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198-171
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //~,~-/~ 7 // File Number of Well History File PAGES TO DELETE Complete RESCAN Color items- Pages: ~ ..~ ~ Grayscale, halftones, pictures, graphs, charts - Pages: ~ ~ Poor Quality Original - Pages: Other - Pages: DIGITAL DATA D Diskeffes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverty Mildred Darethi!qa~n Lowell Date: ~'/~'~--~ /si ,~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha~II Date:-~/~__~ Is/~__~ . • ECEIVED STATE OF ALASKA NOV 1 0 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION kidiSeht th 0 E`: 133iol' la. Well Status: ❑ Oil 0 Gas ❑ SPLUG 0 Other IN Abandoned 0 Suspended lb: W Class: 20AAC 25.105 20AAC 25.110 ❑ Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero IN Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 10/15/2011 198 - 171 310 - 286 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 10/02/1998 50 029 - 20364 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 10/04/1998 PBU R -03Ai 4619' FNL, 4203' FEL, SEC. 32, T12N, R13E, UM 8. KB (ft above MSL): 50.53' 15. Field / Pool(s): Top of Productive Horizon: 429' FNL, 171' FEL, SEC. 31, T12N, R13E, UM GL (ft above MSL): 19.59' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 166' FSL, 4159' FEL, SEC. 29, T12N, R13E, UM 10660' 8853' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 634728 y 5977131 Zone ASP4 11828' 8875' ADL 028279 TPI: x 633391 y 5981298 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Pemiit: Total Depth: x - 634670 y 5981916 Zone ASP4 N/A 18. Directional Survey: ❑ Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, DIR, GR, 4 - Phase RES, CBL 10271' 8661' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 558 cu ft Arcticset 13 -3/8" 72# L -80 Surface 2672' Surface 2672' 17 -1/2" .6785 cu ft Permafrost II 9 -5/8" 47# L -80 Surface 10083' Surface 8509' 12 -1/4" 1409 cu ft Class '0', 130 cu ft Permafrost 7" 29# L -80 9550' 10271' 8079' 8661' 8 -1/2" 500 cu ft Class 'G' 4 -1/2" 12.6# L -80 10118' 11828' 8537' 8875' 6" 252 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 10133' 10076' / 8503' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. i 1 + �� 4 c �� DEPTH INTERVAL (MD)] AMOUNT AND KIND OF MATERIAL USED 'Sf 10660' Set Whipstock 7 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® 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 RBOMS NOV 14 ...,.. 0 1: * Form 10 -407 Revised 12/2009 1 CONTINUED ON REVERSE 3/f r j.„ "Srp}4 iginal • • 29. ,GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes IN 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 10259' 8651' None Shublik 10316' 8696' Sadlerochit / Zone 4B 10461' 8793' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. r �� Signed: Terrie Hubble VA i. Title: Drilling Technologist Date: ! '- // PBU R - 03Ai 198 - 171 310 - 286 Prepared By NameAlumber. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Matt Ross, 564 -5782 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • R -03A, Well History (Pre Rig Sidetrack) Date Summary 08/16/11 T /I /O =0/0/0 temp =S /I MIT -OA to 2000 psi PASSED (CTD Prep) MIT -OA- Pumped 2.4 bbls crude down OA to reach test pressure. On 1st test, OA lost 145 psi in 1st 15 min & 25 psi in 2nd 15 min, for a total loss of 170 psi in 30 min. Pass. Bled OAP ( -2.4 bbls). Pumped 60 bbls diesel down TBG to fluid pack. 08/17/11 MIT -IA 4000 psi * *PASS ** (CTD prep) Pumped 10.5 bbls diesel down IA to reach test pressure. 1st 15 min lost 50 psi, 2nd 15 min lost 10 psi for a total of 60 psi in 30 min. Bled back - 9 bbls. Tags hung on IA, WV. Valve positions upon departure:SV,WV = closed; SSV,MV,IA,OA =open, operator notified. FW HP's= 100/0/0 08/29/11 T /I /0= 50/120/50, Temp =SI. PPPOT-T (PASS), pre CTD. PPPOT -T: Stung into test port (100 psi), bled to 0 psi. Functioned LDS, all moved freely (2.5 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 09/15/11 WELL SHUT -IN ON ARRIVAL. INITIAL T /I /O 0/100/0 RUN PDC LOG. SET DOWN DUE TO DEVIATION AT 10660'. RUN GYRO LOG. SET DOWN DUE TO DEVIATION AT 10623'. BEGIN GYRO LOGGING UP PASS. FINAL T /I /O = 0/100/50 PSI 09/16/11 INITIAL T /I /O = 0/100/50 PSI. CURRENTLY AT 9500'. CONTINUE CONTINUOUS SURVEY. FINISH GYRO DATA LOG. RIG DOWN AND LEAVE LOCATION. FINAL T /I /O = 0/0/0 PSI. JOB COMPLETE. NOTIFY DSO. LEAVE LOCATION. 09/23/11 T /I /O= Vac /100 /0 Conducted PJSM; Performed barrier test on SN (charted) 300 psi /3500 psi; Installed lubricator, P.T. to 300 psi /3500 psi w /each break; Set 4" CIW TWC #283 @ 118" w/1 -2' ext.; Torqued all tree flange nuts to spec. (see log); P.T. (charted) tree to 300 psi /5000 psi; Pulled 4" CIW TWC; Pre Nordic 1 10/03/11 T /I /O =SSV /90/30. Temp =SI. Bleed WHPs to 0 psi. (CTD prep). No well house. Flowline disconnected. Scaffolding partially removed. IA FL= surface. OA FL= surface. Bled IAP from 90 psi to 0 psi in 1 hr (55 gallons returned to slop). Bled OAP from 30 psi to 0 psi in 10 min ( <5 gallons returned to slop). Monitored for 30 min. During monitor no change on WHPs. Job complete. FWHPs = SSV /0/0. 10/04/11 T /I /O =SSV /5/18. Temp= SI. WHPs (Post bleed). IAP increased 5 psi, OAP increased 18 psi overnight. 10/05/11 T /I /O = Vac /0 +/20. Temp = SI. WHP's (Pre CTD). WAG (water). No wellhouse or injection lines. Page 1 of 1 • • North America - ALASKA - BP Page 1 + Operation Summary Report Common Well Name: R -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/9/2011 End Date: X3- 00X6C -C: (3,143,959.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 7/8/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292036400 Active Datum: Orig Rig on R -03A @50.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/9/2011 18:00 - 00:00 6.00 MOB P -13.87 PRE COMPLETED PREPARING RIG FOR MOVE TO R -PAD. 10/10/2011 00:00 - 02:30 2.50 MOB P ._ PRE CONTINUED RIG MOVE FROM H -PAD TO R -PAD. 02:30 12:30 10.00 MOB P ■- PRE STAGE NORDIC 1 AT TOOL SERVI CES S CAN AND PU AND D MOVE RIG MATS TO R -PAD ROAD 12:30 - 13:20 0.83 MOB P PRE CONTINUE MOVING RIG TO R -PAD 13:20 - 14:40 1.33 MOB P PRE RIG ON R -PAD ACCESS ROAD 14:40 - 23:00 8.33 MOB P ■- PRE RIG HAS MOVED AS EAR CAN, WAIT FOR RIG MATS TS TOTO BE MOVED AROUND TO THE FRONT 23:00 - 00:00 1.00 MOB P PRE RIG IS MOVING ONWARDS ON R -PAD ACCESS ROAD AGAIN 10/11/2011 00:00 - 04:15 4.25 MOB P ._ PRE RIG SAT DOWN. WAIT FOR RIG MATS TO BE SHUTTLED AROUND THE RIG. 04:15 - 05:30 1.25 MOB P PRE PERFORM FINAL MOVE ONTO R -PAD. 05:30 - 06:00 0.50 MOB P PRE MOVE RIG ACROSS R -PAD 06:00 - 06:30 0.50 MOB P PRE CREW CHANGE 06:30 - 07:45 1.25 MOB P -_ PRE REPOSITION T -MATS AND LAY DOWN SPILL CONTAINMENT 07:45 - 08:00 0.25 MOB P PRE PJSM TO LINE UP RIG TO SPOT OVER WELL 08:00 - 11:00 3.00 MOB N RREP PRE LINE UP RIG TO SPOT OVER WELL. SET RIG DOWN, FOUND A LEAK ON ONE OF THE AUXILARY HYDRAULIC LINES FOR THE DRIVE SYSTEM 11:00 - 12:00 1.00 MOB P PRE COMMENCE MOVING THE RIG OVER WELL. 12:00 - 15:30 3.50 MOB P -_ PRE HALT OPERATIONS TO ALLOW FOR WSL CREW CHANGE. 15:30 - 16:30 1.00 MOB P ■ PRE CONTINUED WITH PLACING THE RIG OVER WELL. ACCEPTED RIG • 16:00HRS. 16:30 - 23:00 6.50 MOB P PRE REMOVE TREE CAP AND COMMENCE NU BOP'S. REMOVE 2' SECTION FROM RISER BELOW BOP TO SPACE -OUT BOP -STACK BELOW RIG FLOOR. MEANWHILE SPOTTED SATELLITE CAMP AND WELDING SHOP. 23:00 - 00:00 1.00 MOB P -_ PRE HOLD PJSM AND STAB CT INJECTOR ONTO LUBRICATOR. 10/12/2011 00:00 - 01:30 1.50 MOB P PRE HOLD PJSM BEFORE REMOVING GOOSE -NECK FROM INJECTOR. LIFT GOOSE -NECK OFF AND PLACE IN PIPE SHACK FOR SWAPPING ROLLERS SUITABLE FOR 2 3/8" COIL. REMOVE INJECTOR FROM LUBRICATOR AND SET ON LEGS. 01:30 02:15 0.75 MOB P ■- PRE PERFORMED "RIG EVACUATION" DRILL IN CO-ORDINATION WITH NEIGHBOURS 7ES. HELD AAR WITH ALL PARTIES INVOVLED. 02:15 - 02:45 0.50 MOB P PRE HELD PRE SPUD MEETING WITH CREWS. Printed 10/17/2011 1:50:17PM North America - ALASKA - BP Page 2 OW Operation Summary Report Common Well Name: R -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/9/2011 End Date: X3- 00X6C -C: (3,143,959.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 7/8/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292036400 Active Datum_ : Orig Rig on R -03A @50.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:45 - 09:30 6.75 MOB P PRE PERFORMING VALVE MAINTENANCE ON KILL LINE MANUAL AND CHECK VALVE + CHOKE LINE MANUAL VALVE. SLB SWAP GOOSENECK ROLLERS TO 2 -3/8 ". 09:30 - 10:15 0.75 MOB P PRE INSTALL RIG FLOOR CONTAINMENT & MU INJECTOR TO RISER. 10:15 - 12:30 2.25 MOB P PRE HOLD PJSM ON INSTALLING GOOSENECK ON INJECTOR. DISCUSS DROPPED OBJECTS POTENTIALS, COMMUNICATION, AND POSITIONS OF PEOPLE. ATTACH REDRESSED GOOSENECK TO INJECTOR HEAD. HOLD AAR ON REATTACHING GOOSENECK. 12:30 - 14:00 1.50 BOPSUR P PRE RU FOR INITIAL BOPE TEST. FLUID PACK STACK & FLOW THROUGH MGS. HOLD PJSM ON INITIAL BOPE TEST. 14:00 - 15 1.00 BOPSUR P PRE PERFORM INITIAL BOPE TEST. FUNCTION -TEST ALL RAMS + ANNULAR FROM DRILLER'S AS WELL AS CDS DRILLER'S CONSOLE. ALL TESTS TO 250 -PSI LOW / 3500 -PSI. HOLD AND CHART EACH TEST FOR 5- MINUTES. ALL TESTS WITNESSED BY BP WSL AND NORDIC TOOLPUSHER. PERFORM FULL BODY TESTS AGAINST SWAB VALVE. 15:00 - 15:45 0.75 BOPSUR P PRE HOLD RIG EVAC DRILL, COORDINATING WITH NEIGHBORING RIG, 7ES. TESTED GAS ALARM IN CELLAR. WHEN CREW RESPONDED, A MAN DOWN WAS ANNOUNCED AS ELECTRICIAN COULD NOT BE ACCOUNTED FOR. ALL CREW RESPONDED TO PRIMARY MUSTER AREA - 7ES TRUCK SHOP. 7ES WSL, TOOLPUSHER AND SCS ALSO RESPONDED. AN AAR WAS HELD. FINDINGS - EVERYONE MUSTERED CORRECTLY, EFFICIENTLY AND SAFELY. SCS WAS ABLE TO IDENTIFY MAN DOWN WITHOUT DELAY. IN DEPTH DISCUSSION SURROUNDING EMERGENCY NOTIFICATIONS AND RESPONSE, ALARM IDENTIFICATION AND FUNCTIONING OF ALARMS ON RIG. 15:45 - 18:00 2.25 BOPSUR P PRE CONTINUE TO PERFORM INITIAL BOPE TEST. ALL TESTS TO 250 -PSI LOW / 3500 -PSI. HOLD AND CHART EACH TEST FOR 5- MINUTES. ALL TESTS WITNESSED BY BP WSL AND NORDIC TOOLPUSHER. TEST ALL CHOKE VALVES, MUD CROSS VALVES AND COMB! RAMS. 18:00 - 20:00 2.00 BOPSUR P PRE PERFORMED CREW CHANGE AND CONTINUED WTH TESTING SEQUENCE. UNABLE TO ACHIEVE TEST ON 3 1/8" MANUAL CHOKE VALVE. INVESTIGATE: OPEN UP 3 1/8" MANUAL CHOKE AND FIND THAT BODYBUSHING / SEAL RING HAS FAILED. Printed 10/17/2011 1:50:17PM North America - ALASKA - BP • Page 3 d" 1 Operation Summary Report Common Well Name: R -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/9/2011 End Date: X3- 00X6C -C: (3,143,959.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 7/8/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292036400 Active Datum: Orig Rig on R -03A @50.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 22:00 2.00 BOPSUR P PRE REPAIR 3 1/8" MANUAL CHOKE AND RETEST SAME. MEANWHILE, TEST ALL H2S AND METHANE GAS ALARMS. 22:00 - 00:00 2.00 BOPSUR P PRE CONTINUE BOP - TESTING: TEST 2 3/8" X 3 1/2" VBR WITH 2 3/8" TEST -JOINT TO 3,500PS1 / 5MIN. TEST ANNULAR TO 2,500PSI / 5MIN AND BLIND RAMS TO 3,500PSI / 5MIN. 10/13/2011 00:00 - 02:00 2.00 BOPSUR P PRE CONTINUE BOP - TESTING: TEST BLIND RAMS, HYDRAULIC AND MANUAL CHOKE AND 2 3/8" X 3 1/2" VBR WITH 3 1/2" TEST -JOINT TO 3,500PS1 / 5MIN. ear PERFORM DRAWDOWN TEST ON ACCUMULATOR (SYSTEM PRESSURE: 3,100PSI, SHUT -IN: 2,100PSI, 200PSI INCREASE: 22SEC, FULL RECOVERY: 105SEC). 02:00 - 02:20 0.33 MOB P PRE PJSM ON PULLING COIL ACROSS. 02:20 - 03:00 0.67 MOB P PRE PAY OUT CABLE FROM WINCH TO REEL. 03:00 - 04:30 1.50 MOB P ■ PRE INSTALL GRAPPLE AND PULL TEST. CALL OUT FOR FLUID TRUCKS (130BBLS 2% KCL, 580BBLS 3 %KCL). 04:30 - 05:00 0.50 MOB P PRE PULL ACROSS COIL AND FEED THROUGH INJECTOR. CUT OFF GRAPPEL. 05:00 - 06:00 1.00 MOB P PRE STAND BACK INJECTOR, SET ON LEGS AND PREPARE FOR PUMPING SLACK MANAGEMENT. MANUALLY CUT 15' OF COIL TO EXPOSE E -LINE BOOT. INSTALL NEW E -LINE BOOT. 06:00 - 09:40 3.67 MOB P PRE FILL COIL WITH 5 -BBLS MEOH AHEAD AND THEN 8.3 -PPG FRESH WATER. TAKE MEOH RETURNS TO CUTTINGS BOX. BODY TEST REEL IRON TO 250 -PSI LOW / 3500 -PSI HIGH. GOOD TESTS. PUMP SLACK BACK INTO REEL STAGING UP TO 3.9 -BPM (MOVEMENT AT 2.7 -BPM). HEAR E -LINE MOVING. 09:40 - 10:00 0.33 BOPSUR P PRE FINISH INITIAL BOPE TEST - INNER REEL VALVE AND PACKOFF. TEST TO 250 -PSI LOW / 3500 -PSI HIGH. HOLD AND CHART EACH TEST FOR 5- MINUTES. TESTS WITNESSED BY BP WSL. 10:00 - 11:15 1.25 MOB P PRE PJSM ON CUTTING COIL. DISCUSS POSITIONS OF PEOPLE, WICKER POTENTIALS, PROPER PPE AND JOB SEQUENCE. CUT 320' OF COIL BUT DO NOT FIND END OF E -LINE. 11:15 - 12:45 1.50 MOB P PRE MU SLB CTC. PULL TEST - GOOD. PRESSURE TEST, MU STINGER & NOZZLE. PUMP SLACK FORWARD, STAGING UP TO 3.3 -BPM, UNTIL NO LONGER HEAR E -LINE MOVING. LD STINGER & NOZZLE. E -LINE IS VISIBLE - 2.1% SLACK IN REEL. Printed 10/17/2011 1:50:17PM North America - ALASKA - BP Page 4 Operation Summary Report Common Well Name: R -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/9/2011 End Date: X3- 00X6C -C: (3,143,959.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 7 /8/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292036400 Active Datum: Orig Rig on R -03A @50.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:45 - 14:00 1.25 MOB P PRE MEG TEST E -LINE - GOOD. BHI INSTALL UQC WITH DBPV AND HEAD UP TOOLS. TEST DBPV TO 250 -PSI / 3500 -PSI FOR 5- CHARTED MINUTES PER TEST. GOOD TESTS. TEST SLB CTC TO 3700 -PSI - NO VISUAL LEAKS. 14:00 - 14:30 0.50 MOB P PRE STAB INJECTOR ON WELL. PUMP 5 -BBLS MEOH SPEAR AT .6 -BPM WITH 125 -PSI. CHASE WITH 8.3 -PPG FRESH WATER AT 3.3 -BPM AT 2900 -PSI. UNSTAB INJECTOR AND SET BACK ON LEGS OVER CIRC HOLE. 14:30 - 16:00 1.50 MOB P PRE OPEN SWAB AND MASTER VALVES. ATTEMPT TO ENGAGE 4- 1/16" TWC - UNABLE TO GET PULLING TOOL THREADS TO ENGAGE. BUMP UP IN LUBRICATOR AND CLOSE MASTER & SWAB VALVES. UNSTAB LUBRICATOR AND INSPECT PULLING TOOL. OBVIOUS MARKS ON ONE SIDE OF PULLING TOOL INDICATING SITTING DOWN. INSPECT EXTENSIONS. CHANGE OUT MIDDLE EXTENSION (POTENTIALLY VERY SLIGHTLY BOWED). 16:00 - 16:15 0.25 MOB P -_ PRE DSM PUMP OPEN SSV AND INSTALL FUSIBLE CAP. 16:15 - 18:15 2.00 BOPSUR P PRE HOLD PJSM ON RU & TEST DSM LUBRICATOR. TEST DSM LUBRICATOR AGAINST CLOSED SWAB (MASTER CLOSED ALSO) PER WELLS GROUP RP. TEST TO 250 -PSI / 3500 -PSI FOR 5- CHARTED MINUTES PER TEST. 18:15 - 19:45 1.50 BOPSUR P PRE HOLD PJSM WITH ONCOMING CREW ON SECOND ATTEMPT TO PULL TWC. PAINT PULLING TOOL AND MU TOOL STRING. MU LUBRICATOR TO WELL & PRESSURE TEST TO 250 -PSI / 3500 -PSI FOR 5- CHARTED MINUTES PER TEST. 19:45 - 20:00 0.25 BOPSUR P -_ PRE GOT PULLING TOOL ENGAGED. PULL TWC TO SURFACE 20:00 - 20:15 0.25 BOPSUR P -_ PRE PJSM BEFORE LD VALVE CREW LUBRICATOR. 20:15 - 22:00 1.75 BOPSUR P PRE LD LUBRICATOR AND RD VALVE CREW'S EQUIPMENT FROM RIG FLOOR. M/U NOZZLE TO COIL, STAB ON INJECTOR AND TEST QTS TO 3,500PSV5MINS. 22:00 - 22:15 0.25 BOPSUR P PRE PJSM BEFORE BULLHEADING WELL KILL. I I Printed 10/17/2011 1:50:17PM a l North America - ALASKA - BP Page 5 Operation Summary Report Common Well Name: R -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/9/2011 End Date: X3- 00X6C -C: (3,143,959.