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203-186
) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03- 1 '6 fo Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 R?CAN ¢Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: (" MarirC> I' Date: J . Ii, Ob D Other:: 151 ·11~ Project Proofing BY: (" Maria :> , , , Date: I t 1 D~ J X 30 = :J Ó + Date: /., I/r/O~ 111111111111111111 ~j 151 Scanning Preparation BY: (Maria ') (À-S' = TOTAL PAGES (lJ:S' (Count does not include cover sheet) ~ 11' " ~I ,~~~ Production Scanning Page Count from Scanned File: 5~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ÁMaria) Date: ¡ '0/100 Stage 1 If NO in stage 1, page(s) discrepancies were found: 1111111111111111111 Stage 1 BY: Isl NO J 1M YES NO BY: Maria Date: 151 I11I111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc RECEIVED • STATE OF ALASKA • JUL 0 2 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION ACC WELL COMPLETION OR RECOMPLETION REPORT AND O la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ' ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development • ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 6/7/2012 • 203 -186 / 312_-/o2 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 12/4/2003 50 029 - 20843 - 02 - 00 - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/8/2003 PBU C -27B 1755' F-NL, 1033' FEL, SEC. 19, T11 N, R14E, UM 8. KB (ft above MSL): 72 - 15. Field / Pool(s): Top of Productive Horizon: 1876' FNL, 642' FWL, SEC. 29, T11 N, R14E, UM GL (ft above MSL): 37.29' • Prudhoe Bay Field / Prudhoe Bay • Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 1369' FNL, 1048' FWL, SEC. 29, T11 N, R14E, UM 11125' 8948' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 664357 - y- 5959463 • Zone ASP4 11947' • 9025' ' ADL 28305 & 028310 • TPI: x - 666169 y- 5954102 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 666563 y 5954618 Zone ASP4 None 18. Directional Survey: ■■ 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: SGRC, GR, EWR, MGR, CCL, CNL 10518' 8464' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP 1 BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 9 cu vds Concrete 13 -3/8" 72# L -80 Surface 2739' Surface 2684' 17 -1/2" 3906 cu ft Arcticset II 9 -5/8" 47# L -80 Surface 10463' Surface 8420' 12 -1/4" 1455 cu ft Class 'G'. 130 cu ft AS I 7" 26# L -80 10212' 10518' 8222' 8464' 8 -1/2" 451 cu ft Class 'G' 3- 1/2'x3- 3/16'x2 -7/8" 8.81#/6.2#/6.16# L -80 10168' 11947' 8188' 9025' 4 -1/8" x 3 -3/4• 101 cu ft 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): 5 -1/2 ", 17 #, L -80 2511' MD TVD MD TVD 4-1/2",12.6#,L-80 2511' - 11125' 10147' / 8171' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. atoOMED 2 5 r } JUL ' 5 2 012 DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 11125' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production 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 1 1 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes IS No . Sidewall Core(s) Acquired? ❑ Yes ® No . If Yes to either uestion list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, q ( P ) 9Y gas or water P 9 (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None R %DMS JUL 03 2012 l ' �. �3� � 6 I t . I • L Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE 7 glz Submit Original Only V 1 .1 29. GEOLOGIC MARKERS (List all formations andkers • encountered): 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No . Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. • Shublik B 10545' 8485' None Shublik C 10577' 8510' Zone 4B 10597' 8525' Zone 4A 10767' 8642' Top CGL / Top Zone 3 10855' 8713' Base CGL / Top Zone 2C 10957' 8805' 23SB / Zone 2Bu 11020' 8863' 22TS / Zone 2BI 11100' 8930' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the for oing is tr and c . rr ct to the best of my knowledge. Signed: Joe Lastufka L itle: Drilling Technologist Date: b 1Z 112- - PBU C - 27B 203 - 186 Prepared ByName/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Matt Ross, 564 -5782 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only • • C -27B, Well History (Pre Rig Sidetrack) Date Summary 04/12/12 RAN 3.805 CENT TO TOP OF PATCH AT 10,071 SLM (10106' ELMD) ALL CLEAR. 04/13/12 LATCHED 4 -1/2" BAKER KB PATCH AT 10069' SLM (10106' ELMD). PATCH HUNG UP IN GLM #3 (7456' MD) JARRED FOR A TOTAL OF 2 HOURS AT 1800# - 2000 #. MOVED PATCH FROM 7408' SLM - 7291' SLM. 04/14/12 PULLED 4 1/2" BAKER KB PATCH FROM 7301' SLM. (LOST 2 -1/2 ELEMENTS) RAN 3.62 2 PRONG GRAB TO BAKER DEPLOYMENT SLEEVE AT 10164' SLM (10186'MD) REC ONE SMALL PIECE OF ELEMENT, RDFN. 04/15/12 RAN 4 -1/2" BRUSH, 3.5" 4 PRONG GRAB, SAT DOWN @ 10,164 SLM, NO REC. RAN 4 1/2" BRUSH, 3.5" 3 PRONG GRAB, SAT DOWN @ 10,164 SLM, NO REC. RAN 3.5" X 10' PUMP BAILER, W/ JUNK CATCHER, SAT DOWN @ 10,164 SLM, NO REC. RAN 2.70" CENT, 3 -1/2" BRUSH, XO, 1.5 SWAGE, SAT DOWN © 10,217 SLM. PUSHED RUBBER ELEMENTS DOWN TO 11,205 SLM...ALL CLEAR. RAN 3 -1/2 GR W/ 20' X 2.70" DUMMY WHIPSTOCK TO 10,500 SLM, SAT DOWN. DID NOT MAKE TARGET DEPTH, LDFN. 04/16/12 RAN 2.70" X 10' DUMMY WHIPSTOCK TO 10498' SLM. (10520' MD) WHIPSTOCK HUNG UP AT 10479' SLM. (10501' MD) CORRECTION TAKEN OFF LINER TOP. TOTAL OF THREE RUNS TO JAR WHIPSTOCK ALL THE WAY OUT OF LINER. SCRAPE MARKS ON THE CENTER 7' OF DRIFT. 04/28/12 T /I /O= 1964/0/0 Conducted PJSM; Greased all tree valves; Performed leak tight test on MN, SSV & SN (passed); Removed tree cap using MN & SSV as barriers.; Installed lubricator & P.T. (charted) w /each break to 300 psi /3500 psi (passed); Set 6" CIW "J" TWC #423 © 114" w/1 -2' ext; Bled off tree form TWC up (passed); Torqued all tree flange nuts /studs to spec. (see log) w /open bleed.; P.T. (charted & downloaded into U- drive) tree to 300 psi /4700 psi (passed) Note: 4700 was max on P.T. pump; Pulled TWC #423 Q 112" w /1 -2' ext.; Pre Nordic 1. 05/06/12 CTU #9 1.75" Job Scope: 3 3/16" Dummy whipstock drift. RU. MU drift toolstring w/ 2.25" CTC, 2.13" DCV, 2.13" Jar, 2.13" Hyd Disco, 2 x 2.63" Drift bars, 2.63" Bull Nose Guide. OAL= 27.7'./ Clean Drift to 11220' CTM. POOH Freeze protect to 2500' w / 58 bbls of 60/40 Methanol. 05/14/12 T /I /O = SSV /150/0 +. Temp = SI. WHPs(Pre -CTD). Well house and flowline have been removed. Swab platform has no railings or gate. SV, WV, SSV, MV = C. 14:45. 05/16/12 T /1 /O= Vac /140/20. Temp= SI. WHPs (Pre -CTD). Wellhouse and flowline have been removed. Drilling scaffold in place. Cycled MV 1 time. SV, WV, SSV & MV =C. IA & OA =OTG. NOVP. 1500 hrs. 05/28/12 T /I /O = SSV /170/0 +. Temp = SI. Bleed IA & OA to 0 psi. No AL. IA FL near surface. Bled IAP from 170 psi to 0+ psi in 1.5 hours. No monitor due to lack of time. Final WHP's = SSV /0 +/0 +. SV, WV, SSV, MV = Closed. IA & OA = OTG. NOVP. 16:30 . 05/29/12 T /I /O = SSV /24/2. Temp = SI. WHPs (pre CTD). Flowline and wellhouse disconnected. IAP increased 24 psi, OAP increased 2 psi. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 0900. 05/30/12 T /I /O = Vac /24/4. Temp = SI. Bleed IAP & OAP to 0 psi. (Pre CTD). Flowline and wellhouse have been removed. IA FL near surface. OA FL near surface. Bleed IAP from 24 psi to 0 psi in 1 hour and 30 minutes. Bleed OAP from 4 psi to 0 psi in 20 minutes. During OA bleed and 30 minute monitor IAP increased 2 psi. During 30 minute monitor OAP unchanged. FWHP's = Vac /2/0. SV, WV, SSV, MV = Closed. IA, OA = OTG. NOVP. 02:30 hrs. Page 1 of 2 • • C -27B, Well History (Pre Rig Sidetrack) Date Summary 05/31/12 T /I /O= VAC /0 /0. Conducted PJSM; Performed P.T. on SSV and MN to 300 psi /3500 psi (charted) as barriers (passed), removed tree cap, installed lubricator & P.T. (charted) 300 psi low and 3500 psi high (passed); Set 6" CIW "J" TWC #424 @ 114" w /1 -2' ext used, rigged down lubricator, installed tree cap P.T. TWC low of 300 psi and high of 3500 psi (charted +passed) No problems; Shut in I/A Valve monitored for 5 min. *"*no pressure build up''', removed flange, installed second I/A valve torqued to specs per Nordic 1 request, (charted) P.T. low 300 psi /high 3500 psi (passed); Pre Nordic 1. Page 2 of 2 • • North America - ALASKA BP .. page l of 34 Operation Summary Report Common Well Name: C -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/15/2012 End Date: 6/19/2012 X3 -011 WD (2,419,001.00 ) , Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 11/11/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'44.049 °9 Long: 0148°40'08.724'W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) (ft) 6/2/2012 18:00 - 20:15 2.25 MOB I P PRE ' PREP RIG FOR MOVE. WARM UP MOVING I SYSTEM. 20:15 - 20:30 0.25 MOB P PRE NORDIC SUPERINTENDENT ON LOCATION. INSPECT AROUND RIG IN PREPARATION FOR MOVE. HOLD PRE -RIG MOVE SAFETY MEETING WITH RIG CREW, NORDIC FIELD SUPT, TOOLPUSHER, AND WSL. DISCUSS OBSTACLES ON PAD, POSITION OF EQUIPMENT, PLANNED ROUTE, E -STOP FUNCTION, STOP SIGNALS, CLEAR & , CONCISE RADIO COMMUNICATION, AND _ ' SPOTTER POSITION. 20:30 - 22:00 ! 1.50 MOB P PRE PULL OFF C-12. MOVE RIG TO C-27. CONFIRMED TWC INSTALLED, ALL VALVES • • • * • 1 1 : 1 D ANNULUS. PULL OVER C-27. ACCEPT RIG AT 2200 HRS. 22:00 - 00:00 2.00 MOB P PRE SPOT CUTTINGS BOX, TIGER TANK. POSITION EQUIPMENT. PREP FOR OPERATIONS. CONFIRM PRESSURE TESTING OF TREE BODY AND VALVES WITH PRE -RIG TEST CHARTS AND VALVE SHOP FOREMAN. REMOVE TREE CAP, VERIFY LEAK TIGHT TEST. BEGIN NU BOP. 6/3/2012 00:00 - 05:00 5.00 RIGU P PRE ' NIPPLE UP BOP. GREASE MANIFOLD. PREP LOCATION. STAGE TIGER TANK, PRESSURE (TEST LINES. STAGE CUTTINGS BOX. rN GREASE MUD CROSS. N i 05:00 - 11:30 6.50 RIGU P PRE ' CONDUCT RIG MAINTENANCE ON AUDIT !I CORRECTIONS. ,11:30 - 13:00 1.50 BOPSUR P PRE FUNCTION TEST BOPE FROM THE OPS CAB . 13:00 - 13:20 ! 0.33 BOPSUR P PRE SHELL TEST BOPE 13:20 - 17:00 3.67 BOPSUR P ! PRE CALL AOGCC AS REQUESTED AFTER A V GOODS SHELL TEST AND CHUCK SHEEVE 1� HAS WAIVED WITNESSING THE TEST, CONTINUE TESTING BOPE 17:00 - 17:20 0.33 RIGU P PRE REVIEW HIGH GOR SOP AND HOLD PRE -SPUD WITH CREWS (NIGHT TOUR HELD ! - BRIEFS DURING PRE -TOUR MEETING) 17:20 - 17:45 0.42 RIGU P PRE ** *HOLD RIG EVACUATION DRILL * ** GOOD DRILL, ALL PERSONNEL REPORTED TO THE PRIMARY MUSTER AREA IN —2 MIN !WHERE THE HEAD COUNT WAS TAKEN. ONLY DEFFICIENCY TO REPORT WAS A DOOR LEFT OPEN ON THE SECOND LEVEL. I DESCRIBED THE INCIDENT THAT HAPPENED ON THE NABORS RIG WHEN THAT RIG WAS EVACUATED AND SOME OF THE DOORS WERE LEFT OPEN AND THE RIG FROZE UP BY THE TIME THEY MADE ENTRY BACK INTO THE RIG. CLOSE ALL DOORS BEHIND YOU! 17:45 - 20:30 2.75 BOPSUR P PRE , CONTINUE TESTING BOPE. TEST FLOOR SAFETY VALVES. WITH TEST COMPLETE, BARRIERS TO WELL ARE NOW: TWC, MASTER AND SWAB VALVE, TESTED BOP. Printed 6/25/2012 11:05:59AM • North America - ALASKA - BP • Page 2 of 34 Operation Summary Report Common Well Name: C -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/15/2012 I End Date: 6/19/2012 X3-011 WD (2,419,001.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 11/11/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'44.049 "9 Long: 10148 °40'08.724' W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Date I From - To Hrs Task Code I NPT NPT Depth I Phase Description of Operations (hr) (ft) ±20:30 - 23:30 3.00 RIGU P PRE CONDUCT COIL PREPARATION. STAB ON WITH INJECTOR, BREAK OFF OF STUFFING BOX. CUT E -LINE, BOOT UP. CUT MULESHOE FOR COIL. CHANGE OUT BRASS IN COIL STUFFING BOX. CHANGE OUT UPPER AND LOWER PACKOFFS ON 'INJECTOR. 23:30 - 00:00 0.50 RIGU P PRE SIMULATED OUT OF CONTROL FIRE IN MOTOR ROOM. EVACUATE RIG. GOOD RESPONSE. ALL PERSONNEL IN PRIMARY MUSTER AREA IN 2 MINUTES, 15 SECONDS. CONDUCT AAR. ONE TOPIC OF DISCUSSION IS WHETHER OR NOT TO MANUALLY SET RAMS ON WELL TO SECURE WELL. PROCEDURE DOES NOT CALL FOR IT AND DISCUSSION LED TO AGREEMENT THAT PERSONAL SAFETY IS PRIORITY AT THAT POINT. PLAN WOULD DEVELOP BASED UPON WHERE FIRE IS AND DANGER LEVEL. 6/4/2012 100:00 - 00:30 0.50 RIGU P PRE ATTEMPT TO FILL COIL. LEAK AT PRESSURE BULKHEAD. 00:30 01:45 1.25 RIGU N SFAL PRE ''TROUBLESHOOT AND REPAIR PRESSURE �I ',BULKHEAD 01 :45 - 02 :45 1.00 RIGU P PRE FLUID PACK COIL. REVERSE CIRCULATE TO PUMP BACK CABLE. PRESSURE TEST INNER REEL IRON AND INJECTOR PACKOFFS TO 1 250 PSI LOW, 3500 PSI HIGH. PRESSURE BULKHEAD LEAKING DURING HIGH • PRESSURE TEST. 02:45 - 04:45 2.00 RIGU N SFAL PRE TROUBLESHOOT AND REPAIR PRESSURE BULKHEAD. CONTINUE WITH CLEARING AND CLEANING AROUND RIG DURING REPAIR. LOAD IN WHIPSTOCK AND MOTOR FOR MILLING WINDOW. PULL NEW FEED PUMP TO FLOOR. 04:45 - 05:15 0.50 RIGU P PRE FLUID PACK COIL. TEST INNER REEL IRON AND PACKOFFS TO 250 PSI LOW, GOOD TEST. CONTINUE TO PRESSURE UP TO 3500 PSI HIGH, PRESSURE BULKHEAD LEAKING AGAIN. BLEED DOWN PRESSURE. 05:15 - 06:00 0.75 RIGU N SFAL PRE INSPECT PRESSURE BULKHEAD AGAIN. TEARDOWN FOR RE- BUILDING. 6/5/2012 00:00 - 00:45 0.75 EVAL C 1 PROD1 CONTINUE WITH PUMPING OPS TO DETERMINE LIQUID LEAK RATE. - FINAL CIRCULATING PRESSURES AT 1.0 BPM: 2580 PSI ON IA, 1760 PSI SIWHP - REDUCE RATE TO .75 BPM WITH 2545 PSI ON IA, 1770 PSI ON SIWHP - FINAL DETERMINATION OF LIQUID LEAK RATE IS .8 BPM AT 2570 PSI, SIWHP AT 1770 PSI. Printed 6/25/2012 11:05:59AM North America - ALASKA - BP • Page 3 of 34 Operation Sum Report Common Well Name: C -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/15/2012 I End Date: 6/19/2012 X3 -011 WD (2,419,001.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 11/11/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'44.049 "9 Long: 10148°40'08.724"W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT 1 NPT Depth ' Phase 1 Description of Operations (ft) ' 00:45 04:45 I 4.00 EVAL C I PROD1 DOWN ON PUMPS. IA BLED OFF RAPIDLY IN CONJUNCTION WITH WHP. ON WITH RIG PUMPS ACROSS TOP TO KEEP HOLE FULL AT .2 BPM WITH 50 PSI. INITIAL IA PRESSURE CAME UP TO 700 PSI. - PJSM ON STAGING SLB SLICKLINE UNIT, ! STAGING LRHOS AWAY FROM RIG AND RIGGING UP THEIR HOSES FOR PUMPING 1 DOWN IA DURING "SPINNER" LOGGING. I- LINE OUT LRHOS HOSES, PRESSURE TEST ! TO 250 PSI LOW AND 3500 PSI HIGH j STAGE SLB SLICKLINE UNIT. RU SHEAVES. MOBILIZE SLICKLINE LUBRICATOR AND PUMP -IN SUB TO RIG FLOOR. RU SLB BOP UNIT, LUBRICATOR, QUICK TEST SUB, PUMP -IN SUB II - IA PRESSURE INCREASED TO 860 PSI, I I SIWHP INCREASED TO 225 PSI DURING RU OPERATIONS 04:45 - 06:00 1.25 EVAL C T PROD1 STOP PUMPING DOWN TUBING. CLOSE I MASTER, PRESSURE TEST TO 250 LOW, 3500 PSI HIGH. CLOSE SWAB AND TEST SAME. GOOD TESTS. BREAK OFF NIGHT CAP AND RU SLB SLICKLINE LUBRICATOR WITH BOP AND PUMP -IN SUB TO BOP STACK. PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. 1 I IA PRESSURE FALLING OFF DUE TO NO PUMPING DOWN TUBING 06:00 - 07:00 ! 1.00 EVAL ! C PROD1 OPEN UP TO WELL, NO PRESSURE. CREW CHANGEOUT WITH SCHLUMBERGER, LITTLE RED, AND NORDIC CREWS. 07:00 - 10:00 ' 3.00 STWHIP C i WEXIT CONDUCT DRIFT RUN WITH 2.71" CENTRALIZER AND 2.5" BAIL BASKET. NO ISSUES. LD DRIFT BHA. 10:00 - 15:30 5.50 STWHIP C WEXIT I MU "SPINNER" LOGGING BHA. RIH WITH LOGGING BHA WITH NO PUMPS TO DETERMINE BASELINE. PUMP DOWN BACKSIDE, EVENTUALLY REACHING A LIQUID LEAK RATE OF 2500 PSI AT 1.3 BPM. LOG AT ALL INTERVALS OF CONCERN. POH. RETRIEVE MEMORY TOOL FROM BHA. 15:30 - 17:30 2.00 1 , STWHIP C WEXIT DOWNLOAD DATA FROM LOGGING RUN. 1 ANALYZE DATA. MEET WITH WSL ON ' INTERPRETATION. DETERMINED THAT ONLY LEAK POINT IN WELL IS AT CEMENT JOB OF I PREVIOUS TUBING PUNCH. Printed 6/25/2012 11:05:59AM • North America - ALASKA - BP Page 4 of 34 Operation Summary Report Common Well Name: C -27 ' AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/15/2012 End Date: 6/19/2012 X3 -011 WD (2,419,001.00 ) _ _ a Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 11/11/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'44.049 "9 Long: 0148 °40'08.724'W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:45 - 22A5 2.00 WHIP P WEXIT 1 DISPLACE FRESH WATER FROM COIL WITH KCL. PRESSURE TEST AGAINST MASTER AND SWAB TO 250 PSI LOW, 3500 PSI HIGH. GOOD TEST. OPEN UP TO WELL, NO PRESSURE. FILL WELL AGAINST CLOSED ' CHOKE UNTIL WELLHEAD PRESSURE OBSERVED. TOOK 15 BBLS TO OBTAIN POSITIVE WELLHEAD PRESSURE. OPEN UP CHOKE AND FILL ACROSS TOP WHILE MONITORING WELL. - IA AT 645 PSI WHILE PUMPING ACROSS TOP - SHUT DOWN PUMPS AND MONITOR TO DETERMINE LOSS RATE. IA PRESSURE DROPPED TO 600 PSI DURING EVALUATION PERIOD. - ON WITH PUMPS TO FILL WELL. CALCULATE 8 BPH LOSS RATE. BAKER REP ON LOCATION. CONTINUE TO PUMP ACROSS TOP WHILE HAVING PJSM ON BHA MU. 22:45 - 00:00 1.25 STWHIP P WEXIT PULL NIGHTCAP. MONITOR WELL. MU 'WHIPSTOCK BHA. STAB ON WITH INJECTOR. PRESSURE TEST QUICK TEST SUB. 6/6/2012 00:00 - 03:00 T 3.00 STWHIP ' P WEXIT RIH WITH WHIPSTOCK BHA WITH EDC OPEN AND FILLING WELL ACROSS THE TOP. IA PRESSURE WHILE RIH AT 680 PSI. DENSITY 1 CHANGES BEGINING AT 6800'. DENSITY AT 6.2 PPG AT 8100'. NO ISSUES WITH FLOW THROUGH GAS BUSTER. LOTS OF DIESEL COMING BACK WITH RETURNS. DENSITY AND OUT RATE ERRATIC BUT NO ISSUES FLOWING THROUGH MUD GAS SEPARATOR. IA PRESSURE HOLDING AT 690 PSI. PICK UP WEIGHT 43K AT 10,000'. 03:00 - 03:30 0.50 STWHIP P WEXIT INCREASE CIRCULATION DOWN COIL AND PUMP WHILE PICKING UP TO TIE -IN POINT TO KEEP POSITIVE FLOW THROUGH MUD GAS SEPARATOR. PINCH IN CHOKE TO MAINTAIN 100 PSI BACKPRESSURE WHILE PICKING UP HOLE AND DURING LOGGING. PICK UP TO 10,470' FOR LOGGING. - CIRCULATION PRESSURE 770 PSI, IA PRESSURE AT 790 PSI AT 1.90 BPM. INCREASE IN DIESEL RETURNS, DIVERT RETURNS FROM MUD GAS SEPARATOR TO TIGER TANK UNTIL RETURNS ARE BACK TO PRIMARILY KCL. - CIRCULATION PRESSURE 935 PSI, IA PRESSURE AT 895 PSI AT 2.0 BPM + 03:30 - 05:00 1.50 STWHIP P WEXIT LOG TIE -IN WITH -22.5' CORRECTION. - MAINTAIN 2.0 BPM, 915 -930 PSI CIRCULATION. DENSITY AND RATE OUT TO TIGER TANK LOOK GOOD, TAKE RETURNS BACK TO MUD GAS SEPARATOR THROUGH PARTIALLY CLOSED CHOKE TO MONITOR RETURNS. EVENTUALLY OPEN TO FULL OPEN WITH STEADY DENSITY AND OUT ! RATE. TAKE RETURNS THROUGH NORMAL FLOW PATH WITHOUT MUD GAS SEPARATOR - IA AT 775 PSI WHILE PUMPING AT 2.O BPM Printed 6/25/2012 11:05:59AM • North America - ALASKA - BP IP Page 5 of 34 Operation Summary Report Common Well Name: C -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) 1 Start Date: 5/15/2012 1 End Date: 6/19/2012 'X3 -011 WD (2,419,001.00 ) Project: Prudhoe Bay I Site: PB C Pad Rig Name /No.: NORDIC 1 I Spud Date/Time: 11/11/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'44.049 "9 Long: 0148°40'08.724'W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth !, Phase Description of Operations (hr) (ft) 05:00 - 05:30 0.50 STWHIP P I I WEXIT PICK UP TO 9900'. LOG CCL FOR PLACING LINER TOP FROM 9900' TO 10,200'. 05:30 - 06:00 0.50 STWHIP P I WEXIT RIH TO 11,000'. LOG CCL FOR WHIPSTOCK PLACEMENT FROM 11,000' TO 11,300'. 06:00 - 07:30 1.50 STWHIP P I WEXIT PU TO WHIPSTOCK SETTING DEPTH OF 1 11,134' (TOP OF WHIPSTOCK AT 11,125'). ORIENT TO 45 -LOHS. I !CIRCULATE BOTTOMS UP. INCREASE RATE TO 3.25 -BPM IN / 3 -BPM OUT WITH 2580 -PSI. IA / OA PSI AT RATE = 960 -PSI / 20 -PSI. LOSS RATE INCREASES 1SLIGHTLYTO 16 -BPH WHILE CIRCULATING AT INCREASED RATE. 07:30 07:45 0.25 STWHIP 1 P WEXIT I SHUT DOWN PUMP & CLOSE EDC. PRESSURE UP TO SET WHIPSTOCK PER PLAN AT 45 -LOHS WITH TOP AT 11,125'. SEE SET AT 3640 -PSI. PU TO 11,100'. ROUTE RETURNS TO TIGER TANK FOR 10 -BBLS. 07:45 - 08:45 1.00 STWHIP P ' WEXIT j CIRCULATE FULL WELLBORE VOLUME AT 1 2.5 -BPM WITH 2200 -PSI. IA / OA = 900 -PSI / I 20 -PSI. NO LOSS RATE. 08:45 - 11:00 2.25 STWHIP P 1 WEXIT I WITH 102 -BBLS PUMPED - SEE RETURN ' RATE INCREASE. SHUT DOWN PUMP AND MONITOR. PRESSURE NOT INCREASING. ' DISCUSS SITUATION WITH ODE AND CTD SUPT. DECIDE TO CIRCULATE SUSPECTED IA FLUID TO TIGER TANK. SMALL AMOUNT OF GAS & —10 -BBLS DIESEL 'RETURNS TO TIGER TANK. ONCE RETURNS CLEAN UP, TAKE THEM BACK TO THE PITS. I CIRCULATE AT 2.5 -BPM / 2600 -PSI . IA = 950 -PSI. NO ISSUES NOTED AT BOTTOMS UP I FROM SHUT DOWN POINT. CONTINUE TO CIRCULATE FOR A TOTAL OF 2.5X BOTTOMS UP. 11:00 - 12:00 1.00 STWHIP P WEXIT LINE UP TO TIGER TANK TO ALLOW LUBRICATOR GAS TO VENT OUTSIDE. ONCE OUT MM SHOWS NO FLOW, ESTABLISH KCL RETURNS. LINE UP TO POSSUM BELLY AND SHUT I DOWN PUMPS. FLOW CHECK WELL. IA PRESSURE DROPS TO 685 -PSI AS SOON I ! AS PUMPS ARE SHUT DOWN. BLEED IA (ALL FLUID) FROM 685 -PSI, STABLIZES AT 520 -PSI DURING BLEED. SHUT IN AND IA UP TO 675 -PSI IMMEDIATELY, THEN SLOWLY INCREASES AND STABLIZES AT 685 -PSI I AGAIN. I CONTINUE TO FLOW CHECK - NO FLOW 'OBSERVABLE FOR 15- MINUTES. 12:00 - 12:30 0.50 STWHIP 1 P WEXIT ESTABLISH CIRCULATION AT 2.5 -BPM / !, 3250 -PSI AND STAGE PUMP UP TO 3 -BPM / 3400 -PSI. IA / OA = 931 -PSI / 20 -PSI. PVT = 196 -BBLS. ' POH WITH WHIPSTOCK RUNNING TOOLS 'FROM 11,100' TO 8225'. TRIP SHEET I MATCHES CALCULATIONS. Printed 6/25/2012 11:05:59AM North America - ALASKA - BP . Page 6 of 34 Operation Summary Report Common Well Name: C -27 ! AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 5/15/2012 End Date: 6/19/2012 X3 -011 WD (2,419,001.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 11/11/1982 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'44.049 "9 Long: 0148°40'08.724'W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Date From - To Hrs Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (ft) 1 12:30 - 13:00 0.50 I . STWHIP P WEXIT WITH 100 -BBLS PUMPED (BOTTOMS UP I ! FROM KNOWN HOLES) SEE DIESEL / CRUDE !RETURNS. STOP MOVING COIL AND TAKE CRUDE / DIESEL / GAS RETURNS TO TIGER , I , TANK. SCS NOTIFY BP RADIO, PAD OP & SIM OPS OF CONTINUING GAS VENTING. 1 !RETURNS CLEAN UP AFTER 30 -BBLS. TAKE RETURNS BACK TO PITS. 13:00 - 14:30 1.50 STWHIP P WEXIT CONTINUE TO POH FROM 8225' TO 200' CRICULATE AT 2.6 -BPM / 2400 -PSI / PVT = 1 146 -BBLS. IA / OA = 880-PSI/ 20 -PSI. 14:30 - 15:00 0.50 STWHIP 1 P , I WEXIT HOLD PJSM ON FLOW CHECK AND LD 'WHIPSTOCK RUNNING BHA. ' DISCUSS POSITIONS OF PEOPLE, BHA HANDLING IN THE EVENT OF WELL CONTROL OPS, CURRENT WELL CONDITIONS, AND SIMOPS ON RIG SITE. I FLOW CHECK WELL - NO FLOW. IA PRESSURE WITH PUMPS OFF = 688 -PSI. 15:00 - 16:00 1.00 STWHIP P WEXIT UNSTAB INJECTOR & SET BACK OVER CIRC HOLE. ' BLOW DOWN AND LD WHIPSTOCK RUNNING BHA. SEND OUT WHIPSTOCK RUNNING I ! TOOLS. FILL WELL AND MONITOR. BLOW DOWN TIGER TANK HARDLINE. , ', , IA / OA / PVT = 690 -PSI / 20 -PSI / 96 -BRCS. ! 16:00 - 18:30 2.50 STWHIP P WEXIT HOLD PJSM ON RU IA CIRCULATION LINE. DISCUSS EQUIPMENT NEEDED, DOUBLE I I VALVE ISOLATION FROM RIG, COMMUNICATION BETWEEN DSM & RIG CREW AND OBJECTIVES. MOVE SLOP TRAILER AWAY FROM RIG AND SPOT CHOKE SKID. MOVE SLOP TRAILER !BACK INTO POSITION. I HARDLINE CREW MU HARDLINE FROM CELLAR THROUGH CHOKE SKID TO TIE INTO I TIGER TANK LINE. REMOVE FLANGE FROM ' OUTERMOST IA VALVE & INSTALL INTEGRAL FLANGE TO ALLOW TIE -IN TO CIRC HOSE. !MU CIRC HOSE TO HARDLINE. ! ! HARDLINE CREW TEST ALL NEWLY INSTALLED HARDLINE TO 4000 -PSI USING I CRYSTAL DATA RECORDER. GOOD TEST. ! WELL IS STATIC. 