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203-112
• STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 14 2015 WELL COMPLETION OR RECOMPLETION REPORT AND LO9.)GCC la. Well Status: ❑Oil ❑Gas ❑SPLUG 0 Other• ®Abandoned 0 Suspended 1 b. Well Class 20AAC 25.105 2OAAC 25.110 0 Exploratory ❑Stratigraphic ID GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No. of Completions Zero - ® Development 0 Service 2. Operator Name: 5. Date Comp., Susp.,,`r Aband : 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 4/1615 y../'/5 203-112 - 315-119 3. Address: 6. Date Spudded: ft .7 /S 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 10/28/2003 50-029-21809-02-00 - 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 10/31/2003 PBU 07-33B - 1068' FNL, 522' FWL, Sec. 34, T11N, R14E, UM - 8. KB(ft above MSL): 60' - 15. Field/Pool(s) Top of Productive Horizon: 2173' FSL, 5227' FWL, Sec. 27,T11N, R14E, UM GL(ft above MSL): 27.8' - Prudhoe Bay Field/Prudhoe Bay Total Depth: 9. Plug Back Depth(MD+TVD) Oil Pool 2890' FSL,4008' FWL, Sec. 27,T11N, R14E, UM - 10596' 8568'- 4b. Location of Well(State Base Plane Coordinates, NAD. 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 676720 ' y- 5949869 . Zone- ASP4 .12585' 8954' • ADL 028309 - TPI: x- 681341 y- 5953221 Zone- ASP4 11. SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 680104 y- 5953909 Zone- ASP4 None 18. Directional Survey: ❑Yes ® No 19.Water depth, if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: CCL, GR, Memory CNL, MWD, GR - 10800' 8738' . 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" 91.5# H-40 34' 114' 34' 114' 30" 2150#Poleset 13-3/8" 68#/72# K-55/L-80 34' 3365' 34' 3047' 17-1/2" 2000 sx CS III, 200 sx CS I, 600 sx Class'G' 9-5/8" 47# L-80 30' 10413' 30' 8415' 12-1/4" 629 sx Class'G', 400 sx CS I 7" 29# L-80 10166' 10770' 8211' 8713' 8-1/2" 450 sx Class'G' 3-1/2"x3-3/16" 9.3#/6.2# L-80 10080' 10800' 8140' 8738' 3-3/4" 140 sx LARC 2-3/8" 4.6# L-80 10688' 12576' 8645' 8954' 3" 59 sx Class'G' 24. Open to production or injection? ❑Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom; Perforation Size and Number): 4-1/2" 12 6#.13C80 x 5-1/2' 17#,L-80 10254' 9944'/8028' x 4-1/2".12.6# L-80 10135'/8185' h.`) 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. SCANNED SEP 0 9 2015WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes Z No ��'�� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 113e'' Y _ 10596' Set Whipstock / 3./� : q 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 4 - Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ® No . Sidewall Core(s)Acquired? 0 Yes ® No - If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each), and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 10/2012 V TL 1/z,/a CONTINUED ON REVERSE ` Submit Original Only A 9S- ,_;-"") RBDMS.,!. MAY 1 5 2015A1-5q. :5-/r ✓CJ 29. GEOLOGIC MARKERS(List all formations a 3rkers encounter 30. FORMATION TESTS NAME uAD ND Well Tested? ❑Yes IS No • Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Zone 1B 11028' 8921' None Formation at Total Depth: 31.List of Attachment: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Zach Browning,564-5220 Email. Zachary.Browning@bp.com Printed Name: Tale Drilling Technologist Joe Lastufka Si nature: ♦ eL Phone 564-4091 Date: 51121155 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 10/2012 Submit Original Only 07-33B, Well History (Pre-Rig Sidetrack) 3/21/2015 (E-LINE PKR WHIPSTOCK-CTD PREP). SET TOP OF BAKER 3-3/16"PACKER WHIPSTOCK AT 10603' ORIENTED AT 180°. TWO RA TAGS INSTALLED 5.35'FROM TOP OF WHIPSTOCK PUTTING THEM @ 10608.35'. WELL SHUT IN UPON DEPARTURE- DSO NOTIFIED OF WELL STATUS FINAL T/►/O=0/400/0 PSI. 3/21/2015 Assist E-line load and test MIT-T to 3000psi PASSED, (PRE CTD)Pumped 12.8 bbls diesel down TBG to reach test pressure,TBG lost 70 psi in first 15 min. and 12 psi in second 15 min.for a total loss of 82 psi, Bled back+/- 3.5 bbls, Hung tags on MV and WV,SSV/SV/WV=closed, MV/IA/OA=open, FWHP=70/468/41. 4/5/2015 T/IU/O=250/450/0 Removed Tree Cap assembly&installed Test spool#1 Torqeud to spec.and PT to 300 psi- low&5000 psi-high(passed); Set 4"CIW TWC#292(set, Bled off&drifted tree good)Pulled TWC FWP= 250/450/0. 4/9/2015 T/I/O=SSV/510/30. Temp=SI. Bleed T&IA to 0 psi(Pre Rig). Well is demobed w/no WH. Unable to bleed TP due to no scaffolding around well. IA FL near surface. Bled IAP(BT)to 200 psi in 1 1/2 hrs(Gas/fluids,—2 bbls). Monitored 30 min. IAP increased 20 psi. Final WHPs=SSV/220/20. SV,WV,SSV=C. MV=O. IA, OA=OTG. NOVP. 17:00. 4/11/2015 T/I/O=180/240/20. Temp=SI. Bleed Tubing&IAP to 0 psi (Pre Rig). No wellhouse or flowline. Drilling scaffold on well. Tubing FL @ surface. IA FL @ 60'(4 bbls). Bled tubing pressure from 180 psi to 0 psi in 10 min to slop tank(0.5 bbls fluid/trace gas). Bled IAP from 240 psi to 95 psi in 1 hr 23 min to slop tank(gas/trace fluid). Monitored for 30 minutes. Tubing pressure increased 12 psi, IAP increased 20 psi&IA FL is near surface. Job incomplete. Final WHPs= 12/115/20. SV,WV=C. SSV, MV=O. IA&OA=OTG. 17:10. 4/11/2015 T/I/O=20/120/20. Temp=SI. Bleed WHP's to 0 psi(Pre CTD). No AL,wellhouse or flowline. Temporary scaffolding installed. Initial TBG FL=near surface. Initial IA FL=near surface. Initial OA FL=near surface. Bled the TP from 20 psi to 0 psi in—2 minutes(all gas). Bled the OAP from 20 psi to 0 psi in—10 minutes(all gas). Bled the IAP from 120 psi to 4 psi before midnight(2.5 hours, all gas). North America-ALASKA-BP Page 120,1_3, Operation Summary Report Common Well Name:07-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) 1 Start Date:4/12/2015 End Date: X3-016V7-C:(3,939,573.00) Project:Prudhoe Bay • Site:PB DS 07 Rig Name/No.:NORDIC 1 Spud Date/me:5/18/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292180900 Active datum:Kelly Bushing/Rotary Table©60.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) __ (usft) 4/12/2015 03:00 - 03:30 0.50 MOB P1 PRE HOLD PJSM FOR MOVING OFF WELL 03:30 - 04:00 0.50 MOB P PRE MOBILIZE RIG OFF WELLAND STAGE ON PAD -- 04:00 - 04:30 1 0.50 MOB P PRE ROUTE DRIVE WITH RIG MANAGER/DRILLER 04:30 - 09:00 4.50 MOB P PRE MOVE RIG FROM P PAD TO SPINE ROAD 09:00 - 14:00 5.00 MOB N RREP PRE TIRE BLOWOUT WHILE TURNING ONTO SPINE ROAD i '-LEVEL RIG AND REMOVE BAD TIRE -CALL FOR NEW TIRE&TIRE REPAIR TECH -RETRIEVE NEW TIRE FROM PERMAFROST PAD -INSTALL NEW TIRE ON RIG 14:00 - 18:00 4.00 MOB P I PRE MOVE RIG FROM N PAD ENTRANCE ONTO SPINE ROAD TO DRILLSITE 07. 18:00 - 18:30 0.50 MOB P PRE CREW CHANGE ON SPINE ROAD. 18:30 - 22:30 4.00 MOB P I PRE CONTINUE RIG MOVE TO DRILLSITE 07 22:30 - 23:30 1.00 MOB P PRE I ARRIVE ON DRILLSITE 07 '-SET T-MATS,CHECK TUBING/INNER ANNULUS/OUTER ANNULUS PRESSURES- _ALL ZERO PSI 23:30 - 00:00 0.50 MOB P PRE MOVE RIG OVER WELL. RIG ACCEPTED AT i 23:59. 4/13/2015 00:00 - 01:30 1.50 MOB P PRE SECURE CELLAR,INSTALL SSV AND ANNULUS JEWELRY GUARDS,SPOT CUTTINGS BOX. 01:30 - 02:00 0.50 MOB P PRE RIG UP IA AND OA TRANSDUCERS,CYCLE TREE VALVES,VERIFY ZERO PRESSURE ON TREE,RIG UP PRESSURE TRANSDUCER TO WING VALVE,PERFROM LEAK TIGHT TEST. 02:00 - 02:15 0.25 BOPSUR P PRE HOLD PJSM FOR NIPPLING DOWN TREE CAP AND NIPPLING UP BOPS. 02:15 - 02:45 0.50 BOPSUR P I PRE 'NIPPLE DOWN TREE CAP,BEGIN NIPPLING UP BOPS 'PROVIDE EMAIL UPDATE TO AOGCC FOR 0800 BOP TEST' 02:45 - 05:00 2.25 BOPSUR P PRE !NIPPLE UP BOPS,TAKE STACK _ MEASUREMENTS 05:00 - 05:15 0.25 BOPSUR P PRE HOLD PJSM FOR PULLING COIL ACROSS GOOSENECK. 05:15 - 06:15 1.00 BOPSUR P PRE STAB ON INJECTOR AND PULL COIL ACROSS GOOSENECK 06:15 - 07:00 0.75 BOPSUR P PRE CREW CHANGE 1 -INSPECT TOOLS&EQUIPMENT _ y_ 1 _ -HOLD PJSM FOR ONGOING OPERATIONS 07:00 - 09:00 2.00 BOPSUR P PRE PULL COIL ACROSS PIPE SHED TO INJECTOR PULL TEST GRAPPLE/RE-INSPECT(GOOD) ,-REMOVE SHIPPING BAR FROM REEL -PULL COIL ACROSS PIPE SHED/SECURE IN INJECTOR Printed 4/27/2015 12:57:51PM North America-ALASKA-BP Page 2 efed' Operation Summary Report Common Well Name:07-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/12/2015 End Date: X3-016W-C:(3,939,573.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:NORDIC 1 Spud Date/Time:5/18/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292180900 Active datum:Kelly Bushing/Rotary Table©60.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth li Phase Description of Operations (hr) (usft) - — 09:00 - 12:00 3.00 BOPSUR P PRE 'INSTALL SLB COIL CONNECTOR PULL TEST CONNECTION TO 36K -GET ONTO WELL WITH INJECTOR LOOSEN BOLTS TO STUFFING BOX. RAISE INJECTOR OFF STUFFING BOX -CHANGE BRASS&PACK-OFF -LOWER INJECTOR ONTO STUFFING BOX 12:00 - 12:30 0.50 BOPSUR P PRE "SHELL TEST BOPE 250/3500 12:30 - 19:00 6.50 BOPSUR P PRE PERFORMED PASSING SHELL TEST. PERFORM BOPE TEST STATE GIVEN NOTIFICATION OF BOPE TEST 04/12/2015 07:07 STATE INSPECTOR JEFF JONES WAIVED WITNESS 04/13/2015 PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,PTD#215-046,AND CRT-AK-10-45 -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST CHOKE VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES,BOP RAMS AND ANNULAR PREVENTER(2500 PSI) -ALL 2"PIPE RAMS TESTED WITH 2"TEST JOINT -2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT I-BLIND RAMS TESTED ON OPEN HOLE -ANNULAR TESTED WITH BOTH 2-3/8"AND 2" TEST JOINT -TEST FULL OPENING SAFETY VALVE -FUNCTION BOPE FROM BOTH REMOTE IPANELS -TEST GAS ALARMS -PERFORM DRAW DOWN TEST OF ACCUMULATOR 19:00 - 19:45 0.75 BOPSUR P PRE HOLD PJSM AND TEST CTD INNER REEL VALVE AND PACK-OFF TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES -RIG UP SCHLUMBERGER PUMP UNIT TO I TEST REEL HOUSE IRON TO 5000 PSI WHILE TESTING IRV/PACK-OFF RIG UP TEST PLATE ON END OF COIL -(CHECK TORQUE ON TREE BOLTS) 19:45 - 20:00 0.25 BOPSUR P PRE HOLD PJSM WITH NORDIC,SCHLUMBERGER AND BP FOR HIGH PRESSURE TESTING -VERIFY LINE-UP AND DISCUSS PRESSURE CROSSCHECK CARD 20:00 - 21:30 1.50 BOPSUR P PRE 'PRESSURE TEST REEL HOUSE IRON FROM STANDPIPE CONNECTION TO END OF COIL TO 250 PSI LOW/5000 PSI HIGH FOR 5 MINUTES;BLEED PRESSURE AND BLOW DOWN HARDLINE TO PUMP TRUCK 21:30 - 21:45 0.25 BOPSUR P PRE HOLD RIG EVACUATION DRILLAND TEST ESD 21:45 - 22:15 0.50 BOPSUR P PRE PUMP DOWN COIL FOR ELINE SLACK MANAGEMENT 22:15 - 23:15 1.00 BOPSUR P PRE PICKUP INJECTOR AND REHEAD ELINE Printed 4/27/2015 12:57:51 PM • North America-ALASKA-BP Page 313e6 Operation Summary Report Common Well Name:07-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/12/2015 End Date X3-016V7-C:(3,939,573.00) Project Prudhoe Bay Site:PB DS 07 Rig Name/No.:NORDIC 1 Spud Date/Time:5/18/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292180900 Active datum:Kelly Bushing/Rotary Table gp60.00usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) ,23:15 - 23:45 0.50 BOPSUR P PRE MAKE UP AND PRESSURE TEST NIGHT CAP TO 250 PSI LOW/3500 PSI HIGH FOR 5 (MINUTES 23:45 - 00:00 0.25 BOPSUR P PRE OPEN WELL TO CLOSED CHOKE;ZERO PRESSURE WELL TOOK NO FILL;FLOW CHECK FOR 10 MINUTES 4/14/2015 00:00 - 00:15 0.25 STWHIP P WEXIT I HOLD PJSM FOR MAKING UP MILLING ASSEMBLY AND INITIAL ENTRY INTO WELL 00:15 - 01:00 0.75 STWHIP P ( WEXIT MAKE UP WEATHERFORD MILLING • 'ASSEMBLY -GAUGE MILL AND REAMER 2.74 GO/2.73 NO-GO 01.00 01:15 0.25 1- STWHIP P WEXIT iSTAB ON INJECTOR AND PRESSURE TEST QTS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES 01:15 - 04:45 3.50 STWHIP P WEXIT RIH WITH MILLING ASSEMBLY -RIH AT 100 FPM,TAKING RETURNS TO FLOWBACK TANK IN/OUT RATE=1.50/1.84 BPM -IN/OUT DENSITY=8.33/8.33 PPG -TIE IN TO PDC LOG WITH(-8')CORRECTION • -TAG WHIPSTOCK AT 10,598';9.5 PPG POWERPRO-10 BBLS TO BIT 04.45 - 05.45 1.00 STWHIP P WEXIT SWAP WELL TO 9.5 PPG POWERPRO MUD AND CIRCULATE REMAINING WELLBORE FLUID TO FLOWBACK TANK 05:45 - 07:00 1.25 STWHIP P WEXIT CIRCULATE&CONDITION NEW MUD '-FILL PIT AFTER MUD SWAP -CREW CHANGE/INSPECT EQUIPMENT 07:00 - 18:00 11.00 STWHIP P WEXIT TIME MILL WINDOW F/10,596.2'-10,602.5' MM IN/OUT:1.64/1.64 CIRC PSI:3490-3800 FS:3300 01- C I MW IN/OUT:9.53 PPG/9.48 PPG !IA/OA/PVT:148/803/296 ANN PSI/ECD:4545-4554/10.38 WOB:0.2-2.4K CT WEIGHT:17,500 18:00 - 21:40 3.67 STWHIP P WEXIT TIME MILL WINDOW F/10,602.5'-10604.1' MM IN/OUT:1.64/1.64 CIRC PSI:3490-3800 FS:3300 MW IN/OUT:9.53 PPG/9.48 PPG IA/OA/PVT:148/803/296 ANN PSI/ECD:4545-4554/10.38 WOB:0.2-2.4K CT WEIGHT:17,500 MOTOR STALLED. PU TO RECOVER 21:40 - 23:15 I 1.58 STWHIP P WEXIT 'PU. RECORD SLOW PUMP RATES. RIH TO GET MILLING STARTED AGAIN TIME MILL WINDOW F/10604.1'TO 10604.4' 1 MM IN/OUT:1.66/1.66 CIRC PSI:3490-3800 FS:3450 MW IN/OUT:9.52 PPG/9.48 PPG IA/OA/PVT:150/397/296 'ANN PSI/ECD:4545-4554/10.39 WOB:0.2-2.4K CT WEIGHT:17,500 MILL PUNCHING THRU 7". WELL DRANK 5 IBBLSOFMUD LOSSES HEALED BACK TO 7 BPH. Printed 4/27/2015 125751PM North America-ALASKA-BP Page 4 of 28 Operation Summary Report Common Well Name:07-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.4/12/2015 End Date X3-016V7-C.(3939,573.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:NORDIC 1 Spud Date/Time:5/18/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292180900 Active datum:Kelly Bushing/Rotary Table @60.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:15 - 00:00 0.75 STWHIP ! P WEXIT TIME MILL WINDOW MM IN/OUT:1.69/1.57 CIRC PSI:3490-3900 FS:3450 MW IN/OUT:9.53 PPG/9.48 PPG ;IA/OA/PVT:150/411/286 'ANN PSI/ECD:4545-4554/10.39 WOB:2.0-2.4K CT WEIGHT:15,800 4/15/2015 00:00 - 01:00 1.00 STWHIP I P WEXIT TIME MILL WINDOW F/10,605'-10605.5' MM IN/OUT:1.67/1.65 CIRC PSI:3490-3800 ;FS:3450 MW IN/OUT:9.53 PPG/9.48 PPG 'IA/OA/PVT:151/424/283 LOSSES BACK TO MINIMAL ANN PSI/ECD:4545-4554/10.38 WOB:0.2-2.4K CT WEIGHT:16600 LOOKS LIKE MILL OUT. 01.00 - 02:30 1.50 STWHIP P WEXIT I TIME MILL WINDOW F/10605.5'-10607. MM IN/OUT:1.65/1.65 CIRC PSI:3490-3677 FS:3450 MW IN/OUT:9.53 PPG/9.48 PPG IA/OA/PVT:153/433/283 1:1 RETURNS ANN PSI/ECD:4554/10.38 I WOB:0-1K CT WEIGHT:16800 STRING REAMER EXITING. 02:30 - 03:30 1.00 STWHIP P WEXIT REAMER OUT. START DRILLING RATHOLE AT 10'/HR MM IN/OUT:1.67/1.67 CIRC PSI:3940 FS:3450 MW IN/OUT:9.53 PPG/9.40 PPG '1A/0A/PVT:153/433/283 1:1 RETURNS ANN PSI/ECD:4551/10.39 WOB:2.0K CT WEIGHT:15000. 03:30 - 04:00 0.50 STWHIP P WEXIT DRILLED RATHOLE TO 10617' DENSITY ERRATIC. 9.3-9.4 PPG I SHUT PUMPS DOWN. FLOW CHECK. MM NOT READING ANY FLOW +5 GAIN. COME ONLINE WITH PUMPS. PUMP 15 BBLS. OUT RATE INCREASING. fLOW CHECK. WELL FLOWING. SHUT IN. SHOWING 23#. CALL SUPERINTENDENT. CIRCULATE 5 BBLS THRU CHOKE TO TIGER TANK TO KEEP COIL WARM. PUH 04:00 - 07:00 3.00 STWHIP N DPRB 10,617.00 WEXIT ;PJSM, CIRCULATE OUT DIESEL FROM WELL TAKE ALL RETURNS TO TIGER TANK -MM IN/OUT:2.2/2.2 CIRC PSI:4100 WHP: 180-200 -MW IN/OUT:9.45 PPG/8.8 PPG(INITIAL) -MW IN/OUT:9.45 PPG/9.45 PPG(POST) 07:00 - 07:30 0.50 STWHIP N DPRB 10,617.00 WEXIT FLOW CHECK :-PERFORM 20 MIN FLOW CHECK (FINGERPRINT) -SLIGHT DRIBBLE AT NEEDLE VALVE FOR 15 MINS(NO GAIN) -CLOSE NEEDLE VALVE TO MONITOR I SHUT-IN PRESSURE(NO PRESSURE) -NOTIFIED WOSM/TL OF FLOW CHECK RESULTS 1-LINE UP FOR NORMAL OPERATIONS Printed 4/27/2015 12 57.51PM TREE=v FMC GEN 4 VVELLHEAD FMC '"" 07-33B ""' NOTES:WELL ANGLE>70"@11102'*** CHROME TBG SEE RWO/CTD RLE FOR PBTD ACTUATOR AXELSONOKNOTES BELOW THIS DEPTH OF 12517'*** BF. BEV 60' I :/ BF.E3_EV= ? KOP= 1400' 20"CONDUCTOR - 112' Max Angle= 96"@ 11987' I - ' 2216' -{4-1/2"X FSS NP,D=3.813" Datum MD= 10937' 91.5#,F140, Datum TVD, 8800'SS D=19.124" GAS LFT MANDRELS ST MO TVD DEV TYPE V LV LATCH FORT DATE 13-3/8*CSG,68#,K-55 BTC,D-12.415" H 94' 3 3539 3175 42 tarIG-M DMY RK 0 05/11/14 13-3/8"CSG,72#,L-80 BTC,D=12.347" - 3367' 2 7179 5948 41 WAG-M DMY RK 0 05/11/14 1 9851 7953 37 MMG-M OMY RK 0 10/25/03 Minimum ID = 1.92" a@ 10703' I - 9921' H4-1/2"X I1 NP,D=3.813" TOP OF 2-3/8" LNR / z-- 9942' -19-5/8'X 4-1/2"BKR CR S-3 MK,D=3.875' 9966' -14-1/2"X Hes NP,D=3.813" 4-1/2"TBG, 12.6#,13CR,.01522 bpf,D=3.958' --I10025' NI I 10034' I 8.2'UMQLE OVERSHOT or TOP OF 3-1/2"LNR H 10080' r Jl 10080' -13-1/2"DEPLOY MB f7'SLV w/TIEBACK,,D=3.0" 0 Z F-71-64F1-19-5/8"X 5-1/2"BKR FB-1 PKR W/SBE&M.O.E 5-1/2"TBG-FC, 17#,L-80,.0232 bpf,D=4.892" --I 10141' I 10160' H 5-1/2"X 4-1/2"XO(B13-Itt13 LNR) TOP OF 7"LNR -{ 10166' U 10166' --{8-1/4'BOT TACK SLV,ID=6.25" 4-1/2"1BG,12.6#,L-80,.0152 bpf,0=3.958' H 10272' 10179' -I 9-5/8'X r BOT SHORTY LNR HGR,D=6.312' 9-5/8"CSG,47#,L-80BTC-M,D=8.68V H 10413' ' 10272' -14-1/2"WLEG(BB-IND LNR) 3-1/2"LNR,9.3#,L-80,.0087 bpf,ID=2.992' H 10533' 3-3/16*BKR PKR WHIPSTOCK(04/14/15) --I 10598' WHPSTOCK w/RA TAG @ 10805'(10/27/03) -{ 10800' 10532' H3-1/2"X 3-3/16"XO,ID=2.80" F RFORA11ON SUWARY REF LOG:MAV-11/04/03 10688' H TOP OF CMT LNR(11/04/03) ANGLE AT TOP PERE:48°©10980' All Note:Refer to Production 013 for historical pert data i 10697' 1-13-BKR DEPLOY SLV w/3'GS PROF,D=2.250' SEE SPF INTERVAL Opn/Sqz SHOT SQZ i. 1-9/16" 6 ' 11010-11030 C 08/14/06 IMFLOUT WINDOW(07-338) 10798' -10805' 1-9/16" 6 11045-11070 C 03/26/07 1-9/16" 6 10980-11000 C 05/30/09 1-9/16" 4 11175-11215 C 11/06/04 _ 1-9116" 4 11270-11400 C 11/06/04 1-9/16" 4 11455 11540 C 11/06/04 ` 11100' _--I WFD 2-318'CEP(03/22/07) 1-9116" 4 11580-11635 C 11/06/04 1�`` 1-9/16" 4 11695-11830 C 11/06/04 ` 1-9/16" 4 11990-12155 C 11/06/04 •'14. 