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200-096
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done} r"] Two-Sided RESCAN [] Color items: 6a"" Grayscale items: [] Poor Quality Originals: [3 Other: DIGITAL DATA · / Diskettes, No~Q [] Other. No/Type TOTAL PAGES.'~¢ NOTES: ORGANIZED BY: BEVERLY BREN(~SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Isl ~ Project Proofing PROOFED BY: BEVERLY BREN~SHERYL MARIA LOWELL [] Staff Proof By: Date: Scanned (done) PAGES: 5 ¢ SCANNED BY: (at the time of scanning) BEVERLY I~ VINCENT SHERYL MARIA LOWELL RESCANNEDBY: BEVERLY~I VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: Quality Checked (done) RevlNOTScanned.wpd • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑Oil ❑Gas ❑SPLUG ❑Other.181 Abandoned ❑Suspended 1 b. Well Class 20AAC 25.105 20AAC 25.110 ❑Exploratory ❑Stratigraphic ❑GINJ ❑WINJ ❑WAG ❑WDSPL ❑Other No.of Completions Zero ®Development ❑Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: / 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 2/12/2013 �/ 200-096 • 312-479 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 7/11/2000 50-029-20822-01-00 • 4a. Location of Well(Governmental Section): 7.Date T.D. Reached: 14. Well Name and Number: Surface: 7/15/2000 PBU 06-24A - 819' FSL, 1035'FEL, Sec.02,T1ON, R14E, UM • 8. KB(ft above MSL): 71, - 15.Field/Pool(s) Top of Productive Horizon: 2903'FSL, 3111' FEL, Sec. 02,T10, R14E, UM GL(ft above MSL): 37.12' . Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) Oil Pool 3039' FSL,3293' FEL, Sec.02,T1ON, R14E, UM 9478' 8797' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 685942 • y- 5941416 • Zone- ASP4 - 9970' 9176' • ADL 028311 • TPI: x- 683811 y- 5943451 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 683625 y- 5943583 Zone- ASP4 None 18. Directional Survey: 0 Yes 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, RES, DEN, NEU 8137' 7678' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 79' Surface_ 79' _ 30" 1930#Poleset 13-3/8" 72# L-80 Surface 2496' Surface 2496' 17-1/2" 2200 sx Fondu,400 sx Permafrost'C' 9-5/8" 47# L-80 Surface 8137' Surface 7678' 12-1/43 500 sx Class'G', 300 sx PF'C' 7" 26# L-80 7965' 9172' 7514' 8549' 8-1/2" 237 sx Class'G' 4-1/2" 12.6# L-80 9017' 9970' 8418' 9176' 6-1/8" 135 sx Class'G' 24. Open to production or injection? ❑Yes ®No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND) (MD+TVD of Top&Bottom;Perforation Size and Number): 4-1/2", 12.6#, 13Cr80/L-80 9019' 8850'/8280' 8964'/8374' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. RECEIVED WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No • CDEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED MAR 'p 25', .: 9478' Set Whipstock A0300 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 4 28. CORE DATA Conventional Core(s)Acquired? ❑Yes _l No Sidewall Core(s)Acquired? ❑Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize 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 SCANNED AU G 0 2 2.093 RBDMS MAR 0 6 2013 Form 10-407 Revised 10/2012 ONTIN ED ON REVERSE 1/LF bmit Original Only iti 4 /1q / ) 3 � y 6 . 29. GEOLOGIC MARKERS(List all formations a arkers encounter 30. FORMATION TESTS NAME D ND Well Teste.❑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. Sag River 9168' 8546' None Shublik'A' 9203' 8575' Shublik'B' 9232' 8599' Shublik'C' 9235' 8602' Top of Sadlerochit/Zone 4B 9297' 8653' Zone 4A 9431' 8761' Zone3 9533' 8840' Zone 2C 9614' 8903' Zone 2B 9654' 8934' Formation at Total Depth: 31.List of Attachment: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: Bradley.Gorham @bp.com Brad Gorham,564- 49 Title: Drilling Technologist Printed Name: ii :stufka �� Phone 564 4091 Date:3f5/12 Signature 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 ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(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 10/2012 Submit Original Only • • 06-24A, Well History (Pre Rig Sidetrack) Date Summary 01/19/13 (ELINE MILL/WHIPSTOCK). RIH W/WELLTEC MILLING TOOL. MILL OD=3.804". FIRST ATTEMPT TO MILL XN NIP AT 8997'UNSUCCESSFUL, UNABLE TO COMMUNICATE TO MILLER. POOH TO SWAP STROKER&MILLER PORTION OF WELLTEC TOOL. RIH W/BACK UP STROKER&MILLER, MILLED XN NIP AT 8997'. MILL OD AFTER POOH=3.803". RIG UP BKR 45 KB PKR WHIPSTOCK. LRS LOAD WELL W/225 BBL KCL&38 BBL DIESEL. RIH W/BAKER WHIPSTOCK.T/I/O= 245/868/11 Temp=SI Assist E-line(Pre-CTD)Pumped down Tbg. 5 bbls of meth,followed by 230 bbls of 120*f 1%KCL for load then 2 bbls of meth spacer followed by 38 bbls of 70*f diesel to FP Tbg. E-line to RIH to set Whipstock. 01/20/13 T/I/O=200/1032/351 Assist E-line MITT to 2000 psi***PASSED***(Obj: Pre CTD)SB for SEL to RIH and set Whipstock. Pumped 5.8 bbls of-20*f diesel to reach test pressure.Tbg lost 19 psi @ 15 min and 2 psi @ 30 min for a total of 21 psi in a 30 min test. Bled Tbg down to 500 psi,SEL in control of WH at time of LRS departure. FWHP=500/911/20 Notified DSO at departure. WHIPSTOCK SET W/TOP OF WHIPSTOCK AT 9475'. CCL TO TOP OF WHIPSTOCK= 17.83'. C =9457.17'. ORIENTED 59DEG ROHS.2 RA TAGS INSTALLED 9'FROM TOWS. LRS MITT WHIPSTOCK/PACKER TO 2000PSI PASSED. FINAL T/I/O=500/820/10.WELL SHUT IN ON DEPARTURE. 01/29/13 T/I/O=SSV/850/10.Temp=SI.WHPs(CTD Prep). No AL.SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP.0930. 02/02/13 T/I/O=20/850/17.Temp=SI. Bleed IAP and OAP to 0 psi.(Pre CTD). No AL. IA FL near surface. OA FL near surface. Bled IAP from 850 psi to 0 psi in 35 minutes,(All Gas). Bled OAP from 17 psi to 0 psi in 30 minutes,(All Gas). During OA bleed IAP increased 5 psi. Held open bleed on IAP for one hour,(All Gas). During 30 minute monitor IAP and OAP unchanged.Job Complete. Final WHPs=20/0/0.SV,WV,SSV =C. MV=O. IA,OA=OTG. NOVP. 1200 hrs. 02/03/13 T/I/O= 10/0/0 Conducted PJSM w/crew; Replaced spring and all soft goods on Old Style Axelson SSV barrel(won't dump w/out pressure on tree); P.T. SSV to 300 psi/5000 psi(passed), still wont fully dump w/out pressure on tree; Pre Nordic 1. 02/05/13 T/I/O=0/0/0. Conducted PJSM. Barriers= MV, SSV.Verrified by performing independant LTI (Passed). Rigged up lubricator to tree cap with 1-2'extension&5" FMC ISA BPV w/setting tool. PT'd lubricator 200- 300 psi low&3500 psi high for 5 minutes each(Passed).Set BPV#537 @ 90"(set good), bleed TBG off BPV through lubricator. Close barriers, rig down lubricator. Barrier=CMT plug&BPV. N/D 5 1/8"x 7 1/16"FMC Mod.75 tree. N/U new 5 1/8"x 7 1/16"FMC Mod 120(shorty).Torqued MV x TBH Adapter to API spec(739 ft-lb,coated). 02/07/13 T/I/O=BPV/0/0 Conduct PJSM Barriers=SSV and BPV Performed LTT independently Both(Pass). RU CIW Lubricator w/ISA pulling tool. PT'd Lubricator aginst SSV low 250 PSI and High 3500 PSI for 5 min both(Pass). Pull BPV#537 @ 114"Close Barriers MV and SSV rig down lubricator. Installed tree cap and Pt'd to 500 psi. 02/08/13 T/I/O=0/0/0 Conduct PJSM w/crew;SAtrart Barrier list; Barriers=SSV&MV; Installed lubricator&P.T. (charted)w/each break to 300 psi/3500 psi; set 5"FMC ISA TTP#526 @ 90"w/1-2'ext.; P.T.tree (Charted Shell)to 300 psi/5000 psi(passed); Pulled TTP @ 90"; Post TRP-Pre Nordic 2 . Page 1 of 1 • • • serau Common Well Name:06-24 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/10/2013 End Date: X3-01300:(3,525,534.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:10/22/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active datum:Kelly Bushing/Rotary Table @74.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/11/2013 09:30 - 14:00 4.50 MOB P PRE BEGIN RON EVENT AT 0930 ON 02/11/13. RELEASE RIG FROM 06-22B AT 0930. PJSM THEN JACK UP RIG,MOVE OFF WELL 06-22B. SPOT RIG DOWN THE PAD. CLEAN UP MATS AROUND 06-22,MOVE THEM TO 06-24 AND SPOT MATS. 14:00 - 16:00 2.00 MOB P PRE MOVE RIG OVER WELL 06-24 AND SET DOWN. ACCEPT RIG AT 14:00. S ART RIGGING UP. 16:00 - 20:00 4.00 BOPSUR P PRE LEAK TIGHT TEST ON SWAB IS GOOD,TO REMOVE TREE CAP. REMOVE TREE CAP,INSTALL BOPS. 20:00 - 21:30 1.50 BOPSUR P PRE PJSM GREASE VALVES,FILL STACK SHELL TEST BOPE 21:30 - 00:00 2.50 BOPSUR P. PRE START BOPE TFSY TEST WITNESS WAIVED BY AOGCC. 2/12/2013 00:00 - 03:00 3.00 BOPSUR P PRE CONTINUE TESTING BOPE TO 250/3500 PSI FOR 5 CHARTED MIN TEST CHOKE VALVES,CHOKE AND KILL HCR, INSIDE MANUAL VALVES ON CHOKE AND KILL -LINE,BOP RAMS AND ANNULAR PREVENTER. TEST 2 TIW VALVES FUNCTION BOPE FROM BOTH REMOTE PANELS TESTIS WITNESSED BY TOOLPUSHER AND WSL. -SEE ATTACHED CHARTS AND TEST REPORT 03:00 - 03:30 0.50 BOPSUR P PRE RIG EVAC/H2S DRILL WITH CREW FOLLOWED BYAAR 03:30 - 04:30 1.00 BOPSUR P PRE FILL PITS,FILL COIL. 04:30 - 06:00 1.50 BOPSUR P PRE INNER REEL VALVE/PACK-OFF TEST TO 250/3500 FOR 5 CHARTED MIN 06:00 - 08:30 2.50 BOPSUR P PRE PREP TO PUMP SLACK BACKWARDS AND CUT CT. PUMP CABLE SLACK BACK INTO REELAND CUT 270 FT OF CT. INSTALL CT CONNECTOR AND PULL TEST, PRESSURE TEST. INSTALL SWIZZLE STICK TO CATCH CABLE. PUMP SLACK FORWARD UNTIL IT IS SEEN AT END OF CT. 08:30 - 08:45 0.25 BOPSUR P PRE RIG EVAC DRILL AND AAR. 08:45 - 10:30 1.75 STWHIP P WEXIT INSTALL BHI CABLE HEAD. 10:30 - 11:00 0.50 STWHIP P WEXIT PRESSURE TEST NIGHT CAP THEN OPEN WELL UP TO MONITOR. MONITOR FOR 30 MIN,STATIC. PJSM FOR M/U BHA#1. 11:00 - 11:30 0.50 STWHIP P WEXIT GET ON WELL,CLOSE SWAB. PUMP 1 REEL VOLUME FORWARDAT3 BPM. 11:30 - 12:20 0.83 STWHIP P WEXIT MU WINDOW MILLING BHA WITH 2 JOINTS OF 2-3/8"PH6. 12:20 - 14:10 1.83 STWHIP P WEXIT TEST QTS TO 250/3500 PSI.GOOD. RIH WITH MILLING BHA Printed 2/25/2013 11:10:08AM • • l0rth Am nca-YALA Operation Summary Rep., t Common Well Name:06-24 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/10/2013 End Date: X3-01300:(3,525,534 00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:10/22/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWWI: Active datum:Kelly Bushing/Rotary Table @74.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 14:10 - 15:10 1.00 STWHIP P WEXIT TIE-IN AT 9270'WITH(-24)'CORRECTION, FLOW CHECK,NO FLOW GET SPRS AT 9450' PUMP 1:0.5 BPM=820 PSI,1.0 BPM=1018 PSI,2.5 BPM=1996 PSI PUMP 2:0.5 BPM=850 PSI,1.0 BPM=1033 -PSI,2.5 BPM=2010 PSI 15:10 - 16:20 1.17 STWHIP P WEXIT TAGWHIPSTOCKAT9478' ,'.F8 AT 2140 PSI AT 2.64 BPM. PVT.353 BBLS ERRATIC RETURNS,PULL UP AND CIRC BOTTOMS UP. SMALLAMOUT OF GAS IN RETURNS,CIRC THROUGH THE MGS. AFTER BOTTOMS UP,FLOW CHECK,NO FLOW 16:20 - 00:00 7.67 STWHIP P WEXIT 1620 TAG WHIPSTOCK AT AND MILL WINDOW 06/-2 FROM 9477.5'WITH 2K#DHWOB. TIME MILL AT 1 FPH PUMPING 2.65 BPM IN/OUTAT 2180-2230 PSI,1.2-1.5K#DHWOB, 9.47"ECD WITH 8.5 PPG POWER PRO _ PVT355 BBLS,IA 300 PSI,OA 370 PSI _KICK WHILE DRILLING DRILL W/AAR MILL TO 9484.4'AT 1 FPH. 2/13/2013 00:00 - 02:10 2.17 ,STWHIP` P WEXIT TIME MILL WINDOW FROM 9484.4'TO 9486.5' AT 1 FPH. 2.64 BPM IN/OUT,2300 PSI,1.8K#DHWOB 02:10 - 02:50 0.67 STWHIP P WEXIT TIME MILL 1 FT OF FORMATION TO 9487.5'. 2.64 BPM IN/OUT,2300 PSI,1.8K#DHWOB 02:50 - 06:00 3.17 STWHIP P WEXIT DRILL FORMATION AT 2-5 FPH 2.62 BPM IN/OUT,2330 PSI,2K#DHWOB CONFIRM SOME FORMATION CUTTINGS IN SAMPLE. DRILL TO 9498'FOR 10'OF RATHOLE BELOW WINDOyy.,- 06:00 - 07:45 1.75 STWHIP P WEXIT REAM WINDOW WITH THREE UP AND DOWN PASSES. DRY DRIFT. WINDOW SMOOTH. 07:45 - 10:00 2.25 STWHIP P WEXIT OPEN EDC. CIRCULATE OUT OF HOLE. HOLD PJSM NEAR SURFACE. 10:00 - 11:30 1.50 STWHIP P WEXIT TAG UP. FLOW CHECK. GET OFF WELL. UNSTAB COIL. PULL AND LD MILLING BHA. MILL GAUGES. 3.8"GO,3.79"NO GO FOR STRING REAMER AND WINDOW MILL. CLEAN HIGH PRESSURE FILTERS IN REEL HOUSE. 11:30 - 13:00 1.50 DRILL P PROD1 MU BUILD DRILLING BHA. 2.0 DEGAKO WITH HYCALOG RE-BUILD SR42311M-C3 4.25"BIT (WITH NOSE BUTTONS). STAB COIL. TEST TOOLS. GET ON WELL. PRESS TEST QTS. PASSED. 13:00 - 14:00 1.00 DRILL P PROD1 RUN IN HOLE. RECORD SPRS ABOVE WINDOW. 14:00 - 14:15 0.25 DRILL P PROD1 LOG GR TIE IN. SUBTRACT 25'. Printed 2/25/2013 3:49:10PM • orth America-A eration Summa Common Well Name:06-24 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/10/2013 End Date: X3-01300:(3,525,534.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:10/22/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active datum:Kelly Bushing/Rotary Table©74.0ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:15 - 17:30 3.25 DRILL P PROD1 DRILL AHEAD FROM 9498'. 2100 PSI FS AT 2.71 BPM IN/OUT. 100-200 PSI MTR WORK. DHWOB:1.0-1.5K# MW IN/OUT:8.56/8.61 PPG. BHP/ECD/TVD:4291 PSI/9.47 PPG/8740' IA/OA/PVT:387 PSI/89 PSI/364 BBLS. DRILL AHEAD TO 9580'. 17:30 - 20:00 2.50 DRILL P PROD1 _DRILL FROM 9580' , 2300.PSI W/200 PSI MOTOR WORK AT 1.3K# DHWOB 2.67 BPM IN/OUT OF 8.56 PPG MUD W/9.5 PPG EtD 20:00 - 21:45 1.75 DRILL P PROD1 ROP INCREASE TO 80-100 FPH FROM 9675'. 2.68 BPM IN/OUT c 2730 PSI,630 PSI MW DRILL TO 9750'; 21:45 - 00:00 2.25 DRILL P PROD1 WIPER TRIP TO TIE-IN LOG FROM 9150',LOG WHIPSTOCK. RA TAG AT 9487',WINDOW CONFIRMED FROM 947$'TO 9487 2/14/2013 00:00 - 02:00 2.00 DRILL P PROD1 DRILL FROM 9750' 2.67 BPM IN/OUT AT 2400 PSI ROP 80 FPM,1.6K#DHWOB PYT=511 BBLS,IAP 665 PSI,OAP 400 PSI. 02:00 - 02:15 0.25 - DRILL- P PROD1 --BHA WIPER AT 9900' 02:15 - 06:00 3.75 DRILL C N RREP 9,921.0 PR0t1 DRILL TO 9920'.PROBLEM WITH MUD PUMP #2.PULL UP TO ABOVE WINDOW AND CIRCULATE WITH PUMP#1. INVESTIGATION UNDERWAY.TRACTION# 4353320 06:00 - 06:30 0.50 DRILL N RREP 9,921.0 PROD1 CREW CHANGE. DISCUSS OPERATIONS AND EQUIPMENT STATUS. MAKE RIG CHECKS AND ROUNDS. CONTINUE TO CIRCULATE IN CASING. INVESTIGATE TRACTION MOTOR PROBLEM ON PUMP#2. 06:30 - 10:00 3.50 DRILL N RREP 9,921.0 PROD1 DISASSEMBLE TACTION MOTOR ON PUMP#2. SOURCE REPLACEMENT PARTS FOR REPAIRS. HAVE REPLACEMENT TRACTION MOTOR TRANSPORTED TO RIG WELDING SHOP. CONTINUE TO CIRCULATE INSIDE CASING. 10:00 - 14:00 4.00 DRILL N RREP 9,921.0 PROD1 HOLD PJSM WITH RIG TEAM. DISCUSS PROCEDURE FOR REMOVAL OF TRACTION MOTOR. DISCUSS ECD,SSV ISSUES. ALSO DISCUSS USE OF LOADER TO HANDLE MOTOR AND PUMP ROOM WALL PANEL. REMOVE WALL PANEL. LIFT TRACTION MOTOR AND PLACE IN WELDING SHOP. CALL FOR SLB PUMP UNIT. 14:00 - 15:15 1.25 DRILL N RREP 9,921.0 PROD1 WAIT ON SERVICE HAND FROM ANCHORAGE. WIT ON SLB PUMP UNIT. 15:15 - 16:30 1.25 DRILL N RREP 9,921.0 PROD1 SPOT AND RIG UP SLB PUMP UNIT. HOLD PJSM TO DISCUSS PUMPING CONTINGENCY. RU SLB PUMP UNIT. SUPPLY FROM RIG PITS. HARDLINE TO RIG CEMENT LINE. Printed 2/25/2013 11:10:08AM TREE= 5-1/8"FMC120 06-24A S NOTES:m 4-1/2"CHROME TBG*** WELLHEAD= FMC ACTUATOR= BAKER C INITIAL KB.RE 71' I - k J I I 26' H5-112"X 4-112"XO,D=3.958" BF.ELEV= KOP= 299T Max Angle= 41°@ 977T ' I 21$4' H4-1/2"HES X NP,ID=3.813" Datum ND= 9375' Datum ND= 8800'SS GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" H 2496' I ST WD TVD DEV TYPE VLV LATCH FORT DATE 4 3447 3425 22 WAG DMY RK 0 09/09/12 3 6104 5821 27 WAG DMY RK 0 09/09/12 9-5/8"X 7'BKR ZXP LNR TOP PKR, H 7965' I 1-1 I 2 7766 7328 21 MMG DMY RK 0 03/14/06 w/FLEX LOCK HMC HGR,D=6.313" L 1 8762 8279 14 KGB-2 DMY BK 0 03/14/06 9-5/8"CSG,47#,L-80 BT&C,D=8.681" —I '"8137 I MLLOUT WINDOW (06-24A) 8137-8155' Minimum ID =3.725" @ 8997' WINDOW 4-1/2" HES XN NIPPLE 8829' —141/2"HES X NP,D=3.813" Z X 8850' I--17"X 4-1/2"BKR S3 FKR,D=3.870" I ' , 8872' H4-1/2"HES X NP,D=3.813" I 4-1/2"TBG,12.6#,13CR80 VAM TOP, 8931' � .0152 bpf,D=3.958" I $940' H 7"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TBG STUB(03/03/06) H 8932' z I 8964' H 7"X 4-1/2"BKR S-3 PKR,D=3.875" z 8997' I--I4-1/2"HES XN NP,MLLED TO 3.80"(01/20/13) TOP OF 4-1/2"LNR H 9017' ( 9017' 1-17"X"_"BKR ZXP LNR PKR,D=5.250" I 4-1/2"TBG,12.6#,L-80 NSCT.0152 bpf,ID=3.958" 9019' 9019' I-i4-1/2'WILEG,D=3.958" I 9020' H ELMD TT LOGGED ON 09/14/00 9031' H 7"X5"FMC LNR HGR,D=4.375" I 7"LNR,26#,L-80 BTC-M,.0371 bpf,ID=6.184" —I 9172' IJ ■ � � (�5"X4 112"XO,D=3.937" 4-1/2"BKR WS(01/20/13) H 9478' I\ PERFORATION SUMMARY REF LOG:JEVVELRY LOG ON 07/25/00 ANGLE AT TOP PERT 41°@ 9740' Note:Refer to Rod uction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 2-7/8" 6 9740-9746 C 02/06/04 Q 2-7/8" 6 9760-9788 C 02/18/11 I 2-7/8" 4 9762-9770 C 09/21/01 2-1/8" 4 9778-9788 C 08/08/00 I 2-7/8" 4 9778-9788 C 09/21/01 2-1/8" 4 9832-9850 C 08/08/00 I 9878' —I FASDRLL-MLLED&PUSHED TO BTM(03/25/06) PBTD —I 9883' rr a 4-1/2"LNR 12.6#,L-80,.0152 bpf,D=3.953" H 997(r feetea DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UFIT 11/05/82)ROWAN 3:INT1AL COM PLETION 12/13/12 JMD 4-1/2"LNR DEPTH CORRECTIONS WELL 06-24A 07/18/00 NIES SIDETRACK(06-24A) 01/29/13 SET/PJC MLL/OW SET VVS(01/20/13) PERMIT No:"2000960 03/16/06 NORDIC2 RWO 02/11/13 TRP/JMD TREE C/O(02/08/13) API No: 50-029-20822-01 04/05/07 DAV/PAG XO CORRECTION 02/14/13 JIM WBS CORRECTIONS SEC 2,T1 ON,R14E,818'FSL&1034'Fa 02/28/11 SRD/PJC RE PERF(02/18/11) 02/25/13 PJC DRAWING CONVERSION 09/08/12 MBM PJC GLV C/O(09/06/12) BP Exploration(Alaska) • • P8' OF 4i 4. s THE STATE Alaska Oil and Gas OfA LAsKA Conservation Commission Witt ���T GOVERNOR SEAN PARNELL 333 West Seventh Avenue O p. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 John McMullen ,6 Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06 -24A Sundry Number: 312 -479 JAN 1 g ZII13 SCANNED Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, D . lel T. Seamount, Jr. Commissioner DATED this 2v day of December, 2012. Encl. • OIL AND G STATE OF ALASKA AS CONSERVATION COM ION i &RCEVED ALAS APPLICATION FOR SUNDRY APPROVAL DEC 13 2012 20 AAC 25.280 ‘L /+� 1. Type of Request: A" A � ®G C ❑ Abandon e Plug for Redrill - ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 200 -096 • 3. Address: ® Development • ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50. 029 - 20822 -01 -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 06 -24A. Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 028311 ' 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) 9970' • 9176' 9883' • 9110' 9878' None Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2496' 13 -3/8" 2496' 2496' 4930 2670 Intermediate 8137' 9 -5/8" 8137' 7678' 6870 4760 Production Liner 1207' 7" 7965' - 9172' 7514' - 8549' 7240 5410 Liner 953' 4 -1/2" 9017' - 9970' 8418' - 9176' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9740' - 9850' ' 9001' - 9084' 4 -1/2 ", 12.6# 13Cr80 / L -80 9019' Packers and SSSV Type: 7" x 4 -1/2" Baker 'S -3' packer; Packers and SSSV • 8850' / 8280' 7" x 4 -1/2" Baker 'S -3' packer MD (ft) and TVD (ft):. 8964' / 8374' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ►'_ Development , ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation January 1, 2013 • ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commiss Representative: ❑ WAG ❑ SPLUG ® Suspended 4 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Troy Jakabosky, 564 -4868 Printed Name: John McMullen Title: Engineering Team Leader Email: Troy.Jakabosky @bp.com PO (1 i — b 1-( AJ NkGM,v t t Qr- Signature: ., ( r N ATI (2, Phone: 564 -4711 Date: 12- (' - ( Z Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 512 --( aq ❑ Plug Integrity b BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: 8 OP -F.cS 7' to 35 U D p s L Fi � : t :, DEC 212 it _( L Spacing Exception Required? ❑ Yes u No Subsequent Form Required: /10 O Approved By: / APPROVED BY THE COMMISSION Date �2 ��p _ Form 10 -40 - • COMMISSIONER • 0�2 . Approved application is valid for 12 months from the date of approval u it In Duplicate O V -( i !