18:30 - 19:45 1.25 STWHIP ! P WEXIT HOLD PJSM ON MU WINDOW MILLING BHA. I DISCUSS BHA COMPONENTS. MU 2.74" I ! MILLING BHA. STAB ON WITH INJECTOR AND I PRESSURE TEST QUICK TEST SUB. 19:45 - 22:00 I 2.25 STWHIP P WEXIT I RIH WITH MILLING BHA. 22:00 - 23:15 1.25 I STWHIP P I WEXIT FLOG TIE IN. PICK UP AND LOG CCL FROM ! I 9950' TO 10,300'. Printed 6/25/2012 11:05:59AM • North America - ALASKA - BP • Page 7 of 34 Operation Summary Report _J Common Well Name: C -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/15/2012 I End Date: 6/19/2012 X3 -011 WD (2,419,001.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 11/11/1982 12:00:00AM I Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'44.049 "9 Long: 0148 °40'08.724' W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Date I From - To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) ! (ft) 23:15 - 00:00 0.75 ~ STWHIP P 1 WEXIT RIH TO ABOVE TOP OF WHIPSTOCK. BEGIN TO CIRCULATE BOTTOMS UP. INITIAL PRESSURE OF 3860 PSI AT 2.5 BPM. PRESSURE SEEMS HIGH. WALK SURFACE LINES TO MAKE SURE EVERYTHING LINED UP PROPERLY. DOWN ON PUMPS. FUNCTION EDC TO CLOSED AND BACK TO ' OPEN POSITION TO ENSURE OPEN. BRING UP PUMPS TO 2 BPM, 2315 PSI. 2.6 BPM, - - - - - -- - - - - -- 3900 PSI. 6/7/2012 00:00 - 01:00 1.00 STWHIP P WEXIT ! CIRCULATE BOTTOMS UP TO VERIFY CLEAN 1 KCL ALL THE WAY AROUND. 2.55 BPM, 3900 ' I PSI. IA AT 940 PSI, SIWHP AT 40 PSI. NO 1 I CHANGE IN DENSITY, RATES OR PRESSURE I WITH BOTTOMS UP. CONTINUE I CIRCULATING AND PREP TO DISPLACE 50 ! BBLS FROM IA. PJSM ON LINE UP AND DISPLACEMENT. STRAP TIGER TANK, INSPECT LINES. 01:00 - 02:30 1 1.50 STWHIP P WEXIT I LINE UP OUTSIDE CHOKE SKID TO TIGER I TANK. RE- INSPECT VALVE ALIGNMENT ON RIG ISOLATE RIG FROM CHOKE SKID. INITIAL IA PRESSURE AT 690 PSI WITHOUT PUMPS ON. COME ON WITH RIG PUMP VERY SLOWLY AND STAGE RATE UP TO 1.5 BPM AGAINST CLOSED CHOKE TAKING RETURNS I UP IA THROUGH CHOKE SKID TO TIGER 1 I TANK. IA AT 705 PSI, SIWHP AT 65 PSI. IA I INCREASED TO 715 PSI AND SIWHP INCREASED TO 100 PSI. NO GAS TO TIGER TANK, FLUID PACK THE WHOLE TIME. PUMP 75 BBLS AWAY AT 1.5 BPM. FINAL IA PRESSURE 690 PSI, SIWHP 150 PSI. DOWN ON PUMPS, CLOSE IN IA. IA PRESSURE AT 665 PSI, SHUT IN PRESSURE DROPPED OFF TO 25 PSI. SLOWLY OPEN UP CHOKE ON RIG, CHECK FOR FLOW. IA DROPPED TO 575 PSI, INITIAL FLOW DROPPED OFF ' I IMMEDIATELY TO NO FLOW. FLOW CHECK WELL, NO FLOW. 02:30 - 04:45 2.25 STWHIP P WEXIT I DISPLACE FROM 8.4 PPG KCL TO 8.5 PPG DRILLING MUD. 3.0 BPM, 3000 PSI, 8.5 PPG IN AND OUT. CLOSE EDC. RUN DOWN AND DRY TAG AT 11,126.3'. PUW 43K. 04:45 - 05:15 0.50 STWHIP h N SFAL WEXIT TROUBLESHOOT MICROMOTION. OPEN EDC I I TO CIRCULATE AT HIGHER RATES. IA AT 960 PSI, CIRC PRESSURE 1990 PSI AT 2 BPM. COOL DOWN IN MICROMOTION SENSOR, FLUSH OUT MICROMOTION AS PREVENTATIVE MEASURE. IN AND OUT RATES GOOD. 05:15 - 06:00 0.75 STWHIP , P WEXIT I CLOSE EDC. OBTAIN SLOW PUMP RATES. CREEP DOWN AND TAG WHIPSTOCK WITH PUMPS ON AT 11,125.6'. PICK UP AND COME DOWN ON PUMPS. ELECTRICIAN ON SITE TO 1 I l LOOK AT OUT DENSITY ON MICROMOTION. Printed 6/25/2012 11:05:59AM • North America - ALASKA - BP Page 8 of 34 Operation Summary Report Common Well Name: C -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/15/2012 End Date: 6/19/2012 X3-011 WD (2,419,001.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 11/11/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °1744.049"9 Long: 0148°40'08.724'W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Phase Description of Operations ()_... Date From - To Hrs i Task Code NPT (hr) ft 06:00 - 07:30 1.50 STWHIP N SFAL NPT Depth WEXIT I INSPECT OUT MICROMOTION. CHECK FLUID DENSITY USING PRESSURE BALANCE. MW OF FLUID IN PITS = 8.5 -PPG, MW OF RETURNS = 8.5 -PPG. MM IN IS READING 8.62 -PPG, MM OUT IS READING 8.49 -PPG. OPEN EDC AND MOVE PIPE SLOWLY CIRCULATING AT 1.6 -BPM / 1700 -PSI. IA PRESSURE = 960 -PSI. ' DISCUSS WITH CTD SUPT AND AGREE TO TAKE MUD WEIGHTS USING PRESSURE BALANCE EVERY 15 -MIN. MW IN AND OUT PER PRESSURE BALANCE AT 0730 -HRS = 8.5 -PPG. ' CLOSE EDC & RIH. �, �' 07:30 - 18:00 10.50 STWHIP P WEXIT RIH VERY SLOWLY, PUMPING AT 1.67 -BPM / V' '2430 -PSI. IA PRESSURE = 950 -PSI. Cr 2 " 1 C� TAG WHIPSTOCK AT 11,125.6. STALL AND { PICKUP. RIH AGAIN AND BEGIN TIME MILLING FROM 11,125.3'. IA / OA / PVT = 960 -PSI / 25 -PSI / 319 -BBLS. 'TIME MILL FIRST 1', MONITORING DHWOB AND MOTOR WORK. SLOW PROGRESS MILLING AS KEEPING DHWOB BELOW 2.5K -LBS. CONSISTENT MOTOR WORK OF 200 TO 300 -PSI. 'WHILE MILLING WINDOW, GATHER RIG CREW AND HOLD IN -DEPTH DISCUSSION AND WALKTHROUGH OF LINING UP TO CIRCULATE THROUGH MGS. REVIEW NORDIC PROCEDURE & CHECKLIST. ASSIGN PEOPLE TO POSITIONS. PERFORM VERIFICATIONS REQUIRED BY CHECKLIST. SHOW NEW "RED -HAT" ROUSTABOUT ALL EQUIPMENT AND EXPLAIN FUNCTION. REVIEW VALVE LINE UP WITH CREW. EXCELLENT PARTICIPATION AND CONVERSATION. CATCH SAMPLE FROM 11,129.6'. VERY FINE METAL SHAVINGS. Printed 6/25/2012 11:05:59AM , , , • North America - ALASKA - BP • Page 9 of 34 Operation Summary Report Common Well Name: C -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/15/2012 End Date: 6/19/2012 X3-011 WD (2,419,001.00 ) Project: Prudhoe Bay r Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 11/11/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'44.049 "9 Long: , 0148°40'08.724'W Active Datum: ORIG KELLY BUSHING @72.40ft (above Mean Sea Level) Date From - To Hrs Task I Code ! NPT NPT Depth ! Phase Description of Operations 18:00 6.00 STWHIP 00:00 t (hr) — _.; ) --- WEXIT CONDUCT CREW CHANGEOUT. CONTINUE I WITH MILLING. DETERMINE THAT INITIAL EXIT AT 11,130.5' DUE TO PRESSURE • I DIFFERENTIAL AND CALCULATION FROM PINCH POINT. CALCULATE STRING MILL I EXITING WINDOW AT 11,131.5'. CONTINUE I IML MILLINti WINUUW. 13U (I OMS UP SAMPLE FROM 11,129' HAS VERY LITTLE FORMATION IN IT, MOSTLY PIPE SCALE. - HAVING TROUBLE TRANSFERRING WEIGHT I TO BIT. SUSPECT MOTOR HANGING ON WINDOW. CONSULT WITH MUD ENGINEER I , I ON LUBE PERCENTAGES AND BEST METAL -TO -METAL FRICTION ADDITIVE. - PICK UP TO MAKE REAM PASS AND HAVE 110K OVERPULL WITH DIFFICULTY PULLING UP PAST WINDOW. PULL PAST AND STALL ! I MOTOR AT 11,127'. MAKE TWO REAM PASSES TO ENSURE CLEAN EXIT. NO CHANGE IN BOTTOMS UP SAMPLE AT 11,131', PRIMARILY PIPE SCALE AND LINER RUNNING BEADS I- ABLE TO NOW GET GOOD WOB, ' INCREASED TO 2.8K AND DRILLED OFF QUICKLY, SLOWLY GRAB 1 /10TH TO KEEP ' WOB. BEST PARAMETERS SEEM TO BE 2.1- 2.5KWOB DRILLING OFF TO 1.8K WITH 500 -800 PSI DIFFERENTIAL. - DRILL TO 11,134', IN AND OUT MW 8.5 PPG, IA AT 965 PSI AT 1.67 BPM, 2545 PSI CIRC PRESSURE 6/8/2012 00:00 - 06:00 6.00 t STWHIP P WEXIT DRILL INTO OPEN HOLE BY PLACING WOB UP TO 2.5K AND ALLOWING TO DRILL OFF TO ' 1.8K WITH 650 -850 PSI DIFFERENTIAL AND I THEN REPEATING CYCLE. IN AND OUT MW 8.5 PPG, IA HOLDING 1 C ONSTANT AT 965 PSI AT 1.67 BPM, I 2500 -2580 PSI CIRC PRESSURE - BOTTOMS UP FROM 11,135' REVEALS 1 PRIMARILY METAL WITH ' 3% FORMATION COMING BACK - SAMPLE FROM 11,136' IS APPROXIMATELY 25% SANDSTONE WITH REMAINDER METAL - SAMPLE FROM 11,137' INCREASED TO ' [APPROXIMATELY 30% SANDSTONE, CONFIRMING DRILLING INTO OPEN HOLE AND NOT TRACKING CASING , - SAMPLE FROM 11,138' IS 40% SANDSTONE; 1 'CONTINUE DRILLING WITH SAME ' 'PARAMETERS I- MW IN AND OUT 8.5 PPS, CIRC PRESSURE ' 2525 PSI AT 1.65 BPM, IA AT 965 PSI - WINDOW COMPLETE AT 11.140. &' Printed 6/25/2012 11:05:59AM .TREE = * 6 -3 /8" CNN 1AELLHEAD = McEVOY • SAFE•DTES: WELL ANGLE> 70° I. 11252'. ACTUATOR = BAKER C C -2 7 B KB. ELEV = 72.3' BF. ELEV = 38.79' KOP = 2150' 2217' _15 - 1/2" OTIS HRQ SSSV NIP, ID = 4.562" Max Angle = 95° @ 11477' Datum MD = 11034' Datum ND = 8800' SS 2511' —5 -1 /2'X4- 1 /2"XO, ID= 3.958" 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" 2511' 2693' H 9 - 5/8" LW PKR GAS LIFT MANDRELS 1 13 -3/8" CSG, 72 #, L - 80, ID = 12.347" --I 2739' ST MD "ND DEV TYPE VLV LTCH' PORT DATE 7 3033 2913 43 LBD DMY RM 16 02/17/12 6 5037 4357 43 LBD DMY RM 0 01/16/09 5 6252 5235 47 LBD DMY RM 20 02/17112 Minimum ID = 2.372" @ 10338' 4 6992 5769 43 LBD DMY RA 0 10/26/87 3 -3/16 X 2 -7/8" XO 3 7456 6109 43 LBD DMY RA 0 10/26/87 2 7919 6456 41 LBD DMY RA 0 10/26(87 1 8026 6538 40 LBD DMY RA 0 10/26/87 TOP OF CEMENT IN LA (04/04/11) I 10050' I I ■ 10067' _ 4-1/2" OTIS XA SLD SLV, ID = 3.813" Yr ► t' ► i 4 i 0 : 4 i .1".• � - I 10131' HTIW PRB SEAL ASSY 1 TUBING PUNCH (03/22/11) — 10110' - 10112' ELMD �i �0 10125 - 1D1[7 MD ■T . - ' I 10147' H9 /8 "X4 112 " TIWHBBPPKR,ID = 4.750" I 10186' H 3.T BKR DEPLOY SLV, ID = 3.0" 1 10206' H 3 -1 /2" HES X MP, ID = 2.813' ■ 10212' I--1 BOT LNR HGR TIEBACK SLY, ID = ? I 3-1/2" LNR, 8.81#, L -80, .0087 bpf, ID = 2.992" I 10207' ► 4 . 10238' H 3 -1 /2" X 3 -3/16" X0, ID = 2.880" I ►• ►• .4 ► 4 19 -5 /8" CSG, 47 #, 1 -80, ID = 8.681" I--I 10463' I ►• /� ►' MIL LOUT WNDOW (C•27B) 10513' - 10521' •■, TOP OF HIPSTOCK 10518' ► * ,. W ∎ I� .• • ,4 11205'. -I FISH - KB PATCH ELEMENTS V _ e PUSHED BTM (4/16/12) • PERFORATION SUMMARY .•'• • �� .►•••• . 11 •�•�•�•�4�11 11338' — 3- 3116" X 2 -7/8" X0, REF LOG: SPERRY SUN MCNL /GR LOG ON 12/09/03 ■••••4 /■••■ ID = 2.372" ANGLE AT TOP PERF: 69° @ 11250' ► 4 ► Note: Refer to Production DB for historical perf data 4. •• •• ♦ 4 ► ••• u SIZE SPF INTERVAL O n/S z DATE ► 4�4 �4�4�� ► � 11913' -I P8TD P Q ••••••4 2" 6 11250 - 11268 0 06/2 1 /05 ► i � i 4 i 4 i i i$ • i / 4 :i 2" 6 11550 - 11910 0 12109/03 •�4 ►•�•�j •ai • ♦ ♦ ♦ ♦ • ••.•, 3 LNR, 6.2 #, L -80, .0076 bpf, ID = 2 805 11338 7" LNR, 26 #, L -80, ID = 6 276 "] —j 11480' •�• . ' 11,..... I2 -7 /8" LNR, 6.16 #, L -80, .0055 bpf, ID = 2.372" I-1 11947' 7 i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT I 12/14182 INITIAL COMPLETION ' 02/22/12 DAS/JMD GLV C/O (02/17 /12) WELL: C -278 01108/97 CT D SIDETRACK (C-27A) 02/22/12 JMD TVD CORRECTIONS PERMIT No: '031860 12109103 TMN(KK CTDSIDETRACK(C -27B) 04/22/12 JRP/ PJC PULL PATCH/ FISH (4/14- 16/12) AR No: 50- 029 - 20843 -02 06103/11 TW/ PJC SET KB PATCH (06/02/11) SEC 19, T11 N, R14E, 1755' SNL & 1033' WEL 07/29/11 AJ! PJC TREE CIO (07 /18/11) 08/14/11 AT! PJC GLV CJO (08/13/11) I BP Exploration (Alaska) ■ TREE = 6-3/8' CIW III WELLHEAD = McEVOY 2 7 C SAFETY NOTES: WELL ANGLE > 7W 0 11274' '"' ACTUATOR = BAKER C KB. ELEV ; 72:44' PJC DRAFT 1 BF. ELEV = _ - ry - — 38.79' KOP =---- ---- - — 1400' M= 98° @ 11461' 2217' _15 -1/2" OTE HRO SSSV NP, D = 4.562' 1 Datum MD = 11030' IW Datum TVD = 8800' SS 1 2511' H5 -1/2" X 4-1/2' XO, D= 3.958'' 120' X 30' CONDUCTOR 110' 2693' 9-5/8" CA/ PKR 5-1/2" TBG, 174, 1-80 AB -MOD, H 2511• GAS LIFT MANDRELS .0232 bpf, ID = 4.892' ST MD 'YD DEV TYPE VLV LTCH PORT DATE J 7 3033 2913 43 LBD DOME RM 16 07/04/12 1 13 -3/8' CSG, 724, L-80 BUTT, ID = 12.347" 1 2739' 6 5037 4357 43 LBD DMY RM 0 01/16/09 5 6252 5235 47 LSD SO RM 20 07/04/12 4 6992 5769 43 LBD DMY RA 0 06115/97 Minimum ID = 1.78" @ 10150' 3 7456 6109 43 LBD DMY RA 0 06/15/97 2 7919 6456 41 LBD DMY RA 0 06/15/97 WIPER PLUG IN DEPLOY SLEEVE 1 8026 6538 40 LBD DMY RA 0 06/15/97 — 10030• — I4' GS 45 KB PKR, ID = 2.38' 1 (TOP OF CEMENT IN IA (04/04/11) 10050' I' 1. ., tI I I I 10067' J4 -1/2' OTIS XA SID SLV, ID = 3.813' BEHIND LNR 1 • ". 11 10147' — 9-5/8" X4-1/2- TAN HBBP PKR ID = 4.00' TUBING PUNCH (03/22/11) 10125' - 10127' '? �� . *4 (', (D 4. 10110' - 10112' ELMD l 'i I Ill, 10131' --111W PRB SEAL ASSY, ID = 4.00' LNR ►!►. .i4i ►Mt ►mt — 10134' 1J4'GS45KBPKR,D =2.38" 12 -7 /8' LNR, 6.4v, L-80 STL ?, .0058 bpf ID = 2.441" -i 10140 m, 10147' H3.70" FLUTED SCOOP GUDE, D = 2.70' !ESTIMATED TOP OF CEMENT I —10147 S: 4 --13. � � .' 10160' 27'' DEPLOY SLV, D = 1.78' ;i " 10186' H3.7" BKR DE OY SLV, D = 3.0' I BEHIND 'e; , / . ti \i 10206' 1-13.1/7' H E S X N P , D = 2.813' CTD LNR 13 -1/2" LNR, 8.814, L-80 STL, .0087 bpf, ID = 2.992' — 10239' — IV 'l 10212' (-{7' BOT LNR HGR 1�AgC SLV, D =? 1 ; I '. ; I i/ . 10239' H3 -1/2" X 3 -3/18" )OD, D = 2.880' ■ 1 9-5/8' CSG, 474, L-80 BUTT. ID = 8.681' H 10483' ■ I ∎ 1 1 1 I 1. 1 1 I • I , 14 -1/2" TBG, 12.64, L-80 AB -MOD, .0152 bpf, ID = 3.958' —10513 �40 4 I 4 I 1 1,+I ` i 1 ,V II • II 17' LNR, 26 #, L-80 IJ4S, .0383 bpf, ID = 6.276" —10513 ' 4 ' 4 141/2' WHIPSTOCK H 10518' '4 ' 44. ,I 1 i� MILLOUT WINDOW (C-2713) 10513' - 10521' ■ 1 1 I. 1 1 I 3 -3/16' LNR, 6.24,1-80, .0076 bpf, ID = 2.805 " —11125 1 133/16 WHIPSTOCK (06/07/12) -1 11125' 1 ° i it � 3 -3/16' LNR MILLOUT WINDOW (C-27C) 11125' - 11131' / ■ PERFORA 9/I REF LOG: BHI MCNL / GR ON 061 — ANGLE AT TOP PERF: 91° 0 13200' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE I 1.56' 6 13200 -13410 0 06123/12 1.56' 6 13450 - 13490 0 06/23/12 I 4 13496' —I PBTD 12 -3/8' LNR, 4.7', 1-80 STL, .0039 bpf, ID = 1.995' H 13533' •., C -27C DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/13/82 N26E INITIAL COMPLETION WELL C-27C 01/08/97 NORDIC I CTD SIDETRACK (C -27A) PERMIT No: '2120420 12/10/03 NORDICI CTD SIDETRACK (C -27B) API No: 50-029- 20843-03 06/26/12 NORDICI CID SIDETRACK (C -27C) SEC 19, T11N, R14E, 1756' FNL & 1033' FEL 07/14/12 PJC DRLG DRAFT CORRECTIONS 07/15/12 PJC GLV CORRECTIONS (# 1 - # 4) _ BP Exploration (Alaska) 1 ^ ` TREE = 6 -3/8" CM/ IP ' WELLHEAD = McEVOY /� SAF NOTES: - ACTUATOR = BAKER C ( J� KB. ELEV = 72.3' ' proposed CTD sidetrac BF. ELEV = 38.79' KOP = 2150' ---7 - • O 2217' 145-1/2" OTIS HRQ SSSV NIP, ID = 4.562" Max Angle = 95 @ 11477' Datum MD = 11034' GO Datum TV D = 8800' SS 2511' I-I 5-1/2" X 4-1/2" XO, ID = 3.958" I 15-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I 2511' I 2693' I-I 9 -5/8" DV PKR I GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80, ID= 12.347" H 2739' I ST MD TVD DEV TYPE VLV LTCH PORT DATE 7 3033 2840 45 LBD DOME RM 16 08/13/11 6 5037 4284 42 LBD DMY RM 0 01/16/09 Minimum ID = 1.78" L 10100' 5 6252 5162 46 LBD SO RA 20 08/13/11 3" Deployment Sleeve L 4 6992 5696 43 LBD DMY RA 0 04/08/98 3 7456 6037 42 LBD DMY RA 0 04/08/98 Top of 2 -3/8" liner and cement at - 10,050' (cover tbg holes & sliding sleeve) 2 7919 6383 40 LBD DMY RA 0 04/08/98 lb •��1 I 1 8026 6465 40 _ LBD DMY RA 0 04/08/98 f TOP OF CEMENT IN IA (04/04/11) 10050 I ►��� � � 10067' I---14 -112" OTIS XA SLIDING SLV, ID = 3.$13" I ► 1 TSGR = 10,475' MD % % .�% 39 ►.•s 4 0 4 �� 10131' HTIW PRB SEAL ASSY I TUBING PUNCH (03122111) - 01 I 10110' - 10112' ELMD � ►�i 10125 - 10127 MD � = �.. 10147' I- I9 -5/8" X 4 -1/2" TM/ HBBP PKR, ID = 4.750" I . 1Q4 ,4 I 10186' H3.7" BKR DEPLOY SLV, ID= 3 0" I r . 10206' H3-1/2" HES X NIP, D= 2.813" I I3 -1/2" LNR, 8.81 #, L -80, .0087 bpf, D = 2.992" I 10207' �, 10212' i-{7" BOT LNR HGR TIEBACK SLV, D = ? I �� .:•‘$'': 10238' I--I3 -112" X 3- 3/16" XO, ID = 2.880" I •♦ 19 -5/8" CSG, 47 #, L -80, ID = 8.681"1-1 10463' I ► • ►• ■ • TOP OF WHIPSTOCK I 10518' .• = • ;, MLLOUT WINDOW (C -27B) 10513' - 10521' 17" LNR, 26#, L -80, ID = 6.276" I-1 11480' 1--- -4 ►� i� i 45 11338' - 3 -3/16" X 2 -7/8" XO, PERFORATION SUMMARY ID = 2.372" REF LOG: SPERRY SUN MCNUGR LOG ON 12/09/03 ANGLE AT TOP PERF: 69 @ 11250' ! 11913' - I PBTD I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11250 - 11268 0 06/21/05 2" 6 11550 - 11910 0 12/09/03 3 - 3/16" whipstock at 11,125' �!� 2 -7/8" CIBP (if needed) ln________ r- I3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, D = 2.805" I 11338' I2 -7/8" LNR, 6.16#, L -80, .0055 bpf, ID = 2.372" I—I 11947' I 2 -3/8" liner withTD at 13,775' ' DATE REV BY COMMENTS I DATE REV BY COMMENTS PRUDHOE BAY UNfT 12/14/82 INITIAL COMPLETION 06/03/11 TW/ PJC SET KB PATCH (06/02/11) WELL: C-27c 01/08/97 CTD SIDETRACK (C -27A) 07/29/11 AJ/ PJC TREE C/O (07/18/11) PERMIT No: / 2031860 12/09/03 TMN/KK CTD SIDETRACK (C -27B) 08/14/11 AT/ PJC GLV CJO (08/13/11) API No: 50- 029- 20843 -02 03/26/11 SRD /PJC TBG PUNCH (3/22/11) proposed C SEC 19, T11N, R14E, 1755' SNL & 1033' WEL 04/08/11 CJS /PJC CEMENT IA/ MILL PLUG (4/4 -8/11) 04/28/11 BPG/ PJC TBG PUNCH CORRECTION (3/22/11) BP Exploration (Alaska) DATE: 27-Jun-12 TRANS#: 5999 • . . ' .,T2; 'Da La Dellyen! Services Technician rlll[ Miiiiitialri[l 4Praft2cp, :,;- :, y.: : Fi i Ke:;-. :I - .1, 3 'F:::,.r 1.. Ii ' . 43: Consulting Services . . _ - - . 2'.3"`.3 Gambeli St, Ste. 400 Anchorage, AK 99503 R: °MCC: (907) 273-1770 'S.pii,WI:' '-5.1.6'. 110W1,;:,-::,' t4t; ,, , , ' ,, ;.4 , : , : . , ,,,,y„ , , . , • A. III NAME ORDER # DIST DIST DIST DIST LOGGED PRINTS PRINTS V-229 BBSK-00116 X MDT 8-May-12 1 CD MPS-24 BAUJ-00129 X MEMORY LEAK DETECTION LO 1-Jun-12 1 1 CD 13-15 C3NA-00019 X USIT/SONIC SCANNER 22-May-12 1 1 CD 13-15 BVYC-00037 X ISOLATION SCANNER 19-May-12 1 1 CD 04-18 C4W7-00015 X PRODUCTION PROFILE 26-May-12 1 1 CD , ‘ y 1C-27B C600-00011 X MEMORY LEAK DETECTION LO 5-Jun-12 1 1 CD 06-11 C3NA-00014 X CROSS FLOW W/ IBP 12-May-12 1 1 CD V-229 C3NA-00011 X USIT/CBL 8-May-12 1 1 CD D-14A C4W7-00012 X SLIM CEMENT MAPPING TOOL 24-May-12 1 1 CD Z-40 C2JC-00007 X USIT/CBL 27-Mar-12 1 1 CD 15-01B C600-00010 X MEMORY PRODUCTION PROFIT 3-Jun-12 1 1 CD JD X X Please return a signed copy to: Please return a signed copy to: BP PDC LR2-1 WOWED JUL '6 201Z DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 - Anchorage AK 99508 • • Plrik 7 ET:, 0[F SEAN PARNELL, GOVERNOR & - ij ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. ';?L: P.O. Box 196612 r Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C -27B ' �'4 Sundry Number: 312-102 a© 7 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6 1e4;,./e-- Cathy . Foerster Chair KA DATED this day of April, 2012. Encl. • STATE OF ALASKA IVE ALASKA OIL AND GAS CONSERVATION COMMISSION � , APPLICATION FOR SUNDRY APPROVAL / , " "7 • 20 AAC 25.280 1. Type of Request: `.., . S .' ;0.:;.. ii1i:E ss Cif I . ❑ Abandon ® Plug for Redrill ' ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved INetaapage ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Tirne..Extensio ❑ 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 203 - 186 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20843 -02-00 - 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 C -27B • Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 28305 & 028310 Prudhoe Bay Field / Prudhoe Bay Oil Pool " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11947' 9025' - 11913' • 9024' • None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2739' 13 -3/8" 2739' 2684' 4930 2670 Intermediate 10463' 9 -5/8" 10463' 8420' 6870 4760 Production Liner 918' 7" 10212' - 10513' 8222' - 8460' 7240 5410 Liner 1779' 3 -1/2" x 3- 3/16" x 2 -7/8" 10168' - 11947' 8188' - 9025' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11250' - 11910' 9020' - 9024' 5 17#14 12.6# L - 80 10513' Packers and SSSV Type: 9 -5/8" x 4 -1/2" TIW HBBP Packer Packers and SSSV 10147' / 8171' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program ❑ Exploratory 0 Development ' ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 10, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG 0 Suspended • 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Ross, 564 -5782 Printed Name Joh ..40 i Title Engineering Team Leader Prepared By Name/Number: Signatur 4/ Phone 564 -44711 Date 3 i e Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness z ' 7,102_ Sundry Number `. ❑ Plug Integrity RBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 4 35 CZ p5L, 1 3 P ' " Other: ,c 4 �fk.Q- iCs c_Prvr,o . a -," /by � � .q Z .`� . ! l2 C: Subsequent Form Required: `0 - - Li' LrZ- APPROVED BY 4— 2-7/2-- Approved By: - < COMMISSIONER THE COMMISSION Dat Form 10 0 , Submit In Duplicate Z �� 3.�r_ 0R1G1NAL zs- • • To: Alaska Oil & Gas Conservation Commission From: Matthew Ross by CTD Engineer Date: March 15, 2012 Re: C -27B Sundry Approval Sundry approval is requested to plug the C -27B perforations as part of drilling the C -27C coiled tubing sidetrack. W History of C -27B. Well C -2was a rotaryyd drilled in Dec 1982. A coil side track was completed in 1997 and gain in 2003. While the initial production for C -27B was quite prolific, the oil production declined rapidly and reached marginal GOR in -4 mos. Add perforations were completed in Z2A, but no significant production increase was observed. The well continued to cycle for the next 3 years until it was shut -in Nov 2008 for a production packer leak. In April 2011 the packer leak was repaired with a cement squeeze, and the leaking CTD liner lap was also cement squeezed. Unfortunately, the packer cement did not adequately plug the tubing punches causing the post- squeeze MIT -IA to fail. A tubing patch was set and a MIT -IA was successful. C -27B was POP'ed in Aug • 2011 but began cycling for high GOR immediately. The most recent calliper from 2/15/12 showed the tubing to be in good to poor condition • with a maximum wall penetration of 54 %. All sidetrack screening pressure tests passed. Reason for sidetrack. C -27B is no longer a competitive well due to low productivity and • has no remaining wellwork options. The proposed sidetrack will access a target in the Zn2A. Proposed plan for C -27C is to set a 3- 3/16" packer whipstock and drill a through tubing sidetrack with a Coiled Tubing Drilling rig on or around Mayl5 2012. The existing perforations will be isolated by the 3- 3/16" packer whipstock as well as the primary cement job for the liner. The sidetrack, C -27C, will exit the existing 3- 3/16" liner and kick off in Zn2 and ' land in Zn2A. This sidetrack will be completed with a 2 -3/8" liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. GD Q L p id T O au ei 6SA'1a SC qo d ct4d1( wqt r►• /Oyer COW . ` 'f.; Pm s.`o�ct t // to 7z. of /few flier cy 1(,, f}'rri el of «e laud. god/ /( o,.e reco"5t- f/2 • • Pre -Rig Work: (scheduled to begin April 10 2012) 1. F MIT- IA to 3,000 psi, MIT -OA to 2,000 psi). Passed 02/17/12 2. W Cycle LDS; PPPOT- T to 5,000 psi. Passed 12/27/11 3. S Drift tubing down to patch with 3.80" centraliz,r. 4. S Pull 4-1/2" KB patch from 10,106'- 10,142'. ✓ 1') " 5. S Drift to deviation with dummy whipstock. 6. V PT MV, SV, WV. Bleed wellhead pressures down to zero. 7. 0 Bleed production flow and GL lines down to zero and blind flange. 8. 0 Remove wellhouse, level pad. 9. V Double valve IA. 10. F Load IA with 1% KCI & FP with diesel to 2000'. 11. F Load & kill well 24hrs prior to rig arrival. 12. V Set BPV (6 -3/8" `J' profile) 24 hrs prior to rig arrival. Rig Work: (scheduled to begin May 15 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. r _ 2. Run dummy whipstock drift to 11,200'. Set 3- 3/16" packer WS at 11,125'. 