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Home My WebLink About205-208~~~ STATE OF ALASKA OICAND GAS CONSERVATION COMMIS~ON MAY 6`~`~~ • OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil SPLUG ^ Other ®Abandoned ^ Suspended • 2oa-czs.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1b. Well Class: ®Development ^Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 4/9/2010 12. Permit to Drill Number: 205-208 309-395 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 1/10/2006 13. API Number: SO-029-21613-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 1/16/2006 14. Well Name and Number: PBU G-30B FEL, SEC. 12, T11 N, R13E, UM 2519 FNL, 2369 Top of Productive Horizon: 2772' FNL, 203' FEL, SEC. 12, T11 N, R13E, UM g. KB (ft above MSL): 69,78 GL (ft above MSL): 34.g3 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2437' FNL, 2141' FEL, SEC. 12, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD): 9305' 8803' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 657857 y_ 5969122 Zone- ASP4 10. Total Depth (MD+TVD): 11860 9029 16. Property Designation: ADL 028280 TPI: x- 660028 y- 5968914 Zone- ASP4 Total Depth: x- 658082 Y- 5969209 Zone- ASP4 11. SSSV Depth (MD+TVD): N/A 17. Land Use Permit: f TVD 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL rost ( ): 20. Thickness of Perma 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD / NGP GR / ROP, MGR / CCL / CNL 22. Re-DrilULateral Top Window MDITVD: 9520' 8928' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT.' CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED " r 11 rf 1 n r 4' ' " 47# L- urfa 65 0' rf 1 -1! " 75 I ' 7" 4 9 1 -1 4 CI 17 u I / 1 ~ ~~ 24. Open to production or injection? ^ Yes ®No 25. Tuew~'RECORD If Yes, list each interval open (MD+TVD of To & Bottom Perforation Size and Number): SIZE DEPTH .SET MD PACKER .SET MD / TVD ; p 3-1 /2", 9.2#, L-80 9456' 6430' / 6093' MD TVD MD TVD 9398' 18863' 26. ' ACtD,FRACTURE,,CEMENT_SQUEE2:E,fTC. i ,. ,, ~,~+.: , ~ ~~ ~~ ~.` DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED 9350' Set CIBP ' scar - ssas~ s sooa -soon Tubing Punch ' 9337' Set Cmt Retainer & Pump 10 Bbls P&A Cement ' 9320' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqui red? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yes ®No If Yes to either question, list fomtations 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 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only 29. GEOLOGIC MARKERS (List all formati ons and ma encountered): 30. NATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 1 B 9599' 8978' None Zone 1A / TDF 9727' 9030' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. /Q',, ~ '" Signed: Terrie Hubble Title: Technical Assistant Date: • ° PBU G-30B 205-208 309-395 Prepared ey NameAVumber. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Dridinq Engineer: ~Imer Hoffman, 564-4592 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 • • G-30B, Well History (Pre Rig Sidetrack) Date Summary 1/1/2010 INITIAL T/I/O 100/0/0 RUN 1: HEAD / 2 X 1 11/16" WEIGHTS / CCL / GO ADAPTER /FIRING HEAD / 1 11/16" HALIBURTON SETTING TOOL/PLUG. TOTAL LENGTH 26' MAX OD 2.281 ". SET HALIBURTON BRIDGE PLUG AT ~, 9350'. SHUT DOWN DUE TO PHASE 3 WEATHER CONDITIONS. 1/3/2010 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0 = 100/0/0 RUN 1; TUBING PUNCH. TOOL LENGTH 26.3' MAX OD 1 11/16" SHOT TUBING PUNCH FROM 9341' - 9343'. PRESSURE IMMEDIATELY ROSE TO 650/0/0. AFTER RETURNING TO SURFACE, LRS BEGAN PUMPING. ESTABLISHED LEAK RATE AT 0.35 BPM AT 2,800 PSI. CALLED TOWN AND CHANGED PLAN FORWARD TO NOW SHOOT SECOND TUBING PUNCH AT 6450', 6' ABOVE 7" LINER TOP. 1/4/2010 TUBING PUNCH (SMALL) HOLES FROM 9000' - 9002'. SET HLS 3.5" EZ DRILL SVB SQUEEZE PACKER MOE 9337', TOP AT 9335.7', OAL 33". CORRELATED TO PERFORATION RECORD 10-OCT- 2009. FINAL T/I/O = 450/0/0 WELL LEFT SI UPON DEPARTURE AND PAD OPERATOR NOTIFIED OF VALVE POSITIONS. JOB COMPLETE. 2/13/2010 T/I/0= 600/0/0 Temp= SI Infectivity Test- (CTD Prep) Pumped 15 bbls crude down the tubing to establish an infectivity rate of .41 bpm C~ 2800 psi. Final WHP's = 1200/0/0 3/29/2010 Make up HES 3 1/2" star guide stinger. RIH to EZSV. Sting into EZSV at 9323 (CT measurement). Pump 10 bbls,,_15 8 opa cement (9 bbls in annulus 1 bbl on too of cement retainer;lean out tubing and CT with 40 bbls biozan. POOH. RIH w / 2.74" parabolic mill for drift run to retainer set at 9384' and tag high at 9237' ctmd. Mill with multiple stalls at this depth. POOH to inspect mill. Counter was -97' when we got to surface. Cement Retainer at 9337'. Mill showed circular wear at the tip indicating that the mill was in fact turning on the cement retainer. Run in hole to freeze protect well. Freeze protect well with 27 bbls McOH. POOH. RDMO. JOB COMPLETE. 3/31/2010 T/I/O = 200NacNac. MIT Tbg FAILED to 1000 psi. (2nd test). MIT IA Pp SS_~D tg,3000 nsi• MIT OA PASSED to 2000 psi. Pumped down TBG; 3.7 bbls 60/40 meth to test. MIT Tbg lost 220 psi in 1st 15 mins and 40 psi in 2nd 15 mins for a total loss of 260 psi in 30 minute MIT. Rigged down off of Tbg and up to IA. Pumped down IA; 7.5 bbls crude to test. MIT IA lost 80 psi in the 1st 15 mins and 30 psi in the 2nd 15 mins for a total loss of 110 psi in the 30 minute test. RD off of IA and up to OA. Pumped down OA; 3.5 bbls crude to test. MIT OA lost 100 psi in 1st 15 mins and 40 psi in the 2nd 15 mins for a total loss of 140 psi in the 30 minute test. Bled pressures back to starting. Notified Operator of well status. FWHP's=380/0/0. 4/1/2010 DRIFT TO 9280' SLM W/ 20' x 2.70" DMY WHIPSTOCK. RUN X-LINE TO 6,378' SLM FOR +40' CORR. TO 6,418 CMD. RUN 2.5" LIB TO 9,296' SLM (9,336' C D). DRIFT 2.73" G-RING TO 9,296' SLM (9,336' CMD). DRIFT 10'-2.7" DUMMY WHIPSTOCK TO 9,296' SLM (9,336' CMD). DRIFT 20'-2.7" DUMMY WHIPSTOCK TO 9,296' SLM (9,336' CMD). MIT-T ~ 1,000 PSI 3 X (failed all three times). WELL S/I ON DEPARTURE. PAD OP NOTIFIED OF VALVE POSITIONS. 4/2/2010 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0=450/0/0 SET BAKER 3.5" MONOBORE WHIPSTOCK 1NITH TOP OF WHIPSTOCK AT 9310'. WHIPSTOCK DIMENSIONS: TRAY LENGTH = 5.3', PINCH POINT = O', MID POINT = 4.4', FINAL EXIT = 5.2'. 2 RA PIP TAGS INSTALLED IN 5.25' BELOW TOP OF WHIPSTOCK AT A DEPTH OF 9315.25'. WHIPSTOCK IS ORIENTED TO 170 DEG LEFT OF HIGH SIDE (-170 DEG). FINAL T/I/O = 450/0/0. JOB COMPLETE. 4/3/2010 T/I/O = 400/30/0+. Temp = SI. Bleed WHPs to 0 psi (CTD prep). TBG, IA, OA FLs C~ surface. Bled TBG & IA 0 psi in 2.5 hrs (4 bbls liquid). SI, monitored for 30 min. TBG & IA increased to 0+ psi. Heater placed on well (may cause WHPs to increase). Final WHPs = 0+/0+/0+. 4/3/2010 T/I/O = 150/0/0. Set 3" CIW H TWC #303 thru tree C~ 84" using 1-2' ext. Torqued all horizontal valve flanges to API specs. Pressure tested tree to 4700 psi with diesel for 5 min, no loss, no leaks. Pulled TWC #303. Set 3" CIW H BPV #315 thru tree C~ 84" using 1-2' ext. Pre Nordic-1 4/3/2010 T/IA/OA=150/0/0 Temp=Sl PPPOT-T (PASS) (Pre CTD) PPPOT-T : RU 1 HP BT onto THA 1000 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment, re-installed Alemite cap. Cycle and torque LDS "Standard" all functioned with no problems Page 1 of 1 • • BP EXPLORATION Page 1 of 2 Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: MOBILIZATION Start: 4/5/2010 End: 4/9/2010 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 4/5/2010 14:00 - 00:00 10.00 RIGU P PRE 4/6/2010 00:00 - 06:00 6.00 RIGU P PRE 06:00 - 06:30 0.50 RIGU P PRE 06:30 - 10:00 3.50 RIGU P PRE 10:00 - 10:15 0.25 RIGU P PRE 10:15 - 12:00 1.75 RIGU P PRE 12:00 - 12:15 0.25 RIGU P PRE 12:15 - 15:00 2.75 RIGU P PRE 15:00 - 15:30 0.50 RIGU P PRE 15:30 - 18:00 2.50 RIGU P PRE 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 22:00 3.50 RIGU P PRE 22:00 - 00:00 I 2.001 RIGU I P I I PRE 4/7/2010 00:00 - 00:15 0.25 RIGU P PRE 00:15 - 02:30 2.25 RIGU P PRE 02:30 - 02:45 0.25 RIGU P PRE 02:45 - 03:00 0.25 RIGU P PRE 03:00 - 04:30 1.50 RIGU P PRE 04:30 - 04:45 0.25 RIGU P PRE 04:45 - 11:30 6.75 RIGU P PRE 11:30 - 14:00 2.501 BOPSUp P ~ PRE 14:00 - 17:00 3.00 RIGU P PRE 17:00 - 23:00 6.00 BOPSU P PRE 23:00 - 00:00 1.00 BOPSU P PRE 4/8/2010 00:00 - 01:30 1.50 BOPSU P PRE 01:30 - 02:30 1.00 RIGU P PRE 02:30 - 02:45 0.25 RIGU P PRE 02:45 - 04:30 1.75 RIGU P PRE 04:30 - 05:30 1.00 RIGU P PRE 05:30 - 06:30 1.00 RIGU P PRE SWAP OUT TOT'S SWAP OUT TOT'S PJSM WITH INCOMING CREW. CONTINUE SWAP OUT OF TOT'S PJSM FOR RU BRIDLE LINE R/U BRIDLE LINE PJSM FOR L/D OFF DRILLER SIDE WINDWALL VD OFF DRILLER SIDE WINDWALL AND PULL BOARD UP TO DERRICK AND SECURE PJSM FOR SWAPPING OUT INJECTORS LIFT OUT HR 480 INJECTOR AND LIFT IN HR 5100 INJECTOR. CREW CHANGE AND PJSM FOR LIFTING OFF-DRILLER'S SIDE WINDWALL LIFTING WINDWALL. WINDWALL ON DRILLER'S SIDE WAS ALREADY RAISED AND HAD TO BE LOWERED IN ORDER TO LIFT OFF-DRILLER'S SIDE WINDWALL INTO POSITION FIRST SO THE PIN-HOLES LINED UP CORRECTLY. OFF-DRILLER'S SIDE WINDWALL WAS RAISED AND ATTEMPTED TO BE LINED UP INTO POSITIOM PRIOR TO RECOGNIZING THIS. R/U HOSE BUNDLE TO INJECTOR AND SECURE BOP. PREP RIG FOR MOVE TO G-PAD. PJSM FOR MOVING RIG TO G-30 MOVE RIG FROM E-PAD TO G-PAD. PJSM FOR SPOTTING THE RIG OVER THE WELL. SPOT RIG OVER WELL G-30C. ACCEPT RIG ~ 03:00 HRS. SECURE CELLAR. GREASE CHOKE MANIFOLD AND HP VALVES IN SHAKER ROOM. SPOT CUTTINGS BOX. INSTALL STAIRS TO SECOND LEVEL. PJSM FOR NU BOP'S NU BOP'S. INSTALL CHOKE AND KILL LINES. MU HYDRAULIC LINES. INSTALL DRAIN PAN IN RIG FLOOR. FUNCTION TEST BOP'S. SPOT SPOC SHACK. BEGIN SCHEDULED BOP TEST. AOGCC REPRESENTATIVE(BOB NOBLE) WAIVED WITNESS TO . BOP TEST. SWAB VALVE NOT HOLDING. GREASE AND STILL NOT HOLDING. CALLED GREASE CREW OUT TO LOCATION TO ASSIST. P/U BAKER HUGHES TOOLS WHILE WAITING ON GREASE CREW CONTINUE BOP TEST. RE-GREASE CHOKE # 11, FUNCTION HCR & RE-TEST (GOOD). KILL LINE HOSE FAILED. REPAIR AND RE-TEST (GOOD). CONTINUE TEST OF BOPE. PT OF BOPE COMPLETE. RD FLOOR FROM BOPE TEST AND SECURE HOSE BUNDLE TO DERRICK. PREP FOR P/U INJECTOR. PJSM FOR P/U HR 5100 INJECTOR. P/U INJECTOR AND STAB ONTO STUFFING BOX. M/U GOOSENECK ONTO INJECTOR CREW CHANGE AND PREP RIG FLOOR FOR PULLING CT ACROSS INTO INJECTOR. Printed: 4/12/2010 1:13:16 PM • • BP EXPLORATION Page 2 of 2 Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: MOBILIZATION Start: 4/5/2010 End: 4/9/2010 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To .Hours Task Code NPT Phase Description of Operations 4/8/2010 06:30 - 07:00 0.50 RIGU P PRE PJSM FOR PULLNG CT ACROSS PIPE SHED INTO INJECTOR. 07:00 - 08:30 1.50 RIGU P PRE RUN WINCHLINE FROM RIG FLOOR THROUGH INJECTOR BACK TO REEL. INSTALL INTERNAL GRAPPLE IN END OF CT. 08:30 - 09:00 0.50 RIGU N PRE CABLE IS ON THE WRONG SIDE OF THE SHIPPING BAR. RE-STRING WINCH LINE TO CORRECT PROBLEM. 09:00 - 10:10 1.17 RIGU P PRE PREP TO PULL PIPE ACROSS INTO INJECTOR. 10:10 - 13:00 2.83 RIGU P PRE PULL CT ACROSS PIPE SHED AND INTO INJECTOR. INSTALL CT CONNECTOR AND SNUB TEST PLATE. PJSM FOR INSTALLING NEW KILL LINE. PERFORM PULL TEST TO CALIBRATE LOAD CELL. PORTABLE LOAD CELL IS NOT WORKING, SEND SLB ET BACK TO DEADHORSE TO GET ANOTHER. START INSTALLING NEW KILL LINE. 13:00 - 14:00 1.00 RIGU N PRE CONTINUE INSTALLING NEW KILL LINE. 14:00 - 17:00 3.00 RIGU P PRE HOOK UP NEW PULL TEST PLATE. CALIBRATE INJECTOR LOAD CELL WITH PORTABLE PULL TEST PLATE. TEST ELECTRONIC SNUBBING AND OVERPULL SAFETIES. 17:00 - 21:00 4.00 RIGU N PRE FINISH INSTALLING NEW KILL LINE AND PT TO 4800 PSI. 21:00 - 21:30 0.50 RIGU P PRE PJSM FOR PUMPING SLACK AND CUTTING COIL 21:30 - 00:00 2.50 RIGU P PRE RU AND PUMP SLACK INTO CT ~ 3.2 BPM. CUT 318' OF CT TO FIND ELINE. 4/9/2010 00:00 - 00:30 0.50 RIGU P PRE PLACE INJECTOR OVER BUNGHOLE AND PREP FLOOR FOR PULLING BPV. Printed: 4/12/2010 1:13:16 PM • BP EXPLORATION Page 1 ~ Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: RE ENTER Start: 4/7/2010 End: 4/15/2010 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 4/9/2010 00:30 - 00:45 0.25 RIGU P PRE PJSM FOR PULLING BPV. 00:45 - 02:30 1.75 RIGU P PRE RIG UP LUBRICATOR AND PULL BPV. FIRST ATTEMPT PULLING TOOL HUNG UP IN SSV, PUMP IT FULLY OPEN AND GET SEVERAL MORE TURNS ON FUSIBLE. SECOND ATTEMPT PULL BPV, ABOUT 150 PSI UNDER IT. 02:30 - 03:00 0.50 RIGU P PRE INSTALL CT CONNECTOR. PULL TEST TO 35K, GOOD. 03:00 - 03:50 0.83 RIGU P PRE LOAD BTT TOOLS ONTO RIG FLOOR. 03:50 - 04:40 0.83 RIGU P PRE INSTALL BHI CABLE HEAD. 04:40 - 07:00 2.33 BOPSU P PRE TEST INNER REEL VALVE AND CT CONNECTOR, GOOD. INSTALL CHECK VALVES BACK INTO UOC. 07:00 - 07:15 0.25 STWHIP P WEXIT PJSM WITH CREW REGARDING PU OF WINDOW MILLING BHA. 07:15 - 08:15 1.00 STWHIP P WEXIT MU WINDOW MILLING BHA. 08:15 - 09:00 0.75 STWHIP P WEXIT OPEN EDC AND PUMP SLACK FORWARD WITH USED GEOVIS SYSTEM 09:00 - 11:00 2.00 STWHIP P WEXIT RIH WITH WINDOW MILLING BHA 11:00 - 11:15 0.25 STWHIP P WEXIT LOG INITIAL TIE-IN FROM 9000'. +9' CORRECTION. 11:15 - 21:00 9.75 STWHIP P WEXIT RIH TO ENGAGE WHIPSTOCK AND BEGIN MILLING ~ ~~ G WINDOW. . j ESTABLISH FREE SPIN OF 2578 PSI AT 1.56 BPM. UP WEIGHT 27K. RIH WEIGHT OF 20K TAG WHIPSTOCK @ 9305' TWICE. CLOSE EDC AND BEGIN MILLING WINDOW AT 9304.0' TOP WINDOW IS 9304.5 FT. 9305.2' 1.58/1.59 2981 PSI PVT = 330 BBLS DHWOB = .35K 9306.0' 1.59/1.60 2992 PSI PVT = 330 BBLS DHWOB = 1.34K 9307.6' 1.57/1.58 2908 PSI PVT = 328 BBLS DHWOB = 1.2K 9308.1' 1.58/1.60 2926 PSI PVT = 328 BBLS DHWOB = 1.4K 9308.4' 1.57/1.58 2875 PSI PVT = 328 BBLS DHWOB 1.26K 21:00 - 00:00 3.00 STWHIP P WEXIT CONTINUE MILLING WINDOW. 9308.5' 1.55/1.56 2860 PSI DHWOB = 1.29K 9309.0' 1.56/1.58 2930 PSI DHWOB = 1.52K 4/10/2010 00:00 - 04:00 4.00 STWHIP P WEXIT CONTINUE MILLING WINDOW. 9309.30' 1.56/1.58 2930 PSI 1.38K DHWOB 9309.70' 1.57/1.58 3138 PSI 1.40K DHWOB 04:00 - 06:00 2.00 STWHIP P WEXIT AFTER 9310 FT DWOB < 1.OK. 9311.30' 1.56/1.58 2915 PSI 0.84K DHWOB 06:00 - 10:00 4.00 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW. 9312.00' 1.55/1.57 2820 PSI 0.03K DHWOB APPEAR TO BE THROUGH WINDOW. INCREASE RATE TO 2.0' PER HOUR FORMATION SAND NOTED IN SAMPLE FROM 9312' SAMPLE. 10:00 - 13:30 3.50 STWHIP P WEXIT 9322.00' 1.57/1.58 2915 PSI 0.93K DHWOB 10' OF RATHOLE MILLED. PUH AND BEGIN BACK REAMING WINDOW BACKREAM 3 TIMES. SHUT DOWN PUMP AND DRIFT WINDOW DRY. Printed: 4/12/2010 1:13:24 PM TREE.- 3" -SM-EMC _ _ S~FFT ~' ~~= 7 X ~a_5r~," Uu Ii a WELLI~IEAD= MCEVOY ACTUATOR= kB. ELEV. - AXELSON 69.78' 8F. ELEV = KOP = 39.3` 3098' Max Angle = Datum MD = 97° ~ 10042' ..w.__. 9410' Datum TV 0 = 8$00' SS ~~ ~ ~`P,::.. , !~ A~#[7 TFiE l , ~ ~ ; FAR THE STfT~41;; ALE flM~LET#{lfti! *** ~~ ~~ 1'3-318" CSG, 72#, L-80, ID = 12.347" ~--~ 26$x, 9-518" CSG XO NSC~; x RTRS dd7$' Minimum ID =1.81.. $~7' 2.70" KB LINER TOP PACKER 2201' -^~3-1/2" 555V O7t5 LANDING NIP, ID = 2.750" GAS LIFT MANDRELS 3T! MD TVD DEV ' TYPE VLV LATCH PORT DATE 2 '' 4269 4120' 26 McfvltJRRY DOME RK 16 04/27/10 1 6390 5989 32 McMURRY SO RK 20 04127110 6418 3-112" HES X NIP, ID = 2.750" 19-5/8" X 3-1/2" 8KR SAB PKR, ID= 3.25" 1 OF 7" LNR Imo' 6456 9-518" CSG, 47#, L-80, ID = 8.681" 1~ 6600' 6d56~ 9-5/8" x 7" LTP, TIEBACK &LNR HRG, fD = 6.250" EAII_ED LAP TEST, IA3J 3BPM 200fl PS# {#' SG 6475 --~7" LNR PIN, ID = 6.184" 9-518" GSG MILLOli7 WINDOW (G-30A) 6600` - 6645' 1~-ir~•• ~~ Lrs~~r~~~c~, ID--~.~1" I 2.70" I3EPLC7Y SL~~JE, #[5= 2.377"' ~` I.1,s ~ N: , PL NGHES I-I 900 t3'-91}02` 3-112" Whipstock w9320 3-1 t2" crr;t retainer 9337' 3-112" CIBP 93J~0" PERFORA TION SUMMA RY REF LOG: MCNLlCGL/GR ON 01118106 TIE IN LOG: GEOLOGY PDC LOG ANGLE AT TOPPERF: °~' Note: Refer to Production DB for h#stor~al perf data. SQE SPF INTERVAL OPN/SQZ DATE 2-318"' SLTO 1 0305 -1 1 851 SLOT 04{19(10 ~ i $9$3' 2-318°' STL LNF ID = 1.995.' 7" LNR MILLOLfT WINDOW {G-30G) 9305' - 9309' ~~i ~ __ 7U'1;~5" i~ 1-~~es rsr ca-t~inr~ ~uts~ iu PBTD 10179 .. LNR., 4.7#, L-80 STL, .0039 bpf, ID = 1:995" ~ „ DATE REV BY COMMENTS DATE REV BY COMMENTS 0$101186 QPoGINAL COMPLETIC3N 07/30/85 SIDETRACK (G-30A} 01l18J06 NORD1Ci GTQ SIDETRACK {G-30B) 04f22I10 NORDIC 1 CTD SIDETRACK {G-30Cj 04!26/10 P3C DRLG HO CORRECT#ONS 0/01/10 CJN/P.1C GLV C/0 (04!27!10} PRt1DHOE BAY UNf( WELL_ G-30C PERMIT No: A ~ No: 50-029-21613-03 SEC 12, T11 N, R13E, 2519` ENL & 2369' FEL BP Explorat#on {Alaska) • • F 1A - F i, L-1 SEAN PARNELL, GOVERNOR L ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSSION N s ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-30B Sundry Number: 309-395 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount DATED this Chair day of December, 2009 Encl. Gr)"', STATE OF ALASKA Cf 1 Z'� A�SAIL AND GAS CONSERVATION COMMAN RECEIVED APPLICATION FOR SUNDRY APPROVAL NOV 2 4 2009 20 AAC 25.280 1. Type of Request: MOW Oil & Gas Cans, C Ot1r aiss1Of1 ® Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Re -Enter Suspe�y cify: �� ❑ Alter Casing ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Spe ❑ Change Approved Program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 205 - 208 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 21613 -02 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU G -30B- Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028280 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11860' 9029' - 1 11824' - 9028' 10150' None Casing Lenath Size MD TVD Burst Collapse Structural Conductor 11 110 110 Surface 2684' 13 -3/8" 2684' 2684' 4930 2670 Intermediate 6590 9 -5/8" 6590' 6230' 6870 4760 Production Liner 336T 7" 6456'-9520' 6115'-8928' 8160 7020 Liner 2506' 2-3/8 9 11860' 8836'- 029' 1 11200 1 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Above CIBP: 9576'- 10045' 1 8963'- 9028' 3 -1/2 ", 9.2# L -80 9456' Packers and SSSV Type: 9 -5/8" x 3-1/2" Baker'SAB' packer; Packers and SSSV 6430'/6093' 7" x 3 -1/2" Baker'SABL -3' packer I MD (ft) and TVD (ft): 9398'/ 8863' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑Exploratory ®Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 15, 2010 ❑ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ® Abandoned 16. Verbal Approval: Date: ❑ WINJ ❑ GINJ ❑ WAG ❑ Plugged ❑ SPLUG Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Wilmer Hoffman, 564 -4592 Printed Name Jo0v kAcNpLjer9 Title Engineering Team Leade Prepared By Name/Number Signature Phone 564 -4694 Date Z 4, Terrie Hubble, 564 -4628 t Commission Use Onl Conditi approval: Notify Commission so that a representative may witness Sundry Number. ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 3500 / s Other. R'oZ S Subsequent Form Required: APPROVED BY Approved By/ COMMISSIONER THE COMMISSION Date Z /o 7 F -403 R � � Submit In Duplicate ORIGINAL 7 To: Tom Maunder o' Petroleum Engineer 0 h N. Alaska Oil & Gas Conservation Commission "r p `Q 9 �1416 From: Wilmer Hoffman v CTD Engineer s ` oP �� Date: November 19, 2009 �`qC Re: G -30B Sundry Approval o Sundry approval is requested for well G -30B. This well was sidetracked with coil in January 2006 as a 3 Zone 1B horizontal drilled with tiny tools. The drilling operations were plagued throughout by o► directional control problems. The directional problems led to two additional MHO/HOT penetrations `o e that were not intended and an inclination excursion into the upper 14P sand that was also unintended. ~ „� The excursion into the upper 14P required a bit trip for higher bend motor to aggressively steer back ` `o down. The well went to marginal within a year of being completed. The well cycled effectively for a couple v `� of years, but the cycling had become ineffective by early 2009. In June 2009, a plug was set to isolate a Q all the existing G -30B perforations and the well was perforated near the landing point and slightly up into the build. The plug effectively shutoff the old perfs, but the 90' of perforations that we tried to .4 `^ Q place above MHO on either side of the landing point did not produce. There are no more options for this well. `o i h 3 � An MIT -IA passed to 3,000 psi and a MIT -OA passed to 2,000 psi both in September of 2009. d � o � REASON FOR SIDETRACK: c O h � Well G -30B has been uncompetitive due to cycling of production. The old perfs were shutoff and the new perfs do not flow which makes this well a good candidate for a coil sidetrack. The proposed 3 location is intended to optimize off take in 51 acre Zone 2A/1B /lA. The proposed plan for G -30C is to drill a through tubing, dual string exit sidetrack with the SLB/Nordic ; c 1 Coiled Tubing Drilling rig on or around February 20, 2010 The existing perforations will be isolated' u by a cast iron bridge plug (CIBP) along with cementing the 3 -1/2" x 7" annulus. The sidetrack, G -30C, V will perform a dual string exit in the existing 3 -1/2" tubing and 7" liner and kick off into Zone 2. The o target is Zone IA and 1B. The plan is to complete the well with a bonsai completion if no losses are encountered. The contingency for losses is to complete the well with a cased and perforated liner to TD. The following describes the work planned and is submitted as an attachment to Form 10 -403. Schematic diagrams of the proposed sidetrack and its contingency are attached for reference. v O Pre -Rig Work: (scheduled to begin January 15, 2010) 1. S Caliper tubing and drift with dummy whipstock (done on 9/4/09) 2. O MIT -OA to 2,000 psi, MIT -T to 3,000 psi and MIT -IA to 3,000 psi (passed all three on . 9/5/09- 9/9/09) 3. O AC -LDS; AC- PPPOT -IC, T (all passed on 9/26/09) 4. S Dummy off both GLVs 5. E Set 3 -1/2" CIBP at 9,350' MD just above 3" deployment sleeve 6. F MIT -T to 1,000 psi for 10 minutes to prove barrier. 7. E/F Punch holes in the 3 -1/2" tubing at 9,343' and test for injectivity. '-� S te- E•x.�P 8. E Set 3 -1/2" cement retainer at 9,335'. 9. C Create "cement packer" in the 3 -1/2' x 7" annulus with 73 bbls of 15.8 ppg cement 10. C Clean out cement in the tubing down to the cement retainer at 9,335'. 11. E Set 3 -1/2" mono -bore whipstock at 9,320' 12. O Bleed wellhead pressures down to zero. J �� 13. O Bleed production flow lines and GL lines down to zero and blind flange `j 14. O Remove wellhouse, level pad } 1 Rig Work: (scheduled to begin around February 20, 20 10) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 2.80" window at 9,330' and 10' of rathole in Zone 2. Swap the well to Geo -Vis. 3. Drill Build: 3" OH, 570' (19.5 deg/100 planned) 4. Drill Lateral: 3" OH, 2,230' (12 deg/100 planned) with resistivity 5. Run 2 -3/8" bonsai L -80 liner (solid and slotted) leaving TOL at 9,000'. Slotted from TD at 12,130' — 10,300 , solid from 10,300' — 9,000'. 6. Pump primary cement from 10,300' leaving TOC at 9,000', 10 bbls of 15.8 ppg liner curt planned 7. Cleanout liner and MCNL /GR/CCL log 8. Test liner lap to 2,000 psi. 9. Perforate liner per asset instructions — if needed (1,200') 10. Set 3 -1/2" KB Liner Top Packer at 8,990' 11. Freeze protect well, set BPV, RDMO. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Generic GLV's 3. Test separator (ASRC) Wilmer Hoffman CTD Engineer 564 -4592 CC: Well File Sondra Stewman / Terrie Hubble Iii�r �•! i I I . . f i rs - i .I 11 oil 1 1 fl �T��:�w ?r�iTtF .Ti`d� � � ®®' � ,!• �� 1 a ^ 1' �;Y"- LT►�.ctTlf.7��2ST'- Ti-ila �rr�� *� {• + + } } { {! { # + } }� • - fo Vii' }� �� *_ _! � � r"3Tr;�'_ �T•r.�`.TS�7F'+S,i r #l R 1 o f 01 MLILA Lia . 1� . 1 . 1 it • 1 1: +f ++ 1 i:.�iL7 Y.iiia T.�. f�.`��.��i7 .�. - �j' -� ' - I i ' - r . •�.VIY�•u• •1iA.•..�T �� L.I,..I l(. ^Iii - .I:v 1. �� E�.�4I � Tr T . _T _► : -- n; - T REE = 3" -5M -FMC WE MCEVOY SAFIE[YINUIL: — 1 X9-518 LINIAHUR HAS . ... . .. ... . ....... ... .. .. .. ...... ... A . C . T A .. T . OR .... .................. A . X . E . L . SO . IN . G-30C KNOWN LEAK AND THE REASON FOR THE .................... . ..... . . ............. * k.. 6 ....ELEV .. . ......................... . ....... Proposed CTD Sidetrack STRAnni F C13MPI FT113N ... ..... ....... - ... .. .. ... . . ............... . .................. KOP 3098 .......................................................................... Max Angle - 97 ..... ......................... ..... 9410 ' ................ .......... . ................. 3 - 1 f2" S S SV 0 TIS LANDING N IP, 11) 2.7 ID D Datum 8800' SS 0 GAS LIFT MANDRELS 13-318" CSO, 720. 600. ID = 112-347" 2664' — T VD DEV TYPE I VLV ILATCH I PORT� DATE 42 471 S" MD T .-Q 20 26 MCMURRY I DOME I RK 1 16 102A 3X6 M 1 63 9-5" CSO XO NSCC x BTRS 447T 1 6390 59 L go 59 4 32 MCMURRY SO RK 20 102A 3M I I Minimum ID = 1.81 899C 6419 3 - 1n "HESX =z.75o" TOP OF 2.='* LINER Ho x 3 112' 9 KA sAs wR. v - TOP OF 7" LNRj 5456' —[��7 BAKER ZXP LTP ID = 6.25"; FAILED LAP TEST NJ 36PM 200OPSI (presq MILLOLIT WINDOW t&3W 66W 664T 9-518- CSO, 47#, L-80, ID - 8.001' 55W TSGR 8859' �Tp . - �31 ITUBING PUNCHES h ip t, v H2.30', 4.7#, L - 80, S TL So lid LN R , / =t,,b TOP OF 2-38- LNR 9361' -112" TBG.9.2#.L-80, 0087bpt,ID-2.992' 9456' - - - - - - - - - - - - - - - - - - - PERFORATION SUMMARY G16 - - - - - - - - - - - - - - - - - - -I REF LOG: MCINUCaJOR ON 01 A 8106 C TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 58' @ 9627' Nate: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPNfSQZ DATE 9354' 1-9116" 6 9627-9657 0 063009 1-9116" 6 9705-9735 0 06!30109 1-9/16" 6 10015 -10045 0 W29)09 1-9t16" 6 10250 - 10640 k- 01/19/06 awc r wu w mruowr JQWQ 1 -9M 6" 6 10680 - 1 031 0 C 01 A 9106 1-9116" 6 10910 -10960 C 01119106 1-9A6" 6 10990 -11050 C 01119106 1 -9M 6" 6 11070 -11150 C 01H9106 1-9116" 6 11360 - 11440 C 01119106 1-9116" 6 11700 -11820 C 01 A 9106 10150' 2 - 318" VVFDCOP 7" LNR, 29#, L-80. 0,0371 bpf, ID 9823' A 1(06J29)09) IS' I F2- LNR, 4 L-80 STL,.0039 bpt, 10 - �1.9W DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 9M7= CMUGINAL COMPLETION 093009 MSE PROPOSED CTD SIDETRACK WELL 0-30 SUMS 5WTRMX 0M41W PERMIT Na 01A0N 111101111111=1 CTD SMTRMX 1&3M AR No: 50-029-21613-0 01 123)06 JUTLH DRI-0 DRAFT CCRRECTIONS SEC 1 2, T1 N, R1 3E, 2519' FNL & 2369 FEL 02A 3106 TVNS)TLH GLV COO 07/29JO9, R ICIBP)PERFS (06f29-30109) M Exp1swulien (Nooks) Completion proposal with no losses — bonsai TREE = 3" -5M -FMC WELLHEAD MCEVOY SAFE I Y NU I E: "' I X 9 -518 LNR HUR HAS AC - . .. - i ..... ---- A — - --------- . X E L S 0 N G-30C KNOWN LEAK AND THE REASON FOR THE STRAnni F rail FrioN ... ................. Proposed CTD Sidetrack ELEV 3 K P .. 0 . . ... ........................ * ...................... ........................................................................... Max Angle - 97' Q 10042' . ........... ...................................................... i; 0 Datum - 941 Id m SSSV OTIS LANDING NIP, ID 2.7 Datum TVO ........... . ............. .�§ 13 - 3+8" C S 0. 72#, L. 80, ID 12.3 GAS LIFT MANDRELS ! — VD DEV I TYPE I ]LATCH PORT DATE TV Sr _MD T CSO XO NSCC x STIRS -4 4t VLV M 26E9471 9 1201 26 IMcMURRY D OME 6 0211 3 6390 5 1 1 X6 1 19-5/8 L 4.1 6390 5989 1 32 IMcMURRY1 SO RK 2 02A 3006 Minimum ID = 1.920" @ 8900' TOP OF 2-318" LINER z z 9 - 5P8" X 3 -1 8 KR SA 8 PKR, ID - 3.25f] TOP OF 7" LNR 6455' Li'Li; =,-'P _TP ID = 6.25''. FAILED LAP TEST MILLOUT WINDOW (Ill 6600' - =6645' L 9.518" C S G. 47#, L - 80, ID - 8.081 TSGR 8859' Top 02-3x'8" liner deploymentsleeve TUBING PUNCHES] T? 48 TOP OF 2-3�NR 9361' -1/2"TBG,92#,L-80,EIJBBRD.0087bpf,ID-2.992'I 9456' PERFORATION SUMMARY C REF LOG: MCNLJCCLJGR ON 01118/06 TIE-IN LOG: GEOLOGY PDC LOG 177.. L-80 Lin,, - ernent _'rt H ANGLE AT TOP PERF: 58*@9627' Note: Refer to Production DB for historical pert data ED ??� SIZE SPF INTERVAL OPNJSQZ_ DATE 55 4' —F3_.T9_KR DEPLOY SLV. ID - 2.250" 11-91A 6" 6 9627 . 9657 0 06)3009 3 1-9116" 6 9705-9735 0 063009 1 -9116" 6 10015 -10045 0 062909 1 -9116" 6 10250 - 10540 01A 9106 311Ut I KAf-K MMJUW (S.-JU131 1-9116" 6 10680 -10810 C 01 it 9006 it rVAT 93AR111111 fr—'InRl 4111 1 -9116" 6 10910 -10960 C 01)19)06 1-9116 6 10990 -11050 C 01)1 A/6 Ce�C«A 1-9/16" 6 11070 -11150 C 01 A 9006 6e r— to (a- 13. 1 -9116" 6 11360 - 11440 C 011 9106 1-9116" 6 11700 - 11820 01 A 9006 10150' 2-30" wFD C113P IZ - E - clo 5 (06t29fO9) 7 LNR, 29#, L-80. 0.0371 bpf, ID = 6 18T7 9823' A 1 3 12-318" LNR. 4.13#, L-80 STL..0039 bpf, ID 11560' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT CAN?= OffiGIIIIIIAL COMPLETION 09)211 J09 MSE PROPOSED CTD SIDETRACK WELL G-30 01130al SIOETRACK CG-30A) PERMIT No 01AIIII1111114 NORDIC? CTO SJOETRA01 (G-300) API No: 50-029-21613-0 0112306 JLJffLH DRLG DRAFT CORRECTIONS SEC 12, T11 N, R13E, 2519' FNL 3 2369'FEL 02113106 T)ASfTLH GLV C/O JC CIBPPERFS (0629-3009) SP Explorisbion (Nooks) Completion proposal if losses encountered — solid Page 1 of 1 Schwartz, Guy L (DOA) From: Hoffman, Wilmer [hoffmawj @bp.com] Sent: Wednesday, December 02, 2009 11:28 AM To: Schwartz, Guy L (DOA) Subject: G -30B Pre -rig clarification Attachments: G -30B pre rig proposed.pdf a -P 205-2,0V Guy, Per our conversation this morning, here is clarification on the two items discussed for sundry approval to P &A G- 30B in preparation for the CTD sidetrack of G -30C. 1. The 7" Liner Top Packer at 6,456' failed its lap test at 3 bpm / 2,000 psi indicating we should have injectivity into the 3 -1/2" x 7" Annulus for placing cement. If injectivity is not established, we will need to punch an additional set of holes higher up in the 3 -1/2" tubing to be able to circulate cement into the annulus. 2. No cement will be placed below the CIBP in the 2 -3/8" production liner as the CIBP will be placed above the deployment sleeve effectively isolating the existing perforations. There should be some cement on top of the CIBP left between the CIBP and the cement retainer above it. I am attaching a PDF file that will illustrate the proposed work in red. If you need anything else, don't hesitate in letting me know. WJH Operations Drilling Engineer Coiled Tubing Drilling BP (Exploration) Alaska, Inc. Direct 907.564.4592 Cell 907.250.2601 12/2/2009 TREE = 3" -5M -FMC WELLHEA = MCEVOY SAFt 1 1 t: "" 9 -518" LNK HL*i HAS KNOW N ACTUATOR AXEL_SON G - 3 0 B LEAK tHE REASON FOR THE STRADDLE KB. ELEV = _ 69 .78' COMPLETION' re proposed work BF. ELEV = 39.3 KOP = 3098' ............... Max Angle = 97° @ 10042' Datu MD= 9410' 2201' 3 - 1/2" SSSV OTIS LANDING NIP, ID= 2.750" Datum TVD = 8800' SS O GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80, ID = 12.341" 44714' MD TVD DEV TYPE VLV LATCH PORT DATE 4269 4120 26 JWMURRY DOME RK 16 02/13/06 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 4478' 1 6390 5989 32 McMURRY SO RK 20 02/13/06 Minimum ID = 1.920" @ 9361' TOP OF 2 -3/8" LINER sale' 3 -1 /z" HESXNIP, ID= 2.750 6430' 9 -5/8" X 3-1/2" BKR SAB PKR, ID = 3.25" TOP OF 7" LNR 6456' 7 "LTP faiea j � (3 bpm /2,000 psi MILLOUT WINDOW (G -30A) 6600' - 6645' Tubing punch holes (]£needed due tD no in *ctivJry) 3-1/2"W hipstDck @ - 9,320' " 312 Cementzetaner@ 9,335 r Tubing punch hobs @ - 9,343' 9 -5/8" CSG, 47 #, L -80, ID = 8.681 3 -12 "C 113 @ 9,350' 9354' 3.0" BKR DEPLOY SLV, ID = 2.250" 9381 3-1/2" PA RKER SWS NIP, ID = 2.75" TOP OF 2 -3/8" LNR 9361' 9398 7" X 3 -1/2" BAKER SA BL-3 PKR 9424' 3 -112" HESXNIP, ID = 2.750" B ehkid 9434' 3 -112" 10 PERFORATED PUP C LNR 9444' 3 t /2" HESXNIP, ID = 2.750" P &A (01/03/06) 9447' 9456' 3 -1/2" TTL WLEG _ 3 -1 /2" TBG, 9.2 #, L -80, .D087 bpf, ID = 2.992" 11 9456 9447 ELMD TT LOGGED 08/04/9'1 i 7" LNR, 29#, L-80 bpf, ID = 6.184" 9823 aiuL 1 rw4.n vvnvwvv tUaursl K CMT RAMP /C�_30R{ 95711' _ 9 PERFORATION SUMMARY REF LOG: MCNUCCUGR ON 01/18/06 9709' 2 -6/8" MARKER JOINT TIE -IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 58° @ 9627' Note: Refer to Production DB for historical perf data 10150' 2-3/8" SIZE SPF INTERVAL OPNISQZ DATE (0629/009) 9) CIBP 1- 9/16" 6 9627-9657 0 06/30/09 1 -9/15' 6 9705-9735 0 06/30/09 1 -9/15' 6 10015 - 10045 0 06/29/09 1- 9116" 6 10250 - 10640 C 01/19106 1- 9/16" 6 10680 - 10810 C 01/19106 1- 9/16" 6 10910 - 10960 C 01/19/06 1 -9/15' 6 10990 - 11050 C 01/19/06 1 -9/15' 6 11070 - 11150 C 01/19106 1- 9/16" 6 11360 - 11440 C 01/19/06 1 -9/15' 6 11700 - 11820 C 01/19/06 PBTD 11824' 2 -3/8" LNR, 4.6#, L -80 STL, .0039 bpf, ID = 1 .995" 11860' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08107/86 ORIGINAL COMPLETION WELL: G -30B 07130/95 SIDETRACK (G -30A) PERMIT No: w 205208 01119/06 NORDICI CTDSIDETRACK(G -30B) API No: 50 -029- 21613 -02 01/23/06 JLJ/TLH DRLG DRAFT CORRECTIONS SEC 12, T11 N, R13E, 2519' FNL & 2369' FEL 02/13/06 TWS/TLH 1 GLV Cd0 07/29/09 RMH/PJC I CIBP/PERFS (0629 - 30/09) BP Exploration (Alaska) STATE OF ALASKA ALAS iL AND GAS CONSERVATION COMMIS~ REPORT OF SUNDRY WELL OPERATIONS ~~CEIVED OCT ~ 4 ~~09 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ ( 8$ dn$. Q(11(111S Performed: Alter Casing ~ Pull Tubing~ Pertorate New Pooi ~ Waiver~ Time Extensionp pnchorage Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ^~ Exploratory ^ 205-2080 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ API Number: Anchorage,AK 99519-6612 50-029-21613-02-00 8. Property Designation (Lease Number) : Well Name and Number: ~ ADLO-028280 PBU G-30B 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured ~, 11860 feet Plugs (measured) 10450' 6/29/09 feet true vertical~~ 9028.85 feet Junk (measured) None feet Effective Depth measured 11824 feet Packer (measured) 6430' 9698' true vertical 9028 feet (true verticai) 6094' 8863' Casing Length Size MO ND Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surtace 2684 13-3/8" 72# L-80 SURFACE - 2684 SURFACE - 2684 5380 2670 Intermediate Production 6590 9-5/8" 47# L-80 SURFACE - 6590 SURFACE - 6230 6870 4760 Liner 3064 7"29# L-80 6456 - 9520 6115 - 8928 8160 7020 Liner 2506 2-3/8" 4.6# L-80 9354 - 11860 8837 - 9029 11200 11780 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Verticat depth: _ _ _ _ _ Tubing: (size, grade, measured and true verticai depth) 3-1/2" 9.2# L-80 SURFACE - 9456' SURFACE - 8895' Packers and SSSV (type, measured and true vertical depth) 9-5/8"X3-1/2" BAKER SAB PKR 6430' 6094' 7"X3-1/2" BAKER SABL-3 PKR 9698' 8863' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 434 21282 73 294 Subsequent to operation: 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Weli Operations X Well Status after work: Oil ~ Gas WDSPL GS OR ~ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certity that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble TiUe Data Management Engineer Signature Phone 564-4944 Date 10/14/2009 ~ion Form 10-404 R~ised 7/2009 ;~'~ (1~`~,,~ ~~ ~ ~~' ~,, ^~j ~ ~ Submit Original Only ~ ~ Io•/5-05' G-30B 205-208 PERF OTT~4CHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base G-30B 1/19/06 PER 10,250. 10,640. 9,022.66 9,033.99 G-306 1/19/06 PER 11,700. 11,820. 9,024.64 9,028.41 G-30B 1/19/06 PER 11,070. 11,150. 9,027.25 9,026.2 G-30B 1/19/06 PER 11,360. 11,440. 9,031.76 9,024.32 G-30B 1/19/06 PER 10,910. 10,960. 9,026.58 9,027.68 G-30B 1/19/06 PER 10,680. 10,810. 9,033.29 9,026.95 G-30B 1/19/06 PER 10,990. 11,050. 9,028.32 9,027.88 G-30B 6/29/09 BPS 10,150. 10,155. 9,019.39 9,019.35 G-30B 6/30/09 APF 10,015. 10,045. 9,030.73 9,027.5 G-30B 6/30/09 APF 9,627. 9,657. 8,994.63 9,008.96 G-30B 6/30/09 APF 9,705. 9,735, 9,024.9 9,031.08 G-30B 10/10/09 APF o 9,575. 9,595. 8,962.12 8,975.8 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE / • s ~~ G-30B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1 0/1 0/2009 5*"* WELL SHUT IN AND FREEZE PROTECTED ON ARRIVAL"'* (E- ?LINE PERFORATIONS) i INITIAL T/I/O 1400/0/0. ' RUN 1: HEAD/ERSNVEIGHT/CCUFIRING HEAD/1.56" HSD GUN. TOTAL LENGTH 24' MAX OD 1 11/16" PERFORATE FROM 9585_'-959~' / O ~ T/IA/OA: 1500/0/0 AFTER GUN RUN #1 ~RUN 2: HEAD/ERS/WEIGHT/CCL/FIRING HEAD/1.56" HSD GUN. ~TOTAL LENGTH 24' MAX OD 1 11/16" , PERFORATE FROM 9575'-9585' ~ a ~T/IA/OA: 1550/0/0 AFTER GUN RUN #2 :ALL PERFORATIONS CORRELATED TO SLB MCNL DATED 18-JAN- 2006. ~PAD OPERATOR NOTIFIED OF FINAL VALVE POSITIONS: MASTER:O, 3WING:C, SSV:C, SWAB:C, IA/OA:OTG. 9FINAL T/IA/OA: 1550/0/0. WELL LEFT SHUT-IN. ~"'*JOB COMPLETE**" FLUIDS PUMPED BBLS 1 DIESEL 1 Total STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS ~~~~ ~ + ., ~ ~JR~~ d g 2009 S4:.yYic l.'cE '~J4 i.~"x~v 6JVIIJ. ~JUIIIIi1~~OJ'NI 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~ ~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~_ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~elopment ~ - Exploratory ~ 2o5-2oso ~ 3. Address: P.O. Box 196612 Stratigraphic I`~ Senrice ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21693-02-00 ` 7. KB Elevation (ft): 9. Well Name and Number: 69.78 KB _ PBU G-30B ~ 8. Property Designation: 10. Field/Pool(s): ADLO-028280 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11860 • feet Plugs (measured) 10150' 6/29/09 true vertical 9028.85 , feet Junk (measured) None Effective Depth measured 11824 feet true vertical 9028 ` feet Casing Length Size MD ND Burst Coilapse Conductor 110 20" Surface - 110 Surtace - 110 Surface 2684 13-3/8" 72# I-80 Surface - 2684 Surface - 2684 5380 2670 Production 6590 9-5/8" 47# I-80 SurFace - 6590 Surface - 6230 6870 4760 Liner 3064 7" 29# I-80 6456 - 9520 6115 - 8928 8160 7020 Liner 2506 2-3/8" 4.6# I-80 9354 - 11860 8837 - 9029 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 Surface - 9456' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X3-1/2" BAKER SAB PKR 6430 7"X3-1/2" BAKER SABL-3 PKR 9398' 0 0 0 0 12. Stimulation or cement squeeze summary: s~; ~~y~~~~~~ , ~~ ~~. ~; J~ ~ t~ 2OD~ J1 . .. Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to wel~ operation: 315 20952 9 437 Subsequent to operation; 447 21742 447 233 14. Attachments: 15. Wel~ Class after oroposed work: Copies of Logs and Surveys Run Exploratory I~ Development I~- - Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~- Gas ~` WAG I~ GINJ C~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/9/2009 Form 10-404 R ised 04/2006 ~ Submit Original Only ~ "~ ~~ ~UE~ ~ ~ Z~d9 ~~~ G-30B 205-208 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas De pth Top Meas Depth Base Tvd De th Top Tvd Depth Base G-30B 1/19/06 PER 10,250. 10,640. 9,022.66 9,033.99 G-306 1/19/06 PER 11,700. 11,820. 9,024.64 9,028.41 G-306 1/19/06 PER ~ C~c~c~ S 11,070. 11,150. 9,027.25 9,026.2 G-30B 1/19/06 PER 11,360. 11,440. 9,031.76 9,024.32 G-306 1/19/06 PER 10,910. 10,960. 9,026.58 9,027.68 G-30B 1/19/06 PER ~.~ 10,680. 10,810. 9,033.29 9,026.95 G-30B 1/19/06 PER 10,990. 11,050. 9,028.32 9,027.88 G-30B 6/29/09 BPS ~ 10,150. 10,155. 9,019.39 9,019.35 G-30B 6/29/09 APF 10,015. 10,045. 9,030.73 9,027.5 G-306 6/30/09 APF 9,705. 9,735. 9,024.9 9,031.08 G-306 6/30/09 APF 9,627. 9,657. 8,994.63 9,008.96 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRiDGE PLUG Pt1LLED SL SLOTTED LINER BPS BRIDGE PLUG SET ' SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ L J • • G-30B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 1 diesel 1 Total I-~~ DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2052080 Well Name/No. PRUDHOE BAY UNIT G-306 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21613-02-00 MD 11860 TVD 9029 Completion Date 1/19/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Y- DATA INFORMATION Types Electric or Other Logs Run: MWD / NGP GR / ROP, MGR /CCL /CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~E ' D Asc ~ D~" ectional Survey ~ Li 0 11860 Open rC~' D s 13793VGamma Ray 8914 11833 Open 3!912006 GR ROP wog Sonic 2 Blu 1 8600 11800 Case 3/3/2006 MEM GR/CCL/CNL 18-Jan- 2006 C ,Pds~1,'S 13839 .~6`onic 2 1 8600 11800 Case 3/3/2006 MEM GR/CCL/CNL 18-Jan- ' '~ ~ ~ 2006 C tei: ~14439 duction/Resistivity 8914 11863 Open 1 /2 912 0 0 7 LIS Veri, GR, ROP w/Graphics Well C ores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts ADDITIONAL INFORM TION ~, Well Cored? ~ Daily History Received? \/ N Chips Received? ~1LLPd~- Formation Tops Y / Analysis l~.Ql- Received? Comments: Compliance Reviewed By: Date: ~~ • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: C-23B, C-41A_PB1, D-27A, G-30B, J-27A, K-04B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd. , Anchorage, AK 99518 C-23B: X63 -~C~ '~ I `~~' ~'-I 1 Digital Log Images: 1 CD Rom 50-029-20775-02 C-41A PB1: ~U~/- l$t~f ~ 1~~'~~~3 Digital Log Images: 1 CD Rom 50-029-22385-O1, 70 D-27A: c~(~5 - ~`~3 ~ ~ `~~1~1 C7 Digital Log Images: 1 CD Rom 50-029-21543-00 G-30B: 2dS ~av~ ~ 1L1~13`~ Digital Log Images: 1 CD Rom 50-029-21613-02 J-27A: ac,a -2~U ~ 1~-1'!3~ Digital Log Images: 1 CD Rom 50-029-21733-01 K-04B: ~C~~ _ ~ ~~ ~ / ~d~/~/ ~ Digital Log Images: 1 CD Rom 50-029-21023-02 '~~ • • WELL LOG TRANSMITTAL To: State of Alaska February 27, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: G-34B, AK-MW-4148159 1 LDWG formatted Disc with verification listing. API#: 50-029-21613-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMTTTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: (~ ~ ~ Signed: STATE OF ALASKA ALASK, . LAND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 2oAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ®Developme n0~~z~~oratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 1/19/2006 12. Permit to Drill Number 205-208 3. Address:. P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/10/2006 13. API Number 50-029-21613-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/16/2006 14. Well Name and Number: PBU G-30B 2519 FNL, 2369 FEL, SEC. 12, T11 N, R13E, UM Top of Productive Horizon: 2772' FNL, 203' FEL, SEC. 12, T11 N, R13E, UM 8. KB Elevation (ft): 69.78' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 2437' FNL, 2141' FEL, SEC. 12, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 11824 + 9028 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 657857 y- 5969122 Zone- ASP4 10. Total Depth (MD+TVD) 11860 + 9029 Ft 16. Property Designation: ADL 028280 _ ___ __ _ TPI: x-_ 660028 y- 5968914 Zone- ASP4 Total Depth: x- 658082 Y- 5969209 Zone- ASP4 11 • Depth where SSSV set None MD 17. Land Use Permit: _______._.__._______ ___.______________._. -------.--.------- 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / NGP GR / ROP, MGR / CCL / CNL 2. ASING, INER AND EMENTING ECORD CASING ETTINQ EPTH MD ETTIN(i EPTH TVD FfOLE MOUNT`; SIZE WT. PER FT. C~flADE OP , ' TTOM OP - - OTTOM SIZE CEMENTING RECORD PULLED 20" Conductor Surface 110' Surface 110' 30" cu ds Concrete 13-3/8" 72# L-80 Surface 2684' Surface 2684' 17-1/2" 250 cu ft PF'E', 460 cu ft PF 9-5/8" 47# L-80 Surface 6590' Surface 6230' 12-1/4" 75 cu ft Class'G' 7" 29# L-80 6456' 9520' 6115' 8928' 8-1/2" 75 cu ft Class'G' 176 cu ft Class'G' 2-3/8" 4.6# L-80 9354' 11860' 8837 9029' 3" 101 cu ft Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TueIN~ RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 9456' 6430' & 9398' MD ND MD TVD 10250' -10640' 9023' - 9034' 10680' - 10810' 9033' - 9027 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10910' - 10960' 9027' - 9028' 10990' 11050' 9028' 9028' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 11070' - 11150' 9027' - 9026' 2500' Freeze Protect w/ 14 Bbls of 60/40 McOH 11360' - 11440' 9032'- 9024' 11700' - 11820' 9025' - 9028' 26• PRODUCTION TEST Date First Production: February 17, 2006 Method of Operation (Flowing, Gas. Lift, etc.): Flowing Date of Test 2/23/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 373 GAS'MCF 726 WATER-BBL 7 CHOKE SIZE 95.77° GAS-OIL RATIO 1,946 Flow Tubing Press. 20 Casing Pressure 1,460 CALCULATED 24-HOUR RATE OIL-BBL 2,238 GAS-MCF 4,354 WATER-BBL 42 OIL GRAVITY-API (CORK) 24.8 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~ ~p U / .. ~ ~~~. ~~ 0 706 ~/ #~~~~ ~.~~~ ~' 9001 ~ ~ t~~l~ :.~.~~ Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~t~(~II~UED ON REVERSE SIDE RECEIVED l~A~ 0 1 2006 AI ft 1..~ 28. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List Intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 1 B 9599' 8978' None Zone 1 A / TDF 9727' 9030' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date - / °~~~ PBU G-30B 205-208 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. orii~ing Engineer: Ted Stagg, 564-4694 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Page 1 of 11 Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: ell Name: e: Name: ~ From - To G-30 G-30 REENTE NORDIC NORDIC .Hours R+COM CALIS 1 ~, Task ~ PLET TA Code ~ E i NPT ~ Start Rig Rig , Phase Spud Date: 7/23/1986 : 1/6/2006 End: 1/19/2006 Release: 1/20/2006 Number: N1 Description of Operations 1/7/2006 00:00 - 03:30 3.50 BOPSU P PRE ACCEPT RIG AT 0000 HRS, 01/07/06. NU BOPE. Spot tanks and trailers. R/U hardline to frac tank. Grease tree. 03:30 - 11:00 7.50 BOPSU N SFAL PRE Trouble shoot swap and master. Grease test regrease cycle valve etc. Pressure /Function test BOPE. 11:00 - 14:00 3.00 BOPSU P PRE AOGCC Test Witness waived by Chuck Scheeve Continue with general rig up. Complete Reel swap install hard line in reel . 14:00 - 16:00 2.00 BOPSU N SFAL PRE Repair Annular Preventer. It failed to test, replaced inner seals. Changed out BOPE fluid. 16:00 - 19:00 3.00 BOPSU P PRE Continue testing BOP. Send BOP test report to AOGCC. 19:00 - 21:00 .2.00 RIGU P PRE Pull 2" coil to injecter head. Stab pipe. 21:00 - 00:00 3.00 RIGU P PRE Weld on CTC using rig welder. Pull /pressure test CTC. Fill coil with Biozan KCL water. Press test inner reel valve. Circ. Dart. Dart on seat at 40.3 bbls. Open well. Well was dead. 1/8/2006 00:00 - 02:00 2.00 STWHIP P WEXIT M/U BHA #1, 2.74" Pilot hole mill, 1.75 deg motor and Sperry MWD with BOT MHA. OAL = 62.51'. 02:00 - 04:15 225 STWHIP P WEXIT RIH with pilot hole MWD BHA. SHT at 3000'. Orienter OK. MWD OK. RIH to 9200'. 04:15 - 08:30 4.25 STWHIP P WEXIT Log GR tie-in inside 3-1/2" tubing. Correct +45'. Resolve tie-in issues and verify tie-in log is depth corrected. 08:30 - 09:00 0.50 STWHIP P WEXIT RIH .Orient to high side. Tag cement at 9452' 09:00 - 14:20 5.33 STWHIP P WEXIT Drill pilot hole in cement plug. Drilling to high side at 1.74 bpm 3400 psi, FS= 3200 psi, PU Wt 30K. ROP 16. Drill to 9513 beginning of ramp. 14:20 - 14:36 0.27 STWHIP P WEXIT PU above 9450 to orient to low side. 14:36 - 15:20 0.73 STWHIP P WEXIT Drill cement ramp 1.64 bpm at 3360 psi. from 9513 to 9519.5. Motor work increase and Tool face change. Ramp in contact with low side of 7" casing. PU 15' and retag. POH for window mill. 15:20 - 16:45 1.42 STWHIP P WEXIT POH to surface. 16:45 - 17:30 0.75 STWHIP P WEXIT BHA swap pilot milling assy for window milling assy. 17:30 - 19:30 2.00 STWHIP P WEXIT RIH with window milling BHA #2 with 2.5 deg motor. RIH to 9400'. 19:30 - 20:00 0.50 STWHIP P WEXIT Orient TF to 130R. 20:00 - 20:20 0.33 STWHIP P WEXIT RIH to bottom. Tag 3 times at 9517', no depth correction. Pick up to tie-in and confirm depth. 20:20 - 21:00 0.67 STWHIP P WEXIT Log GR tie-in at 8942'. Added 5.5 ft to CTD. 21:00 - 21:30 0.50 STWHIP P WEXIT RIH. Tag TD at 9522'. Pick up to 9510'. RIH to 9518' and start pump. Ease down to 9520.5'. Park and had 145E TF. 21:30 - 21:50 0.33 STWHIP P WEXIT Pick up to 9450' and orient TF to 140R. 21:50 - 22:00 0.17 STWHIP P WEXIT RIH to 9518', start pump and RIH to 9520.5'. TF = 170R. Pick up 1 ft to reduce down force. 22:00 - 00:00 2.00 STWHIP P WEXIT Mill 2.74" window as per procedure. 1.6 bpm, 0 WOB, 3150 psi, 175R. Procedure takes 3 hours to mill first foot. Flagged coil at 9519.5 ft. 1/9/2006 00:00 - 02:30 2.50 STWHIP P WEXIT Milling 2.74" window, 1.65 bpm, 2500 psi, 0 wob, 175R, Milled to 9521'. Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: REENTER+COMPLETE Start: 1/6/2006 End: 1/19/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ;Hours Task Code', NPT Phase ~ Description of Operations 1/9/2006 02:30 -04:45 2.25 STWHIP P WEXIT Milling 2.74" window, 1.65 bpm, 2000 psi, 2500 wob, 175R, Milled to 9523'. Starting to stack weight. 04:45 - 12:30 7.75 STWHIP P WEXIT Milling 2.74" window 1.6 bpm 2200 psi, 3500 wob 175R Stacking weight. Pick up 10 ft. 6K overpull. Up wt = 36K, RIH, Dwn wt = 17K. Drill to 9526 unable to drill. No motor work . Decide to POH. 12:30 - 14:00 1.50 STWHIP P WEXIT POH Snag GLM at 6390. Continue to POH to surface. 14:00 - 16:30 2.50 STWHIP P WEXIT BHA swap Mill NoGo 2.72" gauge ring. Center of mill worn. Make up HC 331 pabarolic pilot mill ,string mill, 1.75 motor & new MWD probe (limiting out battery hours) 16:30 - 18:30 2.00 STWHIP P WEXIT RIH. 18:30 - 19:00 0.50 STWHIP P WEXIT Log GR tie-in. Added 7' to CTD. 19:00 - 22:30 3.50 STWHIP P WEXIT RIH with 170E TF. Ream window starting at 9521'. Several stalls. Orient around to 175R. Several stalls getting to 9524'. Ream window area down to 9526'. 22:30 - 00:00 1.50 STWHIP P WEXIT Mill new formation, 1.65 bpm, 2500 psi, 175R TF, 12 fph, full returns. Milled to 9535'. 1/10/2006 00:00 - 01:00 1.00 STWHIP P WEXIT Ream window up and down 3 times. Swap well to FloPro while reaming. RIH clean thru window with no pump. Back ream up thru window clean. 01:00 - 03:00 2.00 STWHIP P WEXIT POH to surface while circ at 1.6 bpm. Flag coil at 9200' EOP. 03:00 - 03:15 0.25 STWHIP P WEXIT Lay out milling BHA. Mill still at full gauge [2.74" no go]. String reamer at 2.73" no go. 03:15 - 03:50 0.58 DRILL P PROD1 M/U BHA #4 with 2.8 deg BHI X-treme Motor and re-built HCC 2.7 X 3.0" bicenter bit #4. OAL = 59.92'. 03:50 - 05:50 2.00 DRILL P PROD1 RIH with build BHA. SHT tools at 3000'. OK. RIH to flag. Added 6' CTD to correct to flag. 05:50 - 06:10 0.33 DRILL P PROD1 Orient TF to 150R. 06:10 - 06:15 0.08 DRILL P PROD1 RIH thru window. Tag bottom at 9533'. Add 2 ft to CTD to correct depth to 9535'. 06:15 - 06:30 0.25 DRILL P PROD1 Orient TF from 105E to 135R. 06:30 - 12:30 6.00 DRILL P PROD1 Directionally drill 1.67/1.68 bpm ~ 3350 psi, FS 3000 psi. TF 135R 23K Up, 19K Dn , CT Wt 13K. 12:30 - 12:45 0.25 DRILL P PRODi Orient TF to 80R. 12:45 - 14:45 2.00 DRILL P PROD1 Drilling turn /build section, 1.7/1.7 bpm, 3050/3200 psi, 75R, 40 fph, Drilled to 9680'. 14:45 - 15:15 0.50 DRILL P PROD1 Drilling turn /build section, 1.7/1.7 bpm, 3050/3200 psi, 80R, 40 fph, Drilled to 9700'. 15:15 - 15:30 0.25 DRILL P PROD1 Wiper trip to window. 15:30 - 16:45 1.25 DRILL P PROD1 Drilling turn /build section, 1.7/1.7 bpm, 3050/3200 psi, 80R, 80 fph, Drilled to 9790'. 16:45 - 17:15 0.50 DRILL P PROD1 Drilling turn section, 1.7/1.7 bpm, 3050/3200 psi, 80R, 100 fph, Landed at 90 deg incl, at 8965 ft TVDSS at 9790' MD. Drilled to 9818'. 17:15 - 17:45 0.50 DRILL P PROD1 Drilling turn section, 1.7/1.7 bpm, 3050/3200 psi, 80R, 100 fph, Drilled to 9851 ft. 17:45 - 19:15 1.50 DRILL P PROD1 POH for Lateral BHA. 19:15 - 20:00 0.75 DRILL P PROD1 OOH. S/B injector. Check motor & orienter - OK. Check bit OK (1/1/I). L/D MWD guts. 20:00 - 20:30 0.50 DRILL N RREP PROD1 Observe hydraulic oil leakage from annular BOP cap. Suspect annular cap seals must have warmed-up & softened enough to allow leak. Inspect cap & retighten. Pressure annular to Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Operations Summary Report Page 3 of 11 Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: REENTER+COMPLETE Start: 1/6/2006 End: 1/19!2006 Contractor Name: NORDIC CALISTA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Phase Description of Operations --- ~_ 'Task Code NPT - i- ___ - -- - - - -- -- 1/10/2006 20:00 - 20:30 0.50 DRILL N RREP PROD1 1750psi from koomey & observe no further leaks. 20:30 - 21:15 0.75 DRILL P PROD1 M/U & lock tite build section BHA #5 with same HC DOSTRWD 2.7" x 3" bicenter bit, 0.8deg BHI Xtreme motor, Sperry GR-DIR MWD with new guts & battery, orienter & BKR MHA (OAL = 59.92'). Scribe tools & M/U injector. 21:15 - 23:15 2.00 DRILL P PROD1 RIH drilling BHA #5. SHT MWD &orienter C~ 3000' - OK. Continue RIH to 8950'. 23:15 - 00:00 0.75 DRILL P PROD1 Log down GR & tie-into TSAD marker @ 8945' -add 8' to CTD. 1/11/2006 00:00 - 00:30 0.50 DRILL P PRODi Orient TF to LS. 00:30 - 01:00 0.50 DRILL P PROD1 RIH dry & tag BOW 3x C 9525'. Stack bit on BOW. Roll pump & pop thru into OH. Continue RIH clean while orienting TF. Tag TD C~3 9853'. Bring on pumps. TF @ 18R. Freespin = 1.6bpm/3070psi. Up wt = 27k. Run-in wt = 15.5k. PVT = 296bb1s. 01:00 - 01:10 0.17 DRILL P PROD1 Orient TF to 80R. 01:10 - 01:45 0.58 DRILL P PROD1 Drill to 9912' with 95R TF, 1.6/1.6bpm, 3070/3300psi, 3k WOB & 100fph ave ROP. 01:45 - 02:30 0.75 DRILL P PRODi Orient on btm -only getting 10degs clicks. PUH to 9850' & orient TF to 60R. 02:30 - 03:15 0.75 DRILL P PROD1 Drill to 10000' with 60-75R TF, 1.6/1.6bpm, 3100/3300psi, 3k WOB & 100fph ave ROP. 03:15 - 03:45 0.50 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 03:45 -04:00 0.25 DRILL P PROD1 Orient TF to 50R. 04:00 - 04:20 0.33 DRILL P PROD1 Orient & drill to 10042' with 60-75R TF, 1.6/1.6bpm, 3100/3300psi, 3k WOB & 60fph ave ROP. 04:20 - 04:25 0.08 DRILL P PROD1 Orient TF to 100R. 04:25 - 05:00 0.58 DRILL P PROD1 Drill to 10074' with 130R TF, 1.6/1.6bpm, 3100/3300psi, 4k WOB & 80fph ave ROP. Stacking wt. 05:00 - 05:15 0.25 DRILL P PROD1 Short 100' wiper. 05:15 - 06:00 0.75 DRILL P PROD1 Orient & drill to 10100' with 140-170R TF, 1.6/1.6bpm, 3100/3300psi, 4k WOB & 80fph ave ROP. 06:00 - 07:00 1.00 DRILL P PROD1 Drilling lateral in Z1A. 1.8 bpm, 3400-3900 psi, 140R, 92 deg incl, 60 fph, Landed well at 8965' TVDSS, found top of HOT at 8963' SS. Try to hold 8958'SS. Drilled to 10150'. 07:00 - 07:30 0.50 DRILL P PROD1 Wiper trip to window. R{H. Clean hole. 07:30 - 09:00 1.50 DRILL P PROD1 Drilling lateral in Z1A. 1.8 bpm, 3400-3900 psi, 150R, 92 deg incl, 60 fph, Drilled to 10225'. 09:00 - 10:15 1.25 DRILL P PRODi Drilling lateral in Z1A. 1.8 bpm, 3400-3900 psi, 150R, 89 deg incl, 60 fph, Drilled to 10300'. 10:15 - 11:00 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 11:00 - 12:50 1.83 DRILL P PROD1 Drilling lateral in Z1A. 1.7 bpm, 3300-3900 psi, 120R, 88 deg incl, 110 fph, Drilled to 10450'. 12:50 - 13:45 0.92 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 13:45 - 15:45 2.00 DRILL P PROD1 Drilling lateral in Z1A. 1.7 bpm, 3300-3900 psi, 55L, 88 deg incl, 120 fph, Drilled to 10,600'. 15:45 - 16:15 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. 16:15 - 16:50 0.58 DRILL P PROD1 Log GR tie-in at 9550'. Added 4.5' to CTD. 16:50 - 17:20 0.50 DRILL P PROD1 RIH clean to bottom, tag at 10604'. 17:20 - 18:30 1.17 DRILL P PROD1 Drilling lateral in Z1A. 1.7 bpm, 3300-3900 psi, 30L, 88 deg incl, 60 fph, Drilled to 10,666'. 18:30 - 18:45 0.25 DRILL P PROD1 Attempt to orient to 80L - TF rolling hard right. Freespin = 1.7bpm/3350psi. Up wt = 28k. Run-in wt = 15k. PVT = Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Operations Summary Report Page 4 of 11 Legal Well Name: G-30 Common WeII Name: G-30 Spud Date: 7/23/1986 Event Name: REENTER+COMPLETE Start: 1/6/2006 End: 1/19/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 I Date From - To Hours Task Code NPT Phase Description of Operations _ ~, 1 _ ', ___ - - - -_ _ _ _ __ 1/11/2006 18:30 - 18:45 0.25 DRILL P PROD1 224bb1s. 18:45 - 18:50 0.08 DRILL P PROD1 Drill to 10677' with 65L to HS TF, 1.7/1.7bpm, 3350/3450psi, 3k WOB & 200fph ave ROP. Getting 60degs reactive. Drilling hi-porous sand. 18:50 - 19:45 0.92 DRILL P PROD1 Attempt to orient to 80L - TF erratic & rolling hard right. 19:45 - 19:50 0.08 DRILL P PROD1 Drill to 10695' with 75L to 45R TF, 1.7/1.7bpm, 3350/3600psi, 5k WOB & 350fph ave ROP. 19:50 - 20:15 0.42 DRILL P PROD1 Attempt to orient to 80L - TF erratic & rolling hard right. 20:15 - 20:20 0.08 DRILL P PROD1 Control drill to 10698' with 160E TF, 1.7/1.7bpm, 3350/3500psi, 1k WOB & 90fph ave ROP. 20:20 - 21:00 0.67 DRILL P PROD1 Orient 4 clicks & drill to 10758' with 100E to 80L TF, 1.8/1.8bpm, 3300/3750psi, 4k WOB & 65fph ave ROP. 21:00 - 21:15 0.25 DRILL P PROD1 Short 100' wiper. Meanwhile swap well to new flopro mud with 3% L-T, 12ppb K-G & 45k LSRV. 21:15 - 21:30 0.25 DRILL P PROD1 Drill to 10800' with 95L - 115E TF, 1.8/1.8bpm, 3300/3900psi, 7k WOB & 150fph ave ROP. Circulate new mud to bit. 21:30 - 22:10 0.67 DRILL N STUC PROD1 Commence wiper trip & pull heavy C~3 10773'. Got differentially stuck. Work CT up to 60k without success. Circulate new mud to surface. S/D pumps & relax CT for 15 minutes. Stack down max wt & pull CT free with 60k. 22:10 - 23:15 1.08 DRILL P PROD1 Continue wiping up hole clean to the window. RBIH clean to btm. 23:15 - 23:45 0.50 DRILL P PRODi Orient TF around to 80L. 23:45 - 00:00 0.25 DRILL P PROD1 Drill to 10820' with 95-75L TF, 1.7/1.7bpm, 3050/3350psi, 4k WOB & 150fph ave ROP. 1/12/2006 00:00 - 01:15 1.25 DRILL P PROD1 Drill to 10918' with 95-75L TF, 1.7/1.7bpm, 3050/3400psi, 5k WOB & 90fph ave ROP. Sticky & pulling heavy on btm. 01:15 - 01:25 0.17 DRILL P PROD1 Short 100' wiper. 