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 7/8/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292036400 Active Datum: Orig Rig on R -03A ©50.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:15 - 23:30 1.25 BOPSUR P PRE START BULLHEAD: 22:20 - PUMP 5BBLS METH SPEAR 22:30 - COMMENCE PUMPING FIRST 2% KCL, THEN "QUIKDRILN" MUD CATCH FLUIDS AFTER 16BBLS PUMPED. INDICATES THAT FLUID LEVEL WAS AT 1,052FT ACHIEVE 4.5BPM PUMP RATE @ 1,440PS1 CIRC PRESSURE. 22:55 - PUMPED ALL 2% KCL (119BBLS). SWAB TO "QUIKDRILN" MUD 23:00 - PUMP PRESSURE DROPS TO 1,240PS1 AT CONSITENT 4.5BPM. 23:15 - PUMP PRESSURE DROPS TO 1,210PSI, MAINTAINING4.5BPM PUMP RATE. 23:30 - SHUT IN PUMPS. 167BBLS "QUIKDRILN" MUD PUMPED. 23:30 - 00:00 0.50 BOPSUR P PRE WITH PUMPS S /I, OBSERVE WELL SHOWING A SMALL AND DECREASING AMOUNT OF FLOW COMING BACK. 10/14/2011 00:00 - 00:30 0.50 BOPSUR P PRE MONITOR WELL WITH RETURNS DECREASING AND FINALLY STOPPING. OBSERVED IN TOTAL 3BBLS GAIN IN PITS SINCE S/I PUMPS. MEANWHILE COMMENCE TO TOP UP PITS WITH "QUIKDRILN" MUD FROM TRUCKS. 00:30 - 01:15 0.75 BOPSUR P PRE PERFORM 30MIN FLOW -CHECK - GOOD NO FLOW. IA = 90PSI, OA = 297PS1 01:15 - 01:30 0.25 BOPSUR P PRE ATTEMPT TO ESTABLISH FLUIDS -LOSS RATES - WELL STILL LIQUID PACKED W /OUT ANY LOSSES. 01:30 - 01:50 0.33 BOPSUR P PRE COMPLETE LOADING PITS WITH "QUIKDRILN" MUD. 01:50 - 02:10 0.33 MOB P PRE SET INJECTOR TO SIDE AND CAP WELL (STILL FULLY LIQUID PACKED). 02:10 - 03:45 1.58 MOB P WEXIT LOADED 10X JOINTS OF 1 -1/4" CSH+ 11X JOINTS OF 3- 3/16" TCII LINER INTO PIPE SHED, MEASURED AND DRIFTED. 03:45 - 10:00 6.25 MOB P WEXIT PERFORM TRIPLE SUB DRILL AND AAR. IDENTIFY THE NEED FOR AN ELEVATED, WEIGHT DISTRIBUTING WORK PLATFORM IS NEEDED WHEN USING THE FALSE TABLE. DISCOVER THAT THE 3- 3/16" TCII SLIDING PIN CANNOT BE MADE UP TO THE OUTER STRING DUE TO UPSET STACKING OUT IN 3- 3/16" TCII BOX. REVIEW FINDINGS WITH CTD FIELD SUPT AND RWO /CTD WTL. RD ALL HANDLING EQUIPMENT USED IN DRILL. WELL IS STAYING FULL OF FLUID. 10:00 - 10:30 0.50 MOB P WEXIT CLOSE MASTER VALVE & STAB INJECTOR ONTO WELL. DISPLACE COIL FROM MEOH SPEAR & FRESH WATER TO 8.6 -PPG QUIKDRILN MUD, TAKING RETURNS TO CUTTINGS BOX. PUMP AT 3 -BPM WITH 2230 -PSI. FLOW CHECK WELL - STATIC. OPEN MASTER VALVE - WELL IS STILL FULL. SET INJECTOR BACK OVER CIRC HOLE. Printed 10/17/2011 1:50:17PM North America - ALASKA - BP Page 6 Operation Summary Report Common Well Name: R -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/9/2011 End Date: X3- 00X6C -C: (3,143,959.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 7/8/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292036400 Active Datum: Orig Rig on R -03A @50.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:30 1.00 WHIP P WEXIT HOLD PJSM ON MU WHIPSTOCK BHA (BHA #2). DISCUSS HANDLING CONSIDERATIONS, POSITIONS OF PEOPLE AND BHA COMPONENTS. MU WHIPSTOCK RUNNING BHA. OAL = 78.69'. 11:30 - 12:00 0.50 WHIP P WEXIT MU BHA TO COIL AND MU INJECTOR TO LUBRICATOR. TEST QTS TO 250 -PSI / 3500 -PSI FOR 5- CHARTED MIN PER TEST. GOOD TESTS. IA / OA / PVT = 40 -PSI / 125 -PSI / 243 -BBLS. 12:00 - 15:40 3.67 WHIP P WEXIT OPEN EDC AND ESTABLISH CIRCULATION AT .3 -BPM WITH 350 -PSI INITIALLY, 500 -PSI AT 10,340'. RIH WITH WHIPSTOCK BHA AT 75 -FPM, SLOWING THROUGH X- NIPPLE AT 2013'. IA / OA = 350 -PSI / 320 -PSI. 15:40 - 17:45 2.08 WHIP P WEXIT LOG GR TIE IN FROM 10,340' TO 10,540' AT 90 -FPH. CIRCULATE AT .3 -BPM WITH 500 -PSI. MUD SHOWING DARK COLORING COMING BACK WITH FINE BLACK PARTICULATE "SCHMOO ". APPLY -10' CORRECTION. 17:45 - 18:00 0.25 WHIP P WEXIT POH TO 10,500'. LOG CCL FROM 10,500' TO 10,640'. LINER COLLARS SEEN AT 10481', 10522', AND 10563' (IDENTICAL TO CCL TIED TO PDC). OBSERVE INDICATIONS OF POTENTIAL CENTRALIZERS ON CCL LOG, WHICH REGULARLY AT APPROX. 12' BELOW JOINTS. 18:00 - 19:00 1.00 WHIP P WEXIT CALL ODE AND DISCUSS WAY FORWARD. AGREE TO SHIFT WHIPSTOCK'S SETTING DEPTH ABOUT 10' DEEPER TO STAY CLEAR FROM ANY CENTRALIZER. 19:00 - 19:30 0.50 WHIP P WEXIT RIH TO 10,675.7' (BHA- DEPTH) TO PLACE THE a ,� TOWS an. 10,660.0'. W CLOSE EDC, CONFIRM PU- WEIGHT WITH 45K LBS AND RUN BACK IN HOLE TO 10,675.7' (BHA- DEPTH). BRING ON PUMP AND PRESSURE UP COIL TO 2,200PSI BEFORE OBSERVING PRESSURE DROP. SIT DOWN ON WHIPSTOCK WITH 5K TO CONFIRM WHIPSTOCK IS SET. WHIPSTOCK IS SET AS FOLLOWS: TOWS - 10,660' BOWS - 10,675.7' TFO - 82DEG (RIGHT) WELLBORE DEVIATION - 86.16DEG 19:30 - 21:40 2.17 WHIP P WEXIT COMMENCE POOH AT — 100FPM 21:40 - 22:30 0.83 WHIP P WEXIT PERFORMED FLOWCHECK @ 200'. 22:30 - 00:00 1.50 WHIP P WEXIT PULL BHA TO SURFACE. B /OUT AND STAND BACK INJECTOR. LD BHA #2. WHEN B/OUT TOOLS FOUND THAT FLOWSUB COMMUNICATION BOOT DROPPED IN THE LOWER QUICK CONNECT. FLUID PACKED WELL WITH 2.2 BBLS. IA / OA / PVT = 424 -PSI / 597 -PSI / 245 -BBLS. Printed 10/17/2011 1:50:17PM North America - ALASKA - BP 1111 Page 79 Operation Summary Report Common Well Name: R -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 10/9/2011 End Date: X3- 00X6C -C: (3,143,959.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 7/8/1979 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292036400 Active Datum: Orig Rig on R -03A @50.53ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/15/2011 00:00 - 01:00 1.00 STMILL P WEXIT M/U BHA #3 WITH 3.80" WINDOW MILL. CHANGE OUT FLOW SUB IN LOWER QUICK CONNECT. CHECK COMMUNICATION TO SURFACE EQUIPMENT. 01:00 - 01:20 0.33 STMILL P WEXIT STAB ON LUBRICATOR AND PRESSURE -TEST QTS TO 3,500PSI / 5MIN. 01:20 - 03:20 2.00 STMILL P WEXIT RIH @ 100FPM CIRC PESSURE 500PSI @ 0.28BPM IA / OA / PVT = 343 -PSI / 487 -PSI / 240 -BBLS. 03:20 - 04:05 0.75 STMILL P WEXIT AT 10,360' COMMENCE LOGGING DOWN @ 100' / HR TO 10,460'. 04:05 - 04:30 0.42 STMILL P WEXIT CORRELATE TO PDC -LOG AND APPLY A -6' DEPTH CHANGE. LIGHTLY TAG WHIPSTOCK @ 10,660' PU 10', BRING PUMP NO.2 ONLINE TO MAX RATE (2.6BPM ON "IN " -MM) AND RIH. 04:30 - 06:00 1.50 STMILL P WEXIT TAG WHIPSTOCK @ 10,660.6' COMMENCE TIME - MILLING © 1' /HR. CIRC PRESSURE: 1880PS1 / DIFFERENTIAL PRESSURE: <50PSI / PUMP -RATE: 2.61BPM IA / OA / PVT = 593 -PSI / 675 -PSI / 294 -BBLS. 06:00 - 17:15 11.25 STMILL P WEXIT TIME- MILLING @ 10,662.40FT @ 1' /HR .- 29. CIRC PRESSURE: 1990PS1 / DIFFERENTIAL g,�$ PRESSURE: <50PSI / PUMP -RATE: 2.60BPM IA / OA / PVT = 632 -PSI / 771 -PSI / 294 -BBLS AT 10663.5' - 2.6 -BPM / 2050 -PSI / MW = 250 -PSI / DHWOB = 2.5K -LBS. IA / OA / PVT = 710 -PSI / 900 -PSI / 294 -BBLS. BLEED IA FROM 750 -PSI TO 150 -PSI - LIQUID. BLEED OA FROM 950 -PSI TO 200 -PSI - LIQUID. AT 10664.3' SEE ABRUBPT 400 -LB DROP IN STRING WEIGHT AND 300 -PSI DECREASE IN PRESSURE. MILL AHEAD WITHOUT ISSUE. AT 10664.5' - MW = 300 -PSI, DHWOB = 2.5K -LBS. IA / OA / PVT = 190 -PSI / 270 -PSI / 294 -BBLS. AT 10665.5' - MW = 150 -PSI, DHWOB = 1.8K -LBS. AT 10666.5' - MW = 150 -PSI, DHWOB = 1K-LBS. IA / OA / PVT = 250 -PSI / 400 -PSI / 294 -BBLS. AT 10667.5' - MW = 150 -PSI / DHWOB = 1.2K -LBS. IA / OA / PVT = 280 -PSI / 440 -PSI / 294 -BBLS. AT 10668.5' - MW = 200 -PSI / DHWOB =1.2K -LBS. IA / OA / PVT = 300 -PSI / 490 -PSI / 295 -BBLS. APPEAR TO HAVE EXITED WINDOW AT -10669.9'. MOTOR WORK AND DHWOB DECREASING. AT 10670' - MW = 200 -PSI, DHWOB = 900 -LBS. IA / OA / PVT = 350 -PSI / 560 -PSI / 294 -BBLS. AT 10671' - MW = 150-PSI/ DHWOB = 200 -LBS. IA / OA / PVT = 370 -PSI / 600 -PSI / 295 -BBLS. 17:15 - 18:15 1.00 STMILL P WEXIT CONTINUE TO MILL FORMATION FROM 10672' TO 10681'. MOTOR WORK AT 200 to 400 -PSI DIFFERENTIAL. RUN 4500 - 500 -LBS DHWOB. IA / OA / PVT = 380 -PSI / 625 -PSI / 295 -BBLS. Printed 10/17/2011 1:50:17PM TREE = 4- 1/16" MCEVOY • SA NOTES: WELL REQUIRES A SSSV WHEN ON WELLHEAD = MCEVOY R-03A ML WELL ANGLE> 70° @ 10523'. ACTUATOR= BAKER KB. ELEV = 55.11' BF. ELEV = 28.77' KO Max Angle 94 @ 10972' 2013' 1-14-1/2" HES X NIP, ID = 3.813" Datum MD = 11154' Datum TV D = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I-) 2672' 1-A TOP OF 7" LNR 1-1 9559' 1 L Minimum ID = 3.725" @ 10120' 10065' I -14- 1 /2 " HES XNIP, ID= 3.813" I 4 -1/2" HES XN NIPPLE 10 076' I- 7" X 4 -1/2" BKR S -3 PROD PKR, ID = 3.875" I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10083' I--A ■ 10099' I- I4 -1/2" HES X NIP, ID = 3.813" 1 10120' I -14 -1/2" HES XN NIP, ID = 3.725" I I TOP OF 4-1/2" LNR 1-1 10129' 1 L 10129' H TIEBACK SLV 1 14 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 10133' 10133' —14 -1/2" WLEG, ID = 3.958" I I H ELMD TT NOT LOGGED I PERFORATION SUMMARY 10129' H BKR ZXP PKR/ HMC LNR HGR, ID = 4.438" I REF LOG: PDS JEWELRY ON 08/23/99 ANGLE AT TOP PERF: 37 @ 10285' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10285 - 10305 0 08/08/00 MILLOUT WINDOW 2 -7/8" 6 10305 - 10325 0 08/08/00 10271' - 10283' 2 -3/4" 6 10775 - 10815 S 10/10/10 2 -3/4" 6 11020 - 11080 S 10/10/10 -lb �_ i � 2 -3/4" 6 11260 - 11300 S 10/10/10 1 �� � I 2 -3/4" 6 11520 - 11560 S 10/10/10 10, V ` I 2 -3/4" 6 11620 - 11660 S 10/10/10 2 -3/4" 6 11730 - 11770 S 10/10/10 41W 10700' I�TOC (10/05/10) � I 10750' I� WFD CMT RETAINER (10/05/10) I � I♦ 11 ►111111. WHIPSTOCK H 10271' 1,11111 ' 111 114 0 ••• 0 ••• 00' 4 0 ' ��� EZSV I 10286' .4. ∎w∎ i m, , I PBTD I 11150' ►'1'1'1'1'1'1'1'1 ■ 1111111111111111 -mu , 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I—I 11200' •'�"�'4'�'�'�'�" I PBTD H 11785' ■ i 14 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.953" H 11828' I I i i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT i 08/03/79 ORIGINAL COMPLETION 02/15/11 MB /JMD ADDED SSSV SAFETY NOTE WELL: R -03A ! 10/12/98 SIDETRACK COMPLETION PERMIT No: 1 981710 03/14/01 SIS -SLT CONVERTED TO CANVAS API No: 50- 029 - 20364 -01 ! 03/15/01 SIS -MD FINAL SEC 32, T12N, R13E ' 03/27/02 RN/TP CORRECTIONS 10/10/10 RMH/SV CMT SQZ (10/05/10) BP Exploration (Alaska) .91 - t1I 23 -SEP -2011 2irg E Schknkerger No. 5796 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD Z -04A BR12 -00017 PPROF W /DEFT & GHOST 13- Sep -11 1 1 W -05A BCRC -00126 PPROF W/ DEFT 14- Sep -11 1 1 G-30C BUTT -00025 LEAK DETECTION LOG 8-Sep-11 1 1 MPE -23 BCRC -00122 IPROF 11-Sep-11 1 1 • MPB -05A BCRC -00120 IPROF 9-Sep-11 1 1 Z -04A BR12-00017 CEMENT BOND LOG 15- Sep -11 1 1 R-03A -00094 ' PRIMARY DEPTH CONTROL LOG • 15 1 • • 1 B-27A BCRC -00134 PPROF W /GHOST 17- Sep -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 t 2,V1 July 10, 2009 ~~, ,< < ~ :3 ~~~~ ,.~~ :`;~.~~~` ~ ;, u i w. f ~ ~ Mr. Tom Maunder L~ ~ Alaska Oil and Gas Conservation Commission ~~ 3~ 333 West 7th Avenue ~ ~ Anchorage, Alaska 99501 '~ ~~ Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- 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, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. 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) R-pad Date Revised 7/10/2009 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al R-02 50029203540000 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 50029205480000 1810010 0.25 NA 025 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206180000 1810930 2 NA 2 NA 14.5 6/22/2009 R-11 A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009 R-12 50029209210000 1830350 025 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 442 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11 /2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 26, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, ~~ ~, ~ ~ JUL ~ 200~ A~~~k~ ~~€ ~ Ga~ ~on~e Com~~~~iA~ Anchor~~ ~~,~f I~ ~ ~~~ ~ Enclosed please find a spreadsheet with a list of wells from R-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, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. ~~ As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~Cri~~~Yo ~~ii~ °.! ' L'tJ~J 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) ~ ~ Date R-pad 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 1781000 1.25 NA 125 NA 6.8 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31 A 2021500 1.5 NA 1.5 NA 8.5 5/11 /2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11 /2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/1 i/2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 12/08/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall -Inh Ik NO. 4995 Company: State of Alaska ~- ~ ~ ~ 1-- t t ~ t • ~ ~ ; Alaska Oil & Gas Cons Comm "''•~'~~"'~~ ~ ~ "-.~' ~ =~U Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 nn rlu .. ..•:.... n_•_ R-03A 4994 INJECTION PROFILE (REVISED) 10/08/08 1 1 13-23A 4994 INJECTION PROFILE 10/21/08 1 1 01-26A 4994 SCMT 11/13/08 1 1 D-29 4994 USIT 10/19/08 1 1 15-02B 4994 MEM PROD PROFILE 11/25/08 1 1 H-OSA 4994 MEM PROD & INJ PROFILE 11/20/08 1 1 E-32A 4994 SCMT ( 11/04/08 1 1 12-17 4994 PRODUCTION LOG - O C.-/ 11/04/08 1 1 P2-41 4994 PRODUCTION LOG 11/07/08 1 1 1•-291M-25 4994 PRODUCTION LOG (p - 11/04/08 1 1 MPC-05A 4994 MEM LDL r 11/15/08 1 1 L-114A 4994 USIT •- .- ( S 11/03/08 1 1 A-07 4994 PRODUCTION PROFILE ~ - ~ ~• 11/27/08 1 1 07-18 4994 INJECTION PROFILE ~ - - 12/02/08 1 1 15-126 4994 MEM PROD PROFILE ~p •-- .~, ~ 11/27/08 1 1 4-40/P-43 4994 MEM LDL iq '~'" Cr 11/26/08 1 1 N-14B 4994 MCNL -(~'~L~ ~ ` 09/20/08 1 1 01-21A 4994 MCNL 09/29/08 1 1 E-29A 4994 MCNL 09/01/08 1 1 PI FACF Ar`KNAWI Fr1r:F oc r•olor ev Clnr. urar_ nr.~n noTUnwuw~~ n BP Exploration (Alaska) Inc. Petrotechnic:al Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: i' ) Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 8 8 ATTN: Beth Received by: i owl C 10/21/08 ~-``7 ~chlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Joh # 1 nn I']ncerinfinn ~ - nee el n-.1,... P2-41 12034926 PRODUCTION PROFILE 10/08/08 1 1 R-03A 12057651 INJECTION PROFILE 10/08/08 1 1 P2-13 12096919 SBHPS & PERF RECORD ~ 10/09/08 1 1 S-26 12017505 PRODUCTION PROFILE 10/10/08 1 1 S-O5A 12086687 SCMT 19~- (~- 10/12/08 1 1 V-207PB1 40017442 OH MWD/LWD EDIT 07/29/08 2 1 nl ~wc.~ wnvui...n ~...+~ ...- ...-...~ .~ .. ...... ...... ...~ ~--..-_...._ __.- _____ -_ ___ -_ --..----~........~r.+v.~ ..rv r.. . v. v.~w.~.nv e+nv ••~1 Vn1~119V vnG l•Vf ^ CHl•1'i 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2.1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: V• ~ ; '~ N0.4934 Company: State of Alaska Alaska Oil & Gas Cons Comm ' `~- ~ E' ~= ` Plt ` Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~ • Recent MITIAs for 11-38A (PTD~982160), R-03A (PTD #1981710), WGI-OS (PTD #1900250) Page 1 of 1 Re , James B DOA • 99 ~ ) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] i Sent: Sunday, February 17, 2008 6:41 PM ~ ~ y 2 iz~,~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) f Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: Recent MITIAs for 11-38A (PTD #1982160), R-03A (PTD #1981710), WGI-05 (PTD #1900250) Follow Up Flag: Follow up Flag Status: Red Attachments: MIT PBU 11-38A 02-12-08.x1s; MIT PBU R-03A 02-12-08.x1s; MIT PBU WGI-05 02-12-08.x(s Hi Jim, Tom, and Bob, Please find the attached MITIA forms for 11-38A (PTD #1982160), R-03A (PTD #1981710), and WGI-05 (PTD #1900250). 