� 9 17,--- ��j�� ��� 1 • • To: Alaska Oil & Gas Conservation Commission From: Troy Jakabosky by Y Y CTD Engineer Date: December 12, 2012 Re: 06 -24A Sundry Approval Sundry approval is requested for well 06 -24A. 06 -24A was completed as a rotary ST in July -2000 in zones 2A and 2B1. In 2001 perfs were added in Z2Bu. Production went up, and started to decline untill in 2003 additional Z2Bu perfs were added. The well declined till 2005 when it was SI for TxIA communication. the well was worked -over in early 2006, and the tubing was replaced with chrome tubing. The well declined steadily from 2006 to present. The well is currently SI due to the DS -06 LP flowline being out of service. REASON FOR SIDETRACK Well has low oil rates and there are no further wellwork options. The proposed CTD sidetrack will access a 45 acre block in the 2B1 sands in the central part of DS -06. The proposed plan for 06 -24B is to drill a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around February 5, 2013. The existing perforations will be isolated by setting a retrievable packer whipstock, as well as the primary cement job. The sidetrack, 06 -24A, will exit the existing 4.5" liner and kick off in Zone 4 and land in Zone 2. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. f r0 void ctbO j I5 Ail �,� kf e �oir 4 1rPGr br, Car, t v t th well l ?4f leer °r f I eCrei 6o wad we � r c✓r Ta„ we ll ,S nu r s c0/ye prod-cYr 6'hei fl'f relp.e c,oldfi ' Ckj The Ct(ll i s taw Ghd 5 lni,(6/ " r fne��t l ' i /241712, Pre -Rig Work: tl ni i 1 Y$ P °(' ` 0"1 ® (scheduled to begin Jan 1st,' 2013) 1. 0 MIT IA (passed 3000 PSI) 9 \6\2012 2. 0 MIT OA(passed 2000 PSI) 9 \6\2012 3. W AC - LDS, AC PPPOT - T(passed 5000 psi) 9 \13 \12 4. V PT MV, SV, WV. 5. S Whipstock drift to 9525. 6. E Mill XN to 3.80 at 8997' 7. F Load and Kill. 8. E Set retrievable 4 -1/2 KB Packer Whipstock at 9475, 51° ROHS. 9. F Test packer to 2400 psi. 10. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange. 11. 0 Remove wellhouse, level pad. Pei/4 312 Rig Work: (scheduled to begin February 5 2013) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. No h T/ 4 2 hr3 in act mice. 2. Mill 3.80" window at 9,475' and 10' of rathole in Z4. Swami the well to PowerVis. 3. Drill Build: 4.25" OH, 674' (22 deg /100 planned) with resistivity. 4. Drill Lateral: 4.25" OH, 2351' (12 deg /100 planned) with resistivity. P TD 5. Run Triple Combo Open Hole Logs 12- 19 D 6. Run 3 -1/4" x 2 -7/8" L -80 liner leaving TOL at 9,405' MD. 7. Pump primary cement leaving TOC at 9,405' MD, 34 bbls of 15.8 ppg liner cement planned. • 8. Perform liner cleanout with mill, motor and MCNL /GR /CCL log. 9. Test liner lap to 2,400 psi. 10. Perforate liner per asset instructions (- 200'). 11. Freeze protect well to 2500' TVD 12. Set BPV, RDMO. Post - Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set generic GLV's with SL. 3. Set liner top packer if needed with slickline & test to 2,400psi. Troy Jakabosky Y CTD Engineer 564 -4868 CC: Well File Sondra Stewman/Joe Lastufka VIII TREE= 5-1/8" FMC GEN/ 3 III I SAFEllpTES:*** 4-112" CHROME MG*** WELLHEAD= FRAC ACTUATOR --,. ' AXELSON 06-24A KB. ELEV 71 SE ELEV ,,-, KOP. 2997' '''..."---. 26' H5-1/2" X 4-1/2" X0, ND = 3.95T I I'vtax Angle = 41" @ 9777' IDa MD = 573 ''' I I Datum TVD 8800' SS 2184' -14-1/2" I-ES X NP,10 = 3,813" = 13-3/8" CSG, 72#, L-80, U 12.347" H 2496' — ■ GAS LFF MAICRBLS ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 3447 3425 22 1'M3 0M' RK 0 09/09/12 3 6104 5821 27 11/IM3 (".'MY RK 0 09/09/12 2 7766 7328 21 favIG DMY RK 0 03/14/06 1 8762 8207 35 KGB-2 CMY BK 0 03/14106 TOP OF 7" CSG H 7965' I---7, 7 MLLOUT WINDOW (06-24A) 813T - 8155' 8829' H4-1/2' HES X NIP, 113 = 3.813" I Minimum ID = 3.725" @ 8997' 8850' Hr X 4-1/2" BKR S3 PKR, D = 3.870" 4-112" HES XN NIPPLE 8872* - 4-1 /2' HES X NIP, D = 3.813' - -_--__ k 8930' --I TEG STUB (03/03/06) - 7: - - --1 "--• ii 8940" -1r X 4-1/2' UNIQUE OVERSHOT - -- .1 -=.----•-•!:_i_„;114, 8964' -17" X 4-1/2" BKR S-3 FKR, D= 3.875" EZBP H 8160' 1--- ''' - ''m - 41, qn/I No- 8997" H4-1/2" I-ES XN NIP, N)= 3.725' I 9018" -14-1/2" MEG, D = 3.958' '‘ 14 9020' HE3..MDTI" LOGGED 9-5/8" CSG, 47#, L-80, ID= 8.681" --I 9032' I--4 IL 09/14/00 • 9017' - 7' X 4-1/2" BKRZXP LNR FKR, LI= 5250" 4-1/2" TBG, 12.6, 13CR80 VAM TOP, .0152 bpf, D = 3.958" H 8931' Ilt b, . 4-112' TBG, 12.6#, L-80 NSCT .0152 bpf, ID = 3958" -j 9019' 1 I TOP OF 4-1/2 LNR H 9017' • 7"1_143, 29#, L-80, .0371 bpf, D 6.184' --1 9172' • FERFORATION SUIVIVARY • REF LOG: JEWELRY LOG ON 07125/00 • ANGLE AT TOP PERE: 41* © 9740' •iii, Note: Refer to Rod uction DB for historical perf data *%`‘ 4014 SIZE SFF INTERVAL Opn/Sqz DATE I NILLED FASDRILL & RJSHEI) TO BIM ( 3/25/06) 1-- 9878' Al 2-7/8" 6 I 9740 - 9746 0 02/06/04 ' "ifitAtialtil. 2-7/8" 6 9760 - 9788 0 02/18/11 •■• /Tap -1 9883' 2-718" 4 9762 - 9770 0 09121/01 2-1/8" 4 9778 - 9788 0 08/08/00 2-7/8" 4 9778 - 9788 0 09/21/01 4-1/2' Ltsn, 12 6#, L-80, 0152 bpf, ID= 3.953" -I 9970' 2-1/8" 4 9832 - 9850 • 0 08/08100 DATE REV BY COMMENTS DATE REV BY COMI'vENTS PRUDHOE BAY UNIT 11/05/82 ORIGINAL COMPLETION 04/05/07 DAV/PAG X0 CORRECTION WELL 06-24A 07/18/00 SIDETRACK (06-24A) 04/07/07 DAVIPAG SAFETY NOTE CORRECTION PERMT No. '2000960 03/16/06 NORDIC2 RWO 02/28/11 SREVRIC RE-FERF (02/18/11) AR No: 50-029-20822-01 03119/06 KEY/TLH DRLG DRAFT CORRECTIONS 09/08/12 M3 PJC GLV C/0 (09/06112) SEC 2, T1ON, R14E, 271636 FE_ & 2566.36' FTC 03/25/06 CJA/PJC II/ILL FASDRILL & PUSH BIM 12/13/12 JIVE) 4-1/2' LNR DEPTH CORRECTIONS 03/27/06 JRRPJC CIO 1 BP Exploration (Alaska) I F EE = FMC GEN 3 • V V B_LHEAO = FMC SAFEOOTES: * ** 4-1/2" CHROME TBG*** ACTUATOR= AXELSON 06-24B KB. ELEV = 71' PmposedC S iletrack BF. EL B/ _ \ KOP= 2997' 4-sits-- Max Angle = 41 @ 9777' 26' I {5 -1/2" X 4 - 1/2" XO, D = 3.958" Datum MD = 9573 Sa A TV D= - _v - 6 - 86 - 0 7 § - § -- 800' SS I I I 2184' H4-1/2" HES X NIP, ID= 3.813" 13 -3/8" CSG, 72#, L -80, ID =12.347" H 2496' ■ GAS LET MANDRELS ST MD TVD DEV TYPE V LV LATCH PORT DATE 4 3447 3425 22 MMG DOME RK 16 03/27/06 I 3 6104 5821 27 MMG SO RK 20 03/27/06 2 7766 7328 21 MMG DMY RK 0 03/14/06 1 8762 8207 35 KGB -2 DMY BK 0 03/14/06 TOP OF 7" CSG — I 7965' MILLOUT VMNDOW (06 -24A) 8137' - 8155' 8829' H4-1/2" HES X NIP, ID = 3.813" Minimum ID = 3.725" @ 8997' 4-1/2" HES X N NIPPLE 8850' H7" X 4-1/2" BKR S3 PKR, ID = 3.870" 8872' H4 -1/2" HES X NF, ID = 3.813" 8930' T STUB (03/03/06)1 � ; 8940' Hr X 4-1/2" UNIQUE OVERSHOT] ■ 8964' I — 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" EZBP — 8160' ;i 8997' — 14 -1/2" F-ES XN MP, L) = 3.725" ,� 9018' — 14 - 1/2" WLEG, ID = 3.958" 9020' — ELIVD TT LOGGED ,ir 9 -5/8" CSG, 47 #, L -80, ID= 8.681" —I 9032' 1--A \ 09/14/00 1 9011' — 7" X 4 -112" BKR ZXP LNR PKR, HD= 5.250" 4 -1/2" TBG, 12.6 #, 13CR80 VAM TOP, .0152 bpf, D= 3.958^ H 8931' b 4 -1/2" TBG, 12.6#, L -80 NSCT .0152 bpf, 0 = 3.958" H 9019' I TOP OF4 -1/2" LNR H 9019' !- 1/2 "wh}ostnck @ 9,475' 40° Inc 1 °ROxs PERFORATION Sl>IvfvLARY 7" LNR, 29#, L -80, .0371 bpf, 13= 6.184" — 9172' I REF LOG: JEWELRY LOG ON 07/25/00 PI O ANGLE AT TOPPERE: 41 @ 9740' Top of3 1/2 "herand cement@ - 9,405' 2 7 8 "1nerTD @ 12,500' Note: Refer to Production DB for historal perf data SfZE SPF INTERVAL n/ z DATE ; \, 2 -7/8" 6 9740 - 9746 0 02/06/04 /�t\%�\�% 2 -7/8" 6 9760 - 9788 0 02/18/11 \�; \�; 41: 2 -7/8" 4 9762 - 9770 0 09/21/01 3/4"x 2 7/8 "X0 9 - 10,150' " 1 2 -1/8" 4 9778 - 9788 0 08/08/00 2 -7/8" 4 9778 - 9788 0 09/21 /01 3 3 2 -1/8" 4 9832 - 9850 0 08/08/00 MLLE') FASDRILL & PUSHED TO BTM (3/25/06) — 9878' PBTD - L 9984%' 14 -1/2" LNR, 12.6#, L -80, .0152 bpf, ID = 3.953" — I 9970' I - DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/05/82 ORIGINAL COMPLETION 04/05/07 DAV /PAG XO CORRECTION WELL: 06-24A 07/18/00 SIDETRACK (06 -24A) 04/07/07 DAV /PAG SAFETY NOTE CORRECTION PERMIT No: '2000960 03/16/06 NORDIC2 RWO 02/28/11 SRD/PJC REF (02/18/11) AR Ne: 50- 029 - 20822 -01 03/19 /06 KEY/TLH DRLG DRAFT CORRECTIONS SEC 2, T1ON, R14E 2718.36' FEL & 2566.36' FM_ 03/25 /06 CJA /PJC MLL FASDRILL & PUSH BTM 03/27/06 JRP/PJC GLV (/0 BP Exploration (Alaska) MEW NORDIC - CALISTA RIG 1 CHOKE / REEL/CIRCULATION MANIFOLD DIAGRAM 7 V12 — III. .41 MIS r V14 7- 1116" 5000 psi BOP's ID = 7.06" V15 V11 I7 t/te "5000 psi, Rxle Transducers 0 I Tr i ORB V2 1 V1 V 1 — to... GASS Note. typical BOP arrangement for 23/8" .: wiled tubing drilling ...HMI _ m`o 111 3 I 71118" 5000 psi, RX�B i 3 ' V17 �/ HCR II IC ' 1K OK ihii To Poor Boy Gas Buster —.. V18 V19 I ate. 2vte••600o pal , Rx-24 iligilliIlllplltr 11111 I ■ I 3.00" 5000 vol HCR I • ...N M^ 2-1/18 V CHECK VALVE 1 VA Manual Choke p t I ... _ . ,, ) 1/18 Cameron FOV Gate VaNe z• 00 psi EW IMI i9 lir MEOH /Diesel . • � Iiiiii FP Line . =. 1l4 Tun Halco CoFlex Hose 10WOG To Production Tree or Cross Over .. - re a transducers CoFlex Hose N11 '. 0 0 CV12 To Coiled Tubing I Bleed M • _ Inner Reel Valve • _ - Mk ® _ _ ..._- w - ` rr C V13 Cement In I Ground Level Line T e -in 7. CV10 -I CV3 CV2 T Stand Pipe • —_ _... ''' ___ we thed - _ Manual Choke - -- - Pmssure Transducers ..:..: " -i 1 I CV17 ,1 CV9 _ CI Oil Tiger Tank • • • Mud Pump 2 I I s s -"". From O _ M P Baker M 1 b MP 2 Choke • • CV14 � to Pks - - - -- = Rig Floor Mud Pump a1 4) CV16 Reverse Ci , r Cir CT while OOH NM . W O A .. • - - • - - To Mani CV15 1- Jun -2010 Remoras. •■•••••.N,.n Be. / rr.rnile tutu CoFlex Hose bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 January 6, 2012 RF I Mr. Tom Maunder JAN I q 2012 Alaska Oil and Gas Conservation Commission, 1 333 West 7 Avenue tax C ans • co ss' ,ri Anchorage, Alaska 99501 Anr, ;l ortme Subject: Corrosion Inhibitor Treatment of 06 -24A (PTD # 2000960) Dear Mr. Maunder, Enclosed please find a spreadsheet with details of the corrosion inhibitor treatment in the surface casing by conductor annulus of well 06 -24. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatment took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincer ly, Mehreen Vazir r _ ..p. L } !` BPXA, Well Integrity Coordinator }� �. r L • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -06 Date: 10/31/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal 06-01 1750490 50029201720000 06 -02 1770780 50029202820000 06 -03A 1951520 50029201860100 06 -04A 2001020 50029201790100 06 -05 1780200 50029202980000 06 -068 2050980 50029202010200 06 -07 1780210 50029202990000 06-08A 1951950 50029203000100 06 -09 1790730 50029204000000 06 -10A 1981960 50029204020100 06-11 1791100 50029204280000 06-12A 1920640 50029204560100 06 -13A 2061020 50029204570100 06 -14B 2090120 50029204580200 06-15 1800320 50029204590000 06 -16 1800330 50029204600000 06 -18A 2090630 50029207670100 06 -19A 2081020 50029207910100 06 -20A 2050790 50029207990100 06 -21B 2080990 50029208020200 06-22A 1930570 50029208060100 06 -23C 2080920 50029208080300 STATE OF ALASKA . ALASKA. AND GAS CONSERVATION COMMISSI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ WaiverE Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ .0 200 -0960 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 .- 50- 029 - 20822 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO - 028311 f . PBU 06 -24A 10. Field /Pool(s): ,, PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9970 feet Plugs (measured) 9878 feet true vertical 9176.43 feet Junk (measured) 9878 PLUG feet Effective Depth measured 9984 feet Packer (measured) 7965 8857 8973 9026 true vertical 9187.15 feet (true vertical) 7514 8285 8381 8426 Casing Length Size MD TVD Burst Collapse Structural Conductor 83' 20" 91.5# H-40 37 - 120 37 - 120 1490 470 Surface 2475' 13- 3/8 "72# L -80 36 - 2511 36 - 2511 5380 2670 Production 8110' 9 -5/8" 47# L -80 34 - 8144 34 - 7684 6870 4760 Liner 1207' 7" 29# L -80 7974 - 9181 7523 - 8557 8160 7020 Liner 953' 4 -1/2" 12.6# L -80 9026 - 9979 8426 - 9183 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ - _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 33 - 8947 33 - 8360 4 -1/2 "12.6# L -80 8947 -9028 8360 -8427 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 7965 7514 4 -1/2" Baker S -3 PKR 8857 8285 4 -1/2" Baker S -3 PKR 8973 8381 4 -1/2" Baker ZXP Packer E 26 12. Stimulation or cement squeeze summary: Intervals treated (measured): � � ��1 FEB 2 2 2011 Treatment descriptions including volumes used and final pressure: *dm% &Gas Coos, Commission 13. Representative Daily Average Production or Injection /1=MP Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure - ubing pressun Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El Service ❑ Stratigra❑c Daily Report of Well Operations X 16. Well Status after work: Oil - eg Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG GINJ ❑ SUSP❑ SPLUG ❑ 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: NA Contact Joe Lastufka Printed Nam e Lastufka Title Data Manager Signature )\ r Phone 564 -4091 Date 2/22/2011 Fvnn 10 vi t)10 � - 8ubmil Oiiyinal Only 1 06 -24A 1 200 -096 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06 -24A 8/8/00 PER 9,778. 9,788. 9,029.49 9,037.07 06 -24A 8/8/00 PER 9,832. 9,850. 9,070.57 9,084.35 06 -24A 9/14/01 FIL 9,810. 9,850. 9,053.79 9,084.35 06 -24A 9/21/01 APF 9,762. 9,770. 9,017.35 9,023.42 06 -24A 9/21/01 APF 9,778. 9,788. 9,029.49 9,037.07 06 -24A 10/26/03 APF 9,760. 9,788. 9,015.83 9,037.07 06 -24A 2/6/04 APF 9,740. 9,746. 9,000.56 9,005.15 06 -24A 2/18/11 APF 9,760. 9,788. 9,015.83 9,037.07 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 4. • • 06 -24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2/18/2011 ** *WELL SHUT IN ON ARRIVAL * * *(E -LINE PERFORATING) I INITIAL T /I /O = 1800/310/0 PSI INITIAL VALVE POSITIONS: SWAB: CLOSED, SSV: CLOSED, MASTER: OPEN, GAUGES TO CASING: OPEN !CORRELATED TO SLB PRODUCTION PROFILE W/ DEFT DATED 11 -NOV -2011 PERFORATION INTERVAL: 9760' -9788' PERFORATION DONE WITH 2.875" HSD POWER JET OMEGA 2906 HMX FINAL VALVE POSITIONS: SWAB: CLOSED, SSV: CLOSED, MASTER: OPEN, 'GAUGES TO CASING: OPEN FINAL T /I /O = 1840/310/0 PSI !***JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 1 Meth 2 TOTAL TREE = 5 FMC GEN 3 0 1 SAFETY W: ** *CHROME 4 -1/2" TBG* ** I WELLHEAD TUTR FMC 06-24A AC = AXELSON KB. ELEV = 71' BF ELEV = e KOP 2997' Max Angle = 41 @ 9777' 26' 1-15-1/2" X 4 -1/2" X0, ID = 3.958" Datum MD = 9573' 1 ' 2184 H4-1/2" HES X NIP, ID = 3.813" Datum TV D = 8800' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2496' 1- ' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3447 3425 22 MMG DOME RK 16 03/27/06 L 3 6104 5821 27 MMG SO RK 20 03/27/06 2 7766 7328 21 MMG DMY RK 0 03/14/06 1 8762 8207 35 KGB -2 DMY BK 0 03/14/06 TOP OF 7" CSG H 7965' MILLOUT WINDOW 8137' - 8155' Minimum ID = 3.725" @ 8997' 1 8829' 1-14 -1/2" HES X NIP, ID = 3.813" 4 -112" HES XN NIPPLE 8850' H7" X 4-1/2" BKR S3 PKR, ID = 3.870" I 8872' - -14 -1/2" HES X NIP, ID = 3.813" 1 8930' HTBG STUB (03/03/06) I ∎ 8940' H7" X4 -1/2" UNIQUE OVERSHOT I I EZBP I-1 8160' , 8964' 1-17'' X 4 -1/2" BKR 5-3 PKR, ID = 3.875" 8997 —14-1/2" HES XN NIP, ID = 3.725" 9018' I--I4 -112" WLEG, ID = 3.958" �� 1 9020' I 1 09/14/00 EL MD TT LOGGED 9 -5/8" CSG, 47 #, L -80, ID = 8681" H 9032' (-1--A ■ 1 b., 9019' IT X 4 -1/2" BKR ZXP LNR PKR, ID = 5.250" 4 -1/2" TBG, 12.6 #, 13CR80 VAM TOP, .0152 bpf, ID = 3.958" H 8931' I 1.. 4 -1/2" TBG, 12.6 #, L -80 NSCT .0152 bpf, ID = 3.958" 1-1 9019' TOP OF 4-1/2" LNR, — { 9019' ` PERFORATION SUMMARY - 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I 1-1 9172 REF LOG: JEWELRY LOG ON 07/25/00 ANGLE ATTOPPERF: 41 @ 9740' ` Note: Refer to R DB for historical perf data / . SIZE SPF INTERVAL Opn /Sqz DATE .ti*\4% 2 -7/8" 6 9740 - 9746 0 02/06/04 I MILLED FASDRILL & PUSHED TO BTM (3/25/06) I 9878 �41j� \its '■■14,\IttM 2 -7/8" 6 9760 - 9788 0 10/26/03 '■14101. 2 -7/8" 4 9762 - 9770 0 09/21/01 I PBTD I-I 9984' 2 -1/8" 4 9778 - 9788 0 08/08/00 2 -7/8" 4 9778 - 9788 0 09/21/01 2 -1/8" 4 9832 - 9850 0 08/08/00 4 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.953" I-1 9970' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/05/82 ORIGINAL COMPLETION 04/05/07 DAV /PAG XO CORRECTION WELL: 06 -24A 07/18/00 SIDETRACK (06 -24A) 04/07/07 DAV /PAG SAFETY NOTE CORRECTION PERMIT No: " 03/16/06 NORDIC2 RWO AR No: 50- 029 - 20822 -01 03/19/06 KEY/TLH DRLG DRAFT CORRECTIONS SEC 2, T1 ON, R14E, 2718.36' FEL & 2566.36' FNL 03/25/06 CJA /PJC MILL FASDRILL & PUSH BTM 03/27/06 JRP /PJC GLV C/O BP Exploration (Alaska) 12/17/10 berger NO. 5667 Alaska Data 8. Consulting Services Company: State of Alaska 2525 Gambe8 Street, Suite 400 Alaska Out 8 Gas Cons Comm Anchorage, AK 00503-2038 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I Well Job • Log Description Date BL Color CD NK-65A BCRD-00064 RST « G 10/21/10 _ • 1 _. G-09B 11649989 MCNL REDO ' ---1 09/11/07 1 06-24A BCRD-00068 Millile • — a _... 11/12/10 1 14 1 01-06A BCRD-00063 RST — (7 10/29/10 1 0 4 • 1 G-298 AWJI-00113 MCNL — / 10/06/10 1 A roe 1 W-37A BD88-00048 MCNL A — / 09112/10 1 ' OD 1 05-07 BBKA-00077 LDL q Abo /1 11124/10 1 CoiA 1 12-29 B5JN-00067 USIT / W.-- 5a) 10/13/10 giV,j/L) 1 1 K-126 BL65-00002 MEM PROD PROFILE _, -- 11/21/10 1 13 4, _ 1 17-16 BBSK-00036 PROD PROFILE "STiklii: i 11/12/10 1 0041 - 1 . K-12B BCUE-00094 MEM PROD PROFILE _ " 11/22/10 1 ..04. - 1 K-1213 BCUE-00094 MEM PROD PROFILE ° I —'14-1054— 11/23/10 1 t 0 , 1 • 12-04A B5JN-00069 USIT , — , 11/02/10 a • 1 1 09-25 AV1H-00048 INNImmammaraariFarmra■vammiEEEEn ievarvm - , 4 1 06-02 BBKA-00075 SCMT • , 11/19/10 ro, , j MEM 1 18-13B BCZ2-00028 SCMT 00 .. 11/07/10 00 6,/ i 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data 8 Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd, Anchorage, AK 99503-2838 4 7 PI' , ' 5 4 toP 1 ' ' , . . •• • 1111 •,,L,.„: „.,,.,, , , .,,„, , ,, ., ,, , , , ••,., ,,, ,, , :,,,. 0 ..... • ,,.. L.\ \ 11/30/10 Sc al erger NO. 5652 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, Al( 99501 ', Well Job 8 Log Description Date BL Color CO Z -01B BD88 -00070 MEM PROD PROFILE " ♦ . - 4 , 10/31/10 1 ' 0 1 04-25 BJ01400005 INJECTION PROFILE 2" _ I L - p • 1a! 1 04 -25 BJOH -00005 • ' • • r. •:. wn 1 V -07 BAUJ -00052 MEM PROD PROFILE Imo ••• 11/12/10 1 1 06 -24A BCRD -00068 PRODUCTION PROFILE 11/11/10 1 q - 1 F -19A AM-00121 MEM PROD PROFILE � � 11/09/10 1 lilt O. 1 X -25 B088-00068 MEMORY GLS /) /�� - 10 /30l10 1 . )/S v . 1 1 - - P -08A _ BCUE -00090 MEMORY GLS . II - • , 10/22/10 1 • '7a 1 04 -30 BD88 -00063 MEM PROD PROFILE - -'— �' - - 4 • 10/26/10 1 1 • 01 -06A BCRD -00063 PRODUCTION PROFILE S <,`) 10 1 tirl 1 _ - D -33 BD88.00061 MEM PROD PROFILE . ( , 10/20/10 1 r 1 Z -26A B088 -00067 MEM PROD PROFILE , IlirIEM ' o'SrTtr� - 1 Z -13A BD88-00062 ' ' • - • • • - • • /- ` 10/22/10 1 �1"� 1 . 01 -02 BCRD -00066 INJ PROFILE/WFL 10/25/10 1 [!• • 1 V -219 AZ2F -00069 MEM INJECTION PROFILE f) e, / [E a 10 /31/10 1 , /'' 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 z.9031,10,,,1:11',1;:;k::1-R-'t:31::::::::::pro--io' BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 C J Mr. Tom Maunder ~~~.f~'~~~:t ~1~+1~,! ~~ ~ ~~' Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ~ d ~ ..