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Home My WebLink About204-058 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 Ld- - 0 5~ Well History File Identifier Organizing (done) D Two-sided III" 111111" 11111I D Rescan Needed III II 111111 II 111111 RESCAN ~Ior Items: D Greyscale Items: DIGITAL DATA ~iskettes, No. D Other, No/Type: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Date ~/l(;ID~ Date~IIDlo~ ~ X 30 = (p eJ o ~ D Other:: BY: ~ 151 lLl1~ Project Proofing 111111111111111111I BY: LMãriã) 151 mP BY: Date: + -LL- = TOTAL PAGESJj (Count does not include cover sheet) 151 Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: 7 ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES Date: B /10/ ofo If NO in stage 1, page(s) discrepancies were found: 1111111111111111111 p NO Stage 1 YES 151 V\1 r NO BY: ~ BY: Maria Date: 151 1111111111 11111111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 1111I BY: Maria Date: 151 Comments about this file: Quality Checked III "111111I1111111 10/6/2005 Well History File Cover Page.doc RECEIVED • • SEP 252012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ OiI ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 20AAC 25 105 20AAC 25 110 I01 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. \. 9/5/2012 204 - 058 312 - 176 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 6/25/2004 50 029 - 20816 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 7/1/2004 PBU C -24A 1425' FNL, 1030' FEL, SEC. 19, T11N, R14E, UM 8 KB (ft above MSL): 65.72' 15. Field / Pool(s): Top of Productive Horizon: 4364' FNL, 3995' FEL, SEC. 19, T11N, R14E, UM GL (ft above MSL): 37.22' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 3319' FNL, 4106' FEL, SEC. 19, T11N, R14E, UM 10175' 8846' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 664351 y - 5959793 Zone ASP4 11275' 9019' ADL 028305 TPI: x 661462 y 5956792 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 661325 Y - 5957834 Zone ASP4 None 18. Directional Surve : 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): Y ❑ Yes ► No A 1900' (Approx.) electronic and printed information per 20 AAC 25.050) N/A ft MSL ( pp ) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIR / GR, DIR / GR / RES / DEN / NEU / ABI 9310' 8025' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface_ 110' 36" 8 cu yds Concrete 13 - 3/8" 72# L -80 70' 2741' 70' 2692' 17-1/2" 3767 cu ft Arcticset I I 9 -5/8" 47# L -80 Surface 9310' Surface 8025' 12 -1/4" 1453 cu ft Class 'G' & 1117 cu ft AS I 7" 26# L -80 _ 27' 9756' 27' 8443' 8 -1/2" 191 cu ft Class 'G', 1561 cu ft 'G' 4 -1/2" 12.6# L -80 9584' 11274' 8274' 9019' 6 -1/8" 247 cu ft 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 / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6 #, L -80 9592' 9535' / 8228' MD TVD MD TVD fl � 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. scANNED H U DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10175' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ►_ No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize 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 R' ID MS SEP 2 6 2Q12 .:(//77 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Original Only+ 2 ., g V 29. GEOLOGIC MARKERS ( List all formations a arkers encountered): 30. FORMATION TESTS NAME TVD Well Tested Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9760' 8447' None Shublik A 9788' 8474' Shublik B 9820' 8506' Shublik C 9843' 8529' Sadlerochit 9868' 8554' Zone 3 / Top CGL 10052' 8735' Zone 2A / Base CGL 10150' 8825' Zone 1B 10540' 9021' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that th, for oing is - -) c rrect to the best of my knowledge. Signed: Joe Lastufk Y , Title: Drilling Technologist Date: 11I PBU C - 24 204 - 058 312 -176 Prepared By Name/Number: Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Ron Philips, 564 -5913 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only • C -24A, Well History (Pre Rig Sidetrack) Date Summary 06/07/12 INITIAL T /I /O = 2300/0/0 PSI. RIGGED UP ELINE UNIT & TOOLS TO RUN WELLTEC MILL. 06/08/12 RAN WELLTEC MILLING TOOL & MILLED XN A 9580' MD TO 3.805" OD. LAYED DOWN EQUIPMENT FOR THE DAY & WILL RETURN TONIGHT TO SET WHIPSTOCK. 06/12/12 T /I /O= 2300/0/0. Load and kill. (CTD Prep) Pump 5 bbl neat spear followed by 268 bbls SW and 60 bbl dsl freeze protect to kill well for E -Line rig down (swab closewd wing closed ssv closed master open annulus valves open to gauges) FWHP= 100/80/ -1. 06/12/12 CURRENTLY RUNNING IN HOLE W/ 4.5" WHIPSTOCK.` fr' k-b 06/13/12 UNABLE TO ORIENT WS WHILE LOGGING UP. ABLE TO ORIENT WS WHILE LOGGING DOWN. S DECISION MADENERIFIED APE TO CORRELATE WHILE RIH AND SET WS. SET 4/12" BAKER �` PKR/WHIPSTOCK - TOWS AT 10,175' - 269 DEG ROHS. FINAL T /I /O = 0/0/0 PSI. FINAL VALVE W POSITIONS: SWAB /SSV/WING = CLOSED, MASTERNALVES TO CASING = OPEN. LRS TO PERFORM MIT ON LATER DATE. 06/15/12 T /I /0= 145/70/5 Temp =SI MIT -T to 2500psi (PASSED) ( CTD Prep) Pumped 2.5 bbls 40* diesel down TBG to reach test pressure. 1st 15 min lost 104 psi. 2nd 15 min lost 33 psi for a total loss of 137 psi in 30 min. Bled TP ( -1.5 bbls). Tags hung. DSO notified. Valve positions upon departure: SV WV SSV= closed. MV IA OA= open. FWHP's= 150/80/4. 06/16/12 T /I /O= 270/100/0, Conducted PJSM Rig up hoses and test manifold to tree cap Performed bleed off test on Master valve (fail), Open MV shut SSV Performed bleed off test on SSV (fail), Open SSV closed SV and performed a bleed off test, SV leaking by called grease crew to service tree, Retested valves and the MV & SSV still leaking by 160 Ibs in 2min, Performed LP 250 on SV Pass, HP 3500 Pass, Talked to well PE and tree will need to be changed out before rig work over. 06/22/12 T /I /O= 250/0/0 (Tree Change) Conducted PJSM upon arrival, verified tubing pressure 250 psi, closed SSV and SV to perform bleed off test (PASS).Remove tree cap and rig up CIW lubricator w/ 4" (H) TWC and running tool, pressure tested lubricator 250/3500 psi (PASS), set TWC #208 @117 ". Bled off pressure and rig down lubricator. Remove old 4" CIW tree and install new CIW 4" tree w/ blinded WV. Torque to spec (953 ft Ibs). Rienstaled lubricator w/ 4" (H) retrieving tool, pressure tested tree connections 250/5000 psi 5 min (PASS), pulled TWC #208 @117 ", rig down lubricator. Installed tree cap and PT 500 psi 5 min (PASS). 07/16/12 T /I /O= SSV /0 +/0 +, Temp =SI. PPPOT -T (PASS), pre CTD. PPPOT -T: Stung into test port (0+ psi), bled void to 0 psi. Functioned LDS (ET), all moved freely (1 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 08/23/12 T /I /O = 170/150Nac. Temp = SI. WHP's (CTD Prep). Flowline and wellhouse removed. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 23:30 hrs. 08/24/12 T /I /O = SSV /150NAC. Temp = SI. Bleed IAP & OAP to 0 psi (CTD prep). No AL. Integral installed on IA =not current. Well house and flowline removed. IA FL near surface. Bled IAP from 150 psi to 0 psi in 1.5 hrs. Monitored for 30 min. IAP remained at 0 psi. Job complete. Final WHPs = SSV /0/0. SV, WV, SSV, MV = C. IA, OA = 0. 12:00. 08/25/12 T /I /0= SSV /25Nac. Temp =SI. WHPs (CTD prep /post bleed). IAP increased 25 psi overnight, OAP unchanged. SV, WV, SSV, MV =C. IA &OA =OTG. NOVP. 1625. Page 1 of 2 • C -24A, Well History (Pre Rig Sidetrack) Date Summary 08/26/12 T /I /O = 170/45Nac. Temp = SI. Bleed IAP to 0 psi. (Pre CTD). No AL. Wellhouse and flowline removed. Integral flange installed on IA = inspection not current. IA FL near surface. Bled IAP from 45 psi to 0 psi in 25 minutes. During 30 minute monitor IAP and OAP unchanged. Job complete. Final WHP's = 170 /ONac. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 20:45 hrs. 08/28/12 T /I /O = 150/34Nac. Temp = SI. Bleed WHPs to 0 psi. (Pre CTD Screen). No AL. Wellhouse and flowline removed. Integral installed on IA = inspection not current. Tubing FL @ surface. IA FL near surface. Bled IAP from 34 psi to 0 psi in 10 minutes. FO opened MV. Bled tubing pressure from 150 psi to 0 psi in 40 min, multiple bleeds to allow gas to break out. During tubing bleed IAP increased to 5 psi, bled IAP from 5 psi to 0 psi in 5 min. Monitored for 30 min. Job complete. Final WHPs = 30 /2Nac. SV, WV, SSV = C. MV = 0. IA & OA = OTG. NOVP. 13:15 Hrs. 08/30/12 T /I /0 = 40 /30NAC. Temp = SI. Bleed WHPs to 0 psi (Pre CTD). No AL. Wellhouse and flowline removed. TBG FL @ surface, IA FL near surface. Bled TP from 40 psi to 0 psi in 5 min. Bled IAP from 30 psi to 0 psi in 15 min. Held open bleed on TBG and IA for 2 hrs. SI and monitored for 30 min. Job complete. Final WHPs = 0 +/0 +/VAC. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 04:30 hrs. 08/31/12 T /I /0 = 0 + /16NAC. Temp = SI. WHPs (Post Bleed). No AL. Wellhouse and flowline removed. IAP increased 16 psi overnight. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 01:00 hrs. 09/01/12 T /I /0 = SSV /32NAC. Temp = SI. Bleed WHPs to 0 psi (CTD Prep). No AL. Tree Scaffolding, wellhouse and flowline removed. IA FL near surface. Bled IAP from 32 psi to 0 psi in 10 min, held open bleed for 50 min. Monitored for 30 min, IAP unchanged. Final WHPs = SSV /O +NAC. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 21:00 hrs. Page 2 of 2 • • Common Well Name: C -24 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/3/2012 End Date: X3- 0124Y -C: (2,217,200.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/5/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °1747.296 "6 Long: 0148°40'08.689'W Active Datum: ORIG KELLY BUSHING @71.60ft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/3/2012 16:00 - 18:30 2.50 MOB P PRE PREP TO MOVE RIG OVER C-24. WSL HAS TO GOTO WELLS GROUP TO CONDUCT FACE -TO -FACE TO OBTAIN WELL HANDOVER FORMS. 24 -HR NOTICE OF INITIAL BOPE TEST GIVEN TO AOGCC AT 0830 -HRS ON 9/2/12. TIMING UPDATES HAVE BEEN PROVIDED EVERY 12 -HRS TO AOGCC REP BOB NOBLE. 18:30 - 19:15 0.75 MOB P PRE NIGHT WSL ON LOCATION. VERIFY PRESSURES ON OA, IA, TUBING TO BE 0 PSI. CLOSE BACK IN. HANDOVER ON LOCATION AT 1900 HRS. CONDUCT WSL HANDOVER AND CHANGEOUT 19:15 - 19:45 0.50 MOB P PRE PJSM ON MOVING RIG. ` DISCUSS POSITIONS, ■ "STOP". FUNCTION TEST ESD, ALL GOOD. POSITION PERSONNEL. 19:45 - 20:00 0.25 MOB P ® PRE MOVE RIG OVER C-24. RIG ACCEPT AT 2000 HRS. 20:00 - 23:00 3.00 MOB P PRE STAGE WELDING SHACK, SATELLITE CAMP, CUTTINGS BOX, TIGER TANK AND HARDLINE. PT HARDLINE. CONDUCT INSPECTION OF C -03, OBTAIN CLEARANCE FROM PAD OPERATOR AND SIGN OFF ON PERMIT FOR THAT WELL. CONDUCT LEAK TIGHT TEST TO VERIFY BARRIERS WITH 2 VALVES PER CRITERIA IN WELL PLAN TO REMOVE TREE CAP. 23:00 - 23:15 0.25 MOB P PRE PJSM ON REMOVING TREE CAP AND NU BOP. DISCUSS WORK AT HEIGHTS, NU PROCEDURE, DROPPED OBJECT PREVENTION, USE OF HAMMER WRENCH AND PERMITTING. 23:15 - 00:00 0.75 MOB P -_ PRE REMOVE TREE CAP. MOBILIZE BOP OVER TREE. 9/4/2012 00:00 - 00:45 0.75 MOB P -_ PRE MOBILIZE BOP OVER TREE. LINE UP FLANGE BOLTS. SET DOWN. 00:45 - 01:15 0.50 MOB P PRE CONDUCT RIG EVACUATION DRILL. GOOD CREW RESPONSE TIME OF LESS THAN 2 MINUTES IN PRIMARY MUSTER AREA. AAR ON EVAC. NO NOTED IMPROVEMENTS. DISCUSS WELL EXECUTION OF C-24B. REVIEW HIGH GOR RP. 01:15 - 03:15 2.00 BOPSUR P -_ PRE NU BOP. MOBILIZE REEL TRAILER NEXT TO RIG IN PREPARATION FOR LIFT. 03:15 - 03:30 0.25 MOB P PRE PJSM ON LIFTING REEL ON RIG WITH CH2MHILL, SLB, NORDIC CREWS, SITE CONTROL, AND WSL. DISCUSS POSITIONS, LIFTING DANGERS. 03:30 - 05:30 2.00 MOB P PRE LIFT REEL MULTIPLE TIMES IN ATTEMPT TO CALIBRATE NEWLY INSTALLED LOAD CELL METER IN REEL HOUSE. CANNOT GET IT CALIBRATED. LIFT REEL INTO TO PLACE AND SECURE WITH REEL DRIVE PINS. LOCK INTO PLACE WITH SECONDARY LOCKS. 05:30 - 06:00 0.50 MOB P PRE PREPARE REEL FOR OPERATIONS. RU WINCH WITH GRAPPLE TO PULL COIL ACROSS. Printed 9/18/2012 9:40:29AM ? e w r Common Well Name: C -24 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/3/2012 End Date: X3- 0124Y -C: (2,217,200.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/5/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °1747.296 "6 Long: 0148 °40'08.689 "W Active Datum: ORIG KELLY BUSHING @71.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 06:30 0.50 MOB P PRE PERFORM CREW CHANGE AND MAKE WALKAROUNDS. 06:30 - 09:30 3.00 MOB P PRE HOLD PJSM ON PULLING COIL ACROSS ROOF & STABBING IN INJECTOR. REVIEW ORDER OF OPERATIONS, POSITIONS OF PEOPLE, STORED ENERGY POTENTIALS WITH COIL, DROPPED OBJECTS POTENTIALS AND THE IMPORTANCE OF COMMUNICATION. INSTALL GRAPPLE IN COIL. PULL TEST SAME - GOOD. REMOVE CLAMP & SHIPPING BAR. PULL COIL ACROSS ROOF & STAB INTO INJECTOR. SECURE COIL. CHANGE OUT STUFFING BOX BRASS AND PACKOFF. 09:30 - 10:00 0.50 BOPSUR P PRE RU FOR BOP TEST. FLUID PACK MGS & CHOKE MANIFOLD. CTS BEGINS. INSTALLING INNER REEL IRON & PRESSURE BULKHEAD. TEST I12S & LEL ALARMS - GOOD TEST. 10:00 - 11:00 1.00 BOPSUR P PRE PERFORM BOPE BODY TEST TO 250 -PSI. UNABLE TO GET PASSING LOW PRESSURE TEST. TROUBLESHOOT AND IDENTIFY THAT VALVE #9 AND VALVE #14 ARE LEAKING. 11:00 - 12:00 1.00 BOPSUR P PRE REGREASE VALVE #9 & #14. IA / OA = 15 -PSI / 10 -PSI. 12:00 - 18:00 6.00 BOPSUR P PRE BEGIN INITIAL BOPE TEST. ALL TESTS TO 250 -PSI / 3500 -PSI FOR 5- CHARTED, FLAT -LINE MINUTES PER TEST. TESTS WITNESSED BY BP WSL, NORDIC TOOLPUSHER & AOGCC REP BOB NOBLE. BOPE WAS FUNCTIONED FROM RIG FLOOR & OPS CAB REMOTE PANELS AND FROM THE ACCUMULATOR. WHILE TESTING, FILL PITS WITH NEW 8.4 -PPG POWERPRO MUD. 18:00 - 20:30 2.50 BOPSUR P PRE HOLD PJSM. MAKE UP COIL TUBING CONNECTOR AND PULL TEST TO 35K - PASS. MAKE UP NOZZLE, CHANGE OUT HIGH PRESSURE SCREENS AND STAB INJECTOR. REVERSE CIRCULATE COIL WITH KCL WATER. PRESSURE TEST SLB LINES AND CONNECTIONS IN REEL HOUSE TO 250 PSI LOW, 4000 PSI HIGH FOR 5 CHARTED MINUTES EACH - PASS. 20:30 - 21:00 0.50 BOPSUR P PRE TEST INNER REEL VALVE AND PACKOFFS TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH - PASS. 21:00 - 00:00 3.00 BOPSUR P PRE PJSM. TEST MANUAL LOCKS ON LOWER 2 -3/8" COMBIS, LOWER 2 -3/8" X 3 -1/2" VARIABLES, UPPER 2 -3/8" COMBIS AND BLIND SHEAR RAMS TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH - PASS. TESTS WITNESSED BY BP WSL, NORDIC TOOLPUSHER. Printed 9/18/2012 9:40:29AM r Common Well Name: C -24 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/3/2012 End Date: X3-0124Y-C: (2,217,200.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/5/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'47.296 "6 Long: 0148°40'08.689'W Active Datum: ORIG KELLY BUSHING @71.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/5/2012 00:00 - 00:30 0.50 BOPSUR P PRE TEST MANUAL LOCKS ON LOWER 2 -3/8" COMBIS, LOWER 2 -3/8" X 3 -1/2" VARIABLES, UPPER 2 -3/8" COMBIES AND BLIND SHEAR RAMS TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH - PASS. TESTS WITNESSED BY BP WSL, NORDIC TOOLPUSHER. 00:30 - 01:00 0.50 STWHIP P WEXIT PJSM. INSPECT INJECTOR CHAIN. NO PROBLEMS FOUND. 01:00 - 01:30 0.50 STWHIP P WEXIT PJSM. TEST NIGHT CAP TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES EACH - PASS. 01:30 - 02:00 0.50 STWHIP P WEXIT PERFORM FLOW CHECK, (STATIC), FOR 30 MINUTES WHILE CHANGING OUT SLINGS AND SHACKLES FOR INJECTOR LIFTING SYSTEM. 02:00 - 03:00 1.00 STWHIP P WEXIT CHANGE OUT SLINGS AND SHACKLES FOR INJECTOR LIFTING SYSTEM. 03:00 - 06:15 3.25 STWHIP P WEXIT CUT 10' OF COIL, TEST CONTINUITY. HEAD UP AND PULL TEST TO 35K. MAKE UP COIL CONNECTOR AND TEST E -LINE CONNECTIONS. LEAK IN CROSSOVER FROM CTC TO UQC. FILL WELL WITH MINIMAL AMOUNT OF KCL & MONITOR - STATIC. 06:15 - 06:45 0.50 STWHIP N SFAL WEXIT ATTEMPT TO BEGIN REHEAD OF BHI, NOT ENOUGH SLACK TO BREAK CONNECTION. SET INJECTOR OVER CIRC HOLE AND PUMP FORWARD WITH 15 -BBLS KCL, SURGING PUMPS. IA / OA / PVT = 17 -PSI / 12 -PSI / 298 -BBLS. 06:45 - 07:15 0.50 STWHIP N SFAL WEXIT PU INJECTOR. BREAK OUT BHI UQC. REMOVE CROSSOVER. CLEAN, REDOPE & REMAKE CONNECTION. TEST CONNECTIONS TO 3850 -PSI. GOOD TEST. 07:15 - 09:00 1.75 STWHIP P WEXIT REHEAD BHI. TEST DFCV TO 250 -PSI / 3500 -PSI. HOLD AND CHART EACH TEST FOR 5- MINUTES. GOOD TESTS. 09:00 - 09:30 0.50 STWHIP P WEXIT RIG H2S EVAC DRILL & AAR. ALL PERSONNEL ON LOCATION MUSTER QUICKLY AT PRIMARY MUSTER AREA. AAR HIGHLIGHTS THAT ALARMS WERE CLEARLY HEARD BY ALL PERSONNEL ON LOCATION AND THAT LEVEL 1 RESPONSE WAS CLEARLY UNDERSTOOD. SUFFICIENT SCBAS (4- TOTAL) NEEDED FOR RE -ENTRY IN THE EVENT OF AN H2S RELEASE WERE UNAVAILABLE AT PRIMARY MUSTER AREA. PRE -SPUD MEETING WITH RIG CREW. 09:30 - 10:00 0.50 STWHIP P WEXIT HOLD PJSM ON MU WINDOW MILLING BHA. INSUFFICIENT KCL ON LOCATION FOR INITIAL WELL ENTRY. 10:00 - 11:00 1.00 STWHIP N SFAL WEXIT WAIT FOR FULL TRUCK OF KCL TO ARRIVE ON LOCATION. 11:00 - 11:30 0.50 STWHIP P WEXIT MU WINDOW MILLING BHA. BHA CONSISTS OF- 3.8" WINDOW MILL, 3.8" STRING REAMER, 2 -7/8" XTREME MOTOR, XO, 2 -JTS OF 2 -3/8" PH6, XO, XO, BLIND SUB, DGS, DPS, EDC, P &C, WEAR SUB, LQC, UQC, XO, CTC. OAL = 120.11'. Printed 9/18/2012 9:40:29AM o : 1 ^as E Common Well Name: C -24 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/3/2012 End Date: X3- 0124Y -C: (2,217,200.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/5/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'47.296 "6 Long: 0148 °40'08.689'W Active Datum: ORIG KELLY BUSHING @71.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 12:00 0.50 STWHIP P WEXIT STAB ON INJECTOR. TEST QTS TO 250 -PSI / 3500 -PSI. HOLD EACH TEST FOR 5- MINUTES. GOOD TESTS. LINE UP ON RIG WATER TO USE IN SHIFTING E -LINE SLACK TO DOWNHOLE END OF COIL. OPEN EDC. IA / OA / TT STRAP = 20 -PSI / 11-PSI/ 10 -BBLS. 12:00 - 12:45 0.75 STWHIP P WEXIT RIH SLOWLY PUMPING 60 -BBLS FRESH WATER AT 2.4 -BPM / 1780 -PSI TO SHIFT E -LINE SLACK TOWARDS DOWNHOLE END OF COIL. TAKE ALL RETURNS TO TIGER TANK. 12:45 - 15:30 2.75 STWHIP P WEXIT CONTINUE TO RU-I PUMPING 8.4 -PPG 1% KCL AT .4 -BPM / 150 -PSI. TAKE ALL RETURNS TO TIGER TANK, STRAPPING EVERY 1 /2 -HR & HOLDING 100-PSI BACK PRESSURE. INITIALLY 7.2 -PPG DIESEL FREEZE PROTECTION. WITH 60 -BBLS PUMPED (REPORTED AMOUNT OF DIESEL PUMPED PRE -RIG), SEE RETURN DENSITY INCREASE (ON OUT MM) TO 8.3 -PPG SEAWATER TAG WS AT 10,178' UNCORRECTED WITH 5K -LBS DHWOB. 15:30 - 17:00 1.50 STWHIP P WEXIT PU TO 10,165' INCREASE CIRC RATE TO 2.6 -BPM / 2100 -PSI. CBU X2 WITH KCL. TAKE ALL RETURNS TO CUTTINGS BOX. MOVE UPHOLE SLOWLY WHILE CIRCULATING. IA / OA = 30 -PSI / 0 -PSI. 17:00 - 17:15 0.25 STWHIP P WEXIT FLOW CHECK WELL - NO FLOW. 17:15 - 17:30 0.25 STWHIP P WEXIT ESTABLISH CIRCULATION AT 1.5 -BPM WITH MUD GOING DOWN COIL, DISPLACING WELL WITH KCL RETURNS TO TIGER TANK. POH TO 9800'. 17:30 - 19:00 1.50 STWHIP P WEXIT LOG PRIMARY TIE -IN PER GEO AND APPLY A MINUS 1' CORRECTION. CONTINUE DISPLACING WELL TO NEW 8.4 -PPG MUD. OBSERVE CLEAN MUD TO SURFACE AND SHUT DOWN. 19:00 - 19:30 0.50 STWHIP P WEXIT CLOSE EDC AND DRY TAG TOP OF WHIPSTOCK WINDOW AT 10,174' MD. OBTAIN PARAMETERS. UP WEIGHT 33K, DOWN WEIGHT 13K. TAKE SLOW PUMP RATES. 1 PUMP #1 AT 0.5 BPM WITH 1387 PSI. 1.0 BPM WITH 1616 PSI. PUMP #2 AT 0.5 BPM WITH 1388 PSI. 1.0 BPM WITH 1633 PSI. ct- 19:30 - 00:00 4.50 STWHIP P WEXIT MILL AT TOP OF WINDOW OF 10,174' MD. PUMP AT 2.6 BPM WITH 2622 PSI. MUD C-246 WEIGHT IN AND OUT 8.5 PPG. DOWN WEIGHT 14K WITH WOB 0.5K. TIME DRILL FIRST FOOT _r AT 1 FOOT PER HOUR. AT 11175' MD INCREASED WOB TO 1K WITH MOTOR WORK AT 150 PSI. PIT VOLUME AT 320 BBLS. OA = 5 PSI, IA = 50 PSI. CONTINUE TO MILL AHEAD TO 10,177' MD PUMPING AT 2.6 BPM WITH 2930 PSI. DOWN WEIGHT 11K WITH 3.5K WOB. OA = 6 PSI, IA = 52 PSI. Printed 9/18/2012 9:40:29AM ' sa 'W gim °K J Common Well Name: C -24 A No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/3/2012 End Date: X3- 0124Y -C: (2,217,200.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/5/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'47.296 "6 Long: 0148 °40'08.689 "W Active Datum: ORIG KELLY BUSHING @71.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/6/2012 00:00 03:00 3.00 STWHIP P WEXIT MILL AHEAD TO 10,179' MD. PUMP AT 2.6 BPM WITH 2842 PSI. DOWN WEIGHT 12K WITH 2.8K WOB. MUD WEIGHT IN AND OUT 8.5 PPG. PIT VOLUME 321 BBLS. OA = 10 PSI, IA = 59 PSI. LOST 1 K WOB OVER LAST 30 MINUTES OF MILLING AND FIRST STALL AT —10,178.8' MD. PULL OFF BOTTOM AND EASE BACK DOWN AT 0.5 FPM TO CONTINUE MILLING. 03:00 - 06:00 3.00 STWHIP P WEXIT STALLED OUT TRYING TO GET BACK TO BOTTOM FOR MILLING. PULLED BACK OFF BOTTOM AND EASED INTO BOTTOM. MILLING WINDOW AT 10,180' MD. PUMPING AT 2.6 $PM WITH 2755 PSI AND 100 PSI MOTOR WORK. DOWN WEIGHT 13K WITH 1.7K WOB. MUD WEIGHT IN AND OUT 8.5 PPG. PIT VOLUME 322 BBLS. OA = 11 PSI, IA = 62 PSI. W 06:00 - 10:30 4.50 STWHIP P WEXIT CONTINUE TO MILL WINDOW, KEEPING 2K -LBS DHWOB AND MAINTAINING 200 - 250 -PSI MOTOR WORK. PUMP 2.BPM BI WITH 2650 -PSI SPIN. PROBABLE AT 55 - EX 10,182.8' WITH INCREASE IN DHWOB TO 2.7 -KLBS & QUICKLY DRILL OFF. ING AHEAD THEN AT 1 -FPH. CONTINUE TIME MILL / OA / PVT = 65 -PSI / 11 u / / 323 -BBLS. MW IN IA = 8.51 -PPG / MW OUT= = 8.49 -PPG. ECD = 9.82 -PPG. 10:30 - 13:45 3.25 STWHIP P WEXIT M AHEAD IN FORMATION FROM 10,185' TO 10,192.3' ATCH ILL BU SAMPLE FOR GEO FROM 10,184' - S SHOWING HIGH CHERT MAI PERCENTAGE. LY ATION MIL LE AT 2.55 -BP 1.5 - 3K -LBS DHWOB AND SLOW. 200 - SITUATION N PSI WITH DD &ODE & DECIDE TO S OP MILLING RATHOLE AT 10,192.3' IA / OA / PVT 70 -PSI / 13 -PSI / 322 -BBLS. MW IN / - OUT PPG. 8.51 -PPG / 8.48 -PPG. ECD = 9.83 13:45 - 14:30 0.75 STWHIP P WEXIT MAKE REAMING PASSES UP &DOWN THROUGH WINDOW - NO ISSUES. CIRCULATE AI AT IN 2.58 W B / 2840 I. R DR WDO -/ NO ISSUES. IA / OA / PVT = 70-PSI/ 16 -PSI PM / 321 PS -BBLS. 14:30 - 14:45 0.25 STWHIP P WEXIT FLOW CHECK WELL FROM 10,170' - NO FLOW. OPEN EDC & ESTABLISH CIRCULATION AT 3.5 -BPM T 2970 -PSI. WINDO PVT = 320 -BB 14:45 - 16:30 1.75 STWHIP P WEXIT POHI W IG BH. MUD WEIGHT WIT IN AND OUT 8.5 PPG. 16:30 - 17:00 0.50 STWHIP P WEXIT FLOW LL AT M 200 LLIN'. NO FLOW. CLOSE CHECK EDC. IA / OA /PVT = WE 60 -PSI / 20 PSI / 272 -BBLS. Printed 9/18/2012 9:40:29AM TREE= 4-1/16" CMV WELLHEAD = McEVOY • C -24A . SAFEISIOTES: WELL ANGLE > 70° @ 10428' ACTUAtth z BAKER C Kb. ELEV = 71,62' BF ELEV = 37.22' • ■ 4 • ._ • ■ KOP = 1700' ■ • $ • Max Angle = 94* © 10720 • ■ • • ■ 4 Datum MD = 10199' 01 • A 04 • Datum TVD = 8800' SS . • 041 ■4 • ■4 TOP OF SCAB LNR MEM V 2185' 1 — 4-1/2" HES X NIP, ID = 3.813" 01 * 1 • 04 ITOP OF 13-3/8" CSG — 70' • 01 ■ 4 • ■ 4 A • • ■-4 2200' — TOP OF CEMENT 01 • r4 •"4 - 4 04 • • • • 104 1144 13 CSG, 72#, L ID 1 4 12 a47" — 2741' 1-1 • • 4 , *. • 04 ■. GAS LIFT MANDRELS • ,.