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Home My WebLink About201-068 • • McMains, Stephen E (DOA) From: Lastufka, Joseph N (Northern Solutions) [Joseph.Lastufka @bp.com] Sent: Thursday, July 12, 2012 3:32 PM To: McMains, Stephen E (DOA) Subject: B -05B 10 -407, PTD 201 -068 Steve, I had a typo on the Surface Location on this 10 -407, 1600' should be FEL, not FWL. Thanks! Joe SLiD JUL 2. ReDMs JUL 13 2t 1? ,'ED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL t , I WELL COMPLETION OR RECOMPLETION REP(t 1 :OG r ,., t.o �lmisq, 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1 b. Well CIA , r, t , 20AAC 25 105 20AAC 25.110 ® Development Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completion Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., o ban. : 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 6/16/2012 • 201 - 068 • 312 - 189 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 5/12/2001 50 029 - 20276 - 02 - 00 - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 5/30/2001 PBU B -05B ' 855' FNL, 1600' F ,L, Sec. 31, T11 N, R14E, UM 8. KB (ft above MSL): ` 71.50' 15. Field / Pool(s): Top of Productive Horizon: Prudhoe Bay / Prudhoe Ba . cyvi 1353' FSL, 1252' FWL, Sec. 29, T11 N, R14E, UM GL (ft above MSL): Y Bay • Tota Depth: tt 9. Plug Back Depth (MD +TVD 1` 1444' FSL, 123' L, Sec. 29, T11 N, R14E, UM - 11266' 9040" 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 664036 y - 5949795 Zone ASP4 - 11965' 9008' . ADL 028310 TPI: x 666831 y 5952066 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 665701 y - 5952131 Zone ASP4 None 18. Directional Surve : 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): Y ❑ Yes ►'_ No (Approx.) A (Submit electronic and printed information per 20 AAC 25.050) N/A ft M 1900' ( pP ) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, DIR, GR, RES, NEU, DEN 7274' 6011' 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 20" x 30" Insulated Conductor Surface 114' Surface 114' 36" 300 sx Cement 13 -3/8" 72# N -80 Surface 2664' Surface 2664' 17 -1/2" 5200 cu ft Cement 9 -5/8" 47# S00 -95 / N -95 Surface 7274' Surface 6011' 12 -1/4" 1936 cu ft Cement 7" 26# L -80 1784' 7274' 1784' 6011' LTB Liner Tie -Back Sleeve, 1125 cu ft Class 'G' 5 -1/2" 17# L -80 7110' _ 100891 5910' _ 8461' 7" 424 cu ft Class 'G' 3 -1/2" 9.2# L -80 9930' 11963' 8318' 9008' _ 4 -3/4" 174 cu ft Class 'G' 24. Open to production or injection? ❑ Yes IN No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / ND) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6 #, L -80 x 9936' 9885' / 8277' MD TVD MD TVD 3 -1/2 ", 9.2 #, L -80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND / OF MATERIAL USED 4 JUL ,, I�! 11266' Set Whipstock ,/ 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period . Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER-BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? 0 Yes _! No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottqr 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 DDS JUL 1 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE AOriginal On 0 29. GEOLOGIC MARKERS (List all formations an rkers encountered): 30. FORMATION TESTS NAME TVD Well Tested. Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 10104' 8475' None Shublik 10138' 8505' Shublik B 10174' 8537' Shublik C 10194' 8554' Sadlerochit 10224' 8580' 24P 10826' 8988' 22P 11270' 9040' 22N (Invert) 11738' 9028' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the ore oing is tr - V rrect to the best of my knowledge. f Signed: Joe Lastufka Title: Drilling Technologist Date: - ill !I PBU B -04" 201 -068 312 -189 Prepared By Name/Number: Joe Lastufka, 564 - 4091 Well Number Permit No. / Approval No. Drilling Engineer: Troy Jakabosky, 564 -4868 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 • • B -05B, Well History (Pre Rig Sidetrack) Date Summary 05/24/12 T /I /0= 2400/200/0 Conducted PJSM. Opened Swab, SSV, & Master valves, read tubing pressure. Shut Swab and bled off..Pass. Shut SSV, opened Swab, Bled off..Pass. Shut Master, opened SSV, master leaked, needs grease. Shut SSV & Swab, master open, performed leak tight test..pass. Removed tree cap, attached lubricator, PT'd top side of Swab & SSV 250 /Iow..3500 /high..Pass (see chart in TRP folder) Set 4" CIW "H" TWC w/ 1 -1' ext. Tagged @ 114 ". Removed lubricator c/o tools, attached lubricator, PT'd 250 /Iow..3500 /high..pass. Opened Swab & SSV, bled tree to 0 psi. Torqued all flanges to specs. (see log) PULLED TWC. Installed tree cap, PT'd 500 psi. pass. Pre - Nordic 2. 05/28/12 CTU #9 1.75" Coil Tubing - Job scope = Drift the well. Arrived on location and RU. MU 2.74" dummy whipstockdrift BHA. 05/29/12 CTU #9 1.75" Coil Tubing - Job scope = Drift the well. MU drift BHA RIH. Drift and tag at 11328.2ft CTM. POOH, FP the well. RDMO. 06/01/12 T /I /O = SSV /140NAC. Temp = SI. Bleed IAP & OAP to 0 psi (pre CTD). No AL. IA & OA FL near surface. Bled IAP to 0+ in 1 hr 30 min all gas. Monitored for 30 min. IAP increased 4 psi. Job complete. Final WHPs = SSV /4NAC. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 1300. 06/02/12 T /I /O = SSV /10Nac. Temp = SI. WHPs (Post bleed) Pre CTD. IAP increased 6 psi ovemight. SV, WV, SSV =C. MV =O. IA, OA =OTG. NOVP. 14:00. 06/10/12 T/I/O= 2450/77/vac. Load and kill ( CTD Prep) **MV closed on arrival** Pumped 5 bbls neat methanol followed by 227 bbls SW down tbg to secure. Freeze protect tbg with 38 bbls diesel. Pad op notified of well status and tree valve positions as follows: SV,WV,SSV,MV= closed. IA and OA open to gauges. FW H P =0/91 /2. 06/11/12 T /I /O = SSV /100Nac. Temp = SI. Bleed IAP to —0 psi (Pre CTD). No well house or flow line. Ground prepared for drilling. IA FL near surface. Bled IAP to BT from 100 psi to 0+ psi in 20 min (all gas), held open bleed on IA for 30 min. Monitored for 30 min, IAP increased 10 psi. Job complete. Final WHPs = SSV /10Nac. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 16:20. 06/12/12 T /I /O= 0/50/0. Conduct PJSM. TWC was set and tested prior to arrival. Confirmed safe -out with operator (TWC and MV as barriers). Pulled Baker actuator and bonnet cap. Replaced packing. Installed actuator and cycled SSV 4 times to confirm full stroke (passed). PT'd tree (packing test) to 200 -300 psi. low for 5 min. (passed) and 5000 psi. high for 5 min. (passed). Pt'd MV (as per WSL request to 200 -300 psi. low for 5 min. (passed) and 3500 psi. high for 5 min (passed). All tests charted and documented in QC reports (field charted tests). Bled off IA to 0 psi. to bleed trailer (as per WSL request). Job complete. 06/12/12 T /I /0= 2600/14/0. Load and kill (CTD Prep) *"Master Valve closed on arrival** Pumped 5 bbls neat methanol,followed by 253 bbls seawater down tbg. Freeze protect tbg with 38 bbls diesel. Pad op notified of well status and tree valve positions as follows: SV,WV,= closed SSV, MV= open. IA and OA open to gauges. FWHP= vac /30/3. Page 1 of 1 • • x n Common Well Name: B -05 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/12/2012 End Date: 6/23/2012 X3-0120G-C: (2,628,325.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/10/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: B -05B @71.50ft (above Mean Sea Level) Date From - To Hrs (ft) Task Code NPT NPT Depth Phase Description of Operations (hr) 6/12/2012 12:00 - 17:00 5.00 MOB N WAIT 11,265.00 PRE E PREP WORK BEGIN RON EVENT FOR E3-05 AT 12:00 ON 6/12/12. DUE RIG REMAINS OVER B 20 WHIL FOR B-05 CONTINUES: WAIT ON WELLS GROUP TO KILL WELL TO 2400 PSI ON WELL. SET 4 "CAMERON TYPE H TWC WITH WELL ON VAC. GREASE CHOKE AND 2" IRON. CLEAN HP FILTERS. INSPECT PITS. TEST GAS ALARMS. HOLD DISCUSSION WITH RIG CREWS ABOUT ACCUMULATOR AND 'POSSIBLE FAILURE SCENARIOS. 17:00 - 00:00 7.00 MOB N SFAL 11,265.00 PRE NORDIC 2 RIG REMAINS OVER B 20 WELL. TROUBLESHOOT SURFACE SAFETY VALVE (STEM NOT STROKING CLOSED 100 %). CHANGEOUT BORE WITH NO SUCCESS. INSPECT PACKING CARTRIDGE AND DISCOVER DAMAGED INNER SEALS. CHANGEOUT CARTRIDGE AND CYCLE VALVE TO CONFIRM PROPER STROKE LENGTH FOR FULL CLOSURE. RE- PRESSURE TEST TREE SHELL TO 250 PSI LOW AND 3500 PSI HIGH / FOR FIVE MIN EACH (PASSING TESTS). V PREPARE RIG TO MOVE OFF WELL. HOLD DISCUSSION WITH RIG CREWS ABOUT ACCUMULATOR AND POSSIBLE FAILURE SCENARIOS. 6/13/2012 00:00 01:00 1.00 MOB N WAIT , 11,265.00 PRE NORDIC 2 RIG REMAINS OVER B 20 WELL WHILE WELLHEAD AND TREE PREP WORK IS COMPLETED ON B-05. 01:00 - 01:30 0.50 MOB P -_ PRE HOLD PRE -JOB SAFETY MEETING FOR MOVING RIG OFF WELL. 01:30 02:00 0.50 MOB P ■- PRE MOVE RIG OFF WELL B 20. PAD OPERATOR DECLINES WITNESS TO PULLING OFF WELL. STAGE RIG ON B PAD. 02:00 - 07:30 5.50 MOB P . -_ PRE PICKUP RIG MATS FROM B 20 LOCATION AND PLACE AROUND B-05 07:30 - 08:00 0.50 MOB P PRE HOLD DETAILED PJSM PRIOR TO MOVING OVER WELL. DISCUSS SPOTTER LOCATIONS, COMMS, EMERGENCY SHUT DN. Printed 7/2/2012 11:01:50AM Common Well Name: B -05 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/12/2012 End Date: 6/23/2012 X3- 0120G -C: (2,628,325.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/10/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: B -05B @71.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 09:00 1.00 MOB P PRE MOVE RIG OVER B-05 WELL. PAD OPERATOR DECLINES WITNESS TO PULLING OVER WELL. - WELLWORK TRANSFER PERMIT OPEN WITH PAD OPERATOR. - ALL VALVES ON TREE AND WELLHEAD CLOSED FOR PULLING OVER WELL. - SWAB/WING VALVES AND 4" CAMERON TYPE H TWC CONFIRMED AS TWO BARRIERS (SEE - ATTACHED CHARTS) - INITIALT /I /O= TWC /0 /0 PSI - ALL PRE -RIG WORK VERIFIED COMPLETE B -20 WING VALVE LOCKED OUT BY WSL AND PAD OPERATOR FOR ANTI - COLLISION 09:00 - 10:00 1.00 MOB P PRE ACCEPT RIG AT 09:,041 ON 6/13/2012. LOAD PITS WITH 2% KCL WITH 0.6% SAFELUBE BEGIN TO SPOT EXTERNAL EQUIPMENT. ND TREE CAP AFTER VERIFYING TWC AND SWAB TEST RESULTS. 10:00 - 12:00 2.00 MOB P PRE NIPPLE UP 7-1/16" 5K BOP STACK TO 4-1/16" SWAB FLANGE WITH FOLLOWING CONFIGURATION FROM TOP DOWN: - HYDRIL GK ANNULAR - TOT BLIND -SHEAR RAMS - TOT 2" COMBI PIPE RAM/SLIPS - FLOW CROSS WITH 2- 3/16" INNER HCR VALVE AND 2- 1/16" OUTER GATE VALVE ON BOTH KILL AND CHOKE LINE - TOT 2 -3/8" COMBI PIPE RAM/SLIPS - TOT 2" COMBI PIPE RAM/SLIPS 12:00 - 14:00 2.00 BOPSUR P PRE TAKE ON COLD WATER FOR BOP TEST. INSTALL LUBRICATOR . ADJUST SECTIONS TO CLEAR ROTARY BUSHINGS. 14:00 - 15:00 1.00 BOPSUR P PRE PRESSURE TEST BOP SHELL TO 250 PSI LOW AND 4500 PSI HIGH AGAINST SWAB VALVE (PASSING TEST). 15:00 - 15:30 0.50 BOPSUR P PRE HOLD H2S / RIG EVACUATION DRILL. MUSTER IN SAT CAMP. HOLD AAR TO REVIEW DRILL. CONDUCT PRE -SPUD MEETINGS WITH BOTH RIG CREWS. 15:30 - 16:30 1.00 BOPSUR P PRE BEGIN FULL BOP PRESSURE TEST (DETAILS IN 17:30 -21:00 OPERATION SUMMARY). 16:30 - 17:30 1.00 RIGU P PRE TEST EMERGENCY GENERATOR SHUT DOWN SYSTEM ON RIG. ALSO TEST ESD ON SAT CAMP GENSET. BOTH SYSTEMS FUNCTIONED CORRECTLY. Printed 7/2/2012 11:01:50AM Common Well Name: B -05 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/12/2012 End Date: 6/23/2012 X3- 0120G -C: (2,628,325.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/10/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: B -05B @71.50ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 21:00 3.50 BOPSUR P PRE PRESSURE TEST BOP EQUIPMENT TO 250 PSI LOW AND 3500 PSI HIGH FROM FIVE MIN EACH TEST PER ADWOP AND AOGC REQUIREMENTS (SEE ATTACHED DOCUMENTATION). DDDDpp - STATE'S RIGHT TO WITNESS WAIVED BY r2., AOGCC REPRESENTATIVE BOB NOBLE. �� PEFORM ACCUMULATOR DRAWDOWN TEST. FOUR BACKUP NITROGEN BOTTLES PRE- CHARGE CONFIRMED TO BE 2200 PSI. - COMPONENTS FUNCTIONED FROM BOTH ALL CONTROL PANELS. - ONE FAILURE: UPPER 2" COMBI PIPE RAM /SLIPS. CHANGEOUT INSERTS AND TOP SEALS. RETEST (DETAILS IN NEXT TIME OPERATION). , 21:00 - 22:30 1.50 BOPSUR P PRE OPEN UPPER DOUBLE GATE DOORS TO INSPECT UPPER COMB! RAMS. CHANGEOUT INSERTS AND TOP SEALS. RETEST UPPER 2' COMBI PIPE RAM/SLIPS TO 250 PSI LOW AND 3500 PSI HIGH (PASSING TESTS). 22:30 - 23:30 1.00 BOPSUR P PRE COMPLETE FINAL BOP PRESSURE TEST AND RIG DOWN TESTING TOOLS. 23:30 - 00:00 0.50 RIGU R PRE HOLD H2S RIG EVACUATION DRILL AND AAR. 6/14/2012 00:00 - 01:30 1.50 RIGU N WAIT 11,265.00 PRE WAIT ON LIFTING CERTIFICATION FOR LUBRICATOR EQUIPMENT. 01:30 - 03:30 2.00 RIGU P PRE HOLD PJSM AND MIRU VALVE SHOP LUBRICATOR CREW. PRESSURE TEST LUBRICATOR WITH MEOH TO 250 PSI LOW AND 3500 PSI HIGH (PASSING TESTS). 03:30 - 04:30 1.00 RIGU P PRE APPLY 2100 PSI ABOVE TWC. PULL 4" CAMERON TYPE H TWC. 2400 PSI ON WELL (FULL COLUMN OF GAS). CLOSE SSV AND SWAB VALVE. BLEED OFF LUBRICATOR AND MONITOR FOR 5 MIN TO ENSURE NO PRESSURE BUILDUP FOR BREAKING CONTAINMENT. RDMO VALVE SHOP LUBRICATOR CREW. 04:30 - 05:00 0.50 RIGU P PRE INSTALL NIGHT CAP AND PRESSURE TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). 05:00 - 05:30 0.50 RIGU P PRE HOLD PJSM AND LINEUP TO KILL WELL. 05:30 - 07:00 1.50 RIGU P PRE BULLHEAD KILL WELL AS FOLLOWS: - PUMP 5 BBLS MEOH AHEAD MUD PUMP POD CAPS LEAKING SLIGHLY WITH MEOH. LOTO PUMPS. TIGHTEN POD CAPS. PRESS TEST TO 4000 PSI. PASSED. 07:00 - 11:00 4.00 RIGU P PRE PUMP 300 BBLS 2 %KCLW/ SAFELUBE (2 X 1412 BBL VOL TO PERFS) AT 6.5 BPM. ISTP: 2390 PSI. TP:540 PSI WITH 148 BBLS AWAY. FINAL TP: 1025 PSI WITH 300 BBLS AWAY. 6.5 PBM IN. MONITOR WELL. ESTIMATE 1.75 BPM LOSS RATE. NEED TO REDUCE LOSS RATE FOR RNG WHIPS. ORDER LCM AND USED 8.6 PPG FLOPRO FROM MI. Printed 7/2/2012 11:01:50AM Common Well Name: B -05 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/12/2012 End Date: 6/23/2012 X3- 0120G -C: (2,628,325.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/10/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: B -05B @71.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 14:00 3.00 RIGU N WAIT 11,265.00 PRE WAIT ON FLUIDS FROM MI. ORDER 50 BBL LCM PILL. AND 580 BBLS USED 8.6 # FLO -VIS. 14:00 - 15:30 1.50 RIGU P PRE OFF LOAD LCM PILL INTO PIT #4. ADD ADDITIONAL MEDIUM PRODUCT. 10 PPB MED NUTPLUG, 10 PPB MIX 2, 20 PPB SAFECARB, 20 PPB G -SEAL. 15:30 - 17:30 2.00 RIGU P PRE ' BULLHEAD 45 BBLS LCM. DISPLACE TO PERFS WITH 8.6 PPG FLOVIS. 370 PSI AT 3.0 BPM INITIAL RATE. WHP: 2000 PSI WITH 20 BBLS LCM SQUEEZED. BLEED OFF TO 600. PSI. PRESSURE BACK TO 2000 PSI. REPEAT SEVERAL TIMES. BLEED OFF WHP TO ZERO. NOTE: APPROXIMATELY 10 BBLS OF LCM PILL LIFT IN 3- 112" LINER. 17:30 - 18:30 1.00 RIGU P PRE CIRCULATE ACROSS WELL AND MONITOR FLUID LEVEULOSS. WELL LOSING LESS THAN 2 BBLS PER HOUR. 18:30 - 19:00 0.50 RIGU P PRE -FLOW CHECK WELL. FLUID LEVEL STATIC. HOLD PRE -JOB SAFETY MEETING FOR PULLING & STABBING COIL. 19:00 - 22:00 3.00 RIGU P PRE PICKUP INJECTOR AND INSTALL PACKOFF. PULL 2" COIL ACROSS RIG FROM REEL HOUSE. STAB INJECTOR. 22:00 - 00:00 2.00 RIGU P` PRE CUT 500' COIL FOR WELD MANAGEMENT WHILE DRILLING. TOTAL REEL LENGTH = 14773', VOLUME = 36.3 BBLS, E -LINE SLACK = 2.65 %. 6/15/2012 00:00 - 00:30 0.50 RIGU P PRE RIG DOWN HYDRAULIC CUTTER 00:30 - 01:00 0.50 RIGU P PRE TEST E -LINE (PASS). INSULATION TEST: >2000 MEGAOHMS & CONTINUITY TEST = 53 OHMS. 01:00 - 02:00 1.00 RIGU P PRE INSTALL SLB INTERNAL DIMPLE COILED TUBING CONNECTOR. PULL TEST TO 35 KLBS. 02:00 - 03:00 1.00 RIGU P PRE INSTALL BHI E -LINE HEAD. 03:00 - 03:45 0.75 RIGU N SFAL 11,265.00 PRE TROUBLESHOOT MUD PUMPS DUE TO LCM BUILDUP. 03:45 - 04:30 0.75 RIGU P PRE FILL COIL WITH MUD. 04:30 - 06:30 2.00 RIGU N SFAL 11,265.00 PRE CIRCULATE SURFACE SYSTEM TO CLEANUP RESIDUAL LCM. CREW CHANGE. DISCUSS OPERATIONS AND EQUIPMENT STATUS. 06:30 - 07:00 0.50 RIGU N SFAL 11,265.00 PRE CONTINUE TO CIRCULATE TO CLEAN UP LCM 07:00 - 08:30 1.50 BOPSUR P PRE PRESSURE TEST INNER REEL AND INJECTOR PACKOFFS. 250 LOW. 3500 HIGH. CHART. PASSED. 08:30 - 09:00 0.50 RIGU N DPRB 11,265.00 PRE MU CHECKS, STINGER, AND NOZZLE. STAB COIL. GET ON WELL. TEST QTS. PASSED. 09:00 - 11:00 2.00 RIGU N DPRB 11,265.00 PRE RUN IN HOLE. CIRC AT MIN RATE. FULL RTNS. Printed 7/2/2012 11:01:50AM ry/ H 4 U Common Well Name: B -05 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/12/2012 End Date: 6/23/2012 X3- 0120G -C: (2,628,325.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/10/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: B -05B @71.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 11:30 0.50 RIGU N DPRB 11,265.00 PRE RECORD SLOW PUMP RATES #1 0.5 1203 PSI, #1 1.0 1770 PSI #2 0.5 1275 PSI, #2 1.0 1785 PSI 30K# UP WT AT 9800' AT 0.5 BPM. 11:30 - 15:00 3.50 RIGU N DPRB 11,265.00 PRE WASH IN HOLE IN 200' INCREMENTS AT 15 FPM. 3505 PSI AT 2.21 BPM IN/OUT. PU 50' AFTER EACH WASH PASS DOWN. CIRCULATE BTMS UP AT 10850' BEFORE WASHING PAST FIRST SET OF PERFS. TAG OBSTRUCTION AT 10983'. (NEAR BTM OF FIRST SET OF PERFS) SET DN 5K #. WASH/JET AT 2.35 BPM. UNABLE tO MAKE ANY PROGRESS. 2 -5K# OVERPULLS WHEN PICKING UP. 15:00 - 17:30 2.50 RIGU N DPRB 11,265.00 PRE CIRCULATE OUT OF HOLE. 3816 PSI AT 2.38 BPM. 17:30 - 18:00 0.50 RIGU N DPRB 11,265.00 PRE AT SURFACE. FLOW CHECK. GET OFF WELL. UNSTAB COIL. LO NOZZLE BHA. 18:00 - 19:00 1.00 RIGU N DPRB 11,265.00 'PRE CLEANOUT HIGH PRESSURE FILTERS. 19:00 - 20:45 1.75 RIGU N DPRB 11,265.0 PRE ` MAKEUP AND RUN IN HOLE WITH 2 -3/8 ", COILTRAK CLEANOUT BHA. 2.74" D331 MILL - 1.0 DEG AKO MUD MOTOR - FLOAT SUB, HOT, DGS, DPS, EDC, P &C BHA OAL = 60.09 20:45 - 00:00 3.25 RIGU N DPRB 11,265.00 PRE STAB ON WELL WITH INJECTOR. PRESSURE TEST QTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). TRIP IN HOLE FROM BHA AT 60' MD TO PREVIOUS DEPTH ACHIEVED ON NOZZLE RUN OF 11970' MD. TAG HARD OBSTRUCTION. LOG ACROSS TOP OF SAG RIVER AND TIE -IN TO PDC LOG AT 10100' MD ( -16' CORRECTION, FIRST TIE -IN FOR WELL). Printed 7/2/2012 11:01:50AM Common Well Name: B -05 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/12/2012 End Date: 6/23/2012 X3- 0120G -C: (2,628,325.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/10/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: B -05B @71.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/16/2012 00:00 - 04:00 4.00 RIGU N DPRB 11,265.00 PRE CLEANOUT RESIDUAL LCM PILL IN 3 -1/2" PRODUCTION LINER FROM 10970' MD TO 11325' MD (WHISTOCK SETTING DEPTH = 11265' MD) IN 50' - 100' INTERVALS, SEPARATED BY CIRCULATING BOTTOMS UP WHILE PULLING UP HOLE. ALL PICKUPS AFTER MILLING INTERVALS ARE CLEAN, 38 KLBS PICKUP WEIGHT. BASELINE MILLING CLEANOUT = 2925 PSI, < 1 KLBS DHWOB. MW IN/OUT = 8.8 PPG. ECD = 9.8 PPG. NO LOSSES TO WELLBORE DURING CLEANOUT. IA /OA =75/2 PSI. THE ONLY MOTOR WORK OR DOWNHOLE WEIGHT ON BIT WHILE CLEANING OUT WAS OBSERVED AT THE TOP OF THE THREE PERF INTERVALS (10954' MD, 11092' MD AND 11312' MD); ^400 -200 PSI, 1 -2 KLBS) AT 11325' MD, LOSSES TO WELLBORE RESUMED AT 0.5 BPM. CLEANOUT WAS CONCLUDED. WHILE PULLING UP HOLE AND - CIRCULATING FINAL BOTTOMS UP, LOSSES 'HEALED. 04:00 - 06:00 2.00 RIGU N DPRB 11,265.00 PRE "LOG UP WITH CCL OVER FOLLOWING INTERVALS AT 1000 FPH FOR DEPTH CONTROL: 11275' MD - 11200' MD 11800' MD - 11600' MD RE -TIE IN AT TOP OF SAG RIVER, 10100' MD, TO CONFIRM FOR DEPTH CONTROL ( +4' CORRECTION). FLOW CHECK WELL. WELL STATIC. 06:00 - 07:45 1.75 RIGU N DPRB 11,265.00 PRE PULL OUT OF HOLE FROM 10100' MD TO BHA AT 60' MD. FLOW CHECK WELL. 07:45 - 08:30 0.75 RIGU N DPRB 11,265.00 PRE GET OFF WELL. UNSTAB COIL. STANND BACK / LA DOWN BHA. REMOVE MOTOR AND MILL. 08:30 - 09:30 1.00 BOPSUR N DPRB 11,265.00 PRE DRAIN BOP STACK. CYCLE RAMS SLOWLY WITH AIRPRESSURE AND INSPECT FOR LCM. TRACES FOUND. WASH OFF SAME. 09:30 - 10:45 1.25 WHIP P WEXIT HOLD PJSM. MU BTT 35KB 2.74" od WHIPSTOCK ON INTEQ �(�{ _ BHA. STAB COIL AND TEST TOOLS. GET ON WELL. TEST QTS TO 250 AND 3500 PSI. PASSED. 10:45 - 14:15 3.50 WHIP P WEXIT RUN IN HOLE. OPEN EDC. CIRC AT MIN RATE. 1:1 RTNS. SLOW DOWN THROUGH ALL JEWELRY AND PERFS. NO PROBLEM WITH 2.75" XN NIPPLES 14:15 - 14:45 0.50 WHIP P WEXIT LOG GR TIE IN FROM 10,100'. SUBTRACT 16.5' CORRECTION. 14:45 - 15:00 0.25 WHIP P WEXIT CONTINUE TO RUN IN HOLE. 40K# UP, 16K# DN WT AT 11,200' Printed 7/2/2012 11:01:50AM v�•x Common Well Name: B -05 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/12/2012 End Date: 6/23/2012 X3- 0120G -C: (2,628,325.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/10/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: B -05B @71.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 15:45 0.75 WHIP P WEXIT RUN IN HOLE TO 11,276 BTM OF WS. PU TO UP WT OF 40K #. CLOSE EDC. VERIFY TF SET TO 60RHS. PRESSURE COIL TO 2650 PSI TO SET AND 1/J5 SHEAR OF PACKER. W SET DN 3.5K #. NO MOVEMENT. ESTIMATE TOW AT11 265'. WILL CONFIRM WITH MILL RUN TIE IN. 15:45 - 18:00 2.25 WHIP P WEXIT PJSM. CIRCULATE OUT OF HOLE TO BHA AT 59' MD. 0.99 BPM IN / 0.76 BPM OUT. FLOW CHECK WELL. WELL STATIC. UNSTAB INJECTOR AND SETBACK SAME. 18:00 - 19:00 1.00 WHIP P WEXIT LAYDOWN WHIPSTOCK SETTING TOOLS. ALL TOOLS RETURNED. FROM HOLE AND IN ACCEPTABLE CONDITION. 19:00 - 20:00 1.00 STWHIP P WEXIT MAKE , P 2 74" WINDOW MILLING ASSEMBLY AND RUN IN HOLE. - 2.74" NEW HCC DSM WINDOW MILL + 2.74" DIAMOND STRING MILL BAKER 2 -1/8" XTREME STRAIGHT MUD MOTOR + FLOAT SUB 2 -3/8" COILTRAK TOOLS WIT NO HOT BHA OVERAL LENGTH = 111' 20:00 - 22:30 2.50 STWHIP P WEXIT TRIP IN HOLE FROM BHA AT 111' MD TO APPROXIMATE WHIPSTOCK DEPTH AT 11265' MD; 16 KLBS SLACKOFF WEIGHT. LOG ACROSS TOP OF SAG RIVER AT 10100' MD. TIE -IN TO GR SIGNATURE ( -16' CORRECTION, COMPARED TO -16.5' CORRECTION ON LAST RUN). 22:30 - 23:30 1.00 STWHIP P WEXIT _T G—TDP OF.WHIESIO K (PINCH POINT = 0' DOWN ON TRAY) AT 11266.8' MD WITH PUMPS AT MIN RATE; 0.4 BPM, 1325 PSI. PICKUP AND RUN BACK IN HOLE WITH PUMPS AT 1.5 BPM, 2700 PSI. TAG TOP OF WHIPSTOCK AT 11265.7' MD. PERFORM COMPLEX WELL CONTROL DRILL AND AAR: - SIMULATED WELL FLOW AND LEAKING PACKOFF ON INJECTOR - SIMULATED HYDRAULIC FITTING LEAK ON ACCUMULATOR UNIT AND THEREFORE NO SYSTEM PRESSURE - DRILLER AND MOTORMAN RESPONDED CORRECTLY AND PROMPTLY TO SHUT IN MANUAL VALVE ON CHOKE MANIFOLD AND TO WORK THROUGH NITROGEN BACKUP PROCEDURE. - AAR REVIEWED IMPORTANCE OF STRONG COMMUNICATION AND SITUATIONAL AWARENESS + ALTERNATE SCENARIOS FOR DRILL. SLOW PUMP RATES AT 11265' MD, 8.8 PPG MP#1: 0.5 BPM = 1360 PSI, 1 BPM = 1940 PSI MP#2: 0.5 BPM = 1320 PSI, 1 BPM = 1920 PSI END OPERATIONS ON 'B WELLBORE.' Printed 7/2/2012 11:01:50AM Common Well Name: B -05 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/12/2012 End Date: 6/23/2012 X3- 0120G -C: (2,628,325.