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Home My WebLink About201-162 . he.. 1/17'/ð6 šfÀ TE OF ÁLASKA I ALASKA OIL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,Ka Oil & Gas Cons. Commission RECEIVED SEP 1 3 2006 1 a. Well Status: DOil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. Well Class: Anchorage 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/11/2006 201-162 306-135 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 12/12/2001 50-029-22480-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/16/2001 PBU 15-36A 1440' FNL, 887' FWL, SEC. 22, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 4865' FSL, 3916' FWL, SEC. 15, T11N, R14E, UM 65.75 Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 4997' FSL, 2921' FWL, SEC. 15, T11N, R14E, UM 12996 + 8775 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 676825 y- 5960062 Zone- ASP4 13010 + 8776 Ft ADL 028306 TPI: x- 679692 y- 5966437 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 678695 y- 5966545 Zone- ASP4 N/A MD DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: MWD, GR, Memory CCL I GR, CNL 22. CASING, LINER AND CEMENTING RECORD .' (' A ~,.,... . SETTING DEPTH Mb SETTING DEPTHTvD ..... , <....... ,i [-'. ~. < "'S;~~ <Wr.PERFT: GRADE Top BOTTOM Top BOTTOM SIZE .,..", ./ I' PIJltED 20" 91.5# H-40 30' 110' 30' 110' 30" 260 sx Arctic Set (ADDrox.) 10-3/4" 45.5# L-80 35' 3907' 35' 3565' 13-1/2" 1105 sx PF 'E' 375 sx Class 'G' 7-518" 29.7# NT95HS 3~' 11119' 33' 8333' 9-7/8" 1617 sx Class 'G' 5-1/2" 17# NT80 10965' 11425' 8197' 8612' 6-3/4" 126 sx Class 'G' 3-1/2" x 3-3/16" 8.81# 16.2# L-80 1 0923' 13010' 8160' 8776' 3-3/4" 66 sx Class 'G' x 2-7/8" x 6.16# 23. Perforations open to Production (MD + TVD of Top and 24. ..'/' .... IIRII\Ìt:>'{""nl>" iT, .././, / y.. Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-112", 12.6#, L-80 10365' - 10966' 10904' MD TVD MD TVD 25. ..,t\¢ID,i"" . r.",A...t.lT .'~ 'ETÖr·/·· /, // '·x/ SCANNED SEP 14 2005 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED -10697' P&A w/21.5 BBls Class 'G' Cement 10117' Set EZSV 10097' Set Whipstock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-Bsl CHOKE SIZE GAS-Oil RATIO TEST PERIOD . Flow Tubing Casing Pressure CALCULATED Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE+ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 o R \ G \ N t\tINUED ON REVERSE SIDE RBDMS 8Ft $EP 1 4 2006 ~ 2,8. GEOLOGIC MARKE 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 1 11790' 8745' None 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date Dq 13/o~ PBU 15-36A Well Number 201-162 306-135 Permit No. I A roval No. Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 Barbara Lasley, 564-5126 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . 15-36B Prudhoe Bay Unit 50-029-22480-02 206-073 Accept: Spud: Release: Ri: 07/03/06 07/09/06 07/15/06 Nabors 27E Accept: Spud: Release: Ri: PRE-RIG WORK 06/07/06 ATTEMPTED TO Ea. TTP WI NO SUCCESS. CURRENTLY BAILING SCHMOO OFF TOP OF TTP AT 10.813' SLM WI PUMP BAILERS. 06/08106 BAILED SCHMOO OFF TOP OF TTP AT 10815' SLM. PULLED 41/2 XX TTP FROM 10815' SLM, DRIFT WI 2.25" CENT TO 11558' SLM. STOPPED DUE TO DEVIATION (65 DEG DEV). 06/11/06 RIH WITH 2.5" BON. CORRECT DEPTH AT TOL. LOAD WELL WITH 1% KCL. WELL IS TIGHT. CIRCULATE GAS OFF OF TOP OF IA. TOP WELL WITH 100 BBLS DIESEL. POSITION NOZZLE ABOVE THE LINER AT 10913'. PUMP 21.5 BBLS CEMENT. BULLHEAD 18 BBLS INTO LINER (THIS MAY NOT BE EXACT BECAUSE OF THE RESIDUAL GAS IN THE IA. SOME CEMENT MAY HAVE COME NORTH). ESTABLISHED 1000 PSI BUMP IN WHP. LAY IN REMAINING 3.5 BBLS IN TUBING UP TO 10700'. PULL TO SAFE. RBIH AND CONTAMINATE TO 10695'. POH CHASING AT 80%. TOP WELL OFF TO 2500' WITH DIESEL. SECURE WELL WITH 300 PSI WHP. JOB COMPLETE. 06/13/06 DRIFTED W/3.70 CENT AND SAMPLE BAILER, TAGGED TOP OF CEMENT AT 10,697' SLM. PRESS. TUBING AND IA UP TO 1500# WITRIPLEX. CMIT PASSED ON FIRST ATTEMPT. BLED BACK TO 100#. WELL LEFT S/I ON DEPARTURE. 06/16/06 JET CUT TUBING AT 10365' WITH 3.65" POWERCUTTER. GOOD INDICATION OF CUT. JOB COMPLETE- WELL SHUT IN. · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 5-36 1 5-36 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 7/2/2006 Rig Release: 7/15/2006 Rig Number: Spud Date: 9/14/2001 End: 7/15/2006 7/1/2006 00:00 - 03:00 3.00 MOB P PRE RID Floor, Blow Down All lines, Separate All Complexes 03:00 - 04:00 1.00 MOB P PRE Remove Berms from Around Rig 04:00 - 12:00 8.00 MOB P PRE Move All Support Complexes off 15-02B 12:00 - 20:00 8.00 MOB P PRE Move Substructure from 15-02B to 15-36B and Spot over Wellhead. 20:00 - 00:00 4.00 MOB P PRE Set Pipesheds 7/2/2006 00:00 - 06:00 6.00 MOB P PRE Set Pit, Motor and Pump Complexes. 06:00 - 18:00 12.00 MOB N HMAN PRE Start Investigation of Geronimo Line Incident. Identified Possible Hazards Associated with Damaged Derrick Platform. Developed Safe Work Plan to Remove Platform from Derrick. Preliminary Investigation Completed. 18:00 - 20:00 2.00 MOB N HMAN PRE Removed Derrick Platform According to Safe Work Plan. 20:00 - 21 :00 1.00 MOB P PRE Held PJSM, Plan Forward to Get Rig Operational, Pre-Spud Meeting with Rig Crew, MWD and Mudman. 21 :00 - 00:00 3.00 MOB P PRE Finalize Rig Acceptance Check List, Addressed All Outstanding Issues on Check List. 7/3/2006 00:00 - 01 :00 1.00 WHSUR P DECOMP ACCEPTED RIG FOR OPERATIONS AT 0001, 7/3/2006. Installed Double Annulus Valves on IA and OA. 50 psi on OA. o psi on IA. 01 :00 - 02:30 1.50 WHSUR P DECOMP PJSM, P/U and RlU DSM Lubricator. Pull BPV. RID and UD Lubricator 02:30 - 04:30 2.00 WHSUR P DECOMP PJSM, RlU Circulating Lines to Top of Tree and IA from Circulating Manifold. 04:30 - 05:00 0.50 WHSUR P DECOMP Fill All Circulating Lines with Water. Tested Circulating System to 3,500 psi. 05:00 - 08:30 3.50 WHSUR P DECOMP PJSM, Pump 35 bbls Down 7-5/8" 4-1/2" Annulus at 3 bpm, 150 psi. Taking Returns from Tubing Through Choke Manifold to Slop Tank. Shut Down Pumps and Line Up to Pump Down Tubing. Pump 25 bbl Safe-Surf Pill Followed by 430 bbls 120 deg Water Down Tubing Taking Returns from IA Through Choke Manifold To Slop Tank. Final Circulating Pressure 210 psi. 08:30 - 09:30 1.00 WHSUR P DECOMP Set TWC and Pressure Test from Below to 1,000 psi. Bled Down All Pressure to 0 psi and Close Well In. 09:30 - 10:30 1.00 WHSUR P DECOMP Blow Down Circulating Lines and RID Same. 10:30 - 13:30 3.00 WHSUR P DECOMP PJSM, N/D Tree and Adapter Flange. 13:30 - 14:30 1.00 WHSUR P DECOMP Installed 4-1/2" NSCT XO in Tubing Hanger to Check M/U Integrety of the Threads for Pulling Tubing. Made Up 7-1/2 Turns. 14:30 - 22:00 7.50 BOPSU P DECOMP PJSM, N/U BOPE's, M/U Choke and Kill Lines, Installed Drilling Riser and RlU Flowline. Secure BOPE's with Turnbuckles and Pressure Up All Air Boots. 22:00 - 22:30 0.50 BOPSU DECOMP Energized Accumulator and Function Teted and BOPE Components. 22:30 - 23:30 1.00 BOPSU DECOMP P/U 4-1/2" Test Joint. M/U Testing Sub and Floor Safety Valve. Installed Test Joint. 23:30 - 00:00 0.50 BOPSU DECOMP RlU BOPE Testing Equipment. 7/4/2006 00:00 - 09:00 9.00 BOPSU DECOMP Tested BOPE's Utilizing 4-1/2" Test Joint. Test All Rams, Annular, Choke and Kill Line Valves, Choke Manifold and Floor Safety Valves to 250 psV 3,500 psi. All Tests held 5 min each. Witness of Test Waived by AGOCC Rep. John Crisp. Test Witnessed by BP WSL Rodney Kleqzig & Chris Clemens / Nabors Toolpushers Alan Lunda & Rick Brumley Printed: 8/14/2006 11:21:54AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 5-36 1 5-36 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: Rig Release: Rig Number: 7/2/2006 7/15/2006 Spud Date: 9/14/2001 End: 7/15/2006 09:00 - 11 :30 2.50 DHB P 11 :30 - 12:00 0.50 PULL P 12:00 - 12:30 0.50 PULL P 12:30 - 13:30 1.00 PULL P 13:30 - 14:00 0.50 PULL P 14:00 - 15:30 1.50 PULL P 15:30 - 21:00 5.50 PULL P 21 :00 - 21 :30 0.50 PULL P 21 :30 - 00:00 2.50 PULL P 7/5/2006 00:00 - 06:30 6.50 PULL P 06:30 - 07:00 0.50 PULL P 07:00 - 08:00 1.00 PULL P 08:00 - 13:00 5.00 DHEOP P 13:00 - 15:00 2.00 DHEOP P 15:00 - 18:30 3.50 DHEOP P 18:30 - 20:30 2.00 DHB P 20:30 - 21 :00 0.50 DHB P 21 :00 - 23:30 2.50 EVAL P Testing Sequence; (1.) Bottom Pipe Rams, Floor Safety Valve, (2.) Top Pipe Rams, Kill HCR, Choke Valves 1 & 2 (3.) Choke Valves 3,4,5 & 6, (4.) Choke Valves 7,8 & 9, (5.) Choke Valves 10, 11 & 12, (6.) Manual Kill, Choke Valves 13, 14 & 15, (7.) Choke Line HCR, (8.) Choke Line Manual, (9.) Annular, (10.) Accumulator Test, Starting Pressure 2,825 psi, After Closure 1,525 psi, Initial 200 psi Recovery 50 see, Final Pressure 2,825 psi, Full Recovery Time 1 min 50 see., (11.) Blind Rams, (12.) IBOP Top Drive, (13.) Lower Safety Valve - Top Drive. DECOMP Rig down test equipment, blow down choke line, PJSM with rig site maintenance, pull two way check with lubricator. DECOMP Pick up 1 jt 4" dp and XO to 4.5" nsct, screw into tubing hanger 7.5 turns, make up topp drive to drill pipe to pull tbg hanger. DECOMP Check alignment of choke manifold, pull tubing hanger to rig floor. No problem pulling hanger out of spool. Up wt=150k. Monitor well for flow, well static. DECOMP Circulate a bottoms up at 315 gpm at 300 psi. Pick up 4.5" handling equipment and rig up same. DECOMP Monitor well and pump dry job. MW in/out=8.4 ppg. DECOMP Terminate control line, lay down landing jt and tubing hanger. rig up Schlumberger to spool SSSV control line when 4.5" tubing is being laid down. DECOMP POH laying down 52 jts of 4.5" tubing. DECOMP Lay down SSSV, rig down SSSV control line spooler. Retrieved 28 out of 31 stainless steel bands. DECOMP Lay down 38 jts of 4.5" tubing for a total of 90 jts. DECOMP Continue laying down 4.5" tubing for a total of 247 jts, one 20.61' stub, 3 gas lift mandrels, and 3 pup jts. DECOMP Make up running tool and set wear ring. DECOMP Clear floor, rig down tubing tongs and handling equipment. DECOMP Rig up Schlumberger, Run #1- Gamma Ray, Junk Basket, and 6.75" Gauge Ring. Tagged stump up at 10,357'. Recovered 2 stainless steel bands. DECOMP Run #2 - Rerun Junk Basket and recovered 1 stainless steel band for a total of 31 bands DECOMP Rig up EZSV plug, GR, and CCL, run in hole and set at 10,117', pull out of hole and rig down Schlumberger. DECOMP Pull wear bushing, rig up and test 7-5/8" casing to the EZSV to 3,500 psi for 30 minutes and record on chart. DECOMP Rig up to pull 10-3/4" x 7-5/8" pack off, open bottom annulus, no flow. Pull pack off. DECOMP As pack off was being pulled the well started flowing. Monitored well until stack was full. Blind rams were closed and we monitored well from 21: 15 to 22:45 hrs. Notifications were made to Anchorage Rig Team and AOGCC State Inspector Jeff Jones. Casing pressure built from 80 psi to 120 psi. From 22:45 to 22:50 we bled 11 bbls through the choke line through the gas buster, taking returns into the cuttings tank. The well was shut in and monitored the well for 10 minutes to 23:00, building from 40 psi to 80 psi. From 23:00 to 23:05 another 11 bbls were bled off. The well was shut in and from 23:05 to Printed: 8/14/2006 11:21:54AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-36 15-36 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 7/2/2006 Rig Release: 7/15/2006 Rig Number: Spud Date: 9/14/2001 End: 7/15/2006 7/5/2006 21 :00 - 23:30 2.50 EV AL P DECOMP 23:15 the well the pressure went from 20 psi to 50 psi. From 23:15 to 23:25 we bled another 9 bbls, shut the well in and monitored the well from 23:25 to 23:30. In this 5 minutes the well stayed at 20 psi. Gained a total of 65 bbls of dead crude at 7.3 ppg. 23:30 - 00:00 0.50 DHB P DECOMP The choke was opened and flow was monitored into the cuttings tank. The flow slowed to a 1.5" stream. At this point the blind rams were opened and the cellar pump was turned on to suck the stack out through the lower annulus. After the stack was sucked out we installed and energized the 10-3/4" x 7-5/8" pack off and tested it at 5,000 psi for 10 minutes. 7/6/2006 00:00 - 00:30 0.50 DHB DECOMP Lay down pack off running tool. 00:30 - 02:30 2.00 BOPSU DECOMP Test top pipe rams, bottom pipe rams, and hydril to 250 psi low and 3,500 psi high for 5 minutes each. Record on chart. Witnessed by WSL Charlie Noakes and Nabors TP Rick Brumley. 02:30 - 03:00 0.50 BOPSU DECOMP Circulate water through choke line and gas buster to clear dead crude. 03:00 - 03:30 0.50 BOPSU DECOMP Blow down choke line and mud lines to rig pumps. 03:30 - 04:00 0.50 CLEAN DECOMP Install wear bushing, RILDS. 04:00 - 05:00 1.00 CLEAN DECOMP Clear and clean rig floor. 05:00 - 07:00 2.00 CLEAN DECOMP PJSM, Pick up mule shoe and 27 jts of 4" dp 1 x 1. 07:00 - 14:30 7.50 CLEAN RREP DECOMP Replace landing outside derrick board, rig up and secure geronimo line. 14:30 - 15:30 1.00 CLEAN P DECOMP POH and stand back 9 stands 4" dp. 15:30 - 16:00 0.50 BOPSU P DECOMP Test blind rams to 250 psi low and 3,500 psi high for 5 minutes each. Witnessed by WSL Chris Clemens and TP Dave Hanson. 16:00 - 19:00 3.00 CLEAN P DECOMP Pick up window mill, bit sub, string mill, 1 jt 3.5" hwdp, bumper sub, 124.75" spiral dc's, and a xo. 19:00 - 21 :30 2.50 CLEAN P DECOMP Trip in picking up 4" dp 1 x 1 to 2,054'. 21 :30 - 00:00 2.50 CLEAN P DECOMP Cut and slip drilling line. 7/7/2006 00:00 - 02:00 2.00 CLEAN P DECOMP Inspect and adjust draw works brakes. 02:00 - 11 :30 9.50 CLEAN P DECOMP Trip in picking up 4" dp 1 x 1, tag EZSV at 10115'. 11 :30 - 12:00 0.50 CLEAN P DECOMP Circulate bottoms up at 420 gpm, 2,750 psi, MW=8.4 PP9 in/out, UW=170k, DW=150k, RW=160k. 12:00 - 16:30 4.50 CLEAN P DECOMP POH to bha. 16:30 - 18:30 2.00 CLEAN P DECOMP Stand back 4 stands of dc's in derrick 18:30 - 19:00 0.50 STWHIP P WEXIT Pick up MWD, UBHO sub and orient to whipstock slide. 19:00 - 21:30 2.50 STWHIP N SFAL WEXIT Trouble shoot MWD, could not communicate with the tool at surface. 21 :30 - 22:00 0.50 STWHIP P WEXIT Surface test MWD tool. OK 22:00 - 00:00 2.00 STWHIP P WEXIT TIH with whipstock assy. 7/8/2006 00:00 - 07:30 7.50 STWHIP P WEXIT TIH with 7-5/8" whipstock to mill 6-3/4" window. Fill dp every 30 jts. 07:30 - 08:30 1.00 STWHIP P WEXIT Set 7-5/8" whipstock at 71 degrees right of highside. TOW=10,097', BOW=10,110'. 08:30 - 10:30 2.00 STWHIP P WEXIT Displace water out of well with 9.9 ppg LSND mud. Pumped 50 bbl high visc spacer, YP of 75, visc of 300, pump 440 bbls 9.9 ppg LSND mud, visc 45, at 350 gpm at 2,150 psi. 10:30 - 17:00 6.50 STWHIP P WEXIT Mill window from 10,097' to 10,110', pumped 150 visc sweep, drill new formation from 10,110' to 10,124'. UW=154k, DW=140k, RW=145k, 100 rpm's, 350 gpm at 2,400 psi, 5k Printed: 8/14/2006 11:21:54AM I . . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-36 15-36 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 27E Start: 7/2/2006 Rig Release: 7/15/2006 Rig Number: Spud Date: 9/14/2001 End: 7/15/2006 7/8/2006 10:30 - 17:00 17:00 - 18:30 18:30 - 20:00 20:00 - 21 :30 21 :30 - 23:00 7/9/2006 23:00 - 00:00 00:00 - 04:00 04:00 - 07:30 07:30 - 08:00 08:00 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 13:30 13:30 - 17:00 17:00 - 18:00 18:00 - 00:00 7/10/2006 20:00 - 21 :00 21 :00 - 22:00 22:00 - 22:30 22:30 - 00:00 7/11/2006 00:00 - 02:00 6.50 STWHIP P 1.50 STWHIP P WEXIT WEXIT 1.50 STWHIP P WEXIT 1.50 STWHIP P 1.50 STWHIP P WEXIT WEXIT 1.00 STWHIP P 4.00 STWHIP P 3.50 STWHIP P WEXIT WEXIT WEXIT 0.50 STWHIP P 1.50 STWHIP P WEXIT WEXIT 0.50 STWHIP P 0.50 STWHIP P 3.00 STWHIP P WEXIT WEXIT WEXIT 3.50 STWHIP P 1.00 STWHIP P WEXIT WEXIT 6.00 DRILL P INT1 17.50 DRILL P INT1 P INT1 1.00 DRILL P 1.00 DRILL P 0.50 DRILL P 1.50 DRILL P 2.00 INT1 DRILL P DRILL P INT1 INT1 2.00 DRILL P INT1 WOB, 50% increase in cuttings when sweep returned. Pump weighted sweep. 11 ppg, 85 yp. UW=154k, DW= 140k, MW in/out=9.9 ppg. 350 gpm @ 2,400 psi. No increase in cuttings retums. Perform FIT to 11.5 ppg, 625 psi. Held 10 minutes, bled down to 560 psi in 10 minutes. Passed test. Pumped 1 bbl, gained 1 bbl back after bleeding off pressure. MAD Pass up from 10,000' to 9,870'. Pump 24 bbl super sweep, MW 9.9 ppg, visc 70, YP 35, 300 gpm @ 1,900 psi, 20 rpm's. No significant increase in cuttings returns. Circulate while taking blower hose off of TD. Build dry job. Pump dry job. POH to 4-3/4" dc's. Lay down 124.75" dc's, bumper sub, UBHO sub, MWD, float sub, 1 Jt HWDP, upper string mill, bit sub, and starting mill. Back out LDS, pull wear ring. P/U stack flushing tool, flush the stack of metal cuttings, function rams, flush choke and kill lines. Install wear ring, RILDS. Rig Service. P/U bit, motor, float sub, stab, MWD, initialize MWD, P/U 3 nmfdc's, jar, and xo sub. Shallow pulse test MWD TIH to shoe filling dp every 30 stands. Install TD blower hose, set block height, orient motor to 70R, get slow pump rate, exit window to 10,124'. Directiona drill from 10,124' to 10,195'. UW 152k, DW 138k, RW 150k, 350 gpm @ 2,800 psi, WOB 5k, TO on 4k, TO Q 3.5k, RPM's 50, MW 9.9 ppg in/out. AST=2.55, ART= TDT =2.8. Directional drill from 10,195' to 10,988'. RW 150k, 320 gpm @ 2,850 psi, WOB 3.5k, RPM's 100, MW 9.9 ppg info Pump high visc sweep, 200 v· ,40 yp, 9.9 ppg mw. 25% increase in cuttings whe weep came back. Noticed 1/2" long splintered shale co . g over the shaker. Backed off the pump to 275 gpm a owed the rotary to 80 rpm's. MW 9.9 ppg in/out. Mo' ed well 10 minutes, pumped dry job, and short tripped stands into the shoe. No tight spots, no overpull coming through the window. Service rig. 