• 0 • ST MD rv'D I DEVI TYPE VLV LATCH PORT DATE Minimum ID = 3.80" ( AN 9580' A im 4 3286 3130 37 CAMCO D BK 0 03/25112 4-1/2" HES XN NIPPLE • .• 04 0' • '• 3 5921 5262 38 CA MCD DMY BK 0 03/25/12 0 •• 2 7811 6758 33 KBG- 2 DMY BK 0 03/25/12 • 14 0 • •• 1 9238 7963 30 KBG-2 OW BK 0 103/25/12 14 1. • '• 0 •• • 04 0 .4. • '• 0 •• • •• 0 •• • 04 .• •• • '• ■ 0 0 9164' 1 X 7" BKR ZXP LNR TOP PKR I I , 1 PERFORATION SUMMARY 9524' — ELMD TT LOGGED 08/23/83 REF LOG SLB MEM BORAX ON 02/08/11 ANGLE AT TOP PERE 74° @ 10455' ' Note Refer to Production DB for historical pert data MILLOUT WINDOW (C-24A) 9310- 9326' SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10455 - 10470 0 02/07/11 2-7/8" 6 10485 - 10500 0 02/07/11 9514' - -.1 . 4-1/2" HES X NIP, ID = 3.813" 3-318" 6 10515 - 10540 0 02/05/10 2-7/8" 6 10583 - 10608 0 06/09/07 2-7/8" 6 10663 - 10688 0 06/09/07 9535' - -17" X 4-1/2" BKR S-3 PKR 2-7/8" 6 10780 - 10805 C 06109/07 ,:: - 2-7/8" 4 10880 - 11180 C 07103104 MEM "4- -,. ff M:44 M •••••■•1 r ..--- 9559' H4-1/2" HES X NIP, ID = 3 813" . I ■•••••• ••••••4 - ■•••••• ••••••4 ■•••••• r ,....-- 9580' — 4 HE$ xN NIP, MILLED TO ••••••4 ■•••••• ID ,=- 3.805" (06/08/12) e • 9-5/8" CSG, 47#, L-80, ID = 8 681" —I 9759' ■•••••• ••••••4 ■•••••• 9592' —14-1/2" WLEG, ID = 3.958" ••••••4 . •■•■•■•■•■•■4 , 7" LNR, 26#, L-80. 0383 bpf, ID = 6.276' H 10660 ■•••••• 2 k7 ' 9592' — 7" X 5" BKR ZXP LNR TOP [PKR W/ TIEBACK SLV 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" --1 9591' \ L 9605' HS" X 4-1/2" X0, ID = 3.950" I 7" r .ti, L-80. 0383 bpf , ID = 6 276" H 9756' 1-- , 4 BKR PKR/WHIPSTOCK (06/13/12) --1 10175' w,4. I i - .... - 10720' H 4 -t/ 2 " CIBP (02/05/10) ,....., I I 11187' —1 PBTD I •• •• • 4-1/2" LNR, 12.6#, L-80, 0152 bpf , ID = 3 958" H 11274' ... ..•. : DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/23/82 : ORIGINAL COMPLETION 03/27/12 TJI-V PJC GLV 0/0 (03/25/12) WELL C-24A 07/04104 JLM/KAK RIG SIDETRACK(C 06/15/12 JCIVVJMD MILLED XN NIP/SET WS (06/08-13/12' PERMIT No ! 040580 02/27/10 DAV/PJC GLV C/O (02/26/10) 06/26/12 JJMIJMD TREE C/0 (06/22/12) AR No: 50-029-20816-01 02/27/10 JKCIPJC CIBP & A DPERFS (02/05/10) SEC 19, T11N, R14E, 1425' FNL & 1030' FEL 05/18/10 RCT/SV GLV 0/0 (05/13/10) 02/12/11 AIM/PJC ADPERFS (02/07/11) BP Exploration (Alaska) • • - C' "� " SEAN PARNELL, GOVERNOR . r y p ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 � I - Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C -24A Sundry Number: 312 -176 Dear Mr. McMullen: l MAY ° S ZOi w NNE 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, Cath P. Foerster ll /' Chair DATED this l'f day of May, 2012. Encl. .i " STATE OF ALASKA RECEIVED I� r 1 ALA* OIL AND GAS CONSERVATION COM•ION MAY_ 0 $ 2012 (tt APPLICATION FOR SUNDRY APPROVAL b sing- / l 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon ® Plug for Redrill ` ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development - ❑ Exploratory 204 -058 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20816 -01 -00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C -24A , Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028305 ' 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): 11275 - 9019 ' 11187 9019 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2741' 13 -3/8" 70' - 2741' 70' - 2691' 4930 2670 Intermediate 9310' 9 -5/8" 9310' 8025' 6870 4760 Production Liner 1163' 7" 27' - 9756' 27' - 8443' 7240 5410 Liner 2690' 4 -1/2" 9584' - 11274' 8274' - 9019: 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10455' - 11180' 9007' - 9020' 4 12.6# L - 80 9592' Packers and SSSV Type: 7" x 4 Baker "S - Packer Packers and SSSV 9535' / 8228' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory 0 Development . ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 17, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ron Phillips, 564 -5913 Printed Name John Mc Title Engineering Team Leader Prepared By Name/Number Signature Z( Phone 564 - 4711 Date / /2 Joe Lastufka, 564 -4091 Commission Use Only Conditions approval: Notify Commission so that a representative may witness 5 1 �f ` (, jn t��, Sundry Number: Vi ❑ Plug Integrity :1 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: 35 p» 5 / 5oP /z' (ahfy 1,,,5/)ai fs l h dsect, ted a 4-1 male pli> pitici approved per 2C 44c 25 Subsequent Form Required: 6 ,,,,. / ,,, a-7.;2 APPROVED BY 5' _ / _/ -Z Approved By: , l COM ISSIONER THE COMMISSION Date l T Form 10-403 Revised 01/201 5711/17_ " I• . MAY 15 �0 Submit In Duplicate cl • • To: Alaska Oil & Gas Conservation Commission bp From: Ron Philli p s CTD Engineer Date: May 3, 2012 Re: C -24A Sundry Approval Sundry approval is requested to plug the C -24A perforations with a 4 -1/2" Baker Packer Whipstock as part of drilling the C -24B coiled tubing sidetrack. History of C -24A. C -24A is a rotary sidetrack drilled in July 2004 and completed with 300' of perforations in Zone 2A. Initial production rates quickly levelled off with HGOR. The well went to cycle within -6 mos and has been cycling ever since. The high initial gas rate prompted the 6/19/06 STP /Borax/MCNL, however a channel from the perforations to the gas cap was not evident. The MCNL indicated the PGOC lowered from - 8,922' SSTVD to - 8,925' SSTVD since July 2004. 75' of Z2A (three sets of 25') were shot in June 2007 without much effect. In Feb 2010 a CIBP was set at 10,720' to shut off gas, and an additional 25' of Z2A was shot. Both gas and oil rates decreased; the well was unable to flow naturally. 15' of Z2A was added shallower in the heel in Feb 2011. The well was able V to flow naturally but was not competitive. C -24A is currently shut -in for high GOR. The most recent calliper from 3/12/2012 showed the 4 -1/2" tubing to be in fair condition, with a maximum wall penetration of 20 %, 24% and 27% recorded at 5,728', 7,469' and 6,336'. All other wall penetrations are less than 19 %. All sidetrack screening pressure tests passed. Reason for sidetrack. C -24A is no longer a competitive producer due to a high GOR, and - there are no remaining well work options. The proposed sidetrack will access reserves in a -40 acre Zone 2A target in south - western C -pad. Proposed plan for C -24A. The existing perforations will be isolated by setting a 4 -1/2" packer whipstock set pre -rig. The primary cement job for the liner will cover the whipstock by 200'. The sidetrack, C -24B, will exit the existing 4 -1/2" liner and kick off and land in the Ivishak Zone 2A. This sidetrack will be completed with a cemented and perforated 3 -1/4" X 2 -7/8" L- 80 liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. � „�„ dlv�Ps Q OilPC 60/14("r4" 6O wA•�IT Toe Co'v -. Ckr fv`Ie T ,ysc� /fib c ' T , �,,,e q� ,3� rseYt6 0� p cI e 1 Ape r) 0404 - � /►ew l .4oI (oC��/ 540k /N Rte! /Pc ,er`, fr0v ik /OAT,'" A( rig Po/ 'P • . Pre -Rig Work: (scheduled to begin May 17th, 2012) 1. F MIT- IA to 3,000 psi (Passed 3/25/2012) 2. F MIT -OA to 2,000 psi. (Passed 3/28/2012) 3. W Cycle LDS; PPPOT- T to 5,000 psi. (Passed 2/12/2012) 4. S Drift for 4 -1/2" packer whipstock to 10,225'. 5. E Mill XN nipple at 9,580' MD with tO3.80" with Welltec tools. 6. EP Set 4 -1/2" packer WS at 10,175' (orientate 268° ROHS). 7. V PT MV, SV, WV. 8. F MIT -T (4 -1/2" packer WS) to 2,500 psi for 30 minutes.. 9. 0 Blind and bleed lines to zero, remove wellhouse and level pad. 10. V Set 4" CIW TWC 24 hrs prior to rig arrival. Rig Sidetrack Operations: (Scheduled to begin on June 26 2012 using Nordic Rig 1) r 3aGC ir5t, 1. MIRU Nordic Rig 1. `/. / - f , ;0101,a %� 5)1te 74 61, / 2. NU 7- 1/16" CT Drilling BOPE and test. 7" {5 t vPE -f o 30c'o V 5 i Pe 4 3 Mill 3 80" single string window in the 4 -1/2" liner at 10,175'. • 4. Drill Build: 4.25" OH, 505' (29 °/100 planned). ,w 5. Drill Lateral in Z2A: 4.25" OH, 1,785' (12 °/100 planned) with resistivity. PTD 6. Run 3 -1/4" x 2 -7/8" L -80 liner X0 at 10,950' leaving TOL -9,975' MD. 7. Pump primary cement leaving TOC at TOL at 9,975' MD, 27.3 bbls of 15.8 ppg Class G cement planned. 8. Perform cleanout w/ mill, motor and MCNL /GR /CCL log in one run. 9. Test liner lap to 2,400 psi. 10. Perforate well (- 200'). 11. Freeze protect well with diesel to 2,500' TVD. 12. Set BPV. ND 7- 1/16" BOPE stack. 13. Freeze protect tree and PT tree cap to 3,500 psi. 14. RDMO Nordic 1. Post Rig: 1. Re- install wellhouse, flowline and pull BPV. 2. Set 4 -1/2" liner top packer with skickline, and test to 2,400 psi. Ron Phillips CTD Engineer 564 -5913 CC: Well File Terrie Hubble /Joe Lastufka : TREE = 6" CIW WELLHEAD= McEVOY • -SALES: A CTUATOR = OTIS C -2 4A KB. ELEV = 71.62' BF. ELEV = 37.22' KOP = 1700' • : Max Angle = 94 @ 10747' / • Datum MD = 8866' ► • / i Datum TVD = 8800' SS (TOP OF SCAB LNR I 27' 41 j 2 185' J�4 -1/2" HES X NIP, ID = 3.813" • TOP OF 13 -3/8" CSG I 70' • • *4 , �� 2200' - I TOP OF CEMENT I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2741' ► •• GAS LIFT MANDRELS N • 4 ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" @ 9580' ► 4 3286 3130 37 CAMCO DOME BK 16 05/13/10 4 -1/2" HES XN NIPPLE ►: : 3 5921 5262 38 CAMCO DOME BK 16 05/13/10 �• ••• 2 7811 6758 33 KBG-2 DOME BK 16 05/13/10 ►, 0 1 9238 7963 30 KBG-2 SO BK 20 05/13/10 ►• �• • C I 9164' 1-19-5/8 " X 7" BKR ZXP LNR TOP PKR I I 9524' H ELMD TT LOGGED 08/23/83 I PERFORATION SUMMARY REF LOG: SLB MEM BORAX ON 02/08/11 MILLOUT WINDOW (C -24A) 9310' - 9326' I ANGLE AT TOP PERF: 74° @ 10455' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 9514' I -14 -1/2" HES X NIP, ID = 3.813" I 2 -7/8" 6 10455 - 10470 0 02/07/11 2 -7/8" 6 10485 - 10500 0 02/07/11 3 -3/8" 6 10515 - 10540 0 02/05/10 �, C, 9535' -17" X 4-1/2" BKR S -3 PKR 2 -7/8" 6 10583 - 10608 0 06/09/07] 2 -7/8" 6 10663 - 10688 0 06/09/07 2 -7/8" 6 10780 - 10805 C 06/09/07 "' • � ''`'`�' -.. 2 -7/8" 4 10880 - 11180 C 07/03/04 7� , R ►•* * ** *** - 9 559' — 14-1/2" HES X NIP, ID = 3.813" I ■ 4 9580' H4 -1/2" HES XN NIP, ID = 3.725" I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9759' ►• •• •••• •• •• • • ► 9592' 1-14-1/2" WLEG, ID = 3.958" I II • �� 9592' 11 7" X 5" BKR ZXP LNR TO ► • i • i • i • i • i • i 4 4 PKR W/ TIEBACK SLV ♦4444 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" H 10660' ' 9605' 1-1 5" X 4-1/2" XO, ID = 3.950" 14-1/2" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" I-I 9591' Se ' 4 r " , C key INS 1 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" H 9756' I /75-' 10720' — I4 -1/2" CIBP (02/05/10) I i 11187' -I FBTD I I4 -1/2" LNR, 12.6#, L -80, .0152 bpf, ID = 3.958" I 11274' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/23/82 ORIGINAL COMPLETION 02/27/10 DAV /PJC GLV C/O (02/26/10) WELL: C-24A 07/04/04 JLM /KAK RIG SIDETRACK (C -24A) 02/27/10 JKC/PJC CIBP & ADPERFS (02/05/10) PERMIT No: 1 040580 07/21/04 RMH/KAK GLV GO 05/18/10 RCT /SV GLV C/O (05/13/10) AR No: 50- 029 - 20816 -01 08/04/04 ATD/TLP TOP OF CSG /CMT CORRECTIONS 02/12/11 AMW /PJC ADPERFS (02/07/11) SEC 19, T11 N, R14E, 1425' FNL & 1030' FEL 09/21/06 JLJ /PAG GLV C/O 06/10/07 HDR/PAG ADPERFS BP Exploration (Alaska) .(x 6" CIW McEVOY • C-24B SAFET•TES: I OTIS ..: EV = 71.62' proposed CTD sidetrack drELEV = 37.22' ► KOP = 1700' � 1 Max Angle = 94 @ 10747' � ; � • Datum MD = 8866' •�1 V Datum TVD = 8800' SS o TOP OF SCAB LNR 27' ►• i I 2185' H4-1/2" HES X NP, ID = 3.813" • TOP OF 13 -3/8" CSG H 70' i . ∎, ►. �. �� 2200' TOP OF CEMENT 13 -3/8" CSG, 72#, L -80, D = 12.347" H 2741' ►J • ►� • �� GAS LIFT MANDRELS • • � ST MD TVD DEV TYPE VLV LATCH PORT DATE ►, C. ' 3286 3130 37 CAN/CO DOME BK 16 05/13/10 Minimum ID = 2.377" @ 10950' M :i 3 5921 5262 38 CAMCO DOME BK 16 05/13/10 3-1/4" x 2-7/8" XO ►, !, 2 7811 6758 33 KBG-2 DOME BK 16 05/13/10 of � � 1 9238 7963 30 KBG-2 SO BK 20 05/13/10 •• �• TSGR = 9,760' MD ►, • . • ► :� I 9164' I-- 19 -5/8" X 7" BKR ZXP LNR TOP PKR I PERFORATION SUMMARY I 9524' J-I ELMD TT LOGGED 08/23/83 I REF LOG: SLB MEM BORAX ON 02/08/11 ANGLE AT TOP PERF: 74° @ 10455' MILOUT WINDOW (C -24A) 9310' - 9326' Note: Refer to Production DB for historical pert data , SIZE SPF INTERVAL Opn/Sqz DATE 2 -7/8" 6 10455 - 10470 0 02/07/11 2 -7/8" 6 10485 - 10500 0 02/07/11 I 9514' — i4-1/2" HES X NIP, ID = 3.813" 3-3/8" 6 10515 - 10540 0 02/05/10 2 -7/8" 6 10583 - 10608 0 06/09/07 2 -7/8" 6 10663 - 10688 0 06/09/07 " $ ■ 9535' 7" X 4-1/2" BKR S -3 FM I 2 -7/8" 6 10780 - 10805 C 06/09/07 2 -7/8" 4 10880 - 11180 C 07/03/04 - 7��..L' II K.:.:: : I 9559' H4 -1/2" HES X NP, D = 3.813" ► • � • • • • • • • • 4 9580' H 4-1/ 2" I-FS XN NP, ID = 3.80" I ■•••••• 9-5/8" CSG, 47 #, L -80, ID = 8.681" 9759' ►•i•i•i•i•i•i4 milled out ► � • � • � • � • � • � • � J 9 592' H4-1/2" WLE D = 3.958" I 17" LNR, 26#, L -80, .0383 bpf, D = 6.276" H 10660' I _ , 14-1/2" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" 9591' q 9592' H 7" X 5" BKR ZXP LNR TOP PKR W/ TIEBACK SLV 17" LNR, 26#, L -80, .0383 bpf, D = 6.276" H 9756' I 40 3 9605' H5" X 4-1/2" XO, D= 3.950" I 3 -1/2" x 3 -1/4" XO 1i Top of 3 -1/2" liner and cement @ - 9,975' 2 - 7/8" liner TD @ 12,485' I ' 4 -1/2" packer whipstock @ 10,175' i 33 3-1/4" x 2 -7/8" XO @ - 10,950' ' 10720' H4 -1/2" CSP(02/05/10) I a 4 ' e ' ; 11187' H PBTD 14-1/2" LNR, 12.6#, L -80, .0152 bpf, ID = 3.958" 11274' DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 09/23/82 ORIGINAL COM PLETION 02/27 /10 DAV/PJC GLV C/O (02/26 /10) WELL: C-24B 07/04/04 JLM /KAK RIG SIDETRACK (C -24A) 02/27/10 JKC/PJC CEP & ADPERFS (02/05/10) PERMIT No: '040580 07/21 /04 RMH/KAK GLV C/O 05/18/10 RCT /SV GLV C/O (05/13/10) API No: 50- 029 - 20816 -01 08/04/04 ATD/TLP TOP OF CSG/CMT CORRECTIONS 02/12/11 AMW /PJC ADPERFS (02/07/11) SEC 19, T11 N, R14E, 1425' FNL & 1030' FEL 09/21/06 JLJ/PAG GLV C/O 04/11/12 WJH proposed CTD sidetrack 06/10/07 I-DR/PAG ADPERFS BP Exploration (Alaska) NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM V12 A , V14 Ilk II 7 -1l16" 5000 psi BOP's ID = 7.08" V15 V11 17 1/16 °5000 psi, Rx�6 Transducers 0 " ' II OOR B• 1 V V2 , V1 V 16 6"d GA88E � Note: typical BOP or arrangement for 24/9" coiled tubing drilling _. 2 318' Cams � TAT1V 1118" 5000 psi. 12X-44 f f f i V17 H I IC 1K OK To Poor Boy Gas Buster I V18 V19 111013 2 1118° 6000 psi , RX -24 I 3.00'5000 psi NCR I , • 1111111111111W41•11[11 ""'M .• 2 - /16 "5000 Pai CHECK Manual Choke VALVE —10 tiiii— �1l 71/18 Cameron FOV Gate I Valve x 5000 Psl Mt ii f l MEOH /Diesel . . . . „ 4-- FP Line 01 , 71 _ CoFlex Hose . =. 1/4 Tum Hako 10WOG To Production Tree or Cross Over • Ai T • CoFlex Hose CV11 0 0 Bleed Off _ - -•-- sas - ®_ V : —� r Cement Line In l Ground Level Tie-in CV3 CV2 T Stand Pipe :—.=-71:-= - - - - - Manual Choke 61. Mr - - _ V _ Pressure Transducers — InlIMI-1 I I = 41•11. ANL CV III MI/ MEV I I T I iger Tank Mud Pump 2 From `� r O -=. _ AI' _ M B aker MP 1 6 MP 2 ® ► - a Choke _ • • CV14 to Pits I — Rig Floor Mud Pump #1 41 CV16 Reverse Ci . ■ ' 1 Cir CT le s.' gM . - O ® • 4 _ = _ _ • ., • _ _ To Manifold CV15 1-Jun-2010 0...r.s rir.- rn,.ri.... lin. / CT rani nail CoFlex Hose Page 1 of 1 • Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art 1 or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and t operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 11/16/2011 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 0 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 .;� 4 fl RECE 1�1�� 1 Mr. Tom Maunder 416 31 N Alaska Oil and Gas Conservation Commission Als & 333 West 7 Avenue 18 CONS Anchorage, Alaska 99501 itnekIrtoge Subject: Corrosion Inhibitor Treatments of GPB C -Pad D 9 -` 05 Dear Mr. Maunder, 021 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad 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, Gerald Murphy, 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) C -Pad 7/19/11 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 na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -199 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C-41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 I OPERABLE: PRODUCER C-24A (P~ #2040580) TxIA communication mit~ted Page 1 of 2 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, May 13, 2010 8:12 PM "~~ ~' 7~lz~~o To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy t (DOA); AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, OPS Prod Controllers; AK, RES GPB West Production Optimization Engineer; AK, RES GPB East Production Optimization Engineer; AK, D&C Well Integrity Coordinator Cc: Quy, Tiffany; Janowski, Carrie; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC); Robertson, Daniel B (Alaska) Subject: OPERABLE: PRODUCER C-24A (PTD #2040580) TxIA communication mitigated Attachments: C-24A TIO Plot 04-26-10.doc; C-24A.pdf All, Producer C-24A (PTD #2040580) passed a MITIA Dost gas lift valve work. The well has been reclassified as Operable. At a later date, slickline will install a new gas lift design and the well can be returned to production. Please call with any questions or concerns, Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, April 26, 2010 10:29 AM r.~r~ ~'~ <~,~ .~ ~~N~VU~ To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: Kaminski, Alice; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: C-24A (PTD #2040580) Sustained casing pressure on the IA AI I, Producer C-24A (PTD #2040580) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 500/2200/200 psi on 04/23/10. On 04/25/10, a TIFL failed on IA repressurization overnight confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. slickline: Change out OGLV 3. DHD: Re-TIFL A TIO plot and wellbore schematic have been included for reference. 5/17/2010 OPERABLE: PRODUCER C-24A (P #2040580) TxIA communication mit~ted Page 2 of 2 «C-24A TIO Plot 04-26-10.doc» «C-2 .pdf>> Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 5/17/2010 PBU C-24A PTD 204-058 5/13/2010 TIO Pressures Plot ~3r00i i Well: C-2~ • 3.000 ^.i i00 1,000 -~ Tbg -E-- IA -~ OA OOA ~-- OOOA On i Oi f30,'10 02f13f10 02f37f10 03f13f10 03127f10 04f10f10 O~3f24f10 TREE = 6" CNV WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV..- 71.62' BF. ELEV - 37.22' KOP - 1700' Max Angle = 94 @ 1074T Datum MD = 8866' datum TV D = 8800' SS ~ G24A TOP OF SCAB LNR ~--~ 2T r TOP OF 13-3/8" CSG ~ 70' TOP OF CMT 2200' 13-318" CSG, 72#, L-80, ID = 12.347" 2741' Minimum ID = 3.725" @ 9580' 4-1 /2" HES XN NIPPLE BOTTOM OF SCAB LNR I--I 9162' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 84° @ 10515' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8" 6 10515 - 10540 O 02J05/10 2-7/8" 6 10583 - 10608 O 06/09(07 2-7/8" 6 10663 - 10688 O 06/09/07 2-718" 6 10780 - 10805 C 06109107 2-718" 4 10880 - 11180 C 07(03104 9559' `-"'~4-112" HES X NIP, ID = 3.813'° 95$0' 4-1/2" HES XN NIP, ID = 3.725" 9-518" CSG, 47#, L-80, ID = 8.681" (-j 9759' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10660' 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9591' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9756' 9592' 4-1/2" WLEG, ID = 3.958" 9592' 7" X 5" BKR ZXP LNR TOP PKR W/ TIEBACK SLV 9605' 5" X 4-1/2" XO, ID = 3.950" 14-1/2" CIBPf02105/10) I PBTD I 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-1 11274• DATE REV BY COMMENTS DATE REV BY COMMENTS 09/23/82 ORIGINAL COMPLETION 02/27/10 DAV/PJC GLV Ci0 (02/26/10) 07/04/04 JLM/KA RIG SIDETRACK (C-24A) 02/27!10 JKC/PJC CIBP & ADPERFS (02J05/10} 07/21/04 RMH/KA GLV C/O 03/31/10 SWCISV GLV C/O (03122/10) 08/04!04 ATD/TLP TOP OF CSG/CMT CORRECTIONS 09/21/06 JLJ/PAC GLV C!O 06!10(07 HDR/PAG ADPERFS PRUDHOE BAY UNff WELL: G24A PERMIT No: ~"Z040580 API No: 50-029-20816-01 SEC 19, T11N, R14E, 1425' FNL & 1030' FEL BP Exploration (Alaska) 21$5' ~-~ 4-1 l2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3286 3130 37 CAMCO DOME BK 16 03!22/10 3 5921 5262 38 CAMGO DOME BK 16 03!22/10 2 7811 6758 33 KBG-2 DOME BK 16 03/22/10 1 9238 7963 30 KBG-2 SO BK 20 03/22/10 9 164' I-~ 9-5/8" X 7"' BKR ZXP LNR TOP PKR 9524' ~ MD TT LOGGED 08123/83 MILLOUT WINDOW 9310' - 9326' 1 9514' 4-1/2" HES X NIP, ID = 3.813" ~-9535' ~ 7" x 4-1/2" BKR S-3 PKR UNDER EVALUATION: C-24A (PT~#2040580) Sustained casing pressure o~he IA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~ 4''2~'/J Sent: Monday, April 26, 2010 10:29 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr, GPB, Wells Opt Eng Cc: Kaminski, Alice; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: C-24A (PTD #2040580) Sustained casing pressure on the IA Attachments: C-24A TIO Plot 04-26-10.doc; C-24A.pdf All, Producer C-24A (PTD #2040580) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 500/2200/200 psi on 04/23/10. On 04/25/10, a TIFL failed on IA repressurization overnight confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. Slickline: Change out OGLV 3. DHD: Re-TIFL A TIO plot and wellbore schematic have been included for reference. «C-24A TIO Plot 04-26-10.doc» «C-24A.pdf» Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ? u~r` 4' ;. r, t L 4/29/2010 PBU C-24A PTD 2040580 4/26/2010 TIO Pressure Plot 4,000 ?:000 ?,000 1,000 Well: C-2d ~- Tbg ~-- IA -~ OA OOA OOOA On • 01130110 02/13110 02127/10 D3113110 03127110 04110110 04124/10 - 6" CIW WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 71.62' BF. ELEV = 37.22' KOP = 1700' Max Angle = 94 @ 1074T Datum MD = 8866' Datum TV D = 8800' SS ~ C-24 TOP OF SCAB LNR I--1 27' r TOP OF 13-3/8" CSG 70' TOP OF CMT 2200' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2741' Minimum ID = 3.725" ~ 9580' 4-1/2'° HES XN NIPPLE BOTTOM OF SCAB LNR ~-~ 9162' PERFORATK7N SUMMARY REF LOG: ANGLE AT TOP PERF: 84° @ 10515' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-318" 6 10515 - 10540 O 02!05110 2-7/8" 6 10583 - 10608 O 06!09/07 2-718" 6 10663 - 1068$ O 06/09/07 2-718" 6 10780 - 10805 C 06/09/07 2-718" 4 10880 - 11180 C 07(03104 ~ 9-518" CSG, 47#, L-80, ID = 8.681" ~ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ( 10660' 4-1(2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9591' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9756' 9559' --~4-1/2" HES X NIP, ID = 3.813" 9580' 4-1/2" HES XN NIP, ID = 3.725" 9592' 4-1/2" WLEG, ID = 3.958" 9592' 7" X 5" BKR ZXP LNR TOP PKR W/ TIEBACK SLV 9605' ~ 5" X 4-112" XO, ID = 3.950" 14-1/2" CIBP(02/05/101 1 PBTD 1 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ' 11274' 21 $$' ~-) 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3286 3130 37 CAMCO DOME BK 16 03/22/10 3 5921 5262 38 CAMCO DOME BK 16 03/22/10 2 7811 6758 33 KBG-2 DOME BK 16 03/22/10 1 9238 7963 30 KBG-2 SO BK 20 03122/10 9164' -) 9-518" X 7" BKR ZXP LNR TOP PKR 9524' ELMD TT LOGGED 08/23/83 I MILLOUT WINDOW 9310' - 9326' I 9514' 4-112" HES X NIP, ID = 3.813" X9535' ~ 7" X 4-1/2" BKR S-3 PKR DATE REV BY COMMENTS DATE REV BY COMMENTS 09/23182 ORIGINAL COMPLETION 02/27/10 DAV/PJC GLV C/O (02!26!10) 07(04/04 JLMtKA RIG 51DEfRACK{C-24A) 02(27/10 JKC/PJC CIBP& ADPERFS {02!05!10) 07/21/04 RMH/KA GLV C!O 03/31110 SWC/SV GLV C/O (03122!10} 08/04/04 ATD/TLP TOP OF CSG/CMT CORRECTIONS 09/21/06 JLJIPAG GLV C/O 06/10/07 HDR/PAG ADPERFS PRUDHOE BAY UNIT WELL: G24A PERMIT No: ~Z040580 API No: 50-029-20816-01 SEC 19, T11 N, R14E, 1425' FNl & 1030' FEL BP Exploration (Alaska) STATE OF ALASKA ALAS AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB ~ ~ 2~1(l t h er O 1. Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate^ A1. . 1, ~ r+ Pertormed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time 6g$ C91'18. Cummist~o Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re- ter Suspended Well ^ A~~hQr 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory 204-0580 3. Address: P.O. Box 196612 Stratigraphic^ Service .API Number: Anchorage, AK 99519-6612 50-029-20816-01-00 8. Property Designation (Lease N~mber) : .Well Name and Number: ADLO-028305 PBU C-24A 10. Field/Pool(s): \ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured ~ 11275 feet Plugs (measured) 10720' 2/5/10 feet true vertical ~ 9018.94 feet Junk (measured) None feet Effective Depth measured 11187 feet Packer (measured) 9164 9535 9592 true vertical 9019.48 feet (true vertical) 7899 8228 8282 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" SURFACE - 110 SURFACE - 110 Surtace 2671 13-3/8" 72# L-80 70 - 2741 70 - 2692 5380 2670 Intermediate 9310 9-5/8" 47# L-80 SURFACE - 9310 SURFACE - 8025 6870 4760 Production 9729 7" 26# L-80 27 - 9756 27 - 8443 7240 5410 Liner 1690 4-1/2" 12.6# L-80 9584 - 11274 8275 - 9019 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# L-80 SURFACE - 9591 SURFACE - 8282 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X7" BKR ZXP 9164 7899 7"X4-1/2" BKR S-3 9535 - 8228 7"X5" BKR ZXP 9592 8282 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~u Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ 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: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 2/10/2010 Form 10-404 Revised 7/2009 y~~iv rk~ 1 ~ ~~~~ ~.._ ~ _ rZ• / 1, /a Submit Original Only C-24A 204-058 ococ enerruiucuT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-24A 7/3/04 PER 10,880. 11,180. 9,017.65 9,019.51 C-24A 6/9/07 PER 10,663. 10,688. 9,024.99 9,025.18 C-24A 6/9/07 PER 10,780. 10,805. 9,020.39 9,019.54 C-24A 6/10/07 PER 10,583. 10,608. 9,022.28 9,023.29 C-24A 2/5/10 APF 10,515. 10,540. 9,018.78 9,020.65 C-24A 2/5/10 BPS 10,720. 10,730. 9,024.11 9,023.45 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 f~ C-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/5/2010 CTU #9 1.75" CT (Interact Publishing) Job Scope: Set CIBP/ Adperf MU logging tools. RIH w/ logging tools and 3.66" JSN for drift. Tag TD at 11156' Log up to x9500'. POOH download data. Corrected PBTD = 11173.2'. MU HAL 4.5" EZ Drill ;plug. Correct depth to lower flag. Set plug @ 10720' (center element). Stack weight, confirm set. POOH recovered 1/2" ball MU pert guns. }1 w7~~5'PF 3406PJ HMX Perf Guns park coil pert 10515' to 10540' POOH ****** Job Continue ion 2/6/10 WSR "**** 2/6/2010 CTU #9 1.75" CT (Interact Publishing) Job Scope: Set CIBP/ Adperf *`** Continued from 2/5/10 WSR ***** POOH from pert run. Holes in guns confirmed. Freeze protect well w/40 bbls 60/40 Meth. Recovered 1 /2" ball from firing head. RDMO "**** Job Complete "**"** FLUIDS PUMPED BBLS 40 60/40 METH 40 Total TREE = 6" CMl WELLHEAb = McEVOY ACTUATOR = - OTIS KB ELEV = ~-~-- 71.62' BF. ELEV = 37.22' KOP = 1700' Max Angle= 94 @ 1074T Datum MD = 8866' Datum TV D = 8800' SS ~ C-2 TOP OF SCAB LNR ~-i 27' r TOP OF 13-3/8" CSG~ 70' TOP,OF,C~ 2200' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2741' Minimum ID = 3.725'" @ 9580' 4-1i2'" HES XN NIPPLE BOTTOM OF SCAB LNR ~-) 9162' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 88° @ 10583' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 6 10583 - 10608 O 06/09/07 2-7/8" 6 10663 - 10688 O 06/09/07 2-7/8" 6 10780 - 10805 O 06/09/07 2-7/8" 4 10880 - 11180 O 07!03!04 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-) 9759' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ 10660' 4-1I2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9591' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9756' 2185' !-{ 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3286 3130 37 CAMCO DMY BK 0 09/21/06 3 5921 5262 38 CAMCO DMY BK 0 09(21106 2 7811 6758 33 KBG-2 DMY BK 0 07!04!04 1 9238 7963 30 KBG-2 DMY BK 0 07/04104 9I 164' 11 9-5/8" X 7" BKR ZXP LNR TOP PKR 9r 52d' ~ ELMD TT LOGGED 08/23183 MILLOUT WINDOW 9310' - 9326' I 9514' 4-112" HES X NIP, ID = 3.813" ~---~ 9535' 7" X 4-1/2" BKR S-3 PKR CI~P G..~i 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11274' 9559' -j 4-1(2" HES X NIP, ID = 3.813" 9580' 4-1/2" HES XN NIP, ID = 3.725" 9592' 4-1/2" WLEG, ID = 3.958" 9592' ~ 7" X 5"' BKR ZXP LNR TOP ! PKR W/TIEBACK SLV ! 9605' 5" X 4-1/2" XO, ID = 3.950 lv ~t~ - rv s°Kc~ pv~ ~,~q./v PBTD I DATE REV BY COMMENTS DATE REV BY COMMENTS 09/23/82 ORIGINAL COMPLETION 07/04/04 JLM/KA RIG SIDETRACK (C-24A} 07/21!04 RMWKAK GLV C/O 08/04/04 ATD/TLP TOP OF CSG/CMT CORRECTION 09!21106 JLJ/PAG GLV C/O 06/10!07 HDWPAG ADPERFS PRUDHOE BAY UNff WELL: C-24A PERMff No: "rL040580 API No: 50-029-20816-01 SEC 19, T11 N, R14E, 1425' FNL & 1030' FEL BP Exploration (Alaska) • • -~~ -~ MICROFILMED 03/01/2008 DO NOT PLACE N _ , ~ ~.~ H z , °- ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc .- I STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS o o o Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate 0 ~ ¿../.s-~ 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: Exploratory Service 6. API Number: 50-029-20816-01-00 / P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 65.72 KB - PBU C-24A ~ ADLO-028305 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool / 8. Property Designation: Total Depth measured true vertical 11275 - feet 9018.94/ feet Plugs (measured) Junk (measured) None None Effective Depth measured 11187 - feet true vertical 9019.48 - feet Casing Length Size MD TVD Burst Conductor 80' 20" Surface - 110' Surface - 110' Surface 2671' 13-3/8" 72# L-80 70' - 2741' 70' - 2692' 5380 Production 9310' 9-5/8" 47# L-80 Surface - 9310' Surface - 8025' 6870 Liner 9729' 7" 26# L -80 27' 9756' 27' - 8443' 7240 Liner 1690' 4-1/2" 12.6# L-80 9584' - 11274' 8275' - 9019' 8430 Collapse 2670 4760 5410 7500 Perforation depth: Measured depth: 10583' - 11180' True Vertical depth: 9022' - 9020' - $ANNEDJUN 2, 6 2007 - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 9591' Packers and SSSV (type and measured depth) 9-5/8"X7" BKR ZXP 7"X4-1/2" BKR S-3 7"X5" BKR ZXP o 9164' 9535' 9592' o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 587 SHUT-IN Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 35507 14 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 1345 o 13. Service x Contact Gary Preble WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Data Management Engineer Signature Phone 564-4944 Date 6/12/2007 Form 10-404 Revised 04/200'0 R \ GIN A L BFL JUN 19~h~ Submit Original Only . . C-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/8/2007 CTU #8 wi iCoil, Drift & Add Perf; MU and RIH with 2.972" JSN to drift tubing. Continue On WSR 06/09/07; Job In Progress. 619/2007 **** CTU #8 wi From & Add Perf.MU and RIH with 2.972" JSN.Drift tubing down to 11000' i-Coil Depth.POOH and prep for perf guns.MU And RIH wlfiring head with 2-7/8" HSD Perf Gun # 1.Log on depth with ¡- Coil and perf int 10780 - 10805 - Good surface indication gun fired. POH- LD gun # 1-all shots fired-recovered ball - MU/RIH with gun #2 - Log on depth with i-Coil and perf int 10663 - 10688 - Good surface indication gun fired. POH.LD gun # 2-all shots fired-ball recovered.PT ctc - MU/RIH with gun #3- ......Continue On WSR 06/10107........ #8 wi Continue From Add Perf.Log on depth with and perf int 10583 - 10608 - Good surface indication that gun fired.POOH.LD gun # 3- all shots fired - recovered ball. Left well shut in and freeze protected to 2500 feet with 50/50 methanol.DSO notified upon departure. ....Job Complete.... FLUIDS PUMPED BBLS I 48 SO/50 METHANOL 48 TOTAL Schlumberger NO. 4260 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth \~~~ 1-)(;/-1- 05~ .#- 15 I :)« Company: State of Alaska Alaska Oil & Gas Cons iComm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay D CI CD D BL Well Job# Loa escrlption ate o or 03-36 10831325 CH EDIT PDC GR 08/11104 1 MPL-40 98160 OH EDIT MWDILWD (REVISED) 03105198 4 1 L2-18A 11421036 RST 10/14106 1 1 A-04 11221855 RST 03122106 1 1 06-04A 11320998 RST 08102106 1 1 C-24A 11209609 MCNL 06/19106 1 1 P2-57 A 10831796 RST 04129106 1 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 Date Delivered: ¡"lAY ]. G SGANNED MAY 1 7 2007 Z007 Received by: 1- 05/15107 . . RECEIVED Scblum~erger SEP 1 2 2006 NO. 3952 ~.Jæka Oil & Gas Cons. Ccmrr:~n ArcOOr2ge Company: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 86L{-OSif SCANNED S E P 1 9 2005 Field: Prudhoe Bay WII J b# L D C C e 0 og escrlptlon Date BL olor D X-16 10830812 RST/GRAVEL PACK 05/31/04 1 C-24A 11209609 MEM PROD PROFILE 06/19/06 1 V..o2 40010525 OH EDIT OF MWD/LWD 06/10/04 2 1 N..o7A 40010734 OH EDIT OF MWD/LWD 07/19/04 2 1 17..o7A 40010150 OH EDIT OF MWD/LWD 02/17/04 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 09/11/06 . . '-(~. lð~ \p DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Permit to Drill 2040580 Well Name/No. PRUDHOE BAY UNIT C-24A Operator BP EXPLORATION (ALASKA) INC 5';lÃ/¿ 2rJ~À.(Júi AP(No. 50-029-20816-01-00 MD 11275 TVD 9019 Completion Date 7/4/2004 Completion Status 1-01 L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional su~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc Log Log Run Scale Media No C Lis 13628 Name Directional Survey I nd uction/Resistivity Rpt Directional Survey 1:, 0 U, 12641 :::::.:~" Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y Ð Chips Received? ~ Daily History Received? Formation Tops Analysis Received? ~ (data taken from Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received Comments 9294 11275 7/16/2004 IIFR 9310 11275 Open 2/22/2006 ROP DGR EWR SLD CTN plus Graphics 9294 11275 7/16/2004 IIFR 9257 11225 9/3/2004 MWD, GR, CNP, SLD, ROP 9257 10267 9/3/2004 MWD, DSN 12641 . Sample Set Number Comments ~N (J)N . Comments: ~ Date: r)~ ~.~ Compliance Reviewed By: . . WELL LOG TRANSMITTAL d04- ()5B To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 ì ?J{¡~~ RE: MWD Formation Evaluation Logs C-24A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 C-24A: LAS Data & Digital Log Images: 50-029-20816-01 1 CD Rom ~ ~/9r¡¡1{j(p ~ . STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 09/21/04, Put on Production (No Test) 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 7/4/2004 204-058 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/25/2004 50-029-20816-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 7/1/2004 PBU C·24A 1425' SNL, 1030' WEL, SEC. 19, T11N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 4364' SNL, 3995' WEL, SEC. 19, T11N, R14E, UM 65.72' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 3319' SNL, 4106' WEL, SEC. 19, T11N, R14E, UM 11187 + 9019 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 664351 y- 5959793 Zone- ASP4 11275 + 9019 Ft ADL 028305 TPI: x- 661462 y- 5956792 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 661325 y- 5957834 Zone- ASP4 (Nipple) 2185' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: DIR / GR, DIR / GR I RES I DEN / NEU / ABI 22. CASING, LINER AND CEMENTING RECORD ~~Ti~G Gf!ÀP!;. ... . SI;1;TIIIÇ; SI;1;TIN(; ÊF'TH TV!> HOLE ii ~ wT,Pi:R PT. lOþ>i 6ØTTOM TOP I BOTTOM SIZe 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 70' 2741' 70' 2692' 17-1/2" 3767 cu ft Arcticset II 9-5/8" 47# L-80 Surface 9310' Surface 8025' 12-1/4" 1453 cu ft Class 'G' & 1117 cu ft AS I 7" 26# L-80 27' 9756' 27' 8443' 8-1/2" 191 cu ft Class 'G', 1561 cu ft 'G' 4-1/2" 12.6# L-80 9584' 8275' 11274' 9019' 6-1/8" 247 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 24. J61Nü >i. Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9592' 9535' MD TVD MD TVD 10880' - 11180' 9018' - 9020' 25. ..A.Ç;lp,. . ",,¡:MENT ··ii. i DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 80 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): August28,2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oil-Bel GAs-McF WATER-Bel CHOKE SIZE GAS-Oil RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oil-Bel GAs-McF WATER-Bel Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (atta f~sary). Submit core chips; if none, state "none". I '\.1:: V I:: None 5fP~Z SEP 2 1 2004 ~~ ORIGINAL ~ 'cf';; ,;,. :-~,.' Alaska Oil & Gas Cons. Commission ,/ Anchorage LX Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28, GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 9760' 8447' None Shublik A 9788' 8474' Shublik B 9820' 8506' Shublik C 9843' 8529' Sadlerochit 9868' 8554' Zone 3 / Top CGL 10052' 8735' Zone 2A I Base CGL 10150' 8825' Zone 1 B 10540' 9021' R~C~N~O ,.. .~.. '- î\)tJ~ S t. ~ t ~ß",,,,\SS$)n . & Ga',) C$\,S. ~\as¥.a ù\\ ~~tM(a\\e 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date PBU C-24A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 204-058 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e b("¡' ~B~ J2.~tf( WELL LOG TRANSMI1TAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 01,2004 RE: MWD Formation Evaluation Logs C-24A, AK-MW-3126706 1 LDWG formatted Disc with verification listing. API#: 50-029-20816-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Dæe ~f }cI RECE\VED C',.-r-, ." . - 0004 0ti-' U' L. Alaska Oil & Gas Cons. Commission And\Ofage a STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: !HI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 !HI Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 7/4/2004 204-058 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/25/2004 50- 029-20816-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 7/1/2004 PBU C-24A 1425' SNL, 1030' WEL, SEC. 19, T11N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 4364' SNL, 3995' WEL, SEC. 19, T11N, R14E, UM 65.72' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 3319' SNL, 4106' WEL, SEC. 19, T11N, R14E, UM 11187 + 9019 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 664351 y- 5959793 Zone- ASP4 11275 + 9019 Ft ADL 028305 TPI: x- 661462 y- 5956792 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 661325 y- 5957834 Zone- ASP4 (Nipple) 2185' MD i~':'j¡,ii''''''' 18. Directional Survey !HI Yes ONo 19. Water depth, if offshore 26. '~(~~~~st N/A MSL ' , rx.) 21. Logs Run: i j t : ,- ~ DIR / GR, DIR / GR I RES / DEN / NEU / ABI :i~i"k"'. .' ')'7 0 '-f ~n.I)A 22. CASING, LINER AND CEMENTING RECORD 'J~ ~~ð¡,'¡ ~ ;~~. , , i'("^"'~I'" .wr.~ ,.., MP :SETrlNt:: '.'(y. ~?i~ l'i;::¡':':. ~ Ä$[;¡:E . GRADE: TOP I Bcrf'toM TOP BottöM "·i, !"""- 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 70' 2741' 70' 2692' 17-1/2" 3767 cu ft Arcticset II 9-5/8" 47# L-80 Surface 9310' Surface 8025' 12-1/4" 1453 cu ft Class 'G' & 1117 cu ft AS I 7" 26# L-80 27' 9756' 27' 8443' 8-1/2" 191 cu ft Class 'G', 1561 cu ft 'G' 4-1/2" 12.6# L-80 9584' 8275' 11274' 9019' 6-1/8" 247 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. .,.. i'".ii' ii""' '" " .",i·' Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4spf 4-1/2", 12.6#, L-80 9592' 9535' MD TVD MD TVD 10880' - 11180' 9018' - 9020' 25.,.." ....AêID, '..... ~,~~ªiiii i DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 80 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SUbm;tœone, state "none", None "1' i RBDMSBfl. AUG 05 ,)f\r,~ V I GÇÚ ORfhiri'/\ f Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 9760' 844 7' None Shublik A 9788' 8474' Shublik B 9820' 8506' Shublik C 9843' 8529' Sadlerochit 9868' 8554' Zone 3/ Top CGL Zone 2A / Base CGL 10052' 8735' 10150' 8825' Zone 1 B 10540' 9021' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 0 Prepared By Name/Number: Terrie Hubble, 564-4628 Drilling Engineer: Rob Tirpack, 564-4166 PBU C-24A Well Number 204-058 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e :44:09 PM 7/6/2004 Printed: e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 6/12/2004 06:30 - 08:00 1.50 MOB P PRE Move Rig off C-25A - Pull to middle of pad and set down - Derrick up rig move with 48 stands drill pipe in derrick 08:00 - 15:00 7.00 MOB P PRE Prep Location around C-24 for rig - Pad +/- six inchs lower than cellar box, build pad up with gravel and level 15:00 - 20:00 5.00 MOB P PRE Lay Matting boards, herculite and spot sub over C-24 - Spot pit complex - Spot truck shop, Welding shop, Lay herculite and spot cutting tank 20:00 - 21 :00 1.00 RIGU P PRE Hammer up Interconnects, Close Cellar, Prepare walk ways - Accept rig at 1400 hrs 6/12/2004 - Rig acceptance backed up 7 hrs due to site preparation time. 21 :00 - 21 :30 0.50 WHSUR P DECOMP Pre-Spud meeting with drill crew 21 :30 - 22:30 1.00 WHSUR P DECOMP Rig up drill site maintenance Lubricator, Pull CIW 6 3/8 type 'J' BPV, no pressure on well 22:30 - 00:00 1.50 WHSUR P DECOMP Rig up lines to tree and annulus, Pump 30 bbl soap pill and Circulate well to seawater - Recovered 120 bbls diesel freeze protection 6/13/2004 00:00 - 03:00 3.00 WHSUR P DECOMP Finish Circulating well to clean seawater at 4 bpm 350 psi - no gas in returns - Monitor well, ok 03:00 - 04:00 1.00 WHSUR P DECOMP Set CIW 63/8" type 'J' Two way check, test from below to 1000 psi - Blow down lines 04:00 - 05:00 1.00 WHSUR P DECOMP Nipple down Cameron 71/16 Tree and McEvoy 135/8 x 71/16 5000# tubing head adapter 05:00 - 07:00 2.00 BOPSU P DECOMP Nipple up 13 5/8 5K Bop stack 07:00 - 14:30 7.50 BOPSU P DECOMP Rig up Lines, Test bop with 5 1/2" test joint - Test all lines, valves, Hydrill and top rams to 250 low /3500 high, Top rams failed, Change rams and retest ok- Did not test bottom rams due to tool joint across rams - Will test bottom rams after laying down tubing - Witness of Bop test waived by Mr. John Crisp of AOGCC. 