-~ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 06 aV ~ °~7 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-06 Date: 12/10/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al os-o1 1750490 50029201720000 NA Sealed NA 06-02 1770780 50029202820000 NA Sealed NA 06-o3A 1951520 50029201860100 NA Sealed NA 06-04A 2001020 50029201790100 NA Sealed NA 06-05 1780200 50029202980000 NA Sealed NA 06-066 2050980 50029202010200 NA Sealed NA 06-07 1780210 50029202990000 NA Sealed NA os-osA 1951950 50029203000100 NA Sealed NA os-o9 1790730 50029204000000 NA Sealed NA o6-1oA 1981960 50o292oao2o1oo NA Sealed NA 06-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 06-13A 2061020 50029204570100 NA Sealed NA 06-14B 2090120 50029204580200 NA Sealed NA 06-15 1800320 50029204590000 NA Sealed NA os-16 1800330 50029204600000 NA Sealed NA 06-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009 06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009 06-218 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 06-22A 1930570 50029208060100 NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6!2009 06-24A 2000960 50029208220100 NA Sealed NA Schlumbøpger NO. 4249 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth dCD -0'7 k, /'510Ö Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine MahnkE," 333 West 7th Ave, SuitEl100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# loa Description Date Bl Color CD 06-24A 11637328 RST 04/16/07 1 1 l2-16 11414768 RST 10/07/06 1 1 06-07 11637123 RST 05/06/07 1 1 06-21A 11628766 MCNl 04/09/07 1 1 F-09A 11657123 CBl 05/06/07 1 09-15 11630475 CEMENT IMAGE lOG 05/06/07 1 03-36A 11745217 USIT CORROSION 05/03/07 1 03-36A 11745217 US IT CEMENT 05/03/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. ~~E:.'CtÞ · Vi': r.J 2007 =~g~te~:~I~~~ ~~~~center LR2-1 (~\.,,",,",.-p~=,ft· ~:,,-.\.. sCANNED MAY 3 1 Anchorage. Alaska 99508 r1AY 3, 1 2007 Date Delivered: Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '1 ¿. // ) . .... ~i Received by: C.. // t~ -.........,.. ConIng ,~,,)\:,.!' '''1- OS/29/07 . . Schlumberger NO. 4237 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SGANNED MAY 0'7 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 d60 -09ro Field: Prudhoe Bay WII J b# D BL Ci CD L D . f e 0 og eSCrlptlon ate o or S-21 11695054 LDL 03/27/07 1 Y-31 11628764 MEM GLS 04103/07 1 14-04 11660530 MEM PROD PROFILE 04/06/07 1 14-10 11626084 LDL 04/02/07 1 F-17A 11626083 LDL 03/31/07 1 F-30 11626078 LDL 03/26/07 1 X-21A 11660531 MEM PROD PROFILE 04/07/07 1 G-32A 11661134 MEM PROD PROFILE 03/30/07 1 X-36 11649959 MEM iNJECTION PROFILE 04/12/07 1 06-24A 11637328 PRODUCTION PROFILE 04/16/07 1 X-36 11649959 MEM INJECTiON PROFILE 04/12/07 1 12-02 N/A MEM iNJECTION PROFILE 04/14/07 1 J-12 11686735 PROD PROFILE 04/13/07 1 B-26B 11628767 MEM PROD PROFILE 04/11/07 1 11-36 11626477 PROD PROFILE 04/17/07 1 03-18A 11626081 LDL 03/30/07 1 P2-59A 11630470 USIT 04/02/07 1 11-37 11626086 PRODUCTION PROFILE 04/22/07 1 X-10 11686739 LDL 04/23/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SiGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth E'I\/E"'O' f"'-' ....~ f1~E: C ~. .:~.,.. Date Delivered: ~1AY 0 4 2001 Received by: i,\~kª t)¡¡ & Ga$ Cons, c.ommi~ And'IOf~ rl 04/30/07 . . 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: a STATE OF ALASKA _ ALA" OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D o D Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P) . Stratigraphic D Exploratory Service Stimulate D Qther ø Mill Plug Waiver D Time Extension 0 Re-enter Suspended Well 0. 5. Permit to Drill Number: 200-0960 6. API Number: 50-029-20822-01-00 . 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 71 KB 06-24A ADL-028311 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 8. Property Designation: Total Depth measured 9970 true vertical 9176.43 feet feet Plugs (measured) Junk (measured) 9878 9878 plug Effective Depth measured 9984 true vertical 9187.15 feet feet Casing Conductor Surface Production Liner Liner Length Size MD TVD Burst Collapse 83 20" 91.5# H-40 30 - 113 30 - 113 1490 470 2467 13-3/8" 72# L-80 29 - 2496 29 - 2495.94 5380 2670 8109 9-5/8" 47# L-80 28 - 8137 28 - 7677.65 6870 4760 1207 7" 29# L-80 7965 - 9172 7514.41 - 8549.03 8160 7020 951 4-1/2" 12.6# L-80 9019 - 9970 8419.81 - 9176.43 8440 7500 Perforation depth: Measured depth: 9740 - 9746 True Vertical depth: 9000.56 - 9005.15 9760 - 9788 9015.83 - 9037.07 9832 - 9850 SCfÍt,!',iNfD ,J 9070.57 - 9084.35 "'; ~ "..~.~ ......... & Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 26 - 9019 Packers and SSSV (type and measured depth) 7" Baker ZXP Mech Top Packer 4-1/2" Baker S-3 Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 7965 8850 8964 9019 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFt MAY 2 6 2006 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing pressure SHUT-IN 17783 0 480 216 15. Well Class after proposed work: Exploratory Development p) Service 16. Well Status after proposed work: Oil P):. Gas WAG D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 985 x Contact Sharmaine Vestal Title Data Mgmt Engr Phone 564-4424 Date 5/23/2006 R/GINAL Submit Original OnJy AÞ r: z..ç ,Ol,. ~ e e .. 06-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SÙMMÄRY 3/24/2006 MIRU Coil Unit #9. MU/RIH w/ jars/2 7/8" motor/venturi, 3.125" burn shoe. Venturi from 9036'-9044' w/ increasing rates. POOH. Continued on 03/25/06 WSR. 3/24/2006 ** WELL SHUT IN UPON ARRIVAL** {post rig} PULL B&R AND RHC @ 8843' SLM. ****WELL LEFT SHUT IN***pre ctu*** !!!!NOTE: GAS LIFT C/O TO BE DONE LATER!!!!! 3/25/2006 Continued from 03/24/06 WSR. POOH w/ venturi/burn shoe. Recover 1 gallon of heavy solids + 2 pieces of pkr rubber. MU/RIH, trip #2, w/ same jars/2 7/8" motor/venturi/3.125" burn shoe. Venturi from 9043'-9047'. POOH. Recover 1/2 gallon of solids/metal, packer rubber ring and top 3" core of Fasdril. MU/RIH, trip #3, w/ same BHA. On trip #3, tagged at 9058' worked up and down a couple of times, continue RIH until 9831' ( bttm perf interval) where we tagged at same spot 3 consecutive times with motor stalls each time. POOH w/ venturi and burn shoe BHA. Recover slip segments and composite from Fasdril plug in venturi. MU BHA #2, with 3.70", 3 blade mill and RIH. Mill/push plug to 9878',28' rathole. Chase out of hole. FP wellbore from 2500'. Rig down in progress. Continued on 03/26/06 WSR. FLUIDS PUMPED BBLS 240 MeOH 365 1% XS Slick 72 1 % KCL 677 TOTAL j(IL Lj/Jb/tJe; ALAS.L AND ~T:;~g~S~~~:~ON Cc&JSSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS MAR 2 4 2006 A laska Oil & Gas Cons. Carnm' 1. Operations Performed: . , o Abandon o Suspend o Operation Shutdown o Perforate o Other v o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program a Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. PermitTo Drill Number: BP Exploration (Alaska) Inc. a Development o Exploratory 200-096 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20822-01-00 7. KB Elevation (ft): 71' 9. Well Name and Number: PBU 06-24A 8. Property Designation: 10. Field / Pool(s): ADL 028311 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9970 feet true vertical 9176 feet Plugs (measured) 9050 Effective depth: measured 9050 feet Junk (measured) 9050 <f .,. 2nrf; true vertical 8446' feet ,:' "'~; (i :' :;\~ ~1\~ 8:",} 'ì ~'" ."> ,.-yO Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2496' 13-3/8" 2496' 2496' 4930 2670 Intermediate 8137' 9-5/8" 8137' 7678' 6870 4760 Production Liner 1207' 7" 7965' - 9172' 7514' - 8549' 7240 5410 Liner 953' 4-1/2" 9017' - 9970' 8418' - 8430 7500 Perforation Depth MD (ft): 9740' - 9850' Perforation Depth TVD (ft): 9001' - 9084' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 13Cr80 9019' Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer; 8964' 7" x 4-1/2" Baker 'S-3' packer 8850' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily AveraQe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: a Daily Report of Well Operations o Exploratory a Development o Service DWell Schematic Diagram 16. Well Status after proposed work: a Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Barbara Lasley, 564-5126 N/A Printed Name Terrie Hubble Title Technical Assistant . e-1ó ~ rL~ 11 L ¡}'" Phone Date D3/~/o~ Prepared By Name/Number: Signature ß (LYtr]{t' 564-4628 Terrie Hubble, 564-4628 . . < Form 10-404 Revised 04/2004 RBDMS BFL MAR 2 g 1006 .~ OR1G1NAL_ ssion Submit Onglnal Only e e Well: Field: API: Permit: 06-24A Rig Workover Prudhoe Bay Unit 50-029-20822-01-00 200-096 Accept: Spud: Release: Ri: PRE-RIG WORK 02/12/06 PULL STA# 1 S/O GLV. SET DGLV IN STA# 1 SET 4.5" JUNK CATCHER ON PXN PRONG AT 8974' SLM. WELL LEFT S/t. 02/28/06 PULL 4.5" JUNK CATCHER, FROM 8963' SLM. PULLED PRONG FROM 8961' SLM. PULLED 4.5" XN LOCK FROM 8977' SLM. 03/03/06 RUN 1 HALLIBURTON 4.5" FAS DRILL BRIDGE PLUG, SET AT 9050', CCL TO TOP OF PLUG = 16.2' CCL STOP DEPTH = 9033.8'. RUN 2 3.65" SCHLUMBERGER POWER CUTTER CCL TO CUTTER = 14.3' CCL STOP DEPTH = 8915.7' CUT DEPTH = 8930'. 03/04/06 T/I/O=400/400/0 CIRC OUT (PRE RWO). CIRCULATED DOWN IA UP TUBING TO FLOW LINE W/5 BBLS METHANOL, 957 BBLS 2% KCL, AND 172 BBLS 80° DIESEL. U-TUBE TXIA TO FREEZE PROTECT. FREEZE PROTECT FLOW LINE W/5 BBLS METHANOL, 66 BBLS 80° DIESEL. BLED ALL PRESSURES TO O. FINAL WHP'S=O/O/O. Legal Well Name: 06-24 Common Well Name: 06-24 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 P 3/2/2006 20:00 - 00:00 4.00 MOB P PRE 3/3/2006 100:00 - 02:00 2.00 MOB P PRE 02:00 - 02:30 0.50 MOB P PRE 02:30 - 04:00 1.50 MOB P PRE 04:00 - 06:00 2.00 MOB P PRE 06:00 - 06:30 0.50 MOB P PRE 06:30 - 10:00 3.50 MOB P PRE 10:00 - 10:45 0.75 MOB P PRE 10:45 - 16:30 5.75 MOB P PRE 16:30 - 00:00 7.50 MOB N WAIT PRE 3/4/2006 00:00 - 06:00 6.00 MOB C PRE 06:00 - 18:00 12.00 MOB C PRE 18:00 - 20:00 2.00 MOB C PRE 20:00 - 00:00 4.00 MOB C PRE 3/5/2006 00:00 - 01 :00 1.00 MOB C PRE 01 :00 - 03:30 2.50 MOB C PRE 03:30 - 07:00 3.50 MOB C PRE 07:00 - 09:15 2.25 MOB C PRE Start: 3/2/2006 Rig Release: Rig Number: Spud Date: 1 0/22/1982 End: Spot rig to side of satelite island. PU mats and materials from around wellhead. Prep to scope down and lower derrick. Lower derrick into pipe shed. Close doors. Continue to pick up around well head. PJSM on rig to discuss move. Notify Endicott Security. Move off pad and onto ice road. Turn onto Endicott Road. Continue towards OS 17. Shut down rig for crewchange and PJSM re: moving rig. Resume move on endicott causeway road heading toward the spine road at OS9. Currently 9.5 miles away from the "Y" at OS9. Rig at the "Y" at DS 9. Wait for security and CPS. Hold PJSM. Resume move to DS 6 across the DS 17 ice road and thru down town Oeadhorse. Spot rig on OS6 away from well house. Eline still rigged up on well. Well also must be circ'd out, well house and flowline removed, and pad leveled. Stand by on pad prep. Note - Pad prep not completed due to shortage of personnel due to all available people helping out with cleanup from GC2 spill. Continue to stanby on OS 6. Change of scope due to GC2 spill. Personnel/equipment not available. Talk to Veco crew. LRS still circ'ing out well. Plan is to finish circ out. FP well with diesel, and let it u-tube. Set BPV, bleed off flowline, remove flowline, wellhouse, circ out rig up. Waiting on Tool Service for pad prep. (They are prepping P2-18 for 7ES). Tool Service prepping pad for MIRU. Tool Service prepping pad for MIRU. Conduct pad inspection with OS06 pad operator. Change of scope due to GC2 spill. Personnel/equipment not available. Waiting for crane/personnel for BOP staging. -- Continue to prep well location for MIRU. Spot rig mats, sills, and herculite. Continue waiting for crane/personnel for BOP staging. Noticed on 06:00 AM drive to rig that there is a 150 ton Peak crane parked, but not making any lift, at Schlumberger. Called dispatch, and tried to get it sent over to make our pick. That crane will perform a maintenance job later this morning (Mast swap on a coil unit) for Schlumberger. Called Schlumberger and dispatch. Tried to get it sprung free. No possibility. Hard to believe that a routine maintenance job should take priority over a rig that is sitting here burning $5000.00 bills every hour on standby. Talked to dispatch again. It is out of their control. Printed: 3/20/2006 12:12:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-24 06-24 WORKOVER NORDIC CALISTA NORDIC 2 Start: 3/2/2006 Rig Release: Rig Number: Spud Date: 10/22/1982 End: prioritizes this stuff anyway if it is not dispatch? This is a rediculous waste of money. 09:15 - 09:30 0.25 MOB P PRE We finally got the 100 ton crane from Heavy equipment dispatch. Inspect lift and location with crane operator, TP, WSL. No problems observed with the lift. The lift will be done from behind the well, it will not go over the wellhead, or any flowlines. . 09:30 - 09:55 0.42 MOB P PRE PJSM with all rig personnel, Veco truck driver, and heavy eq. , crane operator. Discuss lift, and safety issues. Discuss hazards and mitigations. Non essential personnel to stay clear of the area. Only TP, 4 Nordic hands. truck driver and crane operator to be involved in positioning the BOP stack. 09:55 -11:15 1.33 MOB P PRE Position 13-5/8" BOP stack behind 06-24 wellhead. 11:15 -11:35 0.33 MOB P PRE PJSM Re: moving the rig down the pad and positioning square to the well. Notify pad operator of operations. 11 :35 - 12: 10 0.58 MOB P PRE Move rig down the pad and stage square and in front of the well. 12:10 - 12:30 0.33 MOB P PRE Shutdown, allow crews to change out. 12:30 - 12:45 0.25 MOB P PRE Safety meeting with new crew Re: moving over well. Assign block man, discuss hazards and mitigations. 12:45 - 13:15 0.50 MOB PRE Move rig over well 6-24A and set down. 13:15 - 14:00 0.75 RIGU PRE Build berm around rig. Rig up. 14:00 - 14:15 0.25 BOPSU PRE PJSM with valve crew about pulling BPV. 14:15 - 15:15 1.00 BOPSU PRE PU Valve crew lubricator. Pull BPV. No pressure on well. Rig down valve crew lubricator. 15:15 - 21:30 6.25 BOPSU P PRE Continue with general rig up and rig up to circulate well. RU, inspect tiger tank. RU and test hardline. -- Note: Have PJSM for circulating fluids while hardline crew RU hardline. 21 :30 - 00:00 2.50 BOPSU P PRE RU lines to tree. Test to 250 psi low, 2500 psi high. Displace diesel from tubing and IA. Detailed operations: - RU to pump down IA to displace FP in tubing. - Pump 60 bbls 80 deg SW down IA at 4.5 bpm / 300 psi. - Rig up to pump down tubing to displace FP in IA. - Pump 230 bbls 80 deg SW down tubing at 4.5 bpm at 350 psi. - 580 bbls hole volume, tubing and IA 3/6/2006 00:00 - 02:30 2.50 BOPSU P PRE Flush IA with SafeSurf-O detergent. Detailed operations: - RU to pump down IA for SafeSurf-O detergent soak. - Pump 290 bbls 150 deg SW w/ Safe Surf-O down IA. - Follow with 155 bbls of 80 deg SW from pits. 02:30 - 04:00 1.50 BOPSU P PRE Soak IA with detergent. - This was done on well END 3-11. The pipe was pulled with clean tubing. 04:00 - 06:10 2.17 BOPSU P PRE Circ well to 80 deg SW. Detailed operations: - RU to pump down tubing to displace well to clean SW. Printed: 3/20/2006 12:12:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-24 06-24 WORKOVER NORDIC CALISTA NORDIC 2 Start: 3/2/2006 Rig Release: Rig Number: Spud Date: 10/22/1982 End: - Pump 80 deg SW from pits down tubing until clean SW returns at IA. - 580 bbls hole volume, tubing and IA. 06:10 - 06:50 0.67 PRE SD for crew change and tech limits meeting. This is being done on tour due to long drive to Endicott camp. 06:50 - 08:15 1.42 PRE Dry rod in BPV. Test from below to 500 psi. 08:15 - 13:00 4.75 PRE ND FMC Gen 3 production xmas tree. Confirmed we have RH threads on the tubing hanger, and that they are in good shape. 13:00 - 13:20 0.33 PRE PJSM for using trolly to bring in 13-5/8" BOP stack. 13:20 - 18:00 PRE NU 13-5/8" BOP stack using trolley. 18:00 - 18:30 PRE Crew change / Tech Limits 18:30 - 22:30 PRE PJSM. Finish NU BOPs. Install choke / kill lines and hydraulics. Grease valves. Fill stack. 22:30 - 00:00 1.50 PRE Test BOP to 250 psi low, 3500 psi high. - WSL and AOGCC Jeff Jones witness test. 3/7/2006 00:00 - 01 :30 1.50 PRE Test BOP to 250 psi low, 3500 psi high. -- Test witnessed by WSL and AOGCC rep Jeff Jones. -- Good tests on bag, HCR (choke), Manual (kill) 01 :30 - 04:00 RREP PRE Rebuild test pump and HCR valve. -- Jeff Jones has left location. Will notify when pump/HCR repairs are complete. 04:00 - 06:30 2.50 PRE Continue testing BOPE to 250 psi low, 3500 psi high. -- Test witnessed by WSL and AOGCC rep Jeff Jones. 06:30 - 07:00 0.50 RREP PRE Crew change and tech limits. 07:00 - 08:30 PRE Test PVT and alarms. AOGCC Jeff Jones to witness. 08:30 - 12:00 RREP PRE Change out leaking choke side HCR valve on 13-5/8" stack. 12:00 - 14:00 PRE Attempt to test BOP. Chase leak. Discovered leaking past blanking plug. 14:00 - 17:00 3.00 PRE Pull blanking plug and BPV. Confirmed well dead, pull BPV with T-bar (dispensation from ANC). Run test plug (holds pressure from above, not below). Confirm holding. 17:00 - 18:00 1.00 PRE Body test BOPE against blind rams 18:00 - 18:30 PRE Crew change/TUsafety mtg 18:30 - 00:00 PRE Retest all rams, choke HCR valve, and other valves that were missed or failed previously to 250/3500 psi. Test witnessed by WSL 3/8/2006 00:00 - 02:45 2.75 CASE P DECOMP RU floor tools to pull tubing. MU 5-1/2" landing joint. Screw into hanger w/ test plug still installed. BOLDS. Unseat hanger w/ 140k and the wt dropped to 105k while pull hanger to floor. LD hanger and pup 02:45 - 05:00 2.25 CASE P DECOMP POOH LD 4-1/2" 12.6# L-80 IBT R3 tubing 40 jts LD at 0500 hrs 05:00 - 07:30 2.50 CASE P DECOMP Weekly safety meetings (both crews), plus change out. 07:30 - 12:00 4.50 CASE P DECOMP POOH LD 4-1/2" 12.6# L-80 IBT R3 tubing 80 jts LD (total 120 jts out) 12:00 - 12:30 0.50 CASE P DECOMP Off load 4-1/2" tubing from pipe shed. 12:30 - 13:45 1.25 CASE P DECOMP POOH LD 4-1/2" 12.6# L-80 IBT R3 tubing 50 jts LD (total 170 jts out) 13:45 - 14:00 0.25 CASE P DECOMP Off load 4-1/2" tubing from pipe shed. 14:00 - 16:00 2.00 CASE P DECOMP POOH LD 4-1/2" 12.6# L-80 IBT R3 tubing - 42.5 jts LD (total 212.5 jts out) - 5 GLM's and one nipple recovered - Cut flared to 4-7/8" OD. Requires dressing run. Printed: 3/20/2006 12: 12: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-24 06-24 WORKOVER NORDIC CALISTA NORDIC 2 Start: 3/2/2006 Rig Release: Rig Number: Spud Date: 10/22/1982 End: 3/8/2006 16:00 - 16:30 0.50 CASE P DECOMP Off load 4-1/2" tubing from pipe shed. NORM test all tubulars, okay at 0-5 uRem/hr 16:30 - 18:00 1.50 CLEAN P DECOMP I Load, steam, strap, drift, tally -9000' (300 jts) of 3-1/2" IF drill pipe. One row in is 44 jts 18:00 - 18:30 0.50 CLEAN P DECOMP Crew changerrUsafety mtg 18:30 - 00:00 5.50 CLEAN P DECOMP Continue to load, steam, strap, drift, tally -9000' (300 jts) of 3-1/2" IF drill pipe. 3/9/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Continue to load, steam, strap, drift, tally -9000' (300 jts) of 3-1/2" IF drill pipe. 03:00-04:15 I 1.25 CLEAN P DECOMP CDL 50' 04:15 - 06:00 1.75 CLEAN P DECOMP Finish load, steam, strap, drift, tally -9000' (300 jts) of 3-1/2" IF drill pipe. 06:00 - 07:00 1.00 CLEAN P DECOMP Crew change / tech limits 07:00 - 10:00 3.00 CLEAN P DECOMP Load, steam, strap, tally 35 jts of 2-7/8" PAC drill pipe. PhD=8 Ready rig floor for running 2-7/8" DP. 10:00 - 11 :00 1.00 CLEAN N WAIT DECOMP Waiting on equipment (shear pin guide shoe) for milling FasDrill. 