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Home My WebLink About201-192~~~~~~ STATE OF ALASKA ~pR * ~ '~SKA O~AND GAS CONSERVATION COMMI~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: G ^ Other ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Ex loration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 3/21/2010 12. Permit to Drill Number: 201-192 310-038 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded: 11/11/2001 13. API Number. 'SO-029-21115-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 11 /16/2001 14. Well Name and Number: 15-16A 854 FNL, 165 FWL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 3992' FSL, 4060' FWL, SEC. 15, T11 N, R14E, UM g, KB (ft above MSL): 71 ~ GL (ft above MSL): 32.g~ 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2683' FSL, 63' FWL, SEC. 14, T11N, R14E, UM 9. Plug Back Depth (MD+TVD): 4587' 4392' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676088 y_ 5960631 Zone- ASP4 10. Total Depth (MD+TVD): 13715' 8762' 16. Property Designation: ADL 028306 & 028307 TPI: x- 679858 y- 5965567 Zone- ASP4 Total Depth: x- 681174 Y- 5964290 Zone- ASP4 11 • SSSV Depth (MD+TVD): N/A 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and Tinted information r 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR, ROP, PWD, MCNL, CCL 22. Re-DrilULateral Top Window MD/TVD: 11536' 8702' 23• CASING, LINER AND CEMENTING RECORD SETTING' DEPTH MO SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP. BOTTOM SizE CEMENTING RECORD PULLED u , , a ~ ~ / u ~ a I ~ ~ _1 ~, 24. Open to production or injection? ^ Yes ®No 25. TueiNk RECORD If Yes, Ilse Bach Interval Open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD / TVD 3-1/2", 9.3#, L-80 5000' - 11536' 10243' / 7919' MD TVD MD TVD i 26:' AGtD, FRACTURE,:CEMENT:SQUEEZE, ETC. ~t [ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED 8179' P&A w/ 34 Bbls Class'G' Cement 8153' - 8156' ubin Punch 4609' Set EZSV 458T Set Whi stock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY API (CORK): 28. CORE DATA Conventi onal Core(s) Acqui red? ^ Yes No Sidewall Core(s) Acquired? Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 12/2009 NTINUED ON REVERSE Submit Original Only R6DMS APR 15 ~{•!?• !o ~~~~~ ~' 29. GEOLOGIC MARKERS (List all formati ons and ma ncountered): 30. NATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 1 B 11606' 8738' None Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. / D`f Signed: Terris Hubble Tftle: Drilling Technologist Date: l ~~ !O 15-16A 201-192 310-038 Prepared ey MameMumber- Terris Nubble, 584-4628 Well Number Permit No. /Approval No. Drilling Engineer: Chafes Reynolds, 564-5480 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-Akemating-Gas Injection, Sak 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 recerds 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 ftom more than one interval (mutiple 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. Submft detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • 15-16A, Well History (Pre Rig Sidetrack) Date Summary 1/5/2010 WELL S/I ON ARRIVAL. DRIFT & TAGGED LINER TOP WITH 2.50" CENT, SAMPLE BAILER C 10781' SLM (10795' MD). PUMPED 14 GALLONS OF HYD FLUID DOWN CHEMICAL INJECTION LINE. JOB COMPLETED, TURN WELL OVER TO DSO. 1/14/2010 T/I/0=2100/300/120 Infectivity test (Pre sidetrack). Pumped 5 bbls meth and 243 bbls 1 % KCL down the tubing for infectivity test. Freeze protected with 32 bbls crude. Results are as follows; 1 bpm = 30 psi, 2 bpm = 75 psi, 3 bpm = 350 psi, 4 bpm = 750 psi, and 5 bpm = 1200 psi. FWHPs =vac/500/600 2/25/2010 T/I/0=300/60/700 temp=40` MIT IA 3500 ""'PASS'""* MIT OA 2000 `"""FAIL'**~ Rigged up to IA and pumped 16 bbls crude to reach test pressure. IA lost 60 psi in 15 min's, 20 psi in 2nd 15 min's, for a total loss of 80 psi in 30 min's. Bled back approx. 12 bbls. Rigged up to OA and pumped 1.9 bbls crude to reach test pressure. On 3rd test, OA lost 0 psi in 15 min's, 30 psi in 2nd 15 min's & 20 psi in 3rd 15 min, for a total loss of 50 psi in 45 min's. Bled back approx. 1.2 bbls. PE & DSO notifed of results. FW P=2250/150/280 2/25/2010 T/I/0=2300/240/140 Temp=S1 Freeze protect F/L. Rigged up to treecap and pumped 7 bbls 60/40, 150 bbls crude to freeze protect the F/L. FWHPs= 2300/240/140 2/26/2010 T/I/0=2300/240/140 Temp=S1 MIT OA 2000 psi PASS Rigged up to OA and pumped 2.1 bbls crude to reach test pressure. 2nd test: OA lost 0 psi in 30 minutes. Bled back approx.. 2 bbls FWHP's = 2300/240/100 3/1/2010 T/I/0= 2400/50/140 Temp= S/I Assist SLB cement. Heated UR #38 freshwater to 120°F. Heated UR #08 1%KCL to 120°F. Heated Diesel transport to 75°F (250 bbls). Assist SLB cement, pumped 5 bbls neat meth spear. 3/1/2010 Prep to Pump fullbore P&A, start displace well w/ bbls of 1%. 3/2/2010 continue well kill w/ 280 bbl of 1 % kcl followed with 5 bbl freshwater and 7 bbls 15 8 ooa class L r.PmPn followed with 20 bbls cement w/ aggreqate followed with 7 bbls neat cement. Pumo 2 bbls freSbW9tAt1 divert 4" foam ball followed with 3 bbls freshwater. Follow water w/ 68 bbls 70°F diesel. Held 2500 psi sqz pressure for 30 min and bleed tbg back to 150 psi. est TOC Q 8460'. Grease crew cycle and service tree. Job complete. 3/2/2010 Assist SLB cement (Pre Sidetrack). Pumped 68 bbls 70°F diesel behind cement. Freeze protected hardline with 5 bbls diesel. Final WHPs 120/150/180 3/3/2010 T/I/0=300/40/140 Temp= SI jyIIT-T PASSED to 3500 osi. Pump 2.8 bbls crude down tbg to achieve test pressure. T lost 80 psi 1st 15 mins and 40 psi 2nd 15 mins fora total loss of 120 psi in 30 mins. Bled whp's FWHPs=500/40/140 3/3/2010 WELL SHUT IN ON ARRIVAL. DRIFTED TUBING W/ 2.64" CENTRALIZER & SAMPLE BAILER TO 8179' SLM. RECOVERED SAMPLE OF CEMENT IN BAILER. MIT-T TO 3500 PSI, '"'PASSED""' DRIFTED TUBING W/ 2.70" GAUGE RING TO 5343' SLM. WELL LEFT SHUT IN, DSO NOTIFIED OF DEPARTURE. 3/4/2010 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O: 50/0/120 SHOT SMALL TUBING PUNCH FROM 8153' - 8156', 2' BELOW COLLAR AT 8151'. FINAL T/I/O: 60/0/125. JOB COMPLETED. WELL LEFT SHUT i ni 3/5/2010 T/I/0=0/0/140 Circ-Out Well. Pumped into Tbg w/ 5 bbl meth spear, 855 bbls 1%KCL Pumping down Tbg taking returns up IA to 15-06 FL. Line up to IA, Pumped 157 bbls 90° Diesel down IA taking returns up Tbg to 15-06 FL. U-Tube freeze protect into Tbg for 1 hrs. Pumped 1.7 bbls down Tbg to pressure TxIA to reach test pressure. CMIT TxIA passed to 1500 psi. Loss of 20/20 psi 1st 15 min, Loss of 40/40 psi 2nd 15 min. Held pressure for extra 15 min. Loss of 0/20 psi 3rd 15 min. Bleed WHP to 0 PSI. Freeze protected 15-06 FL w/ 5 bbls methanol, 75 bbls diesel, 10 bbls diesel. Pressured 15-06 FL to 1500 psi. All surface lines flushed with diesel. Turn well over to DSO. Page 1 of 2 • • 15-16A, Well History (Pre Rig Sidetrack) Date Summary 3/6/2010 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O 0/120/0 RUN 2.5" JET CUTTER FOR 3.5" TUBING CUT. CUT TUBING AT 5000~GOOD INDICATION AT SURFACE, CORRELATED TO TUBING TALLY. TREE CAP PRESSURE TESTED. DSO VERIFIED UPON DEPARTURE. FINAL T/I/O = 0/50/0. JOB COMPLETE. WELL LEFT SHUT-IN. 3/7/2010 T/IA/OA= 0/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (FAIL) (Pre Rig) PPPOT-T RU 2 HP BT onto THA 150 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 4900/ 15 minutes, 4900/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycle and torque LDS "Standard" (1) @ 2:00 backed out all others functioned with no problems. PPPOT-IC RU 2 HP BT onto IC test void 0 psi, flush void until clean returns achieved. unable to pressure up. Cycle and torque LDS "Standard" all functioned with no problems. Re test same results. 3/8/2010 T/I/O=0/vac/61. Temp=S1. Bleed IA & OA to 0 psi (Pre- RWO). No AL. Flowline & well house have been removed. BPV is set. OA FL near surface. Bled OAP from 61 psi to 0+ psi in 15 mins (all gas, then FTS). Monitor for 15 mins, OAP increased 30 psi, repeated bleed 2 more times with the OAP increase decreasing. Monitor for 30 minutes during dig down, OAP increased 15 psi. Final W HPs=O/Vac/15. Page 2 of 2 • BP EXPLORATION Page 1 of 1 Operations Summary Report Legal Well Name: 15-16 Common Well Name: 15-16 Spud Date: 11/19/2001 Event Name: MOBILIZATION Start: 3/17/2010 End: 3/18/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/18/2010 00:00 - 12:00 12.00 MOB P PRE INSTALL BRIDLE LINES AND PREPARE TO LD DERRICK. LD DERRICK. MOVE SUBSTRUCTURE FROM DS 17 TO DS 15. SPOT CAMP, PITS AND SHOP ON DS 15 12:00 - 22:00 10.00 RIGU P PRE SPOT RIG OVER 15-16. ,RAISE DERRICK. MOVE IN PITS. PREP FLOOR AND RD BRIDLE LINES. RU TOP DRIVE AND RU INTERCONNECT. CHANGE OUT SAVER SUB TO 4-1/2" IF. INSTALL AUXILLARY ANNULUR VALVES. TAKE ON 105 DEG SEAWATER. ACCEPT RIG AT 22:00 HRS ON 3/18/2010 22:00 - 23:00 1.00 WHSUR P DECOMP TEST TREE. PRESSURE TEST LINES TO 2000 PSI. PT OA TO 2000 PSI FOR 10 MIN. PRESSURE TEST IA AND BPV TO 1000 PSI FOR 10 MIN. 23:00 - 00:00 1.00 WHSUR P DECOMP RU DSM LUBRICATOR. PRESSURE TEST LUBRICATOR TO 500 PSI. PULL BPV AND RD LUBRICATOR. Printed: 3/29/2010 11:46:28 AM • BP EXPLORATION Operations Summary Report Page 1 ~ Legal Well Name: 15-16 Common Well Name: 15-16 Spud Date: 11/19/2001 Event Name: RE ENTER Start: 3/19/2010 End: 5/4/2010 Contractor Name: NORDIC CALISTA Rig Release: 11/20/2001 Rig Name: 1~B+e'1"' ? "'?E~ Rig Number: N1 Date From- To Hours Task Code NPT Phase Description of Operations 3/19/2010 00:00 - 00:30 0.50 WHSUR P DECOMP RU ON OPEN TOP TANK TO CIRCULATE OUT FREEZE PROTECT. 00:30 - 03:00 2.50 WHSUR P ~ DECOMP PJSM, PRESSURE TEST LINES TO 1000 PSI AND "°'`' '" REVERSE CIRCULATE 25 BBLS OF DIESEL OUT THE ` TUBING. BD AND SWAP LINES. CIRCULATE 132 BBLS OF DIESEL OUT THE IA AND CBU iX - 252 GPM, 715 PSI RIG DOWN AND BLOW DOWN LINES 03:00 - 04:00 1.00 WHSUR P DECOMP INSTALL ISA BPV AND TEST FROM BELOW TO 1000 PSI FOR 10 MIN. RD AND BLOW DOWN TEST EQUIPMENT. 04:00 - 06:00 2.00 WHSUR P DECOMP PJSM, ND TREE AND ADAPTOR. INSTALL BLANKING PLUG. 06:00 - 08:30 2.50 BOPSU P DECOMP PJSM, NU BOPE 08:30 - 09:30 1.00 BOPSU P DECOMP RU LINES TO TEST BOPE 09:30 - 14:30 5.00 BOPSU P DECOMP EST BOPE AND CHOKE MANIFOLD TO 250 PSI LOW/ 3500 PSI HIGH WITH ~-1/2" AND 5" TEST JOINI. TEST A'~lRQCQ~T'T~~SS 2500 PSI HIGH WITH 3-1/2" AND 5" TEST JOINT. AOGCC REP JEFF JONES WAIVED WITNESSED TO TEST. TEST ALSO WITNESSED BY NAD TOOLPUSHER CHRIS WEAVER AND BP WSL DAVE NEWLON. 14:30 - 15:30 1.00 BOPSUF~ P 15:30 - 20:00 4.50 WHSUR I P 20:00 - 21:00 I 1.001 PULL I P 21:00 - 22:30 1.50 PULL P 22:30 - 23:00 0.50 PULL P 23:00 - 00:00 1.00 PULL P 3/20/2010 00:00 - 06:30 6.501 PULL P 06:30 - 08:00 1.50 PULL P 08:00 - 10:00 2.00 BOPSU P DECOMP RD TEST EQUIPMENT AND BLOW DOWN LINES DECOMP MU LUBRICATOR EXTENSION AND LUBRICATOR. TEST TO 500 PSI. ATTEMPT TO PULL BPV. UNABLE TO LATCH ON TO BPV. RD LUBRICATOR AND LUBRICATOR EXTENSION SUCK OUT STACK. AND CHECK FOR DEBRI ON PLUG. RU LUBRICATOR EXTENSION. LUBRICATOR EXTENSION MAKING UP OFF CENTER. INSTALL LARGER CENTRALIZER ON PULLING TOOL. RU LUBRICATOR AND LUBRICATOR EXTENSION. PULL BPV. DECOMP RU 4-1/2" SPEAR AND STING INTO TUBIN BACKOUT LDS. PULL TUBING HANGER TO RIG FLOOR. TUBING PULLED F E DECOMP PUMP 35 BBLS SAFE SURF-0 SWEEP. CIRCULATE SWEEP SURFACE TO SURFACE. RU TUBING HANDLING EQUIPMENT. RU CAMCO SPOOLER. DECOMP RD SPEAR AND LD. BACK OFF HANGER AND LD HANGER. DECOMP PULL 1 JT OF 4-1/2" TUBING AND LD 3-1/2" TUBING FROM 5,000' TO 4,800'. REMOVE CLAMPS AND SPOOL CONTROL LINE. - 66K PUW DECOMP CONTINUE TO PULL 3-1/2" TUBING FROM 4.800 WITH CONTROL LINE. RECOVERED 156 JTS OF 3-1/2" TUBING ONE 4.5" JOINT. 1 SSSV, 2 GLM, 8 SS BANDS, 159 CLAMPS AND PINS, AND 21.1' CUT JOINT. DECOMP RD CONTROL LINE SPOOLER AND TUBING HANDLING EQUIPMENT. CLEAN AND CLEAR RIG FLOOR. DECOMP RU AND TEST LOWER PIPE RAMS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MIN WITH 4" AND 5" TEST JOINTS. Printed: 3/29/2010 11:46:35 AM • BP EXPLORATION Page 2.~8 Operations Summary Report Legal Well Name: 15-16 Common Well Name: 15-16 Spud Date: 11/19/2001 Event Name: RE ENTER Start: 3/19/2010 End: 5/4/2010 Contractor Name: NORDIC CALISTA Rig Release: 11/20/2001 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 3/20/2010 08:00 - 10:00 2.00 BOPSU P DECOMP TEST WITNESSED BY NAD TOOLPUSHER CHRIS WEAVER AND BP WSL DAVE NEWLON. 10:00 - 10:30 0.50 CLEAN P DECOMP LOAD PIPE SHED WITH 5" DRILL PIPE. BRING SCRAPER, BIT AND BHA TOOL TO RIG FLOOR. 10:30 - 13:00 2.50 CLEAN P DECOMP PU 8.5" BIT, CASING SCRAPER, 8.5" STRIN MILL AND 769' MDR 13:00 - 16:00 3.00 CLEAN P DECOMP PU DRILL PIPE FROM 769' TO 4980' MD. WASH DOWN AND TAG TUBING STUB AT 4996'. - 130K PUW, 120K SOW 16:00 - 17:00 1.00 CLEAN P DECOMP CBU 1.5X - 550 GPM, 1345 PSI MONITOR WELL, STATIC 17:00 - 18:30 1.50 CLEAN P DECOMP PUMP DRY JOB AND POOH FROM 4996' TO 320' MD 18:30 - 19:00 0.50 CLEAN P DECOMP RACK BACK DRILL COLLARS AND LD CASING SCRAPER, STRING MILL AND 8.5" BIT. CLEAN AND CLEAR RIG FLOOR 19:00 - 20:30 1.50 DHB P DECOMP PJSM, RU E-LINE EQUIPMENT. PU EZSV AND RUNNING TOOL. 20:30 - 23:30 3.00 DHB P DECOMP RIH WITH EZSV, CCL AND GR. LOG UP AND TIE IN LOG. SET TOP OF EZSV AT 4 1 POOH WITH RUNNING TOOL AND LOGGING TOOLS. 23:30 - 00:00 0.50 DHB P DECOMP PRESSURE TEST CASING TO 3500 PSI FOR 30 MIN. LOST 21 PSI IN THE FIRST 15 MIN AND 7 PSI IN THE SECOND 15 MIN. 3/21/2010 00:00 - 02:30 2.50 WHSUR P DECOMP BACK OUT LDS. PULL WEAR RING AND PACKOFF. INSTALL NEW PACKOFF. RUN IN LDS. TEST TO 5000 PSI FOR 30 MIN. INSTALL WEAR RING. 02:30 - 05:00 2.50 STWHIP P WEXIT PJSM, PU WHIPSTOCK MILLING ASGFMRi Y AND POWERPULSE TOOL. CONFIRM SHEAR PINS AND INSTALL SHEAR BOLT. RIH TO 830' MD. 05:00 - 08:00 3.00 STWHIP P WEXIT RIH FROM 830' TO 1396' MD. SHALLOW HOLE TEST MWD AT 450 GPM AND 660 PSI. CONTINUE TO RIH TO 4510' MD. ORIENT WHIPSTOCK 50 DEGREES RIGHT. RIH AND TAG EZSV AT 4609' MD. SO 20K AND SHEAR ANCHOR. PULL 10K OVER TO CONFIRM SET. SO 50K TO SHEAR BOLT. TOW = 4,587' MD BOW = 4604' MD 125K PUW, 120K SOW 08:00 - 08:30 0.50 STWHIP P WEXIT PUMP 50 BBL HIGH VISCOSITY SPACER AND DISPLACE WELL TO 9.0 PPG LSND MILLING FLUID. - 520 GPM, 650 PSI 08:30 - 10:00 1.50 STWHIP N RREP WEXIT TOP DRIVE LUBE OIL FILTER FAILED. CHANGE OUT FILTER AND BYPASS LUBE COOLER. C~-~.1~- 10:00 - 16:00 6.00 STWHIP P WEXIT MILL WINDOW FROM 4587' TO 4591' MD. UTILIZE SUPER `cJ.~~g SWEEPS AS NESSESARY. - 3-5K WOB - 350 GPM, 600 PSI - 6-9K TO ON, 3K TO OFF - 90 RPM - 125K PUW, 120K SOW, 123K RTW DRILL 29' OF NEW FORMATION TO 4620' MD. RECOVERED Printed: 3/29/2010 11:46:35 AM TREEy '- 4-1/85M ELLHEAD= FMC ACTUATOR = Single KB. ELEV = 61 BF. ELEV...- 63.13' KOP = 4587 Max Angle..- _ _ _ 95 Datum MD = 12,523' Datum TV D = 8800' SS ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" '15-'16B SAFETY NOTES: 2230' 4-1/2" HES X Nip, ID 3.813" GAS LIFT MANDRELS I 2495' I Minimum ID = 3.75" i~ XN-Nipple 12,201' Top of Whipstock 4587' HES EZSV 4600' Jet Cut 5000' 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" TOP OF 7" LNR I-i 70492' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10850' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.88" 6 13,380-13,820 O 04/07/10 2.88" 6 14,000-14,450 O 04/07/1.0 2.88" 6 14,600-14,630 O 04/07/10 2.88" 6 14,670-14,750 O 04/07/10 2.88" 6 14,850-15,020 O 04/07/10 3-1 /2" TBG, 9.3#, L-80, ID = 2.992" I 11709' 7" LNR, 29#, L-80, ID = 6.184• 11848' 15-16 TD I-I 11891' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3550 3521 17 MMG DGK RK 1.5" 04/09/10 3 6987 5499 60 KBG DMY BK 1" 04/09/10 2 10589 6995 65 KBG DMY BK 1" 04/09/10 1 12039 7963 35 KBG DMY BK 1" 04/09/10 4441' 7"x9-5/8" Baker ZXP LTP C 12073' -I4-1 /2" HES X Nip, ID 3.813" 121 7" x 4-1/2" HES TNT PKR ID=3.856" 12139' 4-1/2" HES X Nip, ID 3.813" 12215' 4-1/2" HES XN Nip, ID 3.725" 12228' 4-1/2" TBG, 12.6# , VAMTOPI3 CR-85 12219' BKR 5"x 7" ZXPN LTP (10.84' x 5.25" ID 12398' I~ 7" Lnr, 26#, L-80 IBT-M ID = 6.276" 15632' 4-1/2" Liner, 12.6#, L-80, ID=3.813 15-16A 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID= 1.920" 13715' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/30/84 ORIGINAL COMPLETION 11/25/03 BJMcM/TLP ADD PERFS 11/18/90 LAST WORKOVER 03/05/05 JLG/TLH ADD PERFS 11/20!01 CTDSIDETRACK 07/21/08 DMS/SV ADDPERFS 12/31/01 CHITP CTD SIDETRACK 09/28/09 CJN/SV GLV GO (09/07/09) 10/04!01 JBM/KK CMT; XXN PLUG; TBG PUNCH 10/05/09 AMW Proposed Driling Sidetrack 11/07/01 DTR/TLH WHIPSTOCK ~ EMTPY GLV 04/09/10 RRC DRLG DRAFT PRUDHOE BAY UNff WELL: 15-166 PERMIT No: 210020 API No: 50-029-21115-02-00 SEC 22, T11 N, R14E 853' FNL & 165' FWL BP Exploration (Alaska) u u Mr. Greg Hobbs Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 0 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 15-16A Sundry Number: 310-038 Dear Mr. Hobbs: 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Commissioner r~ DATED this 2 33 day of February, 2010 Encl. ,. a,~o ~`~ ~~ STATE OF ALASKA ~~\~ ~ ALASK~L AND GAS CONSERVATION COMMfS•N ~j~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RECEIVE ~~ro~ ~~B ~ 0 2~1~ 1. Type of Request: J ~~" • Abandon !~ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved ProgflMlkherape ^ 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 201-192 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21115-01-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Welt Name and Number: property line where ownership or landownership changes: 15-16A- Spacing Exception Required? ^ Yes ®NO 9. Property Designation: 10. Field /Pool(s): ADL 028306 8~ 028307- 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 ND (ft): Plugs (measured): Junk (measured): 13715' 8762' ~ 13649' - 8760' ~ None None Casin Len Size MD TVD Burst Colla StfUCtUral Conductor ' Surface 4 1-/" 4 4 4 Intermediate 10 0' - / " 7 47 Production Liner 1 7" 1 ' - 115 6' 4' - 87 160 7 Liner 2 20' - / " 1 79 ' - 1 71 2 11 117 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11710' - 13518' 8780' - 8759' 3-1/2", 9.3# L-80 11536' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'D' packer Packers and SSSV 10243' / 7919' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 19, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR Abandoned 16. Verbal Approval Date: ^ WINJ ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: ~S`.G/~~ d •~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Charles Re Holds 564-5480 Printed Name Gre ob s Title Engineering Team Leader Prepared By NameMumber Signature Phone 564-4191 Date /0 !d Terzie Hubble, 564-4628 .Commission Use Onl Conditions of approval: No 'ty Commission so that a representative may witness 3/O_ ~~ Sundry Number: ,..,/ LvJ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance * 3Soo ~s~ QoP %~st \ other: ~"' ~ I~+s ~ .'"~ Z SrO ~ D-s'~- ~h K ". a.Y t `S * , ~ ~ Subsequent Form Required: ~ Q • y a7 APPROVED BY D t 3 a e Approved By: COMMISSIONER THE COMMISSION Form 10-403 Revi~ed~12/2009 Submit In uplicate ~.'~ ~ ~ ~ ~ ~ z • I~,t~BDMS FEB 2 3 X410 ~~/~ )G~ • by GP ~, 15-16A Well Type: Producer Current Status: The well is currently on cycled production MIT - IA Passed to 3500 psi 09/7/09 MIT - OA Passed to 2000 psi 09/7/09 • Request: Approval is requested for the P&A of PBU well 15-16A. 15-16A is a Zone 1A / 1B tiny tools sidetrack drilled to the north of the midfield graben in November 2001. When 15-16A came online in December 2001, it produced at expected rate. By August 2003, production had declined with an increasing GOR. In November 2003 the wellwork platform shot 220' of Z1A perfs with short lived production gains. The interval from 11,825' - 11,900' was shot with coil in February 2005, however, these perfs had very little effect on production. The wellwork platform was once again utilized in July 2008 to shoot a total of 260' of adperfs in three different intervals. Unfortunately, these additional perfs did not bring in any additional oil and consequently could not make 15-16A pick up its productivity or improve its overall uptime and competitiveness.Currently 15-16A's uptime has been on a gradual decline within the LP system. Efforts to swap the well header to HP have been unsuccessful. The well shows very minimal or no recharge after SI periods and always comes back at or above LP MGOR. All the wellwork options have been exhausted. A sidetrack is the only practical alternative that will give 15-16A a new lease of life and allow it to be competitive. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Scope of Work: The sidetrack plan for the 15-16A (an Ivishak Z1 producer) includes the following during pre-rig operations: bullhead cement across the perforations, the 3-1/2" tubing will be cut 400' below planned whipstock exit point. The whipstock exit from the 9-5/8" casing is estimated at 4600"MD and will be milled using an 8-1/2" milling assembly. The 8-1/2" hole will be drilled to the Top of the Sag River where a 7" drilling liner will be run to 150' inside the 9-5/8" casing. The 7" drilling liner will have 1,000' of cement at the shoe. The production hole will be drilled with a 6-1/8" BHA building to horizontal. The well will then run horizontally through the Ivishak formation. The production liner will be 4-1/2" L-80 and fully cemented. Tubing will be 4-1/2" 13Cr, tied into the top of the production liner. MASP: 2446 psi or 3377 ~ s Estimated Pre-Rig Start ate: February 19, 2010 I cdn~d~ , ilrr Well Prddv~f Qr ,~,~~ G~~ ~.~ol over f'~odL~ Fv~ ara~e rlrah ~ L•-reK P~~ ~~>li, l~o~ic~~ ~~~- rc~ flae Norr~i 4F Sze etr~~'!'%.~~ a,~//~~ire ik 4~~r 1'ke ~Te~,,o~ ~ y~9fs ;~~rt S,~~e n ack w;li iz+3~-~r f~~ tee. ~~s • Pre-riq prep work: W 1 Function tubing and casing LDS. Repair/replace as required. Perform PPPOT-IC to 3500psi and PPPOT-T to 5000 si. MIT-IA to 3500, and MIT-OA to 2000 si Passed 9/7/09 S 2 Drift tubin to 7000'. F 3 Flush chemical in~ection line with diesel F 4 Confirm injectivity into the open perfs as required for P&A to follow. If injectivity is sufficient for fullbore P&A, roceed with ste 5. If not, contact ODE F 5 "Bullhead" 34 bbl (10bb1 excess for perts), 15.8ppg G cement to plug and abandon the current well perforations: Liner Size 4.7# 2-3/8" (.0039 bpf) from 10795' to 13649' MD 11 bb/s Tubing size 9.3# 3-1/2" (.0087 bpf) from 10795' to 9300' MD 13 bb/s Bottom of plug 13649_MD Desired Top of Cement 9300' M Total Footage 4350' Top Perf 11,710' MD Bottom Perf 13,518' MD Max TOC - 5500', Min TOC - 9850' S 6 WOC. Drift to TOC and to . F 7 MIT-T to 3,500 psi. Pressure test is required for competent barrier for rig operations. If test fails, contact ODE. Freeze Protect as necessa E 8 Jet cut tubin 5000' MD. - F 9 CMIT TxIA to 3,500 si. If combo fails, contact ODE. D 10 Bleed casin and annulus ressures to zero. V 11 Set a BPV. Remove well house and flow line. Level ad as necessa - *Gyro to 10,000'MD on 15-366 and down to 8500' MD on 15-376 Proposed Procedure: 1. MI / RU Nabors rig 7ES 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. 3. Set and test TWC to 1,000 psi from above and below. 4. Nipple down tree 8~ tubing adapter. Nipple up and test BOPE to 3,500psi high/ 250psi low. Pull TWC. LPK t.~h~vEd. 5. R/U & pull 4-1/2" x 3-'/Z" tubing from the cut depth at 5000' MD. 6. R/U & Run 9-5/8" cleanout BHA down past EZSV setting depth 7. RIH with HES EZSV bridge plug on E-line and set at 4600' MD, as required to avoid cutting a casing collar while milling the window. 8. Pressure-test the 9 g/8' casing to 3,500 psi for 30 minutes. Record test. 9. Change out 9-5/8" Pack offs S` 10. P/U and RIH with 9 5/e" Baker bottom-trip anchor whip stock assembly. Orient whipstock and set on EZSV bridge plug. Shear off of whip stock. 11. Displace the well to LSND based milling fluid. Completely displace the well prior to beginning milling 12. Mill window in 9 g/8" casing, plus approximately 20' beyond middle of window. Circulate well bore clean. 13. Pull up into 9 5/a"casing and perform LOT. POOH. 14. M/U 8-'/2' RSS GR/RES/PWD/MWD assembly. RIH, kick off and drill the 8-%2" intermediate section Pr with LSND drilling fluid. • • 15. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate the well clean, short trip as needed. POOH. 16. Change out to 7" rams, and test to 250 psi / 3,500 psi 17. MU and run 7", 26#, L-80, TCII liner to bottom on drill pipe. Circulate and condition the hole. 18. Pump 1000' of cement behind the 7" liner. Test the liner to 3,500 psi for 30 charted minutes. 19. Set the hanger and packer. 20. Circulate bottoms up, POOH, L/D liner running tool (LRT). 21. Change out rams to variable and test to 250 psi / 3,500 psi 22. M/U the first 6-'/8" Dir/GR/DEN/NEU/Res assembly with an insert bit. Pick Up DP as necessary. 23. RIH, Drill out of cement and 7" liner float equipment. 24. Displace to 8.4 ppg Flo Pro Fluid. 25. Continue drilling out the 7" shoe plus ~20' new formation, pull up into the shoe and perform a FIT. 26. Drill the 6-%6" production interval as per directional plan to TD of pilot hole 27. Pull up to designated sidetrack spot and begin time drilling, trough sufficient footage to start sidetrack. 28. Continue drilling build and land for horizontal BHA 29. POOH for lateral section motor bend and PDC bit. PU horizontal BHA. 30. RIH, drill ahead to TD 31. POOH. UD BHA. 32. MU and RIH to bottom with 4 '/", 12.6#, L-80 solid liner. This will include 150' liner lap inside the 7" drilling liner. 33. Cement the liner. ' 34. Set liner top packer and displace well to clean seawater above the liner top. a. A pert pill will be left in the 4 '/z" liner. 35. POOH, UD LRT. 36. Pressure test casing and liner to 3,500 psi for 30 minutes. 37. RU DPC pert guns, RIH and perforate. Perf intervals to be supplied by asset. 38. R/U and run a 4-%2°, 12.6#, 13Cr, VamTop tubing completion, stinging into the 4-%2' liner tie back sleeve.. 39. Space out and make up tubing hanger per FMC Rep. 40. Land the tubing hanger, and run in lock down screws. 41. Circulate Corrosion Inhibitor. 42. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 43. Shear Circulating Valve 44. Set a BPV. 45. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 46. Freeze protect the well to 2,200' TVD. Secure the well. 47. RD and Move Off. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Replace the DCK shear valve with a dummy GLV. 3. Install well house and instrumentation. 4. Modify S-Riser As Needed. 5. ASRC flowback Drilling Engineer: Charles Reynolds (907) 564-5480 Production Engineer: Eliot Townsend (907) 564-4062 Geologist: Daniel Schafer (907) 564-5098 ATTACH: Current Schematic Pre-Rig Schematic Proposed Schematic 'TREE'- `4-1116" FMC GHV 3 WELLHEAD = ACTUATOR = AXELSO KB. REV = 71.0" BF_ ELEV = NA KOP = 3000' Max Angle - ~ 98 @ 12787 Datum WlD - _ Datum TV D = 8800' SS ~ 13-318" CSG, 72#, L-80, ID =12.347" 1 Minimum ID =1.920" ~ 10802' TOP OF 2-3/8" LINER 15 ~ ~ 6 " SAFELY NOTES: KI~WN LEAK @ GLM #13 -10443' (PATCH PULLED 08/23. ANGLE > 70° @ 17 700' 8~ > 90° 11763'. CMT S Fl 13524 -13649 NOTED X CTD. 69' 4-112" X 3-112" TBG XO, fD = 2.992" 2235' 3-1/2" CAMCO TRDP-1A TRSSSV, iD = 2.812" O LOCKED OUT 08/15!01 GAS L~ f MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2854 2853 7 MMG DMY RK 0 09/07/09 2 4364 4235 42 MMG DMY RK 0 05/21 /95 3 5920 5230 50 MMG DMY RK 0 09/07!09 4 7164 5989 51 MMG DMY RK 0 5 8069 6534 53 MMG DMY RK 0 6 8566 6835 52 MMG DMY RK 0 7 8964 7081 52 MMG DMY RK 0 8 9458 7392 50 MMG DMY RK 0 9 9830 7634 48 MMG DMY RK 0 10 10107 7823 46 MMG EO DMY RK® 0 C ~ 3-112" TBG, 9.3#, L-$0, .0087 bpf, D= 2.992" ~ BKR SEAL BORE EXT, ~ = 4.750" H 10247' 4-1/2" BKR SEAL ASSY, ID = 3.875^ 10259' TOP OF 7" lNR H 10492' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10850' PERFORATION SUMMARY REF LOG: SWS MEMORY GRlCNL ON 11118/01 ANGLE AT TOP PB2F 95 @ 11825' Note: Refer to Productron DB for histor~al pert data SIZE SPF gVT6~VAL Opn/Sgz DATE 1.56" 6 11710 - 11830 O 07/21/08 1.56" 6 11825 - 11900 O 02/18105 1.56" 6 11920 - 11940 O 07/21/08 1.56" 6 11975 - 12160 O 11125/03 1.56" 6 12160 - 12280 O 07/21/08 i .56" 6 12320 - 12355 O 11/25/03 1.56" 4 12680 - 12830 O 11/19101 1.56" 4 12870 -12970 O 11 /19/01 1.56" 4 13120 - 13155 O 11/19/01 1.56" 4 13245 - 13518 O 11/19/01 3-112" TBG, 9.3#, L-80, N3 = 2.992" 7" LNR, 29#, L-80, ®= 6.184" 1 TD 1 11709' 11848' 1 11891' 1 CHEM &V,1 MANDREL ST MD TVD OEV TYPE VLV LATCH PORT DATE 11 10168 7856 49 MMG-LTS CN RCI-2 05/14/95 10243' H 9-5/8" X 4-112° BKR D PKR, ~= 4.750" 10280' 3-112" OTiS X Nom, ~ = 2.813° PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 13 10353 10443 7979 8039 58 60 MMG MMG EMPTY EO DMY RKP 10795' 2.70^ TIW DH~LOYMENT sl_v, ID = 2.250^ 10802' TOP OF 2-3/8" 4.7# LNR ID = 1.920" 3-1 /2" TBG 8~ 7" LNR MLLOUT WNIDOW 11536' - 11542' 11536' WHtl~STOCK ~~ 11541' RA TAG STD H 13649' 2-318" LNR 4.7#, L-8Q .0039 bpf, 1D =1.920" (-i 13715' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/30/84 ORIGINAL COMPLETION 11/25/03 BJMcMlTLP ADD PERFS 11/18/90 _ LAST_ WORKOVB2 03/05/05 JIGITLH ADD PB~FS 11/20/01 CTDSIDETRACK 07/21108 DMS/SV ADDPERFS 12/31/01 CHITP CTD SIDETRACK 09128/09 CJN/SV GLV GO (09/07109) 10!04/01 JBMIKK CMT; XXN PLUG; 7BG PUNCH 11/07/01 DTR/TLH WH~STOCK 8~ EMTPY GLV PRUDHOE BAY UNff WELL: 15-1 6A PB~MfT No: 2011920 AR No: 50-029-21115-01 SEC 22, T11N, R14E853' FNL & 165' FWL BP F~cploration (Alaska) .TREE _ ~ ~4-1/16" FMC GEN 3 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 71.0' BF. ELEV = NA KOP = 3000' Max Angle = 98 @ 12787' Datum MD = Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2495' Minimum ID = Tubing Jet Cut 5000' TOC 9300' 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" BKR SEAL BORE IXT, ID = 4.750" 10247' 4-1/2" BKR SEAL ASSY, ID = 3.875" 10259' TOP OF 7" LNR I~ 10492' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 10850' PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CNL ON 11/18/01 A NGLE AT TOP PERF: 95 @ 11825' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 11710 - 11830 O 07/21/08 1.56" 6 11825 - 11900 O 02/18/05 1.56" 6 11920 - 11940 O 07/21 /08 1.56" 6 11975 - 12160 O 11 /25/03 1.56" 6 12160 - 12280 O 07/21 /08 1.56" 6 12320 - 12355 O 11 /25/03 1.56" 4 12680 - 12830 O 11/19/01 1.56" 4 12870 - 12970 O 11/19/01 1.56" 4 13120- 13155 O 11/19/01 1.56" 4 13245 - 13518 O 11/19/01 3-1/2" TBG, 9.3#, L-80, ID = 2.992" ~ 11709' 7" LNR, 29#, L-80, ID = 6.184" 11848' ~~~ 11891' 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.920" i~ 13715' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/30/84 ORIGINALCOMPLETION 11/25/03 BJMcMITLP ADDPERFS 11/18/90 LAST WORKOVFJ2 03/05/05 JLG/TLH ADD PERFS 11/20/01 CTD SIDETRACK 07/21/08 DMS/SV ADD PERFS 12/31/01 CWTP CTD SIDETRACK 09/28/09 CJWSV GLV C/O (09/07/09) 10/04/01 JBM/KK CMT; XXN PLUG; TBG PUNCH 11/07/01 DTR/TLH WHIPSTOCK & EMTPY GLV PRUDHOE BAY UNIT WE1L: 15-16A PERMff No: `1011920 API No: 50-029-21115-01 SEC 22, T11 N, R14E 853' FNL & 165' FWL BP F~cploration (Alaska) I O I • SAFETY NOTES: KNOW N LEAK @ GLM #13 -10443' (PATCH PULLED 08/23/01 L ANGLE> 70° @ 11700' & > 90° @ 11763'. CMT STRI S F/ 13524 -13649 NOTED X CTD. 69' 4-1/2" X 3-1/2" TBG XO, ID = 2.992" 2235' 3-1/2" CAMCO TRDP-1A TRSSSV, ID = 2.812" LOCKm OUT 08/15/01 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 2854 4364 2853 4235 7 42 MMG MMG DMY DMY RK RK 0 0 09/07/09 05/21 /95 10243' ~ 9-5/8" X 4-1/2" BKR D PKR, ID = 4.750" 10280' 3-1/2" OTIS X NIP, ID = 2.813" 10795' ~ 2.70" TMI DEPLOYMENT SLV, ID = 2.250" 10802 TOP OF 2-3/8" 4.7# LNR, ID = 1.920" 11536' ~ WHIPSTOCK 11541' RA TAG s \ PBTD 13649' TREE _ 4-1/16" FMC GEN 3 WELLHEPtD = FMC ACTUATOR = AXELSON KB. ELEV = 71.0' BF. ELEV = NA KOP = 3000' Max Angle = Datum MD = Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~--~ 2495, Minimum ID = HES EZSV 4600' Jet Cut 5000' 3-1 /2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" TOP OF 7" LNR ~-{ 10492' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 10850' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data 3-1/2" TBG, 9.3#, L-80, ID = 2.992" ~~ 11709, 7" LNR, 29#, L-80, ID = 6.184" 11848' 15-16 TD ~~ 11891' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3 4 5 4450' 7" Liner Hanger /LTP 11481' Top of Intermediate Cement 12210' 4-1/2" HES X Nip, ID 3.813" 12240' 7" x 4-1/2" HES TNT PKR ID=3.870 12270' 12300' 12330' 4-1/2" HES X Nip, ID 3.813" 4-1/2" HES XN Nip, ID 3.725" 4-1/2" TBG, 12.6# , VAMTOP 13 C 12330' i-I BKR 5"x7" Hanger/ LTP ID=4.193" 12481' 7" Csg, 26#, L-80, TCII ID=6.276" 15650' 4-1/2" Liner, 12.6#, L-80, ID = 3.813 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.920" 13715' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/30/84 ORIGINAL COMPLETION 11/25/03 BJMcMITLP ADD PERFS 11/18/90 LAST WORKOVER 03/05/05 JLG/TLH ADD PERFS 11/20/01 CTD SIDETRACK 07/21/08 DMS/SV ADD PERFS 12/31/01 CH/TP CTD SIDETRACK 09/28/09 CJNISV GLV GO (09/07/09) 10/04/01 JBM/KK CMT; XXN PLUG; TBG PUNCH 10/05/09 AMW Proposed Driling Sidetrack 11/07/01 DTRlTLH WHIPSTOCK & EMTPY GLV 15-16B O I J I 15-16A SAFETY NOTES: 2200' 4-1/2" HES X Nip, ID 3.813" GAS LIFT MANDRELS PRUDHOE BAY UNIT WELL: 15-16B PERMIT No: API No: SEC 22, T11 N, R14E 853' FNL & 165' FWL BP Exploration (Alaska) • • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, February 22, 2010 4:36 PM To: 'Hubble, Terrie L' Subject: 15-16A (PTD # 201-192) Terrie, You have verbal approval to proceed with the cementing procedure to abandon the perforations in the well. The sundry should be approved shortly.... As well as the PTD for the Sidetrack. .ya. ~a,,.,-.