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/10/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: B -05B @71.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) ST AK 23:30 - 00:00 0.50 STWHIP P WEXIT BEGIN OPERATIONS ON 'C WELLBORE' AT 23:30 ON 6/16/2012. Q, - 05G MILL WINDOW IN 3 -1/2" PRODUCTION LINER FROM STARTING DEPTH AT 11265.7' MD TO 11266' MD AT MIDNIGHT. SEE DETAILS OF MILLING ON6/17/2012 REPORT. 6/17/2012 00:00 - 06:00 6.00 STWHIP P WEXIT MILL WINDOW IN 3 -1/2" PRODUCTION LINER /� FROM 11266' MD AT MIDNIGHT TO 11272' MD Q" AT 6 AM. BEGIN WINDOW AT 1 FPH; 1 KLBS I DHWOB, 2700 PSI BASELINE CIRCULATING PRESSURE, 100 -200 PSI DIFFERENTIAL; 1.5 BPM. MW IN/OUT = 8.8 PPG. 9.9 PPG ECD. QNLY ONE MOTOR STALL UPON FIRST TAGGING UP ON WHIPSTOCK. AFTER 2': OF MILLING, WOB AND MOTOR WORK BEGAN TO DRILL OFF EASIER. NO SIGN OF FLUID LOSSES TO WELLBORE. 1.5 BPM; 2700 PSI BASELINE CIRC PRESSURE, 200 -300 PSI DIFFERENTIAL, 1 -2.25 KLBS DHWOB. IA / OA = 95 / 2 PSI. 4600 PSI ANNULAR, 5150 PSI BORE. ESTIMATED WINDOW DEPTHS: 11266' MD TO 11272' MD (SEE ATTACHED BAKER WINDOW MILLING REPORT). 06:00 - 09:00 3.00 STWHIP P WEXIT DRILL 10 -FT OF FORMATION TO 11,282 -FT MD. PUMP AT 1.54 BPM WITH 2980 PSI ON BOTTOM, 2830 PSI OFF BOTTOM. MUD WEIGHT IN AND OUT 8.8 PPG WITH 9.9 PPG ECD. WOB 1.5 TO 2.2K. NO HANG UPS OR PROBLEMS WORKING BHA THROUGH WINDOW. 09:00 - 10:00 1.00 STWHIP P WEXIT BACKREAM T 11,265 -FT AND PULL TO 11,255 -FT. UP WEIGHT 40K, DOWN WEIGHT 15K WITH 40 PSI MOTOR WORK OBSERVED THROUGH TOP OF WINDOW AT 11,265 -FT. WORK BACK THROUGH WITH NO MOTOR WORK OBSERVED. RIH TO BOTTOM AT 11,282 -FT. BACKREAM WINDOW AGAIN WITH 30 PSI MOTOR WORK OBSERVED AT TOP OF WINDOW AND NO PSI GAIN AT BOTTOM OF WINDOW. UP WEIGHT 36K, DOWN WEIGHT 16K. BACKREAM WINDOW A THIRD TIME WITH NO PSI MOTOR WORK OBSERVED AT TOP OR BOTTOM OF WINDOW OUT OR IN. DRY DRIFT WINDOW WITH 41K UP WEIGHT AND 17K DOWN WEIGHT. NO INCREASE IN WEIGHT PULLING THROUGH WINDOW AND NO LOSS OF WEIGHT GOING DOWN. WINDOW APPEARS IN GOOD SHAPE. 10:00 - 10:15 0.25 STWHIP P WEXIT ESTABLISH CIRCULATION AT TOP OF WINDOW WITH NO PROBLEMS. SHUT DOWN AND FLOW CHECK FOR 10 MINUTES - STATIC. OPEN EDC. 10:15 - 12:30 2.25 STWHIP P WEXIT POOH FROM 11,255 -FT TO BHA AT 111 -FT. PUMPING AT 2.0 BPM WITH 3210 PSI. MUD WEIGHT IN AND OUT 8.9 PPG. UP WEIGHT 35K. Printed 7/2/2012 11:01:50AM TREE= 4-1/16• CAN • V1f3.LFEAD = 1kEVOY SAFETY ND1ES: '" 6i) � CFE ROUCT10N LIFER" Rl ACATOR = OTS B-05C FRB/IDILS 4VB.LBORE (T3 -05A) MDT SHORAN ON DIAGRAM KB. REV = 71.5' BELOW FALLOUT MEOW. HELL EXCEEDS 70° ®10845' BF. BLEV = 42.02 AND GOES HORIZONTAL tit 11342. KOP= 3000' Max Angle = 5°l1981' ,_ 1784' 9-5/8' x r BKR SBP FKR VW'TEBACK SLV, D = 6.875' I 'Datum ID= 1060 1 .1 e 'Datum = 8800' SS e l { e 2057' 9-5/8' FOC 13-3/8' CSG, 72#, L-80 Burr, H 2664' � /� / , 2194' H4-12 FE5 X NP, D= 3.813' D= 12.347" ►41 1, GAS I9 -518' DV COLLAR H 2673' I--- •! _ 1 1' ST MD ND DEV PE VLV 7CIi PORT 047E 4 1 14 4 3638 3536 26 KBG-2 RP BK 06/05/01 ►1 1' 3 6702 5586 52 KBG-2 DV BK 06/05/01 1 © 1j 2 8353 6838 28 KBG -2 -9 L7V BIM 06/05/01 Minimum ID = 1.78" @10469' ► I 1 9741 lion 26 KBG -2 -9 DV BIM 06/05/01 3" Deployment Sleeve ► ; 1 ► ►1 1 11 •• • 11 1' NOTE: Does 6/4/2001 Pipe Tally incorrectly identify Iii 1 X Nipples at 9864', 9909'.8 9919' A 1, as having ID = 2.75'7 They have been red -lined' 11 1' on this schematic to be 2.813', Please change back A 1 • If this is incorrect. ► •/ 1 . 4-1? TBG, 12.68, L- 80 -NSCT, — 7041' I a / j 7041' H4-1? X 3_1/2' XO, D= 2938' .0152 bpf, ID= 3.958 1 4 1 1+ 141 1 • 11 1 7110' I — r X 5-1? BOT all LNRTOP FERFORA1ION SUMMARY 1 / FIfR VW tf$C D 6' 1AQ = 4.875" 1 1 4 I REF LOG X 88° 0 44 P • 9-5/8' & r FALLOUT V1At DOW ( 13 -06A) 7274' - 28T ANGLE AT TOP FF.RF 88° @ 13550' 1 1� Notre: Wier to Production CB for historical perf data 4 • SEE SFF NIERVAL - Opn/Sgz DATE A 14 ? 1 8864' 3-1E5 X NP, V= 2_813' • 1- 11116' 6 13550 - 13750 O 06/29112 ►1 • 1� 968 5-1/2' X 3-1? BKR S-3 RCR, I) = 2.780' �4 9909 I—II-1/71-ES X NP, D= 2.813" ► • 991W 3-1? KS X NP, D = 2.813" I :1 r v II 1oaK 7274' 1 � 1 ::� 3-1? NAM, , D = 2.992' 19-5/8' CSG, 476, L-80, 0= 8.681' H 7274 ' I 11 �- . - , = 3- 1? Packer NRipstock I , • ,. 1. ■, � �� 13-1? TBG, 9.2#, L-80 NSCT, .0087 W, 0= 2.997 9930' ` 11600' BKR 1- 11/16' BP i ^ (06/18109) I �1? X 3-1/2" BKR cal LNRTOP RWIFE,R vW1�Aa� D= 2997 \*. 9930' 1 ALL �! F6Ft1- 11/16" 15-1? LNR, 176, L-80, S1L -FJ, .0232 bpf, D = 4.892' H 1006W I / % BKR BP 13" Baler Depbyment Sleeve, 10' fiecepttcle, 3" GS Prole, D =1.78' H 10468' I • (TAG 05118109) IP av .D,9'oo D 1 5 "m Z 1.7 "mover, 13548• — Bottom ICT TAG ON 7/29 11382' I / ( of finer 13789' = T11/9 2 -3/8", 4.80, 13CR -85, ST-1, 0.00387 bpi, D = 1.905' I 13-1? UR, 9.26, L-80, STL, .0087 bpf, D = 2.997 11963' 02112/78 ORIGINAL COM PLETION 05/29109 ???RLH PERM & BP FISH (0918/09) WELL' B-05C 06104191 IINO 02102/10 JLVWPJC 9-518' CSG CORRECTION ITT No: `212070 07/01/96 RIG SIDETRACK 6IXX02 NORDIC 2 CTD SDETRACK AR Pb: 50.029- 20276 -03 06/06/01 MG SIDETRACK SEC 31, MN, R14E 855 SNL,1600 WEE 04/22/06 JNA/PJC SET BP 8P &potation (Alaska) • • SUITE EF MAMA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen 1 Engineering Team Leader BP Exploration (Alaska), Inc. a01-0 ' P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B -05B Sundry Number: 312 -189 LU1 Dear Mr. McMullen: MN MAY Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, f Cathy . Foerster Chair DATED this day of May, 2012. Encl. • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMSION APPLICATION FOR SUNDRY APPROVAL M41 2 012 Zo AAC 25.280 AOGC I / 1. Type of Request: ❑ Abandon ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number . BP Exploration (Alaska) Inc. ® Development ' ❑ Exploratory 201 -068 • 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20276 -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 B -05B • Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028310 • Prudhoe Bay / Prudhoe Bay 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11965' ` 9008' • 11900' 9013' 11600' 11755' Casing Length Size MD ND Burst Collapse Structural Conductor 114' 20" 114' 114' 4930 2670 Surface 2664' 13 -3/8" 2664' 2664' 4930 2670 Intermediate 7274' 9 -5/8" 7274' 6011' 8150 5080 Production Liner 5490' 7" 1784' - 7274' 1784' - 6011' 7240 5410 Liner 2979' 5 -1/2" 7110' - 10089' 5910' - 8461' 7740 6280 Liner 2033' 3 -1/2" 9930' - 11963' 8318' - 9008' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10954' - 11825' 9017' - 9019' 4 -1/2 ", 12.6# / 3 -1/2 ", 9.2# L -80 9936' Packers and SSSV Type: 5 - 1/2" x 3 -1/2" Baker SABL -3 Packer Packers and SSSV 9885' / 8277' MD (ft) and ND (ft): 12. Attachments: 13. Well Class after proposed work: IS Description Summary of Proposal IS BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 22, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned ❑ WAG ❑ SPLUG ® Suspended ' Commission Representative: 17. I hereby certify that the for -going is true and correct to the best of my knowledge. Contact Troy Jakabosky, 564 -4868 Printed Name Jo c J,;/ , Title Engineering Team Leader r Prepared By Name /Number: Signature WV Phone 564 -4711 Date) '66/2 Joe Lastufka, 564 -4091 Commission Use Only Conditi.. of approval: Notify Commission so that a representative may witness Sundry Number 5 IV ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: 3.5 9 � / 7 J 130 i75 J ,, Ins /l' 43 l a- e 4- „ a1- 1rr pie)freek ev pp rvf ?ct per 2b.1F44C - ( t ) Subsequent Form Required: / 0 '4-07 APPROVED BY S ` LC ' --- 2._ f� / 0 Approved By: COMMISSIONER THE COMMISSION D to Subm Form 10-403 Revised /2010 ,1, D plicate ' ,,'W 57Z1112-0/7-- ORIG1�S _ - � ,�� • • To: Alaska Oil & Gas Conservation Commission From: Troy Jakabosky CTD Engineer 0 bp Date: May 14, 2012 Re: B -05B Sundry Approval roval Sundry approval is requested to abandon existing perforations on well B -05B in preparation for a Coiled Tubing Drilling Sidetrack. B -05B is a rotary sidetrack drilled in June 2001 and completed in Z2BI with 60' of perfs near the toe of the lateral. It reached MGOR within months of being brought online. In Nov 2001, 60' of adperfs were shot in the lateral in Z2A, but production did not change significantly. B -05B started cycling for high GOR. In July 2002 the plan was to seta CIBP at -11700' to isolate the initial toe perfs and then shoot an additional 60' of perfs from 11380 -440', but CT tagged a liner obstruction at -11382' CTM. The job was aborted. B -05B continued to cycle for the next 4 years. In April 2006 an IBP was set at 11642' CTM isolating the initial Z2BI perfs. The gas rate dropped but only for a month; B -05B continued to cycle. In May 2009 CT ran in hole but did not tag the IBP, indicating it was no longer in place. Another IBP was set at 11600' and 50' of adperfs were shot in Z2BI in the heel. This decreased the gas rate, making B -05B a fulltime producer for a year until it was shut -in for high GOR in July 2010. B -05B is currently cycling with degrading production. Reason for Sidetrack: B -05B is no longer a competitive producer due to a high GOR, and there are no remaining well work options. The proposed sidetrack will access reserves in a -70 acre target (Z2A/2BI HOT play) in northern B -pad. The well is in sound mechanical condition. It passed an MIT -IA to 3000 psi (March 2012) and the MIT -OA passed to 2000 psi (March 2012). The PPPOT -T passed to 5000 psi (February 2012). The sidetrack, B -05C, is scheduled to be drilled by Nordic 2 starting on June 20 2012 targeting Ivishak Zone 1 B /2A. The pre rig work includes service coil drift, Load and Kill, and set TWC. The coiled tubing drilling rig Nordic 2 will then mill the window in Z2A, followed by drilling the planned 2,530' lateral in Zn 1B /2A lateral via 12 DLS. The well will be completed with 2 -3/8" chrome solid, cemented, and perforated liner. The following describes the planned work. A schematic diagram of the proposed sidetrack is attached for reference. i 74e 9 ,7 a, w, ore qve/ &O .s e2 e l AP -1A-€‘1"- we/ f c , �lP/ti /l'�O �d/ t,e11 50 i 7 4 y pilo, ovz re cove, Aode alippe v� f c le — f't f 0;//z__, 1 • • CTD Sidetrack Summary Pre -CT Rig Work: The pre CTD work is planned to begin May 21, 2012. 1. C Run Dummy Whipstock Drift down to -11,320 MD. 2. V PT tree (MV,SV,WV) Bleed wellhead pressures down to zero. 3. 0 Bleed production flow lines and GL lines down to zero and blind flange. 4. 0 Remove wellhouse, and level pad. 5. F Load and Kill -24 hrs prior to rig arrival 6. V Set TWC (CIW 4 ") -24 hrs prior to rig arrival Rig Sidetrack Operations: (Scheduled to begin on June 20 2012 using Nordic Rig 2) 1. MIRU i1/a if 4OC?CC /14 5 �a✓ Z4 Lv'1S p" 2. NU 7- 1/16" CT Drilling BOPE and test TTS 60PE 3 3. Set 3 -1/2" KB Packer Whipstock at 11,270 MD at 60 ROHS p A & 4. Mill 2.74" single string window in the 3 -1/2" liner at 11270'. 5. Drill Lateral 3" Bi- Center bit 2,530 ft(12 °/100) in Zone 1 B /2A to a final TD of 13,820' MD. 6. Run and cement 2 -3/8" Chrome liner leaving TOL/TOC @10,700 ft with 13 BBLS cement. 7. Perform cleanout/log run with mill, motor. /4 C iN V 8. MCNL run. ftst 11 tr i p tp 0o p5- I 113 9. Perforate well (-500' planned) P 10. Freeze protect well to 2500' MD. 11. Set BPV. ND 7- 1/16" BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. 12. RDMO Post -Rig Work: 1. PuII BPV. 2. Set generic GLV's Troy Jakabosky Coiled Tubing Drilling Engineer 564 -4868 CC: Well File Sondra StewmanfTerrie Hubble 2 , TREE= 4- 1/16" CIW • WELLHEAD = McEVOY SAFES: PREVIOUS WELLBORE(B -05A) NOT ACTUATOR = OTIS B -05B SHOWN ON DIAGRAM BELOW MILLOUT WINDOW. WELL KB. ELEV = 71.5' EXCEEDS 70 @ 10845' AND GOES HORIZONTAL @ 11406'. BF. ELEV = 42.02' . KOP = 3000' ' Max Angle = 97 @ 11719' W I 1784' H9 -5/8" x 7" BKR SBP PKR W/TIEBACK SLV, ID = 6.875" I Datum MD = 10607' r1 r • 7 4 Datum TVD = 8800' SS �1 ∎� 2057' 1-19-5/8" FOC 1 41 • I 13 -3/8" CSG, 72 #, L -80 BUTT, 2661,41 1.1 1 I 6 I 2194' I -14 -1/2" HES X NIP, ID = 3.813" I ID = 12.347" 1 • ; ∎• 19-5/8" DV COLLAR H 2673' F- :•1 ■ ■ 1' ■ 1 ∎• GAS LIFT MANDRELS ' �' '� ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 ∎• 4 3638 3536 26 KBG -2 RP BK 06/05/01 1 . 1 � • , 3 6702 5586 52 KBG -2 DV BK 06/05/01 1,) *, 2 8353 6838 28 KBG -2 -9 DV BTM 06/05/01 Minimum ID = 2.75" @ 9864' ►1 • ■ , 1 9741 8077 26 KBG -2 -9 DV BTM 06/05/01 3 -1/2" HES X NIPPLE ■ • 1 •! ► ., ►•1 �•• y ∎• 1.1 o• 1.1 ∎• 1.1 * • 1 1 ■ . '•1 ∎1 1 •; ■ 4 -1 /2" TBG, 12.6 #, L -80 -NSCT, -I 7041' 1 �• .0152 bpf, ID = 3.958" 1.1 • 1 1 • 7041' H4-1/2" X 3-1/2" XO, ID = 2.938" I 1 1 4 • • PERFORATION SUMMARY 1 ■41 1 ∎• 7110' I X 5-1/2" BOT CPH LNR TOP REF LOG: • ■ Ai PKR W /6" TIEBACK, ID = 4.875" ANGLE AT TOP PERF: 83 @ 10954' ` �/ �•� Note: Refer to Production DB for historical pert data 1 _ �� SIZE SPF INTERVAL Opn /Sqz DATE 1 " o, 9 -518" & 7" MILLOUT WINDOW 2 -1/2" 6 10954 - 10984 0 05/19/09 1 ., 7 - 7287 • 2 -1/2" 6 11092 - 11112 0 05/19/09 1 ∎� 9864' (-� 3 -1/2" HES X NIP, ID = 2.750" 2" 6 11312 - 11372 0 11/19/01 1 t 2" 6 11750- 11770 C 06/30/01 1 1 9885' H5-1/2" X 3 -1/2" BKR SABL -3 PKR, ID = 2.780" I 2" 6 11785 - 11825 C 06/30/01 ( • 1 �) 9909' J-13-1/2" HES X NIP, ID = 2.750" I 11 `"% 9919' H3-1/2" HES X NIP, ID = 2.750" I 17" WHIPSTOCK H 7274' I 11, ► 1; 9936' I 3 -1/2" WLEG * 11 • � � 19 -5 /8" CSG, 47# I NO DEPTH Y • • 11600' BKR 1- 11/16" IBP y #i � � (05/18/09) 17" LNR, 29# H NO DEPTH I 0 11755' CTM 1 BKRIBP FISH:1- 11/16" 3 -1/2" TBG, 9.2 #, L -80 NSCT, .0087 bpf, ID = 2.992" H 9930' ,, ``� 5 -1 /2" X 3-1/2" BKR CPH LNR TOP PKR/HGR W/TIEBACK, ID = 2.992" 9930 (TAG 05/18/09) 15-1/2" LNR, 17 #, L -80, STL -FJ, .0232 bpf, ID = 4.892 H I 10089' I CT TAG ON OBSTRUCTION /RESTRICTION (07/29/02) H 11382' PBTD I-1 11899' I 3 -1/2" LNR, 9.2 #, L -80, STL, .0087 bpf, ID = 2.992" H 11963' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/12/78 ORIGINAL COMPLETION 05/29/09 ? ? ?/TLH PERFS & IBP FISH (05/18/09) WELL: B -05B 06/04/91 RWO PERMIT No: 2010680 07/01/96 RIG SIDETRACK API No: 50- 029 - 20276 -02 06/05/01 RIG SIDETRACK SEC 31, T11 N, R14E 855 SNL, 1600 WEL 04/22/06 JNA /PJC SET IBP BP Exploration (Alaska) , TREE= 4-1/16" cm, • WELLHEAD TOR = OTIS = McEVOY B _0'5 C SHOWN ACTUATORIAGRAM BELOW MILLOUT WINDOW. WELL KB. ELEV = 71.5' proposed CTD sidetrack EXCEEDS 70 @ 10845' AND GOES HORIZONTAL @ 11405. BF. ELEV = 42.02' KOP = 3000' Max Angle = 97 a 11719' 2 0 1784' j-- 19 -5/8" x 7" BKR SBP PKR W/TIEBACK SLV, ID = 6.875" Datum MD= 10607' v1 'e' Datum ND = 8800' SS 1 • , 2057' H9 -5/8" FOC I 0. �1 13 -3/8" CSG, 72#, L -80 BUTT, -126_61......R4 O.: 1 1 : • 2194' 1-14-112" HES X NIP, ID = 3.813" ID = 12.347" • 1 . ■ I9 -518" DV COLLAR H 2673' 1 4 GAS LIFT MA NDRELS A l .' ST MO TVD DEV TYPE VLV LATCH PORT DATE ' 1 � 1 . 4 3638 3536 26 KBG-2 RP BK 06/05/01 I _ N 3 6702 5586 52 KBG-2 DV BK 06/05/01 •1 o• 2 8353 6838 28 KBG -2 -9 DV BTM 06/05/01 Minimum ID = 1.78" 10700' * 1 ∎ • 1 9741 8077 26 _ KBG -2 -9 DV BIM _06/05/01 3" Deployment Sleeve Al , . 1 44 i , 4 TSGR = 10,104' MD A ,4 • 1 64 1 . • 4-1/2" TBG. 12.6#, L -80 -NSCT, 7041' I . 1 \ ,j 7041' I-14-112" X 3 -112 XO, ID = 2.938" .0152 bpf, LI = 3.958" '1 #' AI � 7110' 1 T' X 5-1/2" BOT CPH LNR TOP PERFORA DON SUMMA RY Al 9 1 PKR W /6" TIEBACK, ID = 4.875" REF LOG: •1 .4 A NGLEAT TOP PERF: 83 @ 10954' • 1 �� 9 -518" & 7" MILLOUT WINDOW (B 05A) 7274' - 7287' Note: Refer to Production DB for historical perf data � I. SIZE SPF INTERVAL Opn /Sqz DATE 1' ,. 9864' 3 -1/2" HES X NIP, ID = 2.750" I 2-1/2" 6 10954 - 10984 0 05/19/09 A l .4 9885' 5-112"X3-112" BKR S -3 PKR. ID = 2.780" 1 2-1/2" 6 11092 - 11112 0 05/19/09 1 A 2" 6 11312 - 11372 0 11/19/01 . 9909' H3 -112" HES X NIP, ID = 2.750" 1 2" 6 11750 - 11770 C 06/30/01 / 9919' — 13 -1/2" HES X NIP, ID= 2.750" I • 2" 6 11785 - 11825 C 06/30/01 � ' ,`� 9936' I-13-1/2" WLEG. ID = 2.992" W 7" HIPSTOCIK 7274' All 9 -5/8" CSG, 47 #, L -80. ID = 8.681" H 7274' 1 1 1 _ /. • Al. 3-1/2" packer whipstock at 11,270' 0 k Gi S4 ° � 3 -1/2" TBG, 9 2#, L -80 NSCT, .0087 bpf, ID = 2.992' IR 9930' 11600' — BKR 1- 11/16" IBP 1 5-112 "x 3-112 " BKR CPH LNR TOP PKR/HGR W/TIEBACK, OD = 2.992" 9930' �;. '4% (05/18/09) 5 -1 LNR, 17 #, L -80, STL -FJ, .0232 bpf, ID= 4.892 10089' : 1755' CTM — FISH: 11116" BKR IBP Top of 2 -3/8" liner and cement at - 10,700' (TAG OS /18109) 87 i lt=y 2 -3/8" chrome liner with TD at 13,820' ICTTAG ON OBSTRUCTION/RESTRICTION (07/29/02) I 11382' PBTD 11899' I3 -1/2" LNR, 9.2#. L -80, SR, 0087 bpf, ID = 2.992" 11963' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/12/78 ORIGINAL COMPLETION 05/29 +09 ? ? ?1TLH PERFS & IBP FISH (05/18/09) WELL: B -05C 06/04/91 RWO 02/0210 JLW /PJC 9 -5/8" CSG CORRECTION PERMIT No: x 2010680 07/01/96 RIG SIDETRACK 03/26/12 WJH proposed CTD sidetrack API No: 50- 029 - 20276 -02 06/05/01 RIG SIDETRACK SEC 31, T11 N, R14E 855 SNL, 1600 WEL 04/22/06 JNA /PJC SET IBP BP Exploration (Alaska) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM Cho e Panel Standpipe 2" Circulation Line . MM 11 L1 ,...m.. Driller Gaug• , M 10• C Manual Choke CIRCULATING MANIFOLD = M ; M ; MM 20 f � 1. I S O 1 MM 22 fII SLB Transducer — • . MM 6 a ! PVT Sensor • 7- 1/16" 5kpsi BOPE Air Blow down – – • • r ,,, MM 7 . ! . Blind Shears Line ;: :a M M M 15 = Baker Choke MM 4 i MM S MM 21 BUSTE. as :111: 2 -3/8" Combi ••s ME:19. ms Kill Line TOT PIS : . Rev Cir Line — _, !, MM14 CGa— _ F °s I —, ,,. S 1 -twwhoro: '�,ie t .. _ _ it .. t +I€.f:Iowp . �, t � �. ^` „ ■� �„ as -kk -, . . • ,� s • is - BOP 24 .. � � �� ~— III i Coiled Tubing — 1 "t ..... . 2- 318 " -3 -112 " VBR ram Ba er Choke .11. 2 -3/8" Combi MM1• * MP1in ± + MM 13 T$ II' Kill Line - Outlet 4--- Cement Line to Ground I II , c € -- Mud •2 in V I 4 s4 0 P - - - 4 1) u •• •s In r,,, Trandueere COILED TUBING 1111 Millillnl II 1 .881 CIRCULATING SYSTEM Cellar Iika Area [Outlets I F,ow cross ii To Inner Reel s;. Valve _ '•-• . ... HP3 HP 2 HP 1 ' . si • cement line N2 ( SLB ; NORDICS 2 I Circulate Manifold • At, _ •, • CHOKE MANIFOLD in Cellar ' HP 11 N2 TriFlow ./ CM 85 r . Gauge . C4 . -I — k iii ,rr ,11 irr III el 1 -. Test Pump Inlet = ,rr ,rr err ,rr err I f CM3 al 41 HDI Gauge CM18 - • • Flow f/ HCR� Q1 \ \ \, • 4Way Bloc k it To PITS CM14 CM1 CM8 C, 2 C • C C. 1 c Baker Choke Line II I Baker Choke Line from wal "c j BAKER CHOKE LINE CM13 MI faker Choke Line CM2 fT:: 9 — CM 29 o„ C2C = CM4 1 M 1 7 me r'HnKF I I NF E :-. I CM 75 CM10 MAIM - Tige Tank CM 25 Outside 1 • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS ( IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and ✓ operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 ~~, Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, bP ~; ~.._ .q aoi-o6$ ~- ~ ~' Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date: 12/11/09 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al B-Ot 1700080 50029200590000 Sealed Conductor NA NA NA NA NA &02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 &04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-05B 2010680 50029202760200 NA 1.8 NA 13.60 ti/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1:70 8/20/2009 &15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-i6 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 &21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 8-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA &28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 1020 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 6-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA -~ @a° PaoAwrlive D'IaynosTic SesvicES, INC. I/~fELL LAG TI~ANSM/TT,4L To: AC~CC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~Ul-~b~ «~~a ~a~-o31 ~~0~3 ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245.6952 1) Coil Flag 30-May-U9 G27A EDE 2J Coil Flag 19-May-09 B-05B Signed Print Name: EDE • 50-0221646-01 ~~~ Er02 Date ~1~ ail i~ ~~r~. Co~~~i~~io~^ ~~r~o PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCNORAOE, AK 99518 PHONE: (907)245-8951 FAX: (907)245$8952 E-MAIL : p~S~11ChOP~G~l1'1@6T10PVIO~.COB79 WEBSRE : wruuw.Praernorvlog.corro C:\DocianeM, and Settings\Ownet\Desktop\Tcansmit_BP.docx STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS RE~i~~~'~6~' MAY 2 ~ 209 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimutate~ ~~Si"C~ ~,.p~ ~ ~, ~ ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time ExtensiQ °` - °~-~_ Change Approved Program ~ Operat. Shutdown Perforate ~ - Re-enter Suspended V1fe1~.. °'~~~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r' - Exploratory 2o1-osso 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20276-02-00 - 7. KB Elevation (ft): 9. Well Name and Number: 71.5 KB - PBU B-05B - 8. Property Designation: 10. Field/Pool(s): ADLO-028310 _ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11965 - feet Plugs (measured) 11650 4/22/06 true vertical 9008.16 , feet Junk (measured) 11382' Effective Depth measured 11900 feet true vertical 9013 feet Casing Length Size MD TVD Burst Collapse Conductor 114 20" Surface - 144 Surface - 144 Surface 2634 13-3/8" 72# L-80 Surface - 2664 Surface - 2664 5380 2670 Intermediate 7244 9-5/8" 47# L-80 Surface - 7274 Surface - 6011 6870 4760 r tie-back sleeve 5490 7" 29# L-80 1784 - 7274 1784 - 6011 8160 7020 Sidetrack Liner 2979 5-1/2" 17# L-80 7110 - 10089 5910 - 8461 7740 6280 Sidetrack Liner 2033 3-1/2" 9.2# CR80 9930 - 11963 8318 - 9008 10160 10530 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 7041' 3-1/2" 9.2# L-80 7041' - 9930' Packers and SSSV (type and measured depth) 7"X5-1/2" BOT CPH LNR TOP PKR 7110' 5-1/2"X3-1/2" BKR SABL-3 PKR 9885' 5-1/2"X3-1/2" BKR CPH LNR TOP PKR 9930' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~'t~i~J~~~~~.atE~r 4~, ~-) ~ tlut' 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: 293 17922 7 2055 Subsequent to operation: 420 21719 4 1964 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development ~- ServiCe Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas ~ WAG ~ GINJ 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 Prebl Title Data Management Engineer Signature ~ ~ Phone 564-4944 Date 5/28/2009 Form 10-404 Re~iised 04/2006 a~ ~~. ,jE1V ~} r3 ~rQg ~~ Submit r'ginal Only B-056 201-068 PERF oTTO[:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base B-05B 6/30/01 PER 11,750. 