Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
204-146
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. J. a Lb - L LJ. (p Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 111111111111111I11I R~CAN "-- ~olor Items: o Greyscale Items: DIGITAL DATA ~kettes No.~ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date 111/6 lOb o Other:: BY: ~ 151 MP Date III/ò/ Db 1111111111111111111 Project Proofing BY: ~ 151 Mf Scanning Preparation J.. + = TOTAL PAGES~ r (Count does not include cover sheet) \AA, 151 ( V f BY: Production Scanning 11111111111I111111I Stage 1 Page Count from Scanned File: (() J (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ¿ YES NO I^/lr BY: ~ Date: l/ /13/0 to 151 Y 'V Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: 151 11111111I11I11 "III Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 11I11111111I1111111 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA • ° ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 12/23/2010 204 - 146 310 - 375 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 8/24/2004 50 029 - 20653 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 8/30/2004 PBU 15 -11 B 1999' SNL, 3829' WEL, SEC. 22, T11 N, R14E, UM 8. KB (ft above MSL): 57 15. Field / Pool(s): Top of Productive Horizon: 4759' SNL, 402' EWL, SEC. 23, T11 N, R14E, UM GL (ft above MSL): 29.14' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 3995' SNL, 1191' WEL, SEC. 22, T11N, R14E, UM 10763' 8545' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 677402 y- 5959518 Zone ASP4 12968' 8836' ADL 028306 & 028307 TPI: x 681703 y - 5956858 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 680091 y - 5957584 Zone ASP4 N/A 18. Directional Survey: 0 Yes -i No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- DrilVLateral Top Window MD/TVD: DIR / GR / RES, DIR / GR / RES / NEU / ABI 9620' 7769' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H -40 Surface 112' Surface 112' 32" 300 sx Permafrost 13 -3/8" 72# L -80 Surface 2474' Surface 2474' 17 -1/2" 2400 sx Fondu. 400 sx PF 'C' 9 -5/8" 47# L -80 / S00 Surface 9620' Surface 7769' 12 -1/4" 250 sx Class 'G'. 300 sx PF 'C' 7" 26# L -80 9445' 10385' 7664' 8232' 8 -1/2" 211 sx Class 'G' 4 -1/2" 12.6# L -80 10208' 12968' 8125' 8836' 6 -1/8" 339 sx Class 'G' 24. Open to production or injection? ❑ Yes No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom Perforation Size and Number): 4 -1/2 ", 12.6#, 13Cr80 10213' 10155' / 8094' MD TVD MD TVD 26. ` ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 201) 10763' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RECEIVE* RBDMS FEB 2 4 20 FEB 411 Form 10-407 Revised 12/2009 CONTINUED ON RE SE. .v;‘, * - 1 %. °�' 1 ' ' ° �''' "` • ` ' ` Original Only 74' 3'8'// �� " l� Anchorage • 29• GEOLOGIC MARKERS (List all formations and markers encountered): 30. OMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 10391' 8236' None Shublik A 10456' 8279' Shublik B 10487' 8302' Shublik C 10505' 8316' Sadlerochit 10545' 8350' Top CGL 10722' 8508' Base CGL / Top Zone 2B 10800' 8579' 23SB 10870' 8643' 22TS 10930' 8694' 21TS 11000' 8748' Zone 1B 11069' 8792' PGOC 11085' 8801' TDF / Zone 1A 11194' 8847' Base Sadlerochit 11440' 8866' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foreg��iss true and correct to the best of my knowledge. „ / Signed: Terris Hubble ! M,(,C l(L. Title: Drilling Technologist Date: 0 , t PBU 15 - B 204 - 146 310 - 375 Prepared By Name/Number: Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Cody Rymut, 564 -5452 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • 15 -11 B, Well History (Pre Rig Sidetrack) Date Summary 12/10/2010 WELL S/I ON ARRIVAL. DRIFT TO 10,415' SLM W/ 3.70" x 20' DUMMY WHIPSTOCK (Stopped due to dogleg, target = 11,000'). DRIFT TO 10,415' SLM W/ 3.625" x 19' BKR WHIPSTOCK (Stopped due to dogleg, target = 11,000'). DRIFT TO 11,000' SLM W/ 3.70" CENT, 1.75" S -BLR (No problems). WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 12/15/2010 Objective: Drift to 11,000' w/ dummy whipstock. MU BOT Jars w/ 3.7" X 19.25' dummy W/S drift. Perform well kill down backside. Very tight, limited injection. RIH w/ drift to 11000'. (Did not see any restrictions). Open well to tanks, returns were all fluid (no gas) WHP dropped to 100 psi instantly. Pooh pumping pipe displacement w/ diesel. (38 bbls total diesel) Job complete. 12/19/2010 T /I /O= Vac/0 /0 Verified barriers, attached lubricator/ BPV to tree, pressure tested lubricator: Low - 300 psi / Pass High: 3500 psi / Pass. Set 5 -1/8" FMC IS -A BPV# 538 thru tree, 1 -18" ext. used...tag @ 96 ", removed lubricator, changed from setting to pulling tool, reattached lubricator, pressure tested Low / High - Pass. With valves open torqued all studs on tree to specs (see log) pulled BPV. Attached lubricator /FMC - TTP on tree, pressure tested lubricator: Low - 300 psi / Pass High - 3500 psi / Pass, with same equipment set 5 -1/8" FMC - TTP # 527 at same depth, removed lubricator changed from setting tool to pulling tool and reattached lubricator on tree, pressure tested lubricator Low / High - Pass. Attempted to shell test tree both low and high to no avail. Pulled TTP, removed lubricator, reinstalled new setting tool and FMC - TTP #528 repressure tested lubricator / Pass. Set FMC - TTP, removed lubicator changed tools, re- pressure tested lubricator. Shell tested tree to 300 psi / Pass - 3500 psi / Pass - 5000 psi / Pass. Pulled FMC tree test plug. Pressure tested tree cap to 500 psi / Pass. 12/20/2010 T /I /O= vac/100 /0 +. SI. Bleed IA, OA to 0 psi (CTD prep). IA, OA have integral's. Bled IAP to 0 psi in 15 mins with 0.5 bbls returned. SI bleed, monitor for 30 mins. No change in IAP. Job complete. Final W H Ps= vac/0 /0+ Page 1 of 1 • • North America - ALASKA BP 'age1«16 Operation Summary Report Common Well Name: 15 -11 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/20/2010 End Date: 1/3/2011 X3- 00Y02 -C (1,729,151.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 j Spud Date/Time: 9/13/1981 12:00:OOAM Rig Release: 1/17/2011 Rig Contractor: NORDIC CALISTA UWI: 500292065300 Active Datum: 19 : 11 9/13/1981 00:00 @71.00ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr)— — _I, (ft� 12/20/2010 22:00 - 00:00 2.00 MOB P PRE CONTINUED FROM 15 -21A CON REPORT DATED 12/20/2010. PJSM AFTER BACKING OFF WELL 15 -21A FOR MOVE TO WELL 15 -11C. MOBILISE RIG TO WELL 15 -11C. 12/21/2010 00:00 - 04:00 4.00 MOB N WAI PRE CONTINUED FROM WELL 15 -21A CON REPORT DATED 12/20/2010. SPOTTED RIG ON LOCATION IN PREPARATION TO BACK OVER WELL. SET DOWN AND WAIT FOR BPV CREW TO FINISH OIL NORDIC 1. WHILE WAITING FOR BPV CREW CLEAN OUT HP FILTERS, GREASE' CHOKE MANIFOLD, AND PERFORM OTHER GENERAL RIG MAINTENANCE. 01:15 - BPV CREW ON LOCATION. R/U TO SET BPV IN WELL 15-11B SO RIG CAN BACK OVER. 04:00 - BPV SET AND CREW LEAVING LOCATION_ 04 :00 - 04:30 0.50 _ - j MOB P PRE PLACE T -MATS AND BERM AROUND CELLAR (___'_ AND PREP TO BACK RIG OVER WELL 04:30 - 05:30 1.00 ;MOB N WAIT I PRE WAIT TO BACK RIG OVER WELL UNTIL NORDIC FIELD SUPT. IS DONE ASSISTING 1• NORDIC 1. PJSM, SET HERCULITE & RIG — — MATS 05:30 - 07:00 1.50 MOB P PRE PJSM. PULL RIG OVER WELL 07:00 - 07:30 0.50 MOB P PRE INSTALL HANDI -BERM, CREW C /O, LEVEL RIG. — — 07:30 - 11:00 3.50 MOB P PRE NU BOP STACK 11:00 - 17:30 6.50 BOPSUR , P , PRE PRESSURE TEST BOP'S AS PER AOGCC REGS & PROGRAM, and PERMIT TO DRILL. TEST WITNESS WAIVED BY J. JONES, AOGCC. DATA TRANSMITTED TO AOGCC BY EMAIL. 17:30 - 18:30 1.00 RIGU P PRE PJSM FOR PT INNER REEL VALVE AND PACK -OFF. - P/U INJECTOR AND STAB ON WELL. - PT INNER REEL VALVE AND PACK -OFF TO 250/3500 PSI. CHARTED - GOOD. - BLOW COIL BACK W/ AIR. 118 :30 - 20:00 1.50 RIGU P PRE PJSM FOR CUTTING COIL. - POP OFF INJECTOR AND PREP FLOOR FOR CUTTING COIL. - BEGIN CUTTING COIL. * BPV CREW ARRIVED ON LOCATION AT — — 19:45. Printed 2/23/2011 11:37:27AM Qrth America ALASKA , BP Page 2 Qf 16 Operation Summary Report Common Well Name: 15 -11 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/20/2010 End Date: 1/3/2011 X3- 00Y02 -C (1,729,151.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 I Spud Date/Time: 9/13/1981 12:00:OOAM Rig Release: 1/17/2011 Rig Contractor: NORDIC CALISTA UWI: 500292065300 Active Datum: 19:11 9/13/1981 00:00 @71.00ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 RIGU P WEXIT PJSM W/ BPV CREW. - P/U TOOLS AND LUBRICATOR. USE DSM LOADER W/ STINGER TO BRING LUBRICATOR UP BEAVER SLIDE. - R/U LUBRICATOR AND PT TO 250/3500 PSI. - PULL BPV AND UD LUBRICATOR. OFF -LOAD SAME. -- I - - - - -- -- — - -- — -- - - - - -- - - - - - -- — - - -- --------------- - - - -- 12/22/2010 00:00 - 01:30 1.50 RIGU P WEXIT P/U INJECTOR. PUMP SLACK FORWARD TO ' FIND E- LINE. TESTAND ROOT E -LINE. - BLOW BACK COIL. DRESS COIL AND HEAD UP CTC. PULL TEST CTC. TO 40K 01:30 - 02:30 1.00 RIGU P WEXIT RE -HEAD BAKER AND TEST E -LINE. PT DFCV'S TQ 250/3500PSI - WILL NOT HOLD AT LOW PSI. * BQT ARRIVED ON LOCATION AT 02:30. 02 :30 - 04:00 1.50 RIGU N SFAL WEXIT INSTALL NEW CHECK VALVES AND RE -TEST. AT LOW PRESSURE STILL LEAKS OFF. BREAK APART AND PULL CHECK VALVES AND TROUBLESHOOT. )NSERT NEW CHECK VALVES AND REPLACE O- RINGS. STILL BLEEDS OFF AT LOW PRESSURE. DECIDE TO MOVE ON TO KILLING WELL WHILE BHI TROUBLESHOOTS ISSUE. 04:00 - 04:30 0.50 RIGU P WEXIT STAND BACK INJ. AND CLEAR FLOOR IN PREP FOR BULLHEAD KILL. INSTALL TREE CAP. 04:30 - 04:45 0.25 RIGU P WEXIT PJSM FOR BULLHEAD KILLING WELL. - LINE UP AND OPEN UP TO THE WELL. WELL IS ONAVAC. - PUMP 5 BBL McOH SPEAR FOLLOWED BY KCL. - AT 20 BBLS AWAY AT 1.6 BPM HAVE 1900 PSI WHP. 04:45 - CALL ODE AND WTL AND VERIFY A NOZZLE RUN TO KILL WELL FROM BOTTOM IS ACCEPTABLE. — .RE MOVE UQC AND RE -HEAD INJECTOR. RE 06:30 0.50 RIGU P SFAL WEXIT P/U INJECTOR ( BAKER IN PREP TO PT CHECKS. 06:00 - I WEXIT CREW CHANGE. DISCUSS OPERATIONE. MAKE RIG ROUNDS AND CHECKS. CONTINUE TO PREP BHA FOR NOZZLE RUN. 06:30 - 10:30 J 4.00 KILLW P l WEXIT HOLD PJSM. DISCUSS KILL OPERATION. GET ON WELL. TAKING FLUID. RIH . CIRC DOWN COIL. 3400 PSI AT 2.65 BPM IN. NOT ENOUGH TO KILL WELL. REDUCE RATE AND RIH. PARK COIL AT 11100'. 10:30 - 12:00 1.50 KILLW P WEXIT BULL HEAD 15 BBLS KCL. 3050 PSI AT 0.65 BPM. DISPLACE WELL WITH KCL. TAKE RTNS THROUGH CHOKE, OUTSIDE. HOLD 250 -300 PSI WHP. CIRC AT 2.55 BPM AT 1900 PSI. PUMP 150 BBLS. ANN VOL IS 108 BBLS. BLEED OFF WHP. FLOW CHECK WELL. NO FLOW. Printed 2/23/2011 11:37:27AM W orth America - ALASKA - BP Page 3, of 16 Operation Summary Report Common Well Name: 15 -11 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/20/2010 End Date: 1/3/2011 X3- 00Y02 -C (1,729,151.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 9/13/1981 12:00:OOAM Rig Release: 1/17/2011 Rig Contractor: NORDIC CALISTA UWI: 500292065300 Active Datum: 19:11 9/13/1981 00:00 @71.00ft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 12:00 - 15:00 I 3.00 KILLW P WEXIT CIRCULATE OUT OF HOLE. 290 PSI AT 1.0 BBL IN. MAINTAIN KILL SHEET. 15:00 - 15:30 0.50 KILLW P 1 WEXIT AT SURFACE. GET OFF WELL. UNSTAB COIL. LD NOZZLE BHA. 15:30 - 16:00 0.50 STWHIP 1 P WEXIT MU BTT WHIPSTOCK ASSY ON INTEQ BHA. STAB COIL. TEST TOOLS. LOW VOLTAGE FOUND. 16:00 - 19:30 3.50 STWHIP N SFAL WEXIT GET OFF WELL. TROUBLE SHOOT TOOLS AND LINE., BREAK OFF UQC SLEEVE AND ELINE HAD PULLED OUT OF ANCHOR. r j PUMP SLACK AND CUT COIL. E RE HEAD BAKER, PT UQC AND CHECKS_ 19:30 - 22:00 2.50 ! STWHIP N SFAL WEXIT PJSM FOR P /U BTT WHIPSTOCK BHA. STAB COIL. TEST TOOLS -GOOD. 22 :00 - 23:00 1.00 STWHIP P i WEXIT , START, TRIP SHEET AND RIH W/ BTT WHIPSTOCK ASSY THRU OPEN EDC. RIH AT 65 FPM AT 1.4 BPM AND 680 PSI. - -_ SLOW DOWN RUNNING THRU JEWELRY. 23:00 - 00:00 1.00 STWHIP P WEXIT LOQ TIE -IN STARTING AT 10,080 FT TO 10,200 MAKE -16.5 FT CORRECTION. LOSING — 5 BBUHR. 12/23/2010 - STWHIP P WEXIT 00 :00 - 01 :15 1.25 STWHIP P WEXIT CONTINUED FROM RON REPORT DATED 12/22/2010. CONTINUE RIH TO 10,360 FT. NOTHING SEEN GOING PAST XN NIPPLE AT 10200 FT. LOG TIE -IN AND MAKE -29 FT CORRECTION. 01:15 - 01:45 0.50 STWHIP P WEXIT CONTINUE IN HOLE TO SETTING DEPTH. BOTTOM OF WHIPSTOCK AT 10778 FT. ip /5 j CLOSE EDC. PRESSURE UP AND OBSERVE V SHEAR AT 1100 PSI. T•- • t . - • • T20 DEG LEFT OF LS. 01:45 - 02:00 0.25 STWHIP P WEXIT SET 4K DOWN ON PACKER TO VERIFY SET. PICK UP CLEAN AT 36K UP WT. PUH ABOVE — !---- _ —__ -- _ -_— — __ -- _--- _ -__ -- WHIPSTOCK AND PARK COIL. 02:00 - 04:30 2.50 STWHIP P ! WEXIT OPEN EDC AND SWAP WELL OVER TO GEOVIS. 04:30 04:30 06 :00 1.50 STWHIP P WEXIT START TRIP SHEET AND POOH W/ WHIPSTOCK SETTING BHA. 06:00 - 06:30 0.50 STWHIP P 1 WEXIT CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG CHECKS AND ROUNDS. CONTINUE TO POOH WITH SETTING BHA. HOLD BHA PJSM. 06:30 - 07:30 1.00 STWHIP P WEXIT AT SURFACE. GET OFF WELL. UNSTAB COIL. LD BTT TOOLS. II I Printed 2/23/2011 11:37:27AM orth America - ALASKA BP Page 4 of 16 Operation Summary Report Common Well Name: 15 -11 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/20/2010 I End Date: 1/3/2011 X3- 00Y02 -C (1,729,151.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 9/13/1981 12:00:OOAM Rig Release: 1/17/2011 Rig Contractor: NORDIC CALISTA UWI: 500292065300 Active Datum: 19 : 11 9/13/1981 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 0915 1.75 STWHIP P WEXIT PJSM TO PRESS TEST PACKER AND LINER LAP. TEST 4 -1/2" TBG X BTf PACKER TO 250 PSI FOR 5 MIN. NO LOSS. PT 4 -1/2" TBG TO 2366 PSI. W/ 8.6 PPG GEOVIS FLUID. 0810,: 2366 PSI 0818 :2347 0823 ',2340 0E134 : 2329. 0840, : 2321 TEST CHARTED ON PAPER AND DIGITALLY ON NORDIC SYSTEM. TEST PASSED. 09:15 - 10:45 1.50 STWHIP P WEXIT PJSM TO DI$CU §S- HANDLING BHA. Mt) 3. ' MILL / STRU REAMER ON INTEQ JTS P116 STAB COIL. TEST TOOLS. GET ON WELL. 10:45 - 13 :30 2.75 STWHIP P WEXIT RUN IN HOLE. : 1N7ECTOR,SURGING. INSPECT AND CHECK QUT SAME. NTF. CONTINUE IN HOLE. 13:30 - 15:45 2.25 STWHIP P ' WEXIT TAQ XN NIPPLE AT 10,223'. " p) AND GET FS: 2325 PSI AT 2.52 BPM IN/OUT. TIME MILL AHEAD VERY SLOWLY. 15:45 - 17:30 1.75 STWHIP P f WEXIT GAS ALARM SOUNDED WHILE MILLING. CLOSE HCR. SIWHP: 220 PSI. PVT: 348 BBLS HOLD PJSM. RU TO TAKE RTNS TO TIGER TANK. CIRC AT 1450 PSI AT 1.0 BPM (SLOW CIRC RATE). TAKE RTNS TO TIGER. BLEED OFF WHP TO 85 PSI. CONTINUE TO CIRC TO TIGER. RTN DENSITY AND RATE SLOWLY RETURNING TO NOMINAL. (8.6 PPG) RETURNS BACK INSIDE. CONTINUE TO CIRCULATE. 17:30 - 18:00 0.50 STWHIP P 1 WEXIT PRESSURE TEST TBG TO 2400 PSI. HELD SOLID. 18:00 - 18:45 0.75 1 STWHIP P WEXIT CREW CHANGE OUT. MAKE RIG ROUNDS AND CHECKS. DISCUSS CURRENT OPS. DRIFT THRU XN NIPPLE. SEE SLIGHT MW f COMING UP THRU ON FIRST PASS. DRIFT BACK DOWN AND UP CLEAN BOTH WAYS. RIH TO MILL WINDOW. 18:45 19:15 0.50 STWHIP P WEXIT LOG TIE -IN AND MAKE -45' CORRECTION. 19:15 - 21:30 2.25 STWHIP P r WEXIT CONTINUE RIH TO BEGIN TIME MILLING WINDOW. TAG WHIPSTOCK AT 10763.6'. P/U CLEAN. 2380 PSI FS AT 2.54 BPM. TAG AT 10763.2' W/ PUMPS ON. S L j INITIATE TIME MILLING AT 1 F f /HR TO STA tT v-kN-"Sr PATTERN. �S•IIG 150 -250 PSI MW. 1 -2K# WOB. i I MILL TO 10764.9'•- -- Printed 2/23/2011 11:37:27AM TREE = FMC • WELLHEAD = FMC SAFETY NO: WELL ANGLE> 70° @ 11076'. C . UATOR= AXELSON 15-11C ° "4 -1/2" CHROME TBG * ** ORIG WELL, 15-11A & KB. 15 - 11 B NOT SHOWN. BF. ELEV = 28.5 ) ) KOP = 28017 25' H5-1/2" /2" X 4-1/2" XO, 1) = 3.958" I Max Angle = 97° @ 11571' Datum WO = NIA Datum 1 VO = 8800' SS 1 I 2094' 1 HES X NIP, ID = 3.813" 1 113 -3/8" CSG, 72#, L -80, ID = 12.347" H 2474' 1-A , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3326 3306 18 MMG-M DOME RK 16 01/27/11 3 5501 5000 45 NIMG-M SO RK 20 01/27/11 2 7523 6372 44 MMGM DMY RK 0 09/03/04 Minimum ID = 2.380" @ 10219' 1 _9323 7591 54 MMG-M DMY RK 0 09/03/04 4-1/2" KB LTP i 1 9445' 119-5/8" X 7" BKR LNR TOP PKR I fl w /TIEBA SLV ID = 7 .040" 9463' H9 -5/8" X 7" LNR HNGR, D = 7.020" I 7" N1LLOUT WINDOW (16-118) 9620' - 9636' PERFORATION SUMMARY 10135' 1-14-1/2" HES X NP, ID = 3.813" 1 REF LOG: SLB MCNL ON 01/06/2011 ANGLE AT TOP PERF: 96° 11560' 1 10155' H7" X 4-1/2" BKR S3 PKR, D = 3.875" 1 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE = ■- 10179' 1 /2" HES X NP, ID = 3.813" 1 2" 6 11560 -11940 O Di /07/11 i 2" 6 12050 -12670 O 01/07/11 P 10200' 41/2" HES XN NP, D.