11 :00 - 11 :30 0.50 CLEAN P DECOMP Bring tools to rig floor 11:30 -13:00 1.50 CLEAN P DECOMP PJSM. PU milling BHA with overshot shear pin guide. - BOT 4 bladed junk mill - Sperry Motor 3-1/8" - Crossover - Crossover pin x pin - Shear pin guide (13k dn shear pins) 13:00 - 15:00 2.00 CLEAN P DECOMP PU, RIH with 35 jts 2-7/8" PAC DP. 15:00 - 15:30 0.50 CLEAN P DECOMP Change out handling equipment. 15:30 - 17:00 1.50 CLEAN P DECOMP PU, RIH with 3-1/2" IF DP. - Top of 7" Liner at 7965' MD Qoint 216) - Top of 4-1/2" stub at 8930' MD Qoint 246/247) - FasDrill Plug at 9050' MD Qoint 250/251) - PBTD at 9984' MD Qoint 280) 17:00 - 17:30 0.50 CLEAN P DECOMP Break circulation at joint #50. 17:30 - 18:15 0.75 CLEAN P DECOMP PU, RIH with 3-1/2" IF DP to jt #77 18:15-18:45 0.50 CLEAN P DECOMP Crew changerrUsafety mtg 18:45 - 00:00 5.25 CLEAN P DECOMP Resume PU 3-1/2 DP and break circ every 50 jts Tagged 7" TOLat 7965' MD with overshot guide at 7964.6' DPM 3/10/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Work to get overshot guide past TOL (7") at 7965' DPM, then break circ 00:30 - 02:45 2.25 CLEAN P DECOMP Continue PU 3-1/2 DP until tag at 15' in on jt #249 which is 8929' DPM and the top of the 4-1/2" tubing stub which had been cut at 8930'. Slack off 10k and shear pins on overshot guide sheared allowing mill to enter 4-1/2" stub. Break circ 02:45 - 03:00 0.25 CLEAN P DECOMP PU two more singles and tag at 9018' DPM? This is 30' higher than where the FasDrill plug should be. It is also the junction of the 4-1/2" liner x 4-1/2" tubing. It is also near a reported area (9050-9150') of high corrosion PVT 392 03:00 - 05: 15 2.25 CLEAN P DECOMP Start motor 3.0/1020 and ease in hole until first MW at 9019'. Mill/drill w/ 200 psi dilf avg and little/slow progress. Feather, spud, slip, you name it and little progress. Motor doesn't act right either-can't get a good stall, just slow pressure increase. Made about 6-1 0" and gave up Printed: 3/20/2006 12: 12: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-24 06-24 WORKOVER NORDIC CALISTA NORDIC 2 Start: 3/2/2006 Rig Release: Rig Number: Spud Date: 10/22/1982 End: 3/10/2006 05:15 - 05:30 0.25 CLEAN P DECOMP RD circ equipment and RU to standback DP 05:30 - 05:45 0.25 CLEAN P DECOMP POOH w/ 1 std and wet (due to motor).. no circ sub in BHA 05:45 - 06: 15 0.50 CLEAN P DECOMP RU circ equipment and fin CBU while wo pill to slug pipe 06:15 - 07:00 0.75 CLEAN P DECOMP Change out / Tech Limits 07:00 - 09:00 2.00 CLEAN P DECOMP Circulate bottoms up. Waiting on dry job. Telecom working on comms-will be down til tomorrow 09:00 - 18:00 9.00 CLEAN P DECOMP Pump 30 bbls 10.8 ppg dry job. POOH (strapping). Stand back in derrick. - Keeping trip sheet every 5 stands (-1.7 bbls displacement) At surface with BHA #1. Sperry motor is real loose and mill had no wear so apparently motor was not turning. SLM was within l' OAL 18:00 - 18:30 0.50 CLEAN P DECOMP Crew changeout and TL meeting. 18:30 - 20:30 2.00 CLEAN P DECOMP I MU BHA #2. Add 5' guide pipe. MU 3 bladed tapered junk mill Ion BOT 3-1/8" motor. Add circ sub. 20:30 - 00:00 3.50 CLEAN P DECOMP RIH wI 2-7/8" DP followed by 3-1/2" DP f/ derrick. 3/11/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Continue TIH. Ease guide past top of 7" liner with no wt loss. TIH 03:00 - 04:15 1.25 CLEAN P DECOMP Ease guide over 4-1/2" tbg stub on jt# 249 at 15' in (8930') and see shear pins shear w/8k down wt. PU 2 more jts. RU and circulate #252 down. Circ 1.95/535 and see 50-80 psi MW at 9018' DPM. Ease mill down thru junction area of 4-1/2" tbg X 4-1/2" liner w/minor MW for about l' and then was clean. PU jt #253 and circ in hole. See MW at 9046' DPM (assume junk), then find FasDrill plug at 6' in or 9049' DPM. 108k up, 100k dwn. 04:15 - 06:00 1.75 CLEAN P DECOMP Drill on FasDrill plug / junk at 2.3/600 wI several stalls and some overpulls. Circ 30 bbl FloVis pill while milling. Some help but still having stalls. 06:00 - 06:30 0.50 CLEAN P DECOMP Crew changeout and TL meeting 06:30 - 12:45 6.25 CLEAN P DECOMP Continue milling operations. Appears to be more junk than anything on top of FasDril1. Numerous stalls. Pump 2 more high vis pills with little results. Overpulls 10-20k at first then miiled and rolled junk to only 5-1 Ok overpulls after stalls. Mill design not allowing junk to stay in the middle of mill. Decided move on with dressing tbg stub operations rather than stay on bottom any longer risking motor damage and depositing more junk. Dropped .750" ball and opened circ sub. 12:45 - 18:00 5.25 CLEAN P DECOMP TOH standing back 3-1/2 DP Telecom installed new temporary comms. Will finish installation of new system tomorrow dependent on weather 18:00 - 18:45 0.75 CLEAN P DECOMP Crew change/TUsafety mtg 18:45 - 20:30 1.75 CLEAN P DECOMP RU floor tools. POOH LD 2-7/8 PAC DP 20:30 - 00:00 3.50 CLEAN P DECOMP BO and LD BOT wash pipe/motor assy. Load out BHA and 2-7/8 DP Found mill worn and scarred from junk. Found a 3/8" OD x 5/8" long set screw? in between the blades. Circ sub also had junk in one port and was worn (rough) on the (assumed) low side DSM swap out tiger tank (that 4ES claims is theirs) for another tiger tank-musical tanks continue. 3/12/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP MU BHA #3 (dressing run for jet cut 4-1/2" tubing stub) 01 :30 - 06:00 4.50 CLEAN P DECOMP TIH wI 3-1/2 DP. Tag at TOL. RU and circ past top of 7" liner Printed: 3/20/2006 12: 12: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-24 06-24 WORKOVER NORDIC CALISTA NORDIC 2 Start: 3/2/2006 Rig Release: Rig Number: Spud Date: 10/22/1982 End: 3/12/2006 01 :30 - 06:00 06:00 - 06:20 06:20 - 08:50 08:50 - 11 :00 4.50 CLEAN P 0.33 CLEAN P 2.50 CLEAN P 2.17 CLEAN P DECOMP at 7965'. Prep to PU singles DECOMP Crew change and TL meeting. DECOMP PU 32 jts DP DECOMP Tag up on tbg stump at 8930'. Milled over jet-cut flared area. 5.25/1150 continued washing over with a few motor stalls down to 8936' and bottomed out with pilot mill. Mill about 6" of tbg stub. Also pumped 2 hi-vis pills while milling. DECOMP Circulate bottoms-up with last hi-vis pill 6.0/1430 DECOMP LD DP DECOMP Crew changefTUsafety mtg DECOMP Resume LDDP DECOMP Fin LDDP and load out DECOMP LD tubing stub dressing BHA. Boot baskets had a small amount of fines. Load out BOT tools. Load out DP handling tools. Clear drillers side of pipeshed for completion jewelry DECOMP 'Load pipeshed w/ one row 4-1/2" tubing. Load jewelry into pipeshed. Move snow DECOMP Crew change TL meeting incl SWS. Talk about SimOps loading pipe shed while running SL. DECOMP MU 7" lubricator sections for SWS line wiper/pack-off. Spot slickline truck. RIH w/ 6.05" GR and junk basket. Tagged top of 7" liner but able to jump over. Tagged top of 4-1/2" tbg stub at 8937'WL. POH rec'vd small piece of metal band nothing else. RDSL. RUNCMP Continue loading pipe shed w/ 4-1/2" tbg. Drift and tallied. RUNCMP Crew changefTUsafety mtg RUNCMP Pump out stack. Perform a dummy run w/ new FMC hanger using a joint of DP w/2 XO's. Hanger would not land (2" high) due to tite clearance on junk ring. New landing jt arrived so make up hanger (LH Acme) and mark landing joint for future reference. LD landing jt and hanger. Remove junk ring so FMC can send to machine shop to trim. It is also felt that additional weight will help fully seat hanger RUNCMP RU tools to run tubing RUNCMP Safety mtg re: run tubing RUNCMP MU Unique OS assy plus 'X' nipples, 7" BOT S3 Packer and GLM #1 w/ 1" DCK valve. Bakerlock all connections below the packer. Use Jet Lube Seal Guard on the rest. Nabors casing torque turn all connections to optimum. Run 4-1/2" 12.6# 13Cr80 R3 Vam Top tubing RUNCMP Continue running 4-1/2" 12.6" 13Cr80 R3 Vam Top tubing w/ a total of 4 GLM's and 3 'X' nipples at avg 18 jts/hr RUNCMP Crew change. TL meeting discuss all hazards of running tbg. Also discussed recommended practices of running Cr tbg. Doyon csg had several good points to cover. RUNCMP Continue running 4-1/2" 12.6# 12Cr80 R3 Vam Top tbg. Stop the job long enough to discuss with crews to triple inspect the elevators and clearing the rig floor of personnel prior and during pick-up. Also to clear the rig floor of equipment not required at this time. Continue running tbg. RIH with jt#214 up wt 81 k (75k net) 78k dwn wt. Didn't see top of tbg stub but tagged with brass pins 5' inside Unique OS on depth. Sheared pins setting down 5k traveled another 2.75' and 11 :00 - 13:00 2.00 CLEAN P 13:00 - 18:00 5.00 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 00:00 5.50 CLEAN P 3/13/2006 00:00 - 01 :30 1.50 CLEAN P 01 :30 - 04:00 2.50 CLEAN P 04:00 - 06:00 2.00 CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30 - 11 :20 4.83 CLEAN P 11 :20 - 18:00 18:00 - 18:30 18:30 - 21 :00 21 :00 - 21 :30 21 :30 - 21 :45 21 :45 - 00:00 6.67 RUNCO 0.50 RUNCO 2.50 RUNCO 0.50 RUNCO 0.25 RUNCO 2.25 RUNCO 3/14/2006 00:00 - 06:00 6.00 RUNCO 06:00 - 06:25 0.42 RUNCO 06:25 - 13:30 7.08 RUNCO Printed: 3/20/2006 12:12:18 PM , , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-24 06-24 WORKOVER NORDIC CALISTA NORDIC 2 Start: 3/2/2006 Rig Release: Rig Number: Spud Date: 10/22/1982 End: ode NPT RUNCMP tagged no-go. Calculate space out with +/-20' of pup jts. LD 3 full jts. MU pups then 1 full jt. MU FMC tbg hanger and landing jt. to string. Align slot in hanger with tbg spool. Land hanger. Check and it did land correctly. RILDS to further check then I RUNCMP backout same. Messed up threads on 1 LDS. 13:30 - 15:00 RU to rev circ and fix stripped LDS. Unland hanger to bring Unique OS off tbg stub. 15:00 - 18:00 RUNCMP Reverse in 150 bbls of clean/heated SW followed by 450 bbls of SW with corrosion inhibitor. Pumped at 3bpm max 290psi. 118:00 - 18:45 (pump trips set at 750psi) 0.75 RUNCMP Crew change out and PJSM with crews I 118:45 - 21 :15 2.50 RUNCMP Reverse cir in 460 bbl of heated SW with 2- 55 gal drums of Nalco EC1124A corrosion inhibitor. Op = 3 bpm at 270 psi 21:15 - 23:00 RUNCMP RU to land tubing. Landed tubing in hanger PU wt = 82k and slack off at 78k RILDS 23:00 - 00:00 RUNCMP Dropped rod / ball, waited 20 minutes. Pressured up on the tubing to 3,500 psi and charted for 30 min P(final) at 3,425 psi 3/15/2006 00:00 - 02:20 RUNCMP Released pressure on tubing to 1,500 psi. Lined out to PT the IA. PT the IA to 3,500 psi and charted for 30 min.P(final) = 3475 psi. Released tubing pressure quickly and DCK sheared at 3,100 psi. Released pressure and confirmed circulations both ways. LD landing joint and set FMC's 5" ISA BPV in tubing hanger. PT beow to 600 psi. Leaked, retest to 600 psi still leaks. RU to pump down on BPV. 02:20 - 03:30 1.17 RUNCMP RU to circulate down tubing. 03:30 - 05:10 1.67 RUNCMP Circulate down tubing to clean up BPV. PT and still leaking. RU 7" lubricator and pulled BPV. Installed different BPV and PT to 660 psi. 10 min OK 05:10 - 06:00 0.83 RUNCO RUNCMP RD lubricator crew and make ready to ND 13-5/8" BOP stack. 06:00 - 06:30 0.50 BOPSU RUNCMP Crew change and TL meeting. Reviewed BOP ND procedures. The use of hydraulic, air, and hammer wrenchs, their hazards of use and when and when not to use each. 06:30 - 12:00 5.50 BOPSU P RUNCMP ND 13-5/8" BOP stack. 12:00 - 22:00 10.00 WHSUR P POST NU production tree. Installed test test plug and PT tree to 5000 psi with diesel. (OK) 22:00 - 23:30 1.50 WHSUR P POST Pull FMC's Test plug. RU tree cap XO and cirulating hoses for FP well bore 23:30 - 00:00 0.50 WHSUR P POST PJSM on PT with Little Red H.O.S. and cirulating diesel with same 3/16/2006 00:00 - 00:45 0.75 WHSUR P POST PT surface lines. Fixes leaks. PT Surface lines from LR to 2500 psi (OK) 00:45 - 02:15 1.50 WHSUR P POST Pumping 80 deg F Diesel down the lA, taking returns up the tubing to mud pits. Op = 2.0 bpm at 300 psi. 02:15 - 03:20 1.08 WHSUR P POST Equalize FP fluids 03:20 - 04:20 1.00 WHSUR P POST Blow down top of tree and install B PV. PT below to 1000 psi with LR (OK) RD LR 04:20 - 06:00 1.67 DEMOB P POST RD and maker ready to move off well RIG RELEASED AT 06:00 HRS FOR DEMOB TO DS7-36A Printed: 3/20/2006 12: 12: 18 PM TREE = 5-1/8" FMC GEN 3 WELL EAD= FMC ACTUATOR = AXELSON KB. ELEV = 71' BF. ELEV = KOP= Max Angle - Datum MD = Datum iVD- e 2997' 41 @ 9777' 9573' 8800' SS 06-24A SAFf&NOTE5: KVALVEWELL. MAY HAVE BAD NIP~D/OR CONTROL LINES. TBG IN BAD CONDITION. ***CHROME 4-1/2" TBG*** -15-1/2" X 5-1/2" XO, ID = 3.958" I 2184' -14-1/2" HES X NIP, ID = 3.813" I 13-3/8" CSG, 72#, L-80, ID = 12.347" I TOP OF T' CSG I 7965' Minimum ID = 3.725" @ 8997' 4-1/2" HES XN NIPPLE I EZBP I 8160' I 9-5/8" csG, 47#, L-80, ID = 8.681" I 9032' GAS LIFT I'v1ANDRELS DEV TYÆ VLV LATCH 22 MMG DC!< RKP 27 MMG DMY RK 21 MMG DMY RK 35 KGB-2 DMY BK PORT DA TE o 03/14/06 o 03/14/06 o 03/14/06 o 03/14/06 ST MD TVD 4 3447 3425 3 6104 5821 2 7766 7328 1 8762 8207 MILLOUTWINDOW 8137' - 8155' I 14-1/2" TBG, 12.6#, 13CR80 VAM TOP, .0152 bpf, ID = 3.958" 14-112" TBG, 12.6#, L-80 NSCT .0152 bpf, ID = 3.958" ÆRFORA TION SUMI'v1ARY REF LOG: JEWELRY LOG ON 07/25/00 ANGLEATTOPÆRF: 41 @ 9740' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 9740 - 9746 C 02/06/04 2-7/8" 6 9760 - 9788 C 10/26/03 2-7/8" 4 9762 - 9770 C 09/21/01 2-1/8" 4 9778 - 9788 C 08/08/00 2-7/8" 4 9778 - 9788 C 09/21/01 2-118" 4 9832 - 9850 C 08/08/00 DATE 11/05/82 07/18/00 03/16/06 03/19/06 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK (06-24A) NORDIC2 RWO KEY fTLH DRLG DRAFT CORRECTIONS 17" LNR, 29#, L-80. .0371 bpf, ID = 6.184" I PBTD I 9984' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" H 9970' DATE REV BY COMMENTS PRUDHOE BA Y UNrr WELL: 06-24A ÆRMrr No: "2000960 API No: 50-029-20822-01 SEC 2, T10N, R14E, 2718.36' FEL & 2566.36' FNL BP Exploration (Alaska) 8/5/2005 2:33 PM 1 of I Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907-659-5102 907-659-5100 #1923 pgr «06-24A.pdf» Attached is a wellbore schematic. Please call if you have any questions. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Caliper Tbg, change-out OGLV in sta# 3 3. DHD: Re-TIFL All, Well 06-24 (PTD #2000960) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 07/29/05 were 2400/2300/80. The well failed a TIFL on 7/28/05. NSU, ADW Well Integrity Engineer wrote: Jim Regg AOGCC Well schematic includes statement that tubing is in poor condition; what are BP's plans should the TIFL fail subsequent to changing out OGLV #3? -----Original Message----- From: James Regg [mailto:jim re99@admin.state.ak.us] Sent: Tuesday, August 02, 2005 5:04 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Re: 06-24 (PTD #2000960) Classified as Problem Well If" ".. Ir, «'~ i 2 0 0 1~" .) L ¡.J l.J J.. ~ ~J Donald Hope this helps. If 06-24A fails the Re-TIFL post OGLV change out, we will probably try to dummy all the live gas lift valves and perform and MITIA. If however the tubing caliper indicates probable holes or the re-TIFL post DGLVs fails, a TTP will be set for leak detect diagnostics. 06-24A is a producer with good production economics and will justify more complex tubing repair (patch) should it be determined the tubing has holes. /" For a Problem Well on the 28 day clock, all efforts are made to mechanically restore tubing integrity within the 28 day period before securing is the only remaining option. :J12~q 7J1r;;(o> Jim, Subject: RE: 06-24A (PTD#2000960) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Wed, 03 Aug 2005 19:12:10 -0800 To: James Regg <jim_regg@admin.state.akus>, "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP . com> CC: Winton GAubert <winto:q._aubert@admin.state.ak.us> ) RE: 06-24A (PTD #2000960) Classified as Problem Well ') Re: 06-24 (PTD #2000960) Classified as Problem Well ) ) ,li~j~~!E:lte:.'06"2~'œtR~2~~Ö9?~}'~~¡r$~~e(Ì'áS,prøb1~r#\V'~~r' ... Fr~',;...'~~t:n.e$..1~~,gg,,1imp~F~~·@~~~11·.,st~tF··ak;µS>.' :pªte:Tt1,e,02Aug40()5J1:Q4:29~0800 · Well schematic includes statement that tubing is in poor condition; what are BP's plans should the TIFL fail subsequent to changing out OGLV #3? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: All, Well 06-24 (PTD #2000960) has sustained casing pressure on the IA and is classified as a Problem well. TIO'S on 07/29/05 were 2400/2300/80. The well failed a TIFL on 7/28/05. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Caliper Tbg, change-out OGLV in sta# 3 3. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «06-24A.pdf» Thank s , Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907-659-5102 907-659-5100 #1923 pgr 1 of 1 8/2/2005 5:04 PM 06-24 (prD #2000960) Classified as Problem Well ) ) o6-Z4A Subject:~ (PTD #2000960) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 31 Jul2005 18:16:00 -0800 To: "Yancey, Alex N" <Alex.Yancey@BP.com>, "GPB, FS3 DS Ops Lead" <qPBFS3DSOpsLead@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADWWell Operations Supervisor" <NSUADWWeIIOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)" <jim;...~egg@admin.state.alcus>, "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL & Cqmpletion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "OPB, Ops Mgr" <GPBOpsMgr@BP.com>, "GPB, FS3 Area Mgr" <GPBFS3TL@ÐP.com> CC: "NSU, ADW Well IntegrityEngineer" <NSUADWWellIntegrityEngîneer@BP.com>,. "Hughes, A1Ìdrea (VECO)" <hugha4@BP.eom> TfCCA All cb-~24'A , Well..D9-24"(PTD #2000960) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 07/29/05 were 2400/2300/80. The well failed a TIFL on 7/28/05. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Caliper Tbg, change-out OGLV in sta# 3 3. DHD: Re-TIFL v Attached is a wellbore schematic. Please call if you have any questions. «06-24A.pdf» Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907 -659-5102 907 -659-5100 #1923 pgr r,,,-., ,i~ ¡,\,th~ iË-T: (,~ 1r:, 0. I,); (;): ,) n n ~~ U\¡;f\Y-¡¡Ü ~!ð\'.lC....¡l.) "J .1.., jl ,( '''" /,~." ,.' Content-Description: 06-24A.pdf Content-Type: application/octet-stream Content-Encoding: base64 ~ SL\J'~ ,ÆAJ:L( P 't /vCk-j P ~ ~ 24ror~ ìef~ î5 p}tt^"eJj' p~ss L-veS (u~, <-1 ~ q t la\J~e. S l.~ 6ß70r~ 33. ~{o -~ Z3Cüf"5¡ CD Ltq z OA ~() rs: 5300psc L~ 3~1 812-JD~ 1 of 1 8/2/2005 2:07 PM ) ) TREE = W8..LHEAD = ACfUÄfoR';; KB. ELEV = 'ï3ï=~"äË\i ;"" KÖþ,,;"" ,,~~ ~~ª ,~.: Datum MD = DatumTVD = FMC GEN 3 FMC "A'XELSÓ¡,i 71' 06-24A SAFETY NOTES: KVALVE WELL. MAY HAVE BAD NIP AND/OR CONTROL LINES. TOO IN BAD CONDITION. ................ ..................... ""'...........299'7' "....,..~~..,'~..~,!.!.!.', 9573' 8800' SS I 2198' 1--14-1/2"HESXNIP,ID=3.813" I 113-3/8" CSG, 72#, L-80, I) = 12,347" 1-1 2496' r---J ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DA.TE 1 3776 3725 25 IVIVIG RK 2 6307 6002 27 IVIVIG RK 3 7935 7486 19 IVIVIG RK 4 8498 7992 36 KBG-2-LS INT 5 8812 8248 34 KBG-2-LS INT Minimum ID = 3.725" @ 8997' 4-1/2" HES XN NIPPLE L ITOPOF7" CSG 1--1 7965' 1 I MILLOUT WlNOOW 8137' - 8155' I EZBP 1-1 8160' :~.