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201-214
RECEIVED STATE OF ALASKA • DEC 0 6 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOGpO" C L.rCC C la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class 20AAC 25.105 20AAC 25.110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ® Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/17/2012 - 201 - 214 312 - 400 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 11/23/2001 , 50 029 - 22793 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/13/2001 PBU W -02A 1192' FNL, 1190' FEL, Sec. 21, T11N, R12E, UM 8. KB (ft above MSL): 81.55' 15. Field / Pool(s) Top of Productive Horizon: 5240' FNL, 4279' FEL, Sec. 21, T11N, R12E, UM GL (ft above MSL): 53.05' Prudhoe Bay / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD) 3551' FNL, 1896' FEL, Sec. 20, T11N, R12E, UM 10890' 8863' 4b. Location of Well (State Base Plane Coordinates, NAD: 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x - 612049 y - 5959065 Zone ASP4 14500' 8885' ADL 028263 &028262 TPI: x 609029 y - 5954972 Zone ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x - 606104 y - 5956619 Zone ASP4 None 18. Directional Survey: 0 Yes ® No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, RES, GR, DEN, NEU 4277' 4139' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# L -80 Surface 80' Surface 80' 30" 260 sx Arctic Set (Approx.) 13 -3/8" 68# L -80 32' 3118' 32' 3011' 16" 2403 sx CS III, 478 sx Class 'G' 9 -5/8" 47# L -80 29' 4277' 29' 4139' 12-1/4" 910 sx Class 'G' 7" 26# L -80 3845' 10567' 3716' 8640' 8 -1/2" Not Cemented 5 -1/2" 17# L -80 10411' 10840' 8529' 8829' 8 -1/2" 105 sx Class 'G" 3 -1/2" 9.2# L -80 10222' 14500' 8391' 8885' 4 -3/4" 232 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 - 1/2 ", 12.6#, L - 80 10232' 10176' / 8357' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ® No SCANNED LIAR 2p j� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10884' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None F DEC 0 7 "Va Form 10-407 Revised 10/2012 CONTINUED ON REVERSE 74 /2,l0.1z_.-- Submit Original Only 29. GEOLOGIC MARKERS (List all formations allarkers encounter 30. FORMATION TESTS NAME MD TVD Well Tested. Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Kuparuk 8454' 6997' None Miluveach 8581' 7102' Kingak 9271' 7654' Sag River 10832' 8824' Shublik 10869' 8849' Shublik B 10935' 8890' Shublik C 10970' 8910' Eileen 11015' 8932' Sadlerochit / Zone 4B 11094' 8959' Formation at Total Depth: 31. List of Attachment Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ron Phillips, 564 -5913; Ron.Philli s @bp.com Email: Joseph.Lastufka @bp.com Title: Drilling Technologist Printed Name: Joe Las Signature: ' � f� Phone 564 -4091 Date: (Z-' 5111- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only • • W -02A Well History (Pre Rig Sidetrack) Date Summary 10/02/12 RUN 3.25" LIB TO 10150' SLM, UNABLE TO PASS RESTRICTION. RAN 2.77" CENT. & 2.50" LIB TO WRP AT 10,257' SLM (10,256' MD) (impression of shear stud). PULLED 3 -1/2" WRP FROM 10,257' SLM (10,265' MD) (missing 1 element). ATTEMPTED TO FISH ELEMENT W/ 3 -1/2" BLB & 2.62" WIRE GRAB (no element recovered). CURRENTLY RUNNING TANDEM SLB SBHPS GAUGES. 10/03/12 RAN TANDEM SLB SBHPS GAUGES AS PER PROGRAM (good data). 10/09/12 T /I /O = SSV /360/50. Temp = SI. IA FL Request. AL SI @ casing valve. IA FL near surface. SV, WV, SSV = C MV + O. IA, OA = OTG. NOVP. 21:45. 10/10/12 CTU #3 1.75" Coil Tubing - Job Scope: Mill out scale restriction in tubing pre - tubinq patch. Travel from 12 -10 to W -02, stand by for Wells Support to complete RU. RU and perform weekly BOP test. MU BKR mill & motor assy w/ 3.8" Turbo scale mill. CTMD reading 5ft shallow from KB at surface (was not corrected). RIH and dry tag at 10090'. Mill scale from 10090' at .3 -2fpm down to XN -Nip at 10215' ctmd (10220' corr) taking returns to formation. Noticed motor stalls at 10150' and 10194', stalls at the X -Nip are 5ft off. Due to 5ft discrepancy, determined not to mill beyond 10215'ctmd (10220' corr). Ran one pass reaming from 11110' down to XN -Nip at 10220' and back up. Down on pumps, RIH from 10050' to the XN -Nip at 10220' and dry tag w/o seeing any obstructions. POOH. MU and RIH w/ BKR patch drift assy. 10/11/12 CTU #3 1.75" Coil Tubing - Job Scope: Mill out scale restriction in tubing pre- tubing patch. Drift for tubing patch and whipstock. RIH w/ 3.7" BKR patch drift assy. Drifted down to 10150' w/o any obstructions encountered. POOH. MU and RIH w/ 2.63" BKR whipstock drift assy. Drifted down to 11000' w/o any anomalies. 10/13/12 T /I /O= 200/350/60. Temp= SI. WHPs & T FL (CTD Prep). ALP= 370 psi, SI @ casing valve. T FL @ surface. SV, WV & SSV =C. MV =O. IA & OA =OTG. NOVP. 2140 hrs. 10/14/12 INITIAL T /I /O = 250/250/100. SET 3.5" BAKER PKR/WHIPSTOCK TOP @ 10890' (corrected to 10884' with E -Line) - 38 DEG ROHS (2 RA TAGS INSTALLED 5.35' FROM TOP OF WHIPSTOCK) MAX OD = 2.74 ", OAL = 10.68'. LAID DOWN EQUIPMENT FOR NIGHT AND WILL RETURN IN AM TO SET WRP. 10/15/12 INITIAL T /I /0 = 200/200/100. RIH WITH HEAD (6x3) / 2 1- 11/16" WB / CCL / BAKER 10 / 4.5" WRP. OAL = 24 FT, OAW = 250 LBS, MAX OD = 3.77 ". SET PLUG ME AT 10019' (Top @ 10018'), CCL STOP DEPTH = 10010.5', CCL TO ME = 8.5'. PLUG IS A 4.5" STD WRP. PLUG SET IN THE MIDDLE OF THE SECOND FULL JOINT ABOVE GLM #1 AT 10089. FINIAL T /I /O = 30/200/0. 10/18/12 T /I /O = 57/349/89 Temp = S/I MIT -T to PASS 3000 psi, MIT -IA INCONCLUSIVE (CTD) to 2000 psi. Pumped 2.2 bbls amb Diesel to achieve MIT -T 3000 psi test pressure. TBG lost 24 psi in the 1st 15 minutes and 16 psi in the 2nd 15 minutes for a total loss of 40 psi over the 30 min. test.Bled —1.8 bbls back Pumped 10 bbls Dead Crude to achieve 2000 psi MIT -IA 2500 psi test pressure. IA lost 3 psi in the 1st 15 minutes and 3 psi in the 2nd 15 minutes for a total loss of 6 psi over the 30 minute test. FWHP's= 600/450/120 Tags hung Pad Op notified SV, SSV, WV =S /I MV =O IA, OA= OTG AL =S /I. 10/20/12 T /I /O = 577/408/47. Temp = SI. MIT- IA PASS to 2500 psi (Pre CTD). AL SI @ casing valve, ALP = 320 psi. IA FL near surface. Bled gas cap off IA. Pumped 3.5 bbls amb diesel to achive test pressure of 2500 psi. IAP lost 57 psi in the 1st 15 min and 17 psi in the 2nd 15 min. Bled IAP from 2443 psi to 400 psi in 30 min (3.8 bbls). Job complete. Final WHPs = 580/400/44. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00. Page 1 of 2 • W -02A, Well History (Pre Rig Sidetrack) Date Summary 11/04/12 PULL 4 1/2" WFD WRP FROM 9995'SLM. LRS ATTEMPT TO MIT -IA TO 2000 #(unable to get pasing MIT, tubing tracking). LRS ESTABLISH LLR (2 bpm @ 350 psi). 11/04/12 T /I /0= 200/570/151 Temp =S /I Assist SLB, Pre circ to check for rate MIT -IA to 2000 psi FAILED (Pre CTD) Pumped 50 bbls crude down IA. Established LLR of 2 bpm @ 350 psi. 11/05/12 T /I /0= 200/570/151 Temp =S /I Assist SLB, Pre circ to check for rate. Freeze protect F/L (Pre CTD) Pumped 4 bbls meth down F/L for freeze protect Final WHP's 0/0/380 SV,WV,SSV= closed MV,IA,OA= open. 11/06/12 T /I /0= 20/20/0 Temp= S/I Circ out (Pre CTD) Pumped 2.5 bbls of 0* diesel down Tbg to confirm communication with IA. Pumped 5 bbls of 0* neat down Tbg followed by 722 bbls of 100* 2% KCL. Pumped 3 bbls neat followed by 130 bbls diesel down TBG to freeze protect. U -tube for 1 hr. pumped 1 bbls meth followed by 3 bbls diesel down F/L of W -01 to freeze protect. Tags hung, Valve positions upon departure: SV WV SSV= closed MV IA OA= open. FWHPS= 0/0/0. 11/09/12 T /10= 0/0/0 Conducted PJSM; Barriers= SV & SSV; Verified barriers by applying 500 psi against SV through tree cap, LTT passed; Installed lubricator & P.T. (charted SV test) against SV to 300 psi /3500 psi (passed); Set 4" CIW "H" TWC #279 @ 110" w/1 -1' ext.; Torqued all tree flange nuts /studs to API Spec. (see log); P.T. (charted) tree to 300 psi /5000 psi (passed); Pulled 4" CIW TWC; Barrier= I/A & O/A casing valves; LTT passed; Installed second (piggy back) CIW 2- 1/16" I/A & O/A valves, torqued to API specs.; P.T (charted) to 300 psi /3500 psi, passed; Charted tests downloaded into U -drve TRP folder. 11/11/12 T /I/0= 0/0/0 Conduct PJSM; Barriers= MV & SSV, verified barriers by applying 500 psi through tree cap independently for 5 min., LTT passed; Installed un- tapped blind flange on Flow cross companion, torqued to spec.; P.T. (charted) to 300 psi /5000 psi (pass); Charted tests downloaded into U -drive TRP folder. Page 2 of 2 • • ,, "sf> P., e a 3' ' Y:g �' Common Well Name: W -02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/13/2012 End Date: X3- 012X0 -C: (3,125,448.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 8/15/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'49.598 "8 Long: 0149 °05'33.466 "W Active Datum: Kelly Bushing / Rotary Table @82.75ft (above Mean S ea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/13/2012 04:30 - 06:00 1.50 MOB P PRE BEGIN RON EVENT WITH NORDIC 2 CTD RIG AT 04:30 HRS ON 11/13/2012. HOLD PRE -JOB SAFETY MEETING FOR MOVING RIG. CHECK TIRES AND PREPARE TO MOVE OFF WELL. 06:00 - 08:30 2.50 MOB N RREP PRE DISCOVER ISSUE WITH RIG TIRE. CALL OUT SERVICE TECH TO FIX (CODE 8 ON IADC) 08:30 - 11:00 2.50 MOB N WAIT PRE WAIT ON WEATHER (HIGH WINDS AND LOW VISIBILITY) TO MOVE OFF WELL. 11:00 - 13:00 2.00 MOB P PRE MOVE RIG OFF OF P -12 AND STAGE ON P PAD WHILE CLEANING UP RIG MATS AND LOCATION AROUND P -12 WELLHEAD. CONTINUE MOVING TRAILERS AND AUXILLARY EQUIPMENT TO W PAD. 13:00 - 20:00 7.00 MOB P. PRE MOVE RIG FROM P PAD TO N PAD. 17:00 - NOTIFIED AOGCC BY EMAIL OF INTENTION TO TEST BOPE ON W -02 BEGINNING IN 24 HOURS AT 17:00 ON 11/14/12. 20:00 - 00:00 4.00 MOB ` P PRE STAGE RIG ON N PAD WHILE TOOL SERVICE GROUP LAYS OUT RIG MATS ON KUPARUK RIVER BRIDGES AND SANDS THE RAMPS UP TO THE BRIDGES. 11/14/2012 00:00 - 01:30 1.50 MOB P PRE RIG SITTING ON N PAD WHILE TOOL SERVICE GROUP IS LAYING MATS ON KUPARUK RIVER BRIDGES AND SANDING RAMPS UP TO BRIDGES. 01:30 - 06:00 4.50 MOB P PRE MOVE RIG FROM N PAD TO W PAD. RIG ON W PAD ACCESS ROAD AT 05:00. 06:00 - 08:00 2.00 MOB P PRE CONTINUE MOVING RIG. RIG ON W PAD AT 0730. 08:00 - 09:00 1.00 MOB N SFAL PRE BLEED OFF 150 PSI FROM OA. MONITOR FOR 30 MIN AND BUILDS TO 5 PSI, GOOD TO PULL OVER. BLEED OFF 100 PSI FROM SWAB CAP. ALL TREE VALVES SHUT IN. 09:00 - 10:00 1.00 MOB P PRE SPOT RIG MATS AROUND TREE. 10:00 - 12:00 2.00 MOB P PRE PJSM THEN START MOVING RIG OVER WELL. MOVE RIG DOWN THE PAD AND BACK AGAIN TO AVOID A LIGHT POLE DIRECTLY OPPOSITE THE WELL. Printed 11/26/2012 11:17:18AM Common Well Name: W -02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/13/2012 End Date: X3- 012X0 -C: (3,125,448.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 8/15/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'49.598 "8 Long: 0149°05'33.466'W Active Datum: Kelly Bushing / Rotary Table @82.75ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 15:00 3.00 MOB N SFAL PRE ALMOST OVER THE WELL, SPOT A THERMOSIPHON BEHIND THE WELL THAT MUST BE REMOVED PRIOR TO GETTING OVER THE WELL. GALL PAD OPERATOR WHO GETS A CREW OUT TO REMOVE IT. PULL RIG BACK AWAY FROM WELL TO GIVE THEM ROOM TO WORK. PRODUCTION CREW COMES OUT WITH BOOM TRUCK AND CUTS OFF THERIVMOSIPHON NEAR GROUND LEVEL, LAYS IT DOWN. MEANWHILE SPOT OFFICE TRAILER, GET COMMUNICATIONS THERE TUNED IN. 15:00 - 16:00 1.00 MOB P PRE ACCEPT RIG 15:00 „SUNDRY #312 -400, PERMIT TO DRILL #212 -159 PJSM THEN PULL RIG OVER WELL. SET RIG DOWN AND CLOSE CELLAR DOORS. ALL PRE -RIG WORK CONFIRMED COMPLETE W -35I SHUT -IN AND LOTO FOR DURATION OF CTD SIDETRACK FOR PRESSURE CONCERNS - WELLWORK TRANSFER PERMIT IS OPEN 16:00 - 17:00 1.00 R IGU , P PRE PICKUP 2” REEL ( #31117 -E, TOTAL LENGTH = 16040', RUNNING FOOTAGE = 140K, NONE IN CHROME). 17:00 - 18:00 1.00 BOPSUR P PRE ESTABLISH TREE BARRIERS PER WELL PROGRAM WITH LEAK TIGHT TEST (PASS). NIPPLE DOWN TREE CAP. 18:00 - 23:00 5.00 BOPSUR P PRE NIPPLE UP 7- 1/16" 5K BOP STACK AND LUBRICATOR RISER TO 4- 1/16" SWAB FLANGE WITH FOLLOWING CONFIGURATION FROM TOP DOWN: - HYDRIL GK ANNULAR - TOT BLIND -SHEAR RAMS WITH BOOSTERS - TOT 2" COMBI PIPE RAM/SLIPS - FLOW CROSS WITH 2- 3/16" INNER HCR VALVE AND 2- 1/16" OUTER GATE VALVE ON BOTH KILL AND CHOKE LINE - TOT 2 -3/8" COMBI PIPE RAM/SLIPS - TOT 2" COMBI PIPE RAM/SLIPS RIG UP REEL HARDLINE AND GRAPPLE FOR PULLING COIL ACROSS. SPOT CUTTINGS BOX AND FLOWBACK TANK. TEST HARDLINE TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH. RIG UP IA/OA PRESSURE TRANSDUCERS AND SSV CONTROL LINE. INITIAL IA = 45 PSI, OA = 75 PSI 23:00 - 23:30 0.50 RIGU P PRE HOLD RIG EVAC DRILL AND AFTER ACTION REVIEW. NO DEFICIENCIES TO REPORT. 23:30 - 00:00 0.50 RIGU P PRE RIG UP INJECTOR AN PACKOFF. Printed 11/26/2012 11:17:18AM H5p Common Well Name: W -02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/13/2012 End Date: X3-012X0-C: (3,125,448.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 8/15/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'49.598 "8 Long: 0149°05'33.466'W Active Datum: Kelly Bushing / Rotary Table @82.75ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/15/2012 00:00 - 01:00 1.00 BOPSUR P PRE FILL ALL SURFACE LINES AND MUD GAS SEPARATOR. PERFORM SHELL TEST ON BOP STACK AGAINST NIGHT CAP, SWAB VALVE, AND FOUR CHOKE MANIFOLD VALVES TO 250 PSI LOW AND 4500 PSI HIGH (PASSING TESTS, SEE ATTACHED CHART -.AND BOPE TEST REPORT). 01:00 - 03:30 2.50 RIGU P PRE PULL COIL ACROSS FROM REEL HOUSE TO GOOSENECK ON INJECTOR. TROUBLESHOOT MINOR ISSUE WITH REEL BRAKE/TENSIONER WHILE STABBING COIL INTO INJECTOR. 01:15: UPDATE AOGCC REPRESENTATIVE, JEFF JONES, WITH. PHONE MESSAGE AND EMAIL ABOUT INTENTION TO BEGIN BOP TEST WITHIN TWO HOURS. 03:30 - 08:45 5.25 BOPSUR ` P PRE PRESSURE TEST BOPE PER ADWOP AND AOGCC REGULATIONS TO 250 PSI LOW AND epe 3500 PSI HIGH FOR FIVE MIN EACH. - PRESSURE TEST ANNULAR PREVENTER WITH 2" TEST JOINT FUNCTION TEST KOOMEY ACCUMULATOR UNIT PER BP WELL CONTROL MANUAL AND NORDIC PROCEDURE. - TEST AND CALIBRATE GAS ALARMS. - FUNCTION ALL COMPONENTS FROM BOTH REMOTE STATIONS - NO FAILURES TO REPORT - SEE ATTACHED DOCUMENTATION REPORT AND CHARTS. 08:45 09:00 0.25 RIGU P PRE RIG EVAC EXERCISE WITH MAN DOWN. ALL PERSONS EXCEPT MAN DOWN ARE ACCOUNTED FOR. AAR DISCUSS SCENARIOS. 09:00 - 10:00 1.00 BOPSUR P PRE CONTINUE BOP TEST. ALL RAMS AND VALVES TESTED EXCEPT (INNER REEL VALVE AND PACKOFF TO BE TESTED AT LATER TIME INTERVAL) 10:00 - 12:30 2.50 RIGU P PRE LINE UP TO FILL REEL FORWARDS. RE -BOOT CABLE. MAKE UP CT RISER. PREP FOR INNER REEL VALVE TEST. FILL REEL WITH 5 BBLS MEOH THEN WATER. 12:30 - 23:30 11.00 RIGU N SFAL PRE REEL IS FULL, CONTINUE CIRCULATING. SLB MECHANICS WORKING ON OFF DRILLER SIDE REEL MOTOR. DISCOVER BROKEN DRIVE SPROCKET. DISCUSS PLAN FORWARD WITH OPS SUPERINTENDENT TO CONTINUE OPERATIONS WITH ONE REEL BRAKE MOTOR (SECOND MOTOR WILL BE REPAIRED AFTER MILLING WINDOW). MECHANICS RETURN TO LOCATION AND RETURN REEL TO SERVICE CAPABILITY. 23:30 - 00:00 0.50 BOPSUR P PRE PRESSURE TEST INNER REEL VALVE AND INJECTOR PACKOFF TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS, SEE ATTACHED CHART). Printed 11/26/2012 11:17:18AM .' .. , Common Well Name: W -02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/13/2012 End Date: X3-012X0-C: (3,125,448.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 8/15/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 0 17'49.598 "8 Long: 0149°05'33.466'W Active Datum: Kelly Bushing / Rotary Table @82.75ft (above Mean Sea Level) Date From - To Hrs (ft) Task Code NPT NPT Depth Phase Description of Operations (hr) 11/16/2012 00:00 03:00 3.00 RIGU P PRE PAC 2" IL REEL FROM COLD WATER TO DIS 11 0 °F FRESH WATER. E -LINE SLACK NOIL FUNCTION REEL LE WI REMAINING REEL DRIVE MOTOR TH SLB E MECHANICS (PASS). CUT 325' BACK INTO C . COIL WITH HYD CUTTER AND 65' E -LINE (CUT EXTRA 50' COIL THAN CALCULATED TO GET PAST WELD). NEW LEN A . ', VUM = L, E -LINE GTH SLACK 15688 = 1.73 OL %. 03:00 - 05:30 2.50 STWHIP P WEXIT INSTALL SCHLUMBERGER E KENDLE 38.6 BB INTERNAL S DIMPLE LL COILED TEST O 38 TUBING KLBS MAKEUP CONNECTOR BHI E -LI PU T,. NE HEAD (PASS' MEG TEST W/ > 50 OHM, PASS CONTINUITY TEST W/ 2000/ OHM). PRESSURE TEST BOTH CTC AND E -LINE HEAD TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). 05:30 W 06:00 0.50 STWHIP P WEXIT OPEN WELL AND MONITOR FOR 30 MIN. 06:00 - 07:30 1.50 STWHIP P WEXIT MAKEUP 2.80" MILLING ASSEMBLY AND RUN IN HOLE TO BHA OVERALL LENGTH AT 111' MD. PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE EACH (PASSING TESTS). HUGHES 2.8" DIAMOND WINDOW MILL - MIN HUGHES 2.80 GO / 2.79" NO -GO DIAMOND R / I ER _ 1/8 " BAKER R XTREME STRAIGHT MUD MOTOR WITH AME FLOAT SUB (BENCH PRESSURE TESTED) - 2 -3/PR88 U COILTRAK TOOLS 07:30 - 14:00 6.50 STWHIP N SFAL ` WEXIT WAIT AT C DRECO, THE MANUFACTURER SLB IS CONTA OF THE TING REE SURFACE. IF OPERATING IT WITHOUT EEL STAND, TO S ONE OF E RERS T SAFE OPERATING ENVELOPE MOTO IS OF WITHIN THAT EQUIPMENT. TH AT EL 14:00 GET WORD BACK HE FROM DT O RUN E EL STAND WITH ONE MOTO CIRCULATE DOWN RECO CT L REGULARLY RE TO PREVENT FREEZE UP. 14:00 - 15:40 1.67 STWHIP N SFAL WEXIT HE EE L BACK OW HAVE PJSM PUMPED AI TOTAL OF AC 52 BBLS O FRESH T WATER N INTO BHA WELL #1 SINCE D 0730 N. F TO KEEP CT WARM. MAKE UP CT RISER TO WELL AND BLOW BACK 4 BBLS OF FLUID INTO PITS TO EMPTY THE TOP WRAP IN THE REEL HOUSE. IA /OA =95/70 PSI. 15:40 - 23:00 7.33 STWHIP N SFAL WEXIT MOVE INJECTOR BACK OVER THE CIRC HOLE. WAIT FOR REPLACEMENT PART FOR REEL MOTOR. A CONTE R HOUSEKEEPING. W NWHILE ON PIPE SKATE INU CHAIN MAINTENANCE. 23:00 - 00:00 1.00 STWHIP N SFAL WEXIT SLB MECHANS AR OO BEGIN RE- INSTALLING IC RIVE DRIV E SHAFT LOCATI IN N REEL BRAKE MOTOR. Printed 11/26/2012 11:17:18AM • Common Well Name: W -02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/13/2012 End Date: X3-012X0-C: (3,125,448.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 8/15/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'49.598 "8 Long: 0149°05'33.466'W Active Datum: Kelly Bushing / Rotary Table @82.75ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/17/2012 00:00 - 05:30 5.50 STWHIP N SFAL WEXIT SLB MECHANICS INSTALL NEW DRIVE SHAFT IN REEL BRAKE MOTOR. 05:30 - 06:00 0.50 STWHIP P WEXIT FUNCTION TEST REEL BRAKE MOTOR WITH SLB MECHANICS AFTER COMPLETING REPAIRS. 06:00 - 06:40 0.67 STWHIP P WEXIT MAKEUP 2.80" MILLING ASSEMBLY AND RUN IN HOLE TO BHA OVERALL LENGTH AT 111' MD (BHA #2 FOR WELL, BUT ONLY RUN #1 DUE TO ISSUES WITH REEL BRAKE MOTOR). PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). HUGHES 2.8" DIAMOND WINDOW MILL HUGHES 2.80 GO / 2.79" NO -GO DIAMOND STRING REAMER - 2 -1/8" BAKER XTREME STRAIGHT MUD MOTOR WITH FLOAT SUB (BENCH PRESSURE TESTED) - 2-3/8" COILTRAK TOOLS 06:40 - 09:40 3.00 STWHIP P WEXIT PJSM THEN RIH WITH BHA #2. PUMP WATER AT MIN RATE THROUGH OPEN EDC. TAKE RETURNS OUT TO TIGER TANK. STARTING STRAP ON TIGER TANK IS 18 BBLS. 09:40 - 11:10 1.50 STWHIP P WEXIT START LOGGING GR FROM 10080 FT TO TIE -IN DEPTH. AFTER LOGGING 200 FT THE GEO CAN'T MATCH OUR LOG DEFINITIVELY TO THE PDC LOG. 11:10 - 12:40 1.50 STWHIP P WEXIT CONTINUE RIH. UP WT AT 10870 FT IS 35K. TAG WHIPSTOCK AT 10912 FT, UNCORRECTED. TOP WHIPSTOCK WAS SET AT 10890 FT, PRE -RIG. SWAP WELL OVER TO USED 9.08 PPG POWER PRO MUD. CORRECT DEPTH -22 FT BASED ON WHIPSTOCK TAG DEPTH. 12:40 - 13:00 0.33 STWHIP P WEXIT BRING MUD RETURNS BACK INSIDE THE RIG AFTER 9.0 PPG MUD IS AT SURFACE. SHUT DOWN PUMP AND CLOSE EDC. SLOW PUMP RATES, OPEN EDC, 9.1 PPG, 10890' MD: MP #1: 0.5 BPM = 1600 PSI, 1 BPM = 2106 PSI MP #2: 0.5 BPM = 1580 PSI, 1 BPM = 2084 PSI Printed 11/26/2012 11:17:18AM Common Well Name: W -02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/13/2012 End Date: X3- 012X0 -C: (3,125,448.00 ) Project: Prudhoe Bay Site: PB W Pad /� Rig Name /No.: NORDIC 2 Spud Date/Time: 8/15/1997 12:00:00AM Rig Release: � Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'49.598 "8 Long: (((( 0149 °05'33.466 "W Active Datum: Kelly Bushing / Rotary Table @82.75ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) �� 13:00 - 19:0 6 0 STWHTE' P (ftL� WEXIT TAG WHIPSTOCK. KICK -OFF SIDETRACK AND START MILLING WINDOW. 1.5 BPM @ W -028 3450 PSI FREE SPIN (BAKER OIL TOOLS WINDOW MILLING REPORT ATTACHED). 13:30 - 10889.32 FT 0.54K DWOB 14:20 - 10889.90 FT 1.55K DWOB 15 :00 - 10890.51 FT 1.75K DWOB ( ► STALL AT 10890.51 FT, PICKUP IS CLEAN. 15:40 - 10890.90 FT 1.93K DWOB. 17:15 - 10892.1 FT 1.22K DHWOB, 3485 PSI CIRC PRESSURE, 1.5 BPM IN/OUT, NO LOSSES, 9.1 PPG MW IN/OUT, IA/OA = 815/70, ECD = 10.1 PPG 19:00 - 10893.6 FT 1.2KLBS DHWOB, 3550 PSI, 1.5 BPM IN/OUT, NO LOSSES, 9.1 PPG MW IN/OUT, BH ANNULAR PRESSURE = 4575 PSI, BH BORE PRESSURE = 5310 PSI. THIS DEPTH APPEARS TO BE WINDOW EXIT, BASED ON DHWOB. PRELIMINARY WINDOW DEPTHS (UNTIL LOGGING RA TAG): TOP OF WINDOW = 10889' MD (38° ROHS), BOTTOM OF WINDOW = 10894' MD 19:00 - 22:30 3.50 STINHIP P WEXIT MILL 2.80" OD NEW FORMATION FROM 10894' MD TO 10905' MD (11 OUTSIDE OF WINDOW); 1.5 BPM, 3550 -3600 PSI (3450 PSI FREESPIN), 2 KLBS DHWOB, 257 BIT RPM, 9.1 PPG MW IN/OUT, NO LOSSES TO FORMATION, 10.1 PPG ECD, IA / OA = 800 / 15 PSI. 22:30 - 00:00 1.50 STWHIP P WEXIT COMPLETE THREE REAMING PASSES FROM 10905' MD TO TOP OF WINDOW AT 10894' MD; 1 FPM, 1.5 BPM. PICKUP WEIGHT OFF BOTTOM = 33 KLBS, SLACKOFF = 12 KLBS. DRY DRIFT WINDOW ONCE WITH NO ISSUES. PUMP ONE 10 BBL HI-VIS SWEEP WHILE REAMING TO ENSURE METAL SHAVINGS CIRCULATED OUT OF HOLE. Printed 11/26/2012 11:17:18AM •t Common Well Name: W -02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/13/2012 End Date: X3- 012X0 -C: (3,125,448.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 8/15/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'49.598 "8 Long: 0149°05'33.466'W Active Datum: Kelly Bushing / Rotary Table @82.75ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/18/2012 00:00 - 02:00 2.00 STWHIP P WEXIT PULL OUT OF HOLE FROM 10905' MD TO WINDOW AT 10889' MD. UNSUCCESSFULLY ATTEMPT TO OPEN EDC. UNABLE TO REDUCE DIFFERENTIAL PRESSURE ACROSS PWD TO < 200 PSI. PULL OUT OF HOLE FROM WINDOW AT 10889' MD TO 4-1/2" TUBING TAIL AT 10232' MD; 0.75 BPM. 200 PSI PRESSURE DIFFERENTIAL STILL EXISTS ACROSS EDC. APPLY 500 PSI TO BACKSIDE OF COIL TO SUCCESSFULLY REDUCE DIFFERENTIAL AND OPEN EDC. CIRCULATE OUT OF HOLE AT 2.1 BPM, 3550 PSI, 80 FPM FROM 10232' MD TO 8000' MD. PAINT FLAG AT 10700' MD END OF PIPE FOR DEPTH CONTROL ON NEXT TRIP IN HOLE (BECAUSE OF?UNSUCCESFUL LOG TIE -IN ON 11/17/12 TRIP IN HOLE WITH MILLING ASSEMBLY). RE -LOG PLANNED TIE -IN DEPTH 10135' MD - 10190' MD. GR CURVES MATCH EARLIER ATTEMPT TO LOG, CONFIRMING THAT TOOL IS WORKING. 02:00 - 03:30 1.50 STWHIP P WEXIT HOLD UNANNOUNCED KICK WHILE TRIPPING D1 DRILL (BY ALLOWING INACTIVE PIT TO EQUALIZE INTO ACTIVE PIT SYSTEM). ALARMS SOUNDED, WELL SHUT -IN WAS SIMULATED BY RIG CREW. HOLD WELL KILL D5 DRILL. APPLY 400 PSI TO WELLBORE. BRING PUMPS ONLINE WHILE HOLDING CHOKE PRESSURE CONSTANT. ESTABLISH CIRCULATING RATE. VARY CIRCULATING RATE TO SIMULATE SCENARIOS REQURING CHOKE MANIPULATION. HOLD AARS FOR BOTH DRILLS. 03:30 - 05:00 1.50 STWHIP P WEXIT PULL OUT OF HOLE FROM 8000' MD TO BHA AT 111' MD. FLOWCHECK WELL. WELL STATIC. 05:00 - 05:30 0.50 STWHIP P WEXIT UNSTAB FROM WELL AND SETBACK INJECTOR. LAYDOWN MILLING BHA. GAUGE MILLS 2.80" GO, 2.79" NO -GO, NO NOTABLE WEAR. CHECK TORQUE OF TREE BOLTS, NO MOVEMENT ON ANY OF THEM. 05:30 - 06:40 1.17 DRILL P PROD1 MAKE UP BHA #3 (RUN #2 IN WELL), BUILD ASSEMBLY, SCRIBE IN HOLE TO BHA OAL AT 60' MD. MAKE UP CT RISER, PRESSURE TEST QTS. - HUGHES 2.7" X 3" RWD2ST3042.700Q BI- CENTER PDC W/ SLICK COATING, SER #7031783 - 2 -3/8" BAKER XTREME MUD MOTOR, 1.5° BEND W/ FLOAT SUB ABOVE (BENCH TESTED) - 2 -3/8" COILTRAK TOOLS, NO RESISTIVITY Printed 11/26/2012 11:17:18AM Itat =' W/4 -1/16" 5M S1 (NOTES: WELL ANGLE > 70° @ 11050' WELLFEAD = 3-3!8" 5M FMC I ACTUATOR = NA W —O 2A KB. ELEV = 82.75' BE ELEV = 53.05' KOP= 115(7 Max Angle = 99 @ 14416' Datum M3= 10919' 2221' H4 -1/2" FES X MP, D = 3.813" Datum TVD= 8800' SS 113 -3/8" CSG, 68#, L -80, ID = 12.415" - 3118' GAS LIFT MANDRELS ST MD TVD DEV TYFE VLV LATCH PORT DATE 7 3131 3024 19 WAG DM' RK 0 01/05/05 Minimum ID = 2.972" @ 10246' 6 3681 3555 12 MMG DOME RK 16 06/25/06 TOP OF 3-1/2" LINER E 5 5124 4576 52 KBG-2 DM' BK-5 0 01/05/05 4 6894 5845 52 KBG-2 DOME BK-5 16 06/25/06 3 8259 6835 35 KBG-2 DOME BK-5 16 06/25/06 2 9309 7684 38 KBG-2 DOME 8K-5 16 06/25/06 I4 -1/2" TBG, 12.6#, L -80, .0152 bpf, D = 3.958" 1 10089 8293 41 KBG-2 ORIFICE BK-5 24 01/05/05 l. 3845' -19-5/8" X 7" BKR ZXP PKR, D = 6.290" PERFORATION SUMMARY �- �-� REF LOG: SWS MEMORY CNUGR ON 12/19/01 r 3858' H9 -5/8" X 7" BKR HMC HGR, D = 6.300" ANGLE AT TOP PERF: 76 @ 11100' Note: Refer to Production DB for historical pert data 9 -5/8" MLLOUT WINDOW (W -02A) 4277' - 4293' SIZE SPF INTERVAL Opn /Sqz DATE / 2" 4 11100 - 11230 0 12/20/01 2" 4 11250 - 11360 0 12/20/01 2" 4 11380 - 11425 0 12/20/01 10155' -14 -1/2" HES X NP, D = 3.813" 2" 4 11521 - 11580 0 12/20/01 2" 4 11618 - 11786 0 12/20/01 10176' -17" X 4 -1/2" BKR SABL -3 PKR, D = 3.875" 2" 4 11840- 11878 O 12/20!01 2" 4 12773 - 12895 O 12/20!01 :i 10199' (- 14 -1/2" HES X NP, D = 3.813" 2" 4 12925 - 13105 0 12/20/01 :i ' 10220'1-14-1/2" I- ES XN NIP, 13= 3.725" 2" 4 13319 - 13353 0 12/20/01/ 2" 4 13388 - 13478 0 12/20/0 10221' -I TOP OF BKR TACK SLV, D = 5.25" 2" 4 13608 - 13655 0 12/20/01 2" 4 13670 - 13718 0 12/20/01 NIIIIIIIIIIP /. 10229' -17" X 3-1/2" BKR ZXP PKR, D = 4.470" 2" 4 13760 - 13907 0 12/20/01 1 ":41. 4 13949 - 13980 0 12/20/01 0 4 `' 10235' H7 " X3 - 1 /2 " BKR HMO HGR D= 4.408" I 2" 4 14012 - 14085 0 12/20/01/ ligt I 'I' 10411' H 7" X 5 -1/2" BKR PKR, ID = 3.98" 2" 4 14159- 14264 O 12/20!0!1 4 4 10422' H 7" X 5 -1/2" BKR HGR, ID = 3.958" 2" 4 14280 - 14390 O 12/20/01 � � � � � ►11 .4 ► .� 10,884' - 3 -1/2" BKR PKR Whipst ck ovowwo **********• 11:09' CTM (� ROCK SCREEN (06/21/09) BKR KB PKR w /2 9 -5/8" CSG, 47 #, L -80, D = 8.681 " -I 5547' I L�.�.�.�.L�.LIA.1. - 4 -1/2" WLEG, = ?? H 10232' ' ` 11888' CTMD - OBSTRUCTION - 17" LNR, 26#, L -80, ID \ =\6.276" -J 10567' I ■ UNKNOWN .� - ' ORIGIN (03/26/07) 5 - 1/2" LNR, 17 #, L - 80, D = 4.892" --j 10840' ■ I3 -1/2" X 15' MA RICER JT W /RA TAG 11075' % I 14435' HFSTD I3 -1/2" X 15' MARKER sr W /RA TAG -I 12276' `/�'�'�'* ■ v* 13-1/2" LNR, 9.2#, L -80, .0087 bpf, D = 2.972" -I 14500' DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY MT 08/31/97 ORIGINAL COMPLETION 06/28/09 DBM/TLH BRK PKR & ROCK SCREEN SET WELL: W -02A 12/23/01 RIG SIDETRACK PERMIT No: 2012140 03/05/05 SRBTTLH POSSIBLE RESTRICTION API No: 50 029 - 22793 - 01 06/25/06 RCT /PJC GLV C/O SEC 21, T11 N, R12E 1192' SNL 8. 