1-9116" 4 12320-12415 C 11/06/04 ` 1-9/16" 4 12450-12515 C 11/06/04 7"LNR,29#,L-80,D=6.184' -1 11207' ` PBTD 1251 T * 3-3/16"LNR, 6.2#,L-80, ID=2.80' -j 11291' IX ►ve 2-3/8"LNR,4.6#,L-80,.0036 bpf,0=1.92" --I 12585' DATE REV BY COMvE NTS DATE REV BY COMMENTS PRUDHOE BAY MIT 10/25/98 SIDETRACK(07-33A) 05/13/14 C NIJMD GLV C/O(05/11/14) WELL: 07-33B 12/20/03 JLM/TLh RWO&CTD SOTRCK(07-33B) 02/27/15 JNLJJM)ADD®TACK SLV PER TALLY PERMIT No:"`2031120 05/31/09 JL JRLH GLV C/O(05/14/09) 03/21/15 JCMPJC SET BKR PKR W t-PSTOCK AR No: 50-029-21809-02 06/13/09 RREYTU-I ADPR2F(05/30/09) 05/07/15 TR/JPA) TAGGED WS(04/14/15) SEC 34,T11 N,R14E 1068'FNL&522'FW, 02/20/14 C NfJMD FIST+2 TOOLSTRNGS(02/17/14) 05/13/14 RCT/JMD PULLED FISH(05/10/14) BP Exploration(Alaska) • • P`' 1 T1114' THE STATE Alaska Oil and Gas ofALASKA Conservation Commission _ :_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF w h" Main. 907.279.1433 ALAS*P.' Fax• 907 276 7542 www.aogcc.alaska.gov John McMullen 1 Engineering Team Leader saNtiE0 �R r BP Exploration(Alaska), Inc. , 903 - ( 1 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-33B Sundry Number: 315-119 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, Cathy P. oerster Chair DATED this C day of March, 2015 Encl. STATE OF ALASKA RECEIVED • ALASr.A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL MAR 0 2 2015 20 AAC 25.280 h��� I S1k 1. Type of Request: ❑Abandon ®Plug for Rednll • 0 Perforate New Pool 0 Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2 Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 203-112 • 3. Address' ❑Exploratory 0 Stratigraphic Alaska 99519-6612 ®Development 0 Service P.O. Box 196612,Anchorage, 6 API Number: 50.029-21809-02-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 07-33B • Will planned perforations require a Spacing Exception? 0YesNo 9. Property Designatior 10.Field/Pool(s): ADL 028309 • Prudhoe Bay Field/Prudhoe Bay Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD (ft): Plugs(measured): Junk(measured) 12585' • 8954' • 12517' , 8953' • 11100' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 34'- 114' 34'- 114' 1490 470 Surface 3331' 13-3/8" 34'-3365' 34'-3047' 3450/4930 1950/2670 Intermediate 10383' 9-5/8" 30'- 10413' 30'-8415' 6870 4760 Production 604' 7" 10166'- 10770' 8211'-8713' 8160 7020 Liner 720' 3-1/2"x 3-3/16" 10080'- 10800' 8140'-8738' Liner 1888' 2-3/8" 10688'- 12576' 8645'-8954' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11010'- 12515' 8911'-8953' 4-1/2",12 6"x 5-1/2",17"x 4-1/2"12 6# 13Cr80/L-80 10272' Packers and SSSV Type. 9-5/8"x 4-1/2"Baker CR S-3 Packer; Packers and SSSV 9942'/8026'; 9-5/8"x 5-1/2" Baker FB-1 Packer MD(ft)and ND(ft): 10141'/8190' 12. Attachments: 13.Well Class after proposed work. • ®Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation' March 15,2015 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended • 17. I hereby certify that the f egi,9 tr correct to the best of my knowledge Contact' Zach Browning,564-5220 Printed Name: Joh M uN / Title: Engineering Team Leader Email: Zachary.Browning@bp corn Signature: Phone: 564-4711 Date: j / z / S Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 15_\\q ❑Plug Integrity I BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other:8Op i-c-,51" ;✓c, 3SUO/,s, (M17.5P = 238 A3, Aelovlar pl GVtvz 1-Cr-fc5t' to 25-00 ips ,4_l f,r«a fC p 1 v 7 plot c C r e f 4_pp k--0 L,-c-d /7-e• : 2--o .4-i1--C Z5-- 1 / Z l 4 j Spacing Exception Required? ❑YesNo Subsequent Form Required: /a — �, Z J - APPROVED BY /6 -1 S-- Approved By: COMMISSIONER THE COMMISSION Date: 3— Form 10-403 Revised 1 Z1/2 &jjhIv1Iid for 12 months from the date of approval Submit In Duplicate VTC IS apRi �� .6-/� 3 S, - (S RBDM kk APR - 2 2015 /�/ . To: Alaska Oil & Gas Conservation Commission From: Zach Browning biD CTD Engineer Date: February 25, 2015 Re: 07-33B Sundry Approval Sundry approval is requested to plug the 07-33B perforations as part of the preparation, drilling and completing the proposed 07-33C coiled tubing sidetrack. History of 07-33: 07-33 grandparent was drilled in 1988. It was CTD sidetracked out of its 7" production liner in 1998. A Tiny CTD sidetrack was drilled out of that liner in 2003, and that is the bore we have today. As part of that 2003 CTD sidetrack Nordic pulled the existing failed 5-1/2" tubing and replaced it with a new stacker packer chrome 4-1/2" tubing completion. The well today now shows no recharge, and there are no further wellwork options. Proposed plan for 07-33C: Drill a through tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig on or around April 15th, 2015. The 07-33C sidetrack will be a dual string exit from the existing 3-1/4" liner and through the 7" liner. The kick-off is in Zone 4 and will target reserves in Zone 1A. The proposed sidetrack is a -2880' horizontal Ivishak Zone 1A producer to be completed with a 2-3/8" 13Cr solid liner, cemented in place. This Sundry covers plugging the existing 7-33B perforations via the 3-3/16" packer whipstock set pre-rig and liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. 1 COnLv/. e 1.1J2/� ��1 d6`3 l �?�"�< 1,4- 0117 7C'14 �f e `;;,j4.:)( 00e9 ,7", "1006 ced - 60 ,.N .gycels o' 676� �l�ys. �h, s we 1/ 74-i- 8014-- 4- � J �� �;lI D c /n�tr 0 ye o (re v v er,r Pc TO �Dr ' /0/4 of rhe (200). Pre-Rig Work(scheduled to begin March 15th, 2015) 1. E Set 3-3/16" Packer WS (Slickline performed WS drift 1/31/15) 2. F MIT-T to 3000 psi 3. V Bleed wellhead pressures to zero. 4. V Bleed production, flow and GL lines down to zero. 5. V Install Sarber spool and PT Swab valve 6. V Remove wellhouse and level pad Rig Work(scheduled to begin April 15th, 2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP = 2387psi) 2. Mill 2.80" window at 10,595' and 10' of rathole. 4. Drill build section: 3.25" OH, 613' (18°deg/100 planned). 5. Drill lateral section: 3.25" OH, 2267' (12°deg/100 planned) 7. Run 2-3/8" L-80 liner leaving TOL at-10,010' MD. Pump primary cement leaving TOC at TOL, 20.9 bbls of 15.3 ppg liner cmt planned (20% OH 8. excess).* 9. Perform GR/CCL/RPM logging run. Contingency to perform cleanout run first if needed. 10. Test liner lap to 2400 psi. Set LTP on slickline post-rig if test fails.* 11. Perforate well based on log interpretation. 12. Freeze protect well to 2500' MD 13. Set TWC, RDMO * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. Re-install wellhouse, flowline and pull TWC. 2. Install GLVs. 3. Set liner top packer with slickline if liner lap test fails.* 4. ASRC flowback. SIT. Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 TREE= FMC GEN 4 S_ Y NOTES: ***4-112"CHROME TBG'** WELLHEAD FMC 70 R _ ACTUATOR ..._AXELSON V * ALE FORPBTD NOTES BELOW THIS DEPTH/CTD OKE.H-EV= 60' BF.BEV= ? 12517'**" KOP= 1400' Max Angie= 96"@ 11987' I I f 2216' H4-1/2"X HES NP,D=3.813" Datum MD= 10937' Datum ND= 8800'SS GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80,D=12.347" H 3365' 3 3539 3175 42 MMG-M DMY RK 0 05/11/14 L • 2 7179 5948 41 MMG-M DMY RK 0 05/11/14 1 9851 7953 37 MMG-M DMY RK 0 10/25/03 Minimum ID = 1.92" a@ 10703' I I _9921' —14-1/2"x HES NP,D=3.813" TOP OF 2,3/8" LNR ® Z-1 9942' —9-5/8"X4-1/2"BKR CR S-3PRK,13=3.875" I I 9966' —14-1/2"X HES NP,D=3.813" r 10033' —FUNFOUE OVERSHOT 1 4-1/2"TBG,12.6#,13CR,.01522 bpf,D=3.958" H 10026' / TOP OF3-1/2"LNR — 10080' \ 10080' H3-1/2"DEPLOY MOW SLV w/TACK,D=3.0" S 10141' H 9-5/8"X 5-1/2"8KR F13-1 PKR W/SBE 8 M.O.E 5-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" —1 10141' f - 10160' —15-1/2"X 4-1/2'XO(BEHIND LNR) TOP OF 7"LNR H 10166' J [4-1/2"TBG,12.6#,L-80,.0152 bpf,D^3958"J—[,,.__ 10272' 9-5/8"CSG,47#,L-80,D=8.681" — 10413' / % I 10272'.-14-1/2"WLEG(BB-IND LNR) 1 3-1/2"LNR,9.3#,L-80,.0087 bpf,D=2.992" —1 10533' [WHPSTOCK(10/27/03)1H 10800' PERFORATION SUMMARY 10532' H 3-1/2'X 33/16"XO,D=2.80' REF LOG:MCN_11/04/03 ANGLE AT TOP PEFRF:48°@ 10980' 10688' H TOP OF CMT LNR(11/04/03) Nbte:FZefer to Ptoduction 08 for historical pert data SQE SPF IN TB VAL Opn/Sgz SHOT SOZ I 10697' —13"BKR DEPLOY SLV w/3"GS PROF,D=2.250" 1-9/16" 6 11010-11030 0 08/14/06 48.mk) 1-9/16" 6 11045- 11070 0 03/26/07 1 1-9116" 6 10980- 11000 0 05/30/09 i MLLOUT WINDOW(07-33B) 10798' -10805' 1-9/16" 4 11175-11215 C 11/06/04 1-9/16" 4 11270-11400 C 11/06/04 ` 1-9/16" 4 11455-11540 C 11/06/04 1-9/16" 4 11580- 11635 C 11/06/04 11100' H WFD 2-3/8"GBP(03/22/07) 1-9/16" 4 11695- 11830 C 11/06/04 / /e* 1-9/16" 4 11990-12155 C 11/06/04 * ` 1-9/16" 4 12320-12415 C 11/06/04 .1% ` 1-9/16" 4 12450- 12515 C 11/06/04 II/j ` 10805' HRA TAG 7"WHIPSTOCK —I —10760' AV 7"LNR 29#,L-80,D=6.184" — 11027' [TM 1251 T * / , _._I—I. 3-3/16"LNR, 6.2#,L-80, D=2.80" --1 11291' 4.1 OA 2-3/8"LNR,4.6#,L-80,.0036 bpf,D=1.92" —[ 12585' 2-7/8"LNR,6.5#,L-80,D=2.441" —1 12759' DATE FEV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/25/98 SIDE=TRACK(07-33A) 05/13/14 CJNYJMD GLV C/O(05/11/14) WELL: 07-338 12/20/03 JLM/TLI-RWO&CTD SDTIaCK(07-33B) ,02/27/15 JNUJMD ADDED TIEBACK SLV PER TALLY PERMT!sky' 031120 05/31/09 JLJ(TLH GLV C/O(05/14/09) AR No: 50-029-21809-02 06/13/09 RFRIYTL.H ADPE RF(05/30/09) SEC 34,T11N,R14E, 1068'FNL 8 522'FWL 02/20/14 CJNIJMD SET ASH 2 TOOLSTRINGS(02/17/14) 05/13/14 RCT/JMD PULLED 2 FISH(05/10/14) BP Exploration(Alaska) TREE= FMG GEN 4 SAFETY NOTES: ***4-1/2"CHROME Ma** WB11f4D= FMC • ACTUATOR= AXEFSON 07-31 WELL SEE RWO TD RLE FOR PBTD NOTES BELOW KB.ELEV= 60' --__--------------____ BF_ELE1/_ 7 THIS DEPTH(12517') KOP= 1400' Max Angle= 96 0311987' i 1 • 2T-4-1---6-;--- -4_112"X HES NP,D=3.813" I Datum MD= 1093T Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TY FE VLV LATCH FORT DATE 113-3/8"CSG,72#,L-80,D=12.347' `--I 3365' ,, 3 3539 3175 42 MMG-M DOME RK 16 05/14/09 `H 2 7179 5948 41 MMG-M SO RK 20 05/14/09 1 9851 7953 37 MMG-M OMY RK 0 1025/03 Minimum ID = 1.92"@ 10703' I I 9921' —14-12"X FES NP,D=3.813" TOP OF 2-3/8" LNR Z' I 9942' - 918''X 4-12"BKR CR S-3 PRK,iD=3.875' I -9968' 7-14-12"X FIES NP,D=3.813' 3.7"deployment sleeve above 3"deployment sleeve TOL to 10,010' MD TD 10033' --I UM:WE OVERSHOT 4-12'TBG,12.6#,13CR,.01522 bpf,D t-------1=3.958" H 10026' � �[ 100861 I—3-12"DEFLOY RENT SLV,D=3.0" 1 TOP OF 3-12"LNR H 10085' S I 10141' l-- 9-5/8"X 5-1/2'BKR FB-1 PKR W/SBE&M.O.E 5-112"TBG-PC,17#,L-80,.0232 bpf,0=4.892" — 10141' 10160' H 5-12"X 4-1/2"XO(BEHIND LNR) 1 TOP OF 7"LNR — 10166' j 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" —I 10259' 9-5/8"CSG,47#,L-80,ID=8.681" —I 10413' I 10259' I-{4-1/2'1MLEG(BEHIND LNR) 3-1/2"LNR,9.3#,L-80,.0087 bpf,D=2.997 —I 10633' l _ 10532' —3-12"X3-3/16"X0,D=2.80" 1 Pup joint with RA tag(depth TBD) vin IPSTocK(10/27/03)I — 10800' ` ,+'/8 ORATION SUMWIRY • REF LOG:AXIL 11/04/03 ANGLE AT TOP PITT:48°@ 10980' so 3-3/16"packer WS set at 10,595' 2-3/8"L-80 to 13,475 MD TD Note:Refer to Production DB for historical pert data ) -- EL MD and 180 deg ROHS SIZE SPF INTERVAL Opr�ISgz SHOT SOZ 1-9116' 6 11010-11030 0 08/14/06 10688' I-ITOP OF CMi LNR(11104/03) 1-9/16" 6 11045-11070 0 03/26/07 d 1-9/16" 6 10980-11000 0 05/30/09 ii r 10697' I-{3"BKR DEPLOY SLV w/3"GS PROF,D=2.250" 1 1-9116" 4 11175-11215 C 11/06/04 1-9/16' 4 11270-11400 C 11/06/04 ` 1-9/16" 4 11455-11540 C 11/06/04 ' ` 1-9/16' 4 11580-11635 C 11/06/04 ' 1-9/16" 4 11695--11830 C 11/06/04 / 1-9/16" 4 11990-12155 C 11/06/04 k`, 11100' —IVVFD 2-3/8"CIBP(03/22/07) 1-9/16' 4 12320-12415 C 11/06/04 •r%. ` 1-9116' 4 12450-12515 C 11/06/04 `i i 10805' --rRA TAG I7"VVIPSTOCKJ--I -10760' I 7"LNR,29#,L-80,ID=6.184' — 11027' I PBTo H 1251 T * I/ `w 3-3/16"LNR, 6.2#,L-80, ID=2.80' --I 11291' vi M 2-3/8"LNR,4.6#,L-80,.0036 bpf,ID=1.92" H 12585' 2-7/8"LNR,6.5#,L-80,D=2.441" — 12769' DATE REV BY COMMENTS DATE REV BY 0014M34TS PRUDHOE BAY UNIT 10/25198 SIDETRACK(07-33A) 05/31/09 JLJ/TLH GLV CIO(05/14/09) WELL 07-33B 12/20/03 JLM/TLH RWO&CTD SDTRCK(07-33B) 06/13/09 RROVTLH ADPERF(05/30/09) PERMT No:"2031120 08/14/06 GIB/PJC PERFS 02118/15_ NS Proposed CTD AR No: 50-029-21809-02 04/01/07 RDB/PJC SET CBP(03/22/07) — SEC 34,TI 1 N,R14E 3543.46'FEL&3065.86'FNL 04(01/07 RDE/PJC PERFORATION(03/26/07) 05/26/08 JLJ/SV GLV C/O(05/11/08) BP Exploration(Alaska) C 1 !II 0 a-si-co/13 I : .� ufco ii w �s "I aa11i a 1T.mU11. T= F [1-,'•' f X11) a O,� -- u E m •, i11 ,r+.14a � u g g8 { IL7 O c.9 0 m m <— C.11 n I , • 1" 8 I I H 0 ... 1 - I � 1 i ii OI J g0 1 n I III, III O LL �;� t I 0 _ 0 �. mI = .r m m Z I ct7 MI 2 III u a E 1 ... 0137 II III III I zO m 1 U O 1 0 U U�1� 1— g > MI ,1 N Y III I11 w 8 J 0 o e — B IC 1 of .10 (� 1 fl � `� rc rc • • DEC I 1 0 N . U I J _ _ WI rc 1 1 V cc 1 v f O ?1,141 g 1 • • 1 W 1 ► ; I 01 I O 1 t U C9 > 1 CC ' 1 Q -_ N 1 ai Q 1 $� U ; ,2g 1 I ✓ & ETi O 00 ro 0 S I I rc & Z 2 I y IT] —.1 ' �` N C 9 ce 11 111 177. 0 n a l I a` I. 1�� „ P. ro 1■ ry§ 1,:a I ¢ 111 CMI C 1 I 111 fO .k Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" ________ boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, ,� then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab 1 for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the Form 10-407 into listed on the F o RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. -', ) ) . Image pr'oject Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - 1 L~ Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 RE;9AN vCo1or Items: D Greyscale Items: DIGITAL DATA ~kettes No. t D Other, No/Type: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: ~,Maria "") Date: I.}. 1(5/0S- D Other:: Is I yv\ð -1111 I I Isl vy\ð Project Proofing BY: ~.,.lV1aria ') Date: l~ /S/ OS j x 30 = ~3 () + Date: J d- I is /~ / (I) = TOTAL PAGES q1; (Count does not include cover sheet) 11\11,,' () Isl , r, 1111111111111111111 Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: ~ 7 (Count does include C? sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date: Id- i~l{)b If NO in stage 1 page(s) discrepancies were found: BY: Isl NO 0 V11 Stage 1 YES NO BY: Maria Date: Isl Scanning is complete at this point unless rescanning is required. 11111 ReScanned 1111111111111111111 BY: Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc ~~ ~ ~ ~~~tun~~er~e~ ~, N0. 5297 `~` ~~~~~;~ ~:+U ~.. = °p; ~ ~!~ v~ r~laska Data & Consulting Services v~`+~.' ~ Company: State of Alaska 2525 Gambell Streei, Suite a00 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnk~en tlYYRI: Be4h 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~1/ell Job # Log Description Date BL Color CD 07/06/09 ~-06 67-338 AYTO-00035 B4C4-00003 GLS/PROOUCTION PROFILE SCMT a 05/12/09 05/30/09 1 1 1 1 17-14 AVY5-00049 PRODUC ION PRO ILE ~./- 05/31/09 1 1 12-01 AYTU-00039 PRODUCTION PROFILE O6/01/09 1 1 04-43 AXWS-00011 IBP/CROSS FLOW CHECK '} O6/02/09 1 1 D-13A B04C-00059 USIT - 06/03/09 1 1 Z-i12 B2WY-00011 MEM PROD PROFILE '~ - 06/03/09 1 1 06-05 B04C-00061 USIT 06/04/09 1 1 12-18 AV1H-00014 PRODUCTION PROFILE 06/04/09 1 1 A-35 AY3J-00026 USIT U ~-(~" a(p ~ O6lOM09 1 1 92-22 AXWS-00013 PROD PROF/GLS 06/OS/09 1 1 12-16A AXWS-00014 PRODUCTION PROFILE -~ 06/05/09 1 1 18-296 B04C-00062 PSP XY-CALIPER LOG 06/06/09 1 1 C-12A AXWS-00015 SCMT r- f 06/06/09 1 1 B-a7A AXBD-00028 MEM PROD PROFILE 06/11/09 1 1 L2-13A AWJI-00036 MEM CNL & INJ PROFILE O6/17/09 1 1 L2-13A AWJI-00036 MEM PROD PROFILE ~ 06/17/09 1 1 07-21 6146-00064 LDL 06/20/09 1 1 17-01A AYQQ-00030 SBHP SURVEY O6/11/09 1 1 01-25 AP3Q-00041 LDL 06/15l09 1 1 L-202 B2WY-00010 MEM PROD PROFILE ~- C,/ 06/0?J09 1 1 ~.-103 AXBD-00027 MEM INJ PROFILE 06/04/09 1 1 GNI-03 AWJI-00034 MEM PRESS & TEMP SURVEY ~'~.- O6/15/09 1 1 G-31B AWJI-00027 MCNL _03 04/30/09 1 1 15-29BPB1 09AKA0143 OH MWDlLWD EDIT ~ ~~ 05/11/09 2 1 YLCAJC AI.RIVVVVLtUIat HtGtIY 1 tf7 ,Ili1VINla AIVU Mtl UFi1VING UNt GUPY EAGH i0: BP Exp~oration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ~ , a ~ ~ ~` / t, STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N ~REC~~ 6 is-oq :! U i~~ ~. REPORT OF SUNDRY WELL OPERATIONS n,___~__ ,,., 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated t r ~.,,: °' Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate 0. Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory 203-1120 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21809-02-00- 7. KB Elevation (ft): 9. Well Name and Number: 60 KB - PBU 07-33B 8. Property Designation: 10. Field/Pool(s): ADLO-028309 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12585 _ feet Plugs (measured) None true vertical 8953.59 - feet Junk (measured) None Effective Depth measured 12517 - feet true vertical 8953.32 - feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 30' - 110' 30' - 110' 1490 470 Surface 3334' 13-3/8" 72# L-80 31' - 3665' 31' - 3269' 4930 2670 Production 10381' 9-5/8" 47# L-80 32' - 10413' 32' - 8415' 6870 4760 Liner 604' 7" 29# L-80 10166' - 10770' 8211' - 8713' 8160 7020 Liner 1897' 2-3/8" 4.6# L-80 10688' - 12585' 8645' - 8954' 11200 11780 Perforation depth: Measured depth: SEE ATTACHED True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 10160' - 10533' Packers and SSSV (type and measured depth) 9-5/8"x5-1/2" BKR FB-1 ....10141', 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~~ ~ i~ ~~) 'r, *~ ~U~~ ~~ U ~' Treatment descriptions including volumes used and final pressure: 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory ~ Development r' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil r ~ 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 P le Title Data Engineer Signature Phone 564-4944 Date 6/4/2009 if,?I' Form 10-404 evised 04/2004 ~~ ~~ j ~ ,_.,. -1~ ~ ~ t .