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203-086
/Image ~ .~ject Well History File C,,)er 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. Q D"6 - DEb Well History File Identifier Organizing (done) o Two-sided 11I111111I111111111 ~can Needed 1 RE;9AN ~Color Items: o Greyscale Items: ~oor Quality Originals: o Other: DIGITAL DATA ~iskettes, No. ~ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: o Other:: Date: ~ ;)... Lf DS 151 fVV...J 1 nil I BY: Helen ~ Project Proofing BY: Helen ~ Date: ~ ~ Lf DS- 151 vvtj Scanning Preparation BY: Helen ~ :J- X 30 = (PO + I tJ = TOTAL PAGES Zo (Count does 'ot}~clvde cover 5 eet) II1AP Date: <X á Y f)-S/s/ Y Y ; · I r .. Production Scanning Stage 1 Page Count from Scanned File: 7 J (Count does ¡nclu7e cov r sheet) Page Count Matches Number in Scanning Preparation: YEp NO 1/\ A P Heien ~ Date: ~ aCf 'OS/s/ r V I I BY: Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Helen Maria Date: /5/ II! "111111111 /1111 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1 BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1I11I11111111111111 • • McMains, Stephen E (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Thursday, December 01, 2011 4:21 PM To: McMains, Stephen E (DOA) Subject: 10 -407 Correction for 18 -03B / PTD # 203 -086 Hi Steve, Got another correction that Andrea (from the PDC) caught. Please correct the BHL to Range 15. Thanks! Terrie v� ' 7'S L 1 ' •TEOFALASKA • • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other 0 Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 10/29/2011 203 - 086 311 - 167 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 6/14/2003 50 029 - 20776 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 6/19/2003 PBU 18-03B 1184' SNL, 161' FEL, SEC. 24, T11N, R14E, UM 8. KB (ft above MSL): 44.65' 15. Field / Pool(s): Top of Productive Horizon: 4042' FNL, 674' FEL, SEC. 24, T11N, R14E, UM GL (ft above MSL): 16.15' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 126' FNL, 1100' FWL, SEC. 30, T11N, R14E, UM 9284' 8572' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 691605 y - 5960680 Zone ASP4 11823' 8769' ADL 028307 & 028326 TPI: x- 691165 y- 5957810 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 692973 y 5956493 Zone- ASP4 N/A 18. Directional Survey: ❑ Yes 0 N 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIR, GR, RES, ABI, DEN, NEU 9214' 8513' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H -40 Surface 110' Surface 110' 30" 2940 # Poleset 13 -3/8" 72# L -80 Surface 2600' Surface 2600' 17 -1/2" 2400 sx Fondu. 400 sx PF 'C' 9 -5/8" 47# L -80 / S00 Surface 7740' Surface 7126' 12 -1/4" 500 sx Class 'G'. 300 sx PF 'C' 9 -5/8" x 7" 47# / 26# L -80 , 2690' 7585' 2690' 6992' N/A Scab Liner: 318 sx 'G'. 237 sx 'G' 7" 29# L -80 7577' 9214' 6985' 8513' 8-1/2" 525 sx Class 'G' 4 -1/2" 12.6# L -80 9061' 11823' 8372' 8769' 6" 200 sx Class 'G' 24. Open to production or injection? ❑ Yes 0 No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6 #, 13Cr80 9069' 9012' / 8326' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED s 9281' Set Whipstock ( Pa..G L 1.), S) 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes 0 No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and rzrcitltpu 20 AAC 250.071. �p I None Wnv ,, t ?I }1 RBDMS NOV 2 8 7.01; Alaska Chi! & G15 Cons. Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Ai1CfCThge Submit Orisinal Only -- /2-f Z `/f 1��L 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATIOMTESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 2B 9316' 8597' None Zone 2A 9420' 8668' Zone 1B 9488' 8707' Zone 1A 9624' 8767' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. ('/ 2N,Z� Signed: Terrie Hubble -� Title: Drilling Technologist Date: 1( PBU 18 - 03B 203 - 086 311 - 167 Prepared By Name/Number Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Matt Ross, 564 -5782 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • 18 -03B, Well History (Pre Rig Sidetrack) Date Summary 06/21/11 WELL S/I ON ARRIVAL. RAN 3.70" x 20' DRIFT TO 9400' SLM, NO RESTRICTIONS. CHANGED OUT TREE CAP FLANGE. WELL LEFT S /I, DSO NOTIFIED. 06/23/11 WELL SHUT IN ON ARRIVAL. STANDBY FOR LRS TO L &K & FREEZE PROTECT TBG, CURRENTLY RIGGING UP ELINE UNIT TO SET WHIPSTOCK. 06/24/11 WELL SHUT -IN UPON ARRIVAL. INITIAL T /I /O= 0/750/400 RIH WITH MH -22 (4 -3 WP, 1 -3/8" �" FISHING NECK) / ADAPTER /SWIVEL / 2 X CENTRALIZER / W PMOT / W PTET / W PGRT / %.3 ' WPST /FIRING HEAD / BAKER 10 / BAKER 4.5" 45 KB WHIPSTOCK PACKER. TOOL LENGTH = 44.1'. MAX OD = 3.7 ". TOOL WEIGHT = 620 LBS. TOP OF WHIPSTOCK SET DEPTH 9281 CCL TO TOP OF WHIPSTOCK= 14.1', CCL STOP DEPTH= 9266.9' 100 DEG ROHS. TOOL CENTRALIZERS STUCK IN TT AT 9069'. WORKED TOOL UP AND DOWN UNABLE TO PULL THROUGH OR DROP DOWN. MADE MULTIPLE ATTEMPTS TO FREE TOOLS W/ NO SUCCESS. LRS PRESSURE TESTED WHIPSTOCK TO 1000# (PASSED). WORK LINE & INCREASED WINCH SHUTDOWN 100# PER ATTEMPT TO BREAK TOOLS FREE W/ NO SUCCESS. PULLED OUT OF WEAKPOINT AT 4500 #, RECOVERED ALL THE WIRE. * TOP OF FISHING NECK ON TOOLSTRING AT 9064' (FISH = 1.375" FISHING NECK / OAL = 44.1') WILL RETURN AT LATER DATE AFTER SLICKLINE FISHES TOOLSTRING TO MILL XN NIPPLE WITH WELLTEC. FINAL T /I /O= 0/275/0 WELL LEFT SHUT IN - NOTIFIED DSO OF WELL STATUS. 06/25/11 WELL S/I ON ARRIVAL. FISHED E -LINE TOOL STRING & BAKER SETTING TOOL Q 9,043' SLM. SMALL STEEL PIECE ROUGHLY 1 -3/4" x 2" x 3/4" LEFT IN HOLE. DRIFT 3.79" CENT. TO XN NIPPLE CO 9,040' SLM ( +16' CORR TO 9,056 CMD). RAN 3.67" CENT., 10' STEM, 1.25" MAGNET TO TOP OF WHIPSTOCK CCP 9,267' SLM. NOTHING RECOVERED ON MAGNET, SMALL PIECE STILL IN HOLE. WELL S/I ON DEPARTURE, DSO NOTIFIED OF STATUS. * FISH IN HOLE: CENTRALIZER FROM BAKER SETTING TOOL, MEASURING APPROX. 1.75" x 2" x .75" 06/25/11 WELL SHUT -IN UPON ARRIVAL. INITIAL = 0/450/0 PSI. SPOT EQUIPMENT, RIG UP AND BEGIN PT. FINAL T /I /O = 0/450/0 PSI. 06/26/11 INITIAL T /I /O = 0/450/0 PSI. FINISH PT. OPEN SWAB AND SSV. RIH WITH HEAD /ADAPTER/2 X WEIGHT BAR /PBMS. STOP AT 9150' AND PULL CORRELATION PASS OVER JEWELRY. PERFORM TEMP /PRESS STOP COUNTS AT 9275' (ABOVE WHIPSTOCK) AND 9064' (XN NIP). RIG UP WELLTEC MILL TOOL. RIH. SET DOWN ON XN NIP. PERFORM CORRELATION PASS. SET BACK DOWN ON XN NIP. MILL OUT XN NIP TO 3.80 ". PULL UP 10' AND DROP BACK DOWN THRU XN W/ NO PROBLEMS. (WELLTEC MILL MEASURED OUT © 3.800" AFTER MILLING XN). FINAL T /I /O = 0/450/0 PSI. JOB COMPLETE. NOTIFY DSO OF WELL STATUS. 07/31/11 T /I /O= S /I/220/0 Pumped 5 bbls neat methanol and 61 bbls crude down flowline. Had IGV closed. Pressured up flowline to 1500 psi. FWHP= S/I/220/0 08/10/11 T /I /O= S1/200/0 Temp =Sl PPPOT-T (PASS) (Pre CTD) PPPOT -T : RU 1 HP BT onto THA 350 psi bled to 0 psi, opened SBS verified 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 min, 5000/30 min. Bled void to 0 psi, cycle and torqued LDS "Standard" all functioned with no problem. 09/02/11 T /I /O= 50/320/0 Temp= SI MIT -IA PASSED to 3000 psi. (Pre CTD) Pump 6 bbls crude to load IA and reach test pressure. IA lost 118 psi in 1st 15 min and 32 psi in 2nd 15 min for a total pressure loss of 150 psi over 30 min test. Bleed IA to 0 psi ( -4 bbls). Page 1 of 2 • • 18 -03B, Well History (Pre Rig Sidetrack) Date Summary 09/03/11 MIT -OA PASSED to 2000 psi. (Pre CTD) Pump 3 bbls of 70 °F crude into the OA to reach test pressure. OA lost 100 psi in 1st 15 min and 34 psi in 2nd 15 min for a total pressure loss of 134 psi over 30 min test. Bleed OA to 0 psi ( -2 bbls). FWHP = 50/100/0. 10/14/11 T /I /O =SSV /170/100. Bleed WHPs to 0 psi (Pre CTD). Initial IA FL =near surface, OA FL @ surface. Bled IAP from 170 psi to 40 psi in 2 hrs (gas /fluid returns to slop). Monitored for 30 minutes. During monitor no changes on WHPs. Job incomplete due to end of shift. FWHPs =SSV /40/100. 10/16/11 T /I /O= SSV /50/80. Temp= SI. Bleed IA and OA to 0 psi. (Pre CTD). No AL or S- riser. IA FL near surface, OA FL @ surface. Bled IAP from 50 psi to 0+ psi in 2 hrs and 15 mins. (21 gals of gas fluid mixture). Bled OAP to from 80 psi to 0+ psi in 1 min. (5 gallons of fluid). Monitored for 30 mins. IAP increased to 13 psi and OAP increased to 8 psi. Job complete. FWHP= SSV /13/8 10/23/11 T /I/O= 0/0/0; Conduct PJSM; Test barriers to 300 & 3500 psi for 5 min. (passed); R/U lubricator and test to 300 & 3500 psi for 5 min. (passed); Set 5 -1/8" FMC "ISA" BPV #539 thru tree for Nordic 2 pre -rig; 1 -2' ext. used, tagged @ 108 "; Install tree cap And test to 500 psi. for 5 min. (passed); RDMO No Problems Page 2 of 2 • • North America. ALASKA - BP Page 1 Ott Operation. Summa Report p � P Co Common Well Name: 18-03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/26/2011 End Date: X3- 0107Y -C (1,602,431.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 2 Spud Date/Time: 7/30/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292077600 Active Datum: 18 -03: @46.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/26/2011 18:00 - 19:00 1.00 MOB P PRE CREW CHANGE, DISCUSS ONGOING OPS FOR RIG MOVE. NORDIC FIELD SUPERINTENDANT PRESENT FOR MOVING OFF WELL. HAVE DETAILED PJSM FOR MOVING RIG OFF 14 -28A 19:00 - 21:00 2.00 MOB P PRE WARM UP MOVE SYSTEM. JACK RIG UP. MOVE OFF WELL. STAGE RIG ON PAD. 21:00 - 21:30 0.50 MOB P PRE P/U RIG MATS AROUND WELL. P/U LOCATION. WSL AND PAD OPERATOR CLOSE OUT WELL WORK TRANSFER PERMIT. 2200 HRS UPDATE AOGCC ON RIG ARRIVAL TIME. 21:30 - 22:00 0.50 MOB P PRE PJSM WITH ALL CREW MEMBERS, SECURITY , TOOLPUSHER, NORDIC FIELD SUPERINTENDANT, WSL, AND SLB. DISCUSS DRIVE ROUTE IN DETAIL. MATTING DETAIL AND OBSTICALES. 22:00 - 00:00 2.00 MOB P PRE MOVE TO DS 18 10/27/2011 00:00 - 04:00 4.00 MOB P PRE MOVE RIG TO DS 18 -03C 04:00 - 05:30 1.50 MOB P PRE R/U MATS, SET EQUIPMENT. PREP TO BACK RIG OVER 18 -03C 05:30 - 10:00 4.50 MOB P PRE RIG ACCEPT 1000 HRS. CONDUCT AAR ON RIG MOVE. 10:00 - 11:00 1.00 MOB P PRE CONTINUE WITH RIG PREP FOR OPERATIONS. PJSM ON NU BOP. 11:00 - 13:00 2.00 MOB P PRE NU BOP. AAR OF OPERATION. 13:00 - 20:00 7.00 MOB P PRE PJSM OF CHANGING OUT LINE IN REEL HOUSE GANTRY CRANE. RUN CABLE UP AND DOWN ON DRUM SEVERAL TIMES TO ALIGN ON SPOOL. 20:00 - 21:00 1.00 MOB P PRE INSPECT PITS. BEGIN CHANGING OUT LINERS AND SWAB ON PUMP #1. 21:00 - 22:30 1.50 MOB P PRE TAKE ON KCL INTO PITS. PJSM ON PU REEL WITH CH2MHILL, SLB, NORDIC CREW, WSL, TP. PU REEL. REEL PUW 74K. 22:30 - 00:00 1.50 MOB P PRE FILL STACK AND CHOKE MANIFOLD, MGS. INSPECT FOR ANY LEAKS, ALL GOOD. 10/28/2011 00:00 - 03:30 3.50 MOB P PRE BODY TEST OF BOP STACK. COMPLETE REPLACING LINER AND SWAB IN MUD PUMP #1. INSTALL HARDLINE IN REEL, CONNECT E -LINE INTO PRESSURE BULKHEAD. TIGER TANK HARDLINE INSTALLED AND PRESSURE TESTED TO 300/4000 PSI. LUBRICATE, FUNCTION BOP VALVES. FUNCTION BOP COMPONENTS FROM COIL OPS CAB CONSOLE. TEST CONDUCTIVITY IN E -LINE. 03:30 - 06:00 2.50 MOB P PRE PJSM ON PULLING REEL ACROSS. INSTALL GOOSENECK AND PACKOFFS, PULL REEL ACROSS. AAR ON OPERATION. 06:00 - 09:00 3.00 MOB P PRE CUT GRAPPLE OFF OF COIL. SET INJECTOR AND STAB COIL. PUMP 5 BBLS MEOH FOLLOWED BY WARM KCL TO FILL COIL. Printed 11/14/2011 1:25:18PM North /Sriea - ALASKA - BP Page 2 CEO Operation Summary Report Common Well Name: 18 -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/26/2011 End Date: X3- 0107Y -C (1,602,431.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 2 Spud Date/Time: 7/30/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292077600 Active Datum: 18 -03: @46.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 13:00 4.00 BOPSUR P PRE PJSM FOR TESTING BOPE. SHELL TEST TO 4500 #. TEST ALL RAMS, ANNULAR, AND P VALVES TO 250# LOW AND 3500# HIGH. NO n F AILURES. (JEFF JONES W / AOGCC WAIVED RIGHT TO WITNESS AT 0845) / 5 13:00 - 13:30 0.50 BOPSUR P PRE PJSM, BLOW DOWN KILL LINE. 13:30 - 15:30 2.00 MOB P PRE CONDUCT RIG EVACUATION DRILL W/ AAR. CONDUCT PRE -SPUD MEETING W/ RIG CREW AND SUPPORT PERSONNEL 15:30 - BOPSUR P PRE INSTALL COIL CONNECTOR AND RE -HEAD COIL. TEST ALL RIG GAS DETECTORS. 18:00 - 19:30 1.50 BOPSUR P PRE CREW CHANGE OUT, CLEAR AND CLEAN RIG FLOOR. LINE UP VAC TRUCKS THAT ARRIVE ON LOCATION DURING CHANGEOUT. CONDCUT RIG EVAC DRILL WITH CREW, THIRD PARTY PERSONNEL. AAR WITH ALL PERSONNEL. RECORD LESSONS LEARNED. 19:30 - 00:00 4.50 BOPSUR P PRE PJSM WITH LUBRICATOR CREW. MOBILIZE LUBRICATOR TO RIG FLOOR. MU, PT LUBRICATOR AND MASTER VALVE TO 250/3500 PSI. PULL BPV WITH NO ISSUES. NO PRESSURE INDICATED. CLOSE MASTER, SSV AND RD LUBRICATOR. PUMP SSV OPEN, INSTALL FUSIBLE LINK. VALVE CREW INSPECT TREE. RD VALVE CREW EQUIPMENT. 10/29/2011 00:00 - 02:00 2.00 MOB P PRE PJSM ON MU BHA AND RIH. PREPARE TO OPEN CHOKE FOR FLOW CHECK; LINE TO TIGER TANK NOT CLEAR. INSPECT LINE, FROZE AT CONNECTION TO RIG. CLEAR LINE. RE- PRESSURE TEST HARDLINE DUE TO BREAKING CONNECTION. FLOW CHECK, NO FLOW. 02:00 - 03:00 1.00 STWHIP P WEXIT MU MILLING BHA: 3.80" WINDOW MILL, STRING MILL, XTREME MOTOR WITH .6 AKO, XO, 2 JTS PH6, XO, HOT, DGS, DPS, EDC, POWERCOMMS, SUB WEAR PROTECTOR, LQC, UQC, XO, CTC. WINDOW MILL GAUGED AT 3.80" GO, 3.79" NO -GO, STRING MILL GAUGED AT 3.79 ". STAB ON WITH INJECTOR, PT QTS. 03:00 - 06:00 3.00 STWHIP P WEXIT PJSM WITH C2MHILL PERSONNEL WHILE RIH. DISPLACE DIESEL TO TIGER TANK. CONTINUE TO RIH TO 6000' (AS OF 0515). 06:00 - 07:30 1.50 STWHIP P WEXIT TIH TO 9126.9. RESET DEPTH TO 9121.7 ( -5.2' CORRECTION) MAINTAIN 105 ROHS& RIH W/ WT OF 26K PUMING 2.5 BPM @ 1900# W/ OPEN EDC 07:30 - 07:40 0.17 STWHIP P WEXIT RIH AND TAG TOW @ 9284'. PU 10' TO 9274 AND PAINT FLAG. UP WEIGHT 42K. 07:40 - 08:15 0.58 STWHIP P WEXIT INCREASE RATE TO 2.6 BPM @ 2240# AND RIH TO 9284 AND START MILLING WINDOW. 2270# FS / 2333# WP, 450# WOB. MW IN AND OUT 8.6 PPG. 08:15 - 08:40 0.42 STWHIP P WEXIT #2 PUMP HAS SLIGHT LEAK / SWAP TO #1 PUMP. IA 100 #, OA 491 #, WHP 84 #. SPR #1 PUMP = 1.5 BPM / 1811 #, .5 BPM / 648# 08:40 - 09:20 0.67 STWHIP P WEXIT TIME DRILL WINDOW @1 FPH, 2.6 BPM, 325# MW, 680# - 1390# WOB. Printed 11/14/2011 1:25:18PM North erica - ALASKA - BP Page 31:SAV Operation Summary Report Common Well Name: 18 -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/26/2011 End Date: X3- 0107Y -C (1,602,431.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 2 Spud Date/Time: 7/30/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292077600 Active Datum: 18 -03: @46.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:20 - 10:15 0.92 STWHIP P WEXIT TIME DRILL WINDOW @1FPH, 2.6 BPM, 505# MW, 1390# - 3010# WOB. BLEED DOWN IA FROM 938# - 238# 10:15 - 14:00 3.75 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH, 2.6 BPM, 295# MW, 3010# - 1670# WOB. BLEED DOWN IA FROM 734# TO 200 #, OA 934 TO 229, WHP 62, ECD 9.6 14:00 - 15:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. - 2.6 BPM, 2560 -2580 PSI ON, 1.6 -1.88K WOB - BLEED DOWN IA FROM 734# TO 200 #, OA 934 -229 PSI, WHP 62, ECD 9.6 15:00 - 16:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. - 2.6 BPM, 2565 -2590 PSI ON, 1.85 -2.35K WOB 16:00 - 17:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. - 2.6 BPM, 2565 -2635 PSI ON, 2.1 -3.3K WOB 17:00 - 18:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. - 2.6 BPM, 2630 -2635 PSI ON, 1.7 -2.25K WOB 18:00 - 19:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. - 2.6 BPM, 2615 -2645 PSI ON, 1.7 -2.2K WOB - MW IN AND OUT 8.6 PPG, ECD 9.60 PPG 19:00 - 20:00 1.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. - 2.6 BPM, 2615 -2670 PSI ON, 1.8 -2.5K WOB - EXITED WINDOW AT 9293' 20:00 - 00:00 4.00 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. - 2.6 BPM, 2620 -2670 PSI ON, 2.0 -4.5K WOB - MW IN AND OUT 8.6 PPG, ECD 9.60 PPG 10/30/2011 00:00 - 00:30 0.50 STWHIP P WEXIT TIME DRILL WINDOW @ 1 FPH. - 2.6 BPM, 2620 -2670 PSI ON, 2.0 -4.5K WOB - MW IN AND OUT 8.6 PPG, ECD 9.60 PPG - COMPLETE RAT HOLE TO 9303' 00:30 - 01:30 1.00 STWHIP P WEXIT REAM THROUGH WINDOW AT 1 FPM THREE TIMES. DRY DRIFT THROUGH WINDOW, NO PROBLEMS NOTED. PULL INTO WINDOW FOR FLOW CHECK. NO FLOW. 01:30 - 03:30 2.00 STWHIP P WEXIT POH WITH MILLING ASSEMBLY. CONDUCT PJSM ON LD MILLING BHA, PU AND MU OF BUILD BHA WHILE PULLING OUT OF HOLE. STOP AT 200' FOR FLOW CHECK. 03:30 - 04:00 0.50 STWHIP P WEXIT FLOW CHECK WELL, NO FLOW. 04:00 - 04:30 0.50 STWHIP P WEXIT PULL UP WITH BHA TO STACK. BREAK OFF INJECTOR. LD BHA. MILL GAUGED AT 3.80' GO, 3.79" NO -GO. STRING MILL GAUGED AT 3.79" GO, 3.78" NO -GO. - INSPECT TREE, FIND 2 BOLTS NOT TORQUED TO SPEC. CALLED VALVE SHOP; CREW ON WAY OUT TO CHECK AND RE- TORQUE IF NECESSARY. 04:30 - 05:30 1.00 DRILL P INT1 MU BUILD BHA: 3 "X4.125" BI-CTR BIT, 2 -7/8" HI FLOW LO SPEED MOTOR, HOT, DGS, DPS, EDC, POWERCOMMS, WEAR SUB, LQC, UQC, XO, CTC. MU INJECTOR, PT QTS. 05:30 - 07:10 1.67 DRILL P INT1 RIH WITH BUILD BHA TO 9000' © 95 -100 FPM. IA 137, OA 468, WHP 29, ECD 9.29, PITS 385 07:10 - 07:55 0.75 DRILL P INT1 START LOGGING DOWN AT 150 FPH. PARK COIL AT 9052.1 AND ADJUST DEPTH TO 9056. ( +3.9 FT CORRECTION) CHECK INJ COUNTER WHEEL AND FOUND SHIPPING PLASTIC - CLEANED IT Printed 11/14/2011 1:25:18PM North intrioa ALASKA - BP Page 4 of* Operation Summary Report Common Well Name: 18 -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/26/2011 End Date: X3- 0107Y -C (1,602,431.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 2 Spud Date/Time: 7/30/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292077600 Active Datum: 18 -03: @46.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:55 - 08:15 0.33 DRILL P INT1 RIH TO 9250. CLOSE EDC. WT CHK 42K. RETRIEVE SLOW PUMP RATES BEFORE ENTERING OPEN HOLE. #1 PMP= 1.34BPM/1487 #, .5BPM/1084 #. #2 PMP= 1.33BPM/1600 #, .5 BPM / 1333 08:15 - 08:30 0.25 DRILL P INT1 CONTINUE TO RIH @ 1.2 FPM TO BTM @9303' AND BREAK BIT IN PER HCC RP 08:30 - 10:15 1.75 DRILL P INT1 DRILL AHEAD AT 50 FPH, 2500# WOB. PU AND RETRIEVE SURVEYS FOR BHI@ 9345', 9375' 10:15 - 11:30 1.25 DRILL P INT1 STALL MTR @ 9432' - PU AND RESTART MTR. DRILL TO 9446 AND PU TO RETRIEVE SURVEY FOR BHI. 2.33 BPM, 2256# FS, PITS 384, IA 522, OA 693, ECD 9.62. TOP OF ZONE 1B = 9470' 11:30 - 14:45 3.25 DRILL P INT1 DRILL TO 9480'. WIPER TRIP UP HOLE TO 9020' TO TIE IN CORRECTED WINDOW DEPTHS. OPEN EDC © 9261 TO KEEP CUTTINGS GOING UP HOLE. TIE CORRECTION OF 0'. CORRECTED TOW= 9284', BOW = 9293', RA =9293' 14:45 - 17:30 2.75 DRILL P INT1 BOBD @ 9480'. WORK THROUGH SHALE AREA AT 9570'. DRILL TO 9630 WITH NO ISSUES. 17:30 - 20:00 2.50 DRILL P INT1 POH WITH BUILD BHA. PULL INTO WINDOW, FLOW CHECK. STATIC. OPEN EDC, POH WITH MAX RATE. PULL TO 100'. FLOW CHECK WHILE CONDUCTING PJSM ON BREAKING DOWN BHA AND MU LATERAL BHA. STATIC. JOG DOWN, PULL BACK UP INTO TREE. LD BHA. BIT GRADE 3- 3- CT- A- X -I -NO -BHA. 20:00 - 21:30 1.50 DRILL P INT1 MU LATERAL BHA: 3.75 "X4.125" BI- CENTER BIT, 3.125" ULTRA XL MOTOR WITH 1.2 AKO, HOT, USMPR, DGS, DPS, EDC, POWERCOMMS, FLOAT SUB, WEAR SUB, LQC, UQC, CTC. CONDUCT WALK THROUGH OF MU SAFETY JOINT AND STABBING SAFETY VALVE. MU INJECTOR, PT QTS. 21:30 - 23:45 2.25 DRILL P INT1 RIH WITH LATERAL ASSEMBLY TO 9030'. CONDCUT TIE -IN. -4' CORRECTION. CLOSE EDC. 23:45 - 00:00 0.25 DRILL P INT1 ORIENT MOTOR AND BIT, COME ON WITH PUMPS AT MIN RATE. RIH THROUGH WINDOW WITH NO ISSUES. BRING PUMPS UP AND CONTINE TO RIH. 10/31/2011 00:00 - 00:15 0.25 DRILL P INT1 OBTAIN AND RECORD SLOW PUMP RATES. PUMP 1 1470 PSI AT 41 SPM, PUMP 2 1465 PSI AT 41 SPM. RIH WITH LATERAL BHA TO 9630'. 00:15 - 03:00 2.75 DRILL P INT1 DRILL AHEAD IN LATERAL SECTION. FREE SPIN 2580 PSI AT 2.6 BPM. - 2.60 -2.66 BPM, 2685 -3100 PSI, ECD 9.66 -9.72 PPG, WOB 1.4 -3.83 K - MW IN 8.70 PPG, MW OUT 8.68 PPG - CUTTING ACROSS SHAKERS DO NOT SHOW SHALES, PRIMARILY SOME CHERT BUT MOSTLY SANDSTONE FROM 1A 03:00 - 04:15 1.25 DRILL P INT1 WIPER TRIP FROM 9750' TO WINDOW WITH MAD PASS INCORPORATED, 2.65 BPM, 2550 PSI. NO ISSUES NOTED ON WIPER TRIP. Printed 11/14/2011 1:25:18PM TREE= 5 -1/8" McI WELLHEAD F McEVOY SAFETY NOTES: WELIGLE> 70° @ 8563' I ACTUATOR = PJC DRAFT KB. ELEV = 46' i! -o 3 C BF. ELEV = KOP = 2700' Max Angle = 90 °@ 9771' I I 2182' H4 -1/2" CAMCO BAL -O SVLN, ID = 3.812" I Datum MD = 11196' Datum TVD = 8758' SS 20" CONDUCTOR, 91.5 #, 11 2690' h 9 -5/8" X 7" LNR TIEBACK, ID = 7.50" I H -40, ID = 19.124" 2697' H9-5/8" X 7" BKR LTP w / LNR HGR, ID 6.270" J 113 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" H 2600' GAS LIFT MANDRELS kj ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF 7" SCAB LNR H 2690' 4 3 3289 3279 17 KBG -2 DMY BK 0 07/25/10 Minimum ID = 3.725" @ 9056' t 2 ■ 2 5794 5480 32 KBG-2 DMY BK 0 07/25/10 4 -1/2" HES XN NIPPLE 1 N 1 w 7538 6947 31 KBG -2 DMY BK 0 06/23/03 ' '! I 7585' 1-1 9-5/8" X 7" BKR H LTP, ID = 6.188" I 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" H 7584' S 0 • "" 7590' H9-5/8" X 7" BKR HMC LNR HGR, ID = 6.184" I 9 -5/8" CSG, 47 #, L -80 BTC-M, ID = 8.681" I-J 7740' I-- 9 -5/8" MILLOUT WINDOW (18 -03A) 7740' - 7790' 1 8991' H4 -1/2" HES X NIP, ID = 3.813" Z 0 9012' H7" X 4-1/2" BKR S -3 PKR, ID= 3.875" I I 9036' H4 -1/2" HES X NIP, ID = 3.813" 1 I 9056' 1-14-1/2" HES XN NIP, MILLED TO 3.80" (6/26/11) I 9061' 117" X 5" BKR ZXP LTP, 14-1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 9068' w / 11.35" TIEBACK, ID = 4.39" q [ 9069' 1-14-1/2" WLEG, ID = 3.958" I 7" LNR, 29 #, L -80 NSCC, .0372 bpf, ID = 6.184" H -9214 + 9080' H 7" X 5" BKR FLEX -LOCK LNR HGR, ID = 4.39" I 9090' 1-15" X 4-1/2" XO, ID = 3.98" I 13-1/2" LNR, 9.20 #, L -80 STL, .0087 bpf, ID = 2.992" H 9267' 1 '' \�.„...---Th /- 7" MILLOUT WINDOW (18 -03B) 9214' - 9226' 4 -1/2 "WHIPSTOCK (06/24/11) H 9281' .I � � 9267' H3-1/2" X 3- 3/16" XO, ID = 2.786" I 4 -1/2" LNR, 12.6 #, L -80 IBT-M, 9284 I .0152 bpf, ID = 3.958' I 4 -1/2" MILLOUT WINDOW (18 -03C) 9284' - 9293.' 13-3/16" LNR, 6.6 #, L -80 TCII, . ? ? ?? bpf, ID = 2.80" H 9705' I PERFORATION SUMMARY REF LOG: ? ? ??? I 1 9705' 1-13-3/16" X 2 -7/8" XO, ID = 2.377" I I ANGLE AT TOP PERF: 90° @ 10200' • Note: Refer to Production DB for historical perf data 1 SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 10200 - 11120 0 11/04/11 11160' H PBTD I 12-7/8" LNR, 6.4 #, L -80 STL, .0058 bpf, ID = 2.441 I-) 11196' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 PKR 176 ORIGINAL COMPLETION WELL: 18 -03C 02/12/95 N2ES SIDETRACK (18 -03A) PERMIT No: 2110660 06/25/03 N2ES SIDETRACK (18 -03B) API No: 50- 029 - 20776 -03 11/06/11 NORDIC 2 CTD SIDETRACK (18 -03C) SEC 24, T11 N, R14E, 1184' SNL & 161' WEL 11/15/11 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) e _ • • Al-- S c"-' of E E l . :[ - F nsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader _ O BP Exploration (Alaska), Inc. p`�o - -- P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18 -03B Sundry Number: 311 -167 ij Dear Mr. McMullen: �N h Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .... Daniel T. Seamount, Jr. Chair DATED this day of May, 2011. Encl. STATE OF ALASKA 014S 0 ,1$•l RECEIVED ALASKA. AND GAS CONSERVATION COMMI 07 K . APPLICATION FOR SUNDRY APPROVAL ID kl iA‘f -`' ;? O1' - '' 20 AAC 25.280 p � + // 1. Type of Request: Al ka Oil & t Cims. fbf11lSSion ❑ Abandon ® Plug for Redrill - ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Progaiiitnarlig6 ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. Z Development ❑ Exploratory 203 -086 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 - 029 - 20776 - - - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18 -03B - Spacing Exception Required? ❑ Yes Z No 9. Property Designation: 10. Field / Pool(s): ADL 028307 & 028326 • Prudhoe Bay Field / Prudhoe Bay Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11823' - 8769' 11823' - 8769' 9594', 9655' & 10750' None Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2600' 13 - 3/8" 2600' 2600' 4930 2670 I ntermediate 7740' 9 -5/8" 7740' 7126' 6870 4760 Production Liner 1637' 7" 7577' - 9214' 6985' - 8513' 8160 7020 Liner 2762' 4 -1/2" 9061' - 11823' 8372' - 8769' 8430 7500 Scab Liner 4895' 7" 2690' - 7585' 2690' - 6992' 7240 5410 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9566' - 11791' 8744' - 8770' 4 -1/2 ", 12.6# 13Cr80 9069' Packers and SSSV Type: 7" x 4-1/2" Baker 'S -3' packer Packers and SSSV 9012' / 8326' MD (ft) and TVD (ft): 12. Attachments: — 13. 