119(' WEL 03/26/07 RLANPJC OBSTRUCTION @ 11888' 10/17/08 CJNYPJC SFTY NOTE UPDATE BP Exploration (Alaska) • • gw \ \ I %% s � THE STATE Alaska Oil and Gas ��' OfALASI(A Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue r h Anchorage, Alaska 99501 -3572 OF A Ag Main: 907.279.1433 Fax: 907.276.7542 SCANNED JAN 11 2013 John McMullen Engineering Team Leader O l BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W -02A Sundry Number: 312 -400 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 1 �, , •rm. Com ssioner DATED this 'ay of November, 2012. Encl. ' RECEIVED STATE OF ALASKA ALitA OIL AND GAS CONSERVATION COM SSION 7 ,;1.2 APPLICATION FOR SUNDRY APPROVAL i �,�., . ' ' 20 AAC 25.280 AO el CC 1. Type of Request: ❑ Abandon ® Plug for Redrill • ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 201 -214 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22793 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU W -02A ' Spacing Exception Required? ❑ Yes ►C. No 9. Property Designation: 10. Field / Pool(s): ADL 028263 &028262 Prudhoe Bay / Prudhoe Bay - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14500' . 8885' • 14435' 8894' None 11888' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 3086' 13 -3/8" 32' - 3118' 32' - 3011' 4930 2270 Intermediate 4248' 9 -5/8" 29' - 4277' 29' - 4139' 6870 4760 Production Liner 6722' 7" 3845' - 10567' 3716' - 8640' 7240 5410 Liner 429' 5 -1/2" 10411' - 10840' 8529' - 8829' 7740 6280 Liner 4278' 3-1/2" 10222' - 14500' 8391' - 8885' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11100' - 14390' 8961' - 8901' 4 -1/2 ", 12.6#, L -80 10232' 8398' Packers and SSSV Type: 7" x 4-1/2" Baker SABL -3 Packer Packers and SSSV 10176' / 8357' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: • w Description Summary of Proposal IN BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development ® Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 1, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the f. -going is ue and correct to the best of my knowledge. Contact Ron Phillips, 564 -5913 Printed Name Jo j -n Title Engineering Team Leader Prepared By Name /Number Signature �- Phone 564 - 4711 Date /6 //f / 1 Joe Lastufka, 564-4091 % Commission Use Only Conditio of approval: Notify Commission so that a representative may witness y > ;�/a� Sundry Number: `. (j( ❑ Plug Integrity Ea Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: 13 0 P 1 t 11) Jr c7 I"S ) Subsequent Form Required: APPROVED BY �/ Approved By: • = T ONER THE COM lt Date +1 O F1c1 eis� " , WS NOV Q 1 11 LF C � - �� MS N O U 20 bmi In Duplicate I f11 �.Ur \1 ` AIT. Q 1 00- • • To: Alaska Oil & Gas Conservation Commission b From: Ron Phillips P CTD Engineer Date: October 16, 2012 Re: W -02A Sundry Approval is requested to plug the W -02A perforations as part of drilling the W- 02B coiled tubing sidetrack. HISTORY W -02 was originally drilled and completed in Aug. 1997 and sidetracked in December 2001. In June 2006 slickline was unable to reach the XN nipple with a 4 -1/2" Whiddon catcher sub. They then sat down at 10,078' SLM with a 3.50" LIB which showed some sort of obstruction that appeared to possibly be parted pipe. On 2/15/07 coil started milling at 10,239' ctm with a 2.70" OD junk mill. They stalled multiple times but made it down to 11,904 where they encountered an obstruction that showed wear on the mill indicating metal in the well. On 6/19/09 CT made a Venturi run but were unable to get past GLM #1. There was a small mark on the bottom of the Venturi. On 07/7/12 slickline ran a 24 arm caliper. The caliper showed an ID restriction (presumably scale) from 10,100'MD (just below GLM #1) to 10,232' MD (4 -1/2" WLEG). The caliper also indicates lack of integrity at GLM #1. On 7/8/12 slickline set a 3 -1/2" WRP at 10,265' MD and performed a passing CMIT -TxIA but the IA tracked the tubing during an MIT -T attempt. An MIT -OA also failed at this time. Slickline dummied off GLVs with significant trouble setting a valve in GLM #1 and performed a LDL which indicated a leak at GLM #1. They then set a dummy valve with swell packing in GLM #1. Despite this work, the IA still tracked the tubing when pressure was applied to the tubing. Even though there is a leak in the lowest GLM, we do not yet want to replace the tubing in this well because the viability of this CTD sidetrack is uncertain. We do, however, need to prove that a patch will provide mechanical integrity for the tubing after the side track is complete. For this reason, a patch will be set before the sidetrack, tested, and then pulled to allow CTD to drill the well. After the sidetrack is completed, the patch will be reset to allow the well to be POP. If the patch is unable to restore tubing integrity, other options include a packer squeeze since GLM #1 is just above the packer at 10,176' MD. REASON FOR SIDETRACK W -02A is currently non - operable due to failed TxIA leak at GLM #1. With production at 90% water cut and no viable well work options available, a CTD sidetrack is believed to be the best utilization of this wellbore. PROPOSED PLAN The proposed plan for W -02A is to drill a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on or around November 15, 2012. The existing perforations will be isolated by a 3- 1/2" packer whipstock, as well as the primary cement job to top of liner. The sidetrack, W -02B, will exit the existing 3.5" liner and kick off in Shublik and land in zone Z4. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. COj ( 114e T4.5 •l( 0s /uiT 04 7 ace prOc%ct T w 40 4,5 no ) 10 PP RT iYi VS W.C. 4 ack, "f %ors /l f ''t re Cat" *OR lye "(fide of Pie fro/. ("77 • n • Pre -Rig Work: (scheduled to begin Nov 01, 2012 ) 1. S Pull WFD 3 -1/2" WRP. 2. S Conduct SBHPS. 3. C MU appropriate BHA with 3.79" Turbo scale mill. 4. C Pump a tubing volume of 1 -2% KC1 at 4 -5 bpm to fluid pack the tubing. 5. C Shoot fluid level in IA and load IA with crude if IA fluid level is not at surface. 6. C RIH and dry tag scale obstruction at -10,100' MD. 7. C Slowly mill scaled section from top of scale (10,100' MD) to the XN Nipple at 10,220' MD, taking returns to the formation. 8. C POOH and make up tool string with a 4 -1/2" KB dummy patch representative of the patch to be run. 9. C RIH and drift to 10,150' MD with 4-1/2" KB drift. POOH. 10. C Make up tool string with 3 -1/2" dummy whipstock. RIH and drift to 11,000' MD. 11. E MU tool string with setting tool and 3 -1/2" whipstock. 12. E Ensure that the tubing and IA fluid levels are still at surface. If they are not, top off with diesel. 13. E RIH and set 3 -1/2" whipstock at 10,885'. 14. E Set Baker KB patch (20' element to element) at 10,103' MD bottom mid element. 15. F MIT -T to 3,000 psi. 16. F MIT -IA to 2,000 psi. 17. S If MIT -T and MIT -IA pass, pull patch covering GLM #1 18. 0 AC -LDS; AC- PPPOT -IC, T 19. 0 PT MV, SV, WV p 'A ¢6 3 20. 0 Bleed gas lift and production flowlines down to zero and blind flange. 3 2' °U 21. 0 Remove wellhouse, level pad. Rig Work: (scheduled to begin on November 15, 2012) I a ly' f r� f� QF1L°G' ,Ct.C 1. MIRU and test BOPE to 250 psi low and 3500�si high. , y 24' hr5 in y�1/r - C 2. Mill 2.8" window at 10,885' and 10' of rathole. 3. Drill Build: 3" OH, 307' (20 deg/100 planned). 4. Drill Lateral: 3" OH, 2749' (4.5 deg/100 planned) with resistivity. 5. Run 2 -3/8" solid chrome liner leaving TOL at 10,210' 6. Pump primary cement leaving TOC at 10,210', 15.5 bbls of 15.8 ppg liner cmt planned. 7. Cleanout liner run. 8. MCNL /GR/CCL logging run. p 1-0 9. Test liner lap to 2400 psi. 10. Perforate liner per asset instructions (-1500') 11. Freeze protect well, RDMO Post -Rig Work: 1. Set Baker KB patch (20' element to element) at 10,103'. 2. Re- install wellhouse and FL's. 3. Generic GLV's 4. Test separator (1500' of perfs) Ron Phillips CTD Engineer 564 -5913 CC: Well File Joseph Lastufka TREE = CM/4 -1/16" 5M • NOTES: WELL ANGLE > 70° @ 11050' I WELLHEAD = ACTUATOR = 13 -318" 5M FMC VV-02A KB. ELEV,= - 82.75' BF. ELEV = 53.05' KOP = 1150' Max Angle = 99 @ 14416' Datum MD = 10919' I 2221' 1--14-1/2" HES X NIP, ID = 3.813" 1 Datum TVD = 8800' SS 113 -3/8" CSG, 68 #, L -80, ID = 12.415" I-J 3118' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3131 3024 19 MMG DMY RK 0 01/05/05 Minimum ID = 2.972" @ 10246' 6 3681 3555 12 MMG DOME RK 16 06/25/06 TOP OF 3-1/2" LINER II 5 5124 4576 52 KBG-2 DMY BK -5 0 01/05/05 4 6894 5845 52 KBG-2 DOME BK -5 16 06/25/06 3 8259 6835 35 KBG-2 DOME BK -5 16 06/25/06 2 9309 7684 38 KBG -2 DOME BK -5 16 06/25/06 14-1/2" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" I 1 10089 8293 41 KBG -2 ORIFICE BK -5 24 01/05/05 3845' I -19 -5/8" X 7" BKR ZXP PKR, ID = 6.290" I PERFORATION SUMMARY 0 0 • 3858' H9-5/8" X 7" BKR HMC HGR ID = 6.300" REF LOG: SWS MEMORY CNL /GR ON 12/19/01 ANGLE AT TOP PERF: 76 @ 11100' 9 -5/8" MLLOUT WINDOW (W - 02A) 4277' - 4293' Note: Refer to Production DB for historical pert data / SIZE SPF INTERVAL Opn /Sqz DATE 2" 4 11100 - 11230 0 12/20/01 2" 4 11250 - 11360 0 12/20/01 10155' H4-1/2" HES X NIP, ID = 3.813" I 2" 4 11380 - 11425 0 12/20/01 2" 4 11521 - 11580 0 12/20/01 10176' 1-1 7" X 4-1/2" BKR SABL -3 PKR, ID = 3.875" I 2" 4 11618 - 11786 0 12/20/01 10199' H4-1/2" /2" HES X NIP, D = 3.813" I , 2" 4 11840 - 11878 0 12/20/01 �i 2" 4 12773 - 12895 0 12/20/01 :. $ 10220' I--I4 -1 /2" HES XN NIP, ID = 3.725" I 2" 4 12925 - 13105 0 12/20/01 , 2" 4 13319 - 13353 0 12/20/01 10221' _l TOP OF BKR TIEBACK SLV, ID = 5.25" I 2" 4 13388 - 13478 0 12/20/01 2" 4 13608 - 13655 0 12/20/01 I. 10229' — 17" X 3 -1/2" BKR ZXP PKR, ID = 4.470" I 2" 4 13670 - 13718 0 12/20/01 • 2" 4 13760 - 13907 0 12/20/01 1 � �1111 ' •" . /A 10235' 7" X 3 -1/2" BKR HMC HGR, ID = 4.408" /11111 I/ ea 2" 4 13949 - 13980 0 12/20/01 1 1 1 1 1 1 1 1 1 1 10411' --17" X 5 -1/2" BKR PKR, ID = 3.98" I 2" 4 14012 - 14085 0 12/20/01 11111 ••••• 2" 4 14159 - 14264 0 12/20/01 � 1 1 1 1 1 1 1 jj 1 1 10422' I—17" X 5 -1/2" BKR HGR, ID = 3.958" 2" 4 14280 - 14390 0 12/20/01 1 N ••••• ► 1 44„ 11809' CTM I— BKR KB PKR w /2 -7/8" ROCK SCREEN (06/21/09) 1********••• 1 1 1 1 1 1 1 1 1 1 1 1 • 1 1 1 1 • 1 1 • 1 1 • 1 1 • 1 1 4 1 • 1 1 • 1 1 • 1 1 9-5/8" CSG, 47 #, L -80, ID = 8.681" H 5547' 1 1 4 ∎ 4 4.4 4 * • , 11888' CTMD I— OBSTRUCTION - 1 4-1/2" WLEG, ID = ?? H 10232' , UNKNOWN 17" LNR, 26 #, L -80, ® = 6.276" I-1 10567' ` ORIGIN (03/26/07) 15-1/2" LNR, 17 #, L -80, ID = 4.892" H 10840' I3 -1/2" X 15' MARKERJT W /RA TAG I 11075' ' 1 14435' I 1 1 ' 1311D 1 C I 3 -1/2" X 15' MARKER JT W /RA TAG I 12276' • 13-1/2" LNR, 9.2 #, L -80, .0087 bpf, ID = 2.972" I-1 14500' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/31/97 ORIGINAL COMPLETION 06/28/09 DBM/TLH BRK PKR & ROCK SCREEN SET WELL: W -02A 12/23/01 RIG SIDETRACK PERMIT No: 2012140 03/05/05 SRB/TLH POSSIBLE RESTRICTION API No: 50- 029 - 22793 -01 06/25/06 RCT /PJC GLV C/0 SEC 21, T11N, R12E 1192' SNL & 1190' WEL 03/26/07 RLM/PJC OBSTRUCTION © 11888' 10/17/08 CJN/PJC SFTY NOTE UPDATE BP Exploration (Alaska) TREE _ 3IW 4 -1/16" 5M • W-02 B SAS NOTES: WELL ANGLE > 70° @ 11050' VVELLFEAD= 3-3/8" 5M FMC ACTUATOR= NA Proposed CTD sidetrack KB. ELEV = • 8175' Br. ELEV 53.05' KOP= 1150' Max Angle = 99 @ 14416' Datum MD = 10919' I 2221' —14-1/2 FES X NP, D = 3.813" Datum TVD = 8800' SS 13 -3/8" CSG, 68#, L -80, ID= 12.415" I— 3118' J GAS LET MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3131 3024 19 MMG DMY RK 0 01/05/05 Minimum ID = 2.972" @ 10246' 6 3681 3555 12 MMG DOME RK 16 06/25/06 TOP OF 3-1/2" LINER DI 5 5124 4576 52 KBG-2 DMY BK-5 0 01/05/05 4 6894 5845 52 KBG-2 DOME BK -5 16 06/25/06 3 8259 6835 35 KBG-2 DOME BK-5 16 06/25/06 2 9309 7684 38 KBG-2 DOME BK-5 16 06/25/06 4 -1/2" TBG, 12.6#, L -80, .0152 bpf, D = 3.958" 1 10089 8293 41 KBG-2 ORIFICE BK-5 24 01/05/05 i 3845' --I9-5/8" X 7" BKR ZXP PKR, D = 6.290" 1 3858' H9-5/8" X 7" BKR HMC HGR, 13 = 6.300" 9 -5/8" MLLOUT WINDOW (W -02A) 4277' - 4293' 10155' —1 4 -1 /2" HES X NP, D = 3.813" 10176' —17" X 4 -1/2" BKR SABL -3 PKR, D = 3.875" *pa,. 10199' H4-1/2" HES X NP, D = 3.813" I I l k :i 10220' H 4 -1/2" HES XN NP, D = 3.725" * 10221' HTOP OF BKR TIEBACK SLV, ID = 5.25" Top of 2 -3/8" liner and cement @ 10,210' •■ '. 10229' H 7" X 3 -1/2" BKR ZXP PKR, ID = 4.470" I,�'�',� % 10235' H7" X 3-1/2" BKR HMC HGR D= 4.408" -• 7i ∎ ∎ ∎∎ ∎•• •- = :i • •���������♦ ' �� 10411' H7" X 5 -1/2" BKR PKR, ID= 3.98" I 9-5/8" CSG, 47 #, L -80, D = 8.681" H 5547' .�.�.�.�.�.�.�.�. N • 4 -1/2" LEG, = ?? H 10232' Nj W D 10422' H 7" x 5-1/7 BKR HGR, ID= 3.958" • I7" LNR, 26#, L -80, ID= 6.276" —1 10567' 10840' H5 - 1/2" LNR 17 #, L -80, IT.-4.892" TSGR @ 10.825' 3 - 1/2" packer whipstock @ 10,885' I 11809" CTM KB PKR w / ROCK 2 -3/8" liner TD @ 13,926' 1 scR (06 /21/09) il is 3-1/2" X 15' MARKER JT W /RA TAG -1 11075' • 14435' H MID 3-1/2" LNR, 9.2#, L -80, .0087 bpf, 13 = 2.972" H 14500' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/31/97 ORIGINAL COMPLETION 06/28 /09 DBPNTLH BRK PKR & ROCK SCREEN SET WELL: W-02A 12/23 /01 RIG SIDETRACK PERMT No: 2012140 03/05 /05 SRB/TLH POSSBLE RESTRICTION Al I No: 50- 029 - 22793 -01 06/25 /06 RCT/PJC GLV GO SEC 21, T11 N, R12E 1192' SNL & 1190' VVEL 03/26 /07 RLM'PJC OBSTRUCTION @ 11888' 10/17/08 CJN/PJC SFTY NOTE UPDATE BP Exploration (Alaska) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM Choke Friel Standpipe 2" Circulation Line " — • MM 11 et ,.• "'�' Driller Gauge. , M 10 •t • : Manual Choke • ' CIRCU LATING MANIFOLD — • ` MM 8 "° MM 9 MM 20 • . 4 + f MM 22 4 • f SLB Transducer . • i MM 6 • 7- 1/16" 5kpsi BOP " PVT Sensor • Air Blow down _ - � • MM • S . . . u Blind Shears Line ! '• 'Bs Baker Choke am MM 21 °• MM5 'SAS BUS °i • •2" Combi TOT . S. .�. Kill Line P/S i I Rev Cir Line a .... • • c oss -* p ; BOP 24 ` ..� _ _... 4----- Coiled Tubing — �` i* - 2-3/8" Combi ' II - Ba er Choke 2" Combi TOT r MM 1 .... MPt in • MM 13 '+ - •'. .� r I' Kill Line ' Outlet 4--- Cement Line to Ground Mud •tin Vriggi � Pu...s In °°° Tranducers COILED TUBING Choke Line CIRCULATING SYSTEM Cellar Area - _ _ �+�'. • t_ •. HP 14 To Inner Reel Outlets • Valve HP ^0 i HP7 HP3 HP2 HP1 . �. HP1 4 • cement line N2 ( SLB NORDIC'S 2 I Circulate Manifold CHOKE MANIFOLD in Cellar P 11 N2 TriFlowt/} f CM 85 C Gau l ' �.. We - .- CHOKE LINE — Test Pump Inlet — _. J CM3 • HDI Gauge CM18 � Flow f/ HC.. m To TT _ 4Way Block CM14 CMt CM8 To PITS MB CM5 CM6 CM 11 CM 16 IR Baker Choke Line ■oni m Baker Choke Line a from wall HcR POKER CHOKE LINE CM13 _ : ' . , CM7 — - ker Choke Line CM2 — CM19 . — Use for CM 26 CM 29 CM4 CM21 ' ° " " "' e e l M CM20 M —IN : pIMARY El OW P ATH . . ani CM 30 CHOKE LINE CM 75 CM10 MMUS - _ Tige Tank CM 25 a If Outside • I A 0 • Page l of l • A Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art / / or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and I/ operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 DATE: 23- Aug -12 Stephanie Pacillo TRANS #: 6044 Data Delivery Services Technician ., 4,]akanaI( Bender Schiumberger Oilfield Services , o Natural Resources 'rectuuci ,.-tx, II WIRELINF f-!l- 1:3i <:f O1) eY,K Ci.3:-: ( 'c ?11*- '1: r * ?'31 2525 Gambell St, Ste, 400 SCANNED FEB 2 5 2013, ti i -, i; . ' „ . 1 f , - I ,;() t . , , t , ., Anchorage, AK 99503 I : Office: (907) 2734770 .. ;' := Nt it t , SERVICE x r ; 1-:QH ' Rl SERV ;;CM. MECH ° LOG. DESCRIPTION '' DATE B/W COLOR ` C NAME ORDER # DIST DIST DIST DIST LOGGED PRINTS PRINTS G -25B BAUJ -00145 X MEMORY IPROF 25- Jul -12 1 1 CD • E -09C 6C00 -00024 X PPROF /IPROF MCNL 12- Jul -12 1 1 CD G -04B C600-00025 X MEMORY PPROF /IPROF MCNL 10- Jul -12 1 1 CD K -10C _BAUJ -00138 X MEMORY PPROF W/ GHOST 29-Jun -12 1 1 CD V -202 C600 -00031 X MEMORY LDL 22- Jul -12 1 1 CD Z -06A C5XI-00016 X MEMORY PPROF 13- Jul -12 1 1 CD W -02A C5XI -00018 X MEMORY LEAK DETECTION 15- Jul -12 1 1 CD 14 -33A C5XI -00006 X MEMORY PPROF 13- Jun -12 1 1 CD 05 -23B BAUJ -00140 X MEMORY PPROF W/ GHOST 3- Jul -12 1 1 CD H -09 C2JC -00027 X IPROF 23- Jun -12 1 1 CD MPS -01B BZ81 -00021 X PDC CORRELATION 9- Jul -12 1 1 CD MPS -01B BZ81 -00021 _ _ X USIT _ 11-Jul-12 1 1 CD 05 -22B BCRC -00196 X MEMORY PPROF 9- Jul -12 1 1 CD P1 -05 BYS4 -00048 X XFLOW W/ IBP SET RECORD 20-Jun -12 1 1 CD L1 -09 BVYC -00041 X PPROF 16- Jul -12 1 1 CD L1 -21 APBSURVE X PPROF 26- Jun -12 1 1 CD II N -12 APBSURVEEL C -00196 X _ X PPROF _ 19- Jul -12 1 1 CD 05 -22B BCR _ MEMORY PPROF W/ GHOST _ 9-Jul-12 1 1 CD 18 -25A 11996389 X SCMT 13- Mar -08 1 1 CD G -25B BAUJ -00145 X MEMORY PPROF W/ GHOST 24- Jul -12 1 1 CD Z -13A BAUJ -00142 X MEMORY LEAK DETECTION 7- Jul -12 1 1 CD X X ' Please return a signed copy to: Please return a signed copy / to: BP PDC LR2-1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 t\ ,...b' N • • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2.1 900 E. Benson Bbd. Anchorage, Alaska 99508 and ~dl ~~1~-t ~ 1~~t3 ProActive. Diagnostic Services, Inc. Attn:. Robert A. Richey. 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Temperature Survey 12-0ct~08 13-98 1 Color Log / EDE 50-029-20878-00 '~`~~ atic Survey 12~Oct-08 W-O2A Signed Print Name: ~~ .~A .. ~ A EDE Date - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL: ;~~8¢t~:i,''i'Ai~:3~~v~f?3~°S~3i~i''-.;~~ C`J:3'~ WEBSITE:'ib'~~nfd,~3~~i~nfl'a^;~3i1.'~i~a"`i. ' J CiDocumenlsandSettings\Owner\Desktop\Trarvsmit_BP.doc . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate ŒI '. .OthE;!rD WaiverD Ë~'~Ä~¡~~Ef' ,Æ". ,r';: e:,",' :.:"":, :,i'~) !'~" '::;.):. ~'~ (:",~~ Re-enter Suspend~d WE;lltf' 5. Permit to Drill Number: 201-2140 6. API Numbe 50-029-22793-01-00 Measured depth: 11100 -11230,11250 -11360,11380 -11425,11521 -11580,11618 -11786,11840 -11878,12773 -12895 12925 -13105,13319 -13353,13388 -13478,13608 -13655,13670 -13718,13760 -13907,13949 -13980 14012 -14085,14159 -14264,14280 -14390 True vertical depth: 8960.8 - 8986.27,8987.81 - 8986.71,8985.73 - 8983.57,8986.55 - 8988.94,8990.5 - 9006.29,9012.81 - 9015.78 9004.53 - 8999.12,8997.45 - 8991.5,8977.71 - 8974.8,8971.57 - 8965.25,8957.29 - 8954.56,8953.61 - 8950.86 8948.89 - 8939.73,8935.89 - 8933.7,8931.95 - 8927.69,8923.08 - 8914.82,8913.42 - 8901.05 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 26 10232 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10252' -14427' Treatment descriptions including volumes used and final pressure: 241 Bbls 10% HCL, 8% HCL: 2% HF Acid @ 1950 psig Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 0.5 438 1160 0.6 589 0 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Repair Well 0 PluÇJ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 2. Operator Name: 3. Address: 4. Current Well Class: Development Œ:I Stratigraphic D 9. Well Name and Number: W-02A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): ExploratoryD Service D 81.55 8. Property Designation: ADL-0028263 11. Present Well Condition Summary: Total Depth measured 14500 feet 21 t~ true vertical 8884.7 feet ef" f Plugs (mCS{l)~N . ~,,) Effective Depth measured 14435 feet true vertical 8894.3 feet Junk (measured) Casing Conductor Production Surface Length 80 4249 3088 MD TVD 30 110 30.0 - 110.0 28 - 4277 28.0 - 4138.7 29 - 3117 29.0 - 3010.4 Size 20" 94# H-40 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation depth: Packers & SSSV (type & measured depth): 7" Baker ZXP Mech Top Packer 5-1/2" Baker CPH Packer 5" Baker ZXP Top Packer 4-1/2" Baker SABL-3 Packer @ 3845 @ 10411 @ 10222 @ 10176 13 Prior to well operation: Subsequent to operation: Oil-Bbl 370 393 14. Attachments: 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD 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. Contact Garry Catron Printed Name Garry Catron ):1£~ ~~ Title ;( None None Burst 1530 6870 4930 Collapse 520 4760 2270 !.£'"J C.) c:::J C"...J 00 ~ tJ.". iD Ul Z z RBDMS BFl FEB 2i 2005 ~ rr; Tubing Pressure 297 301 DevelopmentŒ) ServiceD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Phone 564-4657 Production Technical Assistant 2/23/05 Signature Form 10-404 Revised 4/2004 0 R \ G \ ¡~ þ~ l Date ) W-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ) 01/20/05 MIRU CTU #5 W/ ASRC TEST UNIT. LOAD IA WITH CRUDE. KILL WELL WITH 163 BBLS OF 3% NH4CL AND 60 BBLS OF CRUDE. INJECTIVITY MEASURED AFTER FLUID PACK. 5 BPM @ 791 PSI, 4 BPM @ 615 PSI, 3 BPM @ 380 PSI. RIH WITH 2" JSN, 2" STINGER, 2" DUAL FLAPPER CHECK AND 1.9" ROLL CONNECTOR. TAG TIE BACK SLEEVE @ 10,228'. UNABLE TO PASS THROUGH. POOH. RECONFIGURE BHA. MU/RIH W/ 2.25" JSN W/2 STINGERS. TAG @ 10252'. JET 10 BBL OF 10% HCL AT TAG. JET TO 10277. PULL UP HOLE, LET ACID SOAK. CONTINUED ON 01/21/05 WSR. 01/21/05 CONTINUED FROM 01/20/05 WSR. SOAK 10 BBL HCL @ 10252-10277'. HARD TAG. JET 20 BBL HCL PILL FROM 10277'-11491' THROUGH VARIOUS BRIDGES OF SCALE. JET 8 BBL HCL PILL FROM 1533-11704'. STICK COIL. JET 20 BBL HCL PILL FROM 11704'- TD @ 14427'. NO SCALE OBSERVED BELOW 12000'. PUMP 173 BBL 10% HCL, 145 BBL 8:2 MUD ACID, 70 BBL DIESEL W/10% U-66, AND 200 BBL NH4CL IN 10 STAGES FROM 14,410' TO 11,000'. FINAL INJECTIVITY 5 BPM @ 980 PSI, 4 BPM @ 915 PSI AND 3 BPM @ 830 PSI. FLUIDS PUMPED BBLS 116 Methanal I Water 411 Crude 424 3% NH4CL 251 100/0 HCL 112 Fresh Water 30 1 % KCL 145 8:2 Mud Acid 70 Diesel wI 100/0 U-66 1559 TOTAL Page 1 "'J;REE';' CIW 4-1/16" 5M -WELLHEAD = 13-3/8" 5M FMC Ä'CTUA T6R ;-------~'-~-"~~ÑA. KB:EL8T;-~-*-_"_~_A'-ã21Š" ï3F'.-"ECE\T-;-.',^'._~_~__'M__- ..5'3:05' KOP = 1150' "Mãx-A"ñgÎë-;'~----"'99(ff144T6¡ "Oâiûm MD.;-"-._~^'-'--~1 0919" "õãilïmïVÖ';"-".~---~'8ãõõ'så r13-3/8" CSG, 68#, L-80,ID= 12.415" l-i 3118' ~ Minimum ID = 2.972" @ 10246' TOP OF 3-1/2" LINER I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 PERFORA TION SUMMARY REF LOG: SWS MEMORY CNL/GR ON 12/19/01 ANGLEATTOPPERF: 76 @ 11100' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 11100 - 11230 0 12/20/01 2" 4 11250-11360 0 12/20/01 2" 4 11380 - 11425 0 12/20/01 2" 4 11521- 11580 0 12/20/01 2" 4 11618-11786 0 12/20/01 2" 4 11840 - 11878 0 12/20/01 2" 4 12773 - 12895 0 12/20/01 2" 4 12925 - 13105 0 12/20/01 2" 4 13319 - 13353 0 12/20/01 2" 4 13388 - 13478 0 12/20/01 2" 4 13608 - 13655 0 12/20/01 2" 4 13670 - 13718 0 12/20/01 2" 4 13760 - 13907 0 12/20/01 2" 4 13949 - 13980 0 12/20/01 2" 4 14012 - 14085 0 12/20/01 2" 4 14159 - 14264 0 12/20/01 2" 4 14280 - 14390 0 12/20/01 ) W-02A SA ) NOTES: WELL ANGLE> 70° @ 11050' AND> 90° @ 11297' I I 2221' 1-i4-1/2" HES X NIP, ID = 3.813" 1 ~ GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT 19 MMG DMY RK 0 12 MMG DOME RK 16 52 KBG-2 DMY BK-5 0 52 KBG-2 DOME BK-5 16 35 KBG-2 DMY BK-5 0 38 KBG-2 DOME BK-5 16 41 KBG-2 SO BK-5 24 DATE 01/05/05 01/05/05 01/05/05 01/05/05 01/05/05 01/05/05 01/05/05 L ST MD 1VD 7 3131 3024 6 3681 3555 5 5124 4757 4 6894 5845 3 8259 6835 2 9309 7684 1 10089 8293 L i 3845' l-i 9-5/8" X 7" BKR ZXP PKR, ID = 6.290" 1 3858' l-t 9-5/8" X 7" BKR HMC HGR, ID = 6.300" 1 J i 9-5/8" CSG SIDETRACK WINDOW 4277' - 4293' (OFF WHIPSTOCK) 10155' 1-14-1/2" HES X NIP, ID = 3.813" 1 I 10176' 1-i7" X 4-1/2" BKRSABL-3 PKR, ID = 3.875" 1 I 10199' 1--14-1/2" HES X NIP, ID = 3.813" 1 I 10220' 1--14-1/2" HES XN NIP, ID = 3.725" 1 10221" I--1TOPOFBKRTIEBACKSLV,ID=5.25" 1 1 0229' 1--17" X 3-1/2" BKR ZXP PKR, ID = 4.470" 1 1 0235" 1--17" X 3-1/2" BKR HMC HGR, ID = 4.408" 1 I 10411" 1-i7"X5-1/2"BKRPKR,ID=3.98" 1 10422" 1-i7" X 5-1/2" BKR HGR, ID =3,958" 1 9-5/8"CSG.47#,L-80,ID=8.681" H 5547' ~ I 4-1/2" WLEG 1-1 10232" I 7" LNR, 26#, L-80, ID = 6.276" 1--1 10567" I 5-1/2" LNR, 17#, L-80, ID = 4.892" 1--1 10840" I 3-1/2" X 15' MARKERJTW/RA TAG l-t 11075" I 3-1/2" X 15' MARKERJTW/RA TAG 1--1 12276" I 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.972" 1-1 14500" 1 DATE 08/31/97 12/23/01 01/05/02 06/18/02 01/05/05 COMMENTS ORIGINAL COM PLETION RIG SIDETRACK CH/TP CORRECTIONS JM!TP GL V C/O LWBITLP MANDREL 1VD CORRECTIONS REV BY 14435" 1-1 PSTD 1 DA TE REV BY COMMENTS PRUDHOE BAY UNIT WELL: W-02A PERMIT No: 2012140 API No: 50-029-22793-01 SEC21, T11N, R12E 1192' SNL & 1190' WEL BP Exploration (Alaska) ;( 3> J~ M(j~ DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2012140 Well Name/No. PRUDHOE BAY UNIT W-O2A Operator BP EXPLORATION (ALASKA) INC 5 ¡2 o.t,J.. '" ~ N a v À~ ( API No. 50-029-22793-01-00 MD 14500 ~ Completion Status 8885 .-- TVD Completion Date 12/23/2001 ,- 1-01L Current Status 1-01L UIC N -- --- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset TYB9 MedlFrmt Number Name "'ÉD ~ Pds -4<f480!rj~4è!i?~~~~$isti\Íity ~~t ~Pds ~48°ci~~Z~~:~S iV~{ t:': C Pdt -r1364 I~ C J.Ø575 J,ED D -14082 I I Log Log Run Scale Media No 1 1 1 1 1 1 Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ...-v-/ N- ~ Daily History Received? Formation Tops Analysis Received? -¥"iN ~ --- ------ _-n__-_-_---- - ----- (data taken from Logs Portion of Master Well Data Maint) ~-- Interval OHI Start Stop CH Received Comments 4200 10840 Open 12/21/2001 4200 1 0840 Open 12/21/2001 10691 14432 Case 9/27/2001 7403 14500 Case 12/3/2002 Digital Well Log Data 9970 14418 Case 1/25/2002 10691 14432 Case 9/27/2001 - --- - - Sample Set Number Comments .--'> ()/N ð/N Comments: N'~ ~ ¡( ~ \) Ao<t [ C ø~ - ~ TrJ'I) i. 'MD ~ L ~ ~~ ~þJv- y.J.. )'-t/- I (J t~ ò .. , Compliance Reviewed By: k Date: ~ :2.1_~ ~--¥- ( 'i( c7? Ù/~d /71 113~i WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 02, 2002 RE: MWD Formation Evaluation Logs: W-02~ AK-MM-11197 W -O2A: Digital Log Images 50-029-22793-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign@C~ c.iho{!:- ----- Date: RECE\VED DEC 0:5 lO02 Alaska O~ & Gas Cons. Commission Anchorage ( t aO/-d)~ ( I o~;t WELL LOG TRANSMITf AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tlt Avenue, Suite 100 Anchorage, Alaska September 26,2002 RE: MWD Formation Evaluation Logs W -02A~ AK-Ml\1-l1197 1 LDWG formatted Disc with verification listing. API#: 50-029-22793-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~'~ Date: RE CE IVED sgp 27 2002 AJaska OH & Gas Cons. Commiasion AnchOl8ge / l STATE OF ALASKA ' ALASKA l,,&... AND GAS CONSERVATION COMMt"'-1 ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-214 301-336 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22793-01 4. Location of well at surface r-" ':',: ',' " ,',~'-' 9. Unit or Lease Name 1192' SNL, 1190' WEL, SEC. 21, T11N, R12E, UM ¡" "', I. lOCAìiQN1 Prudhoe Bay Unit At top of productive interval ~ .i._Z,". '2;'-' 0/ V 39' NSL, 4279' WEL, SEC. 21, T11N, R12E, UM I . .. --'. ' '~...' ~~; 10. Well Number At total depth ;,.::g¿; 1 -..vfit, ~ ~~.. , 1728' NSL, 1896' WEL, SEC. 20, T11N, R12E, UM ~"~.- ,..:~'.:~~:~~ ~t<. < ,..~~\ ' 5 EI f . f t (' d' t KB DF t) 6 L D' f d S . I t..1. ' . 11. Field and Pool . eva Ion In ee In Ica e , , e c. . ease eslgna Ion an ena I'CO. Prudhoe Bay Field / Prudhoe Bay Pool Plan RKB = 81.55' ADL 028263 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/23/2001 12/13/2001 12/23/2001 17. Total Depth (MD+TVD) 18. Plug Back Depth (MO+TVD) 19. Directional Survey 14500 8885 FT 14435 8894 FT IBI Yes 0 No 22. Type Electric or Other Logs Run MWD,RES, GR, DEN, NEU 23. CASING LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 94# L-80 Surface 80' 30" 260 sx Arctic Set lADDrox.) 