3. Mill 2.74" window at 11,125' and 10' of rathole in Zn2. Swap the well to Power -Pro SF. 4. Drill Build: 3.0" OH, 270' (28° /100 planned). 5. Drill Lateral: 3.0" OH, 2,380' (12° /100 planned) with resistivity. 6. Run 2 -3/8" L -80 liner leaving TOL at 10,050' MD. V 7. Pump primary cement leaving TOC at 10,050' MD, 14 bbls of 15.8 ppg liner cmt planned. 8. Cleanout liner and run MCNL /GR /CCL log. 9. Perforate liner per asset instructions (- 800'). lots - 10. Freeze protect well, set BPV, RDMO. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Load IA with crude. 3. Set 4 -1/2" KB liner top packer. 4. MIT IA to 3000psi. 5. Generic GLV's. 6. RU well testers. Matthew Ross CTD Engineer 564 -5782 CC: Well File Sondra Stewman/Terrie Hubble • TREE = 6 -3/8" CM/ • WELLHEAD = McEVOY SAF NOTES: - ACTUATOR; BAKER C KB. 'ELEV = 72.3' BF. ELEV = 38.79' KOP = 2150' 2217' 1-15-1/2" OTIS HRQ SSSV NIP, ID = 4.562" Max Angle = 95 @ 11477' Datum MD = 11034' Datum TVD = 8800' SS 1 2511' H 5 -1/2" X 4-1/2" XO, ID = 3.958" 15-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I 2511' 2693' I-1 9 -5/8" DV PKR I GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2739' I ST MD TVD DEV TYPE VLV LTCH PORT DATE 7 3033 2840 45 LBD DOME RM 16 08/13/11 6 5037 4284 42 LBD DMY RM 0 01/16/09 5 6252 5162 46 LBD SO RA 20 08/13/11 4 6992 5696 43 LBD DMY RA 0 04/08/98 Minimum ID = 2.372" @ 10338' 3 7456 6037 42 LBD DMY RA 0 04/08/98 3 -3/16 X 2 -7/8" XO 2 7919 6383 40 LBD DMY RA 0 04/08/98 1 8026 6465 40 LBD DMY RA 0 04/08/98 (TOP OF CEMENT IN IA (04/04/11) I 10050' 1 1 III 10067' 144_1/2" OTIS XA SLIDING SLV, ID = 3.813" 4 -1/2" BKR KB PATCH, — 1 10106' - 10142' ►t• - - 4.: i�j s ID = 2.45" (06/02/11) r ���� , °A - �! I 10131' I� TIW PRB SEAL ASSY I r TUBING PUNCH (03/22/11) 10110' - 10112' ELMD j . ` . � , ' • I 10147' 1-19-5/8" X 4 -1/2" T M / PKR, ID = 4.750" I 10125 -10127 MD � ∎∎ 1 10186' I - 13.7" BKR DEPLOY SLV, ID = 3.0" I 10206' H3_1/2" HES X NIP, ID = 2.813" I 13-1/2" LNR, 8.81#, L -80, .0087 bpf, ID = 2.992" I-L 1020T , 41-" 10212' 1-17" BOT LNR HGR TIEBACK SLV, ID = ? I • ►∎ • � i i.. • 4 ■ . • 4 � 4 10238' -I 3-1/2" X 3- 3/16" XO, ID = 2.880" I ►• ►• 4 ► 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10463' I • ► • ' ►,. I TOP OF WHIPSTOCK H 10518' I • • � •`• ►• ►• MILLOUT WINDOW (C -27B) 10513' - 10521' • • PERFORATION SUMMARY • Z ••••4 � 11338' - 3 -3/16" X 2 -7 /8" XO, ►�• - • REF LOG: SPERRY SUN MCNL /GR LOG ON 12/09/03 ► ► ♦ ♦ o ID = 2.372" 4 +. • ANGLE AT TOP PERF: 69 @ 11250' 41* * , ,1 G Note: Refer to Production DB for historical pert data ► 4 � � � . 4' 1 11913' PBTD ►� ..� SIZE SPF INTERVAL Opn /Sqz DATE ►4 ••••• •• 4 • 2" 6 11250 - 11268 0 06/21/05 ►4 •�••• , . • •� 2" 6 11550 - 11910 O 12/09/03 ►•j •►•••• •. • #•••••••• ••••••1 -011.1, ♦ • • • • • •∎• I 3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.805" I 11 7" LNR, 26 #, L -80, ID = 6.276" H 11480' •�•• � . 76 12-7/8" LNR, 6.16 #, L -80, .0055 bpf, ID = 2.372" I 11947' (` DATE REV BY COMMENTS I DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/14/82 INITIAL COMPLETION 06/03/11 TW/ PJC SET KB PATCH (06/02/11) WELL: C-27B 01/08/97 CTD SIDETRACK (C -27A) 07/29/11 AJ/ PJC TREE C/0 (07/18/11) PERMIT No: 2031860 12/09/03 TM N/KK CTD SIDETRACK (C -27B) 08/14/11 AT/ PJC GLV C/O (08/13/11) API No: 50- 029 - 20843 -02 03/26/11 SRD /PJC TBG PUNCH (3/22/11) SEC 19, T11 N, R14E, 1755' SNL & 1033' WEL 04/08/11 CJS /PJC CEMENT IA/ MILL PLUG (4/4 -8/11) 04/28/11 BPG/ PJC TBG PUNCH CORRECTION (3/22/11) BP Exploration (Alaska) TREE = 6 -3/8" CW i ' WELLHEAD= McEVOY • SAFETYNOTES: ACTUATOR = BAKER C C -2 7 C KB. ELEV = 72.3' proposed CTD sidetrack BF. ELEV = 38.79' KOP= 2150' 2217' I _15 -1/2" OTIS HRQSSSV NIP, ID= 4.562" Max Angle = 95 @ 11477' Q Datum MD = 11034' Datum ND = 8800' SS I 2511' I—I 5-1/2" X 4-1/2" XO, ID = 3.958" 15-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I 2511' 2693' I 9 -5/8" DV PKR I GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80, ID= 12.347" H 2739' ST MD ND DEV TYPE VLV LTCH PORT DATE 7 3033 2840 45 LBD DOME RM 16 08/13/11 6 5037 4284 42 LBD DMY RM 0 01/16/09 Minimum ID = 1.78" @ 10100' 5 6252 5162 46 LBD SO RA 20 08/13/11 3" Deployment Sleeve 4 6992 5696 43 LBD DMY RA 0 04/08/98 3 7456 6037 42 LBD DMY RA 0 04/08/98 Top of 2 -3/8" liner and cement at 10,050' (cover tbg holes & sliding sleeve) 2 7919 6383 40 LBD DMY RA 0 04/08/98 1 8026 6465 40 LBD DMY RA 0 04/08/98 TOP OF CEMENT IN IA (04/04/11) Fl 10050' I ► • , We, 10067' I _14 -1/2" OTIS XA SLIDING SLV, ID = 3.813" TSGR = 10,475' MD o 1 ! ' 39 •0 •� VII IR 10131' 1-11 PRB SEAL ASSY I TUBING PUNCH (03/22/11) 10110' - 10112' ELMD :! �i�i �, 10147' H9 -5/8" X 4-1/2" TW HBBP PKR, ID = 4.750" I ._, 10125 -10127 MD ■ P 10186' I —I3.7" BKR DEPLOY SLV, ID = 3.0" I ►1 ■ ■ • 10206' I-13-1/2" HES X NIP, ID = 2.813" I 3 -1/2" LNR, 8.81 #, L -80, .0087 bpf, ID = 2.992" H 10207' MI AI 10212' I -17" BOT LNR HGR TIEBACK SLV, ID = ? I • ► • 4 i �•�• .4�� 10238' H 3 -1/2" X 3- 3/16" XO, ID = 2.880" I •♦ 4 � 9 -5/8" CSG, 47 #, L -80, ID = 8.681" hi 10463' I ►• ►• ► ■,. TOP OF WHIPSTOCK' 10518' 4 . ` � • •. � • MILLOUT WINDOW (C -27B) 10513' - 10521' 7" LNR, 26 #, L -80, ID = 6.276" I—{ 11480' I_ % 4 o 0 0 45 11338' — 3 -3/16" X 2 -7/8" XO, PERFORATION SUMMARY ID = 2.372" REF LOG: SPERRY SUN MCNL /GR LOG ON 12/09/03 '4414r ANGLE AT TOP PERF: 69 @ 11250' 11913' - I PBTD I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11250 - 11268 0 06/21/05 2" 6 11550 - 11910 O 12/09/03 lii\ 3 3/16" whipstock at 11,125' ��� 2 -7/8" CIBP (if needed) C I I 3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.805" H 11338' I 2 -7/8" LNR, 6.16 #, L -80, .0055 bpf, ID = 2.372" H 11947' I 2 -3/8" liner withTD at 13,775' ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/14/8 ( INITIAL COMPLETION 06/03/11 TW/ PJC SET KB PATCH (06/02/11) WELL: C-27C 01/08/97 CTD SIDETRACK (C -27A) 07/29/11 AJ/ PJC TREE C/O (07/18/11) PERMIT No: 8 031860 12/09/03 TMN/KK CTD SIDETRACK (C -27B) 08/14/11 AT/ PJC GLV C/O (08/13/11) API No: 50- 029 - 20843 -02 03/26/11 SRD /PJC TBG PUNCH (3/22/11) 02/02/12 WJH proposed CTD sidetrack SEC 19, T11 N, R14E, 1755' SNL & 1033' WEL 04/08/11 CIS/PJC CEMENT IA/ MILL PLUG (4/4 -8/11) 04/28/11 BPG/ PJC TBG PUNCH CORRECTION (3/22/11) BP Exploration (Alaska) s s NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM V12 — 4— V14 I 7-1/16" 6000 psi BOP's ID = 7.06•• 0 V15 Vii • • I1 116" 5000 Psi, 03-46 ITS Transducers soalissmsatrosta ORB V V2 I V1 V 16 —f161 YI— `' GASS ., ' note' l en BOP of rgemenl ' t tor 2-3/8" I ti -� 4, ' coiled tubing drlllin0 imili V1 � f 7 ,H6 5000 Pai, Rx-40 1 HCR IC IK OK iii To Poor Boy Gas Buster _ _ .0 a- C C4 V18 V19 �: 2 1/18•' 5000 psi , Rx - 2/ • 3.00 psi HCR I , V I • PC 2 -1118" 5000 psi CHECK VALVE Manual Choke f „ '/ 1118 Cameron Gate I MINN : Valve x 8000 0 psi iMI i1 Yir MEOH /Diesel , , , , „ FP Line CoFlex Hose CI N(pbpp - 1/4 Turn Halco 10WOG To Production Tree or Cross Over • , •ress e transducers C) CoFlex Hose CV11 " 0 CV12 To Coiled Tubing . ,. Bleed Off Inner Reel Valve ....:70-..7.:12.= I — �_ CV13 Cement e I Ground Lev In Tie -in CV10 - CV3 CV2 T Stand Pipe • _ - = _ Manual Choke ilk E - --- = - - - '° - - _ - - Pressure Transducers llNll CV9 Motion 11 _r II CV17 „ j _ —per „ a• ... CV7 ii r III III ANIL IIII N8 v _ Tiger Tank Mud Pump 2 V O MIMI _ _ _ In From - - Baker MP 1 & MP 2 ► • - 7. .:. 0 Choke • • CV14 to Pits Rig Floor if Mud Pump 91 " CV16 Reverse Ci - ' Cir CT whle••' • . • • To Manifold CV15 1-Jun-2010 Reverse Cirruletinn line / CT while nnR CoFlex Hose • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 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 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_D oc Record \Procedures _ Instructions \FW INTENT PLUG for RE -D... 3/23/2012 u ment _ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 0 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 RECEIVED; et VOW 20 AUG 3 1 ?nn Mr. Tom Maunder Alaska Off & Gas C Alaska Oil and Gas Conservation Commission . n iss" ion 333 West 7 Avenue Ancherags Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB C -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -258 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -378 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 ID • irir...... WELL LOG TRANSMITTAL • PROACTIVE DIAgNo7IC SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave - «',,,r4 4.1 SEP " :' 20Ii 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 attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 r 14 7 �( 417 l 1) Leak Detection - WLD 01- Jun -11 C-27B 7 BL/ CD ', 50- 029 - 20843 -02 2) Signed : (5ZIAL—_ Date : Ji IL �Q Lf Print Name: 140 wcL1 -e- CS Y... L PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAX: (907)245 - 8952 E -MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\ Distribution \TransmittalSheets\BP Transmit.docx STATE OF ALASKA ALASKA IDAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other la TUBING PATCH Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ 10108 -10138 Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 12 Exploratory ❑ - 203 -1860 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20843 -02 -00 - 00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028310 - PBU C -27B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11947 feet Plugs (measured) None feet true vertical 9024.68 feet Junk (measured) None feet Effective Depth measured 11913 feet Packer (measured) 2693. 10106 10137 10147 feet true vertical 9024.29 feet (true vertical) 2645. 8140 8164 8174 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 91.5# H -40 34 - 110 34 - 110 1490 470 Surface 2706' 13 -3/8" 72# L -80 33 - 2739 33 - 2684 4930 2670 Production 10431' 9 -5/8" 47# L -80 32 - 10463 32 - 8420 .. -' ' 6870 4760 Liner 309' 7" 26# L -80 10212 - 10521 822 - 8460 7240 5410 , 52' 3 -1/2" 8.81# L -80 10186 - 10238 8201 - 8242 10530 10160 Liner 1100' 3- 3/16" 6.2# L -80 10238 - 11338 8242 - 9033 8640 7870 Liner 609' 2 -7/8" 6.16# L -80 11338 - 11947 9033 - 9025 11160 10570 Perforation depth: Measured depth: SEE ATTACHED - _ _ � d. True Vertical depth: _ _ JUG � _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 30 - 2511 30 - 2487 4-1/2" 12.6# L -80 2511 - 10521 2487 - 8460 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" DV Packer 2693 2645 /n� 4 -1/2" BKR KB PKR 10106 8140 r" -, L -1/2" BKR KB PKR 10137 8164 Jl t5Ar 4 -1/2" TIW HBBP Packer } E \ Jii4' 8174 12. Stimulation or cement squeeze summary: ?ill: Intervals treated (measured): i13;�' .. f"4 .. Treatment descriptions including volumes used and final pressure: $ , Oil 4 f ;'sror USSIIOf Appeals 13. Representative Daily Averag" Appeals on or In Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development IS ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - isi Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N. - oe La- A Title Data Manager Signa - i VIE Phone 564 -4091 Date 6/28/2011 Form 10 -404 Revised 10 /201cRBDMS UN 2 9 2011 :Y& 6 .,zt- // / Submit Original Only / C -27B 203 -186 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C -27B 12/9/03 PER 11,550. 11,910. 9,026.63 9,024.26 C -27B 6/21/05 APF 11,250. 11,268. 9,020.14 9,025.73 C -27B 4/13/10 BPS 2,188. 11,910. 2,183.58 9,024.26 C -27B 2/18/11 BPP 2,188. 11,910. 2,183.58 9,024.26 C -27B 3/20/11 BPS 10,250. 11,910. 8,251.71 9,024.26 C -27B 3/22/11 MLK 10,110. 10,112. 8,142.66 8,144.21 C -27B 4/4/11 SQZ 10,110. 10,250. 8,142.66 8,251.71 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • I • • C -27B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/2/2011 * * *ON LOCATION JOB CONTINUED FROM 1- JUNE -11 WELL SHUT IN * ** ELINE(BAKER PATCH) INITIAL T /I /O = 0/500/0 SET BAKER KB PATCH 10106' - 10142', OAL= 36.18', 30' MID - ELEMENT TO MID ELEMENT 10108'- 10138', MIN ID OF PATCH 2.45" AT UPPER AND LOWER ELEMENT. NOTIFY DSO OF VALVE POSITION, SWAB /SSV/WING - CLOSED, MASTER - OPEN, IA/OA -OTG FINAL T /I /O =0 /500 /0 ** *JOB COMPLETE LEAVE LOCATION * ** 1 6/4/2011 T /I /O= 680/420/0 Temp= SI MIT -IA to 3000 psi (diagnose TxIA comet) MIT -IA PASSED to 3000 psi. Pumped 8 bbls diesel down IA to pressure up. IA lost 85 psi in 1st 15 min, 35 psi in 2nd 15 min for a total loss of 120 psi over 30 min test. Bleed IAP (— 7 bbls) FWHP 680/475/0 Swab, Wing, SSV closed, Master open, IA and OA i open to gauges FLUIDS PUMPED BBLS 9 DIESEL 1 METH 10 TOTAL 1'REE = - 6" McEVOY WELLHEAD = McEVOY 1 SAFETY Na: ACTUATOR = OTIS C -2 7 g KB. ELEV = 72.3' BF. ELEV = 38.79' KOP = 2150' 2217' U 5 -1/2" OTIS HRQ SSSV NIP, ID = 4.562" I Max Angle = 95 @ 11477' Datum MD = 11034' el Datum TV D = 8800' SS 1 2511' H 5 -1/2" X 4 -1/2" XO, ID = 3.958" I 15 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I 2511' 2693' H 9 -5/8" DV PKR I GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" I - 2739' I ST MD TVD DEV TYPE VLV LTCH PORT DATE 7 3033 2840 45 ' LBD DMY RM 0 01/16/09 6 5037 4284 42 LBD DMY RM 0 01/16/09 5 6252 5162 46 LBD DMY RA 0 01/16/09 4 6992 5696 43 LBD DMY RA 0 04/08/98 Minimum ID = 2.372" @ 10338' 3 7456 6037 42 LBD DMY RA 0 04/08/98 3 -3/16 X 2 -7/8" XO 2 7919 6383 40 LBD DMY RA 0 04/08/98 1 8026 6465 40 LBD DMY RA 0 04/08/98 TOP OF CEMENT IN IA (04/04/11) 10050' 1 1 ■ 10067' J_I4 -1/2" OTIS XA SLIDING SLV, ID = 3.813" I 4 -1/2" BKR KB PATCH, 10106' - "7 _ 4.: ID = 2.45" (06/02/11) �� °�� �� 10131' h TMJ FRB SEAL ASSY TUBING PUNCH (03/22/11) H 10110' - 10112' ELMD " i • I , I 10125. 10127 M D -■ - 10147' 1-19-5/8" X 4 -1/2" TIW HBBP PKR, ID = 4.750" I I M� 10186' H3.7" BKR DEPLOY SLV, ID = 3.0" 4 ■ 10206' 1--I3 - 1/2" HES X NIP, ID = 2.813" I ' 1 w 3 1/2" LNR, 8.81 #, L -80, .0087 bpf , - 2.992" 1H 10207 l�� ‘.� I , ID 10212' � BOT L NR HGR TIEBACK SLV, ID - - ? I •• • • 4► 10238' I-- I3 - 1/2" X 3- 3/16" XO, ID = 2.880" I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I - I 10463' j4 j N 1 TOP OF WHIPSTOCK I 10518' ► f �� ���+ 07 _ � � MILLOUT WINDOW (C - 2713) 10513' - 10521' PERFORATION SUMMARY -� �... ►� + ►OODO 11338' - 3-3/16" X 2 -7/8" X0, REF LOG: SPERRY SUN MCNL /GR LOG ON 12/09/03 14. • • ••∎ ∎ ID = 2.372" ANGLE AT TOPPERF: 69 @ 11250' ► • ~ ∎ ■ ► ►4.•u Note: Refer to Production DB for historical perf data ► 4.• �� �� �.� ��• w 11913 -I PBTD 4 ••••+•4 SIZE SPF INTERVAL Opn /Sqz DATE ► � • � • � • ∎! 2" 6 11250 - 11268 0 06/21/05 ► 4 * • • � • ∎ . • • 4 •� ► ♦ x . 4 1 .• 2" 6 11550 - 11910 0 12/09/03 ► • j � • * � •% 4.4.4 ► • � • � • .�.�:�:� , AAA x `14 ./ • • •v :4∎1 *: 13 3/16 LNR, 6.2 #, L -80, .007 bpf, ID = 2.805" 1 11 17" LNR, 26 #, L -80, ID = 6.276" 1H 11480' •• • •• • • illi e•-• 2 -7/8" LNR, 6.16 #, L -80, .0055 bpf, ID = 2.372" I 11947' ►!.!.! DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/14/82 INITIAL COMPLETION 03/26/11 SRD /PJC TBG PUNCH (3/22/11) WELL: C-27B 10/27/87 RWO 04/08/11 CJS /PJC CEMENT IA/ MILL PLUG (4/4 -8/11) PERMfT No: 2031860 01/08/97 CTD SIDETRACK (C - 27A) 04/28/11 BPG/ PJC TBG PUNCH CORRECTION (3/22/1') API No: 50- 029 - 20843 -02 12/09/03 TM N/KK CTD SIDETRACK (C - 27B) 06/03/11 TW/ PJC SET KB PATCH (06/02/11) SEC 19, T11 N, R14E, 1755' SNL & 1033' WEL 0 03/26/11 SWC/PJC PULLED KB PKR ASSY (3/14/11) 03/26/11 SRD /PJC SET COMPOSITE PLUG (3/20/11) BP Exploration (Alaska) STATE OF ALASKA 4 r • ALASKA WAND GAS CONSERVATION COMMISSIO' REPORT OF SUNDRY WELL OPERATIONS P€ -L . 1. Operations Abandon El Well ❑ Plug Perforations ❑ Stimulate Other 0 \ CEMENT SQUEEZE Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program [] Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ . 203 -1860 3. Address: P.O. Box 196612 Stratigraphic El Service ❑ 6. API Number: Anchorage, AK 99519 -6612 A 50- 029 - 20843 -02 -00 8. Property Designation (Lease Number) : a 9. Well Name and Number: ADLO- 028310 • PBU C -27B 10. Field /Pool(s): w PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11947 feet Plugs (measured) None feet true vertical 9024.68 feet unk (measured) None feet StVitlitij APR tliUIt Effective Depth measured 11913 feet Packer (measured) 2693 10147 feet true vertical 9024.29 feet (true vertical) 2645 8171 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 91.5# H-40 34 - 110 34 - 110 1490 470 Surface 2706' 13 -3/8" 72# L -80 33 - 2739 33 - 2684 4930 2670 Production 10431' 9 -5/8" 47# L -80 32 - 10463 32 - 8420 6870 4760 Liner 309' 7" 26# L -80 10212 - 10521 822 - 8460 7240 5410 Liner 52' 3 -1/2" 8.81# L -80 10186 - 10238 8201 - 8242 10530 10160 Liner 1100' 3- 3/16" 6.2# L -80 10238 - 11338 8242 - 9033 8640 7870 Liner 609' 2 -7/8" 6.16# L -80 11338 - 11947 9033 - 9025 11160 10570 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 30 - 2511 30 - 2487 4 -1/2" 12.6# L -80 2511 - 10521 2487 - 8460 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" DV Packer .°. i�+e ,, 2693 2645 4 -1/2" TIW HBBP Packer V' C "qa r�yy,� 10147 8171 12. Stimulation or cement squeeze summary: � 1� Intervals treated (measured): � R� Treatment descriptions including volumes used and final pressure: p '�+' I ` �' 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development II - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ p WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Name Joe Lastu < t Title Data Manager Signatur 1I Phone 564 -4091 Date 4/14/2011 MOWS AN 15 2011 Form 10-404 Revised 10/2010 v 4$20 , f( Su it Origin Only C -27B 203 -186 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C -27B 12/9/03 PER 11,550. 11,910. 9,026.63 9,024.26 C -27B 6/21/05 APF 11,250. 11,268. 9,020.14 9,025.73 C -27B 4/13/10 BPS 2,188. 11,910. 2,183.58 9,024.26 C -27B 2/18/11 BPP 2,188. 11,910. 2,183.58 9,024.26 C -27B 3/20/11 BPS 10,250. 11,910. 8,251.71 9,024.26 C -27B 3/22/11 MLK 10,110. 10,112. 8,142.66 8,144.21 C -27B 4/4/11 SQZ 10,110. 10,250. 8,142.66 8,251.71 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 411 • S C -27B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY , w 4 �d�4�a 3/2/2011 * ** CONT FROM TICKET 3/1/11 * ** MADE 3 ATTEMPTS TO PULL 4 1/2 PACKER W/4 1/2 GS,W/ NO LUCK,RDFN. * ** LAY DOWN EQUIP. FOR THE NIGHT. * * ** as 1 i v 1 [ 3/3/2011 * ** CONT TICKET FROM 3/2/11 I MADE 3 ATTEMPTS TO PULL PACKER @ 10,152 SLM. I W/ .125 WIRE W/ NO LUCK,RDMO AS PER CO REP. * ** LEFT WELL SHUT IN,TURNED WELOL OVER TO PAD OPER. * * * * ** 3/1 8/201 1 4 ** *WELL SHUT IN ON ARRIVAL ** *(pull Itp /pre pkr sqz) JAR ON KB PACKER AT 10,154'BLM,(f /n stripped after 5 licks) CURRENTLY MAKING UP RELEASABLE SPEAR * * *CONT WSR ON 3/14/11 * ** } 3/14/2011 CONT WSR FROM 3/13/11 ** *(pre pkr sqz) 1SET 4 -1/2" RELEASABLE SPEAR IN KB PKR AT 10,154'BLM. LATCH & PULL KB LNR TOP PACKER FROM 10,154' BLM( missing 1 & 1/2 rubber l elements) RIGGED DOWN BRAIDED LINE & RIGGED UP SLICK LINE RAN KJ, 4 1/2" BRUSH & 2.25" 3 PRONG GRAB TO STA# 6 AT 5,023'SLM.(unable to pass) RAN KJ,4.5" BRUSH & 3.70" GRAB W/ 4 PRONGS TO LNR TOP AT 10,173'SLM. DRIFT W/ 2.70" CENT,S- BAILER TO 10,400'SLM(no problems) 1 CURRENTLY RIH W/ 4 -1/2" 42B0 SHIFTING TOOL. ` * * *CONT WSR ON 3/15/11 * ** • • 3/15/2011I * * *CONT WSR FROM 3/14/11 * ** IRAN 4 -1/2" 42B0 SHIFTING TOOL TO XA SLIDING SLEEVE AT 1 10,042'SLM(sleeve closed). * * *RDMO,LEFT WELL SHUT IN,PAD OP NOTIFIED * ** 3/20/2011 * * ** *WELL SHUT IN ON ARRIVAL * * * * * * *(E -LINE PLUG SET) INITIAL T /I /O = 700/370/0 PSI „SET BAKER 255 QUIK DRILL COMPOSITE FRAC PLUG MIDDLE ELEMENT AT 1 10250 FT. 1 OAL OF PLUG 2.30'. RATED FOR 10K ABOVE AND 8K BELOW. CORRELATED TO SLB MEMORY CNL DATED 9- DEC -03. FINAL T /I /0= 700/350/0 PSI * * * * ** *JOB COMPLETE * * * * * * * * ** *(WELL TURNED OVER TO DSO) 3/21/2011 T/I /O= 880/1300/0 +. Temp= SI. WHPs & T FL (pre MIT -T). No AL. T FL @ 1584' 1SV & WV =C. SSV & MV =O. IA & OA =OTG. NOVP. E � 1 3/21/2011 * * ** *WELL SHUT IN ON ARRIVAL * * * * * * *(E -LINE TUBING PUNCH) ' INITIAL T /I /O = 470/1100/0 PSI !SPOT EQUIPMENT ONTO WELL. PT LUBRICATOR. 1 * * * * ** *JOB CONTINUED ON FOLLOWING DAY * * * * * * * * * ** I � 3/21/2011 T /I /0= 900/1320/20 temp =S /I Injectivity Test (Restore TBG Integrity) Pumped 5 bbls neat meth & 200 bbls 120* crude down TBG for an Injectivity Test. Established Injectivity of .8 bpm & 1600 psi for 45 bbls (40 min). Pad -Op & PE notified. I FWP= 750/1300/20 * *Tag hung. SV, WV & SSV =S /I, MV =Open, IA & OA =OTG ** • • 3/22/2011 * * ** *CONTINUED FROM PREVIOUS DAY * * * * * * *(E -LINE TUBING PUNCH) RUN IN HOLE WITH 1.56" 4 SPF SMALL TUBING PUNCH PUNCH 4.5" TUBING FROM 10110- 10112. CLEAR INDICATION AT SURFACE OF SHOTS FIRED. PUMPED UP ON TUBING WITH TRIPLEX AND OBSERVED 20 PSI INCREASE ON I IA. !FINAL T /I /O = 470/1100/0 PSI ,*******JOB COMPLETE * * * * * * * * ** *(TURN WELL OVER TO DSO) 1 3/27/2011 T /I /0= 200/1040/0 Tem =S /I Well Circ Out (Restore tubing integrity) Pumped � P � ( 9 9 Y) ed 17 P 1bbls meth spear followed by 300 bbls of 100* 1 %KCL. * * *WSR Continued on 28Mar2011*** € � j 3/28/20111 * * *WSR Continued from 27Mar2011 * ** Circ -Out. Pumped 520 bbls of diesel followed by 118 bbls of 1 %KCL with a 58 bbls diesel freeze protect down tubing taking returns! through IA to C -26 flowline. FWHP's= Vac /220/0. WV,SV,SSV =SHUT/ IMV/IA/OA=OPEN { � I � I f E 4/4/2011 CTU #8 w/ 1.75" CT I iScope: Fix packer leak w/ cement/mill out composite plug and return well to !production Move from W -207. MIRU. Circ 5 bbls diesel down tbg up IA.. confirm fluid packed/ G1411/4 no gas. RIH w/ two 2" stingers, 2" BDN, choke closed. Tag Plug @ 10251'. flag @ 10241. Park coil © 10.186' Pumped 14 bbls of 15.8 pm cement with returns from Ct backside. recover 9 bbls in 40 bbl tank, squeeze 3 bbls thru tbg punch and achieve 500 psi increase on IA. Open IA and circ an additional 5 bbls into IA. Contaminate cement down to plug and chase ooh @ 80 % washing all jewelry. Freeze protect well from 2300'. MU BHA; 2.25" ctc, 2.13" dfcv,jars,disco,circ sub, motor,2.15" crossover, 12.62" venturi, 2.75" burnshoe. WO cement compressive strength to reach 500 psi. I Pressure IA from 700 psi to 1100 psi w/ 0.4 bbls diesel. Tbg press rose from 135 psi 'to 250 psi and continued to rise to 435 psi while IA dropped to 1000 psi over 40 min. Packer squeeze looks good, but may have leak from IA to tubing. WO BTT full • • 4/5/2011 CTU #8 w/ 1.75" CT Scope: Fix packer leak w/ cement/mill out composite plug and return well to production 'MU 3.80" milling assy. Monitor tubing and have pencil stream flow from IAP. RIH w/ milling assy to top of liner @ 10,189 without any motor work. Pump 32 bbl gel sweep and chase to surface. MITIA result = 15 gal leak IA -TBG in 30 min. Perform passing MlTcombo 30 min test. Bleed pressures back to starting psi. MU & RIH w/ 2.25" ctc, '2.13" dfcv,jars,disco,circ sub, motor,2.15" crossover, 2.62" venturi, 2.75" burnshoe. 