-.~ Sub Ori Onl 07-33B 203-112 PERF OTTOCHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 07-33B 11/6/03 PER 11,175. 11,215. 8,966.85 8,967.49 07-336 11/6/03 PER 12,320. 12,415. 8,957.39 8,951.14 07-33B 11/6/03 PER 11,990. 12,155. 8,976.2 8,968.58 07-33B 11/6/03 PER 11,695. 11,830. 8,979.49 8,977.92 07-33B 11/6/03 PER 12,450. 12,515. 8,951.36 8,953.29 07-33B 11/6/03 PER 11,455. 11,540. 8,968.36 8,973.45 07-33B 11/6/03 PER 11,270. 11,400. 8,969.48 8,968.05 07-33B 11/6/03 PER 11,580. 11,635. 8,976.03 8,979.09 07-336 8/14/06 APF 11,010. 11,030. 8,911.09 8,921.8 07-33B 3/22/07 APF 11,045. 11,070. 8,929.14 8,940.11 07-33B 3/23/07 APF 11,045. 11,070. 8,929.14 8,940.11 07-33B 3/24/07 APF 11,045. 11,070. 8,929.14 8,940.11 07-33B 3/26/07 APF 11,045. 11,070. 8,929.14 8,940.11 07-33B 3/27/07 APF 1,045. 11,070. 1,044.97 8,940.11 07-33B 5/31/09 APF / 10,980. 11,000. 8,892.91 8,905.43 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 5PS 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 07-33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/30/2009 WELL SHUT-IN ON ARRIVAL, SSV OPEN, INITIAL PRESSURES 2450/800/0. LOG CEMENT BOND LOG FROM 10800 - 10000 FT CEMENT BOND IS ~ GOOD IN ALL LINERS. UPLOAD LOG TO INTERACT FOR REVIEW BY PE'S. , PROCEED WITH PERFORATION. **"JOB IN PROGRESS AND CONTINUEb ON 31 MAY 2009 WSR"** 5/30/2009T/I/0= 2450/800/20 Temp= S/I Assist E-line as directed- Pumped 2 bbls neat ~ methanol spear followed with 266 bbls 120* seawater and 367 bbls 130* 1 KCL and capped with 43 bbls 60* crude down TBG, Final WHP's 0/960/150 -----SLB on well @ departure---- "Valve position @ departure- Wing= SI / Swab, SSV, Master, IA & OA= Open" 5/31/2009'***JOB CONTINUED FROM 30 MAY 2009""* ~RIH W 20 FT 1.56" PERF GUN, PERFORATE INTERVAL: 10.980 - 11.000 Fr. API DATA: 1.56" HSD 1606 PJ HMX, 60 DEG PHASING, 10.7 IN iPENETRATION, 0.19 IN ENTRANCE HOLE, MAXIMUM SWELL IN LIQUID i1.721N. 9 ALL SHOTS FIRED VALVE POSITIONS UPON DEPARTURE: MASTER, SSV -OPEN. SWAB - (CLOSED. DSO NOTIFIED. ***JOB COMPLETE"'''` FLUIDS PUMPED BBLS 2 MEOH 1 diesel 3 Total • ~ <-~.,._ MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_InsertstMicrofilm_Marker.doc .. STATE OF ALASKA _ ALAsWOIL AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS D D o R~C~/II~D OCT StimulateD a~§erJD Úl)' WaiverD Time Extensio~ô ó'as C Re-enter Suspended Well []n OnS. COIr¡ 5. Permit to Drill Number: e 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R Stratigraphic Exploratory Service 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 60 KB 203-1120 6. API Number: 50-029-21809-02-00 PBU 07-33B ADlO-028309 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Representative Daily Average Production or Injection Data Gas-Mcf " I¡)'ater-Bbl .Casing Pressure 20925 88 0 o 0 0 15. Well Class after proposed work: Exploratory Development R 16. Well Status after proposed work: Oil R Gas WAG 8. Property Designation: Total Depth feet feet Plugs (measured) Junk (measured) measured true vertical 12585 8953.59 Effective Depth measured 12517 feet true vertical 8953.32 feet Casing length Size MD TVD Conductor 80' 20" 91.5# H-40 30' - 110' 30' - 11 0' Surface 3334' 13-3/8" 72# l-80 31' - 3665' 31' - 3269' Production 10381 ' 9-5/8" 47# l-80 32' - 10413' 32' - 8415' Liner 604' 7" 29# l -80 10166' - 10770' 8211'-8713' Liner 1897' 2-3/8" 4.6# l-80 10688' - 12585' 8645' - 8954' Perforation depth: Measured depth: 11010' - 12515' True Vertical depth: 8911' - 8953' - - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# l-80 Packers and SSSV (type and measured depth) 9-5/8"x5-1/2" BKR FB-1 o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): >.::;,,-. ^, M:;¡"~F¡) ·.,Vl¡·\...·,·j,.....~'...-;, Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl 545 well shut in x None None Burst 1490 4930 6870 8160 11200 Collapse 470 2670 4760 7020 11780 10160' - 10533' 10141 ' o o o Tubing pressure 347 o Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble WINJ WDSPL Title Data Engineer RBDMS BfL 0 CT 1 7 Z006 Signatur Phone 564-4944 Date 9/29/2006 Submit Original Only ." ~ . . 07-33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/14/2006 PERFORATED FROM 11010' -11030' USING 20' x 1.56" HSD 1606 PJ HMX NO PROBLEMS REACHING REQUIRED DEPTHS WITH TOOL STRING INDICATED IN LOG SECTION. UNABLE TO REACH REQUIRED DEPTH WITH GUN. CORRELATED TO SLB - MCNL DATED 04-NOV-2003. WELL LEFT IN AND TURNED OVER TO DSO. FINAL TI 110 = 24001 70010. COMPLETE*** FLUIDS PUMPED BBLS I 1 .. DIESEL 1 .. TOTAL (obll£..- DATA SUBMITTAL COMPLIANCE REPORT 12/5/20Ó5 Permit to Drill 2031120 Operator BP EXPLORATION (ALASKA) INC Well Name/No. PRUDHOE BAY UNIT 07-33B MD 12585'" TVD 8954'" Completion Date 11/6/2003 r Current Status 1-01l Completion Status 1-01l --~~--~--~-,------~ -~"-.-~-_.- REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes ~- DATA INFORMATION Types Electric or Other Logs Run: CCl, GR, Memory CNl, MWD, GR Well Log Information: >,,¿ À80'iJ..o~J API No. 50-029-21809-02-00 UIC N ~_..,- (data taken from logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Z Med/Frmt Number Name ih Las 12284 Casing collar locator Directional Survey ~ Directional Survey Jið' C Lis 12927 Gamma Ray Interval Start Stop 9783 , 10063 1 0767 12585 10767 12585 10800 12585 Log Log Scale Media Run No OH/ CH Received - Case 11/17/2003 Open 1/22/2004 Open 1/22/2004 Open 12/17/2004 ..I15g 12927 Gamma Ray .-cog 12927 Gamma Ray ~ 12927 LIS Verification ~ C Lis 12993 Gamma Ray 01."" 1?99"'\ r"\i}l')1m:> R")ij ------------ ._-~"._~--- 25 Blu 10800 12585 Open 12/17/2004 10800 12585 Open 12/17/2004 10800 12585 12/17/2004 9780 12514 Case :JMO ~ðé14 C::¡,¡¡ Sample Set Number Comments 25 Blu :2 ;)1... -::T Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y (!!) Chips Received? v J t~ Q/N (jN Daily History Received? Formation Tops Analysis Received? ~ Comments: . Comments G ft ~(..~~ LIS FilE, GRAPHIC IMAGES MWD-GRIDIR LIS FilE, GRAPHIC IMAGES MWD-GRlDIR LIS . FilE, GRAPHIC IMAGES MWD-GRIDIR LIS ' FilE, GRAPHIC IMAGES MWD-GR/DIR MCN/MEM GR/CCUCNl M'G1, '¡1~1!:r~ ðR.,'(JC:".'Ctll / I . DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031120 Well Name/No. PRUDHOE BAY UNIT 07-33B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21809-02-00 MD 12585 TVD 8954 Completion Date 11/6/2003 Completion Status 1-01L Current Status 1-01L UIC N Compliance Reviewed By: J I --_...,._-~--~ u Date: _J~___p~~¿_~-S . . Schlumbergep Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . I '13 -rJ/i¡ C-39 i"'n-A~ E-21A L 9tr 170 C-29A 1-0'3 - ì¡:)..DS 07 -33B /9J-I5J-07.01A ~:'¡-(þC¡ X-27 .~ E-18A !¿"7-C:v/'{ DS 01-24A 112.- ~ E-10A /7>9 -102. Z-12 2..01- O"J ì X-15A l1»{.í;?Jl P1-07A .11· 07èf;G-03A Z47{- 'Z-l,:? L5-17 A ! '/,:J / IJJ7. P1-05 ltJt.f- r/ 2- '¡ MPC-42 ?c4. MPC-42 Well Job # 10715421 10670030 . 10715422 10715361 10889151 10724364 10621786 10563108 10621797 10704020 10704021 10831301 10889210 10942195 10687701 10889141 10621815 Log Description Date 08/19/04 08/22/04 08/22/04 11/04/03 08/18/04 03/10/04 OS/22/04 10/09/03 06/16/04 07/06/04 07/07/04 07/03/04 02/13/05 02/28/05 08/13/04 07/26/04 08/07/04 MCNL MCNL MCNL MCNL RST RST RST RST RST RST RST RST LDL PSP PPROF/DEFT/GHOST PPROF PSP/DEFT/GHOST RST RST PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Jjtv /05' Blueline c2.ð3-!/¿ 03/15/05 NO. 3363 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD 1 1 1 1 ~1:LfJf..J 1 1 1 1 1 1 1 1 'Ý: ~ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 995.,.03'28'U:8 ATTN: Beth .. '/ ReceivÇiV ~ a/~~ . . Z-03-r(è Transmittal Form r'i_ BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 7-33B Contains the following: 1 IJ,~). I LDWG Compact Disc (Includes Graphic Image files) I LDWG lister summary I blueline - GRJDirectional Measured Depth Log 1 blueline - GRJDirectional TVD Log LAC Job#: 569549 Sent By: Gle;~1 I /. /' Received~o/~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Date: Dec 16, 2004 Date: / ¿/rf r/ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ï------------------------~ I InT'.\!'!·1œ-ÞI1nn' W"JU Ii ¡ ; --_m··w';: ;.:y.;;-:;;;;;~.. '''-ï _... _I..··'··u· --. _.! ~ ~~- ..., " ,-,--.... :- ."'- - ""....' '·1~~ -... - .. ..,_. ~... n~ .. .... "" n. .~. -,., """.' :~:'!_----"-----~ --~"",,,,' ::::'~.:~ :..:_- = - -.. · ... STATE OF ALASKA ALASK.L AND GAS CONSERVATION C04SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: B Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 2OAAC25.105 2OAAC25.110 22. CASING, LINER AND CEMENTING RECORD CASING ' , SernNGDEPTH, ;,HOLE.,:,' ";",'.:;'¡:';::'>~'~"'~," '.' SIzE,,;, ,WT.PERFT., ,-:::~~ÀDéJi '·¡.IOP>!:' "Bo~ " ,SIZE:, CEMENT1NG'RecoRD'·", ,.\',',. 20" 91.5# H-40 Surface 110' 30" 2150# Poleset 13-318" 68# /72# K-55/ L-80 Surface 3365' 17-1/2" 2000 sx CS III, 200 sx CS I, 600 sx 'G' 9-5/8" 47# L-80 Surface 10413' 12-1/4" 629 sx Class 'G', 400 sx CS I r 29# L-80 10166' 10770' 8-1/2" 450 sx Class 'G' 3-3116" x 2·7/8" 6.2# /6.5# L-80 10081' 10800' 3-3/4" 140 sx LARC 2-318" 4.6# L-80 10688' 12576' 3" 59 sx Class 'G' 23. Perforations QP.en to Production (MD + TVD of T ~ and Bottom Interval, Size and Numbèr; if none, state none"): 1.56 Gun Diameter, 4 spf MD TVD 11175' - 11215' 8967' - 8967' 11270' - 11400' 8969' - 8968' 11455' -11540' 8968' - 8973' 11580' -11635' 8976' - 8979' 11695' -11830' 8979' - 8978' 11990' -12155' 8976' - 8969' 12320' -12415' 8957' - 8951' 12450' - 12515' 8951' - 8953' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1068' SNL, 522' EWL, SEC. 34, T11N, R14E, UM Top of Productive Horizon: 2173' NSL, 5227' EWL, SEC. 27, T11 N, R14E, UM Total Depth: 2890' NSl, 4008' EWL, SEC. 27, T11N, R14E, UM 4b. location of Well (State Base Plane Coordinates): Surface: x- 676720 y- 5949869 Zone- ASP4 TPI: x- 681341 y- 5953221 Zone- ASP4 Total Depth: x- 680104 Y- 5953909 Zone- ASP4 18. Directional Survey BYes 0 No 21. logs Run: CCl, GR, Memory CNL, MWD, GR MD 26, Date First Production: November 18, 2003 Date of Test Hours Tested PRODUCTION FOR 12/15/2003 5.1 TEST PERIOD ... Flow Tubing Casing Pressure CAlCUlATED -a.. Press. 302 24-HOUR RATE""" One Other 5. Date Comp., Susp., or Aband. 11/6/2003 6. Date Spudded 10/28/2003 7. Date T.D. Reached 10/31/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 60' 9. Plug Back Depth (MD+TVD) 12517 + 8953 Ft 10. Total Depth (MD+ TVD) 12585 + 8954 Ft 11. Depth where SSSV set (Nipple) 2216' MD 19. Water depth, if offshore N/A MSL 1b. Well Class: B Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-112 13. API Number 50- 029-21809-02-00 14. Well Number PBU 07-33B 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028309 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULlED TVD SIZE DEPTH SET (MD) 4-112", 12.6#, L-80 10034' 5-112",17#,L-80x4-1I2",12.6#,L-80 10032' - 10259' 25. ···'··(>·?·~.fRÀC11.JFŒ.CeMENT~EãC;··,··, - "," ,..,.;.J>...;,<....;:...::,;...::..........:. ;i"é.'i>'.:.' '",,'':', '-'t', ,:", "':'t,',<,,, ''',' '_'-'_', ,;,,:':--_ '-,.,-,,', ;,,' ,:<,;:'" .- "_-' ,,-'-','-'" DEPTH INTERVAL (MD) 2500' PACKER SET (MD) 9942' AMOUNT & KIND OF MATERIAL USED Freeze Protected with 38 Bbls of MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl 680 GAS-McF 16,437 GAS-McF 77,351 CoRE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (atta~et..srØetllttl. F'Wssary). Submit~e ~::'if1\Ione, state "none". L.:.:.I V c: U , COMfLi:,ftU:',i ~ None t ~JE/¡. DEC 1 82003 ' ///?â:~3 . ~IF(8) ¡ , ¡ ~-;,'-_~YY.,~ ~'Tf:.J Oll-BBL 3,200 27. W ATER-BBL 149 W ATER-Bsl 701 DlJPLtCATE Fonn 10-407 Revised 2/2003 CoNTINUED ON REVERSE SIDE ill Z I a CHOKE SIZE I GAS-Oil RATIO 90° 24,189 OIL GRAVITY-API (CORR) Alaska Oiì & Gas Con;:,. ,,"'''¡¡'j¡,)síon Anchorage *i~ ~'" ·! ""·~I gg"!.'_':;'¡4\ ~r::: 28. GEOLOGIC MARKE. 29. .ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Zone18 11028' 8921' None RECEIVED DEC 1 82003 Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. S· ed ~ . 1I f1 M tgn Terrie Hubble - I a.1/l.cR _ ~ P8U 07-338 203-112 Well Number Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Title Technical Assistant Date ';).j /6/ Q3 Prepared By NamelNumber: Drilling Engineer: Terrie Hubble, 564-4628 Dan Kara. 564-5667 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-(0). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection. Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 212003 DUPL\ CATE ..... . ....--., BP Operations Summary Report Page 1 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/1512003 10/1612003 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 10/15/2003 11/6/2003 N2 Spud Date: 5/18/1988 End: 11/6/2003 Start: Rig Release: Rig Number: Frölll-To Godé NPT Phase 06:00 - 10:00 4.00 MOB P PRE 10:00 - 12:00 2.00 MOB P PRE 12:00 - 14:00 2,00 MOB P PRE 14:00 - 15:00 1.00 MOB P PRE 15:00 - 20:00 5.00 MOB P PRE 20:00 - 22:45 2.75 MOB P PRE 22:45 - 23:00 0.25 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 00:00 - 01:00 1.00 MOB P PRE 01:00 - 01 :30 0.50 MOB P PRE 01:30 - 07:00 5.50 MOB P PRE 07:00 - 09:00 2.00 RIGU P PRE 09:00 - 18:00 9.00 RIGU P PRE Description of Operations 09:00 - 09:45 Back rig off well L 1-15A. Prep for rig move. Notice spill on pad. ( IR# 2oo3-IR-649812) Lower derrick. Continue to rig down. PJSM for rig move. Move rig to DS-7. Line up with well head on matting boards. PJSM to raise derrick. Raise derrick. Scope up derrick. Pull over well. Continue to RU. Spot cuttings box. RU hard line to tiger tank. RU choke and kill lines. RIG ACCEPT at 03:30, Pull BPV. Prep to blow down CT, position injector on rig floor. Pull CT over to rig floor, stab injector, cut coil, install CTC. RU hard line to blow down CT into tiger tank. PT same. Circulate & displace CT with 2% KCI. RU N2 pumpers. PJSM. Pump N2. Cut coil, remove CTC. Unstab & pull CT back to reel, secure CT. Drop reel. PT lines in cellar, PJSM for well kill Kill well with 2% KCL 5 bpm @325 psi. One full circulation Monitor well slight flow. Well out of balance, U tube well. A little oil and diesel strung out due to holes in tubing. Pull tree cap and blow down lines. Set BPV. Bleed off control lines, RD choke and kill lines. ND tree. Set BPV. Install FMC Blanking plug 5.5 turns. NU 11" x 13-5/8" DSA, 13-5/8" x 11" drilling spool & position 11" BOP stack in cellar. (Spacer spool used to remedy interference of FMC blanking plug wI lowest set of rams) Tech limits, PJSM. NU 11" BOPE. This is the 1 sttime to NU this BOP stack, requiring extra time to dress. Riser is a tight fit with the DSA and extra drilling spool. BOPE top down: Annular, Shaffer double gate, flow cross, Hydril single gate 5-112" pipe rams. RU hydraulic control lines. Cut hole in test joint. Mu test joint. Continue to NU 11" BOPE. Test BOPE. Witnessing of test waived by John Crisp AOGCC. 00:50 hrs 10-18-03. RD floor. Prep to pull blanking plug, Pull FMC blanking plug. RU lubricator. Pull BPV. RD Lubricator, (NB: Floor hand noticed slow leak on IA flange, tightened studs which were relatively loose and leak stopped. Good catch by floor hand while walking around cellar.) Back out LDS. DECOMP PU landing jt. MU into tubing hanger, unseat hanger, PU, up wt= 150K, slack off= 135K Ibs. DECOMP Monitor well, u-tubing up backside. RU to circulate down tubing and displace freeze protect fluid on backside, 5bpm, 1500psi on pumps. (much higher press than we saw yesterday on pumps, check pumps, pumps look good.) Pump press gradually dropped down to 25Opsi. PU wt dropped off to 10K at some point after pumping started. Hmm. PU again, up wt = 15Ok, slack off= 135K. Looks like we are free. 18:00 - 18:30 0.50 RIGU P PRE 18:30 -19:30 1.00 BOPSUR P PRE 19:30 - 22:30 3.00 BOPSURP PRE 22:30 - 23:30 1.00 BOPSURP PRE 23:30 - 00:00 0.50 BOPSURP PRE 10/1712003 00:00 - 02:30 2.50 BOPSUR P PRE 02:30 - 04:00 1.50 BOPSURP PRE 04:00 - 06:00 2.00 BOPSURP PRE 06:00 - 06:30 0.50 BOPSUR P PRE 06:30 - 00:00 17.50 BOPSURP PRE 10/1812003 00:00 - 01 :00 1.00 BOPSURP PRE 01:00 - 05:00 4.00 BOPSURP PRE 05:00 - 06:30 1.50 BOPSURP PRE 06:30 - 09:00 2.50 BOPSUR P PRE 0.75 PULL P 09:45 - 11 :00 1,25 PULL P Printed: 11/1212003 11:02:42 AM ,., - ',,-- - BP Operations .summary'Report Page2of11 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-33 07-338 REENTER+COMPlETE NORDIC CALISTA NORDIC 2 Start: 10/15/2003 Rig Release: 11/6/2003 Rig Number: N2 Spud Date: 5/18/1988 End: 11/6/2003 Date From- To Hours Task Code NPT Phase Description of Operations 10/1812003 11:00 -13:30 2.50 PULL P DECOMP Circulate the long way. 8bpm, 250psi on pumps. Retums cleaned up after a few minutes. Pump 1.5 x tubing volume to chemical cut, approx 1000bbls. Load Camco Spooler, secure same on rig floor. Monitor well, no flow. 13:30 - 14:00 0,50 PULL P DECaMP LD Tubing hanger. 