~"°r~ /~ ~plS~ I ~ ~id .'.^~ Guy Schwartz 3lU-- ~3 p Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Monday, February 22, 2010 4:23 PM c ~ ~O",f'! To: Schwartz, Guy L (DOA) ~ .,: ~~;~~~-~ ~~-~ Cc: Ramirez, Darlene V (DOA); Reynolds, Charles Subject: RE: Looking for Approved Sundry for... Hi Guy, We are in a bit of a pickle... the Sundry for the P&A of 15-16A (PTD # 201-192) had a planned start date of February 19th, which turned out to be accurate and we are just waiting for the approved sundry to start the work. The Permit start date is still planned for March 15th and so we don't need that approved just yet. I know you like to work on them both at the same time, but... In the past, we have always been told that a Sundry could be turned around in about 5 business days and a permit in about 10 business days. It appears that this is the problem; planned start dates are not the same for both the Sundry and the Permit. Do we need to do our submittals differently than we have in the past? It has been awhile, where we didn't have an adequate cushion to work around, but in this case, planning time was a bit shorter. Is there anything we can do to get this Sundry as soon as possible, as the crew is ready and waiting to begin. Thanks! Terrie From: Ramirez, Darlene V (DOA) [mailto:darlene.ramirez@alaska.gov] 2/22/2010 Page 2 of 2 Sent: Monday, February 22, 2010 4:06 PM To: Hubble, Terrie L Subject: RE: Looking for Approved Sundry for... Terrie, Sorry I didn't get back to you sooner. The PTD is in the process. Regards, Darlene From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Monday, February 22, 2010 10:57 AM To: Ramirez, Darlene V (DOA) Subject: Looking for Approved Sundry for... Hi Darlene, We are looking for the following: Approved 10-403 for 15-16A (PTD#201-192), Planned start work on 02/19/10 It was submitted on 02/10/10 so I am surprised that we don't have it yet. Would you mind checking. Thanks so much! Terrie 2/22/2010 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 • January 1, 2010 Mr. Tom Maunder I ~, , ~ ~--' Alaska Oil and Gas Conservation Commission ~~ 333 West 7t" Avenue Anchorage, Alaska 99501 1 / Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 ^ate~ 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200 NA Sealed NA 15-02B 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-O6A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10!8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-318 2050860 50029222850200 NA 1.2 NA 3.4 11/11!2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10!2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11 /9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-48B 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-498 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 - STATE OF ALASKA I ALAS~IL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator SuspendD Repair Well 0 Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate ŒI WaiverD Stimulate 0 Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 201-1920 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development 00 ExploratoryD 71.00 8. Property Designation: ADL-0028307 11. Present Well Condition Summary: Stratigraphic D Service 0 9. Well Name and Number: 15-16A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-21115-01-00 Total Depth measured 13715 feet true vertical 8761.8 feet Plugs (measured) None Effective Depth measured 13649 feet Junk (measured) None true vertical 8760.4 feet ßCI\NNf=n SEP 2 C; 2DD5 _ ... .,,.;..JJ II!.:: ...-1 ~, Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 27 107 27.0 107.0 1490 470 Liner 1293 3-1/2" 9.3# L-80 10243 - 11536 7918.9 - 8702.4 10160 10530 Liner 1044 7" 29# L-80 10492 - 11536 8091.8 - 8702.4 8160 7020 Liner 2920 2-3/8" 4.7# L-80 10795 - 13715 8290.7 - 8761.8 11200 11780 Production 10825 9-5/8" 47# L-80 25 - 10850 25.0 - 8325.3 6870 4760 Surface 2469 13-3/8" 72# L-80 26 - 2495 26.0 - 2494.9 4930 2670 Perforation deoth: Measured depth: 11975 -12160,12320 -12355,12680 -12830,12870 -12970,13120 -13155,13245 -13518 True vertical depth: 8778.81 - 8773.92,8780.41 - 8780.73,8777.26 - 8763.91,8762.69 - 8761.66,8765.62 - 8767.99,8764.65 - 8759.48 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 @ 3-1/2" 9.3# L-80 @ 3-1/2" Cameo TRDP-1A SSV 4-1/2" Baker D Packer 24 69 @ 2235 @ 10243 69 10259 V1AR 1 0 200 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 577 541 ReoresentativeDailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 20.9 9 520 18.6 8 36 Tubing Pressure 405 719 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒI Service D Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown 0 Oil 00 GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )f( Signature Title Production Technical Assistant Phone 564-4657 Date 3/9/04 Form 10-404 Revised 12/2003 OR\G\N ~~Ib ..b ~Ïli~1 I . 15-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/20/03 RAN A 1.75" X 5' DRIVE DOWN BAILER ON 1-1/2 TOOL STRING WENT TO 11522' WLM SAT DOWN HIT ONE TIME FELL THRU & WENT TO 11705' WLM STOPPED FALLING POOH, WELL CLEAR TO 11705' WLM. 11/23/03 CTU#9/KLONDIKE #1: EXTENDED LENGTH PERFORATING. WELL SHUT IN UPON ARRIVAL. PERFORM BOP TEST. KILL WELL WITH 5 BBLS 60/40 METHANOL WATER, FOLLOWED BY 165 BBLS 1% FILTERED KCL, AND 40 BBLS 60/40 METHANOL. RIH W/1- 11/16THS PDS GR/CCL. 11/24/03 CTU #9: KLONDIKE #1: EXTENDED LENGTH PERFORATING. CONTINUED FROM WSR 23-NOV-03. CONTINUE RIH W/PDS 1-11/16TH MEM GR/CCL. RIH AND LOG FROM 12,500 TO 11,600' CTMD AND FLAG COIL AT 11,900' CTMD. SPOT 15 BBLS OF FLO PRO ACROSS PERFORATIONS AND POOH. PERFORM NO FLOW TEST. WELL DRIBBLING FLUID AND WILL NOT SUBSIDE. MU NOZZLE AND RIH. CIRC OUT WELL BORE W/1% KCL. BULLHEAD AND LAY IN FLOW PRO TO 10,236'. NO FLOW OBSERVED. POOH. MU 35' 1.56" 6 SPF PERF GUN AND RIH. CIRCULATE BALL DOWN W/9 BBLS OF FLO PRO AHEAD AND PERFORATE FROM 12320'-12355' MD. PERFORM NO-FLOW TEST AND POOH. 11/24/03 Perforate 12320'-12355' 6 SPF 11/25/03 Perforate 11975'-12160'6 SPF BBLS 224 60/40 Methonal 50 Flo Pro 375 1 % KCL 649 TOTAL FLUIDS PUMPED Page 1 TREE = 4-1/16" FMC GEN 3 WELLI-EAO = FMC ACTUATOR AXELSON K B K M o o 15-16A SAFElY NOTE. OWN LEAK@ GLM #13 -10443' (PATCH PULLs) 08/23/01). W B.L ANGLE > 700 @ 11700' & >900 @ = 11763'. CMT STRINGERS F/13524 - 13649 NOTED X CTD. B. ELEV = 71,0' "- F. ELEV = NA OP= 3000' '1 69' 4-1/Z' x 3-1/2"lBG XO, 10 = 2.992" ax Angle = 98 @ 12787' I atum MO = 2235' 3-1/Z' CAMCO lRlF-1A TRSSSV, 10= 2.81Z' atumTVD= 8800' SS . GAS UFT MANDRELS ST MO TVO DEV TYÆ VLV LATa-t FQRf DATE 1 2854 2853 7 MMG OOtÆ RK 16 11/28/01 I .l-4 ~ 2 4364 4235 42 MMG OMY RK 0 05/21/95 13-318" CSG, 72#, L-80, ID = 12.347" 2495' 3 5920 5230 50 MMG S/O RK 20 11/28/01 L 4 7164 5989 51 MMG OMY RK 0 5 8069 6534 53 MMG OMY RK 0 6 8566 6835 52 MMG OMY RK 0 Minimum ID = 1.920" @ 10802' 7 8964 7081 52 MMG OMY RK 0 TOP OF 2-3/8" LINER 8 9458 7392 50 MMG DMY RK 0 9 9830 7634 48 MMG OMY RK 0 10 10107 7823 46 MMG ED DMY RKEO 0 a-tEM INJ MANDREL C I I STI MO I TVOI DEVI TYÆ I VLV ILATa-t1 FQRfI DATE I I 3-1/2" TBG, 9.3#, L-80, .0087 bpf,lO - 2.992" 11110168178561 49 1 MMG-L TS CIV I RCI-2 I 105/14/951 g ...... 10243' 9-5/8" x 4-1 /2" BKR 0 A<R, 10 = 4.750" I 1 BKRSEAL BORE EXT,ID =4,750" 10247' I ¡.:;..> 1 4-1/2" BKR SEAL ASSY, ID = 3,875" 10259' ý/ I 10280' 3-1/Z' 011S X NP, ID=2.813" 1 PRODUCTION MANDRELS ST MO TVD OEV TYPE VLV LATCH PORT DATE L 12 10353 7979 58 MMG EMPTY 13 10443 B039 60 MMG EQOMY RKP I TOPOF7" LNR 10492' f-- 11II ~ I 10795' 2.70"TIWOEROYtÆNT SLV,IO =2.250" I 10802' TOP OF 2-318" 4.7# LNR, 10 - 1.920" 9-5/8" CSG, 47#, L-BO, 10 = 8.681" 10850' µ ~ PERFORATION SUMIi1ARY 3-1/2" TBG & 7" LI\R MLLOUTWNOOW RB= LOG: SWS MEM:>RY GR/OJL ON 11/18101 I~ 11536' -11542' ANGLEATTOPÆRF: 91 @ 11975' I\bte: Refer to Production DB for historical perf data ~ ~ 11536' WHIPSTOCK I SIZE SPF INTER\! AL OpnlSqz I)ð. TE 1.56" 6 11975 - 12160 0 11/25103 11541' RA TAG 1 1.56" 6 12320 - 12355 0 11/25103 I 1.56" 4 12680 - 12830 0 11/19101 1.56" 4 12870 - 12970 0 11/19101 ~~I 1.56" 4 13120 - 13155 0 11/19101 ~ 1.56" 4 13245 - 13518 0 11/19101 15< 1 PBTO 13649' I 3-1/2" TBG, 9.3#, L-BO, 10 = 2.992" H 11709' .-, I Â ?# 7" LNR. 29#, L-80, D = 6.184" 11848' ~ ~ TO 11891' I 1 2-318" LNR, 4.7#, L-80, .0039 bpf, 10 = 1 ,920" 13715' 1 DATE 06/30/84 11/18/90 11/20/01 12/31/01 06/27/01 08/25/01 REV BY CWTP RNlTP P6'CH COMli1ENTS ORIGINAL COMPLETION LAST WORKOV~ CTDSIŒTRACK IIEW CTO SIDETRACK CORRECTIONS CORRECTIONS I)ð. TE 09/25101 10104101 11107101 11/25103 RBI BY COMtÆNTS I)ð.C PULL PA Ta-t/M:>[Jfd GLM TABLE JBM/KK CMT; XXN PLUG; TBG PlJ'Ja-t OTR/Uh WHPSTOCK & EMTPY GL V IIIc M/TL DO PERFS PRUDI-OEBA Y UNIT WELL: 15-16A PERMIT No: 2011920 AA No: 50-029-21115-01 SEC22, T11N. R14E853' Ff\L & 165' FWL BP Exploration (Alas ka) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl1e\CvrPgs _ Inserts\Microfilm _ Marlœr.doc ) STATE OF ALASKA ) RECE\VEO ALASKA Oil AND GAS CONSERVATION COMMISSION ~R.1J' LOos REPORT OF SUNDRY WELL OPERATIUN~c ns commission MasD 01\ & GaG JO · Stimu'åte D Anchotage OtherD WaiverD Time ExtensionD Re-enter Suspended WellD 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: Repair WellD PluQ PerforationsD Pull TubingD Perforate New PoolO Operation ShutdownD Perforate ŒJ 4. Current Well Class: Development Œ] ExploratoryD 5. Permit to Drill Number: 201-1920 6. API Numbel 50-029-21115-01-00 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 71.00 8. Property Designation: ADL-028307 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: 15-16A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 13715 feet true vertical 8761.8 feet Effective Depth measured 13649 feet true vertical 8760.4 feet Casing CONDUCTOR LINER LINER LINER PRODUCTION SURFACE Perforation depth: Length 80 1044 1293 2920 10825 2469 Plugs (measured) Junk (measured) None None Size 20" 91.5# H-40 7" 29# L-80 3-1/2" 9.3# L-80 2-3/8" 4.7# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 27 107 27.0 107.0 1490 470 10492 - 11536 8091.8 - 8702.4 8160 7020 10243 - 11536 7918.9 - 8702.4 10160 10530 10795 - 13715 8290.7 - 8761.8 11200 11780 25 - 10850 25.0 - 8325.3 6870 4760 26 - 2495 26.0 - 2494.9 4930 2670 Measured depth: 11825 -11900,11975 -12160,12320 -12355,12680 -12830,12870 -12970,13120 -13155,13245 -13518 True vertical depth: 8783.81 - 8779.58,8778.81 - 8773.92,8780.41 - 8780.73,8777.26 - 8763.91,8762.69 - 8761.66,8765.62 - 8767.99 8764.65 - 8759.48 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 3-1/2" 9.3# L-80 @ 24 @ 69 - S('ÞJ>R~Ni=r'~ Apn '1) l" 2005 _ JRlb~'5'g"'~'" n (. J .' Packers & SSSV (type & measured depth): 4-112" Baker D Packer 3-1/2" Camco TRDP-1A SSV @ 10243 @ 2235 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ Oil-Bbl 740 737 Representative Daily AveraQe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 24.7 0 750 26 0 500 Tubing Pressure 360 400 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Garry Catron Garry Catron ß1~ C~ Contact Printed Name Signature DevelopmentŒ) Service D Title Production Technical Assistant Ph~ne 564-4657 ORIGINAL R~ Date 4/15/05 ~f ! ~~ Form 10-404 Revised 4/2004 Page 1 BBLS 142 60/40 Methanal 153 1% KCL 295 TOTAL 02/17/05 MI CTU #9 KILL WELL ...GIH WITH PDS MEMORY LOGGING TOOL ..LOG FROM 12000 -11500 - POH *** CONTINUED ON 2/18/05 WSR *** 02/18/05 Perforate 11850'-11900' 6 SPF 02/19/05 Perforate 11825'-11850' 6 SPF FLUIDS PUMPED 15-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ) ) ._ .T~E.E =.,. 4-1/16" FMC GEN 3 ) WELLHEAD = FMC A'(STUÄ rÖ'Ff;' 'Ä'xt~Cs'öt\i KB. ELEV = 71.0' .""",,,,,,,,,,,,.,,,,,,,.,,..,,,,.,,. " BF. ELEV = NA KÔP ';'~~~'~_H'__.H3ÕÕcŸ "",.",.,,,,..,,,,,,,,,..,,,,,.,,,.,.,...,.,. . "",,,,....,.,,,.,.,,,,,,,.,,.,,,,,.,.,. Max~~gle = 98 @ 1278:' Datum MD = Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 1---1 2495' Minimum ID = 1.920" @ 10802' TOP OF 2-3/8" LIN ER I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" BKR SEAL BORE EXT, ID = 4.750" 1-1 10247' 4-1/2" BKR SEAL ASSY, ID = 3.875" 1---1 10259' 15-16A \ l SAFETYNOT")KNOWN LEAK@ GLM #13 -10443' (PATCH PULLED 08/2.;,,,/1). WELL ANGLE> 70° @ 11700' & > 90° @ 11763'. CMT STRINGERS F/13524 - 13649 NOTED X CTD. 69' 1---1 4-1/2" x 3-1/2" TBG XO, ID = 2.992" 1 2235' 1-1 3-1/2" CAMCO TRDP-1A TRSSSV, ID = 2.812" GAS LIFT MANDRELS DEV TYPE VLV LATCH 7 MMG DOME RK 42 MMG DMY RK 50 MMG S/O RK 51 MMG DMY RK 53 MMG DMY RK 52 MMG DMY RK 52 MMG DMY RK 50 MMG DMY RK 48 MMG DMY RK 46 MMG EQ DMY RKED CHEM INJ MA NDREL 1ST MD TVD DEV TYPE VLV LATCH 11 10168 7856 49 MMG-L TS CIV RCI-2 ~ 'IP ~ ST MD TVD 1 2854 2853 ~ 2 4364 4235 3 5920 5230 4 7164 5989 L 5 8069 6534 6 8566 6835 7 8964 7081 8 9458 7392 9 9830 7634 10 10107 7823 PORT DATE 16 11/28/01 o OS/21/95 20 11/28/01 o o o o o o o C L PORT DATE 05/14/95 ~ r~ 10243' 1---1 9-5/8" x 4-1/2" BKR D PKR. ID = 4,750" 10280' 1---1 3-1/2" OTIS X NIP, ID = 2.813" 1 L PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 10353 7979 58 MMG EMPTY 13 10443 8039 60 MMG EQ DMY RKP I TOP OF 7" LNR 1---1 10492' h 9-5/8" CSG, 47#, L-80, ID = 8.681" 1---1 10850' ~ PERFORA TION SUMMA RY REF LOG: SWS MEMORY GR/CNL ON 11/18/01 A NGLE AT TOP PERF: 95 @ 11825' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1.56" 6 11825 - 11900 0 02/18/05 1.56" 6 11975-12160 0 11/25/03 1.56" 6 12320 - 12355 0 11/25/03 1.56" 4 12680-12830 0 11/19/01 1.56" 4 12870 - 12970 0 11/19/01 1.56" 4 13120 - 13155 0 11/19/01 1.56" 4 13245-13518 0 11/19/01 3-1/2" TBG, 9.3#, L-80, ID = 2.992" 1---1 11709' 1 7" LNR, 29#, L-80, ID = 6.184" 1---1 11848' I TD 1---1 11891 ' DATE 06/30/84 11/18/90 11/20/01 12/31/01 08/25/01 09/25/01 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER CTD SIDETRACK NEW CTD SIDETRACK CORRECTIONS PULL PA TCH/MOD'fd GLMs CHlTP PE/CH DAC Ii t.. 10795' 1---1 2.70" TIW DEPLOYMENT SLY, ID = 2.250" 10802' 1---1 TOP OF 2-3/8" 4.7# LNR. ID = 1.920" 1 3-1/2" TBG & 7" LNR MILLOUTWINDOW ~ 11536'-11542' I 11536' 1---1 WHIPSTOCK 1 i 11541' 1---1 RA TAG 1 I PBTD 1---1 13649' 1 I 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.920" 1---1 13715' I DATE 10/04/01 11/07/01 11/25/03 03/05/05 REV BY COMMENTS JBM/KK CMT; XXN PLUG; TBG PUNCH DTR/TLH WHIPSTOCK & EMTPY GL V BJMcM/TLP ADD PERFS JLG/TLH ADD PERFS PRUDHOE BA Y UNrT WELL: 15-16A PERMrT No: 2011920 API No: 50-029-21115-01 SEC 22, T11 N, R14E 853' FNL & 165' FWL BP Exploration (Alaska) ( l -{ &01 '-lq ~ WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 71t>Street Suite # 700 Anchorage. Alaska 99501 RE: Distribution - Final Print(sJ 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 1 1 1 Res. Eva!. CH 1 1 1 OS 15-16A 11-23-03 Mech. CH 1 I,!.:J ~. (();~ . - - Caliper Survey Signed: ~ \~~ ;£) ~<t' ~ Date: Print Name: RECE.IVED 1 tl ì.1 2 (: 2004 "-'; 1; a J nëdaska Oil & Gas Cons. Commilian PROACTivE DiAGNOSTic SERvicES, INC., PO Box 1 ~69 STAFFo~Ø77 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~i'~~ ;t ð DL(; DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Sp~ II ff\)ú ^-ó"t ( Permit to Drill 2011920 Well Name/No. PRUDHOE BAY UNIT 15-16A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21115-01-00 MD 13715 r 1VD 8762 "'" Completion Date 11/19/2001 /' Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No ----- DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: Log/ Data TYRe rÉo i ~ i Electr Digital Dataset Med/Frmt Number D ....