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Home My WebLink About201-119 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 2OAAC 25.105 2OAAC 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. 11/28/2010 201 -119 310 -354 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 06/30/2001 50- 029 - 22557 -01 -00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 07/02/2001 PBU E -35A 1187' FNL, 501' FEL, SEC. 06, T11 N, R14E, UM 8. KB (ft above MSL): 65.29' 15. Field / Pool(s): Top of Productive Horizon: 1810' FNL, 1516' FEL, SEC. 06, T11 N, R14E, UM GL (ft above MSL): 30.50' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 1186' FNL, 1533' FEL, SEC. 06, T11 N, R14E, UM 9351' 8819' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 664470 y - 5975877 Zone- ASP4 10501' 9066' ADL 028304 TPI: x- 663471 y- 5975232 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 663438 y 5975855 Zone- ASP4 N/A 18. Directional Survey: 0 Yes IN 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, ROP, MEMORY CNL, GR, CCL 9123' 8800' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H Surface 117' Surface, 117' . 30" -260 sx Arctic Set 10 -3/4" 45.5# NT80 35' 3627' 35' 3622' 13 -1/2" 1175 sx CS III. 375 sx Class 'G' 7 -5/8" 29.7# L -80 33' 9123' 33' 8800' 9-7/8" 485 sx Class 'G' 4 -1/2" 12.6# ...-80 8862' 9123' 8736' 8800' 6-3/4" Uncemented Slotted Liner 3 -3/16" x tare" 6.2# / 6.16# _-80 8684' 10501' 8637' 9066' 3 -3/4" 1017 sx (1180 cu ft) 'G' / Uncemented Slotted Liner 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): None 4 -1/2 ", 12.6#, L -80 8750' 8703' / 8650' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 5Ittgi3O011141W APR 2 9 Zdll -9396' Set CIBP 9350' Set Whipstock ✓ 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize I • , - • as or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and labo : , t r f _ AAC 250.071. None ,IAN 2 1 201'. RBDMS JAN 2 0 2011 d2--; A 1 A Coris. C a} 4ssion Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 3./ _ (( w pa /ubmit Original Only 4 • • 29. GEOLOGIC MARKERS (List all formations and 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. Shublik 9390" 8837' None Top Sadlerochit 9494' 8908' TCGL / Zone 3 9606' 8993' 27P 9774' 9067' Formation at Total Depth (Name): 31. List of Attachments: Well work Summary, Summary of Daily Drilling Reports and a Well Schematic Diagram. 32. I hereby certify that the fore• is true and co ct to the best of my knowledge. Signed: Sondra Stewman4 j� " Title: Drilling Technologist Date: . c " C) 1 PBU E - 35A 201 - 119 310 - 354 Prepared By Name/Number. Sondra Stewman, 564 -4750 Well Number Permit No. / Approval No. Driving Engineer: Sean McLaughlin, 564 -4387 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 - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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 TREE = 4 -1/16" CIW E -35 B WELLHEAD = 5M FMC SA TES: WELL ANGLE> 70° @ 9560' * ** DRAFT ACTUATOR = BAKER C KB. ELEV = 65.29' 1 BF. ELEV = 34.79' KOP = 8349' 20" CONDUCTOR, 115' Max Angle = 97° @ 9194' 2205' (- I4 -1/2" HES HXO SSSV NIP, ID = 3.813" 91.5 #, H -40, Datum MD = 9442' IL Datum TV D = 8800' SS ID = 19.124" GAS LIFT MANDRELS 10 -3/4" CSG, 45.5 #, NT -80 BTC, ID = 9.950" H 3627' LI ST MD ?VD DEV TYPE VLV LATCH PORT DATE 3 4053 4048 0 MER DOME BK -5 16 01/05/11 2 6731 6726 0 MER DOME BK -5 16 01/05/11 Minimum ID = 1.780" @ 8648 ' 1 8126 8120 0 MER SO _ BK -5 20 01/05/11 2.70" BTT DEPLOY SLEEVE 8642' H3.70" BKR GUIDE SLEEVE w / XO, ID = 1.810" I TOP OF 2 -3/8" LNR H 8648' 8648' --1 2.70" BTT DEPLOY SLV, ID = 1.780" I 8689' H BKR LOC SUB /SEAL ASSY, ID = 2.39" I 8691' H3-1/2'' BKR DEPLOY SUB, ID = 3.00" I TOP OF 2 7/8" LNR H 8691' ' , ( 8691' 1- -1/2" HES X NIP, ID = 3.813" I 8702' 1-13-1/2" X 3- 3/16" XO, ID = 2.786" I z I 8703' I- � 7 -5/8" X 4 -1/2" BKR SABL -3 PKR W/ K A NCH, ID = 3.87" ' ' 8727' I -14 -1/2" HES X NIP, ID = 3.813" I ' 1 I 8738' H4 -1/2" HES XN NIP, ID = 3.725" I 14 -1/2" TBG, 12.6 #, L -80 NSCC, .0152 bpf, ID = 3.958" I--I 8750' I-7 \ I 8750' 1-14-1/2" WLEG, ID = 3.958" I 8747' I -I ELMD TT LOGGED 4/18/97 I TOP OF 4 -1/2" LNR H 8862' I 8862' I- 7 -5/8" X4 -1/2" 11W HBBP PKR, W/ SCP TOP, ID = 3.920" 7 -5/8" CSG, 29.7 #, L -80 NSCC, -I 8998' I- 4 -1/2" MILLOUT WINDOW (E -35A) 9123' - 9128' ID = 6.875" (OLD SDTRK WINDOW) I4 -1/2" LNR, 12.6 #, L -80 NSCT, ID = 3.958" H -9128 I 12-7/8" WHIPSTOCK (11/26/100 I-I 9350' 3- 3/16" MILLOUT WINDOW (E -35B) 9352' - ? ? ? ?' 3- 3/16" CSG, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.80" I -9352 T PERFORATION SUMMARY REF LOG: MEM CNL,I OR/ COL ON ? ? ? ? ?? ANGLE AT TOP PER': 24° @ 11080' N PBTD H 11163' I Note: Refer to Production DB for historical perf data ® h- C i BP 41.1,.....` SIZE SPF INTERVAL Opn /Sqz DATE cy 2" 6 8981 - 9386 0 12/13/08 (. (`Nc/o t 640 1- 11/16" 6 11080 - 11110 0 12/06/10 ' 12 -3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.992" H 11200' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/11/95 N28E ORIGINAL COMPLETION WELL: E 35B 07/05/01 NORDIC 1 CTD SIDETRACK (E -35A) PERMIT No:2101600 12/07/10 NORDIC 1 CTD SIDETRACK (E -35B) API No: 50- 029 - 22557 -02 12/09/10 PJC DRLG DRAFT CORRECTIONS SEC 6, T11 N, R14E, 1187' FNL & 501' FEL 01/09/11 ET /PJC GLV C/O (01 /05/11) 01/09/11 ET/ PJC MIN ID CORRECTION BP Exploration (Alaska) • • America - ALASKA P i ° °Oration Summary Repa ` Common Well Name: E -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/23/2010 End Date: X3- 00Y24 -C (1,613,705.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 6/27/2001 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292255700 Active Datum: E -35 @65.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 11/23/2010 18:00 - 19:00 1.00 MOB P PRE RIG RELEASE FROM 04 -22AL1 AT 18:00. 19:00 - 19:30 0.50 MOB P PRE PJSM TO PULL OFF WELL. 19:30 - 20:30 1.00 MOB P PRE PULL OFF WELL. 20:30 - 00:00 3.50 MOB P PRE MOVE RIG FROM DS 4 TO E PAD. 11/24/2010 00:00 - 10:30 10.50 MOB P PRE MOVE FROM DS -4 TO E -PAD. 10:30 - 12:00 1.50 MOB P PRE R/U `T MATS AND SPILL CONTAINMENT AROUND E -35B. CLOSE ALL VALVES ON TREE. PREP WELL TO SPOT RIG OVER. 12:00 - 18:00 6.00 MOB P PRE WAIT ON NORDIC CAMP TO ARRIVE AT E -PAD TO GET PAST E -35B BEFORE SPOTTING RIG OVER WELL. 18:00 - 19:00 1.00 MOB P PRE PJSM FOR BACKING OVER WELL. REVEIW NORDICS BACKING OVER WELL PROCEEDURE. SPOT RIG OVER E -35B. RIG ACCEPTED ON E -35B AT 19:00 HRS. 19:00 - 20:00 1.00 MOB P PRE R/U OUTSIDE EQUIPMENT. 20:00 - 00:00 4.00 MOB P PRE PJSM. R/U AND LOWER 2 3/8" REEL. FOUND CRACKED WELDS ON REEL DRIVE PINS. CALL OUT SLB WELDER TO REPAIR. 11/25/2010 00:00 - 00:30 0.50 MOB N RREP PRE REPAIR CRACKED WELDS ON REEL DRIVE PINS. 00:30 - 01:30 1.00 ` MOB P PRE PJSM. P/U AND SECURE 2" REEL. 01:30 - 08:30 7.00 BOPSUR P PRE PJSM. N/U BOPE. C/O RAMS FOR 2" CTB, SERVICE BOP VALVES. SERVICE MASTER AND SWAB VALVES. 08:30 - 09:00 0.50 BOPSUR P PRE FUNCTION BOPE. 09:00 - 11:00 2.00 BOPSUR P PRE PJSM. TEST BOPE TO 250 PSI AND 3500 PSI. BOPE TEST WHITNESS WAVIED BY JOHN CRISP. AOGCC DP SIMULTANEOUS TO BOPE TEST, PERFORM TOP END JOB ON GENERATOR. FIND A CAMSHAFT THAT NEEDS REPLACED. CONFER W/ TOWN NORDIC AND TOWN BP - AGREE TO CONTINUE WITH WELLWORK OPERATIONS WITH ONLY ONE GENERATOR UNTIL WINDOW IS MILLED. 11:00 - 11:30 0.50 BOPSUR P PRE GREASE CREW OPENED SSV. 11:30 - 18:00 6.50 BOPSUR P PRE CONTINUE TESTING BOPE. ALL BOPE TESTED AGAINST THE SWAB VALVE. TESTED MASTER VALVE AND TWC TO 250 PSI AND 3500 PSI. 18:00 - 00:00 6.00 BOPSUR P PRE PJSM. C/O ROLLERS ON GOOSENECK. INSTALL PRESSURE BULKHEAD. PULL 2" COIL TO RIG FLOOR. 11/26/2010 00:00 - 01:30 1.50 BOPSUB P PRE C/O PACK OFF FOR 2" CTB. STAND BACK INJECTOR. Printed 1/20/2011 12:58:29PM _`T North A '.. a of�" r�h America - A�l,.ik�� - BP � , � '��`� '- Operation Summary Rep©rk ; ,. Common Well Name: E -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/23/2010 End Date: X3- 00Y24 -C (1,613,705.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 6/27/2001 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292255700 Active Datum: E -35 @65.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 03:00 1.50 BOPSUB P PRE PJSM. VERIFY CERTS. R/U LUBRICATOR AND TEST TO 250 PSI AND 3500 PSI. PULL TWC, CLOSE MASTER VALVE AND SSV FOR TWO BARRIERS ON WELL. R/D LUBRICATOR AND LOAD OUT. 03:00 - 03:30 0.50 BOPSUB P PRE PJSM. ISOLATE CHOKE, M/U BOP CAP. PUMP OPEN SSV. OPEN MASTER VALVE. 90 PSI ON WELL. 03:30 - 06:00 2.50 BOPSUB P PRE SPEAR INTO WELL W/ 5 BBLS NEAT MEOH. KILL WELL PUMPING 8.4 PPG KCL W/ 0.5% "CFS -520" METAL -TO -METAL FRICTION REDUCING AGENT. RAMP PUMP UP TO 4.5 BPM AT 2500 PSI. PUMP 206 BBLS KCL TOTAL. DOWN ON PUMP. FLOW CHECK WELL FOR 30 MINUTES - GOOD. FILL UP WELL AFTER FLOW CHECK W/ —2 BBLS. BLEED OAP FROM —500 PSI TO —130 PSI. 06:00 - 11:00 5.00 BOPSUB P PRE SHIFT CHANGE. KEEP WELL FULL PUMPING ACROSS THE TOP, TAKING —10 BPH KCL. PJSM. CHECK ELINE - 1100 MEG AND 51 OHM GOOD. STAB ON TO PUMP SLACK BACK. PT INNER REEL VALVE AND PO AND CHART TESTS - BOTH PASSED. CUT 275' CT TO FIND WIRE. TEST WIRE - 1000 MEG AND 52 OHM - GOOD. 11:00 - 14:30 3.50 BOPSUB P PRE OPEN TO WELL. FILL HOLE W/ 15 BBLS KCL. HEAD -UP BHI AND TEST CONNECTIVITY - 420 MEG AND 51 OHM - GOOD. PT AND CHART CTC, GOOD. PT AND CHART CHECKS (FROM BELOW) - GOOD. STAB ON W/ NOZZLE, PUMP SLACK FORWARD. 14:30 - 16:00 1.50 WHIP P WEXIT BEGIN MU WHIPSTOCK SETTING BHA (CHANGE FROM "PRE" PHASE TO "WEXIT' PHASE. MU BHI BHA W/ GR/CCL/HOT W/ BTT WS SETTING ASSEMBLY (SCRIBE WS TO HOT). HOLE STILL DRINKING AT —10 BPH. STAB ON W/ WHIPSTOCK. 16:00 - 18:20 2.33 WHIP P WEXIT OPEN EDC. ONLINE DOWN CT W/ 2% KCL W/ 0.5% CFS -520 THROUGH OPEN EDC AT 550 PSI AT 0.65 BPM W/ —80% RETURNS. BEGIN RIH W/ 3- 3/16" BIT MONOBORE WHIPSTOCK ON BAKER 10 HYDRAULIC SETTING TOOL. 17:20 - RIH AT 4775' MD PUMPING AT 0.66 BPM AT 590 PSI THROUGH OPEN EDC W/ 5% LOSSES (ACCOUNTING FOR CT DISPLACEMENT). PVT: 266 BBL. 18:20 - 19:30 1.17 WHIP P WEXIT LOG GR TIE IN 9130'- 9168'. NEGATIVE 2' CORRECTION. LOG CCL TO DOUBLE CHECK COLLAR LOCATION 9100'- 9320'. MATCHES PDC LOG. 19:30 - 19:45 0.25 WHIP P WEXIT PICK UP TO WS SETTING DEPTH TO 9350' AT 240 DEG. CLOSE EDC. RESSURE UP TO 3000PSI AND SHEAR OFF WS. PVT 265 @ 19:30. SAT DOWN 2K. PICK UP EASY. Printed 1/20/2011 12:58:29PM ......,,,,,,.„,,,,,,,,,,,,,,,,,_„,.,..,,,,,..... ..„...„2.n,,_,,,,,,, _..,,,,,,,, NOtth A I tt� 'rlc� € € €, _ Pie` i 0 ,i;.,. n peraii �3 • ,-- 'a � 4 � Common Well Name: E -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/23/2010 End Date: X3- 00Y24 -C (1,613,705.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.. NORDIC 1 Spud Date/Time: 6/27/2001 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292255700 Active Datum: E -35 @65.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:45 - 21:00 1.25 WHIP P WEXIT PULL OUT OF HOLE AT 65 FPM. PUMPING 1.25BPM. 21:00 - 22:15 1.25 WHIP P WEXIT GRAYLOC FITTING ON HARDLINE BETWEEN MUD PUMP AND REEL, FOUND DRIPPING IN THE PIPE SHED. BLEED DOWN PRESSURE AND ATTEMPT TO TIGHTEN. STILL DRIPPING. POOH AT. 95 FPM. FILL HOLE 1.31 BPM DOWN BACKSIDE THROUGH KILL LINE WHILE POOH. PVT 239 BBL @ 21:00. LOOSING 4 BPH. 22:15 - 22:30 0.25 WHIP P WEXIT PJSM TOLD WS SETTING BHA. 22:30 - 22:45 0.25 WHIP P WEXIT POP OFF WELL AND LD WS BHA. 22:45 - 23:00 0.25 WHIP P WEXIT FP REEL WITH`METHONAL. 23:00 - 00:00 1.00 WHIP N RREP, WEXIT -PJSM TO CHANGE OUT GRAYLOC FITTING. CHANGE OUT GRAYLOC FITTING ON HARDLINE BETWEEN MUD PUMP AND REEL. PRESSURE TEST, STILL LEAKING. 11/27/2010 00:00 - 00:30 0.50 WHIP N RREP WEXIT PJSM TO CHANGE OUT HARD LINE. 00:30 - 06:00 5.50 WHIP N RREP WEXIT CHANGE OUT HARD LINE IN PIPE SHED FROM REEL HOUSE TO MANIFOLD. DUE TO CORROSION IDENTIFIED WHILE REPLACING FAILED GRAYLOC FITTING. / REPLACING W/ 2" IRON. ✓ CORSUS S DOWNTI M NOT OSION NORDIC ISE DOWNTIME THIS 06:00 - 13:00 7.00 WHIP ` N RREP WEXIT KEEP HOLE FULL BY PUMPING 2 %KCL BP ACROSS THE TOP DURING HARDLINE REPLACEMENT WORK. WELL TAKING —10 BPH. CALL FOR ADDITIONAL HARDLINE TO BE DELIVERED FROM CH2MHILL. CONIRM CERTIFICATION OF SAME. INSTALL HARDLINE AND PREPARE TO PRESSURE TEST REPLACED IRON. NOTE: THIS HARDLINE RUN IS 2" IRON. 13:00 - 14:30 1.50 WHIP N RREP WEXIT TEST NEW INSTALLATION TO 250 PSI / 5000 PSI AND CHART TESTS. GOOD. 14:30 15:00 0.50 WHIP P WEXIT END BP NPT. REGROUP, DEBRIEF HARDLINE WORK. PJSM FOR MU MILLING ASSEMBLY. 15:00 - 16:45 1.75 STWHIP P WEXIT INSTALL CHECKS IN BHA. TEST CHECKS FROM BELOW 250 PSI / 1500 PSI. MU WINDOW MILLING ASSEMBLY W/ 2 JTS C BE ABOVE M, " R CENTRALIZER ABOVE OTOR MOTOR 2.70SPIAL , BTT 2 -1/8" EXTREME MOTOR, STRING REAMER AND HCC WINDOW MILL. REAMER AND MILL IT BOTH IH / GAUGED WINDOW AT MIL 2.74" INGASS GO / 2.73 NO -GO. 16:45 - 18:00 1.25 STMILL P WEX R WLELY. 17:00 - RIH AT 3000 PUMPING KCL AT 0.66 BPM AT 930 PSI W/ —10 BPH LOSSES. 18:00 - 18:30 0.50 STMILL P WEXIT RIH W /MILLING BHA. PVT 158BBLS8 AT 9,000' PUMPING KCL AT 0.66BPM AT 800PSI 18:30 - 19:45 1.25 STWHIP P WEXIT LOG A E 9020' 2.0 FPM 0.65 IN5 BP M, 820 PSI FROM Printed 1/20/2011 12:58:29PM North America - ALASK B • ' l€ € l 0 �� ! peratton uma Report €E E., Common Well Name: E -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/23/2010 End Date: X3- 00Y24 -C (1,613,705.00 ) Project: Prudhoe Bay Site: PB E Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 6/27/2001 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292255700 Active Datum: E -35 @65.