= 3.80" 2" 6 12860 -12920 O 01/07/11 MI 12/23/10 10208' H7" X 4-1/2" BKR LTP & LNR HGR w /TEBACK SLV, 0= 4.30" 4-1/2" LNR, 12.6#, 13CR-80 VAM TOP, 10213' 1 10213' 41/2" WLEG, D = 3.958" 1 .0152 bpf, ID = 3.958" 10219' H4-1/2" KB LTP, D = 2.38" 1 '\ 10226' 3.70" BIT DEPLOYMENT SLV, ID = 3.00" 1 10228' H5" X 41/2" XO, D= 4.00" 1 II ' I 10248' 1-13-1/'2" OTIS X NP, D = 2.812" 1 7" LNR, 26#, L -80 BTC-M, -1 10385' I , 0383 bpf, ID = 6.276" 10435' H 3- 1/2" -3 /16" XO, D = 2.80" 1 1 3-1/2" LNR, 9.2#, L -80 STL, 10435' 1 -- - \ / .0087 bpf, D = 2.992" 4-1/2" MLLOUT WINDOW (15 -11C) 10763' - 10773' P Jct. I WHPSTOCK (12/23/10) H 10763' 41/2" LNR, 12.6 #, L -80 BTC-M, -10763' R 10899' H3 -3/16" X 2 -7/8" XO, D = 2.38" 1 .0152 bpf, D = 3.958" r '�- I U 13-3/16" LNR, 6.2#, L -80 TCN, .0076 bpt, ID = 2.80" H 10899' PBTD 12938' 12 -7/8" LNR, 6.16#, L -80 STL, .0058 bpf, ID = 2.441" H 12977' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/18/81 ORIGINAL COMPLETION 01/31/11 /JMD DRLG DRAFT CORRECTIONS WELL: 15 -11 C 10/25/87 RWO 02/13/11 JCM/AGR GLV C/O (01/27/11) PERMT No: ° 2101630 02/11/99 CTD SIDETRACK (15 -11A) 02/18/11 AK/JMD DRLG DRAFT CORRECTIONS API No: 50 -029- 20653 -03 09/05/04 N2E5 SIDETRACK (15 - 118) SEC 22, T11 N, R14E,1997 FNL & 1450' FWL 01/17/11 NORDIC2 CTD SIDETRACK (16 -11C) 01/17/11 SV DRLG HO CORRECTIONS BP Exploration (Alaska) RE: Nordic 2 shut -in on gas Page 1 of 1 • Maunder, Thomas E (DOA) From: Smart, John C [John.Smart@bp.com] Sent: Monday, December 27, 2010 10:30 AM To: McMullen, John C; AK, D &C Rig Nordic 2 Well Site Leader Cc: Sarber, Greg J; Regg, James B (DOA); Maunder, Thomas E (DOA); guy.schwartz @alask.gov; Miller, Kenneth C; Engel, Harry R; Goodrich, Gary T; Rossberg, R Steven Subject: RE: Nordic 2 shut -in on gas Thx John John John Smart Wells Team Leader RWO & CTD Operations r \ ! BP Alaska Drilling & Wells Cell# 1 -832- 693 -6493 E -Mail: smartjc@bp.com From: McMullen, John C Sent: Monday, December 27, 2010 10:28 AM To: AK, D &C Rig Nordic 2 Well Site Leader Cc: Smart, John C; Sarber, Greg J; Regg, James B (DOA); 'Maunder, Thomas E (DOA)'; guy.schwartz @alask.gov; Miller, Kenneth C; Engel, Harry R; Goodrich, Gary T Subject: Nordic 2 shut -in on gas Gary — Please follow -up with notification to the AOGCC on the details of Nordic 2 shutting in BOPE on well 15 -11 B to circulate -out residual gas (12/23/10). I just visited with Tom Maunder about the incident. While he agreed that we were not operating under the PTD ( #210 -163) because we had not yet started window milling or drilling operations, he said that the expectation is to notify the AOGCC as defined in the Drilling section 20 AAC 25.035 (e) (11). Jim/Tom /Guy — please "reply all" on anything I've misstated here or to provide further clarification. Thanks, John 529 -9129 2/18/2011 �P r � SEAN PARNELL, GOVERNOR �7 V ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSCRQATION C01101I ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen + NOV Engineering Team Leader BP Exploration (Alaska), Inc. (y PO Box 196612 O Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15 -11B Sundry Number: 310 -375 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 rovided in AS 31.05.080 within 20 days after written notice of this P Y decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received b 4:30 PM on the 23rd day following the date of this letter, or the Y Y g next working day if the 23rd day falls on a holiday or weekend. j Sinc , No m n ioner DATED this Jday of November, 2010. Encl. STATE OF ALASKA � ALASKIOL AND GAS CONSERVATION COMMISON APPLICATION FOR SUNDRY APPROVAL 1 2 2010 3 20 AAC 25.280 1 1. Type of Request: ❑ Abandon . ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved A age ❑ 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 -14 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20653 -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: —P BU 15 -1113- Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field/ Pool(s): ADL 028306 & 028307 1 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12968' - 8836', 1 12880' 8841'- 11150'/ 12349' None Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 1 153 520 Surface 2474' 13-3/8" 474' 474' 4930 2670 Intermediate 9620' 9 20' 7769' 6820 3330 Production Liner 940' 7" 9445'- 10385' 7663'-8232' 7240 5410 Liner 2760' 1 4 -1/2" 10208'- 12 8125' - 6' 1 8430 1 75 Perforation Depth MD (ft): Perforation Depth TVD (ff): Tubing Size: Tubing Grade: Tubing MD (ft): 11112'- 111� 1 8815'- 8826' 4-1/2",12.6# 13Cr80 10213' Packers and SSSV Type: 7" x 4 - 1/2" BKR S3 Packer Packers and SSSV 10155'/8094' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 20, 2010 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Cody R mut, 564 -5452 Printed Name j9juki Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564 -4711 Date// r Elizabeth Barker, 564 -4628 Commission Use Onl Conditions o pproval: NN tify Commission so that a representative may witness t..t_Q.f Sundry Number: ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: � 3Soo /0 A`"Z `JDO rH Subsequent Form Required: O — 0 C APPROVED BY Appr '( MMISSIONER THE COMMISSION Date Form i Submit In Duplicate RIGINAL % %a To: Alaska Oil & Gas Conservation Commission From: Cody Rymut p CTD Engineer Date: November 8, 2010 Re: 15 -11B Sundry Approval Sundry approval is requested for well 15 -11B. Well 15 -11B is a Rig Sidetrack that was completed in September 2004. The well came on producing at quality rates but quickly fell while the gas rate and GOR climbed to marginal within a few months. The trend of reduced oil production levels continued and in a later ASRC flow test, oil production levels were shown to be at an all time low and a large spike in gas production was revealed. A diesel - xylene perf wash using CT was performed in April 2006 to try and dissolve any alsphaltenes or paraffins that could have been hampering productivity; this treatment did not produce any significant benefits for this well. 15 -11B's very sudden and quick drop in oil rates gave rise to the possibility of plugging taking place within one of the major contributing perforation intervals. Therefore it was decided to re -perf a -30' Zone 1B section in the toe (to bypass damage) and adperf another 80' of Zone IA and 1B rock in the heel (to bring on extra flow). These re -perfs and adperfs were shot in July 2007. The post -perf rates were an increase from previous production rates but were not substantial enough to be considered successful. The well stayed fulltime until December 2007 when it hit MGOR again. A clay acid stimulation (with foam diverter) was pumped in June 2008. The acid job was of minimal benefit - it resulted in no significant oil increase even after swapping the header from HP to LP. In May 2009, a Gas Shut -off plug was set to isolate the bottom two intervals. The plug was successful in shutting off a substantial volume of gas initially, but the oil rate also dropped. In June 2010, a plug was set to shut off all existing perfs and 24' of heel perfs were added in Zone 1B. The resulting well test produced no fluid and a large volume of gas. This end -of -life wellwork effectively exhausts all intervention options and a sidetrack will be pursued. h v/'. 0 l/1,3�0 REASON FOR SIDETRACK: 15 -11B has high gas rates and does not cycle effectively, making it uncompetitive. The well has had EOL wellwork with very poor results. A -50 acre drainage area target was identified in Eastern DS -15 which can accommodate a 2300' horizontal Z2A well; 15 -11C will be utilized for this opportunity. The proposed plan for 15 -11B is to e -line set a whipstock at KOP. SLB/Nordic 2 Coiled Tubing Drilling rig will finishing it off by drilling sidetrack on or around December 7, 2010 The existing perforations will be isolated by the pa cker element associated with whipstock. The sidetrack, 15 -11C, will exit the existing 4 -1/2" casing and kick off into Zone 2, going through Zones 2Bu, 2B1, 2A, 1B, before finishing horizontal through Zone IA. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. Pre -Rig Work: (scheduled to beginlovember 20, 20 10) • 1. S Set dummy GLV's/ drift with dummy whipstock 2. W AC- PPPOT -IC, 3. E Set whipstock at KOP (10770' MD) PeLck CJ.,,pstZa 4. C Freeze protect the well and thoroughly wash the tree 5. D Bleed wellhead pressures down to zero. 6. D Bleed production flow lines and GL lines down to zero and blind flange 7. V Set TWC 24hr prior to rig arrival 8. O Remove wellhouse, level pad Rig Work: (scheduled to begin December 7, 2010) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 4 -1/2" HES XN NIP to 3.80 ". --' 3. Mill 3.8" window at 10770' and 10'of rathole in Zone 2. Swap the well to Geo -Vis. 4. Drill Lateral: 3.75" OH, 2300' (12 deg /100 planned) with resistivity. 5. Run 3 -1/2" x 3- 3/16" x 2 -7/8" tapered L -80 liner leaving TOL at 10,510'. 6. Pump primary cement leaving TOC at 10,510', 22 bbls of 15.8 ppg liner cmt planned. 7. Cleanout liner and MCNL /GR/CCL log. 8. Test liner lap to 2,400 psi. 9. Run and set KB liner top packer if necessary. 10. Perforate liner per asset instructions (-1300'). 11. Freeze protect well, set BPV, RDMO. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Generic GLV's. 3. ASRC flow back test. Cody Rymut CTD Engineer 564 -5452 CC: Well File Sondra Stewman / Liz Barker Tim. 6" 1540 WE Rue SJFFrYNOrES: t 1ALPAFMTWILL e1 ' ` 15-11 B ► cTac�»- >. - - 6a ry 1COP= - 2H8iI &%xAi := 94@ t#T2r st /2x D >ass8 GO1umTVD _ 8800 Ss 4. HM XN P D =32jr GAS Wr M4,N DWS ffi 3nr CSC, 725, L.80. D :12-W 2p4" MMMSV2 OE11 TYPE WLW LATCH PCRf DATE t8 ABrIGA4 044Y RK 0 1(MOt4'fD 4 8 1 4 DAFT RK 0 f011N5110 �tNJITI '" 10200" 44 A Aru DYY RK 0 090" 54 AR1Cr44 OW RK 0 0 4.112" HES XN NIPPLE 940 9,%,xr9mLNi2TOPRa w n*BAC KSLV, D :7A40" 9169' 9.58" X r LNRN84'.� D *7X20* MLLOW NM30 Y (t5.f1B) MiNMOM(0825 MW S8t0".9RT8' ME d.1rrNwxw,D= tj ME rX4.Vr8401S3WRD -3,RS" 9S8" NES6ZSV (082704) ��' 4 =117 Hl S X NP, D -3At3" VBG STUB (�22J[M) 9716` BA TW 1G�09' 4.1,2 - ESXNNBP;Dr3.723 TCPCF2.31B "CNKt 4 -74 D :1-44F • x d.trr BtO2LNFt TRH Rf6t TOP r 1N2 frMACKSLW, D =4 30" 3.117 mG, %X L.80, D : 2992" H 99-6' d- E2" YY 4D D : g95B" 93 B"CSG,478.L•80.D =wsr to fiOW rx4=.ur, CSFPdA (08115/(w) iBSOQ HNMR, D :4.30" 2-vrLK 47A L.BQ D: t_9f1' H lam - s D- &Or P ►TMsLM" Y 4.42TM t2X4 f3MS REP LOG: S NS MEMO Y CNUGRKrL CH aZXBM VAy. _Ot 521Qf, D= 3955 ANGLE AT TOP PEF F. or @ t .. t7 N da Blot b R^odidim D9 fcr Nisim a der F 281, L-80 9TC AR StZE SFF InMWAL Opueqz DATE .0383WjD -a27S 2.71B' 6 11112. it 13S © OBr18/D 2.78" 6 11158.11180 C 07X MW 4 tf 2 'csp1�wt� 14154' 2.78" 6 11226= 11240 c 07X0167 2.78" 4 11300 - 11440 C 0901104 I 385 M Cop (05raX9J MW 2.7AI" 4 11710= t2ttO C 0901104 2.78' 6 11886-11216 c 07XOW 2.78 4 t2180- 12480 c iKJOtt04 1psm mw 2.78" 4 t2530.12730 c 0WOU04 2.78" 4 12820- 12870 c 090VO4 4- t2'LNR12JK 6808TrA( At52b¢, 9) sS958" 2 -78" 6 12826 t2M C 07X6107 DATE REW BY CCA8yB475 P07lrZll REV BY OOAirHa41S PRLDN INf K7EBAY F /87N88f DIBdNAL.COMPLETION 06SRJC MWCPATCNS 07!00+07 Vl - t5 -119 R51B7 (BAND RR t8 EPCBPSET P8WNb:PA4t400 214 84188 GTD C( -ftA) JB KXUC MY (OOr1 nc) AA ND 88X5184 NM 8 K(15110 14.V C)( 5+10) SW22,Tttf4 R14F, %9rF L31450'FML fB11884 GJSRLH GLV {yp 02 71906 RCC7iLN1 EKGCPAFfCCFVU3- ONS E¢ pw( k *) TREE = FMC 15 11 C WE_LHEAU = FMC � SAFETY NOTES: ORIGINAL PARENT WELL NOT ACTLW TOR = AXELSON SHOW. — CHROME TBG "" W ELL ANGLE > 70' Ka. ELEV = 60,cy Proposed CTD Sidetrack 11 i 8 6'. BF. ELLV = 28.5 KOP = 2800` 1 Max ArOe = 94 0 "721' Datum NO = 1 Datum TVD = 8800' SS 2094' a - ^ �� FIES X NIP, IU = 3.813 GAS LIFT MANDRELS '3 318' CSG, 72#, L -80.= 91.347' 2474' ST MU TVD DEV TYPE VLV LATCHI FORT DATE 4 3326 &3 W 18 bMAG -M DOM FCC 16 09J18104 3 5501 5000 45 MMGM SO RK 20 OWI &04 2 7523 6372 44 MMG --M MY RK 0 09103/04 1 Minimum ID = 2.375" @ 10500' 1 9323 7591 54 MMG-M DMY RK 1 D OWOVO4 4 -1/2" BKR KB LTP 9445' 9 S 8' X7' BKR LNR TflP PKR w fT EBACK SL V, D = 7.040' 9463' ___ =• x 7' LNRtMVGR, ID= 7.0211' WtiM'S3.t�4) 9620' MILLOUT WINDOW 115 - 116) "20 - V 10135' 4- ttl' FES x NP, tD = 3.813' 10155' 1' x 4-'' BKR S3 PKR, ID = 3.875' 8' H ES �5� 9656 1 0179 ' 't' HES y _ 9 518' CSG, 4 79, L; 40,0 .88 9' 10240' 10200' a H� °_ : J 10208' 7' x 4- ','Z BKR LNR `t: lheACA SLV, ID= 4.4317' 4 -112" TBG, 12.6# 13 CRB 0 10213' ___ ___ ... ___ VAM, .0152traf, ID= 3.958' 10213' 4 - •12'tNLEG. 10 = 3.9118' 10222' LNRIiN(.�R, ID = 4.317' r LNR, 26#, L B% ^a 10385' 10228' .0383 DO, ID = 6.27b, r I 0 - ItRFORATION SUMMARY 35 10510 aeGL 10769' REF LOG: SWS MBAOR CNLtGR+CC L ON 02 106J99 10770' ANGLE AT TOP PEZF: 61' fp 1111 T Note: Refer b Procucton OB for sto Del cata SIZE SPF INTERVAL 24° 2 6 11112 - 11136 U X812& 10 11300' ". XO 2 -718' 6 11158 -11186 C 07106/07 2 -718' 6 11226 -11246 C 07106107 C 2 - 7A' 4 11300 - 11440 C 09101104 2 -718" 4 11710-12110 C 09/01/04 - - ;T °;0628110) 11150' 2 -TV 6 11896 -11216 C OP06107 - -__- 2 -718" 4 12180 -12480 C 09/01/04 F L -80 Lr . Ce ~ zC &Nrrd —13 2 -78' 4 12530 - 12730 C 09/01/04 2 -7,8' 4 12820 -12870 C OW01/04 2 -7.8 6 12826 - 12856 C 07106/07 B 4 -112' LNR 12.6#.. L-80 BTC-M, .0152 DGf, ID = 3.958" 12968' LIA T E REV B v S DA TE REV BY CObM.1ttJ' s rfdJOHOE BAY UNIT 1W1B181 ORIGINAL CUM PLETION 07,21/07 OMS "PJC r'ERFORATONS (07,06.07) WELL: 15 - 11C 10/25/87 RWO 06103,!09 RRLVTLH CIBP SET {0512 & Fl~ No: 02/11/99 CTDSIDETRACK {15 -11A) 0629110 KJ&IR1C C6rxT'ERFS (06 APINo: 50-??29- 24.''653-0 09105104 NZES SIDETRACK I' S 1 B) 10,07110 NEE PROPOSED CTD SEDErRACK 4. R14E ' - F'Y s "450 FV& 0941 &04 G.&T1 H GLV C:1U 1 02-I"A , 061 P=LH DRLG DRAFT CORRECT ONS I I BP Exploration (Alaska) NORDIC CTD UNIT # 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM - C Slantlpipe I 2 "CMcuktla Lirw _ TYPicaIBOP ram hgurat on -- — DrMer cwMM 22 IM 10 Note CIRCULATING MANIFOLD ` MM B M �- _ M Ol Choke g p l - shown. pOP schematic OP "a configura sL i well d B iran.duear . MM O - PVT Sensor specific Lm.. -BNw Choke... .. Awl' 11111115 -' - 11M21 AS PI1a] cR Rev CI Llna _ MM 12 MM14 ma Called Tubing __.._... __ .,.... ...._ ,.. _._ choke .. ..... _ Kip Line -..- Outlet 1111 r0orneentUnstoGround v Trmlduwra --- C67LED rUBIN1 -- - CIRCULATING SYSTEM CNkry . - — 7 Am._. _..._ ...., ._. .... _.:. .. ._.. ....... .. _...._.: - 11P 18 _... :. To Inns, Rod „. NP HP? HP2 HP 2 HP I Li __. ... cement line N2 SLB NORDICS 2 Ckwriam ManBt,ia __. CHOKE MANIFOLD m C.9.r _N2TdFlow fCMBO g�p - Gauge Teat Pump Inlet CM3 "W HDI Gauge . - i Flow g NC To PITS _ . 4WaY BI , - . 01111114 CM4 Sitar Choke - -line CM1T _ - __ Baker Choke Lhu loded CM12 -. CM? rclwlw Lae - _ - _ CM2 CM1X_9 u..w .. .. _ _. - CM ZS CM 29 _wir CM20 _ CM.90 -- CM24 CM 73 C11111 CM 25 CM 27 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS 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. Well Class Before Work: .Permit to Drill Number: Name: Development ~ Exploratory ^ 204-1460 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20653-02-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028306 ~ PBU 15-11 B 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12968 feet Plugs (measured) 11150 12349 feet true vertical 8836.32 feet Junk (measured) None feet Effective Depth measured 12881 feet Packer (measured) 10155 true vertical 8841.27 feet (true vertical) 8094 Casing Length Size MD ND Burst Collapse Structural Conductor 112 20" SURFACE - 110 SURFACE - 112 Surface 2474 13-3/8" 72# L-80 SURFACE - 2474 SURFACE - 2474 5380 2670 Intermediate Production 9620 9-5/8" 47# L-80 SURFACE - 9620 SURFACE - 7769 6870 4760 Liner 940 7"26# L-80 9445 - 10385 7664 - 8232 7240 5410 Liner 2760 4-1/2" 12.6# L-80 10208 - 12698 8125 - 8836 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR80 SURFACE - 10213 SURFACE - 8128 Packers and SSSV (type, measured and true vertical depth) 7"x4-1/2" bkr s-3 okr 94 80 10155 n aC ~/ C 4.~j1..~ Y 4.V JL1L 1 4 20~~+ 12. Stimulation or cement squeeze summary: ~ " " '~ ff~ ~~OrlN111S5tOn ~ C7$Z COlti ka Intervals treated (measured): ~y ~~ r. ~~ . r ~ t~: S ! ~ z -. ~-' a s~.~a..• ~~ ~ ~': ~'~~ r ~r"`~ . ue ., . . ,. a Rrreherage 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: Subsequent to operation: 361 25214 361 852 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ~ Phone 564-4944 Date 7/13/2010 15-11 B 204-146 o~Q~ eTrerNneGN-r r 1 U n U Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-116 9/1/04 PER 11,300. 11,440. 8,863.79 8,866.15 15-116 9/1/04 PER 11,710. 12,110. 8,859.15 8,850.6 15-11B 9/1/04 PER 12,180. 12,480. 8,848.72 8,849.39 15-11B 9/1/04 PER 12,530. 12,730. 8,849.94 8,848.85 15-11B 9/1/04 PER 12,820. 12,870. 8,844.53 8,841.88 15-11 B 7/5/07 APF 12,826. 12,856. 8,844.22 8,842.64 15-11B 7/6/07 APF 11,226. 11,246. 8,855.51 8,859.34 15-116 7/7/07 APF 11,156. 11,186. 8,833.81 8,844.52 15-11B 7/7/07 APF 11,186. 11,216. 8,844.52 8,853.18 15-11 B 5/27/09 BPS 12,495. 12,530. 8,849.55 8,849.94 15-11 B 5/28/09 BPS 12,349. 12,530. 8,848.46 8,849.94 15-11B 6/28/10 APF 11,112. 11,136. 8,814.76 8,825.69 15-116 6/28/10 BPS 11,150. 12,349. 8,831.47 8,848.46 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 • 15-11B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/27/2010 ***WELL SHUT IN ON ARRIVAL. MASTER SHUT I/O: 500/0 PSI.*** t BEGIN RIGGING UP FOR HES CIBP PLUG RUN. WAITING FOR TOWN ENGINEER TO DECIDE WHETHER OR NOT TO RUN GR/CCL OR IF CCL IS SUFFICIENT DUE TO TIE IN LOG NOT BEING ACROSS ANY JEWELRY. ***JOB CONTINUED ON 28-JUNE-2010.*** 6/27/2010'.***WELL S/I ON ARRIVAL***(profile mod) .DRIFT W/ 3.70" CENT, 3.00" S-BAILER TO DEV @ 11250' SLM ***WELL LEFT S/I, DSO NOTIFIED*** ***JOB CONTINUED FROM 27-JUNE-2010.*** SET CIBP AT 11150'. PERFORATED 11112'-11136' WITH 2.88" HSD 6SPF 60 DEG PHASED PJ2906. DEPTHS CORRECTED TO SLB MEMORY GR/CCL LOG DATED 6-JULY-07.' CONFIRMED ALL SHOTS FIRED. HAND OVER WITH DSO,. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 2 METH 2 DIESEL 4 Total TREE _ : 6" !; MC ACTUATOR = AXELSON KB. ELEV = 60.0' BF. ELEV = 28.5' KOP = 2800' Max Angie = 94 @ 11721' Datum MD = 11236' Datum TV D = 8800' SS ~ 13 3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 2474' Minimum ID = 3.725" @ 10200' 4-1/2" HES XN NIPPLE 15-11B SAFETY~ES: ORIgNAL PARENT WELL NOT SHOW. ***CHROMETBG**** WELLANGLE>70° 11186'. 