11,770. 9,027.04 9,024.83 B-05B 6130/01 PER 11,785. 11,805. 9,023.23 9,021.16 B-05B 6/30/01 PER 11,805. 11,825. 9,021.16 9,019.2 B-05B 11/19/01 APF 11,312. 11,372. 9,042.34 9,045.47 B-05B 4/22/06 BPS 11,642. 11,825. 9,037.75 9,019.2 B-05B 5/19/09 APF 10,964. 10,984. 9,017.83 9,019.51 B-05B 5/19/09 APF 11,092. 11,112. 9,028.3 9,030.2 B-05B 5/20/09 APF 10,954. 10,984. 9,016.7 9,019.51 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 u s • B-05B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/19/2009 CTU #6 w/1.75" OD CT, Job Scope: Drift/Set IBP/ Log/Adperf <InterACT { ' ~publishing> ***Job continued from 5/18/2009*** MU and RIH with PDS memory 1 ~GR/CCL inside 2.2" carrier w/ 2.65" nozzle. Tag down -3.5k at 11,338' PU and pulled to 38k and broke back. PU to logging depth 11,300' ctm to start log. Log 'up hole at 30 fpm, flag pipe at 11,150 ctm and continue logging to 10,750'. POOH. OOH with good data. Based on PDS GR log, APE (Don Brown) & Geo ` (Cole Abel) changed Perf intervals. New Perf depths 10,954' to 10,984' (30 ft) ,and 11,092' to 11,112' (20'). MU Perf Gun BHA and RIH to flag. Correct Depth to j Top Shot and PUH to 11,092' Top Shot Depth and fire guns. POOH and all shots Ifired. MU Gun #2 and RIH w/2.50" Gun loaded with 6 spf-60 degree phasing j ' I2506 PJ charge. Correct to top shot at flag. Perforate interval from 10,964' to ;.10,984'. POOH. At surface reovered ball from firing head. MU and RIH un 3 Ew/2.50" Gun loaded with 6 spf 60 degree phasing 2506 PJ charge. _ `***Job in Progress***_ _ _ __ __ 5/20/2009 CTU #6 w/1.75" OD CT, Job Scope: Drift/Set IBP/ Log/Adperf <InterACT publishing> ***Job continued from 5/19/2009*** Continue RIH Gun #3 w/2.50" Gun loaded with 6 spf-60 degree phasing 2506 PJ charge. Correct to top shot at flag. Perforate interval from 10.954' to 10,964', had 136 psi pressure bump after the last shot. POOH. At surface reovered ball from firing head. Freeze protect tubing with 30 bbls of 50/50 meth. Pressure test tree cap to 3,500 psi. DSO ~ notified of well status M/W/S= O/C/C & Casing Valves open to gauges ***Job Complete*** 3 E FLUIDS PUMPED BBLS 64 50/50 METH 33 KCL 97 Total osn sio8 ~~b~~mbLt'~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~w~~ ~~~ ~ 2~~`~ wpu .Inh s 1 .... n..e.. ..s:.... N0.4887 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n~s~ M-04 11978480 MEM GRADIOMANOMETER LOG - ~~ 08/25/08 1 1 14-32 12031498 LDL - 07/29/08 1 1 H-20 11962621 USIT - "~- ~J 08/28/08 1 1 3-35/L-36 11999039 INJECTION PROFILE 09/04/08 1 1 3-37/L-35 11970845 FLUID LEVEL DETERMINATION (~ ~ 51 09/07/08 1 1 3-37/L-35 11968960 PRODUCTION PROFILE G "" 08/30/08 1 1 NK-38A 12017515 SBHP SURVEY ~ - 6. 09/02/08 1 1 L-215 12031512 INJECTION PROFILE 3 ~ '.. ''~ ~ 09/03/08 1 1 B-05B 12096914 MCNL 08/17/08 1 1 L-205L3 40016965 OH MWD/LWD EDIT "' 06/21/08 2 1 r ~~r. c ncvc~r ~ o ~ a~}a~ ~~ V e~'~`~v GI CJ1~11YIIYV l/,IVC ~.Vr T CMl~ll 1 V: BP Exploration (Alaska) Inc. '~~` . ~ ~"•,~ ~ m i+ , ~" Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~M., t~ _i , Anchorage, Alaska 99508 ~,~ ~t.) y C~ ,'(7~„fy Date Delivered: u,i+-~ ,) ~ ~ . r!,s„,` Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth ~ Received by: i~i • • e e r."~."'..,..._ .:f",~+"'ifi?' "' ., MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F :\LascrFiche\CvrPgs _Inserts\Microfi hn _ Marker.doc Permit to Drill 2010680 MD 11965~' TVD DATA SUBMITTAL COMPLIANCE REPORT 7~8~2003 Well Name/No. PRUDHOE BAY UNIT B-05B Operator BP EXPLORATION (ALASKA) INC 9008 /' Completion Dat 6/30/2001 ,'~' Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20276-02-00 UIC N REQUIRED INFORMATION Mud Log N__9o Sample No Directional Survey ~ ~,. ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt ~"~' Cn See Notes Log Log Run Name Scale Media No (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop OH I Dataset CH Received Number Comments 1 Directional Survey FINAL Directional Survey FINAL 10353 FINAL LIS Verification FINAL Compensated Neu 2/5 FINAL GR/CCL 11214 11515 Case 7233 11912 Open OH CH 7233 11912 oh oh 9798 11906 OH 12/14/2001 z..1.0655 Coil Flag 10/10/2001 z:~.0853 7233-11912 6/19/2001 MWD Survey, Digital Data 6/19/2001 Directional Survey, Paper Copy 10/10/2001 ..-1.0~53 7233-11912 Digital Data 10/10/2001 LIS Verification Paper copy 10/16/2001 9798-11906 BL, Sepia Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y N~ Chips Received? Analysis -YA--N'''''~'' R P.c.P. ivP. d ? Daily History Received? ~_~ / N Formation Tops "~/N Comments: Permitto Drill 2010680 DATA SUBMITTAL COMPLIANCE REPORT 71812003 Well Name/No. PRUDHOE BAY UNIT B-05B Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20276-02-00 MD 11965 TVD Compliance Reviewed By: 9008 ..~pletion Dat 6/30/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Date: -~ ~ J ~.i(~ ,.~ .? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Add Perfs Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Exploratory__ Stratigraphic._ Service_ 4. Location of well at surface 855' FNL, 1600' FEL, Sec. 31, T11N, R14E, UM At top of productive interval 3926' FNL, 4027' FEL, Sec. 29, T11N, R14E, UM At effective depth 438' FNL, 298' FEL, Sec. 25, T11 N, R12E, UM At total depth 3835' FNL, 5155' FEL, Sec. 29, T11N, R14E, UM (asp's 664036, 5949795) (asp's 666831, 5952065) (asp's 665766, 5952130) (asp's 665701, 5952131) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 114' Surface 2634' Intermediate 7244' Liner Tie-Back SIE 5490' Sidetrack Liner 2979' Sidetrack Liner 2033' 11965 feet Plugs (measured) 9008 feet 11900 feet Junk (measured) 9013 feet 6. Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-05B 9. Permit number / approval number 1 o'.~A"l~i'~i~'b'~i: ......... 50-02920276-02 11. Field / Pool Prudhoe Bay Oil Pool NECEiVED FEB 1 5 Alaska Oil & Gas Coas. Commission ^nchoraf]e Size Cemented Measured Depth True Vertical Depth 20" X 30" 300 sx Cement 144' 144' 13-3/8" 5200 cf Cement 2664' 2664' 9-5/8" 1936 cf Cement 7274' 6011' 7" 1125 cf Class 'G' 1784' - 7274' 1784' - 6011' 5-1/2" 424 cf Class 'G' 7110' - 10089' 5910' - 8461' 3-1/2" 174 cf Class 'G' 9930' - 11963' 8318' - 9008' Perforation depth: measured Open Perfs 11312' - 11372', 11750' - 11770', 11785' - 11825' true vertical Open Perfs 9042' - 9045', 9027' - 9025', 9023' - 9019' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 Cr 80 TBG @ 10839'. 4-1/2", 12.6# Tubing Tail @ 10904'. Packers & SSSV (type & measured depth) 9-5/8" x 7" BKR SBP PKR w/TB SLV @ 1784'. 7" x 5-1/2" BeT CPH LNR Top PKR w/ 6" TB @ 7110'. 5-1/2" x 3-1/2" BKR SABL-3 PKR @ 9885', 5-1/2" x 3-1/2" BKR CPH LNR top PKR/HGR w/Tieback @ 9930'. 4-1/2" HES X Nipple @ 2194'. 13. stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/18/2001 Subsequent to operation 01/17/2002 Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Well Shut-In 533 15527 109 Casing Pressure Tubing Pressure 217 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil _X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DeWayne R. Schnorr Form 10-404 Rev 06/15/88 Date January 28, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLiCATE~ 11/09/2001 11/18/2001 11/19/2001 11/09/01 11/18/01 11/19/01 B-05B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DRILL-POST WORK: DRIFT (PRE CTU ADD PERF) DRILL-POST WORK: MEMORY GR/CCL, ADD-PERF 60' DRILL-POST WORK: ADD PERF 60' EVENT SUMMARY DRIFTED WITH 2.30" CENTRALIZER. OVERCOME BY DEVIATION AT 10907' WLM. RDMO. MIRU DOCT #3. BULLHEAD KILL WELL WITH 2% KCL AND CRUDE CAP. RIH W/MEMORY GR/CCL. LOG 11200-11500 AT 30 FPM. POH. VERIFY DATA GOOD. JOB IN PROGRESS. RIH WITH GUN#l- 2" 20' LOADED 6 SPF 60 DEG PHASING RANDOM ORIENTATION. PERFORATE 11352' - 11372'. POH W/ASF. RIH WITH GUN #2. PERF 11332'- 11352'. POOH W/ASF. RIH WITH GUN #3. PERF 11312'- 11332'. POOH W/ASF. FP WELL AND TURN WELL OVER TO DSO & PCC TO POP. FLUIDS PUMPED BBLS 112 60/40 METHANOL WATER 94 CRUDE 142 2% KCL WATER 348 TOTAL ADD PERFS 11/19/2001 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" PJ 6SPF, 60 DEG PHASING, RANDOM ORIENTATION. 11312' - 11372' Page I WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"~Street Suite # 700 Anchorage, Alaska 99501 RE · Distribution- Final Print(s) The technical data listed below is bei'ng submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR -- Open Hole 1 I 1 .__ Res. Eval. CH I I I -- B-O5b 1 1/1 8/01 Mech. CH 1 '-7 [ Caliper Survey Signed · Print Name: Date · RECEIVED 1,.'.; 2001 AJaska 0i~ & Gas Co~s. Commi~ion A,~c~r~e ProActive Diagnostic Services, Inc., 310 K Street SuiTe 200, Anchorage, Al( 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage(~memorylog.com Website: www.memory..Io~, om .......................................... O' .,C. .............. 10/05/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 15t0 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD L2-18A I C~ 8- / L~ ~ LFAK DETECTION LOG 09/17101 MPC-24 <~l --(.~ Hq 21385 PERF RECORD GR (PDC) 08102/0t D.S. 11-01A /C~ ~ .- ~1 ~. 21392 RST-SIGMA 06109/98 P1-02 I ~"-(~)~..~ 21231 RST-SIGMA 04/21/01 B-05~ lC~l~_.,.~ ~/_~,-",'~_~ - 21332 MCNL 0612910t D.S. 11-01A jC~-~lo~ 21232 RST-SIGMA 0412Sl0t M-24A b0/-Io~ 21360 MCNL 08104/01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED OCT 1 001 Alaska 0il & Gas Cons. Commission Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received by~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska October 8, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs B-05B, 1 LDWG formatted Disc with verification listing. APl#: 50-029-20276-02 AK-MM- 10151 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED OCT 1 0 2001 AJaska Oil & Gas Cons. Commission A~omge STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-068 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20276-02 ' 4. Location of well at surface, ' i 3Z3C-A3'tON~ - 9. Unit or Lease Name 855' SNL, 1600' WEL, SEC. 31, T11N, R14E, UM '" ~ Prudhoe Bay Unit At top of productive interval 1353' NSL, 1252' EWL, SEC. 29, T11N, R14E, UM " ~,-; ':'" 10. Well Number At total depth 1444' NSL, 123' EWL, SEC. 29, T11N, R14E, UM .....-., .~..,,., ~ ..... . ...... B-05B ,. 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 71.50' ADL 028310 12. Date Spudded5/12/2001 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband' 115' Water depth' if °ffsh°re "116' N°' °f C°mpletions5/30/2001 6/30/2001 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11965 9008 ETI 11900 9013 FTI []Yes []NoI (Nipple) 2194 MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, Res, Neu, Den 23. CASING~ LINER AND CEMENTIN~ REcoRD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" X 30" Insulated Conductor Surface 114' 36" 300 sx Cement 13-3/8" 72# N-80 Surface 2664' 17-1/2" 5200 cu ft Cement 9-5/8" 47# S00-95/N-9 Surface 7274' 12-1/4" 1936 cuft Cement 7" 26# L-80 1784' 7274' LTD Liner Tie-Back Sleeve, 1125 cu ft 'G' 5-1/2" 17# L-80 7110' 10089' 7" 424 cuft Class 'G' 3-1/2" 9.2# L-80 9930' 11963' 4-3/4" 174 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 SPF 4-1/2", 12.6#, NSCT 7043' 9885' MD TVD MD TVD 3-1/2", 9.2#,' L-80 7043' - 9936' 11750' - 11770' 9027' - 9025' , ....... 11785' - 11825' 9023' - 9019' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) , AMOUNT &, KIND OF MATERIAL USED Freeze Protect with 135 Bbls of Diesel ..... 2,71, PRODUCTION TEST ................................................................ Date First Production ' Method of Operation (Flowing, gas Jift, etc.) ....... July 2, 2001 Gas Lift , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/3/2001 4 TEST PERIOD 727 8973 39 95.82I 12345 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED AUG B 8 7_001 Alaska Oil & Gas Cons. Commission ~ ~ ,, A I I~ I A ! ~,nnhnrR(~e Form 10-407 Rev. 07-01-80 ORiGiNAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. TSGR 10104' 8475' TSHU 10138' 8505' TSHB 10174' 8537' TSHC 10194' 8554' TSAD 10224' 8580' 24P 10826' 8988' 22P 11270' 9040' 22N invert 11738' 9029' 31. List of Attachments: S'u'm'mary of Daily DrilJing Reports, Sun/eys, Leak Off Test Summary ..... 32.' I h 'ere~'y certify th'at the fo'reg/oi'n'g'"iS t~'ue and 'co~rect'io th"e b;st of' mY'knoWledge Signed Terrie Hubble Title ..........TeChn ca Assistant ____._.i !..__ ...._.___ ............................. Dat? ...... B-05B 201-068 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No./Ap.p.[o.v..a! Nor ........................... INSTRUCTIONS (~ENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no COreS taken, indicate 'none'. ORIGINAL Form 10-407 Rev. 07-01-80 Legal Name: B-05 Common Name: B-05B Test Date:I ::: TeSt:~epth (TMD):i: : i :::::: ::AMW Surface pressure Leak Off Pressure (BHP) EMW 5/9/2001 FIT (fi) (ft) (PPg) (psi) (psi) (PPg) 5/11/2001 FIT 7,274.0 (ft) 6,029.0 (ft) 9.80 (ppg) 850 (psi) 3,919 (psi) 12.51 (ppg) 5/21/2001 FIT 10,124.0 (ft) 8,493.0 (ft) 8.50 (ppg) 440 (psi) 4,190 (psi) 9.50 (ppg) i Printed: 6/28/2001 10:31:04 AM BP AMOCO Page I of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 5/8/2001 00:00 - 05:00 5.00 MOB P PRE Move camp,shop & pits. Move & spot Rig over well. Spot pits, PJU all circ. lines Start taking on seawater. ACCEPT RIG @ 05:00 Hrs. 05:00 - 07:00 2.00 RIGU P PRE R/U circ lines to tree & bouy line to cuttings tank. Complete taking on seawater. Test surface lines to 3500 psi. 07:00 - 08:30 1.50 PULL P DECOMP PJSM w/crew & DSM. PJU lubricator, pull BPV, PJD lubricator. Well dead and static. 08:30 - 12:00 3.50 CLEAN P DECOMP Reverse circ. diesel from tubing. Then circ. down tubing to displace diesel from 7" X 9 5/8" annulus. Shut down and observe well - ballanced and dead. 12:00 - 13:30 1.50 CLEAN P DECOMP Circ.tubing and annulus to cut - 7400'. Well Clean. Shut down - Well Static. 13:30 - 14:00 0.50 WHSUR P DECOMP Set TWC - Test to 1000 psi from below. 14:00 - 16:00 2.00 WHSUR P DECOMP N/D Tree & adaptor flange. Check Hgr. threads & LDS 16:00- 18:00 2.00 BOPSUF~P DECOMP N/U BOPE 18:00 - 21:30 3.50 BOPSUF P DECOMP Test BOPE, 250 / 3500 psi. - APl. Witness of test waived by Chuck Scheve, AOGCC. 21:30 - 22:30 1.00 BOPSUF~,P DECOMP R/U DSM, Pull TWC, RID DSM. 22:30 - 00:00 1.50 PULL 'P DECOMP R/U to pull 4.5" Tubing; Tongs and thread protectors to rig floor. M/U Pulling Jt. w/XO to hanger. Run in and screw into Hanger. Back out LDS. 5/9/2001 00:00 - 00:30 0.50 PULL P DECOMP Work Tubing to part Jet cut. Parted @ 205K. Sting wt.of 110K. 00:30 - 01:30 1.00 PULL P DECOMP Break out and LID Tbg Hgr. Appears in good condition. R/U Camco control line spooler. 01:30 - 14:30 13.00 PULL P DECOMP POH w/4.5" completion string. 176 Jts Tubing, 1 SSSV., 2 GLM., and 37.39" of Tbg cut-off. Also recovered 33 out of 57 SS bands: 24 in Hole. Tubing was very tight, had to hammer every Jr. All Tbg, comp., and wellhead equip. NORM Tested. 14:30 - 15:00 0.50 PULL P DECOMP M/U ported jetting sub and flush stack. Install W/R. 15:00 - 17:00 2.00 CLEAN P DECOMP M/U BHA # 1- Baker Whipstock Milling Assy., DC's. Jars& HWDP. 17:00 - 21:30 4.50 CLEAN P DECOMP RIH P/U 4" DP from pipe shed. 21:30 - 23:00 1.50 CLEAN P DECOMP Slip & Cut drilling line 80 ft. Service Top Drive. 23:00 - 00:00 1.00 CLEAN 3 DECOMP Continue RIH w/4" DP from Derrick. 5/10/2001 00:00 - 01:00 1.00 CLEAN 3 DECOMP Cont. RIH Tag Tubing stub @ 7406' P/U = 150K S/O - 120K. 01:00 - 02:00 1.00 CLEAN 3 DECOMP Pump Hi Vis Sweep @ 500 GPM 02:00 - 05:30 3.50 CLEAN 3 DECOMP i POH LID Jars & Mills. 05:30 - 06:30 1.00 CLEAN 3 DECOMP R/U SWS E Line equip PJSM w SWS & HES 06:30 - 09:00 2.50 CLEAN 3 DECOMP Run 6.05 Gauge ring, Junk catcher & PDC-GR. Retrieved 7 SS bands. 09:00 - 14:00 5.00 CLEAN 3 DECOMP Made 3 additional runs with junk catcher. Retrieved 3 SS bands and a few pieces .Wellbore relatively clean. 14:00 - 17:30 3.50 DHEQP 3 DECOMP Run HES CIBP on SWS E-Line. Correlate to PDC - GR. Set CIBP with Top @ 7288'. 17:30 - 18:00 0.50 DHEQP 3 DECOMP Test Casing and CIBP to 3500 psi - 30 minutes OK 18:00-22:00 4.00 STWHIP ~ WEXIT M/U BH^#2-Whipstock/Milling ^ssy., Scribe, plug in and load LWD RIH w/DC's & HWDP. Flow test MWD. OK 22:00 - 00:00 2.00 S'I'WHIP ~ WEXIT RIH w/4" DP. Had to work into Liner Top @ 1792 DD. Dropped in with slight rotation.& minimum wt. 5/11/2001 00:00 - 02:00 2.00 STWHIP ~ WEXIT Continue RIH to 7240'. P/U = 150K S/O = 123K 02:00 - 03:00 1.00 STWHIP ~ WEXIT Break Circ.. Orient Whipstock - Final orientation - 82 deg Left Printed: 6/11/2001 2:50:,40 PM BP AMOCO Page 2 of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/11/2001 02:00 - 03:00 1.00 STWHIP P WEXlT of Highside. RIH Tag CIBP at 7292' DD. Set Anchor w/20K. P/U 5K over to verify. Shear Whipstock w/37 K. 03:00 - 04:00 1.00 STWHIP P WEXlT Displace Wellbore w/9.8 ppg. LSND Mud while working pipe to establish rotation. Established rotation - 60 RPM @ 4K to 5K Torque. 04:00 - 10:30 6.50 STWHIP P WEXlT Mill Window from 7274' to 7287' ROT @ 60 to 125 Torque from 4k to 9K. Cir¢ @ 292 GPM @ 1650 psi. Ran 2K to 10K on Mill. Pump sweep every 5 ft. 10:30 - 13:30 3.00 STWHIP! P WEXIT Drill 6 1/8" Hole from 7287' to 7308'. 115 to 125 RPM, 292 GPM @ 1650 psi. Torque - 6K to 8K. WOB - 4K to 16K. 13:30 - 14:30 1.00 STWHIP P WEXIT Work Mills through Window with pumps, then without pumps. Window Clean and clear Pump Hi Vis Sweep. 14:30 - 15:30 1.00 STWHIP P WEXlT Complete Sweeping Hole clean. Perform FIT w/9.8 ppg.mud & 850 psi surface pressure to an EMW of 12.51 ppg. 15:30 - 21:00 5.50 STWHIP P WEXIT POH. Trying to swab 1st. 5 stands Work pipe & pump out total 10 stands Hole then taking right amt. of displacement. Cont POH. Stand back HWDP & DC's. 21:00 - 23:00 2.00! STWHIP P WEXlT Down load MWD and re-load for next run. LID BHA # 2. Mills In-Guage. 23:00 - 00:00 1.00 STWHIP P WEXlT Service wear bushing. Jet Flush BOP Stack. Blow dn Top Drive. 5/12/2001 00:00 - 02:00 2.00 DRILL P INT1 M/U BHA # 3. Orient. RIH Flow test MWD @ 890'. 02:00 - 06:00 4.00 DRILL P INT1 RIH to 7178'. 06:00 - 07:00 1.00 DRILL ~ INT1 Cut & Slip Drlg. Line Service Brakes & crown. PJSM 07:00 - 07:30 0.50 DRILL 3 INT1 Orient tool face. Slide through window pumps off. Slide to bottom @ 7308'. No Drag - No Fill. Window and Hole Slick! 07:30 - 00:00 16.50 DRILL 3 INT1 Kick Off Sliding per Directional Driller. Drill 4 3/4" X 7" Directional Hole from 7308' to 7551'. WOB 2 to 4K. Pump 268 GPM @ 1720 psi. P/U -- 150K S/O = 121K AST - 15 Hrs. 5/13/2001 00:00 - 00:00 24.00 DRILL 3 INT1 Directional Drill 4 3/4" X 7" Hole from 7551' to 7773'. Pump 266 GPM @ 1740 psi. WOB = 2 - 5K ~P/U = 155K S/O = 125K ALL SLIDE - 19.5 Hrs. 5/14/2001 00:00 - 19:00 19.00 DRILL 3 INT1 Directional Drill 4 3/4" X 7" Hole from 7773' to 8300'. WOB = 2 - 6K, Torque = 6 - 7K ROT = 40 -70 RPM Pump - 266 GPM @ 2180 psi. P/U - 168K, S/O = 122K, ROT = 138K. Tendancy to build angle when Rotating. Still unable to Log w/LWD while rotating - Sperry hand says "too much noise". 19:00 - 20:00 1.00 DRILL 3 INT1 Circ. around Hi Vis Sweep. PJSM 20:00 - 21:00 1.00 DRILL 3 INT1 POH through Window @ 7274' P/U = 185K off bottom w/o pumps. Never more than 5K drag. 21:00 - 22:30 1.50 DRILL ~ INT1 Svc & inspect wear strips on Top Drive. Slip & Cut 130' of drilling line. 22:30 - 00:00 1.50 DRILL P INT1 Orient Mud Motor above Whipstock to 94 deg Left. Stop at btm of window. P/U & orient to 86 deg. Left. RIH to 8300'. No Drag - No Fill. 5/15/2001 00:00 - 00:00 24.00 DRILL P INT1 Cont drill ahead 8300 ft to 9232 ft. Hole good condition at connections. No abnormalties. No lost circ. Flow checks at connections. Encounter top HRZ at 9078 ft.( 7558 tvd ). ART 9.5 hrs AST 0 hrs Up 185, dn 133, Rot 142 Printed: 6/11/2001 2:50:40 PM BP AMOCO Page 3 of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/16/2001 00:00 - 00:00 24.00 DRILL ~ INT1 Cont drill ahead 7" drctnl hole 9232 - 10000 ft. Well bore good condition. No abnormalties, lost circ, !high torque / drag. Flow check at connections. ART10hrs AST0hrs Up 190, Dn 138, Rot 160 5/17/2001 00:00 - 05:00 5.00 DRILL P INT1 Cont drill ahead 7" hole 10000 - 10104 rd. Flow check. Encounter Sag R at 10102 ft MD, 8470 ft TVD 05:00 - 07:30 2.50 DRILL P INT1 Circ for samples, geo confirm rd, circ sweep, shaker clean. 07:30 - 09:30 2.00 DRILL P INT1 Prepare and poh to window, no abnormalties. 09:30 - 10:00 0.50 DRILLP INT1 Service top dr / crown. 10:00 - 14:00 4.00 DRILL P INT1 Flow check, Orient 80 deg L, rih, precautionary wash 90 ft to btm, no fill. Spot liner pill during wash. 14:00 - 18:00 4.00 DRILL P INT1 Flow check, pump wt pill, poh to bha for liner run, lay out same. 18:00 - 20:30 2.50 DRILL P INT1 Lay dn jar, remainder bha, download mwd, break bit / fwd assy. 20:30 - 21:30 1.00 CASE P INT1 Clear rig floor, place liner equip on floor, ru same. 21:30 - 00:00 2.50 CASE P INT1 Flow check, commence rih 5 1/2 liner shoe track, ( shoe, 2jts 5 1/2, float, pup, insert jt ), fill pipe, check floats, follow with 5 1/2 17# L-80 liner jts.