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
205-133
New Plugback Esets 7/24/2024 Well Name API Number PTD Number ESet Number Date CRU CD4-25 PB1 50-103-20608-70-00 209-150 T39276 2-6-2010 KRU 2T-29AL1-01 PB1 50-103-20222-70-00 209-138 T39277 4-6-2010 Nuna 1 PH 50-103-20645-70-00 211-155 T39278 4-18-2012 PBU 18-27D PB1 50-029-22321-70-00 205-133 T39279 10-26-2007PBU 18-27D PB1 50-029-22321-70-00 205-133 T39279 10-26-2007 s • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I 1 a. Well Status: ❑ Oil 0 Gas ❑ SPLUG 0 Other . 181 Abandoned 0 Suspended 1 b. Well Class 20AAC 25.105 20AAC 25110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ® Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., orAband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 10/11/2012 • 205 - 133 ' 312 - 327 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 09/18/2005 50 029 42321 - 04 - 00 • 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 09/26/2005 PBU 18 -27D • 893' FNL, 236' FEL, SEC. 24, T11N, R14E, UM • g. KB (ft above MSL): 53 15. Field / Pool(s) Top of Productive Horizon: 474' FSL, 3768' FEL, SEC. 13, T11N, R14E, UM GL (ft above MSL): 15,7' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD) Oil Pool 525' FSL, 76' FEL, SEC. 14, T11N, R14E, UM ' 12200' 8689' ' 4b. Location of Well (State Base Plane Coordinates, NAD : 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x 691522 ` y - 5960969 ' Zone ASP4 • 12200' 8689' ' ADL 028307 • TPI: x- 687957 y - 5962247 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 686368 y- 5962258 Zone- ASP4 None 18. Directional Surve 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): Y ❑Yes No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD DIR / GR 11641' 8669' 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" 91.5# H -40 Surface 110' Surface 110' 30" 2000# Coldset II 13 -3/8" 68# K -55 / L -80 Surface 3497 Surface 3497' _ 16" 2706 cu ft CS III, 460 cu ft Class 'G' 9 -5/8" 47# L -80 Surface 9069' Surface 8259' 12 -1/2" 2217 cu ft Class 'G' 7" 26# NT8OS 8829' 9827' 8110' 8618' 8-1/2" 398 cu ft Class 'G' 4-1/2" 12.6# L -80 8678' 11641' 8011' 8669' 3 -3/4" 832 cu ft Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6#, L -80 8684' 8629' / 7978' E C MS, a w 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. t� �� - - -. � -. WAS HYDRAULIC FRACTURING USED DURING COMPLETION? ❑Yes El No NOV 0 62.02- DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10302' Set Whipstock 8680' 4 -1/2" KB Liner Top Packer 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 9 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. SCANNED MAR 18 2013 None �DMS NOV tl� ! i.� is i Form 10-407 Revised 10/2012 CONTINUED ON REVERSE 3.3./3 �2 & ubn fin Only /! 29. GEOLOGIC MARKERS (List all formations arkers encounter 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No • Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 18 - 27D Kicked Off in the Sadlerochit None , / Zone 1B 10320' 8661' Formation at Total Depth: 31. List of Attachment: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: oy Jakaboskyy 68; jakato@bp.com Email: lastufjn @bp.com Printed Name: Jo astufk Title: Drilling Technologist / Signatur • Phone 564 -4091 Date: (� ! (0 /'1 Z., INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only • 1 18 -27D, Well History (Pre Rig Sidetrack) Date Summary 09/11/12 T /I /O = 2510/550/0. Conduct PJSM. Barriers = SV and SSV. Closed SSV and opened SV. Bled pressure off above SSV and performed LLT (passed). Closed MV and opened SSV. Bled pressure off above MV and performed LTT(passed). Closed SV and SSV, and opened MV. Removed tree cap and rigged up lubricator with 4" CIW 'H' TWC # 286 and 1 -1' ext. PT'd lubricator against SV to a low off 200 -300 psi. for 5 min.(passed) and a high off 3500 psi. for 5 min. (passed). Charted and documented. Shut SSV and SV and bled off pressure.Torqued all tree flanges to API specs. (see log for details). Rigged down lubricator and attached CIW 4" pulling tool. Rigged up lubricator and Pt'd (same steps as above) passed. Shell tested tree against TWC to 200 -300 psi low for 5 min. (passed) and 5000 psi. high for 5 min. (passed). Charted and documented. Pulled TWC, shut SSV and SV. Rigged down lubricator. PT'd tree cap to 500 psi. for 5 min. (passed). 09/13/12 CTU #9 1.75" Coil Tubing - Job Scope = Dummy Whipstock drift. MIRU, RIH w/ dummy whipstock drift 3.71" drift. stop at 10400' POOH. Well freeze protected with 38 bbls of 50/50 methanol. 09/16/12 T /I /O = 2540/530Nac. Temp = SI. Bleed IAP & OAP to 0 psi. (Pre CTD). Wellhouse and flowline removed. IA FL @ surface. Bled IAP from 530 psi to 0 psi in 30 minutes. (1 bbl fluid). Monitored for 30 minutes. IAP increased 6 psi. Job complete. Final WHP's = 2540/6Nac. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 15:30 hrs. 09/18/12 T /I /O = SSV /20/0. Temp = SI. WHPs(CTD Prep). No well house or flowline. No AL. IAP increased 14 psi since 9/16/12. SV, WV, SSV = C. IA, OA = OTG. 1400. 09/20/12 T /I /0 1100/0/55 Temp =SI Load tubing (pre CTD) Load tubing with 5 bbls meth, 293 bbls seawater. Freeze protect with 23 bbls 60/40 meth SV,WV,SSV= closed, MV =open, IA and OA =OTG. 09/21/12 T /I /0= 300/0/0 Conducted PJSM; Barriers= SV & SSV; Performed LTT on SV (passed); Installed Lubricator & P.T. (charted) to 300 psi /3500 psi (passed); Set 4" CIW "H" TWC @ 112" w/1 -1' ext.; P.T. (charted & downloaded into U- drive) TWC to 600 psi /3800 psi (Test pressure 300 psi higher then normal do to 300 psi tubing pressure). 09/21/12 T /I /O = SSVNacNac. Temp = SI. WHPs (Post L &K). IA has integral installed = inspection not current. Well has no flowline or well house. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 08:00. 09/23/12 T /I /0= 2540/0/0 Conducted PJSM; Barriers= SV & SSV; P.T. (charted) down on SV to 300 psi /3500 psi (passed); Installed lubricator & P.T. (charted) to 300 psi /3500 psi (passed); Pulled 4" CIW "H" TWC #278 @ 110" w 1 -1' ext. Page 1 of 1 • • -`^ � 1;, s ,'� k,,,,'a °'d t;4 a° t` =`'� = fi-':k :, a."' - '°: s,� '^..,:,',,''' w" ..a , ''P `r °'°5 =;;x„ ,�^°. .a,r ,.jr __ = w,,,�,o-. a °� *�:. �. - s: • Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 -01299 (2,713,188.76 ) X3- 01299 - C:DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/5/2012 06:00 - 09:30 3.50 MOB P PRE FINISH RIG MOVE CHECKLIST TASKS. HOLD PJSM ON MOVING RIG OFF OF WELL. ASSIGN SPOTTER POSITIONS, DISCUSS IMPORTANCE OF CLEAR, CONCISE COMMUNICATION AND GENERAL RIG MOVE HAZARDS. MOVE RIG OFF OF B-27 AND STAGE ON B-PAD. 09:30 - 12:30 3.00 MOB P PRE REMOVE T -MATS AND CONTAINMENT FROM AROUND B-27. CLOSE OUT WWT FOR B-27 WITH PAD OPERATOR. DRILLER AND TOOLPUSHER MAKE ROUTE DRIVE FROM B -PAD TO DS 18. 12:30 - 13:00 0.50 MOB P PRE HOLD PJSM ON MOVING RIG FROM B -PAD TO DS 18. REVIEW GENERAL RIG MOVE HAZARDS, SPECIFIC KNOWN HAZARD AREAS IDENTIFIED DURING ROUTE DRIVES, COMMUNICATION WITHIN THE RIG AND ALSO WITH SECURITY. ASSIGN PEOPLE TO POSITIONS. 13:00 - 19:00 6.00 MOB P PRE MOVE RIG FROM B PAD TO LISBURNE ACCESS STAGING AREA. AOGCC GIVEN 24 -HR NOTICE FOR 18 -27 BOPE TEST AT 1422 -HRS. AOGCC REP, CHUCK SCHEVE, LEFT MESSAGE AT 1427 -HRS WAIVING STATE'S RIGHT TO WITNESS THE BOPE TEST. 19:00 - 00:00 5.00 MOB P PRE WAIT AT LISBURNE ACCESS STAGING AREA FOR MATS TO FINISH BEING LAID ON DS 18 ACCESS RD. API VALVE SHOP INSTALL UN- TAPPED BLIND FLANGE ON COMPANION SIDE OF TREE. LO/TO L2 -21 WITH PAD OPERATOR FOR AC ISSUE. 10/6/2012 00:00 - 04:30 4.50 MOB P PRE WAIT AT LISBURNE ACCESS STAGING AREA FOR MATS TO FINISH BEING LAID ON DS 18 ACCESS RD. COMPLETE WELL WORK TRANSFER PERMIT WITH DS 18 OPERATOR. 04:30 - 07:15 2.75 MOB P PRE MOVE RIG DOWN LISBURNE ACCESS ROAD TO DS-18 ACCESS ROAD AND ON TO DS 18. 07:15 - 14:15 7.00 MOB P PRE WAIT FOR MATS TO BE LAID ON DS 18 TO WELL 18 -27. MOVE RIG DOWN BOARDWALK AND TURN TO SPOT RIG JUST IN FRONT OF WELL. 14:15 - 15:15 1.00 MOB P PRE HOLD PJSM ON SPOTTING RIG OVER WELL. DISCUSS EMERGENCY STOP, ASSIGN PEOPLE TO POSITIONS AND STRESS IMPORTANCE OF CLEAR COMMUNICATION. BACK RIG OVER WELL 18 -27 AND SHIM IN PLACE. 15:15 - 16:00 0.75 RIGU P PRE SPOT AUXILIARY EQUIPMENT. RU STAIRS & GERONIMO. 16:00 - 18:00 2.00 RIGU P PRE TAKE ON RIG WATER. CONTINUE SPOTTING AUXILIARY EQUIPMENT. CH2 REMOVING RIG MATS FROM DS 18 ACCESS RD. ACCEPT RIG AT 16:00 HOURS. Printed 10/15/2012 10:33:00AM Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 -01299 (2,713,188.76 ) X3- 01299 - C:DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 23:30 5.50 RIGU P PRE SPOT TIGER TANK, FUEL TRAILER AND SATELLITE CAMP. RIG UP HARD LINE TO TIGER TANK. MOUNT PROTECTIVE COVERS OVER ANNULUS VALVES AND SSV. TEST HARD LINES. 23:30 - 00:00 0.50 BOPSUR P PRE HOLD PJSM. PERFORM DUAL BARRIER LEAK TIGHT TEST ON SWAB, SSV AND MASTER - PASS. RIG UP TO CONTINUOUSLY MONITOR VOID BETWEEN SWAB AND SSV. 10/7/2012 00:00 - 00:30 0.50 BOPSUR P PRE PJSM. NIPPLE DOWN SWAB CAP. 00:30 - 02:00 1.50 BOPSUR P PRE NIPPLE UP BOP AND ASSOCIATED EQUIPMENT. 02:00 - 03:30 1.50 BOPSUR P PRE PJSM. INSPECT TOT ELEMENTS. REPLACE TOP SEAL ON VBRS & BLADE SEAL ON BSRS. ALL OTHER ELEMENTS APPEAR IN GOOD ORDER. 03:30 - 04:00 0.50 BOPSUR P PRE HOLD RIG EVACUATION DRILL. ALL PERSONEL EVACUATED IN THE PROPER DIRECTION IN RELATION TO THE WIND. EVERYONE ACCOUNTED FOR, SECURITY AND DS OPERATOR NOTIFIED. AAR SHOWED PERSONNEL FOLLOWED PROCEDURE, ACCOUNTING FOR THIRD PARTY PERSONNEL AND SIMULATING TURNING OFF EQUIPMENT AS NECCESSARY AND RESTRICTING ACCESS TO THE PAD. 04:00 - 07:00 3.00 BOPSUR P PRE FLOOD LINES AND BOP. ATTEMPT BODY TEST. DOOR SEAL & CHECK VALVE HOUSING LEAK. REPLACE DOOR SEAL & CHECK VALVE HOUSING SEAL. 07:00 - 13:00 6.00 BOPSUR P PRE BEGIN INITIAL BOPE TEST. TEST TO 250 -PSI / 3500 -PSI. HOLD AND CHART EACH TEST FOR 5, FLAT -LINE MINUTES. TESTS WITNESSED BY BP WSL & NORDIC TOOLPUSHER. AOGCC REP CHUCK SCHEVE WAIVED STATE'S RIGHT TO WITNESS AT 1427 -HRS ON 10/5/2012. PERFORM ACCUMULATOR DRAWDOWN TEST. FUNCTION BOPE FROM ALL STATIONS (RIG FLOOR, OPS CAB, ACCUMULATOR). TEST H2S AND LEL ALARMS - GOOD TEST. 13:00 - 14:30 1.50 RIGU P PRE HOLD PJSM ON FILLING COIL. PU INJECTOR AND MU NOZZLE TO COIL. OAL = 4.74'. STAB ON WELL AND FILL COIL WITH FRESH WATER AT 2 -BPM. FILL PIT 4 WITH FRESH WATER FOR ALL REMAINING TESTING / SLACK PUMPING. OBTAIN RKBS. IA / OA - 0 -PSI / 0 -PSI. 14:30 - 15:00 0.50 BOPSUR P PRE TEST INNER REEL VALVE & PACKOFF TO 250 -PSI / 3500 -PSI. HOLD AND CHART EACH TEST FOR 5 MIN FLAT LINE. TEST 2(EA) FOSV TO SAME CRITERIA. GOOD TESTS. Printed 10/15/2012 10:33:00AM y ',: ` � . �S s , ^ B x . ! may €4 : AFE No Common Well Name: 18 -27 Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 01299 (2,713,188.76 ) X3-01 299- C:DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 16:45 1.75 BOPSUR P TEST MANUAL LOCKS ON L PRE POSITION COIL 1' ABOVE SWAB VALVE. OWER COMBI RAMS, 2 -3/8" X 3 -1/2" VBRS AND UPPER COMBI RAMS. GOOD TESTS. 16:45 - 17:30 0.75 MOB P PRE WITH INJECTOR STABBED ON, REVERSE E -LINE SLACK INTO COIL. NOTICE EVIDENCE THAT PRESSURE BULKHEAD MAY BE LEAKING. TIGHTEN AND THEN RESUME REVERSE CIRCULATING. NO MORE LEAKS SEEN. SURGE PUMPS UP TO4 -BPM AND HEAR WIRE MOVING. 17:30 - 19:00 1.50 BOPSUR P PRE UNSTAB INJECTOR & TEST BSR MANUAL LOCKS. TEST TO 250 / 3500 -PSI. HOLD AND CHART EACH TEST FOR 5- MINUTES. GOOD TESTS. 19:00 - 20:00 1.00 BOPSUR P PRE PJSM FOR CUTTING COIL. MOUNT COIL CUTTER AND ESTABLISH LENGTH OF CUTS. CUT 290' OF COIL WITH NO CABLE EXPOSED. 20:00 - 20:30 0.50 BOPSUR P PRE MAKE UP COIL CONNECTOR AND PULL TEST TO 30K - PASS. 20:30 - 21:00 0.50 BOPSUR N SFAL PRE ATTEMPT TO PRESSURE TEST THE COIL CONNECTOR AND THE INNER PRESSURE BULKHEAD. BULKHEAD PACKOFF LEAKING. UNABLE TO STOP LEAK. DECISION TO CHANGE OUT BULKHEAD AND PACKOFF. 21:00 - 00:00 3.00 BOPSUR N SFAL PRE CHANGE OUT INNER PRESSURE BULKHEAD AND PACKOFF. ATTEMPT TO PRESSURE TEST INNER PRESSURE BULKHEAD - FAIL. CONSULT WITH CTS AND DECISION MADE TO TRY SMALLER PACKOFF FOR PRESSURE BULKHEAD. 10/8/2012 00:00 - 03:15 3.25 BOPSUR N SFAL PRE CHANGE OUT PACKOFFS ON INNER PRESSURE BULKHEAD. WAIT ONE HOUR FOR PACKOFFS TO SET UP. TEST COIL CONNECTOR AND INNER PRESSURE BULKHEAD TO 250 PSI LOW, 3800 PSI HIGH - PASS. 03:15 - 04:00 0.75 BOPSUR P PRE PUMP E -LINE FORWARD FOR HEADING UP TO BHI. BOPSUR P 04:00 05:15 1.25 PRE HEAD UP BHI AND TEST. 05:15 07:00 1.75 BOPSUR P PRE STAB INJECTOR AND TEST BHI CHECKS, LUBRICATOR AND QTS CONNECTION. DISPLACE COIL REEL WITH 1% KCL AT 3 -BPM. 07:00 - 08:45 1.75 BOPSUR P PRE HOLD PJSM ON PULLING TWC WITH DSM LUBRICATOR. REVIEW PRESSURE TESTING CRITERIA, SAFE EQUIPMENT HANDLING, AWARENESS OF WELLBORE PRESSURE. PU & RU LUBRICATOR. PRESSURE TEST TO 250 -PSI / 3500 -PSI FOR 5 -MIN PER TEST. GOOD TESTS. Printed 10/15/2012 10:33:00AM .xts -,.x r.7a i u . W x r , a . '" �'y* - : �" i pct € .�, VT— ,: .,.. X1 :. V,, r A c a r , J r .. }#` k; . '4r- 4 , p h .'' •3i :. + y e, n x 3 A b fi ; £` r t s ,r ; „ , `s . .s S °a” :.'� u'S s ¢ ` g v` te r A r ''` "' .� '' "*`".. � '' s ' 0 �;` �`�''�',�r xd � � ixs 7 � � � a" - ....�,,...., Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 -01299 (2,713,188.76 ) X3- 01299 - C:DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:45 - 10:00 1.25 BOPSUR P PRE ENGAGE TWC AND EQUALIZE - 2600 -PSI WELLBORE PRESSURE. PULL TWC. CLOSE MASTER VALVE, BLEED OFF PRESSURE TO TIGER TANK AND LEAK TIGHT TEST FOR 5- MINUTES. NO PRESSURE BUILD UP. CLOSE SSV AND LEAK TIGHT TEST FOR 5- MINUTES. NO PRESSURE BUILD UP. CLOSE SWAB VALVE. UNSTAB DSM LUBRICATOR & RD. LD LUBRICATOR AND TWC. 10:00 - 10:30 0.50 BOPSUR P PRE MU NIGHT CAP & PRESSURE TEST TO 250-PSI/ 3500 -PSI. HOLD AND CHART EACH TEST FOR 5- MINUTES. 10:30 12:00 1.50 BOPSUR P PRE HOLD PJSM ON BULLHEAD KILLING WELL. DISCUSS IMPORTANCE OF GOOD COMMUNICATION, PROPER VALVE ALIGNMENT AND PUMPING SCHEDULE AND FLUID MANAGEMENT IN THE EVENT OF EXCESSIVE LOSSES. PUMP 5 -BBLS MEOH SPEAR AT 1 -BPM / WHPSI = 2500 -PSI WHEN DONE. LINE UP AND BULLHEAD 250 -BBLS 8.4 -PPG 1% KCL AT 5 -BPM. INITIAL BULLHEAD PRESSURE AT 5 -BPM = 2430 -PSI. PRESSURE STEADILY DROPPING UNTIL 160 -BBLS AWAY (FLUID NEARING PERFS). CONTINUE TO BULLHEAD AT 5 -BPM, SEEING STEADY INJECTION AT 5 -BPM / 1750 -PSI WITH 225 -BBLS AWAY. BULLHEAD PRESSURE WITH 250 -BBLS AWAY = 1890 -PSI. IA / OA AT END = 260 -PSI / 0 -PSI. 12:00 - 14:00 2.00 BOPSUR P PRE MONITOR WELL. WELLBORE PRESSURE DROPS TO 0 -PSI. OBTAIN STATIC LOSS RATE OF 18 -BPH. EMPTY PIT #1 OF MUD AND FILL WITH 8.4 -PPG KCL. MONITOR WELL - LOSS RATE = 6 -BPH. FLOW CHECK, REMOVE NIGHT CAP AND OBSERVE FLUID LEVEL SLOWLY FALLING. BRING WHIPSTOCK TO RIG FLOOR WHILE MONITORING WELL. BTT REP MU WHIPSTOCK TO BE RIH. IA / OA = 180 -PSI / 70 -PSI AT START, 0 -PSI / 40 -PSI AT END. 14:00 - 14:30 0.50 WHIP P WEXIT HOLD PJSM ON PU & RUN WHIPSTOCK. DISCUSS POSITIONS OF PEOPLE, WHIPSTOCK HANDLING, AND WELL CONTROL CONSIDERATIONS. MU WHIPSTOCK RUNNING BHA. BHA CONSISTS OF WHIPSTOCK, J-HYD SETTING TOOL, XO, HOT, DGS, DPS, EDC, P &C, WEAR SUB, LQC, UQC, XO, CTC. OAL = 79.26'. 14:30 - 15:00 0.50 WHIP P WEXIT STAB ON INJECTOR. TEST QTS TO 250 -PSI / 3500 -PSI. HOLD EACH TEST FOR 5- MINUTES. OPEN EDC & ESTABLISH CIRCULATION AT .32 -BPM / 60 -PSI. OUT RATE _ .17 -BPM. LOSS RATE = 8 -10 BPH. Printed 10/15/2012 10:33:00AM - - r a r., �i k ., i { i .v{ V I9, li:itigaligjfSz.attfaitoifqwitvvfv_ evagaigNauack c Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 -01299 (2,713,188.76 ) X3- 01299 - C:DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB ©53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 15:45 0.75 WHIP P WEXIT RIH WITH WHIPSTOCK. CONTINUE TO CIRCULATE AT .3 -BPM. AT START, IA / OA / PVT = 0 -PSI / 10 -PSI / 109 -BBLS. 15:45 - 17:30 1.75 WHIP N DPRB 2,540.00 WEXIT INCREASE IN OUT RATE WHILE RIH. SHUT DOWN AND FLOW CHECK - WELL FLOWING. SHUT IN WELL. NOTIFY CTD FIELD SUPT AND ODE. MONITOR PRESSURES AND DEVELOP PLAN FORWARD TO STRIP IN & SET WHIPSTOCK, THEN KILL WELL WITH MUD. ISICP = 200 -PSI. FSICP PRIOR TO STRIPPING IN WELL= 377 -PSI. 17:30 - 18:15 0.75 WHIP P WEXIT STRIP IN WELL WITH WHIPSTOCK FROM 2540' TO 6100' MONITOR SICP CONTINUOUSLY VIA CTDS SCREEN. ISICP = 381 -PSI. FSICP = 546 -PSI. 18:15 - 00:00 5.75 WHIP N DPRB 6,100.00 WEXIT WAIT UNTIL RECIEVE APPROVED OCN FROM ODE. EMPTY PIT #1 AND #4 OF 8.4 -PPG 1% KCL & FILL WITH 8.6 -PPG POWERPRO MUD. MONITOR WELL PRESSURES. SICP FROM 634 PSI TO 1315 PSI. MOVE COIL DOWN 100' FOR FREEZE PROTECT MANAGEMENT. 10/9/2012 00:00 - 02:00 2.00 BOPSUR P WEXIT OPERATION CHANGE NOTE SUBMITTED AND APPROVED TO PROCEED WITH PACKER WHIPSTOCK TO SETTING DEPTH OF 10,300' MD. RIH AT 80 FPM WITH A STARTING PRESSURE OF 1700 PSI SICP. DOWN WEIGHT 10.5K. RIH TO 9100' AND LOG TIE -IN WITH A "0" CORRECTION. RIH TO 10,400' MD WITH 1900 PSI SICP. LOG FROM 10,100 TO 10,400 FOR COLLAR LOCATOR. 02:00 - 03:00 1.00 WHIP P WEXIT PULL UP TO 10,300' MD, UP WEIGHT 44K, DOWN WEIGHT 13K. SICP AT 1900 PSI. RUN DOWN TO 10,316' MD TO PUT WHIPSTOCK IN COMPRESSION FOR SETTING. TOP OF WHIPSTOCK PLACED AT 10,300' MD. ORIENTATION AT 92 DEGREES RIGHT OF HIGH SIDE. CLOSE EDC BRING PUMPS ON AT 0.4 BPM. PUMP A TOTAL OF 2.8 BBLS FLUID AND PRESSURE UP TO 1700 PSI COIL PRESSURE AND 1485 PSI DIFFERENTIAL PRESSURE AND OBSERVE SHEAR OF PACKER WHIPSTOCK, ENERGIZING PACKER SLIPS. SET DOWN 7K ONTO PACKER TO CONFIRM SET. PICK UP TO SHEAR OFF OF PACKER WHIPSTOCK AT 13 -15K OVER NO OBSERVABLE RELEASE AT 57K. STOP AND DISCUSS OPTIONS. DECIDE TO BRING PUMPS BACK ON LINE TO CHECK SHEAR. BRING PUMPS ON AT 0.4 BPM AND PUMP 2.8 BBLS WITH PRESSURE AT 800 PSI VERIFYING SHEAR. ATTEMPT TO PULL UP AND SHEAR OFF OF PACKER. PULL TO 70K AND APPEARS TO BE DRAGGING UP HOLE. STOP AT BIT DEPTH OF 10,300' MD WHICH PUTS TOP OF WHIPSTOCK AT 10,284' MD. STILL 9' BELOW NEXT UPPER COLLAR. SLACK OFF TO 58K SHUT DOWN Printed 10/15/2012 10:33:00AM �. �v" .r r l sa -y m,a .'fi € r r * � i ` ` ' h .. ,,, s . ,• .? , . .,n'S T 3 1 # . . c , c: geS "s r �` d 1 4 ' s ' � r k 0004-,,,,,,-,,.,.,„„ r 3 > •r f� s� '' ` ,.�s i�ypr y { .. � st�,I " ��S.s� �'S �^�^ > r` A �„ y c: °.� � -. � ' b`� ��3,7�A m'n f f e g g L` .a . a �, 'c s"' Ope ` tion uirna [� t ' y s „r r - s t „4,104,g,'„, . . e h r ` ,a '` „,, ,` ^' �; �.. i q .sx” - f ,*R.' r , ` , k . r ` r"'r Fe i`,a'r` ..., t; � w, s '+ � � '�.� r, . ,,A §, sm V '. ...,_ -5''''''''Y'''':''''''''''''''''''''''''''''' ',.� r. `,.�- ..° Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 -01299 (2,713,188.76 ) X3- 01299 -C: DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB ©53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 16:40 13.67 WHIP N DPRB 10,284.00 WEXIT WAIT ON APPROVAL OF PLAN TO CIRCULATE OUT GAS. SICP AT 1875 PSI. PUMP 1 -BBL OF MUD INTO COIL EVERY HOUR AT .3 -BPM / 100 -PSI. 1115 -HRS: NOTIFY AOGCC OF WELL SHUT IN VIA PAGER. AOGCC REP CHUCK SCHEVE RETURNED CALL AND WAS MADE AWARE OF CURRENT SITUATION. CTD SUPT SUBMITTED BOPE USAGE FORM TO AOGCC. 16:40 - 16:55 0.25 WHIP N DPRB 10,284.00 WEXIT APPROVED OCN HAS BEEN SENT, HOLD PJSM WITH CREWS TO BH KILL WELL PUMP DOWN COIL TO LOAD WITH MUD WHP =1810 PSI 16:55 - 17:30 0.58 WHIP N DPRB 10,284.00 WEXIT MOVE IN KCL TRUCK WHILE DISPLACING COIL TO MUD 17:30 - 17:42 0.20 WHIP N DPRB 10,284.00 WEXIT COIL DISPLACED AND UP THE BACKSIDE TO THE PERFS WITH MUD, LINE UP BOTH PUMPS DOWN THE BACKSIDE TO BH KILL WELL STARTING WHP = 1900 PSI PVT = 234 BBLS 17:42 - 18:00 0.30 WHIP N DPRB 10,284.00 WEXIT START BH KILL DOWN THE BACKSIDE 5 BBLS INTO THE KILL WE ARE AT MAX WHP AT 3000 PSI. SHUT DOWN PUMPS AND MONITOPR PRESSURE PRESSURE IS VERY SLOW TO BLEED OFF CALL ODE 18:00 - 19:00 1.00 WHIP N DPRB 10,284.00 WEXIT WHP HAS BLED DOWN 120 PSI IN 20 MIN, WO ORDERS FROM TOWN. 19:00 - 19:30 0.50 WHIP N DPRB 10,284.00 WEXIT TOP UP PITS AND MOVE TRUCKS TO SAFE AREA. NOTIFY PAD - OPERATOR & BP RADIO BEFORE COMMENCING GAS VENTING OPS. 19:30 - 20:00 0.50 WHIP N DPRB 10,284.00 WEXIT HOLD PJSM FOR GAS VENTING OPS. STRAP TIGERTANK (15BBLS). 20:00 - 22:00 2.00 WHIP N DPRB 10,300.00 WEXIT BLEED OFF PRESSURE FROM BACKSIDE: INITIALLY SEE 2,676PS1 SIWHP/ 1,220PSI SICTP. BLEED OFF — 250PSI AND SEE 2,390PS1 SIWHP/ 1,205PSI SICTP.SHUT -IN COIL TUBING PRESSURE IS DECREASING ONLY SLIGHTY. CONTINUE BLEEDING DOWN TO 1,859PSI SIWHP/ 1,113PSI SICTP. RE -STRAP TIGER TANK AND CONFIRM THAT NO LIQUIDS WERE RECEIVED THROUGHOUT BLEEDING. 22:00 - 23:00 1.00 WHIP N DPRB 10,300.00 WEXIT DISCUSS WAY FORWARD WITH TOWN. DECIDE TO CIRCULATE OUT GAS WITH 125BBLS MUD (ANNULUS VOLUME 100BBLS), TAKING RETUNS INTO TIGER TANK. 23:00 - 00:00 1.00 WHIP N DPRB 10,300.00 WEXIT ATTEMPT CIRCULATING OUT GAS APPLYING DRILLER METHOD: INITIAL CIRC PRESSURE: 864PSI/ 1,652PSI SIWHP. PUMP IN TOTAL 7.4BBLS AND SEE 3,000PSI CIRC PRESSURE / 1,685PSI SIWHP. UNABLE TO CIRCULATE DOWN COIL. STOP OPERATIONS SUSPECTING BLOCKAGE IN COIL - TUBING ANNULUS. Printed 10/15/2012 10:33:00AM r� rota . ' :4,FV ` . ,rg n; : : , . 47 ' -A T '17 °"SV* 0.-> s ' re r ... s r p z ;,41 � . t , . 4 x "` %.; r 1 4 .itorittr - WV-MtAitS:I N ra Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 -01299 (2,713,188.76 ) X3- 01299 - C:DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/10/2012 00:00 - 00:15 0.25 WHIP N DPRB 10,284.00 WEXIT ATTEMPT TO REVERSE CIRCULATE; APPLY 200PSI ON BACKSIDE THUS INCREASING PRESSURE FROM 1,650PSI TO 1,850PSI. CANNOT OBSERVE ANY CHANGE IN PRESSURE AT BHA ON DPS (ANNULAR PRESSURE REMAINS AT 5,380PSI, BORE PRESSURE REMAINS AT 5,370PSI). INDICATION FOR COIL BEING PACKED OFF ABOVE BHA. 00:15 - 01:00 0.75 WHIP N DPRB 10,284.00 WEXIT DISCUSS WAY FORWARD WITH CTD SUPERINTENDENT AND CREWS. DISCUSS POSSIBILITY OF BEING TRAPPED BY SHALLOW HYDRATE PLUG. 01:00 - 01:50 0.83 WHIP N DPRB 10,284.00 WEXIT HOLD PJSM, WAIT FOR SLB SERVICE QUALITY COACH TO COME OUT TO RIG AND PREPARE FOR FREE -POINT CALCULATIONS. 01:50 - 02:00 0.17 WHIP N DPRB 10,284.00 WEXIT SLACK OFF CT WEIGHT TO -1.5K LBS, THEN PICK UP WEIGHT TO 44K LBS. SEE 0.6FT STRETCH AND CALCULATE FREE POINT TO BE AT 626'. INCREASE PUW WHEN COIL APPEARS TO GET FREE AGAIN. IMMEDIATELY ATTEMPT FORWARD CIRCULATION, HOWEVER UNABLE TO ESTABLISH CIRCULATION. SEE CIRC PRESSURE = 3,100PSI / SIWHP = 1,620 PSI. 02:00 - 03:00 1.00 WHIP N DPRB 10,284.00 MANAGE TO ESTABLISH INJECTION OF - 0.25BPM AT 3,100PSI CIRC PRESSURE - INTO UPPER PERFS? TRY TO INCREASE INJECTIVITY BUT HAVE TO LIMIT SURFACE PRESSURE TO AVOID DAMAGING WHIPSTOCK PACKER (RESTRICT DOWNHOLE - ANNULAR PRESSURE TO -6,300PSI TO KEEP DIFFERENTIAL PRESSURE ACROSS PACKER <3,200P51). RE -DO RFEE POINT CALCULATION AND CONFIRM FREE POINT AT 650'. 03:00 - 04:00 1.00 WHIP N DPRB 10,284.00 CALL TOWN ODE AND DECIDE TO ATTEMPT WARMING UP COIL AND MELTING HYDRATE PLUG BY PUMPING DOWM COIL INTO UPPER FORMATION. CALL OUT FOR LRS PUMP TRUCK TO BE ABLE TO FOR HEAT UP MUD TO 160DEG F - LRS IS TRYING TO FIND TRUCK. 04:00 - 05:00 1.00 WHIP N DPRB 10,284,00 WEXIT LRS CALLS BACK. PUMP TRUCK WILL BE ONLY AVAILABLE AROUND SHIFT - CHANGE. 05:00 - 05:15 0.25 WHIP N DPRB 10,284.00 WEXIT PUMPRATE HAS INCREASED TO - 0.55BPM AT 3,080PSI CIRC PRESSURE AND 1,685PSI SHUT -IN PRESSURE. 