25' I-i 5-1 /2" X 4-112" XO, ID = 3.958" 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3326 3306 18 MMG-M DOME RK 16 09/18/04 3 5501 5000 45 MMG-M SO RK 20 09118!04 2 7523 6372 44 MMG-M DMY RK 0 09(03104 1 9323 7591 54 MMG-M DMY RK 0 09/03/04 19-5/8" X 7" BKR LNR TOP PKR I w /TIEBACK SLV , ID = 7.040" 9-5/8" X 7" LNR HNGR, ID = 7.020" WHIPSTOCK {08/23/04) ;~~- ~ ~9-518" HES EZSV (08/22/04) I-j 9656' TBG STUB (as/22/o4) 9746' ELM TOP OF 2-3/8" LNR, 4.7#, ID = 1.941" 9881' TOP OF 7" LNR 9924' 3-1/2" TBG, 9.3#, L-80, ID = 2.992" 9976' 9 5/8" CSG, 47#, L-80, ID = 8.681" 10240' TOP OF P&A (08/15104 10500' 2-3/8" LNR, 4.7#, L-80, ID= 1.941" 12264' PERFORATION SUMMARY REF LOG: SWS MEMORY CNUGR/CCL ON 02/06/99 ANGLE AT TOP PERF: 61 ° @ 11112' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11112 - 11136 O 06/28/1 2-7/8" 6 11156 - 11186 C 07/06/07 2-7/8" 6 11226 - 11246 C 07/06/07 2-7/8" 4 11300- 11440 C 09/01/04 2-7/8" 4 11710 - 12110 C 09/01/04 2-7/$" 6 11886 - 11216 C 07/06/07 2-7/8" 4 12180 - 12480 C 09/01/04 2-718" 4 12530 - 12730 C 09/01/04 2-7/8" 4 12820 - 12870 C 09/01/04 2-718" 6 12826 - 12856 C 07/06107 MILLOIIT WINDOW (15-11B) 9620' - 9636' 10135' -14-1i2" HES X NIP, ID = 3.813" 10155' 7" X 4-1/2" BKR S3 PKR, ID = 3.875" 4-112" TBG, 12.6#, 13CR80 -j 10213' VAM, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 BTGM, 10385' .0383 bpf, ID = 6.276" / 4-1/2" CIBP(06/28/10)~~ 3.66" HES CIBP (05/28/0 1179' I-j 4-112" HES X NIP, ID = 3.813" I 10200' 4-1/2" HES XN NIP, ID = 3.725" 10208' 7" X 4-1/2" BKR LNR TOP PKR wlTIEBACK SLV, ID = 4.430" 10213 4-1/2" WLEG, ID = 3.958" 10222' 7" X 4-1/2" LNR HNGR, ID = 4.30" 10228' S" x a-112" xo, ID - 4.00" PBTD 12881' 4-1/2" LNR 12.6#, L-80 BTGM, .0152 bpf, ID = 3.958" 1296$' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/18/81 ORIGINAL COMPLETION 07121!07 DMSlPJC PERFORATIONS (07/06/07) 10125/87 RWO 06/03/09 RRD/TLH CIBP SET (05128/09) 02!11/99 CTD SIDETRACK (15-11A) 06/29/10 KJB/PJC CIBP! PERFS (06/28!10) 09/05/04 N2ES SIDETRACK (15-11B) 09/18/04 GJBlTLH GLV C/O 02/19106 RCC/TLH DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 15-11 B PERMIT No: 1041460 API No: 50-029-20653-02 SEC 22, T11 N, R14E, 1997' FNL & 1450' FWL BP 6cploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 bP Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~' ~~ 333 West 7t" Avenue ~~ ~-~" Anchorage, Alaska 99501 ~~, (~ Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 nata~ 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-016 2042570 50029206960200- NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-048 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 10/7/2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-268 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 15-298 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-336 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-426 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 156 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-488 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 C] ~.,-:~ V V~~~ T~4~4/1~~/,4L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 • RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka .~~ ~'v~. ~G~ t° f ~O ~S LR2-1 900 E. Benson Blvd. ~ ~~ - ~3 2 / (o ~5~ 2~ Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey -~.~ amt t;5,;~ ;~ ~0( 130 West International Airport ~.~ `~~ ~- Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Production Profile 02,Jun-08 15-11 B BL / EOE 2j Static Survey 21 Sep-08 Z-06 Signed Print Name: l' ~,,, fi-s-~} ,~ Q Y~~~~,~ Color / Et~E Date 50-029-20653-02 50-029-21798-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL: ~dS~3'3£i~S~?~'~C'~e~538~E'9";4>6"t~©~.Cis9'=~ WEBSITE:'P~N!P1.Id~g537a~~Y~s3Q.~C4'1j3 ~J C:\Documents and Settings\Owner\Desktop\Tiansttrit_BP.doc • a ~ ~ ~,, '_ / MICROFILMED 03/01 !2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Miicrofilm Marker.doc · STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS D D o ~ ¡J-ß-e?? 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic Exploratory Service 204-1460 6. API Number: 50-029-20653-02-00 ,..- 9. Well Name and Number: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 57.64 KB PBU 15-116- ADLO-028306 ' 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool C 8. Property Designation: Total Depth measured 12968 . feet Plugs (measured) true vertical 8836.32 feet Junk (measured) Effective Depth measured 12881 feet SCANNED JUL 1 B 2007 true vertical 8841.27 / feet Casing Length Size MD TVD Conductor 112' 20" Surface - 112' Surface - 112' Surface 2474' 13-3/8" 72# L-80 Surface - 2474' Surface - 2474' Production 9620' 9-5/8" 47# L-80 Surface - 9620' Surface - 7769' Liner 940' 7" 26# L-80 9445' 1 0385' 7664' - 8232' Liner 2760' 4-1/2" 12.6# L-80 10208' - 12968' 8125' - 8836' Perforation depth: Measured depth: 11186 - 12870 True Vertical depth: 8845 - 8842 - - Tubing: (size, grade, and measured depth) 13CR80 4-1/2" 12.6# Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S3 PKR o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: None None Burst Collapse 5380 2670 6870 4760 7240 5410 8430 7500 ;p. W en ~ Q) ::u Surface - 10213' S? L_ m Q:O C ø r' 0 10155' w ?-'. rn (I"j 0 C"':í t...:) -- r.::> < 0 ~ ',-...,) Cñ 0 c::J m C") c::::> t:;'> --...1 ;1. "" r/l õ' ::I Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 222 517 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 18040 0 0 17018 0 0 Tubing pressure 1221 1014 13. 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. x Contact Gary Preble R8DMS 8FL JUL 1 7 20D7 Title Data Management Engineer Signature Phone 564-4944 OR\G\NAL Service WINJ WDSPL Sundry Number or N/A if C.O. Exempt: N/A Date 7/11/2007 Is "\.h, "") ~ ,;pf't6)J-bmit Original Only . . IS-lIB DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/4/2007 CTU #5 ***Job Scope Drift & Log/Add Perfs**** Perform weekly BOPE test. ***Continue job on 7/5/2007*** 7/5/2007 CTU #5 ***Continue job from 7/4/2007*** InterAct not publishing. Perform weekly BOPE test. MU Weatherford 2.375" MHA and SWS memory tools in 2.2" carrier w/ 3" JSN. RIH and tag PBTD at 12,870' up wt. Paint flag at 12,820.1'. Log up to 10,000' at 60 fpm. POOH. Retrieved good data w. +12' correction RIH w. Gun #1 27/8" HSD-PJ2906 Omega, 6 spf, 60* phasing, Park and shoot holes @ 12826'· 12856' POOH ***Continue job on 7/6/2007*** 7/6/2007 CTU #5 ***Continue job from 7/5/2007*** InterAct not publishing. MU Weatherford 2.375" MHA and SWS memory tools in 2.2" carrier w/ 3" JSN. Log from 10,800' to 11,400'. +8' correction. MU MHA w/ 2.875" guns. Perforate from 11,226' to 11,246' ***Continue job on 7/7/2007*** 7/7/2007 #5 ***Continue job from 7/6/2007*** InterAct not publishing. RIH Gun #3 & #4 (2 7/8"HSD w/ Power Jet Omega, HMX 6 spf, 60* phasing). Add Perfs @ 11,186' - 11,216' and 11,156' - 11,186'. Freeze protect well with 50/50 meth. Notify pad operator of well status. RDMO. ***Job complete*** FLUIDS PUMPED BBLS 91 1 % KCL 31 50/50 METHANOL 122 TOTAL ~ b~ ~~~<:o DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041460 Well Name/No. PRUDHOE BAY UNIT 15-11B Operator BP EXPLORATION (ALASKA) INC 5f1~ AY~)..M.a.( API No. 50-029-20653-02-00 MD 12968 ------ TVD 8836- Completion Date 9/3/2004 r Completion Status 1-01L ~._-- REQUIRED INFORMATION Mud Log No Samples No -~.~- - -~ DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES, DJR / GR / RES / NEU / ASI Well Log Information: Logl Electr Data Digital Dataset Log Log Run IT:? Med/Frmt Number Name Scale Media No ~DASC Directional Survey pt Directional Survey I;f: D Asc Directional Survey I pt Directional Survey I,lD D Lis 13164 Induction/Resistivity I Rpt 13164 LIS Verification ~~ Lis 13711 Ind uction/Resistivity Well Cores/Samples Information: Interval Name Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? Y (ii) Daily History Received? ChipS Received? ',' I 14 Formation Tops Analysis Received? Y'1-N- ~~.~~--~- Comments: ~._~---~ ~ Compliance Reviewed By: Current Status 1-01L UIC N Directional Survey Yes ~- (data taken from Logs Portion of Master Well Data Maint Interval . OH/ Start Stop CH Received Comments 9586 12968 Open 1 0/7/2004 IIFR 9586 12968 Open 1 0/7/2004 IIFR 9586 12968 Open 10/7/2004 MWD 9586 12968 Open 10/7/2004 MWD 9435 12900 Open 6/10/2005 MWD/MPT/EWR4/ROP 9435 12900 Open 6/10/2005 MWD/MPT/EWR4/ROP 9620 12968 Open 2/22/2006 ROP DGR EWR SLD CTN J plus Graphics Sample Set Number Comments . 'G)N ~N ~,-~~~- Date: ~ 9 Jt,t-~ ~ . . ~ 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 131 t \ RE: MWD Fonnation Evaluation Logs 15-l1B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Speny Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 15-11B: LAS Data & Digital Log hnages: 50-029- 20653-02 ;;o'r/4L, 1 CD Rom Q{'~ !1190rOl~ a STATE OF ALASKA ALAS~ AND GAS CONSERVATION COMe ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RË C.ËfVEJJ OCT 0 iF 2004 A!¡¡dr:> rw 11 '" 1a. Well Status: a Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: .t'.j '...¡li!;;L, /,,,- ., 20AAC 25.105 20AAC 25.110 a DevelopmentA!f!1!/~atory .~" DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o SerVice 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/3/2004 204-146 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 8/24/2004 50- 029-20653-02-00 4a. Location of Well (Governmental Section): 7. Date TD. Reached 14. Well Name and Number: Surface: 8/30/2004 P8U 15-118 1999' SNL, 3829' WEL, SEC. 22, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 4759' SNL, 402' EWL, SEC. 23, T11N, R14E, UM 57.6' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ rvD) 3995' SNL, 1191' WEL, SEC. 22, T11N, R14E, UM 12880 + 8841 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+rvD) 16. Property Designation: Surface: x- 677402 y- 5959518 Zone- ASP4 12968 + 8836 Ft ADL 028306 . ,~- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 681703 y- 5956858 Zone- ASP4 -- (Nipple) 2094' MD Total Depth: x- 680091 y- 5957584 Zone- ASP4 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost aYes aNo NIA MSL 1900' (Approx.) 21. Logs Run: DIR I GR I RES, DIR I GR I RES I NEU 1 ABI 2. CASING, liNER AND CEMENTING RECORD CAsiNG . ::>J:JTINgPFPTHr.!D SETTI I G~ EPJHTVD HOl-E ......, ¡'P,ui::n. SIZE WT/PERFT. GRADE Top BO'TTOM lOP .·BOTTOM SIZE 20" 94# H-40 Surface 112' Surface 112' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2474' Surface 2474' 17-1/2" 2400 sx Fondu, 400 sx PF 'C' 9-5/8" 47# L-80 / SOO-95 Surface 9620' Surface 7769' 12-1/4" 250 sx Class 'G', 300 sx PF 'C' 7" 26# L-80 9445' 10385' 7664' 8232' 8-1/2" 211 sx Class 'G' 4-1/2" 12.6# L-BO 10208' 12968' 8125' 8836' 6-1/8" 339 sx Class 'G' 23. Perforations op'en to Production (MD + rvD of To,e and 24. 'T"......~ ... ......... i Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 10213' 10155' MD rvD MD rvD 11300' - 11440' 8864' - 8866' 25. . ACID, · C:>~. .~~_~ 11710' - 12110' 8859' - 8851' 12180' - 12480' 8849' - 8849' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12530' - 12730' 8850' - 8849' 12820' - 12870' 8845' - 8842' 2100' Freeze Protect with 146 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): September 19, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BsL GAs-McF WATER-BSl CHOKE SIZE I GAS-Oil RATIO 9/3012004 3.1 TEST PERIOD .. 140 455 2 85 3247 Flow Tubing Casing Pressure CALCULATED .. Oll-BsL GAs-MCF WATER-Bsl OIL GRAVITY-API (CORR) Press. 335 550 24-HoUR RATE 1085 3522 12 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SUbm.~~~,;oœ, sœte '~e", ",' '"1« , None 1'157 «(f mÐiMSJ OCT 1 l 2ÐfJ4 El ¡ L ûf I ,. , ...! , ¡ ,,~~ on Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS NAME MD rvD Sag River 10391' 8236' Shublik A 10456' 8279' Shublik B 10487' 8302' Shublik C 10505' 8316' Sadlerochit 10545' 8350' Top CGL 10722' 8508' Base CGL I Top Zone 28 10800' 8579' 23SB 10870' 8643' 22TS 10930' 8694' 21TS 11000' 8748' Zone 1 B 11069' 8792' PGOC 11085' 8801' TDF I Zone 1A 11194' 8847' Base Sadlerochit 11440' 8866' 29. RMATlON 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 rrn rç:p REvt:\ V ~y""J OC1 \)5 20(14 0·'& Mas"a h J\i1t\'Ofð\)e 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 ~ Title Technical Assistant Date .. OS-Dlf 204-146 Permit No. I A roval 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. PBU 15-118 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Phil Smith, 564-4897 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 4,283 (psi) 0.00 (ppg) - Printed: 9/7/2004 8:36:07 AM 685 (psi 8.40 (ppg) 8,245.0 (ft) ft 0,405.0 FIT 8/26/2004 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-11 15-11 B REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 8/1 9/2004 Rig Release: 9/4/2004 Rig Number: Spud Date: 9/13/1981 End: 9/3/2004 8/19/2004 06:00 - 09:00 3.00 MOB P PRE Rig down Floor, Bridle up Derrick, Lower Cattle Chute, Lay down derrick - Move sub off DS 07-06B 09:00 - 10:30 1.50 MOB P PRE Move Sub drill site 7 to drill site 15 - Sub rear wheels broke through #2 culvert over Put River on drill site 15 access road crushing top of #2 culvert - Rig sub stuck in road - Exception rig move began at 1030 hrs 8/19/2004 10:30 - 00:00 13.50 MOB N SFAL PRE Evaluation options, notify roads and pads - Mobilize plywood, Cherry picker, and Bob Cat - Shore up under #2 & #1 culverts with plywood, 3x12's & 2 x 6's - Brace up under #3 culvert with 10 x 10's 8/20/2004 00:00 - 09:30 9.50 MOB N SFAL PRE Continue shore up under culvert #2 with plywood, 3 x 12's & 2 x 6's - dump sand and gravel in hole under rig wheels, compact with rig wheels 09:30 - 10:00 0.50 MOB N SFAL PRE Back rig out of hole and back rig up to Oxbow / drill site 15 intersection 10:00 - 14:00 4.00 MOB N SFAL PRE Fill in hole above culvert #2 with gravel and compact - Clean up wood debris 14:00 - 00:00 10.00 MOB N SFAL PRE Lay mats three high over all culverts, Long way, side way, long way - Lay mats on road from culverts to oxbow road 8/21/2004 00:00 - 02:30 2.50 MOB N SFAL PRE Finish lay mats to oxbow road 02:30 - 03:30 1.00 MOB P PRE Move sub from oxbow road intersection to drill site 15 - no problem crossing Put River culverts 03:30 - 05:00 1.50 MOB P PRE Lay herculite & spot sub over DS 15 well 11 05:00 - 07:00 2.00 RIGU P PRE Raise derrick, Pin cattle shute, bridle down, rig up floor 07:00 - 11 :00 4.00 RIGU P PRE Spot mud pits, Camp & shop - Brem cutting tank, Rig up surface lines 11 :00 - 11 :30 0.50 KILL P DECOMP Pre-Spud meeting with rig personnel - Exception rig move over, began regular serive on DS 15-11 Bat 1100 hrs 8/21/2004 11 :30 - 12:30 1.00 WHSUR P DECOMP Rig up drill site maintenance Lubricator, Pull 5" FMC ' ISA' Bpv - rig down lubricator - SITP 0, SICP 0 12:30 - 13:00 0.50 KILL P DECOMP Install double annulus valve on tubing head 13:00 - 15:30 2.50 KILL P DECOMP Test lines 3500 psi, Displace well to seawater - Pump 40 bbl soap pill ahead followed by seawater at 11 bpm 2180 psi - Monitor well - SITP 0, SICP 0 15:30 - 16:00 0.50 WHSUR P DECOMP Dry rod in Bpv, Test to 1000 psi from below 16:00 - 18:00 2.00 WHSUR P DECOMP Nipple down FMC 7 1/16 5k tree with 51/8" bore and 13518 x 7 1/16 5k adapter flange, 5 1/8" bore - Install Bpv planking plug, Inspect tubing hanger landing threads 18:00 - 19:30 1.50 BOPSU DECOMP Nipple 13 5/8 5K bop stack 19:30 - 00:00 4.50 BOPSU DECOMP Install 3 1/2" test jt, Test Choke manifold, top rams and blind rams to 250 low, 3500 high, Test hydrill to 250 low /2500 high, Test top drive & floor valve 250 /3500 psi - witness of test waived by Mr. Chuck Scheve of Aogcc 8/22/2004 00:00 - 00:30 0.50 BOPSU DECOMP Pull Bpv blanking plug 00:30 - 01 :30 1.00 BOPSU DECOMP Rig up drill site maintenance lubricator, Pull 5" FMC 'ISA' bpv, no pressure on well 01 :30 - 03:30 2.00 PULL P DECOMP Make up 5 3/4" RH Acme xo to jt of drill pipe, Screw into tubing hanger, Back out lock down screws and Control line nipples - Pull tubing free with 11 OK, Free pick up 100k - Pull tubing hanger to rig floor and lay down - Rig up Control line spooler and power tongs 03:30 - 13:30 10.00 PULL P DECOMP Lay down 3 1/2 9.3# Eue 8rd tubing, holes in some to tubing string - Lay down total 311 jts + cut il.- recovered all control line Printed: 9f712004 8:36:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-11 15-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/19/2004 Rig Release: 9/4/2004 Rig Number: Spud Date: 9/13/1981 End: 9/3/2004 bands Set test plug, Test top rams, Bottom rams, with 4" test jt to 250 low, 3500 high, Test hydrill 250/2500 - Pull test plug - Install wear bushing 15:00 - 18:00 3.00 DHB P DECOMP Rig up Schlumberger E-Line - RIH with 8.5 GR/JB/CCL to tubing stub at 9,748' ELM - Pooh, junk basket clean 18:00 - 21 :30 3.50 DHB P DECOMP Make up Halliburton 95/8 CIBP - RIH tag stub at 9,748' - Log up, Set BP at 9,656' ELM, 4' above casing collar - Pooh, Rig down Schlumberger 21 :30 - 22:00 0.50 DHB P DECOMP Test 9 5/8 casing to 3500 psi for 30 minutes on chart 22:00 - 00:00 2.00 STWHIP P WEXIT Make up Baker window milling BHA: 8" starter mill, 8" Lower mill, 8 1/2" upper mill, on jt of 5" Hwt drill pipe & MWD - Make up Baker whipstock slide, orient & program MWD 8/23/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT Finish pick up window milling Bha: 9 - 6 1/4" Drill collar, 21 - 5" Hwt drill pipe to 1,045' 01 :00 - 05:00 4.00 STWHIP P WEXIT RIH to 6,649' picking up 4" 15.7# HT-40 drill pipe. 05:00 - 06:30 1.50 STWHIP P WEXIT Cut and slip 112' of drilling line. Service top drive. 06:30 - 09:00 2.50 STWHIP P WEXIT RIH from 6,649' to 9,605' picking up 4" 15.7# HT-40 drill pipe. Install blower hose. 09:00 - 10:00 1.00 STWHIP P WEXIT Orient whipstock to 81 RHS. Tag EZSV @ 9,643'. Set anchor with 25K down. Shear lug with 40K down. TOW - 9,620'. 10:00 - 11 :00 1.00 STWHIP P WEXIT Pump high-vise sweep and displace the well over to 11.5 ppg LSND drilling fluid - 13 bpm, 2,600 psi. 11 :00 - 19:30 8.50 STWHIP P WEXIT Work string and shear off lug. Mill 8-1/2" window. TOW- 9,620', BOW - 9,636'. Drill 21' of new hole to 9,649'. PU- 185K, SO - 140K, ROT - 160K, 539 gpm, 2,800 psi. 19:30 - 20:30 1.00 STWHIP P WEXIT Sweep the hole and work pipe through the window - slick. Circulate bottoms up and pull into the window. Recovered 175# of metal. 20:30 - 21 :00 0.50 STWHIP P WEXIT Perform FIT to 12.5 ppg EMW with 11.5 ppg fluid and 405 psi surface pressure. Monitor well - okay. Slug the pipe and blow down the surface equipment. 21 :00 - 00:00 3.00 STWHIP P WEXIT POH with 4" DP from 9,649' to 1,021 '. 8/24/2004 00:00 - 02:00 2.00 STWHIP P WEXIT POH standing back HWDP from 1,021' to 372'. LD BHA from 372'. Clear and clean the floor. Upper string mill in gauge. 02:00 - 03:00 1.00 STWHIP P WEXIT Pull wear ring. Flush and function the BOPE. Install wear ring. 03:00 - 05:00 2.00 STWHIP P WEXIT MU 8.5" Drilling BHA - 8.5" Smith M75 RR, 7" SperryDrill 7/8 - 6 stage motor, non-mag float sub, 6.75" GR/RES, 6.75" DM HOC, 6.75" TM HOC, 3 x non-mag flex collar, 6 x HWDP, Drilling Jar, 15 x HWDP, XO to 844'. PU single joint of 4" DP and shallow test the MWD tools. 05:00 - 08:00 3.00 STWHIP P WEXIT PU 4" DP and RIH with 8.5" Drilling BHA to 4,950'. 