(3) 5/18/2001 00:00 - 05:30 5.50 CASE P INT1 P/U and run 72 Jts of 5.5" 17# L-80 STL-FJ Casing + BOT 5 1/2" x 7" HMC liner hanger & CPH liner packer. Liner wt - 42.3k. Total length = 2979.03'. Torq-turn was ran while M/U the 5.5" Liner. 05:30 - 06:30 1.00 CASE P INT1 Circulate one liner volume ( 69 bbl ) through the 5.5" casing @ 2 bpm w/400 psi. 06:30 - 10:30 4.00 CASE P INT1 TIH with the 5.5" Drilling liner on 4" DP to the 7" casing window @ 7274'. No mud loses observed. 10:30 - 11:00 0.50 CASE P INT1 M/U the BOT Plug Launcher/Cement Head on a single of 4" DP. LID same in V-Door. 11:00 - 12:00 1.00 CASE P INT1 Break circulation and circulate 69 bbl through 5.5" liner @ 2 bpm w/700 psi. 12:00 - 15:30 3.50 CASE P INT1 Continue TIH with 5.5" Liner on 4" DP to 10,104'. Tagged bottom. P/U 15', set the slips, stood back one stand of 4" DP. P/U BOT Cement head w/one single of 4" DP and M/U in string. When we picked up out of the slips the 5.5" casing was stuck. 15:30 - 16:00 0.50 CASE P INT1 Establish circulation and stage pumps up to 4 bpm w/970 psi with full returns and no mud losses observed. Attempt to free pipe by slacking off with full string wt, no good. Work pipe, maximum pull was 300K. All indications are that the 5.5" casing is differentially stuck with the 5.5" casing shoe @ 10,089'. 16:00 - 18:30 2.50 CASE P INT1 Circulation and condition mud @ 4 bpm w/950 psi. ~ Intermittently work pipe in an attempt to free the 5.5" casing-no success. 18:30 - 19:00 0.50 CASE P INT1 PJSM with Rig Crew, Bariod Mud Engineer, Dowell cementers, Baker Packer Rep and Peak truck drivers. 19:00 - 21:00 2.00 CASE P INT1 Flow check, commence batch mix cmt while testing lines to 4500 psi. Begin pump 12# mud push spacer, 50 bbl 13 ppg lead slurry, 25.5 bb115.8 ppg tail slurry, drop dart, displace Printed: 6/11/2001 2:50:40 PM BP AMOCO Page 4 of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/18/2001 19:00 - 21:00 2.00 CASE P INT1 5 bbl drill water, switch to 10.8 ppg mud with 73 bbls displacement to shear wiper plug (1025 psi), cont displace, bump plug at 2045 hrs with 139 bbls tot displacement. Build to 2150 psi and note liner hgr set. Slack off42 K, verify hgr set. Build to 3510 psi, set liner pkr. Bleed 1.4 bbl to tank, floats holding. 21:00 - 21:30 0.50 CASE P INT1 Determine neutral wt, rotate out / release liner running tool, pu with 1000 psi on liner, note bleed down, seals out of tie back extension. 21:30 - 00:00 2.50 CASE P INT1 Circ / cond mud, clean out liner top. Test lap 1000 psi / 10 min. Test successful. Cont circ / cond. 5/19/2001 00:00 - 01:00 1.00 CASE P INT1 Complete circ, break cmt hd, lay out same, release Dowell. 01:00 - 05:00 4.00 CASE P INT1 Poh stdng bk 52 stds 4" dp. lay dn remaining 69 jts. 05:00 - 05:30 0.50 CASE P INT1 Break and lay out liner run tool, lay out same. 05:30 - 10:00 4.50 CASE P INT1 Drain stack, remove wear bshg, set test plug, test bope, surface equip, floor valves, standpipe ckoke manifold, all related equip to 250/3500 psi as per BP specs. All tests successful. Waived by John Crisp AOGC Remove test plug, install wear bshg. Flow check. 10:00 - 12:30 2.50 CASE N DFAL INT1 PJSM, mu motor / mwd / Iwd bha. Fail to "load" tool. 12:30 - 19:30 7.00 CASE N DFAL INT1 Troubleshoot tools, lay out same, take readings in pipe shed. MU tools once more, failed loading. Perform shallow test in hole, 135 gpm @ 1120 psi. failed test, erratic signals. PU new MWD / LWD assy, re-test, 42 spm @ 2400 psi. Press abnormal. Lay dn assy, test with top drive only, 160 gpm @ 20 psi. Confirm restriction at MWD assy. 19:30 - 00:00 4.50 CASE N DFAL INT1 Make up slick bha / bit, 20 jts hwdp, follow with 2 7/8 dp 5/20/2001 00:00 - 01:30 1.50 CASE = INT1 Rih 2 7/8 dp in sgls to 2615 ft. 01:30 - 04:00 2.50 CASE N DFAL INT1 Flow check, Attempt break ¢irc, build to 3000 psi, no circ, no bleed. Chase pipe, build and bleed. Numerous methods of removing restriction with limited success. Regain slight flow 50 spm @ 2800 psi. 04:00 - 12:00 8.00 CASE N DFAL INT1 Flow check, prepare and poh to bha for inspection. Found Drill Pipe float valve was severly twisted & damaged. This would not allow the flapper to open on float. The inside of the bit sub was also washed at float bore. 12:00 - 12:30 0.50 CASE N DFAL INT1 Lay out jar, XOs monel. 12:30 - 19:30 7.00 CASE N DFAL INT1 Make up mwd / motor assy. Test with H2o, 140gpm @ 580 psi. Test with 10.8 ppg, 155 gpm @ 1250 psi. Change out mwd / resistivity tool. Re-test, 155 gpm @ 1250 psi. Test successfull. Make up motor, bit, test 155 gpm @ 2225 psi. Make up remainder bha #4, rih same. 19:30 - 00:00 4.50 CASE N DFAL INT1 Flow check, follow bha with 2 7/8 dp, 4" dp, filling circulating at 10 std intervals. Ending cir¢= 155 gpm @ 2600 psi, 2900 ft. Full returns. Printed: 6/11/2001 2:50:,40 PM BP AMOCO Page 5 of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/21/2001 00:00 - 04:00 4.00 CASE P INT1 Cont rih 4" dp, filling at 10 std intervals, to 9700 ft. Break circ with 3260 psi / 155 gpm. 04:00 - 04:30 0.50 CASE P INT1 Test csg 3500 psi / 15 min. Test successful. 04:30 - 06:30 2.00 CASE P INT1 Wash to 10007 ft, tag, correllate depth with Sperry Sun. 06:30 - 09:00 2.50 CASE P INT1 Drill out cmt, float equip, shoe track to 10087 ft. 09:00 - 09:30 0.50 CASE P INT1 Test csg to 3500 psi / 30 min. Test successful. 09:30 - 10:00 0.50 CASE P INT1 Drill out guide shoe @10089ft and clean out 7" Rathole to 10104 ft. Flow check. 10:00 - 13:30 3.50 CASE P INT1 Displace well with 8.4 ppg XCD "Quickdrill". Flow check. 13:30 - 14:00 0.50 DRILL P 'PROD1 Drill 4 3/4 hole 10104 - 10123 ft. Flow check. 14:00 - 14:30 0.50 DRILL P PROD1 Perform FIT. 450 surface press = 9.5 ppg EMW Test successful. i14:30 - 18:30 4.00 DRILL P PROD1 Drill ahead 4 3/4 hole to 10204 ft. Flow check. Lost circ. 80 bbl / hr and increasing. 18:30 - 00:00 5.50 DRILL N DPRB PROD1 Pull into 5 1/2 shoe, mix and pump total 3 Icm pills, soaking 30 min each. #1 = 50 bb115 ppb CaCo3, i#2 = 50 bbl 20 ppb CaCo3 / 5 ppb Fibre, #3 = 50 bbl !20 ppb CaCo3 / 10 ppb fibre. Total losses = 220 bbls ~ Regain partial circ 18%, static losses 0. 5/22/2001 00:00 - 02:30 2.50 DRILL N DPRB PROD1 Complete spot final Icm pill, soak 30 min, wash to 10204 ft, returns increasing from 13 to 18%. Losses @ 155 gpm = 28 bph. 02:30 - 03:00 0.50 DRILL P PROD1 Flow check, drill ahead 4 3/4 hole 10204 - 10215 ft. No signal mwd. 03:00 - 04:00 1.00 DRILL P PROD1 Troubleshoot mwd, regain signal. 04:00 - 12:00 8.00 DRILL P PROD1 Resume drlg 10215 - 10403 ft. Can not achieve desired angle/dog leg. Up 164, dn 136, rot 147 tq dn 3K, tq up 3 K. Art .5 hr, Ast 4.5 hrs losses reduced to bph. 12:00 - 12:30 0.50 DRILL P PROD1 Spot Lcm on btm, prepare poh for motor angle. 12:30 - 19:00 6.50 DRILL P PROD1 Flow check, poh to hwdp. 19:00 - 21:00 2.00 DRILL P PROD1 Handle bha, lay out 2 7/8 hwdp, DCs., motor assy. 21:00 - 22:30 1.50 DRILL P PROD1 Make up XOs, flow test motor assy with H2o and 8.4 ppg drlg fluid. 150 gpm @ 660 psi, both tests. 22:30 - 00:00 1.50 DRILL P PROD1 Download and re-program tools, mu mwd /Iwd assy, begin pu 4 3/4 bha. 5/23/2001 00:00 - 00:30 0.50 DRILL P PROD1 Flow check, mu bha #6, follow with 2 jts 2 7/8 dp. 00:30 - 02:30 2.00 FISH N HMAN PROD1 Dropped bha / 2 its 2 7/8 dp in well thru slips. No collar clamp on light string. Prepare for fishing op. Wait on tools. 02:30 - 09:00 6.50 FISH N HMAN PROD1 Place fish bha components on floor, assemble same, rih, flow check. Losses stable at 4 bph. 09:00-15:30 6.50 FISH N ~HMAN PROD1 Follow bha with 2 7/8 dp / 4" dp to TOF10138 ft. 15:30 - 16:30 1.00 FISH N HMAN PROD1 Engage fish, screw in, note torque / press increase. Work string, verify engagement. Stop pump. Flow check. Losses 4 bph. 16:30 - 00:00 7.50 FISH N HMAN PROD1 Poh, indications continue to show fish latched. PJSM, handle 2 7/8 dp. 5/24/2001 00:00 - 07:30 7.50 FISH N HMAN PROD1 Resume poh with fish, break out fish assy, lay dn fish. 100% recovery. Flow check, 3 - 4 bph losses. 07:30 - 10:30 3.00 DRILL N HMAN PROD1 Slip and cut drlg line, service top drive, while wait Printed: 6/11/2001 2:50:,40 PM BP AMOCO Page 6 of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/24/2001 07:30 - 10:30 3.00 DRILL N HMAN PROD1 on XO inspection. 10:30 - 14:30 4.00 DRILL N HMAN PROD1 Place bha # 7 components on rig floor, assemble same. Download mwd, mu and surface test motor/ mwd. 150 gpm 900 psi. test successful. Make up rih remaining bha. Flow check. Losses 3-4 bph. 14:30 - 18:30 4.00 DRILL P PROD1 Rih 2 7/8 dp followed with 4" dp to 5 1/2 liner shoe. 18:30 - 21:00 2.50 DRILL P PROD1 Wash out of liner shoe 90 ft. Hole good cond. Rih 2 stds, precautionary wash 90 ft to btm. No fill. 21:00 - 00:00 3.00 DRILL P PROD1 Commence drill ahead 4 3/4 hole 10402 - 10473 ft. ART - 0, AST - 2 Losses 5 bph 5/25/2001 00:00 - 00:00 24.00 DRILL ' P PROD1 Resume drill ahead 4 3/4 drctnl hole 10473 - 11130 ft Hole good cond, no abnormalties. Sliding total footage. Losses 2-3 bph. Flow checks at connections. ART - 0, AST - 8 1/4 hrs. 169 up, 137 dn, 151 rot. Tq 4 - 5K, Tq off btm 3 -4K 512612001 00:00 - 02:00 2.00, DRILL P PROD1 Circ btms up, pump wt pill, flow check. 02:00 - 03:00 1.00 DRILL P PROD1 Prepare and poh for bit to 5 1/2 shoe at 10065 ft. Tight at 10075 ft, work free. Tight various intervals 11000 - 10400 ft with slight swabbing. Recip string, no swabbing / excess O pull. 03:00 - 14:00 11.00 DRILL P PROD1 Flow check, poh to bha. 14:00 - 16:00 2.00 DRILL P PROD1 Lay dn mwd / motor assy. Download mwd. Inspect bha components. 16:00 - 20:00 4.00 DRILL P PROD1 ;Test bope, standpipe, top drive ibop, floor valves, choke manifold, all related compnents as per BP specs. 250 / 3500 psi 15 min. All tests successful, and witnessed John Spaulding AOGCC. No leaks, or re-tests. 20:00 - 23:00 3.00 DRILL ~ :PROD1 Mu bha # 8, adj motor to 1.5 deg, flow test mwd, motor. 150 gpm / 925 psi. 23:00 - 00:00 1.00 DRILL ~ PROD1 Flow check, follow bha with 2 7/8 dp. 20 jts. 5/27/2001 00:00 - 06:30 6.50 DRILL ~ PROD1 Resume rih 2 7/8 dp, follow with 4"dp to 10069 ft. No resistance 5 1/2 liner top. Losses 2 - 5 bph. '06:30 - 07:30 1.00 DRILL ~ PROD1 Flow check, service rig / top drv, while fill pipe, break circ. Losses 2 - 5 bph. 07:30 - 09:30 2.00 DRILL ~ PROD1 Cont rih, precautionary wash / ream 10629 - 11130 ft due to tight hole conditions this interval at trip out. No fill on btm. 09:30 - 00:00 14.50 DRILL P PROD1 Flow check, orient / drill ahead 4 3/4 hole drctnl 11130 - 11376 ft. Losses 5 bph. Up 166, Dn 138, rot 152 Torque 3-4 K. 5/28/2001 00:00 - 16:00 16.00 DRILL ~ PROD1 Cont drill ahead 4 3/4 hole 11376 - 11618 ft, decline in top and hole angle. Losses - 3 bph. 16:00 - 20:30 4.50 DRILL P PROD1 Flow check, prepare and pump wt pill, commence ~oh for bit. Hole good cond. Monitor well at 5 1/2 shoe. 20:30 - 23:30 3.00 DRILL P PROD1 Resume poh to bha. 23:30 - 00:00 0.50 DRILL P PROD1 Flow check, handle bha # 7. 5/29/2001 00:00 - 02:00 2.00 DRILL P PROD1 Cont POH for bit. LD 3 flex DC. BO bit and LD mtr. Down load MWD. PJSM. 02:00 - 03:00 1.00 DRILL P PROD1 MU bit RR # 7. Orient mtr. Cont PU BHA #9. Printed: 6/11/2001 2:50:40 PM BP AMOCO Page 7 of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/29/2001 03:00 - 04:00 1.00 DRILL P PROD1 PJSM. PU 1 std 2 7/8" DP. Surf test mtr and MWD. 63 spm, 155 gpm, 975 psi. Blow dwn top drive. Fill hole and monitor losses, minimal, less than 4 BPH. 04:00 - 07:30 3.50 DRILL P PROD1 Cont RIH w/2 7/8" DP using dog collar. No indication of 7" liner top at 1784 feet. 07:30 - 08:00 0.50 DRILL P PROD1 RU for 4" DP. Fill pipe. PJSM. 08:00 - 11:00 3.00 DRILL P PROD1 RIH with 4" DP to 10065 feet. No indication of 5 1/2" liner top @ 7110 feet. Minimal losses. Fill pipe. PJSM slip and cut drill line. 11:00 - 12:30 1.50 DRILL i p PROD1 Service rig top drive. Slip & Cut Drilling line 70'. 12:30 - 13:30 1.00 DRILL P PROD1 Cont RIH to 11560 feet. Hole slick. 13:30-15:00 1.50 DRILL P PROD1 Wash / Ream to TD @11618 feet. 2 foot of fill. Pumpsweep around. 15:00 - 00:00 9.00 DRILL P PROD1 Drill 4.75" Directional Hole from 11,618' to 11,660' ART - 0, AST - 5.25 hrs. WOB = 2 - 4 K. 169 K PU, 136 K SO, 152 rot Tq4-5K, Tqoffbtm3-4 K 155 GPM @ 1920 psi. 5/30/2001 00:00 - 22:30 22.50 DRILL P PROD1 Drill 4.75" Directional Hole from 11660' - 11965', TD for well. ART - 9.75, AST - 6.25. WOB = 2 - 4 K. 169KPU, 137KSO, 153KROT Torque 4 - 5 K. 155 gpm @ 2130 psi 22:30 - 00:00 1.50 DRILL P PROD1 Circ high vis sweep @ 65 spm, 1900 psi. 5/31/2001 00:00 - 01:00 1.00 DRILL P PROD1 Circulate Hi Vis Sweep to surface @ 65 spm -1900 psi. Rot. & Reciprocate. PU - 169K, SO - 137K ROT = 153K. Fluid Loss rate approx. 3 bph. 01:00 - 04:00 3.00 DRILL P PROD1 POH past 5.5" shoe to 10,066'. Minimum Drag - 5 to 10 K. Pull slowly to avoid swabbing. 04:00 - 04:30 0.50 DRILL P PROD1 Service top drive & crown. Monitor well - losses same. 04:30 - 06:00 1.50 DRILL P PROD1 RIH slowly ( 30 - 40 ft per min.) to minimize surge and losses to 11,965. Hole slick - No Fill. 06:00 - 09:00 3.00 DRILL P PROD1 Circulate Hi Vis Sweep. Hole Clean. Spot Liner running pill. 09:00 - 13:30 4.50 DRILL P PROD1 POH wet and slow to place PBL sub @ 5.5" Liner top @ 7110'. 13:30 - 16:00 2.50 DRILL ~ PROD1 I Drop vinal ball to open PBL - Did not open. Drop steel ball & circ.down to PBL, then drop 2nd. Vinal ball- PBL opened. Pump sweep around @ 6 bpm.. Shut dn. pumps. Monitor well. - Minimal losses. Pump Pill. 16:00 - 21:30 5.50 DRILL ~ PROD1 POH wi 4" DP. R/U 2 7~8" Equip. Cont. POH laying down 84 Jts 2 7/8" DP. Stand back 24 Stands. 21:30 - 00:00 2.50 DRILL ~ PROD1 LID BHA. Down Load MWD/LWD. 6/1/2001 00:00 - 00:30 0.50 DRILL ~ PROD1 LID MWD Tools. 00:30 - 01:00 0.50 CLEAN ~ COMP Clear Floor. Monitor well. 01:00 - 02:00 1.00 CLEAN ~ COMP PJSM. M/U Circ. Sub For 7" Liner Top Cleanout Run. 02:00 - 03:30 1.50 CLEAN ~ COMP RIH to 1812' w/Circ, sub. 03:30 - 10:30 7.00 CLEAN ~ COMP Stage up Pumps & Rotary. Reciprocate through 7" Liner top @ 1784'. Erratic Pump pressure and torque. Pump Hi Vis sweep. Excessive amounts of sand and carbonate over shaker. Wash 9 5/8" casing up to 1160', pumping Hi Vis sweeps every stand. Casing clean @ 1160'. Run back in to Liner top and circulate sweep. Liner top and casing clean. 10:30 - 12:00 1.50 CLEAN ~ COMP POH w/Circ. Assy. LID. 12:00 - 13:30 1.50 CASE ~ COMP Clear floor & R/U all equip, to Run 3.5" Liner. PJSM with all Hands. Printed: 6/11/2001 2:50:40 PM BP AMOCO Page 8 of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/1/2001 13:30 - 17:00 3.50 CASE P COMP P/U & Run 3.5" Prod Liner. Fill and check float Jts. - OK. Cont. M/U & RIH w/Turb, or Cent. every Jr. 17:00 - 19:00 2.00 CASE N RREP COMP Oil leak on Tongs. Change out to backups. Backup tongs not Dumping properly. CIO dump valve, computor. 19:00 - 22:30 3.50 CASE P COMP Continue Runnig 3.5" Prod. Liner, filling every 10 Jts. Total 63 Jts. Run. 22:30 - 23:00 0.50= CASE P COMP M/U Hanger / Packer Assy. per Baker hand + 1 Jt. 2 7~8" HWDP. 23:00 - 00:00 1.00 CASE P COMP Circulate Liner Volume. RID Liner running equip. 6/2/2001 00:00 - 06:00 6.00 CASE P COMP PJSM. RU 2 7/8" HWDP handling tools. CIH with 3 1/2" liner on 19 jts of 2 7/8" HWDP from pipe shed and 2-7~8" HWDP from derrick. Total 24 stds 2 7/8" HWDP. Fill every 10 stds. 06:00 - 06:30 0.50~ CASE P COMP Circ liner volume. 3 BPM, 450 psi. RD 2 7/8" handling tools and RU 4" DP handling tools. PJSM. 06:30 - 12:00 5.50' CASE P COMP RIH with 3 1/2" liner on 4" DP. Fill / 10 stds. MU cmt head @ 5 1/2" liner shoe. PU 150 K, SO 130 K. 12:00 - 13:30 1.501 CASE P COMP Circ bottoms up @ 5 1/2" liner shoe. 3 BPM, 940 psi. 13:30- 15:00 1.50 CASE P COMP RIH 3 1/2" liner to 11945'. 15:00 - 17:30 2.50 CEMT P COMP RU cmt head. Fill pipe and break circ. Wash to bottom @ 11965'. RU Dowell. Pump 3 BPM, 1340 psi. Circ and condition mud for cmt job while reciprocating liner. PU 182 K, SO 132 K. 17:30 - 19:00 1.50 CEMT P COMP Mix and pump liner cmt job. Pmp 10 BBLS CW-100 pre-flush, test lines to 4500 psi, pmp 10 BBLS CW-100 pre-flush. Pmp 30 BBLS 9.5 ppg MudPUSH XL spacer. Pmp 31 BBLS (132 sxs) Class "G" cmt. Drop DP dart. Displace cmt with 50 BBLS liner perf pill and 49 BBLS mud. Bump plug to 3000 psi. Bleed pressure. Check floats. 3 1/2" liner shoe @ 11963' 19:00 - 19:30 0.50 DHEQP P COMP Pressure up to 3000 psi to set liner hanger. Release from hanger. Pmp 30 BBLS mud. Set string weight down to set liner top pkr. Top of liner packer @ 9930'. 19:30 - 22:30 3.00 CEMT P COMP Circ bottoms up. 10.5 BPM, 2400 psi. 17 BBLS contaminated cmt in returns. Displace well with sea water @ 6 BPM, 1850 psi. LD cmt head. 22:30 - 00:00 1.50 CEMT P COMP POOH stand back 18 stds 4" DP. Cont POOH LD 4" DP. 6/3/2001 00:00 - 01:00 1.00 CASE P COMP Continue LD 4" DP. 01:00 - 02:30 1.50 CASE P COMP Service Top Drive. Cut & Slip Drill line. Ck brakes. 02:30 - 03:30 1.00 CASE P COMP Circ at 5 1/2" liner top (7110'). 175 SPM, 3200 psi. PU 120 K, SO 110 K. Sand in returns. 03:30 - 08:30 5.00 CASE P COMP Continue LD 4" DP. 08:30 - 09:00 0.50 CASE P COMP RD 4" DP handling tools. RU 2 7/8" handling tools. 09:00 - 12:00 3.00 CASE P COMP LD 2 7/8" DP. 12:00 - 13:00 1.00 CASE 3 COMP PJSM with new tour. Remove ice from derrick and lines. 13:00 - 14:00 1.00 CASE 3 COMP Cont LD 2 7/8" tubing. 14:00 - 14:30 0.50 CASE 3 COMP Change out handling tools. RIH with 4" DP from derrick to 7" liner top at 1784'. !14:30 - 16:00 1.50 CASE 3 COMP Circulate at 12 BPM, 950 psi. Substantial sand and polymer in returns. Pmp high vis sea water sweep to clean 9 5~8" csg from 7" liner top. 16:00 - 17:30 1.50 CASE 3 COMP LD 4" DP. 17:30 - 18:00 0.50 RUNCOI~ COMP Pull Wear bushing. 18:00 - 19:00 1.00 RUNCOI~ COMP Test 3 1/2' liner top to 3500 psi/30 minutes aganist blinds rams. Sea water (8.4 ppg) in hole. Printed: 6/1112001 2:50:,40 PM BP AMOCO Page 9 of 9 Operations Summary Report Legal Well Name: B-05 Common Well Name: B-05B Spud Date: 5/10/2001 Event Name: REENTER+COMPLETE Start: 5/8/2001 End: 6/5/2001 Contractor Name: NABORS Rig Release: 6/5/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/3/2001 19:00 - 23:30 4.50 RUNCOr~ COMP PJSM. PU completion BHA as per program and RIH w/88 jts 3 1/2", 9.2#, L-80, NSTC tubing. 23:30 - 00:00 0.50 RUNCOI~ :COMP RU to run 4 1/2" tubing. 6/4/2001 00:00 - 09:00 9.00 RUNCOr~ I COMP RIH with 4 1/2" tubing as per program (Tq - 4000). Tag liner top pkr @ 9932' with stop. PU out of pkr. Circ @ 2 BPM, 136 psi. Tag top again. Pmp pressure up to 400 psi. Set 5 K dwn. Confirm 9932'. Calculate space out. 09:00 - 10:30 1.50 RUNCOI~ COMP Space out with 4.5" pup jts (1 - 2.70', 1 - 9.77', 1 - 19.86'). MU tbg hanger. PU landing jt and land hanger in tbg head. PU tbg hanger for circulation. Total of 170 its 4.5", 12.6# & 88 Jts 3.5" 9.2#, L-80, NSCT tbg in well. 10:30 - 13:30 3.00 RUNCOI~ COMP Reverse circ corrosion inhibited Sea Water. 3 BPM, 415 psi. 13:30 - 14:30 1.00 RUNCOI~' COMP Land tbg hanger. Run in lock down screws. Drop ball & rod (1.3125" ball with 1.50" fishing neck). Back out landing it. 14:30 - 16:30 2.00 RUNCOI~' COMP Pressure up to 4500 psi on tbg to set pkr. Bleed to 3500 psi & hold for 30 rain. Bleed dwn tbg to 1500 psi, pressure up annulas to 3500 psi / 30 min. Bleed tbg pressure to shear RP. 16:30 - 17:30 1.00 RUNCOI~' COMP Install TWC. Test from bottom to 1000 psi. 17:30 - 23:00 5.50 RUNCOI~ COMP ND bell nipple. Pull all rams from stack. Clean / inspect stack and rams. ND BOPE, brk out single gate, mud-X, Dbl gate, and Hydril for inspection. 23:00 - 00:00 1.00 RUNCOI~ COMP Move Adapter Flange and Tree into cellar. NU Adapter flange. 