-10813 Name Log Log Run Scale Media No 1 1 Interval OH / Start Stop CH Received 11516 13715 Open 5/6/2002 10600 13521 Case 1/11/2002 Comments C -- 10553 1 I I I ¡ i -------' Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y I N Daily History Received? Y/N ÐN Chips Received? Y/N Formation Tops ~- Analysis Received? Y/N -- - t.--' K.. 'IS "'- t"'\- \ Comments: ~ ~ ~ "'- \ ./ ' (; 'R (W'\,Vo..J ~ M 1) ~ 1ft. "fI\ \.)i ~ '\ V -Þ M. CN f.-jcc'-- \.ß ~~ ~~ \ Compliance Reviewed By: ~ ----- Date: => \) ~ ^-- tt-\j "'> 01/10/02 ScbltnÞlpger NO. 1711 Alaska Data & ConsulUng Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska 011 & Gas Cons Comm Aftn: LIsa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay -- Well Job # Log DescripUon Date Blueline Sepia Color Prints CD Ì!Ii L 1-09 /95-001 LEAK DETECTION LOG 12/05/01 1 1 , W-37 ,"RR - Cff C-j LEAK DETECTION LOG 12/25/01 1 1 " D.S. 1-D6A ,11 '5~~tì ~ PRODUCTION PROFILE 12/22/01 1 1 I D.S. 3-20A I {,¡ ~ -r )t.f ï PROD PROFILE W/DEFT 12/11/01 1 1 t D.S. 18-34 IC '? -I f.ð t.J LEAK DETECTION LOG 07/07/01 1 1 ~ D.S.2-13A J~ L-/~ S 22007 SCMT 12/21/01 2 . E-15B , J~Gj -Oq~- 99328 RST-BORAX 08/08/99 1 1 1 , H-04 > í/--Q:J. ~ 21525 RST-SIGMA 12/07101 1 1 1 . J-12 (REDO) / --- --¡ 21409 RST-SIGMA 09/05/01 1 1 1 ¡([ )-() I ' M-12A d{~ ~ '} -{ C; I 20517 MCNL 12/15100 1 1 1 - H-22AL1 °, 21526 RST -SIGMA 12/08/01 1 1 1 , D.S.15-16A ð{ OJ -( '1 ~ 21506 MCNL 11/18/01 1 1 1 .... I I -,~::> P1 1... -1 /{ ~" ", 1- } t1 S-;:,) }/ . ;' £' - ..--~, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie ~/) r Received -'. . l.J.J~ Date Delivered: 1/\Ì'1 11 200. 2 VI... A1ika œ & Gas Cons. Commission AnåJorage ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well !HI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface "':"-'-"'-< ~ ,"" ...., 854' SNL, 165' EWL, SEC. 22, T11 N, R14E, UM 'i) ,. , l<Y(:A TìOì.iS At top of productive interval ; _ll:I7...:.Ç'i ! \'¿'~'If-¡:::,:') , 3991' NSL, 4059' EWL, SEC. 15, T11N, R14E, UM' ':JLY:::-,:~,_. t'..~"",:..,,:,,-~, , . ~ At total depth ~ ,.-.--,£P...., : ~ , ~ 2683' NSL, 62' EWL, SEC. 14, T11 N, R14E, UM >.'. .,. "" '0. .:.,~-=-::_-..::j 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 71' ADL 028307 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.t$!Jsp., or Aband. 11/11/2001 11/16/2001 11/~2001 ,it> 17. Total Depth (MD+ 1VD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 13715 8762 FT 13649 8760 FT !HI Yes 0 No 22. Type Electric or Other Logs Run GR, ROP, PWD, MEMORY CNL, CCL 23. CASING SIZE 20" 13-3/8" 9-5/8" Classification of Service Well 7. Permit Number 201-192 8. API Number 50-029-21115-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 15-16A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2235' MD 1900' (Approx.) 7" GRADE H-40 L-80 L-80 L-80 L-80 WT. PER FT. 91.5# 72# 47# 29# 4.6# ASING, LINER AND EMENTING ECORD ETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 80' 30" 1910# Poleset Surface 2495' 17-1/2" 1900 sx Permafrost 'E', 400 sx PF 'C' Surface 10850' 12-1/4" 00 sx Class 'G' 300 sx PF 'C' 10496' 11536" 8-1/2" 80 sx Class 'G' 10795' 13715' 3" 8 sx Class 'G' AMOUNT PUllED 2-3/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 1.56" Gun Diameter, 4 spf MD TVD 12680' - 12830' 8777' - 8764' 12870' - 12970' 8763' - 8762' 13120' - 13155' 8766' - 8768' 13245' - 13518' 8765' - 8759' 25. SIZE 3-1/2",9.3#, L-80 TUBING RECORD DEPTH SET (MD) 11536" PACKER SET (MD) 10243' MD TVD (Top of Window) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 50/50 Glycol 27. Date First Production December 1, 2001 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oil -BBl GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO OIL-Bel GAs-McF WATER-BBl Oil GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECE~VED JAÑ 1 1 2002 \1 1 ~BnMS BFl Alaska Oil & Gas Cons. CommissiŒii Form 10-407 Rev. 07-01-80 .1!\,,~I, ?., 4 2 Submit In Duplicate ~r:!' I -002 (J- ~" ,- ( ( 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Zone 1 B 11606' 8738' 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. ECE':'~\! ,'~E'."'~D'~'.~ , "I I"""", .JAN 1 J 2002 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ Title Technical Assistant Date 0 ( . I 0 .0 15-16A Well Number 201-192 Permit No. I A roval No. Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB. etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/9/2001 11/10/2001 ( ( BP EXPLORATION Operations Summary Report 1 5-16 15-16A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 00:00 - 01 :00 01 :00 - 02:30 02:30 - 06:30 06:30 - 07:00 07:00 - 09:45 09:45 -10:15 10:15-10:35 10:35 - 11:45 11 :45 - 12:00 12:00 -12:25 12:25 -12:35 12:35 - 13:00 13:00 -14:45 14:45 - 14:50 14:50 -15:05 15:05 -15:45 15:45 - 20:00 20:00 - 00:00 00:00 - 01 :10 01:10-03:00 03:00 - 03:30 03:30 - 04:50 04:50 - 05:00 05:00 - 05:30 05:30 - 06:20 06:20 - 06:30 06:30 - 06:40 06:40 - 08:30 1.00 MOB 1.50 RIGU P P 4.00 RIGU 0.50 RIGU P P 2.75 RIGU P 0.50 STWHIP P 0.33 STWHIP P 1.17 STWHIP P 0.25 STWHIP P 0.42 STWHIP P 0.17 STWHIP P 0.42 STWHIP P 1.75 STWHIP P 0.08 STWHIP P 0.25 STWHIP P 0.67 STWHIP P 4.25 STWHIP P 4.00 STWHIP P 1.17 STWHIP P 1.83 STWHIP P 0.50 STWHIP P 1.33 STWHIP P 0.17 STWHIPP 0.50 STWHIP P 0.83 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 1.83 STWHIP P Phase PRE PRE PRE PRE PRE WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Page 1 of 9 Start: 10/19/2001 Rig Release: Rig Number: Spud Date: 11/19/2001 End: Description of Operations Continue move from 15-32A. Accept rig at 0100 hrs 11/9101. ND tree cap. Nipple up BOP stack. Pressure test BOP stack. Witness waived by AOGCC. Standby while DSM crew moves green tank out, builds dike, moves green tank back in place. Resume pressure testing. DSM dike spot and dike flowback tank. RU hardline and PT PU BHA components, MWD collars, motor, etc. Safety meeting prior to making up milling BHA. Shut lateral valve, open wing, bleed off trapped FL pressure of 450 psi. SI wing. MU BHA #1, Special HC longer gauge window mill SN 0324862, with WF fixed 2.5 deg motor. MU injecter. RIH for shallow hole test. Tag up at SSSV several times dry. Check, that it is locked out. Kick on pumps to 0.9 bpm, catch fluid, ran through ok. Shallow hole test of MWD and orienter. Got 2 clicks on second orienting attempt. Continue RIH. Note - S riser remaining at 0 psi. Lateral valve is holding. tagged x nipple, bounced thru it wlo using pumps. Up weight prior to tagging=28 klbs. Tag at 11555', correct to 11536', top of whipstock. Kick on pumps. Found TF = 0 deg. Orient around to 140R. RIH, Tag again at 11535' pumps on, add 1 more foot. Top of whipstock=11536', getting 30 deg reactive. PU orient to 165L. Free spin=21 00 psi @ 1.7 bpm. RIH, start milling at top of whipstock 11536'. Paint flag. TF173L. Mill, keeping WOB less than 2500 psi. Mill to 11538'. Pump 5 bbl bio sweep. Pull up l' to 11537', start time milling as per procedure. Continue time milling at 1'/hr. 11538.5' 5k wtllittle diff/160L, 11540.0' 8k/50 psi/170L, 11541.0' 8. 7k/1 00 psi/170L, 11541.7'/8.6k/300 psi/177L, 11542.1'/7.8k/550/173L, 11542.2'/4.8k/0/143L. Assume exit at 11542.1 ' Millidrill formation from 11542.1' wi 50 psi diff at 8-11K wt 146L to about 11546' actual, 11547.8' stacked. Pump sweep, backream, clean POOH for tapered mill. See flag at 11536.0' Change motor/mills. This was a good mill! Hard to tell that it was even used! MU 1.75 deg motor and 2.80" WF tapered mill RIH wi BHA #2 Fire drill-simulated fire in mud mixing room, discuss Resume RIH Tag at 11553' CTD. PUH 27k, start pump, toggle MWD several times, get TF 1 L. Orient to 173R Tag again wi pump on before flag (at 11536.5' this BHA). SD pump and measure. Corr to 11532.5' Orient around to 170R. Begin milling at top of window. Attempt to mill for 2 hours. Many multiple stalls with no progress at all. Trip for a cutrite only version of the crayola mill. Printed: 11/27/2001 4:14:04 PM ( ,: BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: 1 5-16 Common Well Name: 1 5-16A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 10/19/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/10/2001 08:30 -10:15 1.75 STWHIP P WEXIT POOH with milling BHA #2 (Crayola mill). 10:15 - 10:45 0.50 STWHIP P WEXIT Tag up at surface, mechanical depth counter on depth to electrical. Stand back injector, break out Crayola mill #1, make up crayola mill #2, 2.80" cutrite crayola mill, with no MM buttons. 10:45 - 12:45 2.00 STWHIP P WEXIT RIH with BHA #3. Phz 1 12:45 - 12:55 0.17 STWHIP P WEXIT Dry tag, pick up kick pumps on. Flag appears significantly off depth. Assume new coil stretch. Call tag top of whipstock. Orient to 178R, RIH tag again, make a -8' correction. Set depth to tag at top of whipstock at 11536'. 12:55 -17:15 4.33 STWHIP P WEXIT Begin milling at top of window at 11536'. 1.5/1.3/2020 psi. Getting 400# motor work at 11536' plus lots of stalls. Watch pits for 1/2 hour, no loss in level. Out micro motion is off by about 0.2 bpm. Good work at top of window at 11536' down to 11538.7, Drilling break at 11538.7', easy ROP to bottom of window at 11542'. Numerous stalls at 11543'. 17:15 - 18:10 0.92 STWHIP P WEXIT Hard milling at bottom of window. Seeing a lip at 11543'. Trying to mill at bottom of window. (Possibly TD?) 18:10 -18:40 0.50 STWHIP P WEXIT Make tie in pass down to confirm depth. Log down from 11390' at 60 fph. 18:40 -19:40 1.00 STWHIP P WEXIT No corr. RIH. Ream 11532-44' 1.7/2400/180R, clean. See flag at 11541.4'. Backream same, pump sweep Reream at 165L, clean. Backream at 140L, clean 19:40 - 20:10 0.50 STWHIP P WEXIT Orient around 20:10 - 20:35 0.42 STWHIP P WEXIT Ream at 137R, clean. Ream at 140R, clean. Dry tag, clean. Flag still at 11541.4'. Flag at 11400' EOP 20:35 - 22:10 1.58 STWHIP P WEXIT POOH for drlg assy 22:10 - 22:35 0.42 STWHIP P WEXIT LD milling BHA. Mill was 2.78". Phz 2 22:35 - 23:20 0.75 DRILL P PROD1 MU drilling BHA 23:20 - 00:00 0.67 DRILL P PROD1 RIH wi BHA #4 (1.83 deg motor) 11/11/2001 00:00 - 01 :40 1.67 DRILL P PROD1 Continue RIH. Phz 1. Mud swap trucks held up to convoy 01 :40 - 01 :55 0.25 DRILL P PROD1 Corr at flag -16.8' at 11476'. Chk TF 40R. Orient to low side 01 :55 - 02:30 0.58 DRILL P PROD1 RIH at 144R, clean to tag at 11543.8'. Drilliream (not much room to work) 1.7 12300/136R to 11548' 02:30 - 02:50 0.33 DRILL P PROD1 Orient to drilling TF. Back to normal driving conditions 02:50 - 03:50 1.00 DRILL P PROD1 Drilling in a shale 1.7/2300/70R. See RA tag and corr +2' 03:50 - 04:35 0.75 DRILL P PROD1 Swap to usedlnew Flo Pro mud. Drill to 11572' 1.6/3430/70R 04:35 - 05:05 0.50 DRILL P PROD1 Orient to high side Lost 5 deg wi low side exit that wasn't factored into revised plan. Need to drill high side to catch up build which will delay turn and make it wider. No problem wi geo. Alt plan would be to trip for larger motor which would incr DLS 05:05 - 06:30 1.42 DRILL P PROD1 Drilling painfully slow from 11572' 1.6/3350/1 OR, 1.8/3800 06:30 - 08:15 1.75 DRILL P PROD1 11583', drilling build section. 1.6 inlout. 193 bbls in pits. Free spin 3100 psi at 1.5 bpm. Drilling at 3600 psi. 20 fph. 08:15 - 09:00 0.75 DRILL P PROD1 11600', continue to drill build section slowly. ROP slow, less than 20 fph. S riser pressured up to 375 psi between wing and lateral valve. Bleed off to slop oil trailor. 09:00 - 10:45 1.75 DRILL P PROD1 11605', hard drilling, not making any ROP, difficult holding tool face, but still getting good stalls on motor. POOH to examine bit and motor. 10:45 - 11: 15 0.50 DRILL P PROD1 Tag up at surface. Stand back injecter. No damage at all to Hughes bi centered bit. Suspect weak motor. Change out Printed: 11/27/2001 4:14:04 PM (" (' BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: 1 5-16 Common Well Name: 1 5-16A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 10/19/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/11/2001 10:45 - 11: 15 0.50 DRILL P PROD1 motor. Pick up used DPI bi centered bit. 11: 15 - 11 :30 0.25 DRILL P PROD1 RIH with BHA#5 11:30 -12:00 0.50 DRILL P PROD1 Fire and rig evacuation drill. 12:00 -13:40 1.67 DRILL P PROD1 Continue to RIH with BHA #5. 13:40 - 14:30 0.83 DRILL P PROD1 Kick pumps on 1.7 bpm, 3550 free spin, 100% returns, TF found at 130L, Tag bottom, make -15' correction. Orient around. 14:30 -17:30 3.00 DRILL P PROD1 11605', resume drilling. Still on a hard streak. Getting lots of stalls, low Rap. 17:30 -18:15 0.75 DRILL P PROD1 11615', Difficult drilling. 1.6/1.6, 3500 psi. Very very low Rap. Seeing some pyrite in cuttings, little chert. Geo says formation should be drilling easily, and pyrite should not be an issue??? Continue to pound away. Got to be something wrong. 18:15 - 19:25 1.17 DRILL P PROD1 1.3/2950, 1.413050, 1.5/3300, 1.6/3500/70R Drill to 11621' 19:25 - 20:05 0.67 DRILL P PROD1 Orient around 20:05 - 20:55 0.83 DRILL P PROD1 Drill miserably slow to 11627.7' and had numerous stalls and not getting good surveys 20:55 - 22:35 1.67 DRILL P PROD1 Wiper to window. POOH for bit 22:35 - 00:00 1.42 DRILL P PROD1 Bit okay, PT BHA okay. Change bit, open MWD restrictor, orientor 11/12/2001 00:00 - 02:15 2.25 DRILL P PROD1 RIH wi BHA #6 Hughes Bi center bit. 02:15 - 02:25 0.17 DRILL P PROD1 Corr -15' at 11515'. Start pump, chk TF @ 71 L 02:25 - 03:00 0.58 DRILL P PROD1 RIH thru window at 71 L, clean. Precautionary ream to TD. Tag TD at 11627.7' Drill a foot at 40'/hr wi 3K extra string wt. 1.6/3350/143R. PUH to orient and plugged something in BHA. Try to unplug-nope 03:00 - 04:40 1.67 DRILL N DFAL PROD1 POOH to chk BHA. See flag at 11550' this BHA 04:40 - 05:30 0.83 DRILL N DFAL PROD1 Motor was hard to turn by hand. Send in for inspection. Adjust prior motor to 2.12 deg bend 05:30 - 07:55 2.42 DRILL N DFAL PROD1 RIH wi BHA #7. SHT 1.6/2600. Make -15' correction at 11500', based on depth correction made on last run. Continue RIH, made it thru window with not a bobble. Tag bottom, make an additional -4' depth correction. 07:55 - 08:20 0.42 DRILL N DFAL PROD1 Orient to 90R 08:20 - 08:30 0.17 DRILL P PROD1 11628', Resume drilling, Free spin 3200 psi, 1.5 inlout. (Out MM still reading 0.2 bpm light, pits say no losses), Drilling with new 25 klsrv mud. Making 60 fph. TF 90L by mistake (MWD not sync'd right), drilled great for 8'. 08:30 - 08:40 0.17 DRILL P PROD1 11635', Need to orient to 90R, PU, orient around. 08:40 - 09:20 0.67 DRILL P PROD1 Resume drilling, 80 fph, TF 95R. 1.6/1.6 3500 psi drilling, 300 psi motor work. 09:20 - 09:35 0.25 DRILL P PROD1 11690', orient around to 30R. 09:35 - 10:00 0.42 DRILL P PROD1 Resume drilling. 10:00 -12:00 2.00 DRILL P PROD1 11706', As soon as ROP took off, dog legs dropped to 10 deg/100'. can not land well with current motor. POOH. Discuss with DD and Geo best plan forward. Motor was drilling fine as of start of trip. Tripping for bigger bend motor and PDC bit. 12:00 - 12:45 0.75 DRILL P PROD1 Adjust motor to 2.6 deg, pickup DPI PDC bit. (Non bicentered). 12:45 - 15:00 2.25 DRILL P PROD1 RIH with BHA #8. 15:00 -15:25 0.42 DRILL P PROD1 Tag TD for tie in. Make -22' depth correction. Set depth to 11706', orient to 0 deg. 15:25 -15:30 0.08 DRILL P PROD1 11706', resume drilling. 3200 psi free spin, 1.5 in/out, TF 60R, Printed: 11/27/2001 4:14:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/12/2001 11/13/2001 ( ( BP EXPLORATION Operations Summary Report 15-16 15-16A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 15:25 - 15:30 15:30 -15:50 15:50 -17:45 17:45 - 19:40 19:40 - 20:45 20:45 - 23:00 23:00 - 23:20 23:20 - 23:50 23:50 - 00:00 00:00 - 01 :50 01:50-02:10 02:10 - 02:45 02:45 - 03:05 03:05 - 03:20 03:20 - 04:10 04:10 - 04:40 04:40 - 05:00 05:00 - 05:15 05:15 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 08:20 08:20 - 08:50 08:50 - 09:45 09:45 -11:15 11:15 -12:15 12:15 -12:20 12:20 - 12:30 12:30 - 13:45 13:45 - 14:45 14:45 -17:00 17:00 -17:40 17:40 -18:15 18:15 -19:00 0.08 DRILL 0.33 DRILL 1.92 DRILL 1.92 DRILL 1.08 DRILL 2.25 DRILL 0.33 DRILL 0.50 DRILL 0.17 DRILL 1.83 DRILL 0.33 DRILL 0.58 DRILL 0.33 DRILL 0.25 DRILL 0.83 DRILL 0.50 DRILL 0.33 DRILL 0.25 DRILL 0.25 DRILL 0.50 DRILL 0.50 DRILL 1.50 DRILL 0.33 DRILL 0.50 DRILL 0.92 DRILL 1.50 DRILL 1.00 DRILL 0.08 DRILL 0.17 DRILL 1.25 DRILL 1.00 DRILL 2.25 DRILL 0.67 DRILL 0.58 DRILL 0.75 DRILL P p p P P P P P P P P p P P P N P N P N P P P P p p P P P P p P p P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 STUC PROD1 PROD1 STUC PROD1 PROD1 STUC PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 4 of 9 Start: 10/19/2001 Rig Release: Rig Number: Spud Date: 11/19/2001 End: Description of Operations 3500 psi drilling pressure, 110 fph ROP. Life is good again. Need to orient around to high side. Orient around to 30R Resume drilling. TF=12R, 130 fph. Good drilling. DL= 43 deg in build, in turn we are getting 35 D/100. Should be able to land well easily. Build and turn completed, Landed well at 8709' 1VD, 8735'=estimated depth of Kavik shale. We are in good shape. 