05:15 - 06:00 0.75 WHIP N DPRB 10,284.00 WEXIT PICK UP TO 76K LBS ON COIL WEIGHT INDICATOR - WEIGHT IS VERY SLOWLY DROPPING OFF TO 74K LBS INDICATING SOME MINOR MOVEMENT. SLACK OFF COIL BACK TO 37.5K LBS AND CONTINUE PUMPING. PUMPRATE AT - 0.55BPM AT 3,062PSI CIRC PRESSURE AND 1,699PS1 SHUT -IN PRESSURE. 06:00 - 06:30 0.50 WHIP N DPRB 10,284.00 WEXIT PUMPRATE AT -0.75 BPM AT 2,966PS1 CIRC PRESSURE AND 1,729PSI SHUT -IN PRESSURE. Printed 10/15/2012 10:33:00AM M ow �� ° �`p R v , a q f f • ! a x t a s x' a a„ c :. t v x t o =q t r �'""_ ��' # q �' ,� " ` . = �' ,aa i: .. .M Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3-01299 (2,713,188.76 ) X3- 01299 - C:DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 09:00 2.50 WHIP N DPRB 10,284.00 WEXIT WO LRS TO HEAT UP DRILLING MUD TO PUMP HOT MUD DOWNHOLE TO THAW ICE PLUG AND ESTABLISH CIRCULATION STARTING MUD TEMP AT 60° 09:00 - 10:30 1.50 WHIP N DPRB 10,284.00 WEXIT MUD TEMP AT 100° 10:30 - 11:00 0.50 WHIP N DPRB 10,284.00 WEXIT MUD IS AT 150 °, HOLD PJSM TO CONTINUE MOVING FOWARD WITH OCN #3 WHP = 2000 PSI 11:00 - 11:10 0.17 WHIP N DPRB 10,284.00 WEXIT LRS HAS MUD TO 160 °, RIG DOWN VAC TRUCK AND MOVE TO THE RIG TO PUMP HOT MUD DOWN HOLE 11:10 - 11:35 0.42 WHIP N DPRB 10,284.00 WEXIT START PUMPING NEAT METH DOWN TUBING X CT ANNULAS STARTING WHP = 2161 PSI CTP = 2700 PSI MWD ANN/BORE PSI = 5741/5782 3 -4 BBLS METH PUMPED AND WHP HAS CLIMBED TO 2400 PSI I 5.5 BBLS METH PUMPED WHP = 3000 PSI SHUT DOWN TEST PUMP CTP = 2700 PSI MWD ANN/BORE PSI = 5745/5789 PSI 11:35 - 12:10 0.58 WHIP N DPRB 10,284.00 WEXIT START 160° MUD DOWN HOLE "STARTING PRESSURES WI-/CT = 3051/2706 PSI MWD ANN/BORE = 5742/5785 PSI INCREASE RATE TO 1 BPM CT PSI = 2980 PSI 12:10 - 12:20 0.17 WHIP N DPRB 10,284.00 WEXIT 160° MUD DOWN HOLE to 1700' PRESSURES WH/CT = 3563/2955 PSI MWD ANN/BORE = 5814/5875 PSI 12:20 - 12:30 0.17 WHIP N DPRB 10,284.00 WEXIT 50 BBLS AWAY AND WHP IS STARTING TO DROP FROM 3590 PSI 12:30 - 12:50 0.33 WHIP N DPRB 10,284.00 WEXIT 60 BBLS AWAY INCREASE RATE TO 1.5 BPM AT 3200 CT PSI WHP = 3400 PSI COME ONLINE WITH TEST PUMP WITH NEAT METH WH/CT = 3423/3193 PSI MWD ANN/BORE = 5842/5933 PSI 12:50 - 13:05 0.25 WHIP N DPRB 10,284.00 WEXIT EVERYTHING LOOKS STABILIZED PUMPING DOWN THE CT AND BACKSIDE, PU TO SEE IF WE ARE FREE PICKED UP 1' AND WT LEVELED OFF AT 27K, PU ANOTHER 1.5' CLEAN PU 20' CLEAN, CONTINUE POOH AT 1 FPM STAYING BELOW 8750' (BOTTOM PUT RIVER PERF) 13:05 - 13:50 0.75 WHIP N DPRB 10,284.00 WEXIT LINE UP TO TAKE RETURN OUT TO THE TIGER TANK MAINTAINING <150 PSI DOWNSTREAM OF THE CHOKE STARTING WHP= 3300 PSI IA & OA = 427 PSI & 270 PSI REDUCE PUMP RATE TO 0.5 BPM BHP = 5700 PSI 13:50 - 15:00 1.17 WHIP N DPRB 10,284.00 WEXIT WHP = 2765 PSI BHP = 5460 PSI IAP = 648 PSI OAP = 461 PSI 15:00 - 15:40 0.67 WHIP N DPRB 10,284.00 WEXIT GETTING SOME FLUID BUT MOSTLY GAS, CONTINUE TAKING RETURNS TO TT UNTIL RETURNS CLEAN UP 15:25 RETURNS HAVE CLEANED UP A LITTLE BUT DENSITY IS SHOWING METH OR DIESEL Printed 10/15/2012 10:33:00AM 44', 44K SW,,ec +� t^ ""*"- � c `" ax � .a a JO' rte * _# " . ` t ` +� *,; ^ :�..,.. _. 55 5f ,. �..re,,.ms.. z. ,.: °"� Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 -01299 (2,713,188.76 ) X3- 01299 -C: DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:40 - 15:45 0.08 WHIP N DPRB 10,284.00 WEXIT RETURNS ARE CONSISTENT, CHECK RETURNS FOR MUD. RETURNS LOOK LIKE THINNED OUT MUD, LINE UP TO MGS AND BRING RETURNS INSIDE SENT 10 BBLS TO CUTTINGS BOX AND WE ARE KEEPING THE RETURNS 15:45 - 16:05 0.33 WHIP N DPRB 10,284.00 WEXIT GOOD MUD AT THE SHAKER, ZERO OUT MM, INCREASE RATE TO 2.5 BPM AND CIRC 125 BBLS HOLDING —100 PSI CHOKE 16:05 - 16:50 0.75 WHIP N DPRB 10,284.00 WEXIT POOH TO 8900' WHILE CIRC BOTTOMS UP +25 BBLS AS PER THE OCN 16:50 - 17:05 0.25 WHIP P WEXIT BOTTOMS UP WAS CLEAN AT 100 BBLS 125 BBLS AWAY, LINE UP TO NORMAL FLOW PATH TO FLOW CHECK WELL 17:05 - 19:10 2.08 WHIP P WEXIT GOOD NO FLOW CHECK, COME ONLINE TO CHECK LOSS RATE. ZERO LOSSES. LINE UP TO MGS AND POOH FOR WINDOW BHA 19:10 - 19:45 0.58 WHIP P WEXIT FLOWCHECK WELL. ACHIEVE GOOD NO FLOW. 19:45 - 20:30 .7 L BHA #1. BTT HYDRAULIC SETTING TOOL IS 0 5 WHIP P WEXIT D LOOKING OKAY, NO MARKS OR ANY REASON FOR CONCERN. 20:30 - 20:45 0.25 STWHIP P WEXIT STAB ON INJECTOR AND CIRCULATE TO FILL UP HOLE - HOLE FULL. 20:45 - 21:45 1.00 STWHIP P WEXIT LINE UP TEST -PUMP, CLOSE SWAB VALVE AND CONDUCT PRESSURE -TEST ON HCR / PACK -OFF'S AND DFCV'S TO 3,500PS1 / 5MINS. ACHIEVE GOOD TEST. 21:45 - 22:20 0.58 STWHIP P WEXIT OPEN SWAB VALVE AND VERIFY THAT HOLE IS STILL FULL. POP OFF INJECTOR. MU BHA #2 WITH 3.80" DIAMOND WINDOW MILL. DRIFT WINDOW MILL WITH GAUGE -RING (3.80" GO / 3.79" NO -GO) AND VERIFY STRING MILL'S OD (3.79" GO / 3.78" NO -GO). 22:20 - 23:00 0.67 STWHIP P WEXIT STAB ON INJECTOR AND PRESSURE -TEST QTS TO 300PSI / 5MINS AND 4,000PSI / 5MINS. 23:00 - 00:00 1.00 STWHIP P WEXIT RIH WITH BHA #2. PVT = 305BBLS. 10/11/2012 00:00 - 00:40 0.67 STWHIP P WEXIT CONTINUE RIH TO 9,050' (DO NOT OBSERVE ANY LOSSES WHILE RIH. 00:40 - 01:05 0.42 STWHIP P WEXIT LOG FOR TIE -IN AND APPLY -0.5FT DEPTH - CORRECTION. 01:05 - 01:30 0.42 STWHIP P WEXIT TAKE SCR'S BEFORE COMMENCING MILLING OPS: PUMP #1: PUMP #2: 2.6 BPM - 2,531 PSI - 72 SPM2.6 BPM - 2885 PSI - 71 SPM 1.0 BPM - 2,522 PSI - 45 SPM1.0 BPM - 1,527 PSI - 44 SPM 0.5 BPM - 1,300 PSI - 23 SPM0.5 BPM - 1,326 PSI - 20 SPM 01:30 - 01:50 0.33 STWHIP P WEXIT "DRY -TAG" TOP OF WHIPTSTOCK @ 10,302'. PU 10FT, BRING PUMPRATE TO 2.6BPM AND RE -TAG TOP OF WHIPSTOCK AT 10,301.60' Printed 10/15/2012 10:33:00AM 4 ,� ,w, :- ,� . s i - °` ' s � �� ,0, - :t A l , '7 4 ` w k' Common Well Name: 18 -27 AFE No a Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: X3 -01299 (2,713,188.76 ) X3-01 299 -C: DRI LL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) 1 i Date From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (ft) 01:50 - 04:45 2.92 STWHIP P WEXIT COMMENCE WINDOW MILLING OPERATION 1 11 1 ( 1 (31 . BY TIME - MILLING AT 1 FT /HR. NOTICE ig)-21E STEADILY INCREASE WOB AS MILL IS \ GETTING END 1,60' 2 GAGE 531 PSI . CIRC NO PRESSURE STALLS OCCUR. (FREESPIN = 2, = IAA = 552PSI / OA = 165PSI - 2,552PSI CIRC PRESSURE, 0.70K LBS WOB 10,303.00' - 2,629'PSI CIRC PRESSURE, 2.08K LBS WOB 04:45 - 05:30 0.75 STWHIP P WEXIT 10,303.80' - 2,480'PSI CIRC PRESSURE, 2.19K LBS WOB NOTICE SUDDEN OCCURRENCE OF LOSSES OF NEARLY 50% FOR A BRIEF PERIOD. LOSSES QUICKLY HEAL UP TO —10% (- 0.25BPM). 05:30 - 06:00 0.50 STWHIP P WEXIT 10,303.80' - 2,593'PSI CIRC PRESSURE, 2.71K LBS WOB, PVT = 325BBLS, IA = 833PSI / OA = 515PSI MILL AHEAD WITH <10BBLS /HR LOSSES. 06:00 - 06:30 0.50 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW 06:30 - 07:30 1.00 STWHIP P WEXIT MILLING WINDOW FREE SPIN = 2460 PSI DIFF PSI = 180 PSI WOB = 2.84 K PVT = 318 BBLS 07:30 - 08:00 0.50 STWHIP P WEXIT MILLING WINDOW FREE SPIN = 2460 PSI DIFF PSI = 80 PSI WOB = 2.16 K PVT = 315 BBLS LOSSES —3 BPH 08:00 - 08:15 0.25 STWHIP P WEXIT MILLING WINDOW FREE SPIN = 2460 PSI DIFF PSI = 135 PSI WOB =2.41 K PVT = 314 BBLS LOSSES —2 BPH GETTING GOOD METAL ON MAGNETS 08:15 - 09:15 1.00 STWHIP P WEXIT MILLING WINDOW FREE SPIN = 2460 PSI DIFF PSI = 60 PSI WOB = 2.85 K PVT = 314 BBLS LOSSES —2 BPH 09:15 - 10:05 0.83 STWHIP P WEXIT MILLING WINDOW FREE SPIN = 2460 PSI DIFF PSI = 50 PSI WOB =1.23 K PVT = 311 BBLS LOSSES —2 -3 BPH GETTING A LITTLE FORMATION BACK 10:05 - 10:30 0.42 STWHIP P WEXIT MILLING WINDOW FREE SPIN = 2460 PSI DIFF PSI = 40 PSI WOB =0.7 K PVT = 3310 BBLS LOSSES —1 BPH 10:30 - 11:00 0.50 STWHIP P WEXIT 600# DROP IN WOB, THIS IS THE CALCULATED BOTTOM WINDOW, WINDOW LENGTH = 8.9' ALLOW STRING MILL TO DRESS OFF BOTTOM OF WINDOW BEFORE APPLYING WT TO DRILL RAT HOLE 11:00 - 11:45 0.75 STWHIP P WEXIT INCREASE ROP TO DRILL RAT HOLE IAP = 957 PSI OAP = 699 PSI 11:45 - 12:00 0.25 STWHIP P WEXIT RAT HOLE DRILLED, BACKREAM AT 1 FPM 12:00 - 12:20 0.33 STWHIP P WEXIT BACK REAM IS CLEAN, DOWN REAM AT 1 FPM BLEED OA DOWN FROM 700 PSI TO 400 PSI SAMPLE FROM 10311' ALL SAND 12:20 - 12:35 0.25 STWHIP P WEXIT DOWN REAM WAS CLEAN, PU FOR LAST UP REAM PASS 12:35 - 12:45 0.17 STWHIP P WEXIT DRY DRIFT IN BOTH DIRECTIONS Printed 10/15/2012 10:33:00AM LA North America - ALASKA - BP Page 11 t-b .,r. -. Operation Summary Report -" Common Well Name: 18 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/24/2012 End Date: 1X3 -01299 (2,713,188.76 ) X3- 01299 - C:DRILL Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/11/2012 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 18 -27E New RKB @53.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:45 - 12:55 0.17 STWHIP P WEXIT DRY DRIFTS ARE CLEAN, FLOW CHECK WELL AND POOH 12:55 - 14:15 1.33 STWHIP P WEXIT GOOD NO FLOW CHECK, POOH PUMPING AT MAX RATE THROUGH EDC PVT = 304 BBLS 14:15 - 14:20 0.08 STWHIP P WEXIT STOP POOH TO CLEAN OUT MM 14:20 - 14:50 0.50 STWHIP P WEXIT PJSM TO LD BHA 14:50 - 15:00 0.17 STWHIP P WEXIT FLOW CHECK WELL 15:00 - 15:30 0.50 STWHIP P WEXIT GOOD NO FLOW CHECK POOH AND LD WINDOW BHA 15:30 - 15:45 0.25 STWHIP P WEXIT BHA OOH, MILLS GAUGED 3.80" GO 3.79" NO GO CHECK TREE BOLTS 15:45 - 16:10 0.42 DRILL P PROD1 TREE BOLTS ARE TIGHT, MU THE BUILD BHA 16:10 - 18:15 2.08 DRILL P PROD1 MU INJECTOR TO THE BHA AND RIH 18:15 - 20:30 2.25 DRILL P PROD1 START LOG FOR TIE -IN ONWARDS FROM 9,010'. 20:30 - 20:45 0.25 DRILL P PROD1 STOP LOGGING AT 9,201' - NO DEPTH - CORRECTION NECESSARY. CONTINUE RIH. 20:45 - 21:00 0.25 DRILL P PROD. TAKE SCR'S: PUMP #1: PUMP #2: 2.6 BPM - 2,375 PSI - 108 SPM2.7 BPM - 2,450 PSI - 113 SPM 1.0 BPM - 1,400 PSI - 42 SPM1.0 BPM - 1,440 PSI - 44 SPM 0.5 BPM - 1,228 PSI - 22 SPM0.5 BPM - 1,225 PSI - 20 SPM 21:00 - 21:15 0.25 DRILL P PROD1 RIH TO BOTTOM. 21:15 - 22:00 0.75 DRILL P PROD1 COMMENCE DRILLING FROM 10,321' WITH ROP = 55 FPH, WOB = 0.8K LBS AND CIRC PRESSURE = 2,703PSI AT 2.6 BPM (FREE SPIN = 2,461 PSI AT 2.60 BPM). PVT = 297 BBLS, NO LOSSES. MW IN = 8.50 PPG / MW OUT = 8.52 PPG / ECD = 9.81 PPG IAP = 457 PSI / OAP = 17 PSI 22:00 - 22:50 0.83 DRILL P PROD1 NOTICE LATERAL (XY) VIBRATION UP TO "4 ". BLEED OFF IA FROM 700PSI, SEE -2BBLS DIESEL COMING BACK. 22:50 - 23:45 0.92 DRILL P PROD1 CONDUCT WIPER -TRIP TO WINDOW. MEANWHILE ADJUST GAMMA RAY- DISPLAY AND ALSO VERIFY L2 -21A ELLIPSES ON TRAVELLING CYLIDNER -PLOT WITH ODE. 23:45 - 00:00 0.25 DRILL P PROD1 CONTINUE DRILLING AHEAD. 10/12/2012 00:00 - 01:55 1.92 DRILL P PROD1 DRILLING AHEAD FROM 10,407'. DRILL THROUGH 14N -SHALE WITHOUT GREAT COMPLICATION. ROP = 88 FPH, WOB = 1.2K LBS AND CIRC PRESSURE = 2,717PSI AT 2.6 BPM. PVT = 292 BBLS. MW IN = 8.53 PPG / MW OUT = 8.59 PPG / ECD = 9.91 PPG IAP = 177 PSI / OAP = 298 PSI 01:55 - 02:20 0.42 DRILL P PROD1 2ND 150' WIPER TO WINDOW Printed 10/15/2012 10:33:00AM TREE = 4-1/16" FMC • WELLHEAD= FMC SAFE OTES: WELL ANGLE> 70° @ 9830 "*` ACTUATOR = BAKER C 1 8-27 Li INITIAL WELLBORE, SIDETRACK "A" AND "B" NOT KB. ELEV = 53.35' SHOWN BELOW MILLOUTt 9827' BF, ELEV KOP = 4000' Max Angle 97' @ 11055' Datum MD - NIA 0 2223' — 4 -1/2" CAMCO BAL -O SSSVN, ID = 1812" Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD 7 DEV TYPE VLV LATCH PORT DATE 1 2986 2986 1 MMK3 DMY RK 0 05/15/12 13 CSG. 68 #, L - 80, ID = 12.415" ' ( � 849 n 11, 2 5308 5198 28 MMG DMY RK 0 05/15/12 3 7260 6898 29 MMG DMY RK 0 08/18/05 4 8439 7839 42 MMG DMY RK [ 0 08/18/05 4-1/2" TBG 12.6 #, L -80, .0152 bp€ , ID .= 3.958" 8629' g 8629' 9 - /8" X 4 - 1/2' BKR S - PKR, ID = 3.875" Minimum ID = 2.377" @ 11745' 1 I-1 8662' — 14- 1 /2 " HES X NIP, ID= 3813" 3-1/2" X 2 -718" LNR X0 8678' — TOP OF BKR TIEBACK SLV, ID = 7.50" 8683' — 4-1/2" TTP, 12.6#, L -80, .0152 bpf, ID = 3.958" C 8684' 4-1/2' WLEG ID = 3.958" • 8684' 9 -5/8" X 7" BKR ZXP PKR, ID = 6.30" NN 8692' __ 9 -5/8" X 7' BKR HMC LNR HGR, ID = 6.25" 8699' — 7" X 4-1/2" XO. ID = 3.937" l N 8829' — TOP OF TM/ TIEBACK SLEEVE 8838' I- 9 -5/8" X 7" TMV S -6 PKR 9 - 5/8" GSG, 47 #. L - 80, ID= 8.681" — 1 9075' ■ 8842' — 19 - 5/8" X 7" TM/ DTH-S LNR HGR I 9204' H4 HES X NIP, ID = 3.813" 7" LNR, 26 #, NT80 NSCC, .0383 bpf , ID = 6.276" — 9827' 7" LNR MILLOUT WINDOW (18 -27A) PERFORATION SUMMARY ' 9827-9850' (WHIPSTOCK NOT SHOWN) REF LOG: SWS MEMORY GR/CCL ON 10/04/00 ANGLE AT TOP PERF: 48 @ 8710' 10008' HI4 - 1/2" HES X NIP, ID = 3.813" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8 6 8 ?10 - 8750 0 03/21 /05 I 11500' _, 4-1/2" WED CIBP (02/23/09) I 3 -3/8 6 10860 - 10940 0 02/25/09 4-1/2" LNR MILLOUT WINDOW ___----- 11641' - 11647' (18 -27D) 4 -1/2" LNR, 12.6 #, L -80, IBT, ID = 3.958" H 11641' 11650' H RA TAG [4 -1/2" WFD LSX/N WHIPSTOCK — j 11641' 4 -1/2" CIBP 11682' 4-1/2" LNR MILLOUT WINDOW 12266' - 12278' (18 -27C) 1 4-1/4" x 3 -3/4" OPENHOLE - 12200' DATE REV BY COMMENTS DATE REV BY ' COMMENTS PRUDHOE BAY UNIT 02123193 ORIGINAL COMPLETION 03/03/09 SRB /SV SET CIBP/ADPERF (02/25/09) WELL: 18 -27D 04/11198 RIG SIDETRACK (18 - 27A) 03/19/09 NSISV FINAL DRAFT CORRECTIONS PERMIT: 2051330 11101198 CTD SIDETRACK (18 -27B) 03129/12 PJC DRAWING CORRECTIONS AR No: 50- 029 - 22321 -04 10/18100 CTD SIDETRACK (18 -27C) 05/16/12 JRP /JMD GLV C/O (05/15/12) SEC 24, T11 N, R14E, 893' SNL & 236' WEL 09128105 NORDIC1 CTD ST SUSPENDED (18 -27D) 03/08/07 CJN/PAG GLV C/O BP Exploration (Alaska) • • .P3& I —7-76 Zb5 1330 Regg, James B (DOA) From: Burnett, Richard D [burnr8 @BP.com] Sent: Tuesday, October 09, 2012 11:40 AM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Daniel, Ryan; Kilfoyle, Jeffery A; Allen, Kenneth W; Egbejimba, Uchenna J; McMullen, John C; Reem, David C; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft); Willingham, James M; Sarber, Greg J; Yeager, Kevin E; Jakabosky, Troy; Barker, Abbie; Igtanloc, Mark L Subject: BOPE Usage Report for 18 -27D 10 -8 -2012 Attachments: BOPE Usage Report for 18 -27D 10- 8- 2012.doc Jim, Attached please find the BOPE usage form for well 18 -27D. Please let me know if I can answer any questions or if you need any further clarification. Thanks, Rich Rich Burnett Operations Superintendent RWO /CTD scANNED APR " _. ZD1 +1 (907) 659 -5329 (Office - slope) +1 (907) 748 -5821 (Cell Phone) Harmony 2157 Alternate: Greg Sarber 1 . • • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: Abbie Barker Contact Number: 659 -5329 Contact Number: 659 -4564 / 4433 Traction Number: pending Well Location /Name & Rig Name: PBU 18 -27D / Nordic 1 Permit To Drill (PTD) Number: 2051330; Sundry # 312 -317 as window is not milled yet Date and Time of Incident: 10/8/12 at 1545 -hrs Original Scope of Work: Kill well, Set whipstock, Mill window, Drill pilot hole, Sidetrack well in Z1 Operational Description Leading up to Well Control Event: Kill well & begin RIH with whipstock. BOPE Used and Reason: Flow observed with pumps off. Shut in well against choke HCR & CT Packoff. Is a BOPE Test Required after use ( Yes / No): Yes If no, why? 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Kill well, Confirm status of whipstock. POH with whipstock running tools. Retest BOPE used Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bay a(�,alaska.dov Email CC List Well Integrity Team Leader: Ryan Daniel HSE Advisor: Jeff Kilfoyle Engineering Team Leader: Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager: Steve Rossberg Wells Intervention Manager: Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC Rev 1 September 1, 2010 • • SIMICE A[LASEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader t ' 33 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18 -27D Sundry Number: 312 -327 Dear Mr. McMullen: �` AUG Z 1� Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 Daniel T. Seamount, Jr. Commissioner 5 DATED this 3 day of August, 2012. Encl. •, STATE OF ALASKA � 1 / ° " RECEIVED ALA OIL AND GAS CONSERVATION COM SSION AUG 2 2 2012 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon ® Plug for Redrill , ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 205 - 133 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22321 -04 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18 - 27D Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028307 - 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): 12200' " 8689' • 12200' 8689' 11500' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3497' 13 -3/8" 3497' 3497' 3450 1950 Intermediate 9069' 9 - 5/8" 9069' 8259' 6870 4760 Production Liner 998' 7" 8829' - 9827' 8110' - 8618' 7240 5410 Liner 3588' 4 - 1/2" 8678' - 11641' 8011' - 8669' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8710' - 8750' (Put River) / 11641' - 12200' 8033' - 8059' / 8669' - 8689' 4 12.6# L - 8684' Packers and SSSV Type: 9 -5/8" x 4 -1/2" Baker 'S - packer Packers and SSSV 8629' / 7978' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory r_ Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 27, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Troy Jakabosky, 564 -4868 Printed Name John Mc,' 1,41 AOI Title Engineering Team Leader Prepared By Name /Number: Signature 010 foi r / / Phone 564 -4711 Date 2..///2 Joe Lastufka, 564 -4091 Commission Use Only Conditions of a.• roval: Notify Commission so that a representative may witness I �.32� / Sundry Number: ❑ Plug Integrity EJ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: a3.5 / 13 7 e ? / ma c ` • /�/ h its! 5/7 re' it_ ✓ el r ? G�/ t CL f U Subsequent Form Required: APPROVED BY (13)/) Z proved By COMMISSIONER THE COMMISSION Dat 1.e i :•`' rS• Mel 1 zoia V _ Submit In Duplicates t u r' g OR!G!N.AL g .a , I L •01400144__;e5 � • • , To: Alaska Oil & Gas Conservation Commission From: Troy Jakabosky CTD Engineer 0 bP Date: August 20, 2012 Re: 18 -27D Sundry Approval Sundry approval is requested to abandon existing perforations on well 18 -27D in preparation for a Coiled Tubing Drilling Sidetrack. 18 -27D is a CST drilled in Sept 2005 as the most recent leg of a multi- sidetrack development from the 18 -27A wellbore. The previous CST, 18 -27C, was chosen as the appraisal well to test the Put River Northern Lobe. A plug was set at 9204' and 40' of Put River perfs (8710'- 8750') were shot in March 2005. Subsequently, it was decided to proceed with the 18 -27D coil sidetrack with the intention of producing a Zone 1A target with the Put River perfs isolated behind a liner tie -back. The 18 -27D CST was suspended due to a combination of coil fatigue, a thin LOC, and bad weather. The well presently has about -500' of open hole in the Ivishak this is commingled with the previously shot Put River perfs. The well was tested in April 2007 and produced at high GOR. 18 -27D remained shut -in. In Feb 2009, a CIBP was set to isolate the open hole section and 80' of good quality Z1A was shot back in the original 18 -27A section of the well. Unfortunately, the well only produced gas and was shut -in. 18 -27D has remained shut -in since mid 2010. 18 -27D is not a competitive producer due to a high GOR, and there are no remaining well work options. The proposed sidetrack will access reserves in a -70 acre Zone 1A target in north western DS 18. • The well is in sound mechanical condition. It passed an MIT -IA to 3000 psi (May 2012). The PPPOT -T passed to 5000 psi (November 2011). The sidetrack, 18 -27E, is scheduled to be drilled by Nordic 1 starting on September 10 2012 targeting Ivishak Zone 1A. The pre rig work includes service coil whipstock drift, Load and Kill, and set TWC. The coiled tubing drilling rig Nordic 1 will then set whipstock and mill the window in Z1A. Nordic 1 will drill a planned 1,015' plug back into BSAD and define the Zone 1A target interval. Nordic 1 will then set a aluminium billet and drill the lateral in Zn 1A with 12 DLS. The well will be completed with 2-7/8" x 3-1/4" solid, cemented, and perforated liner. The following describes the planned work. A schematic diagram of the proposed sidetrack is attached for reference. / 60A, P m ° 416t5 494. L otter. ! t� f � � Qh 0/ /ttaier q064 4. 144/�!� ©; PC ,f�rl�f 14e pft q °Q'SO /f 1 • , CTD Sidetrack Summary Pre -CT Rig Work: The pre CTD work is planned to begin August 21, 2012. 1. C Run Dummy Whipstock Drift down to -10,400 MD. 2. V PT tree (MV,SV,WV) Bleed wellhead pressures down to zero. 3. 0 Bleed production flow lines and GL lines down to zero and blind flange. 4. 0 Remove wellhouse, and level pad. 5. F Load and Kill -24 hrs prior to rig arrival 6. V Set TWC (CIW 4 ") -24 hrs prior to rig arrival Rig Sidetrack Operations: (Scheduled to begin on September 10 2012 using Nordic Rig 1) 1. MIRU ,4, ti 6i, / 16 e ir)5pr—e-ioc 24 hrs j?! i f 2. NU 7 -1/16" CT Drilling BOPE and test T t 5 t 13 t i fl-c. 3 /'s' 3. Set 4 -1/2" KB Packer Whipstock at 10,300 MD at 92 ROHS 4. Mill 3.8" sin • le strin • window in the 4 -1/2" liner at 10 300'. 5. Drill with 4.25" Bi- Center bit 1,015 ft(12° /100) in Zone 1A to a PBTD of 11,315' MD. p431 6. Set aluminium billet at 10,845. 7. K/O billet and drill lateral with 3.75" bit 2,340ft (12° /100) in Zone 1A to TD of 13,185' MD. 8. Run and cement 2 -7/8 "x 3 -1/4" liner leaving TOLITOC @9,600 ft with 31 BBLS cement. C /If t w" 9. Run 3 -1/4 tieback and LTP to 8670' MD. Test to 2400 psi. / % D 10. Perform cleanout/MCNL log run with mill, motor. 11. Perforate well ( -800' planned) 12. Freeze protect well to 2500' MD. 13. Set BPV. ND 7- 1/16" BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. 14. RDMO Post -Rig Work: 1. Pull BPV. 2. Set generic GLV's 3. Flowback and well test Troy Jakabosky Coiled Tubing Drilling Engineer 564 -4868 CC: Well File Sondra Stewman!Terrie Hubble 2 TREE= 4- 1/16" FMC • WELLHEAD = FMC SAF NOTES: WELL ANGLE > 70° @ 9830' & > ACTUATOR = BAKER C 1 8-271) 90° @ 10104'. ORIGINAL 18 -27 WELLBORE NOT KB. ELEV = 53.35' SHOWN BELOW 7" LNR MILLOUT WINDOW @ BF. ELEV = NA 9827' (18 -27A); 18 -27B NOT SHOWN. KOP = 4000' Max Angle = 97 @ 11055' Datum MD = N/A W I 2223' H 4 -1/2" CAMCO BAL -O SSSVN, ID = 3.812" I Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH PORT DATE 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3497' I 1 2986 2986 1 MMG DOME RK 16 03/08/07 E 2 5308 5198 28 MMG SO RK 20 03/08/07 3 7260 6898 29 MMG DMY RK 0 08/18/05 4 8439 7839 42 MMG DMY RK 0 08/18/05 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf , ID = 3.958" H 8629' g I 8629' I-I 9 -5/8" X 4-1/2" BKR S -3 PKR, ID = 3.875" Minimum ID = 2.377" @ 11745' 1 I I 8662' H 4 -1/2" HES X NIP, ID = 3.813" I 3-1/2" X 2 -7/8" LNR XO 8678' H TOP OF BKR TIEBACK SLV, ID = 7.50" I 8683' HI 4 -1/2" TTP, 12.6 #, L -80, .0152 bpf, ID = 3.958" I ' ` I 8684' H 4 -1/2" WLEG, ID= 3.958" 8684' H 9 -5/8" X 7" BKR ZXP PKR, ID = 6.30" I NNI 8692' H 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" I 8699' H l 7" X 4-1/2" XO, ID = 3.937" I J 8829' H TOP OF TNV TIEBACK SLEEVE I 8838' H 9 -5/8" X 7" TM/ S -6 PKR 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9075' I I ■ 8842' 9 -5/8" X 7" TM/ DTH -S LNR HGR 7" LNR, #, , , ID = 6.276" — I 9827' I i I 9204' 4 -1/2" HES X NIP, ID = 3.813" I 7" LNR MILLOUT WINDOW (18 -27A) PERFORATION SUMMARY 9827' -9850' (WHIPSTOCK NOT SHOWN) REF LOG: SWS MEMORY GR/CCL ON 10/04/00 f i , - r' t I ANGLE AT TOP PERF: 48 @ 8710' 0 ' 10008' H 4 -1/2" HES XNIP, ID = 3.813" Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 8710 - 8750 O 03/21/05 11500' H 4 -1/2" WFD CIBP (02/23/09) I 3 -3/8" 6 10860 - 10940 0 02/25/09 4 -1/2" LNR MILLOUT WINDOW ,----" 11641' - 11647' (18 -27D) 4 -1/2" LNR, 12.6#, L-80, IBT, ID = 3.958" I 11641' I 11650' H RA TAG I 4 -1/2" WFD LSX/N WHIPSTOCK I 11641' 4 -1/2" CIBP H 11682' 4-1/2" LNR MILLOUT WINDOW 12266' - 12278' (18 -27C) I 4 -1/4" x 3 -3/4" OPENHOLE H 12200' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/23/93 ORIGINAL COMPLETION 03/03/09 SRB /SV SET CIBP /ADPERF (02/25/09) WELL: 18 -27D 04/11/98 RIG SIDETRACK (18 -27A) 03/19/09 NS /SV FINAL DRAFT CORRECTIONS PERMIT: '`1051330 11/01/98 CTD SIDETRACK (18 -27B) API No: 50 -029- 22321 -04 10/18/00 CTD SIDETRACK (18 -27C) SEC 24, T11N, R14E, 893' SNL & 236' WEL 09/28/05 NORDICI CTD ST SUSPENDED (18 -270) 03/08/07 CJN /PAG GLV C/O BP Exploration (Alaska) NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM V14 ILL I 7 -1 /16" 5000 psi BOP's ID = 7.06" W5 V11 (]1116 "5000 psi, RXA6 � Transducers Q a'I I 1 ° I ' •ORB• 1 GASSE V2 I V7 V 16 ' 1111 a roi0e M.". Not typical BOP '� r g nt for 2316" , : W Crlll � ! a ; I 7 1/16 psi, Rxi6 I ` rt V17 �i I I I IC IK OK To Poor Boy Gas Buster . 