6/5/2001 00:00 - 02:00 2.00 WHSUR P COMP N/U Adaptor Flange and Tree. Test both to 5000 psi. 02:00 - 03:00 1.00 WHSUR P COMP R/U DSM. Pull TWC. R/D DSM. 03:00 - 07:30 4.50 CHEM P COMP R/U Hot Oiler. Test Lines to 4000 psi. Reverse circulate 135 bbls diesel. Shut in and let U-tube. 07:30 - 09:00 1.50 WHSUR P COMP Set BP¥. Test to 2500 psi. Secure Well. RIG RELEASED AT 09:00 HRS. Printed: 6/11/2001 2:50:,40 PM Well: B-05B Rig Accept: 05/08/01 Field: Prudhoe Bay Unit Rig Spud: 05/12/01 APl: 50-029-20276-02 Rig Release: 06/05/01 Permit: 201-068 Drilling Rig: 9ES POST - RIG WORK 06/28/01 - 07/01/01 Memory GR/CCL/CNL and IPERFS (Post-S/T, In progress) / Drill post work MIRU CTU #3, pump 7/8" ball thru coil, perform weekly BOP test. Make up Weather'ford BHA, make up memory tool: CCL/GR/CNL RIH with TS. Pump 5 Bbl METH into IA. Log CNL 9800' - TD at 30 FPM, Log TD - 9800 at 30 FPM. Log GR/CCL 9800' to 6800' to tie into BHC-Sonic. Set Flag at 11697'. POH. Under balance using AL Gas. PU 2" x 20 PERF Gun. Make up Weatherford fishing BHA. Pull test, PT, Check Injectivity on Well. None. Open to Flow line, RIH with CT. Tie in to Flag set counter to end of Fishing String. Tag Fish, move to firing position, attempt to fire gun, retag fish, POH to CK TS. Left gun and disconnect in hole. Fish PERF gun. Gun Fired - Shot interval 11805' - 11825', Shot interval 11785' - 11805' and Shot interval 11750' - 11770'. On surface CK TS. Shots fired. Freeze protect well to 2000' with 30 Bbls METH/WTR. DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA B Pad, Slot B-05 B-O5B Job No. AKZZ10158, Surveyed: 30 May, 2001 SURVEY REPORT June, 2001 Your Ref: AP1-500292027601 Surface Coordinates: 5949795.00 N, 664036.00 E (70° 16' 09.0501" N, Kelly Bushing: 71.50ft above Mean Sea Level 148°40'24.2209"VV) m m ~'R i L L I'N I~ E;E'RVICES A Halliburton Company Survey Reft svy10840 Sperry-Sun Drilling Services Survey Report for B. O5B Your Reft API-500292027601 Job No. AKZZIOf58, Surveyed: 30 May, 2001 North Slope Alaska Measured Depth (ft) Sub-Sea Depth (ft) Vertical Depth (ft) 7202.76 51.580 78.840 5895.52 5967.02 7274.00 51.540 78.900 5939.81 6011.31 7287.00 51.760 76.930 5947.88 6019.38 7318.89 51.380 75.400 5967.70 6039.20 7350.14 48.990 73.700 5987.71 6059.21 7378.61 46.440 72070 6006.86 6078.36 7411.38 43.890 70.040 6029.97 6101.47 7441,49 41.140 68.000 6052.16 6123.66 7469.19 38.770 65.950 6073.39 6144.89 7503.53 35.650 63.150 6100.74 6172.24 7534.42 33.460 58.590 6126.19 6197.69 7566.51 31.130 53.470 6153.31 6224.81 7596.54 29,890 48.670 6179.19 6250.69 7627.66 29.400 42.870 6206.24 6277.74 7660.49 28,790 36.800 6234.94 6306.44 7692.53 28.450 29.940 6263.07 6334.57 7724.17 28.900 23.510 6290.83 6362.33 7751.62 29,150 18.010 6314.84 6386.34 7786.62 30.220 10.260 6345.26 6416.76 7817.36 30.620 5.590 6371.77 6443.27 7845,74 30.940 7939.41 31,660 8033.12 30.260 8126.02 29040 8219.99 28.370 6396.15 6476.19 6556.56 6637.29 6719.71 4.080 3.6OO 7.980 8.180 9.210 6467.65 6547.69 6628.06 6708.79 6791.21 8311.34 27.020 11.310 6800.60 6872.10 8406.98 27010 9,450 6885.80 6957.30 8499.16 26.620 8.140 6968.07 7039.57 8590.97 26.650 8.200 7050.14 7121.64 8685.00 26.580 8.680 7134.21 7205.71 Local Coordinates Global Coordinates Northings Eastings - Northings Eastings (ft) (ft) (ft) (ft) 658.70 N 2780.42 E 5950514.14 N 666801.41 E 669.47 N 2835.17 E 5950526.10 N 666855.91 E 671.61N 2845.14 E 5950528.45 N 666865.83 E 677.58 N 2869.40 E 5950534.95 N- 666889.95 E 683.97 N 2892.53 E 5950541.84 N 666912.94 E 690.16 N 2912.66 E 5950548.47 N 666932.93 E 697.69 N 2934.64E 5950556.48 N 666954.74 E 704.97 N 2953.64E 5950564.17 N 666973.57 E 711.92 N 2970.01 E 5950571.48 N 666989.79 E 720.82 N 2988.76 E 5950580.79 N 667008.34E 729.33 N 3004.07 E 5950589.62 N 667023.46 E 738.88 N 3018.29 E 5950599.48 N 667037.47 E 748.44 N 3030.14 E 5950609.30 N 667049.11E 759.17 N 3041.17 E 5950620.26 N 667059.90 E 771.40 N 3051.39 E 5950632.72 N 667069.85 E 784.20 N 3059.82 E 5950645.70 N 667078.00 E 797.74 N 3066.63 E 5950659.39 N 667084.52 E 810.19 N 3071.35 E 5950671.93 N 667088.96 E 826.97 N 3075.55 E 5950688.80 N 667092.80 E 842.37 N 3077.69 E 5950704.25 N 667094.60 E 856.84 N 3078.92 E 5950718.74 N 667095.51 E 905.40 N 3082.17 E 5950767.35 N 667097.71 E 953.33 N 3087.00 E 5950815.38 N 667101.49 E 998.83 N 3093.45 E 5950861.01N 667106.95 E 1043.45 N 3100.27 E 5950905.76 N 667112.80 E 1085.22 N 3107.82 E 5950947.69 N 667119.43 E 1127.95 N 3115.64E 5950990.58 N 667126.32 E 1169.04 N 3122.00 E 5951031.80 N 667131.79 E 1209.78 N 3127.85 E 5951072.66 N 667136.74 E 1251.45 N 3134.03 E 5951114.45 N 667142.02 E Dogleg Rate (°/100ft) 0.086 12.004 3.943 8.715 9.907 8.935 10.216 9.786 10.335 10.967 11,192 9.102 9,349 9.177 10.306 9.851 9.761 11.376 7.800 2.947 0.813 2,830 1.318 0,886 1.823 0.883 O.768 0.044 0,241 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 1016.92 1034.76 1038.18 1047.28 1056.64 1065.41 1075.76 1085.46 1094.49 1105.77 1116.21 1127.54 1138.57 1150.64 1164.11 1177.90 1192.22 1205.17 1222.36 1237.91 1252.42 1300.98 1349.14 1395.09 1440.21 1482.61 1526.00 1567.57 1608.72 1650,84 Tie on point AK-6 BP IFR-AK -- Window point 14 June, 200'1 - 13:12 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-O5B Your Reft API-500292027601 Job No. AKZZfOf58, Surveyed: 30 May, 200f North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8778.00 25,820 7.420 7217.65 7289.15 8963.75 27.510 3.110 7383.66 7455.16 9058.93 25.840 3.180 7468.70 7540.20 9151.67 27.280 359.530 7551.66 7623.16 9246.75 28.060 358.700 7635.86 7707.36 9340.22 27.710 358.530 7718.48 7789.98 9433.49 27.140 359.160 7801.27 7872.77 9526.33 26.940 359.920 7883.96 7955.46 9619.51 26.110 359.710 7967.33 8038.83 9712.58 25.610 358.330 8051.08 8122.58 9805.43 26.860 358.070 8134.37 8205.87 9899.03 26.020 356.070 8218.18 8289.68 9995.29 25.400 355.140 8304.91 8376.41 10026.78 24.840 355.940 8333.42 8404.92 10155.03 27.510 353.040 8448.51 8520.01 10186.36 29.730 353.540 8476.01 8547.51 10217.94 30.640 353.270 8503.31 8574.81 10249.26 33.500 353.250 8529.85 8601.35 10280.21 36.460 352.390 8555.20 8626.70 10310.76 39.180 350.670 8579.33 8650.83 10342.31 40.120 347.290 8603.63 8675.13 10373.13 40.450 342.960 8627.14 8698.64 10411.66 40.890 337.330 8656.38 8727.88 10444.92 42.200 330.820 8681.28 8752.78 10478.46 42.440 322.690 8706.10 8777.60 10502.72 42.590 318.400 8723.99 8795.49 10537.60 45.140 312.220 8749.14 8820.64 10568.25 46.940 307.490 8770.43 8841.93 10596.62 48300 301.820 8789.56 8861.06 10628.07 49.170 298.240 8810.30 8881.80 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1292.10 N 3139.79 E 5951155.22 N 667146.89 E 1375.06 N 3147.34E 5951238.33 N 667152.63 E 1417.73 N 3149.69 E 5951281.03 N 667154.04 E 1459.16 N 3150.63 E 5951322.48 N 667154.09 E 1503.31 N 3149.95 E 5951366.60 N 667152.44 E 1547.01N 3148.89 E 5951410.27 N 667150.43 E 1589.96 N 3148.02 E 5951453.19 N 667148.63 E 1632.17 N 3147.68 E 5951495.38 N 667147.37 E 1673.78 N 3147.55 E 5951536.98 N 667146.33 E 1714.37 N 3146.86 E 5951577.54 N 667144.75 E 1755.39 N 3145.57 E 1797.01N 3143.45 E 1838.64 N 3140.25 E 1851.97 N 3139.21E 1908.25 N 3133.72 E 1923.16 N 3131.96 E 1938.93 N 3130.14 E 1955.44 N 3128.19 E 1973.04N 3125.97 E 1991.57 N 3123.20 E 2011.32 N 3119.35 E 2030.57 N 3114.23 E 2054.16 N 3105.70 E 2073.97 N 3096.06 E 2092.82 N 3083.70 E 2105.47 N 3073.28 E 2122.62 N 3056.28 E 2136.74 N 3039.35 E 2148.64 N 3022.11 E 2160.46 N 3001.65 E 5951618.52 N 667142.57 E 5951660.08 N 667139.54 E 5951701.64 N 667135.44 E 5951714.94 N 667134.11E 5951771.09 N 667127.38 E 5951785.95 N 667125.31 E 5951801.68 N 667123.14 E 5951818.15 N 667120.83 E 5951835.70 N 667118.23 E 5951854.16 N 667115.06 E 5951873.82 N 667110.77 E 5951892.95 N 667105.24 E 5951916.36 N 667096.20 E 5951935.95 N 667086.12 E 5951954.53 N 667073.36 E 5951966.95 N 667062.67 E 5951983.72 N 667045.30 E 5951997.47 N 667028.06E 5952008.99 N 667010.57 E 5952020.36 N 666989.86 E Dogleg Rate (°/100ft) 1.013 1.382 1.755 2.346 0.915 0.384 0.686 0.430 0.896 0.841 1.352 1.308 0.768 2.080 2.308 7.127 2.913 9.132 9.695 9.549 7.456 9.146 9.589 13.560 16.328 11.965 14.283 12.563 15.518 8.992 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 1691.90 1775.14 1817.74 1858.94 1902.62 1945.81 1988.28 2O30.07 2071.31 2111.46 2151.96 2192.94 2233.8O 2246.88 2301.96 2316.50 2331.90 2348.02 2365.17 2383.18 2402.26 2420.67 2442.95 2461.32 2478.39 2489.57 2504.34 2516.13 2525.67 2534.71 14 June, 2001.13:12 Page 3 of 6 Dr#lQ,est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-O5B Your Ref: API-500292027601 Job No. AKZZfOf58, Surveyed: 30 May, 200'/ North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 10658.63 49.930 293.290 8830.14 8901.64 10689.46 52.750 289.000 8849.40 8920.90 10719.76 56.220 287.810 8867.00 8938.50 10751.09 59.910 285.260 8883.57 8955.07 10781.90 63.470 282.250 8898.18 8969.68 10813.44 67.070 281.790 8911.37 8982.87 10844.69 71.430 280.300 8922.44 8993.94 10876.24 75.840 278.480 8931.33 9002.83 10907.72 80.250 277.000 8937.85 9009.35 10938.42 80.560 277.370 8942.97 9014.47 10971.06 85.290 277.130 8946.99 9018.49 11003.09 85.690 276.210 8949.51 9021.01 11033.32 85.390 274.430 8951.86 9023.36 11062.82 85.260 274.250 8954.26 9025.76 11094.92 84.640 274.120 8957.09 9028.59 11126.29 84.150 274.190 8960.15 9031.65 11156.04 86.980 273.550 8962.45 9033.95 11187.91 87.290 273.960 8964.04 9035.54 11218.86 87.050 274.870 8965.57 9037.07 11249.88 86.620 274.760 8967.28 9038.78 11280.42 86.730 274.390 8969.06 9040.56 11312.63 86.730 274.090 8970.89 9042.39 11:344.88 86.280 274.180 8972.86 9044.36 11374.67 89.200 274.000 8974.03 9045.53 11405.85 90.000 274.540 8974.25 9045.75 11436.97 90.090 274.700 8974.23 9045.73 11468.35 92.150 274.380 8973.61 9045.11 11499.25 92.400 274.680 8972.39 9043.89 11530.67 92.090 275.840 8971.16 9042.66 11561.60 93.630 275.130 8969.61 9041.11 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2170.56 N 2980.72 E 5952030.00 N 666968.71 E 2179.22 N 2958.27 E 5952038.17 N 666946.08 E 2187.00 N 2934.87 E 5952045.44 N 666922.51 E 2194.55 N 2909.39 E 5952052.44 N 666896.87 E 2200.99 N 2883.05 E 5952058.30 N 666870.39 E 2206.95 N 2855.03 E 5952063.65 N 666842.26 E 2212.54 N 2826.36 E 5952068.61 N 666813.47 E 2217.48 N 2796.50 E 5952072.89 N 666783.51 E 2221.62 N 2765.99 E 5952076.37 N 666752.92 E 2225.41 N 2735.96 E 5952079.50 N 666722.81 E 2229.49 N 2703.83 E 5952082.89 N 666690.60 E 2233.20 N 2672.12 E 5952085.90 N 666658.82 E 2235.99 N 2642.11 E 5952088.04 N 666628.75 E 2238.22 N 2612.79 E 5952089.63 N 666599.40 E 2240.55 N 2580.90 E 5952091.27 N 666567.46 E 2242.81 N 2549.77 E 5952092.85 N 666536.28 E 2244.82 N 2520.18 E 5952094.21 N 666506.66 E 2246.90 N 2488.41 E 5952095.60 N 666474.86 E 2249.28 N 2457.59 E 5952097.30 N 666443.99 E 2251.88 N 2426.73 E 5952099.23 N 666413.08 E 2254.31 N 2396.34 E 5952101.00 N 666382.64E 2256.69 N 2364.27 E 5952102.68 N 666350.53 E 2259.01 N 2332.16 E 5952104.30 N 666318.38 E 2261.13 N 2302,48 E 5952105.77 N 666288.65 E 2263.46 N 2271.38 E 5952107.42 N 666257.52 E 2265.96 N 2240.36 E 5952109.25 N 666226.45 E 2268.44 N 2209.09 E 5952111.05 N 666195.13 E 2270.88 N 2178.31 E 5952112.82 N 666164.30 E 2273.76 N 2147.05 E 5952115.01 N 666132.99 E 2276.71N 2116.30 E 5952117.29 N 666102.18 E Dogleg Rate (°/100ft) 12.572 14.200 11.890 13.652 14.403 11.491 14.647 15.033 14.744 1.559 14.510 3.124 5.954 0.751 1.973 1.578 9.751 1.612 3.037 1.431 1.262 0.930 1.423 9.821 3.096 0.590 6.643 1.263 3.819 5.481 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 2541.98 2547.63 2552.28 2556.44 2559.37 2561.61 2563.41 2564.39 2564.50 2564.33 2564.17 2563.70 2562.54 2560.91 2559.05 2557.22 2555.33 2553.24 2551.57 2550.10 2548.54 2546.7O 2544.80 2543.02 2541.25 2539.67 2538.04 2536.43 2535.19 2534.10 14 June, 2001.13:12 Page 4 of 6 Dr#/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-OSB Your Reft API-50029202760'i Job No. AKZZlO'I58, Surveyed: 30 May, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11585.00 92.220 274.620 8968.42 9039.92 2278.70 N 2093.01 E 5952118.77 N 666078.86E 11625.25 91.850 271.290 8966.99 9038.49 2280.77 N 2052,85 E 5952119.97 N 666038.66 E 11657.02 94.000 271.100 8965.37 9036.87 2281.44N 2021.13 E 5952119.94 N 666006.93 E 11686.45 95.580 272.050 8962.91 · 9034.41 2282.24 N 1991.81 E 5952120.11 N 665977.60 E 11718.80 97.230 274.460 8959.30 9030.80 2284.07 N 1959.72 E 5952121.23 N 665945.48 E 11749.38 96.510 274.380 8955.64 9027.14 2286.40 N 1929.45 E 5952122.91 N 665915.17 E 11783.48 96.040 273.320 8951.92 9023.42 2288.68 N 1895.63 E 5952124.45 N 665881.31 E 11812.55 95.730 275.110 8948.94 9020.44 2290.81 N 1866.80 E 5952125.95 N 665852.43 E 11844.48 94.930 272.170 8945.97 9017.47 2292.82 N 1835.07 E 5952127.27 N 665820.67 E 11875.42 94.600 273.450 8943.40 9014.90 2294.34 N 1804.28 E 5952128.11 N 665789.85 E 11905.90 94.470 272.960 8940.99 9012.49 2296.03 N 1773.94 E 5952129.15 N 665759.48 E 11936.66 94.070 272.290 8938.70 9010.20 2297.44 N 1743.30 E 5952129.88 N 665728.82 E 11965.00 94.070 272.290 8936.69 9008.19 2298.57 N 1715.05 E 5952130.40 N 665700.55 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vedical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.673° (05-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 7.520" (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11965.00ff., The Bottom Hole Displacement is 2867.89ft., in the Direction of 36.728° (True). Dogleg Rate (°/100ft) 6.407 8.319 6.794 6.259 8.990 2.369 3.383 6.217 9.504 4.258 1.658 2.532 0.000 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 2533.02 2529.82 2526.32 2523.29 2520.89 2519.25 2517.08 2515.42 2513.26 2510.73 2508.45 2505.83 2503.25 Projected Survey 14 June, 2001 - 13:12 Page 5 of 6 DrillQ~xest 2. 00. 08.005 Sperry-Sun Drilling Services Survey Report for B-O5B Your Reft API-500292027601 Job No. AKZZfOI58, Surveyed: 30 May, 200~ North Slope Alaska Alaska Drilling & Wells PBU WOA B Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7202.76 5967.02 658.70 N 2780.42 E 7274.00 6011.31 669.47 N 2835.17 E 11965.00 9008.19 2298.57 N 1715.05 E Comment Tie on point Window point Projected Survey Survey tool program for B.O5B From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 7202.76 5967.02 7202.76 5967.02 11965.00 9008.19 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (B-05) AK-6 BP_IFR-AK (B-O5B) 14 June, 2001 - 13:12 Page 6 of 6 DrillQ~est 2.00.08.005 North Slope Alaska Alaska Drilling & Wells PBU_WOA B Pad, Slot B-05 B-O5B MWD Job No. AKMMIOf51, Surveyed: 30 May, 2001 S UR VEY REPORT June, 200~ Your Ref: API-500292027601 Surface Coordinates: 5949795.00 N, 664036.00 E (70° 16' 09.0501" N, Kelly Bushing: 71.50ft above Mean Sea Level 148° 40' 24.2209" W) DRILLING SERVICES Survey Ref: svy10841 A Halliburton Company Sperry-Sun Drilling Services Survey Report for B-OSB MWD Your Reft API-50029202760'1 Job No. AKMM'IOI5f, Surveyed: 30 May, 2001 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7202.76 51.580 78.840 5895.52 5967.02 7274.00 51.540 78.900 5939.81 6011.31 7287.00 51.760 76.930 5947.88 6019.38 7318.89 51.380 75.400 5967.70 6039.20 7350.14 48.990 59.870 5987.78 6059.28 7378.61 46.440 60.380 6006.94 6078.44 7411.38 43.890 60.160 6030.04 6101.54 7441.49 41.140 55.600 6052.24 6123.74 7469.19 38.770 65.010 6073.49 6144.99 7503.53 35.650 63.750 6100.83 6172.33 7534.42 33.460 58.450 6126.28 6197.78 7566.51 31.130 53.430 6153.41 6224.91 7596.54 29.890 48.150 6179.28 6250.78 7627.66 29.400 42.640 6206.34 6277.84 7660.49 28.790 36.640 6235.03 6306.53 7692.53 28.450 30.450 6263.16 6334.66 7724.17 28.900 23.660 6290.93 6362.43 7751.62 29.150 18.080 6314.93 6386.43 7786.62 30.220 10.170 6345.35 6416.85 7817.36 30.620 5.640 6371.86 6443.36 7845.74 30.940 7939.41 31.660 8033.12 30.260 8126.02 29.040 8219.99 28.370 6396.25 6476.28 6556.65 6637.39 6719.81 3.87O 3.230 7.740 7.940 9.320 6467.75 6547.78 6628.15 6708.89 6791.31 8311.34 27.020 11.710 6800.69 6872.19 8406.98 27.010 9.970 6885.90 6957.40 8499.16 26.620 8.080 6968.17 7039.67 8590.97 26.650 7.410 7050.23 7121.73 8685.00 26.580 8.040 7134.30 7205.80 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 658.70 N 2780.42 E 5950514.14 N 666801.41 E 669.47 N 2835.17 E 5950526.10 N 666855.91 E 671.61N 2845.14 E 5950528.45 N 666865.83 E 677.58 N 2869.40 E 5950534.95 N 666889.95 E 686.61 N 2891.49 E 5950544.46 N 666911.84 E 697.10 N 2909.75 E 5950555.35 N 666929.87 E 708.62 N 2929.93 E 5950567.31 N 666949.79 E 719.42 N 2947.16 E 5950578.48 N 666966.79 E 728.24 N 2962.56 E 5950587.63 N 666981.99 E 737.21 N 2981.29 E 5950597.01 N 667000.51 E 745.65 N 2996.62 E 5950605.78 N 667015.66 E 755.22 N 3010.83 E 5950615.66 N 667029.65 E 764.84 N 3022.64 E 5950625.53 N 667041.25 E 775.64 N 3033.59 E 5950636.57 N 667051.97 E 787.91 N 3043.77 E 5950649.06 N 667061.87 E 800.69 N 3052.24 E 5950662.01 N 667070.07 E 814.19 N 3059.13 E 5950675.66 N 667076.66 E 826.62 N 3063.87 E 5950688.20 N 667081.13 E 843.40 N 3068.07 E 5950705.06 N 667084.96 E 858.81 N 3070.21 E 5950720.51 N 667086.76 E 873.28 N 3071.41 E 5950735.01 N 667087.65 E 921.85 N 3074.42 E 5950783.63 N 667089.60 E 969.81N 3078.99 E 5950831.68 N 667093.12 E 1015.34 N 3085.25 E 5950877.33 N 667098.39 E 1059.96 N 3092.02 E 5950922.09 N 667104.19 E 1101.70 N 3099.75 E 5950963.99 N 667111.00 E 1144.36 N 3107.92 E 5951006.82 N 667118.24 E 1185.42 N 3114.44 E 5951048.01 N 667123.87 E 1226.20 N 3119.99 E 5951088.91N 667128.53 E 1267.95 N 3125.65 E 5951130.76 N 667133.28 E Dogleg Rate (°ll00ft) 0.086 12.004 3.943 38.875 9.O54 7.796 13.713 23.413 9.352 12.035 11.066 9.832 8.895 9.076 9.311 10.390 9.902 11.594 7.573 3.385 0.847 2.891 1.318 1.003 1.914 0.826 1.017 0.329 0.309 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 1016.92 1034.76 1038.18 1047.28 1059.12 1071.91 1085.98 1098.93 1109.69 1121.04 1131.41 1142.76 1153.85 1165.98 1179.48 1193.25 1207.54 1220.49 1237.67 1253.23 1267.73 1316.28 1364.42 1410.38 1455.50 1497.89 1541.26 1582.82 1623.98 1666.10 Tie on point MWD Magnetic Window point 14 June, 200f - 13:06 Page 2 of 6 DrillQ,e.~! 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-O5B MWD Your Ref: API-500292027601 Job No. AKMMfOfSf, Surveyed: 30 May, 200'/ North Slope Alaska Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8778.00 25.820 7.190 7217.75 7289.25 8963.75 27.510 2.960 7383.75 7455.25 9058.93 25.840 3.530 7468.80 7540.30 9151.67 27.280 359.780 7551.75 7623.25 9246.75 28.060 358.930 7635.96 7707.46 9340.22 27.710 358.550 7718.58 7790.08 9433.49 27.140 359.020 7801.36 7872.86 9526.33 26.940 359.610 7884.06 7955.56 9619.51 26.110 359.300 7967.43 8038.93 9712.58 25.610 358.190 8051.18 8122.68 9805.43 26.860 358.090 8134.46 8205.96 9899.03 26.020 355.980 8218.27 8289.77 9995.29 25.400 355.460 8305.00 8376.50 10026.78 24.840 356.140 8333.51 8405.01 10155.03 27.510 353.480 8448.60 8520.10 10186.36 29.730 354.090 8476.11 8547.61 10217.94 30.640 353.430 8503.40 8574.90 10249.26 33.500 353.140 8529.94 8601.44 10280,21 36.460 352.090 8555.30 8626.80 10310.76 39.180 350.190 8579.43 8650.93 10342.31 40,090 347.120 8603.73 8675.23 10373.13 40.450 342.940 8627.25 8698.75 10411,66 40,890 337.590 8656.48 8727.98 10444.92 42.200 331.450 8681.38 8752.88 10478,46 42.440 323.430 8706.20 8777.70 10502.72 42.590 319.080 8724.09 8795.59 10537.60 45.140 313.240 8749.24 8820.74 10568.25 46.940 308.540 8770.52 8842.02 10596.62 48.300 302.340 8789.66 8861.16 10628.07 49.170 296.330 8810.41 8881.91 Local Coordinates Global Coordinates Northings Eastings Northings Eastings · (ft) (ft) (ft) (ft) 1308.64 N 3131.10 E 5951171.57 N 667137.83 E 1391.63 N 3138.38 E 5951254.70 N 667143.30 E 1434.29 N 3140.79 E 5951297.40 N 667144.79 E 1475.72 N 3141.95 E 5951338.84N 667145.05 E 1519.87 N 3141.45 E 5951382.97 N 667143.58 E 1563.57 N 3140.49 E 5951426.64 N 667141.67 E 1606.52 N 3139.58 E 5951469.56 N 667139.82 E 1648.73 N 3139.07 E 5951511.74 N 667138.40 E 1690.34 N 3138.68 E 5951553.34 N 667137.10 E 1730.92 N 3137.79 E 5951593.89 N 667135.33 E 1771.94 N 3136.46 E 5951634.87 N 667133.10 E 1813.56 N 3134.32 E 5951676.43 N 667130.05 E 1855.20 N 3131.20 E 5951718.00 N 667126.03 E 1868.53 N 3130.22 E 5951731.30 N 667124.76 E 1924.85 N 3125.04 E 5951787.49 N 667118.35 E 1939.77 N 3123.42 E 5951802.37 N 667116.41 E 1955.55 N 3121.69 E 5951818.12 N 667114.34E 1972.06 N 3119.75 E 5951834.58 N 667112.03 E 1989.66 N 3117.46 E 5951852.12 N 667109.36 E 2008.16 N 3114.57 E 5951870.56 N 667106.06 E 2027.89 N 3110.61 E 5951890.19 N 667101.67 E 2047.12 N 3105.46 E 5951909.31 N 667096.11 E 2070.74 N 3096.98 E 5951932.74 N 667087.12 E 2090.62 N 3087.49 E 5951952.41 N 667077.19 E 2109.62 N 3075.35 E 5951971.14 N 667064.65 E 2122.40 N 3065.10 E 5951983.69 N 667054.12 E 2139.80 N 3048.35 E 5952000.72 N 667036.99 E 2154.22 N 3031.67 E 5952014.78 N 667020.01E 2166.35 N 3014.61E 5952026.53 N 667002.68 E 2177.91 N 2994.01 E 5952037.65 N 666981.84 E Dogleg Rate (°/t00ft) 0.911 1.368 1.775 2.383 0,919 0.420 O.654 0.360 0.903 0.748 1.347 1.346 0.685 2.001 2.274 7.147 3.067 9.145 9.759 9.685 6.844 8.843 9.119 12.857 16.108 12.131 13.708 12.500 16.835 14.625 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 1707.16 1790.39 1833.00 1874.22 1917.93 1961.13 2OO3.59 2045.36 2086.56 2126.68 2167.18 2208.15 2249.O3 2262.12 2317.27 2331.85 2347.27 2363.39 2380.53 2398.50 2417.54 2435.93 2458.24 2476.71 2493.95 2505.28 2520.34 2532.45 2542.25 2551.02 14 June, 2001. 