11-38A: 2-year MITIA for UIC compliance of a monobore injector ~-03A: 4-year MITIA for UIC compliance and qualification for MI service WGI-05: 4-year MITIA for UIC compliance «MIT PBU 11-38A 02-12-08.x1s» «MIT PBU R-03A 02-12-08.x1s» «MIT PBU WGI-05 02-12-08.x1s» Please let us know if you have any questions. Thank you, ,~'_nnlx 1~u6e, ~'. E. Well Integrity Coordinator Wells Group Phone: (9Gt7) 659-51(?2 Pager: (907) 659-5100 x1'154 ~~~ FED `~ €~r 7_~~ 2/20/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email fo: Winton_Auberf@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AQGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / R 02/12/08 Anna Dube Witness Declined (L. Grimaldi) ~~~~ ~~~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well R-03A Type Inj. W TVD ,526' Tubing 740 740 740 740 Interval 4 P.T.D. 1981710 Type test P Test psi 2132 Casing 700 4000 3940 3920 P/F P Notes: 4-year UIC Compliance MITIA and qualification for OA 200 200 320 360 MI service. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU R-03A 02-12-08.x1s MEMORANDUM State of Alaska 1 TO: Alaska Oil and Gas Conservation Commission THRU: Jim Regg P.I. Supervisor Á7,~1 Z) \'6\dt ~\y2c(,1 DATE: Wednesday, February 18, 2004 SUBJECT: Mechanical Integrity Tests SP EXPLORATION (ALASKA) INC R-03A PRUDHOE SAY UNIT R-03A FROM: Jeff Jones Petroleum Inspector Src: Inspector NON-CONFIDENTIAL API Well Numbe 50-029-20364-01-00 InspN mitlJ040216094341 Inspection Date: 2/15/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: R-03A Type Inj. F TVD 8525 IA 0 4000 3960 3950 P.T. 1981710 TypeTest SPT Test psi 2131.25 OA 0 100 120 180 Interval Other (describe in PIF Pass Tubing 740 740 740 740 nm"~1 Notes: Swap well to MI. 1 bb160/40 methanol pumped. Post W/O MIT Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SAL T WATER INJ. N=NOT INJECTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=Intemal Radioactive Tracer Survey A=Temprature Anomaly Surve Interval I=lnitial Test D=Differential Temprature Test 4=Four Year Cycle. V=Required by Variance W=Test during Workover O=Other (describe in notes) Wednesday, February 18, 2004 Page 1 of 1 ~GA~~ElD, MA~11. 22004 198-171-0 PRUDHOE BAY UNIT ' 'R~03A ...... 50~02'9~2'0'36420i ........... BP'EXPLO~TI'ON"(A~S~)~C MD 11828 TVD 08887 Completion Date: 11/1/98 Completed Status: 1WINJ Current: WAGIN Microfilm Roll / Roll 2 / _ Spud 10/2/98 Elevation: KB 0051 T Name Interval Run Sent Received T/C/D D 9305 1 PDS INJP CH 9/1/99 9/1/99 D 9819 1 PDS INJP 0/13/00 CH L CBL FINAL 9850-10440 CH 5 L IMP-GR FINAL 10300-11782 OH L INJP FINAL 10660-11778 CH 5 L INJP FINAL 10208-10406 0/13/00 5 R SRVYRPT SCHLUM 10195.42-11771.82 OH R USIT FINAL BL(C) 9850-10293 CH T 8967 1 SCHLUM CBT-PDC CH 10/25/00 10/25/00 1/12/99 1/15/99 2/10/99 2/18/99 9/1/99 9/1/99 10/25/00 10/25/00 11/11/98 11/12/98 1/27/99 1/28/99 1/28/99 2/4/99 9/~/QQ 9/1 R/OO OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CERTIFIED MAIL NO. 7099 3220 0004 9024 4355 RETURN RECENT REQUESTED Aprill9,2001 Mr. George Snodgrass Environmental Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: January, 2001 Injection Incidents at wells P-10 and R-3Ai Dear Mr. Snodgrass: The Commission received an email notification from you on January 25, 2001, detailing a possible misinjection of 68 barrels into well R-3Ai in Prudhoe Bay on January 22, 2001. On January 26, 2001 Jack Hartz, on behalf of the Commission, contacted you by email to request additional information regarding this misinjection. The Commission subsequently received a copy of a February 12, 2001 letter from BPXA to EPA Region 10, disclosing a possible misinjection in the above mentioned well and of a second possible misinjection into Prudhoe Bay well P-10 of 45 barrels on January 10, 2001. According to your reports, diesel product was spilled at the bulk fuel area at Prudhoe Bay. The spilled material and associated contaminated snow generated approximately 225 barrels of diesel/snowmelt mixture. The diesel/water mixture used in these two events had not previously been approved by the Commission for Enhanced Oil Recovery injection. The Commission has repeatedly requested information about the relevance of this diesel/snowmelt mixture to Enhanced Oil Recovery operations, but to date, have received no response. In addition, the Commission was assured that you were conducting an investigation into these injection incidents and that further information would be provided to us. Please provide, by April 27, 2001, (1) a copy of the laboratory samPle analysis that your email indicated would be available January 25, 2001; (2) copies of the well work prOgrams sent to operations personnel for their execution; (3) a detailed explanation of the EOR aspect of the well treatment operations; and (4) an analysis of the diesel both at the point of generation and when used. If you have any questions, please contact Wendy Mahan at 793-1236' Sincerely, Oil and Gas Conservation Commission WE'LL LOG TRANSMITTAL:: P~oActive Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petr~Technical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, Alaska 99508 LoG DIGITAL MYLAR / BLUE LINE WELL DATE TYPE DATA SEPIA FILM PRINT(S) Open Hole I I 1 R-O3Ai 8-23-99 Res. Eval. CH I I I Signed: Print Name: Date: ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone: (907) 659-2307 Fax: (907) 659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com Please Check When Transmittal Reports are Returned. Keep copy of this letter in the file for future use. C:LMy DocumentskExcel_Word_DocumentskDistribution_FormskBp_pb_form.doc 2/5/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ANN: Sherrie NO. 12311 Company Alaska Oil & Gas Cons Camm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL Sepia Tape R-03A ,~ '~'~1 99034 IMPULSE/GR 981004 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) lnc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED 1999 Alaska Oil & Gas (z,~]s,_. Corl~misslon Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A'F[N: Sherrie/ ,~0~ ....... Received b~'~ ~ 1/27/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ANN: Sherrie NO. 12276 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Color Well Job # Log Description Date Print Blueline Sepia LIS Tape R-03A {-J.t (-,...- 99033 USIT 981007 1 C-4A ~ ~<::~,~;"'~ 99028 CNTD 981201 1 1 1 X-O3A ~ ~c~. 5 ~ 99020 CNTG 980616 1 1 1 ,I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center MB3-3 900 E, Benson Bivd, Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: JAN ('Iii Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK ~3 Received ,I~,1 ~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 All'N: Sherrie NO. 12224 Company Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1/12/99 Field: Prudhoe Bay (Cased Hole) Color Well Job # Log Description Date Print Blueline Sepia LIS Tape H-30 99009 USIT 971126 1 R-03A CBT 981007 i 1 W-200 PRODUCTION LOG 981221 1 1 Q-02A (REDO) MCNL ~ ~'~r~-" 970825 1 1 1 REDO-TO SHIFT TO MWD-GR PLease ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: ~ ~_..~T'~.Oy I~_~ ~'-~-t~l~E , L.,'~¢,',~.~ ~C'~'C~) BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Bivd. Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, A~-~3 A'FI'N: Sh Receiv STATE OF ALASKA .... J ALASKA OIL AND GAS CONSERVATION COMMISSION WELL 12OMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [--IOil I~Gas I--jSuspended I--]Abandoned [~Service Water & Gas Injector 'iii !-~ :i ..... i~-~ ': ~....~ 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-171 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20364-01 4. Location of well at surface ....... ~.~,,~.~.~.. 9. Unit or Lease Name.. :.'?i 4619' SNL, 4203' WEL, SEC. 32, T12N, R13E, UM ! ; '; : r,r ; :I :,'2 :' '._ . ', ~~.~ ~ Prudhoe Bay Urii( ..... At top of productive interval il /./l~i~¢~ /.,. ,,,..,,_ .... "~~~~ 10. Well Number 327' SNL, 152' WEL, SEC. 31, T12N, R13E, UM - ~ R-03Ai At total depth ;~/:ii~.: 11 Field and Pool 115' NSL, 4238' WEL, SEC. 29, T12N, R13E, UM --- i_~~.~../~-.- ' ................ ~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 50.53'J ADL 028279 12. Date Spudded10/2/98 113' Date T'D' Reached I 14' Date C°mp" Susp" °r ~bend'115' Water depth' if °ffsh°re 116' NO' Of COmpletiOns10/4/98 1~ //,/),,/,¢' ' N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Surv~y-]20. Depth where SSSV set 121. Thickness of Permafrost 11828 8887 FTJ 11783 8884 FTI I~Yes I--lNG I (Nipple) 2013' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, 4-Phase RES, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED i20" x 30" Insulated Conductor Surface 110' 36" 558 cuft Arcticset 13-3/8" 72# L-80 Surface 2672' 17-1/2" 6785 cu ft Permafrost II 9-5/8" 47# L-80 Surface 10083' 12-1/4" 1409 cu ft Class 'G', 130 cuft Permafrost 7" 29# L-80 9550' 10271' 8-1/2" 500 cu ft Class 'G' 4-1/2" 12.6# L-80 10118' 11828' 6" 252 cuft Class 'G 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10133' 10076' MD TVD MD TVD 10775' - 10815' 8866' - 8867' 11020' - 11080' 8860' - 8857' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11260' - 11300' 8848' - 8846' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11520' - 11560' 8855' - 8859' 11620' - 11660' 8866' - 8871' Freeze Protect with 150 Bbls of Diesel 11730' - 11770' 8879' - 8883' T ST Date First Production J Method of Operation (Flowing, gas lift, etc.) ~,2 ", '~ ~ w November 1, 1998I Water & Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL iGAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Shublik 10328' 8728' Shublik 'B' 10404' 8781' Shublik %' 10430' 8796' Top of Sadlerochit / Z4B 10471' 8816' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~--------'-~ __. -,..~. ~ Dan Stone Title Engineering Supervisor Date i~ (fl [ _~,~, R-03Ai 98-171 Prepared By Name/Number: Terrie Hubble. 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 23 Sep 98 24 Sep 98 25 Sep 98 26 Sep 98 27 Sep 98 PB R Pad Progress Report Well R-03A Rig Nabors 2ES Duration Activity 06:00-17:30 17:30-19:00 19:00-00:00 00:00-00:30 00:30-04:30 04:30-06:00 06:00-10:00 10:00-10:30 10:30-11:30 11:30-12:00 12:00-12:30 12:30-14:00 14:00-16:00 16:00-18:30 18:30-19:30 19:30-20:30 20:30-21:00 21:00-00:00 00:00-00:30 00:30-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-09:00 09:00-14:30 14:30-15:30 15:30-00:00 00:00-00:30 00:30-04:00 04:00-06:00 06:00-07:30 07:30-10:00 10:00-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-16:00 16:00-19:00 19:00-19:30 19:30-20:30 20:30-21:30 21:30-22:30 22:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-03:30 03:30-06:00 06:00-07:00 07:00-08:30 08:30-09:00 09:00-11:00 11:00-12:00 11-1/2 hr 1-1/2 hr 5 hr 1/2 hr 4hr 1-1/2 hr 4 hr 1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr 2 hr 2-1/2 hr 1 hr lhr 1/2 hr 3 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 3 hr 5-1/2 hr lhr 8-1/2 hr 1/2 hr 3-1/2 hr 2hr 1-1/2 hr 2-1/2 hr 1 hr 1 hr 1/2 hr 1 hr 1/2 hr 2 hr 3hr 1/2 hr 1 hr 1 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 2-1/2 hr 1 hr 1-1/2 hr 1/2 hr 2 hr 1 hr Rig moved 50.00 % Held safety meeting Rig moved 100.00 % Held safety meeting Fill pits with Seawater Circulated at 9360.0 ft Circulated at 9360.0 ft (cont...) Installed Accessories Held safety meeting Rigged down Surface tree Held safety meeting Removed Surface tree Installed BOP stack Tested BOP stack Removed Accessories Installed Tubing handling equipment Removed Tubing hanger Circulated at 9360.0 ft Held safety meeting Laid down 80.0 ft of Tubing Installed Retrievable packer Removed BOP stack Removed Tubing head spool Removed Tubing head spool (cont...) Installed BOP stack Retrieved Retrievable packer Laid down 9360.0 ft of Tubing Held safety meeting Laid down 9360.0 ft of Tubing Serviced Top ram Made up BHA no. 1 R.I.H. to 6280.0 ft Serviced Block line Singled in drill pipe to 7100.0 ft Held safety meeting Singled in drill pipe to 9375.0 ft Fished at 9375.0 ft Circulated at 9375.0 ft Pulled out of hole to 320.0 ft Pulled BHA Laid down fish Rigged up Drillstring handling equipment Made up BHA no. 2 R.I.H. to 6000.0 ft Held safety meeting R.I.H. to 9462.0 ft Fished at 9462.0 ft Circulated at 9462.0 ft Pulled out of hole to 0.0 ft Pulled out of hole to 0.0 ft (cont...) Pulled BHA Laid down fish Made up BHA no. 3 R.I.H. to 3000.0 ft Page Date 1 10 November 98 Facility Date/Time 28 Sep 98 29 Sep 98 30 Sep 98 01 Oct 98 02 Oct 98 PB R Pad Progress Report Well R-03A Page Rig Nabors 2ES Date Duration Activity 12:00-12:30 12:30-14:00 14:00-14:30 14:30-00:00 00:00-00:30 00:30-06:00 06:00-10:30 10:30-17:00 17:00-19:00 19:00-22:00 22:00-02:00 02:00-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-08:30 08:30-10:30 10:30-13:30 13:30-15:00 15:00-16:00 16:00-19:00 19:00-20:00 20:00-00:00 00:00-00:30 00:30-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-10:30 10:30-14:30 14:30-15:30 15:30-19:00 1/2 hr 1-1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 5-1/2 hr 4-1/2 hr 6-1/2 hr 2 hr 3 hr 4 hr 2 hr 2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 2 hr 3 hr 1-1/2 hr 1 hr 3 hr 1 hr 4 hr 1/2 hr 1-1/2 hr 2 hr 1 hr 1 hr 2 hr 2-1/2 hr 4 hr 1 hr 3-1/2 hr Held safety meeting R.I.H. to 9462.0 ft Fished at 9484.0 ft Repaired Draw works Held safety meeting Repaired Draw works Repaired Rotary table Drilled installed equipment - Production packer Circulated at 9510.0 ft Pulled out of hole to 480.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 5900.0 ft Serviced Block line R.I.H. to 10320.0 ft Circulated at 10320.0 ft Tested Liner - Via annulus Circulated at 10320.0 ft Pulled out of hole to 480.0 ft Pulled BHA Rigged up sub-surface equipment - Cement retainer Conducted electric cable operations Rigged down sub-surface equipment - Setting tools Ran Drillpipe in stands to 10288.0 ft Held safety meeting Mixed and pumped slurry - 20.000 bbl Circulated at 10286.0 ft Laid down 950.0 ft of 5in OD drill pipe Pulled Drillpipe in stands to 0.0 ft Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 5 R.I.H.'to 10291.0 ft Functioned Other sub-surface equipment Circulated at 10291.0 ft 19:00-06:00 06:00-08:00 08:00-09:30 09:30-10:30 10:30-16:00 16:00-16:30 16:30-19:00 19:00-19:30 19:30-20:00 20:00-21:00 21:00-21:30 21:30-23:00 23:00-00:00 00:00-01:00 01:00-05:00 05:00-06:00 06:00-10:00 10:00-12:30 12:30-23:00 23:00-00:30 llhr 2 hr 1-1/2 hr 1 hr 5-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr 1 hr 1 hr 4 hr 1 hr 4 hr 2-1/2 hr 10-1/2 hr 1-1/2 hr Milled Other sub-surface equipment at 10271.0 ft Milled Other sub-surface equipment at 10292.0 ft Circulated at 10292.0 ft Serviced Block line Pulled out of hole to 0.0 ft Retrieved B ore protector Tested BOP stack Installed Wear bushing Made up BHA no. 6 R.I.H. to 2300.0 ft Held drill (Kick while tripping) R.I.H. to 12093.0 ft Milled Liner at 10295.0 ft Circulated at 10295.0 ft Pulled out of hole to 750.0 ft Pulled BHA Made up BHA no. 7 R.I.H. to 10275.0 ft Drilled to 10655.0 ft Circulated at 10655.0 ft 2 10 November 98 Facility Date/Time 03 Oct 98 04 Oct 98 05 Oct 98 06 Oct 98 07 Oct 98 08 Oct 98 Progress Report PB R Pad Well R-03A Page 3 Rig Nabors 2ES Date 10 November 98 00:30-04:30 04:30-06:00 06:00-09:30 09:30-10:00 10:00-11:30 11:30-06:00 06:00-16:00 16:00-18:30 18:30-00:00 00:00-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-10:30 10:30-11:00 11:00-11:30 11:30-14:00 14:00-14:30 14:30-16:00 16:00-17:30 17:30-18:00 18:00-19:00 19:00-23:30 23:30-02:30 02:30-06:00 06:00-07:00 07:00-08:00 08:00-08:30 08:30-11:00 11:00-14:30 14:30-18:30 18:30-20:00 20:00-21:00 21:00-01:00 01:00-02:30 02:30-06:00 06:00-06:30 06:30-14:00 14:00-15:30 15:30-18:30 18:30-19:00 19:00-20:00 20:00-23:30 23:30-05:30 05:30-05:45 05:45-06:00 06:00-07:00 07:00-08:30 08:30-11:30 11:30-13:30 13:30-17:00 17:00-21:00 Duration 4 hr 1-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 18-1/2 hr 10 hr 2-1/2 hr 5-1/2 hr 3 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1 hr 4-1/2 hr 3 hr 3-1/2 hr 1 hr 1 hr 1/2 hr 2-1/2 hr 3-1/2 hr 4 hr 1-1/2 hr 1 hr 4 hr 1-1/2 hr 3-1/2 hr 1/2 hr 7-1/2 hr 1-1/2 hr 3hr 1/2 hr 1 hr 3-1/2 hr 6 hr 1/4 hr 1/4 hr 1 hr 1-1/2 hr 3 hr 2 hr 3-1/2 hr 4 hr Activity Pulled out of hole to 225.0 fi Pulled BHA Made up BHA no. 8 Serviced Block line R.I.H. to 10634.0 ft Drilled to 11500.0 ft Drilled to 11829.0 ft Circulated at 11828.0 ft Pulled out of hole to 680.