4I m�acmw I . =. CI V18 V79 • .._Lg l e 1■1/ 2 1116" 5000 psi , Rx -20 I • 3.00" 5000 psi HCR IIIIIIIIIIIIIIIPIVINal ■ L .... 23/eVau in." .r. 2- 1116 "500076, CHECK VALVE Manual Choke xr••e �� ToT ws �' �. ' 71/16 Cameron FOV Gate I Valve a 5000 psi t i l l i— EOH /Diesel • • i 134? FP Line -- CoFlex Hose ' M otion - - 114 Turn Hales ` O 10WOG To Production Tree or Cross Over • T •res a transducers CoFlex Hose CV11 1I0 O CV12 To Coiled Tubing Bleed Off _ Inner Reel Valve we E - ®- "."."- w - f N13 _ - Cement Line In Ground Level Tie -in I CV10 a'+ -t CV3 CV2 T Stand Pipe ,,,,,, - ss!_. -- —: = - - Manual Choke Pressure Transducers;: CV9 CV17 11 � T Motion „ Mill= CV II Ai Tiger Tank Mud Pump 2 ins . � � _ . _ In From III O Baker MP 1 a MP 2 1 . _ - B NB Choke (J O CV14 to Pits Rig Floor Mud Pump N1 0 CV16 Reverse Ci - l • l.- _ —_ Cir CT whsle OOH ....... EM _ - - 0 • To Manifold CV15 1- Jun -2010 gov <r.o rir.•r,Iatje.. IGw / CT W+ilw OOH CoFlex Hose • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 33 'p, __ __.____ 3~ ~L~ ~~~ T~AIUS/1~`AL 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 E>~loration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastutka iR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive_Diagnostie Sewices,. Inc. tAttn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1) Coil Flag 2) Signed Print Name: 22-Feb-Q9 18-27D t `,. n r ~~f i , ~~ 1 i' ~ ''-~____...__ f` 7- '~- EDE 50-029-22321-04 - ~ , i :. ,LL Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (90n?A5-8951 FAX: (907)245-88952 E-MAIL: ,a`Ji3~~i1y7??3- B~rStr~x'3t'~l~C~''.ii;i'3 YvEB51TE:.~3`;ti.~";3£'if'sa~s"=t~~~j.C',3s~'! ~ C:\Documenffi and Settings\Oacmer\Desktop\Tcansmit_BP.docx i"- STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMA~ION REPORT OF SUNDRY WELL OPERATIONS EIV~® . LIAR 4 6 2009 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ ~ j ~ther ~r ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver BT'ir~ie~k>~h~r~~~~• fIIISSIOfI Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended~~aj}Q 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r Exploratory r 205-1330 3. Address: P.O. Box 196612 StratigraphlC r Service ]~ 6. API Number: Anchorage, AK 99519-6612 50-029-22321-04-00- 7. KB Elevation (ft): 9. Well Name and Number: 53.7 KB ' PBU 18-27D - 8. Property Designation: 10. Field/Pool(s): _ ADLO-028307 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: °~ Total Depth measured 12200 - feet Plugs (measured) 11500' 2/23/09 true vertical 8635 feet Junk (measured) None Effective Depth measured 12200 ' feet true vertical 8635 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 3496 13-3/8"68# L-80 31 - 3497 31 - 3497 3450 1950 Interrnediate 9067 9-5/8" 47# L-80 32 - 9069 32 - 8259 6870 4760 Liner 998 7" 26# NT-80 8829 - 9827 8110 - 8618 7240 5410 Liner 6588 4-1/2"12.6# L-80 8678 - 11641 8011 - 11588 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 8683' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X7" BKR ZXP PKR 8684' 9-5/8"X7" TIW S-6 PKR 8829' 0 0 0 0 12. Stimulation or cement squeeze summary: ~,,~; . ~ y,,, f , n r } Intervals treated (measured): +~~.~~,~.-~ ~t~~~ ~ ~~JLi 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: SI Subsequent to operation: 14. Attachments: 15. WeII Class after proposed work: Copies of Logs and Surveys Run Exploratory I~°' Development (~ . Service Ir Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ ~ Gas ~ WAG r GINJ r WINJ ~ WDSPL 1! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 3/6/2009 Form 10-404 Revis~d 04/2006 ~ f r~, r ~~ ~'f~ j~~ ~3' \ Submit Original Only ~_ 18-27D 205-133 PERF OTTO[:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18-27D 9/15/05 OH 11,641. 12,200. 8,668.57 8,688.53 18-27D 9/15/05 PER 8,710. 8,750. 8,032.89 8,059.07 18-27D 2/23/09 APF 10,910. 10,940. 8,692.65 8,692.78 18-27D 2/23/09 BPS 11,499. 11,500. 8,665.65 8,665.68 18-27D 2/24/09 APF 10,880. 10,910. 8,691.29 8,692.65 18-27D 2/25/09 APF 10,860. ~/ 10,880. 8,689.89 8,691.29 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 • • 18-27D DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIV'ITYDATE,h< _ . ,.. ~ ~ ` ~~ r ~°~, `~' ~ ~ ~> ~ '~ , ~=~~~ :: .., ... ~.< ~ ..Y 2/21/2009 CTU #9, Set CIBP/Pertorate; Road CTU to location. Spot CT Unit. Cont' on WSR 02/22/09 .., 2/22/2009 CTU #9, Set CIBP / Perf; Cont' from WSR 2/21/09 ... MIRU CT #9. SIWHP = 2460 psig. Load and kill well with 1%KCL. MU and RIH with PDS memory GR/CCL inside 2.375" carrier w/ 3.64" JSN/drift. POOH to resolve electronic depth problems. Lay down tools and stand back lubricator. Encoder is good. Depth disparity problem appears to be due to new pack-off harmonic interference with encoder, a little known problem. RIH with memory GR/CCUdrift to11,570' ctmd. PUH logging. Flagge3 p~pend 10900'. POOH with logging tool. Cont' on WSR 2/23/09 ... 2/23/2009 CTU #9, Set CIBP /Pert; Cont' from WSR 2/22/09 ... At surtace recovered good data (made +5' correction to memory GR/CCUCNL dated (22-Sept-2005). M/U WDF 4 1/2" CIBP. Load and kill well with 1%KCL. RIH w/WDF 4 1/2" CIBP. Correct depth at flag and set CIBP with center of element at 11,500' (Ton of CIBP 11499' . POOH. RIH with SWS 30' - 3.375" Power Jet guns loaded at 6 spf. Correlate depth at flag and CIBP. Pertorate interval 10910' to 10940'. PUH, unable to move pipe. Indications are that production tubing is frozen around coil. Free point calculations show stuck depth at approx. 2600'. Still possible to inject down coil. Pump hot KCLm down coil .Pulled CT free and POOH. Hung up at 2,655'. Line up LRS to pump hot crude down lA. Cont' on _~____ WSR 2/24/2009 ... 2/23/2009 _ T/I/0=2100/1400/0 Temp=S1 Assist CTU #9 (ADPERF) RU to IA, pressure test surtace equipment *** Job continued on 2-24-09 WSR*** 2/24/2009 CTU #9, Set CIBP /Pert; Cont' from WSR 2/23/09 ... < InterACT not publishing> Pump hot crude down Inner Annulus. Shut down LRS due to increase on IA pressure. Swap to 60/40 meth down the back side and confirmed communication to perfs. Work coil free and continue POOH. At surface all shots fired and ball recovered. MU and RIH with Gun #2 - 30' SWS 3.375" PJ34 loaded at 6 spf. Correlate depth at CIBP due to excessive coil stretch noted at flag (-25'). PUH and attempt to perforate interval 10880' to 10910'. POOH. Gun #2 did not fire. Re-head and RBIH with Gun #2. Tag and correlate depth at top of CIBP. PUH and oerforate interval 10880' to 10910'. POOH. At surtace. g n fired and ball recovered. MU and RIH Gun #3 - 20' SWS 3.375" i PJ3406 loaded at 6 s f. Cont' on WSR 2/25/09 ... • • 2/24/2009 *** Job continued from 2-23-09 WSR*** Assist CTU #9 (Perfs) Pumped 5 bbls meth, 94 bbls 190*F crude down IA to thaw hydrates/ ice in Tbg. Final WHP's= 2025/1960/0. l CTU on well at time of departure, IA open to gauge. 2/25/2009 CTU #9, Set CIBP/ Perf; Cont' from WSR 02/24/09 ... <InterACT not publishing> Continue RIH with Gun #3. Tag and correlate depth at top of CIBP. PUH and perforate interval 10860' to 10880'. POOH. At surface, gun fired and ball recovered. Line up LRS to pump down IA to ensure IA is not frozen. Loaded IA with an additional 125 bbls of crude and topped off with 10 bbls of 60/40. IA appears to be in communication with the tubing and free of ice. The E________.. ____ production tubing is loaded with 60/40. RD CTU. *** Job Complete *** _ FLUIDS PUMPED BBLS 129 CRUDE 582 1 % KCL 318 60/40 METH 1029 TOTAL a '"", • • WELL LOG TRANSMITTAL To: State of Alaska November 12, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 18-27D PB1 AK-MW-3940183 1 LDWG formatted CD rom with verification listing. API#: 50-029-22321-70 ~~~~ Q~~ ~ ~ ~~Q~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 -- ; a ~:~. _ ~, D~a~e: Signed: ~y.~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 18-27D PB1 November 12, 2007 AK -MW -3940183 1 LDWG formatted CD rom with verification listing. API#: 50-029-22321-70 SCANNED DEC 1 1 2007 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 i1 x 1j/ i � # -i m Date: Signed: _ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051330 Well Name/No. PRUDHOE BAY UNIT 18-27D Operator BP EXPLORATION (ALASKA) INC MD 12200 TVD 8689 Completion Date 9/27/2005 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-22321-04-00 UIC N .~"`~~~-~ REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR Well Log Information: Log/ Electr Data Digital Dataset Tvpe Med/Frmt Number Name Samples No Directional Survey Yes /" (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Ston CH Received Comments ~.tD D Asc Directional Survey 11624 12200 Open 10/26/2005 IIFR D D Asc Directional Survey 11624 13445 Open 1/9/2006 PB 1 og Neutron 25 Blu 1 9450 11855 4/25/2006 Memory CNL in Carrier Memory i~ GR/CCL/CNL/Carrier 22- I Sep-2005 C Pds 13857 neutron 25 1 9450 11855 4/25/2006 Memory CNL in Carrier I Memory ', GR/CCL/CNL/Carrier 22- Sep-2005 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y N Chips Received? -~`~Pd•~ Analysis ~~ Received? Comments: ~~ ~ ay I P Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? V N Formation Tops ~ N Date: s • ~a ~_ by Date 10-12-2007 Transmittal Number:92914 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv auestions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 02-126 aa~--~,~ ~~~5'~l~_~_-. 02-16C ~~-_2~.~__~1s.~c.~1 __ ____. 02-16CP61 ap ~--~$~... ~.lS7ef9 _ 02-18~~~ Al., A.t~T~ 15-16B ~_- c~33---tS6.~-L_~. 15-16BP61 __~~~~_~~ 15-166.PB2 a~L~ ~~~ -~~s, 18-27DP61- _-a0~_13?z__ ~_Sl~~-- --_.____ _____-- A-42A_---o%~2fo_-/3.U___IS~o?~___ _ ._..___.._._.__.. G-24A c?6G - 0~2_._~ ~ ~_._. G-24APB1 a-Ulo_-~~-2..,_.!~~c.-..___~____.___ P2-11APB1 _a(U(o.--c~.g_!o_.._~~b3..4_....______...r_. P2-36A __~Sc._- .Qa-a._ 15'3/-.._ .__....._. . P2-37A aOS=-,DSO- __. lf-_~S__lo3a _. -102PB - ~ Pz Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 - _ ~~,~.~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 AnchoraDe, AK 995 1 9-66 1 2 • ~~ -~, SARAN PAL1N, GOVERNOR .'a ~L[>•-7~A Oay ~ ~-7 333 W. 7th AVENUE, SUITE 100 C011TSERV~~`I011T COI~IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Nancy Hibbert FAX (907) 276-7542 P.E. BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 18-27D Sundry Number: 307-060 Dear Ms. Hibbert: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of February, 2007 Encl. Sincerely, / ~~ ®cr ~~ ~ Z` 1~51'ATE OF ALASKA ~~~ f~, CU ~ ~ V ~~~ ALA OIL AND GAS CONSERVATION COMMIS~"foN FHB ~ 2 0 ~'1 APPLICATION FOR SUNDRY APPROVAL~~f'3 2 07 20 AAC 25.280 ArBS~(8 Di! & Gas COtIS. Comrnlissinn 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Al1C~tOfBg~ther Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Q ' Exploratory ^ 205-1330 3. Address: P.O. Box 196612 6 Stratigraphic ^ .Service ^ . API Number: Anchorage, AK 99519-6612 50-029-22321-04-OOi 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: 18-27D ~ Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028307 ~ 53.7 KB ~ PRUDHOE BAY Field / PRUDHOE 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): 12200 8689 12200 8635 None None Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 30' 110' 30' 110' 1490 470 Surface 3496' 13-3/8" 68# L-80 31' 3497' 31' 3197' 3450 1950 Intermediate 9067 9-5/8" 47# L-80 32' 9069' 32' 8259' 6870 4760 Liner 998' 7" 26# NT-80 8829' 9827' 8110' 8618' 7240 5410 Liner 3588' 4-1/2" 12.6# L-80 8678' 11641' 8011' 11588' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8710 - 8750 8032.89 - 8059.07 4-1/2" 12.6# L-80 Surface - 8683' 12870 - 14170 8666.9 - 8624.94 Packers and SSSV Type: 9-5/8" x 4-1/2" 12.6# Packers and SSSV MD (ft): 8629' 0 0 0 0 0 0 12. Attachments: Descriptive Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^,~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/23/2007 Oil Q Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by nary r~eule 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Nanc Hibbert Printed Name Title Nancy Hibbert P.E. Signature °` -- Phone 564-5672 Date 2/9/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ... Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~^~ ~~ ~`, + ~ ~ ~~~~ i~ ~J APPROVED BY Approved by: MMISSIONER THE COMMISSION Date: ~ , ~ Q Form 10-403 Revised 06/20 ~ ~ 1 ~1 Submit in Duplicate • • by ~~_ ~~ iiiilll~~r /~1~1;A To: Tom Maunder Alaska Oil & Gas Conservation Commission 793-1250 From: Nancy Hibbert Production Engineer Date: February 9, 2007 Re: 18-27D: End Operation Shutdown 18-27D was a coil sidetrack drilled in September 2005. Due to a pinhole leak in the. coil and high winds which prohibited coil change out, it was decided to move off of the well and reevaluate options. An application for sundry (10-403) was approved October 4, 2005 (Sundry # 305-288) for operation shutdown. The well was left with 560' of good quality sand exposed in a horizontal open hole section. BP is submitting a new sundry application to put the well on production in its current status. The wellbore has 40' of Put River formation appraisal perforations which will flow with the Ivishak open hole section. In the area of Drillsite 18 the Put River formation is considered part of the Prudhoe Oil Pool per Conservation Order 341E since the two reservoirs are in hydraulic communication. Based on production from the sand interval BP will evaluate future uphole perforations in the parent well bore, remedial work and drilling options. Nancy Hibbert Production Engineer 564-5672 CC: Well File Terrie Hubble 18-27D (205-133)..305-288 Subject: 18-27D (205-133)..305-288 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Mon, 12 Feb ?007 1.5:44:31 -0900 "['o: Terrie Hubhle <hubble~l;~i.~bE~.coni~ CC: ari Salt~l~arsh ~~=art sa(tm~it~sh~~i:admin.slatc.al~.u5.~~~ C.J Terrie, I was just reviewing the 407 for this well. Was there a determination to go ahead and complete the well "as is"? I checked the file and the last document is a 404 that provides the same summary. Your assistance in sorting this out will be appreciated. Tom Maunder, PE AOGCC 1 of 1 2/12/2007 3:44 PM STATE OF ALASKA ~ ~ ~~ RE~,~~r~~.~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~. WELL COMPLETION OR RECOMPLETION REPORT AND LOG EB .O 6 2QOl Alaska Qil $ Gay ~..~ _ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: AAR ~1-S ®Developmen~f ~~oratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab~~! 09!27/2005 Ci~~ ~' 12. Permit to Drill Number 205-133 305-288 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 09/18/2005 13. API Number 50-029-22321-04-00 ~ 4a. Location of Well (Governmental Section): Surface: ' ~ ' 7. Date T.D. Reached 09/26/2005 14. Well Name and Number: PBU 18-27D~ 893 FNL, 236 FEL, SEC. 24, T11 N, R14E, UM Top of Productive Horizon: 474' FSL, 3768' FEL, SEC. 13, T11N, R14E, UM 8. KB Elevation (ft): 53.7' < 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 525' FSL, 76' FEL, SEC. 14, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 12200 + 8689 Ft Pool ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 691522 y- 5960969 Zone- ASP4 10. Total Depth (MD+TVD) 12200 + 8689 Ft 16. Property Designation: ADL 028307 ~ TPI: x- 687957 y- 5962247 Zone- ASP4 Total Depth: x- 686368 y- 5962258 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: ,~/iiyOosJ MWD DIR / GR ~-~s~ a'~ d!R 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 2000# Coldset II 13-3/8" 68# K-55 / L-80 Surface 3497' Surface 3497' 16" 2706 cu ft CS III 460 cu ft Class'G' 9-5/8" 47# L-80 Surface 9069' Surface 8259' 12-1/2" 2217 c ft Class'G' 7" 26# NT80S 8829' 9827' 8110' 8618' 8-1/2" 398 cu ft Class'G' 4-1 /2" 12.6# L-80 8678' 11 41' 8011' 11588' 3-3/4" 832 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24.' TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 3-3/8" Gun Diameter, 6 spf Open Hole 4-1/2", 12.6#, L-80 8684' 8629' MD TVD MD TVD Appraisal Perfs 11641' - 12200' 8669' - 8689' in Put River 25.. ACID, FRACTURE, CEMENT SQUEEZE, ETC. (From 18-Z7C) DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 8710' - 8750' 8033' - 8059' Freeze Protect w/ 40 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separat~.sheetf~.neeessary). Submit core chips; if none, state "none". „^ ~2gt ~iy* yy~~ ry tn' ' c"0i''~~Y/(~~''1!"'ft None ~ ~.°"°'"°"°" ~~ i~j ~~ /On Form 10-407 Revised 12/200 ~ ~ ~ ~ ` ~ ~ CONTINUED ON REVERSE SIDE ~\V~ 28 GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NnMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 18-27D Kicked Off in the None Sadlerochit /Zone 1 B 10320' 8661' 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. Si d O o5/~ gne Terrie Hubble Title Technical Assistant Date PBU 18-27D 205-133 305-288 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4387 Permit No. / A royal No. INSTRUCTIONS Gerrer~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Page 1 of 10 ~ Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code ~ NPT I Phase Description of Operations 9/15/2005 00:00 - 12:00 12.00 RIGU P PRE Move rig from 2-176 to 18-27D 12:00 - 15:00 3.00 BOPSU P PRE NU BOP 15:00 - 17:00 2.00 BOPSU N WAIT PRE Wait on grease crew. 17:00 - 21:30 4.50 BOPSU P PRE Test BOP's. Witnessing test waived by AOGCC Jeff Jones. 21:30 - 22:00 0.50 EVAL N DPRB WEXIT Open up master & swab: 2200 psi wellhead pressure. Talk to town. Decide to kill well during drift run. 22:00 - 22:15 0.25 KILL N DPRB WEXIT Safety meeting with rig crews to discuss well kill. 22:15 - 00:00 1.75 KILL N DPRB WEXIT Test master valve RU injector & lubricator. Test inner reel valve. Get drift ready. 9/16/2005 00:00 - 00:30 0.50 KILL N DPRB WEXIT Align manifold for bullhead. Retest kill line check valve (leak seen). OK 1 00:30 - 01:00 0.50 KILL N DPRB WEXIT Bleed down well to 1000 psi. j Pressure built back up quickly to 2200 psi. 01:00 - 01:20 0.33 KILL N DPRB WEXIT Equalize pressure on both sides of master valve. Open up master valve. Bullhead well at 5 bpm from surface. Pressure down to 530 psi. 01:20 - 02:20 1.00 KILL N DPRB WEXIT RIH bullheading well at 5 bpm. Building up pressure due to low clearance around drift and formation charging. Bleed down pressures and open up well: well killed. 02:20 - 04:30 2.17 KILL P WEXIT RIH pumping down coil and taking returns. Monitor for gas & freeze protect. No obstructions entered. Tag liner top at 11746.9'. (-8' correction). 04:30 - 05:40 1.17 KILL P WEXIT POOH at 8 fUmin to avoid swabbing. Pump bottoms up. Take returns to tiger tank as needed. 05:40 - 06:30 0.83 KILL N DPRB WEXIT Check for flow. No Flow 06:30 - 09:50 3.33 KILL P WEXIT POH 1.5/.7 bpm took 5bbl to fill. Loss rate .3 bpm. 09:50 - 10:10 0.33 ZONISO P WEXIT Flow check. No Flow. 10:10 - 11:00 0.83 ZONISO P WEXIT MU BP, FAIV,MWD etc. 11:00 - 14:00 3.00 ZONISO P WEXIT RIH with bridge plug. 11395. 14:00 - 14:40 0.67 ZONISO P WEXIT Log tie-in. Circulate 1.56 1355 psi to inicaite MWD signal. Correction +2'. 14:40 - 15:30 0.83 ZONISO P WEXIT RIH to setting depth 11680. Up Wt 42K. Circulate 2.8 bpm C 4550 psi. for 4minutes. Bleed of pressure. Pressure 3700 psi with .8 bbls. 15:30 - 18:30 3.00 ZONISO P WEXIT PU to 11300 EOP flag pipe. Function test orienter. FlowCk. NO FLOW, Continue to POH. 18:30 - 19:15 0.75 ZONISO P WEXIT LD CIBP BHA. PU WS assembly. Install RA tag. 19:15 - 19:30 0.25 WHIP P WEXIT Safety meeting for WS setting. Covered open perfs, setting parameters etc. 19:30 - 23:15 3.75 WHIP P WEXIT Stab injector. RIH with WS, MWD, & Orienter. Correct +3.4' to flag. Tag CIBP @ 11682'. ~-~ Correct -2' to CIBP. PU wt: 44K Ib, SO wt: 26K Ib. Printed: 10/3/2005 3:02:00 PM ' • BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task I Code ~~, NPT Phase Description of Operations a 9/16/2005 23:15 - 00:00 0.75 WHIP P WEXIT Orient TF to 171E Pump 2.65 bpm @ 4450 psi for 4.5 min. Shut down pumps. Bring rate up to 0.3 bbl/min, pin shear at 1400 psi, total 0.4 bbl pumped. SO until 3K Ib stacked, PU. WS set at 11660'. 9/17/2005 100:00 - 00:30 0.50 STWHIP P WEXIT Swap well over to 2 ppb bio-zan. 00:30 - 02:30 2.00 STWHIP P WEXIT POOH swapping well over to 2 ppb Bio-Zan. 02:30 - 03:30 1.00 STWHIP P WEXIT LD WS setting BHA. Behead with Weatherford CTC. Pull test to 39K psi. 03:30 - 04:30 1.00 STWHIP P WEXIT PU milling BHA. Gauge Mill: 3.81 go/3.80 no-go. Gauge String Reamer: 3.80 go/3.79 no-go. 04:30 - 07:00 2.50 STWHIP P WEXIT Correct to flag. + 7.1'.RIH with window milling BHA. Tag WS at 11651 U wt 43K Dn wt 21 K. 07:00 - 16:30 9.50 STWHIP P WEXIT Milling window 2.56/2.56 bpm @ 2010psi FS = 1925 psi PT 326 bbls Mill to 11657 and 10' of formation to 11667. 16:30 - 18:45 2.25 STWHIP P WEXIT Ream window and dry tag. ~ 18:45-20:30 1.75 STWHIP P WEXIT POOH. il~'' ~ Swap over to reconditioned Flo-Pro. 20:30 - 21:00 0.50 STWHIP P WEXIT LD Milling BHA ~~ 21:00 - 21:45 0.75 DRILL P PROD1 Make up SLB CTC. Pressure test to 34K Ib. 21:45 - 22:00 0.25 DRILL P PROD1 Jet stack. 22:00 - 22:15 0.25 DRILL P PROD1 Pre-spud meeting. Discussed possible drilling hazards such as lost circulation etc. 22:15 - 23:15 1.00 DRILL P PROD1 PU build BHA. 23:15 - 00:00 0.75 DRILL P PROD1 RIH. SHT orienter: good. RIH. 9/18/2005 00:00 - 01:20 1.33 DRILL P PROD1 RIH. 01:20 - 02:15 0.92 DRILL P PRODi Tie-into shale f/ 11375'-11437'. Correct (-7'). 02:15 - 02:30 0.25 DRILL P PROD1 RIH to TD. Tag at 11662'. 02:30 - 04:30 2.00 DRILL P PROD1 Drill build section. Off/On btm: 3100 psi/3150 psi. TF: 132L. Control drilling. Tie-in to RA tag. WS adjusted -10'. 04:30 - 05:00 0.50 DRILL P PROD1 Orient around to 70L TF. 05:00 - 06:30 1.50 DRILL P PROD1 Drill build section. Off/On btm: 3100 psi/3500 psi. PU wt: 42K Ib, SO wt: 21 K Ib. TF: 75L - 90L. Wt. stacking, high motor work. 06:30 - 07:00 0.50 DRILL P PRODi Wiper trip to window. 07:00 - 07:15 0.25 DRILL P PROD1 Orient 93L 07:15 - 11:30 4.25 DRILL P PROD1 Drill build section. Off/On btm: 3100 psi/3500 psi. PU wt: 42K Ib, SO wt: 21 K Ib. TF: 90L. Primed: 10/3/2005 3:02:00 PM BP EXPLORATION Operations Summary Report Page 3 of 10 ~ Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALIS TA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date ', From - To ~, Hours Task ~, Code' NPT Phase ~ ~~ Description of Operations 9/18/2005 07:15 - 11:30 4.25 DRILL P PRODi Wt. stacking, high motor work. 11:30 - 14:00 2.50 DRILL P PROD1 POH at end of build and turn. 14:00 - 14:45 0.75 DRILL P PROD1 Dial down motor to .8 degrees 14:45 - 16:50 2.08 DRILL P PROD1 RIH 16:50 - 17:10 0.33 DRILL P PROD1 Tie-in correction -6'. 17:10 - 17:30 0.33 DRILL P PROD1 Orient 96L 17:30 - 18:30 1.00 DRILL P PROD1 Directionally drill 2.5 / 2.5 bpm at 3250psi ,3100 psi FS.PT 290 bbls. CT wt 7K ,ROP 60. 18:30 - 18:55 0.42 DRILL N SFAL PROD1 Wellhead pressure 150 psi. 18:55 - 21:15 I 2.331 DRILL I P 21:15 - 21:50 I 0.581 DRILL I P 21:50 - 00:00 I 2.171 DRILL I P ~ 9/19/2005 100:00 - 01:00 ~ 1.00 ~ DRILL ~ P 01:00 - 01:15 01:15 - 02:00 02:00 - 04:45 04:45 - 05:45 05:45 - 08:00 08:00 - 08:10 08:10 - 09:00 09:00 - 11:58 19/20/2005 11:58 - 12:40 12:40 - 15:30 15:30 - 16:50 16:50 - 18:00 18:00 - 20:00 20:00 - 23:15 23:15 - 23:40 23:40 - 00:00 00:00 - 03:15 0.25 DRILL P 0.75 DRILL P 2.75 DRILL N 1.00 DRILL N 2.25 DRILL N 0.17 DRILL N 0.83 DRILL N 2.97 DRILL P 0.70 DRILL P 2.83 DRILL P 1.33 DRILL P 1.17 DRILL P 2.001 DRILL I P 3.25 DRILL P 0.42 DRILL P 0.33 DRILL P 3.25 DRILL P Stop and see what is causing pressure. No cause found. Drill ahead. PROD1 Drili directional f/ 11980'-12050'. O in/out: 2.6 bpm/2.6 bpm. Pressure on/off btm: 3150 psi/3300 psi. PU wt: 37K Ib. PROD1 Wiper trip to window. Debris along coil in several places. Orient 1 click. PROD1 Drill directional f/ 12050'-12095'. O in/out: 2.5 bpm/2.6 bpm Pressure on/off btm: 3150 psi/3500 psi. PU wt: 38K Ib., SO wt: 21 K Ib. PROD1 Drill directional f/ 12095'-12104'. Pressure on/off btm: 3650 psi/3350 psi. Fairly sharp increase in free spin. ROP dropping f/ 40 fUhr to 18 ft/hr. O in/out: 2.5 bpm/2.5 bpm. Play with WOB - no success. PROD1 Wiper trip to window. PROD1 Attempt to drill, no success. DPRB PROD1 POOH for BHA check/change. DPRB PROD1 MU new bit. Change MWD. DPRB PRODi RIH to drill lateral. DPRB PROD1 tie - in correction -10'. DPRB PRODi RIH work shale at 11859'. PROD1 Directionally drill 2.6 /2.6 bpm at 3300 psi, 3100 psi FS. Swap to new mud. Continue drilling 2.6 / 2.6 3370 psi., FS 3200 psi. CT wt 14K, ROP 40-60. Lost pumps. PROD1 Wiper 250'. PROD1 Directionally drill. 2.5 / 2.5 bpm @ 3350 psi, FS = 3100 psi. CT wt 11 K, ROP 20-30. PROD1 Wiper to window. Stacked out at 11777'. Orient to get through. PROD1 Directionally drill. 2.6 / 2.6 bpm @ 3500 psi, FS = 3100 psi. CT wt 7K, ROP 60-90'. PROD1 Drill directional f/ 12319'-12401'. Pressure on/off btm: 3650-3400 psi/3100 psi O in/out: 2.6 bpm/2.6 bpm PROD1 Wiper trip to tubing tail @ 8640'. PRODi Orient TF to LS to go through window. PRODi RIH to TD PROD1 Drill lateral f/ 12400' - 12536'. Printed: 10/3/2005 3:02:00 PM ~ ~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 1 8-27 Common W ell Name: 1 8-27 Spud Date: 12/28/1992 Event Nam e: REENTE R+COM PLET E Start : 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALIS TA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date ' From - To . Hours Task Code ! NPT Phase Description of Operations ~ 9/20/2005 00:00 - 03:15 ~ 3.25 - DRILL - P - - PROD1 --- --- Pressure offfon btm: 3100 psi/3450 -3550 psi. O in/out: 2.6/2.6 Build angle, find Z1 B for location. 03:15 - 04:15 i 1.00 DRILL P PROD1 Wiper trip to window. 04:15 - 04:30 0.25 DRILL P PROD1 Orient TF to 120E 04:30 - 05:50 1.33 DRILL P PROD1 Drill lateral f/ 12536' - 12665'. Pressure off/on btm: 3100 psi/3300 psi. O in/out: 2.6/2.6 bpm. 05:50 - 06:25 0.58 DRILL P PROD1 Short Wiper set down at 12600. 06:25 - 06:37 0.20 DRILL P PROD1 Drill lateral f/12665'-12,685'. Pressure off/on btm: 3100 psi/3300 psi. O in/out: 2.5/2.5 bpm. 06:37 - 08:00 1.38 DRILL P PROD1 Wiper to window. Motor work at i 1880 & 11820 while. POH. RIH to TD. 08:00 -09:00 1.00 DRILL N DPRB PROD1 Wiper to tubing tail while waiting discussion on plan forward. 09:00 - 10:00 1.00 DRILL N DPRB PRODi Wipe back to bottom. Run thru window no problem. Losing priority pressure on the power pack. Pull back above window 10:00 - 14:30 4.50 DRILL N RREP PROD1 Wait on mechanic to investigate power pack pump failure. Replace priority pump. 14:30 - 15:00 0.50 DRILL P PROD1 RIH to TD. Orient to 170R on way down. 15:00 - 16:50 1.83 DRILL P PROD1 Drill lateral f/ 12685' - 12803'. Pressure off/on btm: 3200 psi/3500 psi O: 2.6 bpm/2.6 bpm 16:50 - 19:30 2.67 DRILL P PROD1 POOH drilling BHA#6 to reset motor bend. 19:30 - 20:15 0.75 DRILL P PROD1 OOH. PJSM. S/B injector. Inspect orienter & motor - OK. Check bit -grade: 1/21/1 with 1 plugged jet & slight balling on the gauge junk slot. L/O bit. Changeout MWD probe & reset motor bend to 1.5degs. 20:15 - 20:45 0.50 DRILL P PROD1 M/U drilling BHA #7 with 1.5deg X-treme motor, MWD/GR, orienter & rebuilt HCC RWDSTR 3-3/4" x 4-1/8" bicenter bit #5. Scribe tools & M/U injector. 20:45 - 23:00 2.25 DRILL P PRODi RIH drilling BHA #7 to 11695' (below window). 23:00 - 23:10 0.17 DRILL P PROD1 Log up GR & tie-into RA Pip tag -subtract 11' from CTD. 23:10 - 23:40 0.50 DRILL P PROD1 RIH relatively clean to btm tagged @ 12817'. 23:40 - 23:50 0.17 DRILL P PROD1 Shoot off btm directional surveys. 23:50 - 00:00 0.17 DRILL P PRODi Orient TF around. 9/21/2005 00:00 - 00:10 0.17 DRILL P PROD1 Orient TF around to 130L. P/U wt = 41 k, S/O wt = 17k. PVT = 278bb1s. 00:10 - 00:30 0.33 DRILL P PRODi Drill to 12835' with 125E TF, 2.5/2.5bpm, 3400/3550psi, 3k WOB & 80fph ave ROP. 00:30 - 01:00 0.50 DRILL P PROD1 Orient 2 clicks & drill to 12869' with 80-95L TF, 2.6/2.6bpm, 3400/3550psi, 4k WOB & 90fph ave ROP. 01:00 - 03:00 2.00 DRILL P PROD1 Drill to 12942' with 60L TF, 2.5/2.5bpm, 3400/3850psi, 4k WOB & 60fph ave ROP. 03:00 - 04:15 1.25 DRILL P PROD1 Wiper trip to window. 04:15 - 04:30 0.25 DRILL P PROD1 Orient TF 90L. 04:30 - 06:00 1.50 DRILL P PRODi Drill to 12984' with 80-105L TF, 2.5/2.5bpm, 3400/3850psi, 4k WOB & 40fph ave ROP. Wt stacking. 06:00 - 10:00 4.00 DRILL P PROD1 Drill f/ 12984'-13101'. Pressure on/off btm: 3700-4000 psi/3400 psi Q in/out: 2.6/2.6 bpm. ~ PU wt: 37K Ib, SO wt:19K Ib ,Drilling wt: 4K-OK Ib. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Operations Summary Report Page 5 of 10 ~ Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task 'Code NPT Phase j Description of Operations 9/21/2005 10:00 - 12:40 2.67 DRILL P PROD1 Wiper trip to tubing tail. Some minor overpulls f/ 11815' - 13101'. 12:40 - 13:15 0.58 DRILL P PROD1 Orient TF to 116E 13:15 - 14:35 1.33 DRILL P PROD1 Drill f/ 13101 - 13189' Low ROP until last 40': 14:35 - 14:55 0.33 DRILL P PROD1 Orient TF to 130L. 14:55 - 16:45 1.83 DRILL P PROD1 Drill f/ 13189' - 13306'. 16:45 - 17:30 0.75 DRILL P 17:30 - 18:15 0.75 DRILL P 9/22/2005 18:15 - 18:45 18:45 - 20:15 20:15 - 20:30 20:30 - 22:00 22:00 - 22:15 22:15 - 22:30 22:30 - 00:00 00:00 - 03:00 03:00 - 03:35 03:35 - 06:00 0.50 DRILL P 1.50 DRILL P 0.25 DRILL P 1.501 DRILL I P 0.25 DRILL P 0.25 DRILL P 1.50 DRILL P 3.00 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 0.58 DRILL P PROD1 2.42 DRILL N DPRB PROD1 06:00 - 07:30 ( 1.501 DRILL I N I DPRB I PROD1 07:30 - 09:30 2.00 DRILL N DPRB PROD1 09:30 - 10:20 0.83 DRILL N DPRB PRODi 10:20 - 10:40 0.33 BOPSU P PROD1 10:40 - 12:00 1.33 DRILL X WAIT PROD1 12:00 - 14:15 2.25 DRILL X WAIT PROD1 14:15 - 14:45 0.50 DRILL C PROD1 14:45 - 15:00 0.25 DRILL C PROD1 Start mud swap to fresh Flo-Pro. Pressure on/off btm: 3550 psi/3250 psi - 2900 psi. O in/out: 2.6/2.6 bpm PU wt: 38K Ib, SO wt: 15K Ib, Drilling wt: 6K Ib - 4K Ib. TF: 90-100L Wiper trip to window. Log up f/ 11695' - 11654 Tie-into RA tag. Correction: +17.5 RIH to TD tagged @ 13317'. P/U wt = 39k, S/O wt = 16k. PVT = 293bb1s. IAP = 250psi. OAP = 240psi. Drill to 13375' with 80L TF, 2.5/2.5bpm, 3000/3400psi, 8k WOB & 40fph ave ROP. Should be @ +/-8697'sstvd. Orient TF to HS. Geo wants to start drilling up to establish well control points. Plan is to build & cross cut back up thru Zone 1A @ +/- 100degs incl. Drill to 13412' with HS TF, 2.5/2.5bpm, 3200/3400psi, 8k WOB & 20fph ave ROP. Stacking wt. Short 300' wiper. Drill to 13445' with HS TF, 2.5/2.5bpm, 3200/3400psi, 8k WOB & 20fph ave ROP. Finished build to +l-100degs. Wiper trip. Wiper trip. Had 30k O/pull @ 11875' with motor work. RBIH & backream shale clean. Continue wiper tripping to 8500'. RBIH below window to 11695'. Log up GR & tie-into RA Pip tag -add 14' to CTD. RBIH & set down several times in shale @ 11950'. Attempt to bounce thru tight spot without luck. Orient to as drilled TF -not getting clicks. PUH & able to orient to 100E while RIH. RBIH & set down @ 11953'. Ream thru tight spot to 11965' with no motor work & +/-1 k WOB. Backream to 11830'. RBIH & ream down from 11850'. Observe motorwork @ 11856'. PUH to 11700' & orient to as drilled TF of 50L. Attempting to get thru 11855'. Orient TF to 50L. Stacking out at 11855' no matter what method was tried. POOH for BHA change to accomodate doglegs at tight spot. LD BHA. Change out MWD for memory download. Equipment damage downhole: Orienter bent. HCC bicenter bit: 1/1/BT/G/X/I/CT/HP Function test BOPE: OK Wait on orders from town. Wait on SLB memory loggers to arrive. Rig up SLB memory loggers. Safety meeting with SLB memory loggers. Printed: 10/3/2005 3:02:00 PM ~ ~ BP EXPLORATION Page 6 of 10 ~ Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 .Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To I Hours 9/22/2005 14:45 - 15:00 15:00 - 16:00 16:00 - 17:40 17:40 - 19:00 19:00 - 19:45 19:45 - 21:30 21:30 - 21:45 21:45 - 22:15 Task Code NPT Phase '! Description of Operations -- - 0.25 DRILL IC PROD1 Topics: Weather, radiation. 1.00 EVAL C PROD1 PU BHA 1.67 EVAL C PROD1 Depth check at surface. Depth check 1000'. RIH to 9450'. 1.33 EVAL C PROD1 Log down C~? 30 ft/min from 9450' & set down @ 11854'. 0.75 EVAL C PROD1 Log up @ 60fpm from 11854' to 9450'. 1.75 EVAL C PROD1 Paint EOP flag @ 8500' & POOH logging BHA#8. 0.25 EVAL C PROD1 PJSM for UD logging BHA. 0.50 EVAL C PRODi S/B injector. R/B 1 std of 2-3/8" PH6 tbg CSH & UD SWS MCNUCCUGR logging tool carrier. Check log data quality ~ OK. 22:15 - 22:30 0.25 EVAL ~ C PROD1 M!U Cementing BHA#9 with 3.0" big hole nozzle, 6' x 2-318" PH6 pup, XO, MHA &CTC (OAL - 11.32') 22:30 - 00:00 1.50 CLEAN C PROD1 RIH with cementing BHA#9. Correct CTD +10' C~ the flag. 9/23/2005 00:00 - 02:00 2.00 CLEAN C PROD1 Continue RIH with cementing BHA#9. Wt chk @ 11800' - Up = 40k, Run-in = 21 k. RIH jetting 2% KCL thru nozzle. Jet thru tight spot @ max rate with slight wt bobbles &RIH clean to 12150'. Wt chk C~ 12150' - Up = 42k, Run-in = 23k. Swap back to flopro & continue RIH. Wt check C~3 12650' - OK. RIH & set down 3x C 13398'. Review situation with ANC & decide to j make a cleanout run before RIH with completion liner. 02:00 - 04:30 2.50 CLEAN X DPRB PROD1 POOH with nozzle BHA #9. O/pull & 13150', 12200', 12120', 11910' & 11880'. Work CT with max SOk pull @ 11880' & pull free. 04:30 - 06:15 1.75 CLEAN N DPRB PROD1 POOH with nozzle BHA. 06:15 - 06:30 0.25 CLEAN N DPRB PROD1 LD nozzle BHA. 06:30 - 07:30 1.00 CLEAN N DPRB PROD1 PU build cleanout BHA. Hycalog bicenter, 3.0 degree mtr, MWD. 07:30 - 09:30 2.00 CLEAN N DPRB PROD1 RIH. 09:30 - 10:00 0.50 EVAL N DPRB PROD1 Tie-in to RA tag. Correct (+7.5'). 10:00 - 13:00 3.00 CLEAN N DPRB PROD1 RIH to 11850. Attempt pass obstruction by orienting. Attempt to work through obstruction with low motor work, high ROP. No progress made, town called well. 13:00 - 13:30 0.50 EVAL N DPRB PROD1 Tie-in to RA tag. Correct (+1'). 13:30 - 15:30 2.00 CLEAN N DPRB PROD1 POOH. Paint flag. 9600' EOP. 15:30 - 16:30 1.00 CLEAN N DPRB PROD1 Set back injector. LD BHA. 16:30 - 18:30 2.00 CASE N WAIT RUNPRD Load 2-3/8" liner. Tally & drift same. 18:30 - 19:00 0.50 CASE P RUNPRD Install Baker CTC. Pull test to 35k & pressure test to 3500psi OK. 19:00 - 20:00 1.00 CASE P RUNPRD Install dart catcher. Load wiper dart. Launch & chase with mud to pig CT. Dart hit ~ 51.8bbls. 20:00 - 20:30 0.50 CASE P RUNPRD RU to run liner. 20:30 - 20:45 0.25 CASE P RUNPRD Held PJSM on M/U &RIH with liner. 20:45 - 23:30 2.75 CASE P RUNPRD M/U 2-3/8" STL indexing guide shoe, float collar, 1 shoe jt, float collar, spacer pup & landing collar. M/U & drift 56jts of 2-3/8" STL 4.7# L-80 liner. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report Page 7 of 10 ~ 18-27 18-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date 'From - To Hours Task 9/23/2005 23:30 - 00:00 0.50 CASE 9/24/2005 00:00 - 01:00 1.00 CASE Spud Date: 12/28/1992 Start: 9/14/2005 End: 9/27/2005 Rig Release: 9/27/2005 Rig Number: N1 Code' NPT Phase Description of Operations N P 01:00 - 03:00 2.00 CASE P 03:00 - 05:30 2.50 CASE N 05:30 - 08:00 2.50 CASE N 08:00 - 08:30 0.50 CASE N 08:30 - 11:45 3.25 CASE N 11:45 - 13:30 I 1.75 I STKOH I C 13:30 - 16:45 3.25 STKOH C 16:45 - 17:15 0.50 STKOH C 17:15 - 17:45 0.50 STKOH C 17:45 - 19:00 1.25 STKOH C 19:00 - 19:40 I 0.671 STKOH I C 19:40 - 20:10 I 0.50 I STKOH I C 20:10 - 20:30 0.33 STKOH C 20:30 - 21:00 0.50 STKOH C 21:00 - 23:15 2.25 STKOH C 23:15 - 23:45 0.50 STKOH C 23:45 - 00:00 9/25/2005 00:00 - 00:30 00:30 - 01:30 0.25 STKOH C 0.50 STKOH C 1.00 DRILL C 01:30 - 03:30 03:30 -04:30 2.00 DRILL C 1.00 DRILL C WAIT RUNPRD Load 12 additional joints of 2-3/8" liner. Tally & drift same. RUNPRD Continue M/U & drift 12jts of 2-3/8" STL 4.7# L-80 liner. M/U XO, 3-1/2" STL pup & Baker Deployment sleeve. M/U CTLRT & injector. RUNPRD RIH with liner (OAL - 2167.94') on CT. Correct +18' Q the flag. Check up wt - 40k, down wt - 19k. Continue RIH @ +/-40fpm. Set down C~ 11876'. P/U, RBIH & bounce thru. Set down C 11886'. DPRB RUNPRD Work liner without progress. Pump down 1 coil volume of 2% KCL water. Park shoe Q 11884' & jet @ 1.77bpm/1285psi - no luck. Discuss situation with ANC & decide to POOH for cement plugback. DPRB RUNPRD POOH with completion liner BHA#11. DPRB RUNPRD LD deployment tools. DPRB RUNPRD Rack back liner w/ cementrilizers. LD liner without cementrilizers. Slow drawworks coming down. Both dog collars needed repair in middle of operation. PROD1 PU PH6 for BHA. Behead CTC f/ Baker to SLB. Stab injector. PROD1 RIH. PROD1 Tag at 11866'. Correct to 11886'. Flag pipe to 11876'. Wt check: 40K Ib. POOH to 11600. RIH to 11886'. Clean. PU to 11630'. Displace well to 2% KCI. One gas burp, 28% LEL. RU cmters. PROD1 Safety meeting with SLB cmters. PROD1 Prime up. Flush/PT lines to 4k. Jet wellbore from 11886' to 11350' @ 3.5bpm/1040psi. RBIH & park nozzle @ 11630'. PROD1 Pump 5bbls of water ahead. Mix & pump 8bbls 17ppg class-G cmt with additives @ 1.6/1.6bpm & 1420psi. Cmt to wt 19:08hrs. Pump 5bbls of water behind. Isolate cementers & clean lines. Chase with KCL ~ 2.6/2.6bpm & 1950psi - 570psi. RBIH & park nozzle ~ 11876'. Pump out 1 bbl of cmt past nozzle & lay-in 7bbls of cmt 1:1 to TOC ~ 11350'. PROD1 POOH to safety @ 10600' circ down bio-KCL @ min rate with 150psi WHP. PROD1 RBIH circ down 60bbls of bio-KCL pill to the nozzle. PROD1 RBIH ~ 30fpm circ C~3 3.0/3.Obpm & 1320psi jetting down to 11680'. Make 3 up/down passes with bio-KCL fluid across the window. Jet up hole to 11350' & jet back in hole to 11680'. PROD1 Jet OOH with nozzle. PROD1 OOH. PJSM. S/B injector. L/D cement nozzle BHA. M/U swizzle stick & stab injector on well. SI master valve. PROD1 Jet BOP stack C~3 max rate. PRODi Continue jetting BOP stack & surface lines @ max rate. PROD1 M/U drilling BHA #13 with 2.4deg X-treme motor, MWD/GR, orienter & rebuilt Smith M09BOPX 3-3/4" PDC bit #6. Scribe tools & M/U injector. PROD1 RIH drilling BHA #13 to 11370'. PROD1 Log down GR & tie-into formation marker @ 11370' -add 5' to Printed: 10/3/2005 3:02:00 PM ~ ~ BP EXPLORATION Page 8 of 10 Operations Summary Report ;Legal Well Name: 18-27 ,Common Well Name: 18-27 Spud Date: 12/28/1992 ',Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 ';Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 ' ~ , From - To Date Hours Task Code ~ NPT Phase ' Description of Operations 9/25/2005 03:30 - 04:30 I 1.00 DRILL C PROD1 CTD. 04:30 - 10:00 5.50 DRILL C PROD1 Park bit @ 11402' & W. O. C. to get to 2000psi compressive I strength. Swap over to Flo-Pro, I 500 psi @ 0800 hrs. 2000 psi @ 1000 hrs. 10:00 - 11:30 1.50 DRILL C PROD1 RIH to TD. Establish cement depth at 11671'. Motor work f/ 11671' - 11685'. ! Drill @ 30 fUhr f/ 11685' - 11690'. 11:30 - 15:15 3.75 DRILL C PROD1 Time drill f/ 11690' - 11703'. Building at 0 degrees TF. 15:15 - 16:15 1.00 DRILL C i PROD1 Orient TF to 90L. Problem with trapped torque on orienter. 16:15 - 16:45 0.50 DRILL C PROD1 Drill directionally and land lateral. Pressure off/on btm: 3000 psi/3100 psi. O in/out: 2.5!2.5 bpm. 16:45 - 17:45 1.00 DRILL C PROD1 Orient TF to 135L. Difficulty orienting. 17:45 - 18:35 0.83 DRILL C ~ PROD1 Drill directionally Pressure off/on btm: 3000 psi/3450 psi. Q in/out: 2.6/2.6 bpm TF: 115E 18:35 - 21:35 3.00 DRILL C PROD1 PUH above window & orient TF 139R. TF flopping to HS once ~i on btm. Orient & reorient but TF still flipping to HS. Finally orient TF to 140R. 21:35 - 22:00 0.42 DRILL C PROD1 Drill to 11791' with 130R TF, 2.5/2.5bpm, 3000/3450psi, 3k WOB & 60fph ave ROP. Drilling 3' & orienting 1 click to work ' TF to LHS. 22:00 - 22:15 0.25 DRILL C PROD1 PUH & orient TF to 125L. ~' 22:15 - 22:35 0.33 DRILL C PROD1 Drill to 11823' with 135E TF, 2.6/2.6bpm, 3000/3550psi, 3k i WOB & 80fph ave ROP. 22:35 - 00:00 1.42 DRILL C PROD1 PUH above window & orient TF to 55L. RBIH to btm. x,9/26/2005 00:00 - 00:30 0.50 DRILL C PROD1 Drill to 11884' with 80-90L TF, 2.6/2.6bpm, 3000/3550psi, 3k ', WOB & 120fph ave ROP. 00:30 - 00:50 0.33 DRILL C PROD1 PUH above window & orient TF to 45L. RBIH to btm. ', 00:50 - 01:30 0.67 DRILL C PROD1 Drill to 11900' with 70-80L TF, 2.6/2.6bpm, 3000/3550psi, 3k ~ WOB & 30fph ave ROP. ', 01:30 - 03:50 2.33 DRILL C PROD1 POOH to cut CT for fatigue management. Currently Q 98% CT life due to repeated orienting above the window. 03:50 - 04:30 0.67 DRILL C PROD1 OOH. PJSM. S/B injector. C/O orienter. Check motor & bit OK. 04:30 - 04:45 0.25 DRILL C PRODi Held PJSM for curtting CT. 04:45 - 05:30 0.75 DRILL C PROD1 R/U hydraulic cutter & cut 400' of CT. Have 13362' of CT left on the reel. 05:30 - 06:00 0.50 DRILL C PROD1 Rehead & M/U SLB CTC. Pull test to 35k & pressure test to 3500psi - OK. 06:00 - 06:30 0.50 DRILL C PROD1 M/U drilling BHA #14 with 2.4deg X-treme motor, MWD/GR, orienter & used Smith M0960PX 3-3/4" PDC bit #7. Scribe tools & M/U injector. 06:30 - 08:30 2.00 DRILL C ~ PROD1 RIH to TD. 08:30 - 10:00 1.50 EVAL C PROD1 Tie-in f/ 11695' up. Correction (+16'). 10:00 - 10:45 0.75 DRILL C PROD1 Attempt to orient to 70L. Difficulty orienting. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Operations Summary Report Page 9 of 10 ~ Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ', Task ', Code' NPT Phase ' Description of Operations _~ 9/26/2005 10:00 - 10:45_ - - - 0.75 DRILL C ~ ~ PROD1 Going up, small to no clicks. 10:45 - 11:30 I 0.751 DRILL IC 11:30 - 12:00 0.50 DRILL C 1200 - 13:00 1.00 DRILL C 13:00 - 13:10 0.17 DRILL C 13:10 - 13:45 0.58 DRILL C 13:45 - 14:15 0.50 DRILL C 14:15 - 16:30 2.25 DRILL C 16:30 - 18:45 2.25 DRILL C 18:45 - 19:15 0.50 DRILL C 19:15 - 19:30 0.25 DRILL C 19:30 - 20:30 1.00 DRILL C 20:30 - 22:35 2.08 DRILL C 22:35 - 23:10 0.58 DRILL C 23:10 - 23:25 0.25 DRILL C 23:25 - 00:00 9/27/2005 00:00 - 00:30 00:30 - 01:00 0.581 DRILL I C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 0.50 DRILL X DFAL PROD1 0.50 DRILL X DFAL PROD1 01:00 - 01:45 01:45 - 03:45 03:45 - 04:30 04:30 - 05:15 05:15 - 05:30 05:30 - 06:30 06:30 - 06:45 06:45 - 09:00 0.751 DRILL X DFAL PROD1 2.00 DRILL X 0.75 DRILL X 0.75 DRILL X 0.25 DRILL X 1.00 DRILL X 0.25 DRILL X 2.25 DRILL X DFAL PROD1 DFAL I PROD1 DFAL 1 PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 Going down/on btm, 10-20 degrees~click. Drill build f/ 11916'-11985'. Pressure off/on btm: 3050 psi/3200 psi. O in/out: 2.5/2.5 bpm PU wt: 35K Ib, SO wt: 18K Ib, on btm: 8K Ib. TF: 68L Orient TF to 120E Drill build f/ 11985' - 12026'. Pressure off/on btm: 3000 psi/3500 psi. O in/out: 2.5/2.5 bpm Orient TF to 75L. Drill build f/ 12206'-12076' Pressure off/on btm: 3000 psi/3500 psi. O in/out: 2.5/2.5 bpm. Wiper trip to window. Drill build f/ 12076'-12200'. Pressure off/on btm: 2950 psi/3450 psi. O 2.6/2.6 in/out: bpm. PU wt: 38K Ib., SO wt: 18K Ib., On btm: 10K Ib. TF: 70L. Finish build at 12200'. Hope for wind to drop for reel swap after POOH. Cranes/N2 called out. OOH. PJSM. S/B injector. Check orienter, motor & bit - OK. Held PJSM with Peak crew to discuss the possibility of reel swap. Call off reel swap operations due to high winds -steady @ 15-18mph & gusting (c~ 24-27mph. M/U lateral BHA #15 with 1.5deg X-treme motor, MWD/GR, orienter & rebuilt Hycalog DS49 3-3/4" PDC bit #8. Scribe tools & M/U injector. RIH lateral BHA #15. SHT MWD - OK. SHT orienter -getting only 10deg clicks. RIH to below window. Log up GR & tie-into RA Pip tag -add 4' to CTD. RIH & set down in shale @ 12128'. P/U drop pumps & bounce thru. RIH & tag TD C~3 12200'. Attempt to orient TF. Observe +/-650psi loss in circ pressure. Also not getting MWD signals. Suspect pinhole in CT. PUH & observe pin-hole in CT C~3 11125'. Held PJSM for inspecting CT to determine if to cut & rejoin with double grapple or continue spooling onto reel. Set upper 2-3/8" combis. Slack off & test slips holding - OK. Strip up injector. Set die collar on CT. Inspect pinhole & decide to spool onto reel. Gently spool pinhole onto reel & continue POOH CT. OOH. PJSM. S/B injector. L/D lateral BHA#15. SI Master. Pump 45bbls of fresh water thru CT & follow with 10bbls of McOH spacer. PJSM for B/D CT with N2. P/Test N2 lines - OK. B/D CT with N2 & bleed off. PJSM for stripping off & pulling back CT to the reel. Slip connector into CT & pull test. Strip-off CT from injector & spool back to reel. Secure CT & prep reel for shipment. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT ~~ Phase Description of Operations 9/27/2005 09:00 - 09:15 0.25 DRILL X DFAL PROD1 R/U & PJSM for BOPE testing. 09:15 - 13:00 3.75 DRILL X DFAL PROD1 Perform weekly BOPE pressure/function test. AOGCC test 13:00 - 15:30 2.50 WHSUR X DFAL POST 15:30 - 17:00 1.50 CLEAN X DFAL POST witnessed by Lou Grimaldi. Suspend BOP P/test for move to W-39. N/D BOP. N/U & pressure test tree cap. Cleanout pits. Release rig C~3 17:00 on 9/27/05. Printed: 10/3/2005 3:02:00 PM Halliburton Sperry-Sun North Slope Alaska BPXA 18-27DPB 1 Job No. AKMW3940183, Surveyed: 26 September, 2005 Survey Report 18 November, 2005 Your Ref.