13:06 Page 3 of 6 DrillQ,est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-OSB MWD Your Ref: API-50029202760f Job No. AKMMfOI5'I, Surveyed: 30 May, 2001 North Slope Alaska Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10658.63 49.930 293.810 8830.24 8901.74 10689.46 52.750 289.270 8849.50 8921.00 10719.76 56.220 287.520 8867.10 8938.60 10751.09 59.910 284.280 8883.68 8955.18 10781.90 63.470 283.390 8898.28 8969.78 10813.44 67.070 281.910 8911.48 8982.98 10844.69 71.430 279.330 8922.55 8994.05 10876.24 75.840 278.480 8931.44 9002.94 10907.72 80.250 273.740 8937.96 9009.46 10938.42 80.560 277.070 8943.08 9014.58 10971.06 85.290 277.350 8947.10 9018.60 11003.09 85.690 280.280 8949.61 9021.11 11033.32 85.390 277.630 8951.97 9023.47 11062.82 85.260 277.020 8954.37 9025.87 11094.92 84.640 277.740 8957.20 9028.70 11126.29 84.150 273.900 8960.26 9031.76 11156.04 86.980 272.770 8962.56 9034.06 11187.91 87.290 272.860 8964.15 9035.65 11218.86 87.050 274.390 8965.68 9037.18 11249.88 86.620 276.470 8967.40 9038.90 11280.42 86 730 275.090 8969.17 9040.67 11312.63 86.730 275.500 8971.00 9042.50 11344.88 86.280 277.930 8972.97 9044.47 11374.67 89.200 275.420 8974.15 9045.65 11405.85 90.000 275.000 8974.36 9045.86 11436.97 90.090 275.740 8974.34 9045.84 11468.35 92.150 275.050 8973.73 9045.23 11499.25 92.400 275.320 8972.50 9044.00 11530.67 92.090 277.580 8971.27 9042.77 11561.60 93.630 274.650 8969.72 9041.22 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2187.76 N 2972.95 E 5952047.03 N 666960.57 E 2196.58 N 2950.56 E 5952055.36 N 666937.99 E 2204.35 N 2927,16 E 5952062.62 N 666914.43 E 2211.62 N 2901.60 E 5952069.33 N 666888.71 E 2218.10 N 2875.26 E 5952075.24 N 666862.24 E 2224.37 N 2847.32 E 5952080.89 N 666834.17 E 2229.74 N 2818.60 E 5952085.64 N 666805.34E 2234.43 N 2788.70 E 5952089.67 N 666775.35 E 2237.69 N 2758.10 E 5952092.27 N 666744.68 E 2240.54 N 2727.97 E 5952094.46 N 666714.49 E 2244.61 N 2695.84 E 5952097.83 N 666682.28 E 2249.50 N 2664.29 E 5952102.03 N 666650.63 E 2254.19 N 2634.52 E 5952106.07 N 666620.77 E 2257.94 N 2605.36 E 5952109.18 N 666591.53 E 2262.05 N 2573.65 E 5952112.60 N 666559.74 E 2265.21N 2542.60 E 5952115.09 N 666528.63 E 2266.94 N 2512.99 E 5952116.17 N 666498.99 E 2268.50 N 2481.20 E 5952117.04 N 666467.17 E 2270.46 N 2450.35 E 5952118.32 N 666436.29 E 2273.39 N 2419.52 E 5952120.58 N 666405.40 E 2276.46 N 2389.18 E 5952122.98 N 666375.00 E 2279.42 N 2357.16 E 5952125.25 N 666342.93 E 2283.19 N 2325,20 E 5952128.32 N 666310.89 E 2286.65 N 2295.64 E 5952131.13 N 666281.26 E 2289.48 N 2264.59 E 5952133.29 N 666250.15 E 2292.39 N 2233.60 E 5952135.52 N 666219.11E 2295.34 N 2202.37 E 5952137.79 N 666187.82 E 2298.13 N 2171.62 E 5952139.91 N 666157.02 E 2301.66 N 2140.43 E 5952142.76 N 666125.76 E 2304.95 N 2109.71 E 5952145.38 N 666094.98 E Dogleg Rate (°/100ft) 6.75O 14.690 12.379 14.686 11.831 12.183 15.944 14.215 20.325 10.743 14.516 9.204 8.796 2.108 2.953 12.282 10.239 1.013 4.998 6.837 4.525 1.271 7.649 12.921 2.898 2.395 6.923 1.190 7.255 10.691 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 2558.02 2563.84 2568.48 2572.34 2575.32 2577.87 2579.44 2580.17 2579.41 2578.29 2578.11 2578.84 2579.59 2579.49 2579.41 2578.49 2576.32 2573.71 2571.61 257O.48 2569.56 2568.31 2567.85 2567.42 2566.16 2564.99 2563.83 2562.57 2561.98 2561.23 14 June, 2001 - 13:06 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-OSB MWD Your Ref: AP1-500292027601 Job No. AKMMfOfSf, Surveyed: 30 May, 200f North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11585.00 92.220 272.530 8968.53 9040.03 2306.41 N 2086.39 E 5952146.33 N 666071.63 E 11625.25 91.850 270.780 8967.10 9038.60 2307.57 N 2046.19 E 5952146.62 N 666031.41 E 11657.02 94.000 270.930 8965.48 9036.98 2308.05 N 2014.46 E 5952146.40 N 665999.69 E 11672.37 94.500 270.870 8964.34 9035.84 2308.29 N 1999.16 E 5952146.31 N 665984.38 E 11686.45 95.580 270.330 8963.10 9034.60 2308.43 N 1985.13 E 5952146.15 N 665970.35 E 11718.80 97.230 273.900 8959.49 9030.99 2309.62 N 1953.01 E 5952146.63 N 665938.22 E 11749.38 96.510 273.760 8955.84 9027.34 2311.65 N 1922.72 E 5952148.00 N 665907.89 E 11783.48 96.040 272.770 8952.11 9023.61 2313.58 N 1888.88 E 5952149.19 N 665874.01 E 11812.55 95.730 274.570 8949.13 9020.63 2315,43 N 1860.02 E 5952150.41 N 665845.12 E 11844.48 94.930 271.760 8946.16 9017.66 2317.18 N 1828.28 E 5952151.48 N 665813.35 E 11875.42 94.600 272.970 8943.59 9015.09 2318.45 N 1797.48 E 5952152.08 N 665782.52 E 11905.90 94.470 272.530 8941.18 9012.68 2319.91 N 1767.13 E 5952152.87 N 665752.15 E 11936.66 94.070 271.840 8938.89 9010.39 2321.08 N 1736.48 E 5952153.37 N 665721.48 E 11965.00 94.070 271.840 8936.88 9008.38 2321.99 N 1708.22 E 5952153.66 N 665693.21 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vedical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.673° (05-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vedical Section is from Well Reference and calculated along an Azimuth of 7.520° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11965.00ft., The Bottom Hole Displacement is 2882.65ft., in the Direction of 36.341° (True). Dogleg Rate (°ll00ff) 10.871 4.441 6.784 3.281 8.569 12.094 2.398 3.198 6.251 9.114 4.041 1.501 2.587 0.000 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 2559.62 2555.51 2551.83 2550.07 2548.38 2545.35 2543.39 2540.88 2538.94 2536.52 2533.75 2531.23 2528.37 2525.58 Projected survey 14 June, 2001 - 13:06 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling' Services Survey Report for B-O5B MWD Your Ref: API-500292027601 Job No. AKMMI0151, Surveyed: 30 May, 2001 North Slope Alaska Alaska Drilling & Wells PBU WOA B Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7202.76 5967.02 658.70 N 2780.42 E 7274.00 6011.31 669.47 N 2835.17 E 11965.00 9008.38 2321.99 N 1708.22 E Comment Tie on point Window point Projected survey Survey tool program for B-O5B MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 7202.76 5967.02 7202.76 5967.02 11965.00 9008.38 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (B-05) MWD Magnetic (B-05B MWD) 14 June, 2001 - 13:06 Page 6 of 6 Dr#lQ,est 2.00.08.005 ALASKA OIL AND GAS CONSERVATION COPI~HSSION TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Unit B-05B BP Exploration (Alaska) Inc. Permit No: 201-068 Sur Loc: 855' SNL, 1600' WEL, SEC. 31, TllN, R14E, UM Btrnhole Loc. 1452' NSL, 217' EWL, SEC. 29, TllN, R14E, UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with .20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice. may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this 4~ day of May, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA .~,."" ALASKA ,_ AND GAS CONSERVATION COMMI~,.,,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Reddll 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 70.52' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028310 ~4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 855' SNL, 1600' WEL, SEC. 31, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1360' NSL, 1276' EWL, SEC. 29, T11N, R14E, UM B-05B Number 2S100302630-277 At total depth 9. Approximate spud date 1452' NSL, 217' EWL, SEC. 29, T11N, R14E, UM 05/01/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028305, 3826' MDI 353' away from B-27A at 9129' MD 2560 11857' MD / 8988' TVD 16. TO be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 7200' MD Maximum Hole Angle 96 ° Maximum surface 2454 psig, At total depth (TVD) 8800' / 3334 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta.qe data) 7" 5-1/2" 17# L-80 STL 3038' 7050' 5950' 10088' 8380' 143 cu ft Class'G' 4-3/4" 3-1/2" 9.3# L-80 STL 1919' 9938' 8285' 11857' 8987' 143 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. RY--, C ~ I'VI¢-?''~ Present well condition summary Total depth: measured 11930 feet Plugs (measured) ,/ PR i 0 2001 true vertical 9079 feet Effective depth: measured 11911 feet Junk (measured) true vertical 9072 feet Alaska Oil & Gas Cons. Commission Anchorage Casing Length Size Cemented MD TVD Structural Conductor 114' 20" x 30" 300 sx cement 114' 14' Surface 2664' 13-3/8" 5200 cuft cement 2664' 2664' Intermediate 10165' 9-5/8" 1936 cuft cement 10165' 7972' Production Liner 1921' 7" 416 cuft Class 'G' 10009' - 11930' 7871' - 9079' Liner Tieback 8223' 7" 1294 cuft Class 'G' 1784' - 10007' 1784' - 7869' Perforation depth: measured Open: 11680'- 11702', 11810'- 11840' true vertical Open: 8993' - 8999', 9032' - 9043' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Schmitz, 564-5773 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true ~o the best of my knowledge _ Signed DanStone ~--- ~.~ Title Senior Drilling Engineer Date '-~ tl~/ ·..:.. :.i:.': '"':: .': ..'. ,.., :.:. '.. ',.:':' .:..i':...i. ;' ~'.: :' ..... . '". '" ':'...:' :. :. :"::..:': .:.::'i:".'c°m'miS'Si~n:.'USe:OnlY ' ' ::'' :i' :':i:. '. ,..:',, ..' .:'....!..::.:.: ~,! .:...::,,..,::...:...'.:~:.'".'i !. :. :,: ".:,. :.:.~..'.. '.:..' .":.'~;·:·: i· ,~(~ I.-(~2 _~ 50-029-20276-02 3 .Z?/.O ! ' I for other requirements Conditions of Approval: Samples Required [] Yes ;l~No Mud Log Required [] Yes '~ No Hydrogen Sulfide Measures '~Yes [] No Directional Survey Required ~J~Yes [] No Required Working Pressure forE~OPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~.3.5K psi Other: ORIGINAL SIGNEE) BY by order of Approved By D Taylor Seamounl Commissioner the commission Date Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate IWell Name: I B-05B Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location: Y: 5949795 X: 664036 855' SNL & 1600 WEL, Sec 31, T11N, R14E Target Location: Y: 5952072.84 X: 666855.38 TVDss-8890 24P in ZONE 2 1360' NSL & 1276' EWL, Sec. 29, T11 N, R14E MD 10780 Bottom Hole Location: Y: 5952142 X: 665795 TVDss-8987 1452' NSL, 217' EWL, Sec. 29, T11N, R14E MD 11857 Well Design: 1. Sidetrack out of 7", 26# @ +/-7200' MD. (Mill 7" & 9 5/8" window). 2. Drill 2889 ft of 4 sA,, pilot x 7" (Ream While Drilling) Intermediate hole directionally to TSGR @ -10,089' MD using 4" DP. 3. Set & cement 5 1/2", 17#, STL FJ drilling liner. 4. Drill 1768 ft of 4 3/4" production hole, 2 7/8" DP, horizontal into Zone 2B @TD. Set & cement 3 ~" solid, STL FJ production liner. 5. Drill Pipe Conveyed: Log SCMT(CBL) & perforate. 6. Install 4 Y2"x 3 ~ NSCT, tubing, GLM's, & completion packer. Objective: Development producer targeting sands in Zone 2B Ivishak. Mud Program: 7" Intermediate Hole (7200-10089' i: LSND Mud Interval Density Viscosity YP PV Gel-10 Fluid (ppg) (seconds) sec Loss Milling 9.8 45-55 25-30 10-15 19/55 15 Interval TD 10.8 45-55 20-27 10-18 12/25 <10 4 ~/4" Production hole 10089-11857): Low Densit~ Quickdriln Interval Density Viscosity YP PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Int. Csg - 8.4-8.5 40-50 20-25 5-8 9.0-9.5 < 10 TD Directional: B-05B (see details in attached plan) KOP: 7200', 52 degrees on a 79 degree azimuth. Drop inclination to 28 degrees and turn from 79 to 6 degree azimuth at TSGR. Production Hole: Build to 90 degrees and turn to 274 deg final azimuth. 353' to producing well B-27A while drilling at 9129' · There are close approach wells associated with the directional plan for this well. The risk of collision is considered to be minor. The consequences of a collision could include lost circulation or a hydrocarbon influx (kick). Remedial action could include circulating out a gas kick, squeeze cementing and sidetracking. Intermediate Hole: Close Approach: Logging Program: Intermediate: Drilling: DIR / GR/RES Production Hole Drilling: DIR / GR / Res / Neu / Den Open Hole: None Planned Cased Hole: SCMT(CBL) & Tubing Conveyed Peds FORMATION TOPS TVDss TVD MD COMMENTS UG1 4950 See Directional Plan for TVD & MD. WS2 5575 WS1 580O SIDE-TRACK & KOP 5895 CM3/K12 5985 CMl 7175 TOP HRZ 7460 INCREASE MW ~ Drill 1048 of HrZ & BASE HRZ/LCU 7635 Kingak Shales. TOP KINGAK/TJC 8050 TJB 8205 TJA 8300 TOP SAG RIVER 8380 I~'~c(:,~ Total 7" hole to drill 2889' 5 ~/~" Drilling Liner Depth 8380 Run/Cmt 5 Y2" Drilling Liner TOP SHUBLIK 8415 TOP SADLEROCHIT 8490 TZ4A 8605 TCGL 8675 Conglomerate, hard on bits! TOP ZONE 2 8760 25P 8860 7.2 EMW 24N 8885 24P HOT Wedge 8890 TARGET OIL BEARING SAND PGOC 8900 22N SHALE 8940 22P 8950 11022 TARGET OIL BEARING SAND TD & RUN 3 1/2" LINER 8917 11857 Total 4 3A" Hole to Drill 1768 ft TD Criteria: Drill -70' MD beyond the top of the 24P(toeing up at TD). Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 7" 5 1~,, 17# L-80 STL -3038' 7050/5950 10088/8380 4 3/4" 3 1/2" 9.3# L-80 STL - 1919' 9938/8285 11857/8987 Tubing 4-1/2" 12.6# L-80 NSCT -7050' 0/0 7050/5950 Tubing 3 1/2" 9.3# L-80 NSCT -2888' 7050/5950 9938/8285 Note: 3 ¥2" NSCT coupling OD 3.941" installed inside '5 ~/-'' ~2 , 17# ID 4.892" drilling liner. Casino. Design Basis: Size 15 Y2" FJ Intermediate Drilling Liner Lead: N/A Lead TOC: N/A Tail: Based on 1000' open hole volume around 5 Y2" liner + 30%. Tail TOC: 1000' from TD of intermediate hole. I Total Cement Volume: I Lead None. I Tail 25 bbls/143 CF/124 sx of CL G, 15.8 ppg, 1.16 cf/sk. Casing Size 13 Y2" FJ Production Liner I DesignI Lead: N/A Basis: I Lead TOC: N/A I Tail TOC: Top of 3 1,~,, liner at the hanger & liner top packer. Tail: Based on open hole volume around 3 Y2" liner + 30% XS & 150' liner over-lap. I Total Cement Volume: Lead Tail1 25 bbls/143 CF/123 sx of CL G, 15.8 ppg, 1.17 cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Maximum Anticipated Surface Pressure: (based on BHP & full gas column at 0.10 psi/ft). Section Max Sfc Pres. Presv TVD Gas Grad. EMW FM Intermediate 2419 3264 8450 0.1 7.4 Sag R Production 2454 3334 8800 0.1 7.3 Zone 1 · Planned BOP test pressure: · Planned completion fluid: 3500 psi Intermediate/3500 psi Production 8.6 ppg Seawater/6.8 ppg Diesel Disposal: No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. · Diesel: 100 deg f Flash point & .1 psia vapor pressure at 100 deg f. Current Well Information: Well Name: B-05A APl Number: 50-029-20276-01 Well Type: Producer Current Status: Shut-in BHP: BHT: Last H2S Sample: PSI 3300 8800 0.375 7.21 210 f 10 ppm @ B-02A & B-04 July 2000. Mechanical Condition: BFE Tubing: 42.02 4 Y2", 12.6#, L80, IBT Mod 3.958" ID TD / PBTD / Fill: 11930/11880/no fill rpt'd Pre-rig expected to place P&A cement 100' above perfs. Casing Head: 13 5/8 5M McEvoy Tree: 71/16" 5M CIW Open Perfs: Tubing Fluids: Annulus Fluids: 11680-11700 Seawater and diesel as per handover Seawater and diesel as per handover Tubing Test: Annular Test: 9 5/8" Pack-off Test: pending pending pending Surface Casing Intermediate Prod Liner 13 3/8", 72# @ 2664' 9 5/8", 47# @ 10215' 7", 26# L80, 7" 29# L80 & 29#Cr from 1784' to 11709' TD. . 5. 6. 7. 10. Pre-Rig Work Outline B-05A: MIRU Slickline. Drift 4 V2" tubing to packer depth @-10882' MD(38 deg inc, 8550 TVD). Refer to B-05A schematic. Load and Kill IA and tubing. Perform injectivity test to verify ability to pump into the well's perforations. 3. Plug & abandon w! 15.8 ppg Class G cement. Over displace to perfs with seawater. Use diesel oil for freeze protection. Place 5 bbls minimum cement behind pipe into peri' s. Max TOC is 7200' to allow tubing to be cut at sidetrack window-milling depth. (90 bbls total cement- displace to 7200' MD). Minimum TOC is 100' above top perforation.(10 bbls total cement displace to 11580' MD). MIRU S/L. Drift/Tag TOC. Test and document top of cement per AOGCC requirements. If TOC is higher than 7200' then MIRU coil. unit with 4.5" mill to clean up cement stringers. Pressure test cement plug and record on chart. Test the McEvoy 9 5/8" mandrel pack-off to 5000 psi and service lock down studs by backing out and re-torqueing one at a time. Test the tubing hanger pack-off to 5000 psi and service each LDS. Test the 9 5!8" x 7" annulus to 3500 psi against the packer. Hold I000 psi on the tubing to prevent from collapsing the tubing. 9. MIRU F_gL unit. RIH with jet cutter and sever 4 V2" tubing below anticipated sidetrack depth at -7200' MD. The drilling rig will set a 7" CIBP & whipstock will be set after removing the 4 ¥2" tubing. Jet cutter is acceptable, as this tubing will not be fished. Note the depths of the GLM's in the tbg string. Circulate clean seawater around IA and tubing. Freeze protect IA and tubing. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 2500 psi. Secure well with 0 psi on tubing and annulus. Remove the well house and flow lines. Level the pad and dig out the cellar. Please provide total well preparation cost on the hand over form to the drilling rig representative. Rig Side-track Operations Procedure B-05B: 1. MIRU Nabors 9ES. 2. Circulate out freeze protection and displace well to seawater. Ensure BPV is set. Nipple down tree. Nipple up and test BOPE. 3. Pull and lay down 4 1/2" production tubing, SSSV nipple & GLM's from E-line cut. Replace 9-5/8" casinghead pack off as required. 4. PU 4" DP & collars. TIH w! 6" watermelon mill assembly(without starter mill) to whipstock depth. Note the whipstock depth at +/-7200' MD is at 52 degrees inclination at an azimuth of 79 degrees and a TVDss of 5900'. The CM3 Seabee/Colville Mudstone formation is opposite the proposed side- track depth. Set 7" CIBP on E-line at whipstock depth. (Set per Baker recommended depth, for this size whipstock, to avoid milling casing collar). Pressure test 9 5/8" casing to 3500 psi. o . o o 10. I1. 12. 13. 14. 15. 16. TIH with 7" Baker bottom-trip anchor whip-stock/mill assembly. Orient whip-stock to -85 deg left of high side with MWD as required and set. Displace w/LSND mud and begin milling window when fluid reaches the mills. Mill window through 7" & 9 5/8" casing strings. Run in hole w/directional drilling assembly. Drill 20' of formation & conduct FIT to 12.5 ppg. EMW. Kick-off and drill 7" (EWD = Enlarge While Drilling Tool) borehole into the top of the Sag River formation at -8380' TVDss and -10237' MD. Run MWD/GR/RES LWD. LSND mud @ 10.5 ppg. Drop ESS. Bit no. 1 & EWD tool. POOH. Run and cement a 5 ¥2", 17# L-80, STL (FJ connection) intermediate drilling liner with 150' of lap to TD. POOH. Pump cement, drop DP wiper plug, and displace with mud. Hydraulic set liner hanger, unsting, circulate cement from liner top, & weight set liner top packer. Make up and Rill with a 4 3/4" bit, directional assembly, 3 aA" DC's, -4500' of 2 7/8" DP, XO, 4" DP & TIH to the landing collar. Test the 9 5/8", 7" casing and 5.5" liner from the landing collar to surface to 3500 psi for 30 minutes. Drill out 20' & FIT to 9.5 ppg EMW. Displace w/low-density mud. Drill -1700' of 4 3/4" hole from 5 V2" liner setting depth to TD in Zone 2. Runl MWD/GR/RES real time LWD. Spot liner running pill in open hole & POOH w/DP. Run 3 V2", 9.3# L-80 STL FJ production liner, w/150' of lap, to TD. Pump cement, drop wiper plug and displace with "perf pill" followed by mud. Hydraulic set liner hanger, unsting & circulate cement from liner top, & weight set liner top packer. Test the 3-1/2", 5.5", 7", & 9 5/8" casing from the landing collar to surface to 3500 psi for 30 minutes. Displace well to clean seawater above liner top. POOH. Drill pipe convey(2 1/16") CBL then ,. . perforate 6spf, 2" guns -100', of the production interval as determined by LWD/Geologic analysis. POOH w/DP. Run WLEG, Profile Nipples, Packer, Profile Nipple, GLM's, 3 ~ L80 NSCT, & 4-1/2" L80 NSCT tubing, SSSV nipple. See attached completion schematic for details. Space out tailpipe into the 3- 1/2" liner top. Reverse circulate clean seawater w/corrosion inhibitor. Drop ball/rod, pump into position to RHC plug, set packer(4500 psi) and test the tubing to 3500 psi. Bleed tubing pressure to 1500 psi. Test annulus to 3500 psi for 30 minutes. Bleed off tubing pressure & pressure up annulus to shear the RP valve in the top GLM. Land tubing, back-out landing joint, & RILDS. Set TWC & test from below to 2500psi. ND BOPE & Nipple up and test tubing head adaptor & tree to 5000 psi. Test control lines. Pull TWC. Displace annulus w/sufficient volume to freeze protect tubing & annulus to -2200' TVD. Allow fluids to U-tube into tubing. Install & test BPV. Secure well. 17. Rig down and move off. Post-Rig Work: · MIRU slickline. Pull the ball / rod and RHC plug from 'X' nipple below the new production packer. Install gas lift valves. Place well on production. B 05a WELLHEAD: McEVOY I BF. ELEV = 42.02 30'x201nsulatedconductor Pipe , 1,784 I~' I 110 ~e~ck Stdng I I . ~ (HESXHXO~ (3.813" ID) 2,222 9-518"FOCI~/I~ '~ ~ ~ k GASx1. LIFT MANDRELS ~5/8'DV Packer 2,673 4.s" CAMCO KBG-2-MOD ( B~ ~TCH 3.9~" ID) 13-3/8". 72 fi/fi, /' / N~ I MD(BKB) , WDss ~v L-SO, BTRS [2,664 ~ 5 5,651 4,020 . KOP ~1' 1,400 ' ' 3 9,386 7,350 42' , KOP ~1:10,172 2 10,405 8,075 ; 39' M~ ANGLE: 75~ 1 10,804 8,396 i 38" I 4-1/2" 12,6~ L~0 IBT-MOD TUBING ID: 3.958" ~ ~. CAPACI~: 0.01522 BB~FT .4-~/2-'x' N~PPLE so,om of 7"26~ MOD- ~ (.~s)(a.o~a" ~) BU~Tieback String ~ ~ i ~ / / 7"X4-1'2" PACKER ~0,882 I 7" X 9 5/8" Liner ~ : /~er S-3) (3.875" ID) Han~er/~kr{Baker) ~~ ~ ~/ 0-5/8~, 47~1~, k-80. ' {HfiS) {3.8~3~ I~) B~ Window I I1 (HES) (3.725" ID) ~ ~~ ~4-1,2"WLEG ~ ~j .960"1D) (ELMD) ~ 0,955 ~. L-S0, BTC- MOO, CS~. ~ ~ I ~ , REF. LOG: ATLAS ACOUSTILOG 6121196 T~E ~. LO~: PBTD, CTMD Size SPF Inte~al OpenlSqzed 7" 29. ~3CR L-80,NSCC BUTT t 1,930 3 3~8" 6 11,680 - 11,700 Open 5~2~99 / 3 3~8" 6 11,680 - 11,690 RepeE 3 3/8" 6 11,688 - 11,702 7/19/99 3 3/8" 4 11,810 - 11,820 SQ~ 2 7~8" 6 11,820 - 11,840 Repeal 3 3/8" 4 11,820 - 11,840 4~20~00 DATE REV. BY COMMENTS PRUDHOE BAY UNIT 7/12/96 WRR Initial Sidetrack Red WELL: B-05a {41-32-11-14) 2121199 KJW Set IBP 4/16/99 Nerds Pull IBP, update APl NO: 50-029-20276-01 wlzw/~ uAJ ~m[~qz SEC 31; TN 11N; PGE 14E 5/2/~ DDW RuFf, ~ Fu~[ OIO4 I~ ~ I 41~1~ ~Wg Repe~ BP Exploration (Alaska) GAS LIFT MANDRELS 4.5" X 1" CAMCO KBG-2-MOD ( BTM LATCH 3.909" ID) N° MD(BKB) TVDss Dev 6 3,023 2,951 8' 5 5,651 4,929 50° 4 7,912 6,339 49° 3 9,386 7,350 42° 2 10,405 8,075 39° 1 10,804 8,396 38° TREE: 7" CIW 5K carbon WH: McEvoy 13 3~8" 5K PRd"" OSED SIDE-TRACK B-05B Nabors 9ES RKB 70.52 est'd BFE 42.02 OKB 68.74 Top of 7" Liner: 1784' Casing: 13 3/8" 72# L80 BTC 2664.' 9 5/8" FOC2057' 9 5/8" DV 2673" GLM Depths Proposed 3600' TVD 5.984 Mandrel OD 4 1/2 5650' TVD 5.984 Mandrel OD 4 1/2 6900' TVD 4.725 Mandrel OD 3 1/2 8150' TVD 4.725 Mandrel OD 3 1/2 Proposed Completion: 2200'4 1/2", 12.6#,BTCM, L80 Tbg 4 1/2" SSSV Nipple @ 2200' 3.8131D 4800'4 1/2" 12.6#BTCM, L80(2200-7000) 4 1/2 BTCM x 3 1/2 NSCT XO 3000' 3 1/2" 9.2# NSCT Tubing 10' pup, 3 1/2 X nipple2.813, 10' pup SABL3 Pkr 5 1/2 x 3 1/2 6-9938' 10', 10' 3 1/2 X nipple, 10', 3 1/2" XN 2.666 ID, 10', Muleshoe 4 1/2 BTCM x 3 I/2NSCT: Cross-over 5 1/2"17#STL drilling liner 7050-10088 MC 5 1/2 x 7 CPH Pkr w/HMC HGR Run Tool w/Pusher Tool ClBP & Whipstock @ -7210' MD Mill 6 1/8" Window through 7" & 9 5/8" Cut 4 1/2" tubing @ +7210 Casing: 9 5/8" 47# L80 @ 10215' Original Completion: X nipple @ 10872 Pkr 7 x 4 1/2 610882' X nipple @ 10905 XN nipple @ 10926 WLEG @ 1O938 P & A Cement Max 7200 MD Min 11580 MD 3 1/2" 9.2# STL liner 9938-11857 MD 3 1/2 x 5 1/2 CPH Packer 3.625" ext 6' HMC HGR (C2 Run Tool & Std Dog Sub) 7 "29# 13Cr, NSCC 11930' "Liner Perfs 11680-11700 DATE 3-08-01 REV. BY Schmitz COMMENTS Proposed Side-track PRUDHOE BAY UNIT WELL: B-05B BP Exploration (Alaska) B-PAD ~. MI LINE TO A-PAD MI GC-3 ,..~ TO GC-1 & GC-2 GLT HEADER MI FROM CGF 6-90 FLOWLINE~ FROM GC I~! ~°.oS:~ ~lI WELL PAD B N ~-- PIPELINE II I I . 8~ II / ACCESS ROAD MI BLOCK 29~ 36~ II / w~w +1 ~ 19 27 II/ I 336 7 I a2o ~30 6 ~ 21 ~ = 22 4 SUMP 23 5 MI LINE TO X-PAD II I - 332A ' ~J ~26 I ~11 ~ WELL AND 6" PRODUCTION ~ ~[L, 6" PRODUCTION LINE AND 3" GLT ' , ~ ~[L, 6' WSW LINE, AND 4" MI I I I I I I I / * ~[L HEAD AND CEL~R I 12 ~ I I ~/ ~SUBS,DENCEWELL I S T I I I III z/ ~ODUO~,ON~,N: W~S~-~ ~- I~~11 ~TTW~N: WELLSB-~&B-35/B-15SB- II I ~11 o ~ ~-~ ~-~<NO WSW TWIN: WELLS B-9, B-13 B-31 & B- SUSPENDED ~.32 ~LLAR ONLY ' NOTE: B-1 & B-27 to get Perm PBGL FLARE PIT TO X-PAD 17 I No h Slope Alaska Alaska Drilling & Wells B-05BPBU-WOAwp05B Pad I DrillQuest' Proposal Data for B-05B WP$ ~l~dO~.:. We, We41 Mea~ummenl Un~: ft Vertical Section D~: Well Vertical Se~on ~: o.oo N.O.00 P Ma~mumd ~ ~ V~ Nc~ E~ Y~ 7202.00 51380 78.855 5966.19 658.03 N 2780,73 E -842,~ 7242.00 52.037 83.912 5990.94 662.73 N 281 l.ll0 E -854.68 10.00 7760.72 28.625 5.746 6406.95 81836 N 3043.62 B -837.68 i 0.00 10148.16 28.623 5.746 8502.58 1956.89 N 31~8.14 E 85.10 0.00 1102135 86.060 274.019 9020.52 2256.01 N 2639.79 E 605.76 I0.00 11021.89 86.064 274.019 9020.52 2256.01 N 2639.75 E 605.78 10.00 11293.52 86.064 274.019 9039.17 2275.00 N 2369.421[ 759.24 0.00 11332.88 q0.lX~0 274.019 9040.52 22T/.76 N 2330.19 E 781.51 10.IX) 11395.01 96.170 273.294 9037.18 2281.71 N 2268.32 E 816_t0 10.IX} 11857.03 96.170 273.294 89tr/.52 230~.11 N 1809.73 E 1071.60 0.~O I9500- ---End Dir, 5 1/2' I.Jner 1OO88.86 8450.52 I I ;tart Sail @ 28.625°: Begin Dir @ 10.00°/10Oft: 11293.52ft MD, 9039.17ft TVD B-O5B T3 % 3 1/2' Uner \ 11857.03 8987.52 Geo Pol), BO5B~ End B-O5B T2 End Dir, Start Sail @ 86.064° : 11021.89ftMD,9020.52ftTVD TI : 11395.01 ftMD,9037.18ft'l'VD · 10148.16ff MD, 8502.57ft TVD$1/2' uner 10O88.86 End Dir, Start Sail @ 28.625°: 7760.72ftMD,6406.95ftTVD -~Begin Dir {} : 10148.16ft MD, 8502.57ft TVD End Dir, Start Sail @ 86.064°: 11021.89ftMD,9020.52ftTVD ~~ _ ~-Begin DIr @ 10.00~/100ff: 11293.52ff MD, 9039.17ft TVD nd Dir, Start Sail @ 96 ..... 170°. 11395 01ftMD 9037 18ftTVD '~05B ~~B 05B T3 I I I I I I I I I I I 1800 2000 2200 2400 2600 2800 3000 3200 -1000 -500 0 500 1000 1500 2000 2500 Scale: lcm = 500ff Section Azimuth: 329.529° (True North) Scale: lcm = 200ft Reference is True North Eastings - 2400 Current Well Propertle~ Ref. Glo, nJ ~: 5~49795.00 N, 6~403~.00 E Ref. Structure Reference: 3312.43 N, 2014.65 E Ref. GeolF'al~nlcaJ Coor~ nate~: 70* 16' 0~.g334" N, 211' 1~' 35.732~' E RKB Elevatio~: 70.$2ft abow Mean Sea Level 70.52fl abo~e b"~ucture Reference Units: Feel - 2200 - 200O - 800 ~ Vertical Section Sperry-Sun Drilling Services Proposal Data - B-O5B - B-O5B WP5 I · ~:~...'.:.' · · .( ) ..... - .... ~...,~.--; · ,: .... L.~..-,~.,~.-~(f~),,:,-' ~ .... , ....... .~. '~,~--," ~ .- ~} .... /lO0~C, .' ~ ....... , . ~ .... ,,~.~......,~ .~,..~., ~ ............ :.,.~.,.~,, .~. , ,.., ...... ~,.., , ~o~. oo .,..::...~: ~:'.':"~.'.s~;'Sel~,~;~.~e;~is~:~,'lr?~t~.~.~,;;. :.:t:~S~:~'.~,~o':~37~?.'~: :'/·. !. ': '.1. ;:. :' .T242.00. ¢0. O0 :.:.~2.0~'t.:~.,.:~a;~[]~9~0~,iI' ;'~:::'~:*'~1 ~:~3.'~:*o ~. ~c. oo as. oo[ ,~:." :'5~ ' ~10~2':0~.i:~?~.~' 8~.0~ .... ~'7~.'~2 9~0}S~;':;~~2256~ ~'2639.7~"E ~0.'~0"':~'2~'6:.'~0 ':}.."~'~0S.$ ' ' ' ' ' ' ; ' ' :' ". ~ '; . ' -' - : - '" · ',-;"-~' '. ' ' ' :' ' · '~ ' · .' · '~ ' "' ' i .~..: " ~:.~ 11~]2;88':..,~23~ ~0.00 27~.02 9040.52.}':~..:'..~?~52277.76 ~2930.1~ E 10.00' '.',0.'.0~ '".,781.5 . .,, .. ......... . '.' . .. ,, ~. .,. ;=:?}:; . - . , . . . . . ~'.' '~:..,o.'~o~':.'. ..: .?o.oo .'"'~',~."~ ~ ............................ : ........ "' ~: -~. ;- ..-'-'-:--' ..... : ....... ~'.~ ..... : -.--'. ~ --:.-..: .: ........ ~. ~-..~ ........ ~.L ............... 20 March, 2001 - 15:09 - 1 - DrillCluest North SI.op.e Alaska ~~ Alaska Drilling & Wel~~~~ PBU_ WOA B Pa~~-'-~ s-o s ~= _ -~~0, ~oo ~ .... ~ Su~ace Coordinates: 664036.00 E (70° 16' ~.9~4" N, 211° 19' 3&7329" E) ~~~g: 70.5~ above Mean ~a Level D F! ii- L:I tl G !~ I= I:IV ICE S Proposal Ref: pro10780 Sperry-Sun Drilling Services Proposal Report for B-O5B WP5 North Slope Alaska Measured Depth (ft) Incl. Azlm. Sub-Sea Depth (ft) 7202.00 51.580 78.855 5895.67 7242.00 52.037 83.912 5920.42 7300.00 47.471 79.223 5957.89 7339.02 44,518 75.674 5985.00 7400.00 40.1 58 69.335 6030.09 7500.00 33.969 56.246 6109.97 7600.00 29.632 39.063 6195.11 7703.00 28.032 18.502 6282.93 7760.72 28.625 5.746 6336.43 7800.00 28.625 5.746 6370.91 7900.00 28.625 7935.68 28.625 8000.03 28,625 8100.03 28.625 8203.00 28,625 8300.03 28.625 8400.00 28.625 8500.00 28.625 8600.00 28.625 8700.00 28.625 8716.06 28.625 8800.00 28,625 8900.00 28.625 9000.00 28.625 9040.75 28.625 5.746 5.746 5.746 5.746 5.746 5.746 5.746 5,746 5.746 5,746 5.746 5.746 5.746 5,746 5,746 5.746 5.746 5.746 5.746 5.746 9100.00 28.625 9200.00 28~25 9240.12 28.625 9300.00 28.625 9400.00 28.625 6458.69 6490.00 6546.46 6634,24 6722.02 6809.79 6897.57 6985.35 7073.12 7160.90 7175.00 7248.68 7336.46 7424.23 7460.00 7512.01 7599.79 7635.00 7687.56 7775.34 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings ~~ga~ (ft) (ft) (ft) (ft) .~~ 5966.19 658.03 N 2780.73 E 5950513.4~A~!_~.. ~~1.~ 5990.94 662.73 N 2811.80 E 595051~ ~, ~=E 6055.52 675.23 N 2882.95 E 59~5,3'v~j~~ ~903.55 E 6180.49 714.44N 2975.63 E ~~_.12N~- 666995.36 E 6265.63 749.25 N 3014.54 E, -~I~~'6 N 667033.49 E 6353.46 790.83 N 3037,~.~;;~-;'.~,~59~ N 667055.68 S 6406.95 818.86 N 304~i62 E '"":i:!;~5067~.99 N 667061.05 E 6441.43 637.58 N ~04SJ5.1 E .-'~50698.75 N 667062.53 E ~3055~ ~ 5950794.28 ~ ~7070.94 ~ 6704.76 0.31 3009.495956937.56 667001.31 7 43.94 1218.92 N 3083.88 E 5951000.84 N 667092.58 E ~68.59 N ,3088.68 E 5951128.60 N 667096.34 E 1274.25 N 3089.45 E 5951136.27 N 667096.94 E : 1314.26 N 3093.47 E 5951176.36 N 667100.10 E 7~ 1361.93 N 3098.27 E 5951224.12 N 667103.85 E 7494~ 1409.59 N 3103.07 E 5951271.88 N 667107.61 E 7530.52 1429.02 N 3105.02 E 5951291.34 N 667109.14 E 7582.53 1457.26 N 3107.86E 5951319.64N 667111.37 E 7670.31 1504.93 N 3112.66E 5951367.40N 667115.12 E 7705.52 1524.05 N 3114.58E 5951366.56 N 667116.63E 7758.00 1552.60N 3117.46E 5951415.16 N 667118.88E 7845.86 1600.26 N 3122.25 E 5951462.93 N 667122.64E Dogleg Rate (°/10Oft) 10.00 10.03 10.00 10.00 10.00 10.00 10.00 10.00 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells PBU_WOA B Pad vertical Section Comment -842.97 -854.67 -871.33 -879.98 -889.28 -893.18 -882.91 -858.78 -837.66 -822.48 -783.83 -770.04 -745.18 -706.53 -867.88 -829.22 -590.57 -551.92 -513.27 -474.62 -468.41 -435.97 -397.31 -358.68 -342.91 -320.01 -281.36 -265.85 -242.71 -204.06 CM3 End DIr, Start Sall @ 28.625°: 7760.72riM D,6406.95ftTVD CM2 CMl Top HRZ LCU 22 March, 2001 - 10:27 Page 2 of 7 DrillQuest 2.00.08,004 Sperry-Sun Drilling Services Proposal Report for B-O5B WP5 North Slope Alaska Meesured Depth In¢l, (~t) 9500.00 28.625 9600.00 28.625 9700.00 28.625 9712.91 28.625 9800.00 28.625 9889.49 28.625 9900.00 28.62~ 9997.72 28.625 10000.00 28.625 10088.86 28.625 Sub-Sea Vertical Local Coordinates Azlm. Depth Depth Northings (~t) (~t) (~t) 5.746 7863.12 7933.64 1647.93 N 5.746 7950.89 8021.41 1695.60 N 5.746 8038.67 8109.19 1743.27 N 5.746 8050.00 8120.52 1749.42 N 5.746 8126.45 8196.97 1790.93 N 5.746 8205.00 8275.52 1833.59 N 5.746 8214.23 8284.75 1838.60 N 5.746 8300.00 8370.52 1885.18 N 5.746 8302.00 8372.52 1886.27 N 5.746 8380.00 8450.52 1928.62 N 10100.00 28.625 5.746 8389.78 10128.73 28.625 5.746 6415.00 10148.16 28.625 5.746 8432.06 10200.00 28.747 354.938 6477.56 10214.20 28.929 352.018 6490.00 10300.00 31.287 335.518 8564.35 10348.10 33.427 327.459 8605.00 10400.00 36.250 319.828 8647.61 10434.43 38.363 315.339 8675.00 10500.00 42.794 307.897 8724.82 10549.41 46.408 303.096 8760.00 106(X).00 50.293 298.755 8793.63 10703.00 58.385 291.471 8851.94 10715.65 59.663 290.452 8860.00 10768.72 64.121 287.187 8685.00 8460.30 1933.94 ~? 3~.~=_5.~83 E ' 8485.52 1947.63 '~..~-E 8502.58 19~N ~i 58~ S 8560.52 __. ~~-~ 3157.50 E ~ '~' 2139.39 N 3041.21 F ~_ 2158.77 N 3008.78 E 8922~ 2192.94 N 2935.26 E 8930.52 2197.74 N 2922.73 E 8955.52 2212.80 N 2878.43 E Global Coordinates Eestings Northinga L~ngs (~t) (~t) 3127.05 E 5951510.69~N 3131.85 E 59515~'~' ~ '~~E 3136.64 E 5951~.~ 66~1 E 3137.26 E 595~6~~- _6~134.39 E 3141.44 E 5~53;~_ ~137.66 E ',,::.,..! .:....: 5951820.25 5951 645.04 N 667150.35 E 5951851.82 N 667149.42 E 5951892.45 N 667136.39 E 5951914.73 N 667123.59 E 5951938.13 N 687105.48 E 5951953.20 N 667091.07 E 5951980.68 N 667058.55 E 5952000.15 N 687029.87 E 5952018.82 N 666997.02 E 5952051.38 N 666922.77 E 5952055.91 N 666910.14 E 5952070.01 N 666865.53 E Dogleg Rate (o/lOOft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 Alaska Drilling & Wells PBU_WOA B Pad vertical Section Comment -165.41 -126.75 -88.10 -83.11 -49.45 -14.86 -10.80 26.97 27.85 62.20 68.50 77.61 85.12 106.41 112.67 154.08 179.76 209.19 229.58 270.08 301.70 334.85 401.59 412.08 447.52 TJC TJB TJA 5 1/2" Liner TSGR TSHU Begin Dir @ 10.00°/10Oft 10148.16ff MD, 8502.57ff TVD TSAD/TZ4B TZ4A/42SB TCGLJTZ3 BCGL/TZ2 25P 24N 22 March, 2001 - 10:27 Page 3 of 7 DrillQuest 2.00.08.004 Sperry-Sun Drilling Services Proposal Report for B-O5B WP5 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth Northings (ft) (ft) (ft) (ft) 10780.38 65.111 286.504 8890.00 8960.52 2215.86 N 10800.00 66.782 285.378 8898.00 8968.52 2220.78 N 10805.13 67,720 285.089 8900.00 8970.52 2222.02 N 10000.00 75.406 280.020 8930.39 9000.91 2241.43 N 11000.00 84.143 275.072 8948.13 g018.65 2254.28 N 11021.85 86.060 274.019 8950.00 9020.52 2256.01 N 11021.89 86.064 274.019 8950.00 9020.52 2256.01 N 11100.00 86.064 274.019 8955.36 9025.88 2261.47 N 11200.00 86.064 274.019 8962.23 9032.75 2268.46 N 11293.52 86.064 274.019 8968.65 9039.17 2275.00 N .....o236g',~12 ~ ..~"~52121.10 N ..?'-'~-:'i!~'.:.. '''~''.'':!~:?'.'..':.~: ~ 11300.00 86.712 274.019 8969.06 0039.58 2275.46 '~,!!~,,..~..~,...~!{~1E 5952121.41 N 11332.88 90.000 274.019 8970.00 9040.52 227~_~ _ '¥[~:~'i~:,~2330;f§ E 5952123.00 N 11395.01 96.170 273.294 8966.66 9037.18 --~1.71-J~-~' ~.32 E 5952125.61 N 11400.00 96.170 273.294 8966.12 g036.64 ~~ 2263.36 E 5952125.78 N 11700.00 96.170 273.294 8933.88 _~;_a~_ _~._ 9.14 N 1965.59 E 5952136.43 N 96.170 273.294 8923.13 ~':~~4.85 N 1866.33 E 11800.00 5952139.98 N 11857.03 96.170 273.294 8917.00 8g~..~- 2308.11 N 1809.73 E 5952142.00 N dat~ is in Feet unless otherwise stated. Dire~on~'and ex, ordinates are relative to lrue ~orth. ¥orfieal depths am relative to Well. Northings and Ea~ngs are relate ~o Well. Local Coordinates Global Coordinates Eastings Northings ~pgs 2868.35 E 5952072.~ -~~ 2851.12 E 595207"( ~ ~.~, ~, ~ E 2~,6.57; 5952q~ ~- ~~7 E 2758.93 E 5952~~? 6e6745.43 E 2651.49 E 5~~~~7.73 E 2639.7..5, E....'~ N 66~5,96 E 25&~;02 E ":::! ~52111.77 N 666548.13 E 248~.50 E ~52116.59 N 666448.46 E 666355.28 E 666348.83 E 666316.00 E 666254.05 E 666249.09 E 666149.73 E C-,?,,~E,0.38 E 665951.02 E 665851.66 E 665795.00 E The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 329.529° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11857.03ft., The Bottom Hole Displacement is 2933.00ft., in the Direction of 38.099° (True). Dogleg Rate (o/looft) 10.00 10.00 10.00 10.00 10.00 10.00 10.00 0.00 0.00 0.00 10.00 10.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells PBU_WOA B Pad Vertical Section Comment 455.27 24P 468.25 471.62 PGOC 532.80 593.29 605.78 605.80 649.93 706.42 759.25 762.91 781.52 816.31 819.07 874.33 929.58 984.84 1040.10 1071.61 Targa - Geo Poly B05B, Current Targe End Dir, Start Sail ~ 86.064°: 11021.89ftMD,9020.52ftTVD Begin Dir @ 10.00°/100ff : 11293.52ft MD, 9039.17ft TVD Target - Ddllers Poly B50B, Curre~ Target End Dir, Start Sail ¢} 95.17(Y': 11395.01flMD,9037.18ftTVD 3 1/2" Uner Target - B-05B T3, Current Target 22 March, 2001 - 10:27 Page 4 of 7 DrillQuest 2.00.08,004 Sperry-Sun Drilling Services Proposal Report for B-O5B WP5 North Slope Alaska Alaska Drilling & Wells PBU_WOA B Pad Comments ,,~,..~. Measured Station Coordinates ~:-~'1~ "'"*~.*~= Depth TVD Northings Eastings Comment 7760.72 6406.95 818.86 N 3043.62 E End Dir, Start Sail @ 28.625°: ~.72f!M~~ffTVO 10148.16 8502.57 1956.89 N 3158.14 E Begin Dir @ 10.00°/100ft ~;~~~ e502.57ft TVD 11021.89 9020.52 2256.01 N 2639.75 E End Dir, Start Sail ~ 86.~11~gftM~.52ftTVD 11293.52 9039.17 2275.00 N 2369.43 E Begin Dire 10.00 /100ff~~-~.52ft MD, 9039.17ftTVD 11395.01 9037.18 2281.72 N 2268.31 E End DIr Start Sail ~_~0'° -------: ~~ftMD,9037.18ftTVD Formation Tops _~ Measured Vertical Sub-Sea ~ Depth Depth Depth Northings Eastings ~~DIr. Formation Name (ft) (ft) (ft) (ft) (ft~~ Deg. 7339.02 6055.52 5985.00 675.23 N 2~'~~' 0.000TM~~ 1.249 CM3 7935.68 6560.52 6490.00 902.26N ~0~ 0.000 1.2249 CM2 8716.06 7245.52 7175.00 1274.25 N ~5 ~.0.000 1.249 CMl 9040.75 7530.52 7460.00 1429.02 N ~3~2 E ~ 0.000 1.249 Top HRZ 9240.12 7705.52 7635.00 1524.05 N '~~58 E 0.000 1.249 LCU 10214.20 8560.52 8490.00 1988.48 N 3157.50 E 0.000 1.249 TSAD/TZ4B 10348.10 8675.52 8605.00 2051.94 N 3133.06 E 0.000 1.249 TZ4A/42SB 10434.43 8745.52 8675.00 2091.11 N 3101.38 E 0.000 1.249 TCGI./'rz3 10549.41 8830.52 8760.00 2139.39 N 3041.21 E 0.000 1.249 BCGL/TZ2 10715.65 8930.52 8860.00 2197.74 N 2922.73 E 0.000 1.249 25P 22 March, 2001 - 10:27 Page 5 of 7 DrillQuest 2.00.08.004 Sperry. Sun Drilling Services Proposal Report for B-O5B WP5 North Slope Alaska Measured Vertical Sub-Sea Depth Depth Depth Northings (ft) (ft) (ft) (ft) Formation Tops (Continued) 10768.72 8955.52 8885.00 2212.80 N 10780.38 8960.52 6890.00 2215.86 N 10805.13 8970.52 8900.00 2222.02 N Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (fl) (ft) (ft) 7202.00 5966.19 10088.86 8450.52 7202.00 5966.19 11857.03 8987.52 Targets associated with this wellpath Target Name B-05B T1 B-05B T2 B-05B T3 Ddllers Poiy B50B Eastings Dip Dip Dir. (ft) Deg. Deg. Casing Detail~j~[ ~~ ~ L~g~31/2" L .~ 2878.43 E 0.000 1.249 2868.35 E 0.000 1.249 2846.57 E 0.000 1.249 ~___GOC'~ Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Formation~ ~/ Name~~ 24N ~~: ___ Target TVD (ft) 9020.52 8950.00 9040.52 8970.00 8987.52 8917.00 9040.52 Entry Coordinates Northings Eastings Target (ft) (fi) Shape 2256.01 N 2639.79 E Point 5952108.00 N 666826.00 E 70° 16' 31.1181" N 211 o 20' 52.6034" E 2277.76 N 2330.19 E Point 5952123.00 N 666316.00 E 70° 16' 31.3330" N 211 ° 20' 43.5881" E 2308.11 N 1809.73 E Point 5952142.00 N 665795.00 E 70° 16' 31.6329" N 211 ° 20' 28.4325" E 2277.76 N 2330.19 E Polygon Alaska Drilling & Wells PBU_WOA B Pad Target Type Current Targa{ Current Targe~ Current Targa{ Current Targa 22 March, 2001 - 10:27 Page 6 of 7 DrillQuest 2.00.08.004 Sperry-Sun Drilling Services Proposal Report for B-O5B WP5 North Slope Alaska Target Name Geo Poly B05B Target Entry Coordinates TVD ~!ngs Eastings Mean Sea Level/Global Coordinates: 8970.00 ~9521'2~.:~ N 666316.00 E Geographical Coordinates: ~70~,~ N 211 ° 20' 43.5881' E Targel Boundary Point #1 904~~~-'~ ~1~ ~..72 N 2561.75 E #2 9(~40~~' ~.~22~ Sl.92 N 2965.43 E #3 ~~.~_ ~2237.99 N 1952.24 E ~-.~["'.'""~'.'<"" "~ ~-~--~.~., e~5952141.00 N 666951.00 E ;-i~;':" #3";"'~:.~-~8970.00 5952075.00 N 665939.00 E ~."~i... #4 '.~'~8970.00 5952038.00 N 666536.00 E _ -..'.~ ?~ Geograph~n;~"#!'~-~ -"'" '.-'/'!"~ 70° 16'31.5581' N 211° 20'50.3312' E ~~-~?#3 70° 16'30.9429" N 211° 20'32.5817' E ~% ~ #4 70° 16' 30.4493" N 211 ° 20' 49.9382' E ~ -~ ~- 9020.52 2256.01 N 2639.79 E Mean ~Global Coordinates: 8950.00 5952108.00 N 666626.00 E ~ ~ '~-_~ll~h. k:,~dCoordinates:~ 70°18'31.1181', 211°20'52.~34'fi Tar~ #4 9020.52 2152.17 N 1805.33 E Vlean Sea Level/Global Coordinates #1 8950.00 5952233.00 N 665797.00 E #2 8950.00 5952206.00 N 666631.00 E #3 8950.00 5951956.00 N 666615.00 E #4 8950.00 5951986.00 N 665794.00 E Geographical Coordinates #1 70° 16' 32.5273" N 211 ° 20' 28.5491' E #2 70° 16' 32.0806' N 211 ° 20' 52.8122" E #3 70° 16' 29.6258' N 211 ° 20' 52.1852' E #4 70° 16' 30.0992' N 211 ° 20' 28.3033' E Alaska Drilling & Wells PBU_WOA B Pad Target Target Shape Type Polygon Current Target 22 March, 2001 - 10:27 Page 7 of 7 DrlllQuest 2.00.08.004 Sperry-Sun Anticollision Report ~ Refemace: Well:. B-05, True Norlh Vertical (TVD) Rd~-e~e: 9ES RKB O 70.52 70.5 ~ BP Am~ FleM: Prudhoe Bay Rofereaee Site: PB B Pad Refemaee Well: B-05 RofereaeeWoilpath: Plan B-058 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200% 100/100O of rofemac~ - There are 'l]~aalls la this rellim: Plan #5 & NOT PLANNED PROGR~ Interpolation Method: MD Interval: 100.0 ft Error Model: ISCWSA Ellipse Depth Range: 7202.0 to 11857.0 ft Scan Mod~od: Trav Cylinder North Maximum Radius: 1382.9 ft Error Sm'face: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ff ff in in 111.8 111.8 20.000 30.000 20" 1452.8 1452.7 13.375 17.500 13 3/8" 7201.8 5966.0 9.625 12.250 9 5/8' 10228.9 8573.4 5.500 7.000 5 1/2" 11701.3 9004.3 3.500 4.750 3 1/2' Plan: Plan #5 Date Composed: 12/19/2(XX) Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary PB B Pad B-04 B-04 V1 PB B Pad B-05 B-05 V4 PB B Pad B-05 B-05A V2 PB B Pad B-07 B-07 Vl PB B Pad B-08 B-08 V1 PB B Pad B-16 B-16 Vl PB B Pad B-20 B-20 Vl PB B Pad B-22 B-22 Vl PB B Pad B-27A B-27A Vl PB B Pad B-27 B-27 Vl PB B Pad B-36 B-38 V1 PB C Pad C-27A C-27A Vl 10715.4 10200.0 943.9 860.6 97.9 Pass: Major Risk 7300.0 7300.0 3.9 No Reference Casings 7300.0 7300.0 3.9 No Reference Casings 7215.5 7000.0 1100.0 919.5 232.8 Pass: Major Risk 8878.4 8900.0 1105.1 851.6 320.3 Pass: Major Risk 11205.3 9900.0 530.9 56.9 530.9 Pass: Minor 1/200 7331.8 7600.0 1024.1 909.5 245.7 Pass: Major Risk 9436.9 9100.0 404.0 59.4 349.8 Pass: Minor 1/200 9438.9 9100.0 404.0 59,4 349.8 Pass: Minor 1/200 7381.4 7100.0 366.0 655.0 241.0 Pass: Major Risk 11411.0 12298.1 778.2 48,7 778.2 Pass: Minor 1/200 9501.4 7934.8 8700.0 7468.7 138.4 165.1 321.27 315.52 7.000 1363.8 906.5 463.1 Pass 9590.0 8012.7 8800.0 7543.5 138.4 168.9 322.85 317.11 7.000 1338.7 917.8 423.2 Pass 9677.8 8089.7 8900.0 7617.2 138.5 172.9 324.58 318.83 7.000 1310.0 929.7 383.9 Pass 9764.3 8165.6 9000.0 7689.6 138.5 177.0 326.47 320.72 7.000 1283.6 942.0 345.3 Pass 9849.4 8240.3 9100.0 7761.1 138.5 181.1 328.49 322.75 7.000 1258.7 954.7 307.2 Pass 9933.9 8314.5 9200.0 7832.3 138.5 185.3 330.64 324.89 7.000 1230.2 967.6 270.7 Pass 10018.1 8388.4 9300.0 7903.4 138.5 189.5 332.89 327.14 7.000 1205.2 980.5 237.2 Pass 10102.0 8462.1 9400.0 7974.7 138.5 193.7 335.22 329.48 7.000 1180.8 993.4 206.3 Pass 10378.8 8700.9 9500.0 8047.4 132.5 171.0 332.01 9.20 7.000 1153.1 898.2 258.5 Pass 10553.5 8833.3 9600.0 8122.1 132.8 149.5 331.42 28.70 7.000 1113.7 838.3 282.0 Pass 10614.4 8873.2 9700.0 8199.7 133.9 144.7 334.30 36.69 7.000 1074.5 834.1 248.8 Pass 10647.5 8893.3 9800.0 8280.0 134.7 143.6 338.27 43.16 7.000 1038.2 837.7 206.5 Pass 10670.0 8906.2 9900.0 8363.1 135.4 143.8 342.80 49.30 7.000 1005.8 843.6 165.6 Pass 10687.6 8915.9 10000.0 8448.7 135.9 144.4 347.74 55.44 7.000 978.2 848.2 131.6 Pass 10700.0 8922.5 10100.0 8536.4 138.3 145.5 353.06 61.59 7.000 956.8 852.5 108.3 Pass 10715.4 8930.4 10200.0 8625.4 136.8 146.4 358.48 68.01 7.000 943.9 860.6 97.9 Pass 10724.2 8934.8 10300.0 8713.3 137.1 147.9 4,22 74.32 7.000 942.5 868.2 105.8 Pass 10729.7 8937.5 10400.0 8799.7 137.3 149.9 10.04 80.47 7.000 953.3 875.9 133.1 Pass 10733.4 8939.3 10500.0 8885.3 137.4 152.1 15.70 86.37 7.000 975.3 883.6 178.3 Pass 10736.4 8940.7 10600.0 8970.4 137.6 154.3 21.07 91.93 7.000 1007.6 891.4 239.2 Pass Rule Assigned: Major Risk Inter-Site Error: 0.0 ft ::No. O0." :'~mowab~:: :::::.':"~, ,.:ii: Sperry-Sun Anticollision Report Cemlma~. BP Amoco Refermee Site: PB B Pad Refermce Well: B-05 Reference Weillmth: Plan B-05~ ~ Ref~-em~ Well: B-05, True Norlh Vertical ('/'VD) R~'emam: 9ES RKB O 70.52. 70.5 Db: Oracle Site: PB B Pad WeU: B-04 Rule Assigned: Major Risk Wellpath: ~ V1 Inter-Site Error: 0.0 Warning 10750.0 8947.1 10700.0 9055.8 138.0 156.1 25.66 97.35 7.000 1049.8 899.5 303.8 Pass 10750.0 8947.1 10800.0 9142.1 138.0 156.4 30.27 101.96 7.000 1099.4 906.4 388.7 Pass 10750.0 8947.1 10900.0 9229.1 138.0 150.6 34.46 106.15 7.000 1155.4 913.3 480.3 Pass 10750.0 8947.1 11000.0 9316.1 138.0 162.9 38.24 109.93 7.000 1217.1 920.4 577.3 Pass 10750.0 8947.1 11100.0 9403.2 138.0 165.0 41.64 113.33 7.000 1283.6 927.1 677.6 Pass 10750.0 8947.1 11109.9 9411.8 138.0 165.3 41.96 113.65 7.000 1290.4 927.8 687.7 Pass Site: PB B Pad Well: B-05 Rule Assigned: NOERRORS Wellpath: B-05 V4 Inter-Site Error: 0.0 ft ft '. fi ;i:i'"' 'ft ft ',. ft;,,': ,:":'ft · ,cleg :., . in .': '.. ff ft ' ,"i, ""' :i. 7300.0 6028.4 7300.0 6027.1 0.0 159.0 15.28 296.06 3.9 FAIL 7398.0 6099.1 7400.0 6089.4 0.1 163.6 83.24 13.68 15.4 No Reference Casings 7488.9 6171.3 7500.0 6151.4 0.0 168.5 96.98 39.09 45.2 No Reference Casings 7569.0 6238.9 7600.0 6212.6 -0.4 168.3 100.03 55.20 90.0 No Reference Casings 7638.0 6298.8 7700.0 6274.0 -0.8 169.5 100.72 69.20 145.8 No Reference Casings 7700.0 6353.4 7800.0 6336.5 -1.4 170.2 100.68 82.18 209.5 No Reference Casings 7750.0 6397.5 7900.0 6400.4 -2.0 171.0 100.73 92.78 279.3 No Reference Casings 7807.7 6448.2 8000.0 6465.0 -2.1 174.7 101.47 95.72 353.1 No Reference Casings 7874.8 6507.1 8100.0 6529.9 -2.0 179.2 102.15 96.41 427.1 No Reference casings 7941.8 6565.9 8200.0 6595.0 -2.0 163.7 102.71 96.96 501.1 No Reference Casings 8008.6 6624.6 8300.0 6660.2 -1.9 188.3 103.18 97.43 575.4 No Reference Casings 8075.5 6683.2 8400.0 6725.8 -1.8 192.8 103.60 97.85 649.6 No Reference casings 8142.4 6742.0 8500.0 6791.6 -1.7 197.3 103.98 98.23 723.8 No Reference Casings 8208.2 6799.7 8600.0 6858.2 -1.6 201.7 104.53 98.78 798.7 No Reference Casings 8273.9 6857.4 8700.0 6926.5 -1.5 205.9 105.25 99.50 873.4 No Reference Casings 8339.9 6915.3 8800.0 6996.6 -1.3 209.9 106.06 100.32 947.4 No Reference Casings 8404.8 6972.3 8900.0 7067.1 -1.2 213.8 106.91 101.16 1022.1 No Reference Casings 6470.0 7029.6 9000.0 7138.0 -1.0 217.7 107.65 101.91 1096.6 No Reference Casings 8535.9 7087.3 9100.0 7209.5 -0.9 221.6 108.33 102.56 1170.7 No Reference Casings 8602.0 7145.4 9200.0 7281.6 -0.7 225.4 108.95 103.21 1244.5 No Reference Casings 8668.5 7203.7 9300.0 7354.7 -0.5 229.1 109.57 103.83 1317.9 No Reference Casings Site: PB B Pad Well: B-05 Rule Assigned: NOERRORS Wellpath: B-05A V2 Inter-Site Error: 0.0 ft '' ':Refereace, '" ,':. '"?': '!],: :iOi'fset:i':': :::': ~r~or: A;Ids :::,i:i: .: ] ' :/i'' ': .'?Ctr~::;,:N°-O0 i ],~ble,',,: :' ,:ili:',':: ..; :::]' "', ':' lea) '... .' x',m ':: :.~v '..':.,rw" :?...'R~..?:'?:.. ::.OUsa: 'r~-o+i~ "n~-o. as' csdng'..~"!: ~' :.Xr~ :..m~iaao.::..i;]~: ;W,.r"l~?: : , ,ft :: , .:'~:; fi" ,! ff '::. ~'.::: ft':'? :-: :ff':'":: :' deg ' '. :deg .: in ]': ,::::,;: ;'/ff :;,:i'. "ft" : :',:: .'*;.': ::' i:. 