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Home My WebLink About202-200 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned • ❑ Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 ® Development • ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 5/19/2012 . 202 - 200 , 312 - 126 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 11/11/2002 > 50 029 - 21733 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/13/2002 • PBU J -27A ' 800' FNL, 1771' FEL, Sec. 09, T11 N, R13E, UM • 8. KB (ft above MSL): 76.9' 15. Field / Pool( s ) Top of Productive Horizon: 2474' FNL, 1417' FEL, Sec. 09, T11 N, R13E, UM GL (ft above MSL): 40.38' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 3298' FNL, 2031' FEL, Sec. 09, T11N, R13E, UM 9305' 8901' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 642582 • y- 5970536 ' Zone ASP4 • 10574' 9038' • ADL 028281 ' TPI: x- 642971 y- 5968869 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 642375 y- 5968034 Zone ASP4 None 18. Directional Survey: ❑ Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, RES, GR, CNL, CCL, ROP 9279' 8881' 23. CASING, LINER AND CEMENTING RECORD S ETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING Wr. PER FT. GRADE To ' BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" Conductor Surface 110' Surface 110' 8 cu vds Concrete 13 -3/8" 72# L -80 / S -95 Surface 2683' Surface 2683' 17 -1/2" 1667 cu ft PF 'E'. 2055 cu ft PF 9 -5/8" 47# L -80 Surface 8699' Surface 8399' 12 -1/4" 1744 cu ft Class 'G' 7" 26# L -80 8451' 9279' 8191' 8881' 8 -1/2" 30 ft Class 'G' 3- 112 "x3 - 3116 "x2 -716" 8.81#16.2#16.16# L -80 8443' 10574' 8185' 9038' 3 -3/4" 112 cu ft Class 'G' 7" 26# L -80 2922' 8151' 2921' 7,* , Tieback 780 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#, 13CR80 x 8416' 7933' / 7763', MD TVD MD TVD 3 -1/2 ", 8.81 #, L -80 8383 / 8135' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED DEPTH 1 9 305 vAL (MD)I W A O ock ( A s D KIND OF failed) L USED JUN 1420122 27. AOGCC 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: 1 Test Period 4 Flow Tubing Casing Press: Calculated OIL - BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes IN No . Sidewall Core(s) Acquired? ❑ Yes ® No , If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None „, <li_ > '3' c j i i_.. , _ ._ Li B8DMS JUN 15 1 n Vi--F I 4' - k Form 10 Revised 12/2009 CONTINUED ON REVERSE * ,/,�/' Submit Original Only 29. GEOLOGIC MARKERS (List all formations "'markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 25P 9277' 8879' None 23P 9380' 8952' 22P 9431' 8977' 21P 9530' 9008' Zone 1B 9928' 9033' 14N 9936' 9034' • Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the f • - . • • • • is true nd co ct to the best of my knowledge. /1 Signed: Joe Lastufka Title: Drilling Technologist Date: (0( 1 1 / Z PBU J - 27A 202 - 200 312 - 126 Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Jacob Leemhuis, 564 -4989 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only �► • J -27A, Well History (Pre Rig Sidetrack) Date Summary 05/02/12 CTU #9 1.75" Job Scope: Mill out 2.7" aluminum guide shoe to 2.74" Unit moved out of the yard to J -27. 05/03/12 CTU #9 1.75" Job Scope: Mill out 2.7" aluminum guide to 2.74" Finished RU. Drifted new reel w/ 1.25" ball. Performed weekly BOP test - passed. Proceed w/ tree cap removal. SSV leaking. Called for grease crew for troubleshooting. Repeated leak off test on SSV. Passed. Killed the well w/ 200bbis of KCI followed by 1 Obbls of 60/40 for freeze protect. RIH w/ milling BHA 2.14" Kendle CTC, 2.14" DCV, 2.13" Hyd Disco, 2.13" Dual Circ Sub, 2.13" Left handed Motor, 2.74" Left handed Parabolic Mill. OAL= 15.91'. Passed through guide shoe depth w/ not tag. PUH. Up weight normal. RIH.Tagged twice at 9330' ctmd on 3- 3/16 "x 2 -7/8" XO (9355' on mech counter). PUH. Backreamed at 1.25bpm, 8fpm from 8430' to 8360' ctmd. No motor work. Make a dry run to 8640' ctmd w/o issues. PUH w/ pumps off. Up weights normal. POOH. Pumped 38bbls of 60/40 down backside for FP. At surface. Lay down toolstring. 05/08/12 DRIFTED TO 9330' SLM/9358' MD WITH 18 1/2' x 2.6" DUMMY WHIPSTOCK NO PROBLEMS. 05/09/12 T /1 /O= Vac /0/140 Conducted PJSM w /crew; P.T. (charted) SN to 300 psi /3500 psi (passed), S/V & SSV used as barriers; Installed Lubricator & P.T. (charted) w /each break to 300 psi /3500 (passed); Set 4" CIW "H" TWC #259 @ 116" w /1 -1' ext.; Torqued all tree flange nuts /studs to spec. (see log) & bench marked; P.T. (charted) tree to 300 psi /5000 psi (passed); pulled 4" TWC; Note: SN & Tree P.T. 05/10/12 T /I /0= 20/02/0 Temp =Sl Load & Kill (Pre E -line) Pumped 5 bbls meth, 160 bbls 1101 1% KCI down Tbg to load. Freeze protected Tbg with 40 bbls diesel. Final WHPs 0/80/0 SV,WV,SSV= Shut MV,IA,OA= Open. 05/10/12 (SLB E -LINE SET BAKER PACKER WHIPSTOCK). INITIAL T /1 /0 = 0/0/400 PSI. ATTEMPT TO ORIFNT WHIPSTOCK TO DESIRED POSITION UNSUCCESSFUL. DIFFICULTY PULLING OUT OF HOLE. TOOLSTRING STUCK AT 8453FT. LRS IN ROUTE TO ATTEMPT PUMP OUT. STANDING BY. 05/11/12 T /I /O= vac /0/188 Temp =Sl Assist E -line (Pre CTD) Pumped 2 bbls meth followed by 197 bbls of diesel down tubing. Pumped 235 bbls of 1 %KCUSafe -Lube mix followed by 5 bbls meth down tubing. Freeze protect tubing with 36 bbls crude. FWHP 1250/0/320 SV,WV,SSV = closed, MV =open, IA and OA =OTG. 05/11/12 (ELINE: WHIPSTOCK). LRS PUMPED 180BBL DIESEL -ABLE TO MOVE FROM 8442' UP TO 8292'. STUCK AT 8292' DECISION MADE TO PUMP 225BBL KCL SAFELUBE, STILL UNABLE TO MOVE TOOLS AFTER PUMPING SAFELUBE. DECISION MADE TO RELEASE FROM ERS. TOOLSTRING LEFT IN HOLE: 1 -3/8" OTIS #2 FISHING NECK (ERS), SWIVEL, 2- CENTRALIZERS, WPMOT, WPTET, WPGRT, SLIM BAKER 10 SETTING TOOL, 3- 3/16" PACKER WHIPSTOCK, OAL =44FT, MAX OD= 2.7" TOP OF TOOL AT APPROX 8277'. LRS WILL FP WELL. FINAL T /1 /O: VAC /0/550 PSI. 05/12/12 RAN KJT, 2.60 BELL GUIDE, 2" JUS.. S/D ON DEPLOY SLV @ 8406' SLM, BOBBLE THROUGH. S/D & LATCH E -LINE TOOL @ 9282' SLM. 05/13/12 RAN 2" JDC TO FISH @ 9282' SLM, MOVE UP TO 9280' SLM. 05/14/12 T /I /O SSV /0/140 Temp= SI PPPOT-T (PASS) CTD Prep. PPPOT -T: stung into test void (1750 psi.). Bled void to 0 psi. Functioned LDS all moved freely (2.5 "). Pumped through void good returns. Pressured test void to 5000 psi. for 30 min. test. Lost 200 psi. in 15 min. Lost 50 psi. in second 15 min. (PASS). Bled void to 0 psi. Page 1 of 2 . . J -27A, Well History (Pre Rig Sidetrack) Date Summary 05/14/12 T /I /O = SSVNAC /150. Temp = SI. Bleed Tbg 250 psi, IA & OA to 0 psi (Pre CTD). No AL. TBG has TWC in hole. Bled OA from 150 to 0 psi in 1.5 hrs. Monitored 30 min. OAP increased 5 psi. Final WHPs = SSVNAC /5. SV, WV, SSV = C. MV = 0. IA, OA = OTG. 1130. 05/14/12 T /I /0 =0 /0 /0 Upon arrival, conducted PJSM. Verified Tubing psi. Shut Swab & SSV. PT'd 3500 psi. from top side 5 min. pass. Removed tree cap, attached lubricator with TWC, pressure tested 250 /Iow..3500 /high..5 min. pass. SET 4" CIW "H" TWC #258 thru tree using 1 -1' ext. Tagged @ 116" Shut Swab & SSV, removed lubricator, installed tree cap, Pressure tested against TWC thru tree cap 250 /Iow..3500 /high..5 min. pass (see chart in TRP folder) Pre Nordic 2. i Page 2 of 2 • North America - ALASKA - BP Page 1 Operation Summary Report Common Well Name: J -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/16/2012 End Date: 5/27/2012 jX3-011 WJ-C: (2,835,643.55 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 6/14/1987 12:00:OOAM Rig Release: 6/1/2012 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.314 "4 Long: 10148°50'37.194'W Active Datum: ORIG KELLY BUSHING @76.90ft (above Mean Sea Level) _ Date From - To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) ft 5/16/2012 00:00 03:00 3.00 MOB P PRE BEGIN RON EVENT AT 00:00 ON 5/16/2012. MOVE NORDIC 2 RIG FROM F PAD TO J PAD (3 MILES). ROAD CONDITIONS = FROZEN SLUSH AND MUD. STAGE RIG ON PAD 03:00 - 06:00 3.00 MOB P PRE SET RIG MATS AROUND J-27 WELLHEAD WHILE RIG STAGED ON J PAD. 06:00 - 06:30 0.50 MOB P PRE CREW CHANGE. DISCUSS RIG MOVE STATUS. MAKE EQUIPMENT CHECKS AND BALL ROUNDS. j CONTINUE TO PREP AROUND WELLHEAD. 06:30 - 07:30 1.00 MOB P PRE ARRANGE RIG MATS. LAY DOWN PLYWOOD FORR CELLAR FOOTING. 07:30 - 08:00 0.50 MOB P PRE HOLD DETAILED PJSM. DISCUSS COMMS, SPOTTER ASSIGNMENTS. 08:00 - 08:30 0.50 MOB P PRE ACCEPT RIG AT 0800 HRS. MOVE RIG OVER WELLHEAD. I INITIAL T /1 /O = TWC /0/20 PSI 08:30 - 10:00 1.50 RIGU P j PRE BEGIN SPOTTING EXTERNAL EQUIPMENT. RU HARDLINE TO TIGER TANK. RUN POWER TO SAT CAMP. SPOT CUTTINGS BOX, WELDING SHACK, SUPPLY TRAILER. 10:00 - 13:00 3.00 BOPSUR P PRE BLEED TREE CAP. REVIEW AWGRS RECORDS TO CONFIRM TWO TESTED BARRIERS: TWC AND SWAB VALVE BOTH PASSED LOW AND HIGH PRESSURE TESTS. CONTINUE TO RU EXTERNAL EQUIPMENT. NIPPLE DOWN TREE CAP AND SET BOP l I STACK ON CAMERON 4 -1/8" TREE. NIPPLE UP BOPS TO SWAB FLANGE WITH FOLLOWING STACK CONFIGURATION: - 7- 1/16" HYDRIL GK ANNULAR PREVENTER - TOT BLIND -SHEAR RAMS - TOT 2 -3/8" COMBI PIPE SLIP /RAMS - MUD CROSS WITH 2- 1/16" MANUAL GATE VALVES + 4- 1/16" HCR VALVES ON BOTH CHOKE AND KILL LINES - TOT 2 -3/8" X 3-1/2" VB RAMS - TOT 2 -3/8" COMBI PIPE SLIP /RAMS. 13:00 - 16:30 3.50 RIGU P PRE COMPLETE ALL MAINTENANCE ITEMS AS PER RIG MOVE CHECK LIST. CLEAN PUMP AND HIGH PRESSURE SCREENS. CONTINUE SHAKER ASSEMBLY REPLACEMENT. 116:30 - 17:00 0.50 RIGU P PRE HOLD RIG EVACUATION DRILL AND AAR. PRE -SPUD MEETINGS HELD WITH EACH CREW. Printed 6/4/2012 11:22:39AM 0 North America - ALASKA - BP • Page 20 Operation Summary Report Common Well Name: J -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/16/2012 1 End Date: 5/27/2012 X3 -011 WJ-C: (2,835,643.55 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 6/14/1987 12:00:OOAM Rig Release: 6/1/2012 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.314 "4 Long: 1 0148 °50'37.194'W Active Datum: ORIG KELLY BUSHING @76.90ft (above Mean Sea Level) Date From - To Hrs Task Code 1 NPT I NPT Depth 1 Phase 1 Description of Operations (hr) 1 I (ft) 17:00 - 18:00 , 1.00 BOPSUR P PRE FILL CHOKE MANIFOLD AND RIG UP FOR 1 BOPE TEST. PERFORM BOP SHELL TEST AGAINST SWAB VALVE TO 4500 PSI ! (PASSING TEST). LOAD PITS WITH 290 BBLS 8.4 PPG 1% KCL , WITH 0.6% SAFELUBE 18:00 - 00:00 6.00 BOPSUR P PRE PRESSURE TEST BOPE PER DWOP ANC) ' AOGCC STANDARDS TO 250 PSI LOW AND 1 3500 PSI HIGH. FOR FIVE MIN ON EACH TEST (ALL PASSING TESTS, SEE ATTACHED DOCUMENTATION. !- TESTS CONDUCTED AGAINST TWC AND I CLOSED SWAB/MASTER/SSV. - ANNULAR AND ALL RAMS TESTED WITH 2 -3/8" TEST JOINT. - TEST ALL GAS ALARMS ON RIG I - ALL COMPONENTS FUNCTIONED FROM BOTH CONTROL PANELS. - TEST COMPLETED AT 00:30 ON 5/17/2012. 5/17/2012 00:00 - 00:30 0.50 BOPSUR P PRE I COMPLETE BOP TEST. PERFORM ACCUMULATOR DRAWDOWN/FUNCTION I i 1 TEST. 100:30 - 01:00 0.50 RIGU P PRE HOLD RIG EVACUATION DRILL AND AAR. COMPLETE PRE -SPUD MEETINGS WITH BOTH RIG CREWS. 01:00 - 03:00 2.00 RIGU P PRE ' STAB ON INJECTOR AND CIRCULATE DIESEL FREEZE PROTECT CAP OUT OF COIL REEL. 03:00 - 05:00 2.00 RIGU P PRE PERFORM E -LINE SLACK MANAGEMENT. 1 UNABLE TO PUMP E -LINE SLACK BACK WITH 1 I I KCL FLUID. SUCCESSFULLY PUMP SLACK 1 j BACK WITH 45 BBLS FRESH WATER. 105:00 - 06:00 l 1.00 RIGU P PRE CUT 241' 2 -3/8" COIL AND PUMP E -LINE - - - -- 1 SLACK FORWARD. ■ 06:00 - 08:00 2.00 RIGU P PRE INSTALL 2 -3/8" KENDLE X 1 -1/2" MT COILED TUBING CONNECTOR. I CREW CHANGE. DISCUSS OPS AND EQUIPMENT STATUS. MAKE RIG CHECKS I AND ROUNDS. 08:00 - 09:00 f 1.00 BOPSUR 1 P PRE PRESSURE TEST INNER REEL VALVE AND PACKOFFS TO 250 AND 3500 PSI. RECORD. 1 PASSED. TEST SSV PANEL AND CYCLE VALVE. 09:00 - 11:30 2.50 BOPSUR P PRE PJSM. I RUN DSM LUBRICATOR. TESTTO 250 AND i 13500 PSI. RECORD. PASSED. I 1 ENGAGE AND RECOVER TWO WAY CHECK 1 I 1 VALVE. 1 1 CLOSE MASTER AND SWAB. � ! RD LUBRICATOR. REMOVE FROM RIG. WHP: 0 PSI. I 1 MU AND TEST DUAL FLAPPER CHECK I VALVES. 250 AND 3500 PSI. RECORD. PASSED. 11:30 - 13:00 1.50 KILLW F P DECOMP MU NOZZLE AND STINGER BHA. GET ON WELL. TEST QTC: 250 AND 3500 PSI 1 RECORD. PASSED. Printed 6/4/2012 11:22:39AM North America - ALASKA - BP • Page 3 °, Operation Summary Report Common Well Name: J -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/16/2012 End Date: 5/27/2012 X3 -011 WJ-C: (2,835,643.55 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 6/14/1987 12:00:OOAM Rig Release: 6/1/2012 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.314 "4 Long: 0148°50'37.194'W Active Datum: ORIG KELLY BUSHING @76.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 14:30 1.50 KILLW P DECOMP HOLD PJSM. ' CIRC DOWN COIL AND ATTEMPT TO BULLHEAD. WELL PRESSURED UP QUICKLY. WILL NOT BE ABLE TO BULLHEAD. 14:30 - 17:00 T 2.50 KILLW P DECOMP RUN IN HOLE WITH NOZZLE BHA. TAKE RTNS TO TIGER TANK. 17:00 - 18:30 I 1.50 KILLW P DECOMP CIRCULATE CRUDE FREEZE PROTECT OUT I OF WELL + BTMS UP WITH SLICK KCL FROM 9000'. MW IN = MW OUT = 8.4 PPG. NO LOSSES TO WELLBORE. FLOWCHECK WELL PRIOR TO POOH. WELL STATIC. 18:30 - 20:30 2.00 KILLW P DECOMP PULL OUT OF HOLE FROM 9000' MD TO SURFACE. CHECK FOR FLOW. WELL STATIC. 20:30 - 21:30 1.00 KILLW P DECOMP LAYDOWN NOZZLE BHA AND MAKEUP 1 FISHING ASSEMBLY WITH 2 -3/8" COILTRAK TOOLS. 1- P &C, EDC, DPS, DGS - DUAL ACTING JARS JDC OVERSHOT 1 - BHA OAL = 44.93', GR IS 9.5' BACK FROM 1 1 JDC 21:30 - 22:00 j 0.50 FISH N DPRB 10,574.00 ! DECOMP STAB ON INJECTOR AND PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING — — TESTS). 22:00 - 00:00 2.00 FISH N 1 DPRB 10,574.00 DECOMP RUN IN HOLE WITH FISHING ASSEMBLY FROM SURFACE TO 8680' MD (STARTING ''POINT FOR DEPTH TIE -IN) AT MIDNIGHT. 5/18/2012 00:00 - 01:00 1.00 FISH N DPRB ! 10,574.00 ! DECOMP LOG DOWN AT 2 FPM FROM 8680' MD AT TOP OF SAG RIVER TO 8750' MD AND ACROSS OLD WHIPSTOCK AT 9285' MD TO PICKUP RA TAG FOR DEPTH CONTROL. TIE -IN TO SAG RIVER GR SIGNATURE AT 8725' MD ( +12 CORRECTION). OBSERVE RA 1TAG IN OLD WELLBORE WHIPSTOCK ON DEPTH AT 9285' MD. 01:00 - 02:30 1.50 FISH N DPRB 10,574.00 DECOMP TAG TOP OF FISH AT 9317' MD (1' DEEPER THAN CALCULATED BASED ON 3- 3/16" X 2 -7/8" LINER XO - BHA LENGTH). LATCH FISH AND PULL UP IN 2 KLBS INCREMENTS TO 20 KLBS OVERPULL. NO JAR HITS. OBSERVE NO MOVEMENT OR PARTING OF FISH. 1 DECISION WITH ODE TO ABANDON FISHIN,C EFFORTS AND PULL OUT OF HOl F FOR NFW.V PACKER WHIPSTOCK. 02:30 03:00 0.50 FISH N DPRB 10,574.00 DECOMP CONFIRM CASING WHIPSTOCK. FLOW P FOR CHECK TO WELL. WELL STATIC. 03:00 - 03:30 0.50 FISH N DPRB 10,574.00 DECOMP I PULL OUT OF HOLE FROM 9100' MD TO 7750' MD DRILL DEPTH). 03:30 - 04:30 1.00 FISH N DPRB 10,574.00 DECOMP PERFORM UNANNOUNCED KICK WHILE !TRIPPING DRILL BY SIMULATING PIT GAIN. SHUT IN WELL, LINE UP AND CIRCULATE THROUGH GAS BUSTER. HOLD AAR. Printed 6/4/2012 11:22:39AM • North America - ALASKA - BP • Page 4 Operation Summary Report Common Well Name: J -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/16/2012 End Date: 5/27/2012 X3 -011 WJ-C: (2,835,643.55 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 2 , Spud Date/Time: 6/14/1987 12:00:OOAM Rig Release: 6/1/2012 Rig Contractor: NORDIC CALISTA ' UWI: / Lat: 070 °19'37.314 "4 Long: 0148°50'37.194'W Active Datum: ORIG KELLY BUSHING @76.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 06:00 1 1.50 FISH N DPRB 10,574.00 DECOMP PULL OUT OF HOLE FROM 7750' MD TO BHA AT 45' MD; 1.1 BPM THROUGH EDC, 110 FPM. FLOW CHECK WELL. WELL STATIC. 06:00 - 06:30 ! 0.50 FISH N DPRB 10,574.00 DECOMP CREW CHANGE. DISCUSS OPERATIONS AND RIG STATUS. MAKE ALL CHECKS AND ROUNDS. CONTINUE TO POOH. 06:30 - 07:30 1.00 FISH N DPRB 10,574.00 DECOMP AT SURFACE. FLOW CHECK WELL. GET OFF WELL. UNSTAB COIL. LD INTEQ OOLS AND FISHING TOOLS. 07:30 - 08:30 1.00 WHIP N DPRB 10,574.00 WEXIT 1MU BAKER 033 WHIPSTOCK AND PACKER ASSEMBLY. SCRIBE TRAY FACE TO HOT HIGH SIDE. MU TOOL STRING. STAB COIL. TEST TOOLS. GET ON WELL. TEST QTS. 250 AND 3500 PSI. RECORD. PASSED. 08:30 - 11:00 2.50 WHIP N DPRB 10,574.00 WEXIT VERIFY EDC IS OPEN. RUN IN HOLE AT 55 -60 FPM. SLOW DOWN AT ALL JEWELRY. 11:00 - 11:30 0.50 WHIP N DPRB 10,574.00 WEXIT LOG GR TIE IN FROM 8720'. ADD 12' CORRECTION (SAME AS PREVIOUS RUN) 11:30 - 12:15 0.75 WHIP N DPRB 10,574.00 WEXIT RUN IN HOLE. 40K# UP WT AT 9200'. TAG TOP OF WHIPSTOCK FISH AT 9317'. PU. RIH. SET TOP OF REPLACEMENT WHIPSTOCK AT 9305'. RA AT 9310' CLOSE EDC. PRESS COIL TO 3000 PSI. SETTING TOOL ACTIVATED AND SHEARED. SET DN 2K #. 12:15 13:30 1.25 WHIP N DPRB 10,574.00 WEXIT POOH TO 8400'. HOLD PJSM. PRESS TEST TBG AND LINER. 250 PSI AND 2500 PSI. RECORD. PASSED AS PER CRT- AK- 10 -45. SEE ATTACHED DOCUMENTATION. 13:30 - 15:30 2.00 WHIP N DPRB 10,574.00 WEXIT CIRCULATE OUT OF HOLE. 15:30 - 18:00 2.50 WHIP N DPRB 10,574.00 WEXIT AT SURFACE. WAIT ON COMPLETION OF HOPKINS DERRICK / DROPS INSPECTION. CONTINUE CIRCULATING COIL WHILE STABBED ON WELL. 18:00 - 20:00 2.00 WHIP N DPRB 10,574.00 WEXIT RUN IN HOLE WITH WHIPSTOCK RUNNING TOOLS FROM SURFACE TO 1000' MD. CIRCULATE ONE COIL VOLUME + BOTTOMS UP TO DEFOAM KCL FLUID. PULL OUT OF HOLE FROM 1000' MD TO SURFACE. 20:00 21:00 DPRB - 1.00 WHIP N I � 10,574.00 WEXIT FLOW CHECK WELL. WELL STATIC. SET BACK INJECTOR AND LAYDOWN WHIPSTOCK RUNNING BHA. 21:00 - 22:00 1.00 STWHIP P WEXIT MU MILLING ASSEMBLY. STAB ON INJECTOR AND PRESSURE TEST QTS TO 250 PSI LOW AND3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). - 2 -3/8" COILTRAK TOOLS (EXCLUDING HOT) - 2 JTS 2- 1/16" CSH PIPE AND BAKER 2 -3/8" EXTREME MOTOR - 2.74" DIAMOND STRING MILL AND 2.74" HCC DSM WINDOW MILL BHA OAL = 109.48' Printed 6/4/2012 11:22:39AM • North America - ALASKA - BP Page 5 ONIk Operation Summary Report Common Well Name: J -27 1AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/16/2012 1 End Date: 5/27/2012 1 X3 -011 WJ-C: (2,835,643.55 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 6/14/1987 12:00:OOAM Rig Release: 6/1/2012 Rig Contractor: NORDIC CALISTA 1 UWI: / Lat: 070 °19'37.314 "4 Long: 10148°50'37.194'W - -- ---- - - - - -- - - - -- -- - - - - -- Active Datum: ORIG KELLY BUSHING @76.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) I 1 22:00 - 23:30 1.50 STWHIP P WEXIT 4 RUN IN HOLE FROM BHA AT 109' MD TO TIE -IN DEPTH AT 8700' MD. 23:30 - 00:00 0.50 STWHIP N DFAL 1- 9,305.00 WEXIT ATTEMPT TO OPEN BAKER COILTRAK TO BEGIN MUD SWAP. UNABLE TO OPEN EDC. DECISION TO TRIP FOR NEW EDC. FLOW CHECK WELL. WELL STATIC. PULL OUT OF I HOLE FROM 8700' MD TO 6000' MD AT MIDNIGHT. 5/19/2012 00:00 - 01:30 1.50 STWHIP N DFAL 9,305.00 WEXIT PULL OUT OF HOLE FROM 6000' MD AT MIDNIGHT TO BHA AT 109' MD. FLOW CHECK WELL. WELL STATIC. UNSTAB INJECTOR AND SETBACK. 01:30 - 01:45 0.25 STWHIP N DFAL 9,305.00 WEXIT ;CHANGEOUT BHI EDC. STAB INJECTOR BACK ON WELL. PRESSURE TEST QTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). EDC DOES NOT SHOW EXTERNAL SIGNS OF FAILURE. FIST -SIZED BUNDLE OF METAL SHAVINGS FOUND ON P &C TOOL WHEN PULLED TO RIG FLOOR. 01:45 - 03:30 1.75 j STWHIP N DFAL 9,305.00 WEXIT RUN IN HOLE WITH MILLING ASSEMBLY FROM BHA AT 109' MD TO TIE -IN DEPTH AT 8780' MD. SAME BHA OAL = 109.48' 03:30 - 04:00 0.50 STWHIP P WEXIT LOG DOWN AT 2 FPM TO TIE -IN TO SAG I RIVER GR SIGNATURE ( +13' CORRECTION 1 COMPARED TO +12' LAST RUN). OPEN EDC I TO BEGIN DISPLACEMENT OF WELL TO MILLING FLUID. RUN IN HOLE TO 9295' MD, 10' ABOVE WHIPSTOCK. 04:00 - 04:45 0.75 STWHIP P WEXIT 1 DISPLACE WELL AT 9295' MD TO NEW 8.5 PPG 3% KCL POWERPRO SF MILLING MUD. 1- 2% LOTORQ, 2% LUBE776, 2% KLASTOP SLOW PUMP RATES AT 9305' MD, 8.5 PPG ' MP1: .5 BPM = 1140 PSI,1 BPM = 1530 PSI, 1.5 BPM = 2020 PSI MP2: .5 BPM = 1130 PSI,1 BPM = 1540 PSI, 1.5 1 BPM = 1978 PSI - - - - - -- -- -- - - -- -- - -- --- - - - - -- - - - - - -- 04:45 - 05:00 0.25 STWHIP P WEXIT RUN IN HOLE WITH PUMPS AT MIN RATE, 0.2 BPM, AND TAG WHIPSTOCK AT 9305.8' MD. PICKUP 10', INCREASE PUMP RATE TO 1.5 BPM AND RUN BACK IN HOLE TO TAG WHIPSTOCK AT 9305.5' MD. END OPERATIONS ON 'A' WELLBORE AT _ 05:00 ON 5/19/2012. 05:00 - 06:00 1.00 STWHIP P WEXIT BEGIN 'B' WELLBORE OPERATIONS AT 05:00 ON 5/19/2012. 5 -216 BEGIN MILLING WINDOW AT 9305.7' MD; 1 FPH, 1.5 BPM, 1950 PSI FREESPIN, 2000 - 2150 PSI CIRCULATING, <1 KLBS DHWOB, 8.5 PPG MW IN/OUT, 9.6 ECD, 95 SEC /QT. IA/OA = 1550/225 PSI. Printed 6/4/2012 11:22:39AM • North America - ALASKA - BP • Page 6 °t* r Operation Summary Report Common Well Name: J -27 ' AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/16/2012 End Date: 5/27/2012 1 X3 -011 WJ-C: (2,835,643.55 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 6/14/1987 12:00:O0AM Rig Release: 6/1/2012 Rig Contractor: NORDIC CALISTA 1 UWI: / Lat: 070 0 1917.314 "4 Long: 0148°50'37.194'W Active Datum: ORIG KELLY BUSHING @76.90ft (above Mean Sea Level) Date From - To Hrs Task ' Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) 1 06:00 - 06:30 0.50 STWHIP P WEXIT I CREW CHANGE. DISCUSS OPERATIONS AND RIG STATUS. MAKE EQUIPMENT CHECKS AND OUTSIDE ;ROUNDS. CONTINUE TO MILL WINDOW. 06:30 - 12:00 5.50 STWHIP P WEXIT MILL AHEAD FROM 9306.5' 1950 PSI FS AT 1.49 BPM IN/OUT. 1.5 -2.0K# DHWOB IA/OA/PVT: 312 PSI / 262 PSI / 412 BBLS BHP /ECD/TVD: 4332 PSI / 9.52 PPG / 8865'. MILL AHEAD TO 9308.9' ESTIMATE WINDOW BTM IS 9308.9' !PERFORM KICK WHILE DRILLING DRILL WITH PARTED PIPE SCENARIO. i12:00 - 18:30 6.50 STWHIP P t WEXIT CONTINUE TO MILL IN OPENHOLE FROM I 1 9308.9' 1960 PSI FS AT 1.50 BPM IN/OUT. 2.5K# DHWOB. SAMPLE CONFIRMS PRESENCE OF FORMATION. MILL TO 9321' MD. OVERALL WINDOW ESTIMATED 9305.7' MD TO 9308.8' MD. 3.1' IS 2.1' SHORTER THAN I � TRAY LENGTH OF 5.2'. 18:30 - 20:30 II 2.00 j STWHIP P WEXIT ! BACKREAM AND REAM THROUGH WINDOW WITH PUMPS THREE TIMES. NO OVERPULL OR EXTRA DRAG RUNNING THROUGH WINDOW. DRY DRIFT WINDOW ONCE TO CONFIRM CLEAN WINDOW. PULL UP ABOVE WHIPSTOCK TO 9300' MD. OPEN EDC AND PERFORM FLOW CHECK. WELL STATIC. 20:30 - 22:30 2.00 STWHIP P WEXIT PULL OUT OF HOLE FROM 9300' MD TO BHA AT 109' MD. NO LOSSES TO FORMATION WHILE MILLING OR TRIPPING. MW IN = MW OUT = 8.6 PPG. PERFORM FLOW CHECK AT BHA. WELL STATIC. 22:30 - 23:30 1.00 STWHIP P WEXIT UNSTAB INJECTOR AND SETBACK. LAYDOWN MILLING BHA. BOTH MILLS IN GREAT CONDITION (2.74" GO, 2.73" NO -GO). 23:30 00:00 0.50 DRILL P PROD1 1CUT 106' 2 -3/8" COIL AND 5/16" E -LINE FOR CHROME MANAGEMENT. 5/20/2012 00:00 - 01:30 1.50 DRILL P PROD1 PREPARE COIL AND MAKEUP NEW BOT KENDLE CONNECTOR AFTER CUTTING COIL 01:30 - 02:00 0.50 BOPSUR P PROD1 STAB ON WELL WITH INJECTOR. PRESSURE TEST LUBRICATOR AND DFCVS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH ' (PASSING TESTS, SEE ATTACHED CHART). 02:00 - 03:00 1.00 , DRILL P PROD1 1 MAKEUP 3" DIRECTIONAL BUILD ASSEMBLY - 2.7" X 3" HYCALOG BI- CENTER SRF3408M -B7 BIT - 2 -3/8" COILTRAK TOOLS, NO RESISTIVITY - BHA OAL =58' 03:00 - 05:00 2.00 DRILL P 1 PROD1 RUN IN HOLE FROM BHA AT 58' MD TO TIE -IN ! ' DEPTH Printed 6/4/2012 11:22:39AM __.....______ _....._ ................_.__. S NOTES: CHROME TBG & 2 -318" TREE = CM/ WELLHEAD * MCEVOY - AC = BAKER C CHROME LNR * ** WELL ANGLE > 70° @ 9538'. KB. ELEV = 76.9Y BF. ELEV = 36.55' ;Al L 2012' H4 - 1/2" I-EES X NP, D= 3.813" KOP = 9276' Max Angle = 116° @ 10587' Datum MD = 9274' N M' 2922' H9 X 7" G-2 ZXP LTP, D =6.290" Datum ND = 8800' SS II 1" kli hil 2938' - 19 -5/8" X 7" FLEXLOCK LNR HGR, ID= 6.240" lit 11 GAS LIFT MANDRELS 111 11. - 13 -3/8" CSG, 72#, L-80 BTRS, ID = 12.347" _ 1 4) ® , MD 7VD i DEV TYPE VLV . LATCH I PORT, DATE ' 2683' 0 3804 `3803. 2 KGB -2, DMY BK 0 . 02/13/12 ' 0 17 • 6022 6020 r 1 KGB -2i DMY BK ' 0 02/13/12 ► 7824 `7673 r 34 KGB -2, DMY , BK r 0 06/30/09 Minimum ID = 1.78" ( 8400' MILLED OUT ALUMINUM $ I 7902' H 4- 112' HES XNP,D= 3.813" BUSHING IN DEPLOY SLEEVE j =' ='v M 1 7933' Hr X 4-1/2" BKR S-3 PKR, D= 3.870' 1 7" TIEBK LNR, 26#, L -80 BTC-M, .0383 bpf. ID = 6.276 ! 8141' B El " I I 8151' 1H7 -1/2" PORTED T1E -BK STEM w/ SEALS, ID =- 6.125" 9-5/8" X 7" ZXP LTP, D = 6.290" 8145' 8164' H 4 HES X NP, D = 3.813" I I9 -5/8' X 7' LNR I-IGR, D= 6.24' -1 8164' 8196• 1-14-1/2" 1NLEG, ID = 3.920" 4 -1/2' TBG, 12.6#, 13CR -80 VAM TOP, 8196' I 0152 bpf, D = 3.958" 8252' _I - X 41/2" XO = 3.958" 8254' - 3 4 -1/2" X3-1/2" X0 = 2.992" 7" CSG, 26#, L -80, BTC-M, D = 6.276" H 8252' I4 -1/2' TBG S1UB (06/18/09) 8321 I 8368' 1- � TNVSEAL ASSY W PBR I BEHIND �t Iii .:zl 8383' H9-5/8 X 41 /2 "TIW HBBP PKR, ID = 4.750' 1 CT LNR 8H88• IH " MILLOUT EXT, ID = 6.00' i ` I 8393' '• - i 7 -5/8" x 4-1/2" )00, ID = 3.956" ' A g 8391' - -2.70' DEPLOY SLV, ID = 2.250' . ALUMINUM BUSHING r 8400' MILLED OUT 3-1/2' TBG, 8.814, L -80 STL, 8416' ki% 84.06' - 12-318' )6) PUP JOINT, ID = 1.995" .0087 bpf, 13= 2.997 a $ 1 , 1 1 lig 101 iim ' 8416' ' - MILLED OUT ALUMINUM GUIDE ? I 10 SHOE, ID = 2.74" (05/03/12) Ili Pi i i 8 4 2 4 ' - I4 -1/2" OTIS X NIP, D= 3.813" BEHIND ITOPOF 7' LNR 1 8451' II Nil li ti CT LNR 91 4 -1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" t 8491' jii ii ∎ , 8443' -13.75" BKRDEPLOY SLV, D= 3.00" l 1118 II 8456' - 4 -1/2' OTIS X NIP, ID = 3.813" 9 -5/8" CSG. 47 #, L -80, D = 8.681" 8698' V I 1 a gel 8458' 1 :3 - 1 /2' HES )C NIP, ID = 2.750' BEHIND 3 - 1/2" LNR, 8.81 #, L - 80, .0081 bpf, D= 2.880" 9230' 10}11'1 IAA IliVi 7" WHPSTOCK w / RA TAG @ 9285 1 - 9276' ONO 8491' -41/2 WLEG, ID = 3.958" CT LNR 7" LNR, 26#, L -80, L$4S, .0383 bpf, ID = 6.276' 1-I -9279 t 9230' 3-1/2" X 3 116" XO, D = 2.800" WHIPSTOCK w/ RA TAG eg 9310 (05/18/12) - 9305' 3 -3/16" LNR, 6.24, L-80, .076 bpf, ID = 2.800" 9305 7" MILLOUT WINDOW (J -27A) 9279' - 9286' PERFORATION SUMMARY 1 3 -3/16' MILLOUT WINDOW (J -27B) 9305'- 9310' REF LOG: MCNU CCU GR ON 5/27/12 ANGLE AT TOP PERF: 91° Q 10550' Note: Refer to Production DB for historical pert data 1 SI SPF INTERVAL Opn /Sqz DATE 1.56' P. 6 10550 -11300 0 05/31/12 1 1.56" ' 6 11400 -11480 0 05/31/12 1.56" 6 11525 - 11550 0 05/31/12 1 2 -3/8" LNR, 4.6 #. 13CR -80 STL, .0039 bpf , ID = 1.995" 11632' K' 11594' 1 - 1 PBTD ( DATE REV 8Y COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/87 AUDI 2 ORIGINAL COMPLETION WELL: J-27B 11/16/02 JLM /KK CTD SIDETRACK (J -27A) PERMIT No: t120510 1 07/02/09 N4ES RWO API No: 50 -029- 21733-02 06/01/12 NORDIC 1 CTD SIDETRACK (J -276) SEC 9, T11 N, R13E, 800' FNL & 1771' FEL 1 06/10/12 PJC DRLG DRAFT CORRECTIONS ' 1 BP Exploration (Alaska) • • a z,:, Tr re\ + SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS! 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 a‘,0 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J -27A Sundry Number: 312 -126 Dear Mr. McMullen: E APR 1 c ZU12. Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this i3 day of April, 2012. Encl. • STATE OF ALASKA • `' vim 5z7/3 , ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ❑ Abandon ® Plug for Redrill • ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development • ❑ Exploratory 202 - 200 ' 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 21733 - 01 - 00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU J -27A . Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028281 - 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): 10574' ' 9038' ' 10541' 9035' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2683' 13 -3/8" 2683' 2683' 4930 2670 Intermediate 8699' 9 -5/8" 8699' 8399' 6870 4760 Production Liner 828' 7" 8451' - 9279' 8191' - 8881' 7240 5410 Liner 2131' 3 - 1/2" x 3 - 3/16" x 2 - 7/8" 8443' - 10574' 8185' - 9038' Scab Liner 5229' 7" 2922' - 8151' 2921' - 7944' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9830' - 10535' 9029' - 9035' 4 - 1/2 ", 12.6# x 3 - 1/2" 8.81# 13Cr - 80 / 8 8490' Packers and SSSV Type: 7" x 4 - 1/2" BKR S - packer, Packers and SSSV 793 , E l 9 -5/8" TIW HBBP packer MD (ft) and TVD (ft): 8383' M,k ?f1? 12. Attachments: 13. Well Class after proposed work: 0 Description Summary of Proposal BOP Sketch AN;k i fli4 I ❑ Detailed Operations Program ❑Exploratory 9pef►einf,i�. ;, 14. Estimated Date for 15. Well Status after proposed work: A f€ f'"- 'f.S'Ot) Commencing Operations: April 15, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG 0 Suspended . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jacob Leemhuis, 564 -4989 Printed Name Jo .. le f/ Title Engineering Team Leader Prepared By Name /Number: Signature / Phone 564 - 4711 Date 34/(z_ Joe Lastufka, 564-4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I J ` I Sundry Number: /Jl I (/0 ❑ Plug Integrity .rBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance . 35e0 , & &r I e.s t Other: • / C 2 0 . iS , 1 Subsequent Form Required: ( ._ e. O .� �( Approved By: COMMISSIONER THE COMMISSION Date l - /1- / Z 1 / P Form 10-403 Revised 0 / APPROVED BY 2010 S A R 16 1012 (4, t l _ /Z 42. ___ . ubmit In Duplicate ., \ • • To: Alaska Oil & Gas Conservation Commission From: Jacob Leemhuis by CTD Engineer Date: March 28, 2012 Re: J -27A Sundry Approval Sundry approval is requested for well J -27A. J -27A is a coil sidetrack completed in November 2002 in Zone 2A with 275' of perforations. While initial production was quite prolific, oil production declined rapidly in a couple of months. It remained a fulltime producer until early 2004 when it was shut -in for tubing and PC leaks. A RWO was completed in July 2009 and restored wellbore integrity with a scab liner and new 4 -1/2" tubing with a 3 -1/2" tubing tail over the old damaged tubing tail. After -8 days of work, service coil was able to push the RWO plug to -10,375' in the 2 -7/8" liner. In August 2009, an ASRC flowback test separator was used to flowback any debris and obtain a well test. J -27A came back online strong but the gas rate quickly rose and caused the well to cycle. In an attempt to shut -off gas production, the liner lap was tested in February 2011, but it passed. A STP with MCNL /Borax was logged in June 2011 and no gas shut -offs were identified. J -27A continues to cycle with degrading production. Reason for a Sidetrack: J -27A is no longer a competitive producer due to a high GOR, and there are no remaining wellwork options. The proposed plan for J -27B is to drill a through tubing sidetrack with the SLB /Nordic 1 Coiled Tubing Drilling rig on or around June 15, 2012. The existing perforations will be isolated by a 3- 3/16" Packer Whipstock as well as the primary cement job. The sidetrack, J -27B, will exit the existing 3- 3/16" liner and kick off in Zone 2C and land in Zone 1B. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. Am toui4 rk f f 1 ,4- e li it,11 Cethle ot- frojvc,>, Concar P K o fc-F) ,4 41(i- All 7 4e Zoo _ �D PQ f rs OR C ya- ys K of 4,r 6 1 �� / &he/at- 4 � - UK+/ /olden 04 14c wljrt 4 �-" , �4 r-- cc/44 4w,, f ''''T fi�O 7 or6 will f rip) w wn case s� ,� �e ma f ,. r' c t &l 74 wet/ hti v 0 C tlei7�1 5 R y ewes" (o�7 off � � � well ry a Axe ��c c 7- '�� l 1 ih� r r cq/td (eCov% (A1/2" • • Pre -Rig Work: (scheduled to begin April 15, 2012) 1. F MIT -IA to 3,000 psi; MIT -OA to 2,000 psi. 2. C Mill out XN- nipple & Aluminum guide shoe 3. S Dummy WS drift. 4. E Load & Kill. Set 3- 3/16" Packer Whipstock at 9,330'. Pressure test to 2.500 psi. 5. W Test: PPPOT -T. Torque LDS. 6. V PT MV, SV, WV. 7. 0 Blind and bleed lines, remove well house, level pad. 8. V Set TWC —24 hrs prior to rig arrival. A Rig Work: (scheduled to begin on June 15, 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.8" window at 9,330' and 10' of rathole. Swap the well to PowerPro. 3. Drill Build: 3" OH, 595' (218 deg /100 planned) 4. Drill Lateral: 3" OH, 2,000' (12 deg /100 planned) with resistivity 5. Run 2 -3/8" solid 13Cr -80 liner leaving TOL at 8,400'. 6. Pump primary cement leaving TOC at 8,400', 17.08 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL /GR /CCL log 8. Test liner lap to 2,000 psi. 9. Perforate liner per asset instructions ( -800') 10. Freeze protect well, RDMO Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Generic GLV's Jacob Leemhuis CTD Engineer 564 -4989 CC: Well File Sondra Stewman/Terrie Hubble . TREE= CIW • J -2 7 A WE N GLE > 70° @ 9484E TUBING & NIPPLES*** WELLHEAD = McEVOY ACTUATOR= BAKERC KB. ELEV = 76.93' 1 BF. ELEV = 36.55' I 2012' I- 14 -1/2" HES X NIP, ID = 3.813" KOP = 9276' Max Angle = 95° @ 10115' I 2922' H9 -5/8" X 7" C-2 ZXP LTP, ID = 6.290" I Datum MD = 9274' Datum TVD = 8800' SS ' i r 1 2938' H 9 -5/8" X 7" FLEXLOCK LNR HGR, ID = 6.240" I ■/ 1 1 GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80 BTRS, ID= 12.347" I-I 2683' I �� ,,, ST MD TVD DEV TYPE VLV LATCH PORT DATE , r 3 3804 3803 2 KGB -. DOME BK 16 07/09/09 �� 2 6022 6020 1 KGB -. SO BK 20 07/09/09 �� * , 1 824 673 34 KGB -. DMY BK 0 06/30/09 • Minimum ID = 2 "372 @ 9358 3- 3/16" X 2 -7/8" XO � ';: • 7902' H 4 -112" HES X NIP, ID = 3.813" I � / =' =11 7933' 1-17" X 4-1/2" BKR S -3 PKR, ID = 3.870" I j I)I 8145' H9 -5/8" X 7" ZXP LTP, ID = 6.290" I 1 i li 8164' H 9 -5/8" X 7" LNR HGR, ID = 6.24" I 8164' I-{ 4 -1 /2" HES X NIP, ID = 3.813" I 8196' I- I4 -1/2" WLEG, ID = 3.920" I ' I 8252' IH 7" X 4-1/2" XO = 3.958" 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, 8196' . 8254' I -j4 -1/2" X 3 -1/2" XO = 2.992" 1 I ' C111(522t, 3BIBB -'M, ID = 6.276" I 8252' ' 1 1 8368' I-ITIW SEAL ASSY IN PBR (BEHIND LNR) 1 = � i 8383' H 9 -5/8 TIW HBBP PKR, ID = 4.750" (BEHIND LNR) 8388' H 7" MILLOUT EXT, ID = 6.00" (BEHIND LNR) I 8393' I-{ 7 -5/8" x 4 -1/2" XO, ID = 3.956" (BEHIND LNR) I 3-1/2" TBG, 8.81 #, L -80 STL, --I 8416' 8416' 11 MILLED OUT ALUMINUM GUIDE .0087 bpf, ID = 2.992" ' . SHOE ID = 2.70" 1 8424' H 4 -1 12" OTIS X NIP, ID = 3.813" I I TOP OF 7" LNR I-I 8451' 8443' I-i 3.75" BKR DEPLOY SLV, ID = 3.00" I 1 1' 8456' H 4 -1/2" OTIS X NIP, ID = 3.813" (BEHIND CT LNR) I 4-1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" ( 8490' I 8458' -I3-1/2" HES XN NIP, ID = 2.750" I / 9-5/8" CSG, 47 #, L-80, ID = 8.681" 1-1 8698' 8490' I- I4 -1/2" WLEG (BEHIND CT LNR) I 1 3 -1/2" LNR, 8.81 #, L -80, .0081 bpf, ID = 2.880" I-I 9230' I TOP OF WHIPSTOCK H 9276' RA TAG I 9285' 9230' H 3-1 / 2 "x 3-3 / 16 " XO, ID = 2.800" I PERFORATION SUMMARY MILLOUT WINDOW 9279' - 9286' 1 REF LOG: MCNL /CCL /GR ON 11/15/02 ANGLE AT TOP PERF: 89° @ 9830' 9358' 1-13-3/16" X 2 -7/8" XO, ID = 2.372" I 0'444444 Note: Refer to Production DB for historical perf data •••••••••••• •4 SIZE SPF INTERVAL Opn /Sqz DATE j • j j • 04 `••♦ 2" 4 9830 - 9880 0 11/15/02 0 • • • ..• 4 . Ill 10541' -1 PBTD 1 2" r 4 10310 - 10535 0 11/15/02 ∎ � -� � � 3 -3/16" LNR, 6.2# 9358' I PBTD 1 9651' L -80, .076 bpf, 1 * / ID = 2.800" 1 7" LNR, 26 #, L -80, IJ4S, .0383 bpf, ID = 6.276" I-I 9697' kt•A•■•.*: 1 2 -7/8" LNR, 6.16 #, L -80, .0058 bpf, ID = 2.441" I-1 10574' DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT P. 06/87 AUDI 2 ORIGINAL COMPLETION 03/26/11 CJN/ PJC PULL IBP(03/15/11) WELL: J -27A 11/16/02 JLM /KK CTD SIDETRACK (J -27A) PERMIT No: ' 022000 07/02/09 N4ES RWO API No: 50- 029 - 21733 -01 08/25/09 DB /JMD DRLG DRAFT CORRECTIONS SEC 9, T11 N, R13E, 800' FNL & 1771' FEL 08/25/09 JA /JMD MILLED FASDRILL (08/19/09) 03/01/11 KJB /PJC SET IBP (02/21/11) BP Exploration (Alaska) ' JVELLHEAD.= McEVOY • SAF•NOTES: ""`CHROME TUBING & NIPPLES "` ACTUATOR = BAKER C J -2 7 B WELL ELL ANGLE > 70 (a7 9484' <Br ELEV = 76.93' proposed CTD sidetrack 9F. ELEV = 36.55' I ■ L 2012' 1 - 1/2" HES X NIP, ID = 3.813" KOP = 9276' Vlax Angle = 5° @10115' Datum MD = 9274' IV • 2922' ] X 7" C-2 ZXP LTP, ID = 6.290" Datum TVD = 8800' SS ki � � 2938' H9-5/8" X 7" FLEXLOCK LNR HGR. ID = 6.240" g ,vA ' CAS LIFT MANDRELS .. ' ® MD TVD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 72 #, L -80 BTRS, ID = 12.347" H 2683' T 3804 3803 2 KGB -2 DOME BK 1 07/0 9/09 �, F 6022 6020 1 KGB -2 SO BK r 20 07/09/09 �, 7824 673 34 KGB -2 DMY BK ` 0 06/30/09 • Minimum ID = 1.78" @ -8400' • 3" Deployment Sleeve �� E 7902' - 4- 1 /2 " HES X NIP, ID= 3.813" A� � � 011 7933' -- 7" X 4 -1/2" BKR S -3 PKR, ID = 3.870" 0 F 8145' --19 -5/8" X 7" ZXP LTP, ID = 6.290" 8164' -- 9 -5/8" X 7" LNR HGR, ID = 6.24" j 8164' I - I4 -1/2" HES X NIP, ID = 3.813" 8196' 14 -1/2" WLEG, ID= 3.920" e 8252' H7" X 4-1/2" XO = 3.958" 4 -1/2" TBG, 12.6#, 13CR -B0 VAM TOP, -1 8196' 8254' -14 -1/2" X 3 -1/2" XO = 2.992" .0152 bpf, ID = 3.958" I I 8368' -] TMV SEAL ASSY IN PBR (BEHIND LNR) 7" CSG, 26#, L -80, BTC-M, ID = 6.276" - 8252' ►�� OM 8383' -19 -5/8 TM/ HBBP PKR, ID = 4.750" (BEHIND LNR) 8388' -17" MILLOUT EXT, ID = 6.00" (BEHIND LNR) Top of 2 -3/8" chrome liner and cement at - 8,400' _. 34 0 8393' -17-5/8" x 4 -1/2" XO, ID = 3.956" (BEHIND LNR) 3-1/2" TBG, 8.81#, L -80 STL, H 8416' 8416' -I MILLED OUT ALUMINUM GUIDE .0087 bpf, ID = 2.992" 011 SHOE ID = 2.74" or 2.80" l 1 8424' -14-1/2" OTIS X NP, D= 3.813" TOP OF 7" LNR H 8451' u N 8443' -1 3.75" BKR DEPLOY SLV, ID = 3.00" 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID= 3.958" H 8490' II I 8456' - 14 - 1/2" OTIS X NIP, ID = 3.813" (BEHIND CT LNR) 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8698' I I 8458' H3 HES XN NIP, ID = 2.750" milled out? TOP OF WHIPSTOCK H 9276' RA TAG H 9285' 8490' - - 1/2" WLEG (BEHIND CT LNR) PERFORATION SUMMARY 1 3 -1 /2" LNR, 8.81 #, L -80, .0081 bpf, ID = 2.880" H 9230' REF LOG: MCNL /CCUGR ON 11/15/02 I 9230' H3 -1/2" X 3- 3/16" XO, ID = 2.800" ANGLE AT TOP PERF: 89° @ 9830' Note: Refer to Production DB for historical perf data MILLOUT WINDOW 9279' - 9286' SIZE SPF INTERVAL Opn /Sqz DATE 2" ■ 4 9830 - 9880 O 11/15/02 r� 9358' H3-3/16" X 2 -7/8" XO, ID = 2.372" I 2" " 4 10310 - 10535 O 11/15/02 1.4 3- 3/16" whipstock at 9,330' ■ FBTD H 9651' i 2 -7/8" CIBP (if needed) 17" LNR, 26#, L -80, IJ4S, .0383 bpf, ID = 6.276" H 9697' 46° 4%%* 10541' PBTD 2 -3/8" chrome liner with TD at 11,925' 3- 3/16" LNR, 6.2# H 9358' L -80, .076 bpf, B C ID = 2.800" 12 -7/8" LNR, 6.16#, L -80, .0058 bpf, ID = 2.441" - I 10574' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/87 AUDI 2 ORIGINAL COMPLETION 03/26/11 CJN/ PJC PULL IBP (03/15/11) 11/16/02 JLM /KK CTD SIDETRACK (J-27A) 03/05/12 WJH proposed CTD sidetrack FERMI No: '2022000 07/02/09 N4ES RWO API No: 50- 029 - 21733 -01 08/25/09 DB/JMD DRLG DRAFT CORRECTIONS SEC 9, T11 N, R13E, 800' FNL & 1771' FEL 08/25/09 JA /JMD MILLED FASDRILL (08/19/09) 03/01/11 KJB /PJC SET IBP (02/21/11) BP Exploration (Alaska) 1 NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM V12 V14 IIILL r 7- 1118" 6000 psi BOP'a ID = 7.08" V15 V11 ' IT vs Miesi,RXdH Transducers 0 I I I •OR Br 1 V V2 ■ V1 V — 4111 Nr — GASS, Note typical BOP arrangement gement for 2-318" ' # coiled tubing drilling a � 1 � 71/16 psi, R%J6 I ,II V17i IK HCR �� IC To Poor Boy Gas Buster 94 0 , � rrawassu v.- V18 V79 Mr. . �.. 2 1/16 psi , R% -24 • 3.00" 5000 Psi HCR I �� 11111.11111Pir 111C ■ ` * �� , 2- 1/18" 5000 Psi CHECK VALVE Manual Choke wet —® € ■— N _ . 7 1/16 Cameron FOV Gate I Valve x 5000 psi li MEOH /Diesel n . — P Line CoFlea Hose y - • t (.11 ' ' 114 Turn Halco 10WOG To Production Tree or Cross Over • II A ( T y CoFlea Hose CV11 0 0 Bleed Off —) Cement Line In Ground Level Tie -in f a. -I CV3 CV2 T Stand Pipe • Mk _ _ _ — — — Manual Choke e. nsn — — Pressure Transducers C1/9 FIIIIMIE — — — ( — ■ — CVt7 11 � - Mohan -- CV1 I I W W Tiger Tank Mud PUMP 2 O (I fr • ii _ In From ■ Baker MP 1 8 MP 2 9 ' — — ,.:.., Choke -- I • - • CV14 to Pits Rig Floor i Mud Pump 81 ill CV,6 Reverse CI . i . i _ ` \J CIr CT le ••• IM Ill MI • • To Manifold CV15 1 Jun - 2010 All Reveres Cin•ulatinn lino / CT while new CoFlea Hose .. • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1 When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code " IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 3/23/2012 20 2,• 200 13-JUL -2011 2. [ 2 l 2 Scghogerger No. 5764 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD W -223 BCRJ -00086 ISOLATION SCANNER 18- May -11 1 1 W -221 BJGT -00040 USIT 16-Jun-11 1 1 C -11A BLPO -00111 PPROF W GHOST 14-Jun-11 1 1 H -19B BLPO -00109 MEMORY PPROF W GHOST 12-Jun-11 1 1 V -227 BCRJ -00090 SCMT 19-Jun-11 1 1 X -22A AWJI -00143 USIT 18-Jun-11 1 1 MPI-09 BCRC -00067 MEMORY LEAK DETECTION LOG 18-Jun-11 1 1 • 14 -36 BCRJ 00091 (PROF 21- Jun -11 1 1 J -27A BAUJ-00090 PPROF W GHOST 20-Jun-11 1 1 D -06A BL65 -00041 PPROF W DEFT GHOST 24- Jun -11 1 1 16-05A BSM4-00008 LEAK DETECTION LOG 27-Jun-11 1 1 Z -27 BSM4-00009 GAS LIFT SURVEY 2-Jul-11 1 1 09 -22 BJGT -00048 (PROF 4-Jul-11 1 1 W -08A BBSK -00076 SCMT 25-Jun-11 1 1 Y -04 AWJI -00147 PPROF W DEFT GHOST 22-Jun-11 1 1 R -28 BJGT -00047 SBHPS 3-Jul-11 1 1 U -11B BG4H -00058 PPROF 16-Jun-11 1 1 Z-31 BCRJ -00093 SCMT 10Jul -11 1 1 F-48 BG4H -00062 PPROF W DEFT GHOST 9-Jul-11 1 1 06 -11 BSM4 -00012 PPROF W DEFT GHOST 4-Jul-11 1 1 C -32C BLPO -00117 PPROF W GHOST 5-Jul-11 1 1 01 -31 BP5G -00001 RST EDIT 17- Mar -11 1 1 N -17 BJOH-00007 PDC -GR EDIT 9- Feb -11 1 C -12B BAUJ -00064 MCNL EDIT 9- Mar -11 1 1 C -22A BL65 -00022 MCNL EDIT 7- Mar -11 1 1 14 -33A BL65-00023 MCNL EDIT 6- Apr -11 1 1 S -129 10AKA0109 OH PDC -GR EDIT 7- Nov -10 1 1 S- 129PB1 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 S- 129P82 10AKA0109 OH PDC-GR EDIT 7- Nov -10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. x - . - Anchorage, AK 99503 - 2838 ` • `7 MNED MAY 1 6 ZO1, Page 1 of 2' ~ ~ ~ Maunder, Thomas E (DOA) From: Stewman, Sond~a D [Sondra.Stewman@bp.com] Sent: Friday, September 04, 2009 3:45 PM To: Maunder, Thomas E (DOA) Subject: RE: J-27A (202-200) Attachments: J-27A Well History update 09-04-09.x1s Tom, Attached is update for Permit to Driii 202-200, Welt J-27A. Pfease advise if you require further information. v P8 v,~-E c~ ~~.~o ~~'~t o~ \ ~c..~v~ t~ ~~'~ b S Svr~r~4.~J Thank you, e l `~,-~'~ Sondra Stewman ADW Drilling Technologist I3~ ~~cr~, b~ ~~r°a>s~tzt aand ~~mc~st o~`~€t~ Xae I'O~s'7'L~~~~r , ~ _ ,~:s ...'' <° ' ~~;:` From: under, Thomas E (DOA) [mailto:tom.maunder@afaska.gov] Sent: Mon , August 17, 2009 10:03 AM To: Stewman, dra D Subject: RE: J-27 02-200) Hi Sondra, ! had a chance to read the rep and see #hat work is presen#ly ongoin , will plan to check back with yau next week to maybe finalize o he detail. Tom From: Maunder, Thomas E (DOA) Sent: Monday, August 17, 2009 9:36 AM To: 'Stewman, Sondra D' Subject: RE; J-27A (202-200) Thanks Sondra. This helps finish ou e work. 1 see the issue here. ports were cut off on 7/29 so you could file the 404. Sort of hard to avaid. Best re ds, Tom From: Stewma ndra D [mailto:Sondra.Stewman@bp.com] Sent: Mond , August 17, 2009 9:25 AM To: Ma er, Thomas E(DOA) Sub" : RE: J-27A (202-200) Morning Tom, 9/8/2009 STATE OF ALASKA " ALA OIL AND GAS CONSERVATION COM ION REP~T OF SUNDRY WELL OPE~IONS ~ V ~ V~ ~~~~ ~~~~ 2 9 20Qa 1. Operations Performed: ;'a:~~i ~~ i~J.i ~~~S COt15. ~Ot'f°ItTIlS3i ^ Abandon ~ Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Ent~rr~~~p~ied Well ~ Alter Casing ~ Pull Tubing _ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ PerForate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. _~ Development ^ Exploratory 202-200 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21733-01-00 ~ 7. KB Elevation (ft): 76 9, 9. Well Name and Number: PBU J-27A- 8. Property Designation: 10. Field / Pool(s): ADL 028281 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 10574' - feet true vertical 9038' _ feet Plugs (measured) N/A Effective depth: measured 10541' feet Junk (measured) --8421' true vertical 9035' feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2683' 13-3/8" 2683' 2683' 4930 2670 Intermediate Production 8699' 9-5/8" 8699' 8399' 6870 4760 Liner g2g' 7" 8451' - 9279' 8191' - 8881' 7240 5410 Liner 2131' 3-1/2" x 3-3/16" x 2-7/8" g443' - 10574' 8185' - 9038' Scab Liner 5229' 7" 2922' - 8151' 2921' - 7944' 7240 5410 Perforation Depth MD (ft): 9830' - 10535' Perforation Depth TVD (ft): 9029' - 9035' 4-1/2", 12.6# x 3-1/2" 8.81# 13Cr-80 / L-80 8490' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): ~~~ x 4-1/2" BKR S-3 packer, 7933', 9-5/8" TIW HBBP packer 8383' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 8299'. Cut and pull 9-5/8" casing from 1997'. Run 7(26#, L-80, BTC-M) scab liner. Cement w/ 161.2 bbls Class 'G' w/ Gas-Blok 905 cu ft/ 780 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 220 Subsequent to operation: 0 0 0 1400 200 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 309-172 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number. Si n ure - Phone 564-5743 Date(~, ~"z~ ~I Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 Submit Original Only ~ ~ ~~, ~~~~ ~ `{ zao~ ~~~ ~~.-~~'~~'~~~~ TREE _ ~ WELLHEAD= McEVOY F'~GTUATOR = BAKER C KB. ELEV - _ 76.93' BF. ELEV - 36.55' KOP = . 9276' Max Angle = 95° @ 10115' Datum MD = 9274' Datum ND = 8800' SS `'~ ~~ ~ ~ ~ ~Z ~A WEL~LE > 70° @ g0 4E TUBING & NIPPLES*"'` 2012~ 4-1l2" HES X NIP, ID = 3.813" 292~-i 9-5/8" X 7" G2 ZXP LTP, ID = 6.290" ~ 2938` 9-5/8" X 7" FLEXLOCK LNR HGR, ID = 6.240" GAS LIFf MANDRELS ~ 13-3/8" GSG, 72#, L-80 BTRS, ID = 12.347" ~ Minimum ID = 2.372" @ 9358' 3-3/16" X 2-7/8" XO 7" PORTED TIE BACK STEM 8141 ~ 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, ~ 8196~ 0152 bpf, ID = 3.958" 7" CSG, 26#, L-80, BTGM, ID = 6.276" ~-{ $252~ 3-1/2" TBG, 8.81#, L-80 STL, 8416~ .0087 bpf, ID = 2.992" 3-1/2" ALUM SHOE, ID = 2.992" 8416' 4-1/2" BKR LNR TOP PKR TOPOF 7" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 3-1/2" LNR, 8.81#, L-80, .0081 bpf, ID = 2.880" TOP OF WHfPSTOCK RA TAG PERFORATION SUMMARY REF LOG: MCNL/CCUGR ON 11/15/02 ANGLE AT TOP PERF: 89° @ 9830' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9830 - 9880 C 11/15/02 2" 4 10310 - 10535 G 11/15/02 PBTD -j 9651, 7" LNR, 26#, L-80, IJ4S, .0383 bpf, ID = 6.276" 9697' ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3804 3803 2 KGB- DOME BK 16 07/09/09 2 6022 6020 1 KGB- SO BK 20 07/09/09 1 7824 673 34 KGB- DMY BK 0 06/30/09 7902' 4-1/2" HES X NIP, ID = 3.813" 7933~ 7" X 4-1/2" BKR S-3 PKR, tD =&.290" 8145~ 9-5/8" X 7" ZXP LTP, ID = 6.290" 8164~ 9-5/8" X 7" LNR HGR, ID = 3.3~CJ" ? 8164~ 4-1/2" HES X NIP, ID = 3.813" 8196~ 4-1/2" WLEG, ID = 3.920" $252' 7" X 4-4/2" XO = 3.95&" 8254~ 4-1/2" X 3-1/2" XO = 2.992„ 8307~ BKR L SLIDING SLV, ID = 3.813" 8368~ - rTNV SEAL ASSF1vIBLY IN PBR 8383~ 9-5/8 TIW HBBP PKR, ID = 4.750" 8388~ 7" MILLOUT EXTENSION, ID = 6.00" 8393~ - {7-5/8" x 4-1/2" XO, ID = 3.956" 8420~ 4-1/2" HES FASDRILL ON TOP OF LNR (06/18/09)? 8424~ 4-1/2" OTIS X NIP, ID = 3.813" $443' 3.75" BKR DEPLOY SLV, ID = 3.00" 8456~ 4-1/2" OTIS X NIP, ID = 3.813" (BEHIND CT LNR) 8458~ 3-1/2" HES XN NIP, ID = 2.750" 8490~ 4-1/2" WLEG (BBi1ND CT LNR) 9230~ -~ 3-1 /2" X 3-3l16" XO, ID = 2.800" ~ ~ MILLOUT WINDOW 9279' - 9286' ~ \ 9358~ 3-3/16" X 2-7/8" XO, ID = 2.372" 10541' I-~ ~TD 3-3/16" LNR, 6.2# L-80, .076 bpf, ID = 2.800" 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" ~-1 10574' DATE REV BY COMMENTS DATE REV BY CAMMENTS O6/87 AUDI 2 ORIGINAL COMPLEfION 11/16/02 JLM/KK CTDSIDETRACK(J-27A) 07/02/09 N4ES RWO 07127/09 ?lJMD DRLG DRAFT CORREC710NS PRUDHOE BAY UNfT WELL: J-27A PERMff No: ~"2022000 API No: 50-029-21733-01 SEC 9, T11 N, R13E, 800' FNL & 1771' FEL BP Euploration (Alaska) . ~ ! ! J-27A Well History Date Summary 05/22/09 T/I/0=0/0/100 Temp=Sl CMIT TxIA PASSED to 1000 psi, MIT OA PASSED to 1000 psi (Pre- RWO) Pressured up T/IA to 1000 psi with 5 bbls of diesel for CMIT TxIA. T/IA lost 0/20 psi in the 1st 15 mins and 0/0 psi in the 2nd 15 mins for a total pressure loss of 0/20 psi in 30 mins. Bled TxIA. Pressured up OA to 1000 psi with 3 bbls of diesel for MITOA. OA lost 40 psi in the 1 st 15 mins and 20 psi in the 2nd 15 mins for a total pressure loss of 60 psi in 30 mins. Bled OA. FWHP's=150/50/i 00. Wing, Swab and SSV shut. Master open, IA and OA open to gauges. Tags hung and pad op notified. 05/26/09 RAN 3.0" x 5' D-DOWN BAILER.TAGGED @ 8367' SLM + 31' CORR = 8,398' MD / RECOVERED CEMENT. TAG ST# 3 WITH 1.40" LIB @ 6991' SLM + 31' CORRECTION = 7,022' MD U~ 1MP 2_3/4 BACS OF SLUGCITS FROM 8.~67' SLM TO 8 338' SLM CURRENTLY RIH W/ 2' 1-7/8" STEM & 3.70" CENT 05/27/09 DRIFT WITH 2' 1-7/8" STEM & 3.70 CENT TO TOP OF SLUGGITS @ 8,338' SLM + 31' CORR = 8.369' M D 05/29/09 FINAL T/I/0=400/125/100 CUT TUBING AT 8261' WITH 3.65" POWER CUTTER 06/02/09 T/I/0= 260/260/140 Temp= SI Circ Out, CMIT TxIA PASSED to 1000.,psi ---2nd att~m~ (Pre RWO). Pumped 10 bbl Neat Meth spear followed by 895 bbls 100*f Seawater down Tbg up IA taking returns down hardline loop over to J-17 flowline to LP. Pumped 140 bbl Diesel freeze protect down Tbg. U-tubed to IA. CMIT-TxIA : Pressured up TxIA with 2.6 bbls diesel. T/IA lost 0/0 psi in 30 min test. Was unable to bleed Tbg below 120 psi. 06/03/09 ~reeze orotected fl~wline of J-27 with 7 bbls meth 53 bbls crude qer WOA recpe. Flushed hardline jumper with 5 bbls diesel. Final WHPs 120/0/100 SV, SSV, WV= Shut MV,IA,OA= Open 06/04/09 T/I/O=SSV/0+/90. Temp=Sl. T& IA FL (pre RWO). No AL or flowline. IA FL C 60' (3 bbls). Grease crew called to open SSV. SV, SSV, WV=Closed. MV=Open. IA & OA= OTG. NOVP. 06/05/09 T/I/O = 120/0+/90. Temp = SI. T FL (pre RWO). No AL, ffowline or wellhouse. Hardline circ out rigged up from IA to J-27 tree cap. T FL @ 810' (19 bbls). SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 06/07/09 T10=120/vac/90. SI. Monitor WHPs (pre RWO). Hard line still rigged up. No change in TP or OAP, IA on vac. 06/08/09 T/IA/OA= 0/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T : Pressure bled through slotted bleed screw verified 0 psi. Removed 1" NPT plug, removed internal check, installed 1" Alemite. RU HP BT onto THA flushed void until clean returns achieved. Pressured void to 5000 psi for 30 min, 5000/ 15 mins, 4950/ 30 mins. Bleed THA void to 0 psi, cycle and torque LDS "Standard" all were in good working and visual condition. RD test equipment, re-installed Alemite cap. PPPOT-IC : Pressure bled through slotted bleed screw verified 0 psi. Removed 1" NPT plug, removed internal check, installed 1" Alemite. RU HP BT onto IC flushed void until clean returns achieved. Pressured to 3500 psi for 30 minutes, 3500/ 15 minutes, 3450/ 30 minutes. Bled off test pressure to 0 psi, cycle and torque LDS "Standard" all were in good working and visual condition. RD test equipment, re-installed Alemite cap. 06/08/09 T/I/0=120/0/90. Temp=Sl. Bleed WHPs to 0 psi (pre RWO). A/L disconnected. Flowline and Well house have been removed. OA FL near surface. Bled OAP from 90 psi to 0 psi (fluid & gas mix). Monitor for 30 mins no change in OAP. TBG FL @ surface. Bled TBGP from 120 psi to 10 psi mostly fluid (2 bbls returns). Unable to bleed below 10 psi. Monitor for 5 mins TBGP increased 110 psi. Final WHPs 120/0/0. SV=Closed MV=Open IA,OA=OTG NOVP Page 1 of 2 ~ ~ J-27A Well History Date Summary 06/10/09 T/I/0=110/0/0, Temp= SI. (Pre RWO) Bled Tbg to 10 psi, shut in bleed, pressure climbs back immediately. Pumped 5.3 bbls ambient diesel down Tbg to pressure up, T/1= 1000/830. Lost 10/0 psi in 15 minutes. U-tubed for 2 hours, T/I/0= 810/780/0. RD off of Tbg and RU to IA. ~~ Pump 0.8 bbls ambient diesel down IA to pressure up, T/1= 1080/1000. Lost 0/0 psi in 15 ~ minutes. Bleed back 2.7 bbls from IA, T/1= 80/0. Bled back 1.1 bbls from Tbg, T/1= 10/vac. U- tubed Tbg to IA. T/1=0/vac. PE & Pad-Op notified upon departure. SV & WV=Shut. SSV, MV, IA & OA=Open. FWHP's=0/vac/0. ~ 06/11/09 T/I/O = 0/0/0 Set 6-3/8" CIW "J" BPV# 415 thru tree,l-2'ext. used....pre-rig....no problems. ~ 07/09/09 T/I/O = 0/0/0 PULLEDD 4-1/8" CIW"H" BPV#254 THRU TREE 1-2' EXT, TAGGED @ 102" P~JLL B&R FROM RHC BODY C~ 8136' SLM PULLED SBK-2-DGLV FROM STA #2 (6007' ~~'c~`t~ SLM, 6021' MD) & BEK-DCK SHEAR VALVE FROM STA #1 (3790' SLM, 3804' MD) SET BK- LGLV IN STA #1 (3790' SLM, 3804' MD) & BK-OGLV IN STA #2 (6007' SLM, 6021' MD P) ULL 4-1/2" RHC PLUG BODY C 8141' SLM DRIFT W/ 2.80" LB TO_8397' SLM... LIB CAME BACK ~...~.~_.:~.~. ~.~ a~.t.,_~. TAPPERED AROUND OUTSIDE) DRIFT W/ 2.63" CENT TO 8397' SLM 07/14/09 T/I/O = 1500/1630/580. Temp = SI. TBG & IA FLs (PO request}. TBG FL @ 6021' (sta #2, s/o)(92 bbls). IA FL @ 6100' (below sta#2)(327 bbls). SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. 07/28/09 CTU #6. Mill Shoe/Fasdrill; MIRU CTU #6. MU and RIH with WFD 2 3/8" motor w/ 2.70" 5-blade bullnose junk mill. Drv taq 3 1/2" auide shoe at 8436' ctmd. Milled through guide shoe and made several passes. RIH dry. Weight bobbled at 8457' ctmd. Dry tagged down with mi!! at 8465' ctmd. PUH dry and saw slight overpull coming back through guide shoe. POOH to pick up venturi junk basket. RIH with 2.60" venturi lunk basket. Dry tag down at 8478' ctmd. Venturi on top of liner making hole down to 8484' ctmd. At surface venturi packed full had some pieces rubber and fines. Had to take venturi to shop to clean out. MU venturi stab onto well. 07/29/09 CTU #6 1.75" CT ( Interact Publishing ) Job Scope: Mill *''** Continued from 7/28/09 "'*'* RIH w/2.60" venturi junk basket again added 6' of venturi barrel. Venturi screen packed off with rubber pieces and fines. Had some aluminum shavings and composite pieces in the fingers. RBIH with venturi. Page 2 of 2 i ~ J-27A Well History Date Summary 07/30/09 CTU #6, 1.75" CT ( Interact Publishing ) Job Scope: Mill ; Continued from WSR 7/29/09 ... PqOH with HSD parabolic mill. At surface check mill, looked like it was working on the outside cutters not much on the face. MU 2.20" JSN. RIH to swap fluid over for video._Pump two gel sweeps off bottom and circulate bottoms up while changing wellbore over to clear water for future video log. Fill pipe voidage with 50/50 methanol down backside while POOH. Inspected pipe at 4973' ctmd and found wall thickness below minimums. Continue POOH. Inspected pipe at 4068' ctmd and found wall thickness below minimums. Continue POOH. At surface. Pipe will have to be spliced or junked. Prep and blow down coil with N2. RD CTU._ Note: CT depths reached (+/- 8474') were significantly deeper, beyond normal error, than the depth of the 41/2" liner top packer originally at 8431' md. 08/04/09 INITIAL T/I/0=500/975/0 PSI. WING CLOSED, MASTER/SSV OPEN, VALVES OTG ASSIST EXPRO WITH VIDEO LOG. LOGGED JEWELRY PASS WITH SLB CCL BEFORE POOH. FINAL T/I/O = 500/975/0 PSI. 08/13/09 CTU #5 w/1.75" OD CT. Job scone - MORU CT/Mill obstruction. «< InterACT publishing »> MORU. MU & RIH w/ 2.13" OD Baker IntemaUdimple CTC, DFCV/Bowen dual acting hyd jar/Hi- load Hyd Disc w/5/8" ball seat set f/3300 psi, DACV w/.5" ball seat pinned f/2700 psi w/5k RD, Baker Extreme motor, 2.30" od Venturi junk basket w/burning shoe. 08/14/09 CTU #5 w/1.75" OD CT. Job scope - Mill junk in liner. «< InterACT publishing »> Job continued from WSR 08/13/2009. RIH w/Baker 2.30" OD venturi and burning shoe assy. Tagged junk @ 8481'. Auto drilled down to 8487.9'. Stalled motor, had to jar free. Pulted up and ~ est free spin. Auto drillled back down and stalled on first contact with junk. Had to jar free. POOH to check venturi basket and bum shoe for any damage or wear pattems. LD 2.3" OD burn shoe, marks on outside of shoe only. Junk basket full of fine metal and composite shavings and pieces. MU and RIH with BHA #2 with 2.625" venturi and 2.70" burn shoe. Tag and burn over junk at 8489'. Had three stalls while buming over before pulling out of hole. Venturi full of fine metal shavings. MU and RIH with BHA #3 with 2.625" venturi and 2.70" burn shoe. Found bad spot on coil Cc~ 5133'. Determine pipe wall thickness to be 0.106" to 0.112", below minimums. POOH. Freeze protected well to 2500' w/50/50 Meth water. Blow down reel w/N2. RDMO CT. Take unit to Deadhorse shoq to cut out bad spot and butt weld coil. 08/16/09 CTU #5 w/1.75" OD CT. MORU CT/Mill junk. «< InterACT Publishing »> Continued from WSR 08-14-2009. Coil repair finished. MORU CT. Pig and drift coil w/1.25" steel ball. BOPE test. MU a~d RIH with Baker 2.70" OD Bum shoe/venturi assembly. Tag obstruction at 8487' ctmd. Stal12 times, mill ahead slowlv to 8500'. POOH. Venturi basket was mostlv full with finE medi~m nieces of inetal,~nosite_ and brass Run back in hole with the same BHA for c~-~ac` additional venturi cleanout. Taa and mill obstruction startinq at 8500' ctmd. Milled down to 8~9', lost motor work. POOH. Bum shoe has what appears to be ~~St iror, ~=~cnod.i~s.tle.a^~+ i protruding out of the shoe. Can't tell wher shoe ends and cast iron piece starts. Venturi full of san , metal shavings, pieces of hard material, cast iron or rock. MU 2.635" OD Bum Shoe. 08/17/09 CTU #5 w/1.75" OD CT. Job scope - Mill junk. «< InterACR publishing »> Continued from WSR 8-16-2009. RIH w/2.625" OD Burn Shoe assy. Mill down to 8514.6'. Started taking wt and loosing motor work. POOH. Burn Shoe was worn badly and plugged off w/unknown material. Page 1 of ~. ~ i J-27A Well History Date Summary 08/18/09 Auto drill down to 9338.9'. Stalled and lost circulation. Pulled 19k Ibs overpull to fire jars but got no jar action. Slacked off and got 1 jar lick down but could not get any up jar action. Managed to work tools up hole to 9315'. Can't get any jar action. Still have fluid movement down coil at 1.3 bpm at 2800 psi. Drop 1/2" ball and open cire sub. Not getting any returns to surface. Surge pumps, pressure up on coil and dump pressure to achieve a hammering effect - unsuccessful. Drop 5/8" ball to disconnect. POOH. Confirm tools disconnected. 5/8" steel ball recovered. Tools remaining in hole: 2.13" x 0.9' Disconn (partial disconnect with 2" GS fishing neck looking up) , 2.13" x 1.01' Circ Sub, 2.13" x 8.17', 2.30" x 1.10' 3 bladed junk mill. OAL of tools remaining in hole = 11.18'. Maximum OD of tools left is 2.30" at the mill. MU and RIH with 2 5/8" Venturi with full mule shoe to clean up top of fish. Washed down to 9843.8', tagged fish. Washed off top of fish. Washed all jewerly on the way out. LD Venturi assy. 08/19/09 LD 2.625" OD Venturi tool assy. Venturi was empty. PU GS spear tool string. RIH. Tagged fish at 9410', set down 6k Ibs. Circulated on top of fish and got a good tatch. Hung up at 9364', worked tools through tight spot. POOH. No fish at surface. RIH w/ GS stop @ 9350 pump 10 bbl gel sweep and circ to surface. RIH to 9463' stack 8k down. Puh no overpull. Rih to top of fish. Pumped 1 bbl, rih sat 10k down on top of fish, PUH had 11 k over pull, jarred finrice. PU to 34k lost tool string weight back to 24k, 1.Ok over stnng weight. OOH to check for fish. Recovered fish. Break off tools. 08/20/09 PU Baker Venturi and 2. 