't window with no problems, TIH to 10,988'. No problems. Stag mps up slowly to 275 gpm @ 2,000 psi and 80 rpm's. Pumped tì visc sweep, YP 45, MW 9.9 ppg, Circulate 3 bo s up at 275 gpm @ 2,000 psi and 80 rpm's. Once the sweep ca back we saw a 30% increase in cuttings with large splintered sha nce the sweep was gone the splintered shale diminished q I. MW 9.9 ppg in/out. Monitor well 10 minutes, pump dry POH to shoe, no problems. Drop 2.5" 0 bbit with 100' of tail, continue to pull out of the hole to the bha. S[ correction. UD 2 jts dp, xo, jar, three 4.75" NMDC's, MWD, stab, e e ~:,~ \"'" I' i ~", I~ :1J; u IT,i rÞ," rm u J: l1U FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ",':f/',(!, IUô.n~·- '..,p,,-:.(¡-.¡:~w';.:l;:r:; ~, àV ,-- I (p ~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-36A Sundry Number: 306-135 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any requÜred test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this /1 day of April, 2006 Encl. rn 4llt/Dl; tfJC~/7k . STÀtE OF ALASKA . ' ALASKA ~L AND GAS CONSERVATION COMMISSION APR 0 7' 2006 APPLICATION FOR SUNDRY APPROV~b Oi! & Gas Ctms. Commission 20 MC 25.280 Anchorage ~Ë'C~j~~ 1. Type of Request: 181 Abandon / o Suspend o Operation Shutdown o Perforate o Other o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 201-162 / 13. Address: D Stratigraphic D Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22480-01-00 7. KB Elevation (ft): 65.75 9. Well Name and Number: PBU 15-36A ./ 8. Property Designation: 10. Field / Pool(s): ADL 028306 Prudhoe Bay Field / Prudhoe Bay Pool Itt;( '/ ,ii. .>,.i« (i '..,' ,n"" '..iii. .....,./.........«. .//....... ./...,../i Total Depth MD (ft): Total Depth TVD (ft):1 Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13010 8776 12996 / 8775 None None Casinq Length Size MD I TVD Burst Collapse Structural Conductor 80' 20" 110' 110' 1490 470 Surface 3872' 10-3/4" 3907' 3565' 5210 2480 Intermediate 11 086' 7-5/8" 11119' 8333' 8180 5120 Production 460' 5-1/2" 10965' - 11425' 8197' - 8612' 7740 6280 Liner 2087' 3-112" x 3-3/16" x 2-7/8" 10923' -13010" 8160' - 8776' 10160 10530 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I T~~~ Size: ' Tubing Grade: I Tubing MD (ft): 12000' - 12990' / 8747' - 8775' /1/ ',12.6# L-80 / 10966 Packers and SSSV Type: 7" x 4-1/2" Baker SABL-3, 4-1/2" BKR KB L T, 7-5/8" x Packers and SSSV MD (ft): 10904',10923',10972', 5-1/2" BKR 'H', 4-1/2" Cameo SSSV Nipple 2228' / 12. Attachments: 13. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: / Commencing Operations: May 15, 2006 / DOH DGas D Plugged 181 Abandoned 16. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Barbara Lasley, 564-5126 Printed Name J?3ve Wesl~y" Title Senior Drilling Engineer Date r'/ö7/od: Prepared By Name/Number: SiQnature Aiftlí( ¡IÚ¿c, é1- Phone Sondra Stewman, 564-4750 / / {/ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ( ?iY 0 - ~ D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance RBDMS BFl APR 1 1 2aa6 Other: T e t., t- goPE fv "šS'oo pyt\. A-,?P ~'O l/td k;yW\.... / t) ~ 40 I (~Õ~d f.o" ç,; JebO<-(£" w..e tl IS~~bß. Subsequent Form Required: \0 - 40~11 ~ U~"A ~MISSIONER APPROVED BY Oat. JIIIJ It) b Approved By: THE COMMISSION Form 10-403 Revised 07/2005 ,l{ V"V L-/ Sfbmit Ih Duplicate o RIG IJ /; L e e Obp GL&ArAry To: Winton Aubert - AOGCC Date: April 7, 2006 From: Barbara M. Lasley - BPXA GPB Rotary Drilling Subject: 15-36A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of P8U well 15-36A. Well 15-36A is an Ivishak producer that is currently shut-in for tubing by IA communication. The well has been shut in and secured with an XX plug set at 10,841' MD, Well 15-36 was sidetracked in December 2001. 15-36A was a full time producer until 2004 when it was first shut in for gas. At the time the GOR was climbing through marginal and the well would have begun cycling. Unfortunately the well developed TxlA and an LDL showed 5 or more tubing leaks. The well was shut-in and secured with a TIP. The plan is to exit the 15-36A wellbore at -10,100' md, A whipstock will be run and a 6-3/4" window will be milled in the 7-5/8" casing. A 6-3/4" hole will be drilled to the Top of the Sag River formation. A 5-1/2" liner will / then be run and cemented, The 4-3/4" wellbore then builds to horizontal, landing in Zone 1 A, with an option to toe up into Zone 18. The planned well runs horizontally for approximately 950 feet. A solid 3-1/2" production liner will be cemented in place. The 15-368 sidetrack is currently scheduled for Nabors 27E beginning the third week of June, 2006. The pre- rig work for this sidetrack will be priority scheduled once Sundry approval has been obtained. Estimated Pre-Rig Start: Estimated Spud Date: 05/16/06 06/19/06 8arbara M. Lasley Q~>«Y4 ~ £Rotary Drilling Engineer Ph: 564-5126 cc: Well file Terrie Hubble / Sondra Stewman 15-36A Application for Sundry e e 15-368 Operations Summary Pre-Ria Operations: 1. CMIT/MIT-OA complete Jan 2006. Tests passed 3500 psi CMIT TxlA and 2000 psi MIT-OA 2, Replace all live gas lift valves with dummy valves and fluid pack as necessary for CT P&A. 3, R/U SL and drift the 4-1/2" tbg down to the 3-1/2" liner top- @ 10923" MD 4. RIH with CT and P&A the 15-36A well bore. Pump 1r1~b1S of 15.8 ppg cement, leaving TOC in the 4- 1/2" tbg at -10,700' MD. Cement volume based on t~l~wing calculations: o 1506' of 2-7/8" liner (cap. = 0.0058 bbl/ft) = 8.7 bbls ~ o 126' of 3-3/16" liner (cap. = 0.0076 bbl/ft) = 1,0 bbls o 455' of 3-1/2" liner (cap. = 0.0087 bbl/ft) = 4.0 bbls o 223' of 4-1/2" liner (cap. = 0.0152 bbl/ft) = 3.4 bbls / 5. RIH with the appropriate jet cutter and cut the 4W' tubing at -10,400' MD 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 7. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all lock down screws, repair or replace as needed, 8. Bleed casing and annulus pressures to zero. 9. Set a BPV. Secure the well. Level the pad as necessary. Ria Operations: 1. MIRU Nabors rig 27E. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Run TWC. 3. Nipple down tree. Nipple up and test BOPE to ~i high, 250 psi low. -- 4. RU. Pull 4-1/2" tubing from the cut at -10,400' ~ 5. RU E-line. 6. MU 6.75" gauge ring I junk basket I CCL. RIH and tag tubing stump. POH. 7. RIH with CIBP. Set bridge plug at -10,118', as required to avoid cutting a casing collar while milling the window. POH. 8. RID E-line. 9. Pressure-test the 7-5/8" casing and CIBP to 3,500psi for 30 minutes. Record test rw, lO· c\J~' PU and RIH with 7-5/8" Baker bottom-trip anchor whip stock assembly on 4" DP. Orient whip stock to 85 ';> ( deg right of high side and set on bridge plug. Shear off of whip stock. ~~W\l~ . 11. Displace the well to 9.9 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 12. Mill window in 7-5/8" casing at ± 10,100' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 13. Pull up into 7-5/8" casing and conduct an FIT to 11.5 ppg EMW. POH. 14. MU 6-3/4" Dir/GR assembly. RIH, kick off and drill the 6-314" intermediate section to the 5 1/2" liner point at top of the Sag River, as per the directional plan. 15. Run and cement a 5-1/2",17#, L-80 Hydril521 flush joint intermediate drilling liner. 16. Test casing and liner lap to 3,500 psi for 30 minutes, chart same. 17. MU 4-3/4" Dir/GR/Res assembly on 2-7/8" DP. RIH to the 5-1/2" liner landing collar. 18. Drill out the 5-1/2" liner float equipment and cement to the shoe. 15-36A Application for Sundry e e 19. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 20. Drill out the 5-1/2" shoe plus -20' new formation, pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to TD per directional proposal. 21. Circulate well bore clean, short trip to shoe, circulate. POH. 22. Run and cement 3%", 9.2#, L-80, IBT-M solid production liner. During displacement spot a perf pill inside the 3-1/2" liner. POH. 23. MU and RIH with DPC perf gun. Planned perfs are 2" PowerJet Omegas at 6 spf. 24. MU and run a 3%,',9.2#, 13Cr, VamTop tubing completion, stinging into the 3W' liner tie back sleeve. 25. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 26. Set a TWC and test. 27. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 28. Freeze protect the well to -2,200' TVD with diesel. Secure the well. 29. Rig down and move off. Post-Riq Operations: 1. MIRU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. 15-36A Application for Sundry TREE = 4-1/16" CrN ~NOTES: WELLANGLEIS>700@ WELLHEAD = FMC e 15-36A ACTUA TOR = BAKER C 11600' & > 900@ 11740'.**LOST 4-1/2" X KEY KB. ELE\! = 65.8' 2"x 1-1/2" X 1/4" (12/11/05)** BF. ELE\! = NA KOP- 1721' Max Angle = 96 @ 11793' I 2228' -f4-1/2" CAMCO SSSV NIP, ID = 3.812" I Oatum MO = N/A . OatumTVO= 8800' SS GAS LIFT MANORELS ST MD TVO DE\! TYÆ VLV LA TCH PORT OATE 110-3/4" CSG, 45.5#, L-80, 10 = 9.950" H ~~ 1 3542 3248 45 CAMCO DMY BK 0 08/02/04 3907' L ~ 2 6961 5432 52 CAMCO DMY BK 0 08/02/04 3 9502 7037 48 CAMCO DMY BK 0 08/10/01 ~ 4 10814 7999 33 CAMCO DMY BK 0 08/10/01 ./~ Minimum ID = 2.377" @ 11504' I 10841' -14-1/2" HES X NIP, ID = 3.813" I 3-3/16" X 2-7/8" LINER XO I . :8 ¡.",-." I 10904' -17" X 4-1/2" BAKER SABL-3 PKR, 10 = 3.875" F-'" '"' 10923' 1-14-1/2" BKR KB L T PKR, 10 = 2.560" I 1 I 10928' -13.70" BKROEA...OYMENTSLV,10=3.00" I TOPOF 3-1/2" LNR, 9.3#, 10 = 2.972" I 10934' II I 10937' -14-1/2" HES X NIP, ID = 3.813" (BEHIND PIPE) I II 10954' 4-1/2" HES XN NIP, MILLED ID = 3.80" (BEHIND PIPE) H 10965' -1 TOP OF BAKER TIEBACK SLY, ID = 6.38" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 10965' I I 10966' 1-14-1/2" TBG TAIL WLEG, 10 = 3.960" (BEHIND PIPE) I 17-5/8" X 5-1/2" BKR H PKR, 10 = 6.56" I 10972' I ~ r 17 -5/8" X 5-1/2" BKR LNR HGR, 10 = 6.56" I 10978' ,It I 10957' H ELMO TI LOGGED 07/24/95 I 5-1/2" LNR MILLOUT WINDOW I 7-5/8" CSG, 29.7#, NT-95 HS, 10 = 6.875" I 11119' ~ ... 11428' - 11435' (OFF WHIPSTOCK) 1 TOP OF WHIPSTOCK I 11430' I ....... I 11378' 1--13-1/2" X 3-3/16" LNR XO, 10 = 2.786" I .,,~ :'-~ IRA TAG 11439' I 1 11504' 1-13-3/16" x 2-7/8" LNRXO, ID = 2.377" I PERFORA TION SUMMARY REF LOG: SWS CNL/GR ON 12/18/01 ANGLEATTOPÆRF: 81 @ 12000' Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz OATE 2" 4 12000 - 12390 C 12/21/01 2" 4 12440 - 12690 C 12/21/01 2" 4 12780 - 12990 C 12/21/01 Y 12-7/8" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.377" I 13010' I 5-1/2" LNR, 17#, NT-80, 10 = 4.892" 11813' I OATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNrr 06/09/94 ORIGINAL COM PLETION 09/24/05 MOR/TLH XX TIP SET (08/06/04) WELL: 15-36A 12/21/01 CH/KAK CTD SIDETRACK 12/11/05 OAV/PJC SFTY NOTE & PULL TIP @ 10841 PERMrr No: ~011620 09/24/01 A TTEM PT CTD SIDETRACK API No: 50-029-22480-01 06/13/03 CMOITLP KB ELE\! A TION CORRECTION SEe 22 ,T11 N, R14E, 1440' SNL & 887' EWL 09/12/03 CMOITLP OA TUM MD & PERF ANGLE 08/02/04 JLJ/TLP GL V ClO BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumìVD= 4-1/16" CNV FMC BAKERC 65.8' NA 1721' 96 @ 11793' NIA 8800'SS e 10-3/4" CSG, 45.5#, L-80, 10 = 9.950" - 3907' Minimum ID = 2.275" @ 10840' 3-1/2" XN Nipple 4-1/2", 12.6#, L-80 tbg cut @ 10,400' TOe @ 10,700' ,.- 7-5/8" X 5-1/2" BKR H PKR, 10 = 6.56" - 10,972 PERFORATION SUMMARY REF LOG: SWS CNUGR ON 12/18/01 ANGLEAT TOP PERF: 81 @ 12000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 4 12000 - 12390 C 12/21/01 2" 4 12440 - 12690 C 12/21/01 2" 4 12780 - 12990 C 12/21/01 7 -5/8" eSG, 29.7#, NT -95 HS, 10 = 6.875" - 11,119' 5-1/2" LNR, 17#, NT-80, 10 = 4.892" -11,813' DATE REV BY COMMENTS 06/09/94 ORIGINAL COM PLETION 12/21/01 CHlKAK CTD SIDETRACK 09/24/01 A TTEM PT CTD SIDETRACK 06/13/03 CMO/TLP KB ELEVATION CORRECTION 09/12/03 CMO/TLP DATUM MD & PERF ANGLE 08/02/04 JLJ/TLP GL V ClO 15-36A / Proposed Completion NOTES: WELL ANGLE IS > 700 @ 11600' & > 900 @ 11740'.**LOST4-1/2" X KEY 2"x 1-1/2" X 1/4" (12/11/05)** 2200 - 3-1/2" X Nipple (2.813" 10) GAS LIFT MANDRELS ST MD ìVD DEV TYÆ VLV LATCH FQRT DATE 1 2 3 4 9,950' 7-5/8" X 5-1/2" BKR ZXP PKR/HGR 10,780' - 3-1/2" X Nipple (2.813"10) 10,800' - 5-1/2" X 3-1/2" BKR S3 Packer 10,820' - 3-1/2" X Nipple (2.813"10) 10,840' 3-1/2" XN nipple (2.725" 10) 10,860' - 3-1/2" WLEG - 5-1/2" X 3-1/2" ZXP PKR/HGR 11,009' - 5-1/2",17#, L-80 liner 3-1/2",9.2#, L-80, IBT-M Liner - 12799' 2-7/8" 6.5#, L-80 Liner - 13010' DATE REV BY COMMENTS 09/24/05 MORlTLH xx TIP SET (08/06/04) 12/11/05 DAV/PJC SFTY NOTE & PULL TIP@ 10841 PRUDHOE BA Y UNIT WELL: 15-36A PERMIT No: "2011620 API No: 50-029-22480-01 SEe 22 ,T11 N, R14E, 1440' SNL & 887' EWL BP Exploration (Alaska) ffi\..IDHCE~y; ffi\..lDHCEOL FR.UJS15 106 1d 2XJ1 œ œ 04 Dàe 05 œ . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc 15-36A (PTD #~O 116~O) Classified as Problem \-Vell ¿> ,7(7.~jIG4- \ «Ii { Subject: 15-36A (PTD #2011620) Classified as Problem Well { 1 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 18 Jul 200409:22:28 -0800 To: "Jenkins, Christopher N" <ChristopherJenkins@BP.com>, "GPB, FS3 TL" <GPBFS3TL@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jim_regg@adrnin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. ''NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB, FS3 DS Operators" <GPBFS3DSOperators@BP.com> cc: "NSD, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Reeves, Donald P" <ReevesDf@BP .com> All, Well 15-36A (PTD #2011620) has been found to have sustained casing pressure on the IA. The WHPs on 07/16/0~ were 2450/2450/0. A TIFL Failed on 07/16//04. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: DGLVs, MITIA. If MITIA fails, set TTP 3. WIE: Eval for tubing repair A wellbore schematic has been included for reference. «15-36A.pdf» The well has been classified as a Problem well. Please questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: ( 907 ) 65 9 - 5102 Pager: (907) 659-5100 xl154 call if you have any 15-36.A.pdf Content-Description: 15-36A.pdf I Content-Type: application/octet-strean1 Content-Encoding: base64 C[llIÇ( z 1f1e~~ ~.~~-\s ( A~~ù '-\;f\.{ P) 10J -:-:> ZÁ':)L\f~' -M. -...:;> -Zit SCf.;.., 3c: I r:;'~ C'¿" öA -'> 0 r::.. 7 34ç f~' I of I 7/18/200-1 9:40 AI\'I 4-1/16' CIW FMC BAKffi C 658' NA 1721' 96 @ 11793' N/A 8800' SS TREE = \llÆLLHEA D = ACTlJA. TOR = KB 8.EV '" BF 8.EV = KOP= Mix Angle = D3tum M) = D3tumTVD = SAFETY NOTES: WELL ANG.E IS > 70° @ 11600' & > 900@ 11740'. 15-36A 2228' l-i 4-1/2" CAMCO SSSV NIP, ID = 3812" I 8 GAS LFT M<\NDRELS ST MD TVD ŒV TYÆ VLV LATCH .. 1 3542 3248 45 HES-SPM OOrÆ BK 2 6961 5432 52 HES-SPM SO BK 3 9502 7037 48 HES-SPM DV BK 4 10814 7999 33 HES-SPM DV BK PORT Dl\ TE 16 12/27101 20 12/27/01 0 0811010 1 0 0811010 1 110-3/4"CSG.45 5#, L-80,ID= 9950" H 3907' ~ L Minimum ID = 2.377" @ 11504' 3-3/16" X 2-718" LINER XO 1 10841' 1-14-1/2"HESXNIP.ID=3813" 1 &-I 1 0904' 1-i7" x 4-lIZ' BAKffi SABL-3 PKR ID= 3875" 1 Z 10923' -4-112" BKR KB L T PKR ID= 2560" 1 1 0928' - 3 70" BKR DEA...OYMENT SL V. ID = 3.00" 1 1 1093T 1-14-1/2" HES X NIP, ID = 3813" 1 1 10954' 1--14-1/2" HES XN NP, (MLLEDTO 380" ID) 1 ~ 10965' 1--1 TOP OF BA Kffi llEBA CK SLV, ID = 6 38" 1 'ï 1 10966' 1-14-1/2" TBG TAIL WLEG,ID '" 3.960" 1 1 1 095T 1--1 ELMO TT LOGGED 07/24/95 1 I :8: g ITOPOF3-112" LNR 9 3#.ID=2.972" 1--1 10934' 1 ~ ~I 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3958" 1-1 10965' 17 - 5/8" X 5-1/2" BKR H A<R. ID = 6 56" 1--1 10972' 17-5/8" x 5-112" BKRLNR HGR, ID =6.56" 1--1 10978' 5-112" LNR MLLOur WlNOOW 11428' - 11435' (OFF WHPSTOCK) 17-5/8" CSG, 29 7#, NT-95 HS, ID = 6.875" 1--1 11119' ~ 11378' 1-13-1/2" X 3-3116" LNR XO, D = 2.786" 1 1 11504' 1--13-3/16"X2-7/8"LNRXO,ID=2377" 1 1 TOP OF WHIPSTOCK 1--1 11430' I 1 RA TAG 1-1 11439' 1 , . .. 4 ~ PERFORATION SU'v11'v\A. RY REF LOG SWS CNLlGR ON 12/18/01 ANGLEATTOPPffiF' 81 @ 12000' Note. Refer to A"oductbn DB for historical perf data SIZE SPF INlERVAL Opn/Sqz DATE 2" 4 12000 - 12390 0 12/21/01 2" 4 12440 - 12690 0 12/21/01 2" 4 12780 - 12990 0 12/21/01 12-7/8"LNR6.5#,L-80,.0058bpf,D=2.377" 1--1 13010' 1 1 5-1/2" LNR, 17#, NT-80,ID = 4.892" 1-1 11813' 1 PRUDHOE BAY UNIT WELL: 15-36A ÆRMfT No: 2011620 API No. 50-029-22480-01 SEC 22 ,T11 N, R14E, 1440' SNL & 887' EWI.. DATE REV BY COM\i1ENTS 09/12/03 CMO/TLP Dl\lUMMD& ÆRFANGLE COMMENTS ORIGINAL COMPLETION CH/KAK CTD SIDETRACK A TTEI\II PT CTD SIDETRACK RN/tlh CORRECllONS CH/lLP CORRECllONS CMOfTLP KB ELEVATION CORRECTION REV BY DAlE 06109/94 12/21/01 09/24101 06/27/01 09/29/01 06/13/03 8P Exploration (Alaska) ~ I J~ Àòa~ DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011620 Well Name/No. PRUDHOE BAY UNIT 15-36A Operator BP EXPLORATION (ALASKA) INC 5 ¡1 ~ f).. 14.. À.Ó{1 ( API No. 50-029-22480-01-00 MD 13010 ~ ND 8776 ~ Completion Date 12/21/2001 -- Completion Status 1-01L Current Status 1-01L UIC N --------- -- -------- - REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~;¡~ .~-- -~- DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Electr Digital Dataset ed/Frmt Number D ~, Directional Survey Log Log Run Scale Media No FINAL Interval Start Stop OH/ CH Received Comments --- --------- -- -- - ---- - I Open 10/15/2001 Directional Survey Digital' Data fJB' ~ - Name k6 C I ~ C I f-Rpr ! j I , ~05 fo559 12886 Case 2/5/2002 Directional Survey 4 1 FINAL 10930 10774 13010 Open 3/15/2002 Open 10/15/2001 Directional Surv:~ Paper Copy ~ tJ. ( ~ --- ____, Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y0 Chips Received? ~ y / f'l ~c_- Daily History Received? WN DYN Formation Tops Analysis Received? ~ ----- - -- -------- Comments: JUt 1-..:..... rl ~ [) M..f. ( Sl~_~~-L - ~ ~ ~ ~ LD 9.~S- - J.¿t.r~ 'G L.- ~ ~ ~ S (~'-iL.J.t... - b YL. ìu b (ð tl ",r - I).. .t.f\;:¡. () /... ~. ~. ~ rJ ~.,.~ ~ ().hvj....~ ~. M~IN\. c.rvf-lc, 't'fc..c..l- I (~At\J\ ~ ----------- __un ___un - -- ---- Compliance Reviewed By: I~ Date: õt t _sJ~~- \.