~ ~~ ~~':~. ,». I!t~. 1--17" X4-1/2" BKR 503 A<R,ID= 3.875" 8997' 1--14-1/2" HES XN NIP, 10 = 3.725" I 9018' 1--14-112" VVLEG, I) = 3.958" I 9020' 1--1 ELMO TT LOGGBJ 09/14/00 1-7" X 4-1/2" BKR ZXP LNR PKR, I) = 5,250" 19-5/8" CSG,47#, L-80,ID= 8.681" 1--1 9032' .. .. 14-1/2"lBG, 12.6#, .0152 bpf, 10= 3.958" 1--1 9019' I TOP OF 4-1/2" LNR 1--1 9019' ÆRFORA 1l0N SU'v1M<\ RY REF LOG: JEWELRY LOG ON 07/25/00 ANGLE AT TOPPffiF: 41 @9740' Note: Refer to Production DB for historical perf data SIZE SFf NTffiVAL Opn/Sqz DATE 2-7/8" 6 9740 - 9746 0 02/06/04 2-7/8" 6 9760 - 9788 0 10/26/03 2-7/8" 4 9762 - 9770 0 09/21/01 2-1/8" 4 9778 - 9788 0 08/08100 2-7/8" 4 9778 - 9788 0 09/21/01 2-1/8" 4 9832 - 9850 0 08/08100 17" LNR, 29#, L-80, .0371 bpf, 10= 6.184" H 9172' I PBTD 1--1 9984' 14-1/2" LNR, 12.6#, L-80, ,0152 bpf, 10=3.953" 1-1 9970' DATE 11/05/82 07/18/00 09/20/01 09/21/01 08/19/03 10/26/03 REV BY COMrvENTS ORIGINAL COMPLETION SIDETRACK RWfP CORRECTIONS JLM'KK ADPffiF/REÆRF CMOfTLP ÆRF A NGLE CORRECTION CJSrrLP ADD PERF DA. TE REV BY COlVlVlalTS 02106/04 MJAITLP A DO PffiFS ffiUŒlOE SA Y UNT W8..L: 0S-24A ÆRMfT No: 2000960 A PI No: 50-029-20822-01 SEC2, T10N, R14E, 2718.36' ÆL& 2566.36' FNL BP EXploration (Alaska) MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc >'-.J' - STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend 0 RepairWeliD Pull TubingD Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate ŒI WaiverD Stimulate D Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 200-0960 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519.6612 7. KB Elevation (ft): 71.00 8. Property Designation: ADL-0028311 11. Present Well Condition Summary: Total Depth measured 9970 feet true vertical 9176.4 feet Effective Depth measured 9818 feet true vertical 9059.9 feet Casing Length Size Conductor 83 20" 91.5# H-40 Liner 1207 7" 29# L-80 Liner 953 4-1/2" 12.6# L-80 Production 8110 9-5/8" 47# L-80 Surface 2465 13-3/8" 72# L-80 Perforation depth: Development 00 StratigraphicD 9. Well Name and Number: 06-24A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceD 6. API Number 50-029-20822-01-00 Plugs (measured) R~CE'VCD MAH 3 0 2004 Ala8a0ll& - None , ' ~It~ Junk (measured) MD TVD Burst Collapse 30 113 30.0 - 113.0 1490 470 7965 - 9172 7514.4 - 8549.0 8160 7020 9017 - 9970 8418.1 - 9176.4 8430 7500 27 - 8137 27.0 - 7677.7 6870 4760 29 - 2494 29.0 - 2493.9 4930 2670 Measured depth: 9740 - 9746, 9760 - 9762, 9762 - 9770, 9770 - 9778, 9778 - 9788, 9832 - 9850 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 True vertical depth: 9000.56 - 9005.15,9015.83 - 9017.35,9017.35 - 9023.42,9023.42 - 9029.49,9029.49 - 9037.07,9070.57 - 9084.35 9019 Packers & SSSV (type & measured depth): @ 22 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 7" Baker ZXP Mech Liner Top Packer 8964 9017 7965 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 @ @ @ Prior to well operation: Subsequent to operation: Oil-Bbl 155 Representative Dailv Averaae Production or Iniection Data Gas-Mel Water-Bbl Casing Pressure 6.4 3 2100 Tubing Pressure 221 242 Daily Report 01 Well Operations, ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron J!ß~' 1476 14. Attachments: Copies of Logs and Surveys run - Signature Form 10-404 Revised 12/2003 7.7 73 2100 15. Well Class after proposed work: ExploratoryD Development[! Service 0 16. Well Status after proposed work: Operational Shutdown 0 Oil I]] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. ISUndry Number or N/A if C.O. Exempt: N/A Production Technical Assistant Title Phone 564-4657 Date 3/26/04 f->-:'-:¡(""'<r¡',fl' >. ¡-ft;l_':':¡\:'~" RIJDMS BfL MAR 3 J 28 " -~' "- , 06-24A . DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/06/04 Perforate 9740'-9746' 6 SPF FLUIDS PUMPED BBLS No Fluids Pumped 0 I TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Suspend D RepairWellD Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate ŒJ WaiverD Stimulate D Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 200-0960 OtherD Name: BP Exploration (Alaska), Inc. 71.00 8. Property Designation: ADL-0028311 11. Present Well Condition Summary: Development ŒJ Stratigraphic D 9. Well Name and Number: 06-24A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory D Service D 6. API Number 50-029-20822-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 9970 feet Plugs (measured) Junk (measured) None true vertical 9176.4 feet Effective Depth measured 9818 feet None true vertical 9059.9 feet Casing Length Size MD TVD Burst Collapse Conductor 83 20" 91.5# H-40 30 113 30.0 113.0 1490 470 Liner 1207 7" 29# L-80 7965 - 9172 7514.4 - 8549.0 8160 7020 Liner 953 4-1/2" 12.6# L-80 9017 - 9970 8418.1 - 9176.4 8430 7500 Production 8110 9-5/8" 47# L-80 27 - 8137 27.0 - 7677.7 6870 4760 Surface 2465 13-3/8" 72# L-80 29 - 2494 29.0 - 2493.9 4930 2670 Perforation deoth: Measured depth: 9760 - 9762, 9762 - 9770, 9770 - 9778, 9778 - 9788, 9832 - 9850 True vertical depth: 9015.83 - 9017.35,9017.35 - 9023.42,9023.42 - 9029.49,9029.49 - 9037.07,9070.57 - 9084.3~'::< f::C-':E","'," æ\5.V"if:, :..,~ t,:¡",,:'" ..... . GO .m"" $ L,.". !.~.f Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 22 9019 FES 2 6 2004 Packers & SSSV (type & measured depth): 4-112" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 7" Baker ZXP Mech Liner Top Packer @ @ @ 8964 9017 7965 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 252 6.7 99 1040 208 477 7.4 84 1950 224 Reoresentative Dailv Averaae Production or Iniection Data 13 14. Attachments: 15. Well Class after proposed work: Exploratory D Development ŒJ ServiceD Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown 0 OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations . ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron C Signature Title Production Technical Assistant Phone 564-4657 Date 2/25/04 Form 10-404 Revised ~ANNED MAR 1 6 2004. ðII8 BfL ftB 2~' il\ 06-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/23/03 (WELL FLOWING UPON ARRIVAL) SHUT WELL IN DRIFT W/2 7/8 DUMMY GUN, SAMPLE BAILER TAGGED @ 9830' SLM, (TARGET DEPTH 9760-9788) NO SAMPLE RECOVERED TURNED WELL OVER TO DSO, POP WELL. 10/26/03 A TOTAL PERFORATED 28' WITH 2-7/811 HSD GUN LOADED WITH POWERJET PJ2906 HMX CHARGES, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. API DATA: PENETRATION = 28.111, ENTRANCE HOLE 0.3211. PERFORATED INTERVAL 9760' - 97881. Tie-in to Sperry-Sun MWD Log dated 9-Jul-2000 to 15-Jul-2000. Tie-in to top of shale at 9788'. FLUIDS PUMPED B:LS : TOTAL No Fluids Pumped Page 1 TREE = FMC GEN 3 W8.LHEAD = FMC ACTUl\ TOR = AXELSON KB. ELEV = 71' BF. ELEV = KOP= 2997' Max Ange = 41 @ 9777' Datum MD = 9573' Datu m TVD = 8800' SS 06-24A SAFETY NOTES: KVALVE WELL. MAY HAVE BAD NIP AND/OR CONTROL LINES. TBG IN BAD CONDITION. 2198' 4-1/2" HES X NIP, ID = 3.813" 13-318" CSG, 72#, L-80, D = 12.347" TOPOF 7" CSG ST rvD TVD 1 3776 3725 2 6307 6002 3 7935 7486 4 8498 7992 5 8812 8248 GAS LIFT MANDRELS DEV TYPE V LV LA. Ta-i 25 rvTv1G RK 27 rvTv1G RK 1 9 rvTv1G RK 36 KBG-2-LS INT 34 KBG-2-LS INT PORT DA. TE Minimum ID = 3.725" @ 899T 4-1/2" HES XN NIPPLE I MILLOur WINDOW 8137' - 8155' I 7" X 4-1/2" BKR ZXP LNR PKR, [) = 5.250" 9-5/8" CSG, 47#, L-80, ID = 8.681" 4-1/2" TBG, 12.6#, .0152 bpf, ID = 3.958" ÆRFORA llON SUMI\AARY REF LOG: JEWELRY LOG ON 07/25/00 ANGLE AT TOPPffiF: 41 @ 9740' Note: Refer to Production œ for historieal perf data SIZE SFT NTffiV A L Opn/Sqz DATE 2- 7/8" 6 9740 - 9746 0 02/06/04 2- 7/8" 6 9760 - 9788 0 10/26/03 2- 7/8" 4 9762 - 9770 0 09/21/01 2-1/8" 4 9778 - 9788 0 08/08/00 2- 7/8" 4 9778 - 9788 0 09/21/01 2-1/8" 4 9832 - 9850 0 08/08/00 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9172' ~ 9984' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" I 9970' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/82 ORIGINAL COMPLETION 02106/04 MJA/TLP ADD PffiFS 07/18/00 SIDEfRACK 09/20/01 RNlTP CORRECTIONS 09/21/01 JLM'KK ADPffiF/REÆRF 08/19/03 CMO/TLP ÆRF ANGLE CORRECTION 10/26/03 CJSffLP ADD PERF ffiUDHOE BA Y UNIT W8.L: 06-24A ÆRMIT No: 2000960 API No: 50-029-20822-01 SEC 2, T10N, R14E, 2718.36' FEL & 2566.36' FNL BP Exploration (Alaska) Permit to Drill 2000960 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT 06-24A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20822-01-00 MD 9970 'I'VD 9176 Completion Dat 8/8/2000 ~" Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__~o Sample N._9 Directional Survey N._~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number 8136 9970 Open 7/18/2001 10191 Comments 8136-9970 Jc' T D D- C CBL 5 FINAL 9150 9750 CH 8/28/2000 SRVY RPT 8097 9970 OH 8/1/2000 SCMT 5 FINAL 9036 9870 CH 8/18/2000 Survey Report 8097 9970 1/9/2001 Survey Report 8097 9970 1/9/2001 LIS Verification FINAL 8139 9933 CH 7/10/2001 LIS Verification FINAL 8139 9933 OH 7/10/2001 10191 FINAL 8136 9970 oh 7/18/2001 10191 BL(C) 9150-9750 SPERRY 8097-9970. BL(C) 9036-9870 8097-9970 Digital Data 8097-9970 Paper Report 8139-9933, Paper Copy 8139-9933, Digital Data 8136-9970 Digital Data Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis ~ R~.c.~.ived ? Daily History Received? L'~N Formation Tops L"~ N Comments: Permit to Drill 2000960 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT 06-24A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20822-01-00 MD 9970 'l-VD Compliance Reviewed By: 9176 Completion Dat 8/8/2000 Completion Statu 1-OIL Current Status 1-OIL Date: UIC N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __X Explorato~__ Stratigraphic_ Service__ 4. Location of well at surface 4460' FNL, 1033' FEL, Sec. 02, T10N, R14E, UM At top of productive interval 2375' FNL, 3111' FEL, Sec. 02, T10N, R14E, UM At effective depth 2278' FNL, 2035' FWL, Sec. 02, T10N, R14E, UM At total depth 2239' FNL, 3295' FEL, Sec. 02, T10N, R14E, UM (asp 's 685942, 5941416) (asp's 683812, 5943450) (asp's 683677, 5943544) (asp's 683623, 5943580) 12. Present well condition summary Total depth: measured true vertical 9970 feet Plugs (measured) 9176 feet 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-24A 9. Permit number / approval number ~.. 10. APi~¢~ 50-029-20822-01 11. Field / Pool Prudhoe Bay Oil Pool Tagged TD @ 9824' MD (09/14/2001). Effective depth: measured true vertical Casing Length Conductor 79' Surface 2425' Production 8066' Liner 1207' Side Track Liner 951' 9871 feet Junk (measured) 9100 feet Size Cemented 20" 1930# Poleset 2200 sx Fondu & 400 sx 13-3/8" PFC 9-5/8" 500 sx 'G', 300 sx PFC 7" 237 sx Class 'G' 4-1/2" 135 sx Class 'G' Measured Depth True VerticalDepth 79' 79' 2496' 2496' 8137' 7678' 7965'-9172' 7514'-8549' 9019'-9970' 8420'-9176' Perforation depth: measured Open Perfs 9762'- 9770', 9778'- 9788', 9832'- 9850' true vertical Open Perfs 9017' - 9023', 9029' - 9037', 9071' - 9084' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 TBG @ 9019'. Cons. 7"x 4-1/2" Baker S-3 Packer @ 8964' MD. 7"x 4-1/2" Baker ZXP Liner Top PKR @ 9019' MD. 4-1/2" HES X @ 2198' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 09/19/2001 Subsequent to operation 09/24/2001 OiI-Bbl 547 Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 7404 41 1292 6035 176 Casing Pressure Tubing Pressure 233 286 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby ce .rtify that the foregoirAg issue and correct to the best of my knowledge. ~,~~-~M~ Title: Technical Assistant DeWayne R. Schnorr Date September 26, 2001 Prepared by DeWayne R. Schnorr 564-51 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 03/23/2001 09/14/2001 O9/21/2OO 1 03/23/01 09/14/O 1 09/21/01 06-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM: PPPOT- MITOA PERF(ADD-PERF): DRIFT W/2 7/8 DUMMY GUN PERFORATE 2 7/8" PJ @ 4 SPF EVENT SUMMARY PPPOT PASSED-MITOA PASSED RIH W/2 7/8 DUMMY GUN W/TEL, LOCATED T.T. @ 9006' SLM + 14 = 9020' ELM. TD @ 9824' CORRECTED DEPTH. POOH. MIRU ELINE, NOTIFY DSO. SHUT WELL IN. RIH WITH 10' 2 7/8" HSD POWERJET PERF GUN 4 SPF. PERFORATE 9778'-9788', POOH. RIH WITH 8'2 7/8" HSD POWERJET PERF GUN 4 SPF. PERFORATE 9762'-9770', POOH. RDMO. NOTIFY DSO TO PUT WELL ON TEST. FLUIDS PUMPED BBLS 0 ITOTAL 9/21/2001 ADD PERFS/RE PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" HSD POWERJET PERF GUN LOADED 4 SPF. 9762'-9770' 9778'-9788' Page I WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska July 16, 2001 RE: MWD Formation Evaluation Logs: 6-24A, AK-MM-00095 ~,~)-24A: igital Log Images: 50-029-20822-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF TllE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED JUL 1 1 001 Ala~Oil&OasCoas. C~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska July 02, 2001 RE: MWD Formation Evaluation Logs - D.S. 06-24A, AK-MM-00095 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20822-01. RECEIVED 'JUL 1 0 2001 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4460' FNL, 1033' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 2375' FNL, 3111' FEL, Sec. 2, T10N, R14E, UM At effective depth At total depth 2239' FNL, 3295' FEL, Sec. 2, T10N, R14E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic_ Service__ (asp's 685942, 5941416) (asp's 683812, 5943450) (asp's 683623, 5943580) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-24A 9. Permit number / approval number 200-096 10. APl number 50-029-20822-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 79' Surface 2425' Production 8066' Liner 1207' Liner 951' 9970 feet Plugs (measured) 9176 feet 9871 feet Junk (measured) 9100 feet Tagged PBTD @ 9871' MD 3/21/2001. Size Cemented Measured Depth True Vertical Depth 20" 1930# Poleset 79' 79' 13-3/8" 2200 sx Fondu & 400 Sx PFC 2496' 2496' 9-5/8" 500 Sx Class G & 300 Sx PFC 81 37' 7678' 7" 237 Sx C~ass G 91 72' 8549' 4-1/2" 135 Sx C~ass G 9970' 9176' Perforation depth: measured 9778' - 9788'; 9832' - 9850'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) true vertical 9029'- 9037'; 9071' - 9084'. 4-1/2", 12.6#, L-80 Tbg @ 9019' MD. APR 0R ?_001 7"X 4-1/2" BAKER S-3 PACKER (~ 8964' MD; 7"X 4-1/2" BAKER ZXP LINER~.,IaskaTO_P.,P.~C.~.R~@,,~I~j[t~I~-iiSSI01'[~ii & b;~ t ........ ' 4-1/2" HES X @ 2198' MD. ~i_l,r;l~(~r~ge 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 498 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 2394 326 847 3869 459 Casing Pressure Tubing Pressure 221 247 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /- Title: DS 6 Surveillance Engineer Deidre Taylor Prepared by Paul Rauf 564-5799 ~,'~_ ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-24A DESCRIPTION OF WORK COMPLETED CT ACID STIMULATION W/DIVERTER Date Event Summary 1/18/2001' 2/12/2001. 2/21/2001' 3/19/2001- 3/20/2001' 3/21/2001' 3/23/2001' RIH & tagged PBTD @ 9825' SLM. RIH & tagged PBTD @ 9818' SLM. Performed PST Treatment (new technology that stimulates the reservoir using sonic vibration) - no change in rate observed. Tagged PBTD @ 9828'. Performed TIFL. A CT Acid Stimulation to increase production was performed as follows: MIRU CTU. PT'd equip. RIH w/CT Jetting Nozzle & performed a FCO to 9884' MD. POOH w/CT. Liquid packed IA w/480 bbls of Crude. RIH w/CT & killed well w/filtered 2% KCL Water. Observed injectivity of 1 bpm @ 1070 psi WHP. Tagged PBTD @ 9871'. Reciprocated an Acid Wash across the following open perforations located f/: 9778' - 9788' MD (Zone 2) 9832' - 9850' MD (Zone 2) Pumped: (a) 10 bbls of Filtered 2% KCL Water @ 2.5 bprn, followed by (b) 50 bbls of 7.5% HCI @ 2.5 bpm, followed by (c) 50 bbls of Filtered 2% KCL Water Overflush @ 2.6 bpm, followed by (d) 5 bbls of 30# HEC Gel loaded w/0.5 ppg wax beads (100# of wax) @ 2.1 bpm, followed by (e) 10 bbls of 50% Diesel - 50% Xylene @ 2.1 bpm, followed by (f) 20 bbls of 7.5% HCl @ 2.0 bpm, followed by (g) 50 bbls of Filtered 2% KCL Water overflush @ 2.5 bpm, followed by (h) 30 bbls of Methanol Water for FP, followed by (i) Shutdown. POOH w/CT Nozzle. RD CTU. Placed well BOL. Performed PPPOT & MITOA - both passed. Obtained representative well test data. Page 1 RECEIVED APR O6 2001 Alaska 0il & Gas (;,~m. {;(~rrimJssim; .Aucll0rag¢ U~/ZZ/ZUU1 1U:~ FAX 9U7 564 42,f$.& BP EXPLORATJON bp March 21,2001 BP Exploration (Alaska) Inc. 900 East Bcnson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: RECEIVED HAR 2 5 2001 Alaska Oil & Gas Cons. Commir~ion Anchorage Re: Prudhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as req~uired under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list 6f well work tentatively' sch6duled for March 19 - 26, 2001' Well 05-01C Work Planned CTE PERFORATION 05-18A 12-15 CTE ADD PERFORATION CT ACID STIMULATION W/DIVERTER SAG HYDRAULIC FRACTURE TREATMENT 13-27A CT ADD PERFORATION W/WORK PLATFORM 16-23Ai NK-65i CHEMICAL CUT TUBING (PRE RIG ST) CTE ADD PERFORATION S-101 S-103 ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. Sincerely,/'~/y. Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells 21-Nov-O0 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 06-24A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,097.00' MD 8,141.00' MD 9,970.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Schh mbe'rg NO. 437 8/21/00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia Color D.S. 1-20 LEAK DETECTION LOG 000814 I '1 D.S. 6-24A 20319 SCMT 000725 1 , AUG 2 9 2000 SIGNED ~. ~'_ DATE: e~o Alaska 0ii & Gas Cons. Commission Anchorage Please sign and return on py of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ..... STATE OF ALASKA ALASK~ ,LAND GAS CONSERVATION COMt SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Sen/ice Well ~Vl~o~ [] Oil [] Gas [] Suspended [] Abandoned [] Service ..: ..ame o, O era,or ,er ,,.um er BP Exploration (Alaska) Inc. 200-096 ~ 3. Address 8. APl Number ;~".-~:' ,,';. ~.;:~,: ': P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20822-01 ~ -2.Z~.,'~Y~ ~ - 4. Location of well at sudace ~¢~ . Unit or Lease Name~ ~.';:,~,; ;t~'.~" ' ~ 817' NSL, 1033' WEL, SEC. 02, T10N, R14E, UM~ ,.~5~~ Prudhoe Bay Unit ~ ~/~ ~ At top of productive inte~al~ ~,:~':.:.:~,~-.~'.~ ..... .,~ NS , 1' s.c. 0N,.14 ,u At total depth 10. Well Number 06-24A 3039' NSL, 3293' WEL, SEC. 02, T10N, R14E, UM ~ ' 11. Field and P~I 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 71' ADL 028311 12. Date Spudded 7/11,2000 113' Date T'D' Reached 114' Date COmp'' Susp'' Or Aband' 7,15/2000 8/8/2000 115' Water depth' if OffshOre N/A MSL J116. No. of Completions One 17. Total Depth (MD+TVD) ~ 18. Plug Back Depth (MD+~D) ]19. Directional Sudsy ~ 20. Depth where SSSV set] 21. Thickness of Permafrost 9970 9176 FT] 9883 9110 FT] ~Yes ~ No~ (Nipple) 2198' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU ,,,,, 23. CASING, LINER AND CEMENTING RECORD CASING SE~ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOSOM SIZE CEMENTING RECORD AMOUNT PULLED ,,,,, 20" 91.5~ H-40 Sudace 79' 30" 1930~ Poleset 13-3/8" 72~ L-80 Sudace 2496' 17-1/2" 2200 sx Fondu, 400 sx Permafrost 'C' 9-5/8" 47~ L-80 Sudace 8137' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' 7" 26~ L-80 7965' 9172' 8-1/2" 237 sx Class 'G' 4-1/2" 12.6~ L-80 9017' 9970' 6-1/8" 135 sx Class 'G' , , 24. Pedorations open t9 Production (MD+~D of Top and 25. TUBING RECORD Bottom and inte~a~, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 4 spf 4-1/2", 12.6~, L-80 9019' 8964' MD ~D MD ~D 9778' - 9788' 9029' - 9037 ..... 