'Mill cement from 10223' to composite plug at 10250'. On third stall got bit stuck. 'Unable to free pipe after 30 solid jar licks. 4/6/2011. CTU #8 w/ 1.75" CT Scope: Fix packer leak w/ cement/mill out composite plug and return well to production 'Jar milling assy free. POOH. Recovered about one inch off of the top of the 'composite plug that was lodged tightly inside the burnover shoe along with 3" of 'cement fines on top. Venturi also had cement fines. Cut off 150' CT. MU BHA; 2.25" ctc 2.13" dfcv,jars,disco,circ sub, motor,2.15" crossover, 2.62" venturi, 2.75" Iburnshoe. Lighty tag plug at 10246' recip to LNR top and circ gel sweeps. RIH, Plug !fell downhole, chase plug to 3 3/16 x 2 7/8 " crossover. Attempt to burnover / mill plug.' 'Pooh. recovered lower (wafer backup ring) wedged in burnshoe. Lower slips 'determined to be intact. MU and RIH w/ same BHA. Tag plug at XO at 11330' CTM and attempt to mill off slips. Had eight stalls w/ no progress and then a loss of 400 •si CTP. POH to check BHA. 4/7/2011 CTU #8 w/ 1.75" CT Scope: Fix packer leak w/ cement/mill out composite plug and return well to production 'Finish POH w/ burnover shoe assy. Threads at the bottom of XO to the top of 'Venturi had parted at the bottom thread leaving the 2.62 OD Venturi and 2.75" burnover shoe in hole (9.28' OAL). WO BTT fishing string. RIH w/ spear to 11326' :sat down three times and pooh. Recovered venturi barrel / burnshoe w/ plug slips and large pieces of composite material. MU and RIH w/ 1.89" dct, 1.69" dfcv, jars, =disco, circ sub, motor, 2.29" mill (oal= 18.71') Tag and mill on plug @ 11333. Milled 'thru and chase to bottom. Tagged hard bottom @ 11903. stall motor twice and dry 'tag at same. maintained 1:1 returns. pooh. Freeze protect well w/ 60 bbls of 60/40 'meth. Begin RD 4/8/20111CTU #8 w/ 1.75" CT !Scope: Fix packer leak w/ cement/mill out composite plug and return well to production Finish RD. MO to W -23. Job complete 'Note: Small IA x tbg leak at (assumed) tbg punch holes will require patch before POP (see AWGRS 4/5/2011) ' i • • FLUIDS PUMPED BBLS 791 1% KCL 47 BIOZAN 118 60/40 METH 22 NEAT METH 584 DIESEL 14 15.8 PPG CEMENT 200 CRUDE 1776 TOTAL TREE= 6" McEVOY WELLHEAD.c McEVOY SAFETY N . ACTUATOR = OTIS -2 KB. ELEV = 72.3' BF. ELEV = 38.79'` KOP = 2150' 2217' I - 15 - 1/2" OTIS HRQ SSSV NIP, ID = 4.562" I Max Angle = 95 @ 11477' Datum MD = 11034' Datum TVD = 8800' SS I 2511' J — I 5 -1/2" X 4 -1/2" XO, ID = 3.958" I 15-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I — ) 2511' 2693' I — I 9 -5/8" DV PKR I GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2739' ST MD TVD DEV TYPE VLV LTCH PORT DATE 7 3033 2840 45 LBD DMY RM 0 01/16/09 6 5037 4284 42 LBD DMY RM 0 01/16/09 5 6252 5162 46 LBD DMY RA 0 01/16/09 4 6992 5696 43 LBD DMY RA 0 04/08/98 Minimum ID = 2.372" @ 10338' 3 7456 6037 42 LBD DMY RA 0 04/08/98 3-3/16 X 2 -7/8" XO 2 7919 6383 40 LBD DMY RA 0 04/08/98 1 8026 6465 40 LBD DMY RA 0 04/08/98 TOP OF CEMENT IN IA (04/04/11) I--! 10050' ' I I I I 10067' I- 14 -1/2" OTIS XA SLIDING SLV, ID = 3.813" I (TUBING PUNCH (03/22/11) I 10110' - 10112' 0 q; O .- 10131' --I TIW PRB SEAL ASSY I AA ' •::: 10147' --I9 -5/8" X 4 -1/2" TIW HBBP PKR, ID = 4.750" I ►ir/ ►�� I 10186' H 3.7" BKR DEPLOY SLV, ID = 3.0" I C ps ►, ►, ■ ; 10206' 113 HES X NIP, ID = 2.813" I 13-1/2" LNR, 8.81 #, L -80, .0087 bpf, ID = 2.992" 10207' ► l � � ► � 10212 Hr BOT LNR HGR TIEBACK SLV, ID = ? •• .iii 10238' - I — I3 - 1/2" X 3- 3/16" XO, ID = 2.880" I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I 10463' • • ► I TOP OF WHIPSTOCK I—I 10518' • `.• 0 MILLOUT WINDOW ( C -27B ) 10513' - 10521' • ► PERFORATION SUMMARY -� • �,� ► i�i�i�i • V1 11338' — 3- 3/16" X 2 -7/8" XO, REF LOG: SPERRY SUN MCNL/GR LOG ON 12/09/03 ► ► ♦ ♦ ∎• ' ID = 2.372" 4 •••4 ANGLE AT TOP PERF: 69 @ 11250' ► 4 ► i • i • i ■ Note: Refer to Production DB for historical perf data OJ �. . ••• •e ■ 11913' --I Pull ►►.•e. SIZE SPF INTERVAL Opn /Sqz DATE ► 4 ► t• • • • ∎! 2" 6 11250 - 11268 0 06/21/05 I •�•�• 4 2" 6 11550 - 11910 0 12/09/03 •�4 ►•�•�• !/ ■ •••••••• e.st i0" • � � � • • • • w * �4! I 3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.805" I 11338' 17" LNR, 26 #, L -80, ID = 6.276" H 11480' •�•• • • ..... 12 LNR, 6.16 #, L - 80, .0055 bpf, ID = 2.372" I 11947' ►!i!i! DATE REV BY COMMENTS 1 DATE REV BY COMMENTS I PRUDHOE BAY UNIT 12/14/82 INITIAL COM PLETION 03/26/11 SWC/PJC PULLED KB PKR ASSY (3/14/11) WELL: C-27B 10/27/87 RWO 03/26/11 SRD /PJC SET COMPOSITE PLUG (3/20/11) PERMIT No: 2031860 01/08/97 CTD SIDETRACK (C -27A) 03/26/11 SRD /PJC TBG PUNCH (3/22/11) I AR No: 50- 029 - 20843 -02 12/09/03 TM N/KK CTD SIDETRACK (C -27B) 04/08/11 CJS /PJC CEMENT IA/ MILL PLUG (4/4 -8/11) SEC 19, T11N, R14E, 1755' SNL & 1033' WE. 03/26/11 MBM/PJC PULLED PRQ PLUG (02/19/11) 03/26/11 MBMIPJC PULLED CAT STD VALVE (2/22/11) BP Exploration (Alaska) To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907j 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka l.R2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~~~,~ ~ ~~r ; ~ ~ -`° 200 ProActive Diagnostic Services, Inc. ~ ~-r/~~ Attn: Robert A. Richey 130 West International Airport Road ~qj 3 Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j Leak Detection - WLD 29-Mar-09 G276 2) /. ,, ,~ ~- Signed : ~ ~_-,.. Print Name: Color Log / EDE 50.029-20843-02 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL : - WEBSITE C:\Documents and Settings\Owner\Desktop\Tiansmit_BP.docx Oilfield Services . . 2525 Gambell Street Suite 400 Anchoraae, Alaska 99503 (907) 273-1700 Fax (907) 561-8317 Schlumberger August 28, 2006 Christine Mahnken Alaska Oil & Gas 333 West 7th Avenue Suite 100 Anchorage, AK 99501 SCANNED SEP 1 920D6 Dear Ms. Mahnken, Enclosed please fiod CDs you returned to Sch/umberger for being corrupted. The CD for Well S-I 7B appears to be blaok, aod a replacement is enclosed. There is notbing wroog with the other two CDs. I successfully opeoed tbe text files ou botb CDs usiog WordPad. The Final.tiff¡les on both CDs were successfolly processed Wid1 Schlumberger sofiware into ASCI! files, which show no sigo of corruption. However, a replacement CD for eacb has been furnisbed to you. If you require furtber assistance reading these CDs, please contact: Sincerely, Dana Kostreba Log Data Planning Coordinator DK:dk Enel: 3 original CDs: Wells C-27B, NK-12C, and S-I7B 3 replacement CDs for the above Jþl- IL.(~ #: loS-7-3 ~ í L-f D5ò do3 -6:')-~- t!..363-/?;(P 'Ft 1381& • • ~F`--_ ~~ ~~~ MICROFILMED 03101/2008 D4 NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_Inserts~Microfilm_Marker. doc e e WELL LOG TRANSMITTAL f). 08 - /6& To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 !òUKJJ RE: MWD Formation Evaluation Logs C-27B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 C-27B: LAS Data & Digital Log Images: 50-029-20843-02 1 CD Rom ~ c9j /)9/ (jp l D J(J\.'^- DATA SUBMITTAL COMPLIANCE REPORT 1/3/2006 Permit to Drill 2031860 Well Name/No. PRUDHOE BAY UNIT C-27B Operator BP EXPLORATION (ALASKA) INC ~pu.¿ tf 4.. À <J~) API No. 50-029-20843-02-00 MD 11947 - TVD 9025 /' Completion Date 12/10/2003 ' Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional surve~ --- -------- DATA INFORMATION Types Electric or Other Logs Run: SGRC, GR, EWR, MGR, CCL, CNS Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH I Start Stop CH ~ Received Comments Rpt Directional Survey ~ D Lis 12615 I nduction/Resistivity ~ Lis LIS Verification 10499 11947 12/22/2003 10458 11902 Open 8/5/2004 MWD,STS LIS, ROP,GR,RPX,RPS,RPM,R PD,FET 10458 11902 Open 8/5/2004 MWD,STS LIS, DSN 12615,ROP,GR,RPX,RPS¡ RPM,RPD,FET ~ Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments - ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~/N œN Chips Received? Jý 1 N Formation Tops Analysis ~Y II>J Received? ----- Comments: Compliance Reviewed By: ~ Date: t.(J~~Co --- -. -------~----- ---------- RECEIVE " ) STATE OF ALASKA' AUG 0 ", . r:; ALASKA OIL AND GAS CONSERVATION COMMISSION 4Ia 3 2005 REPORT OF SUNDRY WELL OPERATION~ska Oil &AGas Cons. Camm;s nch-or8gt: OtherD Time ExtensionD Re-enter Suspended Well D " I: 1 . Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: Repair WellD Pull TubingD Operation ShutdownD BP Exploration (Alaska), Inc. measured 11947 feet true vertical 9024.7 feet measured 11913 feet true vertical 9024.3 feet Length Size P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 72.34 8. Property Designation: ADL-028310 11. Present Well Condition Summary: Total Depth Effective Depth Casing 76 2706 10431 301 52 1100 609 20" 91.5# H-40 13-3/8" 72# L-80 9-518" 47# L-80 7" 26# L-80 3-1/2" 8.81# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 CONDUCTOR SURFACE PRODUCTION LINER LINER LINER LINER Perforation depth: Measured depth: 11250 - 11268, 11550 -11910 True vertical depth: 9020.14 - 9025.73, 9026.63 - 9024.26 Plug Perforations 0 Perforate New Pool D Perforate IX! Stimulate D WaiverD 4. Current Well Class: Development ŒJ 5. Permit to Drill Number: 203-1860 6. API Number 50-029-20843-02-00 ExploratoryD StratigraphicD ServiceD 9. Well Name and Number: C-27B 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 34 110 34.0 110.0 1490 470 33 - 2739 33.0 - 2684.2 4930 2670 32 - 10463 32.0 - 8420.0 6870 4760 10212 - 10513 8222.0 - 8459.9 7240 5410 10186 - 10238 8201.7 - 8242.3 10530 10160 10238 - 11338 8242.3 - 9032.9 8640 7870 11338 - 11947 9032.9 - 9024.7 11160 10570 5-1/2" 17# L-80 4-1/2" 12.6# L-80 9-5/8" DV Packer 4-1/2" TIW HBBP Packer 3-1/2" Baker Liner Top PKR 5-1/2" Otis HRQ SSV Nipple @ 30 @ 2511 @ 2693 @ 10147 @ 10168 @ 2217 2511 1 0513 Tubinq ( size, qrade, and measured depth): Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWay.ne R. SChnorr~ D Signature ß-.d~øf~~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ Form 10-404 Revised 4/2004 Oil-Bbl SHUT-IN 851 ! Representative Dailv Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 19095 o 2123 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil [!] Gas D Development ŒJ ServiceD WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A Title Petroleum Engineer Phone Date 7/28/05 564-5174 ~-{aDMS BFL AUG 0 4 2005 " ') ) C-278 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/13/05 ***WELL SHUT IN ON ARRIVAL*** (DRIFTfTAG, PRE PERF.). DRIFT WITH 2" DUMMY GUN AND TAG @ 11,2901 SLM. ***TURN WELL OVER TO DSO*** 06/21/05 PERFORATED 112501-112681 WITH 2" POWERJET 6 SPF, 18.1" PENE, 0.20" EH, 6.5 GMS. CORRELATED TO SWS MCNL 09-12-03. ***NOTIFY DSO OF WELL STATUS*** FLUIDS PUMPED BBLS o NO FLUIDS PUMPED o TOTAL Page 1 ·'TREE = 6" McEVOY WELLHEAD = McEVOY ,. ACTÜÄmR;'~·'-~~~ÕTIS . 'kEi ELEV; , ... . 72ji B~ÉLEV ';--'--~~"'~áã:79' KOP:; . , ..,. """"2150' "M;;Ängle ~ "9S"'@1-1477; 'ÖätumriïïÖ; , 11034' bäiUmWÖ;' " ääõÖ;sS ) 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 2511' C-278 \sAFETY NOTES: LNR TOP PKR SET ON TOP /OF DEPLOY SLV DUE TO FAILED PT ON LNR LAP CMT JOB. 2217' I~ 5-1/2" OTIS HRQ SSSV NIP, ID = 4.562" 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2739' ~ - - I 2511' 1-1 5-1/2" X 4-1/2" XO, ID = 3.958" 1 =-1 2693' 1-1 9-5/8" DV PKR 1 ~ GAS LIFT fv1ANDRELS ST MD TVDDEV TYÆ VLV L TCH PORT DATE 7 3033 2840 45 LBD DOME RM 16 01/04/04 L 6 5037 4284 42 LBD DMY RM 0 07/13/03 5 6252 5162 46 LBD SO RA 20 01 /04/04 4 6992 5696 43 LBD DMY RA 0 04/08/98 3 7456 6037 42 LBD DMY RA 0 04/08/98 2 7919 6383 40 LBD DMY RA 0 04/08/98 1 8026 6465 40 LBD DMY RA 0 04/08/98 Minimum ID = 2.372" @ 10173' LINER TOP SPACER 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID=2.992" 1-1 10207' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10463' I TOP OF WHIPSTOCK 1-1 10518' ÆRFORA TION SUMfv1ARY REF LOG: SÆRRY SUN MCNL/GR LOG ON 12/09/03 ANGLEATTOPÆRF: 69 @ 11250' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 11250 - 11268 0 06/21/05 2" 6 11550 - 11910 0 12/09/03 I 7" LNR, 26#, L-80, ID = 6.276" 1-1 11480' I I , I :8: ¿S 10067' I~ 4-1/2" OTIS XA SLIDING SLV, ID = 3.813" 10131' 1-1 TIW PRB SEAL ASSY 1 10147' 1-1 9-5/8" X 4-1/2" TIW HBBP PKR, ID = 4.750" 1 10168' 1-1 4-1/2" BKR LNR TOP PKR, ID = 2.560" 1 10186' 1-1 3.7" BKR DEPLOYMENT SLV, ID = 3.0" 10206' 1-1 3-1/2" HES X NIP, ID = 3.813" 1 10212' 1-1 7" BOT LNR HGR TIEBACK SLEEVE 10238' 1-1 3-1/2" X 3-3/16" XO, ID = 2,880" 1 , ~ < MILL OUT WINDOW 10513' - 10521' I 11338' 1-1 3-3/16" X 2-7/8" XO, ID = 2.372" 1 12-7/8" LNR, 6.16#, L-80, ,0058 bpf, ID = 2,441" 1-1 12310' I ~ 12-7/8"LNR,6.16#,L-80,.0055bpf,ID=2.372" 1-1 11947' 1 DATE 12/14/82 10/27/87 01/08/97 12/09/03 01/04/04 06/21/05 REV BY COMMENTS INITIAL COM PLETION RWO CTD SIDETRACK (C-27A) TMN/KK CTD SIDETRACK (C-27B) DAV/KK GLV C/O WJHlPJC ÆRFS DATE REV BY COMMENTS PRUDHOE BAY UNrr WELL: C-27B ÆRMrr No: "2031860 API No: 50-029-20843-02 SEC 19, T11 N, R14E. 1755' SNL & 1033' WEL BP Exploration (Alaska) ) :203-/'?~ (-¿Co r :) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 04,2004 RE: MWD FOmlation Evaluation Logs C-27B, AK-MW-280 1 044 1 LDWG fOmlatted Disc with verification listing. API#: 50-029-20843-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ?f(Ø+ Si~~(' ;L~ , STATE OF ALASKA ALASKj )L AND GAS CONSERVATION COMi }sION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 1m Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519M6612 4a. Location of Well (Governmental Section): Surface: 1755' SNL, 1033' WEL, SEC. 19, T11N, R14E, UM Top of Productive Horizon: 1876' SNL, 642' EWL, SEC. 29, T11N, R14E, UM Total Depth: 1369' SNL, 1048' EWL, SEC. 29, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-_~~~~?X____ y- 5959463, Zone- '____~~~~,____ TPI: x- 666169 y- 5954102 Zone- ASP4 _.. '·_·"'''·__·''''___'''''"''_'h_'_h__.. Total Depth: x- 666563 y- 5954618 . Zone- ASP4 ." '._ ,_.____.·.,,_"'__..h'~_"____,_.._ _.""'"..'''._,._.. '_"__._,,.__._____.~_.. _,,___.__.~~_.____._.__.. 18. Directional Survey 1m Yes 0 No 21. Logs Run: SGRC, GR, EWR, MGR, CCL, CNL 22. One Other 5. Date Camp., Susp., or Aband. 12/10/2003 '! 6. Date Spudded 12/4/2003 7. Date T.D. Reached 12/8/2003 ' 8. KB Elevation (ft): KBE = 72.34' 9. Plug Back Depth (MD+ TVD) 11913 + 9024 Ft 10. Total Depth (MD+ TVD) , 11947 + 9025' Ft 11. Depth where SSSV set (Nipple) 2217' MD 19. Water depth, if offshore NIA MSL CASING, LINER AND CEMENTING RECORD CASING SiZE···. 20" x 30" 13M3/8" 9M5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" . St;TJING¡D~PTHMP TOPi ....} BOTTOM·'· Surface 110' Surface 2739' Surface 10463' 10212' 10518' 10168' 11947' . WT'PER,rr.. Insulated 72# 47# 26# 8.81# /6.2# /6,16# .ß~De, Conductor LM80 LM80 L-80 LM80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 11550' - 11910' 9027' - 9024' SETTING' D¡;P'fI-tTVD· To I? ·BOTTOM Surface 110' Surface 2684' Surface 8420' 8222' 8464' 8188' 9025' 1b. Well Class: 1m Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-186 13. API Number 50M 029-20843M02MOO 14. Well Name and Number: PBU C..27B 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 16, Property Designation: ADL 028310 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) '71 ¡,¢.) ~¡¿¿~ 1(;)/ 5/6 YnÞ AMClU~J, ... . , PUt-LED .1 HOLE 1 Size,··· CEMENTING REC,ORD, 36" 9 cu yds Concrete 17-1/2" 3906 cu ft Arcticset II 12M1/4" 1455 cu ft Class 'G\ 130 cu ft AS I 8M1/2" 451 cu ft Class 'G' 4-1/8" x 3-3/4" 101 cu ft Class 'G' fEB 0 100~ OR\G\NAL 24. · TUBING ReCORD SIZE DEPTH SET (MD) PACKER SET (MD) 5M1/2", 17#, L-80 2511' 4-1/2",12.6#, LM80 2511'-11125' 10147' 25. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL (MD) 2500' AMOUNT & KIND OF MATERIAL USED Freeze Protected with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): January 11, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BSL CHOKE SIZE 1/21/2004 4 TEST PERIOD -+ 2061 30,826 -0- 59.31° Flow Tubing Casing Pressure CALCULATED ....... OIL-BSL GAs-McF WATER-BsL OIL GRAVITy-API (CORR) Press. 661 24-HoUR RATE""" 12,366 184,956 MO- 31.3 27. CORE DATA kt::( '1-IVt::U Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate s-heet, if necessary). Submit core chips; if none, state "none". ' . JAN 2 2 2004 None .-Bfl Form 10-407 Revised 12/2003 GAS-OIL RATIO 14,954 12- '/(;"93 Alaska Oil & Gas Cons. Commission _ ~ D Anchorage ! CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERb ) 29. )ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Shublik B 10545' 8485' None Shublik C 10577' 8510' Zone 4B 10597' 8525' Zone 4A 10767' 8642' Top CGL / Top Zone 3 10855' 8713' Base CGL / Top Zone 2C 10957' 8805' 23SB I Zone 2Bu 11 020' 8863' 22TS I Zone 2BI 111 00' 8930' RECEIVED JAN 2 2 2004 Alaska Oil & Gas COilS. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ A W. . 11 dLJA T tl T h I A t t D t 0\, "\ r"') J-..U Terrie Hubble ···......·lOA,I; 0 J \1U....Jð"UUL i e ec nica ssis an a e ~^ \.....IT PBU C-27B 203-186 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Thomas McCarly, 564-4378 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated, Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1 and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ') ') BP EXPLORATION O;pe réit.ionsSul11 MéiryReport Page·t·of7 Start: 11/19/2003 Rig Release: 12/10/2003 Rig Number: N1 Phase Legal Well Name: C-27 Common Well Name: C-27 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From -To Hours Task. Code NPT 12/1/2003 15:00 - 16:00 1.00 MOB P 16:00 - 18:00 2.00 MOB P 18:00 - 22:00 4.00 MOB P 22:00 - 23:00 1.00 MOB P 23:00 - 23:30 0.50 MOB P 23:30 - 00:00 0.50 MOB P 12/2/2003 00:00 - 08:00 8.00 MOB P 08:00 - 08:30 0.50 MOB P 08:30 - 08:45 0.25 MOB P 08:45 - 13:00 4.25 MOB P 13:00 - 17:00 4.00 MOB P 17:00 - 18:00 1.00 MOB P 18:00 - 18:30 0.50 MOB P 18:30 - 20:30 2.00 RIGU P Spud Date: 11/11/1982 End: 12/10/2003 PRE Rig released from Y-23B @ 15:00Hrs on 12/1/2003. Prepare for move to C pad. R/U tarps & warm hydraulics PRE PJSM. Pull rig off well & set down. Clean up location & conduct post operations pad inspection. PRE PJSM. Pin hydraulic rams for lowering mast. Unpin and lower wind walls. Install derrick rams. Scope down and lower mast. PRE Jack-up rig & move rig down to N. side of V-pad. PRE Held pre-move safety meeting with crew, security, tool services & CPS. Review route, power line, and flow line crossings. CPS measured rig height. Measurement matches placard. PRE Moving rig from V-pad to C-pad. PRE Move rig from V-Pad to C-27. Position rig in front of well. PRE Conduct pre-operations pad inspection with DSO. PRE PJSM. Review procedure, hazards & mitigation for raising mast & windwalls. PRE Raise mast and windwalls. Secure guy wires. PRE Hang BOP stack on blocks & install dikes around tree. Place rig mats under rig. Place tioga heater on tree cap. Tree cap bolts very tight. Spot rig over well. PRE NO tree cap. PRE Pre tour technical limit meeting and crew change. PRE NU BOP stack. Spot cuttings box. Spot generator #3, Tech limits shack, MI Shack, MWD Shack. Call for milling fluid to fill pits. 20:30 - 22:15 1.75 RIGU P PRE 22:15 - 00:00 1.75 BOPSURP PRE 12/3/2003 00:00 - 03:00 3.00 BOPSUR P PRE 03:00 - 05:11 2.18 STWHIP P WEXIT 05: 11 - 05:25 0.23 STWHIP P WEXIT 05:25 - 05:45 0.33 STWHIP N SFAL WEXIT 05:45 - 07:30 1.75 STWHIP P WEXIT 07:30 - 08:00 0,50 STWHIP P WEXIT 08:00 - 08:30 0.50 STWHIP P WEXIT 08:30 - 14:20 5.83 STWHIP P WEXIT 14:20 - 15:15 0.92 STWHIP P WEXIT 15:15-18:05 2.83 STWHIP P WEXIT Rig accepted at 1900hrs 12-2-03 Unstab injector from stabbing box. Stab coil into injector. Clamp off PT BOP, Grease Crew serviced SV & MV. Notified AOGCC, Jeff Jones wavered witnessing BOP test NordiC#1 PT BOP PU CT and WFT Milling BHA, Installed CTC and pulled tested to 30k. Load dart and fill CT with 2% KCL w/1/2ppb biozan, pt CTC to 3500 psi. Open well Pc=O psi RIH to 900 ft with window mill BHA #1 CTP high unable ti circulate CT POOH to look at wellhead flow path. Plug in well between pits and HCR RIH circulating at min rate. Tag up at 10,138'. PU. Start pump and work through easily, RIH and tag up on cement at 10,496', Mill cement to 10,540.3' and motor stalled, pinch point. Correct depth -27' to 10,513', PU=44K, Mill window, 2.66/2.7/ Pump new 2% KCI w/ 1/2 ppb biozan off truck. 10519.0', Pump 15 bbl sweep of 2# biozan. 2.63/2.74/1850. 350 psi motor work. Good metal returns on the ditch magnets. All good indications of proper window milling. 10520.5', Exited 7". Continue milling formation at slow ROP for 10' of rathole. Window length=7.5'. Window Depths; Top of Whipstock=1 0513' Top of Window=1 0513' Printed: 12/17/2003 9:17:53 AM ) ) BPEXPLORATION OperationsS.u.mmary. .Rèp.ort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-27 C-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Page 2of7 Start: 11/19/2003 Rig Release: 12/10/2003 Rig Number: N1 Spud Date: 11/11/1982 End: 12/10/2003 Date From -To · Hours· . Task. Code Description of Operations WEXIT Bottom of Window=1 0520.5' RA Tag=1 0520.5' WEXIT TD rathole at 10530.5', pump 11 bbl high vis sweep, backream window. Dry drift down thru window slick, and back up clean. Continue to ream window while starting mud swap to flowpro, POOH Hold PJSM with all rig hands PU Drilling BHA #1 Pull tested CTC to 35k RIH at min rate RIH with BHA#2 Tagged at 10562', corrected back to 10530' PUH to Tie-In to Sag River Marker (=8 ft) RIH, Orient TF RIH and tagged bottom corrected at 10534ft. Working to get bit to drll with 65R TF Window acts ratty at the base Drilling, slow, hard to get started. Unable to get WOB without it stalling. Hard to keep TF with orienter. Depth drilled to = 10546' POOH to look at bit, change orienter and motor. PT MHA and CTC. Flush BHA w/ water and blow down with air. Good motor vibration while blowing down motor. Check motor. Motor is tight. Break bit. Several broken cutters on the bicenter blades, Change motor and orientor. Set motor bend to 1.04 degrees. MU parabolic diamond mill to BHA. RIH to 10,515'. Orient to HS. RIH 2.6/2.6/3,340 psi and tag at 10,551'. Stall. PU and retag. Stall. Orient 22R. Tag and stall. PU and log tie in. -26.1' correction. TF=22R. RIH at 1.3 fpm. Mill at 10,524.8', 2.6/2.6/3,270 psi. 50 psi motor work. Mill to 10,525.2'. RIH and tag bottom at 10,546'. Back ream window at 11 OR. Ream through window. Orient 60L. Back ream window. DPRB PROD1 10545.5', Tag bottom 0.5' from last TD. We are still exactly on depth to last run. Begin drilling. Making exactly the same ROP with the D331 parabolic mill as we were with the window mill from the window milling run, Making 7-20 fph. At this ROP we are probably in the Shublik, This is typical ROP in the Shublik with a DSM. 12/3/2003 15:15 - 18:05 2.83 STWHIP P 18:05 - 19:35 1.50 STWHIP P 19:35 - 21 :00 1.42 STWHIP P WEXIT 21 : 00 - 21 : 15 0.25 DRILL P PROD1 21:15 - 23:45 2.50 DRILL P PROD1 23:45 - 00:00 0.25 DRILL P PROD1 12/4/2003 00:00 - 02:00 2.00 DRILL N DPRB PROD1 02:00 - 02:25 0.42 DRILL N DPRB PROD1 02:25 - 03:25 1.00 DRILL N DPRB PROD1 03:25 - 06:05 2.67 DRILL N DPRB PROD1 06:05 - 07:30 1.42 DRILL N DPRB PROD1 07:30 - 07:40 0,17 DRILL N DPRB PROD1 07:40 - 08:30 0.83 DRILL N DPRB PROD1 08:30 - 09:30 1.00 DRILL N DPRB PROD1 09:30 - 11 :20 1.83 DRILL N DPRB PROD1 11 :20 - 12:00 0.67 DRILL N DPRB PROD1 12:00 -13:15 1.25 DRILL N DPRB PROD1 13:15 - 14:55 1.67 DRILL N Drilling ahead at 2.71/2.78/3800 psi. TF=10R. DPRB PROD1 10556', Made 10.5' in 1 :05 hours. Confirming ROP of about 10 fph. Exactly the same ROP as seen from last 10' of open hole milling on the window milling run. Attempt to catch bottoms up sample. Not a whole lot of cuttings, but geo reports getting some Shublik cuttings. Again confirming we are in open hole. 14:55 - 15:00 0.08 DRILL N 15:00 - 15:20 15:20 - 17:00 0.33 DRILL N 1.67 DRILL N Orient to 160L to back ream window 1 last time. DPRB PROD1 Backream up thru window at 163L at 60 fph. No motor work. DPRB PROD1 Go pumps down, dry drift down thru the window. No problems, Pull up thru the window dry, No problems. POOH to pick up drill bit. Paint EOP flag at 10465' bit depth, 10400' EOP. Printed: 12/17/2003 9:17:53 AM ) ') BPEXPLORATION Op.eratiol1s·SummaryReport Tag up at surface, stand back injector. Check mill and motor. Motor seemed tight. Mill was recovered at 3.79", with no obvious damage to the mill. The mill did have a metal curly-que in the dimple in the center of the D331. The metal was non magnetic, copper colored, quite hard metal. Break out mill. Pick up hycalog bi center bit. PROD1 RIH with bha #4. Hyclog bicenter bit. 1.04 deg motor. Sperry directional GR only. Tie into EOP flag at 10400'. Make -35' correction. Continue RIH. Slipped right thru the window easily. Tagged bottom at 10556', same as last run. Orient to 60R. Free spin 3170@2.6 bpm. Begin drilling. 