~ Sc_llIDberg8P Alaska Data & Consulting Services 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie _. Well Job # Log Description D.S.15-36A ðDJ-JIc ã. D.S. 15-36A D.S. 15-36A ~ 22059 GR RapS DATA 22059 MD SLiMPULSE-GR 22059 TVD SLiMPULSE-GR ~--' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: RECE\VED ~;1AR '\ :~J 2002. . . ~ BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date 12/16/01 12/16/01 12/16/01 Blueline NO. 1868 Company: 03/05/02 State of Alaska Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia 1 1 Color Prints CD 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received d L&OQ~ ( ( MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No 15-36a Date Dispatched: 7-Feb-O2 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Flo ies Surveys 2 1 FEB 11 002 AI. Oil & Gas Cons. Anchorage Received By: ~ . J.rp ú1b1p~ .~) Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 " -( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '" 1. Status of Well Classification of Service Well !HI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-162 301-278 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22480-01 4. Location of well at surface .-'Ù,,~,.".,., ~,-.,.,- rVCAI" ~~ 9. Unit or Lease Name 1440' SNL 887' EWL SEC. 22 T11N R14E UM ~ !:;(';"",;:-;-:C\! ' V , , , , , . - , .. ',. 00::-- "L.~ ' Prudhoe Bay Unit At top of productive interval I I ),'; ',: D" . ¡Sln«", 4865' NSL, 39161 EWL, SEC. 15, T11N, R14E, UM~ -_7::.~-~L:,-,J.: l\~ '~ " ~ 10. Well Number At total depth '~ìiER'!:~;'~: ; ~~~~...~ 15-36A 4996' NSL, 2921' EWL, SEC. 15, T11N, R14E, UMî: .-_..~.: !. "",.-.-...." ..~, . . ,. .. ., 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 65.75' ADL 028306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 12/12/2001 12/16/2001 12/21 /2001 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13010 8776 FT 12996 8775 FT !HI Yes ONo (Nipple) 2228' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, Memory CCUGR, CNL 123. CASING LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 110' 30" 260 sx Arctic Set (Accrox.) 10-3/4" 45.5# L-80 35' 3907' 13-1/2" 1105 sx PF 'E' 375 sx Class 'G' 7-5/8" 29.7# NT95HS 33' 11119' 9-7/8" 617 sx Class 'G' 5-1/2" 17# NT80 10965' 11425' 6-3/4" 126 sx Class 'G' 3-1/2" x 3-3116" 8.81# x 6.2# L-80 1 0923' 13010' 3-3/4" 66 sx Class 'G' x 2-7/8" x 6.16# 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10966' 10904' MD TVD MD TVD 12000' - 12390' 8747' - 8758' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12440' - 12690' 8758' - 8766' 12780' - 12990' 8768' - 8775' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 30 Bbls of MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 29, 2001 Flowing Date of Test Hours Tested PRODUCTION FOR OIL -BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITy-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiPSRECEIVE D No core samples were taken. F EB 0.,6 2002 Alaska Oil & Gas Coos. Commission Anchorage Form 10-407 Rev. 07-01-80 "I) :'} !i Ii i\, ~ RBOMS 8Fl FEB I I 2002 Submit In Duplicate Ii; j '.'1 I., L." l,~ t I, ~ 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 1 11790' 8745 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 Ó~. OCo.O 15-36A Well Number 201-162 301-278 Permit No. / Approval 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, REGi.tVéD ITEM 28: If no cores taken, indicate 'none'. FEB 0 6 2002 Form 10-407 Rev. 07-01-80 ~ 1M 'r ~'I'.""" Alaska Oil & Gas Cons. Commission Anchorage Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/13/2001 9/14/2001 9/15/2001 9/16/2001 ( - ( , Page 1 of 14 BP EXPLORATION Operations Summary Report 1 5-36 15-36A REENTER+COMPLETE NABORS NABORS 3S Start: 9/14/2001 Rig Release: 12/21/2001 Rig Number: Spud Date: 9/14/2001 End: 00:00 - 00:00 From - To Hours Activity Code NPT PRE 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:30 03:30 - 05:00 05:00 - 10:30 10:30 -15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 -19:00 19:00 -19:45 19:45 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 06:00 06:00 - 07:00 07:00 - 07:15 07:15 - 09:30 09:30 - 13:30 13:30 - 14:45 14:45 -17:15 17:15 -18:00 18:00 -18:15 18:15 -18:45 18:45 - 21:45 22:00 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 03:30 24.00 MOB P 1.00 MOB 1.50 MOB P P 1.00 RIGU P 1.50 RIGU 5.50 RIGU 5.00 RIGU P P P 0.50 RIGU 1.00 RIGU 1.00 RIGU P P P 1.00 RIGU P 0.75 RIGU P 3.25 STWHIP P 1.00 STWHIP P 1.50 STWHIP P 4.50 STWHIP P 1.00 STWHIP P 0.25 STWHIP P 2.25 STWHIP P 4.00 STWHIP P 1.25 STWHIP P 2.50 STWHIP P 0.75 STWHIP P 0.25 DRILL 0.50 DRILL P P 3.00 DRILL P 2.00 DRILL P 0.50 DRILL 1.00 DRILL P P 2.00 DRILL P Phase Description of Operations RD ON 7-16, MOVE RIG AND CAMP TO 15-36A LOCATION. RU. MOVE CTDE FROM 07 -16A TO 15-36A. ARRIVED 15-36A. SPOT SUB OVER WELL. MOVE CAMP TO 15-36A. GENERAL RIU OF CTDE. SPOT BOILER COMPLEX. RAISE MAST. SET-UP BEAVER SLIDE, CATWALK AND PIPE RACKS. SPOT AND RU CTU #4. RIG ACCEPTED @ 05:00 HRS on 9/14/01. PJSM. NU BOPE. PRESS TEST BOPE TO 250 / 3500 AS PER BP / AOGCC REQU I REMENTS. RU LUBRICATOR AND PULL TWC. NO WHP. PU INJECTOR AND CUT PIPE. PRESS TEST INNER REEL VALVE, FLOWBACK LINES AND PACKOFF TO 4,000 PSI - OKAY. PJSM. PULL TEST COIL CONNECTOR TO 4,000 PSI - OK. PRESS TEST MHA TO 4,000 PSI - OK. RIH, TAG X NIPPLE AT 10,937'. MILL X NIP TO 10,940'. FIN MILLING 'XN' NIPPLE, RIH AND DISPLACE WELL TO KCL. WEXIT RIH TO PINCH POINT. BEGIN MILLING WINDOW AT -- 11,428.3' CTM. WEXIT Update at 06:00. Milling ahead at 11431.5', have made 3.2' since 01 :00 AM, and expect the window should be 6-7'. Continue milling. 2.6 bpm in, 2.6 bpm out, 100% returns. 2025 psi CTP. WEXIT Tour safety meeting. Discuss muster area, possible lost circulation zone, well H2S status. Plan for day ahead. WEXIT Continue milling window as before. WEXIT Mill casing to 11435', saw drilling break, probable bottom of window. Probable window length=6.8'. Mill formation to 11445.6', for 10' of rathole. WEXIT Ream up and down 3 times through interval. Slight work on first up pass. Clean afterwards. Dry drift up and down through window, no problems. WEXIT POOH with window milling BHA WEXIT Tag up at surface with milling BHA. No fluid losses while POOH. Lay down BHA #1. Mill slightly under gauge at 3.77", string reamer spot on gauge at 3.80". PROD1 STANDBY FOR NEW CREWS TO CHANGE OUT TOURS. PROD1 PJSM, PTSM - DISCUSS TOOL HANDLING, MU, AND PERSONNEL ASSIGNMENTS. PROD1 PU / MU BHA #2, DEPTH ENCODER TO READING, RECONNECT -OK. PROD1 RIH W/ BHA #2 (TORC DIRECTIONAL ASSEMBLY), SHT @ 1,600'- OK. PROD1 RIH, PASS THRU WINDOW OKAY. PROD1 DISPL HOLE TO FLO-PRO MUD. MAKE GR COORELATION - NO USEABLE DATA. PROD1 DRILL NEW HOLE TO 11,469', TIE IN WITH RA MARKER (-3' CORRECTION) PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE WEXIT WEXIT WEXIT Printed: 12/26/2001 8:44:08 AM f ( { ~ . BP EXPLORATION Page.2 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/16/2001 03:30 - 06:00 2.50 DRILL P PROD1 DRILL AHEAD TO 11,530'. 06:00 - 06:30 0.50 DRILL P PROD1 Changeout and tour safety meeting. 06:30 - 07:00 0.50 DRILL P PROD1 Continue drilling build section. 2.7 in, 2.7 out, no losses. CTP 2850 psi. Holding high side tool face. 07:00 - 07:45 0.75 DRILL N DFAL PROD1 Getting more build than needed, attempt to go to rotation mode with the Torq orienter to straighten out build. Unable to get orienter to accept command properly to rotate. Tried on bottom and when short tripping. Never got it to rotate. Finally sent a different command, and got it to take a 11 OL TF command. Can continue on this TF for now. 07:45 - 10:30 2.75 DRILL P PROD1 11543', Continue on build section, starting turn. 10:30 - 11 :00 0.50 DRILL P PROD1 11570', Need to trip for lateral section motor. POOH. Will attempt to troubleshoot orienter on way DOH. Found probably problem with Torq orienter with surface software. Able to rotate after software debugged. 11 :00 - 11 :30 0.50 DRILL P PROD1 KlcklH2S weekly drill, including rig evacuation. 11:30-12:15 0.75 DRILL P PROD1 Continue POOH. 12:15 - 13:45 1.50 DRILL P PROD1 Tag up at surface. Lay down motor and bit from BHA #2. Bit in good shape. Pick up BHA #3, to drill lateral section. 13:45 - 15:30 1.75 DRILL P PROD1 PU/MU BHA# FOR LATERAL SECTION. 15:30 - 18:00 2.50 DRILL P PROD1 RIH with BHA #3, 1.37 deg motor, and DS49 bit to start lateral section. Also, Schlumberger reports that they have made a software change to their surface computer, while changing BHA's. This should allow rotation while drilling with the Torc orienter. 18:00 - 19:00 1.00 DRILL P PROD1 COORELATE W/ GR. (-2') COORECTION AT RA TAG. HELD WEEKL Y SAFETY MTG W/ DAYLIGHT CREW. 19:00 - 20:30 1.50 DRILL P PROD1 DRILL TO 11, 639' WHERE TF BEGAN WALKING BETWEEN -30 AND 10 DEG. 20:30 - 22:00 1.50 DRILL N DFAL PROD1 WORKED WITH TOOL (TURN OFF/ON), BUT TF STILL NOT CORRECT AT -15 DEG. 22:00 - 22:15 0.25 DRILL P PROD1 WIPER TRIP TO JUST OUTSIDE WINDOW, SEND COMMANDS TO TORC DURING TRIP. 22:15 - 23:15 1.00 DRILL N DFAL PROD1 DRILL HOLE IN LATERAL SECTION. TF LOOKED GOOD WHILE CIRCULATING, BUT WENT TO 9 DEG WHILE ON BTM. RESEND COMMAND TO TURN 90L, NO RESPONSE. TRIED TURNING R, NO RESPONSE, TRIED TURNING INCREMENTALLY, NO RESPONSE. TRIED TO CYCLE POWER TO TORC - NO RESPONSE. CHANGE THROTTLE TIMING AND % MOD. - NO RESPONSE. 23:15 - 00:00 0.75 DRILL N DFAL PROD1 CALL TORC SPECIALISTS, ADVISE TO USE BACKUP TOOL. PREP TO TRIP FOR NEW TORC AND MWD TOOLS. 9/17/2001 00:00 - 01 :30 1.50 DRILL N DFAL PROD1 CONT. POOH FOR NEW TORC ORIENTER AND NEW MWD. 01 :30 - 03:30 2.00 DRILL N DFAL PROD1 PJSM. PU / MU NEW TORC AND MWD. SURFACE TEST - OKAY. 03:30 - 04:15 0.75 DRILL N DFAL PROD1 RIH W/ BHA #4. SHT AT 1,600' - OKAY. 04:15 - 05:30 1.25 DRILL N DFAL PROD1 RIH TO TIE-IN LOGGING POINT. 05:30 - 06:00 0.50 DRILL N DFAL PROD1 RUN GR COOR. LOG. 06:00 - 07:30 1.50 DRILL N DFAL PROD1 Logging Gamma Ray tie in pass over RA pip tag in whipstock. Make a +6' depth correction. 07:30 - 08:45 1.25 DRILL N DFAL PROD1 11751', Orient to 105L TF, no problems with Torc tool. Resume drilling. 2.6 in, 2.6 out, 2850 psi CTP free spin, drilling at 3150 psi. Printed: 12/26/2001 8:44:08 AM f f BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: 1 5-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/17/2001 08:45 - 09:25 0.67 DRILL P PROD1 11820', had hard drilling, sticky, and stalls. Possibly crossed fault. No losses encountered. Still drilling at 2.8 in, 2.8 out, 3100 psi CTP, 100 fph ROP, 105L TF. 09:25 - 09:50 0.42 DRILL N STUC PROD1 11875' Oriented while drilling. Got stuck after orienting sequence was completed. Difficult to see motor work with pressure pulses during orienting. Could not move up. Pulled 65klbs. Positioned pipe at neutral weight, and SI pumps for 20 mintues to wait for the miracle of flo pro mud. 09:50 -10:10 0.33 DRILL P PROD1 Easily pulled free. Short trip up to shoe, no problems up or down. 10:10 -13:30 3.33 DRILL P PROD1 11875', resume drilling. 2.7 in/out, 3080 psi CTP, 90L TF, 75 fph ROP. Drilling smooth, no problems with sticking 11875'. 13:30 - 14:00 0.50 DRILL P PROD1 12040', smooth drilling, no sticky spots. Wiper trip to shoe. 14:00 - 15:50 1.83 DRILL P PROD1 Resume drilling. 2.7 in/out, 100% returns. 75L tool face, 3375 psi CTP. 90 fph ROP. 15:50 - 16:30 0.67 DRILL P PROD1 12160', wiper trip to shoe. Orienter also not wanting to find a proper tool face. 16:30 - 19:30 3.00 DRILL P PROD1 Attempt to return to drilling. Need to get all of motor build to make turn. We may be too close to north bounding fault. Trip for bigger motor. Orienter worked fine on trip out of hole. Will also inspect orienter when at surface. 19:30 - 20:45 1.25 DRILL P PROD1 CHANGE MOTOR ABH SETTING TO 2.00. DOWNLOAD DATA, FUNCTION TEST TORC. (BIT OK, WITH ONE BACKREAMING BUTTON HALF CHIPPED). 20:45 - 21 :30 0.75 DRILL P PROD1 RIH TO 1,600', SHT - OKAY. 21:30 - 23:15 1.75 DRILL P PROD1 CONT. RIH TO WINDOW. 23:15 - 00:00 0.75 DRILL P PROD1 GR COOR. LOG -1' COORECTION AT RA TAG. 9/18/2001 00:00 - 00:45 0.75 DRILL P PROD1 FIN GR DEPTH CORRECTION AT RA TAG (-1'). 00:45 - 01:15 0.50 DRILL P PROD1 CONT. RIH, HOLE VERY STICKY AT 11,920'. 01:15 - 02:15 1.00 DRILL N DFAL PROD1 SEND COMMANDS TO TORC - NO RESPONSE. PUMPS OFF, REPEAT SEQUENCE, NO RESPONSE. 02:15 - 02:45 0.50 DRILL N DFAL PROD1 PULL UP INTO CASING. (PULLING TIGHT THRU 11,920'). 02:45 - 03:00 0.25 DRILL N DFAL PROD1 SEND COMMANDS TO TORC - NO RESPONSE. 03:00 - 04:30 1.50 DRILL N DFAL PROD1 CO NT. POOH. 04:30 - 07:15 2.75 DRILL N DFAL PROD1 LD BACKUP TORC ORIENTER, PU SPERRY MECH ORIENTER. 07:15 - 07:35 0.33 DRILL N DFAL PROD1 RIH with BHA #6, Lateral section BHA, with 2.0 deg motor, DS49 bit, and Sperry orienter. Note - SWS did basic troubleshooting on Tore orienter wile at location, and found a failure in the alternator section. This appears to be the same failure mode as the first tool run. 07:35 - 08:15 0.67 DRILL N DFAL PROD1 Shallow hole test of MWD and new orienter. All worked ok. 08:15 -10:45 2.50 DRILL N DFAL PROD1 Continue to RIH. Hung up at XN nipple at 10954', and had to orient to high side to get through. (Note, we had to mill this out to 3.80" on window milling run 1). Ran to TO, tied into last tag of 12160'. Had to work down from 11900'. 10:45 - 11 :45 1.00 DRILL N DFAL PROD1 Wiper trip up through shaley area to 10900'. Cleaning up hole prior to begining drilling. 11 :45 - 15: 15 3.50 DRILL P PROD1 DRILL AHEAD TO 12,270' THROUGH STICKY, SHALEY SECTION. 15:15 -16:15 1.00 DRILL P PROD1 WIPE TO WINDOW. 16:15 - 20:45 4.50 DRILL N FLUD PROD1 WAIT ON 9.1 PPG FLO-PRO ORIENT TF. 20:45 - 22:00 1.25 DRILL P PROD1 DISPLACE HOLE WITH NEW 9.1 PPG FLO-PRO, WHILE Printed: 12/26/2001 8:44:08 AM { ( BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: 1 5-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/18/2001 20:45 - 22:00 1.25 DRILL P PROD1 DRILLING AHEAD. 22:00 - 23:15 1.25 DRILL P PROD1 WIPE TO 11, 530', WHILE DISPLACING HOLE WITH NEW FP. PULLED 15K OVER 3 TIMES, WHILE POOH. 23:15 - 00:00 0.75 DRILL P PROD1 RIH DISPLAING FP. STACKED OUT AT 12, 275'. RATTY HOLE CONDITIONS ALL THE WAY TO BTM. SLACK OFF WT = 11-12K, RIH RUNNING WT VARIED BETWEEN 10-5K DOWN. ORIENTED 17R. 9/19/2001 00:00 - 00:45 0.75 DRILL P PROD1 ORIENTATE TOOL FACCE TO PROCEED TO DRILL AHEAD 00:45 - 04:36 3.85 DRILL P PROD1 DRILL AHEAD TO 12377'. 04:36 - 06:00 1.40 DRILL P PROD1 SHORT TRIP 877' 06:00 - 06:10 0.17 DRILL P PROD1 PJSM (CREW CHANGE). 06:10-10:15 4.08 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12,446'. 10:15 - 13:10 2.92 DRILL P PROD1 WIPER TRIP 1000' 13:10 - 16:00 2.83 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12,590' 16:00 -17:30 1.50 DRILL P PROD1 WIPER TRIP 1140' 17:30 -18:00 0.50 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12,600'. 18:00 - 18:39 0.65 DRILL P PROD1 PJSM DISCUSS SATILLITE ACCUMULATION AREAS. 18:39 - 19:05 0.43 DRILL P PROD1 DIFFICULTIES GETTING THE ORIENTATOR TO RESPOND. SUSPECT 2 DEGREE MOTOR AND DOGLEG COMBINATION REQUIRING TORQUE ABOVE ORIENTIER CAPABILITY. mOOVE UP AND DOWN HOLE FILALL Y SICESSFUL IN GETTING ORIENTATOR TO FUNCTION NEAD TD 19:05 - 21 :21 2.27 DRILL P PROD1 DIRECTIONALLY DRILL TO 12,623'. 21 :21 - 21 :47 0.43 DRILL P PROD1 ORIENTATE 21 :47 - 23:59 2.20 DRILL P PROD1 DIRECTIONALL Y DRILL TO END OF BUILD AT 12,700'. 9/20/2001 00:00 - 04:15 4.25 DRILL P PROD1 POH FOR MOTOR CHANGE TO 1.37 DEG MOTOR. HAD TO ORIENT TO PULL UP THRU WINDOW. 04:15 - 04:45 0.50 DRILL P PROD1 CHANGE OUT MOTOR AND ORIENTER. RERUN 0549. MU BHA #7. STAB INJECTOR. 04:45 - 08:15 3.50 DRILL P PROD1 RIH WITH BHA #7. SHT MWD - OK. 08:15 - 08:45 0.50 DRILL P PROD1 LOG GR TIE IN. CORR'N -7'. 08:45 - 09:45 1.00 DRILL P PROD1 CO NT RIH AND TAG BOTTOM - OK. HOLE LOOKED GOOD WITH NO REAMING REQUIRED. 09:45 - 12:55 3.17 DRILL P PROD1 ORIENT AND DRILL AHEAD IN ZN 1A. APPEAR TO BE IN GOOD SAND. CONT DRILLING AHEAD. CROSS FAULT AT APPROX 12740' AND CONT DRILLING AHEAD NOW IN ZN 1 B. DRILL TO 12802' 12:55 -14:15 1.33 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12,860 14:15 - 16:00 1.75 DRILL P PROD1 WIPER TRIP UP TO WINDOW - HOLE CONDITION GOOD. RIH TO BOTTOM. 16:00 - 16:25 0.42 DRILL P PROD1 ORIENTATE 16:25 - 18:00 1.58 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12882. 18:00 - 20:19 2.32 DRILL N STUC PROD1 STUCK ON BOTTOM.SLACK OFF AND REDUCE PUMP RATE. NOGO. PULL 90K NO GO. WAIT ON CRUDE. PIPE PULLED FREE PRIOR TO SPOTTING CRUDE OIL AT 2019 HRS WITH 80K 20:19 - 23:59 3.67 DRILL P PROD1 CHANGE OUT MUD. 9/21/2001 00:00 - 00:20 0.33 DRILL P PROD1 CONTINUE DISPLACEMENT TO NEW FLO PRO WHILE RIH TO BOTTOM AFTER SHORT TRIP DURING DISPLACEMENT. 00:20 - 00:40 0.33 DRILL P PROD1 ORIENT. 00:40 - 02:40 2.00 DRILL P PROD1 DRILL AHEAD WHILE ADDING 1.5% FLO-LUBE TO SYSTEM Printed: 12/26/2001 8:44:08 AM ,r ( ( BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/21/2001 00:40 - 02:40 2.00 DRILL P PROD1 FOR ADDITIONAL LUBRICITY. SAW IMPROVED WEIGHT TRANSFER AFTER ADDITION. SURFACE STRING WEIGHT INCREASED FROM 4000 TO 7000#. CONT DRILLING TO 12965'. 02:40 - 03:40 1.00 DRILL P PROD1 DRILL AHEAD TO 13036'. 70-105 R. 2.4/2.4 BPM. STARTING TO STACK WEIGHT. 03:40 - 05:30 1.83 DRILL P PROD1 WIPER TRIP TO WINDOW. LOOKED GOOD COMING OUT AND BACK IN TO 12210'. UNABLE TO WORK PAST THIS DEPTH. NO FURTHER PROGRESS. 05:30 - 07:30 2.00 DRILL N DPRB PROD1 ATTEMPT TO WORK THRU TIGHT SPOT - PUMP ON, PUMP OFF BUT WITHOUT REAMING. LITTLE OR NO PROGRESS. PICK UP CLEAN AS IF NOT SWELLING SHALE BUT OBSTRUCTION. HOLE COLLAPSE?? 07:30 - 07:45 0.25 DRILL N DPRB PROD1 DISCUSS WITH ANCH TEAM. AGREE TO TRY FURTHER ATTEMPTS TO WORK THRU BAD SPOT BEFORE REAMING. 