01:25 - 01:35 0.17 DRILL P PROD1 Drill to 10952' with 90L TF, 1.7/1.7bpm, 3050/3400psi, 3k WOB & 140fph ave ROP. 01:35 - 03:15 1.67 DRILL P PROD1 Wiper trip clean to the window. RBIH clean to btm. 03:15 - 04:15 1.00 DRILL P PRODi Drill to 11042' with 75-60L TF, 1.7/1.7bpm, 3050/3400psi, 5k WOB & 100fph ave ROP. 04:15 - 04:45 0.50 DRILL P PRODi Orient TF around to 80L. Sticky & pulling heavy on btm. 04:45 - 05:00 0.25 DRILL P PROD1 Drill to 11047' with 80L TF, 1.7/1.7bpm, 3050/3400psi, 8k WOB & 20fph ave ROP. Not getting much motorwork -suspect bit balling in shale stringer. 05:00 - 05:10 0.17 DRILL P PRODi Short 100' wiper to unball bit. 05:10 - 05:50 0.67 DRILL P PROD1 Ease in & drill to 11100' with 80L TF, 1.7/1.7bpm, 3050/3400psi, 8k WOB & 120fph ave ROP. 05:50 - 06:50 1.00 DRILL P PROD1 Wiper trip to window. 06:50 - 07:30 0.67 DRILL P PROD1 Log GR tie-in at 9554'. Pulser failed. No data. Surge pumps, RIH to lateral. No Data. 07:30 - 08:30 1.00 DRILL N DFAL PROD1 POH for failed pulser. No data. Pull thru window clean. POH. 08:30 - 10:15 1.75 DRILL N SFAL PRODi Bottom part of injecter head skate failed [8" x 2" thick metal plate, split in half]. Stopped POH and secured coil. Removed lower broken skate. 10:15 - 12:15 2.00 DRILL N SFAL PRODi POH at 30 fpm, using upper and middle chain traction pressure. No damage to coil. No problem while POH. 12:15 - 13:00 0.75 DRILL N SFAL PROD1 UO BHA. 13:00 - 13:15 0.25 DRILL N SFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for removing guide arch, chains and skate on injecter Printed: 1!2312006 1:06:20 PM BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: REENTER+COMPLE TE Start: 1/6/2006 End: 1/19/2006 Contractor Name: NORDIC CALIS TA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 I Date From - To Hours Task I Cod e ~, NPT Phase Description of Operations 1/12/2006 13:00 - 13:15 0.25 DRILL N SFAL PRODi head. 13:15 - 2i :00 7.75 DRILL N SFAL PRODi Remove guide arch, pull chains, remove broken skate, install new skate. Roll chains & function test skates - OK. 21:00 - 21:15 0.25 DRILL N SFAL PROD1 Held PJSM & HA/HM for P/U the injector, M/U the gooseneck & stabbing CT. 21:15 - 00:00 2.75 DRILL N SFAL PROD1 P/U the injector & M/U the gooseneck. 1/13/2006 00:00 - 02:00 2.00 DRILL N SFAL PROD1 R/U & stab CT into injector head. 02:00 - 03:15 1.25 DRILL N SFAL PROD1 R/U & cut 18' of CT. GBR weld-on CTC. Pull test to 35k & pressure test to 3500psi - OK. 03:15 - 04:15 1.00 DRILL N DFAL PROD1 M/U & lock tite build section BHA #6 with a rebuid HC 04:15 - 06:30 2.25 DRILL N DFAL PROD1 06:30 - 07:00 0.50 DRILL P PROD1 07:00 - 08:15 1.25 DRILL P PROD1 08:15 -09:30 1.25 DRILL P PROD1 09:30 - 10:30 I 1.001 DRILL I P I I PROD1 10:30 - 13:15 2.75 DRILL P PROD1 13:15 - 13:45 0.50 DRILL P PROD1 13:45 - 14:00 0.25 DRILL P PROD1 14:00 - 15:45 1.75 DRILL P PROD1 15:45 - 18:50 3.08 DRILL P PROD1 18:50 - 19:05 0.25 DRILL P PRODi 19:05 - 19:15 0.17 DRILL P PROD1 19:15 - 19:30 0.25 DRILL P PROD1 19:30 - 21:15 1.75 DRILL P PROD1 21:15 - 21:45 0.50 DRILL P PROD1 21:45 - 22:15 0.50 DRILL P PROD1 22:15 - 22:30 0.25 DRILL P PROD1 22:30 - 23:40 1.17 DRILL P PROD1 23:40 - 00:00 0.33 DRILL P PROD1 1/14/2006 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 01:15 0.50 DRILL P PROD1 01:15 - 02:40 1.42 DRILL P PROD1 DOSTRW D 2.7" x 3" bicenter bit, 0.8deg BHI Xtreme motor, Sperry GR-DIR MWD orienter & BKR MHA (OAL = 59.92'). Scribe tools & M!U injector. RIH drilling BHA #6. SHT MWD &orienter @ 3000' - OK. Continue RIH. RIH thru window clean. Log GR tie-in below window. Added 4 ft to CTD. RIH to bottom and tag at 11,112". Drill Zi B lateral, 1.7 / 1.7 bpm, 3250 -3800 psi, 90L, 7K wob, Drilled to 11,166'. Drill Zi B lateral, 1.7 / 1.7 bpm, 3250 -3800 psi, 60L, 7K wob, Stacking weight. Not able to drill ahead or get motor work. Drilled to 11,188'. Wiper trip to window. Clean hole. RIH to bottom. Clean hole. Drill Zi B lateral, 1.7 / 1.7 bpm, 3250 -3300 psi, 60L, Stacking full weight with no motor work in sticky shale, same TVD as shale at 10060', acting the same. Orient TF to low side to get below shale. Drill Z1 B lateral, 1.7 / 1.7 bpm, 3250 -3900 psi, 20L, stacking weight, add 2 dums of lubetex. Slow drilling in shales, fast drilling in sand. Drilled to 11,260'. Drill Z1 B lateral, 1.7 / 1.7 bpm, 3250 -3900 psi, 20L, stacking wt in shale. Grind to 11323' & break into sand. Drill to 11337' with 10L TF, 1.7/1.7bpm, 3250/3500psi, 4k WOB & 110fph ave ROP. Orient TF around to 100L. Drill to 11350' with 110E TF, 1.7/1.7bpm, 3250/3500psi, 5k WOB & 50fph ave ROP. Wiper trip clean to the window. RBIH clean to btm. Orient TF to 90R. Up wt = 27k. Run-In wt = 8.5k. Drill to 11418' with 90-110R TF, 1.7/1.7bpm, 3500/3800psi, 5k WOB & 200fph ave ROP. Short 100' wiper. Drill to 11435' with 120R TF, 1.7/1.7bpm, 3500/3800psi, 5k WOB & 120fph ave ROP. Orient 2 clicks & drill to 11445' with 1658 TF, 1.6/1.6bpm, 3300/3600psi, 8k WOB & 5fph ave ROP. Grind on with no progress. Orient 7F around to 110R. Grind on @ 11445'. Meanwhile swap well to new flopro mud with 3% L-T, 12ppb K-G & 45k LSRV. Break into sand & drill to Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: REENTER+COMPLETE Start:. 1/6/2006 End: 1/19/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ~i From - To .Hours ' NPT -~ l -I; Task Code' Phase 1/14/2006 01:15 - 02:40 1.42 DRILL P PROD1 02:40 - 03:00 0.33 DRILL P PROD1 03:00 - 04:00 1.00 DRILL P PROD1 04:00 - 04:15 0.25 DRILL P PROD1 04:15 - 04:45 0.50 DRILL P PROD1 04:45 - 05:50 1.08 DRILL P PROD1 05:50 - 06:30 0.67 DRILL P PROD1 06:30 - 08:30 2.00 DRILL P PROD1 08:30 - 10:00 1.50 DRILL P PROD1 10:00 - 10:30 0.50 BOPSU P PROD1 10:30 - 13:45 3.25 DRILL N HMAN PROD1 13:45 - 14:15 0.50 DRILL N HMAN PROD1 14:15 - 14:35 0.33 DRILL N HMAN PROD1 14:35 - 15:00 0.42 DRILL N HMAN PROD1 15:00 - 15:30 0.50 DRILL N HMAN PROD1 15:30 - 16:30 1.00 DRILL N HMAN PROD1 16:30 - 18:30 I 2.001 DRILL I N I HMAN I PROD1 18:30 - 19:30 1.00 DRILL N HMAN PROD1 19:30 - 19:45 0.25 DRILL P PROD1 19:45 - 20:00 0.25 DRILL P PROD1 20:00 - 20:30 I 0.501 DRILL I P I I PROD1 20:30 - 20:45 I 0.251 DRILL I P I I PROD1 20:45 - 22:25 1.67 DRILL P PROD1 22:25 - 23:15 0.83 DRILL P PROD1 23:15 - 00:00 I 0.751 DRILL I P I I PROD1 1/15/2006 00:00 - 01:15 1.25 DRILL P PROD1 01:15 - 01:45 0.50 DRILL P PRODi Description of Operations 11456'. Orient TF around to 130R. Drill to 11496' with 130-150R TF, 1.65l1.65bpm, 3000l3200psi, 2k WOB & 50fph ave BOP. Getting erratic TF. Orient TF around to 130R. Drill to 11525' with 140-LS TF, 1.65/1.65bpm, 3000/3200psi, 2k WOB & 50fph ave BOP. Getting up to 180degs reactive. Having difficulty dropping angle. Motor is building angle even on LS. Currently C~3 +/-8947'sstvd. May need to POOH for bigger bend motor. Wiper trip to the window. Had 10k O/pull Cr3 11055'. Log GR tie-in. Meanwhile consult with ANG & decide to POOH to P/U a bigger bend motor & agitator. POH for higher bend motor and agitator. Adjust motor to 1.5 deg bend, Re-run bit, place agitator above motor, change out MWD probe and MHA. OAL = 66.0'. Perform weekly function test on BOPE. RIH to window. Stack wt in window with 145E TF. No pump. Orient TF to 160R. Try to go thru window at 160R, 180 deg and 160L. Try different speeds no luck. Log GR tie-in in 3-1/2" tubing. Added 4 ft CTD. Orient TF around. Try to go thru window at 100R, 120R, 140R, 160R, 180R, and 140L. No luck. Tryed different speads and minimum pump to root over bit. No luck. POH to check BHA and set motor at 1.1 deg bend. Circ. in 10 bbl water while POH for cutting coil. OOH. Observe wrong input of MW D internal & external offset data in Sperry surface computer which placed the TFS 70degs off. S/B injector. Check motor &orienter - OK. Check bit - OK (1/1/I). Reset motor bend to 1.3degs & scribe tools. Held PJSM for cutting CT. R/U hydraulic cutter & cut 150' of CT. Have 14792' of CT left on the reel. Behead & weld-on SLB CTC. Pull test to 35k & pressure test to 3500psi - OK. M/U & lock tite build section BHA #8 with same rebuild HC DOSTRWD 2.7" x 3" bicenter bit, 1.3deg BHI Xtreme motor, Agitator, Sperry GR-DIR MWD orienter & BKR MHA (OAL = 66'). M/U injector. RIH drilling BHA #8. SHT MWD &orienter C~3 3000' - OK. Continue RIH to 8945'. Log down GR & tie-into TSAD marker @ 8945' ~ add 3.5' to CTD. Check TF - C~ 158R. S/D pumps. RIH dry & tag BOW 3x C~3 9525'. Stack bit & pop thru into OH. Continue RIH clean. Continue RIH. Observe wt bobble ~ 11050'. Backream area clean & continue RIH. Set down C 11262' & 11445' shales. Backream/ream shales with as drilled TF. Tag TD @ 11534'. Bring on pumps. TF C~J HS. Freespin = 1.6bpm/3050psi. Up wt = 23k. Run-in wt = 9k. PVT = 316bb1s. Orient TF around to 100L. TF roll to 135R. Orient 1 click to Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Page 7 of 1 ~ Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: REENTER+COMPLETE Start: 1/6/2006 End: 1/19/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 Date .From - To I Hours Task ;Code NPT Phase I Description of Operations 1/15/2006 01:15 - 01:45 0.50 DRILL P PROD1 170R. 01:45 - 02:00 0.25 DRILL P PRODi Drill to 11544' with 160R TF, 1.65/1.65bpm, 3050/3125psi, 2k WOB & 75fph ave BOP. 02:00 - 02:30 0.50 DRILL P PROD1 Orient 1 click & drill to 11560' with LS TF, 1.65/1.65bpm, 3050/3125psi, 4k WOB & 65fph ave BOP. Observe CT pressure fluctuations. 02:30 - 03:30 1.00 DRILL P PRODi Orient 1 click & drill to 11579' with 155-170L TF, 1.65/1.65bpm, 2800/2900psi, 16k WOB (-7k CT wt) & <10fph ave BOP. Swap mud pumps & observe abnormally low CT pressure - 2500psi 1.7bpm. Decide to POOH to inspect BHA. 03:30 - 04:20 0.83 DRILL N DFAL PROD1 POOH to inspect BHA. Pull thru window & observe ca. 3/8" CT pinhole @ 9459'. 04:20 - 04:30 0.17 DRILL N DFAL PROD1 Inspect pinhole & decide to spool onto reel. Flag pinhole. 04:30 - 07:30 3.00 DRILL N DFAL PROD1 Gently spool pinhole onto reel & continue POOH filling hole via the backside. 07:30 - 08:45 1.25 DRILL N DFAL PROD1 Lay out drilling BHA and stab back onto well to circulate. 08:45 - 09:00 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for pickling coil. 09:00 - 10:45 1.75 DRILL N DFAL PROD1 Circulate 10 bbls Bleach, 60 bbls fresh water, 15 bbls inhibited water and 5 bbls MEOH thru coil to prep it for storage. 10:45 - 11:00 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for displacing fluid in coil with N2. 11:00 - 12:15 1.25 DRILL N DFAL PRODi Pump N2 at 1000 cfm. Bleed down. 12:15 - 13:15 1.00 DRILL N DFAL PROD1 R/D hardline inside reel. Pull coil stub to reel and secure. 13:15 - 13:30 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for picking reels with Peak crane. 13:30 - 16:30 3.00 DRILL N DFAL PROD1 Pick used reel with Peak Crane. Remove and install new 6.1" bushings. Had trouble removing one bushing. Picked new 2" reel. 16:30 - 18:00 1.50 DRILL N DFAL PROD1 Pull coil to injecter head and stab coil. Install new pack off and brass bushing. 18:00 - 18:30 0.50 DRILL N DFAL PROD1 RU hardline to inner reel valve. 18:30 - 19:00 0.50 DRILL N DFAL PRODi Behead & weld-on SLB CTC. Pull test to 35k. 19:00 - 19:30 0.50 DRILL N DFAL PROD1 Pump 5bbls of McOH & 5bbls of water ahead. Close inner reel valve & PT hardline to 3500psi - OK. 19:30 - 20:00 0.50 DRILL N DFAL PROD1 Flush/fluid-pack coil with flopro mud. PT CTC to 3500psi - OK. 20:00 - 20:45 0.75 DRILL N DFAL PROD1 Install dart catcher. Load wiper dart. Launch & chase with flopro mud. Dart hit @ 4lbbls. 20:45 - 21:45 1.00 DRILL N DFAL PRODi M/U & lock tite build section BHA #9 with a rebuild HC DOSTRWD 2.7" x 3" bicenter bit, 1.3deg BHI Xtreme motor, Agitator, Sperry GR-DIR MWD orienter & BKR MHA (OAL = 65.75'). Scribe tools & M/U injector. 21:45 - 23:30 1.75 DRILL N DFAL PROD1 RIH drilling BHA #9. SHT MWD &orienter @ 3000' - OK. Continue RIH to 8945'. 23:30 - 00:00 0.50 DRILL N DFAL PRODi Log down GR & tie-into TSAD marker C~3 8945' -add 5' to CTD. Check TF - ~ 159R. S!D pumps. 1/16/2006 00:00 - 01:30 1.50 DRILL N DFAL PROD1 RIH dry & tag BOW 4x ~ 9525'. PUH into TT & check TF 179L. RBIH & retag BOW. PUH & check TF - 117L. Orient TF around to 90R keep trying 1 click @ a time. Finally pop thru 170R TF. 01:30 - 03:30 2.00 DRILL P PROD1 Continue RIH. Set down C~3 11060' & 11174'. Backream area clean & continue RIH. Set down @ 11304'. Backream/ream shales with as drilled TF. RIH to btm. Bring on pumps. TF C~ Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Operations Summary Report Page 8 of 11 Legal Well Name: G-30 Common W ell Name: G-30 Spud Date: 7/23/1986 Event Nam e: REENTE R+COM PLET E Start : 1/6/2006 End: 1/19/2006 Contractor Name: NORDIC CALIS TA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 Date '~! From - To ' Hours ~ Task ~ Code ~! NPT Phase i Description of Operations 1/16/2006 01:30 - 03:30 2.00 DRILL P PRODi 97R. Freespin = 1.5bpm/3550psi. Up wt = 27k. Run-in wt = 4k. 03:30 - 03:40 0.17 DRILL P PRODi Orient TF to 170R. 03:40 - 04:00 0.33 DRILL P PROD1 Drill to 11597' with LS TF, 1.5/1.5bpm, 3550/3800psi, 1 k WOB & 95fph ave ROP. 04:00 -04:20 0.33 DRILL P PROD1 Orient 4 clicks & drill to 11631' with 80-60L TF, 1.5/1.Sbpm, 3550/3900psi, ik WOB & 110fph ave ROP. 04:20 -04:35 0.25 DRILL P PROD1 Orient TF around to 120L. 04:35 - 04:45 0.17 DRILL P PROD1 Drill to 11642' with 90L TF, 1.5/1.5bpm, 3550/3800psi, 1 k WOB & 130fph ave ROP. 04:45 - 05:00 0.25 DRILL P PRODi Orient TF around to 150L. 05:00 - 05:20 0.33 DRILL P PRODi Drill to 11662' with 140E TF, 1.5/1.5bpm, 3550/3800psi, 1 k WOB & 100fph ave ROP. 05:20 - 06:30 1.17 DRILL P PROD1 Orient & drill to 11700' with 90-60L TF, 1.5/1.5bpm, 3550/3800psi, 1 k WOB & 90fph ave ROP. Higher circ pressure due to agitator in BHA. Drilled to 11,725'. 06:30 - 09:30 3.00 DRILL P PROD1 Wiper trip to window. 25K up wt. 1.6 bpm, 10K overpull in shales at 11280, 11060, RIH. Ream each shale one extra time while RIH. 09:30 - 09:45 0.25 DRILL P PROD1 Drilling Z1 B lateral, 1.5 bpm, 3900-4300 psi, 40L, 89 deg incl, Drilled to 11760'. 09:45 - 10:00 0.25 DRILL P PRODi Orient TF to 70L. 10:00 - 10:45 0.75 DRILL P PROD1 Drilling Zi B lateral, 1.5 bpm, 3900-4300 psi, 70L, 120 fph, Stacking full wt. Drilled to 11804'. 10:45 - 11:00 0.25 DRILL P PROD1 Orient TF to 90L. 11:00 - 12:00 1.00 DRILL P PROD1 Drilling Z1 B lateral, 1.5 bpm, 3900-4300 psi, 90L, 90 fph, Drilled to 11847' 12:00 - 12:15 0.25 DRILL P PROD1 Orient TF 12:15 - 13:30 1.25 DRILL P PROD1 Drilling ZiB lateral, 1.5 bpm, 3900-4300 psi, 40L, 20 fph, Stacking wt. Drilled to 11,858'. 13:30 - 15:10 1.67 DRILL P PRODi Wiper trip to window. Clean trip. 15:10 - 15:40 0.50 DRILL P PROD1 Log GR tie-in, added 5 ft CTD. 15:40 - 18:00 2.33 DRILL P PROD1 RIH to TD. Tagged Final TD at 11,860'. Lay in 47 bbls new FloPro liner pill with 4% Lubetex while POH. POH at 50 fpm, pump 1.4 bpm. Clean hole. Pull clean thru window. Flag coil at 9300' EOP for TD flag. 18:00 - 19:15 1.25 DRILL P PRODi Flag coil at 6900' for window flag. POH. 100 fph, 1.4 bpm. 19:15 - 20:30 1.25 DRILL P PRODi OOH. PJSM. S/B injector. Flush & L/D drilling BHA. Bit grades 1 /2/I. 20:30 - 21:00 0.50 CASE P RUNPRD R/U to run liner. 21:00 - 21:15 0.25 CASE P RUNPRD Held PJSM on M/U &RIH with liner. 21:15 - 00:00 2.75 CASE P RUNPRD M/U 2-3/8" STL indexing guide shoe, float collar, 1 shoe jt, float collar, spacer pup & landing collar. M/U & drift 1st 5jts of 2-3/8" STL 4.7# L-80 liner. Continue M/U 62jts of 2-3/8" liner. 1/17/2006 00:00 - 01:00 1.00 CASE P RUNPRD M/U one 10ft pup jt & 11 remaining jts of 2-3/8" liner. M/U Baker deployment sub & LBRT. M/U CTC. 01:00 - 02:45 1.75 CASE P RUNPRD RIH with liner on CT. See 1st flag @ 9413.6'. Correct CTD (-6') to 9407.6'. Check up wt - 25k, Run-in wt - 13k. RIH & tag TOW several times C~3 9513'. 02:45 - 03:45 1.00 CASE N DPRB RUNPRD RIH & yoyo liner several times attempting to bounce off cmt ramp without luck. RIH ~ max speed (133fpm) & finally manage to bounce indexing shoe into OH. 03:45 - 04:15 0.50 CASE P RUNPRD Continue RIH Inr in OH @ 50fpm. Observe slight wt bobbles Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Event Name: REENTER+COMPLETE Start: 1/6/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 Date !From - To '~ Hours Task Code NPT I Phase 1/17/2006 03:45 -04:15 -- _ - J - - 04:15 - 05:15 ~ 10.00 CASE ~ P ~ RUNPRD 05:15 - 05:45 0.501 CASE P (RUNPRD 05:45 - 07:30 I 1.751 CASE I N I WAIT I RUNPRD 07:30 - 11:15 I 3.751 CEMT I P I I RUNPRD 11:15 - 11:30 0.251 CEMT P RUNPRD 11:30 - 12:00 0.50 CEMT P RUNPRD 12:00 - 13:15 1.25 CEMT P RUNPRD 13:15 - 13:25 0.171 CEMT P RUNPRD 13:25 - 15:15 I 1.831 CEMT I P I I RUNPRD 15:15 - 16:00 0.75 CEMT P RUNPRD 16:00 - 16:15 0.25 CLEAN P RUNPRD 16:15 - 16:30 0.25 CLEAN P RUNPRD 16:30 - 16:45 0.25 CLEAN P RUNPRD 16:45 - 17:15 I 0.501 CLEAN I P I I RUNPRD Page 9 of 11 Spud Date: 7/23/1986 End: 1 /19/2006 Description of Operations across shale areas. Set down ~ 11157' shale. Work/wash liner past 11157'. Set down C~3 11168'. Work liner & run past shale @ 133fpm. Set down across several shale areas. Continue working liner in hole with -ve wt. See 2nd flag right on depth. Tag @ 11852'. P/U C~ 40k. RBIH C~3 -4k run-in wt & retag TD C~ same depth. Attempt to work past 11852' for 15mins with no progress. Call it good! Reset CTD to 11860'. PUH to ball drop postion @ 11846'. Load 5/8" AL ball &circ with mud @ 1.5/1.5bpm & 2900psi. Set down 10k down on LBRT. Continue circ to seat. Slow down @ 35 bbls away. Ball on seat @ 36bbls. Pressure up to 3000psi & release CTLRT. P/U @ 25k & confirm release. W.O. KCL truck to arrive onsite. Central dispatch completely out of trucks. Getting 1 truck off 4ES to load 2% KCL for us. Clean rig pits and swap well to 2% KCL water. Build 30 bbl, 2# Biozan pill to displace cement. 25% fluid loss with KCL water on formation. Will add to cement volume to account for fluid loss. SAFETY MEETING. Review procedure, hazards and mitigation for pumping cement. Circ. KCL water 1.6 bpm, 1.25 bpm returns. Batch cement. Press test cement line. Stage 18 bbls, 15.8 PPG, G Cement with Latex, 1.6 bpm, 3200 psi, 1.2 bpm returns. Stop at 18.0 bbl. Clean cement line. Insert Dart. Displace dart with Biozan water. 10 bbls displ, 1.65 bpm, 1.24 bpm returns, 2300 psi. 20 bbls displ, 1.62 bpm, 1.26 bpm returns, 2400 psi 32.6 bbls, cement at shoe, saw pressure increase, zero out volume. 34 bbls, swap to KCL water displacement. 