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 1700.0 ft (4-1/2in OD) Ran Liner to 1700.0 ft (4-1/2in OD) Circulated at 1700.0 ft Ran Liner on landing string to 10250.0 ft Circulated at 10260.0 ft Ran Liner on landing string to 11828.0 ft Circulated at 11828.0 ft Held safety meeting Batch mixed slurry - 45.000 bbl Circulated at 10118.0 ft Pulled Drillpipe in stands to 9618.0 ft Serviced Block line Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 9 R.I.H. to 9950.0 ft R.I.H. to 11691.0 ft Circulated at 11740.0 ft Tested Liner - Via annulus and string Drilled installed equipment - Landing collar Circulated at 11783.0 ft Pulled out of hole to 1700.0 ft Laid down 925.0 fi of 2-7/8in OD drill pipe Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Rigged down sub-surface equipment - Production logging tools Rigged up sub-surface equipment - TCP Worked toolstring at 10557.0 ft Pulled Drillpipe in stands to 9300.0 ft Retrieved Retrievable packer Pulled Drillpipe in stands to 820.0 ft Retrieved Gun assembly Singled in drill pipe to 10455.0 ft Washed to 10455.0 ft Ran Drillpipe in stands to 10650.0 ft Ran Drillpipe in stands to 11755.0 ft Circulated at 11783.0 ft Pulled Drillpipe in stands to 10455.0 fi Ran Drillpipe in stands to 11783.0 ft Pulled Drillpipe in stands to 10672.0 fi Pulled out of hole to 0.0 ft Facility Date/Time 09 Oct 98 10 Oct 98 11 Oct 98 Progress Report PB R Pad Well R-03A Page Rig Nabors 2ES Date 21:00-22:30 22:30-03:00 03:00-04:00 04:00-05:30 05:30-06:00 06:00-07:00 07:00-12:00 12:00-14:00 14:00-14:30 14:30-22:00 22:00-00:00 00:00-03:30 03:30-06:00 06:00-15:00 15:00-16:00 16:00-16:30 16:30-04:00 04:00-06:00 06:00-07:00 07:00-09:00 09:00-09:30 09:30-10:00 10:00-12:30 12:30-14:00 14:00-16:00 16:00-17:00 Duration 1-1/2 hr 4-1/2 hr 1 hr 1-1/2 hr 1/2 hr 1 hr 5 hr 2 hr 1/2 hr 7-1/2 hr 2 hr 3-1/2 hr 2-1/2 hr 9 hr 1 hr 1/2 hr 11-1/2 hr 2 hr 1 hr 2hr 1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 2 hr 1 hr Activity Rigged down sub-surface equipment - Casing scraper Ran Drillpipe in stands to 9000.0 ft Serviced Lines / Cables Ran Drillpipe in stands to 11783.0 ft Reverse circulated at 11783.0 ft Reverse circulated at 11785.0 ft Pulled out of hole to 935.0 ft Pulled Drillpipe in stands to 0.0 ft Held safety meeting Ran Drillpipe in stands to 11785.0 ft Perforated Reverse circulated at 10015.0 ft Pulled out of hole to 7500.0 ft Laid down 10500.0 ft of 5in OD drill pipe Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 10118.0 ft (4-1/2in OD) Rigged down BOP stack Rigged down BOP stack Rigged up Adapter spool Tested Tubing hanger Removed Hanger plug Circulated at 10130.0 ft Circulated at 10130.0 ft Tested Tubing Installed Hanger plug 4 10 November 98 Anaddll SURVEY REPORT Client: Field: BP Exploration (Alaska), Inc. Prudhoe Bay RECEIVED 0CT ! 1998 Well Name: R-03Ai APl number: 50-029-20364-01 Job number: 40002857 Rig: Nabors 2ES County: NSB State: AK Survey Calculations Calc method for pos~ons: Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum Depth reference GL above Permanent KB above Permanent DF above Permanent MSL KB 0 ft 50.53 ft 21.76 ft 50.53 ft 49.13 ft Vertical section odgin Latidude (+N/S-): Departure (+E/W-): 4114.26 ft 1274.86 ft Spud Date: Last survey date: Total accepted surveys: MD of first survey: MD of last survey: Geomagnetic data BPX o -_ocl 49 10195.4*2 ft 11771.82 It , ORIGINAL Magnetic Model: Magnetic Date: Magnetic field strength: Magnetic dec (+ENV-): Magnetic Dip: BGGM 1997 Version 21-Sep-98 1146~39 HCNT 27.78 degrees 80.73 degrees MWD Survey Reference Criteria Reference G: Reference H: Reference Dip: Tolerance G: Tolerance H: Tolerance Dip: 1002.68 milliG 1146.39 HCNT 80.73 degrees 3 milliG 7 HCNT 0.3 degrees Azim from RT to target: 67.63 degrees Schlumberger ANADRILL Survey Report Correction Magnetic dec (+E/W-): Gdd convergence (+E/W-): Total az corr (+E/W-): 27.78 degrees 0 degrees 27.78 degrees Seq Measured Incl Azimuth Course # Depth angle angle length (fi) (deg) (deg) (ft) 1 10195.42 36.00 351.0 0.0 2 10271.00 36.59 353.9 75.6 3 10301.51 38.95 1.8 30.5 4 10333.53 41.96 10.0 32.0 5 10365.94 45.86 18.6 32.4 6 10398.34 51.03 27.6 32.4 7 10427.07 56.43 33.1 28.8 8 10457.96 61.78 37.7 30.9 9 10489.39 66.40 44.2 31.4 10 10522.71 70.01 51.1 33.3 11 10553.38 72.58 57.9 30.7 12 10583.95 75.42 62.6 30.5 13 10610.06 79.42 66.8 26.2 14 10648.94 87.91 67.1 38.8 15 10684.15 89.59 70.9. 35.2 TVD depth (~ 8622.93 8683.87 8707.99 8732.35 8755.71 Vertical Displacement section +N/S- +E/W- (ft) (ft) (fi) 389.16 4114.26 -1274.86 400.63 4158.61 -1280.73 407.10 4177.25 -1281.41 416.95 4197.86 -1279.25 430.40 4219.57 -1273.66 8777.22 8794.26 8810.13 8823.86 8836.23 447.71 4241.79 -1264.10 466.19 4261.79 -1252.34 488.63 4283.37 -1236.97 513.86 4304.66 -1218.46 542.90 4325.45 -1195.61 8846.08 8854.50 8860.20 8864.48 8865.25 571.21 4342.31 -1171.95 600.27 4356.85 -1146.50 625.80 4367.76 -1123.39 664.33 4382.85 -1087.94 699.50 4395.46 -1055.09 To~l at Azm DLS displacement (deg/ (fi) (deg) 100~ 4307.25 342.78 0.00 4351.36 342.88 2.40 4369.37 342.95 17.46 4388.45 343.05 19.26 4407.60 343.20 21.97 4426.1'4 343.41 26.18 4441.98 343.62 24.25 4458.40 343.89 21.51 4473.78 344.20 23.72 4487.65 344.55 22.08 4497.68 344.90 22.58 4505.17 345.26 1~.49 4509.92 345.58 21.86 4515.86 346.06 21.89 4520.32 346.50 11.80 Page I "S ,umbergerANADRILLSurvey F ,rt I ;q Measured Incl Azimuth '-~°urse -I-VD .~ Depth angle angle length depth (fi) (deg) (deg) (ft) (fi:) 16 10716.16 89.49 72.7 32.1 8865.51 17 10748.62 89.31 73.9 32.4 8865.85 18 10780.61 89.08 73.6 32.0 8866.29 19 10812.50 89.01 73.5 31.9 8866.83 20 10844.18 88.90 74.2 31.7 8867.40 21 10873,98 89,45 75,0 29,8 8867.83 22 10907,44 92,02 74,4 33,4 8867,40 23 10939,83 93,81 73.0 32.4 8865.76 24 10971,52 93,95 71,1 31.7 8863,61 25 11003,13 93,74 71,2 31,6 8861,49 26 11035.05 93.40 71.0 32.0 8859.50 27 11065.54 93.36 71.0 30.4 8857.71 28 11099.09 93.26 72.3 33.6 8855.77 29 11131.33 93.09 71.9 32.2 8853.98 30 11161.71 93.02 71.9 30.4 8852.36 31 11193.33 93.02 72.2 31.6 8850.70 32 11225.41 92.85 73.7 32.1 8849.06 33 11256.78 92.33 73.2 31.4 8847.64 34 11288.15 92.02 73.3 31.4 8846.45 35 11320.34 92.26 73.1 32.1 8845.25 36 11352.10 90.65 73.7 31.8 8844.44 37 11383.92 87.94 72.7 31.8 8844.83 38 11415.40 86.54 73.5 31.5 8846,35 39 11447.90 85.81 72.0 32.5 8848.52 40 11480.04 8~.68 72.7 32.1 8851.18 41 11512.09 84.64 72.2 32.1 8854,16 42 11543.79 84.09 71.9 31.7 8857.28 43 11576.84 83.71 71.3 33.0 8860.78 44 11607.57 82.58 72.2 30.8 8864.46 45 11638.54 82.54 71.9 30.9 8868.46 46 11670.79 82.30 72.3 32.3 8872.72 47 11702.82 83.44 73.0 32.0 8876.69 48 11734.71 85.68 73.9 31.9 8879.72 49 11771.82 85.19 73.7 37.1 8882.67 Vertical Displacement section +N/S- +ENV- 731.51 4405.48 -1024.60 763.75 4414.79 -993.57 795.56 4423.74 -962.85 827.28 4432.78 -932.26 858.79 4441.59 -901.81 888.37 4449.51 -873.09 921,50 4458.32 -840.88 953.68 4467.40 -809,82 985.21 4477.14 -779,74 1016,67 4487,33 -749,90 1048.55 4497.68 -719.68 1078.85 4507.56 -690.99 1112.31 4518.12 -659.15 1144.36 4528.00 -628.56 1174.63 4537.43 -599.70 1206,09 4547,15 -569,68 1238,01 4556,55 -539,03 1269,21 4565,49 -508,97 1300,44 4574,53 -478,92 1332.36 4583,80 -448,21 1363.99 4592.89 -417.75 1395.63 4602.07 -387.31 1426,95 4611.22 -357.21 1459.24 4620.84 -326,24 1491.12 4630.54 -295.75 1522.97 4640.17 -265.28 1554.42 4649.90 -235.27 1587.15 4660.25 -204.14 1617.65 4669.83 -175.09 1648.20 4679,27 -145.95 1680.12 4689.11 -115.48 1711.75 4698.58 -85.17 1743.34 4707.63 -54.73 1780.10 4717.94 -19.22 Te.tali atAzm DLS displacement (deg/ (fi) (deg) 1000 4523.06 346.91 5.62 4525.21 347.32 3.75 4527.32 347.72 1.18 4529.75 348.12 0.38 4532.22 348.52 2.23 4534.36 348.90 4536.92 349.32 4540.20 349.73 4544.54 350.12 4549.56 350.51 4554.89 350.91 4560.21 351.28 4565~95 351.70 4571.42 352.10 4576.89 352.47 4582.70 352.86 45~88,'~3 353,25 4593,77 353,64 4599,53 354.02 4605,67 354,42 4611.84 354.80 4618.34 355.19 4625.04 355.57 4632.34 355.96 4639.97 356.35 4647.75 356.73 4655.84 357.10 4664.72 357.49 4673.11 357.85 4681.55 358.21 4690.54 358.59 4699.~5 358.96 4707.94 359.33 4717.98 359.77 3.26 7.90 7.01 6.00 0.74 1.23 0.13 3.87 1.35 0.23 0,95 4.70 2,30 1,04 0.97 5.40 9.08 5.12 5.12 4.14 1.56 1.97 2.14 4.68 0.97 1.43 4.17 7.56 1.43 Page 2 MEMORANDUM State of Alaska TO: THRU: Alaska Oil and Gas Conservation Commission Chairma, rf~,~ · Blair Wondzell, P. I. Supervisor FROM' Lou Grimaldi, ~' ,¢,'~-~ SUBJECT: Petroleum Inspector DATE: October 3, 1998 FILE NO: AIMJJAFE.DOC BOPE Test Nabors 2ES BPX well #R-03i Prudhoe Bay. Field PTD #98-171 Saturday, July 25, 1998: I witnessed the weekly BOPE test on Nabors rig 2ES which was performing a redrill on BPX well #R-03i in the Prudhoe Bay field. The rig was not ready to test when I arrived and I made a short tour around the rig, I found all to be clean and in good order. All BOPE equipment was tested with no failures observed. The Gas detectors were tested while i was there and found to be in good shape. The test time of 2 1/2 hours is much better than the four hours I experienced in July. This rig is a good rig to test on as the crews know their job and the test moves along at a brisk pace. The equipment normally tests out "OK". SUMMARY: I witnessed the weekly test of the BOPE on Nabors rig #2ES which is redrilling BPX well #R-03i in the Prudhoe Bay Field. There were no failures observed. Test time 2 1/2 hours. Attachments: AIMJJAFE.XLS CC: Steve Walls/John Raul (Shared Services Drilling) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Nabors ~ Operator: BP Exploration Well Name: R-03Ai Casing Size: Test: Initial Workover: Rig No. 2 Set@ Weekly X Other DATE: PTD # 98-171 Rig Ph.# Rep.: Chadie Russell 10/1/98 Rig Rep.: Keith Spoals Location: Sec. 32 T. 12N R. 13E Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gert) PTD On Location P Standing Order Posted P Well Sign P DH. Rig P Hazard Sec. P BOP STACK: Annular Preventer Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1 Check Valve 1 Quan. Test Press. P/F 1 P 250/2500 250/5,000 MUD SYSTEM: Visual Alarm Tdp Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure I 250/5,000 1 1 1 - P/F P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure 250/5,000 Functioned PIF P P ACCUMULATOR SYSTEM: System Pressure 3000 Pressure After Closure 1700 200 psi Attained After Closure System Pressure Attained 1 Blind Switch Covers: Master: P Nitgn. Btl's: 4 bottles @ 2200 mln's 22 sec. ~mJn's 36 sec. Remot P TEST RESULTS Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves teste 23 Repair or replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax NO. 276.7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: STATE WITNESS REQUIRED? odg-Well File YES X NO c- Oper./Rig c- Database 24 HOUR NOTICE OIVEN c - Trip Rpt File YES X NO c- Inspector Waived By: Witnessed By: Lou Grimaldi TONY KNOWLE$, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 31, 1998 Dan Stone Engineering Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit R-03Ai BP Exploration (Alaska) Inc. Permit No. 98-171 Sur. Loc. 4619'SNL, 4203~VEL, Sec. 32, T12N, R13E, UM Btmnhole Loc. 170'NSL, 4176'WEL, Sec. 29, T12N, R13E, UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission max.' witness the tests. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnstx~ Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. - -~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type o'f work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI .. [] Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 48.99' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028279 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4619' SNL, 4203' WEL, SEC. 32, T12N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 5121' NSL, 4977' WEL, SEC. 32, T12N, R13E, UM R-03Ai At total depth 9. Approximate spud date Amount $200,000.00 170' NSL, 4176' WEL, SEC. 29, T12N, R13E, UM 09/01/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028278, 4176'I No Close Approach 2560 11820' MD / 8830' TVDss 16. To be completed for deviated wells !17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10265' Maximum Hole An,qle 94-2° Maximum surface 2324 psig, At total depth C-VD) 8756' / 3200 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT 1705' 10115' 8503' 11820' 8830' 201 sxClass 'G' ~\L,~., L I V I-L/ ,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary AUG 1 9 1998 Total depth: measured 11205 feet Plugs (measured) true vertical 9431 feet Alattl(ii 0il & (~ C0r~g. Commission Effective depth: measured 11050 feet Junk (measured) fill at 11050' MD (11/90) true vertical 9308 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20"x 30" 558 cuft Arcticset 143' 143' Surface 2639' 13-3/8" 6785 cuft Permafrost II 2672' 2672' Intermediate 10050' 9-5/8" 1409 cuft Class 'G', 130 cuft PF 10083' 8532' Production Liner 1650' 7" 500 cuft Class 'G' 9550' - 11200' 8100' - 9427' Perforation depth: measured Sag River: 10267' - 10316' Ivishak: 10442' - 10715' (nine intervals) true vertical subsea Sag River: 8626' - 8666' Ivishak: 8766' - 8984' (nine intervals) ,, 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris Brown, 564-5582 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ---~-~. -r-n . ._~-~'--~--_~ b/'~/~ Da. Stooe .... Title Engineering Supervisor Date Commission Use Only Permit N~)mb lAP, Number ~..~pproval ~t~ See cover letter ~f ._e~',,~ ! 50-029-20364-01 ~' ~-- for other requirements Conditions of Approval: Samples Required [] Yes [~ No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required ~]Yes [] No Required Working Pressure for BOPE []2M; ,,~3M; []5M; F-I10M' []15M Other: ,Jr~g~nal Signed by David W. Johnston by order of '~/ Approved By Commissioner the commission Date ~-" STATE OF ALASKA ALASKA .