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Home My WebLink About197-072 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 IN 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. 1/23/2012 197 - 072 311 - 374 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 5/18/1997 50 029 - 21755 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 5/22/1997 PBU 18 -15B 813' FNL, 311' FWL, SEC. 19, T11 N, R15E, UM 8. KB (ft above MSL): 48 15. Field / Pool(s): Top of Productive Horizon: 1523' FNL, 2673' FWL, SEC. 19, T11 N, R15E, UM GL (ft above MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 3158' FNL, 4170' FWL, SEC. 19, T11 N, R15E, UM 9024' 8479' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 692067 y 5961063 Zone ASP4 11818' 8753' ADL 028321 TPI: x - 694447 y 5960414 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 695985 Y 5958818 Zone ASP4 None 18. Directional Survey: 0 Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, GR 9024' 8479' 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" 1680# Poleset 13 -3/8" 72# L -80 Surface 2686' Surface 2686' 17 -1/2" 2500 sx CS III. 550 sx CS II 9 -5/8" 47# L -80 Surface 8175' Surface 7808' 12 -1/4" 500 sx Class 'G' 7" 29# L -80 2410' 9547' 2410' 8721' _ 8 -1/2" 625 sx Class 'G'. 869 sx Class 'G' 4 -1/2" 12.6# L -80 9384' 10110' 8695' 8740' 6" Uncemented Slotted Liner 2 -7/8" 6.5# L -80 10030' 11818' 8733' _ 8753' 3 -3/4" Uncemented Slotted Liner 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# 13CR / L -80 8596' 8376' / 7963' MD TVD " s' .EID✓D 8536' / 8090' °� ACID, FRACTURE, CEMENT SQUEEZE, E TC. FEB �� D PTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 4 9060' Set Posiset Plug ! 9043' 8 Gal Cement Alas ° &Gds ns c m f IS , ! 9 Set Whipstock ,/ �11CI11JC3 ----1 27. - "- �- PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes 0 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 laboratory analytical results per 20 AAC 250.071. None ��/y� S � F EB 9 ZU1�Z RBDMS FEB 15 1 11_ ' ` Form 10-407 Revised 12/2009 CONTINUED ON REVERSE /4' z /zq / /L.. Original Only 6 • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. RMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit / Z1 B 9272' 8643' None TDF / Z1A 9378' 8693' Base Sadlerochit 10095' 8739' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that th ?going • t e - d . rr ct to the best of my knowledge. Signed: Joe Lastu � \ t � itle: Drilling Technologist Date: 2 / 1 i fii PBU 18 -1 197 -072 311 -374 Prepared By Name/Number Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Zach Sayers, 564 - 5790 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 -15B, Well History (Pre Rig Sidetrack) Date Summary 12/10/11 WELL SHUT IN ON ARRIVAL. INITIAL T /I /O = 0/240/0 PSI. ET 2.13" POSISET PLUG AT 9060' MID - ELEMENT DEPTH REFERENCED TO SLB RST LOG DATED 4- NOV -99 AS PER THE PROGRAM. SLACKED OFF TO CONFIRM SET. RAN OUT OF TIME TO RUN CEMENT DUMP BAILERS DUE TO 16HR RULE, LAY DOWN FOR NIGHT AND RETURN IN MORNING TO DUMP CEMENT. INFORMED DSO OF SITUATION, SECURED LOCATION FOR NIGHT, RETURN IN MORNING. 12/11/11 DUMEEL ZW RAI RS ONTAINING 8 GALLONS OF CEMENT TOTAL ON TOP OF PLUG AT 9060'. TAGGED PLUG LIGHTLY ON FIRST DUMP TO CONFIRM PLUG STILL THERE. DEPTH CORRECTED TO SLB RST LOG DATED 4- NOV -99. FINAL T /I /O 0/240/0. LEFT WELL SHUT -IN AND HUNG TAG ON WING TO NOT FLOW UNTIL CEMENT IS CURED. HAND OVER WITH DSO PRIOR TO DEPARTURE. JOB COMPLETE. 12/14/11 WELL S/I ON ARRIVAL. RIG UP TO DRIFT TO 9,060' ELM W/ 3.70" x 20' DUMMY WHIPSTOCK. 12/15/11 TAGGED TOC © 9,043' SLM W/ 3.70" x 20' DUMMY WHIPSTOCK (No issues). WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 12/16/11 T/I/O= 0/100/0. MIT -T PASSED to 1000 psi. (CTD Prep) Pumped 5 bbls neat methanol, followed by 4.75 bbls dsl down Tbg to reach test pressure for MIT -T. Tbg lost 7 psi in the 1st 15 min and 3 psi in the 2nd 15 min for a total pressure loss of 10 psi in 30 mins. Bled Tbg to 0 psi (2 bbls). DSO notified of well status. FWHP= 0/120/0. 12/18/11 WELL SHUT -IN ON ARRIVAL. INITIAL T /I /O 0/240/0 ATTEMPTED TO RUN A WHIPSTOCK, ABLE TO RIG UP BUT HAD TO CANCEL OPERATIONS DUE TO TWO TRIPLEX FAILURES INHIBITING ABILITY TO GET A PRESSURE TEST. LAID UNIT DOWN FOR NIGHT, LEAVE SPOTTED, RETURN IN MORNING TO ATTEMPT AGAIN. DSO NOTIFIED WELL SECURE. 12/19/11 WELL SHUT -IN ON ARRIVAL. INITIAL T /I /O 0/240/0 RAN BAKER 4.5" x 7" THRU TUBING WHIPSTOCK TO 9020' DEPTH CORRECTED TO SLB RST LOG DATED 4- NOV -99. WS HAS TWO PIP vs l, 5 TAGS INSTALLED BY BAKER. WS SERIAL # H150 -50 -7010. SET TOP OF WS AT 9020' AS PER PROGRAM. ORIENTATION OF WS IS 144.4° LEFT OF HIGH SIDE. SLACKED OFF TO CONFIRM SET. POOH. LEFT WELL SHUT -IN, HAND OVER WITH DSO PRIOR TO DEPARTURE. FINAL T /I /O 0/240/0. JOB COMPLETE. 01/11/12 T /I /O =SSV /240 /Vac. Temp= SI. Bleed WHPs to 0 psi (Pre CTD). No AL. IA FL © surface. Flow line and well house have been removed. Unable to determine TP due to SSV being inoperable. Bled IAP from 240 psi to 2 psi in 2.5 hrs. (20 gals fluid /gas). Monitored for 30 mins. IAP increased to 10 psi. Job complete. 01/14/12 T /I /O = SSV /75 /VAC. Temp = SI. Bleed IAP to -0 psi (pre CTD). No AL. Flowline and wellhouse removed. Integral installed on IA. Bled IAP to 0+ in 15 min all gas. Monitored for 15 min. IAP increased 10 psi. Job complete. Final WHPs = SSV /10 /VAC. 01/15/12 T /I /O= 40 /60Nac. Temp= SI. WHPs (Pre CTD). No AL. Flowline and well house have been removed. Integral installed on IA. IA increased 50 psi over night. LOTO on master valve has been removed. 01/15/12 T /I /O= 200/0/0 TEMP= SI RG 2401 (SURFACE CASING CORR MITIGATION) PJSM. SET UP HYDRO VAC AND JOB SITE. START AND COMPLETE EXCAVATION ON WELL CELLAR. RDMO. VOID= 18 ". DUST COVER. T /I /0= 200/0/0 TEMP= SI RG 2401 (SURFACE CASING CORR MITIGATION) PJSM. SET UP TRAILER AND JOB SITE. STRAP CONDUCTOR Q 18 ". INSTALL SPILL CONTAINMENT. PUMP 11.05 GALLONS RG2401 TO FILL VOID. RDMO. DUST COVER. 01/16/12 T /I /0= 40 /60Nac. Temp= SI. Bleed T & IA to -0 psi (Pre CTD). Bled TP from 40 psi to 0 psi in 3 mins. (Gas and fluid). Bled IAP from 60 psi to 0 psi in 5 mins. IAP increased to 10 psi within 15 mins. Held open bleed on IAP for 3 hrs (All gas). Monitored for 30 mins. TP increased to 2 psi and IAP increased to 12 psi. FWHPs = 2/12 /Vac. Page 1 of 2 • 18 -15B, Well History (Pre Rig Sidetrack) Date Summary 01/19/12 T /I /O= 7/68 /Vac. Temp= SI. Bleed T & IA to -0 psi (CTD prep). No AL, flowline, or wellhouse. Bled TP from 7 psi to 0+ psi in 20 mins (gas). Bled IAP from 68 psi to 0 psi in 1 hr. Monitored for 30 mins. TP increased 1 psi & IAP increased 13 psi. Job complete. Final WHPs= 1 /13Nac. Page 2 of 2 • • N arth America - ALASKA -. BP Pale s Operati ©n Summary Report Common Well Name: 18 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/20/2012 End Date: X3- 0116N -C: (2,268,182.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 2 Spud Date/Time: 10/1/1987 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292175500 Active Datum: ORIG KELLY BUSHING @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/20/2012 12:00 - 18:00 6.00 MOB N WAIT PRE CONTINUE TO STANDBY ON W -PAD. CONTINUE TO MOVE EQUIPMENT TO DS 18. WAITING ON SECURITY TO COMPLETE KENAI CAMP MOVE TO KUPARUK. 18:00 - 20:30 2.50 MOB N WAIT PRE CREW CHNAGE, CHECK RIG EQUIPMENT. CONTINUE TO WAIT ON SECURITY FOR RIG MOVE. TOUR PUSHER AND DRILLER DROVE ROUTE TO W -PAD- TO INSPECT ROAD CONDITIONS FOR RIG TRAVEL. 20:30 - 21:00 0.50 MOB P PRE PJSM FOR RIG MOVE WITH SECURITY, DRILL CREW, NORDIC FIELD SUPERINTENDANT, WSL, TOUR PUSHER, SLB. REVIEW SOP AND ROUE INSPECTION. 21:00 - 00:00 3.00 MOB P PRE MOVE RIG FROM W -PAD TO DS18. 1/21/2012 00:00 - 05:30 5.50 MOB P PRE MOVE RIG TO DS18. 05:30 - 07:30 2.00 MOB P PRE CREW CHANGE. RIG STOPPED AT PRICE PAD TO ALLOW FIELD CHANGEOUT. DISCUSS RIG STATUS. 07:30 - 12:00 4.50 MOB P PRE CONTINUE TO MOVE RIG TO DS 18. RIG AT CENTRAL POWER STATION. 12:00 - 16:00 4.00 MOB P PRE CONTINUE RIG MOVE TO DS 18. ARRIVE AT DS18 AT 1600 HRS. COMPLETE WELL TRANSFER PERMIT WITH DSO. 16:00 - 20:30 4.50 MOB P PRE PJSM FOR BACKING RIG OVER WELL WITH - WSL, NORDIC FS, TP, DSO AND CREWS. SET RIG MATS IN PLACE. ALIGN RIG AND BACK OVER DS18 -15C. SET RIG DOWN. RIG ACCEPTED AT 20:30 20:30 - 22:00 1.50 RIGU P PRE BERM IN CELLAR, SPOT SATTELITE CAMP, SET LANDINGS AND WALKWAYS. R/U TRANSDUCES TO IA AND OA. R/U VALVE GUARDS ON THE SAME. SPOT RIG EQUIPMENT AS IT SHOWS UP FROM W -PAD. HARDLINE CREW ON LOCATION - R/U FLOWBACK TANK AND HARDLINE. R/U SATTELITE POWER. 22:00 - 22:45 0.75 BOPSUR P PRE PJSM, N/D TREE CAP, N/U BOPE. 22:45 - 00:00 1.25 BOPSUR P PRE PJSM WITH CH2MHILL. LIFT REEL INTO REELHOUSE. CONTINUE WU BOPE. 1/22/2012 00:00 - 01:15 1.25 BOPSUR P PRE CONTINUE N/U BOPE. 01:15 - 04:15 3.00 RIGU P PRE RJSM, R/U REEL HARDLINE AND BULKHEAD. HARDLINE CREW CONTINUES TO SPOT FLOWBACK TANK AND R/U HARDLINE. PT HARDLINE. R/U SUPPORT EQUIPMENT. Printed 1/30/2012 1:57:11PM orb Alilerica ALASKA BP page 2'44714 Operation Summary Report Common Well Name: 18 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/20/2012 End Date: X3- 0116N -C: (2,268,182.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 2 Spud Date/Time: 10/1/1987 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292175500 Active Datum: ORIG KELLY BUSHING ©48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:15 - 04:40 0.42 RIGU P PRE CONDUCT H2S RIG EVACUATION DRILL. MUSTER IN PRIMARY SAFE AREA AT SATTELITE OFFICE. NOTIFY DSO OF DRILL. EVERYONE ACCOUNTED FOR- CONDUCT AAR. GOOD JOB BY ALL, FLOORHAND SHOWED UP WITH SCBA- SCS NOTIFYED VAC TRUCK DRIVERS TO REMAIN AT SIGN IN SHACK. EVAC SIREN HEARD BY EVERYONE. 04:40 - 06:00 1.33 RIGU P PRE FILL PITS WITH 8.6 PPG RECONDITIONED DRILLING MUD. 580 BBLS MUD DELIVERED. PJSM, PREP COIL TO PULL ACCROSS. 06:00 - 06:30 0.50 RIGU P PRE CREW CHANGE. DISCUSS CURRENT OPS AND RIG STATUS. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. CONTINUE TO PREP TO PULL COIL ACROSS. 06:30 - 09:30 3.00 RIGU P PRE PULL AND STAB COIL. 09:30 - 11:30 2.00 RIGU P PRE MU E -COIL HEAD. TEST SAME (PT, PRESS, COND) 11:30 - 13:30 2.00 RIGU P PRE CIRCULATE COIL. PUMP 10 BBLS MEOH, 15 BBLS FRESH WATER. CHASE WITH DRILLING MUD. 13:30 - 18:00 4.50 BOPSUR P PRE SHELL TEST BOPS. BEGIN COMPLETE BOP TEST PROCEDURE. TEST ALL EQUIPMENT AS PER AOGCC REGS, PERMIT TO DRILL, AND BP GUIDELINES. e v P CHART RECORD TESTS. {- TEST WITNESS WAIVED BY JOHN CRISP, i AOGCC INSPECTOR. PERFORM ACCUMULATOR DRAWDOWN TEST. 18:00 - 18:30 0.50 BOPSUR P PRE CREW CHANGE, DISCUSS CURRENT RIG OPS. CHECK EQUIPMENT. 18:30 - 19:20 0.83 BOPSUR P PRE PUMP SLACK FORWARD 3.8 BPM 3300 PSI. 19:20 - 20:20 1.00 BOPSUR P PRE PRESSURE TEST INNER REEL VALVE, PACKOFF AND BULKHEAD - TO 250/3500 PSI 5 MIN EACH. CHART RECORD TEST. 20:20 - 22:00 1.67 BOPSUR P PRE PJSM, DISCUSS POTENTIAL FOR COIL FREEZE UP. -35 DEG. BLOW DOWN KILL LINE. CIRULATE COIL. INSTALL AND TEST DFCV- TO 250/3500 PSI. CHART TEST. Printed 1/30/2012 1:57:11PM orth America - AL.A8KA- BP Page 3 Operation Summary Report Common Well Name: 18 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/20/2012 End Date: X3- 0116N -C: (2,268,182.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 2 Spud Date/Time: 10/1/1987 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292175500 Active Datum: ORIG KELLY BUSHING @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 22:30 0.50 BOPSUR P PRE H2S RIG EVACUATION DRILL- CONDUCT AAR. WHAT WENT RIGHT- ALL HANDS ACCOUNTED FOR. RESONDED IN A TIMLEY MANNER TO MUSTER AREA. WIND DIRECTION WAS IDENTIFIED, SCS NOTIFIED NON RIG PERSONEL. WHAT WENT WRONG- DOGHOUSE RIG EVAC ALARM FAILED TO WORK IN -36 DEG WEATHER, ALTERNATE ALARMS WERE SOUNDED AND A GIATRONICS ANNOUNCMENT WAS MADE. DSO HARMONY NUMBER WAS DIFFERENT DUE TO NEW RELEIF ON SLOPE. LESSONS LEARNED- ALWAYS BE PREPARED FOR THE UNEXPECTED - EVEN THOUGH 1 ALARM DIDN'T SOUND THERE ARE ALTERNATE ALARMS TO USE. HARMONY NUMBERS FOR DSO HAVE CHANGE DUE TO THERE CREW CHANGE - THEY WERE STILL ABLE TO BE NOTIFIED. SCS TO VERIFY DSO HARMONY NUMBERS. 22:30 - 23:40 1.17 BOPSUR P PRE PJSM FOR PULLING TWC VALVE WITH VALVE CREW, WSL DRILL CREW AND TP. REVIEW SOP FOR PULLING TWC. LOAD LUBRICATOR ONTO RIG. R/U LUBRICATOR AND TOOLS. CLOSE SSV, OPEN SWAB. STAB LUBRICATOR. 23:40 - 00:00 0.33 BOPSUR P PRE PRESSURE TEST LUBRICATOR AGAINST CLOSED SSV AND MASTER VALVE TO 250/3500 PSI. CHART RECORD TESTS. OPEN SSV AND MASTER VALVE. 1/23/2012 00:00 - 00:30 0.50 BOPSUR P PRE PULL TWC VALVE. NO WHP OBSERVED., CLOSE MASTER AND SSV. 00:30 - 00:50 0.33 BOPSUR P PRE PRESSURE TEST AGAINST CLOSED BARRIERS TO 250/3500 PSI. CHART TEST. 00:50 - 01:15 0.42 BOPSUR P PRE UD TOOLS AND LUBRICATOR. 01:15 - 01:30 0.25 BOPSUR P PRE INSTALL LUBRICATOR CAP. CLOSE SWAB VALVE. OPEN SSV. INSTALL FUSABLE CAP. LOAD OUT TOOLS. 01:30 - 02:00 0.50 BOPSUR P PRE SHUT IN CHOKE, PRESSURE TEST LUBRICATOR CAP TO 250/3500 PSI. CHART TEST. OPEN MASTER AND SWAB VALVES. NO WHP. OPEN MANUAL CHOKE. 02:00 - 02:40 0.67 BOPSUR P PRE FLOWCHECK WELL FOR 30 MIN. STATIC. PJSM FOR P/U WINDOW MILL BHA. 02:40 - 03:15 0.58 BOPSUR N SFAL WEXIT PREP TO P/U WINDOW MILL BHA. R/U AIR TO CHECK FLOWBACK LINE. FLOWBACK LINE FROZEN. - 45 AMBIENT TEMP FROZE BELOW FLOOR- ICE PLUG. FLUID PACK WITH METHONAL. 03:15 - 04:00 0.75 STWHIP P WEXIT M/U WINDOW MILL BHA # 1. 3.80" DSM, 3.79" STRING MILL, 2 7/8" XTREME MOTOR, XO, 2 JTS 2 3/8" PH6, XO, XO, BS, DGS, DPS, EDC, PC, SWP, LQC, UQC, XO, CTC. M/U INJECTOR. TEST QTS. Printed 1/30/2012 1:57:11 PM *North America - ALASKA - BP Page 4 c Operation Summary Report Common Well Name: 18 -15 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/20/2012 End Date: X3- 0116N -C: (2,268,182.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 2 Spud Date/Time: 10/1/1987 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292175500 Active Datum: ORIG KELLY BUSHING @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 06:00 2.00 STWHIP P WEXIT RIH PUMPING MIN RATE, TAKE DIESEL RETURNS TO TIGER TANK. STRAP RETURNS IN TIGER TANK EVERY 1000' 06:00 - 06:30 0.50 STWHIP P WEXIT CREW CHANGE. DISCUSS..CURRENT OPERATION ...MAKE.EQUIPMENT.CHECKS.INS IDE. AND..OUTSI DE..RIG. CONTINUE TO RIH. 06:30 - 08:30 2.00 STWHIP P WEXIT RUN IN HOLE TO 9039' DISPLACE WELL TO USED DRILLING MUD (POWER VIS) 2552 PSI AT 2.49 BPM IN. 08:30 - 09:30 1.00 STWHIP P WEXIT LOG GR TIE IN TO PDC LOG. SUBTRACT 13' CORRECTION. rO 09:30 - 10:30 1.00 STWHIP P WEXIT GET SLOW CIRC RATE FOR PUMPS. RIH AND TAG WHIPSTOCK AT 9024.4' 41K# UP, 21K# DN. 2960 PSI FS AT 2.60 BPM IN. 10:30 - 14:00 3.50 STWHIP P WEXIT MILL WINDOW FROM 9023.7' SktNe 2960 PSI FS AT 2.6 BPM IN/OUT. k9 -15C. TIME MILL AT 1' PER HOUR. MTR WORK SLOWLY INCREASING. MILL AT 3150 -3200 PSI AT 2.60 BPM. MILL TO 9026.4' 14:00 - 18:00 4.00 STWHIP P WEXIT MILL AHEAD TO 9030'. 