14:30 - 15:30 1.00 BOPSU P DECOMP Rig up Drill Site Maintenance Lubricator, Pull Two way check through BOP stack, no pressure on well 15:30 - 18:00 2.50 PULL P DECOMP Make up 4" drill pipe and Crossover, Screw into tubing hanger - Back out lock down screws - Pull tubing hanger to rig floor, Pull free at 250k, P/u 200k, s/o 125k - Lay down tubing hanger & Landing jt. - Rig up Power tongs, Back up rig tongs and Cameo control line spooling unit 18:00 - 21 :30 3.50 PULL P DECOMP Pooh lay down 51/2" 17# L-80 Btc tubing - Spool control line, Recovered 24 rubber control line clamps & two stainless steel bands - Rig down spooling unit 21 :30 - 00:00 2.50 PULL P DECOMP Continue pooh laying down 51/2" tubing - 100 jts down at 2400 hrs - Tubing in good condition 6/14/2004 00:00 - 05:00 5.00 PULL P DECOMP Continue Pooh laying down 5 1/2" 17.0# L-80 Btc tubing- Total 212 jts - Rig down Tongs & Clear floor 05:00 - 06:30 1.50 BOPSU P DECOMP Install Test Plug, Test Top ram, bottom rams and Hydrill 250 low / 3500 high with 4" test jt. 06:30 - 10:00 3.50 DHB P DECOMP Rig up Schlumberger wireline, RIH with 8.5" GR/JB/CCL - set down at 40' - RIH with 8.25 GRlJB, set down at 40' - RIH with 8.0" GRlJB, set down same spot - Casing collapsed - Rig down Schlumberger wireline 10:00 - 12:00 2.00 DHB C DECOMP Make up 7 3/4" swedge with Bumper sub, Oil jar and drill collar - RIH to 87' - no obstruction - pooh 12:00 - 13:00 1.00 DHB C DECOMP Make up 8.00" swedge - RIH tag up hard at 40' - Pooh, Lay down swedge and jars Printed: 7/6/2004 1 :44:23 PM e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 6/14/2004 13:00 - 15:30 2.50 DHB C DECOMP Make inspection of Derrick, Crown, Top Drive, Drawworks, Brake linkage and traction motor prior to swedging operation 15:30 - 17:00 1.50 DHB C DECOMP Pick up 9 - 6 3/4" drill collars, 8.00" swedge, Bumper sub, Oil jars, 2- 8" drill collar= 35k net wt. 17:00 - 18:30 1.50 DHB C DECOMP Tag up at 40' - Beat down and swedge out ID of 9 5/8 casing to 8.00" - Swedge casing 40 to 42' - TIH to base of permafrost at 1,588', no further obstruction - Pooh 18:30 - 00:00 5.50 DHB C DECOMP Make up 8.25" Swedge, Tag up at 40' - Beat down and swedge out ID of 9 5/8 casing - break through at 42' - obstruction 2' long - Turn swedge assembly 1/8 of turn, Can not pass thru obstruction - Continue Beating down opening up collaspe casing 6/15/2004 00:00 - 06:00 6.00 DHB C DECOMP Continue Beating down with 8.25" swedge opening ID of 9 5/8 47# L-80 collasped casing - Broke through at 42' - Turn assembly 1/8 of turn, can not pass thru, Continue to beat down and swedge out casing 40 to 42' - swedge passing through with 20k wt up and down 06:00 - 07:30 1.50 DHB C DECOMP Lay down 8" drill collar, Swedge (swedge worn down to 8.125") bumper sub, oil jars, - Stand back 9 - 6 3/4" drill collars 07:30 - 15:00 7.50 DHB P DECOMP Rig up Schlumberger wireline - RIH with 8.00" GR/JB/CCL to tubing stub at 9,356' wlm - Pooh, recovered rubber control line clamp parts, and lot of debris - Re-run Junk basket second time - small amount of debris recovered - Make up Halliburton 9518 CIBP - RIH and set BP at 9,335' wlm, 3' above Casing collar - Pooh 15:00 - 18:00 3.00 EVAL C DECOMP RIH with CCL I USIT to 4,000' - Log 4,000 to surface, Top of Cement at 2,100' - Lay down tool string 18:00 - 18:30 0.50 EVAL P DECOMP Attempt test 9 5/8 caisng to 1500 psi, Lost 150 psi 10 minutes, suspect pack-off leaking 18:30 - 21 :00 2.50 DHB C DECOMP Make up Halliburton 9518 Fast drill composite BP, RIH on E-Line, set in middle of jt at 2,620' ELM - Pooh rig down Schlumberger 21 :00 - 22:00 1.00 EVAL C DECOMP Make up 1" CS Hydrill mule shoe and run Tubing into 13 3/5 x 20" annulus, Tag up at 17' below landing ring level - Drop nut on string and verify depth, same 22:00 - 00:00 2.00 WHSUR C DECOMP Prepare cellar area for welding, Obtain hot work permit from production operator- Clean with grinder and prepare for welding cap on 20 x 13 3/8 fluted hanger 6/16/2004 00:00 - 05:00 5.00 WHSUR C DECOMP Install and weld Cap on 20 x 13 3/8 fluted hanger - Cap has two 1502 outlets for taking returns out annulus - Post swedging inspection of drawworks, Top Drive 05:00 - 08:00 3.00 CLEAN C DECOMP Make up 8.375" string mill BHA - 8- 6 3/4 drill collar below, String mill, Bumper sub, Oil jars, 1 -63/4" Drill collar above 08:00 - 09:30 1.50 CLEAN C DECOMP Tag up at 37' with mill - Mill 37' to 46' opening ID of 9 5/8 casing to 8.375" 09:30 - 10:30 1.00 CLEAN C DECOMP TIH with drill pipe - Tag Fast drill BP at 2,620 dpm - no obstruction below 46' 10:30 - 12:00 1.50 CLEAN C DECOMP Pooh - Lay down string mill, and jars, stand back drill collars 12:00 - 13:30 1.50 CLEAN C DECOMP Make up Multi String casing cutter with 3 1/2" kinves, max cut 11" - 8.375" string mill above for stablizer and 3- 6 3/4" drill collar 13:30 - 15:00 1.50 CLEAN C DECOMP TIH, Tag BP at 2,620' 15:00 - 18:00 3.00 CLEAN C DECOMP Circulate 140 deg seawater at 2112 bpm 360 psi, attempt to Printed: 7/6/2004 1 :44:23 PM e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 6/12/2004 7/4/2004 Spud Date: 9/5/1982 End: 7/4/2004 6/16/2004 15:00 - 18:00 3.00 CLEAN C DECOMP heat casing to free up Arctic pack for better displacement - Finish clean pits for oil base mud 18:00 - 21:30 3.50 CLEAN C DECOMP Take on 9.3 ppg synthetic oil base as arrived from MI mud plant 21 :30 - 23:00 1.50 CLEAN C DECOMP Displace seawater with 9.3 ppg oil base mud at 5 bpm 1425 psi - Shut down clean from under shakers 23:00 - 23:30 0.50 CLEAN C DECOMP Pooh from 2,620 to 1,950' 23:30 - 00:00 0.50 CLEAN C DECOMP Locate casing collar at 1,953 and 1,995' with cutter knives - Cut 9 5/8 casing in middle of joint at 1,974' 6/17/2004 00:00 - 01 :00 1.00 CLEAN C DECOMP Close Hydrill, Open 9 5/8 x 13 3/8 annulus to cuttings tank - Attempt to circulate out Arctic pack by pumping synthetic oil mud down drill pipe and out cut at 1,974' and up 9 5/8 x 133/8 annulus - Circulate at 3 bpm 800 psi, Returns to cuttings tank 20 to 30 bbls of water followed by synthetic oil mud with some spurts of gas, not Arctic pack - Appears to be circulating through hole in 9 5/8 casing up high - Circulate 116 bbls annuluar volume- Check to make sure cut made, Knives indicate cut. 01 :00 - 02:00 1.00 CLEAN C DECOMP Pooh, slowly wet pipe 02:00 - 02:30 0.50 CLEAN C DECOMP Lay down Multi string cutter 02:30 - 03:30 1.00 CLEAN C DECOMP Make up Pack-off on joint of hwt drill pipe, Make up Spear with 8.681 grapple - RIH and spear 9 5/8 casing with Pack-off at 62' (below suspected hole in 9 5/8 casing) 03:30 - 04:30 1.00 WHSUR C DECOMP Attempt to Circulate out Arctic pack from 9 5/8 x 13318 - Work pressure up to 1500 psi, no circulation - Bled off and re-pressure, working up to 1500 psi - no circulation (Later found IBOP on top dive in closed position, preventing circulation) 04:30 - 05:30 1.00 CLEAN C DECOMP Back out lock down screws on 9 5/8 pack-off 05:30 - 07:00 1.50 CLEAN C DECOMP Spear 9 5/8 casing with Pack-off at 92' - Work pipe, pull free at 225k, Work pipe +1- 3' stroke - Attempt to circulate out Arctic pack from 9 5/8 x 13 3/8 annulus - Circulate, returns synthetic oil base mud, not arctic pack 07:00 - 09:00 2.00 CLEAN C DECOMP Pooh lay down pack-off, Spear 9 5/8 casing, Attempt to pull casing to rig floor - Work pipe as picking up string at 200 - 220K - Casing hung up in BOP on slack-off, push back down with top drive wt 09:00 - 10:30 1.50 CLEAN C DECOMP Clear rig Floor of tools, while discussion with Anchorage staff 10:30 - 16:30 6.00 EV AL C DECOMP Make up 9 - 6 3/4" Drill collar below 9 5/8 RTTS and bypass, TIH and set Rtts at 70' - Attempt to circulate out Arctic pack from 9518 x 13 3/8 annulus through cut in 9 5/8 at 1,974', Circulate at 2 1/2 bpm 130 psi, returns 9.3 ppg synthetic oil mud - RIH set RTTS at 531' - Circulate out synthetic oil mud - RIH set RTTS at 1,650', Circulate synthetic oil mud, no arctic pack - Verified circulation is going through cut at 1,974' - Pooh lay down Rtts and by-pass, stand back drill collars 16:30 - 18:00 1.50 FISH C DECOMP Make up Casing cutter with 3 1/2" knives, 11" max cut - RIH and cut 9 5/8 casing at 69' dpm 18:00 - 19:30 1.50 FISH C DECOMP Make up Spear with 8.681 grapple, Spear 9 5/8 casing, Pull mandrell hanger with pack-off and casing to rig floor - Work pipe at 200k to get casing to rig floor - Install false bowl and slips for 9 5/8 - Release and Lay down spear - P/U 150 ton 9 5/8 side door elevator and pick up casing, Have full string, Missed cut at 69' Printed: 7/6/2004 1 :44:23 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/12/2004 7/4/2004 Spud Date: 9/5/1982 End: 7/4/2004 6/17/2004 19:30 - 20:30 1.00 FISH C DECOMP Pre-Job safety meeting -Blow down top drive, Rig up to lay down 9 5/8 casing 20:30 - 00:00 3.50 FISH C DECOMP Lay down 9 5/8 casing - 20k over pull as casing collars pass collaspe section of 13318 - Casing connections tight, Hammer and break with rig tong before backing out with power tongs- 34 jts down at 2400 hours - Well stable 6/18/2004 00:00 - 02:00 2.00 FISH C DECOMP Finish laying down 9 5/8 casing from 1,974' - total 47 jts + 21.42' cut jt. - Cut very rough looking 02:00 - 03:00 1.00 FISH C DECOMP Clear rig floor of Tools and clean up oil base mud 03:00 - 05:00 2.00 FISH C DECOMP Pick up 12 1/4" Stab, RIH, Tag at 33' - Make up 81/4" Casing cutter with 14" max sweep knives, 12 1/4" stablizer spaced out above at 32' - RIH with cutter to 46' 05:00 - 06:00 1.00 FISH C DECOMP Cut 13 3/8 72# at 46' - cut with 45 rpm's, 195 gpm with 1500 psi 06:00 - 07:00 1.00 FISH C DECOMP Break and lay down BHA 07:00 - 07:30 0.50 FISH C DECOMP Make up closed TIW valve on Drill collars - RIH with two stands and displace out fluid - Drain stack - Pooh without filling hole 07:30 - 09:30 2.00 FISH C DECOMP Nipple down and set back Bop stack 09:30 - 12:30 3.00 FISH C DECOMP Prepare Cellar for Hot work - Cut off 20 x 13 3/8 diverter cap from 20" 12:30 - 13:30 1.00 FISH C DECOMP Rig up slings - Pull 16' of 13 3/8 stub and casing head - lay down with loader out of cellar - 13 3/8 Caisng collasped down to 10 5/8 I D - 4' split in casing 13:30 - 15:00 1.50 FISH C DECOMP With Vac truck, suck out 13318 caisng to +1- 15' down, Fill with 25 gallons water 15:00 - 18:30 3.50 WHSUR C DECOMP Prep 20" stub - Weld on FMC 20" Landing ring 18:30 - 00:00 5.50 WHSUR C DECOMP Change drip pan from 13318 to 20" opening - Nipple up 21 1/4" 2,000# x 20" diverter riser on to landing ring - Cut to fit and weld out 20" Riser with 21 1/4" 2000# bottom flange and install 6/19/2004 00:00 - 01 :30 1.50 WHSUR C DECOMP Finish nipple up 20" Riser 01 :30 - 02:00 0.50 FISH C DECOMP Break connections on Spear and Lay down 02:00 - 04:00 2.00 FISH C DECOMP Make up milling BHA: 6 - 61/2" drill collar below, Two 12.191 OD string mills, Two 10 1/4" Boot baskets, 6 1/4" Bumper sub and oil jars, 1 - 6 1/2" Drill collar above 04:00 - 06:00 2.00 FISH C DECOMP Tag up with Bottom mill at 47' - Open up ID of 13318 casing to 12.191" 47' to 55' - clean below 55' - rotate at 70 -75 rpm's, Pumping at 500 gpm with 300 psi - Ream down to 175' 06:00 - 07:30 1.50 FISH C DECOMP Pooh, Stand back drill collars below mills - Lay down boot baskets, recovered 310# metal 07:30 - 09:00 1.50 FISH C DECOMP Make up BHA with 12.19" mill and TIH with Mills to 1,000' 09:00 - 09:30 0.50 FISH C DECOMP Circulate at 500 gpm 640 psi, a lot of solids in returns, no noticable arctic pack 09:30 - 11 :30 2.00 FISH C DECOMP Continue TIH to 9 5/8 stub at 1,974', - Taking wt 1,096, 1,478 & 1,618' - Ream tight spot with 2-3K, small amount of gas breaking as reaming down and circulate bottom up at each tight spot - lot of solids, no noticeable arctic pack 11 :30 - 13:30 2.00 FISH C DECOMP Circulate hole clean wtih 546 gpm 1000 psi - full returns, well stable 13:30 - 16:30 3.00 FISH C DECOMP Pooh, Lay down BHA, Clear and Clean rig floor 16:30 - 18:00 1.50 FISH C DECOMP Rig up Baker fishing rig tongs, - Pick up 1-jt 16" wash pipe, Make up wash over shoe with 17.375 od x 14.5" id - Make up drive sub and 1- 61/4" drill collar - Tag up 13318 stub at 47' 18:00 - 00:00 6.00 FISH C DECOMP Washover 13318 casing 47 to 68' at 2400 hrs - pumping 500 to Printed: 7/6/2004 1 :44:23 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 6/19/2004 18:00 - 00:00 6.00 FISH C DECOMP 300 gpm, Rotate at 60 -70 rpm's, 5-15k wOb, Torque 1000 to 3000 fV# - Slow going, Junk under shoe from 65', hard cement and metal over shakers 6/20/2004 00:00 - 03:00 3.00 FISH C DECaMP Continue Washing over 13318 casing - 68' to 71' - Hard going, Junk under shoe 03:00 - 04:00 1.00 FISH C DECaMP Pooh, Change out wash over shoe, shoe worn out, pick up additional drill collar 04:00 - 09:00 5.00 FISH C DECaMP Continue washing over and milling junk 71 to 74' - Pumping 378 gpm at 190 psi, 10 -15 wOb, torque 1000 - 6000 ft/# up to stalling top drive at 16,000 ft/#, - Hard going 09:00 - 10:00 1.00 FISH C DECaMP Pooh, Inspect burning shoe - shoe has gauge ring above cutrite that may be hampering progress - Change out burning shoe 10:00 - 15:00 5.00 FISH C DECaMP Continue washing over 13318 and milling on junk 74 to 82' - casing collar at 70' - Pumping 500 gpm at 220 psi - 15k wob, 1000 to 6000 torque 15:00 - 16:30 1.50 FISH C DECaMP Pooh - Lay down 16" wash pipe - Clear rig floor 16:30 - 17:30 1.00 FISH C DECaMP Make up 12.191" string mill, - RIH, tag tight spot at 50' - Ream out - RIH to 190', no obstruction 17:30 - 18:00 0.50 FISH C DECaMP Circulate hole clean - pull up to 90' - spot clean mud 90' to surface 18:00 - 18:30 0.50 FISH C DECaMP Lay down Mill, clear rig floor 18:30 - 22:00 3.50 FISH C DECaMP Make up Baker 13318 back off tool with 6 - 61/4" drill collars below - RIH and spot top anchor at 66' - Casing collar at 70' - Pressure up to 1800 psi and set bottom anchor, verify with 20K slack-off - Pressure up to 2500 psi and set top anchor, Continue pressure up and cycle tool at 3500 psi, Bled off pressure and cycle tool total of five time, 500 psi to cycle tool last time - Pooh lay down back-off tool, stand back drill collars 22:00 - 00:00 2.00 FISH C DECaMP Make up Spear with 8.681" grapple & 10' extension - RIH and latch fish with stop at 47' - Pick up 10K and rotate free - With 3 turns to left, fish free - Pooh, set 13 3/8 stub in bowl and slips, install safety clamp - Release spear - Lay down caisng stub - Pin end of 13318 damaged, worn down by milling over, +1- 1/8 of casing collar in hole milled away 6/21/2004 00:00 - 01 :00 1.00 FISH C DECaMP Lay down 23' 13318 casing stub - Lay down spear & clear rig floor 01 :00 - 02:00 1.00 FISH C DECOMP Inspect and service top drive 02:00 - 02:30 0.50 FISH C DECaMP Safety meeting with drill crew and Schlumberger 02:30 - 05:00 2.50 FISH C DECaMP Rig up Schlumberger E-Line - RIH with CCL 1640 gr String shot 6' long - Locate 9 5/8 casing collar at 1,995' correlated to US IT log dated 6/15/2004 - Fire string shot across collar- Pooh, Rig down Schlumberger 05:00 - 06:30 1.50 FISH C DECaMP Make up Baker 9 5/8 Back-Off tool with 9 - 6 1/4" drill collars below 06:30 - 08:00 1.50 FISH C DECaMP TIH with Back-off tool to 1,995 08:00 - 09:30 1.50 FISH C DECaMP Position top anchor at 1,990' - Pressure up with rig pump and set bottom anchor with 1500 psi, Continue pressure up and set top anchor with 2000 psi, Continue pressure up and cycle tool with 2300 psi, Bled off pressure and cycle tool total five times, final pressure 750 psi to cycle tool - Release tool with straight pick up 09:30 - 10:00 0.50 FISH C DECaMP Pooh, wet pipe Printed: 7/6/2004 1 :44:23 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 6/21/2004 10:00 - 11 :00 1.00 FISH C DECOMP Cut and slip drill line 11 :00 - 13:00 2.00 FISH C DECOMP Finish pooh, Lay down back-off tool, stand back drill collars 13:00 - 14:30 1.50 FISH C DECOMP Make up Spear with 8.681 grapple - TIH - Tag top of fish at 1,974' 14:30 - 15:00 0.50 FISH C DECOMP Latch fish, Back out stub with 9 turns to left - Circulate bottoms up at 500 gpm, 250 psi 15:00 - 17:00 2.00 FISH C DECOMP Pooh, Lay down 19.32' of 9 5/8 casing stub, left box in hole- pin in good shape - Lay down fishing tools, Clear rig floor 17:00 - 21 :30 4.50 FISH C DECOMP Remove 20" Riser, modify riser with slip joint to allow riser to be picked up 2' to set slips on 9 5/8 casing 21 :30 - 00:00 2.50 CASE C DECOMP Rig up Power tongs, false bowl and slips - Make up Baker fishing triple connection with 11 3/4" guide and 9 5/8 btc casing pin down, Baker lok triple connection - Install Halliburton 9 5/8 40# ES Cementer one jt above triple connection and Baker-Lok both sides - Continue to Run 9 5/8 47# L-80 Btc-mod Caisng - Oil mud running over top, Run slowly until enough pipe in hole to pump slug - 17 jts in hole at 2400 hrs 6/22/2004 00:00 - 00:30 0.50 CASE C DECOMP Mix and pump slug 00:30 - 02:30 2.00 CASE C DECOMP Finish running 9 5/8 47# L-80 Btc-Mod casing total 48 jts 1,969' - Make up torque 10,000 ftllbs, Best of life 2000 NM pipe dope - Pick up 20' pup jt as landing Joint - Make up xo and top drive 02:30 - 03:00 0.50 CASE C DECOMP Break circulation, Wash down and clean connection- Screw into 9 5/8 at 1,995', total of 13 rounds with 10,000 ftllbs torque- Pull test to 125K, OK 03:00 - 04:00 1.00 CASE C DECOMP Break out top drive crossover, Make up Dowell cement head - Pressure up with rig pump and open Halliburton ES Cementer at 1,951' with 1400 psi - Circulate one casing volume at 330 gpm 1 000 psi. Be aware, ES Cementer is 9-5/8", 40#, L-80 and is the weak link in the casing string. 04:00 - 06:00 2.00 CASE C DECOMP Pump 5 bbls CW100, Test Lines 3000 psi, Pump 25 bbls CW 1 00 followed by 1123 sx Arctic Set I, yield .93 cf/sx - 186 bbls slurry mixed at 15.7 ppg - Drop closing plug and displace with 143 bbls of fresh water - Close ES cementer with 1600 psi - 58 bbls of cement to surface - full returns. RD cement head and circulation lines. Flush the riser and the flowline. Cement in place @ 0522 06:00 - 08:00 2.00 CASE C DECOMP Raise the 20" riser up 2'. Set the 9-5/8" casing in the slips with 125K tension. Drain the 9-5/8" casing. Cut and bevel the 9-5/8" casing with the Wach's Cutter. ND 20" riser. 08:00 - 12:00 4.00 CASE C DECOMP Tack weld the Bell Nipple. Install 9-5/8" Hot Head to preheat. Weld Bell Nipple. Install Hot Head to post heat. Wrap with insulation. 12:00 - 22:30 10.50 CASE C DECOMP Wait on the wellhead to cool down. Clean rig. Construct the Wellhead Assembly, consisting of the Spools and the Adapter Flange, away from the well while waiting for the weld to cool. Weld was tested to 300/1300 psi - good test. 22:30 - 23:00 0.50 CASE C DECOMP NU Wellhead Assembly. Metal to metal seal was tested to 1000 psi - good test. 23:00 - 00:00 1.00 CASE C DECOMP NU BOPE. 6/23/2004 00:00 - 01 :00 1.00 CASE C DECOMP NU BOPE. 01 :00 - 05:30 4.50 CASE C DECOMP MU test joint and set the test plug. Test BOPE and all Printed: 7/6/2004 1 :44:23 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 6/23/2004 01 :00 - 05:30 4.50 CASE C DECOMP associated equipment to 250/3500 psi. Witness of the test was waived by Lou Grimaldi of the AOGCC. 05:30 - 07:30 2.00 CASE C DECOMP Pull test plug and set wear ring. MU BHA to 952' - Junk Mill, 2 x Boot Baskets, Float Sub, Oil Jars, 9 x Drill Collars, HWDP. 07:30 - 09:00 1.50 CASE C DECOMP PU DP from 952' and tag cement @ 1,896'. Drill Cement from 1,896'. Drill ES Cementer @ 1,951' -12 bpm, 700 psi. 09:00 - 09:30 0.50 CASE C DECOMP Test 9-5/8", 47#, L-80 to 2,620' (FastDrill) to 3,500 psi and hold for 15 min - good test. 09:30 - 11 :00 1.50 CASE C DECOMP PU DP from 1,989' and tag up on FastDrill Plug @ 2,620'. Drill FastDrill Plug in 15 minutes - 12.5 bpm, 1000 psi. 11 :00 - 14:00 3.00 CASE C DECOMP PU DP from 2,620' to 5,777'. 14:00 - 17:30 3.50 CASE C DECOMP Test Csg to 3,500 psi - no good. Check surface equipment, tighten gland nuts, changeout bull plug. Re-test casing to 3,500 psi - no good. Verify surface equipment holding 3,500 psi. 17:30 - 19:00 1.50 CASE C DECOMP RIH wI DP from 5,777' to 9,334'. 19:00 - 20:30 1.50 CASE P DECOMP Pump Spacer and Displace well over to 10.4 ppg LSND drilling fluid. 20:30 - 22:30 2.00 CASE C DECOMP Pressure test casing to 3,500 psi - loss of 350 psi in 30 minutes. 3 attempts to verify test due to 10% lost failed. 22:30 - 00:00 1.50 CASE C DECOMP POH from 9,334' to 5,530'. 6/24/2004 00:00 - 01 :30 1.50 CASE C DECOMP POH from 5,530' to 952'. 01 :30 - 03:00 1.50 CASE C DECOMP Stand back HWDP and Drill Collars. LD Oil Jars and Boot Baskets. Clear and clean floor. 03:00 - 03:30 0.50 CASE C DECOMP Pressure test the 9-5/8" casing to 3,500 psi - test failed. 03:30 - 08:00 4.50 CASE C DECOMP MU HES 9-5/8" RTTS and RIH on DP to 9,270'. 08:00 - 09:00 1.00 CASE C DECOMP Circulate bottoms up @ 9,270' - 13 bpm, 1,900 psi. 09:00 - 09:30 0.50 CASE C DECOMP Set RTTS and test 9-5/8" casing to 3,500 psi. Isolate surface lines. Test failed. 09:30 - 11 :30 2.00 CASE C DECOMP Release RTTS and POH from 9,270' to 5,542'. 11 :30 - 12:00 0.50 CASE C DECOMP Set RTTS and test 9-5/8" casing from 5,542' to bottom to 3,500 psi. Isolate surface lines. Hold test for 10 minutes - good. 12:00 - 13:30 1.50 CASE C DECOMP Release RTTS and POH from 5,542' to 4,015'. 13:30 - 15:00 1.50 CASE C DECOMP Set RTTS and test 9-5/8" casing from 4,015 to surface to 3500 psi - failed. Test from 4,015' to bottom to 3,500 psi - good. 15:00 - 16:00 1.00 CASE C DECOMP Release RTTS and POH from 4,015' to 2,800'. 16:00 - 17:30 1.50 CASE C DECOMP Set RTTS and test 9-5/8" casing from 2,800' to surface to 3500 psi - failed. Test from 2,800' to bottom to 3,500 psi - good. 17:30 - 19:30 2.00 CASE C DECOMP Release RTTS. Pump dry job and POH from 2,800'. LD RTTS and RD all testing lines in the cellar. Clear the floor. 19:30 - 22:30 3.00 STWHIP P WEXIT MU Whipstock Assembly. Upload MWD and orient. Test MWD - good. Whipstock Assy: Anchor, Slide, Starting Mill, Lower Mill, Upper Mill, 1 x HWDP, Float Sub, MWD, Bumper Sub, 9 x Drill Collars, 21 x HWDP. 22:30 - 00:00 1.50 STWHIP P WEXIT RIH wI Whipstock Assy on DP to 3,553'. 6/25/2004 00:00 - 03:00 3.00 STWHIP P WEXIT RIH wI Whipstock Assy on DP from 3,553' to 9,334'. 03:00 - 03:30 0.50 STWHIP P WEXIT Service Top Drive. 03:30 - 04: 15 0.75 STWHIP P WEXIT Orient Whipstock top 90 LHS. 04:15 - 10:30 6.25 STWHIP P WEXIT Set the Whipstock with 25K and shear the pin. PU above and time mill the window. Top of the window @ 9,310', Bottom of Window @ 9,326' - 430 gpm, 1,880 psi. PU - 21 OK, SO - Printed: 7/6/2004 1 :44:23 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 6/25/2004 04:15 - 10:30 6.25 STWHIP P WEXIT 155K, 60 rpm. Drill new hole to 9,340'. 10:30 - 11 :30 1.00 STWHIP P WEXIT Sweep the hole @ 9,340' - 517 gpm, 2,670 psi. Recovered 125# of metal from window milling operations. 11 :30 - 12:00 0.50 STWHIP P WEXIT Pull back into casing and perform FIT w/1 0.4 ppg fluid. Apply 460 psi for FIT EMW = 11.5 ppg. 12:00 - 12:30 0.50 STWHIP P WEXIT Flow check the well - stable. Pump dry job. Pull one stand and LD single joint. 12:30 - 13:30 1.00 STWHIP P WEXIT Cut oft drilling line and service the top drive. 13:30 - 16:00 2.50 STWHIP P WEXIT POOH from 9,215' to 1,008'. 16:00 - 17:30 1.50 STWHIP P WEXIT Stand back HWDP and Drill Collars. LD Mills. Clear floor. Upper Mill came out full gauge. 17:30 - 18:30 1.00 STWHIP P WEXIT Pull and service wear ring. Flush the stack. Set wear ring. 18:30 - 20:30 2.00 STWHIP P WEXIT PJSM. MU 8.5" Drilling BHA to 1,107'. Shallow test the MWD tools - good. 8.5" Drilling BHA: Smith M75HPX Re-run, 7" motor lobe 7/8 - 6 stage, non-mag float sub, HCIM/GR, DM HOC, TM HOC, 3 x non-mag flex drill collars, 9 X drill collarS, 6 x HWDP, drilling jar, 15 x HWDP, XO. 20:30 - 23:30 3.00 STWHIP P WEXIT RIH from 1,107' to 9,229'. Install blower hose and orient tool face to 90 LHS. RIH to 9,335 without problems. 