14:00 - 18:00 4,00 PULL P DECOMP Pull 5-112" 17" LTC tubing. LD 30jts by 18:00. 18:00 - 21:00 3.00 PULL P DECOMP PJSM. Install thread protectors on 30 joints and remove from pipe shed. Clear ice from derrick. 21 :00 - 00:00 3.00 PULL P DECOMP Continue to LD tubing to SSSV. 57 of 59 bands recovered. 10/1912003 00:00 - 06:00 6.00 PULL P DECOMP Continue to LD 5-112" LTC tubing. LD 165jts at 06:00. 06:00 - 06:30 0.50 PULL P DECOMP PJSM. 06:30 - 11 :30 5.00 PULL P DECOMP Continue LD 5-112" LTC tubing. Recover 251-112 jts. of 5-112" tubing and 1 addtional band for a total of 58 of 59 bands. Chemical cut is clean, OD= 5.53" ,length = 19.12'. 11 :30 - 15:00 3.50 BOPSUR P DECOMP Set test plug, drain stack. Changeout 5-112" Hydril rams for 3-112", Test plug leaked. Simops: Change out horses head in reel house. 15:00 - 16:00 1.00 BOPSUR N RREP DECOMP Pull FMC test plug, replace seal element, drain stack, re-run test plug. Failed 2nd time to test. 16:00 -17:00 1.00 BOPSURP DECOMP Load pipe shed with 3-1/2" WTS 6 Work string, PT Bottom set of 3-1/2" rams and top set of variables. Pull test plug. 17:00 - 22:00 5.00 BOPSUR P DECOMP Change seals on test plug and retest.Get test on lower and variable rams. 22:00 - 00:00 2.00 BOPSURP DECOMP Continue to load drill pipe into pipe shed. 10/2012003 00:00 - 04:00 4.00 CLEAN P DECOMP Continue to load DP into pipe shed and tallying pipe. 04:00 - 05:30 1.50 CLEAN P DECOMP Load XO and floor valve. Install wear ring, Load 5,5" tubing & thread protectors onto truck for retum to stores, 05:30 - 06:00 0.50 CLEAN P DECOMP Conitinue loading pipe shed with 3-112" WTS 6 work string. 06:00 - 06:30 0.50 CLEAN P DECOMP PJSM 06:30 - 10:30 4.00 CLEAN P DECOMP Load pipe shed with 4-3/4" DC's, finish tubing tally and PU Baker tools to rig floor. 10:30 - 12:00 1.50 CLEAN P DECOMP PU kelly swivel and stand back kelly. 12:00 - 12:30 0.50 CLEAN P DECaMP PJSM 12:30 - 13:30 1.00 CLEAN P DECaMP MU BHA #1: Casing scraper / overshot run, 13:30 -15:00 1.50 CLEAN P DECaMP PU 6x 4-3/4" spiral DC's 15:00 - 20:00 5.00 CLEAN P DECOMP RIH with BHA #1 on 3-1/2" WTS 6 workstring. 20:00 - 21 :30 1.50 CLEAN N RREP DECOMP Upper air boot failed. Attempt to replace. NO GO. Pack it off with silicone and soft line, Using trash pump to keep fluid level below the boot until the silicon set up. 21 :30 - 00:00 2,50 CLEAN P DECOMP Continue to RIH. 1012112003 00:00 - 00:30 0.50 CLEAN P DECOMP Continue to RIH, 155 joints. Identify asphaltenes and pariffin in returns, 00:30 - 01 :00 0.50 CLEAN P DECOMP Reverse circulate, bottoms up @ 4bpm, 760 psi. 01:00 - 06:30 5.50 CLEAN P DECOMP Continue to RIH. 06:30 - 07:30 1.00 CLEAN P DECaMP Hook-up standpipe, tighten connections on kelly hose. 07:30 - 08:30 1.00 CLEAN P DECOMP RIH with 3-112" WTS 6 work string. 08:30 - 10:00 1.50 CLEAN P DECOMP PU kellly on joint #311. 10:00 - 10:30 0.50 CLEAN P DECaMP Resume RIH with 3-112" WTS 6 work string. 10:30 - 12:40 2.17 CLEAN P DECaMP Tag at 10033'. (23' down kelly on jt #312) Up wt 107K, Dn wt 75K. Pu and rotate, 90K string wt rotating @ 70RPM (210Amps), 3bpm, 380psi. Rotate over stub and dress, swallow 9' and call it good. Never saw it pressure up but did see 2500 Ib overpull twice when PU while dressing the stub. Printed: 11/1212003 11:02:42 AM ..., .. BP Operations Summary Report Page 3 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/15/2003 11/6/2003 N2 Spud Date: 5/18/1988 End: 11/6/2003 Date From- To Hours Task Code NPT Phase Description of Operations 10/21/2003 10:30 - 12:40 2.17 CLEAN P DECOMP Wanted to see no-go with 10.7' swallowed but did not want to mill down to get there. 12:40 - 16:15 3.58 CLEAN P DECOMP PU 15' above tag and reverse circulate 100k LSRV pill to clean wellbore. Initial 7.0 BPM, 2800 psi. Final 7.0 BPM; 2300 psi, Fair amount of paraffin and dark silty debris. 16:15 - 16:45 0.50 CLEAN P DECOMP Retag dry 10042'. Clean in and out. 16:45 - 18:00 1.25 CLEAN P DECOMP Standback kelly. 18:00 - 00:00 6.00 CLEAN P DECOMP POH LD PH-6 DP. 10/22/2003 00:00 - 08:30 8.50 CLEAN P DECOMP Continue to POH and LD 3,5" DP. 08:30 - 12:00 3,50 CLEAN P DECOMP LD BHA. Recovered one SSSV band. Boot baskets full of paraffin/asphaltenelsilt and moderate amount of metal, Inside of overshot contained about a foot of paraffinlasphaltene (probably from debris external to tubing stub - we tagged dry twice and did not circulate again). Cutrite inside overshot had wear to 6-1/4" OD - not really telling us anything here since we were spinning. Overshot gaged to 5-9/16"ID (5-5/8" tool would not pass through), 12:00 - 13:00 1.00 RUNCOM> COMP PJSM .Pull wear ring, and set test plug, sim ops while continueing to load pipe shed. 13:00 - 14:30 1.50 RUNCOM> COMP Load pipe shed while drifting and strapping tubing. 14:30 - 15:30 1,00 RUN COM> COMP PJSM with PEAK to lift casing equipment to rig floor with crane, Lift equipment per plan. 15:30 - 17:30 2,00 RUNCOM> COMP Continue to load pipe shed. Sim ops Change out lower pipe rams and PU 4-1/2" test joint. 17:30 - 18:30 1,00 RUN COM> COMP Continue to load pipe shed. Sim ops Test rams to 3500 psi. OK 18:30 - 00:00 5.50 RUNCOM> CaMP Continue to load pipe shed, Sim ops RU stabbing board, Install long bails, load GLM and completion equipment. 10/23/2003 00:00 - 04:30 4.50 RUNCOM> COMP Continue to load pipe shed while sim ops RU floor for the casing crew. 04:30 - 05:00 0.50 RUNCOM> COMP PJSM running completion. 05:00 - 05:30 0.50 RUNCOM> COMP Run 4.5" 13% Cr completion. 05:30 - 07:00 1.50 RUNCOM> COMP Tech limit and pre-job meeting with day crew. 07:00 - 18:00 11.00 RUNCOM> COMP Run 4.5" 13% Cr completion. 18:00 - 00:00 6.00 RUNCOM>.l WAIT COMP Placed casing crew on standby to allow rest. They had worked 16 hours and all backup casers were commited to other operations. Clean rig. Remove excess thread protectors from floor. 10124/2003 00:00 - 00:30 0.50 RUNCOM> CaMP PJSM with casing crew. Restart of operation with crew changeout. 00:30 - 07:00 6,50 RUNCOM> CaMP Continue to run 13% Cr completion. 16-18 jts per hour. 07:00 - 10:00 3.00 RUN COM> CaMP Wt chk above tubing stub 92k171 k. Hook-up head pin. Est circ at 2.0 BPM; 50 psi. RIH and lost/regained a little weight at 10030' and then sat down solid at 10035'. No change in circ pressure. Increase rate to 3.0 BPM; 80 psi. Repeat - same bobble and set down depths with no pressure response. Orient pipe 2-1/2 turns (net 1-3/4). Set down same spots - no pressure change. Orient again. Same results. Set about 1-2k down; rotate 5 turns (net 3-1/2). Slack off, but no further progress downhole. Repeat no change, 10:00 -10:45 0.75 RUNCOM> COMP Space out wih pups for comfortable slickline working height and to be 2' shallow to stack-out depth. 10:45-11:00 0.25 RUNCOM> COMP Safety meeting with wireliners, Printed: 11/1212003 11:02:42AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date - .. "- - BP Operations Summary Report 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Page 4 of 11 Start: 10/15/2003 Rig Release: 11/6/2003 Rig Number: N2 Spud Date: 5/18/1988 End: 11/6/2003 From - To Hours Task Code NPT Phase DescriptionofOþerations 10/24/2003 11:00 - 17:30 6.50 RUNCOMII DPRB COMP 17:30 - 21:30 4.00 RUNCOMII DPRB COMP 21:30 - 23:00 1,50 RUNCOMII DPRB COMP 23:00 - 23:30 0.50 RUNCOfvP CaMP 23:30 - 00:00 0.50 RUNCOfvP CaMP 10/2512003 00:00 - 05:00 5.00 RUNCOfvP COMP 05:00 - 06:15 1.25 RUNCOfvP COMP 06:15 - 07:00 0.75 RUNCOfvP COMP 07:00 - 07:30 0.50 RUNCOfvP COMP 07:30 - 07:45 0.25 RUNCOfvP CaMP 07:45 - 08:00 0.25 RUNCOfvP COMP 08:00 - 09:15 1.25 RUNCOfvP COMP 09:15 -11:30 2.25 RUNCOfvP COMP 11:30 -12:15 12:15 - 12:45 12:45 - 18:00 18:00 - 22:30 22:30 - 23:00 23:00 - 00:00 0.75 RUNCOfvP COMP 0.50 RUNCOfvP 5.25 BOPSUR P 4.50 BOPSURP 0.50 BOPSUR P 1.00 BOPSUR.P COMP COMP COMP COMP WEXIT RU slickline. RIH and latch RHC sleeve at 9977' SLM. POOH, RIH with 3.70"x 11' drift. Tag 10042' SLM. Depths suggest we are likely tagging at the top of the tubing stub and the tubing stub is swallowed inside the overshot. Sticky on PU - also believable with the quantity of paraffin seen inside the overshot from the dressing run. Work drift to 10050', sticky on each PU. POOH. RIH with 3.50" x 10' drive down bailer. Tag 10062', Beat down four times and fell through to 10082' (top of 3-112" deployment sleeve). POOH, Bailer nearly fully packed with a mix of a gritty substance that feels like fine sand and paraffin, ashphaltenes, rubber, metal. MU PDS memory GRlCCUcaliper. Log well. POH. Down load data, Log shows Overshot 3' over stub. RIH and set RHC plug, PJSM for well displacement to inhibited seawater. Reverse circulate 3 bpm. 50 bbl Hi Vis, 300 bbl140 degree seawater. 400 bbl140 degree inhibited seawater. Reverse circulate hi vis pill 50 bbls, 300 bbls of 140 deg seawater, 400 bbl inhibited 140 deg seawater with 25 gaV100 bbl Corexit corrosion inhibitor; 3bpm at 240 psi. Retag to confirm spaceout. No Change. Space-out and land hanger, leaving overshot 2' above no go. RILDS. RD tubing running equip, Close bag on LJ. PT body seals on hanger from above by pressuring stack thru kill line to 3500 psi - no leak past body seals. RU HBR on IA. Safety meeting. Reverse 140 bbls crude for FP at 3.0/1250. Drop ball/rod. IA = 180 psi. Pressure tubing to 3480 psi (lAP = 250) to set packer and test tubing. Lost 50 psi to 3430 psi in 30 minutes. No change in lAP. Bleed tubing to 1500 psi. Pressure test IA as follows: Time (min) Tubing P lAP OAP Initial 1520 200 65 Pressure-up IA 0 2060 3400 450 15 2030 3115 405 Re-pressure IA 0 2080 3450 450 15 2040 3220 395 30 2030 3175 375 Bleed pressures, RD HBR. Use Dowell crane to remove Nabors tongs and handling equipment from floor. LD landing joint. Set TWC. ND BOPE. NU and test tree, PJSM for stack installation, NU 7" BOPE. ( annular, blinds, 2" combi, cross, 2-318" combi, Printed: 11/1212003 11:02:42 AM / ~-- .. ... BP Operations Summary Report Page 5 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/15/2003 Rig Release: 11/6/2003 Rig Number: N2 Spud Date: 5/18/1988 End: 11/6/2003 Date From -To Hours Task Cooe NPT Phase Description of Operations 10/25/2003 23:00 - 00:00 1.00 BOPSURP WEXIT 2" combi) 10/26/2003 00:00 - 02:00 2.00 BOPSURP WEXIT NU T' BOPE. ( -1 hour daylight savings time applied) 02:00 - 08:00 6.00 BOPSURP WEXIT Test T' BOPE. Witnessed by Jeff Jones AOGCC representative. 08:00 - 09:00 1.00 BOPSUR P WEXIT Pull ìWC. 09:00 - 10:00 1.00 RUNCOfvP COMP Clear pipe shed of extra tubulars. 10:00 - 14:30 4.50 RUNCOfvP COMP RU slickliners. Safety meeting. Latch and pull ball/rod from 9974' SLM. POOH. Latch and pull RHC sleeve from 9978' SLM, POOH and RD slickline. 14:30 - 15:30 1.00 BOPSUR P WEXIT PU injector. Change packoff. 15:30 - 17:30 2.00 BOPSURP WEXIT Stab pipe. 17:30 - 23:00 5.50 BOPSUR N SFAL WEXIT Reverse to fill coil. Pump at 3.5 bpm 4800 psi for slack management. Slack management to include pumping suffient cable out of reel to allow attachment of cable to bulkhead, Unable to get cable to move by reversing. Circulated 3,5 bpm wire and got some movement. Try reversing again. NO GO, Decision made to swap reels. 23:00 - 00:00 1.00 BOPSURN SFAL WEXIT Blow down reel with nitrogen. 10/27/2003 00:00-01:15 1.25 BOPSUR.N SFAL WEXIT Continue to blow down reel with N2. 01:15 - 01:30 0.25 BOPSURN SFAL WEXIT PJSM, for pulling CT back to reel. 01 :30 - 02:00 0.50 BOPSURN SFAL WEXIT Pull CT back to reel and secure. 02:00 - 06:30 4.50 BOPSURN SFAL WEXIT Perform reel swap, RU hard lines to reel. Restring cables to pull coil to injector. 06:30 - 06:45 0.25 BOPSUR N SFAL WEXIT Safety meeting. 06:45 - 08:00 1.25 BOPSUR N SFAL WEXIT Pull coil to injector; stab pipe. 08:00 - 09:00 1.00 BOPSUR P WEXIT Man down/rig evacuation drill, 09:00 - 10:15 1.25 BOPSUR N SFAL WEXIT Install Roll-on CTC. 10:15 - 12:15 2.00 BOPSUR N SFAL WEXIT Fill coil with 160 deg water at 0.5 BPM. 12:15 - 13:45 1.50 BOPSURP WEXIT Reverse to add slack into the cable. Cut back 35' to find cable. 13:45 - 16:15 2.50 SìWHIP P WEXIT Install CTC. Install E-head. Pull test. Pressure test. 16:15 - 17:00 0.75 SìWHIP P WEXIT MU clean-out BHA - full drilling package, Weatherford motor, 2.74" OD parabolic diamond mill. 17:00 - 19:00 2.00 SìWHIP P WEXIT RIH with circ sub open, pumping 2.7 BPM; 4000 psi to shift slack forward. RIH to 10,000 with out pump. Circulate .5ppb bio at 2.3 bpm and 3700 psi. RIH to 10,850'. No Problem, 19:00 - 19:30 0.50 SìWHIP P WEXIT Circulate 2.5 3,450 psi. 19:30-21:00 1.50 SìWHIP P WEXIT POH chasing 30 bbl 3#lbbl pill, 21:00 - 21:30 0.50 SìWHIP P WEXIT LD bit and motor. 21 :30 - 22:00 0.50 SìWHIP P WEXIT Make up whipstock setting assembly. 22:00 - 00:00 2.00 SìWHIP P WEXIT RIH with whipstock setting assembly, 10/28/2003 00:00 - 00:45 0,75 SìWHIP P WEXIT Tie -in. Correct depth (-3'), 00:45 - 01 :00 0.25 SìWHIP P WEXIT RIH to 10,808.8' placing top of Whipstock at 10,800'. 01 :00 - 01:10 0.17 SìWHIP P WEXIT Orient 165 R. Close circulation sub and pressure to 2670 psi to shear off. Set Down 5K. No movement. 01:10- 03:00 1.83 SìWHIP P WEXIT POH. Flag pipe at 10650 EOP. Continue to POH to surface. 03:00 - 03:45 0.75 SìWHIP P WEXIT LD whipstock running tool and PU milling BHA: HCC diamond whipstock mill and diamond string reamer 03:45 - 05:45 2.00 SìWHIP P WEXIT RIH. Correct depth to flag (-4') 05:45 - 11 :30 5.75 SìWHIP P WEXIT RIH and tag TO whip (essentially the pinch point) at 10799.5' dry. FS = 1,7/2100. Time mill most ofthe window at about 0.1 - 0,2 ft every 15 minutes, seeing 100 - 200 psi MW each step. At 10803.7', got a spike in MW and weight loss - may be bottom of window, Control mill, limiting MW to 400 psi and Printed: 11/1212003 11:02:42 ÞN. ..., . ',- BP Operations Summary Report Page 6 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/15/2003 Rig Release: 11/6/2003 Rig Number: N2 Spud Date: 5/18/1988 End: 11/6/2003 Date From.. To Hours Task Code NPT Phase Description of Operations 10/2812003 05:45 - 11 :30 5.75 STWHIP P WEXIT WOB to 1200 lb. Calling bottom of window at 10805'. 11 :30 - 13:00 1.50 STWHIP P WEXIT Drill formation from 10805' to 10815'. 13:00 -14:00 1.00 STWHIP P WEXIT Dress window area. Dry pass through window without problems. Start swap to Flo-pro mud. 14:00 - 14:30 0.50 STWHIP P WEXIT Circulate new mud to surface. 14:30 - 16:00 1.50 STWHIP P WEXIT TOH 16:00 - 17:00 1.00 DRILL P PROD1 UD window milling BHA and P/U bulid BHA 17:00 - 19:10 2.17 DRILL P PROD1 TIH correct to flag TIH to 10790' 19:10 -19:20 0.17 DRILL P PROD1 log tie-in -5" correction. 19:20 - 00:00 4.67 DRill P PROD1 Tag bottom at 10815'. Up wt 31k dwn 21k Directionally drill build section f/10815'1.4bpm, free-spin 2800psi 300psi MW. T oolface 170R. Slow drilling with frequent motor stalls. Drill ahead following plan to 10860'. 10/29/2003 00:00 - 03:25 3,42 DRill P PROD1 Continue drilling build section f/10860'. Better drilling starting at 10877' and increase pump to 2.0bpm Free-spin 3200 psi 600-7oopsi MW drilling 50'/hr Drill to 10941', 03:25 . 03:35 0.17 DRILL P PROD1 Wiper trip to window, 03:35 - 06:00 2.42 DRill P PROD1 Continue drilling ahead with build section, 0600 depth 11060' 06:00 - 09:00 3,00 DRILL P PROD1 Fin drilling buildlturn 1.8/3800130-60R at 11160' 09:00 - 09:30 0.50 DRILL P PROD1 Ream high DlS area 09:30 -11:30 2.00 DRill P PROD1 POOH for lateral assy 11:30-12:00 0.50 DRILL P PROD1 lD drilling BHA. Bit was 3-1-RO 12:00 - 13:30 1,50 DRILL P PROD1 Pump back slack. Cut off 100' CT due to chrome tbg management. Rehead DS CTC. PT 3500, 30k 13:30 - 15:00 1.50 DRILL P PROD1 Rehead BHI, MU BHA 15:00 -16:50 1.83 DRILL P PROD1 RIH wi BHA #f3 (1.1 deg motor) 16:50 - 17:30 0.67 DRILL P PROD1 Log tie-in down from 10780', COrr -7'. log RA marker to tie into mother WB and found at 10807' 17:30 -18:00 0.50 DRILL P PROD1 RIH to bottom 18:00 - 20:00 2.00 DRill P PROD1 Directionally drill remainder of build section f/11160' to 11193' (8907'tvd). Continue drilling ahead with lateral @ 1.8 bpm 3300 psi FS ( 9.6ppg ECD) 300-4oopsi MW, 2k WOB @ +1- 50'/hr ROP. Drilled to 11224'. 20:00 - 20:25 0.42 DRilL P PROD1 Wiper trip to window. Stacked out 11143' p/u and went through okay. TF was at 120R. 20:25 - 22:25 2.00 DRILL P PROD1 Continue drilling ahead f/11224' to 11332'. Starting to stackout. 22:25 - 23:00 0.58 DRILL P PROD1 Wiper trip to 10825', 23:00 - 00:00 1.00 DRILL P PROD1 Continue drilling ahead f/11332'. Good weight transfer. 7CÞ80'lhr w/1-2k wob, Drilled to 11407'. 10130/2003 00:00 - 03:45 3.75 DRILL P PROD1 Continue directionally drilling ahead f/11407' @ 1.7bpm 3380psi free-spin 400-500psi MW. Drilled to 11541', 03:45 - 04:35 0.83 DRILL P PROD1 Wiper trip to 10830'. No problems at 11140' area. 04:35 - 06:00 1.42 DRILL P PROD1 Drill ahead f/11541'. 1-2k wob 50-60'lhr, 0600 depth 11630'. 06:00 - 07:00 1.00 DRill P PROD1 Drill from 11630' 1.75136oo/8CÞ120R to 11715' 07:00 - 07:35 0.58 DRill P PROD1 Wiper to window 07:35 - 08:50 1.25 DRilL P PROD1 Drill from 11715' 1.9/4000/120l to 11823' and stacking from formation change and wom out mud. Inadvertnetly build angle when trying to hold at 8920' TVD 08:50 - 09:15 0.42 DRILL P PROD1 Wiper to window 09: 15 - 09:25 0,17 DRill P PROD1 log tie-in to RA marker, add 4,0' 09:25 - 09:45 0,33 DRILL P PROD1 RBIH-a little motor work thru 11140-180' 09:45 - 11 :30 1.75 DRILL P PROD1 Drill from 11823' 1.8/3750/120L to 11872' and stacking and seeing shale now on GR while dropping angle to hold at 8920' Printed: 1111212003 11 :02:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .., - "-- - BP Operations Summary Report Page 7 of 11 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/15/2003 Rig Release: 11/6/2003 Rig Number: N2 Spud Date: 5/18/1988 End: 11/6/2003 Date From-To Hours Task Code NPT Phase Description of Operations 10/3012003 09:45 - 11 :30 1.75 DRILL P PROD1 TVD 11 :30 - 12:50 1.33 DRILL P PROD1 Drill from 11872' 1, 7136OO/120L and start new mud. Struggle to make hole in a shale at 8920' TVD and sand must have pinched out. Drill to 11892' 12:50 - 14:05 1.25 DRILL P PROD1 Drill from 11892' 1.8/3650/1 OL and head to new target sand intervals between 8907-12' TVD. Drill to 11916' and still slow progress in shale 14:05 - 15:05 1.00 DRILL P PROD1 Wiper to window 15:05 -17:15 2.17 DRILL P PROD1 Drill from 11916' 1.75/3450/10L w/ neg wt in shale to 11970' 17:15 - 18:30 1.25 DRILL P PROD1 Drill from 11970' 1,75/3550/90L w/ neg wt in shale to 11997' then ROP> to +100'/hr appear to be back into sand. 18:30 -19:15 0.75 DRILL P PROD1 Drill f/11997' to 12100'. 19:15 - 20:15 1.00 DRILL P PROD 1 Wiper trip to 10825' 20:15 - 22:00 1.75 DRILL P PROD1 Directionally drill ahead f/12100' to 12261' 1.7bpm 3550psi FS 300-4oopsi MW 1-2k wob 22:00 - 23:35 1.58 DRILL P PROD1 Wiper trip 23:35 - 00:00 0.42 DRILL P PROD1 Directionally drill ahead to 12300'. 10/31/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Continue to drill ahead with lateral section from 12300'. 1.7bpm 3600spi FS 400 psi MW 1-2k wob. Slow drilling in ratty formation. Drill to 12330'. 01:00 - 01:30 0.50 DRILL P PROD1 Wiper trip 400', Bleed IA f/1 OOOpsi down to 400psi. 01 :30 - 02:00 0,50 DRILL P PROD1 Dril f/12330' to 12388' back into fairly good sand. But having weight transfer problems. 02:00 - 03:10 1.17 DRILL P PROD1 Wiper trip to window. 03:10 - 04:40 1.50 DRILL P PROD1 Drill f/12388' to 12420'. Having trouble with weight transfer, Numerous short wiper trips. Finally getting to the point of not making any progress. Still appear to in sand. Clean pick-ups of 32.2k able to get small amount of WOB with -7k CTW. Ordered new mud system. Will TOH in the meantime just to check BHA for any problems. 04:40 - 07:10 2.50 DRILL P PROD1 TOH 07:10 - 08:10 1,00 DRILL P PROD1 Chk bit, motor. Bit was 1-1-BU, motor appeared okay. Change both 08:10 - 10:10 2.00 DRILL P PROD1 RIH w/ BHA #7 10:10 - 10:25 0.25 DRILL P PROD1 Log tie-in to RA marker. Corr -8' 10:25-11:15 0.83 DRILL P PROD1 Precautionary ream to TD, clean and tag at 12421' 11:15 -11:45 0.50 DRILL P PROD1 Drill ahead slowly w/ neg wt due to probably in 13N (confirmed later by GR) and near lockup at 1.8/3800/170R while pointing TF down to get back into 30 api sand. Drill to 12448' 11 :45 - 15:00 3.25 DRILL P PROD1 Start new mud, Drill from 12448' 1.8/3760/90L and level out in a 30 api sand at 8893' TVD. Fresh mud did not make an immediate/obvious difference so are definitely nearing lockup. Continue drilling at avg 40'/hr w/ neg wt. Ideal TD will be +/-12720', Drill to 12530' and stacked 7k w/ no motor work or progress-the end is near. , Inspect derrick for ice buildup-none found. Temp is 35 deg and snow on Pad has nearly melted down to gravel! 15:00 - 16:20 1.33 DRILL P PROD1 Wiper to window, clean. RBIH and set down at 11140'. RIH to TD tagged at 12529' 16:20 - 18:30 2.17 DRILL P PROD1 Drill from 12529' 1.8I3580190L at 30-40'/hr in nice 30 api sand hoping to get to a revised/acceptable TD of 12625' before total lockup. Drilled to 12573' only with difficulty. Pick-ups adding to coil life quickly in spots. Printed: 11/1212003 11:02:42AM ,., -- ~ ~' BP Operations Summary Report 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-33 07 -338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/15/2003 11/6/2003 N2 Spud Date: 5/18/1988 End: 11/6/2003 Date From - To Hours Task Code NPT Phase Description, of Operation$ 10/31/2003 18:30 - 19:15 0.75 DRill P PROD1 Short 500' wiper trip. 19:15 - 20:00 0.75 DRill P PROD1 With -5k CT weight drilled ahead f/12573' to 12586'. Good MW 3-4oopsi but quickly dropped off and no WOB seen. Try to pick-up for another short wiper trip but diiferentually stuck. 20:00 - 23:00 3.00 DRill N STUC PROD1 Work pipe w & wo pump. Slack off to neutral weight and wait. No luck. Call for crude. Continue working pipe and relaxing pipe while waiting for crude. After 45 minutes of no movement or pumping tried to pull up before pumping crude and pipe came free. 23:00 - 00:00 1,00 DRill P PROD1 Wiper trip to window. Tae-in at RA tag -13' correction. 11/1/2003 00:00 - 01 :40 1.67 DRill P PROD1 Wiper trip to condition hole for liner. RIH tagged at 11135' with TF at 60L orient to SOL went through. Work this area. Continue RIH to bottom at 12585'. 01 :40 - 05:00 3,33 DRill P PROD1 TOH laying in 1:1 new FIo-Pro mud in openhole. Continue TOH to surface, RBIH to 1000' displace hole to water for running liner. 05:00 - 06:00 1.00 DRill P PROD1 Unstab injector continue flushing coil wI methanol. UD BHA. 06:00 - 08:30 2.50 CASE P COMP Safety mtg re: pull CT back on reel Install internal grapple and pull CT back to reel using tugger. Set back injector for running liner. Prep eline reel for swap 08:30 - 08:45 0.25 CASE P COMP Safety mtg re: SIMOPS 08:45 -12:00 3.25 CASE P COMP MU 62 jts 2-3/8" 4,7# l-80 STL liner with float equipment, pup. Drift each connection at 1.90" Lower eline spool onto lowboy. Install cementing spool in reelhouse and RU 12:00 - 12:45 0.75 CASE P COMP MU Baker Deployment Sleeve and set combi 2-3/8". Install CTLRT assy 12:45 -13:45 1.00 CASE P COMP Pull CT to floor and stab into injector 13:45 - 15:00 1,25 CASE P COMP Dress CT stub and install weld-on CTC wI 1.125" 10. PT 35k 15:00 - 16:30 1.50 CASE P COMP RU dart catcher, Fill CT wI FW (had a few ice plugs). Load wiper dart and chase wI mud. Dart landed at 38,9 bbls. RD test equipment. PT CTC at 3500 psi 16:30 - 16:45 0.25 CASE P CaMP Stab CT onto CTLRT. Haul dummy to floor. Open combi rams, Stab onto lubricator 16:45 - 17:00 0.25 CASE P COMP RIH wI liner on CT. 17:00 - 18:00 1.00 CASE P CaMP Park at 3500', circ at min rate Conduct man-down drill under Herb Williams guidance and conditions-see his report 18:00 - 19:30 1.50 CASE P CaMP Resume RIH. Check up wt at window 33k dwn 15k. Continue RIH no problem at 11140', stacking out f/11730 to 12005', Gave AOGCC 24 hr notice of pending BOP test. Witnessing wavied by Chuck Scheve. 19:30 - 00:00 4.50 CASE N DPRB CaMP Work this area and continue to 12517', Pick-up and continually lose footage back to 12100'. P/U to 11970 this puts TOl in the 41/2" tbg. Circulate for 10 min. RBIH and stopped at 12460'. Unable to work down, PIU to 11950' and circulate again. RBIH and again stopped at 12460' area. P/U again this time to 11500' and circulate for 20 min. 11/2/2003 00:00 - 00:40 0.67 CASE N DPRB COMP Continue working liner to bottom, RBIH after circulating at 11500', Stopped at 12416' picked up once and working all the way to bottom 12585'. 00:40 - 02:10 1.50 CASE N MiSe COMP Load and launch 0.625" steel ball. Pump down with 43bbls. Should have hit at 39.9 bbls. Pull cap and check for ball -gone. Printed: 11/1212003 11:02:42 AM //- - - ~ "-~ BP Operations Summary Report Page 9 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/15/2003 Rig Release: 11/6/2003 Rig Number: N2 Spud Date: 5/18/1988 End: 11/6/2003 Date From - TO Hours Task Code NPT Phase Description of Operations 11/212003 00:40 - 02:10 1.50 CASE N MISC COMP Keep pumping to 60 bbl. Increase rate to 2.6 bpm and 4500psi. Check to see if released - nope. Pressure up again to 4800psi at 2.8 bpm plu still not released. Again to 4900psi still not released. 02:10 - 02:35 0.42 CASE P COMP Load and launch another 0.625" ball. On seat at 28.4 bbls plu and release from liner. P/U wt 28k set backdown with full coil weight. 02:35 - 04:00 1.42 CASE P COMP Swap over to 1 % KCL and displace mud. 04:00 - 05:10 1.17 CASE P COMP RIU SLB cementers. 05:10 - 05:20 0.17 CEMT P COMP PJSM review cement procedures. 05:20 - 06:30 1.17 CEMT P COMP PT lines to 4k. Pump 12 bbls cement w/additives. Shutdown clear lines. Load wiper dart. Displace with 20 bbls BioZan followed by 27 bbls KCL water. Dart latched LWP at calc displ. LWP bumped at calc displ. Pressure plug to 2500 psi. Bleed off press and chk floats, ok. CIP 0630 hrs 06:30 - 08:10 1.67 CASE P COMP Unsting from liner wI 300 psi, Diltute 2 bbls excess cement (based on 'ouf MM) with biozan while POOH at planned minimal retums 08:10 - 08:30 0,33 CASE P CaMP LD CTLRT 08:30 - 13:30 5.00 BOPSURP COMP Weekly BOPE test. Witness waived by AOGCC 13:30 - 13:45 0,25 CLEAN P COMP Safety mtg re: Nordic crew change/CSH 13:45 - 16:00 2.25 CLEAN P COMP RU to run 1" CSH. MU 1,875" D331 wI 1-11/16" navidrill motor, MHA. MU 62 CSH singles. MU DS MHA 16:00 - 17:00 1.00 CLEAN P COMP RIH wI BHA #8. Cement compressive strength is 1300 psi 17:00 - 18:00 1.00 CLEAN N RREP COMP RIH at reduced speed while wo mechanics to arrive to fix reel hydraulics 18:00 - 19:00 1,00 CLEAN N RREP COMP Park at 7400'. SLB mechanics looking for problem with hydraulics. Found what appears to be off-drillers side planetary gearing on the reel motor shot. Will replace after cleanout run. 19:00 - 19:40 0.67 CLEAN P COMP Continue RIH tagged cement at 10605'. 19:40-21:30 1.83 CLEAN P COMP Drill cement f/10605' to 10738'. Continue RIH. Tagged at 12530' cleanout to PBTD. 21 :30 - 00:00 2.50 CLEAN P COMP TOH pumping max 1bpm at normal speed. Good amount of cement circulated to surface. 11/3/2003 00:00 - 00:30 0.50 CLEAN P COMP TOH to 1" hydril pipe, 00:30 - 02:00 1.50 CLEAN P COMP Standback 31 stds 1" CSH. 02:00 - 09:30 7.50 CLEAN N RREP COMP Replace output shaft on off-drillers side CT reel motor assembly. 09:30 - 09:45 0.25 EVAL P COMP Safety mtg re: source 09:45 - 11 :35 1,83 EVAL P COMP MU CNL toollMHA on 1 jt 1" CSH. RIH wI 31 CSH doubles 11:35 -13:15 1.67 EVAL P COMP RIH wI BHA #9. Load perf guns in pipeshed 13:15 -13:45 0.50 EVAL N CEMT COMP Log down from 9800' at 60'/min. Tag at 10556' and can't get by. Could be a cement stringer or top of 3-3/16"'iner at 10533' 13:45 - 15:00 1.25 EVAL N CEMT COMP POOH 15:00 -16:15 1.25 EVAL N CEMT COMP Standback CSH 16:15 -16:25 0.17 EVAL N CEMT COMP Safety mtg re: source 16:25 - 16:45 0.33 EVAL N CEMT COMP LD CNL tools and load out 16:45 - 18:00 1.25 EVAL N CEMT COMP Cut off 100' CT (chrome management). Install new weld-on CTC 18:00 - 18:15 0.25 EVAL N CEMT COMP PIU 2.74" mill and motor assembly. 18:15 - 19:45 1,50 EVAL N CEMT COMP RIH. Dry tag at 10530'1 19:45 - 21:00 1,25 CLEAN N CEMT COMP P/U and start cleanout f/1 0500' see MW at 10530' to 10696' and tagged up on liner top. Circulate hi-vis sweep while making Printed: 11/1212003 11:02:421W. / - ( ., - '~ ---; BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1113/2003 11/4/2003 11/5/2003 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 19:45 - 21 :00 1.25 CLEAN N CEMT CaMP 21:00 - 23:30 2.50 CLEAN N CEMT CaMP 23:30 - 23:45 0.25 CLEAN N CEMT CaMP 23:45 - 00:00 0,25 EVAL N CEMT CaMP 00:00 - 01 :40 1,67 EVAL N CEMT COMP 01 :40 - 03:45 2,08 EVAL N CEMT COMP 03:45 - 05:00 1.25 EVAL P COMP 05:00 - 07:10 2.17 EVAL P COMP 07:10 - 08:15 1,08 EVAl P COMP 08:15 - 08:30 0.25 EVAL P COMP 08:30 - 09:10 0.67 EVAL P COMP 09:10 -10:30 1.33 EVAL P COMP 10:30 - 15:00 4.50 PERF N WAIT COMP 15:00 -15:15 0.25 PERF P CaMP 15:15 -17:50 2.58 PERF P COMP 17:50 - 20:15 2.42 PERF P CaMP 20:15 - 21:15 1.00 PERF P COMP 21:15 - 22:15 1,00 PERF N STUC CaMP 22:15 - 00:00 1.75 PERF N DPRB COMP 00:00 - 01 :00 01:00 - 01 :30 01 :30 - 03:30 1.00 PERF N 0.50 PERF N 2.00 PERF N DPRB COMP DPRB COMP DPRB COMP 03:30 - 04:00 04:00 - 04:45 04:45 - 06:30 0.50 CLEAN N 0.75 CLEAN N 1.75 CLEAN N DPRB COMP DPRB COMP DPRB COMP Page100f 11 Start: 10/15/2003 Rig Release: 11/6/2003 Rig Number: N2 Spud Date: 5/18/1988 End: 11/6/2003 Description of Operations another pass. TOH UD motor and mill. PJSM review logging procedures and BHA handling. Make-up BHA #11 with MCNl. RIH Start logging MCNL from 9800' at 60'/min. Tag at 12535'. Lay-in 125K perf pill and log back to 9800' at 5O'/min. TOH w/ MCNL Standback CSH LD CNL tool PT wellbore to 2000 psi for 30 min with IA and OA both at zero psi. Initial pressure 2030 psi, final pressure 1953 psi. No change to IA or OA. Bleed off press WO CNL results. Fax to town, TOL found at 10688', PBD at 12517'. Receive confirmation to perf based on preliminary program WO SWS perf guns. Perf guns had previously been loaded in pipeshed, Since PBD was found 35' higher than expected, SWS had to drop 35' off of the bottom set and load a partial in shop PJSM discuss perf gun handling precautions. P/U 25 guns and MHA (1911,10') stab on injector. RIH. Correct to flag at 7436 (-10' correction). Continue to RIH. Into 2-3/8" liner no problem. Tag PBTD at 12517'. PU to 12515 btm shot depth. 10k# down, 25.5k# up wt. Pump 5 bbls flo pro pill. Drop ball. Chase with 2 additional bbls flo pro. 1.45 bpm @ 2400 psi. Slow to 1.1 bpm after 30 bbls away, Pump 50 bbls total vol, coil volume only 39.9 bbls. Get up weight and POOH slowly at 1 fpm. Increase rate to 1.45 bpm for several bbls. Bleed coil pressure, then surge same at 1.5 bpm several times. No evidence of guns firing and/or ball on seat. Began to pull heavy while moving up hole. Stuck at 12510'. Try to work pipe down. No movement. Cycle pipe, then pull up to 65K#. No movement. Pressure up coil annulus to check for injectivity. Well bore held solid at 1850 psi. Apparently guns have not fired, Surged coil from pressured up annulus with max pull on pipe. Pipe rattled free. POOH with BHA. Don't know what we are coming out with. Up weight same as PU weight recorded earlier. Discuss importance of not circulating with possible live guns & ball on seat. Continue to POOH with perf assembly #1 . At surface. Get off well. Stand back CS hydrill pipe. At firing head. Hold PJSM to discuss handling guns. Find ball on seat. All guns fired. Lay down same in pipe shed to drain same. Perf ed interval 1st run: 11990-12155, 12320-12415, 12450-12515' with HSD 4 spf Powe~et charges. MU clean out BHA with 1.83" mill. Run 22 stands of CSH out of derrick. Get on well. RIH with clean out assembly. Correct to EOP flag at 9000' a -21'. Printed: 1111212003 11:02:421Wo ~ - "-/ BP Operations Summary Report Page 11 of11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-33 07-338 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/15/2003 11/6/2003 N2 Spud Date: 5/18/1988 End: 11/6/2003 Date From- To Hours Task CodeNPT Phase Description of Operations 11/512003 06:30 - 08:15 1.75 CLEAN N DPRB COMP Start cleanout from 10600'. No problem entering 2 318" liner top at 1 0688' pumping hi-vis sweeps. No motor work seen down to 11985', 08:15 - 09:55 1.67 CLEAN N DPRB COMP TOH to CSH pipe setback injector. 09:55 - 10:50 0.92 CLEAN N DPRB CaMP Standback 21 stds of CSH. UD motor and mill. 10:50-11:50 1.00 PERF P COMP Chrome management. Cut-off 100' of coil. Rehead with weld-on CTC and test same. 11 :50 - 13:50 2,00 PERF P COMP P/U 2nd of 3 perf interval guns. 18 guns 387' with 274' net loaded. Total BHA= 1264.81' Make up injector. 13:50 - 15:40 1,83 PERF P COMP RIH correct to EOP flag correct -28' continue RIH to 11835'. 15:40 - 16:30 0.83 PERF P COMP Load and launch 0.500" aluminum ball. P/U wt 33k down wt 15.8k Pump at 1.4bpm @ 1950psi for first 25 bbl then back off to ,6 bpm @ 470psi. Ball on seat after 35.6 bbls away. Pressure up on seat and same time moving pipe up. Guns fired at 2780 psi. Pipe pulling free..alrs well. Some indication on SLB "Shotlndictor". perf intervals: 11455-11540, 11580-11635, 11695-11830.HSD 4 spf 16:30 - 18:30 2.00 PERF P CaMP TOH pumping across top of hole, Paint EOP flag at 8900'. 18:30 - 19:00 0.50 PERF P COMP At surface. Get off well. Stand back CSH work string, 19:00 - 19:15 0.25 PERF P COMP Hold P JSM with crew before LD perf guns. Discuss hazards & floor personnel requirements. 19:15 - 20:30 1.25 PERF P COMP Remove firing head. LD perf guns. All shots fired. Drain guns in pipe shed. 20:30 - 21:30 1.00 PERF P COMP MU 1-11/16" guns for third run. 21 :30 - 22:00 0.50 PERF P COMP Run guns on 18 joints of CSH from derrick. 