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:45 - 20:00 0.25 STMILL P WEXIT LITTLTE MOTOR WORK - PRESSURE UP FROM 802 TO 1600 PSI, IN AND OUT RATES DROPPED AND CT WT DROPPED AT 9,162'. BHA JUST OUTSIDE OLD WINDOW, 3- 3/16" LINER COULD HAVE A DOG LEG THERE. 20:00 - 20:20 0.33 STMILL P WEXIT LOG TIE IN RUN TO 9,240'. NO CORRECTION, ON DEPTH. 20:20 - 23:15 2.92 STMILL P WEXIT SWAP WELL TO USED QUIKDRIL (GEOVIS) AT 9300'. CAN ONLY PUMP 1.5 BPM 23:15 - 23:50 0.58 STMILL P WEXIT WITH MUD CIRCULATED ALL THE WAY AROUND. PVT 335 @ 23:50 POWER PACK AT IDLE CAN ONLY PUMP 1.15 BPM THROUGH EDC WITH ONE GENERATOR ON LINE. 23:50 - 00:00 0.17 STMILL P WEXIT CLOSE EDC. MAX PUMP RATE .92 BPM WITH EDC CLOSED. 11/28/2010 00:00 - 00:45 0.75 STMILL P WEXIT TAG TOWS AT 9,350'. PAINT FLAG ON COIL. 0.92 BPM, FS 2450 PSI. WOB .97K, DIFF PRESS 100PSI. A 00:45 - 01:00 0.25 STWHIP P WEXIT BLEED OA FROM 500 PSI - 90 PSI. MOSTLY CRUDE /DIESEL BLED FOR 9 [ . pt. MINUTES. � PVT 330 BBL. y ✓_ 01:00 - 03:00 2.00 STWHIP P WEXIT MILLING WINDOW AT 9351.9'. .93 BPM, PVT 329 BBLS, WOB 1.76K , DIFF PRESS 238 PSI 03:00 - 05:00 2.00 STWHIP P WEXIT MILLING WINDOW AT 9354.1'. 0.92 BPM, PVT 328 BBLS, WOB 1.64K , DIFF PRESS 62 PSI 05:00 - 05:30 0.50 STWHIP P WEXIT BLEED IA FROM 678 PSI - 71 PSI. MOSTLY CRUDE /DIESEL BLED FOR 9 F -358 MINUTES. BLEED OA FROM 279 PSI - 87 PSI. MOSTLY CRUDE /DIESEL BLED FOR 4 MINUTES. PVT 328 BBL. 05:30 - 06:30 1.00 STWHIP P WEXIT MILLING WINDOW AT 9355.2'. 0.92 BPM, PVT 328 BBLS, WOB 1.36K , DIFF PRESS 100 PSI 06:30 - 11:00 4.50 STWHIP P WEXIT CHANGEOUT. WEEKLY RIG SAFETY MEETING. WEEKLY RIG SAFETY LEADERSHIP TEAM MEETING. 10:30 - MILLING OPEN HOLE AT 9363' MD AT 0.1 FPM AT 1.0 BPM AT 2650 PSI (500 PSI DIFFERENTIAL PRESSURE AT THE MOTOR) W/ 2.2K LB WOB AND 1:1 RETURNS. BHP /ECD /PVT: 4374 PSI / 9.65 PPG / 325 BBL. IAP: 190 PSI. OAP: 210 PSI. NOTE: BTT'S NOTES INDICATE: TOWS = TOW = 9350.3' MD. BOW = 9355.6' MD. MILL OPEN HOLE TO 9365.5' MD. Printed 1/20/2011 12:58:29PM . • E -35A, Well History (Pre Rig Sidetrack) Date Summary 06/02/10 T /I /O= HOT /0/200 TEMP= 40 RG 2401 (SURFACE CASING CORR MITIGATION) PJSM. SET UP HYDRO VAC AND JOB SITE. START AND COMPLETE EXCAVATION ON WELL CELLAR. RDMO. T.P.= 100 06/03/10 T /I /O= SI /0/200 TEMP= SI RG 2401 (SURFACE CASING CORR MITIGATION) PJSM. SET UP TRAILER AND JOB SITE. STRAP CONDUCTOR @ 74 ". INSTALL SPILL CONTAINMENT. PUMPED 51 GALLONS RG 2401 TO FILL CONDUCTOR. RDMO. T.P.= 200 06/04/10 T /I /O= SI /0/200 TEMP= 35 RG 2401 (SURFACE CASING CORR MITIGATION) PJSM. SET UP TRAILER AND JOB SITE. STRAPPED CONDUCTOR @ 3 ". INSTALLED SPILL CONTAINMENT. PUMPED 1.7 GALLONS RG 2401 TO FILL CONDUCTOR. RDMO. T.P.= 0 09/14/10 T /I /0= 2250/0/200 Temp = SI MIT IA Passed to 3000 psi/ MIT OA Failed to 2000 psi./ Established LLR of 4 bpm @ 1500 psi. (CTD Screening) MIT IA pressured up to 3000 psi with 3.2 bbls diesel. IA lost 100 psi in first 15 minutes and 40 psi in second 15 minutes. For a total of 140 psi in 30 minutes. Bled pressure down. MIT OA pressured up to 2000 psi with 1.4 bbls diesel. OA lost lost 800 psi in first 15 minutes. Established LLR of 4 bpm Q 1500 psi. FWHP's= 2250/200/50 VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open - Well SI 09/20/10 T /I /O= SI/280/220 Temp =Sl PPPOT-T (PASS) (Pre CTD screen) PPPOT -T : RU 2 HP BT onto THA 0 psi. Flushed void until clean returns achieved, pressured to 5000 psi for 30 minute test, 15/ min 4000 psi. Bled void to 0 psi cycle and torque LDS "ET style" All functioned with no problems. 2nd test 5000/ 30 min. Bled void to 0 psi RD test equipment. 11/07/10 CT #9 on on E -pad, RU on E -35A well, MU CTC, pull test, MU BOT whipstock drift BHA #1, PT on lubricator, Displace well w/ 5 meth, 215 KCI, 5 meth, RIH w/ drift to 9550 ft, POH, PU PDC GR/CCL max OD 2.2 ", overall tool length 15.46ft, RIH, log from 9500 to 8500 ft at 45 fpm, flags at 9500 and 9350ft, POOH, good data, Correct depth +19', MU & RIH CIBP, freeze protect well by pumping 40 bbl 60/40 meth c j 8l down Annulus while RIH, At the flag, correct depth, set I�ug © 9396 ft mid element of CIBP, 9394.8 ft top s of CIBP, confirm set, POOH to 3600', , Job in progress. cont. 11/8/2010 WSR. 11/08/10 Cont. from 11/7/2010 WSR, VD BHA, recover ball, RD complete, 11/11/10 T/I/O= 0/240/240 C/O SN (4- 1/16" FMC 120 serial# 89- 0269 -H) & P/T to 300 psi low -pass /5000 psi high - pass; Torqued all tree flange nuts to spec. (Except THA to M/V) See log; Pre Nordic 1 11/14/10 T /I /O = VAC/240/240. Temp =S1. Bleed IA & OA to 0 psi (CTD prep). Well House, FL, & control panel removed. Drilling scaffolding is in place. OA FL near surface. Bled OAP from 240 psi to 0 psi in 1 hr, fluid /gas mix. During OA bleed, IAP decreased 80 psi. IA FL near surface. Bled IAP from 160 psi to 0 psi in 1 hrs 30 min. Monitor IAP & OAP for 30 min. IAP increased 2 psi, OAP increased 1 psi. Re -bled IAP & OAP to 0 psi in 1 min. IA & OA FL Q surface. Job complete. Final WHPs= VAC /0/0. SV,WV,SSV,MV = Closed. IA,OA =OTG. NOVP. 11/22/10 T /I /O= 0/0/0 P/T(charted) down individually on SN, SSV & MN to 300 psi /low -pass, 3500 psi high /pass, (Note: MN failed 3500 psi /high test, 106 psi loss in 5 min.); Set 4" CIW TWC #257 Q 114" w /1 -1' ext.; Torqued THA x M/V (see log); P/T (charted) from TWC up, 300 psi /low -pass, 3500 psi -pass & 5000 psi /high -pass; Upon completion P/T tree cap to 500 psi -pass; Pre Nordic 1 11/26/10 T /I /O = 0/0/0 Verify barriers. Rig up lubricator with 4" CIW pulling tool. Pressure tested lubricator to 250 psi low and 3500 psi high. (passed) Pulled 4" CIW H TWC thru stack w/ 3 -5' & 1 -2' ext. CO 109" RKB = 23.95' + 1' Nordic 1 Page 1 of 1 3 EEO ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS . , , 3�3 \N. AVERUE; SUITE 100 CONSERVATION COMl�'IISSIOI�T ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader`) BP Exploration Alaska P (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E -35A Sund ry Number: 310 -354 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Daniel T. Seamount, Jr. Chair DATED this 5 day of November, 2010. Encl. ,` STATE OF ALASKA h' to �+ // /O 1 K s � 1 0 ALASKOL AND GAS CONSERVATION COMMIS•N 1, APPLICATION FOR SUNDRY APPROVAL OCT 2 7 2010 20 AAC 25.280 1. Type of Request: # 04L '`iW ❑ Abandon ® Plug for Redrill / ❑ Perforate New Pool ❑ Repair Well ❑ Change Approve ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ After Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 201 - 119v 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22557 - 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 E -35A Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028304 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): 10501' - 9066' - 1 10464' 9069' 10030' None Casino Len th Size MD TVD Burst Colla Structural Conductor 117' 20" 117' 17' Surface 10 -3/4" 3627' 3622' 5210 2480 Intermediate 9090' 7-M" 9123' 8800' 6890 4790 Production Liner 61' 4 -1/2" 8862'- 9123' 8736'- 7500 1817' - 3/16" x 2 -7/8" 8684'- 10501' 8637'- 066' 13450 138 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8981'- 9865' 1 8777'- 9084' 4 -1/2 ", 12.6# L -80 8750' Packers and SSSV Type: 7-5/8"X4-1/2" BKR SABL -3 Packer Packers and SSSV 8703'/ 8650' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ F Detailed Operations Program Exploratory - ®Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 7, 2010 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG -0 Suspended 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name JOh n Title Engineering Team Leader Sean McLaughlin 564 -4387 Prepared By Name/Number: Signature ,. Phone 564 -4711 Date la Elizabeth Barker, 564 -4628 Commission Use Onl Conditions of approval: No ify Commission so that a representative may witness R � Sundry Number: 3/0 ',� L ❑ Plug Integrity P Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: p Z 5GD S L �•n n � � -e S� �,�� Z o ACc ZS.IIZ� Subsequent Form Required: D 4/ 7 Lo or APPROVED BY Approved By- C O S I N R THE COMMISSION Date ! / Form 10-403 Revi 01 D S NOV O 5 S bmit In Duplicate r • • To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin O bp CTD Engineer Date: October 25, 2010 Re: E -35A Sundry Approval Sundry approval is requested to plug the E -35A perforations as part of drilling the E -35B coiled tubing sidetrack.. History of E -35A. E -35A is a 2001 horizontal CST in Zone 2 in the E -K Graben. During drilling, the HOT was encountered —13' high and as a result more of the wellbore is in the MHO /HOT transition zone than had been planned. The well initially had problems flowing but eventually came online. The well began to cycle in Feb 2002 when it hit MGOR. In March 2002, a stimulation job of 450 bbls microbe mixture was pumped. Marginal oil production benefits were seen. In May 2003, 50' of Zone 2 perforations were shot. These perfs were below the HOT and little benefit was seen. A MCNL/PPROF was logged in Dec 2003 and indicated 100% of production was from the initial perforations. In Dec 2008, a CIBP was set to isolate most of the lateral and 405' of Sag perfs were shot. Production was uncompetitive, so the well was shut in for high GOR. yd�il Due to low remaining value, E -35A was screened for a CST in Aug 2009. The KB liner top packer has been � Oo n pulled. t-Al nor ��rU6Jy i7 Reason for sidetrack. E -35A is currently SI for high GOR with no remaining wellwork options. The a n S�wf proposed sidetrack will access reserves in the southern portion of the E -K Graben. �(e h '5 Proposed plan for E -35B is to drill a thru- tubing sidetrack with a Coiled Tubing Drilling rig on or around m ot1� o /�,* November 20, 2010 The existing perforations will be isolated by the primary cement job. The following r 0,11l 9ro describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed few sidetrack is attached for reference. tG �a I, ��yt�s n The � I pw f� f Il Pre -Rig Work: (scheduled to begin November 07, 2010). w ell 1. W AC -LDS; AC- PPPOT -T d_ I V fi 2. C Dummy WS drift to 9400' MD. cod" 1 �- o 0 3. C MCCL/GR log for depth control. s f « or r o•z4 • <� Qic' Vrd ' A' 4. C Set 3- 3/16" CIBP at 9400' G r �(� �� 1 5. V PT MV, SV, WV ��d r 6. D Bleed gas lift and production flowlines down to zero and blind flange. A ,� 7. O Remove wellhouse, level pad. - r*fv TY 1. 8. V Set TWC -24hr prior to rig arrival.. fir Rig Work: (scheduled to begin on November 20, 2010) P¢ 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull TWC.• A 2. Set 3- 3/16" WS at 9350' MD 3. Mill 2.8" window at 9350' and 10' of rathole. 4. Drill Build: 3.0" OH, 500' (32° /100). 5. Drill Lateral: 3.0" OH, 1400' (12° /100). 6. Run 2 -3/8" solid cemented completion leaving TOL at 8650' MD.T� 7. Pump primary cement leaving TOC at 9100', 9 bbls of 15.8 ppg liner cmt planned. 8. Cleanout run. 9. Run MCNL/GR/CCL log. 10. Perforate 25ft 11. Run 4 -1/2" liner top packer and test liner lap to 2,400 psi. 12. Freeze protect well, set BPV and RDMO. Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Run generic GLV's. Sean McLaughlin CTD Engineer 564 -4387 CC: Well File Sondra Stewman/Terrie Hubble TREE 4-1115"ClW WELLHEAD = 5M FMC SAFET�ES: WELL EXCEEDS 70° @ 8925' ACTUATO = BA KER E - 35A KB. ELEV = s5.3' AND GO ORIZONTAL @ 9100'. BF. ELEV = 34.7 K = 8 _3 Max Angle = 97° 9194' _ Datum MD = _ 9438 2205' 4 -112" HES HXO SSSV NIP, ID = 3.813" Datum ND = _ �� 8800' SS GAS LIFT MANDRELS flI J3 MD TVD DEV TYPE VLV LATCH PORT DATE 3/ 104' CSG, 45.5#, NT -80 BTC, ID = 9.950° 3627' 40 53 4048 0 MR DMY BK-5 0 08/27/09 6731 6726 0 MER DMY BK 5 0 08/27/09 8126 8120 0 MER DMY BK -5 0 04!23101 Minimum ID = 2.37" @ 9998' 3- 3/16" X 2 -7/8 XO $689' BKR LOC SUB/SEAL ASSY, ID = 2.39" 8691 4 -1/2" HES XNIP, ID= 3.813" 8702' 3-1 /7' FL4S LNR X 3 3/15' TC11 LNR XO, ID = 2.80" 8703' 7-5/8° X 4 -1/2" BKR SABL -3 PKR W/ K A N C H, ID = 3.93" 872T 4 -112" HES X NIP, ID = 3.813" 8 ?8$' 4-112" HES XN NIP, ID = 3.725" 4-112" TBG, 12.6#, L -80 NSCT, .0152 bpf, ID = 3.958" 8750' $750' 4 1 /2" WLEG, ID = 3.958 8747' ELMD TT LOGGED 4118/97 TOP OF 4-1/2" LNR 8862' 8862' 7 -5/8" X4 -112" TIW HBBP PKR, W/ SCP TOP, ID = 3.920" 7 -51W CSG, 29.7 #, L -80 NSCC 8998' I = 6.8 (OLD SDTRK WINDOW 4-1 /2" MILLOUT WINDOW (E -36A) 9123' - 9129 41/2" BKR WHIPSTOCK w/ RA RAG 9122' PERFORATION SUMMARY REF LOG: SPERRY MWD ON 05/30/95 ANGLE AT TOP PERF: 76° @ 8981 9998 33/16" X 2 -7/8" XO, ID = 2.37" Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 10030' 2 -7/8" CIBP(I2/12/08) Z. 6 8981 -9386 O 12/13/08 2" 4 9815-9865 O 05/12/03 2" 4 10200 - 10440 C 07/03!01 PBTD 10464' 4 -1/2" LNR, 12.6#, L -80 NSCT, ID = 3.958" 9600' 2 -7/8" LNR, 6.16#, L -80, STL, .0058 bpf, I = 2.37" 10501' DATE REV BY CONIIIAENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06111195 KSB ORIGINAL COMPLETION 02/04/04 CMC/TLP PERF SUMMARY CORRECTIO WELL: E 35A 05/11/95 KSB SIDETRACK COMPLETION 01/12/09 JGIWSV SETCIBP/ADPERF(12113108) PERMIT No: "10111go 07/05/01 CTD SIDETRACK 10102/09 BSE/PJC G_LV CIO & PULL LTP (08/26 -27/0 API No: 50- 029 - 22557 -01 07/21/01 CH/TP CORRECTIONS SEC 6, T11 N, RI 4F, 118T FNL & 501' FEL 05/12/03 JLGKK ADPERFS 07/12/03 CMO/TLP KB ELEVATION CORRECMN BP Exploration (Alaska) TREE 4-1116" CFW WEL LHEAD = 5M FMC • E. -3 5 B SAFE�TES: WELL EXCEEDS 70 @ 8925' ACTUATOR = BAKER AND HORIZONTAL @ 9100'. KB. ELEV == 65.3 P mposed C TD S Eeback B ELEV = 34.79' K = - - - 8349' M ax Angle = 97° 9194 Datum MD = _ _ 94 38 2205' 4 -1/2" HES HXO SSSV NIP, ID= 3.813" Datum TVD = 8800' SS O GAS LIFT MANDRELS T MD TVD DEV TYPE VLV LATCH PORT DATE 10 - 3/4" CSG, 45.5#, NT - 80 BTC, ID = 9.950" 3627' 3 4053 4048 0 MER DMY BK - 5 0 08127/09 6731 6726 0 MER DMY BK -5 0 08/27/09 1 8126 8120 0 MER