23:30 - 00:00 0.50 DRILL P LNR1 Ream undergauged hole from 9,335' to 9,340'. Dir Drill ahead to 9,346'. AST - 0.5, ART - o. PU - 215K, SO - 150K. 548 gpm, 2,700 psi. 6/26/2004 00:00 - 08:30 8.50 DRILL P LNR1 Dir Drill ahead from 9,345' to 9,753'. PU - 220K, SO - 160K, ROT - 185, 570 gpm, 3,350 psi. ART - 1, AST - 4.68 08:30 - 09:30 1.00 DRILL P LNR1 Circulate Hi-Visc sweep around - 13 bpm, 3,200 psi. 09:30 - 10:30 1.00 DRILL P LNR1 Rotate ahead taking samples from 9,753' to 9,757' (TD) - ART 0.12. 10:30 - 11:00 0.50 DRILL P LNR1 POH from 9,757' into the window to 9,275'. 20K overpull seen @ 9,584'. Run back to bottom without problem. 11 :00 - 12:30 1.50 DRILL P LNR1 Circulate on bottom - 13 bpm, 3,200 psi. Spot liner running pill. 12:30 - 14:00 1.50 DRILL P LNR1 Drop ESS w/2" drift. Survey @ 9,757' and 9,688'. MAD Pass from 9,757' to 9,280' 14:00 - 16:30 2.50 DRILL P LNR1 POH from 9,280' to 1 ,107' . 16:30 - 19:00 2.50 DRILL P LNR1 LD 8.5" Drilling BHA from 1,107'. Flush tools. Retrieve ESS. Download MWD tools and clear the floor. 19:00 - 20:00 1.00 CASE P LNR1 PJSM. RU 7" Liner handling equipment. 20:00 - 20:30 0.50 CASE P LNR1 PU Float equipment and RIH. Check floats - good. Fi rst 3 joints Bakerloc'd 20:30 - 21 :30 1.00 CASE P LNR1 PU 7", 26#, L-80, BTC-M liner and RIH. PU HMC Liner Hanger, ZXP Packer, XO, 5' DP pup to 619'. Changeout the handling equipment. Ran a total of 14 joints of 7" casing. Torque - 7,000 ftlbs. Best-o-life 2000 thread lubricant used. Liner Weight - 12K 21 :30 - 22:00 0.50 CASE P LNR1 Circulate Liner volume - 3 bpm, 120 psi. 22:00 - 00:00 2.00 CASE P LNR1 RIH with liner on 4" DP from 619' to 5,289'. Fill Pipe every 10 stands. 6/27/2004 00:00 - 02:00 2.00 CASE P LNR1 RIH with liner on 4" DP from 5,289' to 9,310'. Fill Pipe every 10 stands. LD a single joint of DP. 02:00 - 02:30 0.50 CASE P LNR1 Circulate a Liner and DP volume. 02:30 - 03:00 0.50 CASE P LNR1 RIH with liner on 4" DP from 9,310' to 9,756'. Printed: 7/6/2004 1 :44:23 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 6/12/2004 7/4/2004 Spud Date: 9/5/1982 End: 7/4/2004 6/27/2004 03:00 - 04:00 1.00 CEMT P LNR1 Circulate and condition fluid for cement job. Stage up pumps to 6 bpm. Rig up cement head. 04:00 - 05:30 1.50 CEMT P LNR1 PJSM. Pump Cement Job as follows: Flush 5 bbls fresh water to clear lines. Shut down and pressure test Schlumberger lines to 4,500 psi. Pump 28 bbls of 11.4 ppg Mudpush Spacer @ 4 bpm. Initial- 1,000 psi, Final - 540 psi. Pump 34 bbls of 15.8 ppg cement @ 4.3 bpm. Initial - 613 psi, Final - 238 psi. Displace with the rig. Catch up to the falling cement @ 375 stks - 100 spm, 600 psi. Land casing @ 1,200 stks pumped - 870 psi. Reduce rate to 50 spm @ 1,300 stks - 460 psi. Observed pick up of liner top plug @ 1,415 stks. Bump plug @ 1,751 stks with 4,000 psi. Cement in place @ 05206/27/2004 Set down 20K to set HMC Hanger - good set. Bleed off pressure and check floats - holding. Rotate 15 turns to the right to release from the hanger. Raise DP pressure to 1,000 psi and pick up out of the hangerlpacker assembly. Pump 500 stks @ 12 bpm to get cement above the liner top up the hole. Set down 60K and observe the pins shear on the ZXP packer. Set down 2 more times to ensure set. Rotate down to ensure set of the ZXP packer. Float Shoe @ 9,754' Float Collar @ 9,713' Landing Collar @ 9,672' Liner Hanger @ 9,170' Liner Top Packer @ 9,164' Top of Liner Tieback Sleeve @ 9,152' 05:30 - 07:30 2.00 CEMT P LNR1 Circulate the hole clean - 13 bpm, 3,500 psi. PU - 170K, SO- 130K. Pump dry job. Trace of cement circulated to surface. LD cement head. Cleand and clear floor. 07:30 - 11 :30 4.00 CEMT P LNR1 POH from 9,152' to surface. LD running tool and clear the floor. 11 :30 - 13:00 1.50 CASE C TIEB1 Pull Wear Ring. RU 7" handling equipment. 13:00 - 13:30 0.50 CASE C TIEB1 PJSM. MU Seal Assembly. 13:30 - 21 :30 8.00 CASE C TIEB1 PU 222 joints of 7", 26#, L-80, BTC-M casing + 20' Pup and 6' Pup and tag up on nogo @ 9,162'. Best-o-life 2000 thread lubricant used. Torqued all connections to 7,500 ft-Ibs. 21 :30 - 22:30 1.00 CASE C TIEB1 LD 6' Pup and rig up long bails and 200 ton elevators. MU cement head and circulation lines. 22:30 - 23:00 0.50 CASE C TIEB1 PU 6' Pup joint and sting seal assembly into tieback sleeve - nogo @ 9,162'. Test seals to 500 psi - good. PU and expose the ports. Circulate @ 6 bpm, 1,325 psi during PJSM for cement job. 23:00 - 00:00 1.00 CEMT C TIEB1 Pump 5 bbls Water. Shut down and pressure test Schlumberger lines to 4,000 psi. Pump 25 bbls water spacer @ 6 bpm. Initial -1,100 psi. Final- 1,414 psi. Printed: 7/6/2004 1 :44:23 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 6/27/2004 23:00 - 00:00 1.00 CEMT C TIEB1 Pump 100 bbls of 9.4 ppg OBM @ 4.7 bpm. Intitial- 1,325 psi. Final - 1,300 psi. Pump 10 bbls of 7.1 ppg LVT 200 @ 4 bpm, 1,100 psi. Shut down and drop bottom plug. Batch up Lead Cement to 13.5 ppg. 6/28/2004 00:00 - 02:00 2.00 CEMT C TIEB1 Pump 149 bbls of 13.5 ppg Lead @ 4.9 bpm. Initial-1,690 psi. Final - 1,200 psi. Pump 29 bbls of 15.8 ppg Tail @ 4.7 bpm. Initial- 1,350 psi. Final - 1 ,200 psi. Drop Top Plug. Clear lines with 5 bbls of water. Switch to rig for displacement. Pump 349 bbls of 10.4 ppg LSND mud @ 10 bpm. Initial- 1,300 psi. 2,900 strokes pumped - 940 psi. 4,700 strokes pumped - 1,930 psi. Drop Rate to 6 bpm @ 4,800 strokes pumped - 1,150 psi. 5,200 strokes pumped - 1,310 psi. Drop rate to 4 bpm @ 5,300 strokes pumped - 1,170 psi. Drop rate to 3 bpm @ 5,500 strokes pumped - 1,210 psi. Drop rate to 2 bpm @ 5,600 strokes pumped - 1,050 psi. Bump plug @ 6,059 strokes pumped. Bumped with 2,400 psi - 1,000 psi over. 93% pump efficiency. Slack off to engage seals while bleeding off pressure. Check seals - holding. RD cement head. Ported Seal Assembly @ 9,152' Locator Sub @ 9,151' Float Collar @ 9,130' - 3/8" hole drilled into float. 02:00 - 07:30 5.50 WHSUR C TIEB1 PU 240K and split the stack. Set the emergency slips and cut the 7" casing with the Wach's cutter. Install Packoff. NU stack. Test packoff 4,300 psi. Changeout bails. Install Wear Ring. 07:30 - 11 :00 3.50 DRILL P PROD1 PJSM. PU MWDLWD tools. Load Nukes. Orient and Upload Tools. Surface Test MWD - good. MU BHA to 363'. 6-1/8" BHA: Smith XR20, 5" Motor (7/8 - 6 stg) w/ABI and jet, Stab, Non-mag Float Sub, RLL, DM HOC, Nuke, TM HOC, 3 x Non-mag flex collars, circ sub, 4 x HWDP, Jar. 11 :00 - 12:30 1.50 DRILL P PROD1 Service Top Drive. Cut and slip drilling line. 12:30 - 13:30 1.00 DRILL P PROD1 PU DP from 363' to 2,233'. 13:30 - 16:00 2.50 DRILL P PROD1 RIH wlDP from 2,233' to 9,120'. Fill pipe every 3,000'. Install blower hose. Tag cement @ 9,120'. 16:00 - 16:30 0.50 DRILL P PROD1 Test casing from 9,120' to surface to 3,500 psi for 15 minutes - good test. 16:30 - 18:00 1.50 DRILL P PROD1 Drill cement from 9,120'. Drill Float Collar @ 9,133'. RIH wI DP. Drill cement stringers from 9,600' to the landing collar @ 9,672'. 18:00 - 19:30 1.50 DRILL P PROD1 Circulate bottoms up - 5.5 bpm, 2,400 psi. 19:30 - 20:00 0.50 DRILL P PROD1 Pressure test the 7" 26# L-80 casing to 3,500 psi for 30 minutes on chart - good test. 20:00 - 21 :30 1.50 DRILL P PROD1 Drill Landing collar @ 9,672'. Drill Float Collar @ 9,716' and Shoe Track to 9,755'. Printed: 7/6/2004 1 :44:23 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 6/28/2004 21 :30 - 23:00 1.50 DRILL P PROD1 Displace well over to 8.4 ppg FloPro Drilling Fluid. Pump 150 bbls fresh water spacer, 45 bbls EP Mud Lube spacer, and FloPro mud. Clean under shakers. 23:00 - 23:30 0.50 DRILL P PROD1 Drill out the remainder of the shoe track and 20' of new hole to 9,777'. Perform FIT to 9.5 ppg EMW - good test. 23:30 - 00:00 0.50 DRILL P PROD1 Directional Drill ahead from 9,777' to 9,785'. ART - 0.23, AST- 0.12. PU - 175K, SO - 130K, ROT - 130K. 6/29/2004 00:00 - 12:30 12.50 DRILL P PROD1 Directional Drill ahead from 9,785' to 10,076'. PU - 180K, SO- 140K, ROT - 155K. 285 gpm, 2470 psi. ART - 0.8, AST - 6.69. 12:30 - 13:00 0.50 DRILL P PROD1 Circulate bottoms up - 280 gpm, 2,150 psi. Monitor Well - stable. 13:00 - 13:30 0.50 DRILL P PROD1 POH with DP from 10,076' to 9,756'. Drop dart and open circ sub. Pump dry job. Blow down surface equipment. 13:30 - 16:30 3.00 DRILL P PROD1 POH wI DP from 9,756' to 363'. 16:30 - 19:00 2.50 DRILL P PROD1 Stand back BHA from 363'. PJSM. Remove nuclear source. Download MWD tools. Change out the DM tool. LD Stabilizer. Adjust motor to 1.76. Change out the bit. Add a kick pad. 19:00 - 20:00 1.00 DRILL P PROD1 Upload MWD Tools. Load nuclear source. PU BHA to 359'. Shallow test MWD tools - good. 20:00 - 23:00 3.00 DRILL P PROD1 RIH wI 6-1/8" BHA #2 on DP from 359' to 9,756'. Fill pipe every 3,000'. 23:00 - 23:30 0.50 DRILL P PROD1 Service top drive. Install blower hose. Fill pipe. 23:30 - 00:00 0.50 DRILL P PROD1 RIH wI DP from 9,576' to 10,076'. 6/30/2004 00:00 - 19:30 19.50 DRILL P PROD1 Directional Drill ahead from 10,076' to 10,853'. PU - 185K, SO - 135K, ROT - 160K. AST - 9.43, ART - 4.14. TO on - 6-7K, TO off - 5-6K. 270 gpm, 2,300 psi. 19:30 - 21 :00 1.50 DRILL P PROD1 Work pipe @ 10,853'. Sweep the hole and circulate bottoms up - 270 gpm, 2,100 psi. 21 :00 - 00:00 3.00 DRILL P PROD1 Directional Drill ahead from 10,853' to 11,001'. PU - 185K, SO - 135K, ROT - 160K. AST - 0.29, ART - 1.56. TO on - 6-7K, TO off - 5-6K. 270 gpm, 2,300 psi. 7/1/2004 00:00 - 04:30 4.50 DRILL P PROD1 Directional Drill ahead from 11,001' to 11,275' (TD). PU - 185K, SO - 135K, ROT - 160K. TO on - 6-7K, TO off - 5-6K. 270 gpm, 2,300 psi. AST - 0.57, ART - 2.64 04:30 - 06:00 1.50 DRILL P PROD1 Circulate a High Vise sweep at TD - 270 gpm, 2,150 psi. Monitor well - static. 06:00 - 07:00 1.00 DRILL P PROD1 POH from 11,275' to 9,700' without problem. 07:00 - 07:30 0.50 DRILL P PROD1 Service the top drive and the crown. 07:30 - 08:30 1.00 DRILL P PROD1 RIH from 9,700' to 11,275' without problem. 08:30 - 10:00 1.50 DRILL P PROD1 Circulate High Visc sweep - 270 gpm, 2,150 psi. Spot 65 bbl liner running pill. Monitor well - static. 10:00 - 11 :30 1.50 DRILL P PROD1 LD DP from 11,275' to 9,980'. POH from 9,980' to 9,700'. 11 :30 - 12:00 0.50 DRILL P PROD1 Drop dart and open the circ sub. Pump a dry job and remove the blower hose. Blow down the top drive. 12:00 - 15:00 3.00 DRILL P PROD1 POH wI 4" DP from 9,700' to 359'. 15:00 - 17:00 2.00 DRILL P PROD1 PJSM. LD BHA from 359' to 197'. Remove nuclear source. Flush MWD tools with water. Download MWD tools. LD BHA from 137' and clear the floor. 17:00 - 18:00 1.00 CASE P PROD1 PJSM. RU 4-1/2" liner running equipment. PU float equipment and check floats - good. 18:00 - 20:00 2.00 CASE P PROD1 PU 4-1/2",12.6#, IBT-M liner to 1,664'. MU Hgr/Pkr/Tieback Assembly to 1.696'. RD liner running equipment. Liner weight - 15K. Alii float equipment is Bakerloc'd. Utilized Best-o-life Printed: 7/6/2004 1 :44:23 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 7/1/2004 18:00 - 20:00 2.00 CASE P PROD1 2000 thread lubricant. Torqued liner connections to 3,200 ft-Ibs. 20:00 - 20:30 0.50 CASE P PROD1 Circulate liner volume - 4 bpm, 150 psi. 20:30 - 00:00 3.50 CASE P PROD1 RIH with liner on 4" DP from 1,696' to 8,202'. Fill pipe every 10 stands. 7/2/2004 00:00 - 01 :00 1.00 CASE P PROD1 RIH with liner on 4" DP from 8,202' to 9,670'. Fill pipe every 10 stands. PU - 170K, SO - 135K 01 :00 - 01 :30 0.50 CASE P PROD1 Circulate DP volume - 6 bpm, 850 psi. 01 :30 - 02:30 1.00 CASE P PROD1 Run liner into open hole from 9,670' to 11,255'. RU cement head and tag bottom @ 11,275'. PU -185K, SO - 145K. Float Shoe @ 11,272' Float Collar @ 11,229' Landing Collar @ 11,187' 02:30 - 03:30 1.00 CEMT P PROD1 Circulate and gradually increase rate to 6 bpm. Hold PJSM and batch cement. Cement to 15.8 ppg @ 0330 03:30 - 04:40 1.17 CEMT P PROD1 Pump cement job with reciprocation as follows: Pump 5 bbls Fresh Water ahead PT lines to 4,500 psi. Pump 15 bbls CW 100 @ 4.5 bpm, Initial - 1,200 psi, Final - 1,350 psi. Pump 27 bbls 9.5 ppg Mudpush II @ 4.5 bpm , Initial - 1,150 psi, Final - 1,060 psi. Pump 44 bbls 15.8 ppg Latex Cement @ 4.5 bpm, Initial - 1,500 psi, Final - 900 psi Flush lines wI 3 bbls of Perf Pill. Drop Plug. Start Displacement. Pump 48.5 bbls 8.4 ppg Perf Pill @ 5.3 bpm, Initial - 315 psi, Final - 275 psi. Pump 68.5 bbls 8.7 ppg Mud @ 7 to 2 bpm. Initial - 530 psi, Final - 1600 psi. Caught cement 65 bbls into total displacement. Landed liner @ 75 bbls into total displacement. Bump plug @ 118 bbls of displacement - Cement in place @ 0440 04:40 - 05:00 0.33 CASE P PROD1 SO and set 20K down. Bleed off pressure and check floats - holding. Swap from Dowell to the rig. Rotate 20 turns to the right to release from HMC hanger while applying 1,000 psi on the DP. Expose the seals and circulate 500 strokes @ 10.5 bpm, 2,500 psi. PU and Expose the dogs. Set down 50K and observe ZXP Packer set @ 35K SO. Rotate on top of the packer to ensure set. 05:00 - 06:30 1.50 CEMT P PROD1 Circulate bottoms up @ 12 bpm, 2,640 psi - 20 bbls cement returned to surface. Displace the well over to clean seawater. 06:30 - 07:30 1.00 CEMT P PROD1 Blow down surface equipment. LD cement head. Clean under the shakers. 07:30 - 09:00 1.50 CASE P PROD1 Cut drilling line and service the top drive. 09:00 - 12:30 3.50 CASE P PROD1 POH with DP from 9,584'. LD C-2 running tool. Clear the floor. 12:30 - 13:00 0.50 CASE P PROD1 Test casing to 3,500 psi and record on chart for 30 minutes - good. Hold PJSM for Perf Guns during pressure test. 13:00 - 14:00 1.00 PERFO P OTHCMP PU and MU 2-7/8" Perforating Guns handling equipment and tools. 14:00 - 15:30 1.50 PERFO P OTHCMP MU 2-7/8" PowerJET Perf Guns w/4 spf to 317'. Changeout Printed: 7/6/2004 1 :44:23 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 handling equipment and MU Firing Head to 324'. MU 2-7/8" PAC DP from 324' to 1,642'. Changeout handling equipment. 17:00 - 21 :30 4.50 OTHCMP RIH with 4" DP from 1,642' to 11,187'. Position guns over 10,880' to 11,180'. 21 :30 - 22:30 1.00 OTHCMP PJSM. RU SLB. Pressure up to 2,900 psi. Bleed off pressure. Fire guns - good surface indication. POH from 11,180' to 10,807' and monitor the well - stable. Pump dry job and blow down surface equipment. 22:30 - 23:30 1.00 OTHCMP POH from 10,807' to 8,932'. 23:30 - 00:00 0.50 OTHCMP LD DP from 8,932' to 8,154'. 7/3/2004 00:00 - 04:00 4.00 OTHCMP LD DP from 8,154' to 1,642'. 04:00 - 05:30 1.50 OTHCMP Change out handling equipment. LD 2-7/8" PAC DP from 1,642' to 324' 05:30 - 07:30 2.00 OTHCMP PJSM. LD Perforating guns from 324' - all guns fired. Clean and clear the floor. 07:30 - 08:30 1.00 RUNCMP PU test joint and pull the wear ring. LD test joint. RU to run 4-1/2", 12.6#, IBT-M completion. 08:30 - 15:00 6.50 RUNCMP PJSM. PU WLEG, XN Assy, X Assy, S-3 Packer Assy, X assy and RIH. All connections below the packer are bakerloc'd. PU 4-1/2", 12.6#, IBT-M completion to 7,497'. Torque to 4,000 ft-Ibs. Best-o-life 2000 thread lubricant used. 15:00 - 16:00 1.00 RREP RUNCMP Repair skate chain and buggy. 16:00 - 19:30 3.50 RUNCMP PU 4-1/2" tubing from 7,497' and tag @ 9,593'. Spaceout and position WLEG @ 9,592'. MU landing joint and hanger. Land tubing, RILDS. 226 joints 4-1/2",12.6#, L-80, IBT-M + 3.84 pup joint. WLEG - 9,592' XN w/RHC-M + ball and rod - 9,579' X - 9,558' S-3 Packer - 9,535' X - 9,514' GLM - 9,237' GLM -7,811' GLM - 5,920' GLM w/DCK- 3,286' X - 2,185' 19:30 - 22:30 RUNCMP RU Circulating lines and reverse circulate clean seawater, sea water with corrosion inhibitor, and sea water to position corrosion inhibitor below upper GLM @ 3,286' - 3 bpm, 250 psi. 22:30 - 00:00 RUNCMP Test tubing to 3,500 psi and chart for 30 minutes - good. Bleed off to 1,500 psi on the tubing. Pressure test the annulus to 3,500 psi and chart for 30 minutes - good. Bleed off tubing pressure and shear DCK valve. 7/4/2004 00:00 - 03:00 3.00 BOPSU P RUNCMP Install TWC and test from below to 1,000 psi - good. Blow down mud lines and LD mouse hole. ND BOPE's. 03:00 - 06:00 3.00 WHSUR P RUNCMP NU Tubing Adapter Flange. NU 4-1/8" Redressed CIW tree. Test Tree to 5,000 psi - good. RU DSM and pull TWC wI lubricator.. 06:00 - 09:00 3.00 WHSUR P RUNCMP RU LRHOS and reverse circulate 80 bbls diesel freeze protection fluid. Allow diesel to u-tube. Install BPV and test from below - good. RD LRHOS. Printed: 7/6/2004 1 :44:23 PM e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-24 C-24 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 6/12/2004 Rig Release: 7/4/2004 Rig Number: Spud Date: 9/5/1982 End: 7/4/2004 7/4/2004 09:00 - 10:00 1.00 WHSUR P RUNCMP RD circulation hoses. Remove secondary annulus valve. Install flanges and gauges and secure the well. Rig Released to C-17B @ 1000 hours 7/4/2004. Printed: 7/6/2004 1 :44:23 PM . . 16-Jul-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C-24A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,294.12' MD 9,310.00' MD 11,275.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 1k ú lJ / '.' flftJ./'1 ~i (J Uv~> I Date / b Ji) .m '1 Signed Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) .J D v( -- Ò ~...,~ i/ Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA C Pad C-24A Job No. AKMW3126706, Surveyed: 1 July, 2004 Survey Report 15 July, 2004 Your Ref: API 500292081601 Surface Coordinates: 5959793.00 N, 664351.00 E (70· 17' 47.2958" N, 148· 40' 08.6889" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959793.00 N, 164351.00 E (Grid) Surface Coordinates relative to Structure Reference: 2534.28 N, 1856.83 E (True) Kelly Bushing Elevation: 65. 72ft above Mean Sea Level Kelly Bushing Elevation: 65.72ft above Project V Reference Kelly Bushing Elevation: 65. 72ft above Structure Reference SIO,E!I"""I"""Y-SUf1 CRIL.L.ING SERVICES A Halliburton Company DEFINITIVE e e Survey Ref: svy4296 Halliburlon Sperry-Sun Survey Report for PBU_WOA C Pad - C-24A Your Ref: API 500292081601 Job No. AKMW3126706, Surveyed: 1 July, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9294.12 29.870 231.830 7945.73 8011.45 2871.93 S 2880.26 W 5956858.77 N 661534.23 E -2871.93 Tie On Point MWD Magnetic 9310.00 29.780 231.830 7959.51 8025.23 2876.81 S 2886.47 W 5956853.76 N 661528.13 E 0.567 -2876.81 Window Point 9368.98 29.730 228.970 8010.71 8076.43 2895.47 S 2909.02 W 5956834.61 N 661505.99 E 2.408 -2895.47 9404.26 27.680 226.900 8041.66 8107.38 2906.81 S 2921.61 W 5956823.00 N 661493.66 E 6.457 -2906.81 e 9434.33 25.720 224.860 8068.52 8134.24 2916.21 S 2931.31 W 5956813.39 N 661484.16 E 7.195 -2916.21 9464.30 23.100 222.520 8095.81 8161.53 2925.15 S 2939.87 W 5956804.26 N 661475.80 E 9.317 -2925.15 9497.15 20.800 219.520 8126.28 8192.00 2934.40 S 2947.94 W 5956794.84 N 661467.93 E 7.787 -2934.40 9530.72 18.800 215.850 8157.86 8223.58 2943.39 S 2954.90 W 5956785.70 N 661461.17 E 7.012 -2943.39 9561.40 16.890 211.830 8187.06 8252.78 2951.18S 2960.15 W 5956777.79 N 661456.09 E 7.405 -2951.18 9596.74 15.120 206.180 8221.04 8286.76 2959.68 S 2964.89 W 5956769.19 N 661451.54 E 6.667 -2959.68 9620.32 13.210 201.670 8243.90 8309.62 2964.94 S 2967.24 W 5956763.88 N 661449.30 E 9.349 -2964.94 9639.01 12.460 198.060 8262.12 8327.84 2968.84 S 2968.66 W 5956759.95 N 661447.98 E 5.873 -2968.84 9684.80 11.340 194.090 8306.93 8372.65 2977.91 S 2971.28 W 5956750.83 N 661445.55 E 3.028 -2977.91 9713.43 10.570 189.620 8335.04 8400.76 2983.23 S 2972.41 W 5956745.49 N 661444.54 E 4.003 -2983.23 9787.60 8.670 181.210 8408.16 8473.88 2995.53 S 2973.66 W 5956733.16 N 661443.55 E 3.180 -2995.53 9815.55 5.900 173.700 8435.89 8501.61 2999.06 S 2973.55 W 5956729.63 N 661443.74 E 1 0.459 -2999.06 9845.80 3.420 144.340 8466.04 8531.76 3001.34 S 2972.85 W 5956727.37 N 661444.49 E 11.124 -3001.34 9878.56 3.030 88.800 8498.75 8564.47 3002.12 S 2971.42 W 5956726.62 N 661445.94 E 9.230 -3002.12 9907.33 4.630 44.640 8527.46 8593.18 3001.27 S 2969.84 W 5956727.50 N 661447.50 E 11.252 -3001.27 9941.71 7.790 27.610 8561.64 8627.36 2998.22 S 2967.78 W 5956730.60 N 661449.49 E 10.543 -2998.22 9973.24 10.850 19.900 8592.75 8658.47 2993.53 S 2965.78 W 5956735.33 N 661451.39 E 10.461 -2993.53 e 10002.73 13.470 16.690 8621.58 8687.30 2987.63 S 2963.85 W 5956741.27 N 661453.19 E 9.172 -2987.63 10096.61 21.350 12.690 8711.09 8776.81 2960.44 S 2956.95 W 5956768.60 N 661459.50 E 8.485 -2960.44 10130.04 26.250 11.000 8741.67 8807.39 2947.24 S 2954.20 W 5956781.86 N 661461.96 E 14.797 -2947.24 10162.84 31.240 8.540 8770.42 8836.14 2931.70 S 2951.55 W 5956797.46 N 661464.27 E 15.632 -2931.70 10191.10 35.510 6.250 8794.01 8859.73 2916.29 S 2949.57 W 5956812.91 N 661465.91 E 15.751 -2916.29 10223.99 40.720 3.840 8819.88 8885.60 2896.07 S 2947.81 W 5956833.16 N 661467.23 E 16.471 -2896.07 10255.67 45.530 2.340 8843.00 8908.72 2874.46 S 2946.65 W 5956854.80 N 661467.91 E 15.523 -2874.46 10280.51 49.920 1.030 8859.70 8925.42 2856.09 S 2946.12 W 5956873.17 N 661468.04 E 18.098 -2856.09 10315.59 55.080 358.950 8881.05 8946.77 2828.27 S 2946.14 W 5956900.98 N 661467.41 E 15.442 -2828.27 15 July, 2004 - 10:09 Page 2 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-24A Your Ref: API 500292081601 Job No. AKMW3126706, Surveyed: 1 July, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10346.86 60.250 358.520 8897.77 8963.49 2801.86 S 2946.73 W 5956927.37 N 661466.25 E 16.574 -2801.86 10375.13 62.780 357.200 8911.26 8976.98 2777.04 S 2947.66 W 5956952.17 N 661464.77 E 9.845 -2777.04 10409.35 67.210 354.660 8925.72 8991.44 2746.12 S 2949.87 W 5956983.04 N 661461.88 E 14.588 -2746.12 10440.69 71.360 353.960 8936.80 9002.52 2716.95 S 2952.78 W 5957012.13 N 661458.34 E 13.406 -2716.95 10469.33 75.660 352.750 8944.93 9010.65 2689.68 S 2955.96 W 5957039.32 N 661454.56 E 15.551 -2689.68 e 10503.07 81.700 352.390 8951.55 9017.27 2656.89 S 2960.24 W 5957072.01 N 661449.57 E 17.932 -2656.89 10534.02 86.910 350.880 8954.62 9020.34 2626.43 S 2964.72 W 5957102.36 N 661444.43 E 17.519 -2626.43 10562.04 88.150 351.270 8955.83 9021.55 2598.78 S 2969.06 W 5957129.92 N 661439.48 E 4.639 -2598.78 10595.92 87.590 351.230 8957.09 9022.81 2565.32 S 2974.21 W 5957163.26 N 661433.60 E 1.657 -2565.32 10654.96 88.520 351.010 8959.09 9024.81 2507.02 S 2983.32 W 5957221.34 N 661423.22 E 1.619 -2507.02 10689.20 90.250 350.040 8959.46 9025.18 2473.25 S 2988.96 W 5957254.98 N 661416.84 E 5.792 -2473.25 10719.94 93.710 348.520 8958.40 9024.12 2443.07 S 2994.67 W 5957285.03 N 661410.47 E 12.292 -2443.07 10746.87 94.080 348.900 8956.57 9022.29 2416.72S 2999.93 W 5957311.25 N 661404.64 E 1.967 -2416.72 10795.09 91.730 348.610 8954.12 9019.84 2369.49 S 3009.32 W 5957358.27 N 661394.22 E 4.910 -2369.49 10838.78 91.730 353.820 8952.80 9018.52 2326.35 S 3015.99 W 5957401.26 N 661386.61 E 11.919 -2326.35 10890.67 90.430 356.280 8951.82 9017.54 2274.67 S 3020.46 W 5957452.83 N 661381.00 E 5.361 -2274.67 1 0932.42 88.890 355.790 8952.07 9017.79 2233.02 S 3023.35 W 5957494.40 N 661377.20 E 3.871 -2233.02 10981.36 87.960 353.480 8953.42 9019.14 2184.32 S 3027.92 W 5957542.99 N 661371.57 E 5.087 -2184.32 11024.94 90.620 352.080 8953.96 9019.68 2141.09S 3033.40 W 5957586.09 N 661365.15 E 6.897 -2141.09 11117.50 89.690 353.110 8953.71 9019.43 2049.30 S 3045.33 W 5957677.59 N 661351.21 E 1 .499 -2049.30 11207.23 90.370 351.270 8953.66 9019.38 1960.41 S 3057.52 W 5957766.20 N 661337.08 E 2.186 -1960.41 e 11275.00 90.370 351.270 8953.22 9018.94 1893.43 S 3067.81 W 5957832.94 N 661325.33 E 0.000 -1893.43 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11275.00ft., The Bottom Hole Displacement is 3605.07ft., in the Direction of 238.317° (True). 