0" bu~n over shoe. PT surFace lines. Open swab valve. Pum ed 20 bbls down backside, well pressured up to 1000 psig @ 1.0 bpm. Shut down pump, RIH w/ 2.13" venturi basket.Dry tag @ 9537' worked down to 10345, could not pass thru..stalled motor. pooh. Venturi basket full of milling and mud. The burn shoe was worn with cut-rite worn off.RIH w/ motor and 2.3" 3 blade junk mill. i not see any wt loss @ 10345. Continued to 10375'. stall motor several times and pump several gell sweeps attempting to pass 10375'. on last stall had to pull up to 35k to pull free.Pooh. At surface. MU Venturi basket with 2.3" burn over shoe. RIH. Made several tags w/ over pulls while working down hole with motor'"~* Continued on WSR 08- 20-09 08/21/09 Continue rih with Venturi basket with 2.3" burn shoe. Stalled motor @ 10375'. Work Venturi basket w/burn shoe. Stalled motor @ 10380' ctm. 5' deeper. No progress. Pooh. At surFace break down tool string. Found 3 Ibs metal shavings with pieces of cast iron. Burn shoe plugged. MU same tools with different burn over shoe same OD. RIH tag up @ 10382' worked tools up/down whlie pump sweeps and made it to 10384'. pooh. While pooh applyed poor-boy gas down IA and let well flow to open top. Well unloaded 50 bbls fluid then turn to solid gas, had to shut in due to wind direction blowing toward spine road.RlH w/ motor and 2.27" parabolic mill. 10,375' motor stalled.worked up/down several times with no jar action. Continued untill jars hit and pulled free. attempted one more time and would hang at various places. Decison made to pooh. FP down to 2500'. At surface. RD coil. 08/26/09 ASRC Test Unit #3 MIRU, Begin flow back well test. ~zS~o~~ v c~ (~~ 'CrccSi~v~ ~ ~~-l" ~ \ ~ P ~-~.''~'~ ~ ~ BP E} Operations Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date From - To Haurs Task Code NPT 6/12/2009 22:00 - 00:00 2.00 MOB P 6/13/2009 00:00 - 04:00 4.00 MOB P 04:00 - 06:00 2.00 MOB P 06:00 - 07:00 1.00 RIGU P 07:00 - 09:00 2.00 RIGU P 09:00 - 10:30 1.50 RIGU P 10:30 - 12:30 2.00 RIGU P 12:30 - 13:00 0.50 KILL P 13:00 - 17:00 4.00 KILL P 17:00 - 18:00 I 1.001 WHSUR I P 18:00 - 18:30 0.50 WHSUR P 18:30 - 20:00 I 1.501 WHSUR P 20:00 - 22:00 2.00 BOPSU P 22:00 - 23:00 1.00 BOPSU P 23:00 - 00:00 1.00 BOPSU P 6/14/2009 ~ 00:00 - 06:00 ; 6,00 ~ BOPSUF{ P 06:00 - 07:00 1.00 BOPSUF~ P I 07:00 - 12:00 5.00 BOPSUd P Spud Date: 6/14/1987 Start: 6/10/2009 End: I Rig Release: 7/2/2009 Rig Number: Phase Description of Operations PRE Scope down upper derrick section and lower onto sub. Unhook lines. PRE Move rig off of well D-13, down D-pad access road to Spine, Left onto Spine road to J-Pad Access. Rig move from D-pad to J-Pad was 5 miles. PRE Remove scaffold from J-27a, Lay herculite around well, spot mats. Spot tree and wellhead equipment behind well. Spot Sub over J-27a. PRE Crew change. Continue with rig up. Spot Pipe shed. Level up Rig. PRE Raise and scope up Derrick. Make-up lines to Pits. Off-load first load of hot Sea Water in Pits. Accept Rig at 09:00 hrs. PRE Pick up lubricator and ~ressure test to 500 psi. Pull BPV. Lay down same. TP = 0 psi. PRE Continue to fill Pits with hot Sea Water. Rig up lines to the Tree and the annulus. DECOMP PJSM with All. Discuss Well Kill Ops. DECOMP Pressure test line at 3,500 psi. Circulate Well with hot Sea Water. Initial rate at 3.0 bpm/800 psi. Final rate = 4.5 bpm/1400 psi. 7otal volmune pumped 590 bbls. Monitor Well dead. DECOMP Install Cameron Type J TWC with Cameron welihead tech. Test from below to 1,000 psi and above to 3,500 psi for 10 charted minutes each. DECOMP Crew change, service rig, derrick inspection, Set and test PVT's DECOMP N/D Tree and adaptor flange and remove from cellar. Inspect hanger threads, threads are in good condition, 6-1/2 turns on the IJ4S XO. DECOMP N/U BOP stack, choke and kill lines. Hook up turnbuckles and center stack. Install flow riser. DECOMP M/U BOP test assemblies and fill BOPE with water and purge air from system. DECOMP Perform Initial BOP Test Test Blinds, Choke Manifold, Manual Kill and Choke Valves, HCR Kill and Choke Valves, Floor Valves, 3-1/2" x 6" VBR's with 3-1/2" and 5-1/2" Test Joints, Hydril Annular Preventer with 3-1/2" Test Joint, Kelly Valves, Test Spool Valves. Perform Koomey Draw down test. AOGCC witness of test was waived by Bob Noble, test was witn2ssed by the Nabors Toolpusher and the BP WSL DECOMP Perform Initial BOP Test, Test Blinds, Choke Manifold, Manual Kill and Choke Valves, HCR Kill and Choke Valves, Floor Valves, 3-1/2" x 6" VBR's with 3-1/2" and 5-1/2" Test Joints, Hydril Annular Preventer with 3-1/2" Test Joint, Kelly Valves, Test Spool Valves. Perform Koomey Draw down test. AOGCC witness of test was waived by Bob Noble, test was witnessed by the Nabors Toolpusher and the BP WSL. Fluid was leaking by 5-1/2" Test joint, Test joint was found to be 1/8" out of round in sealing area. Locate another 5-1/2" Test joint and order out. DECOMP Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. Off-load 5 1/2" Test Joint. DECOMP Attem t to re-test VBPRs with different 5 1/2" Test Joint, several times. No-Joy. Change out VBPRs. (Two mechanical Printed: 7/16/2009 4:48:34 PM • ~ BP EXRLQRATlQN ~peC1t10t1S ~r~rnmaru Ra~nnrt Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES 16/14/2009 107:00 - 12:00 I 5.001 BOPSUp P 12:00 - 14:00 I 2.001 BOPSUp P 14:00 - 15:00 1.00 PULL P 15:00 - 16:00 1.00 PULL P 16:00 - 18:00 2.00 PULL P 18:00 - 18:30 0.50 PULL P 18:30 - 19:00 0.50 PULL P 19:00 - 22:30 3.50 PULL P 22:30 - 23:00 0.50 PULL P 23:00 - 00:00 1.00 PULL P Spud Date: 6/14/1987 Start: 6/10/2009 End: I Rig Release: 7/2/2009 Rig Number: Phase Descripti4n of Op~rations DECOMP barriers in place...Fas-Drill Pluq at 8,410' and the TWCV in the Tubing Hanger) Re-test VBPRs with the 3 1/2" and 5 1/2" Test Joints at 250/3500 psi. Good test. Record on chart. Rig down test equipment. DECOMP Pick-u Lubricator and test to 500 si. Pull TWCV. Lay down same. Secure Well. DECOMP Hold weekly Safety meeting with Crew, Tool Pusher, and WSL. DECOMP BOLDS. Pull Tubinq Hanger to floor with no problems. Hanger broke free with 140K. PUlled to floor at 125K. DECOMP L/D Hanger, R/U and circulate bottoms up at 5 bpm at 250 psi. DECOMP Crew change, rig service, derrick inspection, set and test PVT's DECOMP R/U Camco control line spooler. DECOMP POOH la in down 5-1/2" 17# L-8 - with dual 1/4" encapsulated control Iline. Moderate to heavy corrosion and pitting on inside of tubing, encapsulation on control line was intact. Recovered 52 joints of 5-1/2" tubing, SSSV assembly with 5-1/2" x 4-1/2" XO, 26 control line clamps and 4 stainless steel bands. DECOMP R/D Control line spooler and remove from rig floor. DECOMP POOH lavinp down 4-1/2". 12.6#. L-80. BTC-M tubinca. 6/15/2009 100:00 - 04:30 I 4.501 PULL I P 04:30 - 05:30 I 1.001 PULL I P 05:30 - 06:00 0.50 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 07:30 1.00 PULL P 07:30 - 08:00 0.50 PULL P 08:00 - 09:00 1.00 PULL P 09:00 - 11:30 2.50 CLEAN P 11:30 - 18:00 I 6.50 I CLEAN I P 18:00 - 18:30 0.50 CLEAN P 18:30 - 21:00 2.50 CLEAN P 2L00 - 22:30 I 1.501 CLEAN I P 22:30 - 23:30 I 1.001 CLEAN I P 23:30 - 00:00 0.50 CLEAN P 6/16/2009 00:00 - 02:30 2.50 CLEAN P DECOMP POOH laying down 4-1/2", 12.6#, L-80, BTC-M tubing. Moderate to heavy corrosion and pitting inside tubing. Recovered 149 joints + 3.10' cut joint. Good cut on tubing. DECOMP Hold weekly safety meeting with crew. Discussed BP and Nabors Safety Stats, Stop program review and quiz. DECOMP R/D tubing handling equipment. Clear and clean rig floor. DECOMP Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. DECOMP Rig up to handle 3 1/2" Drill Pipe. Bring Tools for BHA to Pipe Shed. DECOMP Install Wear Bushing. DECOMP Clean floor DECOMP Bring BHA to floor. Make-up BHA #1 as follows: 8 1/2" x 4 9/16" Dress Shoe, WP EXT, WP E~, WP Ext, WP Boot -- -_ _.___..__ _ Basket, 7" x 3 7/8" Dress-Off Mill (inside Washpipe), XO, 9 5/8" Casing Scraper, Bit Sub, Bumper Sub, 9 ea 4 3/4" Drill collars, Pump-Out-Sub. DECOMP Trip in with BHA #1 and single 3 1/2" Drill Pipe from Pipe Shed. DECOMP Crew change, service rig, derrick inspection, set and test PVT's DECOMP Trip in with BHA #1 and single 3 1/2" Drill Pipe from Pipe Shed. DECOMP P/U Kelly and establish parameters, P/U 138K, S/O 122K, Rot Wt 130K, 60 rpm with 3,000 Wlbs of torque, 4 bpm with 630 psi. Mill on cement stringers, WOM 5-7K, 70 rpm with 4,000 -7,000 ft/Ibs of torque. Hard drilling then drill off quickly from 1' to 20' hr. Clean out to 8,241' Shoe depth. DECOMP R/U and reverse circulate at 4-1/2" bpm with 1,070 psi. Saw cement at bottoms up. DECOMP P/U Kell and drill cement from 8 241' shoe de th. DECOMP Drill u cement, to 8,260' shoe depth, milled top of stub from 8 2 1' ' 5 rpm with 4,000 -,00 s o torque, Printed: 7/16/2009 4:48:34 PM ~ ~ BP E -r---------- ------°---~ ---r--- Legal Well Name: J-27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/2/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Operations 6/16/2009 00:00 - 02:30 2.50 CLEAN P DECOMP WOM 5- 10K, 4-1/2 bpm with 750 psi. 02:30 - 04:30 2.00 CLEAN P DECOMP Circulate a 35 bbl Hi-Vis sweep around 5-1/2 bpm with 1,100 psi. 04:30 - 06:00 1.50 CLEAN P DECOMP POOH with BHA #1, standing back 3-1/2" drill pipe in derrick. 06:00 - 07:00 1.00 CLEAN P DECOMP Crew change. Rig service. Inspect Derrick. Check PVT Alarms. ' 07:00 - 09:30 2.50 CLEAN P DECOMP Finish tripping out with 3 1/2" Drill Pipe and BHA #1. 09:30 - 11:30 2.00 CLEAN P DECOMP La~down BHA #1 and manqled 4 1/2" tubing that was jammed up inside the Wash pipe. Recovered -17 ft of tubinq and several smaller pieces. 11:30 - 15:30 4.00 FISH N DPRB DECOMP Forward pictures to Anchorage. Discuss options and plan forward with Anchorage Engineering. Order out next BHA. Clean Rig Floor. 15:30 - 18:00 2.50 FISH N DPRB DECOMP Off-Load Next BHA and load in Pipe Shed. Tally, P/U & M/U BHA #2 as follows: 8 1/2 x 6 3/4" Shoe, 2 jts W/O pipe, W/O Boot Basket, XO, Bumper Sub, Jars, PxP Sub, Float Sub, 9- 4 3/4" DCs, Pump Out Sub. TL = 372.18' 18:00 - 18:30 0.50 FISH N DPRB DECOMP Crew change. Service rig, Inspect derrick, Check PVT alarms. 18:30 - 21:00 2.50 FISH N DPRB DECOMP RIH w/ BHA #2 on 84 stands of 3 1/2" DP. _._ _- 21:00 - 00:00 3.00 FISH N DPRB DECOMP P/U single jt of DP & kelly. Tag up on fish C~ 8261' Establish milling parameters & be ing milling & washinq over fish. ist one foot took 1 hour, then rated incresed due to washing thru cement. Made 10' to 8271' P/U Wt = 145K, S/O Wt = 120K, Rot Wt = 129K. 3 BPM ~ 540 psi. Free Torq = 3K ft- Ibs. 68 RPMs. WOB 3-5K. 6/17/2009 00:00 - 05:00 5.00 FISH N DPRB DECOMP Continue millin on fish. Made 28' to 8299'; P/U Wt = 145K, S/O Wt = 120K, Rot Wt = 129K. 3 BPM C~? 540 PSI. Free Torq = 3K ft-Ibs. 68 RPM. WOB 3-10K. 05:00 - 0&:30 1.50 FISH N DPRB DECOMP Pump a 35-bbl Hi-Vis Sweep ~ 6.0 BPM/1200 PSI. Crew change. 06:30 - 07:00 0.50 FISH N DPRB DECOMP Service Rig. Inspect Derrick. Check PVT Alarms. 07:00 - 11:00 4.00 FISH N DPRB DECOMP Set back kelly. Trip out with 3-1/2" DP. 11:00 - 12:00 1.00 FISH N DPRB DECOMP Lay down BHA #2. Recovered several ~ieces of tubinq_that rode out on top of BHA. Boot Basket was full of cement and metal cuttin s. Top Joint of Washpipe was slightly bent. Both Joints of Washpipe were heavely grooved.. Nothinq inside of the Wash i e. Mill worn. 12:00 - 13:15 1.25 FISH N DPRB DECOMP Discuss options with Anchorage Engineering. Develope plan forward. 13:15 - 16:00 2.75 FISH N DPRB DECOMP M - ' ut ide Cutter, 1 Joint of Wash Pipe, Washover Boot Basket, XO sub, 9 ea 4 3/4" Drill Collars. Total lenght = 319.09-ft. 16:00 - 18:00 2.00 FISH N DPRB DECOMP RIH w/ BHA #3 on stands of 3 1/2" DP to perform outside cut. In hole w/ 34 stands. 18:00 - 18:30 0.50 FISH N DPRB DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 21:00 2.50 FISH N DPRB DECOMP Con't to RIH w/ BHA #3 to outside cut tubina. RIH slowly (no float in string) to prevent DP overflow while RIH. Notified town engineer of plan to cut tubing (~ +/- 8287' 4es DPM. RIH w/ 84 stands. 21:00 - 23:00 2.00 FISH N DPRB DECOMP P/U kelly & obtain P/U wt = 142K, S/O wt = 120K, Rot Wt = 130K. Free torque = 3.2K ft -Ibs. P/U 3 singles + 10' pup + 5' pup. Slowly go down over tbq stub to 21' in on kelly for space out.. Total depth = 8292.37'. Cutter C~3 8287', 4 es DPM. Begin Printed: 7/16/2009 4:48:34 PM ~ . Qperations Summary Report Legal Well Name: J-27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/2/2009 Rig Name: NABORS 4ES Rig Number: Date From - TQ Hours Task Code NPT Phase Descrip#ion c~f Operation~ 6/17/2009 21:00 - 23:00 2.00 FISH N DPRB DECOMP rotation w/ 30 rpms, P/U & rotate w/ 3" increments & rotate uo hole for a total of 10' to 8277'. Occasionally saw very small amount of torque rotating. 23:00 - 00:00 1.00 FISH N DPRB DECOMP Hold PJSM. Set back kelly & UD 5& 10' pups. 6/18l2Q09 00:00 - 03:00 3.00 FISH N DPRB DECOMP POH from 8 301' with fish. 03:00 - 04:00 1.00 FISH N DPRB DECOMP LD BHA #3. 04:00 - 05:00 i.00 FISH N DPRB DECOMP Ins ect fish. Fish consisted of last 13.38' of jet-cut joint, 10.36' top pup joint, 3.61' sliding sleeve, and 10.41' bottom pup joint. Started discussion with fishermen and WSLs about plan forward. 05:00 - 06:00 1.00 FISH N DPRB DECOMP Clear and clean rig floor. LD remainder of BHA. Call town engineers to discuss plan forward. I 06:00 - 11:00 5.00 FISH N DPRB DECOMP Wait on town engineers to make decision for plan forward. 11:00 - 15:30 4.50 FISH N DPRB DECOMP PU BHA #4, which consists of the following: 3-518" convex mill, I 2-3/8" reg x 2-7/8" PAC bit sub, eight joints of 2-7/8" PAC drill ~ collars, 3-112" iF x 2-718" PAC XO sub, 4-3l4" Lub. bumper sub, 3 stands 4-3/4" drill collars, and 3-1/2" pump-out sub. ~ R1H. 15:30 - 17:00 1.50 FISH N DPRB DECOMP Stop above 4 1/2" Stump. Cut and Slip Drilling Line. 17:00 - 18:00 1.00 FISH N DPRB DECOMP Continue RIH with 3-5/8" convex mill on 3-1/2" DP to to of stub at 8,301'. Tag up with stub and work over and into stub. 18:00 - 18:30 0.50 FISH N DPRB DECOMP rew change. ervice rig. Check PVT alarms, Inspect derrick. 18:30 - 20:30 2.00 FISH N DPRB DECOMP P/U kelly, establish clean out parameters & break circulation. 3 BPM ~ 600 psi. Run in tubinq to 8304' & took some weiaht. Wash & rotate from 8304' to 8375'. Increased circ rate to 4.1 BPM C~ 1100 psi. Appear to have some iunk/trach ah .aa d nf mill. P/U from 8375' & prep to circ. P/U Wt = 139K, SIO Wt = 120K, Rot Wt = 129K. Free Torq 150 amps/2900 ft-Ibs. 30-40 RPMs. 20:30 - 23:30 3.00 FISH N DPRB DECOMP Pump 40 bbls Hi-Vis sweep & displace well w/ clean seawater. Pump 5.3 BPM C~ 1800 psi. Pumped total of 575 bbls. 23:30 - 00:00 0.50 FISH N DPRB DECOMP Wash & rotate from 8375' to 8386', where we taqqed up on the Fas-Drill lu . P/U Wt = 139K, S/O Wt = 120K, Rot Wt = 129K. Free Torq 150 ampsl2900 ft-Ibs. 30-40 RPMs. 4.5 BPM ~ 540 PSI. WOB 2-5K. 6/19/2009 00:00 - 01:00 1.00 FISH N DPRB DECOMP Milled Fas-Drill alua trom 8386' to 8387'. where the w~U started 1:00 - 02:00 .00 ISH N PRB ECOMP 8420' on the coil liner tOp. Dry drilled for 15 minutes. P/U Wt = 139K, S/O Wt = 120K, Rot Wt = 129K. Free Torq 150 amps/2900 ft-Ibs. 30-40 RPMs. 4.5 BPM ~ 540 PSI. WOB 2-5K. Set Ke~ back and started out of the tubinca/hole from 8420' #o 8375', where the pipe started stickin . 02:00 - 02:30 0.50 FISH N DPRB DECOMP Pi e stuck. Kelly'ed back up and worked pipe free. Pulled 4 jts out of the hole to get the BHA free of the 4-1/2" tubing stub. POH from 8375' to 8255'. 02:30 - 06:00 3.50 FISH N DPRB DECOMP PJSM for POH and stand back DP. POH from 8255' to 537', standing back 3-112" DP. Continuous hole fiif with a 12 bblsJhr ~ loss. 06:00 - 06:30 0.50 FISH N DPRB DECOMP Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 07:30 1.00 FISH N DPRB DECOMP Finish Tripping out with 3 1/2" Drill Pipe. Set back Drill Collars. Printed: 7/16/2009 4:48:34 PM ~ • BP EXPLORATION Page 5€~f i s Operations Summary Report Legal Well Name: J-27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/2/2009 Rig Name: NABORS 4ES Rig Number: i ~ i i i i i; 6/19/2009 07:30 - 08:30 1.00 FISH N DPRB DECOMP Lay down BHA #4. Inspect MIII and observe expected normal wear. 08:30 - 10:00 1.50 FISH N DPRB DECOMP Clear and clean rig floor. 10:00 - 10:30 0.50 FISH N DPRB DECOMP _ B~ #5 as follows: Reverse Circulatinq Junk Basket, Bit Sub, 5 Joints of 2 7/8" PAC Drill Pipe, XO, 4 3/4" Bumper Sub, 9 Joints of 4 3/4" Drill Collars, Pump-Out-Sub. 10:30 - 13:00 2.50 FISH N DPRB DECOMP Tri in with BHA #5 and 3 1/2" Drill Pipe. 13:00 - 13:30 0.50 FISH N DPRB DECOMP Stop just above 4 1/2" Stump. PUW = 134K. SOW = 115K. Wash top of Stump at 3.0 bpm/500 psi. Drop RCJB ball. Pressure increased to 1500 psi when ball went on seat. 13:30 - 15:30 2.00 FISH N DPRB DECOMP Gently work and rotate with rotary table to get the 3.625" MIII to fall into the 4 1/2" Stump. Pick-up Kelly and continue to fall through. No-Joy. Discuss plan forward with Anch Eng. 15:30 - 16:00 0.50 FISH N DPRB DECOMP Set Back Kelly. 16:00 - 18:00 2.00 FISH N DPRB DECOMP Trip out with 3 1/2" Drill Pipe and BHA #5. Out Of hole w/ 35 stands. 18:00 - 18:30 0.50 FISH N DPRB DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 20:00 1.50 FISH N DPRB DECOMP Con't to POOH & stand back 3 1/2" DP. 20:00 - 21:00 1.00 FISH N DPRB DECOMP Break out BHA #5. Rebuild Pump out Sub. 21:00 - 22:00 1.00 FISH N DPRB DECOMP M/U BHA #6 (RCJB) to clean out junk as follows: RCJB w/ Mule shoe, Bit Sub, 5 PAC DCs, XO, Bumper Sub, 9- 4 3/4" DCs, Pump Out Sub. TL = 449.24'. 22:00 - 00:00 2.00 FISH N DPRB DECOMP RIH w/ BHA #6 to clean out ~unk on to of de lo ment sleeve. 6/20/2009 00:00 - 01:30 1.50 FISH N DPRB DECOMP RIH and lightly tag up on 4-1/2" tubing stub ~ 8299' with BHA #6 to clean out junk on top of deployment sleeve 01:30 - 02:30 1.00 FISH N DPRB DECOMP Work i e at to of stub to t to enter tubin ~ PU wt 132K, SO wt 117K, Rot wt 129K, 3 BPM, 550 PSI, 28 RPM, 150 amps, 2900 ft-Ibs free torque 02:30 - 04:30 2.00 FISH N DPRB DECOMP Enter tubin stub and ta u 2' in at 8301 ; drop ball to activate RCJB; Kelly back up and start pumping; see pressure climb to 1500 PSI while pumping at 74 SPM, which indicates that the ball is on seat; PU wt 138K, SO wt 120K, Rot wt 129K, 3 BPM, 550 PSI, 28 RPM, 150 amps, 2900 ft-Ibs free torque 04:30 - 06:00 1.50 FISH N DPRB DECOMP Can't qet any further in the 4-1/2" tubinq stub than 8301'(?); called town engineer to discuss; decision was made to POOH and regroup/decide plan forward at morning meeting after discussion with senior town engineer; set Kelly back and POOH from 8299' to 7000' 06:00 - 10:30 4.50 FISH N DPRB DECOMP POOH from 7000" LD BHA #6. Agree upon plan forward with town engineers. 10:30 - 11:30 1.00 FISH N DPRB DECOMP PU/MU BHA #7 per discussion with fishermen and town engineers. BHA #7 will consist of: 3-5/8" convex mill (same we ran the other da -- iYs still in ood shape), bit sub 2-3/8" Reg x 2-7/8" PAC, 2-7/8" PAC collars (8), XO sub 3-1/2" IF x 2-7/8" PAC, 4-3/4" lub. bumper sub, 4-3/4" oil jar, 4-3/4" drill collars (all 3 stands), and 3-1/2" IF pump-out sub. TL = 548' 11:30 - 16:00 4.50 FISH N DPRB DECOMP RIH with BHA #7 and lightly tag up with top of 4-1/2" tubing stub at 8299'. 16:00 - 17:00 1.00 FISH N DPRB DECOMP Make-up Kelly. Slowly rotate and ease into the top of the 4 1/2" Stump at 8,299-ft with no problems. Pull back out and repeat with no rotation. 17:00 - 18:00 1.00 FISH N DPRB DECOMP P/U 4 singles, RIH & tag up on plug reinate C~3 8420' (15' in kelly) Begin rotating & milling from 8420 to 8421' ( top of Printed: 7/16/2009 4:48:34 PM ~ • BP EXPLQRATION, Page ~ of 16 Operations Summary Report Legal Well Name: J-27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/2/2009 Rig Name: NABORS 4ES Rig Number: ~ . I~ _ ~.. I ~ . I~ . I..~_I ~. I ~ . .. ~~ .. ~ r. ~ ~ .. p.,.,... ' 6/20/2009 17:00 - 18:00 1.00 FISH N DPRB DECOMP deployment sleeve). Pump 5 BPM @ 1580 psi. 18:00 - 18:30 0.50 FISH N DPRB DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 19:30 1.00 FISH N DPRB DECOMP Set back kelly. POOH & UD 8 DP singles. 19:30 - 20:30 1.00 FISH N DPRB DECOMP M/U circulating pin on DP. Close in annular & perform injectivit~ test. Pump 1 BPM & we ressure u to si m strokes ( 2.6 bbis). S/D pump & monitored well. Well held 1100 psi & did not bleed off for over 30 min. Notified town engineer & discussed plan forward. Plan to proceed & set lower Pkr/Lnr Hgr assy. R/D test equip. Charted injection test. 20:30 - 23:30 3.00 FISH N DPRB DECOMP POOH & stand back 82 stands of 3 1/2" DP. 23:30 - 00:00 0.50 FISH N DPRB DECOMP Stand back 3 stands of 4 3/4" DCs. 6/21/2009 00:00 - 00:30 0.50 FISH P DECOMP Finish breaking out & LD BHA #7. Mill looked good & no recovery in junk baskets. 00:30 - 01:00 0.50 CASE P TIE61 Clear & clean rig floor. RD DP handling tools. 01:00 - 02:00 1.00 CASE P TIEB1 RU floor & handling tools for 3 1/2" & 7" lower scab liner assembl . 02:00 - 03:00 1.00 CASE P TIEB1 Hold weekly safety meeting w/Brandenburg's crew. Review recent incidents, rig safety statistics, & new safety procedures. Also, discussed rig commitment to compliance & overall excellence in everything we do. 03:00 - 03:30 0.50 CASE P TIE61 Hold PJSM & review lower scab liner running order between driller, packer hand, and WSLf. 03:30 - 04:30 1.00 CASE P TIEB1 PU lower scab liner assembly & RIH. Run muleshoed 3-1/2" 8.81 # SLT L-80 joint, first fourfull 3-1/2" 8.81 # SLT joints, and 3-1/2"x4-1/2"x7" XO sub. 04:30 - 05:30 1.00 CASE P TIE61 RD smaller casing tongs and RU 7" casing tongs and bring 800# of 20/45 mesh sand to the rig floor up the beaver slide; RIH with first 7" 26# L-80 BTC-M jt with HES RBP installed; WSLf and packer hand visually verified plug installed and r rl oriented 05:30 - 06:00 0.50 CASE P TIE61 PU next 7" jt and RIH; RU hopper on 7" casing stump in rotary table and dum~800# of 20/45 mesh sand (approximately 30') _ to rotect HES RBP _~_ 06:00 - 06:30 0.50 CASE P TIEB1 RIH with Baker lower scab liner hanger assembly (HMC liner hanger, C-2 ZXP liner top packer, hydraulic setting tool, and 5" DP pup joint -- 37.03' total length). 06:30 - 07:00 0.50 CASE P TIE61 Clean and clear rig floor of smaller casing tongs and put 7" casing tongs down the beaver slide. 07:00 - 08:00 1.00 CASE P TIE61 RIH with 3 stands of 4-3/4" drill collars and first 5 stands of 3-1/2" DP, filling after the last stand of DP. 08:00 - 12:00 4.00 CASE P TIEB1 RIH with stands 6-84 of 3-1/2" DP, filling every 10 stands. 12:00 - 13:30 1.50 CASE P TIE61 Taq up with 3-1/2" tubing stinger on the 4-1/2" tubing stub at 8,299'. T to work strin down into tubing stub with no luck. P wt 138K SO wt 117K. 13:30 - 14:00 0.50 CASE N DPRB TIEB1 Fisherman, packer hand, WSLs, and senior Nabors hand exhaust ideas and decide to call town engineer to discuss plan forward. 14:00 - 14:30 0.50 CASE N DPRB TIE61 Decision is made to et a little more a ressive, but no success is achieved and all involved parties, to include the town engineer, agreed to POOH and have an aluminum bull-nose plug approximate y-inc es ong mac ined. 14:30 - 15:30 1.00 CASE P TIE61 Hold weekly safety meeting w/ all hands on Tinsley's crew and all other assigned hands. Review recent incidents, rig safety Printed: 7/16/2009 4:48:34 PM ~ ~ BP EXPLORATf~N Pa~e 7 af ~6 Operations Summary Report Legal Well Name: J-27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/2/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Cod~ NPT Phase De~eription of Operations 6/21/2009 14:30 - 15:30 1.00 CASE P TIEB1 statistics, & new safety procedures. Also, discussed rig commitment to compliance & overall excellence in everything we do. List actions that need to be addressed before ne~ B. Hopkins audit. I 6/22/2009 15:30 - 18:00 18:00 - 18:30 18:30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 01:30 01:30 - 02:30 02:30 - 03:30 03:30 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 11:30 11:30 - 12:30 2.50 CASE N 0.50 CASE N 3.50 CASE N 1.00 CASE N 1.00 CASE N 1.50 CASE N 1.00 CASE 1.00 CASE 5.50 CASE 0.501 CASE 0.50 CASE 0.50 CASE 1.00 CASE 1.00 CASE 12:30 - 13:00 I 0.501 CASE 13:00 - 13:30 I 0.501 CASE 13:30 - 14:00 0.50 CASE 14:00 - 18:00 4.00 CASE 18:00 - 18:30 0.50 CASE 18:30 - 19:00 0.50 CASE DPRB TIE61 POOH wet from 8,299' to 560.15' and start of lower scab liner DPRB DPRB DPRB DPRB TIE61 TIEBi TIEB1 TIEB1 hanger assembly. Crew change. Service rig. Inspect derrick. Check PVT alarms. POOH & stand back total of 82 stands of 3 1/2" DP. String was wet. Set back 3 stands of 4 3/4" DCs. R/D DP handling tools. R/U floor to handle Lower Hanger / Packer Assy. UD Packer / Hanger Assy. R/U Vac truck & suck out sand plug from inside 7" casing. R/D Vac truck & clear floor. ~ DPRB TIE61 UD 2 jts of 7" casing. Pull & UD 4 jts + 1 Muleshoed jt of 3 1/2" STL tubing. Mule shoe showed sliqht damage from attempts to enter tubina stub TIE61 M/U running tool & pull Wear Bushing. Install Test plug & RILDS. TIEB1 R/U test equip & prep to test BOPE. Hold PJSM. TIEB1 Perform Weekl BOP Test Test Blinds, Choke Manifold, Manual Kill and Choke Valves, HCR Kill and Choke Valves, Floor Valves, 3-1/2" x 6" VBRs with 3-1/2" and 4-1/2" Test Joints, Hydril Annular Preventer with 3-1/2" Test Joint, Kelly Valves, Test Spool Valves. Perform Koomey drawdown test. AOGCC witness of test was waived by John Crisp; test was witnessed by the Nabors Tourpusherlfoolpusher and the BP WSLs. Tested to 250/3500 psi. Good test. Recorded on chart. RD test equipment. TIE61 Dressed off Kelly bushing ears with grinder and cleaned up and cleared rig floor. TIEB1 Kelly down and set back in shuck. TIEB1 Pulled test joint and reinstalled wear bushing. TIEB1 RU 3-1/2" casing tongs and brought 7" casing tongs to the rig floor. TIEB1 RIH with Baker-Loc'ed 3-1/2", 8.81#, L-80, STL jt with aluminum bull-nose lug, next fourjts of 3-1/2", 8.81#, L-80, STL joints (all Baker Loc'ed), 3-1/2" STL x 4-1/2" x 7" BTC-M XO sub (Baker-Loc'ed), 1 jt 7", 26#, L-80, BTC-M with HES RBP installed (14' from top of joint), and 1 jt 7", 26#, L-80, BTC-M. Downhole barrier -- HES RBP ~ 8226'. TIE61 Rigged up sand hopper and dumped 800#s of 20/40 mesh sand down the 7" casing joints to the top of the HES RBP (approximately 34'). Top of sand C~ 8192'. TIEB1 RIH with Baker lower scab liner hanger assembly (HMC liner hanger, C-2 ZXP liner top packer, hydraulic setting tool, and 5" DP pup joint -- 37.03' total length). TIEB1 RIH with 3 stands of 4-3/4" drill collars and first 3 stands of 3-1/2" DP. TIEB1 RIH with 3-1/2" DP (stands 4-82) to 8217'. Fill DP every 5 stands. TIEB1 Crew change. Service rig. Inspect derrick. Check PVT alarms. TIEB1 Establish PU wt 136K and SO wt 119K. Pick up three single jts of 3-1/2" DP and RIH to 8299' and on into the 4-1/2" tubina Printed: 7/16/2009 4:48:34 PM ~ ~ BP EXPLORATION i Page 8 of 16 Qperation5 Summary Report Legal Well Name: J-27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: WORKOVER Start: 6/10/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/2/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hc~urs Task Code NPT Phase Qescription of ~peratit~n~ 6/22/2009 18:30 - 19:00 0.50 CASE TIEBi 19;00 - 19:30 0.50 CASE TIE61 19:30 - 20:00 ~ 0.50 ~ CASE TIEB1 20:00 - 20:30 0.50 CASE TIEB1 20:30 - 22:30 2.00 CASE TIEB1 22:30 - 23:00 0.50 CASE TIEB1 23:00 - 00:00 1.00 CASE TIEB1 6/23/2009 00:00 - 01:00 1.00 CASE P TIEB1 01:00 - 01:30 0.50 CASE P TIEB1 01:30 - 02:00 0.50 CASE P TIEB1 02:00 - 02:30 0.50 CASE P TIEB1 02:30 - 08:00 I 5.50~ CASE I P I ITIEBI 08:00 - 10:00 I 2.001 CASE I P I ITIE81 10:00 - 13:00 I 3.OOI CASE I N I DFAL ITIEBI 13:00 - 14:00 1.00 CASE P TIEB1 14:00 - 17:00 3.00 CASE N DFAL TIEB1 17:00 - 18:00 I 1.001 CASE I P I I TIEB1 18:00 - 18:30 0.50 CASE P TIEB1 18:30 - 20:30 2.00 CASE P TIEB1 20:30 - 21:30 1.00 CASE P TIEB1 RIH with last three singles to 8403' and Kelly up. RiH approximately 17' in on the Kelly and tag up with coil liner top and remnants of Fas-Drill olua at 8421'. PU to SO wt plus 5', which is our predetermined packer and liner setting depth. Pressure up to 2000 psi. seeinq indications of the liner hanqer setting at 1675 psi. SO to 80K (down wt = 40K) to verify liner hanger set. After pressure testing Kelly hose to 4000 psi by itself, pressure up to 4000 psi using mud and test pump to set liner top packer ; See positive indications of liner top packer setting at 3300 psi and pressure up to 4000 psi and held for 1 minute and then bleed off. Then, we overpulled 10K# and SO to 110K to ensure the liner top packer was set. We then rotated 16 turns to pull up and out of the packer and hanger assembly. Pulled up one joint and verified our ability to circulate. TOL ~ 8145'. Set back Kelly and LD six single joints of 3-1/2" DP. POOH & stand back 33 stands of 3 1/2" DP. Flush DP, DP wanting to flow back from air in pipe from fill. Pump 3.5 BPM ~ 1080 psi. Pumped 185 bbls. Con't to POOH & stand back 3 1/2" DP. Con't to POOH & stand back 3 1/2" DP. Stand back 3 stands of 4 3/4" DCs. Break out & UD liner running tools. Clear & clean rig floor. P/U & M/U RTTS & circulatinq sub. M/U XO & catcher for drift on bottom of RTTS. RIH w/ RTTS on 3 stands of 4 3/4" DCs, 78 stands DP, and 1 DP single to 7600'. Saw SO wt of 10K at 6098', but worked back up and through with no issues and continued downhole. When on depth at 7600', gave RTTS 2 full turns to set element and then pressured up to 3700 psi and held for 1 minute before pressure rapidly fell off; attempted to set RTTS again with rotary table and pressured up to 2200 psi before the pressure again fell off rapidly. Worked downhole to various depths trying to get the packer element to seal, ending our efforts with a test C~ 7848' with no luck. While we did hang up somewhat on what we proved were 9-5/8" casing collars (right at 40' feet apart across several joints), the immediate failu e nattern of our Rressure losses point to an RTTS failure and not issues with the 9-5/8" casina. Slip and cut 84' of drilling line. POOH to 2991' and set RTTS. Encountered tight spot at 6098' and overpulled to 135K and pulled free. Close annular preventer and pump down kill line to test OA to 3500 psi... Set RTTS (~ 2991'. Pressure up to 3500 psi & test DP x 9 5/8" annulus for 30 min. Held Ok...Good Test. Notified town engineer. Crew change. Service rig. Check PVT alarms. Inspect derrick. Unset RTTS & allow rubbers to relax. Break off circulating pin. Drop 1.8" Drift w/ tattle tail. POOH & stand back 3 1/2" DP. Stand back 3 stands of DCs & recover drift & tattle tail. POOH & UD packer. inspected pkr. ~op element entirely gone, spacer Printed: 7/16/2009 4:48:34 PM ~ . • BP EX Operations Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date From - To Haurs Task Code NPT I 6/23/2009 20:30 - 21:30 1.00 CASE P TI 21:30 - 00:00 2.50 CASE P TI 6/24/2009 00:00 - 01:00 1.00 CASE P TI PLORATION Page 9 of 1 Surnmary Report Spud Date: 6/14/1987 Start: 6/10/2009 End: Rig Release: 7/2/2009 Rig Number: ~se ~ Description of Operations EB EB EB 1 ring had only -4" remnant & Lower element had a-6" slice gone. Notified town enginner & discussed plan forward. 