08:00 - 10:00 2.00 STWHIP P WEXIT RIH w/4" DP from the derrick to 9,524'. Install blower hose. 10:00 - 10:30 0.50 STWHIP P WEXIT Break circulation and orient BHA to 81 RHS. 10:30 - 22:00 11.50 DRILL P INT1 RIH from 9,524' to 9,642'. Ream undergauge hole from 9,642' to 9,649'. Directional drill from 9,649' to 10,347'. PU - 185K, SO - 135K, ROT - 160K, TO off - 8K, TO on - 10K, AST - 2.78, ART - 5.53. 22:00 - 23:00 1.00 DRILL P INT1 Circulate bottoms up for samples - 540 gpm, 3,650 psi. 23:00 - 00:00 1.00 DRILL P INT1 Directional drill from 10,347' to 10,366'. PU - 185K, SO - 135K, ROT - 160K, TO off - 8K, TO on - 10K, ART - 0.29. 8/25/2004 00:00 - 00:30 0.50 DRILL P INT1 Directional drill from 10,366' to 10,385' (TD). ART - 0.17 00:30 - 01 :30 1.00 DRILL P INT1 Circulate High-visc sweep and sample to verify TD - 13 bpm, Printed: 9f1/2004 8:36: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 5-11 15-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 9/13/1981 End: 9/3/2004 8/19/2004 9/4/2004 8/25/2004 00:30 - 01 :30 1.00 DRILL P INT1 01 :30 - 02:30 1.00 DRILL P INT1 02:30 - 04:00 1.50 DRILL P INT1 04:00 - 04:30 0.50 DRILL P INT1 04:30 - 06:00 1.50 DRILL P INT1 06:00 - 07:00 1.00 DRILL P INT1 07:00 - 10:00 3.00 DRILL P INT1 10:00 - 12:30 2.50 DRILL P INT1 12:30 - 13:30 1.00 CASE P LNR1 13:30 - 15:00 1.50 CASE P LNR1 15:00 - 15:30 15:30 - 19:30 19:30 - 20:00 20:00 - 20:30 0.50 CASE P 4.00 CASE P 0.50 CASE P 0.50 CASE P LNR1 LNR1 LNR1 LNR1 20:30-21:15 0.75 CEMT P LNR1 21:15 - 22:30 1.25 CEMT P LNR1 3,630 psi. Monitor well - stable. Short trip from 10,385' to above the window and MAD pass 9,670' to 9,450' @ 350'/hr. PU - 210K. Cut and slip 71' of drilling line. Service the top drive. Inspect and adjust the brakes. RIH from 9,450' to 10,385'. Precautionary wash and ream last stand down - no fill. Pump high visc sweep and circulate bottoms up. Spot liner running pill. Drop 2-3/8" rabbit. POH from 10,385' to 9,524'. Hole in good condition. Pump dry job and remove blower hose. POH from 9,524' to 843'. Changeout handling equipment. LD BHA from 843'. Flush MWD and motor with fresh water. Download MWD. LD Motor and Bit. Clear and clean the floor. RU 7" handling equipment. PU float equipment and check floats. Bakerloc all float equipment connections. PU 915' of 7" 26# L80 BTC-m liner and RIH. TQ - 8000 ftlbs. MU Baker HMC Hanger/SLZXP Packer assembly. Changeout handling equipment. RIH with liner on a single stand of 4" DP to 1,062'. Circulate one liner volume - 3 bpm, 160 psi. RIH w/4" DP from 1,062' to 9,620' filling pipe every 10 stands. Circulate DP and liner volume - 6 bpm, 980 psi. RIH w/4" DP from 9,620' to 10,368'. MU rotating cement head and circulation lines. Tag bottom @ 10,385'. Liner Tieback - 9,445' SLZXP Liner Top Packer - 9,452' Liner Hanger - 9,463' Landing Collar - 10,299' Float Collar - 10,340' Float Shoe - 10,383' Stage pumps up to 7 bpm, 1,780 psi. Hold PJSM while circulating hole. Good returns. Swap valves and line up to Schlumberger. Pump 3 bbls water ahead through "T" to flush lines. Pressure test lines to 4,500 psi. Mix 15 bbls of 12.5 ppg Mudpush /I on the fly. 3 bpm, initial pressure - 960 psi, final pressure - 880 psi. Mix 43.5 bbls of 15.8 ppg Glass G + adds on the fly. 5.4 bpm, initial pressure 1900 psi, final pressure - 1780 psi. Shut down to drop dart and wash lines through "T" to clear any cement behind. Swap over to the rig to displace. Displace with 126 bbls of 11.5 ppg used mud from the pits. Catch the cement @ 17 bbls pumped. Displacement rate - 6 bpm, initial pressure - 1030 psi. Drop rate to 3 bpm and pick up liner plug @ 93 bbls pumped. Bring rate back up to 6 bpm and continue displacement - 1420 psi. Drop rate to 3 bpm and bump the plug with 126 bbls pumped and 1120 psi. Walk the pressure up to 3900 psi and observe indication of the hanger setting. Set down 70k and bleed off pressure. Check floats - holding. Printed: 9/7/2004 8:36:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-11 15-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS2ES Start: 8/19/2004 Rig Release: 9/4/2004 Rig Number: Spud Date: 9/13/1981 End: 9/3/2004 8/25/2004 21:15 - 22:30 1.25 CEMT P LNR1 PU and rotate 20 turns to the right. Came back 2.5 turns to the left when torque was released. PU with hanger released. SO with 55K and observe good indication of packer setting. Repeat with 65k down. Rotate down twice to ensure set. No reciprocation during entire cement job. Circulated 5 bbls cement back. CIP - 2210 hrs. 22:30 - 23:30 1.00 CEMT P LNR1 Circulate bottoms up @ top of the liner - 9,445'. 12 bpm, 3,200 psi. Observed 5 bbls of cement returned to surface. 23:30 - 00:00 0.50 CEMT P LNR1 RD cement head and circulation lines. 8/26/2004 00:00 - 03:45 3.75 CASE P LNR1 POH w/4" DP from 9,445' to surface. LD Baker C2 running tool. Clear and clean floor. 03:45 - 06:30 2.75 DRILL P PROD1 PJSM. MU 6-118" Drilling BHA - 6-118" Smith XR20, 4-3/4" Sperry 7/8 - 2 stg w/ABI (1.83 bend w/kick pad), non-mag float sub, GR/Res, DM HOC, TM HOC, 3 x non-mag collars, circ sub, drilling jar, 5 x HWDP, xo. Orient BHA and upload MWD. Surface test MWD. Changeout handling equipment. 06:30 - 10:30 4.00 DRILL P PROD1 RIH from 363' to 10,073'. Install blower hose. Wash down to the top of the landing collar @ 10,297'. 10:30 - 11 :00 0.50 DRILL P PROD1 Pressure test the 9-518" x 7" to 3,500 psi and hold for 30 minutes - good test. 11 :00 - 13:30 2.50 DRILL P PROD1 Drill the insert landing collar @ 10,297' and float collar @ 10,340' down to the top of the float shoe @ 10,384'. Firm cement in the shoe tract. 13:30 - 16:00 2.50 DRILL P PROD1 Pump 75 bbls fresh water and 50 bbls spacer ahead and displace the well over to 8.4 ppg FloPro drilling fluid. 260 gpm - 1,350 psi. 16:00 - 16:30 0.50 DRILL P PROD1 Drill float shoe and 20' of new hole to 10,405'. Pull back into casing. 16:30 - 17:00 0.50 DRILL P PROD1 Perform FIT to 10 ppg EMW with 8.4 ppg fluid and 685 psi surface pressure @ 8,231' TVD. 17:00 - 00:00 7.00 DRILL P PROD1 Drill directionally from 10,405' to 10,541 '. AST - 4.99, ART - 0.86, PU - 170K, SO - 150K, ROT - 160K, TO on - 6K, TO off - 5K. 8/27/2004 00:00 - 13:30 13.50 DRILL P PROD1 Drill 6-1/8" directionally from 10,541' to 10,984'. ART - 2.57, AST - 6.86, PU - 190K, SO - 145K, ROT - 165K, TO on -7K, TO off - 6k 13:30 - 14:30 1.00 DRILL P PROD1 Pump high vise sweep and circulate bottoms up @ 260 gpm, 1,600 psi. 14:30 - 15:00 0.50 DRILL P PROD1 POH from 10,984' to 10,353'. 15:00 - 16:00 1.00 DRILL P PROD1 Open up the circ sub and circulate bottoms up - 13 bpm - 1,500 psi. Pump dry job and blow down surface equipment. 16:00 - 19:00 3.00 DRILL P PROD1 POH from 10,353' to 362'. 19:00 - 20:30 1.50 DRILL P PROD1 Change out handling equipment. POH w/BHA. Changeout bit and download MWD. Bit graded: 3/6/MT/SIE/4/BT/BHA 20:30 - 22:30 2.00 DRILL P PROD1 MU BHA #4 to 388'. Upload MWD and surface test. Load nuclear sources. BHA: 6-1/8" Hughes MX18, 4-3/4" Sperry 7/8 - 2 stg wlABI (1.83 bend wlkick pad), non-mag float sub, GR/Res, DM HOC, Neutron/Density,TM HOC, 3 x non-mag collars, circ sub, Printed: 9/7/2004 8:36:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-11 15-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 8/19/2004 9/4/2004 Spud Date: 9/13/1981 End: 9/3/2004 8/27/2004 20:30 - 22:30 2.00 DRILL P PROD1 drilling jar, 2 x HWDP, xo. 22:30 - 00:00 1.50 DRILL P PROD1 RIH with 4" DP from 388' to 3,654'. Fill Pipe. 8/28/2004 00:00 - 02:30 2.50 DRILL P PROD1 RIH with 4" DP from 3,654' to 10,984' with precautionary washing and reaming of the last 2 stands due to pulled bit being undergauge. Fill Pipe every 3,000'. 02:30 - 00:00 21.50 DRILL P PROD1 Drill 6-1/8" directionally from 10,984' to 11,687'. AST - 10.39, ART - 6.7, PU - 195K, SO - 140K, ROT - 160K, TO on - 8k, TO off - 7k, 2,230 psi @ 319 gpm. 8/29/2004 00:00 - 00:30 0.50 DRILL P PROD1 Pump high visc sweep and circulate bottoms up @ 260 gpm, 1,600 psi. 00:30 - 01:15 0.75 DRILL P PROD1 POH from 11,687' to 10,287'. PU - 195K w/25K max overpull from 11,420' to 11,360' 01:15-02:00 0.75 DRILL P PROD1 Drop dart and open up the circ sub. Circulate bottoms up @ 13 bpm, 1,500 psi. 02:00 - 03:30 1.50 DRILL P PROD1 Cut and slip 91' of drilling line. Service top drive and crown. 03:30 - 07:00 3.50 DRILL P PROD1 POH from 10,287' to 388'. 07:00 - 10:00 3.00 DRILL P PROD1 Handle BHA # 4. LD Nuclear sources, download MWD. Break out bit and LD 4-3/4" motor. PU 5" motor with 1.5 and RR FM2643 PDC bit. PU GR/Res, Upload MWD. RIH with SHA #5 to 363' and surface test. Hughes MX18 graded: 1/1/ER/AlO/IIWT/PR BHA#5: 6-1/8" RR FM2643, 5" 6/7 6 stg motor with ASI and 1.5 bend, non-mag float sub, GR/Res, DM HOC, TM HOC, 3 x non-mag drill collars, circ sub, 3 x HWDP, jar, 2 x HWDP, xo. 10:00 - 14:00 4.00 DRILL P PROD1 RIH from 363' to 11,687'. Fill pipe every 3,000'. 14:00 - 00:00 10.00 DRILL P PROD1 Drill directionally from 11,687' to 12,594'. AST - 1.94, ART- 3.91, PU - 185K, SO - 135K, ROT - 165K, TO on - 8k, TO off- 7k. 8/30/2004 00:00 - 05:30 5.50 DRILL P PROD1 Drill directionally from 12,594' to 12,968'(TD). PU - 185K, SO - 135K, ROT - 165K, TO on - 8k, TO off - 7k. 05:30 - 07:00 1.50 DRILL P PROD1 Pump sweep and circulate bottoms up - 325 gpm, 2,350 psi. 07:00 - 08:30 1.50 DRILL P PROD1 Short trip from 12,968' to 11,568' without problems. Run pipe back down to bottom without problems. 08:30 - 10:00 1.50 DRILL P PROD1 Pump sweep and circulate bottoms up - 325 gpm, 2,350 psi. Spot liner running pill. 10:00 -11:30 1.50 DRILL P PROD1 POH from 12,968' to 10,354'. 11 :30 - 12:30 1.00 DRILL P PROD1 Drop dart and open the circ sub. Circulate the hole clean. Pump dry job. Blow down surface equipment. 12:30 - 16:00 3.50 DRILL P PROD1 POH from 10,354' to 363'. Change out the handling equipment. 16:00 - 17:30 1.50 DRILL P PROD1 LD SHA from 363'. Download MWD, break bit, clear and clean the floor. Bit graded: 1/2ICT/GR/XII/ERlTD 17:30 - 18:30 1.00 CASE P RUNPRD RU 4-1/2" pipe handling equipment. Hold PJSM. 18:30 - 22:00 3.50 CASE P RUNPRD MU float equipment and check - holding. MU 4-1/2",12.6#, L-80, IBT-m liner to 2,734'. MU liner hanger/packer assembly and RIH on 1 stand of DP to 2,859' and circulate liner volume @ 6 bpm, 180 psi. 22:00 - 22:40 0.67 CASE P RUNPRD RIH with 4" DP from 2,859' to 3,761 '. Printed: 9/7/2004 8:36: 13 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-11 15-11 B REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 8/19/2004 Rig Release: 9/4/2004 Rig Number: Spud Date: 9/13/1981 End: 9/3/2004 8/30/2004 22:40 - 00:00 1.33 CASE N HMAN RUNPRD Started to fill pipe and noticed fluid in the pump room and on the ground. Stopped pumping. Placed TIW valve on the drill string and secured the well. Assembled crew to clean up -20 bbls spill of drilling fluid - reference IR#1032715. 8/31/2004 00:00 - 03:30 3.50 CASE P RUNPRD RIH with 4" DP from 3,761' to 10,329'. 03:30 - 04:00 0.50 CASE P RUNPRD Circulate 4" DP and 4-1/2" liner volume above the 7" liner shoe. 6 bpm, 560 psi. PU - 165K, SO - 135K 04:00 - 05:30 1.50 CASE P RUNPRD RIH with 4" DP into open hole from 10,329' to 12,947'. MU cement head on single joint and RIH. Tag bottom @ 12,968'. PU - 195K, SO - 135K. 05:30 - 06:30 1.00 CASE P RUNPRD Reciprocate and círculate the pipe. Stage up the pumps to 3 bpm, 650 psi. While reciprocating on the up stroke, weight dropped to 165K. We stopped the reciprocation and went back down and tagged up -6' above our bottom tag mark indicating both that the dogs are extended and the liner is on bottom. Circulated bottoms up. 06:30 - 12:00 5.50 CASE N DFAL RUNPRD Tripped out of hole with wet string. Laid down liner running tool w/ seal assembly. 12:00 - 13:00 1.00 CASE N DFAL RUNPRD Cleared floor. Made up PBR pack-off assembly 13:00 - 17:00 4.00 CASE N DFAL RUNPRD Tripped in hole to 10118'. 17:00 - 17:30 0.50 CASE N DFAL RUNPRD Broke circulation. Tagged line at 10207'. Engaged pack-off w/ 5000 Ibs down. Circulated at 3 BPM with 550 psi. 17:30 - 18:30 1.00 CEMT P RUNPRD Held PJSM with all personnel. Circulated while batch mixing cement. 18:30 - 20:00 1.50 CEMT P RUNPRD Pumped 5 BBLS of water. Pressure tested lines to 4500 psi. Pumped 15 BBLS of 8.34 ppg CW 100 spacer, 20 BBLS of 9.6 ppg mudpush spacerand 70 BBLS of 15.7 ppg class G cement with 0.3% D065, 0.11 % D800, 0.2 gal/sx D047 and 2.0 gal/sx water. Displaced cement with 65 BBLS of perforating pill and 143 bbls mud. Bumped plug with 3500 psi. Set hanger. Bleed off pressure. Floats held okay. CIP at 19:25. Set Liner hanger packer. 20:00 - 21 :00 1.00 CEMT P RUNPRD Pressured up to 1000 psi. Picked up and cleared seals. Circulated at 220 SPM while slowly reciprocating pipe. Recovered spacers. Did not see any cement. 21 :00 - 22:30 1.50 CEMT P RUNPRD Displace mud with with 950 BBLS of sea water. Initial displacement was 10 BPM. Lost swab on # 2 pump slowing displacement to 4 - 5 BPM. Dispalcement was not clean. 22:30 - 23:00 0.50 CEMT P RUNPRD Laid down cementing head. Broke out lines. 23:00 - 00:00 1.00 CEMT P RUNPRD Slipped and cut 87' of drilling line. 9/1/2004 00:00 - 00:30 0.50 CHEM P RUNPRD Serviced top drive 00:30 - 03:30 3.00 CHEM N FLUD RUNPRD Cleaned mud pits while waiting on additional sea water. Only two trucks available to haul. 03:30 - 04:30 1.00 CHEM P RUNPRD Circulated 475 BBLS of sea water at 12 BPM. Did not get clean returns. Shut down due to shortage of trucks. 04:30 - 06:30 2.00 CHEM N FLUD RUNPRD Wait on sea water due to shortage of trucks. 06:30 - 07:00 0.50 CHEM P RUNPRD Displaced well with an additional 300 BBLS of sea water. Had clean returns. 07:00 - 10:30 3.50 CHEM P RUNPRD Tripped out of hole. Laid down liner running tool. 10:30 - 11 :00 0.50 CASE P RUNPRD Tested casing and liner to 3500 psi for 30 minutes - okay. 11 :00 - 14:30 3.50 PERFO P OTHCMP Held pre-Job safety meeting with both crews. Rig up floor to run perforating guns. Pick up 1598' of 2 7/8" Perf guns & blanks. Printed: 9/7/2004 8:36: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-11 15-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/19/2004 Rig Release: 9/4/2004 Rig Number: Spud Date: 9/13/1981 End: 9/3/2004 9/3/2004 00:00 - 05:00 5.00 RUNCMP 05:00 - 06:00 1.00 RUNCMP 06:00 - 07:00 1.00 RUNCMP 07:00 - 11 :30 RUNCMP Pick up 1115' (36 jts) of 2 7/8" drill pipe. Tripped in hole with perforating assembly on 4" DP. Tag PBTD at 12880' DPM - Pick up 10', position bottom shot at 12870' dpm OTHCMP Broke circulation to fill DP and annulus. Closed Hydrill, Pressured annulus to 2900 psi and bled off pressure. Guns fired after 10 minutes. Perforated from 11300 - 11440, 11710 - 12110, 12180 - 12480, 12530 - 12730 and 12820 - 12870.' with 2 7/8 HSD Power Jet guns with 4 SPF at 60/120 phasing. Had good indication at surface of guns firing. Pulled out of hole to 11207'. Monitored well. Had no fluid losses. Pumped slug. Pulled out of hole to 7752', laying down DP. Tripped out to 2713', laying down 4" DP. Rigged up floor to lay down 2 7/8" PAC DP. Laid down 2 7/8" DP. Laid down 2 7/8" perforating guns. All shots fired. Cleared rig floor Tripped in hole with 4" DP in derrick and laid down same. Pulled wear bushing Rigged up power tongs, computer and compensator for 4 1/2" chrome completion Held PJSM for running chrome tubing. Made up 4 1/2" tail pipe assembly & Baker 7" x 4 1/2" S-3 permanent packer, thread lock all connection below packer. Run 41/2" 12.6# 13CR Vam Top tubing and gas lift mandrels to 6100'. Make up torque 4440 Nibs. Continued running 4 1/2" chrome completion. Ran a total of 243 joints of 41/2" 12.6# CR13 VAM TOP tubing Tagged top of liner at 10207' and spaced out with pup joints. Picked up FMC 13 5/8" X 5.5" Jigsaw tubing hanger and landed tubing. PU weightt - 135k. SO weightt - 11 OK. Ran in lock down screws and backed out landing joint. Rigged up and reverse circulated 155 bbls filter seawater followed by 342 bbls filter seawater with 25 gal/1 00 bbls of corrosion inhibitor. Displaced with 180 bbls of filter seawater down to top GLM at 3326' at 3 BPM w/150 psi. RUNCMP Dropped 1 7/8" ball on rod & let fall to RHC seat in 'XN' nipple. Pressured tubing to 3500 psi and set packer at 10155. Tested tubing to 3500 psi for 30 minutes - okay. Bled pressure to 1500 psi. Tested annulus to 3500 psi for 30 minutes -okay. Bled tubing pressure to 0 psi and sheared DCR valve, Bled down annulus. Set BPV in hanger. Tested from below to 1000 psi -okay. Removed BOPS. Installed adapter flange and tree. Test tubing hanger pack-off/ void area to 5000 psi - okay. Rigged up lubricator. Pulled BPV and installed test plug. Tested tree to 5000 psi - okay. Pulled test plug. Rigged up lines and hot oil truck. Tested lines to 3500 si. Freeze protected by pumping 146 bbls diesel down annulus taking returns up tubing. Let diesel U-tube until balanced for freeze protection to 2100.' RUNCMP Rigged down circulating hoses. Set back pressure valve and 20:00 - 20:30 20:30 - 21 :30 1.00 PERFO OTHCMP 21 :30 - 00:00 2.50 PERFO OTHCMP 9/2/2004 00:00 - 03:00 3.00 PERFO OTHCMP 03:00 - 03:30 0.50 PERFO OTHCMP 03:30 - 05:00 1.50 PERFO OTHCMP 05:00 - 10:30 5.50 PERFO OTHCMP 10:30 - 14:30 4.00 OTHCMP 14:30 - 15:00 0.50 RUNCMP 15:00 - 16:30 1.50 RUNCMP 16:30 - 17:00 0.50 RUNCMP 17:00 - 00:00 7.00 RUNCMP 11 :30 - 13:30 13:30 - 14:00 0.50 RUNCO RUNCMP 14:00 - 17:00 3.00 RUNCO RUNCMP 17:00 - 18:00 1.00 RUNCO RUNCMP 18:00 - 21 :00 3.00 RUNCO RUNCMP 21 :00 - 22:30 1.50 RUNCO Printed: 9/7/2004 8:36: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-11 15-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/19/2004 Rig Release: 9/4/2004 Rig Number: Spud Date: 9/13/1981 End: 9/3/2004 22:30 - 00:00 1.50 tested to 1000 psi. Rigged down hot oiler. Rigged down remaing circulating lines. RUNCMP Removed annular companion valve. Secured well. Installed pressure gauges. Disposed of remaining fluid in pits. Released rig at 00:00 hours. 9/4/04. Printed: 9/7/2004 8:36: 13 AM . AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 15-11 B 04-0ct-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,586.60' MD 9,620.00' MD 12,968.