13-3/8" 68# L-80 32' 3118' 16" 2403 sx CS III, 478 sx Class 'G' 9-5/8" 47# L-80 29' 4277' 12-1/4" 910 sx Class 'G' 7" 26# L-80 3845' 10567' 8-1/2" Not Cemented Unable to Circulate 5-1/2" 17# L-80 10411' 10840' 8-1/2" 105sxClass'G 3-1/2" 9.3# L-80 10222' 14500' 4-3/4" 232 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 11100' -11230' 8961' - 8986' 11250' - 11360' 8988' - 8987' 11380' - 11425' 8986' - 8984' 11521' - 11580' 8987' - 8989' 11618'-11786' 8991'-9006' 11840' - 11878' 9013' - 9016' 12773' - 12895' 9005' - 8999' 12925' - 13105' 8997' - 8992' 13319' - 13535' 8978' - 8962' 27. Date First Production January 16, 2002 Date of Test Hours Tested 1/27/2002 4 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Classification of Service Well W-02A 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2221' MD 1900' (Approx.) AMOUNT PULLED SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 1 0232' PACKER SET (MD) 10176' MD 13388' - 13478' 13608' - 13655' 13670' - 13718' 13760' - 13907' 13949' - 13980' 14012' - 14085' 14159' - 14264' 14280' - 14390' TVD 8972' - 8965' 8957' - 8955' 8954' - 8951' 8949' - 8940' 8936' - 8934' 8932' - 8928' 8923' - 8915' 8913' - 8901' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 155 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD OIL -BBL 3633 OIL-BBL GAs-McF 2722 GAs-McF WATER-BBL 0 WATER-BBL CHOKE SIZE GAS-Oil RATIO 176 749 OIL GRAVITy-API (CORR) 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. RECE IVED FEB 2~' 2002 Form 10-407 Rev. 07-01-80 ."',, " . ("",i ¡ .. r:' '.. i ," .,. ... \, Alaska Oil & Gas Cons. Commission . . MI!IA ¡.u~ì\t:1 .R B 0 M 5 B F l ~td-1AR 5 2ó5~bmì In Duplicate ,III ( I II", 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. Top of Kuparuk 8454' 6997' Top of Miluveach 8581' 7102' Top of Kingak 9271' 7654' TSGR 1 0832' 8824' TSHU 1 0869' 8849' TSHB 10935' 8890' TSHC 1 0970' 8910' TElL 11015' 8932' TSADITZ4B 11094' 8959' ~""';'I ,7""~'~1""", ~"" '" ~-:';I~' Id,:",", l'I' c. H ':'\ ,'"1:'-':'-" -" ¡!jllt~c" "":i~'I"~'I~,"'\,~"¡,--k,',¡'"r]"\,," . ., ,.,,'~ , ,pi ¡!i,""", ~ ~,~I' ,'1"""" If' ,; .' ., ~'^"""'" I"","",:' ("La 9 n r" C j I.J ,Co 20Tì .L(. ,!H,!:tJ4""""O',' 1:) ,." , .'1IQ"l!';t.~ Ii IX l;1:':'"", r "n,' 'r¡" C" . . '.~',,'¡v "~>.' O¡TI'¥W:r;-' Þn"~",.I,....\"..,, "ø, ",~,:,'!On 'lI"NA"'(,'k~fK::: 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Formation Integrity Test 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ J.Jl.l~ Title Technical Assistant W-02A 201-214 301-336 Well Number Permit No. / Approval No. Date ð^"~.D.;\ Prepared By Name/Number: Sandra Stewman, 564-4750 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 (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: W-O2A Common Name: W-O2A T estDàtê 11/22/2001 12/6/2001 .' :Test Type. FIT FIT .'." .. . T êšfQepti\(TMD)' 4,285.0 (ft) 10,840.0 (ft) . . . .i3P EXPL()R~ TION , .. .' '. ~eak~Off . Test $ u m mà ry; . Test Deþth(TYD) 4,150.0 (ft) 8,830.0 (ft) ÄMW 9.50 (ppg) 8.70 (ppg) Suñace Pressure 660 (psi) 550 (psi) leak Off Pressure (BHP) 2,708 (psi) 4,541 (psi) Page 1 of 1 EMW 12.56 (ppg) 9.90 (ppg) .~- Printed: 12/26/2001 8:51 :22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/18/2001 11/19/2001 11/20/2001 11/21/2001 II" ( {t'" " BP EXPLORATION Operations Summary Report W-02A W-02A REENTER+COMPLETE NABORS NABORS 9ES 00:00 - 21 :00 From - To Hours Activity Code NPT 21 :00 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 14:30 14:30 - 20:30 20:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 03:00 03:00 - 04:00 04:00 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 10:30 10:30 - 12:30 12:30 - 13:00 13:00 - 15:00 15:00 - 00:00 00:00 - 03:00 03:00 - 06:30 21.00 MOB P 3.00 RIGU P 1.50 RIGU P 1.00 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 11.00 CLEAN P 6.00 CLEAN P 2.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 3.00 CLEAN P 1.00 WHSUR P 2.00 WHSUR P 2.00 BOPSUF P 0.50 BOPSUF P 2.00 BOPSUF P 2.00 PULL P 0.50 PULL 2.00 PULL P P 9.00 PULL P 3.00 PULL P 3.50 BOPSUF P Phase PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 1 of 11 Start: 11/18/2001 Rig Release: 12/23/2001 Rig Number: Spud Date: 11/19/2001 End: 12/23/2001 Description of Operations Move Shop, Pits & Camp. Jacking pressures higher than anticipated - unable to lift D/S off ground. Lay down 40 stands DP from Derrick ( left 45 stds. in derrick). Jack up rig & check pressures - Jack rig down & remove DC's and HWDP from shed. Jack rig up - pressures OK. Move rig & spot on W-02A. Spot Pits, Camp & Shop. Rig up interconnect. Ready to take on fluid at 24:00 Hrs. Accept Rig. Take on 8.9 ppg Brine. RlU secondary choke & Kill lines RlU DSM. Pull BPV. 500 psi on tbg. 500 psi on annulus. Rig up line from tree top to choke manifold. PJSM with all personnel. Fill all lines & test to 3500 psi. Bleed gas off annulus & tbg. Both bled to 0 psi. Pump dn ann. - displaced diesel from tbg. Pump dn tbg. - no returns after 15 bbls. Pres up to 1500 psi. Attempt to pump dn ann - no returns. again dn tbg - partial returns from annulus. Cont. pumping- getting Asphaltines back - plugging lines. Hook up Hot oiler. Pump heated brine dn tbg. Returns to cuttings tank - heavily contaminated with black tar like asphaltines.. Shut dn rig pump. PJSM w/ Hot oiler. Pump dn tubing w 190 deg brine taking returns to the Hot oiler. Pump 2.3 bbll min. for 2 complete circulations. Brine still heavily contaminated. Bullhead 17 bbls 190 Deg brine followed by 40 bbls 180 deg. diesel down annulus. Displace with brine to spot diesel just above lower GLM. Shut in - allow diesel to migrate up annulus Pump down tubing and up annulus w/ clean brine taking contminated returns to cuttings tank. Circulate long way until clean. Shut dn and monitor well - losses 10 bbls / Hr. Blow down lines. RlU DSM. Install TWC. Pump down annulus w/ 800 psi - no flow to tree. R/D DSM N/D Tree & Adapter flange. Check Hanger. N/U double studded adapter flange & BOP. Close Hydril and do shell test: 250 psi. - low, 3500 psi - High RlU Tubing tongs. P/U and M/U lubricator extensions and sub for pulling TWC through offset Hanger. Pull same & RID lubricator. P/U landing jt. M/U safety valve. Screw into Hanger. B.O.L.D.S. Pull Hanger above floor. 95 K Up Wt. PJSM wih Centrilift hand and all personnel. RlU ESP cable sheave & elephant trunk. Feed pullover line through sheave Back out landing jt. POH & LID 4.5" Tubing & ESP cable. PJSM. disconnect ESP cable, attach pullover rope and spool cable. lost only 1 SS band. Perfs taking 9 bbls / Hr. PJSM w/ Centrilift. Break down and LID pumps and motor. RID cable sheave and elephant trunk. Clear floor of all tools and equip. Test BOPE: 250 psi - Low, 3500 psi High. Witness waived by Chuck Sheve, AOGCC. Printed: 12/26/2001 8:51 :32 AM . (' " ~" '. BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: W-O2A Common Well Name: W-02A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 11/18/2001 End: 12/23/2001 Contractor Name: NABORS Rig Release: 12/23/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/21/2001 06:30 - 08:00 1.50 CLEAN P DECOMP M/U & RIH wI BHA #1 - bit & scraper. 08:00 - 12:30 4.50 CLEAN P DECOMP RIH, P/U 4" DP. Wash down last 5 Jts. Tag Pkr @ 4438'. 12:30 - 14:00 1.50 CLEAN P DECOMP Circulate Hi-Vis sweep. 14:00 - 17:00 3.00 CLEAN P DECOMP POH. UD scraper & bit. 17:00 - 19:30 2.50 PXA P DECOMP RlU SWS E-Line. RIH wI EZSV. Correlate & set w/top @ 4295' WL depth. POH & RID SWS. 19:30 - 20:00 0.50 PXA P DECOMP Test EZSV Packer & 9 5/8" Casing to 3500 psi for 30 minutes. 20:00 - 00:00 4.00 PXA P DECOMP M/U Baker 8.525" Watermelon casing mill above EZSV cement stinger and RIH. 11/22/2001 00:00 - 01 :00 1.00 PXA P DECOMP RIH with cmt stinger to EZSV. MU head pin & cementing hose. 01 :00 - 01 :30 0.50 PXA P DECOMP Sting in to retainer at 4301' DPM and establish inj rate 4 BPM @ 980 psi. 01 :30 - 01 :45 0.25 PXA P DECOMP Safety meeting with crew & service Co personnel. 01 :45 - 03:30 1.75 PXA P DECOMP Close annular and pressure ann to 1000 psi. RU cementers. Pump 5 bbl H2O & test lines to 4000 psi. Pump 5 H2O followed by 102 bbl Class G w/additives at 15.8 ppg. Displace cement with 42 bbl water at 3.4 BPM @ 560 psi. Reduce rate to 2.1 BPM @ 500 psi. 03:30 - 04:00 0.50 PXA P DECOMP Unsting from retainer and reverse out 1.5 DP vols 8 BPM @ 1350 psi to clear cmt from top of retainer and DP. Test retainer to 3500 psi for 5 min - OK. 04:00 - 04:30 0.50 PXA P DECOMP RD cementers. Pump pill. Blow down top drive. 04:30 - 06:30 2.00 PXA P DECOMP POH with DP. LD mill and cement stinger. 06:30 - 07:30 1.00 PXA P DECOMP Slip & cut 75' drilling line. 07:30 - 07:45 0.25 STWHIP P WEXIT PJSM for PU whipstock & mills. 07:45 - 10:00 2.25 STWHIP P WEXIT MU window mills & MWD. PU whipstock & pin to mill assembly. Orient whipstock face to MWD scribe line. MU UBHO & bumper sub. 10:00 - 11 :30 1.50 STWHIP P WEXIT RIH 9 x 61/2" DC's and 18 x 4" HWDP. 11 :30 - 14:00 2.50 STWHIP P WEXIT RIH with 4" DP - slow. Stop 2 stands above EZSV. 14:00 - 14:30 0.50 STWHIP P WEXIT Orient whipstock face to 60L. RIH and set down on EZSV. Set anchor wI approx 15klbs down and shear off whipstock wI approx 35 klbs down. Final whipstock orientation 53L & TOW @ 4277' MD. 14:30 -15:30 1.00 STWHIP P WEXIT Displace wellbore wI 9.5 ppg. LSND Mud @ 11 BPM - 1350 psi. 15:30 - 22:30 7.00 STWHIP P WEXIT Mill window in 9 5/8" Casing from 4277' to 4293' and open hole to 4312'. Pump Hi Vis on last 4 ft. milled. Work mills through window - no problems. 22:30 - 23:00 0.50 STWHIP P WEXIT Pull up above window and perform FIT to 12.56 ppg. EMW. 23:00 - 00:00 1.00 STWHIP P WEXIT Pump slug. POH 11/23/2001 00:00 - 01 :30 1.50 STWHIP P WEXIT POH wI 4" DP 01 :30 - 03:30 2.00 STWHIP P WEXIT Stand back HWDP. LID BHA. Upper Mill inguage. 03:30 - 04:00 0.50 STWHIP P WEXIT M/U Jetting tool on jt of DP. Function all Rams - Flush Stack. 04:00 - 06:00 2.00 DRILL P INT1 M/U BHA #4. Orient. RIH Test MWD. 06:00 - 08:30 2.50 DRILL P INT1 RIH to 4187'. Orient to 53 deg L. Shut down pumps and slide through window. to 4300' Ream from 4300' to 4312' 08:30 - 00:00 15.50 DRILL P INT1 Directional Drill from 4312' to 5215'. 530 GPM @ 2200 psi. TQ - = 3.5 to 4 K. P/U = 124K SID = 110K ROT = 119K ART = 2 Hrs. AST = 7.5 Hrs. 11/24/2001 00:00 - 13:30 13.50 DRILL P INT1 Drill 8 1/2" directional Hole from 5215' to 6239'. P/U = 138K Slo = 116K ROT = 122K Printed: 12/26/2001 8:51 :32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/24/2001 11/25/2001 11/26/2001 11/27/2001 11/28/2001 (' \' BP EXPLORATION Operations Summary Report W-02A W-02A REENTER+COMPLETE NABORS NABORS 9ES 00:00 - 13:30 From - To Hours Activity Code NPT 13:30 -14:30 14:30 - 17:00 17:00 -18:00 18:00 -19:30 19:30 - 00:00 00:00 - 05:30 05:30 - 07:30 07:30 - 19:30 19:30 - 20:30 20:30 - 23:00 23:00 - 00:00 00:00 - 00:00 00:00 - 19:30 19:30 - 21:00 21 :00 - 22:30 22:30 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 02:30 02:30 - 04:00 04:00 - 09:30 09:30 - 11 :00 11 :00 - 16:00 16:00 - 19:30 19:30 - 21:30 13.50 DRILL 1.00 DRILL 2.50 DRILL 1.00 DRILL 1.50 DRILL 4.50 DRILL 5.50 DRILL 2.00 DRILL 12.00 DRILL 1.00 DRILL 2.50 DRILL 1.00 DRILL 24.00 DRILL 19.50 DRILL 1.50 DRILL 1.50 DRILL 1.50 DRILL 0.50 DRILL 1.50 DRILL 0.50 DRILL 1.50 DRILL 5.50 DRILL 1.50 DRILL 5.00 DRILL 3.50 DRILL 2.00 DRILL p p p p P P P N P p p P P p p P P P P P P P p P p p RREP INn INT1 INT1 INT1 INT1 INT1 INT1 INT1 INn INT1 INT1 INT1 INT1 INT1 INn INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Page 3 of 11 Start: 11/18/2001 Rig Release: 12/23/2001 Rig Number: Spud Date: 11/19/2001 End: 12/23/2001 Phase Description of Operations TO = 3.5K to 5K 535 GPM @ 2700 psi. ART = 5.5 Hrs AST = 3.5 Hrs. Circulate Hi - Vis sweep. Wipe to Window @ 4277'. 15K to 45K Tight @ 5905',5850',5620',5100',4985'. Worked through all twice - OK. Service Top Drive, Crown, Draworks. Change out Saver Sub. Orient Tool Face & RIH to 6147'. Break circ & ream to bottom @ 6239'. Drill from 6239' to 6612'. P/U = 142K SIO = 117K ROT = 128K TQ = 4K to 5.5K. 535 GPM @ 2740 psi Drill from 6612' to 7032'.535 GPM @ 2900 psi. P/U = 150K SIO = 118K ROT = 129K #1 SCR went down. Change out Blower in SCR #1. Drill from 7032' to 8013' 535 GPM @ 3240 psi. P/U = 166K SIO = 127K ROT = 143K Circulate clean & weight up to 10.7 ppg. Wiper trip to 6137'. Tight @ 6800' & 6700'. Worked through- OK. Run back in hole to 7919'. Wash to bottom @ 8013' Drill from 8013' to 8106'.535 GPM @ 3740 psi. P/U = 167K SIO = 127K ROT = 141K Total for Day - AST = 6.3 Hrs. ART = 6.3 Hrs. Drill 8 1/2" Directional Hole from 8106' to 9539'.535 GPM @ 3950 psi. TQ = 9K to 9.5K. P/U = 200K SIO = 137K ROT = 161K 70 RPM WOB = 7K to 15K Hi Vis sweep every 250 to 300 ft. AST = 5 Hrs. ART = 11.8 Hrs. Cont drill ahead 8112 hole drctnl, 9539 - 10722 ft. Circ for samples as per Geologist. Target formation not found. Resume drlg 10722 - 10817 ft. AST = 5.9 hrs, ART = 9.8 hrs WOB 12, RPM 70, SPM 212, GPM 515, Press 3900, Tq 9,000 Up 240, Dn 144, Rot 175 90 ft survey intervals, Sweeps at 300 ft intervals Hole good cond, no abnormalties. Circ for samples as per Geologist. Target formation not found. Drill to 10830'. Circ up sample for geologist. Drill to 10840'. Circ up another sample. Saw Sag R sand in sample and call TO wI est TSAG at 10826' MD. Wiper trip to window. Work thru tight spots at 10560, 10545, 9975, 8667, 8590, 5585. Cont POH above window. Cut drilling line. Service top drive. Orient motor and exit window. RIH. Work thru tight spots. Kelly up & washlream thru tight areas at 9250' and 10450'. MU top drv at 10724, circ I cond, shakers blinding. Wash 1 ream to btm at 10840 ft. No fill. Pump hi-vis sweep, spot liner pill, flow check. Printed: 12/26/2001 8:51 :32 AM ~":'" J . ( BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: W-O2A Common Well Name: W-02A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 11/18/2001 End: 12/23/2001 Contractor Name: NABORS Rig Release: 12/23/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/28/2001 21 :30 - 00:00 2.50 DRILL P INT1 Commence poh for 7" liner. 35K overpull at 10550, 9925 ft. Pump wt pill, resume poh (SLM) no swabbing I with normal drag. 11/29/2001 00:00 - 03:30 3.50 DRILL P INT1 Cont poh for 7" liner. Normal drag, no swabbing I sticking. 03:30 - 05:00 1.50 DRILL P INT1 Flow check, layout bha I drctnl assy. 05:00 - 05:30 0.50 DRILL P INT1 Clear rig floor drlg equip. 05:30 - 07:30 2.00 CASE P LNR1 Change to 7" rams, test door seals 250 I 3500 10 min. Test successful. Re-install wear bshg. 07:30 - 08:00 0.50 CASE P LNR1 PJSM liner Operation. Rig up for liner run. 08:00 - 09:00 1.00 CASE P LNR1 Make up float equip 1 shoe track, test same. 09:00 - 15:00 6.00 CASE P LNR1 Follow shoe track with 7" liner, 26#, L80, IBT mod, to 9 5/8 window, filling at 5 jt intervals. 15:00 - 16:00 1.00 CASE P LNR1 Circ liner volume, make up cmt hd. 16:00 - 18:00 2.00 CASE P LNR1 Flow check, cont rih 7" liner to 6699 ft. 18:00 - 00:00 6.00 CASE P LNR1 MU liner hgr I packer, and run tool. Rih 4" dp to 9100 ft. Taking wt at 9100 ft. Circ, work pipe. Attempt poh. No upward movement possible. Hole packed off, no returns. Continue work pipe, regain downward movement. Cont rih, filling pipe and hole, but no circulation. Still no upward movement possible. Cont in this manner to 10400 ft, slow - steady progress. 11/30/2001 00:00 - 11 :00 11.00 CASE P LNR1 Cont. work I recip, 7" liner 10400 - 10557 ft. No further progress. 11 :00 - 11 :30 0.50 CASE N STUC LNR1 Inspect dwks. Sheared bolts on brakes. 11:30-14:00 2.50 CASE N STUC LNR1 Back out 7" hgr run tool. Poh with run tool for 6 1/6 clean out bha. 14:00 - 15:00 1.00 CASE N STUC LNR1 Flow check. Handle bha #4, layout same. Break out liner run tool. 15:00 - 16:30 1.50 BOPSUF P LNR1 Change to variable rams, install test plug. 16:30 - 19:30 3.00 BOPSUF P LNR1 Commence test bope ( Witness waived by Jeff Jones - AOGCC) Test rams 250 I 3500 psi 15 min. Test annular 250 13000 psi 15 min. Choke I kill 250 I 3500 psi 15 min Standpipe I top drv to pumps 250 I 3500 psi 15 min Floor valves, all related safety equip 250 I 3500 psi 15 min. Accumulator volume I press test as per BP specs. All tests successful. No leaks Ire-tests. 19:30 - 21:00 1.50 CASE P LNR1 Slip I cut drlg line. Service top drive. 21 :00 - 22:30 1.50 CASE N STUC LNR1 Make up bha #5 ( 6 1/8 bit 14314 DCs ), rih same for drill out 7" float equip. I clean out. 22:30 - 00:00 1.50 CASE N STUC LNR1 Follow bha with 4" dp to 1800 ft. 12/1/2001 00:00 - 04:00 4.00 CASE N STUC LNR1 RIH with 6 1/8" cleanout bit. 04:00 - 06:00 2.00 CASE N STUC LNR1 Drill out landing collar at 10471', float collar at 10512' and shoe at 10557'. 06:00 - 09:30 3.50 CASE N STUC LNR1 Clean out open hole below shoe. Appeared to be an obstruction (cuttings/debris?) just below shoe. Clean out same and washlream cautiously down to TD at 10840'. Easy reaming with only minimal packing off. 09:30 - 11 :00 1.50 CASE N STUC LNR1 Pump viscosified sweep around & brought back significant amount of cuttings but not splintery as if unstable shale. 11 :00 - 12:00 1.00 CASE N STUC LNR1 Short trip up to 7" shoe - OK. RIH to bottom. No problems. No Printed: 12/26/2001 8:51 :32 AM (' ~ BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: W-02A Common Well Name: W-02A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 11/18/2001 End: 12/23/2001 Contractor Name: NABORS Rig Release: 12/23/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/112001 11 :00 - 12:00 1.00 CASE N STUC LNR1 fill. 12:00 -15:30 3.50 CASE N STUC LNR1 Circ, pump wt sweep, recip pipe. Spot liner pill. 15:30 -19:30 4.00 CASE N STUC LNR1 Flow check, prepare and poh for 5 1/2 liner. Open hole section good condition. 19:30 - 21:00 1.50 CASE N STUC LNR1 Handle bha, layout bha #5. 21 :00 - 22:30 1.50 CASE N STUC LNR1 Clear floor, place 5 1/2 run equip on floor, rig up same. 22:30 - 00:00 1.50 CASE N STUC LNR1 Make up 5 1/2 float equip, shoe track. Check floats, follow with 51/2, STL, 17#, flush jt csg. to 800 ft. 12/2/2001 00:00 - 01 :30 1.50 CASE N STUC LNR2 Finish PU 10 jts 5 1/2" STL liner + hanger and liner top packer. 01 :30 - 02:00 0.50 CASE N STUC LNR2 RD casing tongs & clear floor. 02:00 - 03:00 1.00 CASE N STUC LNR2 RIH with HWDP. Circ DP + liner vol. 03:00 - 06:00 3.00 CASE N STUC LNR2 RIH with 5 1/2" liner on 4" DP. Run v. slow 4+ minlstd once liner hanger inside 7" liner. Took weight with shoe at 5320'. 06:00 - 07:45 1.75 CASE N STUC LNR2 Work cautiously down to 5720' shoe depth and then no further progress. Acts as if junkldebris alongside hanger/packer. PU clean. PUH to 5632' shoe depth & still takes wt going back down as if dragging junk alongside liner or hanger/packer assembly. 07:45 - 09:45 2.00 CASE N STUC LNR2 POH slow. Lost 2000# drag at 5300' as if junk fell off. Try going down again but takes wt at 5310'. Cont POH slow and position 5 1/2" liner hangerlpacker above 7" liner top at 3845'. 09:45 - 10:00 0.25 CASE N STUC LNR2 Circ at 3.5 bpm at top of 7" liner and attempt to circ debrisljunk up into 9 5/8" casing. 10:00 - 10:15 0.25 CASE N STUC LNR2 Try to RIH with liner but 5 1/2" hanger won't go below 7" liner hanger. Bottom of 5 1/2" hanger is at bottom of tieback sleeve on 7" hanger. Possibly junk now lodged in 7 " hanger or a slip has partially set on the 5 1/2" hanger assembly. No further progress. 10:15 -12:00 1.75 CASE N STUC LNR2 Discuss situation with Anch DE and agree to POH & LD liner & make cleanout trip. Cont recip I work I circ during discussion. Hgr will not pass obstruction. 12:00 - 14:30 2.50 CASE N STUC LNR2 Poh, stand back hwdp. 14:30 - 18:00 3.50 CASE N STUC LNR2 Flow check. Lay dn 5 1/2 liner. Break thread locked shoe track. Layout same. Rig dn 5 1/2 run equip. Clear floor. 18:00 - 20:30 2.50 CASE N STUC LNR2 Make up bha #6 ( 7" scraper assy ), rih same. 20:30 - 21 :30 1.00 CASE N STUC LNR2 Follow bha with 4" dp to 7" liner top. 21 :30 - 23:00 1.50 CASE N STUC LNR2 Circ over liner top with sweeps. Recover sands, polymers, "gunk" at surface. Cont circ shakers clean. 23:00 - 00:00 1.00 CASE N STUC LNR2 Flow check. Resume rih 7" scraper to 4200 ft. Slow going, tight clearance. 12/3/2001 00:00 - 04:00 4.00 CASE N STUC LNR2 Cont rih 7" csg scraper I boot bskts. 04:00 - 05:30 1.50 CASE N STUC LNR2 Circ sweep at 7" liner shoe 10555 ft. Barofibre, sand, shale returns. 05:30 - 06:30 1.00 CASE N STUC LNR2 Wash I ream 10665 - 10840 td. No fill. 06:30 - 08:00 1.50 CASE N STUC LNR2 Circ sweep at 10840, 450 gpm. Shaker clean. 08:00 - 10:00 2.00 CASE N STUC LNR2 Wipe hole to shoe, work past obstruction at 10833 ft, cont to btm at 1 0840 ft. 10:00 - 13:00 3.00 CASE N STUC LNR2 Flow check, poh for gauge ring/JB on E- line. 13:00 - 15:00 2.00 CASE N STUC LNR2 Circ well clean at 6940 ft. Approx 80% Barofibre, 20% sand & Printed: 12/26/2001 8:51:32AM '. \c BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: W-02A Common Well Name: W-02A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 11/18/2001 End: 12/23/2001 Contractor Name: NABORS Rig Release: 12/23/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/312001 13:00 -15:00 2.00 CASE N STUC LNR2 shale returns. 15:00 -16:00 1.00 CASE N STUC LNR2 Flow check, poh to top of 7" liner @ 3840'. 16:00 - 17:00 1.00 CASE N STUC LNR2 Circ hi-vis sweep @520 GPM. Got back mostly fibre from sweep wI minor amt shale & sand. 17:00 - 18:30 1.50 CASE N STUC LNR2 Flow check, pump wt pill, poh to bha. 18:30 - 20:30 2.00 CASE N STUC LNR2 Handle bha, stand back hwdp, layout scraper & junk baskets. No junk & very little cuttings in boot baskets. 20:30 - 23:00 2.50 CASE N STUC LNR2 PJSM, ( Wireline Work ), RU wireline - junk bskt - gauge ring 6.05" CD. RIH same to 10440' WLM. Encounter no obstruction. Poh, lay dn equip, inspect contents junk bskt. No debris. Layout wireline equip, release unit. 23:00 - 00:00 1.00 CASE N STUC LNR2 Prepare run 5 1/2 liner, rig up rig floor. 12/4/2001 00:00 - 00:30 0.50 CASE N STUC LNR2 Assemble float equip, rih test same. 00:30 - 01 :30 1.00 CASE N STUC LNR2 Make up 5 1/2 liner hgr I pkf assy, rih. 01 :30 - 02:00 0.50 CASE N STUC LNR2 Follow liner with 4" dp top 7". 02:00 - 02:30 0.50 CASE N STUC LNR2 Circ top of liner. 02:30 - 13:00 10.50 CASE N STUC LNR2 Flow check, resume rih 4" dp to 10420 ft. 13:00 - 14:30 1.50 CASE N STUC LNR2 Circ I cond mud in preparation for open hole. 14:30 -17:00 2.50 CASE N STUC LNR2 Rih slowly to 10613 ft, at which point begin taking wt. 3 - 7000 Ibs. 17:00 - 19:30 2.50 CASE N STUC LNR2 Wash to btm at 10840 ft. Taking wt entire section. Cont circ I condo 19:30 - 21:00 1.50 CASE P LNR2 Commence cmt 51/2 liner per program as follows: Pump 5 bbls CW 100 Test lines 3500 psi 110 min. Test successful. Pump 5 bbls CW 100 Pump 22 bbls batch mixed, 15.8 ppg, "G", neat slurry. Release plug, displace with 1 06 bbls drlg fluid. Bump plug with correct displacement, 550 psi fcp, build to 3300 psi to set hgr. Check floats. Plug bumped I cmt in place 2100 hrs - 11/04/2001. 21 :00 - 21 :30 0.50 CASE P LNR2 Release run tool, set pkr. 21 :30 - 22:30 1.00 CASE P LNR2 Sting out of pkr, circ possible excess cmt from well bore. Note no cmt returns at surface. 22:30 - 00:00 1.50 CASE P LNR2 Poh 4" dp for 7" pkr set bha. 12/512001 00:00 - 01 :30 1.50 CASE P LNR2 Cont poh 5 1/2 liner run tool to 3845 ft. 01 :30 - 02:00 0.50 CASE P LNR2 Circ well clean at 7" liner top. 02:00 - 04:00 2.00 CASE P LNR2 Resume poh, layout liner run equip. 04:00 - 06:00 2.00 CASE N STUC LNR2 MU 4 3/4 bha with 7" pkr set tool, follow with 7 stds 4" dp. 06:00 - 07:30 1.50 CASE P LNR2 Slip I cut drlg line, service top drive. 07:30 - 09:00 1.50 CASE N STUC LNR2 Resume rih 4" dp to 3845 ft, sting in 7" pkr bore, and set same with 50,000 dn wt. 09:00 - 11 :00 2.00 CASE P LNR2 PJSM ( Press Test) Test 7 X 5112 to 3000psi 130 min. Test 2000 psi dn dp X 2000 psi dn 9 5/8 X 7 annulus 130 min. Test 9 5/8 X 7 X 5 1/2/3000 psi /30 min. All tests successful, no re-test. 11 :00 - 13:00 2.00 CASE N STUC LNR2 Poh to hwdp, flow check. 13:00 - 15:00 2.00 CASE N STUC LNR2 Lay dn bha I pkr set tools. 15:00 - 16:00 1.00 CASE P LNR2 Place bha, 2 7/8 run tools on rig floor. Make up top drv saver sub. 16:00 - 18:30 2.50 CASE P LNR2 Install Sperry Sun transducer on dwks. PU motor, LWD, MU bit, PU MWD. f ~.cc Printed: 12/26/2001 8:51 :32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/5/2001 12/6/2001 12/7/2001 12/8/2001 c r ~~ '- BP EXPLORATION Operations Summary Report W-02A W-O2A REENTER+COMPLETE NABORS NABORS 9ES From - To Hours Activity Code NPT 16:00 -18:30 18:30 - 21:00 21 :00 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 06:30 06:30 - 07:00 07:00 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 16:00 16:00 -19:30 19:30 - 21:00 21 :00 - 23:00 23:00 - 00:00 00:00 - 19:00 19:00 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 00:00 00:00 - 03:30 03:30 - 04:30 04:30 - 06:30 06:30 - 08:30 08:30 - 12:00 12:00 - 12:30 12:30 - 16:30 16:30 -19:30 2.50 CASE 2.50 CASE 1.50 CASE 0.50 CASE 1.00 CASE 6.50 CASE 0.50 CASE 2.50 CASE 0.50 CASE 0.50 CASE 5.50 CASE 3.50 CASE 1.50 CASE 2.00 CASE 1.00 CASE 19.00 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 3.00 DRILL 3.50 DRILL 1.00 DRILL 2.00 DRILL 2.00 DRILL 3.50 DRILL 0.50 DRILL 4.00 DRILL 3.00 DRILL P N P P P P P P P P P P P P P P P P P P P P P P P P P P Phase LNR2 MISC LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 7 of 11 Start: 11/18/2001 Rig Release: 12/23/2001 Rig Number: Spud Date: 11/19/2001 End: 12/23/2001 Description of Operations Lay dn locking collar, dismantle, repair. Resume MU bha #7. Connect and load mwd. Make up remainder bha, rih same. Shallow test MWD I LWD, 44 spm, 2190 psi, 130 gpm. Signals transmitting and receiving. PU 2 7/8 dp from pipe shed. Cont PU 2 7/8 dp, rih. Fill and circ dp volume, check for plugged pipe. Circ 100% Follow 2718 with 4" dp to 10550 ft. Change out Sperry encoder. Wash to 10614 ft, tag hard cmt. Test all strings csg 3000 psi I 30 min. Test successufl. No re-test. Drill cmt, float, shoe track to guide shoe at 10839 ft. Pump sweeps, open PBL, displace well with 8.7 ppg quickdrill @ 4.5 gpm. Close PBL. Drill guide shoe I 20 ft new formation. Lost signal from MWD at this time. LWD signal OK. Signal became intermittent. LWD still OK. Flow check. Circ I clean wellbore for FIT. Perform FIT inside 5112 csg. Results = (550 psi, 9.9 ppg emw.) Did not break down. Drld f/10,860' to 11,143'. PU: 175k; SO: 130k; Rot: 155k; Consistent 110 gpm while drlg. Pumped sweeps every 200'. Wipe 90' @ each connection wI 140 gpm wI 45 rpm.MWD signals erratic. Last 7 hrs drlg spent 1.5 hrs taking surveys. AST: 10.4 hrs; ART: 1 hr. Fire Drill: OS-1 :55 min D1 Drill: OS-1 :20 min Lost MWD signal. Attempt to regain signal wI no success. Circ Hi Vis sweep up into 7" @ 140 gpm. Monitor well. POH to 5.5" liner top wI PBL. Drop ball to open PBL wI no indication of opening. Drop emergency ball wI no indication of opening. Continue to pump sweep out of hole @ 140 spm. Flow check, poh 4" dp for downhole tool malfunction. ( MWD ) Slow going, wet string. Pull 7 stds 2 7/8 dp. Pump hi-vis sweep at 7" liner top. Flow check, resume poh 2 7/8 dp. Handle bha #7, layout drctnl tools. Disassemble pbl sub. Clear rig floor. Pull wear bshg, set test plug. Prepare and test bope as follows Rams, blinds and pipe 250 I 3500 psi 15 min. Annular, 250 I 3500 psi 15 min. Choke and kill system 250 / 3500 psi 15 min. Standpipe to pumps I all valves 250 I 3500 psi Floor safety valves 250 13500 psi 15 min. Accumulator system volume I press test. All tests successful, no re-tests. Test witnessed by Chuck Sheve AOGCC Flow check. Make up bha #8 rih same. 15 min. Printed: 12/26/2001 8:51 :32 AM " , BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: W-02A Common Well Name: W-02A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 11/18/2001 End: 12/23/2001 Contractor Name: NABORS Rig Release: 12/23/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/8/2001 19:30 - 20:00 0.50 DRILL P PROD1 Shallow test drctnl tools. 