22:00 - 00:00 2.00 PERF P COMP MU to coil. Stab on well. RIH with perf assy. 11/6/2003 00:00 - 00:15 0.25 PERF P CaMP Tie into EOP flag at 8900' (-27' correction), Continue in hole to 11400' 32k# up, 16k# down weight. 00:15-01:15 1,00 PERF P COMP Pump 6 bbl flopro pill. Drop 112" aluminum ball. Verify launch. Circulate 30 bbls at 1.4 bpm /1400 psi. Slow to 0.5 bpm. Begin moving up hole at 3 fpm, Ball on seat at 36 bbls. Pressure to 2950 psi, firing head activated. Continue to POOH at 50 fpm. No overpulls inside liner. Shot intervals 11175-11215, 11270-11400, 01 :15 - 03:00 1.75 PERF P COMP Pull out of hole, filling across top. No noticable fluid losses to formation, 03:00 - 03:45 0.75 PERF P COMP At surface. Get off well. Stand back CSH pipe, 03:45 - 05:00 1.25 PERF P COMP Lay down perf guns. All shots fired. Drain guns in pipe shed. Unload pipe shed. 05:00 - 07:30 2.50 PERF P CaMP RIH with CS Hydrill from derrick. 07:30 - 09:30 2,00 WHSUR P CaMP RIH to 2500' and freeze protect well with 38 bbls 60/40 methanol. 09:30 - 10:00 0.50 BOPSU¡;,P POST With swizzle stick wash interior of BOP stack. Functioned rams and checked for cement. 10:00 - 10:15 0,25 DEMOB P POST PJSM review plan forward. Cut 1000' coil and Vd kelly. 10:15 -13:05 2.83 DEMOB P POST Cut 1000' of coil, Coil life over 40% in area needed for next well's fishing operations. 13:05 - 14:30 1.42 DEMOB P POST Break and Vd kelly. Clean mud tanks. 14:30 - 16:30 2.00 DE MOB P POST N/D BOPE install tree cap and test to 50oopsi. Rig released at 1630 hrs 11-06-2003 Printed: 11/1212003 11:02:42AM \ ObP . BP-GDB . Baker Hughes INTEQ Survey Report ~03 -/)~ .ii. IIAKH IUGIIIS INTEQ ... . Company: Field: , Site: Well: Wellpath: BP AnJoco Prudhoe Bay PB DS 07 07-33 07-33B Date: 11120/2003 Time: 10:58:59 Page: 1 Co-ørdinate{NE) Refe..ence: Well: 07-33. True NOrth Ve..tical (I'VD) Referencè: 46 : 335/18/198800:0060.0 Section (VS) Reference: Well (0.00N,O.00E.297,OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0,00 ft Ground Level: 0.00 ft 5948144.78 ft 677382,28 ft Latitude: 70 15 Longitude: 148 33 North Reference: Grid Convergence: 49.847 N 56.934 W True 1,35 deg Well: 07-33 Slot Name: 33 07-33 Well Position: +N/-S 1739.05 ft Northing: 5949868.58 ft Latitude: 70 16 6,950 N +E/-W -621,93 ft Easting : 676719.59 ft Longitude: 148 34 15,037 W Position Uncertainty: 0,00 ft +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0,00 07 -33A 10800.00 ft Mean Sea Level 25.56 deg 80.85 deg Direction deg 297.00 Wellpath: 07-33B 500292180902 Current Datum: 46 : 33 5/18/1988 00:00 Magnetic Data: 10/17/2003 Field Strength: 57579 nT Vertical Section: Depth From (fVD) ft 33,00 Height 60,00 ft Survey Program for Definitive Wellpath Date: 11/20/2003 Validated: Yes Version: 5 Actual From To Survey Toolcode ft ft 100,00 10700.00 Gyro (100.00-11209.00) (0) GCT-MS 10767.00 10767.00 2: MWD - Standard (10767,00-12540.00) (~WD 10800.00 12585,00 MWD (10800,00-12585.00) MWD Tool Name Schlumberger GCT multishot MWD - Standard MWD - Standard Annotation 10767.00 10800.00 12585.00 8710.40 8737.70 8953.59 TIP KOP TD Survey: MWD Start Date: 10/31/2003 Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Engineer: Tied-to: From: Definitive Path RECEIVED ...'.\1- 2 2 Zùû4 ,AtaskaOit& Gas Cons.eommisioo AncMage ~~'bì'Y\~ ObP . BP-GDB . Bií. BAICIIIt IUGIIH Baker Hughes INTEQ Survey Report [NTEQ Company: BP Amoco Date: 11/20/2003 Time: 10:58:59 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-33, True North Site: PB OS 07 Vertical (TVD) Reference: 46: 335/18/198800:0060.0 Well: 07-33 Section (VS) Reference: Well (0.OON,O.OOE,297.00Azi) Wellpath: 07 -33B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD NIS EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10Off 10767,00 33.23 70.99 8710.40 8650.40 3311,92 4672.05 5953289.06 681312.29 -2659.24 0,00 10800,00 35.16 70,38 8737,70 8677.70 3318.06 4689,55 5953295.60 681329.64 -2672.05 5,94 10815.21 33,59 71.00 8750.25 8690,25 3320.90 4697.65 5953298,63 681337,68 -2677.98 10.58 10852,35 21.54 98,35 8783.24 8723.24 3323,27 4714,23 5953301,39 681354.20 -2691.68 46,32 10882.50 24.97 127,28 8811.03 8751.03 3318,60 4724,81 5953296,97 681364.89 -2703.23 39.14 10910.00 23,96 160.21 8836.18 8776,18 3309.79 4731.35 5953288.32 681371,63 -2713.05 49.15 10940.11 33.42 183.54 8862.64 8802,64 3295.68 4732.92 5953274.25 681373,53 -2720,85 48.18 10970,84 44.61 201,60 8886.56 8826.56 3277,09 4728.39 5953255,55 681369.44 -2725.26 51.61 11000,67 55.13 216,62 8905,82 8845.82 3257.40 4717,17 5953235.62 681358.68 -2724,20 52,05 11035.84 60,57 240.61 8924,73 8864,73 3238.09 4694.97 5953215.79 681336.94 -2713,19 59,62 11067.99 65,91 259.16 8939.30 8879,30 3228.39 4668.15 5953205.46 681310.36 -2693,70 54,05 11101.72 69.13 269,12 8952.22 8892.22 3225.24 4637.20 5953201,59 681279,50 -2667.55 28.90 11130,21 76.15 254,16 8960,76 8900.76 3221.24 4610.41 5953196,96 681252,81 -2645.50 55.80 11163,30 85.37 247,08 8966.07 8906.07 3210,39 4579,67 5953185,39 681222,33 -2623.03 34.95 11193,26 89.69 250,88 8967,37 8907.37 3199,66 4551,74 5953174,01 681194.66 -2603.01 19.19 11230,44 89.66 261,83 8967,58 8907.58 3190,90 4515,66 5953164.41 681158,80 -2574.84 29.45 11260.08 85,58 266.38 8968.81 8908.81 3187.86 4486.22 5953160.68 681129.44 -2549,99 20,61 11290.26 88,89 267.03 8970,26 8910,26 3186.13 4456.13 5953158.24 681099.40 -2523,97 11,18 11320,33 91,69 270.55 8970.11 8910.11 3185.50 4426.07 5953156.90 681069.37 -2497.47 14.96 11351.73 92,30 277 .19 8969.02 8909.02 3187.61 4394.78 5953158.28 681038.04 -2468,63 21.22 11382.03 90,77 282.75 8968,20 8908.20 3192.85 4364,96 5953162.82 681008.11 -2439.68 19,03 11410.65 89,88 288.22 8968,04 8908,04 3200.49 4337.39 5953169.81 680980.37 -2411,65 19,36 11440.17 89.79 290,88 8968.13 8908,13 3210.37 4309.58 5953179.03 680952.33 -2382,38 9,02 11470,10 86.93 289,84 8968.98 8908,98 3220,78 4281.53 5953188.78 680924,05 -2352,67 10.17 11500,09 85.95 293.49 8970.85 8910.85 3231,83 4253.72 5953199,17 680895,99 -2322.87 12.58 11530.15 86.47 298.19 8972.83 8912.83 3244.90 4226,73 5953211,60 680868.70 -2292.89 15.70 11560.73 86.16 303.55 8974.80 8914.80 3260.55 4200,55 5953226.63 680842.16 -2262.46 17,52 11591.21 86.75 307.71 8976.69 8916,69 3278.27 4175.83 5953243.76 680817.03 -2232,39 13,76 11620,20 86.53 302,53 8978.39 8918.39 3294.91 4152.16 5953259.85 680792,99 -2203.75 17.85 11650,64 89.63 304.96 8979.41 8919.41 3311,81 4126,87 5953276,14 680767,31 -2173.54 12.94 11681.71 90.00 310.75 8979.51 8919.51 3330.86 4102.35 5953294.62 680742.35 -2143.04 18.67 11710.00 90.28 316.89 8979.44 8919,44 3350.44 4081.95 5953313.71 680721.49 -2115,97 21,73 11740.27 90.37 321,32 8979.27 8919.27 3373,32 4062.14 5953336.11 680701.15 -2087,94 14.64 11770.53 90,98 329.71 8978,91 8918.91 3398,24 4045,02 5953360,62 680683.45 -2061.37 27.80 11800.04 91.62 328.91 8978.24 8918.24 3423.61 4029.96 5953385.63 680667.81 -2036.44 3.47 11830,16 89.57 325,98 8977.93 8917.93 3448,99 4013.76 5953410.62 680651,01 -2010.48 11,87 11860.27 89,54 322.13 8978,16 8918.16 3473,36 3996,09 5953434,57 680632.77 -1983.67 12.79 11890.16 85.57 319,80 8979.44 8919,44 3496.55 3977.28 5953457.31 680613.44 -1956,39 15.40 11924.45 90.49 317,35 8980.61 8920.61 3522,24 3954.62 5953482.46 680590,17 -1924,53 16,03 11956,97 94,67 319.47 8979,15 8919.15 3546,53 3933,06 5953506.23 680568,05 -1894.29 14.41 11987.04 95.50 317.35 8976.49 8916.49 3568.93 3913.18 5953528.16 680547.65 -1866.41 7.55 12021.28 94.58 310.73 8973.47 8913.47 3592.62 3888.67 5953551.27 680522.60 -1833.82 19.45 12054.01 93.35 305,88 8971.21 8911.21 3612.85 3863.06 5953570.89 680496.52 -1801.81 15.25 12082.77 91.84 301.32 8969.91 8909,91 3628.75 3839.13 5953586.22 680472.23 -1773.28 16,69 12110,89 90.00 297.22 8969.46 8909.46 3642.49 3814.61 5953599.38 680447,39 -1745.19 15.98 12142.33 91.60 292.02 8969,02 8909.02 3655,58 3786,05 5953611,80 680418,53 -1713.79 17.30 12170.56 93.13 289.75 8967.85 8907,85 3665.64 3759.70 5953621.23 680391.95 -1685,75 9.69 12200.14 93.10 294.12 8966,24 8906.24 3676.67 3732,30 5953631,62 680364.31 -1656.34 14.75 12230.86 93.56 300.23 8964.46 8904.46 3690.67 3705.03 5953644.97 680336.72 -1625.68 19.91 12255.98 94.60 306.02 8962.67 8902.67 3704.35 3684.06 5953658.16 680315.43 -1600.78 23.36 12287,10 94.27 308,98 8960.26 8900.26 3723.24 3659.45 5953676.46 680290.38 -1570,28 9.54 12328,99 96.12 318,63 8956.46 8896.46 3752.08 3629.37 5953704.58 680259.64 -1530.39 23,36 12360.38 93,96 322.98 8953,70 8893.70 3776,30 3609,62 5953728,34 680239,33 -1501.79 15.42 ObP . BP-GDB . Baker Hughes INTEQ Survey Report B.. BAICD IIUGHIS INTEQ Company: BP Amoco Field: PrUdl10e Bay Site: PBDS 07 Well: 07-33 Wellpath: 07 -33B Survey MD Incl Azim TVD SSTVD ft deg deg ft ft 12389.25 92.79 327.01 8952.00 8892,00 12429.92 90.03 331,71 8951.00 8891.00 12460,31 86.81 328,99 8951.84 8891.84 12490.91 89,02 325.10 8952,95 8892.95 12525.50 89.48 320,00 8953.40 8893.40 12557,59 89.94 317,55 8953.57 8893.57 12585.00 89,94 317.55 8953,59 8893.59 Date: 11/20/2003 Time: 10:58:59 Page: 3 Co-ordinate(NE)Reference: Wef.l: 07 -33, True North Vertical (TVD) Reference: 46 : 335/181198800:0060.0 Section (VS) Reference: Well (0.OON,O.00E,297.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle N/S EIW MapN MapE VS DLS ft ft ft ft ft deg/10Oft 3799.90 3593.09 5953751,54 680222.25 -1476.35 14.51 3834,87 3572.38 5953786,01 680200.73 -1442,02 13.40 3861,27 3557,36 5953812,05 680185.09 -1416.65 13.87 3886,92 3540,72 5953837.30 680167.86 -1390,18 14,61 3914,37 3519,70 5953864.25 680146.20 -1358.99 14,80 3938.50 3498,55 5953887,88 680124.49 -1329.19 7.77 3958.73 3480,05 5953907.66 680105.52 -1303,53 0,00 cids" . WELL LOG TRANSMITTAL . ¡~C)3 -) /~ 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 being 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 WELL DATE loG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR CoLOR Open Hole 1 Res. Eva!. CH 1 1 1 07-338 10-24-03 Mech. CH 1 J()()~Lf Caliper Survey E~\¡ED Signed: ---"N,.\')...x ."A., \ ,C Ç¿.....I..~, JI0 ~ Date : NOV 1 7 2003 Print Name: Alaska 011 &. Gas Cons. Commiaekm Andìmge PRoACTivE DiAGNOSTic SERvicES, INC., PO Box I }b9 STAFFoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~ç,,\.~ . /[\I - ® @ l~ fÀ\ / ¿~ Ltl} 02) "J ü u~u / J\14ASIiA OIL AND GAS / CONSERVATION COMMISSION ! I . (ill FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit, 07-33B BP Exploration (Alaska) Inc. Permit No: 203-112 Surface Location: 1068'SNL, 522' EWL, SEe. 34, TIIN, R14E, UM Bottomhole Location: 2349' SNL, 4055'EWL, SEe. 27, TIIN, R14E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~/L. ~d~ ¿edrich Commissioner BY ORDER OF THE COMMISSION DATED this1..!2 day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section WGA- (ç;" q 1z.."O·$ Hole 3" _ STATE OF ALASKA _ ALASKA _ AND GAS CONSERVATION COMM'fIIION PERMIT TO DRILL 20 MC 25.005 11 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 60' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool /' ADL 028309 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' 07.338 ' Number 2S100302630-277 9. APproXimaæe spudSiàte o 0yø3 Amount $200,000.00 14. Number 0 cres in property 15. ProDQsed depth (MD and TVD) 2560 /12600' MD / 8904' TVD o 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 91 Maximum surface 2350 psig, At total depth (TVD) 8800' / 3250 psig Setting Depth Top Bottom Lenath MD TVD MD. TVD 1900' 10700' 8655' 12600'/ 8904' ~ .Ç/è.%~ 1 a. Type of work 0 Drill III Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 676720, Y = 5949869 1068' SNL, 522' EWL, SEC. 34, TllN, R14E, UM At top of productive interval x = 681504, Y = 5953380 2952' SNL, 115' EWL, SEC. 26, TllN, R14E, UM At total depth X=680150, Y=5953950 2349' SNL, 4055' EWL, SEC. 27, TllN, R14E, UM 12. Distance to nearest property line 113. Distance to nearest well , ADL 028308,1224' MD No Close Approach / 16. To be completed for deviated wells Kick Off Depth 10800' Maximum Hole Angle 18. Casing Program S ec'f'cat'o Size p I I I ns Casina Weight Grade Couclina 2-3/8" 4.6# L-80 STL 11. Type Bond (See 20 AAC 25.025) Quantity of Cement (include staae data) 49 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 12761 feet 8931 feet 10885 feet 8805 feet Length Plugs (measured) 2-1/8" Baker IBP at 10885' (04/03) Junk (measured) Size Cemented MD TVD 110' 3365' 20" 13-3/8" 2150# Poleset 2000 sx CS III, 200 sx CS I, 600 sx G 110' 3365' 110' 3047' 10413' 604' 2681' 9-5/8" 629 sx Class G, 400 sx CS I 7" 450 sx Class G 3-3/16" x 2-7/8" 140 sx LARC 10413' 10166' - 10770' 10081' -12759' RECE 8416' 8211' - 8713' 8141' - 8931' Perforation depth: measured 11175' - 11560', 11771' - 12251', 12465' - 12720' JUN 1 9 2003 Alaska Oil & III Filing Fee 0 Property Plat III BOP Sketch 0 Diverter SketctA"tIWi1ìl6§ Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report III 20 AAC 25.050 Requirements Contact Engineer NameINumber: Dan Kara, 564-5667 Prepared By NameINumber: Sandra Stewman, 564-4750 21. I ~erebY certify tha~ffl true and corre. ct to the best of my kn~~ledge . Signed CanKara ..c,.y~'-- Title CTDnlhngEnglneer Date <;,,)/8/03 ·,·,'~:i:L '?:,"",:' " ,', ,',;:.'~Li;;'~;;:'::~~i;;t{~i~gii~li~jf;Jíir ',.,", Permit Number, I API Number I ¡A9P,roval J>ªte See cover letter 2- Ci. ~ _ / / Z- 50- 029-21809-02 (.. { '2...v¡ OJ for other requirements Conditions of Approval: Samples Required 0 Yes IE No Mud Log Required 0 Yes 181 No Hydrogen Sulfide Measures 18 Yes 0 No Directional Survey Required ,.ø Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Te<;t BOPE to ŠÇÒO ph-" I? A. ,A _ _ ----"Á._ by order of Approved By , ~ ~ ... ~, ,', ", .' 1..--1" "', 0 P,'l~itrf\rl A I the commission Form 10-401 ~FlJJM 2, (111' t\ .. \J , \J 1... true vertical 8946' - 8959', 8954' - 8945',8935' - 8934' 20. Attachments Date t(ø/Ò] Submit In Triplicate e e BP 7-33B RWO/CTD Sidetrack Summary of Operations: Well 7-33A is scheduled for a through tubing sidetrack with coil2tubing. Prior to CTD sidetracking, the 5- 1/2" L-80 tubing will be replaced with 4-1/2" 13-Chrome tubing. The sidetrack, 7-33B, will kick off from a window milled off a mechanical whipstock, out of 3-3/16" liner. The lower Romeo Zone lA will be the target for the sidetrack. . Approximately 1800' of 3" bi-center open hole is planned to access the target./The well will be completed with a solid, cemented liner. Once the liner is in place a memory GRlCCL/CNL log will be run and perforations shot. A liner top packer will be run if necessary. / Pre-rig Prep work. Planned for July 01, 2003 startup. 1. Combo MIT tubing/inner annulus to 3500 psi. 2. A retrievable/inflatable bridge plug is already set at 10885' md and pressure tested to 2000 psi. 3. Chemical cut tubing at -10085' md. Nordic 2 RWO - Tubing Swap. Planned for August 01, 2003 startup. 1. RU Nordic 2 with 13-5/8" BOPE. Test stack. / 2. Pull 5-1/2" L-80 tubing. / 3. RIH w/ casing scraper and dress off tubing stub. /' 4. Complete well with 4-1/2" 12.6# 13Cr-80 tubing with new packer and tubing tail overshot. 5. PT completion. RD 13-5/8" BOPE. NU tree and 7-1/16" CTD BOPE. Test. 6. Install whipstock in 3-3/16" liner at 10800'. ' 7. Continue forward with CTD window milling and open hole drilling. Nordic 2 cm - Mill window, Drill and Complete sidetrack: 1. Mill 2.74" window from whipstock at 10800', through the 3-3/16" liner. 2. Directionally drill -1800' of 3" bi-center hole t~ccess Zone lA reserves. 3. Run 2-3/8" liner from TD~P tOO' md. 4. Cement liner in place with , s, 15.8 ppg Class G cement. ./ 5. Case hole log new lateral memory GRlCNL/CCL. 6. Perforate selected intervals. 7. Install liner top packer if necessary. 8. RD Nordic 2. / Mud Program: · RWO: 2% KCI and 2ppb Biozan for milling. · CTD: Flo-Pro (8.6 - 8.7 ppg) /' Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 1900' of 2-3/8" STL 4.6# L-80 fro~TD up into the 3-3/16" liner to 10,700' md. · Cement liner in place with 10 bbls, 15.8 ppg Class G cement / Well Control: · BOP diagram is attached. /" · Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. e e Directional · See attached directional plan, 1800' planped horizontal. Max. planned hole angle is approx. -90 deg. · Magnetic and inclination surveys will betaken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray will be run over the entire open hole section. · Memory CNL/CCL/GR to be run in cased hole. Hazards /' · The most recent H2S test on 7-33 was 6 ppm on 2/15/01. DS-07 is not considered an H2S pad. · Lost circulation risk is considered low. Reservoir Pressure · Pore pressure is estimated to be 3250 psi at 8800'TVDss (7.1 ppg emw). · Maximum surface pressure with gas (0.1 psi/ft) to surface is 2350 psi /" . TREE = WB..LHEAD = A crl..íÄ:'fOR;-- KB-:--ÈlEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = FMC GEN 4 FMC AXELSON 60' ? 07 -33A ... SAFETY NOTES: 70° @ 11074' 1400' 95 @ 11885' 10961' 8800' SS . 2223' H 5-1/2" CAWCO BAL-O SSSV NIP I 113-318" CSG, 72#, L-80, D = 12.347" H 3365' ~ I Minimum ID = 2A4" @ 11289' 3-3/16" X 2-7/8" XO 1 TOP OF 3-1/2" LNR H 15-1/2" 1BG-IPC, 17#, L-80, .0232 bpf, 10 = 4,892" H ~ 10085' 1 I 10141' ~8: - Z----t 10085' 10141' H 3-1/2" DEPLOYM8'JTSLV, 10=3.0" 1 H 9-518" X5-1/2"BAKERFB-1 PKRW/BKR I SEALBOREEXT, XO, BKRMLLOUTEXT. 