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - 0 Development ❑ Service i 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 1, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR /Abandoned ,� Commission Representative: ❑ WAG ❑ SPLUG - 1r Suspended A/ 17. I hereby certify that the for • • ing is true and correct to the best of my knowledge. Contact Matt Ross, 564 -5782 Printed Name J. S�►r'�„LWn, Title Engineering Team Leader 1 ' Prepared By Name/Number: Signatur: � Phone 564 -4711 Date��p /( Prepared Hubble, 564 -4628 Commission Use Only Conditio s of approval: Notify Commission so that a representative may witness ��' f ( Sundry Number: 6 ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ft 3Sa0 /S“ i..50 /9 test- Other: 2s0 1,9,.:. s i 4 " I I- C 5 . 112. ( `I I- N. 4....64. ela f ct c b pra C /CAL AAC Z C , Subsequent Form Required: /v.. y y / APPROVED BY Approved By: I COMMISSIONER THE COMMISSION Date fi Form 10-403 Revis 01 010 ,� ,� ' S , l7 , ubmit In Duplicate RB&MS MAY 18 2O1 7 " - O R I G I N A A474 ....... • • To: Alaska Oil & Gas Conservation Commission From: Matthew Ross b p CTD Engineer Date: May 5, 2011 Re: 18 -03B Sundry Approval Sundry approval is requested to plug the 18 -03B perforations as part of drilling the 18 -03C coiled tubing sidetrack. History of 18 -03B. 18 -03B is a 2003 horizontal rotary in Zone 1A. The well was brought online with competitive rates until 2009 with the well making high GOR. Reason for sidetrack. 18 -03B is currently SI for high GOR with no remaining wellwork options. The proposed sidetrack will access reserves in the western portion of the Ivishak. Proposed plan for 18 -03C is to drill a thru- tubing sidetrack with a Coiled Tubing Drilling rig on or around June 20, 2011. The existing perforations will be isolated by the primary CST liner cement job. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. L„G��, IaJ,,I! rock r ..' 60 �v1r �sr CTD Sidetrack Summary �i - y' Pre -Rig Work: (scheduled to begin June 1, 2011). C ! , befra rbYrr was 1. S Dummy WS drift to 9,400' MD. , y re cL ' he 2. F Load & kill well prior to setting WS. Freeze protect well to 2000'MD. (w {sr �Gl g nor 3. E Set 4 -1/2" KB packer WS at 9,274' MD. Ow- -ir 4. C Mill XN profile at 9,056' MD. las r fx " )rt e q A0') � 5. V PT MV, SV, WV. � 60R (c�TUfne�A /. r ` 6. D Bleed gas lift and production flowlines down to zero and blind flange. 7. 0 Remove wellhouse, level pad. New l , (C40r j f ! 0a4 /4 /, 8. V Set 4" `H" TWC '-24hr prior to rig arrival. / /de �,4/ Rig Work: (scheduled to begin on June 20, 2011) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull TWC. Pe 2. Mill 3.8" window at 9,274' MD and 10' of rathole. 3. Drill Build: 4.125" OH, 331' (34° /100). 4. Drill Lateral: 4.125" OH, 1681' (12° /100). 5. Run 3- 1/2 "x3- 3/16 "x2 -7/8" solid cemented completion leaving TOL at 9,200' MD. a 6. Pump primary cement leaving TOC at 9,200' MD, 21 bbls of 15.8 ppg liner cmt planned. p) 7. Cleanout run. 8. Run MCNL /GR/CCL log. 9. Perforate 1300ft. 10. Freeze protect well, set BPV and RDMO. Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Run generic GLV's. 3. ASRC flowback. Matthew Ross CTD Engineer 564 -4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = 5-1/8" McEV OY • WELLHEAD = McEVOY 1 8-03 B SAFETY NOT ACTUATOR = AXELSON KB. ELEV = 44.7' BF. ELEV = I j I KOP= 9214' Max Angle = 96 @ 10774' Datum MD = N/A W 2182' H4-1/2" CAMCO BAL -O SV LN, ID = 3.812" I Datum TVD = 8800' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2600' TOP OF 7" SCAB LNR H 2689' k: 2690' H 9 -5/8" X 7" BKR ZXP LTP, ID = ? I 1• Minimum ID = 3.725" @ 9056' i! GAS LIFT MANDRELS 1 ST MD TVD DEV TYPE VLV LATCH PORT DATE 4-1/2" HES XN NIPPLE ; 1 ► ) 1 3 3289 3279 17 KBG -2 DMY BK 0 07/25/10 1 2 5794 5480 32 KBG -2 DMY BK 0 07/25/10 0 i . 1 7538 6947 31 KBG -2 DMY BK 0 06/23/03 1 � i I7" LNR, 26#, L -80, .0383 bpf, ID = 6.276" I 7585' !a ► � � ► � � 7585' H 9 -5/8" X 7" BKR H PKR, ID = 6.188" I g St III I 7590' I— I9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.184" I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 7740' I— I 8991' 1-14-1/2" HES X NIP, ID = 3.813" I =' 9012' - 7" X 4-1/2" BKR S -3 PKR, ID= 3.875" I 9 —{ 4 -1 /2" HES X NIP, ID = 3.813" I 9056' H4-1/2" HES XN NIP, ID = 3.725" I 9061' H 7" X 4-1/2" BKR ZXP LRP, ID = ? I I4 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9068' 6 . , 9069' I-14-1/2" WLEG, ID = 3.958" 9594' H4 -112" HES CIBP (11/20/10) I P l ✓5 MILLOUT WINDOW (18 -03B) 9214' - 9226' cj 2il I 4 9655' 1- I4 -1/2" WFD CIBP (08/02/09) I 40 • I 7" EZSV 9237' ��� 10729' H BKR ECP FKR I 1 7" LNR, 29 #, L -80, .0372 bpf, ID = 6.184" I 9735' t 11821' - I PBTD PERFORATION SUMMARY REF LOG: xxxxxx ON MM/DD /YY 1..•• �� ANGLE AT TOP PERF: 65° @ 9566' Note: Refer to Production DB for historical perf data I4 -1/2" BKR CIBP (08/17/08) H 10750' 1 SIZE SPF INTERVAL Opn /Sqz DATE • 2 -7/8" 6 9566 - 9586 0 11/20/81C • 2 -7/8" 6 9600 - 9625 C 08/02/09 I4 -1 /2" SOLID LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 10843' I .. '' 2-7/8" 6 9850 - 10200 C 04/21/05 2 -7/8" 6 10260 - 10430 C 08/18/08 1 2 -7/8" 6 10470 - 10590 C 04/21/05 14-1/2" SLTD LNR, 12.6 #, L -80, .0158 bpf, ID = 3.958" I 11791' 2 -7/8" SLOT 10843 - 11791 SLOTTED 06/07/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 ORIGINAL COMPLETION 08/22/09 RRD/PJC CIBP / PERFS (08/02/09) WELL: 18 -03B 02/12/95 RIG SIDETRACK (18 - 03A) 06/25/10 RCT /PJC SET PXN (05/15/10) PERMIT No: r 2030860 06/25/03 DAC /KK RIG SIDETRACK (18 - 03B) 07/28/10 JLJ /PJC PULL PXN / GLV C/O (07/25 -26/10 API No: 50- 029 - 20776 -02 07/29/07 CJN/SV SET PXN PLUG (07/28/07) 11/24/10 RRD/PJC CIBP/ PERFS (11/20/10) SEC 24, T11 N, R14E, 1184' SNL & 161' WEL 08/26/07 JRP /SV PULLED PXN PLUG (08/24/07) 09/05/08 JKC/PJKC PERF/ CIBP (08/17/08) BP Exploration (Alaska) • ' TREE= 5 -1/8" McEVOY WELLHEAD = McEVOY • 1 8-03C SAFETY NO ACTUATOR= AXELSON KB. ELEV = 44.7' Proposed CTD Sidetrack BF. ELEV = I KOP = 9214' Max Angle = 96 @ 10774' Datum MD = N/A ® I 2182' I -14 -1/2" CAMCO BA L-0 SVLN, ID = 3.812" I Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I—I 2600' TOP OF 7" SCAB LNR I—I 2689' I 0 2690' I- 19 -5/8" X 7" BKR ZXP LTP, ID = ? I r � GAS LIFT MANDRELS ∎I ST MD TVD DEV TYPE VLV LATCH PORT DATE , 3 3289 3279 17 KBG -2 DMY BK 0 07/25/10 • Minimum ID = 3.725" @ 9056' r , 2 5794 5480 32 KBG -2 DMY BK 0 07/25/10 „ � 0 1 7538 6947 31 KBG -2 DMY BK 0 06/23/03 4 -1/2 HES XN NIPPLE •� 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I 7585' I .4 0 7585' I-19 -5/8" X 7" BKR H PKR, ID = 6.188" I I. 7590' 1-19-5/8" X 7" BKR HMC LNR HGR, ID = 6.184" I I I 8991' 1-14-1/2" HES X NIP, ID= 3.813" I 9-5/8" CSG, 47 #, L -80, ID = 8.681" H 7740' I- ® 3 9012' I-17" X 4 -1/2" BKR S -3 PKR, ID 3.875" I TSGR 8949' I I 9036' H4 -1/2" HES X NIP, ID = 3.813" I ' I ' 9056' H4-1/2" HES XN NIP, ID = 3.725" ►: 14-1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9068' I . 3.7" deployment sleeve / 4.5" KB LTP I� -9200' - TOL/TOC 3- 3/16" x 2 -7/8" XO -9600' C- 37 0 9274' - 4 -1/2" x 7" TT whipstock — 11,285' - TD 7" EZSV I—I 9237' 7" LNR, 29 #, L -80, .0372 bpf, ID = 6.184" I 9735' 6 PERFORATION SUMMARY a I I I I I °Pr' REF LOG: xxxxxx ON MM/DD /Y ‘ � ��� � � � � � � � 0/ ANGLE AT TOP PERF: 65 @ 9566' WAWA Note: Refer to Production DB for historical perf data A SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 9566 - 9586 0 11/20/810 2 -7/8" 6 9600 - 9625 C 08/02/09 2 -7/8" 6 9850 - 10200 C 04/21/05 2 -7/8" 6 10260 - 10430 C 08/18/08 2 -7/8" 6 10470 - 10590 C 04/21/05 2 -7/8" SLOT 10843 - 11791 SLOTTED 06/07/03 MILLOUT WINDOW (18 -03B) 9214' - 9226' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 ORIGINAL COMPLETION 08/22/09 RRD /PJC CIBP/ PERFS (08/02/09) WELL: 18 -03B 02/12/95 RIG SIDETRACK (18 -03A) 06/25/10 RCT /PJC SET PXN (05/15/10) PERMIT No: '2030860 06/25/03 DAC /KK RIG SIDETRACK (18 -03B) 07/28/10 JLJ /PJC PULL PXN / GLV C/O (07/25- 26/10; API No: 50- 029 - 20776 -02 07/29/07 CJN/SV SET PXN PLUG (07/28/07) 11/24/10 RRD /PJC CIBP/ PERFS (11/20/10) SEC 24, T11 N, R14E, 1184' SNL & 161' WEL 08/26/07 JRP /SV PULLED PXN PLUG (08/24/07) 09/05/08 JKC /PJKC PERF/ CIBP (08/17/08) BP Exploration (Alas ka) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM Cho e Pine! Standpipe 2" Circulation Line - Driller Gauge e "PM 10 1* MM MM 8 1 Manual Choke • CIRCULATING MANIFOLD = MM s y • • • ♦ MM 20 � I ® MM 22 *if ee SLB Transducer 4 1 MM 6 PVT Sensor __ 7 -1116" 5kpsi BOPE Air Blow down - • IN MM 7 . • Blind Shears Line :ow, - = Baker Choke :. MN MM 21 MM GAS BUSTER _ -�. 2 -3/8 " Combi TOT PIS • Rev CIr Line l — a- • • Ill MM14 _ _ - Aw a kr - vts ^s ■e ee ek u° �w1 .:H - ►TI - •. +Iwo, " , t • • i x.41 is • sci.+ art a 1 :! B OP 24 IS. �I 1I Coiled Tubing -_- ♦ i i" T 2 -3/8" - 3 -1/2" VBR ram Ba er Choke 2 -318" Combi 0 • • — TOT PIS MM 1 • •�• MPt in � • MM 13 • - ...• 0:4 I Y - Kill Line °- Outlet t- Cement Line to Ground / Mud °2 in � - - '.... Pu; •s In ,,,, Tranducers COILED TUBING f - - -m Choke Line CIRCULATING SYSTEM Cellar ;� 0 / Area — i r I— ® ♦ - „—• .' F low Cross I To Inner Reel Outlets - • Valve . HP 0 I 4488r HP3 . . .. .. — p HP HP 1 HP 12 . • cement line N2 ( SLB i NORDIC'S 2 Circulate Manifold CHOKE MANIFOLD in Cellar , e HP 11 N2 TriFlow ' � ' •/ CM 85 Gauge • ' ' 1•111 CHOKF I INF i Test Pump Inlet = ,p aI„i rr C CM3 °,' _ HDI Gauge _ _ CM78 1 Flow fl HCR SS c = = • 4Way Block CM14 * -:- CMI CM8 : — To PITS C. 2 + C C C,. 1 Inlet - Baker Choke Line from n Baker Choke Line from wal " j CM13 BAKFRCHOKEIINF MI— ....�..,,��r�..,.,.,.r�. — ,. _ raker Choke Line ::: ::: CM 26 M20 M j - -- AHAPV Al !UN PATH CM 30 CHOKF I wF e CM 75 CM10 MAIM Tiger Tank CM 25 Outside E 0 STATE OF ALASKA ALASK& AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS N' 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate E] Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate Q Re -enter Suspended Well ❑ - t C 1 B P 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑� Exploratory ❑ - 203 -0860 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 20776 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028326 f _ PRU 18 -03B 10. Field /Pool(s): _ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11823 feet Plugs (measured) 10750, 9655 feet true vertical 8760.46 feet Junk (measured) None feet Effective Depth measured 11823 feet Packer (measured) 2689 7585 9012 feet true vertical 8760.46 feet (true vertical) 2689 6987 8318 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 91.5# H -40 28 - 108 28 - 108 1490 470 Surface 2572' 13 -3/8" 72# L -80 27 - 2599 27 - 2599 4930 2670 Production 7714' 9 -5/8" 47# L -80 26 - 7740 26 7121 6870 4760 Liner 2158' 7" 29# L -80 2689 - 7585 2689 - 6987 8160 7020 Liner 4869' 7" 29# L -80 7577 - 9735 6980 - 8786 8160 7020 Liner 2762' 4 -1/2" 12.6# L -80 9061 - 11823 8364 - 8761 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 23-8992 23-8299 4 -1/2" 12.6# L -80 8992 -9069 8299 -8371 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 2689 2689 7" Baker H Packer 7585 6987 4 -1/2" Baker S -3 Perm Packer 9012 8318 4 -1/2" Baker ZXP Packer 9061 12. Stimulation or cement squeeze summary: Intervals treated (measured): N OV NO 2 4 2010 SQL) O � � 0 2010 Treatment descriptions including volumes used and final pressure: L4 '33s COAST. G �!'} A "�iQft 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory[] Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas LJ WDSPL GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na oe Lastufl Title Data Manager i Signatu �` Phone 564 -4091 Date 11/22/2010 � O Form 10-404 Revised 10/2010 RBDMs' NQt 2 6 201 E Submit Original Only 18 -03B 203 -086 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Tof Tvd Depth Bas 18 -03B 6/22/03 SL 10,843. 11,791. 8,771.88 8,761.66 18-03B 4/21/05 PER 9,850. 10,200. 8,789.89 8,777.54 18-038 4/21/05 PER 10,470. 10,590. 8,775.23 8,783.35 18-03B 8/16/08 BPS 10,750. 11,791. 8,780.36 8,761.66 18 -03B 8/17/08 APF 10,260. 10,430. 8,774.38 8,772.53 18 -03B 8/2/09 APF 9,600. 9,625. 8,749.53 8,758.7 18-038 8/2/09 BPS 9,655. 10,843. 8,768.42 8,771.88 18 -03B 11/21/10 APF r 1 P 9,566. 9,586. 8,735.91 8,744.1 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 18 -03B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ' 11/20/20101 ** *WELL SHUT -IN ON ARRIVAL * ** INITIAL T /I /O = 2400/1000/0. SSV CLOSED, WING CLOSED. SET HALLIBURTON EZ -DRILL CIBP AT 9 594' MID_E DEPT I REFERENCED TO SLB PLUG / PERF RECORD DATED 2- AUG -09. LRS MIT PLUG TO 3000 PSI AFTER SETTING, (PASSED). LRS BLEED OFF PRESSURE AFTER E IMIT TO 100 PSI. NOT ENOUGH HOURS LEFT TO RUN PERF GUN, LAY DOWN FOR NIGHT. WELL SHUT -IN AND SECURE, HAND -OVER WITH DSO PRIOR TO DEPARTURE. ;SWAB, WING, SSV CLOSED, MASTER AND CV'S OPEN. f FINAL T /I /O = 100/1250/0. !***IN PROGRESS A C ONTINUED ON 11/21 WSR * ** 11/20/2010 =T /1 /O 2400/960/0 Assist Eline with Load an Test -------- MIT -T Passed to 3000 psi {P rofile; !Modification) Pumped 5 bbls of 60/40 followed by 230 bbls of Crude at 5 bpm. i Pumped 5 bbls of Crude to reach test pressure Tbg lost 150 psi in first 15 min. and 60 psi in second 15 min. for a total loss of 210 psi in 30 mins FWH's= 0/1500/0 Eline in control of well. IO /OA =OTG I � � I I j � 11/21/2010 ** *CONTINUED FROM PREVIOUS DAY * ** (E -LINE PERF) i WELL SHUT -IN ON ARRIVAL, SSV CLOSED j INITIAL T /I /O = 100/950/0 3 = P ERFORATED 9 56Ci $f __W 2.8$'L1S 6SPF 60 DEG PHASED PJ OMEGA !2906 GUN. DEPTH CORRECTED TO SLB PERF / PLUG LOG DATED 2- AUG -09. iTAGGED PLUG SET AT 9594' WITH GUN PRIOR TO PERFORATING. UNABLE TO RE -TAG PLUG AFTER SHOOTING DUE TO PERF DEBRIS. !FINAL T /I /O = 100/950/0 = LEFT WELL SHUT -IN, SWAB, SSV, WING CLOSED, MASTER, CV'S OPEN. HAND !OVER WITH DSO PRIOR TO DEPARTURE. I ** *JOB COMPL * * ? FLUIDS PUMPED BBLS 2 DIESEL 1 METH 3 TOTAL TREE = 5-1/8" MC EV OY ACTUATOR = A,X SON 18 SAFETY N KB. ELEV =a 44.7' BF. ELEV = KOP = 9214' Max Angle = 96 @ 10774' Datum Angle = W4 2182' 4 -1/2" CAMCO BAL -O SVLN, ID Datum TV D = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12347" 2600' TOP OF 7" SCAB LNR 2689 2690' 9 -5/8" X 7" BKR ZXP LTP, ID = ? Minimum ID = 3.725" @ 9056' GAS LIFT MANDRELS 4 -1/2" HES XN NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3289 3279 17 KBG -2 DMY BK 0 07/25/10 2 5794 5480 32 KBG -2 DMY BK 0 07125/10 1 7538 6947 31 KBG -2 DMY BK 0 06/23/03 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" 7585' 7585 9 -5/8" X 7" BKR H PKR, ID = 6.188" 7590' 9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.184" 9 -5/8" — C-SG, 47 #, L -80, ID = 8,681" 7740' 8991' — {4 -1/2" HES X NIP, ID 7 3.8 1 - 3 - 1 9012 7" X 4 -1/2" BKR S -3 PKR, ID= 3.875" 9036 4 -1/2" HES X NIP, ID = 3.813" 9056' -- �4 -1/2" HES XN 4 -1/2" LNR, 12.6 #, L-80_0152 bpf, ID = 3.958" 9068' 9061' 7" X 4 -1/2" BKR ZXP LRP, ID = ? 9069' 4 -1 WLEG, ID = 3.958 Grp 5�� MILLOUT WINDOW (18 -03B) 9214'- 9226' N 9655' 4 -1/2" WFD C IBP ( 10729' BKR ECP P KR r'EZSV 923T 7" LNR, 29 #, L-80_0372 bpf, ID = 6.184" 9735' 11821' PBTD PERFORATION SUMMARY REF LOG: xxxxxx ON MM/DD/YY ANGLE AT TOP PERF: 68° @ 9600' 4 -1/2" BKR CIBP (08/17/08) 10750' , Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 9600-9625 O 08/02/09 4 -1/2" SOLID LNR, 12.6 #, L-80_0152 bpf, ID = 3.958" 10843' , 2 -7/8" 6 9850- 10200 C 04/21/05 2 -7/8" 6 10260 - 10430 C 08/18/08 4 -1/2" SLTD LNR, 12.6 #, L-80_0158 bpf, ID = 1958" 11791' 2 -718" 6 10470 - 10590 C 04/21/05 2 -7/8" SLOT 10843 - 11791 SLOTTED 06/07/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/82 ORIGINAL COMPLETION 08/22/09 RRD /PJC CIBP / PERFS (08/02/09) WELL: 18 -03B 02/12/95 RIG SIDETRACK (18 -03A) 06/25/10 RCT /PJC SET PXN (05/15/10) PERMIT No: r 203O860 06/25/03 DAC /KK RIG SIDETRACK (18 -03B) 07/28/10 JLJ /PJC PULL PXN / GLV C/O (07/25 -26/10 API No: 50- 029 - 20776 -02 07/29/07 CJWSV SET PXN PLUG (07/28/07) SEC 24, T11N, R1 4E, 11 84' SNL & 161' WEL 08/26/07 JRP /SV PULLED PXN PLUG (08/24/07) 09/05/08 JKC/PJK PERF/ CIBP (08/17/08) BP Exploration (Alaska) OPERABLE :Producer 18-03B (PTD~030860) Tubing integrity restored • Page 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~~IV+,o Sent: Monday, July 26, 2010 7:42 AM ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, RES GPB East Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead Cc: Janowski, Carrie; AK, D&C Well Integrity Coordinator; Chivvis, Robert Subject: OPERABLE :Producer 18-036 (PTD #2030860) Tubing integrity restored All, Producer 18-03B (PTD #2030860) passed an MITIA after the gas lift valves were dummied off. The passing test verifies tubingintegrity has been restored. The well as been rec asst led as Operable and may be placed on production when convenient for operations. Please be careful when placing the well on production as the IA is fluid packed. Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 4 C f ~'I 4 ~ 1. From: AK, D&C Well Integrity Coordinator Sent: Sunday, May 16, 2010 9:03 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>'; AK, OPS FSl Facility OTL; AK, OPS FSl DS Ops Lead; AK, RES GPB East Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; Sinyangwe, Nathan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, D&C We~ntegrity Coordinator Cc: Janowski, Carrie; Quy, Tiffany; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC); We an, Taylor T Subject: NOT OPERABLE :Producer 18-03B (PTD #2030860) TxIA Communic on All, Producer 18-03B (PTD #2030860) has confirmed IA communication and has been secured with a down hole plug. The well passed a CMIT - TxIA roving competent barriers. The well has been reclassified as Not Operable. The plan forward is: 1. Wellhead: Perform wellhead diag stics on the IC void. 2. Pumping: MIT-IA to 2500 psi Please call if you have ques~ibns or concerns Gerald Murphy (alt. orin Roschinger) Well Integrity Coor ~ ator Office (907) 659- 102 Cell (907) 752 755 Pager (907 59-5100 Ext. 1154 8/10/2010 NOT OPERABLE :Producer 18-03B~TD #2030860) TxIA Communication. Regg, James B (DOA) Page 1 of 2 From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Sunday, May 16, 2010 9:03 PM ~ l To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, RES GPB East Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; Sinyangwe, Nathan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, D&C Well Integrity Coordinator Cc: Janowski, Carrie; Quy, Tiffany; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC); Wellman, Taylor T Subject: NOT OPERABLE :Producer 18-036 (PTD #2030860) TxIA Communication Attachments: 18-03B TIO Plot.doc All, :/ Producer 18-03B (PTD #2030860) has confirmed TxIA communication and has been secured with a down hole plug. The well passed aCMIT - TxIA proving competent barriers. The well has been reclassified as Not Operable. ._--- The plan forward is: 1. Wellhead: Perform wellhead diagnostics on the IC void. 2. Pumping: MIT-IA to 2500 psi Please call if you have questions or concerns. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator ~ ;~•,~ l Office (907) 659-5102 ti "~ '`~ ~~ Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Saturday, May 08, 2010 12:51 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>'; AK, OPS FSl Facility OTL; AK, OPS FSl DS Ops Lead; AK, RES GPB East Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; Sinyangwe, Nathan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, D&C Well Integrity Coordinator Cc: Janowski, Carrie; Quy, Tiffany; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC); Wellman, Taylor T Subject: UNDER EVALUATION :Producer 18-036 (PTD #2030860) TxIA Communication All, Producer 18-036 (PTD #2030860) has confirmed sustained IA casing pressure due to TxIA communication. The wellhead pressures were tubing/IA/OA equal to 1121/2060/20 on 5/6/2010. The well has been reclassified as Under Evaluation. The well will remain shut-in while work is conducted to restore integrity. The plan forward is as follows: 1. Slickline: Set a downhole plug in tubing 2. Pumping: MIT-T to 3000 psi, CMIT TxIA to 2500 psi 3. Slickline: Evaluate gas lift valve replacement, if required A TIO plot and wellbore schematic have been included for reference. 5/19/2010 NOT OPERABLE :Producer 18-03B~TD #2030860) TxIA Communication. Page 2 of 2 «18-03B TIO Plot.doc» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 5/19/2010 PBU 18-03B PTD #2030860 5-16-2010 TIO Pressures Plot r_._...,.~~._,.~..a.~...~._.__.._._ 4.000 3,OOi_i 2,000 1,00;1 Well:18-03 02!13!10 02.~2Df10 02!27!10 03fD6f10 03!13!10 D3f20f10 03.%27!10 04!03110 04!10./10 04!17!10 04124!10 05!01!10 05!08!10 ~- T6g -f- IA -~ OA OOA w OOOA On UNDER EVALUATION :Producer 1~3B (PTD #2030860) TxIA Communic,~ion Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ,, Sent: Saturday, May 08, 2010 12:51 PM ~' To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, RES GPB East Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; Sinyangwe, Nathan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, D&C Well Integrity Coordinator Cc: Janowski, Carrie; Quy, Tiffany; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC); Wellman, Taylor T Subject: UNDER EVALUATION :Producer 18-03B (PTD #2030860) TxIA Communication Attachments: 18-036 TIO Plot.doc; 18-03B.pdf All, Producer 18-036 (PTD #2030860) has confirmed sustained IA casing pressure due to TxIA communication. The wellhead pressures were tubing/IA/OA equal to 1121/2060/20 on 5/6/2010. The well has been reclassified as Under Evaluation. The well will remain shut-in while work is conducted to restore integrity. The plan forward is as follows: 1. Slickline: Set a downhole plug in tubing 2. Pumping: MIT-T to 3000 psi, CMIT TxIA to 2500 psi 3. Slickline: Evaluate gas lift valve replacement, if required A TIO plot and wellbore schematic have been included for reference. «18-036 TIO Plot.doc» «18-03B.pdf» ~ Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 5/12/2010 PBU 18-03B PTD 2030860 5/8/2010 TIO Pressures Plot 4.oon 3,000 2,000 1,000 We11:18-03 02/13110 02i20o1a 02/27110 03!06!10 03/13/10 03~20J10 03127!10 Od103I10 04x10!10 O4/17110 04!24110 05!01110 05/08/10 # T6g -~- IA -~- OA OOA OOOA On • • TREE = 5-1 /8" Mc EV OY WELLHEAD = McEVOY ACTUATOR = AXELSON KB. ELEV = 44.T BF. ELEV = KOP = 9214' Max Angle = 96 @ 10774' Datum MD = WA Datum TV D = 8800' SS 13-3/8" CSG, 72#, 1-80, ID = 12.347" ~ TOP OF 7" SCAB LNR ~ 18-036 ~J 2600' 2~$9' ~ Minimum ID = 3.725" ~ 9056' 4-"I/2" HES XN NIPPLE 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" i--~ 75$5' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 7740' SAFEfY N ~ 4-112" CAMCO BAL-O SVLN, ID = 3.812" ~ 2690' ~--i 9-5(8" X 7" BKR ZXP LTP, ID = ? rAS 1_ IFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 3 3289 3279 17 KBG-2 DOME BK 16 06/29/03 2 5794 5480 32 KBG-2 SO BK 20 06!29/03 1 7538 6947 31 KBG-2 DMY BK 0 06/23/03 75$5' -) 9-518" X 7" BKR H PKR, ID = 6.188" 7590' 9-518" X 7" BKR HMC LNR HGR, ID = 6.184" 8991' -{4-112" HES X NIP, ID = 3.813" 9012' 7" X 4-112" BKR S-3 PKR, ID= 3.875" 9036' 4-112" HES X NIP, ID = 3.813" 9056' ~-~ 4-1 i2" HES XN NIP, ID = 3.725" 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-I 9068' 7" EzSV --~ 923T F 7" LNR, 29#, L-80, .0372 bpf, ID = 6.184" 9735' PERFORATION SUMMARY REF LOG: xxxxxx ON MIiNDDr'YY ANGLE AT TOP PERF: 68° @ 9600' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9600 - 9625 O 08/02/09 2-7/8" 6 9850 - 10200 C 04/21 /05 2-7/8" 6 10260 - 10430 C 08/18/08 2-7/8" 6 10470 - 10590 C 04/21/05 2-7/8" SLOT 10843 - 11791 SLOTTED 06/07(03 9061' --~ 7" X 4-1 /2" BKR ZXP LRP, ID = ? 9069' 4-1 /2" WLEG, ID = 3.958" MILLOUT WINDOW 9214' - 9226' /655' 4-1/2" WFD CIBP (08!02/09} ~~ 10729' BKR ECP PKR 11$21' PBTD '4-1/2"BKR CIBP (08/17/08} 10750' 4-1 /2" SOLID LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 10$43' ' 4-112" SLTD LNR, 12.6#, L-80, ID = 3.958" 11791' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/16!82 ORIGINAL COMPLETION 08/22!09 RRD/PJC CIBP! PERFS (08!02/09) 02!12/95 R1G SIDETRACK (18-03A} 06/25!03 DAClKK RIG SIDETRACK (18-036} 07129/07 CJN(SV SET PXN PLUG (07!28107) 08/26/07 JRP/SV PULLED PXN PLUG (08124/07) 09/05/08 JKC/PJK PERF/ CIBP (08/17/08) PRUDHOE BAY UNIT WELL: 18-038 PERMIT No: 2030860 API No: 50-029-20776-02 SEC 24, T11 N, R14E, 1184' SNL & 161' WEL BP Exploration {Alaska} STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM~ON REPORT OF SUNDRY WELL OPERATIONS ~~~~I~~~~-~~ ~ ~UG ~ ~ ~~~F~ 1. Operations Abandon ~ Repair Weli ~ Plug Perforations ~ Stimulate~ "'° °'~ "° Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~~~<'~~' ~°?