3 bpm, 80 psi. Final - 11 bpm, 200 psi. Monitor well- okay. 17:00 - 19:00 2.00 FISH P DECOMP Circulate 70 bbls of diesel & 45 bbls of soap pill - 5 bpm, 140 psi. Monitor well - dead. 19:00 - 21:00 2.00 FISH P DECOMP POH with BHA to top of 10-3/4" csg fish. Clear floor. 21 :00 - 22:00 1.00 FISH P DECOMP RU 10-3/4" handling equipment. Release from spear. LD20' 10-3/4" cut joint and spear. 22:00 - 00:00 2.00 PULL P DECOMP LD 10-3/4" csg from 1,943' to 997'. 1/20/2004 00:00 - 07:00 7.00 PULL P DECOMP Lay Down 10-3/4" x 9-5/8" Casing From 997' - Clear Floor. 1 0-3/4" total: 44 jts + 1 cut joint 9-5/8" total: 2 jts + Seal Assembly 07:00 - 07:30 0.50 PULL P DECOMP Break And Lay Down Baker Fishing Tools 07:30 - 08:30 1.00 EVAL P DECOMP Close Blind Rams And Attempt To Test Casing - Observe Communication Between 18 5/8" X 13 3/8" Annulus - With 650 Psi. In 133/8" Casing Annulus Pressure Increased To 600 Psi. - Bleed Pressure To 0 Psi. And Open Blind Rams 08:30 - 11 :00 2.50 EVAL C TIEB1 Make Up 81/2" Bit And 133/8" Casing Scraper - RIH Tag Top Of PBR At 2,134' - No Tights Spots During Trip In Hole - String Weight At 80,000 Ibs. Printed: 2/16/2004 9:41:39 AM e e BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/20/2004 1/21/2004 H-05 H-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To I Hours Task. Code NPT Page 40f 18 1/13/2004 2/11/2004 Spud Date: 9/27/1971 End: 2/11/2004 Start: Rig Release: Rig Number: Phase 11 :00 - 12:00 12:00 - 13:30 1.00 EVAL C 1.50 EVAL C TIEB1 TIEB1 13:30 - 17:00 3.50 EVAL C TIEB1 17:00 - 18:30 1.50 EVAL C TIEB1 18:30 - 20:00 1.50 EVAL C TIEB1 20:00 - 00:00 4.00 BOPSURC TIEB1 00:00 - 01 :00 1.00 BOPSURC TIEB1 01 :00 - 01 :30 0.50 BOPSURC TIEB1 01 :30 - 03:00 1.50 EVAL C TIEB1 03:00 - 04:00 1.00 EVAL X DFAL TIEB1 04:00 - 05:45 1.75 EVAL X DFAL TIEB1 05:45 - 08:00 2.25 EVAL C TIEB1 08:00 - 09:00 1.00 EVAL C TIEB1 09:00 - 13:00 4.00 EVAL C TIEB1 13:00 - 15:30 2.50 EVAL C TIEB1 15:30 - 17:30 2.00 EVAL C TIEB1 17:30 - 20:00 2.50 EVAL C TIEB1 20:00 - 20:30 0.50 EVAL C TIEB1 Description of Operations ... -..- .~... -- Circulate And Pump Hi-Vis Sweep POH With 133/8" Casing Scraper From 2,134' To 1,710'- Make Up 13 3/8" RTTS Tool Set HOWCO RTTS Tool At 35' - Attempt To Test Casing Below RTTS No Good Have Communications With Annulus - RIH Set RTTS At 227' - Test Casing At 2,500 Psi. For 10 Minutes (Test Good) - POH And Set RTTS At 133' - Test Casing (Test Good) - POH Set RTTS At 78' - Attempt To Test Casing (No Good) - RIH And Set RTTS At 105' - Test Casing (Good Test) Drain BOP Stack And POH From 1,840' To 1,720' - Lay Down HOWCO RTTS Tool- POH With 133/8" Casing Scraper From 1 ,720' To 309' Change Out Handling Equipment - POH With BHA From 309' - Clean Up Rig Floor Hold Pre-Job Safety Meeting - Pull Wear Bushing - Install Test Plug - Rig Up Testing Equipment - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector John Spaulding - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Choke Manifold At 250 Psi. Low And 3,500 Psi. High Test BOP And Related Equipment - Test Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment Pull Test Plug - Install Wear Bushing And Energize LDS - Blow Down Choke Manifold And Kill Lines - Clear Rig Floor Hold Pre-Job Safety Meeting With Schlumberger - Rig Up Schlumberger - Make Up Logging Tools And Equipment Test Schlumberger Logging Tools - Sonic Logging Tool Not Talking To Computer Lay Down Logging Tools And Trouble Shoot Problem - Change Out Logging Tools Logging Run NO.1 RIH With Cement Bond Log And Collar Locator To 2,150' - POH Logging Up To Surface Lay Down Cement Bond Logging Tools - Make Up Junk Basket And 8.5" Gauge Ring Logging Run NO.2 RIH With 8.50 Gauge Ring, And Junk Basket To 8,150' - POH - Clean Out Junk Basket Half Full Of Seals And Coating From Thermal Casing Logging Run NO.3 RIH With 8.50 Gauge Ring, And Junk Basket To 8,150' - POH - Clean Out Junk Basket Lay Down Junk Basket And Gauge Ring - Make Up Logging Tools For Running 9 5/8" EZ-Drill Bridge Plug Logging Run No.4 RIH With CCL-CPST And Haliburton EZ-Drill Packer (No.1) To 8,150' - Tie In Log And Set Top Of EZSV At 8,018' WLM (4 Feet Above Casing Collar) - Log Up 100 Feet - RIH Tag EZSV Confirm Setting Depth - POH With Logging Tools Close Blind Rams - Attempt To Establish Injection Rate At .5 BPM With Maximum Pressure At 1,500 Psi. (No Good) - Bleed Off Pressure Printed: 2/16/2004 9:41 :39 AM e e Page 5 of 18 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I Date ! From - To I H-05 H-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Hours Task; Code NPT: Phase _____ ._n.__.____ ."__U___ ..._.__ ........ .." .0__ "_____. ._..._....___.__ 1/21/2004 20:30 - 23:00 2.50 EVAL C TIEB1 23:00 - 00:00 1.00 EVAL C TIEB1 1/22/2004 00:00 - 00:30 0.50 EVAL C TIEB1 00:30 - 01 :30 1.00 EVAL C TIEB1 01 :30 - 03:30 2.00 EVAL C TIEB1 03:30 - 04:15 0.75 EVAL C TIEB1 04: 15 - 05:30 1.25 EVAL C TIEB1 05:30 - 07:30 2.00 EVAL C TIEB1 07:30 - 08:30 1.00 EVAL C TIEB1 08:30 - 09:00 0.50 EVAL C TIEB1 09:00 - 09:30 0.50 EVAL C TIEB1 09:30 - 12:00 2.50 EVAL C TIEB1 12:00 - 13:00 1.00 EVAL C TIEB1 13:00 - 13:30 0.50 BOPSURC TIEB1 13:30 - 14:30 1.00 CASE C TIEB1 14:30 - 19:30 5.00 CASE C TIEB1 19:30 - 20:00 20:00 - 20:30 0.50 CASE C 0.50 CASE C TIEB1 TIEB1 Start: Rig Release: Rig Number: Spud Date: 9/27/1971 End: 2/11/2004 1/13/2004 2/11/2004 Description of Operations .-.----.-.------....-...---..... -..,....-. -.- Logging Run NO.5 RIH With CCL-CPST And Haliburton EZ-Drill Packer (No.2) To 2,300' - Tie In Log And Set Top Of EZSV At 2,152' WLM (6 Feet Below Bottom Of PBR) - Log Up 100 Feet - RIH Tag EZSV Confirm Setting Depth - POH With Logging Tools Lay Down Logging Tools - Make Up Lubricator And Firing Head To Peforate 133/8" Casing Secure Lubricator, Pump In Sub, And Pack Off In Annular Element - Pressure Test To 500 Psi (Test Good) Logging Run NO.6 - RIH With 41/2" Power Flow 4621 HMX Perforation Guns At 12 Shots Per Foot To 2,100'- Tie In Log And Set Perforation Guns On Depth Top Shot At 1,700' Bottom Shot At 1,705' - Monitor Well Bore Static - POH With Logging Tools Inspect Perf Guns Verify All Shots Fired - Lay Down Perf Guns, And Logging Tools - Rig Down Schlumberger Wire Line Services - Clear And Clean Rig Floor Make Up Mule Shoe, Joint Of Drill Pipe, Haliburton 13 3/8" RTTS Tools And Equipment RIH With Haliburton RTTS Tool- Tag Top Of EZSV At 2,153'- String Up Weight 68,000#, Down Weight 65,000# - Pick Up Set RTTS And Close By Pass Valve - Unset RTTS And Position Stinger At 2,151' (1 Foot Above EZSV) - Circulate At 5 BPM With 70 Psi. Reduce Pump Rate To 1 BPM - Hold Pre-Job Safety Meeting Regarding Displacement Of Fluids To 9.3 PPG Mineral Oil Displace Well Bore Fluids To 9.3 PPG Mineral Oil - Pump 513 BBLS At 5 BPM With 200 Psi. POH With Haliburton 13 3/8" RTTS From 2,152' To 1,685' - Set RTTS - Close Annular Preventer - Hold Pre-Job Safety Meeting Line Up Well Head Valves - Pump 29 BBLS At 2 BPM With 150 Psi. Taking Returns Out 13 3/8" X 18 5/8" To Cuttings Tank Until 9.3 PPG Mineral Oil Returned To Surface Shut In Annulus Well Head Valves - Open Annular Preventer - Release RTTS And Pump 34 BBLS At 2 BPM With 150 Psi. Circulate Well Bore Until 9.3 PPG Mineral Oil Returned To Surface POH With Haliburton RTTS Tools (Wet) From 1,685' - Lay Down RTTS Tools Clear And Clean Rig Floor - Blow Down And Rig Down Circulating Lines Pull Wear Bushing Rig Up 9 5/8" Casing Handling Tools, Power Tongs And Equipment Hold Pre-Job Safety Meeting Regarding Casing Running Operation - Pick Up Seal Assembly - Baker-Lock Connections To Top Of Float Collar Verify Fluid Passing Thru Ported Float - Continue To RIH With Tie Back Liner 51 Joints 9 5/8" L-80 47 lb. BTC-M Casing To 2,130' - Use Best-O-Life 2000 Thread Compound - Torque To Mark With 10,000 ft/lbs. Change Out 350 Ton Bails To Long Set Pick Up 10' Pup Joint - Work Mule Shoe And Seal Assembly Into PBR At 2,130' Printed: 2/16/2004 9:41 :39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Page 6 of 18 BP EXPLORATION Operations Summary Report H-05 H-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 1/13/2004 2/11/2004 Spud Date: 9/27/1971 End: 2/11/2004 Start: Rig Release: Rig Number: ; Code i NPT I Phase . I 1/22/2004 20:30 - 21 :30 From - To Hours ¡ Task TIEB1 Date ...-.-.-.-- 21 :30 - 23:30 23:30 - 00:00 1/23/2004 00:00 - 02:30 1.00 CASE C 2.00 CEMT C TIEB1 0.50 CEMT C TIEB1 2.50 BOPSURC TIEB1 02:30 - 03:30 1.00 WHSUR C TIEB1 03:30 - 04:00 0.50 BOPSURC TIEB1 04:00 - 05:00 1.00 WHSUR C TIEB1 05:00 - 08:00 3.00 WHSUR C TIEB1 08:00 - 09:00 1.00 WHSUR C TIEB1 09:00 - 11 :00 2.00 BOPSURC TIEB1 11 :00 - 12:00 1.00 BOPSURC TIEB1 12:00 - 12:30 0.50 BOPSURC TIEB1 12:30 - 14:00 1.50 DRILL C TIEB1 14:00 - 15:00 15:00 - 16:30 16:30 - 17:30 1.00 DRILL C 1.50 DRILL C TIEB1 TIEB1 1.00 EVAL C TIEB1 Description of Operations --.-...-.-..-----.... - - -- ..-..--.--.------- Load Top And Bottom Plugs In Dowell Cement Plug Dropping Head - Make Up Cement Head - Install Manifold And Circulating Lines - Pressure Up To 500 Psi. - Unsting Seals From PBR To Expose Circulating Ports - Circulate At 5 BPM With 100 Psi. Held PJSM With All Personal Regarding Cementing Operation - Shut Down And Turn Over To Dowell - Pump 5 BBLS Water- Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Clear Lines With Cement Prior To Going Down Hole - Drop Bottom Plug - Pump 65 BBLS (392 Sacks) 15.8 PPG Arctic Set 1 Cement At 5.0 BPM - Drop Top Plug And Displace With 8.6 PPG Sea Water At 6.1 BPM - With 152 BBLS Of Displacement Pumped Slow Rate To 2.9 BPM With Final Circulating Pressure At 668 Psi. - Bump Plug With A Total Of 157.4 BBLS Pumped Increase Pressure To 1,000 Psi. - Slack Off And Sting Seals Into PBR - Bleed Off Pressure And Verify Seals Holding (Seals Held) - Cement In Place At 23:05 Break Down Cement Circulating Lines And Lay Down Dowell Cementing Head Change Bails To Short Set - Drain 135/8" BOP Stack - Pump Out 9 5/8" Casing - Split BOP Stack From Well Head And Pick Up - Align Casing In Well Head And Install 9 5/8" Slips And Pack Off - Pick Up Casing String To 120,000 Ibs Setting Slips- Energize Lock Down Studs Rig Up And Cut 9 5/8" Casing - Lay Down Partial Cut Off Joint (21.62') And 10' Pup Joint Set Back 13 5/8" BOP On Stump And Secure Remove Secondary Valves On 133/8" And 185/8" Annulus- Make Up Flange With Plug And Install Pressure Gauges - Pick Up Tools In Cellar Area Open Doors And Bring 7" Casing Spool Into Cellar Area - Nipple Up Spool - Install Secondary Annulus Valve Energize Pack Off And Test To 3,500 Psi. (Test Good) Nipple Up 13 5/8 BOP Stack And Related Equipment Hold Pre-Job Safety Meeting - Install Test Plug - Rig Up Testing Equipment - Test BOP And 7" Casing Spool Flanges At 250 Psi. Low And 3,500 Psi. High Rig Down Testing Equipment - Pull Test Plug - Install Wear Bushing And Energize Lock Down Studs Make Up BHA - Pick Up Steel Drill Collar, Make Up Bit Sub, And Hughes 8 1/2" MXC1 Bit - RIH With (9) Steel Drill Collars, (3) HWDP, Daily Drilling Jars, (15) HWDP, And Cross Over To 867' RIH With 8 1/2" Drilling Assembly From 867' To 2,096' Drill Cement From 2,096' To 2,105' - Tag And Drill Wiper Plugs At 2,105' And Ported HES Float Collar At 2,107' - Drill Cement And Clean Out PBR From 2,107' To Top Of 9 5/8" EZSV At 2,152' - WOB Rotating 10,000#, RPM 90, Torque Off Bottom 3,000 ft / Ibs - On Bottom 7,000 ft / Ibs, Pump Rate 350 gpm, SPP 680 psi. String Weight Up 96,000#, String Weight Down 95,000#, String Weight Rotating 95,000# Close Annular Element Test 9 5/8" Casing At 2,500 Psi. Record On Circle Chart For 10 Minutes Lost 120 Psi. - Repeat Printed: 2/1612004 9:41:39 AM e e BP EXPLORATION Operations Summary Report Page 7 of 18 Legal Well Name: H-05 Common Well Name: H-05A Spud Date: 9/27/1971 Event Name: REENTER+COMPLETE Start: 1/13/2004 End: 2/11/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/11/2004 Rig Name: NABORS 2ES Rig Number: Date From - To ! Hours Task Code I NPT Phase I Description of Operations , ...____n_____ .__ ..____.. ____.__.____________...________..__.. - ._..... n_________._ .________......_... ___.. 1/23/2004 16:30 -17:30 1.00 EVAL C TIEB1 Process With Same Results 17:30 - 20:00 2.50 DRILL C TIEB1 Drill Haliburton EZSV NO.1 At 2,152' To 2,155' - WOB Rotating 10,000#, RPM 45 To 90, Torque Off Bottom 3,000 ft / Ibs - On Bottom 7,000 ft / Ibs, Pump Rate 200 To 350 gpm, SPP 680 psi. String Weight Up 96,000#, String Weight Down 95,000#, String Weight Rotating 95,000# 20:00 - 21 :00 1.00 DRILL C TIEB1 RIH With 8 1/2" Drilling Assembly From 2,155' To 4,044' 21 :00 - 00:00 3.00 DRILL C TIEB1 RIH With 8 1/2" Drilling Assembly Picking Up Singles Of 4" HT-40 Drill Pipe From 4,044' To Top Of EZSV NO.2 At 8,006' - Fill Drill String Every 3,000' While Tripping In The Hole - Install Top Drive Blower Hose 1/24/2004 00:00 - 01 :30 1.50 DRILL P TIEB1 Held PJSM With Truck Drivers, Drilling Crews, And Service Personal Regarding Mud Displacement - Pumped 30 Barrel Hi-Vis Spacer Followed Up With 11.2 PPG LSND Mud At 13.0 BPM With 2,170 Psi. - Stand Back 1 Stand Of Drill Pipe To 7,923' 01 :30 - 02:30 1.00 EVAL P TIEB1 Test 9 5/8" Casing At 2,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) - Pump Dry Job - Blow Down Top Drive, Kill And Choke Lines 02:30 - 03:30 1.00 DRILL P TIEB1 Slip And Cut 70 Feet Of 1 1/4" Drilling Line 03:30 - 04:00 0.50 DRILL P TIEB1 Service Top Drive And Traveling Blocks 04:00 - 06:00 2.00 DRILL P TIEB1 POH With 8 1/2" Clean Out BHA From 7,923' To 867' 06:00 - 07:00 1.00 DRILL P TIEB1 Stand Back 8 1/2" Clean Out BHA 07:00 - 08:00 1.00 DRILL P TIEB1 Pick Up Baker Oil Tools Hydraulic Jars And Bumper Sub - Make Service Break And Lay Down - Clear Rig Floor 08:00 - 11 :30 3.50 WHIP P WEXIT Pick Up Directional BHA No.1 - Pick Up 1 Joint 5" HWDP Make Up Upper Mill, Lower Mill, And Starter Mill - RIH Make Up Float Sub, MWD, And UBHO Sub - Install Pulser Orient And Surface Test At 535 GPM With 910 Psi. - Pick Up Slide And Whipstock Trip Anchor Attach With 45,000 lb. Brass Lug Bolt 11 :30 - 15:00 3.50 WHIP N RREP WEXIT Repair Draw Works Mechanical Brakes - Brake Lining Bolts Sheared Due To Jarring And Swedging Operations During Removal Of Thermal Casing - Remove Guards And Mechanical Brake Bands 15:00 - 18:00 3.00 WHIP N RREP WEXIT Incorrect Brake Bands Delivered To Rig From Nabors Deadhorse Yard - Remove Brake Blocks Off Brake Band Previously Removed From Draw Works And Install New Brake Blocks - Clean Up Brake Flanges, And Linkage 18:00 - 21 :00 3.00 WHIP N RREP WEXIT Install Brake Bands, Release Springs, And Stand Off Rollers - Adjust Brakes - Install Draw Works Mechanical Brake Guards 21 :00 - 22:00 1.00 WHIP P WEXIT Pick Up Bumper Sub - RIH With (9) Steel Drill Collars, (18) 5" HWDP, And Cross Over To 962' 22:00 - 23:30 1.50 WHIP P WEXIT RIH With BHA No.1 Whipstock And Milling Assembly With 4" Drill Pipe From 962' To 3,109' 23:30 - 00:00 0.50 WHIP P WEXIT Connect Top Drive And Fill Drill String - Flow Test MWD Tool - No Pluse 