36 bbls displ, slow pump, 1.0 bpm, 0.7 bpm returns, 1900 psi Dart on seat at 41.6 bbls, sheared at 4000 psi. displace LWP at 0.95 bpm, 0.75 bpm returns, 3200 psi. 45 bbls displ, 0.96 bpm, 0.80 bpm returns, 3230 psi. 47 bbls displ, 0.96 bpm, 0.80 bpm returns, 3370 psi. 49 bbls displ, 0.96 bpm, 0.80 bpm returns, 3400 psi. Slow pump to 0.50 bpm. 50 bbls displ, 0.46 bpm, 0.40 bpm returns, 2100 psi. 51.1 bbls, bumbed plug, hold 3160 psi, Cement return volume = 14.9 bbls. Bleed off pressure, check floats, OK. Press up to 500 psi, sting out. POOH C~ 100fpm pumping @ 0.40bpm to replace CT voidage only. OOH. PJSM. S/B injector & UD LBRT. PJSM on P/U & RIH cleanout BHA. R/U to P/U cleanout mill/motor & 1" CHS tbg. Drift MHAs. M/U cleanout BHA #11 with 1.875" mill & 1-11/16" straight motor. Conduct rig emergency evacuation drill -satisfactory response by all rig personnel. Review emergency evacuation roles, responsibilities & procedures. Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: ell Name: e: Name: From - To G-30 G-30 REENTE NORDIC NORDIC ~ Hours R+COM CALIST 1 Task PLET A Code ~ E PT Start Rig Rig Phase I Spud Date: 7/23/1986 : 1/6/2006 End: 1/19/2006 Release: 1/20/2006 Number: N1 Description of Operations 1/17/2006 17:15 - 19:45 2.50 CLEAN P RUNPRD M/U lower MHA, 84jts of 1" CSH & upper MHA. M/U injector. 19:45 - 21:00 1.25 CLEAN P RUNPRD RIH above top of liner to 9100' 21:00 - 21:15 0.25 CLEAN P RUNPRD Wait on 500 psi compressive strength on cement 21:15 - 22:45 1.50 CLEAN P RUNPRD Washing down f/ 9100' to 11821', returns showed cement contamination water w/ 10.0 ppg through window area at 9300', Cmt compressive strength at 500 psi 22:45 - 00:00 1.25 CLEAN P RUNPRD POH to 3501'. 1(18(2006 00:00 - Oi:00 1.00 CLEAN P RUNPRD FIN POH to BHA 01:00 - 02:30 1.50 CLEAN P RUNPRD Breakout MHA, Std Back 1"CSH, LD Motor and mill 02:30 - 02:55 0.42 CLEAN P RUNPRD MU swivel stick, RIH, jet stack, recover cmt in returns, POH, LD same 02:55 - 05:00 2.08 EVAL P LOWERI MU MCNL-GR-CCL, RIH w/ 1" CSH, MHA, stab injector 05:00 - 06:30 1.50 EVAL P LOWERi RIH w/ MCNL BHA to 8600'. 06:30 - 08:45 2.25 EVAL P LOWERI Log down C~ 30fpm from 8600'. Start pumping down 150kcps Flo-Pro pert pill. Continue logging down to 11800' (+J-21' above PBTD). 08:45 - 09:45 1.00 EVAL P LOWERI Log up Q 60fpm from 11800' to 8600' while laying-in 150kcps perf pill in liner. 09:45 - 11:00 1.25 EVAL P LOWERI POOH logging BHA#12. Flag CT EOP C~3 5011'. 11:00 - 11:15 0.25 EVAL P LOWERI PJSM for R/B CSH. 11:15 - 12:45 1.50 EVAL P LOWERI R/B 42 stands of 1"CSH. 12:45 - 13:00 0.25 EVAL P LOWERI PJSM for UD SWS MCNUCCUGR logging tool. 13:00 - 13:15 0.25 EVAL P LOWERI UD SWS MCNVCCUGR logging tool. Check log data quality OK. 13:15 - 14:15 1.00 EVAL P LOWERI Cement ~ 2736psi compressive strength. Line up & P/test wellbore for 30mins as follows: Time WHP CTP IAP OAP Onset 11 0 54 0 0 2040 0 54 0 10 2007 0 54 0 20 1994 0 54 0 30 1981 0 54 0 _> Passed: Leaked 2.9% of test pressure in 30 mins. Will not set LTP. 14:15 - 15:00 0.75 PERFO P LOWERI Load perf guns into pipe shed. R/U safety jt & prep to M/U perf guns. Drift MHAs with 1/2" ball - OK. Meanwhile download CNL data. From log data, TOL = 9354' & PBTD is estmated to be @ 11823'. 15:00 - 15:30 0.50 PERFO P LOWERI PJSM on perforation job. Fax CNL log to ANG Geo. ANC Geo OKs preliminary perf picks. 15:30 - 19:00 3.50 PERFO P LOWERI M/U 74jts of 1.56" HSD 6spf 1606PJ guns & blanks with BCF firing system. Conduct safety jUvalve drill while M/U perf guns satisfactory response. M/U 17 stds of 1 "CSH, MU MHA, stab injector 19:00 - 21:30 2.50 PERFO P LOWERI RIH w/ Perf Gun Assy, EOP correction of +9.2', RIH tagged at 11825.4', corrected -3.4' to 11822' 21:30 - 23:10 1.67 PERFO P LOWERI Dropped 1/2" AL ball, circ down w/ 15 bbls of perf pill ahead and 10 bbls of perf pill behind followed w/ 41 bbls of 2% KCI, ball did not land on seat, dropped second 1/2" steel ball, pumped 36 bbls, ball on seat, pressured up to 2800 psi, sheared ball, fired perf guns on the fly with btm shot at 11820' and top shot at 10250'. Perforated interval = 10250' - 10640', 10680' - 10810', 10910' - 10960', 10990' - 11050', 11070' - Printed: 1/23/2006 1:06:20 PM BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: G-30 Common Well Name: G-30 Spud Date: 7/23/1986 Event Name: REENTER+COMPLETE Start : 1/6/2006 End: 1/19/2006 Contractor Name: NORDIC CALIS TA Rig Release: 1/20/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ,From - To !Hours II, Task ' Code NPT Phase Description of Operations 1/18/2006. 21:30 - 23:10 1.67 PERFO P LOWERI 11150', 11360' - 11440' & 11700' - 11820'. 23:10 - 00:00 0.83 PERFO P LOWERI POH to 9300' 1/19/2006 00:00 - 00:30 0.50 PERFO P LOWERI Flow Check Well above liner lap at 9300', No Flow 00:30 - 01:40 1.17 PERFO P LOWERI POH to Perf Gun Assy 01:40 - 03:00 1.33 PERFO P LOWERI RU handling tools, Std Back 1" CSH 03:00 - 06:30 3.50 PERFO P LOWERI POH, LD Perf Guns, all shots fired. Load out pert guns. 06:30 - 07:00 0.50 RIGD P POST M/U FP nozzle BHA. M/U injector. 07:00 - 10:00 3.00 RIGD P POST RIH nozzle BHA to 2500'. Pump down 14bbls of McOH to nozzle. POOH freeze protecting with 60/40 McOH. FP from 300' with 100% McOH. SI master & swab valves (18-1/2 turns each). 10:00 - 15:30 5.50 RIGD N HMAN POST Observe hardline to tiger tank frozen. Troubleshoot & breakout frozen hardlines. Suspect rig valves to tiger tank were inadvertently left open and/or hardline to tiger tank was not freeze-protected after last mud swap. Call for new hard-line from DSM & change out outside frozen lines to tiger tank. PT hardline to 4000psi. 15:30 - 15:45 0.25 RIGD N POST PJSM for B/D CT with N2. 15:45 - 17:00 1.25 RIGD N POST Pump 13bbls of bleach, 60bbls of fresh water, 15bbls of corrosion inhibitor & 5 bbls of McOH. 17:00 - 17:10 0.17 RIGD N POST P!T N2 lines - OK. 17:10 - 18:00 0.83 RIGD N POST Blow down CT with N2. Meanwhile clean out pits & tanks. 18:00 - 21:20 3.33 RIGD N POST PU Injector, prep for pulling coil across and secure 21:20 - 23:30 2.17 BOPSU N POST C/O BOP rams to 2 3/8", RD BOP, finished cleaning out pits 23:30 - 00:00 0.50 BOPSU N POST P/T tree cap, secured well, released rig at midnight on 01/19/06 Printed: 1/23/2006 1:06:20 PM Halliburton Global Company: BP Amoco Date: 1/25/2006 'l'ime: 10:13:07 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Keference: Welt G-30, True North Site: PB G Pad Vertical (TV"D) Reter ence: 37:30 5/31/1996 1 2:51 69.8 ~~ W'etl: G-30 Section (VS) Reference: Well (O.OON,O.OOE,275.OOAzi) ~ Wellpath: G 30B -- Survey Calculation M ethod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Pla ne Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: G-30 Slot Name: G-30 Well Position: +N/-S 2256.41 ft Northing: 5969122.00 ft Latitude: 70 19 20.401 N +E/-W 1603.05 ft Easting : 657857.00 ft Longitude: 148 43 12.228 W Position Uncertainty: 0.00 ft Wellpath: G-306 Drilled From: G-30A 500292161302 Tie-on Depth: 9498.95 ft Current Datum: 37:3 0 5/31/1996 12:51 Height 69.78 ft Above System Datum: Mean Sea Level Magnetic Data: 1/7/2006 Declination: 24.65 deg Field Strength: 57605 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34 .78 0.00 0.00 275.00 Survey Program for DeTinitive Wellpath Date: 12/18/2005 Validated: Y es Version: 3 Actual From To Survey Toolcode Too} Name ft ft 97.55 6595.00 BOSS-GYRO (97.55-9812 .55) (0) BOSS-GYRO Sperry-Sun BOSS gyro mu ltishot 6714.87 9498.95 MWD (6714.8 7-11789.00) (1) MWD MWD -Standard 9516.00 11860.00 MWD (9516.0 0-11860.00) MWD MWD -Standard Survey ~~ MD Jncl ~ ~Azim ~ TVD Sys'I'VD \/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft ~ 34.78 0.00 0.00 34.78 -35.00 0.00 0.00 5969122.00 657857.00 TIE LINE 97.55 0.18 70.80 97.55 27.77 0.03 0.09 5969122.03 657857.09 BOSS-GYRO 197.55 0.10 165.90 197.55 127.77 0.00 0.26 5969122.00 657857.26 BOSS-GYRO 297.55 0.27 164.90 297.55 227.77 -0.31 0.35 5969121.69 657857.35 BOSS-GYRO 397.55 0.30 187.39 397.55 327.77 -0.80 0.37 5969121.21 657857.39 BOSS-GYRO 497.55 0.50 183.19 497.55 427.77 -1.50 0.32 5969120.51 657857.35 BOSS-GYRO 597.55 0.52 171.81 597.54 527.76 -2.38 0.36 5969119.63 657857.40 BOSS-GYRO 697.55 0.30 190.60 697.54 627.76 -3.09 0.37 5969118.92 657857.44 BOSS-GYRO 797.55 0.25 178.00 797.54 727.76 -3.56 0.33 5969118.45 657857.41 BOSS-GYRO 897.55 0.08 119.61 897.54 827.76 -3.81 0.40 5969118.20 657857.48 BOSS-GYRO 997.55 0.17 143.81 997.54 927.76 -3.97 0.55 5969118.04 657857.63 BOSS-GYRO 1097.55 0.05 270.40 1097.54 1027.76 -4.09 0.59 5969117.93 657857.68 BOSS-GYRO 1197.55 0.10 357.50 1197.54 1127.76 -4.00 0.54 5969118.01 657857.63 BOSS-GYRO 1297.55 0.05 343.70 1297.54 1227.76 -3.87 0.53 5969118.14 657857.61 BOSS-GYRO 1397.55 0.10 307.11 1397.54 1327.76 -3.78 0.45 5969118.23 657857.52 BOSS-GYRO 1497.55 0.20 4.89 1497.54 1427.76 -3.55 0.39 5969118.46 657857.47 BOSS-GYRO 1597.55 0.08 9.19 1597.54 1527.76 -3.31 0.42 5969118.70 657857.49 BOSS-GYRO 1697.55 0.32 53.30 1697.54 1627.76 -3.07 0.65 5969118.94 657857.72 BOSS-GYRO 1797.55 0.42 71.89 1797.53 1727.75 -2.79 1.23 5969119.24 657858.28 BOSS-GYRO 1897.55 0.18 40.80 1897.53 1827.75 -2.56 1.68 5969119.48 657858.73 BOSS-GYRO 1997.55 0.25 340.31 1997.53 1927.75 -2.23 1.71 5969119.80 657858.75 BOSS-GYRO 2097.55 0.15 257.60 2097.53 2027.75 -2.06 1.50 5969119.98 657858.55 BOSS-GYRO 2197.55 0.22 332.61 2197.53 2127.75 -1.91 1.29 5969120.11 657858.33 BOSS-GYRO 2297.55 0.40 195.30 2297.53 2227.75 -2.08 1.11 5969119.94 657858.15 BOSS-GYRO 2397.55 0.20 195.10 2397.53 2327.75 -2.59 0.97 5969119.44 657858.02 BOSS-GYRO 2497.55 0.30 159.40 2497.53 2427.75 -3.00 1.02 5969119.02 657858.08 BOSS-GYRO 2597.55 0.15 128.81 2597.53 2527.75 -3.33 1.21 5969118.70 657858.28 BOSS-GYRO 2697.55 0.27 143.90 2697.53 2627.75 -3.60 1.45 5969118.43 657858.53 BOSS-GYRO Halliburton Global ~i ~ Company: BP Amoco Date: 1/25/2006 ___ Time: 10:13:07 Yage: 2 I Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well: G-30, True North ', Sitr. PB G Pad Vertical (TVD) Reference: 37 :30 5/31/1996 12.51 69.8 j ~ Nell: G-30 N'ellpath: G-30B Section (VS) Reference: Well (O.OON,O.OOE,275.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey MU Ind Azirn TV'U Sys'fVD N/S E/N' V1apN :V1apE Tool ft deg deg ft ft ft ft ft ft ', 2797.55 2.33 65.19 2797.50 2727.72 -2.94 3.44 5969119.14 657860.50 BOSS-GYRO 2847.55 2.98 64.89 2847.44 2777.66 -1.96 5.54 5969120.16 657862.57 BOSS-GYRO 2897.55 3.15 67.30 2897.37 2827.59 -0.88 7.98 5969121.29 657864.99 BOSS-GYRO 2997.55 6.53 72.80 2997.00 2927.22 1.87 15.95 5969124.20 657872.90 BOSS-GYRO 3097.55 8.50 73.60 3096.14 3026.36 5.63 28.47 5969128.23 657885.34 BOSS-GYRO 3197.55 11.10 75.00 3194.67 3124.89 10.21 44.86 5969133.15 657901.63 BOSS-GYRO 3297.55 12.93 77.69 3292.48 3222.70 15.09 65.09 5969138.46 657921.76 BOSS-GYRO 3397.55 14.38 79.10 3389.65 3319.87 19.82 88.22 5969143.67 657944.77 BOSS-GYRO 3497.55 18.57 78.10 3485.52 3415.74 25.46 116.01 5969149.89 657972.43 BOSS-GYRO 3597.55 20.73 79.69 3579.69 3509.91 31.91 149.00 5969157.03 658005.29 BOSS-GYRO 3697.55 23.60 81.69 3672.29 3602.51 37.97 186.23 5969163.88 658042.38 BOSS-GYRO 3797.55 24.68 81.89 3763.55 3693.77 43.81 226.71 5969170.57 658082.72 BOSS-GYRO 3897.55 25.17 82.10 3854.23 3784.45 49.68 268.44 5969177.31 658124.32 BOSS-GYRO 3997.55 25.52 82.69 3944.61 3874.83 55.34 310.87 5969183.86 658166.61 BOSS-GYRO 4097.55 25.52 83.39 4034.85 3965.07 60.56 353.63 5969189.98 658209.26 BOSS-GYRO 4197.55 25.78 83.69 4125.00 4055.22 65.43 396.65 5969195.76 658252.15 BOSS-GYRO 4297.55 25.88 84.10 4215.01 4145.23 70.07 439.97 5969201.30 658295.37 BOSS-GYRO 4397.55 25.85 84.39 4304.99 4235.21 74.44 483.38 5969206.59 658338.67 BOSS-GYRO 4497.55 25.98 84.50 4394.93 4325.15 78.67 526.87 5969211.73 658382.06 BOSS-GYRO 4597.55 25.93 84.80 4484.85 4415.07 82.75 570.45 5969216.73 658425.54 BOSS-GYRO 4697.55 26.12 85.19 4574.71 4504.93 86.58 614.16 5969221.47 658469.16 BOSS-GYRO 4797.55 26.35 85.69 4664.41 4594.63 90.09 658.22 5969225.91 658513.13 BOSS-GYRO 4897.55 26.62 86.10 4753.91 4684.13 93.28 702.71 5969230.04 658557.54 BOSS-GYRO 4997.55 26.88 86.89 4843.21 4773.43 96.04 747.63 5969233.73 658602.39 BOSS-GYRO 5097.55 27.32 87.10 4932.23 4862.45 98.42 793.12 5969237.07 658647.82 BOSS-GYRO 5197.55 27.10 87.50 5021.16 4951.38 100.58 838.80 5969240.19 658693.43 BOSS-GYRO 5297.55 27.42 87.69 5110.06 5040.28 102:50 884.56 5969243.07 658739.14 BOSS-GYRO 5397.55 28.07 87.69 5198.56 5128.78 104.38 931.07 5969245.93 658785.60 BOSS-GYRO 5497.55 28.68 87.69 5286.55 5216.77 106.29 978.56 5969248.84 658833.04 BOSS-GYRO 5597.55 29.18 87.60 5374.07 5304.29 108.28 1026.89 5969251.84 658881.31 BOSS-GYRO 5697.55 29.93 87.30 5461.05 5391.27 110.47 1076.17 5969255.08 658930.53 BOSS-GYRO 5797.55 30.03 87.00 5547.67 5477.89 112.96 1126.08 5969258.61 658980.37 BOSS-GYRO 5897.55 29.93 86.89 5634.29 5564.51 115.62 1175.98 5969262.32 659030.20 BOSS-GYRO 5997.55 29.85 86.80 5720.99 5651.21 118.37 1225.73 5969266.11 659079.88 BOSS-GYRO 6097.55 30.18 86.50 5807.58 5737.80 121.29 1275.67 5969270.08 659129.74 BOSS-GYRO 6197.55 30.57 86.69 5893.85 5824.07 124.29 1326.15 5969274.15 659180.14 BOSS-GYRO 6297.55 30.95 87.10 5979.79 5910.01 127.06 1377.22 5969277.99 659231.14 BOSS-GYRO 6397.55 31.38 87.39 6065.35 5995.57 129.55 1428.91 5969281.56 659282.76 BOSS-GYRO 6497.55 31.38 87.89 6150.73 6080.95 131.69 1480.93 5969284.80 659334.73 BOSS-GYRO 6595.00 31.27 88.18 6233.97 6164.19 133.43 1531.57 5969287.60 659385.31 BOSS-GYRO 6714.87 26.02 101.20 6339.23 6269.45 129.30 1588.55 5969284.67 659442.37 MWD 6811.74 22.78 111.53 6427.48 6357.70 118.28 1626.87 5969274.47 659480.90 MWD 6903.58 18.01 127.46 6513.61 6443.83 103.10 1654.72 5969259.88 659509.06 MWD 6997.42 10.83 140.00 6604.45 6534.67 87.50 1671.92 5969244.64 659526.59 MWD 7091.73 4.64 122.53 6697.87 6628.09 78.65 1680.85 5969235.98 659535.70 MWD 7184.84 5.00 83.10 6790.67 6720.89 77.12 1688.05 5969234.60 659542.93 MWD 7279.08 3.70 87.88 6884.64 6814.86 77.72 1695.17 5969235.35 659550.03 MWD 7330.22 0.69 72.84 6935.74 6865.96 77.87 1697.11 5969235.55 659551.97 MWD 7405.69 1.75 270.36 7011.20 6941.42 78.02 1696.39 5969235.67 659551.25 MWD 7496.04 2.12 267.33 7101.50 7031.72 77.95 1693.34 5969235.54 659548.21 MWD 7590.83 2.18 216.51 7196.23 7126.45 76.42 1690.52 5969233.95 659545.42 MWD 7682.75 2.37 201.90 7288.08 7218.30 73.25 1688.77 5969230.74 659543.73 i MWD ~ Halliburton Global Company: BP Amoco llate: 1/25/2006 Time: 10:13:07 Page: 3 '~ ~ Field: Pru dhoe Bay C o-ord inafe(NE) Reference: Well: G-30, Tr ue North ' Site: PB G Pad Vertical ('I'VD) Reference: 37 :30 5/31/1996 12:51 69.8 well: 6-30 Section (VS) Referen ce: Well (O.OON,O. OOE ,275.OOAzi) Wellpath: G-30B Sur~~ey Calculation Method: Minimum Curvatu re Db: Oracle Surcev - I - D1D In~l _ __ 4zim ___ I'VD _ _- Sys TVD L 'V/b - E/~'~' ~-- Ma r Ma F p - Tool ~ ~ ft deg deg ft ft ft ft ft ft 7776. 10 2. 31 198. 59 7381 .35 7311 .57 69. 67 - -- 1687.45 5969227 .14 659542 .49 MWD 7869. 92 0. 76 216. 73 7475 .13 7405. 35 67. 38 1686.48 5969224 .83 659541 .56 MWD 7963 .38 0 .64 292 .06 7568 .59 7498 .81 67. 08 1685.62 5969224 .51 659540 .72 MWD 8055 .83 0 .79 303 .40 7661 .03 7591 .25 67. 63 1684.61 5969225 .04 659539 .69 MWD 8148 .94 0 .98 313. 99 7754 .13 7684 .35 68. 53 1683.50 5969225 .92 659538 .57 MWD 8241. 35 0 .95 326. 14 7846 .53 7776 .75 69. 72 1682.51 5969227 .08 659537 .55 MWD 8335. 91 1. 12 314. 51 7941 .07 7871 .29 71. 02 1681.41 5969228 .36 659536 .42 MWD 8429. 73 1 .14 318. 62 8034 .87 7965. 09 72. 36 1680.14 5969229 .67 659535 .12 MWD 8530. 08 2. 15 116. 78 8135 .20 8065. 42 72. 26 1681.16 5969229 .60 659536 .15 MWD 8623. 38 9. 62 129. 50 8227 .95 8158. 17 66. 50 1688.75 5969224 .00 659543 .85 MWD 8714 .64 16 .39 131. 10 8316 .82 8247 .04 53. 17 1704.35 5969211 .01 659559 .74 MWD 8808 .27 22 .39 125. 90 8405 .10 8335 .32 34. 01 1728.78 5969192 .37 659584 .55 MWD 8901. 86 28 .93 126. 76 8489 .42 8419 .64 9. 99 1761.39 5969169 .03 659617 .66 MWD 8993. 47 33 .40 122. 04 8567 .80 8498 .02 -16. 67 1800.54 5969143 .21 659657 .36 MWD 9069. 08 38 .06 120. 59 8629 .16 8559. 38 -39. 58 1838.26 5969121 .10 659695 .56 MWD 9150. 19 42. 62 121. 14 8690 .97 8621. 19 -66. 52 1883.31 5969095. 11 659741 .16 MWD 9184. 14 42. 72 120. 99 8715 .93 8646. 15 -78. 39 1903.02 5969083. 66 659761 .11 MWD 9206. 26 42. 39 121. 30 8732 .22 8662. 44 -86. 13 1915,83 5969076 .19 659774 .08 MWD 9238 .20 43 .15 122. 00 8755 .67 8685 .89 -97. 51 1934.29 5969065 .20 659792 .77 MWD 9277 .59 44 .57 121. 50 8784 .07 8714. 29 -111. 87 1957.50 5969051 .33 659816 .28 MWD 9310 .22 45 .82 121. 30 8807 .07 8737. 29 -123. 93 1977.26 5969039 .69 659836 .29 MWD 9341 .90 48 .76 122. 40 8828 .55 8758. 77 -136. 22 1997.03 5969027 .82 659856 .31 MWD 9372 .93 52 .93 121. 50 8848 .14 8778. 36 -148. 94 2017.44 5969015. 53 659876 .98 MWD 9404. 14 55 .56 120. 90 8866 .38 8796. 60 -162. 06 2039.11 5969002. 87 659898 .92 MWD 9436. 25 57 .27 120. 70 8884 .14 8814. 36 -175. 76 2062.08 5968989. 67 659922 .17 MWD 9467 .95 58 .11 120. 30 8901 .08 8831. 30 -189. 35 2085.17 5968976 .56 659945 .54 MWD 9498 .95 60 .03 119. 10 8917 .01 8847. 23 -202. 53 2108.26 5968963 .88 659968 .91 MWD 9516 .00 60 .43 117. 96 8925 .48 8855. 70 -209. 59 2121.27 5968957 .08 659982 .05 MWD 9550 .21 49 .31 131. 36 8945 .19 8875. 41 -225. 24 2144.28 5968941. 93 660005 .39 MWD 9576 .57 44 .48 144. 22 8963 .24 8893. 46 -239. 37 2157.22 5968928. 07 660018 .62 MWD 9607. 76 53 .44 155. 80 8983 .74 8913. 96 -259. 74 2168.79 5968907. 95 660030. 62 MWD 9637. 91 60 .47 170. 91 9000 .24 8930. 46 -283. 87 2175.86 5968883. 98 660038. 20 MWD 9668. 35 68 .20 183. 57 9013 .45 8943. 67 -311. 18 2177.08 5968856. 70 660039. 99 MWD 9701. 74 74. 88 197. 46 9024 .07 8954. 29 -342. 20 2171.25 5968825 .57 660034 .81 MWD 9736 .98 81 .21 209. 23 9031 .39 8961. 61 -373. 76 2157.58 5968793. 73 660021 .81 MWD 9767 .24 85 .69 223. 65 9034 .86 8965. 08 -397. 86 2139.76 5968769. 26 660004 .50 MWD 9798 .20 91 .76 238. 59 9035 .55 8965. 77 -417. 22 2115.75 5968749. 40 659980 .90 MWD 9831 .23 92 .02 256. 87 9034 .45 8964. 67 -429. 68 2085.33 5968736. 31 659950 .75 MWD 9869 .66 90 .61 266. 71 9033 .57 8963. 79 -435. 16 2047.35 5968730. 03 659912. 90 MWD 9907 .09 88 .24 269. 88 9033 .94 8964. 16 -436. 27 2009.94 5968728. 13 659875. 53 MWD 9941. 57 89. 57 270. 30 9034 .60 8964. 82 -436. 22 1975.47 5968727. 46 659841. 07 MWD 9968 .95 93 .16 273. 75 9033 .95 8964. 17 -435. 25 1948.12 5968727. 85 659813. 71 MWD 10010 .18 94 .66 278. 32 9031 .14 8961. 36 -430. 93 1907.23 5968731. 31 659772. 73 MWD 10042 .18 97 .12 281. 30 9027 .85 8958. 07 -425. 51 1875.87 5968736. 07 659741. 27 MWD 10073 .15 96 .85 284. 29 9024 .09 8954. 31 -418. 70 1845.90 5968742. 25 659711. 16 MWD 10106 .17 93 .95 286. 05 9020 .98 8951. 20 -410. 10 1814.17 5968750. 18 659679. 27 MWD 10139 .99 90 .97 290. 44 9019 .53 8949. 75 -399. 52 1782.10 5968760. 08 659646. 98 MWD 10173 .85 89 .65 294. 49 9019 .34 8949. 56 -386. 59 1750.81 5968772. 35 659615. 