~:,L AND GAS CONSERVATION COM'-~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil'. [] Re-Entry [] Deepen []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 110. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 48.99' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028279~'~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4619' SNL, 4203' WEL, SEC. 32, T12N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 5121' NSL, 4977' WEL, SEC. 32, T12N, R13E, UM R-03Ai At total depth 9. Approximate spud date Amount $200,000.00 170' NSL, 4176' WEL, SEC. 29, T12N, R13E, UM 09/01/98 12. Distance to nearest property line113. Distance to nearest well :14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028278, 4176'I No Close Approach 2560 11820' MD / 8830' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10265' Maximum Hole Angle 94.2° Maximum surface 2324 psig, At total depth O'VD) 8756' / 3200 psig 18. Casing Program Specifications Setting Depth Size Top ..... Bottom Quantit..y. of Cement Hole Casing Weight Grade Coupling Length MD I TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT 1705' 10115'I 8503' 11820' 8830' 201 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary AUG ~ 9i998 Total depth: measured 11205 feet Plugs (measured) true vertical 9431 feet Effective depth' measured 11050 feet Junk (measured) fill at 11050' MD (11/90) true vertical 9308 feet AriC~I0ra{~, Casing Length Size Cemented MD TVD Structural Conductor 110' 20"x 30" 558 cuft Arcticset 143' 143' Surface 2639' 13-3/8" 6785 cuft Permafrost II 2672' 2672' Intermediate 10050' 9-5/8" 1409 cuft Class 'G', 130 cuft PF 10083' 8532' Production Liner 1650' 7" 500 cu ft Class 'G' 9550' - 11200' 8100' - 9427' ORIGINAl Perforation depth: measured Sag River: 10267' - 10316' Ivishak: 10442' - 10715' (nine intervals) true vertical subsea Sag River: 8626' - 8666' Ivishak: 8766' - 8984' (nine intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris Brown, 564-5582 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-------------~__ -¢~ ,~ Dan Stone ' Title Engineering Supervisor Date Commission Use Only Perm~ N~u.m b/e~ I APl Number Approval D~ate I See cover letter ! 50-029-20364-01 (¢ ~'r,¢/- ~;~ for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes [~No Hydrogen Sulfide Measures [~Yes [] No Directional Survey Required []Yes [] No Required Working Pressure for BOPE 1--12M; r~3M; [-15M; []10M; []15M Other: by order of Approved By ~¥;i'lal 61§rluu ,~ Commissioner the commission Date~ ,~_..:,.~' '.."..' I_l-~_J._._ Form 10-401 Rev. 12-01-85 ,.'avid W. Johnston Submit In Triplicate I Well Name: [R-03ai I Type of Well: HST Sidetrack Summary Revision #1 I Injector Surface Location: 4619' FNL, 4203' FEL, S32, T12N, R13E, UM Target Location: 5121' FSL, 4977' FEL, S32, T12N, R13E, UM Bottom Hole Location: 170' FSL, 4176' FEL, S29, T12N, R13E, UM I AFE Number: ]4P0984 Estimated Start Date: ] 9/1/98 ]Rig: [Nabors 2ES [Operating days to complete: I 15 IUD: Ilx,820' I I TVI>: 18,830' ss I I wen Design: I HST Sidetrack I I KB Elev. 48.99' Objective: IThis well is to be drilled as a horizontal sidetrack. The new sidetrack will provide tubing mechanical integrity and injection conformance in upper Zone 4. The well is required to updulate through the upper 50' of Zone 4 and maintain access to the Sag. -- Formation Markers Formation Tops TSag K/O 10256' 10265' TVD (ss) 8623' 8630' TSHU 10312' 8667' TSAD 10442' 8756' TD 11820' 8830' TZ3 NR 8915' TZ2 NR 8965' HOT NR 8990' TZ1 NR 9220' Directional IKOP: Il0,265' MD Maximum Hole Angle: Rig Move Close Approaches: Drilling Close Approaches: 94.2° through targets R-33, R-31 will be 35' either side of R- 03ai and will be shut in during the rig move. None Casing/Tubing . rogram Hole Size Tubular WtfFt Grade T Conn~ Length Top Btm O.D. MDfrVDss MD/TVDss 6" 4-1/2" 12.6# LB0 IBT 1705' 10115¥8503' 11820'/8830' Production Tubing NA I 4-1/2" 12.6~ L80 IBT 10089' 26'/-23' 10115'/8503' Mud Program Milling Interval: 6% KC1 Milling fluid Density, ppg I Funnel Vis,'sec I LSRVI pH [ APg FL, cc 8.7-8.8+ I 50- 65 I >35,000 8.5 - 9.0 NC Hazards/Concerns I Maintain viscosity at 50 - 65 to insure adequate removal of metal cuttings. I Ensure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. Production (6" hole) Section: 6 % Quickdriln (viscosified SW) 8.7 - 8.8+ 50 - 65 > 35,000 8.5 - 9.0 NC Hazards/Concerns Potential high torque could require lubricant use. If so, employ Lubetex Be alert for lost circulation, differential sticking due to overbalanced MW. Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8+ ppg. Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt ! Yield Comments 4-1/2" N/A 201 / 15.7 / 1.19 Class G: 40% excess; Pump time = 4 hr.; TOC 200' above TOL. Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Open Hole Logs: Logging Program 6" Hole Cased Hole Logs: MWD Dir/GR/4 phase resistivity No logs unless MWD resistivity unavailable or unusable CBL if required to prove isolation Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Bottom hole pressure is expected to be 3200psi @ 8756' TVDSS Maximum expected surface pressure at 8756' TVDSS is 2324psi (assuming gas column of 0.1psi/ft) Hazards The main production target for this well is Zone 4. Only one minor fault will be crossed in the polygon and recent wells drilled in this area have not experienced severe losses, hence although preparations should be made to pump LCM, lost circulation is not expected to be a major problem. The Boundary Fault is located to the north of the polygon, and hence this edge of the polygon is a hardline to avoid crossing the fault. No potential close approaches have been identified while drilling this well. Sag River The Sag River in this well has a slightly low formation pressure at 6.8ppg EMW and hence is not ex- pected to cause a lost circulation problem. The pad data sheet indicates that only one well (R-36i) has experienced major lost circulation in this production interval, most other drilling wells experiencing only minor losses. This well does cross one minor fault while in the target polygon, and should any losses oc- cur due to the fault, productive zone LCM will be employed to combat them. Recent wells have experi- enced very little or no lost circulation at all while drilling the production interval. On the R-36i well, returns were not obtained while cementing the casing in place. However, this has not been the case on any of the recent R-pad wells. Risk of differential sticking is low based on offset wells, but should it occur, will be mitigated by the use of the Quikdriln drilling fluid which is solids free and does not form a filter cake. Ivishak Differential sticking has occurred frequently on older wells in the Ivishak at +/-9183' TVD. Once the sticking occurs it is very strong and has created difficulty in freeing up the drillstring. On R-35A, the sticking was successfully alleviated by pumping a 20bbl pill of Liquid Casing, OM Seal, and Barafibre and reducing pump rate to 5bpm (to reduce ECD). Note however that these wells were drilled using LSND mud; since this well will employ solids free Quikdriln, this should mitigate the risk of sticking. High torque has been reported on several older wells in the production hole, hence some open hole lu- brication may be required. The pad data sheet incorporates wells from R, F and J pad as the bottom hole location of these wells are all in the same area. Wells from all three pads have experienced problems with bridges, tight hole, differential sticking, and packing off while in the production interval. This has caused numerous incidents of stuck logs, casing, and drillstring. This is a high potential stuck pipe area - be alert while drilling this interval and employ frequent reaming if any sign of unstable hole is seen. Note however, that recent R-pad wells have not experienced any trouble from sticking and it is expected that this well will be drilled without a signficant sticking problem. Disposal All cuttings should be hauled to the ball mill at CC-2A for disposal. Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. Operations Summary Pre-Rig Work: NOTE: If any problems with the 9-5/8" packoff are observed during pre-rig work, contact the well- head manufacturer to initiate repairs and inform the Operations Drilling Engineer. 1. Test 9-5/8" and tubing hanger packoff to 5,000psi if not recently tested (<1 month). If tubing and an- nulus have not recently (_< 1 month) been tested, pressure test to 3,000psi. 2. R/U wireline and RIH to 9,440' with 3-3/8" tubing punch. Perforate 5-1/2" tubing and circulate the well through the perforations until clean returns are obtained. 3. RIH with retrieving tool and attempt to retrieve AVA Model DWP tubing patch from tubing at _+504' (elm) with wireline retrieving tool. RIH and retrieve SSSV and 3.813" insert. . RI/-t with chemical cutter assembly and cut tubing at middle of first full joint above the Baker sliding sleeve at +9380'. Circulate seawater through the cut until clean returns are obtained. Ensure that well will stand full of seawater - bullhead LCM to perforations to stop any losses. Note: Since the tubing is holed close to surface the tubing will be chemical cut to ensure it does not part resulting in a difficult fishing job. Note: If tubing patch could not be successfully retrieved in step 2, the chemical cutter will be unable to fit through the patch/SSSV. Should this be the case, contact the ODE to discuss further options. 5. Freeze protect tubing and annulus to 2,200ft with diesel. Bleed pressures on tubing/annulus. Zero psi on all annuli required. 6. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Rig Work: Prior to rig move, test 9-5/8" packoff to 5,000psi, and function lock down screws (FMC wellhead representative to do this). If any problems with the 9-5/8" packoff are observed, contact the well- head manufacturer to initiate repairs. . MIRU. Circulate the well to clean seawater. Pull BPV and ensure well stands full of seawater be- fore NU BOP' s. If well is taking fluid, bullhead LCM to formation. Set/test TWCV. ND tree, NU BOP's and test same. Pull TWCV. Retrieve 7" x 5-1/2" tubing from chemical cut at 9380'. If tubing parts, RIH with fishing assembly and retrieve remaining tubing. RIH with fishing assembly and retrieve seals by pulling free from PBR at 9474'. Note: If a tubing cut could not be achieved pre-rig, rig will attempt to pull tubing free from PBR at surface. 4. RIH with fishing assembly and retrieve K-anchor. RIH with milling assembly and mill/retrieve the remainder of the existing 5-1/2"x 4-1/2" completion tailpipe. M/U cement retainer on DP and RIH. Set cement retainer at +10285' (placed for window kick off at 10265'). Bullhead 35bbls of cement to perforations to fill open hole below retainer. Release from retainer and POOH. 6. RIH with bottom trip whipstock and set on cement retainer. Shear off and mill window in 7" at 10265'. POOH. 7. RIH with 6" drilling assembly with 4 phase resistivity MWD and tag TD of new hole. Displace well to drilling fluid, and drill section to TD of 11820' as per directional plan. 8. M/U and run 1705' of 4-1/2" solid L80 IBT liner to 11820' and hang off in 7" liner. Cement liner in place and set liner hanger/packer. 9. RU DPC perforating guns and RIH. Perforate ~25% of liner as per asset specifications and POOH. 10. R/U and run 4-1/2" L80 completion with 4-1/2" SSSV, 7"x4-1/2" production packer set at +10050', and standard WOA tailpipe stabbed into 4-1/2" liner top. Note that a 7" x 4-1/2" cross- over will be set on top of the completion at surface to enable the existing wellhead/tree/tubing hanger to be re-used. Circulate freeze protection to +2,200'MD. Land completion and set packer. Set and test TWCV, ND BOP, NU tree. Pull TWCV and set/test BPV. RDMO. TREE: 6" McEVOY WELLHEAD: McEVOY ACTUATOR: OTIS 13-3/8', 72#/ft, I ,3,~'3,',3,l ~ L-80, BTRS ~-_ .. KB: ELEV = 55.11' BF. ELEV = 21.76' 7' x 25'-11" TUbing patch ( min, ID 3,958" ) SSSV LANDING NIPPLE FOC-- --.(OTIS )(5.962" ID) w/o INSERT (3.813" ID) w/INSERT I so4'l IKOP: 2900' MAX ANGLE: 46° @ 6400' 7", 26#/ff, L-80, IJ4S TUBING TUBING ID: 6.276' CAPACITY: .0382 BBL/FT 5 1/2' 17#/ff, L-80, TUBING TUBING ID: 4.892' CAPACITY: .0232 BBL/FT TOP OF 7" LINER 9-5/8", 47#/ft, ~--~, ~ I L-80, BTRS pERFORATION SUMMARY REF LOG: SWS- BHCS (RUN #2)- 7-29-79 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8" 6 10,267 - 10,316' OPEN/7-31-88 3 1/8" 8 10,442- 10,454' OPEN/6-15-85 " 8 10,466 - 10,490' ' " " 8 10,502- 10,514' " " 2 7/8" 8 10,520 - 10,537' " " " 8 10,548 - 10,558' " ' 2 7/8" 4 10,574 - 10,590' OPEN/12-8-79 " 4 10,600 - 10,658' ' " 3 3/8" 1 10,658 - 10,680' OPEN/I-8-89 " 1 10,696 - 10,715' ' " 7", 29#/ft, L-80, BTRS DATE PBTD I 11,150'1 I 11,200' I REV. BY A. TEEL COMMENTS 7" x 5 1/2" X-OVER 5 1/2"SLIDING SLEEVE BAKER "L" (4~313" ID) 19357' [ 9411' 19474' 9594'1 BOT SBR SEAL ASSY. 9 5/8" BOT PACKER (3H) (3.95S"I'D) 4 1/2", 12.6-ff/ftl L-80 TAILPIPE 4 1/2" "X"i NIPPLE (OTIS) (3;8i~3" ID) 4 1/2" TBG TAIL I 9640' (BOT MULEsHOE ) (ELMD) ~ MARKER-joINT: 7" OTIS ND" PACKER FISH: 3/27/93,.CTU BHA 4 1/2" "X'~ NIPPLE (OTIS) (3;e1-3~'iID) "XN" 4 1/2' NIPPLE (OTIS) (3;7'25" ID) 4 1~2~' WLEG (BOT- SOS) DOWN HOLE.CHOKE W/ 3-7/32" HOLES IN "XN' NIPPLE, 11/28/90 (3) 2 SPRINGS FROM~ BOW SPRING CENT. 3/4' x 12" x 1/8" T. LOST 6-26-90 (2) 1.5' OF 4 1/2" TBG. CUT OFF 10-6-83. (1) GEARHART DECENT. FIN, 3" x 26"L. LOST ON 6-5-82. I I I II1[ PRUDHOE BAY UNIT WELL: R-03 (41-31-12-13) . APl NO:. 50-029-20364 SEC 32:TN 12N: RGE 13E BP Expt,oration (Alaska) 1 - 13-92 RWO 03-29-93 RRW REVISED, W/FISH AND D.H. CHOKE 03-25-97 KSB Tubing Patch I 10,577'1 I 10,572' I 1 lO,S76'1 TREE: 8 McEvoy HST i'Pre-ri~ StatiJ.~ CB. IELEV = 19,59' SSSV LANDING NIPPLE @ 2004'- SSSV AND INSERT REMOVED FOC L-80, BTRS @ 2672' FREEZE PROTECTION AT +/- 2200' MD 7~, 26#/ft, L-80, IJ4S TUBING iD: 6,276" CAPACITY: 0,0382 BBL/FT 85PPG SEAWATER CHEMICAL CUT TUBING @ +/- 9380' TUBING ID: 4892" CAPACITY: 0.0232 BBL/FT 4 1/2% 12.6#/ft, L-80 TAILPIPE OIL/GAS FLUIDS @ 7,34PPG 7" LINER 'FOP @ 9559' L-80, BTRS @ 10083' 7" X 5-1/2~ CROSSOVER @ 9357' SLIDING SLEEVE @ 9411' (BAKER, L TYPE 4313" ID) BAKER SBR ASSY. 9474' 9 5/8" EOT 3H PACKER, 3.958" ID @ 9498~ -- 4 1/2" X NIPPLE, 3,813" ID @ 9594' -- 4-1/2" TUBING TAIL @ 9640' (EOT MULESHOE) (El_MD @ 9617') MARKER JOINT 10498' 7" OTIS "WD" PACKER @ 4 1/2" X NIPPLE, 3813"ID (OTIS) 4 1/2" XN NIPPLE, @ 10576' 3.725" ID (OTIS) 4 1/2" WLEG (EOT SOS) FISH: 3/27/98, CTU BHA DOWN HOI E CHOKE W/ 3-7/32" HOLES IN "XN" NIPPLE, t 1/28/90 TD @ 11200' 7", 29#. L-80 BTRS DATE REV, BY COMMENTS Pre-rig Status PRUDHOE BAY UN[[ WELL: R-03i APl NQ.L~0-029-20364-00 _ BP Exploration (Alaska) NOTE: THIS WELL WILL CONTAIN AN X NIPPLE AT 2000' NOT AN SSSV IN COMPLIANCE WITH RECENT BP SSSV MANAGEMENT IMPLEMENTATION PLAN FCC BF ELEV = 21.76' CB, ELEV = 1959' x 4-1/2" CROSSOVER BELOW TUBING HANGER DIESEL FREEZE PROTECTION AT +/- 2200' MD L-80, BTRS @ 2666' TUBING ID: 3958" CAPACITY: 0.0152 BBL/FT 85PPG SEAWATER 7" LINER TOP @ 9 5/8", 47#/ft, L-80, BTRS @ 1007; 4 1/2", t2,6#/ft, L-80 '¥AILPIPE WOA CONFIGURATION X/X/XN WHIPSTOCK SET ON CEMENT RETAINER @ 10285' (FOR KICK OFF @ 10265') CEMENT RETAINER @ -10,285' (35bbls of cement pumped to open hole perforations) 7" X 4~1/2" PRODUCTION PACKER @ +/- 10050' 4 1/2" WLEG STABBED INTO TOP HANGER/PACKER @ 10115' 4 1/2", 12,6#/ft, L-80 iBT LINER DATE 8-13-98 7" OTIS "WD" PACKER 4 1/2" X NIPPLE, @ 3,813" ID (OTIS) 4 1/2" XN NIPPLE, @ 10570' 3,725" tD 4 1/2" WLEG @ (BOT SOS) PBTD @ 11144' TO @ 11194' REV BY COMMENTS CJB Proposed Status FISH: 3/27/93, CTU BHA DOWN HOLE CHOKE W/ 3-7/32" ROLES IN "XN" NIPPLE, 11/28/90 7", 29#, L-80 BTRS PRUDH,Q.E BAY UNIT WELL: R-03ai APl NO: .5_Q.