1 P/U 2nd RTTS inpect & RIH w/ 3- stands of 4 3/4" DCs & 29 stands of 3 1/2" DP. 1 S ace out & set RTTS w/ 20K down wt. @ 3023'. P/U Wt = 60K, S/O Wt = 58K. Close in Pipe Rams & pressure up to 3500 si. Test DP x 9 5/8" cs for 30 min. Tested Good. Charted ~ testin . Monitored OAP. OAP increase from 0 to 375 psi when pressured up. bled off OAP to 0& monitored. No increase or pressure seen. 1 Bled off pressue. Unset RTTS & allow rubbers to relax. R/d test equip. RIH w/ RTTS. (58 stands + single) 1 S ace out & set RTTS w/ 20 K down wt ~ 6010'. This is -87' above tight spot noted on previous run. Pressure up down DP & test RBP/Lower Liner Ass . to 3500 si for 30 min. Tested ood. Charted testin . OAP = 375 psi after pressure up. No flow in DP/Csg annulus. P/U Wt = 100K, S/O Wt = 97K. Note: did not notice any rubber or debris while RIH w/ 2nd RTTS. 1 R/D test equip. Unset RTTS allow rubbers to relax. POOH & stand back 3 1/2" DP. 1 Crew change PTSM. Service rig, check PVT's, daily derrick inspection and enviro walkaround. 1 POH w/9-5/8" Halco RTTS packer standing 3-1/2" DP in derrick. 1 Break out and lay down 9-5/8" Halco RTTS packer. Sealing elements in good condition. 1 Clear and clean rig floor. 1 Rig up floor with 7" pipe handling tools and prepare to RIH w/7" scab liner. 1 PJSM - Review procedure for running in hole with 7" liner with all crew. Also reviewed running order and special instructions for make up of shoe track. 1 PUMU 7" scab liner shoe track as follows: 7-1/2" ported tie-back stem w/seals, 7 6#, -80 BTC 10' pup, 1 jt. 7" 26#, L-80 BTC casing, 7" Halco Ported Float Collar, 1 jt. 7" 26# L-80 BTC casing & 1 jt. 7" 26# L-80 BTC casing with Baker Insert Landing Collar. Made up all connections to mark and Baker-Lok'd all connections. 1 RIH w/7" 26# L-80 BTC scab liner 1 x 1 from pipe shed. Made up all connections to mark. 55-jts. RIH at 16:00-hrs. 80-jts. RIH at 17:30-hrs. 1 Crew change. Service rig. Inspect derrick. Check PVT alarms. 1 Con't to RIH w/ 7" 26#, L-80, BTC-M liner. Make up all threads to triangle. Install 1 Free Floating turbolizer on each jt. Fill liner every 5 jts.RlH w/ total of 127 jts. 1 P/U Liner hanger / ZXP packer assy, inspect same & RIH. Record P/U Wt = 134K, S/O Wt - 130K. 1 Clear floor. R/U handling tools for DP/DCs. Drift & P/U 10 - 6 1/4" DCs + 1 4 3/4" DCs & RIH. 1 Con't Drift & P/U 10 - 6 1/4" DCs + 1 4 3/4" DCs & RIH. RIH w/ 3 stands of 4 3/4" DCs. 1 RIH w/ Scab liner on 24 stands of 3 1/2" OP. Fill every 5 stands. Did not notice any indication of problem area at -6098'. 01:00 - 03:00 2.00 CASE P TIEB 03:00 - 03:30 0.50 CASE P TIEB 03:30 - 06:00 2.50 CASE P TIEB 06:00 - 06:30 0.50 CASE P TIEB 06:30 - 07:30 1.00 CASE P TIEB 07:30 - 08:00 0.50 CASE P TIEB 08:00 - 08:30 0.50 CASE P TIEB 08:30 - 09:30 1.00 CASE P TIEB 09:30 - 10:00 0.50 CASE P TIEB 10:00 - 11:00 ~ 1.00 ~ CASE ~ P ~ ~ TI EB 11:00 - 18:00 I 7.00 I CASE I P I I TIEB 18:00 - 18:30 0.50 CASE P TIEB 18:30 - 22:00 3.50 CASE P TIEB 22:00 - 22:30 0.50 CASE P TIEB 22:30 - 00:00 1.50 CASE P TIEB 6/25/2009 00:00 - 01:00 1.00 CASE P TIEB 01:00 - 03:00 2.00 CASE P TIEB Printed: 7/16/2009 4:48:34 PM • ! BP EXPLQRATIUN' Page 10 of 16 Operations Summary Repar# Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES fl~ta' I Grnm _ Tn ~ 4..lni irc I T~clr I(`nrla I NIPT I' Start: 6/10/2009 Rig Release: 7/2/2009 Rig Number: 6/25/2009 01:00 - 03:00 2.00 CASE P TIEB1 03:00 - 05:00 2.00 CASE P TIEB1 05:00 - 06:00 I 1.001 CASE I P I I TIE61 06:00 - 10:00 I 4.001 CASE I P I I TIEB1 10:00 - 13:00 I 3.001 CEMT I P I I TIEB1 Spud Date: 6/14/1987 End: vcao~iNnviu ui v~ciauv~.ia P/U 2 singles M/U circulating head. Break circulation. 2 BPM ~ 40 psi. Slowly RIH & enter liner receptacle. Saw pressure increase of 200 psi, 24 stands + 1 single + 20' of 2nd single. S/D pump & con't in receptacle & NO-GO out ~ 27.5' in. P/U & verify depths.P/U break off single, P/U 6' DP pup & bury below 2nd single. M/U cementing head. RIH & re-tag to pressure increase & then bottom out. P/U wts changed from 193K up Wt to 177K Up wt. S/O wts went from 177K to 164K respectively. Possibility of rubber from RTTS run causing change in uvts. Circulate bottoms up. Pump 3 BPM, 230/280 psi. Notify town engineer of P/U & S/O wt changes. M(RU Schlumberger cementers and spot vac trucks. Continued circulating. Returns at +80F. Crew change PTSM. PJSM - reviewed liner running, cementing and setting procedure with all crew. Blow air back through lines to cement pump truck and to open top tank. cementers primed up and pumped 5.0-Bbls. fresh water to charged lines. Cementers pressure tested lines to 4800-psig. Batched up tub of cement. Started pumping 160-Bbis. 15.8-ppg Class "G" cement at 3.0-bpm and increased rate to 5.0-bpm at 465-psi. Pumped a total of 161.2-Bbls. cement. Shut down pump and dropped drill pipe wiper dart. ommence pumping seawater isplacement at 4.0-bpm and increased to 5.0-bpm. At 16.0-Bbls. displacement away, slowed pump rate to 3.0-bpm to latch liner wiper plug with drillpipe dart. Did not see wiper dart latch liner wiper plug. At 25.0-Bbls. displacement away, increased displacement pumping rate to 5.0-bpm. Continued pumping seawater displacement at 5.0-bpm. At 165-Bbis. displacement away, treating pressure increased to 2200-psi. Slowed pump rate to 4.0-bpm to keep treating pressure below 2550-psi max. Continued decreasing pump rate down to to a final rate before shutdown of 0.3-bpm at 2585-psi. and with 11-Bbls. cement above liner top packer. Did not bump plug. Bled off pressure and checked float. Float held. Decision made to discontinue pumping displacement all the way to plug bump in order to keep from prematurely setting liner hanger and not getting seai stem in tie-back receptacle. Cement in place at 12:14-hrs. Cement yield = 1.16 ft3/sk. left 10.4-Bbls. cement in liner. Inserted tie-back stem in tie-back receptacle with 15-20K 1000-psi increments to set liner hanger. Increased pressure to 4400-psi to set liner top packer. Verified liner hanger and packer set by setting down entire drillpipe string weight on dog sub two times. Set string in slips and rotated 15 turns to right with rotary table. Pressured up string to 1000-psi and unset running tool from liner tie-back receptacle. Picked string up 25' to clear running tool fro liner top. Pumped 14-Bbls. seawater to clear tie-back receptacle and liner top. Closed annular preventer and reversed out cement to open top tank. Recovered -11-Bbis. cement in returns. Reversed additional 60-Bbls. to open top tank to wash out DP and lines. Printed: 7/16/2009 4:48:34 PM • • BP EXF Operations : Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Spud Date: 6/14/1987 Start: 6/10/2009 End: Rig Release: 7/2/2009 Rig Number: ~; Date From - To Hours Task Code NPT Ph 6/25/2009 13:00 - 18:00 5.00 CEMT P TIEB ase ~ ' Description of Operations 1 POH with one jt. 3-1/2" DP and Baker cementing swivel. Break out and lay down same. POH and lay down one more joint DP. Pickj Baker swivel and joint. Break out Baker swivel and lay down same. POH standing 3-1/2" DP in derrick. Lay down 10 ea. of 6-1/4" drill collars and 1 ea. of 4-3/4" drill collar. Lay down liner running/setting tool. Prepping wellhead with herculite and steam lines to heat wellhead for pack-off changeout. 1 M/U running tool. BOLDS. Pull Wear Bushing. UD same. 1 M/U running tool. RIH & enqage Pack Off. Attempt to pull Pack Off. Worked i e u to 60K. No success. Notified town Engineer. Plan to proceed w/ alternate plan & remove spool. 1 Pull & UD retrieving tool. RILDS. 1 Clear & clean rig floor. 1 P/U & M/U BHA #8 to clean out shoe track as follows: 6 1/8" Bit, 1- 4 3/4" Boot Basket, 7" Scraper, Bit Sub, Bumper Sub, 9 -4 3/4" DCs. TL = 296.04' 1 RIH w/ BHA # 8 on 24 stands of 3 1/2" DP. 1 Crew change. Srvice rig. Inspect derrick. Check PVT alarms. 1 P/U Storm packer & M/U on drill strinp. RIH & set storm packer C~ 35' on 1't of DP. Close blind rams & ressure test storm acker to 1000 si for 10 min. Test Good. Charted test. 1 Hold PJSM & N/D BOPE. Set stack back. 2 Barriers in place are: Storm pkr @ 35' tested to 1000 psi & RBP @ 8226' Tested to 3500 psi. 1 N/D Tubing spool. Pull spooi & pack off. N/U new tubing spool. Notified Well Tie-in supervisor of readiness for wellhead survey. 1 Continue NU new tubing spool and casing packoff. Set test plug and RILDS. Pressure tested new casing packoff to 5000-psi_for 30-minutes. 1 Nippled up BOP stack. Bell Surveyors shot elevations on new tubing spool for future well tie-in. 1 Pressure tested BOP breaks to 250-psi Lo/3500-psi Hi and charted same. BOLDS. Pull and lay down test plug. Set wear ring with I.D. = 9.25" 1 RIH with storm acker retrieving/running tool on joint of 3-1/2" ~ DP made up with closed TIW valve. Engaged with 8 ng t hand turns and released 9-5/8" Halco storm packer. Let packer set for 2 minutes to allow sealing element to relax, pulled packer up hole 1' and let set for an additional 2 minutes allowing element to furthe relax and to ensure no pressure trapped under packer. POH UD same. 1 Crew change PTSM. Reviewed plan forward and current status of well. Serviced rig, checked PVT's, performed daily derrick inspection and enviro walkaround. 1 Review HSE issues from last week with all crew. 1 POH with BHA #8 and drop off 7" Scraper. 1 Break out and lay down 7" casing scraper.~ Make up BHA #8 as follows: 6 1/8" Bit, 1- 4 3/4" Boot Basket, Bit Sub, Bumper Sub, 9-4 3/4" DCs. TL = 292.74'. 1 RIH with BHA #8 to cleanout 7" liner and liner shoe track. 1 Tag up ~ 7552'. P/U kelly & break circulation. RIH & re-fag ~ 18:00 - 18:30 0.50 WHSUR P TIEB 18:30 - 20:00 1.50 WHSUR P TIEB 20:00 - 20:30 0.50 WHSUR P TIEB 20:30 - 21:30 1.00 WHSUR P TIEB 21:30 - 22:30 1.00 WHSUR P TIEB 22:30 - 00:00 1.50 WHSUR P TIEB 6/26/2009 00:00 - 00:30 0.50 WHSUR P TIEB 00:30 - 01:00 0.50 WHSUR P TIEB 01:00 - 02:30 I 1.501 BOPSUR P I I TIEB 02:30 - 06:00 I 3.501 WHSUR I P I I TIEB 06:00 - 08:00 2.00 WHSUR P TIEB 08:00 - 09:00 1.00 BOPSU P TIEB 09:00 - 10:30 1.50 BOPSU P TIEB 10:30 - 11:30 I 1.001 WHSUR I P I I TIEB 11:30 - 13:00 I 1.501 CASE I P I I TIEB 13:00 - 14:00 1.00 CEMT TIEB 14:00 - 15:30 1.50 CEMT P TIEB 15:30 - 16:00 0.50 CEMT P TIEB 16:00 - 18:00 2.00 CEMT P TIEB 18:00 - 18:30 0.50 CEMT P TIEB Printed: 7/16/2009 4:48:34 PM • • ~P EXPLQR~4TlQN Page 12 of 16 Operations Surnmary Report Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES "D Spud Date: 6/14/1987 Start: 6/10/2009 End: Rig Release: 7/2/2009 Rig Number: ate From - To Hours Task Code NPT ~~~~ 6/26/2009 18:00 - 18:30 0.50 CEMT P TIEB1 16/27/2009 100:00 - 06:00 I 6.001 CEMT I P I I TIEB1 06:00 - 08:00 I 2.001 CEMT I P I I TIE61 08:00 - 09:00 1.00 CEMT P TIE61 09:00 - 10:00 1.00 CEMT P TIEB1 10:00 - 10:30 0.50 CEMT P TIEBf 10:30 - 18:00 7.50 CEMT P TIE61 18:00 - 18:30 0.50 CEMT P TIE61 18:30 - 00:00 5.50 CEMT P TIEB1 6/28/2009 00:00 - 03:00 3.00 CEMT P TIEB1 03:00 - 03:30 0.50 CEMT P TIEB1 03:30 - 04:30 1.00 CASE P TIEB1 04:30 - 06:00 1.50 CASE P TIEB1 06:00 - 06:30 0.50 CASE P TIEB1 06:30 - 08:30 2.00 CASE P TIE61 08:30 - 10:00 1.50 CASE P TIEB1 D~scription of Operatians 7552'. Wash down to 7606'. Begin drilling cement from 7606' to 7694'. P/U Wt = 128K, S t= 117 , Rot Wt = 121 K. 5 BPM C~3 950 psi. Free Torq = 2500 ft-Ibs, WOB 3-14K. Pumping Hi-vis sweeps to clean hole. Good cement returns. Drill cement from 7694' to 7866'. P/U Wt = 128K, S/O Wt = 117K, Rot Wt = 121 K. 5 BPM ~ 950 psi. Free Torq - 2500 ft-Ibs, WOB 3-14K. Pumping 15 bbl Hi-vis sweeps to clean hole. Good cement returns. Crew change PTSM. Serviced kelly and continue drilling ahead to 7953'. Circulate hi-vis sweep around to ensure hole is clean. POH laying down 11 jts. 3-1/2" DP. PJSM - RIH w/DP from derrick. RIH w/12 stands 3-1/2" DP from derrick. Kelly up. Break circulation at 5.0-BPM at 1000-PSI. Continue drilling cement from 7953'. RPM = 59, Rotating S/O wt. _ 124K, WOB = 12-15K, SPM = 85 ~ 1000-PSI. Drill out cement, landing collar at 8007' and float collar at 8090'. Pumped hi-vis sweeps at regular intervals to ensure good hole cleaning. Con't to RIH & tag Q 8187' Dry drill from 8187' to 8188'. Crew change. Srvice rig. Inspect serrick. Check PVT alarms. Pump 2- 30 bbl Hi-Vis sweeps around to ciean hole. Had lots of cement returns from sweeps. Also recovered larae amount of rubber. Con't to circulate until hole clean. Pump 5.75 BPM C~ 1350 psi. Set back kelly. Well U-tubing up DP, still have cement in well. Mix 3rd - 30 bbl Hi-Vis pill & circulate around. Had more cement returns, then well cleaned up. Set back kelly. POOH & stand back 3 1/2" DP. Break out & UD BHA #8. Bit looked good, recovered -1 gal of _ cement & Aluminum Close in blind rams & qressure test 7" liner to 3500 psi for 30, sand over pluq. RCJB, PxP O-ver, Boot Basket, Scraper, Bit Sub, Bumper Sub, 9- 4 3/4" DCs and 4-3/4" Pump-Out Sub. TL = 304.47'. RIH w/ same. Crew change PTSM. Service rig, check PVT's, daily derrick inspection and enviro walkaround. Continue RIH with BHA #9 on 3-1/2" DP from derrick. Gave 24-hrs. notice to AOGCC of required weekly BOPE testing. Tap debris at 8184'. Kelly up. Establish circulation, break off kelly and drop 7/8" ball. Pump ball into seat. Shut down pump per Baker Fisherman. Establish rotation at 25-30 RPM. Drill RCJB into top of fill approx. 4' to 8188'. Pick up and establish circulation at 3.0-BPM at ~1500-psi. Set down to make some hole. Strinp was pluqqed. Worked pipe to trv to unqluq strinq. pressure and opened annular preventer. Broke off and set back kelly. Dropped dart to shear pump-out sub. Hokked up circualting hose and waited 15 minutes for dart to fall on seat. pressured up DP to -1600-osi and sheared open pump-out Printed: 7/16/2009 4:48:34 PM ~ • i BF vperations Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date From - To Hours Task Code NPT '' 6/28/2009 08:30 - 10:00 1.50 CASE P 10:00 - 11:30 1.50 CASE P 11:30 - 14:30 3.00 CASE P 14:30 - 15:30 1.00 CASE P 15:30 - 16:00 0.50 CASE P 16:00 - 17:00 1.00 CASE P 17:00 - 18:00 1.00 CASE P 18:00 - 18:30 0.50 CASE P 18:30 - 21:00 2.50 CASE P 21:00 - 23:00 2.00 CASE P 'LORATION F ~urnmary Report Spud Date: 6/14/1987 Start: 6/10/2009 End: Rig Release: 7/2/2009 Rig Number: Descrintion of Oneratit~ns TIE61 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TI EB 1 23:00 - 00:00 I 1.00 I CASE I N I I TIE61 6/29/2009 I 00:00 - 00:30 I 0.50 I CASE I N ~ I TIE61 00:30 - 01:00 I 0.501 CASE I N I I TIEB1 01:00 - 04:00 3.00 CASE P TIE61 04:00 - 05:00 1.00 CASE P TIEB1 05:00 - 06:00 1.00 CASE P TIEB1 06:00 - 07:30 1.50 CASE P TIEB1 06:30 - 09:30 3.00 CASE P TIEB1 09:30 - 11:00 1.50 CASE P TIEB1 11:00 - 14:00 I 3.001 CASE I P I I TIEB1 sub. Swap hole to clean seawater. POH w/BHA #8 standing 3-1/2" DP in derrick. Break out and lay down BHA #8.~ RCJB packed/plugged with cement. Clear and clean rig floor. Crew weekly HSE meeting. Reviewed past weeks HSE issues and their commonality to our operations. M/U BHA #9: Re-run of BHA #8, RCJB w/ scra er to clean out junk above sand. Crew change. Service rig. Inspect derrick. Check PVT alarms. RIH w/ BHA #9 on stands of 3 1/2" DP. P/U kelly break circuiation @ 1 BPM, RIH & tag up ~ 8187'. 84 stands + single + 10' of kelly. P/U break connection & drop ball, open reversing ports. Increase circulation rate to 5.7 BPM C~ 1540 psi. RIH & work RCJB down rotating C~ 20 RPMs_Hiut hard bottom & mill/wash down 2', then penetration rate picked u but was still slow. Circulate down until RCJB made 10'. P/U Wt = 142K, S/O Wt = 120K, Rot WT = 140K. P/U on kelly & pulled tight within 2' of P/U. Could not rotate. Began working pipe & pulled to 50K over. Mixed & pump 20 bbl Hi-Vis sweep. Con't to attempt to regain rotation & movement. Circulating rate & pressure never changed. Notified town engineer of problem. Work pipe established full rotation. Con't to pump sweep around DP & up annulus pumped total of 120 bbls. Stop rotation & P/U string. Pipe free. Con't to P/U kelly to connection. Con't to pump sweep around to surface. Dropped ball & open Pump out Sub. Con't to Pump 5.7 BPM ~ 1200 psi. Recovered v.small amount of rubber & some cement. Set back kelly.UD single. POOH & stand back 3 1/2" DP. Stand back 3 stands of 4 3/4" DCs. Break out & Clean out RCJB. Recovered hard packed cement & several larpe chuncks of rubber. (RTTS rubber lost in hole3lEmpty boot basket. recovered cement & sand. Clear & clean rig floor. Prep M/U BHA #10; 3rd run w/ RCJB, including jars. Crew change PTSM. Service rig: checked PVT's, daily derrick inspection, greased drawworks, traveling block and crown sheaves. Performed enviro walkaround. Performed electrical maintenance in derrick. RIH w/BHA #10 on 3-1/2" DP from derrick. Kelly'd up and obtained parameters: P/U wt. = 142k, S/O wt. _ 120K, pump rate 5.5-BPM at 550-psi. Broke kelly off and dropped ball. Made up kelly and commenced pumping ball down at 3.0-BPM at 440-psi. ball on seat after 18 minutes. Increased pump rate to 5.75-BPM at 1550-psi. Commenced rotating at 15-RPM. Tagged at 8197'. Washed down to 8213'.. Did not encounter anv indication of larae debris. Broke off and set kelly back. POH standing 3-1/2" DP in derrick. Notified AOGCC at 13:00-hrs. of weekly BOPE test beginning in 4.0-hrs. Printed: 7/16/2009 4:48:34 PM ~ ~ BP EX Operations Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Page 14 of 16 Start: 6/10/2009 Rig Release: 7/2/2009 Rig Number: Date From - To Hours Task Code NPT Pha 6/29/2009 14:00 - 15:00 1.00 CASE P TIEB1 16~00 - 18:00 2.00 BOPSU~P TIE61 18:00 - 18:30 0.50 BOPSUF~ P TIEB1 18:30 - 20:30 2.00 BOPSUF~ P TIE61 20:30 - 21:30 I 1.001 CASE I P I I TIE61 21:30 - 22:00 0.50 CASE P TIEB1 22:00 - 00:00 2.00 CASE P TIEB1 6/30/2009 00:00 - 02:30 2.50 CASE P TIEB1 02:30 - 03:30 1.00 CASE P TIE61 03:30 - 06:00 2.50 CASE P TIEB1 06:00 - 06:30 I 0.50 f CASE I P 06:30 - 08:00 I 1.501 CASE I P 08:00 - 14:00 I 6.001 CASE I P 14:00 - 14:30 0.50 CASE P 14:30 - 15:00 0.50 WHSUR P 15:00 - 15:30 0.50 RUNCO 15:30 - 17:00 1.50 RUNCO 17:00 - 18:00 I 1.001 RU T~EB1 TIE61 Spud Date: 6/14/1987 End: Descriptipn of Qperations Broke out and layed down RCJB BHA. Junk basket and boot basket empty of debris. Cleared rig floor. Pull wear ring. Rig up test equipment to test BOPE. Tested all BOPE compenents to 250-psi Lo/3500-psi Hi. Tested Blind/Shear rams, Choke Manifold, Manual Kill and Choke Valves, HCR Kill and Choke Valves, Floor Valve, IBOP, 3-1/2" x 6" VBRs with 3-1/2" and 4-1/2" Test Joints, Hydril Annular Preventer with 3-1/2" Test Joint, upper and lower Kelly Valves, Test Spool Valves. Perform Koomey drawdown test. Chuck Sheve waived state's right to witness testing. Crew change. Service rig. Inspect derrick. Check PVT alarms. Con't Performing weekly BOPE testing per BP/AOGCC requirements. Tested all BOPE compenents to 250-psi Lo/3500-psi Hi. Tested Blind/Shear rams, Choke Manifold, Manual Kill and Choke Valves, HCR Kill and Choke Valves, Floor Valve, IBOP, 3-1/2" x 6" VBRs with 3-1/2" and 4-1/2" Test Joints, Hydril Annular Preventer with 3-1/2" Test Joint, upper and lower Kelly Valves, Test Spool Valves. Perform Koomey drawdown test. Chuck Sheve waived state's right to witness testing. Hold weekly safery meeting w/ entire crew. Discussed latest safety notices, recent incidents & latest directives from Nabors safety policies. Also discussed rig safety culture & goals. P/U Halliburton retrievinq tool & BHA. RIH w/ Retieving tool BHA on stands of 3 1/2" DP. Con't to RIH w/ Retieving tool on 84 stands of 3 1/2" DP. Cut & slip 84' of drilling line. P/U 2 singles & RIH. Tag up on sand 11' in on 3rd jt. Close in annular & reverse out sand from 8197' to top of RBP @ 8223'. Reverse out until clean. P/U Wt = 137K, S/O Wt = 115K. Pump 4 BPM @ 620 psi. Crew change PTSM. Service rig: grease drawworks, traveling block and crown, daily derrick inspection, check PVT's and enviro walkaround. Opened annular preventer. Circulated long way and washed down additional 3 ft. to engage RBP. Set 10K downweight on RBP to shear open equalizing port. Did not see any shearing action. Picked up to check for overpull and latch up with retrieving tool. No latch. Set slips and applied 1 round right hand torque and held same with rotary tongs. Set down with 10K downweight on RBP. Picked up and still no latch. Set 5K downweight on RBP and applied 3/4 turn right hand torque. Picked up and RBP latched up to retrieving tool. Let sealing TIEB1 POH laying down 3-1/2" DP 1 x 1 through pipe shed. 115 jts. POH at 11:45-hrs. TIEB1 Breakout and UD HES RBP. RUNCMP Pull Wear Bushing. RUNCMP Clear and clean rig floor. RUNCMP R/ h ndlin e ui ment to run 4-1/2"com letion, R/U compensator, R/U Torque Turn equipment RUNCMP Load completion jewelry into pipeshed and put into running Printed: 7/16/2009 4:48:34 PM ~ , _ _ __ ' BP E~ Operatio.ns Legal Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date From - To Hc~urs Task Code NPT 6/30/2009 17:00 - 18:00 1.00 RUNCO 18:00 - 19:00 1.00 RUNCO 19:00 - 20:00 1.00 RUNCO 20:00 - 00:00 I 4.00 7/1/2009 100:00 - 06:00 I 6.00 06:00 - 06:30 0.50 RUN 06:30 - 07:30 1.00 RUN 07:30 - 08:30 1.00 RUN 08:30 - 11:00 2.50 RUN 11:00 - 13:30 I 2.50 13:30 - 14:30 I 1.OOI WHSUR I P 14:30 - 15:30 1.00 BOPSU P 15:30 - 17:30 2.00 WHSUR P 17:30 - 19:00 1.50 WHSUR P 19:00 - 21:30 2.50 WHSUR P 21:30 - 00:00 2.50 WHSUR P 7/2/2009 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:00 1.00 WHSUR P 4TION Pa~e 15 c~f 16 nary Report Spud Date: 6/14/1987 Start: 6/10/2009 End: Rig Release: 7/2/2009 Rig Number: , RUNCMP order. RUNCMP Crew change, rig service, derrick inspection. set and test PVT's. RUNCMP M/U 4-1/2", completion jewelry. Break colfars off of 4 joints of 12.6#, 13Cr80, Vam Top joints added below packer, clean and BakerLoc connections. RUNCMP Run 4-1/2" 12.6# 13Cr80 Vam To com letion. Use Compensator and Torque Turn all connections. Used Jet Lube Seal Guard pipe dope. Average M/U torque 4,440 fUlbs. 80 joints in at 00:00 hours RUNCMP Run 4-1/2", 12.6#, 13Cr80, Vam Top completion. Use Compensator and Torque Turn all connections. Used Jet Lube Seal Guard pipe dope. Average M/U torque 4,440 fUlbs. RUNCMP Pre-tour checks and service the Rig. RUNCMP Finish RIH with 4-1/2" Vam Top Gompletion. Ran a total of 188 Joints. Ran 3 ea X Nipples (deepest one with RHC), 3 ea GLMs (upper one with DCK shear valve) and 1 Production Packer. No space out required. Establish final PUW = 103K , SOW = 93K. RUNCMP PUMU Landing Joint and Tubing Hanger with Cameron reps. Land the Tubing Hanger and RILDS. RUNCMP Reverse circulate 120 bbls of 120 degF seawater at a rate of 3 bpm / 175 psi down the IA taking returns up the Tubing. Follow this with 250 bbls of corrosion inhibited seawater at 3 bpm / 175 psi. RUNCMP Drop ball and rod with Baker Packer rep. Allow to fall in the Tubing string. Pressure test the Tubinq to 3,500 qsi for 30 charted mins - aood test. Bleed the Tubina qressure down to - uvua ~esi. i iie ~ uuinu caine uu w c, ivv Nsi uuniiy uie iGS~. Bleed the Tubing pressure off and observe the DCK Valve shear while bleeding the Tubing down. Circulate down the Tubing at 2 bpm / 800 psi and down the IA at 2 bpm / 700 psi to confirm the DCK Valve sheared. RUNCMP PU T-bar and set 4" T e"H" TWC with Cameron rep. Pressure test from above to 3,500 psi for 10 charted mins - good test. Pressure test from below to 1,000 psi for 10 chartec mins - aood test. RUNCMP ND and stack back BOPE. RUNCMP NU McEvoy 13-5/8" x 4-1/8" Adapter Flange and 4-1/8" Tree with Cameron rep. RUNCMP Pressure test Hanger void to 5,000 psi for 30 minutes - good test. Fil! ihe Tree with diesel and pressure test to 5,000 psi for 10 charted minutes - good test with no visable leaks. RUNCMP R/U DSM lubricator and test to 500 qsi. Pull Cameron 4" Type "H" TWC. R/D lubricator. RUNCMP R/U Little Red Services and pressure test lines to 2,500 psi. Pumo 140 bbls of diesel freeze protect down IA takina returns RUNCMP Line up and U-tube diesel freeze protect between IA and Tubing. - RUNCMP Inst ame e"H" BPV and test from below to 1 000 psf for 10 charted minutes. Printed: 7/16/2009 4:48:34 PM ~ ~ Operations Summary Report Legaf Well Name: J-27 Common Well Name: J-27 Event Name: WORKOVER Start: 6/10(2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/2/2009 Rig Name: NABORS 4ES Rig Number: Spud Date: 6/14/1987 End: Date From -'To Hou~s Task Cod~ NPT Phase Descriptian Qf Operations 7f2f2009 02:00 - 03:00 1.00 WHSUR P RUNCMP N/D secondary annulus valve and secure well and cellar. Rig Released at 03:00 hours on 7/2/2009. Printed: 7/76/2009 4:48:34 PM • , ALA5SA OIL A1~TD ricAS CO1~T5ERQATI011T CO1~IIrIISSIOI~T David Reem • 4, SARAH PALIN, GOVERNOR ,. 333 W. 7th AVENUE, SUITE 100 ~"N ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Engineering Team Leader p ~~~ ~~ ~~,, ~ ~ ,~ E~ BP Exploration (Alaska) Inc. `~~`~~" P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU J-27A Sundry Number: 309-172 ~(~ , " ~ ~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum. field inspector at (907) 659-3607 {pager}. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, .~ ~~ Cathy oerster Commissioner DATED this ~ day of May, 2009 Encl. STATE OF ALASKA , ~~ E~,+ ~ V E®,~"~` ALA OIL AND GAS CONSERVATION COM~ION ~ ~ ~'Q APPLICATION FOR SUNDRY APPROVAL ~~ ~~iAY ~ ~ 2009 ~,~ 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensi~~ChOfage ®Alter Casing - - ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -® Development ^ Exploratory 202-200 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21733-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU J-27A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028281 ~ 76.9' - Prudhoe Bay Field !Prudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10574' - 9038' - 10541' 9035' 8410' N/A in Len h fi e M TVD Bu t II e Str tural n r 110' 2 11 11' Surface 2683' 13-3/8" 2 2 4 30 2670 ntermediate 8699' 9-5/8" 8 83 6 70 4760 r n finer 82 ' 7" 8451' - 927 ' 8191' - 8881' 724 10 Liner 2131' 3-1/2" x 3-3/76" x 2-7/8" 8443' -10574' 8185' - 9038' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 9830' -10535' 9029' - 9035' S-1/2", 17# x 4-1/2", 12.6# L-80 8490' Packers and SSSV Type: 9-5/8" TIW 'HBBP' packer Packers and SSSV MD (ft): 8383' 13. Attachments: 14. Wetl Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 30, 2009 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Biork, 564-5683 Printed Na David Reem Title Engineering Team Leader ~ Prepared By NameMumber Signature .y~,, Phone 564-5743 Date ~ /3-0,9 Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~ acf _ ~ rj Z Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity '~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 3s0~ ~Si rG.s-~ ~S~ ~ a ~ Oc'~ps~ r~l•~~..tia ~ c~.+~r~1\,G~~S~ Subsequent Form Required: ~~Oy ~ APPROVED BY S ~~ ` ~~ ` ~~~ ~ ~ L- Z ~ COMMISSIONER THE COMMISSION Date , A roved B : ~ Form 10-403 Revised 06/006 ... _ ~.,~~~~~ w._~~o~ ~i~~i~r~~o~~ Submit In Duplicate Page 1 of 1 Maunder, Thomas E (DOA) From: Bjork, David (Northern Solutions) [David.Bjork@bp.com] Sent: Tuesday, May 19, 2009 9:54 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C Subject: FW: J-27A (202-200) Workover Mr. Maunder, The composite bridge plug (8,410') should fall around 21' before it stops on a coil tubing liner top (8,431'). The 3.0" ID of the coil liner top should hold up the 3.625" plug OD and allow us to drill it up completely. Regards, Dave Bjork 564-5683 From: Reem, David C Sent: Tuesday, May 19, 2009 9:37 AM To: Bjork, David (Northern Solutions) Subject: FW: J-27A (202-200) Workover From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 19, 2009 9:24 AM To: Reem, David C Subject: J-27A (202-200) Workover Dave, Would you forward to Dave Bjork? I don't have his email. In the work procedure, step 6 states to drill out the 4-1/2" composite bridge plug. How far will the BP remains be pushed into the well? Thanks in advance. Tom Maunder, PE AOGCC 5/19/2009 n U by C'~da~3ii'ir~ar J-27a: Expense Rig Workover Scope of Work: Repair production casing leak and replace tubing. Pull old L-80 5-'/z" x 4-%2" tubing, run and cement 7" scab liner, change 9-5/8" pack-offs, re-complete with new 4-'h" 13Cr-80 VamTop tubing and S-3 packer at -8,035' MD. MASP: 2318psi Well Type: Producer Estimated Start Date: May 30, 2009 Production Engineer: Chris Stone Intervention Engineer: David Bjork Pre-Rig Prep Work: F 1 MIT-OA to 1,OOOpsi (may have. an open shoe), CMIT-TxIA to 1,OOOpsi record LLR if necessa and re-test at 500 si if CMIT-TxIA leaks at 1,000 si. E 2 Drift Tubing for PowerJet cutter, the tubing may have a cement sheath. PowerJet cut 4-'h" 13Cr-80 tubing at 8,260' MD, four feet down from the top of the 1 st full joint above the slidin sleeve Reference tubin tall 7-05-87 . F 3 Circulate well with seawater and diesel ca ,recheck CMIT- TxIA. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. Check the IC for lastic ack 'ob. W 5 Set a BPV in the tubin han er. O 6 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU Nabors 4ES. ND tree. NU and test BOPE pipe rams, with 3-'/z" x 6" VBR, to 3,500 psi. Test annular preventer to 3,500 psi. Circulate out freeze protection fluid and circulate well to kill weight fluid through the cut. 2. Retrieve 4-1/z" tubing string down to the tubing cut. 3. Dress off tubing stub. 4. Fully cement 7" L-80 BTC-M scab liner from 2,900' to 8,260'. The 3-'/z" x 6" VBR will NOT be changed to 7" as the barrier to the reservoir will be a tested 4-~/z" Composite Bridge Plug at 8,410' MD and kill weight fluid. 5. Change out 9-5/8" pack-offs, clean out shoe tract and pressure test liner and casing to 3,500psi. 6. Drill up composite bridge plug at 8,410' MD. 7. Run 4-~/z" 13Cr-80 VamTop tubing with Baker S-3 packer and set at 8,035' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3,500psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. I TREE = s" clw WELLHEAD = McEVOY ACTUATOR = AXELSON K'B. ELEV = 76.93' BF. ELEV = 36.55' KOP = 9276' Max Angle = 95 @ 10115' Datum MD = 9274' Datum TV D = 8800' SS 113-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" I • J-27A 7" CSG, 26#, L-80, BTGM, ID = 6.276" 2,900'$,260 - 4-1/2" TBG, 12.6#, 13G-80, VamTop -8,035' 4-1/2" BKR LNR TOP PKR S OTES: 2000' 4-112" HES 9Cr X-Nip, ID=3.813 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3802 3800 0 KBG-2 DCK 2 6002 6000 0 KBG-2 DMY 3 7923 7754 33 KBG-2 DMY - 2,900' 9-5/8" x 7" ZXPand Flexlock Hanger 8,003' 4-1/2" HES 9G X-Nip, ID=3.813 ~ 8,035' 7" x 4-1/2" Baker S-3 Packer ~ 8,065' 4-1/2" HES 9Cr X-Nip, ID=3.813 / $307' BKR L SLIDING SLV, ID = 3.813" $36$' TMJ SEAL ASSEMBLY IN PBR ~ 8383' 9-5/8 TNV HBBP PKR, ID = 4.750" 8388' 7" MILLOUT EXTENSION, ID = 6.00" - 8393' 7-5/8" x 4-1 /2" XO, ID = 3.956" - $424' 4-1/2" OTIS X NIP, ID = 3.813" 8443' I~ 3.75" BKR DEPLOY SLV, ID = 3.00" TOP OF 7" LNR Minimum ID = 2.372" @ 9358' 3-3/16" X 2-7/8" XO 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 19-5/8" CSG, 47#, L-80, ID = 8.681" I 13-1/2" LNR, 8.81#, L-80, .0081 bpf, ID = 2.880" I I TOP OF WHIPSTOCK RA TA G PERFORATION SUMMARY REF LOG: MCNL/CCL/GR ON 11 /15/02 ANGLE AT TOP PERF: 89 @ 9830' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9830 - 9880 O 11/15/02 2" 4 10310 - 10535 O 11/15/02 PBTD 9651' 17" LNR, 26#, L-80, U4S, .0383 bpf, ID = 6.276" I $456' ~4-1/2" OTIS X NIP, ID = 3.813" (BEHIND CT LNR) 845 3-1/2" HES XN NIP, ID = 2.750" I4-1/2" WLEG (BEHIND CT LNR) I 3-1/2" X 3-3/16" XO, ID = 2.800" MILLOUT WINDOW (J-27A) 9279' - 9286' 9358' 3-3/16" X 2-7/8" XO, ID = 2.372" 10541' I~ PBTD 3-3/16" LNR, 6.2# L-80, .076 bpf, ID = 2.800" 12-7/8" LNR, 6.16#, L-80, .0055 bpf, ID = 2.372" I DATE REV BY COMMENTS DATE REV BY COMMENTS 06/87 ORIGINAL COMPLETION 12/13/08 MBM/SV PULL XX PLUG & RED (12/04/08) 11/16/02 JLM/KK CTD SIDETRACK J-27A) 01/14/09 JKD/SV SET PLUG/TBG PCH (01/05/09) 02/27/03 GC/KAK ADD BKR LNR TOP PKR 01/14/09 /SV CORRECTIONS (MO EXT) 05/07/06 TWS/PAG PULLED PX PLUG (05/05/06) 01/15/09 DMS/SV CMT SHEATH (01/14/09) 03/16/08 JIM/TLH SET PX PLUG (03/09/08) 10/16/08 GJF/PJC PULL PX/SET XX&RED (09/28/08 PRUDHOE BAY UNIT WELL: J-27A PERMIT No: "2022000 API No: 50-029-21733-01 SEC 9. T11N. R13E, 800' SNL 8 1771' WEL BP Exploration (Alaska) I TREE = s" cM/ WELLF~AD = McEVOY ACTUATOR = AXELSON KB. ELEV = 76.93' BF. ELEV = 36.55' KOP = 9276' Max Angle = 95 Q 10115' Datum MD = 9274' Datum TV D = 8800' SS • J-27A 2064' I-I CAMCO SSSV LANDING NIP, ID = 4.562" 5-1/2" TBG, 17#, L-80 BTRS, .0232 bpf, ID = 4.892" 13-3/8" CSG, 72#, L-80 BTRS, ID =12.347" I-~ CEMENT SHEATH, ID = 3.79" (01/14/09) 7gg7' Minimum ID = 2.372" @ 9358' 3-3/16" X 2-7/8" XO TUBING PUNCH (01/05/09) 8364'-8: 4-1 /2" BKR LNR TOP PKR I TOP OF 7" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 3-1/2" LNR 8.81#, L-80, .0081 bpf, ID = 2.880" TOP OF WHIPSTOCK RA TAG PERFORATION SUMMARY REF LOG: MCNUCCUGR ON 11/15/02 ANGLE AT TOP PERF: 89 ~ 9830' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9830 - 9880 O 11/15/02 2" 4 10310 - 10535 O 11/15/02 I PBTD H 9s51' 7" LNR 26#, L-80, U4S, .0383 bpf, ID = 6.276" 9697' 5-12" X 4-1/2" XO GAS LIFT MANDRELS 4 5397 5249 1 OTIS DMY RM 3 7022 6921 23 OTiS DMY• RM 2 8036 7791 34 OTiS DMY*" RM 1 8196 7850 35 OT1S DMY" RM * STATION #s 1, 2, 3 =DMY HAS EXTENDED PA '"'"' STATION #s 1, 2 =BEHIND CEMENT SHEATH 8307' BKR L SLIDNVG SLV, ID = 3.813" 83s8' TNV SEAL ASSEMBLY W PBR 8383' 9-5/8 TM/ HBBP PKR ID = 4.750" 8388' 7" MILLOUT EXTENSION, ID = 6.00" 8393' 7-5/8" x 4-1/2" Jam, ID = 3.956" 8410' 4-1/2" HES FASDRILL (01/05/09) 8424' 4-1/2" OTIS X NIP, ~ = 3.813" $443' 3.75" BKR DEPLOY SLV, ID = 3.00" $456' 4-1/2" OTiS X Nom, ID = 3.813" (BEHII 8458' 3-1/2" HES XN NIP, O = 2.750" 8490' I-14-1/2" WLEG (BEHIND CT 0 04/01/04 0 05/06/06 0 07/16/07 0 05/06/06 CT LNR) 9230' H 3-112" X 3-3/16" XO, ID = 2.800" I MILLOUT WNVDOW (J-27A) 9279' - 9286' \ 9358' 3-3/16" X 2-7/8" XO, ~ = 2.372" 10541' H PBTD I l 3-3/16" LNR, 6.2# 9358' L-80, .076 bpf, ro = 2.800" 2-7/8" LNR, 6.16#, L-80, .0055 bpf, O = 2.372" DATE REV BY COMMENTS DATE REV BY COMMENTS 06187 11/16/02 JLM/KK ORIGINAL COMPLETION CTD SIDETRACK J-27A 12/13/08 01/14/09 MBM/SV JKDISV PULL XX PLUG 8~ RED (12/04/08 SET PLUGliBG PCH 01/05/09 02127/03 05/07/06 GGKAK 7WS/PAG ADD BKR LNR TOP PKR PULLED PXPLUG (05/05J06) 01/14/09 01/15J09 /SV DMS/SV CORRECTIONS (MO EXi) C SHEATH {01/14/09) 03/16!08 JIMlTLH SET PX PLUG 03/09/08 10!16/08 GJF/PJC PULL PX/SET XXB~RED (09/28/08 PRUDHOE BAY UNR WELL: J-27A PERMIT No:'2072000 API No: 50-029-21733-01 SEC 9, T11N, R13E, 800' SNL 8 1771' WEL BP Exploration (Alaska) ~"~ ~ '' ~~~ STATE OF ALASKA ~ ~ ~ -S ~~, ~ ALA~OIL AND GAS CONSERVATION COM Fyl ~Cl REPORT OF SUNDRY WELL OPE ONS t~,r~-r~ission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ ~ Other ~ PACKER SQZE Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ ~~~'~ Waiver~tC~~~ Extension FAILED Change Approved Program ~ Operat. Shutdown ~ Perforate ~ . Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 202-2000 3. Address: P.O. Box 196612 Stratigraphic Senrice ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21733-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 76.9 KB - PBU J-27A - 8. Property Designation: 10. Field/Pool(s): _ ADLO-028281. PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10574- feet Plugs (measured) 8410' true vertical 9037.84 _ feet Junk (measured) None 1 '`1"'~ ~~,#~ ~,y~®y@~ r'~ j~ Effective Depth measured 10541 feet c s s true vertical 9035.33 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 30 - 110 30 - 110 Surface 2683 13-3/8" 72# L-80 29 - 2683 29 - 2683 5380 2670 Production 8698 9-5/8" 47# L-80 28 - 8698 28 - 8398 6870 4760 Liner 828 7" 26# L-80 8451 - 9279 8191 - 8881 7240 5410 Liner 799 3-1 /2" 8.81# L-80 8431 - 9230 8175 - 8841 10160 10530 Liner 1216 2-7/8" 6.16# L-80 9358 - 10574 8938 - 9038 10570 11160 Liner 128 3-3/16" 6.2# L-80 9230 - 9358 8841 - 8938 8520 7660 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 30 - 2092 4-1l2" 12.6# L-80 2092 -8490 Packers and SSSV (type and measured depth) 9-5/8" TIW HIBBP PKR 8383' 4-1/2" BKR LNR TOP PKR 8431' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~~ Service 1° Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~' Gas WAG r 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: 308-408 Contact Gary Preble Printed Name Gary P ~ e Title Data Management Engineer Signature Phone 564-4944 Date 3/26/2009 .,.,,, ,., ,.,~~.....,~._.,.,., . _. __ ~ ,~'=.~`4 to '~Q[4 .._ 3.,... J-27A 202-200 PERF OTTOCHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base J-27A 11115/02 PER 9,830. 9,880. 9,029.06 9,029.83 J-27A 11/15/02 PER 10,310. 10,535. 9,032.21 9,034.99 J-27A 9/28/08 BPS 8,388. 10,535. 8,138.94 9,034.99 J-27A 12/4/08 BPP 8,388. 10,535. 8,138.94 9,034.99 J-27A 1/5/09 APF 8,364. 8,366. 8,119.12 8,120.77 J-27A 1/5/09 BPS 8,410. 8,412. 8,157.15 8,158.8 J-27A 1/13/09 SQZ 7,787. 8,410. 7,641.87 8,157.15 J-27A 2/21/09 SQF 7,787. 8,410. 7,641.87 8,157.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • J-27A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/4/2009"""WELL SHUT-IN ON ARRIVAL"*** ;RIG UP E-LINE TO SET FASDRILL AND SHOOT TUBING PUNCH. ***JOB CONTINUED ON 5-JAN-2009**' 1/5/2009;***JOB CONTINUED FROM 4-JAN-2009''** ?CONTINUE RIG UP E-LINE. SET 4.5" HALLIBURTON FASDRILL BRIDGE PLUG @ 8410' MD (TOP OF PLUG) MID ELEMENT = 8411', PLUG LENGTH TUBING PUNCH 9 HOLES FROM 8364'-8366'. CORRELATED TO PDS TECWEL LDL DATED JUNE 21, 2008. WELL SI ON DEPARTURE: FINAL WHP 50/0/100 *''''JOB COMPLETE**'' 1 /11 /2009 CTU #9 w/1.75"CT Job Scope :PKR SQZ «InterAct Publishing» RIH Iw/1.75"BDN and choke closed build up WHP and IA pressures to 500 psi and 'bleed to check for gas. (none) Continued in hole and closed choke to build pressure from penetration of coiled tubing and manipulate CT speed to establish LLR Tag plug at 8413', down , 8410' up, PU to 8390' .paint white & yellow flag ;.Begin mixing Cement . **" Job Continued on 01/12/09**'" ___ _.,._~ _._._ ~ _ _ _ _.....____w____ _ _ __ 1/11/2009 T/I/0=80/0/50 Temp=S1 Circ-Out TxIA (Pre Squeez). Pumped 5 bbls meth, 700 bbls crude down IA thru cut @ 8380' up Tbg taking returns to flowline. Freeze ..protected flowline per WOA recipe. Final WHPs 0/0/200 `SV,WV,SSV= shut MV,IA,OA 1/12/2009 Assist CTU as directed. Job cancelled 1 /12/2009 CTU #9 w/1.75"CT, Job Scope :PKR SQZ «InterAct Publishing» Continued from 1/11/09. LMix 4.2 bbls of 15.8# cement. Saueeze 2.5 bbls into IA, POOH at coil displacement. Wait on cement to build to a min of 500 psi compressive strength. Open well to RIH and IA immP~~atPiy ~p~n n~~, Played around by pumping no more then 0.5 bbls alternating between the IA and tubing. Resulting in deffinent comunication. RIH w/ 1.75" JSN wash down from 8130' with biozan and tapped hard cement at 8364 cfmd chased biozan OOH @ 80% to surface. MU &RIH 2.0' BDN , infection in IA started 0.5 bpm at 1400 psi then broke back to 1 bom at 600 ~s%"*"'Job continued on 1/13/09**"* 1/13/2009 CTU #9 w/1.75"CT, Job Scope :PKR SQZ «InterAct Publishing» Continued from 1/12/09.. Rig up SLB cementers. Mix 5 bbl of 15.8# cement ,squeezed - '4 bbls behind pipe. POOH Compressive straingth up to 500 psi. Conducted "lite PT on cement and had comunication between ti~bin ag nri IA. RI w 1.75' JSN found cement top @ 7997 ctmd. Called town APE's and discussed options. POOH. MU &RIH 3.790" OD 5 blade mill. *"*Job continued on 1/14/09*** • • 1/14/2009 CTU #9 w/ 1.75 CT Job Scope .• PKR SQZ « InterAct Publishing» Job continued from 1/13/09 Milled cement from 7787' to 8407' CTDM millin Istarting to show signs of eing on top of composite plug PUH and called to '1'7~FEGe~ore conl`inuing~i c'I~mposite plug. Decision was made to MIT Test failed. LLR was established by holding WHP/CTP/IAP steady with RO 13 fpm for 5 min CT displacement = .00298 bbls / ft =.0387 bbl/min = 1.62 gal/min Established TxIA LLR of .35 bpm 1600 psi then pressure dropp holes were opening up, increased pump rate to establish LLR of .75 bpm @ ~~i. eceived call from CT scheduler that meeting with BP manageme ;team had been canceled. Called town APE with information decision was to leave composite as is. POOH and freeze protected tubing from 2500'. with face of 3.79" OD mill showing signs that it was on the composite plug. _ _ left S/I **"Job Com let~~.__ 1/28/2009 *"" WELL S/I ON ARRIVAL*** (post packer squeeze) DRIFT CMT SHEATH W/ 3.77" CENT, SAT DOWN Cad 8340' SLM (needed ~=8410' MD EHELD BP SAFETY STAND DOWN ;SSV ACTUATOR NEEDS REPAIRS, RDMO. "JOB IS NOT COMPLETE* *"" WELL S/I ON DEPARTURE'"*'" s wn TxIA P@ 5 ed like nt made OOH Well 1/29/2009 "*" WELL S/I ON ARRIVAL**'' (post pkr squeeze) *** SSV SEALS DO NOT HOLD - VLV IS NOT OPERATIONAL *"* DRIFT THRU CMT SHEATH W/ 5' x 3.00" P-BAILER SD/TAG FASDRILL PLU 386' M 410' MD RECOVERED HALF GAL OF CMT IN BAILER. *'`* WELL S/I ON DEPARTURE, PAD OP NOTIFIED **" 2/5/200 T/I/O = 1Nac/90. Temp = SI. Monitor WHPs, T & IA FL. Grease crew pumped open SSV, dumped on departure. T FL @ 204' (4.8 bbls). IA FL @ 96' (4.2 bbls). ,SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 2/18/2009?***TECWELL LDL, SCMT*** JOB POSTPONED DUE TO WEATHER NEVER RIGGED UP TO TREE ~SSV CLOSED ON DEPARTURE I*"*JOB INCOMPLETE**" 2/18/2009'T/I/O=0/0/0 Assist E-Line, LDL (Pre Cement Squeeze). No Fluids pumped. ~JOb cancelled due to weather. 2/19/2009LRS T90 Tanker support for LDL. ~. 2/19/2009 2/20/2009 -.~..._. ""*TECW ELL LDL, SCMT*** WELL SHUT IN ON ARRIVAL HARDLINE, SCAFFOLDING, TANK INSTALLED PRIOR TO ARRIVAL ""*JOB CONTINUED ON 20-FEB-09"** T/I/O=0/0/0 Assist E-Line with LDL's. (Cement Squeeze) Standby for decrease in wind speed. LDL Step One: Pumped 394 bbls dead crude down Tbg taking returns up IA while maintaining 2000 psi on Tbg @ 1.3 bpm. LDL Step Two: Maintained 3000 psi on Tbg and IA in closed system while E-Line ran LDL . *""WSR continued on 02-21-09.*** j r i 2/20/2009'**"JOB CONTINUED FROM 19-FEB-09*** TECWELL LDL, SCMT _ ~ INITIAL T/I/O = 0/0/0 STANDBY TIME DUE TO WAITING ON WIND. FPRESSURE ON TUBING 2000 PSI, LEAK RATE OF 1.3 BPM. LEAK FOUND AT TUBING PUNCH AND PACKER. E SURE UP ON TUBING AND IA TO 3000 PSI. """'JOB CONTINUED ON 21-FEB-09""" I 2/21/2009 """JOB CONTINUED FROM 20-FEB-09**'" ~~' TECWELL LDL, SCMT ` PDS FOUND IA TO ' i DOWN. SLOGGED SCMT BOND LOG FROM 8389'-7875'. CEMENT AT PERFORATION INTERVAL 8364'-8370' WITH ZERO ISOLATION =T0 PACKER TOP AT 8383'. FREE PIPE ABOVE 8360'. POSSIBLE ~ STRINGERS AT/BELOW SLIDING SLEEVE AT 8307. TREE CAP INSTALLED WITH NEW O-RING AND VALVES LEFT PER DSO. ;FINAL T/I/O = 0/0/0 I F'"'"'"JOB C OMPLETE*"* ~ _ ? _ _ _ _ _ __ __ ~ 2/21/2009T/I/O=0/0/0 Assist E-Line (LDL) Maintained 3000 psi on IA and Tbg while E- ' Line made logging run. FWHP's=0/0/40. E-line in control of well @ LRS dep. IA ~ 1 & OA=OTG. ~ BBLS 6 Diesel 1 Meoh 17 Meth 1546 XS 1 %KCL 344 60/40 METH 9 15.8# CEMENT 40 2% XS KCL 60 BIOZAN 150 1%KCL 80 GEOVIS 2253 Total 03/18/09 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~ ,, - Anchorage, AK 99503-2838 „_;; L *~.~yj„~ ,~~r~ , , ~,,; ,~_ ~ //^^~~ ATTN: Beth t~~ ~~ 1. =~~ ~ Well .Inh fk :.... n..~...:w:.... N0.5133 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Qi '~" y „~tl~}5~'l~~e' ~~ ;`) •, ~... .,,~~ alb a~ ~~~~ J-27A AY3J-00010 CBL - -- -----( _-_ 02/21/09 1v~ 1 S-107 AWJB-26 MEM L L V ~ ~- 02/25!09 1 1 09-34A AZ4D-00005 USIT (REVISED) - 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE ' 02/23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE . _ (b ~ 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) jf . C ~ 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / C/ 03/02/09 1 1 B-25 AVYS-00023 USIT - /'~' /~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG p~- /'~5 ~- - 03/11/09 1 1 F-18 AVY5-00022 USIT ~ •- ~"~ =' _ '~- ~ 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL ~ - 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-211 AY3J-00014 IPROF/RST WFL - ~ 03/16/09 1 1 V-214 AY3J-00013 IPROF/RST WFL --T - ~ 03/15/09 1 1 K-068 AWJI-00017 MCNL ~ - 01/28/09 1 1 L5-15 12113027 RST - /O ~''} / • 12/09/08 1 1 07-18 12071915 RST ~j (~ 12/01/08 1 1 15-15C AWJI-00015 MCNL _ / 01/02!09 1 1 W-218 40018337 OH MWD/LWD EDIT 12!07/08 2 1 R-41 40018496 OH MWD/LWD EDIT ./5 ( 01/04/09 2 1 H-18 11999064 RST / - ~ 1 ~- 12/03/08 1 1 . •_-•-_••••~..~~...,... ..~...-.. . v. v.v..n.aa r~..u nGl Vnn11\V V19G VVrt GNVn I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: c. ~ ~ r2Gt ~ eca~ 3 ~a! ~ 3 t ~" . s ~ Copy ~` Alaska Data & Consulting Services 2525 Gamt>eII Streq.,3urte-400-- Anchorage, AK ~,!~tQ~~2838 q ' ri ,.m ._; _ ATTN: Beth ' Received by: ~ ~ ~ ,~ ') (7; ;Q} gt9 Y A__ i • • WALL L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTf) The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe lastufka LR2-1 900 Benson Bhid. Anchorage, Alaska 89508 and ProActive Diagnostic .Services, Inc. Attn: -~Aobert~`chey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: [907) 245~B952 l g~ -/~~/ ~a -~ !~ ~3~ 1 ~- C~lU 1) Coil Flag 16-Feb-09 18-26A EDE 2) Leak Detection - WLD 20-Feb-09 J-27A Signed Print Name: 50-029-22329-01 1 Color Log / EDE 50729-21733-01 Date - - PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL: ?i~~~3'~?s3s"B~1~479i°S7a~'~'f3i~~J~.-C3i3 WEB$ITE:bL•"iVi~:.~d73F'J?3L3a~.~~-~'3 ~~ C:\Documenffi and Settings\Ow~,~DesktoplTransmit BP.docx • D 0 ~ a o SARAH PAL/N, GOVERNOR r 4iI0-7~~ O~ ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~SERQ~'1`IOAT COl-II~IISSI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Chris Stone FAX (907) 276-7542 Pad Engineer BP Exploration Alaska Inca. a.~,`^~~~u; ,~~`~ ~ ~~~~~~ ~~ ~~~~~ ~. PO Box 196612 • Anchorage, AK 99519-6612 '~,d~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-27A Sundry Number: 308-408 Dear Mr. Stone: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of November, 2008 Encl. Sincerely. _,• //-/~~ ` `O . STATE OF ALASKA 4\ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ - ~' ~ ~~~C ~ ~,`~ ~ \0 V APPLICATION FOR SUNDRY APPRQVAL ~,~\~~ 2n aAC ~s pan ~ ~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ^ Repair well 0 Plug Pertorations^ Stimulate ^ Time Extension ^ PACKER REPAIR Change approved program^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory ^ 202-2000 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21733-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU J-27A . Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028281 ~ 76.9 KB ~ PRUDHOE BAY Field / PRUDHOE 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): 10574 i 9037.84 ~ 10541 9035.33 8424' NONE Casing Length Size MD TVD Burst Collapse Conductor 140 20" 30 110 30 110 Surface 2712 13-3/8" 72# L-80 29 2683 29 2683 5380 2670 Production 8726 9-518" 47# L-80 28 8698 28 8398 6870 4760 Liner 17730 7" 26# L-80 8451 9279 8191 8881 7240 5410 Liner 17661 3-1/2" 8.81# L-80 8431 9230 8175 8841 10160 10530 Liner 19932 2-7/8" 6.16# L-80 9358 10574 8938 9038 10570 11160 Liner 18588 3-3/16" 6.2# L-80 9230 9358 8841 8938 8520 7660 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L-80 30 - 2092 - - 4-1/2" 12.6# L-80 2092 - 8490 Packers and SSSV Type: 9-5(8" TIW HIBBP PKR Packers and SSSV MD (ft): 8383' 4-1/2" BKR LNR TOP PKR 8431' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development 0 - Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/25/2008 OIL Q, GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Stone Printed Name Chris a Title Pad Engineer Signature done 564-5518 Date 11/11/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: g- ~"v~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ``7~ ~ (~~ r ~ ~~1 Other: 35~~:' 1 ~ (` y C Subsequent Form Required: APPROVED BY /~,/ ~~ S ~ Approved by: COMMISS NER THE COMMISSION Date: ` ~VI111 IV-'fVJ nCV1ACU vV/GVyU /. `~/ p V JUUl1111111 vuFlllualc J-27A 202-200 PFRF ~TTO[:HMFNT Sw Name- Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base J-27A 11/15/02 PER 9,830. 9,880. 9,029.06 9,029.83 J-27A 11/15/02 PER 10,310. 10,535. 9,032.21 9,034.99 J-27A 9/28/08 BPS 8,424. 10,535. 8,138.94 9,034.99 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SOUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE by ~ ~ To: C. Olsen/J. Bixby Date: October 31, 2008 GPB Well Ops Team Leaders From: Chris Stone AFE: PBJPDWL27-N J-Pad Production Engineer Est. Cost: $175,000 Subject J-27A Packer Repair IOR: 225 bopd Sten Tyne Summary 1 S Pull PX plug & nipple reducer at 8424', set Composite Bridge Plug, and shoot tubing unches. 2 F Circulate tubin and IA 3 C Perform cement acker re air and mill cement and com osite lu . 4 F WOC 3 da s and erform a MIT-IA to 3000#. Current Status: Last Test: Max Deviation: Min. ID: Last Downhole Ops: Latest Tag: Latest H2S level: Objective SI -TxIA Communication 3/14/04: 773 bopd, 32.0 MMSCF, 41,397 GOR -95° @ 10,115 MD 3.372" @ 9,385' (3-3/16" x 2-7/8" XO) 9/28/08: TecWel LDL 3/9/08: Liner Top @ 8,431' MD No Samples Available The objective of this intervention is to repair the leaky packer and packer seal bore assembly. A Halliburton composite bridge plug will be set at 8410' MD. Tubing punches will then be shot in the tubing from 8365' - 8367'. The tubing and IA will be circulated to dead crude. Cement will be circulated into the IA thru the tubing holes. The remaining cement in the tubing and the composite bridge plug will be milled up when the cement develops 500 psi compressive strength (-5-7 hours, cement samples from lab will be used for time determination). A MIT-IA will be performed to determine the success of the squeeze. Well History J-27A is a 2002 CTD sidetrack producing thru the original completion with L-80 tubing. In early 2004 the well failed a TIFL, failed a MITIA, and was SI and secured with a PX plug at 8424'md. The PXN was pulled after failing a drawdown test, and finally a LTTP was set and successfully CMIT-TxIA tested proving packer and casing integrity. A 5/05/2006 caliper shows the tubing to be in good to poor condition (max wall penetrations 20-51 %) in the form of isolated pitting and general corrosion. A recent Tecwel LDL found the TxIA leak to be at 8379', leaking from the tubing to IA through the upper packer seals. During the LDL the tubing was pressured to 3000 psi with an open bleed on the IA. No returns were taken from the IA due to a 30 bbl void and only 25 bbls pumped away. Recently, 8/22/08, aCMIT-TxIA passed to 2500 psi, verifying that the packer seal elements were holding and the TxIA communication was thru the seal assembly. In preparation for setting a patch across the seal assembly slickline attempted to set a nipple reducer and plug in the X nipple at 8424' MD during the time frame from 9/23/08 - 9/28/08. The well kept failing CMIT-TxIA upon setting the nipple reducer and plug, in an attempt to determine the failing mechanism a memory TecWel LDL was run. While pressured 1 • ~J up on the tubing and the inner annulus the LDL found the source of the failed CMIT-TxIA to be thru the packer, a LLR of 0.2 bpm at 2500# was established during the failed test. To avoid all doubts as to the nature of the leak a packer repair using cement will be performed to return the well to an operable condition. AnnComm History > 03/23/04: TIFL Failed on BUR > 04/01/04: DGLV > 04/03/04: TIFL Failed on BUR > 04/13/04: DGLV #5, MIT-IA Failed > 04/15/04: TTP set C~ 8424 MD > 05/06/06: Caliper 5.5" 23 jts. 20 to 40% and 3 jts. 40 to 85%; 4.5" 98 jts 20-40%, 13 jts 40-85% > 05/07/06: Set CatSV > 05/07/06: Set DGLV > 05/09/06: MITIA Failed (tubing tracked IA), CMIT TxIA Passed to 3000 psi > 05/23/06: Pulled CatSV > 07/06/07: MIT-OA Passed to 500 psi w/ N2 > 07/16/07: Set ext packing DGLV in sta #2 > 07/20/07: MIT-IA Failed > 03/09/08: Set TTP @ 8424' > 06/22/08: TecWel LDL indicates leaking TIW packer @ 8379' > 08/22/08: CMIT-TxIA Passed to 2500 psi > 09/23/08: Pull TTP from 8424' > 09/24/08: Set nip reducer 8424' Set TTP C~ 8424' CMIT-TxIA Failed to 2500 psi w/ LLR = 0.2 bpm > 09/29/08: LDL finds leak Q packer 8383' cc: Well File 2 • Cement Volume in Tubing (8410' - 8337') x 0.0152 bbl/ft = 1 bbls Cement Volume in Annulus (8383' - 8337') x 0.054 bbl/ft = 2.5 bbls Total Cement to Pump 3.5 bbls • 2092' - 5-1/2" x 4-1/2" XO 8196'-GLM#1 8307' - BKR Sliding Sleeve 8337' - TOC 8365' - 8367' -Tubing Punches J-27A Packer Repair 'JW 4 •~ ,. 8368' -TIW Seal Assembly 8383' - 9-5/8" TIW HBBP PKR 8410' -Composite Bridge Plug 8698' - 9-5/8" Casing • ~ slickline J-27A Packer Repair Procedure 1. RIH and retrieve 4-1/2" PX plug and nipple reducer at 8424' MD. 2. RIH and tag liner top packer at 8431' MD. Flag slickline, depths will be used for correlation of setting composite bridge plug. 3. Pick up a Halliburton Composite bridge plug. RIH, correct depth to slickline flag, using a-fire set immediately below the HBBP packer in the first full joint of tubing at 8410' MD, note setting depth should be top of plug. Reference log is the PDS TecWel LDL run 6/21/08. 4. RIH and punch tubing from 8365'-8367' MD using a 1-11/16" two foot gun (mid-pup joint). Tag the composite bridge plug for use as a depth reference. Fullbore 5. Using dead crude, establish circulation down the tubing taking returns up the IA. Coil 6. Rig up coil with a cement nozzle and RIH. Tag the composite plug at 8410' MD. Pickup until full string weight is observed. Ensure that pumping can be established down the coil while taking returns out the IA. 7. Batch mix 3.5 pumpable barrels of 15.8 ppg unislurry cement which will give 500 psi compressive strength 5-7 hours and 2000 psi ultimate compressive strength. Temperature at cement depth should be approximately 190 °F. - Catch a sample of cement for QC testing. (The sample needs to go to the lab to know when the blend should reach the right strength. Lab must be notified prior to job.) Once the blend is approved, line-up cementers to the coil. - Ensure that there is no gas in the tubing or IA. Do not proceed with the repair unless the tubing and IA are liquid packed. 8. Line out the cementers to the coil. Pump the following down the coil: - 10 bbls spacer water - 3.5 bbls Unislurry cement - Coil tubing volume of water - With the coil tubing-by-tubing annulus open and the IA closed, pump 10 bbls of spacer water out the coil followed by 3.5 bbls of cement. Pump approximately 100' of cement above the coil nozzle, and pull up hole, laying in the remaining cement 1-for-1 in the tubing. SAFETY: 3.5 barrels of cement will extend up the tubing to 8180' MD (230' above the composite plug at 8410'MD). 9. When 3.5 bbls of cement are displaced to tubing pull up hole to 100' above safety. Shut in the coil tubing-by-tubing annulus and open up the IA. At minimum rate pump 2.5 bbls down the coil while taking 2.5 bbls of returns out of the IA (This will place 2.5 bbls of cement in the IA above the packer). Close in the IA valve and begin POOH with coil while replacing coil tubing volume to maintain a balanced well bore. 10. Block in everything at the surface and ensure all valves are holding. • • 11. Wait until lab sample reaches 500 psi compressive strength. (This should take about 5 to 7 hours so do not rig down.) Rig up with motor and mill to mill up cement and the Quick Drill Composite Plug. - Note: Use Halliburton guidelines for milling the composite plug and cement retainer. 12. Drift coil to below perfs to ensure perfs are clear of debris. POOH and freeze protect the tubing. RDMO. Post Packer Squeeze Fullbore 13. After 3 days of WOC, MIT-IA to 3000 psi. If the MIT-IA fails establish a leak rate. If you have any questions or concerns regarding this program, please contact Chris Stone at 564-5518 (work) or 440-4011 (cell). • • ~i 6 '~_~ ~7 :~~e~-~-max ~~~ ~, Au+~z ~ ~ _ ass .~r~.3:~ • • _ , . , ._. - ~ - . ~ r -- ~ ~ - ~ _, ~. _ _ ~ ~ i TecWel Leak Detection Log _ - ~~_- . ~ ~ _ ~_j 21-June-08 ~ t---i ,~ : ~ r ~ I ~' ~ r ~ _ - ~. _ _ + ' -- - - - -- - - - 8300 __..:-.. ~~ i-- ~ Sliding ~ L .: _. 1 _ +. ,_ ..~_ ~ ~?t"- Sleeve ~. ; , ~ ~ ~--- r_ - -r-~-- }-.._.__ ... _ . _ _ ._--1- ~ ~ - -- - - - ~ I f ~ 't _~- ~ , ~ .. ' t ~ } ° `'r -~ i- ~ ~ 1~~ ~ ~ ~ ~c~ --• ,~ - i ~~li~ I _ , Y_ ~ _ . ~ -__ ~ 1 _---_ k . - I _ _ i _ ---~--- _. i ~. ~~! :, _, f ';:''s'4,,.p n ~3~~~-j~3b~' ~t~btNb~~iJGaFE~ ~ - -~ .~ ~ ~ ~ l _ __ T , _~: ~~~ -~ - - _; r. ~_ .. I ! ~t~lta...1- tssei~-~~' eak Signature=-~--- _ ~. j . r. - ~ ... ; r <' J s _ - 8400 ~ _ . i . _-.,_~- ~' '- _Li# ~ ~_ _J _.. -- r $Ul0 Co~c7oi ~c8~~., otE,'~; C7C3~- '~ ~ . - :~ - --=-=~ t t --_.__ _ - _ ~ ~, -r ~ , - ~ --f- - ..~ ~ -j _ - - -- ~ _.. -_! _ ~ -.. ~ 1 ~~ i0 __........._...... - WLD-A __.. . _ '. j----- --- __ 4e+00~ 0 Head Tension {fb) 600 ! -- ---- I - _ -- _. Line Speed {ftlmin) -200. 0 YVLD-B 4e+008; 00 CCL -975; 0 ----- ._ t~A..D-C_ _. 4e+006 Temperature {degF) 240 180 Temperature {degFj 200 _'a f"lipua+fiol Tnmr+orohrra liloi.F1 1 7 . ~' TecWel Leak Detection Lo g ` ` 28-Sep-08 r ---. :~ , i i • ~ i ,~ ~ - __ - S .~ i i I. .~-.~____. ' _.__-- ~ ~ ~ _ _.-___ _-. _.. --- i • }• ~ j I ~ - ~. -. .. _.. _..