130 gpm @ 1284 psi. Tools functioning. 20:00 - 00:00 4.00 DRILL P PROD1 Flow check, follow bha with 4" dp. 12/9/2001 00:00 - 02:30 2.50 DRILL P PROD1 Cont rih 4" dp to 11080, filling at 7820 and 10800 ft. 02:30 - 03:00 0.50 DRILL P PROD1 Break circ at 11080 ft, orient, survey, wash to btm at 11143 ft. No fill, down drag. 03:00 - 18:00 15.00 DRILL P PROD1 Commence drill ahead 4 3/4 hole drctnl, 11143 - 11666 ft. 18:00 - 20:00 2.00 DRILL N DFAL PROD1 Trouble shoot signal loss MWD, stand back one std dp, signal returns. 20:00 - 00:00 4.00 DRILL P PROD1 Flow check, resume drlg 11666 - 11800 ft. WeB 5, RPM 40, SPM 60, GPM 150, PRESS 2130, Tq on 5.4, tq off 4.8 Up 179, Dn 135, Rot 155 AST = 8.75 hrs, ART = 2 hrs 12/10/2001 00:00 - 03:30 3.50 DRILL P PROD1 Cont drill ahead 4 3/4 drctnl hole, 11800 - 11981 ft. 03:30 - 05:00 1.50 DRILL N WAIT PROD1 Wait on survey results Sperry Sun. Info being transmitted from Anchorage server. Can not drill ahead blind, no surveys. 05:00 - 09:00 4.00 DRILL P PROD1 Resumedrlg 11981-12175ft. 09:00 - 10:30 1.50 DRILL N DFAL PROD1 Lost signal MWD, troubleshoot I exhaust all possible causes. Pump water flush. 10:30 - 00:00 13.50 DRILL P PROD1 Regain signal, resume drlg 12175 - 12674 ft. No hole problems, parameters stable, no connection difficulties. WeB 5, RPM 70, GPM 150, PRESS 2300, TO 5000 AST = 3.5 hrs, ART = 8.25 hrs Up 185, Dn 136, Rot 158 12/11/2001 00:00 - 10:00 10.00 DRILL P PROD1 Drill 4 3/4" Directional Hole from 12,674' to 13,048'. 150 GPM @ 2250 psi. TQ = 5.6K PIU = 188K SIC = 136K ROT = 159K AST = 3.5 Hrs. ART= 2.5 Hrs. 10:00 -13:00 3.00 DRILL P PROD1 Circulate weighted sweep 13:00 - 14:30 1.50 DRILL P PROD1 Wipe to 5" shoe 10, 840'. Some intermittent tight spots from 12,470' to 11,130'. 20 to 30 K overpull. wiped through - OK. 14:30 - 16:00 1.50 DRILL P PROD1 Cut & Slip drilling line. Service TID, brakes, Blks & crown. 16:00 -18:00 2.00 DRILL P PROD1 RIH. Take wt @ 12,613'. Turn 180 Deg. - wipe through - OK. Wash last stand to bottom. 18:00 - 00:00 6.00 DRILL P PROD1 Drill 4 3/4" Directional Hole from 13048' to 13221' . 150 GPM @ 2290 psi. TO = 5.1K AST = 2 Hrs ART = 1.5 Hrs 12/12/2001 00:00 - 00:00 24.00 DRILL P PROD1 Drill 4 3/4" Directional Hole from 13,221' to 14, 231'. 150 GPM @ 2430 psi. TO = 4.8K PIU = 190K SIC = 138K ROT = 161K. 80 RPM Rotating. Dyynamic losse 8 to 10 BBH. 12/13/2001 00:00 - 05:30 5.50 DRILL P PROD1 Drill 4 3/4" Directional Hole from 14,231' to 14387'. Lost all signal from Sperry MWD. 05:30 - 07:30 2.00 DRILL N DFAL PROD1 Pump KCL water through MWD in attempt to clear. No success. 07:30 - 10:30 3.00 DRILL P PROD1 Continue drillig from 14,387' to 14,500. TD as per Geologists. TSAD called @ 14,390'. 10:30 - 13:30 3.00 DRILL P PROD1 Circ. Lo-Vis > Hi-Vis Sweep. 150 GPM 2400 psi. 13:30 - 16:30 3.00 DRILL P PROD1 POH to Shoe. Tight @ 12,673, 12,640, 12,350 - 15K to 30K ( r ~.. Printed: 12/26/2001 8:51 :32 AM , BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: W-02A Common Well Name: W-02A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 11/18/2001 End: 12/23/2001 Contractor Name: NABORS Rig Release: 12/23/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/13/2001 13:30 - 16:30 3.00 DRILL P PROD1 over. Wiped through all - OK. 16:30 - 17:00 0.50 DRILL P PROD1 Service TD, Blocks & Crown. 17:00 - 19:00 2.00 DRILL P PROD1 RIH.Wipe again through 12,640' to 12,673. No Drag I Ptoblems. Hole Slick. 19:00 - 22:00 3.00 DRILL P PROD1 Pump Lo-Vis > Hi-Vis sweeps @ 160 GPM. Rotate @ 120 RPM. 22:00 - 00:00 2.00 DRILL P PROD1 Drop ball for PBL sub. Press. Decrease from 1300 to 1150 when ball reached PBL Pump 90 Bbl. Liner running pill. 12/14/2001 00:00 - 01 :30 1.50 DRILL P PROD1 Continue to spot liner running pill. Pressure increased to 2200 psi @ 2 BPM when pill in open hole - indicated PBL may not open. 01 :30 - 04:00 2.50 DRILL P PROD1 POH to Shoe. NO DRAG. Hole in good shape 04:00 - 05:00 1.00 DRILL P PROD1 Bring pump on line - PBL not open. Drop ball to open Baker circ sub. Pump down. Pressured up to 4200 psi did not open. 05:00 - 08:00 3.00 DRILL N DFAL PROD1 Hooked up test pump, put 5000 psi on DP - no success. Rigged up Pump in sub on DP wI high pressure connections. pressured up on DP to 8000 psi. Circ. Sub would not open. Rig down test pump & high pres connections and lines. 08:00 - 11 :30 3.50 DRILL P PROD1 POH wet. 11 :30 - 14:30 3.00 DRILL P PROD1 RlU SWS depth counter mechanism to rig geolograph and attempt to calibrat for loging run. Unable to calibrate with present design. 14:30 -15:30 1.00 DRILL P PROD1 Continue POH wet. 15:30 - 18:00 2.50 DRILL P PROD1 RlU Modified depth counter and calibrate same. Calibration successful - will be able to log DPC CNLlGRlCCL memory tool with preise depth control. 18:00 - 20:30 2.50 DRILL P PROD1 Continue POH - Stand back 2 7/8" DP. 20:30 - 00:00 3.50 DRILL P PROD1 Recover dart from Circ sub. Packed above with beads and barafiber. Recovered ball from PBL sub. Ball in catcher - sub not open. LID Jars, bumper sub, monels. Break out bit. 12/15/2001 00:00 - 01 :30 1.50 DRILL P PROD1 Complete LID BHA. 01 :30 - 02:00 0.50 CLEAN P COMP M/U Ported bullnose, XO's & Float sub for cleanout. 02:00 - 07:00 5.00 CLEAN P COMP RIH to 5.5" Liner top @ 10,411. 07:00 - 09:00 2.00 CLEAN P COMP Establish circulation 500 GPM @ 3560 psi. Rotate & reciprocate pipe. Pump Hi-Vis swep. About a Pick up truck full of sand over shakers. Cleaned up well. 09:00 - 12:00 3.00 CLEAN P COMP POH to 7" Liner top @ 3845'. 12:00 - 14:00 2.00 CLEAN P COMP Circulate HI-Vis sweep. Some sand back. 14:00 -18:00 4.00 CLEAN P COMP POH LID 2 7/8" Drill Pipe. 18:00 - 19:30 1.50 CASE P COMP RlU to run 3.5" Production Liner. 19:30 - 20:00 0.50 CASE P COMP PJSM wI crew, casing crew, Baker Hand, TP & Co. Rep. 20:00 - 00:00 4.00 CASE P COMP RUN - 3.5", 9.2 #, L-80 STL Production Liner as per program. 1600 ft Ilbs. Torque. Belled box on one Jt and one cent. Backed off torque to 1500 ft Ilbs. 12/16/2001 00:00 - 07:00 7.00 CASE P COMP Continue M/U & RIH wI 3.5" STL prod. liner 07:00 - 09:00 2.00 CASE N RREP COMP Oil seal went out on torque - turn tongs. Replaced same. 09:00 - 12:00 3.00 CASE P COMP Complete running 140 Jts.3.5" STL Liner and 80 centralizers. 12:00 - 13:00 1.00 CASE P COMP M/U Pkr I Hgr Assy. Circulate Liner volume. RID liner running equip. 13:00 - 14:00 1.00 CASE P COMP P/U & RIH w/21 Jts. 4", HWDP 14:00 - 18:30 4.50 CASE P COMP Run Liner assy. in hole on 4" DP to 10,400'. 18:30 - 20:30 2.00 CASE P COMP Circulate B/U prior to running in open hole. M/U Cement head on single - LID on skate. (' I( Printed: 12/26/2001 8:51 :32 AM (' ..° 1i , BP EXPLORATION Page 1 0 of 11 Operations Summary Report Legal Well Name: W-02A Common Well Name: W-02A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 11/18/2001 End: 12/23/2001 Contractor Name: NABORS Rig Release: 12/23/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/16/2001 20:30 - 00:00 3.50 CASE P CaMP Run liner in open hole to TD @ 14,500'. No Problems. Good displacement> Hole taking 4 to 6 Bbls.l Hr. Establish circulation wI good returns. 12/17/2001 00:00 - 02:00 2.00 CASE P CaMP CBU - 4 BPM @ 1260 psi. - Full Returns. Reciprocating Liner 02:00 - 03:30 1.50 CASE P CaMP Switch to SWS. Pump 5 Bbls CW-100, test to 3500psi, pump 25 Bbls CW-100. Pump 40 Bbls 10.2 ppg MudPush spacer& 63 Bbls of 15.8 ppg cementWash cement lines to floor. Switch back to Rig Pump, drop wiper plug and displace wI 40 bbls Perf. Pill and 97 Bbls Mud. Bump Plug ( & set Hanger) wI 3500 psi. 03:30 - 04:00 0.50 CASE P CaMP Slack off to check Hanger. Bleed off pres. Floats - OK. Rotate to release C-2 tool. Pres to 1000 psi and pull out of Hgr. Circ 30 bbls to clear cement from TOL. Stop circ.. set Down 50K to set Packer 04:00 - 07:00 3.00 CASE P CaMP Complete CBU @ 12.5 Bpm - 2750 psi. Approx. 30 BBLS contaminate cemenUmud to surface. Cont pumping & dislpace well to 8.7 ppg. Brine. 07:00 - 08:30 1.50 CASE P CaMP Cut & Slip DL, Service TD. 08:30 - 13:30 5.00 CASE P CaMP POH UD HWDP 13:30 - 14:00 0.50 CASE P CaMP Pull wear bushing, Run test plug. 14:00 - 17:00 3.00 CASE P COMP Test BOPE - 250 LO I 3500 HI. Witness waived by John Crisp, AOGCC. 17:00 -17:30 0.50 CASE P CaMP Pull test plug, run wear bushing. 17:30 - 19:00 1.50 PERF N WAIT CaMP Wait on SWS Logging tool. In well on CT - 3ES. Having problems. While waitng: cIa pump liner # 2 to 5.5", clean pits, Quarterly TD service,. 19:00 - 20:00 1.00 EVAL P CaMP R/U & Test 3.5" Liner & Lap to 3500 psi for 30 Minutes. - OK 20:00 - 00:00 4.00 PERF N WAIT CaMP Continue to wait on logging tool. Perform rig maintenance & cleaning. 12/18/2001 00:00 - 11 :00 11.00 EVAL N WAIT CaMP Continue to wait on logging tool - being fished on 3ES. 11:00 -12:00 1.00 EVAL P CaMP SWS Tool on location. Program tool. M/U in carrier, P/U to floor. PJSM. 12:00 - 12:30 0.50 EVAL P CaMP M/U SWS CNUGR/CCL Memory Tool & load source. 12:30 - 18:00 5.50 EVAL P CaMP RIH picking up 136 Jts 21/16" Hydril CS DP 18:00 - 21:30 3.50 EVAL P CaMP RIH on 4" DP to 10,000'. 21 :30 - 22:00 0.50 EVAL P CaMP PJSM on DPC logging. 22:00 - 00:00 2.00 EVAL P CaMP Calibrate Tool and begin logging down @ 10,000'. 12/19/2001 00:00 - 10:30 10.50 EVAL P CaMP Continue logging down wI SWS CNL Memory tool to landing collar @ 14,435'. Log up to 10,000'. 10:30 -13:30 3.00 EVAL P CaMP POH, stand back 4" DP. 13:30 -18:00 4.50 EVAL P CaMP POH UD 21/16" Hydril CS DP. 18:00 - 22:00 4.00 EVAL P COMP UD SWS Tool. Downloaded Data. Processed Logs. Faxed field prints to Jim Copen in ANC. Jim confirmed initial contingent perforation interval. Notified HOWCO. HOWCO to M/U additional 14 guns and necessary blanks 22:00 - 00:00 2.00 PERF P CaMP Wait on HOWCO. Making up additional perforating guns as per program. 12/20/2001 00:00 - 05:00 5.00 PERF P CaMP Wait on HOWCO - Making up additional perf guns per Geologists pick after evaluating SWS CNL Memory Log. 05:00 - 06:00 1.00 PERF P COMP Guns on Location. Unload into pipe shed in running order. 06:00 - 11 :00 5.00 PERF P CaMP PJSM. P/U, M/U & RIH wI 3305' of 20' perf guns. Guns: 2", 4 spf, 72 phase Millennium, Printed: 12/26/2001 8:51 :32 AM BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: W-02A Common Well Name: W-02A Spud Date: 11/19/2001 Event Name: REENTER+COMPLETE Start: 11/18/2001 End: 12/23/2001 Contractor Name: NABORS Rig Release: 12/23/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/20/2001 06:00 - 11 :00 5.00 PERF P COMP 23" perforation, 0.25" diameter entrance hole. 11 :00 - 13:00 2.00 PERF P COMP P/U & RIH w/2 1/16" Hydril DP. Fill every Jt. 13:00 - 14:00 1.00 PERF P COMP M?u Safety Jt., 7" Champ IV Pkr, XO & Jars - RIH 14:00 - 19:30 5.50 PERF P COMP RIH on 4" DP to 14,413'. 19:30 - 20:00 0.50 PERF P COMP PJSM wi Crew, HOWCO & Co. Rep. on firing guns 20:00 - 21 :00 1.00 PERF P COMP Tag landing collar @ 14,435'. P/U 45' to space out guns wi bottom shot @ 14,390'. Set Packer. Pressure annulus - guns fired @ 3200 psi. P/U and monitor well. Losses = 36 bbl/Hr. 21 :00 - 22:30 1.50 PERF P COMP POH to 11,047 - guns above perfs. 22:30 - 00:00 1.50 PERF P COMP Circulate DP capacity + annular volume @ 6 bpm 456 psi. 12/21/2001 00:00 - 05:00 5.00 PERF P COMP POH LID 4 " DP. 05:00 - 05:30 0.50 PERF P COMP Break down Packer assy. & LID 05:30 - 07:00 1.50 PERF P COMP POH LID 2 1/16" Hydril DP. 07:00 - 17:00 10.00 PERF P COMP PJSM. POH LID perf guns. Quite a bit of pressure between blanks and fired guns. Took the time to bleed safely. All Guns Fired. 17:00 - 20:00 3.00 PERF P COMP RIH wi 39 stands 4" DP. POH LID same 20:00 - 21 :00 1.00 PERF P COMP PJSM Slip & Cut 150' drilling line. Inspect & adjust brakes. 21 :00 - 22:30 1.50 PERF P COMP LID remainder of 4" DP. 22:30 - 00:00 1.50 RUNCO~ IP COMP Pull wear bushing. Make dummy run wi Tbg. Hgr. RIU to run 4.5" Tbg. Completion. 12/22/2001 00:00 - 00:30 0.50 RUNCO~ IP COMP PJSM: Crew, casers, Baker hand, TP & Co. Rep. 00:30 - 14:00 13.50 RUNCO~ IP COMP Run 4.5" Completion as per program. Space out into tie-back sleeve. 14:00 - 17:00 3.00 RUNCO~ IP COMP Revese circulate to displace well with corrsion inhibited filtered 8.7 ppg. brine 17:00 - 18:00 1.00 RUNCO~ IP COMP Land Tubing Hanger. Drop ball/rod. RILDS & torque to 450 ftllbs. 18:00 - 20:00 2.00 RUNCO~ IP COMP Pressur down tubing to 3500 psi to set Packer. Hold for 30 minutes for tubing test. Bleed to 1500 psi. Pressure ann ulus to 3500 psi. Hold for 30 minutes for packer test. Bleed down tubing, RP sheared @ 900 psi. Bleed to "0". Blow dn all lines & drain stack. 20:00 - 20:30 0.50 WHSUR P COMP Run TWC. test from below to 1500 psi. 20:30 - 22:00 1.50 WHSUR P COMP NID BOPE. 22:00 - 00:00 2.00 WHSUR P COMP N/U Adapter flange & Tree. 12/23/2001 00:00 - 01 :00 1.00 WHSUR P COMP Test tubing head adaptor and Xmas tree to 5000 psi - good tests. 01 :00 - 02:30 1.50 WHSUR P COMP Pull TWC with lubricator. Had a little trouble with sand and debris from inside tree? falling on top of TWC. 02:30 - 07:30 5.00 WHSUR P COMP RU & test lines to 3500 psi. Pump 155 bbl diesel to IA with Hot Oil to freeze protect well. 2 bpm @ 400 psi. Allow diesel to U tube from annulus to tubing to freeze prot Tbg & IA to 2200'. 07:30 - 08:30 1.00 WHSUR P COMP RU lubricator & test to 1500 psi. Install BPV and test to 1500 _. psi - OK. 08:30 - 12:00 3.50 RIGD P COMP Secure tree. Clear cellar area. Finish empty & clean pits. Take down secondary containment berms. RELEASE RIG FROM WELL W-02A AT 1200 HRS ON 12/23/2001. (' ( Printed: 12/26/2001 8:51 :32 AM 00 í .---- AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well W-02A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 4,243.43' MD Window / Kickoff Survey 4,307.76' MD Projected Survey: 14,500.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ c !<¡;~",,'W'. 31-Dec-01 RECEIVED JAN 0:5 2002 Aiaska Oil 8: Gas Cons. Commj~~' I .~fOn Ancl:~rage 0 -'-.-- North Slope Alaska Alaska Drilling & Wells PBU - WOA W Pad, Slot W-O2 W-O2A Job No. AKZZ11197, Surveyed: 13 December, 2001 -- SURVEY REPORT 28 December, 2001 Your Ref: API 500292279301 Surface Coordinates: 5959065.14 N, 612048.95 E (70017' 49.5975" N, 1490 OS' 33.4660" W) Kelly Bushing: 81.55ft above Mean Sea Level ~-- spal'r'y-sull DRILLING seRVices A Halliburton Company Survey Ref: 5vy11057 Sperry-Sun Drilling Services Survey Report for W-02A Your Ref: API 500292279301 Job No. AKZZ11197, Surveyed: 13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 4243.43 11.500 208.290 4024.28 4105.83 797.51 S 451.54 W 5958260.98 N 611609.35 E -7.71 Tie On Point -. AK-6 BP IFR-AK "'"-- 4307.76 13.710 200.590 4087.06 4168.61 810.30 S 457.26 W 5958248.11 N 611603.82 E 4.309 -9.15 Window Point 4339.12 15.980 199.220 4117.37 4198.92 817.86 S 459.99 W 5958240.52 N 611601.21 E 7.324 -10.57 4371.39 18.900 198.180 4148.15 4229.70 827.02 S 463.08 W 5958231.31 N 611598.25 E 9.100 -12.47 4402.28 21.340 197.410 4177.15 4258.70 837.14 S 466.32 W 5958221.15 N 611595.16 E 7.945 -14.72 4432.18 23.480 196.810 4204.80 4286.35 848.03 S 469.68 W 5958210.20 N 611591.97E 7.198 -17.26 4462.44 26.120 196.300 4232.26 4313.81 860.20 S 473.29 W 5958197.98 N 611588.54 E 8.753 -20.22 4492.90 28. 730 195.880 4259.30 4340.85 873.68 S 477.17W 5958184.45 N 611584.85 E 8.592 -23.59 4523.93 31 .170 195.510 4286.18 4367.73 888.59 S 481.36 W 5958169.47 N 611580.89 E 7.886 -27.42 4556.13 33.950 196.560 4313.32 4394.87 905.24 S 486.16 W 5958152.75 N 611576.35 E 8.810 -31.60 4586.60 36.630 198.070 4338.19 4419.74 922.04 S 491.40 W 5958135.88 N 611571.35 E 9.249 -35.45 4616.92 39.310 199.050 4362.09 4443.64 939.72 S 497.34 W 5958118.11 N 611565.67 E 9.060 -39.15 4649.01 42.530 199.490 4386.33 4467.88 959.56 S 504.28 W 5958098.17 N 611559.03 E 10.074 -43.06 4679.35 45.480 200.190 4408.15 4489.70 979.38 S 511.44 W 5958078.24 N 611552.17 E 9.854 -46.77 4712.51 48.530 199.680 4430.76 4512.31 1002.18 S 519.70 W 5958055.32 N 611544.25 E 9.266 -51.01 4743.97 51.580 199.200 4450.96 4532.51 1024.92 S 527.73 W 5958032.46 N 611536.56 E 9.765 -55.44 4774.09 52.350 198.360 4469.52 4551.07 1047.38 S 535.36 W 5958009.89 N 611529.26 E 3.370 -60.05 .-... 4806.60 53.710 197.380 4489.07 4570.62 1072.10 S 543.33 W 5957985.06 N 611521.66 E 4.827 -65.51 4839.18 54.340 195.370 4508.21 4589.76 1097.40 S 550.76 W 5957959.65 N 611514.61 E 5.354 - 71- 73 4871.78 54.480 195.790 4527.18 4608.73 1122.93 S 557.88 W 5957934.01 N 611507.87 E 1.132 -78.33 4905.76 55.120 194.530 4546.77 4628.32 1149.73 S 565.14 W 5957907.11 N 611501.01 E 3.568 -85.44 4935.31 55.480 192.830 4563.59 4645.14 1173.34 S 570.89 W 5957883.42 N 611495.62 E 4.884 -92.27 4967.06 55.600 191.970 4581.56 4663.11 1198.90 S 576.51 W 5957857.77 N 611490.38 E 2.265 -100.18 4997.77 54.830 190.500 4599.08 4680.63 1223.64 S 581.42 W 5957832.97 N 611485.83 E 4.663 -108.29 5028.98 53.960 190.580 4617.25 4698.80 1248.59 S 586.06 W 5957807.95 N 611481.57 E 2.795 -116.75 5060.95 52.620 189.060 4636.36 4717.91 1273.84 S 590.44 W 5957782.64 N 611477.57 E 5.665 -125.59 5091.94 52.240 188.150 4655.25 4736.80 1298.13 S 594.11 W 5957758.30 N 611474.26 E 2.631 -134.55 5124.22 51.960 188.210 4675.08 4756.63 1323.34 S 597.74 W 5957733.04 N 611471.01 E 0.880 -144.01 5153.37 51.800 187.750 4693.08 4774.63 1346.05 S 600.92 W 5957710.28 N 611468.16 E 1.357 -152.61 5246.00 51.590 186.540 4750.50 4832.05 1418.16 S 610.03 W 5957638.04 N 611460.13 E 0.967 -180- 78 - -- --------- --- --------- 28 December, 2001 - 16:10 Page 2 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-O2A Your Ref: API 500292279301 Job No. AKZZ11197, Surveyed: 13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU_WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5336.44 51.300 188.840 4806.87 1488.24 S 619.55 W 5957567.83 N 611451.66 E 1.929 -207.57 ,-. 4888.42 5427.93 52.090 190.250 4863.58 4945.13 1559.03 S 631.46 W 5957496.87 N 611440.81 E 1.486 -232.66 '- 5520.71 52.240 189.150 4920.49 5002.04 1631.26 S 643.80 W 5957424.46 N 611429.54 E 0.950 -258.08 5615.54 52.120 189.990 4978.64 5060.19 1705.13 S 656.26 W 5957350.42 N 611418.19 E 0.711 -284.23 5707.87 52.720 192.520 5034.95 5116.50 1776.88 S 670.54 W 5957278.46 N 611404.97 E 2.267 -307.73 5800.99 52.430 191.360 5091.55 5173.10 1849.23 S 685.84 W 5957205.89 N 611390.75 E 1.037 -330.66 5895.04 52.380 192.840 5148.93 5230.48 1922.09 S 701.46 W 5957132.81 N 611376.22 E 1.248 -353.56 5990.04 51.880 193.380 5207.24 5288.79 1995.13 S 718.47 W 5957059.52 N 611360.30 E 0.692 -375.35 6078.51 51.310 191.550 5262.21 5343.76 2062.81 S 733.44 W 5956991.62 N 611346.35 E 1.744 -396.23 6173.88 51.340 192.430 5321.80 5403.35 2135.64 S 748.90 W 5956918.57 N 611331.97 E 0.721 -419.25 6267.80 50.570 193.280 5380.97 5462.52 2206.76 S 765.13 W 5956847.22 N 611316.81 E 1.080 -440.76 6360.79 51.480 194.770 5439.46 5521.01 2276.89 S 782.65 W 5956776.83 N 611300.33 E 1.584 -460.65 6452.87 52.930 196.110 5495.89 5577.44 2347.02 S 802.03 W 5956706.42 N 611282.00 E 1.950 -478.93 6549.37 52.440 195.550 5554.39 5635.94 2420.86 S 822.97 W 5956632.28 N 611262.16 E 0.686 -497.72 6642.32 53.180 196.570 5610.57 5692.12 2492.01 S 843.46 W 5956560.83 N 611242.74 E 1.182 -515.55 6736.09 52.950 195.660 5666.92 5748.47 2564.02 S 864.26 W 5956488.52 N 611223.01 E 0.814 -533.54 6828.81 52.260 196.430 5723.23 5804.78 2634.81 S 884.62 W 5956417.44 N 611203.71 E 0.995 -551.30 6921.87 51.700 196.090 5780.55 5862.10 2705.19 S 905.15 W 5956346.76 N 611184.24 E 0.667 -568.71 .-_~ 7014.75 51.030 196.120 5838.54 5920.09 2774.89 S 925.27 W 5956276.76 N 611165.15 E 0.722 -586.14 7108.41 50.220 198.180 5897.96 5979.51 2844.07 S 946.61 W 5956207.28 N 611144.85 E 1.907 -602.24 7201.19 49.230 201.970 5957.95 6039.50 2910.54 S 970.88 W 5956140.45 N 611121.57 E 3.294 -614.46 7294.44 48.390 201.910 6019.36 6100.91 2975.63 S 997.10W 5956074.98 N 611096.32 E 0.902 -624.30 7385.38 47.650 201.170 6080.18 6161.73 3038.51 S 1021.93 W 5956011.74 N 611072.44 E 1.014 -634.24 7480.48 46.090 203.090 6145.20 6226.75 3102.80 S 1048.05 W 5955947.06 N 611047.27 E 2.205 -643.76 7572.62 43.220 207.480 6210.75 6292.30 3161.34 S 1075.64 W 5955888.11 N 611020.56 E 4.572 -649.14 7665.18 40.500 213.980 6279.72 6361.27 3214.42 S 1107.09W 5955834.57 N 610989.91 E 5.528 -648.45 7760.38 38.290 218.760 6353.30 6434.85 3263.07 S 1142.84 W 5955785.39 N 610954.88 E 3.941 -641.81 7852.46 37.840 224.550 6425.82 6507.37 3305.46 S 1180.53 W 5955742.45 N 610917.83 E 3.907 -630.36 7946.70 36.670 227.990 6500.84 6582.39 3344.90 S 1221.72 W 5955702.40 N 610877.23 E 2.534 -614.41 8041.98 36.700 231.640 6577.25 6658.80 3381.61 S 1265.19 W 5955665.04 N 610834.32 E 2.289 -595.12 --- "--,- ,-,-- ,------ -------, 28 December, 2001 - 16:10 Page 3 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-O2A Your Ref: API 500292279301 Job No. AKZZ11197, Surveyed: 13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth' Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8136.42 35.520 230.950 6653.55 6735.10 3416.41 S 1308.63 W 5955629.60 N 610791.40 E 1.322 -574.90 -0 8229.81 35.040 233.030 6729.79 6811.34 3449.62 S 1351.12 W 5955595.76 N 610749.41 E 1.385 -554.71 "---' 8321.84 34.470 236.980 6805.41 6886.96 3479.71 S 1394.07 W 5955565.03 N 610706.92 E 2.524 -532.56 8417.25 33.670 239.510 6884.45 6966.00 3507.84 S 1439.50 W 5955536.23 N 610661.91 E 1.706 -507.28 8509.28 33.770 240.480 6960.99 7042.54 3533.39 S 1483.74 W 5955510.02 N 610618.05 E 0.595 -481.74 8603.03 35.4 70 241.150 7038.14 7119.69 3559.36 S 1530.24 W 5955483.37 N 610571.94 E 1.858 -454.45 8695.77 35.020 241.800 7113.88 7195.43 3584.91 S 1577.26 W 5955457.11 N 610525.31 E 0.632 -426.51 8788.48 37.110 240.750 7188.82 7270.37 3611.15S 1625.11 W 5955430.16 N 610477.86 E 2.351 -398.19 8882.44 37.890 240.720 7263.36 7344.91 3639.11 S 1675.01 W 5955401.46 N 610428.38 E 0.830 -368.95 8974.94 37.370 241.730 7336.62 7418.17 3666.30 S 1724.51 W 5955373.53 N 610379.29 E 0.872 -339.68 9069.32 36.640 241.080 7411.99 7493.54 3693.49 S 1774.39 W 5955345.61 N 610329.82 E 0.878 -310.08 9163.15 37.220 240.850 7487.00 7568.55 3720.85 S 1823.68 W 5955317.51 N 610280.95 E 0.635 -281.07 9256.47 38.250 241.230 7560.80 7642.35 3748.50 S 1873.65 W 5955289.12 N 610231.39 E 1.132 -251.62 9348.90 37.460 241.130 7633.78 7715.33 3775.84 S 1923.35 W 5955261.04 N 610182.11 E 0.857 -222.26 9440.99 36.910 241.450 7707.14 7788.69 3802.58 S 1972.16 W 5955233.58 N 610133.70 E 0.633 -193.35 9537.52 38.180 242.950 7783.68 7865.23 3830.00 S 2024.20 W 5955205.38 N 610082.08 E 1.621 -162.00 9631.37 37.930 243.100 7857.58 7939.13 3856.25 S 2075.75 W 5955178.38 N 610030.92 E 0.284 -130.47 9725.11 38.360 244.830 7931.30 8012.85 3881.65 S 2127.77 W 5955152.20 N 609979.28 E 1.229 -98.12 ---- 9820.39 39.160 248.610 8005.61 8087.16 3905.20 S 2182.55 W 5955127.83 N 609924.86 E 2.621 -62.45 9912.22 39.880 252.430 8076.46 8158.01 3924.67 S 2237.63 W 5955107.55 N 609870.09 E 2.760 -24.49 10005.35 40.270 254.170 8147.72 8229.27 3941.89 S 2295.05 W 5955089.47 N 609812.92 E 1.274 16.63 10098.46 41.580 256.430 8218.08 8299.63 3957.35 S 2354.04 W 5955073.13 N 609754.17 E 2.123 59.98 10191.85 42.720 258.850 8287.32 8368.87 3970.75 S 2415.25 W 5955058.82 N 609693.17 E 2.124 106.30 10285.08 43.480 261.400 8355.40 8436.95 3981.66 S 2478.00 W 5955046.97 N 609630.59 E 2.039 155.18 10379.51 43.240 261.370 8424.05 8505.60 3991.38 S 2542.10 W 5955036.31 N 609566.64 E 0.255 205.84 10472.35 43.860 263.090 8491.34 8572.89 4000.02 S 2605.48 W 5955026.72 N 609503.40 E 1.441 256.40 10566.02 45.520 265.530 8557.94 8639.49 4006.53 S 2671.02 W 5955019.24 N 609437.96 E 2.549 309.91 10658.34 46.070 268.190 8622.31 8703.86 4010.14 S 2737.09 W 5955014.63 N 609371.95 E 2.150 365.31 10753.08 45.990 267.880 8688.09 8769.64 4012.48 S 2805.23 W 5955011.28 N 609303.85 E 0.250 423.16 10856.51 47.290 265.490 8759.10 8840.65 4016.85 S 2880.29 W 5955005.80 N 609228.87 E 2.098 485.98 ---._- .------.--. --,- - ----..u_------.-- 28 December, 2001 - 16:10 Page 4 of 9 Drif/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-02A Your Ref: API 500292279301 Job No. AKZZ11197, Surveyed: 13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) -- 10923.20 53.070 259.450 8801.82 8883.37 4023.66 S 2930.99 W 5954998.23 N 609178.27 E 11.107 526.48 10953.53 56.280 257.610 8819.35 8900.90 4028.59 S 2955.24 W 5954992.94 N 609154.10 E 11.683 545.02 -.' 10984.12 59.830 258.770 8835.53 8917.08 4033.90 S 2980.64 W 5954987.25 N 609128.78 E 12.043 564.36 11015.29 62.890 260.250 8850.47 8932.02 4038.87 S 3007.54 W 5954981.88 N 609101.96 E 10.665 585.17 11045.12 68.460 262.530 8862.76 8944.31 4042.93 S 3034.40 W 5954977.42 N 609075.16 E 19.928 606.41 11076.52 73.510 264.770 8872.99 8954.54 4046.20 S 3063.90 W 5954973.71 N 609045.72 E 17.439 630.31 11107.98 76.250 269.100 8881.19 8962.74 4047.82 S 3094.21 W 5954971.64 N 609015.43 E 15.886 655.76 11143.78 77.230 271.700 8889.41 8970.96 4047.57 S 3129.05 W 5954971.37 N 608980.59 E 7.580 686.05 11172.69 77.950 274.180 8895.62 8977.17 4046.12 S 3157.i5 W 5954972.40 N 608952.38 E 8.740 711.20 11203.59 80.820 277.080 8901.31 8982.86 4043.14 S 3187.47 W 5954974.93 N 608922.12 E 13.090 738.86 11235.99 85.140 275.350 8905.27 8986.82 4039.66 S 3219.43 W 5954977.93 N 608890.11 E 14.347 768.27 11265.82 88.680 279.370 8906.88 8988.43 4035.85 S 3248.96 W 5954981.30 N 608860.53 E 17.940 795.75 11297.44 90.550 280.750 8907.09 8988.64 4030.32 S . 