07:45 - 09:35 1.83 DRILL N DPRB PROD1 CO NT ATTEMPTS TO WORK THRU BAD SPOT WITHOUT REAMING ORIENTED SAME WAY AS DRILLED. LITTLE PROGRESS AND NOTHING FURTHER BELOW 12222'. STILL PU CLEAN AS IF OBSTRUCTION NOT SWELLING. 09:35 -11:55 2.33 DRILL N DPRB PROD1 REAM DOWN TO 12275' WITHOUT BREAKING THRU IN TO CLEAN HOLE. SURVEYS CONFIRM WELL IS SIDETRACKED. 11 :55 - 12:30 0.58 DRILL N DPRB PROD1 TIE IN +24 CORRECTION 12:30 - 16:00 3.50 DRILL N DPRB PROD1 POH FOR CEMENTING NOZZLE FOR SPOTTING KICK OFF PLUG. 16:00 - 18:45 2.75 DRILL N DPRB PROD1 INSTALL DART AND PUMP DART 53.7 BBL DISPLACEMENT WITH DART. 18:45 -19:08 0.38 DRILL N DPRB PROD1 MU CEMENTING ASSEMBLY 3.1 BULL NOSE AND 2 JOINTS PAC TUBING 19:08 - 21:45 2.62 DRILL N DPRB PROD1 RIH TO 10947 NO GO. CAN'T GET THROUGH THE MILLED XN NIPPLE. MADE NUMEROUS ATTEMPTS VARYING PUMP RATES, RUNNING SPEED, STACKING WEIGHT,SIT DOWN WITH PUMPS OFF AND THEN STARTING PUMPING. ALL WITH NO POSITIVE RESULTS. 21 :45 - 23:30 1.75 DRILL N DFAL PROD1 POH 23:30 - 00:00 0.50 DRILL N DFAL PROD1 CHANGE OUT BULL NOSE FOR TAPERED NOZZLE. BULL NOSE DIDN'T HAVE A SERIES OF MARKS AS EXPECTED MAYBE ONE NEW FILE LIKE WICKER. 9/22/2001 00:00 - 02:00 2.00 DRILL N DFAL PROD1 RIH WITH 3" OD TAPERED NOZZLE. TAG UP AGAIN AT SAME PLACE AS PREVIOUS RUN -10948'. 02:00 - 04:15 2.25 DRILL N DFAL PROD1 POH WITH NOZZLE. 04: 15 - 04:45 0.50 DRILL N DFAL PROD1 BREAK INJ OFF BHA. LD NOZZLE & INSPECT SAME. ONE MARK ON BULLNOSE END NEAR CENTRE OF NOZZLE. 04:45 - 05:00 0.25 BOPSUF P PROD1 RU FOR WEEKLY BOP TEST. 05:00 - 15:30 10.50 BOPSUF P PROD1 TEST BOP 15:30 -18:00 2.50 BOPSUF P PROD1 PULL TWC WITH LUBRICATOR 18:00 -19:15 1.25 BOPSUF P PROD1 PJSM CREW CHANGE 19:15-21:30 2.25 EVAL N DFAL PROD1 RU SLICK LINE AND RUN 2.7 IMPRESSION BLOCK AND 2.7 DRIFT. NO GO PAST 10,936 WLM. POH TWO SIGNIFICANT MARK ON BLOCK BUT NOT CONCLUSIVE. SOME OF THE MARKS ARE STRAIGHT I.E. SUGGESTING JUNK. 21 :30 - 23:59 2.48 EVAL N DFAL PROD1 RUN CCUGR MEMORY LOG TO 10936 TO LOG JEWELRY Printed: 12/26/2001 8:44:08 AM BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/23/2001 00:00 - 01 :30 1.50 DRILL N DFAL PROD1 POH WITH MEMORY CCUGR. 01 :30 - 03:00 1.50 DRILL N DFAL PROD1 RIH AGAIN WITH LOG WITHOUT 2.7" DRIFT TO LOG DEEPER TO 10950'. 03:00 - 05:30 2.50 DRILL N DFAL PROD1 ACQUIRE MEMORY LOG DATA ACROSS TAILPIPE AND PACKER. POH TO SURFACE. 05:30 - 06:00 0.50 DRILL P PROD1 CREW CHANGE AND SAFETY MEETING WHILE WOO. 06:00 - 08:15 2.25 DRILL N DFAL PROD1 DISCUSS WITH NS PE'S & ANCH. LOG INDICATES TAILPIPE IN PLACE AT LEAST ABOVE XN NIPPLE AND MARKS FROM IMPRESSION BLOCK RUN NOT INDICATIVE OF PARTED T/PIPE. RD SLlCKLINE. AGREE PLAN FORWARD TO RUN DIAMOND MILL ON STRAIGHT MOTOR. 08:15 - 09:30 1.25 DRILL N DFAL PROD1 CUT 100' OF COIL & INSTALL CONNECTOR. 09:30 - 11 :00 1.50 DRILL N DFAL PROD1 PULL TEST & PRESSURE TEST CONNECTOR. MU 3.8" OD DIAMOND SPEED MILL ON STRAIGHT MOTOR & 2 JTS 2 3/8" PH6 TBG, MHA. 11 :00 - 13:00 2.00 DRILL N DFAL PROD1 RIH WITH 3.80" MILL. WT CHK AT 10900' - 39KLBS. 13:00 - 13:15 0.25 DRILL N DFAL PROD1 CO NT RIH AND TAG UP WO CIRC AT 10943'. PU & BREAK CIRC. RUN IN CIRC AT 2 BPM - SAW NO RESISTANCE OR MOTOR WORK DOWN TO TUBING TAIL AT 10954'. 13:15 - 13:30 0.25 DRILL N DFAL PROD1 PUH ABOVE PROD PACKER TO 10880'. RUN IN WO PUMP AND TAKE WEIGHT AT 10945'. KICK PUMP IN AND GO THRU EASILY. 13:30 -16:45 3.25 DRILL N DFAL PROD1 WORK MILL THRU XN NIPPLE MULTIPLE TIMES REAMING TO CLEAN UP SAME. MAKE SUCCESSFUL DRY PASSES THEN MILL WOULD NOT PASS DRY. CIRC AND "ROLL" MILL INTO XN NIPPLE. 16:45 - 17:00 0.25 DRILL N DFAL PROD1 RIH TO WINDOW AT 11430'. 17:00 - 17:15 0.25 DRILL N DFAL PROD1 PASS THRU WINDOW. FIRST ATTEMPT WAS GRABBY BUT CLEANED UP ON SUBSEQUENT ATTEMPTS - PUMP ON. THIS DID NOT ACT LIKE JUNK. MAKE DRY PASS - OK. WENT DOWN TO 11435'. 17:15 - 17:30 0.25 DRILL N DFAL PROD1 POH ABOVE PACKER TO 10850'. RUN IN DRY & TAG UP ON XN NIPPLE?? AT 10942'. PUH AND BREAK CIRC. 17:30 - 18:00 0.50 DRILL N DFAL PROD1 RIH AND TAG UP 2.5/2.5 BPM 2850 PSI. ATTEMPT TO MILL & BREAK THRU BAD SPOT - NO SUCCESS. PUH & DISCUSS WITH ANCH DE. AGREE THAT SHOULD CEASE OPERATIONS AT THIS POINT IN FAVOUR OF FURTHER INVESTIGATION OF WELL CONDITIONS BY NS PE'S. 18:00 - 18:45 0.75 DRILL N DFAL PROD1 CIRC IN KCL AND DISPLACE FLO PRO FROM HOLE. POH TO 2000' CHASING FLO PRO OUT. 18:45 - 21:00 2.25 DRILL N DFAL PROD1 CIRC OUT REMAINING FLO PRO UNTIL HOLE CLEAN. FREEZE PROTECT TUBING WITH MEOH. 21 :00 - 22:00 1.00 DRILL N DFAL PROD1 POH TO SURFACE. 22:00 - 23:00 1.00 DRILL N DFAL PROD1 LD BHA. CLEAN PITS. 23:00 - 23:30 0.50 DRILL N DFAL PROD1 INSTALL BPV 23:30 - 00:00 0.50 DRILL N DFAL PROD1 START RIGGING DOWN FOR MOVE TO P-15A. 9/24/2001 00:00 - 04:00 4.00 DRILL P PROD1 NIPPLE DOWN BOP. NIPPLE UP BLANK FLANGE AND TEST TO 3500 PSI O.K. RELEASE RIG. 11/20/2001 00:00 - 04:00 4.00 MOB P PRE Move Nordic 1 onto DS 15-36A. 04:00 - 06:00 2.00 RIGU P PRE ACCEPT RIG AT 0400 HRS, 11/20/01. General rig up of trailers, etc. 06:00 - 07:30 1.50 BOPSUF P DECOMP N/U BOP Stack and hardline. ( ( Printed: 12/26/2001 8:44:08 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/20/2001 11/21/2001 { (' BP EXPLORATION Operations Summary Report 15-36 15-36A REENTER+COMPLETE NABORS NABORS 3S 07:30 - 15:30 From - To Hours Activity Code NPT DECOMP 15:30 - 16:30 16:30 - 17:00 17:00 - 19:00 19:00 - 19:30 19:30 - 20:30 20:30 - 21:15 21:15 - 23:20 23:20 - 23:45 23:45 - 00:00 00:00 - 02:15 02:15 - 02:45 02:45 - 03:05 03:05 - 04:15 04:15 - 04:50 04:50 - 05:40 05:40 - 07:30 07:30 - 08:30 08:30 - 11 :00 11 :00 - 13:00 13:00 - 14:00 14:00 -15:00 15:00 -15:30 8.00 BOPSUF P 1.00 STWHIP P 0.50 STWHIP P 2.00 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 0.75 STWHIP P 2.08 STWHIP P 0.42 STWHIP P 0.25 STWHIP P 2.25 STWHIP P 0.50 STWHIP P 0.33 STWHIP P 1.17 STWHIP P 0.58 STWHIP P 0.83 STWHIP P 1.83 STWHIP P 1.00 STWHIP P 2.50 STWHIP P 2.00 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 0.50 STWHIP P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 7 of 14 Start: 9/14/2001 Rig Release: 12/21/2001 Rig Number: Spud Date: 9/14/2001 End: Description of Operations Perform initial BOPE pressure / function test. Witness waived by L. Grimaldi. Send test report to AOGCC. Berm green tank. M/U nozzle BHA to kill well. SIWHP = 1900 psi. Bullhead kill well with 2% KCL water. 4.0 bpm, 2300 psi Bullhead 220 bbls KCL water. Circ. thru nozzle at 1075 ft. Pre tour safety meeting. Discuss operations. Moniter well for no flow, sort out BHA. Confirm no flow, make up BHA #1. D331 DSM, baker 0 deg mud motor, daily up/down jars, burst disk circ sub, disco, ctc. RIH with BHA #1. Weight check up at 10500'=26klbs. Tag top of fish at 10959' CTM. Paint flag at this depth, reset counter to 10954', depth of XN nipple from tally. Kick on pumps to 2 bpm. Fell through ok. Pulled back up through fish slick, with no problems. Ran back through the fish with pumps down. Did not see any weight loss. RIH through window. Saw first motor work at 11480', continued to RIH slow to 11535'. Call cementers, PUH to above window. PUH above window. Circulate, waiting on cementers. Wait on cementers. Safety meeting prior to pumping cement. Wait on cementers to batch up and get primed. Down on pumps, line up to cementers. Pump 3 bbls water, PT cementers hard lines to 5000 psi. All OK. On line with cement. Pumping at 1.5 bpm. Pump 24 bbls of cement based on MM. Follow with water from the cementers. Displace coil. Lay in cement out motor at 1.0 bpm. Sticky pickup in open hole. Lay in cement from 11515'. Estimated top of cement 10195', pull up to 10000' for safety depth. Pumped 24 bbls cement, got 1 for 1 returns. Lost total of 1 bbl cement to formation during pumping operations. At safety depth, circulate at minimum rate (0.2 bpm) while waiting on cement. Kick rate up to 2.5 bpm, pumping 2# bio to clean out/contaminate cement. RIH. Clean out to 10930' CTM. PUH to 10000', run back in to 10930', POOH chasing bio with KCL water. Got lots of 10+ Ib cement back. Probably have good cement top at 10930'. Full returns. UO motor / mill BHA. M/U nozzle BHA. RIH and freeze protect 4 1/2" tubing to 2250 ft with 31 bbls MEOH. Close master and swab valves. SIWHP = 0 psi. Clean rig pits. N/D BOPE. Cut coil. Remove guide arch. Lower injecter head in pipe bay. N/U tree cap and press test w/ 4000 psi. RELEASED RIG AT 15:30 HRS, 11/21/01 TOTAL TIME ON WELL WAS 1 DAY AND 11.5 HRS. TOP OF CEMENT DRESSED OFF IN 41/2" TAILPIPE TO 10,930 FT BKB. 2% KCL WATER UP TO 2250 FT. MEOH FREEZE PROTECT Printed: 12/26/2001 8:44:08 AM " ( ~'; ( BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/21/2001 15:00 - 15:30 0.50 STWHIP P PROD1 TO SURFACE. 12/7/2001 17:00 - 23:30 6.50 MOB P PRE Released from U-15B @ 17:00 Hrs on 12-07-2001. RID & made general preparations to move CTDE to 15-36. 23:30 - 00:00 0.50 MOB P PRE Move rig, camp & CTDE from U-15B to 15-36A. 12/8/2001 00:00 - 02:15 2.25 MOB P PRE Move rig, camp & CTDE from U-15B to 15-36A. 02:15 - 10:00 7.75 MOB P PRE Arrived 15-36a. Lay mats & spot sub over well. Spot boiler complex, mud tanks etc. 10:00 - 16:45 6.75 MOB P PRE Setup flowback tanks. Rig accepted @ 11 :00 HRS on 12/8/01. PJSM. Nipple-up BOPE. (Notified AOGCC of BOP test, witnessing wavied by Chuck Shieve) 16:45 - 18:00 1.25 RIGU P PRE Pull BPV and install TWC. Grease all valves. Having problems pulling BPV, junk on top. 18:00 - 00:00 6.00 RIGU P PRE Start testing BOPE as per BP/AOGCC requirements. Meanwhile awaiting arrival of OS CTU#4 undergoing maintenance as DS base. ETA @ 04:00-05:00 Hrs on 12/9/01. 12/9/2001 00:00 - 02:00 2.00 RIGU P PRE Continue testing BOPE. Meanwhile take on 2% KCL water into pit & upright. DSM RIU dike for cuttings tank. Still awaiting arrival of OS CTU#4. 02:00 - 05:15 3.25 RIGU N RREP PRE Changeout leaking inside kill line valve & retested. New valve also leaking. Grease valve & retested -leaking. Meanwhile DS CTU#4 with new CT reel arrived site @ 04:30 Hrs. Spot & R/U CTU. 05:15 - 06:15 1.00 RIGU P PRE Continue RIU CTU#4. 06:15 - 06:45 0.50 RIGU P PRE PJSM crew change review rig-up procedures remaining for today and brief crews of drilling plans/procedures to take place later. 06:45 - 12:10 5.42 RIGU P PRE Retest inside kill line valve -ok. Continue r/u OS #4. On 3S pulling and replacing isolation valve on one of the main hydraulic tanks that was damaged several weeks ago when driveshatt came apart. Anadrill on location since lastnight and rigging up. Pull TWC. Stab coil to injector. Unable to stab coil, missing key for the levelwind, mechanics on the way. Still need to make repairs to OS pump controller in the coilcab. 12:10 - 12:45 0.58 RIGU P PRE Stab coil to injector. 12:45 - 14:00 1.25 RIGU P PRE Continue r/u coil unit install new pack-off assembly to injector. 14:00 - 17:00 3.00 STWHIP P PROD1 Make-up CTC. Load and launch 1 5/16" ball sweep coil w/ methanol. Pressure test CTC 4000 psi & pull test to 30K. 17:00 - 19:45 2.75 STWHIP P PROD1 M/U MHA. PfTest inner reel valve, flowback lines & MHA to 3000 psi - OK. 19:45 - 21:20 1.58 STWHIP P PROD1 M/U drilling BHA#1. Scribe & program TORC tool. Meanwhile displace coil to KCL water. 21 :20 - 22:00 0.67 STWHIP P PROD1 RIH BHA#1 to 3500' displacing FP to open top tank. 22:00 - 00:00 2.00 STWHIP N DFAL PROD1 SHT tools. MWD - OK but TORC not responding to surface commands. Troubleshoot surface computers, sensors, different pump rates & RIH/PUH - no success. TORC was set-up to resume on LS but, not able to orient to HS, 90L/90R or continuous rotation mode. Call for Sperry orienter as backup TORC has a cracked housing & is awaiting spares from Houston. 12/10/2001 00:00 - 01 :00 1.00 STWHIP N DFAL PROD1 POOH BHA#1 for orienter. 01 :00 - 02:00 1.00 STWHIP N DFAL PROD1 OOH. L/D TORC & M/U Sperry Orienter and bleed sub. TORC tool later diagnosed to have downhole data acquisition failure. 02:00 - 03:00 1.00 STWHIP N DFAL PROD1 RIH w/ BHA#2 to 2500'. SHT MWD & orienter - OK. Printed: 12/26/2001 8:44:08 AM t ( BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/10/2001 03:00 - 05:45 2.75 STWHIP P PROD1 Continue RIH BHA#2 to 10850'. Orient TF from LS to 57L. Dry tag cement @ 10922'. Bring on pumps and check TF @ 33L. RBIH & retag @ 10923'. Flag EOP at 10854'. 05:45 - 06:00 0.25 STWHIP P PROD1 PUH to 10745' for GR tie-in. 06:00 - 07:25 1.42 STWHIP P PROD1 Log GR tie-in +2' correction (tie-in point 10756') 07:25 - 08:00 0.58 STWHIP P PROD1 Orient to highside 08:00 - 08:15 0.25 STWHIP P PROD1 TIH to TOC 10924.5' 08:15 -14:50 6.58 STWHIP P PROD1 Drilling cement to top ofTT 12-15'/hr. Ran into something hard at 10946' (1 O'high to TT). Slowly milling ahead without messing with TF to 10949.1' stalling feather in, drill good to 10954' again stalling. Continue on to 10958' then stall. Drill ahead to 10960.5' stall work area orient 1 click straight up continue on drilling 25'/hr to 11000'. 14:50 - 15:15 0.42 STWHIP P PROD1 Short 200' trip no problems. 15:15-17:30 2.25 STWHIP P PROD1 Drilling cement f/11 000' to 11056'. 30'/hr pumping 5 bbl 1.5# bio sweeps per 25 blls of KCL water. 17:30 - 18:20 0.83 STWHIP N RREP PROD1 Nabors pump throttle acting up. Work on same. 18:20 - 18:25 0.08 STWHIP P PROD1 Drilling cement from 11056' to 11059'. Observe TF clicked during pump SO. 18:25 - 19:00 0.58 STWHIP P PROD1 PUH & orient TF to 27L. 19:00 - 20:45 1.75 STWHIP P PROD1 Continue drilling cement from 11059' to 11107' @ 21 L TF, 30fph ROP, 2.6bpm, 3450psi. Motor stalling @ 11101'. 20:45 - 21 :00 0.25 STWHIP P PROD1 Short trip to 11045'. 21 :00 - 21 :45 0.75 STWHIP P PROD1 Drill cement from 11107' to 11136' @ 15L TF, 25fph Rap, 2.6bpm, 3450psi. Occasional motor stalls @ 3600psi. 21 :45 - 21 :50 0.08 STWHIP P PROD1 PUH to 11107' and get a click. RBIH. 21 :50 - 00:00 2.17 STWHIP P PROD1 Drill hard cement from 11136' to 11162' @ HS TF I 20fph ROP, 2.6bpm, 3450psi. 12/11/2001 00:00 - 02:30 2.50 STWHIP P PROD1 Continue drilling hard cement from 11162' to 11199' @ 9R TF, 17fph ROP, 2.6bpm, 3450psi. 02:30 - 02:45 0.25 STWHIP P PROD1 Short trip to 11000'. 02:45 - 03:00 0.25 STWHIP P PROD1 Drill cement from 11199' to 11202'. Very slow progress. Decide to POOH for mill/bit change. 03:00 - 05:40 2.67 STWHIP P PROD1 POOH BHA#2. Flag EOP @ 9800' & continue POOH. 05:40 - 06:10 0.50 STWHIP P PROD1 DOH. Inspect bit and motor. Bit rerunable motor chg out. 06:10 - 06:50 0.67 STWHIP P PROD1 M/U rebuild STR324 bit and p/u new motor. Crew change held PJSM 06:50 - 10:00 3.17 STWHIP P PROD1 RIH to 3000' SHT MWD - OK test orienter - OK RIH pumps off 10900'.11000' no problems. 10:00 -10:20 0.33 STWHIP P PROD1 Orient to highside. 10:20 - 18:20 8.00 STWHIP P PROD1 Drill cement f/11202'. 3700 psi on bottom 3300 off. 2.7 bpm 50-60'/hr making short wiper trips every 75' drilled. Pumping 5 bbl bio sweeps every 25' drilled. Start swap to mud at 10400'. Tagged whipstock 11425' stalled p/u drill through slowly to 11436' that's 2' below window. We tagged the whipstock 5' high than expected and all these depths are uncorrected. Clean out whipstock area. 18:20 - 22:30 4.17 STWHIP P PROD1 TOH for build section BHA 22:30 - 22:45 0.25 STWHIP P PROD1 PJSM change out BHA 22:45 - 00:00 1.25 STWHIP P PROD1 Changeout BHA for building BHA. 12/12/2001 00:00 - 02:30 2.50 STWHIP P PROD1 RIH to 3000' SHT - all tools working good. RIH to 9595' correct to end of flag -20' RIH to 11300' 02:30 - 05:00 2.50 STWHIP P PROD1 Tie in log. Correction +18'. Printed: 12/26/2001 8:44:08 AM (" ~, BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 1 5-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/12/2001 05:00 - 06:40 1.67 STWHIP P PROD1 Attempting to get tool face. BHA in bind thru window. 06:40 - 14:45 8.08 STWHIP P PROD1 Directionally drill build section f/11440' holding highside TF to 30 left. 3200 psi OB 2900 FS 2.7 bpm Drill to 11575'. Projected survey at bit 76* 8647' TVD getting 39* DLS from 2.6 motor. 14:45 -15:15 0.50 STWHIP P PROD1 Wiper trip to window. Slight overpull at window. 15:15 -16:45 1.50 STWHIP P PROD1 TOH for 1.5* motor. Maximum expected DLS with this motor is 19* which should allow us to land well within well plan. 16:45 - 17:00 0.25 STWHIP P PROD1 Make a planned stop at 8181' to change out magnetic pilot valve under CU control panel. Circulate at minimum rate. 17:00 - 18:00 1.00 STWHIP P PROD1 Continue TOH 18:00 -18:20 0.33 STWHIP P PROD1 PJSM 18:20 - 19:00 0.67 STWHIP P PROD1 Change motor bend, bit and download TORC data. 19:00 -19:45 0.75 STWHIP P PROD1 RIH to 3000'. 19:45 - 20:00 0.25 STWHIP P PROD1 Shallow hole test. OK. 20:00 - 21 :25 1.42 STWHIP P PROD1 RIH to 10961'.PU and tie in to RA tag. 21 :25 - 22:30 1.08 STWHIP P PROD1 Tie in correction -5'. 22:30 - 00:00 1.50 STWHIP P PROD1 Drill ahead 11575' to 11595' (continuously rotating 11585'- .1- 11595') then start slide. 12/13/2001 00:00 - 01 :40 1.67 STWHIP P PROD1 Directionally drill f/11575' to 11,630. 01 :40 - 02:00 0.33 STWHIP P PROD1 PU to get survey. Reboot mwd computer. 02:00 - 03:00 1.00 STWHIP P PROD1 Directionally drill f/11630' to 10,645' with 3300 psi at 2.6 bpm 03:00 - 03:15 0.25 STWHIP P PROD1 PU to get survey. 03:15 - 04:20 1.08 STWHIP P PROD1 Directionally drill to 10,675'. 04:20 - 04:35 0.25 STWHIP P PROD1 Pu to get survey. 04:35 - 05:30 0.92 STWHIP P PROD1 Directionally drill to 10713' PU 43000, SO 12000 3300 psi at 2.6 bpm. 05:30 - 05:45 0.25 STWHIP P PROD1 Wiper trip 300' 05:45 - 13:00 7.25 STWHIP P PROD1 Directionally drilling. 3250 psi FS 3900 psi OB 2.6 bpm no losses. Highside TF finishing build section. Landed out at 11740'. Drilled through 1 st fault and was "kicked" up higher than anticapated to 96*. Drilled to 11901' in good sands. Unable to get expected doglegs from the 1.5* motor in these sands to kill the build and still stay reasonalby within the planned wellpath. Tripping to crank up the motor to 2.12* setting. 13:00 - 16:30 3.50 STWHIP P PROD1 TOH 16:30 - 18:20 1.83 STWHIP P PROD1 Change out motor setting to 2.12*, p/u new MWD package, download TORO info. 18:20 - 20:40 2.33 STWHIP P PROD1 RIH to 11348'. 20:40 - 21 :20 0.67 STWHIP P PROD1 Tie - in log correction -6' 21 :20 - 21:40 0.33 STWHIP P PROD1 RIH to 10,950' orientate high side to get thru tubing tail. RIH to 11901. 21 :40 - 22:45 1.08 STWHIP P PROD1 Directionally drill 2.6 bpm @3440 psi ROP 46'/hrFS 3350 psi. drill to 11957' 22:45 - 23:05 0.33 STWHIP P PROD1 PU to survey. 23:05 - 23:40 0.58 STWHIP P PROD1 Directionally drill to 11,985. 2.6 bpm @3700 psi. 23:40 - 00:00 0.33 STWHIP P PROD1 PU to survey 12/14/2001 00:00 - 00:45 0.75 STWHIP P PROD1 Directionally drill to 12022. Differentially stuck on bottom. 00:45 - 01:15 0.50 STWHIP N DPRB PROD1 Pump 10 bbl new mud and spot in open hole while waiting on crude oil. 01: 15 - 01 :20 0.08 STWHIP N DPRB PROD1 Shut down pump let pipe relax 01 :20 - 01 :35 0.25 STWHIP N PROD1 Wait on crude delivery. Pulled free before crude arrived. Canceled crude. Printed: 12/26/2001 8:44:08 AM {" ( BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: 1 5-36 Common Well Name: 1 5-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 38 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/14/2001 01:35 - 02:19 0.73 STWHIP P PROD1 Wiper trip 600', 02:19 - 04:21 2.03 STWHIP P PROD1 Directionally drill to 12,130' @ 2.6 bpm 3750 psi. FS 3440 psi. 04:21 - 05:10 0.82 STWHIP P PROD1 Wiper trip 783' 05:10 - 06:00 0.83 STWHIP P PROD1 Directionally drill from 12130' to 12204'. TORO in constant rotation mode. 06:00 - 07:15 1.25 STWHIP P PROD1 Wiper trip to window backreaming in constant rotation mode. 07:15 - 07:30 0.25 STWHIP P PROD1 Survey 07:30 - 08:55 1.42 STWHIP P PROD1 Orient to 90L Directionally drill f/12204' - 12242' @ 2.6 bpm 3400 FS 4000 OB put in rotation mode at 12242' to 12284'. Drilling ahead and became stuck. 08:55 - 09:15 0.33 STWHIP N DPRB PROD1 Stop pumps put string in neutral weight and wait. Pull free at 74k. 09:15 -10:35 1.33 STWHIP N PROD1 Wiper trip in rotation mode to window. 10:35 -12:00 1.42 STWHIP N PROD1 Directionally drill f/12284' to 12387'. Rotation 316-353' 12:00 - 12:25 0.42 STWHIP N PROD1 Wiper trip 100'. 12:25 - 14:35 2.17 STWHIP N PROD1 Directionally drill f/12387' to 12500' all rotation mode wI TORO. OB 4000 psi. 14:35 - 14:45 0.17 STWHIP N PROD1 Survey 14:45 - 18:15 3.50 STWHIP N PROD1 TOH for 1.5* motor. 18:15 - 19:30 1.25 STWHIP N PROD1 Adjust bend in motor. Swap MWD and download TORC 19:30 - 21 :24 1.90 STWHIP N PROD1 RIH to 11387 21 :24 - 22:30 1.10 STWHIP N PROD1 Tie-in -4' correction. Begin mud swap. 22:30 - 23:00 0.50 STWHIP N PROD1 RIH to 12509 23:00 - 00:00 1.00 STWHIP N PROD1 Directionally drill to 12584'. 12/15/2001 00:00 - 00:45 0.75 STWHIP P PROD1 Directionally drilled to 12644'. 00:45 - 01 :45 1.00 STWHIP P PROD1 Wiper trip 1200' 01 :45 - 04:30 2.75 STWHIP P PROD1 Directionally drill to 12825 @ 2.6 bpm 3200 psi FS 2950 psi ROP 100 ftlhr 04:30 - 06:00 1.50 STWHIP P PROD1 Wiper trip. 1350' 06:00 - 07:25 1.42 . STWHIP N DFAL PROD1 Attempting to issue orientation commands to the TORO orienter but it appears to be Dead. Repeated attempts with various commands - no responce. Surface equipment rebooted and functioning okay. 07:25 - 10:45 3.33 STWHIP N DFAL PROD1 Trip for back-up TORO tool. 10:45 - 11 :45 1.00 STWHIP N DFAL PROD1 Change out TORO and MHA. 11 :45 - 17:20 5.58 STWHIP N DFAL PROD1 TIH. Slow progress: repaired Anadrill's depth sensor cable coming from Dowell encoder, radio silence due to SLB perf job on DS 15, found hairline crack in Nabor's pump fluid-end after replacing valves, seats and seals. 17:20 -18:15 0.92 STWHIP N DFAL PROD1 Log tie-in at 11340' -8' correction. 18:15 -19:35 1.33 STWHIP N DFAL PROD1 TIH to 11850'. Electical problems in DS coil unit cab. 19:35 - 21:20 1.75 STWHIP P PROD1 Directionally drill f/12384' TO 12954' 21 :20 - 22:30 1.17 STWHIP P PROD1 Wiper trip. 1504'. 22:30 - 23:30 1.00 STWHIP P PROD1 Directionally drill to13000'. 23:30 - 00:00 0.50 STWHIP N SFAL PROD1 Failure of the electronic pump controls. Unable to send TORO commands. 12/16/2001 00:00 - 02:00 2.00 STWHIP N SFAL PROD1 POH to 10,666 Repair electronic pump controls. Replaced the relay for the throttle control and precision resistor by isolation cube. Swap to Nabors pump. 02:00 - 02:30 0.50 STWHIP N SFAL PROD1 Test pump controls. Torq accepted commands. Good test. 02:30 - 02:55 0.42 STWHIP N SFAL PROD1 RIH 02:55 - 04:20 1.42 STWHIP P PROD1 Directionally drill to 13010. TORO stopped accepting commands. Printed: 12/26/2001 8:44:08 AM (' ( ( BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 38 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/16/2001 04:20 - 07:50 3.50 STWHIP N DFAL PROD1 POH for TORO. Shallow hole test TORO for science - not working. 07:50 - 08:50 1.00 STWHIP N DFAL PROD1 Freeze protect coil. Same time download TORO data. Set TWC for BOPE test. 08:50 - 08:55 0.08 STWHIP P PROD1 Morñing call with Dick Owens resulted in calling the well TD'd at 13010'. Consult with town and decision made to run liner at this point in well operations. 08:55 - 12:30 3.58 CASE P CaMP RIU to run liner. Removed TWC. (Called AOGCC rep John Crisp asked and received 1 day extension on BOP test followed with e-mail. Plan to runlcmt liner then test.) UD Anadrill tools. Work liner on racks. Prep floor to run liner. 12:30 - 12:50 0.33 CASE P CaMP PJSM covering liner running procedures. 12:50 -17:30 4.67 CASE P CaMP Pick up 2 7/8" x 33/16" x 31/2" solid liner. 17:30 - 18:00 0.50 CASE P CaMP Mlu liner running tools and plu injector. 18:00 -18:35 0.58 CASE P CaMP RU coil connector and pull test. Pressure test coil connector. 18:35 -19:30 0.92 CASE P CaMP Displace freeze protection from coil with Flo-Pro. 19:30 - 22:00 2.50 CASE P CaMP RIH with liner to 13010'. Stalled at 12650' plu once and went to bottom. 22:00 - 22:40 0.67 CASE P CaMP Circulate ball down and release liner. 22:40 - 00:00 1.33 CASE P CaMP Change well over to KCL water. 12/17/2001 00:00 - 00:35 0.58 CEMT P CaMP PJSM for cementing operation. 00:35 - 01 :30 0.92 CEMT P CaMP Mix cement 01 :30 - 01 :45 0.25 CEMT P CaMP Pumped 13.5 bbls of 15.8ppg cement wi additives. 01 :45 - 01 :50 0.08 CEMT P CaMP Drop dart and confirm dart kicked out. 01:50 - 02:15 0.42 CEMT P CaMP Dart landed @ liner wiper plug 2.4 bbl early. 02:15 - 02:30 0.25 CEMT P CaMP Liner plug bumped .1 bbl early. 02:30 - 02:35 0.08 CEMT P CaMP Floats held 02:35 - 05:00 2.42 CEMT P CaMP POH 05:00 - 05:30 0.50 CEMT P CaMP Lay down liner running tool. PU tool to flush BOP stack. 05:30 - 06:15 0.75 CEMT P CaMP Freeze protect coil wi 50/50 methanol. 06:15 - 06:45 0.50 EVAL P PROD1 PJSM. Crew change. Discuss change in plans for today from BOP test to running CNL memory log. Conflicting logging jobs with 9ES nesessitates postponing BOP test until this evening. AOGCC notified of delay. This delay still within the 1 day extension time. 06:45 - 09:00 2.25 EVAL P PROD1 Mobilize logging equipment. Rabbit and strap 1 1/4" CS tubing. 09:00 - 09:15 0.25 EVAL P PROD1 PJSM covering SLB source handling and logging BHA. 09:15 - 12:00 2.75 EVAL P PROD1 P/U logging BHA 12:00 - 12:40 0.67 EVAL P PROD1 P/U injector. 12:40 -13:15 0.58 EVAL P PROD1 Displace meth in coil to opentop. 13:15 -17:00 3.75 EVAL P PROD1 RIH w/MCNL to 10800' Log down tag 12923'. 17:00 -18:30 1.50 EVAL P PROD1 Log up 2123'. 18:30 -19:00 0.50 EVAL P PROD1 PJSM 19:00 -19:50 0.83 EVAL P PROD1 POH to surface. 19:50 - 20:30 0.67 EVAL P PROD1 Freeze protect the coil 20:30 - 21 :30 1.00 EVAL P PROD1 Stand back the 1-1/4" CS Hydril tubing 21 :30 - 23:30 2.00 EVAL P PROD1 NO Logging tools. Wait on notifications and orders. Postponed BOP test OK per John Crisp AOGCC. Permission given for only 1 try at retrieving tools. Wait on fishing tools. 23:30 - 00:00 0.50 EVAL N HMAN PROD1 PJSM . Pick up fishing tools. 12/18/2001 00:00 - 00:45 0.75 EVAL N HMAN PROD1 RIH with CS Hydril. 00:45 - 03:15 2.50 EVAL N HMAN PROD1 RIH with coil top of fish 12904. PU 42000# 03:15 - 03:20 0.08 EVAL N HMAN PROD1 PU 55000# pulled 15M over. Pulled free. POH 42500# Printed: 12/26/2001 8:44:08 AM ( ~' I~ BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/18/2001 03:20 - 04:20 1.00 EVAL P PROD1 LOG up to 10800 at 30'/min 04:20 - 06:00 1.67 EVAL P PROD1 POH to Hydril tubing string. 06:00 - 06:15 0.25 EVAL P PROD1 PJSM standback Hydril and lay down fish. 06:15 - 06:45 0.50 EVAL P PROD1 Break off injector and set on deck. 06:45 - 09:00 2.25 EVAL P PROD1 Stand back 1 1/4" CS Hydril tubing 09:00 - 09:10 0.17 EVAL P PROD1 PJSM concerning the handling of CNL source material. 09:10 - 09:30 0.33 EVAL P PROD1 Pull last joint CSH with fishing tools and MCNL tool. UD same. Sent tools directly to 9ES location on W pad. Will download any logging data there. Notified AOGCC rep John Crisp of pending BOP test. 09:30 - 10:00 0.50 PERF P CaMP Clear floor, ready to test BOP. 10:00 -10:30 0.50 PERF P CaMP Install TWC grease valves. 10:30-18:15 7.75 PERF P CaMP Testing BOPE AOGCC rep John Crisp on location 18:15 -19:00 0.75 PERF P CaMP PJSM prior to Pulling TWC and Picking up cleanout BHA. 19:00 - 20:00 1.00 PERF P CaMP Pull TWC. 20:00 - 22:00 2.00 PERF P CaMP PU BHA. 22:00 - 23:30 1.50 PERF P CaMP Circulate methanol out of coil and stab on injector head. 23:30 - 00:00 0.50 PERF P CaMP RIH with coil to 3000' at midnight. 12/19/2001 00:00 - 01 :25 1.42 PERF P CaMP Continue to RIH to the liner top. 01 :25 - 01 :30 0.08 PERF P CaMP PU wt. of 40,000# and RIH wt. of #15,000 at 10,600'. Start circulating at 1.9 BPM at 2775 psi at 10,928'. 01:30 - 04:15 2.75 PERF P CaMP Continue to run in the liner at 30 FPM and Tag PBTD at 13,010 CTD. Pull to the liner top at 30 FPM while circulating at 1.9 BPM and 2980 psi. 04:15 - 04:45 0.50 PERF P CaMP Pull the BHA up to 10,750'. Attempt to pressure test the liner lap to 2500 psi. No test. Attempt a second time. No test. Could pump into the well at 1 BPM at 2100 psi. 04:45 - 06:00 1.25 PERF P CaMP Circulate a 100,000 LSRV flo-pro pill into the liner in preparation for the upcoming perforating job. 06:00 - 06:30 0.50 PERF P CaMP PJSM 06:30 - 08:23 1.88 PERF P CaMP POH 08:23 - 08:45 0.37 PERF P CaMP Set back injector on deck. 08:45 - 09:10 0.42 PERF P CaMP PJSM for Standing back Hydril 09:10 -10:50 1.67 PERF P CaMP Stand back 32 stands and one single CS Hydril tubing. 10:50-11:17 0.45 PERF P CaMP PU liner top packer and running tools 11 : 17 - 11 :42 0.42 PERF P CaMP PU injector head 11:42 - 15: 15 3.55 PERF P CaMP RIH sting into top of liner Stack 10K over neutral weight. 15:15 -15:46 0.52 PERF P CaMP PU to drop ball. Circulate ball to seat. 15:46 -15:53 0.12 PERF P CaMP Ball on seat stab back into liner top 15:53 -16:00 0.12 PERF P CaMP Set packer. Top of KB packer is at 10,922.57' (pipe tally measure). 16:00 - 16:15 0.25 PERF P CaMP Test liner top packer by pressuring backside to 2000 psi.Terminated test when coil fluid temperature reached 35 degrees. Ambient temperature -30 degrees. 16:15 -18:00 1.75 PERF P CaMP Shear off packer and POH. 18:00 -18:30 0.50 PERF P CaMP PJSM handover 18:30 -18:50 0.33 PERF P CaMP POH to surface 18:50 - 20:00 1.17 PERF P CaMP Lay down packer running tool 20:00 - 20:30 0.50 PERF P CaMP Pressure test liner top packer by pressuring up on the wellbore to 2,000 psi for 30 minutes. Ok. 20:30 - 00:00 3.50 PERF N WAIT CaMP Wind chills dropped below -80 degrees F. (-27 degrees F with 20+ MPH winds) Next planned operation involves picking up perforating guns with personnel exposed to temperature Printed: 12/26/2001 8:44:08 AM ( ( BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 1 5-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 12/21/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/19/2001 20:30 - 00:00 3.50 PERF N WAIT CaMP extremes. Stand down outside operations until wind chill warms up to a temperature above -80 degrees F. 12/20/2001 00:00 - 02:00 2.00 PERF N WAIT CaMP Wait for winds to calm and wind chill to rise above -80 degrees F. 02:00 - 02:15 0.25 PERF P CaMP PJSM to discuss picking up guns. 02:15 - 05:15 3.00 PERF P CaMP Pick up 2" Schlumberger perforating guns loaded with 2006 charges, 4 spf to perf. the following intervals: 12,000'-12,390' , 12,440'-12,690' , 12,780'-12,990' for a total of 850' of perforations (1002.58' counting blank sections and the gun nose). 05:15 - 08:15 3.00 PERF P CaMP Pick up the 32 stands of 1-1/4" CSH. 08:15 -10:24 2.15 PERF P CaMP RIH with perforating guns. 10:24 - 10:52 0.47 PERF P CaMP circulate ball and fire guns. 10:52 -13:00 2.13 PERF P CaMP POH 13:00 - 14:00 1.00 PERF P CaMP Strip off well. Set injector on deck 14:00 - 14:15 0.25 PERF P CaMP PJSM LD Hydril work string. 14:15 -16:30 2.25 PERF P CaMP Lay down Hydril tubing string. 16:30 - 16:45 0.25 PERF P CaMP PJSM lay down perforating guns 16:45 - 18:00 1.25 PERF P CaMP Lay down perforating guns. 18:00 - 18:30 0.50 PERF P CaMP Safety meeting after crew change to go over laying down the remainder of the guns. 18:30 - 20:30 2.00 PERF P CaMP Finish laying down perforating guns. All shots fired. 20:30 - 21 :30 1.00 WHSUR P CaMP Make up nozzle to freeze protect well. 21:30 - 21:50 0.33 WHSUR N MiSe CaMP Thaw out an ice plug in the return line from the rig to the Dowell pump. 21 :50 - 22:50 1.00 WHSUR P CaMP RIH to 2000' and freeze protect the tubing and coil with 60/40 methanol to surface. 22:50 - 23:05 0.25 WHSUR P CaMP Lay down nozzle. 23:05 - 00:00 0.92 WHSUR P CaMP RU lubricator and set BPV. 12/21/2001 00:00 - 00:30 0.50 WHSUR P CaMP Finish setting the BPV. 00:30 - 04:30 4.00 RIGD P CaMP Vac out hard lines, cuttings box, and tiger tank. Nipple down BOP, install and pressure test the tree cap to 4000 psi. Nabors 3S released at 0430 hrs on 12-21-2001 Last report Printed: 12/26/2001 8:44:08 AM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field....................: Prudhoe Bay Well.....................: DS15-36a API number...............: 50-029-22480-02 Engineer.................: E. Roux COUNTY:..................: STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: GR Tie-in @ 11337 ft GL above permanent.......: -50000.00 ft KB above permanent.......: -50000.00 ft DF above permanent.......: -50000.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 287.17 degrees [(c)2001 Anadrill IDEAL ID6_1C_10] 16-Dec-200120:33:02 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 3 10-Dec-01 16-Dec-01 41 11394.75 ft 13010.00 ft -~ ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date............: 09-Dec-2001 Magnetic field strength..: 1149.79 HCNT Magnetic dec (+E/W-).....: 26.55 degrees Magnetic dip.............: 80.80 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G.............. : H. . . . . . . . . . . . . . : Dip. . . . . . . . . . . . : of G.. . . . . . . . . . : of H.. . . . . . . . . . : of Dip. . . . . . . . . : Criteria --------- 1002.68 mGal 1149.79 HCNT 80.80 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees -. ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.55 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.55 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 1 2 3 4 5 11394.75 11430.00 11487.87 11512.92 11542.82 ------ ------ Incl angle (deg) ------ ------ 22.41 22.10 40.96 49.45 59.24 64.42 68.89 72.46 77.71 82.55 85.03 89.62 96.28 95.80 94.80 87.57 81.02 80.08 83.30 89.28 88.08 90.65 90.03 89.14 88.90 88.05 88.53 89.49 89.59 89.62 ------- ------- Azimuth angle (deg) ------- ------- 20.74 20.48 13.72 7.90 5.86 6.71 7.07 7.07 7.78 5.91 3.64 0.67 0.84 356.29 352.00 347.49 339.89 330.41 320.27 309.34 296.03 287.60 286.85 282.93 273.83 264.16 261.15 258.02 260.48 259.99 ------ ------ Course length (ft) ------ ------ 0.00 35.25 57.87 25.05 29.90 21.89 30.15 22.94 29.93 30.99 23.20 37.38 53.42 40.29 35.10 54.70 29.92 35.27 30.00 38.50 36.98 36.02 43.65 45.95 68.40 30.43 52.65 48.02 44.58 46.32 [(c)2001 Anadrill IDEAL ID6_1C_I0] 6 7 8 9 10 11564.71 11594.86 11617.80 11647.73 11678.72 11 12 13 14 15 11701.92 11739.30 11792.72 11833.01 11868.11 16 17 18 19 20 11922.81 11952.73 11988.00 12018.00 12056.50 21 22 23 24 25 12093.48 12129.50 12173.15 12219.10 12287.50 26 27 28 29 30 12317.93 12370.58 12418.60 12463.18 12509.50 -------- -------- TVD depth (ft) -------- -------- 8518.28 8550.90 8600.02 8617.66 8635.07 8645.40 8657.35 8664.94 8672.64 8677.95 8680.46 8682.20 8679.45 8675.21 8671.97 8670.84 8673.81 8679.62 8683.96 8686.46 8687.32 8687.72 8687.46 8687.79 8688.96 8689.78 8691.35 8692.18 8692.54 8692.85 16-Dec-200120:33:02 -------- -------- Vertical section (ft) -------- -------- -1078.17 -1078.97 -1078.45 -1076.41 -1072.05 -1068.41 -1063.47 -1059.68 -1054.78 -1049.31 -1044.35 -1034.68 -1019.61 -1006.83 -993.16 -967.98 -951.59 -928.33 -905.02 -871.04 -835.50 -799.64 -755.99 -710.08 -642.57 -613.70 -565.83 -523.28 -483.90 -442.60 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 5985.03 5997.53 6026.42 6043.86 6067.95 6087.13 6114.60 6136.08 6164.75 6195.05 6218.04 6255.33 6308.65 6348.69 6383.45 6437.21 6465.76 6497.29 6521.66 6548.68 6568.60 6581.97 6594.89 6606.70 6616.65 6616.12 6609.39 6600.71 6592.40 6584.54 2978.18 2982.88 2991.27 2994.53 2997.41 2999.52 3002.84 3005.51 3009.25 3012.88 3014.80 3016.20 3016.90 3015.90 3012.33 3002.60 2994.26 2979.67 2962.80 2935.59 2904.54 2871.14 2829.44 2785.05 2717.46 2687.08 2634.89 2587.68 2543.88 2498.24 --------------- Page --------------- Total displ (ft) At Azim (deg) --------------- --------------- 6685.07 6698.35 6727.96 6745.03 6767.90 6786.04 6812.15 6832.61 6860.01 6888.84 6910.35 6944.54 6992.91 7028.62 7058.51 7103.05 7125.42 7147.95 7163.12 7176.55 7182.12 7180.93 7176.24 7169.72 7152.95 7140.97 7115.25 7089.82 7066.19 7042.54 26.46 26.44 26.40 26.36 26.29 26.23 26.16 26.10 26.02 25.94 25.87 25.74 25.56 25.41 25.26 25.01 24.85 24.64 24.43 24.15 23.85 23.57 23.22 22.86 22.33 22.10 21.74 21.41 21.10 20.78 2 of 3 ----- ----- DLS (deg/ 100f) ----- ----- 0.00 0.92 33.11 37.66 33.21 23.91 14.87 15.56 17.69 16.71 14.45 14.62 12.47 11.29 12.50 15.57 33.43 26.65 35.12 32.30 36.13 24.46 2.23 8.75 13.31 31.89 5.79 6.82 5.52 1.06 ----- ----- ----- ----- TIP MWD SP SP SP MWD MWD SP SP SP MWD MWD SP SP SP SP SP MWD MWD MWD SP MWD SP MWD MWD MWD MWD MWD SP MWD ------ ------ Srvy tool type Tool qual type ------ ------ 6-axis ~- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis .--.. 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 31 32 33 34 35 12567.50 12616.00 12658.50 12706.00 12738.00 ------ ------ Incl angle (deg) ------ ------ 89.79 87.56 84.61 85.23 91.27 89.62 88.08 87.53 87.05 87.67 87.60 ------- ------- Azimuth angle (deg) ------- ------- 259.04 254.57 248.28 250.50 251.85 243.93 252.04 253.12 253.95 258.50 256.00 ------ ------ Course length (ft) ------ ------ 58.00 48.50 42.50 47.50 32.00 56.50 53.41 52.09 55.50 27.50 27.00 [(c)2001 Anadrill IDEAL ID6_1C_10] 36 37 38 39 40 12794.50 12847.91 12900.00 12955.50 12983.00 41 13010.00 -------- -------- TVD depth (ft) -------- -------- 8693.15 8694.28 8697.18 8701.39 8702.36 8701.92 8703.00 8704.99 8707.62 8708.88 8710.00 16-Dec-200120:33:02 -------- -------- Vertical section (ft) -------- -------- -391.23 -349.41 -315.02 -277.63 -251.76 -208.07 -166.72 -123.87 -77.71 -54.16 -30.78 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 6573.99 6562.93 6549.43 6532.78 6522.46 6501.22 6481.22 6465.63 6449.92 6443.38 6437.43 2441.21 2394.01 2353.85 2309.56 2279.30 2227.00 2177.54 2127.88 2074.71 2048.04 2021. 73 --------------- Page --------------- Total displ (ft) At Azim (deg) --------------- --------------- 7012.62 6985.94 6959.57 6929.02 6909.25 6872.07 6837.24 6806.78 6775.39 6761.04 6747.43 20.37 20.04 19.77 19.47 19.26 18.91 18.57 18.22 17.83 17.63 17.44 3 of 3 ----- ----- DLS (deg/ 100f) ----- ----- 1.66 10.30 16.31 4.83 19.34 14.32 15.45 2.33 1.73 16.68 ----- ----- Srvy tool type ----- ----- MWD MWD MWD MWD MWD MWD SP MWD MWD MWD ------ ------ Tool qual type ------ ------ .~ 6-axis 9.26 Projected to TD ,.-..\ ANADRILL SCRLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. ...... .............: Prudhoe Bay Well.....................: 15-36aF~\ API number..... ..........: 50-029-22480-01 Engineer. . . . . . . . . . . . . . . . .: M. Brown COUNTY:..................: Nabors 3S / Dowell # 4 STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS........ ...: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: GR Tie-In @ 11439 ft GL above permanent.......: 0.00 ft KB above permanent.......: -50000.00 ft DF above permanent.... ...: -50000.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-).. ......: -999.25 ft Azimuth from rotary table to target: -57252.81 degrees [(c)2001 Anadrill IDEAL ID6_1C_10] 22-Sep-200109:09:53 Spud date................: Last survey date... ......: Total accepted surveys...: MD of first survey. ......: MD of last survey........: Page 1111/11 ~I~ mlll~ IUIWII rullnß~1II ßIIII~ 1111 ~II 10202641554 W'1-1:J=- /1 ~ 70 T/~#:- IOCl CJ D 1 of 3 15-Sep-01 21-Sep-01 42 11420.00 ft 12996.17 ft -~~ ----- Geomagnetic data ---------------------- Magnetic model..... ... ...: BGGM version 2000 Magnetic date.. ...... ....: 14-Sep-2001 Magnetic field strength..: 1149.75 RCNT Magnetic dec (+E/W-) .....: 26.63 degrees Magnetic dip.............: 80.80 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: R..............: Dip............: of G...........: of R...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.75 RCNT 80.80 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ,-~. ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.63 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.63 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 22-Sep-200109:09:53 Page 2 of 3 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) ( deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 1 11420.00 22.74 20.60 25.20 8541.57 -1317.19 5994.05 2981.61 6694.67 26.45 1.36 MWD 2 11446.00 23.93 17.70 26.00 8565.44 -1317.91 6003.78 2984.98 6704.88 26.44 6.36 MWD 3 11462.00 30.14 15.91 16.00 8579.69 -1318.12 6010.74 2987.07 6712.05 26.43 39.14 MWD 4 11477.39 35.45 14.19 15.39 8592.62 -1318.10 6018.79 2989.23 6720.22 26.41 35.03 MWD 5 11500.00 42.81 11.66 22.61 8610.15 -1317.53 6032.69 2992.39 6734.07 26.38 33.30 MWD 6 11520.19 49.97 9.41 20.19 8624.07 -1316.35 6047.05 2995.05 6748.12 26.35 36.36 MWD - _. 7 11544.59 57.45 6.68 24.40 8638.50 -1313.92 6066.51 2997.77 6766.77 26.30 31.95 SP 8 11570.63 59.23 10.40 26.04 8652.17 -1311.39 6088.42 3001.07 6787.88 26.24 13.95 SP 9 11627.23 69.30 10.28 56.60 8676.72 -1307.17 6138.52 3010.21 6836.87 26.12 17.79 SP 10 11690.35 81.32 9.25 63.12 8692.69 -1301.48 6198.58 3020.53 6895.36 25.98 19.11 MWD 11 11725.18 88.30 10.28 34.83 8695.84 -1298.26 6232.74 3026.41 6928.65 25.90 20.26 SP 12 11774.68 92.68 6.73 49.50 8695.42 -1292.58 6281.68 3033.73 6975.89 25.78 11.39 MWD 13 11813.33 88.70 358.14 38.65 8694.95 -1284.12 6320.25 3035.37 7011.35 25.65 24.49 SP 6-axis 14 11892.18 86.31 349.36 78.85 8698.39 -1255.47 6398.47 3026.81 7078.28 25.32 11.53 MWD 15 11905.68 85.98 347.56 13.50 8699.30 -1249.43 6411.67 3024.11 7089.06 25.25 13.61 SP 16 11973.55 85.43 330.24 67.87 8704.43 -1209.61 6474.57 2999.84 7135.76 24.86 25.44 SP 6-axis 17 12065.95 89.29 317.03 92.40 8708.70 -1137.57 6548.70 2945.23 7180.52 24.22 14.88 SP 6-axis 18 12091.88 90.84 313.61 25.93 8708.67 -1115.17 6567.14 2927.00 7189.90 24.02 14.48 SP 6-axis 19 12127.18 92.05 309.86 35.30 8707.78 -1083.63 6590.62 2900.67 7200.71 23.76 11.19 SP 20 12153.88 89.60 305.21 26.70 8707.40 -1058.96 6606.88 2879.50 7207.11 23.55 19.68 SP 21 12224.00 88.83 289.71 70.12 8708.37 -990.68 6639.11 2817.48 7212.21 23.00 22.12 MWD .-. 22 12275.38 90.38 274.28 51.38 8708.72 -939.54 6649.75 2767.37 7202.61 22.60 30.18 SP 23 12309.69 92.25 267.26 34.31 8707.93 -906.32 6650.21 2733.10 7189.93 22.34 21.17 SP 24 12352.89 90.43 255.78 43.20 8706.92 -866.81 6643.85 2690.46 7167.94 22.05 26.90 SP 25 12393.77 91.65 244.13 40.88 8706.18 -833.45 6629.87 2652.12 7140.65 21.80 28.65 SP 26 12415.82 94.70 238.03 22.05 8704.95 -817.62 6619.23 2632.86 7123.63 21.69 30.89 SP 27 12460.63 98.57 234.54 44.81 8699.78 -788.32 6594.54 2595.85 7087.06 21.49 11.59 MWD 4-axis 28 12517.03 96.53 254.13 56.40 8692.29 -746.17 6570.46 2545.70 7046.39 21.18 34.62 SP 29 12537.11 95.05 259.48 20.08 8690.27 -728.59 6565.91 2526.26 7035.13 21.04 27.51 SP 30 12582.00 93.30 270.00 44.89 8686.99 -686.68 6561.81 2481.74 7015.44 20.72 23.69 MWD ANADRILL SCHLUMBERGER Survey Report 22-Sep-200109:09:53 Page 3 of 3 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) ( deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 31 12606.88 91.55 268.38 24.88 8685.94 -662.77 6561.46 2456.89 7006.36 20.53 9.58 SP - 32 12642.41 89.34 261.73 35.53 8685.66 -629.42 6558.40 2421.51 6991.16 20.27 19.72 SP 6-axis 33 12669.46 88.38 254.18 27.05 8686.20 -605.37 6552.76 2395.08 6976.76 20.08 28.13 SP - 34 12707.90 88.50 260.28 38.44 8687.25 -571.42 6544.27 2357.63 6956.00 19.81 15.87 SP 6-axis 35 12753.42 84.64 241.56 45.52 8690.00 -533.99 6529.50 2314.88 6927.70 19.52 41.91 MWD - 36 12769.60 82.90 238.61 16.18 8691.75 -522.62 6521.48 2300.94 6915.49 19.43 21.07 SP 6-axis -~- 37 12793.15 82.51 232.84 23.55 8694.74 -507.42 6508.33 2281.64 6896.69 19.32 24.36 SP 6-axis 38 12832.63 84.71 225.77 39.48 8699.14 -485.38 6482.77 2251.92 6862.75 19.16 18.65 SP 6-axis 39 12852.41 86.92 221.72 19.78 8700.59 -475.93 6468.52 2238.29 6844.83 19.09 23.28 SP 6-axis 40 12888.52 89.28 221.16 36.11 8701.79 -459.92 6441.46 2214.40 6811.46 18.97 6.72 SP 6-axis 41 12930.75 89.38 229.04 42.23 8702.28 -438.82 6411.68 2184.51 6773.61 18.81 18.66 SP 6-axis 42 12996.17 93.30 238.86 65.42 8700.75 -397.86 6373.24 2131.72 6720.30 18.49 16.14 SP .-,- 02/04/02 Scblunlberger NO. 1778 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherñe 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 Description Date Bluellne Sepia Color Prints CD D.S.7-19A 'ClR- Od t.t 22032 MCNL 12/24/01 1 1 1 D.S. 15-36A <Ãt)J-Itç.~ 22018 MCNL 12/18/01 1 1 1 D.S. 5-26A ~ D}- :l -=:l \ 22047 USIT 01/21/02 2 .-<-. 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 ~~~ Received: . -L-~ Date Delivered: F EB {) ~ 2002 AIa8ka Oil & Gas Cons. Commission And1or8ge Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No 15-36a Date Dispatche 9-Jan-O2 Installation/Rig Nabors 3S / SLB CTU # 4 Dispatched By: Nate Rose (' MWD/LWD Log Product Delivery ('" Data No Of Prints No of Floppies Surveys 2 Received By: C-~ ì 11flÐ OJ).A ... I '~E,(~EI'lE,D LWD Log Delivery V1.1, Dec '97 ,AIs5ka on t1 Gas Cons, CommlSS¡Ol Anchorage 1 Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 ;;)ol-/lJ'ð " .:. ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: a Operation Shutdown 0 Stimulate 0 Pull Tubing 0 Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 0 Plugging 0 Perforate 0 Repair Well 0 Other 5. Type of well: ~ Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (OF or KB) KBE = 65.75' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 1440' SNL, 887' EWL, SEC. 22, T11 N, R14E, UM At top of productive interval N/A At effective depth 4912' NSL, 2997' EWL, SEC. 15, T11N, R14E, UM At total depth 4912' NSL, 2997' EWL, SEC. 15, T11N, R14E, UM 12. Present well condition summary Total depth: measured 8. Well Number 15-36A 9. Permit Number / Approval No. 201-162 301-278 10. API Number 50- 029-22480-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool true vertical 13036 feet 8764 feet 13036' feet 8764 feet Plugs (measured) Set Whipstock at 11430' (08/01) true vertical Effective depth: measured Junk (measured) Tubing Tail has backed off below XN nipple and dropped 2' - 3', setting on top of 5-1/2" Liner. (09/01) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 80' 20" 260 sx Arcticset (Approx.) 110' 110' 3872' 11086' 848' 10-3/4" 7-5/8" 5-1/2" 1105 sx PF 'E', 375 sx Class 'G' 617 sx Class 'G' 126 sx Class 'G' 3907' 11119' 10965' - 11428' 3565' 8333' 8197'- 8615' Perforation depth: measured None Packers and SSSV (type and measured depth) 4-1/2", 12.6#, L-80, Tubing at 10966' OCT 1 7 2001 Baker SABL-3 Packer at 10904'; 4-1/2" SVLN at 2jfi8'k as a Oil & Gas Cons C . . . on""', , .-ge RECEIVED true vertical None Tubing (size, grade, and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Dailv Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 0 Copies of Logs and Surveys run ~ Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Sioned Terrie Hubble ~fu~ t\lJi6et Title Technical Assistant 16. Status of well classifications as: 181 Oil 0 Gas 0 Suspended Service Date ID.{7.01 Form 10-404 Rev. 06/15/88 ORJG'~'At Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate '. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/13/2001 9/14/2001 9/15/2001 9/16/2001 ( ( Page 1 of 6 BP EXPLORATION Operations Summary Report 1 5-36 15-36A REENTER+COMPLETE NABORS NABORS 3S 00:00 - 00:00 From - To Hours Activity Code NPT PRE 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:30 03:30 - 05:00 05:00 - 10:30 10:30 -15:30 15:30 - 16:00 16:00 - 17:00 17:00 -18:00 18:00 -19:00 19:00 -19:45 19:45 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 06:00 06:00 - 07:00 07:00 - 07:15 07:15 - 09:30 09:30 - 13:30 13:30 -14:45 14:45-17:15 17:15-18:00 18:00 - 18:15 18:15 -18:45 18:45 - 21 :45 22:00 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 03:30 24.00 MOB P 1.00 MOB 1.50 MOB P P 1.00 RIGU P 1.50 RIGU 5.50 RIGU 5.00 RIGU P P P 0.50 RIGU 1.00 RIGU 1.00 RIGU P P P 1.00 RIGU P 0.75 RIGU P 3.25 STWHIP P 1.00 STWHIP P 1.50 STWHIP P 4.50 STWHIP P 1.00 STWHIP P 0.25 STWHIP P 2.25 STWHIP P 4.00 STWHIP P 1.25 STWHIP P 2.50 STWHIP P 0.75 STWHIP P 0.25 DRILL 0.50 DRILL P P 3.00 DRILL P 2.00 DRILL P 0.50 DRILL 1.00 DRILL P P 2.00 DRILL P Phase PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 9/14/2001 Rig Release: 9/24/2001 Rig Number: Spud Date: 9/14/2001 End: Description of Operations RD ON 7-16, MOVE RIG AND CAMP TO 15-36A LOCATION. RU. MOVE CTDE FROM 07-16A TO 15-36A. ARRIVED 15-36A. SPOT SUB OVER WELL. MOVE CAMP TO 15-36A. GENERAL R/U OF CTDE. SPOT BOILER COMPLEX. RAISE MAST. SET-UP BEAVER SLIDE, CATWALK AND PIPE RACKS. SPOT AND RU CTU #4. RIG ACCEPTED @ 05:00 HRS on 9/14/01. PJSM. NU BOPE. PRESS TEST BOPE TO 250 / 3500 AS PER BP / AOGCC REQU I REMENTS. RU LUBRICATOR AND PULL TWC. NO WHP. PU INJECTOR AND CUT PIPE. PRESS TEST INNER REEL VALVE, FLOWBACK LINES AND PACKOFF TO 4,000 PSI - OKAY. PJSM. PULL TEST COIL CONNECTOR TO 4,000 PSI - OK. PRESS TEST MHA TO 4,000 PSI - OK. RIH, TAG X NIPPLE AT 10,937'. MILL X NIP TO 10,940'. FIN MILLING 'XN' NIPPLE, RIH AND DISPLACE WELL TO KCL. RIH TO PINCH POINT. BEGIN MILLING WINDOW AT 11,428.3' CTM. Update at 06:00. Milling ahead at 11431.5', have made 3.2' since 01 :00 AM, and expect the window should be 6-7'. Continue milling. 2.6 bpm in, 2.6 bpm out, 100% returns. 2025 psi CTP. Tour safety meeting. Discuss muster area, possible lost circulation zone, well H2S status. Plan for day ahead. Continue milling window as before. Mill casing to 11435', saw drilling break, probable bottom of window. Probable window length=6.8'. Mill formation to 11445.6', for 10' of rathole. Ream up and down 3 times through interval. Slight work on first up pass. Clean afterwards. Dry drift up and down through window, no problems. POOH with window milling BHA Tag up at surface with milling BHA. No fluid losses while POOH. Lay down BHA #1. Mill slightly under gauge at 3.77", string reamer spot on gauge at 3.80". STANDBY FOR NEW CREWS TO CHANGE OUT TOURS. PJSM, PTSM - DISCUSS TOOL HANDLING, MU, AND PERSONNEL ASSIGNMENTS. PU / MU BHA #2, DEPTH ENCODER TO READING, RECONNECT -OK. RIH W/ BHA #2 (TORC DIRECTIONAL ASSEMBLY), SHT @ 1,600'- OK. RIH, PASS THRU WINDOW OKAY. DISPL HOLE TO FLO-PRO MUD. MAKE GR COORELA TION - NO USEABLE DATA. DRILL NEW HOLE TO 11,469', TIE IN WITH RA MARKER (-3' CORRECTION) Printed: 10/17/2001 1:18:51 PM " ( (' BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: 1 5-36 Common Well Name: 1 5-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 9/24/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/16/2001 03:30 - 06:00 2.50 DRILL P PROD1 DRILL AHEAD TO 11,530'. 06:00 - 06:30 0.50 DRILL P PROD1 Changeout and tour safety meeting. 06:30 - 07:00 0.50 DRILL P PROD1 Continue drilling build section. 2.7 in, 2.7 out, no losses. CTP 2850 psi. Holding high side tool face. 07:00 - 07:45 0.75 DRILL N DFAL PROD1 Getting more build than needed, attempt to go to rotation mode with the Torq orienter to straighten out build. Unable to get orienter to accept command properly to rotate. Tried on bottom and when short tripping. Never got it to rotate. Finally sent a different command, and got it to take a 11 OL TF command. Can continue on this TF for now. 07:45 - 10:30 2.75 DRILL P PROD1 11543' Continue on build section, starting turn. 10:30 - 11 :00 0.50 DRILL P PROD1 11570', Need to trip for lateral section motor. POOH. Will attempt to troubleshoot orienter on way OOH. Found probably problem with Torq orienter with surface software. Able to rotate after software debugged. 11 :00 - 11 :30 0.50 DRILL P PROD1 Klck/H2S weekly drill, including rig evacuation. 11:30-12:15 0.75 DRILL P PROD1 Continue POOH. 12:15 -13:45 1.50 DRILL P PROD1 Tag up at surface. Lay down motor and bit from BHA #2. Bit in good shape. Pick up BHA #3, to drill lateral section. 13:45 - 15:30 1.75 DRILL P PROD1 PU/MU BHA# FOR LATERAL SECTION. 15:30 -18:00 2.50 DRILL P PROD1 RIH with BHA #3, 1.37 deg motor, and DS49 bit to start lateral section. Also, Schlumberger reports that they have made a software change to their surface computer, while changing BHA's. This should allow rotation while drilling with the Tore orienter. 18:00 -19:00 1.00 DRILL P PROD1 COORELATE W/ GR. (-2') COORECTION AT RA TAG. HELD WEEKLY SAFETY MTG W/ DAYLIGHT CREW. 19:00 - 20:30 1.50 DRILL P PROD1 DRILL TO 11, 639' WHERE TF BEGAN WALKING BETWEEN -30 AND 10 DEG. 20:30 . 22:00 1.50 DRILL N DFAL PROD1 WORKED WITH TOOL (TURN OFF/ON), BUT TF STILL NOT CORRECT AT -15 DEG. 22:00 - 22:15 0.25 DRILL P PROD1 WIPER TRIP TO JUST OUTSIDE WINDOW, SEND COMMANDS TO TORC DURING TRIP. 22:15 - 23:15 1.00 DRILL N DFAL PROD1 DRILL HOLE IN LATERAL SECTION. TF LOOKED GOOD WHILE CIRCULATING, BUT WENT TO 9 DEG WHILE ON BTM. RESEND COMMAND TO TURN 90L, NO RESPONSE. TRIED TURNING R, NO RESPONSE, TRIED TURNING INCREMENTALLY, NO RESPONSE. TRIED TO CYCLE POWER TO TORC - NO RESPONSE. CHANGE THROTTLE TIMING AND % MOD. - NO RESPONSE. 23:15 - 00:00 0.75 DRILL N DFAL PROD1 CALL TORC SPECIALISTS, ADVISE TO USE BACKUP TOOL. PREP TO TRIP FOR NEW TORC AND MWD TOOLS. 9/17/2001 00:00 - 01 :30 1.50 DRILL N DFAL PROD1 CONT. POOH FOR NEW TORC ORIENTER AND NEW MWD. 01 :30 - 03:30 2.00 DRILL N DFAL PROD1 PJSM. PU / MU NEW TORC AND MWD. SURFACE TEST - OKAY. 03:30 - 04:15 0.75 DRILL N DFAL PROD1 RIH W/ BHA#4. SHT AT 1,600'. OKAY. 04:15-05:30 1.25 DRILL N DFAL PROD1 RIH TO TIE-IN LOGGING POINT. 