7300.0 6028.4 7300.0 6027.1 0.0 159.0 15.28 296.06 3.9 FAIL 7398.0 6099.1 7400.0 6089.4 0.1 163.6 83.24 13.68 15.4 No Reference Casings 7488.9 6171.3 7500.0 6151.4 0.0 168.5 96.98 39.09 45.2 No Reference Casings 7569.0 6238.9 7600.0 6212.6 -0.4 168.3 100.03 55.20 90.0 No Reference Casings 7638.0 6298.8 7700.0 6274.0 -0.8 169.5 100.72 69.20 145.8 No Reference Casings 7700.0 6353.4 7800.0 6336.5 -1.4 170.2 100.68 82.18 209.5 No Reference Casings 7750.0 6397.5 7900.0 6400.4 -2.0 171.0 100.73 92.78 279.3 No Reference Casings 7807.7 6448.2 8680.0 6465.0 -2.1 174.7 101.47 95.72 353.1 No Reference Casings 7874.8 6507.1 8100.0 6529.9 -2.0 179.2 102.15 96.41 427.1 No Reference Casings 7941.8 6565.9 8200.0 6595.0 -2.0 163.7 102.71 96.96 501.1 No Reference Casings 8008.6 6624.6 8300.0 6660.2 -1.9 168.3 103.18 97.43 575.4 No Reference Casings Sperry-Sun Anticollision Report ~ BP Amoco Reference Site: lab El Pad Refereme Well: B-05 Refereace Wdlpath: Plan B-05B ~ Reforeace: Well: B-05, True North ¥ortical (Tt/D) Retemaee: 9ES RKB O 70.52 70.5 Db: Oracle Site: PB B Pad Well: B-05 Wellpath: B-O5A V2 Rule Assigned: NOERRORS Inter-Site Error: 0.0 ft Referem~ Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD · TVD' Ref Offset TFO~AZI TFO-U,q Casing. Distance Area Deviation Warning ft ft ft ft tt ft deg deg in ft ft ft 8075.5 6683.2 8400.0 6725.8 -1.8 192.8 103.60 97.85 8142.4 6742.0 8500.0 6791.6 -1.7 197.3 103.98 98.23 8208.2 6799.7 8600.0 6858.2 -1.6 201.7 104.53 98.78 8273.9 6857.4 8700.0 6926.5 -1.5 205.9 105.25 99.50 8339.9 6915.3 8800.0 6996.6 -1.3 209.9 106.06 100.32 8404.8 6972.3 8900.0 7067.1 -1.2 213.8 106.91 101.16 8470.0 7029.6 9000.0 7138.0 -1.0 217.7 107.65 101.91 8535.9 7087.3 9100.0 7209.5 -0.9 221.6 108.33 102.58 8602.0 7145.4 9200.0 7281.6 -0.7 225.4 108.95 103.21 8668.5 7203.7 9300.0 7354.7 -0.5 229.1 109.57 103.83 649.6 No Reference Casings 723.8 No Reference Casings 798.7 No Reference Casings 873.4 No Reference Casings 947.4 No Reference Casings 1022.1 No Reference Casings 1096.6 No Reference Casings 1170.7 No Reference Casings 1244.5 No Reference Casings 1317.9 No Reference Casings Site: PB B Pad Well: B-07 Weilpath: B-07 Vl Rule Assigned: Major Risk Inter-Site Error: 0.0 ft ff . .ff..:,..ff ,. ..ft,, deg .deg. in., ff ff , , . ,.' . ,. 7215.5 5974.5 7000.0 5771.7 154.0 142.8 4.16 283.59 7384.9 6089.1 7100.0 5838.3 164.6 151.0 0.86 289.85 7786.2 6429.3 7200.0 5904.9 138.2 143.4 353.55 347.81 7867.7 6500.9 7300.0 5972.6 138.2 147.5 358.52 350.77 7951.1 6574.1 7400.0 6041.2 138.2 151.5 359.34 353.60 8034.7 6647.5 7500.0 6109.8 138.3 155.6 2.13 358.38 8118.6 6721.0 7600.0 6178.7 138.3 159.7 4.87 359.13 8202.7 6794.9 7700.0 6248.1 138.3 163.8 7.55 1.81 8286.9 6868.8 7800.0 6317.7 138.3 167.8 10.18 4.43 8371.3 6942.9 7900.0 6387.6 138.3 171.9 12.74 6.99 8455.7 7017.0 8000.0 6457.9 138.3 175.9 15.24 9.49 8540.1 7091.0 8100.0 6528.2 138.3 180.0 17.68 11.93 8624.2 7164.9 8200.0 6598.1 138.3 164.2 20.05 14.30 8708.1 7238.6 8300.0 6667.6 138.3 188.4 22.35 16.60 8791.9 7312.0 8400.0 6736.8 138.3 192.7 24.57 18.82 8875.3 7385.3 8500.0 6805.6 138.3 197.1 26.71 20.97 8958.4 7458.2 8600.0 6874.1 138.3 201.5 28.78 23.03 9041.2 7530.9 8700.0 6942.1 138.4 206.1 30.77 25.02 1100.0 919.5 232.8 Pass 1121.3 947.1 233.1 Pass 1119.8 873.7 284.6 Pass 1117.1 885.8 284.8 Pass 1119.2 897.7 292.4 Pass 1124.5 909.6 305.5 Pass 1132.2 921.5 323.3 Pass 1142.0 933.4 345.4 Pass 1153.9 945.2 371.7 Pass 1167.7 957.0 401.5 Pass 1183.2 968.8 434.7 Pass 1200.9 980.8 471.4 Pass 1220.9 992.9 511.6 Pass 1243.6 1005.3 555.4 Pass 1268.6 1017.9 602.2 Pass 1295.7 1030.6 651.7 Pass 1324.9 1043.6 703.7 Pass 1356.3 1056.8 758.1 Pass Site: PB B Pad Well: B-16 Wellpath: B-16 Vl Rule Assigned: Major Risk Inter-Site Error: 0.0 ft 7810.9 6451.0 7600.0 6869.7 138.2 96.7 224.56 218.81 7.000 1121.6 739.7 744.5 Pass 7889.8 6520.3 7700.0 6945.8 138.2 99.9 221.66 215.91 7.000 1096.8 749.2 685.8 Pass 7969.4 6590.1 7800.0 7022.7 138.2 103.1 218.67 212.92 7.000 1075.7 758.6 629.9 Pass 8049.5 6660.4 7900.0 7100.3 138.3 106.2 215.59 209.84 7.000 1058.5 767.9 577.0 Pass 8130.3 6731.3 8000.0 7178.6 138.3 109.2 212.45 206.71 7.000 1045.3 777.0 528.1 Pass 8211.7 6802.8 8100.0 7257.8 138.3 112.2 209.30 203.56 7.000 1036.0 785.9 483.6 Pass 8293.9 6875.0 8200.0 7338.1 138.3 115.1 208.16 200.41 7.000 1031.4 794.5 444.6 Pass 8376.9 6947.8 8300.0 7419.4 138.3 118.0 203.08 197.31 7.000 1031.1 802.9 411.4 Pass 8460.7 7021.3 8400.0 7501.8 138.3 120.7 200.03 194.29 7.000 1035.0 811.0 384.1 Pass 8544.8 7095.2 8500.0 7584.9 138.3 123.4 197.08 191.34 7.000 1042.5 819.0 382.0 Pass RECEIVED APR 2 3 2001 Drill-Out Steerable Ream While Drilling Ream While Hughes Christensen has a fleet of Ream While Drilling tools that enables you to drill and ream in one continuous operation. The DOSRWD tool is one part of a comprehensive system designed for hole opening applications. RWD tools drill at a fraction of the costs and none of the risks/limitations associated with bi-center bits and conventional underreamers. Drill Out , ...... ',,,,',.,.:~.;tCa:~ _ With the introduction of the Drill Out Steerable Ream While Drilling (DOSRWD) tool, operators no longer need to plan for a drillout trip prior to undertaking a reaming operation. DOSRWD technology allows operators to drill out the cement plugs, float equipment and complete the formation interval in one continuous operation. New technology like a Pass Through Bearing Surface with Guardian Inserts has eliminated earlier concerns of damaged casing and cutters when rotating inside casing. Steerable The DOSRWD is a second-generation steerable RWD tool. its two-piece design .is uniquely engineered to run on steerable systems, comprising either a rotary or motor BHA. Field tests have validated the DOSRWD's ability to achieve the same high build rates as conventional Tricone or PDC bits in directional well paths requiring hole enlargement, while allowing for drill-out with PDC or Tricone pilot. Kill BAKER HUGHES Hughes Christensen Z00~ NOI&V}lOqdY~l (Iq ¢)1~01~ fgt~ /,06 X;V~I 2,0:9'[ '[00Z/f~/t~0 RECEIVED APR 2 5 2001 Alaska 0il & Anchoran.~ 7" DOSRWD46.000 n [ -- In Il I I I I _ Ream While Drilling I I II HOLE OPENING BLADE- The blade design creates a smooth transition from pass through size to drill size, enabling the RWD to stabilize. · PILOT STABILIZATION PAD -- A unique gauge pad ensures the reamer wing is centralized to drill a full-sized hole. DEPTH ADJUSTED CU'FI'ERS -- This cutter arrangement varies the height of each cutter to ensure all cutters are evenly loaded and wear evenly. · INTERCHANGEABLE NOZZLES- Nozzles are placed to maximize cleaning and minimize hole erosion. · BLACK ICE POLISHED CUTrERS-- Highly polished ~utter surfaces reduce shear forces, significantly improving cuttings removal, ROP and drilling efficiency. · STRESS ENGINEERED CUTTERS/ENGINEERED CUTi'ER PLACEMENT ~ Strategically positioned and durable, fracture resistant cutters promote longer bit life for the full spectrum of formations, including the harder sections. · GUARDIAN BEARING SURFACES -- [t · Guardian Ovoids · Guarding Inserts · Trailing Guardian Ovoids PRODUCT spECIFICATIONS.· Number of Blades: 4 Number of Nozzles 2 Total Number of Cutters 16 1/2" (13mm) Back Rake: (Fa(e/Gauge) 20° / 20 Guardian Ovoids 2 Guardian Inserts 4 Gauge Length 2.0" PDC Junk Slot Aree/Ratio 16.89 ir~ / 0.44 Face Volume/Ratio 31.39 ir~ / 0.41 Overall Length: 19.62 / 498.3 Length Shoulder to Shoulder 16.05 / 407.6 APl Connection Type / Size Up Pin 3 1/2' APl Rag APl Connection Type / Size Down Box 2 7/8" APl Rag ECCENTRIC GEOMETRY Pass Through 6.00'r Drill Size 7.00" Pilot Bit Size 4.75" RECOMMENDED OPERATING PARAMETERS: * Total Flow Rate; 250- 400 Gpm (950- 1500 Ipm) Rotation Speed: .100 - 350 Rpm Weight on Bit: 3000 - 5000 Lbs (13.3 - 22.2 kN) Maximum Weighf on Bit: , , 8000 Lbs (35.6 kN) II Reference Part Number:. W0522 October 2000 Hughes Christensen ©2000 Hughes Chris~easea Company. Hughes, Chtiste~sea, ~ ~ emblem, thu Cl~=u ~anoad emblem. Blue Di~ond, Bi~ET~ S~mm. Bilk Ico, C~pM~c, STA~ ~ GT~ Surf ~p, ~, Tdc~=, B~t, ~r~ ~d Hyd~ ~ mgis~md ~dem~s of B~ter Hugh~ l~o~omtcd. H~dRok] High Flow, BOSS, CSEs SEC, ECP.CIe~ Sweep~ ~cePak, KWD, SRWD~ S~WD, DOS~WD ~d Dum~t ~ ~demacks orche company. ' The ranges o~,bit we~ht and RPM sho~ am represen~flve of typl~l ope~tlng pammetem, but will not he--sadly yield optimum b~ li~ or lowest drilling ~ Is n~ recommended that the upper lim~s ~b~h weight and RPM be mn slmu~aneously, con~ your Io~1 Hughes representative for secommendafions in your area gOO ~ NOI3'NHO"Id'~:,! dq OJ'Ot H 184352 t VEN~R ALASKAOILA OD DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 012~01 CKO12~O1M 100.00 100. O0 PYMT (;OMMENTS: Pe~it To D~ill --ee HANDL'.[NO INST: S/H- Te~'~'i Hubb le X4628 THE ATTACHED CHECK IS IN PA¥i~T FOR ;;~ DESC~;.,,.~ ABOVE. --~[I]lf-~llE ] 1 OO. OO 1 O0. OO ,::'BP.EXPLORATION (ALASKA).,JNC., ... '~i. ST':~AT'O~A,:"^.K,O~ ^S"~'~ND 'i"~:i5.O,";~.~:. 191~6'12 i:?:'",,. :"'?(.: ":iii:::.:. ,!"~: :i'.:..,:', .. . ..... :!!:?:."i :,,,.:.' NA'tlONA~'Crr'Y,:BJ~hK ...... ' "' ' ,. ':,.ANCHORAGEi~iALASt~A''' 99519-6612 ~',',:.::' '":':¥" .... : · , .:' .;':" .' i:." :... 'i: ::i:';"; !',;!:i ,:.,;':.!;:' .... .'::ii' :~':~389 :'::' 'i:,,' .... "'"' .... ':!:.: u,..: .... ;" '"' ::::' '""' 4'"'--~' "' '; PAY .TO T,h.e.:~ ORDER ...... ' .... ! NO'If:VALID AFTER~~~!t120 DAYS ........ .., .....,.. :i .;' . i::,. ".:i'. .... .:.ALAS!~A OIL AND~..:.~OAS"::..:::.:.:.:. i:::CoNs~RVAT I ON? C:,~M~[i'sS.I oN ::i ? ~'':~:'' ;:~ ~:.' !ii:i; ~;..~:?....,...~...:::::~ ..... ..~i?. ;: ::::..::: ?.:: .i '...::~".'....::?'..:: '.,:i~ : ::::~:: : ':.: ..:.' q:.. ..s .... ;::, ~ ,~ : :~:~:..:..,,.:, . ;,': .~ '.: , ::: .... ::,'.. '~:,':333:: '~.E5T 7TH '"~:~ENUE:?' ~U I ~'~ ~:',"1 oo ';?:~,...~': ..... · ..... ..~ ' "".'~' '~?,~::::.~':::/ ::~(:~]'~: :[;".~:'.i;}l :,:'% ' .,.,:,;:::.?? ANCHORAGE AK 99501 I1' &Rm.,=~5 BIIm m-'Om., & BO:J,o,q Sm: 00,°,1.,I., ~.~11, WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ ~ 43/.5" ~ INIT CLASS /~z.- /- o,~"',/ WELL NAME ,~" ]-r ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. 13. ENGINEERING GEOLOGY APPR Permit can.be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long stdng to surf csg ........ 18. CMT will cover all known productive hodzons ..... ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ....... ; ..... 23. If diverter required, does it meet regulations .......... 24. Ddlling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ..... ~...._...... 26. BOPE press rating appropriate; test to ..~_..~(~) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ......... 28. Work will occur without operation shutdown ........ . . . 29. Is presence of H2S gas probable ................. 30. 31. 32. 33. 34. ANNULAR DISPOSAL35. APPR DATE PROGRAM: exp GEOL AREA dev ~ redrll "~ serv. (~ ~, UNIT# · N Y N Y N Y N Y N Y N Y N. Y N Y N '- Y N Y N Y N N Y Y (~N N · N N wellbore seg ann. disposal para req ON/OFF SHORE Permit can be issued wlo hydrogen sulfide measures ...... Y N ./"' Data presented on potential overpressure zones ....... Y y ~ /~ Seismic analysis of shallow gas zones... .......... .,Y/N ,,~/.,,"x ~, Seabed condition survey (if off-shore) ............. /'Y N - - " Contact name/phone for weekly progress reports [exploratory o~1~] Y N With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N (B) will not contaminate freShwater; or cause ddlling waste... Y N to surface; ' (C) will not impair mechanical integrity of the well used for disposal; Y' N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: ' UICl~_~nular COMMISSION: ~,..%~ ',~ :: WM '""',-~ Comments/Instructions: 1::7 O Z O c:Vnsoffice\wordian~diana\checklist (rev. 11101//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this .nature is accumulated at the end of the file under APPE .N. DIXi No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Oct 05 16:36:12 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/10/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10151 A. WEAVER B. DECKER B-05B 500292027602 BP Alaska Drilling & Wells Sperry Sun 05-OCT-01 MWD RUN 2 AK-MM-10151 A. WEAVER D. WILLIAMS MWD RUN 4 AK-MM-10151 R. MCNEILL T. ANGLEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 5 AK-MM-10151 R. MCNEILL T. ANGLEN MWD RUN 6 AK-MM-10151 R. MCNEILL T. ANGLEN 31 lin 14E 855 1600 ELEVATION (FT FROM MSL 0 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 71.50 43.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (ET) 4.750 5.500 10088.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-2 AND 4-6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. MWD RUN 3 TOOLSTRING WAS DROPPED WHILE TRIPPING IN HOLE, THEREFORE RUN 3 IS NOT PRESENTED. 4. DIGITAL DATA ONLY IS SHIFTED TO THE GAMMA RAY LOG OF DATE PER THE E-MAIL OF 7/17/2001 FROM D. SCHNOOR OF BP EXPLORATION (ALASKA) INC. LOG AND HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 5. MWD RUNS 1-2 AND 4-6 REPRESENT THE MWD DATA FOR WELL B-05B WITH API% 50-029-20276-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11962' MD, 9009' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 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 7233 5 11912 5 FET 7239 5 11923 5 RPD 7239 5 11923 5 RPM 7239 5 11923 5 RPS 7239 5 11923 5 RPX 7239 5 11923 5 ROP 7262 0 11962 5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 7233 5 7238 7268 7276 7284 7325 7350 7352 7439 7465 7472 7513 7526 7547 7563 7640 7759 7818 7906 7922 7932 8002 8160 8228 8264 8301 8332 8349 8380 8413 8422 8430 8449 8485 8488 8512 8559 8583 8609 GR 7244 5 7250 0 7279 5 7287 0 7295 5 7337 0 7361 5 7363 5 7449 5 7477 5 7484 0 7524 0 7537 5 7558 5 7574 5 7651 0 7771 0 7829 5 7917 5 7932 0 7941 0 8011 0 8171 5 8239 5 8275 0 8311 5 8343 5 8359 5 8391 0 8423 0 8431 5 8439 0 8459 5 8494 5 8497 5 8522 0 8567 5 8592 0 8619 0 EQUIVALENT UNSHIFTED DEPTH 8640 0 8645 0 8667 5 8781 5 8802 5 8844 5 8960 0 8986 5 9048 5 9100 5 9104 0 9123.0 9129.0 9150.5 9167.0 9212 0 9229 5 9255 5 9263 0 9279 5 9298 5 9349 0 9378 0 9412 0 9426 5 9456 5 9501 5 9527 0 9542 5 9561 0 9584 5 9630 5 9706 0 9783 5 9838 5 9898 0 10007 5 10081.5 10092 5 10112 0 10127 5 10134 0 10159 0 10187 5 10196 5 10219 5 10248 0 10259 0 10294 0 10380 0 10394 0 10431 5 10452 0 10485 5 10494 5 10592 5 10680 0 10725 5 10793 0 10807.5 10845.0 8649 8653 8676 8789 8810 8853 8968 8994 9056 9107 9111 9129 9135 9157 9174 9218 9236 9262 9270 9286 9306 9356 9385 9418 9432 9463 9507 9532 9549 9566 9590 9635 9710 9787 9842 9902 10012 10086 10098 10119 10135 10140 10167 10197 10206 10229 10256 10265 10301 10389 10402 10438 10457 10494 10501 10601 10688 10733 10800 10816 10853 0 0 0 5 5 0 .0 5 5 0 0 5 5 0 0 5 0 5 0 0 0 5 0 5 5 0 0 5 5 0 0 5 5 0 5 0 5 0 5 5 0 0 5 5 0 5 5 5 0 0 5 5 5 0 5 0 5 0 5 5 0 10868 5 10922 5 10995 0 11015 0 11133 5 11203 5 11257 5 11285 5 11300 0 11384 0 11461 0 11485 0 11502 0 11555 0 11627 0 11708 0 11720.5 11775.0 11802.5 11873.0 11894.0 11912.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: 10876.5 10931.0 11002.5 11022.5 11141.0 11209 0 11262 5 11290 0 11306 5 11392 0 11470 5 11493 5 11510 0 11563 0 11633 0 11711 5 11723 5 11775 5 11803 5 11875 0 11896 5 11915 0 BIT RUN NO MERGE TOP MERGE BASE 1 7244.5 10104.0 2 10041.0 10402.0 4 10353.0 11130.0 5 11078.0 11618.0 6 11566.0 11965.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 First Last Name Service Unit Min Max DEPT FT 7233.5 11962.5 ROP MWD FT/H -2.58 358.58 GR MWD API 12.84 448.19 RPX MWD OHMM 0.66 1695.47 RPS MWD OHMM 0.47 2000 RPM MWD OHMM 0.16 2000 RPD MWD OHMM 0.13 2000 FET MWD HOUR 0.6755 107.29 Mean Nsam 9598 9459 42.1505 9402 102.817 9359 13.3128 9369 25.8297 9369 29.4163 9369 28.3356 9369 4.88837 9369 Reading 7233.5 7262 7233.5 7239.5 7239.5 7239.5 7239.5 7239.5 Readin¢ 11962 11962 11912 11923 11923 11923 11923 11923 First Reading For Entire File .......... 7233.5 Last Reading For Entire File ........... 11962.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 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 GR RPM RPS RPD FET RPX ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 7244.5 7251 5 7251 5 7251 5 7251 5 7251 5 7273 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 10040.5 10047 0 10047 0 10047 0 10047 0 10047 0 10104 0 17-MAY-01 Insite 66.16 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type'. ................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Memory 10104.0 25.1 51.4 TOOL NUMBER 1961/2019HA 1961/2019HA 7.000 LSND 9.80 49.0 9.3 6OO 3.4 1.500 .730 1.200 1.800 70.0 151.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 RPD MWD010 FET MWD010 OHMM 4 1 68 OHMM 4 1 68 HOUR 4 1 68 20 24 28 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HOUR Min Max 7244.5 10104 -2.58 99.94 26.85 429.22 0.66 1511.22 0.64 1243.3 0.2 2000 0.13 2000 0.735 29.4039 Mean Nsam 8674.25 5720 42.1023 5663 133.226 5593 2.90857 5592 2.99094 5592 16.3014 5592 11.69 5592 2.83095 5592 First Reading 7244.5 7273 7244.5 7251.5 7251.5 7251.5 7251.5 7251.5 Last Reading 10104 10104 10040.5 10047 10047 10047 10047 10047 First Reading For Entire File .......... 7244.5 Last Reading For Entire File ........... 10104 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10041.0 RPX 10047.5 RPM 10051.5 RPS 10051.5 FET 10051.5 RPD 10051.5 ROP 10104.5 STOP DEPTH 10352 5 10363 5 10363 5 10363 5 10363 5 10363 5 10402 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION /DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT'MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ' 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 22-MAY-01 Insite 0.43 Memory 10402.0 27.5 40.5 TOOL NUMBER PBO1977RF3 PBO1977RF3 4.750 Quickdril-N 8.40 86.0 9.2 5OO 10.0 3.50O 1.450 4.000 2.800 66.0 168.8 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min Max Mean Nsam 10041 10402 10221.5 723 6.77 188.56 46.1436 596 18.78 448.19 86.02 624 0.69 1695.47 64.4638 633 0.69 2000 230.913 625 0.16 2000 138.729 625 0.3 2000 141.763 625 0.867 107.29 20.9441 625 First Reading 10041 10104.5 10041 10047.5 10051.5 10051.5 10051.5 10051.5 Last Reading 10402 10402 10352 5 10363 5 10363 5 10363 5 10363 5 10363 5 First Reading For Entire File .......... 10041 Last Reading For Entire File ........... 10402 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 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 ....... 01/10/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10353.0 FET 10360 5 RPD 10360 5 R?M 10360 5 RPS 10360 5 RPX 10364 0 ROP 10402 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 11077 5 11088 5 11088 5 11088 5 11088 5 11088 5 11130 0 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 25-MAY-01 Insite 0.43 Memory 11130.0 40.9 85.7 TOOL NUMBER PBO2016RF3 PBO2016RF3 4.750 Quickdril-N 8.40 42.0 9.5 5OO 10.0 3.500 1.410 4.000 4.100 65.0 172.0 65.0 65.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD040 FT/H 4 1 68 MWD040 API 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 10353 11130 ROP MWD040 FT/H 8.24 265.7 GR MWD040 API 12.84 143.79 RPX MWD040 OHMM 6.7 94.04 RPS MWD040 OHMM 8.12 117.2 RPM MWD040 OHMM 8.91 132.81 RPD MWD040 OHMM 11.4 173.41 FET MWD040 HOUR 0.822 60.3486 Mean 10741.5 50 2455 30 5746 29 3985 36 4618 41 9085 46 3885 4.91036 Nsam 1555 1456 1450 1450 1457 1457 1457 1457 First Reading 10353 10402.5 10353 10364 10360.5 10360.5 10360.5 10360.5 Last Reading 11130 11130 11077 5 11088 5 11088 5 11088 5 11088 5 11088 5 First Reading For Entire File .......... 10353 Last Reading For Entire File ........... 11130 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 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 ....... 01/10/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 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 GR RPM RPS RPD FET RPX ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 11078.0 11088 0 11088 0 11088 0 11088 0 11089 0 11130 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11565 5 11576 5 11576 5 11576 5 11576 5 11576 5 11618 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 28-MAY-01 Insite 0.43 Memory 11618.0 84.2 93.6 TOOL NUMBER PBO1992RF3 PBO1992RF3 4.750 Quickdril-N 8.40 43.0 9.3 500 9.6 3.400 1.560 4.000 3.500 68.0 156.6 68.0 68.0 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 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HOUR Min Max 11078 11618 3.79 358.58 14.61 173.3 5.85 35.6 6.25 62.49 7.15 142.36 8.53 64.7 0.6755 37.5991 Mean Nsam 11348 1081 37 9767 71 5436 15 3283 17 1369 20 1135 18 7913 5.44422 976 976 976 978 978 978 978 First Reading 11078 11130.5 11078 11089 11088 11088 11088 11088 LaSt Reading 11618 11618 11565 5 11576 5 11576 5 11576 5 11576 5 11576 5 First Reading For Entire File .......... 11078 Last Reading For Entire File ........... 11618 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 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 ....... 01/10/05 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: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPX RPD RPM RPS FET ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 11566.0 11577 0 11578 0 11578 0 11578 0 11578 0 11618 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11915.0 11926.0 11926.0 11926.0 11926.0 11926.0 11965.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 30-MAY-01 Insite 0.43 Memory 11965.0 91.8 97.2 TOOL NUMBER PBO1992RF3 PBO1992RF3 4.750 Quickdril-N 8.40 42.0 9.1 5O0 9.6 2.700 1.070 3.500 3.000 70.0 187.3 70.0 70.0 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD060 FT/H 4 1 68 GR MWD060 API 4 1 68 RPX MWD060 OHMM 4 1 68 RPS MWD060 OHMM 4 1 68 RPM MWD060 OHMM 4 1 68 RPD MWD060 OHMM 4 1 68 FET MWD060 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 11566 11965 ROP MWD060 FT/H 3.33 81.35 GR MWD060 API 16.65 157.72 RPX MWD060 OHMM 5.12 32.4 RPS MWD060 OHMM 5.52 39.66 RPM MWD060 OHMM 6.09 55.54 RPD MWD060 OHMM 9.23 67.55 FET MWD060 HOUR 1.1428 32.3024 Mean Nsam 11765.5 799 28.4235 694 67.242 699 14.3409 699 16.1098 697 19.1345 697 21.3171 697 6.77081 697 First Reading 11566 11618.5 11566 11577 11578 11578 11578 11578 Last Reading 11965 11965 11915 11926 11926 11926 11926 11926 First Reading For Entire File .......... 11566 Last Reading For Entire File ........... 11965 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/10/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File