2.6/2.6/3300 psi. ROP=40 fph. IAP=170 psi, OAP=40 psi. 10561', Orient around. Resume drilling at 60R. Drilled 10 to 40 fph to 10637' Survey at 1 0616.18'-43.46deg-193.95Azm, Drilling 19R TF ROP = 60 fph Dir drill from 10640' t010682' at 60TF, ROP 55 fph. Orient TF to 180R' Dir Drill with 180TF ROP = 60 fph. WOB = 3000# Drilled 10682' to 10793' TFf = 135L Orient TF around to 180deg Dir Drill with 180TF ROP =15 to 30 fph. WOB = 800 to 3500#. Drilling @ TFf= 180deg IAP/OA = 811/365 psi. Bleed down to 100/100 psi D=1 0836 ft at 0600hrs Drilled to 10842'. Short trip to window Tie in to RA marker. Correct +2'. Orient LS. Drill to 10,913' at 170L - 180. Orient to 140R. Drill to 10,932' at 2.7 12.7 13,400 psi. 10932', Still in Zone 3, but 9' TVD from base. POOH to change motor bend and bit. Tag up at surface, stand back injector. Safety meeting prior to changing out BHA's, Change out MWD probes, adjust motor AKO to 2,5 deg. Change out bits, Pick up new hycalog bi center bit. Recovered bit was graded 8,4,Ring out, but still could have made a few feet more of zone 3. RIH with BHA #5, Hycalog bi center bit, 2.5 deg AKO, Directional GR. Shallow hole test at 2300'. Continue RIH. Slick thru window, no problems to TD. Tag bottom, make a -26' correction to last depth of 10932', pick up and orient to 180. 10932', Resume drilling. IAP=122, OAP=68 psi. Pit vol=255 bbls. Drilling at 2.53/2.56/3350 psi. Free spin 3200 psi. ROP is dead sloWNWWWW.Yep.still in zone 3 D= 10954ft MD Oriented TF from 180 to 75L Drilling base Z3 ROP = 13 fph. D= 1 0985 ft Dir Drill from 10985' to 11006.50' TF 45L, ROP = 10 to 15 fph Orient TF from 45 L around to 90L Dir Drill from 11006' to 11028'.50' TF 45L, ROP = 10 to 15 fph Orient TF from 75 L around to 90L Drilling from 11028' TF 84L to 55L ROP 10 to 20 fph Lost 22 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-27 C-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From-To Hours Task' . Code· NPT Phase 12/4/2003 17:00 - 17:20 0.33 DRILL N DPRB PROD1 17:20 -19:10 1.83 DRILL P 19:10 - 19:15 0,08 DRILL P PROD1 19:15-19:35 0.33 DRILL P PROD1 19:35 - 19:50 0.25 DRILL P PROD1 19:50 - 23:50 4.00 DRILL P PROD1 23:50 - 00:00 0.17 DRILL P PROD1 12/5/2003 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 03:45 2,75 DRILL P PROD1 03:45 - 04:20 0.58 DRILL P PROD1 04:20 - 06:10 1.83 DRILL P PROD1 06: 1 0 - 07:00 0.83 DRILL P PROD1 07:00 - 12:30 5.50 DRILL P PROD1 12:30 - 12:50 0.33 DRILL P PROD1 12:50 - 13:50 1.00 DRILL P PROD1 13:50 - 15:35 1.75 DRILL P PROD1 15:35 - 15:45 0.17 DRILL P PROD1 15:45 - 16:05 0.33 DRILL P PROD1 16:05 - 16:45 0,67 DRILL P PROD1 16:45 - 19:00 2.25 DRILL P PROD1 19:00 - 19:15 0.25 DRILL P PROD1 19:15-21:55 2.67 DRILL P PROD1 21 :55 - 00:00 2.08 DRILL P PROD1 12/6/2003 00:00 - 01 :30 1.50 DRILL P PROD1 01 :30 - 02:00 0.50 DRILL P PROD1 02:00 - 03:14 1.23 DRILL P PROD1 03: 14 - 03:30 0,27 DRILL P PROD1 03:30 - 06:00 2.50 DRILL P PROD1 Page·30f7 Start: 11/19/2003 Rig Release: 12/10/2003 Rig Number: N1 Spud Date: 11/11/1982 End: 12/10/2003 Description of Operations Printed: 12/17/2003 9: 17: 53 AM ') ) Page 4 of 7 BP EXPLORATION OperationsSµmmary Repo.rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-27 C-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 . Date Start: 11/19/2003 Rig Release: 12/10/2003 Rig Number: N1 Spud Date: 11/11/1982 End: 12/10/2003 From- To Hours Task Code NPT Phase 12/6/2003 03:30 - 06:00 2.50 DRILL P 06:00 - 09:00 3.00 DRILL P 09:00 - 10:35 1,58 DRILL P 10:35 - 11 :45 1,17 DRILL P 11 :45 - 13:40 1.92 DRILL P 13:40 - 14:00 0.33 DRILL P 14:00 - 15:45 1.75 DRILL P 15:45 - 16:00 0.25 DRILL P 16:00 - 16:45 0.75 DRILL P 16:45 - 18:50 2.08 DRILL P 18:50 - 19:40 0.83 DRILL P 19:40 - 20:45 1.08 DRILL P 20:45 - 21 :14 0.48 DRILL P 21 :14 - 21 :55 0.68 DRILL P 21:55-22:15 0.33 DRILL P 22: 15 - 23:50 1.58 DRILL P 23:50 - 00:00 0.17 DRILL P 12/7/2003 00:00 - 01 :45 1.75 DRILL 01 :45 - 04:00 2.25 DRILL 04:00 - 06: 15 2.25 DRILL 06: 15 - 07:00 0.75 DRILL 07:00 - 07:30 0.50 DRILL 07:30 - 08:40 1.17 DRILL N 08:40 - 11 :40 3.00 DRILL P 11 :40 - 11 :50 0.17 DRILL P 11:50-12:10 0.33 DRILL P 12:10 - 13:30 1.33 DRILL P 13:30 - 14:55 14:55 - 15:40 1.42 DRILL N 0.75 DRILL N 15:40 - 18:15 2.58 DRILL N 18:15 - 18:40 0.42 DRILL P .. Description of Operations PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RREP PROD1 PROD1 PROD1 PROD1 PROD1 bbl in last 8 hrs (2.75 bph) Pit volume=297 bbls. IA=297, OA=358 psi. Drill to 11,100'. ROP 20 to 25 fph. Orient to 50L. Drill to 11,110'. Not getting required dog leg. -45% chert in samples. 11110', POOH to change bit and motor bend. Change motor and bend setting to 2,83 degrees. Change bit. Bit grade: 2-3-CT-G-X-NA-WT-BHA. RIH. Tie in to RA marker. Make a +3' correction. RIH to resume drilling. Orient to 70L toolface. Difficult to orient in high dogleg section of well. Finally got the right ballpark for tool face. Free spin=3200 psi at 2.6 bpm. Resume drilling. 2.6/2.6/3500 psi. Making 50 fph. Pit vol=275 bbls. 11123', Tool face fell off, need to get another click. Pull up to the window and orient around and around. Resume drilling. 2.6/2.6/3380. 85 fph. TF=72L. 11238', Wiper trip to shoe. Clean off bottom and to shoe. Resume drilling. 2.6/2.6/3400 psi. ROP=130 fph. Pit Vol=265 bbls. IAP=300 psi, OAP=320 psi. 11326', Orient to 90L. Can;t get clicks at TD. Pull up to the window to orient around again. Orient TF at 10525' (2.8 bent housing) 14 clicks RIH and tagged at 11326' TF 90L. Dir Drilling w/78L to 28L TF. Vp = 263bbl Q = 2.60/2.59 bpm. ROP = 90 to 150 fph. HOT in 11300' Geo Sample POOH at 11440' Wellbore landed POOH OOH, LD BHA, PU used DS49, scribe HS, PU Memory Restivity Tool, Program tool. MU MHA and Injector head BHA len = 89.97 ft RIH, shallow hole test at 500 ft, checked orienter at 5150', RIH. Tie in at RA Marker. -28' correction. MAD pass resistivity data at 900 fph for recorded data only. Tag bottom. Log up for real time resistivity data to pick the HOT. Lost rig power at 11,425'. All systems shut down, Continue logging for real time resistivity to 11,130'. RIH. Drill to 11,465' at 2.5 1 2.5 1 3,500 psi. Attempt to orient to 100L. Problem getting clicks. Pull up to lower dog leg section of hole at 10,900'. Still not getting clicks. RIH to bottom and tag bottom with pumps on. Still not able to orient. Pull up inside casing. DFAL PROD1 11465', POOH to change orientor. DFAL PROD1 Tag up at surface with BHA #7. Change out orienter. Inspect bit and motor. Both looked good. DFAL PROD1 RIH with BHA #8, check new orienter and MWD in shallow hole test at 2000', Continue RIH, Set down in the window 2 times with pumps down, PU, orient to high side, and set down again. Oriented to 45R, and set down again. Finally tagged it 2 more times and popped thru. Continue RIH with Drilling BHA. PROD1 Tag bottom and set depth to last tagged depth of 11465'. Drill Printed: 12/17/2003 9:17:53 AM ) ) BPEXP~ORA TION Operations Summary Re.port Legal Well Name: C-27 Common Well Name: C-27 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 From- To Hours Task Code NPT 12/7/2003 18:15 - 18:40 0.42 DRILL P 18:40 - 19:20 0.67 DRILL P 19:20 - 19:30 0.17 DRILL P 19:30 - 20:50 1,33 DRILL P Page 5 of? Spud Date: 11/11/1982 End: 12/10/2003 Start: 11/19/2003 Rig Release: 12/10/2003 Rig Number: N 1 Phåse DescriptiönöfOþeratiöns PROD1 ahead at 90L. PROD1 11485', Orient two clicks. Have to pull up above high dog leg areas to get clicks again. PROD1 Resume drilling. 2.6/2.6/3700 psi. IAP=515 psi, OAP=170 psi. Pit vol=205. Waiting for vac trucks to deliver new mud. PROD1 11511', Tool face rolled, need to get another click. Have to come back up to the window to get clicks. Aren't getting any clicks up in the vertical section of hole either. Pull up into casing, and try it again. Still not getting clicks. Mud swap in progress. Run back to bottom to lay in new mud. Finally got a couple. Drill ahead with TF at 90L. Drill to 11525'. 11525', Mud swap in progress. We have 65' of low dogleg hole. Need to come around to the right side. Orient to 70R. Getting clicks down here in the low dogleg section of hole. Resume drilling. 2.7/2.7/3400 psi. Free spin =3300 psi. IAP=425 psi, OAP=171 psi. Currently swapping to new mud. New mud has 14 ppb of Kla-gard, and 3% lubetex. Drilled to 11670' Wriper trip to window. Clean Drilling at 90L ROP @ 150 fpm Depth at 2400 hrs = 11707 ft 20:50 - 21 :05 0.25 DRILL P PROD1 21 : 05 - 21 : 1 0 0.08 DRILL P PROD1 21:10 - 22:45 1.58 DRILL P PROD1 22:45 - 23:35 0.83 DRILL P PROD1 23:35 - 00:00 0.42 DRILL P PROD1 12/8/2003 00:00 - 01 :40 1,67 DRILL P PROD1 01:40 - 02:45 1.08 DRILL P PROD1 02:45 - 03:45 1.00 DRILL P PROD1 03:45 - 04:30 0.75 DRILL P PROD1 04:30 - 05:25 0.92 DRILL P PROD1 05:25 - 06:30 1.08 DRILL P PROD1 06:30 - 08:40 2.17 DRILL P PROD1 08:40 - 10:00 1.33 DRILL P PROD1 10:00 - 11 :00 1.00 CASE P COMP 11 :00 - 11: 15 0.25 CASE P COMP 11 :15 - 14:20 3.08 CASE P COMP 14:20 - 14:50 0.50 CASE P COMP 14:50 - 16:45 1,92 CASE P COMP 16:45 - 17:20 0.58 CASE P COMP 17:20 - 20:00 20:00 - 20:20 20:20 - 20:35 2,67 CASE P 0,33 CEMT P 0.25 CEMT P COMP COMP COMP Dir Drilling at 135L to 90L TF Drilled to 11820' Wriper trip to window to 10600' Dir Drilling from 11820' w/90L TF BR = 2,3 and TR -20deg. Some stacking at 11886' TD well at 11935' MD/8952' Wriper to window to Tie-in at RA marker Tie-in at RA Marker at 10525'. Corrected +17 ft) RIH to 11230' and conducted MAD Pass at 15 fpm to TD. Tag TD at 11,947. POOH. Slight bobble pulling through window. Down load MWD data. LD BHA. Install Baker CTC. Pull and pressure test. RU elevators and prepare to run liner. PJSM for running liner. PU 2 7/8" x 3 3/16" liner. Pump dart. Landed on seat at 60.7 bbls away. No debris of any kind found ahead dart. RIH with liner BHA on coil pumping at minimum rate. Weight check at 10400'=43500#. RIH slick thru window., and in open hole to TD, Tag bottom, and make -29' correction, (Correction is same as used during drilling phase). PU at 51 klbs to ball drop location. Pump 5/8" ball to release from liner. Chase with mud. (Coil dart volume was 60.7 bbls). RIH back to bottom, Hard tag at same depth as before. Liner is at TD. Pump to 45 bbls away at 2.6 /2.6/2600 psi. Slow to 0.5 bpm at 45 bbls away. Ball on seat at 51.2 bbls away. Pressure up, good indication of shear at 3900 psi. PU 2' at 36 klbs, confirming we are released. Set weight back down on liner. Circulate well to KCL. Safety meeting prior to pumping liner cement job. Circulate at minimum rate while batching up cement. Printed: 12/17/2003 9:17:53 AM ~) ) BPEXPLQRA TION OperatiensSum>mary <Report Page 6 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-27 C-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11/19/2003 Rig Release: 12/10/2003 Rig Number: N1 Spud Date: 11/11/1982 End: 12/10/2003 ·Date From- To . Hours Task Code NPT Phase 12/812003 20:35 - 21 :35 1.00 CEMT P COMP Cement up to weight at 20:35. Final circ rate 0.5/0.5/200 psi. Down on pumps, line up to cementers. Pump 4 bbls of fresh water to warm lines. Pressure test cementers hard lines to 4000 psi. All passed ok. Come on line with cement. Pump annular volume of cement with 40% excess in open hole, plus 2 bbls cement over the top of the liner. This is 18 bbls of class G cement with additives as per proceedure. Pumping at 1,75/1,61/1030 psi. Drop coil dart. Chase with 2# biozan. Land dart in liner wiper plug on schedule. Land liner wiper plug on schedule, Bumped plug with 1000 psi over. Checked floats. Floats held. Got good returns thruout job, Got 1.8 bbls of cement over top of liner. Based on return rate during job. Good cement job. 21 :35 - 23:05 1.50 CEMT P COMP Put 200 psi on coil, pickup and unsting from CTLRT. Pump 2 bbls of bio at 1.0 bpm, then POOH replacing voidage with biozan. 23:05 - 23:20 0.25 CEMT P COMP OOH, RD CTLRT 23:20 - 23:40 0.33 CEMT P COMP PJSM on Memory CNL and picking up 58 jts of 1-1/4" CSH 23:40 - 00:00 0.33 CEMT P COMP PU SWS Memory CNL, install source and PU 1-1/4" CSH 1219/2003 00:00 - 02:00 2.00 EVAL P COMP PU Memory CNL and 58 jts 1-1/4" CSH. Stab Injector Head 02:00 - 03:05 1.08 EVAL P COMP RIH with Memory CNL BHA to 9000 ft. Wait on cement to achieve +500 psi ccompressives strength. Design thricking time for cement at 5.5 hrs. Cement at density at 2300 hrs 03:05 - 03:40 0.58 EVAL P COMP WOC UCA @ +500 psi at 0340 hrs 03:40 - 03:50 0.17 EVAL P COMP RIH from 9000 to to 10000 ft. 03:50 - 05:00 1.17 EVAL P COMP RIH logging wi Memory CNLlGR at 30 fpm. Tagged at 11937.5 ft (uncorrected) 05:00 - 05:30 0.50 EVAL P COMP PUH logging at 60 fpm 05:30 - 06: 10 0.67 EVAL P COMP RIH to lay in 15 bbl150k LSRV Flo-Pro 06:10 - 07:45 1.58 EVAL P COMP POOH laying in Perf Pill 07:45 - 08:00 0.25 EVAL P COMP Stand back injector. RU to stand back 1 1/4" CSH. 08:00 - 08:15 0.25 EVAL P COMP PJSM for standing back CSH. 08:15 - 09:00 0.75 EVAL P COMP Stand back 27 stands of CHS. 09:00 - 09:15 0.25 EVAL P COMP PJSM for LD RA source and logging tools. 09: 15 - 09:35 0.33 EVAL P COMP Remove RA source. LD logging tools 09:35 - 09:40 0.08 EVAL P COMP RU to test liner lap. 09:40 - 10:40 1.00 CEMT P COMP WOC to reach 2,000 psi compressive strength. 10:40-11:15 0,58 CEMT P COMP Test liner lap. Test failed. 11 : 15 - 11:40 0.42 PERF P COMP PJSM for running perf guns. 11 :40 - 12:30 0,83 PERF P COMP PU 360' of 2" SWS perf guns. 12:30 - 12:45 0,25 PERF P COMP Safety meeting prior to running CS hydril. 12:45 - 13:30 0.75 PERF P COMP Trip in hole with 23 stands of CS hydril. 13:30 - 15:20 1.83 PERF P COMP RIH with guns and CSH on coil. No problems at liner top. Tag bottom at 11937' CTM. Set depth on up weight to 11913'. Position guns at firing depth of 11910.7', 15:20 - 16:10 0.83 PERF P COMP Position the guns at firing depth. Attempt to pressure test the liner lap again prior to firing guns. Bring pressure up to 2000 psi at surface by pumping down the backside. The well is still taking fluid at 0.6 bpm at 1950 psi. We still have a leak downhole. Swap to perf pill. Pump 10 bbls, drop a 5/8" ball to fire perf guns, pump the remaining 12 bbls followed by KCL Coil volume = 62.0 bbls. Pump 45 bbls at max rate, drop rate to 0.5 bpm. Ball on seat at 53.6 bbls. Pressure up to 3000 psi, Printed: 12/17/2003 9:17:53AM ) ) BP EXPLORATION Operations .·Summary.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-27 C-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From -To Hours Task Code NPT Phase 12/9/2003 15:20 - 16: 10 0.83 PERF P COMP 16:10 - 18:00 1.83 PERF P 18:00-18:15 0.25 PERF P 18:15 - 18:30 0.25 PERF P 18:30 - 19:30 1.00 PERF P 19:30 - 19:45 0.25 PERF P 19:45 - 21 :00 1.25 PERF P 21:00 - 21:15 0.25 CEMT P 21 :15 - 22:00 0.75 CEMT P 22:00 - 00:00 2.00 CEMT P 12/1 0/2003 00:00 - 00:20 0.33 CEMT P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 00:20 - 01 :15 0.92 CEMT P COMP 01: 15 - 02:00 0.75 CEMT P COMP 02:00 - 03:30 03:30 - 03:50 1.50 CEMT P 0.33 CEMT P COMP COMP 03:50 - 04:15 0.42 CEMT P COMP 04:15 - 04:30 0,25 DEMOB P POST 04:30 - 06:00 1,50 DEMOB P POST 06:00 - 06:30 0.50 DEMOB P POST 06:30 - 07:00 0.50 DEMOB P POST 07:00 - 07:30 0.50 DEMOB P POST Page 70f .7 Start: 11/19/2003 Rig Release: 12/10/2003 Rig Number: N1 Spud Date: 11/11/1982 End: 12/10/2003 Descriþtionof Op~rations good indication of fire. Interval perforated is 11550'-11910', 6 spf, 60 degree phasing. POH with spent perf guns on coil tubing. Tag up at surface, stand back injector. Prepare to trip CS hydril OOH. PJSM prior to tripping CS hydril OOH. Stand back CSH. SAFETY MEETING. Review procedure, hazards and mitigation for recovery of SWS 2" perf guns. Layout SWS 2" perf guns. All shots fired, SAFETY MEETING. Review procedure, hazards and mitigation for running BKR liner top packer. M/U Baker 4.5" KB Liner top Packer with 6' seal assembly and 10' 2-7/8" pup Joint for space out. BHA total length = 90.71 ft. RIH with Baker 4.5" KB liner top packer BHA. Circ. at 0.2 bpm while RIH at 90 fpm. RIH with 4.5" Baker KB Liner top packer. Up Wt at 10,100 ft. = 41 K. Own Wt = 23K. RIH slow with 0.5 bpm. Seals in at 10,215' [press increase]. RIH and start stacking wt at 10,219 ft. Stack 10K at 10,222.1 ft. Sting out of liner top. Insert 5/8" AL ball and displace with KCL water. Pump 2.1 / 2.1 bpm, 1000 psi. Slow to 0.5 bpm at 46 bbls. Ball on seat at 53.9 bbls, RIH with Packer. Stack 1 OK down at 10,222 ft. OK. Pick up 3.0 ft from up wt of 41 K. Set Packer with 2070 psi. Pick up 45K. Packer is set. Set down 10K, on packer at 1 0219ft. [3.3 ft higher than first tag]. Pressure test 3-3/16" X 4.5" liner lap with 2500 psi, good pressure test. Pressure up to 3900 psi and shear released from Baker 4.5" KB Packer. POH with BKR running tool. Circ. 2.5 / 2.0 bpm while POH. Freeze Protect 5.5" tubing with MEOH water while POH. Stop at 100 ft and circ. 100% MEOH water to surface. Layout BKR running tools. Recover 100% of BHA. Top of 4.5" Baker KB Liner top Packer is at 10,168 ft. BKB. Minimum ID = 2.372". Close Master and Swab valves. WHP = 0 psi, lAP = 40 psi, OAP = 40 psi. Well is secured. SAFETY MEETING. Review procedure, hazards and mitigation to pump N2 and displace KCL water from coil. Pump N2 and displace KCL water from coil. Bleed down N2 pressure, Clean rig pits. Safety meeting to discuss rig down activities. Continue to clean pits and cuttings tank. Begin nippling down stack. Pressure test tree cap to 4000 psi, ok, Continue to clean pits. Release rig at 07:30. Further dims entries carried on K-19AL 1 morning report. Printed: 12/17/2003 9:17:53AM TREE = WELLHEAD: ACTUA TOR: KB. ELEV = 6f1 McEVOY McEVOY OTIS 72,3' = KOP: 2150' Max Angle: 95 @ 11477' Datum MD = 8800' 55 15-1/2" TBG, 17#, 4.892" H 2511' H 2739' 10 MINIMUM ID == UNER TOP 17" BOT LNR HGR TIEBACK SLEEVE I., 10212' I 9-5/8" CSG, 47#, L-aO, ID = 8.681"1" 10463' PERFORATION SUMMARY INTERVAL 13-3/4" BKR DEPLOY MENT SLV, ID =3.000" H 7" X 4-1/2" OTIS HCL PACKER. ID = 4,000" H 14-1/2" TBG, 12,6#, L-80, ,0152 bpf, ID =3.958"1., 10575' 11110' 11125' . SAFETY NQTES: waL ANGLe:> 10" @ 11252' & :> 90"@1131S', .. 5-1/2" OTIS HRQ 5SSV NIP, ID '" 4.562" I ID = 3,958" I 11120' 11123' 11126' Ù10S' 17" LNR. 26#, L-80, ID = 6.276" H 11480' -----.4 12-7/S" LNR, 6,16#, L-80, ,0058 bpI, 10 = 2,441" J-t 12310' DATE 12/14/82 10/27187 01108197 07/02103 07/13/03 09/15/03 REV BY COMMENTS INITIAL COMPLETION RWO CTO SIOETRACK (C·27 A) CMOITLP KB ELEVATION CORRECTION DTRlKK GL V ClO CMOITLP PERF ANGLE CORRECTION MD WD DEV TYPE VLV LTCH PORT DMY 07/13103 DMY 0 07/13/03 5 46 DMY RA 0 04/08/98 4 43 OMY RA 0 0410S/9S 3 42 LBO DMY RA 0 04108/98 2 6383 40 LBO DMY RA 0 04/08/98 1 6465 40 LBO OMY RA 0 04/08/98 , . 4·1/2" OTIS XA SLIDING SLV, 10 = 3,813" I TIN PRB SEAL ASSY I 9·5/8" x 4-112" TiW HBBPPKR, 10: 4.750" I OATE REV BY COMMENTS I I H H ~ 4·1/2"OTIS X NIP, 10 =3.813" I 4·1/2" OTIS XN NIP, *ID MILLBJ TO 3,800" ~;.~:~"~S~~J . I ELMO TT LOG UNA V AILABLE 7" MILLOUT WINDOW 11130' - 11137' (FIBER CMT PLUG) 11375' H 2-7/8" BKR IBP 06102/98 I PBTD H 12247' I PRUDHOE BAY UNIT SF' Exploration (Alaska) ) AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DIFINITIVE Re: Distribution of Survey Data for Well C-27B Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 10,499.94' MD Window / Kickoff Survey: 10,518.00' MD (if applicable) Projected Survey: 11,947.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 4K~~,~~ ) 8C3r-l~(o 18-Dec-03 ,) C~EaV'E[':\ F\ E... ,~. R ',-,,,. ó;...)' DEC 22 2003 AiQskª Oil & Gas Gons. l"..rOWmiS5ion Ancnoft'ige Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA C Pad C-27B Job No. AKMW0002801044, Surveyed: 8 December, 2003 Survey Report 18 December, 2003 Your Ref: API 500292084302 Surface Coordinates: 5959463.00 N, 664357.00 E (700 17' 44.0495" N, 148040' 08.7244" WJ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959463.00 N, 164357.00 E (Grid) Surface Coordinates relative to Structure Reference: 2204.23 N, 1855.61 E (True) Kelly Bushing Elevation: 72.34ft above Mean Sea Level Kelly Bushing Elevation: 72.34ft above Project V Reference Kelly Bushing Elevation: 72.34ft above Structure Reference =npr'I'Y-5Uf1 DRILLING SERViCeS A Halliburton Company L4 9 ~ !!311111. N· ,. ) -, ....:.. V r, 1!111. ". ....... II : ~ ";øg' ~ I ... ,.;> I- _:I i . ~ ~ --- .~ Survey Ref: svy4141 Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-27B Your Ref: API 500292084302 Job No. AKMW0002801044, Surveyed: 8 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10499.94 37.050 181.190 8377.13 8449.47 5113.41 S 1775.28 E 5954389.63 N 666243.67 E -833.13 Tie On Point MWD Magnetic - 10518.00 36.990 181 . 