3050 PSI FS AT 2.58 BPM IN/OUT. 150 -300 PSI MTR WORK. 2.5 -3.5K# DHWOB. 18:00 - 18:30 0.50 STWHIP P WEXIT CREW CHANGE, DISCUSS CURRENT OPS. CHECK EQUIPMENT. 18:30 - 20:10 1.67 STWHIP P WEXIT CONTINUE MILLING WINDOW. MILL AHEAD FROM 9031.2'. DHWOB= 2 -2.5K. F /S= 2.6 BPM 2960 PSI WITH 340 PSI MOTOR WORK. IN/OUT= 2.6 BPM. PVT= 407 BBLS. I /A= 288 PSI. O /A= 338 PSI. MILL EXIT WINDOW AT 9032' FORMATION RETURNS NOTED AT SHAKER. 20:10 - 00:00 3.83 STWHIP P WEXIT CONTINUE MILLING 10' OF RATHOLE TO 9041' 1/24/2012 00:00 - 00:30 0.50 STWHIP P WEXIT MILL RATHOLE TO 9042' PUMPING 2.6 BPM 3420 PSI. DHWOB= 3.9K. ROP= 1.5 FPH. IN/OUT= 2.6 BPM. PVT= 403 BBLS. 00:30 - 01:30 1.00 STWHIP P WEXIT REAM- CLEANUP WINDOW MAKING 3 PASSES. DRY DRIFT WINDOW- CLEAN. TOW AT 9023.7' BOW AT 9031'. 01:30 - 01:40 0.17 STWHIP P WEXIT FLOWCHECKWELL. STATIC. PJSM FOR POH. OPEN EDC. 01:40 - 03:15 1.58 STWHIP P WEXIT POH PUMPING 3.15 BPM 3000 PSI. PERFORM 500' JOG AT SURFACE. 03:15 - 03:20 0.08 STWHIP P WEXIT FLOWCHECK AT SURFACE- STATIC. OPEN EDC, PJSM FOR BHA. PVT= 353 BBLS. 03:20 - 04:10 0.83 STWHIP P WEXIT SET BACK INJECTOR. UD WINDOW MILL BHA # 1 MILL= 3.79" GO, 3.78 NO GO. STRING MILL= 3.79" GO. 3.78" NO GO. LOAD OUT TOOLS. Printed 1/30/2012 1:57:11PM TREE= 4-1/16" CM/ WELLHEAD =, FMC • 18-15C , SAFETY NOS: WELL ANGLE > 70° a 9314' ACTUATOR = BAKER C *** 4-112" CHROME TBG*** KB. ELEV = 48' BF. ELEV = 13-3/8" CSG, H 78' —Pc KOP = 3350 68#, K-55 BTC, 0 2104' —14-1/2" HES HXO NIP1 ID = 3.813" Max Angle = 93° @ 11371' ID = 12.415" Datum MD = 13198' 1 2410' H9-5/8" X 7" BKR ZXP LTP, ID = 6.310' Datum - ND = 8800' SS 1 2428' 1_19-5/8" X 7" BKR FLEX-LOCK HGR, ID = 6.260" TOP OF 7" SCAB LNR — 2410 GAS LIFT MANDRELS III >. ST MD TV 0 DEV TY PE VLV LATCH PORT' DATE 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" I— 2687' i › 4 3008 3008 4 KBG2 DM/ BK 0 '05/14/11 ›.. Minimum ID = 2.377" @ 9364" >, 3 4752 4689 19 KBG2 DMY BK 0 05/14111 2 6375 6213 19 KBG2 DMY BK 0 04/24/05 3-3116" X 2-718" LNR PIN x I 21 7909 7605 38 KBG2 DMY BK 0 04/24/05 . ›.. 17" SCAB LNR, 26#, L-80 BTC-M, ID = 6.276" I-1 8021 8021' —17" BKR C.2 TIEBACK SLV, ID = 7.50" 8028' -- 19-5/8" X 7' BKR H PKR, 10 = 6.188" 8034' —19-5/8" X T BKR HMG HGR, ID = 6.26" 9-5/8" CSG. 47#, L-80 BTC-M, ID = 8.681" H 8175' I 9-5/8" CSG MILLOUT WNDOW (18-15A) • II 8355' 1H4 1/2" HES X NIP, ID = 3.813" I 8175' - 8225' (50' W/ SECTION MILL) Z X 8376' —17" X 4-1/2" BKR S-3 PKR, ID = 3.875" I p 8382' —13.70" DEPLOY SLV, ID = 3,00" I I 8399' _1H 4-1/7 HES X NIP, ID = 3.813" (BEHIND LNR 4-1/2" TBG, 12.6#, 13CR VAM TOP —1 8460' ) = N ' 8404' _13-1/2" X3-114" X0, ID = 2.786 .0152 bpf, ID 3.958" 1 8462' —I TUBING STUB (04/17/05) 1 BEHIND 4-1/2' TBG, 12 6#, L-80 NSCT, — 1 8595' .0152 bpf, ID = 3.958" ---------.... — 17" X 4-1/2" UNIQUE OVERSHOT 1 CT LNR X 8536' HT X 4-1/2" BKR S-3 PKR, ID = 3.875" PERFORATION SUMMARY r- I 1 8552' _14-1/2 HES XN NIP, MILLED TO 3.80" (1995) REF LOG: BEHIND A NGLE AT TOP PERF: ° ' N 8596' —14-1/2" WLEG, ID 4_00" CT LNR Note: Refer to Production DB for historical per data , SIZE - SPF INTERVAL 1 Opn/Sqz DATE • 8742' 1-17" MARKER JOINT ------------- ■ ' MILLOUT WINDOW (18 9024' - 9032' " LNR, 29#, L-80 NSCC, .0371 bpf, ID = 6.184" H – 9024 7" WHIPSTOCK (12/19/11) I 9024' 4Firipirdin _......-1 9365' 4" X 2-7/8" X0, ID = 2.377 COVIENT CAP- 8 GAL (12/11/11) — 9043' SLM , / ---- 2.13" POSISET PLUG (12/11/11) H 9060 3-1/4" L,* 6,6#, L-80 TCII, .0079 bpf, ID = 2.85" 9365' PBTO 11695' At *■r 2 LNR, 6.411, L STL, .0058 bpf, ID = 2.441" H 11730' ! ; DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT : 11103/87 ROW 41 ORIGINAL COMPLETION WELL: 18 05/20/95 N2ES SIDETRACK (18-15A) PERMIT No: "2111720 05/23/97 N4ES CTDSDTRACK (18-15B) AR No: 50 02/05/12 NORDIC 2 CT D SDT RACK (18 SEC 19, T11N, R15E, 813' FNL & 311' FVVL 02/06/12 PJC DRLG HO CORRECTIONS 02/07/12 ZJS/ PJC FINAL DRLG CORRECTIONS 1: BP Exploration (Alaska) ka) • • Ihtil 1E EF AliAsi,`{F , 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 1 1 7 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18 -15B Sundry Number: 311 -374 Dear Mr. McMullen: E 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. S'- ell 0 . f or an .m iss.ner DATED this 6 day of December, 2011. Encl. •4TE OF ALASKA iv 7 -// ALASKA OIL AND GAS CONSERVATION COMMISSION Ian! APPLICATION FOR SUNDRY APPROVAL DEC 0 6 nil 20 AAC 25.280 1. Type of Request: Alaska Gil & X88 Cons. COlIYTI►sgl011 ❑ Abandon IS Plug for Redrill ❑ Perforate New Pool = Repair Well ❑ Change ApprovedA § ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 197 - 072 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 21755 - 02 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18 -15B Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028321 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11818' 8753' 11818' 8753' None See Diagram Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2686' 13 -3/8" 2686' 2686' 4930 2670 Intermediate 8175' 9 -5/8" 8175' 7808' 6870 4760 Production Liner 7137' 7" 2410' - 9547' 2410' - 8721' 8160 7020 Liner 726' 4 -1/2" 9384' - 10110' 8695' - 8740' 8430 7500 Liner 1788' 2 -7/8" 10030' - 11818' 8733' - 8753' 10570 11160 . Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted & Perfd: 9433' - 11788' 8710' - 8751' 4 -1/2 ", 12.6# 13Cr / L -80 8596' Packers and SSSV Type: 7" x 4 -1/2" Baker 'S -3' packer Packers and SSSV 8376' / 7963' 7" x 4 -1/2" Baker 'S -3' packer MD (ft) and TVD (ft): 8536' / 8090' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory IS Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 9, 2011 ❑ Oil ❑ WINJ ❑ WDSPL E ' Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned ❑ WAG ❑ SPLUG iz6uspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Zach Sayers, 564 -5790 Printed Name Jo ( 07 n Title Engineering Team Leader j � -, (Z73:—/k Prepared By Name /Number: Signature �_C/ Phone 564 -4711 Date Terrie Hubble, 564 - 4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness - � I t �� / Sundry Number "� ❑ Plug Integrity !■ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance *. 3.210 3$& #s. /36e /° / s `( Other: / �o AA- G 25.//z— c; ) — /¢({er we •- P(V P 14,c.er...,�- .— 4- p� �'� � .j ' Subsequent Form Required: / 6 . Ci ,; 1 Ill . APPROVED BY /k A Approved By: COM - - THE COMMISSION Date b Form 10-403 Rer7O ((,,�JMy� DEC � ms D 411 '77(0 ,�' l � p R 1 G i N A L Submit In Duplicate � J • . To: Alaska Oil & Gas Conservation Commission • From: Zach Sayers bp Y CTD Engineer Date: November 29, 2011 Re: 18 -15B Sundry Approval Sundry approval is requested to plug the 18 -15B perforations as part of drilling the 18 -15 coiled tubing sidetrack. History of 18 -15. 18 -15A was rotary sidetracked in May 1995 and completed with a slotted liner in Zone 1A. In May 1997 a CTD extension (18 -15B) was drilled out the toe to extend 18 -15A's Zone 1A horizontal section by 1,425' into a 40 acre infill area to the south east. The CTD extension was completed with a 2 -7/8" slotted liner. The original slotted liner was left open to production. 18 -15B produced full time until mid 1999. With production declining, 450' of the original slotted liner was re- perfed (9,550- 10,000') in Nov 1999. The well POP'ed with increased gas and oil rates, but it was shut -in within a month for TxIA comm and a PC leak. It remained shut -in until a RWO was completed in April 2005. 18 -15B produced fulltime until mid 2006 when it began cycling for high GOR. Currently, it no longer exhibits recharge after shut -in periods and is shut -in for high GOR. Reason for sidetrack. 18 -15B is no longer a competitive producer, and there are no remaining wellwork options. The proposed sidetrack will access reserves in a -25 acre Z1A target in eastern DS 18. Proposed plan for 18 -15C is to drill a through tubing sidetrack with the SLB /Nordic 2 Coiled Tubing Drilling rig on or around January 1 2012. The existing perforations will be isolated by the primary cement job for the liner. The sidetrack, 18 -15C, will exit the existing 7" liner, kick off in Z2, and land in Z1A. This sidetrack will be completed with a 3 -1/4" x 2 -7/8" liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. C.04Cd/; tveff f yiFc'% 40 /E'c4r4 �l707 G ''h 6 ae 4 Qf rr' j To 65 /# c-P41O Pre -Rig Work: • (scheduled to begin December., 2011) 1. 0 MIT- IA to 3,000 psi, MIT -OA to 2,000 2. W Cycle LDS; PPPOT- T to 5,000 psi 3. S Dummy WS Drift to deviation 4. F Load & kill well prior to setting WS. Freeze protect well to 2,500' MD 5. E Set through tubing 7" PosiSet plug at 9,060'. 7 6. E Bail 8 gallons cement on top of PosiSet plug (equal to 5' in 7 "CSG). r 1 7. E Set 4 -W x 7" through- tubing Whipstock 8. V PT MV, SV, WV 9. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange 10. 0 Remove wellhouse, level pad 11. V Set TWC (Cameron 4- 1/16" Type H profile) 24 hrs prior to rig arrival FA Rig Work: (scheduled to begin January 1 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" window at 9,020' and 10' of rathole. Swap the well to Geo -Visc. 3. Drill Build: 4.125" OH, 383' (35 deg /100 planned) with out resistivity 4. Drill Lateral: 4.125" OH, 2,330' (4.5 deg /100 planned) with resistivity 5. Run Triple Combo Open Hole Logs 14�' 6. Run 3 -1/4" x 2 -7/8" L -80 liner leaving TOL at 8,394' MD. 7. Pump primary cement leaving TOC at 8,910' MD, 28 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and run MCNL /GR /CCL log. 9. Test liner lap to 2,400 psi. 10. Perforate liner per asset instructions (-1,000') 11. Set 4 -' /Z" liner top packer, and test to 2,400 psi 12. Freeze protect well, set BPV, RDMO Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Generic GLV's 3. Test separator Zach Sayers CTD Engineer 564 -5790 CC: Well File Sondra Stewman/Terrie Hubble TREE = 4- 1/16" CIW WELLHEAD = FMC ACTUATOR= BAKER C - B SAFETY 4 2" CHROME TBG*** 70° @ 9550' KB. ELEV = 48' BF. EI EV ,_n__ KOP = 3350' I 2104' I---I 4-1/2" HES HXO NIPPLE, ID = 3.813" I _Max Angle = 97 @ 10248' Datum MD = 13198' Datum TVD = 8800' SS GAS LIFT MANDRELS ITOP OF 7" SCAB LNR, 263, L -80, ID = 6.276" H 2409' _I-- I :� ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 11 4 3008 3008 4 KGB -2 DMY BK 0 05/14/11 • 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2686' I-Al 3 4752 4689 19 KGB -2 DMY BK 0 05/14/11 '4 II 2 6375 6213 19 KGB -2 DMY BK 0 04/24/05 BTM OF 7" SCAB LNR, 263, L -80, ID = 6.276" I-J 8021' , • 21 7909 7605 38 KGB -2 DMY BK 0 04/24/05 / 1, 1 BKR C-2 TIEBACK SLV, ID = 7.50" I1 8021' I 1� 1 9 -5/8" CSG MILLOUT WINDOW (18 -15A) I9 -5/8" X 7" BKR H PKR, ID = 6.188" I-I 8028' I 1 8175' - 8225' (50' W/ SECTION MILL) 9 -5/8" X 7" BKR HMC HGR, ID = 6.188" I 8034' , • 8355' H4-1/2" HES X NIP, ID = 3.813" I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8175' Ili 8376' 1-17" X 4 -1 /2" BKR S -3 PKR, ID = 3.875" 8399' H4-1/2" HES X NIP, ID = 3.813" ■ V 8462' H TUBING STUB (04/17/05) I 1, 8463' -17" X 4-1/2" UNIQUE OVERSHOT 1 4 -1/2" TBG, 12.6 #, 13CR VAM TOP -I 8506' �i 0152 bpf, ID = 3.958" ,' 8536' 1-17" X 4-1/2" BKR S -3 PKR, ID = 3.875" I 1 8552' I44 -1/2" (MILLED) HES XN NIP, ID = 3.80" I 8596' I- I 4 -1/2" WLEG, ID = 4.00" I 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 8595' 1 ? I_I FISH -IBP RUBBER ELEMENTS (4/23/05) I This well has been drifted with 3.80" cent 9385 _17" X 4-1/2" TIW SS PKR, ID = 4.00" I (8/11) and 2.25" cent (10/09) to 9400' MD 4:4 �; Minimum ID = 2.387" @ 10031" 1 9433' IH 4 -1/2" PORTEDJT(41'), ID= 3.91" I 3-1/2" X 2 -7/8" LNR XO t f � \ \ \ \ ■ ■ ■ ■ \ 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 9547' \ —I 10030' 1-13.70" BKR G SUB FN, ID = 3.00" I \ \ 10031' —13-1/2" X 2 -7/8" X0, ID = 2.387" I 14-1/2" SLOTTED LNR, 12.6 #, L -80, 0.152 bpf, ID = 3.958 H 10087' I \ 1 4-1 /2" SOLID LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I—I 10110' I \ ■ ■ PERFORATION SUMMARY ■ ■ REF LOG: BHCA ON 05/14/95 \ \ ANGLE AT TOP PERF: 91° @ 9550' \\ \\ 1 11788' I- 2 -718" BAKER Note: Refer to Production DB for historical perf data 2 -7/8" SLOTTED LNR, 6.5 #, L -80, 11788' ■ \ / PACKOFF SIZE SPF INTERVAL Opn /Sqz DATE .0058 bpf, ID = 2.387 BUSHING 4 -1/2" SLTD 9474 - 10087 0 05/20/95 � ID = 1.25" 2-7/8" 4 9550 - 10000 0 11/11/99 2 -7/8" SOLID LNR, 6.5 #, L -80, 11818' 2 -7/8" SLTD 10363 - 11788 0 05/22/97 .0058 bpf, ID = 2.387" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/12/87 ORIGINAL COM PLETION 09/17/06 JGM / PJC DRLG DRAFT CORRECTIONS WELL: 18 -15B 05/20/95 RIG SIDETRACK (18 -15B) 05/31/11 JMF/ PJC GLV C/O (05/14/11) PERMIT No: n970720 05/22/97 CTD -EXTEND WELL / 08/22/11 NWR / PJCSSSV PULLED (4/20/08) API No: 50- 029 - 21 755 -02 05/22/97 RUN 2 -7/8" SLTD LNR (18 -15C 10/04/11 EV ADD COMMENTS SEC 19, T11 N, R15E, 813' SNL & 311' EWL 04/27/05 N4ES RWO 05/08/05 KDC /TLH GLV C/O BP Exploration (Alaska) TREE= CRAI 1� 15C WELLHEA,D = FMC C - SAFETY NOTES: Vilk ANGLE > 70° @ 9550' ACTUATOR = BAKER C ***4-1/2" CHROME TBG* ** KB. ELEV = 48' Proposed CTD Sidetrack BF. ELEV = KOP' 3350' I 2104' I-14-1/2" HES HXO NIPPLE, ID = 3.813" I Max Angle = 97 @ 10248' Datum MD = 13198' Datum TVD = 8800' SS GAS LIFT MANDRELS I TOP OF 7" SCAB LNR, 263, L -80, ID = 6.276" I-1 2409' I— 7 w STI MD TVD DEV TYPE VLV LATCH PORT DATE 1 Ii k 4 3008 3008 4 KGB -2 DMY BK 0 05/14/11 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2686' I , ! 3 4752 4689 19 KGB -2 DMY BK 0 05/14/11 • '1 /4 2 6375 6213 19 KGB -2 DMY BK 0 04/24/05 21 7909 7605 38 KGB -2 DMY BK 0 04/24/05 I BTM OF 7" SCAB LNR, 263, L -80, ID = 6.276" H 8021' 01 1 � BKR C-2 TIEBACK SLV, ID = 7.50" H 8021' I 0. 