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.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 7 D j---).Ø-6 0 Signed 1LJ ð/L! Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ·~f::>1J-t c.-{6 Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 15 15-11 B . Job No. AKZZ3242526, Surveyed: 30 August, 2004 Survey Report 28 September, 2004 Your Ref: API 500292065302 Surface Coordinates: 5959518.33 N, 677402.09 E (70017' 41.6766" N, 148033' 48.5454" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 959518.33 N, 177402.09 E (Grid) Surface Coordinates relative to Structure Reference: 654.60 N, 1119.89 E (True) Kelly Bushing Elevation: 57. 60ft above Mean Sea Level Kelly Bushing Elevation: 57. 60ft above Project V Reference Kelly Bushing Elevation: 57. 60ft above Structure Reference spal'""'l'""'V-SUil! DFUL.L.ING seRVIceS A Halliburton Company Survey Ref: svy4390 Halliburton Sperry-Sun Survey Report for P8U_EOA os 15-15-118 Your Ref: API 500292065302 Job No. AKZZ3242526, Surveyed: 30 August, 2004 BPXA 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) 9586.60 52.520 122.960 7690.98 7748.58 2111.83 S 3968.13 E 5957500.74 N 681418.96 E 4440.02 Tie On Point MWD+IIFR+MS 9620.00 52.710 123.800 7711.26 7768.86 2126.43 S 3990.29 E 5957486.67 N 681441.46 E 2.078 4466.51 Window Point 9652.97 52.260 123.950 7731 .34 7788.94 2141.01 S 4012.00 E 5957472.61 N 681463.51 E 1.412 4492.62 9686.61 51.260 124.590 7752.16 7809.76 2155.88 S 4033.84 E 5957458.25 N 681485.69 E 3.327 4519.01 . 9717.88 51.180 125.520 7771.75 7829.35 2169.89 S 4053.79 E 5957444.73 N 681505.97 E 2.333 4543.37 9746.46 51 .520 126.180 7789.60 7847.20 2182.96 S 4071.88 E 5957432.09 N 681524.36 E 2.161 4565.69 9779.88 51.900 127.120 7810.31 7867.91 2198.62 S 4092.93 E 5957416.93 N 681545.77 E 2.483 4591.92 9840.02 53.060 128.880 7846.93 7904.53 2227.98 S 4130.51 E 5957388.46 N 681584.03 E 3.018 4639.61 9887.08 52.500 130.160 7875.40 7933.00 2251.83 S 4159.42 E 5957365.30 N 681613.50 E 2.471 4677.04 9932.76 52.130 131.410 7903.33 7960.93 2275.44 S 4186.79 E 5957342.34 N 681641.42 E 2.312 4713.11 9980.14 51.980 132.710 7932.46 7990.06 2300.47 S 4214.53 E 5957317.97 N 681669.74 E 2.187 4750.33 10026.06 53.140 133.950 7960.38 8017.98 2325.49 S 4241.05 E 5957293.58 N 681696.84 E 3.313 4786.57 10120.19 54.060 135.250 8016.24 8073.84 2378.69 S 4294.99 E 5957241.67 N 681752.02 E 1.480 4861.66 10213.38 53.890 136.200 8071.05 8128.65 2432.65 S 4347.60 E 5957188.97 N 681805.90 E 0.844 4936.16 10306.58 53.140 135.650 8126.46 8184.06 2486.49 S 4399.72 E 5957136.38 N 681859.27 E 0.934 5010.18 10327.10 53.010 135.220 8138.79 8196.39 2498.17 S 4411.24 E 5957124.97 N 681871.06 E 1.791 5026.41 10414.20 50.770 137.720 8192.55 8250.15 2547.84 S 4458.44 E 5957076.43 N 681919.43 E 3.422 5094.00 10445.97 44.950 140.190 8213.86 8271.46 2565.58 S 4473.92 E 5957059.06 N 681935.32 E 19.202 5117.04 10474.41 40.410 143.910 8234.76 8292.36 2580.75 S 4485.79 E 5957044.17 N 681947.54 E 18.255 5135.65 10509.06 35.590 148.980 8262.07 8319.67 2598.49 S 4497.61 E 5957026.72 N 681959.78 E 16.563 5155.76 10539.81 31.600 155.100 8287.68 8345.28 2613.47 S 4505.62 E 5957011.93 N 681968.14 E 17.005 5171.18 . 10567.42 29.790 161.430 8311.43 8369.03 2626.54 S 4510.85 E 5956998.99 N 681973.68 E 13.406 5183.22 10601.74 27.730 170.990 8341 .53 8399.13 2642.52 S 4514.82 E 5956983.11 N 681978.02 E 14.667 5196.00 10632.34 25.940 180.090 8368.85 8426.45 2656.25 S 4515.93 E 5956969.41 N 681979.45 E 14.627 5205.15 10660.64 25.070 188.450 8394.40 8452.00 2668.37 S 4515.03 E 5956957.27 N 681978.85 E 13.076 5211.73 10694.62 23.860 201.660 8425.35 8482.95 2681.89 S 4511.44 E 5956943.67 N 681975.57 E 16.456 5217.00 10725.56 24.300 206.720 8453.60 8511.20 2693.39 S 4506.26 E 5956932.04 N 681970.67 E 6.821 5219.79 10753.85 23.190 211.130 8479.50 8537.10 2703.36 S 4500.77 E 5956921.95 N 681965.41 E 7.400 5221.40 10787.59 23.510 212.090 8510.47 8568.07 2714.75 S 4493.76 E 5956910.40 N 681958.67 E 1.473 5222.65 10818.27 24.540 221.290 8538.50 8596.10 2724.73 S 4486.30 E 5956900.25 N 681951.45 E 12.649 5222.70 28 September, 2004 - 16:39 Page 2 of 5 OrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA OS 15 - 15-11B Your Ref: API 500292065302 Job No. AKZZ3242526, Surveyed: 30 August, 2004 BPXA 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) 10846.74 26.000 230.620 8564.26 8621.86 2733.13 S 4477.57 E 5956891.64 N 681942.92 E 14.883 5220.79 10880.67 29.610 238.920 8594.28 8651.88 2742.18 S 4464.63 E 5956882.28 N 681930.20 E 15.579 5215.90 10912.09 33.090 244.300 8621.11 8678.71 2749.91 S 4450.25 E 5956874.22 N 681916.01 E 14.205 5209.07 10939.59 35.460 249.470 8643.84 8701.44 2755.97 S 4436.01 E 5956867.83 N 681901.91 E 13.645 5201.34 . 10966.33 39.340 255.560 8665.09 8722.69 2760.81 S 4420.53 E 5956862.63 N 681886.55 E 20.033 5191.89 11000.22 44.370 259.590 8690.32 8747.92 2765.63 S 4398.45 E 5956857.28 N 681864.59 E 16.824 5177.16 11030.69 48.780 262.940 8711.27 8768.87 2768.97 S 4376.59 E 5956853.43 N 681842.81 E 16.526 5161.70 11058.88 54.450 264.980 8728.77 8786.37 2771.27 S 4354.62 E 5956850.61 N 681820.91 E 20.896 5145.55 11092.88 58.450 270.090 8747.56 8805.16 2772.46 S 4326.33 E 5956848.75 N 681792.65 E 17.179 5123.67 11122.99 62.790 273.070 8762.33 8819.93 2771.73 S 4300.12 E 5956848.87 N 681766.43 E 16.795 5102.29 11152.60 67.000 278.130 8774.90 8832.50 2769.09 S 4273.45 E 5956850.87 N 681739.71 E 21.010 5079.41 11185.92 70.770 281.410 8786.90 8844.50 2763.81 S 4242.83 E 5956855.43 N 681708.97 E 14.570 5051.78 11215.91 75.660 283.650 8795.56 8853.16 2757.57 S 4214.82 E 5956861.00 N 681680.82 E 17.803 5025.65 11245.32 80.510 285.520 8801.63 8859.23 2750.32 S 4186.98E 5956867.59 N 681652.82 E 17.625 4999.06 11278.09 87.040 289.780 8805.19 8862.79 2740.45 S 4155.96E 5956876.73 N 681621.57 E 23.746 4968.34 11309.44 87.960 294.120 8806.55 8864.15 2728.74 S 4126.92E 5956887.75 N 681592.26 E 14.138 4938.10 11337.50 89.200 297.710 8807.25 8864.85 2716.49 S 4101.69 E 5956899.41 N 681566.76 E 13.532 4910.58 11431.88 89.320 301.350 8808.47 8866.07 2669.98 S 4019.59 E 5956943.97 N 681483.58 E 3.859 4817.02 11525.35 90.800 302.200 8808.37 8865.97 2620.76 S 3940.14 E 5956991.29 N 681402.98 E 1.826 4723.95 11619.02 91.980 300.110 8806.10 8863.70 2572.32 S 3860.01 E 5957037.83 N 681321.73 E 2.562 4630.80 11687.28 93.340 297.720 8802.93 8860.53 2539.35 S 3800.33 E 5957069.38 N 681261.29 E 4.025 4563.30 . 11721.15 93.700 292.060 8800.85 8858.45 2525.13 S 3769.67 E 5957082.88 N 681230.31 E 16.713 4530.25 11751.96 90.740 290.250 8799.66 8857.26 2514.02 S 3740.96 E 5957093.30 N 681201.35 E 11.258 4500.64 11779.64 89.140 288.690 8799.68 8857.28 2504.79 S 3714.87 E 5957101.91 N 681175.04 E 8.073 4474.25 11813.47 88.770 287.920 8800.30 8857.90 2494.17 S 3682.76 E 5957111.77 N 681142.69 E 2.525 4442.21 11845.36 89.140 286.720 8800.88 8858.48 2484.68 S 3652.32 E 5957120.55 N 681112.03 E 3.937 4412.19 11873.02 91.970 290.840 8800.62 8858.22 2475.78 S 3626.14 E 5957128.83 N 681085.65 E 18.069 4385.92 11907.40 91.850 293.310 8799.47 8857.07 2462.87 S 3594.30 E 5957140.98 N 681053.52 E 7.189 4352.73 11938.92 91.980 293.050 8798.42 8856.02 2450.47 S 3565.34 E 5957152.70 N 681024.27 E 0.922 4322.14 11966.49 91.420 292.950 8797.60 8855.20 2439.70 S 3539.97 E 5957162.86 N 680998.66 E 2.063 4295.40 12016.36 91.730 293.830 8796.23 8853.83 2419.91 S 3494.22 E 5957181.57 N 680952.45 E 1.870 4246.95 12061.36 92.160 294.420 8794.70 8852.30 2401.53 S 3453.17 E 5957198.98 N 680910.98 E 1.622 4203.10 12107.98 91.850 294.750 8793.07 8850.67 2382.14 S 3410.81 E 5957217.35 N 680868.17 E 0.971 4157.60 12154.66 91.540 294.480 8791.69 8849.29 2362.71 S 3368.39 E 5957235.78 N 680825.30 E 0.881 4112.03 12212.30 90.250 295.380 8790.79 8848.39 2338.42 S 3316.13 E 5957258.83 N 680772.48 E 2.729 4055.67 28 September, 2004 - 16:39 Page 3 of 5 OrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-11B Your Ref: API 500292065302 Job No. AKZZ3242526, Surveyed: 30 August, 2004 BPXA 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) 12247.60 90.060 295.640 8790.69 8848.29 2323.21 S 3284.27 E 5957273.28 N 680740.28 E 0.912 4021.08 12297.77 89.880 295.460 8790.72 8848.32 2301.57 S 3239.00 E 5957293.84 N 680694.51 E 0.507 3971.91 12340.44 89.810 295.690 8790.83 8848.43 2283.15 S 3200.52 E 5957311 .35 N 680655.60 E 0.563 3930.08 12390.68 89.690 296.260 8791.05 8848.65 2261.15 S 3155.35 E 5957332.28 N 680609.93 E 1.159 3880.77 12434.24 89.510 296.580 8791.36 8848.96 2241.77 S 3116.34 E 5957350.74 N 680570.47 E 0.843 3837.95 . 12482.28 89.380 296.980 8791.82 8849.42 2220.12 S 3073.46 E 5957371.36 N 680527.09 E 0.875 3790.68 12574.46 89.320 297.270 8792.87 8850.47 2178.10 S 2991.42 E 5957411.44 N 680444.08 E 0.321 3699.87 12620.61 89.200 297.730 8793.46 8851.06 2156.79 S 2950.49 E 5957431.78 N 680402.66 E 1.030 3654.35 12668.13 91.050 297.650 8793.36 8850.96 2134.71 S 2908.41 E 5957452.86 N 680360.08 E 3.897 3607.46 12714.51 92.470 297.710 8791.94 8849.54 2113.18 S 2867.36 E 5957473.42 N 680318.53 E 3.064 3561.72 12807.53 92.900 297.210 8787.58 8845.18 2070.33 S 2784.91 E 5957514.31 N 680235.09 E 0.709 3470.08 12901.37 93.270 296.990 8782.53 8840.13 2027.64 S 2701.50 E 5957555.01 N 680150.69 E 0.459 3377.78 12968.00 93.270 296.990 8778.73 8836.33 1997.45 S 2642.22 E 5957583.79 N 680090.72 E 0.000 3312.27 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 127.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12968.00tl., The Bottom Hole Displacement is 3312.27fl., in the Direction of 127.088° (True). . 28 September, 2004 - 16:39 Page 4 of 5 Dri/lQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for P8U_EOA OS 15 - 15-118 Your Ref: API 500292065302 Job No. AKZZ3242526, Surveyed: 30 August, 2004 BPXA North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9586.60 9620.00 12968.00 7748.58 7768.86 8836.33 2111.83 S 2126.43 S 1997.45 S 3968.13 E 3990.29 E 2642.22 E Tie On Point Window Point Projected Survey . Survey tool program for 15-11 B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9586.60 0.00 9586.60 7748.58 12968.00 7748.58 AK-1 BP _HG - GYD-CT-DMS (15-11) 8836.33 MWD+IIFR+MS (15-118) . 28 September, 2004 - 16:39 Page 5 of 5 OrillQuest 3.03.06.006 . . AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-11 B MWD 04-0ct-04 Dear Deaf Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,586.60' MD 9,620.00' MD 12,968.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.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 /J I II / / I Date 7 61~~ signed~ ~~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~/Åð\J(~! t/0' Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 15 15-11B (mwd) . Job No. AKMW3242526, Surveyed: 30 August, 2004 Survey Report 28 September, 2004 Your Ref: API 500292065302 Surface Coordinates: 5959518.33 N, 677402.09 E (70017' 41.6766" N, 148033'48.5454" W) Grid Coordinate System: NA027 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 959518.33 N, 177402.09 E (Grid) Surface Coordinates relative to Structure Reference: 654.60 N, 1119.89 E (True) Kelly Bushing Elevation: 57.60ft above Mean Sea Level Kelly Bushing Elevation: 57. 60ft above Project V Reference Kelly Bushing Elevation: 57. 60ft above Structure Reference SpE!í'í'Y-SU:ï! DAIL.L.ING seAVIc:es A Halliburton Company Survey Ref: svy4391 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-11B (mwd) Your Ref: API 500292065302 Job No. AKMW3242526, Surveyed: 30 August, 2004 BPXA 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) 9586.60 52.520 122.960 7690.98 7748.58 2111.83 S 3968.13 E 5957500.74 N 681418.96 E 4440.02 Tie On Point MWD Magnetic 9620.00 52.710 123.800 7711.26 7768.86 2126.43 S 3990.29 E 5957486.67 N 681441.46 E 2.078 4466.51 Window Point 9652.97 52.260 123.950 7731.34 7788.94 2141.01 S 4012.00 E 5957472.61 N 681463.51 E 1.412 4492.62 . 9686.61 51 .260 124.590 7752.16 7809.76 2155.88 S 4033.84 E 5957458.25 N 681485.69 E 3.327 4519.01 9717.88 51.180 125.520 7771.75 7829.35 2169.89 S 4053.79 E 5957444.73 N 681505.97 E 2.333 4543.37 9746.46 51.520 126.180 7789.60 7847.20 2182.96 S 4071.88 E 5957432.09 N 681524.36 E 2.161 4565.69 9779.88 51.900 131.460 7810.31 7867.91 2199.39 S 4092.31 E 5957416.14 N 681545.17 E 12.451 4591.89 9840.02 53.060 135.670 7846.95 7904.55 2232.26 S 4126.85 E 5957384.09 N 681580.47 E 5.877 4639.26 9887.08 52.500 135.480 7875.42 7933.02 2259.03 S 4153.08 E 5957357.95 N 681607.33 E 1.233 4676.31 9932.76 52.130 131.490 7903.35 7960.95 2283.90 S 4179.30 E 5957333.71 N 681634.13 E 6.959 4712.22 9980.14 51.980 132.560 7932.48 7990.08 2308.91 S 4207.05 E 5957309.36 N 681662.46 E 1.809 4749.44 10026.06 53.140 133.820 7960.40 8018.00 2333.86 S 4233.63 E 5957285.04 N 681689.62 E 3.336 4785.68 10120.19 54.060 135.110 8016.26 8073.86 2386.94 S 4287.70 E 5957233.26 N 681744.93 E 1.474 4860.80 10213.38 53.890 136.020 8071.07 8128.67 2440.75 S 4340.46 E 5957180.70 N 681798.95 E 0.811 4935.33 10306.58 53.140 134.740 8126.49 8184.09 2494.09 S 4393.09 E 5957128.62 N 681852.82 E 1.366 5009.46 10327.10 53.010 134.540 8138.82 8196.42 2505.62 S 4404.76 E 5957117.37 N 681864.76 E 1.004 5025.72 10414.20 50.770 137.310 8192.57 8250.17 2554.82 S 4452.44 E 5957069.31 N 681913.59 E 3.588 5093.41 10445.97 44.950 139.820 8213.88 8271.48 2572.46 S 4468.04 E 5957052.04 N 681929.60 E 19.230 5116.48 10474.41 40.410 143.880 8234.79 8292.39 2587.59 S 4479.96 E 5957037.20 N 681941.88 E 18.661 5135.11 10509.06 35.590 149.080 8262.09 8319.69 2605.33 S 4491.77 E 5957019.74 N 681954.10 E 16.689 5155.21 10539.81 31. 600 155.220 8287.71 8345.31 2620.33 S 4499.75 E 5957004.93 N 681962.43 E 17.028 5170.62 . 10567.42 29.790 161.580 8311.46 8369.06 2633.41 S 4504.95 E 5956991.98 N 681967.94 E 13.455 5182.64 10601.74 27.730 171.170 8341.56 8399.16 2649.40 S 4508.88 E 5956976.09 N 681972.24 E 14.705 5195.40 10632.34 25.940 180.280 8368.87 8426.47 2663.13 S 4509.94 E 5956962.38 N 681973.63 E 14.641 5204.51 10660.64 25.070 188.550 8394.42 8452.02 2675.25 S 4509.01 E 5956950.24 N 681972.99 E 12.943 5211.07 10694.62 23.860 201.770 8425.37 8482.97 2688.77 S 4505.39 E 5956936.65 N 681969.69 E 16.467 5216.31 10725.56 24.300 206.800 8453.62 8511.22 2700.26 S 4500.20 E 5956925.03 N 681964.77 E 6.782 5219.08 10753.85 23.190 211.120 8479.52 8537.12 2710.23 S 4494.70 E 5956914.94 N 681959.50 E 7.292 5220.68 10787.59 23.510 212.170 8510.50 8568.10 2721.61 S 4487.68 E 5956903.40 N 681952.76 E 1.556 5221.93 10818.27 24.540 221.230 8538.53 8596.13 2731.59 S 4480.22 E 5956893.25 N 681945.53 E 12.470 5221.97 28 September, 2004 -16:38 Page 2 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-11 B (mwd) Your Ref: API 500292065302 Job No. AKMW3242526, Surveyed: 30 August, 2004 BPXA 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) 10846.74 26.000 230.710 8564.29 8621.89 2739.99 S 4471.49 E 5956884.64 N 681937.00 E 15.094 5220.06 10880.67 29.610 239.380 8594.31 8651.91 2748.97 S 4458.51 E 5956875.35 N 681924.24 E 15.953 5215.10 10912.09 33.090 244.820 8621.14 8678.74 2756.58 S 4444.06 E 5956867.41 N 681909.98 E 14.267 5208.14 10939.59 35.460 249.770 8643.87 8701.47 2762.53 S 4429.78 E 5956861.12 N 681895.84 E 13.300 5200.31 . 10966.33 39.340 255.850 8665.11 8722.71 2767.29 S 4414.27 E 5956856.00 N 681880.45 E 20.018 5190.79 11000.22 44.370 260.050 8690.35 8747.95 2771.97 S 4392.17 E 5956850.80 N 681858.46 E 16.984 5175.95 11030.69 48.780 263.090 8711.29 8768.89 2775.19 S 4370.28 E 5956847.06 N 681836.66 E 16.183 5160.41 11058.88 54.450 265.120 8728.79 8786.39 2777.44 S 4348.31 E 5956844.29 N 681814.74 E 20.889 5144.22 11092.88 58.450 269.690 8747.59 8805.19 2778.70 S 4320.02 E 5956842.37 N 681786.49 E 16.240 5122.39 11122.99 62.790 272.630 8762.36 8819.96 2778.15 S 4293.80 E 5956842.29 N 681760.26 E 16.736 5101.12 11152.60 67.000 276.800 8774.92 8832.52 2775.93 S 4267.09 E 5956843.88 N 681733.51 E 19.096 5078.45 11185.92 70.770 281.730 8786.93 8844.53 2770.92 S 4236.44 E 5956848.17 N 681702.75 E 17.844 5050.95 11215.91 75.660 283.830 8795.59 8853.19 2764.56 S 4208.45 E 5956853.87 N 681674.61 E 17.629 5024.77 11245.32 80.510 286.020 8801.66 8859.26 2757.15 S 4180.65 E 5956860.62 N 681646.65 E 18.028 4998.11 11278.09 87.040 295.130 8805.22 8862.82 2745.70 S 4150.21 E 5956871 .35 N 681615.95 E 34.058 4966.91 11309.44 87.960 295.120 8806.59 8864.19 2732.40 S 4121.85 E 5956883.97 N 681587.29 E 2.935 4936.26 11337.50 89.200 303.320 8807.28 8864.88 2718.72 S 4097.39 E 5956897.07 N 681562.51 E 29.546 4908.49 11431.88 89.320 295.170 8808.50 8866.10 2672.65 S 4015.12 E 5956941.18 N 681479.17 E 8.636 4815.06 11525.35 90.800 303.400 8808.41 8866.01 2626.97 S 3933.67 E 5956984.93 N 681396.66 E 8.946 4722.52 11619.02 91.980 300.480 8806.13 8863.73 2577.44 S 3854.21 E 5957032.58 N 681316.06 E 3.361 4629.25 11687.28 93.340 300.010 8802.96 8860.56 2543.10 S 3795.31 E 5957065.52 N 681256.36 E 2.108 4561.54 . 11721.15 93.700 297.330 8800.88 8858.48 2526.88 S 3765.65 E 5957081.03 N 681226.33 E 7.969 4528.10 11751.96 90.740 292.330 8799.69 8857.29 2513.96 S 3737.72 E 5957093.29 N 681198.10 E 18.847 4498.01 11779.64 89.140 295.170 8799.72 8857.32 2502.81 S 3712.39 E 5957103.84 N 681172.52 E 11.776 4471.07 11813.47 88.770 289.900 8800.34 8857.94 2489.85 S 3681.16 E 5957116.06 N 681140.99 E 15.614 4438.33 11845.36 89.140 292.020 8800.92 8858.52 2478.45 S 3651.38 E 5957126.75 N 681110.95 E 6.747 4407.69 11873.02 91.970 293.930 8800.65 8858.25 2467.65 S 3625.92 E 5957136.94 N 681085.25 E 12.343 4380.86 11907.40 91.850 295.050 8799.50 8857.10 2453.41 S 3594.65 E 5957150.45 N 681053.65 E 3.275 4347.32 11938.92 91.980 291.530 8798.45 8856.05 2440.95 S 3565.72 E 5957162.21 N 681024.43 E 11 .169 4316.72 11966.49 91.420 293.010 8797.63 8855.23 2430.51 S 3540.22 E 5957172.05 N 680998.69 E 5.737 4290.07 12016.36 91.730 293.290 8796.26 8853.86 2410.91 S 3494.39 E 5957190.56 N 680952.40 E 0.837 4241.66 12061.36 92.160 296.720 8794.73 8852.33 2391.91 S 3453.63 E 5957208.60 N 680911.21 E 7.678 4197.68 12107.98 91.850 297.640 8793.10 8850.70 2370.62 S 3412.19 E 5957228.90 N 680869.28 E 2.081 4151.77 12154.66 91.540 295.690 8791.72 8849.32 2349.69 S 3370.49 E 5957248.85 N 680827.10 E 4.228 4105.87 12212.30 90.250 295.170 8790.82 8848.42 2324.94 S 3318.44 E 5957272.36 N 680774.48 E 2.413 4049.41 28 September, 2004 - 16:38 Page 3 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA OS 15 - 15-11B (mwd) Your Ref: API 500292065302 Job No. AKMW3242526, Surveyed: 30 August, 2004 BPXA 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) 12247.60 90.060 295.170 8790.73 8848.33 2309.92 S 3286.50 E 5957286.62 N 680742.19 E 0.538 4014.86 12297.77 89.880 301.960 8790.75 8848.35 2285.95 S 3242.46 E 5957309.55 N 680697.60 E 13.539 3965.26 12340.44 89.810 295.170 8790.87 8848.47 2265.56 S 3205.00 E 5957329.05 N 680659.67 E 15.914 3923.08 12390.68 89.690 301.500 8791.09 8848.69 2241.73 S 3160.81 E 5957351.83 N 680614.93 E 12.602 3873.44 . 