1/25/2004 00:00 - 01 :00 1.00 WHIP N DFAL WEXIT Trouble Shoot MWD Tool - No Pluse - Pump Fresh Water With No Change - Pump Dry Job - Blow Down Top Drive 01 :00 - 02:00 1.00 WHIP N DFAL WEXIT POH With BHA NO.1 Whipstock And Milling Assembly With 4" Drill Pipe From 3,109' To 962' 02:00 - 03:45 1.75 WHIP N DFAL WEXIT Stand Back BHA - Check Electronics On MWD Tool - Remove Pulser Tool And Lay Down MWD Tool 03:45 - 06:30 2.75 WHIP N DFAL WEXIT Pick Up New MWD Tool And Install Pulser - Orient And Printed: 2/16/2004 9:41:39 AM e e Page 8 of 18 BP EXPLORATION Operations Summary Report Start: 1/13/2004 Rig Release: 2/11/2004 Rig Number: Phase J______u. Description ~~~~:r_~~i~~S WEXIT Initialize MWD And Surface Test - Pick Up Bumper Sub - RIH With (9) Steel Drill Collars, (18) 5" HWDP, And Cross Over To 962' RIH With BHA No.1 Whipstock And Milling Assembly With 4" Drill Pipe From 962' To 3,109' - Test MWD Tool RIH With BHA NO.1 Whipstock And Milling Assembly With 4" Drill Pipe From 3,109" To 8,006' - Fill Pipe Every 3,000' Connect Top Drive - Recorded Slow Pump Rates - String Weight Up 170,000#, String Weight Down 130,000# - Worked String To Orient Whipstock Slacked Off And Tripped Anchor With 22,000# - Whipstock Set At 80 Degrees Right Of High Side - Picked Up On String 1 0,000# Above Neutral Weight to Verify That Whipstock Set - Slacked Off 40,000# To Sheared Retaining Bolt. Legal Well Name: H-05 Common Well Name: H-05A Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date I From - Tol Hours I Task Code NPT ¡ . i 1/25/2004 03:45 - 06:30 2.75 WHIP N 06:30 - 08:00 1.50 WHIP N 08:00 - 10:00 2.00 WHIP P 10:00 - 10:30 0.50 WHIP P DFAL DFAL WEXIT WEXIT WEXIT Spud Date: 9/27/1971 End: 2/11/2004 *NOTE* Tagged Bridge Plug With Bottom Of Whipstock At 8,006' WEXIT Milled Window in 9-5/8" Casing From 7,982' To 7,998' - String Weight Up 170,000#, String Weight Down 130,000#, String Rotating Weight 145,000#, WOM 2,000# - 7,000#, Pump Rate 507 GPM, 2,550 Psi. RPM 80, Torque 9,000 ft / Ibs - 12,000 ftllbs. Exited Window at 7,998' Continued To Mill Formation From 7,998' To 8,014', WOM 6,000# - 14,000#, RPM 90, Torque 10,000 ft / Ibs, Pump Rate 525 gpm, 2,700 psi. Recovered 90 Ibs. Of Metal During Milling Operation. *NOTE*: Top Of Window 7,982' Bottom Of Window 7,998' Under Gauge Hole Drilled From 8,004' To 8,018' WEXIT Work And Clean Window While Pumping MIDF Super Sweep WEXIT Pulled BHA Into Casing To 7,967' - Closed Upper Pipe Rams and Preformed FIT To 12.5 PPG EMW Strokes Pmp'd Pressure 4 80 psi 8 163 psi 12 238 psi 16 317 psi 20 402 psi 22 438 psi Held Test F/ 10 minutes w/ 55 psi Pressure Loss. MW 11.2 PPG, Window TVD 6,409' Pressure 432 psi = 12.50 PPG. EMW. Bled Pressure To 0 Psi. - Opened Pipe Rams. Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive, Choke And Kill Lines- Remove Top Drive Blower Hose POH With BHA NO.1 Whipstock Milling Assembly From 7,967' To 938' Handle BHA No.1 From 938' - Stand Back (18) 5" HWDP, And (9) Steel Drill Collars - Lay Down Bumper Sub, UBHO Sub, MWD Tools, Float Sub, (1) Joint 5" HWDP, Upper, Lower, And Starter Mills 10:30 - 17:15 6.75 S1WHIP P 17:15 -18:00 18:00 - 19:00 0.75 S1WHIP P 1.00 EVAL P 19:00 - 19:30 0.50 S1WHIP P WEXIT 19:30 - 22:30 3.00 S1WHIP P WEXIT 22:30 - 00:00 1.50 S1WHIP P WEXIT 1/26/2004 00:00 - 01 :00 INT1 1.00 DRILL P *NOTE* - Upper Mill Full Gauge At 8.51" O.D. Clear Rig Floor - Bring BHA NO.2 Tools And Equipment To Rig Printed: 2/16/2004 9:41 :39 AM e e BP EXPLORATION Operations Summary Report Page 9 of 18 legal Well Name: H-05 Common Well Name: H-05A Spud Date: 9/27/1971 Event Name: REENTER+COMPlETE Start: 1/13/2004 End: 2/11/2004 Contractor Name: NABORS ALASKA DRilLING I Rig Release: 2/11/2004 Rig Name: NABORS 2ES Rig Number: I I Code I Date I From - To Hours: Task NPT Phase Description of Operations I ! --------" .... .... .....------ ------_._.._......_._._._-_._~...._._----.- 1/26/2004 00:00 - 01 :00 1.00 DRILL P INT1 Floor 01 :00 - 02:00 1.00 BOPSURP INT1 Remove Wear Bushing - Pick Up Johnny Wacker And Flush Out BOP Stack - Lay Down Flushing Tool - Install Wear Bushing And Energize Lock Down Studs - Clear Rig Floor 02:00 - 04:30 2.50 DRILL P INT1 Make Up BHA NO.2 - Pick Up Sperry Sun Motor, Make Up 8 1/2" Hughes DP0912 PDC Bit - Pick Up MWD/LWD Tools, String Stabilizer, Float Sub - Orient And Initialize MWD/LWD Tools - Pick Up (3) Flex Drill Collars - Surface Test Sperry Sun Equipment - RIH With (9) Steel Drill Collars, (3) Joints 5" HWDP, Pick Up Dailey Hydraulic Drilling Jars, (15) Joints 5" HWDP, And Cross Over To 1,039' - Change Out Handling Tools 04:30 - 06:30 2.00 DRILL P INT1 RIH With Directional BHA No.2 Picking Up 4" Drill Pipe From 1,039' To 4,493' - Fill Drill String Every 3,000 Feet 06:30 - 08:30 2.00 DRILL P INT1 RIH With Directional BHA NO.2 From 4,493' To 7,947' 08:30 - 09:00 0.50 DRILL P INT1 Orient Tool Face To 80 Degrees Right Of High Side At 7,947' - Shut Down Mud Pumps - Slide Thru Whipstock Window (7,982 To 7,998') With No Problems - Ream Out Under Gage Hole From 8,004' To 8,014' - Record ECD Base Line At 11.56 09:00 - 16:00 7.00 DRILL P INT1 Drill 8 1/2" Directional Hole By Rotating And Sliding From 8,014' To 8,506' WOB Rotating 5,000# - 12,000#, WOB Sliding 5,000# To 12,000#, RPM 65 To 95, Motor RPM 182, Torque Off Bottom 7,000 ft / Ibs - On Bottom 13,000 ft / Ibs, Pump Rate 549 gpm, SPP Off Bottom 3,490 psi, On Bottom 3,750 psi. String Weight Up 185,000#, String Weight Down 128,000#, String Weight Rotating 155,000# - ART = 2.08 hrs. - AST = 3.07 hrs. 16:00 - 16:30 0.50 DRILL N RREP INn Can-Rig Top Drive Service Loop Problem - POH From 8,506' To 7,850' 16:30 - 21:45 5.25 DRILL N RREP INT1 Work On Can-Rig Top Drive Hydraulic Service Loop 21 :45 - 22:00 0.25 DRILL N RREP INT1 RIH From 7,850' To 7,947' - Orient Tool Face To 80 Degrees Right Of High Side - Shut Down Mud Pumps - Slide Thru Whipstock Window With No Problems - RIH To 8,413' As Precaution Wash Last Stand To Bottom From 8,413' To 8,506' 22:00 - 00:00 2.00 DRILL P INT1 Drill 8 1/2" Directional Hole By Rotating And Sliding From 8,506' To 8,720' - ART = 1.01 hrs. - AST = .20 hrs. 1/27/2004 00:00 - 18:00 18.00 DRILL P INT1 Drill 8 1/2" Directional Hole By Rotating And Sliding From 8,720' To 10,090' WOB Rotating 10,000# - 15,000#, WOB Sliding 5,000# To 15,000#, RPM 100, Motor RPM 175, Torque Off Bottom 11,000 ft / Ibs - On Bottom 14,000 ft / Ibs, Pump Rate 530 gpm, SPP Off Bottom 3,930 psi, On Bottom 4,170 psi. String Weight Up 220,000#, String Weight Down 140,000#, String Weight Rotating 172,000# - ART = 10.37 hrs. - AST = 3.31 hrs. 18:00 - 19:15 1.25 DRILL P INT1 Circulate Sweep While Rotating And Reciprocating Drill String At 12.6 BPM With 3,930 Psi. 19:15 - 20:30 1.25 DRILL P INT1 Monitor Well Bore (Static) - Blow Down Top Drive - POH With Directional BHA No.2 (Wet) From 10,090' To 7,760' With No Problems 20:30 - 21 :00 0.50 DRILL P INT1 Service Top Drive, Traveling Blocks, And Crown Sheaves 21 :00 - 22:00 1.00 DRILL P INT1 Break Circulation And Orient Tool Face To 80 Degrees Right Of High Side - Blow Down Top Drive - Mad Pass For Tie In Log From 7,836' To 8,036' At 350 FPH Printed: 2/16/2004 9:41 :39 AM e e BP EXPLORATION Operations Summary Report Page 10 of 18 Legal Well Name: H-05 Common Well Name: H-05A Spud Date: 9/27/1971 Event Name: REENTER+COMPLETE Start: 1/13/2004 End: 2/11/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/11/2004 Rig Name: NABORS 2ES Rig Number: Date From - To I Hours Task Code NPT Phase Description of Operations 1/27/2004 22:00 - 23:00 1.00 DRILL P INT1 RIH With BHA NO.2 From 8,036' To 9,996' With No Problems As Precaution Wash Last Stand To Bottom From 9,996' To 10,090' 23:00 - 00:00 1.00 DRILL P INT1 Drill 8 1/2" Directional Hole By Rotating From 10,090' To 10,183' - ART = .97 hrs. 1/28/2004 00:00 - 11 :30 11.50 DRILL P INT1 Drill 8 1/2" Directional Hole By Rotating And Sliding From 10,183' To 10,744' WOB Rotating 10,000# -15,000#, WOB Sliding 5,000# To 15,000#, RPM 70, Motor RPM 165, Torque Off Bottom 13,000 ft / Ibs - On Bottom 17,000 ft / Ibs, Pump Rate 498 gpm, SPP Off Bottom 3,850 psi, On Bottom 4,100 psi. String Weight Up 250,000#, String Weight Down 140,000#, String Weight Rotating 182,000# - ART = 4.03 hrs. - AST = 3.54 hrs. 11 :30 - 12:00 0.50 DRILL P INT1 Circulate Sweep And Change Swab In NO.1 Mud Pump 12:00 - 13:30 1.50 DRILL P INT1 Drill 8 1/2" Directional Hole By Rotating From 10,744' To 10,851' - ART = 1.02 hrs. 13:30 - 16:00 2.50 DRILL P INT1 Circulate Up Formation Samples - Drill From 10,851' To 10,855' Casing Point - Circulate Up Samples To Verify Cap Of Sag River Formation 16:00 - 18:00 2.00 DRILL P INT1 Monitor Well Bore (Static) - Blow Down Top Drive - POH With Directional BHA NO.2 (Wet) From 10,855' To 7,854' With No Problems - Normal Up Weight At 280,000 Ibs. 18:00 - 19:00 1.00 DRILL P INT1 Slip And Cut 96 Feet Of 1 1/4" Drilling Line 19:00 -19:30 0.50 DRILL P INT1 Service Top Drive And Traveling Blocks 19:30 - 21 :00 1.50 DRILL P INT1 RIH With BHA NO.2 From 7,854' To 10,744' With No Problems As Precaution Wash Last Stand To Bottom From 10,744' To 10,855' 21 :00 - 00:00 3.00 DRILL P INT1 Circulate Hi-Vis Sweep 2 X Bottoms Up Until Hole Clean While Rotating And Reciprocating Drill String At 11.8 BPM With 3,930 Psi. - Spot Liner Running Pill - Drop Sperry Sun ESS Tool 'NOTE' WeeklyTesting Of BOP Equipment Waived By AOGCC Inspector John Crisp Until 7" Casing Strings Ran And BOP Stack Nippled Up. 1/29/2004 00:00 - 00:30 0.50 DRILL P INT1 Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 00:30 - 02:00 1.50 DRILL P INT1 POH With Directional BHA NO.2 From 10,855' To 7,854' With No Problems - Normal Up Weight At 280,000 Ibs. 'NOTE' Take Surveys With ESS While Pulling Out Of The Hole At The Following Depths: 10,758' - 10,676' - 10,582' - 10,488' - 10,395' - 10,301' 02:00 - 02:30 0.50 DRILL P INT1 Monitor Well Bore At Window (Static) - POH From 7,854' To 6,341' 02:30 - 12:00 9.50 DRILL N RREP INT1 Observe Smoke Coming From Draw Works Traction Motor - Shut Down And Lock Out Draw Works And Traction Motor For Further Investigation - Secure Well With Safety Valve And Circulate Across Top Of Hole To Trip Tank Monitoring Returns - Trouble Shoot Problem - Hold Pre-Job Safety Meeting - Prepare To And Replace Traction Motor 12:00 - 18:00 6.00 DRILL N RREP INT1 Cut Out Roof Section Above Motor For Removal - Hook Up Crane And Remove Motor 18:00 - 00:00 6.00 DRILL N RREP INT1 Remove Hub From Bad Motor - Found Hub To Be Bad - Bring Printed: 2/16/2004 9:41:39 AM e e BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-05 H-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To ; Hours Task I Code [ NPT Phase 1/29/2004 18:00 - 00:00 6.00 DRILL N RREP INT1 1/30/2004 00:00 - 03:00 3.00 DRILL N RREP INT1 03:00 - 09:30 6.50 DRILL N RREP INT1 09:30 - 10:30 1.00 DRILL N RREP INT1 10:30 - 12:00 1.50 DRILL N RREP INT1 12:00 - 14:00 2.00 DRILL N RREP INT1 14:00 - 16:00 2.00 DRILL N RREP INT1 16:00 - 18:00 2.00 DRILL N RREP INT1 18:00 - 20:00 2.00 DRILL P INT1 20:00 - 23:30 3.50 DRILL P INT1 1/31/2004 23:30 - 00:00 00:00 - 00:30 00:30 - 04:00 LNR1 LNR1 LNR1 0.50 CASE P 0.50 CASE P 3.50 CASE P 04:00 - 04:30 0.50 CASE P LNR1 04:30 - 05:00 0.50 CASE P LNR1 05:00 - 08:30 3.50 CASE P LNR1 08:30 - 09:00 0.50 CASE P LNR1 09:00 - 11 :00 2.00 CASE P LNR1 Page 11 of 18 Start: Rig Release: Rig Number: Spud Date: 9/27/1971 End: 2/11/2004 1/13/2004 2/11/2004 Description of Operations __.____ . ... W"... ._........_____ Additional Motor From Nabors Yard Meg And Inspect New Traction Motor And Install Hub - Lift Into Place With Crane And Install Roof Panel Line Up Traction Motor - Install Coupling, Shim And Dial In Motor - Wire In Motor And Install Blower Assembly Grease Coupling, Warm Up And Test Rum Motor - Clear And Clean Work Area Break Circulation Test MWD Tool At 6,360' - RIH From 6,360' To 7,947' Top Of Windoow - Orient Tool Face To 80 Degrees Right Of High Side At 7,947' - Shut Down Mud Pumps - Slide Thru Whipstock Window - Pump Rate 495 gpm, SPP 3,270 psi, String Weight Up 210,000#, String Weight Down 120,000# RIH With BHA NO.2 From 7,947' To 10,744' With No Problems As Precaution Wash Last Stand To Bottom From 10,744' To 10,855' *Note* 7 Feet Of Fill On Bottom Circulate Hi-Vis Sweep Bottoms Up Until Hole Clean While Rotating And Reciprocating Drill String At 11.8 BPM With 3,930 Psi. - Spot Liner Running Pill - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive POH With Directional BHA NO.2 From 10,855' To 7,854' With No Problems - Normal Up Weight At 280,000 Ibs. - Monitor Well (Static) - Continue To POH To 6,341' POH From 6,341' To 1,039' POH Laying Down Directional BHA NO.2 From 1,039' - Lay Down Cross Over Sub, (18) Joints 5" HWDP, Daily Drilling Jars, (9) Steel Drill Collars, (3) Flex Drill Collars - Down Load Sperry Sun MWD/LWD Tools - Retrieve Sperry Sun ESS - Flush Out BHA With Fresh Water - Lay Down Hang Off Collars, MWD/LWD Tools, Float Sub, And String Stabilizer - Remove Hughes 8 1/2" PDC Bit And Lay Down Mud Motor - Clear Rig Floor Rig Up Power Tongs - Casing Tools And Equipment Rig Up Power Tongs - Casing Tools And Equipment Pick Up And RIH With Shoe Track - Baker Lock Connections To Insert Landing Collar Joint NO.3 - Verify Floats Holding - RIH With 73 Joints Of 7" BTC-M 26 lb. L-80 Casing To 2,999' - Make Up To Mark Torqued To 7,200 ftllbs. Change Out Handling Equipment To 5" DP Elevators - M I U Baker HMC Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool - Change Out Handling Equipment PI U Cross Over, (2) 4" Drill Pipe Pup Joints, RIH wI 1 Stand 4" Drill Pipe From Mast To 3,148' Circulate 7" Liner Volume At 252 GPM With 260 Psi. - Recorded Liner Weight At 65,000# With Out Block Weight - Rig Down Casing Tongs RIH With 73 Joints Of 7" BTC-M 26 lb. L-80 Liner On 4" Drill Pipe From 3,148' To 7,950' - Fill 4" Drill Pipe Every 10 Stands Circulate Drill Pipe And 7" Liner Volume At 252 GPM With 700 Psi. - String Weight Up At 172,000 Ibs.- Down Weight At 117,000Ibs. RIH With 7" BTC-M 26 lb. L-80 Liner On 4" Drill Pipe From 7,850' To 10,800' With No Problems - Pick Up Baker Cement Head - Install Manifold And Circulating Lines - Establish Printed: 2/16/2004 9:41 :39 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Page 12 of 18 BP EXPLORATION Operations Summary Report H-05 H-05A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES From - To I Hours Task Code NPT Date ----..--- 1/31/2004 09:00 - 11 :00 11 :00 - 12:30 12:30 - 16:30 16:30 - 17:00 17:00 - 17:30 17:30 - 18:30 18:30 - 19:00 19:00 - 22:00 2/1/2004 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 11 :00 11 :00 - 12:30 12:30 - 13:30 2.00 CASE P 1.50 CASE P 4.00 CEMT P 0.50 CEMT P 0.50 CASE P 1.00 CASE P 0.50 CASE P 3.00 CASE P 0.50 BOPSURP 0.50 CASE P 1.00 CASE P 11.00 CASE P 1.50 CASE P 1.00 CASE P 1/13/2004 2/11/2004 Spud Date: 9/27/1971 End: 2/11/2004 Start: Rig Release: Rig Number: Phase LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 TIEB2 TIEB2 TIEB2 TIEB2 TIEB2 TIEB2 Description of Operations m.. m _ .._______ Circulation At 2 BPM With 420 Psi And Full Returns - Wash To Bottom At 10,855' Stage Up Pumping Rates From 2 BPM With 420 Psi. To 6.2 BPM With 1,850 Psi. Hole Starting To Pack Off, Reduce Rate To 4 BPM With 750 Psi. - Circulate And Condition Mud With Full Returns Held PJSM With All Personal Regarding Cementing Operation - Shut Down And Turn Over To Dowell - Pump 5 BBLS Water - Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Clear Lines With Mud Push Prior To Going Down Hole - Pump 25 BBLS 12.2 PPG Mud Push, Followed With 35 BBLS (170 Sacks) 15.8 PPG Class "G" Tail Cement At 4.8 BPM - Wash Up Lines To Floor - Drop Dart And Displace With 11.2 PPG LSND Mud At 5.0 BPM With 580 Psi. - Latch Liner Wiper Plug With 78.5 BBLS Pumped Away - Continue To Displace With Final Circulating Pressure At 888 Psi. - Bump Plug With A Total Of 190 BBLS Pumped - Increase Pressure To 3,500 Psi. To Set Baker Liner Hanger - Bleed Off Pressure And Check Floats (Floats Held) - Cement In Place At 14:30 Hours - Rotate 15 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To Maximum Rate At 11.7 BPM With 3,425 Psi. And Circulate Fluid Above Liner Hanger Up Hole 30 BBLS - Reduce Pump Rate To 6.4 BPM With 1,379 Psi. Slack Off String With 70,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process Several Times (Clear Surface Indication That Packer Set) - Increase Pump Rate To 12.0 BPM With 3,500 Psi. And Continue To Circulate With No Cement As Planned Back To Surface - Top Of Liner At 7,830', Insert Landing Collar At 10,763', Float Collar At 10,808', Float Shoe At 10,853' Pump Dry Job Blow Down Surface Equipment - Break Down Cement Circulating Lines And Lay Down Baker Cementing Head Monitor Well Bore (Static) - POH From 7,830' To 7,311' Slip And Cut 87 Feet Of 1 1/4" Drilling Line Service Top Drive, Traveling Blocks, And Crown Sheaves POH With Baker 7" Liner Running Tool From 7,311' - Inspect Running Tool Brass Pins Were Sheared Indicating That The ZXP Packer Did Set - Lay Down Cross Overs And Pup Joints - Make Service Breaks On Running Tool And Lay Down Same Rig Up And Pull Wear Bushing Clear And Clean Rig Floor Rig Up Power Tongs - Casing Tools And Equipment Pick Up And RIH With Seal Assembly, Ported Float Valve,And Baffle Collar - Baker Lock Connections To Baffle Collar Bottom Of Joint NO.1 - Verify String Filling Thru Port - RIH With 189 Joints Of 7" BTC-M 26 lb. L-80 Casing To 7,793' - Make Up To Mark Torqued To 8,000 ftllbs. Change Out 350 Ton Bails To Long Set - Install 250 Ton Elevators With Pick Up Sling - Rig Up Casing Stabbing Board Pick Up Joint No. 190 And 10' Pup Joint - Work Mule Shoe Printed: 2/16/2004 9:41:39 AM e e Page 13 of 18 BP EXPLORATION Operations Summary Report Legal Well Name: H-05 Common Well Name: H-05A Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date I From - To : Hours Task Code NPT 2/1/2004 2/2/2004 12:30 - 13:30 13:30 - 15:00 15:00 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 19:30 19:30 - 21:30 21 :30 - 22:00 22:00 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 07:00 1/13/2004 2/11/2004 Spud Date: 9/27/1971 End: 2/11/2004 Start: Rig Release: Rig Number: Phase .."..." ..-... - ....- ._._.~_.__....__... 1.00 CASE P 1.50 CASE P TIEB2 TIEB2 1.50 CEMT P TIEB2 1.00 CEMT N CEMT TIEB2 1.00 CEMT P TIEB2 1.00 CASE P TIEB2 2.00 CASE P TIEB2 0.50 BOPSURP 2.00 WHSUR P PROD1 PROD1 2.00 BOPSURP 0.50 BOPSURP 4.50 BOPSURP PROD1 PROD1 PROD1 07:00 - 07:30 0.50 WHSUR P PROD1 07:30 - 08:00 0.50 EVAL P PROD1 08:00 - 11 :00 3.00 DRILL P PROD1 Description of Operations _..._u_.._._...__.._...__ ...-.------.-.--.--- And Seal Assembly Into 7" Tie Back Sleeve At 7,830' Load Top And Bottom Plugs In Dowell Cement Plug Dropping Head - Make Up Cement Head - Install Manifold And Circulating Lines - Pressure Up To 500 Psi. - Unsting Seals From Tie Back Sleeve To Expose Circulating Ports - Circulate At 6 BPM With 1,200 Psi. Held PJSM With All Personal Regarding Cementing Operation - Test Dowell And Little Red Hot Oil Services Lines And Equipment To 4,500 Psi. (Test Good) - Pump 100 BBLS Sea Water, 50 BBLS Hi-Vis Pill, 100 BBLS Diesel, Followed Up With 5 BBLS Water - Drop Bottom Plug Repair Schlumberger Bulk Truck Delivery Valve - Handle Twisted Off In The Closed Position When Attempting To Open - Replace Valve Pump 29 BBLS (140 Sacks) 15.8 PPG Class "G" Cement At 3.5 BPM - Drop Top Plug And Displace With 5 BBLS Water, Followed Up With 11.2 PPG LSND Mud At 12.3 BPM - With 293 BBLS Of Displacement Pumped Slow Rate To 5.6 BPM With Final Circulating Pressure At 380 Psi. - Did Not Bump Plug With A Total Of 300 BBLS Pumped - Slack Off And Sting Seals Into 7" Liner Tie Back Sleeve - Bleed Off Pressure And Verify Seals Holding (Seals Held) - Cement In Place At 18:09 Break Down Cement Circulating Lines And Lay Down Dowell Cementing Head - Drain 13 5/8" BOP Stack - Split BOP Stack From Well Head And Hoist Up Stack Align Casing In Well Head And Install 7" Slips - Slips Set With 200,000 Ibs - Energize Lock Down Studs - Rig Up And Cut 7" Casing - Lay Down Partial Cut Off Joint (28.51 ') And 10' Pup Joint - Rig Down Cutter Assembly Remove Flow Line Riser - Stand Back BOP And Secure Open Cellar Door And Bring Tubing Spool Into Cellar Area - Nipple Up Spool - Remove Secondary Valves On 9 5/8" X 7" Annulus And Install On Tubing Spool - Energize Pack Off And Test To 4,400 Psi. (Test Good) Nipple Up 135/8" BOP Stack Install Test Plug - Rig Up Testing Equipment Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector John Crisp - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment Pull Test Plug - Install Wear Bushing And Energize LOS - Clear Rig Floor Test 7" Casing Down To Baffle Collar At 7,809' With 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) - Blow Down Choke Manifold, And Kill Lines Held PJSM - Make Up BHA NO.3 - Pick Up Sperry Sun Motor, Make Up 61/8" Smith XR20 Insert Bit, Pick Up MWD/LWD Tools - Orient And Initialize MWD/LWD Tools - Pick Up (1) Flex Drill Collar - Surface Test Sperry Sun Equipment - Hold PJSM And Install Nuke Sources Lower Below Rig Floor - Pick Up (2) Printed: 2/16/2004 9:41 :39 AM e e BP EXPLORATION Operations Summary Report Page 14 of 18 Legal Well Name: H-05 Common Well Name: H-05A Spud Date: 9/27/1971 Event Name: REENTER+COMPLETE Start: 1/13/2004 End: 2/11/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/11/2004 Rig Name: NABORS 2ES Rig Number: Date From - To I Hours Task Code NPT ¡ Phase Description of Operations I .. . ..~-- ..... .. ... ----- 2/2/2004 08:00 - 11 :00 3.00 DRILL P PROD1 Flex Drill Collars, Daily Mechanical Jars, Circulating Sub, And Cross Over Sub To 238' 11 :00 - 12:00 1.00 DRILL P PROD1 RIH With Directional Drilling Assembly BHA NO.3 Picking Up 4" Drill Pipe From 238' To 2,106' 12:00 - 15:00 3.00 DRILL P PROD1 RIH With Directional Drilling Assembly BHA NO.3 From 2,106' To 7,809' 15:00 - 16:30 1.50 DRILL P PROD1 Tag Cement HES Top And Bottom Plugs On Baffle Collar At 7,809' - Drill Wiper Plugs And Baffle Collar- Drill Cement To 7,830' 16:30 - 17:30 1.00 DRILL P PROD1 RIH Pushing Down Float Equipment With Directional Drilling Assembly BHA NO.3 From 7,809' To 10,561' 17:30 - 18:30 1.00 DRILL P PROD1 Wash And Ream From 10,561' To 10,688' 18:30 - 19:30 1.00 EVAL P PROD1 Test 7" Casing At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) 19:30 - 21 :00 1.50 DRILL P PROD1 Wash And Ream From 10,688' To Baker Insert Landing Collar At 10,763' - Drill Landing Collar And Wiper Plugs - Drill Cement To Float Collar At 10,808' - Drill Cement To 10,850' 21 :00 - 23:00 2.00 DRILL P PROD1 Change Over Mud System - Pump 150 BBLS Water Spacer, 30 BBLS Spacer With EP Mud Lube, Followed Up With 8.7 PPG Flo-Pro Mud - Clean Under Shakers 23:00 - 00:00 1.00 DRILL P PROD1 Drill Cement And Float Shoe From 10,850' To 10,855' (Bottom Of Shoe) - Drill New 61/8" Hole By Rotating From 10,855' To 10,875' WOB Rotating 5,000# - 12,000#, RPM 50, Motor RPM 82, Torque Off Bottom 8,000 ft I Ibs - On Bottom 8,900 ft I Ibs, Pump Rate 272 gpm, SPP Off Bottom 2,250 psi, On Bottom 2,350 psi, String Weight Up 178,000#, String Weight Down 135,000#, String Weight Rotating 155,000# - ART = .40 hrs. 2/3/2004 00:00 - 00:30 0.50 DRILL P PROD1 Pull Into Casing Shoe At 10,855' - BHA Hung Up While Pulling Into 7" Casing Shoe - Wash And Ream Area From 10,855' To 10,875' 00:30 - 01 :00 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Preform FIT To 10.0 PPG EMW Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 2 11 0 psi 4 240 psi 6 340 psi 8 430 psi 10 530 psi 11 580 psi Held Test FI 10 minutes wI 40 Psi. Pressure Loss. MW 8.7 ppg, Top Of Window TVD 8,548' Pressure 580 psi = 10.0 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams 01 :00 - 02:00 1.00 DRILL P PROD1 Wash And Ream From 10,855' To 10,875' - Attempt To Pull Into Casing Shoe With Out Rotating Drill String (No Good) - Work Area Until Cleaned Up And Able To Pull Into Casing Shoe 02:00 - 09:00 7.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 10,875' To 10,964' WOB Rotating 12,000# - 20,000#, RPM 75, Motor RPM 82, Torque Off Bottom 8,000 ft I Ibs - On Bottom 9,000 ft I Ibs, Pump Rate 272 gpm, SPP Off Bottom 2,250 psi, Printed: 2/16/2004 9:41 :39 AM e e Page 15 of 18 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-05 H-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To i Hours' Task Code NPT Phase Start: Rig Release: Rig Number: Spud Date: 9/27/1971 End: 2/11/2004 1/13/2004 2/11/2004 Description of Operations .. - .__._._..____... .__n..._.. ......._ ..___o"" ...._ _.____ 2/3/2004 7.00 DRILL P PROD1 On Bottom 2,350 psi. String Weight Up 190,000#, String Weight Down 135,000#, String Weight Rotating 160,000#. ART - 5.79, AST - 0.29. Crossed fault @ 10,920' with 40' upthrow. RREP PROD1 Top Drive Began to Leak Oil. POH from 11,119' to 10,782'. Repair Hydraulic Leak. Replaced Supply Hose for Torque Booster and Leaking Swivel Fitting on Link Tilt. RIH to 11,119'. No Problems. Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11, 119' To 11 ,250'. Target TVD Raised 11' Due To Fault. Attempt to Slide with difficulty. Cuttings Samples show High Amount of Pyrite and Chert. Difficulty Sliding from 11,283. Rotate ahead to 11,319' to get below Cherty formation (30-40% Chert). AST - 0.36, ART - 0.66. PU -190K, SO -135K, ROT - 160K, TO On - 12,000, TO Off - 9,000. Monitorwell. POH from 11,319' to 10,782'. No problems. Open Circ Sub and Circulate Bottoms Up and Pump Dry Job. RU Air Slips. Blow down surface equipment. POH from 10,782' to 238' PJSM. Stand back BHA from 238' to 140'. Remove nuclear source. Download MWD tools and flush same. Blow down surface equipment. LD BHA. Change out bit. Adjust motor bend to 1.83. Change out DM HOC tool to satisfy JORPS and orient. MU BHA to 135'. PJSM. Upload MWD and shallow test same - 220 gpm @ 650 psi - OK. Blow down surface equipment. Load nuclear source. MU BHA from 135' to 232' RIH with DP from 232' to 3,034'. Fill pipe @ 3,034'. Excessive leaking from Hydraulic Service Loop. Replace Hydraulic Service Loop. Service Top Drive. RIH with DP from 3,034' to 11,100'. Ream from 11,100' to 11,318' - 30 rpm @ 272 gpm. Drill 6-1/8" hole from 11,319' to 11,375'. ART - 0.12, AST - 1.82. PU - 185K, SO - 140K, ROT - 164K, TQ Off - 7K, TO On - 9K. 272 gpm @ 2300 psi Drill 6-1/8" hole from 11,375' to 11,719'. PU - 190K, SO - 135K, ROT - 165K, 272 gpm @ 2350 psi. ART - 0.31, AST- 13.13. Circulate Sweep - 6.5 bpm @ 2,200 psi POH from 11,719' to 10,777'. Straight PU - 21 OK. Max PU - 280K. After working through some tight spots, Max PU - 235K. PU @ shoe - 195K. Slip and cut 92' of drilling line. Service Top Drive. POH from 10,777' to 1,167'. POH from 1,167' to top of BHA @ 232'. PJSM. Stand back BHA from 232' to 140'. Remove Radioactive source Flush tools. Blow down surface equipment. Download MWD tools. Change out Pulser and LD 02:00 - 09:00 09:00 - 12:30 3.50 DRILL N 12:30 - 18:00 5.50 DRILL P PROD1 18:00 - 00:00 6.00 DRILL P PROD1 2/4/2004 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 07:00 4.00 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 09:30 1.50 DRILL P PROD1 09:30 - 11 :00 1.50 DRILL P PROD1 11 :00 - 12:00 1.00 DRILL P PROD1 12:00 - 15:30 3.50 DRILL N RREP PROD1 15:30 - 16:00 0.50 DRILL P PROD1 16:00 - 19:30 3.50 DRILL P PROD1 19:30 - 21:00 1.50 DRILL P PROD1 21 :00 - 00:00 3.00 DRILL P PROD1 2/5/2004 00:00 - 17:00 17.00 DRILL P PROD1 17:00 -18:30 1.50 DRILL P PROD1 18:30 - 19:30 1.00 DRILL P PROD1 19:30 - 21 :00 1.50 DRILL P PROD1 21 :00 - 00:00 3.00 DRILL P PROD1 2/6/2004 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 02:30 2.00 DRILL P PROD1 Printed: 2/16/2004 9:41 :39 AM e e Page 16 of 18 BP EXPLORATION Operations Summary Report .' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-05 H-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 9/27/1971 End: 2/11/2004 1/13/2004 2/11/2004 Date From - To Hours Task 'Code NPT Phase Description of Operations ------.----.-- ..__.________n ___.._. ....... _._ _.....__._ _", _...___________ 2/6/2004 00:30 - 02:30 2.00 DRILL P PROD1 remaining BHA. Clean the floor. 02:30 - 04:00 1.50 DRILL P PROD1 Change out Motor and Bit. MU BHA to 207'. Orient. Upload MWD tools and Shallow Test. Good. 04:00 - 08:30 4.50 DRILL P PROD1 08:30 - 10:30 2.00 DRILL P PROD1 10:30 - 00:00 13.50 DRILL P PROD1 2/7/2004 00:00 - 09:30 9.50 DRILL P PROD1 09:30 - 10:30 1.00 DRILL P PROD1 10:30 - 14:00 3.50 DRILL P PROD1 14:00 - 15:30 1.50 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 18:00 0.50 DRILL P PROD1 18:00 - 20:00 2.00 DRILL P PROD1 20:00 - 21 :30 1.50 DRILL P PROD1 21 :30 - 22:00 0.50 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 2/8/2004 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 04:00 2.00 DRILL P PROD1 04:00 - 06:00 2.00 CASE P COMP 06:00 - 06:30 0.50 CASE P COMP 06:30 - 11 :00 4.50 CASE P COMP 11:00-11:30 0.50 CASE P COMP 11 :30 - 16:30 5.00 CASE P COMP 16:30 - 17:00 0.50 CASE P COMP 17:00 - 18:00 1.00 CASE P COMP 18:00 - 20:00 2.00 CASE P COMP 20:00 - 21 :30 1.50 CEMT P COMP Note: Outer gage row has teeth broken and missing. Hard banding protection on the body is worn. RIH from 207' to 11,315'. Fill Pipe every 3,000'. Ream from 11,315' to 11,719'. 30 rpm @ 270 gpm. Drill 6-1/8" hole from 11,719' to 12,085'. AST - 6.27, ART - 3.13, PU - 200K, SO - 130K, ROT - 162K, TQ On - 11 K, TQ Off - 9K. 270 gpm @ 2,550 psi. Drill 6-118" hole from 12,085' to 12,386'. AST - 2.6, ART - 3.94. PU - 200K, SO - 130K, ROT - 160K, TQ On - 11 K, TQ Off - 9K. 270 gpm @ 2,500 psi. Circulate Hi-Visc sweep. 