9832' - 9850' 9071' - 9084' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 132 Bbls of Diesel .... , , ,, 27. PRODUCTION TEST ,i Date First Production Method of Operation (Flowing, gas li~, etc.) August 10, 2000 Gas LiE Date of Test Hours Tested PRODUCTION FOR O~L-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED O~L'BBL GAs-MCF WATER-BBL O~L GRAWTY-API (CORR) Press. 24-Hour RATE 28. CORE DATA ,,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Sag River 9168' 8546' Shublik 'A' 9203' 8575' Shublik 'B' 9232' 8599' Shublik 'C' 9235' 8602' Top of Sadlerochit / Zone 4B 9297' 8653' Zone 4A 9431' 8761' Zone 3 9533' 8840' Zone 2C 9614' 8903' Zone 2B 9654' 8934' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the fore_cloing is true and correct to the best of my knowledge Signed TerrieHubble.~~ ~ Title Technical Assistant Date (~(~"O~"'-(~..,~ 06-24A 200-096 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 Rev. 07-01-80 OP r ti0ns summa RePort Page 1 of 4 Legal Well Name: 06-24 Common Well Name: 06-24 Event Name: RE ENTER Contractor Name: NABORS Rig Name: NABORS 7ES ' Code Date From ~ To Hours '-Activity Phase 7/7~2000 18:00 - 19:00 1.00 RI(GU PRE 19:00 - 19:30 0.50 RIGU PRE 19:30 - 21:30 2.00 WHSUR DECOMP 21:30 - 22:00 0.50 WHSUR DECOMP 22:00 - 23:30 1.50 WHSUR DECOMP 23:30 - 00:00 0.50 WHSUR DECOMP 7/8/2000 00:00 - 00:30 0.50 WHSUR DECOMP 00:30 - 01:30 1.00 WHSUR DECOMP 01:30 - 02:00 0.50 WHSUR DECOMP 02:00 - 04:30 2.50 WHSUR DECOMP 04:30 - 05:00 0.50 WHSUR DECOMP 05:00 - 08:00 3.00 WHSUR DECOMP 08:00 - 08:30 0.50i WHSUR DECOMP 08:30 - 09:00 0.50 WHSUR DECOMP 09:00 - 09:30 0.50 WHSUR DECOMP 09:30 - 10:30 1.00 PULL DECOMP 10:30 - 11:30 1.00 PULL DECOMP 11:30 - 13:30 2.00 PULL DECOMP 13:30 - 23:00 9.50 PULL DECOMP 7/9/2000 7/10/2000 23:00 - 00:00 1.00 PULL DECOMP 00:00 - 00:30 0.50 BOPSUR DECOMP 00:30 - 01:00 0.50 BOPSUR DECOMP 01:00 - 01:30 0.50 BOPSUR DECOMP 01:30 - 03:30 2.00 STWHIP DECOMP 03:30 - 05:30 2.00 STWHIP DECOMP 05:30- 11:00 5.50 STWHIP DECOMP 11:00- 13:30 2.50 STWHIP DECOMP 13:30 - 14:30 1.00 STWHIP DECOMP 14:30- 17:00 2.50 STWHIP DECOMP 17:00 - 18:30 1.50 STWHIP DECOMP 18:30 - 19:30 1.00 STWHIP DECOMP 19:30 - 21:00 1.50 STWHIP DECOMP 21:00 - 21:30 0.50 STWHIP DECOMP 21:30 - 22:00 0.50 STWHIP DECOMP 22:00 - 00:00 2.00 STWHIP DECOMP 00:00 - 00:30 0.50 STWHIP DECOMP 00:30 - 04:30 4.00 STWHIP DECOMP 04:30 - 05:30 1.00 STWHIP DECOMP 05:30 - 07:30 2.001STWHIP DRAW DECOMP 07:30 - 08:00 0.50 STWHIP DECOMP 08:00 - 08:30 0.50 STWHIP DECOMP 08:30 - 19:30 11.00 S TWHIP: DECOMP i 19:30 - 21:00 1.50 STWHIP DECOMP 21:00 - 00:00 3.00 STWHIP DECOMP Start: Rig Release: Rig Number: 7/8/2000 Spud Date: 10/22/1982 End: Group: RIG Description of Operations Lay Herculite, Berm Complexes, Set CTGS Tank Held Pre-Spud Inspection & Safety Mtg, Accepted Rig @ 1800 Hrs R/U Lines & Tanks, Displace Diesel Freeze Protection with Seawater DSM Set BPV, Attempt to Test, No Test Wait On DSM to Pull & Reset BPV R/U DSM Lubricator & Pull Mis-set BPV PT BPV To !000 N/D Tree & TB(G Spool Adapter Check Condition & Type of Thread In TBG HGR, Ring Gasket Groove Full of Mud & Trash, Clean Out Same, Chase Treads on HGR, Threads OK N/U BOP M/U Test Jt W/TIW & Dart Test BOP; 250/3500, Witness By Jeff James AOGCC R/D Test Jt & Equip. R/U & Pull Blanking Plug R/U Lubricator & Pull BPV R/U 5 1/2 TBG Tools Screw Into TB(G HGR, Correct Number of Turns, BOLDS, Attempt to Pull, No Movement In TBG Spool Bowl, Pulled 140K Warm Spool & HGR, Pull Free of TBG Spool W/145K Pull, Reverse Out 4 BBLS, Diesel Pull & L/D 209 Jts, 5 1/2" 17# L80 8rd ABM R3 IPC TBG Plus 9 (GLMs, SSSV, Recovered 26 Control Line Clamps, 3 SS Bands & 1/4" Control Lines, + One Jet Cut Jt TB(G Clear Rig Floor of TBG Handling Tool, R/U to Test Lower Pipe Rams, & P/U DP Workstring Set Test Plug Test Lower Pipe Rams; 250, 3500 Pull Test Plug, Set Wear Ring P/U Mill BHA #1 P/U 4"DP, Stand 21 Stds Back in Derrick Continue P/U 4"DP & RIH W/Mill Assy to 8250 Displace Seawater W/10.5 #/gal Milling Fluid, Take SRPs, 185K UP, 150K Down, 160K Rot W/Mill Fluid Cut & Slip 105' Drlg Line Pump Dry Job, POH to 712' POH W/BHA R/U SWL, PJSM M/U EZSV BP on Wireline, RIH on WL, Run CCL Set EZSV BP @ 8160 WLM, 2' Below CSG Collar @ 8158 WLM, Tag, POH W/WL R/D SWL Test EZSV & CSG to 3000 psi, 30 Minutes OK Held PJSM P/U & M/U Whipstock Tools, Orient w/Sperry MWD Finish P/U, Orient Whipstock W/MWD Scribe Line RIH W/Whipstock, Test MWD@ 1975', Continue RIH Orient Whipstock W/MWD Troubleshoot & Repair Electric Brake Orient Whipstock Set Whipstock @ 325 Deg. Sheared Bolt Cut Window From 8137-8155 (bottom) Mill Formation to 8167 Wipe & Ream Through Window, Circ Hi Vis Sweep Around , POH Printed: 8/10/2000 11:25:26 AM oPerations summa Report Page 2 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From ~ To 7/11/2000 00:00 - 00:30 06-24 06-24 RE ENTER Start: NABORS Rig Release: NABORS 7ES Rig Number: Hours ,Activityl~odet Phase 0.50 STWHIP DECOMP 7/12/2000 00:30 - 02:00 1.50 STWHIP DECOMP 02:00 - 02:30 0.50 STWHIP DECOMP 02:30 - 03:00 0.50 STWHIP DFCOMP 03:00 - 03:30 0.50 STWHIP DECOMP 03:30 - 05:00 1.50 STWHIP DECOMP 05:00 - 07:30 2.50 STWHIP DECOMP 07:30 - 08:00 0.50 STWHIP DECOMP 08:00 - 00:00 16.00 DRILL LNR1 00:00- 17:30 17.50 DRILL LNR1 7/13/2000 17:30 - 18:30 1.00~ DRILL LNR1 18:30 - 20:00 1.50 DRILL LNR1 20:00 - 21:30 1.50 DRILL LNR1 21:30 - 22:30 1.00 DRILL LNR1 22:30 - 00:00 1.50 DRILL LNR1 00:00 - 01:30 1.50 DRILL LNR1 01:30 - 03:00 1.50 DRILL LNR1 03:00 - 03:30 0.50 DRILL LNR1 03:30 - 04:00 0.50 DRILL LNR1 04:00 - 07:30 3.50 DRILL LNR1 07:30 - 08:00 0.50 DRILL LNR1 08:00 - 11:30 3.50 DRILL LNR1 11:30 - 12:30 1.00 DRILL LNR1 12:30 - 14:00 1.50 DRILL LNR1 14:00 - 15:30 1.50 DRILL LNR1 7114/2000 7/15/2000 15:30 - 17:00 1.50 DRILL 17:00 - 20:00 3.00 DRILL 20:00 - 20:30 0.50 DRILL 20:30 - 00:00 3.50 DRILL LNR1 LNR1 LNR1 LNR2 00:00 - 02:30 2.50 DRILL LNR2 02:30 - 03:30 1.00 DRILL LNR2 03:30 - 04:30 1.00 DRILL LNR2 04:30- 05:00 0.50 DRILL LNR2 05:00 - 05:30 0.50 DRILL LNR2 05:30 - 07:30 2.00 DRILL LNR2 07:30- 10:00 2.50 DRILL OTHR LNR2 10:00 - 12:00 2.00 DRILL 12:00 - 12:30 0.50 DRILL 12:30 - 13:00 0.50 DRILL 13:00- 13:30 0.50 DRILL 13:30 - 00:00 10.50 DRILL 00:00 - 09:30 9.50 DRILL 09:30 - 11:30 2.00 DRILL LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 7/8/2000 Spud Date: 10/22/1982 End: Group: RIG Description of Operations Finish POH, SLM, OK Stand Back HWDP, L/D Whipstock Assy, Top Mill Full Gage Wash Out, Jet Stack of Mill Debris, Function Stack Clean Floor & Prep to P/U BHA Rig Service P/U & M/U BHA, Orient MWD, RIH & Shallow Test MWD RIH Orient @ Window DRLG to 8503, ART 2 AST 11.5 Hrs, Pump Hi Vis Sweeps as Required DRLG to Present Depth; AST 4 ART 10.5, Sweep Hole as Needed While DRLG CBU, Sweep Hole W/Hi Vis Sweep, Confirm Formation Short Trip to TOP of Whipstock Window; 2' Fill Circ Sweep, Flow check, Drop ESS per JORPS, POH to 8100' Pump Dry Job, Drop Rabbit POH to Run Liner Finish POH DP L/D BHA Clear & Clean Rig FIoor R/U CSG Tools PJSM, Run 29 Jts 7",26#,L80, BTC-M, R3 Circ Liner Volume RIH w/Liner on 4" DP to 8034(Top of Window) Circ Liner & DP Cap RIH w/Liner, Tagged up @ 9137, Worked Down W/O pump to 9155, Broke Circ Slowly Wash Down to 9172 (TD) 180K Up 130 Down, Circ @ 10 BPM w/Full Returns PJSM, CMT W/Dowell as Follows, 5 BBL B45 Spacer @ 11.2 #/gal, PT Lines OK, 45 BBL B45 Spacer, 237 sx (49 BBL) G plus .28%BWOC D65+.3%BWOC D167+.15%BWOC D800+.2%BWOC D46 Mixed @ 15.8 #/Gal w/fresh water, Launched Dart, Displace W/Dowell, P/U Plug on Schedule, Bump Plug to 3500, SO 50K, Check Floats, OK, Release Liner, P/U & Clear Dogs CIP 1530 Hrs 7/13/00, Full Returns Circ @ 10 BBL/Min, Reciprocate Pipe, Trace Cmt in Returns POH, L/D Setting Tool Service Wear Bushing, OK M/U 6.125 Bit, Motor, New BHA, PJSM; Radio Active Sources, Load Density Tools, RIH W/BHA, Shallow Test MWD & Motor RIH W/6.125 BHA Slip & Cut Drill Line RIH, Tag Cmt @ 9065, Wash Cmt Stringers f/9065-9090 (LC) Circ 2 Liner Volumes Close Bag & Pressure Test CSG/Liner to 3000 psi, OK Drill LC, FC, Firm Cmt, FS @ 9172 CBU w/10.5 Mud While Wait On Peak Trucks to Deliver QuikDril 8.3 Mud Displace 10.5#/Gal Mud to *.3 #/gal QuikDril Mud Clean Out Under Shakers Drlg 9172-9192 Art.5 Hrs Pull Into CSG & Perform FIT to 9.5#/Gal EMW, 8550 TVD, 8.3#/gal MW Drlg, AST 2 ART 7.5 Hrs DRLG f/9645-9970 ART 7.5 AST .5 Hrs CBU, Sweep Hole W Hi Vis Printed: 8/10/2000 11:25:26 AM o ra i°ns summa Report Page 3 of 4 Legal Well Name: 06-24 Common Well Name: 06-24 Event Name: RE ENTER Contractor Name: NABORS Rig Name: NABORS 7ES Date' From- To HourS Activity 7/15/2000 11:30 - 12:00 0.50 DRILL 12:00- 12:30 0.50 DRILL 12:30 - 14:30 2.00 DRILL 14:30 - 15:00 0.50 DRILL 15:00 - 15:30 0.50 DRILL 15:30 - 19:00 3.50 DRILL 19:00 - 20:30 1.50 DRILL 20:30 - 21:00 0.50 DRILL 21:00 - 21:30 0.50 DRILL 21:30 - 22:00 0.50 DRILL 22:00 - 22:30 0.50 DRILL 22:30 - 00:00 1.50 DRILL 00:00 - 00:30 0.50 CASE 00:30 - 01:00 0.50 CASE 01:00 - 01:30 0.50 CASE 01:30 - 04:30 3.00 CASE 04:30 - 05:00 0.50 CASE 05:00 - 05:30 0.50 CASE 05:30 - 06:30 1.00. CASE 06:30 - 07:00 0.50' CASE 07:00 - 08:30 1.50 CASE 7/16/2000 i08:30 - 09:30 1.00 CEMT LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 7/17/2000 09:30- 12:30 3.00 CEMT LNR2 12:30- 14:30 2.00 CEMT LNR2 14:30- 17:00 2.50 CEMT LNR2 17:00- 17:30 0.50 CEMT LNR2 17:30 - 18:30 1.00 BOPSUR LNR2 18:30 - 20:00 1.50 BOPSUR LNR2 20:00 - 20:30 0.50 BOPSUR LNR2 20:30 - 21:30 1.00i BOPSURBARR iCOMP 21:30 - 23:00 1.50 BOPSUR COMP 23:00 - 23:30 0.50 CASE COMP 23:30 - 00:00 0.50 RUNCOM COMP 00:00 - 05:00 5.00 RUNCOM COMP 05:00 - 05:30 0.50 RUNCOM COMP 05:30 - 06:30 1.00 RUNCOM COMP 06:30 - 07:30 1.00 RUNCOM COMP 07:30 - 08:30 1.00 RUNCOM COMP 08:30 - 09:00 0.50 RUNCOM COMP 09:00- 12:30 3.50 RUNCOM COMP 12:30- 14:00 1.50 RUNCOM COMP 14:00- 14:30 0.50 RUNCOM COMP Start: Rig Release: Rig Number: 7~8~2000 Spud Date: 10/22/1982 End: Group: RIG Description of Operations POH to 9159, SLM, OK Observe Well, Static. TIH CBU, Sweep Spot Liner Pill, Drop Ess ~POH t/9150 Rabbit Pipe,Pump Dry Job, POH to Run Liner LID BHA, Unload RadioActive Sources Download MWD Data Finish L/D BHA Clean/Clear Floor, PJU CSG Tool PJSM Run 22 Jts 4.5" 12.6# L-80,R-3 IBT Finish Running 22 Jts 4.5" 12.6# L80 R-3 IBT Liner M/U Baker Liner Hgr/Prk Assy Circ Liner Volume RIH W/Liner on 4" DP, Fill Dp Every 10 stds M/U CMT/Plug Drop Head, L/D Same RIH To 9100' Circ DP & Liner Cap, Check Up & Down Wts Run In Open Hole W/Liner, No Problems, Hole in Good Shape Circ & Condition Mud, Increase Pump Rate In Stages, Full Returns, Held PJSM, All Hands, Baker Head Would Not Test, Replace Same Pump 5 BBL B45 Spacer @ 9.5#/Gal, Pressure Test Lines, Pump 25 More BBL B45 Spacer, Pump 28 BBL batch Mixed Slurry (135 sx G + .28% D65+. 15%D800+.3%D167+.02gps D47 @ 15.8 #/gal w/fresh water) Wash Line @ "T", Launch Dart, Displace WI40 BBL Perf Pill, chased with Seawater, Latch Up with Liner Wiper Plug on Schedule,Displace Bump Plug to 4200, Set HGR, Floats Held, Release From Liner, Pressure Up on DP to 1000 psi, Unsting From PKR & Observe Pressure Loss, Circ Out Excess Cmt @ Max Rate, Set Down On Liner Top PKR w/50K, CIP 0930 Hrs Displace Well With Seawater @ Max Rate While Reciprocate POH, Stand Back 64 std 4"DP POH, L/D 3547' 4" DP Break & L/D Baker Setting Tool Pull Wear Bushing/Set Test Plug Test BOPs 250 Iow 3500 Hi, AOGCC Witness Waived by Crisp Pull Test Plug Choke Line Plugged with Babbit From Targeted "T", Remove From ChokeLine Finish Testing Choke Manifold 250/3000 psi Pressure Test CSG/Liner to 3000 psi, 30 Minutes, OK PJSM,Run Completion Runt 4.5" 12.6#, L80,1BT-M, R3 TBG Service Top Drive Finish Run 213 Jt 4.5" 12.6#, L80, IBT-M R3 TBG Tag TBR on Depth, Space Out, UP 132K, Down 106K M/U Tbg Hgr, Land TBG, RILDS R/U To Reverse, R/D TBG Tools Reverse Circ Clean Seawater, Add Corr Inhib @ 3 BPM Drop Ball & Tail, Set PKR W/3500 psi, Test Tbg 3500/30 Minutes, Bleed Tbg to 2000 PT Annulus to 3000 psi 30 Min, OK,Shear RP Back Out & Pulll Landing Jr., Set BPV & Test to 1000 Printed: 8/10/2000 11:25:26 AM Page 4 of 4 Legal Well Name: 06-24 Common Well Name: 06-24 Event Name: RE ENTER Contractor Name: NABORS Rig Name: NABORS 7ES · HoUrs iActivity Date: From- TOI Code!Phase · Start: Rig Release: Rig Number: 7/8/2000 Spud Date: 10/22/1982 End: Group: RIG 7/17/2000 14:30- 15:30 1.00 BOPSUR COMP 15:30- 16:30 1.00 WHSUR COMP 16:30- 17:30 1.00 WHSUR COMP 17:30 - 18:00 0.50 WHSUR COMP 18:00 - 21:30 3.50 WHSUR COMP 21:30 - 22:00 0.50 WHSUR COMP 22:00 - 00:00 2.00 WHSUR COMP Description of Operations ND BOP NU TBG Spool Adaptor & Test to 5000 NU Tree, RU Lubricator, Pull BPV, Set Tree Test Plug, Test to 5000, OK R/U Lines to Freeze Protect Freeze Protect, Let U-Tube Set BPV Finish Offload Fluids From Pits, Rig Released 0000 Hrs 7/18/00 Printed: 8/10/2000 11:25:26 AM 06-24A DESCRIPTION OF WORK COMPLETED RIG SIDETRACK INITIAL PERFORATION Date Event Summary 7/23/2000: 7/30/2000: 8/01/2000: 8/08/2000: 9/02/2000: RIH & tagged PBTD @ 9816' SLM. RIH & performed FCO to 9890' CTM. RIH & performed SCMT Log to PBTD @ 9878' ELU. MIRU ELU. PT'd equip to 3000 psi. RIH w/perf guns & tagged PBTD @ 9879' MD. Shot 28' of initial perforations @: 9778' - 9788' MD 9832' - 9850' MD Used 3-3/8" carriers & all shots @ 4 SP. POOH w/guns - ASF. RD ELU. Performed TIFL - passed. Placed 06~24A BOL & obtained well test data. Schlumberg NO. 415 8/10/00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-FN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia Color CD D,S. 2-12A 20313 SCMT 000720 1 D.S. 6-24A 20320 SCMT 000801 1 ,-, RF 7 EIVE'u SlGNED:~ ~ DATE: AU(~ '~ 8 2000 Alaska 0il & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~.rage 01-Aug-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 6-24A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 8,097.00' MD 8,141.00' MD 9,970.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) REcEI AUG 0 1 ~n~r~, Alaska 0il & Gas C0~,s. Com,~issiO,~ Anchorage North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 06, Slot 06.24 06-24A Surveyed: 15 July, 2000 S UR VEY REPORT 21 November, 2000 Your Ref: API-50029208220~ Surface Coordinates: 594~4~5.88 N, 685942.02 E (70° ~4' 4~.6528" N, 2~° 30' 07.2779" E) Kelly Bushing: 71.0Oft above Mean Sea Level DRILLING SERVICES Survey Ref: svy9890 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 06-24A Your Ref: APi-500292082201 Surveyed: 15 July, 2000 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 8097.00 17.750 318.000 7568.51 7639.51 8141.00 17.471 318.361 7610.45 7681.45 8170.11 19.840 314.920 7638.03 7709.03 8201.63 21.790 312.390 7667.49 7738.49 8232.72 23.040 310.240 7696.23 7767.23 8263.07 25.080 308.450 7723.94 7794.94 8294.90 27.350 306.840 7752.50 7823.50 8324.51 29.660 305.550 7778.52 7849.52 8356.86 31.770 304.040 7806.33 7877.33 8387.35 34.330 305.290 7831.88 7902.88 8418.60 36.730 307.500 7857.31 7928.31 8450.05 36.850 309.990 7882.50 7953.50 8480.97 36.560 310.630 7907.29 7978.29 8542.12 35.550 312.080 7956.73 8027.73 8634.70 36.000 308.200 8031.85 8102.85 8729.62 34.760 310.640 8109.24 8180.24 8822.87 34.130 312.660 8186.14 8257.14 8916.49 34.360 310.960 8263.54 8334.54 9007.95 33.210 314.710 8339.56 8410.56 9101.22 32.170 315.120 8418.05 8489.05 9130.62 31.710 316.420 8443.00 8514.00 9218.70 33.810 313.030 8517.08 8588.08 9312.41 34.850 308.630 8594.47 8665.47 9405.80 37.520 308.500 8669.84 8740.84 9499.40 40.120 307.680 8742.76 8813.76 Local Coordinates Northings Eastings (ft) (ft) 1548.77 N 1451.88W 1558.69 N 1460.76W 1565.44 N 1467.16W 1573.16 N 1475.27W 1580.98 N 1484.18W 1588.82 N 1493.75W 1597.40 N 1504.89W 1605.74 N 1516.29W 1615.16 N 1529,86W 1624.62 N 1543.53W 1635.41N 1558.14W 1847.19 N 1572.83W 1659.15 N 1586.92W 1682.92 N 1613.94W 1717.79 N 1655.30W 1752.67 N 1697.76W 1787.71N 1737.17W 1822.83 N 1776.44W 1857.37 N 1813.73W 1892.93 N 1849.41W 1904.08 N 1860.26W 1937.58 N 1894.14W 1972.09 N 1934.12W 2006.46 N 1977.23W 2042.64 N 2023.41W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5942928.36 N 684452.37 E 5942938.05 N 684443.25 E 5942944.65 N 684436.69 E 5942952.17 N 684428.39 E 5942959,77 N 684419.29 E 5942967.37 N 684409.53 E 5942975.67 N 684398.18 E 5942983.72 N 684386.58 E 5942992.81N 684372.78 E 5943001.93 N 684358.88 E 5943012.35 N 684344.01E 5943023.77 N 684329.03 E 5943035.37 N 684314.65 E 5943058.47 N 684287.05 E 5943092.31N 684244.84 E 5943126.13 N 684201.54E 5943160.19 N 684161.27 E 5943194.32 N 684121.15 E 5943227.94 N 684083.02 E 5943262.61 N 684046.47 E 5943273.49 N 684035.35 E 5943306.14 N 684000.66 E 5943339.65 N 683959.84 E 5943372.95 N 683915.89 E 5943407.98 N 683868.83 E 0.68 8.97 6.81 4.81 7.14 7.47 8.07 6.94 8.69 8.71 4.76 1.55 2.16 2.50 1,98 1.40 1.05 2.60 1.14 2.81 3.16 2.87 2.86 2.83 Alaska Drilling & Wells PBU EOA DS 06 Vertical Section Comment 2121.01 Tie-on Su~ey 2134.29 Window Point 2143.59 2154.79 2166.62 2178.94 2192.90 2206.88 2223.17 2239.56 2257.54 2276.28 2294.71 2330.64 2384.59 2439.32 2492.0O 2544.62 2595.44 2645.81 2661.36 2709.00 2761.71 2816.55 2874.86 Continued... 21 November, 2000 - 9:45 .2 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 06-24A Your Ref: API-500292082201 Surveyed: 15 July, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) 9592.70 38.340 307.870 8815.03 8886.03 2078.78 N 2070.05W 5943442.96 N 683821.32 E 9683.99 38.950 307.100 8886.33 8957.33 2113.47 N 2115.29W 5943476.52 N 683775.24 E 9777.14 40.780 305.400 8957.83 9028.83 2148.76 N 2163.44W 5943510.61 N 683726.23 E 9870.66 39.740 306.490 9029.20 9100.20 2184.23 N 2212.37W 5943544.87 N 683676.43 E 9918.40 40.020 304.450 9065.83 9136.83 2201.99 N 2237.30W 5943562.00 N 683651.08 E 9970.00 40.020 304.450 9105.35 9176.35 2220.76 N 2264.66W 5943580.09 N 683623.26 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vedical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.131° (22-Jul-00) The Dogleg Severity is in Degrees per 100 feet. Vedical Section is from Well and calculated along an Azimuth of 314.439° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9970.00ft., The Bottom Hole Displacement is 3171.82ft., in the Direction of 314.439° (True). Dogleg Rate (o/looft) 1.91 0.85 2.29 1.34 2.80 0.00 Alaska Drilling & Wells PBU EOA DS 06 Vertical Section Comment 2933.47 2990.05 3049.14 3108.91 3139.15 3171.82 Projected Survey Continued,.. 