-029-20364-01 BP Exploration (Alaska) Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, ~ 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL ¥~LL PLAN for Shared Services Drilling Well ......... : R-O3Ai (PO5) Field ........ : Prudhoe Bay Computation..: Minimu~ Curvature Units ........ : FEET Surface Lat..: 70.34544365 N Surface Long.: 148.90638430 W Legal Description Surface ...... : 660 FSL 4~03_FEL S32 T12N R13E UM Tie-in survey: 4754 FSL 184 FEn S31 T12N R13E UM TGT BS5 ...... : 5121F~L 4917 FEn S32 T12N R13EUM Int TGT ...... : 7 F$5 4572 FEn S29 T12N R13E UM BHL .......... : 170 fS5 4176 FEL S29 T12N R13EUM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 634728.00 5977131.00 633379.50 5981221.35 633858.89 5981576.64 634260.00 5981750.19 634652.50 5981920.00 Prepared ..... : 20 May 1998 Vert sect az.: 67.63 KB elevation.: 48.99 ft Magnetic Dcln: +28.033 Scale Factor.: 0.99992062 Convergence..: +1.02991322 PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH VERTICAL-DEPTHS TVD SUB-SEA SECTION DEPART COORDINATES-FROM ALASKA Zbne' 4 WELLHEAD X Y TOOL DL/ FACE 100 TIE-IN SURVEY 10193.88 36.00 351.00 10200.00 36.05 351.26 SAGR 10256.63 36.52 353.60 TOP OF WHIPSTOCK 10265.00 36.59 353.94 BASE OF WHIPSTOCK 10277.00 37.97 356.15 CURVE 25/1 O0 SHUBLIK 10294.00 37.97 356.15 10300.00 38.29 358.52 10312.30 39.08 3.27 10350.00 42.62 16.66 10400.00 49.32 31.39 TSAD 10442.26 56.18 41.50 (Anadrill (c)98 R03AP05 3.2C 11:05 AM P) 8621.39 8572.40 ' 8626.34 8577.35 8671.99 8623.00 '8678.72 8629.73 8688.27 8639.28 8701.67 8652.68 8706.39 8657.40 8715.99 8667.00 8744.56 8695.57 8779.39 8730.40 8804.99 8756.00 386.59 387.43 395.99 397.38 399.55 402.87 404.12 407.16 420.37 446.42 475.18 4114.26 N 4117.81 N 4151.02 N 4155.98 N 4163.22 N 4173.66 N 4177.36 H 4185.04 N 4209.19 N 4241.72 N 4268.63 N 1274.86 W 633379.50 5981221.35 72R <TIE 1275.42 W 633378.88 5981224.90 72R 2.58 1279.83 W 633373.87 5981258.02 70R 2.58 1280.37 W 633373.24 5981262.97 45R 2.58 1281.00 W 633372.48 5981270.19 HS t6.00 1281.70 W 633371.59 5981280.61 1281.87 W 633371.36 5981284.31 1281.75 W 633371.34 5981291.99 1277.40 W 633375.25 5981316.21 1262.62 W 633389.45 5981349.01 79R 0.00 77R 25.00 73R 25.00 63R 25.00 539 25.00 1242.58 W 633408.99 5981376.26 47R 25.00 END 25.00/100 CURVE 10450.00 57.53 10500.00 66.64 10550.00 76.27 10600.00 86.16 10617.42 89.63 PROPOSED WELL PROFILE DIRECTION VERTICAL-D~PTHS AZIMUTH 'TVD SUB-SEA 43.16 8809.22 8760.23 52.87 8832.65 8783.66 61.29 8848.56 8799.57 69.03 8856.20 8807.21 71.67 8856.84 8807.85 CURVE 10/100 10909.80 89.63 CURVE 8.00/100 10950.12 89.63 DEEPEST PT IN TGT 10954.74 90.00 TGT START PT 10954.74 90.00 11000.00 93.62 SECTION DEPART 481.04 522.60 569.11 618.38 635.77 END 8.00/100 CURVE 11007.59 94.23 CURVE 8/100 11388.28 94.23 INT~DIATE TGT 11388.28 94.23 11400.00 93.29 HIGHEST PT IN'TGT 11441.13 90.00 71.67 8858.73 8809.74 927.42 67.63 8858.99 8810.00 967.70 67.63 8859.00 8810.01 972.32 67.63 8859.00 8810.01 972.32 67.63 8857.58 8808.59 1017.55 11500.00 85.29 END 8/100 CURVE 11557.64 80.68 4-1/2" LINER PT 11820.00 80.68 TD 11820.00 80.68 20 ~[ay 1998 Page 2 COORDINATES-FRC~ ALASKA Zone 4 WELLHEAD X Y .-- TOOL DL/ FACE i00 4273.42 N 1238.22 W 633413.27 5981381.13 4302.77 N 1205.36 W 633445.59 5981411.07 4328.39 N 1165.61 W 633484.88 5981437.40 4349.07 N I120.84 W 633529.27 5981458.87 4354.92 N 1104.44 W 633545.55 5981465.02 46R 25.00 41R 25.00 38R 25.00 37R 25.00 HS 25.00 4446.89 N 826.91 W 633821.36 5981561.95 90L 0.00 4460.90 N 789.12 W 633858.89 5981576.65 HS 10.00 4462.66 N 784.85 W 633863.13 5981578.48 ILS 8.00 4462.66 N 784.85 W 633863.13 5981578.48 HS 8.00 4479.87 N 743.02 W 633904.64 5981596.44 HS 8.00 67.63 8857.06 8808.07 1025.12 4482.75 67.63 8828.99 8780.00, 1404.77 4627.22 67.63 8828.99 8780.00 1404.77 4627.22 67.63 8828.22 8779.23 1416.47 4631.67 67.63 8827.04 8778.05 1457.57 4647.31 67.63 8829.46 8780.47 1516.38 4669.69 , 67.63 8836.50 8787.51 1573.57 4691.45 67.63 8878.99 8830.00 1832.47 4789.96 67.63 8878.99 8830.00 1832.47 4789.96 9035.99 8987.00 736.02 W 633911.59 5981599.44 HS 8.00 384.92 W 634260.00 5981750.18 LS 0.00 384.92 W 634260.00 5981750.18 LS 0.00 374.11 W 634270.74 5981754.83 LS 8.00 336.10 W 634308.46 5981771.15 LS 8.00 281.71 W 634362.42 5981794.50 LS 8.00 228.82 W 634414.91 5941817.21 HS 8.00 10.60 E 634652.50 5981920.00 0.00 10.60 E 634652.50 5981920.00 0.00 (~nadrill [c)98 RO3AP05 3.2C 11:05 AM P) m i i ~nadr I 11 Sck~er R-O3A1 (PO5) PLAN VIEW CLOSURE ..... : 4790 F~t ot Azimuth 0.13 Sh n d S nvlc s Drl 1 lln= ]ECLINATION.: +28.033 (E) SCALE ....... : 1 Inch = 300 feet ]RAWN ....... : 20 Moy 1998 i i i ~rk~r Identification MO N/S E/~ ~) TIE-IN ~RVEY 10194 4114 N 1~5 ]) TOP OF ~IPST~K 1~65 4156 N 1~0 W ;) BASE OF WHIPSTOCK 1~77 4133 N 1~1 W ]) L'UR~ ~/1~ l~g4 4174 N 1~2 W ! D E~ 25.~/100 C~ ~17 4~ N 1104 W :) CURVE lO/lO0 1~10 444? N 827W ~) C~¥E 8.00/100 10950 44§I N 78§ W 4) ~EPEST PT IN T~T I~55 44§~ N 785 W I~ T6f START ~T 10955 446a N?B5 W ' -~-- ' ~ E~ 8.00/100 CU~E 11008 448~ N7a6 W ·~ ~ ~~~..~" 0 CURVE B/I~ 11~84e2?N ~5 W .~ ZNTER,EOI^~E T~T 11~846~? N~85 W ~.. . 4) HI6HEST PT IN TGT I144! 4§47 N 99B W ~~.~-'~ ' :__..~ .... - '))) 4-I/2' LINER PT 11820 4790 N 11E ' ................ ............. - .... , , ~ ......~ .... .................. 2400 22~ 2100 lg50 1800 1~0 1500 1350 1200 1050 gOO 750 BO0 450 300 150 0 150 300 _ (AnaOrlll (c)g8 RO3APO5 3.2C 11,22 AM P) ' , ........ Shor~d S~rv i c~s Dr i 1 1 i R-OB^i (~5) YERTIC^L SECTION ¥IE~ Section at: 8?.§5 TUB Scale.: 1 lnch= 200 feet Oep Scale.: 1 inch = 200 feet Drawn ..... : 20 May 1§§8 Marker IdentlFlcatl MD MB SECTN ~, , .... M~I T%~I X~I I~,~,F %~ ~Ul I Iq&& A) TIE-IN ~RVEY 10194 B~1 B) T~ ~ ~IPSTOCK 10265 BB?g C) BA~ ~ ~HIPSTOCK 10277 8~8 4 ~ ....... D) C~VE 25/100 1029~ E) E~ ~, ~/IOD CURVE 1081~ F) C~ 1D/1DD 10~10 ) ................. 'G) C~VE 8. 00/I~ 10950 8~ c ~) D~T PT IN TGT 109~ 8~9 I> TGT START PT 10955 8~9 5) E~ &O0/l~ CURVE 11008 ) ............. K) C~VE 8/100 11388 L> I~E~IATE TG% 119~ 8~9 ,. M> HIGHEST PT IN TGT 11441 8~7 ~ .......... N) E~ 8/1~ ~R~ 11558 8~8 O) 4-1/2' LINER PT 11820 8~9 P) TD . 11820' 8~9 .lt ]............. c - F ; ~ -~' , ............ ~ ........................ Z...~ ,= ~ . .................................. ...... ~ ' ' i ......... , ,,, ............. ........... ~ ' Z 0 .... I ~ 987 997 400 409 696 927 968 972 872 1025 1405 1405 1458 1574 189~ · 1892 200 900 400 500 600 700 800 INCLN 36. DO 36. 59 37.97 27. 97 89. 69 89. 69 89. 69 90. DO 90. O0 94.29 94. 29 94.29 90. DO 80. 68 80. 68 80. §8 go0 1 DO0 11 O0 Section De mrture 1200 1300 1400 1500 1800 1700 1800 l§O0 2000 (Anadrlll ¢c)gB RD3AP05 3.2C 11,18 AH P) Alaska hared ervlces rilling WELL NAME ¢-.,-- O~ ~ c DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT SUNDRY NOTICE ~Permit ~c~.mentation Prepared: I~/Sundry Documentation Prepared: ODE: ~~/~---- Date: ~[tq'[c]g~ ODE: Date:~ /~ Permit ffpplication Reviewed: D Sundry Application Reviewed: SDE/ES: '~-~-~-~-~' .... ~Date:~/l~j qr~[ SDE/ES: Date: me~LL,~, ~ pp!icatigp S]4bAni3t_ed: ~ D Sundry Application Submitted: TA: 10t/me. ~ Date: Iql~ff[ TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date: Reason for Sundry (Check all that apply) Abandon Change Approved Program Alter Casing Operation Shutdown Suspend Re-enter Suspended Well Repair Well Time Extension Perforate lPlugging ~ Pull Tubing Stin~a~ _ I~Variance -,.--CEIVED II Other(Explain): AUG 1 Alaska Oil & ~ag Cons. Commission APPROVAL TO PROCEED I Well Name: IR-03ai ] [Type of Well: HST Sidetrack Summary Revision #1 Ilnject°r I Surface Location: 4619' FNL, 4203' FEL, S32, T12N, R13E, UM Target Location: 5121' FSL, 4977' FEL, S32, T12N, R13E, UM Bottom Hole Location: 170' FSL, 4176' FEL, S29, T12N, R13E, UM I AFE Number: 14P0984 [Estimated Start Date: [ 9/1/98 Rig: ]Nabors 2ES Operating days to complete: [ 15 IUD: I~,820' [ I TVD: 18,830'ss [ I mBE~ev. [Well Design: I HST Sidetrack [48.99' Objective: I This well is to be drilled as a horizontal sidetrack. The new sidetrack will provide tubing I mechanical integrity and inJec, tion conformance in upper Zone 4. The well is required to [~u--~ulate through the upper 50 of Zone 4 and maintain access to the Sag. Formation Markers Formation Tops MD TVD (ss) TSag 10256' 8623' K/O 10265' 8630' TSHU 10312' 8667' TSAD 10442' 8756' TD 11820' 8830' TZ3 NR 8915' TZ2 NR 8965' HOT NR 8990' TZ1 NR 9220' Directional [KOP: 110,265' MD I Maximum Hole Angle: Rig Move Close Approaches: Drilling Close Approaches: 94.2° through targets R-33, R-31 will be 35' either side of R- 03ai and will be shut in during the rig move. None Casing/Tubing ?rogram Hole Size Tubular Wt/Ft Grade - Conn Lehgth Top Btm O.D. MD/TVDss MD/TVDss 6" 4- I/2" 12.6# L80 IBT 1705' 10115'/8503' 11820'/8830' Production Tubing NA I 4-1/2" 12.6# L80 IBT 10089' 26'/-23' 10115'/8503' Mud Program Milling Interval: 6% KC1 Milling fluid Density, ppg I Funnel Vis, secI LSRVI pH APl FL, cc 8.7-8.8+ I 50 - 65 >35,000 8.5 - 9.0 NC Hazards/Concerns I Maintain viscosity at 50 - 65 to insure adequate removal of metal cuttings. Ensure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. Production (6" hole) Section: 6% Quickdriln (viscosified SW) .Density, ppg FunnelVis, sec[ LSRV pH ] APIFL, cc 8.7 - 8.8+ 50 - 65 > 35,000 8.5 - 9.0 NC Hazards/Concerns Potential high torque could require lubricant use. If so, employ Lubetex Be alert for lost circulation, differential sticking due to overbalanced MW. Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8+ ppg. Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments 4-1/2" N/A 201 / 15.7 / 1.19 Class G: 40% excess; Pump time = 4 hr.; TOC 200' above TOL. Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Open Hole Logs: Logging Program 6" Hole Cased Hole Logs: MWD Dir/GR/4 phase resistivity No logs unless MWD resistivity unavailable or unusable CBL if required to prove isolation Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Bottom hole pressure is expected to be 3200psi @ 8756' TVDSS Maximum expected surface pressure at 8756' TVDSS is 2324psi (assuming gas column of 0. lpsi/ft) Hazards The main production target for this well is Zone 4. Only one minor fault will be crossed in the polygon and recent wells drilled in this area have not experienced severe losses, hence although preparations should be made to pump LCM, lost circulation is not expected to be a major problem. The Boundary Fault is located to the north of the polygon, and hence this edge of the polygon is a hardline to avoid crossing the fault. No potential close approaches have been identified while drilling this well. Sag River The Sag River in this well has a slightly low formation pressure at 6.8ppg EMW and hence is not ex- pected to cause a lost circulation problem. The pad data sheet indicates that only one well (R-36i) has experienced maj or lost circulation in this production interval, most other drilling wells experiencing only minor losses. This well does cross one minor fault while in the target polygon, and should any losses oc- cur due to the fault, productive zone LCM will be employed to combat them. Recent wells have experi- enced very little or no lost circulation at all while drilling the production interval. On the R-36i well, returns were not obtained while cementing the casing in place. However, this has not been the case on any of the recent R-pad wells. Risk of differential sticking is low based on offset wells, but should it occur, will be mitigated by the use of the Quikdriln drilling fluid which is solids free and does not form a filter cake. Ivishak Differential sticking has occurred frequently on older wells in the Ivishak at +/-9183' TVD. Once the sticking occurs it is very strong and has created difficulty in freeing up the drillstring. On R-35A, the sticking was successfully alleviated by pumping a 20bbl pill of Liquid Casing, OM Seal, and Barafibre and reducing pump rate to 5bpm (to reduce ECD). Note however that these wells were drilled using LSND mud; since this well will employ solids free Quikdriln, this should mitigate the risk of sticking. High torque has been reported on several older wells in the production hole, hence some open hole lu- brication may be required. The pad data sheet incorporates wells from R, F and J pad as the bottom hole location of these wells are all in the same area. Wells from all three pads have experienced problems with bridges, tight hole, differential sticking, and packing off while in the production interval. This has caused numerous incidents of stuck logs, casing, and drillstring. This is a high potential stuck pipe area - be alert while drilling this interval and employ frequent reaming if any sign of unstable hole is seen. Note however, that recent R-pad wells have not experienced any trouble from sticking and it is expected that this well will be drilled without a signficant sticking problem. Disposal All cuttings should be hauled to the ball mill at CC-2A for disposal. Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. Operations Summary Pre-Rig Work: NOTE: If any problems with the 9-5/8" packoff are observed during pre-rig work, contact the well- head manufacturer to initiate repairs and inform the Operations Drilling Engineer. 1. Test 9-5/8" and tubing hanger packoff to 5,000psi if not recently tested (< 1 month). If tubing and an- nulus have not recently (<1 month) been tested, pressure test to 3,000psi. 2. R/U wireline and RIH to 9,440' with 3-3/8" tubing punch. Perforate 5-1/2" tubing and circulate the well through the perforations until clean returns are obtained. 3. RIH with retrieving tool and attempt to retrieve AVA Model DWP tubing patch from tubing at +504' (elm) with wireline retrieving tool. RIH and retrieve SSSV and 3.813" insert. . RIH with chemical cutter assembly and cut tubing at middle of first full joint above the Baker sliding sleeve at +9380'. Circulate seawater through the cut until clean returns are obtained. Ensure that well will stand full of seawater - bullhead LCM to perforations to stop any losses. Note: Since the tubing is holed close to surface the tubing will be chemical cut to ensure it does not part resulting in a difficult fishing job. Note: If tubing patch could not be successfully retrieved in step 2, the chemical cutter will be unable to fit through the patch/SSSV. Should this be the case, contact the ODE to discuss further options. 