15 July, 2004 - 10:09 Page 3 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-24A Your Ref: API 500292081601 Job No. AKMW3126706, Surveyed: 1 July, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastin9s (ft) (ft) (ft) Comment 9294.12 9310.00 11275.00 8011.45 8025.23 9018.94 2871.93 S 2876.81 S 1893.43 S 2880.26 W 2886.47 W 3067.81 W Tie On Point Window Point Projected Survey e Survey tool prOf/ram for C-24A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9294.12 0.00 9294.12 8011.45 11275.00 8011.45 CB-GYRO-MS (C-24) 9018.94 MWD Magnetic (C-24A) e 15 July, 2004 - 10:09 Page 4 of 4 DrillQuest 3.03.06.002 · TREE = W8..LHEAO= A Cfl..!A. TOR= KB. ELEV = BF. ELEV - KOP- Max Angle = OatumMO- OatumTVO = fj' ŒN McEV OY 011S 71.62' 37.22' 1700' 94 @ 10747' 8866' 8800' SS TOP OF SCA B LNR 13-3/8" CSG, 72#. L-80, 10 = 12.347" C-24A I SAFETY NOTES: 2185' 4-112" I-ESX NIP, 10=3.813" Minimum ID = 3.725" @ 9580' 4-1/2" HES XN NIPPLE ST !'vi) TVO 4 3286 3130 3 5921 5262 2 7811 6758 1 9238 7963 GAS LIFT IW\NDR8..S OEV TYPE VLV LATCH 37 KBG-2 OOfvE BK 38 KBG-2 SO BK 33 KBG-2 0fv1Y BK 30 KBG-2 0fv1Y BK FORT OA TE 16 07/21/04 20 07/21/04 o 07/04104 o 07/04/04 I BOTTOM OF SCAB LNR I 9162' 9164' 9-5/8" X 7" BKR ZXP LNR TOP PKR 9524' H ELMO TT LOGGED 08/23/83 I MlLOUTWINDOW 9310' - 9326' ÆRFORA 110N SUMIW\RY REF LOG: ANGLE AT TOP PERF: 90 @ 10880' Note: Refer to Production œ for historical perf data SIZE SA" NTERVAL Opn/Sqz DATE 2-7/8" 4 10880 - 11180 0 07/03/04 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 4-1/2" HE'S X NIP, 10 = 3.813" 9-518" CSG, 47#, L-80, D = 8.681" 4-1/2" WLEG, 10= 3.958" 7" X 5" BKR ZXP LNR TOP A<RWITIEBAO< SLV 4-112" I-ES X NIP, D = 3.813" 4-1/2" I-ES XN NIP, 10 = 3.725" 7' LNR, 26#, L-80, .0383 bpf, 10 = 6.27fj' I 10660' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" 11187' OA TE REV BY CO MvlENTS 09/23/82 ORIGINAL COM PLETION 07/04/04 JlM/KAK RIG SIDETRACK (C-24A) 07/21104 RMH'KAK GL V C/O DA lE REV BY COMMENTS FRLDHOE SA Y UNIT WELL: C-24A PERMIT No: 2040580 AA No: 50-029-20816-01 SEC 19, T11N, R14E. 1425' FI\l & 1030' ÆL BP Exploration (Alaska) · -- FRANK H. MURKOWSKI, GOVERNOR AI1ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay C-24A BP Exploration (Alaska) Inc. Permit No: 204-058 Surface Location: 1425' SNL, 1030' WEL, SEC. 19, T11N, R14E, UM Bottornhole Location: 3323' SNL, 4081' WEL, SEC. 19, TUN, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissio witness any required test. Contact the Commission's North Slope petroleum field ins ect at 9-3607 (pager). Sin BY ORDER ~Æ:HE COMMISSION DATED thiS'j- day of April, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSI~ECE'VED PERMIT TO DRILL 20 AAC 25.005 APR 12 2004 kiGI\ t..f/n/¿oo4- 1a. Type of work o Drill IBI Redrill rb. Current Well Class o Exploratory !I~~~tfi,c~~i_~n ORe-Entry o Stratigraphic Test o Service 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well NaMtDIUJlt!J!Imber: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU C-24A / 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11257 TVD 9007 Prudhoe Bay Field I Prudhoe Bay,,- 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028305 1425' SNL, 1030' WEL, SEC. 19, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: / Top of Productive Horizon: 3974' SNL, 4057' WEL, SEC. 19, T11N, R14E, UM June 7, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3323' SNL, 4081' WEL, SEC. 19, T11N, R14E, UM 2560 27,070' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 664351 y- 5959793 Zone- ASP4 (Height above GL):Plan 67.2 feet D-13,848' 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) / Kickoff Depth 9330 ft Maximum Hole Angle 93 0 Downhole: 3794 psig Surface: 2946 psig 18.i.Cì;tsingProgrålT'l ...... TJ ,~~ttiF1~~P~~61 Lilli "II Size < ) (C.t. JI ",ø"'I\<>' ·..···i.. ) Hole Casino Weioht Grade Couplino Lenoth MD TVD MD TVD (includin :¡ staoe data) 8-1/2" 7" 26# L-80 BTC-M 571' 9180' 7926' 9751' 8436' 108 cu ft Class 'G' -' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1657' 9600' 8290' 11257' 9007' 240 cu ft Class 'G' /' 19; f!RESgNT.WELI...C()NDITIØN$I,.)MMþ.~Ym.)·...~·..·cornþl~tedtOl'Rê~"1IAND Re-el1tryQperatiol1$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10665 9255 None 10434 9039 None i. iii i.....·L.~tigtt1i ):Si?èiiii iii iiii . ...,...... MPf.iiii iiTN(£)ii <. Strlldural Conductor 110' 20" x 30" 8 cu vds Concrete 110' 110' Surfar.A 2741' 13-3/8" 3767 cu ft Arcticset 1/ 2741' 2692' Intermediate 9759' 9-5/8" 1323 cu ft Class 'G', 130 cu ft Class 'G' 9759' 8420' Prnrlur.tinn Liner 1163' 7" 360 cu ft Class 'G' 9497' - 10660' 8189' - 9250' Perforation Depth MD (ft): 10380' - 10425' IPerfOration Depth TVD (ft): 8989' - 9031' 20. Attachments a Filing Fee, $100 o BOP Sketch a Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis a Property Plat o Diverter Sketch o Seabed Report a Drilling Fluid Program a 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Rob Tirpack, 564-4166 Printed Name Bill Isaacson Title Senior Drilling Engineer ]. -.11 1 Date ~1/8/0~1 Prepared By Name/Number: Sionature '^-" Phone 564-5521 Terrie Hubble, 564-4628 ) ... i)2i ii ·)i2'. . ^' i./< ii··...··.·ii i i ,} i.' ) ii) ii Permit To Drill I API Number: Permit Approval I ~ee cover letter for Number: 20t¡ -DS'i?' 50-029-20816-01-00 Date: other requirements Conditions of Approval: Samples Required DYes ~No Mud Log Required DYes f8¡ No .. ':'fÆSUffide Measur~s ~Yes 0 No D;",ctional Survey Requ..d !81 Yes 0 No S' l".~ Other: T€.st BOPE :'C:;<DO.pt.,~) c.n\.. ~ tct.<.v t-~~ ~ ~eÔ(,~~ I~ t,(!), , p~:.. . O,S Lh )[1).; o..lte.r"'....:\:~ ßOp~ .S qpro '"- · . ADDroVed {,¡ ...A t;i AnD I ~ I t\I A I ~~~~g~~g~'ON Dat.l/i¥ hcl Form 10-401~e( ~03- "- \",1"'-" I Sutfll)lf In Duplicate 1110 · . I Well Name: I C-24A Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): 1 Horizontal Sidetrack Producer Surface Location: X = 664,351 Y = 5,959,793 As Built 1425' FNL 1030' FEL Sec. 19, T11 N, R14E Umiat ./ Target Location: X = 661,390 Y = 5,957,180 TVDss 8,956' Ivishak Zone 2A 3974' FNL 4057' FEL Sec. 19, T11N, R14E Umiat Bottom Hole Location: X = 661,350 Y = 5,957,830 TVDss 8,940' 3323' FNL 4080' FEL Sec. 19, T11N, R14E Umiat ,/ 1 AFE Number: 1 PBD4P2203 I 1 Estimated Start Date: 1 06/07/04 ~ 11,257' 1 I TVD: 19,007' I I Rig: I Nabors 2ES [' 1 Operating days to complete: 118.0 @El38.7' I KB: 128.5' I 1 KBE: 167.2' I Well Design (conventional, slim hole, etc.): 1 Dual String Horizontal Sidetrack I Objective: I Ivishak Zone 2A Formation Markers (Sperry wp05) Formation To s MD TVD T JD 9,322' 8,036' KOP 9,330' 8,043' TJC 9,414' 8,116' T JB 9,564' 8,255' TShu 9,778' 8,463' TZ4 9,866' 8,550' TZ3 10,061' 8,738' TZ2 10,134' 8,803' TZ2Bu 10,190' 8,849' TZ2BI 10,275' 8,911 ' TZ2A 10,376' 8,969' TD 11,257 9,007' THOT N/A 9,025' TZ1B N/A 9,031' TD Criteria: Based on 300' of erfable Zone 2A. C-24A Permit to Drill TVDss 7,969' 7,976' 8,049' 8,188' 8,396' 8,483' 8,671' 8,736' 8,782' 8,844' 8,902' 8,940' 8,958' 8,964' Comments 8.6 EMW 8.6 EMW 8.6 EMW 8.6 EMW 8.6 EMW H drocarbon bearin H drocarbon bearin H drocarbon bearin H drocarbon bearin H drocarbon bearin H drocarbon bearin H drocarbon bearin Not Penetrated Not Penetrated \0·4 Page 1 . Directional - Sperry wp05 . KOP: 9,330' MD Maximum Hole Angle: -300 in 8-1/2" Intermediate section _930 in 6-1/8" horizontal section. Close Approach Wells: There are no close approach issues. The closest well to C-24A is D-13 with a center to center distance of 848'. Survey Program: Standard MW D Nearest Property Line: 27,070' Casing/Tubing Program Hole Size Csgrrbg O.D. WtJFt Grade Conn Length Top Btm MDrrVD MDrrVD 8-1/2" 7" 26# L-80 BTC-M 571' 9,180'/7 ,926' 9,751 '/8,436' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1,657' 9,600'/8,290' 11,257'/9,007' Tubina 4-1/2" 12.6# L-80 IBT-M 9,572' GL 9,600'/8,290' ./ PH 9.0- 9.5 Chlorides PH <500 9.0 Lo Pro ram 8-1/2" Intermediate: Sample Catchers - None Drillin: Dir/GR- Real time Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GRlReslDen/Neu/ABI- Real time Open Hole: None Cased Hole: None C-24A Permit to Drill Page 2 . . acks Class G @ 15.8 4.5" 12.6#, L-80 Production Liner None 43 bbls, 240 f acks Class G @ 15.8 Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure Production Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure C-24A Permit to Drill * Page 3 . . Disposal . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-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 OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. C-24A Permit to Drill Page 4 . . Pre-RiQ Work: 1. Rig up slickline, pull tubing patch @ 6,298' MD. 2. Drift 4-1/2" tubing to WLEG. 3. Fluid pack tubing and inner annulus. 4. P&A perfs from the PBTD to -9,420' MD. RIH with coil to PBTD. Lay in 37 bbls of cement to - 9420' MD. Obtain Squeeze with 5 additional bbls. POH with coil. 5. Drift 4-1/2" tubing and tag TOC. 6. Chemical cut the 4-1/2",12.6#, L-80 BTC-M tubing at -9,370' MD. 7. Fluid pack T X IA with seawater and freeze protect same with diesel. 8. Pressure test wellbore to 3500 psi for 30 minutes. 9. Test the 9-5/8" pack-off to 5000 psi and tubing hanger seals to 5000 psi. 10. Function all lock-down screws. Repair or replace as needed. 11. Bleed casing and annulus pressures to zero. 12. Set a BPV in tubing hanger. Secure well. 13. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Sidetrack and Complete Procedure Summar\! '3 )2'+101 RiQ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. /' 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. ./ 4. Pull 4-1/2" tubing from above pre-rig cut at about 9,370'. 5. RU e-line. Run GR/JB for 9-5/8", 47# casing with CCL to just above top of tubing stub. 6. PU 9-5/8" Baker bottom trip whipstock assembly with spacer subs on bottom to avoid cutting a casing collar. RIH. Orient whipstock and set on tubing stub. /' 7. Swap over to 10.4 ppg LSND milling and drilling fluid. 8. Mill window in 9-5/8" casing at 9,330' MD (top of window) plus 20' past middle of window. Perform FIT. POOH. 9. MU 8-1/2" drilling assembly with Dir/GR and RIH. Kick off and drill the 8-1/2" intermediate interval, dropping and turning at 6°/100' to an 11 ° hold angle. 10. Drill ahead to casing point at Top Sag River to an estimated depth of 9,751' MD. 11. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing with 150' of overlap. Displace cement with mud. POOH. /' 12. MU 6-1/8" BHA with Dir/GR/RES/Den/Neu/ABI and RIH to the landing collar. 13. Pressure test wellbore to 3500 psi for 30 minutes. 14. Drill shoe track. Swap over to 8.5 ppg mud and drill 20' of new formation. Perform FIT. 15. Drill the 6-1/8" production interval building at 13°/100' to horizontal, targeting Z2 Ivishak. Drill ahead to an estimated TD of 11,257' MD. .,,/ 16. Run and cement a 4-1/2" liner throughout the 6-1/8" wellbore and bacls.into the 7" drilling liner to place top of liner with 150' of overlap. Displace cement with perf pill and mud. /' 17. Release from liner, displace well to clean seawater. 18. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 19. POOH. LD DP and perf guns. 20. Run 4-1/2",12.6#, L-80 completion tying into the 4-1/2" liner top. 21. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 22. Set and test TWC. 23. ND BOPE. NU and test the tree to 5000 psi. / 24. Freeze protect the well to -2200' and secure the well. I' 25. RDMO .,,/ /" /' Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. C-24A Permit to Drill Page 5 . . C-24A Drilling Program Job 1: MIRU Hazards and Contingencies > No wells will require well house removal or shut-in for the rig move onto C-24A. The closest neighboring wells are spaced as follows: C-23 at -110' and C-25 at -103'. Care should be taken while moving onto the well. Spotters will be used at all times. > C Pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Readin C-23 No Readin C-25 No Readin C-22 No Readin C-26 10 m C-26 & C-2? 10 m #1 Closest SHL with H2S Readin #2 Closest SHL with H2S Readin #1 Closest BHL with H2S Readin #2 Closest BHL with H2S Readin Max H2S Readin on Pad Date N/A N/A N/A 1 0/22/00 1 0/22/00 þ.> Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies > The perforations in C-24 have been isolated with a cement plug set during pre-rig operations. Monitor well for any signs of pressure or flows. > Note and record required PU weight to pull tubing at cut point. > NORM test all retrieved well head and completion equipment. > Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 3: Window Mill Hazards and Contingencies > Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP C-24A Permit to Drill Page 6 . . Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies );> The intermediate section will kick off just above the Kingak 'JD' interval and drill to the top of Sag River. For this well, due to the tangent at 300 inclination at a 2300 azimuth, maintain mud weight at 10.4 ppg, from the KOP to the 7" liner point. Follow all shale drilling practices to minimize potential problems. );> There are no fault crossings in the intermediate section. );> There are no close approach issues in the intermediate hole section. );> KICK TOLERANCE: In the worst-case scenario of 9.6 ppg pore pressure at the Sag River depth, a fracture gradient of 11.5 ppg at the 9-5/8" casing window, and 10.4 ppg mud in the hole, the kick tolerance is infinite. /' Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies );> Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. );> Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 6" Production Hole Hazards and Contingencies );> A pump out sub will be run in the BHA to aid in placing LCM material. );> There is one fault crossing in the production section. This occurs at -10,460' MD and has an estimated throw of 20' to the South. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. );> There are no close approach issues in the production hole section. > KICK TOLERANCE: In the worst-case scenario of 8.6 ppg pore pressure in the Ivishak, a fracture gradient of 9.5 ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance is Infinite./' Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP C-24A Permit to Drill Page 7 . . Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Halliburton Cement Program Job 10: DPC Perforate Production CasinQ Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Schlumberger's perforating practices and recommendations. .:. "DPC Perforating" RP Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease RiQ Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto C-24A. The closest neighboring wells are spaced as follows: C-23 at -110' and C-25 at -103'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP C-24A Permit to Drill Page 8 . . C-24A Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There are no close approach issues in the intermediate hole section. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · There are no fault crossings expected in the intermediate hole section. · Lost circulation while drilling the intermediate hole has not been problematic at C Pad. In the event of lost circulation, consult the LCM Decision Tree. · The intermediate hole section will be drilled with a recommended mud weight of 10.4 ppg to ensure shale stability in the Kingak. · Kick tolerance is Infinite with a 11.5 ppg FIT. Production Hole Section: · There is one fault crossing in the production section. This occurs at -10,460' MD and has an estimated throw of 20' to the South. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · There are no close approach issues in the production hole section. · Kick tolerance is Infinite with a 9.5 ppg FIT. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S / · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE C PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. C-24A Permit to Drill Page 9 TREE = WELLHEAD= ACTUA TOR= KB. ELBI = BF. ELBI = KOP= Max Angle = Datum MD = Datum TVD = 6" CrN McBlOY OTIS 71.62' 37.22' 1700' 39 @ 6300' 10254' 8800'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I ECLIPSE PA TCH, ID = 2.863" Minimum ID = 2.863' ECLIPSE PATCH 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = TOP OF 4-1/2 I TOP OF 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 1 9-5/8" CSG, 47#, L-80, ID = ÆRFORA TION SUM REF LOG: BHCS ON ANGLE AT TOP ÆRF: 2 Note: Refer to Production DB fo SIZE SPF INTERVAL 3-1/8" 4 10282 - 10318 3-3/8" 6 10296 - 10300 3-3/8" 6 10306 - 10310 3-3/8" 6 10330 - 10334 3-1/8" 4 10330 - 10363 3-3/8" 6 10346 - 10350 3-3/8" 6 10357 - 10362 3-3/8" 4 10366 - 10399 2-7/8" 6 10380 - 10390 2-7/8" 6 10389 - 10399 2-7/8" 6 10410 - 10425 PBTD AFTER 7" LNR, 26#, L-80, .0383 bpf, 10 = DATE 09/23/82 10/24/97 05/27/01 02/14/03 10/10103 10/12/03 . . I SAFETY NOTES: C-24 ./ . 2139' H 5-1/2" SSSV, OTIS LANDING NIP, ID = 4.562" ~ ¡....., 2740' H 9-5/8" DV PKR I oC GAS LIFT MANDRELS ST MD TVD DBI TYÆ VLV LATCH PORT DATE 13 3231 3015 37 OTIS-LBD RA 1 2741' 1 ~ ~ 12 5098 4535 35 OTIS-LBD RA 11 6429 5586 39 OTIS-LBD RA I 6298'-633301 10 7176 6170 37 OTIS-LBO RA 9 7333 6295 37 OTIS-LBO RA 8 7782 6663 34 OTIS-LBO RA , @ 6298' L 7 7940 6796 33 OTIS-LBD RA 6 8262 7066 33 OTIS-LBD RA 5 8417 7196 33 OTIS-LBD RA 4 8740 7466 33 OTIS-LBD RA 3 8895 7598 32 OTIS-LBD RA 2 9093 7767 31 OTIS-LBD RA 1 9252 7904 30 OTIS-LBD RA I I 9327' H 5-1/2" OTIS XA SLIDING SLEEVE, ID = 4.562" U I 9383' H TUBING SEAL ASSY 1 9403' H 9-518" X 5-1/2" OTIS PKR 1 ~ 4.892" H 9404' J__ - "TBG H 9404' I "- I 9404' H 5-1/2" X 4-1/2" XO I 7"LNR H 9497' I-I I I :I 9467' H 4-1/2" X NIP, ID = 3.813"1 . I , 9506' H 4-1/2" XN NIP, ID = 3.725" I 3.958" 1 9543' .- 9543' H 4-1/2" TBG TAIL WIOTIS WLEG I 8.681" I 9759' l---o4 ~ I 9524' H ELMD TI LOGGED 08/23/83 I MARY 10115' H MARKER JOINT I 09/02/82 2 @ 10282' r historical perf data Opn/Sqz DATE I S 10/24/97 S 10/24/97 II S 10/24/97 S 10/24/97 II S 10/24/97 S 10/24/97 S 10/24/97 S 10/24/97 ~ 0 02/08/98 0 02/08/98 0 10/31/97 J GSO I 10434' I PBTD I 10617' I 6.276" I 10660' RBI BY COMMENTS ORIGINAL COM PLETION NRWO (GSO) RNlTP CORRECTIONS RLltlh CORRECTIONS JCMlTLP PULL TIP CJSITLP SET ECLIPSE PA TCH PRUDHOE BA Y UNIT WELL: C-24 ÆRMIT No: 1821410 API No: 50-029-20816-00 SEe 19, T11N, R14E, 1425' FNL & 1030' FEL DATE REV BY COMMENTS BP Exploration (Alaska) GAS tIfT MANDRElS · C-24A ProJl,sed Completi~ / 2,740' 2,741' 9,180' 9,330' 9,370' 9,403' 9,420' 9,497' 9,497' 9,759' 10,434' 10,660' Date 03-17-04 X nipple @ 2200' 9-5/8" DV Pkr 13-3/8",72#, L-80 TREE = WELLHEAD= ACTUA TOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 6"CW McEVOY OTIS 71.62' 37.22' 1700' 39 @ 6300' 10254' 8800' SS 4-1/2", 12.6#, L-80, IBT-M Tubing Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 9-5/8" X 7" Baker HMC Liner Hanger with ZXP and C-2 running tool Top of window GLM Design: #4 ~ 3308' MD - 4-1/2" X 1-1/2" - SV #3 - 5912' MD - 4-1/2" X 1-1/2" - DV #2 - 7800' MD - 4-1/2" X 1-1/2" - DV #1 ~ 9256' MD - 4-1/2" X 1" - DV 9,550' - 7 X 4-1/2" Baker S-3 Packer 9,600' - 7" X 5" Baker HMC Liner Hanger with ZXP and C-2 running tool 9751' - 7",26#, L-80, BTC-M Liner Top Tubing Tail 9-5/8". 47#, L-80 PBTD 7", 26#, L-80 Rev By Comments RBT Proposed Completion PRUDHOE BAY UNIT WELL: C-24A API NO: Permit NO: GPB Rotary Drilling . SOHIO ALASKA PETROLEUM COMPANY WELLHEAD LOCATION DATA e' I?~ . 1) WELL C-24 ~ 2) Pad CEXT 3) Wellhead Location 1425SNL 1030WEL x = 664,351 Y = 5,959,793 LAT. 70° 17' 47.30" LONG. 148° 40' 08.69" 4) Bearing of Gyro Marker N 5° 53 'W (True) 5) Local Benchmark Elevation M)N C-2 38.88 Ft. AMSL 6) Top Edge of Cellar * 37.22 Ft. ,l1.MSL 7) Base Flange Elevation 38.72 Ft. AMSL 8) Kelly Bushing Elevation 71. 62 Ft. AMSL * Base Flange and Kelly Bushing NOT Installed This Date. 9-9-82 NOTES: 1) Items 1 and 2 should be filled in by the Drilling Supervisor on the rig when a new well spuds in. 2) The surveyor should fill in Items 3, 4, 5 and 6. 3) The completed form should be returned to Drilling Dept. for distribution. 4) The bearing of the Gyro Marker is required as a True, not a Magnetic bearing. 