43 MWD 10204 .49 87 .19 297. 83 9020 .19 8950. 41 -373. 09 1723.33 5968785. 27 659587. 67 MWD 10238. 99 86 .57 299. 76 9022 .07 8952. 29 -356. 49 1693.14 5968801. 22 659557. 14 MWD 10281 .39 89 .35 305. 03 9023 .57 8953. 79 -333. 80 1657.38 5968823. 15 659520. 91 MWD 10312 .04 90 .35 309. 43 9023 .64 8953. 86 -315. 26 1632.98 5968841. 18 659496. 13 MWD 10340 .93 90 .61 314. 35 9023 .40 8953. 62 -295. 98 1611.48 5968860. 00 659474. 23 MWD Halliburton Global Company: BP Amoco Date: 1/25/2006 Time: 10:13:07 Pale: 4 Field: Pru dhoe Bay C o-ord inate(NE) Reference: Weil: G-30, Tr ue North i Site: PB G Pad Vertica l (TVD) Reference: 37 :30 5/31/1996 12:51 69.8 I Well: G-30 Se ction (VS) Refere nce: Well (O.OON,O. OOE ,275.OOAzi) ~~~ Wellpath: G-30B Su rvev Calculation Method: Min imum Curvatur e Db: Oracle Survey' MD Incl Aim 1 Vll Sys I VD N/S H~{W 111apN I~IapE Tool ft deg deg ft ft ft ft ft ft 10381. 73 90. 00 318. 04 9023 .18 8953 .40 -266. 54 1583 .24 5968888. 84 659445 .39 MWD 10407. 94 88. 86 321. 91 9023 .44 8953 .66 -246. 47 1566 .39 5968908. 54 659428 .12 MWD 10440. 45 86. 00 321. 87 9024 .90 8955. 12 -220. 92 1546 .35 5968933. 67 659407 .54 MWD 10473. 92 86. 04 316. 11 9027 .22 8957. 44 -195. 74 1524 .45 5968958. 38 659385 .12 MWD 10513. 46 86. 84 313. 47 9029 .68 8959. 90 -167. 94 1496 .45 5968985. 58 659356 .54 MWD 10543. 64 88. 86 312. 07 9030 .81 8961 .03 -147. 46 1474 .31 5969005. 59 659333 .98 MWD 10576. 83 88. 24 308. 37 9031 .65 8961 .87 -126. 04 1448 .98 5969026. 47 659308 .20 MWD 10607. 51 87. 27 307. 50 9032 .85 8963. 07 -107. 19 1424 .80 5969044. 80 659283 .64 MWD 10637. 37 88. 59 305. 21 9033 .93 8964. 15 -89. 51 1400 .77 5969061. 98 659259 .24 MWD 10668. 05 92. 02 303. 80 9033 .77 8963. 99 -72. 13 1375 .49 5969078. 82 659233 .60 MWD 10706. 85 93. 69 305. 56 9031 .83 8962. 05 -50. 08 1343 .63 5969100. 19 659201. 28 MWD 10749. 54 93. 60 301. 17 9029 .12 8959. 34 -26. 66 1308 .05 5969122. 86 659165. 23 MWD 10788. 94 91. 14 299. 23 9027 .49 8957. 71 -6. 86 1274 .03 5969141. 94 659130 .80 MWD 10820. 32 92. 11 296. 25 9026 .60 8956. 82 7. 74 1246 .27 5969155. 95 659102 .75 MWD 10853. 00 90. 44 294. 49 9025 .87 8956. 09 21. 74 1216 .76 5969169. 32 659072 .94 MWD 10884. 94 88. 79 292. 66 9026 .09 8956. 31 34. 51 1187 .48 5969181. 48 659043. 41 MWD 10923. 91 89. 03 288. 69 9026 .83 8957. 05 48. 26 1151 .04 5969194. 46 659006. 68 MWD 10957. 00 88. 33 285. 70 9027 .59 8957. 81 58. 04 1119 .44 5969203. 57 658974 .89 MWD 10988. 67 89. 12 282. 53 9028 .30 8958. 52 65. 76 1088 .74 5969210. 64 658944 .03 MWD 11018. 60 90. 40 279. 87 9028 .42 8958. 64 71. 58 1059 .38 5969215. 84 658914. 56 MWD 11059. 64 91. 95 276. 90 9027 .58 8957. 80 77. 56 1018 .79 5969220. 96 658873. 86 MWD 11088. 33 91. 17 275. 33 9026 .80 8957. 02 80. 61 990 .28 5969223. 42 658845. 29 MWD 11122. 90 90. 88 271. 64 9026 .18 8956. 40 82. 71 955 .78 5969224. 79 658810. 76 MWD 11152. 88 88. 86 271. 11 9026. 25 8956. 47 83. 43 925 .81 5969224. 88 658780. 79 MWD 11207. 95 84. 46 265. 83 9029 .46 8959. 68 81. 97 870 .89 5969222. 27 658725. 91 MWD 11238. 12 83. 41 263. 73 9032 .65 8962. 87 79. 24 841 .02 5969218. 91 658696. 10 MWD 11268. 79 86. 66 261. 26 9035 .30 8965. 52 75. 25 810 .73 5969214. 28 658665. 91 MWD 11306. 00 91. 32 259. 68 9035 .96 8966. 18 69. 09 774 .05 5969207. 35 658629. 37 MWD 11337. 54 95. 80 258. 28 9034. 00 8964. 22 63. 08 743 .16 5969200. 69 658598. 61 MWD 11374. 94 95. 54 260. 56 9030. 30 8960. 52 56. 25 706 .58 5969193. 09 658562. 19 MWD 11420. 58 95. 01 265. 66 9026 .10 8956. 32 50. 80 661 .47 5969186. 69 658517. 21 MWD 11451. 75 95. 86 270. 61 9023 .15 8953. 37 49. 79 630 .47 5969185. 03 658486. 24 MWD 11488. 02 95. 89 275. 15 9019 .43 8949. 65 51. 60 594 .45 5969186. 09 658450. 19 MWD 11522. 11 95. 45 281. 30 9016. 06 8946. 28 56. 45 560 .89 5969190. 23 658416. 54 MWD 11552. 87 93. 87 283. 76 9013. 56 8943. 78 63. 10 530 .96 5969196. 25 658386. 48 MWD 11586. 11 86. 48 282. 53 9013. 46 8943. 68 70. 66 498 .62 5969203. 12 658353. 99 MWD 11616. 69 85. 52 280. 60 9015. 60 8945. 82 76. 77 468. 73 5969208. 61 658323. 98 MWD 11654. 64 84. 46 277. 26 9018 .91 8949. 13 82. 64 431 .39 5969213. 69 658286. 53 MWD 11682. 77 81. 65 275. 33 9022 .31 8952. 53 85. 70 403 .64 5969216. 17 658258. 72 MWD 11721. 41 84. 46 266. 89 9026. 99 8957. 21 86. 44 365 .33 5969216. 09 658220. 41 MWD 11750. 50 89. 21 267. 94 9028. 60 8958. 82 85. 13 336 .33 5969214. 18 658191. 44 MWD 11782. 59 90. 35 272. 69 9028. 72 8958. 94 85. 30 304. 25 5969213. 68 658159. 36 MWD 11815. 98 90. 61 268. 12 9028 .44 8958. 66 85. 54 270 .87 5969213. 21 658125. 99 MWD 11837. 38 89. 12 264. 78 9028 .49 8958. 71 84. 21 249 .51 5969211. 44 658104. 67 MWD 11860. 00 89. 12 264. 78 9028. 84 8959. 06 82. 16 226 .99 5969208. 91 658082. 19 MWD TREE _ ' 3" -5M -FMC WELLHEAD =13-5/8" -5M McEVOY SSH ACTUATOR = AXELSON KB. ELEV = 69.78' BF. ELEV = 39.3' KOP = 9516' Max Angle = 97.12° @ 10042' Datum MD = 9410' Datum TV D = 8800' SS I 13-3/8" CSG, 72#, L-80, ~ = 12.347" I 9-518" CSG, 47#, L-80, ID = 8.681" TOP OF 9-5/8" CSG • S NOTE: 9-5/8" LNR HGR HAS KNOW N G ~3 O B LEA AND THE REASON FOR THE STRADDLE CTD Sidetrack COMPLETION. I 2684' I I 4478' I Minimum ID =1.92" @ 9360' 2-3/8" STL LN R BOT DEPLOY SLEEVE, 6' LONG, 2.25" ID 9354' 9-5/8" CSG, 47#, L-80, ID = 8.681" I-i 6590' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 94$6' 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" 9823' PERFORATION SUMMARY REF LOG: MCNUCCUGR OF 1/18/2006 TIE IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 87.3° @ 10250' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 10,250' - 10,640' Opn 01/19/06 1.56" 6 10,680' - 10,810' Opn 01/19/06 1.56" 6 10,910'-10,960' Opn 01/19/06 1.56" 6 10,990'-11,050' Opn 01/19/06 1.56" 6 11,070'-11,150' Opn 01/19!06 1.56" 6 11,360' - 11,440' Opn 01/19/06 1.56" 6 11,700'-11,820' Opn 01/19/06 I 11860' I PBTD ~ 11715' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11800' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/86 ORIGINAL COMPLETION 09/28/05 DAV/TLH IBPCORRECTION 07/30/95 SIDETRACK (G-30A) 10/04/05 DAV/TLH PKR CORRRECTION 01/30/02 RWTP CORRECTIONS 01119/06 JUE NORDIGI CTD SIDETRACK 09/02/02 SVC/TP KBE CORRECTION 06/04/03 ATD/TLP GLV CORRECTIONS 08/13/03 JCM/TLH GLV GO PRUDHOE BAY UNfT WELL: G-306 PBZMIT No: 205-208 API No: 50-029-21613-02 SEC 12, T11 N, R13E, 2519' FNL & 2369' FEL BP Exploration (Alaska) O I 3-1/2" SSSV OTIS LANDING NIP, ID = 2.750" I GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 2 1 4269 6390 4120 5989 26 32 McMURRY MCMURRY DMY DMY RK RK 0 0 08/13/03 08/13/03 3-1/2" HES X NIP, ID = 2.750" 9-5/8" X 3-1/2" BAKER SAB PKR, ID = 3.25" SIDETRACK WINDOW 6600 - 6645' TOP OF 2-3/8" LINER & TOP OF CEMENT ~ 9381' -j 3-1/2" PARKERSWS NIP, ID= 9398' 7" X 3-1/2" BAKER SABL-3 P 9424' 3-1/2" HES X NIP, ID = 2.750" 9434' 3-1/2" 10' PERFORATED PUP 944 3-1/2" HES X NIP, ID = 2.750" 9447' ~ ELMD TT LOGGED 08/04/9 9447' TOP OF P8A /PILOT HOLE CI ' - 9525' CEMENT RAMP WINDOW 11823' PBTD j ~ 2-3/8" LINER: CEMEMED & PER ~ 9709' MARKER 10' PUP JOINT a~ _ 9678' ~_X 5" TNV PKR, ID = ???? a~ a n. 10025' --~ 2-1/2" ~P(05/23/01) 11370' a-1/2" x 2-7/a" BAKER MODEL D PKR, ID = 2.688" AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well G-30B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,498.95' MD Window /Kickoff Survey: 11,$37.00' MD (if applicable) Projected Survey: 11,860.00' MD 26-Jan-06 ~p5 - a~8 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date C~~ /7 ~4~~ Signed ', w ;~ ~.~. Please call me at 273-3545 if you -any questions or concerns. Regards, Carl Ulrich Survey Manager • Attachment(s) ° ~ '" . d ~7 a , ~~ ~~ ~ ~ ~ ~ °'a ~ ~ ~ i"' i,~ ~ ~" a i~ t ~ ~ 7 - j F i }~ ~j ~ 7~ ~ ~ ~ ~ ~ ~ ~ 1 ~ ~ a ~ ~ i ~ ~ ~ 'a ~~,~ 4 ~~ ,~ ~+ ~ a ~ ~ ~°' '~ ~ ` ^ ~~ ~w ~~ ~ FRANK H. MURKOWSKI GOVERNOR ; , 7= ~ ~ ~+ O~ ~ ~ ~ 333 W. T" AVENUE, SUITE 100 ' C011T5ER~' O1~T COMD'IISSIOI~T ANCHORAGE, ALASKA 99501-3539 j PHONE (907) 279-1433 1 FAX (907) 27&7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6 12 Re: PBU G-30B BP Exploration (A aska), Inc. Permit No: 205-2 8 Surface Location: 2519' FNL, 2369' FEL, SEC. 12, T11N, R13E, UM Bottomhole Locati n: 2526' FNL, 2035' FEL, SEC. 12, T11N, R13E, UM Dear Mr. Stagg: Enclosed is the approv~d application for permit to drill the above referenced development well. This permit to drill doe not exempt you from obtaining additional permits or an approval required b law from other governmental agencies and does not authorize conducting d filling operations until all other required permits and approvals have been iss ed. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager) . DATED thisZ~ay of December, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA AND GAS CONSERVATION COISSION PERMIT TO DRILL 20 AAC 25.005 1~,6Gr1- ! it t2. ZOt~$ ~~~~ CIEC 2 ~. X005 ;;rti~~a~(:~ ~;~I Gad Cons. Commiss-uft ia. Type of work ^ Drill ®Redrill ^ Re-Entry ib. Current Well Class ^ Exploratory ®Development Oil ne ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU G-30B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11750 TVD 8955ss 12. Field /Pool(s): Prudhoe Bay Field !Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2519' FNL 2369' FEL SEC i2 T11N R13E UM 7. Property Designation: ADL 028280 Pool , , , . , , Top of Productive Horizon: 2520' FNL, 592' FEL, SEC. 12, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 7, 2006 Total Depth: 2526' FNL, 2035' FEL, SEC. 12, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 12,300' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 657857 - 5969122 Zone- ASP4 10. KB Elevation (Height above GL): 69.78' feet 15. Distance to Nearest Well Within Pool G-31 A is offset by 850' 16. Deviated Wetls: Kickoff Depth: 9520 feet Maximum Hole Angle: 97 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3100 Surface: 2220 1s. as ng rogram: Size Specffications Setting Depth To Bottom uanfity O ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3l8" 4.6# L-80 STL 2400' 9350' 8765' 11750' 8955' 5 cu ft Ctass'G' 19. PRESENT WELL CONDITION SUMM ARY (To be completed for'Redrill AND Re-entry Operations) Total Depth MD (ft): 11800 Total Depth TVD (ft): 8965 Plugs (measured): 10025 Effective Depth MD (ft): 10025 Effective Depth TVD (ft): 9025 Junk (measured): None Casin Len h Size Cement Volume MD / TVD I n r 110' 20° cu ds Concrete 110' 110' 2684' 13-3/8" 250 cu ft PF'E', 460 cu ft PF 2684' 2684' I 6590' 9-5/8" 575 cu ft Class 'G' 6590' 6230' P u i n i 3367' 7" 81 cu ft Class 'G', 179 cu ft Class 'G' 6456' - 9823' 6115' - 9021' Liner 2132' 4-1/2" 90 cu ft Class 'G' 9678' - 11800' 8986' - 8965' Perforation Depth MD (ft): 9622' - 9950' (Above IBP) Perforation Depth TVD (ft): 8971' - 9026' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Ptat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Stagg, 564-4694 Printed Name Ted Stagg Title CT Drilling Engineer Preparetl By Name/Number. Si nature Phone 564-4694 Date /A 3! OS Terrie Hubble, 56a-x628 Commission Use Only Permit To Drill Number: zo p API Number: 50- 029-21613-02-00 Permit A proval Date: ( • (' See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes ~No Mud Log Required ^ Yes No Hydrogen Sulfide Measures ~ Yes ^ No Directional Survey Required Yes ^ No Other: ~.~St' ~D ~ 'f'O 3500 pf i . APPROVED BY / - ~ ~ `~ A roved THE COMMISSION Date Form 10-401 ~iised~B9ti"~04~ ~ I ~ I ~ A L Submit In Duplicate TREE 3" -5M -FMC • WELLHEAD =13-5/8" -5M McEVOY SSH ACTUATOR = AXELSON KB. ELEV - ~ 69.78' BF. ELEV..- 39.3' KOP = _ _ _ _ 3098' ~~ Max Angle = ~, 97 @ 10858' Datum MD = 9410' Datum TV D = 8800' SS G-30A S NOTE: 9-5/8" LNR HGR HAS KNOWN LAND THE REASON FOR THE STRADDLE COMPLETION. HORIZONTAL WELL - 70° @ 9654' AND 90° @ 9923' 2201' 3-1/2" SSSV OTIS LANDING NIP, ID = 2.750" 13-3/8" CSG, 72#, L-80, ID = 12.347" I-1 2684' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-1 4478• TOP OF 9-5/8" CSG 447$' TOP OF 7" LNR I-I 6456' Minimum ID = 2.205" @ 11405' 2-7/8" HES XN NIPPLE O o- O ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~--I 6590' ~ 3-112" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I 9456' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I-I 9823' PERFORATION SUMMARY REF LOG: MWD/GR ON 06/30/95 ANGLE AT TOP PERF: 70 @ 9622' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL 4PN/SOZ DATE 2-114" 6 9622 - 9642 O 01115!02 2-1/4" 6 9750 - 9770 O 05/23/01 2-1/4" 6 9780 - 9820 O 05/23/01 2-3/4" 4 9830 - 9950 O 07/24/95 2-314" 4 10100 - 10300 O 07/24/95 2-3/4" 4 10350 - 10390 O 07/24!95 2-314" 4 10760 - 10810 O 07/24/95 2-3/4" 4 10890 - 11100 O 07/24/95 2-314" 4 11440 - 11700 S 06/27/96 6418' ~ 3-1/2" HES X NIP, ID = 2.750" 6430' 9-5/8" X 3-1/2" BAKER SAB PKR, ID = 3.25" SIDETRACK WINDOW 6600 - 664 9381' 3-1/2" PARKER SWS NIP, ID = 2.75" 9398' 7" X 3-1/2" BAKER SABL-3 PKR, ID = 3.875" -- 9424' 3-1/2" HES X NIP, ID = 2.750" _~ 9434' 3-1/2" 10' PERFORATED PUP ~~ $444' 3-1 i2" HES X NIP, iD = 2.750" 9456' -~-1/2" TTL WLEG 9447' ELMD TT LOGGED 08/04/95 9678' 7" X 5" TM/ PKR, ID = '>`? %"? 10025' --j 2-112" IBP(05/23/01) TOP OF 2-7/8" TBG ~~ 11370' ~ 2-3/8" TBG, 4.6#, L-80, 11414' .0087 bpf, 1D = 1.995" PBTD' 4-1/2" LNR, 12.6#; L-80, .0152 bpf, ID = 3.958" 11715' 11800' 11370' 4-1/2" X 2-718" BAKER MODEL D PKR, ID = 2.688" 11405' 2-718" HES X NIP, ID = 2.205" 11414' -i 2-7/8" TT WLEG ELMD TT NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/86 ORIGINAL COMPLETION 09(28(05 DAV/TLH IBP CORRECTION 07/30(95 SIDETRACK (G-30A) 10/04/05 DAV/TLH PKR CORRRECTOON 01130/02 RNlTP CORRECTIONS 09102/02 SVCfTP KBE CORRECTION 06!04103 ATD/TLP GLV CORRECTIONS 08(13J03 JCNUTLH GLV GO PRUDHOE BAY UNIT WELL: G-30A PERMIT No: '1950760 API No: 50-029-21613-01 SEC 12, T11 N, R13E, 2519' FNL & 2369' FEL 13P Exploration {Alaska) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4269 6390 4120 5989 26 32 McMURRY McMURRY DMY DMY RK RK 0 0 08/13/03 08/13103 _~ O ~ LEAK AND THE REASON FOR HHE STRADDLE Proposed CTD Sidetrack COMPLETION. HORIZONTAL WELL - 70° @ 9654' AND 90° @ 9923' 2201' 3-1/2" SSSV OTIS LANDING NIP, ID = 2.750" O 13-3/8" CSG, 72#, L-80, ID = 12.347" 9-518" CSG, 47#, L-80, ID = 8.681" TOP OF 9-5/8" CSG TOP OF 7" LNR 2684' ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 4269 4120 26 McMURRY DMY RK 0 08/13/03 qq]g~ 1 6390 5989 32 McMURRY DMY RK 0 08/13/03 4478' 6418' 3-1/2" HES X NIP, ID = 2.750" 6430' 9-5/8" X 3-1/2" BAKER SAB PKR ID = 3.25" 9-518" CSG, 47#, L-80, ID = 8.681" 6590' I SIDETRACK WINDOW 6600 - 6645' I 9350' Top of 2-3/8" Liner 9381' 3-1/2" PARKER SWS NIP, ID = 2.75" 9388' 7" X 3-1/2" BAKER SABL-3 PKR, ID = 3.875" 9424' 3-1/2" HES X NIP, ID = 2.750" Top of Cement 9350' O g434' 3-1/2" 10' PERFORATED PUP O 9444' 3-1/2" HES X NIP, ID = 2.750" 9456' 3-1/2" TTL WLEG 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 9456' 9447' ELMD TT LOGGED 08/04/95 9447' ~--~ Top of P8A / KO cement plug 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~~ 9823' ~ ~ \ \~ ~ 9520' ~~ Cement Ramp Liner PERFORATION SUMMARY REF LOG: MWD/GR ON 06/30/95 ANGLE AT TOP PERF: 70 @ 9622' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPWSOZ DATE 2-1 /4" 6 9622 - 9642 O 01 / 15/02 2-1/4" 6 9750 - 9770 O 05/23/01 2-1/4" 6 9780 - 9820 O 05/23/01 2-3/4" 4 9830 - 9950 O 07/24/95 2-3/4" 4 10100 - 10300 O 07/24/95 2-3/4" 4 10350 - 10390 O 07/24/95 . 2-3/4" 4 10760 - 10810 O 07/24/95 2-3/4" 4 10890 - 11100 O 07/24/95 2-3/4" 4 11440 - 11700 S 06/27/96 PBTD ~ 11715' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11800' RN/TP COR iVC/TP KBE ~2-318" cemented 8 perforated liner ~ 11900' 9678' 7" X 5" TNV PKR ID = ???? 10025' 2-1/2" IBP(05/23/01) 11370' 4-1/2" X 2-7/8" BAKER MODEL D PKR ID = 2.688" 11405' 2-7/8" HES X NIP, ID = 2.205" 11414' 2a/8° TT wLEG ELMD TT NOT LOGGED 2-3/8" TBG, a.s#, L-8o, 11414' .0087 bpf, ID = 1.995" PRUDHOE BAY UNfT WELL: G-30A PB~MfT No: 1950760 API No: 50-029-21613-01 SEC 12, T11 N, R13E, 2519' FNL & 2369' FEL TREE = 3" -SM -FMC BP Prudhoe Bay G-30B CTD Sidetrack CTD Sidetrack Summary Rig Work: 1) MIRU Nordic 1 and test BOPE to 250 psi low and 3500 psi high. ~ 2) Mi112.74" window in Shublik interval. 3) Dril13" open hole, 2,230' sidetrack into Zone 1B target. 4) Run solid 2 3/8" liner, cement and test to 2000 psi. 5) Cleanout liner and perforate for production (1000 ft of perfs). 6) Freeze protect well and RDMO. Mud Program: • Well kill: 8.5 ppg e • Milling/drilling• 8.6jppg Flo Pro or biozan for milling, new Flo Pro for drilling. r _ Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 2 3/8", 4.6#, L- -L fully cemented liner. Top of liner to be at 9350' MD (8765ss). • A minimum of 17 bls 15.8 ppg cement will be used for liner cementing. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi! • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 97 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 12,300 ft. • Distance to nearest well within pool - 850 ft. (G-31A) ~g~ng • MWD directional and Gamma Ray will be run over all of the open hole section. MCNL log will be run across the cemented liner. Hazards • The maximum recorded H2S level on G Pad is 2_~m (G-OS on 7/4/05). ~' • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 3100 psi at 8800'ss (6.8 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2220 psi. ~ ~L~ ~ • ~M,~ BP-GDB ~~, tN~c~t~ Baker Hughes INTEQ Planning Report Company;: BP Amoco Date: 12/2112005 Time: 11:33:04 Page: 1 Field: Prudhoe Bay Co-ordinste(NE)Reference: Well: G-30, True North 'Site: PB G Pad Vertical (TVD) Reference: 37:30 5/31/1996 12:51 69.8 Well: G-30 Section(VS)Reference: Well (O.OON,O.OOE,275.OOAzi) Wellpath: Plan 6, G306 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map " <_-Latitude'---> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft "ft `ft ft G-30B Polygon 69.78 -469.86 2268.78 5968700.00 660135.00 70 19 15.777 N 148 42 6.018 W -Polygon 1 69.78 X69.86 2268.78 5968700.00 660135.00 70 19 15.777 N 148 42 6.018 W -Poygon 2 69.78 -455.03 1563.89 5968700.00 659430.00 70 19 15.925 N 148 42 26.589 W -Polygon 3 69.78 -181.76 1174.52 5968965.00 659035.00 70 19 18.613 N 148 42 37.951 W -Polygon 4 69.78 -105.53 165.83 5969020.00 658025.00 70 19 19.364 N 148 43 7.388 W -Polygon 5 69.78 199.95 147.25 5969325.00 658000.00 70 19 22.368 N 148 43 7.930 W -Polygon 6 69.78 102.35 1220.51 5969250.00 659075.00 70 19 21.407 N 148 42 36.607 W -Polygon 7 69.78 65.06 2280.04 5969235.00 660135.00 70 19 21.038 N 148 42 5.685 W G-30B Fauk1 69.78 129.99 2046.34 5969295.00 659900.00 70 19 21.677 N 148 42 12.505 W -Polygon 1 69.78 129.99 2046.34 5969295.00 659900.00 70 19 21.677 N 148 42 12.505 W -Polygon 2 69.78 120.27 2746.34 5969300.00 660600.00 70 19 21.579 N 148 41 52.076 W G-306 Fault2 69.78 349.68 875.61 5969490.00 658725.00 70 19 23.840 N 148 42 46.672 W -Polygon 1 69.78 349.68 875.61 5969490.00 658725.00 70 19 23.840 N 148 42 46.672 W -Polygon 2 69.78 245.49 1073.48 5969390.00 658925.00 70 19 22.815 N 148 42 40.898 W -Polygon 3 69.78 188.92 1622.45 5969345.00 659475.00 70 19 22.258 N 148 42 24.876 W -Polygon 4 69.78 245.49 1073.48 5969390.00 658925.00 70 19 22.815 N 148 42 40.898 W G-30B Fault3 69.78 308.31 464.62 5969440.00 658315.00 70 19 23.434 N 148 42 58.668 W -Polygon 1 69.78 308.31 464.62 5969440.00 658315.00 70 19 23.434 N 148 42 58.668 W -Polygon 2 69.78 335.78 585.24 5969470.00 658435.00 70 19 23.704 N 148 42 55.147 W G-306 Faults 69.78 500.80 -126.50 5969620.00 657720.00 70 19 25.327 N 148 43 15.920 W -Polygon 1 69.78 500.80 -126.50 5969620.00 657720.00 70 19 25.327 N 148 43 15.920 W -Polygon 2 69.78 30.24 -106.39 5969150.00 657750.00 70 19 20.699 N 148 43 15.333 W -Polygon 3 69.78 -370.33 -84.81 5968750.00 657780.00 70 19 16.759 N 148 43 14.703 W -Poygon 4 69.78 30.24 -106.39 5969150.00 657750.00 70 19 20.699 N 148 43 15.333 W G-306 Fault6 69.78 -559.18 1046.55 5968585.00 658915.00 70 19 14.901 N 148 42 41.687 W -Potygon 1 69.78 -559.18 1046.55 5968585.00 658915.00 70 19 14.901 N 148 42 41.687 W -Polygon 2 69.78 -604.58 2015.88 5968560.00 659885.00 70 19 14.453 N 148 42 13.400 W Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map EasNng: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: Tnae Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-30 Slot Name: 30 G-30 Well Position: +N/-S 2256.42 ft Northing: 5969122.01 ft Latitude: 70 19 20.401 N +E/-W 1603.05 ft Easting : 657857.00 ft Longitude: 148 43 12.228 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, G-306 Drilled From: G-30A Tie-on Depth: 9498.95 ft Current Datum: 37:30 5/31/1996 12:51 Height 69.78 ft Above System Datum: Mean Sea Level Magnetic Data: 12/18/2005 Declination: 24.67 deg Field Strength: 57604 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (1'VD) +N/-S +E/-W Direction ft ft ft deg 34.78 0.00 0.00 275.00 ~.. ~ ! ~~~ BP-GDB >tiwT~~ Baker Hughes INTEQ Planning Report rip Company: BP Amoco Dater 12/21/2005 Time: 11:33:04 Page: 2 .Field: Prudhoe Bay Co-ordinatetNE) Reference: W ell: Cr30, True North .Site: PB G Pad ` Vertical (TVD) Reference: 37 :<30 5/31/199612:51 69.8 Well: G-30 Section (VS)`Refereace: W eU (O.OON,O.OOE,275.OOAzi) Wellpat6: Plan 6, G-30B Survey Calcuiatlon Method: 'Minimum Curvature Db: Oracle Targets .:.Map' Map <--- Latitude -> <- Longitude -> Name Descripfion TVD tN/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft -Polygon 3 69.78 -607.84 2645.99 5968570.00 660515.00 70 19 14.419 N 148 41 55.012 W -Polygon 4 69.78 -604.58 2015.88 5968560.00 659885.00 70 19 14.453 N 148 42 13.400 W G-306 Fault4 69.78 -247.71 267.87 5988880.00 658130.00 70 19 17.965 N 148 43 4.411 W -Polygon 1 69.78 -247.71 267.87 5968880.00 658130.00 70 19 17.965 N 148 43 4.411 W -Polygon 2 69.78 -247.08 713.01 5968890.00 658575.00 70 19 17.971 N 148 42 51.420 W G-306 Tgt 2 9024.78 2.28 319.14 5969131.00 658176.00 70 19 20.424 N 148 43 2.914 W G-30B Tgt 1 9034.78 -367.73 2168.90 5968800.00 660033.00 70 19 16.782 N 148 42 8.932 W Annotation MD . TVD ft ft 9498.95 8917.01 TIP 9520.00 8927.45 KOP 9534.00 8934.93 End of 40°/100' DLS 9564.00 8954.50 4 9769.18 9033.93 5 9894.18 9025.36 End of 45°/100' DLS 10344.18 9025.13 7 10909.18 9024.97 8 11209.18 9024.93 9 11469.18 9024.90 10 11750.00 0.00 TD Plan: Plan #6 Date Composed: 12/18/2005 Copy Lamar's Plan6 Version: 3 Principal: Yes Tied-to: User Defined Plan Section Information MD Inc[ Azim TVD' +N!-S +E/-W DLS Buihl Turn TFO Target ft deg deg ft ft ft deg/1OOft degl100ft deg/100ft deg _ 9498.95 60.03 119.10 8917.01 -202.53 2108.26 0.00 0.00 0.00 0.00 9520.00 60.52 117.70 8927.45 -211.22 2124.34 6.23 2.33 -6.65 291.60 9534.00 54.92 117.70 8934.93 -216.72 2134.82 40.00 -40.00 0.00 180.00 9564.00 43.59 127.45 8954.50 -228.77 2153.99 45.00 -37.76 32.49 150.00 9769.18 97.20 213.25 9033.93 -394.40 2154.45 45.00 26.13 41.82 82.00 9894.18 90.03 269.20 9025.36 -451.82 2049.39 45.00 -5.73 44.76 94.80 10344.18 90.02 323.20 9025.13 -260.44 1660.39 12.00 0.00 12.00 90.00 10909.18 90.01 255.40 9024.97 -84.45 1157.70 12.00 0.00 -12.00 270.00 11209.18 90.01 291.40 9024.93 -66.97 863.13 12.00 0.00 12.00 90.00 11469.18 90.01 260.20 9024.90 -41.04 607.64 12.00 0.00 -12.00 270.00 11750.00 90.00 293.89 9024.88 -7.09 332.94 12.00 0.00 12.00 90.00 ~~~ ~ BP-GDB ~NT~Q Baker Hughes INTEQ Planning Report Company: BP AmoCO Date: 12/21/2005 Time: 11:33:04 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: G-30, True North Sites PB G Pad Vertical (TVD) Reference: 37 :30 5/31/1 996 12:51 69.8 Well: G-30 Section (VS) Reference: Well (O.pON,0 .00E,275.00Azi) Wellpath: Piar16; G-3pB Survey Calculation Method: Minimum Curvature Db: Oracle ~ Survey MD Intl A7am SSTYD N/S FJW MapN MapE YS DLS Toolface Tool ft deg deg... ft ft ft ft ft ft degl100(t deg 9498.95 60.03 119.10 8847.23 -202.53 2108.26 5968963.88 659968.91 -2117.89 0.00 0.00 M W D 9500.00 60.05 119.03 8847.76 -202.97 2109.06 5968963.46 659969.71 -2118.72 6.23 291.60 MWD 9520.00 60.52 117.70 8857.67 -211.22 2124.34 5968955.53 659985.16 -2134.67 6.23 291.64 M W D 9530.00 56.52 117.70 8862.89 -215.18 2131.89 5968951.73 659992.79. -2142.54 40.00 180.00 MWD 9534.00 54.92 117.70 8865.15 -216.72 2134.82 5968950.25 659995.75 -2145.58 40.00 180.00 M W D 9540.00 52.59 119.40 8868.69 -219.03 2139.07 5968948.03 660000.05 -2150.02 145.00 150.00 M W D 9550.00 48.78 122.48 8875.03 -223.00 2145.71 5968944.20 660006.77 -2156.98 45.00 149.00 M W D 9560.00 45.05 125.94 8881.86 -227.10 2151.75 5968940.23 660012.89 -2163.35 45.00 147.04 M W D 9564.00 43.59 127.45 8884.72 -228.77 2153.99 5968938.61 660015.17 -2165.73 45.00 144.68 M W D 9570.00 44.03 131.29 8889.05 -231.40 2157.20 5968936.04 660018.43 -2169.16 45.00 82.00 MWD 9580.00 45.05 137.55 8896.18 -236.31 2162.20 5968931.24 660023.54 -2174.57 45.00 79.22 MWD 9590.00 46.39 143.55 8903.17 -241.84 2166.74 5968925.81 660028.19 -2179.57 45.00 74.76 M W D 9600.00 48.03 149.26 8909.96 -247.95 2170.79 5968919.79 660032.37 -2184.14 45.00 70.57 M W D 9610.00 49.94 154.66 8916.53 -254.60 2174.33 5968913.21 660036.05 -2188.25 45.00 66.69 M W D 9620.00 52.08 159.75 8922.82 -261.77 2177.34 5968906.11 660039.20 -2191.87 45.00 63.14 M W D 9630.00 54.44 164.54 8928.81 -269.39 2179.79 5968898.54 660041.81 -2194.97 45.00 59.94 M W D 9640.00 56.97 169.05 8934.44 -277.43 2181.67 5968890.54 660043.87 -2197.55 45.00 57.07 MWD 9650.00 59.65 173.29 8939.70 -285.84 2182.97 5968882.17 660045.34 -2199.58 45.00 54.53 M W D 9660.00 62.46 177.31 8944.54 -294.55 2183.68 5968873.47 660046.24 -2201.05 45.00 52.30 MWD 9670.00 65.39 181.12 8948.93 -303.53 2183.80 5968864.49 660046.55 -2201.95 45.00 50.35 M W D 9680.00 68.40 184.75 8952.86 -312.72 2183.33 5968855.30 660046.27 -2202.28 45.00 48.68 M W D 9686.07 70.27 186.88 8955.00 -318.36 2182.75 5968849.65 660045.81 -2202.20 45.00 47.25 G-306 9690.00 71.49 188.23 8956.29 -322.05 2182.27 5968845.95 660045.40 -2202.03 45.00 46.50 M W D 9700.00 74.64 191.59 8959.20 -331.47 2180.62 5968836.50 660043.95 -2201.21 45.00 46.06 M W D 9710.00 77.84 194.85 8961.58 -340.92 2178.39 5968827.00 660041.92 -2199.82 45.00 45.08 M W D 9720.00 81.08 198.03 8963.41 -350.35 2175.61 5968817.52 660039.34 -2197.87 45.00 44.30 MWD 9730.00 84.34 201.15 8964.68 -359.69 2172.28 5968808.11 660036.21 -2195.37 45.00 43.72 M W D 9740.00 87.62 204.24 8965.38 -368.89 2168.44 5968798.83 660032.56 -2192.33 45.00 43.32 M W D 9750.00 90.91 207.32 8965.51 -377.89 2164.09 5968789.74 660028.40 -2188.79 45.00 43.11 M W D 9760.00 94.20 210.40 8965.06 -386.64 2159.27 5968780.90 660023.77 -2184.75 45.00 43.07 M W D 9769.18 97.20 213.25 8964.15 -394.40 2154.45 5968773.04 660019.12 -2180.63 45.00 43.21 M W D 9780.00 96.77 218.13 8962.83 -403.12 2148.19 5968764.19 660013.04 -2175.15 45.00 94.80 MWD 9790.00 96.32 222.64 8961.69 -410.68 2141.75 5968756.49 660006.76 -2169.40 45.00 95.39 M W D 9800.00 95.84 227.14 8960.63 X17.73 2134.74 5968749.30 659999.90 -2163.02 45.00 95.91 MWD 9810.00 95.32 231.63 8959.66 -424.20 2127.19 5968742.67 659992.48 -2156.06 45.00 96.39 M W D 9820.00 94.77 236.11 8958.78 -430.07 2119.14 5968736.63 659984.57 -2148.56 45.00 96.82 M W D 9830.00 94.19 240.59 8958.00 -435.30 2110.66 5968731.22 659976.19 -2140.56 45.00 97.22 M W D 9840.00 93.59 245.06 8957.32 -439.86 2101.78 5968726.48 659967.42 -2132.12 45.00 97.57 M W D 9850.00 92.96 249.52 8956.75 -443.71 2092.58 5968722.44 659958.29 -2123.29 45.00 97.87 M W D 9860.00 92.32 253.98 8956.28 -446.84 2083.09 5968719.11 659948.88 -2114.11 45.00 98.13 M W D 9870.00 91.66 258.44 8955.94 -449.22 2073.39 5968716.53 659939.23 -2104.65 45.00 98.33 MWD 9880.00 90.99 262.89 8955.71 -450.84 2063.53 5968714.70 659929.40 -2094.97 45.00 98.49 M W D 9890.00 90.32 267.34 8955.59 -451.69 2053.57 5968713.64 659919.46 -2085.12 45.00 98.59 MWD 9894.18 90.03 269.20 8955.58 -451.82 2049.39 5968713.42 659915.29 -2080.97 45.00 98.64 M W D 9900.00 90.03 269.89 8955.58 -451.87 2043.57 5968713.25 659909.47 -2075.17 12.00 90.00 M W D 9925.00 90.03 272.89 8955.56 -451.26 2018.58 5968713.34 659884.48 -2050.23 12.00 90.00 M W D 9950.00 90.03 275.89 8955.54 -449.34 1993.65 5968714.73 659859.52 -2025.23 12.00 90.00 MWD 9975.00 90.03 278.89 8955.53 -446.13 1968.87 5968717.42 659834.67 -2000.26 12.00 90.00 M W D 10000.00 90.03 281.89 8955.52 -441.62 1944.28 5968721.41 659810.00 -1975.37 12.00 90.01 MWD 10025.00 90.03 284.89 8955.50 -435.83 1919.96 5968726.69 659785.56 -1950.64 12.00 90.01 M W D 10050.00 90.03 287.89 8955.49 -428.77 1895.98 5968733.24 659761.44 -1926.14 12.00 90.01 M W D 10075.00 90.03 290.89 8955.47 X20.47 1872.40 5968741.04 659737.70 -1901.92 12.00 90.01 M W D 10100.00 90.03 293.89 8955.46 -410.95 1849.29 5968750.08 659714.39 -1878.07 12.00 90.01 M W D ~i~^ n BP-GDB Baker Hughes INTEQ Planning Report ~~ Survey MD Incl Azim ft 'deg deg 10125.00 90.03 296.89 10150.00 90.03 299.89 10175.00 90.03 302.89 10200.00 90.03 305.89 10225.00 90.03 308.89 10250.00 90.03 311.89 10275.00 90.02 314.89 10300.00 90.02 317.89 10325.00 90.02 320.89 10344.18 90.02 323.20 10350.00 90.02 322.50 10375.00 90.02 319.50 10400.00 90.02 316.50 10425.00 90.02 313.50 10450.00 90.02 310.50 10475.00 90.02 307.50 10500.00 90.02 304.50 10525.00 90.02 301.50 10550.00 90.02 298.50 10575.00 90.02 295.50 10600.00 90.02 292.50 10625.00 90.02 289.50 10650.00 90.02 286.50 10675.00 90.02 283.50 10700.00 90.01 280.50 10725.00 90.01 277.50 10750.00 90.01 274.50 10775.00 90.01 271.50 10800.00 90.01 268.50 10825.00 90.01 265.50 10850.00 90.01 262.50 10875.00 90.01 259.50 10900.00 90.01 256.50 10909.18 90.01 255.40 10925.00 90.01 257.29 10950.00 90.01 260.29 10975.00 90.01 263.29 11000.00 90.01 266.29 11025.00 90.01 269.29 11050.00 90.01 272.29 11075.00 90.01 275.29 11100.00 90.01 278.29 11125.00 90.01 281.29 11150.00 90.01 284.29 11175.00 90.01 287.29 11200.00 90.01 290.29 11209.18 90.01 291.40 11225.00 90.01 289.50 11250.00 90.01 286.50 11275.00 90.01 283.50 11300.00 90.01 280.50 11325.00 90.01 277.50 ft 8955.44 8955.43 8955.42 8955.41 8955.39 8955.38 8955.37 8955.36 8955.35 8955.35 8955.34 8955.33 8955.33 8955.32 8955.31 8955.30 8955.29 8955.28 8955.27 8955.27 8955.26 8955.25 8955.24 8955.24 8955.23 8955.22 8955.22 8955.21 8955.21 8955.20 8955.20 8955.19 8955.19 8955.19 8955.19 8955.18 8955.18 8955.18 8955.17 8955.17 8955.17 8955.16 8955.16 8955.16 8955.15 8955.15 8955.15 8955.15 8955.15 8955.14 8955.14 8955.14 N!S ENV ft ft -400.23 1826.71 -388.34 1804.72 -375.32 1783.38 -361.20 1762.75 -346.02 1742.89 -329.82 1723.86 -312.64 1705.69 -294.54 1688.45 -275.57 1672.18 -260.44 1660.39 -255.80 1656.87 -236.38 1641.14 -217.80 1624.41 -200.13 1606.73 -183.40 1588.16 -167.67 1568.73 -152.98 1548.51 -139.37 1527.54. -126.87 1505.89 -115.52 1483.62 -105.36 1460.78 -96.40 1437.45 -88.68 1413.67 -82.21 1389.53 -77.01 1365.07 -73.10 1340.39 -70.49 1315.52 -69.18 1290.56 -69.19 1265.56 -70.49 1240.60 -73.11 1215.74 -77.02 1191.05 -82.22 1166.60 -84.45 1157.70 -88.18 1142.32 -93.04 1117.80 -96.61 1093.06 -98.88 1068.17 -99.84 1043.19 -99.49 1018.20 -97.84 993.25 -94.88 968.43 -90.63 943.80 -85.09 919.42 -78.29 895.37 -70.24 871.70 -66.97 863.13 -61.44 848.30 -53.72 824.53 -47.25 800.38 -42.05 775.93 -38.15 751.24 MapN MapE. VS ft ft ft 5968760.32 659691.59 -1854.64 5968771.74 659669.36 -1831.70 5968784.31 659647.75 -1809.30 5968797.99 659626.83 -1787.53 5968812.75 659606.66 -1766.42 5968828.54 659587.29 -1746.04 5968845.33 659568.77 -1726.45 5968863.06 659551.15 -1707.70 5968881.69 659534.49 -1689.84 5968896.56 659522.38 -1676.77 5968901.13 659518.76 -1672.86 5968920.21 659502.63 -1655.50 5968938.43 659485.52 -1637.21 5968955.73 659467.47 -1618.06 5968972.06 659448.55 -1598.10 5968987.38 659428.80 -1577.37 5969001.64 659408.27 -1555.95 5969014.81 659387.02 -1533.88 5969026.85 659365.12 -1511.22 5969037.72 659342.61 -1488.04 5969047.41 659319.57 -1464.41 5969055.87 659296.05 -1440.38 5969063.09 659272.12 -1416.02 5969069.05 659247.85 -1391.40 5969073.73 659223.29 -1366.59 5969077.12 659198.53 -1341.66 5969079.21 659173.62 -1316.66 5969079.99 659148.64 -1291.68 5969079.46 659123.65 -1266.78 5969077.63 659098.72 -1242.03 5969074.49 659073.92 -1217.49 5969070.06 659049.32 -1193.23 5969064.35 659024.99 -1169.33 5969061.93 659016.13 -1160.65 5969057.88 659000.84 -1145.66 5969052.50 658976.43 -1121.66 5969048.42 658951.77 -1097.32 5969045.63 658926.93 -1072.72 5969044.14 658901.98 -1047.92 5969043.96 658876.99 -1022.99 5969045.09 658852.02 -998.00 5969047.52 658827.14 -973.02 5969051.26 658802.43 -948.11 5969056.28 658777.94 -923.34 5969062.57 658753.75 -898.79 5969070.13 658729.93 -874.51 5969073.21 658721.28 -865.68 5969078.42 658706.35 -850.43 5969085.65 658682.42 -826.07 5969091.60 658658.14 -801.46 5969096.28 658633.59 -776.64 5969099.67 658608.82 -751.71 DLS Toolface Tool deg/100ft deg 12.00 90.01 M W D 12.00 90.02 MWD 12.00 90.02 M W D 12.00 90.02 M W D 12.00 90.02 M W D 12.00 90.02 M W D 12.00 90.02 M W D 12.00 90.02 M W D 12.00 90.03 M W D 12.00 90.03 M W D 12.00 270.00 MWD 12.00 270.00 M W D 12.00 270.00 M W D 12.00 270.00 M W D 12.00 270.00 M W D 12.00 270.00 M W D 12.00 269.99 MWD 12.00 269.99 M W D 12.00 269.99 M W D 12.00 269.99 M W D 12.00 269.99 M W D 12.00 269.99 MWD 12.00 269.99 M W D 12.00 269.99 M W D 12.00 269.99 M W D 12.00 269.99 M W D 12.00 269.99. M W D 12.00 269.98 M W D 12.00 269.98 MWD 12.00 269.98 M W D 12.00 269.98 M W D 12.00 269.98 M W D 12.00 269.98 M W D 12.00 269.98 M W D 12.00 90.00 MWD 12.00 90.00 M W D 12.00 90.00 MWD 12.00 90.00 MWD 12.00 90.00 M W D 12.00 90.00 MWD 12.00 90.00 M W D 12.00 90.00 M W D 12.00 90.00 M W D 12.00 90.00 MWD 12.00 90.00 M W D 12.00 90.00 M W D 12.00 90.00 MWD 12.00 270.00 M W D 12.00 270.00 M W D 12.00 270.00 M W D 12.00 270.00 M W D 12.00 270.00 M W D ~~~ ! i $ BP-GDB ~~TEt~ Baker Hughes INTEQ Planning Report ~'~ Company:; BP Amoco Date: 12121/2005 Time: 11:33:04 Page: 5 :Field: PFudhoe Bay Co-ordinate(NE) Reference: Well: G-30, True North Site: PB G Pad Vertical (TVD) Reference: 37 :30 5/31/1 996 12:51 69.8 Welly G-30 Section(VS)Reference: Well (O.OON,O .OOE,275.OOAzi) Wellpath: Plan 6, G306 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl ` Azim SSTYD N/S F./W -MapN MapE YS DLS Toolface Tool ft deg deg ft ft' ft ft ft ft deg/100ft deg 11350.00 90.01 274.50 8955.14 -35.53 726.38 5969101.76 658583.92 -726.72 12.00 270.00 MWD 11375.00 90.01 271.50 8955.13 -34.23 701.42 5969102.54 658558.93 -701.73 12.00 270.00 M W D 11400.00 90.01 268.50 8955.13 -34.23 676.42 5969102.02 658533.94 -676.83 12.00 270.00 MWD 11425.00 90.01 265.50 8955.13 -35.54 651.46 5969100.18 658509.01 -652.08 12.00 270.00 M W D 11450.00 90.01 262.50 8955.13 -38.15 626.60 5969097.05 658484.22 -627.54 12.00 270.00 MWD 11469.18 90.01 260.20 8955.12 -41.04 607.64 5969093.76 658465.32 -608.90 12.00 270.00 MWD 11475.00 90.01 260.89 8955.12 -41.99 601.90 5969092.69 658459.60 -603.27 12.00 90.00 M W D 11500.00 90.01 263.89 8955.12 -05.30 577.12 5969088.86 658434.90 -578.87 12.00 90.00 M W D 11525.00 90.01 266.89 8955.12 -47.31 552.20 5969086.33 658410.04 -554.23 12.00 90.00 M W D 11550.00 90.01 269.89 8955.12 -48.01 527.22 5969085.10 658385.07 -529.39 12.00 90.00 M W D 11575.00 90.01 272.89 8955.11 -47.40 502.23 5969085.18 658360.08 -504.45 12.00 90.00 M W D 11600.00 90.01 275.89 8955.11 -45.49 477.30 5969086.57 658335.12 -479.45 12.00 90.00 M W D 11625.00 90.01 278.89 8955.11 -42.27 452.51 5969089.27 658310.27 -454.48 12.00 90.00 MWD 11650.00 90.00 281.89 8955.11 -37.76 427.93 5969093.26 658285.60 -429.59 12.00 90.00 M W D 11675.00 90.00 284.59 8955.11 -31.97 403.61 5969098.54 658261.16 -404.86 12.00 90.00 M W D 11700.00 90.00 287.89 8955.10 -24.91 379.63 5969105.09 658237.04 -380.36 12.00 90.00 M W D 11725.00 90.00 290.89 8955.10 -16.61 356.05 5969112.89 658213.29 -356.14 12.00 90.00 MWD 11750.00 90.00 293.89 8955.10 -7.09 332.94 5969121.92 658189.99 -332.29 12.00 90.00 M W D • • S ~ • • are i (n of bag ~ BAG of bag slips Blind/Shears TOTs ~ 2" combi ram/slips ~ -~ Mud Cross I I Mud Cross middle of flow cross of blind/shears 2 3/8" ram TOTs 2" combi ram/slips V Flow Tee • • TERRIE L NUBBLE s9-6/1252 245 BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 oarE ~~" ~~ "~S PAY TO THE ~ ~~ $ ~ ( J' J ~~ ORDER OF w ~ First National Bank Alaska Anchorage, AK 9950 MEMO ~: L 25 200060:99 L4~~~6 2 27~~~ L556~~' 0 245 i i a • TRANSIVIITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TILANSvIITTAL LETTER WELL NA1'IE ~~G~ ~~ 3~~ PTD# 7 4 S -~ Z, D~ CHECK WHAT APPLIES ADD-ONS (OPTIONS MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE , In accordance with 20 AAC 25.005(fj, all (per ~ records, data and togs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PIT) and API number (50 - 70/80) from records, data and togs acquired for well (name on permit). SPACING ,The permit is approved subject to full EXCEPTION i compliance with 20 AAC 25.055. Approval to ;perforate and produce/infect is contingent upon issuance of a conservation order '~ approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE i Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. "CLUE" The permit is for a new wellbore segment of existing well , Permit No, API No. Production should continue to be reported as a function of .the original API number stated above. Rev: 04/01/05 C\jody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 _ -Well Name: PRUDHOE BAY UNIT G_306 _ _ -------Program 9EV_._______._ Well bore seg PTD#:2052080 Company ~P EXPLORATION_(ALASKA~INC ___ Initial ClasslType _ DEV/ 1-01L__GeoArea 890 __ ________- Unit 1_1.650- __ OnlOff Shore On ___ ___ Annular Disposal Administration 1-; Permitfee attached- - . - - - .. _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - Yes - - . 