05:30 - 06:00 0.50 DRILL N DFAL PROD1 RUN GR COOR. LOG. 06:00 - 07:30 1.50 DRILL N DFAL PROD1 Logging Gamma Ray tie in pass over RA pip tag in whipstock. Make a +6' depth correction. 07:30 - 08:45 1.25 DRILL N DFAL PROD1 11751', Orient to 1 05L TF, no problems with Tore tool. Resume drilling. 2.6 in, 2.6 out, 2850 psi CTP free spin, drilling at 3150 psi. Printed: 10/17/2001 1:18:51 PM ( ( BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 9/24/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/17/2001 08:45 - 09:25 0.67 DRILL P PROD1 11820', had hard drilling, sticky, and stalls. Possibly crossed fault. No losses encountered. Still drilling at 2.8 in, 2.8 out, 3100 psi CTP, 100 fph ROP, 105L TF. 09:25 - 09:50 0.42 DRILL N STUC PROD1 11875' Oriented while drilling. Got stuck after orienting sequence was completed. Difficult to see motor work with pressure pulses during orienting. Could not move up. Pulled 65klbs. Positioned pipe at neutral weight, and SI pumps for 20 mintues to wait for the miracle of flo pro mud. 09:50 - 10:10 0.33 DRILL P PROD1 Easily pulled free. Short trip up to shoe, no problems up or down. 10:10 - 13:30 3.33 DRILL P PROD1 11875', resume drilling. 2.7 in/out, 3080 psi CTP, 90l TF, 75 fph ROP. Drilling smooth, no problems with sticking 11875'. 13:30 - 14:00 0.50 DRILL P PROD1 12040', smooth drilling, no sticky spots. Wiper trip to shoe. 14:00 - 15:50 1.83 DRILL P PROD1 Resume drilling. 2.7 in/out, 100% returns. 75L tool face, 3375 psi CTP. 90 fph ROP. 15:50 - 16:30 0.67 DRILL P PROD1 12160', wiper trip to shoe. Orienter also not wanting to find a proper tool face. 16:30 - 19:30 3.00 DRILL P PROD1 Attempt to return to drilling. Need to get all of motor build to make turn. We may be too close to north bounding fault. Trip for bigger motor. Orienter worked fine on trip out of hole. Will also inspect orienter when at surface. 19:30 - 20:45 1.25 DRILL P PROD1 CHANGE MOTOR ABH SETTING TO 2.00. DOWNLOAD DATA, FUNCTION TEST TORC. (BIT OK, WITH ONE BACKREAMING BUTTON HALF CHIPPED). 20:45 - 21 :30 0.75 DRILL P PROD1 RIH TO 1,600', SHT - OKAY. 21:30 - 23:15 1.75 DRILL P PROD1 CaNT. RIH TO WINDOW. 23:15 - 00:00 0.75 DRILL P PROD1 GR COOR. LOG -1' COORECTION AT RA TAG. 9/18/2001 00:00 - 00:45 0.75 DRILL P PROD1 FIN GR DEPTH CORRECTION AT RA TAG (-1'). 00:45 - 01:15 0.50 DRILL P PROD1 CaNT. RIH, HOLE VERY STICKY AT 11,920'. 01:15-02:15 1.00 DRILL N DFAL PROD1 SEND COMMANDS TO TORC - NO RESPONSE. PUMPS OFF, REPEAT SEQUENCE, NO RESPONSE. 02:15 - 02:45 0.50 DRILL N DFAL PROD1 PULL UP INTO CASING. (PULLING TIGHT THRU 11,920'). 02:45 - 03:00 0.25 DRILL N DFAL PROD1 SEND COMMANDS TO TORC - NO RESPONSE. 03:00 - 04:30 1.50 DRILL N DFAL PROD1 CaNT. POOH. 04:30-07:15 2.75 DRILL N DFAL PROD1 LD BACKUP TORC ORIENTER, PU SPERRY MECH ORIENTER. 07:15-07:35 0.33 DRILL N DFAL PROD1 RIH with BHA #6, Lateral section BHA, with 2.0 deg motor, DS49 bit, and Sperry orienter. Note - SWS did basic troubleshooting on Tore orienter wile at location, and found a failure in the alternator section. This appears to be the same failure mode as the first tool run. 07:35 - 08:15 0.67 DRILL N DFAL PROD1 Shallow hole test of MWD and new orienter. All worked ok. 08:15-10:45 2.50 DRILL N DFAL PROD1 Continue to RIH. Hung up at XN nipple at 10954', and had to orient to high side to get through. (Note, we had to mill this out to 3.80" on window milling run 1). Ran to TD, tied into last tag of 12160'. Had to work down from 11900'. 10:45 - 11 :45 1.00 DRILL N DFAL PROD1 Wiper trip up through shaley area to 10900'. Cleaning up hole prior to begining drilling. 11:45 -15:15 3.50 DRILL P PROD1 DRILL AHEAD TO 12,270' THROUGH STICKY, SHAlEY SECTION. 15:15 - 16:15 1.00 DRILL P PROD1 WIPE TO WINDOW. 16:15 - 20:45 4.50 DRILL N FLUD PROD1 WAIT ON 9.1 PPG FLO-PRO ORIENT TF. 20:45 - 22:00 1.25 DRILL P PROD1 DISPLACE HOLE WITH NEW 9.1 PPG FLO-PRO, WHILE Printed: 10/17/2001 1:18:51 PM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 9/24/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/18/2001 20:45 - 22:00 1.25 DRILL P PROD1 DRILLING AHEAD. 22:00 - 23:15 1.25 DRILL P PROD1 WIPE TO 11, 530', WHILE DISPLACING HOLE WITH NEW FP. PULLED 15K OVER 3 TIMES, WHILE POOH. 23:15 - 00:00 0.75 DRILL P PROD1 RIH DISPLAING FP. STACKED OUT AT 12, 275'. RATTY HOLE CONDITIONS ALL THE WAY TO BTM. SLACK OFF WT= 11-12K, RIH RUNNINGWTVARIED BETWEEN 10-5K DOWN. ORIENTED 17R. 9/19/2001 00:00 - 00:45 0.75 DRILL P PROD1 ORIENTATE TOOL FACCE TO PROCEED TO DRILL AHEAD 00:45 - 04:36 3.85 DRILL P PROD1 DRILL AHEAD TO 12377'. 04:36 - 06:00 1.40 DRILL P PROD1 SHORT TRIP 877' 06:00 - 06:10 0.17 DRILL P PROD1 PJSM (CREW CHANGE). 06:10-10:15 4.08 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12,446'. 10:15 - 13:10 2.92 DRILL P PROD1 WIPER TRIP 1000' 13:10 - 16:00 2.83 DRILL P PROD1 DIRECTIONALLY DRILL TO 12,590' 16:00 - 17:30 1.50 DRILL P PROD1 WIPER TRIP 1140' 17:30 - 18:00 0.50 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12,600'. 18:00 -18:39 0.65 DRILL P PROD1 PJSM DISCUSS SATILLITE ACCUMULATION AREAS. 18:39 -19:05 0.43 DRILL P PROD1 DIFFICULTIES GETTING THE ORIENTATOR TO RESPOND. SUSPECT 2 DEGREE MOTOR AND DOGLEG COMBINATION REQUIRING TORQUE ABOVE ORIENTIER CAPABILITY. mOOVE UP AND DOWN HOLE FILALL Y SICESSFUL IN GETTING ORIENTATOR TO FUNCTION NEAD TD 19:05 - 21 :21 2.27 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12,623'. 21 :21 - 21 :47 0.43 DRILL P PROD1 ORIENTATE 21 :47 - 23:59 2.20 DRILL P PROD1 DIRECTIONALL Y DRILL TO END OF BUILD AT 12,700'. 9/20/2001 00:00 - 04:15 4.25 DRILL P PROD1 POH FOR MOTOR CHANGE TO 1.37 DEG MOTOR. HAD TO ORIENT TO PULL UP THRU WINDOW. 04:15 - 04:45 0.50 DRILL P PROD1 CHANGE OUT MOTOR AND ORIENTER. RERUN D849. MU BHA #7. STAB INJECTOR. 04:45 - 08:15 3.50 DRILL P PROD1 RIH WITH BHA #7. SHT MWD - OK. 08:15 - 08:45 0.50 DRILL P PROD1 LOG GR TIE IN. CORR'N -7'. 08:45 - 09:45 1.00 DRILL P PROD1 CONT RIH AND TAG BOTTOM - OK. HOLE LOOKED GOOD WITH NO REAMING REQUIRED. 09:45 - 12:55 3.17 DRILL P PROD1 ORIENT AND DRILL AHEAD IN ZN 1A. APPEAR TO BE IN GOOD SAND. CO NT DRILLING AHEAD. CROSS FAULT AT APPROX 12740' AND CO NT DRILLING AHEAD NOW IN ZN 1B. DRILL TO 12802' 12:55 - 14:15 1.33 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12,860 14:15 - 16:00 1.75 DRILL P PROD1 WIPER TRIP UP TO WINDOW - HOLE CONDITION GOOD. RIH TO BOTTOM. 16:00 - 16:25 0.42 DRILL P PROD1 ORIENTATE 16:25 - 18:00 1.58 DRILL P PROD1 DIRECTIONALL Y DRILL TO 12882. 18:00 - 20:19 2.32 DRILL N STUC PROD1 STUCK ON BOTTOM.SLACK OFF AND REDUCE PUMP RATE. NOGO. PULL 90K NO GO. WAIT ON CRUDE. PIPE PULLED FREE PRIOR TO SPOTTING CRUDE OIL AT 2019 HRS WITH 80K 20:19 - 23:59 3.67 DRILL P PROD1 CHANGE OUT MUD. 9/21/2001 00:00 - 00:20 0.33 DRILL P PROD1 CONTINUE DISPLACEMENT TO NEW FLO PRO WHILE RIH TO BOTTOM AFTER SHORT TRIP DURING DISPLACEMENT. 00:20 - 00:40 0.33 DRILL P PROD1 ORIENT. 00:40 - 02:40 2.00 DRILL P PROD1 DRILL AHEAD WHILE ADDING 1.5% FLO-LUBE TO SYSTEM (' (' Printed: 10/17/2001 1:18:51 PM BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: 1 5-36 Common Well Name: 1 5-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 9/24/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/21/2001 00:40 - 02:40 2.00 DRILL P PROD1 FOR ADDITIONAL LUBRICITY. SAW IMPROVED WEIGHT TRANSFER AFTER ADDITION. SURFACE STRING WEIGHT INCREASED FROM 4000 TO 7000#. CONT DRILLING TO 12965'. 02:40 - 03:40 1.00 DRILL P PROD1 DRILL AHEAD TO 13036'. 70-105 R. 2.4/2.4 BPM. STARTING TO STACK WEIGHT. 03:40 - 05:30 1.83 DRILL P PROD1 WIPER TRIP TO WINDOW. LOOKED GOOD COMING OUT AND BACK IN TO 12210'. UNABLE TO WORK PAST THIS DEPTH. NO FURTHER PROGRESS. 05:30 - 07:30 2.00 DRILL N DPRB PROD1 ATTEMPT TO WORK THRU TIGHT SPOT - PUMP ON, PUMP OFF BUT WITHOUT REAMING. LITTLE OR NO PROGRESS. PICK UP CLEAN AS IF NOT SWELLING SHALE BUT OBSTRUCTION. HOLE COLLAPSE?? 07:30 - 07:45 0.25 DRILL N DPRB PROD1 DISCUSS WITH ANCH TEAM. AGREE TO TRY FURTHER ATTEMPTS TO WORK THRU BAD SPOT BEFORE REAMING. 07:45 - 09:35 1.83 DRILL N DPRB PROD1 CONT ATTEMPTS TO WORK THRU BAD SPOT WITHOUT REAMING ORIENTED SAME WAY AS DRILLED. LITTLE PROGRESS AND NOTHING FURTHER BELOW 12222'. STILL PU CLEAN AS IF OBSTRUCTION NOT SWELLING. 09:35 - 11 :55 2.33 DRILL N DPRB PROD1 REAM DOWN TO 12275' WITHOUT BREAKING THRU IN TO CLEAN HOLE. SURVEYS CONFIRM WELL IS SIDETRACKED. 11:55 -12:30 0.58 DRILL N DPRB PROD1 TIE IN +24 CORRECTION 12:30 -16:00 3.50 DRILL N DPRB PROD1 POH FOR CEMENTING NOZZLE FOR SPOTTING KICK OFF PLUG. 16:00 -18:45 2.75 DRILL N DPRB PROD1 INSTALL DART AND PUMP DART 53.7 BBL DISPLACEMENT WITH DART. 18:45 -19:08 0.38 DRILL N DPRB PROD1 MU CEMENTING ASSEMBLY 3.1 BULL NOSE AND 2 JOINTS PAC TUBING 19:08 - 21 :45 2.62 DRILL N DPRB PROD1 RIH TO 10947 NO GO. CAN'T GET THROUGH THE MILLED XN NIPPLE. MADE NUMEROUS ATTEMPTS VARYING PUMP RATES, RUNNING SPEED, STACKING WEIGHT,SIT DOWN WITH PUMPS OFF AND THEN STARTING PUMPING. ALL WITH NO POSITIVE RESULTS. 21 :45 - 23:30 1.75 DRILL N DFAL PROD1 POH 23:30 - 00:00 0.50 DRILL N DFAL PROD1 CHANGE OUT BULL NOSE FOR TAPERED NOZZLE. BULL NOSE DIDN'T HAVE A SERIES OF MARKS AS EXPECTED MAYBE ONE NEW FILE LIKE WICKER. 9/22/2001 00:00 - 02:00 2.00 DRILL N DFAL PROD1 RIH WITH 3" OD TAPERED NOZZLE. TAG UP AGAIN AT SAME PLACE AS PREVIOUS RUN -10948'. 02:00 - 04:15 2.25 DRILL N DFAL PROD1 POH WITH NOZZLE. 04: 15 - 04:45 0.50 DRILL N DFAL PROD1 BREAK INJ OFF BHA. LD NOZZLE & INSPECT SAME. ONE MARK ON BULLNOSE END NEAR CENTRE OF NOZZLE. 04:45 - 05:00 0.25 BOPSUF P PROD1 RU FOR WEEKLY BOP TEST. 05:00 - 15:30 10.50 BOPSUF P PROD1 TEST BOP 15:30 -18:00 2.50 BOPSUF P PROD1 PULL TWC WITH LUBRICATOR 18:00 -19:15 1.25 BOPSUF P PROD1 PJSM CREW CHANGE 19:15 - 21:30 2.25 EVAL N DFAL PROD1 RU SLICK LINE AND RUN 2.7 IMPRESSION BLOCK AND 2.7 DRIFT. NO GO PAST 10,936 WLM. POH TWO SIGNIFICANT MARK ON BLOCK BUT NOT CONCLUSIVE. SOME OF THE MARKS ARE STRAIGHT LE. SUGGESTING JUNK. 21 :30 - 23:59 2.48 EVAL N DFAL PROD1 RUN CCUGR MEMORY LOG TO 10936 TO LOG JEWELRY ( (" Printed: 10/17/2001 1:18:51 PM . . BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: 1 5-36 Common Well Name: 1 5-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 9/14/2001 End: Contractor Name: NABORS Rig Release: 9/24/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/23/2001 00:00 - 01 :30 1.50 DRILL N DFAL PROD1 POH WITH MEMORY CCUGR. 01 :30 - 03:00 1.50 DRILL N DFAL PROD1 RIH AGAIN WITH LOG WITHOUT 2.7" DRIFT TO LOG DEEPER TO 10950'. 03:00 - 05:30 2.50 DRILL N DFAL PROD1 ACQUIRE MEMORY LOG DATA ACROSS TAILPIPE AND PACKER. POH TO SURFACE. 05:30 - 06:00 0.50 DRILL P PROD1 CREW CHANGE AND SAFETY MEETING WHILE WOO. 06:00-08:15 2.25 DRILL N DFAL PROD1 DISCUSS WITH NS PE'S & ANCH. LOG INDICATES TAILPIPE IN PLACE AT LEAST ABOVE XN NIPPLE AND MARKS FROM IMPRESSION BLOCK RUN NOT INDICATIVE OF PARTED T/PIPE. RD SLlCKLINE. AGREE PLAN FORWARD TO RUN DIAMOND MILL ON STRAIGHT MOTOR. 08:15 - 09:30 1.25 DRILL N DFAL PROD1 CUT 100' OF COIL & INSTALL CONNECTOR. 09:30 - 11 :00 1.50 DRILL N DFAL PROD1 PULL TEST & PRESSURE TEST CONNECTOR. MU 3.8" OD DIAMOND SPEED MILL ON STRAIGHT MOTOR & 2 JTS 2 3/8" PH6 TBG, MHA. 11 :00 - 13:00 2.00 DRILL N DFAL PROD1 RIH WITH 3.80" MILL. WT CHK AT 10900' - 39KLBS. 13:00 -13:15 0.25 DRILL N DFAL PROD1 CONT RIH AND TAG UP WO CIRC AT 10943'. PU & BREAK CIRC. RUN IN CIRC AT 2 BPM - SAW NO RESISTANCE OR MOTOR WORK DOWN TO TUBING TAIL AT 10954', 13:15 - 13:30 0.25 DRILL N DFAL PROD1 PUH ABOVE PROD PACKER TO 10880'. RUN IN WO PUMP AND TAKE WEIGHT AT 10945'. KICK PUMP IN AND GO THRU EASILY. 13:30 - 16:45 3.25 DRILL N DFAL PROD1 WORK MILL THRU XN NIPPLE MULTIPLE TIMES REAMING TO CLEAN UP SAME. MAKE SUCCESSFUL DRY PASSES THEN MILL WOULD NOT PASS DRY. CIRC AND "ROLL" MILL INTO XN NIPPLE. 16:45 - 17:00 0.25 DRILL N DFAL PROD1 RIH TO WINDOW AT 11430'. 17:00 - 17:15 0.25 DRILL N DFAL PROD1 PASS THRU WINDOW. FIRST ATTEMPT WAS GRABBY BUT CLEANED UP ON SUBSEQUENT ATTEMPTS - PUMP ON. THIS DID NOT ACT LIKE JUNK. MAKE DRY PASS - OK. WENT DOWN TO 11435'. 17:15 - 17:30 0.25 DRILL N DFAL PROD1 POH ABOVE PACKER TO 10850'. RUN IN DRY & TAG UP ON XN NIPPLE?? AT 10942'. PUH AND BREAK CIRC. 17:30 - 18:00 0.50 DRILL N DFAL PROD1 RIH AND TAG UP 2.5/2.5 BPM 2850 PSI. ATTEMPT TO MILL & BREAK THRU BAD SPOT - NO SUCCESS. PUH & DISCUSS WITH ANCH DE. AGREE THAT SHOULD CEASE OPERATIONS AT THIS POINT IN FAVOUR OF FURTHER INVESTIGATION OF WELL CONDITIONS BY NS PE'S. 18:00 -18:45 0.75 DRILL N DFAL PROD1 CIRC IN KCL AND DISPLACE FLO PRO FROM HOLE. POH TO 2000' CHASING FLO PRO OUT. 18:45 - 21 :00 2.25 DRILL N DFAL PROD1 CIRC OUT REMAINING FLO PRO UNTIL HOLE CLEAN. FREEZE PROTECT TUBING WITH MEOH. 21 :00 - 22:00 1.00 DRILL N DFAL PROD1 POH TO SURFACE. 22:00 - 23:00 1.00 DRILL N DFAL PROD1 LD BHA. CLEAN PITS. 23:00 - 23:30 0.50 DRILL N DFAL PROD1 INSTALL BPV 23:30 - 00:00 0.50 DRILL N DFAL PROD1 START RIGGING DOWN FOR MOVE TO P-15A. 9/24/2001 00:00 - 04:00 4.00 DRILL P PROD1 NIPPLE DOWN BOP. NIPPLE UP BLANK FLANGE AN D TEST TO 3500 PSI O.K. RELEASE RIG. (' ( Printed: 10/17/2001 1:16:51 PM . . Well: Field: API: Permit: ( ( 15-36A (Ops Shutdown) Prudhoe Bay Unit 50-029- 22480-01 201-162 Rig Accept: Rig Spud: Rig Release: DriliingB!g: "'--""""""""'-"'.-.........-.---...--.-...--...._..-.. "-'.""""""""-'-'-'-"-""'" -. """"'--'-"""'-'-"""--'-"""""""-"'-"--'"""-.-..-.......-'-" '. -""""""'-'-"""""".'-'- -'-.." . "-' . 09/14/01 09/16/01 09/24/01 Nabors 3S -"'."" "-"'--. 09/30/01 Ran video of tubing tail. Tubing has backed off below XN nipple and dropped two to three feet, setting on top of 5-1/2" liner. POST INITIAL RIG WORK - Operations Shutdown bp "',iii'" ,~.' ,. ~." "", ~ (' ( Date: 10-12-2001 Transmittal Number:92283 B PXA WELL D AT A TRANS MITT AL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Date 09-22-2001 10-01-2001 09-24-2001 Media ¡tie HARDCOPY/DISKETTE SURVEY REPORT; HARDCOPY/DISKETTE SURVEY REPORT; HARDCOPY/DISKETTE SURVEY REPORT; ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center AOGCC Attn: Lisa Weepie Phillips Alaska Inc. Attn: Sandy Lemke RECE IVED OCT 1 5 2001 Exxon Mobil Production Co. Attn: Susan Nisbet Alaska Oil & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~, Re: OS 15-36a Resume Operations PTO 201-162 ( It Subject: Re: DS 15-36a Resume Operations PTD 201-162 Date: Tue, 13 Nov 2001 09:50:06 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Stagg, Ted 0 (ORBISr <StaggTO@BP.com> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Ted, I believe the requirement on the 403 was to provide email notice of the plan to resume operations. This notice will suffice. Resumption of operations will be in accord with the requirements of the originally issued permit to drill (201-162). Good luck. Tom Maunder, PE Sr. Petroleum Engineer AOGCC "Stagg, Ted 0 (ORB IS)" wrote: > Operations on CTD sidetrack DS 15-36a were shut down on Sept. 24, 2001 due > to problems involved with a parted 4 ~"tailpipe. This was reported on a > 10-403 and was assigned approval No. 301-278. > > The tailpipe problem has been evaluated by impression blocks and by a video > camera. Results indicate that the tailpipe parted at the top of the XN > nipple and fell about 2 ft to rest in the tie-back receptacle of the 5 ~" > liner. > > Resumption of operations are planned as follows: > Service coil will enter the well with a mill and straight motor and attempt > to work into the parted tailpipe. If successful, 15.8 ppg cement will be > placed from approx. 100 ft below the window to the top of the parted > tailpipe. The purpose of the cement is to stabilize the tailpipe and to > provide a kick off plug for further drilling. If service coil cannot > re-enter the tailpipe, cement will be bullheaded to achieve tailpipe > stabilization. > > Drilling coil will follow service coil on the well. Drilling coil will use > a tapered mill and a bent motor / MWD assembly to mill through the 4 ~" > tailpipe and mill cement to a new kick off point below the window. If > needed, a second cement plug will be placed across the window to provide for > kicking off a new sidetrack. > > The well target and directional plan remain essentially the same as > submitted with the original Permit to Drill application. Service coil > operations are expected to resume in early December and drilling coil > operations will resume late December or early January, 2002. > > Please advise if further info is needed for approval to re-enter and > continue this sidetracking operation. > > Ted Stagg > CT Drilling Engineer > Tel: 564-4694 > Fax: 564-5510 > Cell: 240-8074 1of2 11/13/019:51 AM Re: OS 15-36a Resume Operations PTO 201-162 ( > staggto@bp.com I. Tom Maunder <tom maunder@admin.state.ak.us>111 I Sr. Petroleum Engineer I i Alaska Oil and Gas Conservation com_mi~~o~_____i 2 of2 ,1. It 11/13/01 9:51 AM ii' :\ , \ " , ( STATE OF ALASKA I' ALASKA OIL AND GAS CONSERVATION COMMI&..."ON APPLICATION FOR SUNDRY APPROVAL d1i\!iJul, i-ro, (OJ'OTJ /J -ll ) ulo z.le ( 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging 0 Time Extension 0 Perforate 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other 0 Change Approved Program IBI Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1440' SNL, 887' EWL, SEC. 22, T11 N, R14E, UM At top of productive interval 827' SNL, 3838' EWL, SEC. 15, T11N, R14E, UM At effective depth At total depth 349' SNL, 2572' EWL, SEC. 15, T11 N, R14E, UM (As Planned) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13036 feet 8702 feet 11430 feet 8610 feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 80' 20" 3872' 10-3/4" 11086' 7-5/8" 848' 5-1/2" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 5. Type of well: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) KBE = 65.75' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 15-36A 9. Permit Number 201-162 10. API Number 50- 029-22480-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Plugs (measured) Set Whipstock at 11430' (08/01) Junk (measured) Cemented MD TVD 260 sx Arcticset (Approx.) 