21 November, 2000 - 9:45 - 3 - DrillOuest 2.00.05 Sperry-Sun Drilling Services Survey Report for 06-24A Your Ref: API-500292082201 Surveyed: 15 July, 2000 North Slope Alaska Alaska Drilling & Wells PBU EOA DS 06 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8097.00 7639.51 1548.77 N 1451.88 W 8141.00 7681.45 1558.69 N 1460.76 W 9970.00 9176.35 2220.76 N 2264.66 W Comment Tie-on Survey Window Point Projected Survey Survey tool program for 06-24A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 9970.00 Vertical Depth (ft) 9176.35 Survey Tool Description MWD Magnetic 21 November, 2000 - 9:45 - 4 - DriflOuest 2.00.05 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount ____ Commissioner THRU: Blair Wondzell P.I. Supervisor .OM: Jeff Jones Petroleum Inspector NON- CONFIDENTIAL DATE: July 8, 2000 SUBJECT: Blowout Preventer Test Nabors rig 7ES BP× Drillsite 6 DS 6-24 PTD-200-096 Prudhoe Bay FieldlPBU Operator Rep.: John Raul Contractor Rep.: Cleve Coyne Op. phone: 659-4103 Rig phone: 659-4144 Op. E-Mail: PBU.Rig7es@BP.com Rig E-Mail: PBU.Rig7esToolPusher@BP.com Test Pressures Rams: 3500 psi MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping:, P Rig cond: P PTD On Location P Hazard: P Standing Order: P Annular: 3500 psi Choke: 3500 psi TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm Quantity P/F Trip Tank P P Upper Kelly 1 P Pit Level Indicators P P Lower Kelly I P Flow Indicator P P Ball Type I P Meth Gas Detector P P Inside BOP 1 P H2S Gas Detector P P BOP STACK: Quantity Size p/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5/8 P CHOKE MANIFOLD: P/F Pipe Rams 1 3 1/2 X 6 P Quantity P/F System Pressure 2900 P Lower Pipe Rams I 2 7/8 X 5 No. Valves 14 P After Closure 1700 P Blind Rams I P Man. Chokes I P 200 psi Attained 18 sec. P Choke Ln. Valves 1 4" P Hyd. Chokes 1 P Full Pressure 2 min. P HCR Valves 2 3" P Blind Covers (All Stations): P Kill Line Valves I 2" P N2 Bottles (avg): 6@2150 P Check Valve 0 N/A Test's Details On July 8, 2000 I traveled to BPX's DS 6 well #24 where Nabors Drilling personnel were ready to test BOPE. Ail BOPE equipment was tested with the exception of the lower pipe rams (2 7/8 X 5 variable) which will not be used for the first operation on this well. These rams were not tested because the configuration of the plug in the well did not allow it. They will be tested as soon as the 5 1/2 tubing has been pulled. The testing was accomplished by Nabors personnel in a smooth, safe and efficient manner with no failures. While on location I witnessed a random gas detector alarm system test and recorded no failures. The location and the rig were clean and well organized and the rig crews' experience was evident in the way they performed the tests. Total Test Time: 3 hrs. Number of failures: 0 Attachments: 0 cc: BOP Nab 7ES PBU DS6-24 7-8-00 JJ 7/10/00 F~rcenergy BO['E Test & Update Subject: Forcenergy BOPE Test & Update Date: Sat, 08 Jul 2000 17:29:05 -0800 From: Jeff Jones <jcff_jones~admin.state.ak.us> Internal To: blair_wondzell <blair_wondzell~admin.state.ak.us> CC: bob_fleckenstein <bob_fleckenstein~admin.state.ak.us>, lou grimaldi <lou_grimaldi~admin.state.ak.us> Gentlemen, attached is a BOPE test report from Forcenergy/Nabors rig 160/ McArthur River Unit #3 RD. I called to get an update on the repair of failures witnessed during the test and was informed that everything was fixed and they had tested again without failures. However, I still think it's a good idea to catch another test out there soon. I was also told that after pulling the tubing, they ran in with a 4 3/4"] ~~.~ BHA and encountered problems: apparently an area where the hole angle / U deviation is located has collapsed casing. Their plan is to mill it out/ ~¢ so they can run a string of 7 5/8" casing and cement it to surface. / ~~ comments? Talk to you later, -- ~ Jeff ~Forcenergy West McArthur Name: Forcenergy West McArthur Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 1 of 1 7/10/00 8:19 AM ALASKA O!I, AND GAS CONSERVATION COPlPlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer Phillips Alaska, Inc. P o Box Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 06-24A PhilliPs Alaska, Inc. Permit No: 200-096 Sur Loc: 817'NSL, 1033'WEL, Sec. 02, TION, R14E, UM Btmhole Loc. 2267'SNL, 3292'WEL, Sec. 02, T10N, R14E, UM Dear Mr. Stone: 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 law 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the Noah Slope pager at 659-3607. Sincerely Commissioner BY ORDER OF THE COMMISSION DATED this ~ -/~ day of July, 2000 dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~--. STATE OF ALASKA ALASKA ,_AND GAS CONSERVATION COMtv,, 31ON PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Oj~aJ:or, -~'~--,.- ,.~. ,-/'~0'~'~/-~,~/~' 5. Datum Elevation (DF or KB) 10. Field and Pool AR~~ska Inc. £ . ._~-'~-~ .<:?'D Plan RKB = 67.1' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028311 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 817' NSL, 1033' WEL, SEC. 02, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2323' SNL, 3221' WEL, SEC. 02, T10N, R14E, UM 06-24A Number U-630610 At total depth 9. Approximate spud date 2267' SNL, 3292' WEL, SEC. 02, T10N, R14E, UM 07/08/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028312, 1988' MDI No Close Approach 2560 9942' MD / 9161' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8157' MD Maximum Hole Angle 35.7 o Maximum surface 2420 psig, Attotal depth (TVD) 8800'/3300 psig 18. Casing Program Specifications Setting Depth Size To ~ Bottom Quantity of Cement Hole Casinq Weiqht Grade Couplinq Lenqth MD TVD MD i TVD (includestaqe data) 8-1/2" 7" 26# L-80 BTC-M 1172' 8000' 7541' 9172' 8536' 218 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 922' 9020' 8412' 9942' 9161' 106 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9751 feet Plugs (measured) Fill tagged at 9557' (04/96) true vertical 9239 feet Effective depth: measured 9557 feet Junk (measured) true vertical 9051 feet Casing Length Size Cemented MD TVD Structural Conductor 79' 20" 1930# Poleset 79' 79' Surface 2422' 13-3/8" 2200 sx Fondu, 400 sx Permafrost 'C' 2496' 2496' Intermediate Production 8958' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 9032' 8541' Liner 1019' 7" 305 sx Class 'G' ~ ~:~ ,~% ~, ~. ~,:,~7~?.2.' - 9741' 8240' - 9229' Perforation depth: measured 9516'- 9534', 9556'- 9569' ~.~L.~i~.] ~. (::) 2000 true vertical 9010' - 9028', 9050' - 9062' .Ata$~(a 0ii & Gas Col'ts. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~-----'~' -'--.. "r"7, ~ Title Senior Drilling Engineer Date ~;/~ ~/~ c~ver lett~'r Permit Number ..., ; I APl Number I Approval Date ~ "" ~ ~ 150-029-20822-01 I '~ ~ ~ '~) I for other requirements Conditions of Approval: Samples Required I'"1 Yes [~,,No Mud Log Required [] Yes .]~rNo Hydrogen Sulfide Measures .~es [] No Directional Survey Required .,~'~'es[~No ~ Required Working Pressure for BOPE I-12K; I"] 3K; I-I 4K; I"] 5K; r"110K; r"l 15K Other: ~,.~:~,~ ~(~ ¥~s~"'~ ~"~.~,~.~'~.., by order of Approved By F)RIGINAL SIGNED ~Y Commissioner the commission Date Form 10-401 Rev. 12-01-85 D Taylor Seamount Submit In Triplicate DS 6-24A Rigsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE The Kingak shale has caused problems with stuck pipe on this pad. proper drilling and connection operations are practiced at all times. weights in excess of 10.4 ppg can be expected. Ensure Mud Lost circulation has been encountered in this area even without crossing faults, such as in this well. Be prepared for lost circulation at all times, but especially at and below the Sag River formation. ~/ DS-6 is a designated H2S pad. Follow all applicable H2S procedures. CONSULT THE DS-6 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 DS 6-24A Hazards and Contingencies Page ! of 1 DS 6-24A Permit to Drill I Well Name: 16-24A Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location: 4461' SNL 1033' WEL S2 T10N R14E Umiat Target Location: 2323' SNL 3221' WEL S2 T10N R14E Umiat Bottom Hole Location: 2267' SNL 3292' WEL S2 T10N R14E Umiat I AFE Number: 14J0441 I Estimated Start Date: 107/08/2000 IMD: 19,942' I I TVD: i9,~6~ I I Rig: I Nabors7ES I Operating days to complete: 115.2 I BF/MSL: 137.1 IR:KB: 167.1 I Well Design (conventional, slimhole, etc.): I Conventional Twin Sidetrack I Objective: I Ivishak Zone 2 re-drill I Original Drilling Permit Number: 182-147 (Approved 09/03/1982) Mud Program: Milling/Cutting (;asing Mud Properties: LSND Density (ppg) Funnel Vis I Yield Point 10.5 45 - 55I 25 - 35 Whipstock Window in 9-5/8" r pHI HTHP FL 9 - 9.5 <10 Intermediate Mud Properties: LSND I 8-1/2" hole section From sidetrack depth to 8384' MD (8369' 'I'VD). TD Top of Sag River. Density (ppg)[ Funnel VisI Yield Pointr PV tau0 10.5 45 - 55 23 - 28 10 - 17 3 - 7 pH APl FL <10 to 6 Production Mud Properties: Low Density QUICKDRILn Density (ppg) lFunnel vis I LSRV PV 8.3 - 8.5 40 - 50 < 12,000 cP 5 - 8 6 1/8" hole section YP Ca++ 17 - 22 <100 APl FI <10 IpH 9.0-9.5 Directional: KOP: I 8157' MD-8W' I hole. Maximum Hole Angle: Close Approach Well: 35.7° (~ 8347' (7798' 'I'VD)to TD None DS 6-24A Permit to Drill Logging Program: Intermediate Section Production Hole IDrilling: Open Hole: Cased Hole: Drilling: Open Hole: MWD / GR None Possible USIT MWD / G R PEX w/BHCS (NOTE: Tie-in log is original GR/CNL) Formation Markers: Formation Tops MD TVDss Comments Base Permafrost Not Penetrated SV3 / T5 Not Penetrated SV1 / T3 Not Penetrated UG4 / K15-C1 Not Penetrated UG1 / UgS Not Penetrated WS1 / West Sak 6425' 6040' CM3 / K-12 6619' 6210' CM-1 / K5 7892' 7370' Kick Off Point 8157' 7629' HRZ 8398' 7840' (180' Thick) Kingak 8619' 8020' (449' Thick) Sag River 9172' 8469' (Base of HRZ) Shublik 9208' 8498' Top Sadlerochit / Z4B 9300' 8573' Zone 4A 9517' 8749' TZ3 9532' 8761' TZ2C 9607' 8822' June, 1999 test: 3296 psi @ 8800' (7.2ppg EMW) CGOC 9648' 8855' TZ2A 9789' 8970' HO/T 9802' 8980' COWC 9813' 8989' TZ1 9878' 9042' BSAD 9942' 9094' TD Casinq/Tubinq Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD-bkb MD/TVD-bkb 8-1/2" 7" 26# L-80 BTC-M 1172' 8000'/7541' 9172'/8536' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 922' 9020'/8412' 9942'/9161' Tubing 4-1/2" 12.6# L-80 IBT-M 9020' Surface 9020'/8412' DS 6-24A Permit to Drill Cement Calculations: Casino, Size 17" Intermediate- Single Stage I Basis: Lead' None Tail: Based on 1015' of open hole with 30% excess + 85' Shoe + 150' lap + 200' DP x Casing Annulus Tail TOC: 8000' MD (top of liner lap) I Total Cement Volume: Lead I None Tail 1 45 bbls / 253 ft3/218 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Liner Size 1 4 %" Production I Basis: Tail: Based on 770' of open hole with 50% excess, 150' of 7" x 4.5" liner lap, 200' of 7" x 4" drill pipe annulus volume, and 85' of 4-1/2" shoe joint. Tail TOC: At top of liner ~9,020' MD Total Cement Volume: Tail I 22 bbl/124 ft3/106 sks of Dowell Class 'G' at 15.8 ppg and 1.17 I cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Maximum anticipated BHP: 3300 psi @ 8800' TVDss - Zone 2 Maximum surface pressure: 2420 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned BOP test pressure: · Planned completion fluid: 3500 psi 8.6 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S DS 6 is a designated H2S drill site with measured levels over 100 ppm. Operating Procedures for H2S precautions should be followed at all times. Standard DRILLING CLOSE APPROACH: All wells pass close approach guidelines. DS 6-24A Permit to Drill INTERMEDIATE SECTION: · The original well was drilled with 9.9 ppg mud from the West Sak to the top of the Sag River without any noted hole problems. · The DS6-24A well path will drill approximately 220' of HRZ and 550' of Kingak shale. Follow all established drilling and connection practices for mechanically sensitive shales. · Tight hole conditions and stuck pipe have not been reported on DS 6 wells. · Shallow gas has been an issue on only 3 wells (all to the NE) in the Put River formation. There is no Put River in this well; shallow gas is not expected. · The kick tolerance for the 8-1/2" open hole section would be an infinite volume assuming an influx from the Sag River interval at -9,172' MD. This is a worst case scenario based on a 9.0 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the surface casing shoe, and 10.0 ppg mud in the hole. PRODUCTION SECTION: · DS-6 is an H2S pad. Review and follow all applicable H2S procedures. · There are no planned fault crossings in the reservoir section. Lost circulation has been an issue on DS-6 only when faults are encountered. · The kick tolerance for the 7" shoe would be an infinite influx (annular volume) assuming an influx at section TD of 9,942' MD. This is a worst case scenario based on a 7.5 ppg pore pressure, a minimum fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.3 ppg mud in the hole. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. SUMMARY SIDETRACK PROCEDURES Pre-Rig Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. RU slickline and pull the DB plug in the tailpipe at 8,745' MD. 2. RIH with CTU and perform a cement P&A using 15.8 ppg class 'G' cement with adequate cement volume to fill the 7" liner to 9,300' MD or 160' above the uppermost perforation. A minimum of 100' above the top perforation is required for AOGCC regulations. More cement may be pumped provided the TOC is below 8600' MD. Attempt to squeeze 5 bbls to the perforations. 3. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. 4. Liquid pack the 9-5/8" x 5-1/2" annulus to surface. Test the integrity of the cement plug and 9-5/8" casing by pressure testing both the tubing and 9-5/8" annulus to 3000 psi for 30 minutes (tubing has a leak verified at 7,950' MD).: This step should be done prior to the tubing cut to allow additional trouble-shooting if either the cement plug or 9-5/8" casing is leaking. 5. RU E-line. Cut the 5 %" L-80 tubing at approximately 8,250' MD. NOTE: The type of cutter to be used is at the discretion of the Wells Group. This cut will not be fished, however avoid cutting a tubing collar. 6. Displace the well to clean sea water by circulating down tubing through the tubing cut (and leak point). 4 i! 2 9 2000 DS 6-24A Permit to Drill o Test the FMC GEN 3 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. On both the tubing hanger and 9 5/8" casing head, completely back out and check each lock down screw for breakage (check one at a time). Notify the ODE (Phil Smith 564-4987) immediately concerning any problems with backing out the lock down screws or other potential well head problems. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 9. Remove the well house and flow lines. If necessary, level the pad. Please provide total well preparation cost on the hand over form. Rig Operations: 1. MIRU Nabors 7ES. 2. Pull BPV, circulate out freeze protection and displace well to sea water. Set TVVC and test. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull and lay down 5-1/2" tubing from E-line cut at -8,250 MD. Replace 9-5/8" pack off as required by hanging tubing off below storm packer after pulling the SSSV. 5. RU E-line and make GR/JB run to top of tubing cut. Set BP on E-line at -8,175'MD (set as needed to avoid cutting casing collar). Pressure test the 9 5/8" casing to 3000 psi. 6. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock, with gyro (vertical hole) as desired and set on BP. Mill window in 9-5/8" casing at -8,142' MD. POOH. 7. Kick-off and drill 8 %" hole from 8,157' to 9,172' at the top of the Sag River formation. Run MWD/GR. No other logs are planned for this interval. 8. Run and cement a 7" 26# L-80 intermediate drilling liner. 9. Make up and RIH with a 6-1/8" directional assembly to the landing collar. 10. Test the 9-5/8" casing and 7" liner from the landing collar to surface to 3000 psi for 30 minutes. 11. Drill out 6 1/8" hole from 9,172' to TD of 9,942' at the base of Zone 1. Run MWD/GR only. 12. RU E-line and log PEX + BHC Sonic through the entire open-hole. RD E-line. 13. Run and cement a 4 %", 12.6# L-80 IBT-Mod solid production liner throughout the 6-1/8" well bore. 14. Displace well to clean sea water above liner top. 15. POOH LD DP. 16. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. 17. Run 4-1/2", 12.6# L-80 IBT-Mod completion tying into the 4-1/2" liner top. 18. Set packer @ -8960' MD and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 19. Set BPV, nipple down the BOPE. Nipple up and test the tree to 5000 psi. 20. Freeze protect the well to -2100' and secure well. 21. Rig down and move off. Estimated Pre-rig Start Date: Estimated Spud Date: Phil Smith Operations Drilling Engineer 564-4897 07/03/00 07/08/O0 TREE: 4-1/2"-5M L-80 WELLHEAD: FMC - 5M Gen 3 6-;,4A Proposed Co npletion GL Elevation = 37.1 Nabors 7ES RKB = 67.1' 13 3/8", 72 #/ft, M N-80 2496' Liner Top at I +/-8000' I 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' 4-1/2" 12.6# L-80, IBT Mod Tubing 4-1/2" x 1-1/2" (lowermost -- 1") Camco 'MMG' Gas Lift Mandrels with handling pups installed above and below. GAS LIFT MANDRELS IVD Size Valve Type 1 ' 1-1/2" RP Shear 2 ' 1-1/2" DV 3 ' 1-1/2" DV 4 ' 1" DV (or lit above packer) BAKER 9 5/8" x 7" ZXP Liner Top Packer 'Hydraulic Liner Hanger Window Milled from Whipstock Top of Window at +/- 8142' MD Bridge Plug set at +/-8175' MD TOC at +~-9300' MD Top Perforation at +~-9460' MD 7"x 4 1/2" Baker'S' Packer /2" 'X' Landing Nipple, 3.813" ID 4-1/2" Liner top packer and hanger 7" 26#/ft L-80 BTCM 19020' I 19,172' I PRUDHOE BAY UNIT WELL: 6-24A APl #: 50-029-20822-01 4-1/2" 12.6 #/ft, L-80, IBT-M 19,942'I Date Revised by Comments 06~29~00 PGS Proposed completion ARCO Alas ka, I nc. ~ (2133-2134, 0D:5.500) PBR (8647-8648, 00:5.500) PKR (8662-8663, OD:9.625) Tubing-PC (O-8674, 0D:5.500, ID:4,892) Tubing-PC (8674-8766, 0D:4.500, ID:3,958) SOSUB (8765-8766, 00:4.500) Perf (9460-9466) Pad (9462-9466) Pad (9476-9534) PRB 06-24 06-24 APl: 1500292082200 SSSV Type: ~ Annular Fluid: IDiesel/9.6 NaCI I Reference Log: IBHCS Last Tag: I Last Tag Date: J Well Type: JPRC;D' Orig Completion: 11 Last W/O: J11/4:82 Ref Log Date:Ij10/317.~.2 Max Ho,e Ang.~e_:: J975! 128. deg@ 5800 ,,, Casing String - SURFACE Size I Top I Bottom 13.375 0 2496 Casing String - PRODUCTION Size J Top I Bottom 9.625 0 9032 Casing Strin9 - LINER Size I Top I Bottom 7.000 8722 9741 Tubin(I Strin~l - TUBING 5.500 8674 4,500 ~ 8674 8766 Angle @ TS: J 14 deg @ 9141 An~le ~ TD: ~14 deg ~ 9751 Rev Reason: )Set DB Plug by Last' Ul:x:J~ate: ll 1/6/99 TyD "::I Wt IGrade I Thread 2496 I 72.00 I L-80 I TVD :i:I ..Wt IGrade J Thread 8541...i 47.00 I ,-8o ..I ,.. TvD I Wt IGrade I Thread 9229";I 29.00 I L-~o I TVE'"'I wt IGrade I Thread 8194 I 17.00 I L-80 I 8283 I .!2.~0I N-80 I Perforations Summary "., Interval TVD I Zo.e JStatuslFeetlSPFj D~te| Type I Comment 9460-9466 8956-8962 IZONE2 ! C I 61 ,0~27'!/95Jsqz I 9476-9516 8972-90111ZONE2 I I 401 0~2.::il/951 I 9516-9534 9011-9028 I ZONE2 / O I 181 6J472~/961RPERFI 9556-9569 9050-9062 1ZONE2 / o I 131 4J12~6/95JAPERFI 9569- 9575 9062-~068 IZONE 2/ I 61 o~z,: i/Dq . I Stimulations & Treatments I Interval I Date I Type I Comment 9460 - 95751 12/11/95 ISQZ Gas Lift Mandrels/Valves . StnI MD I'rVD I Man I Man '1 V Mfr I VTyPe I VOD ILatchlPort( TROI Date / Vlv I I IMfr IType I I I ! I I IRun F°mment 1I 28771 28761 cA I MM~G I CA I RD I 1.5IRK 10.2501 019/28/99 / 2149011 47451CA I MM~GI CA I RD 11.5 IRK 10.0001 0i Ul/60 / 31~131 6o081 CA I MM~G I CA I RD 11.5 IRK 10.0001 01 1/1/60 / 4172881 6~851 CA J MMIG J CA J RD J 1.5 IRKio.oooi' 011/1/6o/ "' 5 j 7832j 739oI CA I MMIG I CA I RD J 1.5 IRKio.oool' dl9/28/99 / 6I 79091 74621 CA [ MM~G [ CA I RD I 1.5 IRK 10.0001 01 9/28/99 / 7182351 7771]CA I MU~GI CA I R~' I 1.