DMY BK -5 0 04/23/01 Minimum ID = 2.375" @ 8640' 8640' 4 - 1/2" KB LTP 4 -1/2" BKR KB LTP 8650 TOL 2-318" FLUTED 8689' BKR LOC SUB /SEA L ASSY, ID 8691' 4 -112" HES X NIP, ID = 3.813" 8702' 3-1/2" FL4S LNR X 3- 3/16" TC11 LNR XO, ID = 2.80" $703' 7 -5/8" X4 -112" BKR SABL -3 PKIR W/ K ANCH, ID = 3.93" 8727' 4 -112" HES X NIP, ID = 1813" 8738 4 -1/2" HES XN NIP, ID milled to 4 -1/2" TBG, 12.6#, L -80 NSCT, .0152 bpf, ID = 3.958" 8750' 8750' 41/2" WLEG, ID = 3.958" TO C CTD LNR 8750' (S C M T 10/t9) 8747 ELMD TT LOGGED 4 /18197 TOP OF 4 -112" LNR 8862' 8862' 7 -5/8" X4 - 1/2" TNV HBBP PKR, W/ SCP TOP, ID = 3.920" 7 -5/8" CSG, 29.7 #, L -80 NSCC, 8998 - 65 TO C 2 -3/8" —9100' 8973' TS G R ID = 6.875" (OLD SDTRK WINDOW) 41/2" MILLOUT WINDOW (E -35A) 9123' - 9128' 4 -1/2" slotted liner 9076' -9158' 9350 3- 3116" mono bore w hipstock 4 -1/2" BKR WHIPSTOCK w / RA TAG 9122' 0 7 0 9400' 3- 3/16" CIBP PERFORATION SUMMARY 66 �— REF LOG: SPERRY MAID ON 05130/95 ANGLE AT TOP PERF: 76'@8981' Note: Refer to Production DB for historical pert data 2 -318" L -80 LINER, Cemented & Perforated 11255' SEE SPF INTERVAL Opn /Sqz DATE , 2" 6 8981 -9386 O 12/13/08 9998 , 2" 4 9815-9865 O 05/12/03 2" 4 10200 - 10440 07/03/01 , , PBTD 10464' 4 -1/2" LNR, 12.6#, L -80 NSCT, ID = 3.958" 9600' 2 -7/8" LNR, 6.16 #, L -80, STL, .0058 bpf, ID = 2.37" 10501' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/11/95 KSB ORIGINAL COMPLETION 02/04 /04 CMO/TLP PERF SUMMARY CORRECTIONS WELL: E -35 06/11/95 KSB SIDETRACK COMPLETION 01/12/09 JGM/SV SET CIBP /ADPERF (12/13/08) PERMIT No: 07/05/01 CTD SIDETRACK 10/02/09 BSE/PJC GLV C/O & PULL LTP (08/26 -27/0 A PI No: 50- 029 - 22557 -0 07/21/01 CH/TP CORRECTIONS 10/20/10 MSE PROPOSED CTD SIDETRACK SEC 6, T11 N, R14E, 1187' FNL & 501' FEL 05112/03 JLG /KK ADPERFS 07112/03 CMO/TLP KB ELEVATION CORRECTION BP Exploration (Alaska) 1 NORDIC— CALISTA RIG 1 CHOKE / REEUCIRCULATION MANIFOLD DIAGRAM V12 V74 i x 7.1/16" 5000 pal GOP's 10 = 7.GG" V75 V71 Transducers OR Bo 1 V 12 111 V 16 6115 HgwrppaailWP 4na q{waxb«rs4AM �;. ve xuu tuel> Vic V17 HCR IC uC OK To Poor Boy Gas Buster V4 5 V7 vie ve R V1e "MwW.R1Iae xAe` xgaFW;Mrr1 Manuel Choke Va4Ve — — — — — — — — — — — — — — — — — — — — — — — — — — — — —MCe— — _ _ _ _ — — — — — — — xYf46emen FQY OeN; 11Mw xxaee W MEOH /Diesel �— P Line CoFMx Hose 1/4 Turn Hek:o 1 OW OG To Production Tree or Cross Over Pm transducers CoFlex How N31 _ N12 To Coiled TubkQ Bleed Off kxwr Rwl Vaiw (N73 ', Cemenl Lbw h _..., - Ground Lewl TIs-h ]CV30, CV3 CV2 TSWW Pipe Manuel Choke Pressure Transd L11e 1 CV77 CV1 NS i Tiger Tank Mud Pump 2 h From O Baker +' MP I S MP 2 Kill Choke CV14 to Una Rig Flo" k' p Mud Pump e1 Vie Rem" CkcL"twA Line To IAerdlold CV15 Nun-2010 CoFlex How Schi~6er~r Alaska Data & Consulting Services 2525 Gembell Street, SuBe 400 Anchorage, AK 99503-2838 ATTN: Belh Well Job S Log Description NO.5418 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD P1-25 W-01A AP3Q-00063 82NJ-00026 INJECTION PROFILE MEMORYGLS 1010209 10/02/09 1 1 1 1 72-O6A AZCM-00043 LDL 10/03/09 1 1 W-36 E-35A 12-34 AV1 H•00028 82NJ-00027 AYS4-00104 PROD PROFILE W/GL MEM CEMENT BOND LOG INJECTION PROFILE 09/29!09 10/03/09 10/11/09 / 1 1 1 1 1 Z-O7A AYS4-00101 PRODUCTION PROFILE 10/08!09 1 1 15-18A B2WY-00015 MEM PROD PROFILE 07/01!09 1 1 OS-18A B04C-00069 SCMT 07/30/09 1 1 U-DSA P-07A 6148-00068 AWJI-00051 USIT MEM P O PROFILE ~ 08/17/09 10/09/09 1 1 1 1 09-03 AZCM-00044 PRODUCTION LOG '~ 10/10/09 1 1 1.45/0-26 5-134 V-1D5 82NJ-00032 AWLS-00039 83S0-00026 MEM LDL USR (PROF 10/10/09 09/28/09 10/03/09 1 1 1 1 i 1 BP Exploration (Alaska)Inc. -__... _...........,.,.,.., ..~....,~..,.., ....~...,~. ~....., .... Petrotechnical Data Center LR2-1 900 E. Benson 81vtl. fV1 aloe ~%~Voi- (7~_ , --. Alaska Data & Consulting Services 2525 Gambell Street, SuRe 400 Anchorage, AK 99503-283H 10/16/09 i~ • _~__.~: °` ',_~ ~/ VG~~ ~~JE.~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907j 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTj 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. Petratechnical Data Center Attn: Joe Lastrtfka LR2-1 900 Benson Blvd. l ~~~ ~S~ l'3 3~d Anchorage, Alaska 99508 and ~ l -"?!41 1'~-3~~~ ProActnre Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road . ~~ ~ . ter: ~; ~~~ ~ ~~, ~~G~, Suite C '~d~r~~ Anchorage, AK 99518 Fax (907] 245-8952 1 j Coil Flag 27-Dec-08 17-12 EDE 50-029-21260-00 2j Coil Fleg 11-Dec~08 E35A EDE 50-029-22557-01 Date : `~ ~~31 ~ Signed Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAt3E, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-IIAAIL : ~dsarlcl~orage(a~memoryloea.com WEBSITE : wvvu+.rne~e"sorylo r- C:\Documents end Settings\Owner\Uesktop\Tienstnit BP.docx ., Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 23, 2008 3:01 PM To: 'Preble, Gary B (SAIC)' Subject: RE: E-35A (201-119) AGAIN Page 1 of 1 Gary, Would you check the bridge plug depth on this well? On the 404 it is stated as 10100', but in the job summary it says 10030'. 10100' is the bridge plug depth for C-09A which was also in the packet I am reviewing. Thanks, Tom From: Maunder, Thomas E (DOA) Sent: Tuesday, December 23, 2008 2:45 PM aa.~~~~~l~r ~JA~`~ ~ ~~' ~~~~ To: 'Preble, Gary B (SAIC)' Subject: E-35A (201-119) Gary, I am reviewing the 404 recently submitted for the extended perforating operations conducted on this well. This appears to be another one of the Klondike jobs. As with 01-26A, if there are "other" operations reports 1'd appreciate if you could forward them. Please do this for any of the Klondike jobs. Call or message with any questions. Tom Maunder, PE AOGCC 12/23/2008 .~ • Maunder, Thomas E (DOA) From: Preble, Gary B (SAlC) [Gary.Preble@bp.com] Sent: Tuesday, December 23, 2008 3:25 PM To: Maunder, Thomas E (DOAj Subject: Emailing: E-35A-WORK SUMMARY.PDF \~(~ Attachments: E-35A-WORK SUMMARY.PDF ,~ "~ ~~ r E-35A-WORK S~ ~~~ 4 ~RC~C\~~~ ~v ~~o MMARY.PDF (389 KI ~ //~' `~ Tom, This attachment has the in depth report of the work done on E-35A The BP depth is 10030' as stated in the work summary. The message is ready to be sent with the following file or link attachments: E-35A-WORK SUMMARY.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «E-35A-WORK SUMMARY.PDF» i ' ' ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~~a - /~/~O~ 1.Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated '. Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r- Exploratory 2o1-11so - 3. Address: P.O. Box 196612 StratlgraphlC ~`` Service 6. API Number: Anchorage, AK 99519-6612 50-029-22557-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 65.29 KB ' BPU E-35A' 8. Property Designation: 10. Field/Pool(s): _ ADLO-028304 • PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: 1~®~~ ~t'~ - c ~; Total Depth measured 10501 - feet Plugs (measured) 10 0 12-12-08 true vertical 9066.14 , feet Junk (measured) None Effective Depth measured 10464 feet true vertical 9069 feet Casing Length Size MD TVD Burst Collapse Conductor 117' 20" Surface - 152' Surface - 152' 1530 520 Surface 3592' 10-3/4" 45.5# NT-80 Surface - 3627' Surface - 3622' 5210 2480 Intermediate 9090' 7-5/8" 29.7# L-80 Surface - 8998' Surface - 8780' 6890 4790 Liner 261' 4-1/2" 12.6# L-80 8862' - 9600' 8736' - 8800' 8430 7500 Liner 1817' 3-3/16X2-7/8 8684' - 10501' 8636' - 9066' Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 8750' 0 0 - Packers and SSSV (type and measured depth) 4-1/2" BKR KB LNR TOP BKR 8684 7-5/8"X4-1/2" BKR SABL-3 PKR 8703 7-5/8"X4-1l2" TIW HBBP PKR 8862 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: 255 26207 85 1335 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory T! Development (~`; - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ ' Gas WAG ~ GINJ ~ WINJ 1! WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre d' Title Data Management Engineer Signature - Phone 564-4944 Date 12/15/2008 Form 10-404 Revised 04/2006 ~ 1u~~ ~ (~ Submit Original Only ~~~~ E-35A 201-119 PERF ATTACHMENT C~ Sw Name O eration Date Perf Operation Code Meas Depth Top Meas De th Base Tvd Depth Top Tvd De th Base E-35A 7/3/01 PER 10,200. 10,440. 9,069.55 9,070.37 E-35A 5/12/03 APF 9,815. 9,865. 9,076.94 9,084.46 E-35A 12/12/08 BPS -~ 10,440. 9,073.13 9,070.37 E-35A 12/13/08 APF 8,981. _ 9,386. 8,776.71 8,835.05 AB ABANDONED PER ~ PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • u E-35A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/11/2008 CTU #9 1.75" CT Job Scope: Drift & Log/Set CIBP/Ext Perf w. WWP «InterAct Publishing» Conduct BOPE testing. RIH w. PDS Memory Gama/CCL and 2.25" JSN -log from 10100 to 8600 "'** Job continued on 12/12/08 WSR **** 12/12/2008 CTU 9 w/ 1.75" ***CT Continue job from 12/11/08 WSR *** Job Scope: Set CIBP/Add Pert «InterAct Publishing» Continue POOH w/logging tools Verify good data recovered with + 16' correction. RIH w. WF 2 7/8" CIBP Set @ 10030' corrected de th. RIH w. 2.25" JSN tag and confirm CIBP depth PUH 30' and circulate kill we11. POOH laying in New 150 LSRV FloPro across pertorations.Fill hole and conduct no flow test -well dead. MU/RIH w/ 2" HSD- 6 SPF - 60 deg phase guns '"'""* Job continued on 12/13/08 WSR **** 12/13/2008. CTU 9 - 1.75 CT Continue from 12/12/08 WSR Job Scope: Ext perts w. WWP «InterAct Publishing» RIH w/ 2' HSD - 6 SPF - 60° phase and pert interval from 8981' to 9386'. Good surtace indication guns fired. While POOH hung up around the 3 1/2" x 3 3/13" cross over made several attempts at getting by eventually got by and continued OOH. At surtace no evident marks on CTC or ?locking swivel but just below the locking swivel on the deployment bar there was marks 8"-10" long x 3/8" wide. All shots were fired and 1/2" ball recovered. RIH w. 1.75" slick assembly & 1.75" JSN Tag CIBP PU and circulate out well to diesel. Leave well SI and notify DSO. ***Job Complete*** I FLUIDS PUMPED BBLS 174 DIESEL 102 METH 24 FLOPRO 70 2% KCL 370 Total WellServiceReport • WELL SERVICE REPORT • Page 1 of 2 WELL JOB SCOPE UNIT E-35A PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 12111/2008 JEWELRY LOG--DEPTH CONTROL SCARPELLA COST CODE PLUS KEY PERSON NIGHT SUPV PBEPDWL35-C DS-ANDERSON MCINNIS MIN ID DEPTH TTL SIZE 2.37 " 9998 FT 0 " CTU #9 1.75" CT Job Scope: Drift & Log/set CIBP1Ext Pert w. WWP «InterAcf Publishng» Conduct BOPS testing. RIH w. PDS Memory Gama/CCL and 2.25" JSN - lo_g_from 10100 to 8600 **** Job continued on 12/12/08 WSR **** LOG ENTRIES Init Tb , lA, OA 1340 1360 0 TIME DEPTN TBG CTP BPM BBLS COMMENTS 00:01 0 Continue 'ob from 121101200$ 00:15 0 PU CT in'ector 02:15 0 in'ector on well 02:40 0 Om Fluid ack CT and surface lines w. 60140 Methanol 03:14 0 Top equilizing port on BOP leaking, continue with testing surface valves 04:18 0 Fluid ack and conduct full bod test, still leakin 05:24 0 Orin re aired, tart B 08:38 0 Having problems with valves in reverse out skid, continue with testin other com onents and call out rease crew 09:25 0 Grease crew on location, PJSM 09:38 0 Start reasin reverse out and choke assemblies 10:11 0 Continue with BOPE testin 10:53 ~ 0 Attem tin to test inner reel valve 11:56 0 Having problems with inner reel valve testing, call shop for parts and move forward with testin 11:59 0 Start on testin ba and inserts to rams 12:17 0 Lost hydraulic seal on blind shear ram. Bleed pressure, clean s stem, call mechanic 13:42 0 Attem t to et inner real valve tested for the third time 13:56 0 Inner reel valve assed PT. Mechanic onsite to service BOP. 15:05 0 20 BOP function tested. Hydraulic leak repaired. Continue BOP testin . 17:00 0 ROPE testing complete, pop off well and prep end of pipe for connector 17:15 0 Cut i e and MU Weatherford MHA 17:29 0 Pull test coil connector to 15k 17:36 0 22* Pressure test MHA and TIW valve floor safe valve to 3500 si 17:55 0 SLB Crew chap a and PJSM 19:08 0 MU PDS carrier and 2.25" JSN 19:45 0 Pressure test surface a ui ment Low/Hi h 404/4000 20:10 0 O en well - on line with meths ear to knock WHP down. 20:13 0 1340 1000 3 5/0* Swa to 2% KCL 20:34 0 890 1500 4.7 65/0* Swa t meth -RIH 20:45 0 700 850 3 70 RIH w. Weatherford 2.1$8" MHA. 2.2" PDS Carrier w. Gama/CCL, 2" x-over, 2,1" x-over, 2.25" JSN OAL= 15.01' 21:43 5230 650 470 Wt ck at 9.5k -bleed IA down 1400 - as 22:20 8000 765 0 Wt ck -chains sli in 22:23 8000 770 25 On line with meth 22:27 8000 825 3400 1.7 75/0* Swa to water and warm chains 22:49 8000 850 3450 1.7 87 RIH 23:09 9900 770 100 Wt ck at 21.5k - !A 200 -fluid surface 23:12 10100 765 100 RIH to 10100 elec 10086 mech 23:19 10100 775 400 .5 9 um wa er o warm chains u . 23:24 10100 790 150 1.2 POH to in at 40 f m 23:26 10000 795 125 1.2 95/0* Paint BLUE/YELLOW flag at 10000 (elec} - 9987 (mech)- swap to meth to FP coil 23:31 10000 790 50 .5 15 POH I in http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?ID=6A220B6933AD48... 1.2!23/2008 • We1lServiceReport ~ 23:59 ~ 8600 ~ 920 ~ 250 ~ • 18* ~ Stop at 8600 Page 2 of 2 a5 oo~s or ~ io Kc;~. xxx bbis of 150 I.SRV FloPro (iVew) xxx bbls of Diesel 50 bbis of 60/40 Methanol Perform daily inspection of tanks and sec Visualiy inspected space between inner containment ~r haul on return tank http:/lapps2-alaska.bpweb.bp.com/awgrs-wel lservicereport/default.aspx?ID=6A220B6933 AD48... 