140 8391.55 8463.89 5124.29 S 1775.05 E 5954378.75 N 666243.68 E 0.372 -838.43 Window Point 10548.82 39.120 185.740 8415.82 8488.16 5143.24 S 1773.90 E 5954359.78 N 666242.94 E 11.503 -848.34 10578.29 40.440 189.780 8438.48 8510.82 5161.91 S 1771.34 E 5954341.06 N 666240.80 E 9.847 -859.37 10616.13 43.460 194.520 8466.62 8538.96 5186.61 S 1765.99 E 5954316.24 N 666235.99 E 11.564 -875.69 ,-,". 10647.78 48.550 200.270 8488,61 8560.95 5208.30 S 1759.15 E 5954294.41 N 666229.62 E 20.711 -891.91 10677.62 50.400 201.500 8508.00 8580.34 5229.49 S 1751.06 E 5954273.05 N 666222.00 E 6.946 -909.00 10714.54 47.350 203.900 8532.28 8604.62 5255.15 S 1740.34 E 5954247.17 N 666211.84 E 9.602 -930.51 10744.02 43.610 208.380 8552.95 8625.29 5274.01 S 1731.11 E 5954228.10 N 666203.03 E 16.678 -947.52 10777.29 40.180 202.030 8577.72 8650.06 5294.07 S 1721.62 E 5954207.84 N 666193.98 E 16.383 -965.31 10807.04 36.830 200.270 8601.00 8673.34 5311.34 S 1714.93 E 5954190.43 N 666187.67 E 11.847 -979.33 10838.50 33.390 202.740 8626.74 8699.08 5328.18 S 1708.32 E 5954173.45 N 666181.42 E 11.828 -993.07 10868.92 29.960 200.620 8652.62 8724.96 5343.01 S 1702.41 E 5954158.49 N 666175.84 E 11.853 -1005.26 10897.72 26.960 196,390 8677.94 8750.28 5356.01 S 1698.03 E 5954145.40 N 666171.75 E 12.544 -1015.22 10941.21 20.090 206.970 8717.81 8790.15 5372.15 S 1691.85 E 5954129.13 N 666165.92 E 18.485 -1028.26 10971.58 19.300 182.300 8746.45 8818.79 5381.83 S 1689.28 E 5954119.40 N 666163.56 E 27.308 -1035.07 11004.49 24.670 163.970 8776.99 8849.33 5393.89 S 1690.96 E 5954107.38 N 666165.51 E 26.300 -1039.25 11034.09 28.110 143.180 8803.56 8875.90 5405.44 S 1696.86 E 5954095.96 N 666171.66 E 33.125 -1039.46 11066.49 33.920 130.840 8831.35 8903.69 5417.48 S 1708.29 E 5954084.17 N 666183.35 E 26.505 -1035.02 11094.29 40.970 126.970 8853.41 8925.75 5428.05 S 1721.46 E 5954073.89 N 666196.75 E 26.724 -1028.35 11125.15 44.410 119.210 8876.10 8948.44 5439.41 S 1738.99 E 5954062.91 N 666214.52 E 20.355 -1018.21 11153.77 47.220 105.120 8896.10 8968.44 5447.06 S 1757.92 E 5954055.68 N 666233.61 E 36.588 -1005.09 .~ 11182.08 51.980 95.250 8914.47 8986.81 5450.80 S 1779.10 E 5954052.41 N 666254.87 E 31.394 -988.15 11215.70 60.260 86.790 8933.22 9005.56 5451.19 S 1806.94 E 5954052.62 N 666282.71 E 32.264 -963.75 11251.55 69.780 81.860 8948.35 9020.69 5447.93 S 1839.22 E 5954056.59 N 666314.91 E 29.325 -933.71 11283.97 79.120 77.630 8957.03 9029.37 5442.35 S 1869.91 E 5954062.84 N 666345.4 7 E 31.425 -904.00 11317.88 89.870 72.870 8960.28 9032,62 5433.76 S 1902.49 E 5954072.14 N 666377.86 E 34.636 -871.20 11348.52 88.110 62.300 8960.82 9033.16 5422.10 S 1930.77 E 5954084.42 N 666405.87 E 34.966 -840.75 11383.50 89.160 54.720 8961.66 9034.00 5403.85 S 1960.57 E 5954103.32 N 666435.27 E 21.870 -805.87 11414.53 89.960 44.150 8961.90 9034.24 5383.70 S 1984.11 E 5954123.98 N 666458.36 E 34.160 -775.63 18 December, 2003 - 20:13 Page 20f4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-27B Your Ref: API 500292084302 Job No. A KMW000280 1 044, Surveyed: 8 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11442.37 93.300 37.450 8961.11 9033.45 5362.65 S 2002.28 E 5954145.42 N 666476.07 E 26.879 -749.70 11477.19 94.630 32.690 8958.70 9031.04 5334.22 S 2022.23 E 5954174.27 N 666495.39 E 14.162 -718.74 11520.16 92.510 26.700 8956.02 9028.36 5296.99 S 2043.46 E 5954211.96 N 666515.81 E 14.761 -682.51 11558.41 94.540 31.270 8953.67 9026.01 5263.60 S 2061.96 E 5954245.75 N 666533.56 E 13.052 -650.51 11601.59 93.220 27.940 8950.74 9023.08 5226.15 S 2083.23 E 5954283.65 N 666554.02 E 8.279 -614.14 11632.30 91.630 23.000 8949.44 9021.78 5198.46 S 2096.42 E 5954311.63 N 666566.60 E 16.884 -589.50 .~ 11676.14 89.690 18.070 8948.94 9021.28 5157.42 S 2111.80 E 5954352.99 N 666581.07 E 12.084 -556.66 11707.34 89.870 14.190 8949.06 9021.40 5127.46 S 2120.46 E 5954383.14 N 666589.08 E 12.449 -534.94 11741.39 90.040 7.850 8949.08 9021.42 5094.05 S 2126.97 E 5954416.68 N 666594.85 E 18.626 -513.51 11776.98 87.670 3.090 8949.80 '9022.14 5058.64 S 2130.36 E 5954452.15 N 666597.4 7 E 14.937 -493.89 11806.56 88.630 356.920 8950.75 9023.09 5029.09 S 2130.36 E 5954481.69 N 666596.82 E 21.099 -480.02 11838.47 89.430 353.050 8951.29 9023.63 4997.32 S 2127.57 E 5954513.40 N 666593.34 E 12.382 -467.56 11874.48 89.600 348.290 8951.60 9023.94 4961.79 S 2121.74E 5954548.79 N 666586.73 E 13.226 -456.04 11913.06 89.340 338.600 8951.95 9024.29 4924.86 S 2110.76 E 5954585.4 7 N 666574.94 E 25.125 -448.39 .' 11947.00 89.340 338.600 8952.35 9024.69 4893.26 S 2098.37 E 5954616.79 N 666561.87 E 0.000 -444.49 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 62.000° (True). Magnetic Declination at Surface is 25.468° (03-Dec-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11947.00ft., The Bottom Hole Displacement is 5324.21ft., in the Direction of 156.789° (True). - 18 December, 2003 - 20:13 Page 3 of4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA C Pad - C-27B Your Ref: API 500292084302 Job No. AKMW0002801044, Surveyed: 8 December, 2003 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 10499.94 10518.00 11947.00 8449.4 7 8463.89 9024.69 5113.41 S 5124.29 S 4893.26 S 1775.28 E 1775.05 E 2098.37 E Tie On Point Window Point Projected Survey .~. Survey tool program for C-27B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10499.94 0.00 10499.94 8449.47 11947.00 8449.47 BP High Accuracy Gyro (C-27) 9024.69 MWD Magnetic (C-27B) ---,' 18 December, 2003 - 20:13 Page 4 of4 DrillQuest 3.03.05.005 ) ) -ç ~ -\ fE (êù ['~ % U w ~Ln\ (v) .J~lru ) AI/ASKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit PBU C-27B BP Exploration (Alaska), Inc. Permit No: 203-186 Surface Location: 1755' SNL, 1033' WEL, Sec. 19, T11N, R14E, UM Bottomhole Location: 1413' SNL, 1055' EWL, Sec.29, T11N, R14E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development well. This pemlit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well PBU C-27 A, Permit No 196-139, API 50-029-20843-01. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ,E~~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this .s- day of November, 2003 cc: Department ofFish & Game, Habitat Section wlo enc1. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section W61\- Ii l s l z.co~ o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1755' SNL, 1033' WEL, SEC. 19, T11N, R14E, UM Top of Productive Horizon: 1647' SNL, 722' EWL, SEC. 29, T11N, R14E, UM Total Depth: 1413' SNL, 1055' EWL, SEC. 29, T11N, R14E, UM " STATE OF ALASKA ALASKA l ) AND GAS CONSERVATION COI\" }SSION PERMIT TO DRILL 20 MC 25.005 / II Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: /' PBU C-27B 12. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: B Blanket 0 Single Well Bond No. 2S 100302630-277 6. Proposed Depth: MD 11850 TVD 8954 7. Property Designation: ADL 028310 8. Land Use Permit: 13. Approximate Spud Date: / December 1, 2003 14. Distance to Nearest Property: 31,680' 9. Acres in Property: 2560 4b. Location of Well (State Base Plane Coordinates): Surface: X-664357 Y-5959463 Zone-ASP4 16. Deviated Wells: Kickoff Depth 18.' '.. Càsing Prógfárri', ,',:" ' 'Size 1 Hole Casing WeiQht 4-1/8" x 3-3/16" x 6.2# 16.5# 10518 ft Maximum Hole Angle :SP~~i~c~t~~n'~' ", Grade CouplinQ L-80 TCII /STL 10. KB Elevation KBE = 15. Distance to Nearest Well Within Pool (Height above GL): 72.34' feet C-06APB1 is 1267' away /' 17. Anticipated pressure (see 20 MC 25.035) / 900 Max. Downhole Pressure: 3250 psig. Max. Surface Pressure: 2194 psig '..',;,,·S~~tIÅg'pêpthi:,';:I;, ' quantity of.çel11ent , Top ","',', ',',I Bottom, ' , ,(c,f.orsacks)" LenQth MD TVD MD TVD (including stage data) 1650' 10200' 8140' 11850' 8954' 84 cu ft Class 'G' /' !j ,9;" :" PRE$E~t. 'WI;:LL CÒNDITIQN'SU,MMARY(Tobe; c()rTlplete~:lfpH~edlilnANPRe~entry Operation$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): 12300 9045 11375 11375 9002 '" :LØng~h Junk (measured): N/A "1ïIO" Structural Conductor 110' 20" x 30" 9 cu yds concrete 110' 110' Surface 2739' 13-3/8" 3906 cu ft Arcticset II 2739' 2684' Intermediate 10463' 9-5/8" 1455 cu ft Class 'G', 130 cu ft AS I 10463' 8420' Production Liner 918' 7" 451 cu ft Class 'G' 10212' - 11130' 8222' - 8947' Perforation Depth MD (ft): 11060' - 12230' Perforation Depth TVD (ft): 8893' - 9039' 20. Attachments a Filing Fee a BOP Sketch a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Property Plat 0 Diverter Sketch 0 Seabed Report B Drilling Fluid Program a 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Thomas McCarty Title CT Drilling Engineer Signature /'/-...~ Æ~ Phone 564-4378 I' / ~ Commission Use Only Permit To Drill API Number: Permit Apprp~1 1 See cov,er letter for Number: Z O,,-:r -/~~ b 50-029-20843-02-00 Date: J It vI) / é?.3 other requirements Conditions of Approval: Samples Required 0 Yes J2fNo Mud Log Required [J Yes ~ No Hydrogen Sulfide Measures )?fYes D No Directional Survey Requir~< t~,~~::: r't~9:':,' Other: Te.st BoP6- t-c "3Soo p!-(I. Date: Contact Thomas McCarty, 564-4378 Prepared By Name/Number: Date /O/Jr"íI;> Terrie Hubble, 564-4628 Approved By: ~~ Form 10-401 Revised 3/;001 ~~~ o RIG I N A LBYORDERd~:éS"¿ 3 () '>"1, COMMISSIONER THE COMMISSION ~'I ('"'I¡"""....,~_., ~¡""~.",I""",..,,:, . ~:wch~?df¡~ncie ) ) BP C-27B CTD Sidetrack Phase 1 Operations: Non rig Prep Work: · Drift the production tubing & liner. · Set 2-7/8" Cast Iron Bridge Plug (CIBP) in 2-7/8" liner at approx. 11, 125'md. 7 · Punch holes in the 4112" tubing at 11,100' & 10,230'. oJ 0 l· . · Set a Cement retainer at approx. 10,600' and circulate 15.8ppg cement up backside annulus. · Cleanout cement to 10,550'md. · Install whipstock at approx. 1 0,518'md (8392'TVDss). Phase 2 Operations: Nordic 1 Prep Work: Planned for Nov 5th, 03. · Mill 3.8" dual string window, most likely done by Nordic 1 CTD rig but may be done with service coil /' time permitting. Phase 3 Operations: Drill and Complete sidetrack: Drill the build & lateral sections of the sidetrack as per the attached directional plan. The max hole angle will be __90°. Solid 33116 x 2%" liner will complete the sidetrack, which will be cemented and selectively perforated. Mud Program: · Phase 1: Seawaterl 2% KCI /) · Phase 2,3: Mill with seawater 1 V2lb biozan, drill with Solids Free Flo-Pro (8.6éYPP9) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / The production liner will be solid 33116TCII x 2Ys" STL from a TD of.... -;"&50' (-8954'ss) to 10,200'MD (8, 140'ss) within the 4112" tubing. The liner will be cemented with 5 þbls, 15.8ppg class g cement with a planned TOC at 10,200' within the 4112" tubing. The sidetrack i larflíed for 100-300' of perforations in Zone 2. Parent Well Casings OH size Burst (psi) Collapse (psi) 13%" 72#, L-80, Seal Lock - Intermediate to 2,739' 17% 5380 2670 9%" 47#, L-80, Seal Lock -Int 2,739 -10,212 12\4 6870 4760 7" 26#, L-80, Seal Lock - Production Liner 10212- 8% 7240 5410 10575 2-7/8", L80 STL- Production Liner 10575-12310 3% 10570 11170 Planned Sidetrack Casings 3-3/16" 6.2#, L-80, TCII- Prod LNR 10200-11350 4Ys 8520 7660 2Ys" 6.5#, L-80, STL- Prod LNR 11350-11850 3% 10570 11170 Well Control: · BOP diagram is attached. /' · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90°. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · The nearest well in the pool is C-06APB1 Ctr-Ctr distance is 1267'. / · The nearest Prudhoe Bay property line is approx. 31,680'. I ) ) Logging · MWD Gamma Ray will be run in the open hole section. Memory CNL will be run inside the liner. Hazards /' · H2S was measured at 10ppm in 2000 on C-27. · One fault will be cut by the wellpath. The risk of a lost circulation event is considered moderate. Reservoir Pressure · Res. press. is estimated to be 3250PJ at 8800'ss (7.1 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2194 psi. TREE = 6" WELLHEAD= McEVOY 'A'i:5=rUÄ'TÖR;;"UU"'U"'U' ",u""''''''Öris' ....,....,........"..........,..,...."......................,,,.................,...................., KB. ELEV = 72.3' BF. ELEV = 38.79' KOP= 2150' Max Angle = '98@"1"1"336' Datum MD = 11034' Datum TVD = 8800' SS ) 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1--1 2511' 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2739' ~ Minimum ID = 2.372" @ 10580' 2-7/8" LINER TOP C-27 A SAr )NOTES: WELL ANGLE> 700@ 11237' & > 90° @ 11270'. - - , :8: . 19-5/8" CSG, 47#, L-80, ID= 8.681" l-i 10463' µ I TOP OF 2-7/8" LNR, 6.16#, L-80, ID = 2.372" 1--1 10580' I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" 1-1 11125' 1 PERFORA TION SUMIV1ARY REF LOG: SS rv1VVD GR LOG of 01/05/97 ANGLEAT TOP ÆRF: 95 @ 11300' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-5/8" 8 11060 - 11085 C 10/24/87 1-11/16" 4 11300 - 11350 0 04/04/98 1-11/16" 4 11757 - 11780 C 06/02/98 2-1/8" 4 12040 - 12120 C 06/02/98 2-1/8" 4 12150 - 12230 C 06/02/98 .,",I."""h ::¡~~.~, ':'" :,~iMP~ 2217' I~ 5-1/2" OTIS HRQ SSSV NIP, ID = 4.562" -, I 2511' 1--1 5-1/2" X 4-1/2" XO, ID = 3.958" I =--1 2693' 1--1 9-5/8" DV PKR I ~ GAS LIFT IV1ANDRELS ST MD TVD DEV TYPE VLV L TCH PORT DATE L 7 3033 2840 45 LBD DMY RM 0 07/13/03 6 5037 4284 42 LBD DMY RM 0 07/13/03 5 6252 5162 46 LBD DMY RA 0 04/08/98 4 6992 5696 43 LBD DMY RA 0 04/08/98 3 7456 6037 42 LBD DMY RA 0 04/08/98 2 7919 6383 40 LBD DMY RA 0 04/08/98 1 8026 6465 40 LBD DMY RA 0 04/08/98 I I 10067' I~ 4-1/2" OTIS XA SLIDING SLV, ID = 3.813" ~ 10131' 1--1 TrN PRB SEAL ASSY 1 ~ 10147' 1--1 9-5/8" x 4-1/2" TrN HBBP PKR, ID = 4.750" 7--i 10212' 1--1 7" BOT LNR HGR TIEBACK SLEEVE I ~i~~8 ~ I 10575' 1--1 3-3/4" BKR DEPLOY MENT SL V, ID = 3.000" 1 I ~ ~ 11110' 1--1 7" X 4-1/2" OTIS HCL PACKER, ID = 4,000" 11120' 1--1 4-1/2"OTISXNIP,ID=3.813" 1 11123' 1--1 4-1/2" OTIS XN NIP, .. ID MILLED TO 3.800" 11126' 1-1 4-1/2" WLEG I 11108' 1--1 ELMDlT LOG UNAVAILABLE I , , 7" MILLOUT WINDOW 11130' - 11137' (FIBER CMT PLUG) 11375' \--1 2-7/8" BKR IBP06/02/98 I PBTD \-1 12247' I I 7" LNR, 26#, L-80, ID = 6.276" l-i 11480' 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 1--1 12310' DATE 12/14/82 1 0/27/87 01/08/97 07/02/03 07/13/03 09/15/03 REV BY COMMENTS INITIAL COM PLETION RWO CTD SIDETRACK (C-27A) CMOfTLP KB ELEV A TION CORRECTION DTR/KK GL V C/O CMOfTLP ÆRF ANGLE CORRECTION DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: C-27 A ÆRMIT No: 1961390 API No: 50-029-20843-01 SEC 19, T11 N, R14E, 1755' SNL & 1033' WEL BP Exploration (Alas ka) TREE = ' WELLHEAD= ACTUA TOR= KB, ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= 6" S-112"TBG, 17#, L-80, ,0232 opf, ID = 4,892" H 2511' 72#, L-80, ID = 12,347" H 2739' I T' BOT LNR HGR TIEBACK SLEEVE H 10212' NOTES: WELL ANGLE> 70° @ 11237' & > 1270'. e 2217' I~ 5-1/2"OTIS HRQ SSSV NIP, 10 = 4,562" I ...... - ::- -1 ~ 2511' H X 4-112" XO, 10= 3,958" I 2693' H 9-518" DV PKR 1 rJ LIFT MANDRELS TYPE VLV PORT DMY RM 6 DMYRM 0 5 DMY ~ 0 4 DMY ~ 0 3 LBO DMY~ 0 2 LBO OMY ~ 0 1 LBO DMY ~ 0 DATE 07113103 07/13103 04108198 04/08/98 04/08/98 04108/98 04108/98 10067' IJ 4-112" OTIS XA SLIDING SLV, ID = 3,813" 10131' l-ì TIW PRB SEAL ASSY I 9-518" x 4-1/2" T\W HBSP PKR, ID = 4,750" 11- 19-5/8" CSG, 47#, L-80, ID = 8,681" H 10463' ~ PERFO~ TION SUMMARY REF LOG: SS fv1WDGR LOG of 01/05/97 ANGLE AT TOP PERF: 95 @ 11300' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/5qz DATE 2-5/8" 8 11060-11085 1-11/16" 4 11300 - 11350 1-11/16" 4 11757 - 11780 2-1/8" 4 12040 - 12120 2-1/8" 4 12150 - 12230 13-3/4" 8KR DEPLOYMENT SLV, ID = 3,000" H 10575' T'X4-1/2"OTISHCLPACKER,ID=4,000" H 11110' 14-1/2" TaG, 12,6#, L-80, ,0152 opf, ID = 3,958" H 11125' DATE 12/14/82 10/27/87 01108/97 07/02/03 07113103 09/15/03 I I 4-1/2" OTIS X NIP, ID=3,813" I 4-1/2" OTIS XN NIP, * ID MILLED TO 3,800" 4~1/2"WLEG I ElMDTrLOG UNAVAILABLE I 7" MILLOUT WINDOW 11130' - 11137' (FIBER CMT PLUG) 11375' H 2-7Î8" BKR IBP 06/02/98 I PBID l-ì 12247' 1 I 7" LNR, 26#, L-80, ID = 6,276" H 11480' 12-7/8" LNR, 6,16#, L-80, ,0058 opf, ID = REV BY COMMENTS INITIAl.. COM PI-ETION RWO CTD SIDETRACK (C-27A) CMOfTLP DTR/KK PERF ANGLE eORRECT1ON DATE H 12310' REV BY COMMENTS PRUDHOE BAY UNfT WELL: c-27A PERMfT No: 1961390 API No: 50-029-20843-01 SEe 19, T11N, R14E, 1755' SNL & 1033' WEL ~p ExploratiQI1 (Ala$ka) BP Amoco WELLPATH DETAILS PliII"#4 (:~27B 500292084302 Parent W",tl¥aüll C47 TÚI' 011 MO: 10500.00 ...' Rerf.D.atvm: V.So;:;Uøn ..... &2:.00' C-27A 72.34ft ~11: ~w ~::n.rtin~Ð .,00 REFERENCE INFORMATION Co-ordtnate (N1E) Reference We!! Centre: C~27, True North Vert¡cal (TVD) Reference Systèm: Mean Sea Leve! Sec-hon (VS) Reference: Stot ~ 27 (O.OON,O.OOE) Measured Depth Reference: C~27A 72,34 Calculation Method: Minimum Curvature SECTION DETAILS .« ..... TFJIiICfI To,.., 37.05. 131.1$ 8377.16 -tl-H;J,45 :t77~29 0,00 .... -833.13 36.$ ~5:ii mii! >.5124.28 1715.1)1 0.37 206.63 ~n.4i ~:gg :i;ß:;i 117<M17 d:!! 30.00 :::t~1 n~: ø.u.oo 48.74 204,24 .s23!MW .~oo :~:~ 30.74- 204..2.4- ~~~ ..:5U$.S1 '171-0.;22 ,~.. 100.00 11MI4 204,24 .53#7." 1$'&4.43 12;.00 1ffO,OO _1(119;32 35-50 ,...., 6&01.&3 =:i~ ~~~::: ,~oo ~~5 -~:g ..... n.$3 iliQZ5..28 "'".. 00,00 3I! ....... 1$15.91 ",00 439.40 =:~g ::~: ::ill:g ~¿[~ ~¡: ~~:: ~:~ , , ! ~ . ~~1 ANNOTATIONS TV. MD Annobltiott 1'IP MP · · · · 1 · · " 11 TD 8250 8300 1"8600 " _ 8650 111 ~ :e 8700 GÞ :> 8750 GÞ !880 I- 8850 LEGEND T Azimuths to True North Magnetic North: 25.540 Plan: Plan #4 (C-27!Plan#4 C-27B) Cr-eated By: Sri] Potnis Date: 9/24/2003 M Stre Dip Date: 912412003 Model: bggm2003 -4800 -4900 -485O~ -4950 -5000 .... z::: ~ -5050- ~ -5100 .... +-5150·- -- .z::: 1:: -5200 o ~ -5250 - . -- .z::: -5300 .. :s o -5350~ tI) -5400~ -5450 -5500 -5550 -5600 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 West(-)/East(+) [50ft/in] -1200-1150-1100-1050-1000 -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 -50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 Vertical Section at 62.00· [50ft/in] 9/24/2-003 1;21PM Company: Field: Site: Well: Wellpath: ') bp BP-GDB Baker Hughes INTEQ Planning Report ." . '.... ,.. ,.,.,- 0" ._.......""._,....... ~."."._..,.". .,.. "1'.."'.' .."~,,... .,,'.'. ..'" ..-...... .,._..."_.._.~..,, '" .....,..,..,. .'...-_.".".~,,,.,,.'._-....,_.,.,-.._... -.."-.",",.....",", ..,._.-,-,. ) ..1 . IS: I.N'I'E!.Q ........""....<...-."-.,,..,,.......-. BPAmoco Prudhoe. Bay PBC Pad C-27 Plan#4C.:.27B Date.: ..·...~/24/2003 . .. ..Tiine:13:23:12 Page: Co-ordiraate(NE) Reference: vven:.C~27,Tl1.Je North .vertical (TV[))~eference: System: Mean, Sea Level Secti()n{\'S) Ref~rence:' ,Well (o.QON,O.00E,62.00Azi) :__§~~_~~_C?~_I~,~~~~i~~:~!~~~~:.,__,_~~nimum,:~~~C~"~~~~_ , Db: Oracle ,".,...:..;,_.......;.~....,."..,....,,'_.""_. Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957218.72 ft 662550.03 ft Alaska, Zone 4 Well Centre bggm2003 Latitude: Longitude: North Reference: Grid Convergence: 70 17 22.367 N 148 41 2.797 W True 1.24 deg Well: C-27 Slot Name: 27 C-27 W ell Position : +N/-S 2204.83 ft Northing: 5959462.99 ft Latitude: 70 17 44.049 N +E/-W 1855.20 ft Easting : 664357.00 ft Longitude: 148 40 8.724 W Position Uncertainty: 0.00 ft Wellpath: Plan#4 C-27B 500292084302 Current Datum: C-27A Magnetic Data: 9/24/2003 Field Strength: 57573 nT Vertical Section: Depth From (TVD) ft 39.34 Targets Annotation MD ft 10500.00 10518.00 10538.00 10588.00 10688.00 10838.00 10928.00 . 11028.00 11203.00 : 11314.27 111439.27 : 11850.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 C-27 10500.00 ft Mean Sea Level 25.54 deg 80.85 deg Direction deg . _" ..... .,. .u_.~ .._, _~....,.._._,,~_. 62.00 Height 72.34 ft +N/-S ft 0.00 . .........".. "_' .'~" ...~,',_...._ ',_.n' "-:. ~._. .,.._~.:..._._..,_.. ~,.,._~~.".,... __.. _, .,,,_ .'.,._............~..,_....,,--.."". ~,--- -,-..~ ,. ._"-.~. ..........-.-......,.., ._~. .,~ Name Description ,. ,u ._., ......I:).i,~:,",. Dir. C-27B Polygon4.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 ·Polygon 5 -Polygon 6 -Polygon 7 C-27B T4.1 Fault -Plan out by 1.91 at C-27B T 4.2 C-27B T4.3 MIlP, ........M~p TVD +N/-S +E/-W Northing I. Easting ft -"'--"~-"'- ft ft ft "'". " ·...u......... ....,... .. "'''-'''''~ ...... ,.. ...... -..,<-,--.".".-"--,,., ".,,,.'..,,,,,.,..- 0.00 -5260.69 1878.55 5954245.00 666350.00 0.00 -5260.69 1878.55 5954245.00 666350.00 0.00 -5213.33 1999.62 5954295.00 666470.00 0.00 -5090.42 2097.34 5954420.00 666565.00 0.00 -4958.92 2030.19 5954550.00 666495.00 0.00 -4895.35 2096.60 5954615.00 666560.00 0.00 -5179.05 2490.52 5954340.00 666960.00 0.00 -5460.66 1874.17 5954045.00 666350.00 8867.00 -5427.82 1744.85 5954075.00 666220.00 8867.00 -5426.01 1745.47 5954076.82 666220.58 8954.00 -5393.46 1911.65 5954113.00 666386.00 8954.00 4936.56 2105.70 5954574.00 666570.00 _M_ .. .__._,~___~'. ,,_.~_. --- -....-----.. .._~-~_.- ---.." --'-'--"'--'---~--'_. <-~-- Latitude,--> <-,-Longitude--> Deg MiD Sec Deg Min Sec _~_..,_"._,,,_..".., ......___... .",._."..u.....'.."...,__..."..................,.. 70 16 52.308 N 70 16 52.308 N 70 16 52.774 N 70 16 53.982 N 70 16 55.276 N 70 16 55.901 N 70 16 53.110 N 70 16 50.342 N 70 16 50.665 N 70 16 50.683 N 70 16 51.003 N 70 16 55.496 N .' ._,. __......,.__,. ~ ___ow . '---'--' '._" ---. ..... .--. -.. - -.--.-----.----..-.-----,-.----....-.. TVD ft 8377.18 8391.55 8407.36 8445.57 8516.06 8630.94 8712.16 8801.93 8925.28 8953.66 8953.66 8953.66 TIP KOP 3 4 5 6 7 8 9 10 11 TD 148 39 14.009 W 148 39 14.009 W 148 39 10.482 W 148 39 7.635 W 148 39 9.590 W 148 39 7.655 W 148 38 56.184 W 148 39 14.138 W 148 39 17.904 W 148 39 17.886 W 148 39 13.046 W 148 39 7.390 W -------,---,-,--,--,,---- Company: BP Amoco Field: Rrudhoe> Bay Site: PS C Pad Well: C~27 Wellf)a.th: PI~~~_'?:~!~, Plan: Plan #4 Identical to Lamar's Plan #4 Principal: Yes bp Plan Section Information MD ft 10500.00 10518.00 10538.00 10588.00 10688.00 10838.00 10928.00 11028.00 11203.00 11314.27 11439.27 11850.00 Survey MD ft 10500.00 10518,00 10525.00 10538.00 10550.00 Incl deg 37.05 36.99 38.56 41.83 48.74 30.74 19.94 35.50 60.29 90.00 90.00 90.00 Azirn (jeg n. u',,, .,.,"'" '...".. ~ ""_".,,.. , 181.19 181.14 182.58 190.38 204.24 204.24 204.24 144.81 78.83 62.86 44.11 342.50 Incl deg 37.05 36.99 37.54 38.56 39.29 Azim deg ..,.... .., ..,." .n. .... ". _._.. '" 181.19 181.14 181.66 182.58 184.55 ) ') 11.·1 BAKIIR IIUGIIIS IN'I'EQ BP-GDB Baker Hughes INTEQ Planning Report "."., ............. .~.,..~.." ..~..,. '''''''''<'.__.."".~,."",-_.~,~ '. . '-"~_. ,~., ,"...- ...~.. .,,_., ,_. - ,'..."......~._,._---'..,-"'-,,~~.._--_.__.~.._-,._-...~+^:'""._.,-~-_.. ··--:-·__·--··~·7--··_·__·..·-·-'-·_-_·," r..··'·-"_·····~--"- '. ..._-_...-~ ....-....-,." "" ..._ ~,.,.,.,._,._.Jh.,..... ..,'. ._.r_" .....~....".~.. "". ."_.".,,...... Date: ·.·..·.