• API 500292232170 Surface Coordinates: 5960969.34 N, 691522.34E (70° 17' 52.5352" N, 148° 26' 56.0303" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 53.70ft above Mean Sea Level ___ Ct to ~ L 1,,,. N ~+~ __~~ s E t~ v i cc, ~ Survey Ref: svy4742 A Hailibunton Company Halliburton Sperry-Sun Survey Report for 18-27DP61 Your Ref: API 500292232170 Job No. AKMW3940183, Surveyed: 26 September, 2005 North Slope Alaska Measured Depth (ft) 11624.12 11641.00 11669.40 11698.21 11731.21 11763.51 11794.07 11838.46 11870.30 11900.27 11930.34 11961.81 11991.98 12022.97 12050.72 Incl 89.540 89.800 83.410 76.380 78.590 78.660 79.450 74.270 80.770 86.400 88.330 89.120 87.980 86.840 89.300 True Azim. 277.790 278.180 271.870 265.420 257.890 247.980 236.910 222.490 214.410 207.730 205.970 200.870 198.580 195.950 192.960 12078.43 12107.07 12146.93 12177.39 12206.48 12252.72 12281.85 12315.08 12345.07 12378.04 12411.10 12443.59 12473.90 12512.97 12543.82 12573.24 12601.66 12630.83 12661.21 12713.54 91.850 88.240 89.120 89.650 90.350 92.990 94.130 91.490 90.970 90.700 91.490 94.480 95.620 95.800 95.800 94.480 92.990 91.050 88.860 87.980 192.610 190.150 188.570 187.330 184.170 178.900 176.960 175.910 175.210 172.040 170.110 169.410 170.810 164.660 163.430 159.210 160.970 157.450 154.290 157.980 Sub-Sea Depth (ft) 8614.78 8614.88 8616.56 8621.62 8628.78 8635.16 8640.98 8651.12 8658.01 8661.36 8662.74 8663.44 8664.21 8665.61 8666.54 Vertical Depth (ft) 8668.48 8668.58 8670.26 8675.32 8682.48 8688.86 8694.68 8704.82 8711.71 8715.06 8716.44 8717.14 8717.91 8719.31 8720.24 Local Coordinates Northings Eastings (ft) (ft) 1735.03 N 4762.03 W 1737.38 N 4778.74 W 1739.86 N 4806.95 W 1739.21 N 4835.28 W 1734.53 N 4867.12 W 1725.25 N 4897.35 W 1711.39 N 4923.91 W 1683.56 N 4956.81 W 1659.24 N 4976.09 W 1633.75 N 4991.44 W 1606.95 N 5005.00 W 1578.09 N 5017.50 W 1549.70 N 5027.68 W 1520.14 N 5036.87 W 1493.29 N 5043.79 W Global Coordinates Northings Eastings (ft) (ft) 5962582.45 N 686717.64 E 5962584.37 N 686700.87 E 5962586.13 N 686672.61 E 5962584.76 N 686644.31 E 5962579.27 N 686612.59 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) -4390.08 Tie On Point 2.777 -4402.62 Wlndow Point 31.586 -4422.66 32.871 -4440.37 23.259 -4457.25 5962569.22 N 686582.61E 30.078 -4469. 58 5962554.69 N 686556.42E 35.656 -4476. 03 5962526.03 N 686524.24E 33.702 -4475. 86 5962501.22 N 686505.58E 32.092 -4469. 62 5962475.35 N 686490.89E 29.036 -4459. 95 5962448.21 N 686478.01E 8.682 -4448. 15 5962419.04 N 686466.25E 16.395 -4434. 07 5962390.41 N 686456.80E 8.477 -4418. 87 5962360.62 N 686448.37E 9.241 -4402. 13 5962333.60 N 686442.13E 13.947 -4386. 01 8666.26 8719 .96 1466. 27 N 5049. 92 W 5962306.44 N 686436. 69E 9.289 -4369. 25 8666.24 8719 .94 1438. 20 N 5055. 57 W 5962278.23 N 686431. 76E 15.252 -4351. 38 8667.16 8720 .86 1398. 88 N 5062. 05 W 5962238.76 N 686426. 28E 4.536 -4325. 43 8667.49 8721 .19 1368. 72 N 5066. 26 W 5962208.50 N 686422. 84E 4.427 -4305. 03 8667.49 8721 .19 1339. 78 N 5069. 18 W 5962179.49 N 686420. 67E 11.126 -4284. 73 8666.14 8719 .84 1293. 59 N 5070. 42 W 5962133.29 N 686420. 60E 12.742 -4250. 15 8664.33 8718 .03 1264. 54 N 5069 .37 W 5962104.28 N 686422. 39E 7.713 -4227. 22 8662.70 8716 .40 1231. 42 N 5067 .30 W 5962071.22 N 686425. 30E 8.548 -4200. 52 8662.06 8715 .76 1201. 53 N 5064. 98 W 5962041.39 N 686428. 38E 2.907 -4176. 13 8661.57 8715 .27 1168. 77 N 5061. 32 W 5962008.74 N 686432. 88E 9.649 -4148. 68 8660.94 8714 .64 1136. 11 N 5056. 19 W 5961976.23 N 686438. 84E 6.307 -4120. 37 8659.25 8712 .95 1104. 19 N 5050. 43 W 5961944.46 N 686445. 41E 9.451 -4092. 21 8656.58 8710 .28 1074. 45 N 5045. 24 W 5961914.86 N 686451. 36E 5.943 -4066. 09 8652.69 8706 .39 1036. 48 N 5036. 99 W 5961877.11 N 686460. 58E 15.670 -4031. 70 8649.57 8703 .27 1006. 97 N 5028 .55 W 5961847.83 N 686469. 76E 3.967 -4003. 67 8646.94 8700 .64 979. 22 N 5019 .17 W 5961820.33 N 686479. 85E 14.974 -3976. 38 8645.09 8698 .79 952. 55 N 5009 .51 W 5961793.92 N 686490. 18E 8.104 -3949. 75 8644.06 8697 .76 925. 31 N 4999 .16 W 5961766.94 N 686501. 22E 13.771 -3922. 23 8644.08 8697 .78 897. 59 N 4986 .75 W 5961739.55 N 686514. 34E 12.655 -3893. 01 8645.52 8699 .22 849. 76 N 4965 .59 W 5961692.27 N 686536. 71E 7.246 -3842. 77 18 November, 2005 - 15:17 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 18-27DP81 Your Ref.• API 500292232170 Job No. AKMW3940183, Surveyed: 26 September, 2005 North Slope Alaska BPXA 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) (°I100ft) 12747.61 85.690 156.920 8647.41 8701.11 818.34 N 4952.54 W 5961661.20 N 686550.55E 7.405 -3810.32 12785.88 83.500 163.780 8651.01 8704.71 782.49 N 4939.73 W 5961625.68 N 686564.27E 18.739 -3774.62 12818.36 81.210 168.350 8655.34 8709.04 751.25 N 4931.98 W 5961594.66 N 686572.81E 15.625 -3745.71 12849.32 79.540 164.130 8660.52 8714.22 721.61 N 4924.73 W 5961565.21 N 686580.82E 14.480 -3718.34 12879.79 80.600 154.290 8665.78 8719.48 693.59 N 4914.08 W 5961537.47 N 686592.18E 31.998 -3690.03 12913.21 83.930 148.840 8670.28 8723.98 664.49 N 4898.32 W 5961508.78 N 686608.68E 18.982 -3657.61 12942.48 87.890 144.800 8672.37 8726.07 640.07 N 4882.34 W 5961484.77 N 686625.27E 19.300 -3628.63 12974.02 86.310 140.930 8673.97 8727.67 614.96 N 4863.33 W 5961460.16 N 686644.91E 13.238 -3597.18 13003.14 87.100 137.060 8675.64 8729.34 593.02 N 4844.26 W 5961438.72 N 686664.54E 13.542 -3568.11 13036.04 88.150 130.560 8677.01 8730.71 570.28 N 4820.55 W 5961416.59 N 686688.82E 19.996 -3535.45 13063.59 87.890 126.160 8677.96 8731.66 553.20 N 4798.97 W 5961400.06 N 686710.83E 15.989 -3508.49 13092.93 85.870 121.070 8679.56 8733.26 536.99 N 4774.58 W 5961384.47 N 686735.62E 18.640 -3480.40 13126.85 84.990 114.390 8682.26 8735.96 521.26 N 4744.67 W 5961369.51 N 686765.93E 19.801 -3449.12 13158.96 86.840 109.820 8684.55 8738.25 509.21 N 4715.00 W 5961358.23 N 686795.89E 15.320 -3420.83 13189.22 89.560 103.840 8685.50 8739.20 500.46 N 4686.07 W 5961350.21 N 686825.04E 21.700 -3395.52 13225.86 85.780 100.150 8686.99 8740.69 492.85 N 4650.27 W 5961343.52 N 686861.02E 14.410 -3366.69 13262.34 86.480 95.230 8689.46 8743.16 487.99 N 4614.21 W 5961339.57 N 686897.19E 13.592 -3339.78 13297.63 86.040 91.710 8691.76 8745.46 485.85 N 4579.07 W 5961338.34 N 686932.37E 10.031 -3315.56 13328.43 86.130 87.840 8693.86 8747.56 485.98 N 4548.35 W 5961339.24 N 686963.08E 12.539 -3295.90 13356.78 86.040 79.230 8695.80 8749.50 489.16 N 4520.27 W 5961343.14 N 686991.07E 30.301 -3280.29 13387.99 87.710 79.050 8697.50 8751.20 495.03 N 4489.67 W 5961349.79 N 687021.52E 5.382 -3265.12 13420.41 94.040 77.300 8697.01 8750.71 501.67 N 4457.96 W 5961357.23 N 687053.05E 20.257 -3249.82 13445.00 94.040 77.300 8695.28 8748.98 507.06 N 4434.03 W 5961363.23 N 687076.83E 0.000 -3238.57 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 140.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13445.OOft., The Bottom Hole Displacement is 4462.93ft., in the Direction of 276.524° (True). • • 18 November, 2005 - 15:17 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 18-27DP61 Your Ref.• API 500292232170 Job No. AKMW3940183, Surveyed: 26 September, 2005 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11624.12 8668.48 1735.03 N 4762.03 W 11641.00 8668.58 1737.38 N 4778.74 W 13445.00 8748.98 507.06 N 4434.03 W Survey tool program for 18-27DPB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 13445.00 8748.98 Comment Tie On Point Wlndow Point Projected Survey Survey Tool Description MWD Magnetic (18-27) BPXA CI 18 November, 2005 - 15:17 Page 4 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun North Slope Alaska BPXA 18 27D Job No. AKMW3940183, Surveyed: 26 September, 2005 Survey Report 3 October, 2005 Your Ref: API 500292232104 Surface Coordinates: 5960969.34 N, 691522.34E (70° 17' 52.5352" N, 148° 26' 56.0303" W) Grid Coordinate System: NAD27Alaska Sfate Planes, Zone 4 Kelly Bushing Elevation: 53.70ft above Mean Sea Level ~ R ~ ~ ~ ~ ~ Survey Ref: svy4670 A Halliburton Company Halliburton Sperry-Sun Survey Report for 18-27D Your Ref: AP1500292232104 Job No. AKMW3940183, Surveyed: 26 September, 2005 North Slope Alaska Measured Depth (ft) 11624.12 11641.00 11671.59 11703.12 11740.70 11773.91 11805.24 11843.09 11878.34 11910.88 Incl. 89.540 89.800 85.520 92.200 88.770 90.530 86.840 83.580 83.670 86.840 True Azim. 277.790 278.180 273.230 268.120 262.040 257.300 254.310 244.460 238.140 231.100 Sub-Sea Depth (ft) 8614.78 8614.88 8616.13 8616.75 8616.43 8616.64 8617.36 8620.52 8624.44 8627.14 Vertical Depth (ft) 8668.48 8668.58 8669.83 8670.45 8670.13 8670.34 8671.06 8674.22 8678.14 8680.84 Local Coordinates Northings Eastings (ft) (ft) 1735.03 N 4762.03 W 1737.38 N 4778.74 W 1740.41 N 4809.14 W 1740.78 N 4840.63 W 1737.56 N 4878.05 W Global Coordinates Northings Eastings (ft) (ft) 5962582. 45 N 686717.64 E 5962584. 37 N 686700.87 E 5962586. 63 N 686670.41 E 5962586. 20 N 686638.92 E 5962582. 02 N 686601.59 E 1731. 61 N 4910.71 W 5962575.24 N 1723. 93 N 4941.07 W 5962566.79 N 1710. 68 N 4976.32 W 5962552.64 N 1693. 86 N 5007.04 W 5962535.05 N 1675. 10 N 5033.45 W 5962515.62 N 11943.93 91.320 225.660 8627.67 8681.37 1653.16 N 5058.14 W 5962493.06 N 11975.69 88.070 217.920 8627.84 8681.54 1629.50 N 5079.29 W 5962468.87 N 12007.83 85.960 211.940 8629.51 8683.21 1603.20 N 5097.66 W 5962442.11 N 12043.96 85.340 202.800 8632.26 8685.96 1571.25 N 5114.20 W 5962409.74 N 12074.86 86.480 191.730 8634.47 8688.17 1541.86 N 5123.33 W 5962380.13 N 12105.59 88.770 184.700 8635.74 8689.44 1511.49 N 5127.71 W 5962349.66 N 12140.09 89.910 180.300 8636.14 8689.84 1477.04 N 5129.22 W 5962315.18 N 12176.95 91.850 167.820 8635.57 8689.27 1440.45 N 5125.41 W 5962278.70 N 12200.00 91.850 167.820 8634.83 8688.53 1417.93 N 5120.55 W 5962256.31 N 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 140.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12200.OOft., The Bottom Hole Displacement is 5313.25ft., in the Direction of 285.478° (True). 686569.09 E 686538.94 E 686504.04 E 686473.76 E 686447.83 E 686423.71 E 686403.18 E 686385.48 E 686369.76 E 686361.38 E 686357.77 E 686357.14 E 686361.88 E 686367.31 E Dogleg Vertical Rate Section (°/100ft) -4390.08 2.777 -4402.62 21.379 -4424.49 26.667 -4445.02 18.573 -4466.60 15.224 15.156 27.322 17.820 23.657 -4483.03 -4496.66 -4509.17 -4516.03 -4518.64 21.318 26.428 19.706 25.283 35.923 24.040 13.174 34.259 0.000 -4517.71 -4513.17 -4504.84 -4490.99 -4474.35 -4453.90 -4428.47 -4398.00 -4377.63 BPXA Comment Tie On Point Window Point • Projected Survey • 3 October, 2005 - 17:10 Page 2 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 18-27D Your Ref: API 500292232104 Job No. AKMW3940183, Surveyed: 26 September, 2005 North Slope Alaska BPXA Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11624.12 8668.48 1735.03 N 4762.03 W Tie On Point 11641.00 8668.58 1737.38 N 4778.74 W Window Point 12200.00 8688.53 1417.93 N 5120.55 W Projected Survey From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 12200.00 8688.53 MWD Magnetic (18-27) • 3 October, 2005 - 17:10 Page 3 of 3 Dri11Ouest 3.03.06.008 TREE = 41 /16" FMC ~ Q ~ /~ ~ D 18-27D CTD Attempted L/Ops Shutdown 9/28/05 13-3/8" CSG, 68#, L-80, ID = 12.415" 41 /7' TBG, 12.6#, L-S0, .0152 bpf , ID = 3.958" ~ 8629' Minimum ID = 3.812" @ 2223' 4-1 /2" CAMCO BAL-0 SSSVN PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CCL ON 10/04/00 A NGLE AT TOP PERF: 48 @ 8710' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 8710 - 8750 2" 4 4'~u 9-5J8" CSG, 47#, L-80, ID = 8.681" 9075' - ~ MECHANICALwHIr~-ocK 11 11sa1' WINDOW 11641 ° - 11647' P.A P'~P r~G 11650' 11739' TOP OF 2-7/8" LNR, ID = 2.377" 41 /2" LNR, 12.6#, L-80, IBT, ID = 3.958" 1 ? ^'~ ~ 12266' MILL OUT WINDOW (WHIP NOT SHOWN) 1/8" 13445' ~ PLUG BACK #1 TD DATE REV BY COMMENTS DATE REV BY COMMENTS 02/23/93 ORIGINAL COMPLETION 09/13!03 CMO/TLP DATUMMD/TVD& PERFANGLE 04/11!98 RIG SIDETRACK (18-2TA) 03/04/05 RAC/TLH GLV CJO 11!01/98 CTD SIDETRACK (18-27B) 04/01!05 LDK/TLH PERFS (03131/05) 10/18/00 CTD SIDETRACK (18-27C) 08/19/05 MSE PROPOSED CTD SIDETRACK 11 /23/01 CH/TP CORRECTIONS :, rD 'D T? 1 C'r: 06/15/03 CMO/TLP MAX ANGLE CORRECTION PRUDHOE BAY UNfT WELL: 18-27 D PERMIT: 205-133 API No: 50-029-22321-04 SEC 24, T11 N, R14E, 893' SNL & 236' WEL BP Exploration (Alaska) I O I SAFETY NOTES: WELL ANC2_E> 70° ~ 9830' & > 90° ~ 10104'. ORIaNAL 18-27 WR I ~ NOT SHOWN BELOW 7" LNR MLLOITT WINDOW (d~ 9827' (18-27A). 1 /2" CAMCO BAL-O SSSVN, ID = 3.812" CAS LIFTMANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2986 2966 1 MMG DOME RK 16 02/28/05 2 5308 5198 28 MMG DOME RK 16 02/28/05 3 7260 6897 30 MMG DOME RK 26 02/28/05 4 8439 7839 40 MMG SO RK 22 02/28/05 ~ 9-5/8" X 41/2" BKR S-3 PKR, ID = 3.875" ~ 8662' 8683' 4-1 /2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 8684' 9-5/8" X 7" BKR ZXP PKR, ID = 6.30" 8692' 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" 86gg' 7" X 4-1;2" XO, ID = 3.937" 8829 I, ., ,..,~ 9204' ~ 4-1 /2" HES X NIP, ID = 3.813" 1D008' ~ _ 11671' ~ SIDETRACK POINT 4-1/4" X 3-3/4" OH 12200' S%T HOLE TD 11886' BTM OF CMT PLUG • • 06-Dec-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 18-27DPB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,624.12' MD Window /Kickoff Survey: 11,641.00' MD (if applicable) Projected Survey: 13,445.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorag , AK 99518 Date a~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 2 0~ -~ 3 3 ~;1~ • • 04-Oct-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 18-27D Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. _..:, , _ . ~,~_~ '~ CIC~ `~ ~ r,~~. Tie-on Survey: 11,624.12' MD Window /Kickoff Survey: 11,641.00' MD (if applicable) Projected Survey: 12,200.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 , ~~ , ~ , Date. ~f~vt"~Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~, ~ ~ ~ 13 3 F''(,~ STATE OF ALASKA ALASKA AND GAS CONSERVATION CO~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ^ Abandon ^ Suspend ®Operation Shutdown ^ Perforate ^ Other ^ Alter Casing ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 205-133 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22321-04-00 7. KB Elevation (ft): 53.35' 9. Well Name and Number: PBU 1 &27D 8. Property Designation: 10. Field /Pool(s): ADL 028307 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 12200 feet ~° true vertical 8635 feet ~ Plugs (measured) None /~/Q ~ Effective depth: measured 12200 feet ~~ Junk (measured) None 8,p~,~ ~~ ~^ . Q;, ~~ ~ o ~ true vertical 8635 feet , + ~~S i C ~ Q d~ G' ~~ as ng Length Size p~gllapse lp~ MD TVD B °~ Structural g~° ~~'j~~j Conductor 110' 20" 110' 110' 1490 47i7 Surface 3497' 13-3/8" 3497' 3497' 3450 1950 Intermediate 9069' 9-5/8" 9069' 8259' 6870 4760 Production Liner 998' 7" 8829' - 9827' 8110' - 8618' 7240 5410 Liner 3588' 4-1/2" 8678' - 11641' 8011' - 11588' 8430 7500 Perforation Depth MD (ft): 8710' - 8750' (Put River Appraisal) Perforation Depth TVD (ft): 8033' - 8059' 4-1/2", 12.6# L-80 8684' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer 8629' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ~~.- C4i.~tl `~ ~OQ~ 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surreys run 15. Well Class after proposed work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations ® Well Schematic Diagram 16. Well Status after proposed work: ® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. ere y certi that t e oregoing is true and correct to the est o my knowle ge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564-4387 305-288 Printed Name Terrie Hubble Title Technical Assistant ' ~ Prepared ey Name/Number: Phone ~ Signature I p Terrie Hubble, 56a-x628 564-4387 Date Form 10-404 Revised 04/2004 ~ Submit Original Only R M BP EXPLORATION Page 1 of t0 Operations'Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To I Hours Task I Code I NPT 1 Phase ~ Description of Operations 9/15/2005 00:00 - 12:00 12.00 RIGU P PRE 12:00 - 15:00 3.00 BOPSU P PRE 15:00 - 17:00 2.00 BOPSU N WAIT PRE 17:00 - 21:30 4.50 BOPSU P PRE 21:30 - 22:00 0.50 EVAL N DPRB WEXIT 122:00 - 22:15 0.25 KILL N DPRB WEXIT j22:15-00:00 1.75 KILL N DPRB WEXIT 9/16/2005 i 00:00 - 00:30 0.50 ~ KILL I N DPRB WEXIT 00:30 - 01:00 0.50 KILL N DPRB WEXIT j 01:00 - 01:20 0.33 KILL N DPRB WEXIT 01:20 - 02:20 1.00 KILL N DPRB WEXIT 02:20-04:301 2.17~KILL jP WEXIT 04:30 - 05:40 I 1.171 KILL I P I I WEXIT 05:40 - 06:30 0.83 KILL N DPRB WEXIT 06:30 - 09:50 3.33 KILL P WEXIT 09:50 - 10:10 0.33 ZONISO P WEXIT 10:10-11:00 0.83 ZONISO P WEXIT 11:00-14:00 3.00 ZONISO P WEXIT 14:00 - 14:40 0.67 ZONISO P WEXIT 14:40 - 15:30 I 0.831 ZONISO I P I I WEXIT 15:30 - 18:30 3.00 ZONISOI P WEXIT 18:30- 19:15 0.75 ZONISO P WEXIT 19:15-19:301 0.25IWHIP IP WEXIT 19:30-23:15 3.75 WHIP P WEXIT Move rig from 2-176 to 18-27D NU BOP Wait on grease crew. Test BOP's. Witnessing test waived by AOGCC Jeff Jones. Open up master & swab: 2200 psi wellhead pressure. Talk to town. Decide to kill well during drift run. Safety meeting with rig crews to discuss well kill. Test master valve RU injector & lubricator. Test inner reel valve. Get drift ready. Align manifold for bullhead. Retest kill line check valve (leak seen). OK Bleed down well to 1000 psi. Pressure built back up quickly to 2200 psi. Equalize pressure on both sides of master valve. Open up master valve. Bullhead well at 5 bpm from surface. Pressure down to 530 psi. RIH bullheading well at 5 bpm. Building up pressure due to low clearance around drift and formation charging. Bleed down pressures and open up well: well killed. RIH pumping down coil and taking returns. Monitor for gas & freeze protect. No obstructions entered. Tag liner top at 11746.9'. (-8' correction). POOH at 8 fUmin to avoid swabbing. Pump bottoms up. Take retums to tiger tank as needed. Check for flow. No Flow POH 1.5/.7 bpm took 5bbl to fill. Loss rate .3 bpm. Flow check. No Flow. MU BP, FAIV,MWD etc. RIH with bridge plug. 11395. Log tie-in. Circulate 1.56 1355 psi to inicaite MW D signal. Correction +2'. RIH to setting depth 11680. Up Wt 42K. Circulate 2.8 bpm ~ 4550 psi. for 4minutes. Bleed of pressure. Pressure 3700 psi with .8 bbls. PU to 11300 EOP flag pipe. Function test orienter. FlowCk. NO FLOW, Continue to POH. LD CIBP BHA. PU WS assembly. Install RA tag. Safety meeting for WS setting. Covered open perfs, setting parameters etc. Stab injector. RIH with WS, MWD, & Orienter. Correct +3.4' to flag. Tag CIBP ~ 11682'. Correct -2' to CIBP. PU wt: 44K Ib, SO wt: 26K Ib. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Event Name: REENTER+COMPLETE Start: 9/14/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Page 2 of 10 ~ Spud Date: 12/28/1992 End: 9/27/2005 Date From - To Hours Task Code NPT Phase Description of Operations 9!16/2005 23:15 - 00:00 0.75 WHIP P WEXIT Orient TF to 171E Pump 2.65 bpm C~3 4450 psi for 4.5 min. Shut down pumps. Bring rate up to 0.3 bbl/min, pin shear at 1400 psi, total 0.4 bbl pumped. SO until 3K Ib stacked, PU. WS set at 11660'. 9/17/2005 00:00 - 00:30 0.50 STWHIP P WEXIT Swap well over to 2 ppb bio-zan. 00:30 - 02:30 2.00 STWHIP P WEXIT POOH swapping well over to 2 ppb Bio-Zan. 02:30 - 03:30 1.00 STWHIP P WEXIT LD WS setting BHA. Rehead with Weatherford CTC. Pull test to 39K psi. 03:30 -04:30 1.00 STWHIP P ~ WEXIT PU milling BHA. Gauge Mill: 3.81 go/3.80 no-go. Gauge String Reamer: 3.80 go/3.79 no-go. 04:30 - 07:00 2.50 STWHIP P WEXIT Correct to flag. + 7.1'.RIH with window milling BHA. Tag WS at 11651 Up wt 43K, Dn wt 21 K. 07:00 - 16:30 9.50 STWHIP P WEXIT (Milling window 2.5612.56 bpm @ 2010psi FS = 1925 psi PT X326 bbls Mill to 11657 and 10' of formation to 11667. 16:30 - 18:45 2.25 STWHIP P WEXIT Ream window and dry tag. 18:45 - 20:30 1.75 STWHIP P WEXIT POOH. Swap over to reconditioned Flo-Pro. 20:30-21:00 0.50 STWHIP P WEXIT LD Milling BHA 21:00 - 21:45 0.75 DRILL P PROD1 Make up SLB CTC. Pressure test to 34K Ib. 21:45 - 22:00 0.25 DRILL P PROD1 Jet stack. 22:00 - 22:15 0.25 DRILL P PROD1 Pre-spud meeting. Discussed possible drilling hazards such as lost circulation etc. 22:15 - 23:15 1.00 DRILL P PROD1 PU build BHA. 23:15 -00:00 0.75 DRILL P PROD1 RIH. SHT orienter: good. RIH. 9/18/2005 00:00 - 01:20 1.33 DRILL P PROD1 RIH. 01:20 - 02:15 0.92 DRILL P PROD1 Tie-into shale f/ 11375'-11437'. Correct (-7'). 02:15 - 02:30 0.25 DRILL P PROD1 RIH to TD. Tag at 11662'. 02:30 -04:30 2.00 DRILL P PROD1 Drill build section. Off/On btm: 3100 psV3150 psi. TF: 132L. Control drilling. Tie-in to RA tag. WS adjusted -10'. 04:30 - 05:00 0.50 DRILL P PROD1 Orient around to 70L TF. 05:00 -06:30 1.50 DRILL P PROD1 Drill build section. Off/On btm: 3100 psi/3500 psi. PU wt: 42K Ib, SO wt: 21K Ib. TF: 75L - 90L. Wt. stacking, high motor work. 06:30 - 07:00 0.50 DRILL P PRODi Wiper trip to window. 07:00 - 07:15 0.25 DRILL P PROD1 Orient 93L 07:15 - 11:30 4.25 DRILL P PROD1 Drill build section. Off/On btm: 3100 psi/3500 psi. PU wt: 42K Ib, SO wt: 21 K Ib. TF: 90L. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Page 3 of 10 Operations Sumlmary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27!2005 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours Task Code I NPT Phase Description of Operations 9/18/2005 07:15 - 11:30 4.25 DRILL P I PROD1 Wt. stacking, high motor work. 11:30 - 14:00 2.50 DRILL P PROD1 POH at end of build and turn. 14:00 - 14:45 0.75 DRILL P ! PROD1 Dial down motor to .8 degrees 14:45 - 16:50 2.08 DRILL P PROD1 RIH 16:50 - 17:10 0.33 DRILL ~ P PROD1 Tie-in correction -6'. 17:10 - 17:30 0.33 DRILL I P PROD1 Orient 96L 17:30 - 18:30 1.00 DRILL P i PROD1 Directionally drill 2.5 / 2.5 bpm at 3250psi ,3100 psi FS.PT 290 bbls. CT wt 7K ,ROP 60. 18:30 - 18:55 0.42 DRILL N ;SEAL PROD1 Wellhead pressure 150 psi. ! I Stop and see what is causing pressure. I No cause found. Drill ahead. 18:55 - 21:15 2.33 DRILL P PROD1 Drill directional f/ 11980'-12050'. O in/out: 2.6 bpm/2.6 bpm. ~ ~ ' Pressure on/off btm: 3150 psi/3300 psi. i ~ PU wt: 37K Ib. 21:15 - 21:50 0.58 DRILL ~ P i PROD1 Wiper trip to window. i ! Debris along coil in several places. ' ! ~ Orient 1 click. 21:50 - 00:00 2.17 DRILL P PROD1 Drill directional f! 12050'-12095'. O in/out: 2.5 bpm/2.6 bpm Pressure on/off btm: 3150 psi/3500 psi. i PU wt: 38K Ib., SO wt: 21 K Ib. 9/19/2005 00:00 - 01:00 1.00 DRILL i, P PROD1 Drill directional f/ 12095'-12104'. Pressure on/off btm: 3650 psi/3350 psi. Fairly sharp increase in free spin. ~ i ROP dropping f/ 40 ft/hr to 18 ftlhr. j ~ Q in/out: 2.5 bpm/2.5 bpm. Play with WOB - no success. 01:00 - 01:15 0.25 DRILL P PRODi Wiper trip to window. 01:15 - 02:00 0.75 DRILL I P I PROD1 Attempt to drill, no success. 02:00 -04:45 2.75 DRILL N i DPRB PROD1 POOH for BHA check/change. 04:45 - 05:45 1.00 DRILL N ~ DPRB PRODi MU new bit. Change MW D. 05:45 - 08:00 2.25 DRILL N DPRB PROD1 RIH to drill lateral. 08:00 - 08:10 0.17 DRILL N DPRB PROD1 tie - in correction -10'. 08:10 - 09:00 0.83 DRILL N DPRB PROD1 RIH work shale at 11859'. 09:00 - 11:58 2.97 DRILL P PRODi Directionally drill 2.612.6 bpm at 3300 psi, 3100 psi FS. Swap to new mud. Continue drilling 2.6 / 2.6 3370 psi., FS 3200 psi. CT wt 14K, ROP 40-60. Lost pumps. 