1 TOP OF 4-lIZ' 1BG H 10160' TOPOF7"LNRH 10166' r----. I 1 10160' H 5-1/2" X4-1/2"XO 1 14-1/2" TBG, 12,6#, L-80, .0152 bpf, 10 = 3,958" I~ 10259' I 1 10259' H 4-1/2" WLEG I 19-518" CSG, 47#, L-80, 10= 8.681" H 10413' ... 3-1/2" LNR, 9,3#, L-80, .0087 bpf, 10= 2.992" H 1 TOP OF 3-3116" LNR H 1 TOP OF WHPSTOO< H 10533' 10533' 10767' 10532' H 3-1/2"X3-3/16"XO,D=2.80" I 11 2-1/8" BAKER IBP (SET 06129101 ) PUSf-ED DOWN HOLE (04106/03) 10885' MLLOur WINOOW: 10773' 11289' H 3-3116" X 2-718" XO, 10 =2,44" I 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" H 11027' I 13-3116" LNR, 6,2#, L-80, .0076 bpf , 10 = 2.80" 11555' H OBSTRUC1lON I PERFORATION SUMv1ARY REF LOG: MCf'..I... ON 10/21/98 ANGLEATTOPÆRF: 80@ 11175' Note: Refer to Production œ for historical perf data SIZ E SPF INTER.! A L OpnlSqz [)/\ TE 2-1/8" 4 11175 - 11355 0 03106JÜO 2" 4 11340 - 11560 0 1 0/22198 Z' 4 11771 -12251 0 10/22198 2" 4 12465 - 12720 0 10/22198 2-7/8" LNR, 6.5#, L-80, .00579 bpf, 10 = 2.441" H 12759' 1 [)/\ TE 1988 1 0/25/98 03106/01 02105/02 12/11/02 03ßO/03 RBI BY CO Mv1ENTS ORGINAL COI'vPLETION SIDETAACKED (07-33A) SIS-rvo FINAL RN'TP CORRECTIONS TWC/ijh MIN 10, XO, IBPCORREC1l0NS JAFITLH PULL FQGLM [)/\ TE REV BY COMM:NTS 04106103 JJ/KAK PLU POGLMS; RJSH IBP DH PRLÐI-D E BA Y UNIT WELL: 07 -33A PERMIT No: 1981440 AR No: 50-029-21809-01 SEC 34 T11 N R14E3543.46 FB.. 3065.86 Ff'..I... BP Exploration (Alaska) TREE = FMC GEN 4 WELLHEAD = FMC AcfuÀ TOR; AXElSON Mä){-)Çngî"ã"; '"gtfiªi' Tfã8'5'ì DatumMO= '" ." ·10961' ·Dáium TVO ~88ÒO;SS I 113-3/8" CSG, 72#, L-80, 10= 12.347" H 3365' ~ ~ H 3-1/2" LNR \~ 15-1/2" TBG-IPC, 17#, L-80, .0232 bpf, 10 = 4.892" 1-1 I ~8: - & TOPOF4-1/2"TBG H 10160' TOP OF 7" LNR 1-1 10166' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" H 10259' I--J 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 10413' \---.tI 3-1/2" LNR, 9.3#, L-80, .0087 bpf, 10 = 2.992" H 10533' TOPOF3-3/16" LNR - TOP OF WHIPSTOCK H 10767' I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6ß4\ H . I 13-3/16" LNR, 6.2#, L-80, .0076 bpf, lOt 2.8t!'il-l TOPOF 2-7~~J;1>IR --f PERFORA TION SUMMARY REF LOG: MCNL ON 10/21/98 ANGLEATTOPPERF: 80 @ 11175' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/8" 4 11175 -11355 2" 411340-11560 2" 4 11771 - 12251 2" 4 12465 - 12720 DATE 1988 10/25/98 03/06/01 02/05/02 12/11/02 03/30/03 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACKED (07-33A) SIS-MO FINAL RNITP CORRECTIONS lWCltlh MIN 10, XO, IBPCORRECTlONS JAFrrLH PULL POGLM I l I ! 10085' H 10141' 11 .. OTES: 70"@11074' H I I 3-1/2" DEPLOYMENT SLV, 10 = 3.0" I 9-5/8" X 5-1/2" BAKER FB-1 PKR W/BKR SEALBORE EXT, XO, BKR MILLOUT EXT. I 10160' Ii 5-1/2" X 4-1/2" XO I I 10259' H 4-1/2" WLEG I ... I I 10532' H 3-112" X 3-3/16" XO, 10 = 2.80" I I MILLOUT WINDOW: 10773' I 11027' 11291' 11291' 11289' 11555' 1",)00.. t 12725' 12759' DATE REV BY COMMENTS 04/06/03 JJ/KAK PULL POGLMS; PUSH IBP OH ¡ 2-1/8" BAKER IBP (SET 06/29/01) PUSHED DOWN HOLE (04/06/03) 3-3/16" X 2-7/8" XO, 10 = 2.44" I OBSTRUCTION I PaTO 1 2-7/8" 6.5#, L-80 liner PRUDHOE BA Y UNIT WELL: 07 -33A PERMIT No: 1981440 API No: 50-029-21809-01 SEC34 T11N R14E3543.46 FEL 3065.86 FNL BP Exploration (Alas ka) BP Amoco WELl-PATH OETAlU> Pb1jtt#6 G7--338 5002&2140002 Parent W<llUpath~ 070033A Tie....n MP: 101-67.00 Rig, R.f. D.htM1 46 ~ 33 Sf1af19.8e O )~O ) OO.GOff v.s~: O+rm!$ ~~f= ~::1!k 0.00 Om.'! REFERENCE JNFORMATJON 60,00 .$arrJ<)N flfl'Allá' .. "'" it~ ~~:~: 33.04 71.72 90'.00 236.07 .00.00 255.$2 an.N U7.$2 fUMO 291.$2: .&1.02 <35::;.06 ASnos ::~:~ 4&1¢40- 4$KAI$ 4049AW 3$ft:24 UU,.OIt- ])1."9 TF..ce "Set' T!Uget 0.00 ROO $."94 MIi,67 ig:g& 1~:~ 3Q,:$ß 'ØU.Uß 12.00 ${US i.2.00 ..$.50 n.oo .as,at Moo.40 0017.70 86.00.12 8908,00 89(1&;00 ßM&.44 :~g::: î~~ã:~¡ -:u.m;rg- 322Q.17 31~$Q """,. 3597.49 ,...m ANNOTA110.N$ TV.o MU M.ftOœtioff TIP KOP > · · · 7 TO Azimuths to True North Plan Plan #8 (OI-33/Plan#8 07-338) Magnetic North: 25,BT~ Created By: Brij Potnìs. Date: 6/1712003 Magnetic Field Strength: 57549nT Dip An9ie: 80,82' Date: 611712003 Model: BGGM2002 ¡ntormation 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 West(.)/East(+) [100ft/in] -2900 -2850 -2800 -2750 -2700 -2650 -2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200 -2150 -2100 -2050 -2000 -1950 -1900 -1850 -1800 -1750 -1700 -1650 -1600 -1550 -1500 -1450 -1400 -1350 -1300 -1250 -1200 -1150 -11 00 -1 050 -1 000 Vertical Section at 29'1.00· [50ft/in] ObP BP Baker Hughes INTEQ Planning Report e e -. ..... INTEQ Date: 6/17/2003 Time: 14:45:37 Co-ordinate(NE) Reference: Well: 07-33, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.OON,O.00E,297.00 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 -~--~-~~-~ _"___n._____ -----,,_._--~."---- .,----...---.---..-- Site: PB DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144,78 ft 677382,28 ft Latitude: 70 15 Longitude: 148 33 North Reference: Grid Convergence: 49.847 N 56,934 W True 1,35 deg ----_._--'~._--_..~----- ~~---._- Well: 07-33 Slot Name: 07-33 Well Position: +N/-S 1739.05 ft Northing: 5949868,58 ft Latitude: +E/-W -621.93 ft Easting: 676719.59 ft Longitude: Position Uncertainty: 0.00 ft 33 70 16 6.950 N 148 34 15.037 W -.------.-- --_.,,--~----_.,._~_.,._----._--- ---_._-----~ ----".._--_._"._-----~ Wellpath: Plan#8 07-33B 500292180902 Current Datum: 46: 335/18/198800:00 Magnetic Data: 6/17/2003 Field Strength: 57549 nT Vertical Section: Depth From (TVD) ft 0,00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 07-33A 10767.00 ft Mean Sea Level 25.87 deg 80.82 deg Direction deg 297,00 Height 60.00 ft -----...---"--..--'" Targets 07-33B Fault 1 0,00 4026.53 3717.20 5953981.00 680340.99 70 16 46.542 N 148 32 26.777 W -Polygon 1 0.00 4026.53 3717,20 5953981.00 680340.99 70 16 46.542 N 148 32 26.777 W -Polygon 2 0.00 3643.57 4093.34 5953607.00 680726.00 70 16 42.773 N 148 32 15.829 W -Polygon 3 0.00 3468.81 4208.27 5953435.00 680844.99 70 1641,054 N 148 32 12.485 W -Polygon 4 0.00 3643.57 4093.34 5953607.00 680726.00 70 16 42.773 N 148 32 15.829 W 07-33B Fault 2 0.00 3921.27 4834.11 5953902.00 681459,99 70 16 45,500 N 148 31 54.251 W -Polygon 1 0.00 3921.27 4834.11 5953902.00 681459.99 70 16 45.500 N 148 31 54.251 W -Polygon 2 0.00 3650.82 4891.78 5953633.00 681523.99 70 16 42.840 N 148 31 52,576 W -Polygon 3 0,00 3129.68 4762.50 5953109.00 681406.99 70 16 37.715 N 148 31 56.351 W -Polygon 4 0,00 3650.82 4891.78 5953633,00 681523.99 70 16 42.840 N 148 31 52.576 W 07-33B Fault 3 0.00 3395.64 5620.03 5953395.00 682257.99 70 16 40.325 N 148 31 31.373 W -Polygon 1 0,00 3395.64 5620.03 5953395.00 682257.99 70 16 40.325 N 1483131.373W -Polygon 2 0.00 2751,66 5481.86 5952748.00 682134.99 70 16 33.993 N 148 31 35.410 W 07-33B Fault 4 0,00 3588.78 5063,38 5953575.00 681696,99 70 16 42,229 N 148 31 47.580 W -Polygon 1 0,00 3588.78 5063,38 5953575.00 681696,99 70 16 42.229 N 148 31 47,580 W -Polygon 2 0,00 3083.66 5146.55 5953072.01 681791.99 70 16 37,260 N 148 31 45,168 W 07-33B Fault 5 0,00 3475.04 5348.81 5953468.00 681984,99 70 1641,108 N 148 31 39.270 W i -Polygon 1 0,00 3475.04 5348,81 5953468.00 681984,99 70 1641,108 N 148 31 39.270 W -Polygon 2 0,00 3486.08 5773.21 5953489.00 682408.99 70 1641.213N 148 31 26,910 W 07-33B Fault 6 0.00 3309,65 3914.44 5953269,00 680555.00 70 16 39.490 N 148 3221.044 W -Polygon 1 0.00 3309.65 3914.44 5953269.00 680555.00 70 16 39.490 N 148 32 21.044 W -Polygon 2 0.00 3085.92 4070.24 5953049.01 680715.99 70 16 37.289 N 148 32 16.510 W -Polygon 3 0.00 1030.64 4691.20 5951009.00 681384.99 70 16 17.072 N 148 31 58.465 W -Polygon 4 0,00 3085.92 4070.24 5953049.01 680715.99 70 16 37.289 N 148 32 16.510 W 07-33B Fault 7 0,00 3710.21 5600.41 5953709.00 682230,99 70 1643.419 N 148 31 31,938 W -Polygon 1 0.00 3710.21 5600.41 5953709.00 682230.99 70 1643.419 N 148 31 31,938 W ----".._- -----,,----_.~------_...._--.,," ObP BP Baker Hughes INTEQ Planning Report e e B.. .... tN'TEQ Site: P8 DS 07 Well: 07-33 Wellpath: Plan#8 07-338 VerticaJ (fVD) Reference: Section (VS) Reference: Survey Calculation Method: System: Mean Sea Level Well (0.00N,O.00E.297.00Azi) Minimum Curvature Db: Oracle Targets -Polygon 2 0,00 3204.81 6376.81 5953222.00 683019.00 70 16 38.442 N 148 31 9.339 W 07-338 Polygon7.1 0.00 3362.73 4763.97 5953342.00 681403,00 70 16 40.007 N 148 31 56.303 W -Polygon 1 0.00 3362,73 4763.97 5953342.00 681403.00 70 16 40.007 N 148 31 56.303 W -Polygon 2 0,00 3286,89 4245.01 5953254.01 680885.99 70 16 39,264 N 148 32 11.418 W -Polygon 3 0,00 3529,38 4014.63 5953491,01 680650.00 70 1641,651 N 148 32 18.123 W -Polygon 4 0,00 3931.43 3634.94 5953884.01 680261.00 70 16 45,607 N 148 32 29.174 W -Polygon 5 0,00 4229,83 3451.88 5954178.01 680071.00 70 16 48,542 N 148 32 34.502 W -Polygon 6 0,00 4148.11 3225.88 5954091.01 679846.99 70 16 47.740 N 148 3241.085 W -Polygon 7 0,00 3508.83 3782.07 5953465.00 680418,00 70 1641.450 N 148 3224.896 W -Polygon 8 0.00 3383.16 3979,18 5953344.00 680617.99 70 16 40.213 N 148 32 19.157 W -Polygon 9 0.00 3253.56 4088,18 5953217.01 680730.00 70 16 38.938 N 148 32 15.985 W -Polygon 10 0.00 3036.82 4542,24 5953011.00 681188.99 70 16 36.803 N 148 32 2.766 W 07-338 T8.3 8904.00 4001.41 3525.22 5953951.38 680149.67 70 16 46,295 N 148 32 32.369 W 07-338 T8.1 8908,00 3220,23 4618.42 5953196.13 681260.84 70 16 38,607 N 148 32 0,545 W 07-338 T8.2 8910.00 3565.83 3886.63 5953524.44 680521.19 70 16 42.010 N 148 32 21.850 W Annotation 10767.00 10800.00 10815.00 11123.02 11173.02 ¡ 11773,02 i 12073.02 j 12600.00 ~-------- 8650.40 8677.70 8690,12 8908.00 8908.00 8909.44 8909.81 8904,06 TIP KOP 3 4 5 6 7 TO _.,,------------,------_._^ ~- Plan: Plan #8 New landing and targets Principal: Yes Date Composed: Version: Tied-to: 611712003 3 From: Definitive Path .-------- -....-----.. Plan Section Information ft ft deg/1000 deg/100ft deg/100ft 10767.00 33.23 70.99 8650.40 3311.92 4672.05 0.00 0.00 0.00 0,00 10800,00 35.16 70.38 8677.70 3318.06 4689,55 5,94 5,85 -1.85 349.67 10815,00 33.04 71,72 8690.12 3320.79 4697,50 15.00 -14,14 8.91 161.10 11123.02 90,00 236.07 8908.00 3220.17 4616.40 39.50 18.49 53,36 161.53 11173.02 90,00 255,82 8908.00 3199.89 4570.96 39.50 0.00 39,50 90.00 11773.02 89.76 327,82 8909.44 3408,52 4049.89 12.00 -0.04 12,00 90.25 12073.02 90.10 291.82 8909.81 3597.49 3823.24 12.00 0.11 -12.00 -89.50 12600,00 91.02 355.06 8904,06 3999.57 3525.02 12,00 0.17 12.00 88.91 --~---_._----- ---------- ObP e BP e B.. ..... Baker Hughes INTEQ Planning Report INTEQ Date: 6/17/2003 Time: 14:45:37 Co-ordinate(NE) Reference: Well: 07-33, True North Vertical (fVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,297.00 Survey Calculation Method: Minimum CUNature Db: Oracle Survey N/S EIW 10767.00 33.23 70.99 8650.40 3311,92 4672.05 5953289.06 681312.29 -2659.24 0.00 0.00 TIP 10775.00 33,70 70.84 8657,08 3313.37 4676.21 5953290.60 681316,43 -2662.30 5.94 349.67 MWD 10800.00 35.16 70.38 8677.70 3318.06 4689,55 5953295.60 681329,64 -2672.05 5.94 349.80 KOP 10815.00 33,04 71.72 8690.12 3320.79 4697,50 5953298.52 681337,53 -2677.89 15.00 161.10 3 10825.00 29,32 74,27 8698,67 3322.31 4702.44 5953300.16 681342,44 -2681.61 39.50 161.53 MWD 10850.00 20.35 84.29 8721.35 3324.41 4712.69 5953302.49 681352,63 -2689.78 39.50 159.34 MWD 10875.00 12.72 107.06 8745.32 3324.03 4719.66 5953302.28 681359,61 -2696.17 39.50 150.21 MWD 10900.00 10.13 156.98 8769.88 3321.20 4723.16 5953299,53 681363,17 -2700.58 39.50 128.32 MWD 10925.00 15.37 196.44 8794.30 3315.98 4723.08 5953294.31 681363.22 -2702.87 39.50 79.26 MWD 10950.00 23.73 212,56 8817.85 3308.54 4719.43 5953286.79 681359.74 -2702.99 39.50 40.66 MWD 10975.00 32.91 220.34 8839.84 3299.10 4712,31 5953277.19 681352.84 -2700.93 39.50 25.42 MWD 11000.00 42.37 224.99 8859.62 3287.94 4701.93 5953265.79 681342,73 -2696,76 39,50 18.54 MWD 11025.00 51.97 228.18 8876.60 3275.39 4688.60 5953252.92 681329,70 -2690.58 39.50 14.85 MWD 11050.00 61.63 230.63 8890.27 3261.81 4672.72 5953238,98 681314,15 -2682.59 39,50 12,67 MWD 11075.00 71.33 232.67 8900.24 3247.62 4654.76 5953224.37 681296.52 -2673.03 39.50 11.32 MWD 11100.00 81,04 234.49 8906.20 3233.23 4635.24 5953209.53 681277,35 -2662,17 39.50 10,51 MWD 11123.02 90,00 236.07 8908.00 3220.17 4616.40 5953196.03 681258,82 -2651,31 39,50 10,07 4 11125.00 90.00 236.85 8908.00 3219.08 4614.75 5953194.90 681257.19 -2650.34 39.50 90.00 MWD 11150.00 90.00 246,73 8908,00 3207,28 4592,74 5953182.59 681235.48 -2636.09 39.50 90.00 MWD 11173.02 90.00 255,82 8908,00 3199,89 4570,96 5953174.69 681213.88 -2620.04 39.50 90.00 5 11175.00 90.00 256,06 8908,00 3199.41 4569.04 5953174.17 681211.97 -2618.55 12.00 90.25 MWD 11200.00 89,99 259.06 8908.00 3194.03 4544.63 5953168.21 681187,69 -2599.24 12,00 90.25 MWD 11225.00 89.97 262.06 8908.01 3189.93 4519.98 5953163.53 681163,14 -2579.13 12.00 90.25 MWD 11250.00 89.96 265,06 8908,02 3187,12 4495.14 5953160.15 681138.38 -2558.27 12.00 90.25 MWD 11275.00 89.95 268,06 8908,04 3185.62 4470,18 5953158.06 681113.47 -2536.72 12.00 90.25 MWD 11300.00 89,93 271.06 8908,07 3185.43 4445.19 5953157.28 681088.48 -2514.54 12.00 90.24 MWD 11325.00 89,92 274,06 8908.10 3186.54 4420.22 5953157.81 681063.49 -2491.78 12.00 90.24 MWD 11350,00 89.91 277,06 8908,14 3188,96 4395,34 5953159.64 681038.57 -2468.51 12.00 90.24 MWD 11375,00 89.90 280,06 8908,18 3192,68 4370,62 5953162.78 681013.77 -2444.80 12.00 90.23 MWD 11400,00 89,89 283,06 8908,23 3197,69 4346,13 5953167.21 680989.17 -2420.71 12.00 90.23 MWD 11425.00 89.87 286,06 8908.28 3203.97 4321.93 5953172.93 680964.83 -2396.30 12,00 90.22 MWD 11450,00 89,86 289.06 8908.34 3211.52 4298.10 5953179.91 680940.83 -2371,64 12,00 90,22 MWD 11475,00 89.85 292.06 8908.40 3220.29 4274.69 5953188,13 680917,23 -2346,80 12,00 90,21 MWD 11500.00 89.84 295,06 8908.47 3230.28 4251,78 5953197.58 680894.09 -2321,85 12.00 90.20 MWD 11525,00 89,83 298,06 8908,54 3241.46 4229.42 5953208.23 680871.47 -2296,85 12.00 90,19 MWD 11550,00 89.82 301.06 8908.61 3253.79 4207.68 5953220,04 680849.45 -2271.88 12.00 90.19 MWD 11575.00 89.81 304.06 8908.69 3267.24 4186.61 5953233.00 680828.07 -2247.00 12.00 90.18 MWD 11600.00 89.81 307.06 8908,78 3281.78 4166.27 5953247.05 680807.40 -2222.28 12.00 90.17 MWD 11625.00 89.80 310.06 8908,86 3297.36 4146.73 5953262.17 680787.49 -2197.79 12,00 90,16 MWD 11650,00 89,79 313.06 8908.95 3313.94 4128.02 5953278,30 680768.41 -2173.60 12.00 90.15 MWD 11675.00 89.78 316.06 8909.05 3331.48 4110.21 5953295.42 680750.19 -2149.76 12.00 90.14 MWD 11700.00 89.78 319.06 8909.14 3349.93 4093.34 5953313.46 680732.89 -2126,36 12.00 90.12 MWD 11725.00 89.77 322,06 8909,24 3369,23 4077.46 5953332.39 680716.56 -2103.44 12,00 90,11 MWD 11750.00 89.77 325,06 8909,34 3389,34 4062,61 5953352.14 680701.25 -2081.08 12,00 90,10 MWD 11773,02 89.76 327,82 8909,44 3408.52 4049.89 5953371,02 680688.08 -2061.04 12.00 90.09 6 11775,00 89,76 327.58 8909.45 3410.19 4048.83 5953372.66 680686.98 -2059.34 12.00 270.50 MWD 11800,00 89,79 324.58 8909.54 3430.94 4034.88 5953393,07 680672.55 -2037.49 12.00 270.50 MWD 11825,00 89.82 321.58 8909.63 3450.92 4019.86 5953412.70 680657.07 -2015.04 12.00 270.51 MWD 11850.00 89.85 318.58 8909.70 3470.09 4003.82 5953431.49 680640.59 -1992.04 12.00 270.52 MWD 11875.00 89.87 315.58 8909.76 3488.40 3986.80 5953449.39 680623.14 -1968.57 12.00 270.53 MWD 11900.00 89.90 312.58 8909.81 3505.79 3968.85 5953466.35 680604.78 -1944.67 12.00 270.54 MWD 11925,00 89,93 309,58 8909.85 3522.22 3950,00 5953482,33 680585.56 -1920.43 12.00 270.54 MWD 11950.00 89.96 306,58 8909,87 3537,64 3930,33 5953497.28 680565.53 -1895,90 12,00 270,55 MWD -------.----.'...------.---.----.--....--------- .-------,.----...------ ----,.-._-_._.-_._._...~._--- ..----.,--,.------------- _._--_._..._---_.__._._-------_._.~-_...- ObP It BP e B.. ..... Baker Hughes INTEQ Planning Report INTEQ Date: Time: 14:45:37 Co-ordinate(NE) Referenœ: Well: 07-33, True Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Referenœ: Well (0.OON,O,OOE,297.00Azi) Survey Calculation Method: Minimum Curvature Db: -. --,-----_.-...