12/23/2008 • . We1lServiceReport Page 1 of 3 WELL SERVICE REPORT WELL JOB SGOPE UNIT E~35A PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 12/12/2008 SET MECHANICAL PLUG SCARPELIA COST CODE PLUS KEY PERSON NIGHT SUPV PBEPDWL35-C DS-W{LLIAMS MCINNIS MIN ID DEPTH TTL SIZE 2.37 " 9998 FT 0 " POOH wllogging tools Verify good data recovered with + 16' correction. RIH w. WF 2 7!8" CIBP Set Q 10030' corrected depth. RIH w. 2.25" JSN tag and confirm GIBP depth PUH 30' and circulate kill well. POOH laying in New 150 LSRV FloPro across perforations.Fill hole and conduct no flow test -welt dead. MU/RIH w/ 2" HSD- 6 SPF - 60 deg phase guns **** Job continued on 12!13!08 WSR **** LOG ENTRIES Init Tb , IA, OA 925 200 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 8600 920 275 .5 18 Cont POH w/ PDS -down on um 01:32 0 820 100 On surface 01:45 0 Break off well 01:51 0 LD tools 02:10 0 Veri data - +16' shift correction 02;41 0 MU / WOT 2.18 CC-2.18 DCV-2.18 Disco(5/S baN)- 2.18 BCSub/R Disk-2.12 Set toaE 1/2 bait - 2 718 CIBP-2 718 GIBP - OAL 8.2' 02:50 0 Stab onto well - 02:55 0 2 PT surface a ui 300!2000 03:05 0 RIH - w! CIBP 04:00 ~ 5200 1170 0 Wt ck at 10.5k 04:48 8600 1240 0 Wt ck at 17.5k 04:51 8700 1240 0 No roblem nt r'n 05:08 10014 1260 0 Stop- at flag - reset elec counter to corrected depth of 10014.2 ;~~ roblems enterin the 2 718 liner 05:12 10049 1260 0 R1H to bail dro sition 05:15 10049 1260 0 Load i launch 1/2 ball -confirm ball rollin 05:22 10030 1260 0 1.5 5 PUH to CIBP de th at 10030 05:25 10030 1285 2300 1.5 24 Pum ball 05:40 10030 1295 400 .5 25 Slow um rate 05:47 10030 1300 600 .5 30 Ball on seat 05:48 10030 1300 2200 .5 30.5 Too{ sheared at 2200 si 05:49 10030 1320 70 Clean PU 05:51 10030 1325 70 Set 3k down on CIBP 05:52 10030 1325 60 POH » noti SLBfTCP 07:16 0 1230 0 BHA surface, PJSM 07:37 0 Po off wall and brake down BHA, SLB/TCP on location 07:53 0 Recovered 1/2" ball 08:07 0 Om Fill coil w. 60!40 meth to ressure test 08:21 0 13 Pressure test MHA and lockin swivel to 3500 si 08:29 0 15 Ca and ressure test 7" Otis tree ca on stack to 2500 si 08:40 0 PJSM w. TCP S ecialist on liftin o s 09:02 0 Start loadin handlin a ui ment and uns onto WWP 09:24 0 Anti to-b{ock on crane locked up will not allow winch or boom to sco a out. Call CH2 mechanic 09:43 0 Problem fi ured out and re aired, contiune 10:15 0 Line up down kill side of stack to pressure test to 1500 psi against swab valve be#ore o enin 10:19 0 1244 2.5 0 Swab open 23 turns and start 5 bbis spear of 60/40 meth IAP= 130 OAP= 0 10:24 0 1214 4.7 5m Swa to 2% KCL 10:36 0 2800 0 48 Shut down urn in a ears formation is ve ti ht. 10:41 0 2144 .6 48k Very slow bleed down, swap to 60/40 meth and freeze protect surface lines and ut a cou ie barrels down tree 10:48 0 MOC/PJSM 10:51 0 54m Shut down umping all surface equipment and 4 bbls down well. http://apps2-ai aska.bpweb.bp.com/awgrs-well servicereport/default.aspx?ID=2FD2FB78900C448... 12/23/2008 • We1lServiceReport Page 2 of 3 11:21 D MU two stin ers and 2.25" 11:53 0 0 LPPT 300 si 11:59 0 3 NPPT 4000 si 12:05 0 1220 O en swab 23 turns 12:07 0 1220 RIH w. 2.188" MHA, x-over, two 2" stin ers, 2.25" JSN OAL= 13.51' 12:10 0 Coil Op having problems getting in hole bleed off gas while attem tin fo et in hole 12:43 743 778 6m*" Shut in choke and freeze rotect surface lines 13:38 6485 Wt ck 12k riw 5.8k 13:50 8575 Wt ck 17k, riw 8.2k 14:04 10000 1280 3321 1.5 Ok Online with 2% KCL down the call, crack choke to take returns and establish stable circulation rate 14:29 10006 At fla an coil, conect de th to confirm set de th of CIBP 14:31 10030 Ta CIBP town en ineers ob'ective mef PUH 30' 19k and start circulation kil! 15:02 10000 1275 3142 1.5 34/Ok o L at nozzle, zero micro motion and start using kill sheet bottoms u #or volume um ed and choke ad'ustments 15:08 10000 1200 3213 1.5 8.4 Start using MD for volume pump to meet 500' TVD choke ad'ustments of 75 si 15:12 10000 1125 3182 1.5 14.5 Reduce WHP 75 si IAP= 130, OAP= 0 as in returns 15:16 10000 1050 3163 1.5 20.7 Reduce WHP 75 si IAP= 130, OAP= 0 intermintant as and fluid 15:20 10000 975 3136 1.5 26.8 Reduce WHP 75 si IAP= 130, OAP= 0 15:25 10000 900 3083 1.5 32.9 Reduce WHP 75 si IAP= 130, OAP= 0 intermintant as and fluid 15:29 10000 825 3024 1.5 39 Reduce WNP 75 si IAP= 130, OAP= 0 intermintant as and fluid 15:33 10000 750 2966 1.5 45.1 Reduce WHP 75 si IAP= 130, OAP= 0 'intermintant as and fluid 15:37 10000 675 29D7 1.5 51.3 Reduce WHP 75 si IAP= 130, OAP= 0 intermintant as and fluid 15:41 10000 600 2849 1.5 57.4 Reduce WHP 75 si IAP= 130, OAP= 0 15:45 10000 525 2790 1.5 63.5 Reduce WHP 75 si IAP= 130, OAP= 0 15:49 1000D 450 2731 1.5 69.6 Reduce WHP 75 si IAP= 130, OAP= 0 15:53 1D000 375 2673 1.5 75.7 Reduce WHP 75 si IAP= 130, OAP= 0 15:57 10000 300 2610 1.5 81.9 Reduce WHP 75 si IAP= 130, OAP= 0 16:01 10000 225 2578 1.5 88 Reduce WHP 75 sl IAP= 130, OAP= 0 16:05 10000 150 2519 1.5 94.1 Reduce WHP 75 si IAP= 130, OAP= 0 16:09 - 10000 75 2460 1.5 100.2 Reduce WHP 75 si IAP= 130, OAP= 0 16:13 10000 0 2401 1.5 106.4 Reduce WHP 75 si IAP= 130, OAP= 0 16:24 10000 0 2316 1.5 122E Well a ears dead swa to New FloPro down CT 15bbls 16:42 10000 0 1644 1.5 137k* wa to 0 17:05 10000 D 1855 1 157 FloPro nozzle, let one bbl out nozzle 215' u backside of coil 17:06 10000 0 712 .6 158 Reduce um rate and start la in in 1:1 80 f m = .6 b m 17:23 8350 0 875 .8 173 FloPro out nozzle, cantinue POOH 17:50 5400 0 817 .9 194/0* Swa to diesel down the coil 1$:14 4900 0 3780 1.7 35 Diesel nozzle increase um rate 18:20 4900 0 3800 1.7 46 Diesel around nozzle, crew chap a com fete, POOH 19:04 1000 0 321 .3 112 Well displace on overbalanced by 229 psi, reduce pump rate to CT dis lacement CT void 19:19 0 0 0 ,3 125 On surface 19:20 0 129 Close swab - FP surface a ui t tanks 19:36 0 129.7 Pum across flow cross to fill hole for No-flow test 19:40 0 Start no low test - 19:50 0 PJSM -for LD tools 20:10 0 129.7 Pum across tree- uick returns - no fluid toss 2fl:12 D MU lockin swivel to MHA and PT same -Pest late orin leaked 20:40 0 No flow from well in 1 hr 20:46 0 Re lace orin - PT MHA - 500!3000 - ood tesf 21:01 0 130.6* Pum across tree - 0.1 bbls to fill welt in 1 hr 10 min 21:05 0 PJSM; MU guns, pinch pts, overhead work, slippery surface, traction device, communication, sto 'ob, safe area. 21:30 0 130.7 Pum across tre - 0.1 bbls #o fill well in 1 hr 29min 21:32 0 Now the lockin swivel is made u and PT 900/3000 21:45 0 Set u ri floor un handlin for rennin ens 22:14 0 Safe 'oint drill -all hands and valves in osition -1 min 10 sec 22:20 0 Start Makin u ens 23:11 0 Guns made u - de to ment bar made u 23:14 0 Stab on with coil 23:24 0 RIH with 2" ens 23:59 0 Continue RIH w( ens Final Tb , IA, QA http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?ID=2FD2FB789000448... 12/23/2008 • ';3 of3 ~o uws vi ovr4u rnear 256 bbls of 2°~ KCL 15 bbis of New FioPro 150k LSRV 131 bbls of Diesel - -- Perform daily visual secondary containment and tank inspection http://apps2-alaska.bpweb.bp.corn/awgrs-wellservicereport/default. aspx?ID=2FD2FB78900C448... 12/2312008 WellServiceReport ~ • WeIlServiceReport Page 1 of 2 1NELL SERVICE REPORT WELL JOB SCOPE UNIT E-35A PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 12/13/2008 PERFORATING; RIG DOWN SCARPELI.A COST CODE PLUS KEY PERSON NIGHT SUPV PBEPDWL35-C DS-ANDER50N MCINNIS MIN ID DEPTH TTL SIZE 2.37 " 9998 FT 0 " CTU 9 -1.75 CT Continue from 12/12/08 WSR Job Scope: Ext perfs w.1n1WP «InterAct Publishing» RIH w/ 2' HSD - 6 SPF - 60° phase and pert interval from 8981' to 9386'. Good surface indication guns fired. While POOH hung up around the 3 112" x 3 3113" cross over made several attempts at getting by eventually cot by and continued OOH. At surface no evident marks on CTC or locking swivel but just below the locking swivel on the d sployment bar there was marks 8"-10" long x 318" wide. All shots were fired and 1/2" ball recovered. RIH w. 1.75" slick assembly & 1.75" JSN Tag CIBP PU and circulate out well to diesel. Leave well SI and notify DSO. ***Job Comoiete*** LOG ENTRIES Init Tb IA, OA 0 130 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 Continue RIH w/ 2" guns 00:47 5200 0 0 Wt ck at 9.5k 01:40 8550 0 400 Wt ck at 15.5k 01:48 10053 Ta CIBP at 10053 01:49 10048 PU at 10048 01:59 10029 Correct counter 1 o btm shot -10029.3(elec) 9571(mech) 02:00 9386 ull u to ball dn~p depth for btm shot at 9386 and top shot at 8981 02:20 9386 0 Om On line with meth spear 02:22 9386 0 1535 .9 2k Swa to water 02:27 ~ 9386 20 3200 1.5 7f Swa to flo ro 02:37 9386 30 2900 1.5 23k Swa to water 02:39 9386 0 540 1.5 25 Down on um 02:40 9386 0 540 0 0 load /launch 1/:? ball 02:50 9386 15 2880 1.5 25 Pum ball down 02:53 9386 30 2475 1.5 30m Swa to meth 03:06 9386 15 850 .7 50 Stow rate 03:11 9386 20 950 .7 53.9 Ball on seat 03:13 9386 0 2660 .7 54.9 Surface indication puns fired 03:14 9396 0 770 1.5 56 POH cont FP coil 03:19 9148 30 2670 1.5 62 Ta at 9128'a 03:21 9148 30 2650 1.5 68 Down on um -close choke - FP surface equip and coil 04:01 9148 0 80 Pump down BS -well pressures up -work pipe up/dn RIH to 9500 to burn off burrs- cunt to tag at 9148 - go down hole freely 04:07 9148 0 85 Pum down coil ender tension - no luck pullin~up hole 04:30 0 0 RBIH to bum burrs off -Confer with CT Cord 05:01 0 0 Pull up hole -tag at 9148 -held 5k strain -saw weight bleed off - uil bak fo 5k ow3r -pipe started moving erratically and came free. 05:10 0 0 .2 90 Continue POH - <eeping hole ful! down BSw/meth at min rate 06:31 0 0 .2 110.3 On surface 06:35 0 0 110.5 Pum across we'I - 0.2 bbls to fill 06:36 0 0 110.5 Start no flow test 07:06 0 .3 110.5 Pum across to of well to check losses 07:11 0 112 Fctahlished returns_off line w. sumo. 1.5 bbls lost = 132.4' down backside of uns 07:40 0 112 Pum across to of well 07:42 0 113.4 Gettin returns 07:44 0 PJSM with crew 08:00 0 Start ullin un:: 08:15 0 BODE drill 08:19 0 Continue ullin duns 09:40 0 11 Guns O H r~ swab 23 turns 09:45 0 PJSM on handling of equipment from floor down to ground 10:37 0 Floor cleared, PJSM for dean out 10:53 0 Pre end of i e for CTC and make up http://apps2-alaska.bpweb.by.com/awgrs-wellservicereport/de fault. aspx?ID=CCB23 39B2C8947... 12/23/2008 We1lServiceReport • Page 2 of 2 11:12 0 Pull test CTC to 10k 11:17 0 MU BHA 11:42 0 Stab in ector onto wellhead and line u to flood surface lines 11:55 0 Om Flood surface a ui ment w. 60!40 Meth 11:57 0 10 LPPT 244 si 12:03 0 11 HPPT 4067 si 12:11 0 RIH w. 1.9" CRC, 1.75" DCV's, two 2" stingers, 1.75" JSN OAL= 12.125' 14:02 9121 wt ck - u wei h# 17k. rih wt - 11 k. 14:18 0 At CIBP. PU to start circ out of kill fluids. 14:21 10028 Found suction ca leakin on SPM um .Isolate and re air. 14:55 10028 PT um and continue with o eration 14:56 10028 19 2180 1.2 1210 Start um in water 15:13 10028 15 812 .8 20 Swa to FloPro 15:23 10028 8 865 1.8 28 Swa to water 15:30 10028 38 2780 1.8 35 KCL at nozzle 15:40 1002$ 41 2759 1.8 55 Gel at nozzle 15:42 10028 37 2810 1.8 63 KCL at nozzle 15:43 10028 36 2765 1.8 66* Swa #o deisel 16:04 10028 26 3320 1.6 101 diesel at nozzle 16:13 10028 28 3200 1.6 112 Start POOH. 17:28 2900 161 191 0 240 Diesel to surface and a few bbls. shut down oum~,. Continue OOH with BHA. 17:55 0 300 44 0 240 Ta ed u with BHA. Close swab. 23 1!2 turns. 17:56 0 308 40 244 Flush out stack and surface Tines with methanol 18:08 0 SLB crew chap e 18:20 0 Po off well and break dawn BHA 18:30 0 Start ri in down unit 23:59 0 End 'ob. Final T , IA OA 308 134 0 70 bbls 2%KCL 102 bbls 60140 Meth 24 bbls FloPro 174 bbls Diesel Perform daily inspection of tanks and secondary containment VisualEY_ irsspected space- between hauls on_500 bbl OT BOTTOM DEPTH http://apps2-alaska.bpweb.bp. com/awgrs-wellservicereport/default.aspx?ID=C CB2339B2C8947... 12/23/2008 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _ Inscrts\Microfilm _ Marker.doc 01/22/04 Schlumberger NO. 3095 Alaska Data & Consulting Services Company: State of Alaska 3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color (' Well Job # Log Description Date Blueline Prints CD D.S.06-02 \.::¡ '1- -['flCX 10874399 PROD PROFILE 11/22/03 1 E-35A ;£Ln' ... \ \ L:I 10715373 MEM PROD PROFILE 12/27/03 1 P1-06 \ q () '- \ -::;; 'O-::¡.. 10703984 PPROFILE/DEFT/GHOST 12/24/03 1 D.S. 15-49A I'=-Jf)h~ IT ~ 10679043 LDL 12/23/03 1 M-38A .f:)("'){.... ~~ 10709678 LDL 12/25/03 1 D.S.09-15 \'-::¡-:¡ -( ~( íJ 10709680 STATIC SURVEY 12/27/03 1 X-27 '9; 1:..\ ---() ()'"'~1 10679046 LDL 01/08104 1 ~ I l \ .'"" ", ",,,"'" ':-;::';".:,4::1~ :/,~, ':',>..j:""."',,,,,. :,V': ,."",..,... " '. , , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotechnical Data Center LR2-1 RECE v, 3940 Arctic Blvd, Suite 300 900 E. Benson Blvd, ' ,I ED Anchorage, AK 99503-5711 Anchorage, Alaska 99508 ATTN: Beth !l\~J -) C "004 ',..~...~.. ". '"'''''' "'"'''''' , D t D I' d '-'I 'Ii \. L R' "~.. \ \ . C:.. ' a e e Ivere : ecelved by: "': ~~ \....( ^'/,,'¡~ .C\.:-,.~.V\ AJs!ka OU & Gas Gons.Commlloo Andøaøe '. ('< I L,~ ~¡ k\ U rt::: R'" ~'-- IE \[Ì) (¡'¡\ 6J¡ t) n n ~ @(GAò\1tl\1it;.¡¡JlfCD U.<iÞ {.UlN~ ~ "-"--:--......., <::';'~,,'\ \ (, Permit to Drill 2011190 MD 10501 TVD DATA SUBMITTAL COMPLIANCE REPORT 7~30~2003 Well Name/No. PRUDHOE BAY UNIT E-35A Operator BP EXPLORATION (ALASKA) INC 9066 -' Completion Dar 7/4/2001 _.~- Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22557-01-00 UlC N REQUIRED INFORMATION Mud Log N_po Sample N_9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital i:lia Fmt Log Scale .