11,900' POOH for lateral section BHA. Change motor, bit, MHA, MWD probe. Change out reel swivel and PT. RIH wi BHA #9 (0.91 deg motor) Corr -15' at 11515'. RIH thru window, clean. Precautionary ream to TD, clean Tag TD at 11903' CTD and corr to 11900'. Get MWD Nsync and TF at 90L. Orient around to right 1.6/3450 Drilling from 11900-910' 1.6/3450/80R Drill from 11910-12050' 1.5/3150, 1.6/3350/90R at 90 deg avg Wiper to window Log tie-in from 11570', add 10.0' RIH to TD and tag at 12058' Orient to left side Drill from 12058-12171' 1.6/3340/140L Diff stuck CT @ 12171'. Wiper to 12000'. Lost TF when back to TD and tagged 6' early Wiper to window, Clean trip. Log up from 11565', add 5.0' RIH to TD and tagged at 12175' Orient around from 60L Drill from 12175- 1.6/3330/130L 12244', Drilling ahead at good Rap. 1.6/1.6 Getting lots of reactive. May be crossing a fault. Possible fault at 12235', no losses observed. Orienting. 12315', Resume drilling. Making mud swap to 25k LSRV mud. 12350', New mud to bit, short trip to shoe. New mud to bit, not to surface yet. Free spin 2950 at 1.6 bpm. No losses. Free spin prior to start of mud swap was 3200 psi. Seems to have dropped some. 12500', wiper trip to shoe. Resume drilling. Orient to 130R Resume drilling. 1.6 in/out. Drilling at 130 fph, 140 TF 12623', heavy pickup, so lets make a wiper trip to the shoe. SWS wanted to stop to fix problem with reel at 12360'. Stopped for 5 minutes. Mistake. Very heavy pickup afterwords. Pulled max to get free. Won't do that again. Continue wiper trip to shoe. Resume drilling. 1.7 11.7 bpm, 3350 psi, 90R TF. Drilled to 12,707 ft. Very sticky hole. Stack wt while RIH off bottom. Wiper trip to window. Log Tie-in at RA marker. Added 21 ft CTD. RIH to TD. tag TD at 12,722 ft. Clean hole while RIH. Printed: 11/27/2001 4:14:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/13/2001 11/14/2001 11/15/2001 ( { Page 5 of 9 BP EXPLORATION Operations Summary Report 1 5-16 1 5-16A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 19:00 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 23:00 23:00 - 00:00 00:00 - 02:15 02:15 - 03:15 03:15 - 04:00 04:00 - 04:30 04:30 - 05:15 05:15 - 06:45 06:45 - 07:10 07:10 - 08:20 08:20 - 08:40 08:40 - 09:00 09:00 - 10:30 10:30 - 12:45 12:45 - 13:00 13:00 - 17:00 17:00 -17:30 17:30 -19:00 19:00 - 20:00 20:00 - 21 :30 21:30-21:45 21 :45 - 22:30 22:30 - 22:45 22:45 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 05:00 05:00 - 06:00 06:00 - 07:10 07:10 - 07:50 07:50 - 08:15 08:15 - 08:45 08:45 - 10:40 1.00 DRILL 0.50 DRILL 0.50 DRILL 2.00 DRILL 1.00 DRILL 2.25 DRILL 1.00 DRILL 0.75 DRILL 0.50 DRILL 0.75 DRILL 1.50 DRILL 0.42 DRILL 1.17 DRILL 0.33 DRILL 0.33 DRILL 1.50 DRILL 2.25 DRILL 0.25 DRILL 4.00 DRILL 0.50 DRILL 1.50 DRILL 1.00 DRILL 1.50 DRILL 0.25 DRILL 0.75 DRILL 0.25 DRILL 1.25 DRILL 1.50 DRILL 1.50 DRILL 2.00 DRILL 1.00 DRILL 1.17 DRILL 0.67 DRILL 0.42 DRILL 0.50 DRILL 1.92 DRILL Phase P P P N PROD1 PROD1 PROD1 STUC PROD1 N STUC PROD1 N STUC PROD1 N STUC PROD1 P P P P PROD1 PROD1 PROD1 PROD1 P P PROD1 PROD1 P P P P PROD1 PROD1 PROD1 PROD1 P P PROD1 PROD1 P P P PROD1 PROD1 PROD1 P P P PROD1 PROD1 PROD1 P P P PROD1 PROD1 PROD1 P P PROD1 PROD1 P P P PROD1 PROD1 PROD1 P P PROD1 PROD1 P PROD1 Start: 10/19/2001 Rig Release: Rig Number: Spud Date: 11/19/2001 End: Description of Operations Drilling, 1.5 I 1.5 bpm, 3000 psi, TF = 90R. PU off btm several times to orient. Drill to 12810'. PU to orient again. Diff stuck at 12771'. Rest hole. Pull 50-60K and rest hole several times. No movement. Able to orient. Order crude. Unable to get prime from crude transport. Attempt to thaw frozen manifold to charge pump. Unable to off load crude from transport. Order crude on vac truck from Peak. Circulate 10 bbls crude down coil. Spot 5 bbls in OH. Let soak for 5 minutes. Pulled free at 55k#. Short trip to window. Log gr tie in. Add 14'. RIH. Drilling, 1.6 I 1.6 bpm, 3300 psi, 160R TF, 92 deg incl. Drilled to 12,863 ft. Orient TF to 90R. Drilling, 1.6 I 1.6 bpm, 3300 psi, 150R TF, 91 deg incl. Drilled to 12,929 ft. Orient TF. Drilled to 12,952 ft. Stacking wt. Wiper trip to window. Swap to new FloPro. Clean Hole. Drilling, 1.6 I 1.6 bpm, 3200 psi, 130R TF, 91 deg incl. Drilled into shale at 12,972 ft. Drilled to 12,990' Orient to left side. Drilling, 1.6 11.6 bpm, 3200 psi, 120R TF, 89 deg incl. Still drilling shale. Drilled to 13,054 ft. Decide to orient around to lowside to find sand quicker. Orient around. Drilling, 1.7 11.7 bpm, 3300 psi, 150R TF, Drilling, 1.7 11.6 bpm I 3500 psi, 120L. Drill to 13100'. Still in shale. Short trip to just below window (11560') Hole mostly smooth. Orient to 90L. Drilling, 1.6 @ 3300 FS, 90L Wt xfer deteriorating some now that back in shaley section. Orient stright up to try and stay in sand. Drill ahead AT 13175' Drill ahead from 13180'. 1.6 I 3400 fs I 85L. In and out of sand. Target sand appears to be very thin. Drill to 13215'. Drill to 13250'. Wiper trip to window. Had trouble getting back through shales at 12950-13100'. Reduced pump rate helped RIH. Ream from 13200'-13249'. Orient around twice. TF rotated from 150R to 90. Drilling, 1.5 I 1.5 BPM, 3400 psi, 150R TF, 94 deg incl. Drilled to 13286 ft. ROP = 120 fph. Orient around. Dwn wt = 5K, Up wt = 20K Drilling, 1.5 I 1.5 bpm, 3400 psi, 130R TF. Drilled to 13,310 ft. Wiper trip to window. RIH to TD. Hole was clean. Printed: 11/27/2001 4.14:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/15/2001 11/16/2001 11/17/2001 ( (' ... BP EXPLORATION Operations Summary Report 1 5-16 15-16A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 10:40 -11:30 11:30 -14:50 14:50 - 15:40 15:40 -17:15 17:15 - 18:30 18:30 -18:45 18:45 - 20:00 20:00 - 20:45 20:45 - 21 :30 21 :30 - 23:00 23:00 - 23:15 23:15 - 00:00 00:00 - 00:45 00:45 - 01 :00 01:00 - 01:45 01 :45 - 03:00 03:00 - 03:30 03:30 - 05:30 05:30 - 07:45 07:45 -10:15 10:15 -10:20 10:20 - 11 :30 11:30 -13:15 13:15 - 15:30 15:30 - 18:30 18:30 - 20:30 20:30 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 03:45 03:45 - 04:45 0.83 DRILL 3.33 DRILL 0.83 DRILL 1.58 DRILL 1.25 DRILL 0.25 DRILL 1.25 DRILL 0.75 DRILL 0.75 DRILL 1.50 DRILL 0.25 DRILL 0.75 DRILL 0.75 DRILL 0.25 DRILL 0.75 DRILL 1.25 DRILL 0.50 DRILL 2.00 DRILL 2.25 DRILL 2.50 DRILL 0.08 DRILL 1.17 DRILL 1.75 DRILL 2.25 DRILL 3.00 DRILL 2.00 DRILL 2.00 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 2.50 DRILL 0.75 DRILL 1.00 DRILL P P p P P P P P p P P P P p P P P P P P P p P P P P P P p P N P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DPRB PROD1 PROD1 PROD1 Page 6 of 9 Start: 10/19/2001 Rig Release: Rig Number: Spud Date: 11/19/2001 End: Description of Operations Orient around Drilling, 1.5 I 1.5 bpm, 3400 psi, 150R TF, Stacking wt. Slow Drilling. Drilled to 13,420 ft. 90 deg. incl. Stacking wt. Wiper trip to window. Clean hole. Log GR tie-in to RA marker. Added 66 ft to CTD. Serious slippage occured at some point during trips or drilling. Tightened measuring wheel and greased it. RIH to TD. Tag TD at 13,475 ft. Will log GR up 12,800 ft at start of next wiper trip. Swapped over to new FloPro. Sent 300 bbls old FloPro to MI for storage. Orient TF to 120L Drill ahead, 1.7 I 3300 fs I 11 OL. Tough drilling at 13496'. Having trouble getting mwd in sync. Cycle pumps, etc. Lost orientation while working mwd. Orient to 120R Drill ahead. 120R. In sand. ROP: 80-100 fph. Drill to 13557'. Orient to 100L. Drill ahead 13560'. Drill ahead to 13574'. Appear to be back in shale. Orient to 40L to climb. Drill ahead to 13605'. 1.6 I 3300 fs Short trip to window. Hole smooth. Log gr tie-in. MWD quit (past expected battery life) Circulate OOH for BHA. At surface. Change out BHA. Add PWD sub. M/U New 0.8 deg motor, re-run bit, M/U new Orienter, new MWD with memory GR and PWD. MIU new MHA. RIH with MWD BHA #10. 0.8 deg motor and MWD / PWD sub. Shallow test OK. RIH. SAFETY, Performed kick while trip drill, while RIH. Log Tie-in at window, -5 ft CTD. Log PWD info at window. 10 minlO bpm, 5 min/1.4 bpm, 5 min/1.6 bpm, 5 min/1.8 bpm. RIH to TD. Ream shales 13080 - 13220 ft. RIH. Stack out at 13582 ft. Ream shale to 13590 ft. RIH and tag TD at 13,614 ft BKB. Drilling, 1.5 11.5 bpm, 3100 psi, TF = 55L, Incl = 90 deg. 15 fph, drilling shale. Stacking wt. Drilled to 13,653 ft. Drilling, 1.6 11.6 bpm, 3300 psi, TF = OL, Incl = 91 deg. 10 fph, drilling shale, Stacking Wt. Drilled to 13,678 ft. Drilling, 1.4 I 1.4, 3300 psi fs, tf:HS 10 fph, drilling shaley sand. Drill to 13714'. HS tf, but angle dropping. Short trip to window & wait on 100 bbls new mud. Will circ mud to see if wt transfer improves, but suspect we are at TD. Sticky section at 13130'. Log gr tie in from 11571'. Add 4' correction. RIH. Tag corrected TD at 13715'. On btm with new mud. Cannot make it drill. Call TD at 13715' (corrected) Log gr from TD to 12800', to fill in big gaps incurred due to counter wheel slipage. Log at 350 FPH. RIH to spot new mud in OH. POOH 1:1 Lay in new FloPro wi 5% lubtex Printed: 11/27/2001 4:14:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date (' ( - BP EXPLORATION Operations Summary Report 1 5-16 1 5-16A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 11/17/2001 04:45 - 06:30 06:30 - 07:30 07:30 - 07:45 07:45 - 09:30 09:30 - 10:00 10:00 -11:15 11: 15 - 11 :20 11:20-12:30 12:30 - 14:00 14:00 - 15:10 15:10 -16:30 16:30 - 18:00 18:00 -18:45 18:45 -19:00 19:00 - 20:00 20:00 - 21 :30 21 :30 - 22:30 22:30 - 00:00 1.75 DRILL 1.00 DRILL P P 0.25 CASE P 1.75 CASE P 0.50 CASE 1.25 CASE 0.08 CASE 1.17 CASE P P P P 1.50 CASE P 1.17 CASE P 1.33 CASE P 1.50 CASE P 0.75 CASE 0.25 CASE P P 1.00 CASE P 1.50 CASE N 1.00 CASE P 1.50 CASE P Phase PROD1 PROD1 CaMP CaMP CaMP CaMP CaMP CaMP COMP COMP CaMP COMP CaMP CaMP CaMP DFAL CaMP CaMP CaMP Page 7 of 9 Start: 10/19/2001 Rig Release: Rig Number: Spud Date: 11/19/2001 End: Description of Operations Circulate COHo Flag EOP at 8650' UO BHI MWD and PWD, motor and bit. Bit still in good condition [1-1-1]. SAFETY MEETING. Review liner running hazards and procedures. M/U 2 3/8", 4.6#, L-80, STL liner with TIW float equipment. M/U 45 jts. Fill liner with water. M/U total of 89 jts, 2 3/8" liner with 1 ten ft pup jt. SAFETY: Held kick drill, stabbed TIW valve in 15 sec. M/U TIW deployment sleeve and liner running tools with liner wiper plug. Liner total length = 2,918.28 ft. RIH with liner on CT. circ at 0.2 bpm at 1500 psi while RIH at 90 fpm. Stop at 11,525 ft. Up Wt = 25.5 K, Own Wt. = 12K at 0.2 bpm. RIH to flag at 11,600 ft. Correct to 11,580 ft. [-20 ft.]. RIH at 50 fpm, circ at 0.2 bpm.. Sat down at 13,080,13180,13190,13233,13360,13450, 13490,13520,13550,13600,13630,13660,13690,13711 ft. Land liner at CTD of 13,711 ft. Sat down 4 times at same depth. Corrected liner TD at 13,715 ft BKB. Insert 5/8" steel ball and displace with FloPro. 0.9 bpm, 2900 psi, 0.7 bpm returns. 20% fluid loss with FloPro. Slow to 0.5 bpm, full returns at 30 bbls. Ball on seat at 42.6 bbls. Press to 2800, 3100, 3400, 3800 psi, Sheared at 3800 psi. Picked up, liner was free. Stack 9K back on liner. Clean pits, Circulate well to 2% KCL slick water [triple slick]. Pump 1.2 bpm with 1.1 bpm returns at 2200 psi with slick water around shoe. pump 1.4 bpm I 1.2 bpm at 2400 psi. Batch 20 bbls Class G, latex, 15.8 ppg cement. Hold pre job safety mtg. Discuss contingencies, wash up, pump schedules, safety. Pump 3 bbls water. Test lines to 4000 psi. Pump 19 bbls Class G cmt. Shut down and load dart. Displace 1 bbl kcl. Check dart away. Continue displacement at 1.5 bpm 12500 psi. 1.2 bpm out. Slow rate to 0.7 in / 0.5 out at 2900 psi. Dart bumped at 41.4 bbls, and sheared at 2400 psi, pumping at 0.5 bpm. Continue displacement at 0.5 in/O.4 out. Calc displacement: 52.5. Plug did not bump at 53.5 bbls. CIP at 2000 hrs. Attempt to POOH. Unable to get off liner. Pull max to 70k# up wt. Cycle pipe. No effect. Free point indicates probably stuck at top of liner. Pump down coil to attempt to circ cement OOH. Plug landed at 55.2 bbls. Pressure up coil & liner to 4500 psi. Cycle pipe. Popped free. (Whew! ) Pump flo vis pill down hole to help contaminate any cement falling into liner. Wash liner top area with same. 1: 1 rtns while circulating Circulate OOH. Printed: 11/27/2001 4:14:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/18/2001 11/19/2001 11/20/2001 (' (' BP EXPLORATION Operatio,ns Summary Report 1 5-16 15-16A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 07:45 07:45 - 08:00 08:00 - 10:45 10:45 - 12:15 12:15 -14:30 14:30 - 16:30 16:30 - 17:30 17:30 - 19:15 19:15 - 19:45 19:45 - 21:00 21:00 - 22:15 22:15 - 22:30 22:30 - 00:00 00:00 - 01 :30 01 :30 - 03:45 03:45 - 05:15 05:15-07:30 07:30 - 07:45 07:45 - 10:00 10:00 - 10:15 10:15 - 13:00 13:00 -18:00 18:00 - 20:00 20:00 - 21 :30 21 :30 - 00:00 00:00 - 02:00 1.00 CASE P 0.50 CASE P 6.25 BOPSUF P 0.25 EVAL P 2.75 EVAL P 1.50 EVAL 2.25 EVAL P P 2.00 EVAL P 1.00 EVAL 1.75 EVAL 0.50 EVAL P P P 1.25 CASE 1.25 EVAL 0.25 PERF P P P 1.50 PERF 1.50 PERF P P 2.25 PERF P 1.50 PERF P 2.25 PERF 0.25 PERF P P 2.25 PERF P 0.25 PERF P 2.75 PERF P 5.00 RUNCO~IP 2.00 RUNCO~IP 1.50 RUNCO~IP 2.50 RIGD P 2.00 RIGD P Phase CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP COMP CaMP CaMP CaMP CaMP COMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP Page 8 of 9 Start: 10/19/2001 Rig Release: Rig Number: Spud Date: 11/19/2001 End: Description of Operations POOH with liner running tools. Set back injector. LD TIW tools. Weekly test of BOPs. Witness waived by C. Scheve, AOGCC. Send test report to AOGCC. SAFETY MEETING. Review CNUGR logging tool running procedure. MIU SWS Memory CNUGR logging tools and 49 stds, 1" CSH workstring. BHA total length = 3,018 ft. RIH, 0.5 bpm, 500 psi. Log down from 10,600' CTD at 30 FPM. Circ. at 0.8 bpm, 1200 psi. Tag PBTD early at 13,524 ft CTD. Depth not accurate until CNUGR is tied-in. Set down firm four times at 13,524 ft. PBTD by liner tally was 13,648 ft BKB Log up at 30 fpm, Laid in 15 bbls, high viscosity new FloPro for perf pill. POOH. Stand back CSH workstring in doubles. SAFETY MEETING. Review procedure and hazards for laying out CNUGR. Pressure test liner lap with 2,100 psi for 30 min. Held solid. Evaluate CNUGR log. Calibrate micro motion meters. Hold PJSM regarding gun run. MU, handling, pumping schedule etc, safety discussed. MU 38 1-11/16" guns on CSH. Run 49 stands 1" CSH out of derrick. MU connecot. Get on well. RIH with gun assy. Stop at EOP flag at 11433'. Minus 4' correction. Set btm shot at 13520' Circulate 14 bbls flo-vis. Drop 0.5" ball. Displace with KCL water. 