3280.09 W 5954986.36 N 608829.32 E 7.350 825.48 11329.51 92.280 286.430 8906.30 8987.85 4022.79 S 3311.24 W 5954993.43 N 608798.06 E 18.509 856.22 11359.10 92.030 289.950 8905.19 8986.74 4013.56 S 3339.32 W 5955002.24 N 608769.84 E 11.917 885.16 11389.23 94.150 293.470 8903.56 8985.11 4002.44 S 3367.27 W 5955012.94 N 608741.73 E 13.623 914.92 11420.91 91.170 299.130 8902.09 8983.64 3988.42 S 3395.62 W 5955026.53 N 608713.17 E 20.172 946.48 11452.43 88.460 301.170 8902.19 8983.74 3972.59 S 3422.87 W 5955041.96 N 608685.68 E 10.761 978.00 .~. 11482.31 87.200 303.550 8903.33 8984.88 3956.61 S 3448.09 W 5955057.56 N 608660.23 E 9.007 1007.83 11514.36 87.750 305.970 8904.74 8986.29 3938.36 S 3474.40 W 5955075.42 N 608633.66 E 7.736 1039.74 11546.36 87.630 306.870 8906.03 8987.58 3919.38 S 3500.13 W 5955094.01 N 608607.65 E 2.835 1071.51 11577.59 87.720 308.490 8907.29 8988.84 3900.30 S 3524.82 W 5955112.72 N 608582.67 E 5.191 1102.43 11609.21 87.600 309.820 8908.59 8990.14 3880.36 S 3549.32 W 5955132.30 N 608557.88 E 4.220 1133.62 11639.76 87.630 310.120 8909.86 8991.41 3860.75 S 3572.71 W 5955151.56 N 608534.19 E 0.986 1163.69 11670.67 84.110 310.130 8912.08 8993.63 3840.88 S 3596.28 W 5955171.07 N 608510.33 E 11.388 1194.03 11702.91 83.860 309.790 8915.46 8997.01 3820.29 S 3620.86 W 5955191.29 N 608485.45 E 1.304 1225.61 11732.24 83.870 306.740 8918.60 9000.15 3802.23 S 3643.75 W 5955209.00 N 608462.29 E 10.339 1254.47 11765.58 83.280 307.060 8922.33 9003.88 3782.34 S 3670.25 W 5955228.50 N 608435.50 E 2.010 1287.36 11797.57 83.080 304.790 8926.13 9007.68 3763.71 S 3695.97 W 5955246.75 N 608409.51 E 7.073 1318.95 11830.33 82.860 302.740 8930.14 9011.69 3745.64 S 3722.99 W 5955264.41 N 608382.21 E 6.247 1351.39 ------ ----- --- n_- ------ ------ 28 December, 2001 - 16:10 Page 5 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-O2A Your Ref: API 500292279301 Job No. AKZZ11197, Surveyed: 13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) ~-o 11862.14 86.140 299.570 8933.19 9014.74 3729.26 S 3750.08 W 5955280.38 N 608354.88 E 14.307 1383.04 11891.98 86.510 298.110 8935.10 9016.65 3714.90 S 3776.17 W 5955294.36 N 608328.59 E 5.038 1412.81 ~ 11920.70 86.860 298.180 8936.76 9018.31 3701.37 S 3801.45 W 5955307.50 N 608303.11 E 1.243 1441.47 11953.22 90.560 296.490 8937.49 9019.04 3686.45 S 3830.33 W 5955322.00 N 608274.01 E 12.507 1473.94 11984.39 90.250 297.090 8937.27 9018.82 3672.40 S 3858.15 W 5955335.63 N 608245.98 E 2.167 1505.06 12014.72 89.600 297.230 8937.31 9018.86 3658.55 S 3885.13 W 5955349.07 N 608218.79 E 2.192 1535.35 12047.42 86.960 297.250 8938.29 9019.84 3643.59 S 3914.19 W 5955363.59 N 608189.51 E 8.074 1567.99 12077.41 86.570 296.660 8939.98 9021.53 3630.02 S 3940.88 W 5955376.77 N 608162.63 E 2.356 1597.89 12107.73 86.260 295.900 8941.88 9023.43 3616.62 S 3968.01 W 5955389.76 N 608135.30 E 2.703 1628.09 12136.52 85.870 295.660 8943.86 9025.41 3604.13 S 3993.88 W 5955401.86 N 608109.25 E 1.590 1656.73 12169.99 86.880 293.870 8945.97 9027.52 3590.14 S 4024.21 W 5955415.40 N 608078.72 E 6.131 1690.00 12199.71 86.980 292.700 8947.56 9029.11 3578.41 S 4051.47 W 5955426.73 N 608051.28 E 3.945 1719.47 12230.59 86.610 292.550 8949.29 9030.84 3566.55 S 4079.93 W 5955438.16 N 608022.65 E 1.293 1750.05 12263.58 86.660 292.380 8951.23 9032.78 3553.96 S 4110.36W 5955450.29 N 607992.03 E 0.536 1782.69 12294.90 86.610 291.410 8953.07 9034.62 3542.30 S 4139.37 W 5955461.52 N 607962.85 E 3.096 1813.65 12325.03 90.490 291.120 8953.83 9035.38 3531.38 S 4167.43 W 5955472.02 N 607934.63 E 12.913 1843.41 12357.57 93.940 291.000 8952.57 9034.12 3519.70 S 4197.77 W 5955483.25 N 607904.12 E 10.609 1875.53 12388.02 94.120 292.000 8950.43 9031.98 3508.57 S 4226.03 W 5955493.96 N 607875.69 E 3.329 1905.57 -'">, 12419.09 93.940 292.180 8948.25 9029.80 3496.91 S 4254.75 W 5955505.18 N 607846.81 E 0.818 1936.27 12450.45 93.390 291.590 8946.24 9027.79 3485.25 S 4283.79 W 5955516.41 N 607817.60 E 2.569 1967.25 12480.44 93.960 292.020 8944.32 9025.87 3474.13 S 4311.58 W 5955527.11 N 607789.65 E 2.379 1996.87 12511.58 95.000 291.900 8941.89 9023.44 3462.52 S 4340.37 W 5955538.29 N 607760.68 E 3.362 2027.61 12542.81 95.190 291.560 8939.11 9020.66 3451.00 S 4369.27 W 5955549.38 N 607731.62 E 1.243 2058.39 12574.61 95.330 291.150 8936.20 9017.75 3439.47 S 4398.76 W 5955560.47 N 607701.96 E 1.357 2089.70 12607.14 94.810 293.630 8933.32 9014.87 3427.13 S 4428.72 W 5955572.36 N 607671.82 E 7.760 2121.82 12638.60 94.010 294.020 8930.90 9012.45 3414.46 S 4457.41 W 5955584.60 N 607642.94 E 2.827 2153.00 12669.42 93.670 294.930 8928.84 9010.39 3401.72 S 4485.40 W 5955596.92 N 607614.77 E 3.146 2183.61 12700.80 92.500 297.840 8927.15 9008.70 3387.80 S 4513.46 W 5955610.43 N 607586.50 E 9.982 2214.88 12732.18 93.240 298.720 8925.58 9007.13 3372.95 S 4541.06 W 5955624.86 N 607558.68 E 3.661 2246.20 12763.39 94.000 303.410 8923.61 9005.16 3356.88 S 4567.74 W 5955640.53 N 607531.77 E 15.194 2277.34 28 December, 2001 - 16:10 Page 6 of 9 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-O2A Your Ref: API 500292279301 Job No. AKZZ11197, Surveyed: 13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment eft) eft) (ft) (ft) (ft) (ft) (ft) (0/100ft) -. 12794.25 92.250 304.450 8921.93 9003.48 3339.68 S 4593.30 W 5955657.35 N 607505.95 E 6.594 2308.08 12825.57 92.400 304.940 8920.66 9002.21 3321.87 S 4619.03 W 5955674.77 N 607479.96 E 1.635 2339.26 12857.62 92.490 305.340 8919.29 9000.84 3303.44 S 4645.22 W 5955692.81 N 607453.50 E 1.278 2371.16 12888.08 92.710 306.140 8917.91 8999.46 3285.67 S 4669.92 W 5955710.22 N 607428.54 E 2.721 2401.43 12918.98 93.390 307.970 8916.26 8997.81 3267.07 S 4694.54 W 5955728.44 N 607403.64 E 6.310 2432.05 12948.91 93.700 307.820 8914.41 8995.96 3248.73 S 4718.11W 5955746.43 N 607379.80 E 1.150 2461.64 12980.74 91.850 307.760 8912.87 8994.42 3229.24 S 4743.24 W 5955765.54 N 607354.39 E 5.815 2493.14 13010.52 91.630 308.000 8911.97 8993.52 3210.97 S 4766.73 W 5955783.46 N 607330.62 E 1.093 2522.63 13042.58 90.620 306.960 8911.34 8992.89 3191.46 S 4792.17 W 5955802.58 N 607304.90 E 4.521 2554.41 13072.88 90.250 307.070 8911.11 8992.66 3173.22 S 4816.36 W 5955820.46 N 607280.43 E 1.274 2584.48 13104.90 93.880 305.420 8909.95 8991.50 3154.31 S 4842.16 W 5955838.99 N 607254.35 E 12.451 2616.28 13135.00 94.480 305.460 8907.76 8989.31 3136.90 S 4866.62 W 5955856.03 N 607229.64 E 1.998 2646.17 13165.55 94.220 305.770 8905.44 8986.99 3119.16S 4891.38 W 5955873.40 N 607204.61 E 1.322 2676.48 13197.81 93.920 305.150 8903.15 8984.70 3100.49 S 4917.59 W 5955891.67 N 607178.13 E 2.131 2708.51 13228.83 93.170 304.980 8901.23 8982.78 3082.71 S 4942.93 W 5955909.08 N 607152.52 E 2.479 2739.35 13260.26 93.010 304.190 8899.54 8981.09 3064.89 S 4968.77 W 5955926.51 N 607126.42 E 2.561 2770.64 13294.87 93.020 304.540 8897.72 8979.27 3045.38 S 4997.30 W 5955945.59 N 607097.61 E 1.010 2805.10 13326.40 94.820 303.860 8895.56 8977.11 3027.70 S 5023.32 W 5955962.88 N 607071.33 E 6.101 2836.47 --.., 13355.46 95.210 303.310 8893.02 8974.57 3011.69S 5047.43 W 5955978.53 N 607046.98 E 2.314 2865.36 13388.58. 95.380 303.720 8889.97 8971.52 2993.48 S 5074.93 W 5955996.33 N 607019.21 E 1.335 2898.28 13419.38 93.980 304.250 8887.45 8969.00 2976.32 S 5100.38 W 5956013.11 N 606993.51 E 4.858 2928.90 13449.48 93.480 304.110 8885.50 8967.05 2959.45 S 5125.23 W 5956029.61 N 606968.41 E 1.725 2958.86 13483.04 93.790 304.060 8883.37 8964.92 2940.68 S 5152.97 W 5956047.96 N 606940.40 E 0.936 2992.26 13510.19 93.710 304.200 8881.59 8963.14 2925.48 S 5175.40 W 5956062.83 N 606917.75 E 0.593 3019.29 13541.61 93.360 303.730 8879.66 8961.21 2907.96 S 5201.40 W 5956079.96 N 606891.48 E 1.863 3050.57 13573.38 93.380 304.180 8877.79 8959.34 2890.24 S 5227.71 W 5956097.28 N 606864.91 E 1.415 3082.21 13603.72 93.400 302.800 8875.99 8957.54 2873.53 S 5252.97 W 5956113.61 N 606839.41 E 4.541 3112.44 13635.95 93.210 304.360 8874.14 8955.69 2855.73 S 5279.78 W 5956131.01 N 606812.34 E 4.868 3144.55 13666.29 93.740 305.030 8872.30 8953.85 2838.50 S 5304.67 W 5956147.87 N 606787.18 E 2.813 3174.73 13695.13 93.270 305.700 8870.53 8952.08 2821.84 S 5328.15 W 5956164.18 N 606763.46 E 2.834 3203.39 -- -- -_u_-- 28 December, 2001 - 16:10 Page 7 of 9 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-02A Your Ref: API 500292279301 Job No. AKZZ11197, Surveyed: 13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment eft) eft) eft) . (ft) (ft) (ft) eft) (°/1 OOft) 13726.22 -- 92.740 306.010 8868.90 8950.45 2803.65 S 5353.31 W 5956181.99 N 606738.03 E 1.974 3234.28 13758.02 92.570 306.550 8867.43 8948.98 2784.85 S 5378.92 W 5956200.40 N 606712.15 E 1.779 3265.85 "- 13788.10 92.840 306.470 8866.01 8947.56 2766.98 S 5403.07 W 5956217.92 N 606687.73 E 0.936 3295.71 13818.75 93.480 305.910 8864.32 8945.87 2748.91 S 5427.77 W 5956235.62 N 606662.77 E 2.773 3326.13 13853.85 93.680 306.470 8862.13 8943.68 2728.22 S 5456.04 W 5956255.88 N 606634.19 E 1.691 3360.96 13884.42 94.250 306.450 8860.02 8941.57 2710.10 S 5480.57 W 5956273.63 N 606609.40 E 1.866 3391.26 13915.49 95.400 307.480 8857.40 8938.95 2691.48 S 5505.31 W 5956291.88 N 606584.38 E 4.961 3421.99 13948.78 95.080 306.780 8854.36 8935.91 2671.47 S 5531.74 W 5956311.49 N 606557.66 E 2.304 3454.89 13979.02 93.110 306.930 8852.20 8933.75 2653.38 S 5555.87 W 5956329.22 N 606533.26 E 6.533 3484.83 14009.87 93.150 307.200 8850.52 8932.07 2634.82 S 5580.45 W 595634 7.42 N 606508.40 E 0.883 3515.40 14041.74 93.400 306.570 8848.70 8930.25 2615.72 S 5605.90 W 5956366.13 N 606482.67 E 2.124 3546.99 14072.52 93.390 307.070 8846.87 8928.42 2597.30 S 5630.49 W 5956384.18 N 606457.80 E 1.622 3577.50 14103.81 93.240 305.910 8845.07 8926.62 2578.73 S 5655.61 W 5956402.38 N 606432.42 E 3.732 3608.54 14135.08 93.830 305.840 8843.14 8924.69 2560.44 S 5680.90 W 5956420.29 N 606406.86 E 1.900 3639.58 14165.39 93.920 305.000 8841.09 8922.64 2542.91 S 5705.54 W 5956437.45 N 606381.95 E 2.781 3669.69 14197.00 94.500 305.770 8838.77 8920.32 2524.66 S 5731.24 W 5956455.32 N 606355.98 E 3.044 3701.07 14229.38 94.660 306.060 8836.18 8917.73 2505.72 S 5757.38 W 5956473.86 N 606329.56 E 1.020 3733.18 14260.98 94.960 305.830 8833.53 8915.08 2487.24 S 5782.88 W 5956491.96 N 606303.80 E 1.195 3764.50 -" 14290.79 95.110 305.500 8830.92 8912.47 2469.93 S 5807.00 W 5956508.91 N 606279.42 E 1.212 3794.05 14322.32 96.200 302.780 8827.81 8909.36 2452.32 S 5832.97 W 5956526.13 N 606253.19 E 9.255 3825.34 14352.64 96.890 302.490 8824.35 8905.90 2436.07 S 5858.33 W 5956541.99 N 606227.59 E 2.466 3855.43 14416.12 98.870 302.990 8815.65 8897.20 2402.07 S 5911.22 W 5956575.21 N 606174.20 E 3.215 3918.23 14460.77 98.440 302.920 8808.93 8890.48 2378.06 S 5948.26 W 5956598.66 N 606136.80 E 0.975 3962.32 14500.00 98.440 302.920 8803.17 8884.72 2356.97 S 5980.84 W 5956619.27 N 606103.92 E 0.000 4001.07 Projected Survey -------- - -- --- 28 December, 2001 - 16:10 Page 8 of 9 DrillQlIcst 2.00.08.005 North Slope Alaska Sperry-Sun Drilling Services Survey Report for W-02A Your Ref: API 500292279301 Job No. AKZZ11197, Surveyed: 13 December, 2001 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. . Magnetic Declination at Surface is 26.264° (05-Dec-01) \ ,-. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 300.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14500.00ft., The Bottom Hole Displacement is 6428.51ft., in the Direction of 248.491° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4243.43 4307.76 14500.00 4105.83 4168.61 8884.72 "---. 797.51 S 810.30 S 2356.97 S Survey tool program for W-02A From Measured Vertical Depth Depth (ft) (ft) 0.00 4243.43 0.00 4105.83 To Measured Vertical Depth Depth (ft) (ft) 4243.43 14500.00 4105.83 8884.72 28 December, 2001 - 16:10 _-n______- ""'---""-----'--'-"----'---"-- 451.54 W 457.26 W 5980.84 W Tie On Point Window Point Projected Survey Survey Tool Description MWD Magnetic (W-02) AK-6 BP _IFR-AK (W-02A) Page 9 of 9 . Alaska Drilling & Wells PBU WOA W Pad .-, -~-" '-__n.- DrillQuest 2.00.08.005 (" f ~" :J"~,,,it::"'!"!'~""rJ'¡""\::"(:"""""":::"""""';'2" "":'P/""'~"""""';":' '~I"""'" "," - 31-Dec-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well W-02A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 4,243.43' MD Window / Kickoff Survey 4,307.76' MD Projected Survey: 14,500.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAr"J 0 3 2002 Alaska Oil & Gas Cons. Commission ,Anct;;orage North Slope Alaska Alaska Drilling & Wells PB U - WOA W Pad, Slot W-O 2 W-O 2A MWD Job No. AKMM11197, Surveyed: 13 December, 2001 -ò SURVEY REPORT 31 December, 2001 Your Ref: API 500292279301 Surface Coordinates: 5959065.14 N, 612048.95 E (70017' 49.5975" N, 149005' 33.4660" W) Kelly Bushing: 81.55ft above Mean Sea Level .--"< spe""'Y-SUI1 DEUL.I.-ING SERVices A Halliburton Company Survey Ref: 5vy11065 Sperry-Sun Drilling Services Survey Report for W-02A MWD Your Ref: API 500292279301 Job No. AKMM11197, Surveyed: .13 December, 2001 ,. Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) -. 4243.43 11.500 208.290 4024.28 4105.83 797.51 S 451.54 W 5958260.98 N 611609.35 E 712.50 Tie On Point 4307.76 13.710 200.590 4087.06 4168.61 810.30 S 457.26 W 5958248.11 N 611603.82 E 4.309 722.51 Window Point 4339.12 15.980 199.220 4117.37 4198.92 817.86 S 459.99 W 5958240.52 N 611601.21 E 7.324 727.82 4371.39 18.900 198.180 4148.15 4229.70 827.02 S 463.08 W 5958231.31 N 611598.25 E 9.100 734.06 4402.28 21.340 197.410 4177.15 4258.70 837.14 S 466.32 W 5958221.15 N 611595.16 E 7.945 740.78 4432.18 23.480 196.810 4204.80 4286.35 848.03 S 469.68 W 5958210.20 N 611591.97 E 7.198 747.89 4462.44 26.120 196.300 4232.26 4313.81 860.20 S 473.29 W 5958197.98 N 611588.54 E 8.753 755.72 4492.90 28.730 195.880 4259.30 4340.85 873.68 S 477.17 W 5958184.45 N 611584.85 E 8.592 764.27 4523.93 31 .170 195.100 4286.18 4367.73 888.60 S 481.31 W 5958169.46 N 611580.94 E 7.963 773.59 4556.13 33.950 196.590 4313.32 4394.87 905.27 S 486.05 W 5958152.72 N 611576.45 E 8.985 784.11 4586.60 36.630 197.690 4338.19 4419.74 922.09 S 491.24 W 5958135.83 N 611571.51 E 9.039 795.11 4616.92 39.310 198.810 4362.09 4443.64 939.80 S 497.09W 5958118.03 N 611565.93 E 9.126 807.04 4649.01 42.530 199.240 4386.33 4467.88 959.67 S 503.94 W 5958098.07 N 611559.37 E 10.073 820.70 4679.35 45.480 199.790 4408.15 4489.70 979.53 S 510.98 W 5958078.10 N 611552.63 E 9.804 834.54 4712.51 48.530 200.260 4430.76 4512.31 1002.31 S 519.29 W 5958055.20 N 611544.66 E 9.256 850.62 4743.97 51.580 198.940 4450.96 4532.51 1025.03 S 527.37 W 5958032.36 N 611536.92 E 10.214 866.47 4774.09 52.350 198.060 4469.52 4551.07 1047.53 S 534.90 W 5958009.75 N 611529.73 E 3.440 881.72 4806.60 53.710 197.280 4489.07 4570.62 1072.28 S 542.78 W 5957984.89 N 611522.22 E 4.602 898.13 ~~.." 4839.18 54.340 195.440 4508.21 4589.76 1097.58 S 550.20 W 5957959.48 N 611515.17 E 4.963 914.31 4871.78 54.480 195.680 4527.18 4608.73 1123.12 S 557.32 W 5957933.84 N 611508.44 E 0.737 930.29 4905.76 55.120 195.340 4546.77 4628.32 1149.87 S 564.74 W 5957906.98 N 611501.42 E 2.053 947.01 4935.31 55.480 192.850 4563.59 4645.14 1173.43 S 570.66 W 5957883.33 N 611495.85 E 7.034 961. 15 4967.06 55.600 195.040 4581.56 4663.11 1198.84 S 576.96 W 5957857.84 N 611489.92 E 5.700 976.33 4997.77 54.830 193.020 4599.08 4680.63 1223.30 S 583.08 W 5957833.28 N 611484.17 E 5.956 990.99 5028.98 53.960 193.570 4617.25 4698.80 1248.00 S 588.91 W 5957808.50 N 611478.71 E 3.134 1005.48 5060.95 52.620 190.740 4636.36 4717.91 1273.05 S 594.32 W 5957783.38 N 611473.68 E 8.241 1019.69 5091.94 52.240 190.050 4655.26 4736.81 1297.21 S 598.75 W 5957759.15 N 611469.61 E 2.149 1032.67 5124.22 51.960 188.340 4675.09 4756.64 1322.35 S 602.82 W 5957733.95 N 611465.91 E 4.269 1045.67 5153.37 51.800 189.940 4693.08 4774.63 1344.99 S 606.46 W 5957711.26 N 611462.61 E 4.353 1057.36 5246.00 51.590 186.180 4750.51 4832.06 1416.94 S 616.65 W 5957639.17 N 611453.49 E 3.193 1093.22 - ------- --"--- 31 December, 2001 - 13:42 Page 2 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-02A MWD Your Ref: API 500292279301 Job No. AKMM11197, Surveyed: ,13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOff) ~, 5336.44 51.300 191.370 4806.90 4888.45 1486.79 S 627.43 W 5957569.16 N 611443.76 E 4.498 1128.86 5427.93 52.090 191.940 4863.61 4945.16 1557.105 641.93 W 5957498.64 N 611430.30 E 0.992 1168.14 5520.71 52.240 188.660 4920.53 5002.08 1629.18 S 655.03 W 5957426.37 N 611418.28 E 2.797 1206.75 5615.54 52.120 190.960 4978.69 5060.24 1702.99 S 667.79 W 5957352.39 N 611406.62 E 1.920 1245.68 5707.87 52.720 192.250 5035.00 5116.55 1774.665 682.51 W 5957280.50 N 611392.97 E 1.284 1285.66 5800.99 52.430 191.810 5091.59 5173.14 1846.99 S 697.93 W 5957207.95 N 611378.64 E 0.488 1326.52 5895.04 52.380 193.940 5148.97 5230.52 1919.635 714.53 W 5957135.07 N 611363.12 E 1.795 1368.60 5990.04 51.880 193.480 5207.29 5288.84 1992.48 S 732.30 W 5957061.96 N 611346.43 E 0.650 1411.85 6078.51 51.310 191.510 5262.25 5343.80 2060.165 747.31 W 5956994.07 N 611332.44 E 1.860 1450.62 6173.88 51.340 191.720 5321.85 5403.40 2133.09 5 762.30 W 5956920.92 N 611318.54 E 0.175 1491.30 6267.80 50.570 193.920 5381.01 5462.56 2204.21 5 778.4 7 W 5956849.57 N 611303.42 E 1.995 1532.43 6360.79 51.480 195.090 5439.50 5521.05 2274.195 796.58 W 5956779.32 N 611286.36 E 1.384 1574.94 6452.87 52.930 196.130 5495.93 5577.48 2344.27 S 816.17 W 5956708.96 N 611267.82 E 1.810 1618.85 6549.37 52.440 195.610 5554.43 5635.98 2418.095 837.16W 5956634.84 N 611247.94 E 0.664 1665.44 6642.32 53.180 196.370 5610.62 5692.17 2489.27 S 857.56 W 5956563.36 N 611228.60 E 1.029 1710.52 6736.09 52.950 195.410 5666.96 5748.51 2561.365 878.08 W 5956490.98 N 611209.16 E 0.854 1756.04 6828.81 52.260 196.970 5723.28 5804.83 2632.09 S 898.61 W 5956419.94 N 611189.68 E 1.530 1801.08 6921.87 51.700 196.020 5780.60 5862.15 2702.39 S 919.43 W 5956349.35 N 611169.91 E 1.004 1846.22 -" 7014.75 51.030 196.470 5838.59 5920.14 2772.04 S 939.72W 5956279.40 N 611150.66 E 0.815 1890.64 7108.41 50.220 198.920 5898.01 5979.56 2841.01 S 961.72 W 5956210.11 N 611129.70 E 2.199 1936.39 7201.19 49.230 201.730 5957.99 6039.54 2907.38 5 986.29 W 5956143.38 N 611106.12 E 2.545 1983.59 7294.44 48.390 202.150 6019.40 6100.95 2972.475 1012.51 W 5956077.90 N 611080.87 E 0.962 2031.84 7385.38 47.650 201.510 6080.23 6161.78 3035.22 5 1037.65 W 5956014.78 N 611056.67 E 0.967 2078.24 7480.48 46.090 202.920 6145.25 6226.80 3099.48 S 1063.87 W 5955950.15 N 611031.40 E 1.965 2126.20 7572.62 43.220 207.360 6210.80 6292.35 3158.095 1091.31 W 5955891.13 N 611004.84 E 4.600 2173.22 7665.18 40.500 213.830 6279.76 6361.31 3211.24 S 1122.63 W 5955837.52 N 610974.32 E 5.510 2221.85 7760.38 38.290 219.680 6353.35 6434.90 3259.65 5 1158.69W 5955788.58 N 610938.98 E 4.537 2273.14 7852.46 37.840 225.000 6425.87 6507.42 3301.58 S 1196.89 W 5955746.08 N 610901.42 E 3.595 2324.05 7946.70 36.670 229.210 6500.89 6582.44 3340.42 5 1238.64 W 5955706.63 N 610860.25 E 2.975 2377.14 8041.98 36.700 231.950 6577.30 6658.85 3376.55 S 1282.61 W 5955669.84 N 610816.83 E 1.718 2431.29 ---------------- 31 December, 2001 - 13:42 Page 3 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-O2A MWD Your Ref: API 500292279301 Job No. AKMM11197, Surveyed: -13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU_WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) -.- 8136.42 35.520 232.190 6653.60 6735.15 3410.77 S 1326.50 W 5955634.98 N 610773.44 E 1.258 2484.67 8229.81 35.040 234.090 6729.84 6811.39 3443.12S 1369.65W 5955601.98N 610730.78E 1.282 2536.68 8321.84 34.470 238.070 6805.46 6887.01 3472.40 S 1413.16 W 5955572.06 N 610687.72 E 2.542 2587.89 8417.25 33.670 239.980 6884.49 6966.04 3499.91 S 1458.98 W 5955543.87 N 610642.32 E 1.400 2640.61 8509.28 33.770 240.560 6961.04 7042.59 3525.24 S 1503.34 W 5955517.87 N 610598.33 E 0.366 2691.17 8603.03 35.470 241.170 7038.19 7119.74 3551.17 S 1549.87 W 5955491.26 N 610552.20 E 1.851 2743.96 8695.77 35.020 241.790 7113.93 7195.48 3576.72S 1596.89W 5955465.01 N 610505.57 E 0.620 2797.08 8788.48 37.110 240.820 7188.87 7270.42 3602.94S 1644.75W 5955438.08N 610458.10E 2.337 2851.22 8882.44 37.890 241.320 7263.41 7344.96 3630.60 S 1694.82 W 5955409.67 N 610408.45 E 0.891 2907.94 8974.94 37.370 242.830 7336.67 7418.22 3657.06 S 1744.71 W 5955382.48 N 610358.96 E 1.144 2964.06 9069.32 36.640 241.670 7412.04 7493.59 3683.50 S 1794.98 W 5955355.29 N 610309.08 E 1.070 3020.53 9163.15 37.220 241.960 7487.04 7568.59 3710.13 S 1844.68 W 5955327.92 N 610259.79 E 0.645 3076.52 9256.47 38.250 241.360 7560.85 7642.40 3737.24 S 1894.94 W 5955300.06 N 610209.94 E 1.172 3133.23 9348.90 37.460 241.290 7633.82 7715.37 3764.46 S 1944.70 W 5955272.11 N 610160.59 E 0.856 3189.50 9440.99 36.910 241.680 7707.19 7788.74 3791.03 S 1993.61 W 5955244.81 N 610112.08 E 0.650 3244.75 9537.52 38.180 243.300 7783.73 7865.28 3818.19 S 2045.78 W 5955216.88 N 610060.32 E 1.666 3303.24 9631.37 37.930 244.120 7857.63 7939.18 3843.81S 2097.65W 5955190.48N 610008.84E 0.601 3360.89 .- 9725.11 38.360 245.690 7931.35 8012.90 3868.36S 2150.08W 5955165.15N 609956.78E 1.132 3418.67 - ~- 9820.39 39.160 249.760 8005.66 8087.21 3890.94 S 2205.26 W 5955141.75 N 609901.95 E 2.803 3478.29 9912.22 39.880 252.870 8076.50 8158.05 3909.65 S 2260.60 W 5955122.22 N 609846.89 E 2.293 3536.64 10005.35 40.270 254.750 8147.77 8229.32 3926.36 S 2318.18 W 5955104.66 N 609789.57 E 1.365 3596.33 10098.46 41.580 257.170 8218.12 8299.67 3941.14 S 2377.34 W 5955089.00 N 609730.63 E 2.208 3656.79 10191.85 42.720 259.940 8287.37 8368.92 3953.55 S 2438.76 W 5955075.67 N 609669.41 E 2.335 3718.48 10285.08 43.480 262.140 8355.44 8436.99 3963.47 S 2501.68 W 5955064.82 N 609606.64 E 1.807 3780.65 10379.51 43.240 261.600 8424.10 8505.65 3972.63 S 2565.86 W 5955054.69 N 609542.61 E 0.468 3843.73 10472.35 43.860 264.180 8491.39 8572.94 3980.54 S 2629.32 W 5955045.84 N 609479.27 E 2.028 3905.67 10566.02 45.520 266.730 8557.99 8639.54 3985.74 S 2694.98 W 5955039.66 N 609413.70 E 2.609 3968.66 10658.34 46.070 269.100 8622.36 8703.91 3988.14 S 2761.10W 5955036.28 N 609347.61 E 1.934 4031.06 10753.08 45.990 269.220 8688.14 8769.69 3989.14 S 2829.28 W 5955034.26 N 609279.46 E 0.124 4094.86 10856.51 47.290 265.900 8759.16 8840.71 3992.36 S - 2904.39 W 5955029.92 N 609204.41 E 2.650 4165.92 ----- --~ 31 December, 2001 - 13:42 Page 4 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-O2A MWD Your Ref: API 500292279301 Job No. AKMM11197, Surveyed: ,13 December, 2001 .~. ~ Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) ~. 10923.20 53.070 257.900 8801.89 8883.44 3999.72 5 . 2954.98 W 5955021.81 N 609153.93 E 12.638 4215.68 10953.53 56.280 257.890 8819.42 8900.97 4004.90 S 2979.17 W 5955016.26 N 609129.82 E 10.584 4240.09 10984.12 59.830 259.060 8835.61 8917.16 4010.08 S 3004.61 W 5955010.71 N 609104.47 E 12.050 4265.65 11015.29 62.890 260.430 8850.54 8932.09 4014.95 S 3031.52 W 5955005.44 N 609077.62 E 10.547 4292.48 11045.12 68.460 262.580 8862.83 8944.38 4018.95 S 3058.39 W 5955001.04 N 609050.81 E 19.792 4318.95 11076.52 73.510 264.830 8873.06 8954.61 4022.20 S 3087.89 W 5954997.35 N 609021.37 E 17.450 4347.58 11107.98 76.250 269.100 8881.27 8962.82 4023.80 S 3118.21 W 5954995.30 N 608991.08 E 15.732 4376.37 11143.78 77 .230 271.790 8889.48 8971.03 4023.52 5 3153.05 W 5954995.05 N 608956.24 E 7.809 4408.68 11172.69 77.950 274.100 8895.69 8977.24 4022.07 S 3181.24 W 5954996.08 N 608928.03 E 8.191 4434.38 11203.59 80.820 276.620 8901.38 8982.93 4019.23 S 3211.48 W 5954998.47 N 608897.75 E 12.268 4461.47 11235.99 85.140 274.550 8905.34 8986.89 4016.115 3243.47 W 5955001.12 N 608865.72 E 14.764 4490.09 11265.82 88.680 278.460 8906.95 8988.50 4012.735 3273.06 W 5955004.06 N 608836.08 E 17.666 4516.38 11297.44 90.550 279.630 8907.16 8988.71 4007.76 S 3304.28 W 5955008.56 N 608804.79 E 6.976 4543.60 11329.51 92.280 279.910 8906.37 8987.92 4002.32 S 3335.87 W 5955013.53 N 608773.12 E 5.465 4571.00 11359.10 92.030 281.030 8905.26 8986.81 3996.95 S 3364.95 W 5955018.47 N 608743.96 E 3.876 4596.09 11389.23 94.150 285.620 8903.63 8985.18 3990.02 S 3394.22 W 5955024.96 N 608714.60 E 16.759 4620.77 11420.91 91.170 281.850 8902.16 8983.71 3982.51 S 3424.95 W 5955032.01 N 608683.76 E 15.158 4646.61 11452.43 88.460 280.820 8902.27 8983.82 3976.31 S 3455.85 W 5955037.75 N 608652.77 E 9.198 4673.09 .--, 11482.31 87.200 281.130 8903.40 8984.95 3970.63 S 3485.16W 5955042.99 N 608623.37 E 4.342 4698.28 11514.36 87.750 302.240 8904.83 8986.38 3958.86 5 3514.75 W 5955054.32 N 608593.62 E 65.823 4721.49 11546.36 87.630 302.240 8906.12 8987.67 3941.81 5 3541.79 W 5955070.97 N 608566.32 E 0.375 4740.39 11577.59 87.720 302.510 8907.38 8988.93 3925.105 3568.14 W 5955087.28 N 608539.72 E 0.911 4758.79 11609.21 87.600 302.100 8908.67 8990.22 3908.21 S 3594.85 W 5955103.77 N 608512.77 E 1.350 4777.44 11639.76 87.630 302.620 8909.94 8991.49 3891.88 S 3620.63 W 5955119.72 N 608486.75 E 1.703 4795.44 11670.67 84.110 307.660 8912.17 8993.72 3874.145 3645.83 W 5955137.07 N 608461.28 E 19.852 4812.38 11702.91 83.860 309.160 8915.55 8997.10 3854.22 S 3670.95 W 5955156.61 N 608435.87 E 4.692 4828.45 11732.24 83.870 306.740 8918.69 9000.24 3836.29 S 3693.95 W 5955174.20 N 608412.61 E 8.204 4843.27 11765.58 83.280 311.040 8922.42 9003.97 3815.50 S 3719.73 W 5955194.61 N 608386.52 E 12.938 4859.63 11797.57 83.080 307.900 8926.22 9007.77 3795.31 S 3744.25 W 5955214.43 N 608361.70 E 9.766 4875.04 11830.33 82.860 299.900 8930.23 9011.78 3777.19 S 3771.21 W 5955232.15 N 608334.47 E 24.245 4893.48 - ------------- ------- 31 December, 2001 - 13:42 Page 5 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-02A MWD Your Ref: API 500292279301 Job No. AKMM11197, Surveyed:;13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) ~,- 11862.14 86.140 304.620 8933.28 9014.83 3760.29 S 3797.97 W 5955248.64 N 608307.46 E 18.011 4912.18 11891.98 86.510 314.920 8935.20 9016.75 3741.275 3820.83 W 5955267.32 N 608284.32 E 34.469 4926.47 11920.70 86.860 309.940 8936.86 9018.41 3721.93 S 3841.99 W 5955286.35 N 608262.88 E 17.354 4939.07 11953.22 90.560 299.600 8937.60 9019.15 3703.42 S 3868.65 W 5955304.46 N 608235.94 E 33.757 4957.09 11984.39 90.250 279.530 8937.37 9018.92 3693.03 5 3897.87 W 5955314.40 N 608206.57 E 64.395 4980.47 12014.72 89.600 279.880 8937.41 9018.96 3687.92 S 3927.77 W 5955319.07 N 608176.60 E 2.434 5006.41 12047.42 86.960 282.100 8938.40 9019.95 3681.69 5 3959.85 W 5955324.82 N 608144.43 E 10.546 5033.97 12077.41 86.570 276.930 8940.09 9021.64 3676.745 3989.37 W 5955329.33 N 608114.84 E 17.261 5059.62 12107.73 86.260 285.510 8941.99 9023.54 3670.86 5 4019.02 W 5955334.77 N 608085.10 E 28.261 5085.05 12136.52 85.870 272.900 8943.97 9025.52 3666.27 S 4047.32 W 5955338.93 N 608056.74 E 43.717 5109.69 12169.99 86.880 285.820 8946.10 9027.65 3660.85 S 4080.21 W 5955343.86 N 608023.78 E 38.642 5138.30 12199.71 86.980 278.840 8947.69 9029.24 3654.52 S 4109.18W 5955349.76 N 607994.71 E 23.455 5162.94 12230.59 86.610 280.110 8949.42 9030.97 3649.44 S 4139.59 W 5955354.39 N 607964.23 E 4.277 5189.37 12263.58 86.660 280.760 8951.35 9032.90 3643.48 S 4171.98 W 5955359.87 N 607931.76 E 1.973 5217.31 12294.90 86.610 274.000 8953.19 9034.74 3639.46 S 4202.97 W 5955363.42 N 607900.71 E 21.547 5244.67 12325.03 90.490 287.490 8953.96 9035.51 3633.86 S 4232.49 W 5955368.58 N 607871.11 E 46.566 5270.08 12357.57 93.940 287.780 8952.70 9034.25 3624.01 S 4263.47 W 5955377.97 N 607839.99 E 10.640 5295.29 --. 