--Gort~sated NEU/GR 2 Directional Survey Name Directional Survey Ver LIS Verification Ver LIS Verification Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint) Log Media Run No Interval Start Stop OH / Dataset CH Received Number Comments FINAL 8601 FINAL 8601 FINAL FINAL 10459 OH 8/3/2001 8601-10459 BL, Sepia 10459 CH 8/3~/2001 __j.Q224 8601-10459, Digital Data ch 8/2/2001 Directional Survey Digital Data ch 8/2/2001 Directional Survey Paper Copy 1 9106 10468 Open 8/23/2002 ~9 1 9106 10468 Open 8/23/2002 1 9110 10501 Case 1/31/2003 --'KF~5 Digital Well Logging Data Interval Name Start Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? "'"'/"¢'N'---'~ Analysis ~Y-,NN-'""~" R~.~.iv~.d ? Daily History Received? ~ N Formation Tops ~)/N Comments: Permit to Drill 2011190 DATA SUBMITTAL COMPLIANCE REPORT 7~30~2003 Well Name/No. PRUDHOE BAY UNIT E-35A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22557-01-00 MD 10501 TVD Compliance Reviewed By: Completion Statu 1-OIL Current Status 1-OIL UIC N Date: c.__/_ _~_~__. _~_ ._~j___~_.. WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: RE' State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM COLOR Open Hole I I 1 Res. Eval. CH I 1 .,~C)~''~ 1 1 E-35A 5-11-03 Mech. CH 1 Caliper Survey Signed ' Print Name: Phone:(907) 245-8951 Fax:(907) 245-8952 Date · ;'~.~ ........ ~' ,. i:'"'c', e" ' ...... ' ~chor~ge PRoAcTivE Dinqnosfic SERVICES, lac., ~ lO K STREET SUITE 2~, Ancho~qE, AK 99~Ol E-m~l: pdsanchorage~memo~log, com Website: ~.memo~log. com !' i' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE] SuspendE] Operation Shutdownr--~ Perforate. VadanceE] Annuar DisposalE] After Casincl[~ Repair WellE] Plucl Perforations[~ stimulateE] Time Extension E] Other~'-I Change Approved ProgramF~ Pull TubingE] Perforate New PoolF~ Re-enter Suspended WellE] ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement [] ExploratoryE] 201-119 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 StratigraphicE] Service[~ 50-029-22557-01-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 65.00 E-35A 8. Property Designation: 10. Field/Pool(s): 028304 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 10501 feet true vertical 9066 feet Plugs (measured) Effective Depth measured 10464 feet Junk (measured) true vertical 9069 feet Casing Length Size MD TVD Burst Collapse Conductor 117' 20" 152' 152' 40K 520 Surface 3592' 10-3/4" 3627' 3622' 80K 2480 Intermediate 9090' 7-5/8" 8998' 8780' 80K 4790 Sidetrack Liner 261' 4-1/2" 8862'-9123' 8736'-8800' 80K 7500 Sidetrack Liner 1817' 3-3/16"x2-7/8" 8684'-10501' 8636'-9066' 80K (---) x 11160 Perforation depth: Measured depth: Open Peffs 9815'-9865', 10200'-10440' RECE VEL} True vertical depth: Open Perfs 9076'-9084', 9070'-9070'JUN Z 6 2003 Tubing:( size, grade, and measured depth) 4-1/2" 12.6# L-80 NSCT @ 8750'. Aiasl(a 0ii & Gas Ce,$. At~ch0ra~e Packers & SSSV (type & measured depth) 4-1/2" BKR KB LINER Top PKR @ 8684'. 7-5/8" x 4-1/2" BKR SABL-3 PKR @ 8703'. 4-1/2" HES 'HXO' SSSV @ 2205'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1104 19954 210 1254 Subsequent to operation: 970 24948 272 1060 14. Attachments: 15. Well Class after proposed work: Exploratory E] Development~ serviceE] Copies of Logs and Surveys run _ 16. Well Status after proposed work: O,[] CasE] WAGE] G~NJE] W~NJE] WDSPLI--I Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact DeWa)/ne R. Schnorr I N/A Printed Name DeWavx~e R. Schnorr /I Title Techical Assistant S,gnature ~-~'f"/'Czcc'~/~"P~~~ . 07/564-5174 Date Mav 29,2003 ' '-' - k. nni£-II hfn/ f Form 10-404 Revised 2/2003 E-35A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/11/2003 PERFORATING: JEWELRY LOG--DEPTH CONTROL; PERFORATING 05/12/2003 PERFORATING: PERFORATING EVENT SUMMARY 05/11/03 MIRU CTU # 9. PJSM. (2 HOUR RIG UP). PT/BOPE/LINES, 600/3500 PSI, PULL TEST WOT/MHA 20K. RUN PDS MEMORY TOOLS. LOGGED 9900-9350 @ 35 FPM. POH AND VERIFY DATA. JOB IN PROGRESS. 05/12/O3 PERFORATE 9815' - 9865' AT SPF USING 2" POWERJET GUNS WITH RANDOM ORIENTATION AND 60 DEGREE PHASING. ALL SHOTS FIRED ON ALL GUNS RUNS. WHP 225 PSI. WILL NEED PBGL TO BRING WELL ON FP WELL, WHP 0 AFTER FP. RDMO <<< NOTIFY PAD OPERATOR / PCC OF WELL SHUT-IN STATUS >>> FLUIDS PUMPED BBLS 158 METHANOL 122 2% KCL WATER 280 TOTAL ADD PERFS 05/12/2003 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" HSD POWERJET, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9815' - 9865' Page 1 TREE= 4-1/16" CIVV SAFETY NOTES: WELL EXCEEDS 70° @ 8925' AID WB. LHEAD = 5M FMC ' ' E 35A ACTUATOR BAKER I KB. EL~ = ~5~29' BF. ELEV = 34.79' . ...... KOP-- ~4~ Datum'l-VD = 8800' SS GAS LIFT MANDRELS ~ 3 4053 4047 0 MI~ DV BK-5 04/23/01' [--~ 2 6731 6726 0 MER DV BK-5 04/23/01 1 8'125 8020 0 MER DV BK-5 04/23/01 Minimum ID = 2.37" @ 0008' 3-$/1 6" X 2-?18 XO ~'l ~-, I 8~8~' MTOPOFBKRCOCSUe~SE~C^SS¥,~D=2.39" I ~ 8?02' H3-1/2" R-45 CNR X 3-3/16" |TC11 CNRXO,~D=2.80" I ,I I t 87a8' Id4-1/:2' .ES XN NIP, ID = 3.725" 14-1r2"mG, 12.6#,C-80NSCT, 0.0152 bp*, 'D = 3.958" ~ 8750' I--~ ~' I o?so' I-I~-~/~"~,~I I*°~°~-~"~l--I ~2' I--- ~,~2' I-~?-6/8"×4-112"TIW.BBP I PI~FOR~TION $Uh/IMARY REF LOG: TCP PERF , ( ANGLEATTOPFERF: 77 @ 9815' Note: Refer to Production DB for historical perf dala '~1 9122' HTOPBAKERWSTRAYW/RATCOBALT60TAG I SIZE SFF INTERVAL Opn/Sqz DATE ~ 2" 4 9815- 9865 O 5/12/2003 ~ 2" 4 10200- 10440 O 07/03/01 I I-I 9600' · : . 10464' DATE REV BY COIVIVIENTS DATE REV BY I COMMENTS PRUDHOE BAY UNIT 06/11/95 KSB ORIGINAL COMPLETION WELL: E-35A 06/11/95 I KSB SIDETRACK COIVPLETION PERMIT No: 2011190 07/05/01 C'rD SIDETRACK APl No: 50-029-22557-01 04/27/01 CH/TP CORRECTIONS SEC6, T11N, R14F_, 1187' FNL &501' FEL 07/21/01 CH/TP i CORRECTIONS i 05/12/03 JLG/KK ADPERFS BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: TCP PERF ANGLEATTOPFERF: 77 @ 9815' Note: Refer to Production DB for historical perf dala SIZE SFF INTERVAL Opn/Sqz DATE 2" 4 9815 - 9865 O 5/1 2/2003 2" 4 10200 - 10440 O 07/03/01 DATE REV BY COrvtMENTS DATE REV BY COMMENTS 06/11/95 KSB ORIGINAL COMPLETION 06/11/95 KSB SIDETRACK COIVPLETION 07/05/01 CTD SIDETRACK 04/27/01 CH/TP CORRECTIONS 07~21/01 CH/TP CORRECTIONS 05/12/03 JLG/KK ADPERFS To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 30, 2003 MWD Formation Evaluation .Logs · E-35A, AK-MW-11114 E-35A' Digital Log Images 50-029-22557-01 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 Bl. vd. Anchorage, Alaska 99508 Date: Sign~ RECE%VED JAN ~ 1 ~.00~ 0it & Ge~ Cons. WELL LOG TRANSMITTAL To: State of Alaska August 21, 2002 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs E-35A, AK-MW- 11114 1 LDWG formatted Disc with verification listing. API#: 50-02%2255%01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical iData Center LR2-1 900 'E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED AUG 2 5 2O02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate _ Microbe Treatment Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~]e, AK 99519-6612 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service_ 4. Location of well at surface 1186' FNL, 500' FEL, Sec. 06, T11N, R14E, UM At top of productive interval 1810' FNL, 1516' FEL, Sec. 06, T11N, R14E, UM At effective depth 1215' FNL, 1556' FEL, Sec. 06, T11N, R14E, UM At total depth 1186' FNL, 1533' FEL, Sec. 06, T11 N, R14E, UM (asp's 664470, 5975877) (asp's 663471, 5975232) (asp's 663415, 5975826) (asp°s 663438, 5975855) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 117' Surface 3592' Intermediate 9090' Slotted Liner 261' Slotted Liner 1817' 10501 feet Plugs (measured) 9066 feet 10464 feet Junk (measured) 9069 feet 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number E-35A 9. Permit number / approval number 201-119 10. APl number 50-029-22557-01 11. Field / Pool Prudhoe Bay Oil Pool Size Cemented Measured Depth True Vertical Depth 20" 260 sx ArcticSet (Aprox) 152' 152' 10-3/4" 1175 sx CS III, 375 sx 3627' 3622' Class 'G' 7-5/8" 485 sx Class 'G' 8998' 8780' 4-1/2" Uncemented 8862' - 9123' 8736' - 8800' 3-3/16" x 2-7/8" 118 cf 'G', Uncemented 8684' - 10501' 8636'.- 9066' Perforation depth: measured Open Perfs 10200' - 10440' true vertical Open Perfs 9070' - 9070' RECEIVED Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) MAR g8 4-1/2", 12.6#, L-80 TBG @ 8703'. 4-1/2", 12.6# Tubing Tail @ 8750'. 4-1/2" BKR KB LNR TOP PKR @ 8684'. 7-5/8" x 4-1/2" BKR SABL-3 P~3'. 7-5/8" x 4-1/2" TIW HBBP PKR @ 8862'. 4-1/2" HES HXO SSSV Nipple @ 2205'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 03/06/2002 Subsequent to operation 03/21/2002 OiI-Bbl 950 Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 21670 82 1291 17435 282 Casing Pressure Tubing Pressure 954 911 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil _X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is trl~e and correct to the best of my knowledge. ,~~l~.~/ ,~~)~ Title: Techical Assistant DeWayne R. Schnorr ~ Date March 25, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~~ E-35A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/07/2002 02/O8/2002 O3/O7/2O02 MICROBE TREATMENT: DRIFT/TAG; MICROBE TREATMENT MICROBE TREATMENT: AC-TIFL MICROBE TREATMENT: MICROBE TREATMENT EVENT SUMMARY 02/0~02 RIH W/1.5" ROLLER STEM, 2.25" CENTRALIZER & SAMPLE BAILER. OVERCOME BY DEVIATION @ 9058' SLM. BAILER EMPTY. RDMO. 02/08/02 T/I/O = 950/1380/0. TEMP = 1127. TIFL PASSED. (PRE-MICROBE TREATMENT.) IA JEWLERY FROZEN. THAWED AND SHOT INITIAL IA FL @ 6640'. SI IN WELL AND TBG PRESSURED UP TO 2540 PSI. BLED IA FROM 1380 PSI TO 500 PSI IN 1 HOUR. IA FL REMAINED AT 6640'. SI IN IA BLEED AND MONITORED lAP FOR 30 MINIUTES. NO INCREASE IN lAP. PUT WELL BOL. FINALWHP's = 1040/50O/0. 03/07/02 MICROBE STIMULATION --- 451 BBLS MICROBE MIXTURE(12 DRUMMS BEN- BAC,12 DRUMSPARA BAC, 6 DRUMS CORROSO BAC MIXED W/2% KCL TO MAKE UP DIFFERENCE TO 451 BBLS) , 34 BBLS MEOH, 123 BBLS CRUDE , 20 BBLS 2% KCL FLUIDS PUMPED BBLS 34 METHANOL WATER 123 CRUDE 20 2% KCL WATER 451 MICROBE MIXTURE(12 DRUMMS BEN-BAC,12 DRUMSPARA BAC, 6 DRUMS CORROSO BAC MIXED W/2% KCL TO MAKE UP DIFFERENCE TO 451 BBLS) 628 TOTAL Page 1 STATE OF ALASKA il .... ALASKA OIL AND GAS CONSERVATION COMM,$SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-119 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22557-01 i-' ,7--17,.;. '-:'7 v, '~ 4. Location of well at surface , ,-: '~:~' :~'~' ~ 9. Unit or Lease Name _~i ~.~..[~ ,:[ LOCATION~ Prudhoe Bay Unit 1187' SNL, 501' WEL, SEC. 06, T11N, R14E, UM ~ ~ "' At top of productive interval i i"' i : 1810' SNL, 1516' WEL, SEC. 06, T11N, R14E, UMi V£i'jj-:!~;:i ~~ At total depth ~ ~ --'"~-~ ..... ~ I g. H~J~. 10. Well Number ~ 1186' SNL, 153~ WEL, SEC. 06, T11N, R14E, UM ......' ~-"7--~'~ E-35A 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 65.29' ADL 028304 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. Ne. of Completions 6/30/2001 7/2/2001 7/4/2001 N/A MSLI One 17. Total Depth (MD+'rVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 10501 9066 FTI 10464 9069 FTI I~1 Yes [] NoI (Nipple) 2205 MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, ReP, Memory CNL, GR, CCL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 117' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# NT80 35' 3627 13-1/2" 1175 sx CS I1.1~ 375 sx Class ,G, . 7-5/8" 29.7# L-80 33' 9123' 9-7/8" 485 sx Class 'G' 4-1/2" '12.6# L-80 8862' 9123' 6-3/4" Uncemented Slotted Liner ........... 3'3/16"x 2'7/8" 6.2# / 6.'1'6#' "L.80 .... 8684,' 'i0501', '3'.'3/4. 118'CU ft 'G'/Uncemen'ied 'Slotied Liner .............. 24. Perfo~ati'0ns'open i~ Production' iMD+TvD 0f'T0p'and ...... 25. ' ........ 'I:uE, NG R'EcoRD ............. Bottom and interval, size and number) .................... sizE' DEPTH SET, (MD)' ' PA~KE~R'SE~'I:'(MD)' 2" Gun Diameter, 4 SPF ' 4-1/2'I','12.6#, L:80 8750' "8684" &'8703' ' MD TVD MD TVD ....... 10200' -10440' 9070' - 9070' 26. AC~D, FRACTURE, CEMENT SQUEEZ~=, 'ETC. ' , DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 26 bbls of MECH. ,,,, ,, , , 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 9, 2001 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 8/12/2001 4 TEST PERIOD 1440 15396 63 95.59I 10690 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 25.9 , 28. CORE DATA Brief ciescHPti0n ofiith'o'iogY, po~0sity, fractures', a'Ppa~ent dips and presence o, oi,,'gas orwat~r. Submit Core CCEiVED AUG g 2 ?_001 Alaska Oil & Gas Cons. Commission Anchorage __ Form 10-407 Rev. 07-01-80 Submit In Duplicate i 29. Geologic Markers 30. Formation Tests , Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Shublik 9390' 8837' TSAD 9494' 8908' Zn3 (TCGL) 9606' 8993' 27P 9774' 9067' '31"i' L. ist of Attac'hmentsl .... summary"of Daily"'Drilii'ng RePorts', ~rveys ........................................................... 32. I hereby certify that the foregoing is true and correct to the best Of my knowledge Signed Terrie Hubble ,,~.~~ ~ Title Technical,Assistant Date 09'A~,' OI E-35A 201-119 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No./Approval No. , INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM '~ 6 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation' (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL BP EXPLORATION Page I of 5 Operations Summary Report Legal Well Name: E-35 Common Well Name: E-35A Spud Date: 6/27/2001 Event Name: REENTER+COMPLETE Start: 6/27/2001 End: 7/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/28/2001 00:00 - 06:00 6.00 MOB P PRE Move rig from B-30A to E-35A. (derrick down) 06:00 - 11:30 5.50 MOB P PRE RU Nordic 1. Raise mast & windwalls. Spot over well. 11:30 - 14:30 3.00 BOPSUF P DECOMP ACCEPT RIG ON E-35A AT 11:30 HRS, 06-28-01. NU BOPs. Spot & RU cuttings and flow back tanks. Load pits with KCL water. 