272 gpm @ 2,350 psi. Drill 6-118" hole from 12,386' to 12,470'. AST - 0.13, ART- 2.17. PU - 200K, SO -130K, ROT - 160K, TQ On -11K, TQ Off - 9K. 270 gpm @ 2,500 psi. Circulate Hi-Visc sweep. Circulate Bottoms Up - 270 gpm @ 2,000 psi. Monitor well - stable. POH. LD DP from 12,470' to 12,097'. POH standing back pipe from 12,097' to 10,844'. Service Top Drive. Adjust brakes. RIH from 10,844' to 12,470'. No problems. Pump Hi-Visc Sweep. Circulate Bottoms Up - 270 gpm @ 2,050 psi. Spot Liner Running Pill. Monitor well - stable. LD DP from 12,470' to 10,844'. PU - 210K at TD. PU - 195K at shoe. No overpulls seen. Drop dart and slug the pipe. Blow down the surface equipment. POH standing back from 10,844' to 4,874'. POH from 4,874' to 207'. LD BHA from 207'. Flush and download MWD tools. LD Motor. Clear Floor PJSM. RU 4.5" Casing handling equipment. Remove centralizers from first 3 joints. MU float equipment. Check floats - good. MU 4.5", 12.6#, 13Cr80, Vam Ace Liner to 1,731 - Torqued to 3,620 ft-Ibs'. RD Casing handling equipment. MU Baker HMC Hanger and ZXP Packer to 1,772'. Fill Tie-Back sleeve with Pal-Mix. Let set 30 minutes. Install saver sub. RIH 1 stand to 1,871' and circulate Liner volume - 6 bpm @ 300 psi. PU - 50K, SO - 50K. RIH wlliner on 4" DP from 1,871' to 10,832'. Fill Pipe. Circulate DP and liner volume @ 10,832'. 6 bpm @ 1,000 psi. Blow down surface equipment. RIH wlDP from 10,832' to 12,448'. MU cement rotary head, manifold and hoses. Break circulation. RIH and tag bottom @ 12,470'. Stage up pumps to 6 bpm @ 1400 psi. Pump 5 bbl water ahead. P-test cement lines to 4,500 psi. Bleed pressure. Pump 15 bbls CW-100 Preflush, 27 bbls 9.6 ppg Mudpush weighted spacer, 48 bbls 15.8 Latex cement Printed: 2/1612004 9:41 :39 AM e e Page 17 of 18 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date H-05 H-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To ! Hours I Task Start: Rig Release: Rig Number: I Code! NPT I Phase . ! ... .....----.-- .-----.- 2/8/2004 1.50 CEMT P 20:00 - 21 :30 COMP 21 :30 - 22:00 0.50 CEMT P COMP 22:00 - 00:00 2.00 CEMT P COMP 2/9/2004 00:00 - 01 :00 1.00 CEMT P COMP 01 :00 - 05:30 4.50 CEMT P COMP 05:30 - 06:30 1.00 CEMT P COMP 06:30 - 08:00 1.50 PERF P COMP 08:00 - 09:00 1.00 CEMT P COMP 09:00 - 10:30 1.50 PERF P COMP 10:30 - 13:00 2.50 PERF P COMP 13:00 - 18:00 5.00 PERF P COMP 18:00 - 19:00 1.00 PERF P COMP 19:00 - 19:30 0.50 PERF P COMP 19:30 - 00:00 4.50 PERF P COMP 2/10/2004 00:00 - 01 :30 1.50 PERF P COMP 01 :30 - 03:30 2.00 PERF N RREP COMP 03:30 - 06:00 2.50 PERF P COMP 06:00 - 08:00 2.00 PERF P COMP 08:00 - 10:30 2.50 PERF P COMP 10:30 - 12:30 2.00 RUNCOMP COMP 12:30 - 13:30 1.00 RUNCOMP COMP 13:30 - 18:00 4.50 RUNCOMP COMP 1/13/2004 2/11/2004 Spud Date: 9/27/1971 End: 2/11/2004 Description of Operations ___________n_____ _ ._n_ __n____ __.___. slurry. Wash lines. Drop dart and displace with 50 bbls Perf Pill. Chase pill with mud. Pick up dart @ 104 bbls. Bump plug @ 129 bbls and 3,200 psi to set Hanger. Increase pressure to 4,500 psi. Bleed off pressure and check floats - okay. Note: Reciprocated pipe until 30 bbls into the displacement with perf pill due to increased drag while moving pipe. Set Pipe on Bottom. Top of Liner Tieback: 10704.87' ZXP Packer: 10716.22' Liner Top Hanger: 10726.72' Landing Collar: 12,382.26' Float Collar: 12,424.24' Float Shoe: 12,468.21' Set Packer. Increase pressure to 1,000 psi. Unsting and circulate bottoms up - 12 bpm @ 3200 psi. 3 bbls of cement returned to surface. Displace well to Seawater - 12 bpm @ 3,500 psi. LD cement rotary head, hoses and manifold. Blow down surface equipment. Slip and cut 71' drilling line. Inspect Brakes. POH from 10,650'. LD Liner running tools. Clear the floor. Service Top Drive PJSM. RU 2-7/8" Pipe handling equipment. Pressure test casing to 3,500 psi for 30 minutes. Good test. MU 2-7/8" PowerJet, 4spf, and firing head to 389'. PU 2-7/8" PAC DP from 389' to 1,781'. RD handling equipment. RIH wI DP from 1,781' to 12,382'. PJSM. RIH and tag Landing Collar @ 12,382'. Spaceout and fire 2-7/8" Perf Guns from 12,020' to 12,375'. POH standing back 5 stands from 12,376' to 11,953'. Monitor well. Static Loss Rate - 3 bph. Blow down sureface equipment. LD 4" DP from 11,953' to 5,888'. Note: BOP test, which was due today, was waived by John Spaulding as we are getting ready to run our completion. RIH with 5 stands of 4" DP from 5,888' to 6,355'. LD 4" DP from 6,355' to 5,705'. PJSM. Repair skate linkage. LD 4" DP from 5,705' to 1,781' RU 2-7/8" handling equipment. LD 2-7/8" DP from 1,781' to 389'. PJSM. Change out handling equipment. LD Schlumberger 2-7/8" PowerJet perf guns from 389' - all guns fired Clear and clean floor. Pull wear ring. PJSM. RU 4-1/2" Chrome Tubing equipment. PJSM. PU Tail Pipe assembly and S-3 Packer. All connections below packer are made up with Baker-Lok PU 4-1/2", 12.6#, 13Cr80, Vam Top Tubing to 4,346'. Connections made up with Jet Lube Seal Guard and torqued to Printed: 2/16/2004 9:41:39 AM e e Page 18 of 18 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-05 H-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I Date From - To Hours Task Code NPT: Phase .-".-..----...--- 2/10/2004 13:30 - 18:00 4.50 RUNCOMP COMP 18:00 - 18:30 0.50 RUNCOMP COMP 18:30 - 00:00 5.50 RUNCOMP COMP 2/11/2004 00:00 - 03:00 3.00 RUNCOMP COMP 03:00 - 05:00 2.00 RUNCOMP COMP 05:00 - 07:30 2.50 RUNCOMP COMP 07:30 - 09:00 1.50 RUNCOMP COMP 09:00 - 10:00 1.00 WHSUR P COMP 10:00 - 19:00 9.00 WHSUR P COMP 19:00 - 20:00 1.00 WHSUR P COMP 20:00 - 23:30 3.50 WHSUR P COMP 23:30 - 00:00 0.50 WHSUR P COMP Start: 1/13/2004 Rig Release: 2/11/2004 Rig Number: Spud Date: 9/27/1971 End: 2/11/2004 Description of Operations _____...__ _.. _.._ ____ _n .___ __ __ _.. . ......----..--- 4,440 ft-Ibs. Service Top Drive. PU tubing from 4,346' to 8,519'. PU tubing from 8,519' to 10,712'. Connections made up with Jet Lube Seal Guard and torqued to 4,440 ft-Ibs. Tagged Top ofTieback Sleeve @ 10,712'. Tagged bottom @ 10,723', tubing measurement. PU - 145K, SO - 105K. Spaceout and land tubing on hanger @ 10,719'. RILDS. Clear Floor. Reverse Circulate Seawater and corrosion inhibitor. 3 bpm @ 300 psi Drop 1-7/8" ball and rod. Set packer and test tubing to 3,500 psi for 30 minutes. Bleed off tubing pressure to 1,500 psi. Test annulus to 3,500 psi for 30 minutes. Bleed off tubing pressure to 0 psi and shear DCK in upper GLM. Weather conditions are at Phase 2. Dry rod TWC and test from below to 1,000 psi. Blow down surface equipment. NO BOP's. NU Tree and addapter flange. Test to 5,000 psi. RU DSM with lubricator and pull TWC. RD DSM. RU and test circulating lines. RU LRHOS and reverse circ 75 bbls Diesel FP. U-Tube Diesel. Dry rod BPV and test from below to 1,000 psi. RD LRHOS Remove secondary Annulus Valve. Release Rig @ 2400 hrs 2/11/2004 Printed: 2/16/2004 9:41:39AM . . t)Q3æð 19-Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well H-05A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,908.70' MD 7,982.00' MD 12,470.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) Fr-.... ? 6 1)'''':'\4' '-C,LJ~. ¡;..JU; f:~a~{a Oil &. Gas Cons. Commision P£lct¡orage ~ß~\\\D · . DEFt N ITIVE Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA H Pad H-05A e Job No. AKMW2853212, Surveyed: 7 February, 2004 Survey Report 10 February, 2004 Your Ref: API 500292010601 Surface Coordinates: 5960015.36 N, 643312.65 E (70017' 53.7180" N, 148050'21.7248" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 960015.36 N, 143312.65 E (Grid) Surface Coordinates relative to Structure Reference: 2405.49 N, 1994.34 E (True) Kelly Bushing Elevation: 72.83ft above Mean Sea Level Kelly Bushing Elevation: 72.83ft above Project V Reference Kelly Bushing Elevation: 72.83ft above Structure Reference spar"'r"'Y-SUI! DRILLING SeRViCeS A Halliburton Company Survey Ref: svy4157 Halliburton Sperry-Sun Survey Report for PBU_WOA H Pad - H-05A Your Ref: API 500292010601 Job No. AKMW2853212, Surveyed: 7 February, 2004 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7908.70 47.080 318.000 6286.66 6359.49 2234.47 N 2795.42 W 5962196.11 N 640475.13 E 537.40 Tie On Point MWD Magnetic 7982.00 47.150 318.000 6336.54 6409.37 2274.38 N 2831.36 W 5962235.34 N 640438.44 E 0.095 554.00 Window Point 8063.73 47.360 325.330 6392.05 6464.88 2321.41 N 2868.53 W 5962281.64 N 640400.37 E 6.589 576.13 8157.67 47.450 333.870 6455.70 6528.53 2380.95 N 2903.46 W 5962340.51 N 640364.31 E 6.690 610.23 e 8202.38 46.580 337.920 6486.19 6559.02 2410.79 N 2916.82 W 5962370.09 N 640350.39 E 6.905 629.39 8251.77 46.400 338.150 6520.19 6593.02 2444.01 N 2930.22 W 5962403.04 N 640336.36 E 0.497 651.46 8344.50 41.270 334.950 6587.07 6659.90 2502.93 N 2955.68 W 5962461.46 N 640309.77 E 6.025 689.76 8437.45 40.500 331.950 6657.35 6730.18 2557.34 N 2982.86 W 5962515.35 N 640281.56 E 2.269 723.29 8532.02 39.720 332.870 6729.67 6802.50 2611.34 N 3011.08 W 5962568.80 N 640252.32 E 1.036 755.94 8624.45 39.740 335.420 6800.76 6873.59 2664.49 N 3036.84 W 5962621.45 N 640225.55 E 1.763 789.10 8715.59 40.160 329.720 6870.66 6943.49 2716.38 N 3063.78 W 5962672.82 N 640197.62 E 4.041 820.56 8808.63 40.010 332.180 6941.84 7014.67 2768.75 N 3092.87 W 5962724.62 N 640167.54 E 1.710 851.37 8903.36 39.160 331.630 7014.85 7087.68 2822.00 N 3121.30 W 5962777.32 N 640138.10 E 0.971 883.27 8994.65 41.500 330.280 7084.44 7157.27 2873.64 N 3149.99 W 5962828.40 N 640108.43 E 2.736 913.64 9089.04 44.080 329.210 7153.70 7226.53 2929.01 N 3182.31 W 5962883.15 N 640075.06 E 2.840 945.44 9162.45 44.660 333.150 7206.19 7279.02 2973.97 N 3207.04 W 5962927.63 N 640049.48 E 3.835 972.02 9274.63 44.390 336.210 7286.18 7359.01 3045.06 N 3240.68 W 5962998.06 N 640014.49 E 1.928 1016.76 9368.24 43.880 338.750 7353.37 7426.20 3105.26 N 3265.64 W 5963057.78 N 639988.38 E 1.966 1056.41 9462.21 43.420 338.040 7421.36 7494.19 3165.57 N 3289.52 W 5963117.62 N 639963.36 E 0.715 1096.70 9555.96 42.980 339.840 7489.70 7562.53 3225.45 N 3312.59 W 5963177.05 N 639939.15 E 1.396 1137.03 9649.94 42.350 337.660 7558.81 7631.64 3284.80 N 3335.66 W 5963235.95 N 639914.95 E 1.709 1176.89 e 9742.40 41 .440 339.980 7627.64 7700.47 3342.36 N 3357.98 W 5963293.08 N 639891.54 E 1.943 1215.58 9835.61 40.490 337.280 7698.03 7770.86 3399.26 N 3380.23 W 5963349.54 N 639868.21 E 2.155 1253.73 9928.48 39.670 340.410 7769.10 7841.93 3455.01 N 3401.81 W 5963404.87 N 639845.57 E 2.343 1291.22 10021.92 38.540 333.140 7841.64 7914.47 3509.10 N 3424.98 W 5963458.51 N 639821.38 E 5.052 1326.48 10114.32 38.460 329.970 7913.96 7986.79 3559.67 N 3452.37 W 5963508.54 N 639793.03 E 2.137 1356.58 10207.75 38.620 332.600 7987.05 8059.88 3610.71 N 3480.33 W 5963559.04 N 639764.10 E 1.762 1386.80 10301.63 39.890 329.300 8059.75 8132.58 3662.61 N 3509.18 W 5963610.39 N 639734.26 E 2.603 1417.33 10395.01 41.510 330.320 8130.54 8203.37 3715.25 N 3539.80 W 5963662.43 N 639702.65 E 1.875 1447.60 10488.61 40.880 332.290 8200.97 8273.80 3769.32 N 3569.40 W 5963715.92 N 639672.02 E 1.541 1479.63 10 February, 2004 - 9:31 Page 2 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA H Pad - H-05A Your Ref: API 500292010601 Job No. AKMW2853212, Surveyed: 7 February, 2004 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 1 0582.4 7 41.710 334.780 8271.50 8344.33 3824.76 N 3596.99 W 5963770.83 N 639643.38 E 1.961 1513.85 10676.01 42.270 334.280 8341.02 8413.85 3881.26 N 3623.90 W 5963826.80 N 639615.39 E 0.697 1549.32 10769.55 41.070 332.870 8410.90 8483.73 3936.95 N 3651.56 W 5963881.96 N 639586.67 E 1.628 1583.72 10804.87 40.570 333.170 8437.62 8510.45 3957.52 N 3662.04 W 5963902.33 N 639575.81 E 1.521 1596.30 10898.64 41 .180 334.770 8508.53 8581.36 4012.66 N 3688.96 W 5963956.94 N 639547.84 E 1.292 1630.59 e 10992.00 41.800 334.750 8578.46 8651.29 4068.61 N 3715.34 W 5964012.37 N 639520.40 E 0.664 1665.85 11054.44 41.840 334.970 8624.99 8697.82 4106.30 N 3733.02 W 5964049.72 N 639502.00 E 0.244 1689.65 11082.76 41.900 334.530 8646.08 8718.91 4123.39 N 3741.09 W 5964066.66 N 639493.61 E 1.058 1700.42 11117.15 42.080 335.440 8671.64 8744.47 4144.24 N 3750.81 W 5964087.32 N 639483.49 E 1.846 1713.61 11148.44 43.930 339.380 8694.53 8767.36 4163.94 N 3759.00 W 5964106.86 N 639474.93 E 10.425 1726.58 11175.74 45.650 343.340 8713.91 8786.74 4182.16 N 3765.13 W 5964124.96 N 639468.45 E 12.003 1739.29 11209.44 46.700 343.990 8737.24 8810.07 4205.49 N 3771.97 W 5964148.16 N 639461.17 E 3.412 1756.08 11241.99 46.590 343.570 8759.59 8832.42 4228.22 N 3778.58 W 5964170.75 N 639454.12 E 0.997 1772.45 11270.58 46.510 344.590 8779.25 8852.08 4248.18 N 3784.27 W 5964190.60 N 639448.05 E 2.605 1786.89 11304.80 46.540 345.530 8802.80 8875.63 4272.17 N 3790.67 W 5964214.46 N 639441.19 E 1.995 1804.47 11335.82 48.370 349.540 8823.78 8896.61 4294.48 N 3795.59 W 5964236.67 N 639435.85 E 11.201 1821.33 11363.72 50.690 353.500 8841.89 8914.72 4315.46 N 3798.71 W 5964257.60 N 639432.33 E 13.626 1837.95 11398.08 53.630 357.480 8862.97 8935.80 4342.50 N 3800.82 W 5964284.59 N 639429.71 E 12.523 1860.31 11429.75 57.680 0.040 8880.83 8953.66 4368.64 N 3801.38 W 5964310.71 N 639428.66 E 14.423 1882.66 11458.39 61.460 2.220 8895.34 8968.17 4393.32 N 3800.88 W 5964335.40 N 639428.68 E 14.739 1904.29 11492.21 65.470 7.210 8910.45 8983.28 4423.45 N 3798.37 W 5964365.57 N 639430.61 E 17.739 1931.64 11522.37 66.750 11.710 8922.67 8995.50 4450.64 N 3793.83 W 5964392.85 N 639434.63 E 14.286 1957.45 e 11552.17 70.020 15.540 8933.65 9006.48 4477.56 N 3787.30 W 5964419.88 N 639440.65 E 16.221 1984.03 11585.26 75.070 20.560 8943.58 9016.41 4507.54 N 3777.51 W 5964450.04 N 639449.87 E 21.028 2014.89 11616.29 79.680 23.530 8950.36 9023.19 4535.59 N 3766.14 W 5964478.31 N 639460.70 E 17.547 2044.87 11645.13 83.000 26.240 8954.70 9027.53 4561.45 N 3754.14 W 5964504.39 N 639472.20 E 14.792 2073.26 11684.25 88.770 31 .430 8957.51 9030.34 4595.60 N 3735.33 W 5964538.89 N 639490.36 E 19.812 2112.24 11712.49 90.560 34.960 8957.68 9030.51 4619.23 N 3719.88 W 5964562.81 N 639505.36 E 14.015 2140.43 11745.36 93.640 37.130 8956.47 9029.30 4645.78 N 3700.55 W 5964589.73 N 639524.17 E 11 .459 2173.09 11777.93 91.170 41.960 8955.10 9027.93 4670.87 N 3679.84 W 5964615.20 N 639544.40 E 16.644 2205.17 11807.12 91.230 41.930 8954.49 9027.32 4692.57 N 3660.33 W 5964637.28 N 639563.49 E 0.230 2233.72 11839.32 93.340 43.330 8953.21 9026.04 4716.24 N 3638.55 W 5964661.36 N 639584.83 E 7.862 2265.11 11871.26 91.240 49.230 8951.93 9024.76 4738.29 N 3615.49 W 5964683.84 N 639607.46 E 19.592 2295.73 11899.22 90.430 54.220 8951.52 9024.35 4755.60 N 3593.55 W 5964701.57 N 639629.06 E 18.079 2321 .70 11933.04 90.490 59.160 8951.25 9024.08 4774.17 N 3565.30 W 5964720.67 N 639656.96 E 14.607 2351.90 10 February, 2004 - 9:31 Page 3 of 5 Dri/lQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA H Pad - H-05A Your Ref: API 500292010601 Job No. AKMW2853212, Surveyed: 7 February, 2004 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11964.22 88.580 66.050 8951.51 9024.34 4788.51 N 3537.63 W 5964735.53 N 639684.34 E 22.929 2378.15 11992.48 92.530 69.330 8951.23 9024.06 4799.23 N 3511.50 W 5964746.75 N 639710.27 E 18.166 2400.51 12026.00 90.990 73.620 8950.20 9023.03 4809.87 N 3479.74 W 5964758.00 N 639741.82 E 13.592 2425.60 12057.40 90.490 78.640 8949.80 9022.63 4817.40 N 3449.27 W 5964766.10 N 639772.14 E 16.065 2447.35 12084.93 90.680 82.340 8949.51 9022.34 4821.94 N 3422.12 W 5964771.17 N 639799.20 E 13.457 2464.86 e 12119.89 91.420 85.880 8948.87 9021.70 4825.53 N 3387.36 W 5964775.41 N 639833.89 E 10.343 2485.35 12151.15 91.980 89.060 8947.95 9020.78 4826.91 N 3356.14 W 5964777.39 N 639865.07 E 10.325 2502.15 12179.53 92.590 91.010 8946.81 9019.64 4826.89 N 3327.79 W 5964777.91 N 639893.42 E 7.194 2516.32 12213.33 91.050 95.540 8945.74 9018.57 4824.96 N 3294.07 W 5964776.63 N 639927.17 E 14.149 2531.50 12244.75 91.670 98.140 8945.00 9017.83 4821.22 N 3262.89 W 5964773.48 N 639958.42 E 8.505 2543.86 12273.26 91.850 97.870 8944.12 9016.95 4817.25 N 3234.67 W 5964770.05 N 639986.71 E 1.138 2554.53 12307.01 90.000 97.430 8943.57 9016.40 4812.76 N 3201.22 W 5964766.20 N 640020.23 E 5.634 2567.36 12337.94 89.010 98.080 8943.84 9016.67 4808.59 N 3170.58 W 5964762.61 N 640050.95 E 3.829 2579.07 12365.63 88.950 98.290 8944.33 9017.16 4804.65 N 3143.17 W 5964759.19 N 640078.42 E 0.789 2589.36 12399.65 89.880 99.840 8944.68 9017.51 4799.29 N 3109.58 W 5964754.47 N 640112.11 E 5.313 2601.51 12470.00 89.880 99.840 8944.83 9017.66 4787.26 N 3040.27 W 5964743.77 N 640181.64 E 0.000 2625.76 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 30.000° (True). Magnetic Declination at Surface is 25.322° (22-Jan-04) e Based upon Minimum Curvature type calculations, at a Measured Depth of 12470.00ft., The Bottom Hole Displacement is 5671.08ft., in the Direction of 327.581 ° (True). 