11:58 - 12:40 0.70 DRILL P PROD1 Wiper 250'. ! 12:40 - 15:30 2.83 DRILL P PROD1 Directionally drill. 2.5 / 2.5 bpm ~ 3350 psi, FS = 3100 psi. CT wt 11 K, ROP 20-30. 15:30 - 16:50 1.33 DRILL P PROD1 Wiper to window. Stacked out at 11777'. Orient to get through. 16:50 - 18:00 1.17 DRILL P PROD1 Directionally drill. 2.6 / 2.6 bpm ~ 3500 psi, FS = 3100 psi. CT wt 7K, ROP 60-90'. 18:00 - 20:00 2.00 DRILL P PROD1 Drill directional fl 12319'-12401'. Pressure oNoff btm: 3650-3400 psi/3100 psi , O in/out: 2.6 bpm/2.6 bpm 20:00 - 23:15 3.25 DRILL P PROD1 Wiper trip to tubing tail ~ 8640'. 23:15 - 23:40 0.42 DRILL P PROD1 Orient TF to LS to go through window. 23:40 - 00:00 0.33 DRILL P PROD1 RIH to TD 9/20/2005 00:00 - 03:15 3.25 DRILL P PROD1 Drill lateral f/ 12400' - 12536'. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/20/2005 00:00 - 03:15 ' 3.25 DRILL P PRODi Pressure off/on btm: 3100 psi/3450 -3550 psi. O in/out: 2.612.6 Build angle, find Z1 B for location. 03:15 - 04:15 i 1.00 DRILL P PROD1 Wiper trip to window. 04:15 -04:30 0.25 DRILL P PROD1 Orient TF to 120E 04:30 - 05:50 1.33 DRILL P PROD1 Drill lateral f/ 12536' - 12665'. Pressure off/on btm: 3100 psi/3300 psi. O in/out: 2.6/2.6 bpm. 05:50 - 06:25 , 0.58 DRILL P PROD1 Short Wiper set down at 12600. 06:25 - 06:37 ~ 0.20 DRILL P PROD1 Drill lateral f/12665'-12,685'. I Pressure off/on btm: 3100 psi/3300 psi. i ~ O in/out: 2.5/2.5 bpm. 06:37 - 08:00 i 1.38 DRILL ~ P PROD1 Wiper to window. Motor work at 11880 & 11820 while POH. I RIH to TD. 08:00 - 09:00 1.00 DRILL N DPRB PROD1 Wiper to tubing tail while waiting discussion on plan forward. 09:00 - 10:00 1.00 DRILL N DPRB PROD1 Wipe back to bottom. Run thru window no problem. Losing priority pressure on the power pack. Pull back above window 10:00 - 14:30 4.50 ~ DRILL N RREP PROD1 Wait on mechanic to investigate power pack pump failure. I Replace priority pump. 14:30 - 15:00 0.50 i DRILL P PROD1 RIH to TD. 1 Orient to 170R on way down. 15:00 - 16:50 1.83 DRILL P PROD1 Drill lateral f/ 12685' - 12803'. Pressure offlon btm: 3200 psi/3500 psi O: 2.6 bpm/2.6 bpm 16:50 - 19:30 2.67 DRILL P PROD1 POOH drilling BHA#6 to reset motor bend. 19:30 - 20:15 0.75 DRILL P PROD1 OOH. PJSM. S/B injector. Inspect orienter & motor - OK. I Check bit -grade: 1/21/1 with 1 plugged jet & slight balling on the gauge junk slot. UO bit. Changeout MWD probe & reset motor bend to 1.5degs. 20:15 - 20:45 0.50 DRILL P PROD1 M/U drilling BHA #7 with 1.5deg X-creme motor, MWD/GR, orienter & rebuilt HCC RWDSTR 3-3/4" x 4-1/8" bicenter bit #5. Scribe tools & M/U injector. 20:45 - 23:00 2.25 DRILL P PROD1 RIH drilling BHA #7 to 11695' (below window). 23:00 - 23:10 0.17 DRILL P PROD1 Log up GR & tie-into RA Pip tag -subtract 11' from CTD. 23:10 - 23:40 0.50 DRILL P PROD1 RIH relatively clean to btm tagged ~ 12817'. 23:40 - 23:50 0.17 DRILL P PROD1 Shoot off btm directional surveys. 23:50 -00:00 0.17 DRILL P PROD1 Orient TF around. 9/21/2005 00:00 - 00:10 0.17 DRILL P PROD1 Orient TF around to 130L. P/U wt = 41 k, S/O wt = 17k. PVT = 278bb1s. 00:10 - 00:30 0.33 DRILL P PROD1 Drill to 12835' with 125E TF, 2.5/2.5bpm, 3400/3550psi, 3k WOB & 80fph ave ROP. 00:30 - 01:00 0.50 DRILL P PROD1 Orient 2 clicks & drill to 12869' with 80-95L TF, 2.6/2.6bpm, 3400/3550psi, 4k WOB & 90fph ave ROP. 01:00 - 03:00 2.00 DRILL P PROD1 Drill to 12942' with 60L TF, 2.5/2.5bpm, 3400/3850psi, 4k WOB & 60fph ave ROP. 03:00 -04:15 1.25 DRILL P PROD1 Wiper trip to window. 04:15 -04:30 0.25 DRILL P PROD1 Orient TF 90L. 04:30 -06:00 1.50 DRILL P PR001 Drill to 12984' with 80-105L TF, 2.5/2.5bpm, 3400/3850psi, 4k WOB & 40fph ave ROP. Wt stacking. 06:00 - 10:00 4.00 DRILL P PROD1 Drill f/ 12984'-13101'. Pressure on/off btm: 3700-4000 psi/3400 psi O in/out: 2.6/2.6 bpm. PU wt: 37K Ib, SO wt:19K Ib ,Drilling wt: 4K-OK Ib. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Event Name: REENTER+COMPLETE Start: 9/14/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Page 5 of 10 ~ Spud Date: 12/28/1992 End: 9/27/2005 Date From - To Hours Task Code NPT Phase Description of Operations 9/21/2005 10:00 - 12:40 2.67 DRILL P PROD1 Wiper trip to tubing tail. Some minor overpulls f/ 11815' - 13101'. 12:40 - 13:15 0.58 DRILL P PROD1 Orient TF to 116E 13:15 - 14:35 1.33 DRILL P PROD1 Drill f/ 13101 - 13189' Low ROP until last 40'. 14:35 - 14:55 0.33 DRILL P PROD1 Orient TF to 130L. 14:55 - 16:45 1.83 DRILL P PROD1 Drill f/ 13189' - 13306'. 16:45 - 17:30 0.75 DRILL P 17:30 - 18:15 0.75 DRILL P 19/22/2005 18:15 - 18:45 18:45 - 20:15 20:15 - 20:30 20:30 - 22:00 22:00 - 22:15 22:15 - 22:30 22:30 - 00:00 00:00 - 03:00 03:00 - 03:35 03:35 -06:00 0.50 DRILL P 1.50 DRILL P 0.25 DRILL P 1.501 DRILL I P 0.25 DRILL P 0.25 DRILL P 1.50 DRILL P 3.00 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 0.58 DRILL P PROD1 2.42 DRILL N DPRB PRODi 06:00 - 07:30 I 1.50 ~ DRILL I N I DPRB I PROD1 07:30 -09:30 2.00 DRILL N DPRB PROD1 09:30 - 10:20 0.83 DRILL N DPRB PRODt 10:20 - 10:40 0.33 BOPSU P PROD1 10:40 - 12:00 1.33 DRILL X WAIT PROD1 12:00 - 14:15 2.25 DRILL X WAIT PROD1 14:15 - 14:45 0.50 DRILL C PROD1 14:45 - 15:00 0.25 DRILL C PROD1 Start mud swap to fresh Flo-Pro. Pressure on/off btm: 3550 psi/3250 psi - 2900 psi. O in/out: 2.6/2.6 bpm PU wt: 38K Ib, SO wt: 15K Ib, Drilling wt: 6K Ib - 4K Ib. TF: 90-100L Wiper trip to window. Log up f/ 11695' - 11654 Tie-into RA tag. Correction: +17.5 RIH to TD tagged ~ 13317'. P/U wt = 39k, S/O wt = 16k. PVT = 293bb1s. IAP = 250psi. OAP = 240psi. Drill to 13375' with 80L TF, 2.5/2.5bpm, 3000/3400psi, 8k WOB & 40fph ave ROP. Should be ~ +/-8697'sstvd. Orient TF to HS. Geo wants to start drilling up to establish well control points. Plan is to build & cross cut back up thru Zone 1A C~ +/- 100degs incl. Drill to 13412' with HS TF, 2.5/2.5bpm, 3200/3400psi, Sk WOB & 20fph ave ROP. Stacking wt. Short 300' wiper. Drill to 13445' with HS TF, 2.5/2.5bpm, 3200/3400psi, 8k WOB & 20fph ave ROP. Finished build to +/-100degs. Wiper trip. Wiper trip. Had 30k O/pull ~ 11875' with motor work. RBIH & backream shale clean. Continue wiper tripping to 8500'. RBIH below window to 11695'. Log up GR & tie-into RA Pip tag -add 14' to CTD. RBIH & set down several times in shale ~ 11950'. Attempt to bounce thru tight spot without luck. Orient to as drilled TF -not getting clicks. PUH & able to orient to 100E while RIH. RBIH & set down ~ 11953'. Ream thru tight spot to 11965' with no motor work & +/-1k WOB. Backream to 11830'. RBIH & ream down from 11850'. Observe motorwork ~ 11856'. PUH to i 1700' & orient to as drilled TF of 50L. Attempting to get thru 11855'. Orient TF to 50L. Stacking out at 11855' no matter what method was tried. POOH for BHA change to accomodate doglegs at tight spot. LD BHA. Change out MWD for memory download. Equipment damage downhole: Orienter bent. HCC bicenter bit: 1/1/BT/G/X/I/CT/HP Function test BOPE: OK Wait on orders from town. Wait on SLB memory loggers to arrive. Rig up SLB memory loggers. Safety meeting with SLB memory loggers. Printed: 10/312005 3:02:00 PM BP EXPLORATION Page. s of 10 Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contrac#or Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of_Operations 9/22/2005 14:45 - 15:00 0.25 DRILL C PROD1 Topics: Weather, radiation. 15:00 - 16:00 1.00 EVAL IC PROD1 PU SHA 16:00 - 17:40 1.67 EVAL i C PROD1 Depth check at surface. Depth check 1000'. R I H to 9450'. 17:40 - 19:00 1.33 EVAL C PROD1 Log down ~ 30 fUmin from 9450' & set down ~ 11854'. 19:00 - 19:45 0.75 EVAL C PROD1 Log up ~ 60fpm from 11854' to 9450'. 19:45 - 21:30 1.75 EVAL C PROD1 Paint EOP flag ~ 8500' & POOH logging BHA#8. 21:30 - 21:45 0.25 EVAL C PRODi PJSM for UD logging BHA. 21:45 - 22:15 0.50 EVAL ~ C PROD1 S/B injector. R/B 1 std of 2-3/8" PH6 tbg CSH & UD SWS MCNUCCUGR logging tool carrier. Check log data quality - OK. 22:15 - 22:30 0.25 EVAL i C PROD1 M/U Cementing BHA#9 with 3.0" big hole nozzle, 6' x 2-3/8" PH6 pup, XO, MHA &CTC (OAL - 11.32') 22:30 - 00:00 1.50 CLEAN C PROD1 RIH with cementing BHA#9. Correct CTD +10' ~ the flag. 9/23/2005 00:00 - 02:00 2.00 CLEAN I C i PROD1 Continue RIH with cementing BHA#9. Wt chk ~ 11800' - Up = ~ 40k, Run-in = 21 k. RIH jetting 2% KCL thru nozzle. Jet thru '~ tight spot ~ max rate with slight wt bobbles &RIH clean to 12150'. Wt chk ~ 12150' - Up = 42k, Run-in = 23k. Swap back to flopro & continue RIH. Wt check ~ 12650' - OK. RIH & set ~ ~ down 3x C~3 13398'. Review situation with ANC & decide to make a cleanout run before RIH with completion liner. 02:00 -04:30 2.50 CLEAN X DPRB PROD1 POOH with nozzle BHA #9. O/pull & 13150', 12200', 12120', 11910' & 11880'. Work CT with max 80k pull ~ 11880' & pull free. 04:30 - 06:15 1.75 CLEAN N DPRB ~ PROD1 POOH with nozzle BHA. 06:15 - 06:30 0.25 CLEAN ~ N DPRB PROD1 LD nozzle BHA. 06:30 - 07:30 1.00 CLEAN ~ N DPRB PROD1 PU build cleanout BHA. Hycalog bicenter, 3.0 degree mtr, MWD. 07:30 - 09:30 2.00 CLEAN N DPRB PROD1 RIH. 09:30 - 10:00 0.50 EVAL N DPRB PROD1 Tie-in to RA tag. Correct (+7.5'). 10:00 - 13:00 3.00 CLEAN N DPRB PROD1 RIH to 11850. Attempt pass obstruction by orienting. Attempt to work through obstruction with low motor work, high ROP. No progress made, town called well. 13:00 - 13:30 0.50 EVAL N DPRB PROD1 Tie-in to RA tag. Correct (+1'). 13:30 - 15:30 2.00 CLEAN N DPRB PROD1 POOH. Paint flag. 9600' EOP. 15:30 - 16:30 1.00 CLEAN N DPRB PROD1 Set back injector. LD BHA. 16:30 - 18:30 2.00 CASE N WAIT RUNPRD Load 2-3/8" liner. Tally & drift same. 18:30 - 19:00 0.50 CASE P RUNPRD Install Baker CTC. Pull test to 35k & pressure test to 3500psi - OK. 19:00 - 20:00 1.00 CASE P RUNPRD Install dart catcher. Load wiper dart. Launch & chase with mud to pig CT. Dart hit ~ 51.8bbls. 20:00 - 20:30 0.50 CASE P RUNPRD RU to run liner. 20:30 - 20:45 0.25 CASE P RUNPRD Held PJSM on M/U &RIH with liner. 20:45 - 23:30 2.75 CASE P RUNPRD M/U 2-3/8' STL indexing guide shoe, float collar, 1 shoe jt, float collar, spacer pup & landing collar. M/U & drift 56jts of 2-318" STL 4.7# L-801iner. Printed: 70/372005 3:02:00 PM `.'BP .EXPLORATION Page 7 of 10 Operations .Summary Report.. Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/23/2005 23:30 - 00:00 0.50 CASE N WAIT RUNPRD Load 12 additional joints of 2-3/8" liner. Tally & drift same. 9/24/2005 00:00 - 01:00 1.00 CASE P RUNPRD Continue M/U & drift 12jts of 2-3/8" STL 4.7# L-80 liner. M/U XO, 3-1/2" STL pup & Baker Deployment sleeve. M/U CTLRT & injector. 01:00 - 03:00 2.00 CASE P RUNPRD RIH with liner (OAL - 2167.94') on CT. Correct +18' C~3 the flag. Check up wt - 40k, down wt - 19k. Continue RIH ~ +/-40fpm. Set down ~ 11876'. P/U, RBIH & bounce thru. Set down ~ 11886'. 03:00 - 05:30 2.50 CASE N DPRB RUNPRD Work liner without progress. Pump down 1 coil volume of 2% KCL water. Park shoe ~ 11884' & jet ~ 1.77bpm/1285psi - no Tuck. Discuss situation with ANC & decide to POOH for cement plugback. 05:30 - 08:00 2.50 CASE N DPRB RUNPRD POOH with completion liner BHA#11. 08:00 - 08:30 0.50 CASE N DPRB ,RUNPRD LD deployment tools. 08:30 - 11:45 325 CASE N DPRB RUNPRD Rack back liner w/ cementrilizers. 1 LD liner without cementrilizers. ~ Slow drawworks coming down. Both dog collars needed repair in middle of operation. 11:45 - 13:30 1.75 STKOH C PROD1 PU PH6 for BHA. Behead CTC f/ Baker to SLB. Stab injector. 13:30 - 16:45 3.25 STKOH C PROD1 RIH. 16:45 - 17:15 0.50 STKOH C ~ PRODi Tag at 11866'. Correct to 11886'. Flag pipe to 11876'. Wt check: 40K Ib. POOH to 11600. RIH to 11886'. Clean. PU to 11630'. Displace well to 2% KCI. ~ I One gas burp, 28% LEL. RU cmters. 17:15 - 17:45 0.50 STKOH C ~ PROD1 Safety meeting with SLB cmters. 17:45 - 19:00 1.25 STKOH C PROD1 Prime up. Flush/PT lines to 4k. Jet wellbore from 11886' to 11350' ~ 3.5bpm/1040psi. RBIH & park nozzle ~ 11630'. 19:00 - 19:40 0.67 STKOH C PROD1 Pump 5bbls of water ahead. Mix & pump 8bbls 17ppg class-G cmt with additives ~ 1.6/1.6bpm & 1420psi. Cmt to wt ~ 19:08hrs. Pump 5bbls of water behind. Isolate cementers & clean lines. Chase with KCL ~ 2.6/2.6bpm & 1950psi - 570psi. RBIH & park nozzle ~ 11876'. Pump out lbbl of cmt past nozzle & lay-in 7bbls of cmt 1:1 to TOC ~ 11350'. 19:40 - 20:10 0.50 STKOH C PRODi POOH to safety ~ 10600' circ down bio-KCL ~ min rate with 150psi WHP. 20:10 - 20:30 0.33 STKOH C PROD1 RBIH circ down 60bbls of bio-KCL pill to the nozzle. 20:30 - 21:00 0.50 STKOH C PROD1 RBIH ~ 30fpm circ ~ 3.0/3.Obpm & 1320psi jetting down to 11680'. Make 3 up/down passes with bio-KCL fluid across the window. Jet up hole to 11350' & jet back in hole to 11680'. 21:00 - 23:15 2.25 STKOH C PRODi Jet OOH with nozzle. 23:15 - 23:45 0.50 STKOH C PROD1 OOH. PJSM. S/B injector. L/D cement nozzle BHA. M/U swizzle stick & stab injector on well. SI master valve. 23:45 -00:00 0.25 STKOH C PROD1 Jet BOP stack ~ max rate. 9/25/2005 00:00 - 00:30 0.50 STKOH C PROD1 Continue jetting BOP stack & surface lines ~ max rate. 00:30 - 01:30 1.00 DRILL C PROD1 M/U drilling BHA #13 with 2.4deg X-treme motor, MWD/GR, orienter & rebuilt Smith M0980PX 3-3/4" PDC bit #6. Scribe tools & M/U injector. 01:30 - 03:30 2.00 DRILL C PROD1 RIH drilling BHA #13 to 11370'. 03:30 -04:30 1.00 DRILL C PROD1 Log down GR & tie-into formation marker ~ 11370' -add 5' to Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours Task Code NPT Phase Description of Operations 9/25/2005 03:30 - 04:30 1.00 DRILL C PRODi CTD. 04:30 - 10:00 5.50 DRILL C PROD1 Park bit ~ 11402' & W. O. C. to get to 2000psi compressive strength. Swap over to Flo-Pro. 500 psi ~ 0800 hrs. 2000 psi ~ 1000 hrs. 10:00 - 11:30 1.50 DRILL C i PROD1 RIH to TD. Establish cement depth at 11671'. Motor work f/ 11671' - 11685'. I Drill C°3 30 fUhr f/ 11685' - 11690'. 11:30 - 15:15 ~ 3.75 DRILL C PROD1 Time drill f/ 11690' - 11703'. I ' Building at 0 degrees TF. 15:15 - 16:15 1.00 ~ DRILL C i PROD1 Orient TF to 90L. ~ ~ , ~ Problem with trapped torque on orienter. 16:15 - 16:45 i 0.50 DRILL I C j i PROD1 Drill directionally and sand lateral. Pressure off/on btm: 3000 psi/3100 psi. ' O in/out: 2.5/2.5 bpm. 16:45 - 17:45 1.00 DRILL C ! PROD1 Orient TF to 135L. Difficulty orienting. 17:45 - 18:35 0.83 DRILL ~C ~ PROD1 Drill directionally ~ i !Pressure off/on btm: 3000 psi/3450 psi. O in/out: 2.6/2.6 bpm TF: 115E 18:35 - 21:35 3.00 DRILL C ~ i PROD1 i PUH above window & orient TF 139R. TF flopping to HS once ~ on btm. Orient & reorient but TF still flipping to HS. Finally orient TF to 140R. 21:35 - 22:00 0.42 DRILL C j i PROD1 Drill to 11791' with 130R TF, 2.5/2.5bpm, 3000/3450psi, 3k I I WOB & 60fph ave BOP. Drilling 3' & orienting 1 click to work TF to LHS. 22:00 - 22:15 0.25 DRILL C PROD1 PUH & orient TF to 125L. 22:15 - 22:35 0.33 DRILL C PROD1 Drill to 11823' with 135E TF, 2.6/2.6bpm, 3000/3550psi, 3k WOB & SOfph ave BOP. 22:35 - 00:00 1.42 DRILL C PROD1 PUH above window & orient TF to 55L. RBIH to btm. 9/26/2005 00:00 -00:30 0.50 DRILL C PROD1 Drill to 11884' with 80-90L TF, 2.6/2.6bpm, 3000/3550psi, 3k WOB & 120fph ave BOP. 00:30 -00:50 0.33 DRILL C PROD1 PUH above window & orient TF to 45L. RBIH to btm. 00:50 - 01:30 0.67 DRILL C PROD1 Drill to 11900' with 70-80L TF, 2.6/2.6bpm, 3000/3550psi, 3k WOB & 30fph ave BOP. 01:30 - 03:50 2.33 DRILL C PROD1 POOH to cut CT for fatigue management. Currently ~ 98% CT life due to repeated orienting above the window. 03:50 -04:30 0.67 DRILL C PRODi OOH. PJSM. S/B injector. C/O orienter. Check motor & bit ' OK. 04:30 -04:45 0.25 DRILL C PROD1 Held PJSM for curtting CT. ~i 04:45 - 05:30 0.75 DRILL C PRODi R/U hydraulic cutter & cut 400' of CT. Have 13362' of CT left on the reel. 05:30 -06:00 0.50 DRILL C PROD1 Behead & M/U SLB CTC. Pull test to 35k & pressure test to ~, 3500psi - OK. 06:00 -06:30 0.50 DRILL C PRODi M/U drilling BHA #14 with 2.4deg X-treme motor, MWD/GR, orienter & used Smith M0980PX 3-3/4' PDC bit #7. Scribe tools & M/U injector. 06:30 - 08:30 2.00 DRILL C PROD1 RIH to TD. 08:30 - 10:00 1.50 EVAL C PROD1 Tie-in f/ 11695' up. Correction (+16'). 10:00 - 10:45 0.75 DRILL C PROD1 Attempt to orient to 70L. Difficulty orienting. Printed: 10/3/2005 3:02:00 PM $P EXPLORATION Page 9 of t0 Operations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/26/2005 10:00 - 10:45 0.75 DRILL C PROD1 Going up, small~to no clicks. Going down/on btm, 10-20 degrees/click. 10:45 - 11:30 0.75 DRILL C PROD1 i Drill build f/ 11916'-11985'. Pressure off/on btm: 3050 psi/3200 psi. O in/out: 2.512.5 bpm PU wt: 35K Ib, SO wt: 18K Ib, on btm: 8K Ib. TF: 68L 11:30 - 12:00 0.50 DRILL C PROD1 Orient TF to 120E 12:00 - 13:00 1.00 DRILL C PROD1 Drill build f/ 11985' - 12026'. ~ Pressure off/on btm: 3000 psi/3500 psi. O in/out: 2.5/2.5 bpm 13:00 - 13:10 0.17 DRILL C PROD1 ~ Orient TF to 75L. 13:10 - 13:45 0.58 DRILL C PROD1 ~ Drill build f/ 12206'-12076' j ~ Pressure off/on btm: 3000 psi/3500 psi. ~ ~ O in/out: 2.5!2.5 bpm. ~ 13:45 - 14:15 0.50 DRILL C PROD1 ~ Wiper trip to window. 14:15 - 16:30 2.25 DRILL C PROD1 Drill build f/ 12076'-12200'. j Pressure off/on btm: 2950 psi/3450 psi. O 2.612.6 in/out: bpm. PU wt: 38K Ib., SO wt: 18K Ib., On btm: 10K Ib. TF: 70L. 16:30 - 18:45 2.25 DRILL C PROD1 Finish build at 12200'. Hope for wind to drop for reel swap after POOH. I Cranes/N2 called out. 18:45 - 19:15 0.50 DRILL C PROD1 OOH. PJSM. S/B injector. Check orienter, motor & bit - OK. 19:15 - 19:30 0.25 DRILL C ~ PROD1 Held PJSM with Peak crew to discuss the possibility of reel swap. Call off reel swap operations due to high winds -steady 15-18mph & gusting ~ 24-27mph. 19:30 - 20:30 1.00 DRILL C PRODi M/U lateral BHA #15 with 1.5deg X-treme motor, MWD/GR, orienter & rebuilt Hycalog DS49 3-3/4' PDC bit #8. Scribe tools & M/U injector. 20:30 - 22:35 2.08 DRILL C PROD1 RIH lateral BHA #15. SHT MWD - OK. SHT orienter -getting only 10deg clicks. RIH to below window. 22:35 - 23:10 0.58 DRILL C PROD1 Log up GR & tie-into RA Pip tag -add 4' to CTD. 23:10 - 23:25 0.25 DRILL C PROD1 RIH & set down in shale ~ 12128'. P/U drop pumps & bounce thru. RIH & tag TD ~ 12200'. 23:25 - 00:00 0.58 DRILL C PROD1 Attempt to orient TF. Observe +/-650psi loss in circ pressure. Also not getting MWD signals. Suspect pinhole in CT. 9/27/2005 00:00 - 00:30 0.50 DRILL X DFAL PROD1 PUH & observe pin-hole in CT ~ 11125'. 00:30 - 01:00 0.50 DRILL X DFAL PROD1 Held PJSM for inspecting CT to determine if to cut & rejoin with double grapple or continue spooling onto reel. 01:00 - 01:45 0.75 DRILL X DFAL PROD1 Set upper 2-3/8' combis. Slack off & test slips holding _ OK. Strip up injector. Set die collar on CT. Inspect pinhole & decide to spool onto reel. 01:45 -03:45 2.00 DRILL X DFAL PROD1 Gently spool pinhole onto reel & continue POOH CT. 03:45 -04:30 0.75 DRILL X DFAL PROD1 OOH. PJSM. S/B injector. UD lateral BHA#15. 04:30 - 05:15 0.75 DRILL X DFAL PROD1 SI Master. Pump 45bbls of fresh water thru CT & follow with 10bbls of McOH spacer. 05:15 - 05:30 0.25 DRILL X DFAL PROD1 PJSM for B!D CT with N2. 05:30 -06:30 1.00 DRILL X DFAL PROD1 P/Test N2 lines - OK. B/D CT with N2 & bleed off. 06:30 -06:45 0.25 DRILL X DFAL PROD1 PJSM for stripping off & pulling back CT to the reel. 06:45 - 09:00 2.25 DRILL X DFAL PROD1 Slip connector into CT & pull test. Strip-off CT from injector & spool back to reel. Secure CT & prep reel for shipment. Printed: 10/3/2005 3:02:00 PM BP EXPLORATION Page 10 of 10 0:perations Summary Report Legal Well Name: 18-27 Common Well Name: 18-27 Spud Date: 12/28/1992 Event Name: REENTER+COMPLETE Start: 9/14/2005 End: 9/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 9/27/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code. NPT Phase Description of Operations 9/27/2005 09:00 - 09:15 0.25 DRILL X DFAL PROD1 R/U & PJSM for BOPE testing. 09:15 - 13:00 3.75 DRILL X DFAL PROD1 Perform weekly BOPE pressure/function test. AOGCC test witnessed by Lou Grimaldi. Suspend BOP P/test for move to W-39. 13:00 - 15:30 2.50 WHSUR X DFAL POST N/D BOP. N/U & pressure test tree cap. , 15:30 - 17:00 1.50 CLEAN X DFAL POST Cleanout pits. Release rig ~ 17:00 on 9/27/05. Printed: 10/3/2005 3:02:00 PM TREE = 4-1/16" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 53.35' BF. ELEV = NA KOP= 11641' Max Angle = 93° @ 1220^' Datum MD = WA Datum TV D = 8800' SS ~ 13-3/8" CSG, 68#, L-80, ID = 12.415" ~ ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf , ID = 3.958" ~--~ 8629' Minimum ID = 3.812" @ 2223' 4-1/2" CAMCO BAL-0 SSSVN PERFORATION SUMMARY REF LOG: SWS MEMORY GFZ'CCL ON 10/04100 ANGLE ~~T TOP PERF 4P ';r? 8710' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 8710 - 8750 O 2" 4 12870-14170 S 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 9075' ~2 7 D S OTES: WELL ANGLE> 70° @ 9830' 8 > CTD Sidetrack so° @ 1o1oa'. ORIdNAL 18-27 WELLBORE NOT SHOWN BELOW 7" LNR MILLOUT WINDOW 9827' (18-27A). 2223' 4-1/2" CAMCO BAL-O SSSVN. ID = 3.812" MECHANICAL WHIPSTOCK ~~ 11641' WINDOW 11641' - 11647' RA PIP TAG 11650' 11739' TOPOF 2-7/8" LNR, ID= 2.377" 4-1/2" LNR 12.6#, L-80, IBT, ID= 3.958" 1s-27C 12266' MILL OUT WINDOW (WHIPNOT SHOWN) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2986 2966 1 MMG DOME RK 16 02/28/05 2 5308 5198 28 MMG DOME RK 16 02/28!05 3 7260 6897 30 MMG DOME RK 26 02/28/05 4 8439 7839 40 MMG SO RK 22 02/28/05 ~ 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" ~ I 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" X 7" BKR ZXP PKR ID = r, ;;^° H699' ~ i" X 4..112" XO. ID - 3.937" ) 4-?/2" NES X N~ fD= 3.8?3" ~ 10{1ill;£''," I-i II-'112" HES X NIP., ID = 3.$13" i7~1 SIDETRACK 4-1/4" X 3-3/4" OH I 11886' t 12200' ~--{ S/T HOLE TD ~ ~ 1/8" DATE REV BY COMMENTS DATE REV BY COMMENTS 02/23/93 ORIGINAL COMPLETION 09/13/03 CMO/TLP DATUM MD/TVD 8 PERF ANGL 04/11/98 RIG SIDETRACK (18-27A) 03/04/05 RAGTLH GLV GO 11/01/98 CTD SIDETRACK (18-276) 04/01/05 LDK/TLH PERFS (03/31/05) 10/18/00 CTD SIDETRACK (18-27C) 08/19/05 MSE PROPDSED CTD SIDETRACK 11/23/01 CHITP CORRECTIONS 09.%28rG5 JUE NORDIC 1 CTD SIDETRACK 06/15/03 CMO/TLP MAX ANGLE CORRECTION 13445' ~ PLUG BACK #1 TD PRUDHOE BAY UNR WELL: 18-27D PERMR: 205-133 API No: 50-029-22321-04 SEC 24, T11 N, R14E, 893' SNL & 236' WEL BP Exploration (Alaska) • ice. .~ ?~ ~ y ! ~ ,.~, ~... ~. ~, '~ ~. ALA.SSA OII, A1~TD GAS CO1~T5ER~ATI011T CO1~IIrIISSIOr1T Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU 18-27D Sundry Number: 305-288 Dear Mr. McLaughlin: L~ l FRANK H. MURKOWSKI, GOVERNOR N° 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 a,~" ~~ 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. 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) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of October, 2005 Encl. Sincerely, STATE OF ALASKA ~ ~~ ~a/.