5) Base Flange and Kelly Bushing Elevations measured by the Drilling Supervisor. CIRCULATION: District Field Engineer - 2 District Drilling Engineer/Drilling Engineer - 1 Slope - to Rig for Posting - 2 Well Record Clerk, Geology - 1 Well Files Engineering Associate, Drilling - Original Petroleum Engineering, SFO -1 Ell e n ~1. ¡'1i 11 e r ~""'\ --- Of ~{ \" .:;~~.............4û': -. ,;-..... 0 . *.. "" . ,.. -., ..- .' .:'''9'', t* fG!;.-!! \ * ~ I····· .. ...~~J.~.......-. . I. ~ ..... .. ih. ç At¿... ó' .. ~ 'I. ~ '. ',"" : ~ ~ ~JI '; -:. Geary L Mc:NeU .o.~ ~ 'Iff <J'~... ls.5121 .t·~'v , . ~~ .... t"~'::; ,., , '0 ~II .......... ~~ - '\ OFESSION~\. \.t' _- ,'\.",,,,,~CIP- April 20, 1!:J~2 Date - SCALE: 1" == 300' bs14495.dgn COMPANY DETAILS BP<~ REFERENCE INFORMATION 800 8200 84 " I 1- CI ïi 1:: :: " e 1- 880 90 n C·24 (C-24) 4200 44i}O Vertica! Section at 238.((6° [200Mn] SURVEY PROOR.AM Ikpìh Fm I:)epth To Surv¡ry!Pian 9330,00 I 1257.0.1 Plillmcd: C~24A wp05 V7 Plan: C-24A wp05 (C-24/Plan C~24A) Too! C~d By: Ken AHen Clwckcd; IJ3.re; 1/2612004 om' MWD Rc-viewe4; Date:~ WELL DETAJLS "- Nmthíng """"'" Laritude glot C~24 25343.12 ¡8S633 5959193.00 66435Loo 7WI1'41.2tJ6N ¡~4{ì'OKmW TAROE'fDbÏAILS See MD !nc I 2 3 4 5 6 7 8 9 !O 11 12 13 14 15 SECTION DETAILS +N!·S vS.c Target TVD DLe¡¡ TFace C-24A TIC C-24A T2C C-24A T3C C-24A T4C CASING DETAILS Name Si"" 7" 41!2" No. TVDFeth MDI>ath Formation I 2 3 4 5 6 7 g 9 !O II COMPANY DETAiLS BP Amooo REFERENCE INFORMATION No. TVD ·1 1 2 , 1 1257.m' Ml). 9007.22' TVD ¡ ¡ 176.4!' MD, 9010.94' TVD ·2W , 10964.51' MD, 9020.g8'TVD : 10942.08' MD, 9022.07' TVD : 108%.66' MD, 9023.22'TVD 'E' ~ 8 ·2 t!1 :£ t ~ i " '" if) , 10760.'14' Ml), 902J.22'TVD ,2 FORMA nON TOP DETAILS No. TVDPath MDPath Formation I 2 3 4 5 6 7 8 9 W 11 CASING DETAILS MD Name Tj -4 Inn ,2400 Size SURVEY PROGRAM Depth Fm Depili Tú SurwylPlim 933{},OO T!Z57.{}!P!a!tlU!!±C><14..4. v.1J05 V7 See MD !ne ¡ 2 3 4 5 6 7 8 9 10 11 12 IJ 14 15 P¡an:C~24A wp05 (C-24fPJan C~24A) TooJ MWD Created By: Ken Allen Cheeked: Date:_ Dat-e:~ Date: 1J2-6!2004 Reviewed: WELL DiETAILS N_ -. - Latitude l..;:mg:inJde Slol C~24 25,34.92 ¡S5633 5959793.00 664351.-00 7if'j1'47.2%N 148"'4{!'ÛU89'W 24 TARDET DETA1LS A,,1 SECTION DETAILS +NI~S +fIJ·W vSec Target TVD DL@g TPooe C,24A T2C C,24A BC C·24A T4C &per .'y-...., D.ULLINØ ....VIC.. A U41"UM'M'IUN(....._, . . Sperry-Sun - Draft Copy KW A Planning ObP Company: Field: Site: Well: WeHpath: BPAmoco Prudhoe Bay PB C Pad C-24 Plan C-24A Date: 1/26/2004 TIme: 10:18:22 Page: 1 Co-ordlaate(NE) Referenee: Well: C-24, True North Vertleal (fVD) Reference: 67.22' 67.2 Seetion (VS) Referenee: WeD (0.OON,O.OOE,238.Q6Azi) Survey Calculatloø Method: Minimum Curvature Db: Oracle Plan: C-24A wp05 Date Composed: Version: Tied-to: 1/21/2004 7 From: Definitive Path Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Eastlng: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957218.72 ft 662550.03 ft Latitude: 70 17 Longitude: 148 41 Nortb Referenee: Grid Convergence: 22.367 N 2.797 W True 1.24 deg Well: C-24 Slot Name: C-24 Well Position: +N/-S 2534.92 ft Northing: 5959793.00 ft Latitude: +EI-W 1856.33 ft Easting: 664351.00 ft Longitude: Position Uncertainty: 0.00 ft 24 70 17 47.296 N 148 40 8.689 W Wellpatb: Plan C-24A +N/-S ft 0.00 DriHed From: Tie-on Deptb: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 C-24 9330.00 ft Mean Sea Level 25.47 deg 80.85 deg Direction deg 238.06 Current Datum: Magnetic Data: Field Strengtb: Vertical Section: 67.22' 11/26/2003 57578 nT Deptb From (fVD) ft 34.22 Height 67.22 ft Casing Points MD TV» DiaI'ÍIeter Hole Size Name ft ft in in 9750.89 8436.22 7.000 8.500 7" 11257.00 9007.22 4.500 6.125 4 1/2" Formations MD TVD Fo......tions ft ft 9322.44 8036.22 TJD 0.00 0.00 9413.64 8116.22 TJC 0.00 0.00 9564.05 8255.22 TJB 0.00 0.00 9750.89 8436.22 TSGR 0.00 0.00 9778.36 8463.22 TShu 0.00 0.00 9865.74 8550.22 TZ4 0.00 0.00 10061.12 8738.22 TZ3 0.00 0.00 10133.85 8803.22 TZ2 0.00 0.00 10189.55 8849.22 TZ2Bu 0.00 0.00 10274.66 8911.22 TZ2BI 0.00 0.00 10376.09 8969.22 TZ2A 0.00 0.00 Targets Map ~ap <--. Latitude Name Description TV» +N/-S +EI·W NortlûDg EastiJlg Beg Min See Dip. Dir. ft ft ft ft ft C-24A T4C 9007.22 -1897.04 -3043.42 5957830.00 661350.00 70 17 28.632 N 148 41 37.376 W C-24A PolyB 9018.22 -2610.17 -3139.04 5957115.00 661270.00 70 17 21.618 N 148 41 40.154 W -Polygon 1 9018.22 -2610.17 -3139.04 5957115.00 661270.00 70 17 21.618 N 148 41 40.154 W -Polygon 2 9018.22 -2148.39 -3213.97 5957575.00 661185.00 70 1726.160N 148 41 42.343 W sp&!I ..'y-liil...M a..ILLING ....VIC.. ,,~vrtlNc._.oUrIY . . Sperry-SuD - Draft Copy KW A Planning ObP Company: Field: Site: WeD: Wellpath: Targets BP Amoco Prudhoe Bay PB C Pad G-24 Plan C-24A Date: 112612004 Time: 10:18:22 Page: 2 Co-ordiaate(NE) Referenee: Well: G-24. True North Vertieal (fVD) Referenee: 67.22' 67.2 Section (VS) Referenee: Well (0.OON.0.OOE.238.06Azi) Survey Caleulatiou Method: Minimum Curvature Db: Oracle Map MìIP Name ~riptioD TVD +EI·W NO~Dg ~I Dip. Dir. ft ft ft ft -Polygon 3 9018.22 -1726.30 -3074.70 5958000.00 661315.00 70 17 30.311 N 148 41 38.290 W -Polygon 4 9018.22 -1738.49 -2974.93 5957990.00 661415.00 70 17 30.192 N 148 41 35.382 W -Polygon 5 9018.22 -2083.65 -2972.48 5957645.00 661425.00 70 17 26.797 N 148 41 35.307 W -Polygon 6 9018.22 -2520.21 -2907.01 5957210.00 661500.00 70 17 22.504 N 148 41 33.394 W C-24A T3C 9019.22 -2153.43 -3075.04 5957573.00 661324.00 70 17 26.111 N 148 41 38.294 W C-24A T1 C 9023.22 -2547.80 -3017.64 5957180.00 661390.00 70 17 22.232 N 148 41 36.617 W C-24A T2C 9023.22 -2252.52 -3072.20 5957474.00 661329.00 70 17 25.136 N 148 41 38.211 W Plan Section Information MI> lnel AzIm TVD +N/-S +EI.W DLS Wd TUrn TFO ft <leg <leg ft ft ft degl1 OOftdegl100ftdegl1 00ft <leg 9330.00 29.68 231.81 8042.79 -2882.50 -2893.68 0.00 0.00 0.00 0.00 9350.00 29.98 227.02 8060.14 -2888.97 -2901.23 12.00 1.48 -23.94 -85.00 9750.89 10.77 178.80 8436.22 -2996.29 -2974.80 6.00 -4.79 -12.03 -160.00 9770.89 10.77 178.80 8455.87 -3000.03 -2974.73 0.00 0.00 0.00 0.00 10037.84 24.00 6.78 8716.95 -2970.14 -2967.57 13.00 4.96 -64.44 -174.30 10078.65 24.00 6.78 8754.23 -2953.66 -2965.61 0.00 0.00 0.00 0.00 10597.83 90.00 347.01 9023.22 -2547.80 -3017.64 13.00 12.71 -3.81 -21.48 G-24A T1C 10597.85 90.00 347.01 9023.22 -2547.78 -3017.65 8.00 0.00 6.55 89.97 10760.94 90.00 347.01 9023.22 -2388.86 -3054.30 0.00 0.00 0.00 0.00 10898.66 90.00 358.03 9023.22 -2252.52 -3072.20 8.00 0.00 8.00 90.00 C-24A T2C 10942.08 93.04 358.03 9022.07 -2209.15 -3073.70 7.00 7.00 0.00 0.01 10964.51 93.04 358.03 9020.88 -2186.76 -3074.46 0.00 0.00 0.00 0.00 10997.90 92.66 0.00 9019.22 -2153.43 -3075.04 6.00 -1.14 5.90 100.87 C-24A T3C 11176.41 92.64 10.72 9010.94 -1976.14 -3058.40 6.00 -0.01 6.01 89.84 11257.01 92.64 10.72 9007.22 -1897.04 -3043.42 0.00 0.00 0.00 0.00 C-24A T4C Survey MD Ind Azlm TVD Sys TVD l\f!tpN l\f!tPI: AHVS ft cIég cIég ft ft ft ft ft 9322.44 29.73 231.81 8036.22 7969.00 5956850.50 661524.14 3976.72 0.00 0.00 0.00 TJD 9330.00 29.68 231.81 8042.79 7975.57 5956848.12 661521.25 3980.45 3.75 0.54 183.13 MWD 9350.00 29.98 227.02 8060.14 7992.92 5956841.49 661513.84 3990.28 13.70 12.00 275.00 MWD 9400.00 27.18 224.77 8104.05 8036.83 5956824.49 661497.02 4013.66 37.61 6.00 200.00 MWD 9413.64 26.42 224.09 8116.22 8049.00 5956820.01 661492.82 4019.64 43.76 6.00 201.97 TJC 9450.00 24.42 222.06 8149.06 8081.84 5956808.38 661482.40 4034.71 59.37 6.00 202.59 MWD 9500.00 21.72 218.71 8195.06 8127.84 5956793.21 661470.02 4053.38 78.96 6.00 204.42 MWD 9550.00 19.11 214.48 8241.92 8174.70 5956779.02 661459.91 4069.62 96.40 6.00 207.50 MWD 9564.05 18.40 213.08 8255.22 8188.00 5956775.21 661457.48 4073.73 100.92 6.00 211.47 TJB 9600.00 16.62 208.99 8289.51 8222.29 5956765.84 661452.09 4083.37 111.74 6.00 212.79 MWD 9650.00 14.33 201.73 8337.69 8270.47 5956753.72 661446.60 4094.61 125.07 6.00 216.69 MWD 9700.00 12.33 191.99 8386.35 8319.13 5956742.67 661443.44 4103.29 136.60 6.00 223.69 MWD 9750.89 10.77 178.80 8436.22 8369.00 5956732.58 661442.63 4109.49 146.79 6.00 233.18 7" 9770.89 10.77 178.80 8455.87 8388.65 5956728.85 661442.79 4111.41 150.53 0.00 0.00 MWD 9775.00 10.24 178.50 8459.91 8392.69 5956728.10 661442.83 4111.79 151.28 13.00 185.70 MWD 9778.36 9.81 178.23 8463.22 8396.00 5956727.51 661442.85 4112.08 151.86 13.00 185.99 TShu 9800.00 7.02 175.73 8484.62 8417.40 5956724.36 661443.08 4113.62 155.03 13.00 186.25 MWD 9825.00 3.84 168.34 8509.51 8442.29 5956722.02 661443.41 4114.62 157.39 13.00 188.73 MWD 9850.00 1.15 116.79 8534.48 8467.26 5956721.10 661443.83 4114.78 158.48 13.00 196.09 MWD 9865.74 1.93 37.85 8550.22 8483.00 5956721.24 661444.13 4114.45 158.90 13.00 247.61 TZ4 9875.00 3.01 25.09 8559.47 8492.25 5956721.59 661444.32 4114.10 159.30 13.00 326.53 MWD 9900.00 6.15 14.31 8584.39 8517.17 5956723.49 661444.89 4112.58 161.30 13.00 339.28 MWD 9925.00 9.37 10.85 8609.15 8541.93 5956726.81 661445.53 4110.23 164.67 13.00 350.03 MWD sper"""y-SLrI D..ILLING ....VIC.. A~ÇIAII'AI'C'I . . Sperry-Sun - Draft Copy KW A Planning ObP Compa..y: BP Amoco Date:. 112612004... .. Time: 10;18;22 ..!tie: 3 Field: Prudhoe Bay ço-onliDate(NE) Refereaœ: Wetl;Ç-?4. True North Site: PB C Pad Ve~~(TVD) Refei'C!aœ: 67.22' 67:2 WeD: C-24 ~D.(VS)Ref~reaœ: We"(0.OON·Q¡øqJ:,5~~·~) Wellpath: Plan C-24A S8J"VeyCa1e1llatioD MetJlod: Minimum C.urvature Db: oracle Survey MD IDCI Azim TVD Sys'i'VD MapN MapE VS AHVS DLS DO 1'001 ft deg deg ft ft ft . ft ft ft deg/100ft .deg 9950.00 12.61 9.16 8633.69 8566.47 5956731.52 661446.24 4107.06 169.44 13.00 353.46 MWD 9975.00 15.85 8.14 8657.92 8590.70 5956737.61 661447.03 4103.06 175.58 13.00 355.12 MWD 10000.00 19.09 7.47 8681.77 8614.55 5956745.06 661447.88 4098.27 183.08 13.00 356.10 MWD 10025.00 22.34 6.99 8705.15 8637.93 5956753.86 661448.80 4092.69 191.93 13.00 356.75 MWD 10037.84 24.00 6.78 8716.95 8649.73 5956758.88 661449.29 4089.52 196.98 13.00 357.20 MWD 10061.12 24.00 6.78 8738.22 8671.00 5956768.31 661450.21 4083.60 206.45 0.00 0.00 TZ3 10078.65 24.00 6.78 8754.23 8687.01 5956775.41 661450.89 4079.14 213.58 0.00 0.00 MWD 10100.00 26.60 4.52 8773.53 8706.31 5956784.50 661451.58 4073.58 222.70 13.00 338.52 MWD 10125.00 29.69 2.33 8795.57 8728.35 5956796.28 661452.02 4066.77 234.49 13.00 340.57 MWD 10133.85 30.79 1.66 8803.22 8736.00 5956800.74 661452.08 4064.28 238.95 13.00 342.49 TZ2 10150.00 32.80 0.53 8816.95 8749.73 5956809.25 661452.05 4059.64 247.46 13.00 343.08 MWD 10175.00 35.93 359.01 8837.58 8770.36 5956823.35 661451.68 4052.23 261.57 13.00 344.04 MWD 10189.55 37.77 358.22 8849.22 8782.00 5956832.06 661451.27 4047.80 270.29 13.00 345.29 TZ2Bu 10200.00 39.09 357.70 8857.41 8790.19 5956838.55 661450.90 4044.56 276.79 13.00 345.92 MWD 10225.00 42.25 356.56 8876.37 8809.15 5956854.79 661449.72 4036.65 293.08 13.00 346.33 MWD 10250.00 45.42 355.55 8894.40 8827.18 5956872.03 661448.15 4028.53 310.39 13.00 347.20 MWD 10274.66 48.56 354.65 8911.22 8844.00 5956889.96 661446.21 4020.34 328.42 13.00 347.93 TZ2BI 10275.00 48.61 354.64 8911.44 8844.22 5956890.21 661446.18 4020.23 328.68 13.00 348.54 MWD 10300.00 51.79 353.82 8927.45 8860.23 5956909.27 661443.83 4011.76 347.88 13.00 348.55 MWD 10325.00 54.99 353.07 8942.35 8875.13 5956929.15 661441.10 4003.16 367.95 13.00 349.07 MWD 10350.00 58.18 352.37 8956.12 8888.90 5956949.78 661438.01 3994.46 388.81 13.00 349.52 MWD 10375.00 61.39 351.72 8968.70 8901.48 5956971.10 661434.55 3985.68 410.41 13.00 349.90 MWD 10376.09 61.53 351.70 8969.22 8902.00 5956972.05 661434.39 3985.30 411.37 13.00 350.23 TZ2A 10400.00 64.59 351.11 8980.05 8912.83 5956993.04 661430.75 3976.86 432.68 13.00 350.24 MWD 10425.00 67.80 350.54 8990.14 8922.92 5957015.53 661426.60 3968.01 455.55 13.00 350.51 MWD 10450.00 71.01 349.98 8998.94 8931.72 5957038.50 661422.14 3959.17 478.95 13.00 350.74 MWD 10475.00 74.22 349.45 9006.41 8939.19 5957061.87 661417.37 3950.37 502.81 13.00 350.94 MWD 10500.00 77.43 348.94 9012.53 8945.31 5957085.57 661412.31 3941.63 527.04 13.00 351.09 MWD 10525.00 80.64 348.43 9017.28 8950.06 5957109.52 661406.97 3932.99 551.58 13.00 351.22 MWD 10550.00 83.85 347.94 9020.66 8953.44 5957133.64 661401.37 3924.47 576.35 13.00 351.32 MWD 10575.00 87.07 347.45 9022.64 8955.42 5957157.87 661395.53 3916.10 601.27 13.00 351.38 MWD 10597.83 90.00 347.01 9023.22 8956.00 5957180.00 661390.00 3908.61 624.08 13.00 351.42 C-24A T1C 10597.85 90.00 347.01 9023.22 8956.00 5957180.02 661389.99 3908.60 624.11 6.55 89.97 MWD 10600.00 90.00 347.01 9023.22 8956.00 5957182.11 661389.46 3907.90 626.26 0.00 0.00 MWD 10700.00 90.00 347.01 9023.22 8956.00 5957279.03 661364.86 3875.43 726.26 0.00 0.00 MWD 10760.94 90.00 347.01 9023.22 8956.00 5957338.09 661349.87 3855.64 787.20 0.00 0.00 MWD 10800.00 90.00 350.14 9023.22 8956.00 5957376.19 661341.30 3841.96 826.26 8.00 90.00 MWD 10850.00 90.00 354.14 9023.22 8956.00 5957425.54 661333.38 3821.57 876.26 8.00 90.00 MWD 10898.66 90.00 358.03 9023.22 8956.00 5957474.00 661329.00 3798.71 924.92 8.00 90.00 C-24A T2C 10900.00 90.09 358.03 9023.22 8956.00 5957475.33 661328.92 3798.05 926.26 7.00 0.01 MWD 10942.08 93.04 358.03 9022.07 8954.85 5957517.32 661326.56 3777.04 968.32 7.00 0.01 MWD 10964.51 93.04 358.03 9020.88 8953.66 5957539.69 661325.30 3765.85 990.72 0.00 180.00 MWD 10997.90 92.66 0.00 9019.22 8952.00 5957573.00 661324.00 3748.70 1024.06 6.00 100.87 C-24A T3C 11000.00 92.66 0.13 9019.12 8951.90 5957575.10 661323.95 3747.59 1026.16 6.00 89.84 MWD 11050.00 92.66 3.13 9016.80 8949.58 5957625.04 661324.28 3719.98 1076.11 6.00 89.84 MWD 11100.00 92.66 6.13 9014.48 8947.26 5957674.89 661327.22 3690.22 1126.06 6.00 89.98 MWD 11150.00 92.65 9.14 9012.16 8944.94 5957724.51 661332.77 3658.41 1176.00 6.00 90.12 MWD 11176.41 92.64 10.72 9010.94 8943.72 5957750.59 661336.75 3640.80 1202.38 6.00 90.26 MWD 11200.00 92.64 10.72 9009.85 8942.63 5957773.83 661340.63 3624.84 1225.95 0.00 180.00 MWD 11257.01 92.64 10.72 9007.22 8940.00 5957830.00 661350.00 3586.25 1282.89 0.00 180.00 C-24A T4C Name- +NI~3 ",£!.w Northìng fasting Lai:itude Longitude Slot C-24 2534.-92 185633 5959793.00 66435UJO 70"I7'472%N I<W4ìYO!t689W 24 160 o 40 o 27 160 WELL DETAIl.S COMPANY DETAILS BPA!I1ö!:ú ANTI.cOLLJSION SETIINGS SURVEY PROGRAM l:À.^þth r·m Depth To Smvey/f'lan 9330.00 j ¡37.m PÙ!1med: C-24A \\--p05 V7 MWD Teol WEf.LPA1H DETAILS From C.olour ToMD P!anC~24.<\ 0 300 Pat~:~~; C-24 300 600 933(tOO 600 1000 ~ Ref. Datum: 67.22' WOO 1500 Ori¡¡m Ori¡jn -. 1500 2000 +N!:.s ..-f..:J·W F~ TVD 2000 3000 23K{!6" 0,00 0,00 3000 5000 5000 7000 7000 10000 10000 13000 LEGEND SECTiON DETAILS ¡ , , 4 5 f 1 $ 9 IV H !2 n 14 IS DLeg TFuc~ V&x; 'froze! sper""Y-&Lr1 D'ULLINa ....VIE:.. 4 1.IAU.,IaIII1U'< U!MI'AIt'i . . Sperry-SUD - Draft Copy Anticollision Report ObP Cø~~~: BPAmoco Field: PrlJdhoe Bay Referenc:êSite: PBC Pad Referell,ç~'WeU:c..24 .ReferenceWeUpath: PlEin C-24A GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There a~ells In thB'~1 Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9330.00 to 11257.01 ft Scan Method: Trav Cylinder North Maximum Radius: 1322.28 ft Error Suñace: Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/12/2004 Validated: No Version: 3 Planned From To Survey Tooleode ft ft 95.62 9330.00 1: Camera based gyro multisho (95.62-106~0-MS 9330.00 11257.01 Planned: C-24A wp05 V7 MWD Tool Name Camera based gyro multishot MWD - Standard Casing Points MD TV» Diameter Hole Size Name ft ft in in 9750.89 8436.22 7.000 8.500 7" 11257.00 9007.22 4.500 6.125 4 1/2" Summary <: OffsetWeIlpath > Site WeD WeUpath PB B Pad B-30 B-30 V3 PB C Pad C-05 C-05 V2 PB C Pad C-05 C-05A V9 PB C Pad C-11 C-11 V1 PB C Pad C-22 C-22 V1 PB C Pad C-24 C-24 V7 PB D Pad D-13 D-13A V1 Offset MD ft 12565.00 9750.00 9750.00 Reference MD ft 10037.84 9350.00 9350.00 Ctr-Ctr No-Go DIstance Area ft ft 1090.10 259.85 1225.49 408.17 1225.49 408.28 9345.61 9350.00 10957.78 12290.00 0.26 0.00 848.01 324.26 Site: PB B Pad Well: 6-30 Wellpath: B-30 V3 .Rererell(e MD TV» ft ft 10000.00 8681.77 10000.00 8681.77 10000.00 8681.77 10010.00 8691.18 10012.83 8693.83 Rule Assigned: Inter-Site Error: Offset MD TV» ft ft 12300.00 9024.82 12325.00 9025.23 12350.00 9025.72 12375.00 9026.24 12400.00 9026.79 SelJli..MajorAxiS.<>;.. ... ..... ...... .. . Ctr-ctr<No-Go Ref Offsêt TFØ+AZI TFO-HS CìlSillgIH~~ee Area ft ftdeg deg in ft ft 44.48 47.35 145.92 138.45 7.000 1312.65 248.08 44.48 47.55 145.51 138.04 7.000 1291.07 248.98 44.48 47.74 145.08 137.61 7.000 1269.66 249.92 44.37 47.91 144.63 137.37 7.000 1248.24 251.03 44.33 48.09 144.18 136.98 7.000 1227.00 252.06 0.26 523.75 Major Risk 0.00 ft AllOwable DeViation ft 1064.57 1042.09 1019.74 997.21 974.94 Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Pass: NOERRORS Pass: Major Risk -"ruing Pass Pass Pass Pass Pass 10015.75 8696.56 12425.00 9027.38 44.30 48.28 143.71 136.56 7.000 1205.88 253.12 952.76 Pass 10025.00 8705.15 12450.00 9027.99 44.19 48.44 143.22 136.24 7.000 1184.94 254.32 930.62 Pass 10025.00 8705.15 12475.00 9028.64 44.19 48.65 142.74 135.75 7.000 1164.03 255.40 908.63 Pass 10025.00 8705.15 12500.00 9029.30 44.19 48.87 142.23 135.25 7.000 1143.29 256.55 886.73 Pass 10025.00 8705.15 12525.00 9029.95 44.19 49.10 141.71 134.73 7.000 1122.72 257.75 864.97 Pass 10032.04 8711.64 12550.00 9030.61 44.10 49.29 141.17 134.30 1102.27 259.04 843.23 Pass 10037.84 8716.95 12565.00 9031.00 44.03 49.41 140.83 134.05 1090.10 259.85 830.25 Pass Site: PB C Pad Well: C-05 Wellpath: C-05 V2 Reference MD TV» ft ft 9350.00 8060.14 9372.65 8079.88 9384.47 8090.28 9400.00 8104.05 9400.00 8104.05 Offset MD TV» ft ft 9750.00 7485.14 9775.00 7502.61 9800.00 7520.12 9825.00 7537.70 9850.00 7555.39 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft Sc9nI-MaJor AxiS; . .... ... ·.ii Ctr-ctr No-Go .Ref Offset'fF()+AZITFO-QSCa....glHS>istance Area ft ft deg deg in ft ft 45.26 306.24 208.89 341.87 1225.49 408.17 45.27 307.45 208.88 342.83 1232.12 407.50 45.27 308.66 208.94 343.43 1239.02 406.86 45.28 309.83 208.99 344.21 1246.08 406.10 45.28 311.02 209.12 344.35 1253.25 405.32 817.33 824.63 832.16 839.97 847.93 Pass Pass Pass Pass Pass sp&i!I""'r'y-sun aRIL..L..INUI .."VIC.. "~roN ~"-"""" Compllny: BP Amoco Field: Prudhoe Bay Reference Site: PB C Pad ReferenceWeU: . . 0-24 Reference Wellpath: PlanC-24A Site: PB C Pad Well: C-05 Wellpath: C-05 V2 Reference MDTVD ft ft 9419.51 8121.49 9431.05 8131.88 9450.00 8149.06 9450.00 8149.06 9465.11 8162.86 9476.24 9500.00 9500.00 Offset MD TVD ft ft 9875.00 7573.17 9900.00 7591.05 9925.00 7608.97 9950.00 7626.85 9975.00 7644.70 . . Sperry-Sun - Draft Copy Anticollision Report Date: 1/2612004 Time: . 09:56:48 ObP Co-ordinate(NE) Reference: Verdeal (TVD) Reference: Well: C-24, True 67.22' 67.2 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft Se.......Major Axis ... Ctr-CtI' . No-Go Ref Offset TFO+AZI1'FO-BSCasinglllS)istance Area ft ft deg deg in ft ft 45.28 312.17 209.16 345.38 1260.44 404.45 45.28 313.32 209.24 346.09 1267.78 403.49 45.28 314.43 209.29 347.23 1275.34 402.49 45.28 315.62 209.46 347.40 1283.08 401.18 45.27 316.73 209.55 348.42 1291.10 399.98 8173.09 10000.00 7662.52 45.27 317.86 209.67 349.27 8195.06 10025.00 7680.30 45.26 318.93 209.72 351.01 8195.06 10050.00 7698.06 45.26 320.13 209.92 351.21 1299.39 398.58 1308.06 397.41 1316.70 395.48 Site: PB C Pad Well: C-05 Wellpath: C-05A V9 Reference MD TVD ft ft 9350.00 8060.14 9372.65 8079.88 9384.47 8090.28 9400.00 8104.05 9400.00 8104.05 Offset MD TVD ft ft 9750.00 7485.14 9775.00 7502.61 9800.00 7520.12 9825.00 7537.70 9850.00 7555.39 Rule Assigned: Inter-Site Error: Semi-Major Axis . Ctr-Ctr No-Go Ref Offset TFo+AZI TFQ--HSCasing/HS>istanee .AJoe8 ft ft deg deg in ft ft 45.26 306.24 208.89 341.87 9.625 1225.49 408.28 45.27 307.45 208.88 342.83 9.625 1232.12 407.61 45.27 308.66 208.94 343.43 9.625 1239.02 406.97 45.28 309.83 208.99 344.21 9.625 1246.08 406.21 45.28 311.02 209.12 344.35 9.625 1253.25 405.43 855.99 864.29 872.85 881.91 891.12 Pass Pass Pass Pass Pass 900.81 910.65 921.22 Pass Pass Pass Major Risk 0.00 ft AUowllble Deviation ft 817.22 Pass 824.52 Pass 832.05 Pass 839.87 Pass 847.82 Pass 9419.51 8121.49 9875.00 7573.17 45.28 312.17 209.16 345.38 9.625 1260.44 404.56 855.88 Pass 9431.05 8131.88 9900.00 7591.05 45.28 313.32 209.24 346.09 9.625 1267.78 403.60 864.18 Pass 9450.00 8149.06 9925.00 7608.97 45.28 314.43 209.29 347.23 9.625 1275.34 402.60 872.74 Pass 9450.00 8149.06 9950.00 7626.85 45.28 315.62 209.46 347.40 9.625 1283.08 401.28 881.80 Pass 9465.11 8162.86 9975.00 7644.70 45.27 316.73 209.55 348.42 9.625 1291.10 400.09 891.02 Pass 9476.24 8173.09 10000.00 7662.52 45.27 317.86 209.67 349.27 9.625 1299.39 398.69 900.70 Pass 9500.00 8195.06 10025.00 7680.30 45.26 318.93 209.72 351.01 9.625 1308.06 397.52 910.54 Pass 9500.00 8195.06 10050.00 7698.06 45.26 320.13 209.92 351.21 9.625 1316.70 395.59 921.11 Pass Site: PB C Pad Well: C-24 Rule Assigned: NOERRORS WeUpath: C-24 V7 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis .... .. ... . ... .. . Ctr..çtrNø-Ço A.IIowa~ MD TVD MD TVD Ref Offset TFO+AZI 1'FO-BS CasingIHS>istante.. Area Deviation \V....g ft ft ft ft ft ft deg degin ft ft ft 9345.61 8056.34 9350.00 8060.75 45.23 45.30 328.89 100.83 9.625 0.26 0.00 0.26 Pass 9370.58 8078.07 9375.00 8082.50 45.27 45.44 320.03 93.89 9.625 1.33 0.00 1.33 Pass 9395.52 8100.07 9400.00 8104.28 45.27 45.58 307.15 82.15 9.625 2.68 0.00 2.68 Pass 9420.39 8122.28 9425.00 8126.08 45.28 45.72 296.38 72.65 9.625 4.47 0.00 4.47 Pass 9445.17 8144.67 9450.00 8147.87 45.28 45.85 288.10 65.75 9.625 6.83 0.00 6.83 Pass 9469.81 8167.17 9475.00 8169.67 45.27 45.98 281.90 61.08 9.625 9.81 0.00 9.81 Pass 9494.28 8189.75 9500.00 8191.47 45.26 46.11 277.22 56.09 9.625 13.41 0.00 13.41 Pass 9518.57 8212.36 9525.00 8213.30 45.25 46.23 273.68 56.42 9.625 17.60 0.00 17.60 Pass 9542.64 8234.97 9550.00 8235.17 45.24 46.36 270.96 55.80 9.625 22.34 0.00 22.34 Pass 9566.50 8257.54 9575.00 8257.08 45.22 46.48 268.81 55.98 9.625 27.62 0.00 27.62 Pass 9590.10 8280.03 9600.00 8279.03 45.20 46.59 267.04 56.84 9.625 33.43 0.00 33.43 Pass 9613.43 8302.39 9625.00 8301.03 45.18 46.70 265.58 58.33 9.625 39.77 0.00 39.77 Pass 9636.47 8324.60 9650.00 8323.06 45.15 46.80 264.35 60.44 9.625 46.64 0.00 46.64 Pass 9659.20 8346.62 9675.00 8345.12 45.12 46.90 263.30 63.15 9.625 54.03 0.00 54.03 Pass 9681.61 8368.41 9700.00 8367.22 45.09 47.00 262.40 66.49 7.000 61.93 0.00 61.93 Pass 9703.70 8389.97 9725.00 8389.39 45.06 47.09 261.62 70.48 7.000 70.26 0.00 70.26 Pass 9725.50 8411.30 9750.00 8411.65 45.02 47.17 260.95 75.14 7.000 78.96 0.00 78.96 Pass 9746.99 8432.39 9775.00 8434.01 44.99 47.26 260.37 80.44 7.000 88.00 0.00 88.00 Pass . . 