14:30 - 00:00 9.50 BOPSUF P DECOMP Test BOPE. L. Grimaldi with AOGCC witness. Slow test due to leaking valves in choke manifold and leaking 2" drain valves on stack, which were replaced. NOTE: Well is twinned, Press tested wing valve OK, closed lateral valve and bled flowline to zero, lateral valve holding OK. Double block and bleed OK for isolation from twinned well. 6/29/2001 00:00 - 05:30 5.50 BOPSUR P DECOMP Continue initial BOPE pressure / function test. Witnessed by L. Grimaldi. Replaced 2 leaking 2" valves. Fill coil with KCL water and press test inner reel valve. Initial BOPE pressure test complete. 05:30 - 06:45 1.25 STWHIP P WEXIT M/U Starter mill BHA with 3.80" Baker starter mill and 2 7/8" straight motor. 06:45 - 09:00 2.25 STWHIP P WEXIT RIH with milling BHA #1. 36k# up, 24k# dn wt. 09:00 - 10:15 1.25 STWHIP P WEXIT Tag WS at 9126'. (e-line TOW was 9124'.) Mill to 9127'. Flag pipe at 9012' EOP. Hole taking 5 bph kcl water. 10:15 - 11:30 1.25 STWHIP P WEXIT POOH for window mill assembly. 11:30 - 12:00 0.50 S'I'WHIP P WEXIT LD starter mill. MU reamer "long" string reamer and HTC 3.8" DSM mill. Starter mill showed good wear pattern. 12:00 - 14:00 2.00 S'I'WHIP; P WEXIT RIH. Tag XN nipple at 8738'. Mill through same. RIH. 14:00 - 16:00 2.00 STVVHIPI P WEXIT Tag whipstock at 9123'. 1500 psi@ 2.7 bpm. 200-400 dpsi motor work. A few stalls, milled very easily, overall. Drill formation to 9140'. 16:00 - 18:00 2.00 STWHIP P WEXIT Ream and back ream window. TOW uncorrected at 9123', btm at 9128'. 18:00 - 18:30 0.50 STWHIP P WEXIT Begin displacing well to flopro. Dry drift window. Very smooth. 18:30 - 20:00 1.50 STWHIP P WEXlT POOH while circ FIoPro. Dispose of KCL water. 20:00 - 21:00 1.00 DRILL P PROD1 L/O milling BHA. Mill and reamer at 3.80" gauge. M/U drilling BHA with 1.7 deg motor and HC 3.75" x 4.13" bi-center bit. 21:00 - 22:45 1.75 DRILL P PROD1 RIH with BHA #3. Shallow test tools. RIH. 22:45 - 23:50 1.08 DRILL P PROD1 Log tie-in with GR. logged across Sag River, Added 2 ft to CTD. 23:50 - 00:00 0.17 DRILL P PROD1 Orient TF to 50R. 6/30/2001 00:00 - 03:00 3.00 DRILL N RREP PROD1 Rig down time, Power Pack hydraulic pumped failed. Park Bit at 8990 ft. Replaced hydraulic pump. 03:00 - 04:45 1.75 DRILL P PROD1 Drilling, Start at 9140 ft. Tied-in depth. TF - 51R-160R, 2.5 bpm, 3100 psi, ROP = 60 FPH. Full returns, drilled to 9200 ft. ! RA tag at 9,133 ft BKB. 04:45 - 05:30 0.75 DRILL P PROD1 Drilling, TF - 163R, 2.6 bpm, 3100 psi, ROP = 80 - 10 fph. Drilled to 9246'. 05:30 - 06:45 1.25 DRILL P PROD1 Orient around. 06:45 - 08:00 1.25 DRILL P PROD1 Drilling, TF = 165R. Drill to 9346'. 2950psi @ 2.5 bpm. 15k# up, 39k# dn wt. 200-400 dpsi. 08:00 - 08:30 0.50 DRILL P PROD1 Short trip to window. 08:30 - 14:30 6.00 DRILL P PROD1 Drilling, TF:169L. Drill to 9500'. Very hard drilling in Shublik Printed: 7/9/2001 3:51:04 PM BP EXPLORATION Page 2 of 5 Operations Summa Report Legal Well Name: E-35 Common Well Name: E-35A Spud Date: 6/27/2001 Event Name: REENTER+COMPLETE Start: 6/27/2001 End: 7/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/30/2001 08:30 - 14:30 6.00 DRILL P PROD1 from 9346' to 9474'. 14:30 - 15:00 0.50 DRILL P 'PROD1 Short trip to window. Hole smooth. 15:00 - 17:15 2.25 DRILL P PROD1 Drilling. TF: 45R. Start build in Zone 4. 3200 psi@ 2.7 bpm. Drill to 9656'. 17:15 - 17:45 0.50 DRILL P PROD1 Short trip to window. 17:45 - 19:40 1.92 DRILL P PROD1 Drilling build / turn section in zone 3. TF:25R. 2.5 bpm, 3300 psi, 30-40 fph. ,Ip Drilled to 9712 ft. 19:40 - 21:20 1.67 DRILL PROD1 Drilling, 2.7 bpm, 3350 psi. TF = 40R, 25 fph, drilled to 9742 ft. 21:20 - 23:00 1.67 DRILL P PROD1 Drilling at base of Zone 3. 2.7 bpm, 3350 psi, TF=40R, 20 FPH. Drill to 9770' 23:00 - 23:45 0.75 DRILL P PROD1 Drilling, 2.7 bpm, 3350 psi, TF = 45R, 60-80 fph. drilled to 9800 ft. 23:45 - 00:00 0.25 DRILL P PROD1 Wiper trip to window, hole in good condtion. 71112001 00:00 - 00:15 0.25 DRILL P PROD1 Wiper trip to window. 00:15 - 01:00 0.75 DRILL P PROD1 Log tie-in with RA tag, Added 12 ft to CTD. 01:00 - 01:30 0.50 DRILL P PROD1 RIH to 'I'D. 01:30 - 03:00 1.50 DRILL P PROD1 Drilling, 2.6 bpm, 3200 psi, TF = 30R, 80-120 fph, Drilled to 9878 ft. 03:00 - 03:30 0.50 DRILL P PROD1 Drilling, 2.6 bpm, 3200 psi, TF = 30R, 120 fph, Drilled to 9920 ft. Landed well at 9021 ft TVDSS at 9890 ft md. Saw tar in samples at 9018 ft tvdss. Drill at 95 deg incl to get above HOT. 03:30 - 03:45 0.25 DRILL P PROD1 Orient TF to 90R. 03:45 - 04:10 0.42 DRILL P PROD1 Drilling, 2.5 bpm, 3050 psi, TF = 85R, Drilled to 9960 ft. 04:10 - 05:00 .0.83 DRILL P PROD1 Wiper trip to window. RIH. Hole in good condition. 05:00 - 05:45 0.75 DRILL P PROD1 Drilling, 2.7 BPM, 95R. Drilled to 10,006 ft. Need to drill at 80R. 05:45 - 06:10 0.42 DRILL P PROD1 Orient around. 06:10 - 08:15 2.08 DRILL P PROD1 Drilling, 2.6 bpm, 3450 psi, TF = 84R, Drill to 10150'. 08:15 - 09:15 1.00 DRILL P PROD1 Short trip to window. Hole smooth. 09:15 - 11:45 2.50 DRILL P PROD1 Drilling, 2.4 bpm@ 3200 psi. TF: 124R. Displace to new mud. ROP died. Bit appears to be shot. Drilled to 10209'. 11:45 - 13:30 1.75 DRILL P PROD1 POOH for motor & bit. 13:30 - 14:30 1.00 DRILL P PROD1 At surface. LD bit & motor. Bit worn on gauge, lots of missing pilot cutters, but looks to be in or very near gauge. Change reel swivel. 14:30 - 16:30 2.00 DRILL P PROD1 RIH. 16:30 - 16:45 0.25 DRILL P PROD1 Log GR tie in, up, from 9180'. Add 1' correction. 16:45 - 17:15 0.50 DRILL N RREP PROD1 Replace level wind chain. 17:15-18:15 1.00 DRILL P PROD1 Orient to get thru window. Thru window at 65R. (nopump) 18:15 - 19:00 0.75 DRILL P PROD1 Continue to RIH. RIH to TD with no motor work. 19:00 - 21:00 2.00 DRILL P PROD1 Drilling, TF = 160R, 2.6 bpm, 3400 psi, 60 fph. Drilled to 10,270 ft. Clean Zone 2 sand, 25 APl GR sand. 21:00 - 21:30 0.50 DRILL P PROD1 Orient around. 21:30 - 00:00 2.50 DRILL P PROD1 Drilling, TF = 110R, 2.6 bpm, 3400 psi, 60 fph. Full returns, Drilled to 10350'. 7/2/2001 00:00 - 01:30 1.50 DRILL P PROD1 Wiper trip to window. RIH to TD. Hole was clean. 01:30 - 02:00 0.50 DRILL P PROD1 Orient around. 02:00 - 04:15 2.25 DRILL P PROD1 Drilling, 2.7 bpm, 3300 psi, TF = 90R. Slow ROP. 40-60 fph. Printed: 7/9/2001 3:51:0,4 PM BP EXPLORATION Page 3 of 5 Operations Summa Report Legal Well Name: E-35 Common Well Name: E-35A Spud Date: 6/27/2001 Event Name: REENTER+COMPLETE Start: 6/27/2001 End: 7/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/2/2001 02:00 - 04:15 2.25 DRILL P PROD1 Drilled to 10,400' 04:15 - 06:00 1.75 DRILL P PROD1 Drilling, 2.7 bpm, 3300 psi, TF = 90R. Slow ROP. 30-60 fph. Drilled to 10,458' 06:00 - 08:00 2.00 DRILL P PROD1 Drilling, 2.7 bpm, 3300 psi, TF - 90R, Slow ROP. 30-60 fph. Drilled to 10,497'. Bit worn out, unable to drill or stall. Call TD. 08:00 - 09:00 1.00 DRILL P PROD1 Wiper trip to window to prep for liner. 09:00 - 09:30 0.50 DRILL P PROD1 Log gr tie in at RA tag, starting at 9180'. Add 12' correction. Final, corrected TD at 10501'. 09:30 - 11:45 2.25 DRILL P PROD1 Condition hole from window to TD. Lay in new FIoPro mud in OOH. 11:45 - 13:30 1.75 DRILL P PROD1 Circulate OOH. 13:30 - 14:20 0.83 DRILL P PROD1 LD directional BHA. Bit in good shape. 14:20 - 14:30 0.17 CASE COMP PJSM / tool box for testing VB rams. Notified AOGCC of test. Witness waived by J. Crisp. 14:30 - 16:30 2.00 CASE P COMP Install and test 2-3/8" x 3-1/2" TOT VB rams, in upper cavity of lower TOTs. Held 250 & 3500 psi on 2-3~8" test joint with 1500 accumulator pressure. 16:30 - 16:45 0.25 CASE P COMP Hold pre job for running liner. 16:45 - 17:15 0.50 CASE P COMP RU floor to run liner. MU 3-3/16"x 2-7~8" liner assembly (41 jts TClI, 15 jts STL) 17:15 - 17:30 0.25 CASE P COMP SAFETY MEETING. Review procedure / hazards for running liner. 17:30 - 20:00 2.50 CASE P COMP Run 15 jts 2 7~8", STL liner with float equip, turbos, pup jt and XO. Run 41 jts 3 3/16", TCll liner. Total length of Liner = 1809.4 ft. 20:00 - 20:15 0.25 CASE P COMP SAFETY MEETING. Review make up procedure for Baker CTLRT. 20:15 - 22:00 1.75 CASE P COMP M/U Baker CTLRT to liner and pull test. Install new Baker CTC and pull / press test. 22:00 - 00:00 2.00 CASE P COMP RIH with Liner on CT. Circ. at 0.4 bpm at 1500 psi. RIH to 9000 ft. 71312001 00:00 - 00:30 0.50 CASE P COMP Up wt at 9000 ft = 35K. RIH with Liner. Ran thru window with no wt loss. RIH to TD of 10,506 ft CTD. Corrected TD was 10,501 ft. Up wt with no pump = 42K. 00:30 - 01:00 0.50 CASE P COMP Insert 5/8" ball and displace with FIoPro. Liner sat down at TD with 1 OK. Pump 30 bbls at 2.5 bpm, slow to 0.5 bpm. Ball on seat at 36 bbls. Sheared at4000 psi. Pick up. Liner was free. Stack 10K. 01:00 - 02:30 1.50 CASE P COMP Circ. well to 2% KCL water. 2.9 bpm, 3100 psi, Full returns. Dispose of used FIoPro. 02:30 - 03:30 1.00 CASE P COMP R/U DS cement equip. Batch mix cement. Cement at wt at 03:15 hrs. 03:30 - 03:45 0.25 CASE P COMP SAFETY MEETING. Review cementing procedure and hazards with all personnel. 03:45 - 04:20 0.58 CASE P COMP Press test cement line. Stage 21.0 bbls, 15.8 ppg, G cement with latex. Purge cement line. Insert dart, Pump 2 bbls displacement. Check dart, gone. 04:20 - 04:50 0.50 CASE P COMP Displace cement at 3.0 bpm, 1800 psi, 2.9 bpm returns. Slow pump at 43 bbls displ. Dart on seat at 46.5 bbls, sheared at 2900 psi, Displace cmt around at 3.1 bpm, 2.8 bpm returns. 3100 psi, LWP bumped at 58.9 bbls [0.2 bbls early]. Hold Printed: 7/9/2001 3:51:0,4 PM BP EXPLORATION Page 4 of 5 Operations Summa Report Legal Well Name: E-35 Common Well Name: E-35A Spud Date: 6/27/2001 Event Name: REENTER+COMPLETE Start: 6/27/2001 End: 7/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2001 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/3/2001 04:20 - 04:50 0.50; CASE ,P COMP 2000 psi. Steady. Lost 1.3 bbls cement to formation. [19.7 bbls CMT returned past shoe]. 04:50 - 05:00 0.17 CASE P COMP Bleed off CT press. Check floats. OK. Press up to 1000 psi and sting out. Circ. at top of liner at 3.0 bpm, full returns, 1750 psi. Chase any cement to surface. 05:00 - 05:30 0.50 CASE P COMP Circulate at liner top. 3.0 / 3.0 bpm, 1750 psi. Full returns. Good Cement Job, no problems. 05:30 - 07:00 1.50 CASE P COMP POOH with CT. Dump CMT contaminated KCL water. Pump 3.0 bpm, 1600 psi. 07:00 - 07:30 0.50 CASE P COMP LD liner running tool. 07:30 - 07:45 0.25 PERF P COMP Pre job mtg regarding MU CNL & jointed pipe. 07:45 - 10:30 2.75 PERF P COMP MU CSH work string with MHA (60 its CSH) 1900.86': OAL 10:30 - 12:00 1.50 PERF P COMP Run in hole with CNL memory log. 12:00 - 13:00 1.00 PERF P COMP Log CNL down pass. Start FIoPro high vis pill down coil. Tag PBTD at 10457'. 13:00 - 13:45 0.75 PERF P COMP Log up pass. Lay in hi vis pill. 13:45 - 15:30 1.75 PERF P COMP POOH with logging tools. Some cement in rtns (pH up to 14). 15:30 - 17:30 2.00 PERF P COMP At surface. Stand back CSH. LD logging tools. 17:30 - 18:30 1.00 PERF P COMP Press test liner lap with 2200 psi. Slow leak. Bleed off press. Discontinue press test. 18:30 - 18:45 0.25 PERF P COMP SAFETY MEETING. Review procedures / hazards for running perf guns. 18:45 - 20:00 1.25 PERF P COMP Prep safety joint. RIH with 12 SWS, 2" Power Jet perf guns at 4 spf. Total Loaded Perf interval = 240.0 ft. 20:00 - 23:00 3.00 PERF P COMP RIH with perf guns on CT. Tag PBTD of 10,464 ft at 10,454 ft CTD. Correct depth to 10,464 ft. Position bottom perf charge at 10,440 ft. 23:00 - 23:50 0.83 PERF P COMP Press test liner lap with 2200 psi, lost 1100 psi in 15 min. Re-test to 2200 psi, lost 1500 psi in 15 min. Liner lap is leaking. Valves on rig double blocked and flowline still at 0 psi. Order liner top packer from Baker. 23:50 - 00:00 0.17 PERF P COMP Pump 4 bbls high vis FIoPro into CT. Insert 5/8" steel ball for perforating. 7/4/2001 00:00 - 00:30 0.50 PERF P COMP Displace 5/8" steel ball with KCL water at 2.0 bpm at 2500 psi. Bottom perforating charge located at 10,440 ft. Firing head sheared at 3900 psi. 00:30 - 01:50 1.33 PERF P COMP POOH with perf guns. 01:50 - 03:00 1.17 PERF P COMP Lay out CSH workstring in singles for rig maintenance. 52 its. 03:00 - 03:15 0.25 PERF P COMP SAFETY MEETING; Review procedure and hazards for laying out perf guns 03:15 - 03:45 0.50 PERF P COMP Lay out SWS 2" Power Jet perf guns. All shots fired. PERFORATED INTERVAL: 10,200 - 10,440 FT BKB. 03:45 - 04:15 0.50 RUNCOr~ COMP M/U Baker KB 4 1/2" Liner top packer with 3" seal assembly on 1 jt 2 3/8" PH6 and DS BHA. BHA = 51 ft. 04:15 - 06:15 2.00 RUNCOI~ COMP RIH with 4 1/2" Liner top Packer on CT. 75 fpm, 0.2 bpm, 50 psi. ~06:15 - 07:10 0.92 RUNCOr~ COMP Up Wt at 8600 ft = 33K. RIH. Seals entered at 8694 ft, stacked wt at 8699 ft. Stacked 10K at 8700.7 ft. Pull out and pump 5/8" AL ball. On seat at 36.4 bbls. 07:10 - 07:30 0.33 RUNCOI~' COMP RIH with packer / seal assy. Stack wt. Pick up 1.7 ft off Iocator. Printed: 7/9/2001 3:51:04 PM BP EXPLORATION Page 5 of 5 Operations Summa Report Legal Well Name: E-35 Common Well Name: E-35A Spud Date: 6/27/2001 Event Name: REENTER+COMPLETE Start: 6/27/2001 End: 7/4/2001 Contractor Name: NORDIC CALISTA Rig Release: 7/4/2001 ~Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/4/2001 07:10 - 07:30 0.33 RUNCOI~ COMP Set packer. Top of KPB Packer set at 8,681.4 ft BKB, ref. Memory CNI_JGR of 7-3-01. Minimum ID of Packer / Seal Assy = 2.39". 