·9/24/2003·. . ..' .:Ome:1t3::23:12·" Page: 2 <:o-or~in~te(NE).l{eference: · Wen:, C-27 , TrlJe North V ~rti(:al(TV-'»Referenee: '. '. System: Mean. Se~ Level Seçtion(VS)Refe~ence: .... W~II(0.00N O~OOE,62.00Azi) ",~."..~~-';:~~5:~I~~'~~~~~'~'~~~~:~::.:,~,::c~:~:~~iT,~:~\9c~~~,t~~e., ,..,,,,..,,,.: '.....~b:. Oracle Date Composed: Version: Tied-to: 9/24/2003 2 From: Definitive Path .. . _'...,_ ,."~ _ '. ,.".""..._.,."..~,.,,,.,,,...,,_..,,.,, ,_ ." ,.' .".. ',~~..,'.'_..,_." .,_,..'..",_~,~".,.......'_. _.~"..,.,~__.,_.__,. ~..k"...._.,_.~'..._. .,_,_,___ ~_._ __..............,..,..._ ,__~._".",..~.'. ."..._,_~._"_.,_,_,..,,._.._ ._ .,.._._~ ....-....-_. ..~.._,.... TVD TN/..S +E/~W [)LS ·.Suil4 ..Tur.. TFO rarget ft "...,._..._~."..",...~~_.":..;_.:,..".~,~~:..,_,,.,. _,._...~!~/1p,~~~~~1..~~~"'~~:~L~~~"..._:_~.:~.._"_..."'...._.,..''','__ __,,,,..,,,, 8377.18 -5113.45 1775.29 0.00 0.00 0.00 0.00 8391.55 -5124.28 1775.07 0.37 -0.33 -0.28 206.63 8407.36 -5136.52 1774.67 9.00 7.84 7.22 30.00 8445.57 -5168.52 1770.96 12.00 6.55 15.60 60.00 8516.06 -5235.84 1749.44 12.00 6.91 13.86 60.00 8630.94 -5322.91 1710.22 12.00 -12.00 0.00 180.00 8712.16 -5357.98 1694.43 12.00 -12.00 0.00 180.00 8801.93 -5398.18 1704.39 30.00 15.56 -59.43 270.00 8925.28 -5427.03 1816.16 30.00 14.17 -37.70 270.00 8953.66 -5391.27 1915.91 30.00 26.70 -14.35 330.00 8953.66 -5317.22 2015.93 15.00 0.00 -15.00 270.00 8953.66 -4936.50 2105.97 15.00 0.00 -15.00 270.00 , , Sys TVD ft ...u._'.'.' . ........... 8377.18 8391.55 8397.12 8407.36 8416.70 ..... .._ ....·..._.__....h N/S E/W MapN ft¡ ft ft ..'...¡,... ":..,~..,,.. ...-..,. "''''-' ~,_.~_.'..,,~.,..,,- "_..~,'".,,..._'.~- ......~' , ,..~.....,,~"'... -5113.45 1775.29 5954389.94 -5124.28 1775.07 5954379.10 -5128.52 1774.97 5954374.87 -5136.52 1774.67 5954366.86 -5144.05 1774.20 5954359.32 VS DLS TFO "'__,_,~__,,_" .~e~~,1Y~~,~:,,_,~_~.~ -833.13 0.00 0.00 -838.41 0.37 206.63 -840.49 9.00 30.00 -844.51 9.00 29.59 -848.46 12.00 60.00 MapE ft ......-..'".."..._~~._.- .'". .'.,.... ,~. 666243.56 666243.57 666243.56 666243.44 666243.14 Tool TIP KOP MWD 3 MWD 10575.00 40.93 188.46 8435.82 -5160.04 1772.37 5954343.29 666241.65 -857.59 12.00 58.47 MWD 10588.00 41.83 190.38 8445.57 -5168.52 1770.96 5954334.79 666240.43 -862.81 12.00 55.48 4 10600.00 42,57 192.23 8454.46 -5176.42 1769.38 5954326.85 666239.02 -867.91 12.00 60.00 MWD 10625.00 44.19 195.90 8472.64 -5193.07 1765.20 5954310.12 666235.21 -879.42 12.00 58.63 MWD 10650.00 45.92 199.37 8490.30 -5209.92 1759.83 5954293.15 666230.21 -892.07 12.00 55.96 MWD 10675.00 47.75 202.62 8507.41 -5226.94 1753.29 5954276.00 666224.05 -905.83 12.00 53.52 MWD 10688.00 48.74 204.24 8516.06 -5235.84 1749.44 5954267.02 666220.39 -913.4~ 12.00 51.29 5 10700.00 47.30 204.24 8524.09 -5243.97 1745.77 5954258.81 666216.90 -920.47 12.00 180.00 MWD 10725,00 44.30 204.24 8541.52 -5260.31 1738.42 5954242.31 666209.90 -934.64 12.00 180.00 MWD 10750.00 41.30 204.24 8559.86 -5275.80 1731.44 5954226.68 666203.27 -948.06 12.00 180.00 MWD 10775.00 38.30 204.24 8579.06 -5290.38 1724.87 5954211.95 666197.02 -960.71 12.00 180.00 MWD 10800.00 35.30 204.24 8599.08 -5304.04 1718.72 5954198.17 666191.17 -972.55 12.00 180.00 MWD 10825.00 32.30 204.24 8619.85 -5316.72 1713.01 5954185.37 666185.74 -983.55 12.00 180.00 MWD 10838.00 30.74 204.24 8630.94 -5322.91 1710.22 5954179.12 666183.09 -988.92 12.00 180.00 6 10850.00 29.30 204.24 8641 ,33 -5328.39 1707.76 5954173.59 666180,74 -993.66 12..00 180.00 MWD 10875.00 26.30 204.24 8663.44 -5339.02 1702.97 5954162.86 666176.19 -1002.88 12.00 180.00 MWD 10900.00 23.30 204.24 8686.13 -5348.57 1698.67 5954153.21 666172.10 -1011.17 12.00 180.00 MWD 10925.00 20.30 204.24 8709.34 -5357.04 1694.86 5954144.66 666168.47 -1018.51 12.00 180.00 MWD 10928.00 19.94 204.24 8712.16 -5357.98 1694.43 5954143.71 666168.07 -1019.32 12.00 180.00 7 10950.00 20.96 185.50 8732.79 -5365.32 1692.51 5954136.33 666166.31 -1024.47 30.00 270.00 MWD / 10975,00 24.25 167.87 8755.90 -5374.81 1693.16 5954126.86 666167.17 -1028.35 30.00 287.58 MWD 11000.00 29.07 154.98 8778.25 -5385.35 1696.82 5954116.41 666171.05 -1030.07 30.00 303.88 MWD 11025.00 34,77 145.74 8799.47 -5396.76 1703.41 5954105.14 666177.89 -1029,61 30.00 315.42 MWD 11028.00 35.50 144.81 8801.93 -5398.18 1704.39 5954103.75 666178.90 -1029.40 30.00 323.28 8 11050.00 36.03 133,54 8819.80 -5407.87 1712.77 5954094.24 666187.49 -1026.55 30.00 270.00 MWD 11075,00 37.85 121.42 8839.81 -5416.94 1724.66 5954085.43 666199.58 -1020.31 30.00 279.15 MWD 11100.00 40.80 110.52 8859.16 -5423.81 1738.88 5954078.87 666213.94 -1010.99 30.00 288.86 MWD 11110.47 42.32 106.38 8867.00 -5426.01 1745.47 5954076.82 666220.58 -1006.20 30.00 297.30 C-27B T 4 11125,00 44.65 101.03 8877 .54 -5428.37 1755.18 5954074.68 666230.33 -998.73 30.00 300.40 MWD 11150.00 49.19 92.83 8894.63 -5430.52 1773.27 5954072.92 666248.47 -983.76 30.00 304.29 MWD - "'...- --'- . ---- -,. -- .- ObP ) BP-GDB ) Baker Hughes INTEQ Planning Report . - .... -.', -- ....-..._..",.._.~.,,". """" BAli·· ...HlS iÏ~;ijiij"'""""--"-''"'' . ._.~." '~"'T"""'."-""-'''''-'~'''·-:'''''''''---'' "¥___"'_"""'" """"''''-:' '''''''~''., ",.. ,._....._....,....._.""....-.,~_.-'. .,~'.'4 ...-...,.. ..-.. ."_,.,, .--_. ···-···..·t·,"··· '..: ....' ... ' . ..._,,, ",.,..- . ...,.~"'.'_. . Company: BPAmoco Field: PrudhoeB~y Site: PBC Pad Well: C-27 Wellpath: Plan#4.C-27B Date:..·~/2~/2o.03... .......... .·.·.....TiDîe: .13:23:12 Page: 3 C0-c>r.dinate(NE)Ref~rence: VVf:!II:. C~27,. TruE> North Yertical (TV())Refer~~ce: Syst~m¡Mea~ Sea· Level $ection(VS)Ref~rence:..... Well (0.Oo.N,O.o.OE,62.o.o.Azi) Surv~y'~~I~_,!I~~~!~..~!~~~~:.,._." Minimum<?_u.~~,t~~~, Db:, . 9~a~I~_, Survey MD ft 11175.0.0. 1120.0..0.0. 1120.3.00. 11225.0.0. 11250.,00. 11275.0.0. 1130.0..00. 11314.27 11325.00. 11350..00. 11375.00. 1140.0..00. 11425.00 11439.27 11450..0.0 11475.00. 11500..00. 11525.00. 11550..00. 11575.00. 1160.0..00. 11625.00. 11650..00 11675.00 11700..0.0. 11725.00. 11750..00. 11775.00 1180.0..00 11825.0.0 11850.00. loci deg 54.22 59.62 60.29 66.05 72.70 79.40 86.15 90.0.0 90.0.0 90..00. 90.00 90.00 90.00 90.00 90.00 90..00 90.0.0 90.00 90.0.0 90.00 90.00 90..00 90.00 90.00 90.0.0 90.0.0 90.00 90.00 90.00 90.0.0. 90.00 Azim deg 85.74 79.53 78.83 75.22 71.50. 68.04 64.72 62,86 61.25 57.50. 53.75 50.0.0 46.25 44.11 42.50 38.75 35.00. 31.25 27.50. 23.75 20.00 16.25 12.50 8.75 5.0.0. 1.25 357.50 353.75 350..0.0 346.25 342.50 SysTVD ft 8910.13 8923.78 8925.28 8935.21 8944.01 8950.04 8953.18 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 8953.66 .._. _ .... ...... ____ .". __no '" ...__._ _ N/S E/W ft ft .' ..,...~~ .," ."..."""'.,,,,,....,,.........,,...". -5430.23 1792.86 -5427.51 1813.61 -5427.03 1816.16 -5422.61 1835.28 -5415.90. 1857.67 l\iIapN MapE VS DLS ,......._,.._~.,_.,__,,_,,_, ,,,.,,~_~,~_.,""..:..,_ ..:.,i, ft . ,..,,_...~,:~~~p,o.!~._ 59540.73.64 666268.05 -966.33 30.00 5954076.81 666288.73 -946.74 30.0.0. 5954077.35 666291.27 -944.26 30.00 59540.82.19 666310..28 -925.31 30.00. 5954089.39 666332.53 -902.38 30..00 TFO Tool deg ....' .._.. '~', ....".".''''.~_L. ,..~,." 309.89 MWD 314.29 MWD 317.69 9 330.0.0 MWD 331.63 MWD -5407.50. -5.397.56 -5391.27 -5386.24 -5373.51 -5359.39 -5343.96 -5327.28 -5317,22 -5309.41 -5290.44 -5270.45 -5249.51 -5227.73 -5205.19 -5182.0.0. -5158.24 -5134.03 -510.9.46 -50.84.65 -5059.69 -5034.70 -500.9.77 -4985.03 -4960.57 -4936.50 1880..42 190.3.12 1915.91 1925.39 1946.90 1967.53 1987.20 2005.81 2015.93 2023.29 20.39.56 20.54.56 20.68.22 2080.48 2091.29 2100.61 210.8.38 2114.59 2119.20 2122.19 2123.55 2123.28 2121.38 2117.84 2112.70 210.5.97 59540.98.27 5954108.70 5954115.28 5954120.51 5954133.71 5954148.27 5954164.13 5954181.21 5954191.49 5954199.46 5954218.78 5954239.09 5954260.32 5954282.36 595430.5.13 5954328.52 5954352.44 5954376.78 5954401.44 5954426.31 5954451.29 5954476.28 5954501.15 5954525.81 5954550.15 5954574.07 666355.08 666377.56 666390..21 666399.58 666420..80 666441.12 666460.44 666478.68 666488.58 666495.76 666511.62 666526.18 666539.37 666551.15 666561.47 666570.27 666577.53 666583.20. 666587.27 666589.72 666590..54 666589.72 666587.27 666583.19 666577.52 666570..26 -878.36 -853.65 -839.40 -828.66 -803.70 -778.85 -754.25 -729.98 -716.33 -706.16 -682.88 -660.25 -638.36 -617.31 -597.19 -578.07 -560..06 -543.21 -527.61 -513.31 -500..39 -488.90 -478.88 -470.38 -463.44 -458.09 30.00 30..00 30.00. 15.00. 15.00 15.00 15.0.0 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00. 15.00 15.00 15.00 15.00 15.00 15.0.0 332.94 MWD 333.78 MWD 334.20 10 270.00. MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 11 270.00 MWD 270.00 MWD 270..00 MWD 270.0.0 MWD 270.0.0 MWD 270.00 MWD 270.00 MWD 270..00 MWD 270..00 MWD 270..0.0. MWD 270.00. MWD 270.00 MWD 270.00 MWD 270..00 MWD 270.0.0 MWD 270.0.0 MWD 270.00 TD Weill L, " '" , " ' , 1,3~'5000 psi L.-J ..".. I T ..;':':':': , ~~~?? I, ) BOP-Tree ) I I, I I KB Elevation , QIIP .~...,..," Lu~ri~:tar ID - 637~ with 6" Otis Uni"" Rig Floor I I Hv.:1r,llI.r,rlul:'l, I 17 1/16" 5000 psi BOP's. 10 = 7.06" I ~ I I I +-i!fHh:~!!:¡:ªQþ'ºj~@)~*f4ß.:@:(:}¡1 tt~~tt~t?t BI n~~~ears j~~J~tt~~ttt~1 / , , . ... " H4 Turn L T VaJve I 1"·.."""..,,:1 ~ j Ö L."!TIt, J /' ,.M. .J0""@llli:,,;:~~,~ J v~t;O~R;' ~,., Choke Line 11"".'.' I, Kill Line It·' L.J I /' I:;:::;:;:::;:::;::::;;::;::::~II v 8,jl" R;¡rn:'l~ 121/16" 5000 psi RX-24 I :;:::;::;;: :.;,:.;.;.:.;.:,:.:,:.:,:.:,'. ~ ~ T (\ T, , ' :;:::;:;;;: I " " " ' :::::::::::: I / 1"':':':':':':':':':':':':-:'12 j Ij 1~',jrTrbl I ' "I ~ .........,',.,',.,',.....,',., TOT , , ,', 7,1/16" 5000 psi (RX-46) or t 'd"'. j ..- 41/16" 5000 psi (RX-39) kQ~".':\ ~ ~. Swab Valve jl:~;~~::~~~:~~:~Ú:;:~:::~Ù;;~¡b ,',':'::::::,':','. '""""""" ~ ~:: J~Fi~Ün.I~-+ m::,:::::::::::::::::::::::::::::::}:g~ilil~~::::::':'::::;'::::::: ------.-.---------- ::;:':':':':;:;:;:':: Y""""""""""f I':::::::::::::::::::i'" I I ~:~::~O)::::::: SSV ",~~;::~:~~ti~I,. ' R"""""'''''~ ~e; ~.J~~;~;~~:f:~:ml {~~~~~;~~i~~ I' : :~~:~:~~l~:~: "1 I I I I, .. I I Tree Size I I Master Valve I I [()(g" J)()J . ~ . . . - . - ' . ,,:'. :. .: . .. .._n 11111111111111111111 ......... ~"~?~?~'~v..m'~ I, Base Flan!le 1 I Page 1 p055155 DATE 8/22/2003 CHECK NO. 055155 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 8/22/2003 INV# PR082003N PERMIT TO DRILL FEE H C- · ~ 18 -~ f~ECE"JVI:~f" Ut\t 1...u-:J OC'r 3 0 ')0' (Yi ,.,..,d ::.lj,J Alask~ Oil & G ... C· ,. '\ '. a ~ d;) ùdS. Cor;:1fl'/""'(i" I, I ,),)1"" Anchorane THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGt;, AK9951ß-6612 NATIONAL CITY BANK Ashland. Ohio 56-389 412 No. P 0 5 515 5 CONSOLIDATED COMMERCIAL ACCOUNT PAY: I!iJ QU ~ ~J"tr(, ~::~:, £J2":_. r-,:--- -, ~ ~ DATE August 22; 2003 AMOUNT TO THE ORDER OF: . -"--. - -~ . -" - - - .. ~ ~ .. "- - ---.---. -- "..--_-"_ - -0.0" -- -_ -.".- __ - c-_ . -"- -------- "-- -----.--- ~,:--~- .;~:. ~~~~~~~:~~~ ,~~~:-.'~~~~~~ ~~~~,~,~,~.~,~.~~:~.-. -- ---~~~:.~~~ ~~~~~.~ :.~~,.~~, -:,---.- -"- -,-. .:.:'--" ----.--:-- .--.---- ::--:. . -- --. A~~KA CRIL &GAS CPNSERVJ\TION 333 W7TEj A\lENJ,JE SUITE 10Çh,u"u ~~~~~,.~~.~~ ANCHORA~E,AK 9P501-3539 -~ *******$100.00******* NOT~IDAITOl H20 fJf.,Vr;.,,,·. '^'" .. 'U,;~~. .}:~: ~.·:::':::::·S:: :::~ ~::¡::'~'::' ~~:""._}.:~~~;.~:: :;iS~ / ::,:,:,:.::, :.J ...... .~... f.. ~ .... ....<t '..-' .-.. ...... ...../ :'\'i':~:'" .~ .~~.~ ~~~. "-':-"'~;':'-: :.\- :~>'~~I i~:~::··:~:::..:: :~.:::~·:·::i~.. :{-~:}{:·~Ù?~:::; ~~~~i?~f \~ ~.::..:::: ~:',j II- 0 5 5 . 5 5 II- I: 0 ~ ~ 2 0 ~ a ., 5 I: 0 ~ 2 7 a ., b 1111 ) TRANS1VI1TAL LETTER CHECK'LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK WHAT APPLIES ;/ Rev: 07/10/02 C\jody\templates WELL NAME ,//1 r"-A C -- /_ 715 PTD# ./n,,-;> -/?{;,. ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) paOT (PH) "CLUE" The permit is for a new wellboresegment of existing well />./JC,( , C - 2. 7 fJ Permit No,/?6' -/37 API No. .so-o~j:¡-" 2.. 0 ~Y3 -D I Production should continue to be reported as a function' of the original API number, stated above. BOLE 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 Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ,to full compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. ~~~bc;,e:5BM!1;ç,~.,~,2~~t~t; Company __ap_EK~I.,QBAILQr~L(A.Lt\SJ~A1JNÇ__._.._____..,____, _____._.._..._ Well Name: .PRUQliQEJ~.AY_UJ~JJI.._Ç~22EL_______ Program .QE..\l____..._..___ Well bore seg PTD#: 2031860 Field & Pool _E.RU.DJ:KtE..B8Y_..PRUQtLQE_QLL:....6A.015"O Initial Class/Type _[JEY.í1:..OLL_ GeoArea .8_9.0 Unit J__Hi5_0._ On/Off Shore .0.0._ Annular Disposal Administration 1 P~(mitfe~ attache.d. . ' . . _ . . _ _ . . . . . Yes 2 .Leas~ numb~r .approl:>riat~ Yes. 3 _U.ni.q\..le well. n.atn~ _ancj OUlTJb.er . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . ye$ . . . . . . . . . . . . . .. .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . [4 .W~II.lQcat~d i.n.a defineJ:! .pool. Yes. 15 _W~IIIQcat~d proper .di.stance. from dri.lling unit.b_ounda(y. . . . Yes. I 16 .W~II.lQcat~d proper J:!i.stance, from Qtb~r w~lIs_ . . . Yes 7S.ufficiel1t .acr~a9.e.a'Jail;:tble i,n,d,rilJiog unjt. , _ _ . . _ . . . .. . . . . . Yes. 8 .If.d~viatecj,is. wellbQre plat,incJu.ded . . . . . Y~s 9 .Qper.ator only affected party . _ _ _ _ . _ . _ Yes 1 0 .O-p~r.ator bas. appropriate. b,ond i.n JQrç~ .. . . . . . . _ _ . . .. . . . . . . . . _ . . . .. . . . _ _ _ . _ No _ _ _ _ _ _ . . . . . . . . . . _ _ . _ . _ . . . _ . . . . _ _ _ . . . . _ .. _ . . . . . . . . _ . . _ . . . . . . . . . . _ . . _ _ . . . . . . . . . 11 P~(mit. c.an be i.ssued wjtbQut co.ns~rva.tion order. . . . . . . _ . Yes . . . . . . . _ _ _ . _ _ _ _ _ . . . . _ _ . _ _ _ _ . . _ _ _ _ . _ . . _ . _ _ _ _ . Appr Date 12 P~(mit c,an Þe i.ssu,ed witlJQut ad_l11ilJist(ati\(e. approvaJ . . . , - _ - - - - - . . . - , . . - . . , - . . Y ~s _ . _ . . . . _ _ _ _ _ _ . . _ _ _ _ . . _ . _ _ . _ . . . . . _ . _ . _ , . . . . . . . . . . . . . . . . _ _ _ . RPC 11/5/2003 13 Can permit be approved before 15-daywait Yes 14 _W~IIJQcated within area and. strata .author~ed by.l[1jectioo Ord~( # (putlO# in.c.o01m~nts).(For. NA , . . . _ . . . . . . . . . . . . . .. . _ _ _ . . . . _ _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . _ _ _ _ . 15 .AJI w~l]s.WitJ1i.n_1l4..l1Jil.e_ar~a_of (eyi~w id~(ltified (F.o(~ervj~_w.etl onl~>- _ _ . _ _ . . _ . .. . . . _ .NA _ _ _ _ . _ . . . _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ . . . . . . . . . . . . _ _ .. _ .. . _ _ .. .. . _ _ _ _ _ .. .. . .. _ _ _ _ . . . . . 16 PJ~-procju.cedinjeçtor; J:!ur;:ttio.n.ofpr~-proJ:!uGtiOIJI~$$.ttlan.3montbs.(For.s~r:.vi.cewellonJy). _ NA_... _ _ _ _... _... _" _ _ _........... _... _...... _ _........ _.............. _..... _ _ _. 17 .ACMP.finding.ofCQn.si.stenGy.h.as Þee.nJ$.sued.forJbi$ pr.oiect . . . . . . . . . . . . . . . . . . . NA _ _ . _ . . _ _ . _ . . . . . . . . . . . . . . . . . " . . . . . . _ . _ _ _ _ _ . . . . _ . . . . . _ . . . . . . . . . . . . . . . _ . . . . . . . 18 .C_O(lcju.ctor $t(in.g.PJQv¡d~d . . _ . . . . . . . _ . . _ . . . . . . . . _ _ . . _ . . _ . . _ . . . . . . . . .NA . . . . . . . . . . . . . , . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . _ _ . . . . . . _ _ _ . . . . . _ . . 19 .S.udac~.ca~ing.PJotec.t$. alLknown. USDWs _ . _ . . . . _ . . . . . . . . _ . . . . . _ . . . . . . . _ .NA . _ . . _ . _ _ . _ _ _ . . . . . . . . . . . . . . . , _ . . ." . _ _ _ _ _ . . . . . . _ . . . . . . . . . . . . . . . . . . . . _ . . . . 20 .CMT.v.ol.é!d~quate,to circ.ul.ate.o.n.cond_uçtor.& SUJtc.sg . . . . _ . . _ _ _ , . _ . . _ _ . . . . . . . NA . _ . . , . .. . . . . . . . . . . . . . . . _ _ _ . _ _ . . . . _ . . . _ . . . . . . . . . . . . . . . _ . _ _ . . . . _ _ _ . _ _ . . . _ . _ _ _ 21 .CMT. v.ol. ad~q u.ate. to tie-i.n .long .string to .S!,J d c~g. . . . . . . . . _ . . _ _ .. . .. . . . . . . . . . . . .NA . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . .. . _ . . . . _ _ . . _ . . . . . . . 22 .CMT. will coyer .aJl .klJown .pro.ductiye bori~on_s. . . _ . . _ . . . . . . . . . . . . _ . . . . _ . _ . _ . Y ~$ . .. _ . . .. . _ . . . . . . . .. _ . . . . . . . _ . _ . . . " _ . . . . . . " . . . _ . .. . . _ _ _ _ . . . . . . . . . . . . . . . . _ _ . . . 23 "C.asi[1g d~sig[ls adequate. f.or C,.T., B.&.p-erl1Jafr.ost . . . _ _ " ' , . " . . . . . . . . . . . . . Yßs. . _ _ _ . _ _ . _ . _ _ _ _ . . . . . . . . . . ., , . . . . . . . . , " _ _ _ . _ . _ _ . . . . . " , " . . . _ _ . _ . _ . . _ _ . . . . . 24 Adequpte.tan.kage.oJ re_serve pit. . . . . . . _ _ . . _ . . . . . . , . . . . . . , . _ . . . . . . . . . YßS _ . _ _ _ _ . CTDU.. _ _ . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . _ . . . . _ . _ . . . . . . . . . . . . . _ . _ . . . . . . , . 25 Jf.a.re-J:!riltl.1as.a.tO::-403fo.rpbé!ndon.l11entbe~(lapPJov~d. _. _, ..".....,...... .N.o....... _40.3.p~oding.ilJfofromßP,.........". _... _ _............".. _....... _ _......, _ _. 26 _AJ:!equpte"we!lbor~ ~ep~lraijo.n.pro'po~e~ _ _ _ _ _ _ _ _ _ " . . . . . _ . . _ _ _ _ _ _ _ _ _ .. _ . . . _ _Yß$ . _ . . _ .. . _ . . . _ . _ . _ _ . . " _ .. .. . . _ . _ .. .. _ _ _ .. _ _ _ . . . . . . . . _ " . _ _ _ _ _ _ . . . . _ . . _ _ . . _ _ _ _ _ _ _ . . _ 27 Jf.djvßrte.r Je.q.uired, dQe.s jt .meßt rßguJatiol1s_ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ . " . . . " . . . . . . . . .NA . . . _ _ " . Sidetrack. _ " _ . . . _ " . . . .. .".. _ . " _ _ _ _ _ _ _ _ . _ " _ . _ _ _ _ " _ . . . . . . . . . . . " " _ . . _ . . . . . Appr Date 28 .DJillio9 flujd.p-rogram sc.hematic_& eq_uipJist.adequate. _ . . . . , " _ _ _ . . _ _ _ . _ . . . . . , . .Y~s . . . . . . . Max MW.8J, ppg, . . . . _ . . . . _ . . _ " _ . _ . . . . . . . . . . . . . . .. . _ " . _ . . . . . . . . . . _ _ _ _ _ _ _ . . . WGA 11/5/2003 29 _BOPEs.. d.o .they .me~l reguJation _ . . . . . . . . . . . . . . . _ _ " _ " . . _ . _ . _ . . . . . . . . . .Y ß$ . . . _ . . . . . . . _ . . . . . . . _ . . . . . . . " . . . . . . . _ _ _ _ . _ . . . . . . . . _ . . . _ . . . _ . _ . . _ . . . . , . . " _ " . _ 30 _BOPE.pr~ss ratiog appropriate;"te.stto.(put psig in_comlJlents). _ _ _ _ _ _ _ _ _ _ " . . . . . . . . .Yß$. " . _ " " . T~stto.3500.psi. .MS~ 21.94 psi.. . . _ _ _ _ . _ _ _ _ " . _ _ . . . _ _ . . . . _ . _ _ _ " _ . . . . . . . . . _ _ _ _ _ _ _ _ 31 .C.hoke.l1Janifold cOITJPJie$. w/API. RP-53 (May 84>. _ . . _ . . . _ . . . . . . _ . . . _ . . . . . . . . .Yß$ . . _ . . . . . . . . . . _ . . . . . _ . . . . . . . . , . . . " . " . _ . . . . . . _ . . _ _ . . . . . _ " _ . . . . . . _ . . . . . . _ " " . . , 32 _WQrk will oCC.U( withoutoperation .sl.1utdown. . _ _ . . . . . . . _ . . _ . _ . _ . _ _ _ _ . . . . . . . .Yß$ . . . . . . , . . . . . . . . . . . _ . . . . . . . . .. . . " . " _ _ _ . . . . . . . " . . . . _ . _ _ . . . . . . . . . . . . . _ _ _ _ , . . , . 33 .Is presence. Qf H2S. gas_ probable. . . . . . . . . . _ _ _ . _ _ . _ _ . ., . .. . . . . . . . . . . . . . Yßs . . " . . . . 10. ppm. _ . . _ . . . _ . . . . . _ . . , . . . . . _ _ . . _ . . . . . . _ . . . . . . . " . . _ _ _ _ " _ _ _ _ " . . . . , . _ _ _ 34 Mecba.nical.cOlJdition.of W~II$ wi.thin AOB. verified (For_ s.ervic~ w~1J only). . . . . . . . . . . _ . . NA . _ _ _ . . _ . . _ . . _ . _ _ . _ . . . . . . . . . . . . . . . . . . . . _ . . . " . _ . . . _ . . . . , . . " _ _ . . . . . . . . . . . . _ , " . 35 .Pßrmit c.a(l Þe i.ssueçlw/Q hydr:.ogen. s.ulfide lJleas.!J(e§) _ . " . . . , . , . . . _ . . . . . . . , " _ _ _ .N.o _ " _ . " , . . . . . . . , . . . _ " . _ " . _ _ _ " _ . _ . _ _ _ . " . . . . . . . . " _ _ " . _ _ _ . . . . . . . . . . . " . . . . . . . . . . _ _ 36 .D.ata.PJe.s~lJteQ on. pote.ntial oveJPre$.surß .zOl1e.s. _ . . . . . . . . , . . _ . _ . _ _ . . _ . _ . . .NA . _ . , . " . . . . . . . . . . . . . " . . _ . . .. _ _ _ " . . . . . . . . . . . . . " .. . . . . . . .. . . _ . _ _ . . . . . . . . Appr Date 37 .S~islJlic.analysjs_ of shallow gas.z.ooe.s. . . . . _ _ . . . " _ . . '" ".".."..... _ . . . _ .NA . _ . " _ . _ . " _ " _ _ . . . . . . . . . . . . . ., . . . . . " . . " _ . . " . _ . _ _ _ . . . . " _ " . _ _ . . . ., . . . . " . RPC 11/5/2003 38 .SßabeJ:! .conditiolJ survey .(if Qff-~h.o(e) . " _ . .. _ . . . . . . . " . _ . . , _ . . _ _ _ _ . . . . . . . . .NA. ' . . . " . . . . . . . . . . . . . .. _ . . . . _ _ . . _ . . . , . . . . . . . . . . . . " " . . . . . . . . " . _ . . . . . . . . . , . " 39 . CQnta_ct nam.elphon.e.for.weß~ly progres.s.reports [exploratory .only]. . . . _ . _ . . . _ ... _ " .NA . " . . . .. . . . . . . . . _ . . . . . .. . " . . . " . . " . . _ . . . . . " . . . . . . . . . . " . . . . . . . . . . . . . . . _ . . _ . . , " . " Engineering Geology Geologic Commissioner: Jjþ ~ [] - - - - - - - - - - - - - . - - - - ~ - ~ - . - (' ( Date: Engineering Commissioner: ~ Public Commissioner Date 1/ I S'/0 Date ~ ~~ ) ) Welll-Jistory File APPENDIX Inforrnation ot detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomìation, information of this nature is accumulated at the end of the tHe 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 $ Tue Aug 03 15:12:09 2004 ) ;Zo3-lgc;, /2.Cø t5 Reel Header Service name........... ..LISTPE Oa t e . . . . . . . . . . . . . . . . . . . . . 04/08/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel. Name................UNKNOWN Continuation Number......01 Previous Reel. Name.......UNKNOWN Comments. . .. . . . . . . . .. . . . .31'S LIS Wri.ting L.ibrary. Sci.entific Technical Services Tape HeadeJ:: Service name.............LISTPE Date. .. . ... . . .. . .. .. . . . . . 04/08/0:3 Origin. . .. . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Nurn.ber...... 01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical Eor Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERA.TOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002801044 S. LA'I'Z KOLSTAD/SARB ,JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002801044 S. LA'rZ KOLSTAD/SARB ,JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD F\UN 7 MW0002801044 S. LATZ KOLSTAD/SARB # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) !I WELL CASING RECORD C-27B 500292084302 BF Exploration (Alaska), Inc. Sperry-Sun Drilling Services 03-AUG-04 MWD RUN 2 MW000280l044 S. LATZ KOLSTAD/SARB MWD RUN 3 MW0002801044 S. LATZ KOLSTl\D/ SARB MWD RUN 5 MW0002801044 S. LA'I'Z KOLSTAD/SARB MWD RUN 6 MW0002801044 S. LATZ KOLSTAD/SARB MAD RUN 7 MW0002801044 S. LA'I'Z KOLSTAD/SARB 19 llN 14E 17 55 1033 72 _ 34 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ) ) 1ST STRING 2ND S~[,RING 3RD STRING PRODUCTION STRING 4.125 4.500 10518.0 # REMARKS: 1. ].I"LL DEP'THS ¡!"'RE Bn DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEP'l'H - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FEOM ]!.,. WI-IIPSTOGK IN THE C-27A WELLBORE.THE TOP OF THE WHIPSTOCK WAS AT 105181MD AND 'rim BOTTOM WAS AT 10525 'MD. 4. MWD RUNS 1 - 5 COMPRISED DIREC'nONAL AND DUAL GAMMA EAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. TIE-IN SGEC DATA WERE ACQUIRED AFTER MWD RUNS 1 AND 2. THESE MAD PASS DATA WERE MERGED WITH MWD DATA FROM RUN 1- DUE TO A TOOl, MALFUNCTION NO USABIÆ SGRC DATA WERE ACQUIRED DURING RUN 5. 5. MWD RUNS 6 & 7 COMPRISED DIRECTIONAL WITH GM AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS SGRC DATA WERE ACQUIRED OVER THE RUN 5 INTERVAl, PRIOR TO DRILI,ING RUN 6 AND WERE MEHGED WITH RUN 6 MWD DATI!"'. A FINAL MAD PASS WAS RUN OVER THE INTERVAL 1l231'MD - 11947'MD (BIT DEPTHS) AFTER REACHING TO. A SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG PROVIDED BY K. COONEY (SIS/BP) ON 30 JULY 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1. - 7 .REPRESENT WE,LL C-27B WITH APU: 50-029-20843-02. '1'HIS WELL REACHED A TOTAL DEPTH (TO) OF 11947'MD/8952'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAM.MA 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. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ file Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation..... ..04/08/03 Maximum Physical Record..65535 File Type............... .LO Previous file Name.......STSLIB.OOO Comment Record FI LE HEADER fILE NUMBER: 1 EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FI LE SUMMARY PBU TOOL CODE GR RPS RPX RPM FET RPD ROP ¢ .;> ') ) clipped curves; all bit runs merged. .5000 START DEPTH 10458.5 10533.0 10533.0 10533.0 10533.0 10533.0 10536.0 STOP DEPTH 11902.5 11916.0 11916.0 11916.0 11916.0 11916.0 11947.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA. (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10458.5 10460.0 10462.0 10478.0 10482.0 10485.5 10490.0 10498.0 10500.0 10505.5 10509.5 10514.0 10518.0 10522.5 10525.0 10527.5 10533.0 10547.5 10551.0 10554.5 10561.0 10564.5 10567.5 10573.0 10580.5 10588.5 10592.0 10598.5 10613.5 10617.5 10632.0 10643.0 10649.5 10655.0 10669.0 10676.5 10695.0 10698.0 10716.0 10721.0 10732.5 10743.0 10746.0 10755.5 10760.0 10761.5 10778.0 10787.5 10798.5 10801. 0 10803.0 10809.5 10828.5 10835.5 10861.5 10864.5 GR 10459.0 10460.5 10462.0 10479.0 10482.5 10485.0 10489.0 10495.0 10497.5 10504.0 10508.5 10514.5 10516.5 10523.0 10524.5 10526.5 10531. 5 10546.5 10549.5 10555.0 10559.0 10562.5 10566.0 lOS'll. 5 10580.0 10586.5 10589.5 10596.5 10611. 5 10616.0 10631.0 10641. 5 10649.0 10656.0 10668.0 10673.5 10693.0 10695.5 10714.5 10721.0 10730.0 10740.5 10744.5 10752.5 10756.5 10758.5 10774.0 10785.0 10798.0 10799.5 10801.5 10809.5 10829.5 10836.0 10863.0 10865.0 10870.0 10873.5 10881.0 10889.5 10896.0 10901. 0 10907.0 10929.5 10948.5 10961.5 10974.5 11003.5 11006.0 11017.0 11023.5 11060.5 11077.5 11094.0 11097.0 11106.0 11120.0 11122.0 11135.5 11138.5 11147.0 11156.5 11195.5 11207.5 11223.0 11226 _ 0 11229.0 11237.0 11258.5 11277.0 11309.0 11335.0 11340.5 11375.0 11401.5 11424.0 11440.5 11459.5 11465.5 11473.5 11483.0 11490.0 11502.0 11524.0 11571.5 11589.5 11599.0 11639.5 11657.0 11660.5 11679.5 11694.0 11735.5 11759.0 11790.5 11801.5 11804.5 11827.0 11833.5 11848.5 11869.0 11881.5 11891.0 11894.0 11947.5 $ II MERGED DATA SOURCE PBU TOOL CODE M~'i)D MWD ') 10870.5 10872.5 10881.5 10888.5 10894.5 10901. 0 10906.5 10930.5 10949.5 10963.5 10975.0 11005.0 11008.5 11018.0 11023.5 11061.5 11078.5 11095.5 11098.5 11107.0 11121.0 11122.5 11136.0 11138.0 11148.0 11158.0 11197.0 11208.0 11223.0 11226.5 11229.0 11238.5 11259.5 11278.0 11308.5 11335.5 11342.0 11374.5 11401.5 11423.0 11437.5 11456.0 11461.0 11471.0 11478.0 11485.0 11498.0 11521.5 11569.5 11586.5 11594.5 11635.0 11652.5 11656.0 11675.0 11688.5 11733.0 11758.0 11787.0 11797.0 11801. 5 11825.0 11832.0 11848.0 11866.5 11880.0 11890.0 11893.5 11947.0 BIT RUN NO 1 2 MERGE TOP 10459.0 10545.0 MERGE BASE 10545.0 10555.0 ) ) MWD MWD MWD MWD MWD $ 3 4 5 6 7 10555.0 10932.0 11113.5 11447.5 11464.0 10932.0 11113.0 11447.5 11464.0 11947.0 # REMARKS: MERGED MAIN PASS. $ 'if Data Format Specification Record Data Record Type.................. 0 Data Speci ficat10n Block 'I'ype..... 0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specificat10n Block sub-typ(~... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 1. 6B 0 1 ROP MWD F'I'/H 1 68 4 2 GR MWD API 1 68 8 3 RPX MWD OHMM <1 1 68 12 <1 RPS MWD OHM.M 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Se,rv.ice Unit Mi,n Max Mean Nsam Reading Reading DEPT FT 10458.5 11947.5 11203 2979 10458.5 11947.5 ROP MWD F'l' / H 0.03 867.69 75.1759 2824 10536 11947.5 GR MWD API 14.25 483.64 46.4494 2889 10458.5 11902.5 RPX MWD OHMM 0.36 69.41 15.5913 2767 10533 11916 RPS MWD OHMM O. 2 t~ l(H . 34 23.3142 2767 10533 11916 RPM MWD OHMM 0.24 323.65 30.8658 2767 10533 11916 RPD MWD OHMM 0.58 2000 63.5489 2767 10533 11916 F.E.T MWD HOUR 0.13 76.33 22.6629 2767 10533 11916 First Read.ing For Entire File......... .10458.5 Last Reading For Entire File. ....... ...11947.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/08/03 Maximum Physical Record..65535 File Type................ LO Next File Name....... ....STSLIB.002 Physical EOF File I-¡eader Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.... ...04/08/03 Maximum Physical Record..65535 File Type................ LO Previous file Name.......STSLIB.OOl Comment Record FI LE HEADE.R FILE NUMBER: - ) ") EDITED MER.GED MAD Depth shifted and DEPTI-I INCHEMENT: # FILE SUMMARY PBU TOOL CODE GR HPS FET RPM RPX RPD RAT $ cl:i.pped curves; all MJ.\D runs meJ.:'ged using earliest passes. .5000 START DEPTH 11193.0 11202.0 11202.0 11202.0 11202.0 11202.0 11233.0 STOP DEPTH 11901. 0 11915.0 11915.0 11915.0 11915.0 11913.5 11945.0 if MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE T'OP 7 1 11194.5 MERGE BASE 11947.0 # REMARKS: MERGED MAD PASS. .$ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction........ ...... ...Down Optical log depth units...........Feet Data Reference Point... ... '" ... ..Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order' Units Si.ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT!H 4 1 68 4 2 GR MAD API 4 1 68 8 3 rzpx MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 EPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 F.i.rst Las't Name Service Unit Min Max Mean Nsam Reading Read:Lng DEPT FT 11193 11945 11569 1505 11193 11945 EAT MAD FT!H 237 944 910.051 1425 11233 11945 GR MAD API 7.69 113.5 32.0505 1417 11193 11901 RPX MAD OI-IMM 3.94 23.83 10.5911 1427 11202 11915 RPS MAD OHMM 5.63 25.95 12.8011 1427 11202 11915 RPM MAD OHMM 6.53 27.6 14.4323 1427 11202 11915 RPD MAD OHMM 8.93 37.52 17 .2121 1424 11202 11913.5 FET MAD HOUR 2.82 35.61 15.7571 1427 11202 11915 First Reading For Entire File..........11193 Last Reading For Entire File...........11945 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04!08!03 Maximum Physical Record..65535 File Type.... ............LO Next file Name... ...... ..STSLIB.003 Physical EOt' ") File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HE.ADEH FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEP'l'l-I INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ') header data for each bit run in separate files. 1 .5000 START DEPTH 10459.0 10534.5 S1:'OP DEPTH 10516.5 10545.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SUEFACE SOFTTrifARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-'I'IM£:): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (E'T): BIT ROTATING SPEED (RPM): HOLE INCLINA'rION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING ('rOp TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHl,ORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Ty~e.....O LoggÙ1g Direction................. Down 04-DEC-03 Insite 4.3 Memory 10545.0 10534.0 10545.0 .0 .0 TOOL NUMBER 72829 4.125 10518.0 Flo Pro 8.60 65.0 9.0 22000 9.6 .000 .000 .000 .000 .0 127.0 .0 .0 .0 .0 # LOG HEADER DATA DATE LOGGED: SOfTWARE SURfACE SOfTWARE VERSION: DOWNHOLE SOfTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (fT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: Insite 4.3 Memory 10555.0 10545.0 10555.0 04-DEC-03 STOP DEPTH 10527.0 10555.0 START DEPTH 10517.0 10545.5 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: IJE,PTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ header data for each bit run in separate files. 2 .5000 File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation...... .04/08/03 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..8'1'8LIB.003 I?hysical EOr File Trailer Service name.............STSLIB.003 Service Sub Level Name... Versj"on Number...........1. 0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 Fi 1 e 'I'ype................ LO Next File Name...........STSLIB.004 first Reading for Entire File..........10459 Last Reading For Entire File...........l0545 First IJast Name Service Unit Min Max Mean Nsa.!11 Reading Readinq DEPT FT 10459 10545 10502 173 10459 10545 ROP MWD010 FT/H 0.09 23.16 7.16818 22 10534.5 10545 GR MWDOI0 API 32.97 17 4.09 66.6b9 116 10459 10516.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 ROP MWD010 F'T / H 4 1. 68 4 2 GR MWD010 API 4 1 68 8 3 Optical log depth units...........F'eet Data Reference Point............ ..Undefined ~rame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value...................... -999 Depth Units.. '" . . ... . . . ... . . . . . . . Datum Specification Block sub-type...O ~) ) ) # TOOL STRING (TOP TO BO'l"rOM) VENDOR TOOl., CODE 'TOOL 'TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): It BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERA.'TURE (DEGF) MUD AT MEl!.,SURED 'TEMPERATUl\E (MT): MUD AT MAX CIECUIJA1'ING TERMPERNrUl\E: MUD FILTRATE AT MT: MUD CAI<E: l~T MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOl,E CORRECT'ION (IN): # TOOL STANDOFF (IN): EWE FREQUF.,NCY (HZ): ti REMARKS: $ H 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 .lIN Max frames per record.............Undefined Absent, value...................... -999 Depth Units....................... Datum Specification Block sub-type...O TOOL NUMBER 72829 3.800 10518.0 Flo Pro 8.60 65.0 9.0 22000 9.6 .000 .000 .000 .000 Name Service Order UrLL ts 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 ) .0 131. 0 .0 .0 Fi.rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT F'T 10517 10555 10536 77 10517 10555 ROP MWD020 FT/H 0.14 47.34 10.698 20 10545.5 10555 GR MWD020 API 30.17 444.13 100.75 21 10517 10527 First Reading For Entire File..........10517 Last Reading For Entire File... ........10555 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 ) Physical EOF File Header Service name............. S'1'SLIB. 005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 file Type................ LO Previous File Name... ....S'1'SLIB.004 Comment Record .FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DE PTH I NCREMEN'I' : H FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 ) header data for each bit run in separate files. 3 .5000 S'TART DEPTH 10527.:) 10555.5 STOP DEP'I'H 10903.5 10932.0 11 V,')G HEADER DATA DATE LOGGED: SOFTWAIŒ SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG IN'TERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ BOREHOLE AND CJ\SING DNrJ\ 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 eMT): MUD AT MAX CIRCULATING TERM PERATURE: 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 OS-DEC-03 Insite 4.3 Memory 10932.0 10555.0 10932.0 27.0 50.4 TOOL NUMBER 72829 4.125 10518.0 FIo Pro 8.60 65.0 8.5 21000 6.4 .000 .000 .000 .000 _ 0 131.0 .0 .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...O Name Service Order Units Size Nsam R('~p Code Offset Channel DE P'I' F'1' 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 F:Lrst I"ast Name Serv.i.ce Un:Lt MJn Max Mean Nsam Reading ReadJng DEPT F'I' 10527.5 10932 10729.8 810 10527.5 10932 ROP MWD030 F'I'/ H 0.19 101. 07 34.7951 754 10555.5 10932 GR MWD030 API 17.94 4B3.64 76.6159 753 10527.5 10903.5 First Reading For Entire File..........l0527.5 Last Reading For Entire File...........l0932 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.006 Phys:Lca.l EOr File I-leader Service name.............STSLIB.006 Service Sub Level Name... Ve r s ion Numb e r. . . . . . . . . . . 1. 0 . 0 Date of Generation.......04/08/03 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: ~ FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 4 .5000 START DEPTH 10904.0 10932.5 STOP DEPTH 11085.:ì 11113.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE, SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 06-DEC-03 Insite 4.3 !V1emory 11110.0 10932.0 11110.0 19.3 ) MAXIMUM ANGLE: if TOOL STJUNG (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ if BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): if 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 TEMPERATlŒ.E (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FIL'1'Rl\TE 1\'1' M'1': MUD CAKE AT MT: if NEUTRON 'rOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STJ\NDOFF (IN): EWR FREQUENCY (HZ): if REMARKS: $ if 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 33.9 TOOL NUMBER 93091. 4.125 10518.0 Fl0 Pro 8.70 65.0 8.5 22000 6.0 .000 .000 .000 .000 .0 138.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 ROP MWD040 F'T/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsarn Reading Reading DEPT FT 10904 11113 11008.5 419 10904 11113 ROP MWD040 FT/H 0.03 52.39 15.5131 362 10932.5 11113 GR MWD040 API 14.25 42.74 23.6518 364 10904 11085.5 First Reading For Entire File..........l0904 Last Reading For Entire File...........l11l3 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 Fi 1 e Type................ 1.,0 Next File Name..... ......3T3LIB.007 ') Physical EOF File Header Service name............. S'rSLIB. 007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 File Type................ 1JO Previous File Name.. .....STSLIB.006 Comment Record FILE HEADER FILE NUMBER: I'\AW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: II- FILE SUMMARY VENDOR TOOL CODE ROP $ 7 ') header data for each bit run in separate files. 5 .5000 START DEPTH 11113.5 STOP DEPTH 11447.5 II- LOG HEADER DATA DATE I,OGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME:): TD DRILLER (F'I'): TOP LOG INTERVAL (1:'T): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM I\NGl.E: TOOL STRING (TOP TO BOTTOM) VENDOR '1'OOL CODE '1'OOL 'PYPE 8M Dual GR $ jt BOREHOLE ]~ND CASING DI-".'I'A OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): II- 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: If NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): II- TOOL STANDOFF (IN): EWR FREQUENCY (HZ): II- RE!'lARKS : .;:> II- Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O 06-DEC-03 Insite 4.3 Memory 11440.0 11110.0 11440.0 41. 0 90.0 TOOL NUMBER 93091 4.125 10518.0 Flo Pro 8.80 93.0 8.5 22000 5.6 .000 .000 .000 .000 .0 141.0 .0 .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...O Name Servj"ce Order Units Size Nsam Rap Code Offset Channel DEP'T FT 1 68 0 1. ROP MWD050 FT/H 1 68 4 2 Fi"rst Last Name Service Unit Min Max Mean Nsam Read:Lng Reading DEPT FT 11113.5 11447.5 11280.5 669 11113.5 11447.5 ROP MWD050 FT/H 1. 04 867.69 90.8112 669 11113.5 11447.5 First Reading For Entire File..........11113.5 Last Reading For Entire File........ ...11447.5 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.008 Physical EOt' File Header Service name.............STSLIB.008 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/08/03 Maximum Physical Record..65535 Fjl~; Type................ LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: P..AW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD RPS RPX PET GR ROP $ 8 header data for each bit run in separate files. 6 .5000 START DEPTH 10531.5 10531.5 10531.5 10531.5 10531.5 11086.0 11448.0 STOP DEPTH 11432.0 11432.0 11432.0 11432.0 11432.0 11417.5 11464.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAl, (FT): 07-DEC-03 Insite 4.3 Memory 11464.0 11440.0 11464.0 ) BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. 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 l,OSS (C3): RESISTIVITY (OHMM) A'I' TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRA'fE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSI'rY: 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 93.3 93.3 TOOL NUMBER 78012 178425 3.750 10518.0 Flo Pro 8.60 65.0 8.5 21000 5.6 .150 .090 .140 .210 85.0 141.0 85.0 85.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OI-IMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Mi.n Max Mean Nsam Reading Reading DEPT FT 10531.5 11464 10997.8 1866 10531.5 11464 ROP MWD060 FT/H 2.41 127.27 105.829 33 11448 11464 GR MWD060 API 16.04 209.06 37.2057 664 11 086 11417.5 RPX MWD060 OHMM 0.36 69.41 17.5119 1802 10531.5 11432 RPS MW0060 OHMM 0.28 101. 34 28.5554 1802 10531.5 11432 RI?M MW0060 OHMM 0.24 323.65 39.6475 1802 10531.5 11432 RPO MWD060 o Hf"1M 0.58 2000 90.655 1802 10531. 5 11432 FET MítiJD060 HOUR 7.94 76.33 34.210-/ 1802 10531. 5 11432 ) First Reading For Entire File.... ......10531.5 Last Reading For Entire File...........11464 File Tra:Ller Service name.............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 Fj.l e 'l'ype............... .LO Next File Name........ ...STSLIB.009 Physical EOF nle Header Service name.............STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/08/03 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 9 ) header data for each bit run in separate files. '7 .5000 START DEPTH 11418.0 11432.5 11432.5 11432.5 11432.5 11432.5 11464.5 # LOG HEADER DAT.A DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ STOP DEPTH 11902.0 11915.5 11915.5 11915.5 11915.5 11915.5 11947.0 BOTTOM) TOOL TYPE Dual GR 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 (8): MUD PH: MUD CHLORIDES (PPM): 08-DEC-03 Insite 4.3 Memory 11947.0 11464.0 11947.0 87.7 94.6 TOOL NUMBER 78012 178425 3.750 10518.0 Flo Pro 8.60 65.0 9.0 22000 ) ) FLUID LOSS (C3): RESISTIVITY (OHMM) A1' TEMPERATURE (DEGE') MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FH,TRATE AT MT: MUD CAKE AT MT: 12.8 .150 .090 .140 .210 85.0 141.0 85.0 85.0 # 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.....O Logging Direction............. ....Down Optical log depth units...........Feet Data Reference Point.......... ....Undefined Frame Spacing.....................60 .1IN Max fr.ames per record.............Undefined Ab s en t val u e . . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units....................... Datum Specifi,cation Block sub-type... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT F'I' 4 1 68 0 1 ROP MWD070 FT/I-! 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FE.T MWD070 HOUR 4 1 68 28 8 First Last Name Service Uni.t Min Max Mean Nsam Reading Reading DEPT FT 11418 11947 11682.5 1059 11418 11947 ROP MWD070 FT/H 3.09 199.67 119.191 966 11464.5 11947 GR MWD070 API 17 . 97 79.71 33.0335 969 1l4H~ 11902 RPX MWD070 OHMM 5.16 32.33 11.8999 967 11432.5 11915.5 RPS MWD070 OHMM 6.33 30.28 13.6486 967 11432.5 11915.5 RPM MWD070 OHMM 6.98 31.32 14.897 967 11432.5 11915.5 RPD MWD070 OI-IMM 9.6 41.34 17.2967 967 11432.5 11915.5 FET MWD070 HOUR 0.13 18.72 1.23455 967 11432.5 11915.5 first Reading for Entire File..........11418 Last Reading For Entire File...........11947 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 File Type................ LO Next File Name. ..........STSLIB.010 Physical EOF File Header Service name.............STSLIB.010 Service Sub Level Name... Version Number....... ....1.0.0 ) Date of Generation.......04/08/03 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: it FILE SUMMARY VENDOR TOOL CODE GR FET RPD EPM RPS RPX RAT ,$ 10 ) header data for each pass of each run in separate files. .5000 7 1 START DEPTH 11194.5 11203 _ 0 11203.0 11203.0 11203.0 11203.0 11233.5 it LOG HEADEE DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 'TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (F'I'): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM }\NGLE: MAXIMUM ANGLE: it s'1'op DE PTH 11900.5 11914.5 11913.0 11914.5 11914.5 11914.5 11944.5 TOOL STrUNG (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR EWR4 ELECTROMAG. RESIS. 4 $ it BOREHOLE AND CASING DAT.A OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): EESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: 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 08-DEC-03 Insi -te 4.3 Memory 11947.0 11231.0 11947.0 87.7 94.6 '1'OOL NUMBER 78012 178425 4.125 10518.0 Flo Pro 8.60 65.0 9.0 22000 12.8 .150 .090 .140 .210 85.0 141.0 85.0 85.0 ') ) Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units...........Feet Data Reference Point.. .... ........Undefined Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Da"tum. Speci ficati.on Block sub-type... 0 Name Service Orde:[ Uni ts S:Lze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD071 FT/!-! 4 1 68 4 2 GR MADOn API 4 1 68 8 3 RPX MADO'71 OHMM 4 1 68 12 4 RPS MADOn OHMM 4 1 68 16 5 RPM MADOn OHMM 4 1 68 20 6 RPD MADOn OHMM 4 1 68 24 '7 FET MADOn HOUR 4 ], 68 28 8 First Las't Narne Service Unit Min Max Mean Nsarn Reading Reading DEPT FT 11194.5 11944.5 11569.5 1501 11194.5 11944.5 RAT MADOn FT/H 47 944 909.055 1423 11233.5 11944.5 GR MADOn API 7.69 113. ~) 32.106 1413 11194.5 11900.5 RPX MAD071 OHMM 3.94 23.83 10.6175 1424 11203 11914.5 RPS MAD071 OHMM 5.63 25.95 12.8392 1424 11203 11914.5 RPM MADOn OI-IMM 6.53 27.6 14.4793 1424 11203 11914.5 RPD MAD071 OHMM 8.93 37.52 17.2467 1421 11203 11913 FET MADOn HOUR 2.82 35.61 15.6123 1424 11203 11914.5 First Reading For Entire File..........l1194.5 Last Reading For Entire File.. .........11944.5 File Trailer 8ervice narne.............8T8LIB.010 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.......04/08/03 Maximum Physical Record..65535 File 'rype................ LO Next File Name...........STSLIB.011 Physical EOr Tape Trailer Service name...... .......LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 04 / 08/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......01 Next Tape Name..... ......UNKNOWN Comments........... ......3TS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............. LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/08/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................3TS LIS Writing Library. Scientific Technical Services Physical EOF ) ) Physical EOF End Of LIS File