0, 9 -5/8" CSG MILLOUT WINDOW (18 -15A) 19-5/8" X 7" BKR H PKR, ID = 6.188" I-I 8028' I 1 8175' - 8225' (50' W/ SECTION MILL) 9 -5/8" X 7" BKR HMC HGR, ID = 6.188" H 8034' • • 8355' H4-1/2" HES X NIP, ID = 3.813" I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8175' , 8376' H7" X 4-1/2" BKR S -3 PKR, ID = 3.875" 8399' 1-14-1/2" HES X NIP, ID = 3.813" I 3.7" deployment sleeve / 4 0 8462' 1--I TUBING STUB (04/17/05) I 4.5" KB LTP @ 8,394' MD i 8463' 1-17" X 4-1/2" UNIQUE OVERSHOT I 4-1/2" TBG, 12.6 #, 13CR VAM TOP — 8506' , '. .0152 bpf, ID = 3.958" ,' ` 8536' H7" X 4-1/2" BKR S -3 PKR, ID = 3.875" I 8552' I _14 -1/2" (MILLED) HES XN NIP, ID = 3.80" I 8596' H4 -1/2" WLEG, ID = 4.00" I 14 -1 /2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 8595' TSGR - 8,642' MD Minimum ID = 2.44 "@ 9500' TOC 8,910' MD 3- 3/16" x 2 -7/8" XO I 9020' I4 WS TO ALLOW KOPAT 9,020' MD I 3- 3/16" x 2 -7/8" XO @ 9,500' MD 0100 _I 9060' h POSI SET PLUG W /CMT ON TOP i, 9385' J_1 7" X 4 -1/2" TIW SS PKR, ID = 4.00" I .D 9433' H4-1/2" PORTED JT (41'), ID = 3.91" 2 -7/8" 4.7# L -80 liner \ \ \ TD @ 11,733' MD \ ■ 18 -15C \ \ I 9547' hi 7" LNR, 29 #, L -80, ID= 6.184" I \ \ \ 10030' I - 3.70" BKR G SUB, ID = 3.00" I \ \ \ PERFORATION SUMMARY I 10110' H4 -1/2" SOL /SLTD LNR I REF LOG: BHCA ON 05/14/95 18 -15A ANGLE AT TOP PERF: 91° @ 9550' \ \ Note: Refer to Production DB for historical pert data \ \ \ \ SIZE SPF INTERVAL Opn /Sqz DATE \ \ 4 -1/2" SLTD 9474 - 10087 C PENDING \ \ 2 -7/8" 4 9550 - 10000 C PENDING \ \ \ \ 2 -7/8" SLTD 10363 - 11788 C PENDING \ 2 -7/8" SOLID LNR, 6.5 #, L -80, —I 11818' \ 18 -15B .0058 bpf, ID = 2.387" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/12/87 ORIGINAL COMPLETION 09/17/06 JGM / PJC DRLG DRAFT CORRECTIONS WELL: 18 -15C 05/20/95 RIG SIDETRACK (18 -15B) 05/31/11 JMF/ PJC GLV C/O (05/14/11) PERMIT No: PENDING 05/22/97 CTD -EXTEND WELL / 08/22/11 AMR / PJCSSSV PULLED (4/20/08) API No: 50- 029 - 21755 -02 05/22/97 RUN 2 -7/8" SLTD LNR (18 -15C' 11/02/11 EV PROPOSED CTD SEC 19, T11 N, R15E, 813' SNL & 311' EWL 04/27/05 N4ES RWO 05/08/05 KDC /TLH GLV C/O BP Exploration (Alaska) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM 11111.1111, Pr Cho e Panel Standpipe 2" Circulation Line — ` LIkj s. , Driller Gauge�■ , M 10 �= MM 11 p Manual Choke CIRCULATING MANIFOLD MM8 ,, ; ^ MM • 20 •V r MM 22 2 s ••e • SLB Transducer `. MM 8_ PVT Sensor — - 7 -1116" 5k05i BOPE Air Blow down - - . a .. II MM 7 Line �'• �`- - e Baker Choke Blind Shears NMI MM 5 MM 21 OAS BUSTER 2 -318" Combi S ! Kill Line TOT PIS Rev Cir Line l� �� S �. MM14 e I- I vv kw e vv vv III i • _ Mi. : t - � � - -I c�� ..r.. , i. „4l 4 e . - 0.i:l MS II u u � B OP 20 � � .. � a . 4---- �� :.. Coiled Tubing — • i i � ! 2 -318” - 3 -112" M�aI111ar�lat � 1OI == .ariori111�1 - VBR rant Ba er Choke 2 -3/8" Combi 0 T PIS MM 1 ... MP1 in �• MM 13 * i .a . - Kill Line '- Outlet t--- Cement Line to Ground • V Mud 'tin Pu• • s In Tranducers COILED TUBING Y Choke Line • in CIRCULATING SYSTEM Cellar ,. Area • HP 14 To Inner Reel Outlets ~_ Valve HP7 HP3 HP2 HP1 _ A HP 1 I - • cement line N2 ( SLB NORDICS 2 Circulate Manifold . CHOKE MANIFOLD in Cellar HP 11 N2 TriFlow Na \I / CM 85 e',4 • � • Gauge - '•r r111,F I INF Test Pump Inlet — ' CM3 � • • HDI Gauge CM18 • " Flow fl HC mo :111 _ To PITS 4Way Block CMI4 CMt CM8 C 2 C C.. 1 Baker Choke Line Baker Choke Line from wal "`K from CHOKE I INF CM73 _ _ CM7 — ■aker Choke Line • MI CM2 = CM19 ■ — Micro Use for Blowing _ CM 26 CM 29 Moilon Back MM CM20 CM4 - - CM21 M 1 - 7 7 1 7 CM 30 rnnKF I INF = a = C M 75 CM10 MAIM Tiger Tank CM 25 N I Outside 0 0 a. • • Fisher, Samantha J (DOA) From: Seamount, Dan T (DOA) Sent: Thursday, December 08, 2011 10:49 AM To: Fisher, Samantha J (DOA) Subject: Re: Sundry PBU 18 -15B Approved Sent from my iPad On Dec 8, 2011, at 1:44 PM, "Fisher, Samantha J (DOA)" <samantha.fisher @alaska.gov> wrote: > Please review and approve. > Thank you > Samantha Fisher, Executive Secretary II > Alaska Oil and Gas Conservation Commission > (907)793 -1223 > <S45C- 211120811370.pdf> 1 ✓ Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, December 07, 2011 3:41 PM To: 'Sayers, Zach J' Subject: RE: 18 -15B Sundry Approval (PTD 197 -072) Zach, Have the Sundry in hand and have reviewed it. You have verbal approval to proceed with the sundry 311 -374 to P & A DS 18 -15B as written. Guy Schwartz w )) Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Sayers, Zach J [mailto:Zach.Sayers @bp.com] Sent: Wednesday, December 07, 2011 2:37 PM To: Schwartz, Guy L (DOA) Subject: 18 -15B Sundry Approval As we discussed on the phone, we would like to receive verbal approval to proceed with the pre -rig prep work outlined in the sundry, most notably the Posiset plug. Thank you, Zach Sayers Drilling Engineer, Coil Tubing Drilling Alaska Drilling & Wells (907) 564 -5790 — Direct (907) 575 -5189 cell 12/7/2011 Page 1 of 4 • Schwartz, Guy L (DOA) From: Sayers, Zach J [Zach.Sayers ©bp.com] Sent: Tuesday, December 06, 2011 4:16 PM p.S 1? 6 To: Schwartz, Guy L (DOA) Subject: RE: DRAFT PTD additions ()pp Attachments: image001.png We do not have ability to seal on these work strings or BHA components; therefore do not test the any portion of the BOPE to them. We mitigate this non - sealable small pipe by making up a safety joint (that is a tested size) and burying the Hydrill below the stack. Zach Sayers Drilling Engineer From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, December 06, 2011 3:52 „NAIttic" ; r :� j To: Sayers, Zach J Subject: RE: DRAFT PTD additions Zach, That is an improvement... thanks. When you guys run "CS hydrill" pipe do you ever test the Annular with that OD of pipe ?? (will it seal ? ?) I was thinking about all the Hydrill pipe you run for the Memory CNL and FCO run inside the liner. Although the liner is cemented off before you run the logs it would be at least nice to know that the annular would close on the smaller pipe if you needed it to. As you mentioned you use it to space out the TCP pert guns too and even more important there as the well is "live" on the way out of the hole. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Sayers, Zach J [mailto:Zach.Sayers @bp.com] Sent: Tuesday, December 06, 2011 9:53 AM To: Schwartz, Guy L (DOA) Subject: DRAFT PTD additions E c,77) Mr. Schwartz, Please find my additions to our standard PTD highlighted in yellow: To: Alaska Oil & Gas Conservation Commission From: Zach Sayers bp CTD Engineer Date: December 6, 2011 12/7/2011 Page 2 of 4 • Re: 18 -15C Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well 18 -15. CTD Drill and Complete 18 -15C program: Rig Start Date: January 1st, 2012 Pre -Rig Work: (scheduled to begin December 9 2011) 1. 0 MIT- IA to 3,000 psi, MIT -OA to 2,000 2. W Cycle LDS; PPPOT- T to 5,000 psi 3. S Dummy WS Drift to deviation 4. F Load & kill well prior to setting WS. Freeze protect well to 2,500' MD 5. E Set through tubing 7" PosiSet plug at 9,060'. 6. E Bail 8 gallons cement on top of PosiSet plug (equal to 5' in 7 "CSG). 7. E Set 4 -W x 7" through - tubing Whipstock 8. V PT MV, SV, WV 9. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange 10. 0 Remove wellhouse, level pad 11. V Set TWC (Cameron 4- 1/16" Type H profile) 24 hrs prior to rig arrival Rig Work: (scheduled to begin January 1s 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" window at 9,020' and 10' of rathole. Swap the well to Geo -Visc. 3. Drill Build: 4.125" OH, 383' (35 deg /100 planned) with out resistivity 4. Drill Lateral: 4.125" OH, 2,330' (4.5 deg /100 planned) with resistivity 5. Run Triple Combo Open Hole Logs 6. Run 3 -1/4" x 2 -7/8" L -80 liner leaving TOL at 8,394' MD. 7. Pump primary cement leaving TOC at 8,910' MD, 28 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and run MCNUGR/CCL log. 9. Test liner lap to 2,400 psi. 10. Perforate liner per asset instructions (-1,000') 11. Set 4 -W liner top packer, and test to 2,400 psi 12. Freeze protect well, set BPV, RDMO Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Generic GLV's 3. Test separator 12/7/2011 Page 3 of 4 • • Mud Program: • Well kill: 8.4 ppg brine. • Milling /drilling: 8.6 ppg Geo Vis for milling window and drilling ( 594 psi over - balance ). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. size: si e: 4.125" Liner Program: • 3 -1/4 ", 6.6 #, L -80, TC -II Solid Liner 8,394' MD — 9,500' MD • 2 -7/8 ", 6.5 #, L -80, STL Solid Liner 9,500' MD — 11,733' MD • A minimum of 28 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 8,910' MD) • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 91 °. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 27,000' to the North. • Distance to nearest well within pool — 884' to 18 -16B. Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Triple Combo Open Hole Logging: Gamma Ray, Induction Resistivity, Density, Neutron. • Cased hole GR /CCUMCNL logs will be run. Dv 47@..0 w( In CSH pips) • •• • Perforating: • SWS 1.56 ", 6 spf, perf guns, 1" CSH work string, & 2 -1/16" CSH • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti - Collision Failures • Hazards • The maximum recorded H2S level on DS 18 was 70 ppm on well 18 - 18B on 5/22/2010. Reservoir Pressure • The reservoir pressure on 18 -15C is expected to be 3,340 psi at 8,800' TVDSS. (7.3 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi /ft) to surface is 2,460 psi. • An EMW of 8.4 ppg for this well will provide 500 psi over - balance to the reservoir. 12/7/2011 Page 4 of 4 ti • • Zach Sayers CC: Well File CTD Engineer Sondra Stewman/Terrie Hubble Thank you, Zach Sayers Drilling Engineer, Coil Tubing Drilling Alaska Drilling & Wells (907) 564 -5790 — Direct (907) 575 -5189 -- Cen 12/7/2011 SChlumbeplep NO. 5180 Alaska Data & Consulting Services ry Company: State of Alaska 2525 Gambell Street, Suite 400 t t �j� Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2836 "�� - F Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job B Log Description Date BL Color CD OWDW -SW B3S0 -00032 R 11/07/09 1 1 L -223 8581 -00014 USIT 10/21/09 1 1 S -218 B5JN -00018 USIT 1 10/21/09 1 1 L -222 83SO -00031 USIT 11/07109 1 1 1-2 -24 8148 -00079 RST 10/31109 1 1 1-2 -32 8148 -00078 RST 10130109 1 1 L1 -14 AVI"0029 RST 10/27/09 1 1 L2 -18A 8148 -00077 RST 10130/09 1 1 0-289 AXED -00053 MCNL 10102/09 1 1 S -228 BSK5 -00008 RST 1 10127/09 1 1 D-24 AWLS -00038 RST 09/27/09 1 1 18 -158 AYS4 -00107 RST 10131109 1 1 04 -21 ANHY -00115 RST 10!27/09 1 1 L2 -07A AYGO -00047 RST Qu 10129/09 1 1 OWDW -SW 83SO -00032 RST 11/07/09 1 12- 05AP61 40015441 ON MWD/LWD EDIT 07/01/07 2 1 06 -218 08AKA0016 ON MWD/LWD EDIT 07/28/08 2 1 D-16A 09AKA0176 ON MWD/LWD EDIT 09/07/09 2 1 L -223 09AKA0081 ON MWD/LWD EDIT 0 10/10/09 2 1 L -223 8581 -00014 CH EDIT PDC (USIT) 10/21/09 1 S -218 B5JN -00018 CH EDIT POC (USIT)10/21/09 t L -222 83So -00031 CH EDIT PDC (USIT) 11/07109 1 04 -33A 09AKA0075 ON MWD/LWD EDIT 09/19/09 2 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnicaf Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2938 '\, STATE OF ALASKA ) R' ~ '~, ""'~-.\,' ',,-'-"'- ALASKA ..AL AND GAS CONSERVATION CG",¡MISSION t:CE.VE:rJ REPORT OF SUNDRY WELL OPERATIONSAAY 062005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program Alrski Oil & Gas Cons.. Commission d8~19,aye 181 Repair Well 0 Plug Perforations 0 Stimulate o Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 48' 8. Property Designation: ADL 028321 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 11818 8749 11818 8749 Casing Structural Conductor Surface Intermediate Production Liner Length 110' 2686' 8175' 1526' 726' 1788' Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 197-072 6. API Number: 50-029-21755-02-00 99519-6612 9. Well Name and Number: PBU 18-15B 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) Nq~.. f,\N~\\E~) MA'f 1 .,~ "ìGOS 1... ~."" ~ ".~, ,,,. ' ,,_e feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 13-3/8" 2686' 2686' 4930 2670 9-5/8" 8175' 7808' 6870 4760 7" 2410' - 9547' 2410' - 8717' 8160 7020 4-1/2" 9384' - 10110' 8692' - 8737' 8430 7500 2-7/8" 10030' - 11818' 8730' - 8749' 10570 11160 Slotted Sections: 9474' - 11788' 8714' - 8747' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4-1/2", 12.6# 13Cr80 x L-80 8596' 7" X 4-1/2" Baker 'S-3' packer; 7" x 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'HXO' Nipple 8536' & 8376'; 2104' Treatment description including volumes used and final pressure: ReOMS 8Ft MAY 1 0 2005 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 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: Contact David Reem, 564-5743 NIA Printed Name Terrie Hubble Signature ~Q/ljI;Q .~1.~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone 564-4628 OHIGINAL OSL to I Prepared By Name/Number: Date iD IDS Terrie Hubble, 564-4628 Submit Original Only ) ) Well: Field: API: Permit: 18-15B Prudhoe Bay Unit 50-029-21755-02-00 197 -072 Accept: Spud: Release: Rig: 04/15/05 N/A 04/26/05 Nabors 4ES PRE-RIG WORK 03/14/05 RAN DUMP BAILER 3" & 3.20 LIB. TAGGED IBP AT 8497' SLM. DUMPED 2 LOADS OF SLUGGITS ON IBP. CROWNED OUT AT SURFACE ON SECOND RUN & DROPPED TOOLSTRING. NO WIRE LEFT IN HOLE. PREP TO FISH TOOLS. 03/15/05 PULL TOOL STRING FROM 8457' SLM. DUMP LAST BAILER LOAD OF SLUGGITS AT 8494' SLM, RETAG AT 8487' SLM. - 10' OF SUGGITS ON TOP OF IBP. 03/21/05 RIH W/3.70" DUMMY DRIFT TO 8,480' SLM. 03/31/05 TUBING PUNCH 8438' - 8440'. SET DOWN IN GLM AT 6033' WITH STRING SHOT, COULD NOT GET PAST. 04/01/05 STRING SHOT INTERVAL 8453' - 8467'. CHEMICAL CUT TBG WITH 3-5/8 CUTTER AT 8465' (MIDDLE OF 2ND FULL JOIN.J~ABOVE PKR - REF TBG TALLY). ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15B 18-15B WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Frorn<- To HoUrs Task Code NPT Phase 4/15/2005 04:00 - 06:00 2.00 RIGD P PRE 06:00 - 18:00 12.00 MOB P PRE 18:00 - 20:00 2.00 KILL P DECOMP 20:00 - 20:30 0.50 KILL P DECOMP 20:30 - 22:30 2.00 KILL P DECOMP 22:30 - 00:00 1.50 KILL P DECOMP 00:00 - 02:00 2.00 KILL P DECOMP 02:00 - 02:30 0.50 WHSUR P DECOMP 02:30 - 04:00 1.50 WHSUR P DECOMP 04:00 - 07:00 3.00 BOPSUF P DECOMP 07:00 - 11 :30 4.50 BOPSUP P DECOMP 4/16/2005 11 :30 - 12:30 1.00 WHSUR P DECOMP 12:30 - 13:00 0.50 PULL P DECOMP 13:00 - 13:30 0.50 PULL P DECOMP 13:30 - 20:30 7.00 PULL P DECOMP 20:30 - 22:30 2.00 RIGU P PRE 22:30 - 23:30 1.00 CLEAN P DECOMP 23:30 - 00:00 0.50 CLEAN P DECOMP 4/17/2005 00:00 - 05:00 5.00 CLEAN P DECOMP 05:00 - 05:30 0.50 CLEAN P DECOMP 05:30 - 05:45 0.25 CLEAN P DECOMP 05:45 - 06:30 0.75 CLEAN P DECOMP 06:30 - 07:00 0.50 CLEAN P DECOMP 07:00 - 10:30 3.50 CLEAN P DECOMP 10:30 - 11 :00 0.50 CLEAN P DECOMP 11 :00 - 11 :30 0.50 EVAL P DECOMP 11 :30 - 14:00 2.50 EVAL P DECOMP 14:00 - 15:30 1.50 EVAL P DECOMP Start: 4/14/2005 Rig Release: 4/26/2005 Rig Number: Spud Date: 10/1/1987 End: 4/26/2005 DescriptiOn ofOperatiöl1s Scope down and lower Derrick. Rig down Pipe Shed, and Pits. Move Rig from DS 17 to DS 18. R/U to Kill Well Safety Meeting held with all personnel on scope of operations. Drill Site Maintenance arrives hold PJSM. R/U Pull BPV with lubricator. Test lines to 3500 psi Displace diesel freeze protect and packer annular fluid with 120 degree 9.8 ppg brine around from tbg. cut at 8465' Continue displace annular fluids with 582 bbls 9.8 ppg NaCL brine. Set TWC, Blow down lines N/D Production Tree N/U BOPE. Prep for BOPE Test. Rig up test equipment. Perform BOPE test per BP/AOGCC requirements at 250/3,500 psi. State's right to witness Test was waived by J. Chrisp. Rig down test equipment. Test witnessed by Rig Rep and TP. Pick-up Lubricator. : Pull TWC. Lay döwn same.' Make-up Landing Joint. BOLDS. PLiIl, Tubing Hanger to Rig Floor with no problems. PUW = 94K. Lay down same. Rig up to handle 41/2" completion. Rig up Camco Spooling Unit to spool Control Line. Start POOH with 4 1/2" L-80 Tubing. Single down Tubing in Pipe Shed. Stop to Lay down SSSV and rig down Camco Spooling Unit. (Control Line recovered complete...recovered 52 SS Bands. Left 5 in Hole). Continue POOH. Recovered 201 Jts, SSSV, 3 ea GLMs, and a 21.25' chemical cut stub. Chemical cut was good. Set wear bushing. Clean rig floor. R/U for 3-1/2" DP P/U BHA #1 Wash pipe with shoe, Scraper" Boot baskets, Oil jar, Circulating sub, and Drill collars. P/U 3-1/2" single DP RIH BHA #1 Continue run BHA #1 on 3-1/2" DP Tagged top of 7" Tie-back Liner at -8,021'. Pick-up Kelly and wash/rotate through with no problems. Set back Kelly. Continue RIH picking up single Drill Pipe from Pipe Shed. Pick-up Kelly. PUW = 126K. SOW = 115K. RTW = 120K. Tag top of 4 1/2" Stump at 8,462' 4es. Dress off Stump with no problems. Swallow Stump down to 8,472'. Work on/off Stump 3 times with no problems. Reverse Circulate Drill Pipe x 2 at 4 bpm/600 psi. Clean returns. Set back Kelly. TOH with 31/2" Drill Pipe and Drill Collars. Lay down BHA #1. Clean and Clean Floor. (Start to load and tally 7" Liner in Pipe Shed). Pick-up and Make-up Halco 7" RBP. TIH with RBP, Running Tool, 9 ea Drill Collars, and 247 jts Drill Pipe. Set RBP at 8,098' (Ref: top of Tool). Lay down Single. Pull 1 Stand. Dump 700 Ibs of 20/40 river Sand down Drill Pipe. Displace Drill Pipe (53 bbls) with 9.8 Ib/gal Brine. RIH and tag TOS at 8,065'. (Cal TOS = 8,066'). Pull 1 Stand. Printed: 5/2/2005 7:57: 1 0 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15B 18-158 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/14/2005 Rig Release: 4/26/2005 Rig Number: Spud Date: 10/1/1987 End: 4/26/2005 Date From-To Hours Ta.sk Code NPT Phase Description otOperations 4/17/2005 15:30 - 16:00 0.50 EVAL P DECOMP Unable to do any kind of pressure test. Perform injection test at 1.25 bpm/150 psi. 2.0 bpm/325 psi. 3.0 bpm/800 psi. 16:00 - 18:30 2.50 EVAL P DECOMP RIH with 1 Stand. Tag final TOS at 8,066'. POOH with Drill Pipe, Drill Collars, and Running Tool. 18:30 - 20:30 2.00 EVAL P DECOMP Rack Back Drill Collars Lay Down Running tool. Pick up BHA #2 Polishing Mill, Scrapper, Oil Jars, Circulating Sub and Drill Collars 20:30 - 00:00 3.50 EVAL P DECOMP TIH with BHA #2 on 243 jts of 3-1/2" drill pipe. Pick up Kelly and Polish Baker C-2 Tieback Sleeve from 8021' - 8026'. Reverse 2 pipe volumes back 4/18J2005 00:00 - 02:30 2.50 EVAL P DECOMP POH with 3-1/2" DP with BHA #2 02:30 - 03:00 0.50 EVAL P DECOMP Rack Back Drill Collars, Lay down BHA #2 Clean rig floor 03:00 - 03:30 0.50 EVAL P DECOMP M/U Halliburton 9-5/8" RTTS packer with running tool on Drill Collars 03:30 - 05:30 2.00 EVAL P DECOMP RIH RTTS on 3-1/2". 05:30 - 07:00 1.50 EVAL P DECOMP Set RTTS Packer at 2,535'. Rig up pressure recording chart. Test 9 5/8" Casing from Packer back to surface at 3,500 psi/30 mins. Good test. 07:00 - 08:00 1.00 EVAL P DECOMP Release Packer and TOH. 08:00 - 09:30 1.50 CASE P TIEB1 Rig up to handle 7" Casing. Perform final inspection of the Shoe Track. 09:30 - 10:00 0.50 CASE P TIEB1 PJSM with All. 10:00 - 17:00 7.00 CASE P TIEB1 Pick-up 7" Shoe Track and 7" Liner as folows: Ported Seal Stem, 20-ft Pup Jt w/Float Collar in box end, 1 ea 7" Casing Joint, 1 ea 7" Casing Joint w/Landing collar in pin end, and 132 Jt 7" Casing. 17:00 - 17:30 0.50 CASE P TIEB1 Rig down 41/2" handling equipment and rig up 3 1/2" handling equipment. Pick-up Baker Liner Hanger and Packer. 17:30 - 19:30 2.00 CASE P TIEB1 RIH 7 " Liner on 3-1/2" DP Stab into C-2 Tie Back Sleeve at 8021' Pressure up to verify. 19:30 - 20:30 1.00 CASE P TIEB1 Establish parameters and space out. P/U Cement Head 20:30 - 21 :00 0.50 CEMT P TlEB1 PJSM with all personnel 21 :00 - 00:00 3.00 CEMT P TIEB1 Set max pump pressure at 1800 psi. Hanger setting low end 2120 psi. High end 2650 psi per Baker rep. Test lines to 4800 psi, Preflush with 50 bbls of 80 F fresh water, Pump 179.63 bbls of Class G 15.8# Cement ( Gel time 3hrs 29 min.) Displace to be 228 bbls. Displace 222 bbls with rate at .25 bbls and 1875 psi, Shut pumps down, TOO CLOSE TO SETTING HANGER! Slack off and seat seal in tie back. Set hanger with 2050 psi, Slack off verify. Set ZXP Liner top Packer with 3500 psi. Unlatch from Packer apply 500 psi in DP pick up out of Packer with running tool and pump 10 bbls. Estimate 161' of cement in 7" (6 bbls) 4/19/2005 00:00 - 01 :00 1.00 CEMT P TIEB1 P/U 20' and Reverse circulae 117 bbls, saw no returns of cement, P/U 50' and reverse circulate 35 bbls saw no cement 01 :00 - 02:00 1.00 CEMT IP TIEB1 POH with 3-1/2" DP and Baker running tool 02:00 - 07:00 5.00 CEMT ,p TIEB1 Wait on cement to cure. Service and maintain Rig. Prep for 6 1/8" Bit clean-out Trip. Verify with Cement Lab the UCA results. After 7 1/2 hours, CS = 1,100 psi. 07:00 - 08:00 1.00 CEMT ¡p TIEB1 Make-up BHA #3 Drilling Assembly as follows: 61/8" Bit, 2 ea , Boot Baskets, Bit Sub, Oil Jars, and 9 ea 4 3/4" Drilling Collars. OAL = 301.68'. Printed: 5/2/2005 7:57:10 AM ) ) Bp: EXPLO.RATION Operäti()nsi.SumrnêlrY...i=leport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15B 18-15B WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/14/2005 Rig Release: 4/26/2005 Rig Number: Spud Date: 10/1/1987 End: 4/26/2005 Date From -'To Hours Task Code NPT Description of Operations 4/19/2005 08:00 - 11 :30 3.50 CEMT P TIEB1 TIH with 31/2" Drill Pipe. Tagged TOS at 7,698'. Lay down 11 singles for "Drilling Joints". 11 :30 - 12:30 1.00 CEMT P TIEB1 Rig up and test Casing/Packer/Liner Hanger and 7" Liner at 3,500 psi/30 mins. Record on Chart. Good test. 12:30 - 18:00 5.50 CEMT P TIEB1 RIH with Drill Pipe Stands from Derrick. Pick-up Kelly. PUW = 122K, SOW = 108K, RTW = 115K, WOB = 5 - 10K, Pump Rates at 3 bpm/400 psi, 4 bpm/650 psi, 5 bpm/750 psi. Brgin drilling Cement from 7,698' to 7905'. 18:00 - 23:30 5.50 CEMT P TIEB1 Con't to drill cement & shoe track from 7905 to 8019' Landing collar @ 7955'. Float collar @ 7999'. Stopped @ top of 7" 29# to circ hole clean & pump sweep prior to cleaning out. P/U 130K, S/O 105K, Rot 115K. 80 RPMs, Torq 4K, WOB 8-1 OK. 3 1/2 BPM @ 600 psi. Lots of cement over shaker. Hi-Vis fluid blinding shaker screens. Cut fluid w/ seawater. 23:30 - 00:00 0.50 CEMT P TIEB1 Pump Hi-Vis sweep @ 8019'. 41/2 BPM @ 700 psi. 4/20/2005 00:00 - 01 :00 1.00 CEMT P TIEB1 Con't to circulate Hi-Vis sweep around. Returns cleaned up. Sweep recovered very small amount of cement. 4 1/2 BPM @ 700 psi. 01 :00 - 03:00 2.00 CEMT P TIEB1 Drill cement from 8019 to 8062'.80 RPMs, WOB 8-10K, Torq 4K. 31/2 BPM @ 600 psi. Wash sand from 8062 to 8075'. 03:00 - 04:30 1.50 CEMT P TIEB1 Circulate hole clean. Pump Hi-Vis sweep. 5 BPM @ 750 psi. 20/40 Mesh Sand in returns. 04:30 - 05:00 0.50 CEMT P TIEB1 Set back Kelly. Pull up hole to 7,998' 05:00 - 06:00 1.00 CEMT P TIEB1 Rig up test equipment. Pressure test 7" Liner at 3,500 psi/15 min. Lost -100 psi. Rig down test equipment and blow down lines. 06:00 - 07:30 1.50 CLEAN P DECOMP Cut and Slip Drilling Line. WO Sea Water to arrive on Location. 07:30 - 09:30 2.00 CLEAN P DECOMP Final Sea Water load on Location. Swap Well over to clean Sea Water at 5 bpm/1000 psi. total bbls pumped = 365. 09:30 - 13:00 3.50 CLEAN P DECOMP TOH with 31/2" Drill Pipe and 6 1/8" Bit. Lay down Bit and empty Boot Baskets. 13:00 - 15:00 2.00 DHB P DECOMP Make-up Halco Retreiving Tool. TIH with 3 1/2" Drill Pipe to 8,073'. Tag top of Sand. 15:00 - 15:30 0.50 DHB P DECOMP Reverse Circulate through 20/40 Mesh Sand down to top of RBP at 8,098'. Reverse clean. 15:30 - 16:30 1.00 DHB P DECOMP Release Halco 7" RBP. Monitor Well. 16:30 - 19:30 3.00 DHB P DECOMP Lay down 1 single. TOH with 31/2" Drill Pipe. 19:30 - 20:00 0.50 DHB P DECOMP UD RBP & Running tool. 20:00 - 21 :00 1.00 CLEAN P DECOMP Clear & clean rig floor. Load tools for BHA #4. 21 :00 - 22:00 1.00 CLEAN P DECOMP M/U BHA #4, RIH as follows: Bit, 2 Boot Baskets, 7" scraper, Bit Sub, Bumper Sub, Jars, 9 * 4 3/4" DCs. TL = 314.55'. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH w/ BHA #4 to 8044'. Scrape casing. 4/21/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP Circulate bottoms up. No Gas, No Losses. 5 bpm @ 1000 PSI. 01 :00 - 04:00 3.00 CLEAN P DECOMP POOH w/ BHA #4. Break out & UD same. 04:00 - 04:30 0.50 CLEAN P DECOMP Clear & clean rig floor. Load & tally BHA # 5. 04:30 - 05:30 1.00 FISH P DECOMP M/U BHA #5 to fish IBP. 05:30 - 07:00 1.50 FISH P DECOMP RIH w/ BHA #5 and 3 1/2" Drill Pipe. Tagged (hit lip of Liner Packer to hard) top of 7" Scab Liner at 2,409'. 07:00 - 08:30 1.50 FISH P DECOMP POOH to inspect Mule Shoe on the end of Overshot. Mule Shoe damaged beyond repair. Lay down Overshot Assembly. 08:30 - 10:30 2.00 FISH P DECOMP Wait on Fishing Tool replacement. Discussed plan forward with Anch Eng. Printed: 5/2/2005 7:57:10 AM ) ) BP.,EXPLORATION QþerªtionsSu.rnmary,.Røþort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15B 18-15B WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/14/2005 Rig Release: 4/26/2005 Rig Number: Spud Date: 10/1/1987 End: 4/26/2005 Date From,-To Hours Task Code NPT Description of Operations 4/21/2005 10:30 - 11 :00 0.50 FISH P DECOMP Make-up new Mule Shoe on Overshot. Also added Shear Sub (Canfield Bushing w/3 brass shear pins = 12K shear value) to BHA to help guide BHA into 7" Scab Liner Packer and to guide Overshot inside top of 41/2" Chemical Cut Stump at 8,462'. 11 :00 - 13:00 2.00 FISH P DECOMP RIH with BHA and 31/2" Drill Pipe. Lightly set down on 7" Scab Liner Packer top. Work to get through several times with no-joy. Tried one more time with a little more weight, but pins sheared. 13:00 - 17:00 4.00 FISH P DECOMP POOH. Discuss plan forward with Anch Eng. 17:00 - 20:00 3.00 FISH DECOMP RIH with Overshot. Lightly tagged top of Liner and worked through. Continue RIH. Work overshot & BHA into 41/2" liner at 8,462'. Tagged up on fill @ 8470' Wash & circulate down to IBP @ 8526'. Slack off wi 8K & engauge fishing neck. P/U w/ 5K overpull. 20:00 - 21 :30 1.50 FISH P DECOMP Circulate & pump 20 bbls Hi-Vis sweep. 5 BPM @ 1600 psi. sweep recovered fine sand, pipe dope & black oily debris. 21 :30 - 23:30 2.00 FISH P DECOMP Jar on IBP. Jarred up to 30K. Jarred 23 times & plug started to move. Work pipe up & down till Plug is free. Fluid :Ievel slowly dropped. Well on vacuum. Pulled up 1 full jt & allow rubbers, to relax for 20 min. Had intermittant drag of 3-6K. 23:30 - 00:00 0.50 FISH P DECOMP P/U single & RIH 20' past original set depth to insure plug did not come apart. POOH & UD 5 singles. Plug now in 7" casing. Prep to POOH & UD Drill Pipe. 4/22/2005 00:00 - 06:00 6.00 FISH P DECOMP POOH. Lay down 31/2" Drill Pipe. 06:00 - 07:00 1.00 FISH P DECOMP Break out IBP fish. Rubber Element not recovered. Lay down BHA. Pull Wear Bushing. Clear and Clean Rig Floor. 07:00 - 07:30 0.50 RUNCOtvP RUNCMP PJSM with All. Review safety and handling proceedures for running Chrome Completion. 07:30 - 08:30 1.00 RUNCOrvP RUNCMP Rig-up to handle 41/2" Chrome Tubing. Rig-up torque Turn equipment. Perform final Jewelry inspection. 08:30 - 16:30 8.00 RUNCOWP RUNCMP Make-up Jewelry section and Baker Packer. Baker-Lac all connections below Packer. Start run in hole with 41/2" 12.6 Ib/ft 13Cr-80 Vam Top Tubing. 16:30 - 17:30 1.00 RUNCOrvP RUNCMP Stop at Jt #147. Rig-up camco Spooling Unit. Pick-up SSSV Make-up Control Lines. Test. 17:30 - 21 :00 3.50 RUNCOrvP RUNCMP Con't to RIH w/4 1/2" completion string. Ran 197 jts. 21 :00 - 22:30 1.50 RUNCOrvP RUNCMP Attempt to space out overshot on 4 1/2" tubing stub. Tagged up @ 8463'. Work string up & down & did not see any shear pin action on weight indicator. Check tally. Appear to be on top of stub. Slacked off to 20K & no further movement down hole. No confidence on overshot swallow depth. Consult w/ engineer. Plan to RIU & drift w/ Slickline unit. 22:30 - 00:00 1.50 RUNCOM\J DPRB RUNCMP Call out & wait on Slickline unit. Service & clean rig. 4/23/2005 00:00 - 00:30 0.50 RUNC0r, DPRB RUNCMP Continue to WO S-Line Unit. 00:30 - 03:00 2.50 RUNCO DPRB RUNCMP Spot Slick Line Unit. Rig-up Lubricator and equipment. 03:00 - 04:30 1.50 RUNCOrvN DPRB RUNCMP Run in hole and pull Dummy Nipple from SSSV. 04:30 - 06:00 1.50 RUNCOM\J DPRB RUNCMP Run in hole and pull RHC-M Plug from X-Nipple. 06:00 - 10:00 4.00 RUNCOM\J DPRB RUNCMP Run in hole with a 3.750" GR. Set down at 8,460' wlm. Work debris (possibly rubber element from IBP) down through 4 1/2" Stump and on out the TT at 8,596' Continue down to 8,900' in 7" Liner. Work GR through the Unique Overshot and down into the TT several times. Had to "bobble" through on each pass. Printed: 5/2/2005 7:57:10 AM ) ) BP'EXRLORAJION OperätionsßUn1rnªry<Rep()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15B 18-15B WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/14/2005 Rig Release: 4/26/2005 Rig Number: Spud Date: 10/1/1987 End: 4/26/2005 Date Frorn- To Hours Task Code. ··NPT Phase Description bfOperations 4/23/2005 06:00 - 10:00 4.00 RUNCOtvN DPRB RUNCMP Discuss Plan forward with Anch and Slope Eng. Ran a 3.750" LIB. POOH to have a "look-see" at the LIB. Impression shows approx 40% of the 41/2" Chemical Cut Stump on the side and leading edge of the LIB. Low side of the Hole. 10:00 -11:30 1.50 RUNCOtvN DPRB RUNCMP Rig Down SWS S-Line equipment and Unit. 11 :30 - 12:00 0.50 RUNCOtvN DPRB RUNCMP Pick-up Landing Joint and make one more attempt to swallow Stump. No-Joy. 12:00 - 13:00 1.00 PULL N DPRB DECOMP Rig up to handle and lay down 41/2" Chrome Completion. 13:00 - 17:00 4.00 PULL N DPRB DECOMP TOH and single down Tubing. Spool dual control lines. 17:00 - 18:00 1.00 PULL N DPRB DECOMP Stop at SSSV. Rig down Camco Spooling Unit. Lay down SSSV. 18:00 - 23:00 5.00 PULL N DPRB DECOMP Con't to POOH & LID completion. Inspect packer & overshot. No damage. 23:00 - 00:00 1.00 PULL N DPRB DECOMP Clear & clean rig floor. R/D tubing tools. 4/24/2005 00:00 - 00:30 0.50 BOPSURN DPRB DECOMP R/U BOP test equip. 00:30 - 05:00 4.50 BOPSUPN DPRB DECOMP Test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Jeff Jones wi AOGCC. No Failures. 05:00~.06:00 1.00 BOPSURN DPRB DECOMP Clear & clean rig floor. Blow down &LIDtest:equip. 06:00 - 06:30 0.50 CLEAN N DECOMP Lub Rig. 06:30 - 08:30 2.00 CLEAN N DPRB DECOMP Load BHA in Pipe Shed. Make-up BHA as follows: 6" x 41/2" Shoe, 3 ea Wash Pipe Extensions, Dress Mill (4 1/2" x 3.80") Drive Sub, XO, Casing Scraper, 2 ea Boot Baskets, XO, Bumper Jar, Oil Jar, 9 ea Drill Collars. 