07:30 - 08:00 0.50 RUNCO~ COMP Pressure test liner Top Packer / seal assy to 2200 psi. for 30 Min. Chart press test. Good Test. Lost 20 psi in 30 min. 08:00 - 09:15 1.25 RUNCO~ COMP Pressure up CT to 3500 psi and shear release from packer. Sting running tool out of packer and POOH. 09:15 - 09:40 0.42 RUNCO~ COMP Freeze protect 4 1/2" tubing from 2000 ft to surface with MEOH. Lay in total of 26 bbls. 09:40 - 10:00 0.33 RUNCO~ COMP Lay out Baker running tool. 10:00 - 12:00 2.00 RUNCO~ F~ COMP Displace CT with N2 and bleed down press in coil. 12:00 - 14:00 2.00 RUNCO~ F) COMP Cut off CTC and secure CT stub at reel. 14:00 - 15:00 1.00 RUNCO~ F~ COMP Nipple down BOPE. Clean rig pits. RELEASED RIG AT 15:00 HRS, 07-04-01. TOTAL TIME ON WELL WAS 6 DAYS, 3 1/2 HOURS. 15:00 - 0.00 RUNCO~ I:) COMP Remove goose neck from injector head. Prep to remove Tioga heater, injector head, and reel with Peak crane. Printed: 7/9/2001 3:51:04 PM 27-Jul-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well E-35A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk 2o/-//? Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,111.69' MD 9,123.00' MD 10,501.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 0 2 2001 Alaska 0il & Gas Cons, Commission An~orage DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA E Pad, Slot E-35 E-35A Job No. AKMWfI114, Surveyed: 2 July, 2001 SURVEY REPORT August, 200f Your Reft AP1.$0029225570t Surface Coordinates: 5975877.2t N, 664470.46 E (70° 20' 25.4301" N, Kelly Bushing: 65.29ft above Mean Sea Level 148°39'54.9239"W) A HiIIlburt~n Survey Ref: svy10891 Sperry-Sun Drilling Services Survey Report for E-35A Your Ref: APt.50029225570t Job No. AKMWfff14, Surveyed: 2 July, 2001 DEFiNiTiV North Slope Alaska Mealured Depth Incl. Azim. Sub-Sea Depth (ft) 9111.69 87.200 215.615 8734.37 9123.00 88.000 214.100 9154.68 92.720 217.100 9193.88 96.500 221.400 9220.08 91.600 224.300 8734.84 8734.64 8731.49 8729.64 9252.28 85.430 227.900 8730.48 9286.68 79.280 231.800 8735.05 9314.88 73.480 234.930 8741.69 9349,08 66.800 235.510 8753.30 9380.48 61.260 239.550 8767.05 9409.28 55.110 239.200 9442.88 45.000 236.920 9474.88 37.790 245.180 9515.48 34.540 252.380 9551.28 40.520 261.700 8782.23 8803.77 8827.78 8860.57 8888.97 Vertical Depth (ft) 8799.66 8800.13 8799.93 8796.78 8794.93 8795.77 8800.34 8806.98 8818.59 8832.34 8847.52 8869.06 8893.07 8925.86 8954.26 9584.08 46.050 264.340 8912.84 8978.13 9665.48 61.520 281.560 8961.02 9026.31 9691.68 64.510 287.010 8972.92 9038.21 9747.08 70.880 297.470 8993.98 9059.27 9769.68 74.090 300.550 9000.78 9066.07 9800.88 76.820 304.420 9008.62 9856.48 83.230 313.560 9018.27 9888.28 88.240 317.770 9020.63 9923.68 95.540 325.330 9019.46 9952.48 95.710 332.540 9016.64 9073.91 9083.56 9085.92 9084.75 9081.93 Local Coordlnatem Global Coordinates Northings Ea~tlngs Northing$ Eastings (ft) (ft) (ft) (ft) 433.82 S 540.73 W 5975431.63 N 663939.37 E 443.09 S 547.19 W 5975422.22 N 663933.12 E 468.84 $ 565.63 W 5975396.08 N 663915.25 E 499.09 S 590.33 W 5975365.29 N 663891.22 E 518.24 S 608.10 W 5975345.76 N 663873.87 E 540.54 S 631.28 W 5975322.95 N 663851.19 E 562.52 S 657.32 W 5975300.41 N 663825.64 E 578.87 S 679.29 W 5975283.58 N 663804.03 E 597.21 S 705.69 W 5975264,66 N 663778.04 E 612.38 S 729.48 W 5975248.98 N 663754.59 E 624.84 S 750.53 W 5975236.06 N 663733.81 E 638.41 S 772.38 W 5975222.01 N 663712.27 E 648.72 S 790.80 W 5975211.29 N 663694.08 E 657.44 S 813.07 W 5975202.10 N 663672.00 E 662.20 $ 834.29 W 5975196.87 N 663650.89 E 664.90 S 856.60 W 5975163.68 N 683628.65 E 660.57 S 921.52 W 5975196.58 N 663563.65 E 654.80 S 944.13 W 5975201.85 N 663540.92 E 635.35 S 991.42 W 5975220.27 N 663493.22 E 624.90 S 1010.26 W 5975230.30 N 663474.15 E 608.68 S 1035.72 W 5975245.96 N 663448.34 E 574.24 S 1078.19 W 5975279.45 N 663405.13 E 551.57 S 1100.34 W 5975301.63 N 663382.49 E 523.91 $ 1122.31 W 5975328.81 N 663359.91 E 499.37 S 1137.09 W 5975353.02 N 663344.60 E Alaska Drilling & Wells PBU_WOA E Pad Dogleg Vertical Rate Section Comment (°/100ft) 75.60 15.140 73.61 17.652 68.44 14.577 64.52 21.716 63.54 22.180 64.16 21.113 67.03 23.222 71.01 19.597 76.71 21.093 82.81 21.379 88.88 30.532 94.73 28.228 100.46 13.165 110.05 22.995 121.69 17.737 135.56 25.438 184.52 21.764 204.58 20.899 251.78 19.251 272.49 14.855 301.97 '19.868 356.34 20.552 388.03 29.668 423.14 24.921 450.93 Tie On Point MWD Magnetic Window Point 1 August, 2001 - 14:51 Page 2 of 4 13HIIQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for E-35A Your Reft API.500292255701 Job No. AKMW11114, Surveyed: 2 July, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl, Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~t) (ft) (ft) (~t) 9999.68 93.430 336.760 9012.87 9078.16 456.86 S 1157.23 W 5975395.07 N 663323.53 E 10039.68 93.160 341.860 9010,57 9075.86 419.52 S 1171.33 W 5975432.10 N 663308.61 E 10095.48 92.110 353.810 9008.00 9073.29 365.13 S 1183.05 W 5975486.22 N 663295.70 E 10141.68 90.120 4.620 9007.10 9072.39 319.01 S 1183.68W 5975532.31 N 663294.06 E 10171.28 93.230 11.500 9006.23 9071.52 289.74 S 1179.54 W 5975561.67 N 663297.56 E 10198.64 94.600 14.340 9004.36 9069.65 263.14 S 1173.44 W 5975588.40 N 663303.08 E 10234.64 91.490 18.240 9002.45 9067.74 228.64 $ 1163.35 W 5975623.10 N 663312.40 E 10268.24 87.430 20.620 900277 9068.06 196.96 S 1152.18 W 5975655.02 N 663322.88 E 10306.04 89.380 24.040 9003,82 9069.11 162.02 S 1137.83 W 5975690.27 N 663336.46 E 10359.64 86.820 28,310 9005.60 9070.89 113.96 S 1114,21 W 5975738.84 N 663359.02 E 10404.64 91.180 34.250 9006.38 9071.67 75.53 S 1090.86 W 5975777.77 N 663381.52 E 10462.04 94.190 38.410 9003.69 9068.98 29.35 S t056.90 W 5975824.68 N 663414.45 E 10501.00 94.190 38.410 9000.85 9068.14 1.09 N 1032.76 W 5975855.65 N 663437.92 E 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. Magnetic Declination at Surface is 26.669° (28-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 315.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10501.00ff,, The Bottom Hole Displacement is 1032.76ft., in the Direction of 270,061 ° (True), Dogleg Rate (°/100ft) 10.137 12.747 21.475 23.786 25.496 11.503 13.843 14.006 10.412 9.284 16.370 8.938 0.O00 Alaska Drilling & Wells PBU_WOA E Pad Vertical Section Comment 495.23 531.61 578.36 611.41 629.18 643.68 660.94 675.44 690.00 707.28 717.94 726.59 731.05 Projected Survey 1 August, 2001 - 14:51 Page 3 of 4 DrtllOuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for E-35A Your Ref: AP1.50029225570f Job No. AKMW11114, Surveyed: 2 July, 2001 North Slope Alaska Alaska Drilling & Wells PBU_WOA E Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9111.69 8799.66 433.82 S 540.73 W 9123.00 8800.13 443.09 S 547.19 W 10501.00 9066.14 1.09 N 1032.76 W Comment Tie On Point Window Point Projected Survey Survey tool program for E-35A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 9111.69 8799.66 9111.69 8799.66 10501.00 9066.14 Survey Tool Description AK-3 BP_HM - BP High Accuracy Magnetic (E-35) MWD Magnetic (E-35A) 1 August, 2001. 14:51 Page4 of 4 DrfllOuest 2.00.08_005 08/01/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57tl ATTN: Sherrie NO. 1345 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 18-28 i c,/c~ - o 7/-V' PSP-LDL 07/22/01 t 1 B-30A 2.O1-i0S 21329 MCNL 06/25101 1 I '1 'E-35A ~Ot-Tl'~ 21333 MCNL 07103/01 1 1 1 K-10A ~2.~i'" O~ 21331 MCNL 06127/01 1 1 1 D.S. t8-32A ~_cq-IO7 21328 MCNL 06121/01 1 1 1 Y-15A ?-OI '-0~'¢/ 21334 MCNL 07105101 1 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A-I-rN: Sherrie RECEIVED AUG 0,3 2001 Received by: Ala~a Oil & Gas Cons, Commission Anchorage E-35a (PN 201-119)approval of changes to approv~!i,, ' ~ 1 Subject: E-35a (PN 201-119)approval of changes to approved 401 Date: Tue, 26 Jun 2001 12:41:21 -0800 From: Jane Williamson <Jane_Williamson@admin.state.ak.us> Organization: Alaska Oil & Gas Conservation Commission To: "Endacott, Mary S" <EndacoMS@BP.com> CC: "Hubble, Terrie L" <HubbleTL~BP.com>, "Kara, Danny T" <KaraDT~BP.com>, "NSU, ADW Drlg Nordic 1 Supervisor" <NSUADWDrlgNordic 1Supervisor@BP.com> "Stanley, Mark J (ANC)" <StanleMJ@BP.com>, "Cubbon, John R" <CubbonJR@BP.com>, Julie M Heusser <julie_heusser~admin.state.ak.us>, "AOGCC Prudhoe Bay (E-mail)" <aogcc_prudhoe_bay@admin.state.ak.us> Mary, We have reviewed the requested changes to the rig, BOP stack and liner configuration for coiled tubing sidetrack Well E-35a. The 401 permit (201-119) was approved by the Commission on June 20, 2001. Your proposed changes (attached) are acceptable and this is sufficient documentation for update of our records. You have approval to proceed. Per 20 AAC25.015 (a) (2), this change can be approved administratively without the submittal of additional forms as there is not a change in location, and you have not yet spudded the well. Please note that Blowout prevention equipment must be tested in accordance with 20 AAC25.035. Sufficient notice (24 hrs) must be given to allow a represntative of the Commission to witness a test of BOPE installed prior to drilling new hole. Please contact the Commissions petroleum field inspector on the North Slope (pager 659-3607 or phone 659-2714) Jane Williamson AOGCC Petroleum Engineer "Endacott, Mary S" wrote: Jane Attached please find updated sketch of BOP and proposed wellbore completion for E-35a. Two changes have occurred since this well was permitted (drilling permit no. 201-119). First, Nordic 1 will be the rig in place of Nabors 3S and Second, the proposed liner will be 3 3/16" x 2 7/8" in place of 3 1/2" x 2 7/8" The two sketches in the enclosure reflect the use of variable bore rams in the BOP and the new liner ODs. Bottom hole location has not changed. Planned spud date is this Wednesday 6/2 7/01. <<update. ZIP>> Mary S. Endacott BP Coil Tubing Drlg Engr 907-564-4388 endacoms~bp, corn Name: update. ZIP update. ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 I of 2 6/26/01 12:46 PM ~KA OIL AND GAS CONSERYA~EION COPl)I~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Cubbon Coil Tubing Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit E-35A BP Exploration (Alaska) Inc. Permit No: 201-119 Sur Loc: 1187' FNL, 501' FEL, SEC. 6, TllN, R14E, UM Btmhole Loc. 1014' FNL, 1476' FEL, SEC. 6, T1 IN, R14E, UM Dear Mr. Cubbon: Enclosed is the approved application for permit to redrill the above referenced well. The permit to .redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular.disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit E-35A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~,Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this 20 ~4 day of June, 2001. jjc/Enclosures CCi Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. t"' STATE OF ALASKA i" ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work: Drill E~ Redrill [] lb. Type of well. Exploratory [--] Stratigraphic Test r-'] Development Oil r~ Re-entry D Deepen D Service D Development Gas D Single Zone r'~ Multiple Zone D 2. Name o! Operator 5. Datum elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska), Inc. RKB 65.29 feet 3. Address 6. Property Designation Prudhoe Bay Field P. O. Box 196612 Anchorage, AK 99519-6612 ADL 28304 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1187' FNL, 501' FEL, Sec. 6, T11 N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1522' FNL, 952' FEL, Sec. 6, T11 N, R14E, UM ~" :3;~'~ #2S100302630-277 At total depth 9. Approximate spud date Amount 1014' FNL, 1476' FEL, Sec 6, T11 N, R14E, UM June 28, 2001 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 28299, 1014' @ TD feetI No Close Approach feet 2469 10976 MD / 9076 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) i Kicko~l depth: 9190' MD Maximum hole angle 97° Maximum surface 2236 pslg At total depth (TVD) 3300 psig @ 8800' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Weight Grade couplin~l Length MD TVD MD TVD (include sta~le data) 3-3/4" 3-1/2'x2-7/8' 9.3#/6.2# L-80 ST-L 2261' 8715' 8658' 10976' 9076' 19 bbls LARC 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 9600 feet Plugs (measured) tree vertical 8825 feet Effective Depth: measured 9600 feet Junk (measured) tree vertical 8825 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 117' 20" 260 Sx AS 110' 110' Surface 3592' 10-3/4" 1175 Sx CS III & 375 Sx Class G 3627' 3622' Production 9270' 7-5/8" 485 Sx Class G 9303' 8800' Liner 738' 4-1/2" Uncemented 9600' 8825' Perforation depth: measured 8991' - 9032'; 9077' - 9159'; 9203' - 9244'; 9245' - 9573'. .' ,, ,~ .--~ ,,, tmevertlcal 8779' - 8789'; 8797' - 8801'; 8801'- 8801'; 8801'- 8822'. 20. Attachments Filing fee ~ Property Plat I~l BOP Sketch ~1 Diverter Sketch I~l Drilling program ~ !i: i": i::'~ ¥:.~'i'-'~ Drilling fluid program lime vs depth plot I~l Refraction analysis I--I Seabed report I~ 20 AA¢ 25.050 requirements I'--I 21. I hereby certify that the foregoing is true and correct to tho best of my knowledge Ouestion$? Gall dohn Gubbon @ $64-415B. Signed Title: Coil Tubing Drilling Engineer Date June 15, 2001 Pro?arod b~/ Paul Ftat~f ..~4o$799 Commission Use Only Approval date~ ~._.. ~ '1 I See cover letter ~ <C~/-- y/,~ 50-029-22557-0t ~ Iforotherrequirements Conditions of approval Samples required ~1 Yes .~ No Mud log q' I--I Yes [~] No Hydrogen sulfidemeasures ~ Yes I~ No Directional survey required ~] Yes I--'l No Required working pressure for BOPE I-'12M; r-I aM; I'-I SM; ~ 10M;[~ [~aS00psiforCTU Other: ... Approved by ' ~k:;l~&£ ~l~i~ll:::ih r~ Commissioner the commission Dale Form 10-401 Rev. 12/1/85 · : :~vlor Seamount Submit in triplicate BPX E-35A Sidetrack Summary of Operations: A CTD sidetrack of well E-35A will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. ~'"Phase 1: Isolate & integrity test inner annulus, (IA). Drift/caliper liner and set whipstock. Mill window \ if service coil is available. / Planned for June 21, 2001 // · Drift well with dummy whipstock and caliper liner near setting depth. z,~ · Integrity test IA after displacing to seawater & installing d, ummy gas lift valves. ,) · Set through tubing whipstock using coil at approx. 