5. Freeze protect tubing and annulus to 2,200ft with diesel. Bleed pressures on tubing/annulus. Zero psi on all annuli required. 6. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Rig Work: . Prior to rig move, test 9-5/8" packoff to 5,000psi, and function lock down screws (FMC wellhead representative to do this). If any problems with the %5/8" packoff are observed, contact the well- head manufacturer to initiate repairs. . MIRU. Circulate the well to clean seawater. Pull BPV and ensure well stands full of seawater be- fore NU BOWs. If well is taking fluid, bullhead LCM to formation. Set/test TWCV. ND tree, NU B OP's and test same. Pull TWCV. . Retrieve 7" x 5-1/2" tubing from chemical cut at 9380'. If tubing parts, Rltt with fishing assembly and retrieve remaining tubing. RIH with fishing assembly and retrieve seals by pulling free from PBR at 9474'. Note: If a tubing cut could not be achieved pre-rig, rig will attempt to pull tubing free from PBR at surface. 4. RIH with fishing assembly and retrieve K-anchor. RIH with milling assembly and mill/retrieve the remainder of the existing 5-1/2"x 4-1/2" completion tailpipe. , M/U cement retainer on DP and RIt-I. Set cement retainer at +10285' (placed for window kick off at 10265'). Bullhead 35bbls of cement to perforations to fill open hole below retainer. Release from retainer and POOH. 6. RIH with bottom trip whipstock and set on cement retainer. Shear off and mill window in 7" at 10265'. POOH. 7. RIH with 6" drilling assembly with 4 phase resistivity MWD and tag TD of new hole. Displace well to drilling fluid, and drill section to TD of 11820' as per directional plan. 8. M/U and run 1705' of 4-1/2" solid L80 IBT liner to 11820' and hang off in 7" liner. Cement liner in place and set liner hanger/packer. 9. RU DPC perforating guns and RIH. Perforate -25% of liner as per asset specifications and POOH. 10. R/U and run 4-1/2" L80 completion with 4-1/2" SSSV, 7"x4-1/2" production packer set at _+10050', and standard WOA tailpipe stabbed into 4-1/2" liner top. Note that a 7" x 4-1/2" cross- over will be set on top of the completion at surface to enable the existing wellhead/tree/tubing hanger to be re-used. Circulate freeze protection to +2,200'MD. Land completion and set packer. Set and test TWCV, ND BOP, NU tree. Pull TWCV and set/test BPV. RDMO. TREE: 6" McEVOY WELLHEAD: McEVOY ACTUATOR: OTIS 13-3/8", 72#/ft, I ,'3c::~',3~1 L-80, BTRS IKOP: 2900' MAX ANGLE: 46° @ 6400' 7", 26~/f1:, L-80, IJ4S TUBING TUBING ID: 6.276" CAPACITY: .0382 BBI_/FT . 5 1/2" 17#/ft, L-80, TUBING TUBING ID: 4.892" CAPACITY: .0232 BBI../FT TOP OF 7" LINER BF. ELEV = 21.76' 7' x 25'-11" Tubing patch LANDING NIPPLE FO )(5.962' ID) w/o INSERT -- (3.813" ID) w/INSERT 9-5/8·, 47#/ft, L-80, BTRS ~ ~ PERFORATION SUMMARy REF LOG: SWS- BHCS (RUN #2)- 7-29-79 '~ F INTERVAL OPEN/SQZ'D 10,267 - 10,316' OPEN/7-31-88 OPEN/6-15-85 · · · · · · · · OPEN/12-8-79 · · OPEN/I-8-89 · · 10,442 - 10,454' 10,466 - 10,490' 10,502 - 10,514' 10,520 - 10,537' 10,548 - 10,558' 10,574 - 10,590' 10,600 - 10,658' 10,658 - 10,680' 10,696- 10,715' 7", 29#/ft, L-80, BTRS DATE PBTD 111,15o'1 I 11,200'1 REV. BY A. TEEL 7· x 5 1/2" X-OVER 5 1/2"SLIDING SLEEVE BAKER 'L" (4.313' ID) 9357'1 9411' I BOT SBR'SEA[. ASSY. 9 5/8' BOT PACKER (3H) (3.958'1D) 4 1/2', 12.6~/fti L-80 TAILPIPE 4 1/2' 'X"' NIPPLE (OTIS) (3.813' ID) 4 1/2" TBG TAIL (BOT MULESHOE (ELMD) I I 9474' 9594'I 9640' ! 9617' I MARKER JClNT~ J 10,498'J 7" OTIS "WD' PACKER ~ ~ ,~~ FISH: 3/27/93; CTU BHA 4 1/2' 'X~ NIPPLE (OTIS) (318,1:3' ID) 4 1/2· "XN" NIPPLE (OTIS) (3]725' ID) 4 1'72~' WLEG 0,577~ 1 1 (BOT- SOS) ' DOWN HoLE CHOKE W/ 3-7/32'~ HOLES IN I "XN' NIPPr E, 11/28/90 COMMENTS 1 10,5721J (3) 2 SPRINGS FROM: BOW SPRING CENT. 3/4· x 12' x 1/8' T. L. OST 6-26-90 (2) 1.5' OF 4 1/2" TBG. CUT OFF 10-6-83. (1) GEARHART DECENT. FIN, 3" x 26"L. LOST ON 6-5-82. 1-13-92 RWO 03-29-93 RRW REVISED, W/FISH AND D.H. CHOKE 03-25-97 KSB Tubing Patch PRUDHOE BAY UNIT WELL: R-03 (41-31-12-13) APl NO: 50-029-20364 SEC 32 ;TN 12N; RGE 13E BP Exploration (Alaska) TREE: 6" McEvoy WELLHEAD: McEvoy R-03i HST (Pre-rig Status) ORigiNAl_ x~. ELEV: S~.~ Biz. ELEV = 21.76' CB. ELEV = 19.59' SSSV LANDING NIPPLE @ 2004' - SSSV AND INSERT REMOVED FOC 8PPG DIESEL FREEZE PROTECTION AT +/- 2200' MD 13 3/8", 72#/fl, L-80, BTRS @ 2672' 7", 26#/ft, L-80, IJ4$ TUBING ID: 6.276" CAPACITY: 0.0382 BBL/FT 8.SPPG SEAWATER CHEMICAL CUT TUBING @ +/- 9380' 5-1/2", 17#/ft, L-80 TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT 4 1/2", 12.6#/ft, L-80 TAILPIPE OIL/GAS FLUIDS @ 7.34PPG 7" LINER TOP @ 9559' 9 5/8", 47#/ft, L-80, BTRS @ 10083' 7" X 5-1/2" CROSSOVER @ 9357' SLIDING SLEEVE @ 9411' (BAKER, L TYPE 4.313" ID) BAKER SBR ASSY. 9474' 9 5/8" EOT 3H PACKER, 3.958" ID @ 9498' 4 1/2" X NIPPLE, 3.813" ID @ 9594' 4-1/2" TUBING TAIL @ 9640' (BOT MULESHOE) (ELMD @ 9617') MARKER JOINT 10498' 7" OTiS "WD" PACKER @ 1 4 1/2" X NIPPLE, @ 10572' 3.813" ID (OTIS) 4 1/2" XN NIPPLE, @ 10576' 3.725" ID (OTIS) 4 1/2" WLEG @ 1 (BOT SOS) FISH: 3/27/93, CTU BHA DOWN HOLE CHOKE W/ 3-7/32' HOLES IN "XN" NIPPLE, 11/28/90 PBTD @ 11150' TO @ 11200' 7", 29~, L-BO BTRS DATE REV. BY COMMENTS CJB Pre-riq Status P_BUDHOE BAY. U~ WELL: R-03i APU::¢~: 50-029-20364:00 BP Exploration (Alaska) TREE: 6" McEvoy WELLHEAD: McEvoy NOTE: THIS WEt_[_ WILL CONTAIN AN X NIPPLE AT 2000' NOT AN SSSV tN COMPLIANCE WITH RECENT BP SSSV MANAGEMENT IMPLEMENTATION PLAN FCC R-03ai HST (Proposed Status) NABORS2ES KB. ELEV = 48.99' BF. ELEV = 21.76' CB. ELEV = 19.59' x 4-I/2" CROSSOVER BELOW TUBING HANGER IPPG DIESEL FREEZE PROTECTION AT +/- 2200' MD 13 3/8", 72#/fl, L-80, BTRS @ 2666' 8.5PPG SEAWATER 4-1/2", 12.6#/ft, L-80 TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT 7" LINER TOP @ 9 5/8", 47#/ft, L-80, BTRS @ 10077' 4 1/2", 12.6ff/ft, L-80 TAILPIPE WOA CONFIGURATION X/X/XN WHIPSTOCK SET ON CEMENT RETAINER @ 10285' (FOR KICK OFF @ 10265') CEMENT RETAINER @ -10,285' (35bbls of cement pumped to open hole perforations) 7" X 4-1/2" PRODUCTION PACKER @ +/- 10050' 4 1/2" WLEG STABBED INTO ~ LINER TOP X 4-1/2" LINER HANGER/PACKER @ 10115' 4 1/2% 12.6#/ft, L-80 IBT LINER 6"TD @ 11820' 7" OTiS "WD" PACKER @ 4 1/2" X NIPPLE, @ 3,813'1D (OTIS) 4 1/2" XN NIPPLE, @ 10570' 3.725" ID (OTIS) 4 1/2' WLEG @ (BOT SOS) PBTD @ 11144' TD @ 11194' FISH: 3/2W93, CTU BHA DOWN HOLE CHOKE W/ 3-7/32" HOLES IN "XN" NIPPLE, 11/28/90 7", 29#, L-80 BTRS DATE 8-13-98 REV. BY CJB COMMENTS Proposed Status ERUDHOE BA~ UNIT ~ELL: B-02ai APl_btO: 50~;~64-01 Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL ¥~LL PLAN for Shared Services Drilling Well ......... : R-O3Ai (PO5) Field ........ : Prudhoe Bay Computation..: Minim~ Curvature Units ........ : FEET Surface Lat..: 70.34544365 N Surface Long.: 148.90638430 W Legal Description Surface ...... : 660 FSL 4~03_FEL S32 T12N R13E UM Tie-in survey: 4754 FS5 184 FEn S31 T12N R13E ~ TGT ESL ...... : 5121F~L 49~7 FEn S32 T12N R13E UM Int TGT ...... : ? FSL 4572 FEn S29 T12N R13E UM BH5 .......... : 170 FSL 4176 FEn S29 T12N R13EUM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 634728.00 5977131.00 633379.50 5981221.35 633858.89 59815?6.64 634260.00 5981750.19 634652.50 5981920.00 Prepared ..... : 20 May 1998 Vert sect az.: 67.63 KB elevation.: 48.99 ft Magnetic Dcln: +28.033 (E) Scale Factor.: 0.99992062 Convergence..: +1.02991322 , PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH VERTICAL-DEPTHS TVD SUB-SEA SECTION DEPART COORDINATES-FROM WELLHEAD ALASKA Z~ne' 4 TOOL DL/ X Y FACE 100 TIE-IN SURVEY 10193.88 36.00 351.00 10200.00 36.05 351.26 SAGR 10256.63 36.52 353.60 ?OP OF WHIPSTOCK 10265.00 36.59 353.94 BASE OF WHIPSTOCK 10277.00 37.97 356.15 CURVE 25/100 $HUBLIK 10294.00 37.97 356.15 10300.00 38.29 358.52 10312.30 39.08 3.27 10350.00 42.62 16.66 10400.00 49.32 31.39 TSAD 10442.26 56.18 41.50 8621.39 8572.40 8626.34 8577.35 8671.99 8623.00 8678.72 8629.73 8688.27 8639.28 870t.67 8652.68 8706.39 8657.40 8715.99 8667.00 8744.56 8695.57 8779.39 8730.40 8804.99 8756.00 386.59 387.43 395.99 397.38 399.55 402.87 404.12 407.16 420.37 446.42 475.18 4114.26 N 1274.86 4117.81 N 1275.42 4151.02 N 1279.83 4155.98 N 1280.37 4163.22 N 1281.00 4173.66 N 1281.70 4177.36 N 1281.87 4185.04 N 1281.75 4209.19 N 1277.40 4241.72 N 1262.62 W 633379.50 5981221.35 72R <TIE W 633378.88 5981224.90 72R 2.58 W 633373.87 5981258.02 70R 2.58 W 633373.24 5981262.97 45R 2.58 W 633372.48 5981270.19 HS 16.00 633371.59 5981280.61 79R 0.00 633371.36 5981284.31 77R 25.00 633371.34 5981291.99 73R 25.00 633375.25 5981316.21 63R 25.00 633389.45 5981349.01 53R 25.00 4268.63 N 1242.58 W 633408.99 5981376.26 47R 25.00 (Anadrill (c)98 R03AP05 3.2C 11:05 AM P) PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIFFUTH 'TVD SUB-SEA SECTION DEPART 20 Na~ 1998 Page 2 COORDINATES-FRC~ ALASKA Zone 4 WELLHEAD × Y TCOL FACE DL/ END 25.00/100 CURVE 10450.00 5?.53 10500.00 66.64 10550.00 76.27 10600.00 86.16 106I?.42 89.63 CURVE iO/lO0 CURVE 8.00/100 DEEPEST PT IN TGT TGT START PT 10909.80 89.63 10950.12 89.63 10954.74 90.00 10954.74 90.00 11000.00 93.62 END 8.00/100 CURVE CURVE 8/100 INT~DIATE TGT HIGHEST PT IN'TGT 11007.59 94.23 11388.28 94.23 11388.28 94.23 11400.00 93.29 11441.13 90.00 mm 8/lOO CURVE 4-1/2" LINER PT TD 11500.00 85.29 11557.64 80'.68 11820.00 80.68 11820.00 80.68 (Anadrill (c)98 R03AP05 3.2C 11:05 ~ P) 43.16 8809.22 8760.23 481.04 4273.42 N 1238.22 W 52.87 8832.65 8783.66 522.60 4302.77 N 1205.36 W 61.29 8848.56 8799.57 569.11 4328.39 N 1165.61 W 69.03 8856.20 8807.21 618.38 4349.07 N I120.84 W 71.67 8856.84 8807.85 635.77 4354.92 N 1104.44 W 71.67 8858.73 8809.74 927.42 4446.89 N 826.91 67.63 8858.99 8810.00 967.70 4460.90 N 789.12 67.63 8859.00 8810.01 972.32 4462.66 N 784.85 67.63 8859.00 8810.01 972.32 4462.66 N 784.85 67.63 8857.58 8808.59 1017.55 4479.87 N 743.02 67.63 8857.06 8808.07 1025.12 4482.75 N 736.02 67.63 8828.99 8780.00 1404.?? 4627.22 N 384.92 67.63 8828.99 8780.00 1404.77 4627.22 ~ 384.92 67.63 8828.22 8779.23 1416.47 4631.67 N 374.11 67.63 8827.04 8778.05 1457.57 4647.31 N 336.10 67.63 8829.46 8780.47 1516.38 4669.69 N 281.71W 67.63 8836.50 8787.51 1573.57 4691.45 N 228.82 W 67.63 8878.99 8830.00 1832.47 4789.96 N 10.60 E 67.63 8878.99 8830.00 1832.47 4789.96 N 10.60 E 9035.99 8987.00 633413.27 598138t.13 633445.59 5981411.07 633484.88 5981437.40 633529.27 5981458.87 633545.55 5981465.02 46R 25.00 41R 25.00 38R 25.00 37R 25.00 HS 25.00 633821.36 5981561.95 90L 0.00 633858.89 5981576.65 HS 10.00 633863.13 5981578.48 MS 8.00 633863.13 5981578.48 H$ 8.00 633904.64 5981596.44 HS 8.00 633911.59 5981599.44 HS 8.00 634260.00 5981750.18 LS 0.00 634260.00 5981750.18 LS 0.00 634270.74 5981754.83 ns 8.00 634308.46 5981771.15 ns 8.00 634362.42 5981794.50 ns 8.00 634414.91 59~1817.21 MS 8.00 634652.50 5981920.00 0.00 634652.50 5981920.00 0.00 ~nodr I I 1 S~h l umb~r~r R-03^l (PO5) PLAN VIE~ Shormd Smrv 1 cms [3r 1 1 1 1 n~ :LOSURE. · 4790 ?eet et Azimuth 0.13 iCLINATION.: +28. 033 (E) :ALE ....... : i inch = 300 (AWN ....... : 20 May 1998 ,, I . I inker Ident~F!cntton MO N/S E/W , t. -,, i , TIE-IN SURVEY 10194 4114 N 1275 W TOP OF VHIPSTOCK 10~85 4156 N l~O W BASE OF ~HIPSTOCK 1~77 4183 N 1~1 , ~ ~/1~ 1~g4 4174 N 1~2 ' E~ ~5. ~/]OO C~ 1~17 43~ N 1104 ' CURVE lO/l~ l~lO 4447 N ~7 ~ C~VE 8.00/100 10950 4481 N 789 ) ~EPEST PT IN TGT I~55 4483 N 785 ~ ,, , ~ ....... > INTERMEDIATE TGT 11~8 4827 N 385W _~ ~ : ~ .... , ) HIGHESTPT INTGT 11441 4847N ~BW , _~ ~~ , , ~~ ) ENO B/lin CUR~ 11558 4891 N ~g W ) 4-l/2' LINER PT 11820 4790 N I1 E ........ , .... ......... ~ ........... , ~) :) ]) :) ;) ~) D 0 .) 0 2400 2250 2100 1950 1800 1850 1500 1350 1200 1050 §DO 750 BO0 450 LO0 )750 <- WEST: EAST -> 300 nodrlll (c)g8 RO3AP05 3.2C 11,22 AX P) Sh red Serv i cas [Ir i 1 1 1 4nadr 111 Sch_ l umbsr,,, , c~r R-O3A1 (PO5) VERTICAL SECTION VIEW Section ct: 87.6~ TVD Scale.: 1 inch: 200 feet Oep Scale.: 1 inch = 200 Ceat Drown ..... : 2D MoX 1@§8 ~c Identlf t I MIll'l~l- .~U~III,..Lr ,I. IWI. It.,.I, UII MI.I ~O , A) TIE-IN SURVEY 10194 B~21 B) TOP OF ~IPSTOCK 10265 8679 C) B}kSE O~ WHIPSTOCK 10277 BBSB 400 ' ' ' D) C~VE 25/100 10294 87~ 403 E) END 2S. O0/lOO CURVE 10617 68S7 638 F) CUR~ 1D/IOO 10910 8F59 g27 ................. G) CURVE 8.00/100 lOgSD 885~ H) DEEPEST PT IN TGT 10~ 8~9 972 I) TGT START PT 10955 8BSg J) END ~LOO/IDO CURVE llOOB 6857 102S I · ................ K) C~VE 8/1DO 11288 6829 1405 L) I~E~E'DIATE TGT 11286 B~9 14D5 H) HIGHEST PT IN TGT 11441 B~? 14SB } ................. N) END 8/1Qt] CURVE 115S8 BBB6 1574 D) 4-1/2' LINER PT 1162D 6879 1822 P) ll] . 11820' 8879 ,1822 , .... - .................................................................................... i ..... - - '~ ~Itlr-~' - ......... 21 . _tt.u£-- ' ......................... ~ 1t.~ 'ig/l~ I~ ............ 1. ........................ ]-_~_~ ........ ~ ............... .__. ,-,, ............ , , , ', Ii ~'F~- Tr~.~,~'''-'''--''''~ ' ] .__E. ..... F ~ _.J. .................................................................... i. i 0 ~ _ __i ...... .'_';'_ .i .................~ .... ' ' ' ..L~ .'~Lf ' .~.~ 200 300 400 500 6DO 700 800 gO0 lDO0 1100 1200 1200 1400 1500 1BO0 1700 1800 1900 Sect1 on Departure · II!CLN 38. 59 g7.97 37. 97 89. 63 89.6~ gO. OD §0. O0 94.~ 94.26 gO. O0 80. B8 80. ~ 80. 68 2000 Alaska hared · ervlces rilling WELL NAME DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET The attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT I~ Permit ~me.~ntation Prepared: "ODE: . Date: ~ Permit ~pplication Reviewed: [-~oSDE/ES: ~_:::~.-~..9._,-..., ~, Date:~s [ Pe~~pp!i~atigo S~b~ted: TA: [ ~~. ~ Date:~q~ SUNDRY NOTICE r-'! Sundry Documentation Prepared: ODE: Date: D Sundry Application Reviewed: SDE/ES: Date: D Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW PRE-RIG WORK Reason for Sundry (Check all that apply) Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date: Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate RECEIVED APPROVAL TO PROCEED Anchorage H14,1162 :j~3i98 HANDL INVOICE / CREDIT MEMO CKO731~BA INST: S/~ TERRIE HUBBL GRO~ I00.00 x4~ DISCOUNT _._._.__._...-.--. VENDOR A.__.._._..._.~ASF, AST i 4 OO_ NET i00. O0 · WELL PERMIT CHECKLIST COMPANY .~ ~ WELL NAME ~9 [~ t.,,L ~. -,,~'~]/3r~ PROGRAM: exp E] dev [] redrll,J~'serv,~wellbore seg Il ann. disposal para FIELD 8, POOL __&___~ 0_/__~ ~ ADMINISTRATION 1 2. 3. 4 5 7. 8. 9. 10. 11. iR DATE 12. INIT CLASS . Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. · Well located in a defined pool .................. . Well located proper distance from drilling unit boundary .... · Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING ,GEOLOGY 14. Conductor string provided ................... '15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg 17. CMl" vol adequate to tie-in long string to surf csg ........ '18. CM! will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. DOPEs, do they meet regulation ................ 26. DOPE press rating appropriate; test to ~ OOO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide rneasures~ ~_~../. 31. Data presented on potential overpressure z~.ones"% ..... 32. Seismic analysis of shallow gas~. .... '. ....... 33. Seabed condition su~e.y-~if'Sff-shore) ............. 34. Congress reports ....... ory only] GEOL AREA ~ ~ I~ UNIT#. ] [ ~.~Li~3__._ ON/OFF SHORE A~ DATE ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR [:)ATE (B) will not contaminate freshwater; or cause drilling waste... to surface; ..................... (C) will not impair mechanical integrity of the well used for' disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. (~N N ~N G~ N Y N_/~/~ Y N .................................................................................................................. Y N Y N ................................................................................................................... Y N Y N Y N GEOI,~GY: ENGI~EE~RING: UlC/Annular COMMISSION' ......... RNC - j D H.~.~.,..,,.~ - co ~"/~, ,, M:r:hcl~lisl H;v 05/29/98 rllfC \nl~,¢)ff icad\wi )i(Jinrl\dlr H I;l\, :t i(~f Id u,t Comments/Instructions: 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. * ALASKA COMPUTING CENTER . . ............................ ....... SCHLUMBERGER ....... . ............................ COMPANY NAME : B.P. EXPLORATION WELL NAME : R- 03A FIELD NAME : PRUDHOE BAY BOROUGH · NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20364-01 REFERENCE NO : 99034 RECEIVED ~ ~'R ! 8 1999 Alaska Oil & Gas Cons, Commiss~ Andmr~e * ALASKA COMPUTING CENTER * ............................ ....... SCHLUMBERGER ....... * ............................ COMPANY NAME : B.P. EXPLORATION WELL NAME : R-O3A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : AI~ASKA API NUMBER : 50-029-20364-01 REFERENCE NO : 99034 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-1999 14:00 PAGE: * * * * REEL HEADER * * * * SERVICE NAME : EDIT DATE · 99/02/ 1 ORIGIN : FLIC REEL NAME · 99034 CONTINUATION # : PREVIOUS REEL : CD~MENT : B.P. EXPLORATION, PRUDHOE BAY R-O3A, API #50-029-20364-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/02/ 1 ORIGIN : FLIC TAPE NAME : 99034 CONTINUATION # : 1 PREVIOUS TAPE COP~4ENT : B.P. EXPLORATION, PRUDHOE BAY R-O3A, API #50-029-20364-01 TAPE HEADER PRUDHOE BAY MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING R-O3A 500292036401 B. P. EXPLORATION SCHLUMBERGER WELL SERVICES 1 -FEB-99 BIT RUN1 99034 NUTTER RUSSELL BIT RUN 2 99034 NUTTER RUSSEL BIT RUN 3 32 12N 13E 50.53 50.53 21.76 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 10270.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-1999 14:00 3RD STRING PRODUCTION STRING REMARKS: Well drilled 2-OCT through 4-0CT-98 with IMPULSE. Data was collected in two bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: O. 5000 FILE SUIZk4ARY LDWG TOOL CODE BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10244 . 0 11834.0 BASELINE DEPTH .............. 88888 0 10391 5 10383 5 10380 0 10367 5 10359 0 10356.0 10347 5 10328 0 10312 5 10295 5 10278 0 10276 0 10251 0 100 0 $ MERGED DATA SOURCE LDWG TOOL CODE .......... EQUIVALENT UNSHIFTED DEPTH .......... 88893.5 10397.0 10389.0 10386.0 10374.0 10365 0 10361 0 10353 0 10333 5 10318 5 10301 0 10285 5 10283 5 10259 0 108 0 BIT RUNNO. MERGE TOP MERGE BASE LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-1999 14:00 PAGE: MWD 1 10244.0 10660.0 MWD 2 10392.0 11834.0 $ REMARKS: The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS. All otherMWD curves were carried with the GR. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CH_AN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 ROP ~4~D F/HR 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 GR ~D GAPI 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OPH~4 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OHI4M 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OPff4M4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RPM ~4~'~ 0HR~44000285 O0 000 O0 0 1 1 1 4 68 0000000000 RPD M~ OPff~4 4000285 O0 000 O0 0 1 1 ! 4 68 0000000000 RAS MWD OH~k4 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 RAM MWD OH~4M4000285 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-1999 14:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RAD MWD OH~4~ 4000285 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10244. 000 ROP.MWD -999. 250 FET.MWD O. 000 GR.MWD RPXX. MWD O. 140 RPX.MWD O. 140 RPS.MWD O. 170 RPM. MWD RPD.N~D 0.180 RAS.MWD 0.100 ~.MWD 0.380 RAD.MWD DEPT. 10500.000 ROP.MWD 75.010 FET.MWD 0.733 GR.MWD RPX~Y.MWD 11.280 RPX.MWD 12.650 RPS.MWD 13.300 RPM.MWD RPD.MWD 13.170 RAS.MWD 9.400 RAM. MWD 9.250 RAD.MWD DEPT. 11000.000 ROP.MWD 59.210 FET.MWD 1.069 GR.MWD RPX~.MWD 6.240 RPX.MWD 6.920 RPS.MWD 7.440 RPM. MWD RPD.MWD 7.950 RAS.MWD 7.260 RAM.MWD 7.450 ~.MWD DEPT. 11500. 000 ROP.MWD 61. 860 FET.MWD 1. 033 GR.MWD RPX~Y.MWD 7.960 RPX.MWD 8.260 RPS.MWD 8.560 RPM.MWD RPD.MWD 8.410 P~S.~D 9.020 RAM.MWD 9.220 RAD.MWD DEPT. 11834.000 ROP.MWD 56.610 FET.MWD -999.250 GR.MWD RPX~.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 RAS.MWD -999.250 RAM. MWD -999.250 RAD.MWD 83.110 0.200 300.000 24. 420 13.270 9. 010 22.670 7.750 7.450 36.330 8. 620 9. 010 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-1999 14:00 PAGE: FILE HEADER FILE NUMBER 2 RAW~D Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUN~4ARY VENDOR TOOL CODE START DEPTH MWD 10236.0 $ 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: STOP DEPTH .......... 10654.0 04-0CT-98 5.1-12 5.0 N~EMOR Y 11834.0 10236.0 11834.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE IMP RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : ~ PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHFk4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 36.0 79.5 TOOL NUMBER IMP 012 6. 000 10270.0 6% QUIKDRILN 8.70 55.0 8.9 O. 141 70.0 · '. i LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-1999 14:00 PAGE: TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: *** RUN1 IMP 10295'-10655'*** *** RUN2 IMP 10655'-11828'*** DATA FROM DOWNHOLE MEMORY, VS.0C SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VA~UE 1 66 0 2 66 0 3 73 48 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILENUMB NUMB SIZE REPR PROCESS ID ORDER # LOC TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 PIOH LW1 O~ 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 P16H LW1 OH~4~ 4000285 O0 000 O0 0 2 t 1 4 68 0000000000 P22H LW1 OPk4~ 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 P28H LW1 Otk4~I4000285 O0 000 O0 0 2 1 1 4 68 0000000000 P34H LW1 OH~ff44000285 O0 000 O0 0 2 1 1 4 68 0000000000 A22H LW1 OH~4~!4000285 O0 000 O0 0 2 1 1 4 68 0000000000 A28H LW1 0~I 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 A34H LW1 OH~ffff 4000285 O0 000 O0 0 2 1 1 4 68 0000000000 . LIS Tape Verification Listing Schlumberger Alaska Computing Center l-FEB-1999 14:00 PAGE: ** DATA ** DEPT. 10236. 000 ROP.LW1 -999.250 TAB.LW1 O. 000 GR.LW1 PiOH. LW1 0 . 136 P16H.LW1 0 . 141 P22H. LW1 O. 170 P28H. LW1 P34H. LW1 0.182 A22H. LW1 0.100 A28H. LW1 0.378 A34H. LWl DEPT. 10500. 000 ROP. LW1 75.316 TAB. LW1 1 . 236 GR. LW1 P1 OH. LW1 8.486 P16H. LW1 9. 529 P22H. LW1 10. 464 P28H. LWl P34H.LW1 11.544 A22H.LW1 11.501 A28H. LW1 11.862 A34H. LW1 DEPT. 10654 . 500 ROP. LW1 57. 326 TAB. LW1 1 . 125 GR. LW1 PIOH.LW1 9.627 P16H.LW1 11.162 P22H.LW1 11.992 P28H.LW1 P34H. LW1 12.207 A22H.LW1 10.742 A28H.LW1 10.804 A34H.LW1 83.112 0.198 300.000 25.276 11.130 11.748 21.849 12.138 10.472 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 99/02/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUNk4AugY VENDOR TOOL CODE START DEPTH STOP DEPTH MPtD 10387.0 11828.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-1999 14:00 PAGE: $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MENORY or R~-TIME) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE IMP RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~k4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): E~R FREQUENCY (HZ): RENARKS: 04-0CT-98 5.1-12 5.0 MEMORY 11834.0 10236.0 11834.0 36.0 79.5 TOOL NUMBER IMP 066 6. 000 10270.0 6% QUIKDRILN 8.70 55.0 8.9 0.141 70.0 LIS FORMAT DATA *** RUN1 IMP 10295'-10655'*** *** RUN2 IMP 10655'-11828'*** DATA FROM DOWNHOLE MEMORY, VS.0C SOF~WARE $ 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-!999 14:00 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 48 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 F/HR 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 TAB LW2 HR 4000285 O0 000 O0 0 3 1 ! 4 68 0000000000 GR LW2 GAPI 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 PiOH LW2 OPZ~M 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 P16H LW2 OH~4M4000285 O0 000 O0 0 3 1 1 4 68 0000000000 P22H LW2 OP~4~ 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 P28H LW2 OH~4M4000285 O0 000 O0 0 3 1 1 4 68 0000000000 P34H LW2 OPff~M4000285 O0 000 O0 0 3 1 1 4 68 0000000000 A22H LW2 OH~ff44000285 O0 000 O0 0 3 1 ! 4 68 0000000000 A28H LW2 OH~ff44000285 O0 000 O0 0 3 1 1 4 68 0000000000 A34H LW2 OHMM 4000285 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10386.500 ROP.LW2 -999.250 TAB.LW2 0.086 GR.LW2 PIOH.LW2 0.134 P16H.LW2 0.149 P22H.LW2 0.158 P28H. LW2 P34H.LW2 0.200 A22H. LW2 0.100 A28H.LW2 1.355 A34H. LW2 168.990 0.171 300.000 .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-FEB-1999 14:00 PAGE: 10 DEPT. 10500. 000 ROP. LW2 PiOH.LW2 255. 465 P16H. LW2 P34H. LW2 214. 841 A22H. LW2 DEPT. 11000. 000 ROP. LW2 P1 OH. LW2 7. 123 P16H. LW2 P34H. LW2 8. 352 A22H. LW2 DEPT. 11500. 000 ROP. LW2 PIOH.LW2 9.262 P16H. LW2 P34H. LW2 11 . 492 A22H. LW2 DEPT. 11828. 500 ROP. LW2 P1 OH. LW2 8.196 P16H. LW2 P34H. LW2 9. 056 A22H. LW2 621. 906 TAB.LW2 248.619 P22H. LW2 300. 000 A28H.LW2 53. 414 TAB.LW2 7. 642 P22H. LW2 7. 607 A28H. LW2 39.559 TAB. LW2 9. 780 P22H. LW2 10. 593 A28H. LW2 56. 607 TAB. LW2 8.517 P22H. LW2 9. 569 A28H. LW2 O. 103 GR. LW2 264. 329 P28H. LW2 300. 000 A34H.LW2 1. 097 GR. LW2 7. 990 P28H. LW2 7. 830 A34H. LW2 1. 092 GR. LW2 10. 269 P28H. LW2 10. 722 A34H. LW2 1.308 GR. LW2 8. 761 P28H. LW2 9.930 A34H. LW2 82. 381 250. 788 270. 056 27.414 8.189 7.845 40.976 10.850 10.380 21.069 8.931 9.978 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/02/ 1 ORIGIN : FLIC TAPE NAME : 99034 CONTINUATION # : 1 PREVIOUS TAPE : CON~4ENT : B.P. EXPLORATION, PRUDHOE BAY R-O3A, API #50-029-20364-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/02/ 1 ORIGIN : FLIC REEL NAME : 99034 CONTINUATION # : PREVIOUS REEL : COGENT · B.P. EXPLORATION, PRUDHOE BAY R-O3A, API #50-029-20364-01 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : R-O3A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : AK API NUMBER : 500292036401 REFERENCE NO : 99031 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1999 12:11 PAGE **** REEL H~ER **** SERVICE NAME : EDIT DATE : 99/01/27 ORIGIN · FLIC REEL NAME '. 99031 CONTINUATION # : PREVIOUS REEL : COR~4ENT : BP EXPLORATION, PRUDHOE BAY, R-O3A, API #50-029-20364-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/01/27 ORIGIN · FLIC TAPE NAME : 99031 CONTINUATION # : 1 PREVIOUS TAPE : CO~I4ENT : BP EXPLORATION, PRUDHOE BAY, R-O3A, API #50-029-20364-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: R- 03A API NUMBER: 50029203 6401 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 27-JAN-99 JOB NUMBER: 99031 LOGGING ENGINEER: D. KIRKBY OPERATOR WITNESS: C. RUSSELL SURFACE LOCATION SECTION: 32 TOWNSHIP: 12N RANGE: 13E FNL : 4619 FSL: FEL: 4203 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 50.53 DERRICK FLOOR: 49.13 GROUND LEVEL: 20.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 11820.0 2Nl~STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1999 12:11 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... ' GRCH REMARKS: CONTAINED HEREIN IS THE PRIMARY DEPTH CONTROL GR/TENS DATA ACQUIRED ON BP EXPLORATION WELL R-O3A ON 7-0CT-98 WITH A CEMENT BOND TOOL (CBT). NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 99/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUAEfARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10412.0 9463.0 CET 10448.0 9463.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CET LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1999 12:11 PAGE: REMARKS: THIS FILE CONTAINS THE CLIPPED PRIMARY DEPTH CONTROL GR/TENS DATA. ONLY VALID DATA IS PRESENTED IN THIS FILE. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ~K]MB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6037497 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI 6037497 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CET LB 6037497 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10448.000 GRCH. CET -999.250 TENS. CET 3986.000 DEPT. 9463.000 GRCH. CET 91.930 TENS. CET 3553.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1999 12:11 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 99/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION . O01CO1 DATE : 99/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10504.0 9461.0 CBT $ LOG HEADER DATA DATE LOGGED: 7-0CT-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 400 7-0CT-98 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : 9850.0 BOTTOM LOG INTERVAL (FT): 10440.0 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GANk4A RAY CBT CEMENT BOND $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER SGT-L CBT-EB 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1999 12:11 PAGE: DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 11820.0 BRINE 8.50 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: 4.5' LINER FROM 10118' DOWN (DRILLERS DEPTH). PRIMARY DEPTH CONTROL USED. 5 FT OF STRETCH ADDED. LOG MEASURED FROM ORIGINAL KE AT 55.11 ' ELEVATION. COULD NOT REACH DESIRED DEPTH WITH USIT RAN IN HOLE WITH CEMENT BOND TOOL TO ATTAIN DESIRED DEPTH. THIS FILE CONTAINS THE RAW PRIMARY DEPTH CONTROL GR/TENS DATA FOR THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1999 12:11 PAGE: TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NOMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6037497 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 6037497 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 6037497 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10504.000 GR.PS1 483.582 TENS.PSi 2309.000 DEPT. 9461.000 GR.PS1 86.203 TENS.PSi 3553.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 27-JAN-1999 12:11 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/01/27 ORIGIN · FLIC TAPE NAME : 99031 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : BP EXPLORATION, PRUDHOE BAY, R-O3A, API #50-029-20364-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/27 ORIGIN : FLIC REEL NAME : 99031 CONTINUATION # : PREVIOUS REEL : CONk4ENT · BP EXPLORATION, PRUDHOE BAY, R-O3A, API #50-029-20364-01