1.2 bpm @ 2900 psi. Ball on seat will 42 bbls pumped. Sheared at 3500 psi. Perf intervals: 12680-12830,12870-12970,13120-13155, 13245-13518 FT. 1.56" guns, HSD PJ1606, 4 spf, 60 deg phase POOH with guns. No fluid loss noted. SAFETY MEETING. Review hazards and procedure for laying down singles Lay Out 98 jts of 1" CSH workstring in singles, for derrick down rig move. SAFETY MEETING. Review hazards and procedures to pull fired perf guns. Layout SWS, 1.56" perf guns. All shots fired. Field test Baker completion equipment. Pump several types of darts thru coil. Cut 200' coil. Install new weld on connector. RIH to 2300'. FP well with 50/50 glycol. POOH. ND BOPs. NU tree cap. Secure well Continue to RD & prep for move to 15-36A. Clean 'pits & location. RELEASED RIG AT 0200 HRS, 11-20-2001. Printed: 11/27/2001 4:14:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date { (' BP EXPLORATION Operations Summary Report 1 5-16 1 5-16A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/19/2001 Rig Release: Rig Number: 11/20/2001 00:00 - 02:00 From - To Hours Activity Code NPT Phase COMP Description of Operations 2.00 RIGD p Page 9 of 9 Spud Date: 11/19/2001 End: TOTAL TIME ON WELL WAS 11 DAYS, 1 HOUR. Tubing freeze protected. Well secured. Flowline connected. Move rig to 15-36A. Printed: 11/27/2001 4: 14:04 PM ~, ,," ( BP Amoco Baker Hughes INTEQ Survey Report llïi8 BAIŒII HUGIll. ------ INTEQ " ObP Compa.y: Field: Site: WeD: WeUpatla: Field: BP Amoco Prudhoe Bay PB DS 15 15-16 15-16A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 11/27/2001 TIme: 09:31:30 Page: 1 Co-ordlaate(NE) Reference: Well: 15-16, True North Vertical (TVD) RefereDce: 26: 1661611984 00:00 71.0 Sectloa (VS) Refereace: Well (0.00N,O.00E.135.00Azi) Sarvey Calcalatloa Metlaod: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Eastlng: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: 70 17 35.236 N Longitude: 148 34 21.213 W North Reference: True Grid Convergence: 1.34 deg Site: Well: 15-16 15-16 Well Position: +N/-S 1797.92 ft Northing: +E/-W -166.68 ft Eastlng: Position Uncertainty: 0.00 ft Slot Name: 16 5960630.76 ft 676088.19 ft Latitude: Longitude: 70 17 52.919 N 148 34 26.072 W Wellpath: 15-16A 500292111501 Current Datum: 26: 166/6/1984 00:00 Magnetic Data: 11/8/2001 Field Strength: 57504 nT Vertical Section: Depth From (TVD) ft 0.00 Survey: MWD Drilled From: 15-16 Tle-on Depth: 11536.00 ft Height 71.00 ft Above System Datum: Mean Sea Level Declination: 26.58 deg Mag Dip Angle: 80.81 deg +N/-S +E/-W Direction ft ft deg 0.00 0.00 135.00 Start Date: 11/16/2001 Engineer: Tied-to: From: Definitive Path Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Annotation MD ft 11536.00 13715.00 TVD ft 8702.37 8761.80 KOP TD Survey MD Inel Azlm TVD SSTVD N/S EIW MapN MapE DLS VS ft deg deg ft ft ft ft ft ft deg/100ft ft 11536.00 62.39 36.54 8702.37 8631.37 4803.95 3842.58 5965523.11 679816.91 0.00 -679.79 11573.86 57.39 44.80 8721.39 8650.39 4828.79 3863.85 5965548.44 679837.58 23.02 -682.32 11621.76 64.95 55.06 8744.51 8673.51 4855.62 3895.96 5965576.02 679869.06 24.50 -678.58 11651.06 64.42 51.89 8757.05 8686.05 4871.38 3917.24 5965592.27 679889.96 9.95 -674.68 11684.14 66.27 54.71 8770.85 8699.85 4889.34 3941.34 5965610.79 679913.64 9.55 -670.34 11724.74 79.01 61.74 8782.95 8711.95 4909.62 3974.24 5965631.83 679946.05 35.44 -661.41 11763.42 90.26 71.23 8786.57 8715.57 4924.92 4009.47 596564 7.95 679980.90 37.96 -647.32 11804.57 93.34 89.16 8785.27 8714.27 4931 .90 4049.82 5965655.87 680021.08 44.18 -623.72 11835.77 95.54 101.11 8782.84 8711.84 4929.12 4080.75 5965653.82 680052.06 38.83 -599.89 11872.45 92.72 114.47 8780.19 8709.19 4917.96 4115.50 5965643.48 680087.06 37.13 -567.43 11908.91 88.86 125.37 8779.68 8708.68 4899.81 4147.04 5965626.07 680119.02 31.71 -532.29 11942.71 91.41 131.35 8779.60 8708.60 4878.84 4173.53 5965605.74 680145.99 19.23 -498.73 11977.09 91.41 136.62 8778.76 8707.76 4854.98 4198.25 5965582.46 680171.26 15.32 -464.38 12013.44 92.81 142.60 8777.42 8706.42 4827.33 4221.78 5965555.37 680195:43 16.88 -428.19 12054.24 93.34 148.57 8775.23 8704.23 4793.74 4244.79 5965522.33 680219.22 14.67 -388.16 12089.09 91.76 147.52 8773.68 8702.68 4764.20 4263.22 5965493.23 680238.34 5.44 -354.25 12138.74 88.95 142.24 8773.37 8702.37 4723.61 4291.77 5965453.32 680267.83 12.05 -305.35 12177.91 87.36 138.03 8774.63 8703.63 4693.56 4316.86 5965423.88 680293.61 11.48 -266.37 ."~ :-.... hn ~ ,"" u >.-.- ~. ' ( BP Amoco ( Baker Hughes INTEQ Survey Report .¡¡. BAKU. HUGIll S "~"--- -"----------- INTEQ " Company: BP Amoco FIeld: Prudhoe Bay Site: PB OS 15 Well: 15-16 Wellpatlt: 15-16A Date: 11/27/2001 TIme: 09:31 :30 Page: 1 C«HÞrdlaate(NE) Reference: Well: 15-16. True North Vertical (TVD) Reference: 26: 1661611984 00:00 11.0 Secdoa (VS) Refereace: Well (0.00N.0.OOE.135.00Azi) Sarver Calcaladoa Metllod: Minimum Curvature Db: Oracle Survey MD IDcI AzIm TVD SS TVD NIS E/W MapN MapE DLS VS It deg deg It It It It It It deg/10OO ft 12215.03 85.87 135.56 8776.82 8705.82 4666.56 4342.22 5965397.47 680319.60 7.76 -229.34 12255.68 86.75 130.29 8779.44 8708.44 4638.94 4371.92 5965370.56 680349.93 13.12 -188.81 12308.36 90.88 126.78 8780.53 8709.53 4606.14 4413.10 5965338.74 680391.87 10.29 -136.50 12347.91 88.95 123.26 8780.59 8709.59 4583.45 4445.48 5965316.81 680424.77 10.15 -97.56 12433.06 87.36 113.06 8783.34 8712.34 4543.34 4520.41 5965278.47 680500.62 12.12 -16.21 12474.57 89.82 108.14 8784.36 8713.36 4528.74 4559.24 5965264.79 680539.77 13.25 21.57 12506.14 92.90 104.98 8783.61 8712.61 4519.75 4589.49 5965256.51 680570.22 13.97 49.31 12589.57 91.76 110.96 8780.22 8709.22 4494.04 4668.74 5965232.67 680650.05 7.29 123.53 12659.13 91.85 120.80 8778.02 8707.02 4463.73 4731.22 5965203.83 680713.22 14.14 189.14 12701.84 92.81 123.61 8776.28 8705.28 4440.99 4767.32 5965181.94 680749.84 6.95 230.75 12740.88 95.36 130.29 8773.50 8702.50 4417 .60 4798.42 5965159.29 680781.48 18.27 269.28 12786.51 97.56 138.03 8768.36 8697.36 4386.05 4830.93 5965128.51 680814.71 17.53 314.58 12817.71 95.27 140.84 8764.87 8693.87 4362.50 4851.09 5965105.44 680835.42 11.57 345.49 12850.09 91.23 142.95 8763.04 8692.04 4337.06 4871.03 5965080.48 680855.95 14.07 377.57 12880.89 90.53 146.11 8762.56 8691.56 4311.98 4888.90 5965055.83 680874.40 10.51 407.94 12910.89 89.30 150.68 8762.61 8691.61 4286.44 4904.62 5965030.66 680890.71 15.78 437.12 12944.79 91.14 157.36 8762.48 8691.48 4255.99 4919.46 5965000.57 680906.26 20.44 469.14 12975.52 92.90 162.28 8761.39 8690.39 4227.17 4930.05 5964972.01 680917.52 16.99 497.01 13008.42 89.82 164.04 8760.61 8689.61 4195.70 4939.58 5964940.77 680927.78 10.78 526.00 13042.59 89.03 159.12 8760.96 8689.96 4163.29 4950.37 5964908.62 680939.33 14.58 556.55 13072.77 86.48 158.06 8762.14 8691.14 4135.21 4961.38 5964880.82 680950.99 9.15 584.18 13105.80 85.34 153.85 8764.49 8693.49 4105.13 4974.80 5964851.06 680965.11 13.17 614.94 13140.82 85.87 149.28 8767.18 8696.18 4074.44 4991.42 5964820.77 680982.45 13.10 648.40 13177.72 90.26 147.87 8768.43 8697.43 4042.98 5010.64 5964789.77 681002.40 12.49 684.24 13210.40 94.13 145.41 8767.17 8696.17 4015.71 5028.59 5964762.93 681020.99 14.03 716.22 13242.15 94.22 145.76 8764.86 8693.86 3989.59 5046.49 5964737.23 681039.49 1.14 747.34 13276.22 93.08 148.22 8762.69 8691.69 3961.08 5065.01 5964709.17 681058.67 7.94 780.60 13306.38 92.20 153.14 8761.30 8690.30 3934.82 5079.76 5964683.26 681074.03 16.55 809.60 13363.28 90.00 159.47 8760.21 8689.21 3882.75 5102.61 5964631.75 681098.09 11.77 862.57 13446.23 90.09 162.99 8760.14 8689.14 3804.23 5129.29 5964553.87 681126.61 4.24 936.96 13482.05 90.53 168.61 8759.95 8688.95 3769.51 5138.08 5964519.38 681136.20 15.74 967.12 13517.53 90.97 174.24 8759.49 8688.49 3734.45 5143.36 5964484.45 681142.31 15.92 996.25 13558.63 89.03 177.40 8759.49 8688.49 3693.46 5146.36 5964443.55 681146.26 9.02 1027.35 13593.50 88.68 173.18 8760.18 8689.18 3658.73 5149.22 5964408.89 681149.94 12.14 1053.94 13623.44 90.09 171.07 8760.50 8689.50 3629.07 5153.32 5964379.35 681154.73 8.48 1077.81 13653.11 90.26 170.02 8760.41 8689.41 3599.81 5158.20 5964350.20 681160.29 3.58 1101.95 13689.40 88.07 168.61 8760.94 8689. 94 3564.15 5164.92 5964314.72 681167.85 7.18 1131.92 13715.00 88.07 168.61 8761.80 8690.80 3539.07 5169.98 5964289.76 681173.49 0.00 1153.22 WELlPATH DETAILS Nordic 1 26, 16616/198400,00 7!.11Oft Origin +EJ.IN 135.00" 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Centre: 15-16, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot-16 (O.OON,O.OOE) Measured Depth Reference: 26. 166/6/198400:00 71.00 Calculation Method: Minimum Curvature ANNOTATIONS TVD MD Annota1Œ 663137 11636.00 KOP 669080 13715.00 TO 7700 7800 7900 .....¡JOOO i::: æS1O0 0 08200 'I/"' .... J::::8300 .... CI. 1116400 Q i8500 U t:8600 II.! >8700 III i! 8800 ¡.. 8900 9000 9100 9200 T LEGEND Azimuths to True North I Wellpath 11S-t6/15-16A) Magnetic North: 26.58" Created By. Brli Potnl, Date 11/2712001 I : , " ,': ., 4900 " , , . , '" " , , " . 4800 : /'Œ ,\:,,'" ,,' .., ".: ,' ,! i rN 4600 ¡ ,. , "j : "~, --';I~"'.: ~ ~ " ' ~'" ' ': ' :" .,:' " "- : : ,: :: ' ,. [, ~I\. : , I I . . I : I ,. I ' ". ," \\ ' ' I ' I," " . ' 4300 , /- !, , :: .: \\ : '¡ , .,..~LVU, V : , I' " , : ,: \\ $'41/ ' 'I : ' , ¡' . . [\,. , ' , 4000 \ \ ' , . J . 3800 , '" , ' ' . I ' : " C 3700 " . . . I , " " !, I 3600 m~ ' L&' - I~rr " ' '" = 3500 : " ;f=f', " "" '} , ., :\ I' E 1 \i Ii," vvVU , ,\..-" . , , 3200 ' : ,! : , " '. " . 3300 3400 3500 3100 3¡ 00 31 00 3¡ 00 4100 4100 4, 00 4: 00 4i '00 4500 ';60~ ' 41100 4¡ 00 5000 5100 5200 5300 5'00 5500 5600 5700 51100 5BO( i ~V~VŒ rnJ~ ~~!Æ~~!Æ {' ALAS KA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR / 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 M.S. Endacott CT. Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 15-16A BP Exploration (Alaska) Inc. Pennit No: 201-192 Sur Loc: 854' SNL, 165' EWL, SEC. 22, T11N, R14E, UM Btmhole Loc. 2412' NSL, 232' EWL, SEC. 14, T11N, R14E, UM Dear Mr. Endacott: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit 15-16A.. 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. Sincerely, Úl/rn~l1/f)uIwL" ~_d~", CV~~y~echsli Ta~~Q -- - Chair . BY ORDER OF THE COMMISSION DATED this 3rd day of October, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA (' ALASKA Oil AND GAS CONSERVATION COMMI~SION PERMIT TO DRILL 20 AAC 25.005 , c:AV\ 11 t <JI , , l - ") , ' \[-,1;1'-' ' to ¡ \ \\J L --- ¡ Ð/- /é.ý (;) <-/0 I" 116911-116951,11740'-117841 Sqzd: 116751 -11695" 11714' -117401 true vertical 87701 - 87721, 87901 - 88081 Sqzd: 87641 - 8772" 87791 - 87901 ¡\Ias!\a Oil i.Z G::¡S Cc;ns. (~I '"" IBI Filing Fee 0 Property Plat IBI BOP Sketch 0 Diverter Sketch ÞIIJIiJ)r,iU~rrg Program IBI Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the ~,7go.~ngJis?tru~/a,l,?c~,r~:,?,\,t~,h,t~best of my kn~~ledge. Ill//7/:::.jC\/' Signed M.S. Endacott 7' / I ¡ 'Y. ~~/7 k.tCll. Llz.¡ Title CT Drilling Engineer Date j/ L~j I ,""" ""'"",:',',"""";""""',",'."',"'""",'::',"',:"'.,"""",'",,:/"::ÇÞt11n"i~siøntJse.øhly',',:.'", ",.':'::',':.'.'--;.':'..,':' ," """"""""",t.'",""'."",, '," '" API Number Ap )rov~1 Date See cover letter 50- 029-21115-01 I C) '91)() \ for other reQuirements Samples Required 0 Ves .zg'"No Mud Log qeqL ired 0 Ves ~o Hydrogen Sulfide Measures 0 Ves ~ No Directional Survey Required "lXVes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K ~.5K psi for CTU Other: Approved By Original Sìgned By Form 10-401 Rev. 12-01-85 I,;ammy Uechsll 0 F< I GIN A L 1 a. Type of work 0 Drill IBI Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 8541 SNL, 1651 EWL, SEC. 22, T11N, R14E, UM At top of productive interval 35211 NSL, 3696' EWL, SEC. 15, T11N, R14E, UM At total depth 24121 NSL, 2321 EWL, SEC. 14, T11N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028306,232' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 115201 MD Maximum Hole Angle 18. Casin9 Program Specifications Size Casina Weicht Grade CouDlina Lenath 2-3/8" 4.6# L-80 ST-L 32001 1 b. Type of well Hole 3" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11891 feet 8850 feet 11826 feet 8824 feet Length Size 80' 2495' 20" 13-3/8" 108501 13521 9-5/8" 7" Perforation depth: measured 20. Attachments Permit Numbej ..;zo/- /'92- Conditions of Approval: 0 Exploratory 0 Stratigraphic Test IBI Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 711 Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028307 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number ~'f1"",1.5".'" ' ':.... 9. Approximate spud date 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 ~~ Amount $200,000.00 . r. 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14000' MD / 86581 TVDss 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 950 Maximum surfac,.", í.¡jI1':"" --'At total depth (TVD) 8800' /3300 psig Setting Depth';~"'-" TOD Bottom MD TVD MD TVD 108001 82221 140001 86581 Quantitv of Cement (include staae data) 69 sx Class 'GI Plugs (measured) Junk (measured) Fish: See Diagram (10/95 & 01/98) Cemented MD TVD 1910# Poleset 1900 sx PF 'EI, 400 sx PF ICI 80' 24951 80' 24951 500 sx Class IG', 300 sx PF IC' 380 sx Class IG' 1 0850' 104961 - 118481 8325' 80941 - 88331 ."., -",' :'",.~, (" ".. I) " I' "') n r 1 ,)L! I~,:!I ,J¡ ¿ud~ Commissioner by order of the commission Date I 0 ~ 0 \ Submi In r iplicate ( i ì~ , BPX 15-16A Sidetrack Summary of Operations: A CTD sidetrack of well 15-16A will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. , '1~ }J ,.. 0 Phase 1: Isolate & integrity test inner annulus, (IA). Drift tubing and tag PBTD in liner, set whipstock and abandon current perforations. Planned for September 29, 2001 . Drift and caliper well and tag as deep as possible with slickline . Liquid pack and integrity test the IA . P&A the existing perforations at 11,714'-784' MD with permanent plug in XN . Pull DGl V in straddle. Perform injectivity test into straddle. . Punch holes in straddle at 11,400' and abandon perf behind it (11691-95) below cement retainer with 30bbls of 17ppg cement. . Install whipstock at 11520' Phase 2: Drill and Complete CTD sidetrack: Planned for October 7,2001 2" coil will be used to drill a -2400 foot, 3" open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 2-3/8" liner completion. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.5 - 8.6 ppg) Disposal: . -", ii'" '. ~':1 . :ñ\~~!ft:êìlf1ì',il~'~i\iMDII:'I';:;'I;:': . . ' 1~-~_~,~i~~.I:t . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 2-3/8", l-80, solid liner will be run from 10,800'MD (Tal, 8,222' TVDss) to TD at approximately 14,000'MD. Liner will be cemented to top of liner with approximately 14 bbls (annular volume plus 250/0 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 3i~" . The annular preventer will be tested to 400 psi and 2,200 psi. . "., ~i 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 . ~.~ -, ~ ~~.~ 9, r~,ckt2f.)Ji>.Œb.O'1~:~¿~~?J~~lJ,¡,¡¡.¡,Q;.19~i§~tMMI§!I]'ri":~9~~;Bçh.1p¡J2:§~,~gç!U!.%!!~ ~~.. . Minor faulting should not present drilling problems, however as they exist, vigilant monitoring of potential fluid loss should be carried out. Reservoir Pressure Reservoir pressure is estimated to be 3,300 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surfa"I'<¡"'Y" ' . { 1REE= Ftv'C GEN 3 WELLHEAD = Ftv'C AC1UA TOR = AXELSON OLD KB. REV = 71' BF. REV = KOP= 3000' Wax Angle = 66 @ 11891' D:itum tv[) = 11919' D:itum lVD = 8800' SS 4-1/2" 12.6# x 3-1/2" 9.3# TBG XO,ID = 2.992" 13-3/8" CSG, 72#, L-80,ID = 12.347" Minimum 10 = 1.75" @ 10442' AVA ECLPSE PATCH BKR SEAL BORE EXT, ID = 4.750" 4-1/2" BKR GBH-22 SEAL ASSY, ID = 3.875" TOP OF 7" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORA llON SLKv11'v\ð. RY REF LOG: BI-CS ON 06/24/84 ANGLEATTOPPERF:66 @ 11675' Note: Refer to Production œ for historical perf data 69' 2495' 10247' 10259' 10492' 10850' SIZE SPF INTERV A L Opn/Sqz DATE 3-1/8" 0 11675-11695 S 11/08/90 4-1/2" 2 11691-11695 0 11/14/90 4" 0 11714-11777 S 11/08/90 3-318" 4 11740-11784 0 11/14/90 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID= 2.992" I FBTD 7' LNR, 29#, L-80, 0.0371 bpf, ID= 6.184" 11709' 11826' 11848' 11891' 15-16 e 2235' 10168' 10243' l' '~ SAFETY NOTES: AV A 3.5" Ea...IPSE PA TCH ACROSSGLM#13@ 10443' (11/17/95),ID= 1.75" STA 1 2 3 4 5 6 7 8 9 10 11 12 13 3-1/2" CAMCO TRDP-1 A SSSV NIP (SNGLE CONTROL LINE), ID = 2.812" GA.S LIFT MAN£:RRS MD TVD DEV TYPE MA. N VL V LATCH 2854 2853 7 MM3-2- 7 1-1/2" RK 4364 4235 42 MM3-2-7 1-1/2" RK 5920 5230 50 MM3-2-7 1-1/2" RK 7164 5989 51 MM3-2-7 1-1/2" RK 8069 6534 53 MM3-2-7 1-1/2" RK 8566 6835 52 MM3-2- 7 1-1/2" RK 8964 7081 52 MM3-2-7 1-1/2" RK 9458 7392 50 MM3-2-7 1-1/2" RK 9830 7634 48 MM3-2-7 1-1/2" RK 10107 7823 46 MM3-2-7 1-1/2" RK 10168 7856 49 MM3-L TS 1-112" RK 10353 7979 58 MM3-2-7 1-1/2" RK 10443 8039 60 MM3-2-7 1-1/2" RK -I CI-EMMAND-MM3-LTS-RK, DEV = 49 I 9-5/8" X 4-1 (2" BA KER MODEL D PERM PKR, ID = 4.750" 10280' -I 3-1/2" OTIS X NIP, ID = 2.813" 10442' -1AV A3.5" Ea...PS PATCH, 09/30/98, ID = 1.75" I 11698' -13-1/2" BKR GBH-22 SEALASSY, ID = 3.00" I 11699' -I 7"X 3-1/2" BAKER FB-1 PERMPKR, ID= 4.000" I 11710' - 3-1/2"OTISXNNIP,D=2.750" I 11712' -I 3-1/2"BAKERWLEG, ID= 2.867' 11750' 11760' DAlE REVBY COWMENTS DAlE REV BY COWMENTS 06130/84 ORIGINAL COMA...EnON 08/25/01 P61CH CORRECTIONS 11/18/90 LAST WORKOVER 12/11/00 SIS-151 CONVERlED TO CANV AS 01/19/01 SIS-tv[) FINAL 06127/01 RN/lP CORRECllO NS (2) RLBBER RErvlENTS 2" X 2.74"; 2 SLIP KEYS 1 "X5/8"X3/8" F/A VA ECLIPSE - 01/07/98 (4) SLIP REIvENTS & 1 RUBBER EL8v1ENT - 10/17/95 PRUDI-OE BAY l1'J1T WELL: 15-16 PERtvIT f\b: 84-074 AANo: 50-029-21115-00 Sec. 22 T11N R14E, 1069.52 ÆL 1068.55 FI'I.. BP Exploration (Alaska) :rnEE = FMC GEN 3 WELLHEA D = FMC "'""W""""""""""""""'w"""""""'"."