12388.02 94.120 282.980 8950.56 9032.11 3615.96 S 4292.75 W 5955385.58 N 607810.59 E 15.736 5319.58 12419.09 93.940 279.770 8948.38 9029.93 3609.84 S 4323.13 W 5955391.24 N 607780.12 E 10.322 5345.60 12450.45 93.390 305.900 8946.34 9027.89 3597.80 S 4351.72 W 5955402.86 N 607751.36 E 83.167 5367.79 12480.44 93.960 280.130 8944.38 9025.93 3586.20 S 4379.03 W 5955414.05 N 607723.87 E 85.770 5388.94 12511.58 95.000 312.320 8941.88 9023.43 3572.67 S 4406.51 W 5955427.17 N 607696.19 E 103.100 5409.55 12542.81 95.190 309.900 8939.11 9020.66 3552.22 S 4429.95 W 5955447.27 N 607672.46 E 7.742 5423.86 12574.61 95.330 310.740 8936.20 9017.75 3531.73 S 4454.09 W 5955467.40 N 607648.01 E 2.667 5438.81 12607.14 94.810 280.350 8933.25 9014.80 3517.92 S 4482.98 W 5955480.77 N 607618.92 E 93.061 5460.62 12638.60 94.010 315.960 8930.75 9012.30 3503.36 S 4510.18W 5955494.93 N 607591.50 E 112.873 5480.59 12669.42 93.670 311.560 8928.69 9010.24 3482.10 S 4532.39 W 5955515.86 N 607568.98 E 14.287 5493.45 12700.80 92.500 311.790 8927.00 9008.55 3461.26 S 4555.79 W 5955536.34 N 607545.27 E 3.800 5507.59 12732.18 93.240 314.260 8925.43 9006.98 3439.88 5 4578.70 W 5955557.38 N 607522.04 E 8.207 5521.06 12763.39 94.000 277.680 8923.39 9004.94 3426.4 7 S 4606.23 W 5955570.38 N 607494.32 E 116.988 5541.75 - -- ___n____- -,,-- - -- -'-_--__n______--_u _--n--____'-- 31 December, 2001 - 13:42 Page 6 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-02A MWD Your Ref: API 500292279301 Job No. AKMM11197, Surveyed: ,13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) --'0, 12794.25 92.250 313.650 8921.65 9003.20 3413.34 S 4633.54 W 5955583.10 N 607466.82 E 116.513 5562.35 12825.57 92.400 318.220 8920.38 9001.93 3390.86 S 4655.30 W 5955605.26 N 607444.72 E 14.587 5574.35 12857.62 92.490 312.820 8919.01 9000.56 3368.02 S 4677.72 W 5955627.76 N 607421.96 E 16.836 5586.84 12888.08 92.710 317.440 8917.63 8999.18 3346.46 S 4699.19 W 5955648.99 N 607400.18 E 15.169 5598.90 '- 12918.98 93.390 319.150 8915.98 8997.53 3323.42 S 4719.71 W 5955671.72 N 607379.31 E 5.948 5609.56 12948.91 93.700 319.320 8914.13 8995.68 3300.80 S 4739.22 W 5955694.05 N 607359.47 E 1.181 5619.41 12980.74 91.850 317.560 8912.59 8994.14 3277.01 S 4760.31 W 5955717.52 N 607338.03 E 8.018 5630.31 13010.52 91.630 318.850 8911.69 8993.24 3254.82 S 4780.15 W 5955739.42 N 607317.86 E 4.392 5640.63 13042.58 90.620 310.980 8911.05 8992.60 3232.21 S 4802.83 W 5955761.69 N 607294.84 E 24.744 5653.44 13072.88 90.250 317.760 8910.82 8992.37 3211.03 S 4824.47 W 5955782.54 N 607272.88 E 22.409 5665.81 13104.90 93.880 315.240 8909.67 8991.22 3187.82 S 4846.50 W 5955805.41 N 607250.52 E 13.797 5677.79 13135.00 94.480 312.980 8907.48 8989.03 3166.93 S 4868.05 W 5955825.98 N 607228.66 E 7.749 5690.18 13165.55 94.220 314.570 8905.16 8986.71 3145.86 S 4890.04.W 5955846.73 N 607206.35 E 5.259 5702.92 13197.81 93.920 310.440 8902.87 8984.42 3124.12 S 4913.76 W 5955868.11 N 607182.31 E 12.804 5717.02 13228.83 93.170 320.530 8900.95 8982.50 3102.07 S 4935.44 W 5955889.83 N 607160.31 E 32.555 5729.10 13260.26 93.010 312.610 8899.25 8980.80 3079.30 S 4957.00 W 5955912.28 N 607138.41 E 25.167 5740.81 13294.87 93.020 314.900 8897.43 8978.98 3055.40 S 4981.96 W 5955935.81 N 607113.10 E 6.607 5755.27 ~ 13326.40 94.820 312.770 8895.27 8976.82 3033.61 S 5004.65 W 5955957.25 N 607090.09 E 8.832 5768.39 13355.46 95.210 317.240 8892.73 8974.28 3013.15S 5025.11 W 5955977.41 N 607069.32 E 15.382 5779.92 13388.58 95.380 318.080 8889.67 8971.22 2988. 77 S 5047.32 W 5956001.45 N 607046.75 E 2.577 5791.65 13419.38 93.980 318.530 8887.16 8968.71 2965.85 S 5067.74 W 5956024.07 N 607025.99 E 4.773 5802.24 13449.48 93.480 314.870 8885.20 8966.75 2943.99 S 5088.34 W 5956045.61 N 607005.07 E 12.247 5813.39 13483.04 93.790 317.140 8883.07 8964.62 2919.90 S 5111.60 W 5956069.36 N 606981.45 E 6.813 5826.20 13510.19 93.710 320.390 8881.30 8962.85 2899.53 S 5129.45 W 5956089.46 N 606963.30 E 11.949 5835.34 13541.61 93.360 316.060 8879.36 8960.91 2876.15 S 5150.34 W 5956112.53 N 606942.06 E 13.800 5846.20 13573.38 93.380 319.360 8877.49 8959.04 2852.69 S 5171.68 W 5956135.66 N 606920.38 E 10.369 5857.45 13603.72 93.400 314.100 8875.70 8957.25 2830.64 S 5192.43 W 5956157.40 N 606899.30 E 17.307 5868.68 13635.95 93.210 315.730 8873.84 8955.39 2807.93 S 5215.22 W 5956179.77 N 606876.18 E 5.083 5881.55 13666.29 93.740 318.900 8872.00 8953.55 2785.67 S 5235.74 W 5956201.72 N 606855.32 E 10.574 5892.49 13695.13 93.270 319.300 8870.24 8951.79 2763.91 S 5254.59 W 5956223.20 N 606836.15 E 2.138 5902.04 --.. ----- --.. '-- -, ---", - ----- 31 December, 2001 - 13:42 Page 7 of 9 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-O2A MWD Your Ref: API 500292279301 Job No. AKMM11197, Surveyed: .13 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) '-', 13726.22 92.740 320.040 8868.61 8950.16 2740.24 S 5274.69 W 5956246.56 N 606815.71 E 2.925 5912.06 13758.02 92.570 314.540 8867.13 8948.68 2716.91 S 5296.22 W 5956269.57 N 606793.82 E 17.285 5923.54 13788.10 92.840 316.370 8865.71 8947.26 2695.50 S 5317.30 W 5956290.67 N 606772.43 E 6.143 5935.30 13818.75 93.480 308.090 8864.02 8945.57 2674.95 S 5339.94 W 5956310.88 N 606749.48 E 27.054 5948.83 13853.85 93.680 309.610 8861.83 8943.38 2652.97 S 5367.22 W 5956332.44 N 606721.88 E 4.359 5966.15 13884.42 94.250 314.750 8859.71 8941.26 2632.50 S 5389.81 W 5956352.57 N 606698.98 E 16.877 5979.67 13915.49 95.400 315.330 8857.10 8938.65 2610.60 S 5411.69 W 5956374.15 N 606676.78 E 4.142 5991.99 13948.78 95.080 308.030 8854.05 8935.60 2588.57 S 5436.43 W 5956395.81 N 606651.72 E 21.858 6006.93 13979.02 93.110 312.020 8851.89 8933.44 2569.17 S 5459.52 W 5956414.86 N 606628.34 E 14.684 6021.30 14009.87 93.150 317.790 8850.21 8931.76 2547.44 S 5481.33 W 5956436.27 N 606606.21 E 18.676 6033.62 14041.74 93.400 316.060 8848.39 8929.94 2524.19 S 5503.06 W 5956459.18 N 606584.13 E 5.476 6045.32 14072.52 93.390 316.180 8846.57 8928.12 2502.05 S 5524.36 W 5956481.01 N 606562.51 E 0.391 6057.01 14103.81 93.240 314.420 8844.76 8926.31 2479.84 S 5546.33 W 5956502.88 N 606540.21 E 5.636 6069.31 14135.08 93.830 315.050 8842.83 8924.38 2457.88 S 5568.50 W 5956524.51 N 606517.71 E 2.757 6081.88 14165.39 93.920 313.130 8840.78 8922.33 2436.84 S 5590.22 W 5956545.23 N 606495.68 E 6.327 6094.38 14197.00 94.500 314.470 8838.46 8920.01 2415.02 S 5612.97 W 5956566.71 N 606472.61 E 4.609 6107.55 14229.38 94.660 316.690 8835.87 8917.42 2391.97 S 5635.56 W 5956589.42 N 606449.68 E 6.852 6120.11 ,,-. 14260.98 94.960 312.090 8833.22 8914.77 2369.95 S 5658.06 W 5956611.10 N 606426.86 E 14.537 6132.96 14290.79 95.110 318.480 8830.60 8912.15 2348.86 S 5678.94 W 5956631.88 N 606405.66 E 21.359 6144.66 14322.32 96.200 310.020 8827.49 8909.04 2326.98 S 5701.39 W 5956653.42 N 606382.88 E 26.923 6157.53 14352.64 96.890 314.000 8824.03 8905.58 2306.83 S 5723.77 W 5956673.24 N 606360.21 E 13.238 6170.96 14416.12 98.870 314.440 8815.33 8896.88 2262.97 S 5768.83 W 5956716.41 N 606314.50 E 3.194 6196.80 14460.77 98.440 314.570 8808.61 8890.16 2232.03 S 5800.31 W 5956746.88 N 606282.56 E 1.005 6214.75 14500.00 98.440 314.570 8802.85 8884.40 2204.80 S 5827.96 W 5956773.70 N 606254.51 E 0.000 6230.48 Projected Survey - --- ~-._.- -.. -- .-------_..- .~._------- 31 December, 2001-13:42 Page 8 of 9 DrillQllest 2.00.08.005 . Sperry-Sun Drilling Services Survey Report for W-O2A MWD Your Ref: API 500292279301 Job No. AKMM11197, Surveyed:.13 December, 2001 . North Slope Alaska Alaska Drilling & Wells PBU WOA W Pad All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. ~. Magnetic Declination at Surface is 26.240° (31-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 248.491° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14500.00ft., The Bottom Hole Displacement is 6231.07ft., in the Direction of 249.278° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4243.43 4307.76 14500.00 4105.83 4168.61 8884.40 797.51 S 810.30 S 2204.80 S 451.54 W 457.26 W 5827.96 W Tie On Point Window Point Projected Survey --. Survey tool program for W-02A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 14500.00 8884.40 MWD Magnetic (W-O2) .--- ------ 31 December, 2001 - 13:42 Page 9 of 9 DrillQuest 2.00.0B.005 .-- -.- - --- Sc~lun1bePßer Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503.5711 ATTN: Sherrle '"- Well D.S. 1-31 NK-22A W-o2A D.S. 4-31 D.S.5-128 D.S.11-16 D.S.11-18 '- Job # Log Description PRODUCTION PROFILE STATIC PRESSUREITEMP 22005 MCNL 22016 RST-SIGMA 22017 MCNL 22020 RST -SIGMA 22022 RST-SIGMA PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: RECEIVED JAN 2 5 2002 AIãIiãORGãSCons. ConInisaion Anchorage Date 01/07/02 01/09102 12/19/01 12/11/01 12/16/01 12/23/01 12/26/01 Blueline 01/24/02 NO. 1742 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Received & Jbe p D FW: Details of Abandonment on W-O2 (" { .Subject: FW: Details of Abandonment on W-O2 Date: Thu, 27 Dee 2001 12:47:44 -0600 From: "Magee, D Neil" <MageeDN@BP.com> To: "Winton Aubert (E-mail)" <winton_aubert@admin.state.ak.us> Winton, Here's the cement volume detail for the squeeze below the EZSV which formed the abandonment of W-O2. Regards, Neil Magee > -----Original Message----- > From: Magee, D Neil > Sent: Wednesday, October 24,2001 12:43 PM > To: Tom Maunder (E-mail) > Cc: Robertson, Brian B > Subject: Details of Abandonment on W-02À > > Tom, > > > > > > > > > > > > > > If you have any further questions on the abandonment please let me know. > > > > > > > > > As you requested, I have provided below the details of the abandonment slurry for well W-02A. Our intention is to meet the requirements set --- forth in Article 20AAC25 .105. (R) (1) (C). We will be abandoning the exposed gravel pack interval at 4452' to 4853' by placing a cement retainer above the interval at 4290' and pressure testing the retainer/casing above to 4000 psi. We will then squeeze below the retainer with 15.8 ppg G cement (1.17cuft/sk). We intend on filling the void beneath the retainer, the void across the gravel pack assembly and the casing below the gravel pack assembly to the float collar depth of 5465'. This will entail pumping a cement volume of 575 cuft. Regards, Neil Magee Alaska Drilling & Wells 907 564-5119 Office 907 564-4040 Fax 907 240-8038 Cell 1 of 1 12/27/01 10:07 AM c- ;Lot -IQ? ?-ùl- f 5;\ ;).. D I ~ ;1 '1 ~ 12/19/01 SC~Itn'lpger NO. 1703 Alaska Data & ConsuIUng Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sheme Company: State of Alaska Alaska 011 & Gas Cons Comm Attn: Usa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date Bluellne Sepia Color Prints CD D-18A 21480 RST -SIGMA 11/08/01 1 1 1 D.S. 1-Q4A 21519 PP, ARC DATA 08/28/01 1 D.S. 1-Q4A 21519 MD VISION RESISTIVITY 08/28/01 1 1 D.S. 1-Q4A 21519 TVD VISION RESISTIVITY 08/28/01 1 1 W-Q2A 21515 CDR DATA 11/22101 1 W-Q2A 21515 MD CDR RESISTIVITY 11/22101 1 1 W-Q2A 21515 TVD CDR RESISTIVITY 11/22101 1 1 - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 AnN: Sherrie Recelve~ ú.. !:2.0 f1,Q" - ./ I RECEIVED Date Delivered: DEC 2 1 2001 AIBka'ðit& Gas Coos. GamRu8SÏQn Anchorage . ( STATE OF ALASKA r ~i()~ O'V)- ALASKJI: ~,L AND GAS CONSERVATION COMJ:~310N, £:i APPLICATION FOR SUNDRY APPROVAL I ,-/0 vJ6f\ ! ¿J (?I 0 I Þ- \ ';,), lD L 1. Type of Request: 0 Abandon 0 Alter Casing iii Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 0 Suspend 0 Plugging 0 Time Extension 0 Perforate 0 Repair Well 0 Pull Tubing 0 Variance 0 Other 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: 1m Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) Plan RKB = 77' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 1192' SNL, 1190' WEL, SEC. 21, T11N, R12E, UM At top of productive interval 4530' SNL, 465' WEL, SEC. 20, T11 N, R12E, UM (As Planned) At effective depth 8. Well Number W-02A 9. Permit Number 201-214 10. API Number 50- 029-22793-01 11. Field and Pool Prudhoe Bay Field 1 Prudhoe Bay Pool At total depth 3572' SNL, 1899' WEL, SEC. 20, T11 N, R12E, UM (As Planned) 12. Present well condition summary Total depth: measured 10840 feet Plugs (measured) true vertical 8830 feet Effective depth: measured feet true vertical feet Set EZSV at 4295', P&A W-02 with 102 Bbls Class 'G', Set Whipstock on top of EZSV (11/01) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 801 30861 20" 13-3/8" 260 sx Arcticset (Approx.) 2403 sx CS III, 478 sx Class 'G' 801 3118' 80' 3011' 5518' 6722' 9-5/8" 7" 910 sx Class 'GI Not Cemented, Unable to Circulate 4277' (TOW) 3845' - 10567' 4139' 37161 - 8639' Perforation depth: measured N/A RECEIVED true vertical N/A Tubing (size, grade, and measured depth) N/A DEC 0 4 2001 Packers and SSSV (type and measured depth) 7" x 9-5/8" 'ZXP' liner top packer at 3845' Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments 181 Description Summary of Proposal 0 Detailed Operations Program 15. Status of well classifications as: 181 Oil 0 Gas 0 Suspended 0 BOP Sketch 14. Estimated date for commencing operation November 30, 2001 16. If proposal was verbally approved ).~-1}Y1 Tom Maunder * 11/30/2001 Name of approver Date Approved Contact Engineer Name/Number: Neil Magee, 564-5119 17. I ~ereby certify that the foregoing i ~true and correct to the best of my knowledge Signed B. R b rt ..." ß / Title Senior Drilling Engineer rlan 0 e son .r~ . ..: . . . .'1. .. ... ':C:°Ï11mission~Üt;,()nly'. Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 1 0- ~~ tO~~~~ vJ~ I ./ Approved bY order of the Commission - .. . ft. . Rv Commissioner Date \ ¡ 4r/o:;-. Form 10-403 Rev. 06/15/88 - - . Submit I~-Triþlicate Service Prepared By Name/Number: Terrie Hubble, 564-4628 Date fl lit/;>! . ". . Approval No. ~t - æ<o C"'~tGINAL (' ,\t~~I. b P .........~"4 ,..~.--- ~4!:- --:4!:~ '*.~ F'-' .','t\Yi. "" ~ To: Tom Maunder, AOGCC Date: December 3, 2001 From: Neil Magee (BP Alaska) Subject: Sundry to Cover Chan2e of Operations on W -O2A Attached is a Sundry to cover the Change in Well Plans in well W -02A brought about by our failure to case and cement the 7" intermediate hole as programmed in the Approved Permit to Drill. As passed on to you by Brian Robertson (Prudhoe Bay Senior Drilling Engineer) on 30 November, we were unable to run the 7" casing to the prescribed casing point due to deteriorating hole conditions. As a consequence we set the 7" casing some 273' above the programmed casing point (Top Sag River), and were unable to initiate circulation to cement this liner. Our plan forward is to run and cement a second 5-1/2" intermediate liner to the top of the Sag River to cover the exposed Kingak shale. Afterwards we will continue drilling the well as per the original plan, however the hole size in the production hole will be reduced to 4-3/4" and we will complete with a 3-1/2" production liner. Should you have any questions concerning the amended drilling plan, please do not hesitate to call me at 564-5119. Sincerely, ~ -f}.J1IYÝ/r Neil Magee Prudhoe Bay Drilling Engineer (' ( W-O2A Revised Well Details 8-1/2" 8-1/2" 4-3/4" Tubin f {vJGk- '-I {I at: . tJ. C<-- ,., J D .---- Grade Conn Length Top 8tm MDIT D M DITVD 7" 26# L-80 BTC-Mod -6274' 38 ' 3716' 10,567' 1 8639' 5-1/2" 17# L-80 IBT -Mod -400' 10 ~75' 18572' 10,840' 1 8922' 3-1/2" 9.2# L-80 STL -3800' 10, 25' 18750' 14,486' 1 8922' 4-1/211 12.6# L-80 IBT-Mod -10,455' GL 10,455' 1 8685' Production Interval Mud Properties: Quikdril-n Fluid 4-3/4" hole Density Plastic Yield Point MBT API FL El Viscosity (lb/1 00ft2) Dril-n 8.7-8.9+ 5-8 20- 25 <3 N/C 8.5-9.0 Cement Program Casing Size 1 5-1/2" Intermediate Liner I Basis: Lead: None Tail: Based on 82' of 5-1/2" shoe track, 273' of open hole with 30% excess, 150' of 7" x 5Y2" liner lap, and 200' of 7" x 4" DP annulus volume. Tail TOC: -150' above Liner toP. Fluid Sequence & Volumes: Pre 10 bbls CW1 00 at 8.3 ppg Flush Spacer NA Lead None Tail 22 bbl 1 123 fe 1 80 sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.54ft/sk, (use actual circulating temps recorded by MWD at TO), TT = Batch Mix +1- 4 hrs Casing Size 13-1/2" Production Liner I Basis: Lead: None Tail: Based on 82' of 4-112" shoe track, 3646' of open hole with 30% excess, 300' of 7/5-1/2" x 4%" liner lap, and 200' of 7" x 4" DP annulus volume. Tail TOC: -150' above Liner top. Fluid Sequence & Volumes: Pre 10 bbls CW100 at 8.3 ppg Flush Spacer 20 bbls MudPUSH viscosified spacer weighted to 9.5 ppg Lead None Tail 52 bbl 1 292 fe 1 190 sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.54ft/sk, (use actual circulating temps recorded by MWD at TO), TT = Batch Mix +1- 4 hrs (' ( Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3900 psi @ 8875' TVDss - Zone 4 . Maximum surface pressure: 3013 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/h) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater / 6.8 ppg Diesel . ( (I" W -O2A Revised Intermediate/Production Hole Plan RiQ Operations: 1. Run 7", 26# intermediate drilling liner to 10567'. (-270' Kingak left open.) POH. 2. Make up and RIH with 6-1/2" clean out assembly. Drill out uncemented liner and clean out to we~D at 1 0840' . 3. Run and cement. 5" FJ intermediate drilling liner at 10840' to cover up exposed Kingak fo ation. ./ 4. Pressure test liner laps to 3500 psi. 5. Make up and RIH with a 4-3/4" directional assembly (with MWD/GR/RES). Drill landing collar and clean out shoe track. /' 6. Drill 20' of new formation. Conduct FIT to 9.9 ppg EMW. 7. Dri!V'4-3/4" production section as per directional plan to an estimated TD of 14,486' MD (8922' TVD). 8. Run and cement a 3 ¥2", 9.2# L-80 solid production liner throughout the 4-3/4" wellbore. Displace well to perf pill across liner and after setting liner top packer and circulating out excess cement displace to clean seawater above liner top. 9. Test the 3-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3500 psi for 30 min. POH LD excess 4" drill pipe. 10. Perforate well via TCP or complete well and perforate via coi/- Issue to be decided. 11. Run a 4-1/2", 12.6# L-80 IBT-Mod completion tying into the 4-1/2" liner top. 12. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. v" 13. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 14. Freeze protect the well to -2200' and secure the well. 15. Rig down and move off. TREE: 4-1/6" 5M L-80 WELLHEAD: 13-5/8" 5M FMC Gen 5 133/8",68 #Ift, L-80, BTC I 3118' I 4-1/2"12.6#, L-80 IBTTubing +/- 10,570' Window Milled from Whipstock Top of Window at +/- 4,252' MD Bridge Plug set at 4,298' MD 9-5/8" HES Versatrieve Packer I 4,432' I ......::::I 9-518" BWD Sump packer I 5,547' I 9-5/8",47 lIft, L80, BTC 15,547' 1 W-O2A Proposed Completion Cellar Elevation = ???' Nabors 9ES RKB = ????' 4-1/2" 'X' Landing Nipple with 3.81 "seal bore. I 2200' I 4-112" Cameo Gas Lift Mandrels with handling pups installed above and below. GAS LIFT MANDRELS I ! No I fvD I Size I Valve Type! I 7 I I i41/2"XH/2"1 RPShear ! ! 6 ¡ : 141/2" x 1-1/2" I DV i i 5 i 141/2" x 1-1/2" !,' DV : I' 4 'I ' 41/2" X 1-1/2" ! " ! ,I . ¡ 3: i41/2"x1" I " ! I , I , , i 2 i, !41/2"x1" [ " ; ¡. " '" ¡ 1 ¡41/2"x1" ¡ ! -., 1 3,845' 1 BAKER 7" x 9-5/8" 'Flex-Lock' Hydraulic Liner Hanger with ZXP liner top packer 4-1/2" 'X Nipple with 3.81" seal bore. 7"x 41/2" Baker S-3 Production Packer 4-1/2" 'X Nipple with 3.81 "seal bore. 4-112" 'XN' Nipple 4-1/2" WireLine Entry Guide spaced-out into liner top. ~I x 7" Flex Lock hanger and tie-back sleeve and ZXP packer 5-112" x 7" HMC hanger and tie-back sleeve and CPH packer 110,567'17" 26#, L-80, BTC-M Casing ~~J 10,840' 1~~1~~:: ~~#,.~~.80, STL-FJ Csg 3-1/2" 9.2 lIft, STL FJ I +/-14,486' I I +/-14,402' I Plug Back Depth .--~, 5-1/2" .0012" Gage screen Perf intervals from 4560-4724',4763-4846" Date Comments PRUDHOE BAY UNIT WELL: W-O2A API NO: 50-029-22793 Rev By NM 11/13/01 Proposed Completion 12/4/01 Prudhoe Bay Drilling (' ~lf~1fŒ rnJ~ lÆ~lÆ~lK\lÆ (' ALAS KA. 0 IL AND GAS COl\TSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]rH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit W -02A BP Exploration (Alaska), Inc. Pennit No: 201-214 Sur Loc: 1192' SNL, 1190' WEL, Sec. 21, TIIN, RI2E, UM Btmhole Loc. 3572 SNL, 1899' WEL, Sec 20, TIIN, RI2E, UM Dear Mr. Robertson: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit W -02A. 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. S incerel y, ~~a~ Chair BY ORDER OF THE COMMISSION DATED this 16th day of November, 2001 jj c/Enc1osures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA ALASKA(_,L AND GAS CONSERVATION COMrJ PERMIT TO DRILL 20 AAC 25.005 ðM\t "'ilbID' kIlLS- 310N 1 a. Type of work 0 Drill 1m Redrill 1 b. Type of well 0 Exploratory ~ratigraPhiC Test 1m Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas Sin~ Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (OF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 77' Prudhoe Bay Field 1 Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 £.">z8.2tz4--'ADL 028263~- 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1192' SNL, 1190' WEL, SEC. 21, T11 N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 4530' SNL, 465' WEL, SEC. 20, T11N, R12E, UM W-02A Number 2S100302630-277 At total depth 9. Approximate spud date 3572' SNL, 1899' WEL, SEC. 20, T11N, R12E, UM 11/15/01 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047452,1707' MD W-37 is 206' away at 4521' MD 2560 14258' MD 1 8936' TVD 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 4279' MD Maximum Hole Angle 94 Maximum surface 3013 psig, At total depth (TVD) 8875' 1 3900 psig 18. Casing Program Specifications Setting Depth Ow:mtitv nf (' c ii7P. Tln - -~ Hole r ""..1. r Lennth MD TVD MD TVD linrilino st~ne d::Jt~ \ ~.,r;.¡n~ 8-1/2" 7" 26# L-80 BTC-M 6476' 4129' 3989' 10605' 88121 ~49 sx Class 'G'. 412 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3804' 104551 8685' 142591 8937' 27 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 5560 feet Plugs (measured) true vertical 5400 feet Effective depth: measured 5464 feet Junk (measured) true vertical 5305 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset (Approx.) 80' 80' Surface 3086' 13-3/8" 2403 sx CS III, 478 sx Class 'G' 3118' 3011' Intermediate Production 5518' 9-5/8" 910 sx Class 'G' 5547' 5387' Liner RECE IVED Perforation depth: measured 4560' - 4724', 4763' - 4846' NOV 0 2 2001 true vertical 4416' - 4577', 4616' - 4697' Alaska Oil & Gas Cons, Comm' . A h 18Sl00 nc oraop. 20. Attachments 1m Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Neil Magee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoin is Ir e a~ÎcorreCI 10 the best of my knowledge 111"/01 Signed Brian Robertson "1 '\T.r ~ Title Senior Drilling Engineer Date .. ' " " ,,::.t, ',:': .,~.', ':" '- ..':",::'",,' ',', ::.',I,COI11ÓJ,iS$iøtl::Usê::Ørily:,::,I".,":,,:, , "'.,',:,':,:,',,;,.',; ",i """",:;, :,'.'~:f'~:,' ",,:' " ," ..' " " , ", ' ,'",', "'. .." , .. -'" Permit Number, y: API Number APPro,;, ~ Datà I See cover letter ;¿C~ I-. 2/ 50- 029-22793-01 III '0 for other reQuirements Conditions of Approval: Samples Required DYes IX] No Mud Log Reqúl,led I DYes ~No Hydrogen Sulfide Measures &J Yes DNo Directional Survey Required IXI Yes DNo Required Working Pressure for BOPE D2K D3K D4K D5K D 10K D15K ~3.5K psi f~ OthtJrigina1 Signed By by order of I J!I {¡;!J I Approved Bv Cammy Oechsli ....... - . ~ . .c )rTlmi sioner the commission Date Form 10-401 Rev. 12-01-85 U t. \ I b 11\ A~ ~utSmit If, Triplicate (' (' ¡Well Name: I W -O2A Drill and Complete Summary l.!ïPe of Aedrill (producer or injector)-=-J Producer Suñace Location: KOP: x = 612,048.950 / Y = 5,959,065.140 40871 FSL 11911 FNL 1189' FEL 4089' FWL See 21, T11 N, R12E X = 611,605.80 / Y = 5,958,254.14 3283' FSL 1996' FNL 1646' FEL 3632' FWL , See 21 T11 N, R12E X = 607,552.00 / Y = 5,955,660.00 748' FSL 4530' FNL 465' FEL 4814' FWL , See 20, T11 N, R12E X = 606,101.00/ Y = 5,956,598.00 1707' FSL 3572' FNL 1899' FEL 3379' FWL , See 20, T11 N, R12E Target Location: Bottom Hole Location: 1 AFE Number: 4P1423 I Estimated Start Date: 111/15/01 ~ Nabors 9ES l.Qperatin~s to complete: 128.0 I TVD: 18936' I I I MD: 114,258' I I Cellar Elevation: 147' I AKa: 177' I Well Desig!!Jconventional, slimhole, etc.)-=-I Conventional Big Bore - 9-5/8" Sidetrack ~ective: I Complete well as Zone 4B Horizontal Producer to replace original wellbore. Formation Markers Formation Tops MD TVDss Comments UG1 4182' KOP Top Schrader (Ma sand) 4480' 2100 psi I 9.0 PPQ EMW Hvdrocarbon BearinQ WS 4615' 2175 psi I 9.1 PPQ EMW Schrader Oa 4894' 2210 psi 8.7 PPQ EMW CM3 5144' 2325 psi 8.7 PPQ EMW Schrader Obf base) 5257' 2365 psi 8.7 PPQ EMW ) Hvdrocarbon BearinQ CM2 5585' 2460 psi I 8.5 PPQ EMW CM1 6195' 2725 psi 8.5 PPQ EMW THRZ 6673' 2940 psi 8.5 PPQ EMW BHRZ 6946' 3060 psi 8.5 PPQ EMW TKUP 6946' 3600 psi 10.0 ppg EMW) Hvdrocarbon BearinQ LCU 6946' 3060 psi 8.5 PPQ EMW TMLV 7037' 3100 psi 8.5 PPQ EMW TKNG 7532' 3315 psi 8.5 PPQ EMW Top KinQak JG) 7549' 3325 psi 8.5 PPQ EMW Top KinQak JF 7860' 3460 psi 8.5 PPQ EMW Top KinQak JEI 8054' 3550 psi 8.5 PPQ EMW Top KinQak j JD) 8268' 3640 psi 8.5 PPQ EMW Top Kinaak I JC) 8485' 3735 psi 8.5 PPQ EMW Top Kinaak JB 8590' 3780 psi 8.5 PPQ EMW W-02A Draft Well Plan Page 1 ( 8650' 8725' 8750' 8800' 8820' 8840' 8845' 8875' 8990' Not Reached c IT b" p f asing, u Ing rogram Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDrrVD MDrrVD 8-1/2" 7" 26# L-80 BTC-Mod -6476' 4129' 13989' 10,605' 1 8812' 6-1/8" 4-1/2" 12.6# L-80 I BT -Mod -3804' 10,455' 1 8685' 14,259' 1 8937' Tubing 4-1/211 12.6# L-80 IBT-Mod -10,455' GL 10,455' 18685' -940 throu h reservoir section All wells pass BP Close Approach guidelines. The nearest close approach well is W-37 which is -206' center to center at 4,521' MD and passes under Ma'or Risk rules. Standard MWD Surve s from kick-off to TD. I e rac n erva u ro~ e les: UI oe Density Plastic Yield Point tauo Fluid Loss .eH Viscosity (lb/1 OOft~) (lb/1 00n2) Initial 9.5 10-15 25 - 35 4-8 API <8 8.5 - 9.5 200' above H RZ 10.8 15 - 25 20 - 27 3-7 HTHP<10 8.5-9.5 Final 10.8 15 - 25 20 - 27 3-7 HTHP<10 8.5 - 9.5 ro uc Ion n erva U roper les: UI rI -n UI oe Density Plastic Yield Point MBT API FL aJ:i ViscosiW (lb/1 OOft~) Dril-n 8.7-8.9+ 5-8 20 - 25 <3 N/C 8.5-9.0 LSND PV 10 - 15 S.d t kit 1M d P rf LSND FI .d P d f I t 1M d P f Q .kd 1 W-02A Draft Well Plan Whipstock Window in 9-5/8" Yield Point tauO H 30 - 35 4 - 8 8.5 - 9.5 HTHP ee's/3D min <10 8 1/2" h I FI .d 6 1/8" h I Page 2 (' r ~ Hydraulics: Intermediate Hole: 8-1/2" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 4129'-10605' 550 4" 17.5# 208 3600 11.5 N/A 6 x14 .902 Production Hole: 6 1/8" Interval Pump Drill Pipe AV (fpm) Pump PSI ECD Motor Jet Nozzles TFA GPM ppg-emw ("/32) (in2) 10605' - 266 4" 17.5# 111 2900 10.0 N/A 5x12 .552 14259' Lo 8 Y2" Intermediate: Drilling: MWD IGR IRes - Realtime over entire interval. Sam Ie catchers as er on-site Geolo ist. No 0 en hole 10 s are lanned. No cased hole 10 s are lanned. Open Hole: Cased Hole: 6-1/8" Production: Drilling: Open Hole: Cased Hole: MWD IGR IRes - Realtime over entire interval. Den I Neu - Recorded over entire interval. Sam Ie catchers as er on-site Geolo ist. No 0 en hole 10 s are lanned. No cased hole 10 s are lanned. Cement Program (Preliminary) Abandonment I I Basis: I Based on 575' of 9-5/8" 471b/ft casing and EZSV set at 4290' Fluid Sequence & Volumes: Slurry 103 bbll 575 ft" I 495 sks of Dowell Premium 'G' at 15.8 ppg at 1.17 disk, BHST to be advised Casing Size I 7" Drillin_g Liner I Basis: Lead: : Based on 3675' of open hole with 30% excess. Lead TOC: -4129' MD (4018' TVD) Tail: Based on 2800' of open hole with 30% excess and 82' of 7" shoe joint. Tail TOC: -7805' MD 8820' TVD) Fluid Sequence & Volumes: Pre 40 bbl of CW100. Flush Spacer 20 bbls MudPUSH Viscosified Spacer weighted to 11.2 ppg Lead 107.4 bbl/602 ft"/249 sks of Dowell Premium 'G' at 12 ppg Tail 85.3 bbl/478 ft;:l 1412.25 sks of Dowell Premium 'G' at 15.8 ppg use actual circulating temps recorded by MWD at TD) Casin Basis: W-02A Draft Well Plan Page 3 ( ~.. ( Tail: Based on 82' of 4-1/2" shoe track, 3572' of open hole with 50% excess, 150' of 7" x 4%" liner lap, and 200' of 7" x 4" DP annulus volume. Tail TOG: -10,455' MD (8685' TVD).