10 February, 2004 - 9:31 Page 4 of 5 DrillQuest 3.03.05.005 · . Halliburton Sperry-Sun Survey Report for PBU_WOA H Pad - H-05A Your Ref: API 500292010601 Job No. AKMW2853212, Surveyed: 7 February, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7908.70 7982.00 12470.00 6359.49 6409.37 9017.66 2234.47 N 2274.38 N 4787.26 N 2795.42 W 2831.36 W 3040.27 W Tie On Point Window Point Projected Survey e Survey tool program for H-05A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 7908.70 0.00 7908.70 6359.49 12470.00 6359.49 BP High Accuracy Gyro (H-05) 9017.66 MWD Magnetic (H-05A) e 10 February, 2004 - 9:31 Page 5 of 5 DrillQuest 3.03.05.005 'Ræ~" 4 1/16" VãIHÈÄD:= . MCEVOY ;âri.JATõFf;;--~--OTïš B,ELEV";' "········64ß Þ. 8.EV ':'; . ---«.Sa'· JP = 2742' .. -~.- ~.~ ~."g!o =, JlÎ.Jrn MO :: ¡¡üm"1VÖ ::: .-.... ~" ........: .~ ~. . . ....... ,.. .. . 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'l,!...,Œ.L_!,¡~ '~":""" .~,.Jt~.~~,~_."..j,.tUJ....i,J. .~ª". ,~1~11."~I11.Jtl"t5j~hJ:.J?Y"_1~J!:..",,~.~:_~,, .:£:LfJ.I.ttl: _~, ,,,~:l..~~,, ".2~..""..J.: ._:tl. .!:!~l?;: J.~,_J~,~....l. .~___ :¥¡~J-º1: _ 1, .,i,!~~:\;JL,,,$]~"J",. "t 1.,..r:t4~)t, ~;N. .~~~. ..' ... ,. ~~1Jtlb'\} 'Mlr,irn~m 1'6 ~ à:125" @'IO;':)I:(j ¡. 4..1/2" XN NIPPLE L~~,1!2~~G~ 12'~~'i13cr:~O~"þ,~ ~:~) 3-' r'r] [~Ii~te TOC 9 5/8w x' 7; A~ln~/~~ ,. .H~~3..'~G~ . ___ ~ . rC ~~L.80 Scab Line, (Ù7~'iÕ),J-7Ø 'M' '.I _ ( 17~'26#,L"â?",Ori1JIr1~_~lnor (6·..271ì" IO))-[ i:~~ 'g~\Q,i 1 ~ j . 'It '\1 ij i , ~. , 'to': I á,~ni~~I,~t. (~?~ ot,.fish) ~ I-~f. ,~~,5Ó''','1 ,--- lliJ2~ ·1r}j""lR'.~/8"' Wi~ld~~ . J L1(*4,~:J~4 1/2~'xYi~pï~(3.813" 10) , J . [Jd~l,CJ-{7.". )('4 1/2" 8!k~r ,.. Pac,~er'l UÞ0ª:LJ-{4 1/~.~X'~ip'pIO-.~3.8,13~'¡~)~ .,,'.., ~I :[@~tD"1V~4 1/2~ XN.Nippla,p,~72~~,'?).. I . . I t ö'·?ï~~!-{4 , ~ t2~~~~~~~, t~p I~ÜiG .:',,, . ".. u. [iõ''Zl~' . ]-{~~ /2~,~'lJ!lg~r l.!it~er top ~acke~" ITä~~fl'" r 2HÙ'L~a~'(6~27?"'IO) O.383,~þ. PERFORA'OON SUM\V\RV REF LOG:SWS·BHCS ON 10/21171 A NGLE, A TTOPPERF: ' Note: Refer to A'oduclloll Defat hlslorlcal perf data "size ''''SFr MmvAL"- ÔprvSqz 'DATE '2 7fa~ 4 . ". , ,....,. TOPOF 7~ LNR}i 9416' K¡j ;~ ;:23C;: ~~ ~ 't;~ '.' '.' i I ..,J !:;~: ,¡:::: ;::;.Ö~~:~:~pr~¡~t~~:!· . . ,r . " 11314' 1-i7." X4',~12" orIS HC A<R. io"~-~Ü~~"I 1135Si . t-{~-112" C?~·mG TAIL. 10 ~ 3._958~ I 19-5~~~ cs'~ ~!~,L:~~:Ô = 8.681~1-{ 10011' ( AHD I-I 11581' 17" LNR.~.9#, N-8~. :~371 bpf~ 0 = 6.184" l-f 116SÒ' )A TE . . Rev BY- . , COMM8'ffS -' -, 118/77 ORIGINAL COMPLETION 'J12/87 ~o , l01iofT sts:.t'i~·T¡:"'^~'~···":-:"''' ",' .'--'~ .. .. ... ,I, ii2'7iÕ3ro Srrilh p¡.oposed Sidetrack Corrpletion OA TE R£:.I BY CÓMMENTS . .: I ,. ,. ..-¡-' .. , , , .~~"5.'. ~~: ::.. r~UDHOE SA Y UNIT WELL: H-05A ÆHMrr No; 1710240 ·,,,'..1. ,.... .' ...,. . ·...A·~ ~,:,. t:,t.\ 1)"'0.-""\'106-01:' S[-t; ¿, ; , or' 1 N. r-< I.JG. 773' FNL &. 1265' Fa. , , '" _._............."...,4...._.............._......................._.___....................."................._..........................................._...................................._...'_.._..__.,......... ,....,......,.....'........--.........-...."'....-.---...----............. OP F.xplonltiOM (l\I:I~k..) ,......." ..,.................."'-....".."...... ,..,."" . "..",.,... ....-.,".. .-..",,".........-........ ...~.... ...-. . ", ", .'".. .......R............._.........._,_,. "'" ,~..__.........,...................~... .....,.. . . eCt3~ ddO WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7111 Avenue, Suite 100 Anchorage, Alaska February 25, 2004 RE: MWD FOI11lation Evaluation Logs H-05A, AK-MW -2853212 1 LDWG fOI11latted Disc with verification listing. ÞùPI#: 50-029-20106-01 ) é)Lß3 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECJ::IVED . ~ \' ~ SIgned: ~) \}J... .~ \:~~ (~íY\. p~~-~ ? 6 ;':1í¡,J * .-.. :..; '- ..~.._' v"'~ /\!Bska Oi! & Gas Cons. Commi33i0n. ;'r"l'~,,,..t~"/A ì ,,>i! pj d;~~'" ~~~rn~ lit e I FRANK H. MURKOWSKI, GOVERNOR .AI,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FÞèK (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe bay Unit H-05A BP Exploration (Alaska), Inc. Permit No: 203-220 Surface Location: 773' SNL, 1265' WEL, Sec. 21, T11N, R13E, UM Bottomhole Location: 3961' NSL, 3997' WEL, Sec. 16, TUN, R13E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sinc..er..:~y,. . ../'/·):j7 ' /.......} 'l I)' §~~~~~.\t 'fr- Chair BY ORDER 2:';; THE COMMISSION DATED thj~ day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. t;JGA I z..{ 2..z../2..003 o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. location of Well (Governmental Section): Surface: 773' SNl, 1265' WEl, SEC. 21, T11N, R13E, UM Top of Productive Horizon: 3888' NSl, 4925' WEl, SEC. 16, T11N, R13E, UM Total Depth: 3961' NSl, 3997' WEl, SEC. 16, T11N, R13E, UM 4b. location of Well (State Base Plane Coordinates): Surface: X-643313 Y-5960015 Zone-ASP4 16. Deviated Wells: Kickoff Depth Casing~rc:>grarn Size Casing 7" . STATE OF ALASKA .- ALASKA O. NO GAS CONSERVATION COM_SION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: IHI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 12760 TVD 9043 7. Property Designation: ADl 028284 . Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU H-05A / 12. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. land Use Permit: 13. Approximate Spud Date: . 01/10104 ,/ 14. Distance to Nearest Property: 27600' 9. Acres in Property: 2560 8000 ft Maximum Hole Angle 92° 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool ,- (Height above Gl): 73.2' feet N-22A is 602' away at 11250' MD 17. Anticipated pressure (see 20 AAC 25.035) / Max. Downhole Pressure: 3300 psig. Max. Surface Pressure: 2300 psig Qua~ti'~f ent (c.f: or s s) (including stage data) 169 sx Class 'G' 257 sx Class 'G' Hole 8-1/2" 6-1/8" 4-1/2" Weight 26# 12.6# Grade Coupling length l-80 BTC-M 3014' 13Cr80 Vam Top 2050' MD 7850' 10710' TVD 6317' 8400' MD 10864' 12760' TVD 8548' 9043' ~ /' PRESENT'A'EL.L Qc:;>NDITION SUMMARY (To !)øçqrnpleted for Redrill ANP Re-entrS' QpßrâliQQ$) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD 11678 9265 NIA 11581 9178 Structural Conductor 100' 30" 265 sx Permafrost II 100' 100' Surface 2299' 18-5/8" 6200 sx Permafrost " 2299' 2298' Intermediate 2251' 13-3/8" 2251' 2250' Production 10011' 11-3/4" x 10-3/4" x 9-518" 875 sx Class 'G' 10011' 7862' liner 2174' 7" 675 sx Class 'G' 9476' - 11650' 7450' - 9240' 20. Attachments IHI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8978' - 9044' IHI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IHI Drilling Fluid Program 1H120 AAC 25.050 Requirements Perforation Depth MD (ft): 11355' - 11430' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Signature l ~ lL. t t.. Phone 564-5521 Date \ l/r:t/o'J, Commission Use Only I Permit APProval/~·. '1J Ii I See cover letter for Date: Zf/ 7 other requirements Mud log Required I:) ~ f" C'A~a m Hydrogen Sulfide Measures 181 Yes 0 No Directional Survey R~f¡d\J ~te~ 'E! ~ Other:·T~,.;t-- ~'ÛPE' +c ~C;O~ ft;{' " , ~ , t. DEC 1 8 '2ü03 , Per ?fiJMc 'Z-S,O'3S (h,ìU\) t\h.W- sp~"-<<:.. f-t~ rt.t~~ ~L("'(~VVl~IA.J· iSc',.v~h.tnd. Araska Oil & Gas Cons. o~ . Original Signed By BY ORDER OF Anchorage '10/1 '?~... # Approved By: .. Sarah pali\").. . . COMMISSIONER THE COMMISSION Date I Þ 'Z¿;" ~:)'l/ Form 10-401 Revis_ fWl DEC 2 ~ 1JlJ3 U i ¡ G i i~ A L Sub it In uprkate Date: Contact Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill I API Number: Number:.203 - 2- 2..<:::1 50-029-20106-01-00 Conditions of Approval: Samples Required DYes ~No tit e I Well Name: I H-05A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Target Location: Ivishak Zone 28 Bottom Hole Location: x = 643,313 Y = 5,960,015 773' FNL 4015' FWL Sec. 21, T11N, R13E Umiat X = 639,554 Y = 5,964,606 TVDss 8970' 1392' FNL 355' FWL Sec. 16, T11N, R13E Umiat X = 640,480 Y = 5,964,696 TVDss 8970' 1319' FNL 1282' FWL Sec. 16, T11N, R13E Umiat /' /' / I AFE Number: I PBD4P2169 I I Rig: I Nabors 2ES ,/ I Estimated Start Date: 101/10/2004 I /' I Operating days to complete: 123.5 I MD: 112,760' II TVD: 19043' I I GL: 144.7' I KB: 128.5' I I KBE: 173.2' I Well Design (conventional, slim hole, etc.): I Two String Horizontal Sidetrack I Objective: I Ivishak Zone 2B Directional - Sperry wp03 KOP: I 8000' MD Maximum Hole Angle: Close Approach Wells: Survey Program: Nearest Property Line: Nearest Well within Pool: -47° in the 8-1/2" intermediate section (KOP; 41.7° at section TD) -91.5° in the 6-1/8" horizontal section @ 12,129' The nearest well is N-22A at 602' center-center distance at 11,250' MD of the planned well (in the reservoir section). This well has been minor risked at 1/200' to pass the close approach criteria. All other wells pass major risk criteria. MWD Standard 27,600' to the nearest PBU property line N-22A is 602' away from planned well H-05A at 11,250' planned MD. CasinglTubing Program Hole Size CsglTbg WtlFt Gr~e Conn Length Top Btm O.D. / MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 3014' 7,850/6,317' 10,864'/8,548' 6-1/8" 4 Y2" 12.6# 13Cr-80 Vam Top 2050' 10,710'/8,400' 12,760'/9,043' Tubing 4 Y2" 12.6# 13Cr-80 Vam Top -10,680' GL 10,710'/8,400' H-05A Permit to Drill Page 1 Formation Markers Formation Tops (wp03) TVDss CM3 Above KOP KICKOFF -6355 CM1 -6497 THRZ -6863 BHRZ/LCU/KINGAK -7136 T JF -7514 THE -7675 T JD -7925 T JC -8193 T JB -8310 SAG RIVER -8475 SHUBLIK -8505 TSAD 1 TZ4B -8588 TCGL 1 TZ3 -8740 BCGL 1 TZ2C -8800 PGOC -8851 25N -8894 22N -8952 MHO/HOT -8973 21N BelowTD TD -8970 9043 12,760 TD Criteria: The goal of the well is to perforate 600' of hole in the lateral section. The minimum amount of perforations is 300' incorporating 150' standoff from faults. e Mud Program Section Millin¡ Mud Properties: LSND Density (ppg) Viscosity I PV 11.2 50-65 15-25 Intermediate Mud Properties: LSND Den"ðßi ppg) I Viscosity I PV 1.~ 45-55 12-15 ~ Production Mud Properties: FloPro Density (ppgL- Viscosity I PV 8.4 - 8.5.7 I 45-55 10 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR/Res Open Hole: None Cased Hole: None TVD 6428 6570 6936 7209 7587 7748 7998 8266 8383 8548 8578 8661 8813 8873 8924 8967 9025 9046 e MD Comments 8,000 8,702 8,978 9,613 10,116 10,467 10,740 10,864 10,909 10,016 11,213 11,312 11,383 11 ,463 11,617 3140 psi @ 8800' TVDss / Not penetrated I Whip Stock Window 9-5/8",47# I YP I TauO I APIFL 40+ 5-9 4-6 PH 9.0-9.5 I 8-1/2" hole section YP I TauO 22-28 3-7 I APIFL PH 5-6 9.0 YP MBT 30 < 3 I API FI 4-6 pH 9.0-9.5 6-1/8" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/G R/Res/Neu/Den None Contingent MCNL if Neu/Den fails while drilling H-05A Permit to Drill Page 2 e e Cement Program I Casing Size 17" 26#, L-80 Intermediate Liner Basis: lead: None Tail: Based q,p-8CJ'ßhoe track and 1000' of 7" X 8-1/2" open hole with 40% excess. Tail TOC:~6~D (1000' above shoe) I Total Cement Voluffii!: I Spacer 125 bbls MudPus~ ~ ppg ~ Tail 34.8 bbls, 195 ft~~acks Class G @ 15.8 PP9'f.:~t3/sack I Casing Size 1 7" 26#, L-80 Scab Liner Basis: lead: None Tail: 100~' of ..?!-X 9-5/8" casing annulus with 0% excess (7850' - 6850' MD) Tail TOC: 5 MD I Total Cement Vol:c I Preflush 115 bbls CW-100 ~ /) Tail 26 bbls, 146 ft3,~acks Class G @ 15.8 PP9,~1Øft3/sack I Casing Size 14.5" 12.6#, 13Cr-80 Production Liner 1 Basis: lead: None Tail: Base~on 8 'shoe track, 1900' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner lap, a 20' of 7" excess. Tail TOC: ,7 MD (Tal) I Total Cement Volu ." Preflush 15 bbls CW-100 Spacer 25 bbls MudPush ~5 ppg /I Tail 53 bbls, 298 ft3~]-Éacks Class G @ 15.8 ppg,e.~/sack / Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole 7" Drilling Liner Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids H-05A Permit to Drill 3300 psi @ 8500' TVDss (estimated, 7.5 ppg EMW) 2300 psi (.10 psi/ft gas gradient to surface) Infinite with a 12.5 ppg FIT Rams test to 3,500 psi/250 psi / Annular test to 2,500 psi/250 psi 3500 psi surface pressure 12.5 ppg FIT after drilling 20' from middle of window The VBRs will not be changed to accommodate the 3000-ft 7" drilling 1 liner. Instead, the current and best practice of picking up a joint of . drillpipe, with crossover to the casing thread, will be employed in the event of a kick. This practice provides two rams capable of closing ~'5~'5<'Þ:J(Ì) on the pipe across the BOP stack instead of just a single 7" ram. 3180 psi @ 8800' TVDss (7.0 ppg EMW) 2300 psi (.10 psi/ft gas gradient to surface) Infinite with a 10.0 ppg FIT Rams test to 3,500 psi/250 psi. / Annular test to 2,500 psi/250 psi 3500 psi surface pressure 10.0 ppg FIT after drilling 20' from shoe 8.4 ppg Seawater / 7.2 ppg Diesel Page 3 e e Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Pre-Riq Work: * Notify the field AOGCC representative with intent to plug and abandon * ./ The tubing was drifted to 3.77" on 9/23/03 to prepare for a USIT log of the IA above the packer. 1. Downsqueeze the 18 5/8" x 13 3/8" annulus (7.75 bpf) with 77 bbls arctic grade cement, followed dead crude. Follow procedure distributed by J. Julian December 2, 2003. The cement and crude will provide two barriers for testing and changing out the 13 3/8" pack-off. 2. Pressure test the 185/8" x 133/8" annulus to 1000 psi. (80% of 185/8" burst = ±2000 psi, 80% of 13 3/8" collapse = ±1550 psi). Bleed OOA to zero. 3. Coordinate with Cameron to pressure test the 133/8" pack-off. 4. RIH with coiled tubing and P&A the tubing with 49 bbls 15.8 ppg cement from top of IBP at 11,258 to ±8500'MD. Dress off the top of cement. 