....",,, "",., "w'. "",.,."" "". A CTUA TOR = AXELSON OLD .",_.. ""oo "."" ,.,.. KB. ELEV = 71' oo..-~""""""""""" """"""""",..,, .. BF. ELEV = "oo. ".m- OO"oo' KOP = 3000' ..". ,oo""moo... ..... ".... "'oo" "... ...." "., "..,..." "" .""..... Max Angle = 66 @ 11891' ",.."", "". """"". """"..",,m "oo".",,"""""""""~""""" Datum MD = 11919' Datum ìVD = 8800' SS 14-1/2" 12.6# x 3-1/2" 9.3# TaG XO, ID = 2.992" I 13-3/8" CSG, 72#. L-80, ID = 12.347" I I BKR SEAL BORE EXT, ID = 4.750" I I 4-1/2" BKR GBH-22 SEAL ASSY, ID = 3.875" I Note: Retrieved 3-1/2" Eclipse Patch from 10442' MD in August of 2001 I TOP OF 7" LNR I 9-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORATION SUMMARY REF LOG: BHCS ON 06/24/84 ANGLEATTOPÆRF: 66 @ 11675' Note: Refer to Production DB for historical perf data 15-16A ~, PROPOSED CTD SIDETRACK 69' 2495' 10247' 10259' 10492' 10850' SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 0 11675-11695 S 11/08/90 4-1/2" 2 11691-11695 0 11/14/90 4" 0 11714-11777 S 11/08/90 3-3/8" 4 11740-11784 a 11/14/90 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I I PBTD I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" I I I TD 11709' 11826' 11848' 8> 2235' STA 1 2 3 4 5 6 7 8 9 10 11 12 13 10168' 10243' 3-1/2" CAMCO TRDP-1A SSSV NIP (SINGLE CONTROL LINE), ID = 2.812" GAS LIFT MANDRELS MD ìVD DEV TYÆMAN VLV LATCH 2854 2853 7 MMG-2-7 1-1/2" RK 4364 4235 42 MMG-2-7 1-1/2" RK 5920 5230 50 MMG-2-7 1-1/2" RK 7164 5989 51 MMG-2-7 1-1/2" RK 8069 6534 53 MMG-2-7 1-1/2" RK 8566 6835 52 MMG-2-7 1-1/2" RK 8964 7081 52 MMG-2-7 1-1/2" RK 9458 7392 50 MMG-2-7 1-1/2" RK 9830 7634 48 MMG-2- 7 1-112" RK 10107 7823 46 MMG-2-7 1-1/2" RK 10168 7856 49 MMG-L TS 1-1/2" RK 10353 7979 58 MMG-2-7 1-1/2" RK 10443 8039 60 MMG-2-7 1-1/2" RK -f CHEM MAND -MMG-L TS -RK, DEV = 49 I 9-5/8" X 4-1/2" BAKER MODEL D ÆRM PKR, ID = 4.750" 10280' -f 3-1/2" OTIS X NIP, ID = 2.813" I 111400' 1-1 Punch Hole in Straddle I I~ II J~I~ .1 I 2-3/8" L-80 Liner, Cemented & Perforated 11698' 11699' 11710' 11712' 11750' 11760' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/30/84 ORIGINAL COMPLETION 08/25/01 Æ/CH CORRECTIONS 11/18/90 LAST WORKOVER 08/30/01 pcr 15-16A ST proposal 12/11/00 SIS-isl CONVERTED TO CANVAS 01/19/01 SIS-MD FINAL 06/27/01 RNlTP CORRECTIONS 11891' -13-1/2" BKR GBH-22 SEAL ASSY, ID = 3.00" I -17" X 3-1/2" BAKER FB-1 ÆRM PKR, ID = 4.000" I -I 3-1/2" OTIS XN NIP, ID = 2.750" I -i 3-1/2" BAKER WLEG, ID = 2.867" I (2) RUBBER ELEMENTS 2" X 2.74"; 2 SLIP KEYS 1 "X5/8"X3/8" F/AVA ECLIPSE- 01/07/98 (4) SLIP ELEMENTS & 1 RUBBER ELEMENT - 10/17/95 PRUDHOE BA Y UNIT WELL: 15-16A Proposed ST ÆRMrT No: 184-074 API No: 50-029-21115-01 Sec. 22 T11N R14E,1069.52 FEL 1068.55 FNL BP Exploration (Alaska) ,~,,' ( (' ... sa.. INTEQ ObP BP Amoco Baker Hughes INTEQ Planning Report ¡-Co;;~ny: -ap Amoco -----------------'- Date: 9/19/2001 Time: 11 :08:43 Page: 1 I \1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-16, True North I Sire: PB DS 15 Vertical (fVD) Reference: System: Mean Sea Level I I Well: 15-16 Section (VS) Reference: Well (0.00N,0.00E,135.00Azi) : l- - ~~!~!~:..- .~~~~~~_~_16~__- -- --- - ------ ------ ----------------~...~!!- C~~ula ~_n Method: ___--~i ni '!'_':. m Cu rvatur!_____-~~~-~~~~_.- - - j !__F_i;Id:______P~_(j"hoe B~Ÿ------- - ,-_. -- --- ---------------------------------------------------,-------------------- ------1 i North Slope ' , .. UNITED STATES , Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 : Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre I Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2001 c- - _. ..------ ---_.._,--_u----- --.....,.....,..-- --- ""'------."'-"-,-,--"", ,--_.., _.._----,---.. -------------_____--n..___"'--.----,-.-..-------........------- - - __n_--__--..---..----------.., ,- ---.. ! Sõ;: --_nf~-?i~1r--- - .- _.n ---- -- -- - ------------------.. ---_w--I UNITED STATES: North Slope I Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg ,,---...-..--..,-.. -"'..--..--.... ---..--..".-- --,..,.,.-...-------.--------..-..--------------,....---------- .._------------------------,--------------------,----..----,-..---...-- --- .._--,--- ,.-.-.,--.. - '.-..-..-------- ,,-..--_..... .._-... ---,....- -." ",..--,.-------..,-.. -- ..,_., -"-"--"--"-"-""""-----'--"---"--""'-'-""---------'----...--. -,---..,,---------.-.---.-----..--,-----,-------..-----------------..--..---- Well: 15-16 15-16 Well Position: +N/-S 1797.92 ft +E/-W -166.68 ft Position Uncertainty: 0.00 ft Slot Name: 16 Northing: Easting : 5960630.76 ft 676088.19 ft Latitude: Longitude: 70 17 52.919 N 148 34 26.072 W ,..._-, "-----"---------------,...-..-...-----.. --'---"""-----,------_._,--_..",.....,--,--. ..-,..,,----------...-..... ....,---"_....,....,,._--_._----,-,-_..._---_._-----,-,- .. ",--_..,-----,,--_.._-.. .--------" '_'_un.___"_.------......"".- ..",-" """"""""""'-'-"'--"'"..-----.."..---,,---.--_......__h____._n.......___--"...-.--..--..---.-,..,,---- "'--"---'-"------"""""-'-"---'---'--"----""-" ---",--, ",-_.._,.. ........--- ""-..-..--.. ,'-..,..-...,-.. -----,-_. -"...._' --.....- Wellpath: Plan#1 15-16A 500292111501 Current Datum: 26: 166/6/198400:00 Magnetic Data: 9/19/2001 Field Strength: 57502 nT Vertical Section: Depth From (TVD) ft ',-....,.."..-.,..--,..,.-..-",---..."--,-..".......".............--,,..----....-..",-..-......,..,".....-..,..--..".."".. 0.00 Drilled From: 15-16 Tie-on Depth: 11520.00 ft Height 71.00 ft Above System Datum: Mean Sea Level Declination: 26.63 deg Mag Dip Angle: 80.81 deg +N/-S +E/-W Direction ft ft deg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rincipal: Plan #1 Identical to Lamar's Plan #1 Yes Date Composed: Version: Tied-to: 9/19/2001 1 From: Definitive Path Plan: . ,_.."..,,- --""'-_h..""....."-...,,..-..,---..--.- '--"'--" ,_.._, """"'..-'--- -"-"'-"'---""'--"-""--"--"""" ""'-".....__.......,,,.. -"-",-""---""-,,,,,,_..,,..._,-, --".-""..-.---.....----..,,---..---------..--..-------..-..,,-..-----...---.---..--,,--,,-....-..-,,---..---..- Targets r' ""-,,... - - .,,- "'--'---- -",,-_..~-,-- -...---,--...- '--",,-- ----- ------, --"_.,,-"----- - .~-~- .,--~-,,-_.__.._-,,--- '-~" - -' ----- M;; -'---"------M; p ---~---~~-':-L~tlt;d; --=~:;-"-~:"-L~gii~d-;~~----;-~1 Name Description TVD +N/-S,' +E/';W Northing Easting DegMin, See Deg Min See I " 'ft" ft 'ft..ft" ft ,""'" ' ' -..".....-,-----...--".."-.-..-,-,.-,-,,---..--..-..,,-..-..,,..-...-..-"'--"-"""'" -"""'---'----..,__._'_m"_.___-"......-.."-,.....-----.---'--,,.-"-..."..."...",..-.......,,....--..--,,-.... -,.. "--"""-'-"'--"""""-""""'--""""'------'--""--"-""-"'"-"'-"""""""""-"""-"-"""'--""-""-"-""- - "..- "-"""-"-"-----"'--"'--"'-"-"."'--""""""-"'" 15-16A T1.1 8720.00 4771.68 4225.25 5965499.82 680200.20 70 1839.836 N 148 32 22.827 W 15-16A T1.2 8720.00 8680.00 4508.82 3874.56 4769.27 5154.52 5965249.80 680750.20 5964624.78 681150.18 70 18 37.248 N 70 18 31.008 N 148 32 6.964 W 148 31 55.740 W 15-16A T1.3 15-16A T1.4 8660.00 3245.01 5339.80 5963999.78 681350.14 70 18 24.815 N 148 31 50.349 W .-""",""'- .... "'" -"'-"'--'-"-"'" -- ......-......-..--..--......-",'..".." "'-'---""""----"""..._",...._,-_.._",-,.. -.".......""", ,-,-"--.."..-..--"",...-,--..,-.--.-.-.-..,..--..,,,-,---..,,------""""""""""""'_"_-------"'_'_.._.._-""-,,.._--..-.........,--...-..,-...-,...----..-.....---...---.-.-,,-....-,,---.-..---. ,...."..-"-"'.-'--"- Annotation 11500.00 8614.49 TIP 11520.00 8623.92 KOP 11530.00 8628.75 1 11835.38 8718.31 2 11985.38 8718.31 3 12255.38 8718.31 4 12605.38 8718.31 5 12905.83 8710.26 6 13155.83 8693.85 7 13355.83 8678.18 8 13505.83 8668.62 9 13755.83 8660.61 10 14000.00 8658.05 TO """"_"_""".-0,""""""-"-""'-----_"'_"""""--""" , -""""""""--"-'-----"-"""-"-"'-----------'........-,-........---....--_..__.""-"-,_.._-..,...............".."._....",,,,,-,........,_..,....,,_......-- ,...---,--....--..- ,- ,..-....",..,....,,--..,_.. ....,...""....._"".,,-_... - --..,-."..,..-".....---...- ,,' ( ( ObP BP Amoco Baker Hughes INTEQ Planning Report II.. 8AIfII8 IIUC: ... lNT EQ ICompan;: BP Amoco Date: 9/19/2001 Time: 11 :08:43 I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-16. True North I Site: PB OS 15 Vertical (TVD) Reference: System: Mean Sea Level ¡Well: 15-16 Section (VS)Reference: Well (0.00N,O.00E,135.00Azi) ! t... -~ !.Upa~~__~la~~_.~_5-16~- ..--.-----.------------- ------- ___~~rve!£.!lcul~ti°l!..~!~~~-=--- _~i nim~m__<2.~_~a.~e________Db.~__~ra~I~_- -.---j Plan Section Information ¡------ MD------ Incl-----A;j~----- TVD +N/-S +IÙ-W-OLS-- Build Torn TFO T~et'---'--------------'l i ft deg deg ft ft ft deg/1 000 deg/1 00ft deg/10OO deg I -- "--'" ---.------.-------.. -- --.- .-.-------- '-- "'------'-----'-----'--------'--------- ---.----------.---.----.------. -----.--.- --..-..--- ..-..-------.---.-, 11500.00 61.68 36.47 8614.49 4778.39 3823.66 0.00 0.00 0.00 0.00 . 11520.00 62.07 36.51 8623.92 4792.57 3834.15 1.96 1.95 0.20 5.18 11530.00 60.19 37.30 8628.75 4799.57 3839.41 20.00 -18.77 7.88 160.00 11835.38 90.00 111.51 8718.31 4857.87 4101.77 25.00 9.76 24.30 82.00 11985.38 90.00 126.51 8718.31 4785.33 4232.57 10.00 0.00 10.00 90.00 12255.38 90.00 99.51 8718.31 4680.76 4478.80 10.00 0.00 -10.00 -90.00 12605.38 90.00 134.51 8718.31 4524.27 4785.79 10.00 0.00 10.00 90.00 12905.83 93.00 164.42 8710.26 4268.56 4936.69 10.00 1.00 9.95 84.00 13155.83 94.41 139.41 8693.85 4050.20 5053.16 10.00 0.56 -10.01 274.00 13355.83 94.48 159.47 8678.18 3879.39 5154.04 10.00 0.04 10.03 89.00 13505.83 92.78 174.40 8668.62 3733.99 5187.76 10.00 -1.13 9.96 96.00 13755.83 90.83 149.46 8660.61 3498.33 5264.67 10.00 -0.78 -9.98 266.00 14000.00 90.35 173.88 8658.05 3268.31 5340.88 10.00 -0.20 10.00 91.00 Page: 2 . -- ........ - - .....--..-..---.------.---------.------------.---..-..-.-----------.--- .-..--...- .--...-....---..---.-.--- ..-- '--.--'----------------.--.--.--.-.-.----- "--'--"-.--'---' -.--....-,.------------.,----. ,.-.--..--.--..----.-..-..-,.--.--. Survey 1-"'" 'ff~~g ~g._-'-"~ ~ : ~~---""---~'f~f-'- :~~~ ~f"-"1~~ ~: ;r"----~:~r~~--"-" ~-~~~~~~:I~--..-'-~r~~~:~f"- .., - ~:~~--_.__..~~ ~r~~-"---'.'--"'I~~----l~ ~. ---." 11525.00 61.13 36.90 8626.30 4796.10 3836.78 5965515.13 679811.29 20.00 -678.34 160.00 MWD 11530.00 60.19 37.30 8628.75 4799.57 3839.41 5965518.66 679813.84 20.06 -678.94 159.79 1 11550.00 61.01 42.96 8638.57 4812.88 3850.64 5965532.23 679824.75 25.00 -680.41 82.00 MWD 11575.00 62.35 49.90 8650.45 4828.03 3866.57 5965547.75 679840.33 25.00 -679.85 79.22 MWD 11596.07 63.75 55.60 8660.00 4839.39 3881.52 5965559.45 679855.00 25.00 -677.32 75.93 15-16A 11600.00 64.04 56.64 8661.73 4841.36 3884.45 5965561.49 679857.88 25.00 -676.64 73.34 MWD 11625.00 66.02 63.18 8672.29 4852.70 3904.05 5965573.29 679877.21 25.00 -670.80 72.88 MWD 11644.63 67.77 68.17 8680.00 4860.13 3920.50 5965581.10 679893.48 25.00 -664.42 70.12 15-16A 11650.00 68.28 69.51 8682.01 4861.93 3925.14 5965583.00 679898.08 25.00 -662.41 68.16 MWD 11675.00 70.76 75.63 8690.76 4868.93 3947.47 5965590.53 679920.24 25.00 -651.57 67.66 MWD 11700.00 73.44 81.56 8698.45 4873.62 3970.78 5965595.76 679943.43 25.00 -638.41 65.51 MWD 11725.00 76.29 87.33 8704.98 4875.95 3994.78 5965598.65 679967.37 25.00 -623.08 63.69 MWD 11750.00 79.27 92.95 8710.28 4875.88 4019.20 5965599.16 679991.79 25.00 -605.76 62.18 MWD 11775.00 82.34 98.46 8714.27 4873.42 4043.75 5965597.27 680016.38 25.00 -586.67 60.99 MWD 11800.00 85.49 103.90 8716.93 4868.60 4068.12 5965593.03 680040.86 25.00 -566.02 60.11 MWD 11825.00 88.67 109.28 8718.20 4861.47 4092.04 5965586.46 680064.93 25.00 -544.07 59.53 MWD 11835.38 90.00 111.51 8718.31 4857.87 4101.77 5965583.09 680074.75 24.99 -534.64 59.23 2 11850.00 90.00 112.97 8718.31 4852.34 4115.30 5965577.87 680088.40 10.00 -521.16 90.00 MWD 11875.00 90.00 115.47 8718.31 4842.08 4138.10 5965568.15 680111.43 10.00 -497.79 90.00 MWD 11900.00 90.00 117.97 8718.31 4830.84 4160.43 5965557.44 680134.02 10.00 -474.05 90.00 MWD 11925.00 90.00 120.47 8718.31 4818.64 4182.24 5965545.75 680156.11 10.00 -450.00 90.00 MWD 11950.00 90.00 122.97 8718.31 4805.49 4203.51 5965533.11 680177.68 10.00 -425.67 90.00 MWD 11975.00 90.00 125.47 8718.31 4791.43 4224.18 5965519.54 680198.67 10.00 -401.11 90.00 MWD 11985.38 90.00 126.51 8718.31 4785.33 4232.57 5965513.64 680207.20 10.00 -390.86 90.00 3 12000.00 90.00 125.05 8718.31 4776.78 4244.43 5965505.37 680219.26 10.00 -376.43 270.00 MWD 12025.00 90.00 122.55 8718.31 4762.88 4265.20 5965491.96 680240.35 10.00 -351.91 270.00 MWD 12050.00 90.00 120.05 8718.31 4749.89 4286.56 5965479.47 680262.01 10.00 -327.62 270.00 MWD 12075.00 90.00 117.55 8718.31 4737.85 4308.47 5965467.95 680284.19 10.00 -303.62 270.00 MWD 12100.00 90.00 115.05 8718.31 4726.77 4330.88 5965457.40 680306.85 10.00 -279.94 270.00 MWD 12125.00 90.00 112.55 8718.31 4716.69 4353.75 5965447.86 680329.95 10.00 -256.63 270.00 MWD 12150.00 90.00 110.05 8718.31 4707.61 4377.04 5965439.32 680353.45 10.00 -233.74 270.00 MWD 12175.00 90.00 107.55 8718.31 4699.55 4400.71 5965431.83 680377.29 10.00 -211.31 270.00 MWD 12200.00 90.00 105.05 8718.31 4692.54 4424.70 5965425.38 680401.44 10.00 -189.39 270.00 MWD 12225.00 90.00 102.55 8718.31 4686.57 4448.98 5965419.98 680425.85 10.00 -168.00 270.00 MWD 12250.00 90.00 100.05 8718.31 4681.68 4473.49 5965415.66 680450.47 10.00 -147.21 270.00 MWD 12255.38 90.00 99.51 8718.31 4680.76 4478.80 5965414.87 680455.80 10.00 -142.81 270.00 4 . --.- '.'-----'--"-----'-.-....-..-.----.- -'-.'..."'----'.'-- ....---.-..... .........-.._.. -.-....---....--.......-...-.--..-..-. -'--.---..--...,_._.__h._,.'O..--.-,......-.----....-.....--.,------...-....--...------.. "'..'-'_'___h______--------.---.-.....----.. .. .--.,--.--.--..--... --.-'O-----" -'---'-'.--""'--"--"--'.---' .. ObP ( ( BP Amoco Baker Hughes INTEQ Planning Report .ii8 .... INTEQ r-- . - - '.--- - - -.... l I Company: BP Amoco Date: 9/19/2001 Time: 11 :08:43 Page: 3 I ¡ Field: Prudhoe Bay Co-ordtnate(NE) Reference: Well: 15-16, True North I ! Site: PB DS 15 Vertical (fVD) Reference: System: Mean Sea Level I ! Well: 15-16 Section (VS) Reference: Well (0.OON,O.00E,135.00Azi) I 11- W!!~!~~~~~n#!! 5-1 ~-~---- --. ---------------_._-----_._._~~ey .!=alcu~tion ~et!'od-=-_._- Mi~~_~~_~urv~~!~--------~~~___~CI~____.¡ Survey E~---'" M~PN M~E d~~ OO~---- ~S ---~~g '---T~-;¡-'i ---"4498.09--5965411~75---68õ475~-17--1Õ~ÕÕ-'-'--"~126.64----9-Õ~ÕO----MWD-"1 4522.48 5965406.82 680499.67 10.00 -105.51 90.00 MWD i I ] c- ..-----. -.-..---. - -------..-------- ---.-- --.- ------ : MD loel Aztm SSTVD NIS I ft deg deg ft ft r' """'-"-'-----.'------------,--------,----- ---'-- -- - _____h__' 12275.00 90.00 101.47 8718.31 4677.19 12300.00 90.00 103.97 8718.31 4671.68 12325.00 12350.00 12375.00 12400.00 12425.00 12450.00 12475.00 12500.00 12525.00 12550.00 12575.00 12600.00 12605.38 12625.00 12650.00 12675.00 12700.00 12725.00 12750.00 12775.00 12800.00 12825.00 12850.00 12875.00 12900.00 12905.83 12925.00 12950.00 12975.00 13000.00 13025.00 13050.00 13075.00 13100.00 13125.00 13150.00 13155.83 13175.00 13200.00 13225.00 13250.00 13275.00 13300.00 13325.00 13350.00 13355.83 13375.00 13400.00 13425.00 13450.