~15. ALASKA AND GAS CONSERVATION COM ISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ^ Abandon y-®-Suspend Operation Shutdown ^ Perforate ^ Other _ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspenc I ~`~ ~~ ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension~'~p, !,~" ~~~~~ ~ ~ ~ ~ a • 2. Operator Name: 4. Current Well Class: 5. Permit To ~u~ber BP Exploration (Alaska) Inc. ~ ®Development ^ Exploratory < 205133 ~ ~`~~ G' 3. Address: ^ Stratigraphic ^ Service 6. API Number: @ SS%p P.O.Box196612,Anchorage,Alaska 99519-6612 50-029-22321-04-00 7. KB Elevation (ft): 53 35 9• Well Name and Number: . PBU 18-27D ~ 8. Property Designation: 10. Field /Pool(s): ADL 028307 Prudhoe Bay Field / Prudhoe Bay Pool 11'. PRESENT WELL CO NDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12200 8635 12200 8635 None None Casin Len th Size MD TVD Burst Colla se tr trl 110' 20" 110' 110' .1490 470 rf 3497' 13-3/8" 3497' 3497' 3450 1950 9069' 9-5/8" 9069' 8259' 6870 4760 P i Lin r 998' 7" 8829' - 9827' 8110' - 8618' 7240 5410 Liner 3588' 4-1/2" 8678' - 11641' 8011' - 11588' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8710' - 8750' 8033' - 8059' 4-1/2", 12.6# L-80 8684' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker 'S-3' packer; Packers and SSSV MD (ft): 8629' 4-1/2" Camco'Bal-O' SSSV Nipple 2223' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program ,..,, 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Septem r 27 •'2005 ®Oil ^ Gas ^ Plugged ^ Abandoned 16. Verbal Approval: Da ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Re resentative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer // /~ ,~ Prepared By Name/Number: ri H 4628 T bbl 564 °s ~ ° ° ~ ~ er e u e, - Si nature J/ / ~ Phone 564-4387 Date ~S ' Commission Use Only Sundry Number: ~~~ ~ ~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance BFI ~ CT ~ ~ 2005 Other: ~ ~ t~e~c~ ~~~`' Subsequent For e J' ~d APPROVED BY ~~ THE COMMISSION 0 Approve COMMISSIONER Date Form 10-403 Rid 00 '°'~ ~ Su~mit!'~i Duplicate (^" ~ ~~<<~~~~ U To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: September 28, 2005 Re: 18-27D -Suspend Well C by j ) As allowed under 20 AAC 25:-1-~6 BP is applying to-snspe~ well operations on 18-27D. A lateral was placed in zone 1 as planned but only shale was found. That hole was eventually lost due to uncontrollable swelling shales. An OHST was performed at 11690' and the well was drilled to 12200' with only a minimal amount of pay. At this time the coil developed a pinhole leak. We are unable to swap coil strings due to high winds. The plan forward is to move on to W-39A while we regroup and evaluate options on 18-27D. This well remains a candidate for redrilling. BP also requests to not plug the well and leave the well uncompleted. Adding a completion will add no value and would limit future options. There is value to leaving the window unobstructed as it could be used for future drilling operations. Likewise, plugging the well would limit future operations. Currently 560' of Zone 1B and 40' of Put river perforation are open. There is a wellhead installed that will meet barrier requirements. BP asks ~` the commission to waive the requirement of a bridge plug capped with SOft of cement in this case. The level of activity and surveillance on DS 18 are sufficient to adequately monitor the well. Sean McLaughlin CTD Engineer 564-4387 -~ /~.~C? W Gu V ~G. y^ h.GC,P~„t q, rs~-~ ~ v ©j'J ~ S ~.~~ ~ ,,~, , 1 1~1G ~`~ r~~3~~~s CC: Well File Sondra Stewman/Terrie Hubble TREE= 4-1/16" FMC: WELLHEAD = FMC ACTUATOR = BAKER C KB. E1EV = 53.35' BF. ELEV = NA KOP= 11641' Max Angle = 93° @ 12200' Datum MD = WA Datum TV D = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" ~-~ 3497' 4-1/2" TBG, 12.6#, L-80, .0152 bpf , ID = 3.958" Minimum ID = 3.812" @ 2223' 4-112" CAMCO BAL-O SSSVN PERFORATION SUMMARY REF LOG: SWS MEMORY GIZ~CCL ON 1G/04/00 ANGLE AT TOPPERP ?~ ~~~' 3?10' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 8710 - 8750 2" 4 12870-14170 S 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9075' MECHANICAL WHIPSTOCK 11 11641' WINDOW 11641' - 11647' RA PIP TAG 11650' ~3~ TOPOF 2-7/8" LNR, ID= 2.377' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2986 2966 1 MMG DOME RK 16 02/28/05 2 5308 5198 28 MMG DOME RK 16 02/28/05 3 7260 6897 30 MMG DOME RK 26 02/28/05 4 8439 7839 40 MMG SO RK 22 02/28/05 8629' 9-5l8" X 4-1/2" BKR S-3 PKR, ID = 3.875" t-i~-w::: ~~ _.' ~1sS -: NIP. ID - 3 1311;'. 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" X 7" BKR ZXP PKR. ID = 6 3C" 8699' -j 7" X 4-y2" XC ~D = 3.9 ~, ~ 4-?l2" MES X fVIP, ID= 3.8?3" ~ 1000 t: I-i 4-112" HES X NIP, ID = 3.813 11671' -i SIDETRACK POINT 4-1/4" X 3-3/4" OH 12200' SiT HOLE TD 11886' ~-i BTM OF CMT PLUG 4-1/2" LNR 12.6#, L-80, IBT, ID= 3.958" 18-27C I I 12266' MILL OUT WINDOW (WHIP NOT SHOWN) DATE REV BY COMMENTS DATE REV BY COMMENTS 02/23/93 ORIGINAL COMPLETION 09/13/03 CMOlTLP DATUM MD/TVD & PERF ANGL 04/11/98 RIG SIDETRACK (18-27A) 03/04/05 RAGTLH GLV GO 11/01/98 CTD SIDETRACK (18-276) 04/01/05 LDKlTLH PERFS(03/31/05) 10/18/00 CTD SIDETRACK (18-27C) 08/19/05 MSE PROPOSED CTD SIDETRACK 11/23/01 CHITP CORRECTIONS 09/28/05 JUE NORDIC-1 CTD SIDETRACK 06/15/03 CMO/TLP MAX ANGLE CORRECTION 1/8" 13445' H PLUG BACK #1 TD I PRUDHOE BAY UNIT WELL: 18-27D PERMrr: 205-133 API No: 50-029-22321-04 SEC 24, T11 N, R14E, 893' SNL 8 236' WEL BP Exploration (Alaska) 8 ~2 7 D S NOTES: WELL ANGLE > 70° @ 9830' & > CTD Sidetrack 90° @ 10104'. ORIGINAL 18-27 WELLBORE NOT SHOWN BELOW 7" LNR MILLOUT WINDOW @ 9827' (18-27A). ® 222$' 4-1l2" CAMCO BAL-O SSSVN, ID = 3.812" GAS LIFT MANDRELS ~ ~ t ~ ~~ t ~~ y ~ ; ~ ~ { ~ / ` 3 ~ ~ ~ ~ ~ ~ ~ ~jfi '°~~ ' ~~~~ ~~~~-y , ~ ~.~~ ~ ~ '~ . ~~ ~'~i ~ FRANK H. MURKOWSKI, GOVERNOR d~-7~ OIL ~ v1>•.a7 333 W. 7TM AVENUE, SUITE 100 COI~TSERQATIOI~T COAiI-~IIS$IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe 18-27D BP Exploration (Alaska) Inc. Permit No: 205-133 Surface Location: 893' FNL, 236' FEL, SEC. 24, T 11 N, R 14E, UM Bottomhole Location: 534' FNL, 4276' FEL, SEC. 24, T 11 N, R 14E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petrole ~ eld inspector at (907) 659- 3607 (pager). ~~ in ~h~ K. N Cha~irr z DATED thi~ day of September, 2005 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. r~Gr~- q j~/i~a~° STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ~ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. Z S /erg 3 11. Well Name and Number: z 6,3a -2; PBU 18-27D q~z~ Z°"'s 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~, MD 13850 TVp 8688ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 893' FNL 236' FEL SEC 24 T11 N R14E UM 7. Property Designation: ADL 028307 Pool , , . , , , Top of Productive Horizon: 896' FSL, 191' FEL, SEC. 14, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: ~, September 15, 2005 Total Depth: 534' FNL, 4276' FEL, SEC. 24, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 31,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 691522 y- 5960969 Zone- ASP4 10. KB Elevation (Height above GL): 53.35 feet 15. Distance to Nearest Well Within Pool 1,190' 16. Deviated Wells: Kickoff Depth: 11660 feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA .0 ) Downhole: 3396 Surface: 59 1 Casing. Program: Size Specifications Setting Depth To Bottom Qu y o Cement c.f. or sacks Hole Casin Wei ht Grade Cou tin Len th MD TVD MD TVD includin sta a data a-,!a" x 33/a" 3-1/2" x 3-3/16" 8.81 # / 6.2# L-80 STL / TCI I 2370' 11480' 8612' 13850' 8688' 107 ft Class 'G' x 2-~/a" / 6.16# N/A 3-1/2" 9.2# L-80 STL 2834' 8646' 7936' 11480' 8612' Liner Tieback 19. " PRESENT WELL CONDITION SUMMARY{To be'completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 14208 Total Depth TVD (ft): 8695 Plugs (measured): None Effective Depth MD (ft): 14182 Effective Depth TVD (ft): 14182 Junk (measured): None Casing Length Size Cement Volume MD TVD r Con u t r 110' 20" 2000# Coldset II 110' 110' rf 3497' 13-3/8" 2706 cu ft Coldset III, 460 cu ft Class 'G' 3497' 3497' I 9069' 9-5/8" 2217 cu ft Class 'G' 9069' 8259' Pro u ti n 998' 7" 398 cu ft Class 'G' 8829' - 9827' 8110' - 8618' Liner 3588' 4-1/2" 832 cu ft Class'G' 8678' - 12266' 8011' - 8685' Liner 2473' 2-7/8" 107 cu ft LARC 11735' - 14208' 8671' - 8695' Perforation Depth MD (ft): 8710' - 8750'; 12870' - 14170' Perforation Depth TVD (ft): 8033' - 8059'; 8706' - 8692' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow,Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 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 Sean Mctaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By NamelNumber: Si nature .._-- fit, /~-~ Phone 564-4387 Date ~ 30 05 Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: Z ~S-~„s' API Number: 50- 029-22321-04-00 Permit A ro I ,/ Date: ~~~ See cover letter for other requirements Conditions of Approval: Sampl equired ^ Yes~No Mud Log Required ^ Yes ,~No Hyd ge Sulfide Measures Yes ^ No Directional Survey Required Yes ^ No Other: I ~-r,,'~- P ~' 3 S G t~ ~ ~° . APPROVED BY ~ D A roved B '1-Hf COMMISSION Date D Form 10-401 Revised 20 ~ b it In Duplicate BP Prudhoe Bay 18-27D CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: 1. S Caliper Tubing 2. S Run DGLV's 3. O AC-LDS/POT; AC-PPPOT-IC, T MIT IA, OA; PT MV, SV, WV 4. C Run dummy whipstock 5. C Set CIBP at 11700' 6. C Set whipstock at 11680' 7. O Bleed gas lift and production flowlines down to zero and blind flange 8. O Remove wellhouse, level pad The pre CTD work is slated to begin on September 7, 2005. Rig Work: t ~~,5 l 0 ~ Gr ( wPP'~`~~( , 1. MIRU and test BOPE to 250 psi low and 3500 psi high. ~ 2. Mi113.8" window at 11680' and 10' of Zone 1B. Swap the well to Flo-Pro. ~ 3. Drill Build: 4.125" OH, 245' landing in Zone lA (35 deg/100 planned) 4. Drill Lateral: 4.125" x 3.75" OH, 1655' horizontal (12 deg/100 planned) 5. Run 3'/i" x 3 3/16" x 2 7/8" solid lin aving TOL at 11480' ~~ 6. Pump primary cement job to TOL 19 1 of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL/GR/C og 8. Test liner lap to 2000 psi. 9. Run a 3.5" tie back string to 8646'(isolate put river perfs at 8710-8750') ~' 10. Perforate liner per asset instructions 11. Run a liner top packer 12. Freeze protect well, RDMO Post-Rig Work: 1. Move wellhouse, Install production 17owline 2. Run GLVs 3. Flowback well to separator Mud Program: • Well kill: 8.5 ppg i • Milling/drilling: .6 pg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 3'/z" x 3 3/16" x 2 7/8" fully cemented liner - 11480'MD to 13850'MD • A minimum of 19 bbls 15.8 ppg cement will be used for liner cementing. Casin~/Liner Information 13 3/8", N-80, 68#, Burst 5020 psi; collapse 2260 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 7", N-80, 26#, Burst 7240 ;collapse 5410 psi 4'/i", L-80, 12.6#, Burst 8431; collapse 7500 psi Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directiona~n. Max. planned hole angle is 91 deg. • • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 31,000 ft. • Distance to nearest well within pool - 1190 ft. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. • A cased hole GR/CCL log will be run. Hazards • The maximum recorded H2S level on DS 18 is 0 )m . • Lost circulation risk is medium, crossing one fau t. Reservoir Pressure Res. press. is estimated to be 3250 psi at 8800'ss (7.1 ppg EMW). SIBHP in the Put River interval is 3396 psi at 7989'ss (8.2 ppg EMW)~ Max. surface pressure with gas (0.10 psi/ft) to surface is 2597 psi. / TREE = 4-1116" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 53.35' BF. ELEV = NA KOP = 4000' Max Angle = 97 @ 11055' Datum MD = WA Datum TV D = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" ~ 18-27C I ~ I I 3497' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf , ID= 3.958" I 8629' I NOTES: WELL ANGLE > 70° @ 9830' 8 > 90° @ 10104'. ORIgNAL 18-27 WELLBORE NOT SHOWN BELOW 7" LNR MILLOUT WINDOW @ 9827' (18-27A). 2223' I-I 4-1/2" CAMCO BAL-O SSSVN, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2986 2966 1 MMG DOME RK 16 02/28/05 2 5308 5198 28 MMG DOME RK 16 02/28/05 3 7260 6897 30 MMG DOME RK 26 02/28/05 4 8439 7839 40 MMG SO RK 22 02/28/05 8s29' ~-~ 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" Minimum ID = 2.377" @ 11745' 8ss2' 3-1/2" X 2-7/8" LNR XO 8s78' 8683' 8684' 8s84' 8s92' 8s99' ~~ 4-1/2" HES X NIP, ID = 3.813" ' TOP OF BKR TIEBACK SLV, ID = 7.50" 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 4-1/2" WLEG, ID = 3.958" 9-5/8" X 7" BKR ZXP PKR, ID = 6.30" 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" 7" X 4-1/2" XO, ID = 3.937" $$29' TOP OF TMJ TIEBACK SLEEVE 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 9075' PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CCL ON 10/04/00 ANGLE AT TOP PERF: 48 @ 8710' Note: Refer to Production DB for historical perf data SIZE SPF ER AL Opn/Sqz DATE 3-3/8" 6 8710 8750 O 03/21/05 2" 4 128 - 13030 O 10/18/00 2" 4 31"90 - 13430 O 10/18/00 2" 4 13550 - 13650 O 10/18/00 2" 4 13790 - 13875 O 10/18/00 2" 4 13920 - 14000 O 10/18/00 2" 4 14038 - 14170 O 10/18/00 4-1/2" LNR MILLOUT WINDOW 13136' - 13144' (18-276 / P&A'D ) ( 2-7/8" SLTD LNR NOT SHOWN ) $$3$' 9-5/8" X 7" TM/ S-6 PKR 8842' 9-5/8" X 7" TMJ DTH-S LNR HGR 9204' 4-1/2" HES X NIP, ID = 3.813" 7" LNR MILLOUT WINDOW (18-27A) 9827'-9850' (WHIPSTOCK NOT SHOWN) 10008' ~ 4-1/2" HES X NIP, ID = 3.813" 11739' 3-3/4" BAKER DEPLOYMENT SLV, ID = 3.00" 11745' TOP OF 2-7/8" LNR, ID = 2.377" 4-1/2" LNR MILLOUT WINDOW 12266' - 12278' (18-27C) I 122ss' TOP OF WHIPSTOCK 4-112" LNR, 12.6#, L-80, ID = 3.958" ~ 14557' 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.377" 14182' I~ PBTD 14208' DATE REV BY COMMENTS DATE REV BY COMMENTS 02/23/93 ORIGINAL COMPLETION 09/13/03 CMO/TLP DATUM MD/TVD & PERF ANGL 04/11/98 RIG SIDETRACK (18-27A) 03/04/05 RAC/TLH GLV C/O 11/01/98 CTD SIDETRACK (18-27B) 04101/05 LDK/TLH PERFS (03/31/05) 10/18/00 CTD SIDETRACK (18-27C) 11/23/01 CH/TP CORRECTIONS 06/15/03 CMO/TLP MAX ANGLE CORRECTION PRUDHOE BAY UNff WELL: 18-27C PERMff: 2001540 API No: 50-029-22321-03 SEC 24, T11N, R14E, 893' SNL & 236' WEL BP Exploration (Alaska) TREE= 4-1/16" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. E1EV = 53.35' BF. ELEV = NA KOP = 4000' Max Angle = 97 @ 11055' Datum MD = WA Datum TV D = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" ~1 ~~, 4-1/2" TBG, 12.6#, L-80, .0152 bpf , ID = 3.958" 8629' Minimum ID = 2.377" @ 12550' 3-1 /2" X 2-7/8" LN R XO 3-1/2" TBG, 9.2#. L-80, 0.00870 bpf , ID = 2.992" 114 8 ~2 7 D S NOTES: WELL ANGLE > 70° @ 9830' 8~ > 90° @ 10104'. ORIgNAL 18-27 W ELLBORE NOT Proposed CTD Sidetrack SHOWN BELOW 7" LNR MILLOUT WINDOW 9827' (18-27A). 2223' 4-1/2" CAMCO BAL-O SSSVN, ID = 3.812" GAS LIFT MANDRELS 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9075' PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CCL ON 10104%00 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 8710 - 8750 I PRO~SED 2" 4 12870-14170 S PROPOSED 11739' TOP OF 2-7/8" LNR, ID = 2.377" 4-1/2" LNR, 12.6#, L-80, IBT, ID = 3.958" 18-27C 12266' MILL OUT WINDOW (WHIP NOT SHOWN) ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2986 2966 1 MMG DOME RK 16 02/28/05 2 5308 5198 28 MMG DOME RK 16 02/28/05 3 7260 6897 30 MMG DOME RK 26 02/28/05 4 8439 7839 40 MMG SO RK 22 02/28/05 $629' ~ 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8640' ~ BAKER KB LINER TOP PACKER ID=XXX 8646' 3-3/4" BAKER DEPLOYMENT SLV, ID = 3.00" 8670' 3 1/2" X NIPPLE ID=2.XX" 8683' 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 8684' 9-5/8" X 7" BKR ZXP PKR, I;~) = h 30" 8692' 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.25" 92~' 11 4-1/2" HES X NIP, ID = 3.813" 11480' ~ 3-3/4" BAKER DEPLOYMENT SLV, ID = 3.00" 11500' 3 1/2" X NIPPLE ID=XXXX 11680' I-{ TOP OF 13-3/16" X 2-7/8" LNR, ID = 2.377" I DATE REV BY COMMENTS DATE REV BY COMMENTS 02/23/93 ORIGINAL COMPLETION 09/13!03 CMO/TLP DATUM MD/TVD & PERF ANGL 04/11/98 RIG SIDETRACK (18-27A) 03/04/05 RAC/TLH GLV C/0 11/01/98 CTD SIDETRACK (18-276) 04/01/05 LDK/TLH PERFS (03/31/05) 10/18/00 CTD SIDETRACK (18-27C) 08/19/05 MSE PROPOSED CTD SIDETRACK 11/23/01 CH/TP CORRECTIONS 06/15/03 CMO/TLP MAX ANGLE CORRECTION 12550' I~ 3 3/16" X 2 7/8" XO 13800' I~ ~~ ~~'`~ PRUDHOE BAY UNfr WELL: 18-27 D PERMfT: API No: 50-029-22321-04 SEC 24, T11 N, R14E, 893' SNL 8 236' WEL BP 6rploration (Alaska) i • ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report .~~ u~r~c~ Company: BP Amoco Date: 8/22/2005 Time: 10:28:24 Page: t Field: Prudhoe Bay Co-ordiaate(NE) Reference: Well: 18-27, True NOr'th Site: PB DS 18 Vertical (TVD) Reference: 51:27 11/12/1997 13:47 53.7 well: 18-27 Section (VS) Reference: WeN (O.OON,O.OOE,140.OOAzi) Wellpath: Plan 4, 18-27D Survey Calculation Method: Miramum Curvature Db: Oracle j Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre !~ Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.46 deg Well: 18-27 Slot Name: 27 18-27 Well Position: +N/-S 1756.75 ft Northing: 5960968.81 ft Latitude: 70 17 52.530 N +E/-W -16.31 ft Easting : 691522.37 ft Longitude: 148 26 56.030 W Position Uncertainty: 0.00 ft Wellpath: Plan 4, 18-27D Drilled From: 18-27A Tie-on Depth: 11655.88 ft Current Daturo: 51 : 27 11/12/1997 13:47 Height 53.70 ft Above System Datum: Mean Sea Level Magnetic Data: 8/18/2005 Declination: 24.94 deg Field Strength: 57614 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.70 0.00 0.00 140.00 Plan: Plan #4 Date Composed: 8/18/2005 lower doglegs version: 10 Principal: Yes Tied-to: From: Definitive Path Targets Name 18-27D Polygon -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 18-27D Fault -Polygon 1 -Polygon 2 18-27D Target 1 18-27D Target 2 18-27D Target 3 18-27D Target 4 Annotation Description TVD Dip. Dir. ft 53.70 53.70 53.70 53.70 53.70 53.70 53.70 53.70 53.70 53.70 8708.70 Map Map c._ Latitude --> <-- Longitude -> +N/-S +El-W Northing Fasting Deg Min . Sec Deg Min Sec ft ft ft ft J 1665.41 -5241.94 5962500.00 686240.00 70 18 8.891 N 148 29 28.867 W 1665.41 -5241.94 5962500.00 686240.00 70 18 8.891 N 148 29 28.867 W 1656.23 -4882.03 5962500.00 686600.00 70 18 8.803 N 148 29 18.373 W 998.76 -4598.68 5961850.00 686900.00 70 18 2.339 N 148 29 10.100 W 455.42 -3887.25 5961325.00 687625.00 70 17 56.999 N 148 28 49.350 W 208.04 -3993.60 5961075.00 687525.00 70 17 54.566 N 148 28 52.447 W 612.89 -5158.73 5961450.00 686350.00 70 17 58.540 N 148 29 26.419 W 1443.94 -5187.56 5962280.00 686300.00 70 18 6.713 N 148 29 27.277 W 1443.94 -5187.56 5962280.00 686300.00 70 18 6.713 N 148 29 27.277 W 1491.87 -4321.00 5962350.00 687165.00 70 18 7.190 N 148 29 2.013 W 1635.99 -5029.60 5962476.00 686453.00 70 18 8.603 N 148 29 22.675 W 8713.70 1364.56 -5095.55 5962203.00 686394.00 70 18 5.933 N 8743.70 1199.35 -5128.77 5962037.00 686365.00 70 18 4.308 N 8753.70 315.42 -3849.80 5961186.00 687666.00 70 17 55.622 N 148 29 24.592 W 148 29 25.558 W 148 28 48.257 W MD TVD ft ft 11655.88 8668.91 TIP 11660.00 8668.91 KOP 11680.00 8669.25 End of 9°/100' DLS • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report wrEt~ Company: BP Amoco ~ Date: 8/22/2005 Time: 10:28:24 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reterence: WeU: 18-27, True North ~ Site: PB DS 18 Vertical ('f VD) Reference: 5 1:27 11!12/1997 13:47 53.7 Well: 1 8-27 Section(VS)Reference: WeII(O:OON,O.OOE,140.OOAzi) Wellpath: Plan 4, 1 B-27 D Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 11720.00 8675.11 4 11820.00 8699.41 5 11905.33 8709.43 End of 35°/100' DLS 11955.33 8710.30 7 12155.33 8712.95 8 12285.33 8731.67 9 12355.33 8747.72 10 12480.33 8757.76 11 12960.33 8749.41 12 13060.33 8748.31 13 13410.33 8744.85 14 13850.00 8741.78 TD Plan Section Information MD Inc! Azim TVD +N!-S +E/-W DLS Build Tarn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/t00ft deg 11655.88 90.03 278.53 8668.91 1739.31 -4793.18 0.00 0.00 0.00 0.00 11660.00 89.93 278.43 8668.91 1739.92 -4797.25 3.43 -2.43 -2.43 225.00 11680.00 88.13 278.43 8669.25 1742.85 -4817.03 9.00 -9.00 0.00 180.00 11720.00 75.00 273.52 8675.11 1746.99 -4856.28 35.00 -32.83 -12.29 200.00 11820.00 77.76 237.58 8699.41 1723.00 -4948.62 35.00 2.76 -35.94 270.00 11905.33 89.00 209.67 8709.43 1662.20 -5006.25 35.00 13.18 -32.70 290.00 11955.33 89.01 203.67 8710.30 1617.55 -5028.68 12.00 0.01 -12.00 270.00 12155.33 89.50 179.67 8712.95 1423.13 -5068.84 12.00 0.25 -12.00 271.00 12285.33 73.90 179.67 8731.67 1294.89 -5068.11 12.00 -12.00 0.00 180.00 12355.33 79.60 186.01 8747.72 1226.90 -5071.53 12.00 8.15 9.05 48.00 12480.33 91.19 176.43 8757.76 1102.69 -5074.09 12.00 9.27 -7.66 320.00 12960.33 90.64 118.83 8749.41 714.22 -4827.81 12.00 -0.11 -12.00 270.00 13060.33 90.62 130.83 8748.31 657.21 -4745.87 12.00 -0.01 12.00 90.00 13410.33 90.46 88.83 8744.85 541.15 -4423.96 12.00 -0.OS -12.00 270.00 13850.00 90.28 141.59 8741.78 360.46 -4040.07 12.00 -0.04 12.00 90.00 Survey MD Inc! Azim SS TVD N/5 E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11655.88 90.03 278.53 8615.21 1739.31 -4793.18 5962585.31 686686.70 0.00 -4413.39 0.00 MWD 11660.00 89.93 278.43 8615.21 1739.92 X797.25 5962585.81 686682.61 3.43 -4416.47 225.00 MWD 11675.00 88.58 278.43 8615.40 1742.12 -4812.09 5962587.63 686667.73 9.00 -4427.69 180.00 MWD 11680.00 88.13 278.43 8615.55 1742.85 X817.03 5962588.24 686662.77 9.00 -4431.43 180.00 MWD 11700.00 81.56 276.01 8617.34 1745.36 -4836.78 5962590.24 686642.96 35.00 -4446.04 200.00 MWD 11720.00 75.00 273.52 8621.41 1746.99 -4856.28 5962591.37 686623.42 35.00 -4459.83 200.22 M W D 11725.00 75.00 271.70 8622.70 1747.21 -4861.11 5962591.47 686618.60 35.00 -4463.10 270.00 MWD 11750.00 75.25 262.65 8629.13 1746.02 -4885.21 5962589.67 686594.53 35.00 -4477.68 270.47 MWD 11775.00 75.85 253.64 8635.38 1741.05 -4908.88 5962584.10 686571.00 35.00 -4489.09 272.80 MWD 11800.00 76.79 244.68 8641.30 1732.42 -4931.55 5962574.89 686548.56 35.00 -4497.05 275.05 M W D 11820.00 77.76 237.58 8645.71 1723.00 -4948.62 5962565.04 686531.73 35.00 -4500.81 277.17 M W D 11825.00 78.36 235.90 8646.75 1720.32 -4952.71 5962562.26 686527.77 35.00 -4501.38 290.00 M W D 11850.00 81.51 227.61 8651.12 1705.09 -4972.02 5962546.54 686508.80 35.00 -4502.13 290.35 M W D 11875.00 84.84 219.45 8654.10 1687.11 -4989.09 5962528.13 686492.19 35.00 -4499.33 291.80 M W D 11900.00 88.26 211.39 8655.61 1666.79 -5003.54 5962507.45 686478.27 35.00 -4493.05 292.77 M W D 11905.33 89.00 209.67 8655.73 1662.20 -5006.25 5962502.79 686475.68 35.00 -4491.27 293.26 M W D 11925.00 89.00 207.31 8656.08 1644.91 -5015.63 5962485.28 686466.74 12.00 -4484.06 270.00 MWD 11950.00 89.00 204.31 8656.51 1622.42 -5026.51 5962462.51 686456.44 12.00 -4473.82 270.04 MWD 11955.33 89.01 203.67 8656.60 1617.55 -5028.68 5962457.59 686454.40 12.00 -4471.48 270.09 MWD 11975.00 89.05 201.31 8656.94 1599.38 -5036.20 5962439.23 686447.34 12.00 -4462.40 271.00 MWD 12000.00 89.10 198.31 8657.34 1575.86 5044.67 5962415.51 686439.47 12.00 -4449.83 271.04 MWD 12025.00 89.16 195.31 8657.72 1551.94 -5051.90 5962391.41 686432.86 12.00 -4436.15 271.09 MWD 12050.00 89.22 192.31 8658.07 1527.66 5057.86 5962366.99 686427.51 12.00 -4421.39 271.13 MWD • . ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~ INTEQ Company: BP Amoco Date: 8/22/2005 Time: 10;28:24 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeU: 18-27, True North Site: PB DS 18 Vertical (TVD) Refe rence: 51:27 11/12/1997 13:47 53.7 Well: 18-27 Section (VS) Reference: WeU (O.OON,O.OOE,14-0.OOAzi) Wellpath: Plan 4, 18-27 D _ Survey Calculation Method: Minimum Curvature Db: Oracle Survey _ MD Inc! Azim SS TVD N/S E!W MapN MapE DLS VS TFO Tool ~ ft deg deg ft ft ft ft ft deg/100ft ft deg 12075.00 89.28 189.31 8658.40 1503.11 -5062.55 5962342.33 686423.45 12.00 -4405.60 271.18 MWD 12100.00 89.35 186.31 8656.70 1478.35 -5065.95 5962317.49 686420.68 12.00 -4388.81 271.22 MWD 12125.00 89.42 183.31 8658.97 1453.44 -5068.05 5962292.54 686419.22 12.00 -4371.08 271.25 M W D 12150.00 89.48 180.31 8659.21 1428.46 -5068.84 5962267.55 686419.07 12.00 -4352.45 271.28 M W D 12155.33 89.50 179.67 8659.25 1423.13 -5068.84 5962262.22 686419.21 12.00 -4348.36 271.31 MWD 12175.00 87.14 179.67 8659.83 1403.47 -5068.72 5962242.57 686419.82 12.00 -4333.23 180.00 MWD 12200.00 84.14 179.67 8661.73 1378.54 -5068.58 5962217.66 686420.60 12.00 -4314.05 180.00 MWD 12225.00 81.14 179.67 8664.94 1353.75 -5068.44 5962192.88 686421.37 12.00 -4294.97 180.00 MWD 12250.00 78.14 179.67 8669.43 1329.16 -5068.30 5962168.30 686422.14 12.00 -4276.04 180.00 M W D 12275.00 75.14 179.67 8675.21 1304.84 -5068.16 5962144.00 686422.89 12.00 -4257.32 180.00 MWD 12285.33 73.90 179.67 8677.97 1294.89 -5068.11 5962134.05 686423.20 12.00 -4249.66 180.00 MWD 12300.00 75.08 181.03 8681.89 1280.75 -5068.19 5962119.92 686423.48 12.00 -4238.89 48.00 MWD 12325.00 77.11 183.30 8687.90 1256.51 -5069.11 5962095.65 686423.18 12.00 -4220.90 47.64 MWD 12334.72 77.91 184.17 8690.00 1247.04 -5069.73 5962086.17 686422.80 12.00 -4214.05 47.09 18-27D 12350.00 79.16 185.54 8693.04 1232.12 -5071.00 5962071.23 686421.91 12.00 -4203.43 46.90 MWD 12355.33 79.60 186.01 8694.02 1226.90 -5071.53 5962066.00 686421.52 12.00 -4199.78 46.63 MWD 12375.00 81.42 184.48 8697.26 1207.59 -5073.30 5962046.65 686420.24 12.00 -4186.12 320.00 MWD 12400.00 83.73 182.55 8700.49 1182.85 -5074.81 5962021.88 686419.35 12.00 -4168.14 320.25 MWD 12425.00 86.04 180.63 8702.72 1157.96 -5075.51 5961996.98 686419.30 12.00 -4149.52 320.50 MWO 12450.00 88.37 178.73 8703.94 1132.99 -5075.37 5961972.03 686420.07 12.00 -4130.30 320.67 MWD 12475.00 90.69 176.84 8704.15 1108.01 -5074.40 5961947.08 686421.67 12.00 -4110.55 320.77 MWD 12480.33 91.19 176.43 8704.06 1102.69 -5074.09 5961941.77 686422.12 12.00 -4106.27 320.7$ MWD 12500.00 91.19 174.07 8703.65 1083.10 -5072.46 5961922.22 686424.25 12.00 -4090.21 270.00 MWD 12525.00 91.18 171.07 8703.14 1058.31 -5069.23 5961897.53 686428.11 12.00 -4069.15 269.95 MWD 12550.00 91.17 168.07 8702.62 1033.74 -5064.70 5961873.08 686433.26 12.00 -4047.42 269.89 MWD 12575.00 91.16 165.07 8702.11 1009.43 -5058.90 5961848.93 686439.68 12.00 -4025.06 269.83 MWD 12600.00 91.15 162.07 8701.61 985.46 -5051.83 5961825.15 686447.36 12.00 -4002.16 269.77 MWD 12625.00 91.13 159.07 8701.11 961.89 -5043.52 5961801.80 686456.27 12.00 -3978.76 269.71 MWD 12650.00 91.11 156.07 8700.62 938.79 -5033.98 5961778.95 686466.39 12.00 -3954.93 269.65 MWD 12675.00 91.09 153.07 8700.14 916.21 -5023.25 5961756.66 686477.70 12.00 -3930.74 269.59 MWD 12700.00 91.06 150.07 8699.67 894.24 -5011.35 5961735.00 686490.15 12.00 -3906.26 269.53 MWD 12725.00 91.03 147.07 8699.21 872.91 -4998.31 5961714.01 686503.73 12.00 -3881.54 269.47 MWD 12750.00 91.00 144.07 8698.77 852.30 -4984.18 5961693.77 686518.38 12.00 -3856.67 269.42 MWD 12775.00 90.97 141.07 8698.34 832.45 -4968.99 5961674.31 686534.07 12.00 -3831.70 269.36 MWD 12800.00 90.93 138.07 8697.93 813.43 -4952.78 5961655.71 686550.76 12.00 -3806.71 269.31 MWD 12825.00 90.89 135.07 8697.53 795.28 -4935.59 5961638.01 686568.40 12.00 -3781.76 269.26 MWD 12850.00 90.85 132.07 8697.15 778.05 -4917.48 5961621.25 686586.94 12.00 -3756.92 269.22 MWD 12875.00 90.80 129.07 8696.79 761.80 j1898.49 5961605.48 686606.34 12.00 -3732.26 269.17 MWD 12900.00 90.76 126.07 8696.45 746.56 -4878.68 5961590.76 686626.53 12.00 -3707.85 269.13 MWD 12925.00 90.71 123.07 8696.13 732.38 -4858.10 5961577.11 686647.47 12.00 -3683.76 269.09 MWD 12950.00 90.66 120.07 8695.83 719.29 -4836.80 5961564.57 686669.09 12.00 -3660.05 269.05 MWD 12960.33 90.64 118.83 8695.71 714.22 -4827.81 5961559.72 686678.21 12.00 -3650.38 269.01 MWD 12975.00 90.64 120.59 8695.55 706.95 -4815.07 5961552.78 686691.13 12.00 -3636.62 90.00 MWD 13000.00 90.63 123.59 8695.27 693.67 -4793.89 5961540.05 686712.64 12.00 -3612.83 90.02 MWD 13025.00 90.63 126.59 8695.00 679.30 -4773.44 5961526.21 686733.45 12.00 -3588.68 90.05 MWD 13050.00 90.62 129.59 8694.73 663.88 -4753.76 5961511.29 686753.51 12.00 -3564.22 90.09 MWD 13060.33 90.62 130.83 8694.61 657.21 -4745.87 5961504.83 686761.56 12.00 -3554.04 90.12 MWD 13075.00 90.62 129.07 8694.45 647.80 -4734.63 5961495.70 686773.04 12.00 -3539.60 270.00 MWD 13100.00 90.62 126.07 8694.18 632.56 -4714.82 5961480.97 686793.24 12.00 -3515.19 269.98 MWD 13125.00 90.62 123.07 8693.91 618.38 -4694.23 5961467.32 686814.17 12.00 -3491.10 269.95 MWD 13150.00 90.61 120.07 8693.65 605.29 -4672.94 5961454.78 686835.80 12.00 -3467.38 269.92 MWD 13175.00 90.60 117.07 8693.38 593.34 -4650.98 5961443.40 686858.05 12.00 -3444.12 269.88 MWD Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~^ iNT~c~ Company: BP Amoco Date: 8/22/2005 Time: 10:28:24 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Welt: 18-27, True North Site: PB DS 18 Vertical (TVD) Refe rence: 5 1:27 11!12/1997 13:47 53.7 WeII: 18-27 Sectioa (VS) Refereuce: Well (O.OON,O.OOE,140.OOAzi) Wellpath: Plan 4, 18-27D Survey Calculation Method: Minimum Curvature Db: Oracle Survev MD Intl Azim SS'TVD N/S E/W MapN MapE DI.S VS TFO Tool ft deg deg ft ft ft ft ft degt100ft ft deg 13200.00 90.60 114.07 8693.12 582.55 -4628.43 5961433.19 686880.86 12.00 -3421.36 269.85 MWD 13225.00 90.59 111.07 8692.86 572.96 -4605.35 5961424.19 686904.18 12.00 -3399.18 269.82 MWD 13250.00 90.57 108.07 8692.61 564.59 -4581.80 5961416.42 686927.94 12.00 -3377.62 269.79 MWD 13275.00 90.56 105.07 8692.36 557.46 -4557.84 5961409.91 686952.07 12.00 -3356.76 269.76 MWD 13300.00 90.55 102.07 8692.12 551.60 -4533.54 5961404.67 686976.51 12.00 -3336.65 269.73 MWD 13325.00 90.53 99.07 8691.89 547.02 -4508.97 5961400.71 687001.18 12.00 -3317.35 269.70 MWD 13350.00 90.51 96.07 8691.66 543.73 X484.19 5961398.05 687026.04 12.00 -3298.90 269.67 MWD 13375.00 90.49 93.07 8691.44 541.74 -4459.27 5961396.70 687051.00 12.00 -3281.36 269.65 MWD 13400.00 90.47 90.06 8691.23 541.05 x{434.29 5961396.65 687075.99 12.00 -3264.78 269.62 MWD 13410.33 90.46 88.83 8691.15 541.15 -4423.96 5961397.02 687086.31 12.00 -3258.21 269.59 MWD 13425.00 90.46 90.59 8691.03 541.23 -4409.29 5961397.47 687100.97 12.00 -3248.84 90.00 MWD 13450.00 90.46 93.59 8690.83 540.32 -4384.31 5961397.19 687125.97 12.00 -3232.09 90.01 MWD 13475.00 90.46 96.59 8690.63 538.10 -4359.41 5961395.61 687150.91 12.00 -3214.39 90.04 MWD 13500.00 90.45 99.59 8690.43 534.59 -4334.66 5961392.73 687175.74 12.00 -3195.79 90.06 M W D 13525.00 90.45 102.59 8690.23 529.78 -4310.13 5961388.55 687200.38 12.00 -3176.34 90.09 MWD 13550.00 90.44 105.59 8690.04 523.70 -4285.89 5961383.09 687224.77 12.00 -3156.09 90.11 MWD 13575.00 90.43 108.59 8689.84 516.35 X262.00 5961376.35 687248.85 12.00 -3135.11 90.13 MWD 13600.00 90.43 111.59 8689.66 507.77 -4238.52 5961368.37 687272.53 12.00 -3113.44 90.16 MWD 13625.00 90.42 114.59 8689.47 497.97 X215.53 5961359.16 687295.77 12.00 -3091.15 90.18 MWD 13650.00 90.41 117.59 8689.29 486.98 -4193.08 5961348.74 687318.49 12.00 -3068.30 90.20 MWD 13675.00 90.39 120.59 8689.12 474.82 X171.23 5961337.15 687340.63 12.00 -3044.95 90.22 MWD 13700.00 90.38 123.59 8688.95 461.55 -4150.05 5961324.42 687362.14 12.00 -3021.17 90.24 MWD 13725.00 90.37 126.59 8688.79 447.18 -4129.60 5961310.58 687382.96 12.00 -2997.01 90.26 MWD 13750.00 90.35 129.59 8688.63 431.76 -4109.92 5961295.67 687403.01 12.00 -2972.55 90.28 MWD 13775.00 90.33 132.59 8688.48 415.33 -4091.08 5961279.73 687422.27 12.00 -2947.86 90.30 MWD 13800.00 90.32 135.59 8688.34 397.94 -4073.13 5961262.80 687440.66 12.00 -2923.00 90.32 MWD 13825.00 90.30 138.59 8688.21 379.63 -4056.11 5961244.93 687458.14 12.00 -2898.03 90.34 MWD 13850.00 90.28 141.59 8688.08 360.46 -4040.07 5961226.17 687474.66 12.00 -2873.03 90.35 MWD ~-- • • BP Amoco '~ r••:s~ w ~waa• NEFERENLE INFORMATION e ~ Relar•n~'. ~M6 C.ne~+re ra5ea leve'~~ +n Hel~nce 51 2]+t,~~+99] "AT Si ~r~ +n McUOa m(:u i ni~ii m uo ~-...rw v _s amru wm++~ .~mm ~i; .awn vw 8250 ', d 2 6600- E 6650 8900- 6950 __ 9000 West(-)/East(+) [100ft/in] _~ :::.-~~: ilk ~~~`~ i~!~~ ~I ~ 'j 'I I;;II ,: I I - .- ill _ _ .. i(t 1 -- .i ._ _.: + i~ ._ , ) ~. t .. , ~ ~ i ,i , ~ fl'i ~ ~ ! '~ i ;~ ::. ' ii i- 'i' + I i t +e.n) iB3'I +anAl M Magnetic North: 24.94' dsr•4 By BN Mkz+•N•on On•: eastzms b +e n +Anq +sn ~dncl ~~+sxm . Magnetic Fieltl Strenggthe 57614nT Di Mgle'. 80.91' Bate: 8 /1 812 0 0 5 Mood. Dggm2005 r,-,n,x ~. inlom,a~. ,;r pJi v~.cn;wi:,M o~rer.:: (sari zr,~-n82~ ceu t~n~ Ir+ Tarn [-,,..,i o,., m,cnsexr~r2. n,ea«~ to to __ ....~„. ~~_ i ___~. E .+, I I (~~ _, AM Vertleal Seetion at 140.00' [SOftlin] ~•~- - • • are from top i ~_ ~ 18-27D of bag BAG 7 1 /16" 5000 psi. of pipes of flow cross of blind/shears Blind/Shears TOTs 2 3/8" combi rare/slips ~ ~ ?/16'° 5ooopsi Mud Cross I I Mud Cross 7 1/16" 5000psi variable bore pipe 3 1/2"-2 3/8" TOTs ~ 2 3/8" combi ram/slips ~ 1/i s" 5ooopsi Flow Tee TERRIE L RUBBLE ss-si125z 222 BP' EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 ~~~~ DATE PAY TO THE / ~~ ORDER OF l! Y 1. ~~~~lll.../// DOLLARS t ational Bank Alaska Anchorage, AK .99501 .MEMO- ~: 1 2 5 2 0 0 0 6 0 ~: 9 9 1 4 ~~~ 6 2 2? ~~~ L 5 5 6 l~' 0 2 2 2 ~~ ~\ • • ~ TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME l°.~G~ ~~ Z~ ~ PTD# .~~5--~/ 3~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If .API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC Z5.005(f), all (pT~ records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\ j od y\tra n s m itta I_c h ec kl i st WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT 18-27D Program DEV Well bore seg ^ PTD#:2051330 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-OIL GeoArea 890 Unit 11650 On1Off Shore On Annular Disposal ^ Administration 1 Permit fee attached----------------------_-__--______- _-- --___Yes_-__- -_-___-_---_-__-..--..____-__.-___-_- 2 Lease number appropriate- - - - - - - Yes - - - - - - - 3 Uniquewell_nameandnumber_-._________________________ _________ Yes_._._ -_ 4 Well located in-a-definedpool______________________________ _________Yes_____ _______________________________ 5 Well locatedp[operdistance-ftomdrillingunitboundary--.-----__-_-_ _--__-__Yes_____ __________________________ -------------------------------------------- 6 Well located properdistance-f(omotherwells_____________________ _________Yes_--_- .-_-__-_-____--_--.---._--_____-----__-___--__----._ - -- - - 7 Sufficient acreage availablein_drillingunit--------------________ _______Yes__ ___________ ---------------------------------------------------- 8 If deviated, is_wellbore plat_inclu_ded - - - - Yes - - - - - - 9 Operator only affected party- - - - - - - - Yes - - - - ------------------------------------- 10 Ope[atorhas_appropriate.bondinforce------------------------ ---------Yes_---- .-C9RRECTED-BY HAND ON 401-RQC...__.__.___.______________._. --------------- 11 Permit_canbeissuedwithoutco_nservationorder___________________ ___ _____Yes_____ --__-__-__--__-----.-___________-__-____-__-___-__-_--___-__--______ Appr Date 12 Permit_canbeissuedwithoutadministrative_approval________________ _________Yes_____ _______________-___________ ------------------------------------------- RPC 912!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_strataauthprizedby_InjectionOrder#(put_1O#in_comments)-(For_NA__-__ --__--------------____________--_--__-_----__--__-____--_--_______ 15 All wells-within114_mile area ofreyiewidentified(ForseNicewellonly)------ --------- NA__-_-_ _---_--_-___-_._-_-.---___--_-_-_- ------------------------------------ 16 Pre-produced injector: duration of pre productionl_essthan_3months_(Forservicewellonly)-_NA______ ___________________________________________________________ 17 ACMP_FindingofConsistency_h_asbee_ni&sued-foCthisproject___________ _________ NA______ ___________________________________________________________________,-- Engineering 18 Conductor string_provided - - - - - NA 19 Surface casing_protects all_known USl)Ws - - - - - - NA - 20 CMT_vol-adequate_tocircul_ateonconductor_&surf_csg_------------- --------- NA______ _______-________ -- 21 CMT_v_oladeguate_totie-in long string tosurfcsg________ __________ ___ _____ NA______ ______- -------------------------------------------------------------- 22 CMT_willcoyerallknow_n_productivehorizon_s--------------------- ---------Yes-__-_ __Adequateexcess,___-----__-__--_- --------------------------------------- 23 Casingdesgnsadequatefo[C,TB&_permafrost------- ---------- ---------Yes----- ----------------------------------.------------------------------ 24 Adequate tankage_or reserve pit - - - - - - - Yes CTDU. - - - 25 Ifa_re-drill,has-a-10-403forabandonment been approved_____________ _________ Yes__--_ _-91212005,___--___--__-___-____________---_____ ------------------------- 26 Adequatewellboreseparation_proposed________________________ _________Yes_____ _- -------------------------------------------------------------------- 27 Ifdive[terrequired,doesitmeetregulations____---------------- --------- NA___--_ _-$idet[ack.___--__---__. Appr Date 28 Drilling fluid_program schematic & equip listadequake_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ Max MW-8,6 ppg._ _ _ _ - - - _ - - _ _ - - _ - WGA 9!6!2005 29 BOPEs,dotheymeetregulation--__-______________________ _________Yes___-_ __-_____________________ 30 BOPE_pressratingappropriate;testto_(putpsigincomments)___________ _________Yes_-_-_ _Testto3500 psi.-MSP2597 psi.-__-___-__-__--_---__-___-_---__-__-__-___--_-_-- 31 Choke-manifold complies w/APl_RP-53(M_ay84)___________________ _________Yes__--_ _--_----.__--__---__--__-___-_--__--_---__--__-_---____-___-___-______ 32 Work will occur without operation shutdown_____________________ ________Yes__--_ _-_------__--__----_--__--_ 33 Is Rresence_of H2S gas_probable - - - - - - - No - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mechanical_conditiongfwellswithinAORyerified(Forservicewellonly)_____ _________ NA______ __________________________________________________ Geology 35 Permit.canbeissuedw/ohyd[ogen-sulfide measures-___-___-______ _________ No______ ________________________-_______________ 36 Data_presentedon_pote_ntialoye_rpres_surezones---------------___ _________NA_____ -______--_ - - - - Appr Date 37 Seismicanalysisofshallowgas_zones_________________-__---- ------.-_NA-__--- -.__--_--__ RPC 912/2005 38 Seabed condition suryey_(if off_-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - NA - -- - -- -- - -- - - - - - -- --- 39 Contact namelphone for weekly progress_reports [exploratory only]_ NA_ Geologic Engineering u Date Date: Date Commissioner: Q15~ Com i Commissioner: ~~7~5 ~ s ~~0 ~ ~-o . • Well History File APPENDIX • Information of detailed nature that is not particularty 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 infom~ation, information of this nature is accumulated at the end of the file under APPENQIX. No special effort has been made to chronologically organize this category of information. • • 18-27d.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Nov 06 16:06:09 2007 Reel Header Service name .............LISTPE Date . ...................07/11/06 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date .....................07/11/06 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Library. scientific Technical services Physical EOF ` DEC ~` ~ 207 comment Record ~ TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: 18-27D (Suspended) API NUMBER: 500292232104 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 06-NOV-07 JOB DATA MWD RUN 3 MWD RUN 8 MWD RUN 9 JOB NUMBER: MW0003940183 MW0003940183 MW0003940183 LOGGING ENGINEER: S. LATZ B. JAHN B. JAHN OPERATOR WITNESS: B. LAULE/S. S. NOYNBAERT S. NOYNBAERT SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 14E FNL: 893 FSL: FEL: 236 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 53.70 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Page 1 c7Ds-l~ rs ~-a~ • • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 18-27d.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 11641.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. THIS WELLBORE WAS DRILLED FROM A CEMENT PLUG IN 18-27D PB1. THE KOP WAS AT 11690'MD/8617'TVDSS. 4. MWD RUNS 1-3,8,9 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. SGRD TIE-IN DATA FROM RUN 1 WERE MERGED WITH RUN 3 MWD DATA. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN ON 9/22/2005 IN 18-27. THESE LOG DATA WERE PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 8/8/07, AS AUTHORIZED BY ROGER FURLEY (BP). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-3,8,9 REPRESENT WELL 18-27D WITH API #: 50-029-22321-04. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12200'MD/8635'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11345.5 ROP 11667.5 S all bit runs merged. STOP DEPTH 12178.5 12209.0 Page 2 • • 18-27d.tapx BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 11345.5 11337.5 11356.5 11348.5 11364,0 11357.0 11375.5 11368.0 11381.0 11375.0 11382,0 11376.5 11383.0 11377.5 11388.0 11382.5 11393.0 11387.0 11402.0 11397.5 11642.5 11636.0 11647.5 11641.5 11652.5 11648.0 11654.5 11649.5 11677.5 11672.5 11679.5 11673.5 11688.5 11681.0 11693.5 11684.5 2209.0 12200.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 3 11337.5 11690.0 MwD 8 11690.5 11904.0 MwD 9 11904.0 12200.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units.. ..........Feet Data Reference Point ..............undefined Frame Spacing....... ....... ...60 .lIN Max frames per record .............undefined Absent value......... .............-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11345.5 12209 11777.3 1728 11345.5 12209 GR MwD API 24.29 814.25 64.9826 1203 11345.5 12178.5 ROP MWD FT/H 1 271.3 94.7366 1084 11667.5 12209 First Reading For Entire File..........11345.5 Page 3 • 18-27d.tapx Last Reading For Entire File...........12209 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/06 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.......07/11/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11337.5 11690.0 $OP 11662.5 11690.0 LOG HEADER DATA DATE LOGGED: 18-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11690.0 TOP LOG INTERVAL (FT): 11337.5 BOTTOM LOG INTERVAL (FT): 11690.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.3 MAXIMUM ANGLE: 89.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 11641.0 BOREHOLE CONDITIONS Page 4 • 18-27d.tapx MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9,6 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 150.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX.: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units.... .....Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units .size Nsam Rep code Offset Channel DEPT FT 4 1 68 0 1 GR MwD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11337.5 11690 11513.8 706 11337.5 11690 GR MWD030 API 24.29 814.25 48.1224 246 11337.5 11690 ROP MWD030 FT/H 1 57.58 38.8339 56 11662.5 11690 First Reading For Entire File..........11337.5 Last Reading For Entire File...........11690 File Trailer Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/06 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Page 5 r: 18-27d.tapx Physical EOF File Header Service name... .....STSLIB.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER • FILE NUMBER: 3 RAW MWD curves and log header data for eac h bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11690.5 11873.0 ROP 11690.5 11904.0 LOG HEADER DATA DATE LOGGED: 26-SEP-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11904.0 TOP LOG INTERVAL (FT): 11690.0 BOTTOM LOG INTERVAL (FT): 11904.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.6 MAXIMUM ANGLE: 92.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): 11641.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): .0 MUD PH: 9.0 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATU RE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMP ERATURE: .000 152.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL Page 6 • • MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 18-27d.tapx REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... .......,....60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code, offset channel DEPT FT 4 1 68 0 1 GR MwD080 API 4 1 68 4 2 ROP MWD080 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11690.5 11904 11797.3 428 11690.5 11904 GR MWD080 API 26.6 134.85 42.4773 366 11690.5 11873 ROP MWD080 FT/H 1.39 173.41 96.3171 428 11690.5 11904 First Reading For Entire File..........11690.5 Last Reading For Entire File...........11904 File Trailer Service name... ......,STSLIB.003 Service sub Level Name... version Number.. ........1.0.0 Date of Generation......,07/11/06 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.......07/11/06 Maximum Physical Record..65535 File Type. ...........:LO Previous File Name.......STSLI6.003 comment Record Page 7 • 18-27d.tapx FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11873.5 12169.5 ROP 11904.5 12200.0 LOG HEADER DATA DATE LOGGED: 26-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY. OR REAL-TIME): Memory TD DRILLER (FT): 12200.0 TOP LOG INTERVAL (FT): 11904.0 BOTTOM LOG INTERVAL (FT): 12200.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.3 MAXIMUM ANGLE: 91.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $CG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 11641.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 20.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 154.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... .........0 Data specification Block Type.....0 Page 8 • 18-27d.tapx Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ...........,60 .lIN Max frames. per record .............undefined Absent value ......................-999 Depth Units. .. .. .... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD090 API 4 1 68 4 2 ROP MWD090 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11873.5 12200 12036.8 654 11873.5 12200 GR MWD090 API 38.62 212.78 85.4572 593 11873.5 12169.5 ROP MWD090 FT/H 4.44 271.3 99.5936 592. 11904.5 12200 First Reading For Entire File..........11873.5 Last Reading For Entire File...........12200 File Trailer Service name... .......STSL26.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/11/06 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 . ... ...............07/11/06 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Physical EOF Page 9 • 18-27d.tapx Physical EOF End Of LIS File Page 10