- Liner top. Fluid Sequence & Volumes: Pre 20 bbls CW100 at 8.5 ppg Flush Spacer 25 bbls MudPUSH Viscosified Spacer weighted to 10.0 ppg Lead None Tail 110 bbl 1 617 fe 1 527 sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.1714f/sk, (use actual circulating temps recorded by MWD at TD), TT = Batch Mix +1- 4 hrs W -02A Draft Well Plan Page 4 ( ( Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3900 psi @ 8875' TVDss - Zone 4 . Maximum surface pressure: 3013 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater / 6.8 ppg Diesel . Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS- 04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. . . W-02A Draft Well Plan Page 5 f' ( , Sidetrack and Complete Procedure Summary Pre-Ria Work: 1.Ensure well is freeze protected and no ice plug is present in tubing. Bullhead 30 bbls diesel down tubing to freeze protect tubing to 2000'. Record SITP and IA pressure. (Original completion records indicate annulus is freeze protected to 2100' however there is no mention of the tubing being freeze protected following shut down of ESP pump.) 2. Function test alliockdown screws on the FMC Generation IV wellhead by backing out and re-torquing one at a time. Test the tubing hanger seals to 5000 psi and 9-5/8" pack-off to 3500 psi.. 3. Set BPV in tubing hanger and secure well. 4.Prior to rig arrival remove well house and flowlines. If necessary level the pad and dig out the cellar. 5. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 9ES. Circulate out freeze protection and displace well to 8.9 ppg kill weight brine Set TWC. 2. Nipple down tree. Nipple up and test BOPE. 3. Pull and lay down 4-1/2" tubing/ ESP and cable. 4. RIH with EZSV on e-line and set at 4,290'. Pressure test to 4000 psi. 5. Pick up cementing stinger and RIH PU 4" drillpipe. (Discuss running in with mill assembly) 6. Sting into EZSV, establish breakdown rate abandon perfs below by pumping approximately 575 cuft Class G cement below stinger. Unsting, reverse out and pull out of hole. 7. MU 9-5/8" whipstock window milling assembly and RIH to top EZSV. POOH. (If not combined with run above) 8. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Mill window in 9-5/8" casing at -4250' MD. Prior to POH, perform FIT to 12.5 ppg EMW. 9. RIH with 8-1/2" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-1/2" intermediate section to Top Sag @ :1:10,604' MD (8811' TVD). 10. Run and cement 7", 26# intermediate drilling liner to -150' back into window. Set liner top packer and circulating out excess cement above liner top. 11. POH. 12. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/DEN/NEU). Pressure test casing to 3500 psi. Drill landing collar and clean out shoe track. 13. Drill 20' of new formation. Conduct FIT to 9.9 ppg EMW. 14. Drill 6-1/8" production section as per directional plan to an estimated TD of 14,256' MD (8936' TVD). 15. Run and cement a 4 Y2", 12.6# L-80 solid production liner throughout the 6-1/8" wellbore. Displace well to perf pill across liner and after setting liner top packer and circulating out excess cement displace to clean seawater above liner top. 16. Test the 4-1/2",7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3500 psi for 30 min. POH LD excess 4" drill pipe. 17. MU TCP assembly and selectively overbalance perforate 4-1/2" liner as directed. 18. Make clean out run .PU 2-7/8" drillpipe to reach bottom of liner. (If required) 19. Run a 4-1/2",12.6# L-80 IBT-Mod completion tying into the 4-1/2" liner top. 20. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 21. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 22. Freeze protect the well to -2200' and secure the well. 23. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below production packer. Install gas lift valves. W-02A Draft Well Plan Page 6 ( (' Job 1: MIRU Hazards and Contingencies ~ Two wells will require shut-in for the rig move to W-02. The two adjacent wells W-01 and W-03 are both approximately 35' from the W-02 wellhead and have a rig to wellhead separation of approximately 10'. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. If it appears the 5' distance will be crossed, the move should be stopped, the rig backed up, and the move re-attempted. )0> W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Reference RPs Operational Specifics Job 2: Decomplete Well Hazards and Contingencies )0> The RFT data taken during August 1997 during the completion of the wellbore indicates a formation pressure of 2146 psi at 4622' TVD (8.6 ppg EMW) Prior to pulling the completion monitor the well closely for any signs of underbalance and have additional brine weight up material available on site. )0> Do not close the pipe rams on the landing joint while it is screwed into the tubing hanger Due to the offset penetration either the landing joint or tubing hanger may be damaged. )0> Ensure that adequate Driller/Spooler Operator communication is in place prior to retrieving the ESP cable. Hand held radios should be available for Spooler Operator and Rig Floor personnel during spooling operation. )0> Have a cable cutter onsite for emergency use on Centrilift cable. )0> NORM inspect all equipment laid down and report readings on Morning Report. Reference RPs Operational Specifics ""'" -, ... , ""~"..... "",,- m_A '" , ., "~ -"M '" Job 3: Run Whipstock Hazards and Contingencies )0> Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. Reference RPs Operational Specifics Job 5: Drill 8112" Intermediate Hole Hazards and Contingencies )0> On prior W Pad wells, tight hole and packing off has been experienced in the upper intermediate hole section while drilling shallow sandstone intervals. W Pad has a limited history of wellbore stability problems within the Kingak shales and of the problems encountered, minor incidents of tight hole and packing off have been the main problems. No stuck pipe incidents are noted on the pad data sheet. Most situations have been handled with additional washing and reaming followed by increased mud weights to W-02A Draft Well Plan Page 7 (' (' stabilize the shale. Problems have been encountered in both high and low angle wells, however high angle wells have been most problematic. Follow all shale drilling practices to limit high ECD's, and maintain proper mud weights and shale stabilizers in the drilling fluid. Several incidents of lost circulation have been seen when the Sag River formation was inadvertently penetrated. Extreme care should be taken when picking the 7" casing point. ~ W-02A is expected to penetrate a fault in the Kingak TJC shale at 10,200' MD (8492' TV D) The estimated through of this fault is 25'. The well trajectory is downthrown and running parallel to a large offset (150'-250' throw) fault from the Schrader Bluff to the top of the Sag River. A standoff of 300' to 1000' is planned for the well and particular attentions should be taken not to get behind the plan and into this fault zone. ~ The kick tolerance for the 8%" open hole section would be 51 bbls assuming a kick from the Kuparuk at -8,340' MD. This is a worst case scenario based on an 10.1 ppg pore pressure gradient in the Kuparuk reservoir, a fracture gradient of 12.5 ppg at the 9-5/8" window with 10.8 ppg mud in the hole. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is W-37 which is -206' center-to-center at 4,521' MD and passes under Major Risk rules. Note tolerance lines and allowable deviation from the planned W -02A well-path. Reference RPs Operational Specifics Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RPs Operational Specifics --"~'" , r , ._~- Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ No fault crossings are planned in the drilling of W -02A, however the given target polygon is hard. ~ W Pad has a history of lost circulation events while drilling in the reservoir section. Losses have ranged from minor to severe (-120 bph). All cases of severe losses have been fault related and were managed by pumping fiberous LCM pills. As noted above, no fault crossings are planned in the drilling of W -02A, however be prepared for losses by establishing a contingency plan. ~ The kick tolerance for the 6-1/8" open hole section would be an infinite influx assuming a kick from the Ivishak at -14,258' MD. This is a worst case scenario based on an 8.7 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 7" shoe, and 8.9 ppg mud in the hole. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. W-02A Draft Well Plan Page 8 { (' Reference RPs Operational Specifics Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem. The 8.9 ppg Quickdril will be -190 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RPs Operational Specifics Job 10: Perforate Well Hazards and Contingencies ~ The well will be perforated over select intervals prior to running the completion. After placing a8.8 brine perf pill the well will be perforated across a 8.5 ppg EMW reservoir for an overbalance of 130 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. Reference RPs Operational Specifics Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RPs OperailonalSpecifics Job 13: ND/NU/Release Rig Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. Reference RPs Operailonal Specifics W-02A Draft Well Plan Page 9 ,( { W -O2A Well Summary of Drillin~ Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Section: --.j Window milling & upper section of intermediate hole will be drilled with 9.8 ppg mud initially. The intermediate section will be drilled with a recommended mud weight of 10.8 ppg to ensure shale stability in the HRZ shale and Kingak shale section. Read the Shale Drilling Recommended Practice. --.j Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. --.j Schrader/Kuparuk/Sag River are expected to be hydrocarbon bearing. --.j W-02A will penetrate a fault in the Kingak T JC shale at 10,200' MD (8492' TVD) The estimated throw of the fault is 25' and is not anticipated to be a lost circulation concern. Should lost circulation occur, consult the Lost Circulation Contingency Plan. --.j The kick tolerance in the Intermediate Hole section is expected to be 51 bbls based on a 10.0 ppg formation pressure in the top Kuparuk and fracture gradient of 12.5 ppg EMW at the casing exit point (Ugnu Formation) Production Interval: --.j Ivishak Zone 4B is hydrocarbon bearing, permeable, sandstone. Lost Returns, Gas Cut Mud & Stuck Pipe have been experienced during past Drill Site Operations. Mud weight will be maintained in the 8.7-8.9+ ppg range to control formation influx. --.j No fault crossings are planned in the Production interval HYDROGEN SULFIDE - H2S . This drill-site is not designated as an H2S drill site. Standard Operating Procedures for H2S precautions should be followed at all times. --.j CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 TREE: 4-1/6" 5M L-80 WELLHEAD: 13-5/8" 5M FMC Gen 6 W-O2A Proposed Completion Cellar Elevation = 7??' Nabors 9ES RKB = ????' 4-1/2" 'X' Landing Nipple with 3.81 "seal bore. I 2200' I 133/8",68 lIft, L-80, BTC I 3118' I 4-1/2"x 1-1/2"Camco 'MMG' Gas Lift Mandrels with handling pups installed above and below. I GAS LIFT MANDRELS I :§:] rvo I Size I Valve Type 7 I I 14 1/2" x 1-1/2" I' RP Shear i 6 I ' '41/2" x 1-1/2" DV I 5 I ' 41/2"X11/2" DV . I 4 I ' 41/2" X 1~1/2" I " I i 31 ' 41/2"X1"! " I ! 2 I ' '41/2"x1" " 11 r ' 141~2"X1" " ~ 4-1/2" 12.6# , L-80 Tubing +/- 9,600' 9-518",47 #Ift, L80, BTC 15,547' I I +/- 4,150' I BAKER 7" x 9-5/8"'HMC' Hydraulic Liner Hanger with ZXP liner top packer 4-1/2" 'X Nipple with 3.81" seal bore. 7"x 41/2" Baker S-3 Production Packer 4-1/2" 'X Nipple with 3.81 "seal bore. 4-1/2" 'XN' Nipple 4-1/2" WireLine Entry Guide spaced-out into liner top. 4-1/2" x 7" Flex Lock hanger and tie-back sleeve and ZXP packer 1+/-10,604'1 7" 26#, L-80, BTC-M Casing 4-1/2" 12.6 #Ift, L-80 Window Milled from Whipstock Top of Window at +/- 4,250' MD Bridge Plug set at 4,290' MD 9-5/8" HES Versatrieve Packer I 4,432' I .....o::::::J ~. --=:::J 9-5/8" BWD Sump packer I 5,547' I 5-1/2" .0012" Gage screen Perf intervals from 4560-4724',4763-4846" Date 1 0/22/01 Rev By NM Comments PRUDHOE BAY UNIT WELL: W-O2A API NO: 50-?? Proposed Completion Prudhoe Bay Drilling ~. ÇIW 41/16 5M wI 19..:. 13 518" 5M FMC Gen 6 -', Unibore 133/8" 68 ppf, L-80 I 3118' I KOP @ 300' Max. hole angle = 22 Degrees @ 2277' Hole angle through perfs = 11°. 4.5",12.6 ppf, L-80 IBT tubing Capacity: .0152 BBUFT Centrilift No.1, CL-81 Cable 95/8", 47 ppf, L-80 Btrc. mod. prod. csg Gravel Pact< Summary: - 6.6 M# of 20-40 mesh Carbolite behind pipe prior to screen out Perforation Summary: Size SPF Interval 41/2 12 560-4724 4 1/2 12 763-4846 OPEN/SOZ PEN 9/3/97 PEN 9/3/97 DATE 9/6/97 REV. BY JLM/MWL COMMENTS COMPLETION l Orig. DF elev. = 82.75 Orig. GL elev. = RKB To 9 5/8" hng. = 4.5 x 1.5 CAMCO LB GLM WI 1.5 RA LATCHES NO. MD TVDss DEV. 2 173 173 0 1 4265 4046 12 Centrilift HC 7000 HPUT Tandem ESP, series 675, (2-35) 70 stages. I 4282 ' Centrilift HSTDBHL, Series 675 seal section I 4317' I Centrilift HMF, 725 Series, I 4331' I 400 hp. motor, 2200v./ 110a 14366' I Centrilift PHD 9 5/8" HES Versatrieve pkr. Closing sleeve ass'bly 5 1/2", 20 ppf, N-80, LTC blank pipe (10 = 4.778") 4432' 4441' 14455' 51/2",0.012" Ga. screen 14555' I ~853' I HES 9 5/8" 'BWD' sump pkr. I I 9 5/8" Float collar (PBTD) 5465' 9 5/8" csg. shoe I I 5547' PRUDHOE BAY UNIT WELL W-O2 BP EXPLORATION W - 0 2A Schlumberuer Proposed Well Profile - Geodetic Report Report Date: October 16, 2001 Survey f DLS Computation Method: Minimum Curvature I Lubinski Client: Alaska Drilling & Wells Vertical Section Azimuth: 254.050° Field: Prudhoe Bay Unit - WOA (Drill Pads) y Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure f Slot: W-PAD / W-02 TVD Reference Datum: KB Well: W-02 I!III TVD Reference Elevation: 81.5 ft relative to MSL Borehole: W-O2A I Sea Bed f Ground Level Elevation: 47.830 ft relative to MSL UWlfAPI#: 500292279301 Magnetic Declination: 26.258° I .--.. Survey Name f Date: W-O2A (P10) / October 16,2001 Total Field Strength: 57460.345 nT Tort f AHD f DDI f ERD ratio: 189.003° 18740.71 ft/6.415/ 0.96E Magnetic Dip: 80.739° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Fee! Declination Date: December 10, 2001 Location Lat/Long: N 70.29711042, W 149.09262945 Magnetic Declination Model: BGGM 2000 Location Grid NfE YfX: N 5959065.140 flUS, E 612048.950 flUS North Reference: True North Grid Convergence Angle: -+D.85425535° Total Corr Mag North -) True North: +26.258° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Grid Coordinates Geo ra hie Coordinates Station ID I MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (O) (O) (ft) (ft) (ft) (ft) (Of100ft) ftUS ftUS Tie-In Survey 4243.43 11.50 208.29 4105.83 653.31 -797.52 -451.54 0.00 5958261.05 611609.39 N 70.29493162 W 149.09628514 Top Window 4250.00 11.51 208.30 4112.27 654.23 -798.67 -452.16 0.11 5958259.89 611608.79 N 70.29492848 W 149.09629016 Base Whipstock 4266.00 13.43 208.30 4127.89 656.64 -801.71 -453.80 12.00 5958256.82 611607.19 N 70.29492017 W 149.09630343 KOP Crv 8/100 4279.00 13.43 208.30 4140.53 658.74 -804.37 -455.23 0.00 5958254.14 611605.80 N 70.29491291 W 149.09631501 4300.00 15.10 207.81 4160.88 662.34 -808.93 -457.66 8.00 5958249.55 611603.44 N 70.29490045 W 149.09633468 4400.00 23.09 206.41 4255.30 684.60 -838.07 -472.49 8.00 5958220.19 611589.05 N 70.29482084 W 149.09645473 UG1 4408.99 23.81 206.33 4263.55 687.00 -841.27 -474.07 8.00 5958216.97 611587.52 N 70.29481210 W 149.09646752 ~. 4500.00 31.08 205.71 4344.26 715.02 -878.95 -492.44 8.00 5958179.02 611569.71 N 70.29470915 W 149.09661622 4600.00 39.08 205.27 4426.03 753.01 -930.80 -517.13 8.00 5958126.82 611545.80 N 70.29456750 W 149.09681608 4700.00 47.08 204.96 4499.01 797.83 -992.60 -546.09 8.00 5958064.60 611517.77 N 70.29439866 W 149,09705050 End Crv 4711.06 47.96 204.93 4506.48 803.17 -1000.00 -549.53 8.00 5958057.15 611514.44 N 70.29437844 W 149.09707835 Top Schrader 4793.29 47.96 204.93 4~61.55 843.14 -1055.38 -575.27 0.00 5958001.39 611489.53 N 70.29422714 W 149.09728670 WS2 4994.90 47.96 204.93 4696.55 941.15 -1191.15 -638.39 0.00 5957864.71 611428.44 N 70.29385622 W 149.09779761 Schrader Oa 5411.55 47.96 204.93 4975.55 1143.68 -1471.76 -768.84 0.00 5957582,21 611302.20 N 70.29308958 W 149.09885345 CM3 5784.89 47.96 204.93 5225.55 1325.16 -1723.20 -885.73 0.00 5957329.08 611189.09 N 70.29240263 W 149,09979947 Base Schrader 5953.64 47.96 204.93 5338.55 1407,20 -1836.85 -938.57 0.00 5957214.66 611137.95 N 70.29209213 W 149.10022710 CM2 6443.47 47.96 204.93 5666.55 1645.30 -2166.74 -1091.92 0.00 5956882.55 610989.55 N 70.29119083 W 149.10146806 W-02A (P1 0) report.xls Page 1 of 3 10/16/2001-2:19 PM Grid Coordinates Station ID MD Inti Azim TVD VSec NJ.S EI.W DLS Northing Easting (ft) (O) (O) (ft) (ft) (ft) (ft) (0/100ft) (ftUS ftUS CM1 7354.42 47.96 204.93 6276.55 2088.12 -2780.25 -1377.13 0.00 Cry 4/100 7355.22 47.96 204.93 6277.08 2088.51 -2780.78 -1377.38 0.00 7400.00 46.87 206.86 6307.39 2110.50 -2810.44 -1391.78 4.00 7500.00 44.56 211.43 6377.22 2161.14 -2872.96 -1426.57 4.00 5956171.48 610665.49 N 70.28926134 W 149.10417582 7600.00 42.45 216.36 6449.77 2213.68 -2930.09 -1464.89 4.00 5956113.79 610628.03 N 70.28910524 W 149.10448589 7700.00 40.56 221.69 6524.68 2267.87 -2981.57 -1506.54 4.00 5956061.70 610587.16 N 70.28896458 W 149.10482291 7800.00 38.94 227.41 6601.59 2323.44 -3027.14 -1551.31 4.00 5956015.48 610543.08 N 70.28884006 W 149.10518518 End Cry 7868.57 38.00 231.55 6655.28 2362.21 -3054.85 -1583.71 4.00 5955987.29 610511.10 N 70.28876434 W 149.10544737 -.. Top HRZ 7994.54 38.00 231.55 6754.55 2433.87 -3103.08 -1644.45 0.00 5955938.16 610451.09 N 70.28863254 W 149.10593889 ' Base HRZ / Top Kup / 8340.99 38.00 231.55 7027.55 2630.92 -3235.71 -1811.49 0.00 5955803.07 610286.06 N 70.28827010 W 149.10729058 Top Miluveach 8456.47 38.00 231.55 7118.55 2696.61 -3279.92 -1867.17 0.00 5955758.04 610231.05 N 70.28814929 W 149.10774113 Top Kingak 9084.63 38.00 231.55 7613.55 3053.90 -3520.41 -2170.05 0.00 5955513.08 609931.81 N 70.28749206 W 149.11019189 TJG 9106.20 38.00 231.55 7630.55 3066.18 -3528.67 -2180.45 0.00 5955504.67 609921.54 N 70.28746949 W 149.11027604 TJF 9500.87 38.00 231.55 7941.55 3290.66 -3679.76 -2370.74 0.00 5955350.77 609733.54 N 70.28705656 W 149.11181569 T JE 9747.06 38.00 231.55 8135.55 3430.69 -3774.01 -2489.44 0.00 5955254.77 609616.27 N 70.28679898 W 149.11277606 T JD 10018.63 38.00 231.55 8349.55 3585.16 -3877.98 -2620.38 0.00 5955148.87 609486.90 N 70.28651481 W 149.11383545 TJC 10294.01 38.00 231.55 8566.55 3741.79 -3983.40 -2753.15 0.00 5955041.49 609355.73 N 70.28622668 W 149.11490960 TJB 10427.25 38.00 231.55 8671.55 3817.58 -4034.41 -2817.40 0.00 5954989.53 609292.25 N 70.28608726 W 149.11542940 TJA 10503.39 38.00 231.55 8731.55 3860.89 -4063.56 -2854.11 0.00 5954959.84 609255.99 N 70.28600759 W 149.11572639 Top Sag River 10598.56 38.00 231.55 8806.54 3915.02 -4100.00 -2899.99 0.00 5954922.72 609210.66 N 70.28590799 W 149.11609756 10598.57 38.00 231.55 8806.55 3915.03 -4100.00 -2900.00 0.00 5954922.72 609210.65 N 70.28590799 W 149.11609764 7" Csg Pt 10604.91 38.00 231.55 8811.55 3918.64 -4102.43 -2903.06 0.00 5954920.25 609207.63 N 70.28590135 W 149.11612240 Shublik A 10630.29 38.00 231.55 8831.55 3933.07 -4112.15 -2915.30 0.00 5954910.35 609195.53 N 70.28587478 W 149.11622142 Cry 24/100 10638.57 38.00 231.55 8838.07 3937.78 -4115.31 -2919.29 0.00 5954907.13 609191.59 N 70.28586614 W 149.11625370 Shublik B 10695.85 43.70 250.76 8881.55 3974.00 -4132.88 -2951.93 24.00 5954889.08 609159.22 N 70.28581811 W 149.11651778-~, 10700.00 44.23 251.98 8884.54 3976.88 -4133.80 -2954.67 24.00 5954888.11 609156.49 N 70.28581559 W 149.11653995 Shublik C 10724.43 47.57 258.70 8901.55 3994.40 -4138.21 -2971.63 24.00 5954883.45 609139.60 N 70.28580353 W 149.11667718 Shublik D 10755.49 52.32 266.21 8921.55 4017.87 -4141.27 -2995.17 24.00 5954880.04 609116.11 N 70.28579514 W 149.11686767 Top Eileen 10763.80 53.67 268.06 8926.55 4024.33 -4141.60 -3001.79 24.00 5954879.61 609109.50 N 70.28579423 W 149.11692124 10800.00 59.82 275.40 8946.41 4053.11 -4140.62 -3032.00 24.00 5954880.14 609079.28 N 70.28579688 W 149.11716572 Top Sadlerochit 10821.41 63.64 279.30 8956.55 4070.41 -4138.20 -3050.69 24.00 5954882.28 609060.56 N 70.28580347 W 149.11731697 10900.00 78.35 291.84 8982.17 4133.24 -4118.01 -3121.80 24.00 5954901.41 608989.16 N 70.28585855 W 149.11789249 End Cry 10948.26 87.67 298.78 8988.04 4169.17 -4097.54 -3165.01 24.00 5954921.23 608945.65 N 70.28591442 W 149.11824224 Cry 6/100 12487.96 87.67 298.78 9050.75 5262.12 -3356.88 -4513.41 0.00 5955641.64 607586.48 N 70.28793597 W 149.12915776 12500.00 88.39 298.85 9051.17 5270.66 -3351.08 -4523.96 6.00 5955647.28 607575.85 N 70.28795179 W 149.12924317 5956264.91 5956264.38 5956234.51 610713.54 N 70.28951464 W 149.10377580 610713.30 N 70.28951319 W 149.10377782 610699.34 N 70.28943216 W 149.10389433 W-02A (P1 0) report.xls Page 2 of 3 10/16/2001-2:19 PM Geo ra hie Coordinates Station ID MD Inel Azim TVD VSee NI.S EI-W DLS Latitude Longitude (ft) (O) (O) (ft) (ft) (ft) (ft) (°11 OOft) - -- Target 299.00 302.41 303.88 303.88 9051.55 9049.80 9047.97 8936.55 12527.04 12600.00 12631.40 14258.99 90.00 92.75 93.93 93.93 End Cry TD /5-1/2" Csg Pt Legal Description: Surface: 4088 FSL 1190 FEL S21 T11N R12E UM Tie-In: 3290 FSL 1643 FEL S21 T11N R12E UM : 5267 FSL 4099 FEL S28 T11N R12E UM Target: 748 FSL 465 FEL S20 T11N R12E UM TO I BHL: 1707 FSL 1900 FEL 820 T11N R12E UM W-02A (P1 0) report.xls 5289.82 5339.88 5360.40 6407.78 -3338.01 -3300.77 -3283.63 -2378.40 -4547.62 -4610.32 -4636.56 -5984.60 Northing (Y) fftUSl 5959065.14 5958261.05 5954922.72 5955660.00 5956598.00 Page 3 of 3 6.00 6.00 6.00 0.00 5955660.00 5955696.30 5955713.04 5956598.00 607552.00 N 70.28798746 W 149.12943472 607488.75 N 70.28808909 W 149.12994235 607462.26 N 70.28813587 W 149.13015481 606101.00 N 70.29060630 W 149.14107083 Easting eX) fftUSl 612048.95 611609.39 609210.65 607552.00 606101.00 --'. "-"- 10/16/2001-2:19 PM ( ~ ( VERTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: W-02A (PI0) Field: Prudhoe Bay Unit - WOA Structure: W-PAD Section At: 254.05 deg Date: October 16, 2001 Schlumbepger -2000 - Proposal -Survey 0 ...,.... 2000 .J. ! Tlo.ln sun¡oY4243 MD 4106 TVD 11.50' 2°f.29' az 653 departure TopWI~dow4250MD 4112TVD : /11.51' 1208.30' az 654 departure: Baa. Whlp8tock4266 MD 4128 TVD i I/; ///13.4F' 208,30' az 657 departure! // KOP Crv 8/1004279 MD 4141 TVD! ,/ // 1~,43' 208,30' az 659 departure: ...,., "_f«~,:~~:'-'::~':'+'~,~i:~'~~~~~~~~~~'~i"~~~~~~~ïJrë'.."" /,., i ..¡... ! ¡ I 1 J... I I I I '1 i 1 - - Q.)- Q.)....J '+-u) o~ a a Q.) N > II .8 c co ;:~ ..........1.(') .c:~ - -r- Q.CC Q.) .......... Dee ~ 4000 ......"........................................ ...... ...., ..... ..... I..... ..... ,.... ¡... ,.., ..." I """;"""""""""""""""""""""""""""¡"""""UCI'HO;;~,IO"::¡:,1'1VI) i I ""'1:,,:.:,:. ¡,>p :':"hr.~,I,'1 .,79,1 NlO "~)(;2 '[\II) Wi,:: ,),'9(; N)O """'" '[VI) ,')c:hmcl.þrO" S41::MO ",¡¡¡) TV!:! I CM,\ 6ï~;l; NIl) ~j::2,) TIll) I::::: [j,."".> S~I'"",kr :;%" MO ö3:'!.\1 TVlJ I'" CM:~ ,:),q~ NlD "(':6, IVI) I .."."""""".."""".......,,),. .., CM: ï:'¡l'4MD \,)fïTVD , "'" .."" "". ')">1' I,m": /91)(: NlD '){% ¡'It) . 6000 .."................................,.., I".. ...... ..,.. ...., ..... ..... ...... ....:::: I:::: ..", ,... ""j: ..Hold..Angle 4if ,,96~ . i.... ...., ..,.. "'" ..... ,...., i,.... i " Crv 4/100 735S MD 6277 TVD '>/" 47:96"'20,ï:ij3f~i 2ÖŠ9 d~pa;i~re ,....:;:,."<"..".........."..,..",,.:..,....,....,....,............., ...., ...... ..,.. ..... ...... ..,.. ..,.. ..... co .. U'+- .- Q.) to:: Q.) > > Q.)~ :JW ~ ~ ,"'" , , , 8000 ,....,..1.."........... ..1 .,~.-..-: E~d C~7,,~6ë MD 66Š5 iVD ,""'" ...,.J'...,. ----..--.-- 38,00' 2~1,55' az 2362 departure ".. ..... .... i,HQlçI :Angle:3a.Qdll~::' -.. ...., ...., ..... 1,.1..:.. O,\~"HRl..irvpl\up!LCIJ !,,)~'I loll) 'IO2f-',NO '!'oprvlih,IY",¡¡(,h ~4%Nli:) '11-!1) 1\;0 : r~~ i : 10605 MD 8812 TVD I " "'" w""'" "-"",, "","" ".' "M '" m" "'" i ,,'" :"""" '38,00" m,5S'az"'" """'" "w ",'" "'" "w ,,' !'" '!/W"K;;1:;;Ä\f;~~;";(;;i;\CU'1 'lV1) --I------I-~~~f~~~Ji~=i:l:\~~,:;:~~~j' I : 87,67' 298,78' az 1 87.67' 298,78' az Target i 93,93' 303,88' az : i ¡ 4169 departure i 5262 departure 12527 MD i 9052 TVD 5360 departure ¡ i . . 90,00' 29$,00' az ' '! 5290 dapa~ure """"""""""""" "'" "'" "" ::::: I::::: 10000 12000 0 2000 4000 6000 8000 Vertical Section Departure at 254.05 deg from (0.0, 0.0). (1 in = 2000 feet) .J £-. ...~ IRO-----_n I... n.-~ - - .'AWII""'IoWUA ^ ^ ^ I I- 0::: a z -1000 -2000 I l- => -3000 a (j) v v v -4000 0 PLAN VIEW Client: Well: Alaska Drilling & Wells W-02A (PI0) Prudhoe Bay Unit - WOA Field: Structure: W-PAD 1 in = 1000 ft 16-0ct-2001 Scale: Date: -6000 -5000 -4000 -3000 -2000 True North Mag Dec ( E 26.26° ) ----______n______n______--n_U.