~IRK 10.0001 0i 1/1/60 / 8183141 7847JCA I MMIG I CA I RD I 1.5IRK 10.0001 01 1/1/60 / 9185061 6o311CA I MMIG I CA I Rg '1 1.5 iRK 10.0001 01 1/1/60 / 101 85851 81081 CA I MMIG I CA IRKED J 1.5 IRKP 10.0001 0! 1/1/60 / Other (plugs, equip., etc.) - JEWELRY Depth ITVDI Type Description 2133~ 21331 SSSVNIP 5-1/2`' Camco BAL-O SSSV Nipple 8647~ 81671 PBR 5-1/2`' Baker PBR Assembly 8662J 8182J PKR )-5/8" x 5-1/2" Baker SAB Packer 86._~1~.t___ xo ,Cross--l/2" ( 874~2J PLUG~_~.._.~DB Plug 11/6/~- ~/ ~87"~0 J NiP 4-1/2" C a m co---~-~' D J~--~'~l'i~ ~Je .... ' 87651 82821 SOSUB 4-1/2'' Baker Shearout Sub 8766~ 82831 TTL 4-1/2'' Tubing Tail JID J 0,000 J 0.000 J 0,000 J 0,000 J 3.813 J 0.000 I o.ooo Depth Annotations ~ DePthI Comment 8753J8753' MIN ID = 3.813" (4-1/2" Camco DB-6 Nipple) Safety Notes Date I Note 10/15/99 ~Tubing Leak Logged General Notes Date INote 11/5/82 JTTL ELM (~ 8762: ELM Tubing Tail (Logged 04130/83) Daterun: 1982-11-05 11/6/99 JFound rocks in plug bod~; Shared Services Drilling 06-24A W.n 05 7800 8100 8400 8700 m 9000 II Current Well Properties Well: 06 Z4A WP Ref. Gtoba~ Coe~dloat~: 59 1415.88 Ret Geographical Co~d~ates: 70' 14' 41.( Ref. Sbucture Reference: 49.69 S, 1 RKB ElevaSo~: 67.12fl abo~ 67 121t abo U~s: Feet North Reference: True North 06-24A WPS 5941415.88 N, 685942.02 E 494.69 S, 1253.73 E 70° 14' 41.6528" N, 148' 29' 52.7221" W 67.12~ above Mean ~ea level 67.12~ above Structure I~ence 2200 - Exit @ 10.000°/100ft, 343.000° TF · 8157.00ft MD, 7696.55ft TVD Dir @ 10.000°/100ft: 8197.00ft MD, 7734.32ft TVD Dir' 8346.64ft MD, 7865.61ft TVD HRZ- 7907.12 TVD Kingak. 8087.12 TVD 7" Casing 9172.41 MD 8536.12 TVD .......... ' ~'h;,biik :'b~65. TSAD/Z4B - 2000 -- Z 1800 - I 2100 2400 Scale:linch: 300ff 4 1/2" Liner 9942.13 MD 9161.12 '~/D TZ2C- 8889.12 TVO 9057.12 2158.80 N~ 2189.92 TZ2A - 9037.12 1-VD i i i HOLT- 9047.12 TVD COWC - 9056.12 TVD TZ1 - 9109.12 TVD BSAD - 9161.12 TVD I I 2700 3000 Section Azimuth: 308.412° (True North) Vertical Section Scale: linch = 200ft -2200 I Eastings -2000 -1800 -1600 I I I 4 1/2" Liner ~MD 9161.12 TVD 06-24 TARGET TVD 2138.80 N, 2189.92 2000 7" Casing 9172.41 MD 8536.12 TVD End Dir' 8346.64ft MD, 7865.61ft TVD Begin Dir 10.000°/100ft: 8197.00ft MD 7734.32ft ST Exit @ 10.000~100ft, 343.000° TF: 8157.00ft'MD, 7696.55ft TVD 22OO 2O00 1800 1600 '- .. I -2200 Scale: linch = 200ft I I 1 -2000 -1800 -1600 Eastings Reference is True North Proposal Data for 06-24A WP05 Vertical Origin: Well Horizontal Odgin:Well Measurement Units: ft North Reference: True North Dogleg sevedty: Degrees per 100ff Vertical Section Azimuth: 308.412° Vertical Section Description: Well Vertical Section Odgin: 0.00 N,0.00 E Measured Incl. Azlm. Vertical Northlngs Easflngs VerticalDogleg Depth Depth Section Rate 8157.00 17.270318.629 7696.55 1563.12 N I464.66 W 2118.84 8197.00 21.127315.385 7734.32 1572.71 N 1473.66 W 2131.85 10.000 8346.64 35.710308.105 7865.61 1619.12 N 1527.27 W 2202.69 10.000 9789.42 35.710308.105 9037.12 2138.80 N 2189.92 W 3044.80 0.000 9801.74 35.710308.105 9047.12 2143.23 N 2195.58 W 3051.99 0.000 9942.13 35.710308.105 9161.12 2193.80 N 2260.06 W 3133.94 0.000 Single Well Target Data for 06-24A WPS Measurement Units: Coordinate Target Point TVDssTVDrkb Northings Eastings ASPY ASP X Name Type 06-24 TARGET En~x'yPoint 8970.00 9037.12 2138.80N 2189.92 W 5943500.00N 683700.00 E North Slope Alaska Alaska State Plane 4 ~eu ~o~ ~$ o~, o~-~4~ w~$ ~-~4~ w~s-o ~ ~ Revised: 2g June, 2~~1~ ~ PROPOSA~EPORT ~~~ooo A~~ , . Su~ace Coordinates: 594f4~~ 685942.02 E (70° f4 4f.6528 N, ~ing: 67, ~2~ above Mean Sea Level s~~-s~ !~ R till.-- L_il N G 5ERvi'r-ES 148° 29' 52.7221" W) ~-~Jt~ Proposal Ref: pro9841 Sperry-Sun Drilling Services Proposal Report for 06-24A WPS - 06-24A WP05 Revised: 29 June, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 8157.00 17.270 318.629 7629.43 8197.00 21.127 315.385 7667.20 8200.00 21.415 315.150 7670.00 8300.00 31.129 309.699 7759.57 8346.64 35.710 308.105 7798.49 8397.76 35.710 308.105 7840.00 8400.00 35.710 308.105 7841.82 8500.00 35.710 308.105 7923.02 8600.00 35.710 308.105 8004.21 8619.44 35.710 308.105 8020.00 8700.00 35.710 308.105 8085.41 8800.00 35.710 308.105 8166.61 8900.00 35.710 308.105 8247.81 9000.00 35.710 308.105 8329.01 9100.00 35.710 308.105 8410.20 9172.41 35.710 308.105 8469.00 9200.00 35.710 308.105 8491.40 9208.13 35.710 308.105 8498.00 9300.00 35.710 308.105 8572.60 9300.49 35.710 308.105 8573.00 9400.00 35.710 308.105 8653.80 9500.00 35.710 308.105 8735.00 9517.25 35.710 308.105 8749.00 9532.02 35.710 308.105 8761.00 9600.00 35.710 308.105 8816.19 Vertical Local Coordinates Global Coordinates Depth Nothings Eastings Nothings Eastings 7696,55 1563,12 N 1464.66W 59429~ 684439.24 E 5942981.22 ~ 5942996.83 N 7734.32 1572.71 N 1473.66W 7737.12 1573.48 N 1474.42W 7826.69 1603.01 N 1507.277V~__ 7865.61 1619.12 N 1527.27"1W~ 7907.12 1637.53 N ~[llili~/ 7908.94 1638.34 N 7990.14 1674.36 N 8071.33 1710.3~N 8087.12 171~~ 1652.56 W 8152.53 1~11~1~.4~41H 1689.56 W 8233.73 N 1735.49 W 8314.93 N 1781.42 W 8396.13 ~ ]1854.45 N 1827.35 W 8477.32 ~ 1890.47 N 1873.28 W 8536.12 1916.56 N 1906.53W 8558.52 1926.49 N 1919.21W 8565.12 1929.42 N 1922.94W 8639.72 1962.51 N 1965.14W 8640.12 1962.69 N 1965.36W 8720.92 1998.53 N 2011.06W 8802.12 2034.55 N 2056.99W 8816.12 2040.76 N 2064.91W 8828.12 2046.09 N 2071.70W 8883.31 2070.57 N 2102.92W 684430.01E 684429.23 E 684395.66 E 684375.27 E 5943014.66 N 684351.35 E 5943015.44 N 684350.30 E 5943050.31N 684303.50 E 5943085.19 N 684256.69 E 5943091.97 N 684247.59 E 5943120.06 N 684209.89 E 5943154.94 N 684163.09 E 5943189.81 N 684116.28 E 5943224.69 N 684069.48 E 5943259.56 N 684022.67 E 5943284.82 N 683988.78 E 5943294.44 N 683975.87 E 5943297.27 N 683972.07 E 5943329.31 N 683929.07 E 5943329.49 N 683928.84 E 5943364.19 N 683882.26 E 5943399.06 N 683835.46 E 5943405.08 N 683827.39 E 5943410.23 N 683820.47 E 5943433.94 N 683788.66 E Dogleg Rate (°/lOOft) 10.000 10.000 10.000 10.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_EOA DS 06 Vertical Section (ft) 2118.84 2131.85 2132.93 2177.01 2202.69 2232.53 2233.83 2292.20 2350.57 2361.91 2408.93 2467.30 2525.67 2584.04 2642.41 2684.67 2700.77 2705.52 2759.14 2759.43 2817.51 2875.88 2885.94 2894.57 2934.24 Comment ST Exit(~.10.000°/100ff, 343.000°-rF:8157.00ff MD, 7696.55ff TVD Be~in Dir~.10.000°/100ff: 8197.00ffrvTD, 7734.32ff TVD End Dir' 8346.64ft MD, 7865.61ff TVD HRZ Kingak 7" Casing TSGR Shublik TSAD/Z4 B Z4A TZ3 Continued... 29 June, 2000 - 11:44 - 2 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for 06-24A WPS - 06-24A WP05 Revised: 29 June, 2000 North Slope Alaska Measured Sub-Sea Ve~ical Local Coordinates Depth Incl. Azim. Depth Depth Nothings Eastings Nothings (fi) (~) (~) (~) (~) (~) 9607.15 35.710 308.105 8822.00 8889.12 2073.15 N 2106.21W 9647.79 35,710 308,105 8855.00 8922.12 2087.78 N 2124.87W 594: 9700.00 35.710 308.105 8897.39 8964.51 2106.59 N 2148.85W N 9789.42 35.710 308.105 8970.00 9037.12 2138.80 N 2189.92W N 9800.00 35.710 308,105 8978.59 9045.71 2142.61N 2194.78 ~3503.69 N 9801.74 35.710 308,105 8980.00 9047.12 2143.23 N 2195 5943504.30 N 9812.82 35,710 308.105 8989.00 9056.12 2147.23 N 5943508.16 N 9878.09 35.710 308.105 9042.00 9109.12 2170.74 N 5943530.92 N 9900.00 35.710 308.105 9059.79 9126.91 2178.63 N 5943538.57 N 9942.13 35.710 308.105 9094.00 9161.12 2193.80 N W 5943553.26 N data is in feet unless otherwise stated. Directions and coordi~~re relative to True North. Vertical depths are relative to Well. Northings and Eastin~~bel~ive to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 308.412° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9942.13ft., The Bottom Hole Displacement is 3149.71ft., in the Direction of 314.148° (True). Global Coordinates Eastings (fi) 683785.31E 683766.29 E 683741.85 E 683700.00 E 683695.05 E 683694.24 E 683689.05 E 683658.50 E 683648.24E 683628.52 E Dogleg Rate (°IIOOR) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_EOA DS 06 Ve~ical Section (fi) 2938.42 2962.14 2992.61 3044.80 3050.98 3051.99 3058.46 3096.56 3109.35 3133.94 Comment TZ2C CGOC TZ2A 06-24 TARGET, Geological HO/T COWC TZ1 Total Depth: 9942.13ft MD, 9161.12ft TVD 4 1/2" Liner BSAD Continued... 29 June, 2000 - 11:44 - 3 - DrillQuest 1.05.04c ...... STATE OF ALASKA -- ALASK. _)IL AND GAS CONSERVATION COb. SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: I~! Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 817' NSL, 1033' WEL, SEC. 02, T10N, R14E, UM At top of productive interval 2586' NSL, 2644' WEL, SEC. 02, T10N, R14E, UM At effective depth 2672' NSL, 2695' WEL, SEC. 02, T10N, R14E, UM At total depth 2711' NSL, 2719' WEL, SEC. 02, T10N, R14E, UM 5: Type of well: [] Development I-I Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB = 74' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 06-24 9. Permit Number 182-147 10. APl Number 50- 029-20822-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition Summary Total depth: measured Effective depth: 9751 feet true vertical 9239 feet measured 9557 feet true vertical 9051 feet Plugs (measured) Junk (measured) Fill tagged at 9557' (04/96) ORIGINAL Casing Length Size Cemented Structural Conductor 79' 20" 1930# Poleset Surface 2422' 13-3/8" 2200 sx Fondu, 400 sx Permafrost 'C' Intermediate Production 8958' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' Liner 1019' 7" 305 sx Class 'G' MD 79' 2496' 9032' 8722' - 9741' RECEIVED Perforation depth: measured 9516' - 9534', 9556' - 9569' JUN 2 9 2000 true vertical 9010' - 9028', 9050' - 9062' Alaska 0it & Gas Cons. Com~ An omge Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 8674'; 4-1/2", 12.6#, N-80 to 8766' Packers and SSSV (type and measured depth) Baker SAB packer at 8662'; 5-1/2" Camco BaI-O SSSV at 2133' TVD 79' 2496' 8541' 8240' - 9229' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation July 3, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Numbec Phil Smith, 564-4897 15. [] Detailed Operations Program [] BOP Sketch Status of well classifications as: []Oil [] Gas [] Suspended Service Prepared By Name/Nurnben Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is ~ect to the best of my knowledge Signed Dan Stone ~'~....~.~,.~ Title Senior Drilling Engineer Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate I DATE J CHECK NO. -- J00169427 H1 6942.7 ....... VENDOR t~L,~51~5 1/~ ! 1U DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ~52&00 CKOS~&OOC 100. O0 100. O0 HANDLING INST' s/h ter~ie x E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOV~ FIRST'NATIoNAL-BANK OF ASHEAND No. H 1694;2.7 :{'"'?i ': ;":' :AN:'A~FI~;IATE:OP ':::ii::i!i'' :'i:... CONSOL]DATED COMMERCIAL:ACCOUNT .. NATION~'CI~:B~K ';:';':: :. CEEvEL~No, OHIO ': ..~ '..::~ .... '" :' ";:- ' ';::..;'56-389. 412 CO 1 &~427 ~AY ON£ :"::ku~6~ED :~ii&: 06~! l***************************************** us:: DOLLAR :.il;;i{.- ' "i~i,' ::'? ?'.:': "::::?? ¥ DATE i''~' ;i ' "i" "' ' ' AMOUNT l' 05/26/0011 $100' O0 ! · i :i !ii .!:i ':' ":i' :. .:! NOT'!VALID AFTER 120 DAYS ':i.'.: 'i' . :.:: ,:.. :}. .::i:'', · .! ?.' :"::i'ii'iiii: i.~::.,~'''~ ~.¢ ]::::i:!i!.'.:':' I ANCHORAQE AK 99501 IIm&RqL,2?,' m=C) h&203m/3qSm: OO/3L, h~.qll' WELL PERMIT CHECKLIST COMPANY /~/~, '//1',~-,~ WELL NAME b~-~_.ST/.4 PROGRAM: exp FIELD & POOL ~~/~ INIT CLASS ~~ ~/~ GEOL AREA ADMINISTRATION _~~ DATE 12. ENGINEERING 1. Permit fee attached.. ..................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. Y~N Y N Y N Y N _~~ DATE GEOLOGY APPR DAT.~ dev ,,'" redrll ~ serv wellbore seg UN T# ann. disposal para req ON/OFF SHORE 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~(~ N 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to -'~r~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N ..... ~ , , 29. Is presence of H2S gas probable ................. U 30. Permit can be issued w/o hydrogen sulfide measures ..... , ~.-~-,~,-~xN ~% ~ ~, ~.~ % ,z.c.~,,,,h\~,__ ~ %e,,.t,~?_:,~-% ~ , 31. Data presented on potential overpressure zones ....... /,~,,,~ 32. Seismic analysis of shallow gas zones ............. A//~!?~ Y N 33. Seabed condition survey (if off-shore) ............. /t/,W Y N 34. Contact name/phone for weekly progress reports [exploratory only~ N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: O Z O ITl Z --I -1- c:\msoffice\wordian\diana\checklist (rev. 02/17/00) 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. :/00 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Jun 29 14:37:56 2001 Reel Header Service name ............. LISTPE Date ..................... 01/06/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/06/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 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: WELL CASING RECORD MWD RUN 2 AK-MM-00095 J. SACK J. RALL / D. DS 6-24A 500292082201 Phillips Alaska Inc. Sperry-Sun Drilling Services 29-JUN-01 MWD RUN 3 AK-MM-00095 J. SACK J. RALL / D. 2 I0N 14E 817 1033 .00 71.00 37.10 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8137.0 6.125 7.000 9170.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET THE WHIPSTOCK, AND NO DATA ARE PRESENTED ON THIS PLOT. 3. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 3 WAS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 {EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHNOOR, GEOQUEST, TO RAY OAKLEY, SSDS, DATED 6/27/01, QUOTING A DISCUSSION WITH COLE ABEL, BP EXPLORATION{ALASKA). 6. MWD RUNS 1, 2, & 3 REPRESENT WELL DS 6-24A WITH API%:50-029-20822-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9970'MD / 9176.62'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY {DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLDSLIDE = SLIDE INTERVALS ADJUSTED FOR THE SLD SENSOR-TO-BIT DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.3 PPG MUD SALINITY: 800-900 PPM CHLORIDES FORMATION WATER SALINITY: 11,500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8139.5 ROP 8167.5 NCNT 9098.5 FCNT 9099.0 NPHI 9099.0 PEF 9113.5 DRHO 9134.5 RHOB 9134.5 FET 9142.0 RPD 9142.0 RPM 9142.0 RPS 9142.0 RPX 9142.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: STOP DEPTH 9933.0 9970.0 9895.5 9896.0 9895.5 9911 5 9911 5 9911 5 9940 0 9940 0 9940 0 9940 0 9940.0 EQUIVALENT UNSHIFTED DEPTH - BIT RUN NO MERGE TOP MERGE BASE 2 8139.5 9171.5 3 9171.5 9970.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR ROP RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 MWD API 4 1 68 4 2 MWD FT/H 4 1 68 8 3 MWD OHMM 4 1 68 12 4 MWD OHMM 4 1 68 16 5 MWD OHMM 4 1 68 20 6 MWD OHMM 4 1 68 24 7 MWD HOUR 4 1 68 28 8 MWD PU-S 4 1 68 32 9 MWD CNTS 4 1 68 36 10 MWD CNTS 4 1 68 40 11 MWD G/CM 4 1 68 44 12 MWD G/CM 4 1 68 48 13 MWD BARN 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 8139.5 9970 9054.75 3662 GR MWD API 12.01 513.14 115.657 3588 ROP MWD FT/H 1 189.89 58.6643 3606 R?X MWD OHMM 0.71 1144.88 30.3339 1597 RPS MWD OHMM 0.77 1973.85 38.1123 1597 RPM MWD OHMM 0.85 2000 84.7441 1597 RPD MWD OHMM 0.81 2000 78.7771 1597 FET MWD HOUR 0.24 44.28 2.46499 1597 NPHI MWD PU-S 0.93 52.74 15.5408 1594 FCNT MWD CNTS 121.35 3107.71 769.39 1595 NCNT MWD CNTS 14301.7 49607.7 28797.3 1595 RHOB MWD G/CM 1.87 2.87 2.36211 1555 DRHO MWD G/CM -0.59 0.36 0.0367846 1555 PEF MWD BARN 1.1t 14.25 2.83096 1597 First Reading 8139.5 8139.5 8167.5 9142 9142 9142 9142 9142 9099 9099 9098.5 9134.5 9134.5 9113.5 Last Reading 9970 9933 9970 9940 9940 9940 9940 9940 9895.5 9896 9895.5 9911.5 9911.5 9911.5 First Reading For Entire File .......... 8139.5 Last Reading For Entire File ........... 9970 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/29 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 ....... 01/06/29 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 NUHBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8139.5 ROP 8167.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9143.5 9171.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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: HUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 12-JUL-O0 Insite 65.4099960327148 Memory 9172.0 17.5 36.8 TOOL NUMBER PB01562HG6 8.500 Water Based 10.50 41.0 9.2 1000 3.4 .000 .000 .000 .000 .0 152.6 .0 .0 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 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 MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 8139.5 9171.5 8655.5 2065 GR MWD020 API 65.8 413.41 164.651 2009 ROP MWD020 FT/H 1 137.05 47.2459 2009 First Reading 8139.5 8139.5 8167.5 Last Reading 9171.5 9143.5 9171.5 First Reading For Entire File .......... 8139.5 Last Reading For Entire File ........... 9171.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/29 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 ....... 01/06/29 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT FCNT NPHI PEF DRHO RHOB FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9098.5 9099 0 9099 0 9113 5 9134 5 9134 5 9142 0 9142 0 9142 0 9142 0 9142 0 9144 0 9172 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION {DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9895.5 9896.0 9895.5 9911.5 9911.5 9911.5 9940.0 9940.0 9940.0 9940.0 9940.0 9933.0 9970.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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): 15-JUL-00 Insite 4.15 Memory 9970.0 33.8 40.8 TOOL NUMBER PBO1569NLF4 PBO1569NLF4 PBO1569NLF4 PBO1569NLF4 6.125 Water Based 8.30 37.0 9.9 85O 13.2 1.000 68.0 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 Depth Units ....................... Datum Specification Block sub-type...0 .390 2.500 2.400 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 183.0 68.0 68.0 Name Service Unit Min Max DEPT FT 9098.5 9970 GR MWD030 API 12.01 513.14 ROP MWD030 FT/H 2.65 189.89 RPX MWD030 OHMM 0.71 1144.88 RPS MWD030 OHMM 0.77 1973.85 RPM MWD030 OHMM 0.85 2000 RPD MWD030 OHMM 0.81 2000 FET MWD030 HOUR 0.24 44.28 NPHI MWD030 PU-S 0.93 52.74 FCNT MWD030 CNTS 121.35 3107.71 NCNT MWD030 CNTS 14301.7 49607.7 RHOB MWD030 G/CM 1.87 2.87 DRHO MWD030 G/CM -0.59 0.36 PEF MWD030 BARN 1.11 14.25 Mean 9534.25 53 3208 73 0285 30 3339 38 1123 84 6224 78 7771 2.46499 15.5408 769.39 28797.3 2.36211 0.0367846 2.83096 Nsam 1744 1579 1597 1597 1597 1597 1597 1597 1594 1595 1595 1555 1555 1597 First Reading 9098.5 9144 9172 9142 9142 9142 9142 9142 9099 9099 9098.5 9134.5 9134.5 9113.5 Last Reading 9970 9933 9970 9940 9940 9940 9940 9940 9895.5 9896 9895.5 9911.5 9911.5 9911.5 First Reading For Entire File .......... 9098.5 Last Reading For Entire File ........... 9970 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... t.0.0 Date of Generation ....... 01/06/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/06/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Ree 1 Trailer Service name ............. LISTPE Date ..................... 01/06/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