- l l 1 I - l , ~ , ~ .' !L ~3 r ' 8300 ~ . : ~. ~ - --- -- -- _ ---- -- - _ __-_. -- ---- ._. ... ~ Sliding ?' Sleeve t CCL i I . -- - -. ___ _ ~~ Line Speed i c Temperature -- ~~- Temperature' ` -- ~ _ ' a ~ (; t ~ ; _ Seal Assy ~ ; ! ' Differential Temperature •~, i ! ~ - I a - -• - Packer .. ~ ~, _ ~ ~ - --Leak Signature• - •. "- f - _. ~ ~ ~ I ~ -=>? - ---. r; • _~ ~~ _ r r..._:; i - _ _ __ - __ 8000 CCL -865 i i 0 WLD-.A 4e+00B 0 Line Speed Iftrmin} -200 0 'NLD-B 4e+006 40 Temperature (degF} 2ao o WLp-C 4e+006 K mc~ c a' rmnr Wf3LHEAD= McEVOY ACTUATOR = AXt3SON KB. F3_EV = 76.93' BF. B-EV = 36.55' KOP= 9276' bhaxAngle= 95 {d3t0i15' DaWmMD- ~ 9274' DaWmND = 8800' SS 1 5-112' BUTT 78G, 17#, L-8D, .D232 bpf, ID = d. ~2' 1 13"3/8' t SG, 72#. L-80, BTFZS. D =12.347" H 268 Minimum 1D = 2.372" @ 9358' 3-3116" X 2 718" XO A J -27A SAFEfY"°TES: - 1 ® 2064' CA MCO SSSV LANDNG NfP; D = 4.562' I 2492' I GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3202 146 3 OTLS DMY FAA 0 04113/04 4 5397 5249 1 OTFS DMY FtM 0 04/07104 3 ozz szt 23 oT~ DMV• RM D osro6lDs 2 $036 791 34 OTkS DMY" RM 0 07116rb7 1 6196 $50 35 OTIS DMY' RM 0 0510610fi - a r H ~ rvrv as ~~, c, s = um r rwa r~ ~ wur:u rn~.nima PERFOFiATgfJ SUf4tYlARY FIEF LOG. INCFi,'CCL,'GR ON 11/15/02 ANGLEAT TOPPERF: 89 (c~ 983D' Note: Refer to Floducdon l)8 for historical pert data SIZE SPF INTEFSJAL OpnlSgz DATE 2' 4 9830 -9880 C. 11115!02 2" 4 103? 0 - 10536 C t 1115/02 !TOP OF 7' LNR I"1 8451' 12.6#, L-8D, .0152'. bpf. ®= 3.958" $490' ;'-518' CSG, 47#, L-B0, ID = 8.68i" 8698' 8.81#, L-80..0087 bpf. D = 2.880' 9230' SEAL ASSE3utBLY N PBR R TFN F168P PKR. ®= 4.7'_ tF443- s.ra-nnttutnurmrrt~ sLV.v=~.uu- 8456' 4-1iT OTIS X NP, D = 3.813" (BB~tlND CT LNR~ $458' 3-i1T FIES XN NIP, ID = 2.750" 8490' 4-i!T WL~ (86$NDCT LNR) MLLOUT WNDOW 9279 - 9286' I 9230' 3-NT X 3-3116' XO, ~ _ 2.800" \ I 9358' I--~3-3116° X 2-718" XO, D = 2.372" 7' LA92.26#, 3-3116" WF2 6.2#, L-80, .0076 bpf, O = 2.BD0' H 9356' I 2-NB' LM1IR, 6.18#, L-8D, .0055 bpf, ID = 2.372" 10574' DATE REV BY tAhA+BVTS DATE REV BY COMv1BJTS 06!87 0T8GINALCOMPLi°TKNJ Q3i16+08 JM'TLH SETPXPLUG(03/09/08) 11/16/02 JLMIKK CTDSIDETRACK J"27A 02/27103 GGKAK DDBKRLNRTOPPKR 05/47106 TWS/R4 F'IKLF:DPX PLUG (05105106) 05113108 WTStPIq GLV CIO (051DFJ06) 0722107 KS&'PJC GLY G'O (07116107) F'RllDFiOE BAY IRVR WF31: J-27A PERMT No: 2022000 A R No; 50.029-21733.01 SEC 9, 711 N, R13E, $00' Sh18 1771' WFi BP Exploration (Alaska) 9 ±, 1, ~~~! V~~~~~ ~~ _~~.., ~,.~ J__ _. _____ __ 3 _., ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ao~-abd ~f~9~l9 ~ °YO - I35~ ~~ ~ 9s~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~~ ~ ~~;v,, ~," i+ ~~, - 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Leak Detection -WLD 27Sep-08 J-27A 2) Leak Detection -WLD 03,Sep-08 F-38 Signed Print Name: ~~~r'; ~f~ ll~~-f'.JLILt~n,.,(,CP~., Color Log / EDE 50-029-21733-01 Color Log / EDE 50-029-22093-00 Date , ~ - ~ - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-WAIL : ~d~~~t~~~rage~~ae~aol~~r9agx~al3a WEBSITE : ~rnv=n~.l~el-~ac~:°tt~c~€~.c~lt? ~'l ,. `- C:\Documerts and Settings\Ownei~Desktop\Transmit_BP.doc • ~6~ L ,, , ~. - -- ~ ~; ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~~~~~E~ JUN (~ 200 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe I.astuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActnre Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 .~ o~ ~-~~p r~ ~j~ 1) Leak Detection - WLD 21-Jun-08 J-27A 2) Signed : ~ l,. , ~~_./ f ~ Print Name: f ,~ljb ~ n r~ _ ~ Il ~ d~~,tlo - f _. , 1 BL/ E~ 50-02921733-014 Date J , PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-NIAII . - ~ `_ 't . 'ra WEBSITE : ~ C:\Documents and Settings\Oamer\Desktop\Trans[nit_BP.doc . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: C-23B, C-41A_PBl, D-27A, G-30B, J-27A, K-04B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic.Blvd.,.AuGhQfage; AK 99518 C-23B: DD3 -óCoO 11 I t...jL/i../ / Digital Log Images: ~NED FEB 0 1 2007 50-029-20775-02 1 CD Rom C-41A_PB1: .90LI-I't7f 13 lL.(/"'/L/3 Digital Log Images: 50-029-22385-01, 70 l;CD Rom D-27 A: fJO-S--/CJ3 1:1 Digital Log Images: 50-029-21543-00 G-30B: QöS- -dO?) 11 L./LI3'1 Digital Log Images: 50-029-21613-02 1 L.fLIL{ D ¡ 1 CD Rom 1 CD Rom J-27 A: 'db d -.;)00 tt 1'-/LI375 Digital Log Images: 50-029-21733-01 1 CD Rom K-04B: ';;ó9 ~ d s-3 -:P I '-/¿¡,L! d. Digital Log Images: 50-029-21023-02 1 CD Rom -:::¡- (fOd -~ e e ~\ ,jÎÌ¡.. 11 't ~ !,.p" : 'I ~ 1. ~ '~ ~ ~; FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Chris Zamora Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 SCAf>I\,\¡¡:;n . rU'I\~ -¡ ,) ?nnr.; ,~" ,', '\1......'~_ - ' '" .J;... t.,} _!oJ ~A.J Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, J-27A Sundry Number: 306-196 Dear Mr. Zamora: " Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this r day of June, 2006 Encl. {)O'è) -(;)cÞ 1. Type of Request: ~ ¡fæ.. b/5/;/ . ') ~EævE1f1iz-oo(, STATé'~F ALASMt:Áb ~ ;}..- IR A~ OIL AND GAS CONSERVATION COM~ION JUN 0 5 2006 APPLICATION ~~~;2~.~8~RY APPROVAL Alaska Oil & Gas Cons. Conmssion Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development Suspend Repair well 0 Pull Tubing 0 . . . Waiver èhorage Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Other Abandon Alter casing 0 Change approved program 0 2. Operator Name: Stratigraphic ø /'XPloratory 0 o Service 0 202-2000 -- BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 6. API Number: 50-029-21733-01-00 / Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 76.9 KB J-27A / 8. Property Designation: ADL-028281 10. Field/Pools(s): PRUDHOE BAY Field / PRUDHOE 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): 10574 9037.84 10541 9035.33 None None Casing Length Size TVD Burst Collapse Conductor 140 20" Conductor 30 110 30 110 Surface 2712 13-3/8" 72# L -80 29 2683 29 2683 5380 2670 Production 8726 9-5/8" 47# L-80 28 8698 28 8398 6870 4760 Liner 17730 7" 26# L -80 8451 92798191.15 8881 7240 5410 Liner 17661 3-1/2" 8.81# L-80 8431 9230 8174.55 8841 10160 10530 Liner 18588 3-3/16" 6.2# L-80 9230 9358 8841.24 8938 Liner 19932 2-7/8" 6.16# L-80 9358 10574 8938.49 9038 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9830 - 9880 9029.06 - 9029.83 5-1/2" 17# L-80 30 - 2092 10310 - 10535 / 9032.21 - 9034.99 4-1/2" 12.6# (' L-80 2092 - 8490 Packers and SSSV Type: 9-5/8" TIW HBBP Packer Packers and SSSV MD (ft): 8383 Liner Top Packer 8431 / 12. Attachments: Descriptive Summary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name hris ~ Title Petroleum Engineer Signature Phone 564-4138 Date COMMISSION USE ONLY Date: 13. Well Class after proposed work: / Exploratory 0 Developm ent ø Service 0 15. Well Status after proposed work: Oil ø Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Chris Zamora 6/2/2006 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: c3tJto-/q ~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Form 10-403 Revised 7/2005 RBDMS 8Ft ,¡UN 0 7 2006 Subsequent Form Required: Approved by: APPROVED BY THE COMMISSION Date: b";- ~þ Submit in Duplicate e e To: C. Olsen/J. Bixby, GPB Well Ops TL Well Operations Team Leader Date: June 1, 2006 From: Jessica Pedota, Wells Engineer Chris Zamora, J Pad Engineer Subject: J-27 OA DownsQueeze PBJPDWL27-M Est. Cost: ~ lOR: 250 Please pump cement down the OA as described in the following procedure. This procedure includes the following steps: Step Type Procedure 1 0 Shoot FLs and record WHPs. Bleed tbg, IA and OA to +/- 200 psi. 2 F Fluid pack and flush OA with diesel. OA cement down squeeze. / 3 F MIT OA after WOC (3 days) J-27A is a flow to surface producer that needs a T x IA waiver to be produced. A waiver would require production casing as a primary barrier (passing CMIT-TxIA 05/09/06) and surface casing as secondar;y-barrier (MIT-OA). The well failed an MITOA 10/19/02 with a liquid leak rate (LLR) a(2 BPM at 1250 psi. An OA downsqueeze is recommended to comply with the latest waiver principals so we can get the well back online. This program is designed to pump approximately 500 feet of cement to seal off the open shoe. With a good cement seal at the shoe we should be able to get a successful MITOA to qualify for a waiver. The fluid level has already been depressed to 2450 feet (with +/- of fluid level tool, that is to the shoe) on OS/29/06. If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (W), 274-0929 (H), 240-8037 (C), or Jessica Pedota 830-2377 (C). cc: Well file C. Zamora w/o: S. Rossberg e e JOB PLANNING DETAILS: MITOA on 10/19/02 failed with a LLR of 2 bpm at 1250 psi. Current wellhead temperature = Shut In (Cold) OA= 13-3/8" 72# L-80 IA= 9-5/8" 47# L-80 Shoe at 2683' OAxIA Annular Capacity=0.0581 bbl/ft Volume to shoe=156 bbl 500' of cement=29 bbl Displacement= 156 -5 (H20 spacer) - 29 (cement) - 5 (H20 flush) = 117 bbls ./ Approximate Fluid Requirements (DownsQueeze Only): Diesel: 234 bbl DS CW101: 10 bbl Fresh Water: 100 bbl of 80 of (includes water for cement mixing and clean up.) Crude Displacement: 117 bbl at 30-60°F Arctic Set 1 Cement (15.7 ppg): 29 bbl pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. DHD/FB PRE-SQUEEZE: 1. Shoot fluid levels and record WHP's. Bleed the Tbg, IA, and OA to +/- 200 psi. 2. Rig up the OA with a flanged 1502 integral union and in-line T valve. NOTE: Ensure that the OA has two valves as per double barrier policy. CEMENTING OPERATIONS: 1. Rig up cementers and Little Red/HOT Oil to OA. Flood lines with warm fresh water or diesel and pressure test lines to 3000 psi. 2. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate / up to the maximum pressure of 2400 psi. Note injectivitt. á) pertinent times during the displacement. MITOA on 10/19/02 failed with a LLR ~r,~ibpm at 1250 psi. Start pumping into the OA as follows: ,/ a. Fluid pack OA with warm diesel. then pump and additional 75 bbls of overflush (-50% annular volume to remove the crude off the casing wettinQ surfaces for better cement bond) b. 5 bbl of fresh water spacer c. 10 bbl of DS CW101 surfactant (may be omitted) d. 5 bbl of fresh water spacer e. 29 bbl of 15.7 ppg Arctic Set 1 cement e e f. 5 bbl of fresh water flush g. 117 bbl of 30-60 OF crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 107 bbl of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbl, then drop the rate to 0.5 BPM for the last 5 bbl. This will leave the leading edge of the cement 5 bbl short of the shoe or 86 feet. This is what we want - do not place edge of r"" cement at shoe. 3. Shut down pumps and leave the well SI. Please DO NOT try to achieve a sQueeze or to build sQueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up / on the OA. 4. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post Saueeze: FB: 5. woe for 3 days. MIT-OA to 2400 psi (1.2 times max qas lift pressure.) Have a pre- job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. J-27 A ~NOTES GA S LIFT MA NORELS DEV TY PE V LV LA TCH PORT 3 OTIS OMY RM 0 04/1 1 OTIS OMY RM 0 04/01/04 23 OTIS OMY' RM 0 05/06/06 34 OTIS DMY* RA 0 05/06/06 1 8196 7850 35 OTIS OMY* RM 0 05/06/06 * STATION #s 1, 2, 3 = DM Y HAS EXTENDED PACKING e TREE = WELLHEAD I 5-1/2" BUTT TBG. 17#, L-80, .0232 bpi, 10 = 4.892" Minímum 10 = 2.372" @ 9358' 3-3/16" 2-7/8" XO PERFORA TION SUMMARY REF LOG MCNL/CCLlGR ON 11/15/02 A NGLE A T TOP PERF 89 9830' Note Reier to Production DB lor historical perl data SIZE SPF INTERV AL Opn/Sqz DA TE 2." 9830 9880 0 11/15/02 2" 4 10310 10535 0 11/15/02 I I 8307' 8368' 8383' 8424' 8431' 8443' 8456' 8458' 14-1/2" TBG, 12.6#, L-80, .0152 bpI. 10 = 3.958" I 8490' 8490' ,/ -1 CAMCO SSSV LANDING NIP, 10 - 4.562" HBKRLSLlOINGSLV, 10=3.813" I H TIW SEAL ASSEMBLY IN PBR I 1--19-5/8 TIW HBBP PKR, 10 - 4.750" H4-1I2" OTIS X NIP, 10 = 3.813" I H 4-1/2" BKR LNR TOP PKR I H 3.75" BKR DEPLOYMENT SLV, 10 = 3.00" I H4-1/2" OTIS X NIP, 10 = 3813" (BEHIND CT LNR) I -j 3-1/2" HES XN NIP, 10 = 2.750" I H4-112" WLEG (BEHIND CT LNR) I MILLOUT WINDOW 9279' - 9286' / 9230' H3-1/2" X 3-3/16" XO, ID = 2.800" I rop OF WHIPSTOCK H IRA TAG I 9651' 9697' I 3-3/16" LNR, 6.2#, L-80, .0076 bpi, ID = 2.800" I 12.7/8" LNR, 6.16#, L-80, .0055 bpi, DATE 06/87 11/16/02 02/27/03 04/01/04 04/13/04 09/25/05 REV BY COMMENTS ORIGINAL COM PLETION JLM/KK CTD SIDETRACK (J-27A) GC/KAK ADD BKR LNR TOP PKR GJB/KAK GLV C/O JLJ/KAK GLV C/O lWS/TLH PX PLUG SET (09/19/05) OA TE REV BY COMMENTS 05/07/06 TWS/PAG PULLED PX PLUG (05/05/06) 05/13/06 WTS/PAG GLV C/O (05/06/06) PRUDHOE BA Y UNIT WELL: J-27A PERMIT No "2022000 API No 50-029-21733-01 SEC 9, T11N, R13E, 800' SNL 1771' WEL BP Exploration (Alaska) e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas ConseIVation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23, 2004 /3&[/ RE: MWD Formation Evaluation Logs: J-27 A, AK-MW-22178 J-27 A: Digital Log Images 50-029-21733-01 JD9- :)DO 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ Date: 9J:39J[)l.1} . . '" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc j ~ t)~.~ M~ô ~\ DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2022000 Well Name/No. PRUDHOE BAY UNIT J-27A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21733-01-00 MD 10574 TVD 9038 /' Completion Date 11/16/2002 ,f" Completion Status 1-01l ---_._----~~--------_.~- --- -~-----._---~----~ REQUIRED INFORMATION Mud log No Samples No _._--------_._-----~---- ~---,--~-------~~--- -----.-- DATA INFORMATION Types Electric or Other logs Run: Well Log Information: MWD, RES, GR, CNL, CCl, ROP log/ Electr Data Digital Dataset Type Med/Frmt Number Name lÇog - Neutron J£g/ Gamma Ray ~~ 0 Directional Survey V"ED C A 1532 Neutron ~ LIS Verification ;M)g Casing collar locator Log Log Run Scale Media No 25 Blu 1 25 Blu 25 Blu -/ ED ..',0 6pt/ ~ 695 LlSjleriffcation rJ\ ~ {lv.-. Directional Survey -- -----._-~-- ----~------~~ Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION v&> Chips Received? 'Y7Ñ Well Cored? Daily History Received? Formation Tops Analysis Received? ""'f"t'M'""' -~----_..._.. -------------..--- Current Status 1-01l UIC N Directional Survey Q..../ (data taken from logs Portion of Master Well Data Maint) ~ Interval OH / Start Stop CH Received Comments 8286 10522 Case 217/2003 8286 1 0522 Case 2/7/2003 9200 10574 Open 12/6/2002 8286 10522 Case 217/2003 Digital well logging data 9043 10529 Open 4/17/2003 8286 1 0522 Case 2/7/2003 9043 10529 Open 4/17/2003 9200 10574 Open 12/6/2002 A Directional Survey log is required to be submitted. This record automatically created from Permit to Drill Module on: 10/1/2002, G\' Lw .~ ¡,( (\..0 r. '---- Sample Set Number Comments (ß/N 0'N DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2022000 Well Name/No. PRUDHOE BAY UNIT J-27A Operator BP EXPLORATION (ALASKA) INC MD 10574 TVD 9038 Completion Date 11/16/2002 Completion Status 1-01l Current Status 1-01l Comments: --- --~---~---------- ~ Date: - "-" ~~------~-~_._~ Compliance Reviewed By: API No. 50-029-21733-01-00 UIC N ~ ~J V'v-- L\}~ ~.. .~-7 ----- ) é)oa-doo 17095 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 08, 2003 RE: MWD Formation Evaluation Logs J-27 A, AK-MW-22178 1 LDWG formatted Disc with verification listing. API#: 50-029-21733-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: -r ~~ Si?}lOO:(/ ~{j~ .'\.Þ RECEIVED APR 1 7 2003 Alaska œ & Gas Cons. Commiaeion Anchorage Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job # Log Description Date K-317B fi10/-/':í!¡J 23013 MCNL 01/02/03 l5-09 1 () -/::}, t./ 23007 RST -SIGMA 11/03/02 l-02 ~nl-~OJ 23003 OH EDIT PEX,AIT & BHC (PDC) 12/08/02 L-02 23003 PEX-RESISTIVITY 12/08/02 L-02 23003 PEX-NEUTRON/DEN 12/08/02 L-02 23003 PEX-BHC 12/08/02 L-02 V 23003 PEX-CALlPER 12/08/02 D.S. 1-19A ~~ -aa~ 22510 MCNL (PDC) 11/06/02 J-27A df)ri-~O 23014 MCNL 11/15/02 L3-02 ¡c:gtn -} 5 23006 RST-SIGMA 11/10/02 K-317B ~r-¡ Sf,. 23045 OH EDIT LWD GR & ROP5 12/30/02 K-317B 23045 MD SLlMPULSE GR 12/30/02 K-317B 23045 TVD SLlMPULSE GR 12/30/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 RECEIVED Date Delivered: fFB 0 7 2003 A1a!ka Oii & Gas Cons. Commission Anchorage Blueline NO. 2835 Company: 01/30/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Lisburne Sepia Color Prints 1 1 1 1 1 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Receive~ CD ~ 1 1 1 1 1 1 1 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well ø§ Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 800' SNL, 1771' WEL, SEC. 09, T11 N, R13E, UM At top of productive interval .lL!./~.:.I¿U 2474' SNL, 1417' WEL, SEC. 09, T11N, R13E, UM At total depth 3298' SNL, 2031' WEL, SEC. 09, T11 N, R13E, UM x = 642375, Y = 5968034 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 76.90' ADL 028281 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/11/2002 . 11/13/2002 I 11/16/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10574 9038 FT 10541 9035 FT Ø§ Yes 0 No 22. Type Electric or Other Logs Run MWD, RES, GR, CNL, CCL, Rap Classification of Service Well <:~~V).i1"" l:íJCAì'1DNj i: VE.,fti..E!;Ð 1. .... ~ .~".'). r. 1 ~U,J~' . .. ....!~. ':ì ~ ~~~~:'~:~"~'Y,>""':~"--':';':~.,,..,.:,:,, x = 642582. Y = 5970536 7. Permit Number 202-200 8. API Number 50- 029-21733-01 9. Unit or Lease Name Prudhoe Bay Unit x = 642971. Y = 5968869 10. Well Number J-27 A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost 2064' (Nipple) MD 1900' (Approx.) ,..,.-/b-J ....J~ 17-7~ ; pi Þ I . ø.f> 71" f'YÞ 7" 3-1/2" x 3-3116" x 2-7/8" WT. PER FT. Conductor 72# 47# 26# 8.81# /6.2# 6.16# GRADE CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' Surface 2683' Surface 8699' 8451' 9279' 8443' 10574' CEMENTING RECORD 8 cu yds Concrete 17-1/2" 1667 cu ft PF 'E' , 2055 cu ft PF 12-1/4" 1744 cu ft Class 'G' 8-1/2" 430 cu ft Class 'G' 3-3/4" 112 cu ft Class 'G' AMOUNT PULLED 23. CASING SIZE 20" 13-3/8" 9-5/8" L -80 / S-95 L-80 L-80 L-80 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 SPF MD TVD 25. TUBING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, L-80 2092' 4-1/2", 12.6#, L-80 2092' - 8490' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 40 Bbls of MeOH. PACKER SET (MD) MD TVD 8383' 9830' - 9880' 9029' - 9030' 10310' - 10535' 9032' - 9035' 27. Date First Production December 1, 2002 Date of Test Hours Tested 1/17/2003 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL -BBL TEST PERIOD 1613 Flow Tubing Casing Pressure CALCULATED Press. 1,028 24-HoUR RATE OIL-BBL GAs-McF 21,888 GAs-McF WATER-BBL 90 WATER-BBL CHOKE SIZE 96° GAS-OIL RATIO 13,570 OIL GRAVITY-API (CORR) 35.1 28. CORE DATA . . . , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiR E eEl E No core samples were taken. JAN 2, & (,Ç Form 10-407 Rev. 07-01-80 RBDMS BFl Submit In Duplicate JAN 2 8 ) ) 29. Geologic Markers Marker Name Measured Depth 25P 9277' 23P 9380' 22P 9431' 21P 9530' Zone 1 B 9928' 14N 9936' 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8879' 8951' 8977' 9008' 9033' 9034' R I JAN 2 1 31. list of Attachments: Summary of Daily Drilling Reports and Post Rig Summary, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ØJIlÆ {\.I ~ Title Technical Assistant Date 0 ¡. GZO -Ó è J-27 A 202-200 Prepared By Name/Number: Sandra Stewman, 564-4750 Well Number P . / N Drilling Engineer: Mary Endacott, 564-4388 ermlt No. Approval o. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (Gl) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ') ) Bp...'EXPEORJ-\Tl0N- Qp"r~tiøtj!S.:~'&J.m,m-ra.,..;Ré.pq....t . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-27 J-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/31/2002 Rig Release: 11/16/2002 Rig Number: N1 Spud Date: 6/14/1987 End: 11/16/2002 Date From;;;To . HoUrs. Task Code NPT 11/8/2002 12:15 - 12:40 0.42 MOB P PRE Safety meeting prior to rigging down windwalls and derrick with rig moved off 1-19a. 12:40 - 17:00 4.33 MOB P PRE Rig down wind walls and derrick 17:00 - 17:30 0.50 MOB P PRE Safety mtg w/ rig moving support personnel 17:30 - 18:30 1.00 MOB P PRE Move rig to entrance to OS 1 18:30- 00:00 5.50 MOB P PRE Enter Spine and head North on West Dock road 11/9/2002 00:00 - 06:00 6,00 MOB P PRE Continue move from DS 1 Turn off on K Pad road at 0115 hrs, at Twin Towers at 0600 hrs 06:00 - 06:30 0.50 MOB P PRE Crew change/safety mtg 06:30 - 10:00 3.50 MOB P PRE Continue to move from twin towers onto spine road, and west to J pad. 10:00 - 14:00 4.00 MOB P PRE Pull onto J pad, short of well J-27 to raise rig derrick, 14:00 -14:15 0.25 MOB P PRE Move onto J pad, sqaure to the well. 14:15 - 14:45 0.50 MOB P PRE Safety meeting pror to moving over well. 14:45 - 15:25 0.67 MOB P PRE Unflange tree cap, set spill dike, install OAlIA protective cages and gauges. Double check all tree valves are closed. 15:25 - 15:45 0.33 MOB P PRE Back rig over tree, well J-27. 15:45 - 17:45 2.00 RIGU P PRE Nipple down swab flange to install BOP's. Studs very rusted and damaged when removed. 12 new studs ordered from valve shop. Flange at top of swab valve in good condition. Accept rig at 16:00PM, 17:45 - 19:00 1.25 RIGU P PRE Nipple up BOP stack. IA 10, OA 92 19:00 - 22:00 3.00 RIGU P PRE Pull injector out of box. Install gooseneck. Stab CT. load 300 bbls 2% KCI w/ bio in pits 22:00 - 00:00 2,00 BOPSURP DECOMP Install test joint. Test BOPE. Witness waived by AOGCC 11/10/2002 00:00 - 04:00 4,00 BOPSURP DECOMP Finish BOPE test. Blind/shear rams leaked-replace and retest 04:00 - 04:45 0.75 BOPSUR P DECOMP Grease crew open SSV, Check well for press-none, Fill w/3 bbls, load BOT tools to floor Prespud mtg 04:45 - 05:40 0.92 STWHIP P WEXIT MU BOT CTC. PT 35k. Install dart catcher 05:40 - 06:30 0,83 STWHIP P WEXIT load wiper dart, Fill CT w/ 2% KCI w/ bio. Dart landed on money at 57.7 bbls away, 06:30 - 06:45 0.25 BOPSUR P DECOMP Pressure test inner reel valve. 06:45 - 07:30 0,75 STWHIP P WEXIT Prespud safety meeting prior to picking up first BHA. Discuss status of well, results of rig move, preventative action plan for avoiding minor slips/trip/falls that could lead to more serious events. Take 15 minutes to do rig walkaround to be sure that no items were overlooked from rig move. 07:30 - 07:55 0.42 STWHIP P WEXIT Make up BHA#1, Window milling BHA. IAP=30 psi, OAP=120 psi, BHA #1 =Hughes 0261 DSM, Baker string reamer, Baker Extreme motor, 2 jts PH6, MHA, CTC, 07:55 - 09:40 1.75 STWHIP P WEXIT RIH BHA #1. Taking crude returns to tiger tank. Note - Tubing is fluid packed with crude. 09:40 - 09:50 0.17 STWHIP P WEXIT 9200', weight check up=39klbs. RIH, dry tag top of whipstock at 9283', uncorrected. PU, kick on pumps to 2.4 bpm, 1200 psi free spin. Tag top of whipstock with pumps on, make -8- correction. Set depth to pinch point of 9279'. 09:50 - 11 :00 1.17 STWHIP P WEXIT Begin window milling at 9279', corrected to ELM whipstock set depth. 2,31?/1320 psi. Continuing to junk fluid to tiger tank. Pit vol=220 bls, more KCl ordered. 11 :00 - 14:30 3.50 STWHIP P WEXIT 9280.2', Continue milling. All crude displaced from well, free spin has changed. 2.212.2/1600 psi. Printed: 11/1812002 4:00:53 PM ') ') BP.eXPEO'RATION . , '" .P'p~r.~igQ-$.\lm'tj~'ry...:!'R@:p~nt. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-27 J-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/31/2002 Rig Release: 11/16/2002 Rig Number: N1 Spud Date: 6/14/1987 End: 11/16/2002 Dáte Frorh~To Hours ,:Tásk . Code NPT 11/10/2002 14:30 - 15:30 1.00 STWHIP P WEXIT 9283.2', IAP=1150 psi, OAP=914 psi. Bleed down OA and IA. IAP=150, OAP=105 psi. Pit vol=332 bbls. Did not loose any fluid when bleeding IA. 15:30 - 17:00 1.50 STWHIP P WEXIT 17:00 - 18:00 1.00 STWHIP P WEXIT 18:00 -19:20 1,33 STWHIP P WEXIT 19:20 - 20:35 1.25 STWHIP P WEXIT 20:35 - 22:05 1.50 STWHIP P WEXIT 22:05 - 22:45 0.67 STWHIP P WEXIT 22:45 - 23:45 1.00 DRill P PROD1 23:45 - 00:00 0,25 DRill P PROD1 11/11/2002 00:00 - 01 :50 1,83 DRill P PROD1 01:50 - 02:15 0.42 DRill P PROD1 02:15 - 03:00 0.75 DRill P PROD1 03:00 - 03:30 0.50 DRill P PROD1 03:30 - 04:00 0.50 DRill P PROD1 04:00 - 05:40 1.67 DRill P PROD1 05:40 - 06:00 0,33 DRill P PROD1 06:00 - 06:45 0.75 DRill N WAIT PROD1 06:45 - 07:15 0.50 DRill P PROD1 07:15 - 08:50 1.58 DRill P PROD1 08:50 - 09:05 0.25 DRill P PROD1 09:05 - 10:00 0.92 DRill P PROD1 10:00 - 11 :00 1,00 DRill P PROD1 11 :00 - 12:00 1,00 DRill P PROD1 12:00 - 13:00 1.00 DRill P PROD1 Note - The new SWS system of monitoring lAP and OAP real time, in coil operations cabin, works very well! Exited window at 9286.0'. Window depth for now is 9279'-9286', for a 7' window. we will confirm these depth on first MWD run. Drill 1 0' of open hole. 9290.0', We have pumped 2 bottoms up since exiting window. Examine cutting sample in geo's microscope. Sample was 70% steel, and 30% formation sand, confirming we have an exit. Continue to mill formation slowly to get our 10'. 9296.0', Ten foot of rathole completed. Back ream window. Dry tag. All passes showed a burr at btm of window at 9285.6-9286' Ream burr clean, Pump hi vis Flo Vis pill, then swap to used Flo Pro mud POOH for drilling assy. IA tracking ECD's-went from 100 psi at TO to -14 vac by 5000' at 2.5 bpm lD milling BHA. Both mill and string reamer in gauge. Center wear on mill diamonds. MU drilling BHA. PT BOT CTC @ 3500 spi RIH w/ BHA #2 (1.69 deg motor). SHT RIH w/ BHA #2 log tie-in to BHCS at 9087' 2.4/2900/90R, add 6.0' Orient to left. RIH thru window at 45l, clean. Tag TO at 9298'. Chk TF 2.5/3050/601. Orient Drill from 9297.5' 2.6/3100/49R and lots of stalls-this is hard rock Geo calls to say landing point is 8945' or 10' TVD higher than plan! We really ought to know these things before the BHA goes in the hole. . . . 9301' and going nowhere fast. POOH for bit and maybe motor bend Geo reports primarily conglomerate w/ pyrite OOH, Pull BHA and hang Wait on bit 3-3/4" Smith tricone bit with diamond enhanced cutters on location. Makeup to 1.69 deg motor. OAP=O,IAP=O RIH with BHA #3, to begin build section, and drill chert intervals. Run thru window clean. Kick on pumps. Free spin 3020 psi at 2.5 bpm. OAP=O,IAP=O. Tag bottom, make +1.5' correction, Orient to high side. 9301', Begin drilling. 2.6/2.6/3030 psi, 1000 Ibs weight on bit. Pit vol=343 bbls. ROP 25 fph. 9325', Continue drilling. 2.5/2.5/3120 psi, Pit vol=344 bbls. ROP 25 fph. 9356', Continue drilling. 2.5/2.5/3100 psi, Pit vol=344 bbls. ROP=42 fph. 9383', Continue drilling. 2.5/2.5/3110 psi, Pit vol=343 bbls. Printed: 11/18/2002 4:00:53 PM ) ') B'P','EXPtO'RA'fIQN . . .. . . ,. " . ~pér~tiþ,.,,~.'.;.~~:mm:-ry.....~~:p~rt Legal Well Name: J-27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: REENTER+COMPLETE Start: 10/31/2002 End: 11/16/2002 Contractor Name: NORDIC CALISTA Rig Release: 11/16/2002 Rig Name: NORDIC 1 Rig Number: N1 Task Code NPT 11/11/2002 12:00 - 13:00 1.00 DRill P PROD1 ROP=30 fph, IAP=140 psi, OPA=273 psi. 13:00 - 13:20 0,33 DRill P PROD1 9399', Continue drilling. 2.5/2.5/3140 psi, Pit vol=341 bbls. ROP=25 fph. 13:20 -14:30 1.17 DRill P PROD1 9404', ROP fell off. Geo indicates we are thru most of chert, Pick up for survey off bottom, POOH to change bits. Total on bottom time on bit = 4 hours, 20 minutes. Total depth drilled = 103'. 14:30 - 14:55 0,42 DRill P PROD1 Tag up at surface with BHA#3, recover Smith tricone bit. PU Smith M09 bit. Run same motor, MWD, MHA back in the hole. Note - Smith tricone bit was recovered in very good condition, DO graded as 1,1 ,-,-,E,I,HR. It gauged at 3,75" after the run! 14:55 - 16:25 1.50 DRill P PROD1 RIH with BHA #4, M09 bit, 1.69 deg motor, to finish build section. Hung up at the window 2 times. Orient to get thru 16:25 - 16:35 0.17 DRill P PROD1 Orient to drill. 16:35 - 17:45 1.17 DRill P PROD1 9404', Begin drilling. 2.5/2.5/3500 psi. Free spin 3000 psi. Pit volume=339 bbls, TF=49R. ROP=80 fph. 17:45 - 18:00 0.25 DRill P PROD1 9476', Orient around to 30R. 18:00 - 19:35 1.58 DRill P PROD1 Resume drilling, 2.5/2.5/3350 psi. Free spin 3050 psi. Pit vol=334 bbls, TF=30R, ROP=95 fph. OAP=275 psi, IAP=175 psi. We have lost 5 bbls of mud in last 1.5 hours, Drill to 9565' 19:35 - 21 :15 1,67 DRill P PROD1 Begin MAD pass for geo's logging recorded data up at 5'/min from TO to 9070' since they feel we are off depth by 10' TVD 21:15 - 22:25 1.17 DRill P PROD1 POOH from 9070' 22:25 - 23:15 0.83 DRill P PROD1 lD MWD BHA 23:15 - 0.00 DRill P PROD1 MU resistivity BHA 11/12/2002 00:00 - 00:30 0.50 DRill P PROD1 Upload Sperry res tool. Fin MU BHA. Chg motor and bit 00:30 - 02:10 1.67 DRill P PROD1 RIH w/ BHA #5 (1.37 deg motor). Bounce thru window 02:10 - 02:25 0.25 DRill P PROD1 Precautionary ream to TO 2.6/3100/19R. Tag at 9575' and corr to 9565' 02:25 - 02:45 0.33 DRill P PROD1 Orient 02:45 - 04:00 1.25 DRill P PROD1 Drill from 9565' 2.5/3030/11 OR to 9655' 04:00 - 05:00 1.00 DRill P PROD1 Orient around, and then again 05:00 - 06:05 1,08 DRill P PROD1 Drill from 9655' 2.6/3060/1 Ol-1 OR to 9703' 06:05 - 06:30 0.42 DRill P PROD1 9703', Wiper to window. Pulled heavy at 9460'. Dropped down, and back up, Did not see it a second time. 06:30 - 06:40 0.17 DRill P PROD1 log tie in pass @ 9340'. Make +3' correction. 06:40 - 07:00 0.33 DRill P PROD1 RIH continue wiper trip in, Ream area around 9460', up and down. No problems observed. 07:00 - 07:30 0.50 DRill P PROD1 9703', Continue drilling. 2.5/2.5/3000 psi free spin. Pit vol=305 bbls, OAP=450 psi, IAP=350 psi. 07:30 - 09:30 2.00 DRill P PROD1 9711', 2,5/2.3/3400 psi. Ratty drilling. loosing a bit of fluid. DD reports this is the expected depth of fault #2. We may be crossing it now. Continue drilling. 09:30 - 10:30 1.00 DRill P PROD1 9743', Drilling continues to be hard and slow. Geo reports 60% chert in sample at 9700'. Significant chert in lower zone 2 may . Continue to drill to observe ROP, try to drop TVD by 5' as per geo. 10:30 - 11 : 10 0.67 DRill P PROD1 9755', Drilling ROP has improved. ROP now 90 fph. Pit vol=296 bbls, IAP=425 psi, OAP=335 psi. 11:10-12:00 0.83 DRill P PROD1 INC at bit 86 deg. Orient to 90R to hold angle. Plan is to still drop TVD by 5' to 8955'. 12:00 - 12:20 0.33 DRill P PROD1 9853', Wiper trip to shoe. Clean 12:20 - 12:40 0.33 DRill N SFAl PROD1 Repair coil tubing drive bushing. Printed: 11/1812002 4:00:53 PM ) ") .BP'f;XP'bORATION . . ppEir~lit>:IÎ,~...".'~'Qmrn..'.tt¡'..'~~pqrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-27 J-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Spud Date: 6/14/1987 Start: 10/31/2002 End: 11/16/2002 Rig Release: 11/16/2002 Rig Number: N1 Date. Hours Task. ...;Code NPT. 11/12/2002 12:40 - 13:00 0.33 DRill P PROD1 13:00 - 14:00 1,00 DRill P PROD1 14:00 - 14:05 0.08 DRill P PROD1 14:05 - 14:25 0.33 DRill P PROD1 14:25 - 14:35 0.17 DRill P PROD1 14:35 - 16:35 2.00 DRill P PROD1 16:35 - 17:45 1,17 DRill P PROD1 17:45 - 18:25 0.00 DRill P PROD1 18:25 - 18:50 0.42 DRill P PROD1 18:50 - 21 :30 2.67 DRill P PROD1 21 :30 - 22:00 0.50 DRill P PROD1 22:00 - 22:30 0.50 DRill P PROD1 22:30 - 23:30 1,00 DRill P PROD1 23:30 - 00:00 0.50 DRill P PROD1 11/13/2002 00:00 - 00:20 0,33 DRill P PROD1 00:20 - 00:50 0.50 DRill P PROD1 00:50 - 01:10 0.33 DRill P PROD1 01:10 - 02:10 1.00 DRill P PROD1 02:10 - 03:15 1.08 DRill P PROD1 03: 15 - 05:00 1.75 DRill P PROD1 05:00 - 06:45 1,75 DRill P PROD1 06:45 - 07:45 1.00 DRill P PROD1 07:45 - 10:20 2.58 DRill P PROD1 10:20 - 11 :00 0.67 DRill P PROD1 11 :00 - 11:10 0.17 DRill P PROD1 11:10 -11:40 0.50 DRill P PROD1 11 :40 -12:10 0.50 DRill P PROD1 12:10 - 12:20 0.17 DRill P PROD1 12:20 - 12:35 0.25 DRill P PROD1 12:35 - 12:50 0,25 DRill P PROD1 Wiper back in the hole. Clean. Resume drilling. 2.6/2.6/3050 free spin. 292 bbls pit volume, IAP=420 psi, OAP=332 psi. Orient 4 clicks. Resume drilling. 9900', Orient to left side tool face. Resume drilling. 2.5/2,5/3065 psi free spin. 293 bbls pit volume. IAP=460 psi, OAP=35 psi. (Bled off to tiger tank sin~ last reading). Drill to 9949'. Oriènt 2 clicks & drill to 9994' with 48l TF, 2.5/2.5bpm, 3050/3350psi & 44 ave ROP. 0.6% solids in mud system, 698' footage on used mud. Call for new mud system. Wiper trip clean to window, RBIH to btm. Orient TF to 451. Drilling, 2.5/2,5 bpm, 3060 - 3600 psi, 60 FPH, 60l, Swapped over to new FloPro at 10,070'. Drilled to 10,080', Drilling, 2.5/2.5 bpm, 3060 - 3600 psi, 60 FPH, 60l, Drilled to 10,101' Orient TF to 85R Drilling, 2.5 / 2.5 bpm, 3060 - 3600 psi, 60 FPH, 80R, Trouble getting valid MWD surveys while drilling ahead, Pick up several times and circ off bottom to try and get valid surveys. Drilled to 10,141'. Wiper trip to window, log Tie-in with RA tag at 9286'. No correction to CTD, RIH clean to TD of 10,141'. Orient TF to low side. Drilling lateral, 2.6/2.6 bpm, 3100 - 3600 psi, 165R, Drilled to 10,185'. Getting questionable Dir, GR and Resistivity data, Decide to POH and C/O tools. log MAD pass up from TO to 9,750' at 450 FPH. POH to C/O Sperry tools. Open hole was clean on trip to window. POH. At surface, UO orienter, Down load Res / GR. Check bit - 6/4/1 & beginning to core - suspect worn bit was the cause of downhole MWD problems. C/O bit to a new DS49. Adjust motor to 1.04deg bend. C/O orienter & MlU BHA #6 with same MWD (GR, G&I & Res) tool. Initialize MWD tool. RIH with BHA#6 to 740'. SHT - OK. Continue RIH & tag btm @ 10185'. log MAD pass up from TO to 10112', RBIH. Orient TF to 90R. Drill to 10202' with 80-90R TF, 2.6/2.6bpm, 3000/3200psi, 2k WOB & 34fph ave ROP. Drill to 10244' with 80-90R TF, 2.6/2.6bpm, 3000/3500psi, 2k WOB & 90fph ave ROP. Drill to 10258' with 80-90R TF, 2.6/2.6bpm, 3000/3480psi, 2k WOB & 65fph ave ROP. TF all over from 140R to 40R. Drill to 10267' with 100R TF, 2.6/2.6bpm, 3000/3480psi, 2k WOB & 45fph ave ROP. Drill to 10285' with 90-100R TF, 2.6/2.6bpm, 3000/3250psi, 2k Printed: 11/18/2002 4:00:53 PM ) ') BP'EXPlORATION . . - . . Qpij,riJ~i,g"Š......~p'mtij.~....ßE!.P9rt Legal Well Name: J-27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: REENTER+COMPLETE Start: 10/31/2002 End: 11/16/2002 Contractor Name: NORDIC CALISTA Rig Release: 11/16/2002 Rig Name: NORDIC 1 Rig Number: N1 Date From~Tò . Hourso.,Task .Çode NPT Ph~$e' . 11/13/2002 12:35 - 12:50 0,25 DRill P PROD1 WOB & 65fph aye ROP. 12:50 - 13:10 0,33 DRill P PROD1 Drill to 10299' with 90-100R TF, 2,6/2.6bpm, 3000/3250psi, 2k WOB & 45fph aye ROP, 13:10 - 13:50 0.67 DRill P PROD1 Drill to 10310' with 90R TF, 2.6/2.6bpm, 3000/3250psi, 2k WOB & 95fph aye ROP. 13:50 -14:15 0.42 DRill P PROD1 Drill to 10351' with 85-90R TF, 2.6/2.6bpm, 3000/3250psi, 3k WOB & 90fph aye ROP, 14:15 - 15:45 1.50 DRill P PROD1 Wiper trip clean to window, RBIH. Saw little bobble @ 9960'. Continue RIH to btm, 15:45 - 15:55 0.17 DRill P PROD1 Orient TF to 901. 15:55 - 16:25 0,50 DRill P PROD1 Drill to 10404' with 85-90l TF, 2.6/2.6bpm, 3000/3550psi, 3k WOB & 150fph aye ROP. Cut thru water sand @ 10360'. 16:25 - 16:35 0.17 DRill P PROD1 Short wiper trip 10200' RBIH. 16:35 - 16:40 0.08 DRill P PROD1 Drill to 10411' with 90l TF, 2.6/2.6bpm, 3000/3550psi. 16:40 - 16:55 0.25 DRill P PROD1 Orient TF to 1 001. 16:55 -17:15 0.33 DRill P PROD1 Drill to 10445' with 105l TF, 2,6/2.6bpm, 3000/3500psi, 3k WOB & 11 Ofph aye ROP. 17:15 - 17:50 0.58 DRill P PROD1 Orient 1 click & drill to 10500' with 80l TF, 2.6/2.6bpm, 3000/3400psi, 2k WOB & 150fph aye ROP. 17:50 - 18:30 0.67 DRill P PROD1 Wiper trip clean to 9350'. 18:30 - 19:00 0.50 DRill P PROD1 log GR tie-in from 9350'. Added 1 ft to CTD. 19:00 - 19:30 0,50 DRill P PROD1 RIH clean to TO, 19:30 - 19:45 0.25 DRill P PROD1 Orient TF to 701. 19:45 - 21 :00 1.25 DRill P PROD1 Drilling, 2.6/2,6 BPM, 3100 - 3600 PSI, 80 FPH, 70l, 86 DEGINCl. Drilled to end of Polygon at 10,575' BKB, Call TD at 10,575'. 21 :00 - 21 :45 0.75 DRill P PROD1 Wiper trip to window. 2.6 bpm, 3100 psi. Clean hole to window. 21 :45 - 22:05 0.33 DRill P PROD1 log final tie-in with RA tag at 9,285'. Minus 2 ft CTD. 22:05 - 22:35 0.50 DRill P PROD1 RIH to TO. Tag TO at 10,574 ft BKB, Final TO. 22:35 - 23:45 1.17 DRill P PROD1 log MAD Pass with Resistivity / GR from TO to 10,100 ft. 2.6 bpm, 3100 psi, 400 FPH. 23:45 - 00:00 0.25 DRill P PROD1 POH to run liner. 11/14/2002 00:00 - 01 :45 1.75 DRill P PROD1 POH to run liner. Flag CT at 7000' EOP. POH. 01 :45 - 03:00 1,25 DRill P PROD1 Down load Res/GR. UO MWD BHA. 03:00 - 03:15 0.25 CASE P COMP Prep rig floor to run liner. Raise catwalk. 03:15 - 03:30 0,25 CASE P COMP SAFETY MEETING. Review liner running procedure, hazards and mitigation. 03:30 - 06:00 2.50 CASE P COMP RIH with BKR Float Shoe, 1 Jt 2-7/8", Turbo, BKR Float Cllr, BKR latch Cllr. RIH with 23 Jts, 2-7/8", 6,16#, l-80, STlliner. 10 ft pup, 14 Jts, 2-7/8", STlliner, XO. RIH with 4 jts, 3-3/16", 6,2#, l-80, Tell liner, XO. 06:00 - 06:15 0.25 CASE P COMP Crew change & PJSM for running liner, 06:15 - 08:15 2.00 CASE P COMP Continue RIH with 26jts of 3-1/2",8.81#, l-80, STlliner. Total length of liner = 2131.1 ft. 08:15 - 09:30 1.25 CASE P COMP Install Baker CTlRT. Install Baker eTC. Pull test to 40k & pressure test to 3500 psi. 09:30 - 11 :20 1.83 CASE P COMP RIH with liner on CT to flag @ 9132' - correct CTD to 9140'. Up wt check - 40k, Run-in wt - 24k. RIH thru window & continue smoothly to btm tagged @ 10578'. P/U @ 42k & retag @ same depth. Correct CTD to 10574'. 11 :20 - 12: 1 0 0.83 CASE P COMP load & circ 5/8" phenolic ball. Stack 5k. Circ ball & slow down Printed: 11/1812002 4:00:53 PM ) ) .BP:E}(PtORÄTION . ~pø~gl1~(~grnm~'~~ÞÞ~ Legal Well Name: J.,27 Common Well Name: J-27 Spud Date: 6/14/1987 Event Name: REENTER+COMPLETE Start: 10/31/2002 End: 11/16/2002 Contractor Name: NORDIC CALISTA Rig Release: 11/16/2002 Rig Name: NORDIC 1 Rig Number: N1 Hours [as( Code NPT 11/14/2002 11:20-12:10 0.83 CASE P COMP to 1 bpm after 40bbls away. Ball on seat @ 50bbls. Ramp up & sheared @ 4400 psi. PUH @ 29k & confirm liner release. Stack 1 Ok, 12:10 -14:10 2.00 CASE P COMP Displace well to 2% KCI @ 3.0/2.9bpm & 3150psi. Ship used mud to MI. Meanwhile RlU Dowell cementers. 14:10 - 14:25 0.25 CEMT P COMP PJSM for cement job. Review procedure, hazards & mitigation. 14:25 - 16:20 1,92 CEMT P COMP Batch mix 20bbls 15.8ppg cmt with additives. Cmt to wt @ 14:50 hrs. Flush/PT lines to 4k. Pump 20bbls cmt slurry @ 2,1/1.3bpm & 2100psi. Close inner reel valve & clean lines. load CTWP, launch with 500psi & confirm launch. Chase with 26 bio-pill & KCl @ 2.7/1.7bpm & 1600psi. CTWP engage lWP at 77.3bbls away. Shear plug with 3300psi. Reset MM-in. Continue displacing lWP @ 2.1/1.3 bpm, 1770 psi & bump @ 14bbls away. 12bbls cmt pumped around shoe. Floats held. Pressure up to 500 psi & sting out of liner, CIP at 16:15 hrs 16:20 - 18:00 1.67 CASE P COMP POOH @ circ @ O,9/0.7bpm & 320psi to minimize ECDs. 18:00 - 18:45 0.75 CASE P COMP UD CTlRT, M/U BKR motor and used 2,30" Parabolic diamond mill 18:45 - 19:00 0.25 EVAl P COMP SAFETY MEETING. Review procedure, hazards and mitigation for running SWS Memory CNUGRlCCllogging tool. 19:00 - 19:30 0.50 EVAl P COMP M/U SWS CNUGRlCCl, circ sub, hyd disc and XO. 19:30 - 21 :15 1.75 EVAl P COMP M/U 70 singles of 1-1/4" CSH workstring. M/U OS MHA. BHA total length = 2225', 21:15-22:20 1.08 EVAl P COMP RIH with SWS Memory CNUGRlCCl, motor and 2,30" mill to cleanout liner and log. 22:20 - 00:00 1.67 EVAl P COMP log down at 30 fpm from 8300 ft. circ at 1.4 /1.4 bpm at 2230 psi. Tag PBTD at 10,528', Clean liner, no motor work to TD, Circ. new FloPro to bottom for perf pill, 11/15/2002 00:00 - 00:30 0.50 EVAl P COMP Circ. new FloPro perf pill to TO. 1.4 bpm, 2300 psi. 00:30 - 01 :45 1.25 EVAl P COMP log up with SWS Memory CNUGRlCCllogging tools at 30 fpm. lay in FloPro at 0,3 bpm. log up to 8300 ft. 01 :45 - 03:00 1.25 EVAl P COMP POH with logging tools, motor and mill. 03:00 - 05:15 2.25 EVAl P COMP Stand back 35 stds of CSH workstring. Wet stands. 05:15 - 05:30 0.25 EVAl P COMP SAFETY MEETING. Review procedure, hazards and mitigation for UO of CNl source. 05:30 - 06:00 0.50 EVAl P COMP layout SWS CNUGRlCCl. UO motor and mill. 06:00 - 08:00 2.00 CEMT P COMP line up to pressure test liner lap. OS UCA cement sample at 2200 psi at 0600 hrs. Note IA & tbg communicating via GlM#2. IA & OA @ Opsi from onset of test. Staged up wellbore in stages to 2000psi, bringing-up IIA to 2000psi. 08:00 - 08:45 0.75 CEMT P COMP PfTest wellbore @ 2000 psi with 2000psi on IA. Wellbore leaked 450psi while IA increased by 70psi in 1 st 15 mins. Wellbore leaked 40psi while IA remained constant in 2nd 15 mins, Observed no change in OA pressure thoughout test. Review results with town & decide retest. 08:45 - 10:00 1.25 CEMT P COMP Repressurize wellbore & IA to 2050psi. Again wellbore leaked - 450psi while IA increased by 80psi in 1 st 15 mins, Wellbore finally stabilized @ 1550psi while IA remained constant @ 2130psi in 2nd 15 mins. Bleed off pressures. Review forward plan with town & decide to run KB Inr top Pkr after perforating. 10:00 - 10:15 0.25 PERF P COMP PJSM for perforating job. Review procedures, hazards & Printed: 11/18/2002 4:00:53 PM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) , ,BP'Ð<:FH¿O~J]ON . ' 'PÞ~'r.~iQI1:~...'..$"tJ'm:tI1.~.fN."....R~pì>-'t':t . J-27 J-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 . Hours .Tàsk 'Cöde. NPT . Start: 10/31/2002 Rig Release: 11/16/2002 Rig Number: N1 Spud Date: 6/14/1987 End: 11/16/2002 11/15/2002 10:00 - 10:15 0.25 PERF P 10:15 - 10:50 0.58 PERF P 10:50 - 12:00 1.17 PERF P 12:00 - 14:00 2.00 PERF P 14:00 - 14:10 COMP COMP COMP COMP 0.17 PERF P COMP 14:10 - 14:15 0.08 PERF P COMP 14:15 - 14:30 0,25 PERF P COMP 14:30 - 15:30 1.00 PERF P COMP 15:30 -16:40 1.17 PERF P COMP 16:40 - 18:00 1.33 PERF P COMP 18:00 - 18:15 0.25 PERF P COMP 18:15 -18:45 0.50 PERF P COMP 18:45 - 19:00 0,25 RUNCOIVP COMP 19:00 - 19:50 0.83 RUNCOIVP COMP 19:50 - 21 :40 1.83 RUNCOIVP COMP 21 :40 - 22:30 0.83 RUNCOIVP COMP 22:30 - 23:45 23:45 - 00:00 11/16/2002 00:00 - 01 :40 01 :40 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 06:00 1.25 RUNCOIVP COMP 0,25 RUNCOflP 1.67 RUNCOf..oP 0.33 RUNCOf..oP 1.00 RUNCOf..oP COMP COMP COMP COMP 1.50 RIGD P COMP 1.50 RIGD P COMP .' p~scriptiqnOf()þeråtiQn$ mitigation, M/U 14 SWS 2" HSD PJ 2006, 4spf, 60degs phasing perf guns & blanks with CBF & HDF firing systems, M/U 31 doubles of 1-1/4" CSH. M/U coil. RIH perforating BHA#9 with CT. Tag PBTD @ 10539'. Pull to P/U wt (34k) to postion for bottom shot @ 10535' & correct depth to 10535.7', Fluid pack wellbore. Set-up sonogram detector to choke manifold for shot detection & function test it OK. line up for HDF-fire system pumping into CT & annulus from Ops cab. Shut-in choke. Allow wellbore to stabilize for 3 minutes. Presure-up CT & wellhead to 2000psi & hold for 1 min. Dump pressure to Opsi & wait for 5mins. Observe HDF fire btm interval: 10310' - 10535'. PUH to 10122.5' & postion for bottom shot @ 9880'. Pump 10 bbl perf pill & load 5/8" steel ball. Blow ball in to CT & chase ball to seat slowing to 1 bpm @ 40bbls. Ball on seat @ 54.7bbls away. Pressure up to 3000psi & observe CBF fire top interval: 9830' - 9880', POOH with perf guns. SIB 31 CSH doubles. Crew change & PJSM for UD perforating guns. UD perf guns. All shots fired. SAFETY MEETING. Review procedure, hazards, and mitigation for M/U of BKR liner top packer BHA. M/U BKR 4.5" KB liner Top Packer with seal assembly, GH running tool, Hyd discon, 2 jts PH6 and eTC. Total length = 81.92 ft. RIH with liner Top Packer BHA. 80 fpm. 0.2 bpm, 250 psi, Up Wt at 8400 ft = 31K, Dwn Wt. = 24K. Sting into liner Deployment sleeve with seal Assy at 8437' CTD, Saw pump press increase, indicating seals holding press. RIH 6' and stack 10K on locator sub above 6' long seal assy. Press test liner lap with seal Assy stung into deployment sleeve. WHP = 2000, lAP = 2470 psi at 23:00 hrs, Double block. WHP = 1840 psi, lAP = 2480 psi. at 23:10 hrs, WHP and lAP balanced at 23:10 hrs. WHP = 1810 psi, lAP = 2440psi at 23:40 hrs. loss of 30 psi in 30 min. Good test. POH with liner top Packer BHA. 80 fpm, 0.7 bpm, 160 psi. POH with l T PKR BHA. UO BKR BHA. Recover 100%. M/U side jetting nozzle BHA. Jet stack with 3.3 bpm, cycle up and down 3 times jetting stack with KCl water. RIH to 2000 ft. Freeze protect tubing with MEOH. lay in 40 BBl of MEOH at 75%, POH at 90 fpm, pump 1.5 bpm in 5-1/2" tubing. Stop at 200 ft, circ 100% MEOH to surface. POH. Close Master and Swab valves, Clean rig pits and cuttings tank. N/D BOPE. N/U tree cap and press test with 4000 psi. SIWHP = 0 psi, lAP = 600 psi. OAP = 0 psi. RELEASED RIG AT 0600 HRS, 11-16-2002. Printed: 11/18/2002 4:00:53 PM ) ) . BPE)('I?:l.,(;)~llÐN . .~P"~~'~~~'~!.~~~.~~~.~i"B~p~trt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-27 J-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Spud Date: 6/14/1987 Start: 10/31/2002 End: 11/16/2002 Rig Release: 11/16/2002 Rig Number: N 1 Date From ...To ~ HóursTask Code' NPT Q~~Þriþti()nór pp~ratipo~ . COMP TOTAL OF 6 DAYS, 14 HRS ON WELl. PREP TO MOVE RIG TO J-01 B 11/16/2002 04:30 - 06:00 1,50 RIGD P Printed: 11/18/2002 4:00:53 PM Well: Field: API: Permit: ) ) J-27 A Prudhoe Bay Field I Prudhoe Bay Pool 50-029-21733-01 202-200 Rig Accept: 11/09/02 Rig Spud: 11110102 Rig Release: 11/16/02 Drilling Rig: Nordic 1 POST RIG WORK 11/21/02 T/I/O=VAC/46010 TBG FL NS. IA FL AT SURFACE. 11/26/02 SET SLIP STOP C-SUB, PULL DGLV FROM STA #2. SET DGLV WI EXTENDED PACKING IN STA. (UPPER SET =4.6" LONG. LOWER SET =3.375" LONG.) PULL C-SUB DID A MITIA TO 2500 PSI AND HELD FOR 30 MIN - GOOD TEST. 11/28/02 PULL DGLV'S FROM STA'S #4 & #5 11/29/02 SET GENERIC DESIGN IN TOP 2 STA'S. RA LATCHES REPLACED WI RM LATCHES. SET LGLV IN ST A #5 SET OGLV IN STA #4 ) ) a Oð--dOO 20-Nov-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well J-27 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,200.00' MD Window / Kickoff Survey 9,276.00 I MD (if applicable) Projected Survey: 10,574.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED DEC 06 2002 Alaafœ 0i1 & Gas Cons. Comrmssion Anchorage " Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA J Pad J-27 A -> Job No. AKMW22178, Surveyed: 13 November, 2002 Survey Report 19 November, 2002 Your Ref: API 500292173301 Surface Coordinates: 5970536.00 N, 642582.00 E (70019' 37.3137" N, 148050' 37.1936" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 970536.00 N, 142582.00 E (Grid) Surface Coordinates relative to Structure Reference: 2283.44 N, 1471.40 E (True) Kelly Bushing: 76.90ft above Mean Sea Level Elevation relative to Project V Reference: 76.90ft Elevation relative to Structure Reference: 76.90ft Sp~"'-'Y-5UI! D A (cHe IN G S En:~V( c: e s A Halliburton Company Survey Ref: svy11369 Sperry-Sun Drilling Services Survey Report for PBU _WOA J Pad - J-27 A Your Ref: API 500292173301 Job No. AKMW22178, Surveyed: 13 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9200.00 35.300 165.380 8739,89 8816,79 1421.94 S 334.02 E 5969120.66 N 642942.98 E 1046,81 Tie On Point MWD Magnetic -- 9276.00 35.880 164.390 8801,70 8878,60 - 1464.64 S 345.56 E 5969078.19 N 642955.33 E 1.076 1077.47 Window Point 9306.79 40.620 167.500 8825.87 8902.77 1483.13 S 350.16 E 5969059.79 N 642960.28 E 16.612 1090,95 9336.66 46.430 169.920 8847,52 8924.42 1503.30 S 354.16 E 5969039.71 N 642964.67 E 20.232 1106.17 9368.41 53,300 172.040 8867.98 8944.88 1527.26 S 357.94 E 5969015.82 N 642968.90 E 22.230 1124,76 ~ 9423,61 63,610 175.060 8896,82 8973.72 1573.94 S 363.15 E 5968969.25 N 642974.99 E 19.247 1162.09 9457.08 67,840 180.340 8910.59 8987.49 1604.40 S 364.35 E 5968938.81 N 642976.77 E 19,140 1187.59 9484.31 71.720 184.040 8920.00 8996.90 1629.93 S 363.36 E 5968913.27 N 642976.27 E 19.118 1209,97 9526.54 79,650 190.030 8930.44 9007.34 1670.48 S 358.32 E 5968872.63 N 642972.00 E 23.262 1247,33 9555.08 84.490 195.320 8934.38 9011.28 1698.04 S 352.12 E 5968844.96 N 642966.32 E 24.988 1274,15 9586.16 84.050 198.850 8937.49 9014.39 1727.59 S 343.03 E 5968815.24 N 642957.80 E 11,389 1304.16 9627.25 80,880 205,540 8942.88 9019.78 1765.29 S 327.66 E 5968777.26 N 642943.15 E 17.888 1344.39 9665.18 82.730 208.710 8948.29 9025.19 1798.69 S 310.55 E 5968743.53 N 642926.67 E 9.603 1381.84 9697.91 88.190 208.010 8950.88 9027.78 1827.39 S 295.06 E 5968714.54 N 642911.73 E 16.818 1414.42 9730.78 89.600 212.410 8951.51 9028.41 1855.79 S 278.52 E 5968685.84 N 642895,74 E 14,054 1447.27 9762.03 90.570 215.940 8951.46 9028.36 1881.63 S 260.97 E 5968659.66 N 642878.68 E 11.715 1478.46 9804.63 88.810 222.630 8951.70 9028.60 1914.59 S 234.02 E 5968626.21 N 642852.36 E 16.238 1520.59 9835.98 89,160 226.690 8952.25 9029.15 1936.88 S 211.99 E 5968603.50 N 642830.76 E 12.997 1551,05 9865.58 89.430 231.090 8952.62 9029.52 1956.33 S 189.69 E 5968583.62 N 642808.84 E 14.892 1579.21 9895.41 86.610 236,910 8953.65 9030.55 1973.85 S 165.59 E 5968565.65 N 642785.07 E 21.668 1606.63 9930.88 84.41 0 230.210 8956.43 9033.33 1994.84 S 137,16 E 5968544.13 N 642757,04 E 19.825 1639.27 9962.66 85.900 225,100 8959.11 9036.01 2016.16 S 113.76 E 5968522.37 N 642734.06 E 16.693 1669.59 ~ 9992.78 89.430 221 .400 8960,34 9037.24 2038.07 S 93.15 E 5968500.06 N 642713,86 E 16.969 1698.99 10053.93 89.340 210,300 8961,00 9037.90 2087.56 S 57.39 E 5968449.91 N 642679.05 E 18.152 1759.83 10115.03 95.150 203.600 8958,60 9035,50 2141.92 S 29.75 E 5968395.03 N 642652.44 E 14.504 1820.67 10149.05 94.630 211 , 180 8955,70 9032.60 2172.00 S 14.16 E 5968364.66 N 642637.44 E 22.252 1854.47 10183.12 89.250 212,590 8954,55 9031.45 2200.90 S 3.82W 5968335.43 N 642620.01 E 16,323 1888.50 10214.29 89.870 215,940 8954,79 9031.69 2226.65 S 21.36 W 5968309,34 N 642602.95 E 10.930 1919.62 10244.84 90.750 220,170 8954.62 9031.52 2250.70 S 40.19 W 5968284.94 N 642584.59 E 14.142 1949,93 10275.79 89.340 223.160 8954,60 9031.50 2273.82 S 60.76 W 5968261.43 N 642564.46 E 10.681 1980.34 ... ----,..-------------.-- ----.-- 19 November, 2002 - 16:12 Page 20f4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA J Pad - J-27A Your Ref: API 500292173301 Job No. AKMW2217B, Surveyed: 13 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10306.62 88.370 225.280 8955.21 9032.11 2295.91 S 82.26 W 5968238.94 N 642543.39 E 7.561 2010,34 10344.40 88.280 229.150 8956.32 9033.22 2321.56 S 109.97 W 5968212.77 N 642516.17 E 10.242 2046,60 10388.29 91.190 226.510 8956,52 9033.42 2351.02 S 142.49 W 5968182.70 N 642484.21 E 8.952 2088.60 10417.29 90.930 224,750 8955.98 9032.88 2371.29 S 163.22 W 5968162.04 N 642463.88 E 6.134 2116.65 10453.97 88.990 219,640 8956.01 9032.91 2398.46 S 187.84 W 5968134.41 N 642439.77 E 14.901 2152.62 217.000 8956,73 9033.63 2426.64 S 210.11 W 5968105.81 N ~. 10489.90 88,720 642418.04 E 7.384 2188.25 10524.27 88.190 213.470 8957,65 9034.55 2454.69 S 229.93 W 5968077.38 N 642398.75 E 10.382 2222.51 10551,50 85.460 208.010 8959,16 9036.06 2478.05 S 243.82 W 5968053.76 N 642385,31 E 22.389 2249.68 10574.00 85,460 208.010 8960,94 9037.84 2497.85 S 254.36 W 5968033.76 N 642375.15 E 0.000 2272.08 Projected Survey All data is in Feet (US) unless otherwise stated, Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and .Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 211.000° (True). Magnetic Declination at Surface is 25,981 °(1 0-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 10574.00ft., The Bottom Hole Displacement is 2510,77ft., in the Direction of 185.814° (True). Comments ~. Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9200,00 9276.00 10574.00 8816,79 8878,60 9037.84 1421,94 S 1464.64 S 2497.85 S 334.02 E 345.56 E 254.36 W Tie On Point Window Point Projected SUNey --_...---___~__d._-V---.'-'-- -. .--.-- -._- ---_._._------_._-~---- 19 November, 2002 - 16:12 Page 3 0'4 Dril/Quest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA J Pad - J-27 A Your Ref: AP/500292173301 Job No. AKMW22178, Surveyed: 13 November, 2002 North Slope Alaska BPXA Survey tool program for J-27 A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 9200,00 0,00 9200.00 8816,79 10574.00 8816.79 AK-1 BP _HG - BP High Accuracy Gyro(J-27) 9037.84 MWD Magnetic(J-27A) '-/ '-/ ~ -.. ~---_._--_._---.-~-- . --~~~-H___-_----~-- ~-~--' 19 November, 2002 - 16:12 Page 4 0(4 DrillQuest 3.03.02.004 ') ~u!ÆlrŒ ffi)~ Æ.\.\@fV(Iii\..8\. Lfu @ Ü~ lr\J TONY KNOWLES, GOVERNOR AlfA~1iA. OIL A1ft) GAS CONSERVATION COMMISSION 333 w. -¡rtt AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279.1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BPExploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudboe Bay Unit J-27 A BP Exploration (Alaska), Inc. Permit No: 202-200 Surface Location: 800' SNL, 1771' WEL, Sec. 09, T11N, R13E, UM Bottomhole Location: 3278' SNL, 2024' WEL, Sec. 09, T11N, R13E,UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. . The 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 fJ Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this~ day of September, 2002 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encI. 1 a. Type of work 0 Drill II Redrill 0 Re-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 800' SNL, 1771' WEL, SEC. 09, T11N, R13E, UM At top of productive interval 2039' SNL, 14781 WEL, SEC. 09, T11 N, R13E, UM At total depth 3278' SNL, 2024' WEL, SEC. 09, T11 N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028284, 2002' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9314' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Hole Casina Weiaht Grade Couplina 3-3/4" 3-1/2" x 3-3116" 8,81#/6.2# L-80 ST-L x 2-7/8" 6,16# '\ STATE OF ALASKA ALASKA '- IL AND GAS CONSERVATION COMrv¡.~ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 76.90' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028281 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / J-27 A 9. Approximate spud d~ 09-30-02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10600' MD 18970' TVD 17. Anticipated pressure {S;7'20 AAC 25.035 (e) (2)} 90 0 Maximum surface 2280 psig, At total depth (TVD) 8800' I 3337 psig Setting Depth . TOD Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 2160' 8440' 8105' 10600' 8970' 101 cu ft Class 'G' ./ ~4A- 'lz'l/dJ1- ~CjIÞ51~ 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 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 9700 feet 9216 feet 9651 feet 9178 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 8 cu yd Concrete 110' 110' 1667 cu ft of PF 'E', 2055 cu ft PF 2683' 2683' 1744 cu ft Class 'GI 8699' 8399' 430 cu ft Class 'G1 8451' - 9697' 8190' - 9214' 110' 20" 2683' 13-3/8" 8699' 9-5/8" 1246' 7" true vertical Open: 9342' - 9346' , 9450' - 9480' , 9500' - 9530' Open: 8932' - 8935' , 9019' - 9043' , 9059' - 9083' Perforation depth: measured 20. Attachments 181 Filing Fee 0 Property Plat 181 BOP Sketch 0 Diverter Sketch 181 Drilling' Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By Name/Number: Sondra Stewman, 564-4750 21. ~~:::y ::~~::~~%jiS~ and correcl I 3;E~~:ineer . Dale 9//9 /02- Permit Number API Number APpr~val Jate See cover letter Z02- - .2.. 00 50- 029-21733-01 ~ ~() b,^ for other reauirements Conditions of Approval: Samples Required 0 Yes I:!I No Mud Log Re uired 0 Yes I!I No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required 9 Yes D No Required Working Pressure for BOPE D 2K D 3K D 4K 0 5K D 10K D 15K D 3.5K psi for CTU Other: TëSt- Bo PE ~ ~50o PI,,' . ç~~:C;~AL 3:G(~r:::~ ""V D T;:aYlcr SOtu,,~~,,~" Approved By Form 1 0-401 Rev. 12-01-85 Date c' ?f) n~ Su :>mit In ,Triplicate I~."o.~ ) ) BP J-27a CTD Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for J-27. The coil sidetrack, J-27a, will exit the 7" casing in the Ivishak Zone 2 formation and target Zone 2. / Phase 1: Prep work. Planned ASAP. i 1. Set plug and perform combo MIT IA x T / 2. Slick line set plug in XN at 9360' 3. Eline to set whipstock at 9314' Phase 2: Mill window, Drill and Complete sidetrack: Planned for September 30,2002. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Mud Program: . Phase 2: Mill with seawater/biozan, drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: / /' /' . The production liner will be 3-1/2 ST-L x 3 3/16" TC II x 2 7/8" ST-L from TD to approx. 8,440'MD (-810~_~~S). . Liner cement volume will a minimum t~~. 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. / Directional . See attached directional plan. Max. planned hole angle is 90 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray, Resistivity will be run over all of the open hole section. Hazards . J-27 last test was 5ppm H2S. J pad has no production over 100ppm H2S. /' . Two fault crossings expected, risk of lost circulation is moderate. Reservoir Pressure Res. press. is estimateçt to be 3337 psi at 8800'ss (7.3 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2280 psi. / '. TREE = . 6" CrN WELLHEAD = McEVOY AëTOÄ'TÕ"Fr;-'~~ÄXELSÕÑ . KB-:-ã.E\r;~-,-,w,,,w-"-76:"93"; 13'r=:^Ë['Bl";-""""""w,,w'-"36:S5'" 'K-6¡;-;WU"~N'W,"""'_N',"-'W'N__-63ÖÕ;' ^Mãx'Ãñgìe;;-""""38'@"970Õ' 'BãtumMÕ-;-~~~W-^~-92-j4' Dâtûm ñ7Ö';-'-'-^88Öö"SS 5-1/2" BUlTTBG, 17#, L-80, -i 0,0232 bpf, 10 = 4.892" I TOP OF 4-1/2" TBG l-i 113-3/8" CSG, 72#, L-80, BTRS, ID = 12.347" 1-1 Minimum 10 = 3.725" @ 9360' 4-1/2" OTIS XN NIPPLE ) J-27 8) 2092' 1 \ I 2092' ~ 2683' ~ l - I 9-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" 1-1 4580' r-- 1 TOP OF 9-5/8" CSG 1-1 4580' ~ --. II L :8: 1 TOP OF 7" LNR BOT HNGR 1-1 8451' J I :8:-, I I ~ ~ J ~ 14-1/2" TBG, 12,6#, L-80, 0.0152 bpf, ID = 3,958" 1-1 8490' 19-5/8" CSG, 47#, L-80, BTRS, 10 = 8,681" l-i 8698' ~ PERFORA TION SUMMARY REF LOG: BHCS ON 06/26/87 ANGLE AT TOP PERF: 37 @ 9450' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 9450-9480 0 9/15/87 3-3/8" 4 9500-9530 0 8/22/94 8 8 )( r PBTD 1-1 9651' I I 7" LNR, 26#, L-80, LJ4S, 0.0383 bpf, 10 = 6.276" l-i 9697' 1 DATE REVBY COMMENTS DATE REVBY 06/87 ORIGINAL COMPLETION 03/12/01 SIS-CS CONVERTED TO CANVAS 03/12/01 SIS-MD FINAL 10/06/01 RNITP CORRECTIONS COMMENTS ~ ~ SAFE' ")>TES ,I 2064' 1-1 CAMCO SSSV LANDING NIP, 10 = 4.562" 1 2092' 1-15-12" X 4-1/2" XO 1 ~ ST MD TVD 5 3202 3146 4 5397 5249 3 7022 6921 2 8036 7791 1 8196 7850 GAS LIFT MANDRELS DE\! TYPE V LV LATCH PORT DATE 3 OTIS RA 1 OTIS RA 23 OTIS RA 34 OTIS RA 35 OTIS RA 8307' 1-1 BKR L SLIDING SLV, ID = 3.813" 1 8368' 1-1 TOP OF PBR I 8383' 1-19-5/8 TrN HBBP PKR, 10 = 4,750" 1 8424' 1-14-1/2" OTIS X NIP, ID = 3.813" I 8456' 1-14-1/2" OTIS X NIP, ID = 3,813" I 8490' 1-14-1/2" WLEG 1 8484' 1-1 ELMD TT LOG UNA V AILABLE 1 9334' 1-1 OTIS WD PKR 1 9354' I-iOTIS HLC PKR I 9360' 1-14-1/2" OTIS XN NIP, ID = 3.725" I 9362' 1-14-1/2" SHEAROUT SUB 1 9361' 1-1 ELMO TT LOGGED 08/03/96 I PRUDHOE BAY UNIT WELL: J-27 PERMIT No: 187-0580 API No: 50-029-21733-00 SEe 9, 11N, 13E BP Exploration (Alaska) , TREE:::!' 6" erN McEVOY AXB.SON . ." '..,,-~ "-.', "u."" . 76.93' 36.55' )- walHEAD = ACTUATOR ::: .. .. .. _.~. .. KB. B.EV = BF. 8.EV = KOP= . . -" . . Max ~ngle_=.. Datum MD = ... ~... ..,.-.'~. u.. '" Datum "TVD = J-27A 8 9274' - .' -,~..... ".~. ....... 