9,190. ,,,,, · Mill window with service coil if available. Phase 2: Drill and Complete CTD sidetrack: Planned for June 28, 2001 2-3/8" coil will be used to drill a -1700 foot, 3-3~'' open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 3 Y2" x 2-7/8" liner completion. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6- 8.7 ppg) Disposal: · No annular injection on this well. · 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: · 3 1/2" x 2-7/8", L-80, solid liner will be run from approximately 8,715'md (8,593' TVDss) to TD at approx 10,976'md (9011' ss). Liner will be cemented in place with approximately 19 bbls (annular volume plus 25% excess in OH) of 15.8ppg class G cement. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2200 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over the open hole section. · A memory CNL will be run inside the liner. Hazards H2S concentration at E-35 is less than 100 ppm. The well-path will cross 1 mapped fault. The reservoir in this area of the field is highly faulted with high dip. In addition to the mapped fault, additional small faults will likely be encountered along the well-path. Reservoir Pressure Res. pressure is estimated to be 3300 psi at 8800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2236 psi. 4-1/16" - 5M CIW WELLHEAD: 13 518" - 5M FMC ACTUATOR: BAKER E-35a Proposed Completion KB. ELEV = 65.29' BF. ELEV = 34.79' GL. ELEV = 30.50' 10-3/4", 45.5#/ft,I 3,627,! NT-80 Butt LONG STRING 7-5/8", 29.7# NT95HS L-80 NSCC KOP: 40°- @ 8,600' MAX ANGLE: 94° @ 9,200' ANGLE at TD @ 80° 4,1/2", 12.6#/ft, L-80, NSCT, TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT Top 3 1/2" liner approx. 8715' MD LONG STRING 7-5/8" , 29.7# NT95HS L-80 NSCC 4.50" SLOTTED LINER DEPTH'S 41/2" SLOTTED LINER MLAS 41/2" SLOTTED LINER MLAS 41/2" SLOTTED LINER NO-GO SUB ( 3.00" ID ) 41/2" SLOTTED LINER DRILLABLE PACK OFF 8,991' - 9,032' 9,032' - 9,076' 9,076' - 9,158' 9,158' - 9,203' 9,203'- 9,244' 9,245' 9,245'- 9,573' 9,574' 7 5/8" section milled 8998 - 9048 LANDING NIPPLE I I ( HES)( 3.813" Id) 2,205' Merla, TMPDX , GLM i zt R" w/1" RI<' i ATC, H) MI3iRKR~ 14052 6731 8125 tv r~.,:::.,:: Ang 4047 I0 6726 0 8020 0 HES X-NIPPLE (3.813"1D) J 7-5/8" x 41/2" Baker "SABL-3" I PKR. W/"K" Anchor Assey. HES X-NIPPLE (3.813"1D) I HES XN-NIPPLE (3.725"1D) I 4-1/2" WLEG J 8,691' J 8,702' 8,726' 8,737' 8,750' 3 1/2" St-L J 7-5/8" X 4-1/2" TIW "SS" HORIZONTAL Packer W/Scoop Top J 8,862' J SLOTTED LINER 4.5" , 12.6# , NSCT Top whipstock approx. 9190' --~, X-O 3 1/2" ST-L to 2 7/8" ST-L 'approx. 9240' MD 3.75" open hole PBTD ~ 4.50" 26# 1-80 NSCT ~ TD 10 976' MD r~l ~S E-'3 5 Vertical Section Path Distance (Feet) 0 500 1,000 1,500 2,000 2,500 8550 8600 4.5" WELG 8750' MD 8650 ~--Top slotted liner packer 8862' 8700 ~TSGR~ Angle ¢~ K.O,= 90 8750 \ / - case ] 08 ~ April 24, 2001 ?oo ~ ~ed ×~69~ ~8850 8900 8905_TZ3 I Zone 3: 80fttodrill 8950 I i 8970-TZ2C 9000 , 9050 Tot Drld:1786 ft 10976 TD 9100 Marker Depths @Orig Wellbore 9,020~ft TVD 8905-TZ3 ~ ft TVD 8970-TZ2C~D [KickOff ~ft [~ft TVD MD [Deprtr @KO 784 ft MD KO Pt MD New Hole Total MD 9,190] 1786] 9,011 I ~TVD TD DLS deg/lO0 Curve I Z~O6 Curve 2 Curve 3 2t~ Curve 4 20 Curve 5 20 Curve 6 ~0 Curve 7 Tool Face Length -~0 E-35a Case ] 08 April 24, 2001 Ted x4694 E-35 500 Well Name E-35 ] CLOSURE Distance 990 ft Az 279 deg NEW HOLE E/W (X) N/S (¥) Kick Off -574 -512 TD -978 153 State Plane 663,490 5,976,028 Surface Loc 664,468 5,975,875 -soo i DLS deg/1 O0 Tool Face Length Curve 1 6 45 30 Curve 2: 20 160 310 Curve 3 20 28 360 Curve 4 20 110 104 Curve 5 20 90 559 Curve 6 20 -90 224 Curve 7 20 90 199 1,786 t ~500 -2,000 -1,500 -1,000 -500 0 X distance from Sfc Loc Drawn: 6/15/2001 11:17 Plan Name: Case 122 3S CTD BOP Detail CT Injector Head g Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection ~ Otis 7" WLA Quick I' ' I Connect - I! I I I J 7-1/~a~l~ySi~0~ ~[~ing pressure Manual ov~O~y~raulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR 7-1/i~DF, y]~0~ ~[~ing pressure Manual ove~OH°y~raulic 2" ~de 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure IBlindlShear J 3 112" Combi Pipe/Sli[~ Fire resistant Kelly Ho Flange by Hammer up 1 Kill line check valve Valve on DS Hardline to ~ ~ ~.=,=,.,~~/ manifold L 718" Combi Pipe/Slip I 2 3/8" Combi Pipe/Slip XO Spool as necessary Single Manual Master Valve 2 flanged gate valves MOJ 5/16/01 7" Annulus 9 5/8" Annulus I DATE I CHECK NO. H 1911 z~ 7 Io~/o'~/o~. Iooi~ i~7 VENDOR DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 060i0i CKOSOiO1C i00. O0 100. O0 PYMT COMMENTS: PERP IT TO DRILL FiEE HANDLING INST: S/H - TERRIE HUBBLE X4&~8 rHE A'r~AOHEO OHEOK IS IN PAYMENT FOFI ITEMS DESCRIBED ABOVE. I I[e]l ~,_1 ~ ~ 100. O0 100. O0 BP EXPLORATION, (ALASKA)INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 No.H 191147 CONSOLIDATED COMMERCIAL ACCOUNT O0191147 PAY To The ORDER 0~ ONE:'.'HUNDRED & ******************************************** US/DOLLAR , , ALASKA OIL AND GAS 'CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAOE AK 99501 DATE, AFTER' DAYS ::.~ ~......~_'i~] __. · .. TR~'SMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES "CLUE" ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR D/ISPOSAL (\_/) NO ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES + SPACING EXCEPTION The permit is for a new weilbore segment of existing well , Permit No, ~ API No. __. Production should continue to be reported as a function of the original AP1 number stated above. In accordance with 20 AAC 25.005(0, all records, dataand logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please nOte that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name)will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY WELL NAME ~'-~->.~,,4 PROGRAM: exp FIELD & POOL INIT CLASS Z~ ~.,z/ .? ~-¢,'// dev ,,%~ redrll ,,~ serv wellbore seg ann. disposal para req GEOL AREA ~?c"') UNIT# //~', (¢'-) ON/OFF SHORE ¢'~,,-O N N Y Y ADMINISTRATION DATE / / 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs...' ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... GEOLOGY .~R D,~TE/ 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ........ .... ....... 26. BOPE press rating appropriate; teSt to '%~'~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable.. : .............. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; .... : . . Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; ' (C) will not impair mechanical integrity of the well'used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N 30.' Permit can be issued w/o hydrogen sulfide measures .... ' . Y N / 31. Data presented on potential overpressure zones ....... Y ~/ / j 32. Seismic analysis of shallow gas zones ..... ........ Y/'N ,/U/, ~, 33. Seabed condition survey (if off-shore) .... ......... ~ N 34. Contact name/phone for weekly progress reports [exploratory ~,r~] Y N . t Commentsllnstructions: GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: TEM~ ¢.,; {~ ~,_, JMH ~.~..A~ ~_ j c:\msoffice\wordian\diana\checklist (rev. 11/011/00) Well History File APPENDIX Information of detailed nature that is not particu[ady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this . nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Aug 19 08:35:34 2002 Reel Header Service name ............. LISTPE Date ..................... 02/08/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/08/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW-ii114 S. LATZ GOODRICH/WHI E-35A 500292255701 BP Exploration (Alaska), Inc. Sperry Sun 19-AUG-02 MWD RUN 2 AK-MW-ii114 S. LATZ GOODRICH/WHI 6 llN 14E 1187 501 65.29 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 10.750 3627.0 2ND STRING 7.625 8998.0 3RD STRING 4.500 9123.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 & 2 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC LOG OF 07/03/01 (MCNL GR) WITH A KBE OF 65.29' AMSL. THIS WELL KICKS OFF FROM E-35 AT 9123' MD, 8735' SSTVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES MWD RUNS 1 & 2 REPRESENT WELL E-35A WITH API # 50-029-22557-01. THIS WELL REACHED A TOTAL DEPTH OF 10501' MD, 9001' SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9106.5 10468.5 ROP 9140.5 10499.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9106.5 9111.5 9115.5 9117.5 9123.5 9132.5 9135.0 9142.0 9171.0 9178.0 9187.5 9190.5 9194 5 9198 5 9205 5 9210 5 9230 5 9240 5 9250 0 9298 0 9326.5 9329 5 9334 0 9342 5 9376 5 9379 5 9389 5 9394 0 9402 5 9406 0 9430 0 9433 0 9441 5 9446 5 GR 9109.5 9114.5 9117.0 9119.5 9123.5 9132.5 9135.0 9141.5 9171.5 9179.0 9187.5 9192.0 9195.5 9199.5 9205.5 9210 5 9232 0 9242 0 9250 5 9298 5 9327 5 9330 0 9337 0 9343 0 9381 5 9384 0 9394 5 9399 0 9406 0 9410 0 9434 0 9437 5 9443 0 9448 0 EQUIVALENT UNSHIFTED DEPTH 9453.0 9456.0 9461.0 9463.0 9466.5 9467.5 9470.5 9479 0 9487 5 9490 5 9496 0 9500 0 9507 0 9522 0 9528 0 9534 5 9539 5 9543 5 9548 5 9551 5 9556.0 9559.5 9567.5 9578.5 9582.0 9585.5 9594 0 9599 0 9626 0 9632 0 9634 5 9636 5 9649 0 9653 5 9655 5 9658 5 9689 5 9697.5 9702.0 9706.5 9721.0 9747.0 9749 0 9752 0 9758 5 9765 5 9773 5 9783 5 9786 0 9805 0 9811 0 9819 5 9847 0 9855 0 9856 0 9860 5 9870 0 9891 5 9896 0 9901 0 9911 5 9923 0 9933 5 9935 5 9938 5 9946.0 9948.5 9952.5 9957.5 9962.0 9975.0 9977.5 9979.5 9989.5 10011.5 10014.5 9454 0 9456 5 9461 5 9464 0 9466 5 9468 0 9470 5 9478 0 9486.5 9490.0 9495.0 9498.5 9506.0 9524 5 9527 5 9534 5 9539 0 9544 5 9550 0 9553 0 9557 0 9560 0 9567 5 9579 0 9582 5 9585 5 9594 0 9599.0 9626.5 9632.0 9633.5 9635 5 9648 0 9651 0 9655 0 9657 0 9688 5 9696 5 9701 5 9706 0 9720 5 9745 5 9749 0 9752 0 9759 0 9765 5 9775 5 9784 5 9786.0 9805.0 9811.0 9820.0 9848.5 9856.0 9857.5 9862.5 9872.5 9894.5 9899.0 9904.5 9915 0 9926 0 9936 0 9938 0 9942 0 9946 5 9948 5 9953 0 9958 0 9962 5 9976 0 9978 5 9983 0 9991 0 10013.0 10015.5 10026.5 10031.5 10036.5 10040.0 10047.0 10050.5 10068.0 10078.5 10086.0 10090.5 10094.0 10099.5 10101.5 10118.0 10119.5 10132 5 10208 0 10211 5 10222 0 10226 0 10242 5 10247 0 10252 0 10257 5 10264 5 10276 5 10284 5 10288 5 10292 0 10315.0 10319.5 10320.5 10337.5 10345.5 10350.0 10353.5 10361.0 10368.5 10373.0 10377.5 10383.0 10386.5 10394.5 10401.5 10406.0 10409.0 10414.5 10419.0 10423.5 10427.5 10442.0 10448.0 10450.0 10453.0 10499.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ 10029.0 10031.5 10037.5 10041.0 10050.0 10053.5 10071.0 10081.5 1O088.5 10095.0 10098.5 10102.0 10105.0 10118.0 10120.5 10134 5 10207 0 10213 5 10223 0 10225 0 10241 0 10246 0 10251 5 10257 5 10264 5 10276 5 10284 5 10288 0 10292 0 10315 0 10319 0 10320 5 10335 5 10342 5 10347 0 10352 5 10359 5 10366.0 10369.5 10376.5 10381.5 10384 0 10393 5 10399 0 10403 5 10407 0 10411 5 10415 5 10420 5 10425 0 10441 5 10449 5 10453 0 10455 0 10501 0 BIT RUN NO MERGE TOP MERGE BASE 1 9109.5 10218.0 2 10218.5 10501.0 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9106.5 10499 9802.75 2786 ROP MWD FT/H 1 737.76 129.283 2718 GR MWD API 15.21 897.96 49.3721 2725 First Reading For Entire File .......... 9106.5 Last Reading For Entire File ........... 10499 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 9106.5 9140.5 9106.5 Last Reading 10499 10499 10468.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9109.5 10187.0 ROP 9140.0 10218.0 $ # LOG HEADER DATA DATE LOGGED: 01-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10218.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 34.5 MAXIMUM ANGLE: 96.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ NATURAL GAMMA PROBE BOREHOLE AND CASING DATA TOOL NUMBER 002 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.61 MUD VISCOSITY (S) : 56.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 9.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 146.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9109.5 10218 9663.75 2218 ROP MWD010 FT/H 2.94 737.76 139.365 2157 GR MWD010 API 15.21 897.96 55.1769 2156 First Reading For Entire File .......... 9109.5 Last Reading For Entire File ........... 10218 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 9109.5 9140 9109.5 Last Reading 10218 10218 10187 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10187.5 10470.5 ROP 10218.5 10501.0 $ LOG HEADER DATA DATE LOGGED: 02-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10501.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 94.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 002 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.61 MUD VISCOSITY (S): 58.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 7.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 150.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10187.5 10501 10344.3 628 ROP MWD020 FT/H 1 659.33 88.4324 566 GR MWD020 API 15.86 57.01 24.3949 567 First Reading For Entire File .......... 10187.5 Last Reading For Entire File ........... 10501 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Last Reading Reading 10187.5 10501 10218.5 10501 10187.5 10470.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/08/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/08/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File