2 Lease number appropriate-___ ........................... __..--.Yes _ _ _ 3 Unique well_name and number _ _ _ _ - - _ .. - Yes _ _ _ _ _ - ; 4 Well located ins_defnedpool_-._---__-______ --. _---__---Yes _ i 5 Well located proper distance from drilling unit_boundary- _ _ - - - - - _ _ - - - .Yes 6 Well located proper distance from other wells__--------------- - --__.. -Yes- _____ ______ _____________ ____ 7 Sufficient acreage available in-driilinq unit- - .. - .Yes - 8 If deviated, is_wellbore platincluded : _ _ - _ _ Yes - _ - - _ _ - _ _ _ - - _ _ _ _ _ . _ 9 Operator only affected party- . - - _ - - _ - .. Yes . . 10 -Operator has appropriate_bond in force .... - . - . - . - .... Yes - 11 Permit can be issued without conservation order,. - - - - _ _ - - Yes . . - ... - . - Appr Date 12 Permit-rzn be issued without administrative_approval _ _ _ _ , - - - - - - - - - - - - - - - - - - - Yes _ - . - . _ _ _ _ i RPC 1212212005 13 Can permit be approved before 15-daywait- - - - - - - - - - - - - - - - _ ... Yes j 1 14 Well located within area and strata authorized by_Injection O[der# (put_IO# in-comments)_(for, NA_ . - 15 All wells-within 1l4_mil_e area of review identified (For service:well only) NA- - - . , - - 1.6 Pre-produced injector;. duration of pre production Less than-3 months_(For seNire well-only) - . NA_ _ ACMP_Finding of Consistency. has been issued-for_this project- _ . NA . .. - - --- ---- -- -- ---- Engineering 1 18 Conductor stung provided - _ - NA_ - 19 Surface casing-protects all-known USDWs - - NA_ _ _ 20 CMT_v9l adequate-to circulate on conductor&surfcsg - - - - - - - - -- - - - - - - - - N_A_ - . - - - . _ - - . 21 CMT-votadeguate.to tie-in long string to surf csg- - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT-will cover all knownproductiye horizons- - - _ - - _ _ - _ - - . . - _ - Yes .. _ Adequate excess, 23 Casing designs adequate fo[ C, T B &_permafrost- _ _ _ _ _ _ _ - . - - _ - - - - - - -- - - - - -Yes 24 Adequate tankage-or reserve pit - _ - .. Yes - . . - . - CTDU. - _ - ... - 25 If_a_re-drill, has-a-10-403 for abandonment been approved - - - _ _ _ _ _ _ _ - _ - _ . _ _ _ Yes - ...' .. - . - - _ - . - . .. _ - _ _ - 26 Adequate wellbore separationproposed- - - - Yes 27 If diverter required., does it meet_regulations- - - - - - - - - - - - - - NA_ Sidetrack. - Appr Date 28 Drilling fluid-program schematic & equip list adequate- - - - - - - - - - - - - - - - - - - - - _ - _ Yes - ... - . - Max MW 8,6 Rpg, - - - .. _ - - - - _ . - _ - _ _ _ _ _ - _ _ _ - - WGA 1212212005 129 BOPEs, do they meet re ulation _ 9 Yes - - - - - - - - - - - - - - - - - _ _ . ~30 BOPE_press rating appropriate; test to_(put psig in comments). _ _ . Yes - - - .. Test to 3500-psi. -MSP 2220 psi.- , - - - - _ _ 31 Choke-manifold complies WIAPI-RP-53(May84)___________________ _____-.-Yes. -.. _- _ __ - ___ ________ _____ ___ ___ _ -___-__- 32 Work will occur without operation shutdown- _ - - _ - - - Yes - ~33 Js presence of H?S gas- probable - - - .. - - No 20 ppm. on.pad. - _ 34 Mechanical condition of wells within AOR verified ~For_service well onty) - - _ _ - NA_ -- Geology X 35 ---- Permit can be issuedwlohydrogensulfidemeasures________________ _________No._ -.- ___ _ -__ - ---_--- -__ -_--_ _..... i 36 Data-presented on_ potential overpressure zones _ _ _ _ _ _ _ _ _ _ - . _ _ _ - - - - _ - - - _ NA_ _ _ _ _ _ _ _ _ _ _ _ ... _ Appr Date 37 Seismic analysisof shallow gas,zones_ NA- - - RPC 1212212005 38 Seabed condition survey-(if off shore) . _ NA- - - 39 Contact namelphone for weekly progress reports- [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- - . Geologic Engineering P lic Date Date: ' Date Commissioner: C i tier Commissioner: prs ~z~~~ ~ l ~~ ^Z Z _~ • • • Well History File APPENDIX Information of detailed nature that is not particularly germane io 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 inforrnaiion. ~~- - Sperry-Sun Dri~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 23 15:31:50 2006 Reel Header Service name .............LISTPE Date .....................06/02/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/02/23 ~ Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF a Scientific Technical Services ~}~u3 Scientific Technical Services Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: G-30B API NUMBER: 500292161302 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 23-FEB-06 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0004148159 MW0004148159 MW0004148159 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: B. LAULE/R. B. LAULE/R. B. LAULE/R. MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: MW0004148159 MW0004148159 MW0004148159 LOGGING ENGINEER: S. LATZ B. JAHN B. JAHN OPERATOR WITNESS: B. LAULE/R. R. WHITLOW/J R. WHITLOW/J MWD RUN 8 MWD RUN 9 JOB NUMBER: MW0004148159 MW0004148159 LOGGING ENGINEER: B. JAHN B. JAHN OPERATOR WITNESS: R. WHITLOW/J R. WHITLOW/J SURFACE LOCATION SECTION: 12 TOWNSHIP: 11N RANGE: 13E FNL: 2519 FSL: FEL: 2369 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 69.78 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.000 7.000 9519.0 r: 1. ALL DEPTHS ARE MEASURED DEPTH (MD} UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED OFF A CEMENT RAMP WITHIN THE 7" CASING OF THE G-30A WELLBORE. THE TOP OF THE RAMP IS AT 9513'MD/8854'TVDSS, AND THE TOP OF THE WINDOW IS AT 9519'MD/8858'TVDSS. 4. MWD RUNS 1-9 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO DATA WERE ACQUIRED ON MWD RUN 7. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 2/23/06. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-6,8,9 REPRESENT WELL G-30B WITH API #: 50-029-21613-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11,860' MD / 8,959' TVDSS SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type,..>............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8914.0 11833.5 ROP 9500.0 11863.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 8914.0 8913.0 8915.0 8914.0 8917.0 8916.0 8919.5 8918.0 8922.0 8922.5 8928.0 8927.0 8930.0 8928.5 8933.0 8930.0 8935.5 8934.5 8943.0 8941.5 8944.5 8944.5 8948.5 8947.5 8957.0 8956.5 8961.5 8961.0 8970.0 8969.5 8977.0 8975.0 8992.5 8991.0 9021.5 9017.0 9026.0 9022.5 9028.0 9026.0 9030.5 9029.5 9032.5 9031.0 9046.5 9046.0 9049.0 9048.5 9055.0 9054.5 9056.0 9056.0 9062.0 9062.5 9064.0 9064.5 9068.0 9068.5 9071.0 9071.5 9080.5 9081.5 9083.0 9084.0 9099.0 9099.0 9107.5 9106.5 9113.5 9113.5 9119.5 9119.0 9122.5 9122.5 9128.5 9127.5 9131.5 9130.5 9133.5 9133.0 9145.0 9145.0 9153.5 9152.0 9156.5 9154.5 9176.5 9175.5 9182.0 9179.5 9186.0 9184.5 9193.5 9192.0 9208.5 9206.5 9232,5 9231.0 9425.5 9424.0 9436,5 9437.0 9447.5 9447.0 9452.0 9450.5 9454.0 9452.5 9486.0 9485.5 9503.0 9502,5 9525.5 9522.0 9528.5 9525.0 9530.5 9528.0 9535.5 9532.5 9540.5 9537.5 9544.0 9541.0 9551.0 9548.0 9554.0 9557.0 9562.0 9565.0 9571.0 9585.5 9588.5 9596.5 9605.5 9618.0 9619.5 9622.5 9624.0 9628.5 9639.0 9647.0 9650.0 9654.5 9662.0 9666.0 9670.5 9699.5 9702.0 9719.0 9728.0 9733.5 9761.5 9767.5 9796.0 9807.0 9813.0 9817.5 9858.0 9874.0 9888.5 9897.5 9915.0 9926.5 9985.0 9996.0 10016.5 10023.0 10032.0 10041.5 10053.0 10066,5 10086.5 10098.5 10101.5 10108.0 10109.0 10113.0 10115.0 10144.0 10149.0 10165.0 10189.0 10197.5 10208.5 10216.0 10218.5 10229.0 10234.0 10263.5 10280.0 10290,0 10295.5 10305,5 9550 9553.5 9558.0 9562.0 9567.0 9581.5 9585.5 9593.5 9602.5 9614.5 9616.5 9619.0 9620.5 9625.0 9635.5 9644.0 9647.5 9651.0 9659.0 9663.0 9668.0 9695.5 9698.0 9717.0 9725.0 9732.0 9759.5 9763.5 9793.0 9806.0 9811.5 9815.5 9857.0 9873.0 9886.5 9895.5 9912.5 9923.5 9983.5 9995.0 10014.0 10022.5 10032.0 10041.0 10052.0 10065.0 10084.5 10098.5 10100.5 10106.0 10110.0 10112.5 10115.5 10143.5 10148.5 10165.5 10187.5 10195.5 10207.0 10214.5 10217.0 10227.5 10234.0 10263.5 10278.0 10286.0 10293.0 10302.0 10317.5 10335.5 10341.0 10349.5 10378.0 10404.0 10406.5 10430.5 10437.0 10445.5 10449.5 10457.0 10459.5 10462.0 10464.5 10493.0 10540.5 10581.5 10608.0 10620.5 10636.5 10652.0 10656.5 10672.5 10686.0 10688.5 10804.5 10865.5 10891.5 10895.5 10904.0 10924.5 10929.5 10934.0 10937.5 10947.0 10953.5 10965.0 10973.0 10976.5 10979.5 10991.0 10996.5 11020.0 11024.5 11037.0 11044.0 11050.5 11061.5 11065.0 11070,5 11083.5 11125.0 11137.0 11144.5 11151.5 11165.5 11171.0 11177.0 11179.0 11183.0 11189.0 11201.0 11206.5 11217.5 11226.5 11241.0 11245.0 10313. 5~ 10333.0 10339.0 10348.0 10376.5 10403.0 10405.5 10428.5 10432.5 10442.5 10445.5 10452.0 10456.0 10459.5 10462.0 10491.5 10536.5 10581.0 10607.0 10618.0 10635.0 10648.5 10655.0 10672.5 10683.5 10685.5 10799.5 10860.5 10885.0 10890.0 10897.5 10919.5 10925.5 10931.0 10933.0 10941.5 10946.0 10959.0 10968.5 10971.5 10974.5 10986.5 10992.0 11013.5 11017.5 11030.5 11038.0 11045.5 11055.5 11059.0 11066.5 11081.5 11124.0 11137.5 11145.5 11153.5 11167.0 11170.0 11174.5 11176.0 11180.5 11188.0 11197.5 11205.5 11217.0 11223.5 11239.0 11244.5 • 11249.5 11253.5 11254.5 11259.5 11263.0 11264.5 11269.0 11271.0 11275.5 11280.0 11285.5 11294.5 11296.5 11300.0 11318.5 11322.5 11343.5 11349.0 11352.0 11360.0 11364.5 11375.0 11389.5 11440.5 11443.0 11466.0 11469.5 11471.5 11477.5 11479.0 11482.5 11487.0 11520.5 11527.5 11533.5 11541.0 11546.5 11557.5 11560.5 11565.0 11577.5 11585.0 11589.0 11597.0 11611.5 11639.0 11643.0 11652.0 11668.5 11679.5 11682.0 11685.5 11692.0 11700.0 11712.0 11719.5 11727.5 11743.0 11749.5 11759.0 11764.0 11767.5 11769.5 11774.5 11779.0 11781.5 11785.0 11863.5 11249. 11254.0 11255.5 11258.5 11261.5 11264.5 11267.5 11269.0 11274.5 11279.5 11284.5 11292.5 11295.0 11298.5 11316.0 11319.0 11340.0 11344.5 11348.5 11356.5 11361.0 11371.5 11385.5 11436.5 11439.5 11461.5 11465.0 11467.5 11472.5 11476.0 11481.0 11486.5 11521.5 11531.5 11538.0 11546.5 11550.0 11557.0 11561.0 11565.0 11578.5 11585.0 11590.0 11596.5 11610.5 11637.5 11641.5 11650.0 11668.5 11677.5 11681.0 11683.5 11689.5 11698.5 11706.5 11714.5 11724.0 11740.5 11747.0 11755.5 11759.5 11763.5 11766.5 11772.0 11775.5 11778.0 11782.0 11860.0 S MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 8913.0 9519.0 MWD 2 9519.0 9530.0 MWD 3 9530.0 9535.0 MWD 4 9535.0 9853.0 MWD 5 9853.0 11112.0 MWD 6 11112.0 11534.0 MWD 8 11534.0 11575.0 MWD 9 11575.0 11860.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8914 11863.5 10388.8 5900 8914 11863.5 GR MWD API 9.3 387.36 55.2916 5469 8914 11833.5 ROP MWD FT/H 0.01 3429.69 121,441 4728 9500 11863.5 First Reading For Entire File..........8914 Last Reading For Entire File...........11863.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name....,......STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 • Comment Record FILE HEADER • FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8913.0 9493.0 ROP 9500.0 9519.0 LOG HEADER DATA DATE LOGGED: 08-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9519.0 TOP LOG INTERVAL (FT): 9513.0 BOTTOM LOG INTERVAL (FT) 9519.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 2.750 DRILLER'S CASING DEPTH (FT) 6590.0 BOREHOLE CONDITIONS MUD TYPE: KCL Water MUD DENSITY (LB/G) 8.30 MUD VISCOSITY (S) 65.0 MUD PH: .0 MUD CHLORIDES (PPM): 14000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 133.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type,....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing...........~......60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8913 9519 9216 1213 8913 9519 GR MWDO10 API 9.3 3 87.36 27.2686 790 8913 9493 ROP MWDO10 FT/H 2.65 16.11 13.459 39 9500 9519 First Reading For Entire File..........8913 Last Reading For Entire File...........9519 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type...... .........LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9493.5 9500,5 ROP 9519.5 9530.0 LOG HEADER DATA DATE LOGGED: 09-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9530.0 TOP LOG INTERVAL (FT): 9519.0 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 PCG Natural gamma ray BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 9530.0 .0 .0 TOOL NUMBER TLG016 2.750 6590.0 KCL Fluid 8.30 65.0 .0 14000 .0 .000 .0 .000 154.3 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9493.5 9530 9511.75 74 9493.5 9530 GR MWD020 API 17.81 20.96 19.0667 15 9493.5 9500.5 ROP MWD020 FT/H 0.01 1 40.88 13,733 22 9519.5 9530 First Reading For Entire File......~....9493.5 Last Reading For Entire File...........9530 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY • run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9501.0 9508.5 ROP 9530.5 9535.0 LO G HEADER DATA DATE LOGGED: 10-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9535.0 TOP LOG INTERVAL (FT) 9530.0 BOTTOM LOG INTERVAL (FT) 9535.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 2.750 DRILLER'S CASING DEPTH (FT) 9456.0 BOREHOLE CONDITIONS MUD TYPE: KCL Fluid MUD DENSITY (LBjG): 8.30 MUD VISCOSITY (S) 65.0 MUD PH: .0 MUD CHLORIDES (PPM): 14000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TE~RATURE (MT) .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 158.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN}; EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .IIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9501 9535 9518 69 9501 9535 GR MWD030 API 19.26 26.32 22.0231 16 9501 9508.5 ROP MWD030 FT/H 2.36 16.43 10.82 10 9530.5 9535 First Reading For Entire File..........9501 Last Reading For Entire File...........9535 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9509.0 9829.0 ROP 9535.5 9853.0 LOG HEADER DATA DATE LOGGED: 10-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9853.0 TOP LOG INTERVAL (FT) 9535.0 BOTTOM LOG INTERVAL (FT) 9853.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 44.5 MAXIMUM ANGLE: 92.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.000 DRILLER'S CASING DEPTH (FT) 9456.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATTNG TERMPERATURE: .000 150.1 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: S Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record...~......Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9509 9853 9681 689 9509 9853 GR MWD040 API 18.31 172.32 59.5984 641 9509 9829 ROP MWD040 FT/H 2.52 143.74 65.9302 636 9535.5 9853 First Reading For Entire File..........9509 Last Reading For Entire File...........9853 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation..,....06/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9829.5 11088.0 ROP 9853.5 11112.0 LOG HEADER DATA DATE LOGGED: 12-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11112.0 TOP LOG INTERVAL (FT): 9853.0 BOTTOM LOG INTERVAL (FT) 11112.0 BIT ROTATING SPEED (RPM) • HOLE INCLINATION (DEG MINIMUM ANGLE: 86.0 MAXIMUM ANGLE: 97.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.000 DRILLER'S CASING DEPTH (FT) 9456.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 171.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD050 API 4 1 68 4 2 ROP MWD050 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9829.5 11112 10470.8 2566 9829.5 11112 GR MWDO50 API 28.51 191.52 62.3714 2518 9829.5 11088 ROP MWD050 FT/H 3.6 3429.69 142.694 2518 9853.5 11112 First Reading For Entire File..........9829.5 Last Reading For Entire File...........11112 ~; , e mY, . , ~r • s Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11088.5 11504.0 ROP 11112.5 11534.0 LOG HEADER DATA DATE LOGGED: 14-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11534.0 TOP LOG INTERVAL (FT) 11112.0 BOTTOM LOG INTERVAL (FT) 11534.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.4 MAXIMUM ANGLE: 95.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.000 DRILLER'S CASING DEPTH (FT) 9456.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 36400 FLUID LOSS (C3) 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 0 MUD AT MAX CIRCULA~G TERMPERATURE: .000 17~ MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (TN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD060 API 4 1 68 4 2 ROP MWD060 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11088.5 11534 11311.3 892 11088.5 11534 GR MWD060 API 31.59 199.78 61.4088 832 11088.5 11504 ROP MWD060 FT/H 0.06 956.61 114.431 844 11112.5 11534 First Reading For Entire File..........11088.5 Last Reading For Entire File...........11534 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER • FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11504.5 11549.5 ROP 11534.5 11575.0 LOG HEADER DATA DATE LOGGED: 15-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11575.0 TOP LOG INTERVAL (FT) 11534.0 BOTTOM LOG INTERVAL (FT) 11575.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 93.9 MAXIMUM ANGLE: 95.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.000 DRILLER'S CASING DEPTH (FT) 9456.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 8.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 180.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value............ • ......-999 • Depth Units ..... ............ ...... Datum Specificat ion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD080 API 4 1 68 4 2 ROP MWD080 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11504.5 11575 11539.8 142 11504.5 11575 GR MWD080 API 32.2 70.4 40.7116 91 11504.5 11549.5 ROP MWD080 FT/H 4.43 188.12 58.8271 82 11534.5 11575 First Reading For Entire File..........11504.5 Last Reading For Entire File...........11575 File Trailer Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF File Header Service name .............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11550.0 11830.0 ROP 11575.5 11860.0 LOG HEADER DATA DATE LOGGED: 16-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11860.0 TOP LOG INTERVAL (FT) 11575.0 BOTTOM LOG INTERVAL (FT) 11860.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG • • MINIMUM ANGLE: 81.9 MAXIMUM ANGLE: 95.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma raY TOOL NUMBER TLG005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 3.000 9456.0 Flo Pro 8.60 65.0 9.1 24000 8.4 .000 .0 .000. 188.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD090 API 4 1 68 4 2 ROP MWD090 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11550 11860 11705 621 11550 11860 GR MWD090 API 29.5 125.58 54.225 561 11550 11830 ROP MWD090 FT/H 17.73 343.8 122.149 570 11575.5 11860 First Reading For Entire File..........11550 Last Reading For Entire File...........11860 File Trailer Service name............~SLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06j02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.010 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/02/23 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/02/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF • Scientific Technical Services Scientific Technical Services End Of LIS File