08:30 - 15:00 6.50 CLEAN N DPRB DECOMP RIH with BHA. Pick-up single 31/2" drill Pipe from Pipe Shed. Total 256 Jts. 15:00 - 15:30 0.50 CLEAN N DPRB DECOMP Pick-up 3 1/2" Pup Jt. Pick-up Kelly. Tagged top of 4 1/2" Stump at 8,462'. 15:30 - 18:00 2.50 CLEAN N DPRB DECOMP P/U kelly, rotate & wash from 8462 to 8475'. POW 134K, SOW 120K, ROW 125K. Reverse Circulate/Circulate at 1 - 3 bpm/O psi. Well on vacuum. 18:00 - 23:00 5.00 CLEAN N DPRB DECOMP POOH & LOOP. Total 256 jts. Break out & LID BHA. No recovery in junk baskets. 23:00 - 00:00 1.00 CLEAN N DPRB DECOMP Clear & clean rig floor. Pull Wear bushing. LID same. 4/25/2005 00:00 - 01 :30 1.50 RUNCOtvN DPRB RUNCMP RID DP handling tools. R/U tubing tools. 01 :30 - 02:00 0.50 RUNCOtvN DPRB RUNCMP Hold PJSM w/ all hands. Review completion running procedure & running order. 02:00 - 06:00 4.00 RUNCOtvN DPRB RUNCMP P/U 41/2" completion & RIH as per program. Baker lock all assys below S-3 Packer. Torque turn all connnections to 4440 ft-Ibs. 06:00 - 06:30 0.50 RUNCOtvN DPRB RUNCMP Service & lube rig 06:30 - 08:30 2.00 RUNCOtvN DPRB RUNCMP Con't to RIH w/4 1/2" completion. Torq turn all connections to 4440 ft-Ibs. 08:30 - 11 :30 3.00 RUNCOtvN DPRB RUNCMP RIU Camco spooling unit for SS control lines to SSSV. M/U SSSV. Connect lines & test lines to 5000 psi for 20 min, OK. 11 :30 - 15:00 3.50 RUNCOtvN DPRB RUNCMP Con't to RIH w/4 1/2" completion. Torq turn connections to 4440 fy-Ibs. Install SS control line bands on every jt. RIH w/ 197 jts, Tagged up 7' in on 198th jt. TL = 8462'. 15:00 - 15:30 0.50 RUNCOtvN DPRB RUNCMP Space out completion. sheared out pins w/1 OK weight. Install pups for final space out after P/U of 3'. Ran total of 196 jts. Ran a total of 56 SS bands. 115:30 - 18:00 2.50 RUNCOtvN DPRB i RUNCMP M/U landing jt & tubing hanger. Install & test control lines to I 5000 psi. Clear & clean rig floor. Printed: 5/2/2005 7:57:10 AM 1\ ." -) ) Bp··EXPL0RATION Qperations,·Su.mmary.. .Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15B 18-15B WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/14/2005 Rig Release: 4/26/2005 Rig Number: Spud Date: 10/1/1987 End: 4/26/2005 Date From-To Hours Task Code NPT Phase Description of Operations 4/25/2005 18:00 - 19:00 1.00 RUNCOM\l DPRB RUNCMP Land 41/2" Cr13 Vam Top completion. RILDS. UD landing jt. P/U 100K, S/O 88K. 19:00 - 00:00 5.00 RUNCOM\l DPRB RUNCMP Wait on trucks w/140 degree seawater. Trucks tied up @ Pad 3 disposal. 4/26/2005 00:00 - 02:30 2.50 RUNCOM\l DPRB RUNCMP Con't to wait on trucks w/ heated seawater. Clean & work on rig. 02:30 - 03:30 1.00 RUNCOMP RUNCMP R/U & reverse circulate 150 bbls of 120 degree heated seawaterdown 41/4" x 7" annulus. Pumped 3 BPM, pressure increased from 100 to 375 psi. Had returns after pumping 134 bbls. 03:30 - 05:00 1.50 RUNCOrvP RUNCMP Reverse circulate 290 bbls of 120 degree inhibited seawater down 41/2" x 7" annulus. Pumped 3 BPM @ 375 psi. 05:00 - 07:30 2.50 RUNCOMP RUNCMP Drop ball/ rod & allow to fall. Pressure up tubing & set packer w/ 3500 psi. Hold pressure for 30 min, OK. Bleed tubing to 1500 psi & pressure 9 5/8" & 7" liner to 3500 psi to top of packer, 30 minutes, charted, OK. Bleed all pressure & slowly pressure up back side to shear DCK shear valve, sheared @ 2500 psi. Pump thru. shear valve both ways, 2 bpm /1500 psi. 07:30 - 08:30 1.00 BOPSUF, P RUNCMP PJSM. Set 2 way check valve & test @ 1000 psi, OK. Blow down lines. 08:30 - 09:30 1.00 BOPSUR P RUNCMP PJSM. N/D BOPE. 09:30 - 13:00 3.50 WHSUR P RUNCMP PJSM. N/U tree. Test void, tree & control lines @ 5000 psi, OK. 13:00 - 13:30 0.50 WHSUR P RUNCMP PJSM. Pick up lubricator, pull two way check. 13:30 - 16:30 3.00 WHSUR P RUNCMP PJSM. Rig up Little Red & test lines to 3500 psi, OK. Pump diesel down I/A @ 2 bpm /1300 psi, taking returns up tubing. Pressure gradually increasing. W/120 bbls away, pressure @# 3000 psi @ .4 bpm. Stop & discuss options. Opt to limit pressure to 3500 psi. Bring on pump & pump remaining desiel @ 1 bpm, 3200 psi highest pressure seen, then dropped off to 1900 psi. (DCK valve plugged). Pumped 145 bbls diesel total. 16:30 - 17:30 1.00 WHSUR P RUNCMP Allow diesel freeze protect fluid to U-tube. 17:30 - 18:00 0.50 WHSUR P RUNCMP R/D lines. Set & test BPV to 1000 psi. RELEASE RIG @ 1800 Hrs. Printed: 5/2/2005 7:57: 1 0 AM ^ TREE T! 4- 1/16" CM! • WELLHEAD= FMC 18-15B F M DRLG - DRAFT ACTUATOR = BAKER C KB. ELEV = 48' BF. ELEV = KOP = 3350' - -. Max Angle = 97 @ 10248' I I 2104' I-{ 4 -1/2" HES HXO, ID = 3.813 ", 9Cr I Datum MD = N/A Datum TVD = 8800' SS t • 2409' I-I BKR ZXP Liner Top Packer /Hanger Ass'y I si i: 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2686' ■•• H r i• :•3 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE !;! 4 3008 KGB -2 DCK 04/24/05 ;'• 3 4752 KGB -2 DMY 04/24/05 7 ", 26 #, L -80, Scab Liner fully H '2 1' I ;; 2 6374 KGB -2 DMY 04/24/05 • cemented 2409' - 8021' ! $4. 1 7908 KGB -2 DMY 04/24/05 1• �;. BKR C -2 TIEBACK SLV, ID = 7.50" I 8021' 9 -5/8" X 7" BKR H PKR, ID = 6.188" I 8028' l •• 9-5/8" X 7" BKR HMC HGR, ID = 6.188" H 8034' h I 8355' H 4 -1/2" HES "X" NIP, ID = 3.813 ", 9Cr I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I- I 8175' I 8375' H BKR S -3 PKR, 3.875" ID, 9Cr I 4 -1/2" TBG, 12.6 #, 13Cr -80, ID = 3.958" H 8506' �� I 8398' H 4 -1/2" HES "X" NIP, ID = 3.813 ", 9Cr C; 8463' I-1 7" X 4 -1/2" 13Cr UMI Overshot I 1 Minimum ID = 2.387" @ 10031" ;; 8536' H 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 3-1/2" X 2 -7/8" LNR XO :: 8552' 412" FMS XN IMP, MLL ®T0 3.80" ID 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I-f 8595' ` 8596' H I 4 -1 /2 WLEG. ID = 4.00" I i•� 9385' I-17" X 4 -1/2" TIW SS PKR, ID = 4.00" I 4 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I-I 9433' I `' TOP OF 4 -1/2" SLOTTED LNR H 9474' I ■ 7" LNR, 294, L -80, ID = 6.184" H 954T I \ \ \ \ \ \ \ \ \ \ ■ BTM OF 4 -1/2" SLOTTED LNR 1-1 10087' I 10030' I- 3.70" BAKER G -SUB FN 4 -1/2" LNR, 12.6 #, L -80. .0152 bpf, ID = 3.958" H 10110' I ID = 3.00" PERFORATION SUMMARY TOP OF 2 -7/8" SLOTTED LNR I-i 10363' I---'‘ \ REF LOG: BHCA ON 05/14/95 \ \ ANGLE AT TOP PERF: 83 @ 9474' \\ \ \ / I 11788' I- 2 -7/8" BAKER Note: Refer to Production DB for historical perf data \ \ PACKOFF SIZE SPF INTERVAL Opn /Sqz DATE \ 4 -1/2" SLTD 9474 - 10087 0 05/20/95 BTM OF 2 -7/8" SLOTTED LNR I 11788' BUSHING ID = 1.25" 2 -7/8" 4 9550 - 10000 0 11/11/99 2 -7/8" SLTD 10363 - 11788 0 05/22/97 2 -7/8" LNR, 6.5 #. L -80, .0058 bpf, ID = 2.387" I-I 11818' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/12/87 ORIGINAL COMPLETION 05/03/05 KSB /PJC CORRECTION WELL: 18 -15B 05/20/95 RIG SIDETRACK PERMIT No: '1970720 05/22/97 CTD- EXTEND WELL / API No 50- 029 - 21755 -02 04/24/05 RUN 2.7/8" SLTD LNR SEC 19. T11 N, R15E, 813' SNL & 311' EWL 10/24/01 CH /KAK CORRECTIONS 09/13/03 CMO /TLP DATUM MD/TVD /PERF ANGLE BP Exploration (Alaska) '--'~~HIS coYER~ ON OR BEFORE iAlquARY 03 200 L _ c:LOKlXMI~LM-I)OC Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Desc.: Pipe Use: ARCO Alaska, Inc. March 4, 2000 4017 1 4.5" 12.6 lb. L-80 IJ4S Tubing Well: 18-15b Field: Prudhoe Bay State: Alaska APl No.: 50-029-21755-02 Top Log Intvl: Surface Bot. Log Intvl: 8522 Ft. (MD) Inspection Type' Corrosive Damage Inspection COMMENTS · This survey was run to assess the condition of the tubing with respect to corrosive damages. The caliper recordings indicate that the tubing ranges from good to poor condition with respect to corrosive damage. The top 2705' of pipe shows the least corrosive damage, with penetrations ranging from 2% to 38%. The damage is most severe in the interval 4600' to 6120', with penetrations ranging from 67% to 100%. Most of the damage appears in the form of isolated pitting with deeper penetrations forming a line of corrosion on the Iow side. No area of significant cross-sectional wall loss (in excess of 10%) was recorded throughout the interval logged. No area of significant ID restriction (in excess of 0.10 in.) was recorded throughout the interval logged. MAXIMUM RECORDED WALL PENETRATIONS: Hole (100%) Jt. 140 @ 5,831' MD Hole (100%) Jt. 141 @ 5,881' MD Hole (100%) Jt. 142 @ 5,920' MD Hole (100%) Jt. 143 @ 5,945' MD Hole (100%) Jr. 147 @ 6,131' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No area of significant cross-sectional wall loss (in excess of 10%) was recorded throughout the interval MAXIMUM RECORDED ID RESTRICTIONS ' No area of significant ID restriction (in excess of 0.10 in.) was recorded throughout the interval logged. Mi UriLM Field Engineer' R. Richey Analyst: S. Adcock Witness: J. Middendorf J RECEIVED ')fL' , £ £ f ProActive Diagnostic Sei~vlces, Inc. / P.O. Box 1__.~o9, Sta,i:orJ, 7X Phone: (28Z) or rp~o~ . . ~ooo? 565-9085 Fax: (28Z) 565-1369 E-mail PDS~)memorylog.com Pi~Jdhoe Bay Field Office Phon,.:'o APR 05 2000 '..laska Ud & Gas Cons. Commission Anchorage Well: 18-15b Field: Pmdhoe Bay Unit Company: ARCO Alaska, Inc. Country: USA PDS Caliper Overview Body Region Analysis Survey Date: March 5, 2000 Tool Type: MFC40 99493 Tool Size: 2 3/4" ins No. of Fingers: 40 Analysed: Steve Adcock Tubing: Size Weight Grade & Thread NocmOD NomJD Nom. Upset 4.5 ins 12.6 ppi' L-80 [J4S 4.5 ins 3.958 ins 4.5 ins 0 to 1 to I0 to 20 to 4,0 to above 1% 10% 20% 40% 85% 85% Number of joints anab/sed jtotat = 212) Pene 1 26 25 51 81 28 Loss 50 162 0 0 0 0 Damage Configuration ( body ) Numbe~- of joints damaged (total = 183) 95 17 4g 0 28 [~rnage P~file (% wall) penetration body t:~;:a metal foss body 0 50 5 GLM 1 94 GLM 2 GLM 3 Bottom of Survey = 203 100 Analysis Overvie~ page PDS JOINT TABULATION Pipe: 4.5 ins 12.6 ppf L-80 t]4S Well: 18-15b Wall thickness. Body: 0.271ins Upset = 0.271ins Field: Pmdhoe Bay' Unit Nominal ID: 3.958 ins Company: ARCO Alaska, [nc, Country; USA Date: Ma~ch 5, 2000 penetration body metal toss body I]oint ----' Penetration M~a~T Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches [ % % inches inches inches ___ 3 50 10 .11 0 .O0 4 0 .03 3,88 [ PUP 4 0 . .01 I 0 I 0 3.9t 7 0 I .01 2 [ 0 0 3.91 0 3.92 3 0 0 3 ~92 ~ 6 '[---0 ~ .02 8 2 0 0 3.92 t 7 ~ 0 ,02 8 1 0 0 3.91 20 ] 0 .03 10 I 0~ ~0 3.91 22] 0 ,03 10 4 0 0 ~ ~.92 23 0 ~ ,04 /5 5 ] 0 0 [ 3.93 Shallow p~in~. 24 0 ~ .03 [ "1--~ 2 [ 0 0 ~ 3.91 28 [ 0 .03 I2 2 0 0 3.9l ~. 29 ] 0 .03 13 3 0 0 3.92 Shallow pi~ing. 30 [ 0 .04 14 5 [ 0 .04 3.92 Shallow p~ng. 31 J 0 .03 1~ 2 ~ 0 [ 0 3.91 Shallow pi~ing. 33 0 .05 19 6 0 ~ ,04 3.92 Shallow pi~ing~ 34 0 [ .06 23 6 0 I .02 3.92 Corrosion. DeposiU. 35 [ 0 ~ .05 20 5 0' '-~-~i'04 3.93 ~Sha ow corros o ~05 ~ 8 4 0 ~05 3.90 Shallow cor~osion~ .05 t8 3 0 .o41 3.92 Shallow corrosion. .04 16 2 0 ~] 3.92 Shallow ~i~ing. .05 17 4 0 .03 3.92 Shallow plttlng~ 40 0 ~ .05 20 3 0 ~ .03 3.9~ ~ Shallow Ditting. 41 0 .05 20 7 [ 0 .03 3.90 Corrosion. ~ 0 i ~9 I 31 8 j .04 .00~ 3.9l ILine corrosion. Lt, Deposit. 45 0 [ .0~ ~ /0 ~ .05 .~ 3.90 [Lineco~rosion. LtDeposi~. 47[ 0 .08 ~0 ] ,041 3.90 Line corrosion. 48 0 .08 ~ .04~ 3.90 Line cor~osion~ Pipe Tabulations page 1 RE IVED A?R 05 2000 PDS OINT TABULATION S Pipe: 4.5 ins 12.6 ppf L~0 IJ4S Wall thickness. Body: 0.271ins Upset - 0.271 Norninat ID: 3,958 ins ins Well: Field: Countw: Date: 18-!5b Pmdhoe Bay Unit ARCO Alaska, Inc. USA March 5, 2000 62 81 0 Upset Body inches inches 0 0 .06 0 .09 0 .09 0 ,09 0 .10 .10 0 .11 0 0 .I0 0 0 ~ ./3 13 2 561 4 Minimum ID inches 3.89 3.9l 3.88 3.91 SSSV 3.9I 3.90 3.c~9 3.90 3.85 ] 0 0 0 3.90 3.88 3.90 3.90 3.89 3.90 3.88 3.90 3.89 3.89 3.88 3.88 3.89 3.86 3,86 3.89 3,89 3.87 3.88 3.88 3.88 3.89 3.87 3.88 3.88 3.89 3~88 3.88 3.88 i 3.86 0 3.90 3.90 3.88 3.90 o I .07i 3.B8 3.88 3.88 .02 3.91 3.89 3.90 tine corrosion. Lt. _Deposits. Line corrosion. Lt_ Deposits. Line corrosion. Lt. Deposits, PUP Isolated pitting. Isolated line co~roston. ] Isobted pittin~ Lt D~posits. ] Isolated J:.j!ti_12 .L_ _._ Isolated pitting= LL Deposits. Line corrosion. Lt. Deposits. Line corrosion. Isolated ~itting. Lt. Deposits. PUP Isolated GLM I /Latch @ 10:30) PUP 8hailow pitting. Line corrosion. Line corrosion Lt. _D_..e. jposits. Line corrosion. Lt. Deposits. Isolated pitting, Lt. Deposits. 3,88 [Line corrosion. Line corrosion, Line corrosion, Lt. Deposits. Isolated pittir Pipe Tabulations page 2 penetration body metal loss body Damage profile (% walt) 50 100 PDS JOINT TABULATION Pipe: 4,5 ins 12.6ppf L40 IJ4S Wall thickness. Body: 0,271ins Upset = 0,271ins Nominal ID: 3.958 ins Well: 184 5b Field: Prudhoe Bay Unit Company: ARCO Alaska, Inc. Countly; USA Date: March 5, 2000 Upset inches Meta[l Pro}ection [ Minimum Loss Upset Body [ ID % J inches J inchesI~ inches 6] 0 3.89 Line corrosion. 3.90 Line corrosion, 3.90 Line corrosion. Lt. Deposits. 3.89 ;Line con'osion. 3.89 Line corrosion, LL Deposits. 3.88 Line corrosion, 3.88 Line corrosion. 3.90 Line corrosion, 3.89 Line corrosion. Lt. Deposits. 3.87 Line corrosion, Lt, Deposits. 3,88 Lir. e corrosior~. 3.90 Line corrosion. 3.88 Line corrosion. 3,88 Line corrosiot% Lt. Deposits. 3.89 Line corrosion. 3.88 Line corrosion. 3,8l Line corrosion, 3.89 Multiple Possible Holes. 3.87 .! Multiple Possible Holes. 3.89 Possibfe Holes. 3.88 3.88 Possible Holes. 3.88 .041 3.89 Possible Holes. 3.87 Possible Holes. 3.88 Possible Holes· 3,85 Possible Holes. 3.84 hoies. 3.88 Possible Holes. 3.86 holes. 3.88 Possible Ho[es, 3.88 3.88 . Possible .05] 3.89 3.89 3,86 3.89 3.88 3.90 I Isobted 3.89 IMuitiple Possible Holes. [ 3.89 I Line corrosion. 3.90 Possible Hole, 3.89 Poss ble Hole. 3.89 3.89 3.89 3.89 3.88 3.88 3.86 holes. penetration body metal toss body ] Damage profile (% wall} 50 I00 Pipe Tabulations page 3 RECEIV 05 PDS JOINT TABULATION Pipe: 4.5 ins 12,6 ppf L4~0 iJ4S Well: t8-15b Wall thickness. Body: 0.27t ins Upset = 0.27/ins Field: Prudhoe Bay Unit Nominal ID: 3.958 ins Company: ARCO Alaska, Inc. Countw: LISA Date: March 5, 2000 penetration body metal loss body I joint Penetration [ Metal Pro ection i Minimum Damage profile No. Upset Body Loss Upset ' IBod, y ] ID Comments (% wall} inches inches [ % i % ~ inches incnes inches 50 144 t 0 .259'~921 5 0 .06 3~87 IPossibleHote -~]]~-F-- 0 .0 321 2 0 .05 3.89 [ PUP Line corr~ion. , 144.2~ 0 0 -'~ 0 0 0 3.89 GLM 2 ~Latch ~ 5:00) 1~3~ 0 ~ ~8~ 65 4 0 .02- 38~ PUPIsobtedpi~ieg. t45 ~ 0 [ .26 96 6 ] 0 .02 3.89 Possible Hole. t46 ~ 0 [ .2t 79 3 0 .05 3.8~ts&ated iffm. _ 147 i 0 35 100 3 0.06~ 0 ~.90 IHole. Deposits. t48 [ 0 .0938 ~ .02 3z8 .)~p.i~_. __ 149--[ 0 .13 47 2 '---~ 0 %89 Hsotatedpi~ing. Deposi~. t 50~ 0 .16 58 4~ .,D5[ .03 3.86~ Isolated pi~ing. lSl 0 ~ .15 55 2 [ 0.04[[ ,02~ 3,89 Ilsolatedpi~ing. t52 ~ 0 ] 20[ 74 4 [ .03 3.90 Isolated pi~ing. t53 ~ 0 12. 