5. Drift the tubing and tag top of cement. Chemical cut the 5%" tubing at ± 8,150' in the middle of a joint. 6. Combo test the tubing and IA & OA to 2500 psi (80% of 13 3/8" 68# K-55 burst = 2760 psi). 7. Reverse circulate 600 bbls (1 well volume) of 1800 seawater down the IA (returns up the tubing) while bleeding the OA and OOA to zero. It will be important to bleed all of the pressure from the annuli to prepare the well for the planned rig work. Perform multiple circulations and shut-downs if necessary. 8. When all annulus pressures have been confirmed zero, freeze protect the IA and tubing with diesel to 2000'. Leave the well with zero psi on all gauges before freeze protecting & rigging down the flowline. 9. Cycle the tubing hanger and all pack-off lock down screws. 10. Remove the well house. If necessary, level the pad. Provide total well preparation cost on the handover form. Ri!:l Operations: 1. MIRU Nabors 2ES. Bleed annulus pressures as required. 2. Circulate out freeze protection and displace well to seawateý.' Set TWC. 3. Nipple down tree. Nipple up and test BOPE. /' 4. Pull 5W' tubing from above pre-rig cut. 5. RU E-line and run a gauge ring / junk basket to 8100'. Set a bridge plug at ±8030' to avoid cutting a ./ casing collar with the whipstock mill. 6. Nipple down BOPs and tubing spool. 7. Weld the emergency slips to the 9 5/8" casing. 8. NU and Test BOPs. 9. Spear casing and pull from the PBR at 2130'. 10. Circulate Arctic Pack from the 13 3/8" x 9 5/8" annulus with diesel followed by seawater. 11. Lay down three joints of thermal casing and 2000' of 10 %" casing. ./ 12. RIH with 8 %" bit to bridge plug at 8030'. Include a 133/8" casing scraper spaced out to top of PBR at 2130'. Circulate out residual Arctic Pack. 13. Circulate well to 11.2 ppg milling/drilling fluid. POH, LD BHA. / 14. NO BOPs, change out 133/8" packoff, test, install new YB style casing spool, NU and test BOPs. 15. RIH with 8 %" whipstock and milling assembly to bridge plug depth. Test the casing to 2500 psi. Orient and set the whipstock. 16. Mill window in 9 5/8" casing at ±8,OOO' MD plus 20' from mid window. Perform FIT to 12.5 ppg. POH. 17. Kick-off and drill the 8%" section to the top of the Sag River at -10,864' MD. 18. Run and cement a 7",26# L-80 intermediate drilling liner, cemented -1000' above the 7" casing shoe. // 19. RIH with 7" 26# L-80 BTC-mod tieback string with perforated seal assembly. H-05A Permit to Drill Page 4 e e 20. Locate seal assembly into tieback receptacle and pump diesel freeze protection followed by 1000' /' annular feet of cement. Land tieback casing into the receptacle. ND BOP, install casing slips, cut and dress the 7" casing, install packoff and test. / 21. NU tubing spool. NU and test BOPs. Pressure test casing to 3500 psi. 22. Make up and RIH with 6-1/8" directional assembly to the landing collar. 23. Drill out the 7" shoe tract and change the well over to 8.4 ppg Drill-In fluiej. 24. Drill 20' of new formation and perform FIT to 10.0 ppg. ../ 25. Drill the 6-1/8" production section as per directional plan to an estimated TD of 12,760' MD. 26. Run & cement a 4 W', 12.6# 13Cr-80 production liner. Displace well to clean seawater above linß-r' top. 27. DPC Perforate the well with Schlumberger 2 7/8" guns at 4 spf, 600' planned. POH LD DP. 28. Run 4-1/2", 12.6# 13Cr-80 completion tying into the 4-1/2" liner top. /' 29. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 30. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 31. Freeze protect the well to -2200' and secure the well. 32. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. H-05A Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ H-05 is positioned in the main row of N-S wells. No wells will require well house removal or shut- in for the rig move onto H-05. The closest neighboring wells are H-33 at 55' center to the north and H-04 at 100' to the south. ~ H Pad is not designated as an H2S site. Standard Operating Procedures for H2S precautions /' should be followed at all times. Recent H2S data from the pad is as follows: #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name H-35 H-36 N-22A N-21 A H2S Reading No Data No Data 10 ppm 10 ppm Date 07/25/2000 09/09/2000 The maximum H2S reading on H Pad is 180 ppm on H-22A on 5/5/2001. The latest reading /" of 110 ppm was recorded on 3/20/2003. ~ Post Permit to Drill in the dog house and camp prior to spud Job 2: De-complete Well Hazards and Contingencies ~ H-05 has been shut-in with an IBP in the tailpipe since June 2002; the tubing is expected to be in reasonable condition with the last caliper indication <12% wall loss. ~ Pre-Rig operations will include P&Aing the well with cement. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested & freeze protected. ~ As part of the pre-rig work, the 13 3/8" x 18 5/8" annulus will be downsqueezed with 600 annular feet of cement, followed by dead crude. This will provide the mechanical barrier and overbalance required to change out the 13 5/8" packott. H-05A Permit to Drill Page 5 e e >- The highest risk identified with the decompletion is with gas breaking out of the Arctic Pack (and possibly the thermal casing itself) while pulling the thermal casing. To reduce the gas breakout potential, the well will be circulated with hot water while bleeding down the annulus as part of the pre-rig. Be prepared on surface for gas breakout nevertheless and route returns from the annulus to a closed top /vented slop tank. >- Parted thermal casing is suspected. Notify Baker Fishing to be prepared with necessary equipment to fish parted casing if required. Job 4: Window Mill Hazards and Contingencies >- Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. >- The 9 5/8" casing was cemented with 96 bbls 12.8 ppg and 110 bbls 15.8 ppg Class G which would fill approximately 3700' of 12 1,4" x 9 5/8" gauge annulus, or TOC ±6300'. Washout to 14.1" average would put the TOC at the KOP of 8000' MD. No CBL has been run in the 9 5/8" casing. Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies >- The intermediate section will kick off in the Colville CM2 and drill through the Kingak shale package and TD at the top of Sag River. Since H-05A will be at _400 inclination, maintain mud weight at minimum 11.2 ppg to interval TD. Follow all shale drilling practices to minimize potential problems. >- The well plan is expected to cross one fault in this section. The first fault intercept is in the Kingak immediately after the KOP. The fault trends W -E for 1,500 ft. and has -30 ft. of throw down to the south. While drilling the H-05 parent there were no recorded losses or instances of hole collapse in the Kingak. In the Kingak interval, only one lost circulation event was encountered in the nearby wells: H-26 well lost 9 barrels of fluid at -6561 TVDss; lost circulation is not considered high risk for this well. >- KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradient of 12.5 ppg at the 9-5/8" casing window, and 9.8 ppg mud in the hole, the kick / tolerance is Infinite. Job 6: Install 7" Intermediate Liner and Tieback Hazards and Contingencies >- Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. >- Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. >- To minimize fire hazard, perform standard precautionary measures, obtain a Hot Work Permit, and use a hydraulic cutter to cut the 7" casing tieback at surface after setting the slips. H-05A Permit to Drill Page 6 e e Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies þ.> A single fault in the Zone 2 sands will be crossed in this hole section. The fault trends WoE for 500 ft. and has 15-20 ft. of throw down to the north. It is not considered high risk for lost circulation. It should be noted that the high velocity gradients in the region contribute to the uncertainty of the fault location. þ.> All polygon lines should be considered hardlines - there are either adjacent faults, or the polygon is constrained to cross a fault at the most optimal location. þ.> If MHO/HOT or POWC is higher than progonosed, geosteer 5 feet above the observed contact using cuttings and resistivity. If MHO/HOT is lower than prognosed, geosteer downward find MHO/HOT boundary and geosteer 5 to 10 feet above the co ct. );- KICK TOLERANCE: In the worst-case scenario 0 8. pg pore pressure in the Ivishak, a fracture gradient of 9.5 ppg at the 7" casing windo , nd 8.5 ppg mud in the hole, the kick tolerance is Infinite. /' -* Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies þ.> Differential sticking is a concern. The 8.5 ppg mud will be -700psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. );- Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Job 10: DPC Perforate Production CasinQ Hazards and Contingencies þ.> Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Job 12: Run Completion Hazards and Contingencies þ.> Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Job 13: ND/NUlRelease Riq Hazards and Contingencies þ.> No wells will require well house removal or shut-in for the rig move off of H-05. See Job 1 for nearby well data and use spotters for moving the rig. H-05A Permit to Drill Page 7 TREE = WELLHEAD = ,.........,..,-.----.--,--".."....~--,----~-..".-.--,----. ACTUA TOR = ,·__'_____nu"_w____ä"k'··'''· KB. ELEV = "'_.".,,"~~~, .·.".~m'''.''.''.~, BF. ELEV = p'·'····'w,~~w,·,",·,p~p,~'w.w,··',·,wp,~'" KOP= N'N""="·W"""~"W·~W""~ Max Angle = ·~",n--___'_____Y"·w.w_______p-ww__·'··'y' Datum MD = ,.....-....,.-.-__.y.·.·.·_·.·.,·................._.·.__··y.·.'w.·,'....,...._..._.__., Datum TVD = 6" CrN MCEVOY OTIS 64.13' ".m~vmm'""""""mw,,,n 44.68' 2742' ""·".wN'~""'''w''.~'''' 53 @ 4000' ,-"w"p-",·___w"""""'m,_."'''",_·v.v''', 11224 ' 8800'SS SAFETYITES: HOLES IN TP BELOW 7" OTIS PKR· / POSS CAUSED BY LEAKING SQZ PERFS BEHIND TP SE P TELEX· 05/31/93. WL PLUGS WON'T TEST BELOW PKR DUE TO HOLES IN TP e H-05 ~ ~ 21' - 140' H 11-314" X 9-518" THERMOCASE II 1 V 2017' H9-5/8" PBRSEALASSEMBLY NO GO I 2 ~ 2220' 1-1 5-1/2" OTIS SSSV LA ND NIP, ID = 4.562" I ..----J 2251' H 13-3/8" X 9-518" XO, ID = 8.681" 1 / ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 4 3342 3230 29 OTIS RA 3 7135 5759 47 OTIS RA 2 9203 7183 44 OTIS RA 1 9271 7234 43 OTIS RA 110-3/4" CSG, 55.5#, N-80, ID = 9.760" H164' - 2020' 113-3/8" CSG, 68#, K-55, ID = 12.415" 1 118-518" CSG, 96.5#, K-55, ID = 17.655" H 2299' ~" . L 1 ESTTOCIN OA (DWNSQ06/28/02) H 8560' 9200-9246' H GMT SHEATH IN TBG (06/28/02) I 9351' H 5-1/2" OTIS XA SLIDING SL V, ID = 4.562" 1 9410' HTBG SEAL ASSY I I I Minimum ID = 3.725" @ 11351' 4-1/2" OTIS XN NIPPLE 9426' H5-1/2" X 4-112" XO 1 9426' H 9-5/8" X 4-1/2" BKR PKR, ID = 4.0" 1 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H 9426' 1 TOP OF 7" LNR H 9476' ¡----,; 19-5/8" CSG, 47#, L-80, ID = 8.681" H 10011' ~ I ~ J ÆRFORA TION SUMMARY REF LOG: SWS-BHCS ON 10/21/71 ANGLEATTOPÆRF: 30@ 11200' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 11200 - 11227 S 03/22/87 4" 4 11238 - 11258 S 03/22/87 4" 4 11269 - 11304 S 03/22/87 4" 4 11315-11345 S 09/12/97 3-3/8" 4 11355-11381 0 01/07/88 3-3/8" 4 11391 - 11411 0 10/15/88 3-3/8" 6 11411 -11422 0 01/29/94 3-3/8" 6 11425 - 11430 0 01/29/94 H MARKER JOINT 1 H IBP & FILL 06/29/02 (IBP NOT SET) 1 11 CEMENT SHEATH BEHIND I TA ILPlÆ & INSIDE TBG H 7" X 4-1/2" OTIS HC PKR, ID = 3.88" 11210' 11258' 11300' 11314' 11340' H4-1/2" OTIS X NIP, ID=3.813" I 11351' H4-1/2" OTIS XN NIP, ID = 3.725" 1 11355' H4-1/2" OTIS TBGTAIL, ID= 3.958" 1 11356' HELMD TT LOGGED 01/13/96 1 14-112" TAILPlÆ, 12.6#, L-80, .0152 bpf, ID = 3.958" 1--1 11355' t--' o ~ I PBTD H 1 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" H 11581' 11650' DATE 02/18/77 12/12/87 03/01/01 08/23/01 03/30102 06/03/02 REV BY COMMENTS ORIGINAL COM PLETION RWO FINAL CORRECTIONS CORRECTIONS REMOVE PACK-OFF SL V REV BY COMMENTS ONS/TP IBP/MIP ELEMENT JLG/tlh OA CMT SQZ (06/28/02) A TD/tlh CASING (THERMO) CORRECT. DCR/TLH CORRECTIONS CMO/TLP MAX ANGLE CORRECTION DATE 06/15102 09/16/02 12/08/02 02/20103 07/14/03 PRUDHOE BAY UNrT WELL: H-05 ÆRMrTNo: 1710240 API No: 50-029-20106-00 SEC21, T11N, R13E, 773' FNL & 1265' FEL SIS-LG RN/KAK TMN/KK RL/KAK BP Exploration (Alaska) TREE = WELLHEAD = ACTUA TOR = w~mw',w ,,""WN_,__, KB. ELEV = ~m""""',""'·,·"'~~ BF. ELEV = KOP= Max Angle = h"'._·___·,.________·____'w'.,._,',_______,'_______________·,.__·_·__.,·.,·w.., Datum MD = .m.w_·.w_·,_·_"'_·_·.·,·_···.·_··_··_·_···______·_.__··,_ow Datum TVD = 4 1/16" MCEVOY OTIS 64.13' ,··,·'·',,"w··,_______________,_ 44.68' 2742' H-O~ ProposecJI1 ~0~:~~.133/8..X185/8..annulusisopento W""""'N~u ,-"""',,,·w===_ m···,·,·""wm.mmu~~ 8800'SS 113-318" CSG, 68#, K-55, ID = 12.415" H 2251' 118-5/8" CSG, 96.5#, K-55, ID = 17.655" H 2299' Minimum ID = 3.725" @ 10,690' 4-1/2" XN NIPPLE 14-1/2" TBG, 12.6#, 13Cr-80, ID = 3.813" I Estimate TOC 9 5/8" x T' Annulus 1-1 IT' 26# L-80 Scab Liner (6.276" ID) 1-1 17" 26# L-80 Drilling Liner (6.276" ID) H 6850' 7850' 7850' ÆRFORA TION SUMMARY REF LOG: SWS-BHCS ON 10/21/71 ANGLEATTOPÆRF: ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 7/8" 4 I Chemical Cut (Top of Fish) H 8150' TOP OF 7" LNR H 9476' 19-5/8" CSG, 47#, L-80, ID=8.681" H 10011' I PBTD H 11581' I T' LNR, 29#, N-80, .0371 bpf, ID = 6.184" H 11650' DATE 02/18/77 12/12/87 03/01/01 10/27/03 REV BY COMMENTS ORIGINAL COM PLETION RWO SIS-LG FINAL PG Smith Proposed Sidetrack Completion ~\ I ) -- ,~ 2200' -2130' ST MD 5 4 3 2 1 L ./ I: I ,I: ':j:: I ~ 1-141/2" X Landing nipple, ID = 3.813" H 3 joints 9518 casing + BOT PBR 1 GAS LIFT MANDRELS TVD DEV 1YÆ VLV LATCH PORT DATE 8000' H 9 518" Window I I 10645' H4 1/2" X Nipple (3.813" ID) 1 I 10,660' H T' x 4 1/2" Baker Premier Packer I I 10,680' H4 1/2" X Nipple (3.813" ID) 1 I 10,690' H4 1/2" XN Nipple (3.725" ID) 1 I 10,700' H 4 1/2" liner top I WLEG I I 10,710' 1-14 1/2" Hanger I liner top pac ker 1 I 10,864' HT' 26# L-80 (6.276" ID) 0.383 bpf I ~ 141/2" 12.6# 13Cr-80 Liner PBTD H 12,675' 141/2" 12.6# (3.958" ID) 0.0152 bpf H 12,760' 11314' HT' X 4-1/2" OTIS HC PKR, ID = 3.88" 11355' H4-1/2"OTISTBGTAIL,ID=3.958"1 DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: H-05A ÆRMIT No: 1710240 API No: 50-029-20106-01 SEC 21, T11 N, R13E, 773' FNL & 1265' FEL BP Exploration (Alaska) op COMPANY DETAILS REFERENCE INFORMA nON DP Amoco Co-ordinate (NÆ) Reference: Well Centre: H.05, Tme North Vertical (1VD) Reference: 73.18' 73.18 Section (VS) Reference: Slot - 05 (O.OON,O.OOE) MeasmedDepIhRefereoce: 73.18' 73.18 Calculation Method: Minimwn Culvatw'e Calculation Method: Minimum Curvature Enur System: ISCWSA Scan Method: Trav Cylinder North ElTOr Surface: Elliptkal + Ül5ing Wamit1:\ Method: Rules Based Start Dir 8'1100': 12129.1' MD, 9038. 