12434.24 89.510 295.170 8791.39 8848.99 2221.06 S 3122.49 E 5957371.58 N 680576.13 E 14.537 3830.40 12482.28 89.380 295.170 8791.86 8849.46 2200.63 S 3079.01 E 5957390.98 N 680532.18 E 0.271 3783.38 12574.46 89.320 297.4 70 8792.90 8850.50 2159.77 S 2996.40 E 5957429.89 N 680448.63 E 2.496 3692.81 12620.61 89.200 312.330 8793.50 8851.10 2133.44 S 2958.66 E 5957455.32 N 680410.28 E 32.198 3646.82 12668.13 91.050 308.770 8793.40 8851.00 2102.55 S 2922.56 E 5957485.34 N 680373.46 E 8.442 3599.40 12714.51 92.470 307.000 8791.98 8849.58 2074.08 S 2885.97 E 5957512.94 N 680336.21 E 4.891 3553.05 12807.53 92.900 299.340 8787.61 8845.21 2023.28 S 2808.25 E 5957561.89 N 680257.31 E 8.239 3460.41 12901.37 93.270 303.880 8782.56 8840.16 1974.18S 2728.47 E 5957609.09 N 680176.40 E 4.847 3367.15 12968.00 93.270 303.880 8778.76 8836.36 1937.10S 2673.25 E 5957644.86 N 680120.31 E 0.000 3300.73 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 127.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12968.00ft., The Bottom Hole Displacement is 3301.30ft., in the Direction of 125.928° (True). . 28 September, 2004 - 16:38 Page 4 of 5 OrílfQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA OS 15 - 15-11B (mwd) Your Ref: API 500292065302 Job No. AKMW3242526, Surveyed: 30 August, 2004 BPXA North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9586.60 9620.00 12968.00 7748.58 7768.86 8836.36 2111.83S 2126.43 S 1937.10 S 3968.13 E 3990.29 E 2673.25 E Tie On Point Window Point Projected Survey . Survey tool program for 15-11 B (mwd) Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9586.60 0.00 9586.60 7748.58 12968.00 7748.58 AK-1 BP _HG - GYD-CT-DMS (15-11) 8836.36 MWD Magnetic (15-11 B (mwd) . 28 September, 2004 - 16:38 Page 5 of 5 Ori/lQuest 3.03.06.006 15-118 Tubing cut . . (ill P \ I ! lJ::¡ ~ c0 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 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: PBU 15-11B BP Exploration (Alaska), Inc. Pennit No: 204-146 Surface Location: 1999' SNL, 3829' WEL, Sec. 22, TI1N, R14E, UM Bottomhole Location: 4051' SNL, 1109' WEL, Sec, 22, T11N, R14E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 65 607 (pager). BY ORDER OF THE COMMISSION DATED thisl1:"day of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encI. VJGA S //o!z.oo4 . STATE OF ALASKA fA ALASKA ~. AND GAS CONSERVATION COrJftW/SSION PERMIT TO DRILL / 20 MC 25.005 Revised: 08/09/04, Changed 4-1/2" Csg Top 1a. Type of work DDrill III Redrill rb. Current Well Class D Exploratory III Development Oil D Multiple Zone D Re-Entry D Stratigraphic Test D Service D Development Gas D Single Zone 2. Operator Name: 5. Bond: II Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU 15-11B - 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 12850 TVD 8815 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028306 1999' SNL, 3829' WEL, SEC. 22, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 4710' SNL, 274' EWL, SEC. 23, T11N, R14E, UM August 21,2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4051' SNL, 1109' WEL, SEC. 22, T11N, R14E, UM 2560 29,500 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 677402 y- 5959518 Zone- ASP4 (Height above GL);Plan 57.6' feet 15-42A is 456' away at 11900' MD 16. Deviated Wells: Kickoff Depth: 9600 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 94 degrees Downhole: 3250 Surface: 2380 113: Casing .if:'rogram: ~ T¡;ettiha~Pt~... '^"" ....... Size .......... Y tc.f. LJI _"",,::o,·.i .i Hole CasinQ WeiQht Grade CouplinQ LenQth MD TVD MD TVD (includinQ staQe data) 8-1/2" 7" 26# L-80 BTC-M 891' 9450' 7672' 10341 ' 8211' 203 sx Class 'G' 6-118" 4-1/2" 12.6# L-80 IBT-M 2660' 10190' 8118' 12850' 8815' 324 sx Class 'G' . 19. PRI;SI;NT V\I!:LL C:ÓNDITlONSOMMARY(TO be completed for Rc¡¡driUANO Re"entrýOPømtjPI'Î$) ..:i.,..'.."> Total Depth MD (ft): Total Depth TVD (ft): / Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft):/ Junk (measured): 12271 8834 None 12232 8829 None (Yi. .1··Arlðtl'li .,. 'ql4~'... (ii<ii iii ii·. i' <Fi ..... (.MDu(····.. iii ..V!Äli I Cnnrlur.tnr 112' 20" 300 sx Permafrost 112' 112' 2474' 13-3/8" 2400 sx Fondu, 400 sx Permafrost 'C' 2474' 2474' 10240' 9-5/8" 250 sx Class 'G', 300 sx Permafrost 'C' 10240' 8172' Production I inAr 809' 7" 30 sx Class 'G' 9924' - 10733' 7964' - 8529' Liner 2388' 2-3/8" 66 sx LARC 9876' - 12264' 7933' - 8833' Perforation Depth MD (ft): 11095' -12231' IPerfOration Depth TVD (ft): 8821' - 8828' 20. Attachments o Filing Fee, $100 II BOP Sketch II Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report II Drilling Fluid Program 1120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name Lo~1I Crane Title Senior Drilling Engineer SiQnature-\.~<'C:£/I /~ Prepared By Name/Number: Phone 564-4089 Date f'.~ '7 - C'f Terrie Hubble, 564-4628 .···(.·ii··i··.·i (././ i.i i ··········i ti. .iii .i ·i iii·i"··.·.·· .iii·i;!..i...< .. ····i.·.··..· i. Permit To Drill 4 l4;¿, API Number: I Permit APpr~1 ~ .' I ~ee cover letter for /',"..... Date: g; /"7" ëJ Ç/ other requirements Number: '-IV - 50- 029-20653-02-00 Conditions of Approval: Samples Required DYes gNo Mud Log Required DYes ~No Hydrogen Sulfide Measures L2š Yes D No Directional Survey Required EYes DNo Other:Test ßo pE 3500 , c.. f9" 5i{p.úoo ck C"'/u.·y(.·...... t/C--lø¿.s:' Irlpproved p$.{ , y?t'·v .(Y/f,U¡ ..>cde..- ~ I - D\ , Date ;?h 1- /0 f~ Anoroved Bv I ;. ~tA APPROVED BY ./ ;..\ THE COMMISSION Form 10-401 ReviM"06/2 WÞ" '--""""" UKIGINAL ,ßubmitfln Duplicate e e IWell Name: 115-11 B Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: X = 677,401.9 Y = 5,959,518.6 / Estimated 1997' FNL 1450' FWL Sec. 22, T11 N, R14E Umiat Target Location: X = 681,574.0 Y = 5,956,904, TVDss 8785' ~ Ivishak Zone 1 A 569' FSL 274' FWL Sec. 23, T11N, R14E Umiat Bottom Hole Location: X = 680,174.0 Y = 5,957,529.0 TVDss 8757' ./' 4051' FNL 4170' FWL Sec. 22, T11 N, R14E Umiat I AFE Number: I PBD4P2274 I I Estimated Start Date: 108/21/04 @[] 12,850' II TVD: 18,815' I I Rig: I Nabors 2ES I Operating days to complete: 116.0 ./ 1 GL: 129.1' I I KB: 128.5' I I KBE: 157.6' I Well Design (conventional, slim hole, etc.): I Two String Horizontal Sidetrack I Objective: ¡Ivishak Zone 1 A Formation Markers Formation Tops (wp01) MD TVD TVDss Comments CM2 6745 -6687 ABOVE KICKOFF CM! 7436 -7378 " THRZ 9674 7802 -7744 " BHRZ 9989 7995 -7937 LCU 10,044 8029 -7971 TJA 10,189 8118 -8060 SAG RIVER 10,341 8211 -8153 SHUBLIK 10,409 8253 -8195 TSAD 10,511 8326 -8268 TCGL 10,677 8466 -8408 BCGL 10,755 8537 -8479 TZlB 11,057 8769 -8711 3250 PSI @ 8800' TVD = 7.1 PPQ EMW TDF 11 , 172 8820 -8762 BSAD 8848 -8790 Not Penetrated TD TD Criteria: Reach planned TD unless drilling conditions deteriorate. ,/ 15-11 B Permit to Drill Page 1 e Directional - Sperry wp01 e KOP: 19600' MD Maximum Hole Angle: -530 in the 8-1/2" intermediate section -940 in the 6-1/8" horizontal section Close Approach Wells: All wells pass major risk criteria for this well plan. The nearest well is 456' ctr-ctr with 147' allowable deviation. Survey Program: MW 0 Standard Nearest Property Line: 29,500' to the nearest PBU property line Nearest Well within Pool: 15-42A at 456' center to center at 11,900' planned depth. ram Wt/Ft Grade Co~ Length Top Btm / MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 891' 9450'/7,672' 10,341 '/8,211' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2560' 10,290'/8180' 12,850/8815' Tubin 4-1/2" 12.6# 13Cr-80 V AM To -10,260' GL 10,290/8180' PV 15-22 FloPro PV <10 8-1/2" hole section YP TauO 22-30 2-4 Lo Pro ram 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GRlRes Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GR/Res/Neu/ABI (Neu/Den may be discontinued after picking GOC) Open Hole: None Cased Hole: None 15-11 B Permit to Drill Page 2 e e Size 4.5" 12.6#, L-80 Production Liner Lead: None Tail: Based on 80' shoe track, 2673' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, and 200' of 7" X 4" DP excess. Tail TOG: 10,290' MD (Top of Liner) Total Cement Volume: Tail 67 bbls, 376 ft ,32 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 AOGGG. Intermediate Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure Production Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure 15-11 B Permit to Drill Page 3 e e 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. Sidetrack and Complete Procedure Summarv Current Condition: ,/' Passed MITOA to 2000 psi and fail eMIT TxlA on 4/13/03. Suspect leaking tubing plug. ,/' Passed PPPOT-Ie 3200 psi on 4/27/03 ,/' Failed second eMIT TxlA on 7/29/04 with zero pressure increase on OA; suspect leaking packer or tailpipe plug. ,/' The well has been shut in for two years due to corroded tubing. Previously produced about 600 bopd, 25K GOR, 0% we. Scope Pre~RiQ Work: 1. Pull tubing plug at 9780' MD. 2. Fluid pack as necessary for cement abandonment. 3. R/U and RIH with coil tubing to plug and abandon the well bore from PBTD at 11,232' to window depth of 10,500'. Estimated cement volume = 7 bbls. 4. Pressure test the tubing and cement plug to 3500 psi. 5. R/U slick-line. Drift the 3 W' tubing to at least 9,800' md to confirm clear to the required cut depth. 6. R/U E-line. RIH with chemical cutter and severe the 3 W' tubing in the center of the full joint of tubing above the GLM -9,750' md. 7. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,100' MD with diesel. 8. Bleed casing and annulus pressures to zero. 9. Cycle the tubing hanger LDS and test the 9 5/8" mandrel packott to 5000 psi. 10. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. RiQ Operations: 1. MI I RU Nabors rig 2ES. Pull BPV. 2. Circulate out diesel freeze protection and displace the well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. R/U. Pull 3 W' tubing from the cut at -9,750' MD and above. 5. RIH wi 8 W' gauge ring I junk basket to top of tubing stub. 6. RIH with HES EZSV and set bridge plug as required to avoid cutting casing collar and place top of whip stock at -9600. POOH. RID E-line. I , ( 7. Pressure-testthe95/8"casin to 3500 si for 30 minutes. Record test. Tv,Â,..¡. 10 - 401 et-tJpVC\fct , 8. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 11.5 ppg LSND based milling fluid. Completely displace the well prior to beginning / milling operations. 10. Mill window in 9 5/8" casing at ± 9,600' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.5 ppg EMW. POOH. ./' 15-11 B Permit to Drill Page 4 e e 12. M/U 8 Y2" Dir/GR/Res assembly. RIH, kick off and drill the 81/2" intermediate section to the top of the. Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. ",- 13. Run and cement a 7",26.0#, L-80 intermediate drilling liner. /'" 14. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 15. M/U 61/8" Dir/GR/Neu/Den/Res/ABI assembly. RIH to the landing collar. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus drill -20' new formation; pull up into the shoe and conduct an FIT to 1 O.Oppg /' EMW. Drill ahead to horizontal landing point. POOH for bit I BHA change. Drop Neu/Den. 19. RIH, drill horizontal section to planned TD, short trip as necessary. 20. Circulate, short trip, spot liner running pill, POOH. 21. Run and cement a 4 W', 12.6#, L-80 solid production liner. POOH UD all drill pipe. /' 22. RIH with 2 7/8" perf guns and perforate ±1000'. 23. R/U and run 41/2",12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. - 24. Set a TWC and test to 1000 psi 25. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 26. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 27. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. / 28. Rig down and move off. Post-Ria Work: 1. Install well house and instrumentation 2. MI I RU slick-line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. Historv Parker 176 drilled DS15-11 in October 1981. Over the well's life it recovered 6 million bbls of oil. The primary cement over the production liner was poor and led to an immediate squeeze. During its life, 15-11 had three more squeezes, as well as two fracture treatments. Gas production was a constant problem. Following a cement squeeze in December 1997, the well would not flow, and plans were made to sidetrack the well. 15-11 A was drilled using CTD tiny tools in February 1999 and has since produced another 1.1 million bbls oil. Following its completion with -1000' of perforations, 15-11 A was consistently a full-time producer, with initial rates of 2937 BOPD, 0% WC, and a GOR of 1300 (3.8 MMSCFD). In the fall of 2002, the well was diagnosed with TxlA communication and secured (at the time, the well was making -575 BOPD, 0% WC, at a GOR of 29,000 (17 MMSCFD). A caliper survey of the tubing found holes or possible holes in 27 joints. The development team believes that 15-11A does not have sufficient reserves to justify a RWO, hence the planned rig sidetrack. ./ 15-11 B Drilling Program Job 1: MIRU Hazards and Contingencies ~ 15-11 A is 60' south of 15-31 A and 120' north of 15-12A. No well houses will require removal or shut-in for the rig move onto 15-11 A. ~ D515 is!!!!.!.. designated as an HzS site. Recent H2S data from the pad is as follows: Well Name H2S Readina Date #1 Closest SHL 15-31 A No data #2 Closest SHL 15-12A 10 oom 4/20/2004 #1 Closest BHL 15-42A No data #2 Closest BHL 15-25A 15 oom 5/29/2004 15-11 B Permit to Drill Page 5 e e Most ells ave more than 10 - 20 ppm H25 recorded. The maximum on the pad is D515- 21 A t 50 pm ).> Post P rmit to Drill 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-comDlete Well Hazards and Contingencies ~ DS15-11 was coiled tubing sidetracked to 15-11 A and completed with a 2 3/8" liner hung off in the original tubing tailpipe. Pre-Rig operations will include P&Aing the perforations in the 2-3/8" liner with cement to approximately 500' above the perforations. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested and freeze protected. ~ A 2002 caliper log indicates significant pitting and line corrosion in the tubing. The cross-sectional wall loss, however, is less than 10% therefore the maximum overpull can remain at the standard 80% of tensile strength for the 3 W' tubing. ~ 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 Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the Colville and TO at the top of Sag River. Since 15-11 B will start at <530 inclination and maintain inclination, 11.5 ppg mud weight will be adequate to maintain wellbore stability though the Kingak shale to interval TO. Follow all shale drilling practices to minimize potential problems. ~ There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ KICK TOLERANCE: In the worst-case scenario of 8.4 ppg pore pressure at the Sag River depth, a fracture gradient of 12.5 ppg at the 9-5/8" casing window, and 11.5 ppg mud in the hole, the kick tolerance is infinite. / Reference RP .:. "Shale Drilling, Kingak and HRZ" RP 15-11 B Permit to Drill Page 6 e e .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" 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 -~""""--'''''~' Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ The well is planned to land about 5' above the base of Zone 1 A. Check the projection early and trip for a motor change if necessary to avoid drilling the Kavik ~ The well is also planned to bisect the 15-42/15-11 A and 15-25A perforations to minimize risk of production interference. Avoid deviating greatly from the planned trajectory to optimize the well's drainage. ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance 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 8.5 ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running 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. 15-11 B Permit to Drill Page 7 e e ;.. 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" .:. Schlumberger Cement Program Job 10: DPC Perforate Production Casina 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 perforating practices and recommendations. .:. "OPC Perforating" RP ---",,,,,,-., -"'»,.,,~,- 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/NUlRelease Ria Hazards and Contingencies );> No wells will require well house removal or shut-in for the rig move off of 15-11 B. See MIRU section for nearest well. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 15-11 B Permit to Drill Page 8 TREË =' WELLHEAD = , ACTUATOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= 6" FMC FMC AXELSON 60.0' NA 2800' 1-'1 B Proposed I "NOTES I 30' I-iCrossover: 5 1/2" x 41/2" NA 8800' SS I 133/8" CSG, 72#, L-80, ID = 12.347" I I Minimum ID = 3.725" @ XN I 4 1/2" 12.6# 13Cr-80, ID = 3.958" Proposed tubing cut l-i 9 5/8 x 3 1/2" PKR + Top 2-3/8" LNR 1-1 9-5/8" X 7" BOT LNR HGR -i 9700' 9881' 9924' TOC: 2 7/8" abandoned liner H 10,500' ÆRFORA TION SUMMARY REF LOG: SWS MEMORY CNUGRlCCL ON 02/06/99 ANGLEATTOPÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE DATE 10118/81 10/25/87 02/11/99 07/14/04 I 7"LNR,29#,L-80,ID=6.184" I 11240' REV BY COMMENTS ORIGINAL COM PLETION RWO CTD SIDETRACK PGS Proposed RST Completion 2100' H4-1/2" X Nipple ID = 3.813" ST MD 1VD 4 3318 3250 3 5496 5000 2 7547 6400 1 9342 7600 GAS LIFT MANDRELS DEV TYPE VLV LATCH PORT DATE DCK DMY DMY DMY 9600' H 9 5/8" Window I 10,135' H4 1/2" X Nipple (3.813" ID) I I 10,150' -i7" x 4 1/2" Baker Premier Packer I I 10,165' H41/2"XNiPPle(3.813"ID) I I 10,180' H4 1/2" XN Nipple (3.725" ID) I I 10,190' H4 1/2" WLEG I I 10,190' 1-141/2" Hanger I liner top packer I I 10,341' -i7" 26# L-80 (6.276" ID) 0.383 bpf , 141/2" 12.6# L-80 Liner PBTD H 12,765' 141/2" 12.6# (3.958" ID) 0.0152 bpf H 12,850' Old 7" WINDOW 10733' - 10748' 12-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.941" H 12264' I DATE COMMENTS PRUDHOE BA Y UNrr WELL: 15-11B ÆRMrr No: 1982480 API No: 50-029-20653-02 SEC22, T11N, R14E, 1997' FNL & 1450' FWL REV BY BP Exploration (Alaska) TREË'; 6" FMC WELLHEAD = FMC e S~ NOTES: WElL ANGLE> 700 @ 11080' & > . ACTUATOR= AXELSON 15-11 A 900 11171'. * 3·112" DUMMY SSSV SET @ 2223' KB. ELEV = 60.0' ON 10/20/01, ID = 1.75" BF. ELEV - NA , KOP- 2800' ........... - I Max Angle = 99 @ 11728' --I 39' H 5-112" X 3-1/2" XO, ID = 2.992" Datum MD = NA r--- . 2223' 3-1/2" OTIS SERIES 10 TRSSSV, ID = 2.813" Datum TVD = 8800' SS ~ I 133/8" CSG, 72#, L-80, ID = 12.347" I 2474' ~ ~ Minimum ID = 2.813" @ 2223' ~ GAS LIFT MANDRELS 3-1/2" OTIS TRSSSV II I STI MD I TVD DEVITYPEIVLVI LATCH I PORT DATE I L....! I 1 I 9765177921 52 I OTIS I DMY I RA I 0 10105/021 :8: 9780' H 3-1/2" WRP PLUG (SET 11107102) I I 9876' H 2.70" BKRDEPLOYMENTSLV,ID= 1.969" I I TOP OF 2-3/8" LNR, 4.7#, ID = 1.941" I 9881' I ~ P I 9881' H 9-5/8" X 3-1/2" OTIS WD PKR, ID = 5.00" I I 9924' H 9-5/8" X 7" BOT LNR HGR I :s 9965' H 3-1/2" XN NIP, ID = 2.80" (BEHIND LNR) I I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I 9976' I I 9977' H 3-1/2" TBG TAIL, ID = 2.992" I I 95/8" CSG, 47#, L-80, ID = 8.681" I J ~ I 9948' H ELMDTTLOGGED 12/18/89 I 10240' I 7" LNR MILLOUT WINDOW I ~ 10733' - 10748' (OFF GMT RAMP) ~ PERFORA TlON SUMMARY REF LOG: SWS MEMORY CNLlGRlCCL ON 02/06/99 ANGLE AT TOP PERF: 74 @ 11095' ~~ PBTD I Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 1-11/16" 4 11095 - 11495 0 02/08/99 1-11116" 4 11655 - 12231 0 02/08/99 , I 12-318" LNR, 4.7#, L-80, .0039 bpf,ID= 1.941" I 12264' I I 7" LNR, 29#, L-80, ID = 6.184" I 11240' ... DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 10/18/81 ORIGINAL COMPLETION 09/11/03 CMOffiP DATUM MDlTVD & PERF ANGLE WELL: 15-11A 10/25/87 RWO 06/12/04 CNJ/KA K MIN ID CORRECTION ÆRMIT No: 1982480 02/11/99 CTD SIDETRACK API No: 50-029-20653-01 11/22/01 CHITP CORRECTIONS SEC22, T11N, R14E, 1997' FNL & 1450' FWL 10105/02 SDF/KK GL V C/O 11107/02 CAO/KK SET WRP PLUG BP Exploration (Alaska) SURVEY PROGRAM lB wpOI {l5-J l¡Plan 15-1 IE) Depth Fm Depth To SUfveyiPlau Too! Created By: DigítaJ BusineS1i CHen! User Date: 7/9/2004 9600.00 12849.83 Planned; 15-IJB wpOJ \110 MWD Checked: Date: "_ Reviewed: Date: - - - - ..VEIL DETAILS N~ ¡-N/·S -'E/·W NortJ1ing F-asting Latitude Lougitucie SIo, 15·]1 654.91 1120.85 595951833 677402.09 7WI7'4L677N 148"33'4S.545W 11 - - - Soo MD Ine Azi TVD +NI-S +EI-W DLeg TFace VSec Target I 7756.73 00 0.00 2 7768.84 00 85.00 3 7841,09 00 100.24 4 8245.49 00 0.00 5 8842.60 00 146.86 15-llBTI 6 8842.06 )0 38.58 7 8828.84 )0 0.00 8 8827.60 )0 102.97 15-llB T2 9 8827.74 )0 -161.45 10 8834.98 )0 0.00 11 8835.60 iO 77.90 15-lJB n 12 8832.88 iO 0.00 13 8814.60 10 0.00 15-1lB T4 No. TVDPath MDPath Fmmation I 2 3 4 5 True Nortb ¡ COMPANY DE1AJL$ 01' Amoco CASING DETAILS No. TVD MD Natne Size 8210.60 10340.78 7" 7.000 8818.36 12800.00 4 112" 4.500 .... ......... TARGET DETAILS Name TVD +NI-S +E/-W Northing Easting Shape !T4 8814.60 5957529.00 !T2 8827.60 5957143.00 in 8835.60 5957373.00 in 8842.60 5956904.00 :s ¢; "'" "'" 12 -S "- Ö õj " ·E >- " " þ TDF SURVEY PROGRAM Plan: 1B wpOl (J5-llfPlan ]B) Depth Pm Ikpth To SUf'l~yW!an f"0ú CR>a1e;;! By: DígitJ.! Business Client User Date-: 7/912004 9600.00 !2849Jß Planned: 15-IIB wpOl VW MWD - - - - - N,,* "'N!-S -;-Ef·W Northing Bastiog LatitlJde Longitude Slot IS-I! 654.91 148°.u'48545W " - TARGET DETAILS Name TVD +N/-S +EI-W Northing Easting Shape T4 8814.60 -2054.33 2724.36 5957529.00 680174.00 Point T2 8827.60 -2457.93 3464.09 5957143.00 680923.00 Point T3 8835.60 -2216.72 2992.62 5957373.00 680446.00 Point II 8842.60 -2712.25 4109.31 5956904.00 681574.00 Point - - - - ...... Sec MD Ine Azi TVD +N/-S +E/-W DLeg IFaco VSec Target I 2 3 4 5 15-IIB II 6 7 8 15-I1B T2 9 10 II I5-IIB T3 12 13 COMPANY DETAILS 13P Amoco FORMA nON TOP DETAILS No. TVDPath MDPath Fonnation CASING DETAILS No. TVD MD Name Size 7" 4 II2' 7801.60 7994.60 8028.60 8117.60 8210.60 8252.60 8325.60 8465.60 8536.60 8768.60 8819.60 I 2 3 4 5 6 7 8 9 10 II "2 £i <::> <::> ~ :;:- f z 2 -B ::> c U'1 e BP-GDB BP Planning Report e Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 GeoDatum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 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 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: 35.236 N 21.213 W True 1.34 deg Well: 15-11 Slot Name: 15-11 Well Position: +N/-S 654.91 ft Northing: 5959518.33 ft Latitude: +E/-W 1120.85 ft Easting: 677402.09 ft Longitude: Position Uncertainty: 0.00 ft 11 70 17 41.677 N 148 33 48.545 W Casing Points 0.00 CM3 0.00 0.00 0.00 CM2 0.00 0.00 0.00 CM1 0.00 0.00 9674.01 7801.60 THRZ 0.00 0.00 10340.78 8210.60 TSGR 0.00 0.00 Targets 15-11BT4 8814.60 -2054.33 2724.36 5957529.00 680174.00 70 17 21.467 N 148 32 29.164 W 15-11B T2 8827.60 -2457.93 3464.09 5957143.00 680923.00 70 17 17.495 N 148 32 7.615 W 15-118 T3 8835.60 -2216.72 2992.62 5957373.00 680446.00 70 17 19.869 N 148 32 21.349 W 15-118T1 8842.60 -2712.25 4109.31 5956904.00 681574.00 70 17 14.991 N 148 31 48.820 W Plan Section Information 9600.00 52.60 122.91 7756.73 -2117.58 3977.12 0.00 0.00 0.00 0.00 9620.00 52.84 125.91 7768.84 -2126.57 3990.25 12.00 1.24 15.00 85.00 9738.60 52.15 131.83 7841.09 -2185.56 4063.46 4.00 -0.59 4.99 100.24 10397.65 52.15 131.83 8245.49 -2532.62 4451.20 0.00 0.00 0.00 0.00 11311.89 90.00 290.00 8842.60 -2712.25 4109.31 15.00 4.14 17.30 146.86 15-11BT1 11356.19 91.39 291.11 8842.06 -2696.70 4067.83 4.00 3.13 2.50 38.58 11903.31 91.39 291.11 8828.84 -2499.74 3557.56 0.00 0.00 0.00 0.00 12005.77 90.00 297.09 8827.60 -2457.93 3464.09 6.00 -1.35 5.85 102.97 15-11BT2 e BP-GDB BP Planning Report e 12022.42 89.05 296.78 8827.74 -2450.39 3449.24 6.00 -5.69 -1.91 -161.45 12460.29 89.05 296.78 8834.98 -2253.14 3058.38 0.00 0.00 0.00 0.00 12535.49 90.00 301.19 8835.60 -2216.72 2992.62 6.00 1.26 5.87 77.90 15-11B T3 12607.61 94.33 301.19 8832.88 -2179.41 2930.98 6.00 6.00 0.00 0.00 12849.83 94.33 301.19 8814.60 -2054.33 2724.36 0.00 0.00 0.00 0.00 15-11B T4 Survey 9600.00 52.60 122.91 7756.73 7699.13 -2117.58 3977.12 0.00 5957495.34 681427.82 MWD 9620.00 52.84 125.91 7768.84 7711.24 -2126.57 3990.25 12.00 5957486.66 681441.16 MWD 9625.00 52.81 126.16 7771.87 7714.27 -2128.92 3993.47 4.00 5957484.39 681444.43 MWD 9650.00 52.64 127.40 7787.01 7729.41 -2140.83 4009.40 4.00 5957472.86 681460.64 MWD 9674.01 52.49 128.59 7801.60 7744.00 -2152.56 4024.42 4.00 5957461.48 681475.94 THRZ 9675.00 52.49 128.64 7802.20 7744.60 -2153.06 4025.04 4.00 5957461.01 681476.56 MWD 9700.00 52.34 129.89 7817.45 7759.85 -2165.59 4040.38 4.00 5957448.84 681492.19 MWD 9725.00 52.21 131.15 7832.75 7775.15 -2178.44 4055.41 4.00 5957436.35 681507.52 MWD 9738.60 52.15 131.83 7841.09 7783.49 -2185.56 4063.46 4.00 5957429.42 681515.74 MWD 9750.00 52.15 131.83 7848.08 7790.48 -2191.56 4070.16 0.00 5957423.58 681522.58 MWD 9775.00 52.15 131.83 7863.42 7805.82 -2204.73 4084.87 0.00 5957410.77 681537.59 MWD 9800.00 52.15 131.83 7878.77 7821.17 -2217.89 4099.58 0.00 5957397.95 681552.61 MWD 9825.00 52.15 131.83 7894.11 7836.51 -2231.06 4114.29 0.00 5957385.14 681567.62 MWD 9850.00 52.15 131.83 7909.45 7851.85 -2244.22 4129.00 0.00 5957372.32 681582.64 MWD 9875.00 52.15 131.83 7924.79 7867.19 -2257.39 4143.71 0.00 5957359.51 681597.65 MWD 9900.00 52.15 131.83 7940.13 7882.53 -2270.55 4158.41 0.00 5957346.70 681612.67 MWD 9925.00 52.15 131.83 7955.47 7897.87 -2283.72 4173.12 0.00 5957333.88 681627.68 MWD 9950.00 52.15 131.83 7970.81 7913.21 -2296.88 4187.83 0.00 5957321.07 681642.69 MWD 9975.00 52.15 131.83 7986.15 7928.55 -2310.05 4202.54 0.00 5957308.26 681657.71 MWD 10000.00 52.15 131.83 8001.49 7943.89 -2323.22 4217.25 0.00 5957295.44 681672.72 MWD 10025.00 52.15 131.83 8016.83 7959.23 -2336.38 4231.96 0.00 5957282.63 681687.74 MWD 10050.00 52.15 131.83 8032.17 7974.57 -2349.55 4246.67 0.00 5957269.82 681702.75 MWD 10075.00 52.15 131.83 8047.51 7989.91 -2362.71 4261.37 0.00 5957257.00 681717.76 MWD 10100.00 52.15 131.83 8062.85 8005.25 -2375.88 4276.08 0.00 5957244.19 681732.78 MWD 10125.00 52.15 131.83 8078.19 8020.59 -2389.04 4290.79 0.00 5957231.37 681747.79 MWD 10150.00 52.15 131.83 8093.53 8035.93 -2402.21 4305.50 0.00 5957218.56 681762.81 MWD 10175.00 52.15 131.83 8108.87 8051.27 -2415.37 4320.21 0.00 5957205.75 681777.82 MWD 10200.00 52.15 131.83 8124.21 8066.61 -2428.54 4334.92 0.00 5957192.93 681792.84 MWD 10225.00 52.15 131.83 8139.55 8081.95 -2441.70 4349.62 0.00 5957180.12 681807.85 MWD 10250.00 52.15 131.83 8154.90 8097.30 -2454.87 4364.33 0.00 5957167.31 681822.86 MWD 10275.00 52.15 131.83 8170.24 8112.64 -2468.03 4379.04 0.00 5957154.49 681837.88 MWD 10300.00 52.15 131.83 8185.58 8127.98 -2481.20 4393.75 0.00 5957141.68 681852.89 MWD 10325.00 52.15 131.83 8200.92 8143.32 -2494.36 4408.46 0.00 5957128.86 681867.91 MWD 10340.78 52.15 131.83 8210.60 8153.00 -2502.68 4417.74 0.00 5957120.78 681877.38 7" 10350.00 52.15 131.83 8216.26 8158.66 -2507.53 4423.17 0.00 5957116.05 681882.92 MWD 10375.00 52.15 131.83 8231.60 8174.00 -2520.70 4437.88 0.00 5957103.24 681897.94 MWD 10397.65 52.15 131.83 8245.49 8187.89 -2532.62 4451.20 0.00 5957091.63 681911.54 MWD 10400.00 51.85 132.08 8246.94 8189.34 -2533.86 4452.58 15.00 5957090.42 681912.94 MWD 10425.00 48.75 134.81 8262.91 8205.31 -2547.08 4466.55 15.00 5957077.54 681927.22 MWD 10450.00 45.72 137.82 8279.89 8222.29 -2560.34 4479.23 15.00 5957064.59 681940.21 MWD 10475.00 42.77 141.15 8297.80 8240.20 -2573.58 4490.57 15.00 5957051.61 681951.86 MWD 10500.00 39.93 144.86 8316.56 8258.96 -2586.76 4500.51 15.00 5957038.67 681962.11 MWD 10525.00 37.23 149.03 8336.11 8278.51 -2599.81 4509.03 15.00 5957025.83 681970.93 MWD 10550.00 34.69 153.73 8356.35 8298.75 -2612.68 4516.07 15.00 5957013.13 681978.27 MWD 10575.00 32.36 159.05 8377.19 8319.59 -2625.31 4521.61 15.00 5957000.63 681984.11 MWD · , e BP-GDB BP Planning Report e 10600.00 30.27 165.06 8398.55 8340.95 -2637.65 4525.63 15.00 5956988.39 681988.42 MWD 10625.00 28.50 171.80 8420.34 8362.74 -2649.65 4528.11 15.00 5956976.46 681991.18 MWD 10650.00 27.10 179.26 8442.46 8384.86 -2661.25 4529.03 15.00 5956964.88 681992.38 MWD 10675.00 26.12 187.35 8464.82 8407.22 -2672.41 4528.40 15.00 5956953.71 681992.01 MWD 10700.00 25.63 195.87 8487.32 8429.72 -2683.07 4526.22 15.00 5956943.00 681990.08 MWD 10725.00 25.64 204.55 8509.87 8452.27 -2693.20 4522.49 15.00 5956932.79 681986.59 MWD 10750.00 26.16 213.06 8532.37 8474.77 -2702.74 4517.23 15.00 5956923.13 681981.56 MWD 10775.00 27.16 221.12 8554.71 8497.11 -2711.66 4510.47 15.00 5956914.05 681975.01 MWD 10800.00 28.58 228.55 8576.82 8519.22 -2719.92 4502.24 15.00 5956905.60 681966.97 MWD 10825.00 30.37 235.25 8598.59 8540.99 -2727.48 4492.56 15.00 5956897.81 681957.48 MWD 10850.00 32.47 241.22 8619.93 8562.33 -2734.32 4481.48 15.00 5956890.72 681946.56 MWD 10875.00 34.81 246.51 8640.75 8583.15 -2740.39 4469.05 15.00 5956884.35 681934.28 MWD 10900.00 37.36 251.18 8660.95 8603.35 -2745.68 4455.32 15.00 5956878.74 681920.68 MWD 10925.00 40.07 255.33 8680.46 8622.86 -2750.17 4440.35 15.00 5956873.90 681905.82 MWD 10950.00 42.91 259.02 8699.19 8641.59 -2753.83 4424.20 15.00 5956869.86 681889.77 MWD 10975.00 45.86 262.33 8717.05 8659.45 -2756.65 4406.95 15.00 5956866.64 681872.59 MWD 11000.00 48.90 265.33 8733.98 8676.38 -2758.61 4388.67 15.00 5956864.24 681854.36 MWD 11025.00 52.01 268.05 8749.90 8692.30 -2759.72 4369.43 15.00 5956862.68 681835.15 MWD 11050.00 55.17 270.55 8764.74 8707.14 -2759.95 4349.31 15.00 5956861.97 681815.05 MWD 11075.00 58.38 272.87 8778.44 8720.84 -2759.32 4328.42 15.00 5956862.11 681794.14 MWD 11100.00 61.63 275.03 8790.93 8733.33 -2757.82 4306.82 15.00 5956863.10 681772.52 MWD 11125.00 64.92 277.06 8802.17 8744.57 -2755.47 4284.62 15.00 5956864.93 681750.27 MWD 11150.00 68.22 278.98 8812.11 8754.51 -2752.27 4261.91 15.00 5956867.59 681727.49 MWD 11175.00 71.55 280.82 8820.71 8763.11 -2748.23 4238.79 15.00 5956871.09 681704.29 MWD 11200.00 74.90 282.58 8827.92 8770.32 -2743.37 4215.35 15.00 5956875.39 681680.75 MWD 11225.00 78.26 284.29 8833.72 8776.12 -2737.72 4191.71 15.00 5956880.48 681656.97 MWD 11250.00 81.63 285.96 8838.09 8780.49 -2731.29 4167.95 15.00 5956886.34 681633.07 MWD 11275.00 85.01 287.61 8840.99 8783.39 -2724.12 4144.18 15.00 5956892.95 681609.14 MWD 11300.00 88.39 289.23 8842.43 8784.83 -2716.24 4120.51 15.00 5956900.27 681585.29 MWD 11311.89 90.00 290.00 8842.60 8785.00 -2712.25 4109.31 15.00 5956904.00 681574.00 15-11B T1 11325.00 90.41 290.33 8842.55 8784.95 -2707.73 4097.00 4.00 5956908.22 681561.59 MWD 11350.00 91.19 290.95 8842.20 8784.60 -2698.92 4073.61 4.00 5956916.48 681538.00 MWD 11356.19 91.39 291.11 8842.06 8784.46 -2696.70 4067.83 4.00 5956918.56 681532.17 MWD 11375.00 91.39 291.11 8841.61 8784.01 -2689.93 4050.29 0.00 5956924.92 681514.47 MWD 11400.00 91.39 291.11 8841.01 8783.41 -2680.93 4026.97 0.00 5956933.36 681490.95 MWD 11425.00 91.39 291.11 8840.40 8782.80 -2671.93 4003.66 0.00 5956941.81 681467.43 MWD 11450.00 91.39 291.11 8839.80 8782.20 -2662.93 3980.34 0.00 5956950.26 681443.91 MWD 11475.00 91.39 291.11 8839.19 8781.59 -2653.93 3957.02 0.00 5956958.70 681420.39 MWD 11500.00 91.39 291.11 8838.59 8780.99 -2644.93 3933.71 0.00 5956967.15 681396.87 MWD 11525.00 91.39 291.11 8837.98 8780.38 -2635.93 3910.39 0.00 5956975.59 681373.35 MWD 11550.00 91.39 291.11 8837.38 8779.78 -2626.93 3887.08 0.00 5956984.04 681349.83 MWD 11575.00 91.39 291.11 8836.78 8779.18 -2617.93 3863.76 0.00 5956992.49 681326.31 MWD 11600.00 91.39 291.11 8836.17 8778.57 -2608.93 3840.44 0.00 5957000.93 681302.79 MWD 11625.00 91.39 291.11 8835.57 8777.97 -2599.93 3817.13 0.00 5957009.38 681279.27 MWD 11650.00 91.39 291.11 8834.96 8777.36 -2590.93 3793.81 0.00 5957017.83 681255.75 MWD 11675.00 91.39 291.11 8834.36 8776.76 -2581.93 3770.49 0.00 5957026.27 681232.23 MWD 11700.00 91.39 291.11 8833.75 8776.15 -2572.93 3747.18 0.00 5957034.72 681208.71 MWD 11725.00 91.39 291.11 8833.15 8775.55 -2563.93 3723.86 0.00 5957043.16 681185.19 MWD 11750.00 91.39 291.11 8832.55 8774.95 -2554.93 3700.55 0.00 5957051.61 681161.67 MWD 11775.00 91.39 291.11 8831.94 8774.34 -2545.93 3677.23 0.00 5957060.06 681138.15 MWD 11800.00 91.39 291.11 8831.34 8773.74 -2536.93 3653.91 0.00 5957068.50 681114.62 MWD 11825.00 91.39 291.11 8830.73 8773.13 -2527.93 3630.60 0.00 5957076.95 681091.10 MWD e BP-GDB DP Planning Report e 11850.00 91.39 291.11 8830.13 8772.53 -2518.94 3607.28 0.00 5957085.39 681067.58 MWD 11875.00 91.39 291.11 8829.52 8771.92 -2509.94 3583.97 0.00 5957093.84 681044.06 MWD 11900.00 91.39 291.11 8828.92 8771.32 -2500.94 3560.65 0.00 5957102.29 681020.54 MWD 11903.31 91.39 291.11 8828.84 8771.24 -2499.74 3557.56 0.00 5957103.41 681017.42 MWD 11925.00 91.09 292.37 8828.37 8770.77 -2491.71 3537.42 6.00 5957110.96 680997.10 MWD 11950.00 90.75 293.84 8827.97 8770.37 -2481.90 3514.43 6.00 5957120.22 680973.89 MWD 11975.00 90.42 295.30 8827.71 8770.11 -2471.51 3491.69 6.00 5957130.07 680950.92 MWD 12000.00 90.08 296.76 8827.60 8770.00 -2460.54 3469.23 6.00 5957140.51 680928.20 MWD 12005.77 90.00 297.09 8827.60 8770.00 -2457.93 3464.09 6.00 5957143.00 680923.00 15-118 T2 12022.42 89.05 296.78 8827.74 8770.14 -2450.39 3449.24 6.00 5957150.19 680907.98 MWD 12025.00 89.05 296.78 8827.78 8770.18 -2449.23 3446.94 0.00 5957151.30 680905.65 MWD 12050.00 89.05 296.78 8828.19 8770.59 -2437.96 3424.62 0.00 5957162.03 680883.08 MWD 12075.00 89.05 296.78 8828.61 8771.01 -2426.70 3402.31 0.00 5957172.76 680860.50 MWD 12100.00 89.05 296.78 8829.02 8771.42 -2415.44 3379.99 0.00 5957183.49 680837.93 MWD 12125.00 89.05 296.78 8829.43 8771.83 -2404.18 3357.67 0.00 5957194.22 680815.35 MWD 12150.00 89.05 296.78 8829.85 8772.25 -2392.92 3335.36 0.00 5957204.95 680792.78 MWD 12175.00 89.05 296.78 8830.26 8772.66 -2381.66 3313.04 0.00 5957215.68 680770.21 MWD 12200.00 89.05 296.78 8830.67 8773.07 -2370.40 3290.73 0.00 5957226.41 680747.63 MWD 12225.00 89.05 296.78 8831.09 8773.49 -2359.13 3268.41 0.00 5957237.14 680725.06 MWD 12250.00 89.05 296.78 8831.50 8773.90 -2347.87 3246.09 0.00 5957247.87 680702.48 MWD 12275.00 89.05 296.78 8831.91 8774.31 -2336.61 3223.78 0.00 5957258.60 680679.91 MWD 12300.00 89.05 296.78 8832.33 8774.73 -2325.35 3201.46 0.00 5957269.34 680657.33 MWD 12325.00 89.05 296.78 8832.74 8775.14 -2314.09 3179.15 0.00 5957280.07 680634.76 MWD 12350.00 89.05 296.78 8833.15 8775.55 -2302.83 3156.83 0.00 5957290.80 680612.19 MWD 12375.00 89.05 296.78 8833.57 8775.97 -2291.57 3134.51 0.00 5957301.53 680589.61 MWD 12400.00 89.05 296.78 8833.98 8776.38 -2280.30 3112.20 0.00 5957312.26 680567.04 MWD 12425.00 89.05 296.78 8834.39 8776.79 -2269.04 3089.88 0.00 5957322.99 680544.46 MWD 12450.00 89.05 296.78 8834.81 8777.21 -2257.78 3067.56 0.00 5957333.72 680521.89 MWD 12460.29 89.05 296.78 8834.98 8777.38 -2253.14 3058.38 0.00 5957338.14 680512.59 MWD 12475.00 89.24 297.64 8835.20 8777.60 -2246.42 3045.30 6.00 5957344.55 680499.36 MWD 12500.00 89.55 299.11 8835.46 8777.86 -2234.54 3023.30 6.00 5957355.91 680477.09 MWD 12525.00 89.87 300.57 8835.59 8777.99 -2222.10 3001.62 6.00 5957367.83 680455.12 MWD 12535.49 90.00 301.19 8835.60 8778.00 -2216.72 2992.62 6.00 5957373.00 680446.00 15-11B T3 12550.00 90.87 301.19 8835.49 8777.89 -2209.21 2980.20 6.00 5957380.22 680433.41 MWD 12575.00 92.37 301.19 8834.78 8777.18 -2196.26 2958.83 6.00 5957392.65 680411.74 MWD 12600.00 93.87 301.19 8833.42 8775.82 -2183.34 2937.47 6.00 5957405.07 680390.08 MWD 12607.61 94.33 301.19 8832.88 8775.28 -2179.41 2930.98 6.00 5957408.85 680383.50 MWD 12625.00 94.33 301.19 8831.57 8773.97 -2170.43 2916.14 0.00 5957417.47 680368.46 MWD 12650.00 94.33 301.19 8829.68 8772.08 -2157.52 2894.82 0.00 5957429.87 680346.83 MWD 12675.00 94.33 301.19 8827.79 8770.19 -2144.61 2873.49 0.00 5957442.27 680325.21 MWD 12700.00 94.33 301.19 8825.91 8768.31 -2131.70 2852.17 0.00 5957454.68 680303.59 MWD 12725.00 94.33 301.19 8824.02 8766.42 -2118.79 2830.84 0.00 5957467.08 680281.97 MWD 12750.00 94.33 301.19 8822.13 8764.53 -2105.88 2809.51 0.00 5957479.48 680260.34 MWD 12775.00 94.33 301.19 8820.25 8762.65 -2092.97 2788.19 0.00 5957491.88 680238.72 MWD 12800.00 94.33 301.19 8818.36 8760.76 -2080.06 2766.86 0.00 5957504.28 680217.10 41/2" 12825.00 / 94.33 301.19 8816.47 8758.87 -2067.15 2745.54 0.00 5957516.68 680195.47 MWD 12849.83 94.33 301.19 8814.60 8757.00 -2054.33 2724.36 0.00 5957529.00 680174.00 15-118 T4 e e TERRIE L HUBBLE BP EXPLORATION AK INC POBOX 196612 MB7-5 ANCHORAGE, AK 99519-6612 89-6/1252 133 "Mastercard Check" DATE œ-OS~tf-f 'CC $ /00 ro DOLLARS First National Bank Alaska Anchorage, AK 99501 MEMO \ S~ L\ \6 ~ 'vf Mß&r -: ~ 2 5 2000 b 0 -: 1111 ~ I. II' b 2 2 7 II. ~ 5 5 b II- 0 ~ ~ ~ e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME$U /5-//~ PTD# 20 L/ - /~? / ),<: Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLVEn APPLIES (OPTIONS) MULTI The permit is for a Dew wen bOTe segment of LATERAL existing well . Permit No, API No. . (If API Dumber ProductioD.should continue to be reponed as last two (2) digits a function ·of tbe original API number. stated are between 60-69) above. Pll..OT HOLE In accordance with 20 AAC 25.005(f), an (PH) records, data and logs acquired for tbe piJot bole must be dearly differentiated In botb name (name on permit plus PH) ,. and API Dumber (SO - 70/80) from records, data and logs acquired for wen (name on permit). SPACING The permit is approved subject ,to fun EXCEPTION compliance with 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing ex ception. (Company Name) assumes the liability of any protest to tbe spacing .e:Jception that may occur. DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and ] 0' sample intervals through target zones. .. PTD#: 2041460 Administration Well bore seg Annular Disposal o o Appr Date RPC 8/5/2004 Engineering Appr Date WGA 8/10/2004 Geology Appr RPC Date 8/5/2004 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 15-11B Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 1 Pe(nJilfee~ttaçhed ...... ...... ....... .V~s ...... 2Le~s.e.numberapRrQpriale. . .. . . . . . . . . . . . . . . . V.es. . . . . . . . . . . . . . . . . . . . . 3 .U.nique welln.am.e.and Ol!mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. .... _ V~s . . _ . . . . . . . . _ _ _ . _ _ . . . . _ _ . . . _ . . . . _ . . _ _ . _ . . . . _ _ . . . . . _ _ . . _ _ . _ _ _ _ _ . . . _ _ . . _ _ _ _ _ _ _ 4 WeU/Qc¡¡t.ed inad.efjne_dpPQI . . _ . _ _ . . . . _ . _ . . . . _ _ . _ . V.es _ . . . _ _ _ . 5 WeJUQcaled proper _distance. from driJling unilb.ound_ary . . . . _ _ . .Y~s _ . _ 6 WeU/Qcated proper _distance. from otber welJs. _ . . _ _ _ . . . Yes. _ _ . . . _ . . . . _ _ . . . . . _ _ . . . . . . _. . . . . . _ . . . . _ _ 7 .S_utfiçient.açre~geaY~ilable indrilliogl!njL . . _ . _ . . V.es . . _ _ . . . . . _ . . . . . _ _ . . 8 /f.d.eyi~ted, js weJlbQre platincJuded . _ _ . . _ _ _ . . . _ _ . . . _ . . . . . _ Yes. . . . _ _ . . . . . _ . . . _ . . . _ _ _ _ . 90per.ator only ~ft:eçted party. _ . . . . _ _ . . . . _ _ . . . _ V~s. . . _ _ . . . . . _ _ . . . . _ _ _ . . . _ _ . . 10 _Ope(ator bas.apprppriate_bond [nJorce . . . . . . _ . . . _ _ _ . . _ _ _ . . . . _ _ _ . . _ _ . . . _ V~s . . . _ . . . . . _ _ . . _ . . . . . . _ . . _ _ _ . _ _ . . _ . _ . . _ _ _ _ _ . . _ _ . _ _ _ . . . _ . _ . . _ . . . . . . . . . . _ _ _ . . . _ 11 P.e(mil G.é!n be [sSl!ed witbQut co_nserva.tion order. . . _ . _ _ . . . . _ _ . . . . V~s. . . . _ _ _ . . . . _ . . . . . . _ . . . _ _ . . . . _ _ . . . . . . . . 12 P.ermilc.a/1beisSl!edwitbQut~dminist(atÍlle.apprpyaJ.. _... _ _. _ .. _ _.... _ V.es. ... _ _... _ _ _. ... _ _... _ _.' .... _.. 13 Can permit be approved before 15-day wait Yes 14 WelUQcaled w[thin ~re~ ~n.dstrata .authorized by.l/1jectipo Ord.er # (PuUO# in.c_omm.e/1ts).(For .NA . . . _ _ . . _ . . . _ _ . . . . . _ . . . . . . _ . 15 .AJI welJs.wit]1[n.114.mile.area.of reyieW id.eotlfied (Fou~ervjc_e-"'lell only). . . . . _ . . _ _ _ _ _ . . .NA . . . _ . _ _ _ _ . . _ _ . _ . . . . . . _ . . . . . . . . . . . . _ _ . _ _ _ _ . _ . . . . . . . . . . _ _ _ _ _ . . . _ . . . . . . _ . . . . _ . 16 Pre-produced injector; duration.of pre-productipo l.es$. than 3 montbs. (For_serv[ce well onJy) .NA _ . . . . _ . _ . . _ _ _ . . _ _ . . 17 ACMPFjndjng.ofCon.si$lency.h_as been.i$.sued.fpr.this pr_oleçt . . . . _ _ . . . . NA . . . . _ _ . . . _ . . . . . . _ _ . . . . . . _ . Program DEV On/Off Shore On - - - - -- - 18 .C.o/1du.clor string.prQvided . . . . . _ . . . .NA . . . _ _ _ . . . . _ _ _ . . . . . _ _ . . . . _ . 19 .S_urf~c.eca$.ing protect$. ~lIknown. USDWs . . . . . . . . . _ . . .NA . . . . _ _ _ . . . . . _ _ . 20 .CMTv.oladequ.ate.to çirculate.o_n_cpnduçtor_& su.rf.C$g . . . . _ _ . . . . _ _ . . . _NA . . . _ _ _ . _ . . _ . . . . . _ _ . . 21CMTv_oladequ_ate.totie-[n/Qngstringto.surfC!'ig. . . . . _ _ _ . .. _ .. . . . . _ _ .NA _ _ . . _ _ . _ . ... _ . . . . _ . . 22 _CMTwill coyeraJl koo-"'lnpro.ductiYe bQri~on.s . . _ . . . . . . _ _ _ . . . _Y.es. _ . . . _ . . . . . _ . . . . . _ _ . 23 .C.asi/1g designs ~d.eQuate foc C,_T~ B&.permafr.ost . . . _ V~s. . . _ _ . . . . . . _ _ . 24 Adequatetankageorre.serve pit . . . . _ . . . . . _ . . . . _ . . _ . V~s . _ N~b.ors.2ES, _ . . . _ . . . . . _ _ _ . . . . _ . . 25 Jf.a_re-d(ill~ has a 10A03 fQr abandonment be~o approved _. .. _ _ . . . _ V.es. . . _ _ . . . _ _ _ . . . . . _ . . 26 Adequate.wellbore$.epar¡¡tjon.proposed.... _ . . . . . _ _ _ _ _ _ . _ . . _ . . . . . _ _ _ _ _ _ . V.es. . . . . . . . . . _ . . _ . . . . . . . . . _ . _ _ . . . . _ . . . . . _ . . . . _ . . . . . . . . . . _ _ _ _ _ . . 27 Jf.divecter required, dQes iLmeel reguJations. _ . . . . . . _ _ . . .NA . . Sidet(ack.. _ . . . . . _ _ . . . . . . _ . . . . _ _ . 28 .Drilliog fluid program schematic.& eq.uip /istadequale_ . . . . _ . . . . . . . _ _ . . V.es . _ . Max MW 1.1._5_ppg.. . . . . . _ _ . . . _ . . . . . . . _ . . . . _ _ _ 29 6PPES,do.theymeelreguJatipn _. .. _ ... . . _ _ _ . . _ Yes. . . _ _ . . . 30 .BPPEpressra.ti/1gappropriate;testlo_(putpsig[ncomments) _ _.... _ . V.es.. .Testto.3500.RS¡.MS~2380psi._. .... __ 31ChokemanifoldçQmpJie$.w/APJR~-53(May84L. ... _.. ... _ _. . V.es. ... _.. ..... _....... ...... 32 WQrk will OCCU( withputoperatjonshl!tdQwn. . _ . . . . . _ . . . . V.es _ . . . . _ _ . . . . . . _ . _ . . . _ _ . . . _ _ . 33 J$.Rre$.ençeQfH2Sg~s.probable ....... ... _ _. . N.o.. . Notan H2S pad.. ..... _.... _....... 34 Mecba.nicaLcood.itlonofwells w[thinJl.ORyerified (fpr.servjcewelJ 0 n/y) . . . _ NA . . _ . .. . . _ _ . . - - - - - - - - - - - - - - - - ~ - - - - - -- - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - e - - - - - - - - - - -- 35 P.ermil can be [sSl!ed wlQ hyd(ogen_ s.ulfide meas.u(es. . 36 .D.ata_preseoted on. pote.ntial pyerRre$.sure _ZQne$. _ . 37 _S~ismic_analysjs. Qf shaJlow gaszooes. . . . . _ _ . 38 .S.eabedconditioo Sl!rvey(if oft:-sh.oœ) . _ _ . 39 . CQnta.ct namelp]1onefor.weekly prpgress.reRorts [explQratory _only] . . . _ _ . . _ N.o NA NA. ..NA __ .NA - - - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - -- Geologic Commissioner: Date: Engineering Commissioner: ~ ~"e' j7:r/ ~ DJ;s Date ?/fJ!1- 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 infonnation. information of this nature is accumulated at the end of the me under APPENDIX. No special effort has been made to chronologically organize this category of information. $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 22 12:47:55 2005 ff(-/'Ie, tl )\ ~V( . . . Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/22 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. . . . . . . . . . , . . . . . . . . . .05/04/22 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 PBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-11B 500292065302 BP Exploration Sperry Drilling Services 22-APR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003242526 J. BOBBITT R. BORDES MWD RUN 3 MW0003242526 J. BOBBITT R. BORDES MWD RUN 4 MW0003242526 J. BOBBITT R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003242526 D. RICHARDSO R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 llN 14E 1997 1450 57.64 29.10 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 8.500 6.125 SIZE (IN) DEPTH (FT) 9.625 9620.0 7.000 10385.0 . # 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. THIS WELLBORE EXITS 15-11 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 9620'MD/7769'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. NO DATA ARE PRESENTED. 5. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). NO EWR DATA ARE INCLUDED FOR RUNS 3 & 4 DUE TO A TOOL MALFUNCTION. RUNS 4 & 5 INCLUDED AT-BIT INCLINATION (ABI) . RUN 4 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD) . 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN ON 3 OCTOBER 1981 IN THE 15-11 WELLBORE. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SIS/BP) VIA E-MAIL ON 6 APRIL 2005. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1 - 5 REPRESENT WELL 15-11B WITH API#: 50-029-20653-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12968'MD/8836'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 (SEDP). 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 SIZE: 6.125" BIT MUD WEIGHT: 8.4 PPG MUD SALINITY: 3000 - 4000 PPM CHLORIDES FORMATION WATER SALINITY: 10,994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name........ .... .STSLIB.001 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .05/04/22 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 ROP RPX RPS RPM RPD FET FCNT NPHI NCNT RHOB DRHO PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9435.5 9435.5 9594.0 9594.0 9594.0 9594.0 9594.0 10885.0 10886.0 10886.0 10899.5 10899.5 10899.5 STOP DEPTH 12900.5 12952.5 12907.5 12907.5 12907.5 12907.5 12907.5 11582.5 11582.5 11582.5 11597.0 11597.0 11597.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 9443.0 9464.5 9476.5 9497.0 9508.0 9511.0 9513.5 9522.0 9533.5 9539.0 9553.0 9561. 0 9589.0 9596.5 9603.0 9608.5 9621.0 12952.5 $ GR 9458.5 9480.5 9493.0 9513.0 9524.0 9526.5 9529.5 9537.5 9549.5 9554.5 9568.5 9576.5 9605.0 9612.5 9620.5 9625.0 9636.5 12968.0 . . # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 2 3 4 5 MERGE TOP 9451. 0 10385.0 10984.0 11686.0 MERGE BASE 10385.0 10984.0 11686.0 12968.0 # 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9435.5 12952.5 11194 7035 9435.5 12952.5 ROP MWD FT/H 0.49 1109.58 125.138 7035 9435.5 12952.5 GR MWD API 15.06 550.79 88.7503 6931 9435.5 12900.5 RPX MWD OHMM 0.69 1905.22 72.8118 4038 9594 12907.5 RPS MWD OHMM 0.65 1825.56 68.3918 4038 9594 12907.5 RPM MWD OHMM 0.59 2000 67.0333 4038 9594 12907.5 RPD MWD OHMM 0.58 2000 67.4879 4038 9594 12907.5 FET MWD HOUR 0.17 16.04 0.975936 4038 9594 12907.5 NPHI MWD PU-S 12.89 31.29 23.2724 1394 10886 11582.5 FCNT MWD CNTS 353 1431.7 614.813 1396 10885 11582.5 NCNT MWD CNTS 19882.8 39965.6 27724.3 1394 10886 11582.5 RHOB MWD G/CM 2.013 2.931 2.41396 1396 10899.5 11597 DRHO MWD G/CM -0.162 0.484 0.0414613 1396 10899.5 11597 PEF MWD BARN 1.21 6.96 2.47444 1396 10899.5 11597 First Reading For Entire File........ ..9435.5 Last Reading For Entire File.. ....... ..12952.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 . Date of Generation.... ...05/04/22 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... ... .05/04/22 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP GR RPD FET RPM RPS RPX $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 9451. 0 9451.0 9610.0 9610.0 9610.0 9610.0 9610.0 # 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: # STOP DEPTH 10385.0 10353.5 10345.5 10345.5 10345.5 10345.5 10345.5 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): 25 -AUG-04 Insite 66.37 Memory 10385.0 9620.0 10385.0 51.2 54.1 TOOL NUMBER 163686 157645 8.500 9620.0 LSND 11.50 49.0 9.4 1700 4.0 '" .. . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . 1.200 .630 1. 300 2.100 70.0 140.0 70.0 70.0 # 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 Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9451 10385 9918 1869 9451 10385 ROP MWD020 FT/H 2.26 1109.58 140.586 1869 9451 10385 GR MWD020 API 28.92 385.63 155.228 1806 9451 10353.5 RPX MWD020 OHMM 0.69 1905.22 5.84783 1472 9610 10345.5 RPS MWD020 OHMM 0.65 1825.56 6.99993 1472 9610 10345.5 RPM MWD020 OHMM 0.59 2000 14.8675 1472 9610 10345.5 RPD MWD020 OHMM 0.58 2000 32.0044 1472 9610 10345.5 FET MWD020 HOUR 0.25 2.3 0.756284 1472 9610 10345.5 First Reading For Entire File..........9451 Last Reading For Entire File.... ...... .10385 File Trailer Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation..... ..05/04/22 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...... .05/04/22 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 GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 10354.0 10385.5 STOP DEPTH 10931.5 10984.0 # 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): 27 -AUG- 04 Insite 66.37 Memory 10984.0 10385.0 10984.0 23.2 50.8 TOOL NUMBER 184054 159436 6.125 10385.0 FLO-PRO 8.40 60.0 9.8 3500 10.4 1.300 .670 1. 300 1. 200 70.0 142.0 70.0 70.0 EWR FREQUENCY (HZ): . . # REMARKS: $ # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type.....O Logging Direction....... ... .......Down Optical log depth units........ ...Feet Data Reference Point............. . Undefined Frame Spacing..... .......... ..... .60 .1IN Max frames per record. .......... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT Rap MWD030 GR MWD030 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10354 10984 10669 1261 10354 10984 Rap MWD030 FT/H 2.63 198.6 49.8896 1198 10385.5 10984 GR MWD030 API 16.01 550.79 66.1562 1156 10354 10931.5 First Reading For Entire File........ ..10354 Last Reading For Entire File..... ..... .10984 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ......05/04/22 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... ....05/04/22 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 FCNT 4 header data for each bit run in separate files. 4 .5000 START DEPTH 10900.5 STOP DEPTH 11598.0 NCNT NPHI PEF DRHO RHOB GR ROP $ . 10901.5 10901. 5 10915.0 10915.0 10915.0 10932.0 10984.5 11598.0 11598.0 11612.5 11612.5 11612.5 11633.5 11686.0 # 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 CTN ASLD EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Azimuthal Litho-Den 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.....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 . 28-AUG-04 Insite 66.37 Memory 11686.0 10984.0 11686.0 35.5 92.0 TOOL NUMBER 184054 110041 10508945 159436 6.125 10385.0 FLO-PRO 8.40 50.0 9.4 3500 8.2 1. 300 .740 1.300 1. 200 70.0 129.0 70.0 70.0 . . Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 NPHI MWD040 PU-S 4 1 68 12 4 FCNT MWD040 CNTS 4 1 68 16 5 NCNT MWD040 CNTS 4 1 68 20 6 RHOB MWD040 G/CM 4 1 68 24 7 DRHO MWD040 G/CM 4 1 68 28 8 PEF MWD040 BARN 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10900.5 11686 11293.3 1572 10900.5 11686 ROP MWD040 FT/H 0.52 352.33 55.349 1404 10984.5 11686 GR MWD040 API 15.06 157.44 71.2734 1404 10932 11633.5 NPHI MWD040 PU-S 12.89 31.29 23.2724 1394 10901.5 11598 FCNT MWD040 CNTS 353 1431.7 614.813 1396 10900.5 11598 NCNT MWD040 CNTS 19882.8 39965.6 27724.3 1394 10901. 5 11598 RHOB MWD040 G/CM 2.013 2.931 2.41396 1396 10915 11612.5 DRHO MWD040 G/CM -0.162 0.484 0.0414613 1396 10915 11612.5 PEF MWD040 BARN 1.21 6.96 2.47444 1396 10915 11612.5 First Reading For Entire File... ...... .10900.5 Last Reading For Entire File.......... .11686 File Trailer Service name..... ...... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/04/22 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...... .05/04/22 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 VENDOR TOOL CODE GR FET RPD 5 header data for each bit run in separate files. 5 .5000 START DEPTH 11634.0 11641. 0 11641. 0 STOP DEPTH 12916.0 12923.0 12923.0 . . RPM RPS RPX ROP $ . 11641. 0 11641.0 11641. 0 11686.5 12923.0 12923.0 12923.0 12968.0 # 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.....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 . 30-AUG-04 Insite 66.37 Memory 12968.0 11686.0 12968.0 89.1 93.7 TOOL NUMBER 62456 130910 6.125 10385.0 FLO-PRO 8.40 49.0 9.4 3500 7.9 1. 500 .810 1. 700 1. 500 70.0 136.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 A . . ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11634 12968 12301 2669 11634 12968 ROP MWD050 FT/H 0.49 393.68 187.183 2564 11686.5 12968 GR MWD050 API 31. 89 168.75 61.6821 2565 11634 12916 RPX MWD050 OHMM 18.45 232.78 110.954 2565 11641 12923 RPS MWD050 OHMM 22.12 192.9 103.334 2565 11641 12923 RPM MWD050 OHMM 26.12 167.34 97.4382 2565 11641 12923 RPD MWD050 OHMM 32.37 201.7 89.7925 2565 11641 12923 FET MWD050 HOUR 0.17 16.04 1.10147 2565 11641 12923 First Reading For Entire File......... .11634 Last Reading For Entire File....... ....12968 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/04/22 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/22 Origin.. ................ .STS Tape Name......... .......UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/22 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