5~Y-EiL.n Sperry-Sun - Draft Copy ObP g..ILLINCII ....Vlc:.. "u.u.u..L1{1'UN L"UNt'A/IlY Anticollision Report CODlpany: BPAmoco Date:· ... .1/2612004 Time: 09:56:48 Field: Prudhoe Bay Reference Site: PBC Pad CCHlrdiJ¡ate(l'œ) Reference: Well: G-24, Reference Well: . . C-24 Verti~ (TVJ» Refe~nee: 67.22' 67.2 Reference WelIpatb; PlanC·24A Site: PB C Pad WelI: C-24 Rule Assigned: NOERRORS WelIpatb: C-24 V7 Inter-Site Error: 0.00 ft Referenee Offset Semi"Major ~ .. ...... <> ...... ...<Ctr-Çtr <No-Go Allowable MD TVD MD TVD Ref Offset 'fFO+AZI TFo-HSC.w.glmÐisfanee Ar~ Dem.tJon W"""ng ft ft ft ft ft ft deg deg in ft ft ft 9769.87 8454.87 9800.00 8456.46 44.98 47.37 259.98 81.18 7.000 97.21 0.00 97.21 Pass 9791.86 8476.55 9825.00 8478.99 45.12 47.61 259.40 82.53 7.000 106.41 0.00 106.41 Pass 9813.49 8498.03 9850.00 8501.58 45.23 47.81 258.39 85.55 7.000 115.79 0.00 115.79 Pass 9834.74 8519.23 9875.00 8524.25 45.29 47.97 257.05 96.34 7.000 125.39 0.00 125.39 Pass 9855.53 8540.01 9900.00 8546.98 45.32 48.09 255.48 175.86 7.000 135.24 0.00 135.24 Pass 9875.00 8559.47 9925.00 8569.74 45.31 48.18 253.74 228.64 7.000 145.47 0.00 145.47 Pass 9895.38 8579.79 9950.00 8592.52 45.25 48.23 251.88 236.50 7.000 156.17 0.00 156.17 Pass 9914.31 8598.59 9975.00 8615.31 45.17 48.26 249.96 237.97 7.000 167.37 0.00 167.37 Pass 9932.55 8616.59 10000.00 8638.12 45.07 48.26 248.03 237.80 7.000 179.11 0.00 179.11 Pass 9950.00 8633.69 10025.00 8660.94 44.95 48.25 246.10 236.95 7.000 191.39 0.00 191.38 Pass 9966.90 8650.11 10050.00 8683.80 44.81 48.21 244.22 235.80 7.000 204.18 0.00 204.18 Pass 9983.02 8665.62 10075.00 8706.69 44.66 48.17 242.39 234.49 7.000 217.49 0.00 217.49 Pass 10000.00 8681.77 10100.00 8729.62 44.48 48.09 240.63 233.16 7.000 231.33 0.00 231.33 Pass 10013.20 8694.18 10125.00 8752.58 44.33 48.04 238.94 231.75 7.000 245.66 0.00 245.65 Pass 10027.32 8707.29 10150.00 8775.59 44.16 47.96 237.33 230.38 7.000 260.45 0.00 260.45 Pass 10041.96 8720.72 10175.00 8798.65 44.03 47.92 235.80 229.01 7.000 275.68 0.00 275.68 Pass 10060.41 8737.57 10200.00 8821.75 44.03 48.03 234.42 227.63 7.000 291.11 0.00 291.11 Pass 10078.65 8754.23 10225.00 8844.89 44.02 48.12 233.17 226.39 7.000 306.62 0.00 306.61 Pass 10093.24 8767.47 10250.00 8868.05 43.74 47.94 231.85 226.66 7.000 322.32 0.00 322.32 Pass 10107.05 8779.81 10275.00 8891.24 43.46 47.74 230.55 226.69 7.000 338.35 0.00 338.34 Pass 10120.28 8791.46 10300.00 8914.45 43.18 47.54 229.28 226.57 7.000 354.68 0.00 354.68 Pass 10132.96 8802.45 10325.00 8937.68 42.89 47.32 228.04 226.32 7.000 371.33 0.00 371.33 Pass 10145.09 8812.80 10350.00 8960.93 42.60 47.10 226.83 225.97 7.000 388.29 0.00 388.29 Pass 10156.68 8822.53 10375.00 8984.20 42.31 46.87 225.66 225.56 7.000 405.56 0.00 405.56 Pass 10167.76 8831.68 10400.00 9007.49 42.02 46.65 224.52 225.10 7.000 423.14 0.00 423.13 Pass 10175.00 8837.58 10425.00 9030.79 41.83 46.51 223.46 224.46 7.000 441.03 0.00 441.03 Pass 10188.43 8848.34 10450.00 9054.09 41.46 46.17 222.36 224.08 7.000 459.18 0.00 459.18 Pass 10200.00 8857.41 10475.00 9077.42 41.14 45.87 221.31 223.62 7.000 477.64 0.00 477.64 Pass 10207.25 8863.00 10500.00 9100.76 40.93 45.70 220.34 222.99 496.35 0.00 496.35 Pass 10216.02 8869.66 10525.00 9124.11 40.68 45.49 219.39 222.44 515.32 0.00 515.32 Pass 10225.00 8876.37 10550.00 9147.46 40.41 45.26 218.47 221.91 534.57 0.00 534.57 Pass 10232.39 8881.80 10575.00 9170.82 40.19 45.07 217.60 221.35 554.06 0.00 554.06 Pass 10240.03 8887.32 10600.00 9194.17 39.96 44.88 216.76 220.83 573.80 0.00 573.80 Pass 10250.00 8894.40 10625.00 9217.52 39.66 44.59 215.93 220.39 593.78 0.00 593.78 Pass 10250.00 8894.40 10650.00 9240.87 39.66 44.66 215.25 219.70 613.98 0.00 613.98 Pass 10258.35 8900.20 10665.00 9254.88 39.40 44.40 214.75 219.52 626.17 0.00 626.17 Pass Site: PB D Pad Well: 0-13 Rule Assigned: Major Risk WelIpatb: D-13A V1 Inter-Site Error: 0.00 ft Referenee Offset Semi-Major ~ .... .... ... Ctr-CtrNo-Ço Allowable MD TVD MD TVD Ref Offset TFO+AZI TF()..HS CasiDgllJS>istanee· Area Dem.tJon W~ ft ft ft ft ft ft deg deg in ft ft ft 10898.66 9023.22 11775.00 9014.85 35.47 58.07 268.59 270.56 1311.08 324.17 986.90 Pass 10881.07 9023.22 11800.00 9016.07 34.86 65.37 267.13 270.51 1289.62 344.48 945.14 Pass 10877.17 9023.22 11825.00 9017.53 34.73 67.01 266.77 270.46 1267.15 348.98 918.16 Pass 10874.03 9023.22 11850.00 9018.44 34.62 68.34 266.48 270.42 1243.71 352.62 891.09 Pass 10871.57 9023.22 11875.00 9018.38 34.53 69.38 266.30 270.43 1219.64 355.48 864.15 Pass 10869.67 9023.22 11900.00 9017.19 34.47 70.19 266.21 270.50 1195.21 357.70 837.52 Pass 10868.64 9023.22 11925.00 9016.33 34.43 70.63 266.18 270.55 1170.40 358.91 811.49 Pass 10868.51 9023.22 11950.00 9015.68 34.43 70.68 266.21 270.60 1145.42 359.09 786.34 Pass 10869.29 9023.22 11975.00 9014.90 34.46 70.35 266.33 270.65 1120.54 358.21 762.33 Pass spEll ....,y-sun DRILLING ....VIC.. AU.u......'KfQfllt'OW'AI'ft· . . Sperry-SuD - Draft Copy Anticollision Report Company: BP Amoco Field: Prudhoe Bay Referenee Site: PB C Pad Referenee.WeD: .c-24 Referenee Wellpatb:Planc-24A Site: PB D Pad Well: 0-13 . Wellpath: D-13A V1 Reference MD ft 10871.05 9023.22 Rule Assigned: Inter-Site Error: Semi-Major Axis Ctr-Ctr No-Go Ref Offset TFO+AZI TFO-BS CasingIBS>istance Area ft ft deg deg In ft ft 34.52 69.61 266.54 270.72 1095.99 356.21 Offset MD TVD ft ft 12000.00 9013.84 10873.75 9023.22 12025.00 9012.70 34.61 68.46 266.83 270.80 1071.98 353.11 10877.36 9023.22 12050.00 9011.66 34.73 66.94 267.20 270.87 1048.69 348.96 10881.88 9023.22 12075.00 9010.33 34.89 65.04 267.65 270.96 1026.35 343.76 10898.66 9023.22 12100.00 9008.70 35.47 58.07 269.11 271.08 1005.07 324.36 10898.66 9023.22 12125.00 9007.69 35.47 58.06 269.19 271.16 983.56 324.44 10898.66 9023.22 12150.00 9008.65 35.47 58.05 269.16 271.13 962.15 324.55 10910.18 9023.14 12175.00 9012.37 35.48 57.71 268.95 270.92 940.98 325.08 10922.42 9022.88 12200.00 9019.18 35.49 57.74 268.53 270.50 920.19 325.36 10933.28 9022.49 12225.00 9028.29 35.49 58.11 267.94 269.91 899.73 325.33 10942.78 9022.03 12250.00 9039.11 35.50 58.65 267.20 269.17 879.68 325.00 10952.16 9021.53 12275.00 9050.14 35.54 58.64 266.41 268.38 859.84 324.56 10957.78 9021.24 12290.00 9056.76 35.57 58.64 265.92 267.89 848.01 324.26 Major Risk 0.00 ft AJlowabl4! Deviation w.,mng ft 739.78 Pass 718.87 Pass 699.73 Pass 682.59 Pass 680.71 Pass 659.12 Pass 637.60 Pass 615.90 Pass 594.83 Pass 574.40 Pass 554.69 Pass 535.28 Pass 523.75 Pass ObP p055262 DATE INVOICE I CREDIT MEMO 3/2/2004 PR022604D THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGI;, AK99Q19-6612 PAY; TO THE ORDER OF: STATE OF ALASKA AOGCC 333 WEST 7TH AVENUE SUITE 1 ANCHORAGE AK 99501 DESCRIPTION GROSS PERMIT TO DRILL PPLlCATIONS POUCH TO TERRI UBBLE MB7-5 C .6t{k DATE I I CHECK NO. I 3/2/2004 055262 VENDOR DISCOUNT NET RECE VED APR 1 2 2004 Alaska Oil & Gas C os. Commission Ancho age TOTAL ~ NATIONAL CITY BANK Ashland, Ohio 1110 5 5 2 b 2111 I: 0 ~ ¡. 20 :1 B 11 5 I: 0 ~ 2 ? a 11 bill 56-389 412 No. p 055262 CONSOLIDATED COMMI:RCIAL ACCOUNT· DATE 3/2/2004 H . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,/80 r:-;/ If/? PTD# 20 9- o. c;<¡T X Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new weJlbore segment of LATERAL existing well , Permit No, API No. . (If API number Production sbould continue to be reported as last two (2) digits a function 'of tbe original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), an (PH) records, data and logs acquired for the pilot hole must be dearly differentiated in both name (name on permit plus PH) .' and API Dumber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Companv Name) assumes tbe Jiability of any protest to tbe spacing .exception tbat may occur. DRY DITCH AlJ dry ditch sample sets submitted to the SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample intervals tbrougb target zones. · e Well bore seg D Annular Disposal D PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT ,Ç-24A _Program DEV RATION (ALASKA) INC Initial ClasslType _DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Administration p.ßrmit fee attached - - - - - - ~ - _ , _ _ Y.ßs _ _ - - - - - - - 2 teas.ß _number _appropriate_ - - - - - - - - _ _ _ _ , , _ _ Y.ßs _ _ - - - - - - - - - - - - - - - - - 3 _U_nlqUe weltn_a!1l~_and oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ Y.ßs _ _ - - - - - - - - - - - - - - - - - - - - 4 Well JQcat~d lna d_efil1e~ pool, _ - - - - - - - - - - _ , , _ _ Y.ßs 5 WellJQcated proper _dlstance_ from drilling ul1itb_oUl1d_a(y_ _ _ ' _ _ _ Y.ßs _ _ - - - - - - - - - - - - - - 6 WellJQcat~d proper _dlstance from otber welJs_ _ _ _ Y.ßs_ - - - - - - - - - - - - - 7 _S_u{ficieI1Lacreageayailable in_drilliog unjL - - - - - - _ _ _ , _ _ Y.ßs_ - - - - - - - - - - - 8 Jtd.ßviated, js weJlbQre platiocJu_ded _ - - - - - - - - - - - - - - ' _ _ Y.ßs_ - - - - - - - - 9 Operator Ol1ly affected party _ , - - - - - - _ _ _ Y.ßs_ - - - - - - - - - - 10 _Operator bas_approprlate_b.ond lnJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ Y.ßs _ _ - - - - - - - - - - - - - - - - - - - - 11 P.ßrmit can be lssued wjtbout cOMervatiOI1 order _ _ _ _ _ _ , , _ Y.ßs _ _ - - - - - - -- - - - - Appr Date 12 P.ßrmit can be lssued wjtbQut ad,mil1istratilleapprovaJ _ _ _ _ _ _ Y.ßs_ - - - - - - - - - - - - - - - RPC 4/12/2004 13 Can permit be approved before 15-day wait Yes 14 WeIUOC<lt.ßd wlthil1 area and_strata _authorized byJnjectioo Ord.ßr # (puUO# In_ cmn!1l_eots) (FOLNA - - - - - - - - - - - - - - - - - 15 AJI welJs_withinJl4JDile_area_of review id.ßoUfied (For servjC.ß)v_e[l ol1lYL _ _ _ _ _ _ _ _ _ _ _ _ _NA __ _ ø _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produ_ced injector; ~uratio_n_of pre-pro~uctioo l.ßss than_ 3 mOl1tbs_ (For_service well onJy) NA - - - - - - - - - - - - - 17 ACMPfinding _of Con_sistency_has beenjssued_ forJbis pr_oject _NA __ - - - - - - - - - Engineering 18 _C9ndu_ctor stringprovlded _ _ _ _ _ - - - - - - - - - NA Sidetrack. _ _ _ _ _ _ _ _ _ 19 _S_urfaC.ß ,casil1g protects all_known_ USQWs _ - - - - -. - - - - NA _ - - - - - - - - - - 20 CMT v_oj a.deq u_ate to circulate oncood_uctor_ & SUJf csg _ _NA _ - - - - - 21 CMT v_oj a.d~qu_ate_ to tie-in Jong _string to_surf csg_ - - - - - - - - NA - - - - - - - - 22 _CMTwill cover_all koown-Pfo_ductiYe hQriZOl1s_ _ _ _ _ _ _ Y.ßs _ _ - - -. - - - - -- 23 Casiog de_signs àdequate for C"T> B_&_Rermafrost _ _ _ , _ _ _ _ _ Y.ßs_ - - - - - - - - 24 A~equatetankageor re_serve pit _ _ , , _ _ _ _ _ _ _ _ _ _ _ Xes f\Jabors2ES, 25 Ita_re-drilt bas a, to:403 fQr aba.ndonmeÐt be.ßO approved. ~ - - - - - Yes __ 3/24/20_0~L _ _ _ 26 A~equatewellbore sepªratioÐ-Pf0po!¡ed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.ßs _ _ - - - - - - - - - - - - - - - - - - -- 27 Jfdiverter rectuiJ~d, dQes it me~t reguJa.tioos_ _ _ _ _ _ _ _NA __ Sidetrack. _ _ _ _ _ . Appr Date 28 _DJiUiog fluid p,rOQJanJ schematic & ~ctuip Jistadequate_ - - - - - -- Y.ßs _ _ Max MW_1DA_ppg._ WGA 4/12/2004 29 BOPEs,_d_o,they rneetreguJatioo _ _ , _ , _ _ _ _ - - - - - - - - ~ Y.ßs_ - - - - - - -- - - - -- 30 _BOPEwe_ss ratil1g appropriate; J~st to (put p!¡ig tn_commeots) Y.ßs_ Test to 3500_p,si. _MS~ 29A6 psi. 31 C_hoke_nJanifold cOnJpJies w/API R~-53 (May 84) - - - - - - - - - - Y.ßs. 32 WQrk will OCC,Ur withoutoperationsbutdown_ _ . - - - - - - - - -- Y.ßs_ - - - - - - 33 Js presence oJ H2S gas_ probable_ - - - - - - - - - - - -- No_ f\JQ!.an H2S pact 34 Mecba,nical.c:podjtlon of wells wtthio 80ß verified (for s_ervice w~1] onJy) NA Geology 35 P.ßrmit c_an be tssued w/o hydrogen_ s_ulfide meaSJJre$ _ _ No 36 _D_ata,PJ~seoted on pote_ntial overpres.surezones _ _ _ _ _ _ _ . NA Appr Date 37 S.ßtsmicanªlysjs, of sbaJlow gaszooes_ _ _ _ _ _ _ . _ _ . , _ _ _NA RPC 4/12/2004 38 S~abed _conditioo survey (if of(-!¡hore) , _ _ _ _ _NA - - - - - - - - - 39 _ CQnta_ct namelphoneJocweeisly progre!¡srep,orts [explorato(y _onlYl NA - Geologic Date: Engineering Date Commissioner q(/1{ 1- Commissioner f) I)' e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ . . 0(0 tf-05"g" !2(P c{./ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Aug 31 10:13:56 2004 Reel Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/08/31 Origin...................STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/08/31 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA C-24a 500292081601 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 31-AUG-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 MW0003126706 J. BOBBITT R. BORDES MWD RUN 3 MW0003126706 P. SMITH R. BORDES MWD RUN 4 MW0003126706 J. BOBBITT J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 19 llN 14E 1425 65.72 RECEIVED SEP 0 :'; 2004 AlllieOil & Gas Cons. ComrniaIion AndIonIge 1030 . . GROUND LEVEL: 37.22 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 9310.0 9756.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK. THE TOP OF THE WHIPSTOCK WAS AT 9310'MD/8025'TVD AND THE BOTTOM OF THE WHIPSTOCK WAS AT 9326'MD/B039'TVD. SGRC DATA FOR THE RUN 1 INTERVAL WERE ACQUIRED DURING RUN 2. THESE DATA ARE MERGED WITH RUN 2 MWD DATA. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS) AND ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4). 5. MWD RUNS 3 AND 4 COMPRISED DIRECTIONAL DGR; EWR4; STABILIZED LITHO-DENSITY (SLD); COMPENSATED THERMAL NEUTRON POROSITY (CTN); AND AT-BIT INCLINATION (ABI). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED 4' DOWNWARD, PER E-MAIL INSTRUCTIONS RECEIVED FROM K. COONEY (SIS/BP) ON 7/21/2004. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL C-24A WITH API# 50-029-20816-01. THIS WELL REACHED A TOTAL DEPTH OF 11275' MD I 9019' TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP . . RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVALS REFLECTING BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 - 8.7 PPG MUD SALINITY: 1900 - 3000 FORMATION WATER SALINITY: FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ PPM CHLORIDES 10,994 PPM CHLORIDES File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/08/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP NPHI FCNT PEF NCNT RPX RPS RPM RPD FET DRHO RHOB $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9257.0 9345.5 9729.0 9729.0 9729.0 9729.0 9749.5 9749.5 9749.5 9749.5 9749.5 9762.0 9762.0 # BASELINE CURVE FOR SHIFTS: STOP DEPTH 11225.0 11278.5 11188.0 11188.0 11203.5 11188.0 11232.0 11232.0 11232.0 11232.0 11232.0 11203.5 11203.5 . . CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9257.0 11278.5 $ GR 9253.0 11274.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 2 3 4 MERGE TOP 9253.0 9756.0 10076.0 MERGE BASE 9756.0 10076.0 11274.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.. ...............Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9257 11278.5 10267.8 4044 9257 11278.5 ROP MWD FT/H 2.63 553.66 72.379 3867 9345.5 11278.5 GR MWD API 16.46 514.52 60.2996 3937 9257 11225 RPX MWD OHMM 0.22 1955.6 25.5909 2966 9749.5 11232 RPS MWD OHMM 0.26 1979.28 33.7557 2966 9749.5 . . 11232 RPM MWD OHMM 0.38 1948.56 39.8273 2966 9749.5 11232 RPD MWD OHMM 3.16 1920.51 42.4139 2966 9749.5 11232 FET MWD HOUR 0.45 64.8 2.23729 2966 9749.5 11232 NPHI MWD PU-S 5.1 58.43 22.906 2919 9729 11188 FCNT MWD CNTS 106.9 3501. 4 705.335 2919 9729 11188 NCNT MWD CNTS 13762.7 51577.1 28635.4 2919 9729 11188 RHOB MWD G/CM 2.087 3.19 2.3502 2884 9762 11203.5 DRHO MWD G/CM -0.107 0.483 0.0790326 2884 9762 11203.5 PEF MWD BARN 1.47 18.09 2.55456 2950 9729 11203.5 First Reading For Entire File..........9257 Last Reading For Entire File...........11278.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/08/31 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 Nurnber...........1.0.0 Date of Generation.......04/08/31 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 9253.0 9341. 5 STOP DEPTH 9724.5 9756.0 . # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE 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: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....... . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 26-JUN-04 Insite 66.37 Memory 9756.0 9340.0 9756.0 10.6 29.7 TOOL NUMBER 126027 8.500 .0 LSND 10.40 59.0 9.5 700 3.3 .000 .000 .000 .000 .0 136.4 .0 .0 . . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT IT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT IT 9253 9756 9504.5 1007 9253 9756 ROP MWD020 FT/H 16.17 245.46 84.2367 830 9341.5 9756 GR MWD020 API 59.24 145.5 112.154 944 9253 9724.5 First Reading For Entire File..........9253 Last Reading For Entire File...........9756 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/31 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FI LE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF NCNT FCNT NPHI GR 3 header data for each bit run in separate files. 3 .5000 START DEPTH 9725.0 9725.0 9725.0 9725.0 9725.0 STOP DEPTH 9997.0 9981. 0 9981.0 9981.0 10018.0 . RPM RPD RPS RPX FET ROP DRHO RHOB $ 9745.5 9745.5 9745.5 9745.5 9745.5 9756.5 9758.0 9758.0 10025.0 10025.0 10025.0 10025.0 10025.0 10076.0 9997.0 9997.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electrornag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LBfG): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # . 29-JUN-04 Insite 66.37 Memory 10076.0 9756.0 10076.0 3.0 13.5 TOOL NUMBER 184054 154267 100983 159436 6.125 9756.0 FLO-PRO SF 8.40 52.0 9.8 2000 3.2 .620 .385 .540 .810 75.0 125.0 75.0 75.0 . . Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9725 10076 9900.5 703 9725 10076 ROP MWD030 FT/H 3.21 207.8 50.6619 640 9756.5 10076 GR MWD030 API 22.2 514 . 52 84.1395 587 9725 10018 RPX MWD030 OHMM 0.22 1955.6 78.4163 560 9745.5 10025 RPS MWD030 OHMM 0.26 1979.28 99.5975 560 9745.5 10025 RPM MWD030 OHMM 0.38 1883.64 95.2726 560 9745.5 10025 RPD MWD030 OHMM 3.16 1920.51 115.49 560 9745.5 10025 FET MWD030 HOUR 1.4 64.8 4.74461 560 9745.5 10025 NPHI MWD030 Pu-s 5.1 58.43 22.7353 513 9725 9981 FCNT MWD030 CNTS 106.9 3501. 4 864.424 513 9725 9981 NCNT MWD030 CNTS 13762.7 51577.1 29082.8 513 9725 9981 RHOB MWD030 G/CM 2.087 3.19 2.39277 479 9758 9997 DRHO MWD030 G/CM -0.038 0.483 0.105618 479 9758 9997 PEF MWD030 BARN 9997 . 1.47 18.09 4.13114 First Reading For Entire Fi1e..........9725 Last Reading For Entire File...........10076 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Nurnber...........1.0.0 Date of Generation.......04/08/31 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name............. STSLIB. 004 Service Sub Level Name... Version Nurnber...........l.0.0 Date of Generation.......04/08/31 Maximum Physical Record..65535 File Type................ LO Previous File Name. ... ...STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPS RPX RPM RPD FET ROP $ 4 . 545 header data for each bit run in separate files. 4 .5000 START DEPTH 9981. 5 9981. 5 9981. 5 9997.5 9997.5 9997.5 10018.5 10025.5 10025.5 10025.5 10025.5 10025.5 10076.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 11184.0 11184.0 11184.0 11199.5 11199.5 11199.5 11221. 0 11228.0 11228.0 11228.0 11228.0 11228.0 11274.5 01-JUL-04 Insite 66.37 9725 ~ . DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units............ . . . . . . . . . . . Datum Specification Block sub-type...O . Memory 11275.0 10076.0 11275.0 18.2 94.1 TOOL NUMBER 184054 154267 100983 159436 6.125 9756.0 FLO-PRO 8.60 51. 0 9.6 20000 8.2 .200 .096 .170 .300 64.0 140.0 64.0 64.0 Name Service Order DEPT ROP MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 , . . . GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM. 4 1 68 12 4 RPS MWD040 OHMM. 4 1 68 16 5 RPM MWD040 OHMM. 4 1 68 20 6 RPD MWD040 OHMM. 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9981. 5 11274.5 10628 2587 9981.5 11274.5 ROP MWD040 FT/H 2.63 553.66 74.0715 2397 10076.5 11274.5 GR MWD040 API 16.46 141. 82 34.1381 2406 10018.5 11221 RPX MWD040 OHMM 3.69 92.95 13.2957 2406 10025.5 11228 RPS MWD040 OHMM 4.74 364.71 18.4309 2406 10025.5 11228 RPM MWD040 OHMM 5.11 1948.56 26.9224 2406 10025.5 11228 RPD MWD040 OHMM 5.75 1391. 25 25.4053 2406 10025.5 11228 FET MWD040 HOUR 0.45 14.57 1. 65371 2406 10025.5 11228 NPHI MWD040 PU-S 8.23 36.18 22.9424 2406 9981. 5 11184 FCNT MWD040 CNTS 290 2129.6 671. 414 2406 9981. 5 11184 NCNT MWD040 CNTS 21222.5 42564.6 28540 2406 9981. 5 11184 RHOB MWD040 G/CM 2.095 2.893 2.34172 2405 9997.5 11199.5 DRHO MWD040 G/CM -0.107 0.458 0.0737376 2405 9997.5 11199.5 PEF MWD040 BARN 1. 48 6.78 2.19728 2405 9997.5 11199.5 First Reading For Entire File..........9981.5 Last Reading For Entire File...........11274.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/08/31 Maximum Physical Record..65535 File Type............. ...LO , . . . Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name.............LISTPE Date.....................04/08/31 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comrnents.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........ .... .LISTPE Date.... ... . . .. . . . . . . . .. .04/08/31 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comrnents.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File