18'TVD 4500 5000- 4000 :s ., 0 0 ~ +' :¡¡ 3500 1:: 0 ~ .c: :; 0 '" 3000 2500 SURVEY PROGRAM PI"" H-05A wpOJ (H-05/P1", H-05A) Depth Fm Depth To Survey/Plan Tool Date: 10/23/2003 Created By: Speny Wellplanner Checked: 8000.00 12760.12 Planned: H.oSA wp03 V8 MWD Date:_ Date Reviewed: WELL DETAILS N"", +NJ.s +EJ-W Northing Easling Latitude Longitude Slol H-05 2406.09 199233 5960015.19 643312.65 70017'S3.716N 148°50'21.725W 05 TARGET DETAILS N"", 1VD +NI-S +E/-W Northing Ea~1ing Shape H-05APoly 9033.18 4663.35 ·2744.43 5964625.00 640480.00 Polygon H-05A T2.1 9038.18 4842.14 -3360.18 5964792.00 639861.00 Point H-05A ILl 9043.18 4662.01 -3670.70 5964606.00 639554.00 Point H-05A n.l 9043.18 4734.34 -2743.08 5964696.00 640480.00 Point SECTION DETAILS See MD 1ne Azi TVD +N/-S +E/-W DLeg TFaee VSee Target 1 8000.00 47.16 318.00 6421.73 2284.05 -2840.01 0.00 0.00 3400.07 2 8020.00 47.42 321.25 6435.29 2295.24 -2849.53 12.00 85.00 3414.53 3 8298.89 41.74 334.97 6634.33 2459.95 -2953.41 4.00 125.30 3609.12 4 11207.99 41.74 334.97 8805.08 4214.71 -3772.85 0.00 0.00 5538.25 5 11760.35 90.00 37.00 9043.18 4662.01 -3670.70 13.00 68.39 5874.07 R-05A TI.I . 6 12129.10 91.47 82.77 9038.18 4842.14 -3360.18 12.42 87.95 5874.25 R-05A T2.1 7 12404.47 89.01 104.67 9037.02 4824.38 -3087.08 8.00 96.29 5721.97 8 12760.12 89.01 104.67 9043.18 4734.34 -2743.08 0.00 0.00 5471.61 R-05A n.1 CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Fonnation 8548.18 10863.70 7" 7.000 1 6935.18 8702.07 THRZ 9043.18 12760.12 41/2" 4.500 2 7141.18 8978.14 BHRZ 3 7207.18 9066.58 LCU 4 7615.18 9613.36 TJF 5 7990.18 10115.91 TJD 6 8252.18 10467.02 TJC 7 8456.18 10740.41 TJA 8 8548.18 10863.70 TSag 9 8582.18 10909.27 TShu 10 8662.18 11016.48 TSadfTZ4 B 11 8809.18 11213.49 TCGUfZ3 12 8879.18 11312.30 BCGLrrZ2C l I I I I I , I ; l l tit 4'/100': 8020' MD, 6435.29'TVD art Dir 12'/100': 8000' MD, 6421.73'TVD 2000 I I I I I -4000 -3500 -3000 West(-)Æast(+) [500ft/in] All TVD depths are ssTVD plus 73. 18'for RKBE. I I -2000 I I I I I I , I -1500 ~ ¢: o o ~ ..c 15. ~ "§ '€ ~ " " þ COMPANY DETAILS BP Amoco Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: T rav Cylinder North Error Surface: Eliptical+Casing Wamine; Method: Rules Based FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 6935.18 8702.07 THRZ 2 7141.18 8978.14 BHRZ 3 7207.18 9066.58 LCU 4 7615.18 9613.36 TJF 5 7990.18 10115.91 TJD 6 8252.18 10467.02 TJC 7 8456.18 10740.41 TJA 8 8548.18 10863.70 TSag 9 8582.18 10909.27 TShu 10 8662.18 11016.48 TSad/TZ4 B 11 8809.18 11213.49 TCGLffZ3 12 8879.18 11312.30 BCGLrrZ2C 6500 REFERENCE INFORMATION Co-ord.inale (NÆ) Refen.-'T1ce: Well Centre: H-05, True North Vertical (1VD) Reference: 73.18'73.18 Section (VS) Reference: 51ot- 05 (O.OON,O.(H}E) Measured Depth Reference: 73.18' 73.18 Calculation Method: MiDÍmtun Curvature SURVEY PROORAM Depth Fro Depth To SurveylP]an 8000.00 12760.12 Planned: H-05A wp03 V8 Plan: H·05A wp03 (H-05/Plan H-05A) Tool Date: 10/23/2003 Created By: Sperry Wellplanner Checked; Date MWD Reviewed: Date CASING DETAILS WELL DETAILS N"", +N/-S +E/-W Northing Easting Latitude Longitude Slot H·05 2406.09 1992.33 59600]5.19 643312.65 70~17'53.716N 148"50'21.725W 05 TARGET DETAILS N""" TVD +N/-S +E/-W Northing Easting Shape H-05APoly 9033.18 4663.35 -2744.43 5964625.00 640480.00 Polygon II-05A n.1 9038.18 4842.14 -3360.18 5964792.00 639861.00 Point H-05A ILl 9043.18 4662.01 -3670,70 5964606.00 639554.00 Point H·05AT3.1 9043.18 4734.34 -2743.08 5964696.00 640480.00 Point MD Name Size No. TVD 8548.18 10863.70 7" 9043.18 12760.12 41/2" 7.000 4.500 KOP Start Dir 12°/100': 8000' MD. 6421.73'TVD Start Dir 4°/100' : 8020' MD, 6435.29'TVD SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 8000.00 47.16 318.00 6421. 73 2284.05 -2840.01 0.00 0.00 3400.07 End Dir : 8298.89' MD. 6634.33' TVD 2 8020.00 47.42 321.25 6435.29 2295.24 -2849.53 12.00 85.00 3414.53 3 8298.89 41.74 334.97 6634.33 2459.95 -2953.41 4.00 125.30 3609.12 e 4 11207.99 41.74 334.97 8805.08 4214.71 -3772.85 0.00 0.00 5538.25 5 11760.35 90.00 37.00 9043.18 4662.0 I -3670.70 13.00 68.39 5874.07 H-05A TI.1 6 12129.10 91.47 82.77 9038.18 4842.14 -3360.18 12.42 87.95 5874.25 H-05A n.1 7 12404.47 89.01 104.67 9037.02 4824.38 -3087.08 8.00 96.29 5721.97 8 12760.12 89.01 104.67 9043.18 4734.34 -2743.08 0.00 0.00 5471.61 H-05A n.1 7000 -- 8000 l ;I I I ;I ;I " ;I ~ I l, , #' # ;< 8500 Start Dir 13°/100': 11207.99' MD, 8805.08'TVD All TVD depths are ssTVD plus 73.18'for RKBE. I I I 3500 ,.~. ...) ,¡ . " ;I~:; ;:,:<~:il-::- . ~ I I I I Iq \/¿I I I I \ 5500 Start Dir 12.42°/100': 11760.35' MD. 9043.18'TVD Jì'>.o / (l' I:,:~',,_ ,<. ";1:1111).. ..... ',10'; 12129.1'MD,9038.18'TVD .:....- j1~j."",.' \'''V'' I I I 6000 , I ' 6500 I I I I I I I I J I I I I I I I I I J J 4500 I I I 5000 Vertical Section at 329.910 [500ft/in] e BP KW A Planning Report Company: Field: Site:' Wen: WeIlpath: BP Amoco Prudhoe Bay PB H Pad H-05 Plan H-05A Date: 10/23/2003 Time: 10:27:45 Page: Co-ordinate(NE) Reference: Well: H-05, True North Vertical (TV D) Reference: 73.18' 7.3.2 Section (VS) Reference: Well (0.ÖON,O.00E,329.91Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB H Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957572.25 ft 641366.07 ft Latitude: 70 17 Longitude: 148 51 North Reference: Grid Convergence: e Alaska, Zone 4 Well Centre bggm2003 30.055 N 19.802 W True 1.08 deg Wen: H-05 Slot Name: 05 H-05 Wen Position: +N/-S 2406.09 ft Northing: 5960015.19 ft Latitude: 70 17 53.716 N +E/-W 1992.33 ft Easting: 643312.65 ft Longitude: 148 50 21.725 W Position Uncertainty: 0.00 ft Wenpath: Plan H-05A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 73.18' 8/14/2003 57561 nT Depth From (TVD) ft 28.50 Height 73.18 ft +N/-S ft 0.00 Plan: H-05A wp03 Date Composed: Version: Tied-to: Principal: Yes Casing Points H-05 8000.00 ft Mean Sea Level 25.50 deg 80.83 deg Direction deg 329.91 10/23/2003 8 From: Definitive Path :VID TVD [)jameter Hole Size Name ft ft in in 10863.70 8548.18 7.000 8.500 7" 12760.12 9043.18 4.500 6.125 41/2" Formations NtD TVD Formations Lithology Dip Angle I>ip Direction ft ft deg deg 8702.07 6935.18 THRZ 0.00 0.00 8978.14 7141.18 BHRZ 0.00 0.00 9066.58 7207.18 LCU 0.00 0.00 9613.36 7615.18 TJF 0.00 0.00 10115.91 7990.18 TJD 0.00 0.00 10467.02 8252.18 TJC 0.00 0.00 10740.41 8456.18 TJA 0.00 0.00 10863.70 8548.18 TSag 0.00 0.00 10909.27 8582.18 TShu 0.00 0.00 11016.48 8662.18 TSadfTZ4B 0.00 0.00 11213.49 8809.18 TCGUTZ3 0.00 0.00 11312.30 8879.18 BCGUTZ2C 0.00 0.00 Targets Map Map <-- Latitude ---> <--- Longitude --> Name Description TVI> +N/~S +E/-W Northing Easting .' Deg Min Sec Deg Min Sec Dip. Dir. e BP e KW A Planning Report Company: BP Amoco I>ah~:< ·1 0/23/2003 Time: 10:27:45 Page: 2 Field: Prudhoe Bay . Co-ordinate(NE) Reference: Well: Hc05, True North Site: PB H Pad Vertical (rVI» Reference: 73.18' 73.2 Well: H-05 . Section (VS) Reference: Well (O.00N,0.00E,329.91Azi) Wellpath: Plan H-05A Stir:veÿCalculation Method: MinimlJm Curvature I>b: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target .ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8000.00 47.16 318.00 6421.73 2284.05 -2840.01 0.00 0.00 0.00 0.00 8020.00 47.42 321.25 6435.29 2295.24 -2849.53 12.00 1.28 16.24 85.00 8298.89 41.74 334.97 6634.33 2459.95 -2953.41 4.00 -2.04 4.92 125.30 11207.99 41.74 334.97 8805.08 4214.71 -3772.85 0.00 0.00 0.00 0.00 11760.35 90.00 37.00 9043.18 4662.01 -3670.70 13.00 8.74 11.23 68.39 H-05A T1.1 12129.10 91.47 82.77 9038.18 4842.14 -3360.18 12.42 0.40 12.41 87.95 H-05A T2.1 12404.47 89.01 104.67 9037.02 4824.38 -3087.08 8.00 -0.89 7.95 96.29 12760.12 89.01 104.67 9043.18 4734.34 -2743.08 0.00 0.00 0.00 0.00 H-05A T3.1 Survey ·MI> Incl Azim TVD Sys TVI> MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/100ft deg 8000.00 47.16 318.00 6421.73 6348.55 5962244.49 640429.82 3400.07 0.00 0.00 MWD 8020.00 47.42 321.25 6435.29 6362.11 5962255.50 640420.09 3414.53 12.00 85.00 MWD 8100.00 45.62 324.90 6490.35 6417.17 5962301.20 640384.33 3472.14 4.00 125.30 MWD 8200.00 43.56 329.78 6561.58 6488.40 5962359.50 640345.31 3542.23 4.00 122.79 MWD 8298.89 41.74 334.97 6634.33 6561.15 5962418.18 640313.10 3609.12 4.00 119.31 MWD 8300.00 41.74 334.97 6635.16 6561.98 5962418.85 640312.77 3609.85 0.00 0.00 MWD 8400.00 41.74 334.97 6709.78 6636.60 5962478.61 640283.46 3676.16 0.00 0.00 MWD 8500.00 41.74 334.97 6784.40 6711.22 5962538.38 640254.15 3742.48 0.00 0.00 MWD 8600.00 41.74 334.97 6859.02 6785.84 5962598.15 640224.84 3808.79 0.00 0.00 MWD 8700.00 41.74 334.97 6933.64 6860.46 5962657.91 640195.53 3875.11 0.00 0.00 MWD 8800.00 41.74 334.97 7008.26 6935.08 5962717.68 640166.22 3941.42 0.00 0.00 MWD 8900.00 41.74 334.97 7082.88 7009.70 5962777.45 640136.91 4007.73 0.00 0.00 MWD 9000.00 41.74 334.97 7157.50 7084.32 5962837.22 640107.59 4074.05 0.00 0.00 MWD 9100.00 41.74 334.97 7232.11 7158.93 5962896.98 640078.28 4140.36 0.00 0.00 MWD 9200.00 41.74 334.97 7306.73 7233.55 5962956.75 640048.97 4206.67 0.00 0.00 MWD 9300.00 41.74 334.97 7381.35 7308.17 5963016.52 640019.66 4272.99 0.00 0.00 MWD 9400.00 41.74 334.97 7455.97 7382.79 5963076.29 639990.35 4339.30 0.00 0.00 MWD 9500.00 41.74 334.97 7530.59 7457.41 5963136.05 639961.04 4405.62 0.00 0.00 MWD 9600.00 41.74 334.97 7605.21 7532.03 5963195.82 639931.73 4471.93 0.00 0.00 MWD 9700.00 41.74 334.97 7679.83 7606.65 5963255.59 639902.42 4538.24 0.00 0.00 MWD 9800.00 41.74 334.97 7754.45 7681.27 5963315.35 639873.11 4604.56 0.00 0.00 MWD 9900.00 41.74 334.97 7829.07 7755.89 5963375.12 639843.79 4670.87 0.00 0.00 MWD 10000.00 41.74 334.97 7903.69 7830.51 5963434.89 639814.48 4737.19 0.00 0.00 MWD 10100.00 41.74 334.97 7978.31 7905.13 5963494.66 639785.17 4803.50 0.00 0.00 MWD 10200.00 41.74 334.97 8052.93 7979.75 5963554.42 639755.86 4869.81 0.00 0.00 MWD 10300.00 41.74 334.97 8127.55 8054.37 5963614.19 639726.55 4936.13 0.00 0.00 MWD 10400.00 41.74 334.97 8202.17 8128.99 5963673.96 639697.24 5002.44 0.00 0.00 MWD 10500.00 41.74 334.97 8276.79 8203.61 5963733.73 639667.93 5068.75 0.00 0.00 MWD 10600.00 41.74 334.97 8351.41 8278.23 5963793.49 639638.62 5135.07 0.00 0.00 MWD 10700.00 41.74 334.97 8426.02 8352.84 5963853.26 639609.30 5201.38 0.00 0.00 MWD 10800.00 41.74 334.97 8500.64 8427.46 5963913.03 639579.99 5267.70 0.00 0.00 MWD 10900.00 41.74 334.97 8575.26 8502.08 5963972. 79 639550.68 5334.01 0.00 0.00 MWD 11000.00 41.74 334.97 8649.88 8576.70 5964032.56 639521.37 5400.32 0.00 0.00 MWD 11100.00 41.74 334.97 8724.50 8651.32 5964092.33 639492.06 5466.64 0.00 0.00 MWD 11207.99 41.74 334.97 8805.08 8731.90 5964156.87 639460.41 5538.25 0.00 0.00 MWD 11225.00 42.59 338.01 8817.69 8744.51 5964167.25 639455.66 5549.59 13.00 68.39 MWD 11250.00 43.99 342.29 8835.89 8762.71 5964183.25 639449.54 5566.45 13.00 66.13 MWD 11275.00 45.54 346.35 8853.65 8780.47 5964200.10 639444.47 5583.49 13.00 63.02 MWD 11300.00 47.22 350.19 8870.90 8797.72 5964217.74 639440.46 5600.66 13.00 60.13 MWD 11325.00 49.03 353.82 8887.59 8814.41 5964236.12 639437.53 5617.90 13.00 57.48 MWD 11350.00 50.94 357.25 8903.66 8830.48 5964255.17 639435.68 5635.15 13.00 55.06 MWD 11375.00 52.95 0.49 8919.08 8845.90 5964274.83 639434.93 5652.37 13.00 52.85 MWD e BP e KW A Planning Report Company:' BPAmoco )ate: 10/23/2003 Time: 10:27:45 Page: 3 Field: Prudhœ Bay Co"ordinate(NE) Reference: Well: H-05, True North Site: PB H Pad Vertical (TV» Reference: 73.18' 73.2 Well: H-05 Section (VS) Reference: Well (0.00N,0.00E,329.91Azi) Wellpath: Plan H~05A Survey Calculation :\'Iethod: Minimum Curvature Db: .Oracle Survey MD. IneI Azim TVD Sys TVD MapN MapE vS DLS TFO.·· Too ft deg deg ft ft ft ft ft deg/100ft ',,:,deg' 11400.00 55.04 3.57 8933.77 8860.59 5964295.05 639435.27 5669.49 13.00 50.85 MWD 11425.00 57.21 6.49 8947.71 8874.53 5964315.75 639436.70 5686.46 13.00 49.04 MWD 11450.00 59.44 9.27 8960.84 8887.66 5964336.86 639439.22 5703.22 13.00 47.41 MWD 11475.00 61.72 11.92 8973.12 8899.94 5964358.33 639442.82 5719.73 13.00 45.95 MWD 11500.00 64.06 14.46 8984.52 8911.34 5964380.09 639447.48 5735.92 13.00 44.65 MWD 11525.00 66.44 16.90 8994.98 8921.80 5964402.05 639453.21 5751.76 13.00 43.49 MWD 11550.00 68.85 19.25 9004.49 8931.31 5964424.16 639459.96 5767.17 13.00 42.47 MWD 11575.00 71.30 21.53 9013.02 8939.84 5964446.33 639467.73 5782.12 13.00 41.58 MWD 11600.00 73.77 23.74 9020.52 8947.34 5964468.51 639476.49 5796.56 13.00 40.80 MWD 11625.00 76.26 25.90 9026.98 8953.80 5964490.61 639486.20 5810.44 13.00 40.14 MWD 11650.00 78.78 28.01 9032.39 8959.21 5964512.57 639496.85 5823.72 13.00 39.58 MWD 11675.00 81.31 30.08 9036.71 8963.53 5964534.32 639508.39 5836.35 13.00 39.12 MWD 11700.00 83.84 32.13 9039.94 8966.76 5964555.78 639520.79 5848.29 13.00 38.76 MWD 11725.00 86.39 34.15 9042.07 8968.89 5964576.89 639534.00 5859.51 13.00 38.50 MWD 11750.00 88.94 36.17 9043.08 8969.90 5964597.58 639547.99 5869.97 13.00 38.33 MWD 11760.35 90.00 37.00 9043.18 8970.00 5964606.00 639554.00 5874.07 13.00 38.24 MWD 11775.00 90.07 38.82 9043.17 8969.99 5964617.73 639562.78 5879.56 12.42 87.95 MWD 11800.00 90.18 41.92 9043.12 8969.94 5964637.08 639578.60 5887.92 12.42 87.95 MWD 11825.00 90.29 45.02 9043.02 8969.84 5964655.54 639595.45 5894.99 12.42 87.96 MWD 11850.00 90.40 48.13 9042.87 8969.69 5964673.07 639613.27 5900.76 12.42 87.97 MWD 11875.00 90.50 51.23 9042.67 8969.49 5964689.60 639632.01 5905.20 12.42 87.99 MWD 11900.00 90.61 54.33 9042.43 8969.25 5964705.10 639651.62 5908.30 12.42 88.01 MWD 11925.00 90.72 57.43 9042.14 8968.96 5964719.51 639672.04 5910.06 12.42 88.04 MWD 11950.00 90.82 60.54 9041.80 8968.62 5964732.79 639693.21 5910.46 12.42 88.08 MWD 11975.00 90.92 63.64 9041.42 8968.24 5964744.91 639715.07 5909.51 12.42 88.12 MWD 12000.00 91.02 66.74 9041.00 8967.82 5964755.82 639737.55 5907.21 12.42 88.17 MWD 12025.00 91.11 69.85 9040.54 8967.36 5964765.51 639760.59 5903.57 12.42 88.22 MWD 12050.00 91.20 72.95 9040.03 8966.85 5964773.93 639784.12 5898.59 12.42 88.28 MWD 12075.00 91.29 76.06 9039.49 8966.31 5964781.06 639808.07 5892.30 12.42 88.34 MWD 12100.00 91.38 79.16 9038.90 8965.72 5964786.89 639832.37 5884.70 12.42 88.41 MWD 12125.00 91.46 82.26 9038.28 8965.10 5964791.39 639856.95 5875.83 12.42 88.48 MWD 12129.10 91.47 82.77 9038.18 8965.00 5964792.00 639861.00 5874.25 12.42 88.56 MWD 12150.00 91.29 84.44 9037.68 8964.50 5964794.73 639881.71 5865.86 8.00 96.29 MWD 12200.00 90.84 88.41 9036.75 8963.57 5964798.80 639931.52 5843.55 8.00 96.33 MWD 12250.00 90.39 92.39 9036.21 8963.03 5964799.40 639981.50 5818.19 8.00 96.41 MWD 12300.00 89.94 96.36 9036.06 8962.88 5964796.54 640031.41 5789.90 8.00 96.45 MWD 12350.00 89.49 100.34 9036.31 8963.13 5964790.23 640080.99 5758.82 8.00 96.46 MWD 12404.47 89.01 104.67 9037.02 8963.84 5964779.46 640134.37 5721.97 8.00 96.44 MWD 12500.00 89.01 104.67 9038.67 8965.49 5964757.04 640227.21 5654.72 0.00 0.00 MWD 12600.00 89.01 104.67 9040.41 8967.23 5964733.58 640324.39 5584.33 0.00 0.00 MWD 12700.00 89.01 104.67 9042.14 8968.96 5964710.11 640421.57 5513.93 0.00 0.00 MWD 12760.12 89.01 104.67 9043.18 8970.00 5964696.00 640480.00 5471.61 0.00 0.00 MWD P055195 DATE INVOICE I CREDIT MEMO DESCRIPTION 11/25/2003 PR 111803E PERMIT TO DRILL FEES THE ATTACHED CHECK IS I~I PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AI< 99519-6612 PAY: .B.'P' t:..; "'''' ,'IH', ,'lIh! . .. .. .... !JutL '~UH IIIWI TO THE ORDER OF: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 I DATE I 11/25/2003 CHECK NO. 055195 GROSS VENDOR DISCOUNT NET \\ ~oSA NATIONAL CITY BANK Ashland, Ohio No. P 0 5 519 5 56·389 412 CONSOLIDATED COMMERCIAL ACCOUNT f'*"¡ rut' Ulfil DATE AMOUNT November 25, 2003 I I *******$100.00******1 NOT,Y~~?~·~~::!trS III 0 5 5 ~ 11 5 III ! ~ 0 l¡ è 2 0 ~ 8 11 5 I: 0 ~ 2 ? 8 11 b III H e e e e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRJA TE LETTERfP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) "CLUE" Tbe permit is for a new wel1bore segment of existing well Permit No, API No. Production. should continue to be reported as a function' of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(t), an records, data and logs acquired for tbe pilot hole must be dearly differentiated in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and Jogs acquired for wen (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates The permit is approved subject to fuD compliance witb 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (CompaU'y Name) assumes tbe liability of any protest to the spacing . e:ICeption tbat may occur. An dry ditch sample sets submitted to tbe Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals tbrough target zones. D D Well bore seg Annular Disposal On Program DEV On/Off Shore 11650 Unit _ Well Name: PRUDHOE BAY UNIT H-05A DEV I 1-01L GeoArea ..a90 e Yes Yes Yes YJ3S Yes Yes Yes Yes YJ3S YJ3$ Y_es Yes Yes NA _NA _NA NA nitial ClassfType 640150 I~C Pßrmit fee attaçhe~ _LeasJ3numberapRropJiate namJ3_anQ OUJl']b_er _U_nique welt We JQcatJ3d ina d_efine~pool Wel JQcatJ3d proper distance WellJQcatJ3d proper _distance bound_ary from QriJling unit from Qtber wßlJs _S.uffiçient _acrßage_ayailab1e in_dJilJiog unj JtdJ3viated, jsweJlbQre platinclu~ed _Qpßrator Only affeçtßd party _Opßrator has_appropriate_ b.ond in JorCe Pßrmit c_an be issued witbQut COMervation order PJ3rmit c_an be issued witbQut administrati\(e_apprpvaJ 5-day wait WellJQcated within arßa alldstrata _authorized by_lnjectioo Ordßr # (put 10# in_ CJ)mmßllts)_ (for AJI Wßl]s_ within J l4JlJite _area_of reyißW idJ3lltifieQ (Fpr seNjc_e -'Iv.ell Only) PJe-produced injßctor; ~uratiQn_of prß-pro~uctioo IJ3Ss_ than 3. mOl']tbs_ (forsßrvice well QnJy) _Af;MPFJndjngof Consistency_has bee_nissued_ forJhis pr_ojeçt Can permit be approved before 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Administration Date Appr RPC 12/19/2003 Nabors_2ES, . Max MW_11 Lioer ra_m requiremßotwaiveQ. Test MSF' 2300 psi. .2_ppg. e to 3500 Rsi _NA NA NA NA Yes Yßs Yßs Yes _Yßs NA Yßs Yßs Yes Yes Yes No_ NA _C_OnQuctor _S.urfaœ _casing PJQteGts al strlng_pJQvided & SUJt csg known_ USDWs ,~.~ _ on _cond_uctoc gstring to_surf çsg_ CMT v_or adßQu_ate_ to çircul""v _CMT vol adßQuate_ to tie-in _CMT will coyer_alll<oownpro_ductiye hQrizons CoT, B _& permafrpst Adequate tankage_ OJ reSeIYe pit abandonment beJ31l apPJQvßd Jtdivßde.r JequiJed, dQes )t meßt reguJatioos _DJiUiog fluid program schßmatic_& e~uip Jistadequatß _BOPEs,_dp · BOPE_pres: C_asing de_signs adeQua_te fpr Jtue-drilt has a_ to-4_03 fOJ _A~equate-,^,ellbore separatjo_n proposed 18 19 20 21 22 23 24 25 26 27 28 Engineering Date 12/22/2003 29 Appr WGA ,hey meßt reguJatioo Jest to (puJ PSig in wmmßnts) _Choke manifold çQmpJies w/APtRF'-53 (May 84) WQrk will occ_ur without ratillg appropriate; 30 31 32 33 34 _operatJonshutdQwn Wells within AOR yerified (For_s_ervice WßIJ Only) Js presence Qf H2S gas_ prob.ablß Meçba_nicatcOlldJlion pf No_ NA NA NA _NA PJ3rmit can be issued w!o hydrogen s_ulfide mßaS.ures D_ata_PJe.sßoted on_ Rote_ntial oveJj:!ressurßzOnes 35 36 Date 37 2/19/2003 38 39 Geology Appr RPC _SJ3ismicanalysjs_ Qf sbaJlow gaszolles_ Off-shore) (if _SJ3abed _conditipo survey for weßkly progress reRorts [explorç¡tory _onlYl Public ~ioi2/~ß~ Date Engineering Commissioner CQnta_ct Ilamelphone_ Date: 12/<<-/3 Geologic Commissioner: DTs e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr4lllng Services LIS Scan Utility . 190,3 -6>dÒ $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 25 10:38:41 2004 . ~ '/)3 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/02/25 Origin.................. .STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date.................... .04/02/25 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA H-05a 500292010601 BP Exploration Sperry-Sun Drilling Services 25-FEB-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002853212 J. SACK J. RALL / D. MWD RUN 3 MW0002853212 J. SACK J. RALL / D. MWD RUN 4 MW0002853212 J. BOBBITT R. BORDES / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002853212 J. SACK R. BORDES / MWD RUN 6 MW0002853212 J. SACK R. BORDES / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 21 11N 13E 773 1265 MSL 0) 72.83 44.68 # WELL CASING RECORD OPEN HOLE CASING DRILLERS R~~\'\\~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION # REMARKS: BIT S. 8.500 6.125 (IN) SIZE (IN) DEPTH (FT) 9.625 8014.0 7.000 10853.0 . STRING 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 2 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, THE TOP OF WHICH WAS AT 7982'MD AND THE BOTTOM WAS AT 7998'MD. TIE-IN SGRC DATA OVER THIS INTERVAL WERE ACQUIRED AFTER MWD RUN 3. THESE MAD PASS DATA WERE MERGED WITH MWD DATA FROM RUN 3. 4. MWD RUNS 3 - 6 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4 & 5 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD). RUN 3 INCLUDED PRESSURE WHILE DRILLING (PWD). RUNS 4 - 6 INCLUDED AT-BIT INCLINATION (ABI). NO PROGRESS WAS MADE ON MWD RUN 1. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 5' UPHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 24 FEBRUARY 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 2 - 6 REPRESENT WELL H-05A WITH API#: 50-029-20106-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12470'MD/9018'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. . . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.5 - 8.6 PPG MUD SALINITY: 25000 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM RPS RPX FET FCNT PEF NCNT NPHI DRHO RHOB $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7795.5 7976.5 7995.5 7995.5 7995.5 7995.5 8009.5 10758.0 10773.5 10835.0 10835.0 10849.0 10849.0 STOP DEPTH 12413.5 12465.0 12420.5 12420.5 12420.5 12420.5 12420.5 11626.5 11641.0 11626.5 11626.5 11641.0 11641.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH GR 7795.5 7800.5 12465.0 12470.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 7981.5 8014.0 MWD 3 7800.5 10855.0 MWD 4 10763.0 11318.5 MWD 5 11227.0 11719.0 MWD 6 11668.5 12470.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data.Spec~fica~ion Block4llbe.....0 Logglng Dlrectlon. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7795.5 12465 10130.3 9340 7795.5 12465 ROP MWD FT/H 0.19 259.84 86.4725 8978 7976.5 12465 GR MWD API 15.39 556.04 100.01 9237 7795.5 12413.5 RPX MWD OHMM 0.23 979.35 5.68164 8851 7995.5 12420.5 RPS MWD OHMM 0.27 1332.39 7.23977 8851 7995.5 12420.5 RPM MWD OHMM 0.44 1465.79 8.58447 8851 7995.5 12420.5 RPD MWD OHMM 0.6 1906.81 17.9251 8851 7995.5 12420.5 FET MWD HOUR 0.23 133.22 3.03655 8823 8009.5 12420.5 NPHI MWD PU-S 4.78 60.64 20.0205 1584 10835 11626.5 FCNT MWD CNTS 98.4 3602.8 833.054 1585 10758 11626.5 NCNT MWD CNTS 11494.3 51485.1 30133.8 1584 10835 11626.5 RHOB MWD G/CM 2.094 3.082 2.33943 1585 10849 11641 DRHO MWD G/CM -0.175 0.784 0.0807256 1585 10849 11641 PEF MWD BARN 1 17.96 3.30415 1736 10773.5 11641 First Reading For Entire File......... .7795.5 Last Reading For Entire File.......... .12465 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .04/02/25 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record..35 File Type................ 0 Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 7981.5 STOP DEPTH 8014.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet 25-JAN-04 Insite 66.37 Memory 8014.0 7982.0 8014.0 .0 .0 TOOL NUMBER 8.500 .0 LSND 11.20 .0 9.1 2200 4.0 .000 .000 .000 .000 .0 98.0 .0 .0 Data Reference Point... .4IÞ...... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 Name Service Unit DEPT FT ROP MWD020 FT/H Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Min 7981.5 0.57 Max 8014 7.86 Mean 7997.75 5.45015 Nsam 66 66 First Reading For Entire File......... .7981.5 Last Reading For Entire File.......... .8014 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX ROP FET $ 3 4IÞ First Reading 7981.5 7981.5 Last Reading 8014 8014 header data for each bit run in separate files. 3 .5000 START DEPTH 7800.5 8000.5 8000.5 8000.5 8000.5 8014.5 8014.5 STOP DEPTH 10818.5 10810.5 10810.5 10810.5 10810.5 10855.0 10810.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 28-JAN-04 Insite DOWNHOLE SOFTWARE VER~T: DATA TYPE (MEMORY OR REA~~ME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units....... ... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 66.37 Memory 10855.0 8014.0 10855.0 . 38.5 47.5 TOOL NUMBER 126027 127479 8.500 8014.0 LSND 11.20 53.0 9.4 1500 4.2 1.000 .450 .700 2.000 68.0 158.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 · .st Last Name Service Unit Min Max Mean Nsam ading Reading DEPT FT 7800.5 10855 9327.75 6110 7800.5 10855 ROP MWD030 FT/H 0.24 259.84 111.406 5682 8014.5 10855 GR MWD030 API 37.61 331.39 133.253 6037 7800.5 10818.5 RPX MWD030 OHMM 0.63 12.97 1.93503 5621 8000.5 10810.5 RPS MWD030 OHMM 0.62 11.6 1.93446 5621 8000.5 10810.5 RPM MWD030 OHMM 0.63 12.45 1.98441 5621 8000.5 10810.5 RPD MWD030 OHMM 0.6 10.58 2.03471 5621 8000.5 10810.5 FET MWD030 HOUR 0.23 6.84 0.816236 5593 8014.5 10810.5 First Reading For Entire File........ ..7800.5 Last Reading For Entire File.......... .10855 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type........ . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT PEF FET RPM RPS RPX RPD GR NCNT NPHI DRHO RHOB ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 10763.0 10778.5 10806.0 10811.0 10811.0 10811.0 10811.0 10819.0 10840.0 10840.0 10854.0 10854.0 10855.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 11226.5 11241.0 11269.5 11269.5 11269.5 11269.5 11269.5 11263.0 11226.5 11226.5 11241.0 11241.0 11318.5 04-FEB-04 Insite 66.37 DATA TYPE (MEMORY OR REA4IIkME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing............. ....... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Memory 11319.0 10855.0 11319.0 . 41.2 46.7 TOOL NUMBER 184054 154267 100983 159436 6.125 10853.0 FLO-PRO 8.70 60.0 9.5 25000 4.8 .240 .130 .300 .220 68.0 136.4 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT RHOB DRHO PEF MWD040 MWD040 MWD040 MWD040 CNTS G/CM G/CM BARN - 4 4 1 1 1 1 40 44 48 52 11. 12 13 14 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10763 11318.5 11040.8 1112 10763 11318.5 ROP MWD040 FT/H 0.19 191.94 45.2758 927 10855.5 11318.5 GR MWD040 API 17.19 556.04 67.3859 889 10819 11263 RPX MWD040 OHMM 0.23 979.35 24.3361 918 10811 11269.5 RPS MWD040 OHMM 0.27 1332.39 36.7669 918 10811 11269.5 RPM MWD040 OHMM 0.44 1465.79 46.4061 918 10811 11269.5 RPD MWD040 OHMM 1. 09 1906.81 133.587 918 10811 11269.5 FET MWD040 HOUR 0.67 133.22 16.9077 927 10806 11269.5 NPHI MWD040 PU-S 4.78 60.64 20.166 774 10840 11226.5 FCNT MWD040 CNTS 98.4 3602.8 870.471 775 10763 11226.5 NCNT MWD040 CNTS 11494.3 51485.1 30183 774 10840 11226.5 RHOB MWD040 G/CM 2.102 3.082 2.38064 775 10854 11241 DRHO MWD040 G/CM -0.175 0.784 0.0438142 775 10854 11241 PEF MWD040 BARN 1.15 17.96 4.69119 926 10778.5 11241 First Reading For Entire File......... .10763 Last Reading For Entire File.......... .11318.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type.............. . . LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT RHOB DRHO PEF GR 5 header data for each bit run in separate files. 5 .5000 START DEPTH 11227.0 11227.0 11227.0 11241.5 11241.5 11241.5 11263.5 STOP DEPTH 11631.5 11631. 5 11631. 5 11646.0 11646.0 11646.0 11668.0 RPX RPS RPM FET RPD ROP $ 11270.. 11270.0 11270.0 11270.0 11270.0 11319.0 11675.0 11675.0 11675.0 11675.0 11675.0 11719.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... . 05-FEB-04 Insite 66.37 Memory 11719.0 11319.0 11719.0 46.5 84.6 TOOL NUMBER 184054 154267 100983 159436 6.125 10853.0 FLO-PRO 8.70 47.0 9.1 18500 5.5 .250 .130 .260 .220 70.0 136.4 70.0 70.0 Datum Specification BlOC~b-type...o . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11227 11719 11473 985 11227 11719 ROP MWD050 FT/H 1 135.79 29.4058 801 11319 11719 GR MWD050 API 15.39 123.16 26.1609 810 11263.5 11668 RPX MWD050 OHMM 3.78 24.09 10.6966 811 11270 11675 RPS MWD050 OHMM 4.2 36.05 13.1941 811 11270 11675 RPM MWD050 OHMM 4.65 48.28 15.7423 811 11270 11675 RPD MWD050 OHMM 4.93 59.53 17.5682 811 11270 11675 FET MWD050 HOUR 1.16 23.96 4.54848 811 11270 11675 NPHI MWD050 PU-S 8.71 28.39 19.8815 810 11227 11631. 5 FCNT MWD050 CNTS 432.7 1965.1 797.254 810 11227 11631.5 NCNT MWD050 CNTS 24221.2 43346.3 30086.8 810 11227 11631.5 RHOB MWD050 G/CM 2.094 2.871 2.3 810 11241.5 11646 DRHO MWD050 G/CM -0.145 0.57 0.116042 810 11241.5 11646 PEF MWD050 BARN 1 8.65 1.71848 810 11241.5 11646 First Reading For Entire File......... .11227 Last Reading For Entire File.......... .11719 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD header da.or 6 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ START DEPTH 11668.5 11675.5 11675.5 11675.5 11675.5 11675.5 11719.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # each bit run in separate f~. STOP DEPTH 12418.5 12425.5 12425.5 12425.5 12425.5 12425.5 12470.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet 07-FEB-04 Insite 66.37 Memory 12470.0 11719.0 12470.0 84.8 92.6 TOOL NUMBER 184054 159436 6.125 10853.0 FLO-PRO 8.70 50.0 9.3 13800 5.6 .480 .230 .430 .520 69.0 154.0 69.0 69.0 Data Reference Point... .4IÞ...... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 4IÞ Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11668.5 12470 12069.3 1604 11668.5 12470 ROP MWD060 FT/H 1.2 202.21 51.5705 1502 11719.5 12470 GR MWD060 API 15.74 73.39 25.4816 1501 11668.5 12418.5 RPX MWD060 OHMM 2.67 23.47 5.5935 1501 11675.5 12425.5 RPS MWD060 OHMM 2.7 28.05 5.83154 1501 11675.5 12425.5 RPM MWD060 OHMM 2.9 28.46 6.30171 1501 11675.5 12425.5 RPD MWD060 OHMM 3.67 26.94 6.88703 1501 11675.5 12425.5 FET MWD060 HOUR 0.54 20.91 2.69108 1501 11675.5 12425.5 First Reading For Entire File......... .11668.5 Last Reading For Entire File.......... .12470 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/25 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name........ . . . . .LISTPE Date.................... .04/02/25 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.. ............. . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name... . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/02/25 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF . . Physical EOF End Of LIS File