46 2 i 0 [ .02, 3.90 lsob~d ~156 0 [ .17 64 2 ] 0 ] 0 3~89 isolated pi~ing. [ ~57 ~ 0 .17 64 2 .09 .02 3.90 Isolated pi~in~. Deposils. ~~ 56 I .09I 0 I 3.89 I Isolated pi~ing. Deposit. ~j59 }~__O____L .....13 ~ 0 _J 0 3.90 Isolated pitting. ~160 0 [ .'[5l 54 2 0 .03 3.89 solated pi~in~. ,1 61 0 ~ ~. 0 0 3.86 ~tsolated pi~ing. ] 62 0 ~ .14 1531 I .04 i._~. 3~88 ~ Isolated pi~ing. 163 0 I ~/-~ .... 0 0 3.89 Isolated pi~Jng. t64 0 ] H 4 ] 52 2 .07 0 3.87 Isolated piing. Depg.~its. 1165 0 r--'~-~ 44 2 0 04 3.89 Line corrosion. 166 [ 0 .t 1 41~ 1 0 ,04 389 Isolated pi~ing, 167 ~ 0 .t6 58[ 2 .06 .02 3.90 Isolam~m ~e ~s i 0 I .~a ~ ~ .05 .04 ~.88 ]~ t69 ~ ~ .t9[ 68[ ~ .04 .03[ 3.90 Isotatedpitdng. 17t ~ 0 .09 [ 34 2 0 [ 0 ~ 3.89 isolated pitting. 172 ~ 0 .t0~ 3e 2 i 0 ~ -03 3.89 lso_ fatedpi~ing. it73 0 I .071 27 I ] 0 I .06 3.88 Isolated t)i~il]~:_.~ Deposit. ~kt ~ 3.83 Isolated pittin~ Lt DeposiB. ~1/2 0 I .0/~ 27 I ] 0 .0,] 3.86 [[solatedpt~mg. LtD_posits. 177 [~. 15 5~ I 0 .04 3.88 Isolated piUinfi x >~ x~ 178 ~ 0 I .t6 5~ I ,06 ,03 3.89 isolated pitting. Deposits. 179 J 0 } .08 3C = ~ 0 .0~ ~.89 bo,amd R~O.~.__ 180 ~ 0 ] .17 63 t .04 .02 3.87 Isolated pi~infi. i~81 ' 0 ' .1~ 55 I O ,05 3.89 lsolatedpi~iog, -~; ?'~ ~:< 1~82 0 [ .~ 4c ~ [ -0G .04. 3.89 ~obt~i~ 185 ' 0 I .14 51~ t 0 ~ .06~ 3.88 lsolated~osi~. 186 0 [ .06 2tl i 0 [ 0 I 3.88 187 0 I .13 47 2 0 ~ .05 3.87 lsobted pi~ing. [ 188 0 ] .17 61 3 0 ~ ,06 3.87 so~ated p tting. LL Deposits. ~Q______!~O 1 31 I 0m .05 3.87 .p PUP., ~t88.2~ 0 I 0 ] O~-~--'[ 0 I 0 3.87 IGLM~ (Latcbe2:00) Pipe Tabulations page 4 APR O5 2000 PDS C JOINT TABULATION Pipe: 4.5 ins 12.6 ppf L-80 Ij4S Walt thickness. Body: 0.271 ins Upset = 0.271ins Nominal ID: 3.958 ins Well: i 8-/5b Field: Prudhoe Bay Unit Company: ARCO Alaska, Inc. Country: LISA Date: March 5, 2000 penetration body metal loss body Penetration Metal Body Loss % Minimum ! ~D Comments inches 3.87 PUP Line deposits. 3.88 Line corrosion. Lt. Deposits. 3.86 Line corrosion. 3.88 3.86 3.87 3.88 3.88 3.87 3.87 3.89 3.88 3.88 3.88 3.88 3.88 Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal waft thickness Ring - damage area exceeds 60% of circumference, but depth range does not exceed 2 * pipe ID Line - damage depth range exceeds 4 * pipe ID, but extends tess than 30% of circumference General - damage depth range exceeds 2 * pipe [D and/or extends more than 30% of circumference Isolated - damage depth range does not exceed 4 * pipe ID or extend more than 30% of circumference Damage reporiing threshold = 30 thou inches deviation in body, 50 thou in upset Modal tine length = 0.273 feet. Damage profile (% wall) 50 100 Pipe Tabulations page 5 RECEIVED 05 A~aska Oit & Gas Cons. C, ommissior Anchorage Well: 18-15b Field: Prudhoe Bay Unit Conlpany: ARCO Alaska, Inc, Country: USA Tubins;: 4.5 ins 12.6 pp~ bSO IJ4S PDS Caliper Sections Survey Date: March 5, 2000 Tool Type: MFC40 99493 Tool Size: 2 3/4" ins No. of Fingers: 40 Analysed: Steve Adcock Cross section for Joint 142 Too[ speed = 71 Nominal ID = 3,958 Nominal OD = 4.500 Remaining wall area = 98 % Tool deviation = / 8 ° at depth 5920.05 ft Finger 19 Penetration = 0.276 ins HOLE HIGH SIDE = UP RECEIVED Cross-Sections page 1 PDS Caliper Sections Well: 18-I 5b Field: Prudhoe Bay Unit Company: ARCO Alaska, Inc, Country: USA Tubirl 4,5 ins 12.6 ppf L-80 IJ4S Survey Date: March 5, 2000 Tool Type: MFC40 99493 Tool Size: 2 3/4" ins No. o~' Fingers: 40 Analysed: Steve Adcock Cross section for Joint 143 Tool speed = 69 Nominal ID = 3,958 Nominal OD = 4.500 Remaining wall area = 98 % Tool deviation = I g ° at depth 5945.16 ft Finger 17 Radius = 2.292 ilqs HOLE HIGH SIDE=UP RECEIVED APR 05 ~006 Cross-Sections page 2 PDS CALIPER JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 IJ4S Wall thickness. Body: 0.2 71 ins Upset = 0.2 71 ins Nominal ID: 3.958 ins Well: 18-15b Field: Prudhoe Bay Unit Company: ARCO Alaska, Inc. Country: USA Date: March 5, 2000 Joint Depth Length l Measured Type No. ID feet feet inches .1 -.07 5.58 3.945 PuP 1 5.51 41.34 3.969 2 46.85 41.82 3.966 3 88.67 41.85 3.969 4 130.52 41.56 3.966 5 172.08 41.60 3.966 6 213.68 40.52 3.962 7 254.20 42.68 3.967 8 296.88 41.58 3.969 9 338.46 4t .56 3.965 10 380.02 35.08 3.965 11 415.10 41.38 3.962 12 456.48 41.80 3.967 13 498.28 41.58 3.963 14 539.86 41.34 3.972 15 581.20 41.81 3.967 16 623.01 41.79 3.972 1 7 664.80 41.93 3.966 18 706.73 41.60 3.967 19 748.33 41.77 3.965 20 790.10 41.31 3.971 21 831.41 41.90 3.970 22 873.31 40.65 3.966 23 913.96 42.34 3.971 24 956.30 40.03 3.971 25 996.33 42.88 3.970 26 1039.21 41.91 3.975 27 1081.t2 35.55 3.975 28 1116.67 4! .54 3.970 29 1158.21 41.59 3.973 30 1199.80 41.31 3.974 31 1241.11 41.1 4 3.971 32 1282.25 41.36 3.976 33 1323.61 41.54 3.968 34 1365.15 41.22 3.972 35 1406.37 41.62 3.970 36 1447.99 41.81 3.965 3 7 1489.80 41.56 3.974 38 1531.36 41.31 3.974 39 1572.67 41.93 3.97t 40 1614.60 41.34 3.970 41 1655.94 41.72 3.963 42 t 697.66 41.36 3.968 43 1739.02 41.62 3.966 44 1780.64 36.46 3.972 45 1817.10 41.62 3.9651 46 1858.72 36.33 3.970 47 1895.05 36.95 3.960 48 1932.00 41.29 3.968 49 1973.29 4I .83 3.956 Joint Depth Length Measured Type No. ID feet feet inches 50 2015.12 41.11 3.959 51 2056.23 41.71 3.960 51.1 2097.94 10.01 3.951 PUP 51.2 2107.95 6.84 3.960 Sssv 51.3 2114.79 9.50 3.965 Pup 52 2124.29 41.73 3.953 53 2166.02 41.36 nominal 54 2207.38 41.25 3.953 55 2248.63 41.65 3.955 56 2290.28 41.07 3.948 57 2331.35 41.98 3.953 58 2373.33 41.43 3.952 59 2414.76 41.49 3.955 60 2456.25 41.39 3.955 61 2497.64 40.99 3.953 62 2538.63 42.15 3.950 63 2580.78 41.60 3.946 64 2622.38 41.61 nominal 65 2663.99 41.55 3.954 66 2705.54 41.51 3.954 67 2 747.05 41.48 3.953 68 2788.53 41.58 nominal 69 2830.11 41.43 3.951 70 2871.54 41.71 3.949 71 2913.25 41.77 3.953 72 2955.02 41.36 nominal 73 2996.38 41.79 3.948 74 3038.1 7 41.35 3.946 75 3079.52 41.49 3.949 76 3121.01 40.54 3.944 77 3161.55 42.83 3.952 78 3204.38 41.30 3.947 79 3245.68 41.57 3.946 80 3287.25 41.61 3.940 81 3328.86 41.80 3.949 82 3370.66 41.63 3.943 83 3412.29 41.32 3.947 84 3453.61 41.64 3.946 84.1 3495.25 8.99 3.948 Pup 84.2 3504.24 9.51 3.960 Glml 84.3 3513.75 9.79 3.950 Pup 85 3523.54 41.50 3.945 86 3565.04 41.24 3.948 87 3606.28 41.54 3.944 88 3647.82 41.92 3.950 89 3689.74 41.28 3.941 90 3 731.02 41.90 3.943 91 3772.92 41.33 3.951 92 3814.25 41.78 3.952 93 , 3856.03 41.35 3.943 Joint Ta|~, page 1 RECEIVED APR 05 2000 Alaska Oil & Gas Cons. Oornmissior Anchorage PDb CALIPER JOINT TALLY SHEE1 Pipe: 4.5 ins 12.6 ppf L-80 IJ4S Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Well: 18-15b Field: Prudhoe Bay Unit Company: ARCO Alaska, Inc. Country: USA Date: March 5, 2000 Joint Depth Length Measured Type No. ID feet feet inches 94 3897.38 41.78 3.950 95 3939.16 41.15I 3.942 96 3980.31 41.97[ 3.952 97 4022.28 41.08 3.944 98 4063.36 41.90 3.944 99 4105.26 41.24 3.942 100 4146.50 41.54 3.943 101 4188.04 41.7l 3.943 102 4229.75 41.62 3.947 103 4271.37 41.91 3.950 104 4313.28 40.94 3.952 105 4354.22 41.56 3.943 106 4395.78 41.69 3.952 107 4437.47 41.75 3.946 108 4479.22 41.54 I 3.951 109 4520.76 41.81 3.948 110 4562.57 41.98 3.945 111 4604.55 41.38 3.945 112 4645.93 41.58 3.943 113 4687.51 41.91 3.948 114 4729.42 41.49 3.939 115 4770.91 41.63 3.944 t 16 4812.54 41.30 3.944 11 7 4853.84 41.64 3.944 118 4895.48 41.87 3.936 119 4937.35 41.60 3.942 120 4978.95 41.30 3.943 121 5020.25 41.45 3.939 122 5061.70 4! .48 3.937 123 5103.18 41.36 3.938 124 5144.54 41.54 3.928 125 5t 86.08 41.55 3.939 126 5227.63 41.35 3.940 12 7 5268.98 41.40 3.936 128 5310.38 41.50 3.934 129 5351.88 41.50 3.936 I 130 5393.38 41.36 3.938 131 5434.74 41.88 3.938 1 132 5476.62 41.34 3.939 t33 5517.96 4t.75 I 3.941 t 34 5559.71 41.48 3.936 135 5601.19 4t.75 3.935 136 5642.94 41.57 3.936 I I t 37 5684.51 41.62 3.936 138 5726. t3 41.55 3.935 139 5767.68 41.84 3.938 140 5809.52 41.10 3.933 141 5850.62 40.68 3.940 142 5891.30 42.56 3~942 143 5933.86 41.05 3.937 [Joint Depth Length Measured Type i No. ID feet feet inches 144 5974.91 41.43 3.937 i44.1 6016.34 5.87 3.929 Pup 1 44.2 6022.21 12.92 3.960 Giro2 144.3 6035.13 9.56 3.922 Pup i. 145 6044.69 41.41 3.941 146 6086.10 41.60 3.942 147 6127.70 41.67 3.939 148 6169.37 41.42 3.938 149 6210.79 41.64 3.934 150 6252.43 40.84 3.933 151 6293.27 42.27 3.935 152 6335.54 41.57 3.931 153 6377.11 41.56 3.932 154 6418.67 41.87 3.934 155 6460.54 41.54 3.941 156 6502.08 41.36 3.938 157 6543.44 41.81 3.935 158 6585.25 41.29 3.940 159 6626.54 41.78 3.938 160 6668.32 41.67 3.93 7 161 6709.99 41.35 3.936 162 675t.34 41.79 3.932 163 6793.13 41.40 3.929 164 6834.53 41.31 3.927 165 6875.84 42.2 7 3.934 166 6918.11 41.18 3.933 167 6959.29 41.84 3.935 168 7001.13 41.40 3.93 7 169 7042.53 41.94 3.938 170 7084.47 41.60 3.937 171 7126.07 41.64 3.939 1 72 7167.71 41.62 3.941 1 73 7209.33 41.32 3.932 174 7250.65 41.59 3.933 175 7292.24 41.76 3.928 176 7334.00 41.76 3.935 1 77 7375.76 41.48 3.931 1 78 741 7.24 41.32 3.931 1 79 7458.56 41.88 3.940 180 7500.44 41.34 3.932 18t 7541.78 42.12 3.930 182 7583.90 41.37 3.934 183 7625.2 7 41.52 3.930 184 7666.79 41.78 3.934 185 7708.57 41.54 3.925 186 7750.11 41.25 3.930 187 7791.36 41.78 3.934 188 7833.14 41.46 3.931 188.1 7874.60 11.40 3.923 Pup 188.2 7886.00 8.40 3.960 GIm3 Joint Tally page 2 RECEIVED APR 0,5 2000 ~,taska 011 & Or~ ~;t.~. ~;ommissior, PDS CALIPER JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 IJ4S Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Joint Depth ] Length Measured Type No. ID feet feet inches 188.3 7894.40 8.56 3.929 Pup 189 7902.96 41.90 3.932 190 7944.86 41.30 3.934 191 7986.16 42.02 3.933 192 8028. t 8 41.32 3.937 193 8069.50 41.89 3.935 194 8111.39 41.15 3.934 195 8152.54 41.78 3.938 196 8194.32 41.85 3.929 197 8236.17 41.51 3.928 198 8277.68 41.37 3.928 I 199 8319.05 41.46 3.93 ! '200 8360.51 41.45 3.934 201 8401.96 41.45 3.928 202 8443.41 41.02 3.916 203 8484.43 unknown I 3.972 Well: 18-15b Field: Prudhoe Bay Unit Company: ARCO Alaska, Inc. Country': USA Date: March 5, 2000 JointI Depth Length Measured Type No. ID feet feet inches joint Tally page 3 RECEIVED APR 0,5 2000 Alaska Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 48 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Ser~ce__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 813' FNL, 4641' FEL, Sec. 19, T11N, R15E, UM 18-15B At top of productive interval 9. Permit number / approval number 1464' FNL, 2280' FEL, Sec. 19, T11N, R15E, UM 97-72 At effective depth 10. APl number ~ 50-029-21755-02 At total depth 11. Field / Pool 3100' FNL, 791' FEL, Sec. 19, T11N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11818 feet Plugs (measured) true vertical 8749 feet ....... Effective depth: measured 11818 feet Junk (measured) Alaska 0JJ ~' ', true vertical 8749 feet Arichoragp, casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 1680# Poleset 1 10' 1 10' Surface 2638' 13-3/8" 2500 Sx CS I, & 55o Sx CS, 2686' 2686' Production 8127' 9-5/8" 500 Sx C~ass G 8175' 7808' Liner 1526' 7" 625 Sx C~ass G 9547' 8717' Slotted Liner 726' 4-1/2" Uncemented 10110' 8737' Slotted Liner 1788' 2-7/8" Uncemented 11818' 8749' Perforation depth: measured Slotted liner @ 9433'- 10087' & 10363'- 11788'; Reperf'd @ 9550'- 10000'. true vertical Slotted Liner @ 8707'- 8735' & 8729'- 8747'; Reperf'd @ 8717'- 8727'. Tubing (size, grade, and measured depth) 4.'1/2~'12.~#, 1-80'I'bg @ 850~' MD. Packers & SSSV {type & measured depth) 7' X 4-1/2' IIW 8s HORIZONTal PACKfiR @ ~05' MD; 7" X 4-'I/2" B~KFR S-a PACKER @ ~537' MD. 4-'1/2' GAMGO TRGF-4^ SSSV @ 2'12~' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure lubing Pressure Pdor to well opera,on (shut Subsequent to operation 1008 7058 269 12@7 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil .__X Oas ~ Suspended _ Service 17. I hereby certi~ that the fore,ding is true and correct to the best of my knowledge. Signed ~.~-'.~ i~~ ~ '* Title ARCO EngineeringSupervisor Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 18-15B DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summa~ 11/10/1999: 11/11-12/1999: MIRU work platform & CTU. PT'd BOPE. RIH & tied into XN nipple w/TEL. Killed well w/ KCL Water. FP IA w/Crude. Flushed tbg w/KCL Water & laid in FIo Pro. POOH. MU perf guns. RIH w/Tubing Conveyed Perf Guns & reperforated 450' of the 4-1/2" slotted liner @: 9550' - 10000' MD (Zone 1 B) Reference Log: BHCA 5/14/1995. Used 2-7/8" carriers and all shots @ 4 SPF, 90° phasing, balanced press & random orientation. POOH w/guns. Verified ASF. RDMOL. Returned well to production & obtained a valid well test. .... We received a waiver from the state to produce this well for 2 week period to collect production data. Prior to the perforation job, the well was shut in for annular communication. Future options are being evaluated. RECEIVED 1999 11-16-99 ? 15:01 Frem-E0C PreMmmm T-334 P.O1/04 F-253 To; blair_wondzell@admin.state.ak.us, tom_maunder@adrnin.state.ak.us cc: (bcc: PRB Problem Wells/AA.I/ARCO) Subject: 18-15 Flow Request Hi Tom and Blair. We would like to flow well 18-15 for up to 2 weeks to evaluate the ~vell rate post. re-perf. Well 18-15 was shut-in 10/7/99 due to Tubing by 9-5/8" Casing communication, A video log run 10/22/99 identified holes in the ~from 5926' - 6135'. Well tests indicate the well is not producing any water, implying we have competent 9-5/8" casing. Wel~ rates at the time of shut-in were <100 BOPD, 0 BWPD, 10 MMCFPD. The well is capable of unassisted flow of hydrocarbons up the Tubing x 9-5/8" annulus. The short term test would allow us to evaluate well repair options, During the flow te,~It, we will increase well surveillance. The 9-5/8" x 13-::~" annulus has successfully pressure tested to 2000 psi, Call if you have any questions, Joe Anders Problem Well ,Specialist ARCO Alaska, Inc. (907) 659.5102 p104t @mail .aai.a rco.com RFCEIVED NOV 6 1999 u. ~ vas uu.s. Commission Anchorage Post-ItTM brand fax transmittal memo 76-/1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I 1 Status of Well Classification of Service Well Oil_X Gas__ Suspended__ Abandoned__ Service__ 2 Name of Operator !7 Permit Number ARCO Alaska, Inc. 97-72 1:3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 _~ ......... 50-029-21755-02 4 Location of well at surface ~ r~'~ r,.z~ ;~ ~;'. ~I ~:i~' '~ ~, ~-¢~, 9 Unit or Lease Name , '¢'L~'-Y~ ; ,.~.,,~r.'* "'i-- /---- ._~ PRUDHOE BAY UNIT 4466' NSL, 4642' WEL, Sec 19, T11 N, R15E, UM. ~ ,***E ~ At Top Producing interval !! ~-.~¢'~'"~/~¢,__ , _'~'~'~ 10 Well Number 3705' NSL, 2209' WEL, Sec 19, Tll N, R15E, UM.;i~¢.~--%'~_,~ i ;-~"~ 18-15B At Total Depth J ~ i-~. ~ r 11 Field and Pool 3100' FNL, 791' FEL, Sec 19, T11N, R15E, UM. ~ ........ '~ ............ ;..~ : ~'~"'~ PRUDHOE BAY FI ELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 48' RKB ADL 28321 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 5/18/97 5/22/97 5/23/97 N/A 1 17 Total Depth (MD+-FVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 11818' MD / 8749' TVD 11818' MD / 8749' TVD YES_X NO__ 2125' feet MD 1900' feet (approx) 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. .GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 91.5# H-40 Surf 110' 30,' 1680# Poleset - 13-3/8" 72# L-80 Surf 2686' 17.5" 2500 Sx CS III & 550 Sx CS II - 9-5/8" 47# L-80 Surf 8175' 12.25" 500 Sx Class G - 7" 29# L-80 8021' 9547' 8.5" 625 Sx Class G - 4-1/2" 12.6# L-80 9384' 10110' 6,, Uncemented (Slotted Liner) - 2-7/8" 6.5# L-80 10030' 11818' 3.75" Uncemented (Slotted Liner) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Slotted Liner: 0RI61NAL 4-1/2" Tbg 8596' 8536' 9433 - 10087' MD; 8707- 8735' TVD. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 2-7/8" Slotted Liner: DEPTH INTERVAL MD AMT & KIND MATERIAL USED 10363 - 11788' MD; 8729 - 8747' TVD. 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 5/27/97 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR 6/8/97 4.4 TEST PERIOD --I 1366 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL I GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 568 - 24 HOUR RATE _X 3362 3555 38 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-401 form approved 5/5/97 (Permit # 97-72). JLJN ]9 1997 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, and fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and time of each phase. Sag River 8644' 8126' N/A Shublik 8696' 8166' Top Sadlerochit 8776' 8231' ; -., 31 LIST OFATTAGHMENTS Summary of 18-15B Ooil Tubing Wellbore Extension Dril[in~ Operations. 321 hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 18-15B DESCRIPTION OF WORK COMPLETED CTU WELLBORE EXTENSION DRILLING 5/17/97: MIRU CTU & PT BOP. 5/18~97: MU & RIH w/milling BHA while killing well. Milled out the XN Nipple at 8552' MD to 3.80", then RIH & milled on the PO bushing at 10086' MD & guide shoe at 10110' MD. Milled through PO bushing & guide shoe, then POOH displacing the well to FIo Pro. RIH w/drilling BHA & drilled a 3.75" extension borehole out of the 4-1/2" liner to 10135' MD. 5/19/97: Drilled horizontally to 11320' MD. POOH w/BHA. RIH w/drilling BHA & resumed drilling to 10513' MD. Shod tripped to 9300' MD, then RIH drilled to 10635' MD. 5/20/97: Drilled to 10650' MD. Shod tripped to 9300', then RIH & drilled to 10826' MD. Shod tripped to 9300', then RIH & drilled to 10923' MD. POOH w/BHA. RIH w/drilling BHA. Drilled to 11010' MD & pipe stuck. Pumped 25 bbls Crude & worked pipe free. 5/21/97: PU to 9000' MD & displaced well to new FIo Pro. RIH & continued drilling w/shod trips to 11710' MD. 5/22J97: Drilled to 11800' MD. Short tripped to 9300' MD, then RIH & drilled to TD at 11818' MD. Circulated Hi-Vis sweep & POOH w/BHA. MU & RIH w/2-7/8" slotted liner assembly. Landed liner at 11818' MD. Released to leave liner assembly at 10030' to 11818' MD. POOH circulating well over to Crude. 5/23/97: ND BOP. NU & PTtree. RD & released rig. Placed the well on production & obtained a valid production test. SPE"--'(-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / 18-15B 500292175502 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052197 MWD SURVEY JOB NUMBER: AK-MW-70146 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9998.00 8726.70 8678.70 10110.00 8736.85 8688.85 10120.22 8737.88 8689.88 10130.17 8738.94 8690.94 10140.29 8739.81 8691.81 84 84 83 84 85 48 S 18.30 E .00 1304.80S 2632.70E 2934.90 48 S 18.30 E .00 1410.70S 2667.72E 3017.03 34 S 20.30 E 22.84 1420.29S 2671.08E 3024.64 17 S 20.31 E 7.14 1429.57S 2674.52E 3032.15 46 S 19.38 E 17.34 1439.05S 2677.94E 3039.75 10152.69 8740.55 8692.55 10170.87 8740.99 8692.99 10180.17 8740.93 8692.93 10192.12 8740.64 8692.64 10209.64 8739.89 8691.89 87 89 9O 91 93 23 S 16.25 E 28.34 1450.84S 2681.72E 3048.80 49 S 14.59 E 16.19 1468.35S 2686.56E 3061.54 56 S 12.91 E 21.77 1477.39S 2688.77E 3067.87 50 S 11.43 E 14.45 1489.06S 2691.28E 3075.75 4 S 9.85 E 11.46 1506.26S 2694.52E 3086.94 10228.84 8738.43 8690.43 10247.89 8736.32 8688.32 10266.17 8734.53 8686.53 10286.87 8733.29 8685.29 10301.27 8732.56 8684.56 95 97 94 92 93 37 S 6.68 E 21.12 1525.21S 2697.27E 3098.57 7 S 5.10 E 11.40 1544.03S 2699.21E 3109.43 7 S 5.80 E 16.79 1562.14S 2700.94E 3119.75 43 S 10.02 E 21.46 1582.60S 2703.78E 3132.19 3 S 13.26 E 22.60 1596.69S 2706.68E 3141.58 10322.47 8731.36 8683.36 10351.49 8729.58 8681.58 10383.44 8727.92 8679.92 10407.67 8727.31 8679.31 10420.34 8727.26 8679.26 93 93 92 9O 9O 25 S 16.88 E 17.14 1617.12S 2712.19E 3156.33 35 S 19.52 E 9.10 1644.64S 2721.23E 3177.62 22 S 21.10 E 6.26 1674.55S 2732.31E 3201.85 29 S 19.74 E 9.58 1697.25S 2740.75E 3220.28 0 S 21.45 E 14.04 1709.11S 2745.21E 3229.94 10444.07 8727.31 8679.31 10470.12 8727.41 8679.41 10488.44 8727.79 8679.79 10513.49 8729.20 8681.20 10549.72 8731.64 8683.64 89 89 87 85 86 44 S 22.85 E 6.00 1731.09S 2754.16E 3248.45 49 S 24.08 E 4.73 1754.98S 2764.53E 3269.14 48 S 26.55 E 17.41 1771.54S 2772.36E 3284.04 46 S 29.89 E 15.56 1793.57S 2784.18E 3305.09 28 S 31.12 E 3.90 1824.71S 2802.53E 3336.28 10580.77 8733.31 8685.31 10619.84 8734.51 8686.51 10629.82 8734.59 8686.59 10642.57 8734.52 8686.52 10680.82 8733.61 8685.61 87 89 9O 9O 92 21 S 32.17 E 4.41 1851.10S 2818.80E 3363.33 7 S 33.75 E 6.05 1883.86S 2840.04E 3397.83 0 S 33.23 E 10.24 1892.19S 2845.55E 3406.69 37 S 33.75 E 6.35 1902.82S 2852.58E 3418.01 6 S 34.81 E 4.78 1934.41S 2874.12E 3452.20 10698.17 8732.97 8684.97 10728.49 8731.80 8683.80 10750.37 8731.19 8683.19 10778.14 8730.85 8682.85 10806.77 8730.59 8682.59 92 92 90 90 90 6 S 34.98 E .97 1948.63S 2884.03E 3467.78 18 S 36.78 E 5.97 1973.18S 2901.79E 3495.24 52 S 36.21 E 6.99 1990.76S 2914.80E 3515.16 31 S 38.85 E 9.59 2012.78S 2931.71E 3540.65 31 S 40.61 E 6.15 2034.79S 2950.01E 3567.34 ORIGINAL JUN 1 ] 1997 Gl & Gas Cons. ""'~ ~ '''~ '" ,~chorage SPF Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / 18-15B 500292175502 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052197 MWD SURVEY JOB NUMBER: AK-MW-70146 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10838.92 8730.41 8682.41 90 5 S 41.49 E 3.06 2059.04S 2971.12E 10885.19 8730.41 8682.41 89 54 S 42.19 E 1.56 2093.51S 3001.98E 10927.54 8730.25 8682.25 90 31 S 42.37 E 1.53 2124.84S 3030.47E 10952.34 8730.04 8682.04 90 26 S 44.48 E 8.52 2142.85S 3047.52E 10988.99 8729.84 8681.84 90 10 S 48.52 E 11.05 2168.07S 3074.10E 3597.59 3641.32 3681.46 3705.11 3740.61 11032.44 8729.71 8681.71 90 10 S 52.21 E 8.49 2195.78S 3107.55E 11053.29 8729.85 8681.85 89 1 S 56.08 E 19.36 2207.99S 3124.45E 11088.96 8730.18 8682.18 89 54 S 58.89 E 8.25 2227.16S 3154.52E 11113.79 8730.08 8682.08 90 31 S 61.53 E 10.92 2239.50S 3176.07E 11141.44 8729.93 8681.93 90 5 S 64.52 E 10.93 2252.04S 3200.71E 3783.32 3804.02 3839.62 3864.45 3892.08 11170.64 8730.07 8682.07 89 22 S 66.45 E 7.04 2264.15S 3227.27E 11200.11 8730.34 8682.34 89 33 S 68.73 E 7.76 2275.38S 3254.51E 11239.46 8730.01 8682.01 91 24 S 71.72 E 8.93 2288.69S 3291.53E 11268.09 8729.28 86.81.28 91 29 S 74.36 E 9.22 2297.04S 3318.90E 11293.56 8728.80 8680.80 90 41 S 76.12 E 7.57 2303.53S 3343.53E 3921.18 3950.44 3989.26 4017.24 4041.90 11340.39 8728.62 8680.62 89 44 S 79.81 E 8.14 2313.29S 3389.32E 11378.54 8728.09 8680.09 91 50 S 81.74 E 7.48 2319.41S 3426.97E 11396.11 8727.70 8679.70 90 41 S 83.68 E 12.80 2321.64S 3444.39E 11426.04 8727.45 8679.45 90 15 S 84.20 E 2.28 2324.79S 3474.15E 11467.24 8727.11 8679.11 90 41 S 85.43 E 3.17 2328.52S 3515.18E 4086.66 4122.52 4138.83 4166.36 4204.02 11484.64 8726.99 8678.99 90 5 S 86.31 E 6.15 2329.77S 3532.53E 11506.69 8727.17 8679.17 88 56 S 87.37 E 7.09 2330.99S 3554.54E 11531.74 8728.00 8680.00 87 16 S 88.60 E 8.25 2331.87S 3579.56E 11562.56 8729.72 8681.72 86 19 N 89.08 E 8.12 2332.00S 3610.32E 11617.96 8733.65 8685.65 85 31 N 87.01 E 4.00 2330.11S 3665.54E 4219.79 4239.61 4261.89 4288.83 4336.15 11663.86 8737.31 8689.31 85 20 N 81.21 E 12.60 2325.42S 3711.03E 11717.74 8741.77 8693.77 85 10 N 77.52 E 6.83 2315.51S 3763.80E 11769.04 8745.78 8697.78 85 52 N 73.12 E 8.66 2302.55S 3813.26E 11780.99 8746.64 8698.64 85 52 N 71.01 E 17.61 2298.88S 3824.60E 11818.00 8749.30 8701.30 85 54 N 64.40 E 17.81 2284.89S 3858.73E 4373.61 4414.88 4451.79 4459.91 4482.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4484.48 FEET AT SOUTH 59 DEG. 22 MIN. EAST AT MD = 11818 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 119.12 DEG. TIE-IN SURVEY AT 9,998.00' MD WINDOW POINT AT 10,110.00' MD PROJECTED SURVEY AT 11,818.00' MD SP5 f-SUN DRILLING SERVICES ~NCHOP_AGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU / 18-15B 500292175502 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052197 JOB NUMBER: AK-MW-70146 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9998.00 8726.70 8678.70 10998.00 8729.81 8681.81 11818.00 8749.30 8701.30 1304.80 S 2632.70 E 1271.30 2173.99 S 3080.89 E 2268.19 996.89 2284.89 S 3858.73 E 3068.70 800.51 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. PAGE 4 ~f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA SHARED SERVICES DRILLING PBU / 18-15B 500292175502 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052197 JOB NUMBER: AK-MW-70146 KELLY BUSHING ELEV. = 48.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTi52qGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9998.00 8726.70 8678.70 11818.00 8749.30 8701.30 1304.80 S 2632.70 E 1271.30 2284.89 S 3858.73 E 3068.70 1797.40 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 5, 1997 Erin M. Oba Engineering Supervisor ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoe Bay Unit 18-15B ARCO Alaska, Inc. Permit No: 97-72 Sur. Loc.: 4466'NSL, 4642'WEL, Sec. 19, TllN, R15E, UM Btmhole Loc: 2976'FNL, 771'FEL, Sec. 19, T11N, R15E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by,la~v from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman ' . BY ORDER OF THE COMMISSION dlf/enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll_ Redrill ~ lb. Type of Well ExploratoryM Stratigraphic Test _ Development Oil Re-Entry__ Deepen ~ Service_ Development Gas M Single Zone X Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 48' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28321 Prudhoe Bay Oil Pool 4, Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 4466' NSL, 4642' WEL, Sec 19, T11 N, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 3705' NSL, 2209' WEL, Sec 19, T11 N, R15E, UM. 18-15B #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 2976' FNL, 771' FEL, Sec 19, T11 N, R15E, UM. May, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line I No Close Approach 11680' MD / 8733' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth N/A Maximum hole an~lle 92° Maximum surface 2800 psig At total depth (TVD) 3500 psi~ 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 1500' 10000' 8729' 11600' 8733' N/A (Slotted Liner) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10110 feet Plugs(measured) true vertical 8737 feet ORIGINAL Effective depth: measured 10086 feet Junk (measured) true vertical 8735 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 1680 # Poleset 110' 110' Surface 2638' 13-3/8" 2500 Sx CS I11,550 Sx CS I1 2686' 2686' Production 8127' 9-5/8" 500 SxCl G 8175' j~ ~1~ ~ V Liner 1526' 7" 625 Sx CIG 9547' Slotted Liner 726' 4-1/2" Uncemented 10110' '-' Perforation depth: measured Slotted Liner: 9433- 10087' AF'R 1 G 1997 4laska 0ii & 6as Cons. true vertical Slotted Liner: 8707 - 8735' Ar~ch0rage 20. Attachments Filing fee ~ Property plat_ BOP Sketch X Diverter Sketch _ Drilling program x Drilling fluid program __ Time vs depth pict_ Refraction analysis _ Seabed report-- 20 AAC 25.050 requirements 21. I hereby certify that th e foregoing is true and correct to the best of my knowledge ~j ~,5-t-.;o ;.~ 5 ~ C ~ i ~ 5 ~' ~'V ¢ ¥,,/0. ¢'c~. ~.'[' ~ ~ 5~'- Signed ~"~_,~V' ~ - ~ Titlle Engineering Supervisor Date /./4 _ / 5- c/7 Commission Use Only Permit NL'g~n--~2 iAP' number z_[ Approval date ~f See cover letter for ~.,~_.~ 50- 0.2-~'- ~ ~' ~;2 ,,~'.~'_ c:s _ ¢~'~ ,~'.., other requirements Conditions'of apl~roval Samples required Yes ~ No Mud Icg requ~ed _ Yes ~ No Hydrogen sulfide measures '~,~Yes _ No Directional survey required '~-<'Yes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M _~.-[~3500 psi for CTU Other: d~'~g~na~ $lgnea dy David W. Johnston by order of Approved by Commissioner the commission Date ~"-" ~.~-"~ 9 Form 10-401 Rev. 7-24-89 Submit in tdl: icate DS 18-15B CT Extension and Completion Intended Procedure Objective: Directionally drill -1500', 3-3/4" horizontal extension from the wellbore. Complete with 2-7/8" slotted liner. existing Intended Procedure: · RU CTU/Nabors 3S. RIH and mill out shoe in 4-1/2" slotted liner. Load well with +8.9 ppg polymer mud. Directionally drill ~1500' of 3-3/4" horizontal hole to access Romeo reserves. · Run 2-7/8" slotted liner to TD. · RD CTD, return well to production. April 15, 1997 DS 1 8-1 5B Proposed Wellbore Sketch Extension of Wellbore & Completion 4-1/2" Camco TRCF-4A SSSV 3.812" ID 2125' --4-1/2" Production Tubing 1/2" Camco GLMs 7" Liner top 7"Baker $-3 Packer 4-1/2"HES No-Go Nipple 8021' 8536' 8552' 2.875" Slotted Liner 9-5/8" Window @ 8175- 8225' 7" Liner Shoe 9547' 4-1/2" Slotted Liner to 10110' TIW SS Packer @ 9384' 3.75" Openhole +/-1500' T 2.875" TOL ~ 10000' TD +/- 11600' ARCOPRUDHOENABORS18-¶5 AALASKA ALASKA BAY 4 INC. rue (+0) ag (+28.62) ii i ARCO ALASKA INC. 1815AT 1815ORTR -1200 -1500 -1800 -2100 Departure Scale I inch · 300 ft 18-15 A ~ 7 APPROXIMATE FAULT LOC. - 8600 ---. -2400 ? -- ~' N, 18-15 A o Vertical Section Scale I inch · 200 ft PLANE OF VERT SECTn 119.12° RELATIVE TO TRUE NORTH lO-APR-97 DRILEX SYSTEMS. INC PAGE: 009 08:29 INVENTORY TRANSACTION XMT POST REGISTER TRX ITEM TRX COMPONENT LOCATION NO TRX DATE TYPE TYPE SERIAL NO W/H TRF MWD PRODUCT QTY PART NO DESCRIPTION AMOUNT 203399 09-APR-97 C T ST NZ7516 MH HU I 14-475-093 STATOR 5" OD W/ DX 4-1/4 W/ $2195.38 ****** RECORD POSTED 09-APR-97 1646 203400 09-APR-97 C T ST NZ7410 MH HU ****** RECORD POSTED 09-APR-97 1646 1 14-475-093 STATOR 5" OD W/ DX 4-1/4 W/ $2195.38 203401 09-APR-97 C T ST NZ7512 MH HU ****** RECORD POSTED 09-APR-97 1646 1 14-475-093 STATOR 5" OD W/ DX 4-1/4 W/ $2195.38 203402 09-APR-97 C T ST NZ7511 MH HU ****** RECORD POSTED 09-APR-97 1646 1 14-475-093 STATOR 5" OD W/ DX 4-1/4 W/ $2195.38 203403 09-APR-97 C T ST NZ7515 MH HU ****** RECORD POSTED 09-APR-97 1646 1 14-475-093 STATOR 5" OD W/ DX 4-1/4 W/ $2195.38 040974 07-APR-97 C R OS NX7183 OK CA ****** RECORD POSTED 07-APR-97 0247 1 14-475-087 OUTPUT SHAFT $766.87 040975 07-APR-97 C R OS NX7169 OK CA ****** RECORD POSTED 07-APR-97 0247 1 14-475-087 OUTPUT SHAFT $766.87 040976 07-APR-97 C R OS NS7065 OK CA ****** RECORD POSTED 07-APR-97 0247 1 14-475-256 OUTPUT SHAFT $1699.83 040977 07-APR-97 C R OS NS7064 OK CA ****** RECORD POSTED 07-APR-97 0247 I 14-475-256 OUTPUT SHAFT $1699.83 040978 07-APR~97 C R OS NS7063 OK CA ****** RECORD POSTED 07-APR-97 0248 1 14-475-256 OUTPUT SHAFT $1699.83 040943 07-APR-97 C R UH YM2010 OK CA ****** RECORD POSTED 07-APR-97 0248 I 14-475-060P BOTTOM SUB F/ADJUSTABLE BENT $1024.40 040944 07-APR-97 C R UH YM2009 OK CA ****** RECORD POSTED 07-APR-97 0248 1 14-475-060P BOTTOM SUB F/ADJUSTABLE BENT $1024.40 040945 07-APR-97 C R UH WJ7031 OK CA ****** RECORD POSTED 07-APR-97 0248 1 P14-475-591-00 UNIVERSAL HOUSING - STRAIGHT $0.01 040946 07-APR-97 C R UH WJ7030 OK CA ****** RECORD POSTED 07-APR-97 0248 1 14-475-591-00 UNIVERSAL HOUSING - STRAIGHT $921.44 040947 07-APR-97 C R UH WJ7029 OK CA ****** RECORD POSTED 07-APR-97 0248 1 P14-475-591-00 UNIVERSAL HOUSING - STRAIGHT $0.01 ITEM TYPE : ( C = COMPONENT E = EXPENDABLE M = PRODUCT TRX TYPES ; ( 0 = ORIGINAL ISSUE $ = SALE OF PART TANDEM CODES: (N = NON-TANDEM T = THIRD PARTY X = MWD Y = TANDEM 1 18.-15A.xls . ~- 3-33 A DIRECTIONAL SIDETRACK PLAN ~ 4/15/97 4:3~ AM ARCO 18-15 A PREPARED APRIL 15 1997 I VERTICAL SECtiON ~SEDII: 119.12° RELAT)¥E TO TR~ ~ORTHI I I i ! I __ RKB I :~47.90 , , ' ' ' ' ' NOTE[ : N/S &EAN EEL. TO TRUE NORTH/ASP COOED. ARE EEL. TO GRID NORTHI SURF^CE LOC. t~ I ~ J I i SU.FACE LOCATe. MAG. DEC. TO TRUE N. ~ : 28.63° II i I / ASPY ASP X GRID CON~RGENCE Inc. I: 1.~[1' ~1 aui~d ~ ~ I'/ 5961061'0/ASp Y 692~7.0 Comments MD D r SS DE~ VS N/~ ~-W~ Tum~ Dog~eg~ ASP X 1. TIP 9998.0 84.8~ 161.7 867&7) 2934.9 -1304.8~ 2~2.7 J 0.0J 0.0~ 0.0J 5959824.0 694732.0 10020.0 84.8 ~ 161.7 8680.7 j 2951.1 -1325.6~ ~.6 j 0.0~ 0.0 j 0.0 J 5959803.5 ~4739~ 10050.0 84.8 16~.7 8683.4 2973.11 -1354.0/ 2649.0 0.0' 0.0 0.0 5959~5.5 694749~ 10080.0 ~.8 161.7 8~6.1 ~95.0 -1382.3~ 2~8.4 0.0 0.0 0.0 5959747.0 694759.6 2. KOP BUILD 20~ HIGHSIDE 10110.0 ~.8 161.7 8~8.9 3017.0 -1410.7 2667.7 0.0 0.01 0.0[ 5959719_0 6~769.7 3. HOLD 10146.0 92.0 161.7 8689.9 ~ ~.5 -1444.8 ~ 2679.0 ~ 20.0 ~0.0 ~.0 694781.9 10170.0 92.0J 1~.5 8689.0 30~.5 -1~7.9 26~.6 ~ 0.0 20.0 20.0 5~96~.5~ ~4789.0 4. TURN LEFT 20~ DL ~0~ TFC 10196.0 92.0~ 171.7 8688.1 ~77.2 -1493.4 -0.1 . 20.0 20.0 6947~ 26~.5 5959~7.0 1~00.0 ~.0 170.9 8688.0 3079.6 -1497.4 2691.1 0.01 -~.0i 20.0 595~3.0 ~4795.3 164.9 ~ I 102~.0 92.0 ~87.0 ~99.4 - t 526.7 2697.4 { 0.0' -20.0 { 20.0 5~.0 { 6~2,3 10260.0 91.9 158.9 8685.9~ 3121.4 -1555.2 2706.7 ~ ~.1 -20,0 ~.0 5~75.5 ~12.3 10290.0 91.9 152.9 8684.9 31~.4 -1~2.5 2718.9j -0.2 -20.0 20.0 595~.5 ~25.3 5. DROP 20~ 10291.0 91.9~ 152.7 8684.9 31~,2 -1583,4 2719,4~ ~.2 -20,0 20.0 595~47.5 ~ 694825.8 6. END DROP 5.29~ DL ~90~ TFC 10300.3 90,0 152.7 8684,8~ 31~.0 -1591.7 27~,7 ~ -20,0 0.0 20,0 5959539.5~ 694830.3 10320.0~ 90.0 151,7 86~.8 3170.5 -16~.1: 2732,9 ~ 0.0 -5,3~ 5.3 5959522.5~ 6~9,9 103~.0 90.0 150.18684.8 ~ 31~.0 -1635.3: 2747.5 { 0.0 -5.3] 5.3 5~9496.5 ~ 6948~.1: ~.3~ 5.3 595~71.0~ ~71.1: ~3~.~; ~0.~ ~.~.5 ~-si ~'~1 -~1.~ 27~.~ o.oi , _ 10410.0 90.0 ~.3~ 5.3 5~94~.0 ~ ~4~7,8 10440.0 90.0 145.3, "84.81 3275.0, -1711.3~ 27~.6, 0.0, ~.3 5.3 -1735.8 2813.0 I ~ 10470.0 90,01 ~43.7 ~ 86~.81 ~02,1 ~ 0.0~ -5,3~ 5,3~ 5959398,0 ~ 694923,2 10500.0 90.0 142,1 86~.8~ ~.6 -1759.7 2~1.1~ 0,0} -5.3~ 5.3i 5959374,5 ~ ~4~1.9 10530.0 90.0 140.5 8684.8 3357.3 -1783.1 t 2849.8~ -5.3~ 5,3' 5959351,5~ 694~1.2 8684.8 33~.4 - 18~.0 28~.2 ~ 0.0 ~.3 ~ 5.3 ~ 5959329.0 ~ ~4981.2 10560.0 90.0 139.0 10620.0 90.0 135.8 86~.7 ~42.4 -1~0.1 ~09.8 i 0.0 -5.3 5.3 5~92~.0 695~.9 10650.0 90.0 134.2 86~.7 ~71.2 -1871.4 ~31.0~~ 0.0 -5.3 5.3 5~.0 ~044~ 10680.0 90.O 132.6 8~4.7 ~ ~0.3 -18~.0 2~2.81 0.0 -5.3 5.3 595~45.0 6~0~ ~.0 131.0 8684.7 3529.6 -1912.0 ~75.2~ 0.0 ~.3~ 5.3~ 595~6.0 695~.8 10710.0 9O.O 10740.0 129.4 86~.7 ~59.0 -~.31 29~.1~ 0.0 ~.3~ 5.31 5959207.0 ~113~ 10800.0 90.0~ 126.3 8684.7 ~18.3 -1~.2 3045.5/ 0.0 -5.31 5.3 5~9171.51 695161.5 10830.0 90.0 124.7 8684.7 ~8.1 -1~5.6~ 3069_9/ 0.0~ -5.3~ 5.3 5~9154.5 6951~.~ 0.0~ -5.3 -5.3 5.3 10860.0 ~.0 123.1 86~.7 ~78.0 -2002.3~ 3~.8~ 59591~.5 695211.7 10890.0 90.0~ 121.5 8684.7 3708.0 -20~8.31 3120.2 0.0 5.3~ 5~9123.0~ ~5~7.4 I 0.0 I I 5~91~.5 10920.0 90.0 119.9 8~4.7 3738.0J -~3.6 31~.0 -5.3 5.3~ 6~3~ 10950.0 90.0 118.3 8684.7 3768.0~ -20~.2 3172.2~ -5 3~ 5.3~ 3797.9' -20~.1 3198.8~ 0.0 -5.31 5.3 595~81.5~ 695317.1 10980.0 90.0 116.7 8684.7 ~27.9 11010.0 90.0 115.2 8~4.7 -2075.2 3~5.7 0.0 -5.3j 5.3 5~69.0~ 695344.~ 11040.0 90.0 113.6 8684.7 3857.8 ~ -2~7.6 3253.1 0.0 ~ -5.3~ 5.3 595~7.5 ~ 695372_1 11070.0 90.0 112.0 86~.7 ~ 3~7.6~ -2099.2 3280.7 ~ 0.0~ ~.3~ 5.3, 595~6.5 ~ ~0.1 ~00.0 90.0 ~0.4 8~.7/ 3917.3~ -2110.1] ~.7 0.0~ ~.3 5.3~ 5~36.0 ~ ~28.3 f 1130.0 90.0 ~08.8 8684.7 3946~ -2f~. 1 3337.0 0.0 -5.3 5.3~ 5959027.0 695456.8 11160.0 90.0 107.2 86~.73976.31 -2129.4 ~65.5 0.0{ -5.3 5.31 5959018.5 6~485.6 ~90.0 ~0.0 ~0~.~ -2~37.s ~.3 5.31 5~0.~1 11220.0 ~.0 104.0 8684.7 4034.71 -21~.6 ~.3~ 0.0 ~.3 5.3 5~03.5 6955~.7 11250.0 90.0 102.5 ~84.7 4063.5J -2152.4 3~2.5~ 0.01 ~.3 5.3 5~8997.5 6~73.1 11280.0 90.0 100.9 8684.7 4092.2 -2158.5 ~1.81 0.0~ ~.3 5.3 5~8992.0~ ~02~ 11310.0 90.0 99.3 ~.7 4120.5 -2l~.7 ~11.4{ 0.0~ -5.3 5.3 59~987.5{ ~2.~ 11~0.0 90.0 97.7 8~.7 4148.6~ -2168.2 ~41.01 0.0 ~ -5.3 5.3 5958~.01 6~2.0 ~ -2171.8 I I I 11370.0 90.0 96.1 86~.7 4176.4~ ~70.8 ~ 0.0~ -5.3 5.3 5~8~1.0[ 6~91.9 11400.0 90.0 94.5 8684.7 4203.8 -2174.6 3~.71 0.0~ ~.3 5.3 59~979.0 ~5721.8 11430.0 90.0 92.9 8~4.7 42~.9 -2176.5 3~0.6 ~ 0.0~ ~.3~ 5.3~5~977.5 59~978.0~ ~78 ~5751.81.8 11460.0 ~.0 91.4 8684.7 4257.6 -2177.6 36~.6~ 0 0 ~ 3 5.3~ 114~.0 ~.0 89.8 ~.7 42~.0 -21 ~.9 ~.6~ 0~0 -5~3 5.3{ 5~978.0 ~ 69~11.8 90.0 I i 11620.0 88.2 S6~.7 4309.91 -21~.4 3720.6 0.01 -6.3 ~-3l 6~897~-b I 69~ 11 ~0.0 90.0 86.6 37~.6 0.0~ -6.3 b.3 ] 69~1 8~.?i 433~.4 ~ -21~6.0 -b.3 11680.01 90.0 8b.O 8~4.7 ~60.b -2~7~.8 ~780~1 0-01 ~.3 ~.~! 6~8984-~1 ~90~ ~6~0.0, ~0.0 8~.4 8~84.~ ~8~.~ -2~70.8 ~8~0.~ 0.01 ~.si ~88.~ ] ~.~1 ~ ~ 640.01 90.0 s~ .8 8684.7 ~09.21-2~e~.~ ~.~ °'°t~ ~'31 s'3I 11670,0 90,0 80.2 8~4,7 ~32.8~ -21~.2~ ~69,7/ -5,3 I 5~.0 695999.9 TRX START DATE: TRX STOP DATE: Run Date: APR 11, 1997 - 08:17 DRILEX SYSTEMS, INC. FIELD MANAGEMENT INFORMATION P R O D U C T X M T A U D I T L I S T I N G Page: 2 Trans. Tandem Components: Number Misc. Components: Ass Date Dis Date Type Type/Size Bent House Loc Third Serial No 45185 No MT T675TD OS Y RO Y RO ST Y ST UH Y BC Y BB N BN N XX N XX N XX N XX N XX N 031097 000000 C 675 67181-10 ***** RECORD IS POSTED 45187 No MT T675TD OS Y ROY RO ST Y ST UH Y BC Y BB N BN N XX N XX N XX N XX N XX N 033197 000000 C 675 67190-10 ***** RECORD IS POSTED 45195 No MT T675TD OS Y ROY RO ST Y ST UH Y BC Y BB N BN N XX N XX N XX N XX N XX N 033197 000000 C 675 67190-10 ***** RECORD IS POSTED 45198 No MT T675TD OS Y ROY RO ST Y ST UH Y BC Y BB N BN N XX N XX N XX N XX N XX N 033197 000000 C 675 67090-10 ***** RECORD IS POSTED 45201 No MT KM7101 OS KM7101 ROE 7657 ST D 7930 UH KL7212 BC KRX158 BB KYX7758 SU HLX038 SU M3X6894 033197 000000 A 675 2.00 HU HU HU HU HU ***** PRODUCT ALREADY APARTLY ASSEMBLED, CANNOT ASSEMBLE 45205 No MT KM7101 OS KM7101 ROE 7657 SU M3X6894 / THIRD PARTY ALREADY EXIST ST D 7930 UH KL7212 BC KRX158 BB KYX7758 SU HLX038 073196 033197 C NA 2.00 HU ***** RECORD IS POSTED 45206 No MT KM7101 OS KM7101 SU M3X6894 ROE 7657 ST D 7930 073196 UH KL7212 BC KRX158 BB KYX7758 SU HLX038 033197 R NA 2.00 HU ***** PRODUCT NOT IN DATA BASE FILE 45216 No MT 7475TD OS Y ROY XX N XX N XX N 47239-32 ***** RECORD IS POSTED 45236 No MT NS7143 OS NS7143 RO AL7273 RO XX N ST Y ST UH Y BC Y BB N BN N XX N 033197 000000 C 475 HU ST NZ7553 040197 UH PA7033 BC NY051 BB NBB BN FA7139 000000 A 475-5 O0 HU ***** PRODUCT ALREADY APARTLY ASSEMBLED~ CANNOT ASSEMBLE 45237 No MT NS7143 OS NS7143 RO AL7273 / THIRD PARTY ALREADY EXIST ST NZ7553 UH PA7033 BC NY051 012097 030397 R NA BB NBB BN FA7139 HU ***** PRODUCT NOT IN DATA BASE FILE 45251 No MT T475TD OS Y ROY XX N XX N XX N 47113-32 ***** RECORD IS POSTED RO XX N ST Y ST UH Y BC Y XX N 040297 000000 C BB N 475 BN N HU TRANSACTION TYPES: A - Assembly D - Disassebmly COMPONENT CODES: OS - Output Shaft ST - Stator ~__~,- RO - Rotor UH - Universal Housing C T Drilling Wellhead Detail Methanol Injection Otis 7" WLA Quick I Connect ~ I ~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold \ Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over .Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 2" Pump-In 0.458' (5.5") Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus I I13-3/8" Annulus Mu~ 'Tanks 60/401 I TrplxI I-ire Ext. Shop Fuel Boilers Water Pump Roor Ext. Pire Ext. /~Pipe rack r-O') EDOWell Drilling I quipment Trailer Preferred Major Equipment Layout for CT Drilling WELL PERMIT CHECKLISToo. Y INIT CLASS WELL NAME · GEOL ~A . PROGRAM: expo dev~redr~serv[q wellbore segr] ann disp para reqO 0N/O F SHORE 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 drlg 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. . 13. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ................ Y 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg. . Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y REMARKS CMT will cover all known productive horizons ....... 19.18' Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .................... 26. BOPE press rating adequate; test to ~d~ psig 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y// N 33. Seabed condition survey (if off-shore) ........ ./~ N 34. Contact name/phone for weekly progress reports . . . ;/. Y N [exploratory only] GEOL~G.Y: ENGINEERING: CO. SION: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Sep 12 14:19:01 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/09/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 AK-MW-70146 A. WORTHINGT HUPP JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: M CROF LN [D 18-15B 500292175502 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 12-SEP-97 MWD RUN 2 MWD RUN 3 AK-MW-70146 AK-MW-70146 A. WORTHINGT W.C. JACKSON HUPP J. HUPP 19 llN 15E 4466 4642 -48.00 .00 .00 RECEIVED SEP 1 7 1997 Alaska Oil & Gas Cons. Corr~mis.sior~ Anchorage WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8175.0 7.000 9547.0 4.500 10110.0 3.750 11818.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL TRUE VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD). 3. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL WITH NATURAL GAMMA RAY PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 4. DEPTH SHIFTING/CORRECTION IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN DICK OWENS OF ARCO ALASKA, INC. AND ALI TURKER OF SPERRY SUN DRILLING SERVICES ON 8/19/97. 5. MWD RUNS 1-3 REPRESENT WELL 18-15B WITH API#: 50-029-21755-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF llS18'MD, 8702'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAM>iA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10050.0 11790.5 ROP 10110.0 11817.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 10110.0 10321.0 2 10321.0 10923.0 MWD 3 10923.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 11818.0 Name Service Order Units Size Nsam Rep Code Offset Channel DE?T FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10050 11817.5 10933.8 3536 10050 GR 44.12 181.85 70.3474 3482 10050 ROP 12.24 1104.08 89.9349 3416 10110 Last Reading 11817.5 11790.5 11817.5 First Reading For Entire File .......... 10050 Last Reading For Entire File ........... 11817.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 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 ....... 97/09/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUM~RY VENDOR TOOL CODE START DEPTH GR 10050.0 ROP 10110.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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: STOP DEPTH 10293.0 10320.0 18-MAY-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 10321.0 10110.0 10321.0 83.6 97.1 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER NGP SPC 243 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 3.750 3.8 REMARKS: $ Data Format Specification Record FLO PRO 8.80 .0 8.9 6.2 .000 .000 .000 .000 58.6 .3 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down OpTical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR M%~D 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEFT 10050 10320 10185 541 10050 GR 44.22 170.22 104.381 487 10050 ROP 15.27 926.72 69.479 421 10110 Last Reading 10320 10293 10320 First Reading For Entire File .......... 10050 Last Reading For Entire File ........... 10320 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 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 ....... 97/09/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10293.5 ROP 10320.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined STOP DEPTH 10896.0 10923.0 19-MAY-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 10923.0 10321.0 10923.0 85.8 93.6 TOOL NUMBER NGP SPC 288 3.750 3.8 FLO PRO 8.80 .0 8.8 6.3 .000 .000 .000 .000 60.9 .3 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order. Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR M~D 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10293.5 10923 10608.2 1260 10293.5 GR 44.12 96.25 64.7257 1206 10293.5 ROP 12.24 291.56 87.3922 1206 10320.5 Last Reading 10923 10896 10923 First Reading For Entire File .......... 10293.5 Last Reading For Entire File ........... 10923 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUNmtARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10896.5 11790.5 ROP 10923.5 11817.5 $ LOG HEADER DATA DATE LOGGED: 21-MAY-97 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 MINII~JM ~d~GLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 11818.0 10923.0 11818.0 85.2 91.5 TOOL NUMBER NGP SPC 288 3.750 3.8 FLO PRO 8.90 .0 9.2 5.4 .000 .000 .000 .000 63.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 'FT/H 4 1 68 Name Min Max Mean Nsam DEPT 10896.5 11817.5 11357 1843 GR 47.57 181.85 64.8724 1789 ROP 36.86 1104.08 96.4628 1789 First Reading 10896.5 10896.5 10923.5 Last Reading 11817.5 11790.5 11817.5 First Reading For Entire File .......... 10896.5 Last Reading For Entire File ........... 11817.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services .Reel Trailer Service name ............. LISTPE Date ..................... 97/09/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File