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.21 90.47 90.73 90.98 91.24 91.50 91.75 92.00 92.24 92.48 92.72 92.95 93.00 93.13 93.30 93.46 93.61 93.76 93.90 94.03 94.16 94.28 94.38 94.41 94.44 94.47 94.50 94.51 94.52 94.52 94.51 94.49 94.48 94.28 94.01 93.73 93.44 106.47 108.97 111.47 113.97 116.47 118.97 121.47 123.97 126.47 128.97 131.47 133.97 134.51 136.46 138.95 141.43 143.92 146.41 148.90 151.38 153.87 156.36 158.85 161.35 163.84 164.42 162.50 160.01 157.51 155.01 152.51 150.00 147.50 145.00 142.49 139.99 139.41 141.33 143.84 146.35 148.86 151.36 153.87 156.38 158.89 159.47 161.38 163.87 166.36 168.85 8718.31 8718.31 8718.31 8718.31 8718.31 8718.31 8718.31 8718.31 8718.31 8718.31 8718.31 8718.31 8718.31 8718.27 8718.13 8717.87 8717.50 8717.01 8716.41 8715.70 8714.89 8713.96 8712.93 8711.80 8710.57 8710.26 8709.23 8707.83 8706.36 8704.82 8703.21 8701.54 8699.81 8698.02 8696.18 8694.29 8693.85 8692.37 8690.43 8688.47 8686.51 8684.54 8682.57 8680.60 8678.64 8678.18 8676.72 8674.91 8673.22 8671.66 4665.12 4657.51 4648.87 4639.21 4628.56 4616.93 4604.35 4590.84 4576.42 4561.12 4544.98 4528.02 4524.27 4510.28 4491.79 4472.59 4452.71 4432.20 4411.08 4389.41 4367.23 4344.56 4321.47 4297.99 4274.16 4268.56 4250.21 4226.58 4203.32 4180.48 4158.10 4136.23 4114.91 4094.18 4074.08 4054.64 4050.20 4035.48 4015.69 3995.25 3974.21 3952.60 3930.47 3907.86 3884.82 3879.39 3861.38 3837.59 3813.48 3789.11 4546.60 4570.41 4593.87 4616.92 4639.54 4661.67 4683.27 4704.30 4724.72 4744.49 4763.58 4781.94 4785.79 4799.54 4816.37 4832.37 4847.53 4861.80 4875.17 4887.61 4899.10 4909.61 4919.13 4927.63 4935.10 4936.69 4942.14 4950.16 4959.20 4969.25 4980.28 4992.27 5005.21 5019.06 5033.80 5049.41 5053.16 5065.35 5080.49 5094.75 5108.11 5120.52 5131.99 5142.47 5151.95 5154.04 5160.44 5167.89 5174.29 5179.65 5965400.82 5965393.77 5965385.69 5965376.57 5965366.46 5965355.35 5965343.28 5965330.26 5965316.33 5965301.50 5965285.81 5965269.29 5965265.63 5965251.96 5965233.87 5965215.05 5965195.54 5965175.37 5965154.57 5965133.20 5965111.29 5965088.88 5965066.02 5965042.75 5965019.10 5965013.54 5964995.32 5964971.88 5964948.84 5964926.25 5964904.14 5964882.56 5964861.55 5964841.15 5964821.40 5964802.33 5964797.98 5964783.55 5964764.12 5964744.02 5964723.30 5964701.99 5964680.14 5964657.79 5964634.97 5964629.59 5964611.74 5964588.13 5964564.18 5964539.95 680523.94 680547.92 680571.57 680594.85 680617.70 680640.10 680661.99 680683.33 680704.08 680724.20 680743.66 680762.42 680766.35 680780.43 680797.68 680814.13 680829.74 680844.49 680858.36 680871.30 680883.30 680894.34 680904.39 680913.44 680921.47 680923.19 680929.07 680937.64 680947.22 680957.80 680969.35 680981.85 680995.29 681009.62 681024.83 681040.88 681044.74 681057.27 681072.87 681087.60 681101.45 681114.37 681126.34 681137.35 681147.37 681149.59 681156.41 681164.41 681171.38 681177.30 .. """"'-""""-"""--"-------"'..... ",.---,-"",-'."'-- .- .--"'.'-----.".'.....'--".'-"'-'. 'h"._.."""""" .......---..--.... ..................-._..... ...-..-......-... 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.02 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.93 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.99 10.00 10.00 10.00 10.00 -83.81 -61.59 -38.89 -15.76 7.76 31.63 55.80 80.23 104.86 129.66 154.57 179.55 184.92 204.54 229.51 254.40 279.18 303.78 328.16 352.28 376.09 399.55 422.61 445.22 467.35 472.44 489.27 511.65 534.49 557.74 581.37 605.31 629.53 653.99 678.63 703.41 709.20 728.23 752.93 777.47 801.79 825.85 849.60 873.00 896.00 901.31 918.58 940.67 962.24 983.26 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 5 84.00 MWD 84.00 MWD 84.02 MWD 84.04 MWD 84.08 MWD 84.13 MWD 84.19 MWD 84.26 MWD 84.34 MWD 84.43 MWD 84.54 MWD 84.65 MWD 84.78 6 274.00 MWD 273.90 MWD 273.76 MWD 273.61 MWD 273.46 MWD 273.29 MWD 273.13 MWD 272.95 MWD 272.78 MWD 272.59 MWD 272.54 7 89.00 MWD 89.15 MWD 89.34 MWD 89.54 MWD 89.74 MWD 89.93 MWD 90.13 MWD 90.33 MWD 91.07 8 96.00 MWD 96.15 MWD 96.33 MWD 96.49 MWD ObP /' ~, ( BP Amoco Baker Hughes INTEQ Planning Report Company: BP Amoco Field: Prudhoe Bay Site: PB OS 15 WeD: 15-16 L n~~Upa~~la~~J 5-1 ~_._------_._---------------- Survey r-'-'-------- ----------------- i ~D InJ~ Azim SS~VD N: l__..__--_.._---------~eg --------- , 13475.00 93.15 171.34 8670.23 3764.53 13500.00 92.85 173.82 8668.92 3739.77 13505.83 92.78 174.40 8668.62 3733.99 13525.00 92.64 172.49 8667.71 3714.97 13550.00 92.46 169.99 8666.60 3690.29 13575.00 13600.00 13625.00 13650.00 13675.00 13700.00 13725.00 13750.00 13755.83 13775.00 13800.00 13825.00 13850.00 13875.00 13900.00 13925.00 13950.00 13975.00 14000.00 92.28 92.09 91.90 91.70 91.50 91.29 91.09 90.88 90.83 90.80 90.75 90.70 90.66 90.61 90.55 90.50 90.45 90.40 90.35 167.49 165.00 162.51 160.01 157.52 155.03 152.53 150.04 149.46 151.38 153.88 156.38 158.88 161.38 163.88 166.38 168.87 171.38 173.88 8665.56 8664.61 8663.74 8662.96 8662.26 8661.65 8661.13 8660.70 8660.61 8660.34 8660.00 8659.68 8659.39 8659.11 8658.86 8658.63 8658.42 8658.23 8658.05 Bii8 .A~ IIUGIIIS INTEQ Date: 9/19/2001 Time: 11 :08:43 Page: 4 Co-ordlnate(NE) Referenœ: Well: 15-16, True North Verdeal (TVD)Referenee:; System: Mðan Sea Level Section (VS)Referenee: Well (0.OON,O.OOE,135.00Azi) Survey Caleulation Metbod:.._..~inimul'!'_9urvatu~!___Db~__9~cle ___1 E~ --- M~PN M~E -- d:;~ Oatt ~S----T~~--T oo¡-l -- --------- '--------------------'-----'------ -- ---. ------.-1 5183.94 5964515.47 681182.17 10.00 1003.68 96.65 MWD 5187.16 5964490.80 681185.97 10.00 1023.46 96.79 MWD 5187.76 5964485.03 681186.70 9.93 1027.97 96.84 9 5189.95 5964466.07 681189.33 10.00 1042.97 266.00 MWD 5193.75 5964441.48 681193.71 10.00 1063.11 265.91 MWD 3665.79 3641.53 3617.54 3593.88 ,3570.59 3547.71 3525.29 3503.37 3498.33 3481.66 3459.46 3436.79 3413.67 3390.16 3366.31 3342.15 3317.73 3293.11 3268.31 5198.63 5204.57 5211.56 5219.58 5228.63 5238.69 5249.73 5261.74 5264.67 5274.13 5285.62 5296.14 5305.65 5314.15 5321.62 5328.03 5333.39 5337.68 5340.88 5964417.11 5964392.99 5964369.18 5964345.72 5964322.64 5964300.01 5964277 .85 5964256.22 5964251.26 5964234.81 5964212.89 5964190.47 5964167.59 5964144.29 5964120.61 5964096.61 5964072.33 5964047.81 5964023.10 681199.16 681205.67 681213.22 681221.80 681231.39 681241.98 681253.54 681266.06 681269.11 681278.96 681290.96 681302.01 681312.06 681321.10 681329.13 681336.11 681342.03 681346.90 681350.68 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.04 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.01 10.01 1083.88 1105.24 1127.14 1149.55 1172.42 1195.70 1219.36 1243.36 1248.99 1267.47 1291.29 1314.76 1337.83 1360.46 1382.61 1404.23 1425.28 1445.73 1465.53 265.80 MWD 265.69 MWD 265.60 MWD 265.51 MWD 265.43 MWD 265.37 MWD 265.30 MWD 265.25 MWD 265.09 10 91.00 MWD 91.03 MWD 91.06 MWD 91.09 MWD 91.12 MWD 91.15 MWD 91.18 MWD 91.20 MWD 91.13 MWD 91.15 TO .. -- .-..---- .----...-- _'_n_____. ... . ..-...-.-.. .._n_.._- -------------------..----------------------------...-------.---..--..----.---------------. -..-. .---.....-...--------..--------------..--____--_n______.. 0 0 N m ~ ~ ;" ,3 " 0 ~ "O ~ ~ ¡¡: Õ Q. c ~ iî ifi c 0 J ð ø ð -~~- €M ~'ë~oo 0'" .-","'aa Z", CLaa""" 2~ ~~:êô ';'6 §,£g>~i6 _Z ~ g'~1ii-¡¡¡ 1;6°6 U) ;;; r- !.1 § -~. . iii ;1 ~ ~ ~ ~ ~ - a a æ '" a a '" '" g c- '" .g ~ n â ~ . ~ :;: '" in ~ ~~ g ~ g~ . ij! ~~ ~¡ -.n! ~ f¡;¡ . ." ~:> l '" a a ~ a a L~ '" a a a a a a a a ~ g g ~ g g g ~ [u!¡~¡oo ¡] (';)I.I~ON/(-)4¡I'IOeoS a a eo eo ~ a 0 ;:: ~ mm~mm . eo.o.oooooggg ~ â"ê~¡¡~¡¡~~¡¡~~. r gæggggggggggg i ò.~~~~~~~~~~~ ~ * mm~mm z . ~~~~~~t~~~~~" i ~ ~mmm~~~ ~ m~mmm ~ m~~~~mm . "'.......... . mmmm¡¡ . ggg~~~~æ~~~~g ~ ~~~~~~~~~~m ! - a a '" eo a a '" eo a ~ a a a '" a a æ '" a a '" '" a a Gi a a '" '" a a '" '" a a '" '" a a eo '" a a '" '" a a Vi a a .... g i: a~ a= 'i'o gO "'.... '" .... a -- f: + "'- glii ~ CII aW g;;;;.. "'~ a"'- ~ = gi: eo '" a a '" '" a a .,. a a a .,. a a i'i a a '" eo a a ¡;; a a if; a a '" eo a a co eo a a ;; a a i:5 § m~~ii a a L~ c- a a '" c- a ~ a a a a a a a a a a a a a a a a a a a a '" æ a-", eo .,. '" '" c- c- [u'!¡:uoo ¡.f Iudag "'¡e:»!¡Ja^ a~J.t a a a æ a a .,. '" a a eo '" a a '" '" a a ;;; a a a '" a a æ ¿ « r--- 0 ..- ..- ..... 0 0 N -- 0) ..- -- 0) a a '" a a c- a a '" a a '" a ~ a a eo a a '" a a a a a .... - I: a~ a.... æ .... 0 go "'T" ..... êo aO ¡¡Sli') M g.... "'.... a 1\'1 ~ ¡:: (I a ,- a.... eo ~ a Q gtn aiij ~ ~ ;; a ¡ a:> a ';' a a '" a a '? a a l' a a L? a a '9 a a ';- - a a '? ~ i ~~ .0 . < "".NO'..'...>- ð ~ g ~ ~ mm~mm -, a a q :e - a a a a a a a '" [ a a eo ';' a a ;! a a '" a a '" '" ';' a a æ ro ,,"/" " ( ," " ~ ~ ~ "CT 10,000 psi Pack-ûff lubricator 71/16" Annular Blind/Shear 71/16" Pipe/Slips . Pipe/Slips 71/16" Pipe/~/;~ . ... 7 "'~ IC 5,000 psi SWAB OR MASTER VALVE d-. tt 3/ II :;) lCZ :t II { { --- DATE 07/31/01 CHECK NO. 00194718 H 194718 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 072701 CK072701I PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it To Drill ee 8/H - Terrie Hub Ie X4628 \"5 . \ lç¡ A- -IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 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 No.H 194718 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 412 00194718 PAY , " , Of\lEHUNDRED & OO/100!if**~***************~;Jt;**************** US Df3LLAR , DATE AMOUNT Ô71 311 0 1 II $"100','~1 NOTVALID AFTER 120 DAYS' To The ORDER O-f 'ALAS~A OIL AND GAS. CONSERVATION COMMISSION 33~lWEST 7TH AVENuE SUITE 100 ANCHORAGE AK 99501 \2'.,.'" "'-"""'."""" '<' ß.." f fl" ",', if>:. $ ,r , 1.." (~ ~: ~ "",~{[t""l"~ '... , ""d'" ç III . g ... ? . a III I: 0 ... . 2 0 ~ a g 5 I: 0 0 a ...... . g III .. ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL V EXPLORATION INJECTION WELL INJECTION WELL RED RILL WELL NAME ¡;ß~ CHECK WHAT APPLIES ADD-ONS OPTIONS MULTI LA TERAL (If Bpi number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULA~D. I SAL NO / ANNULAR DISPOSAL L-) YES ANNULAR DISPOSAL THIS WELL / S" -/ ç; ;L} / "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal. of drilling wastes will not be approved. . . Annular Disþosal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-) YES + SP ACING EXCEPTION Templates are located m drive\jody\templates 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 tbat may occur. WELL PERMIT CHECKLIST COMPANY ¿f1 WELL NAME FIELD & POOL C "7òISr:J INIT CLASS ()t?-.;/ /-~J./ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is welibOre 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.. . . . . . . . . . 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. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . A¡~II¡IA 9(\;TE.. E 26. BOPE press rating appropriate; test to ~~O psig. ~r~ . 27. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued wlo hydrogen sulfide measures. . . . .. 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . PR cPA!Y 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~ 34. Contact name/phone for weekly progress reports (exploratory 0 ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. " to surface; .. .' (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: . UIC/Annular COMMISSION: Rpr- ~- wM----.. -8~s SF~ <0 JM ~R~ ENGINEERING GEOLOGY APPR DATE PROGRAM: exp - dev GEOL AREA r'!o Y N Y N Y N Y Y Y Y N, Y N Y N Y N Y N Y N Y N ~ ~ \ .,;,~~~ á«-~'\c,.\'\ "":, ~ \\ ~~ è}) ~ ~~~ ~ I ~ '{'(.~~ ~J. ~ ~ ~ ~~">~~ ~~ ~,,~'t~ $~ , § ~~">~ ~~~ ;).,9.35,,"->\. " . .. y ~ ~~ <;.\-0:\ ~ ~ ~ \\,. "> """ ~~ R ~ "'" ~ ~ "'" I ~ ~ ">~ G \:. ~ >- Y N Y h, /J~I serv wellbore seg _ann. disposal para req- UNIT# / (c. CoON/OFF SHORE ð AJ c 0 Z 0 -I ~ ;;0 f - -I' m - Z -I .J: - en » :xl m > { Y N Y N Comments/Ins tructions: - '116h>2io- t c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ( I! Well History File APPENDIX Information of detailed nature that is not " particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically "; : organize this category of information. ~ ~, (: ¿;;Oj~lCj ~ / O'6J3 **** REEL HEADER **** MWD 02/03/26 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/03/19 226187 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11516.0000: STOP.FT 13715.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD. FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 22 TOWN.N 11N RANG. 14E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 71 DMF KB EKB .F 71 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) Section from 13715' MD (8691' SSTVD) to 12800' MD (8695' SSTVD) was logged during a MAD pass. (4) Well 15-16A is an extension of the original well 15-16, kicked off at 11536' MD (8631' SSTVD). (5) Well 15-16A was drilled to 13715' MD (8691' SSTVD). (6) The interval from 13703' MD (8690' SSTVD) to 13715' MD (8691' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC Remark File Version 1.000 Extract File: Idwg.las 1.20 : NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration, Inc. 15-16A Prudhoe Bay Unit 854' SNL, 165' EWL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 17-Nov-01 500292111501 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 / ( (' (8) (Primary Depth Control) curve supplied by BPX (SWS, 18-Nov-2001). A Magnetic Declination correction of 26.58 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 19.15 ft. 23.61 ft. 2 19.95 ft. 24.41 ft. 3 19.95 ft. 24.41 ft. 4 18.98 ft. 23.44 ft. 5 18.95 ft. 23.41 ft. 6 18.95 ft. 23.41 ft. 7 18.95 ft. 23.41 ft. 8 18.75 ft. 23.21 ft. 9 18.66 ft. 23.12 ft. 10 20.46 ft. 24.95 ft. CURVE SHIFT DATA BASELINE, MEASURED, 11539.3,11538.7, 11549.0, 11549.4, 11578.1, 11583.4, 11605.5, 11616.9, 11637.3, 11649.8, 11690.2, 11702.9, 11708.0, 11718.3, 11907.6, 11913.8, 11954.7, 11967.4, 12215.9, 12218.5, 12234.4,12237.2, 12765.6, 12771.4, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX and GRAM Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration, Inc. 15-16A Prudhoe Bay Unit North Slope Alaska DISPLACEMENT -0.606445 0.404297 5.25293 11.3125 12.5254 12.7266 10.3027 6.2627 12.7266 2.62695 2.82812 5.8584 92 records... 8 bytes 132 bytes ( j{ ~ *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 18-Nov-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX13 ROPS13 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 API API 4 4 4 4 ------- 8 Total Data Records: 53 Tape File Start Depth 11516.000000 Tape File End Depth 13715.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 2 62 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN mwd.xtf 150 BP Exploration, Inc. ( ( WN FN COUN STAT 15-16A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples units Size Length 1 2 GRAX ROPS MWD MWD 68 68 1 1 API API 4 4 4 4 ------- 8 Total Data Records: 53 Tape File Start Depth 11516.000000 Tape File End Depth 13715.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 62 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/03/19 226187 01 **** REEL TRAILER **** MWD 02/03/26 ( ~.. , BHI 01 Tape Subtile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subtile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 11516.0000 36.4870 -999.2500 11516.5000 31.7211 -999.2500 11600.0000 20.7050 9.7396 11700.0000 124.7198 89.8283 11800.0000 47.5975 124.0132 11900.0000 39.7219 152.5905 12000.0000 46.2883 130.8261 12100.0000 31.7884 150.4573 12200.0000 56.7568 134.7984 12300.0000 63.1760 108.9674 12400.0000 55.3981 153.4598 12500.0000 55.1264 142.1518 12600.0000 72.8686 129.5689 12700.0000 55.5981 108.4849 12800.0000 47.8927 88.4280 12900.0000 34.4708 78.6496 13000.0000 126.3605 48.3132 13100.0000 138.2161 56.4604 13200.0000 128.1724 42.5271 13300.0000 44.4876 55.8812 13400.0000 38.3227 97.9882 13500.0000 27.6509 67.0331 13600.0000 56.0678 71.1829 13700.0000 74.0038 16.8027 13715.0000 -999.2500 -999.2500 Tape File Start Depth 11516.000000 Tape File End Depth 13715.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 11516.0000 -999.2500 -999.2500 11516.5000 36.8760 -999.2500 11600.0000 23.5270 7.8320 11700.0000 57.3190 57.9590 11800.0000 49.3430 124.8430 11900.0000 59.6710 151.2480 12000.0000 36.3300 134.2260 12100.0000 43.0460 73.7760 12200.0000 55.2200 136.0290 12300.0000 60.9970 104.1140 12400.0000 57.1090 151.6500 12500.0000 73.1670 144.0000 12600.0000 63.8860 128.2200 12700.0000 54.3650 125.5260 12800.0000 -999.2500 79.2480 12900.0000 34.7570 77.9510 13000.0000 124.3580 13.2850 13100.0000 149.8750 123.3770 13200.0000 137.7050 55.3920 13300.0000 41.2020 84.7290 13400.0000 31.2720 106.0330 13500.0000 32.0120 75.3600 r 13600.0000 13700.0000 13715.0000 ii 43.6070 -999.2500 -999.2500 ,,{'( \ 20.6640 12.5100 0.4990 Tape File Start Depth 11516.000000 Tape File End Depth 13715.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS