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204-019
e e 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. ~ 0 If- - [) L Cj- Well History File Identifier '. Organizing (done) o Two-sided ""1111111" 111111 RESCAN ~olor Items: o Greyscale Items: DI~TAL DATA . ~Diskettes, No. d- O Other, Norrype: o Poor Quality Originals: o Other: NOTES: BY: ~ Datefol40~ Date (p /6 /0 h cl. x 30 = (p 0 Date:~ I ~ / (J (¡; Project Proofing BY: ~ Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: 7' I, Page Count Matches Number in Scanning Preparation: Date: big 10 b If NO in stage 1, page(s) discrepancies were found: o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mp 151 111111111111111111I mr 151 + /5 = TOTAL PAGES 't-JÖ (Count does not include cover Jeet) IA Ii ï) 151 J V t r 1111111111111111111 (Count does include cover sheet) V YES BY: ~ Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: NO YES 151 Mf NO 151 1111111111111111111 IIIIIIIIIIII~ 11111 151 Quality Checked 111111111I111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended 2oAACZS.~os 2oAACZS.»o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions.. Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., Aban ": 6/20/2010 12. Permit to Drill Number: 204-019 310-099 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 4/22/2004 13. API Number: 50-029-22485-02-00 4a. Location of Well (Governmental Section): Surface: ' 7. Date T.D. Reached: 5/3/2004 14. Well Name and Number: PBU 15-376 FWL, SEC. 22, T11 N, R14E, UM 1446' FNL, 858 Top of Productive Horizon: 3429' FSL, 3047' FWL, SEC. 15, T11 N, R14E, UM g, KB (ft above MSL): 59.5 GL (ft above MSL): 31' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2853' FSL, 4609' FWL, SEC. 15, T11N, R14E, UM 9. Plug Back Depth (MD+TVD): 11350' 8795' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676796 y- 5960056 Zone- ASP4 10. Total Depth (MD+ND): 12471' 8780' 16. Property Designation: ADL 028306 TPI: x- 678860 y- 5964980 Zone- ASP4 Total Depth: x- 680436 Y- 5964442 Zone- ASP4 11 • SSSV Depth (MD+ND): N/A 17. Land Use Permit: ND f P f t Thi k 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL ros ): ness o erma ( c 20. 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 MDlfVD: 3881' 3559' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CiASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-4 rface 110' rface 11 0 sx Ar i et -/" 47# rf rf 1 -1/4" 7 x x PF' ' 7" 26# L-80 27' 101 27' 8242' 8-1/2" 3 9 sx s'G' 14 x Clas 'G' 4-1/2" 1 L-80 99 ' 12466' 4' 8780' -1/ " 9 sx Cla 'G' 24. Open to production or injection? ^ Yes ®No 25. TusiNG RECORD If Yes, IISt each Interval Open Si nd Number): & B P rf ti MD+ND f T tt SIZE DEPTH SET MD PACKER SET MD / ND om; ora on ze a ( o op o e 4-1/2", 12.6#, 13Cr80 10009' 9952' / 8040' MD TVD MD ND 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,~.,, ,~ , ~ , a~ ~ , ~~, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED d µ ) ~ ~ a!'+ws t° ~°` -' ~ " °` ° ~ ~ `' 11350' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewall Core(s) Acquired? ^ lY'es® No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and pG~"~I~~ 11Pi~:twu (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analyti 71 None ~~_~~<. ~ ~ ZQ~~ RBDMS JUL ~ 4 ~iaska 0~1 ~ Gas Caps. CMrlrnlss t~-ic~ra on Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 7-~ rl+, / v 5uomlt ungmal vnry 29. GEOLOGIC MARKERS (List all formations and ma ncountered): 30. NATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 10165' 8247' None Shublik A 10213' 8294' Shublik B 10242' 8322' Shublik C 10260' 8340' Sadlerochit 10282' 8362' 42SB 10362' 8440' 41S6 10409' 8485' Base CGL 10483' 8555' 22TS 10599' 8653' 21TS 10667' 8702' Zone 1 B 10790' 8767 Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ • ~~ 3~1 ~ Signed: Terrie Hubble Title: Drilling Technologist Date: PBU 15-376 204-019 310-099 Prepared By NameAVumber. Terrie Hubble, 5644628 Well Number Permit No. /Approval No. Drilling Engineer: Eli Vfizquez, 564-5918 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 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 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 permaftost 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 • • 15-37B, Well History (Pre Rig Sidetrack) Date Summary 4/5/2010 T/I/0=2250/0/160 temp=Sl MIT IA (Passed to 3000 psi/ MIT OA (Passed) to 2000 psi (Pre-CTD),. MIT IA pressured up to 3000 psi with 4.5 bbls crude. IA lost 100 psi in first 15 minutes and 40 psi in second 15 minutes, for a total of 140 psi in 30 minutes. Bled pressure down. MIT OA pressured up to 2000 psi with 1.4 bbls crude. OA lost 40 psi in first 15 minutes and 20 psi in second 15 minutes, for a total of 60 psi in 30 minutes. Bled pressure down. FWHP's=2250/0/280 4/29/2010 Pump 10 bbl's 50/50 meth, swap to 1% KCL W/safe tube, knock down WHP to -1000 psi, reduce rate & RIH W/ , 3.68" OD x 18.73' long Dmy whpstock drift. (OAL=31.86'). RIH was clean and tapped CIBP at 11 X868' ctmd_. PU and tagged again at same depth & POOH. OOH well left shut in and FP with 33 bbls of 50/50 Meth down to 2.,170'. RDMO. Job Complete. 5/26/2010 T/IA/OA= SSV/0/0 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (Pre CTD) PPPOT-T : RU 2 HP BT onto THA 100 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycle and torque LDS "ET style" all functioned with no problems. PPPOT-IC RU 2 HP bleed tools onto IC test void 0 psi, flush void until clean returns achieved. `~ Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycle and torque LDS "Standard" all moved with no problems. Page 1 of 1 • • North America -ALASKA - BP Page 1 of 3 Operation Summary Report __ Common Well Name: 15-37 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 6/16/2010 End Date: 6/18/2010 X3-OOVM8-C (540,233.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 6/6/1994 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'47.101"1 Long: 0148°34'05.850"W Active Datum: 15-37 @65.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 6/16/2010 05:00 - 06:30 1.50 MOB P PRE REMOVE T-MATS FROM AROUND WELL. PICK UP HERCULITE. CREW CHANGE. DISCUSS RIG MOVE OPERATIONS. MAKE RIG CHECKS AND EXTERNAL ROUNDS. -- 06:30 - 07:30 1.00 MOB P PRE CONTINUE TO CLEAN UP AROUND 15-07C ..WELLHEAD AREA. CALL FOR DSO TO INSPECT LOCATION. CONTINUE TO PREP AREA AROUND WELLHEAD ON 15-37C WELLHEAD. MOVE RIG OVER TO 15-37C ~ SPOT RIG IN FRON OF WELL. SET DOWN RIG ON MATS. 07:30 13:00 ~ 5.50 BOPSUR P PRE NU BOP COMPONENTS.. CHANGE SHORT STUDS ~ TO MEET TWO-THREAD CRITERIA AS PER j DISCUSSION:-WITH ADW MANAGEMENT. ~ NU BOP EQUIPMENT BACK UP. PU IN CELLAR. 13:00 - 14:00 1.00 MOB P PRE MOVE 121G OVER WELL HEAD. LEVEL AND SET DOWN ON MATS.\ _ ACCEPT RIG AT 1400 HRS ON 6-16-10_ 14:00 - 15:00 L00 MOB P PRE RU CELLAR AND EXTERNAL SUPPORT EQUIPMENT. SPOT FLOW BACK TANK, CUTTINGS BOX. BERM CELLAR. 15:00 - 18:00 ! 3.00 BOPSUB P - PRE NU BOPS IN CELLAR. 18:00 - 00:00 ~ 6.00 BOPSUB N RREP PRE CHANGEOUT STUDS ON CHOKE MANIFOLD TO COMPLY WITH BP REQUEST FOR TWO THREADSY VISIBLE ABOVE NUT. CONTINUED ON REPORT 06/17/2010 6/17/2010 00:00 - 06:00 6.00 BOPSUR N RREP PRE CONTINUED FROM REPORT 06/16/2010. CONTINUE REPLACING STUD BOLTS ON CHOKE MANIFOLD TO ENSURE TWO THREADS EXPOSED PAST NUT. 06:00 - 06:30 _ ~ 0.50 BOPSUR P i PRE CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG ROUNDS AND OUTSIDE WALK AROUNDS. DISCUSS PLAN FORWARD TO CONTINUE CHOKE MANIFOLD STUB REPLACEMENT TASK. 06:30 - 10:30 4.00 BOPSUR P PRE CONTINUE TO REPLACE STUDS ON CHOKE MANIFOLD AS PER BP RP. 10:30 - 12:30 2.0 B OPSUR P PRE _PERFORM_HIGH AND LOW PRESSURE ~HELL_, TEST ON BO_P_EQUIPMENT,INCLUDING KILL AND_ CHOKE LINES AND CHOKE._MANIFOLD, 250 PSI i AND 4000 PSI. HELD AND CHARTED FOR 30 ~__ MIN. PASSED. _ Printed 7/1/2010 11:26:09AM r1 North America - F,LASKA - BP Page 2 of 3 Operation Summary Report Common Well Name: 15-37 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 6/16/2010 End Date: 6/18/2010 X3-OOVM8-C (540,233.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 6/6/1994 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'47.101"1 Long: 0148°34'05.850"W _ Active Datum: 15-37 @65.7ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _____ 12:30 - 19:30 7.00 BOPSUR P _ PRE INTITIAL BOP TEST ON WELL 15-37C. TEST WITNESS WAIVED BY C. SCHEVE, AOGCC. TEST ~ ALL BOP AND RELATED EQUIPMENT AS PER AOGCC REGS, PERMIT TO DRILL, APPROVED WELL PLAN. ALL TESTS RECORDED ON CHART BY NORDIC, AND ELECTRONICALLY BY NORDIC AND SCHLUMBERGER. 19:30 - 20:30 1.00 RIGU P _ PRE PJSM FOR PULLING BPV. REQUESTED CERTIFICATION FOR LIFTING EQUIPMENT FOR THIS OPERATION -DISCOVER THAT THE BPV LUBRICATOR IS OUT OF CERTIFICATION FORITSTUBOSCOPE INSPECTION: SEND FOR CERTIFIED REPLACEMENT. ALSO, DISCOVER ONE BOLT ON BONNET OF WING VALVE THAT IS JUST FLUSH WITH NUT (NOT TWO THREADS PROUD). SEND FOR REPLACEMENT STUD. PJSM FOR PULLING COIL ACROSS WHILE WE WAIT FOR NEW BPV LUBRICATOR. 20:30 - 21:30 1.00 RIGU... P PRE PULL CT ACROSS. REMOVE GRAPPLE. 21:30 - 00:00 2.50 RIGU P PRE PULL BPV. SET TWC. TEST TREE TO 3500 PSI AND CHART (PASSED). REMEDIATE STUD BOLT ON WING VALVE BONNET. CONTINUED ON REPORT 06/18/2010. 6/18/2010 00:00 - 00:30 0.50 RIGU P PRE CONTINUED FROM REPORT 06/17/2010. FINISH PT TREE. PULL TWC. _ 00:30 - 01:30 1.00 I RIGU P _ ~ PRE FILL COIL W/ 48 BBLS KCL W/ SAFELUBE. TEST ELINE: > 2000, 52 OHM. CONTACT WELL INTEGRITY COORDINATOR REGARDING HISTORY OF POSSIBLE HYDRAULIC COMMUNICATION BETWEEN OA OF 15-37 AND ~ CELLAR OF EMPTY WELL SLOT NEXT DOOR. WELL INTEGRITY RECOMMENDS REPEAT MITOA TO CONFIRM NO COMMUNICATION EVIDENT. 01:30 - 03:00 1.50 RIGU P PRE INSTALL CTC. PULL TEST TO 40K LB (GOOD). 03:00 - 03:45 0.75 RIGU N RREP j PRE LOST RIG POWER UNTIL 03:45 -- ~ - 03:45 - 04:45 F 1.00 RIGU P PRE BEGIN REHEAD BH1. RU LRS TO OA TO MITOA. - -- 04:45 - 05:00 0.25 RIGU N DPRB PRE PJSM FOR OA PUMP TEST. 05:00 - 11:00 6.00 ~ RIGU N DPRB PRE PRESS OA TO 2000 PSI. SLOWLY BLED TO 1680 PSI IN 15 MIN. RE=PRESSURE TO 2000 PSI. OA BLED OFF TO 700 PSI IN 1 MIN. ESTABLISH INJECTION RATE OF 4.0 BPM AT ~ 1200 PSI. NOTE BUBBLES IN ODS CONDUCTER AREA IN ~ ADJACENT WELL. SMALL AMOUNT OF BUBBLES NOTES. BUBBLES WHERE NOT "HYDROCARBON" OR FLAMABLE ~'~f,,to e Printed 7/1/2010 11:26:09AM r ~ North America -ALASKA - BP ~ eye ~ ~` j Operation Summary Report __ _ ___ __ _-- _--- Common Well Name: 15-37 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 6/16/2010 End Date: 6/18/2010 X3-OOVM8-C (540,233.00 ) ~ _ __ _. Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 6/6/1994 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'47.101"1 Long: 0148°34'05.850"W Active Datum: 15-37 @65.7ft (above Mean Sea Level) Date ~ From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 13:00 2.00 RIGU _ N DPRB PRE WELLS GROUP AND WELL INTEGRITY GROUP IDENTIFY ADDITIONAL TESTING IS REQUIRED. DISCUSS MOVING TO 15-32c. ~ DISCUSS OA COMPLICATIONS AND OPTIONS ~ __ WITH CTD TEAM. ____ 13:00 14:00 _ 1.00 RIGU ~ N DPRB PRE HOLD PJSM AND THA WITH DHD CREW IN DOG HOUSE.. IDENTIFY RISKS AND MITIGATION. REVIEW _ PROCEDURE. _ 14:00 - 18:00 4.00 RIGU N DPRB PRE PRESSURE OA WITH NITROGEN AND SHOT FLUID LEVELS IN 1OO PSt INCREMENTS TO ATTEMPT TO DETERMINE DEPTH OF CASING --~ ------ ------ _ LEAK. 18:00 - 00:00 6.00 ~ RIGU N DPRB. PRE pR 1 0 P I F FVFI A'[,Sn' ; PRESSURED OA TO 1200 PSI W/ N2, OA FLUID LEVEL AT 42'. MITOA W/ N2 TO 1200 PSI PASSED, LOSING 10 ~ PSI tN THE FIRST 15 MINTUES AND 5 PSI IN THE SECOND 15 MINUTES FOR A TOTAL LOSS OF 15 PSI IN 30 MINUTES: NO BUBBLING OBSERVED IN NEIGHBORING CELLARS. BLEED OAP FROM 1200 PSI TO ZERO PSI IN 7 MINUTES, ALL GAS. WELL INTEGRITY REVIEWS THE RESULTS OF ~ THIS TEST AND GRANTS US THE GO-AHEAD TO ~ CONTINUE WITH SIDETRACK. RDMO DHD. PJSM WITH CREW REGARDING CONCLUSION OF DHD DIAGNOSTICS AND PLAN FORWARD FOR NOZZLE RUN. CONTINUED ON RON REPORT 06/19/2010 Printed 7/1/2010 11:26:09AM C~ • North America -ALASKA - BP Page 1 61Z$ Operation Summary Report ........................_ __ - _ _ _ __ Common Well Name: 15-37 DIMS ~ AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 6/19/2010 End Date: X3-OOVM8-C (1,516,534.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 6/6/1994 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'47.101"1 Long: 0148°34'05.850"W Active Datum: 15-37 @65.7ft (above Mean Sea Level) Date From - To j Hrs Task Code NPT NPT Depth Phase Description of Operations j (hr) (ft) 6/19/2010 __ _ 00:00 - 01:30 1.50 CLEAN P _ WEXIT CONTINUED FROM MOB REPORT 06/18/2010. IDENTIFY LEAK FROM OTIS QUICK UNION ABOVE ANNULUAR. UNSTAB AND REPLACE O-RING. TEST O-RING TO 250 PSI / 3500 PSI -PASSED. 01:30 - 05:30 4.00 CLEAN P WEXIT _RIH W/ NOZZLE ASSEMBLY. PARK AT 4000' MD AND CIRCULATE DIESEL FP ~ OUT OF HOLE WITH -60% RETURNS AT 1.59 BPM ATS75 PSI. CONTINUE RIH AT 100 FPM CIRCULATING AT 0.25 BPM AT 30 PSI WITH FULL RETURNS. ~ ~ RETURNS BEGIN TO TAPER OFF AT 9500' MD. BY 10400' MD, HAVE ZERO RETURNS. INCREASE PUMP RATE TO 0.6 BPM, STILL NO RETURNS. 04:30 -WEIGHT CHECK: 43000 LB AT 10400' MD. CONTINUE RIH AT 24000 LB RIH WEIGHT NOT PUMPING. b5:15 - RIH TO 11500' MD CLEAN. PUH TO - 11350' MD, UP WEIGHT 45000 LB PUMPING AT 0.3 BPM W/ NO RETURNS. PARKED AT 11350' MD, INCREASE RATE TO 1.5 BPM AT 710 PSI WITH 0.85 BPM RETURNS. INCREASE RATE TO 2.05 BPM AT 1250 PSI W/ j 1.38 BPM RETURNS. INCREASE RATE TO 2.5_ BPM AT 1840 PSI W/ 1.78 BPM RETURNS. DECREASE RATE TO 1 BPM AT 290 PSI W/ 0.25 BPM RETURNS AND BEGIN POOH. _____ 05:30 - 06:00 0.50 CLEAN _ P WEXIT PULL OUT OF HOLE CONTINUE TO TAKE RETURNE. WELL CONTINUES TO LOSE FLUID. ____ ___ 06:00 - 06:30 ____ 0.50 CLEAN P _ WEXIT CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG CHECKS AND EXTERNAL ROUNDS. _ CONTINUE TO POOH. _ _ _ _ _ 06:30 - 08:30 2.00 __ CLEAN ~ __ P WEXIT PULL OUT OF HOLE. ORDER ADDITIONAL FLUID. ____ 08:30 - 10:00 1.50 _ STWHIP P __ _ WEXIT AT SURFACE. GET OFF WELL. REMOVE NOZZLE BHA. MU BTT 3.625 X 4.5 MONOBORE WS WITH 45K8 ACKER. ! SCRIBE TO INTEQ TOOLS WITH HOT. STAB COIL. TEST TOOLS. GET ON WELL. ______ 10:00 - 14:00 ~ __ 4.00 STWHIP P ' _ WEXIT RUN IN HOLE. MONITOR HOLE FILL. 14:00 - 14:30 0.50 STWHIP P WEXIT LOG GR TIE IN FROM 10,900'. SUBTRACT 8.5' ~_ TIE IN. Printed 7/1/2010 11:26:52AM North America -ALASKA - BP Page 2 ~ Operation Summary Report __ __ __ __ Common Well Name: 15-37 DIMS AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 6/19/2010 End Date: X3-OOVM8-C (1,516,534.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 6/6/1994 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'47.101"1 Long: 0148°34'05.850"W Active Datum: 15-37 @65.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 15:00 0.50 STWHIP P _ WEXIT RIH TO SETTING DEPTH. 47.2K# UP WT. RIH TO PLACE TOP OF WHIPSTOCK AT 11,350'. ~ PRESSURE COIL TO 1850 PSI. WS CLOSE EDC. SET A LITTLE EARLY. &ET 5t<# DN WT TO VERIFY SET. 15:00 - 18:00 ___ __ 3.00 _ STWHIP P WEXIT HOLD. TRIP PJSM WITH DRILLER. CIRCULATE OUT OF HOLE. 18:00 - 19:40 ____ 1.67 _ STWHIP P WEXIT TAG UP, BLEED OFF. UNSTAB. INSPECT SETTING TOOL - IT IS FULLY STROKED, ~ INDICATING A GOOD SET. LD WHIPSTOCK SETTING ASSEMBLY. MU WINDOW MILLING ASSEMBLY WITH 3.80" MILL AND REAMER{MILLS ARE 3.80" GO / 3.79" NO-GO). 19:40 - 21:30 1.83 STWHIP P WEXIT RIH WITH MILLING ASSEMBLY. 21:30 - 22:30 1.00 STWHIP P WEXIT PARK COIL JUST ABOVE XN NIPPLE. CONTINUE TO CIRCULATE AT LOW RATE AND SLOWLY RECIPROCATE CT. I HOLD UNANNOUNCED RIG EVACUATION DRILL. MUSTER RIG PERSONNEL. I HOLD AAR TO REVIEW RIG EVACUATION DRILL. 22:30 - 00:00 i 1.50 STWHIP P WEXIT TAG XN NIPPLE AT 10015.5' DOWN, 10012.3' UP. UP WEIGHT IS CLEAN AT 42500 LB. ESTABLISH °- FREESPIN OF 2.61 BPM AT 2430 PSI W/ 2.27 BPM RETURNS. BHP/ECD/PVT: 4120 PSI / 9.04 PPG 33. TIME DRILL INTO XN NIPPLE FROM 10011' CTMD. ENGAGE AT 23:50 AT 10012.8' CTMD -SEE 60 ~ PSI INCREASE IN CIRC PRESSURE, NO WOB CHANGE. CONTINUE TIME DRILLING. IAP: 5 PSI OAP: 76 PSI I COTINUED ON REPORT 06/20/2010 Printed 7/1/2010 11:26:52AM North America -ALASKA - BP Page ~ ~a~A- Operation Summary Report __ Common Well Name: 15-37 DIMS AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 6/19/2010 End Date: X3-OOVM8-C (1,516,534.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 6/6/1994 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'47.101"1 Long: 0148°34'05.850"W Active Datum: 15-37 @65.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/20/2010 00:00 - 06:00 6.00 STWHIP P WEXIT CONTINUED FROM REPORT 06/19/2010 IAP: 5 PSI OAP: 76 PSI E_TIME MILLING THROUGH XN NIPPLE. MAINTAINING -2500 PSI CIRC PRESSURE AT 2.62 BPM W/ 2.41 BPM RETURNS. SEE -200 LB WOB INCREASE EACH TIME WE RIH 0.1 FT (EVERY SIX ~ MINUTES).. WOB WORKS OFF OVER EACH 6 MINUTE INTERVAL. HAVE ONE.. STALL AT 10014.2' CTMD WHILE TIMEbRILLING (-700 PSI OVER FREESPIN). SUSPECT WE HAD.A LITTLE SLIP/STICKING OCCURING IN THIS CHROME COMPLETION. i DOWN ON PUMP AND PU. RBIH MILLING, SEE MOTOR WORK SPIKE AT 10013.9' CTMD THAT i WORKS OFF AND ANOTHER AT 10014.2' CTMD THAT WORKS OFF. CONTINUE TIME MILLING I - AHEAD.. 03:30- PUH FROM 10014.5' CTMD. RIH THROUGH XN AT 2 FPM -SEE -300 PSI MOTOR WORK AT -10013' CTMD, OTHERWISE CLEAN. RIH AT 2 FPM TO 10025' CTMD. BACKREAM THROUGH XN, STALL AT 10012'. 04:45 - DRESS XN NIPPLE WITH SEVERAL SLOW RECIPROCATIONS UNTIL CLEAN BOTH DIRECTIONS. 05:45 -DRY DRIFT WINDOW UP AND DOWN, CLEAN. LOST COMMUNICATION WITH TOOLS I TEMPORARILY. RESTARTED TOOLS SEVERAL TIMES TO NO AVAIL. THEN, SUDDENLY ~ ~ REGAINED COMMUNICATION. CONTINUE RIH TO ___ TIE-I N. _ 1 06:00 - 06:30 0.50 STWHIP P WEXIT CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG CHECKS AND OUT SIDE ROUNDS. CONTINUE TO RIH TO TOP OF WHIPSTOCK. 06:30 - 10:15 3.75 STWHIP P WEXIT TAG WHIPSTOCK TOP AT 11,350.3. STALL AND OVER PULL DURING PICKUP. 45K# UP WT. COMPLETE DISPLACEMENT OF WELL TO GEOVIS. 2677 PSI FS AT 2.48 BPM IN/OUT. ~~}~.. i BEGIN TIME MILLING FROM 11,350.3' AT 0.1' PER /s~~~ I 6 MINUTES. NUMEROUS STALLS TRYING TO ESTABLISH A MILLING PATTERN. ______ MILL TO 11,350.5'. 10:15 - 13:00 2.75 STWHIP P WEXIT CONTINUE TO TRY TO MILL AHEAD. ~ CONTINUE TO STALL EVERY TIME WE TAG BTM. ESSENTIALLY LOSING GROUND. LOTS OF METAL ON MAGNETS. Printed 7/1/2010 11:26:52AM TREE= 4-1/16" MCEVOY r/VELLHEAD = FMC ACTUATOR= NA KB. ELEV = 65.7' BF. ELEV = 33.37 KOP = 3881' Max Angle = 97° _... _ @ 13761' Datum MD = 11523' Datum TVD = 8800' SS X15-37C SAFETY NO . 4-112"' C~#ROMETBG, 2191' I-14-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS 9-5/8" CSG, 47#, L-80, ID = 8.681" I-~ 3876' in ID = 2.377" 1`1327' 3-112" x 2-7/8" ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3470 3263 40 KBG-2 DMY BK 0 04/05/09 4 5509 4759 44 KBG-2 DMY BK 0 04/05/09 3 7003 5844 44 KBG-2 DMY BK 0 05/08/04 2 8286 6749 43 KBG-2 DMY BK 0 05/08/04 1 9360 7515 39 KBG-2 DMY BK 0 05/08/04 CEMENT RAMP WINDOW 3881' - 3977' 9931' H 4-1 /2" HES X NIP, ID = 3.813" CIBP I-~ 4097' P~ iek 6Qfl' n 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" ~~ 10372' I5" LNR, 15#, 13-CR, .0189 bpf, ID = 4.408" ~ 11056' T~aR `{ 0170' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" - 9952' ~ 7 X 4-1/2" BKR S3 PKR 9975' I-14-1/2" HES X NIP, ID = 3.813" 9996' 4-1/2" HES XN NIP, ID = 3.80" MILLED () 10006' 7" X 5" BKR ZXP LNR TOP PKR W/ TIEBACK SLV 10009' 4-1/2" WLEG, ID=3.958" 10019' 5" X 4-1 /2" XO, ID = 3.960" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" -1 10160' Y ~(~ 10544` 3-112" BKR DEPLOYMENT PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 93° @ 12230' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12230 - 12670 O 07/02/10 2" 6 13310 - 13690 O 07/02/10 2" 6 13840 - 13953 O 07/02/10 SLV, ID = 3.00 TOC 10544' 1 3-1/2" LNR, 9.2#, 1132T ~ ~~ 4-1/2" MILLOUT WINDOW (15-37C) 11350' -' i L-80, STL , '~ .0088bpf, ID = 2.992" i / 11, 327' XO 4-112" BKR PACKER 11350° ~ WHIPSTOCK `~ ~ ~~~~uh~i~u~ar ~ 1395T PBTD ~ i -~ ~..~_ _ / I2-7l8" LNR, 6.16#: L-80, STL .0058 bpf, ID = 2.441" ~ 13976' ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 12466' DATE REV BY COMMENTS 06/28/94 ORIGINAL COMPLETION 08/01/00 CTDSIDETRACK(15-37A) 05/08/04 DAV/KA RIG SIDETRACK(15-37B) 07/03/10 NORDIC2 CTD SIDETRACK (15-37C) 07/09/10 SV DRLG HO CORRECTIONS PRUDHOE BAY UNIT WELL: 15-37C PERMfT: `2100380 API No: 50-029-22485-03 SEC 22, T11 N, R14E, 1445' FNL & 4419' FEL BP F~cploration (Alaska) ~J John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. ~ ~..~ Q P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-37B Sundry Number: 310-099 r~ A ; 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 rehearing. A request for rehearing is considered timely if it is received. by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this J'S day of April, 2010. Encl. Daniel T. Seamount, Jr. Chair STATE OF ALASi(A R~~'V~ q,, jy` ALAS~L AND GAS CONSERVATION COMMIS•N APPLICATION FOR SUNDRY APPROVAL APR 0 ~ '2010 20 AAC 25.280 alaa.iirC111 Q fa_w..t+..we C`tw7Y~M 1. Type of Request: ^ Abandon ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-019 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22485-02-00 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 15-37B Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028306 Prudhoe Bay Field / Prudhoe Bay Oil Pool 1 L PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12471' 8780' 12421' 8784' 11860' None Casin Len Size MD TVD Burst Colla Structural Conductor 11 11 11 ' Surface 3 76' -5/8" 87 ' 63' 70 47 0 Intermediate 1 1 7" 1 160' 242' 7 4 541 Production Liner 24 8' 4-1 /2" ' - 1 4 8 4' - 8780' 4 7 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11000' - 10870' 8818' - 8799' 4-1/2", 12.6# 13Cr80 10009' Packers and SSSV Type: 7" x 41/2" Baker'S-3' packer Packers and SSSV 9952' / 8040' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 1, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG Plugged ^ SPLUG Commission Representative: L/.,S' ~ ,~oregoing is true and correct to the best of my knowledge. Contact Eli Viz uez 564-5918 17. I hereby certify that th e / ~ Printed Name J fSn c ,, ull ~ ,,~' Title Engineering Team Leader Prepared By Name/Numbec Signature ;' ~.f"~ ~(--' Phone 564-4711 Date I ~1 Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness ' I Sundry Number: / ,,.,/ ^ Plug Integrity Lief BOP Test ^ Mechanical Integrity Test ^ Location Clearance x 3500 ~s~ ,t3o~' l~s~ Other: ~ 4..~ ~ ~s ~ C~ J st 9-'1~ J $ ` / QO ho ~ 7t Subsequent Form Required: ~ Q • y O~ / APPROVED BY / ~~ 6 / Approved By: COMMISSIONER THE COMMISSION Date // / Form 10-403 Revised 12/2009 RBDMS APR 152010 ~~ ~ ~~~ Submit In Duplicate ,fin ~ j~o • • To: Alaska Oil & Gas Conservation Commission From: Eli Vazquez CTD Engineer Date: March 30th, 2010 Re: 15-376 Sundry Approval Sundry approval is requested to abandon perforations on well 15-37B in preparation for a CTD sidetrack. Well 15-37B was a May 2004 rig sidetrack in the north-eastern part of DS-15 and was completed with 1,070' of Z1A/1 B perforations. The rig sidetrack also fixed the PC leak at 6800' MD and run new 4-1/2" 13-Cr tubing after abandoning the parent well that had sustained formation damage after being dump flooded with cretaceous water. The well came on at very strong rates and solution GOR. It produced fulltime for the next two years. The well hit MGOR in spring 2008. In hopes of improving productivity, a CIBP was set at 11,860' MD and then 25' of Zi B perfs were shot in the heel on March 10, 2009. The initial rates (post GSO/add perforations) were encouraging. However, the well went to producing at high GOR within a month. There are currently no viable well work options left on this well and the on-time has now dropped to below 20%. The most recent test on August 10, 2009 had the well producing at poor levels with high GOR and with no ability to recharge or cycle. Well 15-37B is in sound mechanical condition. The well passed the MITIA to 3000 psi on April 5th, 2009 and failed the MITOA to 2000 psi on June 5th, 2009. The OA pressure dropped from 2000 psi to 680 psi after 15 minutes (both the Tubing and IA pressures stayed constant) indicating that the 9-5/8" shoe may have been blown off. Bubbling was also noticed in the. next door empty well slot while performing the MITOA. However, the LEL readings showed no presence of hydrocarbons. The well passed the PPPOT-T to 5000 psi on June 18, 2009. A coil tubing sidetrack will enable this 4~/z" monobore to be more effectively utilized and bring value to the field. The sidetrack, 15-37C, is scheduled to be drilled by Nordic 2 starting on June 20th, 2010. This horizontal lateral will target Ivishak Zone 1A. A CIBP will be set Pre Rig at 11,350' MD to abandon the perforations below this depth. Next, the injectivity of the perforations above will be assessed to determine if a plug or squeeze work is desired. The "C" sidetrack lateral will exit the parent well at 11,335' MD in the Ivishak Zone 2 via a 4~/z" monobore whipstock and a 2,555' lateral will be drilled to a TD of 13,890' MD. The sidetrack will be completed with a solid, cemented and perforated 3'/z" x 3-3/16" x 2-7/8" solid L-80 tapered liner. The following describes work planned. A schematic diagram of the proposed sidetrack is attached for reference. 1 e ®.~CU~' 7~~° ~i.''C~f'C~c/ IS~'~~C wCl~ w. // 7~yP~ 7~i' /°~I~ie~ sriyc!' 4,f (v~/Ph i~ .G'/UC~~ i~~( /J``i jv~l~i I"?L'/P G+ fPw ~vnr~rC' r/ ~c y' `r'te ~i~ T CJ /~El~~~/ ~ v c°,'c( f6 ~ ~,f ~ G ~ / " a l+~r~ t, ~i C v /YPl1t' ~y [',r~'r~; ~,ie w~1 % ~jf' fJilJ.~/tY f'r~1r/itJK° CTD Sidetrack Summary ~~ ro~~~.-~. ; ~., rl ~~ ~'o~t•c'~ ~ ° ~E ~Z~~ Q ;~ ~~ _ ~ f ~~ Pre-CT Rig Work: The pre CTD work is planned to begin June 1St, 2010. 1. D MIT-IA to 3000 psi, MIT- OA to 2000 psi. o 2. W Check tubing hanger LDS. 3. W PPOT-T to 5000 psi, PPOT-IA to 3500 psi. 4. V PT tree (MV,SV,WV) 5. C Mill XN Nipple at 9,996' MD to 3.80" ID. 6. C Drift for CIBP and 4~/z" Mono-Bore whipstock. - 7. C Set CIBP at 11,350' MD. 8. C Swap well over to 8.5 ppg Flo Pro and assess injectivity to determine if cement plug or squeeze is desired. 9. C Freeze protect well and thoroughly wash the tree. 10. D Bleed wellhead pressures down to zero. 11. D Bleed production flow lines and GL lines down to zero and blind flange. 12. O Remove wellhouse, level pad. l~J • Rig Sidetrack Operations: (Scheduled to begin on June 20`h, 2010 using Nordic Rig 2) 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT brilling BOPE and test 3. Drift for 4~/z" Mono-Bore whipstock. 4. Set 4~/z" Mono-Bore whipstock hiah side at 11.335' MD. 5. Mill 3.8" dual string window in 4~/z" 12.6# L-80 production liner from mechanical whipstock. 6. Drill lateral section with 4-1/8" bicenter bit to 13,890' MD. 7. Run 3'/z" x 3-3/16" x 2-7/8" L-80 tapered liner string. Place liner top at 10,500' MD. 8. Cement L-80 tapered liner. Expect ~28 bbl of 15.8 ppg cement. 9. Make a cleanout run with mill and motor. 10. Make a MCNL run. 11. Test Liner lap to 2000 psi. 12. Perforate well 13. Run Liner Top Packer, if needed. 14. Freeze protect well to 2000' TVD. 15. Set BPV. ND 7-1/16" BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. 16. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. RU test separator. Eli Vazquez CTD Engineer ~T~ ~ ~ r 1~3 ~ CC: Well File Sondra Stewman/Terrie Hubble TRH= 4-1/16" MCEVOY WELLHEAD = FMC ACTUATOR = NA KB. ELEV = 65.7' BF. ELEV = 33.37' KOP = 3881' Max Angle = 95 @ 12471' Datum MD = 11523' Datum TV D = 8800' SS 9-5/8" CSG, 47#, L-80, ID = 8.681" i--{ 3876' SAFETY N~: 5" CHROME LNR; 4-1 /2" CHROME 15 -3 7 B TBG. 2191.' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3470 3263 40 KBG-2 DMY BK 0 04/05/09 4 5509 4759 44 KBG-2 DMY BK 0 04/05/09 3 7003 5844 44 KBG-2 DMY BK 0 05/08/04 2 8286 6749 43 KBG-2 DMY BK 0 05/08/04 1 9360 7515 39 KBG-2 DMY BK 0 05/08/04 Minimum ID = 3.725" @ 9996' 4-1 /2" HES XN NIPPLE cIBP H 4097 CEMENT RAMP WINDOW 3881' - 3977' 4-1/2" HES X NIP, ID = 3.813" ~ 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" ~ 10372' ~ 5" LNR, 15#, 13-C R, .0189 bpf, ID = 4.408" 11056' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 10009' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10160' PERFORAl10N SUMMARY REF LOG: ANGLE AT TOP PERF: 89° @ 11000' Note: Refer to Production DB fur historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-7/8" 4 11000 - 11320 O 05/05/04 2-7/8" 4 11490 - 11840 O 05/05/04 2-7/8" 6 10845 - 10870 O 03/10/09 2-7/8" 4 11880 - 12040 C 05/05/04 2-7/8" 4 12080 - 12172 C 05/05/04 2-7/8" 6 12172 - 12320 C 05/05/04 9952' H 7 X 4-1 /2" BKR S3 PKR 9975' 4-1/2" HES X NIP, ID = 3.813" 9996' 4-1/2" HES XN NIP, ID = 3.725" 10009' 4-1/2" WLEG, ID=3.958" 10006' 7" X 5" BKR ZXP LNR TOP PKR W/ TI~ACK SLV 10019' 5" X 4-1/2" XO, ID = 3.960" 11860' ~4-1/2" WFD CIBP (03/10/09) ~ 4-1/2" LNR 12.6#, L-80, .0152 bpf, ID = 3.958" (--i 12466' DATE REV BY COMMENTS 08/28194 ORIGINAL COMPLETION 08/01/00 CTD SIDETRACK (15-37A) 05/08/04 DAV/KA RIG SIDETRACK (15-37B) 05/14/04 KSB/KAK GLV GO 03/18/09 RMWSV SET CIBP/ADPERF (03/10/09) 06/03/09 ???/TLH GLV GO (04/05/09) PRUDHOE BAY UNff WELL: 15-37B PERMIT: 2040190 API No: 50-029-22485-02 SEC 22, T11 N, R14E, 1445' FNL & 4419' FEL BP Exploration (Alaska) Page 1 of 2 Maunder, Thomas E {DUA) From: P1SU, ADW Wei! Integrity Engineer (VSUADWVI{elllntegri#yEngneeri~,~BP.com] Sent; Wednesday, April 14, 2010 8:45 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); NSU, ADW Well lnt~rity Engineer Subject: RE: DS 15-37B (204-019) Attachments: 15-37B.pdf ,~ • ~ si~w.~st~...~ A }~ Il = ~ ~ A Hi Tom, Thank you for sending this to us for review. I wilt be working with town engineers to review these Sundry requests before they are submitted to avoid future confusion. The original completion of 15-37 in June, 1994 left an open shoe to formation. During the MIT-OA on 15-37B on June 5, 2009, the first attempt at the MITOA to 2000 psi passed losing 120 psi in the first 15 minutes, and 40 psi in the second 15 minutes. The OA was again pressured to 2000 psi. The OA pressure fell off to 680 psi in 15 minutes. It is believed that the additional fluid caused the formation to temporarily open. While bleeding down the OA pressure after the test, there was bubbling noted in the empty well slot between 15-37B and 15-38A. There was ice and water in the cellar of 15-37B obstructing a view of the flutes. Later in the day, both the cellar on 15- 376 and the conductor between 15-37B and 15-38A where monitored with no signs of bubbling although ice and water inflow where noted in the conductor between 15-37B and 15-38A and across the pad. This is normal spring thaw activity. Minor bubbling was noted the next day on June 6, 2009 with zero LEL readings. The area was monitored daily for the next week with no note of LELs or bubbling. This is thought that the original bubbling was due to spring thaw when air trapped in the gravel pad/tundra can find a path to surface. Recently a MITOA passed to 2000 psi on 15-37B on April 5, 2010 confirming surface casing integrity and supporting the belief that the formation at the OA shoe will hold some pressure. A wellbore schematic has been included for reference. Please let us know if you have any further questions. Thank you, ~ Batt Torin ~Z roger) Weft Integrity Coardr~ator GPB Wells Group Phone: (907) 659-'tt} Pager:. (907) 659-5TE1E~ ~t154 From: Maunder, Thcxrias E {DOA) [matito:torn.maunder@alaska.grn+l Sent: Friday, April 09, 2010 1:38 PM To. NS1J, ADW Well Integrity Engineer cc: Regg, :larr~s s (DOA), Schwartz, Guy s_ (DOA) Subject: DS 15-37B (204-019) Torin or Anna, 4/24/2010 Page 2 of 2 Attached is the "letter" received regarding the intended P&A and sidetrack of DS 15-37B. The information in paragraph 2 is of interest. It appears that while attempting a MITOA on June 5, 2009, pressure was lost and there were bubbled in an adjacent slot. I don't believe the suppositions that the "shoe may have been blown off' and "the well is in sound mechanical condition" accurately describe what appears to be the failure, potentially shallow, of the 9-5/$" surface casing. Jim and I have checked our records and we do not find any correspondence regarding the events of June 5. Would you examine your records to see what might be available? Thanks in advance, Tom Maunder, PE AOGCC 4/24/2010 • • To: Alaska Oil & Gas Conservation Commission From: Eli Vazquez i~^ ~~ ~ `"` ~~ CTD Engineer ~- Date: March 30t", 2010 ~'"`~©~d~~-. Re: 15-37B Sundry Approval Sundry approval is requested to abandon perforations on well 15-37B in preparation for a CTD sidetrack.. Well 15-37B was a May 2004 rig sidetrack in the north-eastern part of DS-15 and was completed with 1,070' of Z1A/1 B perforations. The rig sidetrack also fixed the PC leak at 6800' MD and run new 4-1/2" 13-Cr tubing after abandoning the parent well that had sustained formation damage after being dump flooded with cretaceous water. The well came on at very strong rates and solution GOR. It produced fulltime for the next two years. The well hit MGOR in spring 2008. In hopes of improving productivity, a CIBP was set at 11,860' MD and then 25' of ZTB perfs were shot__in- #fie-heron ~fVl-arch _fi0; ~~2009:---T#~e~inittal rates (post GSO/add perforations) were encouragin~,,bornrever, the well went to producing at high GOR withiri~a#rr-a~th There are currently no viable well w ~k`options left on this well and the on-time has now dropped to below 20%. The t recent test on Aug t 10, 2009 had the well producing at poor. levels with high GOR and with no ability to recharge cle. ell 15-37B i in soun mec arncal condition. The well passed the MITIA to 3000 psi on April 5t", 2009 an ~~~~ ~~~ f filed the MITOA to 2000 psi on June 5t", 2009. The OA pressure dropped from 2000 psi to 680 psi after 15 inutes (both the Tubing and IA pressures stayed constant) indicating that the 9-5/8" shoe may have been town off. Bubbling was also noticed in the next door empty well slot while performing the MITOA. However, the EL readings showed no presence of hydrocarbons. The well passed the PPPOT-T to 5000 psi on June 18, 009. A coil tubing sidetrack will enable this 41/2" monobore to be more effectively utilized and bring value to t~ The sk, 15-37C, is scheduled to be drilled by in on June 20~", 2010. izontal lateral will target Ivishak Zone 1A. A CIBP will be set Pre Rig at 11,350' M to a an on t e perforations below this depth. Next, the injectivity of the perforations above will be assessed to determine if a plug or squeeze work is desired. The "C" sidetrack lateral will exit the parent well at 11,335' MD in the Ivishak -Zone 2 via a 4Yz" monobore whipstock and a 2,555' lateral will be drilled to a TD of 13,890' MD. The sidetrack will be completed with a solid, cemented and perforated 31/2" x 3-3/16" x 2-7/$" solid L-80 tapered liner. The following describes work planned. A schematic diagram of the proposed sidetrack is attached for reference. CTD Sidetrack Summarv Pre-CT Rig Work: The pre CTD work is planned to beoin June 1St. 2010. 1. D MIT-IA to 3000 psi, MIT- OA to 2000 psi. 2. W Check tubing hanger LDS. 3. W PPOT-T to 5000 psi, PPOT-IA to 3500 psi. 4. V PT tree (MV,SV,WV) 5. C Mill XN Nipple at 9,996' MD to 3.80" ID. 6. C Drift for CIBP and 41/2" Mono-Bore whipstock. 7. C Set CIBP at 11,350' MD. 8. C Swap well over to 8.5 ppg Flo Pro and assess injectivity to determine if cement plug or squeeze is desired. 9. C Freeze protect well and thoroughly wash the tree. 10. D Bleed wellhead pressures down to zero. 11. D Bleed production flow lines and GL lines down to zero and blind flange. 12. O Remove wellhouse, level pad. G ~®_ ' ~ {~_ - PJ-~" ~. _ _~~' ~ _ ,~, Al~ax ~ - ~i i2~~'~" ~ m?'4iCM- ~-5~'~" max, a7,: ~-s~d, D = 8_t' 1"'1 3$7~ ST 'Fi/F3 @]E~ ~~ dfL9/ ~AT(~-f F19~E 5 347! KBG2 ~F( ~ tlkR R 55~ X759 Ff~G-2 BdK Ei 3 ? 44 K@$r2 ~!C CD 2 ~a7 ~3 F~C~-~ E3Ff ~ Z 7 a15 ~4! IB6-2 Bt4 ~ MIIIE[Ftl~[Yi ~ = 3.~ZrJ~` ~ 9~~~ 4-"I/2~ NES )CN [NIPPLE i~ts~ 1" - 33T(" iii` H~-~~z° x ®_ ~.~~~~ 1 ~ ~. ~z_r'3-cam e~~~ , o= ~_ [--~ 1oi1Q9r' ~ ~~e ~~~T~~f ~m~,~ ;~ ~~ s¢~ s~ ee~. a~e~€ a-~ ~ ~~ - ~~r o 2-aa ~ ~ ~a~ -1 ~ o ~-ate ~ ~ - ~z~ a ~sa ~-pits" ~ ~ ~ - ~ o 2-7U~° 4 ~ - t2~~2 C3 ~-7M~" ~ ~@~6- ~232Q ~ x a-~ ss ~ = ~_as~ g91s .~-~~° t~ x ~ n = ~_s~~° 999G ~-~~' ~s ~ ~ a = ~_~2~° t~ ~° x ~ ~x zxw ~ ~ c~cc ~v ~aa~s ~x~-,x~,~s=~. '11860` ~~-~~r° ~v ('t~~ 1 12~T8' 1 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 • Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ,w~'~~4~~~ =- JAIL ~` ~~ Z~k`° Anchorage, Alaska 99501 aa~- ©~ 9 Subject: Corrosion Inhibitor Treatments of GPB DS 15 / S _ Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 natP• nvns/an Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200- NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-04B 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11!11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 1017!2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11!12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8!2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-31B 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-37B 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-42B 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-45B 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-48B 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-49B 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 OPERABLE: 15-37B (PTD #20190) Tubing Integrity Restored • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] i Sent: Monday, April 06, 2009 6:57 AM ~~~~ ~` t~~ ~c To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Welt Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Sinyangwe, Nathan Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 15-37B (PTD #2040190) Tubing Integrity Restored All, -/ Well 15-376 (PTD #2040190) passed an MIT-IA to 3000 psi on 04/05/09 after dummy gas lift valves were set. The passing test confirms that tubing integrity has been restored. The well has been reclassified as Operable and my be put on production when convenient. Please take caution as the IA is liquid packed. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ,. From: NSU, ADW Well Integrity Engineer Sent: Friday, March 27, 2009 7:40 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GCl/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Sinyangwe, Nathan Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: 15-376 (PTD #2040190) TxIA Communication AI I, Well 15-37B (PTD #2040190) has been found to have sustained casing pressure on the IA. The TIOs were 2440/2460/0 psi on 03/26/09. The well failed a subsequent TIFL on 03/27/09 when the IA increased 1320 psi overnight. The well has been reclassified as Under Evaluation and may be put on production while diagnostics continue. The plan forward for the well is as follows: D: TIFL -FAILED 2. S: Set DGLVs and Caliper 3. F: MITIA to 3000 psi A wellbore schematic and TIO plot have been included for reference. Please call with questions or concerns. 4/14/2009 OPERABLE: 15-37B (PTD #20190) Tubing Integrity Restored • Page 2 of 2 Thank you, Andrea Hughes Well Integrity Coordinator 659-5102 4/14/2009 PBU 15-37B PTD 2040190 4/6/2009 TIO Plot 4.i.ii ii i 3,000 2,000 1,000 ~- Tbg -f- IA -~- OA OOA -+ OOOA -~- On 12~27r08 01 X03709 01 i 1009 01 !17109 01 l2~i 09 01 X31 !09 02r'07~09 0211 ~~09 0221 I09 02!28!09 0310709 03l14~09 03x21109 TREE= 4-1/16" MCEVOY WELLHEAD = FMC ACTUATOR = NA KB. ELEV = 65.7' BF. ELEV = 33.37' KOP = 3881' Max Angle = 95 @ 12471' Datum MD = 11523' Datum TVD = 8800' SS 15 ~~ ~ ~ SAFETY NOTES: 5" CHROME LNR; 4-1 /2" CHROME TBG. 9-5/8" CSG, 47#, L-80, ID = 8.681" I-I 3876' Minimum ID = 3.725" @ 9996' 4-1 /2" HES XN NIPPLE cIBP I~ 4097' CEMENT RAMP WINDOW 3881' - 3977' 9931' F-14-1/2" HES X NIP, ID = 3.813" 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" ~ 10372' 5" LNR, 15#, 13-CR, .0189 bpf, ID = 4.408" 11056' ~4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 89° @ 11000' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11000 - 11320 O 05/05/04 2-7(8" 4 11490 - 11840 O 05/05/04 2-7/8" 6 10845 - 10870 O 03/10/09 2-7/8" 4 11880 - 12040 C 05/05/04 2-7/8" 4 12080 - 12172 C 05/05/04 2-7/8" 6 12172 - 12320 G 05/05/04 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I~ 10160' 9952' H 7 X 4-1/2" BKR S3 PKR 9975' 4-1/2" HES X NIP, ID = 3.813" 9996' 4-1/2" HES XN NIP, ID = 3.725" 10009' 4-1/2" WLEG, ID=3.958" 10006' 7" X 5" BKR ZXP LNR TOP PKR W/ TIEBACK SLV 10019' 5" X 4-1/2" XO, ID = 3.960" 11860' ~-~4-1/2" WFD CIBP (03/10/09) PBTDI~ 12378' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" i-j 12466' DATE REV BY COMMENTS 06/28!94 ORIGINAL COMPLETION 08/01/00 CTD SIDETRACK 15-37A 05/08/04 DAV/KAK RIG SIDETRACK 15~37B 05/14/04 KSB/KAK GLV C/O 03/18/09 RMH/SV SET CIBP/ADPERF (03/10/09) 2191-~4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3470 3263 40 KBG-2 DOME BK 16 05/14104 4 5509 4759 44 KBG-2 SO BK 20 05/14/04 3 7003 5844 44 KBG-2 DMY BK 0 05/08/04 2 8286 6749 43 KBG-2 DMY BK 0 05/08/04 1 9360 7515 39 KBG-2 DMY BK 0 05/08/04 PRUDHOE BAY UNIT WELL: 15-37B PERMIT: FZ040190 API No: 50-029-22485-02 SEC 22, T11N, R14E, 1445' FNL &4419' FEL BP Exploration (Alaska) To: AO[~CC Christine Mahnken ,.~,,.. '~ 333 W. 7th Ave a~ ~~~ ; ~ P ~?v °,~ ~ Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hote/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 Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic.. Services,. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~~' d~Q/ Anchorage, AK 99518 Fax: (907) 245-8952 /~'~S~l ~j" 1 ~ ~`~9 1) Coil Flag 06-Marv09 15~37B (run 1) EDE 50-029-22485-02 2) Coil Flag 10-Mar~09 15-07B (run 2) EDE 50-029-22485.02 Signed : Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E~MIAIL ~.i~_,, ~ - .. ~ .__ _.~_~~ WEBSITE: __; ~ ' _.T_®~`~`t ~\ C:\Documents and Settir~s\OwneclDesMoplTransmit_BP.docx ~ ' ~~°1 STATE OF ALASKA -J,. ~,~~ ALA~OIL AND GAS CONSERVATION COM~ION A~ ~ ~ 209 ~ Alaska Oil & Gas Cotes. Commis REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other 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. Current Well Class: 5. Permit to Drill Number: Name: Development l~ Exploratory 204-0190 - 3. Address: P.O. Box 196612 Stratigraphic ~~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22485-02-00 - 7. KB Elevation (ft): 9. Well Name and Number: 59.5 KB PBU 15-376- 8. Property Designation: 10. Field/Pool(s): ADLO-028306 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12471 - feet Plugs (measured) 11860 true vertical 8779.83 _ feet Junk ( m e asured) None 'i r ~ ~( f7 t( Effective Depth measured 12421 - feet true vertical 8784.03 - feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" 91.5# H-40 Surface - 110 Surface - 110 1490 470 Production 3876 9-5/8" 47# L-80 Surface - 3876 Surface - 3563 6870 4760 Liner 10160 7" 26# L-80 Surface - 10160 Surface - 8242 7240 5410 Liner 2468 4-1 /2" 12.6# L-80 9998 - 12466 8084 - 8780 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13-CR SURFACE -10009' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S3 PKR 9952' 7"X5" ZXP LNR TOP PKR 10006' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 468 28340 6 1845 Subsequent to operation: 617 24591 18 1814 14. Attachments: 15. Well Class after proposed work: copies of Logs and surveys Run Exploratory l~ Development I/ ~ Service [ Daily Report of Well Operations X 16. Well Status after proposed work: Oil l~ - Gas r WAG l~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O, Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~ Phone 564-4944 Date 3/24/2009 Form 10-404 Reviled 04/2006 9 ,~ ( ~ , ,, r 700 ~i Submit Original Only L ~~ 15-376 204-019 PERF ATTA(:HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-376 5/5/04 PER 11,000. 11,320. 8,817.87 8,814.26 15-37B 5/5/04 PER 11,490. 11,840. 8,807.3 8,804.9 15-376 5/5/04 PER 11,880. 12,040. 8,802.62 8,793.32 15-376 5/5/04 PER 12,080. 12,151. 8,793.15 8,794.61 15-37B 5/5/04 PER 12,151. 12,320. 8,794.61 8,792.03 15-37B 3/10/09 APF 10,845. 10,870. 8,789.92 8,798.86 15-37B 3/10/09 BPS 11,860. 11,865. 8,804.01 8,803.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 • 15-37B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 3/9/2009 CTU # 9 Job scope; set CIBP / adperf. pump drift ball (1.25") thru new coil. RIH w/ PDS memory logging tools inside carrier.** Job continued on WSR 03-10-09** ..~... m _ _._ 3/10/2009**continued fro WSR 03-09-09** continue RIH w/ PDS logging tools. Tag btm ! @ 12406', paint flag @ 12000'. Log @ 40 fpm up to 9700'. pooh. Download data -good data. -20' correction (10' discrepancy between program log copy ?and actual tie-in log-confer with APE and corrected pert depth -10') -MU/RIH with Weatherford 4.5 CIBP and set at 11860' set check with 2k down PU at ;11859.7' - POH - LD setting tools -recover 5/8 ball - MU /RIH with 25' of 2 7/8 Powerjet HMX - 6 SPF pert gun. Tag plug and corr depth, puh to btm shot @ 10870'. drop and pump ball. saw indication of firing. Shot interval C~ E 10 845- 10870'. POOH. all shots fired. perform weekly BOP test. ***job ;complete*** FLUIDS PUMPED BBLS 1 diesel 116 60/40 METH 117 Total • • 4~~- ~, MICROFILMED 03/01/20.08 DO NOT PLACE ..=;;. „~` ~ "~' ~,: V „_ ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_InsertslMicrofilm_Marker. doc '7 J~ Æ~~ t,o DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040190 Well Name/No. PRUDHOE BAY UNIT 15-37B Operator BP EXPLORATION (ALASKA) INC MD 12471,,/' TVD 8780"" Completion Date 5/7/2004/' Completion Status 1-01 L Current Status 1-01L - --_.,--- ----------,--_...,,-,- - --,--- -.--.---..-.----.----- ---.---.---- ---"._"--_._--~.._- ----_._-----...--_._-----,--- -,._--------------- --- -----""--.-.--------.--- - ----.---. ---.------.---. - _.-._------~_..._-- -"--- ---.--.-.----- -.----.-.-.--.-.-------.-------- -------_._----,,-- - - ..---.-----.- ------- ._------..._-_..~--_._._._._,._._._-_._--_.- -.------"'--_. -.-- --.---..------- ----- ---.----.------.--.-- REQUIRED INFORMATION )f "Ld ~ ~ ~ ~ a C) c.{ API No. 50-029-22485-02-00 UIC N Mud Log No Samples No Directional survey~ -- _._----_._------------,-_.---._, - ------.- - . - -_._------~_._._-_._- -.----------..-.------.-----.--.--.-.---..---..-----.-.-----.--..--..--.-.- --..- ----.-_.- --~----_._---------_..__._-----_.- DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~~-~~~~~- Nu~~er---6~::;nal-sürvëy-------------m------------------------.--- Scale Me~~_~_<:'________~ta~_____~~E____~~_______~~_~~~___M~6~~-~-~~--- --------------- MWD :rD Directional Survey Asc Directional Survey % Directional Survey D Lis 12579 Gamma Ray /' Lis 12579 LIS Verification ~ C Lis 13706 I nd u ction/Resistivity 6/9/2004 6/9/2004 0 0 6/9/2004 0 0 6/9/2004 3613 12422 Open 6/9/2004 3613 12422 Open 6/9/2004 3881 12471 Open 2/22/2006 _. _...,. .·.·_._·~·_._'_R_'·._"'._.,.._,,_"'___,__,,___·_,._.__.·_.___..__..._____.__,__".___.___." ------,-_.._---- _.__._____.___R'"'____ ._____. _~._..__.__"'._.______,_____._._,_._.___~__.____._______..___,____._...____.__ .._..__._.__._. _.___.________.__,___._.,_~_..___ Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORM~ON Well Cored? ~~ Chips Received? 'Y / N Daily History Received? ¿)N é> Formation Tops Analysis Received? Y/N - . --.--------. _._. "'__._____..,,___ ,..__.__...__._.,,_,._____.___._..__..____. .___...______..___..___.________..___._____.__.___________________________._....__R.._·._.._·._.._~_______"_.____ IIFR IIFR MWD, GR, EWR4, ASI, CNP, SLD, ROP, PWD MWD, GR, EWR4, ASI, CNP, SLD, ROP, PWD ROP DGR EWR SLD CTN plus graphics ( _.._____,_____.__.._.._____..~._____._..______.___.____._.,_._____._...,__.____.w____. _..~".._---_._.._,~...._-_._-,_...... Comments: _ _...._..."~,,-,----,,._._-_._."."- --_.._.._--_.._.__.,-~-_._. ---,----_._---~. .--,.--..-.---- -,,------- ----..------------.-.-.-----.------.--.-.-..,---.----- ..._-_.__.__._-~..-.._--._-- ------_.__._-~-------- ____R______.__.__.._ -----_._--_._-...._-~_.._---,,-----~---~.-_..~...__._-~---.------------. ---------- DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040190 Well Name/No. PRUDHOE BAY UNIT 15-37B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22485-02-00 ::mPli::::1ReViewe::: 8780... JJ;:PI::n::e__. 5~ 120=- Completion Status 1-01L Current Status 1-01L UIC N Date: __ ?__J~~__º~_~ ( ( L - --/ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 /37aCo RE: MWD Fonnation Evaluation Logs 15-37B, 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, AI<.99518 907-273-3500 15-37B: LAS Data & Digital Log Images: 50-029-22485-02 00+ -6tg 1 CD Rom ~!J !1\ 'ò'J}D~ STATE OF ALASKA .. C· E- r 'E--:· 0- ALASKA~L AND GAS CONSERVATION COMr\ì'i':OSION RE. >. -1\/l WELL COMPLETION OR RECOMPLETION REPORT AND LOG JUN 1 42004 1a. Well Status: II 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 99519-6612 4a. Location of Well (Governmental Section): Surface: 1445' SNL, 4419' WEL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 3429' NSL, 2233' WEL, SEC. 15, T11N, R14E, UM Total Depth: 2853' NSL, 671' WEL, SEC. 15, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676796 y- 5960056 Zone- ASP4 TPI: x- 678860 y- 5964980 Zone- ASP4 Total Depth: x- 680436 y- 5964442 Zone- ASP4 18. Directional Survey II Yes 0 No 21. Logs Run: 22. One Other 5. Date Comp., Susp., or Aband. 5/7/2004 6. Date Spudded 4/22/2004 7. Date T.D. Reached 5/3/2004 8. KB Elevation (ft): 59.5' 9. Plug Back Depth (MD+TVD) 12421 + 8784 10. Total Depth (MD+TVD) 12471 + 8780 11. Depth where SSSV set (Nipple) 2191' MD 19. Water depth, if offshore N/A MSL CASING SIZE 20" 9-5/8" 7" 4-1/2" GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH.TVD .HOlE Top BOTTOM Top BOTTOM - SIZÉ Surface 110' Surface 110' 30" Surface 3876' Surface 3563' 12-1/4" 27' 10160' 27' 8242' 8-1/2" 9998' 12466' 8084' 8780' 6-1/8" CEMENTING RECORD 260 sx Arcticset 375 sx Class 'G', 920 sx PF 'E' 369 sx Class 'G', 140 sx Class 'G' 295 sx Class 'G' WT. PER FT. 91.5# 47# 26# 12.6# 23. Perforations 0Ren to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state I none"): 2-7/8" Gun Diameter, 4 spf 2-7/8" Gun Diameter, 6 spf MD TVD MD TVD 11000' -11320' 8818' - 8814' 12151' -12320' 8795' - 8792' 11490' - 11840' 8807' - 8805' 11880' - 12040' 8803' - 8793' 12080' - 12151' 8793' - 8795' 26. Date First Production: May 15, 2004 Date of Test Hours Tested 24. SIZE 4-1/2", 12.6#, 13Cr80 .^1"'L>.J...~1 ::r¡1 ~ ....a~· 1"'''1-.2 r:nHlmissjon 1 D:\H"eít B å~:u ~ v....·" = _.- II Developm~choraÇ[!) Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 204-019 13. API Number 50- 029-22485-02-00 14. Well Name and Number: PBU 15-37B 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PUllED TÙBINGRECORD DEPTH SET (MD) 10009' PACKER SET (MD) 9952' 25. ACID, FRACTURE,CEMENT SQUEEZE, ETC~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 76 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-BBl PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED .......... Oll-Bsl Press. 24-HoUR RATE""" 27. GAs-McF W A TER-BBl CHOKE SIZE GAS-Oil RATIO GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SUbr~~.~?(.~: C~~~P:~ if none, state "none". None î.;1þ~~ ~ !~D~___' Form 10-407 Revised 12/2003 OR\G\NAL CONTINUED ON REVERSE SIDE RBDMS BFL ~~ 1M 1.~ 6 100It G 28. -- GEOLOGIC MARKERS NAME MD TVD Sag River 10165' 8247' Shublik A 10213' 8294' Shublik 8 10242' 8322' Shublik C 10260' 8340' Sadlerochit 10282' 8362' 4288 10362' 8440' 41S8 10409' 8485' 8ase CGL 10483' 8555' 22TS 10599' 8653' 21TS 10667' 8702' Zone 18 10790' 8767' 29. -'-' FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None REC \VED JUN 1 Ll '[004 Alaska Oil &. ~~:Ì\~~::~ C\ìmm\~~\~n 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 Terrie HUbble~Q./IIlJ· 0 .&~ TiUe Technical Assistant Date Db - { (- O<f P8U 15-378 204-019 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number DrilUng Engineer: Rob Tirpack, 564-4166 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 20: True vertical thickness. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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 Legal Name: 15-37 Common Name: 15-37 Test Date 4/22/2004 4/29/2004 4/30/2004 LOT FIT FIT Test Type Test Depth (TMD) 3,906.0 (ft) 10,184.0 (ft) 10,184.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 3,578.0 (ft) 8,264.0 (ft) 8,244.0 (ft) AMW 9.80 (ppg) 8.40 (ppg) 8.40 (ppg) Surface Pressure 250 (psi) 250 (psi) 515 (psi) Leak Off Pressure (BHP) 2,072 (psi) 3,856 (psi) 4,112 (psi) Page 1 of 1 EMW 11.15 (ppg) 8.98 (ppg) 9.60 (ppg) /' ( Printed: 5/10/2004 9: 19:35 AM Operations Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-37 15-37 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/23/2004 Rig Release: 5/7/2004 Rig Number: Spud Date: 6/6/1994 End: 5/7/2004 Prep cellar for rig move Bridal up, secure service loops & all lines, knock out derrick pins, (pits, camp & shop down the road), chute down, derrick over, sub off the hole, cellar doors up. Off P1-07 A. Transport sub to DS 15, well 15-37B Lay herculite in cellar area Spot sub over well, spot shop-pits & hook up interconnect PJSM. Raise derrick & pin. Raise pipe chute, RU floor. Berm and spot cuttings tank. PJSM. Bridle down and complete pre-spud checklist Accept rig at 20:00 hrs 4/18/2004 Hold pre-spud/HSE safety meeting DSM remove VR plugs from OA & IA annulus valves Install secondary IA valve. RU circulating hoses RU DSM lubricator & pull BPV. RU to circulate 9.8 brine for kill operation SITP 210 psi - SICP 40 psi. Reverse circulate 36 bbls 9.8 ppg brine at 2 BPM taking returns to cuttings tank until 9.8 ppg brine seen at surface. Circulate 9.8 ppg brine down tubing at 2.8 BPM, 3100 strokes (181 bbls) until 9.8 ppg brine returned to surface. DECOMP Flow checked well for 15 minutes. No flow, well dead. Set BPV and tested same. Tested BPV from below, at 260 psi began injecting though hole in 7". DECOMP ND CIW 4-1/16", 5K tree and 13-5/8" 5K x 4-1/16" 5K adapter. NU BOPE. Function test BOP. DECOMP PJSM. RU and test BOPE 250 low - 3,500 high. Note: Witness of test waived by Chuck Scheeve w/AOGCC 4/17/04. DECOMP RU DSM lubricator and pull TWC. Well on vacuum DECOMP MU spear and engage 3-1/2" tubing below 4-1/2" XO. BOLDS. Pull hanger to rig floor - 60K up weight. LD spear and hanger. DECOMP RU and circulate hole volume with 9.8 ppg brine at 7 bpm/650 psi. Monitor well for 30 minutes. Lost 48 bbls during circulation. DECOMP LD 3-1/2" tubing, SSSV and spooling unit. Retrieved 22 SS bands out of 37 total on control line. 15 SS bands left in hole. DECOMP Continue LD tubing. Retrieved 127 full joints, 1 GLM, SSSV and 1 cut joint (13.27'). DECOMP PU test plug and 4" test joint. Test annular and both pipe rams to 250 psi 10/3,500 psi hi. Install wear bushing. DECOMP PJSM. RU Schlumberger e-line for CCUGR/JB run. DECOMP RIH with Schlumberger e-line w/CCL-6" GR-JB Tagged tubing stub at 4,108' ELM. POOH with same. DECOMP MU and RIH wn" CIBP. E-line came under tension when pulling up from 4,079' indicated on correlation run. Made 3 attempts to pull up further - No go. CIBP set at 4,090' ELM. POOH and RD e-line. DECOMP Test casing to 3,500 psi for 30 minutes - Good Test. DECOMP MU baker mechanical casing cutter dressed for 7". TIH picking up 4" DP. Tag Plug @ 4,097' DPM. POH to 3,977' to cut casing. DECOMP Cut 7",26# L-80 casing @ 3,977' DECOMP POH. LD cutting assembly. Pull Wear ring DECOMP MUSpear assembly. Stab into the 7" casing. I· Date From - To Hours Task Code 4/18/2004 00:00 - 00:30 0.50 MOB P 00:30 - 06:00 5.50 MOB P 06:00 - 13:30 7.50 MOB P 13:30 - 14:00 0.50 MOB P 14:00 . 16:00 2.00 MOB P 16:00 . 20:00 4.00 RIGU P 20:00 . 21 :00 1.00 RIGU P 21 :00·21 :30 0.50 WHSUR P 21 :30 . 22:30 1.00 WHSUR P 22:30 - 23:30 1.00 WHSUR P 23:30 - 00:00 0.50 WHSUR P 4/19/2004 00:00 - 03:30 3.50 KILL P PRE PRE PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 03:30 - 04:00 0.50 KILL P 04:00 - 07:30 3.50 BOPSUP P 07:30 - 12:30 5.00 BOPSUPP 12:30 - 13:00 0.50 BOPSUF P 13:00 - 14:30 1.50 PULL P 14:30 - 15:30 1.00 PULL P 15:30 - 18:00 2.50 PULL P 18:00 - 22:00 4.00 PULL P 22:00 - 23:00 1.00 BOPSUF P 23:00 - 00:00 1.00 PULL P 4/20/2004 00:00 - 01 :30 1.50 DHB P 01 :30 - 03:00 1.50 DHB P 03:00 - 04:00 1.00 DHB P 04:00 - 08:00 4.00 PULL P 08:00 - 09:00 1.00 PULL P 09:00 - 11 :30 2.50 PULL P 11 :30 - 12:00 0.50 PULL P Printed: 5/10/2004 9:19:44 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-37 1 5-37 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I Date From - To Hours Task Code NPT I Phase 4/20/2004 12:00 - 13:30 1.50 PULL P DECOMP 13:30 - 15:00 1.50 PULL P DECOMP 15:00 - 16:00 1.00 PULL P DECOMP 16:00 - 18:00 2.00 PULL P DECOMP 18:00 - 19:00 1.00 PULL P DECaMP 19:00 - 20:00 1.00 PULL P DECOMP 20:00 - 00:00 4.00 PULL P DECOMP 4/21/2004 00:00 - 01 :00 I 1.00 PULL P DECOMP 01 :00 - 05: 15 4.25 REMCM-P WEXIT 05: 15 - 06:30 1 .25 REMCM-P WEXIT 06:30 - 07:00 0.50 REMCM-P WEXIT 07:00 - 08:00 08:00 - 09:00 1.00 REMCM-P 1.00 REMCM-P WEXIT WEXIT 09:00 - 11 :30 ! 2.50 REMCM-P WEXIT 11 :30 - 12:00 12:00 - 13:30 13:30 - 18:00 0.50 REMCM-P 1.50 REMCM-P 4.50 STWHIP P WEXIT WEXIT WEXIT 18:00 - 20:00 2.00 STWHIP P WEXIT 20:00 - 00:00 I I 4.00 STWHIP P WEXIT Start: 2/23/2004 Rig Release: 5/7/2004 Rig Number: Spud Date: 6/6/1994 End: 5/7/2004 Description of Operations PJSM. RU Secondary valve and circulation lines on outer annulus and line up to the choke, SIP - 350 psi Open choke to 30% and bleed dead crude to the cuttings tank until the well was dead - 25 bbls gained. Close bag and back out the lock down screws. PU on 7" casing and unseat 7" packoff with 190K. Continue to PU to 225K - casing free. Displace 7" annulus with 9.8 ppg NaCI Brine throught the OA @ 4 bpm - initial loss rate of 200 bph. Slow rate to 2 bpm, 50 psi DPP with 100% open on the choke until clean fluid to surface. Shut down pumps and shut in the annulus. Open the bag and take returns to the pits @ 4.5 bpm while pumping soap pill to surface. Dynamic loss rate - 40 bph. Pump and spot 80 ppb LCM pill and monitor well. Static Loss rate - 4 bph. Pull 7" casing hanger to the rig floor. Break out and lay down the spear and hanger. Changeout the elevators. LD 7" casing from 3,977'. Retrieved 81 jts of 7", 26#, L-80 LTC and 15 jts + 6.7' cut jt of 7",26#, L-80 IJ4S and 2 turbolators. Well static. Clean and clear the floor. R/U 4" DP handling equipment. P/U 3-1/2" mule shoe and 4" DP in singles and RIH. Tag CIBP @ 4,097'. Rig up circulation lines. Circulate & condition mud prior to setting cement plug. No fluid losses while circulating. Held PJSM with Rig Crew & Dowell personnel while circulating. Dowell prime up cement equipment. Shut down & turn over to Dowell - Pump 5 bbl fresh Water- Test surface lines to 3,500 psi. Set cement plug from 4097' to 3655' as follows: Pump 14 bbl fresh water + 10 bbls "G" Cement + 1 0 bbllG" with 1 ppb CemNet + 8 bbl Class "G". Total 28 bbls (160 sk) of slurry mixed @ 17 ppg (Yield = 1.01 ft3/sk). Displace with 3 bbl fresh Water + 30 bbl of 9.8 NaCI @ 5.2 bpm with 613 psi FCP. CIP @ 07:00 hrs. Lost 9 bbls fluid while puming cement. POOH slowly with 4" DP to 3200' (10 std). M/U TDS. Circulate 2 x Btms-up from 3200' with 392 gpm @ 1100 psi. No cement observed at surface & no fluid losses while circulating. flow check. Well static. Close Hydril BOP. Apply & hold 200 psi squeeze for 2.5 hrs. Squeezed away +1- 1 bbl. Bleed off annulus pressure. Open well. flow check. Well static. NOTE: Prepare to change out Swivel Packing on TDS while holding squeeze. finish changing out Swivel Packing on TDS. POOH from 3200' with 4" DP. UD Mule Shoe Jt. Changeout elevators. MU BHA #1. Changeout elevators. Install Air Slips. Blow down Top Drive. PU 30 jts of 4" DP from 1,130' to 2,063'. flow test MWD. RIH with 4" DP from 2,063' to 3,648'. Wash down and tag cement @ 3,681'. Drill cement from 3,681' (firm cement @ 3,710') to 3,881'. Printed: 5/10/2004 9:19:44 AM .---- -- Legal Well Name: 15-37 Common Well Name: 15-37 Spud Date: 6/6/1994 Event Name: REENTER+COMPLETE Start: 2/23/2004 End: 5/7/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/7/2004 Rig Name: NABORS 2ES Rig Number: Date From - To Ho u rs Task Code NPT I Phase Description of Operations 4/21/2004 20:00 - 00:00 4.00 STWHIP P WEXIT WOB - 15K, ROP - 75 fph, TO -7K, PU - 125K, SO - 110K, ROT - 118K 4/22/2004 00:00 - 02:30 2.50 DRILL P INT1 Time drill from 3,881' to 3,886'. ROP increased with corresponding formation cuttings over the shakers. Work pipe over the ramp to ensure it is in good shape. Change over the fluids from 9.8 ppg NaCI Brine to 9.8 ppg LSND Mud while drilling 20' of new hole to 3,906'. 02:30 - 04:00 1.50 DRILL P INT1 Attempt FIT to 11.8 ppg twice. Both times, while performing the FIT, pressure broke over @ 250 psi - 11.2 EMW. Pressure increased to 275 psi after deviating from the straight line. We shut in and monitored for 10 minutes. During this time, pressure dropped off linearly from 275 psi to 50 psi in 10 minutes. We checked for leaks and found none. Informed ODE and the decision was made to drill ahead. 04:00 - 07:30 3.50 DRILL P INT1 Directional drill 8.5" hole from 3,906' to 4,072'. PU - 130K, SO - 100K, ROT - 115K, AST -, ART - , 570 gpm @ 2070 psi. 07:30 - 08:00 0.50 DRILL N HMAN INT1 Circulate and condition the hole. Flow check - stable. Pump Dry Job. Prepare to POH to run Baker Retrievamatic and pressure test 9-5/8" casing. 08:00 - 12:00 4.00 DRILL N HMAN INT1 POH from 4,072' to 1,130'. LD BHA #1 from 1,130'. Clear floor. 12:00 - 14:30 2.50 EVAL N HMAN INT1 MU Baker Retrievamatic packer on 5" HWDP to 659'. RIH on 4" DP to 3,775' 14:30 - 16:00 1.50 EVAL P INT1 Set Packer and close the rams. Test 9-5/8" 47# casing @ 3,775' to 3,500 psi and hold for 35 minutes - good test. Bleed off pressure, unset packer and RIH to 3,875'. Repeat casing test. Hold for 10 minutes - good test. Bleed off pressure and unset packer. LD single joint and pump dry job to POH. NOTE: Received permission to drill ahead from Winton Aubert of the AOGCC. 16:00 - 17:30 1.50 EVAL N HMAN INT1 POH from 3,875' to 750'. 17:30 - 18:00 0.50 EVAL N HMAN INT1 FMC inspected and adjusted leaking gland packing on a single casing head lock down screw. Set packer and test to 3,500 psi - good test, leak stopped. Bleed off pressure and unset packer. 18:00 - 18:30 0.50 EVAL N HMAN INT1 POH from 750' and LD Baker Retrievamatic Packer. 18:30 - 20:30 2.00 DRILL N HMAN INT1 MU BHA #2. Adjust motor bend, scribe and surface test. RIH to 1,132' 20:30 - 22:00 1.50 DRILL N HMAN INT1 RIH from 1,132' to 3,828'. Fill Pipe and install blower hose. 22:00 - 22:30 0.50 DRILL N HMAN INT1 Orient to 95 Land RIH to 4023. Precautionary wash down from 4,023' to 4,072'. 22:30 - 00:00 1.50 DRILL P INT1 Drill 8-1/2" Directional Hole from 4072' to 4209 AST - 0.19 hrs, ART - 0.6 hrs. TO on - 7K. WOB - 15K. PU - 130K, SO - 95K, ROT - 115K. 4/23/2004 00:00 - 00:00 24.00 DRILL P INT1 Dir Drill 8.5" from 4,209' to 6,735'. TO on - 9-13K. WOB- 5-15K. PU - 180K, SO - 120K, ROT - 140K, AST - 3.22, ART- 12.49 4/24/2004 00:00 - 00:30 0.50 DRILL P INT1 Directional Drill 8.5" from 6,735' to 6,820'. TQ on - 9-13K. WOB - 5-15K. PU - 180K, SO - 120K, ROT - 140K. ART - 4.0, AST - 0 00:30 - 01 :30 1.00 DRILL P INT1 I Circulate Bottoms up @ 575 gpm, 2,800 psi, 85 rpm. 10.55 ppg EMW prior to POH for planned wiper trip. Monitor well - static. Printed: 5/10/2004 9:19:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: '--- "~ 15-37 15-37 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/23/2004 Rig Release: 5/7/2004 Rig Number: Spud Date: 6/6/1994 End: 5/7/2004 Date From - To Hours Task Code NPT Phase Description of Operations 4/24/2004 01 :30 - 05:00 3.50 DRILL P INT1 POH from 6,820' to 4,880'. Encountered some tight spots with max overpull of 40K. Worked pipe over those intervals and pipe then pulled clean. From 4,880' to 4,290', BHA entering the window, saw many more intervals which required a longer time to work pipe. At 4,290', an attempt to pump out was made without much success. Backream out of the hole from 4,290' to 3,836', TO - 9K, 70 rpm, 550 gpm, 2,400 psi. 05:00 - 06:30 1.50 DRILL P INT1 Slip and cut drilling line. Adjust Brakes. Service Top Drive. 06:30 - 08:00 1.50 DRILL P INT1 RIH wI 4" DP from 3,836' to 6,820'. Average drag of 15-20k was seen while RIH. Precautionary wash last stand to bottom - no fill on bottom. 08:00 - 09:00 1.00 DRILL P INT1 Pump Hi-Vise sweep and CBU @ 6,820' - 550 gpm, 2,800 psi 09:00 - 12:00 3.00 DRILL P INT1 Directional Drill 8.5" from 6,820' to 7,286'. AST - 0, ART - 1.98, PU - 195K, SO - 115K, ROT - 145K. TO on - 13-14K, TO off- 10-13K. 12:00 - 00:00 12.00 DRILL P INT1 Directional Drill 8.5" from 7,286' to 8,414'. AST - 3.51, ART- 4.5, PU - 195K, SO - 125K, ROT - 150K. TO on - 11-15K, TO off - 9-12K. 4/25/2004 00:00 - 00:30 0.50 DRI LL P INT1 Directional Drill 8.5" from 8,414' to 8,448'. PU - 195K, SO - 125K, ROT - 150K. TO on - 11-15K, TO off - 9-12K. AST- 0.25, ART - 0 00:30 - 01 :00 0.50 DRILL N RREP INT1 Circulate with one pump & work drill string while changing swab in #1 Mud Pump. 01 :00 - 07:00 6.00 DRILL P INT1 Directional Drill 8.5" from 8,448' to 9001'. PU - 200K, SO - 135K, ROT - 162K. TO off - 8-9K, TO on - 11-12K. AST- 1.37, ART - 2.62 07:00 - 07:30 0.50 DRILL P INT1 Circulate & increase mud weight from 9.8 ppg to 10.2 ppg. 07:30 - 14:45 7.25 DRILL P INT1 Directional Drill 8.5" from 9,001' to 9434'. PU - 200K, SO - 135K, ROT - 162K. TO off - 8-9K, TO on - 11-12K. AST- 2.91, ART - 1.53 14:45 - 16:00 1.25 DRILL P INT1 Pump sweep. Circulate hole clean from 9434'. Reciprocate & rotate (100 rpm) while circulating. Flow check. Well static. Pump slug. 16:00 - 17:00 1.00 DRILL P INT1 POOH for wiper trip from 9434'. The first 10 stands pulled normal with 10-20k drag. From 8500' to 7990' hole pulling tight with 30-60k drag. Wipe through each tigh spot. This eliminated the tight hole problem but hole not taking the proper amount of mud on fill ups. Pulled 15 stands total. 17:00 - 17:30 0.50 DRILL P INT1 TIH to 9339' with no problems. M/U TDS. Establish circulation. Precautionary wash & ream to bottom. No Fill. Pump Lo-Vis sweep. 17:30 - 19:00 1.50 DRILL P INT1 Circulation & condition mud @ 9434'. 19:00 - 21 :00 2.00 DRILL P INT1 Flow Check - okay. POH from 9,434' to 7,748' with 10-25K drag. Pulled 50K over @ 7,748'. Worked pipe and then pulled clean to 7,643'. At 7,643', we tried multiple attempts to work pipe and reduce the overpull with no success. Hole was taking correct fill. 21 :00 - 22:00 1.00 DRILL P INT1 Backream out of the hole from 7,643' to 7,416' - 90 rpm, 500 gpm, 3,400 psi. Hole torque started to stall the rotary. 80 bbls mud lost to the formation without any indication on PWD of exceding ECD limitations - max seen was 11.1 ppg. 22:00 - 23:00 1.00 DRILL P INT1 RIH from 7,416' to 9,339':- Precautionary wash and ream last stand to bottom. GainedAO bbls back on trip in. Printed: 5/10/2004 9:19:44 AM -- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/25/2004 4/26/2004 4/27/2004 '- 15-37 1 5-37 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I From - To I Hours Task 23:00 - 00:00 1.00 DRILL 00:00 - 02:30 02:30 - 04:30 04:30 - 11 :30 11 :30 - 12:00 12:00-13:00 13:00 - 16:00 16:00 - 00:00 00:00 - 01 :45 01:45-02:15 02: 15 - 04:30 04:30 - 07:00 07:00 - 07:30 07:30 - 10:00 10:00 - 11 :30 11 :30 - 14:30 14:30 - 16:30 16:30 - 20:30 20:30 - 00:00 Code NPT P INT1 2.50 DRILL P INT1 2.00 DRILL P INT1 7.00 DRILL P INT1 0.50 DRILL 1.00 DRILL P P INT1 INT1 3.00 DRILL INT1 P 8.00 DRILL P INT1 1.75 DRILL P INT1 0.50 DRILL N RREP INT1 2.25 DRILL P INT1 2.50 DRILL P INT1 0.50 DRILL P INT1 2.50 DRILL P 1.50 DRILL P 3.00 DRILL P INT1 INT1 INT1 2.00 DRILL P INT1 4.00 DRILL P INT1 3.50 DRILL P INT1 Start: Rig Release: Rig Number: Phase I 2/23/2004 5/7/2004 Spud Date: 6/6/1994 End: 5/7/2004 Description of Operations Circulate and condition fluid. Pump low-visc sweep around to ensure hole is clean. PWD reading 10.98 ppg. No appreicable amount of cuttings coming back over the shakers. 100 rpm, 570 gpm, 3400 psi. Loss of 19 bbls while circulating. Total loss for the day of 59 bbls. Circulate another low-vise sweep around. No appreciable solids seen across the shakers. PWD reading 10.98 ppg, 100 rpm, 3,500 psi, 540 gpm. Monitor well. Blow down surface equipment. Losses slowed to 6 bph. POH from 9,434' to 7,356'. At 7,356' we pulled 60K over. Same result after multiple attempts. Attempt to pump out of the hole was unsuccessful. Backream out of the hole from 7,356' to 6,820'. POOH to 6,709'. Hole tight. Backream to 6,258'. POOH from 6,258' to 9-5/8" casing shoe with no other problems. Clean rig floor. Service Top Drive. CBU x 2 from 3,836'. Had a considerable amount of cuttings come over shakers. The cuttings were clay mixed with silt & LCM. TIH to 9,342' with no problems. Precautionary wash to bottom @ 9,434'. Pump sweep. C & C mud prior to the start of drilling. Had a considerable amount of cuttings come over shakers. Dritl 8-1/2" hole from 9,434' to 9,935'_ AST - 3.97, ART - 1.42. TO on - 13-16K, TO off - 12-14K. PU - 240K, SO - 145K, ROT - 170K. No Losses. Total Losses for the day - 78 bbls Drill directionally from 9,935' to 10,030'. AST - 1.02, ART - 0.37. TO on - 13-15K, TO off - 11-13K. PU - 240K, SO- 145K, ROT - 170K. Circulate with one pump & work drill string while changing swab in #1 Mud Pump. Drill directionally from 10,030' to 10,164 DPM (TD). PU - 245K, SO - 145K, Rot - 183K. TO on - 14K, TQ off - 12K. AST- 0.67, ART - 0.68. Circulate bottoms up sample to correlate with MWD logs. Circulate sweep around and condition fluid for wiper trip to the shoe. 540 gpm, 100 rpm, 3400 psi. ECD - 11.04 ppg. POH with 4" DP from 10,164' to 9,247'. Monitor well - static. Slug pipe and blowdown surface equipment. POH from 9,247' to 3.836' - 40K drag from 8,530' to 8,500'. Cut drilling line and service top drive. RIH with 4" DP from 3,836' to 10,164'. Precautionary wash last stand down. Tight spots seen with 25K drag @ 8,693', 9,155', 9,205' and 9,310'. Circulate and condition mud to run casing - 550 gpm, 3,500 psi. Saw an excess of cuttings across the shakers. Flow check the well - stable. POH 10 stands DP from 10,164' to 9,230'. Flow check - static. Pump slug and continue POH from 9,230' to the top of the BHA @ 1,131'_ LD HWDP and BHA from 1,131' to~90'. Flush the MWD tools with water and download same. Printed: 5/10/2004 9:19:44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: -- 15-37 15-37 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 4/28/2004 00:00 - 02:00 2.00 DRILL P INT1 02:00 - 02:30 0.50 BOPSUF P INT1 02:30 - 05:15 2.75 CASE P LNR1 05:15 - 09:00 3.75 CASE P LNR1 09:00 - 09:30 09:30 - 11 :30 11 :30 - 12:00 0.50 CASE P 2.00 CASE P 0.50 CASE P 12:00 - 14:30 2.50 CASE P LNR1 14:30 - 15:00 0.50 CASE P LNR1 15:00 - 23:00 8.00 CASE P LNR1 23:00 - 00:00 4/29/2004 00:00 - 01 :00 01 :00 - 03:30 1.00 CEMT P 1.00 CEMT P 2.50 CEMT P -- LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 Start: 2/23/2004 Rig Release: 5/7/2004 Rig Number: Spud Date: 6/6/1994 End: 5/7/2004 Description of Operations LD BHA from 90'. Break out bit, graded - 3/2/LT/N/X/1/ERfTD. Clean and clear the floor in preparation to run 7" casing. Pull Wear Bushing. Changeout Saver Sub. MU Franks fill-up tool, RU scaffold, 350 Tons and other casing running equipment. PJSM. PU 7", 26#, BTC-M, L-80 Float Shoe Joint, Single Joint, and Float Collar (80' shoe tract) and RIH Baker lock Shoe Tract. RIH with 7" casing to 2,500'. All connections torqued to 8,000 ft-Ibs. Pushing fluid while running in the hole. Attempt to regain Circulation by CBU @ 2,500' @ 2 bpm, 150 psi. RIH with 7" casing from 2,500' to 3,881'. CBU @ 3,881'. Stage up pump to 6 bpm @ 550 psi. PU- 105K, SO - 95K. Had to back the pump down to 5 bpm due to losing fluid. Shut down the pump and monitored the well - breathing. Total Losses for the last 12 hours - 20 bbls. RIH with 7" casing from 3,881' to 5,200'. Fill each joint with the Franks fillup tool and top off every 10 joints. Break circulation every 20 joints. CBU @ 5,200' - 3 bpm, 400 psi. Circulate 3/4 of a full bottoms up with partial returns. Shut down. Well breathing. RIH with 7" casing from 5,200'. Broke circulation with 30 bbls every 1000'. At 6,300' - 3 bpm, 440 psi. At 7,300' - 3 bpm, 445 psi. Breathing ceased over this interval and anything lost, stayed in the hole. Attempted to break circulation @ 8,300' and got back 21 bbls of the 30 bbls pumped. RIH to 9,000' and attempt to break circulation again. Pumped 30 bbls with no returns. Cut the circulaton short and RIH. Saw drag up to 50K from 9,914' to bottom. Tag bottom @ 10,164'. Attempt to gain circulation on bottom through fillup tool. RD Franks fillup tool and RU cement head. Attempt to regain circulation by staging up the pumps from 0.5 bpm to 3 bpm. Total Losses durning RIH - 260 bbls. (98 bbls from steel displacement and 162 bbls from the mud system) Continue to circulate in an attempt to regain circulation. Pumped 100 bbls without any returns. Hold PJSM for cement job while circulating. Line up Schlumberger to pump cement. The job went as follows: Pumped 5 bbls FW and pressure tested lines to 4,000 psi Pump 27 bbls of 11 ppg Mudpush II spacer @ 5 bpm, 750 psi Drop plug - indicated by tattletail on cement head Pump 157 bbls of 12 ppg Lead Cement Slurry. Initial Conditions - 4.8 bpm, 630 psi. Final Conditions - 4.8 bpm, 330 psi. Pump 29 bbls of 15.8 ppg Class G + adds. Initial Conditions - 3.7 bpm, 210 psi. Final conditions - 3 bpm, 100 psi. Drop plug - indicated by tattletail on cement head. Pump 5 bbls FW to chase the plug from the head and switch Printed: 5/10/2004 9:19:44 AM -- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 4/29/2004 01 :00 - 03:30 03:30 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 12:30 12:30 - 13:30 13:30 - 16:00 16:00 - 18:00 18:00 - 21 :00 21 :00 - 21 :45 21 :45 - 22:30 22:30 - 00:00 4/30/2004 00:00 - 01 :30 01 :30 - 03:15 .~ -- 15-37 15-37 R EENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Hours Task Code NPT i Phase P I LNR1 2.50 CEMT 6.00 CEMT P 0.50 CASE P 0.50 CEMT P 2.00 CASE P 1.00 BOPSUP P 2.50 BOPSUF P 2.00 BOPSUF P 3.00 BOPSUF P 0.75 BOPSUF P 0.75 CASE P 1.50 DRILL P 1.50 DRILL P 1.75 DRILL P - LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 PROD1 PROD1 PROD1 Start: 2/23/2004 Rig Release: 5/7/2004 Rig Number: Spud Date: 6/6/1994 End: 5/7/2004 Description of Operations over to the Rig for the remainder of the displacement with 10.2 ppg mud.. Caught the cement -600 strokes @ 6.5 bpm, 320 psi. Reduce rate to 5.2 bpm, 300 psi. At -3,500 strokes, 5.2 bpm, the pressure started to increase as the 12 ppg cement rounded the shoe. At -4,350 strokes the pressure flatlined @ 700 psi, 5.2 bpm. At 5,831 strokes, reduced the rate to 3 bpm, 420 psi. At -6,000 strokes the pressure again started to increase as the tail slurry rounded the shoe. At 6,276, switched from displacing with mud to displacing with FW. Also reduced the rate to 2 bpm. The pressure prior to reducing the rate was 570 psi and the pressure after reducing the rate was 500 psi. The pressure continued to increase to 620 psi, 2 bpm when we exceeded the strokes to bump the plug @ 96% efficiency - 6,577 (381.3 bbls + 5 bbls from Dowell). Total displacement of 386.3 bbls fluid. The plug did not bump. Bleed off pressure and check the floats - not holding. Shut in at the cement head and for WOC. Total fluid lost during the cement job - 620 bbls. Cement in place @ 0330 wac. Monitor well on the trip tank. Gain of 4 bbls. Cement compressive strength 1,000 psi. Perform injectivity test with 10 bbs of 10.2 ppg mud @ 3 bpm, 650 psi. Blow down surface equipment. Bleed off 7" casing - no flow back. RD cement head and clear the floor Monitor well - breathing. Shut in backside - 100 psi after 1 hour. Bleed off pressure and monitor the well - 1 bbls gained and then flow stopped. Drain annulus and remove fluid from the 7" landing joint. Blow down lines. ND and raise BOP's. PU 340K on casing. Set slips. Cut and Bevel casing with Wachs cutting and bevelling tool from Cameron. Install primary packoff. Run in lock down screws. Install secondary packoff in the tubing hanger. Test choke mainfold to 3,500 psi in simultaneous operation. NU BOP's and test pack off to 4,300 psi for 10 minutes - good test. MU test joint and RIH with test plug. Test BOPE to 250 psi low and 3,500 psi high. Pull the test plug and run the wear ring. Rig down the test joint. John Spaulding of the AOGCC waived the witnessing of the BOP E test. Test the top drive BOP's. Freeze protect the 7" x 9-5/8" annulus with LRHOS. Pump 60 bbls of diesel down annulus. OASIP - 800 psi. Pressure test the 7",26#, L-80, BTC-M casing to 3,500 psi and hold for 30 minutes - good test. Bleed off pressure. PU BHA #3. 6-1/8" Hughes Insert MX20DX bit,S" Motor, Non Mag Float sub, and 4-3/4" GR/RES tool. Orient and Upload MWD tools. PU BHA # 3 from 69' to 389'. Hold Pre-job meeting prior to loading the nuclear source into the LWD tool. PU 4" DP. RIH from 389' to 3,469'. Fill pipe and test MWD_- Printed: 5/10/2004 9:19:44 AM -- Legal Well Name: 15-37 Common Well Name: 15-37 Spud Date: 6/6/1994 Event Name: REENTER+COMPLETE Start: 2/23/2004 End: 5/7/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/7/2004 Rig Name: NABORS 2ES Rig Number: Date From - To Hou rs Task I Code NPT Phase Description of Operations 4/30/2004 01:30-03:15 1.75 DRILL P PROD1 good. 03: 15 - 05:00 1.75 DRILL P PROD1 RIH with 4" DP from 3,469' to 9,717'. Fill pipe every 3,000'. 05:00 - 05:30 0.50 DRILL P PROD1 Service Top Drive and MU Blower hose. 05:30 - 06:00 0.50 DRILL P PROD1 RIH with 4" DP from 9,717' and tag up on cement stringer at 9,990'. 06:00 - 08:00 2.00 DRILL P PROD1 Circulate and condition mud. Drill cement stringers from 9,990 to tag of float collar @ 10,071'. Drill up float collar. 08:00 - 10:30 2.50 DRILL P PROD1 Displace well over to new 8.5 ppg FloPro mud. 10:30 - 11 :30 1.00 DRILL P PROD1 Drill remaining shoe tract and 20' of new hole to 10,184' MD. 11 :30 - 12:00 0.50 DRILL P PROD1 Perform FIT with 8.4 ppg mud to EMW of 9.6 ppg (515 psi Surface Pressure). TVD - 8,244' 12:00 - 00:00 12.00 DRILL P PROD1 Directional Drill from 10,184' to 10,538'. AST - 7.27, ART- 2.33, PU - 175K, SO - 135K, ROT - 155K, TO on - 6K, TO off - 5K. 5/1/2004 00:00 - 08:00 8.00 DRILL P PROD1 Directional Drill from 10,538' to 10,651'. PU - 180K, SO- 135K, ROT - 155K, TO on - 6K, TO off - 5K. ART - 0.16, AST - 5.55 08:00 - 08:30 0.50 DRILL P PROD1 Circulate hole clean in preparation for trip. Monitor well - stable. ! 08:30 - 10:00 1.50 DRILL P PROD1 POH from 10,651' to 10,092'. Monitorwell- stable. Open circ I sub and circulate a sweep around at 12 bpm, 1,950 psi. Pump dry job and blow down the Top Drive. 10:00 - 13:00 3.00 DRILL P PROD1 POH from 10,092' to 388'. 13:00 - 14:00 1.00 DRILL P PROD1 Handle BHA from 388' to 105'. PJSM. Clear floor and remove radioactive source. 14:00 - 14:30 0.50 DRILL P PROD1 Handle BHA. Changeout Bit and Kick Pad. Adjust Motor to 1.83 bend. Changeout jet in Motor. Install Stabilizer and handle BHA to 105'. 14:30 - 15:00 0.50 DRILL P PROD1 PJSM. Insert radioactive source. Read MWD tools. 15:00 - 15:30 0.50 DRILL P PROD1 Handle BHA from 105' to 393'. Changeout elevators and RIH 1 stand to 486'. 15:30 - 16:00 0.50 DRILL P PROD1 Shallow pulse test MWD tools @ 486' - good. 250 gpm, 930 psi. Blow down surface equipment. 16:00 - 19:00 3.00 DRILL P PROD1 RIH with 4" DP from 486' to 10,097'. Fill pipe every 3,000'. 19:00 - 20:30 1.50 DRILL P PROD1 Cut off drilling line. Service Top Drive. Install Blower Hose. Fill pipe. 20:30 - 21 :00 0.50 DRILL P PROD1 RIH with DP from 10,097' to 10,651'. Precautionary ream of last stand - no fill. 21 :00 - 00:00 3.00 DRILL P PROD1 Directional Drill from 10,651' to 10,775'. PU - 180K, SO- 135K, ROT - 160K, TO on - 7K, TO off - 6K. ART - 1.23, AST - 0.45 5/2/2004 00:00 - 12:00 12.00 DRILL P PROD1 Directional Drill from 10,775' to 11,235'. PU - 180K, SO- 135K, ROT - 160K, TO on - 7K, TO off - 6K. AST - 5.43, ART - 2.28. 12:00 - 00:00 12.00 DRILL P PROD1 Directional Drill from 11,235' to 12,020'. PU - 180K, SO- 130K, ROT - 155K, TO on - 9K, TO off - 6K. AST - 2.6, ART - 4.03. 5/3/2004 00:00 - 07:30 7.50 DRILL P PROD1 Directional Drill from 12,020' to 12,471'. PU - 180K, SO- 125K, ROT - 155K, TO on - 8K, TQ off - 7K. AST - 2.33, ART - 2.28. 07:30 - 09:30 2.00 DRILL P PROD1 Circulate a Hi-Vise sweep and 3 bottoms up to clean up the hole - 8 bpm, 2,670 psi. Monitor well - stable. 09:30 - 10:30 1.00 DRILL P PROD1 Short trip to the shoe from 12,471' to 10,097'. No tight spots. Printed: 5/10/2004 9:19:44 AM --- -- --' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 15-37 1 5-37 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To i Hours Task Code NPT Start: 2/23/2004 Rig Release: 5/7/2004 Rig Number: Phase 5/3/2004 10:30 - 11 :00 0.50 DRILL P 11 :00 - 12:00 1.00 DRILL P 12:00 - 14:30 2.50 DRILL P 14:30 - 16:00 1.50 DRILL P 16:00 - 17:00 1.00 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 17:00 - 20:00 3.00 DRILL P 20:00 - 20:30 0.50 DRILL P 20:30 - 21 :30 1.00 DRILL P 21 :30 - 22:00 0.50 DRILL P 22:00 - 22:30 0.50 CASE P 22:30 - 23:00 0.50 CASE P 23:00 - 00:00 1.00 CASE P 5/4/2004 00:00 - 01 :00 1.00 CASE P 01 :00 - 01 :30 0.50 CASE P 01 :30 - 02:00 0.50 CASE P 02:00 - 05:30 3.50 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 07:30 1.50 CASE P 07:30 - 09:30 2.00 CASE P I 1.00 CEMT P 09:30 - 10:30 ' PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 10:30 - 11 :00 0.50 CEMT P COMP 11 :00 - 12:30 1.50 CEMT P COMP 12:30 - 13:00 0.50 CASE P COMP 13:00 - 13:30 0.50 CASE P COMP 13:30 - 17:30 4.00 CASE P COMP Spud Date: 6/6/1994 End: 5/7/2004 Service the top drive. RIH to TD from 10,097' to 12,471'. No excess drag. Circulate a Hi-Visc sweep and 3 bottoms up to clean up the hole - 8 bpm, 2,670 psi. Monitor well - stable. Pump dry job. LDDP from 12,471' to 10,164'. Drop dart and open the circ sub. CBU @ 13 bpm and 2,100 psi. Pump dry job. Blow down surface equipment. Remove top drive blower hose. POH with 4" DP from 10,164' to top of the BHA at 393'. LD BHA from 393' to 141'. Flush MW D tools with water. Blow down surface equipment. PJSM. Remove nuclear source. Download MWD tools. LD BHA from 141'. Clean and clear the floor. PJSM. RU 4-1/2" casing handling equipment. PU and Bakerlock the 4-1/2" Float Shoe joint, Float Collar Joint, Insert Landing collar joint and RIH. Check Floats - good. PU 4-1/2", 12.6#, L-80, IBT-M liner to 1,267'. Torqued to mark @ 3,900 ft-Ibs. Fill Pipe every 5 joints. PU 4-1/2",12.6#, L-BO, IBT-M liner from 1,267' to 2,441. Torqued to mark @ 3,900 ft-Ibs. Fill Pipe every 5 joints. Change out handling equipment and MU ZXP Packer/HMC Hanger assembly. RIH with 1 stand of 4" DP and circulate liner volume - 3 bpm, 230 psi. PU - 60K, SO - 55K. RIH with 4-1/2" Liner on 4" DP from the derrick from 2,474' to the 10,111', filling pipe every 10 stands. Circulate pipe volume at 5 bpm, 790 psi. PU - 165k, SO - 130k. RIH f/ 10111' to 12445, MU cmt hd Brk circ at 1 bpm, 480 psi, Tag fill at 12455', washed down to 12471', staged pumps up to 5 bpm, 1200 psi, PU - 190k, SO- 135k, Circ and reciprocate pipe, PJSM with all invovled personnel, Batched Mixed Cement Pumped cmt job as follows: 5 bbls of H20, test lines to 4500 psi, 15 bbls of CW1 00, 30 bbls of mudpush11 at 9.5 ppg, 63 bbls of CL G cmt with latex at 15.8 ppg at 5 - 3 bpm f/ 1350 - 439 psi, wash lines, bumped pill with 135 bbls of perf pill and mud at 7 - 3 bpm f/ 558 - 1653 psi, bumped plug with 4200 psi and set liner hanger at 10012', cement in place at 10:30 hours on 05/04/04, released pressure, check floats, holding, rotate to release f/ liner hgr. Note reciprocated liner until cement rounded corner, hole sticky, unable to get back to bottom, float shoe 5' off bottom at 12466' float collar at 12421', landing collar at 12378', TOL at 9998' Circ 8.5 ppg mud at 12 bpm with 3100 psi, recovered -16 bbls of cement in returns Displace well to clean seawater at 12 bpm at 3100 psi, string wt 160k up, 130k dn Weight and rotate set liner packer several times with SO to 65 k. Blow down surface lines, RD cement rotary hd, related valves and hoses POH, LD Baker running tool, cleared floor Printed: 5/10/2004 9:19:44 AM - ~- -- BP EXPLORATION . __ -_ -._., n___ ___ __n _ __ _ .__ ___ _. ... OperationsS,utnl11ary<Rep9rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-37 15-37 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT 5/4/2004 17:30 - 18:00 0.50 CASE P 18:00 - 19:00 1.00 PERF P 19:00 - 19:30 0.50 CASE P 19:30 - 21 :00 1.50 PERF P 21 :00 - 23:00 2.00 PERF P 23:00 - 00:00 1.00 PERF P 5/5/2004 00:00 - 03:30 3.50 PERF P 03:30 - 03:45 0.25 PERF P 03:45 - 04:00 0.25 PERF P 04:00 - 04:30 0.50 PERF P Phase COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 04:30 - 05:30 1.00 PERF P COMP 05:30 - 06:30 1.00 PERF P COMP 06:30 - 11 :00 4.50 PERF P COMP 11 :00 - 13:00 2.00 PERF P COMP 13:00 - 17:30 4.50 PERF P COMP 17:30 - 18:00 0.50 PERF P COMP 18:00 - 19:00 1.00 PERF P COMP 19:00 - 19:30 0.50 RUNCOrvP COMP 19:30 - 21 :00 1.50 RUNCOrvP COMP 21 :00 - 21 :30 0.50 RUNCOrvP COMP 21 :30 - 00:00 2.50 RUNCOrvP COMP 5/6/2004 00:00 - 11 :00 11.00 RUNCOrvP 11 :00 - 13:30 2.50 RUNCOrvP 13:30 - 15:00 1.50 RUNCOrvP 15:00 - 15:30 15:30 - 17:30 17:30 - 20:00 20:00 - 21 :00 21 :00 - 00:00 0.50 RUNCOrvP 2.00 BOPSUP. P 2.50 WHSUR P 1.00 WHSUR P 3.00 WHSUR P COMP COMP COMP COMP COMP COMP COMP COMP F>élgeJ9of 11 Start: 2/23/2004 Rig Release: 5/7/2004 Rig Number: Spud Date: 6/6/1994 End: 5/7/2004 Service Top Drive RU handling equipment for perf guns and 27/8" workstring, load pipeshed with guns Pressure test 4 1/2' liner back to surface with 3500 psi for 30 minutes. OK. Held PJSM on handling running and firing Perf guns PU, RIH wI 27/8" perf guns with 6 spf and 4 spf to 1346' PU, RIH w/2 7/8" DP fl 1346' - 2423' RIH wI 4" DP to 5039' RIH wI 4" DP fl 5039' to 12378' tagged up on landing collar, PU 185k, SO 145k POH LD 2 joints of DP, Position guns with bottom shot at 12320' and top shot at 11000' Held PJSM with crew, discussed perforating job Pressured up to 2600 psi, bleed off pressure to 0 psi, monitor well, guns fired within 8 minutes after pressure was bled off, fluid level drop 10' in well, good surface indication on graph that guns fired. Monitor well, stable, POH wI 15 stands to 10940', Monitor well, stable Slip and cut drill line, while monitoring well, inspect brakes, static loss rate at 3 bph POH LD 4" DP fl 10940 - 2419 POH LD 2 7/8" DP f/2419-1346' PJSM on handling fired perf guns, POH LD perf guns, all shots fired, cleared and cleaned floor MU mule shoe, RIH wI 4' DP to 1400' POH LD 4" DP Pull wear rung RU 41/2" handling equipment, tongs, compensator PJSM on running 4 1/2" 13CR completion PU, RIH w/4 1/2" 12.6# 13CR VAM TOP completion string to 2150', MU torque is 4440 ft-Ibs, thread dope is jet lube, baker locked tubing tail from packer down, all tubing was drifted to 3.833" , No fluid lost to well PU, RIH w/4 1/2" 12.6# 13CR VAM TOP completion string, tag up, Space out, land tbg hgr, RILDS MU torque is 4440 ft-Ibs, thread dope is jet lube, all tubing was drifted to 3.833", Up Wt 130 k, So Wt 105 k Rev Circ well with clean seawater treated with corrosion inhibitor at 3bpm, 250 psi Drop 1 7/8" ball and rod assy wI 1 3/8' fishing neck down tubing on top of RHC-M plug in XN nipple at 9996', Pressure up to 3500 psi, set packer, test tubing for 30 minutes, bleed tubing down to 1500 psi, test annulus to 3500 psi for 30 minutes, good test on tbg and annulus, bleed off pressure on tubing, shear out DCK valve in GLM at 3469'. Set TWC, test fl below to 1000 psi ND BOP Stack NU adapter flange and tree, test to 5000 psi RU DSM, pull TWC wI lubricator RU, t~st circ lines to 3500 psi, pump 76 bbls of 60 degrees diesel down tbg annulus at 2.5 bpm 800 psi, U-tube to tubing Printed: 5/10/2004 9:19:44 AM -- '-'" Date 15-37 15-37 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To Hours Task I Code I NPT 00:00 - 00:30 0.50 WHSUR P 00:30 - 01 :00 0.50 WHSUR P 01 :00 - 02:00 1.00 WHSUR P Start: 2/23/2004 Rig Release: 5/7/2004 Rig Number: Spud Date: 6/6/1994 End: 5/7/2004 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Phase Description of Operations 5/7/2004 COMP COMP COMP Finished U-tubing Diesel to tbg for freeze protect Set BPV, Test to 1000 psi RD Circ lines, and secondary annulus valve, secured well, RELEASED RIG AT 0200 HOURS on 05/07/04 Printed: 5/10/2004 9:19:44 AM ~- -~_.' ~ AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-378 ,{2Ö4-- Ole¡ 21-May-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 3,827.93' MD Window / Kickoff Survey: 3,881.00' MD (if applicable) Projected Survey: 12,471.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 1 JWtA M~ L~ 1J / Signed ~. oLi~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) À 0 Ll - (j I '{ Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 15 15-37B Job No. AKZZ3034589, Surveyed: 3 May, 2004 Survey Report 18 May, 2004 Your Ref: API 500292248502 Surface Coordinates: 5960055.71 N, 676795.62 E (70017' 47.1011" N, 148034' 05.8492" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 960055.71 N, 176795.62 E (Grid) Surface Coordinates relative to Structure Reference: 1206.19 N, 526.17 E (True) Kelly Bushing Elevation: 59. 50ft above Mean Sea Level Kelly Bushing Elevation: 59. 50ft above Project V Reference Kelly Bushing Elevation: 59. 50ft above Structure Reference SP:E!:r"'r-'Y-J5Uil1 DJ R'n."; I.... fN' G· ·$eft=t v'fi:: e's A Halliburton Company D· -... N pa'D~V \ - _r I. . 1 ~ i .'= -, j œ t! j =-- ( Survey Ref: svy4264 DrillQuest 3.03.06.002 Page 20f6 18 May, 2004 - 15:42 Halliburlon Sperry-Sun Survey Report for PBU _EOA DS 15 - 15-37B Your Ref: API 500292248502 Job No. AKZZ3034589, Surveyed: 3 May, 2004 BPXA North Slope Alaska Measured True 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) (o/100ft) 3827.93 44.310 20.490 3466.97 3526.47 1091.99 N 394.25 E 5961156.67 N 677164.08 E 1 087.26 Tie On Point MWD Magnetic - MWD+IIFR+MS 3881.00 43.860 20.250 3505.09 3564.59 1126.60 N 407.11 E 5961191.57 N 677176.11 E 0.904 1121.95 Window Point 3901.01 43.420 19.270 3519.57 3579.07 1139.60 N 411.78 E 5961204.68 N 677180.47 E 4.032 1134.87 3927.70 43.600 17.960 3538.93 3598.43 1157.01 N 417.64 E 5961222.22 N 677185.93 E 3.446 1151.94 ( 3958.75 44.110 16.440 3561.32 3620.82 1177.56 N 424.00 E 5961242.92 N 677191.80 E 3.768 1171.71 4002.84 44.480 14.250 3592.88 3652.38 1207.25 N 432.15 E 5961272.79 N 677199.25 E 3.569 1199.61 4052.12 44.750 11.810 3627.96 3687.46 1240.96 N 439.95 E 5961306.68 N 677206.25 E 3.520 1230.34 4145.49 44.020 7.160 3694.70 3754.20 1305.34 N 450.72 E 5961371.29 N 677215.51 E 3.570 1286.36 4237.55 43.430 2.580 3761.25 3820.75 1368.71 N 456.13 E 5961434.77 N 677219.43 E 3.497 1338.14 4332.26 42.600 3.920 3830.50 3890.00 1433.21 N 459.79 E 5961499.34 N 677221.57 E 1.304 1389.65 4426.32 41.940 5.260 3900.10 3959.60 1496.27 N 464.85 E 5961562.50 N 677225.14 E 1.188 1440.96 4519.53 41.050 5.240 3969.92 4029.42 1557.77 N 470.50 E 5961624.12 N 677229.34 E 0.955 1491.47 4612.82 40.460 5.390 4040.59 4100.09 1618.41 N 476.14 E 5961684.87 N 677233.56 E 0.641 1541.32 4705.55 39.880 4.830 4111.44 4170.94 1677.99 N 481.47 E 5961744.56 N 677237.48 E 0.737 1590.15 4799.33 41 .450 7.090 4182.58 4242.08 1738.75 N 487.83 E 5961805.46 N 677242.42 E 2.295 1640.57 4893.10 43.730 13.240 4251.64 4311.14 1801.14 N 499.09 E 5961868.09 N 677252.20 E 5.059 1695.38 4986.77 43.680 13.100 4319.36 4378.86 1864.16 N 513.84 E 5961931.44 N 677265.46 E 0.116 1752.94 5079.87 43.850 13.150 4386.59 4446.09 1926.87 N 528.46 E 5961994.48 N 677278.61 E 0.186 1810.19 5172.31 43.230 15.720 4453.61 4513.11 1988.53 N 544.32 E 5962056.49 N 677293.02 E 2.029 1867.43 5265.20 43.120 16.160 4521.35 4580.85 2049.64 N 561.78 E 5962118.00 N 677309.03 E 0.345 1925.30 5358.92 42.920 15.4 70 4589.87 4649.37 2111.16 N 579.21 E 5962179.91 N 677325.00 E 0.546 1983.45 ( 5452.10 43.430 16.220 4657.82 4717.32 2172.50 N 596.61 E 5962241.64 N 677340.97 E 0.776 2041 .45 5544.42 43.680 16.630 4724.73 4784.23 2233.51 N 614.60 E 5962303.06 N 677357.51 E 0.409 2099.58 5637.66 44.110 16.040 4791.92 4851 .42 2295.55 N 632.78 E 5962365.51 N 677374.23 E 0.637 2158.62 5731.12 43.590 15.060 4859.32 4918.82 2357.92 N 650.14 E 5962428.27 N 677390.12 E 0.915 2217.38 5826.23 43.770 16.070 4928.10 4987.60 2421.20 N 667.77 E 5962491.95 N 677406.25 E 0.757 2277.00 5917.18 44.040 20.900 4993.65 5053.15 2480.98 N 687.76 E 5962552.18 N 677424.83 E 3.694 2335.49 6012.74 44.450 24.280 5062.11 5121.61 2542.52 N 713.37 E 5962614.30 N 677448.98 E 2.505 2398.96 6105.04 44.360 23.420 5128.06 5187.56 2601.58 N 739.48 E 5962673.97 N 677473.70 E 0.659 2460.87 6197.25 44.040 23.450 5194.16 5253.66 2660.57 N 765.05 E 5962733.54 N 677497.87 E 0.348 2522.37 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 -15-37B Your Ref: API 500292248502 Job No. AKZZ3034589, Surveyed: 3 May, 2004 BPXA North Slope Alaska Measured True 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) 6292.05 43.430 23.460 5262.66 5322.16 2720.69 N 791.14E 5962794.26 N 677522.54 E 0.644 2585.07 6385.20 42.900 23.730 5330.60 5390.10 2779.09 N 816.64 E 5962853.24 N 677546.66 E 0.603 2646.07 6477.85 42.580 23.590 5398.65 5458.15 2836.68 N 841.88 E 5962911.41 N 677570.54 E 0.360 2706.29 6572.05 42.860 23.490 5467.85 5527.35 2895.27 N 867.40 E 5962970.58 N 677594.67 E 0.306 2767.46 6664.65 43.010 23.290 5535.65 5595.15 2953.16 N 892.44 E 5963029.05 N 677618.35 E 0.219 2827.78 ( 6756.94 42.050 21.810 5603.66 5663.16 3010.77 N 916.37 E 5963087.20 N 677640.91 E 1.502 2887.17 6849.51 42.600 21.650 5672.10 5731.60 3068.67 N 939.45 E 5963145.63 N 677662.62 E 0.605 2946.23 6942.71 42.980 20.830 5740.50 5800.00 3127.68 N 962.38 E 5963205.16 N 677684.16 E 0.723 3006.04 7035.72 44.020 20.330 5807.96 5867.46 3187.62 N 984.88 E 5963265.61 N 677705.25 E 1.178 3066.28 7128.66 45.080 21.070 5874.19 5933.69 3248.61 N 1007.93 E 5963327.13 N 677726.86 E 1.270 3127.67 7214.07 45.270 19.730 5934.40 5993.90 3305.38 N 1029.05 E 5963384.39 N 677746.63 E 1.135 3184.60 7317.66 46.050 22.700 6006.81 6066.31 3374.43 N 1055.86 E 5963454.04 N 677771.81 E 2.184 3254.57 7392.76 46.230 24.080 6058.85 6118.35 3424.13 N 1077.36 E 5963504.23 N 677792.13 E 1.346 3306.35 7503.14 46.620 26.140 6134.94 6194.44 3496.53 N 1111.30 E 5963577.41 N 677824.36 E 1.397 3383.49 7596.93 46.730 27.440 6199.29 6258.79 3557.43 N 1142.05 E 5963639.02 N 677853.67 E 1.015 3449.80 7690.55 46.920 30.030 6263.36 6322.86 3617.29 N 1174.87E 5963699.63 N 677885.07 E 2.028 3516.66 7783.95 46.220 31.410 6327.57 6387.07 3675.60 N 1209.51 E 5963758.74 N 677918.33 E 1.309 3583.53 7876.55 45.450 32.200 6392.09 6451.59 3732.05 N 1244.52 E 5963816.00 N 677952.00 E 1.032 3649.21 7971.52 43.700 30.780 6459.73 6519.23 3788.87 N 1279.34 E 5963873.63 N 677985.48 E 2.120 3715.06 8064.39 43.070 30.720 6527.23 6586.73 3843.70 N 1311.96 E 5963929.20 N 678016.80 E 0.680 3777.95 8159.78 43.050 31.890 6596.92 6656.42 3899.34 N 1345.80 E 5963985.63 N 678049.32 E 0.838 3842.26 8252.54 42.980 30.980 6664.75 6724.25 3953.33 N 1378.80 E 5964040.38 N 678081.04 E 0.673 3904.77 ( 8346.59 42.250 29.570 6733.96 6793.46 4008.32 N 1410.90 E 5964096.11 N 678111.84 E 1.278 3967.46 8438.74 43.690 30.410 6801.39 6860.89 4062.72 N 1442.30 E 5964151.23 N 678141.96 E 1.682 4029.24 8532.08 44.110 30.060 6868.65 6928.15 4118.63N 1474.89 E 5964207.90 N 678173.22 E 0.520 4092.95 8624.14 44.930 30.830 6934.28 6993.78 4174.28 N 1507.60 E 5964264.30 N 678204.61 E 1.066 4156.52 8717.68 46.130 31.350 6999.81 7059.31 4231.44 N 1542.07 E 5964322.25 N 678237.73 E 1.343 4222.40 8810.85 46.800 32.000 7063.99 7123.49 4288.92 N 1577.54 E 5964380.55 N 678271.84 E 0.879 4289.17 8904.57 46.020 30.770 7128.61 7188.11 4346.86 N 1612.90 E 5964439.31 N 678305.82 E 1.263 4356.21 8996.80 45.690 30.190 7192.84 7252.34 4403.90 N 1646.47 E 5964497.12 N 678338.04 E 0.576 4421.41 9090.43 44.980 29.160 7258.66 7318.16 4461.75 N 1679.44 E 5964555.74 N 678369.64 E 1.090 4486.84 9183.82 44.440 27.900 7325.03 7384.53 4519.47N 1710.82E 5964614.18 N 678399.65 E 1.111 4551.14 9278.42 42.210 28.600 7393.85 7453.35 4576.65 N 1741.53 E 5964672.06 N 678429.01 E 2.411 4614.59 9370.40 38.800 30.870 7463.78 7523.28 4628.53 N 1771.12E 5964724.62 N 678457.37 E 4.039 4673.28 9465.85 35.240 32.660 7539.98 7599.48 4677.40 N 1801.34 E 5964774.19 N 678486.43 E 3.897 4730.08 18 May, 2004 - 15:42 Page 3 of6 DrillQuest 3.03.06.002 DrillQuest 3.03.06.002 Page 4 of6 18 May, 2004 - 15:42 Halliburlon Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-37B Your Ref: AP/500292248502 Job No. AKZZ3034589, Surveyed: 3 May, 2004 BPXA North Slope Alaska Measured True 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) 9559.07 30.620 30.500 7618.20 7677.70 4720.52 N 1827.91 E 5964817.93 N 678511.98 E 5.113 4780.15 9652.98 26.000 27.590 7700.86 7760.36 4759.40 N 1849.60 E 5964857.30 N 678532.75 E 5.133 4823.81 9746.90 22.450 27.970 7786.50 7846.00 4793.49 N 1867.55 E 5964891.80 N 678549.89 E 3.783 4861.41 9840.06 19.400 30.210 7873.51 7933.01 4822.58 N 1883.68 E 5964921.26 N 678565.34 E 3.384 4894.02 9933.33 16.780 28.780 7962.16 8021.66 4847.77 N 1897.96 E 5964946.78 N 678579.02 E 2.849 4922.46 (' 1 0027.46 14.610 25.360 8052.77 8112.27 4870.41 N 1909.59 E 5964969.69 N 678590.11 E 2.505 4947.24 10099.70 11.700 20.800 8123.11 8182.61 4885.49 N 1916.09 E 5964984.92 N 678596.26 E 4.274 4962.94 10161.75 11.610 24.810 8183.89 8243.39 4897.04 N 1920.95 E 5964996.58 N 678600.84 E 1.313 4974.89 10211.26 9.190 28.880 8232.58 8292.08 4905.03 N 1924.95 E 5965004.66 N 678604.65 E 5.105 4983.56 10305.64 10.000 36.250 8325.64 8385.14 4918.24 N 1933.43 E 5965018.07 N 678612.82 E 1.557 4999.12 10339.31 13.560 52.820 8358.61 8418.11 4922.98 N 1938.31 E 5965022.93 N 678617.59 E 14.485 5005.89 10370.98 15.700 56.680 8389.25 8448.75 4927.58 N 1944.85 E 5965027.68 N 678624.02 E 7.422 5013.63 10398.98 16.670 60.400 8416.14 8475.64 4931.64 N 1951.51 E 5965031.90 N 678630.58 E 5.069 5021.04 1 0433.17 19.040 74.040 8448.69 8508.19 4935.60 N 1961.14 E 5965036.08 N 678640.11 E 14.014 5030.30 1 0464.49 21.970 84.840 8478.04 8537.54 4937.54 N 1971.89 E - 5965038.26 N 678650.82 E 15.242 5038.74 10492.62 25.450 92.880 8503.80 8563.30 4937.71 N 1983.17 E 5965038.70 N 678662.09 E 16.861 5046.18 10527.14 30.530 100.580 8534.28 8593.78 4935.72 N 1999.22 E 5965037.09 N 678678.18 E 18.033 5055.06 10551.80 33.520 102.620 8555.18 8614.68 4933.08 N 2012.02 E 5965034.76 N 678691.04 E 12.893 5061.34 10584.84 36.600 106.740 8582.23 8641.73 4928.25 N 2030.36 E 5965030.36 N 678709.49 E 11.752 5069.55 10618.95 41.940 107.870 8608.63 8668.13 4921.82 N 2050.96 E 5965024.41 N 678730.24 E 15.794 5077.99 10649.29 46.570 111.630 8630.36 8689.86 4914.64 N 2070.87 E 5965017.71 N 678750.31 E 17.535 5085.42 10677.30 51.220 111.350 8648.76 8708.26 4906.91 N 2090.50 E 5965010.44 N 678770.12 E 16.618 5092.25 ( 10713.41 57.530 110.110 8669.79 8729.29 4896.54 N 2117.94E 5965000.72 N 678797.80 E 17.695 5102.13 10744.90 60.570 109.800 8685.98 8745.48 4887.33 N 2143.33 E 5964992.10 N 678823.39 E 9.691 5111.56 1 0772.73 61.070 108.770 8699.55 8759.05 4879.30 N 2166.26 E 5964984.62 N 678846.50 E 3.697 5120.30 10807.97 64.620 106.960 8715.63 8775.13 4869.69 N 2196.10 E 5964975.72 N 678876.56 E 11.061 5132.31 10839.07 67.720 107.290 8728.20 8787.70 4861.32 N 2223.28 E 5964967.98 N 678903.94 E 10.015 5143.54 10867.01 69.700 107.590 8738.34 8797.84 4853.51 N 2248.12 E 5964960.76 N 678928.95 E 7.157 5153.69 10900.95 76.280 106.130 8748.26 8807.76 4844.11 N 2279.16 E 5964952.10 N 678960.20 E 19.818 5166.64 10931.27 82.070 105.890 8753.96 8813.46 4835.90 N 2307.78 E 5964944.56 N 678989.00 E 19.112 5178.92 10958.75 86.170 103.720 8756.77 8816.27 4828.92 N 2334.20 E 5964938.20 N 679015.58 E 16.861 5190.72 10992.78 88.890 101.490 8758.24 8817.74 4821.50 N 2367.37 E 5964931.57 N 679048.92 E 10.332 5206.56 11023.57 89.690 99.460 8758.62 8818.12 4815.91 N 2397.65 E 5964926.69 N 679079.32 E 7.086 5221.91 11 051 .48 90.740 100.580 8758.51 8818.01 4811.05 N 2425.13 E 5964922.48 N 679106.91 E 5.501 5236.02 11085.32 90.620 101.400 8758.11 8817.61 4804.60 N 2458.35 E 5964916.81 N 679140.26 E 2.449 5252.62 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-37B Your Ref: API 500292248502 Job No. AKZZ3034589, Surveyed: 3 May, 2004 BPXA North Slope Alaska Measured True 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) (o/100ft) 11113.26 91.420 104.520 8757.62 8817.12 4798.34 N 2485.57 E 5964911.19 N 679167.62 E 11.526 5265.49 11144.48 91.170 104.790 8756.91 8816.41 4790.44 N 2515.76 E 5964904.00 N 679198.00 E 1.178 5279.03 11178.71 90.620 107.500 8756.37 8815.87 4780.92 N 2548.64 E 5964895.26 N 679231.09 E 8.077 5293.08 11209.70 90.620 108.830 8756.04 8815.54 4771.26 N 2578.08 E 5964886.30 N 679260.75 E 4.291 5304.80 11238.18 90.800 109.050 8755.69 8815.19 4762.02 N 2605.01 E 5964877.69 N 679287.89 E 0.998 5315.21 ( 11287.03 90.680 110.700 8755.06 8814.56 4745.41 N 2650.95 E 5964862.17 N 679334.21 E 3.386 5332.32 11330.77 90.250 109.060 8754.70 8814.20 4730.54 N 2692.08 E 5964848.27 N 679375.68 E 3.876 5347.63 11424.50 93.770 112.640 8751.41 8810.91 4697.22 N 2779.59 E 5964817.01 N 679463.95 E 5.354 5378.94 11517.75 92.040 113.280 8746.69 8806.19 4660.89 N 2865.34 E 5964782.71 N 679550.53 E 1.978 5406.82 11611.98 90.680 113.680 8744.45 8803.95 4623.36 N 2951.74 E 5964747.22 N 679637.79 E 1.504 5434.20 11646.12 89.260 110.920 8744.47 8803.97 4610.40 N 2983.32 E 5964735.01 N 679669.67 E 9.091 5444.80 11704.80 88.890 110.370 8745.42 8804.92 4589.72 N 3038.23 E 5964715.63 N 679725.04 E 1.130 5464.61 11755.49 88.210 110.980 8746.70 8806.20 4571.82 N 3085.64 E 5964698.85 N 679772.86 E 1.802 5481.70 11798.35 91.600 111.570 8746.77 8806.27 4556.28 N 3125.57 E 5964684.25 N 679813.15 E 8.028 5495.72 11847.94 92.280 110.940 8745.09 8804.59 4538.31 N 3171.76 E 5964667.37 N 679859.75 E 1.869 5511.96 11891.10 95.620 110.580 8742.12 8801.62 4523.05 N 3212.02 E 5964653.06 N 679900.35 E 7.783 5526.42 11941.42 94.010 108.230 8737.89 8797.39 4506.39 N 3259.31 E 5964637.53 N 679948.02 E 5.647 5544.36 11984.82 91.850 107.840 8735.68 8795.18 4492.97 N 3300.52 E 5964625.08 N 679989.53 E 5.057 5560.84 12033.71 92.040 109.810 8734.02 8793.52 4477.21 N 3346.76 E 5964610.41 N 680036.14 E 4.046 5578.79 12078.58 88.950 109.660 8733.63 8793.13 4462.06 N 3388.99 E 5964596.26 N 680078.71 E 6.895 5594.61 12129.30 88.700 112.640 8734.67 8794.17 4443.77 N 3436.28 E 5964579.08 N 680126.42 E 5.895 5611.31 12172.92 89.200 114.820 8735.47 8794.97 4426.22 N 3476.20 E 5964562.4 7 N 680166.74 E 5.127 5623.80 ( 12266.24 91.540 116.450 8734.87 8794.37 4385.85 N 3560.33 E 5964524.09 N 680251.79 E 3.056 5647.55 12359.62 94.820 114.600 8729.69 8789.19 4345.68 N 3644.45 E 5964485.91 N 680336.83 E 4.031 5671.45 12396.70 94.820 114.940 8726.57 8786.07 4330.20 N 3677.99 E 5964471.23 N 680370.74 E 0.914 5681.39 12471.00 94.820 114.940 8720.33 8779.83 4298.98 N 3745.13 E 5964441.59 N 680438.59 E 0.000 5701.10 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 40.380° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12471.00ft., The Bottom Hole Displacement is 5701.51ft., in the Direction of 41.0610 (True). 18 May, 2004 - 15:42 Page 5 of6 DrillQuest 3.03.06.002 DrillQuest 3.03.06.002 Page 60f6 18 May, 2004 - 15:42 ( 3526.47 MWD Magnetic (15-37) 8779.83 MWD Magnetic - MWD+IIFR+MS (15-378) 0.00 3827.93 3526.47 12471.00 0.00 3827.93 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) From Measured Vertical Depth Depth (ft) (ft) Survey tool program for 15-37B ( Tie On Point Window Point Projected Survey 394.25 E 407.11 E 3745.13 E 1091.99 N 1126.60 N 4298.98 N 3526.4 7 3564.59 8779.83 3827.93 3881.00 12471.00 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) Comments North Slope Alaska BPXA Halliburlon Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-37B Your Ref: API 500292248502 Job No. AKZZ3034589, Surveyed: 3 May, 2004 .~- --- 21-May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~blf- () 1 Of Re: Distribution of Survey Data for Well 15-378 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 3,827.93' MD Window / Kickoff Survey: 3,881.00' MD (if applicable) Projected Survey: 12,471.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date c/JV'N\ M~ L( Signed ~.. /~.II l)~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Jncl-Qi1 Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 15 15-37B MWD ( Job No. AKMW3034589, Surveyed: 3 May, 2004 Survey Report 18 May, 2004 Your Ref: API 500292248502 Surface Coordinates: 5960055.71 N, 676795.62 E (70017'47.1011" N, 148034'05.8492" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ( Surface Coordinates relative to Project H Reference: 960055.71 N, 176795.62 E (Grid) Surface Coordinates relative to Structure Reference: 1206.19 N, 526.17 E (True) Kelly Bushing Elevation: 59. 50ft above Mean Sea Level Kelly Bushing Elevation: 59. 50ft above Project V Reference Kelly Bushing Elevation: 59. 50ft above Structure Reference Sp:1!I r-'r-"\I-' SU'I! OFO'L.\C"I'NG ·se'RV"1 'c:;"e's A Halliburton Company Survey Ref: svy4265 DrillQuest 3.03.06.002 Page 20f6 18 May, 2004 - 15:45 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-37B MWD Your Ref: API 500292248502 Job No. AKMW3034589, Surveyed: 3 May, 2004 BPXA North Slope Alaska Measured True 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) (°/1 aaft) 3827.93 44.310 20.490 3466.97 3526.4 7 1091.99 N 394.25 E 5961156.67 N 677164.08 E 1 087.26 Tie On Point 3881.00 43.860 20.250 3505.09 3564.59 1126.60 N 407.11 E 5961191.57 N 677176.11 E 0.904 1121.95 Window Point 3901.01 43.420 19.270 3519.57 3579.07 1139.60 N 411.78 E 5961204.68 N 677180.47 E 4.032 1134.87 3927.70 43.600 17.960 3538.93 3598.43 1157.01 N 417.64 E 5961222.22 N 677185.93 E 3.446 1151.94 3958.75 44.110 16.440 3561.32 3620.82 1177.56 N 424.00 E 5961242.92 N 677191.80 E 3.768 1171.71 4002.84 44.480 14.250 3592.88 3652.38 1207.25 N 432.15 E 5961272.79 N 677199.25 E 3.569 1199.61 4052.12 44.750 4.690 3628.00 3687.50 1241.31 N 437.82 E 5961306.97 N 677204.12 E 13.628 1229.23 4145.49 44.020 1.920 3694.73 3754.23 1306.50 N 441.59 E 5961372.23 N 677206.36 E 2.217 1281.33 4237.55 43.430 3.490 3761.26 3820.76 1370.05 N 444.59 E 5961435.84 N 677207.86 E 1.342 1331.69 4332.26 42.600 3.910 3830.51 3890.01 1434.53 N 448.76 E 5961500.40 N 677210.51 E 0.927 1383.50 4426.32 41 .940 5.610 3900.11 3959.61 1497.57 N 454.00 E 5961563.55 N 677214.27 E 1.404 1434.93 4519.53 41 .050 5.250 3969.93 4029.43 1559.05 N 459.85 E 5961625.15 N 677218.67 E 0.989 1485.55 4612.82 40.460 4.680 4040.60 4100.10 1619.72 N 465.12 E 5961685.93 N 677222.51 E 0.748 1535.18 4705.55 39.880 4.670 4111 .46 4170.96 1679.34 N 470.00 E 5961745.64 N 677225.98 E 0.626 1583.75 4799.33 41.450 6.660 4182.59 4242.09 1740.14 N 476.05 E 5961806.57 N 677230.60 E 2.171 1633.99 4893.10 43.730 12.670 4251.65 4311 . 15 1802.62 N 486.76 E 5961869.29 N 677239.84 E 4.970 1688.52 4986.77 43.680 12.730 4319.37 4378.87 1865.76 N 500.99 E 5961932.74 N 677252.58 E 0.069 1745.84 5079.87 43.850 13.040 4386.60 4446.10 1928.54 N 515.35 E 5961995.84 N 677265.46 E 0.294 1802.96 5172.31 43.230 15.450 4453.61 4513.11 1990.25 N 531.01 E 5962057.90 N 677279.66 E 1.917 1860.12 5265.20 43.120 16.170 4521.36 4580.86 2051.40 N 548.32 E 5962119.44 N 677295.54 E 0.543 1917.92 5358.92 42.920 15.440 4589.88 4649.38 2112.93 N 565.74 E 5962181.36 N 677311.50 E 0.573 1976.07 5452.1 0 43.430 15.960 4657.83 4717.33 2174.30 N 582.99 E 5962243.12 N 677327.31 E 0.667 2034.00 ( 5544.42 43.680 16.550 4724.74 4784.24 2235.37 N 600.80 E 5962304.60 N 677343.67 E 0.517 2092.06 5637.66 44.110 15.960 4791.93 4851.43 2297.43 N 618.89 E 5962367.07 N 677360.30 E 0.637 2151.06 5731.12 43.590 15.130 4859.33 4918.83 2359.81 N 636.25 E 5962429.83 N 677376.18 E 0.830 2209.82 5826.23 43.770 16.260 4928.11 4987.61 2423.04 N 654.02 E 5962493.47 N 677392.46 E 0.842 2269.50 5917.18 44.040 21.320 4993.66 5053.16 2482.71 N 674.33 E 5962553.60 N 677411.36 E 3.869 2328.11 6012.74 44.450 24.550 5062.12 5121.62 2544.10 N 700.31 E 5962615.58 N 677435.89 E 2.397 2391.70 6105.04 44.360 23.840 5128.06 5187.56 2603.01 N 726.78 E 5962675.09 N 677460.96 E 0.547 2453.72 6197.25 44.040 23.910 5194.17 5253.67 2661.79 N 752.80 E 5962734.47 N 677485.59 E 0.351 2515.36 6292.05 43.430 23.670 5262.67 5322.17 2721.76 N 779.23 E 5962795.05 N 677510.61 E 0.667 2578.17 6385.20 42.900 23.970 5330.61 5390.11 2780.06 N 804.97 E 5962853.93 N 677534.97 E 0.610 2639.25 6477.85 42.580 23.850 5398.66 5458.16 2837.54 N 830.45 E 5962912.00 N 677559.09 E 0.356 2699.55 6572.05 42.860 23.770 5467.86 5527.36 2896.01 N 856.25 E 5962971.06 N 677583.51 E 0.303 2760.80 6664.65 43.010 23.860 5535.66 5595.16 2953.71 N 881.72 E 5963029.35 N 677607.62 E 0.175 2821.26 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 -15-37B MWD Your Ref: API 500292248502 Job No. AKMW3034589, Surveyed: 3 May, 2004 BPXA North Slope Alaska Measured True 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) 6756.94 42.050 22.240 5603.67 5663.17 3011 . 11 N 906.15 E 5963087.30 N 677630.69 E 1.578 2880.81 6849.51 42.600 21.520 5672.11 5731.61 3068.95 N 929.38 E 5963145.67 N 677652.55 E 0.792 2939.92 6942.71 42.980 20.910 5740.50 5800.00 3127.97 N 952.29 E 5963205.22 N 677674.06 E 0.603 2999.72 7035.72 44.020 20.300 5807.97 5867.47 3187.90 N 974.82 E 5963265.66 N 677695.18 E 1.206 3059.97 7128.66 45.080 21.120 5874.20 5933.70 3248.88 N 997.88 E 5963327.17 N 677716.80 E 1.298 3121.36 ( 7214.07 45.270 19.900 5934.41 5993.91 3305.62 N 1019.10 E 5963384.39 N 677736.68 E 1.037 3178.33 7317.66 46.050 22.950 6006.82 6066.32 3374.57 N 1046.17 E 5963453.95 N 677762.12 E 2.236 3248.39 7392.76 46.230 24.430 6058.86 6118.36 3424.15 N 1067.93 E 5963504.03 N 677782.70 E 1 .441 3300.26 7503.14 46.620 26.440 6134.95 6194.45 3496.36 N 1102.27 E 5963577.03 N 677815.34 E 1.366 3377.51 7596.93 46.730 27.740 6199.30 6258.80 3557.10 N 1133.34 E 5963638.48 N 677844.97 E 1.015 3443.91 7690.55 46.920 30.300 6263.37 6322.87 3616.79 N 1166.46 E 5963698.94 N 677876.68 E 2.004 3510.84 7783.95 46.220 31.830 6327.58 6387.08 3674.89 N 1201.45 E 5963757.84 N 677910.29 E 1 .406 3577.77 7876.55 45.450 32.460 6392.10 6451.60 3731.13 N 1236.79 E 5963814.90 N 677944.30 E 0.964 3643.50 7971.52 43.700 31.230 6459.74 6519.24 3787.74 N 1271.97 E 5963872.33 N 677978.13 E 2.055 3709.42 8064.39 43.070 31.030 6527.24 6586.74 3842.35 N 1304.95 E 5963927.69 N 678009.82 E 0.694 3772.38 8159.78 43.050 32.010 6596.93 6656.43 3897.87 N 1339.00 E 5963984.00 N 678042.55 E 0.702 3836.73 8252.54 42.980 31.100 6664.76 6724.26 3951.79 N 1372.11 E 5964038.68 N 678074.39 E 0.673 3899.26 8346.59 42.250 30.380 6733.97 6793.47 4006.52 N 1404.66 E 5964094.16 N 678105.65 E 0.933 3962.04 8438.74 43.690 31.190 6801.40 6860.90 4060.47 N 1436.81 E 5964148.86 N 678136.52 E 1.674 4023.97 8532.08 44.110 30.960 6868.65 6928.15 4115.91 N 1470.22 E 5964205.06 N 678168.61 E 0.481 4087.84 8624.14 44.930 31.070 6934.29 6993.79 4171.23N 1503.48 E 5964261.15 N 678200.56 E 0.895 4151.53 8717.68 46.130 31.530 6999.82 7059.32 4228.26 N 1538.16 E 5964318.98 N 678233.89 E 1.330 4217.44 ( 8810.85 46.800 32.190 7063.99 7123.49 4285.62 N 1573.81 E 5964377.17 N 678268.18 E 0.884 4284.24 8904.57 46.020 30.700 7128.62 7188.12 4343.53 N 1609.23 E 5964435.89 N 678302.23 E 1.421 4351.29 8996.80 45.690 30.060 7192.85 7252.35 4400.62 N 1642.70 E 5964493.76 N 678334.35 E 0.613 4416.47 9090.43 44.980 28.990 7258.67 7318.17 4458.56 N 1675.52 E 5964552.45 N 678365.79 E 1.112 4481.87 9183.82 44.440 27.830 7325.04 7384.54 4516.35 N 1706.78 E 5964610.96 N 678395.69 E 1.048 4546.14 9278.42 42.210 28.740 7393.86 7453.36 4573.51 N 1737.52 E 5964668.83 N 678425.08 E 2.448 4609.60 9370.40 38.800 31.080 7463.79 7523.29 4625.30 N 1767.27 E 5964721.30 N 678453.60 E 4.058 4668.32 9465.85 35.240 32.990 7539.99 7599.49 4674.03 N 1797.71 E 5964770.73 N 678482.88 E 3.919 4725.16 9559.07 30.620 30.760 7618.21 7677.71 4717.01 N 1824.51 E 5964814.33 N 678508.67 E 5.123 4775.27 9652.98 26.000 27.880 7700.87 7760.37 4755.78 N 1846.38 E 5964853.61 N 678529.62 E 5.129 4818.97 9746.90 22.450 28.230 7786.51 7846.01 4789.79 N 1864.50 E 5964888.03 N 678546.93 E 3.783 4856.61 9840.06 19.400 30.470 7873.51 7933.01 4818.80 N 1880.76 E 5964917.42 N 678562.50 E 3.384 4889.25 9933.33 16.780 29.040 7962.17 8021.67 4843.93 N 1895.15 E 5964942.88 N 678576.30 E 2.849 4917.71 18 May, 2004 - 15:45 Page 3 of6 Dri/lQuest 3.03.06.002 DrillQuest 3.03.06.002 Page 4 of6 18 May, 2004 - 15:45 Halliburton Sperry-Sun Survey Report for PBU _EOA DS 15 - 15-37B MWD Your Ref: API 500292248502 Job No. AKMW3034589, Surveyed: 3 May, 2004 BPXA North Slope Alaska Measured True 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) 1 0027.46 14.610 25.630 8052.78 8112.28 4866.51 N 1906.89 E 5964965.73 N 678587.50 E 2.504 4942.52 10099.70 11.700 20.970 8123.12 8182.62 4881.57 N 1913.45E 5964980.94 N 678593.71 E 4.284 4958.24 10161.75 11.610 24.810 8183.89 8243.39 4893.11 N 1918.32 E 5964992.59 N 678598.31 E 1.258 4970.19 10211.26 9.190 28.850 8232.59 8292.09 4901.10 N 1922.32 E 5965000.67 N 678602.12 E 5.102 4978.87 10305.64 10.000 36.630 8325.65 8385.15 4914.28 N 1930.85 E 5965014.05 N 678610.33 E 1.618 4994.43 ( 10339.31 13.560 53.220 8358.62 8418.12 4918.99 N 1935.75 E 5965018.87 N 678615.13 E 14.493 5001.20 10370.98 15.700 57.010 8389.26 8448.76 4923.55 N 1942.32 E 5965023.58 N 678621.59 E 7.399 5008.92 10398.98 16.670 60.390 8416.15 8475.65 4927.59 N 1948.99 E 5965027.79 N 678628.16 E 4.828 5016.33 10433.17 19.040 74.700 8448.70 8508.20 4931.49 N 1958.64 E 5965031.91 N 678637.71 E 14.535 5025.55 10464.49 21.970 85.430 8478.05 8537.55 4933.31 N 1969.42 E 5965033.98 N 678648.44 E 15.181 5033.91 10492.62 25.450 93.340 8503.81 8563.31 4933.37 N 1980.70 E 5965034.31 N 678659.72 E 16.735 5041.27 10527.14 30.530 101.180 8534.29 8593.79 4931.24 N 1996.72 E 5965032.55 N 678675.79 E 18.143 5050.03 10551.80 33.520 102.610 8555.19 8614.69 4928.54 N 2009.51 E 5965030.15 N 678688.64 E 12.508 5056.26 10584.84 36.600 107.430 8582.24 8641.74 4923.59 N 2027.82 E 5965025.64 N 678707.06 E 12.529 5064.35 10618.95 41.940 108.820 8608.64 8668.14 4916.87 N 2048.33 E 5965019.40 N 678727.72 E 15.865 5072.51 10649.29 46.570 112.130 8630.37 8689.87 4909.44 N 2068.14 E 5965012.44 N 678747.71 E 17.050 5079.69 10677.30 51.220 111.000 8648.78 8708.28 4901.69 N 2087.77 E 5965005.16 N 678767.51 E 16.877 5086.50 10713.41 57.530 109.730 8669.80 8729.30 4891.49 N 2115.28 E 5964995.61 N 678795.25 E 17.706 5096.56 10744.90 60.570 109.100 8685.99 8745.49 4882.52 N 2140.74 E 5964987.24 N 678820.92 E 9.805 5106.22 10772.73 61.070 110.000 8699.56 8759.06 4874.39 N 2163.64 E 5964979.65 N 678844.00 E 3.347 5114.86 10807.97 64.620 106.980 8715.65 8775.15 4864.46 N 2193.37 E 5964970.42 N 678873.96 E 12.633 5126.56 10839.07 67.720 106.460 8728.21 8787.71 4856.28 N 2220.62 E 5964962.88 N 678901.39 E 10.084 5137.98 ( 10867.01 69.700 108.300 8738.35 8797.85 4848.50 N 2245.46 E 5964955.69 N 678926.40 E 9.374 5148.14 10900.95 76.280 105.580 8748.28 8807.78 4839.06 N 2276.49 E 5964946.98 N 678957.65 E 20.845 5161.06 10931.27 82.070 104.040 8753.97 8813.47 4831.46 N 2305.27 E 5964940.06 N 678986.60 E 19.737 5173.91 10958.75 86.170 100.350 8756.79 8816.29 4825.69 N 2331.98 E 5964934.92 N 679013.43 E 20.024 5186.82 10992.78 88.890 102.460 8758.25 8817.75 4818.97 N 2365.30 E 5964928.98 N 679046.90 E 10.112 5203.29 11023.57 89.690 98.230 8758.64 8818.14 4813.44 N 2395.58 E 5964924.17 N 679077.31 E 13.981 5218.69 11051.48 90.740 98.820 8758.53 8818.03 4809.30 N 2423.18 E 5964920.68 N 679105.00 E 4.315 5233.42 11085.32 90.620 98.520 8758.13 8817.63 4804.20 N 2456.63 E 5964916.37 N 679138.56 E 0.955 5251.21 11113.26 91.420 105.370 8757.63 8817.13 4798.42 N 2483.94 E 5964911.24 N 679166.00 E 24.679 5264.50 11144.48 91.170 1 08.260 8756.93 8816.43 4789.39 N 2513.82 E 5964902.91 N 679196.08 E 9.289 5276.98 11178.71 90.620 106.990 8756.39 8815.89 4779.03 N 2546.44 E 5964893.32 N 679228.93 E 4.043 5290.22 11209.70 90.620 115.360 8756.05 8815.55 4767.85 N 2575.31 E 5964882.82 N 679258.06 E 27.007 5300.40 11238.18 90.800 106.740 8755.70 8815.20 4757.63 N 2601.86 E 5964873.23 N 679284.84 E 30.271 5309.82 DrillQuest 3.03.06.002 Page 50f6 18 May, 2004·15:45 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 -15-37B MWD Your Ref: API 500292248502 Job No. AKMW3034589, Surveyed: 3 May, 2004 BPXA North Slope Alaska Measured True 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) 11287.03 90.680 107.200 8755.07 8814.57 4743.37 N 2648.58 E 5964860.07 N 679331.88 E 0.973 5329.22 11330.77 90.250 1 06.480 8754.72 8814.22 4730.70 N 2690.44 E 5964848.39 N 679374.03 E 1.917 5346.69 11424.50 93.770 122.410 8751.41 8810.91 4692.08 N 2775.43 E 5964811.78 N 679459.91 E 17.393 5372.34 11517.75 92.040 112.850 8746.67 8806.17 4648.95 N 2857.85 E 5964770.60 N 679543.32 E 10.405 5392.87 11611.98 90.680 115.360 8744.43 8803.93 4610.48 N 2943.83 E 5964734.16 N 679630.18 E 3.029 5419.27 ( 11646.12 89.260 1 08.410 8744.45 8803.95 4597.76 N 2975.49 E 5964722.19 N 679662.13 E 20.777 5430.09 11704.80 88.890 111 .790 8745.40 8804.90 4577.60 N 3030.58 E 5964703.33 N 679717.68 E 5.794 5450.43 11755.49 88.210 116.060 8746.68 8806.18 4557.06 N 3076.89 E 5964683.88 N 679764.46 E 8.527 5464.78 11798.35 91.600 110.990 8746.75 8806.25 4539.96 N 3116.16 E 5964667.71 N 679804.13 E 14.228 5477.20 11847.94 92.280 114.460 8745.07 8804.57 4520.81 N 3161.87E 5964649.65 N 679850.27 E 7.126 5492.23 11891.10 95.620 116.070 8742.10 8801.60 4502.44 N 3200.80 E 5964632.20 N 679889.63 E 8.587 5503.45 11941.42 94.010 116.330 8737.88 8797.38 4480.30 N 3245.79 E 5964611.13 N 679935.12 E 3.241 5515.74 11984.82 91.850 106.960 8735.65 8795.15 4464.34 N 3286.03 E 5964596.11 N 679975.73 E 22.127 5529.64 12033.71 92.040 113.930 8733.99 8793.49 4447.28 N 3331.79 E 5964580.14 N 680021.87 E 14.254 5546.29 12078.58 88.950 115.730 8733.61 8793.11 4428.44 N 3372.50 E 5964562.26 N 680063.02 E 7.969 5558.32 12129.30 88.700 109.780 8734.65 8794.15 4408.84 N 3419.24 E 5964543.76 N 680110.21 E 11.739 5573.67 12172.92 89.200 116.580 8735.45 8794.95 4391.68 N 3459.31 E 5964527.55 N 680150.67 E 15.629 5586.56 12266.24 91.540 115.890 8734.84 8794.34 4350.43 N 3543.01 E 5964488.28 N 680235.31 E 2.614 5609.36 12359.62 94.820 111.340 8729.66 8789.16 4313.09 N 3628.40 E 5964452.96 N 680321.56 E 6.000 5636.24 12396.70 94.820 104.110 8726.54 8786.04 4301.85 N 3663.57 E 5964442.55 N 680356.99 E 19.429 5650.46 12471.00 94.820 104.110 8720.30 8779.80 4283.80 N 3735.38 E 5964426.20 N 680429.20 E 0.000 5683.23 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 40.380° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12471.00ft., The Bottom Hole Displacement is 5683.66ft., in the Direction of 41.088° (True). DrillQuest 3.03.06.002 Page 60f6 18 May, 2004 - 15:45 ( 8779.80 MWD Magnetic (15-37) 0.00 12471.00 0.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) From Measured Vertical Depth Depth (ft) (ft) Survey tool program for 15-378 MWD ( Tie On Point Window Point Projected Survey 394.25 E 407.11 E 3735.38 E 1091.99 N 1126.60 N 4283.80 N 3526.47 3564.59 8779.80 3827.93 3881.00 12471.00 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) Comments BPXA North Slope Alaska Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-37B MWD Your Ref: API 500292248502 Job No. AKMW3034589, Surveyed: 3 May, 2004 ·-.--.....-"............ ""_"'-'-':"'-~'_"':___:>:':'A-~:",,'i,,JiN~_ .. ._..________:.,..:....,."""'·.,..N_~· _......-..........__...._----~. PRUDHOE BAY UNiT WELL: 15~378 API NO: 50-029-22485-02-00 Permit NO: 204-019 --------:~.:......_... GPB Rotary Dr-flUng ._...-....-'--~-..-.,~..""~--- R~~ ProP05Üj Cornp¡euü~ JOF t-!abors 2ES Actual Completion 05-04-03 11-21-03 ,,"_<''''''...·~...,:¡o.ù:.....=-- Rev By Comments Date 'X' NIpple @ 9931' MD 7" X 4.5" S<3 Packer @ ~ L 4>·1/2",12_6#, L-80, !ST-M @ ~' CZ,'fCø(, ~, LC«12 '123/8', FC>gij r, 26#. l-80, BTC~M @ ~10,Î6Ü{ 'X' Nippfe @ 9975' MD, 'XN' Nîppie (Œ 9996' MD WLEG @ 1..QQQ.[ T X t}" HJ'v1C Uner Hanger \vnh ZXP Liner Top Packer HtOîO' - ~ 4~1¡T X i"» SV #4 ~ 5509- MO - 4750' TVD ·4·1/2« X. r- DV '#3· yona' MD - 5850' TVD« 4-1f2~ Xl" - DV \~:-5!8'" 47#, L-80 \\ , \ \. \,\ ' '4' -1/2" l' '¿~ CUi, ,I< ."c" f \¡",~.,~ T",OP \ .-s...__------- - ~l J ..Vft) ið _" YKr¥f- ......."" : ~, ' \ \ \, \ \., \. - \\ \ \ \ \ \ \ TO" c.\ 7 927' - 't', ~~t "} \ \W\ ' ,v 18. ' (BS!!1¡<.'heu \ \ \ \ \ '10 :ft2 ". 8_286~ fv1D -:-;> -675-0í 1'"\lí)·- 4-=1!2::-~ ;< -or' .,.> D\/ if.1 - 93ßCY MD ... 750ú~ T\JD -- 4-~-1l2~j x_ f~~ -- fJ\l ) . .n~·" .~ ..... , L' ø .. . " , r1 I r ,. 4115' 3977' 4097' ~' 3B "/&,' 'X' Nipple @ 219'1' MD n ti 15-378 Nabors 2ES Com I -- <'#~ ,,,$'i£, 4%, ! I L' __........_..__ "--' '.-- ---- "-'- ÁO'I-Ol'l ])s¡J /257'1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska May 14, 2004 RE: MWD Formation Evaluation Logs I5-37B, AK-MW-3034589 1 LDWG formatted Disc with verification listing. API#: 50-029-22485-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO mE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-l 900 E. Benson Blvd. Anchorage, Alaska 99508 Datefíd~~ siQ~jlLð (/ RECE'\lEO ~ JUN 0 9 2.004 ( A\~aO\\&Gaseons.comn~i ~~ -- 201,. Ol~ . Winton, As per our conversation this afternoon, BP was unable to achieve the 11.8 ppg FI~ as shown in the approved 15-37B Permit to Drill (#204-019), Drilling ahead will continue at 15-37B with caution, monitoring for losses and/or gains. Operations leading up to the failed FIT include: cutting and pulling 7" casing from -90' below the existing 9-5/8" shoe, experiencing lost circulation, spotting LC material, pulling 7" casing, spotting a 17 ppg cement kick-off plug, kicking off the plug with the directional BHA, and drilling 20' of new hole. The FIT was conducted with fresh 9.8 ppg LSND mud in the hole. As the hole was pressured up for the 11.8 ppg FIT, deviation from a straight line was noticed at 250 psi. At 275 psi the line broke over and the well started to loose pressure. The pressure stabilized at 50 psi, equating to a 10.1 ppg LOT. A second FIT yielded the same results. Drilling ahead proceeded for -170' with no losses, at which time the decision was made to POOH. A RTTS was run to the base of the 9-5/8" and the casing pressure tested to 3500 psi for 30 mins. The 9-5/8" casing was originally run and cemented in 6/94 with 1545 sxs of cement, passed a 3000 psi casing test prior to drilling out, and had a 13.7 ppg EMW LOT in the original 8.5" hole. Regards, Rob Tirpack tirpacrb@bp.com GPB Ops Drlg Eng 564-4166 office 440-8633 cell -- . ~ FRANK H. MURKOWSKI, GOVERNOR AI#ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: PBU l5-37B BP Exploration (Alaska), Inc. Permit No: 204-019 Surface Location: 1445' SNL, 4419' WEL, Sec. 22, TllN, RI4E, UM Bottomhole Location: 2810' NSL, 794' WEL, Sec. 15, TUN, RI4E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit 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. 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. PI ç provide at least twenty-four (24) hours notice for a representative of the Commission t wi ess any required test. Contact the Commission's North Slope petroleum field' pe or 659- 07 (pager). Si e 1 , BY ORDER Qf THE COMMISSION DATED this~ day of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. W~I\ l(2..ll:z..cotf o Drill II Redrill 1a. 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: 1445' SNL, 4419' WEL, SEC. 22, T11N, R14E, UM yo Top of Productive Horizon: 3386' NSL, 2044' WEL, SEC. 15, T11N, R14E, UM Total Depth: 2810' NSL, 794'WEL, SEC. 15, T11N, R14E, UM'/ 4b. Location of Well (State Base Plane Coordinates): Surface: x-676796' y-5960056/ Zone-ASP4 16. Deviated Wells: Kickoff Depth 18. C~sil'1gPr()Qråm Size Casing 7" .. STATE OF ALASKA _ ALASKA CW'AND GAS CONSERVATION COM_SION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: 181 Blanket 0 Single Well Bond No. 2S100302630-277 ... 6. Proposed Depth: MD ... 12363 TVD 8784 ,/ 7. Property Designation: ADL 028306 ,/ II Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU 15-37B ( 12. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Date: February 14, 2004 14. Distance to Nearest Property: 21,965 9. Acres in Property: 2560 Hole 8-1/2" 6-1/8" ... 4000 ft Maximum Hole Angle 930 Specifications Grade Coupling L-80 BTC-M L-80 IBT-M Weight 26# 12.6# Length MD TVD MD TVD 10123' Surface Surface 10151' 8235' 2362' 10001' 8086' 12363' 8784' 10. KB Elevation Planned = 15. Distance to Nearest Well Within Pool (Height above GL): 59.5' feet 15-36A is 174' away at 4006' MD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: ... 3656 psig Surface: v 2839 psig Quagtity (c;f. or sa (including stage data) 348 sx Class 'G', 155 sx Class 'G' 282 sx Class 'G' 4-1/2" 19. PRI;$I;NT.WELLÇ()NDITION $QMMARY("O·..~.cø..nplétedforRedriIIANDR~ntry Ope@tiQgS) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD 12550 8785 NIA 12503 8782 Structural . Conductor 110' 20" 260 sx Arcticset 110' 110' Surface 3876' 9-5/8" 375 sx Class 'G', 920 sx PF 'E' 3876' 3563' Intermediate 10372' 7" 301 sx Class 'G' 10372' 8299' Production Liner 497' 5" 118 sx Class 'G' 10198' - 10695' 8137' - 8609' Liner 2384' 2-3/8" 61 sx LARC 10156' - 12540' 8098' - 8784' 20. Attachments 181 Filing Fee 0 BOP Sketch 181 Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8806' - 8781' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements Perforation Depth MD (ft): 11090' - 12450' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Date: Contact Rob Tirpack, 564-4166 Phone 564-5521 Permit To Drill· API Number: Number: ,?,L"t/·- ð /9 50- 029-22485-02-00 Conditions of Approval: Samples q ired Hydro n Su Ide Measures , o r~i. DYes ~No øYes D No Permit App~o~1 ~ See cover letter for Date: ;f :;? 0 0 i other requirements Mud Log Require D Yes ~No Directional Survey RR~C'§VE 0 JAN .2 0 2004~~ BY oRlMRlafOu & Gas . THE CDMMISSION A ~~P"··~" < ~ l' d nc. lurage Sub it In D lical ORIG'~'^L " e I Well Name: 115-378 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer ¡/ Surface Location: As built Target Location: Ivishak Zone 1 A Bottom Hole Location: x = 676,796 v Y = 5,960,056 ./ 1446' FNL 858' FWL Sec. 22, T11 N, R14E Umiat 0/ X = 679,050 Y = 5,964,942 TVDss 8,750' 1894' FNL 2044' FEL Sec. 15, T11N, R14E Umiat X = 680,314 Y = 5,964,396 TVDss 8,724' 2470'FNL./ 794' FEL Sec. 15, T11 N, R14E Umiat ./ I AFE Number: I PBD4P2178 I I Estimated Start Date: I 02/14/04 I Rig: 1 Nabors 2ES I Operating days to complete: 125.3 " I MD: 112,363' I I TVD: I 8784' I I GL: 131.0' I I KB: 128.5' 1 I KBE: 159.5' I Well Design (conventional, slim hole, etc.): I Dual String Horizontal Sidetrack I Objective: I Ivishak Zone 1 A/1 B / Formation Markers (Sperry wp05) Formation Tops MD TVD TVDss KOP 4,000' 3,650' 3,590' SV2 4,132' 3,752' 3,692' SV1 4,684' 4,142' 4,082' UG4 5,371' 4,638' 4,578' WS2 7,205' 5,960' 5,900' WS1 7,467' 6,149' 6,089' CM3/K10 7,775' 6,371' 6,311' CM2 8,392' 6,815' 6,755' CM1 9,328' 7,492' 7,432' THRZ 9,717' 7,819' 7,759' BHRZ 9,914' 8,003' 7,943' LCUrr JB 9,978' 8,065' 8,005' T JA 10,061' 8,146' 8,086' TSAG 10,151' 8,235' 8,175' TSHU 10,197' 8,280' 8,220' TSAD- TZ4B 10,268' 8,350' 8,290' TZ2 10,476' 8,550' 8,490' TZ1B 10,759' 8,754' 8,694' TZ1A 10,877' 8,797' 8,737' TD 12,363' 8,784' 8,725' TD Criteria: Based on 1000' of perfable Zone 1 A/1 B. 15-37B Permit to Drill Comments 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW 0' 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW 7.2 ppg EMW " /' Page 1 e - Directional - Sperry wp05 KOP: 4,000' MD ./ Maximum Hole Angle: _440 in 8-1/2" Intermediate section -930 in 6-1/8" horizontal section. Close Approach Wells: There are no close approach issues. Closest Well: The closest well is 15-36A, which has a 174' center to center distance. This occurs at 4006' MD at 15-37B and at 4025' MD at 15-36A. Survey Program: MWD with IFR/Cassandra. Nearest Property Line: 21,965' CasingJTubing Program Hole Size CsgITbg O.D. WtI? Grade Conn Length Top Btm / MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 10,123' GL 10,151 '/8,235' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2,362' 10,001 '/8,086' 12,363'/8,784' Tubing 4-1/2" 12.6# L-80 IBT-M 9,823' GL 9,951 '/8,033' Mud Program Intermediate Mud Properties: LSND Depth Density Viscosity Kick-off 9.8 40 - 60 KTO:R~ t~~~Z § / :g ~ ~g Production Mud Properties: Flo-Pro Density (ppg) I PV I YP 8.4 - 8.5 . 8-15 35-45 I 8-1/2" hole section I PV YP 10 sec gel 15-25 30-40 15-20 12-14 25-33 15-20 12-14 25-33 15-20 Chlorides <1000 <500 <500 PH 9.0-9.5 9.0 9.0 API FI 4-6 5-6 5-6 6-1/8" hole section pH I API FI 9.0 - 9.5 4 - 6 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GRlRes/PWD- Real time </ Open Hole: None Cased Hole: None Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described " Dir/GRlReslDenslNeulABI - Real time ,/ Dens/Neu required through build section only ./ None None 6-118" Production: Drilling: 15-37B Permit to Drill Page 2 e . Cement Program Casing Size I 7" 29#, L-80 Intermediate Casing 1 Basis: Lead: Based on 4651' of 7" X 8-1/2" open with 40% excess Lead TOC: 4500' MD (500' from KOP) Tail: Based on 1000' of 7" X 8-1/2" open hole with 40% excess and 80' shoe track Tail TOC: 9,151' MD (1000' above shoe) ~~ I Total Cement Volume: I Lead 1147 bbls, 825 ft , 348~cks Class G @ 12.0 pOO, 2.37 3/sack Tail 32 bbls, 180 ft ;J9-'SaCkS Class G @ 15.8 PP~6 Isack I Casing Size 14.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: Based on 2212' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, 80' shoe track and 200' of 7" X 4" DP excess. Tail TOC: 10,001' MD (TOL) I Total Cement Volume: I Lead Tail I None ./'fR-::2 ---J 61 bbls, 339 ft~",aCkS Class G @ 15.8 ppg{;~0.)f3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing/7" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3656 psi (8.6 ppg @ 8175' TVDss)./ 2839 psi (.10 psilft gas gradient to surface) ,. 117 bbls with a 11.8 ppg FIT Rams test to 3,500 psi/250 psi. ,./ Annular test to 2,500 psi/250 psi 3500 psi surface pressure 11.8 ppg FIT after drilling 20' outside window 3271 psi (7.2 ppg @ 8737' TVDss) ,/ 2397 psi (.10 psilft gas gradient to surface) ¥ Infinite with 9.6ppg FIT Rams test to 3,500 psi/250 psi. / Annular test to 2,500 psi/250 psi 3500 psi surface pressure 9.6 ppg EMW FIT 8.4 ppg Seawater I 6.8 ppg Diesel Disposal · No annular injection in this well. ./ · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 15-37B Permit to Drill Page 3 e e Sidetrack and Complete Procedure Summary Pre-Riq Work: 1. Drift 3-1/2" tubing to top of tubing patch. 2. Drift 2-3/8" liner as deep as possible 3. Fluid pack tubing and IA with 9.8 ppg brine - caution cretaceous leak. 4. P&A production interval with cement to 10,000' MD. 5. Tag TOC. 6. Pressure test 3-1/2" tubing and P&A plug. 7. Chemical cut the 3-1/2" tubing at -4100' MD. 8. Circulate to 9.8 ppg brine and freeze protect with diesel. 9. Test the casing and tubing pack-offs. Test the OA. Function all Lock Down Screws. 10. Set BPV. Secure well. Remove the wellhouse. If necessary, level the pad. Riq Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to 9.8 ppg brine. 3. Monitor IA for pressure. Calculate required fluid weight to killlA. 4. Circulate kill weight fluid. Verify well is dead. 5. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. 6. Pull 3-1/2" tubing from pre-rig cut. 7. RU e-line. Run GR/JB for 7",26# casing to top of tubing stub. / 8. MU 7", 26# bridge plug on e-line with CCL. RIH and set at 4050' MD. 9. Pressure test casing to 3500 psi for 30 minutes. 10. RIH with 7, 26# mechanical casing cutting assembly. / 11. Spot a 18 ppg pill below cut point. Swap over to 9.8 ppg LSND cutting/drilling fluid. 12. Cut 7" casing at 4000' MD. POOH. 13. Pull 7" casing from cut. /"' 14. RIH open ended, tag bridge plug in lower casing stub. Circulate botto,ms up. 15. Lay in a 17 ppg cement kick-off plug from 4050' to -3700'. WOC. / 16. MU 8-1/2" drilling assembly with Dir/GR/Res and RIH: Drill excess cement in 7" casing to 3876'. 17. Kick off and drill 8-1/2" hole -20' past cement kick-off plug. Perform FIT. / 18. Drill the 8-1/2" intermediate interval, turning at 4°/100' to a 44° hold angle and then dropping angle. 19. Verify that the mud weight is at least 1 0.2 ppg prior to cutting HRZ and Kingak. / 20. Drill ahead to casing point at Top Sag River to an estimated depth of 10,151' MD. 21. Run and cement 7" casing throughout the 8-1/2" hole and back to surface. Land 7" casing in emergency slips. Displace cement with mud. POOH. v , ' 22. MU 6-1/8" BHA with Dir/GR/~s/ABI and RIH to the landing collar. $u:-/~~ð rr--- ß 23. Pressure test wellbore to 3500 psi for 30 minutes. / 24. Drill shoe track. Swap over to 8.5 ppg mud and drill 20' of new formation. Perform FIT. 25. Drill the 6-1/8" production interval building at 13°/100' to horizontal, targeting Z1A Ivishak." Drill ahead to an estimated TD of 12,363' MD. 26. Run and cement a 4-1/2", 12.6# liner throughout the 6-1/8" w~ore and back into the 7" drilling liner to 10,001' MD. Displace cement with seawater. Release from TOL. 27. Displace well to clean seawater. / 28. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 29. POOH. LD DP and perf guns. 30. Run 4-1/2",12.6#, 13Cr80 completion tying into the 4-1/2" liner top. / 31. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. ' 32. Set and test TWC. 33. ND BOPE. NU and test the tree to 5000 psi. / 34. Freeze protect the well to -2200' and secure the well. 35. RDMO 15-37B Permit to Drill Page 4 e e Post-Riq Work: 1. Install wellhouse, flowlines and instrumentation. 2. MIRU slickline. Pull the ball and rod I RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves 15-378 Drilling Program Job 1: MIRU Hazards and Contingencies ~ One well will require well house removal for the rig move onto 15-37B. The closest neighboring wells are spaced as follows: 15-36A at -30' and 15-38A at -60'. Care should be taken while moving onto the well. Spotters will be us~ at all times. ~ Drill Site 15 is not designated as an HzS site. However, Standard Operating Procedures for H2S ./ precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Reading Date 15-36A No Data N/ A 15-38A No Data NI A 15-16A 12 ppm ./ 03/09/01 15-17 5 ppm 04/30/01 15-44 33 ppm ,I 03/23/96 t #1 Closest SHL with H2S Reading #2 Closest SHL with H2S Reading #1 Closest BHL with H2S Reading #2 Closest BHL with H2S Reading Max Recorded H2S Reading on the Pad ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP --"""'.,,--'" Job 2: De-complete Well Hazards and Contingencies ~ The perforations in 15-37 A have been isolated with a cement plug set during pre-rig operations. The well also passed a MIT-Tubing to 3500 psi. Monitor well for any signs of pressure or flows. ~ A cretaceous leak exists in the 7" production casing. Maintain kill weight fluid in the hole at all times. ~ Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ""~<,,.~'m~; I _!i>!!:!mI!m:.; " ~-~,,~~~:.., 15-37B Permit to Drill Page 5 - - Job 4: Casinq Cut and Pull Hazards and Contingencies ~ Once casing cutting is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. ~ Maintain cretaceous kill weight fluid in the hole at all times. Reference RP .:. "Setting a Kick-off or Abandonment Plug in Open Hole" RP .:. "Casing cut and pull" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the SV3 sand. ~ The intermediate section will cut the HRZ and Kingak intervals and drill to the top of Sag River. For this well, maintain mud weight at 10.2 ppg, from the THRZ to the 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ There are no fault crossings in the intermediate section. ~ There are no close approach issues in the intermediate section. ~ KICK TOLERANCE: In the worst-case scenario of 8.6 ppg pore pressure at the Sag River depth, a fracture gradient of 11.8 ppg at the 9-5/8" surface casing shoe, and 10.8 ppg mud in the hole, the kick tolerance is 117 bbls. / Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" < ,~_ m~'~¡'¡';!!!;:-' J!!!»:~"'i(\=~n-:»m..¡v¡mi®ff:fflm·.-!!!!!.-!!!.-¡¡;;..,_,~;_~ Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP 15-37B Permit to Drill Page 6 e . Job 7: Drill 6" Production Hole Hazards and Contingencies ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ There are no fault crossings in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ There are no close approach issues in the production section. ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradient of 9.6 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolepmce is Infinite. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "lubricants for Torque and Drag Management" RP ,_.,,-.,~~.~ Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.6ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Halliburton Cement Program ,_,~,~,(...._ e-:''''''''''''''_ Job 1 0: DPC Perforate Production Casinq Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Schlumberger's perforating practices and recommendations. .:. "DPC Perforating" RP ^~~"~'.:>"";"'n_.~"'_ .,- -"'-.~'«. =_."~, 15-37B Permit to Drill Page 7 - e Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is- 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRele8se RiQ Hazards and Contingencies ~ The closest neighboring wells are spaced as follows: 15-36A at -30' and 15-38A at -60'. 15-36A will have the well house removed. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 15-378 Permit to Drill Page 8 e e 15-378 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There are no close approach issues. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · There are no fault crossings expected in the intermediate hole section. · Lost circulation while drilling the intermediate hole has not been problematic at DS15. In the event of lost circulation, consult the LCM Decision Tree. · The HRZ and Kingak intervals will be drilled with a recommended mud weight of 10.2 ppg to ensure shale stability. · Kick tolerance is 117 bbls with a 11.8 ppg FIT. Production Hole Section: · There are no fault crossings in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · There are no close approach issues while drilling the production hole section. · Kick tolerance is Infinite with a 9.6 ppg FIT. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent tests indicate a very ./ low concentration of H2S. As a precaution, Standard Operating Procedures for/' H2S precautions should be followed at all times. CONSULT THE OS 15 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 15-378 Permit to Drill Page 9 e Minimum ID = 1.75" @ 6451" Eclipse Series III PKR Straddle Assy 19-5/8" CSG, 47#, L-80, ID = 8.681" -i 3876' ~ 15-37A aFETY NOTES: WELL IS 700 @ 10959' AND ~ES- HORIZONTAL @ 11149'. rECLlPSESERIES III A<RSTRADDLEASSY, ID = 1.75" -i 6451' ~_ ~ -;? , I cretal:::~~~~:::~=~:8~~1:~ I TOP OF 2-318" LNR, ID = 1.995" -i 10160' I I TOP OF BKR TIEBACK SLEEVE -i 13-1/2" TBG, 9.2#, L-80, .00870 bpf, ID = 2.992" -i 17" x 5" BKR LINER HGR -i 10198' 10205' 10206' 17" CSG, 26#, L-80, .0383 bpf, ID = 6.276" -i 10372' ~ ÆRFORA TION SUMMARY REF LOG: BH MWD/GR ON 07/31/00 ANGLEATTOPÆRF: 85 @ 11090' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 1-9/16" 4 11090-11260 0 08/21/00 1-9/16" 4 11310-11400 0 08/21/00 1-9/16" 4 11430-11800 0 08/21/00 1-9/16" 4 12300-12450 0 08/21/00 15" LNR, 15#, 13-CR-80 1J45, ID = 4.408" -i 11056' ~ .J . 2099' H3-1/2" CAMCOTRDPSSSV NIP, ID= 2.812" .. GAS LIFT MANDR8..S ST MD TVD DEV TYÆ VLV LATCH PORT DATE L 1 3485 3276 37 CA-MMG DV RK 05/02/01 2 6474 5389 44 CA-MMG DV RK 05/02/01 3 8742 6977 47 CA-MMG DV RK 05/02/01 4 10034 7987 46 CA-MMG DV RK 05/02/01 I 10095' -i3-1/2" OTIS X NIP, ID = 2.813" I E 10147' -i3-/12" X 4-1/2" XO, ID = 2.992" I 10150' -i7" X 4-1/2" BAKER SABL-3 A<R, ID = 3.875" I --- 10154' -i4-1/2" X 3-1/2" XO, ID = 2.992" I I 10156' -i2.70" BKRLNRDEPLOYMENTSLV, ID= 1.969" I ~ I 10175' -i3-1/2"OTISXNIP(BEHINDLNR),ID=2.813" I 10194' 1--i3-1/2" OTIS XN NIP (BEHIND LNR), ID = 2.75" 10206' -i3-1/2" TBG TAIL WLEG I -i ELMD TT NOT LOGGED I II. 5" MILLED WINDOW 10695' - 10699' I PBTD -i 12503' _ J I O-RING SUB, ID = 1.00" -i 12503' I 12-3/8" LNR, 4.6#, 13-CR-80, .00387 bpf, ID = 1.995" -i 12540' I I TD -i 12550' I DATE REV BY COMMENTS 01/02102 DDW/KAK' ECLIPSE SERIES III A<R 06/13/03 CMOITLP KB ELEVATION & MAX ANGLE DATE 06/28/94 08/01/00 09/28/00 02/13/01 06/23/01 08/25/01 REV BY COMMENTS ORIGINAL COM PLETION CTD SIDETRACK CONVERTED TO CANVAS FINAL CORRECTIONS CORRECTIONS SIS-Isl SIS-MD CHITP Æ/CH TREE = 4-1/16" MCEVOY WELLHEAD = FMC '~mm..,..~nuu , ". m'MM~m~_ ACTUATOR = NA KB. ELEV = 65.7' BF. ELEV = 33.37' m< _<~<~. ~ m,m", < KOP = 1500' ........~,'....m...".._.__,__"_____,__"_._"'.'_'._,_._.___.________._.,._............~...~u. Max Angle = 100 @ 11906' ~.~~mO'M M "m...~~.~~nm'~ Datum MD = '~'m...'._"_"'.'''_'.....,,........... ......... ...., ...'"......,.~~,~ Datum TVD = 8800' SS PRUDHOE BAY UNIT WELL: 15-37A ÆRMIT: 2000720 API No: 50-029-22485-01 SEC 22, T11 N, R14E, 1445' FNL & 4419' FEL BP Exploration (Alas ka) 11-37 A Pre-Rib / Minimum ID = 1.75" @ 6451" Eclipse Series III PKR Straddle Assy . 19-5/8" CSG, 47#, L-80, ID = 8.681" H 3876' r-.4 ~ I ECLIPSE SERIES III PKR STRADDLE ASSY, ID = 1.75" H I Cretaceous Leak @ 6780' I 6451' " ~ ~" -:? IChem Cut tubing @ 4100' MOl 1 TOP OF BKRTIEBACKSLEEVE H 13-1/2" TBG, 9.2#, L-80, .00870 bpf, ID = 2.992" H 17" x 5" BKR LINER HGR H 10198' 10205' 10206' I ~ ~J I Top of P&A Cement @ +/- 10,000' MO I BKRKBH-SEALASSY,ID=3.938" H 10149' I ITOP OF 2-3/8" LNR, ID= 1.995" H 10160' J ) \ II 17" CSG, 26#, L-80, .0383 bpf, ID = 6.276" H 10372' ~ ~ TREE = 4-1/16" MCEVOY WELLHEAD = FMC ACTUATOR = NA . ,,~~~ .. "..'M~~UW KB. ELEV = 65.7' BF. ELEV = 33.37' KOP = 1500' ,~ U~. Max Angle = 100 @ 11906' Datum MD = u..u~",< Datum lVD = 8800' SS 15" LNR, 15#, 13-CR-80 U45, 10 = 4.408" H 11056' I PBTO H 12503' I I O-RING SUB, 10 = 1.00" H 12503' I 12-3/8" LNR, 4.6#, 13-CR-80, .00387 bpf, 10= 1.995" H 12540' I 1 TO H 12550' I DATE 06/28/94 08/01/00 09/28/00 02/13/01 06/23/01 08/25/01 REV BY SIS-Isl SIS-MD CHITP Æ/CH COMMENTS ORIGINAL COM PLETION CTD SIDETRACK CONVERTED TO CANVAS FINAL CORRECTIONS CORRECTIONS DATE REV BY COMMENTS 01/02/02 DDW/KAK ECLIPSE SERIES III PKR 06/13/03 CMOffLP KB ELEVATION & MAX ANGLE PRUDHOE BAY UNfT WELL: 15-37A PERMfT: 2000720 API No: 50-029-22485-01 SEe 22, T11 N, R14E, 1445' FNL & 4419' FEL BP Exploration (Alaska) 3700' 3876' 4000' 4050' 4100' Date 11-20-03 11-378 Kick-.ff Top of Cement 9-5/8",47#, L-80 Mechanical Casing Cut 7" CIBP / Chern Tubing Cut ~ .J .... ~ Rev By Comments RBT Proposed Kick-off TREE = 4-1/16" MCEVOY WELLHEAD = FMC ACTUATOR = NA KB. ELEV = 65.7' ~~._~" ..0'..... ..._....._.~.__^~~m,," "0 BF. ELEV = 33.37' KOP= 1500' ~.~..,_..^. '. _..~~" Max Angle = 1 00 @ 11906' Datum MD = 5atûiïîï'\/D~",--aaOÖ;mSS PRUDHOE BAY UNIT WELL: 15-37B API NO: Permit NO: GPB Rotary Drilling 15-378 Ptoposed Cdtnpletion 3876' 4000' 4050' 4100' vvvv - - ~ .1 .. Date 11-21-03 12-01-03 Rev By RBT RBT 'X' Nipple @ 2200' MD TREE = 4-1/16" MCEVOY WB...LHE:AD = FMC ActuATOR = U""NÞ: KB. B...EV = 65.7' . M~.".~.M.~,..~...~M.M~..~.,,~_~_<_u_ . . BF. B...EV = 33.37' . . u KOP = 1500' u ~...~,~,_,______"_____,_____,______ _________, u" ,~~~ Max Angle = 100 @ 11906' U~ ~M . , <~'~'~nm Datum MD = .--P........."................. Datum lVD = 8800' SS 9-5/8",47#, L-80 4-1/2", 12.6#, 13Cr, VAM-ACE Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG TOC @ 4,500' / GLM Design: #4 - 3150' TVD - 4-1/2" X1" - SV #3 - 5000' TVD - 4-1/2" X 1" - DV #2 - 6500' TVD - 4-1/2" X 1" - DV #1 - 8000' TVD - 4-1/2" X 1" - DV 7" X 4-1/2" Packer @ 9,951' ) \ . 7" X 4-1/2" HMC Liner Hanger with C2/ZXP Liner Top Packer @ 10,001' ~ ./ 7",26#, L-80, BTC-M @ 10,151' 4-1/2", 12.6#, L-80, IBT-M @ 12,363' ¡/ Comments PRUDHOE BAY UNIT WELL: 15-37B API NO: Permit NO: GPB Rotary Drilling Proposed Completion Proposed Completion e 21 . 19 . 18. 17 . 16 . -t~ ~~ &0 6 · v¡b{ 26. 5 · 4 · 3 · 23. 2 · 1 · 24. 32 + ~~ 'lU ~::J I n ( ì LOCATED WITHIN PROTRACTED SEC. 22, T. 11 N., R. 14 L, U.M., AK. WELL A.S.P. PLANT GEODETIC CELLAR SECTION NO. COORDINA TES COORDIN A TES POSITION BOX ELEV. OFFSETS 32 ~: 5':i::~;~:~; ~.. 92~ci:3~ 1 ~~'.~~~i".~~~: 33.3' 1 ~~~: ~~ 33 Y=5,960,923.44 N.2094.75 70'17'55.812" 32.6' 559' FNL X= 676,021.45 E. 200.82 148'34'27.817" 106' FWL Y=5,960,075.99 N.1075.17 70'17'47.280" 30.7' 1428' FNL 34 X= 676,882.82 E. 849.52 148'34'03.295" 945' FWL Y=5,960,069.36 N.1075.22 7017'47.222" 30.8' 1434' FNL 35 X= 676,853.88 L 819.82 148'34'04.143" 916' FWL 36 Y=5.960,062.30 N.1074.90 70'17'47.159" "1.0' 1440' FNL X.. 676,824.72 L 789.83 148'34'04.997"" 887' FWL 37 Y= 5,960.055.71 v N.1075.03 7017'47.101" "1.0' 1446' FNLo/ X= 676795.62" L 759.99 148'34'05.850"" 858' FWL.... TBD Y=5,960,049.05 N.l075.07 70'17'47.042" 31.0' 1452' FNL x= 676,766.58 L 730.20 148'34'06.701" 828' FWL 38 Y=5,960,042.07 N.l074.90 70'17'46.980" 31.3' 1458' FNL x= 676,737.11 L 699.91 148'34'07.564" 799' FWL 39 Y=5,960,035.53 N. 1075.11 70'17'46.923" 31.3' 1464' FNL X= 676,707.84 L 669.92 148'34'08.422" 769' FWL Y= 5,960,028.61 N.l074.90 70'17'46.862" 31.2' 1470' FNL 40 x= 676,678.81 L 640.07 148'34'09.272" 740' FWL 41 Y=5,960,022.09 N.l075.22 70'17'46.804" 31.5' 1476' FNL X= 676,649.16 L 609.72 148'34'10.141" 710' FWL \,...",1;' ~ ..........~ > 1 o REV. 4/11/94 3/20/94 DATE I -~- I DRILL SITE 15 ~ LEGEND -+ AS- BUlL T WELLS . EXISTING WELLS TBD '-- \J e - \t. "0 o "0 o n 15 ~. - - a Z è2 :5 0 Q.. 21 °0 \} VICINITY MAP N.T.S. r- NOTES 1. . DATES OF SURVEYS: FEB. 2, 18, MAR. 20 AND APR. 10 1994. 2. REF. FIELD BOOK: PB94-02 (PGS. 57-59) PB94-12 (PGS. 16-17) PB94-10 (PGS. 32-38) PB94-10 (PGS. 63-65) 3. HORIZONTAL/VERTICAL CONTROL BASED ON MONUMENTS ÐS-15C AND DS-15D. 4. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD27. 5. DRILL SITE SCALE FACTOR: 0.9999355. 6. WELL TBD (TO BE DETERMINED) IS WELL 37 ON REV. 0 AND AS-STAKED, WELL TO BE NUMBERED AT A LATER DATE. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 10, 1994. F. R. BELL & ASSOCIATES ARCa Alaska Inc. ~~ bftA","G NAIIE: DRILL SITE 15 WELLS 32-41 AS-BUILT CONDUCTORS "bAIl: CHECK: _OVAl.: OftAWN: MINISH ALLISON CADO fILE ,: DS15AB 3/20/94 DENNY fu<f: Atlf: ADM ADM SCALE: 1"=300' SAD .tJ8f: lsue JWf: DRAWING f: SK-DS15A8 SHt.lT: I REV#: 1 Of 1 1 CHANGED WELL NUMBERS AND LOCATIONS ORIGINAL AS-BUILT ISSUE REVISIONS TRE ORA WN CHECK " :¡;¡ '" '" ~ + ~ ~ £' " " en COMPANY DETAILS BP Amoco REFERENCE INFORMATION Co-ordimlre (N/E) Iœf~'fIœ; Vertiall(TVD)~nce: &.-.:tiou (VS) Refurence: Measured Depth Ref..mmœ: Cakularion Method: 59.50 Calculation Method; Minimum Curvature ErrorSystem: ISCWSA Scan Method: Trav Cylinder North Error Surface: ElJìptîcal+Casîng Wam~ Melhod: Rules Ba.wd CASING DETAILS No. TVD MD Name 8234.50 10151.41 7" 8784.01 12363.00 4 1/2" 5600- 4800 4000- ~~. 2400- 800 West(-)lEast(+) [800f11in Size 7.000 4.500 SURVEY PROGRA_M Depth Fm Depth To SurveylPJan 4000.00 12363.00 Planned: 1$-378 wp05 V4 Too! MWD+lFR+MS Plan: 15-37B wp05 (IS-31/Plan 15·378 Shallow KG) Created By: Ken Allen Checked: Date: 12/ 1/2003 Date Reviewed: Date WELL DETArts N..~ +N/-S +Ef-W Northíng Ea:aing Latit'l.k.k Loogitude Slot 15·37 1206J9 521.09 5%0055.70 676795jjf) 70"17'47JOIN 148"34'05..850W 37 TARGET DETAILS Nmoo TVD +NI-S +Ef·W Northing Ew¡ring Shape 15-31BA Point 15-31BT3a Point !5+37BFJt#! Polygon 1.5-37B T2 Point 15~37BTl Point 15*37BPo!y Polygon SECTION DETAILS See MD Ine AD TVD +N/-S +E/-W DLeg TFace VSee Target 1 4000.00 44.95 19.88 3650.22 1204.24 435.41 0.00 0.00 1199.44 2 4020.00 45.21 16.51 3664.34 1217.68 439.82 12.00 -&5.00 1212.55 3 4250.00 43.86 352 3828.63 1375.81 467.97 4.00 -103.00 1351.24 4 4600.00 43.&6 352 4080.98 1617.88 4&2.85 0.00 0.00 1545.29 5 48&8.03 43.86 16.00 4289.04 1813.78 51654 3.00 9450 1716.35 6 5988.03 43.86 16.00 5082.13 2546.49 726.64 0.00 0.00 2410.64 7 6149.69 43.86 23.00 5198.69 2652.03 764.01 3.00 90.00 2515.24 8 7249.69 43.86 23.00 5991.77 3353.68 1061.84 0.00 0.00 3242.69 9 7422.99 43.93 30.50 6116.74 3460.82 1115.85 3.00 91.99 3359.30 10 9221.67 43.93 30.50 7412.15 4536.01 1749.20 0.00 0.00 458&.68 11 9535.86 32.00 24.00 765950 4706.65 1838. 74 4.00 -164.00 4776.67 15-37B A 12 10105.43 9.22 22.85 8189.12 4888.98 1918.90 4.00 -179.52 4967.49 13 10296.70 9.22 22.85 8377.91 4917.21 1930.80 0.00 0.00 4996.71 14 10985.49 90.00 1l0.00 8&09.50 4832.23 2368.87 v/Í3.oo 87.19 5215.76 15-37B T1 15 11103.70 90.68 114.68 8808.80 4787.31 2478.18 4.00 81.74 5252.36 16 12022.40 90.68 114.68 8797.92 4403.74 3312.90 0.00 0.00 5500.90 17 12074.05 92.48 115.69 8796.50 4381.77 3359.62 4.00 29.40 5514.43 15-37B T2 . 18 12363.00 92.48 115.69 8784.01 4256.61 3619.75 0.00 0.00 5587.60 15-37B T3a FORMATION TOP DETAILS No. TVDPath MD1'ath Formation 1 4141.50 4683.82 Formation 3 2 4637.50 5371.33 UG4 3 595950 7204.93 WS2 4 6 14850 7467.09 WSl 5 637050 7775.34 CM3/KI0 6 6&14.50 8391.84 CM2 7 7491.50 9328.28 CMl & 7818.50 9716.71 THRZ 9 8002.50 9913.72 BHRZ 10 8064.50 9978.10 LCU/TJB 11 814550 10061.13 TJA 12 8234.50 10151.41 TSGR 13 8279.50 10197.00 TSHU 14 8349.50 10267.91 TZ4B 15 8549.50 10475.70 TZ2 16 8753.50 10759.40 TZlB 17 8796.50 10877.48 TZIA I I I ..I " I ¡P I ; ,I /.. COMPANY DETAILS SP A.moco REFERENCE fNFORMA TION SURVEY PRDGRAM Depth Fm Depth To Survey!Pùm 4000.00 !1363.00 Planned: 15-31B wp05 V4 Plan: 15-37B wp05 (15~37!P!lln 15-37B ShaUow KO) Tool Created By: Ken Allen Checked: Date: 12{ f2003 Calculation Method: Mìnimum C-UtVUture .furor System: JSCWSA Sdt.n Method: Tm\' Cylinder North Error SII.t'ÍÌlce: EUíptkaJ + Casíng Wamiull Method: Rules Based MWD+-JFR+MS Date 59.50 Reviewed: Date 3600- WELL DETAILS Næœ +-Nl-S +E/-W Nocfumg Easting Latitude LöJIßìtude Slot 15·37 120639 527.09 5960055.70 616795.60 7Q*11'47.JOJN J48"34'05.85ùW 37 TARGET DETAILS Nmre TVD +Nt...s +£!-w Norfuiog Easting Shap' J5-3-7SA Porn, J5-37BT3a POÚ1,t 15-37BFlt#1 Polygon 15-37BT2 P;;ínt 15-37B T1 Poínt 15-37ßf>-oly Polygon SECTION DETAILS Sec MD Ine Azi TVD +N/-S +E/-W DLeg TFace vSec Target I 4000.00 44.95 19.88 3650.22 1204.24 435.41 0.00 0.00 099.44 2 4020.00 4521 16.51 3664.34 1217.68 439.82 12.00 -85.00 1212.55 3 4250.00 43.86 3.52 3828.63 1375.81 467.97 4.00 -103.00 1351.24 4 4600.00 43.86 3.52 4080.98 1617.88 482.85 0.00 0.00 1545.29 5 4888.03 43.86 16.00 4289.04 1813.78 516.54 3.00 94.50 1716.35 6 5988.03 43.86 16.00 5082.13 2546.49 726.64 0.00 0.00 2410.64 7 6149.69 43.86 23.00 5198.69 2652.03 764.01 3.00 90.00 2515.24 8 7249.69 43.86 23.00 599L77 3353.68 1061.84 0.00 0.00 3242.69 9 7422.99 43.93 30.50 6116.74 3460.82 1 115.85 3.00 91.99 3359.30 10 9221.67 43.93 30.50 7412.15 4536.0 1 1749.20 0.00 0.00 4588.68 11 9535.86 32.00 24.00 7659.50 4706.65 1838;74 4.00 -164.00 4776.67 15-37B A 12 10105.43 9.22 22.85 8189.12 4888.98 1918.90 4.00 -179.52 4967.49 13 10296.70 9.22 22.85 8377.91 4917.21 1930.80 0.00 0.00 4996.71 14 10985.49 90.00 110.00 8809.50 483223 2368.87 13.00 87.19 5215.76 15-37B TI Dir 31100' : 7249.69' MD, 5991.77'TVD 15 11103.70 90.68 114.68 8808.80 4787.31 2478.18 4.00 81.74 5252.36 16 12022.40 90.68 114.68 8797.92 4403.74 3312.90 0.00 0.00 5500.90 17 12074.05 92.48 115.69 8796.50 4381.77 3359.62 4.00 29.40 5514.43 15·37B T2 18 12363.00 92.48 115.69 8784.01 4256.61 3619.75 0.00 0.00 5587.60 15-37B T3a " ~ '" ~ oS '" " " ';¡j " .~ ;;. ~ ¡ 7200 End Dir : 4888.03' MD. 4289.04' TVD 5400- Start Dir4/1oo': 9221.67' MD, 7412.1S'TVD FORMATION TOP DETAILS No. TVDPafu MDPath Fonnation 1 4141.50 4683.82 Formation 3 2 4637.50 5371.33 UG4 3 5959.50 7204.93 WS2 4 6148.50 7467.09 WSI 5 6370.50 7775.34 CM3/KI0 6 6814.50 8391.84 CM2 7 7491.50 9328.28 CMl 8 1818.50 9716.71 THRZ 9 8002.50 9913.72 BHRZ 10 8064.50 9918. 10 LCU/TIB l! 8145.50 l006U3 TJA 12 8234.50 10151.41 TSGR 13 8279.50 10197,00 TSHU 14 8349.50 10267.91 TZ4B 15 8549.50 10475.10 TZ2 16 8753.50 10159.40 TZ1B 17 8196.50 10877.48 TZIA CASING DETAILS No. TVD MD Name Size 8234.50 10151.41 7" 1.000 8784.01 12363.00 4112" 4.500 10296.7' MD, 8377.9l'TVD Tota! Depth : 12363' MD, 8784.01' TVD 15-37B wpü5 / 15-37 (15-3704.) ¡ I 6300 I r 1 I ¡ ] I Vertical SecJíon at 40.38" [900ft/in] speI"""".....y-!iII....n a...._...INII ....Vll::.. 'perry-Sun - Draft Copy . KW A Planning ,. 11AUØl'lt'tON UN'AN'o' Plan: 15-37B wp05 Principal: Yes 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 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft ObP 11/2412003 4 From: Definitive Path Alaska, Zone 4 Well Centre bggm2003 35.236 N 21.213 W True 1.34 deg Well: 15-37 Slot Name: 37 15-37 Well Position: +N/-S 1206.39 ft Northing: 5960055.70 ft Latitude: 70 17 47.101 N +E/-W 527.09 ft Easting : 676795.60 ft Longitude: 148 34 5.850 W Position Uncertainty: 0.00 ft Wellpath: Plan 15-37B Shallow KO Current Datum: Magnetic Data: Field Strength: Vertical Section: 59.500' @ 0.0 (59.50') 7/15/2003 57573 nT Depth From (TVD) ft 28.50 Casing Points 10151.41 8234.50 12363.00 8784.01 7.000 4.500 8.500 6.125 Formations 4683.82 5371.33 7204.93 7467.09 7775.34 8391.84 9328.28 9716.71 9913.72 9978.10 10061.13 10151.41 10197.00 10267.91 10475.70 10759.40 10877.48 4141.50 4637.50 5959.50 6148.50 6370.50 6814.50 7491.50 7818.50 8002.50 8064.50 8145.50 8234.50 8279.50 8349.50 8549.50 8753.50 8796.50 Formation 3 UG4 WS2 WS1 CM3/K10 CM2 CM1 THRZ BHRZ LCUfT JB TJA TSGR TSHU TZ4B TZ2 TZ1B TZ1A Date Composed: Version: Tied-to: Map Zone: Coordinate System: Geomagnetic Model: 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: Height 59.50 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 +N/-S ft 0.00 7" 4 1/2" 15-37 4000.00 ft Mean Sea Level 25.68 deg 80.86 deg Direction deg 40.38 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ........ .. 'Y-!i5L.Jn C:UULLIWCI ....VIC.. Company: Field: Site: Well: Wellpath: Targets Au.u.a..øutoU\l~ .perry-Sun - Draft Copy . KW A Planning 6P Amoco Prudhoe Bay P6 DS 15 15-37 Plan 15-376 Shallow KO Name 15-376 A 15-376 T3a 15-376 FIt#1 -Polygon 1 -Polygon 2 15-376 T2 15-376 T1 15-376 Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 Deseription TVD Dip. Dir. ft 7659.50 8784.01 8784.50 8784.50 8784.50 8796.50 8809.50 8809.50 8809.50 8809.50 8809.50 8809.50 8809.50 8809.50 Plan Section Information MD ft 4000.00 4020.00 4250.00 4600.00 4888.03 5988.03 6149.69 7249.69 7422.99 9221.67 9535.86 10105.43 10296.70 10985.49 11103.70 12022.40 12074.05 12363.00 Survey MD ft 4000.00 4020.00 4100.00 4200.00 4250.00 4300.00 4400.00 4500.00 4600.00 4683.82 4700.00 4800.00 4888.03 Incl deg 44.95 45.21 43.86 43.86 43.86 43.86 43.86 43.86 43.93 43.93 32.00 9.22 9.22 90.00 90.68 90.68 92.48 92.48 Azim AA9 19.88 16.51 3.52 3.52 16.00 16.00 23.00 23.00 30.50 30.50 24.00 22.85 22.85 110.00 114.68 114.68 115.69 115.69 Incl deg 44.95 45.21 44.57 44.03 43.86 Azim deg 19.88 16.51 12.06 6.39 3.52 43.86 43.86 43.86 43.86 43.72 3.52 3.52 3.52 3.52 7.15 43.71 43.72 43.86 7.85 12.19 16.00 TVD ft 3650.22 3664.34 3828.63 4080.98 4289.04 5082.13 5198.69 5991.77 6116.74 7412.15 7659.50 8189.12 8377.91 8809.50 8808.80 8797.92 8796.50 8784.01 TVD ft 3650.22 3664.34 3721.03 3792.63 3828.63 3864.68 3936.78 4008.88 4080.98 4141.50 4153.19 4225.49 4289.04 +N/.s ft 1204.24 1217.68 1375.81 1617.88 1813.78 2546.49 2652.03 3353.68 3460.82 4536.01 4706.65 4888.98 4917.21 4832.23 4787.31 4403.74 4381.77 4256.61 Sys TVD ft 3590.72 3604.84 3661.53 3733.13 3769.13 3805.18 3877.28 3949.38 4021.48 4082.00 4093.69 4165.99 4229.54 ObP Date: 12/112003 Time: 09:47:49 Page: Z Co-ordiJlate(NE) Reference: Well: 15-37, True North Vertical (TVD) Referenee: 59.500' @ 0.0 (59.50') 59.5 Section (VS) Reference: Well (0.OON,O.OOE,40.38Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +N/.s ft 4706.65 4256.61 4021.36 4021.36 4430.82 4381.77 +EI-W ft 1838.74 3619.75 3499.19 3499.19 4166.04 3359.62 2368.87 4832.23 4742.63 4742.63 4132.59 4265.72 4462.59 4633.82 4894.12 2392.77 2392.77 3618.84 3785.03 3963.72 3403.56 2459.36 +EI-W ft 435.41 439.82 467.97 482.85 516.54 726.64 764.01 1061.84 1115.85 1749.20 1838.74 1918.90 1930.80 2368.87 2478.18 3312.90 3359.62 3619.75 MapN ft 5961269.77 5961283.32 5961338.31 5961407.43 5961442.05 5961476.67 5961545.91 5961615.15 5961684.39 5961742.23 5961753.35 5961821.62 5961881.01 Map Map Northing EastiDg ft ft 5964804.00 678523.00 5964396.00 680313.99 5964158.00 680199.00 5964158.00 680199.00 5964583.00 680856.00 5964515.00 680051.00 5964942.00 679050.00 5964853.00 679076.00 5964853.00 679076.00 5964272.00 680316.00 5964409.00 680479.00 5964610.00 680653.00 5964768.00 680089.00 5965006.00 679139.00 <- Latitude --> <- Longitude -'> Deg Min See Deg MiD See 70 18 33.388 N 148 33 12.221 W 70 1828.956 N 70 1826.643 N 70 18 26.643 N 70 18 30.666 N 70 18 30.188 N 70 18 34.622 N 70 18 33.741 N 70 18 33.741 N 70 18 27.736 N 70 1829.045 N 70 1830.980 N 70 1832.667 N 70 18 35.230 N DLS Build Turn degl100ft cleg/100ft degl100ft 0.00 12.00 4.00 0.00 3.00 0.00 3.00 0.00 3.00 0.00 4.00 4.00 0.00 13.00 4.00 0.00 4.00 0.00 MapE ft 677202.53 677206.63 677219.28 677228.86 677231.04 677232.36 677234.98 677237.60 677240.22 677244.25 677245.45 677255.86 677269.30 0.00 1.29 -0.58 0.00 0.00 0.00 0.00 0.00 0.04 0.00 -3.80 -4.00 0.00 11.73 0.57 0.00 3.48 0.00 0.00 -16.85 -5.65 0.00 4.33 0.00 4.33 0.00 4.33 0.00 -2.07 -0.20 0.00 12.65 3.96 0.00 1.97 0.00 VS ft 1199.44 1212.55 1263.24 1322.97 1351.24 1378.96 1434.40 1489.84 1545.29 1592.76 1602.15 1661.75 1716.35 TFO AA9 0.00 -85.00 -103.00 0.00 94.50 0.00 90.00 0.00 91.99 0.00 -164.00 -179.52 0.00 87.19 81.74 0.00 29.40 0.00 DLS TFO degl100ft deg 0.00 0.00 12.00 275.00 4.00 257.00 4.00 260.15 4.00 264.21 0.00 0.00 0.00 0.00 3.00 3.00 3.00 3.00 Target 15-376 A 15-376 T1 15-376 T2 15-376 T3a 148 32 20.282 W 148 3223.801 W 148 3223.801 W 148 32 4.347 W 148 32 27.867 W 148 32 56.758 W 148 32 56.061 W 148 32 56.061 W 148 32 20.310 W 148 32 15.462 W 148 32 10.247 W 148 3226.582 W 1483254.118W Tool MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 94.50 Formation 3 91.88 MWD+IFR+MS 91.37 MWD+IFR+MS 88.23 MWD+IFR+MS \ ....... .. ·y-sun .perry-sun Draft Copy e a..II.....INII ....VIC.. - ObP " Iw.u&WlUN t.,...~ KW A Planning ÇOlJlpåny: BPArnoco ~te: 12/112003 . Tlme:09:47:49 ~!ig.: 3 Field: Prudhoe Bay ço-,ordina~)~f~l"C:nee: .Well: 15.37,Tfue'it)l0rtQ Site: PBDS15 y,rtieal (TVD~R~~ren«:5~;59()'@ 0·9(~~·?9~~~;~ Well: 15--37 ~on (VS) ~fer~"ee: l/\Ient9,.()QN,O.00¡:,4Q;~i) Wellpatb: P/an15-37B Shallow KO Sl1rvey ÇaleulatiOnMetboo: MinilJlumCurvature Dbi OraCle Survey Inel AZim ¡;teg deg 4900.00 43.86 16.00 4297.68 4238.18 5961889.04 677271.40 1723.91 0.00 0.00 MWD+IFR+MS 5000.00 43.86 16.00 4369.78 4310.28 5961956.08 677288.92 1787.02 0.00 0.00 MWD+IFR+MS 5100.00 43.86 16.00 4441.87 4382.37 5962023.11 677306.45 1850.14 0.00 0.00 MWD+IFR+MS 5200.00 43.86 16.00 4513.97 4454.47 5962090.15 677323.98 1913.26 0.00 0.00 MWD+IFR+MS 5300.00 43.86 16.00 4586.07 4526.57 5962157.19 677341.50 1976.38 0.00 0.00 MWD+/FR+MS 5371.33 43.86 16.00 4637.50 4578.00 5962205.01 677354.01 2021.40 0.00 0.00 UG4 5400.00 43.86 16.00 4658.17 4598.67 5962224.23 677359.03 2039.49 0.00 0.00 MWD+IFR+MS 5500.00 43.86 16.00 4730.27 4670.77 5962291.26 677376.56 2102.61 0.00 0.00 MWD+IFR+MS 5600.00 43.86 16.00 4802.37 4742.87 5962358.30 677394.08 2165.73 0.00 0.00 MWD+IFR+MS 5700.00 43.86 16.00 4874.47 4814.97 5962425.34 677411.61 2228.84 0.00 0.00 MWD+IFR+MS 5800.00 43.86 16.00 4946.57 4887.07 5962492.37 677429.14 2291.96 0.00 0.00 MWD+IFR+MS 5900.00 43.86 16.00 5018.66 4959.16 5962559.41 677446.67 2355.08 0.00 0.00 MWD+IFR+MS 5988.03 43.86 16.00 5082.13 5022.63 5962618.42 677462.09 2410.64 0.00 0.00 MWD+IFR+MS 6000.00 43.86 16.52 5090.76 5031.26 5962626.44 677464.23 2418.21 3.00 90.19 MWD+IFR+MS 6100.00 43.86 20.85 5162.86 5103.36 5962692.57 677484.87 2482.58 3.00 91.56 MWD+/FR+MS 6149.69 43.86 23.00 5198.69 5139.19 5962724.80 677496.97 2515.24 3.00 90.78 MWD+IFR+MS 6200.00 43.86 23.00 5234.96 5175.46 5962757.20 677509.83 2548.51 0.00 0.00 MWD+IFR+MS 6300.00 43.86 23.00 5307.06 5247.56 5962821.60 677535.40 2614.64 0.00 0.00 MWD+IFR+MS 6400.00 43.86 23.00 5379.16 5319.66 5962886.00 677560.96 2680.78 0.00 0.00 MWD+IFR+MS 6500.00 43.86 23.00 5451.26 5391.76 5962950.40 677586.53 2746.91 0.00 0.00 MWD+IFR+MS 6600.00 43.86 23.00 5523.36 5463.86 5963014.80 677612.10 2813.04 0.00 0.00 MWD+IFR+MS 6700.00 43.86 23.00 5595.45 5535.95 5963079.20 677637.66 2879.17 0.00 0.00 MWD+IFR+MS 6800.00 43.86 23.00 5667.55 5608.05 5963143.61 677663.23 2945.30 0.00 0.00 MWD+IFR+MS 6900.00 43.86 23.00 5739.65 5680.15 5963208.01 677688.79 3011.44 0.00 0.00 MWD+IFR+MS 7000.00 43.86 23.00 5811.75 5752.25 5963272.41 677714.36 3077.57 0.00 0.00 MWD+IFR+MS 7100.00 43.86 23.00 5883.85 5824.35 5963336.81 677739.93 3143.70 0.00 0.00 MWD+IFR+MS 7200.00 43.86 23.00 5955.95 5896.45 5963401.21 677765.49 3209.83 0.00 0.00 MWD+IFR+MS 7204.93 43.86 23.00 5959.50 5900.00 5963404.38 677766.75 3213.09 0.00 0.00 WS2 7249.69 43.86 23.00 5991.77 5932.27 5963433.21 677778.20 3242.69 0.00 0.00 MWD+IFR+MS 7300.00 43.83 25.18 6028.06 5968.56 5963465.35 677791.67 3276.14 3.00 91.99 MWD+IFR+MS 7400.00 43.89 29.51 6100.18 6040.68 5963527.60 677822.02 3343.62 3.00 90.42 MWD+IFR+MS 7422.99 43.93 30.50 6116.74 6057.24 5963541.59 677829.67 3359.30 3.00 87.29 MWD+IFR+MS 7467.09 43.93 30.50 6148.50 6089.00 5963568.30 677844.57 3389.44 0.00 0.00 WS1 7500.00 43.93 30.50 6172.20 6112.70 5963588.24 677855.69 3411.94 0.00 0.00 MWD+IFR+MS 7600.00 43.93 30.50 6244.22 6184.72 5963648.83 677889.48 3480.29 0.00 0.00 MWD+IFR+MS 7700.00 43.93 30.50 6316.24 6256.74 5963709.41 677923.28 3548.63 0.00 0.00 MWD+IFR+MS 7775.34 43.93 30.50 6370.50 6311.00 5963755.06 677948.74 3600.13 0.00 0.00 CM3/K10 7800.00 43.93 30.50 6388.26 6328.76 5963770.00 677957.07 3616.98 0.00 0.00 MWD+IFR+MS 7900.00 43.93 30.50 6460.28 6400.78 5963830.58 677990.87 3685.33 0.00 0.00 MWD+IFR+MS 8000.00 43.93 30.50 6532.30 6472.80 5963891.17 678024.66 3753.68 0.00 0.00 MWD+IFR+MS 8100.00 43.93 30.50 6604.32 6544.82 5963951.75 678058.45 3822.03 0.00 0.00 MWD+IFR+MS 8200.00 43.93 30.50 6676.34 6616.84 5964012.34 678092.25 3890.38 0.00 0.00 MWD+IFR+MS 8300.00 43.93 30.50 6748.36 6688.86 5964072.92 678126.04 3958.73 0.00 0.00 MWD+IFR+MS 8391.84 43.93 30.50 6814.50 6755.00 5964128.56 678157.08 4021.49 0.00 0.00 CM2 8400.00 43.93 30.50 6820.38 6760.88 5964133.51 678159.84 4027.07 0.00 0.00 MWD+IFR+MS 8500.00 43.93 30.50 6892.40 6832.90 5964194.09 678193.63 4095.42 0.00 0.00 MWD+IFR+MS 8600.00 43.93 30.50 6964.42 6904.92 5964254.67 678227.42 4163.77 0.00 0.00 MWD+IFR+MS 8700.00 43.93 30.50 7036.44 6976.94 5964315.26 678261.22 4232.12 0.00 0.00 MWD+IFR+MS 8800.00 43.93 30.50 7108.46 7048.96 5964375.84 678295.01 4300.47 0.00 0.00 MWD+IFR+MS 8900.00 43.93 30.50 7180.48 7120.98 5964436.43 678328.80 4368.82 0.00 0.00 MWD+IFR+MS 9000.00 43.93 30.50 7252.50 7193.00 5964497.01 678362.60 4437.17 0.00 0.00 MWD+IFR+MS 9100.00 43.93 30.50 7324.52 7265.02 5964557.60 678396.39 4505.51 0.00 0.00 MWD+IFR+MS \ ....._ .. ·y-sun .perry-Sun - Draft Copy e "...I-I-ING ....Vll::.. ObP .\~"_ANY KW A Planning ç~æp¡i!lY: BPAmoCQ Jj'i~: Prydhoe Bay ~.~; PBDS.15 \V¢ll; 15¡,3:'? Wellpat)î: PIahJ15-,37BShalIoWKO Survey 9200.00 43.93 30.50 7396.54 7337.04 5964618.18 678430.19 4573.86 0.00 0.00 MWD+IFR+MS 9221.67 43.93 30.50 7412.15 7352.65 5964631.31 678437.51 4588.68 0.00 0.00 MWD+IFR+MS 9300.00 40.92 29.18 7469.96 7410.46 5964677.74 678462.73 4640.62 4.00 196.00 MWD+IFR+MS 9328.28 39.84 28.67 7491.50 7432.00 5964693.98 678471.21 4658.58 4.00 196.98 CM1 9400.00 37.11 27.25 7547.64 7488.14 5964733.86 678491.21 4702.16 4.00 197.37 MWD+IFR+MS 9500.00 33.34 24.94 7629.31 7569.81 5964786.20 678515.40 4758.05 4.00 198.48 MWD+IFR+MS 9535.86 32.00 24.00 7659.50 7600.00 5964804.00 678523.00 4776.67 4.00 200.37 15-,37B A 9600.00 29.43 23.96 7714.64 7655.14 5964834.24 678535.60 4808.10 4.00 180.48 MWD+IFR+MS 9700.00 25.43 23.87 7803.37 7743.87 5964876.77 678553.28 4852.27 4.00 180.51 MWD+IFR+MS 9716.71 24.77 23.86 7818.50 7759.00 5964883.32 678556.00 4859.07 4.00 180.59 THRZ 9800.00 21.43 23.76 7895.11 7835.61 5964913.51 678568.48 4890.39 4.00 180.60 MWD+IFR+MS 9900.00 17.44 23.60 7989.39 7929.89 5964944.28 678581.13 4922.25 4.00 180.69 MWD+IFR+MS 9913.72 16.89 23.57 8002.50 7943.00 5964948.03 678582.66 4926.13 4.00 180.84 BHRZ 9978.10 14.31 23.42 8064.50 8005.00 5964964.06 678589.19 4942.70 4.00 180.87 LCU/T JB 10000.00 13.44 23.35 8085.76 8026.26 5964968.92 678591.16 4947.72 4.00 181.02 MWD+IFR+MS 10061.13 10.99 23.11 8145.50 8086.00 5964980.92 678595.98 4960.07 4.00 181.08 TJA 10105.43 9.22 22.85 8189.12 8129.62 5964988.15 678598.84 4967.49 4.00 181.32 MWD+IFR+MS 10151.41 9.22 22.85 8234.50 8175.00 5964995.00 678601.54 4974.52 0.00 180.00 7" 10197.00 9.22 22.85 8279.50 8220.00 5965001.80 678604.22 4981.48 0.00 180.00 TSHU 10200.00 9.22 22.85 8282.46 8222.96 5965002.24 678604.40 4981.94 0.00 180.00 MWD+IFR+MS 10267.91 9.22 22.85 8349.50 8290.00 5965012.37 678608.39 4992.32 0.00 180.00 TZ4B 10296.70 9.22 22.85 8377.91 8318.41 5965016.66 678610.08 4996.71 0.00 180.00 MWD+IFR+MS 10300.00 9.25 25.52 8381.17 8321.67 5965017.14 678610.28 4997.22 13.00 87.19 MWD+IFR+MS 10325.00 10.09 44.32 8405.82 8346.32 5965020.58 678612.60 5001.35 13.00 84.55 MWD+IFR+MS 10350.00 11.78 59.01 8430.37 8370.87 5965023.55 678616.25 5005.95 13.00 66.02 MWD+IFR+MS 10375.00 14.03 69.56 8454.74 8395.24 5965026.04 678621.22 5011.02 13.00 51.59 MWD+IFR+MS 10400.00 16.61 77.08 8478.85 8419.35 5965028.05 678627.50 5016.53 13.00 41.29 MWD+IFR+MS 10425.00 19.39 82.57 8502.63 8443.13 5965029.56 678635.07 5022.47 13.00 34.04 MWD+IFR+MS 10450.00 22.29 86.70 8525.99 8466.49 5965030.58 678643.89 5028.82 13.00 28.82 MWD+IFR+MS 10475.00 25.27 89.91 8548.87 8489.37 5965031.09 678653.95 5035.56 13.00 24.96 MWD+IFR+MS 10475.70 25.35 89.99 8549.50 8490.00 5965031.10 678654.25 5035.76 13.00 22.02 TZ2 10500.00 28.31 92.48 8571.18 8511.68 5965031.11 678665.22 5042.67 13.00 21.94 MWD+IFR+MS 10525.00 31.38 94.59 8592.87 8533.37 5965030.62 678677.65 5050.12 13.00 19.72 MWD+IFR+MS 10550.00 34.49 96.35 8613.84 8554.34 5965029.64 678691.20 5057.89 13.00 17.90 MWD+IFR+MS 10575.00 37.62 97.86 8634.05 8574.55 5965028.16 678705.83 5065.95 13.00 16.42 MWD+IFR+MS 10600.00 40.76 99.16 8653.43 8593.93 5965026.18 678721.50 5074.29 13.00 15.20 MWD+IFR+MS 10625.00 43.92 100.31 8671.91 8612.41 5965023.72 678738.16 5082.86 13.00 14.19 MWD+IFR+MS 10650.00 47.09 101.33 8689.43 8629.93 5965020.78 678755.74 5091.66 13.00 13.34 MWD+IFR+MS 10675.00 50.26 102.25 8705.93 8646.43 5965017.38 678774.20 5100.63 13.00 12.62 MWD+IFR+MS 10700.00 53.44 103.10 8721.37 8661.87 5965013.51 678793.47 5109.77 13.00 12.01 MWD+IFR+MS 10725.00 56.63 103.87 8735.70 8676.20 5965009.21 678813.50 5119.03 13.00 11.49 MWD+IFR+MS 10750.00 59.82 104.59 8748.86 8689.36 5965004.47 678834.21 5128.39 13.00 11.05 MWD+IFR+MS 10759.40 61.02 104.85 8753.50 8694.00 5965002.58 678842.16 5131.93 13.00 10.67 TZ1B 10775.00 63.02 105.27 8760.82 8701.32 5964999.31 678855.55 5137.83 13.00 10.54 MWD+IFR+MS 10800.00 66.22 105.90 8771.53 8712.03 5964993.75 678877.44 5147.29 13.00 10.34 MWD+IFR+MS 10825.00 69.42 106.51 8780.97 8721.47 5964987.82 678899.81 5156.77 13.00 10.07 MWD+IFR+MS 10835.35 70.74 106.75 8784.50 8725.00 5964985.25 678909.19 5160.69 13.00 9.84 15-,37B FIt#1 10850.00 72.62 107.09 8789.10 8729.60 5964981.52 678922.59 5166.22 13.00 9.76 MWD+IFR+MS 10875.00 75.83 107.65 8795.90 8736.40 5964974.88 678945.71 5175.62 13.00 9.65 MWD+IFR+MS 10877.48 76.14 107.71 8796.50 8737.00 5964974.20 678948.01 5176.55 13.00 9.50 TZ1A 10900.00 79.03 108.20 8801.34 8741.84 5964967.92 678969.09 5184.94 13.00 9.49 MWD+IFR+MS 10925.00 82.24 108.73 8805.41 8745.91 5964960.66 678992.66 5194.14 13.00 9.38 MWD+IFR+MS 10950.00 85.45 109.26 8808.09 8748.59 5964953.12 679016.34 5203.20 13.00 9.29 MWD+IFR+MS '. "Uü.Ll.lltJk1Ufrl~ .perry-Sun - Draft Copy . KW A Planning ObP ., ........ 'I 'y-s¡u, O".._....NCS ....VIC.. Survey 10975.00 88.65 109.78 8809.38 8749.88 5964945.34 679040.05 5212.09 13.00 9.24 MWD+IFR+MS 10985.49 90.00 110.00 8809.50 8750.00 5964942.00 679050.00 5215.76 13.00 9.21 15-378 T1 11000.00 90.08 110.57 8809.49 8749.99 5964937.29 679063.72 5220.75 4.00 81.74 MWD+IFR+MS 11103.70 90.68 114.68 8808.80 8749.30 5964899.67 679160.33 5252.36 4.00 81.74 MWD+IFR+MS 11200.00 90.68 114.68 8807.66 8748.16 5964861.54 679248.74 5278.41 0.00 180.00 MWD+IFR+MS 11300.00 90.68 114.68 8806.48 8746.98 5964821.94 679340.55 5305.46 0.00 180.00 MWD+IFR+MS 11400.00 90.68 114.68 8805.29 8745.79 5964782.34 679432.36 5332.52 0.00 180.00 MWD+IFR+MS 11500.00 90.68 114.68 8804.11 8744.61 5964742.74 679524.17 5359.57 0.00 180.00 MWD+IFR+MS 11600.00 90.68 114.68 8802.92 8743.42 5964703.14 679615.98 5386.62 0.00 180.00 MWD+IFR+MS 11700.00 90.68 114.68 8801.74 8742.24 5964663.54 679707.79 5413.68 0.00 180.00 MWD+IFR+MS 11800.00 90.68 114.68 8800.56 8741.06 5964623.94 679799.60 5440.73 0.00 180.00 MWD+IFR+MS 11900.00 90.68 114.68 8799.37 8739.87 5964584.34 679891.41 5467.79 0.00 180.00 MWD+IFR+MS 12000.00 90.68 114.68 8798.19 8738.69 5964544.74 679983.22 5494.84 0.00 180.00 MWD+IFR+MS 12022.40 90.68 114.68 8797.92 8738.42 5964535.86 680003.79 5500.90 0.00 180.00 MWD+IFR+MS 12074.05 92.48 115.69 8796.50 8737.00 5964515.00 680051.00 5514.43 4.00 29.40 15-378 T2 12100.00 92.48 115.69 8795.38 8735.88 5964504.31 680074.62 5521.00 0.00 0.00 MWD+IFR+MS 12200.00 92.48 115.69 8791.05 8731.55 5964463.13 680165.64 5546.32 0.00 0.00 MWD+IFR+MS 12300.00 92.48 115.69 8786.73 8727.23 5964421.94 680256.65 5571.65 0.00 0.00 MWD+IFR+MS /12363.00 92.48 115.69 8784.01 J 8724.51 5964396.00 680313.99 5587.60 0.00 0.00 15-378 T3a POSS203 DATE: INVOICE: / CRE:D/T MEMo 11/25/200 PR 111803M DËSCRIPTION G/1oss PERMIT TO DRILL EE:S ~~ VE:NDO/1 DISCOUNT 15'378 Nn RECEIVE JAN 2 0 2004 Cons COt mission Ala ka Oil & Gas . Anchorage "" An",... """". ON ...._, "'" "- __.'" A80". Sf> EXPLORJI,TION. (JI,LAS/(JI,) INc. PRUDHOE BAY UNIT Po BOX 196612 ANCHORAGE, AK99519-6612 PAY: TO THE ORDER OF: Á~ <;Ill &,GAs CONSËRViI TIO¡¡ 333 W 7TH A VENUE SUITE 100 ANCHORAGE, AK 99501-3539 N4TIONAL CI1Y 8ANK AShland, Ohio Sß'38n ~ No. P 055203 P·. .... ..... ~:1. ~ '17"'· 111f1', ,II/! II 'I "/11,1 f,,,,,, ...... If" CONSOL/OA1'E:D COMME:FlCIAL ACCOUNT OATE November 25, 2003 AMOUNT "055203", ':01, ¡ 20 38 c¡ 5,: 0 ¡ 2 ?8C¡G,' ..."..................yO.?AY~. "\ " .. '. ", .. .. .. .......\,....\......,.. \.....~...,..... ...... ,. ;;.':<:;' ,::ø. "':''':J)~ "~~%<).;..' \. i,; . ··,1··"~~y~......IS.._~.._.,."'.. ..... j:~ H e e e e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRJATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME $¿j( /'~S-~ 3-Zð PTD# ~/c/-. ûl'l' CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wellbore segment of existing well Permit No, API No. Productionsbould continue to be reported as a function of the original API number. stated above. HOLE In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for we)) (name on permit). PD...OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\j ody\templates Tbe permit is approved subject -to fuD compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing e:xception. (Company Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample intervals through target zones. Administration Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 15-37B Program DEV_ PTD#: 2040190 Company BP EXPLORATION (ALASKA) INC Initial ClassfType DEV 1 PEND GeoArea 890 Unit 11650 On/Off Shore On 1 Pecmittee attaçhe~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Leasenl,Jmberappropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_niql,Je weltn_ame_and o~mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJUQcated ina d_efine~ pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJUQcated proper _distance_ from driJling I,Jnilb_ol,Jnda(y_ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WeJUQcated prpper _distance_ from other wel]s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7S_uffiçienLacreage_aYailable in_dJilliog ~niL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jtdeviated, is weJlbQre platincJuded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _Opecator only: affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _Opecator has:apprppriate_bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Pecmit c_al1 be iss~ep without co_nservaJion order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 12 Pecmit cal1 be iss~ep without administcative_apprpvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ 1/20/2004 13 Can permit be approved before 15-daywait Yes 14 WelUQcated within area alld_strata_al,Jthorized by_ll1jectioo Or dec # (pl,JlIO# in_cpmm_el1ts) (For_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 15 AJI wel]s_ within JI4_llJite_area_of ceyiew idel1tified (Fpc servjce)'(e[l 01J1y:) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produced injector; ~l,Jration_of pre-pro~l,Jctioo less than 3 months_ (for_service well onJy) _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 ACMPJ:jndingof COllsi$tency.has bee_nJssl,JedforJbis pr_oject . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ Re-drill_of exisJil1g well, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 18 _C_ol1du_ctor stcillgpJQvided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_udace _casing_ PJote~ts alLknowll USDWs _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ N/A; Je-drilLof existiog well, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTv_oladequ_ateJo çirc_utate_on_cOlJd_uctOt& SUJtcsg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _CMTv_otadequ_ateJotie-inJong string to_surfcsg_ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 22 _CMTwil! coyer.aU koown_pro_dl,Jctiye hQrizOIlS_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23Casil1g de_sigl1S ad_equa_te fpc CoT, B_&_pe!11Jafrpst _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 _Mequatetallkage_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ yes _ _ _ _ _ _ _ Nab9rs2E$, _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 JtaJe-dcilL has a_ to,.403 for abandOllment beel1 apPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ 12/t5/2_003. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 _MequateJ"leUbore separatio_nproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdiver:ter Jequired, does it meet reguJaJiOlJs_ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ Sidetcack. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 _DJilliogfJuid_programs~hematic&eq.uipJistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ Yes_ _ _ _ _ _MaxMW_tO.2_ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ WGA 1/21/2004 29 _BOPEs, do_they meetreguJa_tiOIJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 BOPE_press ratil1g appcopciate;Jest to_(put psig in_commelJts) _ _ _ _ _ _ _ _ _ _ _ _ _Y_es _ _ _ _ _ _ Test to_3500_psi.I\lIS~ 28_39 psi. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _CMke_llJanifold çQmpJies w/APtR~-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work wiU occ_uc withoutoperation _sb~tdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Js presence Qf H2S gas prob_able _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Meçha_nicaLcoodjUonpf wells within AOR Yerified (for_s_ervice welJ onM _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Well bore seg Annular Disposal D D - - - - - - Appr SFD Date e Engineering e Appr SFD Date 1/20/2004 35 Pecmit can be iss~ep w/o hypcogen_ s_ulfide meas_uces _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ 1:125 is pcesent on DS j 5: _ peJ 20 MC 25.065, if H2S i$ _kl1own, H25 measuces rnustbetakeo. _ _ _ _ _ _ _ _ _ _ _ _ 36 _D_ata_PJeseotedon_pote_ntialoveJpressl,Jre_zone$_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _Expectedreservoirpress~reis_8,6_ppgEMWtpJop_oJSag,thel17._2_ppgthroughSag-_TD-,- 37 _Seismic_analysjs_ of shaJlow gas_zPoes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 38 _Seabed _conditioo s~rvey Jif off-shpce) _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Contact lJamelpholleJorweekly progreSHeports [explorato(y _only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date DT5 \\2Ó{+- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun DrtlÞing Services LIS Scan Utility e ~ð tf-o Ie¡ D3 ¡./ / ~!J-? , $Revision: 3 $ LisLib $Revision: 4 $ Thu May 13 13:02:02 2004 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/05/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............ ... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name......... ... .LISTPE Date.................... .04/05/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name.... ...UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-37B 500292248502 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 13-MAY-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003034589 T. GALVIN D. WILLIAMS MWD RUN 2 MW0003034589 T. GALVIN D. WILLIAMS MWD RUN 3 MW0003034589 J. SACK D. GREEN / J JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003034589 J. SACK D. GREEN / J # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 11N 14E 1446 858 RECE\VEO !! \\.! 0 9 2004 \JVl'i au &. Gas Cons. conUi\Iss\On At_a AncnOiB9€ 59.50 31.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT silt 8.500 6.125 (IN) SIZE (IN) DEPTH (FT) 9.625 3881.0 7.000 10164.0 e # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) ¡ AND PRESSURE WHILE DRILLING (PWD). 4. MWD RUNS 3 & 4 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ COMPENSATED THERMAL NEUTRON POROSITY (CTN) ¡ STABILIZED LITHO-DENSITY (SLD) ¡ AND AT-BIT- INCLINATION (ABI). 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 10' DEEPER PER E-MAIL FROM K. COONEY (SIS/BP), DATED 5/12/04. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 6. MWD RUNS 1 - 4 REPRESENT WELL 15-37B WITH API#: 50-029-22485-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12741'MD/8780'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.4 - 8.5 PPG MUD SALINITY: 1900 - 3000 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: $ SttSTONE e File Header Service name. ........... .STSLIB.001 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation..... ..04/05/13 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NPHI NCNT FCNT RHOB DRHO PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3613.0 3870.0 3870.0 3870.0 3870.0 3870.0 3891.0 10160.0 10160.0 10160.0 10164.0 10164.0 10164.0 STOP DEPTH 12422.5 12429.5 12429.5 12429.5 12429.5 12429.5 12481.0 12387.5 12387.5 12388.0 12401. 5 12401. 5 12401.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH GR 3613 .0 3603.0 12481.0 12471. 0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 3603.0 4071. 0 MWD 2 4071.0 10164.0 MWD 3 10164.0 10653.0 MWD 4 10653.0 12471.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.... .... ........ ..0 Data Specification Block Type.....O Logging Direction............ .... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing......... ........... .60 .1IN Max frames per record..... ....... .Undefined Absent value................ ..... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 ROP MWD FT/H e 1 68 4 2 e GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 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 FCNT MWD CNTS 4 1 68 32 9 NCNT MWD CNTS 4 1 68 36 10 RHOB MWD G/CM 4 1 68 40 11 DRHO MWD G/CM 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3613 12481 8047 17737 3613 12481 ROP MWD FT/H 0.16 388.78 155.368 17181 3891 12481 GR MWD API 7.99 548.3 86.5082 17620 3613 12422.5 RPX MWD OHMM 0.35 2000 79.9632 17120 3870 12429.5 RPS MWD OHMM 0.37 2000 49.4787 17120 3870 12429.5 RPM MWD OHMM 0.36 2000 55.7472 17120 3870 12429.5 RPD MWD OHMM 0.11 2000 78.1571 17120 3870 12429.5 FET MWD HOUR 0.14 80.33 1.34852 17120 3870 12429.5 FCNT MWD CNTS 101. 2 2686.1 759.385 4457 10160 12388 NCNT MWD CNTS 12510.4 48045.7 30149.1 4456 10160 12387.5 RHOB MWD G/CM 1.792 3.181 2.33477 4476 10164 12401.5 DRHO MWD G/CM -0.234 0.682 0.0759388 4476 10164 12401. 5 PEF MWD BARN 0.57 7.64 1.99661 4476 10164 12401. 5 NPHI MWD PU-S 5.79 59.71 21.7689 4456 10160 12387.5 First Reading For Entire File......... .3613 Last Reading For Entire File.......... .12481 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/05/13 Maximum Physical Record..65535 File Type.......... ... ...LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number. ......... .1.0.0 Date of Generation...... .04/05/13 Maximum Physical Record..65535 File Type........... .... .LO Previous File Name... ... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 2 header data for each bit run in separate files. 1 .5000 FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPD FET RPM ROP $ e START DEPTH 3603.0 3860.0 3860.0 3860.0 3860.0 3860.0 3881.0 STOP DEPTH 4039.0 4031.0 4031.0 4031.0 4031.0 4031.0 4071.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.................. ....-999 e 22-APR-04 Insite 66.37 Memory 4071.0 3881.0 4071.0 42.9 44.5 TOOL NUMBER 149205 136749 8.500 3881.0 LSND 9.80 40.0 9.1 6000 4.8 .400 .340 .480 .800 70.0 82.4 70.0 70.0 Depth Units............. _....... e Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3603 4071 3837 937 3603 4071 ROP MWD010 FT/H 0.61 270.66 111.804 381 3881 4071 GR MWD010 API 32.79 106 58.0921 873 3603 4039 RPX MWD010 OHMM 0.42 1874.3 19.8411 343 3860 4031 RPS MWD010 OHMM 0.64 2000 39.7143 343 3860 4031 RPM MWD010 OHMM 0.37 2000 36.4624 343 3860 4031 RPD MWD010 OHMM 0.11 2000 77.3573 343 3860 4031 FET MWD010 HOUR 0.21 4.89 1.66528 343 3860 4031 First Reading For Entire File.. ....... .3603 Last Reading For Entire File.......... .4071 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ......04/05/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/13 Maximum Physical Record..65535 File Type............ ... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET 3 header data for each bit run in separate files. 2 .5000 START DEPTH 4031.5 4031.5 4031.5 4031.5 4031.5 STOP DEPTH 10124.0 10124.0 10124.0 10124.0 10124.0 GR ROP $ 4039._ 4071.5 10129.5 10164.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value................. ... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Units FT FT/H API e 27-APR-04 Insite 66.37 Memory 10164.0 4071.0 10164.0 11.7 46.9 TOOL NUMBER 149205 136749 8.500 3881.0 LSND 10.20 47.0 9.2 2100 3.5 1.300 .730 1. 700 3.000 70.0 129.2 70.0 70.0 Offset o 4 8 Channel 1 2 3 RPX MWD020 OHMM - 1 68 12 4 e RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4031.5 10164 7097.75 12266 4031.5 10164 ROP MWD020 FT/H 1.26 388.78 175.995 12186 4071.5 10164 GR MWD020 API 7.99 433.29 99.493 12181 4039.5 10129.5 RPX MWD020 OHMM 0.35 45.79 3.32933 12186 4031.5 10124 RPS MWD020 OHMM 0.37 41.7 3.32104 12186 4031.5 10124 RPM MWD020 OHMM 0.36 34.33 3.3277 12186 4031.5 10124 RPD MWD020 OHMM 0.39 729.43 3.51766 12186 4031.5 10124 FET MWD020 HOUR 0.14 27.04 0.76346 12186 4031.5 10124 First Reading For Entire File......... .4031.5 Last Reading For Entire File...... ... ..10164 File Trailer Service name. ........... .STSLIB.003 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .04/05/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .04/05/13 Maximum Physical Record. .65535 File Type.......... ......LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPM RPD GR NPHI FCNT NCNT RHOB PEF DRHO 4 header data for each bit run in separate files. 3 .5000 START DEPTH 10124.5 10124.5 10124.5 10124.5 10124.5 10130.0 10150.0 10150.0 10150.0 10154.0 10154.0 10154.0 STOP DEPTH 10607.5 10607.5 10607.5 10607.5 10607.5 10600.5 10565.5 10565.5 10565.5 10579.5 10579.5 10579.5 ROP $ 10164._ 10653.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ..... ...... ..0 Data Specification Block Type.....O Logging Direction... ... ... ...... ..Down Optical log depth units....... ... .Feet Data Reference Point... .......... . Undefined Frame Spacing................. ....60 .1IN Max frames per record............ . Undefined Absent value........ ............ ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD030 e 01-MAY-04 Insite 66.37 Memory 10653.0 10164.0 10653.0 9.2 36.6 TOOL NUMBER 151107 112032 113413 148579 6.125 10164.0 Flo-pro 8.40 49.0 9.5 3000 7.8 .850 .380 1.100 1. 200 67.0 156.2 67.0 67.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 GR MWD030 API - 1 68 8 3 e RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10124.5 10653 10388.8 1058 10124.5 10653 ROP MWD030 FT/H 0.65 195.9 44.2215 978 10164.5 10653 GR MWD030 API 16.29 548.3 63.6984 942 10130 10600.5 RPX MWD030 OHMM 1.14 1510.34 111. 342 967 10124.5 10607.5 RPS MWD030 OHMM 1.5 1808.52 169.682 967 10124.5 10607.5 RPM MWD030 OHMM 0.77 2000 323.522 967 10124.5 10607.5 RPD MWD030 OHMM 1. 73 2000 495.188 967 10124.5 10607.5 FET MWD030 HOUR 0.79 80.33 8.63758 967 10124.5 10607.5 NPHI MWD030 PU-S 5.79 59.71 17.006 832 10150 10565.5 FCNT MWD030 CNTS 101. 2 2686.1 1093.27 832 10150 10565.5 NCNT MWD030 CNTS 12510.4 48045.7 31587.5 832 10150 10565.5 RHOB MWD030 G/CM 1.792 2.899 2.2824 852 10154 10579.5 DRHO MWD030 G/CM -0.06 0.596 0.0776643 852 10154 10579.5 PEF MWD030 BARN 0.57 7.64 1.73128 852 10154 10579.5 First Reading For Entire File... ...... .10124.5 Last Reading For Entire File.......... .10653 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation.... ...04/05/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name........ .... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/05/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 5 header data for each bit run in separate files. 4 .5000 VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ START ItTH 10566.0 10566.0 10566.0 10580.0 10580.0 10580.0 10601.0 10608.0 10608.0 10608.0 10608.0 10608.0 10653.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 12377.5 12378.0 12377.5 12391. 5 12391.5 12391.5 12412.5 12419.5 12419.5 12419.5 12419.5 12419.5 12471.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ............0 e 03-MAY-04 Insite 66.37 Memory 12471.0 10653.0 12471.0 41. 9 95.6 TOOL NUMBER 151107 112032 113413 148579 6.125 10164.0 FIo-pro 8.50 49.0 9.5 1900 6.0 .850 .420 1.100 1. 200 67.0 143.0 67.0 67.0 Data Specification Block4lÞPe.....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 e Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 MWD040 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10566 12471 11518.5 3811 10566 12471 ROP MWD040 FT/H 0.16 302.77 120.698 3636 10653.5 12471 GR MWD040 API 13.89 177.51 55.6381 3624 10601 12412.5 RPX MWD040 OHMM 3.61 2000 334.968 3624 10608 12419.5 RPS MWD040 OHMM 3.52 2000 173.538 3624 10608 12419.5 RPM MWD040 OHMM 3.47 2000 162.386 3624 10608 12419.5 RPD MWD040 OHMM 3.99 2000 217.937 3624 10608 12419.5 FET MWD040 HOUR 0.23 17.3 1.34089 3624 10608 12419.5 NPHI MWD040 PU-S 11.7 47.3 22.8624 3624 10566 12377.5 FCNT MWD040 CNTS 221 1244.7 682.754 3625 10566 12378 NCNT MWD040 CNTS 16074.8 37932.3 29818.8 3624 10566 12377.5 RHOB MWD040 G/CM 2.083 3.181 2.34708 3624 10580 12391.5 DRHO MWD040 G/CM -0.234 0.682 0.0755331 3624 10580 12391. 5 PEF MWD040 BARN 0.58 5.63 2.05899 3624 10580 12391.5 First Reading For Entire File......... .10566 Last Reading For Entire File.......... .12471 File Trailer Service name..... ....... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .04/05/13 Maximum Physical Record. .65535 File Type............... . LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/05/13 Origin.................. .STS Tape Name............... . UNKNOWN Continuation Number... ..4It 4IÞ Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/05/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name... ....... .UNKNOWN Comments.......... .... ...STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