--_U_---- -----------"---------_U_------------------ ---~._-_._--- - Proposal -Survey - - - - n_____'uun _nu_____n____n______m___" -- -------_00_00_--0000--____--- - - - 00 -----_____uAnn_u -1000 lie-In Survey 4243MD 4106TVD n1i:sö'-2ö8:2ifaž" 798-5 452W Top Window 4250MD 4i12TVD II_51' 208_30' az ' 7995 452W Base Whipstock -- \ 4266MD 4128TVD.---------- \,\ 13.43' 208.30" az - -----------.:. 8025 454 W 0 ó? '!;1-' ~ s .f -- ._.n.._~t~- .-.-..-. .-.-.-.-. TO / 5-1/2" Csg PI 14259 MD 8937 TVD 93.93. 303.88' az 23785 5985 W End Cry 12631 MD 9048 TVD . 0 93.93. 303.88' az : ~~ 3284 5 4637W ' Target ,.... A- 1252~ MD 90:2 TVD . ,..,:,'? / , 90.( {) 299.00 az : ~ . : i / ,33385 4548W : ~ ~ -- ~-//_n :u_-~;:~~~~_.nu___u__._unu :\Ø""---_____~n____n_- 1// ~ 12488 MD 9051 TVD ~q . /~. .: 87.67" 298.78' az ~O : [ 33575 4513W Crv~""100 . 106~ MD 8838 TVD 38.00," 231.55' az 4115ß 2919W ~~41- ----_u_-_u u.-.-.- i ~Íl}(¡~ : <98~ : : . 80, ~. _.::::om._-Crv..4I-1nn. ..n.. . - ..... . 7355 MD 6277 TVD 47.96' 204.93' az 2781 5 1377 W End Cry 7869 MD 6655 TVD 38.( {)~ 231,55. az 3055 ~ 1584 W End Cry - 10948 MD 8988 TVD 87.67' 298.78' az 40985 3165 W --- ~ V--- - -- _n__- n- --, - - __nn- n- - - - n u- u : 5(/ ' ~. <J ---.......... T" Csg PI' 10605 MD' 8812 TVD 38.00' 231.55' az 41025 2903W -6000 -5000 -4000 «< WEST -3000 -2000 EAST »> -1000 Schlumberger 0 \ -LKOPCrv 8/100 , 4279MD 4141TVD 13.43' 208.30. az 804 5 455 W End Crv: 4711 MD: 4506 TVD 47.96' ~O4.93' az 10005 ~50W 0 0 -,. -1000 -2000 -3000 -- u4'Ol(y .4. .i c.qh.. -t/(¡~ , ~O~ .880 -4000 ( Schlum berger Anticollision Report f ,--------- ------------------ ------ -,----- - -- -------,------,-------, -----------------------------, -,-----,--,---- ------------ '--------- [ Company: BP Amoco ! Field: Prudhoe Bay I Reference Site: PB W Pad Co-ordinate(NE) Reference: Well: W-02, True North I Reference Well: W-02 Vertical (TVD) Reference: W-02A plan 81.5 . ~~~~_ce Wellpath: Plan W-02A ---------------------------------------------------- -------_____~b:- Sybase --_.J I NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Pri~~¡;;r Pla~ & PLÃNNE~D-PROGRAM : I Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse i ¡ Depth Range: 4250.00 to 14258.99 ft Scan Method: Trav Cylinder North ~__~~~imu~_~!.~~~:.._~9~0.:~~_---~--_..__..,---- -- - - - --------,-----~!.~~~~~!~~_e~___~I!~p_~~:'".(~~~i~_- - -- I I-S~;~ey P-;ogramfur Definit~-e Welipath--------------- -----------------~----------------------------------------,- ------ì ] Date: 10/16/2001 Validated: No Version: 9 I Planned From To Survey Toolcode Tool Name ft ft 119~40 --4-243.43---1-: MWD - Stand~rd (0)---------------- MWD MWD - Standard ---------~-------l 4243.43 ___~4258:?9 -- ----- PI~_~~:~~~~~:_~~-~--------------------- M_~~__- ------------- MWD ~!>.!~-~~~~~------_.._-------- ------ -------.l Date: 10/16/2001 Time: 14:10:06 Page: 1 Casing Points ,--------------,,------------ -------,--- -------- -- ----"- ,---- ----..----- - -----------, ------- ------- -------- --'--'------- MD TVD Diameter Hole Size ft ft in in -..----..----",----,----- --,--,-- ----------,---- ----, -,-------- -..------- ..--- - -----"----- ----------"------....----- ,-------- 3115.80 3009.23 13.375 16.000 133/8" 4250.00 4112.27 9.625 12.250 95/8" 1 0605.00 8811.67 7.000 8.500 7" 14258.00 8936.42 5.500 6.000 51/2" Name -----,-------- --------------'-- ------------'-----'- ----..,----,-- -----------------------,-, --------- ,------..--- -,-,-_._,--, ----------,-------- ----- Summary -----------"---'----------'----"-----'------"----'--'----------------'._"------,-_.- -.,,------- ...----.- '----------...._---------'------------"'-------,-- ---------------------,..-- - ,--.---- ----- ",'--' ----.---------------- ---" <---'---'--"";'-'--'-----'~-'- Offset Well path -'-'-"'-'-'---------'----> Reference Offset Ctr-'Ctr No-'Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft ----------..- - - --- - ------ ---------------- --- ---- -.. --- ---,--- --------------- ----- ------ --,-, --- ..-- -- - ---- -- - '-, - ---- ---,,-- --- PB W Pad W-01 W-01 V1 4250.00 5650.00 3303.35 119.99 3200.50 Pass: Major Risk PB W Pad W-02 W-02 V4 4250.00 4250.00 0.00 100.78 -53.50 FAIL: Major Risk PB W Pad W-03A W-03A V3 4260.62 4450.00 1295.30 97.62 1202.99 Pass: Major Risk PB W Pad W-03 W-03 V1 4250.00 4300.00 878.37 81.29 819.62 Pass: Major Risk PB W Pad W-04 W-04 V1 4258.72 4500.00 1141.36 91.73 1059.87 Pass: Major Risk PB W Pad W-05 W-05 V1 4256.22 6000.00 3724.10 128.54 3613.15 Pass: Major Risk PB W Pad W-06A W-06A V2 4260.07 5400.00 2811.42 117.44 2704.69 Pass: Major Risk PB W Pad W-06 W-06 V1 4260.07 5400.00 2811.42 117.44 2704.69 Pass: Major Risk PB W Pad W-07 W-07 V1 4250.28 5450.00 3063.74 122.04 2951.79 Pass: Major Risk PB W Pad W-08 W-08 V1 4258.00 5650.00 3175.80 118.50 3072.76 Pass: Major Risk PB W Pad W-09 W-09 V1 5065.71 4500.00 2085.01 144.01 1984.95 Pass: Major Risk PB W Pad W-10 W-10 V3 5004.98 4500.00 1943.97 135.79 1846.99 Pass: Major Risk PB W Pad W-11 W-11 V1 4994.26 4350.00 1712.13 133.64 1629.28 Pass: Major Risk PB W Pad W-12A W-12A V3 4941.81 4500.00 1971.29 132.94 1858.86 Pass: Major Risk PB W Pad W-12 W-12 V1 4941.81 4500.00 1971.29 132.94 1858.86 Pass: Major Risk PB W Pad W-15 W-15 V1 4250.00 4550.00 1506.48 91.77 1435.30 Pass: Major Risk PB W Pad W-15 W-15PB1 V6 4250.00 4550.00 1506.48 91.77 1435.30 Pass: Major Risk PB W Pad W-15 W-15PB2 V1 4250.00 4550.00 1506.48 91.77 1435.30 Pass: Major Risk PB W Pad W-16 W-16 V1 4257.21 4400.00 1294.57 73.76 1244.09 Pass: Major Risk PB W Pad W-17 W-17 V1 4250.00 5450.00 3174.63 115.93 3085.19 Pass: Major Risk PB W Pad W-18 W-18 V1 4250.00 4400.00 1359.11 78.14 1303.76 Pass: Major Risk PB W Pad W-19A W-19A V5 4250.00 4850.00 2260.96 93.14 2189.65 Pass: Major Risk PB W Pad W-19 W-19 V1 4250.00 4850.00 2260.96 93.14 2189.65 Pass: Major Risk PB W Pad W-200PB1 W-200PB1 V7 4257.76 4550.00 1782.44 79.04 1722.94 Pass: Major Risk PB W Pad W-200 W-200 V4 Plan: Undefin 4350.00 4850.00 1677.37 73.86 1619.06 Pass: Major Risk PB W Pad W-201 W-201 V4 PB W Pad W-20 W-20 V1 4256.59 4550.00 1677.19 92.08 1608.54 Pass: Major Risk PB W Pad W-21 Plan W-21A V9 Plan: PI 4259.58 4450.00 1497.49 76.79 1443.66 Pass: Major Risk PB W Pad W-21 W-21 V3 4259.58 4450.00 1497.49 76.90 1443.55 Pass: Major Risk PB W Pad W-22 W-22 V1 4266.00 4450.00 1491.29 75.02 1438.53 Pass: Major Risk PB W Pad W-23 W-23 V1 4250.00 4700.00 2222.71 83.45 2165.01 Pass: Major Risk PB W Pad W-24 W-24 V1 4256.81 4450.00 1572.81 73.90 1520.97 Pass: Major Risk PB W Pad W-25 W-25 V1 4266.00 4400.00 1165.38 86.85 1089.53 Pass: Major Risk PB W Pad W-26A W-26A V3 4250.00 5650.00 3623.02 115.76 3524.40 Pass: Major Risk PB W Pad W-26 W-26 V1 4250.00 5700.00 3655.81 116.11 3557.13 Pass: Major Risk PB W Pad W-27 W-27 V1 4250.00 4450.00 969.23 98.34 873.78 Pass: Major Risk PB W Pad W-29 W-29 V1 4250.00 4600.00 1723.56 85.78 1649.64 Pass: Major Risk PB W Pad W-30 W-30 V1 4250.00 4400.00 1241.93 86.65 1163.13 Pass: Major Risk PB W Pad W-31 W-31 V1 4258.95 4550.00 1425.46 143.47 1283.94 Pass: Major Risk PB W Pad W-32 W-32 V1 4250.00 4650.00 1992.95 83.63 1927.96 Pass: Major Risk PB W Pad W-34 W-34 V1 4250.00 4350.00 841.47 117.22 724.37 Pass: Major Risk ----------- ------------,----,,--_.._--- --"'-., ,-- - - ------------------------------,-, - ,------- --,--_.,-" --", -----,-----.. -..------------- ---,,---..----- ----- ---- --, (' Schlumberger Anticollision Report (- Company: Field: i Reference Site: i Reference Well: : Reference Wellpath: ------ Summary 1< I ! Site , c---- : PB W Pad I PB W Pad I PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad ----------- BP Amoco Prudhoe Bay PB W Pad W-02 Plan W-02A 10/16/2001 Time: 14:10:06 Page: Date: 2 Co-ordinate(NE) Reference: Vertical (TV D) Reference: Well: W-02, True North W-02A plan 81.5 Db: Sybase ----- --- -_..--------- ----- ----------- -- ------- - ---- -------- ------------------------- ---,,--- - -- - ---------- -------- -- -- ------ ------------, Offset Well path > Reference Offset Ctr-Ctr No-Go Allowable ¡ Well Well path MD MD Distance Area Deviation Warning ! ft ft ft ft ft I W~35 -------------W~-5-V1------------_._---430Ö~ÖO-----435o. OÓ---537~37-1io~81--- 42 O. 4-7--Pass: M-~j~¡-R¡;-k--------1 W-36 W-36 V1 4270.18 4300.00 740.68 73.75 688.27 Pass: Major Risk I W-37 W-37 V1 4521.93 4600.00 206.34 101.72 115.04 Pass: Major Risk - W-38 W-38 V1 4956.10 4350.00 1560.08 138.57 1468.62 Pass: Major Risk W-39 W-39 V1 4256.65 4250.00 624.58 77.30 569.44 Pass: Major Risk W-40 W-40 V1 4259.23 4250.00 595.93 76.40 541.98 Pass: Major Risk W-42 W-42 V1 4267.75 4250.00 511.76 73.75 461.26 Pass: Major Risk W-44 W-44 V1 4250.02 4850.00 1853.00 101.50 1758.17 Pass: Major Risk -. -,,------------.--,,-------------------------------------------- ------------ _._-- --- ~----- ---------- ------..-----------.--------------------- ---------- ,I: \ , " I' \. DATE 09/28/01 CHECK NO. 00198737 H 198737 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT 092701 CK092701A PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it to Drill ee S/H - Terri Hubb e X4628 WJD~Jt REG I\/ELJ NO\¡, ( :: ( Alaska Oil & Gas ons. CornrnlSSlor', Anch rage E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 56.389 412 C~S~:DA~D CO:M~~L:C:~:T I 00198737 BP EXPLORATION, (ALASKA) INC. P.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO PAY ONE HUNDRED ~ 00/100********************~**************** US DOLLAR DATE 09/28/01 I I AMOUNT $100,001 NOT VALID AFTER 120 DAYS To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 Ç( ,. .h rr ," " ~(!;"I..;1/l, ".):",,/ , I. "'.'f~~ ' .' "~~ " ,"" a III . g a 7 :1 7 III I: 0... ¡. 2 0 :1 a g 5 I: 0 0 a ...... . g III .," ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELL NAME tð'?f ¡¿) ~ out CHECK 1 ST ANDARD LEITER DEVELOPMENT CHECK WHA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILL /' PILOT HOLE (PH) EXPLORA TION / ANNULAR DJ5.!OSAL L..!O N 0 INJECTION WELL ANNULAR DISPOSAL <-.J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new well bore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved.. . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS <-.J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. COMPANY WELL NAME td-ozA PROGRAM: exp - dev - redrll - ') INIT CLASS .~ 7 ¿Y L GEOL AREA C'..) 1.Permitfeeattached........................ ~N 2. Le~se number appropriate¥"'. ~..l:- .'~ .~êPy . "-:0. ~ / Y ÇfD* - tÁ-r.~ ,,¿'- c.::.? ~-"'-. VÌ<- A-t::> L .Ö 2521f=- '5 I 3. Unique well name and number... . . . . . . . . . . . . . . . N ~ 7t:?l-tJvf Æ~ ~ A-P¿ æSz.rc,z, ~ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N (/ 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells. . . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . "\ N. 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . ~ N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . ' N 10. Operator has appropriate bond in force. . . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can.be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N ~~: ~~~~:~:~;~i~~~~e:1I kn~~' US'OW's.' '. .. .. '. '. .. '. . . . ~ ~~ þ..dr'// þ¡' .L-)U~-h; h<./I'. ~b 16. CMT vol adequate to circulate on condudor & surf csg. . . . . Y N - . 17. CMT vol adequate to.tie-in long string to surf csg. . . . . . . . N 18. CMT will cover all known produdive horizons. . . . . '. . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . . N ~ . ~ ~ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N <:è..."-\ ",,~,~, t<) Ç"'CL~~<l ~\ 21. If a re-drill, has a 10-403 for abandonment been approved. . . N -;~\- ~Ö"). ~ ,,~ ~ ~ " 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N --S..~~tè- o.~~o..c \c)t~ '\ '\~U 23. If diverter required, does it meet regulations. . . . . . . . . . -.w. ~~ 24. Drilling .fluid program schematic & equip list adequate. . . . . Y N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N . Q. .. IftCihnIt DAT>-- - 26. BOPE press rating appropriate; test to )S\::)O psig. N ""~~~ ~..... -\- 7..f::J\ ~ ~~ \ ~~ \\{(2 27. Choke manifold compliesw/API RP-53 (May 84). . . . . . .. . N . 28. Work will occur without operation shutdown. . . . . . . . . . . Â' ~'" . ~ I ~ \ . 29. IspresenceofH2Sgasprobable................. Y~~">~Ct..-c.~Ct.c o~,~~ ~'t'~'~~'H~ .~ ~Ct'"'~C~ C'Q.,~~. 30. Permit can be issued w/o hydrogen sulfide measures. . . . .. Y@ ;' , ' " ~ 31. Data presented on potential overpressure zones. . . . . . . rY)'-N /Iþ~&" h'~r'~ EmaJ ~~'I')~j,~~ 141.-- ,K-/'~c,(,lL. Cr- I of 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . .. 44~ ó'(.f~ .-7J t:>c...,.--1t.¿n q ~- ~ . APPR pArE / 33. Seabed condition survey (if off-shore). . . . . . . . . ," ~ Y N /Ð If. Cø .0 34. Contad name/phone for weekly progress reports [exp!9m°ry only] Y N 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 pf the well used for disposal; Y N (0) 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 GEOLOGY: ENGINEERING:.' UIC/Annuiar COMMISSION: j8dt: wtll---. 8~s Æ:r H( I ç JMI1 serv wellbore seg _ann. disposal para req- ON/OFF SHORE Ó /1 WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION DATE / I .~ . ó I GEOLOGY APPR DATE UNIT# Y N Y N b~J Com mentsllnstructions: "'.blol c:\msoffice\wordian\diana\chècklist (rev. 11/01/100) ( c 0 Z 0 -I ~ :;0 ( - -I m - Z -I J: - en > :;0 m » ( ..' ( ( Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process. but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically organize this category of information. ~: Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 12 11:16:26 2002 Reel Header Service name.... ....... ..LISTPE Date.....................02/09/12 Origin...................STS Reel Name....... ..... ....UNKNOWN Continuation Number... ...01 Previous Reel Name. ..... . UNKNOWN Comments.................STS LIS Tape Header Service name........... ..LISTPE Date.....................02/09/12 Origin...................STS Tape Name.. ............. . UNKNOWN Continuation Number... ...01 Previous Tape Name...... . UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-11197 T. GALVIN T. ANGLEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ( Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services W-02A (Lower Section 500292279301 BP Exploration (Alaska), Inc. Sperry Sun 12-SEP-02 MWD RUN 2 AK-MM-11197 S. LATZ T. ANGLEN 21 11N 12E 1192 1190 .00 81.55 53.05 CASING SIZE (IN) 9.625 7.000 5.500 DRILLERS DEPTH (FT) 4250.0 10567.0 10840.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 & 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 c3,OJ-dJt.j JIO9:~ ( ( (EWR4) . 3. GAMMA RAY (SGRC) DATA FROM 10695' MO, 8729' TVD TO 10783' MO, 8790' TVD WAS OBTAINED ON A MADPASS WHILE RUNNING IN THE HOLE BEFORE DRILLING MWD RUN 1. THIS DATA IS APPENDED TO THE DRILLING DATA ON MWD RUN 1. 4. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 10695' MO, 8729' TVD TO 10840' MO, 8830' TVD. 5. THE MWD SERVICES IN THE LOWER SECTION OF THIS WELL ARE PERFORMED BY SPERRY-SUN DRILLING SERVICES. THE UPPER SECTION OF THIS WELL ARE PERFORMED BY ANADRILL. THE MWD SERVICES IN 6. DIGITAL DATA AND LOG DATA ARE DEPTH CORRECTED TO THE PDC GR LOG OF 12/19/01 WITH KBE = 81.5' A.M.S.L.. THE LOWER SECTION OF THIS WELL DRILLS OUT OF 5.5" CASING AT 10840' MO, 8830' TVD. ALL MWD LOG AND HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 & 2 REPRESENT W-02A WITH API # 50-029-22793-01. DEPTH OF 14500' MO, 8843' TVD. THE LOWER SECTION OF WELL THIS WELL REACHED A TOTAL SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name........... ..STSLIB.OOI Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .02/09/12 Maximum Physical Record. .65535 File Type... ............ .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 10691. 5 10826.5 10826.5 10826.5 10826.5 10826.5 10835.0 STOP DEPTH 14432.5 14443.5 14443.5 14443.5 14443.5 14443.5 14490.0 # ( ,( BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 10691. 5 10698.0 10699.5 10704.0 10718.0 10725.0 10734.5 10736.0 10742.0 10749.0 10762.0 10784.0 10789.5 10797.0 10807.0 10829.0 10832.0 10835.5 10843.0 10863.5 10872.0 10879.5 10891. 5 10904.0 10907.5 10921.5 10926.5 10949.0 10955.5 10965.0 10970.0 10972.0 10981.0 10986.0 10991. 0 10994.0 11002.5 11005.0 11010.0 11020.5 11027.0 11035.5 11039.5 11045.5 11052.0 11057.0 11078.0 11094.0 11101.0 11103.5 11111. 0 11118.5 11133.0 11138.0 11144.5 11148.5 11153.5 11170.0 11178.5 11186.0 11190.0 11202.0 11217.5 11227.5 11234.5 11240.5 11246.0 11269.5 11311. 0 11313.0 11336.5 11341.5 DEPTH GR 10694.5 10701.0 10704.5 10707.0 10721. 0 10727.5 10736.5 10738.5 10743.0 10749.5 10763.5 10781. 5 10787.5 10795.0 10808.5 10833.0 10837.0 10840.5 10852.0 10870.0 10879.5 10886.5 10898.0 10909.0 10913.5 10926.5 10930.0 10954.5 10960.0 10969.5 10974.5 10977.0 10985.0 10990.5 10996.0 10999.0 11007.5 11010.5 11014.5 11024.0 11031.5 11040.0 11044.0 11048.5 11052.5 11059.0 11081.5 11093.5 11101.5 11104.5 11113.5 11118.5 11133.0 11140.0 11144.5 11149.0 11154.0 11171.0 11178.5 11187.0 11191.0 11201. 5 11215.5 11227.5 11233.5 11240.0 11245.0 11271.5 11310.0 11312.5 11336.0 11341.0 ( ( 11352.5 11361.0 11367.5 11371.5 11374.5 11391.5 11402.0 11411.5 11422.5 11430.5 11442.0 11447.5 11456.5 11471.5 11483.0 11496.0 11502.0 11511.0 11514.0 11517.0 11518.5 11522.0 11557.0 11576.5 11583.0 11587.5 11593.0 11595.0 11604.0 11606.5 11613.0 11633.0 11647.5 11664.5 11671.0 11702.0 11716.0 11720.0 11734.0 11757.0 11761.0 11 765 . 0 11787.0 11810.5 11820.0 11830.0 11834.5 11856.5 11861.5 11871.5 11875.5 11883.0 11886.5 11900.0 11920.0 11928.0 11934.0 11945.5 11955.5 11978.5 11990.0 12018.5 12036.0 12044.0 12051.5 12063.5 12073.5 12082.5 12110.5 12123.5 12138.0 12143.5 12156.0 12162.0 12169.0 12188.5 11352.5 11361.0 11367.5 11371.0 11374.5 11391.5 11401.0 11411.5 . 11422.5 11429.5 11440.0 11445.5 11453.5 11469.5 11481.5 11494.0 11502.0 11510.0 11512.5 11516.5 11518.0 11521.0 11556.0 11574.0 11579.5 11586.5 11593.5 11599.0 11607.0 11610.5 11615.5 11634.5 11649.0 11667.0 11674.0 11702.0 11716.0 11720.0 11735.5 11 760.5 11764.5 11768.0 11791.0 11815.0 11823.5 11831.0 11837.0 11861.0 11865.0 11875.0 11879.0 11888.0 11890.0 11905.0 11920.0 11929.0 11935.5 11947.0 11956.0 11980.5 11992.5 12018.5 12037.0 12048.0 12054.5 12066.0 12078.0 12087.0 12113.5 12128.0 12141. 5 12148.0 12161. 0 12165.5 12171.0 12192.0 ~. i~' , 12196.5 12215.5 12219.0 12222.0 12224.0 12230.0 12238.0 12246.5 12289.5 12295.5 12343.5 12351.0 12362.5 12368.5 12375.0 12407.0 12410.5 12414.0 12422.0 12446.0 12457.0 12460.5 12467.5 12475.0 12478.0 12486.5 12490.5 12495.0 12499.0 12503.0 12519.5 12523.0 12530.0 12535.5 12542.0 12545.5 12558.5 12563.0 12567.0 12571. 0 12573.0 12581. 5 12586.0 12602.5 12610.5 12615.5 12623.0 12626.5 12635.5 12639.5 12643.5 12652.5 12655.5 12664.5 12669.0 12681.5 12694.5 12726.0 12735.0 12738.5 12743.5 12747.0 12752.0 12766.5 12770.0 12774.5 12778.0 12790.0 12794.5 12802.5 12809.5 12820.0 12831.5 12843.0 12850.5 12857.5 12201.0 12218.0 12222.0 12225.0 12227.0 12231. 5 12241.0 12255.0 12298.0 12304.5 12349.5 12357.0 12367.0 12375.0 12381. 5 12410.0 12415.5 12418.5 12426.5 12453.5 12463.0 12466.0 12471.0 12478.5 12483.5 12491. 5 12496.0 12500.5 12503.5 12508.5 12524.0 12527.0 12533.5 12542.0 12548.5 12551.0 12567.0 12570.0 12574.5 12577.0 12579.0 12586.5 12591.5 12610.5 12617.0 12621. 5 12631.0 12634.0 12643.5 12648.0 12650.5 12657.5 12661.0 12672.5 12678.0 12690.5 12703.0 12732.0 12740.0 12742.0 12747.5 12751.0 12757.0 12770.5 12774.0 12778.5 12783.0 12794.5 12797.5 12805.0 12810.0 12819.0 12831.5 12845.0 12852.5 12858.0 " It ,{ 12860.5 12862.5 12870.0 12878.0 12882.5 12892.0 12904.5 12916.5 12940.5 12956.0 12983.5 12995.0 13006.0 13027.0 13049.0 13053.0 13055.0 13072.5 13090.0 13102.0 13116.5 13120.5 13124.5 13141.0 13171.5 13181. 5 13192.0 13198.5 13210.0 13222.5 13229.5 13249.5 13258.5 13264.0 13275.0 13278.0 13282.5 13292.0 13307.0 13315.0 13352.5 13369.0 13380.0 13391.5 13400.5 13407.5 13411.5 13443.5 13452.5 13482.0 13486.5 13500.0 13504.5 13507.0 13511. 0 13515.0 13518.5 13542.0 13555.5 13569.0 13585.0 13588.5 13594.5 13623.0 13638.0 13643.0 13647.5 13653.5 13663.5 13695.0 13707.0 13712.0 13717.0 13722.0 13727.5 13735.0 12862.5 12865.0 12875.5 12883.0 12888.5 12897.0 12910.5 12921. 0 12947.0 12963.0 12990.0 13004.0 13014.5 13035.5 13056.0 13060.5 13063.5 13078.5 13096.5 13110.0 13123.5 13128.5 13132.5 13149.0 13181. 0 13190.0 13197.0 13203.5 13217.0 13232.5 13239.0 13263.5 13272.5 13276.0 13284.5 13288.0 13293.5 13302.0 13318.0 13326.5 13362.5 13380.5 13390.0 13400.5 13409.0 13415.0 13420.5 13452.0 13460.0 13491. 5 13496.5 13512.5 13516.0 13518.5 13522.5 13526.0 13529.5 13553.0 13565.5 13580.5 13594.0 13598.5 13605.5 13631. 5 13649.0 13655.0 13661.0 13669.5 13678.5 13705.0 13716.0 13722.5 13728.5 13731.5 13738.5 13749.5 ~. {' 13758.0 13817.5 13824.5 13843.0 13854.5 13857.5 13862.5 13878.5 13898.5 13915.0 13926.5 13932.5 13934.5 13951.5 13964.0 13967.5 13972.5 13975.0 13996.5 14078.0 14103.5 14111.5 14124.0 14127.5 14132.5 14138.5 14151. 0 14160.5 14175.0 14179.5 14242.5 14245.0 14255.5 14262.5 14264.5 14268.0 14269.5 14273.0 14276.5 14281. 0 14286.0 14295.0 14301.5 14319.0 14337.5 14368.0 14377.5 14392.5 14490.0 $ 13771.0 13828.0 13838.0 13857.5 13868.0 13871.0 13874.5 13890.5 13913.5 13927.5 13934.0 13944.5 13947.0 13964.0 13976.0 13981. 0 13985.0 13988.0 14010.0 14091. 0 14116.5 14125.0 14136.5 14140.0 14146.0 14150.5 14163.5 14171. 5 14183.5 14189.5 14255.0 14257.0 14267.5 14274.5 14277.0 14279.5 14282.0 14284.5 14288.0 14293.5 14297.5 14314.0 14321.0 14335.0 14351. 0 14383.0 14390.0 14402.5 14500.0 # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 MERGE TOP 10694.5 11143.5 MERGE BASE 11143.0 14500.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.... ..............0 Data Specification Block Type.....O Logging Direction.. ............. ..Down Optical log depth units......... ..Feet Data Reference Point..... ...... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 " i RPX RPS RPM RPD FET MWD MWD MWD MWD MWD OHMM OHMM OHMM OHMM HR 4 4 4 4 4 (, 1 1 1 1 1 68 68 68 68 68 4 5 6 7 8 12 16 20 24 28 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10691. 5 14490 12590.8 7598 10691.5 14490 ROP MWD FT/H 0.61 348.9 70.3594 7311 10835 14490 GR MWD API 20.95 424.87 51. 4253 7483 10691.5 14432.5 RPX MWD OHMM 0.29 2000 35.8953 7235 10826.5 14443.5 RPS MWD OHMM 0.56 2000 31.0282 7235 10826.5 14443.5 RPM MWD OHMM 2.05 2000 26.2631 7235 10826.5 14443.5 RPD MWD OHMM 3.04 2000 29.2973 7235 10826.5 14443.5 FET MWD HR 0.55 34.07 2.01036 7235 10826.5 14443.5 First Reading For Entire File.... ..... .10691.5 Last Reading For Entire File..... .... ..14490 File Trailer Service name.... .... .... .STSLIB.001 Service Sub Level Name... Version Number.. .... .... .1.0.0 Date of Generation...... .02/09/12 Maximum Physical Record..65535 File Type................LO Next File Name........ ...STSLIB.002 Physical EOF File Header Service name..... ....... .STSLIB.002 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .02/09/12 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPS RPM ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10694.5 10830.0 10830.0 10830.0 10830.0 10830.0 10840.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG STOP DEPTH 11087.0 11098.0 11098.0 11098.0 11098.0 11098.0 11143.0 07-DEC-01 Insite 4.05.5 4.3 Memory 11143.0 (' MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF'(IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ....... .........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units. .... .... ..Feet Data Reference Point.... .... .... ..Undefined Frame Spacing. .......... .... .... ..60 .1IN Max frames per record........... ..Undefined Absent value..... ............... ..-999 Depth Units....................... Datum Specification Block sub-type...O ( 47.2 76.3 TOOL NUMBER 72830 PB02300RF3 4.750 LSND 8.70 48.0 9.3 29000 11. 9 .190 .097 .180 .140 69.0 141.0 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10694.5 11143 10918.8 898 10694.5 11143 ROP MWD010 FT/H 0.75 348.9 32.9828 607 10840 11143 GR MWD010 API 47.01 424.87 109.98 786 10694.5 11087 RPX MWD010 OHMM 0.29 2000 307.795 537 10830 11098 RPS MWD010 OHMM 0.56 2000 245.969 537 10830 11098 RPM MWD010 OHMM 2.5 2000 185.27 537 10830 11098 RPD MWD010 OHMM 5.25 2000 212.412 537 10830 11098 FET MWD010 HR 1. 63 10.99 3.5711 537 10830 11098 First Reading For Entire File........ ..10694.5 Last Reading For Entire File.......... .11143 ( File Trailer Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/09/12 Maximum Physical Record..65535 File Type..... ........ ...LO Next File Name...... .....STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .02/09/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 ( header data for each bit run in separate files. 2 .5000 START DEPTH 11087.5 11098.5 11098.5 11098.5 11098.5 11098.5 11143.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 14442.5 14453.5 14453.5 14453.5 14453.5 14453.5 14500.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 13-DEC-01 Insite 4.05.5 4.3 Memory 14500.0 77 .2 96 .2 TOOL NUMBER 78897 PB02300RF3 4.750 LSND 8.70 49.0 9.0 30000 4.7 .170 .072 69.0 171.0 % ( MUD FILTRATE AT MT: MUD CAKE AT MT: .160 .100 69.0 69.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ...... ......0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point.. .......... ..Undefined Frame Spacing... ................ ..60 .1IN Max frames per record............ .Undefined Absent value.......... ...... ..... .-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11087.5 14500 12793.8 6826 11087.5 14500 ROP MWD020 FT/H 0.61 286.76 73.7401 6714 11143.5 14500 GR MWD020 API 20.95 237.38 44.6661 6711 11087.5 14442.5 RPX MWD020 OHMM 1. 61 1559.3 14.7733 6711 11098.5 14453.5 RPS MWD020 OHMM 1. 87 ~1.79 14.3274 6711 11098.5 14453.5 RPM MWD020 OHMM 2.05 59.25 13.8575 6711 11098.5 14453.5 RPD MWD020 OHMM 3.04 328.84 14.8699 6711 11098.5 14453.5 FET MWD020 HR 0.55 34.07 1.88003 6711 11098.5 14453.5 First Reading For Entire File......... .11087.5 Last Reading For Entire File.... ."'" .14500 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...02/09/12 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name....... ... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/09/12 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name....... ... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services ( Reel Trailer Service name. ......... ...LISTPE Date.....................02/09/12 Origin...................STS Reel Name................UNKNOWN Continuation Number..... .01 Next Reel Name.. ... ..... . UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. ~'Î " , Scientific Technical Services