~ ~' Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: ivame: De~lopment ~ Exploratory ~ 2o3-osso 3. Address: P.O. Box 196612 StP2tig1'2phIC ~ Senrice ~~ 6. API Number. Anchorage, AK 99519-6612 50-029-20776-02-00 7. KB Elevation (ft): 9. Well Name and Number: 44.65 KB PBU 18-036 8. Property Designation: 10. Field/Pool(s): ADLO-028326 PRUDHOE BAY Fieid/ PRUDHOE OIL Pool 11. Present Well Condition Summary: ~ Total Depth measured 11823 feet Plugs (measured) 10750 9655 true vertical 8760.46 feet Junk (measured) None Effective Depth measured 11823 feet , true vertical 8760.46 feet ' ~~'°`~~ ~~ ~~~~~ ~ '° ' ° r , *?.aJ ~ ' ~~ '`~ t ~i~~ Casing Length Size MD ND Burst Collapse Conductor 108 20" 91.5# H-40 28 - 108 28 - 108 1490 470 Production 7714 9-5/8" 47# L-80 26 - 7740 26 - 7121 6870 4760 Surface 2572 13-3/8" 72# L-80 27 - 2599 27 - 2599 4930 2670 Liner 2158 7" 29# L-80 7577 - 9735 6980 - 8786 8160 7020 Liner 4869 7" 29# L-80 2689 - 7585 2689 - 6987 8160 7020 Liner 2762 4-1/2" 12.6# L-80 9061 - 11823 8364 - 8761 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 23 - 8992 4-1/2" 12.6# L-80 8992 - 9069 Packers and SSSV (type and measured depth) 7" Baker ZXP Top Packer 2689 7" Baker H Packer 7585 4-1/2" Baker S-3 Perm Packer 9012 4-1/2" Baker ZXP Packer 9061 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 649 49090 7 1117 Subsequent to operation: 14. Attachments: 15. Well Class after qroposed work: Copies of Logs and Surveys Run Exploratory ~~ Development t""v Service ~ Daily Report of Weli Operations X 16. Well Status after proposed work: Oil ~ Gas 1~ WAG ~ GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 8/5/2009 Form 10-404 Revsi ed 04/2006 ~ ' ~,~ ~~ , := ~ -j ~~,~,; ~ Submit Origmal Only "`-~~? s :s U+,? ~.. ~ I l'~ ` ~,'y r..~' '%,y r C~% 18-03B 203-086 PERF ATTACHMENT ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18-03B 6/22/03 SL 10,843. 11,791. 8,771.88 8,761.66 18-03B 4/21/05 PER 9,850. 10,200. 8,789.89 8,777.54 18-03B 4/21/05 PER `~' 10,470. 10,590. 8,775.23 8,783.35 18-03B 8/16/08 BPS ~ 10,750. 11,791. 8,780.36 8,761.66 18-03B 8/17/08 APF 0,260. 10,430. 8,774.38 8,772.53 18-036 8/2/09 APF 9,600. 9,625. 8,749.53 8,758.7 18-03B 8/2/09 BPS 9,655. ~ 10,843. 8,768.42 8,771.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LlNER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE s ~ ~ 18-03B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED ,.~~~ STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERATI,QNS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' ~ Exploratory ~ 2o3-oa6o - 3. Address: P.O. Box 196612 Stratigraphic ~ S@rVICe 6. API Number: Anchorage, AK 99519-6612 50-029-20776-02-00 7. KB Elevation (ft): 9. Well Name and Number: 44.65 KB- PBU 18-03B 8. Property Designation: 10. Field/Pool(s): ADLO-028326 ~ "-~ " "`~PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11823. feet Plugs (measured) 'V"~ ~\~~ ,~~5~~`^~ true vertical 8760.46 ~ feet Junk (measured) None "~ "° c"3 ~ ~ ' ve Effective Depth measured 11823 ~ feet ~ - ~ ~ true vertical 8760.46 - feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28 - 108 1490 470 Production 7714 9-5/8" 47# L-80 26 - 7740 26 - 7121 6870 4760 Surface 2572 13-3/8" 72# L-80 27 - 2599> ~ 27 - 2599 4930 2670 Liner 2158 7" 29# L-80 7577 - 9735 6980 - 8786 8160 7020 Liner 4869 7" 29# L-80 2689 - 7585 2689 - 6987 8160 7020 Liner 2762 4-1/2" 12.6# L-80 9061 - 11823 8364 - 8761 8430 7500 Perforation depth: Measured depth: SEE ATTACHMENT - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 23 - 8992 4-1/2" 12.6# L-80 8992 - 9069 Packers and SSSV (type and measured depth) 7" Baker ZXP Top Packer 2689 7" Baker H Packer 7585 4-1/2" Baker S-3 Perm Packer 9012 4-1/2" Baker ZXP Packer 9061 ECP PKR 10729 12. Stimulation or cement squeeze summary: Intervals treated (measured): S ~F~x. SEP ~ '~ 20D6 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 442 41809 0 1531 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development ass - Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ' -Gas ~~ WAG ~~ GINJ WINJ ~il~; WDSPL ~:~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Titfe Data Management Engineer ~ Signature ,, ; ~, Phone 564-4944 Date 8/19/2008 Form 10-404 Revised (1412(}06 "> ~~ J{ ~ Submit Original Only Page 1 of 1 • Maunder, Thomas E {DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, September 17, 2008 8:44 AM To: 'Preble, Gary B (SAIC)' Cc: 'Cismoski, Doug A' Subject: RE: DS 18-03B (203-086) Gary, As 1 was completing the review, I noted that your pert sheet does not mention the CIBP set at 10750' on 8/17. Would you check and if appropriate update the pert sheet and email me a corrected copy. I will make a hand entry on the 404 regarding the plug. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Wednesday, September 17, 2008 8:35 AM To: 'Cismoski, Doug A'; Preble, Gary B (SAIL) Subject: RE: DS 18-03B (203-086) Thanks. From: Cismoski, Doug A [mailto:CismosDA@BP.com] Sent; Tuesday, September 16, 2008 5:11 PM To: Maunder, Thomas E (DOA); Preble, Gary B (SAIC) Subject: RE: DS 18-03B (203-086) Tom - Here are the daily reports for the perforating. Doug Doug Cismoski P.E. Wells Team Leader Alaska Drilling and Wells 907-564-4303 (o) 907-240-8041 (m) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, September 16, 2008 4:37 PM To: Preble, Gary B (SAIC) Cc: Cismoski, Doug A Subject: DS 18-03B (203-086) ~~~~~1~~ Gary and Doug, I am reviewing the 404 and brief operations report submitted for the recent extended perforating job. Are reports available that contain more detail like a rig report'? Email is fine. I look forward to your reply. Tom Maunder, PE AOGCC 9/17/2008 Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) (Gary.Preble@bp.comj Sen#: Wednesday, September 17, 2008 10:25 AM To: Maunder, Thomas E (DOA) Subject: Emailing: 18-03B-PERF-ATTACH.pdf Attachments: 18-03B-PERF-ATTACH. pdf 18-036-PERF-AITA CH.pdf (36 KB)... «18-03B-PERF-ATTAC~i.pdf» The message is ready to be sent with the following file or link attachments: 18-03B-PERF-ATTACH.pdf Nate: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. 1 0 0 0 OQ O lV j ( ~ € ~ 1 N j ! ( , i 3 I ( ~~Nt~~h;~Iti( ~~~ i I ~V O - ~- If +i ~~ ` ~ ~'-i iW1W W`~t~N~ iM~ { (~~WIdjG"~W~~!QIO Qrip~j(t!j(C1lt: !iLiW~~i~~~(lLl~LLI~QjQ >~ ., ., s ~-i0DC0I00sOD;001 Q.F~;N,NNjf/3(tntn'fn .,... _.f ......... ......f._.,... i ~ ! ~ ` ~f i f~ i ~ i ( , ( ( m~ ' I ( ! ~ r , ! f i E r ~~(Q ( .h~ 0 r 1 { I t i ~ ( rn?ora~;ua cn` I r~;~I~(~ ter! iw=a~~~alaio((cN.~ r;a:G~O~OS f r,rirarir"! i0.(L>:I(nf(~IU9~V3tf,A sr r "~rri! 'ca!d(© N rPIC1h~=tArW ~;~ ~i ~(l"` N ~~0 00fo'oici ~r tJl(t-it- r 1._ ~ i ( w' t ~ 1115 Q ~ I , v! ~ ? i ~ ' i i i I0= ! I~~~ NJI~iUi1WwiL/yL~IE7-'s ! ' J ri r ~ I~1X' .~_.t...._i.-._~.___._._._...III.~.., s i _. r ~...._ ...:~ W O O! fl1 ~ ~ r ~ ~ 1Zu. n"~.~aa~ Iv,v,v~w o! ~ o~~~ rW~ ~zlzfz~o +~lrr~in ~ ;001 ~Cl~i~i~~V~ i,Q(Q~a(x Cf~ v;~=i; ~h`0"~p~ Q~p t];~I,ai..flV;UiUjW !C. ~N,,r`1r• m pj~j(~{wr~~1jW(W;WF0. oo=mmlm~m; ~ ~ M€ ~r~c~ !~; oj~o ~(oi ; u.~n.cAO~ ~'~iY Oo`"sas(cSl r00: (mjaa(a~c~i-~~- I~~C r!r'r.r(rl jQ iQ m~mllL jLL. g ~jG 18-03B 203-0860 PERF ATTAC:HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18-03B 6/22/03 SL 10,843. 11,791. 8,771.88 8,761.66 -036 4/21/05 PER 9,850. 10,200. 8,789.89 8,777.54 18- _ 4/21/05 PER 10,470. 10,590. _ 8,775.23 __ 8,783.35 18-036 18/08 APF 10,260. 10,430. 8,774.38 8,772.53 AB ABANDO PER PERF APF ADD PERF RPF REPERF _ BPP BRIDGE PLUG P UL SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SOZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~~~~~® • ~J • t~_J 18-03B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY i ACTIVITYDATE~ SUMMARY -~ 8/15/2008 CTU #9 1.75" CT Extended Perf on WWP Road From P2-13 MU BOP's. ~*******~ 'Continued on 8/16/08 WSR *'`******* 8/15/2008 T/I/0=2300/200/0; Pull 5-1/8" ISA BPV thru dry hole tree with BOP stack for `Klondike; 1-2' ext. used, tagged @ 90"; (Best/Wortham) 8/16/2008' CTU#9 1.75"CT MIRU. Extended perforations. Chuck Sheve with AOGCC has 'waived the BOP test. RIH w /logging tools GR/CNL for coil flag. Drift w / 3.625" ':nozzle POOH M/U CIBP BHA ***'** Continued on 8/17/08 WSR ~~'***** 8/17/2008 CTU # 9 1.75" CT (extended perf )"'`*''*** Continued from 8/16/08 WSR ******* M/U CIBP RIH to set at 10750' PUH pump kill and FloPro. M/U 170' of HSD !2906PJ 60 deg 6 spf perforating guns. Perforate from 10430' to 10260'. Recovered 1/2" ball all shots fired.M/U 2.71" JSN RIH sweep out flopro ******* Continued on 8/18/08 WSR ******* 8/18/2008`T/I/0=0/0/0; Set 5-1/8" ISA BPV #519 thru dryhole tree with dry-rod; (Best/Wortham) 8/18/200&.CTU # 9 1.75" CT "***"" Continued from 8/17/08 WSR ******* Extended Perf job 'POOH Blowdown coil w/N2 for pipe swapdue to below min. wall thickness in a :'.couple of areas. Freeze protect well with 53 bbls diesel. RDMO `, ****'`*******" Job Complete ************ FLUIDS PUMPED BBLS 571 KCL 120 DIESEL 5 METH 15 FLO PRO 711 Total • • WELL SERVICE REPORT Page 1 of 2 WELL JOB SCOPE UNIT '~ 8_038 PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 8/16/2008 SET MECHANICAL PLUG tMM COST CODE PLUS KEY PERSON NIGHT SUPV PBD18WL03-C DS-WAGONER CULPEPPER M!N ID DEPTH TTL SIZE 3.725 " 9056 FT 4.5 " MMARY CTU#9 1.75"CT MIRU. Extended perforations. Chuck Sheve with AOGCC has waived the BOP test. RIH w /logging tools GR/CNL for coil flaa. Drift w / 3.625" nozzle POOH M/U CIBP BHA ****** Continued on 8/17/08 WSR **"***** LOG ENTRIES snit Tb , IA, OA 2425 150 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 MIRU CTU 07:59 0 Function test BOP'S 08:07 0 Scaffolding crew AOL to build scaffolding around the BOP'S on the WWP 09:44 0 P/U in'ector M/U ctc & nozzle for BOP test 10:17 0 Stab on well start BOP test 16:20 0 BOP test is com leted GOOD TEST 16:36 0 M/U WFD CTC ull test to 20 k t MHA to 3500 si 17:11 0 M/U to in tools GR/CNL 17:21 0 Stab on well LPT 300 si HPT 4000 si 17:43 0 Open swab 23.5 turns RIH w / WFD ctc dcv hydro disco blank sub 2.875"x 247' xo 3.125"x 0.44' xo 3"x 0.50" logging carrier & 3.625" nozzle 15.1' AOL = 19.02' 17:50 0 2425 403 5 Come online w / um to knock down well head ressure 18:27 0 400 123 RIH 19:34 5966 183 3 0 126 Wt Ck 10.5k 20:14 8922 312 0 0 126 Wt Gk 17k 20:36 10850 455 0 0 126 Sto at to in de th confirm memlo er read . 20:39 10850 470 0 0 126 Start to er u 40 m 20:44 10700 470 0 0 126 Sto aint white & red fla at 10700' 20:58 10200 544 0 0 126 Sto at to of to in de th 21:05 10200 544 0 0 126 POOH 22:41 0 800 0 0 126 Ta at surface/Dose master & swab valve 23:07 0 Po off well 23:19 0 Breakdown memo tools 23:36 0 ,~(~ IBP >yIHA 2.875" x 2.4T Setting tool 3.625" x 5.3T setting sleeve 3.560" x 1.03' CIBP 3.562" x 1.10' OAL= 9.9T 23:59 0 LPT 250 si HPT 4000 si Final Tb , IA, OA JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL CH2MHILL LABOR $6,800 $17,360 EQUIPMENT FLEET $14,875 $35,350 HOT WATER PLANT $1,185 $1,185 MI FLUIDS $0 $0 ORBIS $2,600 $5,200 SCHLUMBERGER $24,145 $30,451 SCHLUMBERGER PLUS 15 PERCENT $3,622 $4,568 WAREHOUSE $0 $48 WEATHERFORD $15,094 $15,094 TOTAL FIELD ESTIMATE: $68,321 $109,256 FLUID SUMMARY file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-002 18-03B~IMM~ 16Aug20... 9/ 17/2008 C] 123 bbls 1% KCL bbls Diesel bbls Flo Pro • Page 2 of 2 file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-002 18-03B~IMM~16Aug20... 9/17/2008 • WELL SERVICE REPORT Page 1 of 2 WELL JOB SCOPE UNIT 18_036 PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 8/17/2008 PERFORATING IMM COST CODE PLUS KEY PERSON NIGHT SUPV PBD18WL03-C DS-WAGONER CULPEPPER MIN ID DEPTH TTL SIZE 3.725 " 9056 FT 4.5 " c; i u ~ a ~. i5° c; i f extenaea pert /~;_,._,. c;onnnueo rrom ~nciiuu w5K -x,._-°° Miu c;irsr rtiH to set at ~u~ov run pump Km and FloPro. M/U 170' of HSD 2906PJ 60 deg 6 spf perforating guns. Perforate from 10430' to 10260'. Recovered 1/2" ball all shots fired.MJU 2.71" JSN RIH sweep out flODrO ******* Continued on 8/18/08 WSR ***"'""` LOG ENTRIES Init Tb , IA, OA 950 0 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 LPT 250 si HPT 4000 si 00:05 0 950 0 0 0 Start KCL down B/S to knock down ressure 00:15 0 750 0 5 50 Continue to knock down 00:29 0 677 0 2 120 Swa to meth 00:33 0 300 0 0 125 S/D meth RIH 02:29 8800 328 40 0 125 Wt Ck 11 k continue RIH 03:02 10701 470 23 0 125 Sto at fla Reset to corrected de th of 10687' Mech at 10687' 03:04 10687 470 23 0 125 Wt Ck 13k 03:11 10750 480 20 0 125 load ball to set CIBP 5/8" ball 03:16 10750 490 695 1.4 125/0 Dro ball chase down 03:33 10750 713 772 .9 28 Reduce rate 03:35 10750 773 2800 .9 30 Ball on seat Settin tool sheared set CIBP at 10750' PUH 03:38 10750 758 26 0 30 Ta lu set 5k on it 03:44 10473 837 1647 1.2 30 In'ectivi test 03:47 10473 968 155 0 36 S/D um PUH to 9750' 03:59 9705 877 33 2.0 36 Brin um online down B/S onl for kill 04:02 9705 1677 31 3.0 50 Increase rate 04:24 9705 2700 35 2.2 105 Continue kill 05:44 9705 2700 23 2.0 265d Swa to diesel 05:58 9705 2882 23 0 293f Swa to Flo ro down the coil onl 06:01 9705 1780 2048 1 293 Start flo ro 06:36 10500 2313 3676 1 328 La in Flo Pro 1:1 POOH 07:14 8000 29 0.3 Start fillip well down back side w /diesel 07:30 3500 129 PJSM w /crews for loadin ups onto WWP 08:10 0 At surface Gose master valve 23.5 turns 08:37 0 Finished brie in un onto WWP 08:38 0 Po off well UD WFD settin tools 08:50 0 Ca well o n master valve 23.5 turns 08:55 0 Preform no flow test ~--- 10:19 0 PJSM w / TCP & Crews for ickin u ups 10:31 0 P/U erf ups 11:22 0 RIH w I WFD MHA 2.875"x 4.69' deployment bar 1.75"x 19.11') 9 2906PJ ups 2.88" OAL = 218.98' 13:16 10700 Wt ck 19.5 k 13:20 10743 Ta CIBP uh correct de th to 10748.7' + 9.7' 13:36 10748 PUH to erforatin de th 13:43 10447 983 1 Pum 5 bbls Flo ro 13:46 10447 1100 1 Dro 1/2" ball PUH 13:50 10430 2137 1.9 Park at 10430' bottom shot 14:10 10430 1244 0.8 25 Reduce um rate 14:17 10430 Ball on seat ups fired 2500 si 14:22 10430 POOH um in diesel down B/S onl 15:53 0 At surface reform no flow test 16:11 0 PJSM for la in down ups file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-001 ~18-03B~IMM~17Aug20... 9/17/2008 • • Page 2 of 2 16:17 0 Po off welt start la in down uns 16:42 0 Recovered 1 /2" ball 17:10 0 Guns are out of the hole Gose master valve 23.5 turns 17:20 0 Load uns out of WWP 18:05 0 Crew chap e 18:21 0 M/U 2.71" nozzle 18:46 0 Stab on well Fluid ack coil 18:50 0 LPT 200 si 18:54 0 HPT 4000 si 19:01 0 0 0 0 15 O en well RIH 20:20 6425 Sto to check i e .089 wall 20:35 7106 Sto check butiweld in i e looked ood 20:46 7802 S t check i e .106 wall continue RIH 21:29 10750 0 0 0 15 Ta CIBP line u Kcl down coil 21:32 10750 13 2200 1.4 15 POOH Chasin flo ro 22:56 5170 11 2306 1.4 135 Swa to diesel 23:19 3500 26 2340 1.4 168 Diesel nozzle 23:39 2000 11 2259 1.4 195 Swa to KCL 23:59 300 11 2324 1.4 212 Continue to POOH Final Tb , IA, OA JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL CH2MHILL LABOR $920 $18,280 EQUIPMENT FLEET $3,023 $38,373 HOT WATER PLANT $1,146 $2,331 ORBIS $2,600 $7,800 PAD THREE $870 $870 SCHLUMBERGER $59,006 $89,457 SCHLUMBERGER PLUS 15 PERCENT $8,896 $13,464 WAREHOUSE $5,796 $5,844 MI FLUIDS $0 $0 WEATHERFORD $0 $15,094 TOTAL FIELD ESTIMATE: $82,256 $191,512 571 bbis KCL 120 bbls Diesel 5+bbls Meth 15+bbls FloPro Tanki file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-001 ~ 18-03B~IMM~ 17Aug20... 9/17/2008 • • WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT 8-03B PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 8/18/2008 PERFORATING IMM COST CODE PLUS KEY PERSON NIGHT SUPV PBD18WL03-C DS-WAGONER CULPEPPER MIN ID DEPTH TTL SIZE 3.725 " 9056 FT 4.5 " to below min. wall thickness in a couple of areas. Freeze protect well with 53 bbls diesel. RDMO ****"******** Job Complete ****"*"***** LOG ENTRIES Init Tb , IA, OA 0 0 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:00 300 11 2324 1.4 212 Continue to POOH N2 um AOL 00:04 75 0 0 0 227 S/D um 00:07 0 Ta u at surface Close swab and master 01:11 0 Test n2 line 01:15 0 Brin n2 online 1500 scf/min 01:31 0 S/D n2 Pum 02:30 0 Start breakin down WWP stack 08:00 0 Finish ri down close out ermit Road to sho 09:00 0 Arrive at sho Final Tb , IA, OA 0 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL BAKER OIL TOOLS $361 $361 CH2MHILL LABOR $0 $18,580 ORBIS $2,600 $10,400 PAD THREE $0 $870 SCHLUMBERGER $13,322 $102,779 SCHLUMBERGER PLUS 15 PERCENT $1,815 $15,279 MI FLUIDS $0 $0 WEATHERFORD $0 $15,094 EQUIPMENT FLEET $0 $38,373 WAREHOUSE $0 $5,844 HOT WATER PLANT $0 $2,331 TOTAL FIELD ESTIMATE: $18,098 $209,910 file://C:\ternp\Temporary%20Internet%20Files\OLKF\WSR-000 18-03 B~IMM~ 18Aug20... 9/ 17/2008 FLUID SUMMARY 15 bbls KCL • • _~,.. ::..4 _- MICROFILMED 03101 !2008 ~: ,~ ~~ ,~.> DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_InsertslMicrofilm Marker.doc R~~~¡ " L.Ù AUG 0 8 Z006 Schlumbel'gel' ~_ Oif & Gas Cons. Co~ NO. 3883 .Anchorage Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ()5" '""7,' ()C~" 0, --... ".- '. " ~----- \~J ' -- c·r ú ¡¡'~!\.\':J_ ':¿yr'~}'_~: ,..\.-~-j, (' .... \1 "' 2D Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII J b# L D D BL C C e 0 og escrlptlon ate olor D NK-43 11211388 PROD PROFIL " 04/02/01> 1 NK-22A 10568415 PR IDEFT 02/26/03 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17 -21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 SBHP 12/02/05 1 X-15A 11212877 USIT 07/18/06 1 J-01 B 11511430 US IT 07/24/06 1 15-12A 11221595 US IT 07/25/06 1 Z-14B 11217268 US IT 07/29/06 1 5-400 10987564 CH EDIT PDC-GR OF US IT 01/26/06 1 D-03A 11217269 USIT 07/31/06 1 05-28A 11217267 USIT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 08/01/06 . . e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 ~o1¡7 RE: MWD Formation Evaluation Logs 18-03B, 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 18-03B: LAS Data & Digital Log Images: 50-029-20776-02 ;}D ?J ,- ()?5l.o 1 CD Rom ~ r1) 0'0'·1 D(P Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 A TTN: Beth Received by tfùQDö) .~ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ~ Color CD Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I Field: Prudhoe Bay ~ 0 3 - 0 í b NO. 3677 02/09/06 «.'-r-" Jj 1T\H... F [~' = C n t:'j¡ ") ., n! fI h ~\,,#Cîc t"''\;jb.~, r c ti f'j b d}wv BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: .?'{ {'J? ( 00 Well Job# Log Description Date BL 13-31A .Qo5-iIDD 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 DS 18-03B ~05 ~Of"',(" 11057071 SBHP SURVEY 12102/05 1 NK-43 rQ~/- C () 1 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /t¥¡ - 057 11183463 LEAK DETECTION LOG 01/28/06 1 DS 06-22A Ie:¡ ?y-c s 7 N/A SENSAlMEM LDL 01/28/06 1 DS 11-26 I ß f.1;'~ '3 4- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 J 9& ., is 1- 11098756 PROD PROFILE W/DEFT & GHOST 01/30/06 1 L5-05 JA7-L'<'cCj' 11058541 RST 11/11/05 1 Z-29 ie:q-cÜ:Ç" 11051081 RST 08;10/05 1 L5-09 /C¡C -·/~ 11090725 RST 11/11/05 1 15-44 ,qú - II () 11194155 RST 01/15/06 1 C-2DB ..;{O(-I /4- 11075913 MCNL 08/29/05 1 02-14A Q03 . /.;?S 11075901 MCNL 07/29/05 1 Z-21 A -9ð 1- ìO f 11076449 RST 06/30/05 1 F-27 A d05-1&4- 10928641 MCNL 09/01/05 1 MPH-15 .f)c6··/59 11076486 USIT 12/15/05 13-31A -;::}CS-ILßb 11133211 SCMT 12/23/05 WGI-04 ) 7<1 - cSD 11183461 USIT 01/26/06 WGI-04 1'7et -C'~. 11211566 USIT 02/03/06 WGI-08 14(,1.... O¥1 10987559 US IT 01/02/06 WGI-08 ,C,O - c4Q 11058259 USIT 01/12/06 ._.. ~,!!:~. '....-·;JiUi~!¡~~S!{JL Pd1COOraGC Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth FEB22-~6 Schlumberger ~~~ {~'~ f-: ~ l! í~ L~ SChlurnbel'gel' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECEiVED DEC 2 1 2005 ~ ŒI & Gas ConS. Ccmrf:~kn ,~nchorage Well Job# Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L 1-15A 10715359 PROD PROFILE W/DEFT 11/04/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE WIDEFT 07/16/05 1 D.S 18-03B ~?>... OF3lt> 11057071 SBHP SURVEY 12102/05 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 11057072 SBHP SURVEY 12/03/05 1 A-31A 11072881 LDL 08/07/05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE W/DEFT 10/25/05 1 AGI-10 11087429 LDL 09/05/05 1 S-36 11152365 LDL 11/08/05 1 K-20B 11057076 SBHP SURVEY 12/06/05 1 M-18B 11072876 INJECTION PROFILE 08/02/05 1 2-18/L-16 11087185 LDL 10/01/05 1 2-62/Q-17 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~CANNfD ,-J¡:H\~ 2 5: 200b Date Delivered: 12/21/05 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. Color CD - ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received bY~n ~ J jlJ1~ Â\) ~ \- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030860 Well Name/No. PRUDHOE BA V UNIT 18-03B Operator BP EXPLORATION (ALASKA) INC 5(1 iA. ¿ t" J wYYl Â.I,¡~..3 API No. 50-029-20776-02-00 MD 11823 ...- TVD 8761"'" Completion Date 6/23/2003'" Completion Status 1-OIL -._-- ----.--------.---- - ---- ---~-- REQUIRED INFORMATION Mud Log No Samples No ~ --- - -- ----- -. ---------- DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, RES, ASI, DEN, NEU Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No - --- - _.--~ ED 0 11807 LIS Verificotion f'ù.A.. /J!.pt 0 Asc Directional Survey ~pt 0 Asc Directional Survey i Rpt LIS Verification "----- ----- --- 4 final final 4 Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? - '1' / N Daily History Received? Formation Tops Analysis~- Received? - - --._-- --- ------ Comments: ---._-----~ ---- - ----------- Compliance Reviewed By: ~ Current Status 1-01L UIC N Directional Survey Ves (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH ~ Received Comments 8958 11766 Open 7/24/2003 9194 11823 Open 7/1/2003 9194 11823 Open 7/1/2003 8958 11766 Open 7/24/2003 Sample Set Number Comments 6.11 c~tl,'1 (lv;d S,",/~ t1o¡d ''"'\ ~ ç , J .' MWD 0N f}/N Date: (5 ~v ~~ S-- ¡ ", -) STATE OF ALASKA \ ECEiVE1) ALASKA OIL AND GAS CONSERVATION COMI\mSSION .JU~ 1 3 2005 REPORT OF SUNDRY WELL OPERATIO~s ~f'm~ eomm~SS~m1 ¡.\'ask~ O~II & ClI.., \..~.., Stimulate D ~\nt,hl]~a~herD WaiverD Time Extension D Re-enter Suspended WellD Repair Well 0 PluQ PerforationsD Pull Tubing D Perforate New Pool 0 Operation Shutdown D Perforate ŒJ 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development [!] Exploratory D 5. Permit to Drill Number: 203-0860 6. API Number 50-029-20776-02-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 44.65 8. Property Designation: ADL-028326 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: 18-038 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 11823 feet true vertical 8760.5 feet Effective Depth measured 11823 feet true vertical 8760.5 feet Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 108 28.0 108.0 1490 470 Liner 2158 7" 29# L-80 7577 - 9735 6980.4 - 8785.8 8160 7020 Liner 4896 7" 29# L-80 2689 - 7585 2688.9 - 6987.3 8160 7020 Liner 2762 4-1/2" 12.6# L-80 9061 - 11823 8363.7 - 8760.5 8430 7500 Production 7714 9-5/8" 47# L-80 26 - 7740 26.0 - 7121.1 6870 4760 Surface 2572 13-3/8" 72# L-80 27 - 2599 27.0 - 2599.0 4930 2670 Perforation depth: Measured depth: 9850 -10200,10470 -10590,10843 -11791 True vertical depth: 8789.89 - 8777.54, 8775.23 - 8783.35, 8771.88 - 8761.66 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 4-1/2" 12.6# L-80 @ 23 @ 8992 @ 7585 @ 2689 @ 9061 @ 10729 8992 9069 Packers & SSSV (type & measured depth): 7" Baker H Packer 7" Baker ZXP Top Packer 4-112" Baker ZXP Packer 4-1/2" Baker ECP Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFL "UN 14 Z005 Prior to well operation: Subsequent to operation: Oil-Bbl 757 663 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 34.9 0 358 29.3 0 0 Tubing Pressure 456 402 13 Copies of Logs and Surveys run _ Daily Report of Well Operations_ x 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilŒJ GasD Development ŒI Service D 14. Attachments: Signature Garry Catron Garry Catron }l~- 0.~. WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 6/9/05 Form 10-404 Revised 4/2004 OR\G\NAL ) 18-038 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/21/05 Perforate 98501-1020016 SPF, 104701-10590' 6 SPF FLUIDS PUMPED BBLS 30 60/40 Methanal/Water 374 Diesel 348 20/0 KCL 45 Flo Pro 797 TOTAL Page 1 ) Tr<'EE:':: " , 5-1/8" McEVOY WELLHEAD = McEVOY ACTÜÃT'ÔR ~,_.m~Ã)<ELSÕÑ kB':ä8J; 44,7' BF. ELEV == 'KoÞ; . .. .. 9214; Max An~iî;~-'96@1 0?!4' Datum MD = N/A DaiumTVÖ; 880Ó;SS ') SAFET )rES: 18-038 - 2182" 1-1 4-1/2" CAMCO BAL-O SVLN, ID = 3.812" 1 ~ 2690" 1-1 9-5/8" X 7" BKR ZXP LNR TOP PKR 1 GA S LIFT MA NDRELS L ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 3 3289 3279 17 KBG-2 DOME BK 16 06/29/03 2 5794 5480 32 KBG-2 SO BK 20 06/29/03 1 7538 6947 31 KBG-2 DMY BK 0 06/23/03 2600" ~ 2689" 13-3/8" CSG, 72#, L-80, ID == 12.347" 1-1 I TOP OF 7" SCAB LNR 1-1 Minimum ID = 3.725" @ 9056' 4-1/2" HES XN NIPPLE I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 7585" 1-1 9-5/8" X 7" BKR H PKR, ID == 6.188" 1 1-1 9-5/8" X 7" BKR HMC LNR HGR, ID == 6.184" 7585" 7590" 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 7740" I- I I & & 8991" 1-1 4-1/2" HES X NIP, ID = 3.813" 1 9012" 1-1 7" X 4-1/2" BKR S-3 PKR, ID= 3.875" 1 9036" 1-1 4-1/2" HES X NIP, ID = 3.813" 1 9056" 1-1 4-1/2" HES XN NIP, ID = 3.725" 1 9061" 1-1 7" X 4-1/2" BKR ZXP LNR TOP PKR 1 9069" 1-1 4-1/2" WLEG, ID == 3.958" 1 MILLOUT WINDOW 9214' - 9226' ~ ~ l J & ~ I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID == 3.958" 1-1 9068" I- 10729" 1-1 BKR ECP PKR 1 I EZSV l-i 9237" ''' ,I, ,~1~:~IDI 7" LNR, 29#, L-80, .0372 bpf, ID = 6.184" 1-1 9735" ~ ÆRFORA TION SUMMARY REF LOG: xxxxxx OÎ'-i Mtv1!DD!YY ANGLE AT TOP ÆRF: 910 @ 9850' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 9850 - 1 0200 0 04/21/05 2-7/8" 6 10470 - 10590 0 04/21/05 I I I 4-1/2" SOLID LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 10843" 1 ~' I 4-1/2"SLTDLNR,12.6#,L-80,ID=3.958" 1-1 11791" 1 06/07/03 SL TO LNR 10843 - 11791 o DA TE REV BY COMMENTS 02/04/04 CMO/TLP KB ELEV/ ANGLE CORRECTION 04/22/05 KEY/TLH ADÆRF PRUDHOE BA Y UNIT WELL: 18-03B ÆRMIT No: "2030860 API No: 50-029-20776-02 SEC 24, T11N, R14E. 1184' SNL & 161' WEL REV BY COMMENTS ORIGINAL COM PLETION RIG SIDETRACK (18-03A) DAC/KK RIG SIDETRACK (18-03B) CAO/KK GLV C/O TLI-VTLP SL TD LNR DEPTH CORRECTION CMO/TLP DATUM MD/lV D CORRECTIONS DATE 08/16/82 02/12/95 06/25/03 06/29/03 08/04/03 09/13/03 BP Exploration (Alas ka) ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMllsslON WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 22. CASING, LINER AND CEMENTING RECORD I""'" (', A' S', 1,"1," ~, ',','""",,,' ,,' , " ' , ,"", ,"", ""SE"I:'''':I~'j~I~'' ¡;P"H' ·"'I',il',\, 1,1;,;." :LI';"\I:' ¿:::",;," ' ~ II~~ ;';; ',:,:',",,:',":, ',:,::,:"::."i':;:""";"!"::!:";::':;I\~!li:,,,:,,',';~ ¡'I",\I"I:,;;,:::':,:I':'I".,":·,I,II ,;,;;!,", ,.:",::"':,/ 1.1': I' ,~I, " ,~i,:,'," I~~,,","", 'T'~",'" ",",' "::~",,I',II~" ',", !.",I!,I !,',',:~I'IJ'~,' " 11:'1I,' 'II-, '''', ",:"i!"I'l"""",III:,:I~ " ',:, S~ZE ',' I',i';' ,1"'\fII'ý; ,:PER:, ¡¡;iY;'I:I" ",(3'RÄPE',!;,'~';' ~::rtO'M',i:: "'I' '!',~'ZE' ',', 'I," 20" 91.5# H-40 Surface 110' 30" 13-3/8" 72# L-80 Surface 2600' 17-1/2" 9-5/8" 47# L-80 I SOO-95 Surface 7740' 12-1/4" 9-518" x 7" 47# 126# L-80 2690' 7585' NIA 7" 29# L-80 7577' 9214' 8-1/2" 4-1/2" 12.6# L-80 9061' 11823' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD 10843' - 11791' 8772' - 8762' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1184' SNL, 161' WEL, SEC. 24, T11N, R14E, UM Top of Productive Horizon: 4175' SNL, 563' WEL, SEC. 24, T11N, R14E, UM Total Depth: 154' SNL, 1149' EWL, SEC. 30, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 691605 y- 5960680 Zone- ASP4 TPI: x- 691279 y- 5957680 Zone- ASP4 Total Depth: x- 693022 y- 5956466 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR, GR, RES, ABI, DEN, NEU MD 26. Date First Production: July 7,2003 Date of Test Hours Tested PRODUCTION FOR 7/28/2003 8.1 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 22C 24-HoUR RATE One Other 5. Date Camp., Susp., or Aband. 6/23/2003 ./ 6. Date Spudded 6/14/2003 ./ 7. Date T. D. Reached 6/19/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 44.65' 9. Plug Back Depth (MD+ rvD) 11823 + 8761 10. Total Depth (MD+TVD) 11823 + 8761 11. Depth where SSSV set (Nipple) 2182' MD 19. Water depth, if offshore NIA MSL 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-086 13. API Number 50- 029-20776-02-00 14. Well Number PBU 18-03B 15. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Lease Designation and Serial No. ADL 028326 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) f71t.1~~ ¡ ~/:z./t./" n7þ ~ I, I,' I' I, ~ :: I ' i, I : I"', 'I': ,I :' I ,¡' : ' : i :, i; ; II , ,I ~ ,', I ,I, :, " ;,', I' ::,' :', ; I , I, " I :, I : 'I I:' "I ,~AMci:l:J~Ï;,lp'Ul~I;D ',':". 2940 # Poleset 2400 sx Fondu, 400 sx PF 'C' 500 sx Class 'G', 300 sx PF 'C' Scab Liner: 318 sx 'G', 237 sx 'G' 525 sx Class 'G' sx Class 'G' SIZE 4-1/2", 12.6#, 13Cr80 PACKER SET (MD) 9012' TVD DEPTH SET (MD) 9069' 2,5~': Adl[>','.FFtA.CTtJR~,·ÇEME~T.SQUEEZE E-rC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 155 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl 1,744 Oll-Bsl GAs-McF 8,562 GAs-McF W A TER-Bsl 39 W A TER-Bsl GAS-Oil RATIO 4,911 CHOKE SIZE 84° Oil GRAVITY-API (CORR) 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 trI'DiS BFA.. AUG 0 5 2,01J3 r-;:;': '~~:i ::'~riTl ~-~;.::: \ ~ -.b~_Z3~ ð~ ¡ ,~:~:--I OR\G\NAL Form 10-407 Revised 2/2003 ~V' CONTINUED ON REVERSE SIDE -,'-' 28. GEOLOGIC MARKEh. ) 29. ,) FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Zone 2B 9316' 8589' None Zone 2A 9420' 8660' Zone 1 B 9488' 8699' Zone 1A 9624' 8758' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~.AW ({ ~ Title Technical Assistant Date D8 "'OLf .0.3 PBU 18-03B 203-086 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number I I N Drilling Engineer: Rob Tifipack, 564-4166 Permit No. Approva o. 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-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing 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 2/2003 OR\G\NAL Legal Name: Common Name: Test Date 6/14/2003 FIT 18-03 18-038 Test Type Test Depth (TMD) 9,214.0 (ft) EMW 9.58 (ppg) TesfDepth(TVD) 8,504.0 (ft) AMW 8.70 (ppg) SurfacêPrèS$Ul'e L~ãK QffPres$lJrê (i3HP) 390 (psi) 4,233 (psi) -' -~- Printed: 6/30/2003 1:50:41 PM ) ') BP Q:pØratio ns .Sl.Irnma ryRepo.rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From.. To Hours Task Code NPT Phase Descriptionöf Oþeration~ 6/7/2003 03:30 - 07:00 3.50 MOB P PRE Hold PJSM - Rig Down Nabors 2ES And Prepare To lay Mast Over - Move Camp Unit - load Truck Shop And Welding Shop - Move Pump And Pit Complex And Stage On Pad 07:00 - 08:00 1.00 MOB P PRE Pull Sub Base Off Well C-16A And Position On Pad - Hold Pre-Job Safety Meeting With Security And Rig Team Regarding Move To DS 18-03B 08:00 - 15:30 7.50 MOB P PRE Move Sub Base From C-16A To DS-18B 15:30 - 16:30 1.00 MOB P PRE lay Out Herculite And Spot Sub Base Over DS-18B Well Slot 16:30 - 19:00 2.50 RIGU P PRE Change Out Crown Saver Bell Line - Hold Pre-Job Safety Meeting - Raise Mast And Pin To A-legs - Bridle Down 19:00 - 21 :00 2.00 RIGU P PRE Spot Truck Shop - Mud Pit And Pump Complex - Camp Unit ~ Cuttings Tank 21 :00 - 22:00 1.00 RIGU P PRE Finish Rigging Up Rig Floor Area - Hook Up Utilities And Service Lines Between Pit Complex And Sub Base Rig Accepted For Well Work On DS 18-03B At 22:00 Hours 06/07/2003 22:00 - 22:30 0.50 WHSUR P DECaMP Hold Pre-Spud Meeting With All Personal Regarding Up Coming Well Operations 22:30 - 00:00 1.50 WHSUR P DECaMP Install Second Annulus Valve - Rig Up To Circulate Out Freeze Protection 6/8/2003 00:00 - 00:30 0.50 WHSUR P DECaMP Hold PJSM - Continue To Rig Up Circulating Lines From Tree To Choke Manifold 00:30 - 01 :30 1.00 WHSUR P DECaMP Hold PJSM - Rig Up lubricator with DSM - Pull BPV - Rig Down lubricator - Clear Rig Floor 01 :30 - 07:30 6.00 WHSUR P DECaMP Hold PJSM - Open Up Well Annulus Pressure At 320 Psi. And Tubing On Vacuum - Pump Down Annulus To Displace Tubing Freeze Protect Notice Increase In Pressure Shut Down And Check Control Line Pressure At 1100 Psi. Increase Control Line Pressure To 4300 Psi. - Swap To Tubing And Establish Circulation Pump Condet Spacer Followed With 9.8 PPG Brine At 3 BPM 460 Psi. Holding 340 Back Pressure With Choke Manifold - With 9.8 PPG Brine Back To Surface Shut In Well And Record Tubing (20 Psi) And Casing (10 Psi) Pressure's - After 2 Minutes Tubing At 200 Psi. And Casing At 210 Psi - Bleed Off Pressure Thru Choke Manifold To Cuttings Tank For 1 Minute Estimated Volume 3 BBlS. - Shut In Well And Record Pressures Same As Before - Repeat Process With Same Results - Shut In Well Calculate Required Kill Weight Fluid - Contact Anchorage Drilling Engineer Phil Smith Regarding Shut In Pressures - Balance Fluid Weight Required 10.4 PPG Raise Brine To 10.5 PPG - Contact lPC Flow Station Regarding Injector lPC-01 07:30 - 11 :30 4.00 WHSUR P DECaMP Weight up surface volume from 9.8 ppg to 10.5 ppg brine. 11 :30 - 17:30 6.00 WHSUR P DECaMP Circulate 10.5 ppg brine at 1 1/2 bpm and 320 psi, maintaining 240 psi on backside. Once turning the corner, maintained 80 psi on drill pipe until 1 0.5 ppgbrine verified at surface. 17:30 - 18:00 0.50 WHSUR P DECaMP Shut in well and verify dead. Monitor for 15 minutes. Tubing and casing 0 psi. 18:00 - 21 :30 3.50 WHSUR P DECaMP Open well. Circulate 10.5 ppg BU at 3 bpm and 340 psi. 21 :30 - 22:00 0.50 WHSUR P DECaMP Monitor well. verify dead. Dry rod TWC (Cameron). 22:00 - 00:00 2.00 WHSUR P DECaMP Bleed pressure off adaptor and control line. Function lock-down screws. NID tree and adapter. Printed: 6/30/2003 1 :50:54 PM ) ) BP . QperationsSummaryReport Page 20f 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From-To Hours Task Code NPT Phase Description of Operations· 6/9/2003 00:00 - 01 :30 1.50 BOPSUR P DECaMP N/U BOPE. 01 :30 - 03:30 2.00 BOPSUR P DECaMP Test BOPE to 250 psi low and 3,500 psi high. Witness of test waived by Chuck Sheave of the AOGCC. 03:30 - 05:00 1.50 BOPSURP DECaMP Pull blanking plug. R/U DSM and pull TWC with DSM lubricator. 05:00 - 06:00 1.00 PULL P DECaMP M/U tubing hanger crossover to landing joint. Screw into tubing hanger. BOLDS. 06:00 - 06:30 0.50 PULL P DECaMP Pull hanger to floor with 125K up weight. Monitor well. Static loss rate 5 bbl per hour. 06:30 - 07:00 0.50 PULL P DECaMP LID tubing hanger 07:00 - 07:30 0.50 PULL P DECaMP R/U casing equipment and Camco spooling unit. 07:30 - 09:30 2.00 PULL P DECaMP LID 4 1/2", 12.6#, L-80, NSCT tubing from 9,280' to 6,694'. 09:30 - 10:00 0.50 PULL P DECaMP LID SSSV. R/D Camco spooling unit. Recovered 59 SS control line bands. 10:00 - 12:00 2.00 PULL P DECaMP LID 41/2",12.6#, L-80, NSCT tubing from 6,694' to 4,008'. Fluid loss for tour 57 bbls. 12:00 - 15:00 3.00 PULL P DECaMP LID 41/2", 12.6#, L-80, NSCT tubing from 4,008'. 15:00 - 16:00 1.00 PULL P DECaMP R/D casing equipment. Install wear bushing. 16:00 - 16:30 0.50 EVAL P DECaMP PJSM. R/U SWS. 16:30 - 18:30 2.00 EVAL P DECaMP RIH with 6.06" Gauge Ring / Junk Basket to 9,271' WLM. POOH. Tight spot at 9,170' on trip out. Worked down and up a couple passes; worked through. 18:30 - 22:30 4.00 DHEQP P DECaMP M/U HES 7" EZSV. RIH with E-line and set EZSV at 9,237' (WLM), 5 feet above a collar. POOH with E-line. 22:30 - 23:00 0.50 DHEQP P DECaMP RID SWS. 23:00 - 00:00 1.00 DHEQP P DECaMP P/U 6 1/4" drill collar and MIU HES 9 5/8" RTTS. Fluid loss for tour 39 bbls. 6/1 0/2003 00:00 - 02:45 2.75 DHEQP P DECaMP Held PJSM - Pick Up (9) - 61/4" Drill Collars And 80 Joints 4" HT40 Drill Pipe To 2,800'. 02:45 - 03:00 0.25 EVAL P DECaMP Hold Pre-Job Safety Meeting - Set Haliburton RTTS At 2,800'. 03:00 - 04:00 1.00 EVAL P DECaMP Pressure Test 9 5/8" Casing Above 2,800' To 3,500 psi For 30 Minutes. Record Test On Circle Chart 04:00 - 05:00 1.00 BOPSURP DECaMP Held PJSM - POOH From 2,800' With 4" Drill Pipe And RTTS To Drill Collars 05:00 - 06:00 1.00 BOPSURP DECaMP Held PJSM - Lay Down Collars And 95/8" Haliburton RTTS - Clear Rig Floor 06:00 - 10:30 4.50 CLEAN P DECaMP Held PJSM - P/U Baker Tie Back Polish Milling Assembly - Pick Up 162 Joints Of 4" Drill Pipe RIH To 5,041' 10:30 - 11 :00 0.50 CLEAN P DECaMP Continue To RIH With 4" Drill Pipe From Mast To 7,568' - Connect Top Drive And Establish Circulation At 3.3 BPM And 180 psi. 11 :00 - 11 :30 0.50 CLEAN P DECaMP Held PJSM - Polish Tie Back Sleeve At 7,579' - Up Weight 135K, Down Weight 130K, Rotating Weight 135K - 70 RPM With 6,700 ftllbs Torque - 3.3 BPM With 180 Psi. - Polish Tie Back To "No Go" Repeat Process (4) Times 11 :30 - 14:30 3.00 CLEAN P DECaMP Circulate Bottoms Up At 11 BPM With 1025 psi. - Shut Down And Prepare To POH - Fluids Out Of Balance - Connect Top Drive And Circulate Additional 1 0 Minutes - Fluids Still Out Of Balance - Mix And Pump Dry Job - Blow Down Surface Equipment 14:30 - 15:30 1.00 CLEAN P DECaMP Held PJSM - POH With Polish Milling Assembly From 7,568' To 3,800' Printed: 6/30/2003 1 :50:54 PM ) ) BP OperätionsSu mmaryReport Page30f 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From - To Hours Task Code ··NPT Phase Descri ptionof Operations 6/10/2003 15:30 - 16:30 1.00 CLEAN P DECaMP Held PJSM - Slip And Cut 100 Feet 1 1/4" Drilling Line 16:30 - 17:00 0.50 CLEAN P DECaMP Held PJSM - Service Can-Rig Top Drive And Traveling Blocks 17:00 - 18:30 1.50 CLEAN P DECaMP Held PJSM - Continue To POH With 4" Drill Pipe - Service Break Baker Polish Mill And Lay Down Same - Clear Rig Floor 18:30 - 19:30 1.00 BOPSUR P DECaMP Held PJSM - Remove Variable Rams In Top BOP Gate And Change To 7" 19:30 - 20:00 0.50 BOPSUR P DECaMP Held PJSM - Test 7" Rams At 250 psi. (Low) And 3,500 psi. (High) - Rig Down Testing Equipment 20:00 - 21 :00 1.00 CASE P TIEB1 Held PJSM - Rig Up Casing Tools And Equipment 21 :00 - 00:00 3.00 CASE P TIEB1 Held PJSM - Pick Up And Run 7" Scab Liner Per Well Program - Pick Up Tie Back Seal Assembly And Locator, Pup Joint With Orifice Float Collar, 1 Joint With Landing Collar Insert - Verify That Casing Filling While Running In Hole - RIH With 56 Joints 7" L-80 26 lb. Casing With Right Hand Turbolators Every Other Joint (Floating Full Length) 6/11/2003 00:00 - 02:30 2.50 CASE P TIEB1 Held PJSM - RIH With 119 Joints 7" L-80 BTC- Mod 26 lb. Casing With Right Hand Turbolators Every Other Joint (Floating Full Length) - Make Up To The Diamond Torque At 7,000 ftllbs *NOTE* - 7" (26 Ib) Liner Top From 2,689' To 7,579' Top Of Tie Back Sleeve Tied Into 7" (29 Ib) Tie Back Sleeve From 7,579' To 7" EZSV Located At 9,232' 02:30 - 03:00 0.50 CASE P TIEB1 Held PJSM - Change Elevators - Pick Up Baker Running Tool, ZXP Packer, Liner Hanger And Verify Wiper Plug With Out Latch Installed - Change Elevators - Install Cross Over And Pick Up Space Out Pup Joint - RIH With (1) Stand 4" Drill Pipe - Rig Down Casing Tools And Equipment - Clear Rig Floor 03:00 - 03:30 0.50 CASE P TIEB1 Circulate Liner Volume At 12.4 BPM With 273 psi.- Liner When Full Up Weight At 140K And Down Weight At 135K - Blow Down Top Drive 03:30 - 04:15 0.75 CASE P TIEB1 Held PJSM - RIH With 4" Drill Pipe From Mast To 7,572' - Lay Down Single Of 4" Drill Pipe 04:15 - 04:30 0.25 CASE P TIEB1 Held PJSM - Make Up Baker Plug Dropping Head - Rig Up Circulating Lines 04:30 - 05:00 0.50 CASE P TIEB1 Establish Circulation - Shut Down Mud Pumps - Sting Into Tie Back Sleeve With Seal Assembly - Pump Down Casing And Drill Pipe - Pressure Up To 1,100 Psi. - Verify Seals And Circulation Ports Stung Into Tie Back Sleeve - Bleed Off Pressure And Unsting Pick Up 4' To Clear Ports 05:00 - 06:00 1.00 CASE P TIEB1 Circulate At 2 BPM With 100 Psi. - Hold Pre-Job Safety Meeting Regarding Cementing Operation - Prime Up Dowell Schlumberger Cementing Unit 06:00 - 07:30 1.50 CEMT P TIEB1 Swap Over To Dowell - Pump 5 BBL. Water - Test Surface Lines And Equipment To 4,500 Psi. - Bleed Off Pressure - Pump 30 BBLS 11.5 PPG Mud Push - 102 BBLS. 13.5 PPG Lead Slurry - 49 BBLS 15.8 PPG Tail Slurry - Drop Dart And Kick Out With 10 BBLS Fresh Water - Turn Over To Rig For Displacement - Displace With 201 BBLS 10.5 PPG Brine At 10 BPM - Bump Plug With No Excess Pressure - Cement In Place At 07:30 Hours - Slack Off To "No Go" With Seals - Check Floats (OK) - Increase Pressure And Set Hanger With 3,200 Printed: 6/30/2003 1 :50:54 PM ) ) BP Operations· SÜnlnlCi ry. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Page 4 oftS Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Psi. Continue To Increase Pressure To 4,200 Psi. Setting ZXP Liner Top Packer - Rotate 15 Turns To The Right And Release From Liner Pressure Up To 1,000 Psi. - Unsting Cups And Circulate Bottoms Up At 12 BPM With 2,240 Psi. - 58 BBLS. Contaminated Mud Push And Cement Back To Surface Held PJSM - Rig Down Circulating Lines And Lay Down Baker Cementing Head - Clear Rig Floor Held PJSM - POH With 4" Drill Pipe And Liner Running Tool Held PJSM - Lay Down Baker Running Tool - Clear Rig Floor Held PJSM - Pull Wear Ring And Install Test Plug - Change Rams In Top BOP Gate To 31/2" X 6" Variables - Rig Up Testing Equipment And Test Upper Rams To 250 Psi. Low And 3,500 Psi. High - Install Wear Ring And Energize Held PJSM - Pick Up BHA And Make Up Clean Out Assembly To 1,066' Held PJSM - Change Out Handling Equipment - Pick Up And Rabbit 4" Drill Pipe From 1,066' To 5,274' Held PJSM - RIH With 4" Drill Pipe From 5,274' To 7,320' Held PJSM - Connect Top Drive And Establish Circulation - Shut Down And Close BOP Equipment - Pressure Test Casing At 3,500 Psi. For 15 Minutes (Test Good) Held PJSM - RIH From 7,320' To 7,455' - Drill Cement Stringers From 7,455' To 7,548' Drill Liner Wiping Plug At 7,548' - Landing Collar At 7,555' - Orifice At Float Collar At 7,558' Held PJSM - RIH With 4" Drill Pipe From 7,558' To 9,232' Tag EZSV - Set Down 30K On EZSV - Push Junk From 7,558' To 7,750' Held PJSM - Displace Well Bore To 8.7 PPG Quick Drill Mud System At 7 BPM With 1,190 Psi. - Up Weight 175K, Down Weight 160K, Rotating Weight 170K, Torque 4,000 ftllbs Held PJSM - Test Casing And Liner Top Packer To 3,500 Psi. For 30 Minutes (Test Good) Held PJSM - Pump Dry Job - Blow Down Top Drive - POH With 4" Drill Pipe From 9,232' To 1,066' Held PJSM - Lay Down BHA - Clear And Clean Rig Floor Held PJSM - Pick Up Whipstock And Milling Assembly - Make Up MWD Tools And Initialize - Surface Test MWD Equipment At 5 BPM With 340 Psi. Held PJSM - RIH With Whipstock And Milling Assembly On 4" Drill Pipe From 488' To 9,200' - Establish Circulation Every 3,000' While Tripping In Hole Connect Top Drive - - Record Slow Pump Rates - Orient Tool Face Straight Up (360 Degrees) - Slack Off And Tag EZSV At 9,232' - Trip Bottom Anchored Whipstock - Pick Up And Verify Whipstock Set - Shear Bolt With 35K Down Weight WEXIT Mill 6" Window And Formation From 9,214' To 9,228' - String Weight Up 175,000#, String Weight Down 160,000#, String Rotating Weight 170,000#, Pump Rate 275 GPM, 1,430 Psi. RPM 100, Torque 3,700 ft /Ibs - 4,290 ftllbs. Milled Window in 7" Casing from 9,214' - 9,226', WOM 5,000# - 28,000#, RPM 100 - Observed Cement And Sand At Shakers While Milling At Date· From-To Hours Task Code NPT 6/11/2003 06:00 - 07:30 1.50 CEMT P TIEB1 07:30 - 08:30 1.00 CEMT P TIEB1 08:30 - 09:00 0.50 CEMT P TIEB1 09:00 - 10:00 1.00 BOPSUR P TIEB1 10:00 - 10:30 0.50 BOPSURP TIEB1 10:30 - 13:00 2.50 BOPSURP TIEB1 13:00 - 15:00 2.00 BOPSURP TIEB1 15:00 - 18:00 3.00 BOPSURP TIEB1 18:00 - 19:00 1.00 BOPSUR P TIEB1 19:00 - 19:30 0.50 BOPSUR P TIEB1 19:30 - 20:00 0.50 DRILL P TIEB1 20:00 - 22:30 2.50 DRILL P TIEB1 22:30 - 00:00 1.50 DRILL P TIEB1 6/12/2003 00:00 - 01 :45 1.75 DRILL P TIEB1 01 :45 - 02:30 0.75 EVAL P TIEB1 02:30 - 05:30 3.00 DRILL P TIEB1 05:30 - 07:00 1.50 DRILL P TIEB1 07:00 - 09:30 2.50 STWHIP P WEXIT 09:30 - 15:00 5.50 STWHIP P WEXIT 15:00 - 15:30 0.50 STWHIP P WEXIT 15:30 - 22:30 7.00 STWHIP P Descri ption· of Operations Printed: 6/30/2003 1 :50:54 PM ) ) Þage50f 15 ..BP ·Operations SlJl11l11ary Repe>rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From... To Hours Task Code NPT Description of Operations 6/12/2003 15:30 - 22:30 7.00 STWHIP P WEXIT 9,228' - Unable To Make Any Hole With Current Milling Assembly - Pull Aboove Whipstock Ramp *NOTE*: Top Of Window 9,214' Bottom Of Window 9,226' WEXIT Circulate Rest Of Sweep Out Of The Hole - Pump Dry Job - Blow Down Top Drive WEXIT Held PJSM - POH With 4" Drill Pipe From 9,228' To 8,401' RREP WEXIT Held PJSM - Secure Well With Full Opening Safety Valve - Circulate Across Top Of Hole With Trip Tank Pump - Lock And Tag Out Drawworks - Clean Commentator And Replace 752 Traction Motor Brushes Held PJSM - Continue To POH With Window Milling Assembly No.1 On 4" Drill Pipe From 8,401' To 1,117' Held PJSM - Stand Back 3 1/2" HWDP And 4 3/4" Drill Collars Held PJSM - Down Load MWD Tool Data - Lay Down MWD Tool, UBHO Sub, Lower String Mill, And Starter Mill Held PJSM - Make Up Window Milling Assembly NO.2 - Pick Up Starter Mill, And Bit Sub - RIH With Upper String Mill, 3 1/2" HWDP, And 4 3/4" Drill Collars From Mast - Pick Up Drilling Jars And Cross Over To 1,088' WEXIT Held PJSM - RIH With Milling Assembly NO.2 On 4" Drill Pipe From 1,088' To 9,214' WEXIT Held PJSM - Connect Top Drive And Establish Circulation - Ream Slide Area And New Hole From 9,214' To 9,228' - Mill New Hole From 9,228' To 9,233' - String Weight Up 175,000#, String Weight Down 160,000#, String Rotating Weight 170,000#, Pump Rate 275 GPM, 1,430 Psi. RPM 100, Off Bottom Torque 4,000 ft /Ibs, - On Bottom Torque 6,000 ft /Ibs, WOM 5,000# - 25,000#, RPM At 120 22:30 - 23:00 0.50 STWHIP P 6/13/2003 23:00 - 00:00 00:00 - 01 :00 1.00 STWHIP P 1.00 STWHIP N 01 :00 - 04:00 3.00 STWHIP P WEXIT 04:00 - 04:30 0.50 STWHIP P WEXIT 04:30 - 05:00 0.50 STWHIP P WEXIT 05:00 - 06:00 1.00 STWHIP P WEXIT 06:00 - 09:00 3.00 STWHIP P 09:00 - 12:00 3.00 STWHIP P 12:00 - 13:30 1.50 STWHIP P WEXIT 13:30 - 17:00 3.50 STWHIP P WEXIT 17:00 - 18:30 1.50 STWHIP P WEXIT 18:30 - 19:00 0.50 STWHIP P WEXIT 19:00 - 19:30 0.50 BOPSUR P PROD1 19:30 - 21 :00 1.50 BOPSURP PROD1 *NOTE*: Top Of Window 9,214' And Bottom Of Window 9,226' Recovered 95 Ibs Of Metal During Window Milling Operation Circulate Sweep Around At 9,233' - 6.5 BPM With 1,430 Psi. Held PJSM - POH With Window Milling Assembly NO.2 From 9,233' To 1,088' Held PJSM - Lay Down 3 1/2" HWDP, 4 3/4" Drill Collars, Drilling Jars, Float Sub, (1) Joint 31/2" HWDP, Upper String (In Gauge) And Starting Mill - Clear Rig Floor Held PJSM - Pick Up Johnny Wacker Mixing Sub - Connect Top Drive - Circulate And Flush BOP Stack - Function Rams And Reflush - Lay Down Flushing Tool Held PJSM - Pull Wear Bushing - Install Cameron Test Plug - Rig Up Testing Equipment Held PJSM - Fill BOP Equipment With Water - 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, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test Printed: 6/30/2003 1 :50:54 PM ) ) page.6of·15 BP OperationsSumrrïaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From;.. To Hours Task Code NPT· PROD1 Held PJSM - Rig Down BOP Testing Equipment - Pull Cameron Test Plug - Install Wear Bushing And Energize - Lay Down Test Joint And Clear Rig Floor PROD1 Held PJSM - Pick Up Directional Drilling Assembly BHA - Orient Mud Motor And MWD - Pick Up Bit NO.1 - Initalize MWD Tools And Surface Test At 6 BPM With 760 Psi. - Disconnect Head Pin And Blow Down Circulating Lines - Wash Off Rig Floor Held PJSM Regarding Loading Radioactive Sources - Load Source And Lower Below Ground Level - Continue To Pick Up 6" Directional Drilling Assembly From 131' To 226' Held PJSM - RIH With Directional BHA From 226' To 9,000' - Fill Drill String Every 3,000' Held PJSM - Slip And Cut 1 1/4" Drilling Line - Service Top Drive And Traveling Blocks Held PJSM - Madd Pass Tie In Log From 9,000' To 9,233' Per Geologist - Connect Top Drive At 9,164' And Establish Circulation Orient Motor To 360 Degrees (Straight Up) And Slide Thru Window From 9,214' To 9,226' - Continue To Slack Off Thru 6 1/16" Hole To 9,229' PROD1 Wash And Ream 5 5/8" Under Gauge Hole From 9,229' To Bottom At 9,233' PROD1 Drilled 6" Directional Hole By Sliding From 9,233' To 9,246' WOB Sliding 2,000# To 5,000#, Motor RPM 288, On Bottom Torque 5,000 ft /Ibs, Pump Rate 275 gpm, SPP Off Bottom 1,680 psi, On Bottom 1,800 psi. String Weight Up 170,000#, String Weight Down 150,000#, String Weight Rotating 160,000# - ART = 0 hrs, AST = 2.0 hrs. PROD1 Hold Pre-Job Safety Meeting - Preform FIT To 9.5 PPG EMW 6/13/2003 0.50 BOPSUR P 21 :00 - 21 :30 21 :30 - 00:00 2.50 DRILL P 6/14/2003 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 03:00 2.50 DRILL P PROD1 03:00 - 04:30 1.50 DRILL P PROD1 04:30 - 05:30 1.00 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P 06:00 - 08:30 2.50 DRILL P 08:30 - 09:00 0.50 DRILL P Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 4 40 psi 9 60 psi 13 250 psi 16 390 psi Held Test F/1 0 minutes wf1 0 Psi. Pressure Loss. MW 8.7 ppg, Csg Window Top TVD 8,504' Pressure 390 psi = 9.58 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams PROD1 Drilled 6" Directional Hole By Rotating And Sliding From 9,246' To 9,462' WOB Rotating 2,000# - 7000#, WOB Sliding 2,000# To 5,000#, RPM 60, Motor RPM 288, Torque Off Bottom 4,000 ft /Ibs To 6,000 ft /Ibs - On Bottom 6,000 ft fibs To 7,000 ftllbs, Pump Rate 275 gpm, SPP Off Bottom 1,680 psi, On Bottom 1,800 psi. String Weight Up 170,000#, String Weight Down 150,000#, String Weight Rotating 160,000# ART = 1.60 hrs, AST = 5.3 hrs. 09:00 - 00:00 15.00 DRILL P Lithologies encountered 6/14/03 9234-9250 (Zone 2B Sand) Pred fine to medium grained Printed: 6/30/2003 1 :50:54 PM ) ) BP Qperations··.Surn>mary Report Page Tof 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From ;'To Hours Task Code NPT 6/14/2003 09:00 - 00:00 15.00 DRILL P PROD1 sand, clean, disaggregated, well sorted and and poorly cemented quartz sand. Mineral flu only, no visible o/stn. Persistent difficulty sliding, averaging 10-20'/hr, rotating averaging 50'/hr +. 9250-9315 Zone 2 Sd (25P) Pred fine to med gr sand, with abdt (20-40%) angular chert fragmts. Poorly sorted, clean, locally with light tan pyritic siltstone interbeds. Motor stalling with higher WOB, making sliding difficult. ROP while rotating averaging 50-100'/hr. Logs indicate clean sands, with GR averaging 20 API. Elevated resistivities of 100+ ohms indicative of gas. 9315-9330 Zone 2 (24N) Predominantly light tannish brown siltstone with minor interbedded sand. Siltstone is locally pyrite rich. 9330-78 Zone 2 (24P) Predominately chert rich sand, poorly sorted, locally tightly cemented with common interbedded siltstone, as above. Chert is variable in color, consists entirely of angular fragments, suggestive of lag gravel sands. Persistent slow progress while sliding to build angle, averaging 20'/hr. 9378-9422 Zone 2 (23N/P) Fine to medium grained sands with locally abundant chert and minor siltstone. Irregular ROP as above, slowed by chert rich beds. Sands remain clean, 20-30 API on GR, and gas productive. 9422-60 Zone 2 (22P) Fine to medium grained sand, slightly decreasing amounts of chert, with locally abundant light tan siltstone beds. ROP in excess of 1 OO'lhr while rotating, erratic ROP while sliding. 6/15/2003 00:00 - 04:00 4.00 DRILL P PROD1 Drilled 6" Directional Hole By Rotating And Sliding From 9,462' To 9,512' - WOB Rotating 2,000# - 7000#, WOB Sliding 2,000# To 5,000#, RPM 60, Motor RPM 288, Torque Off Bottom 4,000 ft Ilbs To 6,000 ft Ilbs - On Bottom 6,000 ft Ilbs To 7,000 ftllbs, Pump Rate 275 gpm, SPP Off Bottom 1,680 psi, On Bottom 1,800 psi. String Weight Up 170,000#, String Weight Down 150,000#, String Weight Rotating 160,000# 04:00 - 04:30 0.50 DRILL P Drilled Below 8,702' TVD In Order To Get Into Clean Sand In Hopes That ROP Would Increase - ROP Slowed To 10 To 15 Feet Per Hour And Motor Continued To Stall With 4,000 WOB - Prepare To POH PROD1 Held PJSM - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive PROD1 Held PJSM - POH With Directional Drilling Assembly From 9,512' To 9,200' (Above Whipstock) - Monitor Well Bore (Static) - Continue To POH With 4" Drill Pipe From 9,200' To BHA - Stand Back 31/2" HWDP And 4 3/4" Drill Collars To 228' 04:30 - 07:00 2.50 DRILL P Printed: 613012003 1 :50:54 PM ) ') BP Operations Summary :Report Page80f15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 618/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From"To Hours Task Code NPT Phase 6/15/2003 07:00 - 09:00 2.00 DRILL P PROD1 Desc:ription of Operations 09:00 - 10:30 1.50 DRILL P Held PJSM Regarding Removing Radioactive Sources - Remove Source's And Down Load Data From MWD/LWD Tools - Remove Smith 6" PDC Bit And Lay Down 4 3/4" Sperry Mud Motor - Clear Rig Floor PROD1 Held PJSM - Pick Up New 4 3/4" Sperry Mud Motor And 6" Security FM2631 PDC Bit - Make Up MWD Tools And Orient- Initialize MWD/LWD Tools And Surface Test - Held PJSM Regarding Loading Radioactive Sources - Load Source's And Lower Below Ground Level - Continue To RIH With 6" Directional Drilling Assembly From 131' To 228' PROD1 Held PJSM - RIH With Directional BHA From 228' To 9,192' - Fill Drill String Every 3,000' - Establish Circulation Orient Motor To 360 Degrees And Slide Thru Window From 9,214' To 9,226' - RIH To 9,471' - Circulation As Precaution Wash To Bottom At 9,512' PROD1 Drilled 6" Directional Hole By Rotating And Sliding From 9,512' To 9,811' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 14,000#, RPM 60, Motor RPM 280, Torque Off Bottom 5,000 ft Ilbs To 6,000 ft Ilbs - On Bottom 4,000 ft Ilbs To 5,000 ftllbs, Pump Rate 267 gpm, SPP Off Bottom 1,690 psi, On Bottom 2,000 psi. String Weight Up 175,000#, String Weight Down 145,000#, String Weight Rotating 160,000# ART = .50 hrs, AST = 4.9 hrs. 10:30 - 14:00 3.50 DRILL P 14:00 - 00:00 10.00 DRILL P 00:00 - 0.00 DRILL P PROD1 Lithologies encountered 6/15/03 9460-82 Zone 2 (22P) Fine to medium grained sand, slightly decreasing amounts of chert, with locally abundant light tan siltstone beds. ROP in excess of 1 OO'Ihr while rotating, erratic ROP while sliding. 9482-9584 Zone 1 B Fine to coarse grained sand with decreasing amounts of chert fragments. Locally abundant light tanish brown siltstone. Sands are moderately sorted, clean, disaggregated with poor to no visible oil shows. Common mineral fluorescence only (calcite mud additive). Logs indicate clean sands with GR showing 20-30 API, and high resistivities indicative of gas. With new bit and motor at 9512 MD, ROP's increased significantly, averaging 50-60'/hr while sliding to build angle. 9584-9800 Zone 1A TDF Predominantly very fine to fine sand and siltstone. Sands are generally clean, well sorted and disaggregated. Localized chert was encountered at 9700 MD with no apparent affect on ROP. Minor interbedded light tan siltstone present in thin beds. From 9750-9800, thin beds of coal/carbonaceous shale were encountered. Coal was black, brittle, with a conchoidal fracture and produced anomalously high GR spikes. Sands are commonly stained with light brown oil staining and yield a weak, diffuse cut fluorescence. A decrease in resistivity below 9630 (8715 TVDSS) indicates a tentative PGOC pick. As well landed at 9800, indications of proximal BSAD lithology affecting logs (increasing GR, Printed: 6/30/2003 1 :50:54 PM ) ) BP ·OperatiònsSum maryRE!Port Page90f 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From -To Hours Task Code NPT Phase Description of Operations 6/15/2003 00:00 - 0.00 DRILL P PROD1 decreasing lithology). Now Commence sliding to invert wellbore. 6/16/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drilled 6" Directional Hole By Rotating And Sliding From 9,811' To 10,572' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 14,000#, RPM 60, Motor RPM 280, Torque Off Bottom 5,000 ft Ilbs To 6,000 ft Ilbs - On Bottom 7,000 ft /Ibs To 8,000 ftllbs, Pump Rate 267 gpm, SPP Off Bottom 1,650 psi, On Bottom 2,050 psi. String Weight Up 175,000#, String Weight Down 135,000#, String Weight Rotating 160,000# Lithologies encountered 6/16/03 9800-9860 Possible healed fracture zone, Proximal BSAD/Kavik. Abundant calciteldolomite in samples. Anomalously high deep resistivity. Erratic Rap while sliding to invert wellbore. No mud losses, no sign of Kavik lithology in samples despite elevated GR (100+ API). 9860-10255 Zone 1A, (Inverted wellbore) Predominantly very fine to fine grained sand with minor siltstone and thin coals/carbonaceous shales. Sands are clean and vf-fgr , clean, disaggregated and well sorted, with good oil staining and fluorescence. Minor interbedded light tan siltstone present in thin beds. GR averaging 50-60 API, resistivity averages 100-200 ohms. Interval drilled well while sliding and rotating averaging 50-100'/hr, although slides failed to revert the wellbore. 10255-10420 TDF Well reverted in clean sand, very fine to medium grained, disaggregated with clean GR (30 API) and high resistivity (1000 ohms+). Sand was commonly oil stained and showed faint fluorescence. Erratic ROP's drilling this interval as a result of continuous sliding to drop inclination and roll over wellbore. 10420-10550 Zone 1A Predominantly sand and siltstone. Sands are fine to very fine grained, well cemented and tight in uppermost portion of interval, becoming increasingly friable to disaggregated with depth. Several siltstone beds in uppermost part of interval. Siltstones are light tan to medium gray, firm, blocky to platey. Overall GR renging from 50-70 API, resistivities decreasing from 30-12 ohms. Good oil shows in samples. Interval drilled well, averaging 80-1 OO'/hr while sliding to land well 15-20' below base of TDF. 6/17/2003 00:00 - 13:30 13.50 DRILL P PROD1 Drilled 6" Directional Hole By Rotating And Sliding From 10,572' To 10,871' WOB Rotating 5,000# -10,000#, WOB Sliding 5,000# To 14,000#, RPM 60, Motor RPM 280, Torque Off Bottom 5,000 ft Ilbs To 6,000 ft Ilbs - On Bottom 7,000 ft I Ibs To 8,000 ftllbs, Pump Rate 267 gpm, SPP Off Bottom 1,650 psi, On Bottom 2,050 psi. String Weight Up 175,000#, String Weight Down 135,000#, String Weight Rotating Printed: 6/30/2003 1 :50:54 PM ) ) BP Oper~ti()I1$Sul1'lmaryReport Page. 10 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date From -To Hours Task Code NPT Phase Description of Operations 6/17/2003 00:00 - 13:30 13.50 DRILL P PROD1 160,000# Actual Slide Time = 5.66 Hours - Actual Rotating Hours = .45 Hours 13:30 - 15:00 1.50 DRILL P PROD1 Held PJSM - Circulate Bottoms Up At 10,871' At 6 BPM With 1,720 Psi. - Monitor Well Bore (Static) 15:00 - 16:00 1.00 DRILL P PROD1 Held PJSM - POH From 10,871' To 9,189' (No Problem) 16:00 - 17:00 1.00 DRILL P PROD1 Held PJSM - Service Top Drive, Traveling Blocks, And Crown Sheaves 17:00 - 17:30 0.50 DRILL P PROD1 Held PJSM - RIH From 9,189' To 10,871' (No Problem) 17:30 - 20:30 3.00 DRILL P PROD1 Drilled 6" Directional Hole By Rotating And Sliding From 10,871' To 10,927' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 14,000#, RPM 60, Motor RPM 280, Torque Off Bottom 5,000 ft Ilbs To 6,000 ft Ilbs - On Bottom 7,000 ft I Ibs To 8,000 fUlbs, Pump Rate 277 gpm, SPP Off Bottom 1,750 psi, On Bottom 2,020 psi. String Weight Up 175,000#, String Weight Down 140,000#, String Weight Rotating 160,000# Actual Slide Time = 1.38 Hours - Actual Rotating Hours = 0 Hours Lithologies Encountered 6/17/03 10550-10620 Zone 1A Predominantly sand and siltstone. Sands are fine to very fine grained, increasingly well cemented and tight. Siltstones are light tan to medium gray, firm, blocky to platey. Overall GR ranging from 50-60 API, resistivities averaging 120 ohms. Good oil shows in samples. Interval drilled well, averaging 80-1 OO'/hr while sliding to land well 15-20' below base ofTDF. 10620-10745 BSAD Predominantly brown shale and tight sand. Shale is platey, slightly to very sandy and silty, and very firm. Sands are fine to very fine grained, well cemented, tight, and locally argillaceous. Encountered difficulty maintaining toolface while sliding up to reenter targeted interval. Fault at 10425 cut out significant overlying 1A section, causing well to enter BSAD. 10745-10927 Zone 1A Predominantly sand and siltstone. Sands are fine to very fine grained, increasingly friable to disaggregated. Siltstones are light tan to medium gray, firm, blocky to platey. Overall GR ranging from 40-60 API, resistivities gradually increasing from 120-300 ohms. Good oil shows in samples. Interval drilled erratically, averaging 20-50'/hr while sliding to turn well down to follow targeted interval. Inability to drop angle caused trip at 10927 for new BHA. 20:30 - 22:00 1.50 DRILL P PROD1 Circulate High Vis-Sweep Around At 6.5 BPM With 1,750 Psi. - Monitor Well Bore (Static) 22:00 - 00:00 2.00 DRILL P PROD1 Held PJSM - POH With Directional Drilling Assembly From 10,927' To 9,183' (No Problem) - Monitor Well Bore (Static)- Pump Dry Job - Blow Down Top Drive - POH From 9,183' To Printed: 6/30/2003 1 :50:54 PM ) ) BP Operation$Sul11.maryReport Page 11 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date. From.~ To Hours Task Code NPT Phase Description of Operations 6/17/2003 22:00 . 00:00 2.00 DRILL P PROD1 7,698' 6/18/2003 00:00 - 02:30 2.50 DRILL P PROD1 Held PJSM - POH With Directional Drilling Assembly From 7,698' To 228' 02:30 - 04:30 2.00 DRILL P PROD1 Held PJSM Regarding Removing Radioactive Sources - Remove Source's And Down Load Data From MWDILWD Tools - Lay Down Nuke Tools - Remove Security 6" PDC Bit And Lay Down 4 3/4" Sperry Mud Motor - Clear Rig Floor 04:30 - 06:30 2.00 DRILL P PROD1 Held PJSM - Pick Up New 4 3/4" Sperry (Slow Speed) Mud Motor With Inc. At Bit - Change Bend To 1.83 AKO - Install 5 7/8" Stab On Motor - Make Up 6" Smith XR20 Insert Bit - Make Up MWD Tools And Orient - Initialize MWDILWD Tools And Surface Test - Continue To RIH With 6" Directional Drilling Assembly From 89' To 210' 06:30 - 10:30 4.00 DRILL P PROD1 Held PJSM . RIH With Directional BHA From 210' To 10,927' - Fill Drill String Every 3,000' - Establish Circulation Orient Motor To 360 Degrees And Slide Thru Window From 9,214' To 9,226' - Work Thru Hard Section At 9,601'· RIH From 9,601' To 10,853' - As Precaution Wash To Bottom At 10,927' 10:30 - 00:00 13.50 DRILL P PROD1 Drilled 6" Directional Hole By Rotating And Sliding From 10,927' To 11,185' WOB Rotating 5,000# - 10,000#, WOB Sliding 10,000# To 15,000#, RPM 30 To 55, Motor RPM 89, Torque Off Bottom 4,000 ft Ilbs To 5,000 ft Ilbs - On Bottom 6,000 ft Ilbs To 8,000 ftllbs, Pump Rate 270 gpm, SPP Off Bottom 2,020 psi, On Bottom 2,150 psi. String Weight Up 175,000#, String Weight Down 135,000#, String Weight Rotating 160,000# Actual Slide Time = 2.74 Hours - Actual Rotating Hours = 3.26 Hours Lithologies encountered 6/18/03 10927-11200 Zone 1A Predominantly sand, minor siltstone and coal. Sands are clear, light brown to light gray in color, very fine to fine grained, well sorted, locally tightly cemented, tho overall disaggregated or friable, clean, and well sorted, with uniform light brown oil staining and fluorescence. Siltstones are light tan to light gray, commonly sandy and firm. Coal appears present in thin beds, and locally disseminated within the sand. ROP remaining steady at 30-50'/hr, whether rotating or sliding to remain within targeted interval. Sands range from 40-60 API on GR, resistivities of 100-300 ohms in clean sand. 6/19/2003 00:00 - 22:30 22.50 DRILL P PROD1 Drilled 6" Directional Hole By Rotating And Sliding From 11,185' To 11,823' WOB Rotating 5,000# - 10,000#, WOB Sliding 10,000# To 15,000#, RPM 30 To 55, Motor RPM 89, Torque Off Bottom 4,000 ft Ilbs To 5,000 ft Ilbs - On Bottom 6,000 ft Ilbs To 8,000 ftllbs, Pump Rate 270 gpm, SPP Off Bottom 2,020 psi, On Bottom 2,190 psi. String Weight Up 175,000#, String Weight Down 130,000#, String Weight Rotating 155,000# Actual Slide Time = 2.19 Hours - Actual Rotating Hours = 14.86 Hours Printed: 6/30/2003 1 :50:54 PM ) ) ··BP o perations·SUmrnary ··Re port Page 120f15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Date·· From- To Hours Task Code ·NPT Phase Descri ptionof Operations 6/19/2003 00:00 ~ 22:30 22.50 DRILL P PROD1 Lithologies Encountered 6/19/03 11200-11415Zone 1A Predominantly sand, minor siltstone and coal. Sands are clear, light brown to light gray in color, very fine to fine grained, well sorted, locally tightly cemented, tho overall disaggregated or friable, clean, and well sorted, with uniform light brown oil staining and fluorescence. Siltstones are light tan to light gray, locally a tannish white, commonly sandy and firm. Coal appears present in thin beds, and locally disseminated within the sand. ROP remaining steady at 30-50'/hr, whether rotating or sliding to remain within targeted interval. Sands range from 40-60 API on GR, resistivities of 100-300 ohms in Clean sand. 11415-11823 Zone 1A Interbedded Sandstone, increasing Siltstone, minor Coal. Sands remain very fine to fine grained, commonly silty, clean to slightly shaley, commonly well cemented but overall friable, well sorted, locally carbonacelus with uniform light to medium brown oil staining and faint yellow fluorescence. GR averages 40-60 API in sand section. Siltstones are increasingly light gray, commonly tannish brown or white to light tan, locally sandy and/or carbonaceous, and quite firem and platey. GR in siltier zones ranges from 70-120 API. Coal is black, blocky with a vitreous luster, and commonly pyritic, appears commonly disseminated in sands and siltstones, but probably occurs in thing beds also. Probably indicated by zones of high GR (>100 API) and lower resistivity (40-60 ohms). ROP averaging 40-50'/hr in sands, 15-20'/hr while rotating in siltstone intervals. 22:30 - 00:00 1.50 DRILL P PROD1 Circulate Hi-Vis Sweep Around While Rotating And Reciprocating Drill String - 6.5 BPM With 2,210 Psi. 6/20/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Monitor Well Bore (Static) - POH From 11,823' To 9,196' (Wet) - Lay Down 5 Joints 4" Drill Pipe Normal Upward Drag On Trip To Window At 185K To 190K - Tight From 11,670' To 11,255' - 20K To 45K Above Normal Drag 01 :30 - 02:00 0.50 DRILL P PROD1 Wash Off Rig Floor - Monitor Well Bore (Static) 02:00 - 03:00 1.00 DRILL P PROD1 Held PJSM - Slip And Cut 1 1/4" Drilling Line 03:00 - 03:30 0.50 DRILL P PROD1 Held PJSM - Service Top Drive And Traveling Blocks 03:30 - 04:30 1.00 DRILL P PROD1 Held PJSM - RIH From 9,196' To 11,724' - Normal Drag At 145K - 20K To 30K Additional Drag At 10,700' And 11,601' - Wash Last Stand To Bottom 11,823' 04:30 - 07:00 2.50 DRILL P PROD1 Circulate Hi-Vis Sweep Around While Rotating And Reciprocating Drill String - 6.5 BPM With 2,210 Psi. - Spot Liner Running Pill - Monitor Well Bore (Static) 07:00 - 09:00 2.00 DRILL P PROD1 Held PJSM - POH Laying Down 4" Drill Pipe (Wet) From 11,823' To 9,189' - No Problems On Trip Out To Window 09:00 - 10:00 1.00 DRILL P PROD1 Drop Dart And Shear Open Pump Out Sub ~ Circulate Bottoms Up At 12 BPM With 1,690 Psi. - Monitor Well Bore (Static)- Pump Dry Job - Drop 23/8" Rabbit - Blow Down Top Drive 1 0:00 - 13:30 3.50 DRILL P PROD1 Held PJSM - POH With Directional BHA From 9,189' To 210' 13:30 - 16:00 2.50 DRILL P PROD1 Held PJSM - Down Load MWD/LWD Tools - Lay Down 6" Printed: 6/30/2003 1 :50:54 PM ) ') BP OperationsSumrnary RE!port Page 13 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES . Date Fröm~ To Hours Task Code NPT . . Phase 6/20/2003 13:30 - 16:00 2.50 DRILL P PROD1 16:00 - 16:30 0.50 CASE P CaMP 16:30 -19:30 3.00 CASE P CaMP 19:30 - 20:00 0.50 CASE P CaMP 20:00 - 22:30 2.50 CASE P CaMP 22:30 - 23:30 1.00 CASE P CaMP 23:30 - 00:00 0.50 CASE P CaMP 6/21/2003 00:00 - 01 :00 1.00 CASE P CaMP 01 :00 - 01 :30 0.50 CASE N RREP CaMP 01 :45 - 03:30 1.75 CASE P CaMP 03:30 - 04:00 0.50 CASE P CaMP 04:00 - 04:30 0.50 CASE P CaMP 04:30 - 06:00 1.50 CASE P CaMP 06:00 - 07:00 1.00 CASE P CaMP 07:00 - 11 :00 4.00 CEMT P CaMP Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Description of Operations Directional BHA - Clear Rig Floor Held PJSM - Rig Up To Run 4 1/2" Bonzai Liner Held PJSM - Pick Up And RIH With (66) Joints Of Slotted And Solid 4 1/2" IBT-M 12.6 Ib L-80 Liner Held PJSM - Set Low In Rotary Table - Rig Up To Run 2 7/8" Fox Inner String Held PJSM - Pick Up And RIH With Baker Cup Inflation Tool Assembly And (52) Joints Of 2 7/8" Fox 6.4 Ib Tubing Inner String - Pick Up 10' Space Out Pup, And Cross Over Held PJSM - Change Handling Tools - Pick Up Baker Liner Hanger And ZXP Packer - Make Up To Inner String - Mix Up Thin Block Gel And Allow 30 Minutes Set Up Time Held PJSM - Circulate 4 1/2" Liner Volume At 3 BPM With 180 Psi. *NOTE* 4 1/2" Liner Weight At 30,000 Ibs. - Inner String Weight At 8,000 Ibs. Held PJSM - RIH With 4 1/2" Bonzai Liner On 4" Drill Pipe From 2,770' To 4,730' Held PJSM - Change Out Aero-Union Boots On Bell Nipple RIH With 41/2" Bonzai Liner On 4" Drill Pipe From 4,730' To 9,122' Held PJSM - Pick Up Baker Cementing Head Torque To 18,000 ftllbs - Lay Down Cementing Head And (1) Single Of 4" Drill Pipe Circulate Drill Pipe Volume At 2.8 BPM With 480 Psi. - Up Weight 165,000 Ibs And Down Weight 145,000 Ibs - Blow Down Top Drive Held PJSM - RIH With 4 1/2" Bonzai Liner On 4" Drill Pipe From 9,122' To 11,798' Held PJSM - Pick Up Baker Cementing Head - Install Plug Valve Manifold And Circulating Hose - Pick Up Single Of 4" Drill Pipe - Establish Circulation At 1.2 BPM With 450 Psi. Tag Bottom At 11,823' Held Pre-Job Safety Meeting With All Personal Regarding Cementing Operation - Insert (2) Stage Plug - Swap Over To Dowell Schlumberger Pump 5 BBL Water To Flow Line Pressure Test Surface Lines To 5,000 Psi (Test Good) - Displace (2) Stage Plug To Catcher Sub At 3.0 BPM With 869 Psi Latch Up And Shear Inner String Plug - Displace Inner String Plug To Reverse Plug Catcher - Set Baker Flex-Lock Liner Hanger Slack Off 20,000 Ibs And Verify Hanger Set - Release "HR" Running Tool - Close PPIT And Test To 1,000 Psi - Locate ZXP Position And Verify - Inflate ECP With Cement Unit (Volume To Inflate ECP 1/2 BBL Calculated 1/8 BBL) - Locate HMCV Open With 2,000 Psi. - Establish Circulation 2.9 BPM With 748 Psi. - Batch Mix Cement - Pump 15 BBLS 8.3 PPG CW-100, 25 BBLS 9.6 PPG Mud Push, 41 BBLS (191 Sacks) 15.8 PPG Tail Cement Slurry - Displace With 5 BBLS Water And 85 BBLS 8.7 PPG QuickDril Mud Under Displacing By 1 BBL Final Circulating Pressure 2,182 Psi. - Close HMCV And Bleed Pressure Back To Dowell Verifying HMCV Closed - Cement In Place At 10:29 Hours - Printed: 6/30/2003 1 :50:54 PM ) ) Page 14 of15 BP ()perationsSummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From-To HoLirs Task. Code NPT 6/21/2003 07:00 - 11 :00 4.00 CEMT P Phase COMP 11 :00 - 12:30 1.50 CEMT P COMP 12:30 - 13:00 0.50 CASE P COMP 13:00 - 13:30 0.50 CASE P COMP 13:30 - 15:00 1.50 CASE P COMP 15:00 - 20:30 5.50 CASE P COMP 20:30 - 21 :00 0.50 CASE P COMP 21 :00 - 21 :30 0.50 CASE P COMP 21 :30 - 22:30 1.00 CASE P COMP 22:30 - 23:30 1.00 CASE P COMP 23:30 - 00:00 0.50 BOPSUR P COMP 6/22/2003 00:00 - 02:30 2.50 BOPSUR P COMP 02:30 - 03:00 0.50 BOPSUR P COMP 03:00 - 04:30 1.50 RUNCOIVP COMP 04:30 - 12:30 8.00 RUNCOIVP COMP 12:30 - 14:00 1.50 RUNCOIVP COMP 14:00 - 17:30 3.50 RUNCOIVP COMP 17:30 - 18:30 1.00 RUNCOIVP COMP 18:30 - 19:30 1.00 RUNCOIVP COMP 19:30 - 20:30 1.00 RUNCOIVP COMP Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Test HMCV To 3,250 Psi (Test Good) - Set ZXP Packer With 50,000 Ibs Repeat Process While Rotating - Reverse Circulate 5 BBLS Back To Dowell At 1.9 BPM With 577 Psi. - Pick Up String Above Profiles And Shear Open Drain Sub With 4,356 Psi. Circulate Cement Out Long Way While Reciprocating String With Short Strokes At 9 BPM With 3,100 Psi. - Estimated Cement Back To Surface At 10 BBLS. Held PJSM - Set Down On ZXP Packer And Pressure Test Liner Top At 2,500 Psi. For 10 Minutes (Test Good) Held PJSM - Break Down Circulating Lines - Lay Down Baker Cementing Head And (3) Singles 4" Drill Pipe Held PJSM - Displace Well To 8.6 PPG Seawater At 9 BPM And 3,100 Psi. - Clean Out Surface Equipment Held PJSM - POH Laying Down 288 Joints Of 4" Drill Pipe Held PJSM - Break Down Baker Liner Running Tool Held PJSM - Rig Up Power Tongs And Equipment For 2 7/8" Fox Inner String Held PJSM - Lay Down 2 7/8" Fox Inner String And Baker Cup Inflation Tool Assembly Held PJSM - Rig Down Power Tongs And Equipment - Clear Rig Floor Held PJSM - Pull Wear Bushing And Rig Up BOP Testing Equipment Held PJSM - Fill BOP Equipment With Water - 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, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test Held PJSM - Rig Down BOP Testing Equipment - Pull Cameron Test Plug - Lay Down Test Joint And Clear Rig Floor Held PJSM - Rig Up Single Line Compensator, Power Tongs And Equipment For Chrome Completion Held PJSM - Run 41/2" Completion Per Well Program - Pick Up Tail Pipe Assembly Baker Lock Connections Below Baker S -3 Packer - RIH With (3) Gas Lift Mandrels And 160 Joints 4 1/2" 13 CR80 12.6 lb. Vam Ace Tubing To 6,872' Held PJSM - Pick Up SSSV - Rig Up Haliburton Control Line Spooler - String (2) Control Lines Make Up To Valve And Test To 5,000 Psi. (Test Good) Continue To RIH With 212 Joints 4 1/2" 13 CR80 12.6 lb. Vam Ace Tubing To 9,072' Bottom Of Tie Back Sleeve - Lay Down Joint No. 212 Held PJSM - Rig Down Single Joint Compensator - Make Up Top Drive Saver Valve - Change Elevators - Pick Up Landing Joint And Make Up Cross Overs Held PJSM - Make Up Cameron Tubing Hanger - Install (2) SSSV Control Lines And Test To 5,000 Psi. (Test Good) - 54 Total Stainless Steel Bands Ran On Dual Control Lines Held PJSM - Record Completion String Weights - 127,000 lb. Up And 115,000 lb. Down Land Completion String - Install Printed: 6/30/2003 1 :50:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') BP Operations SUl11l11aryReport 18-03 18-03B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date FrOm ~ To Hours Task Code NPT Phase 6/22/2003 19:30 - 20:30 1.00 RUNCOIVP COMP 20:30 - 23:00 2.50 RUNCOIVP COMP 23:00 - 00:00 1.00 RUNCOIVP COMP 6/23/2003 00:00 - 01 :00 1.00 RUNCOIVP COMP 01 :00 - 01 :30 0.50 RUNCOIVP COMP 01 :30 - 02:30 1.00 BOPSUR P COMP 02:30 - 04:00 1.50 WHSUR P COMP 04:00 - 06:00 2.00 WHSUR P COMP 06:00 - 08:30 2.50 WHSUR P COMP 08:30 - 09:00 09:00 - 10:00 0.50 WHSUR P COMP 1.00 WHSUR P COMP Start: 6/8/2003 Rig Release: 6/23/2003 Rig Number: Spud Date: 7/30/1982 End: 6/23/2003 Descri ptionof· Oþerations . Control And Balance Line Nipples In Hanger Thru Tubing Spool - Test To 5,000 Psi. (Test Good) Held PJSM - Reverse Circulate Clean Sea Water And Corrosion Inhibitor At 3 BPM With 180 Psi Held PJSM - Drop Ball And Rod Allow Time To Get On Seat In RHC-M Plug Located In "XN" Nipple At 9,056' - Pressure Up On Tubing To Set Baker S-3 Packer Continue To Pressure Up To 3,500 Psi. Test Tubing For 30 Minutes (Test Good) Held PJSM - Bleed Tubing Pressure To 1,500 Psi. - Pressure Up Inner Annulus To 3,500 Psi. For 30 Minutes (Test Good) - Bleed Off Tubing Pressure Rapidly And Shear DCK Valve Located In GLM At 3,289' Held PJSM - Install Back Pressure Valve And Test From Below To 1,000 Psi. (Test Good) Held PJSM - Blow Down All Surface Lines And Equipment - Nipple Down BOP And Related Equipment Held PJSM - Nipple Up Tubing Head Adaptor And McEvoy Production Tree Held PJSM - Pull BPV With DSM Lubricator - Install Tree Test Plug - Test Adaptor And Production Tree To 5,000 Psi. (Test Good) - Pull Tree Test Plug - Rig Down DSM Held PJSM - Rig Up Little Red And Test Surface Lines To 2,000 Psi. - Reverse Circulate 155 BBLS Diesel Freeze Protection Down Inner Annulus At 3 BPM - U Tube Diesel Into Tubing Held PJSM - Install BPV - Test From Below To 1,000 Psi (Test Good) Held PJSM - Break Down Surface Equipment - Remove Secondary Annulus Valve - Secure Well Rig Released From Well Work On DS 18-03B At 10:00 Hours On 06/23/2003 Printed: 6/30/2003 1 :50:54 PM ) ) 26-J u n-03 AOGCC -lluward Okland- LIe; ~ we:eV'I"e. 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 18-038 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 9,194.30 I MD Window / Kickoff Survey: 9,214.00 I MD (if applicable) Projected Survey: 11,823.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, éJ.JJ3-b8b ~,p' ;-.' ....~r-.. 'VED .... ~\ --.11 t: g . ' William T. Allen Survey Manager JUL 0 1 2003 Attachment(s) ¡'i.i<Jt,I:,... 'l?'" - ~ liOOs. ~ 1~ /)~-- I ~ ~ ~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 18 18-03B -~/ Job No. AKZZ0002488472, Surveyed: 19 June, 2003 Survey Report 26 June, 2003 Your Ref: API 500292077602 Surface Coordinates: 5960680.25 N, 691604.91 E (70017' 49.6720" N, 148026' 53.8389" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 c._ Surface Coordinates relative to Project H Reference: 960680.25 N, 191604.91 E (Grid) Surface Coordinates relative to Structure Reference: 1465.99 N, 56.78 E (True) Kelly Bushing: 44.65ft above Mean Sea Level Elevation relative to Project V Reference: 44.65ft Elevation relative to Structure Reference: 44.65ft srpa...........y-sul! DRILLiNG·· sERvíé:es A Halliburton Company Survey Ref: svy4060 Sperry-Sun Drilling Services Survey Report for PBU_EOA OS 18 - 18-03B Your Ref: API 500292077602 Job No. AKZZ0002488472, Surveyed: 19 June, 2003 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) (°/1 o Oft) 9194.30 24.560 153.720 8442.38 8487.03 2706.94 8 547.21 W 5957960.24 N 691126.89 E 1254.71 Tie On Point AK-6 BP _IFR-AK 9214.00 25.880 152.320 8460.21 8504.86 2714.42 8 543.40 W 5957952.86 N 691130.89 E 7.353 1262.34 Window Point 9245.99 31.630 153.960 8488.24 8532.89 2728.158 536.47 W 5957939.31 N 691138.16 E 18.141 1276.31 9280.52 37.440 155.250 8516.67 8561.32 2745.838 528.10 W 5957921.85 N 691146.99 E 16.958 1293.86 9312.14 40.520 156.210 8541 .25 8585.90 2763.96 8 519.93 W 5957903.93 N 691155.62 E 9.926 1311.54 -- 9341 .18 43.820 156.980 8562.77 8607.42 2781.858 512.19 W 5957886.24 N 691163.81 E 11 .502 1328.72 9372.15 47.530 157.700 8584.41 8629.06 2802.308 503.66 W 5957866.03 N 691172.86 E 12.094 1348.11 9404.52 51.050 158.380 8605.52 8650.17 2825.05 8 494.49 W 5957843.51 N 691182.61 E 10.990 1369.45 9433.98 53.160 155.290 8623.61 8668.26 2846.41 8 485.34 W 5957822.39 N 691192.30 E 10.944 1389.90 9468.57 56.390 152.190 8643.56 8688.21 2871.748 472.83 W 5957797.39 N 691205.45 E 11 .864 1415.44 9496.60 58.490 151 .180 8658.65 8703.30 2892.53 8 461.62 W 5957776.89 N 691217.19 E 8.084 1437.15 9527.83 62.000 150.170 8674.15 8718.80 2916.178 448.34 W 5957753.60 N 691231.06 E 11 .584 1462.25 9559.29 64.500 150.770 8688.31 8732.96 2940.61 8 434.49 W 5957729.52 N 691245.53 E 8.127 1488.29 9589.47 66.940 146.820 8700.72 8745.37 2964.138 420.24 W 5957706.37 N 691260.38 E 14.410 1514.08 9621.24 69.050 146.350 8712.62 8757.27 2988.71 8 404.02 W 5957682.21 N 691277.22 E 6.782 1542.07 9652.07 72.390 149.400 8722.80 8767.45 3013.358 388.55 W 5957657.97 N 691293.31 E 14.301 1569.50 9686.70 76.480 148.260 8732.09 8776.74 3041.898 371 .29 W 5957629.88 N 691311.30 E 12.229 1600.77 9715.51 79.760 147.960 8738.02 8782.67 3065.828 356.40 W 5957606.34 N 691326.79 E 11 .430 1627.31 9749.81 84.740 146.950 8742.65 8787.30 3094.468 338.12 W 5957578.17 N 691345.80 E 14.809 1659.44 9780.96 87.900 148.540 8744.65 8789.30 3120.758 321.53 W 5957552.32 N 691363.05 E 11.351 1688.77 9808.61 89.570 147.950 8745.26 8789.91 3144.25 8 306.98 W 5957529.19 N 691378.19 E 6.405 1714.78 9843.19 90.490 147.560 8745.24 8789.89 3173.50 8 288.53 W 5957500.43 N 691397.38 E 2.890 1747.42 0-' 9874.44 93.090 146.760 8744.26 8788.91 3199.748 271 .60 W 5957474.63 N 691414.98 E 8.705 1777.00 9902.48 93.520 146.840 8742.65 8787.30 3223.168 256.27 W 5957451.60 N 691430.90 E 1.560 1803.57 9936.91 93.950 146.390 8740.40 8785.05 3251.858 237.36 W 5957423.41 N 691450.53 E 1.806 1836.21 9968.07 92.100 145.650 8738.76 8783.41 3277.65 8 219.97 W 5957398.06 N 691468.57 E 6.393 1865.88 9995.88 91.980 145.630 8737.77 8782.42 3300.59 8 204.29 W 5957375.52 N 691484.84 E 0.437 1892.43 1 0029.11 88.400 145.470 8737.66 8782.31 3327.99 8 185.49 W 5957348.61 N 691504.33 E 10.784 1924.18 10060.00 89.810 145.890 8738.14 8782.79 3353.508 168.08 W 5957323.55 N 691522.38 E 4.763 1953.68 10088.23 91.910 144.760 8737.72 8782.37 3376.71 8 152.02 W 5957300.76 N 691539.03 E 8.447 1980.69 26 June, 2003 - 13:42 Page2of5 OrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 -18-03B Your Ref: API 500292077602 Job No. AKZZ0002488472, Surveyed: 19 June, 2003 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) 10122.21 92.590 144.590 8736.38 8781.03 3404.41 8 132.39 W 5957273.57 N 691559.36 E 2.063 2013.29 10153.81 93.020 142.100 8734.84 8779.49 3429.738 113.55 W 5957248.74 N 691578.84 E 7.987 2043.79 10181.16 92.220 140.470 8733.59 8778.24 3451.05 8 96.46 W 5957227.86 N 691596.47 E 6.633 2070.43 10215.19 92.900 138.480 8732.07 8776.72 3476.89 8 74.37 W 5957202.59 N 691619.21 E 6.174 2103.80 10240.08 93.270 137.810 8730.73 8775.38 3495.408 57.79 W 5957184.51 N 691636.26 E 3.072 2128.29 -' 10274.61 92.780 136.240 8728.90 8773.55 3520.63 8 34.28 W 5957159.89 N 691660.40 E 4.757 2162.39 10308.33 90.920 136.830 8727.82 8772.47 3545.09 8 11.10 W 5957136.03 N 691684.20 E 5.787 2195.76 10340.49 91.110 136.950 8727.25 8771.90 3568.56 8 10.88 E 5957113.12 N 691706.76 E 0.699 2227.56 10368.71 90.060 136.340 8726.96 8771.61 3589.08 8 30.25 E 5957093.11 N 691726.65 E 4.303 2255.49 10400.09 89.380 135.710 8727.11 8771.76 3611.66 8 52.04 E 5957071.09 N 691749.01 E 2.954 2286.60 10431.54 87.960 135.580 8727.84 8772.49 3634.148 74.02 E 5957049.17 N 691771.55 E 4.534 2317.79 10462.76 84.750 135.070 8729.83 8774.48 3656.308 95.92 E 5957027.59 N 691794.01 E 10.410 2348.72 10497.04 84.630 135.340 8733.00 8777.65 3680.528 119.97 E 5957003.99 N 691818.67 E 0.859 2382.61 10525.46 85.620 133.650 8735.41 8780.06 3700.36 8 140.17 E 5956984.66 N 691839.37 E 6.873 2410.77 10555.74 87.280 131.520 8737.29 8781.94 3720.81 8 162.42 E 5956964.79 N 691862.13 E 8.907 2440.91 10588.51 88.270 130.140 8738.56 8783.21 3742.228 187.19 E 5956944.02 N 691887.45 E 5.180 2473.63 10619.44 89.260 127.230 8739.23 8783.88 3761.55 8 211.33 E 5956925.31 N 691912.07 E 9.936 2504.55 10646.33 89.320 123.790 8739.56 8784.21 3777.168 233.21 E 5956910.26 N 691934.34 E 12.794 2531 .40 10681.33 89.750 120.260 8739.85 8784.50 3795.728 262.88 E 5956892.47 N 691964.47 E 10.160 2566.17 10712.43 93.270 120.310 8739.03 8783.68 3811 .39 8 289.72 E 5956877.48 N 691991.71 E 11.319 2596.94 10739.76 96.310 118.000 8736.74 8781.39 3824.66 8 313.50 E 5956864.83 N 692015.82 E 13.952 2623.81 10775.38 96.370 115.690 8732.81 8777.46 3840.65 8 345.08 E 5956849.65 N 692047.80 E 6.448 2658.49 10806.15 94.700 115.690 8729.84 8774.49 3853.92 8 372.68 E 5956837.08 N 692075.73 E 5.427 2688.36 - 10832.56 93.950 116.270 8727.85 8772.50 3865.468 396.36 E 5956826.15 N 692099.69 E 3.586 2714.07 10868.26 93.640 116.670 8725.49 8770.14 3881.34 8 428.24 E 5956811.09 N 692131.97 E 1.416 2748.92 10890.10 93.330 115.840 8724.16 8768.81 3890.988 447.79 E 5956801.95 N 692151.76 E 4.050 2770.22 10901.31 93.210 115.650 8723.52 8768.17 3895.84 8 457.87 E 5956797.35 N 692161.96 E 2.002 2781.14 10936.03 91.420 113.020 8722.12 8766.77 3910.138 489.48 E 5956783.87 N 692193.92 E 9.158 2814.78 10966.86 87.1 00 112.210 8722.52 8767.17 3921.998 517.93 E 5956772.74 N 692222.66 E 14.256 2844.43 10995.31 87.900 112.560 8723.76 8768.41 3932.81 8 544.21 E 5956762.59 N 692249.21 E 3.069 2871.74 11027.14 88.770 113.100 8724.68 8769.33 3945.158 573.53 E 5956751.00 N 692278.84 E 3.217 2902.39 11056.88 88.460 113.090 8725.40 8770.05 3956.82 8 600.88 E 5956740.04 N 692306.48 E 1.043 2931.06 11090.24 92.040 112.980 8725.25 8769.90 3969.878 631.58 E 5956727.77 N 692337.49 E 1 0.736 2963.21 11182.05 91.110 111.890 8722.73 8767.38 4004.898 716.40 E 5956694.93 N 692423.19 E 1.560 3051 .42 11275.83 89.260 111 .150 8722.43 8767.08 4039.298 803.64 E 5956662.76 N 692511.27 E 2.125 3141.13 26 June, 2003 - 13:42 Page 3 of 5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 -18-03B Your Ref: API 500292077602 Job No. AKZZ00024BB472, Surveyed: 19 June, 2003 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) (°/1 o Oft) 11367.33 88.520 112.250 8724.20 8768.85 4073.11 S 888.64 E 5956631.11 N 692597.10 E 1 .449 3228.73 11414.31 88.090 112.250 8725.59 8770.24 4090.90 S 932.10 E 5956614.45 N 692641.01 E 0.915 3273.83 11461.68 89.750 113.720 8726.48 8771.13 4109.39 S 975.70 E 5956597.07 N 692685.06 E 4.680 3319.47 11555.94 91.360 113.480 8725.57 8770.22 4147.12 S 1062.07 E 5956561 .55 N 692772.37 E 1.727 3410.57 11649.08 92.470 111.790 8722.46 8767.11 4182.95 S 1147.98 E 5956527.93 N 692859.16 E 2.170 3500.13 - 11743.92 92.100 112.270 8718.68 8763.33 4218.49 S 1235.83 E 5956494.64 N 692947.89 E 0.639 3591.03 11775.94 92.160 113.250 8717.49 8762.14 4230.87 S 1265.34 E 5956483.01 N 692977.70 E 3.064 3621.84 11823.00 92.160 113.250 8715.71 8760.36 4249.44 S 1308.54 E 5956465.56 N 693021.37 E 0.000 3667.22 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 128.450° (True). Magnetic Declination at Surface is 25.956°(09-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11823.00ft., The Bottom Hole Displacement is 4446.35ft., in the Direction of 162.885° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) .- Comment 9194.30 9214.00 11823.00 8487.03 8504.86 8760.36 2706.94 S 2714.42 S 4249.44 S 547.21 W 543.40 W 1308.54 E Tie On Point Window Point Projected Survey 26 June, 2003 - 13:42 Page 4 of 5 DrillQuest 3.03.02.005 North Slope Alaska Survey tool program for 18-038 From Measured Vertical Depth Depth (ft) (ft) 0.00 7699.35 9194.30 0.00 7085.87 8487.03 26 June, 2003 - 13:42 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 -18-03B Your Ref: API 500292077602 Job No. AKZZ0002488472, Surveyed: 19 June, 2003 BPXA To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 7699.35 9194.30 11823.00 7085.87 8487.03 8760.36 BP High Accuracy Gyro (18-03) MWD Magnetic (18-03A) AK-6 BP _IFR-AK (18-03B) -- - Page 5 of 5 DrillQuest 3.03.02.005 ) ") I 26-Jun-03 AOGCC h "Howard nkland L t~ fA ~.n::'€, i e... 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 18-038 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 9,194.30 I MD Window / Kickoff Survey: 9,214.00' MD (if applicable) Projected Survey: 11,823.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, ~03-bß0 RECEIVED William T. Allen Survey Manager JUL 0 1 2003 Alaeka on & Gas Cons. Commiaeion r~ Attachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 18 18-03B MWD --- Job No. AKMW0002488472, Surveyed: 19 June, 2003 Survey Report 26 June, 2003 Your Ref: API 500292077602 Surface Coordinates: 5960680.25 N, 691604.91 E (70017' 49.6720" N, 148026' 53.8389" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -- Surface Coordinates relative to Project H Reference: 960680.25 N, 191604.91 E (Grid) Surface Coordinates relative to Structure Reference: 1465.99 N, 56.78 E (True) Kelly Bushing: 44. 65ft above Mean Sea Level Elevation relative to Project V Reference: 44.65ft Elevation relative to Structure Reference: 44.65ft Srl=lJl......y-5ul! DRfL.L.INS- SERvJc:es A Halliburton Company Survey Ref: svy4061 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 - 18-03B MWD Your Ref: API 500292077602 Job No. AKMW0002488472, Surveyed: 19 June, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (It) (It) (It) (It) (It) (It) (It) (0/1001t) 9194.30 24.560 153.720 8442.38 8487.03 2706.948 547.21 W 5957960.24 N 691126.89 E 1254.71 Tie On Point 9214.00 25.880 152.320 8460.21 8504.86 2714.42 8 543.40 W 5957952.86 N 691130.89 E 7.353 1262.34 Window Point 9245.99 31.630 139.830 8488.26 8532.91 2727.03 8 534.74 W 5957940.47 N 691139.87 E 25.914 1276.97 9280.52 37.440 157.690 8516.77 8561 .42 2743.728 524.88 W 5957924.04 N 691150.15 E 33.657 1295.07 9312.14 40.520 156.210 8541.35 8586.00 2762.01 8 517.08 W 5957905.95 N 691158.41 E 10.175 1312.55 '--- 9341 .18 43.820 161.220 8562.88 8607.53 2780.178 510.04 W 5957887.98 N 691165.92 E 16.219 1329.36 9372.15 47.530 160.330 8584.51 8629.16 2801.09 8 502.74 W 5957867.26 N 691173.75 E 12.154 1348.08 9404.52 51.050 157.830 8605.62 8650.27 2823.99 8 493.97 W 5957844.58 N 691183.10 E 12.349 1369.20 9433.98 53.160 155.540 8623.72 8668.37 2845.348 484.76 W 5957823.48 N 691192.85 E 9.429 1389.68 9468.57 56.390 152.770 8643.67 8688.32 2870.75 8 472.43 W 5957798.38 N 691205.82 E 11 .400 1415.14 9496.60 58.490 151.210 8658.75 8703.40 2891.61 8 461.34 W 5957777.82 N 691217.44 E 8.839 1436.80 9527.83 62.000 150.330 8674.25 8718.90 2915.268 448.10 W 5957754.51 N 691231.28 E 11.502 1461.88 9559.29 64.500 150.770 8688.41 8733.06 2939.72 8 434.29 W 5957730.41 N 691245.71 E 8.044 1487.90 9589.47 66.940 146.820 8700.82 8745.47 2963.24 8 420.03 W 5957707.26 N 691260.56 E 14.410 1513.69 9621 .24 69.050 146.350 8712.73 8757.38 2987.83 8 403.81 W 5957683.10 N 691277.41 E 6.782 1541 .68 9652.07 72.390 149.400 8722.91 8767.56 3012.478 388.34 W 5957658.86 N 691293.49 E 14.301 1569.12 9686.70 76.480 147.540 8732.20 8776.85 3040.898 370.90 W 5957630.89 N 691311.66E 12.894 1600.45 9715.51 79.760 148.000 8738.13 8782.78 3064.748 355.87 W 5957607.43 N 691327.29 E 11 .492 1627.05 9749.81 84.740 147.070 8742.75 8787.40 3093.408 337.63 W 5957579.24 N 691346.26 E 14.765 1659.16 9780.96 87.900 148.930 8744.75 8789.40 3119.768 321.16 W 5957553.31 N 691363.39 E 11.765 1688.45 9808.61 89.570 148.360 8745.36 8790.01 3143.37 8 306.77 W 5957530.08 N 691378.37 E 6.382 1714.39 9843.19 90.490 147.550 8745.34 8789.99 3172.68 8 288.43 W 5957501.25 N 691397.46 E 3.545 1746.99 9874.44 93.090 147.290 8744.37 8789.02 3199.008 271.61 W 5957475.37 N 691414.95 E 8.361 1776.52 "- 9902.48 93.520 147.310 8742.75 8787.40 3222.55 8 256.49 W 5957452.21 N 691430.67 E 1.535 1803.02 9936.91 93.950 149.640 8740.51 8785.16 3251.84 8 238.52 W 5957423.39 N 691449.37 E 6.867 1835.29 9968.07 92.100 149.060 8738.86 8783.51 3278.60 8 222.66 W 5957397.03 N 691465.91 E 6.221 1864.36 9995.88 91.980 148.190 8737.87 8782.52 3302.33 8 208.19 W 5957373.68 N 691480.98 E 3.156 1890.45 10029.11 88.400 149.500 8737.76 8782.41 3330.76 8 191.00 W 5957345.70 N 691498.89 E 11 .472 1921.59 10060.00 89.810 145.960 8738.25 8782.90 3356.88 8 174.52 W 5957320.02 N 691516.03 E 12.334 1950.74 10088.23 91.910 143.740 8737.82 8782.47 3379.95 8 158.27 W 5957297.36 N 691532.87 E 10.824 1977.81 10122.21 92.590 146.480 8736.49 8781.14 3407.80 8 138.85 W 5957270.02 N 691552.99 E 8.302 2010.34 10153.81 93.020 144.010 8734.94 8779.59 3433.738 120.86 W 5957244.56 N 691571.64 E 7.925 2040.55 10181.16 92.220 144.590 8733.69 8778.34 3455.92 8 104.91 W 5957222.78 N 691588.14 E 3.612 2066.83 10215.19 92.900 143.070 8732.17 8776.82 3483.36 8 84.85 W 5957195.86 N 691608.90 E 4.889 2099.61 10240.08 93.270 143.830 8730.83 8775.48 3503.33 8 70.05 W 5957176.28 N 691624.20 E 3.392 2123.62 26 June, 2003 - 13:52 Page 2 of 5 DríllQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA OS 18 - 18-03B MWD Your Ref: API 500292077602 Job No. AKMW0002488472, Surveyed: 19 June, 2003 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) C/100ft) 10274.61 92.780 138.590 8729.01 8773.66 3530.19 S 48.45 W 5957149.97 N 691646.47 E 15.220 2157.24 10308.33 90.920 135.690 8727.92 8772.57 3554.89 S 25.53 W 5957125.86 N 691670.02 E 10.213 2190.55 10340.49 91.110 140.110 8727.35 8772.00 3578.75 S 3.98W 5957102.57 N 691692.17 E 13.754 2222.26 10368.71 90.060 140.900 8727.06 8771.71 3600.52 S 13.97 E 5957081.26 N 691710.67 E 4.656 2249.85 10400.09 89.380 139.010 8727.21 8771.86 3624.54 S 34.15 E 5957057.76 N 691731.46 E 6.401 2280.60 --- 10431.54 87.960 137.330 8727.94 8772.59 3647.97 S 55.12 E 5957034.87 N 691753.02 E 6.993 2311.59 10462.76 84.750 135.300 8729.93 8774.58 3670.50 S 76.64 E 5957012.90 N 691775.10 E 12.158 2342.45 10497.04 84.630 137.670 8733.10 8777.75 3695.25 S 100.14E 5956988.76 N 691799.22 E 6.893 2376.24 10525.46 85.620 136.930 8735.52 8780.17 3716.06 S 119.34 E 5956968.44 N 691818.95 E 4.343 2404.22 10555.74 87.280 134.490 8737.39 8782.04 3737.69 S 140.44 E 5956947.36 N 691840.60 E 9.733 2434.20 10588.51 88.270 131.930 8738.66 8783.31 3760.11 S 164.31 E 5956925.56 N 691865.03 E 8.370 2466.83 10619.44 89.260 129.910 8739.33 8783.98 3780.36 S 187.67 E 5956905.91 N 691888.90 E 7.272 2497.72 10646.33 89.320 123.560 8739.67 8784.32 3796.43 S 209.21 E 5956890.39 N 691910.84 E 23.614 2524.58 10681.33 89.750 126.890 8739.95 8784.60 3816.62 S 237.80 E 5956870.94 N 691939.93 E 9.593 2559.52 10712.43 93.270 122.310 8739.13 8783.78 3834.26 S 263.37 E 5956853.95 N 691965.95 E 18.568 2590.53 10739.76 96.310 122.090 8736.85 8781.50 3848.77 S 286.42 E 5956840.03 N 691989.36 E 11 .152 2617.60 10775.38 96.370 115.650 8732.91 8777.56 3865.86 S 317.40 E 5956823.74 N 692020.77 E 17.970 2652.49 10806.15 94.700 116.820 8729.94 8774.59 3879.40 S 344.87 E 5956810.91 N 692048.58 E 6.617 2682.42 10832.56 93.950 124.240 8727.95 8772.60 3892.77 S 367.54 E 5956798.12 N 692071.58 E 28.159 2708.48 10868.26 93.640 125.260 8725.58 8770.23 3913.07 S 396.81 E 5956778.57 N 692101.35 E 2.980 2744.03 10890.10 93.330 126.190 8724.26 8768.91 3925.80 S 414.51 E 5956766.30 N 692119.37 E 4.481 2765.80 10901.31 93.210 123.210 8723.62 8768.27 3932.17 S 423.71 E 5956760.16 N 692128.73 E 26.562 2776.97 10936.03 91.420 112.520 8722.21 8766.86 3948.36 S 454.33 E 5956744.76 N 692159.75 E 31.192 2811.02 -" 10966.86 87.100 113.190 8722.61 8767.26 3960.33 S 482.73 E 5956733.52 N 692188.45 E 14.180 2840.71 10995.31 87.900 111.030 8723.85 8768.50 3971.02 S 509.06 E 5956723.49 N 692215.05 E 8.089 2867.98 11 027.14 88.770 113.430 8724.78 8769.43 3983.06 S 538.51 E 5956712.21 N 692244.79 E 8.017 2898.53 11056.88 88.460 113.570 8725.49 8770.14 3994.92 S 565.78 E 5956701.06 N 692272.35 E 1.144 2927.25 11090.24 92.040 124.680 8725.35 8770.00 4011 .12 S 594.87 E 5956685.60 N 692301.85 E 34.984 2960.11 11182.05 91.110 133.970 8722.82 8767.47 4069.22 S 665.78 E 5956629.33 N 692374.22 E 10.165 3051.78 11275.83 89.260 1 07.150 8722.51 8767.16 4116.46 S 745.80 E 5956584.14 N 692455.41 E 28.665 3143.82 11367.33 88.520 104.630 8724.28 8768.93 4141.51 S 833.78 E 5956561.34 N 692544.00 E 2.870 3228.29 11414.31 88.090 104.260 8725.67 8770.32 4153.22 S 879.25 E 5956550.79 N 692589.76 E 1.207 3271.19 11461.68 89.750 109.570 8726.57 8771.22 4167.00 S 924.55 E 5956538.18 N 692635.39 E 11 .742 3315.23 11555.94 91.360 111.360 8725.65 8770.30 4199.95 S 1012.85 E 5956507.49 N 692724.50 E 2.554 3404.87 11649.08 92.470 106.880 8722.54 8767.19 4230.44 S 1100.77E 5956479.25 N 692813.18 E 4.953 3492.69 26 June, 2003 - 13:52 Page 3 of 5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for P8U_EOA DS 18 - 18-038 MWD Your Ref: API 500292077602 Job No. AKMW0002488472, Surveyed: 19 June, 2003 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11743.92 92.100 1 09.450 8718.76 8763.41 11775.94 92.160 105.080 8717.57 8762.22 11823.00 92.160 105.080 8715.79 8760.44 Local Coordinates Northings Eastings (ft) (ft) 4259.98 S 4269.47 S 4281.71 S 1190.81 E 1221.36 E 1266.76 E 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 128.450° (True). Magnetic Declination at Surface is 25.956°(09-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11823.00ft., The Bottom Hole Displacement is 4465.16ft., in the Direction of 163.519° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9194.30 9214.00 11823.00 2706.94 S 2714.42 S 4281.71 S Tie On Point Window Point Projected Survey 8487.03 8504.86 8760.44 547.21 W 543.40 W 1266.76 E 26 June, 2003 - 13:52 Page 4 of 5 Global Coordinates Northings Eastings (ft) (ft) - 5956452.02 N 5956443.31 N 5956432.23 N 692903.94 E 692934.72 E 692980.42 E Dogleg Vertical Rate Section (°/1 o Oft) 2.736 13.640 0.000 8PXA Comment 3581.57 3611.40 3654.57 Projected Survey --' --- DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 - 18-03B MWD Your Ref: API 500292077602 Job No. AKMW0002488472, Surveyed: 19 June, 2003 BPXA North Slope Alaska Survey tool program for 18-038 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 7699.35 0.00 7699.35 7085.87 11823.00 7085.87 BP High Accuracy Gyro (18-03) 8760.44 MWD Magnetic (18-03A) '--- -" 26 June, 2003 - 13:52 Page 5 of 5 DrillQuest 3.03.02.005 ) ) ,^oô..þßV \ J 'DO 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska July 18, 2003 RE: MWD Formation Evaluation Logs 18-03B, AK-MW-2488472 1 LDWG formatted Disc with verification listing. API#: 50-029-20776-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~VED18 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 JUL 24 2.003 A1~t&\& Gas Conß. CcmmiS8ion AnChorage Signed: ?2fu~ ~lT&\uE 1'0\~ ! . I ~ ) &\ ~&\ ~ ~~!Æ ) AI/A~KA. OIL AND GAS CONSERVATION COJDIISSION FRANK H. MURKOW5KI, GOVERNOR 333 W. "'fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 18-03B BP Exploration (Alaska) Inc. Permit No: 203-086 Surface Location: 1184' SNL, 161' WEL, Sec. 24, TIIN, RI4E, UM Bottomhole Location: 103' SNL, 1161' EWL, Sec. 30, TIIN, RI5E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit 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 pennit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ;f.:-~ ~~ ~ Randy Ifuedrich Commissioner BY ORDER ?l THE COMMISSION DATED this-14--- day of May, 2003 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section 6" - STATE OF ALASKA ALASKA,- 2 AND GAS CONSERVATION COMM~ JION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service D Development Gas D Single Zone D Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan KBE = 44.6' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028326 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /" 18-038 9. Approximate spud date ' 06/16/03 7 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 /11858' MD / 8765' TVD o 17. Anticipated pressure {S~O AAC 25.035 (e) (2)} 91 Maximum surface 2438 psig, At total depth (TVD) 8720' I 3310 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 5077' 2500' 2500' 7577' 6980' 2782' 9075' 8377' 11857' 8765' iAi61r s fr~/'-oo'5 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 691605, Y = 5960680 1184' SNL, 161' WEL, SEC. 24, T11 N, R14E, UM At top of productive interval x = 691563, Y = 5957117 4745' SNL, 294' WEL, SEC. 24, T11 N, R14E, UM At total depth x = 693034, Y = 5956517 103' SNL, 1161' EWL, SEC. 30, T11 N, R15E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 12. Distance to nearest property line 13. Distance to nearest well /' ADL 028321, 103' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9225' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casina Weight Grade Couplina 7" 29# L-80 BTC-M 4-1/2" 12.6# L-80 IBT-M Hole Quantity of Cement (include staae data) Scab Liner; 587 sx Class 'G' 314 sx Class 'G' ,/ /' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 11736 feet 8761 feet 11653 feet 8761 feet Length Plugs (measured) 4-1/2" HES PXN Plug set at 9337' (11/99) Junk (measured) Size Cemented MD TVD 110' 110' 2600' 2600' 7740' 7121' 110' 20" 2600' 13-3/8" 7740' 9-5/8" 2158' 7" 2175' 4-1/2" 2940# Poleset 2400 sx Fondu, 400 sx PF 'C' 500 sx Class 'g', 300 sx PF 'C' 525 sx Class 'G' 270 sx Class 'G' 7577' - 9735' 6981' - 8779' 9fteœl"~'d761 Perforation depth: measured 9750' - 11600' (15 Intervals) true vertical 8780' - 8761' 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis MAY 13 2003 AIaIIra Oii & .: Cons. CoIß/niseion o Diverter Sketch II Drillin~!cf~m o Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Rob Tirpack, 564-4166 21. I hereby certify that the foregoing i\ true and correct to the best of my ~nowl~~ge . Signed Billlsaacson 'Ù L 1. ~"'e.""'--- Title Senior Drilling Engineer Commission U$e.Onl~ Prepared By Name/Number: Terrie Hubble, 564-4628 Date ~~"( t z. I Z.OO3 Permit Number API Number 20.3" .. Q xc. 50- 029-20776-02 Conditions of Approval: Samples Required 0 Yes ÆI No Hydrogen Sulfide Measures ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: T~~ t "ED P& to 3\'00 ps.¿.. :~:O~~~~i Rev. 12_0/!4?- - ~~ ~oRftmrAt ..ðP;roval 'pate See cover letter S / ! J¡ D '1 for other requirements Mud Log Required 0 Yes ~ No Directional Survey Required EI Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU by order of the commission Date S//.? / ò? Submit In:.triPlicaie ) ) I Well Name: 118-038 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 2A Bottom Hole Location: x = 691,605 Y = 5,960,680 1184' FNL 161' FEL Sec. 24, T11 N, R14E Umiat /" X = 691,563 Y = 5,957,117 TVDss 874p' 4745' FNL 294' FEL Sec. 24, T11N, R14E Umiat /' X = 693,034 Y = 5,956,517 TVDss 8720' 103' FNL 1161' FWL Sec. 30, T11 N, R15E Umiat / I AFE Number: 1 PBD4P2089 1 I Estimated Start Date: 106/16/03 /1 1 MD: 111,858' 1 I TVD: 18765' I I Rig: 1 Nabors 2ES /' I Operating days to complete: 118.0 I GL: 116.1' I KB: 128.5' 1 I KBE: 144.6' I Well Design (conventional, slim hole, etc.): 1 Single String Horizontal Sidetrack 1 Objective: 1 Ivishak Zone 1 A Formation Markers Formation Tops (wp01) Sag River Shublik TSAD - Zone 4B SAD - Zone 2 Kick Off Point SAD - Zone 1B SAD - Zone 1A TD BSAD MD 8,892' 8,942' 8,956' 9,216' 9,225' 9,481 ' 9,596' 11,858' N/A TVD 8,206' 8,252' 8,310' 8,507' 8,515' 8,703' 8,753' 8,765' N/A TVDss 8,161' 8,207' 8,265' 8,462' 8,470' 8,658' 8,708' 8,720' 8,743' Comments Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing 7.3 ppg EMW 7.3 ppg EMW 7.3 ppg EMW 7.3 ppg EMW 7.3 ppg EMW 9.L o~ 7.3 ppg EMW '"() U1 r 7.3 ppg EMW 7.3 ppg EMW 7.3 ppg EMW TD Criteria: Based on 1000' of periable sand in horizontal. Geo polygon is hardline due to faulting. Directional - Sperry wp01 KOP: I 9,225' MD Maximum Hole Angle: Close Approach Well: Survey Program: 18-038 Permit to Drill -910 in 6" horizontal section. There are no close approach issues. MWD with IFR/Casandra. Page 1 ) ') CasinglTubing Program Hole Size CsgfTbg WtlFt Grade Conn Length Top Btm O.D. ,/'/ /' MDfTVD MDfTVD 9-5/8" Casing 7" 29# l-80 BTC-M 5,077' 2,500'/2,500' 7,577'/6,980' 6" 4-1/2" 12.6# l-80 IBT-M 2,782' 9,075'/8,377' 11,857'/8,765' Tubing 4-1 /2" 12.6# l-80 IBT-M 9047' Gl 9,075'/8,377' Mud Program Section Milling Mud Properties: Quickdril I Density (ppgy Viscosity PV YP MBT PH API FI 8.4 - 8.7 55-65 7-11 30-40 <3 8.5-9.0 N/C Production Mud Properties: Quickdril Density (ppgy, Viscosity PV YP MBT pH API FI 8.3-8.6 45-55 4-7 20 - 28 <3 8.5 - 9.0 N/C Logging Program 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GR/Res/ABI - Real time; Den/Neu - recorded mode Open Hole: None Cased Hole: None Cement Program Casing Size I 7" 26#, L-80 Scab Liner I Basis: lead: Based on 3500' of 7")( 9-5/8" casing annulus with 20% excess (6000' - 2500' MD) lead TOC: 2500' (Tal) ,/' Tail: Based on 80' shoe track and 1577' of 7" X 9-5/8" casing annulus with 20% excess (7577' to 6000' MD) Tail TOC: 6000' MD I Total Cement Volume: /-'-"'" ,+""'.,.,.....-~) lead 1 08 bbls, 604 ft¥335 Ss;lcks Class G @ 13.5 PP9.,1(80 ft~/sack Tail 52 bbls, 292 ~aCks Class G @ 15.8 PP9~3/SaCk Casing Size 14.5" 12.6#, L-80 Production Liner I Basis: lead: None Tail: Based on 80' shoe track, 2632' of 4-1/2" X 6" open hole with 40% excess, 150' 4-1/2" X 7" Liner lap, and 200' of 7" X ~P excess. Tail TOC: 9075' MD (Tal) I Total Cement Volume: lead None./...."¡i"/) Tail 65 bbls, 365 ftr3~aCks Class G @ 15.8 pp~3/saCk 18-03B Permit to Drill Page 2 ) ') 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. 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 3310 psi (7.3 ppg @ 8720' TVDss) 2438 psi (.10 psi/ft gas gradient to surface) ./ Infinite with 9.5 ppg FIT Rams test to 3,500 psi/250 psi. /' Annular test to 2,500 psi/250 psi 3500 psi surface pressure 9.5 ppg EMW FIT 8.4 ppg Seawater /6.8 ppg Diesel 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. 18-03B Permit to Drill Page 3 ) I ') Sidetrack and Complete Procedure Summary Pre-Rh:l Work: 1. Rig up slick line, drift 4-1/2" tubing to the top of the 'XN' plug at -9,337' MD. 2. RU E-line. RIH with RST logging tool in gravel pack mode. Log from top of packer looking for fill in 7 X 4-1/2" annulus. Confirm top of fill below -9,245' MD 3. RIH with Chemical cutter and cut the 4 ¥2" tubing at -9,245' MD. 4. Displace the well to 9.6 ppg brine by circulating down the tubing through the tubing cut. Continue to circulate until clean brine returns to surface. Freeze protect top 500' MD with diesel. 5. Test the 9-5/8" pack-off and tubing hanger seals to 5000psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 6. Bleed casing and annulus pressures to zero. 7. Set a BPV in the tubing hanger. Secure well. 8. If necessary, level the pad. Please provide total well preparation cost on the handover form. / .Bi~ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to 9.6 ppg brine. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. /' 4. Pull 4-1/2" tubing from above pre-rig cut. 5. PU and RIH with 7-7/16" polishing mill. Polish 7" TBE at 7577' MD. /" 6. Run and cement a 7" scab liner from 2500' MD to top of existing 7" liner. 7. RIH with 6" bit and watermelon mill. Drill scab liner shoe track. Circulate clean. 8. RIH to top of 4-1/2" tubing stub. Displace ho~ver to 8.6 ppg milling/drilling fluid. Circulate clean. 9. PT casing to 3500 psi for 30 mins. POOH. 10. RIH with 7", 29# Baker bottom trip whipstock assembly. Orient whipstock and set on tubing stub. 11. Mill window in 7" casing at -9,225' MD, plus 20' past middle of window. Perform FIT. POOH. "'-' 12. MU 6" BHA with Dir/GR/Res/ABI/Den/Neu and RIH. .".,..--' 13. Drill the 6" production interval building at 12°/100' to horizontal, targeting Z1 A Ivishak. Drill ahead to an estimated TO of 11,857' MD 14. Run and cement a 4-1/2" solid liner throughout the 6" wellbore and back into the 7" liner to 9075' MD. Displace cement with perf pill and clean seawater. Release from TOL. /' 15. Displace well to clean seawater. 16. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 17. POOH. LD DP and perf guns. 18. Run 4-1/2",12.6#, chrome completion with SCSSV tying into the 4-1/2" liner top. /' 19. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 20. Set and test TWC. 21. NO BOPE. NU and test the tree to 5000 psi. /' 22. Freeze protect the well to -2200' and secure the well. 23. RDMO Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. 18-03B Permit to Drill Page 4 ) \) 18-038 Drilling Program Job 1: MIRU Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto 18-038. The closest neighboring wells are spaced as follows: 18-17 at -59' and 18-04 at -120'. Care should be taken while moving onto the well. Spotters will be usej-at all times. ~ Drill Site 18 is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Reading Date #1 Closest SHL with H2S Reading 18-24AL2 12 ppm 01/12/00 l #2 Closest SHL with H2S Reading 18-23A 3 ppm 02/06/00 #1 Closest 8HL with H2S Reading 18-26A 10 ppm 12/16/99 #2 Closest 8HL with H2S Reading 18-31 15 ppm 07/22/99 The maximum level recorded of H2S on the pad was 16 ppm at 18-09B in 07/23/99. / ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP n.I.III.IT- .11_I:m-I-I--II-'-IIIIII:IIIIIIIIIIIIIIIIT _ _11_ _ "".1_ _11_1111_11_1_ .1_111:-'--'-:111111111111-'-- - -1111:111111111I11I. _11_· -lllInl. _11_ _ 111"':--:1:11:--11:1. _1_ --'-1:11:--11-11'1111111111I ,:. ;:1. .11::1::1:-11I11"-'11'11:---1-'11111:11:-1111-- - _ ,mllllllllll""11 _ .lm'.II.I.I:IIIIII. -:IIII'--·,IIIIIIII'-;'-IIII;IU:IIIII.I.II .1:--1':11--1111 Job 2: De-complete Well Hazards and Contingencies ~ 18-03A is currently Shut-in with a tubing tail plug in the 'XN' nipple. Pre-Rig operations will NOT ~ include cement work. The existing perforations will remain uncemented. Since 18-038 will be in the same zone as 18-03A (Zone 1A), there is no need to cement the existing horizontal.1'solation will come from the -150' cemented liner lap. ~ Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. 8e prepared with necessary equipment to remove. ~ The cretaceous leak will be repaired prior to cutting the window in the existing 7" liner. 8e prepared with LCM to control any losses. ~ Keep 9.5-9.6 ppg brine in the hole at all times until the cretaceous leak has been repaired. The ~ cretaceous leak has a potential pore pressure of 9.0 ppg. ./ Reference RP .:. "De-completions" RP 18-038 Permit to Drill Page 5 ') ") Job 4: Window Mill Hazards and Contingencies ~ The 4-1/2" tubing stub will be used to set the whipstock. ~ 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. Reference RP .:. "Whipstock Sidetracks" RP ~'ffl'I'Ii'ffl'n-,t( .1"NI;;;;;¡III"-··J·'''''-·'''·''-~;::'-::,·.η¡¡'. Job 7: Drill 6" Production Hole Hazards and Contingencies ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ There are no fault crossings in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ There are no close approach issues while drilling the production hole section. ~ KICK TOLERANC~:".. In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a /' fracture gradienk6f 9(5 ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance ~ Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.6ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. 18-03B Permit to Drill Page 6 ) ') Job 10: DPC Perforate Production CasinQ Hazards and Contingencies ~ Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. uDPC Perforating" RP ..,/ nllll~mlllm_ '1llalmlUI- 1IIIIIIIImI1ll1111Im:IIII.I:II---.--,--a:mlllrllll,111I11II11II1II1mm"II_r~': :::11:II~mmm,:nlnlllll:I:I-.--I-m'WW-:I~III 1ml:UIII:III:mlllll-m:llllIIll:m:mlllilmna:lmIIlIalIWII__L_I:lm1m : awlalw··....··~m' _.:. .1. tl· ·....·"~·m'Y~1'~II__II_ .11. _'IIIII,IY~:lmm_ .mln:mlllllll~__ 1:111. _1,m'IIIIIIWllllou:mlllll_l. ,.I'mW~II'lIInlm Job 12: Run Completion Hazards and Contingencies ~ 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. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move off of 18-038. The closest neighboring wells are spaced as follows: 18-17 at -59' and 18-04 at -120'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 18-038 Permit to Drill Page 7 ') ') 18-038 Well Summarvof Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Decompletion: · The 9-5/8" casing has a cretaceous leak at -6250' MD. Keep 9.5-9.6 ppg fluid in the hole at all time prior to patching the casing leak. Production Hole Section: · There are no fault crossings expected in the production hole section. Lost circulation risk is low. Use LCM Decision Tree in the event of losses. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · Kick tolerance is Infinite. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S ..,/ · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE DS18 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 18-038 Permit to Drill Page 8 -It ~\tf;t!~~ ;1(~j1:~n.~ :'~;: ~~~;¡J4'"~ ; :~::j.....~~ " ,.:~j1.J:J:'~~ ~~:!~i~~f'~~f~ ~ . '. "",I1.f-\(¡ :;~~T~~~~'tff1i,. <. f,:.,J.,··~rt!· ·:!:~f~1 t,f ·~t1~I.1á~ ,,it 001 ~h~h~W. "~!~'" . 'r " . ..', ~ .!I'M~iíd.f~~1f.;;:..." t".. ..... .'" . ..'ri,' .t " 'JJ~ . I... .,. _ - . ~~..ï.u~~~~~rP.1g.~~Þ~\"~~ttJ~7i':fr~~~~~m_~~~ TREE = WELLHEAD = ACMTÕ-Ff; -¡;{B: 8...ÈV = BF. 8...EV = ï<õP= tvax Angíê"-;;,,mv-_-r, Datum MD = Datum TVD = DATE 08/16/82 02/12/95 01/02/01 02/01/01 10/11/01 5-1/8" McEVOY McEVOY AXELSON 46.33' ) ----_.....~,.._.....--.....,.,., 3000' m---"93"@'988ãí 11736' 8716' SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" H 2600' rJI Minimu m ID = 3.725" @ 9352' 4·112" HES XN NIPPLE 7" BKR FKRTIEBACK SLEEVE, 10= 6.125" H 7577' 1 9-518" X 7" BKR H PKR, 10 = 6.188" 1-1 7585' 9-5/8" X 7" BKR Hrv'C LNR HGR, 10 = 6.184" H 7590' 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 7740' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 18-03A ~ I ~ l- I 4-112" TIP, 12.6#, L-80, .0152 bpf, D =3.958" 1-1 9363' TOP OF BKR C-2 TIEBACK SL V, 10 = 5.250" 1-4 9561' '" 7" X 4-1/2" BAKffi LNR HGR, D =4.469" 1--1 9574' I 7" LNR, 29#, L-80, 10 = 6.184" 1-1 9735' PffiFORATION SUMMARY RS= LOG: TCP ÆRF ON 02/11/95 ANGLEATTOPÆRF: 88 @ 9750' I\Ote: Refer to Production DB for historical perf data SIZE SA=" INTER\! AL Opn/Sqz DATE SEE PAGE 2 FOR PERF BREAKDOWN ) SA FEfY NOTES: WELL ANGLE> 70 DEG @ 9604' & > 90 DEG @ 9826. SWS LEAK DETECT LOG OF 12/04/99 FOUND1BGLEAK@ 7088'. FTSWELL.PO'SHAVE LEAKED IN lHEPAST. e 26' 1-1 5-1/2" X 4-1/2" XO, 10 = 3.958" 1 2236' 1-1 4-1/2" CArv'CO TRDP-4A TRSV, 10 = 3.812" . GA S LIFT MA. NDR8...S ST MD TVD DEV TYPE VLV L TCH PORT DATE 1 3298 3288 18 TFD r::N T-2 0 08126/99 L 2 5811 5494 32 TFD r::N T-2 0 12/03195 3 7538 6947 31 TFD r::N T-2 0 11/21/99 (MERLA) ) ~ 9-5/8" SIDEfRACK WNDOW 7740' - 7790' (SECfION MLL) NOTE: FRE-SDTRK W8...LBORE HAS BEEN P&A'D AND IS NOT SHOWN B8...0W 9-5/8" MlLOUT WINOOW. 9296' 1-4 4-1/2" HESX NIP, 10=3.813" 1 9308' 1-1 7" x 4-1/2" BKR SABL-3 FKR, 10 = 3.875" 9341' 1--1 4-1/2" HES X NIP, 10 = 3.813" I 9352' 1--1 4-1/2" HES XN NIP, 10 = 3.725" I 9337' 1--1 4-112" I-ES PXN PLUG SEf ON 11/14/99 (SL 9364' H 4-1/2" WLEG I 9569' l-t 7" X 4-1/2" BKR H PKR , 10 = 4.313" 1 l-t ELMO TI NOT LOGGI3:> I PBTD H 11653' I 1 4-112" LNR, 12.6#, L-80, .0152 bpf, D = 3.958" H 11736' REV BY COMrvENTS ORIGINAL COM'LEfION . RIG SIDEfRACK SIS-lsl CONVERTED TO CANVAS SIS-LG REVISION a-i/KA K CORRECfIONS DATE 10/12/01 REV BY CH'tlh CO MrvENTS ADD MISSING XO INFO PRLDI-DE BAY LNrT W8.L: 18-03A PffiMT 1\0: 194-1020 AR No: 50-029-20776-01 1184' SNL & 161' WEL, Sec. 24, T11N, R14E BP Exploration (Alaska) 9-5/8" CSG, 47#, L-80, ID = 8.681" l-f 7740' I- Sc::>.-- Pre-Rig Tubing Cut @ 9245' MD ~- ~ TREE'= WELLHEAD = ,..,..,........"""..".."......,.,.......,..",."., ACTUA TOR = KB. ELEV = 'BF:äË\T; , KOP= ",..."..,,,.........,,................ "",.... Max Angle = "....... .... Datum MD = 'bï:1tumTVb;" 5-1/8" McEVOY McEVOY '''' .....,,,,,,,,,,,,,,,.',..,,.,,,,,,,,'. AXELSON 46.33' ) 18-03A 3000' "','" "'gà@"g'a8'8' 11736' , "'" ""'ai1S'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" l-f 2600' ~ Minimum ID = 3.725" @ 9352' 4-1/2" HES XN NIPPLE I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7" BKR PKR TIEBACK SLEEVE, ID = 6.125" l-f 7577' I 9-5/8" X 7" BKR H PKR, ID = 6.188" l-f 7585' 9-5/8" x 7" BKR HMC LNR HGR, ID = 6.184" l-f 7590' I L--~ P 4-1/2" TIP, 12.6#, L-80, .0152 bpf, ID = 3.958" l-f I TOP OF BKR C-2 TIEBACK SLV, ID = 5.250" l-f 9363' I 9561' I 7" X 4-1/2" BAKER LNR HGR, ID = 4.469" l-f 9574' 7" LNR, 29#, L-80, ID = 6.184" l-f 9735' e Pre-R~J ~ 26' l-f 5-1/2"X4-1/2"XO,ID=3.958" I I 2236' l-f 4-1/2" CAMCO TRDP-4A TRSV, ID = 3.812" ~ GAS LIFT MANDRELS ST MD ND DEV TYÆ VLV L TCH PORT DATE 1 3298 3288 18 TPD DV T-2 0 08/26/99 L 2 5811 5494 32 TPD DV T-2 0 12/03/95 3 7538 6947 31 TPD DV T-2 0 11/21/99 (MERLA) J ~ 9-5/8" SIDETRA CK WINDOW 7740' - 7790' (SECTION MILL) NOTE: PRE-SDTRK WELLBORE HAS BEEN P&A'D AND IS NOT SHOWN BELOW 9-5/8" MILLOUT WINDOW. 9296' l-f 4-1/2" HES X NIP, ID = 3.813" I 9308' l-f 7" x 4-1/2" BKR SABL-3 PKR, ID = 3.875" 9341' l-f 4-1/2" HES X NIP, ID = 3.813" I 9352' l-f 4-1/2" HES XN NIP, ID = 3.725" I 9337' l-f 4-1/2" HES PXN PLUG SET ON 11114/99 (SL 9364' l-f 4-1/2" WLEG I 9569' l-f 7" X 4-1/2" BKR H PKR, ID = 4.313" I l-f ELMD TI NOT LOGGED I ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ON 02/11/95 ANGLE AT TOP ÆRF: 88 @ 9750' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE SEE PAGE 2 FOR ÆRF BREAKDOWN PBTD l-f 11653' I I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" l-f 11736' I SAFETY NOTES: WELL ANGLE> 70 DEG @ 9604' & > 90 DEG @ 9826. SWS LEAK DETECT LOG OF 12/04/99 FOUND TBG LEAK @ 7088'. FTS WELL. PO'S HAVE LEAKED IN THE PAST. DATE 08/16/82 02/12/95 01/02/01 02/01/01 1 0/11/01 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK SIS-lsl CONVERTED TO CANVAS SIS-LG REVISION CHlKA K CORRECTIONS DATE 10/12/01 REV BY CI-Vtlh COMMENTS ADD MISSING XO INFO PRUDHOE BA Y UNrr WELL: 18-03A ÆRMrr No: 194-1020 API No: 50-029-20776-01 1184' SNL & 161' WEL, Sec. 24, T11N, R14E BP Exploration (Alaska) ) ) 18-038 7" Scab Liner 2500' ----g 2600'~ 9-5/8" X 7" HMC Liner Hanger with r ZXP Liner Top Packer & C-2 Running Tool ,~ ~ 13-3/8", 72#, L-80 TREE = -WB.LHEAO = AcrUA TOR = KS. ELEV = SF. ELEV = KOP= Max A'ngle = Datûm MO = Datum TVO = 5~1/8" McEVOY McEVOV - A'XRSON , 46.33' .~~.. H 7", 29#, L-80, BTC-M, Scab Liner I t " - 3'000' 93 @ 9888' 11736' 8716' SS I' 1 M~¡ 6250'- ,II II /' ;~ ~ Cretacecous Leak in 9-5/8" Casing :Wi .1:1 ~ 7577' -~ i'~j )~ 9-5/8" X 7" Type H Packer with TSE ~ 9-5/8" X 7" HMC Liner Hanger 9-5/8", 47#, L-80, Top of Section 7740' - 9245'- 9308' 7", 29#, L-80 Liner Rev By Comments Date 4-24-03 RBT Completion Design PRUDHOE BAY UNIT WELL: 18-03B API NO: Permit NO: GPB Rotary Drilling 18-038 P~oposed Corhpletion 6250'- ~ H 7", 29#, L-80, BTC-M, Scab Liner I 4 "1--14-1/2", 12.6#, 13Cr80, VAM ACE Tubing I j; t1! "[ ~ Cretacecous Leak in 9-5/8" Casing TREE = WB.LHEAD = ACTUATOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MD = DatumTVD = 5-1/8" McEVOY McEVOY AXB.SON 46.33' 2200' 2500' ---g 2600'..,J 4-1/2" Cameo Bal-O Wireline Retrievable SCSSV: 3,812" 10, 6.0" 00 o } 9-5/8" X 7" HMc Liner Hanger with ~ ZXP Liner Top Packer & C-2 Running Tool ~ ~ 13-3/8", 72#, L-80 3000' 93 @ 9888' ". n736' 8716' SS \:;'1, GLM Design: #3 - 3288' TVD - 4-1/2" X 1" #2 - 5464' TVD - 4-1/2" X 1" #1 - 6947' TVD - 4-1/2" X 1" , 7577' -1 1¡~I, J. 9-5/8" X 7" Type H Packer with TBE ~ 9-5/8" X 7" HMc Liner Hanger TubinQ Tail: -10' Pup Joint -x Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 7740' - 9-5/8",47#, L-80, Top of Section 9025'-lfr X 4-1/2" S-3 Permanent Packer 9075' - ~ ~_ 7" X 4-1/2" Flex Lock Liner Hanger with '\. ZXP Liner Top Packer and HR Running Tool ~, ; I 9225'- Top of Window . . . .._ .._ .¿4:1/~:..~.~.~..L~~~.. ~T-M.Pro.d.U~ion~i:r 9308' II 1'. -t, ~ .'Il" . '.~ '1rt"r\1 . ',. .,,'.1 '. . '"" . .:. ,J'(.i.. ",~' .. .-:r '. . . ....... . 11,;~." . .". . . /" 11,857' MD Date 4-24-03 7", 29#, L-80 Liner Rev By Comments RBT Completion Design PRUDHOE BAY UNIT WELL: 18-03B API NO: Permit NO: GPB Rotary Drilling Plan: 18-03B wpOl (I8-03A1P1an 18·03B) Created By: Ken Allen Date: 4/1612003 Checked: Date: Reviewed: Date: SURVEY PROGRAM Depth Fm Depth To Sun'e)'lPIan Tool 9225.00 11857.87 Planned: 18-038 ~l VI MWD REFERENCE INFORM.... TION Co-cnIinate (WE) Reference; WeD Centre: 18-03A. True North VcnicaI (lVD) Refereoce: 44.65' 44.65 Sectioo (VS) Reference: SIoI· 03 (O.OON,O.OOE) Measured Depth Refereoce: 44.65' 44.65 CaIcuIatioa Med1od: MioÌlnlm eur,,,,,,,,, COMPANY DETAILS 8P Amoco Calculalion MdOOd: Minimøn Cun"""" =~C ~s,;v~~~ Nonh Error Suñ_ EUipôcaI + C&>ÙIg WarninR MdOOd: Rules Based ò Slot 03 Lati_ Longilnde 70"1 T49.672N 148""..6'S3.839W WELL DETAILS _g Easting 596068025 001604.91 +E/-W 58.86 +W-S 1466.16 Nami: I8-03A TARGET DET AD.S Narœ 1VD +NI-S +E/·W Northing Easting Sbape 18-038 D 8764.65 -419858 132256 5956517.00 003034.00 Point 18-038 TI 8784.65 -314724 -28325 5957527.00 001402.00 Point 18-0381'2 8784.65 -3563.70 ·35.71 5957111.00 001660.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFace vSec Target 1 9225.00 26.62 151.59 8514.73 -2718.71 ~~:~:~ ~g 0.00 2430,51 2 9705.79 84,26 148.06 8776,15 -3044.43 -4.16 2799.62 3 9754.33 84,26 148.06 8781.01 -3085.42 -321.09 0.00 0.00 2846.39 4 9826,93 89.99 149.00 8784.65 -3147.24 -283.25 8.00 9.36 2916.72 18-03B Tl 5 9830.49 89.99 149.28 8784.65 -3150.29 -281.42 8.00 89.97 2920,19 6 10298.32 89.99 149.28 8784.73 -3552.50 -42.47 0.00 O. 00 3375.60 7 10311.38 90.72 149.00 8784.65 -3563.70 -35,77 6.00 -21.32 3388.31 18-03B T2 8 11052.07 90.72 104.55 8774.82 -3996.09 542.68 6.00 -89.70 3974.51 '-' 9 11857.87 90.72 104.55 8764.65 -4198.58 1322.56 0.00 0.00 4401.96 18-03B T3 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 8506.65 9215.99 TZ2 8702.65 9480,66 TZlB 8752.65 9595.63 TZIA CASING DETAILS Size 4.500 No. TVD MD Name 8764.65 1857.86 4 1/2' All TVD depths are ssTVD plus 44. 65'for RKBE. o Ir! I I ~I ~ ,I ¡P ,I ¡fJ II ~. ~. il~~~1 . I ì i I ¡ : ì I I ! . ! I I I I 4500 11857.8T MD, 8764,65' TVD i I/~ ì ! ì i I I I I I I., ro I 4200 I I Total Depth I ¡ 1t<>3A (18-03A~ , I I r'. : . I I ¡ j ! ì 'ICOO! I I I ! i i IIÒ52.ot ~,!87V4.þ' rvp Ii! i ¡ J I I : I II i ¡ I ¡ ¡ I : i ¡ . !! ¡ I I ¡ J I I I I I I I I 3900 ! I i i 3m Djr I : I 3600 [300ft/in] I 3300 Vertical Section at 162.52 9225' MD, 8SI4.73'TVD End Die : 9705,79' MD, 8776, IS' TVD ! Start Die 8/100' : 9754,33' MO, 878LOI'1VD End Die : 9830.49' MD, 8784.65' TVD !t '~i~Jj e..L!! I ~ II illlll ~z'r :u~" ,~ "": I -t:5-" -¡ +' . I "\ I I t I I ! _L ! - J - -¡,J --!-TT+' I~ I I i ~ I ! ¡ - 1. - J -I ,J j' ¡ ! I I I! ! - ! J - -: - ¡ -[- j-~1tj' J>fl(O(l'l1~298.3*· MDJ 8784 73-:rVp. !! I Ó!AU8.( J) - iLL l, I: I I I! ! I Ii! ill: 1'111 I ~¡ illl ¡ ¡i! i , I I ' . j - f : -rn r ': - - -----.-- , ' I I ------¡-;---r---r----; ! ¡ r !!! _ I ' . . 1 ~ :! ! ¡ I ¡ ! ,__1._ " ¡ '--~··i-,__L__", I' I· , : i !: I I I! I:! I! I ! I Ii: I I I I I I I I I I I I I I I I I I I I I I I I 2700 3000 121100' 2400 . . I 1 ¡ -- J i -Î I ì I i I ! ¡ î ! ¡ 8400- -- c £! o ~ .c E. Ö "3 ï:: >. 8700 2 I- 9000 Plan: 18-03B wpO I (l8-03AlPlan 18-03B) Created By: Ken Allen Date: 41161200 Checked: Date: Reviewed: Date: Tool MWD SURVEY PROORAM Depth Fm Depth To s.rn,yIPIan 9225.00 11857.87 PIanœd: 18.oJB wpOl VI REFERENCE INFORMA 1100 Co-ordinar< (NIE) Reference: Well CeI!Ire: 18-03A, True North Venical (TVD) Refm:uœ: 44.65' 44.65 Section (VS) Reference: SIoI· 03 (0.00N,0.00E) Measun:d Depth Reference: 44.65' 44.65 CakulaIioo M<Ihod: Mìninmn Quwture COMPANY DETAILS BI' Amxo CalcubOon Method: Minimum eur...... Error S)'SI<m: ISCWSA San Mctbod Tn. Cylirda' North Error Suñace: Elliplical + Casing Wamin¡¡ Method: Rules &>cd d WElL DETAILS NOdhing Easling LatiItrle 5%068025 69160491 70017'49.672N Slot 03 LoogituŒ 148"2653.839W +F).W 58.86 Name +NI-S 8-03A 1466.16 '-' .~-"'- TARGET DETAILS +f!J-W Northing EasIing Shape 1322.56 59565 17.00 693034.00 Point -28325 5957527.00 691402.00 Point -35.77 5957117.00 691660.00 Point DLeg TFace VSec Targe 0.00 0.00 2430.51 12.00 -4.16 2799.62 0.00 0.00 2846.39 8.00 9.36 2916.72 18-03B TI 8.00 89.97 2920.19 0.00 0.00 3375.60 6.00 -21.32 3388.3 I 18-03B T2 6.00 -89.70 3974.51 0.00 0.00 4401.96 18-03B T3 FORMATION TOP DETAll..S TVDPath MDPath Fonnation 8506.65 9215.99 TZ2 8702.65 9480.66 TZIB 8752.65 9595.63 TZIA No. 1 2 3 SECTION DETAILS +N/-S +FJ-W -541.16 -346.64 -321.09 -283.25 -281.42 -42.47 -35.77 542.68 322.56 Size 4.500 8764.65' TVD I I 2000 TVD 8514.73 -2718.71 8776.15 -3044.43 8781.01 -3085.42 8784.65 -3147.24 8784.65 -3150.29 8784.73 -3552.50 8784.65 -3563.70 8774.82 -3996.09 8764.65 -4198.58 +N!-S 419858 ·3]4124 -3563.70 TVD 8764.65 8784.65 8784.65 (18-03A) I 1600 CASING DETAILS No. TVD MD Name 1 8764.65 1857.86 4112' Ii: ~ . 5Z.07' ¥D' 8 I ¡ ""'~" !.: !, '. --............:. U--. : I +--L1 , ¡, I I: ¡[--..l.o---w.. n--Q!.. ¡, ==tit!. II I i. TDtal Depth ' i 1-, ~ I : . , . , I I I I Ii" I ¡ ¡ . '8-0'8 wpO : II I I I ,! , '______, 4 Ii i i 1¡lli Ii I ~Uli i I I I I ': i i8-o"" f' r-ò i I I I I ¡ I i I : ! III I 'I I I I I ' 'I , " , , , I I : I ! I ¡ : ¡ i 'I I ¡ I I ' , , I ' I '~ : I I I I ~ : ! 'I I I :: : i ,I; I I ¡ i I '-+-i- i :" I 1200 : ; I I ¡ I I I 800 400 1East(+) [400ft/in] West(-) Narœ 18-03B 1'3 18-03B TI 18-03B 1'2 18-03A MD IDe Azi 9225.00 26.62 151.59 9705.79 84.26 148.06 9754.33 84.26 148.06 9826.93 89.99 149.00 9830.49 89.99 149.28 10298.32 89.99 149.28 10311.38 90.72 149.00 11052.07 90.72 104.55 11857.87 90.72 104.55 See 1 2 3 4 5 6 7 8 9 '''~ , -...yt'" ., ,/, .,. ",' RKBE. \Tf) ------ 10298.32' MD, 8784.7J 8514.73'TVD o All TVD depths are ssTVD plus 44.65'for -I I I 1 I j 1- I -t'l . 1 1'1 I I ¡ ¡ I î 1- ·800 -2800 -3200 '2 ~ o o ~ +' :c t: ~ '7' -3600 :c :; o VJ i - i f -4000 -4400 ) BP KW A Planning Report MAP Company: BP Amoco Field: Prudhoe Bay Site: PB DS 18 Well: 18-03A Wellpath: Plan 18-03B 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 Date: 4/16/2003 Time: 15:01 :48 Page: 1 Co-ordinate(NE) Reference: Well: 18-03A, True North Vertical (TVD) Reference: 44.65' 44.6 Section (VS) Reference: Well (0.00N,O.00E,162.52Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre BGGM2002 Site: PB DS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959213.15 ft 691583.44 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 35.252 N 148 26 55.555 W True 1.46 deg Well: 18-03A Slot Name: 03 18-03A Well Position: +N/-S 1466.16 ft Northing: 5960680.25 ft Latitude: 70 17 49.672 N +E/-W 58.86 ft Easting : 691604.91 ft Longitude: 148 26 53.839 W Position Uncertainty: 0.00 ft Well path: Plan 18-03B Principal: Yes Date Composed: Version: Tied-to: 18-03A 9225.00 ft Mean Sea Level 26.01 deg 80.85 deg Direction deg 162.52 4/15/2003 1 From: Definitive Path _,..__._M_____._.____ +N/-S ft 0.00 Drilled From: Tie-on Depth: 44.65 ft Above System Datum: Declination: Mag Dip Angle: +E/-W ft _,__,__.____~_._M_.._____,.·._·_...___.____·. 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 44.65' 4/15/2003 57555 nT Depth From (TVD) ft _·___·_____"_~____"·___·_,_____.____,_._·___.,,._.._.h_ 0.00 Height Plan: 18-03B wp01 Casing Points MD TVD Diameter Hole Size Name ft ft in in 11857.86 8764.65 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 9215.99 8506.65 TZ2 0.00 0.00 9480.66 8702.65 TZ1B 0.00 0.00 9595.63 8752.65 TZ1A 0.00 0.00 Targets Map Map <- Latitude -> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 18-03B T3 8764.65 -4198.58 1322.56 5956517.00 693034.00 70 17 8.378 N 148 26 15.309 W 18-03B T1 8784.65 -3147.24 -283.25 5957527.00 691402.00 70 17 18.719 N 148 27 2.092 W 18-03B poly 8784.65 -3385.85 -27.24 5957295.00 691664.00 70 17 16.372 N 148 26 54.632 W -Polygon 1 8784.65 -3385.85 -27.24 5957295.00 691664.00 70 17 16.372 N 148 26 54.632 W -Polygon 2 8784.65 -3673.39 303.56 5957016.00 692002.01 70 17 13.544 N 148 26 44.995 W -Polygon 3 8784.65 -4150.32 1744.95 5956576.00 693455.00 70 17 8.852 N 148 26 3.003 W -Polygon 4 8784.65 -4406.86 1605.36 5956316.00 693322.01 70 17 6.329 N 148 26 7.072 W -Polygon 5 8784.65 -4092.13 679.03 5956607.00 692388.01 70 17 9.426 N 148 26 34.056 W -Polygon 6 8784.65 -3790.49 -86.58 5956889.00 691615.00 70 17 12.393 N 148 26 56.361 W -Polygon 7 8784.65 -3376.75 -227.08 5957299.00 691464.01 70 17 16.462 N 148 27 0.455 W -Polygon 8 8784.65 -3385.98 -22.24 5957295.00 691669.00 70 17 16.371 N 148 26 54.487 W ) 'I ) BP KW A Planning Report MAP Company: BP Amoco Date: 4/16/2003 Time: 15:01 :48 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-03A, True North Site: PB DS 18 Vertical (TVD) Reference: 44.65' 44.6 Well: 18-03A Section (VS) Reference: Well (0.OON,O.OOE,162.52Azi) Wellpath: Plan 18-038 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <-- Latitude --> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 18-038 T2 8784.65 -3563.70 -35.77 5957117.00 691660.00 70 17 14.623 N 148 26 54.881 W 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 9225.00 26.62 151.59 8514.73 -2718.71 -541.16 0.00 0.00 0.00 0.00 9705.79 84.26 148.06 8776.15 -3044.43 -346.64 12.00 11.99 -0.74 -4.16 9754.33 84.26 148.06 8781.01 -3085.42 -321.09 0.00 0.00 0.00 0.00 9826.93 89.99 149.00 8784.65 -3147.24 -283.25 8.00 7.89 1.30 9.36 18-038 T1 9830.49 89.99 149.28 8784.65 -3150.29 -281.42 8.00 0.00 8.00 89.97 10298.32 89.99 149.28 8784.73 -3552.50 -42.47 0.00 0.00 0.00 0.00 10311.38 90.72 149.00 8784.65 -3563.70 -35.77 6.00 5.59 -2.18 -21.32 18-038 T2 11052.07 90.72 104.55 8774.82 -3996.09 542.68 6.00 0.00 -6.00 -89.70 11857.87 90.72 104.55 8764.65 -4198.58 1322.56 0.00 0.00 0.00 0.00 18-038 T3 Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 9215.99 26.01 152.18 8506.65 8462.00 5957952.25 691131.30 2426.59 0.00 0.00 TZ2 9225.00 26.62 151.59 8514.73 8470.08 5957948.78 691133.27 2430.51 7.35 336.41 MWD 9250.00 29.61 151.15 8536.77 8492.12 5957938.59 691139.18 2442.07 12.00 355.84 MWD 9275.00 32.61 150.79 8558.17 8513.52 5957927.46 691145.73 2454.73 12.00 356.22 MWD 9300.00 35.60 150.48 8578.87 8534.22 5957915.43 691152.92 2468.44 12.00 356.54 MWD 9325.00 38.60 150.21 8598.81 8554.16 5957902.52 691160.71 2483.18 12.00 356.80 MWD 9350.00 41.60 149.97 8617.93 8573.28 5957888.77 691169.09 2498.91 12.00 357.01 MWD 9375.00 44.59 149.76 8636.18 8591.53 5957874.23 691178.04 2515.57 12.00 357.19 MWD 9400.00 47.59 149.57 8653.52 8608.87 5957858.92 691187.53 2533.13 12.00 357.34 MWD 9425.00 50.59 149.40 8669.89 8625.24 5957842.90 691197.53 2551.53 12.00 357.47 MWD 9450.00 53.58 149.25 8685.25 8640.60 5957826.20 691208.02 2570.73 12.00 357.59 MWD 9475.00 56.58 149.10 8699.56 8654.91 5957808.87 691218.97 2590.68 12.00 357.68 MWD 9480.66 57.26 149.07 8702.65 8658.00 5957804.87 691221.51 2595.29 12.00 357.77 TZ18 9500.00 59.58 148.96 8712.78 8668.13 5957790.97 691230.35 2611.31 12.00 357.78 MWD 9525.00 62.58 148.84 8724.87 8680.22 5957772.53 691242.12 2632.57 12.00 357.84 MWD 9550.00 65.58 148.72 8735.79 8691.14 5957753.61 691254.26 2654.41 12.00 357.90 MWD 9575.00 68.57 148.60 8745.53 8700.88 5957734.26 691266.73 2676.76 12.00 357.95 MWD 9595.63 71.05 148.51 8752.65 8708.00 5957718.00 691277.25 2695.55 12.00 358.00 TZ1A 9600.00 71.57 148.49 8754.05 8709.40 5957714.53 691279.50 2699.57 12.00 358.03 MWD 9625.00 74.57 148.38 8761.33 8716.68 5957694.48 691292.54 2722.76 12.00 358.03 MWD 9650.00 77.57 148.28 8767.35 8722.70 5957674.16 691305.79 2746.29 12.00 358.07 MWD 9675.00 80.57 148.18 8772.09 8727.44 5957653.64 691319.24 2770.07 12.00 358.09 MWD 9700.00 83.56 148.08 8775.54 8730.89 5957632.95 691332.85 2794.05 12.00 358.11 MWD 9705.79 84.26 148.06 8776.15 8731.50 5957628.15 691336.01 2799.62 12.00 358.12 MWD 9754.33 84.26 148.06 8781.01 8736.36 5957587.83 691362.60 2846.39 0.00 0.00 MWD 9800.00 87.86 148.65 8784.15 8739.50 5957549.67 691387.48 2890.57 8.00 9.36 MWD 9826.93 89.99 149.00 8784.65 8740.00 5957527.00 691402.00 2916.72 8.00 9.32 18-03B T1 9830.49 89.99 149.28 8784.65 8740.00 5957523.99 691403.91 2920.19 8.00 89.97 MWD 9900.00 89.99 149.28 8784.66 8740.01 5957465.16 691440.92 2987.85 0.00 0.00 MWD 10000.00 89.99 149.28 8784.68 8740.03 5957380.52 691494.17 3085.20 0.00 0.00 MWD 10100.00 89.99 149.28 8784.70 8740.05 5957295.89 691547.42 3182.54 0.00 0.00 MWD 10200.00 89.99 149.28 8784.71 8740.06 5957211.25 691600.67 3279.89 0.00 0.00 MWD 10298.32 89.99 149.28 8784.73 8740.08 5957128.03 691653.02 3375.60 0.00 0.00 MWD 10300.00 90.08 149.25 8784.73 8740.08 5957126.61 691653.92 3377.24 6.00 338.68 MWD 10311.38 90.72 149.00 8784.65 8740.00 5957117.00 691660.00 3388.31 6.00 338.68 18-03B T2 ) ') BP KW A Planning Report MAP Company: BP Amoco Date: 4/16/2003 Time: 15:01 :48 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-03A, True North Site: PB DS 18 Vertical (TVD) Reference: 44.65' 44.6 Well: 18-03A Section (VS) Reference: Well (0.00N,0.00E,162.52Azi) Wellpath: Plan 18-03B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 10350.00 90.73 146.68 8784.16 8739.51 5957084.85 691681.38 3425.66 6.00 270.30 MWD 10400.00 90.74 143.68 8783.52 8738.87 5957044.55 691710.96 3473.38 6.00 270.27 MWD 10450.00 90.76 140.68 8782.86 8738.21 5957005.86 691742.61 3520.26 6.00 270.23 MWD 10500.00 90.76 137.68 8782.20 8737.55 5956968.87 691776.23 3566.16 6.00 270.19 MWD 10550.00 90.77 134.68 8781.53 8736.88 5956933.70 691811.75 3610.96 6.00 270.15 MWD 10600.00 90.78 131.68 8780.85 8736.20 5956900.43 691849.06 3654.54 6.00 270.11 MWD 10650.00 90.78 128.68 8780.17 8735.52 5956869.16 691888.06 3696.78 6.00 270.07 MWD 10700.00 90.78 125.68 8779.49 8734.84 5956839.98 691928.64 3737.56 6.00 270.03 MWD 10750.00 90.78 122.68 8778.81 8734.16 5956812.96 691970.70 3776.77 6.00 269.99 MWD 10800.00 90.77 119.68 8778.14 8733.49 5956788.18 692014.11 3814.31 6.00 269.95 MWD 10850.00 90.77 116.68 8777.46 8732.81 5956765.70 692058.76 3850.06 6.00 269.91 MWD 10900.00 90.76 113.68 8776.80 8732.15 5956745.60 692104.53 3883.94 6.00 269.87 MWD 10950.00 90.75 110.68 8776.14 8731.49 5956727.91 692151.28 3915.85 6.00 269.83 MWD 11000.00 90.74 107.68 8775.49 8730.84 5956712.70 692198.90 3945.70 6.00 269.79 MWD 11052.07 90.72 104.55 8774.82 8730.17 5956699.53 692249.26 3974.51 6.00 269.75 MWD 11100.00 90.72 104.55 8774.22 8729.57 5956688.67 692295.94 3999.93 0.00 0.00 MWD 11200.00 90.72 104.55 8772.96 8728.31 5956666.02 692393.32 4052.98 0.00 0.00 MWD 11300.00 90.72 104.55 8771.69 8727.04 5956643.37 692490.71 4106.03 0.00 0.00 MWD 11400.00 90.72 104.55 8770.43 8725.78 5956620.72 692588.09 4159.07 0.00 0.00 MWD 11500.00 90.72 104.55 8769.17 8724.52 5956598.07 692685.48 4212.12 0.00 0.00 MWD 11600.00 90.72 104.55 8767.91 8723.26 5956575.41 692782.87 4265.16 0.00 0.00 MWD 11700.00 90.72 104.55 8766.64 8721.99 5956552.76 692880.25 4318.21 0.00 0.00 MWD 11800.00 90.72 104.55 8765.38 8720.73 5956530.11 692977.64 4371.26 0.00 0.00 MWD I 11857.87 90.72 104.55 8764.65 8720.00 5956517.00 693034.00 4401.96 0.00 0.00 18-03B T3 P055057 ) '\ DATE 4/4/2003 CHECKNÕ~-' 055057 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 4/4/2003 INV# CK0401 03G PERMIT TO DRILL FEE \ß-O"bJ3 RECe\VED N f\'{ 13 2003 A1a~8or &GascQns.CQmm~ Anttont.ge THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRISED ABOVE. TOTAL ... BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 .' ANCHORAGE, AK9951~~6612 NATIQNAL CITY BANK Ashland, Ohio 56-389 412 No. P 055057 CONSOLIDATED COMMERCIAL ACCOUNT B. ::; ',:,': /':.::::~<,~"'",", ':,.,:. -::",.: ", "DATE:' Apf!l4,?OPi3 AMOUNT PAY: TO THE , ORDER OF: ".;' '. . .' ,,"> . ,::.' ' .',' . -.'i',: "', ',' ,:", :,' " ~ :', ' ' ,,,, ": ," ," '" , ",,",' '::,':', ,: . <. .,,:',' ,,:". ,::: \}:'/:. '~: .:(: , \::' '\ "":,:}¡,,,,'.: :',,::. :'.,:,:,"::,..,:, '<:)(::" ',;":, ALA~KA <?IL &.'GÂs GºNSËß\{~TldN GQty1MIS&ION:·/i,<. 333 W 7T~ A\t'EN~E SUITE 100":. ANCHORAGE,'ÄK 9~501-3539 ***.~1rt*$1 00.00******* ..' ': ~. .... . . . .. . .. . .., .... .. ' , ' :.'. . .','. ~', ,', ' '. " . - " ':-'." ,,",, :',,' - ,.,,1, :', ,<. NdTVALI!)~9:¡::J? '?ßD~~~~_..",."...;·;} ....... . n._ ::'\~:~\:::~:;'.":~'.~:::1:::':::::~:f:·:~:"~~.;'.'~~.':'~;:~~{~~"~~:~. :~~.~~.:.{:~}.~ ::....~.,.~;:..: ·,ff' "<", ,.},'~'~~~. ~:~":'~~"~"#":".. ~"... ;-.# ":\..~ ........ ~. ~:l t;.;<...,..."..:~,....." '(, , ...t,¡þI t r~~:.?:~:.~::.: :;:.:~·:·:Ù'.·· /f:'~~1~~Ù~~:j3~tj;:?~:~~~\:: /i III 0 5 SO 5 7 III I: 0 L. . 20 j 8 c¡ 5 J: 0 ~ 2 ? 81i b III Rev: 07/10/02 C\jody\templates ) ~ f TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMiTTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to· be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number· (50 70/80) from. records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY AfJ )¿ WELL NAME pß l-( /? -0 ~ ß FIELD & POOL ~ 0/0/1; C> INIT CLASS /Jt".d / -~#ï ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located wlin area & strata authorized by injection order#_ (Service Well Only) 14. All wells wlin % mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE IlL- -ç/JaJh~ APPR DATE WGA- Sl(~'()~ (Service Well Only) GEOLOGY APPR DATE 4/ S 113 It:> ~ (Exploratory OnTy) 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. '. . . . . . 21. Adequate tankage or reserve pit.. . . . . . ., . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. . . . . . . . '. . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to~3 ~ 00 psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Sèismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. ...... PROGRAM: Exp _ Dev -X Redrll ~ Re-Enter _ Sarv _ Wellbore seg _ GEOL AREA ~7 <:) UNIT# /I~ 5"1") ON/OFF SHORE..t:JL!J 0N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N Y Y AJ,~· YN @~ -Y N AJ/A- Y N ,,J/~ I,. ~ N"-Þ\?v""- 1.. E~ . N "St11()~' N ¡Jllt- ~ ¡V/"I.-¢ {ll/k./ ~. 7 ff'i . ~~. ~ ~ ~ n1 ~p .,~ 4~ -8 -j7Ýl,. ~~ --¥--N-N/k- ~~ N ,>9, 't N N ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/Instructions: RP~ TM JH JR ::WQ /' MW DSOSjI3/ÓÝ SFD_ WA Rev: 2/25/03 \weltyerm it_checklist ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennilting Process but is part of the history file. To improve the readability of the Well History file and to sim'plify finding infomlation. 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 ,Dr_ 2ing services LIS Scan Utility ) B.,03-D8(., (1 BO 7 $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 30 14:29:58 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .03/06/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 18-03B 500292077602 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 30-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MM0002488472 J. BOBBITT R. BORDES / MWD RUN 3 MM0002488472 J. SACK R. BORDES / MWD RUN 4 MM0002488472 J. SACK J. RALL / D. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 24 11N 14E 1184 161 44.65 16.15 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 9214.0 # REMARKS: ) ) 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 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK (THE TOP OF WHICH WAS AT 9214'MD/8505'TVD) - NO RUN 1 DATA ARE PRESENTED. TIE-IN SGRC DATA OVER THE INTERVAL 9004'MD TO 9228'MD WERE ACQUIRED WHILE RIH FOR RUN 2 AND ARE PRESENTED WITH RUN 2 DRILLED DATA. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND AT-BIT INCLINATION (ABI). MWD RUNS 2 & 3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY ( S LD) . 4. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED 6' DEEPER PER E-MAIL FROM D. SCHNORR DATED 6/27/03. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 5. MWD RUNS 2 - 4 REPRESENT WELL 18-03B WITH API#: 50-029-20776-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11823'MD/8760'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 SIZES: 6.0" MUD WEIGHT: 8.7 PPG MUD SALINITY: 11000 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: $ b. '~STONE ) File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/30 Maximum Physical Record. .65535 F i I e 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 FET RPX RPS RPM RPD NPHI FCNT NCNT PEF DRHO RHOB ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8958.0 9206.0 9206.0 9206.0 9206.0 9206.0 9206.0 9206.0 9206.0 9218.5 9218.5 9218.5 9239.5 STOP DEPTH 11766.0 11773.5 11773.5 11773.5 11773.5 11773.5 10851.0 10851.5 10851.0 10865.0 10865.0 10865.0 11829.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 8958.0 11829.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 8952.0 11823.5 BIT RUN NO 2 3 4 MERGED MAIN PASS. $ MERGE TOP 8952.0 9512.0 10927.0 MERGE BASE 9512.0 10927.0 11823.5 # 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 Name Service Order DEPT ROP MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 '1 ) GR MWD API 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8958 11829.5 10393.8 5744 8958 11829.5 ROP MWD FT/H 0.04 5646.08 56.5307 5181 9239.5 11829.5 GR MWD API 9.99 344.58 53.305 5617 8958 11766 RPX MWD OHMM 0.36 1680.04 109.67 5136 9206 11773.5 RPS MWD OHMM 0.63 2000 209.986 5136 9206 11773.5 RPM MWD OHMM 0.51 2000 273.701 5136 9206 11773.5 RPD MWD OHMM 10.92 2000 419.363 5136 9206 11773.5 FET MWD HOUR 0.52 43.17 3.12727 5136 9206 11773.5 NPHI MWD PU-S 9.39 35.01 22.3932 3291 9206 10851 FCNT MWD CNTS 370 1621 711.507 3292 9206 10851.5 NCNT MWD CNTS 22880 37350 30306.8 3291 9206 10851 RHOB MWD G/CM 1.729 3.782 2.32994 3294 9218.5 10865 DRHO MWD G/CM -0.671 1.287 0.0176002 3294 9218.5 10865 PEF MWD BARN 0.82 14.47 1.92158 3294 9218.5 10865 First Reading For Entire File......... .8958 Last Reading For Entire File.......... .11829.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/30 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...... .03/06/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 2 header data for each bit run in separate files. 2 .5000 VENDOR TOOL CODE GR FCNT RPX NCNT RPS RPM RPD FET NPHI PEF DRHO RHOB ROP $ 1TH STOP DEPTH 9457.0 9431.0 9464.0 9431.0 9464.0 9464.0 9464.0 9464.0 9431.0 9444.0 9444.0 9444.0 9512.0 START 8952.0 9200.0 9200.0 9200.0 9200.0 9200.0 9200.0 9200.0 9200.0 9212.5 9212.5 9212.5 9233.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR 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 ) 15-JUN-03 Insite 66.37 Memory 9512.0 9233.0 9512.0 25.9 56.4 TOOL NUMBER 129046 110059 100983 159439 6.000 9214.0 QUIKDRIL-N 8.70 47.0 8.6 11000 5.6 .480 .220 .380 .570 65.0 150.0 65.0 65.0 Data Specification Block fpe.....o Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 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 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 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 8952 9512 9232 1121 8952 9512 ROP MWD020 FT/H 0.04 119.28 24.3789 558 9233.5 9512 GR MWD020 API 9.99 344.58 32.0735 1011 8952 9457 RPX MWD020 OHMM 0.36 1680.04 81.0878 529 9200 9464 RPS MWD020 OHMM 0.63 2000 318.084 529 9200 9464 RPM MWD020 OHMM 0.51 2000 643.115 529 9200 9464 RPD MWD020 OHMM 10.92 2000 1027.12 529 9200 9464 FET MWD020 HOUR 1.85 43.17 8.14439 529 9200 9464 NPHI MWD020 PU-S 9.39 28.02 16.8773 463 9200 9431 FCNT MWD020 CNTS 494 1621 937.978 463 9200 9431 NCNT MWD020 CNTS 24291 37350 30349.4 463 9200 9431 RHOB MWD020 G/CM 1.729 3.782 2.24027 464 9212.5 9444 DRHO MWD020 G/CM -0.671 1.287 0.00717888 464 9212.5 9444 PEF MWD020 BARN 0.9 14.47 2.38274 464 9212.5 9444 First Reading For Entire File......... .8952 Last Reading For Entire File.......... .9512 File Trailer Service name............ .STSLIB.002 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation... ... .03/06/30 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/30 Maximum Physical Record. 1535 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 NCNT FCNT NPHI RHOB DRHO PEF GR RPX RPS RPM RPD FET ROP $ 3 ) header data for each bit run in separate files. 3 .5000 START DEPTH 9431.5 9431.5 9431.5 9444.5 9444.5 9444.5 9457.5 9464.5 9464.5 9464.5 9464.5 9464.5 9512.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 10845.0 10845.5 10845.0 10859.0 10859.0 10859.0 10872.0 10879.0 10879.0 10879.0 10879.0 10879.0 10927.0 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: # 17-JUN-03 Insite 66.37 Memory 10927.0 9512.0 10927.0 58.5 96.4 TOOL NUMBER 129046 110059 100983 159439 6.000 9214.0 QUIKDRIL-N 8.70 43.0 8.5 900 6.3 .520 .290 .510 .600 70.0 133.0 70.0 70.0 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 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 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9431.5 10927 10179.3 2992 9431.5 10927 ROP MWD030 FT/H 0.06 194.94 65.5897 2830 9512.5 10927 GR MWD030 API 16.48 164.63 57.6832 2830 9457.5 10872 RPX MWD030 OHMM 8.7 1189.14 109.888 2830 9464.5 10879 RPS MWD030 OHMM 8.69 2000 223.101 2830 9464.5 10879 RPM MWD030 OHMM 9.07 2000 274.662 2830 9464.5 10879 RPD MWD030 OHMM 11.33 2000 435.848 2830 9464.5 10879 FET MWD030 HOUR 0.52 13.95 2.2405 2830 9464.5 10879 NPHI MWD030 PU-S 15.26 35.01 23.2963 2828 9431.5 10845 FCNT MWD030 CNTS 370 1038 674.442 2829 9431.5 10845.5 NCNT MWD030 CNTS 22880 35171 30299.8 2828 9431.5 10845 RHOB MWD030 G/CM 2.086 3.071 2.34464 2830 9444.5 10859 DRHO MWD030 G/CM -0.108 0.629 0.0193088 2830 9444.5 10859 PEF MWD030 BARN 0.82 6.87 1.84596 2830 9444.5 10859 First Reading For Entire File......... .9431.5 Last Reading For Entire File.......... .10927 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/30 Maximum Physical Record. J!535 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...... .03/06/30 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 RPD RPM RPX FET GR RPS ROP $ 4 ) header data for each bit run in separate files. 4 .5000 START DEPTH 10872.0 10872.0 10872.0 10872.0 10872.5 10879.5 10927.5 # 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: # STOP DEPTH 11767.5 11767.5 11767.5 11767.5 11760.0 11767.5 11823.5 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) 19-JUN-03 Insite 66.37 Memory 11823.0 10927.0 11823.0 86.7 93.2 TOOL NUMBER 129046 159439 6.000 9214.0 QUIKDRIL-N 8.70 41.0 8.8 9500 6.5 MUD MUD MUD MUD AT MEASURED Th. '1RATURE (MT): AT MAX CIRCULATING TERMPERATURE: FILTRATE AT MT: CAKE AT MT: 1.460 .740 1.440 1.480 ) I Vi. 0 144.0 70.0 70.0 # 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.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10872 11823.5 11347.8 1904 10872 11823.5 ROP MWD040 FT/H 0.56 5646.08 52.2383 1793 10927.5 11823.5 GR MWD040 API 33.58 257.67 58.4148 1776 10872.5 11760 RPX MWD040 OHMM 14.99 235.09 117.344 1791 10872 11767.5 RPS MWD040 OHMM 18.18 559.68 156.918 1777 10879.5 11767.5 RPM MWD040 OHMM 24.65 1935.44 161.886 1791 10872 11767.5 RPD MWD040 OHMM 38.91 1780.8 211.759 1791 10872 11767.5 FET MWD040 HOUR 0.98 20.75 3.15828 1791 10872 11767.5 First Reading For Entire File......... .10872 Last Reading For Entire File.......... .11823.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/30 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF ) ) Tape Trailer Service name............ .LISTPE Da te . . . . . . . . . . . . . . . . . . . . . 03/06/30 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 Da te . . . . . . . . . . . . . . . . . . . . . 03/06/30 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