8800' SS 5-1/2" BUTTTBG, 17#,l-80, -I 2092' 1 \ 0.0232 bpf, D = 4.892" ITOPOF4-1/2"TBG 1-1 2092' ~ 113-3/8" CSG, 72#, L-80, BTRS, D = 12.347" 1-1 2683' ~ I Minimum 10 = .J 1 9-5/8" CSG, 47#, l-80, NSCC, ID = 8.681" - 4580' I TOP OF 9-5/8" BTRS CSG - 4580' ~ ~ II L J 1 Z Z, 1 3,5" XN Nip - 2.75" ID - 8450' ~ I TOP OF 7" LNR - 8451' --..... I 1-: I 1 14-112" TBG, 12.6#, l-80, 0.0152 bpf, D = 3.958" 1-1 8490' 1 I 19-5/8" CSG, 47#, l-80, BTRS, D = 8.681" 1-1 8698' ~ 1 31/2" x 3 3/16" XO H 9254' 1 PERFORATION SUMMARY REF lOG: BHeS ON 06/26/87 ANGLE AT TOP PERF: 37 @ 9450' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 3-3/8" 4 9450-9480 0 9/15/87 3-3/8" 4 9500-9530 0 8/22/94 . .....:J..T'."..,. ~...",-",~.~ ~. I'" 0.1 ~ I PBTD H 9651' t 1 7" lNR, 26#, l-80, U4S, 0.0383 bpf, Ð = 6.276" H 969T t DATE 06/87 03112/01 03112/01 10/06/01 09/18/02 COMMENTS REV BY DATE REV BY COMlt1ENTS ORIGt-JAl COm.EOON SIS-CS CONVERTED TO CAW AS SIS-M:> Ft-JAl RNITP CORRECTIONS MSE PROPOSB:> ern SÐETRACK SAF ) .iOTES 2064' 1-1 CAMCO SSSV LANDING NIP, ID = 4.562" 1 2092' 1-15-12" X 4-1/2" XO 1 ~ ST MD "TVD 5 3202 3146 4 5397 5249 3 7022 6921 2 8036 7791 1 8196 7850 GAS lIFT MANDRElS DEV 1YPE Vl V LATCH PORT DATE 3 OTIS RA 1 OTIS RA 23 OTIS RA 34 OTIS RA 35 OTIS RA '4' 8307' H BKR l SLIDING Sl V, ID = 3.813" 1 8368' 1-1 TOP OF PBR 1 8383' H9-5/8 TIN HBBP PKR, ID = 4.750" 1 8424' 1-14-1/2" OTIS X NIP, ID = 3.813" 1 8440' 1-1 Top of 31/2" x 3-3/16" x 27/8" Liner I 8456' 1-14-1/2" OTIS X NIP, ID = 3.813" 1 8490' - 4-1/2" WlEG 1 8484' - B.MDlTlOG UNAVAIlABLE 1 H Top of Cement 1-13-3/16 x 2-7/8 X-over 1 - .--:->::-,¡---, -"'-r-- - - r-} .. , 1 31/2" X 3-3/16" X 2-7/8" cmt'ed and perfed 1--1 10600' I 9314' 1-1 rvechanical Whipstock I 9334' - OTIS WD PKR \ 9354' - OTIS HLC PKR 9360' H4-1/2" OTIS XN NIP,ID = 3.725" SET A.UG I 9362' - 4-1/2" SHEA ROUT SUB 1 9361' - aMD IT lOGGB:> 08/03/96 I PRUDHOE BAY UNIT W8.L: J-27A PERMIT No: API No: 50-029-21733-01 SEC9,11N,13E BP Exploration (Alaska) ------~----- Direct (e07) 267-6613 E-mail: brij.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 T ^M ¿ LEGEND J-27 (J-27) - Plan#4 J-27A - Plan #4 Plan: Plan #4 (J-27/Plan#4 J-27A) Created By: Brij Potnis Date: 9/18/2002 Azimuths to True North Magnetic North: 26.03. Magnetic Field Strength: 57527nT Dip Angle: 80.81. Date: 9/18/2002 Model: BGGM2002 ~' ~..r¡'2j BP Amoco h~1?EQ Contact information: P.""~=-::;:£: RI.. R.t.O.ltlftU W8LLPATH DnAlL8 "..114 J.27A lOO282UUOt J.27 uoo.oo ~-.,;~ ,~ Nordic 2 38 I 27 'ft~t8" 00100 78,8Oft 8450-=- v.a-:::.: o.'m!: 2t1.oo. ::::~ 0.00 ~=~= 0.00 -1000 - REFERENCE INFORMATION .~:- ...ji..,;i~ ¡Iii,', R~r,,~..,:~ Well Centre: J-27, True North . ; ';'.:,?' .'. ~ : I::,: ~~:;: ~::::: ~ro~~~i %~8BJg~Õ~)el Measuraa Oepm Kelerenca: 38: 276/14/198700:00 76.90 Calculation Method: Minimum Curvature .... 1 8300.00 38.80 184.07 2 8314.00 n.n 1"'" :I 8U"'00 "." 184.14 4 88...23 10.00 181.a. I "8&0 80.00 187.". 8 8808.23 80.00 IU.7. 7 100_13 88.12 10.11 . 10381.23 ...n IN.I4 . 10e00.oo 88." U2." .8C'tIONDITAlU +fI" - 8811.M .1477." 3..31 &an.n -101.13 3151.17 ""'78 -1""'.20 384." ....... -1708.41 371.82 88MH -170.12 3'141 :::t.:: :::~ ~....;iT..t: ....." ..22M.oe "70.18 -2478,83 .147." 0.00 0.00 1088.88 1.32 310.12 10n.41 8.00 10.00 1100.80 22.00 11.00 1271.12 22.00 80.00 1342.28 12.00 10.00 1481.28 12.00 83.20 1707.11 12.00 210.00 20n.8' 12.00 80.00 2212.0t DL.. n:.ee \'he T.rg8t ANNOTATION' TVO MD AallOlaUOtI 1121,18 1380,00 TIP "12,71 13t<l.OO KOP IHI,78 'n.I.80 1 11""1 8111,2J 2 ......, 18H,2J , ....... '_.2J . ""'" tOO38.2J I IH','" 10181,2J . 1"°'" to_.OO TD TARGET DETAILS TVD +N/-S +EJ.JN Shape ~~~~~ 1 805g.~ :~rn-~ ~~~ ~~ J-21ATU =.~ ~ffi1~ .m~ ~: 8500-- 8550-::=- 8600-=- . - -. C ~ 8650 ~' II) 8700-':T - -23QO-=- . -2400 - -2500 - -2600 - . 5 8750-: . t - " 8800:-' 'i 885c0 1: 8900-:--- G» _. > . 8950::.; ë . ... 9000-::' 400 500 600 West(-)/East(+) [100ft/in] j I I 905<>--:::-1 " I 9100~ I 915~ . . .H' 9200--¡! ¡ ¡ i ¡ i ì I ¡ i I ì ¡I ¡ii l i i ¡¡UII i 850 900 950 1000 1050 1100 9/18/2002 5:31 PM --" ,-ç ') ) BP Baker Hughes INTEQ Planning Report ........-......--..---...----- 1N"fEQ Company:'BPAmoeo ' , Fie.~:, 'Prudl1O&f3ay .' Site:. PBJPad WeÙ: J~27,' , WeUpath; Pfé1n#4 .J/J.7A , Dattki,:9/1812002' ,. Tiíne;', J7:3t50 'C9~rdQ¡~~)':I{~~e~~:, W~II,;J~'l:?..:Tru,~;North ,-Y~~aI(f~J»R~er~n~; '. '$~~~:mt.~~ll$"al~vøl S~~~(¥,~)~ef~~nee:,>. .. ''JV~I,I.(O;.oON.,O.9PF.¥H.OQAzi) '. 'SurV~yçalc,~~ati~.M~~:. Mimmu.mGurvature' . Db: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: PB J Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: J-27 J-27 Well Position: Well: Page: Oraclè Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 5968224.22 ft 641155.79 ft Latitude: Longitude: North Reference: Grid Convergence: 70 19 14.845 N 148 51 20.092 W True 1.08 deg Slot Name: 27 +N/-S 2284.73 ft Northing: 5970536.00 ft Latitude: +E/-W 1469.55 ft Easting: 642582.00 ft Longitude: Position Uncertainty: 0.00 ft 70 19 37.314 N 148 50 37.194 W Wellpath: Plan#4 J-27 A 500292173301 Current Datum: 38: 276/14/198700:00 Magnetic Data: 9/18/2002 Field Strength: 57527 nT Vertical Section: Depth From (TVD) ft 0,00 Targets Name Description Dip. Dir. J-27 A Polygon4.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 J-27A Fault1 -Plan out by 5.96 at J-27 A T 4.2 8920.00 8920,00 8955,00 8960.00 J-27A Fault2 J-27A T4.1 J-27A T4.3 8965.00 8970.00 J-27A Fault3 8970,00 9000.00 J-27A Fault4 Annotation MD ft 9300,00 9314,00 9334,00 TVD ft 8821.36 8832.73 8848.79 TIP KOP 1 Drilled From: J-27 Tie-on Depth: 9300.00 ft Height 76.90 ft Above System Datum: Mean Sea level Declination: 26.03 deg Mag Dip Angle: 80.81 deg +N/-S +E/-W Direction ft ft deg 0.00 0.00 211.00 l\tJp : l\i.p , <";';"";.L~titude:. ~ ~....I,.oQ~de..'.--> +N/~S +Eì;,W NÒrthÙJg East)og' ,'DegMin ....Seç DegMin:. Sec ft ' 'ft ft, ft -1992.03 290.22 5968550.00 642910.00 70 19 17.722 N 148 5028.724 W -2425.20 -338.17 5968105.00 642290.00 70 19 13.462 N 148 5047.062 W -2537.76 -205.28 5967994.99 642425.00 70 19 12,355 N 148 50 43.184 W -1992.03 290.22 5968550.00 642910.00 70 19 17.722 N 148 50 28.724 W -1764.43 419.58 5968780,00 643035.00 70 19 19.961 N 148 50 24.948 W -1540.31 468.85 5969005.00 643080.00 70 19 22,165 N 148 50 23.510 W -1304.38 423.32 5969240.00 643030.00 70 19 24.485 N 148 50 24.838 W -1316.05 248.05 5969225.00 642855.00 70 19 24.370 N 148 50 29.954 W -1532.55 323.96 5969010.00 642935.00 70 19 22.241 N 148 50 27,739 W -1583.42 369.01 5968960.00 642981.00 70 19 21.741 N 148 50 26.424 W -1577.46 368.96 5968965.96 642980.84 70 19 21.799 N 148 50 26,425 W -1914.02 290.71 5968628.00 642909.00 70 19 18.489 N 148 50 28.710 W -1837.92 339.16 5968705.00 642956,00 70 19 19.238 N 148 50 27.295 W -1687.23 410.05 5968857.00 643024.00 70 19 20,720 N 148 50 25.226 W -2481.75 -257.22 5968050.00 642372.00 70 19 12.906 N 148 50 44.700 W -2124.11 29.65 5968413.00 642652.00 70 19 16.423 N 148 50 36.328 W -2717.98 -458.76 5967810.00 642175.00 70 19 10.582 N 148 50 50.581 W ') ) ...,.'. -. INTEQ BP Baker Hughes INTEQ Planning Report Company: BPAl11òcÓ 'n.te::'9/l81200Z" ,Tiïné:17;31:'50 . 'Pag~: Fißld: ~itJdhoØBC1Y ~rdjRåtf.'(l'(E)~eter~:' '.,WèJl:J~27, TrúeNófth Site: PBJPaØ. Yer;tiç,aI(r~~p)~~er~I1~; ~y$~~m::M~hS~~~vel. Well: J.;27 ~~i~~(V~),I{~fe~nç~:: " ,VVøUJ().P~N;O;09~.211;OOAzi) Wellpath: . Pféln#4J.;27A . ~ûtveyèalCülli:ti91f M~~Øð: . ,.MinimumCùrvature " ,. Db: Oré¡lcte Annotation MD TVD ft ft 9581.23 8954.96 2 9656.23 8954.96 3 9806.23 8954.96 4 10036.23 8957.99 5 10361.23 8965.76 6 10600.00 8970,36 TO Plan: Plan #4 Date Composed: 9/18/2002 Identical to lamar's Plan #4 Version: 4 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD lnel AzOO TV» +Nl-S -fE/.;;W DLS ,BoW' Tüi:o TFO T;.rg~t ft deg deg ft ft ft deg/1 OOftdeg/1ÒOft'degI1~ , 'deg 9300,00 35.60 164.07 8821.36 -1477.89 349.31 0,00 0.00 0.00 0.00 9314.00 35.72 163.83 8832.73 -1485,73 351.57 1.32 0.86 -1.71 310,52 9334,00 37.49 164.34 8848.79 -1497.20 354,84 9.00 8.87 2.57 10.00 9581,23 90.00 181,28 8954,96 -1709.41 373.82 22.00 21,24 6.85 21.00 9656.23 90.00 197.78 8954,96 -1783.12 361.45 22.00 0.00 22.00 90.00 9806.23 90.00 215.78 8954.96 -1916.48 294.13 12.00 0.00 12.00 90.00 10036.23 88.52 243.35 8957.99 -2064.21 120.78 12.00 -0.64 11,98 93.20 10361.23 88.85 204.34 8965.76 -2294.06 -99.94 12.00 0.10 -12.00 270.00 10600.00 88.99 232.99 8970.36 -2478.53 -247.54 12.00 0.06 12.00 90,00 Survey MD Inel Azim SSTVD N/S ElW ,MapN MapE VS OLS TFO, Tool ft deg deg ft ft ft It ,ft ' ft degl100ft deg 9300.00 35.60 164.07 8821.36 -1477,89 349.31 5969065,13 642959.30 1086.89 0,00 0.00 TIP 9314.00 35.72 163.83 8832.73 -1485.73 351.57 5969057.33 642961.71 1092.45 1.32 310.52 KOP 9325.00 36.70 164.12 8841.61 -1491.98 353.36 5969051.12 642963.62 1096.88 9.00 10.00 MWD 9334.00 37.49 164,34 8848.79 -1497.20 354.84 5969045.93 642965,20 1100.60 9.00 9.77 1 9350.00 40.80 166.27 8861.19 -1506.97 357.39 5969036.21 642967.94 1107.66 22.00 21.00 MWD 9375.00 46.01 168.82 8879,35 -1523.74 361.08 5969019.51 642971.94 1120.13 ;;2.00 19.50 MWD 9400.00 51.27 170.96 8895.87 -1542.21 364.36 5969001.11 642975.57 1134.27 22.00 17.65 MWD 9425.00 56.57 172,80 8910.58 -1562.20 367.20 5968981.18 642978,79 1149.95 22.00 16.24 MWD 9443.01 60.40 173.99 8920,00 -1577.46 368.96 5968965.96 642980.84 1162.11 22.00 15.15 J-27A Fa 9450.00 61.89 174.42 8923.37 -1583.54 369.58 5968959.89 642981.57 1167.01 22.00 14.53 MWD 9475.00 67.23 175.90 8934.11 -1606.03 371.48 5968937.44 642983.90 1185.31 22.00 14.32 MWD 9500.00 72.57 177.26 8942.70 -1629.46 372.87 5968914.05 642985.74 1204.67 22.00 13,68 MWD 9525.00 77.93 178.54 8949.06 -1653.61 373.75 5968889.92 642987.08 1224.92 22.00 13.22 MWD 9550.00 83.30 179.78 8953.13 -1678.26 374,11 5968865.28 642987.91 1245.87 22.00 12.89 MWD 9575.00 88.66 180,98 8954.89 -1703.19 373.95 5968840.36 642988.21 1267.32 22,00 12,69 MWD 9581.23 90.00 181.28 8954.96 -1709.41 373.82 5968834.13 642988.21 1272,72 22.00 12.60 2 9600.00 90.00 185.41 8954.96 -1728.15 372.73 5968815.38 642987.47 1289.35 22.00 90.00 MWD 9625.00 90.00 190.91 8954.96 -1752,89 369.18 5968790.58 642984.39 1312.38 22.00 90.00 MWD 9650.00 90.00 196.41 8954.96 -1777.17 363.28 5968766,19 642978.95 1336.23 22.00 90,00 MWD 9656.23 90.00 197.78 8954.96 -1783.12 361.45 5968760.21 642977.24 1342,28 22.00 90.00 3 9675.00 90.00 200.04 8954.96 -1800.88 355.36 5968742.33 642971.49 1360.63 12.00 90.00 MWD 9700.00 90.00 203.04 8954.96 -1824.13 346.19 5968718.91 642962.76 1385.29 12.00 90.00 MWD 9725.00 90.00 206.04 8954.96 -1846.87 335.81 5968695.98 642952.81 1410,13 12.00 90.00 MWD 9750.00 90.00 209.04 8954,96 -1869.04 324.25 5968673.60 642941.68 1435.08 12.00 90.00 MWD 9775.00 90.00 212.04 8954.96 -1890.57 311.55 5968651.84 642929.39 1460.07 12.00 90.00 MWD 9800.00 90.00 215.04 8954.96 -1911.41 297.74 5968630.74 642915.98 1485,05 12.00 90.00 MWD 9806.23 90.00 215.78 8954.96 -1916.48 294.13 5968625.60 642912.47 1491.25 12.00 90.00 4 9825.00 89.87 218.03 8954.98 -1931.49 282.86 5968610.38 642901.49 1509.93 12.00 93.20 MWD 9850.00 89.71 221.03 8955.07 -1950.77 266.95 5968590.80 642885.95 1534.65 12.00 93.20 MWD 9875.00 89.54 224.02 8955.23 -1969.19 250.06 5968572.06 642869,41 1559.14 12.00 93.19 MWD ) BP ) -lr: Baker Hughes INTEQ Planning Report .......~---,....~~~~-- INTRQ Company:'. .BP:AmocO ' Ðatè::'911612002 '. - ,'tIJn'f;':,'11:31:5() , ;;~ag~:' . Fiêld.: PrOdtio&Bay ~r~llIate(NE),~t~çe:. W~Jt;-.J;21,Trqe_NQrth Sitê: PBJ Pa(i ¥~.~~;-(f¥!»-~ft~~~~ .' - Sy~'el'f1;M~f1~~:~Vel.,., . . Well: J..27 ~~i()..(YS)~efel'ê~~;; . '.' . .Wel:(p"00NJ(LOQe:J211J)0~) W~lIpatb: Plari#4J;.21A - $uJ'\reyç~l~n~tiOJl:M~o~: . Mirii\Tnjm Curvature .' _DÞ~ Oracle Survey MD Inel, AZim M'a,Pl\l1 l\1apJ! . VS I>LS T~O Tool' ft (i&g deg ft 'ft .-'~, dØQll00ft ti~ 9900.00 89.38 227.02 8955.47 -1986.71 232.22 5968554.22 642851.91 1583.34 12.00 93.17 MWD 9925.00 89.21 230.01 8955.78 -2003.26 213.50 5968537.31 642833.51 1607.17 12.00 93.14 MWD 9950.00 89.05 233.01 8956.16 -2018.82 193.93 5968521.39 642814.24 1630.58 12.00 93.10 MWD 9975.00 88.89 236.01 8956.61 -2033.33 173.58 5968506.49 642794.17 1653.50 12.00 93.06 MWD 10000.00 88.74 239.00 8957.12 -2046.76 152.50 5968492.67 642773.36 1675.87 12.00 93.00 MWD 10025.00 88.59 242.00 8957.71 -2059.06 130,75 5968479.95 642751.84 1697.62 12.00 92.94 MWD 10036.23 88.52 243.35 8957.99 -2064.21 120.78 5968474.61 642741.97 1707.17 12.00 92.87 5 10050.00 88.52 241.69 8958.35 -2070.57 108.57 5968468.03 642729.88 1718.91 12.00 270.00 MWD 10075.00 88.52 238.69 8958.99 -2082.99 86.89 5968455.20 642708.44 1740.72 12.00 270.04 MWD 10100.00 88.53 235.69 8959.64 -2096.53 65.88 5968441.26 642687.70 1763.15 12.00 270.12 MWD 10125.00 88.54 232.69 8960.21 -2111.15 45.62 5968426.26 642667.72 1786.12 12.00 270.20 MWD 10150.00 88.56 229,69 8960.91 -2126.81 26.15 5968410.23 642648.55 1809.57 12.00 270.27 MWD 10175.00 88.58 226.69 8961.53 -2143.47 7.52 5968393.22 642630.25 1833.44 12.00 270.35 MWD 10200.00 88.60 223.69 8962.14 -2161.09 -10.21 5968375.28 642612.86 1857.67 12.00 270.42 MWD 10225.00 88.63 220.69 8962.75 -2179.60 -26.99 5968356.45 642596.43 1882.18 12.00 270.50 MWD 10250.00 88.66 217,69 8963.34 -2198.97 -42.78 5968336.78 642581,02 1906.92 12.00 270.57 MWD 10275.00 88.70 214.68 8963.91 -2219.14 -57.53 5968316.34 642566.65 1931,81 12.00 270.64 MWD 10300.00 88.74 211.68 8964.47 -2240.06 -71.21 5968295.17 642553.37 1956.78 12.00 270.71 MWD 10325.00 88.78 208.68 8965.01 -2261.66 -83.78 5968273.33 642541.22 1981.77 12.00 270.78 MWD 10350.00 88.83 205.68 8965.54 -2283.89 -95.19 5968250.89 642530.23 2006.71 12.00 270,84 MWD 10361.23 88.85 204,34 8965.76 -2294.06 -99.94 5968240.63 642525.68 2017.87 12.00 270,91 6 10375.00 88.85 205.99 8966.04 -2306.53 -105.79 5968228.06 642520.06 2031,57 12.00 90.00 MWD 10400.00 88.85 208.99 8966.54 -2328.70 -117.33 5968205.67 642508.95 2056.51 12.00 89.97 MWD 10425.00 88.86 211.99 8967.04 -2350.23 -130.01 5968183.90 642496.68 2081.50 12.00 89.91 MWD 10450.00 88.87 214.99 8967.54 -2371.08 -143.80 5968162.80 642483.29 2106.47 12.00 89.85 MWD 10475.00 88,88 217.99 8968.03 -2391,17 -158.67 5968142.43 642468.81 2131.35 12.00 89.79 MWD 10500.00 88.90 220.99 8968.51 -2410.46 -174.56 5968122.85 642453.29 2156.07 12.00 89.73 MWD 10525.00 88.92 223.99 8968.99 -2428.88 -191.44 5968104.10 642436.76 2180.56 12.00 89,67 MWD 10550.00 88.94 226.99 8969.46 -2446.40 -209.27 5968086.25 642419.27 2204.76 12.00 89.61 MWD 10575.00 88.96 229,99 8969.92 -2462.97 -227.98 5968069.34 642400.88 2228.60 12.00 89.56 MWD 10600.00 88.99 232.99 8970.36 -2478.53 -247.54 5968053,41 642381.62 2252.01 12.00 89.50 TO ') BOP-Tree N ORt¿l C ) KB Elevation I<~;'.'"~......~....~........,l...,...........................,,~i~...~I~.~.~.............<"........I~I.I.~.....................~¡[¡¡¡¡¡¡¡¡¡¡M[. I I I ~ ~ lubrica~or JD = 6,375" with.6' Otis Unions t"".~t~_,:"" ~ 1'('" , 17 1116" 5000 psi BOP's. 10 = 7.06" I I I --1, I ....""...l..+---f7 1/16" 5000 psi, RX-46 I Bfind:she-ai'S ' I ~ Swab Valve I Tree Size I ssv I I Master Valve I t IOI11 ,.11C)J .......~IIIIIIIIIIIIIIIIIIII....-....... I . : ,. '" ,m '" ,m '" ,. ,. ,. ,. '" ,m ,. ,....; Base FlanQe I I . . 111111111111."..'"1'"'''' Page 1 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DATE CHECK NO. 08/01/02 H207048 VENDOR .1 DISCOUNT NET H $100.00 H 207048 8/01/02 CK0731020 Permit To Drill Fee :T-dlA PIs contact Sondra Stewman X4750 for check pick~ .~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ $100.00 BP EXPLORATION, P.O. BOX 196612 ANCHORAGE, No. H 20704-8 CONSOLIDATED COMMERCIAL ACCOUNT PAY TO THE ORDER OF Alaska Oil & Gas Conservation Corom 333 W 7th Ave, Ste 100 Anchorage, AK 99501 NOT VALID AFTER 120 DAYS .~ 118 20 ? 0 t. 8118 I: 0 t. ~ 2 0 ~ 8 ~ 51: 008 t. t. ~ ~ 118 :'"", .. ",",:' ': ,"., :':';,\::::::~:;ž.:~~.~~.~~i.~~:: ~S:::! \::: ~.;\ '.... ,.." ¡..'~;r' ~ ::''''''''':''''.'''''''''''''''':'''''' .{S~;~{f\ {0~::\\:~;~~:;~:~;);:~~:\1 I . ") ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME/'ßt:-A. {=-27A PTD# 20¿ - 2.. 00 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the. original API number stated above. In accordance with 20 AAC 25.005(1), 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 (SO 70/80) from records, data and logs acquired for well (name on permit). . 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. (Company 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. WELL PERMIT CHECKLIST COMPANY /J/lk WELL NAME /ÞAt' { v: 2. 7 A FIELD & POOL G <70/. <" ~ INIT CLASS .oe-v ¡Wð/ J ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. ~ . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . ~L ~ ~ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . ~ ~~¿ 9. Operator only affected party.. . . . . . . . . . . . .. . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located wlin area & strata authorized by injection order #~ (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE APPR DATE \iJ(;,A- 1/7,1101- 15. Conductor string provided. . . .. . . . . . . .. . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol ádequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . .. . 20. Casing designs adequate for C, T, B & permafrost. . .. . . . 21. Adequate tankage or reserve pit.. . . . . . . . .. . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to 3-ÇOO psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable... . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact name/phone for weekly progress reports. . . . . . . . (Service Well Only) GEOLOGY APPR DATE ~ V:{ %2- (Exploratory Only) PROGRAM: Exp - Dev K- Redrll ~ Re-Enter - Serv - Wellbore seg - GEOL AREA g-, d UNIT# / / b..ç" t'1 ON/OFF SHORE a 11) "" Y' N Y N Y N Y N Y N Y N Y N Y N Y N Y N ,Y N ~N ~ A/,Av ¥--N- ~^'I Å-- i~~TD~ * ~ '"l11.4(o'L J. ~ ~ tl1'f.-t J(.7 ep'1 N 1//1/;' {) l. ~ fo P ç¿ . N N ~ 1\1 /,4;- Y@ ~ Noll. GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RPL TEM JDH :r¡::::- JBR COT DTS WGA \¿J6k- MJW NtvØ ?/.1~Z.' Rev: 07/12/02 SFD- G:\geology\perm its\checklist.doc ) ') Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . . organize this category of information. ) aDa-aOD / lto 95 Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 04 10:08:46 2003 Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name..... ..UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: Writing Library. Scientific Technical Services J-27A 500292173301 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 04-APR-03 MWD RUN 1 MWD RUN 2 MWD RUN 3 MW2217800000 MW2217800000 MW2217800000 D. RICHARDSO D. RICHARDSO D. RICHARDSO SARBER/SEVCI SARBER/SEVCI SARBER/SEVCI MWD RUN 4 MWD RUN 5 MAD RUN 5 MW2217800000 MW2217800000 MW2217800000 D. RICHARDSO D. RICHARDSO D. RICHARDSO SARBER/SEVCI EGBEJIMBA/WH EGBEJIMBA/WH 9 11N 13E 800 1771 MSL 0) 76.93 39.43 ') ) # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.850 8490.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. MWD RUNS 1 - 5 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. RUNS 4 AND 5 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MAD PASS DATA (SGRC ONLY) ABOVE THE START OF RUN 1 ACQUIRED AFTER RUN 3 WERE MERGED WITH RUN 1 DATA. MAD PASS DATA ACQUIRED AFTER THE COMPLETION OF RUN 5 ARE PRESENTED SEPARATELY. 5. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE CNL LOG (NEAR COUNTS AND NEAR/FAR COUNT RATIO) RUN IN J-27A ON 15 NOVEMBER 2002. THESE PDC DATA WERE PROVIDED TO SSDS BY DEWAYNE SCHNORR ON 3 FEBRUARY 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1 - 5 REPRESENT WELL J-27A WITH API#: 50-029-21733-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10574'MD/8961'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . RESISTIVITY (EXTRA. RESISTIVITY (SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/04/04 ') Maximum Physical Record..65535 File Type............... .LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM RPX FET RPS $ 1 ') clipped curves¡ all bit runs merged. .5000 START DEPTH 9043.0 9298.0 9532.5 9532.5 9532.5 9532.5 9532.5 STOP DEPTH 10529.5 10574.0 10542.5 10542.5 10542.5 10542.5 10542.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE 9043.0 9047.5 9053.0 9066.5 9069.0 9075.5 9087.5 9101.5 9110.0 9133.0 9150.5 9160.0 9203.0 9215.5 9219.0 9238.5 9271.0 9276.5 9302.0 9304.0 9314.0 9336.5 9353.0 9363.5 9367.0 9386.5 9389.5 9402.0 9423.5 9460.5 9530.0 9654.0 9934.0 9946.5 9956.5 10045.0 10201.0 10222.5 10295.0 DEPTH GR 9045.5 9050.0 9055.5 9066.5 9069.5 9075.0 9087.0 9100.0 9108.0 9134.0 9152.5 9161.0 9203.0 9214.5 9216.0 9236.0 9272.5 9276.5 9303.0 9305.0 9314.5 9337.5 9358.5 9365.5 9372.0 9390.0 9394.5 9405.0 9427.5 9461.5 9532.0 9654.0 9933.5 9947.5 9956.5 10042.5 10197.5 10223.0 10296.5 ) ") 10377.0 10409.5 10574.0 $ 10376.0 10409.5 10574.0 # MERGED PBU MWD MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 4 5 MERGE TOP 9043.0 9301.0 9403.0 9565.0 10185.0 MERGE BASE 9301.0 9403.0 9565.0 10185.0 10577.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..,...............O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9043 10574 9808.5 3063 9043 10574 ROP MWD FT/H 0.38 1436.92 78.1171 2553 9298 10574 GR MWD API 7.99 186.07 30.9888 2918 9043 10529.5 RPX MWD OHMM 1.94 24.06 9.93488 2021 9532.5 10542.5 RPS MWD OHMM 2.38 24.15 11.0553 2021 9532.5 10542.5 RPM MWD OHMM 2.78 24.52 11.3871 2021 9532.5 10542.5 RPD MWD OHMM 4.51 23.3 11.6967 2021 9532.5 10542.5 FET MWD HOUR 0.2422 10.1088 1.57563 2021 9532.5 10542.5 First Reading For Entire File......... .9043 Last Reading For Entire File.......... .10574 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 ') ) Physical EOF File Header Service name........ .... .STSLIB.002 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPM RPD RPS RPX FET RAT $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 10034.0 10046.5 10046.5 10046.5 10046.5 10046.5 10078.0 STOP DEPTH 10531.5 10545.5 10545.5 10545.5 10545.5 10545.5 10577.0 # MERGED DATA PBU TOOL MWD $ SOURCE CODE MAD RUN NO. MAD PASS NO. MERGE TOP 5 1 10032.0 MERGE BASE 10577.0 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last ') ') Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10034 10577 10305.5 1087 10034 10577 RAT MAD FT/H 10.21 430.15 376.841 999 10078 10577 GR MAD API 13.21 153.83 31.8646 996 10034 10531.5 RPX MAD OHMM 1.69 20.12 6.21843 999 10046.5 10545.5 RPS MAD OHMM 2.07 26.15 7.88909 999 10046.5 10545.5 RPM MAD OHMM 2.56 27.8 8.85928 999 10046.5 10545.5 RPD MAD OHMM 4.25 27.21 10.1834 999 10046.5 10545.5 FET MAD HOUR 2.11253 27.8758 11.1896 999 10046.5 10545.5 First Reading For Entire File......... .10034 Last Reading For Entire File.......... .10577 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation..... ..03/04/04 Maximum Physical Record. .65535 File Type........ . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record..65535 File Type... . . . . . . . . . . . . . LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9043.0 ROP 9104.0 $ 3 header data for each bit run in separate files. 1 .5000 STOP DEPTH 9273.0 9301.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11-NOV-02 Insite 4.3 Memory 9301.0 9045.0 9301.0 .0 .0 # ) ') TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 8490.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.60 65.0 9.5 24000 1.0 .000 .000 .000 .000 .0 74.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record.... . . . . . . . . .Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9043 9301 9172 517 9043 9301 ROP MWD010 FT/H 0.38 220.66 111.449 96 9104 9301 GR MWD010 API 7.99 70.29 22.0455 402 9043 9273 First Reading For Entire File......... .9043 Last Reading For Entire File.......... .9301 File Trailer Service name............ .STSLIB.003 ') ') service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 2 .5000 START DEPTH 9273.5 9301.5 STOP DEPTH 9375.0 9403.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11-NOV-02 Insite 4.3 Memory 9403.0 9301.0 9403.0 35.8 53.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 8490.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT Flo Pro 8.70 65.0 9.5 24000 5.0 TEMPERATURE (DEGF) ) ) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 .0 141.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... . . .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9273.5 9403 9338.25 260 9273.5 9403 ROP MWD020 FT/H 0.67 47.69 28.4799 204 9301.5 9403 GR MWD020 API 12.11 112.69 32.0283 204 9273.5 9375 First Reading For Entire File......... .9273.5 Last Reading For Entire File.......... .9403 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 ) File Type................LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 ) header data for each bit run in separate files. 3 .5000 START DEPTH 9375.5 9403.5 STOP DEPTH 9537.0 9565.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 11-NOV-02 Insite 4.3 Memory 9565.0 9403.0 9565.0 61.5 78.7 TOOL NUMBER 82758 3.750 8490.0 Flo Pro 8.70 65.0 7.5 24000 2.0 .000 .000 .000 .000 .0 148.9 .0 .0 ) ) Data Record Type..................O Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9375.5 9565 9470.25 380 9375.5 9565 ROP MWD030 FT/H 0.5 142.16 89.1423 324 9403.5 9565 GR MWD030 API 12.4 72.87 29.1035 324 9375.5 9537 First Reading For Entire File......... .9375.5 Last Reading For Entire File.......... .9565 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/04/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX 6 header data for each bit run in separate files. 4 .5000 START DEPTH 9534.5 9534.5 9534.5 9534.5 STOP DEPTH 10153.5 10153.5 10153.5 10153.5 ) RPS GR ROP $ 9534.5 9537.5 9565.5 10153.5 10139.5 10185.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing........ ............ .60 .1IN Max frames per record........... ..Undefined Absent value.... ..... '."" ...., ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ') 11-NOV-02 Insite 4.3 Memory 10185.0 9565.0 10185.0 80.9 95.2 TOOL NUMBER 69706 126583 3.750 8490.0 Flo Pro 8.60 65.0 8.5 24000 10.0 .120 .060 .230 .160 70.0 156.0 70.0 70.0 ) ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9534.5 10185 9859.75 1302 9534.5 10185 ROP MWD040 FT/H 0.58 585.6 60.7379 1240 9565.5 10185 GR MWD040 API 18.13 186.07 36.2856 1205 9537.5 10139.5 RPX MWD040 OHMM 1.94 21.38 10.582 1239 9534.5 10153.5 RPS MWD040 OHMM 2.38 24.03 11.5176 1239 9534.5 10153.5 RPM MWD040 OHMM 2.78 22.96 11.7479 1239 9534.5 10153.5 RPD MWD040 OHMM 4.51 19 11.949 1239 9534.5 10153.5 FET MWD040 HOUR 0.33 8.01 1.56232 1239 9534.5 10153.5 First Reading For Entire File......... .9534.5 Last Reading For Entire File.......... .10185 File Trailer Service name............ .STSLIB.006 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS 7 header data for each bit run in separate files. 5 .5000 START DEPTH 10140.0 10154.0 10154.0 10154.0 10154.0 STOP DEPTH 10529.5 10542.5 10542.5 10542.5 10542.5 ) RPX ROP $ 10154.0 10185.5 10542.5 10574.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... ...Undefined Absent value.................... ..-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 13-NOV-02 Insite 4.3 Memory 10574.0 10185.0 10574.0 85.6 91.2 TOOL NUMBER 69706 126583 3.750 8490.0 Flo Pro 8.60 65.0 8.5 24000 10.0 .120 .050 .230 .160 70.0 168.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel ') ) DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10140 10574 10357 869 10140 10574 ROP MWD050 FT/H 1.83 1436.92 115.369 778 10185.5 10574 GR MWD050 API 17.35 69.6 28.0181 780 10140 10529.5 RPX MWD050 OHMM 3 24.06 8.92406 778 10154 10542.5 RPS MWD050 OHMM 3.35 24.15 10.3416 778 10154 10542.5 RPM MWD050 OHMM 3.54 24.52 10.8375 778 10154 10542.5 RPD MWD050 OHMM 5.63 23.3 11.3037 778 10154 10542.5 FET MWD050 HOUR 0.2422 10.1088 1.57037 778 10154 10542.5 First Reading For Entire File......... .10140 Last Reading For Entire File.......... .10574 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type......... . . . . . . . LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX 8 header data for each pass of each run in separate files. .5000 5 1 START DEPTH 10032.0 10044.0 10044.0 10044.0 10044.0 STOP DEPTH 10531.5 10545.5 10545.5 10545.5 10545.5 ) FET RAT $ 10044.0 10075.5 10545.5 10577.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. '..'" ...........0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 13-NOV-02 Insite 4.3 Memory 10574.0 10100.0 10574.0 85.6 91.2 TOOL NUMBER 69706 126583 3.750 8490.0 Flo Pro 8.60 65.0 8.5 24000 10.0 .120 .050 .230 .160 70.0 168.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel ) ) DEPT FT 4 1 68 0 1 RAT MAD051 FT/H 4 1 68 4 2 GR MAD051 API 4 1 68 8 3 RPX MAD051 OHMM 4 1 68 12 4 RPS MAD051 OHMM 4 1 68 16 5 RPM MAD051 OHMM 4 1 68 20 6 RPD MAD051 OHMM 4 1 68 24 7 FET MAD051 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10032 10577 10304.5 1091 10032 10577 RAT MAD051 FT/H 10.21 430.15 377.337 1004 10075.5 10577 GR MAD051 API 13.21 153.83 31.6613 1000 10032 10531.5 RPX MAD051 OHMM 1.69 20.12 6.25018 1004 10044 10545.5 RPS MAD051 OHMM 2.07 26.15 7.92456 1004 10044 10545.5 RPM MAD051 OHMM 2.56 27.8 8.89682 1004 10044 10545.5 RPD MAD051 OHMM 4.25 27.21 10.2073 1004 10044 10545.5 FET MAD051 HOUR 2.11253 27.8758 11.1746 1004 10044 10545.5 First Reading For Entire File......... .10032 Last Reading For Entire File.......... .10577 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number.....,.... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.009 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF ') ~) End Of LIS File