-,,- MapN MapE VS DLS TFO ft ft ft deg/100ft deg 5953511,16 680544.74 -1871.15 12.00 270.55 MWD 5953523.94 680523.26 -1846.25 12.00 270.55 MWD 12025.00 90.05 297,58 8909.87 3577.43 3866.85 5953535.57 680501.14 -1821.27 12,00 270.55 MWD 12050,00 90.08 294.58 8909,84 3588.42 3844.40 5953546.03 680478.44 -1796.27 12.00 270,55 MWD 12073.02 90.10 291.82 8909,81 3597.49 3823.24 5953554.60 680457,07 -1773.31 12.00 270,55 7 12075,00 90,11 292.06 8909.80 3598.23 3821.40 5953555.30 680455.22 -1771,33 12.00 88.91 MWD 12100.00 90,16 295.06 8909.74 3608.22 3798.49 5953564.75 680432.08 -1746.38 12.00 88.91 MWD 12125.00 90.22 298.06 8909.66 3619.40 3776.13 5953575.40 680409.47 -1721.39 12,00 88.92 MWD 12150.00 90.28 301,06 8909.55 3631.73 3754.39 5953587,21 680387.44 -1696.41 12,00 88.93 MWD 12175.00 90.33 304,06 8909.42 3645.18 3733,32 5953600,16 680366.06 -1671.53 12.00 88.94 MWD 12200.00 90,38 307.06 8909.26 3659,72 3712.98 5953614.22 680345.39 -1646.82 12.00 88.96 MWD 12225,00 90.44 310.06 8909,08 3675.30 3693.44 5953629.33 680325.49 -1622.33 12.00 88,97 MWD 12250.00 90.49 313.06 8908.88 3691.88 3674.73 5953645.47 680306.40 -1598.13 12,00 89.00 MWD 12275.00 90.54 316.06 8908.66 3709.41 3656,92 5953662.58 680288.18 -1574,30 12,00 89.02 MWD 12300.00 90.59 319.06 8908.41 3727,86 3640.05 5953680.63 680270.89 -1550,90 12.00 89.05 MWD 12325.00 90,64 322.05 8908.14 3747,16 3624.17 5953699.55 680254.56 -1527.98 12.00 89.08 MWD 12350,00 90.68 325.05 8907,86 3767.27 3609.32 5953719.30 680239.24 -1505.62 12.00 89,11 MWD 12375.00 90.73 328.05 8907.55 3788.13 3595,55 5953739.83 680224.98 -1483,88 12.00 89.14 MWD 12400,00 90.77 331,05 8907.22 3809.67 3582.88 5953761.07 680211.81 -1462.81 12,00 89.18 MWD 12425,00 90.81 334,05 8906.88 3831.86 3571,36 5953782,97 680199.78 -1442.48 12,00 89.22 MWD 12450.00 90.85 337,05 8906.52 3854.61 3561,02 5953805.48 680188.90 -1422,93 12.00 89.26 MWD 12475.00 90,88 340.05 8906.14 3877.87 3551.88 5953828.52 680179,22 -1404.23 12.00 89.30 MWD 12500.00 90.91 343,06 8905.75 3901.58 3543.97 5953852.04 680170.76 -1386.42 12.00 89.35 MWD 12525.00 90.94 346,06 8905.34 3925.67 3537.31 5953875,96 680163.54 -1369.55 12,00 89.40 MWD 12550.00 90.97 349,06 8904.93 3950.08 3531,93 5953900.23 680157.58 -1353,67 12.00 89.45 MWD 12575.00 91.00 352,06 8904.50 3974.74 3527.83 5953924,78 680152.90 -1338.82 12,00 89,50 MWD 12600.00 91.02 355,06 8904.06 3999.57 3525,02 5953949,54 680149.52 -1325,05 12,00 89.55 TD -----..-------..-...-.------------.--------- Well I I I, I, 'H' I- I Tree Size r , I . , · · I · I · · · I · BOP-Tree Rig Floor , . . . I, SSV . I, Master Valve , Base Flanie . 1 ,j . p055081 DATE INVOICE / CREDIT MEMO GROSS DESCRIPTION 6/9/2003 INV# CK060403A Of .333 PERMIT TO DRILL THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DeSCRIBED ABove. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK99519-6612 PAY: TO THE ORDER OF: AMOUNT Jun~ 9.20Q3 t .. ;1 ***fr~r*$1bO,00******i NCtrvALlD AFTER 120 DAYS 2!:':;j~~2i.t~~Q:\:¡;18J ·i;\(~%~~~s~Ù~;j;¡~~,;!¥:,~; NATIONAL CITY BANK Ashland, Ohio ALASKA QIL & GAS 333 W 7TH AVENUE SUITE 100 ANCHORAGE. AK 99501-3539 III 0 5 5 0 8 L III , : 0... ¡. 2 0 j B £1 5 I: 0 ¡. 2 '? B £1 b III (, DATE ¡ ¡CHECK NO. 6/9/2003 055081 VENDOR DISCOUNT NET RECEIVE JUN 1 9 2003 A ¡;'ska Oil & Cornmissiofl Am:horage 56-389 41'2 No. p 055081 CONSOLIDATED COMMERCIAL ACCOUNT H . . Rev: 07/10/02 C\jody\templates . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMlTT AL LETTER CHECK WHAT APPLIES WELL NAME PTD# ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing weU-, Permit No, API No. Production should continue to, be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). Pß..,OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 'lfËIA~,flg;r!IIIIIT CfI..Ç~!-!§.l Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT 07-33B Program DEV Well bore seg D PTD#:2031120 Field & Pool PRUDHOEBAY,PRUDHOEOIL-640150 InitialClasslType DEV/1-0IL GeoArea 890 Unit 11650 On/OffShore ~ Annular Disposal D Administration 1 Pel1TJitfee ~ttacheØ. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .Le~s~.numberappropriat.e.................................. . .Y~s . . . . .. ........................................... . . . . . . . . . . . . . . . . . . 3 .U.n[que weltn.ame.and nl.!mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . .Y~s . . . _ . . . . . . . . . . . . . . _ . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . _ . . _ . . . . . . . . . . . . . . . . . . . . . . . 4 Well .located [n.a.d.efjneppool. . . . . . . . . . . . . . . . _ _ _ . .. ................ .Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............. . . . . _ . 5 WelUocated pr.oper pistance. from driJling unitb.ound.ary. . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 WelUocated proper .distance. from otber welJs. . . . . . . . . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . . . . . _ . . .. ............................ . . . . . . . . . . 7 .S.utficient .acre~ge.ay~iIable in.dJilling l.!njt. . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Jf.devi~ted, js. weJlbore platincJuped . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 90pe(ator onl}! affected party. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .Ope(atof has.appropriate.bond in.force. . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . .Y~s . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . _ _ . . . . . . . . . 11 P~l1TJit. c.an be iSSl.!ed wjtbout co.nserva.tion order. . . . . . . . . . . . . _ . . . . . . . . . . . . . . .Y ~s . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . .. ................. . . . . . . . . Appr Date 12 Pel1TJitc.an be issued wjtbout ~d.ministratÏ\le.approvaJ . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ..... _ . . RPC 6/19/2003 13 Can permit be approved before 15-day wait Yes 14 WeIlJocatedwithinªre~~nd.strata.authorizedby.lnjectionOrd~r#(PuUO#in.comm.ents).(For. NA......................... ............................................ 15 AJlwelJs.witÞi.nJl4.l1Jite_afea.ofreYiewjd~nt[fied(ForseNj~.wellOI'!I}!)............... .NA.............................................................. _............. 16 Pre-produ~edinjector; puration.ofpre-propuctiol'!l~s~th~1l3montbs.(For.servi.œwellonly).. .NA.............. ....................................................... 17 ACMP.Fjnding.ofCon,Si,Stency.h.as bee.nj~sued.for.this pr.oject . . . . . . . . . . . . . . . . . . . NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . Engineering 18 .C.onductor strillg.PJovided . . . . . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . . . . . . . . NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .S.urf~ce .ca~ing. pJQtecl~ alLknowll USDWs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .NA. . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20 .CMT v.ot adeQu.ate.to circ~tate.o.n.cOl'!d.uctor. & SUJf.csg . . . . . . . . . . . . . . . . . . . . . . . . .NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . 21CMT v.ot adeQu.ate.to tie-in Jong .string to.surf csg. . . . . _ _ _ . . . . . _ . . . . . . . . . . . . . . NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 .CMTwill coyeraJl know/l.pro.ductiYe borilOlls. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s. ..................... _ . _ . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . _. . . . . . . . . . . . . 23 .C.asing designs ~d.equa.te for C,.T~ B&perroafrost . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............. . . . . . . . . . . . . 24 Apequate.tan.kage.oJ re.serve pit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . .. CTDU...................................................... . . . . . . . 25 Jf.a.re-$:!ril~ h~s.a. tO~03 for abandollme.nt been approved. . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Apequatewellboreseparatio.npfoposep.. _ . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . .Y~s. . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . 27 Jf.djverter req.uired, does jt meet reguJatiol'!s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA. . . . . . . . Sidetrack.. . . . _ . _ . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 28 .Drilling flujd.program schematic.& eq.uipJistadequate. . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . Max MW.8J. ppg.. .............. ....... _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . WGA 6/19/2003 29 .BOPEs,.dothey meetreguJatiol'! . _ . . . . . . . . . . . . . . _ . . . .. .............. .Y~s ....................................... . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . 30 BOPE.pressralingappropriate;.testto.(putpsigi.n.comments).. _................ .Yes..... . Testto.3500.psi.MSfl23.50psi.. ...... ........................ _. ............ 31Choke.l1Janifold compJies. w/APtRfI-53 (May B4). . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 Work will oCC.ur without.operation .shutdown. . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . 33 .Is presence. of H2S g~s. probable. . . . . . . . . . . . . . . . . . . . .. .......... N.o. . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....... _ . . . . 34 MecbanicaLcondJt[on of wells within 808. verified (for.s.ervice welJ onJy) . . . . . . . . . . . . . NA. . . . . . .. ............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Geology 35 Pel1TJit can be iSSl.!ed w/o hydrogen. sulfide meas.ure$. . . _ _ . . .. ......... _ . . N.o. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36 .D.atapJesented on. pote.ntial overpreS.sure .zOl'!es. . . . . . . . . . . . . . . . . . . . . . . . NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . Appr Date 37 .Seismic.analysJs of sbaJlow gas. zones. . . . . . . . . . _ . . . _ . . . . . . . . . . _ . . . . . NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . RPC 6/19/2003 38 .Seabep .condition survey (if off-shore) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . .NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39 . Conta.ct l'!arnelpÞOlleJor.weekly progress. reports [exploratory .only] . . . . . . . . . . . . . . . . .NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............ . . . . . _ . . . . . . . . . . . . . . . . Geologic Commissioner: Drs Date: Engineering Commissioner: Date Public Commissioner Date O&(èO( Q.S ~ tG/~p - e Well History File APPENDIX Information of detailed nature that is not particularly gennane 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 infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infonnatian. e e ~()3-(12- **** REEL HEADER **** MWD 04/12/14 ::{: p../1 µ I BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/10/31 569549 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10767.0000: STOP.FT 12585.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 34 TOWN.N 11N RANG. 14E UM PDAT. MSL EPD . F 0 LMF . RF FAPD.F 60 DMF OF EKB .F 0 EDF .F 60 EGL . F 0 CASE.F 10806 OSl . DIRECTIONAL OS2 . PRESSTEQ I -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data is realtime data. (4) Baker Hughes INTEQ utilized CoilTrack downhole tools and ADVANTAGE Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska) Inc. 07-33B Prudhoe Bay 70 deg 16' 6.950" N, 148 deg 34' 15.037" W North Slope Alaska Baker Hughes INTEQ 2.375" CoilTrak - Gamma Ray 31-0ct-03 500292180902 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Other Services Line 1 e e surface system. (5) Tools run in the string included Casing Coil Locator, Electrical Disconnect and Circulating Sub, a Drilling Performance Sub, (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and a Hydraulic Orienting Sub with near bit inclination sensor. (6) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) recorded by SWS on 04-Nov-03. The depth shifting was performed on interval 10806' - 12500' MD (8682' - 8893' SSTVD) (7) The sidetrack was drilled from milled window in 4 1/2 inch liner. Top of window: 10800 ft MD (8677 ft. TVD) Bottom of window: 10806 ft MD (8682 ft. TVD) (8) The interval from 12560 ft. to 12585 ft. MD (8893.5 ft to 8893.6 ft. TVD) was not logged due to bit to sensor offset. (9) Tied in to 07-33A at 10774 ft. MD. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 10802.4, 10801.6, 10810.8,10812, 10828.5, 10828.9, 10833.7, 10833.5, 10846.2,10842.6, 10848.2,10850.1, 10870, 10869.1, 10875.2,10873.5, 10888.5, 10883.7, 10895.7, 10891, 10913.4, 10912, 10917.1, 10916.1, 10920, 10918.8, 10926.5,10925.9, 10930.4,10930, 10935.4, 10934, 10941. 4, 10941. 9, 10953.9, 10951.9, 10959.9, 10959, 10965.7, 10967.6, 10973.1, 10972.3, 10978.4, 10977.3, 10984, 10983.6, 10991.9, 10991.7, 11000.5, 10999.9, 11008.2, 11007.4, 11027.7, 11026.7, 11050.2, 11050.2, 11057.4, 11055, 11061.4, 11060.4, 11068.3, 11067.7, 11079.7, 11078.4, 11095.8, 11094.3, 11104.3, 11103.7, 11107.2, 11107.8, 11114.4, 11112.1, 11127.3, 11124.6, 11140.2, 11138.1, 11154.4, 11147.5, 11159.6, 11156, 11162.7, 11164.6, 11168.9, 11167.3, 11175.6, 11173.9, 11182.1, 11180.7, 11194.8, 11193.3, 11202.5, 11203.7, 11219.3, 11219.3, 11238.2, 11236.4, 11255, 11259.3, 11260.4, 11263.9, 11279.5, 11277.6, DISPLACEMENT -0.831055 1.24707 0.416016 -0.208008 -3.53223 1.87109 -0.831055 -1.66211 -4.78027 -4.78027 -1. 45508 -1.03906 -1.24707 -0.623047 -0.416016 -1. 45508 0.416016 -2.07812 -0.831055 1.87012 -0.832031 -1.03906 -0.416016 -0.207031 -0.624023 -0.831055 -1. 03906 o -2.49414 -1.03906 -0.623047 -1. 24609 -1.45508 -0.623047 0.623047 -2.28613 -2.70117 -2.07812 -6.85742 -3.53223 1.87109 -1.66211 -1.66211 -1. 45508 -1. 45508 1.24707 o -1.87012 4.36426 3.5332 -1.87012 11289.9,11288.2, 11293.3, 11291, 11314, 11313.6, 11332.1, 11328.3, 11339.5, 11336.8, 11350.9, 11346.7, 11391.6, 11388.1, 11396, 11393.1, 11404.9, 11403.9, 11415.5, 11413.6, 11423.2, 11421.5, 11431.9, 11429.8, 11441.1,11440.2, 11449.4, 11450.9, 11457.1, 11456.7, 11486.4, 11485.8, 11531.4, 11530.2, 11554.1,11554.1, 11573.4, 11572.6, 11624.7, 11620.7, 11639, 11635, 11642.7, 11639.4, 11669.9,11669.9, 11684, 11681.3, 11816, 11811.7, 11823.6, 11818.8, 11829.1, 11822.5, 11835, 11829.8, 11839.1, 11834.3, 11859.3, 11852.4, 11865.5, 11860.7, 11891.5, 11882.2, 11900, 11894.2, 11904.2, 11898.4, 11926.4, 11925, 11932.5, 11933.9, 11936.4, 11941, 11948.8, 11953.8, 11966.8, 11962.3, 11971, 11967.5, 11973.7, 11970.6, 11978.5, 11977.7, 11982,11980.9, 11983.9, 11982.4, 11986.8, 11986.2, 11989.9, 11988.3, 11994.5, 11994.3, 12062.5, 12062.5, 12072.9, 12073.7, 12226.3,12229.2, 12237.5, 12244.6, 12249.6, 12248.9, 12258.9, 12258.9, 12277.4, 12276.4, 12293.1, 12291.8, 12305.7, 12303.4, 12329, 12329, 12343.1, 12341.5, 12354.5, 12353.8, 12411.9, 12406.5, 12421,12414.3, 12445.1,12438.2, 12457.5, 12451.1, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: e e -1.66309 -2.28613 -0.416016 -3.74023 -2.70117 -4.15625 -3.53223 -2.90918 -1. 03906 -1.87109 -1.66211 -2.07812 -0.831055 1. 4541 -0.415039 -0.623047 -1.24707 o -0.831055 -3.94922 -3.94824 ! -3.3252 ! 0 -2.70117 -4.36426 -4.7793 -6.64941 -5.19531 -4.7793 -6.8584 -4.7793 -9.35156 -5.81934 -5.81934 -1.45508 1.45508 4.57227 4.98828 -4.57227 -3.5332 -3.11719 -0.831055 -1.03906 -1.45508 -0.623047 -1.66211 -0.208008 o 0.832031 2.90918 7.06543 -0.623047 o -1.03906 -1.24707 -2.28613 o ! -1.66211 -0.623047 -5.40332 -6.65039 -6.85742 -6.44141 183 records... 10 bytes 132 bytes e e **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 7-33b 5.xtf 150 BP Exploration (Alaska) Inc. 07-33B Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 04-Nov-03 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX01 ROPS01 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth 10: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 44 Tape File Start Depth Tape File End Depth 10767.000000 12585.000000 e e Tape File Level Spacing Tape File Depth Units 0.500000 feet **** FILE TRAILER **** Tape Sub file: 2 53 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT r. xtf 150 BP Exploration (Alaska) 07-33B Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 e Total Data Records: 87 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10767.000000 12584.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 96 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/10/31 569549 01 **** REEL TRAILER **** MWD 04/12/14 BHI 01 Tape Subfile: 4 2 records. . . Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Sub file 2 is type: LIS DEPTH GR ROP 10767.0000 -999.2500 -999.2500 10767.5000 -999.2500 -999.2500 10800.0000 44.5881 16.5651 10900.0000 30.4098 82.4377 11000.0000 29.3518 88.2370 11100.0000 72.2371 20.0161 11200.0000 39.8204 53.3597 11300.0000 43.1760 56.2070 11400.0000 68.7466 103.8463 11500.0000 58.3337 78.5106 11600.0000 63.9445 98.1222 11700.0000 60.3919 104.0486 11800.0000 56.6850 85.4650 11900.0000 131.2577 16.3674 12000.0000 59.9191 60.4003 12100.0000 62.7561 111.7935 12200.0000 77.5278 103.2291 12300.0000 98.4829 110.6973 12400.0000 34.9984 165.2787 12500.0000 34.2177 47.6211 e ------- 8 e e 12585.0000 -999.2500 -999.2500 Tape File Start Depth 10767.000000 Tape File End Depth 12585.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet , . e e Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 10767.0000 -999.2500 -999.2500 10767.2500 -999.2500 -999.2500 10800.0000 44.4100 60.0000 10900.0000 26.1000 55.7500 11000.0000 27.8200 85.3300 11100.0000 50.0500 30.2100 11200.0000 39.8300 58.9600 11300.0000 42.3700 56.2700 11400.0000 63.6700 106.4800 11500.0000 63.0100 78.7600 11600.0000 61. 2300 85.9200 11700.0000 60.0100 102.3400 11800.0000 59.0600 92.8000 11900.0000 123.0100 19.9600 12000.0000 59.3100 73.2500 12100.0000 62.2200 114.0900 12200.0000 83.0600 101.9100 12300.0000 104.4100 105.5000 12400.0000 39.3400 121. 5600 12500.0000 36.5200 59.4600 12584.7500 -999.2500 -999.2500 Tape File Start Depth 10767.000000 Tape File End Depth 12584.750000 Tape File Level Spacing 0.250000 Tape File Depth Units feet