110' 110' 1105 sx PF 'E', 375 sx Class 'G' 3907' 3565' 617 sx Class 'G' 11119' 8333' 126 sx Class 'G' 10965' - 11428' 8197'- 8615' f' [" P .1\) I' ,~) C, "(~;;) 2 0 0 1 4-1/2", 12.6#, L-80, Tubing at 10966' ,l\las!~a Oill~, Gas Con;:;, Packers and SSSV (type and measured depth) Baker SABL-3 Packer at 10904'; 4-1/2" SVLN at 2228'. Name of approver Contact Engineer Name/Number: Ted Stagg, 564-4694 17. I hereby certify that the foreg in is true and correct to the best of my knowledge Signed Ted Stagg Title CT Drilling Engineer 13. Attachments 181 Description Summary of Proposal 14. Estimated date for commencing operation September 23,2001 16. If proposal was verbally approved Date Approved 0 Detailed Operations Program 15. Status of well classifications as: 181 Oil 0 Gas 0 Suspended 0 BOP Sketch Service Prepared By Name/Number: Terrie Hubble, 564-4628 "':::'::'::¡:::':' '!\::~',,)::':':":"."!}',;',::;::¡:!;:.:,:::(\¡~,:l"¡:':".,':j':::;:~jl:j:..::!::!::;r!::::::::;¡',:,;:!:,;::;:::':çf~m~iìi~~¡ij:;:~~!:i@r.";',::'::3::r:::;',.~:::!;:i.,,::;:~:'::,::,'::?::,:,':,i::'::';,'.::,:.::;) :::':;::~:::::: :::..,:.::-":::.' Approval No. ~ - ~ 7 g Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test- 0 . ~uQs.e~ent.fg[m. required 10-~ «:.~\\"\e\-'\~ o"'rtS;.~'\~\a"" ngmal ~Ignea ay A roved b order of the Commission . Commissioner Date t1. V Form 10-403 Rev. 06/15/88 Submit I T ¡plicate """ ,::' c'," ,',c "":, ,'" , (' ( .i " Hubble, Terrie L From: Sent: To: Cc: Subject: Stagg, Ted 0 (ORBIS) Monday, September 24, 2001 10:51 AM Tom Maunder (E-mail) Hubble, Terrie L DS 15-36a Ops Shutdown Nabors 3S shut down operations on DS 15-36a at 6:00pm yesterday, Sept. 23, 2001. Our intent is to work out a plan forward and return to the well to complete the sidetrack within 60 days. 15-36a was drilled to a depth of 13,036' when the well was inadvertantly sidetracked at approx. 12,210' while ream ing shale. A cementing nozzle was picked up with the intention of plugging back with cement and re-drilling the original plan. However, the cement nozzle could not be run past the 4 1/2" XN nipple in the tubing tailpipe. An impression block and Gamma Ray/GGL log were run on slick line to investigate the problem. Both the LIB and the collar log stopped at the depth of the XN nipple. It appears that the 4 1/2" tailpipe has backed off at the XN nipple and is sitting on top of the 5 1/2" liner. A motor and mill were run and found that with rotation the mill could be worked into and through the "loose" tailpipe. However, the mill could not be run through the loose tailpipe without using the motor. 15-36a was displaced to 2%KCL, freeze protected and a BPV set. The AOGGC field inspector was notified on Sept. 23 as soon as the decision was made to shut down operations. Nabors 3S has rigged down and is moving to P Pad. A Sundry Notice will be prepared and filed today. Ted Stagg 564-4694 1 ( ( ~1r~1fŒ lID~ ~~~~[K\~ ALAS KA 0 IL AlVD GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 15-36A BP Exploration (Alaska) Inc. Permit No: 201-162 Sur Loc: 1440' SNL, 887' EWL, SEC. 22,T11N, RI4E, UM Btmhole Loc. 349' SNL, 2572' EWL, SEC. 15, TI1N, R14E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 15-36A. I 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, ~LL£ .11, ~¿¿/)X ~ Julie M. Heusser Commissioner BY ORDER OF THE WMMISSION DA TED this § -.:.--- day of August, 2001 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 , ' 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1440' SNL, 887' EWL, SEC. 22, T11 N, R14E, UM At top of productive interval 827' SNL, 3838' EWL, SEC. 15, T11N, R14E, UM At total depth 349' SNL, 2572' EWL, SEC. 15, T11 N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028303, 349' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8556' MD Maximum Hole Angle 18. casi4nrz~rogram Specifications Hole Lð~IIIU t"" _I CouDlina Lenath 3-3/411 3-3116' x 2-7/8' 6.4# / 6.2# TCII / L-80 ST-L 2966' 1 b. Type of well 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 11813 feet 8975 feet 11659 feet 8830 feet Length Size 80' 2011 3872' 11086' 848' 10-3/411 7-5/811 5-1/211 Perforation depth: measured Open: 11630' - 11660' Open: 8803' - 8831' true vertical 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 65.75' Prudhoe Bay Field / Prudhoe 6. Property Designation ~IC/ Bay Pool ADL Q2iae:¡ ~/ ~ 7: ..... 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Prudhoe Bay Unit 8. Well Number 15-36A 9. Approximate spud date 08/20/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13386' MD / 8720' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 90 Maximum surface 2440 psig, At total depth (TVD) 8800' / 3320 psig Setting Depth T41D - MD TVD Mn 10920' 8092' 13386' Number 2S 100302630-277 OLlðl ¡tit" of l t TVD linclwlø staae data) 8720' Mßx Class 'G' .. - )~....(' I-< t- ( ~ ~ I \/ t- IJ / £)Qf)¡ )r- I - I."'" 1.>- JUl is 1 IUUl Plugs (measured) Alaska Oil & Gas Cons. Commission Anchorage Junk (measured) Fish at 11808' MD (11/14/97) See attached diagram Cemented MD TVD 260 sx Arcticset (Approx.) 110' 110' 1105 sx PF 'E', 375 sx Class 'G' 617 sx Class 'G' 126 sx Class 'G' 3907' 11119' 10965' - 11813' 3565' 8333' 8197'- 8915' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is tru~nd correct to the best of my knowledge / Signed Mark JOhnson~... 1- a W-A"'-' Title CT Drilling Engineer Date 7 /~I /0/ : :' ",,' ,: :,i' : ,,:,:;< i,: >:':\'::,:,::,: :,:¡':¡¡;2<:jY'):':<:; ::::'¡:, ii:i",:,:'::,"Ø~'q,rn,i¡_.iq,i~.e",O'~I¥';;':::,:::: ':::",;:':,:,:"/'::::>:::'""",: ::::,,':0'. ",::"..,:::: ",::,:: ,:";,,:' Permit Number API NÖfnber Al?QrÇ>val Date See cover letter 2.0/- '7hZ 50- 029-22480-01 X I i/6 I for other reauirements Conditions of Approval: Samples Required 0 Yes BI No Mud Log Reqùired 0 Yes E No Hydrogen Sulfide Measures 0 Yes E No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: 20. Attachments by order of the commission Approved By Form 10-401 Rev. 12-01-85 ORIGI~ SIGNED ~y. Commissioner U~t-{TlJ , '\J 1-\ L Date?? J9)n ) Suomit In Triplicate ( ( BP 15-36a Sidetrack SummarY of ODerations: A GTO sidetrack of OS 15-36 is scheduled for rig N3S. This sidetrack will involve shutting off the existing Zone 1 perfs and drilling to a new Zone 1 target. This sidetrack will be done in two phases. Phase 1: Confirm mechanical integrity, set whipstock, squeeze existing perfs. Planned for August 13, 2001 . An MIT on the IA will be performed. . Tubing and liner will be drifted and logged with a Kinley caliper. . The wellhead and tree valves will be tested. . E-line will set a mechanical whipstock at approx. 11,435' (8556's). . Service coil will pump approx. 20 bbls cement past the whipstock to shut off existing perfs. Phase 2: Mill window, Drill and Complete CTD sidetrack: Planned for August 20,2001 . 23/8" drilling coil and 2% KGI will be used to mill a 3.8" window. . 3.75" hole will be drilled with 8.6 ppg Flo-Pro to approx. 13,386'MO (8720'ss) with a BHL of 678,347; 5,966,470. . 33/16" x 27/8" liner will be cemented from TO to approx. 10,920' MO (8092'ss). . Approx. 1000 ft of perforations are anticipated. . Mud Program: . Phase 1: 2% KGI . Phase 2: 2% KGI and Flo-Pro (8.6 ppg) Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 33/16" TCII x 2 7/8" ST-L, L-80, solid liner will be cemented from TO to approx. 10,920' MO (8092' 55). This liner will be cemented with approx. ~s of 15.8ppg class G cement. dd-'o't)\<:> ~~,'t-\a~ &o( ç.. Well Control: lfi~ . BOP diagram is attached. v ." , . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2200 psi. Directional . See attached directional plan . Magnetic and inclination surveys will be taken every 30 f1. No gyro will be run. Logging . An MWO Gamma Ray log will be run over the open hole section. . A memory CNL log will be run inside the cemented liner. Hazards The maximum H2S measured in produced fluids from OS 15 wells is less than 50 ppm. Possible lost circulation at the fault crossing is the primary drilling hazard. Reservoir Pressure Res. pressure is estimated to be 3320 psi at 8800'ss. Maximum surface pressure with gas (0.10 psi/ft) to surface is 2440 psi. ( TREE = ---_? WELLHEAD= CrN ACTUATOR-- BAKER C KB. ELEV = 66' BF. ELEV = KOP= 1721' Max Angle = 53 @ 6263' Datum MD = 11701' Datum 1VD= 8800' SS 110-3/4" CSG, 45.5#, L-80, ID = 9.953" I 3907' Minimum ID = 3.725" @ 10954' 4-1/2" HES NOGO NIPPLE ¡TOP OF 5-1/2" LNR I 10965' 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I 10966' 17-5/8" CSG, 29.7#, NT-95 HS, ID = 6.875" I 11119' PERFORA TION SUMMARY REF LOG: BHCA-GR on 6/5/94 ANGLEATTOPÆRF: 20 @ 11608' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 0 11608 - 11612 C 08/04/95 3-3/8" 6 11630 - 11660 0 07/31/94 3-3/8" 6 11632 - 11646 0 03/23/98 1 PBTD I 15-1/2" LNR, 17#, NT-80, 0.0232 bpf, ID = 4.892" I 11730' 11813' 15-36 (I) 2228' (' SAFETY NOTES: 3636 psi (ZERO SAFETY FACTOR) PA TCHFLEX COLLAPSE RATING 1-14-1/2" CAMCO SVLN SSSV NIP, ID = 3.81" I GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH SIZE DATE 1 3542 3315 44 SPM 1" BK 2 6961 5498 51 SPM 1" BK 3 9502 7104 48 SPM 1" BK 4 10814 8066 32 SPM 1" BK 10841' 10904' 10937' 1 0954' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/09/94 ORIGINAL COMPLETION 12/18/00 SIS-isl CONVERTED TO CANVAS 03/01/01 SIS-MD FINAL 06/27/01 RN/tlh CORRECTIONS 10966' 10957' 11603' 11808' -14-1/2" HES X NIPPLE, ID = 3.81" I -f7" X 4-1/2" BAKER SABL-3 PACKER, 10 = 3.880" I --14-1/2" HES X NIPPLE, ID = 3.810" I -14-1/2" HES XN NIPPLE, ID = 3.725" I 4-1/2" TBG TAIL WLEG, ID = 3.960" ELMD TT - LOGGED 07/24/95 -15-1/2" DRILLFLEX PATCH - SET 01/05/98 I FISH - (2) PINS 1-1/4"X1/2" & (4) ROLLERS 1 "X1/4" (LOST 11/14/97) PRUDHOE BA Y UNIT WELL: 15-36 ÆRMfT No: 94-072 API No: 50-029-22480-00 Sec. 22 T11 N R14E 1344.1 FEL 592.77 FNL BP Exploration (Alaska) _? BAK~I 66' ( (' I =~D= ACTUATOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD= 1721' 53 @ 6263' 11701' 8800' SS 10-3/4" CSG, 45.5#. L-80. ID = 9.953" 3907' Minimum ID = 3.725" @ 10954' 4-1/2" HES NOGO NIPPLE Top 3 3/16" approx. 10,920' ¡TOP OF 5-1/2"LNR I 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1 17-5/8" CSG, 29.7#, NT-95 HS, 10 = 6.875" I Top Whip approx. 11 ,435' ÆRFORA TION SUMMARY REF LOG: BHCA-GR on 6/5/94 ANGLE AT TOP ÆRF: 20 @ 11608' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 3-3/8" 0 11608 -11612 C 08/04/95 3-3/8" 6 11630 - 11660 0 07/31/94 3-3/8" 6 11632 - 11646 0 03/23/98 Cement downsqueezed past whipstock 1 A31D I 15-1/2" LNR, 17#, NT-80, 0.0232 bpf, ID = 4.892" I 15-36a Proposed Completion 8 10965' 10966' 11119' 2228' ST MD lVD 1 3542 3315 2 6961 5498 3 9502 7104 4 10814 8066 SAFElY NOTES: 3636 psi (ZERO SAFElY FACTOR) PA TCHFlEX COLLAPSE RA riNG 4-1/2" CAMCO SVLN SSSV NP.1D = 3.81" GAS LIFT MANDRELS DE\! TYÆ VLV LATCH SIZE 44 SPM 1" BK 51 SPM 1" BK 48 SPM 1" BK 32 SPM 1" BK DATE 10841' -l4-1/2" HES x NiPPlE. ID = 3.81" 1 10904' -i7" x 4-1/2" BAKER SABL-3 PACKER, ID = 3.880" 10966' 10957' 10937' -l4-1/2" HES x NiPPlE. ID = 3.810" I 10954' -l4-1/2" HES XN NiPPlE. ID = 3.725" I 4-1/2" TBG TAIL WLEG, ID = 3.960" ELMD TT - LOGGED 07/24/95 ',: ,'n:;b:::1ili::1 3 3/16" x 2 7/8" cemented liner "'{~:jj;~¡!(IÎ'I;'~ /.. .. "\\I:!8!i~;,^ , :. ' ',":: """ ", ," ' 11730' 11813' . ' , ' . ',' ,.", ':.""':' :' , 11603' -l5-1/2" DRILLFlEX PATCH- 5ET01/05/98 I 11808' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/09/94 ORIGINA L COMPlETlON 12/18/00 SIS-isl CONVERTED TO CAtoN AS 03/01/01 SIS-MD FINAL 06/27/01 RNItih CORRECTIONS FISH - (2) PINS 1-1/4"X1/2" & (4) ROLLERS 1 "X1/4" (LOST 11/14/97) PRUDHOE BAY UNIT WELL: 15-36 PERMIT No: 94-072 API No: 50-029-22480-00 Sec. 22 T11N R14E 1344.1 FEl592.77 FNL BP Exploration (Alaska) rei M5 Vertical Section ,-.., .... ( ( !t-8600 CI ¡::: 8650 8700 8750 8800 0 8400 500 1,000 8450 8500 8550 Angle @ K.O.= 22 deg MD:11435 15-36 1,500 Path Distance (Feet) 2,000 2,500 3,000 15-36a case 1 01 Ted x4694 TotOrld:1951ft 13386 TO Marker Depths @Orig Wellbore 8,7001 a,700~t TVD 3,500 I a,S491ft TVO I a,490ft TVO 25P TZ2C 8,7201 a,720ft TVO Kick Off Oeprtr @KO I I MO KO Pt MO New Hole 11,435 1951 Total MD TVDTD 1 3,386 8,720 DLS deg/l00 Tool Face Curve 6 1,951 u 0 -I ~ E 0 '- 0<- m u c: «! .... <I) 'õ >- 0 1,000 1 5-36 15-36a Case 1 01 July 19, 2001 Ted x4694 1,500 2,000 X distance from Sfc Loc 2,500 3,000 7,500 7,000 6,500 6,000 5,500 3,500 IWel1 Name 15-36 I CLOSURE I Distance 6,586 ft I Az 13deg NEW HOLE E/W (X) N/S (Y) Kick Off 2,842 TO 1 6,408 State Plane 678,347 5,966,470 Surface Loc 676,825 5,960,062 Length 20 221 1,951 Drawn: 7/27/2001 10:12 Case 122 Plan Name: ( ,. ( 35 CTD BO P Detail Methanol Injection Otis 7" WLA Quick Connect ---- 7-1/16" 10,5000 psi working pressure Ram Type Dual Gate BOPE ~ Manual over Hydraulic ~ Flanged Fire Resistant Kelly Hose to Dual Choke Manifold - HCR [l@ 7-1/16" 10, 5000 psi working pressure Ram Type Dual Gate BOPF::::::l ~ Manual over Hydraulic XO Spool as necessary Single Manual Master Valve (optional depending on RU) MOJ 5/21/01 -- CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ - 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure 2 3/8" Pipe/Slip I Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on OS Hardline to Standpipe manifold Z' Side outlets @ I 3 1/2" Combi Pipe/Slip I I 23/8" x 3 1/2" VBR seal rams I 2 flanged gate valves ~ 7" Annulus 9 5/8" Annulus 15-36A liner cement volumes ( Subject: 15-36A liner cement volumes Date: Man, 6 Aug 2001 14:09:13 -0500 From: IIJohnson, Mark 0" <JohnsoMO@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> Tom, you are correct on needing more cement to target liner TOC at 10920'. The permit should read 22 Bbl instead of 18 Bbl in the casing program section. Will this e-mail suffice as a correction? Thx MOJ (j.JV'-~ \ ~ ~ ~ ~\: Ù Cc " ~ 1 of 1 ( 8/6/01 12:12 PM ( f If , ., ., J DATE 07/06iOl CHECK NO. 00193326 H 193326 DATE GROSS VENDOR DISCOUNT INVOICE I CREDIT MEMO DESCRIPTI.9N NET 070201 CKO70201M PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Pe~ it t~ Drill ee S/H - Terrie 'Hub l~ X4628 or Sandra Ste man X4750 \CS~ ~ A HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. p.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL 'BANK OF ASHLAND AN 'AFFILIATECIF NATIONAL CITY BANK CLEVELAND. OHIO No.H 193326 , CONSOLIDATED COMMERciAL ACCOUNT 56..389 4i2 00193326 """, To The ORDER Of , , ' . ..,' .." ,', , .. ' " ,..", 'ALASKA otL AND ~ÅS , C(J~SERV4TIOtsl:~OM~IS~1(JttJ 3'3~",:,)W" EST"',,, ", 7"", " L:.I ,""",VEkl,',' ,U' E ,',": ..::J,"', , /J"" 1'",r:' M 1,'1 SUITE 190 ,\, ," , ," ANCHORA@E ,,> ..' dNEHUNDRED & OO/100~**~,************~**~*,*~**~**********if- u~ D~LLAR DATE:, ' AMOUNT Ô~IÓ~/O1 :, ::I::.'."'i""",.,,:' ,.,$,:,',:,',.,:,',~oo",',:","":,,:-,,:,',.,,',,,,',:,,(),,(?j,.',"~I:::' ',," "":""':':":':"",','" ,.. NQ"PVALlQ'~FTER1~O,DAYS ":'"""" l: ~r~ ìP~~ ~ PAY All+. 99561 III ~ Ii ~ ~ 2 ¡; III I: 0'" ~ 2 0 ~ a Ii 5 I: 0 0 a ~ ~ ~ ~ III ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~¿: bt CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTILATERAL (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILLV PILOT HOLE (PH) EXPLORATION ANNUL~. ~p. OSAL NO INJECTION WELL ANNULAR DISPOSAL L.J YES INJECTION WELL REDRILL ANNULAR DISPOSAL THIS WELL /5-<64 - "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(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will ~ot be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L.J YES + SPACING 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. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. .. F. WELL PERMIT CHECKLIST COMPANY /f~)/ WELL NAME /S.. ~ FIELD & POOL b'76/..~~ INIT CLASS ,.¿>c~ / -d./ / ADMINISTRATION 1. Pennitfee 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 wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Pennit can be issued without conservation order. . . . . . . . 12. Pennit 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 totia-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~I. DATE, 26. BOPE press rating appropriate; test to 3500 psig. ~ ~f~ --0 , . 27. Choke manifold complies w/API 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. . . . . . . . . . . . . AJjÎ~ Ç>J'.TF . 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Zfl..I&L 34. Contact name/phone for weekly progress reports [exploratory onl 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 formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOL Y: ENGINEERING:' UIC/Annular COMMISSION: ~þ ~ t"\- W~ ~ '8M~sl1<~A;'}/}j/' ~6-t'-é) J H . ~R~T r~ D . ENGINEERING GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) PROGRAM: exp - dev L redrtl G~L AREA 8-1 Ò I Y N Y N Y N Y N Y N Y N Y N. Y N Y N Y N Y N Y N ~ N ~ ~ 1...\~~"'<-~ ~,,~ "'\ "->~\., Y N Y N 'N N t.'f-\~~\:u-~ ~/,,~ ~~~~~",\ N .~Ö\- "t>";)~ l~-c\ . N 'x N ~~ N ' ~ \-\.~~ ~ ~~~, ~~d Ct ;2\..\~a ~~, ~ SCJa,,"'> ~~~~~ N . N, r-. . , y ~ ~t) ~\Ð~~ ~~L\~Û fè- ~~'> ~ ~~~ \:~ ~~,\~,\>~.~, <>~t(!1\ß~~ Y N Y serv wellbore seg _ann. disposal para req - // ~ (' rJ ON/OFF SHORE UNIT# c 0 Z 0 -f :E :::u ( - -t' m -' Z -I ,X - en )- :::u m > ( N ~/v/) N ' Y N "./ Y N Y N Comments/Instructions: