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208-134
Ima a Project Well History File Cov~e~age g XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ - ~ ~ ~- Well History File Identifier Organizing (done) ~.~,a.d iuuiiiiumiim o R~~a~N~a iiiimimuiuu RES AN DIGI L DATA for Items: iskettes, No. ~- Greyscale Items: `I ~ ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~Maria~ Date: c ~ ~ ~ ~!~ _ /s/ ~ ~ I Project Proofing BY' aria Date: 3I ~ /~a /s/ I~~ "~'~~ / re aration x 30 = d + ~ =TOTAL PAGES Scanning P p 3/ ~ ~~ (Count does not include cover sheet) `/- /- BY: Maria Date: /s/ V ~/ ` Production Scanning """"""" ""' Sta e 1 Pa a Count from Scanned File: ~ (Count does include cover sheet) g g Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ~ / ® /s/ V y I, ~~ 111 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I (III ReScanned II I II II II V I II I I III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III 10/6/2005 Well History File Cover Page.doc i • i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended lb. Well Class • 20AAC 25105 20AAC 25110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero '= Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 2/3/2013 '� 208 - 134 • 313 - 055 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 8/30/2008 50 029 - 22172 - 01 - 00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 9/9/2008 PBU 05 -35A • 2323' FNL, 124' FWL, SEC. 32, T11N, R15E, UM • 8. KB (ft above MSL): 62 85 15. Field / Pool(s) Top of Productive Horizon: 1157' FNL, 673' FWL, SEC. 31, T11N, R15E, UM GL (ft above MSL): 34.2' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD) Oil Pool 4217' FNL, 27' FWL, SEC. 30, T11N, R15E, UM 10485' 8885' 4b. Location of Well (State Base Plane Coordinates, NAD: 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x- 697190 • y- 5949122 - Zone- ASP4 • 13000' 8894' • ADL 028326 • TPI: x- 692707 y- 5950172 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 692005 y 5952375 Zone- ASP4 None 18. Directional Survey: ❑Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIR / GR 1 RES / PWD, DIR / GR / RES / DEN 3861' 3760' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H -40 Surface 115' Surface 115' 30" 11 cu yds Coldset 9 -5/8" 36# J -55 Surface 3861' Surface 3760' 12 -1/4" 1141 sx CS III, 300 sx 'G', Top Job: 195 sx CS II 7" 26# L -80 27' 9676' 27 8335' 8 -1/2" 218 sx LiteCrete, 168 sx Class 'G' 4 -1/2" 12.6# L -80 9510' 12999' 8203' 8894' 6 -1/8" 423 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 - 1/2 ", 12.6#, 13Cr80 9520' 9402' / 8118' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ® No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED FE R 2 u 2013 10800' Set Flow Through Packer Whipstock 10485' Set Whipstock 6 P4 c_ (� c.•,4 i p S 446 ) AOGCC 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No • Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. N cBDMS MAR 01 2013 SCANNED APR 2 4 2013 Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE LI l7 � ? mit n al Only 4 -20 7_,,/ -I 24 7(7/ 29. GEOLOGIC MARKERS (List all formations markers encounter 30. • FORMATION TESTS NAME D TVD Well Tested? ❑ Yes ® No • Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9676' 8335' None Shublik A 9726' 8375' Shublik B 9752' 8396' Shublik C 9767' 8408' Sadlerochit 9812' 8444' 42 SB / Zone 4A 9948' 8553' CGL / Zone 3 10032' 8617' Base CGL / Zone 2C 10118' 8680' 23SB / Zone 2B 10228' 8755' Zone 1B 10522' 8898' 14N 10560' 8910' TDF / Zone 1A 10653' 8933' Base Sadlerochit 10743' 8945' Formation at Total Depth: 31. List of Attachment 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: David Johnston, 564 -5 Email: David.Johnston2 @bp.com Printed Name: Jo La Title: Drilling Technologist . fka Signature: Phone 564 Date: /zvll3 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 • • Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/26/2013 14:00 - 16:30 2.50 MOB P PRE HOLD PJSM AND SWAP REELS. 16:30 - 17:00 0.50 MOB P -_ PRE PREPARE RIG FOR RIGMOVE; SECURE CELLAR AND PIPSHED 17:00 - 22:30 5.50 RIGU P PRE HOLD PJSM. JACK UP RIG AND PULL OFWELL 01 -17C. MOVE RIG TO ENTRANCE OF DS01. CONTINUE RIG MOVE TO DS05 AND LINE UP - RIG IN FRONT OF WELL. 22:30 - 00:00 1.50 RIGU P PRE HOLD PJSM AND SPOT RIG OVER WELLAND COMMENCE SPOTING OUTSIDE EQUIPMENT. 1/27/2013 00:00 - 01:00 1.00 RIGU P PRE STACK PLYWOOD UNDERNEATH RIG AND ■ SET DOWN RIG. ACCEPT RIG AT 01:OOHRS. 01:00 - 02:00 1.00 RIGU P PRE FINISH SPOTTING OUTSIDE EQUIPMENT ■ (CUTTINGS BOX, TIGERTANK, WELDING SHOP,...) AND PREPARE RIG FOR NU BOP'S. 02:00 - 03:15 1.25 RIGU P PRE LUBRICATE VALVES IN REELHOUSE, ESA ON MANIFOLDS. CHANGE OUT VALVE LVE 12 12'ON CHOKE MANIFOLD. 03:15 - 04:00 0.75 RIGU P PRE HOLD PJSM AND ESTABLISH BARRIERS FOR BREAKING CONTAINMENT - PRESSURE -UP TREE CAVITY THROUGH FWVAND CONFIRM LEAK TIGHT. BLEED OFF PRESSURE AND CONFIRM NO FLOWACROSS SSV / MASTER. INSTALL PRESSURE -GAUGE AND COMMENCE MONITORING TREE CAVITY. REMOVE TREE CAP. 04:00 - 06:00 2.00 BOPSUR P PRE NU BOPE AND INSTALL REEL IRON IN REELHOUSE. HARDLINE CREW RIG UP THE TIGERTANK AND INSTALL AND PRESSURE -TEST SURFACE LINE TO THE TANK. 06:00 - 06:30 0.50 BOPSUR P PRE HOLD RIG EVAC DRILL /MAN DOWN DRILL VNTH ALL CREWS. GOOD RESPONSE BY CREW, ALL MUSTERED PROMPTLY IN PRIMARY MUSTER AREA. ONCE MUSTERED DISCUSS WITH CREW HOW TO RE -ACT INA MAN -DOWN SITUATION AS PER PROCEDURES. 06:30 - 10:00 3.50 BOPSUR P PRE FINISH NU BOPE & INSTALLING INNER REEL IRON. MU RISER TO TOP OF BOP STACK & INSTALL HOT TUB. 0837 -HRS: EMAIL AOGCC INSPECTORS REGARDING UPCOMING BOPE TEST. ALSO SUBMIT ONLINE FORM. 0900 -HRS: AOGCC REP BOB NOBLE WAIVES STATE'S RIGHT TO WITNESS. Printed 2/18/2013 2:13:10PM Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 12:30 2.50 RIGU P PRE HOLD PJSM ON PULLING COIL ACROSS ROOF. ASSIGN PEOPLE TO POSITIONS, IDENTIFY DROPPED OBJECT POTENTIALS, REVIEW JOB STEPS AND HIGHLIGHT THE IMPORTANCE OF CLEAR, CONCISE COMMUNICATION. PU INJECTOR & STRING UP WINCH TO REEL HOUSE. INSTALL GRAPPLE IN COIL & PULL TEST - GOOD. REMOVE SHIPPING BAR & CLAMPS. PULL COIL ACROSS ROOF AND STAB INTO INJECTOR HEAD. CUT OFF GRAPPLE & RD ALL HANDLING EQUIPMENT. ' **SIM OPS - TEST H2S & LEL GAS ALARMS - GOOD TEST." 12:30 - 13:30 1.00 BOPSUR P PRE RU TO PERFORM INITIAL BOPE PRESSURE TEST. FLUID PACK BOP STACK, MANIFOLD & MGS. - BEGIN INITIAL BOPE TEST BY PERFORMING KOOMEY DRAWDOWN TEST & FUCTION TEST OF OPS CAB PANEL. 13:30 - 17:45 4.25 BOPSUR P PRE PERFORM INITIAL BOPE TEST. TEST TO 250 -PSI / 3500 -PSI FOR 5- CHARTED MIN PER TEST. AOGCC REP BOB NOBLE WAIVED STATE'S RIGHT TO WITNESS BOPE TEST. ALL TESTS WITNESSED BY BP WSL & NORDIC TOOLPUSHER. TEST 2 -3/8" COMBIS WITH 2 -3/8" TEST JOINT. TEST 2 -3/8" X 3 -1/2" VBRS WITH 2 -3/8" & 3 -1/2" TEST JOINTS. TEST TWO(EA) FOSV. 17:45 - 18:30 0.75 BOPSUR P PRE HOLD H2S RIG EVAC DRILL WITH ENTIRE RIG TEAM. SIMULATED H2S ALARM ON THE RIG FLOOR &ALL MUSTERED SAFELY AND PROMPTLY TO PRIMARY MUSTER AREA HELD AAR AND EXPLAINED H2S HAZARDS AND RESPONSE TO NEW ROUSTABOUT. ALSO IDENTIFIED THAT WIND INDICATORS WERE IN PLACE ON EITHER SIDE OF THE RIG. ALL WARNING LIGHTS WORKED AS DESIGNED. EVAC SIREN ON REEL HOUSE DID NOT SOUND. HOLD PRE -SPUD MEETING WTH RIG CREW. 18:30 - 21:30 3.00 BOPSUR P PRE COMPLETE BOPE -TEST BY TESTING ALL VALVES ON KILL AND CHOKE LINE AS WELL AS KILL AND CHOKE MANIFOLDS. SEE ATTACHED CHARTS. 21:30 - 22:30 1.00 BOPSUR P PRE CLEAR RIGFLOOR. LAY DOWN TEST JOINT AND PACK UP TEST PUMP. CHECK INJECTOR, PRESSURE -UP N2- BOTTLES. 22:30 - 23:00 0.50 RIGU P PRE HOLD PJSM BEFORE CUTTING COIL. PICK UP INJECTOR AND MU COIL CUTTER. 23:00 - 00:00 1.00 RIGU N SFAL PRE HAVE CUT -25' WHEN SLB DRILLER NOTICES THAT COIL IS NOT MOVING FREELY. INSPECT GOOSENECK AND NOTICE THAT ROLLERS ARE TOO TIGHT, THEREFORE HAVE TO RE- ADJUST GOOSENECK ROLLERS. 1/28/2013 00:00 - 00:30 0.50 RIGU P PRE HOLD PRESPUD MEETING WITH CREWS AND REVIEW WELLPLAN. Printed 2/18/2013 2:13:10PM North America - ALASKA B 1 Aeration Summary Re Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 01:15 0.75 RIGU N SFAL PRE CONTINUE RE- ADJUSTING GOOSENECK ROLLERS. 01:15 - 01:45 0.50 RIGU P PRE COMPLETE CUTTING COIL (CUT 80' TOTAL) AND MEG -TEST CABLE FOR CONTINUITY. 01:45 - 03:30 1.75 RIGU P PRE MU COILED TUBING CONNECTOR, PULL -TEST TO 35K LBS. MU BHI UPPER QUICK CONNECT AND FLOW SUB. MEG - TESTAGAIN, ALL GOOD. 03:30 - 05:00 1.50 RIGU P PRE PUMP 1OBBLS OF METHANOL, FOLLOWED BY 10BBLS RIG WATER. CLOSE INNER REEL VALVE AND PRESSURE -TEST REELHOUSE IRON TO 300PSI / 5 MINS AND 3,500PSI / 5MINS - ACHIEVE GOOD TEST. 05:00 - 05:30 0.50 RIGU P PRE PICKUP INJECTOR AND INSTALL TEST- PLATE. PRESSURE -TEST INNER REEL VALVE AND COILED TUBING CONNECTOR TO 300PSI / 5MINS AND 3,500PSI / 5MINS. NOTICE SMALL LEAK ON CTC. BLEED DOWN PRESSURE. 05:30 - 07:15 1.75 RIGU N SFAL PRE PICK UP INJECTOR, REMOVE UPPER QUICK CONNECT AND CUTOFF CTC. INSTALL NEW CTC. PULL TEST TO 35K -LBS - GOOD TEST. PRESSURE TEST CTC TO 3500 -PSI - NO LEAKS. 07:15 - 08:30 1.25 BOPSUR P PRE STAB ON WELL. TEST INNER REEL VALVE, PACKOFFAND LUBRICATOR TO 250 -PSI / 3500 -PSI FOR 5 -MIN PER TEST TO COMPLETE BOPE TEST. GOOD TESTS. 08:30 - 09:30 1.00 RIGU P PRE BHI MU UQC. MEG TEST GOOD. 09:30 - 11:00 1.50 RIGU P PRE TEST BHI DBPV TO 250 -PSI / 3500 -PSI FOR 5 -MIN PER TEST. GOOD LOW PRESSURE TEST BUT HIGH PRESSURE BLEEDING OFF BUT NO VISIBLE LEAKS. INSPECT CHECKS BUT NO ISSUES IDENTIFIED. RE- INSTALL AND PRESSURE TEST GOOD. SET INJECTOR OVER CIRC HOLE. 11:00 - 11:45 0.75 RIGU P PRE HOLD PJSM WITH VALVE SHOP. DISCUSS LUBRICATOR HANDLING, TESTING & TWC RETRIEVAL PROCEDURE AND THE IMPORTANCE OF CLEAR COMMUNICATION REGARDING PLAN FORWARD. PU DSM LUBRICATOR & MU TO CT RISER. 11:45 - 12:15 0.50 RIGU P PRE TEST DSM LUBRICATOR TO 250 -PSI / 3500 -PSI FOR 5- CHARTED MIN PER TEST. GOOD TESTS. 12:15 - 13:00 0.75 RIGU P PRE OPEN SSV, MASTER & SWAB VALVES. ATTEMPT TO ENGAGE TWC WITH PULLING TOOL AND UNABLE TO SUCCESSFULLY MU TO TWC. 13:00 - 13:15 0.25 RIGU N PRE POH WITH POLISH ROD & TAG UP IN LUBRICATOR. CLOSE MASTER &SSV. LEAK TIGHT TEST - NO FLOW. CLOSE SWAB VALVE & UNSTAB LUBRICATOR. INSPECT TIP - SEE TAG MARK ON NOSE OF PULLING TOOLAND SMALL MARK ON STARTING THREADS. CHANGE OUT PULLING TOOL. Printed 2/18/2013 2:13:10PM Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:15 - 14:30 1.25 RIGU N PRE STAB ON LUBRICATOR AND PRESSURE TEST TO 250 -PSI / 3500 -PSI. GOOD TESTS ATTEMPT TO ENGAGE TWC WITHOUT SUCCESS. ADJUST ANGLE OF BOP STACK/TREE TO ASSIST IN ENGAGING TWC - NO SUCCESS. UNSTAB LUBRICATOR AND LD POLISH ROD. 14:30 - 17:30 3.00 RIGU N PRE DISCUSS SITUATION WITH ENGINEERING & OPS SUPT. ORDER OUT VENTURI BASKET AND REQUEST MAGNETS FROM WIRELINE TOOL SERVICE. ASSESS OPTIONS ONCE EQUIPMENT ON LOCATION AND DECIDE TO RUN MAGNET ON LUBRICATOR POLISH ROD FIRST. 17:30 - 18:00 0.50 RIGU N PRE MU MAGNET TO POLISH ROD. STAB DSM LUBRICATOR ON WELLAND PRESSURE TEST TO 250 -PSI LOW/3500-PSI HIGH. GOOD TESTS PER TEMPORARY PIPEWORK CRITERIA. RIH WITH MAGNET ON POLISH ROD AND TAG 5" HIGHER THAN LAST TIME - ICE ?? POH. CLOSE SWAB, MASTER & SSV. LD LUBRICATOR AND MAGNET. 18:00 19:00 1.00 _ RIGU N PRE NO DEBRIS RECOVERED BY THE MAGNET. HOLD DETAILED CHAGE -OUT. ALSO GIVE TO DRILL SITE MAINTENANCE TO CONDUCT THEIR CHANGE -OUT. AGREE ON PLAN FORWARD TO MAKE UP VENTURI BASKET. 19:00 - 19:30 0.50 RIGU N PRE CLEAR RIGFLOOR AND PICKUP INJECTOR. INSTALL BLIND SUB TO BHI UPPER QUICK CONNECT AND MAKE UP VENTURI BASKET (BHA #1). 19:30 - 19:50 0.33 RIGU N PRE STAB ON INJECTOR AND PRESSURE -TEST QTS. 19:50 - 20:00 0.17 RIGU N PRE OPEN MASTER (23 1/2 TURNS), SSV AND SWAB (23 1/2 TURNS). 20:00 - 21:10 1.17 RIGU N PRE CAREFULLYRIHANDTAGUPAT27 .5'RIGHT UNDERNEATH THE MASTER VALVE (MV IS AT 26.90'). PICK UP SLIGHTLY TO 27.4' AND BRING ON PUMPS. START PUMPING WITH 2.46BPM / 3,070 PSI CIRC PRESSURE. FLUID TEMPERATURE IN IS 53DEGF, FLUID OUT IS 73DEG F. 21:10 - 21:30 0.33 RIGU N PRE ONCE 120BBLS HAVE BEEN PUMPED AT — 2.40BPM, START JOGGING UP TO 24' AND DOWN TO 27.5' AGAIN IN ORDER TO STIR UP ANY POTENTIAL DEBRIS BY CHANGING HYDRAULICS. AFTER 8X UP /DOWN PASSES, TAG UP AGAIN AND SIT DOWN AT 28'. HAVE GAINED 0.5FT? DECIDE TO PULL OFF INJECTOR AND CHECK BASKET. HAVE PUMPED IN TOTAL 190BBLS. 21:30 - 22:00 0.50 RIGU N PRE POP OFF INJECTOR AND INSPECT VENTURI BASKET. NOTHING INSIDE BASKET WHICH COULD HAVE PREVENT TWC PULLING TOOL FROM GETTING ENGAGED IN TWC (ONLYA VERY SMALLAMOUNT OF SAND AND 2 PIECES OF ELECTRICAL TAPE WERE RECOVERED). Printed 2/18/2013 2:13:10PM Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date /me: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 22:50 0.83 RIGU N PRE MOVE INJECTOR TO SIDE AND CIRCULATE IN BUNGHOLE. PICK UP DSM LUBRICATOR, STAB ONAND PRESSURE TEST TO 250 -PSI / 3500 -PSI. ACHIEVE GOOD TEST. 22:50 - 23:45 0.92 RIGU N PRE OPEN SWAB, SSVAND MASTERVAVLE. RIH WITH ROD AND ACHIEVE 155" WITHOUT ISSUE. FIRST ATTEMPT TO SCREW PULLING TOOL INTO TWC FAILS. SECOND, HOWEVER, IS SUCCESSFUL. FULLY ENGAGE PULLING TOLLAND RECOVER TWC TO SURFACE. CHECK FOR PRESSURE AND CONFIRM THAT WELL IS ON A STRONG VAC. CLOSE TREE VAVLES AND POP OFF LUBRICATOR. 23:45 - 00:00 0.25 RIGU P PRE LIFT OUT DSM LUBRICATOR AND CLEAR RIG FLOOR. 1/29/2013 00:00 - 00:15 0.25 RIGU P PRE FINISH CLEARING RIG FLOOR. 00:15 01:30 1.25 RIGU P PRE PICK UP INJECTOR, INSTALL NOZZLE AND STAB ON. LINE UP AND PUMP 5BBLS WATER / 8BBLS METHANOL / 5BBLS WATER INTO COIL. PUMP METHANOL OVER GOOSENECK FOR FREEZE- PROTECTION. 01:30 - 02:00 0.50 RIGU, P PRE PrCK UP INJECTOR AND STAND TO SIDE. INSTALL NIGHT CAP. 02:00 - 03:00 1.00 RIGU P PRE HOLD PJSM. PRESSURE -TEST NIGHT CAP TO 300 PSI / 5MINS AND 3,500PSI / 5MINS. BLEED OFF PRESSURES. 03:00 03:30 0.50 RIGU P PRE LINEUP METHANOL PUP. OPEN SWAB AND MASTER VALVES AND SEE OPSI SITHP. 03:30 - 05:00 1.50 RIGU P PRE COMMENCE WELL KILL - BULLHEAD WELL WITH A SPEAR OF 8BBLS METHANOL, FOLLOWED BY 200BBLS KCL AND 200BBLS MUDAT4.5BPM. PUMP WITH BOTH MUD -PUMPS AT - 2,000PSI CIRC PRESSURE. 05:00 - 05:30 0.50 RIGU P PRE STOP PUMPING. OPEN HCR AND CHOKE AND BLEED BACK 3BBLS FROM CHARGED WELL. 05:30 - 06:00 0.50 RIGU P PRE CONDUCT 3OMIN FLOWCHECK- ACHIEVE R GOOD NO FLOW FOR 30MINS. 06:00 - 07:00 1.00 RIGU P PRE FILL HOLE AND SEE FIRST RETURNS AFTER <1 BBL PUMPED. MONITOR IN AND OUT RATES AND SEE LOSS RATE -3 -BPH. 07:00 - 08:30 1.50 WHIP P WEXIT HOLD PJSM ON MU WHIPSTOCK RUNNING BHA. DISCUSS POSITIONS OF PEOPLE, ORDER OF MU, TOOL HANDLING AND WELL CONTROL CONSIDERATIONS (BHA IS SHORT ENOUGH TO POH). MU WHIPSTOCK RUNNING BHA. BHA CONSISTS OF 4 -1/2" KB PACKER FLOW -THRU WHIPSTOCK, RUNNING TOOL, XO, HOT, DGS, DPS, EDC, P &C, WEAR SUB, LQC, UQC, XO & CTC. OAL = 79.26'. MU COIL TO BHA & STAB ON WELL. TEST QTS TO 250 -PSI / 3500 -PSI FOR 5 -MIN PER TEST. GOOD TESTS. OPEN EDC & CIRCULATE OUT MEOH FREEZE PROTECT FROM COIL. 08:30 - 10:30 2.00 WHIP P WEXIT RIH WITH WHIPSTOCK RUNNING BHA. CIRCULATE AT .22 -BPM / 830 -PSI. LOSS RATE CONTINUES AT -3 -BPH. Printed 2/18/2013 2:13:10PM North America - ALASKA B M k' a / Aeration Summary Re po kitiAaerittg Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:30 1.00 WHIP P WEXIT LOG TIE IN PRE GEO FROM 9790'. APPLY -15' CORRECTION. CIRCULATE AT .22 -BPM / 750 -PSI WHILE LOGGING. MW IN / OUT = 8.48 -PPG / 8.54 -PPG. IA / OA = 10 -PSI / 190 -PSI. 11:30 - 12:00 0.50 WHIP P WEXIT CONTINUE TO RIH WITH WHIPSTOCK. LOG CCL FROM 10,750' TO 10,900'. 12:00 - 12:20 0.33 WHIP P WEXIT POH TO PLACE WS ON DEPTH WITH TOP AT 10,800' (BOTTOM OF WS AT 10,816.25') ASSESS SET DEPTH WITH REGARD TO COLLARS - SET DEPTH 4' BELOW COLLAR. CONFIRM PLACEMENT WITH ODE. PRESSURE UP TO SET WHIPSTOCK. SEE SHEAR AT 2800 -PSI. SHUT DOWN PUMP AND STACK 5K -LBS DOWN TO CONFIRM SET. 12:20 - 12:45 0.42 WHIP P WEXIT FLOW CHECK WELL. 12:45 - 14:30 1.75 WHIP P WEXIT POOH FOR WINDOW MILLING BHA 14:30 - 14:45 0.25 WHIP P WEXIT FLOW CHECK WELL 14:45 - 15:15 0.50 WHIP P WEXIT PJSM TO LD WS BHAAND MU WINDOW MILLING BHA 15:15 - 15:45 0.50 WHIP P WEXIT BHA CHANGE 15:45 - 16:00 0.25 STWHIP P WEXIT PU INJECTOR & MU TO THE BHAAND PT THE QTS 16:00 - 17:45 1.75 STWHIP_ P WEXIT RIH 17:45 - 18:40 0.92 STWHIP P WEXIT LOG TIE IN AND INCREASE RATE TO CHECK LOSS RATE - RETURNS ARE 1:1 APPLY -13FT DEPTH CORRECTION 18:40 - 19:00 0.33 STWHIP P WEXIT TAG WHIPSTOCK'S PINCH POINT AT 10,801'. PICK UP AND RE -TAG 10,802'. PUW = 41K LBS, FREE SPIN = 2,750PSI. PICK UP AND TAKE SLOW PUMP RATES: PUMP #1: PUMP #2: 2.7 BPM - 2,703 PSI - 121 SPM 2.7 BPM - 2,750 PSI - 122 SPM 1.5 BPM - 1,714 PSI - 66 SPM 1.5 BPM - 1,703 PSI - 65 SPM 0.5 BPM - 1,095 PSI - 23 SPM 0.5 BPM - 1,040 PSI - 23 SPM 19:00 - 20:20 1.33 STWHIP P WEXIT SLOWLY RIH AT 1 F /MIN. FREE SPIN - 2,750PSI. SEE FIRST MOTORWORKAT 10,801.4' - START TIME - MILLING THE WINDOWAT 1FT /MIN. 19:12HRS / 10,801.40' / MM -IN - 2.68 BPM / MM -OUT - 2.7 BPM / CIRC P - 2,838 PSI / DIFF P - 448PSI Printed 2/18/2013 2:13:10PM North America - ALASKA B,.�� Operation Summary Report. p rY Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UM: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:20 - 00:00 3.67 STWHIP P WEXIT HAVE MILLED 1ST FOOT. STOP TIME - MILLING AND SLOWLY INCREASE WOB. 20:25HRS / 10,802.60' / MM -IN - 2.64 BPM / MM- OUT - 2.65 BPM / CIRC P - 2,904 PSI / DIFF P - 557 PSI / WOB - 0.07 K LBS 22:15 10,804.20 2.65 2.69 2,900 607 3.18 22:53 10,805.40 2.63 2.65 2,831 565 3.32 23:29 10,806.40 2.63 2.64 2,802 534 2.57 23:56 10,807.40 2.63 2.65 2,845 606 2.27 1/30/2013 00:00 - 01:30 1.50 STWHIP P WEXIT 00:17HRS / 10,808.30' / MM -IN - 2.63 BPM / MM -OUT - 2.66 BPM / CIRC P - 2,761 PSI / DIFF P - 545PSI / WOB - 0.65 K LBS AT 10,808.3' OBSERVE A DISTINCT DROP IN WOB, SUGGESTING THAT THE MILL HAS FULLY BROKE THROUGH THE TUBING WALL. REVERT BACK TO TIME - MILLING AT 10,808.4' (7' FROM TOWS) AND MILL TO 10,810'. 01:30 - 02:45 1.25 STWHIP P WEXIT START MILLING 10' RATHOLE. 02:20HRS / 10,818.30' / MM -IN - 2.63 BPM / MM -OUT - 2.66 BPM / CIRC P - 2,761 PSI / DIFF P - 545PSI / WOB - 0.65 K LBS 02:45 - 03:45 1.00 STWHIP P WEXIT PICK UP TO 10,979', THEN PERFORM 3X UP /DOWN PASSES TO REAM THE WINDOW. PUMP 2OBBLS HIGH VISC PILL TO HELP LIFTING OUT METAL SHAVINGS FROM MILLING WINDOW. GEO CONFIRMS FORMATION (SILTSTONE) IN 10,820'- SAMPLE. 03:45 - 04:00 0.25 STWHIP P WEXIT DRY -DRIFT WINDOW, DO NOT OBSERVE ANY ISSUES. PULL TO 10,785' AND PERFORM 5MINS FLOWCHECK. 04:00 - 05:50 1.83 STWHIP P WEXIT POOH. * * ** MEANWHILE CONDUCT KICK WHILE TRIPPING / MUD GAS SEPARATOR DRILL * * ** CONDUCTED A KICK WHILE TRIPPING DRILL, FOLLOWED BYAMGS LINE -UP DRILL. SIMULATED TO MAKE THE WELL SAFE BY CLOSING HCR AND LINE UP TO CHOKE. INSTALLED PRESSURE GAUGE TO READ SITP AND EQUALIZED ACROSS HCR. DISCUSSED HOW TO LINE UP MGS AND WHAT TO CONSIDER BEFORE USING THE MGS (CONFIRM OPEN VENT, SHUT -IN IGNITION SOURCES). GOOD DRILL, CREWS KNEW WHAT TO DO, ALL REQUIRED ACTIONS WERE TAKEN IN A TIMELY MANNER. 05:50 - 06:20 0.50 STWHIP P WEXIT PULL TO 220' AND FLOWCHECK WELL. ACHIEVEA GOOD NO- FLOWAND PULL TO SURFACE. Printed 2/18/2013 2:13:10PM F North America - ALASKA 6 � Operation Summary Repo Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UVM: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:20 - 06:45 0.42 STWHIP P WEXIT CREW CHANGE COMPLETED, HOLD PJSM TO CHANGE OUT BHA'S 06:45 - 07:05 0.33 STWHIP P WEXIT TAG UP, REMOVE INJECTOR AND LD MILLING BHA 07:05 - 07:15 0.17 STWHIP P WEXIT BHAOOH GAUGE MILLS VMNDOW MILL = 3.80 GO 3.79 NO GO STRING MILL = 3.80 GO 3.79 NO GO MILLS ARE IN GAUGE, VMNDOW MILL SHOWS GOOD WEAR ON THE FACE INDICATING WAS ON METAL 07:15 - 07:30 0.25 DRILL P WEXIT FILL HOLE, HOLE IS FULL NO LOSSES CHECK TREE BOLTS 07:30 - 08:00 0.50 DRILL P WEXIT MWD WOULD NOT BLOW DOWN WITH MOTOR ON, RUN MVVD BACK IN THE WELL TO BLOW DOWN REMOVE MWDAND PREP TO MU BHA 08:00 - 08:30 0.50 DRILL P WEXIT HOLD OFF ON RUNNING THE BHA, LITTLE RED IS REQUESTING ACCESS TOAWELL BEHIND OUR RELIEF TANK LINE TO FREEZE PROTECT IT 08:30 - 09:30 1.00 DRILL P WEXIT THE FLOWLINE LITTLE RED IS TRYING TO ACCESS IS ALREADY FROZE UP AND IS APPERENTLY NOTA PRIORITY CONTINUE BHA MU PT QTS 09.30 - 11:15 1.75 DRILL P WEXIT RIH 11:15 - 11:50 0.58 DRILL P WEXIT LOG TIE IN 11:50 - 12:10 0.33 DRILL P WEXIT CORRECT DEPTH -12' 12:10 - 12:20 0.17 DRILL P WEXIT TAG TD AT 10821', PU AND OBTAIN PARAMETERS 12:20 - 12:40 0.33 DRILL P WEXIT ON BOTTOM DRILLING PU WT = 35K RIH WT = 17K DRILL AS PER GEO AT 93° UNTIL WE SEEA CHANGE IN THE GAMMA FREE SPIN = 3300 PSI AT 2.70 BPM RATE IN = 2.69 BPM RATE OUT = 2.70 BPM ROP = 60 FPH WOB = 3 -4K CIRC PSI =3685 PSI MW IN =8.54 PPG MW OUT =8.52 PPG ECD = 10.03 PPG IAP =7 PSI OAP =0 PSI PVT= 342BBLS NO LOSSES 12:40 - 13:50 1.17 DRILL P WEXIT MADEACOUPLEFEETTHENJUSTSTACKING WT, PU AND TRY WORKING MOTOR THROUGH THE WINDOW. TAG BUT NO MOTOR WORK, PU AND TRYA LITTLE FASTER RIH SPEED. TAGGED BOTTOM AND ITS TRYING TO STALL, PU AND PULL HEAVY -25K OVER. ROLL TF TO 90° THE SAME TF THE VMNDOW WAS CUTATAND SEE IF WE CAN GET TO BOTTOM. GETTING WT TO BIT AFTER STACKING 9K BUT THEN STALLS, TRY STACKING 6K THEN ORIENT AROUND TO OPEN UP THE HOLE AND SEE I THATALLOWS THE MOTOR TO SLIDE THROUGH Printed 2/18/2013 2:13:10PM Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:50 - 14:05 0.25 DRILL P WEXIT NOT MAKING MUCH PROGRESS, PU ABOVE WINDOW THEN TRY RIH TO BOTTOM AGAIN TAGGED VNTH 5K WOB, BRING PUMP UP TO FULL RATE AND WE ARE AT FREE SPIN PRESSURE, MOTOR IS JAMMED IN THE WINDOW GO TO MIN RATE, PU WITH 15K OVER PULL, CALL ODE AND DISCUSS PULLING TO DROP THE 3 -1/8" 18 +' MOTOR FOR A 12' 2 -7/8 MOTOR TO GET THROUGH THE WINDOW 14:05 - 14:10 0.08 DRILL N DPRB WEXIT FLOW CHECK WELL AND POOH FORA2 -7/8" ULTRA LOW SPEED MOTOR 14:10 - 15:15 1.08 DRILL N DPRB WEXIT GOOD NO FLOW POOH, PVT = 346 BBLS 15:15 - 15:40 0.42 DRILL N DPRB WEXIT PJSM WHILE POOH TO SWAP MUD MOTORS 15:40 - 15:50 0.17 DRILL N DPRB WEXIT CONTINUE POOH 15:50 - 15:55 0.08 DRILL N DPRB WEXIT FLOW CHECK WELL FROM 200' 1 15:55 - 16:45 0.83 DRILL N DPRB WEXIT GOOD NO FLOWCHECK, TAG UP AND REMOVE THE INJECTOR TO PULL THE BHA 16:45 - 17:00 0.25 DRILL N DPRB WEXIT UQC IS PACKED OFF WITH CLAY AND SHALE AND ITS 80' FROM THE WNDOWAND THE BIT IS COMPLETELY BALLED UP WITH THE SAME. DISCUSS FINDINGS WITH ODE AND WE ARE GOING TO RUN THE 2 -7/8" ULSM W/ HCC DBL SLICK BIT. HYC BIT GRADE = 1 -1 17:00 - 19:15 2.25 DRILL N DPRB PROD1 MU BHA #5, TEST THE QTS AND RIH. 19:15 - 19:35 0.33 DRILL N DPRB PROD1 LOG TIE IN AND APPLY A -12' DEPTH CORRECTION. 19:35 - 19:45 0.17 DRILL P • PROD1 RIH THROUGH WINDOW TO 10,817'. 19:45 - 20:10 0.42 DRILL P PROD1 FROM 10,817' SNEAK TO BOTTOM AT 1 FT /MIN. FREESPIN = 2,970 @ 2.93BPM. MW IN =8.53 PPG / MW OUT =8.52 PPG / ECD = 10.05 PPG / PVT = 342 BBLS, NO LOSSES. IA = 4 PSI / OA = 0 PSI 20:10 - 22:00 1.83 DRILL P PROD1 AT 10,824' NOTICE AN INCREASE IN VVOB TO 1.86K LBS INDICATING THAT BIT HAS REACHED BOTTOM. COMMENCE DRILLING AHEAD. CURRENT MOTOR / BIT -COMBO IS DOING A GOOD JOB DRILLING - NO STALLS, NO PICKING UP, SLOW BUT STEADY DRILLING AHEAD. ROP = 20 - 30 FPH, VVOB = 2.2- 2.9 K LBS, CIRC PRESSURE = 2,980 - 3,050 PSI @ 2.85BPM. MM IN = 2.85 BPM / MM OUT = 2.89 BPM MW IN =8.54 PPG / MW OUT =8.52 PPG / ECD = 9.91 PPG PVT = 343 BBLS, NO LOSSES IA = 122 PSI / OA = 71 PSI Printed 2/18/2013 2:13:10PM Common Well Name: 05 -35 AFE No Event Type: RE- ENTER - ONSHORE (RON) Start Date: 1 /17/2013 End Date: 2 /2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name/No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 22:15 0.25 DRILL P PROD1 DRILL TO 10,865'. DGS HAS PASSED RA -TAG, SO PICK UP AND LOG TO DEPTH - CORRECT WHIPSTOCK. RA -TAG - 10,810' / TOWS - 10,801' / TOW - 10,802' / BOW - 10,809'. ALSO TAKE SLOW PUMP RATES: PUMP #1: PUMP #2: 2.9 BPM - 2,853 PSI - 127 SPM 2.9 BPM 2,849 PSI - 127 SPM 1.5 BPM - 1,685 PSI - 66 SPM 1.5 BPM - 1,677 PSI - 66 SPM 0.5 BPM - 985 PSI - 24 SPM 0.5 BPM - 905 PSI - 21 SPM 22:15 - 22:30 0.25 DRILL P PROD1 BACK TO BOTTOM DRILLING. 22:30 - 00:00 1.50 DRILL N SFAL PROD1 NEED TO PICK OFF BOTTOM DUE TO ISSUE WITH MWD COMPUTER. DIRECTIONAL DRILLER TAKES OPPORTUNITY TO REBOOT HIS COMPUTER, HOWEVER COMPUTER CANNOT BOOT UP ANYMORE. SPEND TIME FAULT FINDING BUT THEN DECIDE TO REPLACE DDS COMPUTER. 1/31/2013 14:55 15:10 0.25 DRILL P PROD1 ROP INCREASE & DECREASE IN CIRC PRESSURE AND WOB, LOOKS LIKE WE FOUND A SAND 00:00 - 00:30 0.50 DRILL N SFAL PROD1 COMPLETE REPLACING DD'S COMPUTER. 00:30 03:40 3.17 DRILL P PROD1 BACK TO BOTTOM AND BACK TO DRILLING. ROP =20 -40 FPH, WOB = 2.5- 4.0 K LBS, CIRC PRESSURE = 3,000 - 3,100 PSI, NO LOSSES. 03:40 - 03:50 0.17 DRILL P PROD1 LOOSE DIFF PRESSURE. NEED TO PICKUP AND TAKE OPPORTUNITY FOR 100' WIPER -TRIP - PUW = 37.5 - 38.5 K LBS. 03:50 - 05:00 1.17 DRILL P PROD1 CONTINUE DRILLING AHEAD WITH EFFECTIVELY SAME PARAMETERS THAN BEFORE. ROP = 20 - 40 FPH, WOB = 2. 2- 2.9 K LBS, CIRC PRESSURE = 2,980 - 3,050 PSI @ 2.85BPM. SAMPLES SHOW 100% "CLAYEY" SILTSTONE WITH NO SAND AT ALL. DRILL AHEAD AT AN INCLINATION OF 93? TO GET TO A TVD OF 8,875' WHICH SHOULD BE THE BOTTOM OF THE TARGET -SAND. 05:00 05:15 0.25 DRILL P PROD1 PERFORM FURTHER 100' WIPER TRIP. PUW= -39.5 K LBS, SOW = 12.5 K LBS. 05:15 - 08:00 2.75 DRILL P PROD1 CONTINUE DRILLING AHEAD. ROP = 20 - 40 FPH, WOB = 3.0- 4.0 K LBS, CIRC PRESSURE = 3,070 - 3,200 PSI @ 2.76BPM. MM IN = 2.79 BPM / MM OUT = 2.82 BPM / MW IN =8.57 PPG / MW OUT =8.56 PPG / ECD = 9.97 PPG PVT = 338 BBLS, NO LOSSES IA = 352 PSI / OA = 33/8 PSI Printed 2/18/2013 2:13:10PM North America - ALASKA ,,, , 4 444afite,VINWAV404WialOVS:giti;:it /'/ o peration Summary Report Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 I Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 09:00 1.00 DRILL P PROD1 DIFF PRESSURE DRILLED OFF, WENT TO PU AND STARTED PULLING HEAVY FOR 15'. RAN BACK DOWN, PU AGAIN & PULLED TO 61K RAN BACK DOWN AND RELAXED COIL FOR A FEW MINUTES THEN PULLED TO 62K AND PULLED FREE. POOH TO WINDOW TO MAKE SURE HOLE IS CLEAN 09:00 - 09:20 0.33 DRILL P PROD1 PUMP 20 BBL HI -VIS PILL CLOSE TO BOTTOM OF WINDOW THEN RIH 09:20 - 09:35 0.25 DRILL P PROD1 OBTAIN SPR'S 09:35 - 10:30 0.92 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN = 2922 PSI ROP = 40 FPH WOB = 4,0- 6.0 K LBS CIRC PRESSURE = 3230 PSI MM IN = 2.85 BPM / MM OUT = 2.86 BPM MW IN = 8.58 PPG / MW OUT = 8.59 PPG ECD = 9.97 PPG. PVT = 338 BBLS, NO LOSSES IA = 352 PSI OA = 338 PSI 10:30 - 12:10 1.67 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN 2922 PSI .ROP = 40 FPH WOB = 4.0- 6.0 K LBS CIRC PRESSURE = 3230 PSI MM IN = 2.85 BPM / MM OUT = 2.86 BPM MW IN = 8.58 PPG / MW OUT = 8.59 PPG ECD = 10.1 PPG PVT = 319 BBLS, NO LOSSES IA = 511 PSI OA = 496 PSI BLEED DOWN TO 300 & 100 PSI 12:10 - 13:20 1.17 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN = 2922 PSI ROP = 35 FPH WOB = 4.0- 6.0 K LBS CIRC PRESSURE = 3520 PSI MM IN = 2.85 BPM / MM OUT = 2.83 BPM MW IN =8.61 PPG /MW OUT =8.61 PPG ECD = 10.15 PPG PVT = 320 BBLS, NO LOSSES IA = 291 PSI OA = 103 PSI 13:20 - 13:45 0.42 DRILL P PROD1 BHA WIPER TO CHECK PARAMETERS PU WT 40K RIH WT 13K 13:45 - 14:55 1.17 DRILL P PROD1 PARAMETERS LOOK GOOD, CONTINUE DRILLING AHEAD. FREE SPIN = 2922 PSI ROP = 20 FPH WOB = 4.0- 7.0 K LBS CIRC PRESSURE = 3275 PSI MM IN = 2.79 BPM / MM OUT = 2.80 BPM MW IN =8.61 PPG /MW OUT =8.61 PPG ECD = 10.12 PPG PVT = 320 BBLS, NO LOSSES IA = 325 PSI OA = 137 PSI 15:10 - 15:15 0.08 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN 2922 PSI ROP = 130 FPH WOB = 3.87 K CIRC PRESSURE = 3473 PSI MM IN = 2.79 BPM / MM OUT = 2.82 BPM MW IN = 8.63 PPG /MW OUT = 8.68PPG ECD = 10.28 PPG PVT = 319 BBLS, NO LOSSES IA = 376 PSI OA = 183 PSI Printed 2/18/2013 2:13:10PM North America - ALASKA B Operation Summary Repo, , Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:15 - 15:40 0.42 DRILL P PROD1 DRILLING ROP BACK TO 30 FPH, LOOKS LIKE WE BLEW PAST IT AND HAVE TO COME BACK DOWN. 15:40 - 16:00 0.33 DRILL P PROD1 GEO SAYS WE NEED TO COME BACK DOWN AND IT IS STARTING TO TAKE A LOT OF WT TO DRILL. PU'S ARE GETTING A LITTLE STICKY WITH 15K OVER PULLS, SHORT TRIP TO THE WINDOW TO CLEAN UP THE HOLE AND GIVE THE DD SOME TIME WITH HIS WELL PLAN 16:00 - 16:15 0.25 DRILL P PROD1 LOG TIE IN 16:15 - 16:35 0.33 DRILL P PROD1 CORRECT DEPTH +6.5' AND RIH 16:35 - 17:00 0.42 DRILL P PROD1 BACK ON BOTTOM DRILLING FREE SPIN = 3000 PSI ROP = 50 FPH WOB = 3.10 K CIRC PRESSURE = 3256 PSI MM IN = 2.79 BPM / MM OUT = 2.83 BPM MW IN = 8.65 PPG /MW OUT =8.70PPG ECD = 10.18 PPG PVT = 317 BBLS, LOST 2 BBLS IA= 360 PSI OA= 171 PSI 17:00 - 18:00 1.00 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN = 3000 PSI ROP = 110 FPH WOB = 2.38 K CIRC PRESSURE = 3325 PSI MM IN = 2.75 BPM / MM OUT = 2.77 BPM MW IN = 8.63 PPG / MW OUT = 8.68 PPG ECD = 10.23 PPG PVT = 317 BBLS, NO LOSSES IA = 396 PSI OA = 189 PSI 18:00 - 18:15 0.25 DRILL N SFAL PROD1 PU OFF BOTTOM TO SORT OUT DD'S WELL ARCHITECT. 18:15 - 19:15 1.00 DRILL P PROD1 DRILL AHEAD FROM 11,350' AND NOTICE CLEAN SANDSTONE DETERIORATING TO SILT / CLAY / DIRTY SANDSTONE WITH GAMMA- READINGS AROUND 130 - 150 API. ROP DROP TO 60FT /HR AT BEST. 19:15 - 19:45 0.50 DRILL P PROD1 DRILL TO 11,450' AND PERFORM 100' BHA - WIPER. OVERALL PUW WAS 40K LBS WITH FEW SPIKES UP TO 43 / 44 KLBS. SOW WAS 11.5K LBS WHEN RUNNIGN BACK IN HOLEAGAIN. 19:45 - 23:00 3.25 DRILL P PROD1 CONTINUE DRILLING AHEAD. PUMPED 15BBLS HIGH VIS PILL WITHOUTANY ROP = 40 - 80 FPH, WOB = 3.3- 6.3 K LBS, CIRC PRESSURE = 3,100 - 3,400 PSI © 2.76BPM. MM IN = 2.76 BPM / MM OUT = 2.78 BPM / MW IN =8.67 PPG / MW OUT =8.68 PPG / ECD = 10.31 PPG PVT = 313 BBLS, NO LOSSES IA = 497 PSI / OA = 288 PSI 23:00 - 00:00 1.00 DRILL P PROD1 DRILLED FURTHER 150' TO 11,600'. PU FOR WIPER -TRIP TO WINDOW. WHEN PULLING UP, SEE PUW= 40K LBS WITH A FEW OVERPULLS OF 10 - 15K LBS. Printed 2/18/2013 2:13:10PM A North America - ALASKA B 0 exation Summary Report er Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date /me: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/1/2013 00:00 - 00:50 0.83 DRILL P PROD1 PULL INTO WINDOWAND OPEN EDC. CONTINUE TO PULL UP TO 9,900' (ONWARDS FROM WHERE WELLBORE INCLINATION IS <40DEG) TO HELP LIFTING OUT CUTTINGS. CLOSELY MONITOR SHAKERS WHEN PIT COMES BACK TO SURFACE: CANNOT SEE ANY SIGNIFICANT INCREASE IN CUTTINGS. 00:50 - 01:30 0.67 DRILL P PROD1 LOG FOR TIE- IN.PERFORMA +3FTDEPTH CORRECTION. 01:30 - 05:10 3.67 DRILL P PROD1 BACK TO DRILLING IN A MONOTONOUS CLAY / SILT / DIRTY SANDSTONE WITH GAMMA RAY SHOWING —130 API. GEO CALLS AND REQUESTS DD TO STEER DOWN TO TVD = 8,886 - 8,888'. ROP = 20 - 30 FPH WOB = 4.0- 6.0 K LBS CIRC PRESSURE = 3,200 - 3,400 PSI FREE SPIN =3,000 PSI MM IN = 2.77 BPM /MM OUT = 2.82 BPM MW IN = 8.69 PPG / MW OUT = 8.69 PPG ECD = 10.42 PPG PVT = 311 BBLS, VERY STABLE PVT NO LOSSES ATALL IA = 575 PSI OA = 345 PSI 05:10 - 05:20 0.17 DRILL P PROD1 PICK UP FOR SHORT BHA -WIPER FROM 11,689' TO 11,600'. OBSERVE PUW= 40K LBS, SEE SOW = 10K LBS. NOT STICKY, ALL APPEARS TO BE CLEAN. 05:20 - 06:00 0.67 DRILL P PROD1 DRILL AHEAD TO 11,700' AT SAME DRILLING PARAMETERS THAN BEFORE. ROP REMAINS LOWAROUND 20- 30FT /HR, WOB RANGES BETWEEN 4 - 6 KLBS AND SEE MOSTLY BETWEEN 300 - 400 PSI MOTORWORK 06:00 - 08:50 2.83 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN = 3400 PSI ROP = 40 FPH WOB = 4.0- 6.0 K LBS CIRC PRESSURE = 3230 PSI MM IN = 2.85 BPM / MM OUT = 2.86 BPM MW IN = 8.58 PPG / MW OUT = 8.59 PPG ECD = 9.97 PPG PVT = 338 BBLS, NO LOSSES IA = 352 PSI OA = 338 PSI 08:50 - 09:05 0.25 DRILL P PROD1 DRILLING AHEAD AT 45 FPH STARTED STACKING WT WENT TO PU AND WE ARE PULLING HEAVY. TRIED WORKING PIPE UP AND DOWN TO 70 -80K THEN WORKED PIPE SEVERAL TIMES DOWN AND GOT FREE. 09:05 - 09:45 0.67 DRILL P PROD1 POOH TO TIE IN 09:45 - 10:10 0.42 DRILL P PROD1 PULLED TO 10826' JUST BELOW THE WINDOWAND GOT HUNG UP AGAIN. WORKED PIPE DOWN TO GET FREE AND START CIRCULATING 20 BBLS LOWAND HI -VIS PILLS TO CLEAN OH AND WELL BORE 10:10 - 10:50 0.67 DRILL P PROD1 PULLED INTO THE CASING, TURNAROUND AND RUN DOWN TO PUT THE EDC JUST BELOW THE WS. OPEN THE EDC AND PUMP AT MAX RATE WITH LOWAND HI -VIS PILLS CHASING THEM UP TO 9700' WHERE WELLBORE INCLINATION IS <40° Printed 2/18/2013 2:13:10PM Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Datefine: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:50 - 11:40 0.83 DRILL P PROD1 THE LEAD OF THE LOW VIS BROUGHT UP GRAVEL SIZE CHUNKS OF SHALE THEN WHEN THE HI -VIS CAME IT CARRIED OUT 2X MORE ROCKS AND CUTTINGS. CONTINUE POOH UNTIL RETURNS CLEAN UP POSSIBLY TO -3000' * * * *WE ARE ONLY ABLE TO PULLAT 38 FPM AND 3.8 BPM BECAUSE WE ARE AT 80% POWER CONSUMPTION * * * ** 11:40 - 12:15 0.58 DRILL P PROD1 RETURNS HAVE CLEANED UP, RIH TO CONTINUE DRILLING 12:15 - 12:30 0.25 DRILL P PROD1 CLOSE EDC AND TIE IN 12:30 - 13:15 0.75 DRILL P PROD1 CORRECT DEPTH +11' AND RIH TAG AT 11007' WITH MOTOR WORK, PU AND TRY WORKING DOWN. MADE IT PAST CONTINUE RIH START PULLING OLD MUD FROM PITS TO PREP FOR MUD SWAP 13:15 - 14:00 0.75 DRILL P PROD1 BACK ON BOTTOM DRILLING ROP = 40 FPH WOB = 4.0- 6.0 K LBS CIRC PRESSURE = 3180 PSI MM IN = 2.83 BPM / MM OUT = 2.85 BPM MW IN = 8.73 PPG /MW OUT = 8.67PPG ECD = 10.56 PPG PVT = PREP FOR MUD SWAP IA = 651 PSI OA = 436 PSI 14:00 14:30 0.50 DRILL P PROD1 SWAP TO NEW MUD 14:30 - 15:25 0.92 DRILL P PROD1 CONTINUE DRILLING AHEAD FREE SPIN = 3261 PSI ROP = 68 FPH WOB = 4.0- 6.0 K LBS CIRC PRESSURE = 3596 PSI MM IN = 2.85 BPM / MM OUT = 2.89 BPM MW IN = 8.76 PPG / MW OUT = 8.78 PPG ECD = 10.65 PPG PVT = 38 BBLS IA = 212 PSI OA = 198 PSI 15:25 - 15:35 0.17 DRILL P PROD1 NEW MUD AT SURFACE 15:35 - 15:50 0.25 DRILL P PROD1 OUT MM READING-0.2 BPM MORE THAN THE IN MM, PU OFF BOTTOM AND FLOW CHECK THE WELL 15:50 - 15:55 0.08 DRILL P PROD1 GOOD NO FLOW CHECKAT THE SHAKER, OUT MM MUST HAVE DEBRIS BLOCKING ONE OF THE TUBES BLOW DOWN OUT MM THEN CHECK PARAMETERS PARAMETERS ARE GOOD, CONTINUE DRILLING NEW 9.0 PPG MUD IS REQUIRING A LOT OF SURFACE WT TO DRILL, ABOUT 13K MORE DRILLING AT -9K SURFACE WT 15:55 - 16:45 0.83 DRILL P PROD1 DRILLED 150' WIPER TO WINDOW TO SEE IF IT IMPROVES OUR WEIGHT TRANSFER Printed 2/18/2013 2:13:10PM North America - ALA ° • r Operation Summary Repo Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:45 - 17:20 0.58 DRILL P PROD1 PULLED INTO SOMETHING JUST BELOW THE WINDOW. WE WERE ABLE TO WORK FREE AND PUMP AT A LOW RATE TO MOVE, IF WE INCREASE OUR RATE WE GET BIT STUCK. WORKED OUR WAY UP INTO THE CASING AND THEN STARTED WORKING OUR WAY DOWN TO CLEAN UP THE WINDOW. MADE IT DOWN TO 11900, PU SLOW TO THE WINDOW AND GOT BIT STUCKAGAIN. WORK BACK DOWN TO GET FREE, GOT FREE. KEEP TRYING TO WORK UP. 17:20 - 17:25 0.08 DRILL P PROD1 MADE IT UP TO 10815' RIH TO 10870' AND OPEN THE EDC JUST BELOW THE WINDOW TO CLEAN UP THE WELLBORE CALL OUT FOR MORE KLA-STOP TO INCREASE THE CONCENTRATION TO 4 %. 17:25 - 17:50 0.42 DRILL P PROD1 POOH SLOW TO 9900' PUMPING THROUGH THE EDC FOR A BOTTOMS UP 17:50 - 20:50 3.00 DRILL P PROD1 ABOUT 30 BBLS FROM BOTTOMS UP THE MICROMOTION IS PLUGGING OFF WITH SHALE, TAKE RETURNS THROUGH THE BYPASS LINE UNTIL THE RETURNS CLEAN UP. 20:50 - 22:30 1.67 DRILL P PROD1 - BACK TO BOTTOM; TAG UP AT 11,953' AND CONTINUE DRILLING AHEAD. ROP = 20 -30FPH WOB = 5.0- 6.0 K LBS CIRC PRESSURE = 3,300 - 3,400 PSI FREE SPIN = 3,100 PSI MM IN = 2.83 BPM / MM OUT = 2.91 BPM MW IN =8.97 PPG /MW OUT =8.91 PPG ECD = 10.76 PPG PVT = 345 BBLS (NO LOSSES) IA = 450 PSI OA= 229 PSI 22:30 - 23:10 0.67 DRILL P PROD1 INCREASE CONCENTRATION OF KLASTOP TO 4% IN MUDSYSTEM. 23:10 - 23:30 0.33 DRILL P PROD1 NOTICE THAT FOLLOWING 12,000' THE ROP INCREASES NOTABLY FROM - 25FT /HR TO >70FT /HR AND WOB DROPS FROM >5K LBS DOWN TO <3K LBS. CIRC PRESSURE REMAINS STEADY AT 3,300 - 3,400 PSI. DRILL TO 12,008' AND PU TO PERFORM A BHA -WIPER TO 11,930. OBSERVE PUW = 38K LBS, SOW= 9K LBS. NOT STICKY, APPEARS TO BE CLEAN. 23:30 - 00:00 0.50 DRILL P PROD1 ONCE BACK TO BOTTOM DRILL TO 12,060'. 2/2/2013 00:00 - 00:30 0.50 DRILL P PROD1 DRILL TO 12,100'. PUMP 2OBBLS LO -VIS / 2OBBLS HIGH -VIS PILL INTO COIL AND TIME SO THAT PILL COMES OUT OF BIT JUST BELOW 12,000' (MAIN SHALE INTERVAL). Printed 2/18/2013 2:13:10PM North America - ALASKA - BPS Operation Summary Repo Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 02:00 1.50 DRILL P PROD1 PU FOR WIPER TRIP TO WINDOW WHILE PULLING UP HOLD TOOL FACE AS DRILLED. PUW = 38K LBS. SEE OVERPULLS OF 10 -15K LBS AT 12,050' AND 12,025'. RUN BACK TO 12,060' TO ENSURE LO -VIS / HIGH -VIS PILL EXISTS BELOW "STICKY" SPOTS. ON 2ND PASS ACROSS INTERVAL 12,050' - 12,025' DO NOT NOTICE ANY OVERPULLS, NO FURTHER ISSUES DOWN TO 11,800' (TOP OF SHALE). CONTINUE SLOWLY PICKING UP. WHEN LO -VIS / HIGH -VIS PILL COMES BACK TO SURFACE, NOTICE A FEW BUT NOT MANY 0.5" - 1" LARGE CLAYSTONE / SHALE BITS RUNNING OVER SHAKER. OUT - MICROMOTION GETS PLUGGED UP A COUPLE OF TIMES WHILE PICKING UP ALSO INDICATING AN INCREASED RETURN OF SOLIDS. 02:00 - 02:30 0.50 DRILL P PROD1 ENCOUNTER SEVERAL "STICKY" SPOTS SHALLOWER THAN -10,900' HOWEVER GET TEMPORARILY STUCK AT 10,840'. WORK COIL AND GET FREE. 02:30 - 03:20 0.83 DRILL P PROD1 PULL INTO WINDOW. PU FROM WINDOWTO 10,200' PUMPING AT -3BPM TO AGITATE SOLIDS ON LOWSIDE OF HIGH -ANGLE TUBING. OPEN EDC AND RUN BACK IN HOLE PUMPING WITH BOTH PUMPS AT 4.26 BPM / 4,000 PSI CIRC PRESSURE. 03:20 - 04:05 0.75 DRILL P PROD1 RUN DOWN TO 10,870' (DEEPEST DEPTH WE CAN GO TO W /OUT GETTING THE OPEN EDC IN OPEN HOLE). TURN AROUND AT 10,870' AND PICK UP AGAIN. WHEN BOTTOMS UP FROM WINDOW ARRIVES AT SHAKER, SHAKER IS JUST FLOWING OVER WITH SOLIDS AND SHALE PEBBLES. 04:05 - 04:30 0.42 DRILL P PROD1 PULL UP TO 9,900'. TURN AROUND AND RIH STILL PUMPING THROUGH OPEN EDC AT 4.5BPM WITH - 4,000PSI CIRC PRESSURE. 04:30 - 05:40 1.17 DRILL P PROD1 RIH TO 10,757'. CLOSE EDC AND PERFORM TIE -IN LOG. APPLYA +5FT DEPTH CORRECTION. MEANWHILE START WEIGHING UP MUD SYSTEM TO 9.5PPG. 05:40 - 07:00 1.33 DRILL P PROD1 CONTINUE DRILLING AHEAD FROM 12,100' DRILLING AT -90 FPH, WT TRANSFER IS GOOD, CONTINUE DRILLING TO NEXT WIPER DEPTH OF 12250' 07:00 - 07:40 0.67 DRILL P PROD1 9.5 PPG MUD ALL THE WAY AROUND PVT= 313 BBLS DRILLED 150', WIPER TO WINDOW MAINTAINING AS DRILLED TOOLFACES THROUGH SHALE & POTENTIAL TROUBLE ZONES 12020' 1 10K OVER PULL, OUT MM IS ALREADY STARTING TO SHOW SIGNS OF PLUGGING BUT CLEARING ITSELF 11310' STARTING TO SEE SOME OVER PULLS Printed 2/18/2013 2:13:10PM �,,,, `' North America - ALASKA - BP ' O• eratIon Summary Report Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/17/2013 End Date: 2/2/2013 X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12.00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum. 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:40 - 08:20 0.67 DRILL P PROD1 11300' PUMP LOW FOLLOWED BYA HI -VIS PILLS 11100' OUT MM IS PLUGGED OFF, SWAP TO BYPASS LINE 10900' SLOW POOH SPEED TO CLEAN UP JUST BELOW THE WINDOW, THIS IS WHERE WE HAVE BEEN GETTING BIT STUCK ON WIPER TRIPS 10870' LOW VIS PILLAT THE BIT 10825' GETTING MOTOR WORKAND PULLING A LITTLE WT BIT STUCKAT 10820', WORK PIPE DOWN AND GOT FREE, RIH AND STACKING WT GOING DOWN THEN CLEARED UP AT 10850' CONTINUE DOWN TO 10900' INCREASE PUMP RATE AND PU TO WINDOW WITH REMAINING 10 BBLS OF HI -VIS PILL 08:20 - 09:30 1.17 DRILL P PROD1 WELL IS CLEAN TO THE BOTTOM OF THE WINDOW, RIH TO 10870' AND OPEN THE EDC. EDC OPEN, JET THE WS AND TUBING UP TO 9700' WATCHING FOR BOTTOMS UP WELL CONDITIONS ARE NOT IMPROVING WITH CHEMICALS OR MUD WEIGHT. CALL DRLG SUPT TO DISCUSS UPCOMING FUNCTION TEST AND WELL CONDITIONS AND HE IS COMING TO OUR LOCATION 09:30 - 10:15 0.75 DRILL N DPRB 12,257.0 PROD1 AFTER DISCUSSING OUR WELL CONDITIONS WITH THE DRLG SUPTAND GEO WE FEEL IT IS BEST TO SETANOTHER WS AND KICK OFF ATA HIGHER MD TO GETAWAY FROM THE KAVIK SHALE THAT IS JUST OUTSIDE THE WINDOWAND CONTINUES TO BE PROBLEMATIC. CALLED THE ODE AND DISCUSSED WHAT WE ARE SEEING AND HE AGREES AND IS MAKING CALLS FOR APPROVAL. WAIT ON ORDERS FROM TOWN CALL BTT TO PREP 4.5" WS PACKER BHA 10:15 - 10:40 0.42 DRILL N DPRB 12,257.0 PROD1 GOTAPPROVAL TO SETANOTHER WS RIH TO THE WINDOW WHILE PUMPING A20 BBL HI -VIS PILL 10:40 - 12:05 1.42 DRILL N DPRB 12,257.0 PROD1 POOH CHASING HI -VIS PILL TO SURFACE 12:05 - 12:20 0.25 DRILL N DPRB 12,257.0 PROD1 PJSM TO LD BHAAND JET STACK 12:20 - 12:40 0.33 DRILL N DPRB 12,257.0 PROD1 1400' OUT MM IS PLUGGING OFF, OPEN BYPASS 100' JOG IN HOLE TO 300' WELL IS CLEAN 12.40 - 12:50 0.17 DRILL N DPRB 12,257.0 PROD1 STOP AT 100' AND FLOW CHECK WELL 12:50 - 13:15 0.42 DRILL N DPRB 12,257.0 PROD1 GOOD NO FLOW CHECK, TAG UP 13:15 - 14:00 0.75 DRILL N DPRB 12,257.0 PROD1 BHA OOH, FILL HOLE BIT GRADE = 2 -3 CT MU NOZZLE TO JET TREE AND BOPE 14:00 - 14:15 0.25 DRILL N DPRB 12,257.0 PROD1 REMOVE INJECTOR AND NOZZLE BHA. PREP RIG FLOOR TO RUN WS BHA ***SEE OPEN WELLS REPORT RON, DRILL SIDETRACK B (2/2/2013) FOR THE CONTINUATION OF THE REPORTING *" Printed 2/18/2013 2:13:10PM + • • ter. Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/2/2013 End Date: X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Project: Y Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/2/2013 14:15 - 14:30 0.25 DRILL N DPRB 12,257.0 PROD1 HOLD PJSM TO MU THE WS BHA (BHA #6) 14:30 - 15:40 1.17 DRILL N DPRB 12,257.0 PROD1 MU THE WS BHA RIH WITH WS BHA 15:40 - 17:05 1.42 DRILL N DFAL 2,700.0 PROD1 LOST COMMS TO MWD, POOH HOLD PJSM TO LD BHAAND TROUBLE SHOOT ELINE 17:05 - 17:10 0.08 DRILL N DFAL 2,700.0 PROD1 FLOW CHECK WELL 17:10 - 17:30 0.33 DRILL N DFAL 2,700.0 PROD1 GOOD NO FLOW, TAG UP, REMOVE INJECTOR AND TEST THE UQC, UQC LOOKS OK, TEST UPPER SECTION OF MWD 17:30 - 19:30 2.00 DRILL N DFAL 2,700.0 PROD1 MWD - TOOLING APPEARS TO HAVE AN INTERMITTENT SHORT. REPLACE MWD TOOLSTRING ALL TESTS GOOD. 19:30 - 20:00 0.50 DRILL N DPRB 12,257.0 PROD1 MU BHA #7 COMPLETE WITH 4.5" KB PACKER WHIPSTOCKAND 10# J HYDRAULIC SETTING TOOL. ,'.. 20:00 - 20:30 0.50 DRILL N DPRB 12,257.0 PROD1 STAB ON INJECTOR. PRESSURE -TEST QTS TO 300PSI / 5 MINS AND 4,000PSI / 5 MINS. ACHIEVE GOOD TEST. 20:30 - 22:30 2.00 DRILL N DPRB 12,257.0 PROD1 COMMENCE RIH WITH BHA #7. MEANWHILE CONTINUE WORKING DIRECTIONAL PLAN. 22:30 - 23:20 0.83 DRILL N DPRB 12,257.0 PROD1 LOG FOR TIE -IN AND APPLY DEPTH CORRECTION OF -14'. 23:20 - 23:40 0.33 DRILL N DPRB 12,257.0 PROD1 CONTINUE RIH. 23:40 - 00:00 0.33 DRILL -- N DPRB 12,257.0 PROD1 PERFORM CCL -LOG FROM 10,350' - 10,600' AND PICK UP TO WHIPSTOCK SETTING DEPTH. 2/3/2013 00:00 - 00:20 0.33 DRILL N DPRB 12,257.0 PROD1 ANALYSE CCL -DATA WHILE PICKING UP TO WHIPSTOCK SETTING DEPTH: NOTICE 4.5" TUBING COLLAR AT 10,504'. IF THE WHIPSTOCK WAS SETAS PER OPERATIONAL CHANGE NOTE (OCN) WITH TOP OF WHIPSTOCK (TOWS) AT 10,495', THEN THE BOWS WOULD BEAT 10,510.7'. THIS WOULD PLACE THE PACKER - ELEMENT AT 10,506' - TOO CLOSE TO THE COLLAR. THUS DECIDE TO PLACE TOWS 10' HIGHER AT 10,485'. THAT WAY THE BOWS WILL BE AT 10,500.7'. THIS WILL GIVE 3.3' DISTANCE TO THE COLLAR. DISCUSS AND AGREE THIS CHANGE WITH ODE, GEO AND DD. 00:20 - 00:40 0.33 DRILL N DPRB 12,257.0 PROD1 PICKUP WHIPSTOCK TO PLACE TOWS - 10,485' AND BOW - 10,500.7'. ORIENT TRAY TO 340DEG TOOLFACE (I.E. 20DEG LOHS). BRING PUMPS ONLINE AND SHEAR WHIPSTOCK AT 2,800PSI. SLACK OFF 3K LBS COIELD TUBING WEIGHT TO CONFIRM THAT WHIPSTOCK IS PROPERLY SET. OBSERVE NO ISSUES. 00:40 - 02:45 2.08 DRILL N DPRB 12,257.0 PROD1 POOH WITH WHIPSTOCK RUNNING TOOL. 02:45 - 03:00 0.25 DRILL N DPRB 12,257.0 PROD1 PULL TO 200' AND FLOWCHECK WELL FOR 5 MINS. 03:00 - 03:30 0.50 DRILL N DPRB 12,257.0 PROD1 UNSTAB INJECTOR AND LD BHA #7. Printed 2/18/2013 2:21:01 PM Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/2/2013 End Date: X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date /me: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 03:50 0.33 DRILL N DPRB 12,257.0 PROD1 FUNCTION -TEST BOPE FROM DRILLER'S SIDE. ALL UPPER COMBI, VBRS, LOWER COMBI AND HCR FUNCTION & CLOSE WITHIN <5SEC. CHANGE -OUT PACK -OFFS ON INJECTOR. 03:50 - 04:40 0.83 DRILL N DPRB 12,257.0 PROD1 HOLD PJSM. CUT OFF CTC FOLLOWED BY 100' COIL FOR CHROME MANAGEMENT. CHANGED OUT PACK -OFF'S ON INJECTOR. 04:40 - 05:20 0.67 DRILL N DPRB 12,257.0 PROD1 MU COILED TUBING CONNECTOR AND PULL -TEST TO 38K LBS; ALL GOOD. BOOT E -LINE CABLE AND CLOSE SWAB VALVE. 05:20 - 05:50 0.50 DRILL N DPRB 12,257.0 PROD1 INSTALL 5FT- STINGER AND PRESSURE -TEST COILED TUBING CONNECTOR. 05:50 - 07:15 1.42 DRILL N DPRB 12,257.0 PROD1 HEAD UP BHI AND MEG ELINE CABLE. PT UQC 07:15 - 07:50 0.58 DRILL N SFAL_ 12,257.0 PROD1 STAB INJECTOR ON THE WELL, CIRC TO WARM COILAND ENSURE THE WELL IS FULL. CLOSE THE,SWAB TO PT THE PACK-OFFS, QTS AND BHI CHECK VALVES. GOOD LOW PT, HIGH NOT DOING SO WELL. LINE UP TO WARM COILAND RETEST 07:50 - 08:10 0.33 DRILL N SFAL 12,257.0 PROD1 RETEST PACK -OFFS, QTS AND BHI CV'S 08:10 - 08:45 0.58 DRILL N SFAL 12,257.0 PROD1 STILL NOTABLE TO GETA HIGH PT, BLEED OFF AND CIRC DOWN COIL TO TEST THE PACK -OFFS AND QTS, SUSPECT THE CVS ARE LEAKING. IF WE GET GOOD PACK OFF AND QTS TEST THEN PU THE INJECTOR AND TEST THE BHI CVS INDEPENDENTLY LOOKS LIKE EVERYTHING IS HOLDING, BLEED OFF CT PRESSURE TO FINISH HIGH PT ON CHECK VALVES PRESSURE ALMOST STABILIZED BUT WE NEED TO PUMP TO WARM THE COIL 08:45 - 09:00 0.25 DRILL N SFAL 12,257.0 PROD1 FOUNDASMALLLEAKATTHEFLANGE ABOVE THE SWAB. THE SPOTTER IN THE CELLAR NOTICED IT AFTER WALIKNG AROUND IN THE CELLAR. CALLED CTD SUPT AND DISCUSSED FINDING WITH HIM AND THE DRILLING HSE ADVISOR. WE ARE GOING TO CHECKALL FLANGE BOLTS AND PERFORM A FULL BODY TEST 09:00 - 09.50 0.83 DRILL N SFAL 12,257.0 PROD1 RETEST PACK -OFFS, QTS, BHI CVS AND FULL BODY TEST WE HAVE TRIED PUMPING FROM THE TEST PUMP AND COIL TO EQUALIZE THE PRESSURE AND WE ARE STILL NOTABLE TO GETA HIGH TEST BLEED OFF AND REMOVE INJECTOR FROM THE WELL TO TEST THE BHI CVS WITH THE TEST PUMP INSTALL THE NIGHT CAP AND TEST THE STACK 09:50 - 10:35 0.75 DRILL N SFAL 12,257.0 PROD1 PT THE BHI CVS, FAILED HIGH PT. R &R CHECK VALVES 10:35 - 11:05 0.50 DRILL N SFAL 12,257.0 PROD1 RETEST CHECK VALVES, FAILED, PULLAND INSTALL ANOTHER SET Printed 2/18/2013 2:21:01PM N orth America - ALASKA - BP % °f` /�� ° rte Operation Summary Report Common Wet Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/2/2013 End Date: X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:05 - 12:15 1.17 DRILL N SFAL 12,257.0 PROD1 PT THE BHI CVS AND THEY FAILED INSTALL NIGHT CAP AND TEST STACK WHILE BHI TROUBLESHOOTS THEIR CVS GOOD LOW & HIGH TEST ON STACK WO BHI TECHS TO FIGURE OUT THE SEAL ON THE FLAPPER VALVES 12:15 - 12:45 0.50 DRILL N SFAL 12,257.0 PROD1 INSTALL 5TH SET OF BHI CVS AND TEST 12:45 - 13:00 0.25 DRILL N DPRB 12,257.0 PROD1 BHI CV TEST PASSED, REMOVE TEST EQUIPMENT AND STAB INJECTOR ON THE WELL TO TEST THE PACK-OFF AND QTS 13:00 - 13:25 0.42 DRILL N DPRB 12,257.0 PROD1 , TEST PACK-OFF AND QTS 13:25 - 13:30 0.08 DRILL N DPRB 12,257.0 PROD1 GOOD PT, BLEED OFF AND CIRC TO WARM COIL LINE UP TO OPEN WELLAGAINSTA CLOSED CHOKE OPEN MASTER & SWAB VALVES 13:30 - 13:50 0.33 DRILL N DPRB 12,257.0 PROD1 NO PRESSURE ON WELL OPEN CHOKEAND PUMP TO ENSURE WELL IS FULL WELL IS FULL, SHUT DOWN TO MONITOR WELL FOR FLOW AND HOLD PJSM TO MU THE MILLING BHA GOOD NO FLOW 13:50 - 14:15 0.42 DRILL N DPRB 12,257.0 PROD1 REMOVE INJECTOR AND MU THE MILLING BHA 14:15 - 14:45 0.50 DRILL N DPRB 12,257.0 PROD1 PU THE INJECTOR AND MU TO THE BHA, PT THE QTS 14:45 - 16:20 1.58 DRILL N DPRB 12,257.0 PROD1 RIH WITH BHA #8 TO MILL THE WINDOW 16:20 - 16:40 0.33 DRILL N DPRB `1 2,257.0 PROD1 * * * * *KWTDRILL * * * ** CTS DRILLED CALLED OUT THAT HE IS SEENINGAN INCREASE IN OUT FLOW, } STOPPED RIH AND SHUT DOWN HIS PUMP. THE NORDIC DRILLER STRAPPED THE PITS AND CONFIRMED A 5 BBL GAIN IN THE PITS AND THE WELL WAS SIMULATED TO BE SHUT IN AS PER THE DRILLERS STANDING ORDERS AND MONITORED FOR PRESSURE. SIMULATED NOTIFICATIONS WERE MADE TO THE DRLG SUPT, NORDIC SUPT & TOOL PUSHER. THE DRILLER CALLED OUT AND SAID HE IS SHOWING 150 PSI WELLHEAD PRESSURE THAT HAS STABILIZED AND I MADE NOTIFICATION TO THE DRLG SUPT WHO THEN GOT PERMISSION FROM THE WTL FOR US TO OPEN UP TO THE WELLAND START TAKING RETURNS THROUGH THE MGS USING THE DRILLERS METHOD TO CIRCULATE OUT THE KICK. 16:40 - 18:25 1.75 DRILL N DPRB 12,257.0 PROD1 LOG LONG 200' TIE IN 18:25 - 18:45 0.33 DRILL N DPRB 12,257.0 PROD1 CORRECT DEPTH -14' AND RIH TO TAG PINCH POINT 18:45 - 19:00 0.25 DRILL N DPRB 12,257.0 PROD1 TAG UP AT 10,486'. PU AND SLOWLY RIH AT 1F/MIN. FREE SPIN - 2,800PSI. Printed 2/18/2013 2:21:01PM 7, North America - ALASKA F fl Operation Summary Repo Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/2/2013 End Date: X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 19:45 0.75 DRILL N DPRB 12,257.0 PROD1 S FIRST MOTORWORKAGAIN AT 10,486' - w i 1 35/6 STARTTIME- MILLING EE THE WINDOWAT �'C� 1 FT /MIN. 19:13HRS / 10,806.50' / MM -IN - 2.53 BPM / MM -OUT - 2.54 BPM / CIRC P - 2,981 PSI / DIFF P - 543PSI. 19:45 - 00:00 4.25 DRILL N DPRB 12,257.0 PROD1 HAVE MILLED 1ST FOOT. STOP TIME - MILLING AND SLOWLY "LEAN" ON MILL TO INCREASE WOB. 20:30HRS / 10,488.0' / MM -IN - 2.50 BPM / MM -OUT - 2.53 BPM / CIRC P - 2,996 PSI / DIFF P - 593 PSI / WOB - 2.35 K LBS 22:37 10,489.0' 2.49 2.50 2,950 614 2.63 00:00 10,489.6' 2.51 2.53 2,988 640 3.32 2/4/2013 00.00 - 01:30 1.50 DRILL N DPRB 12,257.0 PROD1 00:30HRS / 10,490.0' / MM -IN - 2.48 BPM / MM -OUT - 2.46 BPM / CIRC P - 2,944 PSI / DIFF P -640 PSI / WOB -3.17 K LBS 01:30 10,492.0' 2.53 2.50 2,970 632 3.11 01:30 - 03:45 2.25 DRILL N DPRB 12,257.0 PROD1 AFTER 6' OF MILLING GO BACK TO TIME - MILLING TO ENSUREA CLEAN WINDOW IS CUT W /OUT EARLY EXIT OR LEDGES. 02:00 10,492.4' 2.52 2.51 2,904 2.50 02:30 10,493.1' 2.51 2.52 2,900 581 3.30 03:00 10,493.9' 2.49 2.50 3,043 748 3.80 AT 10,494.1' NOTICE THAT WOB AND MOTORWORK DROP SLIGHTLY, INDICATING THAT THE MILL HAS POPPED OUT OF THE WINDOW. 03:30 10,494.3' 2.48 2.48 2,970 667 2.70 03:45 - 04:15 0.50 DRILL N DPRB 12,257.0 PROD1 FOLLOWING 10,494.5 SEE AN INCREASE IN WOBAND MOTORWORKAGAIN, INDICATING THAT THE STRING MILL IS PASSING THROUGH THE WINDOW. 03:00 10,494.6' 2.51 2.50 3,069 738 3.24 04:15 - 05:00 0.75 DRILL N DPRB 12,257.0 PROD1 TIME MILL TO 10,495.8'. 0500 10,494.8' 2.7 2.5 3,029 702 3.22 05:00 - 06:00 1.00 DRILL N DPRB 12,257.0 PROD1 STOP TIME - MILLING AND START DRILLING 20FT RATHOLE. 06:00 - 08:40 2.67 DRILL N DPRB 12,257.0 PROD1 CONTINUE DRILLING RAT HOLE FREE SPIN = 2800 PSI CIRC PSI = 3018 PSI IN RATE = 2.50 BPM OUT RATE = 2.48 BPM ROP = 6 FPH WOB = 5.09K Printed 2/18/2013 2:21:01 PM Common Well Name: 05 -35 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/2/2013 End Date: X3- 0133Y- C:DRILL (2,110,316.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NORDIC 1 Spud Date/Time: 6/1/1991 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UVVI: 500292217200 Active datum: 05 -35 @72.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:40 - 10:10 1.50 DRILL N DPRB 12,257.0 PROD1 CONTINUE DRILLING RAT HOLE FREE SPIN = 2800 PSI CIRC PSI = 3062 PSI IN RATE = 2.51 BPM OUT RATE = 2.49 BPM ROP = 4 FPH WOB = 4.6K PUMP 20 BBL HI VIS PILL 10:10 - 10:20 0.17 DRILL N DPRB 12,257.0 PROD1 PILLATTHE MILL PU THROUGH WINDOW 10:20 - 11:00 0.67 DRILL N DPRB 12,257.0 PROD1 - PILL IS GONE, RIH TO FINISH RAT HOLE 11.00 - 12:40 1.67 DRILL N DPRB 12,257.0 PROD1 RAT HOLE DRILLED, PU TO DRESS WINDOW HI -VIS PILL DID NOT BRING UP ANY MORE THAN NORMAL CUTTING OR METAL FREE SPIN = 2670 PSI PASS COMING UP IN THE OH HAD A300PSI INCREASE IN MOTOR WORK BUT THE VNNDOW WAS CLEAN PASS GOING DOWN IS CLEAN PASS COMING UP HAD A LITTLE WORK, MAKE ANOTHER PASS DOWN AND UP WINDOW LOOKS CLEAN, DRY DRIFT IN BOTH DIRECTIONS, WINDOW IS CLEAN. PUH TO FLOW CHECK THE WELL 12:40 - 12:50 0.17 DRILL N DPRB 12,257.0 PROD1 FLOW CHECK WELL 12:50 - 14:00 1.17 DRILL N DPRB 12,257.0 PROD1 .GOOD NO FLOW, POOH FOR DRILLING BHA PVT = 301 BBLS 14:00 - 14:35 0.58 DRILL N DPRB 12,257.0 PROD1 PJSM TO LD & MU BHA'S 14:35 - 14:45 0.17 DRILL N DPRB 12,257.0 PROD1 JOG IN HOLE 200' THEN FLOW CHWCK WELL BEFOPRE TAG UP 14:45 - 14:50 0.08 DRILL N DPRB 12,257.0 PROD1 FLOW CHECK WELL 14:50 - 15:00 0.17 DRILL N DPRB 12,257.0 PROD1 GOOD NO FLOW CHECK, TAG UP AND REMOVE INJECTOR 15:00 - 15:20 0.33 DRILL N DPRB 12,257.0 PROD1 PULL BHA MWD COULD NOT BE BLOWN DOWN, MOTOR IS TO TIGHT, STBK MWD AND LD PH6 AND MOTOR 15:20 - 15:30 0.17 DRILL N DPRB 12,257.0 PROD1 BHA PULLED, WINDOW MILL GAUGED 3.80 GO 3.79 NO GO, COULD NOT GET THE GAUGE ON THE STRING MILL. BTT HAND VNLL BREAK THE MILLS OFF THE MOTOR AT THE SHOP AND GAUGE THE STRING MILL RERUN MWD AND BLOW DOWN 15.30 - 16:00 0.50 DRILL N DPRB 12,257.0 PROD1 MU DRILLING BHA 16:00 - 16:25 0.42 DRILL N DPRB 12,257.0 PROD1 STAB INJECTOR ON VVELLAND PT THE QTS. RIH 16:25 - 18:15 1.83 DRILL N DPRB 12,257.0 PROD1 TIE IN. APPLY -15.5' DEPTH CORRECTION. 18:15 - 19:15 1.00 DRILL N DPRB 12,257.0 PROD1 CONTINUE RIH JUST BEFORE TAGGING BOTTOM, TAKE SLOW PUMP RATES. PUMP #1: PUMP #2: 3.07 BPM - 3,100 PSI - 129 SPM 3.7 BPM - 3,075 PSI - 127 SPM 1.53 BPM - 1,830 PSI - 64 SPM 1.54 BPM - 1,950 PSI - 64 SPM 0.5 BPM - 1,290 PSI - 21 SPM 0.52 BPM - 1,385 PSI - 22 SPM Printed 2/18/2013 2:21:01PM 9 TREE= `M" • ' a 05-35A LHEAD= FMC SAFETY NOTES: WELL ANGLE> 70° @ 10511 "" ACTUATOR = BAKER C 4 -112" CHROME TBG'""' ORIG WELL NOT SHOWN KB. ELEV = 72' LI BELOW WHIPSTOCK © 3861' """ BF. ELEV = V KOP = 2800 Angle = 95° @ 11029' Datum MD = 10429' Datum TVD = 8800' SS 1 2204' - 4 - 1/2" HES X NP, D = 3.813" 4-1/2" TBG, 13.5#, 13CR-80 VAM TO H 72' .0150 bpf, ID = 3.920" 120" CONDUCTOR, 94.5#, H-40, D = 19.124" H 110' GAS LF1' MANDRELS 9-5/8" W- PSTOCK (08/29/08) 1-1 3861' ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3775 3690 35 KGB2 DMY BK 0 12/30/12 195/8" CSG, 36#, J-55 ETC, ID= 8.921" 1- - 3875 - 1 6401 5739 42 KGB2 DMY BK 0 12/30/12 Minimum ID = 3.80" @ 9508' MLLOUTVMNDOW(05 -35A) 3861'- 3875' I 4 HES XN NIPPLE (MILLED 02/20/11) Illi 9371' I - 4-1/2" F ES X NP, D = 3.813" 1 li 9402' - 17" X 4-1/2" BKR S-3 A<R, 13= 3.870" 1 1 9435' - 4-1/2" I-ES X N? D = 3.813" 7" CSG, 26#, L -80 Tq XO L -80 BTC-M -1 4212' 1 ( 9508' -14 -1/2" I-ES XNl NP, MILLED TO 3.80" (02/20/11) 1 NOTE POSSBLEDANAGE TO LNR TOP / WLEG 9510' 1 - 7" X 5" I-Ft ZXP LTP w /TEBACK SLY, ID = 4.460" POST CTD M. (07 /2011) 4-1/2" TBG, 12.6#, 13CR - VAM TOP, H 9520' likl 1 9520' 1 - 4-1/2" VVLEG, D= 3.958" 1 .0152 bpf, ID = 3.95$" 95 • HIT X 5" BKR MAC LNR HGR, D = 4.450" �1 9542' H5" X 4-1/2" XO, ID= 3.930" 17" CSG, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" H 9676' , MLLOUf VVrDOW (05- 35AL1) 11222' - 11234' 1 VVhPSTOCK (02/03/13) 10485' ' FLO THRU' M-PSTOCK (01/29/13) 1 10800' kits, 11250' 1- 13.70" DEPLOY SLV, 13= 2.950" 1 PERFORATION SUMMARY Ilk,. 11251' - 13 -1/2" X 2 -7/8" XO, D = 2.370 F2IEF LOG: ANGLE AT TOP FERE WA - N. Note: Refer to Production DB for historical pert data . SIZE SPF INTERVAL Opn/Sgz DATE I 05-35A -- 2 -7/8" 6 11290 - 11430 0 09/12/08 2 -7/8" 6 11630 - 11890 0 09/12/08 N. , • ` L 2 -7/8" 6 11990 - 12910 0 09/12/08 I .. 05 -35AL1 •i�i F'BTD H 13170' -.. illb 2 -7/8" SLID 11252 - 13169 SLOT 07/13/11 ••• •�9 2 -7/8" LNR, 6.16#, L -80 STL, .0.58 bpf, D = 2.441" -1 13190' PBTD - I 12911' 4-1/2" LM , 12.6#, L -80 BT - .0152 bpf, D = 3.958" H 12999' 1 V HOLE 5 • DATE REV BY CONVENTS DATE REV BY COMMBVTS F'RUDFIOE BAY UNT 07/19/91 D9/ N2ES IMTIAL COMPLETION 08/12/11 AK/PJC FNAL DRLG CORRECTIONS WELL: 05-35A / L1 09/14/08 ME5 SIDETRACK (05 -35A) 11/19/12 RCT /JM) GLV CJO (11!16/12) PERMT No: 2081340 / 2110080 07/18/11 NORDIC 2 CTD M IDTI -LAT (05- 35AL1) 01/16/13 DLW /JM) GLV GO (12/30/12) AR Nu: 50.029 22172 -0, (60) 07/26/11 PJC DRLG DRAFT CORRECTIONS SEC 32, T11 N, R15E, 2323 FNL & 124' FWL 08/08/11 RCP/ PJC GLV C!O (07/29/11) BP Exploration (Alaska) OF r • • • y w \ ����� j ,�s� THE STATE Alaska Oil and Gas a �, of Conservation Commission Witt ALASI�:A _ GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ALAS� Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 ( 1 . 0 John McMullen N pR Engineering Team Leader SC BP Exploration (Alaska), Inc. an - P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05 -35A Sundry Number: 313 -055 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this day of February, 2013. Encl. , STATE OF ALASKA ~�, R E C V G D Z zs l3 p, ALAS OIL AND GAS CONSERVATION COMMI ION i FEB 2013 -S 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. ❑ Exploratory ❑ Stratigraphic 208 - 134 • 3. Address: El Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029 22172 - 01 - 00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 05 -35A Will planned perforations require a Spacing Exception? ❑ Yes N o 9. Property Designatior 10. Field / Pool(s): ADL 028326 • 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) 13000' - 8894' • 12911' 8898' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 3861' 9 -5/8" 3861' 3760' 3520 2020 Intermediate 9676' 7" 9676' 8335' 7240 5410 Production Liner 3489' 4 - 1/2" 9510' - 12999' 8203' - 8894' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11290' - 12910' 8938' - 8898' 4 - 1/2 ", 12.6# 13Cr80 9520' Packers and SSSV Type: 7" x 4 Baker S - Packer Packers and SSSV 9402' / 8118' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: CI Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation February 4, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date 2/4/2013 ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned • Commission Representative: Guy Schwartz ❑WAG ❑ SPLUG ®Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Johnston, 564 -5985 r--- Printed Name: John M ulle Title: Engineering Team Leader mail: David.Johnston2 aGbp.com Signature: Phone: 564-4711 Date: Lf ? Commission Use Only l / Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k--os ❑ Plug Integrity ®B Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: ' a -OMS FEB 26 nu 1 Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: / — 4 II t / APPROVED BY 25 - Approved By: ,,� COMMISSIONER THE COMMISSION Date: Z Forn{1� �d� rci � 1 Submit In DuplicV 'K` Approved application is valid for 12 months from th date of a a L v f' �1 ?zI 13 ,19 / 1-.1. , • • • To: Alaska Oil & Gas Conservation Commission bp From: David E Johnston o Jo CTD Engineer Date: February 4, 2013 Re: 05 -35A and 05 -35AL1 Sundry Approval The Nordic rig 1 was executing approved drilling program and permit to drill for 05 -35AL2 when wellbore stability problems at the window forced a decision to plug back and start over. Sundry approval to abandon the 05 -35A and 05 -35AL1 laterals is requested. 05 -35A was completed in September 2008. The A bore came on at marginal rates with minimal WC, and minimal gas. The well stayed around these production values until July -2011 when a slotted liner lateral was added to the 05 -35A in an attempt to make it a more economical well to produce. The well had a few flush tests then settled out right back at the prior rates of 05 -35A. the L1 lateral was drilled in very low net to gross sand, and the production trends agree with this. The rig will set a 45 KB Packer whipstock at 10,485' MD and drill a new B lateral. Final P&A of the 05 -35A, 05 -35AL1 and 05 -35AL2 PB1 will be completed with the primary liner cement of • 05 -35B. A MIT of the liner lap will be completed to 2,400 psi. If the liner lap test fails we will set and test a 45 KB liner top packer post rig and MIT to 2,400 psi. Rig Work: (Began on January 26, 2013) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Bull head kill the well with 1% 8.4 ppg KCI. 3. Set 4 - %" TT flow through packer whipstock at —10,800' MD. (Below the new gas contact point). - --- -• 4. Mill 3.80" window at 10,485' and 20' of rat hole. 6. Drill Build /Lateral: 4.25" OH, 2,750' (12 deg /100 planned) with resistivity to a TD of 13,235'. 7. Run 3 -1/2" X 3 -1/4" X 2 -7/8" L -80 Cemented liner leaving TOL at —10,285' MD. 8. Pump primary cement leaving TOC at 10,285' MD, 31 bbls of 15.8 ppg liner cmt planned. 9. Perform liner cleanout with mill, motor and MCNL /GR /CCL log. 10. Test liner lap to 2,400 psi. 11. Perforate liner per asset instructions (-1,000'). 12. Freeze protect well to 2500' TVD 13. Set BPV, RDMO. Post - Rig Work: 1. Re- install wellhouse, flow line and pull BPV 2. Set liner top packer if needed with slickline & test to 2,400 psi 3. Set Gas lift valves 4. Test separator. David E. Johnston CTD Engineer 564 -5985 CC: Well File Joe Lastufka TREE= CMJ . WELLHEAD= FMC 05-35B omrrfilioa Ica. VV L.L rVRlLC - I U kcu IWOII ACTUATOR = BAKER C 4 - 1/2" CHROME TBG *"` ORIG WELL NOT SHOWN KB. ELEV = 72' 111:1 (1W WHIPCTIIrK i B RRAI' *-- Proposed Cemented CTD sidetrack BE ELEV = I I KOP= 2800' r ,-, Max Angle = 95° @ 11029' Datum MD = 10429' Datum TVD = 8800' SS ' 2204' F— 4 -1/2" HES X NP, ID = 3.813" 20" CONDUCTOR, 94.5#, H-40, ID = 19.124" 110' 4 -1/2" TBG, 13.5#, 13CR -80 VAMTOP, H 72' .0150 bpf, D = 3.920" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 -5/8" WHIPSTOCK (08/29/08) H 3861' 2 3775 3690 35 KGB2 DOME BK 16 07/29/11 9 -5/8" CSG, 36#, J -55 BTC, D = 8.921" H —3875 \ 1 6401 5739 42 KGB2 SO BK 20 07/29/11 MILLOUT WINDOW (05 -35A) 3861' - 3875' 7" CSG, 26#, L -80 TCII XO L -80 BTC-M H 4212' PERFORATION SUMMARY REF LOG: Minimum ID = 3.80" @ 9508' ANGLE AT TOP PERF: N/A 4 -1/2" HES XN NIPPLE (MILLED 02/20/11) Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 9371' }- 4 -1/2" HES X NP, D = 3.813" 05-35A 2 -7/8" 6 11290 - 11430 0 09/12/08 2 -7/8" 6 11630 - 11890 0 09/12/08 2 -7/8" 6 11990 - 12910 0 09/12/08 X 9402' — 7" X 4 -1/2" BKR S -3 PKR, D = 3.870" I 05 -35AL1 9435' F— 4 -1/2" HES X NP, D = 3.813" 2 -7/8" SLID 11252 - 13169 SLOT 07/13/11 r 9508' F— 4 -1/2" HES XN NP, MILLED TO 3.80" (02/20/11) N O T E P O S S I B L E D A M A G E T O L N R TOP / W L E G POST CTD ML (0 7/ 2 0 1 1 ) 9510' H 7" X 5" HR ZXP LW w /TIEBACK SLV, D=4.460" 4 -1/2" TBG, 12.6#, 13CR -80 VAM TOP, — 9520' l 9520' — I4 - 1/2" WLEG, D = 3.958" .0152 bpf, D = 3.958" 1 9533' F — 7" X 5" BKR HMC LNR HGR, ID = 4.450" 9542' I— 5" X 4-1/2" XO, D = 3.930" 7" CSG, 26#, L -80 BTC-M, .0383 bpf, D = 6.276" —{ 9676' ■ 10,285' - Top of 3 -1/2" liner and Top of cement 10,485' - Top of 4-1/2" KB Packer whipstock , i • % 4 -1/4" open hole TD at 13,235 MD' 0 '✓ /10,800' Top of 4 -1/2" whipstock 2-7/8" solid liner at 13,235 MD'._ 11250' 3.70" DEPLOY SLV, ID = 2.950" 11251' J- 3-1/2" X 2 -7/8" XO, ID = 2.370 V ' 1 \ - F LOUT WINDOW (06- 36AL1) 11222' - 11234' I - 05 -35 AL2 PB1 I _ ••W • • •• • 11 FBTD H 13170' PBTD 12911' •■•,•, 4 -1/2" LNR, 12.6#, L -80 IBT -M, .0152 bpf, ID = 3.958" — I 12999' [2 -7/8" LNR, 6.16#, L -80 Sm, .0.58 bpf, D = 2.441" —I 13190' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/19/91 ORIGINAL COMPLETION 08/12/11 AK/PJC FINAL DRLG CORRECTIONS WELL: 05-35A / L1 09/14/08 N7ES ORIGINAL COMPLETION PERMIT No: 2081340 / 2110080 07/18/11 NORDIC 2 CTD MULTI -LAT (05- 35AL1) API No: 50- 029 - 22172 -0, (60) 07/26/11 PJC DRLG DRAFT CORRECTIONS SEC 32, T11 N, R15E, 2323 FNL & 124' FWL 08/08/11 RCT/ PJC GLV GO (07/29/11) BP Exploration (Alaska) TREE= aW • VVELLHEAD= 05 -35A S A T : W E L L ANGLE >70° @10511"' ACTLWTOR = BAKER - 6 41/2 CHROME TBG OM WELL NOT SHOWN KB. El V = 72' L 1 BELOW WHIPSTOCK + 3861' "*" BF.ELEV= I � KOP = 2800' Max Angle = 95° @ 11029' Datum MD = 10429' Datum TV 8800' SS 2204' — 14 -1/2" H X NP, D = 3.813" 41/2" TBG, 13.5#, 13CR -80 VAM TOP, —1 72' .0150 bpf, ID = 3.920' 120" CONDUCTOR, 94.5#, H-40, D= 19.124" H 110' GAS LIT MADIJF2H S 9-5/8" WHIPSTOCK (08/29/08) H 3861' ST M7 ND DB/ _ TYPE VLV LATCH FORT DATE 1 9-518" CSG, 36#, J-55 BTC, ID= 8.921" H - 3875 r- M 2 3775 3690 35 KGB2 DOE BK 16 11/16/12 1 6401 5739 42 KGB2 SO _ BK 20 11/16/12 Minimum ID = 3.80" 9508 MLLOUT VODOW (45 - 35A) 3861' - 3875' I 4 HES XN NIPPLE (MILLED 02/20111) WI 9371' 1-- 41/2" HES X NP, D = 3.813" 9402' — X 4-1/2" BKR S-3 R<R, D = 3.870" II 9435' — 141/2" HES X NP, L)=3.813' 17" CSG, 26#, L-80 TC/ XO L -80 BTC-M 1-1 4217 I 9J08• H 41/2" HES XN NP, MILLED TO 3.80" (02/20/11) NOTE POSSIBLE DAMAGE TO !..NR TOP WLEG 9510' 7" X 5" FR ZXP LTP w TIEBACK SLV, D = 4.460" POST CiD Rt 197'2011 ` 4-1/2" 113G, 12.6#, 13C14-80 VAM TOP, —1 9520' I l 1 9520' H41/2" WLEG, D= 3.958" 1 .01 52 bpf, D = 3.958" 9533• HT" X 5" BKR HMC LNR HGR, D = 4.450" I 9542' 1— 5" X 41/2" XO, D = 3.930" 1 1 7" CSG, 26#, L -80 BTC-M .0383 bpf, D = 6.276" H 9676' Ha MLLOUT WINDOW (05-35A L1) 11272' -11234' PERFORATION SLMIAARY REF LOG: 11250' H 3.70" DEPLOY SLV, D = 2.950" ANGLE AT TOP PEW: NA Note: Refer to !Production DB for historical pert data 11251 • 1-13 112" X 2 -7/8" XO, D= 2.370 SCE SPF IN DAT INTERVAL Opn/Sqz E -. 05-35A N. , 2 -7/8° 6 11290 - 11430 0 09/12108 I \ 2 -7/8" 6 11630 - 11890 0 09/12/08 -. " - \ 2 -7/8" 6 11990 - 12910 0 09/12/08 I 05 -35AL1 \ - 2 -7/8" SLID 11252 - 13169 SLOT 07/13/11 I " " ❖:•: 1 P BTD (— 13 170' 1 -: \ ■ 4 PBTD — 12911' � 141/2" LNR, 12.6#, L -80 BT -M .0152 bpf, D = 3.958" H 12999' 12 -7/8" LNR, 6.16#, L -80 STL, .0.58 bpf, D = 2.441" 1 13190' 'OPEN HOLE TD 1-1 11386' DATE REV BY COMu43•1TS DATE REV BY COM ENTS PRUDHOE BAY UNIT 06/19/91 ORIGINAL COMPLETION 08/12/11 AK/PJC FTIAL DRLG CORRECTIONS WELL: 05-35A / L1 09/14/08 N7ES ORIGINAL COMPLETION 11/19/12 RCT /JM3 GLV C/O (11/16/12) FERMf No: 2081340 / 2110080 07/18/11 NORDIC 2 CTD MULTI -LAT (05- 35AL1) API No: 50- 029 - 22172 -0, (60) 07/26/11 PJC DRLG DRAFT CORRECTIONS SEC 32, T11 N, R15E, 2323 FM_ & 124' FWL 08/08/11 RCT/ PJC GLV C/O (07/29/11) BP Exploration (Alaska) • NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM V12 19551 II iiiiir V14 7 -1/18" 5000 psi BOP, ID • 7.08" AIM V15 V11 ' 171/16 Psi, Rx-se Transducers 0 1 Ili d V 2 1 V1 V 16 —WO d.— Note typical Bop silliik in B ement for 234 coletl tub'ng tlri lling tONW 71118" 8550 psi, RXde 1 11 V17 HCR IC ; / IK OK C lc To Poor Bov Gas Buster } ......,4 �� V18 V19 '!!'rf`. II 'Xi 2 1118" 6000 psi. RX-24 • I 3.00 .. 6000 psi NCR ` ', .a. inempir 4 • �� 2 J/6V trz ■�. 5000 CHECK VALVE I Manual Choke _ re . �,,, wwsw .. .1 2 i ar a 11 N - IOU .7riiiT. .. 7 1 /18 Cameron FGV Gate I - Valve x 5000 psi t Ma . MEOH /Di , . 4 FP Line CoFlex Hose ,-. U .... 1/4 Tum Hako 10WOG To Production Tree or Cross Over • 4 !'� CoFlex Hose T - re:: e transducers - 0/11 41 lo l i• CV12 To Coiled Tuning '' —�.—� — . -- — Bleed Off _ Inner Reel Valve I -1 CV3 CV2 CV13 Cement Line In [k Ground Level Tie -in CV10 T Stand Pipe • Manual Choke T•_ Mr ... : -.. -aw Pressure Transducers n 1 cvn 1 1 1 Tiger Tank Mud Pump 2 s I II ■ O — -- _ In From • � Baker MP 1 d MP 2 Nor '#w ■ I. • . — ` . Choke •- -- • CV14 — to Pits Rig Floor Mud Pump #1 4 CVI6 Reverse Ci -:'. • Cur CT while OOH 111 • • To Manifold CV15 1Jun -2010 e 4 Revers rie.•.d.. ate ling. i r while. nnH T wh 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_ DocumentRecord \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 ce Cn DATE: 30- Jan -13 \ \ Stephanie Pacillo TRANS#: 6273 Data Manager )NIakana K B ender Scblumberger Oilfield Services -", -- Natural Resources Technician II WIRELINE 1:u'as&a Oil & Gas ConserVatIonc Commission 2525 Gambell St, Ste. 400 _ Anchorage, AK 99503 � � °3 r`. : V?:ia� i :;:;C.17:`.I ::;c �.; , r G - Office: (907) 273-1770 ICE .OH: RESERV CNL ME CH ,,:. �,� LOG DESCRIPTION DATE, CH , ry V I�EL I . . SERV BAN ,, COLOR , , - CDs NAME pool :.# DIST Dig ;' ; DIS T :` , ; - LOGGED PRINTS PRINTS • A -28 C4W7 -00011 X RST BORAX 5- May -12 1 1 CD N -12 C2EW -00023 X RST 20- Jul -12 1 1 CD C -21 C49E -00012 X RST BORAX 22- Aug -12 1 1 CD 06 -03A BG4H -00128 X RST 9- Aug -12 1 1 CD M -15 C2EW -00026 X RST 26- Jul -12 1 1 CD C -28B BYS4 -00049 X RST 3- Aug -12 1 1 CD H -02B C4W7 -00035 X RST BORAX 25- Aug -12 1 1 CD C -22A C3NA -00024 X RST 5- Jul -12 1 1 CD N -22B C1 UB -00026 X RST 30- Aug -12 1 1 CD L2 -25 C1UB -00027 X RST 2- Sep -12 1 1 CD K -07E BBSK -00120 X RST 27- May -12 1 1 CD 06 -24A BZ81 -00032 X RST 14- Aug -12 1 1 CD J -28 C3NA -00026 X RST 8- Jul -12 1 1 CD 05 -35A BR12 -00008 X MCNL 3- Jul -11 1 1 CD 01 -17C BJJ8 -00138 X (FLEX 17-Jan -13 1 1 CD • Z -61 C2JC -00078 X CBL -MSIP 23-Jan -13 1 1 CD SCANNED JUL 1 0 2013 X ll — .," Please return a signed copy to: Please return a signed co .y to: BP PDC LR2 -1 900E Benson Blvd Wireline 2525 Gambell St, Suite 400 Anchorage AK 99508 Anchorage AK 99503 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue AUU 2U Anchorage, Alaska 99501 O — 3 f4 Subject: Corrosion Inhibitor Treatments of GPB DS -05 O 5 --3 sA Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 05 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, off.. Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-05 Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 05 -01C 1990280 50029201360000 Sealed conductor NA NA N/A N/A NA 05 -02A 2012410 50029201440100 Sealed conductor NA NA N/A N/A NA 05 -03C 2000940 50029201470300 Sealed conductor NA NA N/A N/A NA 05 -04A 1960890 50029201520100 Sealed conductor NA NA N/A N/A NA 05 -05B 1961800 50029201700200 Sealed conductor NA NA N/A N/A NA 05 -06A 1950840 50029201730100 0 NA 0 N/A N/A NA 05 -07 1770130 50029202430000 Sealed conductor NA NA N/A N/A NA 05 -08A 2100550 50029202480100 Sealed conductor NA NA N/A N/A NA 05 -09A 1990140 50029202540100 Sealed conductor NA NA N/A N/A NA 05 -10C 2070980 50029202630300 Sealed conductor NA NA N/A N/A NA 05 -11A 1960970 50029202520100 Sealed conductor NA NA N/A N/A NA 05 -12B 2011800 50029202440200 Sealed conductor NA NA N/A N/A NA 05 -13B 2071460 50029202500200 Sealed conductor NA NA N/A N/A NA 05 -14A 1930820 50029202530100 Sealed conductor NA NA N/A _ N/A NA 05 -158 1960230 50029202550200 Sealed conductor NA NA N/A N/A NA 05 -16B 1991000 50029202620200 Sealed conductor NA NA N/A N/A NA 05 -17B 1981040 50029202710200 Sealed conductor NA NA N/A N/A NA 05 -18A 1981740 50029219600100 , Split conductor NA NA N/A N/A N/A 05 -19 1890780 50029219620000 1.4 NA 1.4 N/A 8.5 4/11/2011 05 -20B 2042340 50029221370200 1.2 NA 1.2 N/A 5.1 4/18/2011 05 -21A 1981180 50029219690100 Dust Cover NA NA N/A N/A N/A 05 -22B 2071260 50029219760200 3.1 NA 3.1 N/A 18.7 4/17/2011 05 -238 2080610 50029219630200 1.2 NA 1.2 N/A 5.1 4/11/2011 05 -24A 2042180 50029222040100 1.5 NA 1.5 N/A 10.2 4/11/2011 05 -25C 2091240 50029219880300 6.0 NA _ 6.0 N/A 44.2 4/18/2011 05 -26A 2012210 50029219840100 0.5 NA 0.5 N/A 3.4 4/12/2011 05 -278 2081910 50029219790200 Sealed conductor NA NA N/A N/A N/A 05 -28B 2060890 50029222080200 0.6 NA 0.6 N/A 1.7 4/10/2011 05 -30 1911150 50029222130000 1.2 NA 1.2 N/A 10.2 4/11/2011 05-31B 2100850 50029221590200 1.3 NA 1.3 N/A 6.8 4/12/2011 05 -32A 2020010 50029221900100 20.0 6.0 0.5 7/13/2011 3.4 7/23/2011 05 -33B 2100810 50029221680200 4.8 NA 4.8 N/A 37.4 4/27/2011 05 -34A 2080370 50029222170100 3.9 NA 3.9 N/A 18.7 1/4/2012 ../ 05 -35A 2081340 50029221720100 2.7 NA 2.7 N/A 18.7 4/18/2011 05 -36A 2050700 50029221820100 2.3 NA 2.3 N/A 13.6 4/12/2011 05 -38 1961850 50029227220000 1.8 NA 1.8 N/A 15.3 4/10/2011 05 -39 1961730 50029227150000 1.3 NA 1.3 N/A 10.2 4/10/2011 05-40 1961590 50029227070000 1.6 N/A 1.6 N/A 16.2 1/10/2012 05-41A 2031700 50029226960100 5.0 NA 5.0 N/A 58.7 1/8/2012 DATA SUBMITTAL COMPLIANCE REPORT 313/2010 Permit to Drill 2081340 Well Name/No. PRUDHOE BAY UNIT OS-35A Operator BP EXPLORATION (ALASF(A) INC MD 13000 TVD 8894 Completion Date 9/14/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-22172-01-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directionai Survey Yes DATAINFORMATgN Types Electric or Other Logs Run: dir / gr 1 res / pwd, dir / gr /res /den / Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH_ Received Comments r D,. D Asc Directional Survey 0 13000 Open 9/25/2008 pt Directional Survey 0 13000 Open 9/25/2008 og Sonic 5 Col 65 9491 Case 11/7/2008 USIT w/CBL and SPIT, DSLT, GR, CCL 11-Sep- 2008 Cy.~~cZ C Pds 17083 ~ic 65 9491 Case 11/7/2008 USIT w/CBL and SPIT, ~ DSLT, GR, CCL 11-Sep- 2008 C Las 17274 Induction/Resistivity 9607 13000 Open DRHO, RPM, GF2, RPD, RPS, RPX, FIELD DATA D C Lis 18231 Gamma Ray 48 4578 Case 7/6/2009 LIS Veri, GR, CCL C Lis 18238 Induction/Resistivity 3820 12994 Open 7/6/2009 LIS Veri, GR, ROP, FET, RPX< RPS, RPM, RPD, DRHO, NPHI, TRPM g Induction/Resistivity i /R i ti it I d 25 Blu 25 Blu 3854 3854 13000 13000 Open Open 7/6/2009 7/6/2009 MD Vision Service ~ TVD Vision Service on es s v y n uct Nell Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments si DATA SUBMITTAL COMPLIANCE REPORT 3/3/2010 Permit to Drill 2081340 Well NameiNo. PRUDHOE BAY UNIT 05-35A MD 13000 TVD 8894 ADDITIONAL INFORMATION Well Cored? Yi"~ Chips Received? Y~~ Analysis ~/„y_. Received? Completion Date 9/14/2008 Operator BP EXPLORATION (ALASKIy INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? ("~/ N Formation Tops ,~" N API No. 50-029-22172-01-00 UIC N Comments: Compliance Reviewed By: Date: 06/26/09 NO. 5289 Alaska Data F~ Consulting Services Company: State of Alaska 2525 Gambell :itreet, Suite 400 ' Alaska Oil & Gas Cons Comm Anchorage, AI<; 99503-2838 Attn: Christine MahnkE+n ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD i• i• A-44 09AKA0048 OH MWD/LWD EDIT °t' ~°~ 04/26/09 2 1 4-04A/T-30 09AKA0040 OH MWD/LWD EDIT 03/28/09 2 1 18-01A 62WY-00003 MCNL 04/30/09 1 1 15-298 09AKA0143 OH MWD/LWD EDIT - 05/30/09 2 1 05-35A 40017778 OH MWDlLWD EDIT ~U$ °- 09/10/08 2 1 V-115L2 11962618 OH WIRELINE 08/22/08 1 1 MPS-41 11966289 OH WIRELINE ~-l~j /'"~a~ 11/19!08 6 1 G-01A BOOR-00006 MCNL ~ ~'~ _ ~ ~ ~- 04/01/09 1 1 _ 4-04A/T-30 BOCV-00014 ~ CH EDI r rv~.~-GR (SCMT) (REVISE DATA) ~ /27/09 1 05-35A AWJI-00008 CH EDIT PDCL-GR (MEM CORRELATION) ~ 12/03/08 1 07-148 AYOQ-00029 CH EDIT PDCL-GR (LDL) - [. 05/26/09 1 L3-08 AWL9-00028 RST / 06/11/09 1 i n.c~ "~~ •---••••~•..-~.+u~-..~~~.. . v, •a.wvnv~a new n~~ Vn1Y 11Y1] VrvG liVri CNl.ll 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~a ff 06/26/09 a~~'~1~~~~~~ N0. 5289 Alaska Data F: Consulting Services Company: State of Alaska ?525 Gambell Street, Suite 400 A-aska Oil & Gas Cons Comm Anchorage, AK; 99503-2838 Attn: Christine Mahnke+n ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD • A-44 09AKA0048 OH MWD/LWD EDIT "~' --~ 04/26!09 2 1 4-04A/T-30 09AKA0040 OH MWD/LWD EDIT 03/28/09 2 1 18-O1A 62WY-00003 MCNL 04/30/09 1 1 15-296 09AKA0143 OH MWD/LWD EDIT 05/30/09 2 1 05-35A 40017778 OH MWD/LWD EDIT ~UFS °- ~ 09/10/08 2 1 V-115L2 11982618 OH WIRELINE 08/22/08 1 1 MPS-41 11966289 OH WIRELINE ~-L~ /~a~ 11/19/08 6 1 G-O1A BOOR-00008 - ~ MCNL ~~ ~ _ 0 ~ 04/01/09 1 1 4-04A/T-30 BOCV-00014 _ ~ _ CH EDI i rv~.~-GR (SCMT) (REVISE DATA) - ~ !27/09 1 05-35A AWJI-00008 CH EDIT PDCL-GR (MEM CORRELATION) e- ~ 12/03!08 1 07-148 AYOO-00029 CH EDIT PDCL-GR (LDL) (~ 05/28!09 1 L3-08 AWL9-00028 RST / 06/11/09 1 1 BP Exploration (Alaska) Inc. ~v~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. v , v~~a~.n •~a ~~~u nc ~ vn1Y11Y~a VIYC V Vr i CNlil"1 1 V: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 10/15/08 ~~ ~.~ dC~~~m~~~~~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Joh # 1 nn naerrinfinn N0.4931 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnkeni 333 West 7th Ave, Suite 100 Anchorage, AK 99501 rlnfn RI f`nlnr t`n I~ 07-30B 12005233 SCMT ~ (~ ~ 09/22/08 1 1 W-31 12031513 USIT ~ ls~{ 09/18/08 1 1 05-35A 11975794 USIT G 09/11/08 1 1 M-08 12096917 PRODUCTION PROFILE - 10/06/08 1 1 P2-46 11970849 INJECTION PROFILE 10/09/08 1 1 D-OSA 11962617 RST 08/21/08 1 1 05-02A 12103674 RST - ~ p 08/24/08 1 1 07-30B 12005233 MCNL 09/23/08 1 1 13-14 11978482 RST - ~ 09/13/08 1 1 1'LGFIJG FiV n1YV YYLGlJt7C ACVGr I OT .71lArvlrvt7 ArvV 1'fG1 unrvliVU VIVO l.tJr1 CAlin 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503- 8 ATTN: Beth Received by: ~/ ' . ~ ~ Page 1 of 1 Maunder, Thomas E (DOA From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Thursday, October 23, 2008 10:36 AM To: Maunder, Thomas E (DOA) Subject: RE: DS 05-35A (208-134) Hi Tom, It took a little while to get the data back from the cementing folks, but I wanted to verify the data that I had with them. Yes, the lead cement was planned to have a yield of 2.45, but instead it was 3.34, which does work out to 218 sx. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 22, 2008 9:41 AM To: Hubble, Terrie L Subject: DS 05-35A (208-134) Terrie, I am reviewing the 407 for this well and have a question regarding the lead cement for the 7" casing. Based on the yield provided in the permit (2.45 ft^3/sx) and the actual volume reported in the operations report (130.2 bbls), I calculate about 300 sx was pumped. Can you confirm the lead sx count? Thanks in advance. Tom Maunder, PE. AOGCC 10/23/2008 ~~~iv~ J ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION 0 C T ~ 4 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG - ,<;;' _ ~?~! Cis Cans. Cammissian 1a. Well Status: ®Oil ^Gas ^ Plugged ^Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: ~~~4-`=~~~6 ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband~~/, 9/14/2008 !~ 12. Permit to Drill Number 208-134 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudd~ 8/ /2008 13. API Number 50-029-22172-01-00 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 9/9/2008 ~ 14. Well Name and Number: PBU 05-35A 2323' FNL, 124' FWL, SEC. 32, T11 N, R15E, UM Top of Productive Horizon: 1157' FNL, 673' FWL, SEC. 31, T11N, R15E, UM 8. KB (ft above MSL): 72' Ground (ft MSL): 34.2' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4219' FNL, 25' FWL, SEC. 30, T11N, R15E, UM 9. Plug Back Depth (MD+TVD) 12911' 8898' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 697190 y- 5949122 Zone- ASP4 10. Total Depth (MD+TVD) 13000' 8894' 16. Property Designation: ADL 028326 TPI: x- 692707 y- 5950172 Zone- ASP4 5952373 Zone- ASP4 692003 T t l D th 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: : x- y- ep o a 18. Directional Survey ®Yes ^ No u mi I r ni an rin i i n r 20 2. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 2 AAC 25.071): DIR / GR /RES / PWD, DIR / GR /RES /DEN /4/iy.Do%/G~,~86/~~ -~ 60 ~7YD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM .TOP BOTTOM SIZE CEMENTING RECORD PULLED " 1. H 11 rf 11 1 C _ _ ' 1741 sx CS III, 300 sx'G'; Top Job: 195 sx CS II 7" 7' 76' 7' -1 1 i r 'G' -1/ " 1 L- 1 1 -1/ " 4 I ' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, IISt each i & B P MD TVD f T tt nteNal Open r Si d N b rf ti SIZE DEPTH SET MD PACKER SET MD + ): ze an um e om; ora on ( o op o e 2-7/8" Gun Diameter 6 s f `° 4-1/2", 12.6#, 13Cr80 9520' 9402' , p ~ MD TVD MD TVD 11290' - 11430' 8938' - 8943' 11 ' 8938' - 8925' ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11630 - 890 11990' - 12910' 8920' - 8898' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected w/ 75 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: 10/5/2008 HOUrS Tested: 8 PRODUCTION FOR TEST PERIOD OIL-BBL: 51 GAS-MCF: 1,233 WATER-BBL: -0- CHOKE SIZE: 176 GAS-OIL RATIO: 24,026 Flow Tubing Press. 272 Casing Press: 1,500 CALCULATED 24-HOUR RATE• OIL-BBL: 154 GAS-MCF: 3,700 WATER-BBL: -0- OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Core s A wired? ^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, 'rf needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~, .rtf~ 7id1V ~ None ~ 9.j. A ~~41 ~~.. f~ i° i ~ `' ?one ~ Form 10-407 Revised 02/2007 ~ t f , ~ CONTINUED ON REVERSE SIDE _' ! 2S! GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9676' 8335' None Shublik A 9726' 8375' Shublik B 9752' 8396' Shublik C 9767' 8408' Sadlerochit 9812' 8444' Zone 4A / 42S6 9948' 8553' Zone 3 /Top CGL 10032' 8617' Zone 2C /Base CGL 10118' 8680' Zone 26 / 23SB 10228' 8755' Zone 1 B 10522' 8898' 14N 10560' 8910' Zone 1A /TDF 10653' 8933' Base Sadlerochit 10743' 8945' Formation at Total Depth (Name): Zone 1 A /TDF 10653' 8933' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~~ ~« Signed Terrie Hubble Title Drilling Technologist Date PBU 05-35A 208-134 Prepared ByNameMumber• Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: ~o„y R08ch, 564-4352 INSTRUCTIONS GeNew-~: 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. 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). 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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: 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. IreM 29: 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 25.07E Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 05-35 Common Name: 05-35 Test Date Test Type 8/29/2008 FIT 9/4/2008 FIT - - -- - - Test Depth (TMD) Test Depth (TVD} AMW Surface Pressure Leak Off Pressure (BHP) EMW 3,875.0 (ft) 3,771.0 (ft) 9.20 (ppg) 420 (psi) 2,222 (psi) 11.34 (ppg) 9,676.0 (ft) 8,335.0 (ft) 10.31 (ppg) 806 (psi) 5,270 (psi) 12.17 (ppg) C: Printed: 9/22/2008 12:40:01 PM BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT ' Phase I Description of Operations - - -- 8/23/2008 00:00 - 08:00 8.00 MOB P PRE Rig still on D-22C. Nabors 2ES Broken through road. Limited trucking and security resources available due to Assistance for j 2ES. Prepare Derrick to be laid over. Hook up and move Iliamna Camp from D-22C to DS-5. 08:00 - 12:00 4.00 MOB P PRE Lay over derrick. Prepare pits and truck shop for rig move. 12:00 - 00:00 12.00 MOB N WAIT PRE Perform general rig maintenence. Standing by to move pit module and truck shop due to emergency response route availability issues related to 2ES blocking road. 8/24/2008 00:00 - 10:00 10.00 MOB N WAIT PRE Perform general rig maintenence. Standing by to move pit 10:00 - 16:30 I 6.50 I MOB I P 16:30 - 20:00 3.50 MOB P 20:00 - 00:00 4.00 MOB P 8/25/2008 00:00 - 06:00 6.00 MOB P 06:00 - 10:00 4.00 MOB P 10:00 - 12:00 2.00 MOB P 12:00 - 16:00 4.00 MOB P 16:00 - 18:00 I 2.001 KILL I P 18:00 - 18:30 I 0.501 DHB I P 18:30 - 20:00 1.50 DHB P 20:00 - 21:30 1.50 KILL P 21:30 - 22:30 1.00 DHB P 22:30 - 00:00 1.50 WHSUR P 8/26/2008 00:00 - 03:00 3.00 BOPSU P 03:00 - 09:30 6.50 BOPSU P module and truck shop due to emergency response route availability issues related to 2ES blocking road. PRE Nabors Rig 2ES off of spine road. Proceeding with rig move. Move Pit Module and Truck shop from D-22C to DS 05-35. PRE Lay Rig mats on D-Pad road for rig substructure move. Mats previously unavailable due to 2ES divot. PRE Begin moving rig substructure from D-Pad to DS-05. Rig on K-Pad Access Road at 23:59 PRE Move rig substructure from K-Pad access road to Across from DS-02 on the way to DS-05. Lay out herculite and spot rig mats. PRE Move rig onto DS-05 and spot substructure over wellhead. PRE Raise Derrick. Rig down bridle lines. Rig up topdrive. PRE Spot pits and connect lines from sub unit to pit module. Berm cellar area. Prepare rig floor and pit module for well. DECOMP Acce t ri ~ 16:00 hour .Take on 9.8ppg brine. RU Lines to tree, and prepare for testing and circulating. DECOMP Re-test tubing and annulus (MIT-TxIA) to 2000 psi. Initial pressure 2015 psi, 15min pressure 1980 psi, 30min pressure 1960 psi. DECOMP U DSM I bricator test to 500 si. Pull BPV. DECOMP Reverse circulate 92 degF 9.8ppg brine w/ soap sweep surface to surface at 3 bpm, 210 psi. Dump soap when back to surface. DECOMP Set BPV and test from below to 1000 psi for 10 minutes. Solid ressure loss. DECOMP Bleed off control line pressure. Nipple down production tree. Install blanking plug in BPV. DECOMP Nipple up BOPE. Rig up for pressure testing. "'00:00 - 01:00 -Held 1 hour safety standdown w/Guess crew, BP WSL M. Martyn &NAD TP L. Toussant after crew came off tour. 3 of 4 crews complete. DECOMP Begin testing BOPE to 250 low and 3 500 iah. AOGCC Rep. Jeff Jones waived state witness of BOP test. NAD Toolpusher Chris Weaver, Lenward Toussant and BP WSL's Duncan Ferguson and Matt Martyn witness the test -PJSM with Rig Crew on testing BOP's -each test held for 5 minutes and charted Test with 4" test jt #1 Test -Top Pipe 3 1/2" x 6" Var.Rams, Choke Valves 1,2,3,16, HCR Kill valve, Upper IBOP rnrnea: aiLUZwn IG4U:1 I rm BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task ,Code NPT Phase Description of Operations 8/26/2008 03:00 - 09:30 6.50 BOPSU P DECOMP #2 Test -Choke Valves 4,5,6, Manual Kill valve, Manual IBOP #3 Test -Choke Valves 7,8 & 9 #4 Test -Test Super Choke and Manual Choke #5 Test -Choke Valves 10, 11 and 15 #6 Test -Choke Valve #14 #7 Test -Manual Valve on BOP stack #8 Test -Annular, Choke Line HCR Valve on Stack -Accumulator Test #10 Test -Blind Pipe Rams, Choke Valves 12 &13 09:30 - 11:00 I 1.501 DHB I P 11:00 - 12:00 1.00 ~ PULL ~ P 12:00 - 13:00 I 1.001 PULL I P 13:00 - 18:00 5.001 PULL ~ P 18:00 - 19:00 1.00 ~ PULL ~ P 19:00 - 20:30 1.501 BOPSUq P 20:30 - 00:00 ~ 3.50 ~ EVAL ~ P ~ 8/27/2008 ~ 00:00 - 07:30 ~ 7.50 EVAL ~ P 07:30 - 09:30 2.00 BOPSUFjP 09:30 - 10:30 1.00 BOPSU P Test with 3 1 /2": test jt. -Top Set of Pipe rams -Test Annular No Failures, Good Test DECOMP Rig Up DSM Lubricator and test to 1000 DECOMP Pull Tubing Hanger to Floor -Screw in Crossover into Tubing hanger -Back out Lock Down Screws -Hanger pulled free at 65,000 DECOMP CBU -285 gpm / 465 psi -Take SPR's - Monitor well, Static 9.8 ppg In /Out **Pre-Spud Meeting with Driller Dave Guess 's crew during pre tour meeting. DECOMP Lay Down Hanger, Pup Jt, 93 jts of 3 1/2" tubing, SSSV, 1 GLM, 21.4' of cut off jt DECOMP Rig Down tubing handling equipment and Rig Up Floor to Test Lower set of Pipe Rams DECOMP Test Lower Set of 2.875 x 5" VBR Pipe Rams to 250 low and 3,500 psi high. -Jones waived state witness of BOP test. -NAD TP Lenward Toussant and BP WSL Dave Newlon witness test -each test held for 5 minutes and charted Test with 4" test jt Good Test -Rig Down Test euipment and set wear bushing DECOMP PJSM with Schlumberger and NAD Rig Crew -R/U Wireline Unit and Bring Sheaves and equipment to floor -RIH with 6.125" GR and Junk Baskets, unable to get past 365' No Debris in JB when pulled to surface -R/U and Run 5.75" GR and JB's DECOMP Finish 5.75" GR and JB Run to 4000', No Problems RIH No Debris in baskets -R/U and Run USIT Lo -R/D wireline unit DECOMP Change Top set of Pipe Rams from 3.5 x 6" VBR to 7" Rams DECOMP Test Rams to 250 psi Low and 3500 psi High -Good Test Printea: sizzizoun iz:au:ii rnn ~~ BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task 'Code ', NPT Phase Description of Operations 8/27/2008 09:30 - 10:30 1.00 BOPSU P ( DECOMP -Test witness by BP WSL Duncan Ferguson and NAD TP Chris 10:30 - 11:00 0.50 BOPSU P 11:00 - 11:30 0.50 FISH P 11:30 - 15:00 3.50 FISH P 15:00 - 15:30 0.50 FISH P 15:30 - 16:30 I 1.001 FISH I P 16:30 - 19:00 2.501 FISH ~ P 19:00 - 21:00 ~ 2.00 ~ FISH ~ P 21:00 - 00:00 3.00 CASE P 8/28/2008 00:00 - 05:00 5.00 CASE P 05:00 - 06:30 1.50 CASE P 06:30 - 07:30 1.00 BOPSU P 07:30 - 08:00 0.50 BOPSU P 08:00 - 08:30 0.50 BOPSU P 08:30 - 11:00 2.50 CLEAN P 11:00 - 14:00 3.00 CLEAN P 14:00 - 16:00 2.00 CLEAN P Weaver -7" Test Joint Used DECOMP Install Wear Bushing DECOMP Make Up BOT Casin Cutter BHA -M.S. Cutter with 2.25 Knives, 6.125 Stabilizer, Crossover DECOMP RIH with casing cutter picking up 4" Drill Pipe 1 x 1 -RIH to 3950' DECOMP Position Knives at 3950' -Initiate cut and completed cut in 6 minutes -70 rpm / 1-2k Wlbs Torque -175 gpm / 720 psi -85k PUW / 84k SOW / 85k RtWt DECOMP Circulate Dead Crude from the 9 5/8 x 7" annulus -Pump 50 bbls Safe Surf-O Sweep -29 bbls of Diesel /Crude returns -Circulate 9.8 brine surface to surface -194 gpm / 276 psi Monitor Well, Showing minor Loss 9.8 ppg In /Out DECOMP POH -Laydown Casing Cutter tools -Lost 5 bph to hole on trip out DECOMP Make Up 7" Casing Spear -RIH to NoGo -BOLDS -Pull casng Landing Mandrel and Pack Off to Floor -125k to pull casing free, hanging weight 120k -Lay Down Spear DECOMP Laydown 7" 26# L-80 LTC casing -7000 - 9000 ft/Ibs to break out DECOMP La down 7" 26# L-80 LTC Casin -Total of 97 jts laydown, 3.46' of cut joint, 16 clamps, 20 centralizers, 15 stop rings DECOMP Rig Down casing handling equipment and clear floor for testing BOP Rams DECOMP Change Top set of Pipe Rams from 7" to 3.5 x 6" VBR_ DECOMP Test Rams to 250 psi Low and 3500 psi High -Good Test -Chart Record Test -Test witness by BP WSL Duncan Ferguson -4" Test Joint Used DECOMP R/D test equipment and set wear bushing DECOMP Make up 8 1/2" bit, 9 5/8" casing scraper ,string mill, 9 DC's, 18jts 4" HWDP DECOMP RIH picking up 4" Drill Pipe 1 x 1 -T with 10k down DECOMP CBU with 9.8 ppg brine -wash down to top of stump ~ 3950' -Pump 75 bbls of fresh water -Pump 50 bbl Hi-Vis sweep -Displace to 9.3 ppg LSND mud -460 gpm / 560 psi Printetl: 9/222008 1L:4U:11 F'M BP EXPLORATION operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date 'From - To Hours Task Code NPT 8/28/2008 ~ 14:00 - 16:00 2.00 CLEAN P 16:00 - 18:30 2.50 CLEAN P 18:30 - 23:00 4.501 DHB P 23:00 - 00:00 1.00 CASE P 18/29/2008 100:00 - 03:30 I 3.50 I WHIP I P 03:30 - 04:30 1.00 WHIP P 04:30 - 07:00 2.50 WHIP P 07:00 - 08:30 1.50 WHIP P Start: 8/23/2008 Rig Release: 9/14/2008 Rig Number: Page 4 of 13 Spud Date: 6/1/1991 End: Phase Description of Operations DECOMP Monitor well, Static 9.3 ppg In /Out DECOMP POH -Lay Down casing scraper, and string mill DECOMP Rlg up Schlumberger E-Line and make up 9 5/8" HES EZSV casing bridge plug. -RIH tag stump at 3933' E-Line MD -Log up and correlate log with previous USIT log -Place EZSV Bridge plug 3 feet above collar at 3891' -Set Bridge plug with bottom at 3888' and top of plug ~ 3885' -POH and rig down wireline unit DECOMP Test 9 5/8 casing and EZSV Bridge plug to 3500 psi for 30 minutes -Chart recorded test -Good Test, less than 10 psi for the first 15 minutes and zero psi for the second 15 minutes Conduct PJSM for picking up the Smith Whipstock during pressure test WEXIT Make Up Smith 9 5/8" TrackMaster Hyd. Set Whipstock -Anchorstock whipstock, TrackmasterTri- Mills, Running Tools, -Shallow hole test and function test multi-cycle tool, Good Test WEXIT RIH with DC's and HWDP WEXIT RIH to top of EZSV 3888' Drill Pipe MD WEXIT Orient Whipstock face to 45 degree left of highside, -Cycle Tool and set anchor -Top of slide C~ 3861' -Middle of Slide ~ 3868' -Bottom of Slide @ 3875' -Set Down and confirm set -Shear off of whipstock 'Suspect washout, unabe to pressure up on tool as normal, tool never completly shut off flow and would not hold pressure 08:30 - 10:00 1.50 WHIP N DFAL WEXIT POH looking for a washout -Washout in Multi-Cycle tool 10:00 - 12:00 2.00 WHIP N DFAL WEXIT Laydown MWD, UBHO, Multicycle tool 12:00 - 13:00 1.00 WHIP N DFAL WEXIT Make Up Tri-Mills and 1 x 5" HWDP -RIH with DC's and 4" HWDP 13:00 - 14:30 1.50 WHIP N DFAL WEXIT RIH with to top of slide `'~-` -300 gpm / 535 psi ~5~35~ -70 rpm / 3k Ft/Ibs of Torque -Drill New hole from 3868' - 3888' ~ -WOB 10-15k -PUW - 105k /SOW - 103k / RtWt - 104k -Milling window and cutting returns indicated cement behind pipe -150 Ibs to 200 Ibs of metal returns Work mills trough window several times to cleanout window 20:00-20:30 0.50 WHIP P WEXIT CBU -Finish circulating out Hi-Vis Super Sweep and circ. hole clean -300 gpm / 490 psi 20:30 - 21:30 1.00 WHIP P WEXIT Perform FIT to 11.3 ppg Printed: 9/22/2008 12:40:11 PM ~ ~ BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours' Task Code I NPT I Phase i Description of Operations ' -- - - - - 8/29/2008 20:30 - 21:30 1.00 WHIP P ~ WEXIT -3875' and / 3771' tvd 21:30 - 22:00 0.50 WHIP P 22:00 - 23:00 1.00 WHIP P 23:00 - 00:00 1.00 WHIP P 8/30/2008 100:00 - 01:00 I 1.00 I WHIP I P 01:00 - 03:00 2.001 DRILL ~ P 03:00 - 05:00 I 2.001 DRILL I P 05:00 - 06:00 1.00 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 12:00 ~ 5.50 ~ DRILL ~ P 12:00 - 00:00 12.001 DRILL P 8/31/2008 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL P -9.2 ppg In /Out -Pressure up to 420 psi @ .5 bpm Pump a total 0.7 bbls /returned 0.7 bbls Chart Recorded test and held test for 10 min. with zero pressure bleed off -Monitor Well, Static WEXIT Service TDS, Draw Works and Crown WEXIT POH to DC's WEXIT Lay Down BHA -Lay down 9 - 6 1/2" DC's -UD 5" HWDP -UD Tri-Mills, Pilot mill 3/8" undergauge, 1st watermelon mill 1/4" undergauge, Top Mill Full Gauge WEXIT Function BOP rams and Jet Stack to flush metal cuttings from BOPE -Service Wear Bushing INT1 M/U 8 1/2" Drillin BHA -8 1/2" PDC, 1.5 degree PDM, LWD (ARC6), MWD, 8 1/2"NM Stab, 2 x NM spriral DC's, 8 1/2" NM Stab, NM Spriral DC, Float Sub, XO, Jars, HWDP, -Shallow test MWD ~ 1st Stand of DP, Good Test INT1 RIH to Top of Window -Finish Picking up 66 jts of 4" HT40 DP INT1 Slip and Cut Drilling Line INT1 Break Circ., Estabilish clean hole ECD's, SPR's, -Slide trough window -Start drilling 8 1/2" hole INT1 Directional Drill 8 1/2" Intermediate hole 3888 - 4552'md (4288' tvd) -WOB = 8-14k -550 gpm / 1750 psi off / 1840 psi on -80 rpm 3k ft/Ibs Torque off btm. / 5k ft/Ibs Torque on btm. PUW = 115k /SOW = 100k / RtWt = 105k CECD = 10.06 /AECD = 10.31 ART = 1.73 hrs / AST = 1.75 hrs Total hrs on bit = 3.48 hrs INT1 Directional Drill 8 1/2" Intermediate hole 4552' - 6272md (5643' tvd) -WOB = 8-20k -550 gpm / 2260 psi off / 2400 psi on -80 rpm 5k ft/Ibs Torque off btm. / 6k fUlbs Torque on btm. PUW = 145k /SOW = 110k / RtWt = 120k CECD = 10.07 /AECD = 10.24 ART = 6.80 hrs / AST = 1.07 hrs Total hrs on bit = 11.35 hrs INT1 Directional Drill 8 1/2" Intermediate hole 6272 - 7801'md (6826' tvd) -W06 =14-25k -550 gpm / 2860 psi off / 3200 psi on -100 rpm 7k ft/Ibs Torque off btm. / 10k ft/Ibs Torque on btm. PUW = 165k /SOW = 125k / RtWt = 135k CECD = 10.34 /AECD = 10.88 ART = 6.72 hrs / AST = 1.47 hrs Total hrs on bit = 19.54 hrs Printed: 9/22/2008 12:40:11 PM ~ • BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: r Date ~ From - To Hours Task Code NPT Phase Description of Operations 8/31/2008 12:00 - 00:00 12.00 DRILL P INT1 Directional Drill 8 1/2" Intermediate hole 7801 - 8756'md (7597' tvd) -WOB =14-20k -550 gpm / 3350 psi off / 3700 psi on -100 rpm 7k fUlbs Torque off btm. / 10k ft/Ibs Torque on btm. PUW = 175k /SOW = 135k / RtWt = 145k CECD = 10.35 /AECD = 10.70 ART = 4.50 hrs / AST = 3.22 hrs Total hrs on bit = 27.24 hrs 9/1/2008 00:00 - 12:00 12.00 DRILL P INT1 Directional Drill 8 1/2" Intermediate hole 8756' - 9617 and -W06 =14-20k -500 gpm / 3400 psi off / 3620 psi on -100 rpm 8k ft/Ibs Torque off btm. / 10.5k ft/Ibs Torque on btm. PUW = 200k /SOW = 140k / RtWt = 155k CECD = 11.57 /AECD = 11.73 Weight up to 10.8 ppg mud wt with the addition of spike fluid ~ 8954' AST = 5.42 hrs /ART = 4.20 hrs /Total Bit Hrs = 36.83 12:00 - 13:00 1.00 DRILL P INT1 Directional Drill 8 1/2" Intermediate hole 9617' - 9676' and (8334' tvd) -WOB =14-20k -500 gpm / 3400 psi off / 3620 psi on -100 rpm 8k fUlbs Torque off btm. / 10.5k ft/Ibs Torque on btm. PUW = 200k /SOW = 140k / RtWt = 155k CECD = 11.57 /AECD = 11.73 AST =0 hrs /ART = 0.47 hrs /Total Bit Hrs = 37.29 13:00 - 14:30 1.50 DRILL P INT1 Circulate Hole Clean -500 gpm / 3420 psi -100 rpm / 9k FULbs of Torque Monitor well, Statib 10.8 ppg In /Out Reduce actual ECD from 11.70 to 11.44 EMW 14:30 - 18:30 4.00 DRILL P INTi POH to from 9676 - 9234 25 - 30k overpulls -Back Ream from 9234 -7323' and -500 / 3020 psi -100 rpm / 7k Wlb of Torque No Issues Backreaming Back Reamed to 1 stand above where the Top Ghost Reamer worked through 18:30 - 23:00 4.50 DRILL P INT1 POH -Circ. 15 min to clear BHA -POH on the Hook until 4394' md, 25 -40k overpulls -Pump out to 4073' and 100 gpm / 3000 psi -Pull through window to 3755' -No Issues running through window 23:00 - 23:30 0.50 DRILL P INT1 Circ. hole clean -1 1/2" - 3" chunks of coal in returns Shaker 85% of ca icit , -one piece of coal 4" wide x 14" long -Hole cleaned up after 1.5 x bottoms up 23:30 - 00:00 0.50 DRILL P INT1 Service Top Drive, Draw Works, Crown, Blocks and Iron Roughneck 9/2/2008 00:00 - 02:00 2.00 DRILL P INT1 RIH, -Pass through whipstock window without issues -20k increase in drag RIH at 8150 - 8250 -Sat with 50k ~ 9527, Pick up and Kelly up Nrinceo: aizuzuuo icau: i i rm ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 05-35 Page 7 of 13 ~ Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To II Hours Task I Code ~ NPT Phase Description of Operations 9/2/2008 102:00 - 02:30 0.50 ~ DRILL P INT1 Pre-cautionary ream from 9527 to 9676' -Stage up to 475 gpm / 3310 psi -80 rpm / 9.5 ft/Ibs of Torque Hole cleaned up with no issues with tight hole. Circulate Hole Clean -Pump 38 bbl Hi-Vis Sweep -500 gpm / 3500 psi -60 rpm / 9k ft/Ibs Torque Sweep brought up 25% increase in cutting Monitor well, Static 10.8 ppg In /Out POH Lay down HWDP & BHA components. -Function test BOP. Change upper rams to 7" casing rams. -Test casing rams to psi ow an 500 psi high,hold for 5 minutes and chart. -Pull wear bushing. Rig up to run 7", 26# casing. Run 7" , 26#,BTC-M, L-80 casing to 3851' Circulate,stage pumps up to 5 BPM ~ 447 psi. Up wt. 114k,down wt. 110k. Run 7",26# casing from 3851' to 7156'. -Losses while running from 5500',total losses 23 bbl. (5500'-7156') -Up wt 187k,down wt. 132k Torque turn 7",26# TCII, opt. torque 10,100 ft/Ibs. -7156' to 9676' -Break circulation ~ 7950',8600' -Up wt. 240k,down wt.153k Circulate casing on bottom,210 GPM ~ 825 psi. -Volume lost while running and circulating casing 50 bbls. Rig down Franks Tool, make up cement head and circulating lines. Circulate casing Q 5 BPM,825 psi. -Hold pre-job meeting with cementing and rig crews. Cement 7",26#,L-80 casing -Pump 5 bbls water to floor through tee. -Pressure test surface line to 4000 psi.,good test. -Pump 24.62 bbls,10.9 ppg Mud Push,4 bbl/min -Drop bottom plug -Pump lead cement 130.21 bbls,i l ppg Lite Crete w/first 15 bbls having CemNet. -Pump tail slurry 34.7 bbls,15.8 Class G -Drop top plug and chase with 10 bbls water(cement on top of plug). -Switch to rig pumps and displace at 5 BPM to 2 BPM as per pumping schedule -Bump plug C~ 6157 stks,357 bbls, 1500 psi. -Check floats,OK -Cement in place 10:15 09/03/2008 -30 bbls fluid lost while cementing and displacing. 02:30 - 05:00 2.50 DRILL P INT1 05:00 - 08:30 3.50 DRILL P INT1 08:30 - 10:00 1.50 DRILL P INT1 10:00 - 11:30 1.50 CASE P INT1 11:30 - 13:00 13:00 - 18:00 18:00 - 19:00 19:00 - 00:00 1.50 CASE P 5.00 CASE P 1.00 CASE P 5.00 CASE P INTi INT1 INTi INT1 19/3/2008 100:00 - 04:00 I 4.001 CASE I P INT1 04:00 - 06:30 2.50 CASE P INTi 06:30 - 07:00 0.50 CASE P INT1 07:00 - 07:30 0.50 CEMT P INT1 07:30 - 10:30 3.00 CEMT P INT1 Pri ntetl: 9/222UU8 1L:4U:11 YM i ~ BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: 0 5-35 Common W ell Name: 0 5-35 Spud Date: 6/1/1991 Event Nam e: R EENTE R+COMPLETE Start : 8/23/2008 End: Contractor Name: N ABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: N ABOBS 7ES Rig N umber: Date From - To Hours Task ' Code ~ NPT Phase Description of Operations 9/3/2008 10:30 - 11:00 0.50 CEMT P INT1 Pressure test casin to 3500 psi. hold for 30 min & chart. 11:00 - 12:00 1.00 CEMT P INT1 Inject 10 bbls 10.8 ppg Drilling Mud to 9 5/8" x 7" annulus Moniter Well Inject 1 bbl Moniter Well 12:00 - 13:30 1.50 CEMT P INT1 Wait On Cement to obtain 100 be prior to nipple down. 13:30 - 15:30 2.00 CEMT P INT1 Nipple Down BOP's Split Wellhead @ Casing Spool Raise Tubing Spool & BOP Rig Down Casing Elevators & Cement Head 15:30 - 18:00 2.50 CEMT P INT1 Set Emergency Slips -200K Hook Loa riot To Setting Slips Cut Casing with Wach's Cutter -31.05' Cut Joint Install Packoff 18:00 - 21:00 3.00 CEMT P INT1 Nipple Up BOP's Run In Lock Down Stews Test Pack Off 4300psi/30-min 21:00 - 22:00 1.00 CEMT P INT1 Chan a To Rams to 3.5" X 6" VBR 22:00 - 23:00 1.00 CEMT P INT1 Rig Up To Test BOP 23:00 - 00:00 1.00 CEMT P INT1 Test BOPE 250/3500psi AOGCC Rep Bob Noble Waived Witness To BOP Test Witnessed by BP Rep: Blair Neufeld Nabors Tool Pusher: Biff Perry Drilling Engineer: Zach Sayers Inject 130 bbls 10.8 ppg Mud Down OA -3 BPM -880 psi 9/4/2008 00:00 - 03:00 3.00 BOPSU P 03:00 - 03:30 0.50 DRILL P 03:30 - 04:30 1.00 DRILL P 04:30 - 07:00 2.50 DRILL P 07:00 - 07:30 0.50 DRILL P 07:30 - 09:30 2.00 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 12:00 I 2.00 DRILL P 12:00 - 13:00 1.00 DRILL P 13:00 - 14:00 1.00 DRILL P 14:00 - 00:00 10.00 DRILL P INT1 Test BOP's To 250 psi Low, 3500 psi High Witness To Test Waived By AOGCC Rep Bob Noble. Test With 4" and 4.5" Test Joints PROD1 Install Wear Bushing PROD1 Pick Up BHA PROD1 Pick Up 99 joints 4" Drill Pipe to 3349'. *"Note: Out of critical path, RU Little Red Hot Oil Services to OA and inject 57 bbls 50degF diesel down OA for freeze protect @ 1 BPM - ICP - 800 psi, FCP - 1100 psi. PROD1 Set Schlumberger MWD drawworks calibration. PROD1 Run in hole with 6 1/8" directional assembly from 3349' to top of float collar ~ 9592' PROD1 Drill float collar, and shoe track to 9671' -Up wt. 200k,down wt. 100k,rotating wt, 120k -220 GPM ~ 2060 psi -40 RPM ~ 9k torque. PROD1 Pump 50 bbl H2O,50 bbl spacer pill. -Displace well to 8.5 ppg Flo-Pro mud -240 GPM X1940 psi. -Clean shaker bed and ditches. -Record slow pump rates. PROD1 Drill shoe track from 9671' to 9676', drill new hole to 9696'. PROD1 Perform FIT to 10.3 ppg EMW. PROD1 Drill 6 1/8" hole from 9696' to 9978'. Printed: 9/22/2008 12:40:11 PM BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: Date 'From - To ~ Hours Task Code NPT Phase Description of Operations '..9/4/2008 14:00 - 00:00 10.00 DRILL P PROD1 -WOB 15k ,5k torque on bottom,4k torque off bottom. -Up wt. 183k,down wt 137k,rotating wt. 150k -242 GPM,1619 psi on bottom,1533 psi off bottom. -Mud wt in and out 8.5ppg. 9/5/2008 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6 1/8" hole from 9978' to 10,327'. -WOB 15k,5k torque on bottom,4k torque off bottom. -Up wt. 188k,down wt 143k,rotating wt. 150k -250 GPM,1750 psi on bottom,1610 psi off bottom. -Mud wt in and out 8.5ppg,Vis 49. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6 1/8" hole from 10,327' to 10,730'. -WOB 15k,7k torque on bottom,6k torque off bottom. -Up wt. 190k,down wt 138k,rotating wt. 148k -250 GPM,1830 psi on bottom,1715 psi off bottom. -Mud wt in and out 8.5ppg,Vis 50. 9/6/2008 00:00 - 01:30 1.50 DRILL P PROD1 Drill 6 1/8" hole from 10,730' to 10,762'. -WOB 15k,7k torque on bottom,6k torque off bottom. -Up wt. 190k,down wt 138k,rotating wt. 148k -250 GPM,1830 psi on bottom,1715 psi off bottom. -Mud wt in and out 8.5ppg,Vis 50. 01:30 - 02:30 1.00 DRILL P PROD1 Circulate bottoms up,250 GPM ~ 1705 psi. -Mud wt in and out 8.5 ppg. -Monitor well, static 02:30 - 05:00 2.50 DRILL P PROD1 POH from 10,762' to 10,510'. -Hole pulling 25-35k over -Back ream from 10,510' to shoe at 9676'. -240 GPM C~ 1500 psi. -60 RPM,torque 5-10k. -Some overpull while reaming due to long slide intervals and hole geometry. 05:00 - 05:30 0.50 DRILL P PROD1 Monitor well static. -Pump dry job. -Mud wt in and out 8.5 ppg. 05:30 - 08:30 3.00 DRILL P PROD1 POH from 9676' to BHA. 08:30 - 09:00 0.50 DRILL P PRODi Lay down BHA. 09:00 - 10:30 1.50 DRILL P PROD1 Download MWD. -Make up 6 1/8" assembly #2. -Hold PJSM for handling radioactive sources,install sources. 10:30 - 14:00 3.50 DRILL P PROD1 Run in hole to 9589' testing MWD at 1179'. -Fill pipe every 30 stds. 14:00 - 15:00 1.00 DRILL P PROD1 PJSM. Cut and slip 139' of drilling line. -Service top drive and crown. -Inspect and adjust brakes. 15:00 - 16:00 1.00 DRILL P PROD1 Run in hole from 9589' to 10,758',wash last stand to bottom. -BHA took weight at 10,572' & 10,654',worked through without pump. -4' fill on bottom. -Record slow pump rates. 16:00 - 21:30 5.50 DRILL P PROD1 MAD pass log, drilled section with MWD. -Backream at 300'/hr,250 GPM ~ 1720 psi. -40 RPM,6K torque -Up wt. 190k,down wt. 138k,rotating wt.150k 21:30 - 22:00 0.50 DRILL P PROD1 Run in hole from 9676' to 10,762'. -Wash to bottom, 4' fill. P fl ntetl: 9/ZZ/Z008 1'L:4U:11 I'M i • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: Date ', From - To'~ Hours Task Code NPT Phase Description of Operations 9/6/2008 22:00 - 00:00 2.00 DRILL P PROD1 Drill 6 1/8" hole from 10,762' to 10,775'. -WOB 15k. -Up wt. 190k,down wt 138k,rotating wt. 148k -250 GPM,1650 psi on bottom,1620 psi off bottom. -Mud wt in and out 8.5ppg. 9/7/2008 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6 1/8" hole from 10,775' to 11,117'. -WOB 15k.Torque off bottom 5k,on bottom 8k -Up wt. 193k,down wt 140k,rotating wt. 150k -250 GPM,1950 psi on bottom,1675 psi off bottom. -Mud wt in and out 8.6ppg. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6 1/8" hole from 11,117' to 11,385'. -WOB 15k.Torque off bottom 5k,on bottom 8k -Up wt. 193k,down wt 140k,rotating wt. 150k -250 GPM,1860 psi on bottom,1685 psi off bottom. -Mud wt in and out 8.6ppg. 9/8/2008 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6 1/8" hole from 11,117' to 11,818'. -WOB 15k.Torque off bottom 6k,on bottom 8k -Up wt. 195k,down wt 140k,rotating wt. 153k -250 GPM,2060 psi on bottom,1720 psi off bottom. -Mud wt in and out 8.5ppg. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6 1/8" hole from 11,818' to 12,095'. -WOB 15k.Torque off bottom 6k,on bottom 8k -Up wt. 195k,down wt 130k,rotating wt. 150k -250 GPM,1980 psi on bottom,1740 psi off bottom. -Mud wt in and out 8.5ppg. 9/9/2008 00:00 - 06:00 6.00 DRILL P PROD1 Drill 6 1/8" hole from 12,095' to 12,262'. -WOB 10k.Torque off bottom 6k,on bottom 8k -Up wt. 195k,down wt 130k,rotating wt. 150k -250 GPM,1980 psi on bottom,1740 psi off bottom. -Mud wt in and out 8.5ppg. 06:00 - 12:00 6.00 DRILL P PROD1 Directionally drill ahead from 12,262' to 12,551' md. - PU - 195k, SO - 130k, RTW - 150k, 10-20k WOB 250 gpm, 2020 psi on, 1810 psi off 60 rpm, 9.Ok TO on, 6.Ok TO off MW - 8.6 ppg. No losses. ART - 2.52 hrs, AST - 4.38 hrs, ADT - 6.9 hrs from 00:00-12:00 12:00 - 23:30 11.50 DRILL P PROD1 Directionally drill ahead from 12 551' to TD f~ 13 000' md. - PU - 200k, SO - 125k, RTW - 150k, 8-20k WOB 250 gpm, 2050 psi on, 1835 psi off 60 rpm, 9.Ok TO on, 7.Ok TO off MW - 8.6 ppg. No Losses. 12:00-23:30 -ART - 3.70 hrs, AST - 2.15 hrs, ADT - 5.85 hrs. 23:30 - 00:00 0.50 DRILL P PROD1 Begin circulating one bottoms up - 250 gpm, 1840 psi. 9/10/2008 00:00 - 00:30 0.50 DRILL P PROD1 Finish circulating one bottoms up - 250 gpm, 1840 psi. 00:30 - 06:00 5.50 DRILL P PRODi MAD Pass ~ no faster than 720 fph from TD C~3 13,000' and to 10,639' md. 250 gpm, 1650 psi, PU - 190k, SO - 125k, RTW 150k, 80 rpm, 6k TQ. 06:00 - 07:00 1.00 DRILL P PROD1 Backream out for hole cleaning from 10,639' and to 9,676' md. 80 rpm, 7k TO, RTW - 145k 250 gpm, 1710 psi. 07:00 - 07:45 0.75 DRILL P PROD1 Drop 1.87" OD ball & open circ sub w/ 2520 psi pressure spike. Circulate 1 bottoms up. Very little cuttings load on shakers Pflfll2C1: 9/22/2UU8 12:4U:11 PM BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Common W Event Name Contractor Rig Name: Date ; Name: 0 ell Name: 0 : R Name: N N From - To ~ 5-35 5-35 EENTE ABOBS ABOBS Hours R+COM ALASK 7ES Task PLET A DRI Code E LLING NPT Start I Rig R Rig N Phase ', Spud Date: 6/1/1991 : 8/23/2008 End: elease: 9/14/2008 umber: Description of Operations 9/10/2008 07:00 - 07:45 0.75 DRILL P PROD1 throughout bottoms up. 505 gpm, 1875 psi, 80 rpm. 07:45 - 08:00 0.25 DRILL P PROD1 Shut down, monitor well -static. MW in 8.6, MW out 8.6. Pump dry job, remove blower hose, prepare to pull out of hole. 08:00 - 11:00 3.00 DRILL P PROD1 POH from 9,676' and to top of BHA ~ 223'. 11:00 - 13:00 2.00 DRILL P PROD1 PJSM w/ all hands on handling nuclear sources. Lay down BHA#8. BitGradel-l-WT-A-X-I-NO-TD. 13:00 - 14:00 1.00 CASE P RUNPRD Function all BOPE Rams. RU liner running equipment.. 14:00 - 18:30 4.50 CASE P RUNPRD MU shoe track w akerlok. RIH and check floats -function as required both ways. MU tq on IBT-M 3,000 ft lbs. RIH w/ 83 joints of 4.5" 12.6# L-80 IBT-M liner string at 1 jt. per minute to 3,494' and filling each jt w/ top drive off every 10 joints. 18:30 - 19:00 0.50 CASE P RUNPRD MU 4.5" x 7" Flexlock liner hanger/ZXP liner top packer & HR running tool w/ rotating dog sub to 4.5" liner. PU 5' and 15' pup for spaceout. 19:00 - 19:30 0.50 CASE P RUNPRD Circulate 1.5 liner volumes - 80 bbls ~ 5 bpm, 390 psi. PU - 68k, SO - 68k 19:30 - 22:00 2.50 CASE P RUNPRD RIH from 3,494' to 9,676' w/drillpipe from derrick. Slight losses at -2 bph while RIH. 22:00 - 23:00 1.00 CASE P RUNPRD Stage up pumps at 7" casing shoe to 5 bpm, 715 psi. Pump 173 bbls. 23:00 - 00:00 1.00 CASE P RUNPRD RIH from 9,676' to 11,352 w/drillpipe from derrick. Slight losses at -2 bph while RIH. PU - 170k, SO - 130k. Still losing 2 bph. Total losses while RIH ~ 23 bbls. 9/11/2008 00:00 - 01:30 1.50 CASE P RUNPRD RIH w/ 4.5" liner on drillipipe from 11,352'to 12,881' md. MU topdrive cementing head and single of drilpipe. Wash down last joint to 13,000' TD ~ 45 gpm, 574 psi. PU - 190k, SO - 125k. Tag up and pick up 1 foot. 01:30 - 03:00 1.50 CASE P RUNPRD Stage pumps up to 5 bpm, 1130 psi. Circulate and reciprocate while rigging up Schlumberger cementers. No noticable losses while circulating. 03:00 - 04:30 1.50 CEMT P RUNPRD PJSM. Pump 3 bbls mudpush to floor w/Schlumberger pumps and down hole. Shut in. Test lines to 4000 psi and walk lines. Pump a total of 20.8 bbls 12.0 ppg mud push down hole. At 03:39 start to pump 88.2 bbls class G tail w/ GasBlok slurry at 5 bpm. ICP - 430 psi, FCP - 250 psi. Shut down. Clear lines of cement by pumping mud through topdrive to bleeder. Drop drill pipe wiper dart and note plug drop indicator trip. Total displacement = 146.5 bbls. Pump 58 bbls Perf pill followed by 8.5 ppg FloPro mud ~ 5-6 bpm, 15 psi until catch cement. Slow to 3 bpm at 90 bbls away & see drill pipe wiper dart catch liner wiper plug C~? 94 bbls away, and shear off at 1300 psi. At 141 bbls away, reduce pump rate to 2 bpm for plug bump. See n in collar as ex ected - 2430 strokes, 1800 psi. Saw good lifting pressure throughout displacement. No measureable losses during displacement. Cement in place at 04:21. Reciprocated pipe in 20' strokes during job until wiper lu latch u -after latch u ulled to 50k over and unable to RIH back to TD. Lost 2 feet. PU - 185k, SO - 120k. At plug bump bring pressure up to 2600 psi and hold f/3 mins to set liner hanger slips. 04:30 - 05:00 0.50 CASE P RUNPRD Setting hanger and packer after bumping plug. Slack off to 50k & check liner hanger. Hanger holding. PU to 85k and pressure Printetl: 9/2Z/20D8 12:aU:11 rnn ~ ~ BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: 05-35 Common Well Name: 05-35 Spud Date: 6/1/1991 Event Name: REENTER+COMPLETE Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/14/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code', NPT Phase Description of Operations ~ 9/11/2008 04:30 - 05:00 0.50 CASE P _ RUNPRD to 3,500 psi and hold. PU to expose rotating dog sub and slack off 100k -Good indication of set -felt strong jolt on rig floor. Rotate at 15 rpm. Slack off while rotating to confirm set of ZXP packer. Saw no further indication. Bleed off pressure to zero and check floats for bleedoff back to surface. Floats holding. Pressure up to 600 psi. PU until PBR packoff cleared liner top extension sleeve and pressure bled off. Circulate cement above liner top. PU 20' to clear liner top w/stinger and put NOGO mark on drill pipe. Circulate 1.3 bottoms up at 500 gpm, 1100 psi. Mudpush and 20 bbls of sidewalk cement seen at surface. 05:00 - 06:00 1.00 CEMT P RUNPRD ut own and lay down cementing head and 1 single. Displace well to seawater. 06:00 - 10:30 4.50 CEMT P RUNPRD TOOH, LD DP. 10:30 - 16:30 6.00 EVAL P RUNPRD Log USIT from 9497 to surface. TOC clear) defined at window at 3855. 16:30 - 19:00 2.50 BOPSU P RUNPRD PJSM. Pull wear ring. Test BOPs. PT lower ram's and annular w/ 2-7/8 test joint 250/3500psi. Good test. RD test equipment. Install wear ring. 19:00 - 20:00 1.00 CASE P RUNPRD Close blind rams and test 7" casing & 4.5" Liner to 3500 si for 30 min. Lost 30 psi in 1st 15 min. Lost 10 psi in last 15 min._ RD, BD lines. 20:00 - 23:00 3.00 PERFO P OTHCMP PJSM. RU to run 2-7/8 pert guns. 1320' 6spf, 60-deg phasing PJ and PJ Omega. RIH to 1645. 23:00 - 00:00 1.00 PERFO P OTHCMP RU power tongs to run 2-7/8 Fox pipe handling equipment. Faulty gauge, mobilize gauge to location and replace. 9/12/2008 00:00 - 01:00 1.00 PERFO N SFAL OTHCMP Replace faulty gauge. RU to torque crossover to disconnect. Overtorqued connection, threads gauled. Gauge found with hydraulic port not open. Mobilize replacement crossover. 01:00 - 07:30 6.50 PERFO P OTHCMP RIH with erf uns on 2-7/8 Fox i e. Place guns at depth for bottom shot at 12910' Perf Intervals: 11290' - 11430' ' ' - 11890 11630 11990' - 12910' 07:30 - 08:00 0.50 PERFO P OTHCMP PJSM with rig crew and SLB. Covered pert gun firing sequence. 08:00 - 08:30 0.50 PERFO P OTHCMP Initiate firing sequence with pressure pulse. Indications of guns firing -drill pipe jolted and the fluid level in the annulus began to drop. 08:30 - 09:00 0.50 PERFO P OTHCMP Trip out of hole and rack drill pipe in stands until guns are clear of the top perforation at 11059' 09:00 - 10:30 1.50 PERFO P OTHCMP Circulate and condition hole bottoms up (231 bbls, 5 bpm f~ 880 psi). Performed 15 minute flow monitor. No flow indicated. Established static loss rate of 2 bph. 10:30 - 15:30 5.00 PERFO P OTHCMP Trip out of the hole and lay down drill pipe one by one to the pipe shed from 11059' to 4082' 15:30 - 16:00 0.50 PERFO P OTHCMP Trip in the hole with previously racked stands from 4082' to 5814' 16:00 - 17:00 1.00 PERFO P OTHCMP Slip and cut 96' of drilling line, service top drive and inspect drawworks breaks. 17:00 - 18:30 1.50 PERFO P OTHCMP Trip out of the hole and lay down drill pipe one by one to the pipe shed from 5814' to 3508'. Printed: 9/22/2008 12:40:11 PM ~' ~ B'P EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 0 5-35 '..Common W ell Name: 0 5-35 Spud Date: 6/1/1991 'Event Name : R EENTE R+COM PLETE Start : 8/23/2008 End: Contractor Name: N ABOBS ALASK A DRILLING I Rig R elease: 9/14/2008 Rig Name: N ABOBS 7ES Rig N umber: Date From - To Hours Task ~ Code NPT Phase Description of Operations 9/12/2008 18:30 - 21:30 3.00 PERFO P OTHCMP RU 2 7/8" Fox handling tools, hold PJSM. Trip Fox out of hole from 3508' to 1645'. 21:30 - 00:00 2.50 PERFO P OTHCMP PJSM, trip out of hole and lay down pert guns. 9/13/2008 00:00 - 00:30 0.50 PERFO P OTHCMP Trip out of hole and lay down pert guns. All shots fired. 00:30 - 03:00 2.50 BUNCO RUNCMP Rig down pert gun handling equipment. Pull wear bushing Make dummy run with tubing hanger. Verifyed RKB to tubing spool flange = 26.12'. RU 4.5", 13Cr80, 12.60#, Vam Top tubing & completion handling equipment w/"Torque Turn" torque contol equipment, recording unit, and compensator. 03:00 - 14:30 11.50 BUNCO RUNCMP MU tail pipe assembly to packer assembly and RIH w/ 4.5" 12.6# 13Cr80 Vam Top completion. Torque Turn set to 4,440 ft./Ibs optimum torque 14:30 - 16:00 1.50 BUNCO RUNCMP Space out tubing as necessary to place WLEG into middle of PBR. Space out w/three pup jts below top joint of tubing. PU/MU landing joint w/hanger assy and land completion w/WLEG at 9520' w/6.5' stung into Liner Top Extension Sleeve. Run in lock down screws per FMC representative. Counted leftover jts 4.5" Vam Top and found 21 as expected. 16:00 - 18:00 2.00 BUNCO RUNCMP Hook up lines and reverse circulate 147 bbls of 8.5 ppg clean seawater followed by 108 bbls seawater w/corrosion inhibitor. Follow w/67 bbls clean seawater w/out corrosion inhibitor. Pumped at no more than 3 bpm to avoid eroding packer elements. 18:00 - 20:30 2.50 BUNCO RUNCMP Drop ball and rod to RHC plug. LD landing jt. Close blind rams set packer and test tubing and record on chart. Passing test 15min 3590 si 30min 3580 si). Bleed tubing to 1500 si. Pressure annulus to 3515 psi and record test on chart for 30 mins. Passin test (15 min 3485 psi, 347 psi . ee o annulus pressure to 0 psi. Bleed o to ing to psi. ressure up on annulus and shear DCK valve in GLM at 3777' w/1900 psi. Pump both ways to ensure valve open. Install TWC and test from below via annulus and sheared DCK valve. Passing test. 20:30 - 22:00 1.50 BUNCO RUNCMP Nipple Down BOP stack and stand back on pedestal. 22:00 - 00:00 2.00 BUNCO RUNCMP Nipple up the tree and adaptor flange. PT adaptor flange to 5000 psi. Passing 30 min test. PT tree to 5000 psi. No leaks. 9/14/2008 00:00 - 02:00 2.00 WHSUR P RUNCMP Lubricate out TWC and RU LRS for circ out and freeze protect. - Pumped 75 bbls 50* diesel at 2 bbls min trough the sheared DCK at 3777'. Allowed tubing to U-tube. 02:00 - 03:30 1.50 WHSUR P RUNCMP CH2M lubricate in BPV. PT to 1000 psi with LRS. Secure well. 03:30 - 06:00 2.50 RIGD P RUNCMP Prepare for rig move. Release rig at 0600hrs Printed: 9/LlJLUUtl 1'L:aU:ll F'M _=- - -- -- DS05-35A Survey er Report Report Date: September 10, 2008 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 278.000° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: DS-05 / 05-35 TVD Reference Datum: Rotary Table Well: 05-35 TVD Reference Elevation: 62.85 ft relative to MSL Borehole: 05-35A Sea Bed /Ground Level Elevation: 34.20 ft relative to MSL UWVAPIR: 500292217201 Magnetic Declination: 23.180° Survey Name /Date: 05.35A /September 10, 2008 Total Field Strength: 57689.946 nT Tort /AHD / DDt / ERD ratio: 318.718° / 7142.53 ft / 6.520 / 0.798 Magnetic Dip: 80.922° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 05, 2008 Location LaflLong: N 70.26516814, W 148.40553262 Magnetic Declination Model: BGGM 2008 Location Grid NIE Y/X: N 5949121.630 ftUS, E 697189.820 ftUS North Reference: True North Grid Convergence Angle: +1.50086131 ° Total Corr Mag North -> True North: +23.180° Grid Swle Factor: 0.99994417 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft tt ft ft de 100 ft ftUS ftUS RTE U.UU U.UU U. UU -bL. t55 U.UV V.UV U•UU U.VU U.VV V.VV V.VV ~7.7`1~IGI. VJ Vim/ IOJ.OL IV /V.G VJIVUIY VV IYU. YVJJJLVG WRP 28.65 0.00 0. 00 -34. 20 28.65 0.00 0.00 0.00 0.00 0.00 0.00 5949121. 63 697189.82 N 70.26516814 W 148. 40553262 SCH GCTG 90.85 0.22 132. 33 28. 00 90.85 -0.10 0.12 0.12 -0.08 0.09 0.35 5949121. 55 697189.91 N 70.26516792 W 148. 40553191 190.85 0.12 325. 41 128. 00 190.85 -0.19 0.21 0.21 -0.12 0.17 0.34 5949121. 51 697189.99 N 70.26516780 W 148. 40553124 290.85 0.25 234. 81 228. 00 290.85 0.04 0.48 0.18 -0.16 -0.07 0.28 5949121. 47 697189.76 N 70.26516769 W 148. 40553316 390.85 0.57 175. 95 328. 00 390.85 0.10 1.14 0.81 -0.78 -0.21 0.49 5949120. 84 697189.63 N 70.26516599 W 148. 40553432 490.85 0.28 150. 92 427. 99 490.84 -0.15 1.87 1.50 -1.49 -0.06 0.34 5949120. 13 697189.80 N 70.26516406 W 148. 40553308 590.85 0.11 167. 90 527. 99 590.84 -0.33 2.21 1.80 -1.80 0.08 0.18 5949119. 83 697189.95 N 70.26516322 W 148. 40553195 690.85 0.24 259. 77 627 .99 690.84 -0.17 2.47 1.94 -1.93 -0.10 0.27 5949119. 69 697189.77 N 70.26516286 W 148. 40553346 790.85 0.59 176. 81 727 .99 790.84 -0.07 3.09 2.50 -2.48 -0.28 0.61 5949119. 14 697189.60 N 70.26516135 W 148. 40553489 890.85 0.22 135. 59 827 .99 890.84 -0.32 3.77 3.14 -3.14 -0.12 0.45 5949118. 49 697189.78 N 70.26515957 W 148. 40553 990.85 0.12 93. 07 927 .99 990.84 -0.58 4.06 3.28 -3.28 0.12 0.15 5949118. 36 697190.03 N 70.26515918 W 148. 3 4055 1090.85 0.08 292. 70 1027 .99 1090.84 -0.61 4.10 3.26 -3.26 0.16 0.20 5949118. 38 697190.07 N 70.26515924 W 148. 40553 1190.85 0.22 220 .81 1127 .99 1190.84 -0.44 4.34 3.38 -3.38 -0.03 0.21 5949118. 26 697189.88 N 70.26515892 W 148. 40553285 1290.85 0.32 106 .73 1227 .99 1290.84 -0.61 4.68 3.60 -3.60 0.11 0.46 5949118. 03 697190.03 N 70.26515830 W 148. 40553171 1390.85 0.44 105 .16 1327 .98 1390.83 -1.27 5.34 3.86 -3.78 0.75 0.12 5949117. 87 697190.67 N 70.26515781 W 148. 40552655 1490.85 0.56 120 .40 1427 .98 1490.83 -2.10 6.21 4.41 -4.13 1.54 0.18 5949117. 54 697191.47 N 70:26515686 W 148. 40552014 1590.85 0.98 108 .59 1527 .97 1590.82 -3.40 7.55 5.41 -4.65 2.78 0.45 5949117. 06 697192.72 N 70.26515544 W 148. 40551018 1690.85 0.93 108 .74 1627 .96 1690.81 -5.03 9.21 6.77 -5.18 4.35 0.05 5949116 .56 697194.31 N 70.26515398 W 148. 40549742 1790.85 0.76 109 .60 1727 .95 1790.80 -6.48 10.69 8.07 -5.67 5.75 0.17 5949116 .12 697195.71 N 70.26515266 W 148. 40548615 1890.85 1.17 104 .60 1827 .93 1890.78 -8.14 12.37 9.59 -6.15 7.36 0.42 5949115 .68 697197.34 N 70.26515135 W 148. 40547312 1990.85 0.74 79 .10 1927 .92 1990.77 -9.77 14.01 10.96 -6.28 8.98 0.59 5949115 .59 697198.96 N 70.26515098 W 148 .40546000 2090.85 0.53 66 .75 2027 .91 2090.76 -10.78 15.12 11.69 -5.98 10.04 0.25 5949115 .92 697200.01 N 70.26515181 W 148 .40545144 SurveyEditor Ver SP 2.1 Bld( doc4Ox_1OO) 05-35\05-35\05-35A\05-35A Generated 10/8/2008 11:36 AM Page 1 of 6 2190.85 0.93 56. 09 2127.90 2190.75 -11. 78 16. 39 12.35 -5. 34 11. 14 0.42 5949116. 58 697201.10 N 70.26515355 W 148. 40544256 2290.85 0.72 56. 09 2227.89 2290.74 -12. 85 17. 83 13.14 -4. 54 12. 34 0.21 5949117. 42 697202.27 N 70.26515574 W 148. 40543290' 2390.85 0.52 47. 65 2327.89 2390.74 -13. 60 18. 91 13.75 -3. 88 13. 19 0.22 5949118. 10 697203.11 N 70.26515753 W 148. 40542597 2490.85 0.38 44. 07 2427.89 2490.74 -14. 09 19. 69 14.16 -3. 34 13. 76 0.14 5949118. 65 697203.66 N 70.26515902 W 148. 40542140 2590.85 4.09 321. 82 2527.80 2590.65 -11. 71 23. 37 11.79 -0. 29 11. 78 4.06 5949121. 64 697201.61 N 70.26516733 W 148. 40543736 2690.85 8.60 315. 62 2627.16 2690.01 -3. 21 34. 41 8.98 7. 86 4. 35 4.56 5949129. 60 697193.96 N 70.26518960 W 148. 40549749 2790.85 9.95 311. 92 2725.85 2788.70 9. 88 50. 52 20.33 18. 97 -7. 31 1.48 5949140. 40 697182.01 N 70.26521997 W 148. 40559174 2890.85 13.77 301. 27 2823.71 2886.56 27. 99 71. 01 39.10 30. 93 -23. 92 4.39 5949151. 92 697165.10 N 70.26525263 W 148. 40572601 2990.85 15.60 300. 04 2920.44 2983.29 51. 39 96. 36 63.35 43. 84 -45. 74 1.86 5949164. 25 697142.95 N 70.26528790 W 148. 40590237 3090.85 17.49 290. 82 3016.31 3079.16 78. 51 124. 78 90.71 55. 91 -71. 43 3.23 5949175. 65 697116.96 N 70.26532089 W 148. 40611007 3190.85 19.09 288. 71 3111.26 3174.11 109 .24 156. 16 120.90 66. 50 -100. 96 1.73 5949185. 46 697087.15 N 70.26534981 W 148. 40634886 3290.85 23.61 291. 51 3204.37 3267.22 144 .80 192. 55 156.55 79. 10 -135. 10 4.63 5949197. 16 697052.70 N 70.26538422 W 148. 40662484 3390.85 24.51 292. 20 3295.69 3358.54 184 .38 233. 32 196.97 94. 28 -172. 94 0.94 5949211. 34 697014.48 N 70.26542569 W 148. 40693 3490.85 29.10 295. 50 3384.92 3447.77 227 .70 278. 39 241.92 112. 59 -214. 12 4.82 5949228. 57 696972.84 N 70.26547573 W 148. 0 40726 3590.85 29.92 295. 03 3471.95 3534.80 274 .74 327. 65 291.13 133. 61 -258. 66 0.85 5949248. 42 696927.76 N 70.26553315 W 148. 40762' 3690.85 33.46 292. 17 3557.03 3619.88 325 .33 380. 16 343.55 154. 58 -306. 81 3.84 5949268. 11 696879.09 N 70.26559041 W 148. 40801300 Tie-In Survey 3790.85 35.05 292. 40 3639.68 3702.53 379 .88 436. 45 399.69 175. 92 -358. 89 1.60 5949288. 08 696826.47 N 70.26564873 W 148. 40843406 TOW (Inc+Trend) 3861.00 34.77 292. 45 3697.21 3760.06 418 .76 476. 59 439.76 191. 24 -396. 00 0.40 5949302. 42 696788.97 N 70.26569056 W 148. 40873408 BOW 3875.00 35.96 290. 39 3708.62 3771.47 426 .64 484. 70 447.84 194. 19 -403. 54 12.03 5949305. 18 696781.35 N 70.26569864 W 148. 40879506 3916.80 39.51 290. 30 3741.68 3804.53 451 .63 510. 27 473.31 203. 09 -427. 52 8.49 5949313. 44 696757.15 N 70.26572292 W 148. 40898896 4012.54 43.35 280. 30 3813.53 3876.38 514 .31 573. 52 535.58 219. 55 -488. 51 7.98 5949328. 30 696695.76 N 70.26576790 W 148. 40948200 MWD+IFR+MS 4108.98 44.25 275. 42 3883.15 3946.00 581 .02 640. 25 599.88 228. 65 -554. 59 3.62 5949335. 67 696629.46 N 70.26579275 W 148. 41001628 4203.30 40.91 274. 65 3952.59 4015.44 644 .74 704. 06 661.06 234. 27 -618. 16 3.58 5949339. 61 696565.78 N 70.26580807 W 148. 41053014 4298.98 39.48 275. 03 4025.68 4088.53 706 .40 765. 81 720.64 239. 47 -679 .68 1.52 5949343. 21 696504.14 N 70.26582228 W 148. 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692576.18 N 70.27012536 W 148 .44247000 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 05-35\05-35\05-35A\05-35A Generated 1 0/8/2008 1 1:36 AM Page 4 of 6 11348.04 87.07 11379.67 88.99 11411. 99 89.13 11444. 15 89.10 11475. 84 89.44 11506. 23 91.22 11539. 31 92.08 11570. 98 93.04 11603. 31 92.70 11634. 97 93.94 11666. 60 94.49 11698. 64 93.08 11731. 01 92.94 11763 .23 91.84 11794 .20 92.08 11826 .65 92.18 11858 .93 92.80 11890 .09 92.91 11922 .32 92.63 11953 .93 93.04 11985 .55 93.56 12017 .69 93.15 12049 .72 91.91 12081 .03 89.15 12113 .13 88.92 12145 .51 89.13 12177 .11 89.37 351.94 352.48 354.73 354.67 354.14 354.76 355.86 355.78 355.65 355.57 355.92 356.28 355.31 353.85 352.01 351.44 348.37 8878.51 8941.36 8879.60 8942.45 8880.13 8942.98 8880.63 8943.48 8881.03 8943.88 8880.86 8943.71 8879.90 8942.75 8878.49 8941.34 8876.87 8939.72 8875.04 8937.89 8872.71 8935.56 8870.60 8933.45 4785.31 4793.91 4801.95 4809.34 4816.79 4823.91 4831.18 4837.85 4844.72 4851.50 4858.20 4864.79 8868.90 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8906.86 8905.63 4916.61 4927.53 4939.53 4952.56 4966.19 4980.52 4995.58 5012.35 5030.56 5048.99 5491.74 4931.74 5523.35 4947.52 5555.66 4963.12 5587.82 4978.27 5619.51 4993.50 5649.89 5008.23 5682.96 5023.98 5714.60 5038.96 5746.89 5054.46 5778.49 5069.84 5810.04 5085.27 5842.01 5100.89 6033.27 6065.47 6097.04 6128.60 6160.69 6192.69 6223.99 6256.09 6288.46 6320.06 5116.98 5133.75 5150.76 5169.28 5188.66 5208.07 5228.43 5249.55 5271.59 5294.40 5317.80 5341.56 5366.97 5393.57 5420.04 1847.22 -4572.73 1878.54 -4577.01 1910.65 -4580.61 1942.67 -4583.58 1974.20 -4586.67 2004.45 -4589.61 2037.40 -4592.32 2068.96 -4594.62 2101.16 -4597.03 2132.67 -4599.45 2164.13 -4601.79 2196.02 -4603.97 2228.26 -4606.34 2260.31 -4609.38 2291.02 -4613.19 2323.11 -4617.86 2354.86 -4623.51 2385.36 -4629.69 2416.87 -4636.29 2447.45 -4644.11 2477.73 -4653.01 2508.39 -4662.47 2538.72 -4672.68 2567.99 -4683.77 2597.42 -4696.57 2626.46 -4710.87 2654.44 -4725.55 5068.07 6352.48 5447.38 2683.05 -4740.80 5086.78 6384.16 5474.19 2710.97 -4755.77 5105.32 6415.80 5500.91 2738.94 -4770.56 5124.16 6448.29 5528.28 2767.77 -4785.53 5142.20 6479.68 5554.67 2795.72 -4799.82 5160.14 6510.85 5178.64 6543.01 5197.10 6574.72 5215.97 6606.75 5234.67 6639.03 5253.07 6670.69 5272.11 6702.82 5290.81 6734.46 5309.50 6766.37 5327.89 6798.34 5580.94 5608.09 5635.06 5662.49 5689.98 5717.03 5744.76 5772.09 5799.58 5826.96 2823.45 -4814.04 2852.08 -4828.70 2880.18 -4843.40 2908.44 -4858.48 2937.09 -4873.33 2965.17 -4887.97 2993.46 -4903.22 3021.32 -4918.19 3049.54 -4933.10 3077.99 -4947.67 5346.18 6830.09 5854.22 3106.24 -4962.17 4.77 5950848.34 6.31 5950879.54 6.97 5950911.54 0.21 5950943.47 1.99 5950974.91 6.20 5951005.07 4.22 5951037.94 3.04 5951069.42 1.13 5951101.55 3.92 5951132.98 2.06 5951164.37 4.54 5951196.19 692570.54 692565.44 692561.00 692557.19 692553.28 692549.55 692545.98 692542.85 692539.60 692536.35 692533.19 692530.18 N 70.27021083 W 148.44250914 N 70.27029638 W 148.44254394 N 70.27038410 W 148.44257320 N 70.27047157 W 148.44259738 N 70.27055772 W 148.44262251 N 70.27064035 W 148.44264643 N 70.27073037 W 148.44266845 N 70.27081657 W 148.44268726 N 70.27090453 W 148.44270693 N 70.27099062 W 148.44272665 N 70.27107656 W 148.44274573 N 70.27116369 W 148.44276347 3.02 5951228.35 692526.97 N 70.27125176 W 148.4427 5.67 5951260.31 692523.09 N 70.27133930 W 148.4428 5.99 5951290.91 692518.48 N 70.27142321 W 148.44283 1.78 5951322.87 692512.97 N 70.27151087 W 148.44287640 9.69 5951354.45 692506.49 N 70.27159759 W 148.44292226 1.18 5951384.78 692499.51 N 70.27168091 W 148.44297240 3.55 5951416.10 692492.09 N 70.27176697 W 148.44302595 12.39 5951446.47 692483.47 N 70.27185050 W 148.44308932 1.75 5951476.51 692473.78 N 70.27193323 W 148.44316148 4.29 5951506.91 692463.52 N 70.27201697 W 148.44323810 6.34 5951536.95 692452.53 N 70.27209980 W 148.44332081 12.26 5951565.92 692440.68 N 70.27217975 W 148.44341063 8.94 5951595.00 692427.11 N 70.27226013 W 148.44351431 7.96 5951623.66 692412.05 N 70.27233944 W 148.44363014 1.32 5951651.24 692396.64 N 70.27241586 W 148.44374899 5.98 5951679.44 692380.65 N 70.27249398 W 148.44387248 0.74 5951706.96 692364.95 N 70.27257023 W 148.44399369 1.89 5951734.53 692349.44 N 70.27264663 W 148.44411344 1.34 5951762.95 692333.72 N 70.27272536 W 148.44423464 1.21 5951790.52 692318.70 N 70.27280169 W 148.4443 1.72 5951817.87 692303.76 N 70.27287743 W 148.44446553 1.97 5951846.10 692288.36 N 70.27295562 W 148.44458420 5.56 5951873.81 692272.93 N 70.27303237 W 148.44470319 2.14 5951901.66 692257.12 N 70.27310953 W 148.44482532 2.45 5951929.91 692241.52 N 70.27318779 W 148.44494560 3.31 5951957.60 692226.15 N 70.27326448 W 148.44506412 3.76 5951985.47 692210.17 N 70.27334171 W 148.44518758 2.76 5952012.93 692194.47 N 70.27341782 W 148.44530881 0.20 5952040.75 692178.83 N 70.27349488 W 148.44542955 4.52 5952068.81 692163.52 N 70.27357258 W 148.44554756 5.56 5952096.67 692148.28 N 70.27364974 W 148.44566498 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 05-35\05-35\05-35A\05-35A Generated 1 0/8/2008 1 1:36 AM Page 5 of 6 12719.48 92.01 331.82 8841.72 8904.57 5365.10 6862.23 5882.10 3134.60 -4977.28 1.08 5952124 .62 692132.44 N 70. 27372718 W 148 .44578736 12751.01 92.36 331.89 8840.52 8903.37 5383.68 6893.73 5909.50 3162.38 -4992.15 1.13 5952152 .00 692116.85 N 70. 27380305 W 148 .44590771 12782.75 92.67 333.77 8839.13 8901.98 5401.94 6925.44 5936.85 3190.59 -5006.62 6.00 5952179 .82 692101.64 N 70. 27388009 W 148 .44602496 12814.51 91.67 333.53 8837.93 8900.78 5419.85 6957.18 5964.03 3219.03 -5020.71 3.24 5952207 .87 692086.81 N 70. 27395776 W 148 .44613904 12845.85 91.57 333.14 8837.04 8899.89 5437.67 6988.51 5991.00 3247.03 -5034.77 1.28 5952235 .49 692072.03 N 70. 27403421 W 148 .44625290 12878.22 92.12 334.81 8836.00 8898.85 5455.77 7020.86 6018.71 3276.10 -5048.96 5.43 5952264 .18 692057.08 N 70. 27411361 W 148 .44636786 12910.43 92.36 335.07 8834.74 8897.59 5473.33 7053.05 6046.04 3305.25 -5062.60 1.10 5952292 .97 692042.69 N 70. 27419324 W 148 .44647828 12941.66 92.56 334.96 8833.40 8896.25 5490.32 7084.25 6072.56 3333.53 -5075.78 0.73 5952320 .89 692028.77 N 70. 27427047 W 148 .44658502 Last Survey 12945.94 92.53 334.72 8833.21 8896.06 5492.66 7088.52 6076.20 3337.40 -5077.59 5.65 5952324 .71 692026.85 N 70. 27428104 W 148 .44659975 TD (Projected) 13000.00 92.53 334.72 8830.82 8893.67 5522.29 7142.53 6122.36 3386.24 -5100.66 0.00 5952372 .92 692002.52 N 70. 27441442 W 148 .44678655 Survey Type: Definitive Survey NOTES: GCT MS - (Schlumberger GCT multishot -- GCT surveys in casing or open hole. GCT = "Gyro Continuous Tool".) GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees incli nation.) INC+TREND - (Inclinometer + known azi trend --Inclination only surveys in near-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azim uth in known quadrant)" model. ) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Leaal Description: Northing (Yl I ftUSI Easting (X) (ftUSI Surface : 2956 FSL 5156 FEL S32 Ti 1 N R15E UM 5949121.63 697189.82 BHL : 1060 FSL 4965 FEL S30 T11 N R15E UM 5952372.92 692002.52 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 05-35\05-35\05-35A\05-35A Generated 1 0/8/2008 1 1:36 AM Page 6 of 6 /ELLHEADs= ' FMC • O 5 _3 5A CTUATOR = AXELSON B. ELEV = 72' F. EL EV = oP= DRL~ ~3RAFT lax Angle = 95° @ 11029' atum MD = 10429' atum TV D = 8800' SS Minimum ID = 3.725" @ 9508' 4-1/2" HES XN NIPPLE 9-5/8" WHIPSTOCK - 29~Tr ~8~~ 9-5/8" EZSV - 3885 ~ 7" CASING CUT -4999 ST TOC BEHIND 7" BASED ON 30% WASHOUT - -4000' 9-5/8" CSG, 36#, J-55, ID = 8.921" 4023' TUBING CUT - 4z~@@' SQUEEZE TOC -47$6' TUBING PUNCH - X20' CMT Retainer 6~zFi CTMD TUBING PATCH 6148' 17x4" PKR - 9,415' I/ TOP OF 5" LNR 9470' 7" CSG, 26#, L-80, ID = 6.276" I-j 9787' PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: 87° @ 11290' Nnta~ Rafar to Prnriuctinn DB for historical oerf data SIZE SPF INTERVAL Opn/Sqz DATE 2 7/8 6 11290-11430 O 09/12/08 2 7/8 6 11630-11890 O 09/12/08 2 7/8 6 11990-12910 0 09!12/08 PBTD I~ 10550' LNR, 15#, 13-CR, .0178 bpf, ID = 4.408" 10592' 10597' f 8?7y SAFETY NOTES: CHROM E TBG 2204' - 4-1/2" X Nipple (3.813" ID) r A S I IFf" MA NDRFL S ST MD TVD DEV TYPE VLV LATCH PORT DATI 2 1 3775 6401 3690 5739 35 42 KBG2 KBB2 DCK DMY BEK BK 0 0 09/12/ 09/12/ -3,861 Top of window' -9,351' - 4-112" TBG, 12.6# 13CR VAMTOP 9371' - 4-1/2" X Nipple (3.813" ID) 9,402' - 7" X 4-1/2" BKR Packer 9,435' - 4-1/2" X Nipple (3.813" ID) 9,508' 4-1/2" XN nipple (3.725" ID) 9510' - 7" X 4-1/2" BKR PKR/HGR 9,519' - 4-1/2" WLEG 9676' - 7" 26# L-80 BTC-M (PREM THREAD FM TOC TO SURFACE) 12,999' - 4-1/2" 12.6# L-80 IBT-M SOLID, PERFORATED LINER DATE REV BY COMMENTS DATE REV BY COMMENTS 06/19/91 ORIGINAL COMPLETION 08/13/08 JER PROPOSED RIG ST 11/21/00 SIS-SLT CONVERTED TO CANVAS 09/14/08 MED POST RIG - 7ES 02/09/01 SIS-LG REVISION 08/12/01 RN/KAK CORRECTIONS 06/05/02 CORRECT CORRUPTED FILE PRUDHOE BAY UNIT WELL: 05-35A PERMIT No: 191-068 API No: 50-029-22172-01 SEC 32, T11 N, R15E 3999.28 FEL 241.79 FNL BP Exploration (Alaska) SCHLUMBERGER Survey report Client .................... Field ..................... Well ...................... API number ...............: Engineer .................. COUNTY :................... STATE :...................: ----- Survey calculation m Method for positions.....: Method for DLS...........: BP Exploration Alaska Inc Prudhoe Bay 05-35A 50-029-22172-01 E. Galotta NSB Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Depth GL above permanent.......: 34.50 ft KB above permanent.......: N/A ft DF above permanent.......: 62.8 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 278.00 degrees (v O© [(c)2008 IDEAL ID13_OC_10] f .-~ 10-Sep-2008 01:45:40 Page 1 of 8 Spud date ................: 28-Aug-08 Last survey date.........: 10-Sep-08 Total accepted surveys...: 206 MD of first survey.......: 0.00 ft MD of last survey........: 13000.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2008 Magnetic date ............: 28-Aug-2008 Magnetic field strength..: 57690.28 GAMA Magnetic dec (+E/W-).....: 23.19 degrees Magnetic dip .............: 80.92 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............. Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.00 meal 57690.50 GAMA 80.92 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.19 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.19 degrees (Total az corr = magnetic dec - grid cony) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction 5=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • SCHLUMBERGER Survey Report 10-Sep-2008 01:45:40 Page 2 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 1 -------- 0.00 ------ 0.00 ------- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP_ GCT MS 2 28.65 0.00 0.00 28.65 28.65 0.00 0.00 0.00 0.00 0.00 0.00 BP_ GCT MS 3 90.85 0.22 132.33 62.20 90.85 -0.10 -0.08 0.09 0.12 132.33 0.35 BP_ GCT MS 4 190.85 0.12 325.41 100.00 190.85 -0.19 -0.12 0.17 0.21 125.87 0.34 BP_ GCT MS 5 290.85 0.25 234.81 100.00 290.85 0.04 -0.16 -0.07 0.18 202.34 0.28 BP_ GCT MS 6 390.85 0.57 175.95 100.00 390.85 0.10 -0.78 -0.21 0.81 194.99 0.49 BP_ GCT MS 7 490.85 0.28 150.92 100.00 490.84 -0.15 -1.49 -0.06 1.50 182.16 0.34 BP_ GCT • MS 8 590.85 0.11 167.90 100.00 590.84 -0.33 -1.80 0.08 1.80 177.37 0.18 BP_ GCT MS 9 690.85 0.24 259.77 100.00 690.84 -0.17 -1.93 -0.10 1.94 183.06 0.27 BP_ GCT MS 10 790.85 0.59 176.81 100.00 790.84 -0.07 -2.48 -0.28 2.50 186.45 0.61 BP_ GCT MS 11 890.85 0.22 135.59 100.00 890.84 -0.32 -3.14 -0.12 3.14 182.15 0.45 BP_ GCT MS 12 990.85 0.12 93.07 100.00 990.84 -0.58 -3.28 0.12 3.28 177.88 0.15 BP_ GCT MS 13 1090.85 0.08 292.70 100.00 1090.84 -0.61 -3.26 0.16 3.26 177.17 0.20 BP_ GCT MS 14 1190.85 0.22 220.81 100.00 1190.84 -0.44 -3.38 -0.03 3.38 180.49 0.21 BP _GCT MS 15 1290.85 0.32 106.73 100.00 1290.84 -0.61 -3.60 0.11 3.60 178.20 0.46 BP _GCT MS 16 1390.85 0.44 105.16 100.00 1390.83 -1.27 -3.78 0.75 3.86 168.76 0.12 BP _GCT MS 17 1490.85 0.56 120.40 100.00 1490.83 -2.10 -4.13 1.54 4.41 159.51 0.18 BP _GCT MS 18 1590.85 0.98 108.59 100.00 1590.82 -3.40 -4.65 2.78 5.41 149.16 0.45 BP _GCT MS 19 1690.85 0.93 108.74 100.00 1690.81 -5.03 -5.18 4.35 6.77 139.96 0.05 BP _GCT MS 20 1790.85 0.76 109.60 100.00 1790.80 -6.48 -5.67 5.75 8.07 134.59 0.17 BP _GCT MS 21 1890.85 1.17 104.60 100.00 1890.78 -8.14 -6.15 7.36 9.59 129.86 0.42 BP _GCT MS 22 1990.85 0.74 79.10 100.00 1990.77 -9.77 -6.28 8.98 10.96 124.96 0.59 BP _GCT M5 23 2090.85 0.53 66.75 100.00 2090.76 -10.78 -5.98 10.04 11.69 120.76 0.25 BP _GCT MS 24 2190.85 0.93 56.09 100.00 2190.75 -11.78 -5.34 11.14 12.35 115.61 0.42 BP _GCT MS 25 2290.85 0.72 56.09 100.00 2290.74 -12.85 -4.54 12.34 13.14 110.20 0.21 BP _GCT MS 26 2390.85 0.52 47.65 100.00 2390.74 -13.60 -3.88 13.19 13.75 106.40 0.22 BP _GCT MS 27 2490.85 0.38 44.07 100.00 2490.73 -14.09 -3.34 13.76 14.16 103.64 0.14 BP _GCT MS 28 2590.85 4.09 321.82 100.00 2590.65 -11.71 -0.29 11.78 11.79 91.43 4.06 BP _GCT MS 29 2690.85 8.60 315.62 100.00 2690.01 -3.21 7.86 4.35 8.98 28.95 4.56 BP _GCT MS 30 2790.85 9.95 311.92 100.00 2788.70 9.88 18.97 -7.31 20.33 338.92 1.48 BP _GCT MS [(c)2008 IDEAL ID13_OC_10] SCHLUI"IBERGER Survey Report 10-Sep-2008 01:45:40 Page 3 of 8 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD -- Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 31 -------- 2890.85 ------ 13.77 ------- 301.27 ------ 100.00 -- 2886.56 27.99 30.93 -23.92 39.10 322.28 4.39 BP_ GCT MS 32 2990.85 15.60 300.04 100.00 2983.29 51.39 43.84 -45.74 63.35 313.79 1.86 BP_ GCT MS 33 3090.85 17.49 290.82 100.00 3079.16 78.51 55.91 -71.43 90.71 308.05 3.23 BP_ GCT MS 34 3190.85 19.09 288.71 100.00 3174.11 109.24 66.50 -100.96 120.90 303.37 1.73 BP_ GCT MS 35 3290.85 23.61 291.51 100.00 3267.22 144.80 79.10 -135.10 156.55 300.35 4.63 BP_ GCT MS 36 3390.85 24.51 292.20 100.00 3358.53 184.38 94.28 -172.94 196.97 298.60 0.94 BP_ GCT MS 37 3490.85 29.10 295.50 100.00 3447.77 227.70 112.59 -214.12 241.92 297.74 4.82 BP_ GCT MS 38 3590.85 29.92 295.03 100.00 3534.80 274.74 133.61 -258.66 291.13 297.32 0.85 BP_ GCT MS 39 3690.85 33.46 292.17 100.00 3619.88 325.33 154.58 -306.81 343.55 296.74 3.84 BP_ GCT MS 40 3790.85 35.05 292.40 100.00 3702.53 379.88 175.92 -358.89 399.69 296.11 1.60 BP_ GCT MS 41 3861.00 34.77 292.45 70.15 3760.06 418.76 191.24 -396.00 439.76 295.78 0.40 BP_ GCT MS 42 3875.00 35.96 290.39 14.00 3771.47 426.64 194.19 -403.54 447.84 295.70 12.03 BP_ BLIND 43 3916.80 39.51 290.30 41.80 3804.53 451.63 203.09 -427.52 473.31 295.41 8.49 BP_ INC+TREND 44 4012.54 43.35 280.30 95.74 3876.37 514.31 219.55 -488.51 535.58 294.20 7.98 BP_ INC+TREND 45 4108.98 44.25 275.42 96.44 3946.00 581.02 228.65 -554.59 599.88 292.41 3.62 BP _MWD+IFR+MS 46 4203.30 40.91 274.65 94.32 4015.44 644.74 234.27 -618.16 661.06 290.76 3.58 BP _MWD+IFR+MS 47 4298.98 39.48 275.03 95.68 4088.53 706.40 239.47 -679.68 720.64 289.41 1.52 BP _MWD+IFR+MS 48 4394.96 36.80 273.56 95.98 4164.01 765.54 243.93 -738.78 778.01 288.27 2.95 BP _MWD+IFR+MS 49 4490.44 37.11 271.70 95.48 4240.31 822.69 246.56 -796.12 833.43 287.21 1.22 BP _MWD+IFR+MS 50 4585.32 37.83 273.58 94.88 4315.62 880.15 249.23 -853.77 889.40 286.27 1.42 BP _MWD+IFR+MS 51 4681.03 37.24 275.94 95.71 4391.52 938.36 254.06 -911.87 946.60 285.57 1.62 BP _MWD+IFR+MS • 52 4776.68 36.63 272.85 95.65 4467.98 995.70 258.47 -969.16 1003.04 284.93 2.04 BP _MWD+IFR+MS 53 4872.13 38.76 276.77 95.45 4543.51 1053.95 263.41 -1027.29 1060.52 284.38 3.36 BP _MWD+IFR+MS 54 4967.53 38.24 275.41 95.40 4618.17 1113.30 269.72 -1086.34 1119.32 283.94 1.04 BP _MWD+IFR+MS 55 5062.97 37.88 273.81 95.44 4693.32 1172.03 274.45 -1144.98 1177.41 283.48 1.10 BP _MWD+IFR+MS 56 5159.41 38.92 279.28 96.44 4768.92 1231.87 281.30 -1204.44 1236.85 283.15 3.68 BP _MWD+IFR+MS 57 5253.29 38.61 277.96 93.88 4842.12 1290.64 290.12 -1262.55 1295.45 282.94 0.94 BP _MWD+IFR+MS 58 5350.00 38.84 279.84 96.71 4917.57 1351.13 299.48 -1322.32 1355.80 282.76 1.24 BP _MWD+IFR+MS 59 5446.10 38.39 278.93 96.10 4992.66 1411.08 309.26 -1381.49 1415.68 282.62 0.75 BP _MWD+IFR+MS 60 5538.57 38.07 277.06 92.47 5065.30 1468.30 317.22 -1438.15 1472.72 282.44 1.30 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_10] SCHLUMBERGER Survey Report 10 -Sep-2008 01:45:40 Page 4 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5632.66 37.82 277.63 94.09 5139.50 1526.15 324.62 -1495.53 1530.35 282.25 0.46 BP _MWD+IFR+MS 62 5723.89 37.51 278.62 91.23 5211.72 1581.89 332.49 -1550.71 1585.96 282.10 0.75 BP _MWD+IFR+MS 63 5822.40 37.32 277.91 98.51 5289.96 1641.75 341.10 -1609.94 1645.68 281.96 0.48 BP _MWD+IFR+MS 64 5923.53 37.91 276.89 101.13 5370.07 1703.47 349.04 -1671.15 1707.21 281.80 0.85 BP _MWD+IFR+MS 65 6019.27 37.68 277.95 95.74 5445.73 1762.13 356.62 -1729.33 1765.72 281.65 0.72 BP _MWD+IFR+MS 66 6113.88 37.63 276.31 94.61 5520.63 1819.92 363.79 -1786.68 1823.34 281.51 1.06 BP _MWD+IFR+MS 67 6209.97 40.56 278.95 96.09 5595.20 1880.50 371.88 -1846.71 1883.78 281.39 3.51 BP _MWD+IFR+MS • 68 6308.58 41.05 278.31 98.61 5669.85 1944.93 381.55 -1910.42 1948.15 281.29 0.65 BP _MWD+IFR+MS 69 6402.83 41.52 281.11 94.25 5740.68 2007.08 392.04 -1971.70 2010.30 281.25 2.02 BP _MWD+IFR+MS 70 6498.16 41.36 278.31 95.33 5812.15 2070.13 402.68 -2033.88 2073.36 281.20 1.95 BP _MWD+IFR+MS 71 6598.01 42.11 280.25 99.85 5886.66 2136.57 413.41 -2099.47 2139.78 281.14 1.50 BP _MWD+IFR+MS 72 6689.42 40.56 281.00 91.41 5955.29 2196.88 424.53 -2158.81 2200.15 281.13 1.78 BP _MWD+IFR+MS 73 6785.38 39.69 281.43 95.96 6028.67 2258.62 436.56 -2219.47 2261.99 281.13 0.95 BP _MWD+IFR+MS 74 6880.21 37.95 280.71 94.83 6102.55 2317.98 447.98 -2277.80 2321.44 281.13 1.90 BP _M[nID+IFR+MS 75 6975.18 37.77 281.37 94.97 6177.53 2376.19 459.14 -2335.01 2379.72 281.12 0.47 BP _MWD+IFR+MS 76 7071.18 38.04 280.97 96.00 6253.28 2435.07 470.56 -2392.87 2438.70 281.13 0.38 BP _MWD+IFR+MS 77 7164.48 37.50 280.12 93.30 6327.03 2492.16 481.02 -2449.05 2495.84 281.11 0.80 BP _MWD+IFR+MS 78 7263.08 38.27 281.31 98.60 6404.85 2552.64 492.29 -2508.54 2556.39 281.10 1.08 BP _MWD+IFR+MS 79 7362.18 38.59 278.76 99.10 6482.49 2614.18 503.01 -2569.18 2617.96 281.08 1.63 BP _MWD+IFR+MS 80 7453.01 38.97 279.99 90.83 6553.29 2671.05 512.28 -2625.31 2674.82 281.04 0.95 BP _MWD+IFR+MS 81 7549.06 37.48 279.57 96.05 6628.75 2730.45 522.38 -2683.87 2734.24 281.01 1.57 BP _MWD+IFR+MS • 82 7645.65 38.17 277.02 96.59 6705.05 2789.68 530.91 -2742.48 2793.39 280.96 1.77 BP _MWD+IFR+MS 83 7739.22 37.23 274.37 93.57 6779.09 2846.84 536.61 -2799.40 2850.37 280.85 2.00 BP _MWD+IFR+MS 84 7831.48 36.73 276.62 92.26 6852.79 2902.28 541.91 -2854.64 2905.62 280.75 1.56 BP _MWD+IFR+MS 85 7929.06 35.48 273.83 97.58 6931.63 2959.70 547.17 -2911.88 2962.85 280.64 2.12 BP _MWD+IFR+MS 86 8026.63 36.03 274.10 97.57 7010.81 3016.57 551.11 -2968.76 3019.48 280.52 0.59 BP _MWD+IFR+MS 87 8121.29 36.03 275.49 94.66 7087.37 3072.16 555.77 -3024.24 3074.88 280.41 0.86 BP _MWD+IFR+MS 88 8218.54 36.94 278.38 97.25 7165.56 3129.96 562.76 -3081.63 3132.59 280.35 2.00 BP _MWD+IFR+MS 89 8312.92 35.43 276.82 94.38 7241.74 3185.67 570.14 -3136.85 3188.24 280.30 1.87 BP _MWD+IFR+MS 90 8407.54 36.41 279.13 94.62 7318.37 3241.17 577.86 -3191.81 3243.70 280.26 1.77 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_10] SCHLUMBERGER Survey Report 10-Sep-2008 01:45:40 Page 5 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8498.84 37.54 278.71 91.30 7391.30 3296.08 586.37 -3246.06 3298.60 280.24 1.27 BP _MWD+IFR+MS 92 8599.28 36.16 278.55 100.44 7471.68 3356.31 595.41 -3305.61 3358.81 280.21 1.38 BP _MWD+IFR+MS 93 8689.88 38.08 283.08 90.60 7543.93 3410.88 605.71 -3359.27 3413.45 280.22 3.69 BP _MWD+IFR+MS 94 8791.15 35.93 282.45 101.27 7624.80 3471.62 619.18 -3418.72 3474.34 280.27 2.16 BP _MWD+IFR+MS 95 8887.43 34.91 280.74 96.28 7703.26 3527.30 630.41 -3473.37 3530.11 280.29 1.48 BP MWD+IFR+MS 96 8981.83 34.46 277.31 94.40 7780.89 3580.99 638.84 -3526.40 3583.80 280.27 2.12 BP MWD+IFR+MS 97 9078.63 35.74 279.63 96.80 7860.09 3636.64 647.06 -3581.44 3639.43 280.24 1.91 BP _ _MWD+IFR+MS 98 9175.63 36.44 279.65 97.00 7938.47 3693.76 656.62 -3637.78 3696.56 280.23 0.72 BP _MWD+IFR+MS 99 9268.53 36.80 277.61 92.90 8013.04 3749.16 664.93 -3692.56 3751.95 280.21 1.37 BP _MWD+IFR+MS 100 9364.73 38.36 280.51 96.20 8089.28 3807.81 674.20 -3750.48 3810.59 280.19 2.45 BP MWD+IFR+MS 101 9461.13 39.06 280.46 96.40 8164.50 3868.04 685.17 -3809.75 3870.88 280.20 0.73 BP _MWD+IFR+MS 102 9555.79 37.77 278.09 94.66 8238.67 3926.83 694.66 -3867.79 3929.68 280.18 2.07 BP _MWD+IFR+MS 103 9617.19 37.05 278.66 61.40 8287.45 3964.13 700.09 -3904.69 3966.96 280.16 1.30 BP _MWD+IFR+MS 104 9699.32 36.17 279.86 82.13 8353.37 4013.09 707.97 -3953.03 4015.93 280.15 1.38 BP _MWD+IFR+MS 105 9794.96 36.05 279.74 95.64 8430.64 4069.43 717.56 -4008.57 4072.29 280.15 0.15 BP MWD+IFR+MS 106 9826.43 36.61 281.56 31.47 8455.99 4088.05 721.01 -4026.89 4090.93 280.15 3.86 BP _MWD+IFR+MS 107 9858.84 37.30 281.92 32.41 8481.89 4107.49 724.97 -4045.97 4110.41 280.16 2.23 BP _MWD+IFR+MS 108 9890.76 37.84 285.61 31.92 8507.19 4126.85 729.61 -4064.87 4129.83 280.18 7.25 BP _MWD+IFR+MS 109 9921.61 37.20 285.67 30.85 8531.66 4145.47 734.67 -4082.96 4148.53 280.20 2.08 BP _MWD+IFR+MS 110 9954.75 38.02 285.03 33.14 8557.92 4165.53 740.03 -4102.46 4168.67 280.23 2.74 BP MWD+IFR+MS 111 9984.09 40.64 289.13 29.34 8580.61 4183.88 745.50 -4120.22 4187.12 280.26 12.57 BP _MWD+IFR+MS 112 10017.81 41.17 292.60 33.72 8606.10 4205.40 753.37 -4140.85 4208.82 280.31 6.92 BP _MWD+IFR+MS • 113 10048.81 42.23 297.13 31.00 8629.25 4225.12 762.04 -4159.54 4228.77 280.38 10.30 BP _MWD+IFR+MS 114 10081.85 43.15 302.24 33.04 8653.54 4245.92 773.13 -4178.99 4249.90 280.48 10.85 BP _MWD+IFR+MS 115 10112.79 43.97 306.22 30.94 8675.97 4265.03 785.13 -4196.61 4269.42 280.60 9.25 BP MWD+IFR+MS 116 10144.50 46.09 310.79 31.71 8698.38 4284.34 799.10 -4214.14 4289.24 280.74 12.19 BP _MWD+IFR+MS 117 10177.88 46.66 312.65 33.38 8721.41 4304.44 815.18 -4232.17 4309.97 280.90 4.38 BP _MWD+IFR+MS 118 10208.95 48.20 315.34 31.07 8742.43 4322.94 831.07 -4248.63 4329.15 281.07 8.08 BP _MWD+IFR+MS 119 10240.44 50.16 318.06 31.49 8763.02 4341.53 848.42 -4264.96 4348.53 281.25 9.03 BP _MWD+IFR+MS 120 10273.96 53.18 319.82 33.52 8783.81 4361.38 868.25 -4282.22 4369.36 281.46 9.91 BP MWD+IFR+MS [(0)2008 IDEAL ID13_OC_10] SCHLiTMBERGER Survey Report 10-Sep-2008 01:45:40 Page 6 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 10306.72 56.24 321.77 32.76 8802.73 4381.00 888.97 -4299.11 4390.06 281.68 10.53 BP _MWD+IFR+MS 122 10336.88 59.12 323.28 30.16 8818.86 4399.16 909.20 -4314.61 4409.37 281.90 10.44 BP _MWD+IFR+MS 123 10368.23 60.98 325.11 31.35 8834.51 4417.96 931.23 -4330.50 4429.49 282.14 7.80 BP _MWD+IFR+MS 124 10399.98 61.88 325.87 31.75 8849.69 4436.80 954.21 -4346.30 4449.81 282.38 3.53 BP _MWD+IFR+MS 125 10431.26 65.01 329.18 31.28 8863.68 4454.95 977.81 -4361.31 4469.58 282.64 13.77 BP MWD+IFR+MS 126 10462.58 127 10494.51 128 10525.81 129 10558.60 130 10590.23 131 10621.23 132 10654.51 133 10686.24 134 10710.97 135 10742.51 136 10775.20 137 10807.02 138 10838.86 139 10870.54 140 10901.98 141 10933.54 142 10965.84 143 10997.77 144 11029.12 145 11061.32 146 11092.39 147 11123.51 148 11156.92 149 11189.55 150 11220.47 66.17 330.27 31.32 8876.62 4472.61 1002.44 -4375.68 4489.04 282.90 4.87 BP MWD+IFR+MS 68.88 331.50 31.93 8888.83 4490.41 1028.21 -4390.04 4508.84 283.18 9.20 BP _ _MWD+IFR+MS 71.88 333.43 31.30 8899.34 4507.54 1054.35 -4403.66 4528.12 283.46 11.21 BP _MWD+IFR+MS 72.24 333.87 32.79 8909.44 4525.14 1082.31 -4417.50 4548.16 283.77 1.68 BP _MWD+IFR+MS 75.28 335.15 31.63 8918.28 4541.89 1109.72 -4430.57 4567.43 284.06 10.37 BP _MWD+IFR+MS 76.95 336.85 31.00 8925.72 4557.84 1137.21 -4442.81 4586.04 284.36 7.57 BP _MWD+IFR+MS 77.75 337.68 33.28 8933.01 4574.43 1167.16 -4455.36 4605.70 284.68 3.42 BP _MWD+IFR+MS 81.41 339.53 31.73 8938.75 4589.74 1196.21 -4466.73 4624.14 284.99 12.88 BP _MWD+IFR+MS 83.76 341.87 24.73 8941.94 4600.99 1219.35 -4474.84 4637.99 285.24 13.35 BP _MWD+IFR+MS 86.42 344.61 31.54 8944.64 4614.15 1249.43 -4483.90 4654.72 285.57 12.08 BP _MWD+IFR+MS 88.13 347.32 32.69 8946.19 4626.40 1281.11 -4491.81 4670.93 285.92 9.79 BP _MWD+IFR+MS 89.23 350.56 31.82 8946.93 4636.78 1312.32 -4497.92 4685.45 286.27 10.75 BP _MWD+IFR+MS 90.12 352.47 31.84 8947.11 4645.82 1343.81 -4502.61 4698.87 286.62 6.62 BP _MWD+IFR+MS 93.27 353.63 31.68 8946.17 4653.98 1375.24 -4506.44 4711.62 286.97 10.60 BP _MWD+IFR+MS 93.32 353.56 31.44 8944.36 4661.79 1406.44 -4509.95 4724.16 287.32 0.27 BP _MWD+IFR+MS 93.42 353.93 31.56 8942.51 4669.55 1437.75 -4513.38 4736.85 287.67 1.21 BP _MWD+IFR+MS • 93.28 353.84 32.30 8940.62 4677.41 1469.81 -4516.81 4749.94 288.03 0.52 BP _MWD+IFR+MS 93.08 353.21 31.93 8938.85 4685.38 1501.49 -4520.41 4763.25 288.37 2.07 BP _MWD+IFR+MS 94.59 354.55 31.35 8936.75 4693.01 1532.59 -4523.74 4776.31 288.72 6.43 BP _MWD+IFR+MS 93.22 353.09 32.20 8934.56 4700.88 1564.53 -4527.20 4789.92 289.06 6.21 BP _MWD+IFR+MS 92.91 350.74 31.07 8932.90 4709.48 1595.24 -4531.57 4804.15 289.39 7.62 BP _MWD+IFR+MS 92.12 351.67 31.12 8931.53 4718.46 1625.97 -4536.32 4818.92 289.72 3.92 BP _MWD+IFR+MS 89.17 350.60 33.41 8931.16 4728.15 1658.97 -4541.47 4834.99 290.07 9.39 BP _MWD+IFR+MS 86.89 349.55 32.63 8932.28 4738.19 1691.09 -4547.09 4851.37 290.40 7.69 BP _MWD+IFR+MS 87.00 349.74 30.92 8933.93 4747.91 1721.47 -4552.64 4867.23 290.71 0.71 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_10] SCHLUMBERGER Survey Report 10 -Sep-2008 01:45:40 Page 7 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 151 11252.46 86.45 350.56 31.99 8935.75 4757.70 1752.93 -4558.10 4883.55 291.04 3.08 BP _MWD+IFR+MS 152 11284.57 86.66 351.75 32.11 8937.68 4766.99 1784.60 -4563.03 4899.60 291.36 3.76 BP _MWD+IFR+MS 153 11316.33 86.49 350.54 31.76 8939.58 4776.18 1815.93 -4567.91 4915.63 291.68 3.84 BP _MWD+IFR+MS 154 11348.04 87.07 351.94 31.71 8941.36 4785.31 1847.22 -4572.73 4931.74 292.00 4.77 BP _MWD+IFR+MS 155 11379.67 88.99 352.48 31.63 8942.45 4793.91 1878.53 -4577.01 4947.52 292.31 6.31 BP MWD+IFR+MS 156 11411.99 89.13 354.73 32.32 8942.98 4801.94 1910.65 -4580.61 4963.12 292.64 6.97 BP MWD+IFR+MS 157 11444.15 89.10 354.67 32.16 8943.48 4809.34 1942.67 -4583.58 4978.27 292.97 0.21 BP _ _MWD+IFR+MS 158 11475.84 89.44 354.14 31.69 8943.88 4816.79 1974.20 -4586.67 4993.50 293.29 1.99 BP _MWD+IFR+MS 159 11506.23 91.22 354.76 30.39 8943.71 4823.91 2004.45 -4589.61 5008.23 293.59 6.20 BP _MWD+IFR+MS 160 11539.31 92.08 355.86 33.08 8942.75 4831.17 2037.40 -4592.31 5023.98 293.92 4.22 BP MWD+IFR+MS 161 11570.98 93.04 355.78 31.67 8941.34 4837.85 2068.96 -4594.62 5038.96 294.24 3.04 BP _MWD+IFR+MS 162 11603.31 92.70 355.65 32.33 8939.72 4844.72 2101.16 -4597.03 5054.46 294.56 1.13 BP _MWD+IFR+MS 163 11634.97 93.94 355.57 31.66 8937.89 4851.50 2132.67 -4599.45 5069.84 294.88 3.92 BP _MWD+IFR+MS 164 11666.60 94.49 355.92 31.63 8935.56 4858.20 2164.13 -4601.79 5085.27 295.19 2.06 BP _MWD+IFR+MS 165 11698.64 93.08 356.28 32.04 8933.45 4864.79 2196.02 -4603.97 5100.89 295.50 4.54 BP MWD+IFR+MS 166 11731.01 92.94 355.31 32.37 8931.75 4871.62 2228.26 -4606.34 5116.98 295.81 3.02 BP _MWD+IFR+MS 167 11763.23 91.84 353.85 32.22 8930.40 4879.09 2260.31 -4609.38 5133.75 296.12 5.67 BP _MWD+IFR+MS 168 11794.20 92.08 352.01 30.97 8929.34 4887.14 2291.02 -4613.19 5150.76 296.41 5.99 BP _MWD+IFR+MS 169 11826.65 92.18 351.44 32.45 8928.14 4896.23 2323.11 -4617.86 5169.28 296.71 1.78 BP _MWD+IFR+MS 170 11858.93 92.80 348.37 32.28 8926.73 4906.24 2354.86 -4623.51 5188.66 296.99 9.69 BP MWD+IFR+MS 171 11890.09 92.91 348.72 31.16 8925.18 4916.61 2385.36 -4629.69 5208.07 297.26 1.18 BP _MWD+IFR+MS • 172 11922.32 92.63 347.61 32.23 8923.62 4927.53 2416.87 -4636.29 5228.43 297.53 3.55 BP _MWD+IFR+MS 173 11953.93 93.04 343.71 31.61 8922.06 4939.53 2447.45 -4644.11 5249.55 297.79 12.39 BP _MWD+IFR+MS 174 11985.55 93.56 343.52 31.62 8920.24 4952.56 2477.73 -4653.01 5271.59 298.04 1.75 BP _MWD+IFR+MS 175 12017.69 93.15 342.20 32.14 8918.36 4966.19 2508.39 -4662.47 5294.40 298.28 4.29 BP MWD+IFR+MS 176 12049.72 91.91 340.59 32.03 8916.94 4980.52 2538.72 -4672.68 5317.80 298.52 6.34 BP _MWD+IFR+MS 177 12081.03 89.15 337.92 31.31 8916.65 4995.58 2567.99 -4683.76 5341.56 298.73 12.26 BP _MWD+IFR+MS 178 12113.13 88.92 335.06 32.10 8917.20 5012.35 2597.42 -4696.57 5366.97 298.94 8.94 BP _MWD+IFR+MS 179 12145.51 89.13 332.49 32.38 8917.75 5030.56 2626.46 -4710.87 5393.57 299.14 7.96 BP _MWD+IFR+MS 180 12177.11 89.37 332.15 31.60 8918.16 5048.99 2654.44 -4725.55 5420.04 299.32 1.32 BP MWD+IFR+MS [(c)2008 IDEAL ID13_OC_10] SCHLUMBERGER Survey Report 10-Sep-2008 01:45:40 Page 8 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) ------- (deg) -------- 100f) ----- type (deg) ----- ------ 181 12209.53 91.26 331.72 32.42 8917.98 5068.07 2683.05 - 4740.80 5447.38 299.51 5.98 BP_MWD+IFR+MS 182 12241.22 91.43 331.88 31.69 8917.24 5086.78 2710.97 - 4755.77 5474.19 299.68 0.74 BP_MWD+IFR+MS 183 12272.87 91.12 332.39 31.65 8916.53 5105.32 2738.94 - 4770.56 5500.91 299.86 1.89 BP_MWD+IFR+MS 184 12305.36 91.39 332.73 32.49 8915.82 5124.16 2767.77 - 4785.53 5528.28 300.04 1.34 BP_MWD+IFR+MS 185 12336.76 91.40 333.11 31.40 8915.06 5142.20 2795.72 - 4799.82 5554.67 300.22 1.21 BP MWD+IFR+MS 186 12367.94 187 12400.11 188 12431.83 189 12463.86 190 12496.14 191 12527.81 192 12559.95 193 12591.61 194 12623.55 195 12655.55 196 12687.33 197 12719.48 198 12751.01 199 12782.75 200 12814.51 201 12845.85 202 12878.22 203 12910.43 204 12941.66 205 12945.94 206 13000.00 91.53 332.59 31.18 8914.26 5160.14 2823.45 -4814.04 5580.94 300.39 1.72 BP MWD+IFR+MS 91.33 333.19 32.17 8913.46 5178.64 2852.08 -4828.70 5608.09 300.57 1.97 BP _ _MWD+IFR+MS 90.57 331.60 31.72 8912.93 5197.10 2880.18 -4843.39 5635.06 300.74 5.56 BP _MWD+IFR+MS 90.88 332.21 32.03 8912.53 5215.97 2908.44 -4858.48 5662.49 300.91 2.14 BP _MWD+IFR+MS 90.74 332.99 32.28 8912.07 5234.67 2937.09 -4873.33 5689.98 301.08 2.45 BP MWD+IFR+MS 90.88 331.95 31.67 8911.62 5253.07 2965.17 -4887.97 5717.03 301.24 3.31 BP_ MWD+IFR+MS 91.95 331.39 32.14 8910.83 5272.10 2993.45 -4903.22 5744.76 301.40 3.76 BP_ MWD+IFR+MS 92.43 332.12 31.66 8909.62 5290.81 3021.32 -4918.19 5772.08 301.56 2.76 BP_ MWD+IFR+MS 92.39 332.17 31.94 8908.28 5309.50 3049.54 -4933.10 5799.58 301.72 0.20 BP_ MWD+IFR+MS 92.67 333.59 32.00 8906.86 5327.89 3077.99 -4947.67 5826.96 301.89 4.52 BP MWD+IFR+MS 91.77 332.07 31.78 8905.63 5346.18 3106.24 -4962.17 5854.22 302.05 5.56 BP_ MWD+IFR+MS 92.01 331.82 32.15 8904.57 5365.09 3134.60 -4977.28 5882.10 302.20 1.08 BP_ MWD+IFR+MS 92.36 331.89 31.53 8903.37 5383.68 3162.38 -4992.15 5909.50 302.35 1.13 BP_ MWD+IFR+MS 92.67 333.77 31.74 8901.98 5401.94 3190.59 -5006.62 5936.85 302.51 6.00 BP_ MWD+IFR+MS 91.67 333.53 31.76 8900.77 5419.85 3219.03 -5020.71 5964.03 302.67 3.24 BP MWD+IFR+MS 91.57 333.14 31.34 8899.89 5437.67 3247.02 -5034.77 5991.00 302.82 1.28 BP _MWD+IFR+MS 92.12 334.81 32.37 8898.85 5455.77 3276.10 -5048.96 6018.71 302.98 5.43 BP _MWD+IFR+MS • 92.36 335.07 32.21 8897.59 5473.33 3305.25 -5062.60 6046.04 303.14 1.10 BP _MWD+IFR+MS 92.56 334.96 31.23 8896.25 5490.31 3333.53 -5075.78 6072.56 303.30 0.73 BP _MWD+IFR+MS 92.53 334.72 4.28 8896.06 5492.65 3337.40 -5077.59 6076.20 303.32 5.64 BP _MWD+IFR+MS 92.53 334.72 54.06 8893.67 5522.29 3386.24 -5100.66 6122.36 303.58 0.00 Projected_TD [(c)2008 IDEAL ID13_OC_10] Schlumber er 9 Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken (AOGCC) Well No 05-35A Date Dispatched: 26-Aug-08 Installation/Rig Nabors-7ES Dispatched By: Franklin Medina LWD Log Delivery V2.1, 03-06-06 Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H. Johnson R@CBlved By: BP Exploration (Alaska) Inc. Petrotechnical Data CenterjLR2-1) \t ~ ~ ~ J 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~bp.com • ~~ ~r '~~~ ~,,~-? 1 ~ ~ ~' ~.~ ~~ ~~; x ;~,~) ~ ~ l t_ ~ SARAH PALIN, GOVERNOR ~S~A OI~ ~i`~ a][v*7 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOIIT COl-II-TI5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-35A BP Exploration Alaska Inc. Permit No: 208-134 Surface Location: 2323' FNL, 124' FWI,, SEC. 32, T11N , R15E, UM Bottomhole Location: 4603' FNL, 206' FWL, SEC. 30, T11N, R15E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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 m the revocation or suspension of the permit. 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). Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of August, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI PERMIT TO DRILL 20 AAC 25.005 H . ...4' .. .,~ , ..s~ ~~ LU~iS 1 a. Type of work 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Drill 'll ^ Service ^ Multiple Zone e-E ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Cogdfh~he= ~^ G~sNyi~ratss -, ^ Shale Gas r, . 2. Operator Nam BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU OS-35A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12609 TVD 8820 ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028326 Pool FWL, SEC. 32, T11 N, R15E, UM 2323 FNL, 124 Top of Productive Horizon: 724' FNL, 457' FWL, SEC. 31, T11N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 23, 2008 Total Depth: 4603' FNL, 206' FWL, SEC. 30, T11 N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 22000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-697190 y-5949122 Zone-ASP4 10. KB Elevation (Height above GL): 72' feet 15. Distance to Nearest Well Within Pool: 259.71' 16. Deviated Wells: Kickoff Depth: 3984 feet Maximum Hole An le: 93.7 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3280 Surface: 2400 18. Casin P ram: S ecificatio ns To - Settin D e th -:Bo ttom uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M/TCII 9686' Surface Surface 9686' 8284' 358 sx LiteCrete 169 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3073' 9536' 8228' 12609' 8883' 307 sx Class'G' 1g. PRESE NT-WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10597' Total Depth TVD (ft): 9023' Plugs (measured): None Effective Depth MD (ft): 10550' Effective Depth TVD (ft): 8987' Junk (measured): 10451' :Casing Length Size: Cement Volume MD D Conductor /Structural 115' 20" 11 Yards Cement Slur 115' 115' Surface 4023' 9-5/8" 1141 sx CSI11, 300 sx 'G', to Job 195 sx CS II 4023' 3895' Intermediate g78g' 7" 378 sx Class 'G' 152 sx Class 'G' 9788' 8400' Production Liner 1122' 5" 27 bbls ARC 9470' - 10592' 8147' - 9019' Perforation Depth MD (ft): 10443' - 10464' Perforation Depth TVD (ft): 8906' - 8922' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fore oing 's'true and correct. Contact Jovy Roach, 564-4352 Printed Name Greg H b Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date r^ '• ~ Sondra Stewman, 56a-4750 Commission Ilse On1 Permit To Drill Number: ~ API Number: 50-029-22172-01-00 Permit Approval See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales:~,,// Samples Req'd: ^ Yes [~NO Mud Log Req'd: ~^ Y/~s L7No ,~~ S ` ~ ~ ~ HZS Measures: I1G Yes ^ No Directional Survey Req'd: IllYes ^ No Other. ~ ® ~C..S~ Zo / (~ APPROVED BY THE COMMISSION 6 Date ,COMMISSIONER -: -z Form 10-401 Revised 12/2005 / Submit In Duplicate ,;~ ;~, ~ ~~r ~ ":~ ~ k~, ~.~~ To: Alaska Oil & Gas Conservation Commission From: Jovy Roach, ODE Date: August 18, 2008 Re: 05-35A Sidetrack Permit to Drill The 05-35A well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location ~ August 23, 2008. The plan is to exit the parent 05-35 wellbore from the 9-5/8" casing at 3800' MD with an 8-1/2" BHA. The 8-1/2" hole will then be drilled to TD at the top of the Sag River formation, and 7" casing will be run and cemented. A 6-1/8" hole will then be drilled building to horizontal in the Ivishak Zone 1A. The planned well then runs horizontally for approximately 1500' to a final well TD at 12,610' MD. A solid 4-1/2" production liner will be run and cemented in place. Please note the following Well Summary as detailed on the next few pages: 05-35A Permit to Drill Application Page 1 Planned Well Summary Well 05-35A Well Horizontal Target Zone T e Sidetrack Ob'ective 1 A API Number: 50-029-22172-01 Current Status 05-35 Shut-In and P&A Procedures commencing Estimated Start Date: 23-Au -2008 Time to Com lete: 32 Da s Surface Northin Eastin Offsets TRS Location 5,949,122.31 697,189.88 2323' FNL /124'FWL 11 N, 15E, 32 Northin Eastin TVDss Offsets TRS Target 5,950,600 692,480 -8,942 724' FNL / 457' FWL 11 N, 15E, 31 Locations 5,950,259 692,658 -8,963 1069' FNL / 626' FWL 11 N, 15E, 31 5,951,484 692,454 -8,903 5119' FNL / 453' FWL 11 N, 15E, 30 Bottom Northin Eastin TVDss Offsets TRS Location 5,951,994 692,194 -8,882 4603' FNL / 206' FWL 11 N, 15E, 30 Planned KOP TOW : 3984'MD / 3799'TVDss Planned TD: 12,609'MD / 8820' TVDss Ri Nabors 7ES RT-GL: 28.2' RT-BF: 25.65' u~r~cuc~na~ - Scniumner KOP: 3984' MD ger triu~ Maximum Hole Angle: ~ 38.19° sail angle in the 8-1/2" intermediate section 93.70° in the 6-1/8" horizontal section Close A roach Wells: All wells pass major risk criteria for close approach. Surve Pro ram: MWD Standard + IIFR + MS Nearest Pro ert Line: 22,000' (West) to the PBU property line Nearest Well within Pool: 05-11 is the closest well at 259.71' ctr-ctr with 106' of allowable deviation at tanned de th of 9,010' MD. Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Jovy Roach 564-4352 Priya Maraj 564-4181 James Dean 564-4668 E-mail jow.roach C~2 bp.com priya.marai C«~ bp.com james.dean G bp.com 05-35A Permit to Drill Application Page 2 TREE =FMC ULTRA SLIMHOLE WELLHEi4D= FMC ACTUATOR= AXELSON KB. ELEV = 72' BF. ELEV = KOP= 2800' Max Angle = 42 @ 8100' Datum MD = 10397' Datum N D = 8800' SS 9-5/8" CSG, 36#, J-55, ID= 8.921" H 4023' Minimum ID = 1.31" @ 6148' HES RETRTBG PATCH SAFETYNOTFS: CHROMETBGBLNR 3-1/2" Ol1S FMX TRSV SSSV NIP, ID = 2.813" GA S L IFT MANDR~S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3283 3261 24 CA-MMG RK 2 5698 5246 36 CA-MMG RK 3 7114 6351 39 CA-Mv1G RK 4 7922 6960 42 CA-MMG TG 5 8557 7437 41 CA-MMG RK 6 8931 7721 40 CA-Mv1G RK 7 9260 7980 37 CA-MMG TG 148' 3-1/2" HES REfRTBG PATCH 2900#, DB_TA P, ID =1.31 " 415' 7" X 4" Ol1S BW D PKR, ID = 4.000" OF 5" LNR H 9470' 9530' 3-1/2" PARK~2 SWN NIP, ID= 2.75" 3-1/2"TBG, 9.3#, 13-CR-80, 9541' 9541' 3-1/2"O11S SHEAROUTSL6, ID=2.992" .00870 bpf, ID = 2.992" 9540' ELMD TT LOGG®08/16/91 7" CSG, 26#, L-80, ID = 6.276" ~--~ 9787' FERFORAl1ON S LIMMA RY R~ LOG: BHCS ON 08/16/91 ANGLE AT TOP PERF: 42 @ 10443' Nnte• Refer to Production DB for historical oerf data SIZE SFF INTB~VAL Opn/Sqz DATE 3-3/8" 4 10443 - 10453 O 07/17/91 2-1/2" 4 10443- 10453 O 10/20/94 3-3/8" 4 10457 - 10464 O 07/17/91 2-1/8" 4 10457- 10464 O 10/20/94 I PBTD H 10550' 5" LNR, 15#, 13-CR, .0178 bpf, ID= 4.408" 10592' TD 10597' 05-35 10451' FISH -SWAB CUP + 3" X 2.9" OD W/ 1-1/2" HOLE (LOST 01/21/95) DATE REV BY COMMENTS DATE REV BY COMMENTS 06/19/91 ORIGNAL COMPLETION 11/21/00 SIS-SLT CONVERTED TO CANVAS 02/09/01 SIS-LG REVISION 08/12/01 RN/KAK CORREC11ONS 06/05/02 CORRECT CORRUPTED FILE PRUDHOEBAY UNff WELL: OS-35 PERMIT No: 1910680 API No: 50-02 9-221 72-0 0 SEC 32, T11 N, R15E 3999.28 F~ 241.79 FNL BP Exploration (Alaska) IKCC = rIViU ULIKH JLINII-1VLC WELLHEAD = FM ACTUATOR = AXELSON KB. ELEV = 72' BF. ELEV = KOP = Max Angle = C~atum MD = Im TVD = d~i5A Proposed Draft Mrimm ID = i 9-5/8" WHIPSTOCK - 3984 9-5/8" EZSV - 4000 7" CASING CUT - 4000 EST TOC BEHIND 7" BASED ON 30% WASHOUT - -4000' 9-5/8" CSG, 36#, J-55, ID = 8.921" ^'4T023' ~~~~ W i ~ SQUEE7F TOC N 4700' TUBING PUNCFI M 8128' TUBING PATCH 8148' P~/-TOC ~ 93'50' 7x4" PKR - 9,415' TOP OF 5" LNR 9470' 17" CSG, 26#, L-80, ID = 6.276" I PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical erf data SIZE SPF INTERVAL N DATE PBTD I~ 10550' ~ 15" LNR, 15#, 13-CR, .0178 bpf, ID = 4.408" { AFETY NOTES: -3,800' - KOP -9,550' - 4-1/2" TBG, 12.6# 13CR VAMTOP 9,484' - 4-1/2" X Nipple (3.813" ID) 9,494' - 7" X 4-1/2" BKR Packer 9,521' - 4-1/2" X Nipple (3.813" ID) 9,541' 4-1/2" XN nipple (3.725" ID) 9,551' - 7" X 4-112" BKR PKR/HGR 9,554'-4-1/2" WLEG 9,686' - 7" 26# L-80 BTC-M (PREM THREAD FM TOC TO SURFACE) 12,609' - 4-1/2" 12.6# L-80 IBT-M SOLID, PERFORATED LINER GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3847 6400 3750 5763 4TE REV SY COMMENTS DATE REV BY COMMENTS u6/19/91 ORIGINAL COMPLETION 08/13/08 JER PROPOSED RIG ST 11/21/00 SIS-SLT CONVERTEDTOCANVAS 02/09/01 SIS-LG REVISION 08/12/01 RWKAK CORRECTIONS 06/05/02 CORRECT CORRUPTED FILE I 10597' PRUDHOE BAY UNIT WELL: 05-35A PERMIT No: API No: 50-029-22172-01 SEC 32, T11 N, R15E 3999.28 FEL 241.79 FNL BP Exploration (Alaska) ~ Planned Well Summar M Well 05-35A Well Horizontal Target Zone T e Sidetrack Ob'ective 1 A API Number: 50-029-22172-01 Current Status 05-35 Shut-In and P&A Procedures commencing Estimated Start Date: 02-Sept-2008 Time to Com lete: 32 Da s Northin Eastin Offsets TRS ' ' Lo at on 122.31 949 5 697 189.88 FNL / 2322.96 FWL 8 11 N, 15E, 32 , , , Northin Eastin TVDss Offsets TRS Target 5,950,600 692,480 -8,942 724' FNL / 457' FWL 11 N, 15E, 31 Locations 5,950,259 692,658 -8,963 1069' FNL / 626' FWL 11 N, 15E, 31 5,951,484 692,454 -8,903 5119' FNL / 453' FWL 11 N, 15E, 30 Bottom Northin Eastin TVDss Offsets TRS Location 5,951,994 692,194 -8,882 4602' FNL / 206' FWL 11 N, 15E, 30 Planned KOP TOW : 3984'MD / 3799'TVDss Planned TD: 12,609'MD / 8820' TVDss Ri Nabors 7ES RT-GL: 28.2' RT-BF: 25.65' Directional - Schlumberger (P70) KOP: 3984' MD Maximum Hole Angle: ~ 38.19° sail angle in the 8-1/2" intermediate section 93.70° in the 6-1/8" horizontal section Close A roach Wells: All wells pass major risk criteria for close approach. Surve Pro ram: MWD Standard + IIFR + MS Nearest Pro ert Line: 22,000' (West) to the PBU property line Nearest Well within Pool: 05-11 is the closest well at 259.71' ctr-ctr with 106' of allowable deviation at tanned de th of 9,010' MD. Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Jovy Roach 564-4352 Priya Maraj 564-4181 James Dean 564-4668 E-mail iow.roach C~ bp.com priva.marai @ bp.com james.dean~bp.com 05-35A Permit to Drill Application Page 2 r Formation Markers~5-35A ( Based on SO TVDss R) "' Planned MD Base Permafrost -1920 n/a SV4 (est) -3020 n/a KOP -3433 n/a SV2 (est) -3769 n/a SVl (est) -4141 4415 UG4 (est) -4689 5112 UG3 -4857 5326 UGl -5367 5975 WS2 -6020 6806 WS1 -6248 7096 CM3 -6470 7378 CM2 -6928 7961 CM1 -7578 8788 THRZ -7962 9277 BHRZ -8135 9497 LCU -8147 9512 TJA -8169 9540 TSGR -8284 9686 TSHU -8329 9744 TSAD -8399 9833 42SB -8505 9968 TCGL -8570 10051 BCGL -8631 10132 23SB -8722 10265 21TS -8795 10392 TZ1B -8838 10486 TDF -8873 10589 BSAD -8902 Casinq/Tubinq Program Hole Size Csg / Tb O.D. WUFt Grade Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 8-'/z" 7" 26# L-80 BTC-M 7,240 5,410 5,686' 4000 / 3874 9686 / 8284 8-1/2" 7" 26# L-80 TC II 7,240 5,410 4,000' Surface 4000 / 3874 6-1/8" 4'h" 12.6# L-80 IBT-M 7,500 8,430 3,073 9536 / 8228 12609 / 8883 Tubing 4'/z" 12.6# 13Cr-80 Tom 8,430 7,500 9,536' Surface 9536 / 8228 05-35A Permit to Drill Application Page 3 Mud Program Whi stock Millin Mud Pro erties: LSND Whip Stock Window 9-5/8", 47# Densit PV YP API FL HTHP FL MBT PH 9.3 15-22 30-40 6-8 N/C N/C 9.0-9.5 Intermediate Mud Pro erties: LSND 8-1/2" hole section Depth Interva Density (pp PV YP API FL HTHP FL MBT PH 4000 - 9077 9.3 - 10.0 8-14 18-24 <6.0 N/C <15 9.0-10 9077 - 9686 HRZ to Sa 10.8 12-20 18-28 4.0-6.0 <10.0 <20 9.0-10 Production Mud Pro erties: FLOPRO SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densit PV YP LSVR API FI H MBT 9686'-12609' 8.4 - 8.5 6-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 4 Logging Program 8-1/2" Intermediate: Sample Catchers - as required by Geology Drillin Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Cement Program Casin Size: 7" 26#, L-80 Intermediate Casin Basis: Lead: 4694' of 7" x 8-1/2" o en hole with 40% excess, lus 242' inside 7" x 9-5/8" annulus Tail: 1000' of 7" x 8-1/2" open hole with 40% excess, plus 80' shoe tract TOC: 3750' MD for Cretaceous isolation Total Cement Volume• Spacer 40 bbls of Viscosified Spacer weighted to 11.0 ppg (Mud Push II) Lead 156 bbl, 12.0 Lite Crete slur ,Yield 2.45 Tail 35 bbls, 197 cuft, 169 sks 15.8 Ib/ al Class G, Yield 1.16 cuft/sk Tem BHST =180° F, BHCT TBD b Schlumberger Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: 2923' of open hole with 40% excess, 80' shoe tract, 150' 4-'/z" x 7" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 9,336' MD (200' above Liner Top) Total Cement Volume: Spacer 40 bbls of Viscosified Spacer weighted to 12.0 ppg (Mud Push II) Lead None Tail 64 bbls, 359 cuft, 306 sks 15.8 Ib/ al Class G + adds -1.17 cuft/sk Tem BHST = 185° F, BHCT TBD b Schlumber er 05-35A Permit to Drill Application Page 4 Surface and Anti-C~ision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface 5-13 to the north and 5-15 to the south are nearest at 60' centers. Close Approach Shut-in Wells: All wells pass major risk criteria. Hydrogen Sulfide DS 05 is not designated as an H2S site. The last H2S data from the pad is as follows: Date of Well Name H2S Level Readin #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) 05-13 7 m 11 /8/1985 05-126 5 m 1/4/1996 05-11 A 0 m 3/29/1992 02-29C n/a n/a 05-05B 27 m 11 /1 /1990 No H2S data exists for OS-35. Faults The 05-35A wellpath is not expected to intersect any mapped faults. The well plan passes well clear (400 ft) of a small fault in the Kingak. After landing, additional faults are present 120 feet and 130 feet to the west of the polygon. The polygon is a hardline in this direction. The planned well will also pass within 70 feet of another small fault within the polygon in Zone 1 A near 11800 ft MD; however the low permeability of this section should minimize the risk of loss circulation. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for 05-35A will be 14 days during drilling phase and 7 days during decompletion and surface casing work. BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 2649 si C«3 5537' TVDss 9.2 EMW Maximum surface ressure 2095 si .10 si/ft as radient to surface Kick tolerance 52 bbl over 11.3 ppg FIT assuming 9.2 max pore pressure and 4" drill i e Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface ressure Inte rit Test - 8-1/2" hole 11.3 FIT after drillin 20' from middle of window 05-35A Permit to Drill Application Page 5 Production Interval Maximum antici ated BHP 3280 si C«~ 8800' TVDss 7.2 EMW Maximum surface ressure 2400 si .10 si/ft as radient to surface Kick tolerance Infinite with a 10.0 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin "Liner Test 3500 si surface ressure Inte rit Test - 6-1/8" hole 10.0 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Variance Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I waste to Pad 3 for disposal. 05-35A Permit to Drill Application Page 6 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.2 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation/Breathing A. The well plan passes well clear (400 ft) of a small fault in the Kingak. After landing, additional faults are present 120 feet and 130 feet to the west of the polygon. The polygon is a hardline in this direction. The planned well will also pass within 70 feet of another small fault within the polygon in Zone 1 A near 11800 ft MD; however the low permeability of this section should minimize the risk of loss circulation. B. The proposed 05-35A well lies in a high risk province of the field for lost circulation at faults as documented bythe WURD team. Eighteen loss circulation events were encountered in the Tertiary through Jurassic sections in 13 of the 40 Drill Site 5 wells (33%). In addition, 14 loss circulation events were encountered in the Sadlerochit in 10 of the surrounding 37 wells (27%). Risk of loss circulation for the proposed 05-35A well is moderate but costs are not included. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for both the intermediate and production hole sections is infinite with planned mud weights. The FIT will prove up adequate formation strength for expected ECD's. B. Integrity Testing Test Point Test De th Test t e EMW Ib/ al 9 5/8" window 20-ft minimum from the 9-5/8" window FIT 11.3 minimum 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip / back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. DS 05 is not designated as an H2S site; H2S levels of potentially lethal concentrations have been recorded on this pad, however, current levels are below the 100 ppm threshold to be considered an H2S pad. VI1. Faults A. The 05-35A wellpath is not expected to intersect any mapped faults. See Section II on lost circulation for more details. VIII. Anti-Collision Issues B. All wells pass major risk criteria for close approach. 05-11 is the closest well at 259.71' ctr-ctr with 106' of allowable deviation at planned depth of 9,010' MD. CONSULT THE DS 05 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 05-35A Permit to Drill Application Page 7 • 05-35A Ouerations Summary ~~a`~ ~~~ ~ Q~~~ Well Status: 1. Shut-in since 1996. 2. Tubing patch set it 1994. Last MIT-T was 8/13/96 -passed to 2000 psi. 2. IA status: Cretaceous leak at ~ 6150 confirmed in 1993. Unable to be fixed after 3 gel squeezes and tubing patch. 3. MIT-OA 12/27/07 failed with LLR of 3/a bpm. Suspected flow out surface casing shoe. Pre Rig Operations: W 5 PPPOT - IC (9-5/8") 3,500 psi, PPPOT-T (3-1/2") 5,000 psi. Function all lock-down screws. DONE 7/26/08 S 1 Drift 3-1/2" tubing to patch at 6148' MD. Retrieve HES Teledyne Repeata B Tubing. Patch. Drift tubing to TD. Record tubing tail depth and tag bottom. Unable to ull atch. Stri ed fishin neck. F 2 P & A the perforations, bullheading cement from surface, in the 05-35 wellbore with ~ 21 bbl + excess 15.8 ppg Class G cement. Planned TOC at 9350'. (See P&A program.) Test to 2150 si er AOGCC Re s. Ensure assin MIT-T before unchin tubin . E 3 Punch the 3-1/2", 9.3#, 13-Cr-80 tubing ~ 20' above the tubing patch at 6148': punch tubing at 6128' MD. F 5 Circulate the well to seawater throu h the tubin unch to fluid ack before cementin . F 4 Bullhead 50 bbl squeeze cement through tubing punch to cover Cretaceous leak at 6148'. Test to 2150 si er AOGCC Re s. Ensure assin MIT-T before cuttin tubin . E 5 Jet cut the 3-1 /2", 9.3#, 13-Cr-80 tubin at in the middle of a full 'oint at ~ 4200'. F 5 Circulate the well to 9.8 brine throu h the tubin cut for freeze rotect. Ca with 500' of diesel. F 6 CMIT-TxIA to 3500 psi for 30 min. (Last MIT-IA 12/6/94 to 500 psi: LLR 0.5 gpm.) MIT-OA (9- 5/8" surface casing) to 2000 psi for 30 min. (MIT-OA 12/27/07 failed with LLR 3/a bpm.) Bleed all casin and annulus ressures to zero. W 7 Set BPV in tubin han er. Secure well. O 8 Remove well house. Level the ad. Provide total well re cost on the handover form. Rig Operations: 1. MIRU. 2. MIT-OA 2000 psi. If the MIT fails, obtain a LLR. Pull BPV. Circulate out freeze protection and displace well to 9.8 ppg brine. Set BPV and test from below to 1000 psi (also tests TxIA). 3. Nipple down tree. Install blanking plug. 4. Nipple up and test BOPE. Pull BPV and blanking plug. 5. RU and pull the 3-1/2" tubing from the pre-rig jet cut. Spool up SSSV control lines. Count bands and clamps retrieved. 6. RU E-line. Run USIT/GR/CCL from tubing stub to surface to confirm the TOC behind 7" casing. 7. Cut and pull 7" casing from above the TOC, or just inside surface casing shoe, whichever is higher. 8. RU E-line and run GR/JB from 7" casing stub to surface until 9-5/8" casing is clean. 9. E-line set 9-5/8" EZSV at ~ 4000' (max hole angle is 35° at 3800' MD). 10. PU 9-5/8" whipstock and 8.5" window milling assembly (to include full gauge string mills). RIH to the 11. Mill a window in the 9-5/8" casing from - 4000' MD' plus 20' of formation from mid-window. Note: Verify that the mud weight is correct prior to cutting the window. 12. Perform a FIT. POOH for Drilling BHA. 13. MU the 8-1/2" drilling assembly with DIR/GR/RES/PWD and RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the Top of the Sag River (~ 9745' MD). CBU, short trip to window and back to TD, circulate well clean and POOH. 14. Change rams to accommodate 7" casing. Test rams. 15. Run and cement 7" casing throughout the 8-1/2" hole and back into the 9-5/8" casing to surface. 16. Pressure test 7" casing. 17. Install packoff. Test packoff to 4300 psi for 30 min. 18. Change rams to accommodate drillpipe. 05-35A Permit to Drill Application Page 8 19. MU 6-1/8" BHA with DIRi"~!R/RES/NEU/DEN and RIH to the 7" landin~llar. 20. Drill out shoe tract. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform a FIT. 21. Drill ahead building to horizontal landing point ~ 11113' MD. POOH for bit & BHA change. 22. MU 6-1/8" BHA with DIR/GR/RES/NEU/DEN. RIH and MAD pass build section. Drill ahead in the horizontal as per plan to an estimated TD of ~ 12610' MD. 23. CBU, short trip, circulate until clean and spot a liner running pill. POOH. 24. Run and cement a 4-1/2", 12.6#, L-80, IBT-M liner throughout the 6-1/8" wellbore and 150' back into the 7" intermediate casing to ~ 9595' MD. Set liner top packer and displace well to clean seawater above the liner top. Test liner to 3500 for 30 min charted. NOTE: A pen` pill will be left in the 4-1/2" liner. 25. RIH with DPC pert guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance, - 1200' of perfs. POOH, LD DP and pert guns. 26. Run the 4-1/2", 12.6#, 13Cr, Vam Top completion. Tie into the 4-1/2" liner top. 27. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes each. 28. Set and test TWC. 29. ND BOPE. NU and test tree to 5,000 psi (Change to a 4" tree and use a new adapter flange). 30. Freeze protect the IA and tubing to 2,200' and secure the well. 31. RDMO. 05-35A Permit to Drill Application Page 9 by ~. _~ ~:~~ ~~ ~. ~i~~~~ Schlumberger DS05-35A (P10) Proposal Report Date: August 5, 2008 Survey 1 DLS Computation Method: Mlnlmum Curvature I Lubinskl Client: BP Exploration Alaska Vertical Section Azimuth: 278.00° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: ~ N 0.000 ft, E 0.000 ft Structure 1 Slot: DS-05105-35 ~~ ~ TVD Reference Datum: Rotary Table Well: 05-35 ~ TVD Reference Elevation: 62.70 ft relative to MSL Borehole: Plan 05-35A ~ L`J Sea Bed 1 Ground Level Elevation: 34.20 ft relative to MSL UWIIAPI#: 500292217201 Magnetic Declination: 23.173° Survey Name 1 Date: 05-35A (P10) kop up in casing I August 5, 2008 Total Field Strength: 57690.456 nT Tort 1 AHD 1 DDI 1 ERD ratio: 161.119° / 6742.98 ft 16.184 / 0.752 Magnetic Dip: 80.922° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 10, 2008 Location LaULong: N 70.26516814, W 148.40553262 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 5949121.630 ftUS, E 697189.820 ftUS North Reference: True North Grid Convergence Angle: +1.50086131 ° Total Corr Mag North -> True North: +23.173° Grid Scale Factor. 0.99994417 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de d ft ft ft ft ft d de 1100 ft Index ftUS ftUS Tie-In survey 3SyU./U 34.6b YyZ.4/ 3/L7./5 3/i54.4O 43b. ZZ ly/./3 -411./l -IV/.UIL U.4U 3900.00 34.63 292.37 3729.40 3792.10 440. 34 199.75 -416.59 106.93E 0.67 Top Whipstock 3984.00 34.47 291.42 3798.58 3861.28 486 .58 217.51 -460.80 60.00E 0.67 Base Whipstock 4000.00 35.47 288.55 3811.69 3874.39 495 .55 220.64 -469.41 --- 12.00 KOP Crv 4/100 4013.00 35.47 288.55 3822.28 3884.98 502 .97 223.04 -476.57 71.09E 0.00 4100.00 36.72 283.04 3892.60 3955.30 553 .71 236.94 -525.85 66.64E 4.00 End Crv 4185.56 38.19 277.95 3960.53 4023.23 605 .65 246.37 -576.98 --- 4.00 SV1 4415.17 38.19 277.95 4141.00 4203.70 747. 62 266.02 -717.58 -- 0.00 UG4 5112.41 38.19 277.95 4689.00 4751.70 1178. 71 325.67 -1144.52 --- 0.00 UG3 5326.16 38.19 277.95 4857.00 4919.70 1310. 86 343.95 -1275.41 --- 0.00 UG1 5975.05 38.19 277.95 5367.00 5429.70 1712. 06 399.47 -1672.74 --- 0.00 WS2 6805.89 38.19 277.95 6020.00 6082.70 2225. 74 470.55 -2181.49 --- 0.00 WS1 7095.98 38.19 277.95 6248.00 6310.70 2405. 10 495.36 -2359.12 --- 0.00 CM3 7378.43 38.19 277.95 6470.00 6532.70 2579. 74 519.53 -2532.08 -- 0.00 CM2 7961.16 38.19 277.95 6928.00 6990.70 2940. 03 569.38 -2888.90 --- 0.00 CM1 8788.18 38.19 277.95 7578.00 7640.70 3451. 35 640.14 -3395.31 -- 0.00 THRZ 9276.75 38.19 277.95 7962.00 8024.70 3753. 43 681.93 -3694.48 -- 0.00 BHRZ 9496.87 38.19 277.95 8135.00 8197.70 3889. 52 700.76 -3829.26 --- 0.00 LCU 9512.13 38.19 277.95 8147.00 8209.70 3898. 96 702.07 -3838.61 --- 0.00 TJA 9540.13 38.19 277.95 8169.00 8231.70 3916. 27 704.47 -3855.75 -- 0.00 TSAG 9686.44 38.19 277.95 8284.00 8346.70 4006. 73 716.98 -3945.34 -- 0.00 7" Csg Pt 9686.46 38.19 277.95 8284.01 8284.01 4006. 74 716.98 -3945.35 - 0.00 4.3/ OJ4`J3U8.DU OyO//3.1U IV /U. LOU/UbJU VV 148.4U88O1V/ 4.37 5949310.39 696768.16 N 70. 26571380 W 148.40890058 4.42 5949326.98 696723.51 N 70. 26576232 W 148.40925796 4.44 5949329.89 696714.82 N 70. 26577087 W 148.40932763 4.45 5949332.10 696707.60 N 70. 26577743 W 148.40938544 4.52 5949344.70 696657.98 N 70. 26581540 W 148.40978388 4.58 5949352.79 696606.62 N 70. 26584116 W 148.41019725 4.67 5949368.75 696465.56 N 70. 26589479 W 148.41133397 4.87 5949417.19 696037.23 N 70. 26605761 W 148.41478569 4.91 5949432.04 695905.92 N 70. 26610751 W 148.41584390 5.03 5949477.13 695507.29 N 70. 26625895 W 148.4190 5.15 5949534.85 694996.88 N 70. 26645278 W 148.4231 5.19 5949555.01 694818.67 N 70. 26652044 W 148.42460576 5.22 5949574.64 694645.15 N 70. 26658630 W 148.42600417 5.28 5949615.12 694287.17 N 70. 26672214 W 148.42888919 5.35 5949672.58 693779.11 N 70. 26691486 W 148.43298372 5.39 5949706.53 693478.96 N 70. 26702866 W 148.43540268 5.40 5949721.82 693343.74 N 70. 26707993 W 148.43649248 5.40 5949722.88 693334.36. N 70. 26708348 W 148.43656808 5.41 5949724.83 693317.17 N 70. 26709000 W 148.43670667 5.42 5949735.00 693227.28 N 70. 26712407 W 148.43743110 5.42 5949735.00 693227.27 N 70. 26712407 W 148.43743117 WeIlDesign Ver SP 2.1 Bld(doc4Ox_1OO) 05-35\05-35\Plan OS-35A\05-35A (P1O) kop up in casing Generated 8/13/2008 9:56 AM Page 1 of 2 Measured Vertical Mag 1 Grav Directional Comments Inclination Azimuth Sub-Sea ND ND NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft d de 1100 ft Index ftUS ftUS ISHU y/4:i./U :SC.7y L//.yb 2tJLy.VU ifS`J7./V 4V4L.7;J /L7. tftf -:SytfU.4V --- U.VV 5.4E by4y/Jtf.'J/ TSAD 9832.76 38.19 277.95 8399.00 8461.70 4097.20 729.50 -4034.94 --- 0.00 5.43 5949745.16 42S8 9967.63 38.19 277.95 8505.00 8567.70 4180.58 741.04 -4117.52 --- 0.00 5.44 5949754.53 Crv 10/100 9993.99 38.19 277.95 8525.72 8588.42 4196.88 743.29 -4133.66 76.53R 0.00 5.44 5949756.36 10000.00 38.33 278.90 8530.44 8593.14 4200.60 743.84 -4137.34 75.79R 10.00 5.44 5949756.81 TCGL 10050.94 39.84 286.62 8570.00 8632.70 4232.56 750.95 -4168.61 69.79R 10.00 5.48 5949763.11 10100.00 41.75 293.54 8607.16 8669.86 4263.85 761.98 -4198.66 64.55R 10.00 5.52 5949773.34 BCGL 10132.33 43.22 297.80 8631.00 8693.70 4284.64 771.44 -4218.33 61.40R 10.00 5.54 5949782.28 10200.00 46.76 305.97 8678.89 8741.59 4328.26 796.76 -4258.82 55.62R 10.00 5.59 5949806.53 23S8 10265.31 50.67 312.94 8722.00 8784.70 4370.03 827.97 -4296.61 51.01R 10.00 5.63 5949836.74 10300.00 52.90 316.32 8743.46 8806.16 4391.89 847.12 -4316.00 48.92R 10.00 5.65 5949855.37 21 TS 10392.29 59.25 324.40 8795.00 8857.70 4448.23 906.11 -4364.60 44.40R 10.00 5.71 5949913.07 10400.00 59.80 325.03 8798.91 8861.61 4452.79 911.54 -4368.44 44.08R 10.00 5.71 5949918.39 TZ18 10485.98 66.14 331.56 8838.00 8900.70 4501.56 976.68 -4408.54 41.11R 10.00 5.76 5949982.46 10500.00 67.20 332.56 8843.55 8906.25 4509.12 988.05 -4414.57 40.71 R 10.00 5.76 5949993.67 TDF 10588.70 74.03 338.56 8873.00 8935.70 4553.87 1064.18 -4449.06 38.71R 10.00 5.81 5950068.86 10600.00 74.91 339.30 8876.03 8938.73 4559.16 1074.34 -4452.98 38.52R 10.00 5.81 5950078.91 10700.00 82.81 345.55 8895.35 8958.05 4601.39 1167.77 -4482.49 37.30R 10.00 5.86 5950171.53 10790.12 90.00 351.00 8901.00 8963.70 4631.70 1255.75 -4500.74 12.89R 10.00 5.90 5950259.00 10800.00 90.96 351.22 8900.92 8963.62 4634.57 1265.51 -4502.26 12.89R 10.00 5.91 5950268.71 End Crv 10828.10 93.70 351.85 8899.77 8962.47 4642.53 1293.27 -4506.39 --- 10.00 5.92 5950296.36 Crv 6/100 11112.09 93.70 351.85 8881.44 8944.14 4721.36 1573.81 -4546.58 118.33R 0.00 5.96 5950575.73 11136.70 93.00 353.15 8880.00 8942.70 4727.93 1598.17 -4549.79 118.59R 6.00 5.96 5950600.00 End Crv 11153.35 92.52 354.03 8879.20 8941.90 4732.07 1614.70 -4551.64 --- 6.00 5.97 5950616.47 Crv 6/100 11796.91 92.52 354.03 8850.88 8913.58 4887.31 2254.14 -4618.54 90.98E 0.00 6.04 5951253.90 11800.00 92.52 353.84 8850.75 8913.45 4888.06 2257.21 -4618.86 90.99E 6.00 6.05 5951256.97 11900.00 92.40 347.84 8846.45 8909.15 4917.52 2355.80 -4634.76 91.25E 6.00 6.07 5951355.10 12000.00 92.26 341.83 8842.38 8905.08 4956.81 2452.19 -4660.89 91.49E 6.00 6.10 5951450.77 12035.56 92.20 339.70 8841.00 8903.70 4973.07 2485.74 -4672.59 90.99E 6.00 6.11 5951484.00 12100.00 92.13 335.83 8838.57 8901.27 5005.48 2545.34 -4696.95 91.14E 6.00 6.13 5951542.93 End Crv 12130.19 92.09 334.02 8837.45 8900.15 5021.95 2572.66 -4709.74 --- 6.00 6.14 5951569.91 TD / 4-1/2" Lnr 12608.57 92.09 334.02 8820.00 8882.70 5289.14 3002.41 -4919.16 --- 0.00 6.19 5951994.00 Legal Description: Northing (ln fftUSl Easting (X) fftUSl Surface : 2956 FSL 5156 FEL S32 T11 N R15E UM 5949121.63 697189.82 4210 FSL 4372 FEL S31 T11 N R15E UM 5950259.00 692658.00 4552 FSL 4420 FEL S31 T11 N R15E UM 5950600.00 692600.00 160 FSL 4540 FEL S30 T11 N R15E UM 5951484.00 692454.00 TD / BHL : 677 FSL 4785 FEL S30 T11 N R15E UM 5951994.00 692194.00 b`J37`JZ.17 N /V.Yb/7J/4U W 14tf.4J//7402f 693137.39 N 70.26715814 W 148.43815554 693054.54 N 70.26718954 W 148.43882329 693038.35 N 70.26719567 W 148.43895380 693034.65 N 70.26719716 W 148.43898358 693003.21 N 70.26721655 W 148.43923641 692972.88 N 70.26724662 W 148.43947944 692952.98 N 70.26727245 W 148.43963848 692911.84 N 70.26734154 W 148.43996600 692873.25 N 70.26742675 W 148.440271 692853.37 N 70.26747904 W 148.44042 692803.24 N 70.26764013 W 148.44082 692799.26 N 70.26765494 W 148.44085281 692757.47 N 70.26783285 W 148.44117732 692751.14 N 70.26786390 W 148.44122613 692714.67 N 70.26807181 W 148.44150538 692710.49 N 70.26809956 W 148.44153707 692678.54 N 70.26835477 W 148.44177620 692658.00 692656.22 692651.36 692603.84 692600.00 692597.71 692514.10 692513.69 692495.22 692466.58 692454.00 692428.09 692414.59 692194.00 N 70.26859510 W 148.44192411 N 70.26862175 W 148.44193650 N 70.26869760 W 148.44197005 N 70.26946394 W 148.44229635 N 70.26953049 W 148.44232240 N 70.26957563 W 148.44233749 N 7027132244 W 148.44288157 N 70.27133083 W 148.44288422 N 7027160014 W 148.44301327 N 70.27186344 W 148.44322502 N 70.27195508 W 148.44331 N 70.27211784 W 148.44351 N 70.27219247 W 148.44362068 N 70.27336614 W 148.44531656 WeIlDesign Ver SP 2.1 Bld(doc40x_100) 05-35\05-35\Plan 05-35A\05-35A (P10) kop up in casing Generated 8/13/2008 9:56 AM Page 2 of 2 ! • ~ ° ~~~~~~ Schlamberger ~ .~ ~. ~~p~~A~ WELL DS05-35A (P10) FIELD Prudhoe Bay Unit - EOA STRUCTURE DS-05 Ma9ndk Pa2nielers Moeel: aGGM 2009 Dip: 00.922° Dale: SeplemCer 10.2000 Su,lace La:albn NAD2] Abaka Slate Planet, Zane 0a, US Feet Lat: N]015 50.605 N°Min9: 59a9121.fi3 %US Gntl Do,rv: •1.SW80131 ° Miscellane SbL ous 0535 ND RN: MSL (O.OO fl a8ore MSL) Ma9 Dec: .23.1]3' FS: 5]890.5 nT Lon: W1aB 2d 19.91] Eanenp: 08]109.0211U5 Swb Fad: 0.9999161]10 Plan: OSJSA IPtgl lwp upF Casi„$rvy Date: August 06, 2000 2000 2500 3000 3500 4000 4500 7" Csg Pt P` ~ .~ ~.. _.._.._.._.._.._ _ ._.._.._.. _.._.._.,_.._ ._.._.._.._,. _.._.._.. _.._.._.. _.. _.._.,_.._. _.._.._.._.._.. _.._.._..y,.. ....g,. : .! t ° .._.. ~Ab_. ._.._.._. ._.._.._.._y .._.._.._.._.._.._.._.,_;._.._.._.._.._.._,._.._...;.._.._.._.._.._.._.._.._..:.. L n crvtm~oo ~00 8500 .. ~~.".^ ~v,,.w,.,,,., ti~-er,-.^..~ ~ 8500 ~ .._..i-.._.. CGL .._.._.._.._,i-.._.._.._.. _.._.._.._.. _.~_.._. .._.._.,_.._.. _.._i._.._.._.. _.._.._.._.._. _.._.._.._.._.. _.._.._..i,. : . s 0) n .......... ..G~ _.._.._.._._ ._.._.._.._.._..-..-.._ _..-.._ ,..«...«...«.. _. -iCrv&100._.._.._......_... .. ......_..».TD 14412" Lets... End Crv . , ~ _35 4 Tie-In Survey t4: U _ Crv BN00 ;, !ISlX.._......... ,., .}._.._.._ . ..»..j»..»,..,,.,.,. .. ,_ _.._. _.._.._..y. .....".._.._.._.._..»...... ,.. ._.._.,_. _. _. _. _. _. B_, ~ Top Whipstock (n , End Crv , ' Base Whipstock ~ : «.._,._.._.._.._.._.._.. ........ ..... .,.. .._..~.._.. _.._.._.. _.._.. _,'_.._.. _.._.._ .-.._.._..-v .._.. _.._, ,.®.. _.._j._.. _.. _. .._.._ SA (P10) KOP Crv 4N 00 4000 ..9.QQ0 .... : OS 35 ~ : .......:....................................................................:............................:... ............................. ....».......,..,,.........., ; : 9000 End Crv ., .._.. _.._.._.._. .._.._.._.._ 2000 25Q0 3000 3500 40Q0 4500 Vertical Section (ft) Azim = 34(j°, Scale = 1(in):50~(ft) Origin = 0 N/-S„0 /-V 4800 .......................................................................................i.......,,..,,....................,,,.,.,.....,..,...............,,,w,......,,............,.,.,,..., 4800 5600 .....................{.................,.,...............;...., ..................,...,.,p....,,................,...........;.,,,,..,.,........,,,.......,,,....;....................,,,,,,........;...., 5600 ; o ; ; c ._.._.._.._. _ _.._,._.._.._.._.._,._. _ _.._.._.._.._.._.._ _ ..51._.._.._.._„_.._.._ _ ._.._.._.._.._.._.._.._ ._.,_.._.._.._.._.._.._ , ii ~ 6400 i E .....................;.......,,,,,,.........,..........,,:,,,,.,.,.,.................,,,,.:.... .................,,,,.......e..,,.........,,.,.,.,,,,,,,.......,.........,.,,,,....,....,...... 6400 U 0 7200 ..................... i..,.......................,.......,.,............,,,,,,....,..,..,..i.........,.................... ...,,,...........,.,,,,,.......,,,,i..,...,,,,.............,...... 7200 8000 ......, .. .. -,,..........> ., ~. -...... ~,,,~,,,~„ -., ~..,;.. ~..,~,. ~„ ~., -..'......'::4., ,,.. -.. ~.,., _ - _ . -...'..,- ................' 8000 7" Cag Pt ' ` uaro..,.n.n.11.o.110„i1,.o.1,.1,.11.o.,,e.nr„i.l:ausosn.anll , ui,.1, 1wi1w1..,:r11.1uuw11.nw.let ~..... .. crr.lv,An. :. b "' ~... - _ - - - - GL- - - ._.._.._,._. _;._.._,._.._.._.._.._.._.."i.._.._.._.,_„_.._.._.._...~..._.._.._.._.._.._.._.._..~ ._.._.._.._.._.._.._.._ _.._. . _ .s~.._.._.._;_,. 8800 8800 5-35 End Crv rv 61100 Crv 6NOp End C 800 1600 2400 3200 4000 4800 Vertical Section (ft) Azim = 278°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V by T~~A~ ~~ Schlmberger _~. =.'3 ~'e ALL DS05-35A (P10) FIELD Prudhoe Bay Unit - EOA STRUCTURE DS-05 MaOnelk Pararrelna SuKace Leratun NAD2] Alaska Slate Planes, Zone D4, US Feet M'scellaneous Motlel: 8GGM 2008 Dip: 80.922° Dale: Segember 10, 2008 Lrt: M01554.805 NoMing: 5949121.83 BUS Gtk Dam: •1.50088131° SbL 0535 TW ReI: Relary Table (82.]OM aEOVe MSL) Mag Dec: s23.1]3° F5: 5]690.5 nT Lan: W1482419.91] Esatlre: 89]189.82 BUS Scale PaG: 0.9999441]18 Plan: OS-35P (P1B)kap up in casi~ny Date: August 05, 2008 -4500 -3750 -3000 -2250 -1500 -750 SVUU 2250 A A Z O O C 1500 Ol V V V 750 0 TD 1 a-tn= t.nr OS-35A (P10) '~(~ En Crv -_ Crv 6/ I00 ................ .... .............oe ................. ....,...............................,. ..............,...,..........,......,. ...................................... ...................................... ...................,... i 5-35A Flt 4 8 ss 5 \ End Crv Crv 61100 OS-35A FIl 3 8880s End Crv ~~ ~ 05-35A Flt 2 89025s t 7 7 ; ....................................},................ ....., ~........p,................. .....,....,.............j,..........................,.....,.........g...<,.....,..,...,.......,........... ...q crv tm~oo 7" Csg Pt 05.35A Flt 1 8220ss ....y ...........................................g...................,.......................j...,...,....,..............................j.......................................... KOP Crv 4N00 Base Whipstock Top Whipstock re-in sMrvey end Crv ~ ......g ........................................... ..... 3000 • 2250 1500 750 0 • -4500 -3750 -3000 -2250 -1500 -750 0 «< W Scale = 1(in):600(ft) E »> Field; Prudhoe l3ay Site: PB AS l15 Well.: 05-35 Wellpath: Plan QS-3SA ,.-~~~. . rye. z~ ,, ffi K ~. .~ tl z 0:~ y. t!1 M ~ t ~ MI ~ d4 ~ ~~ m t ~ ~i 1 r, J ~ Y6 ;, ~ pV, ysn ~. Y5 ff //J Ty ~ fff}}}~` Rx n t'.; ~`. ~. d, y ~ y` ~. § s .. mm N "~---~_ m~ ~ .,., ~ y . _ ,... pt \\ _ 1. ~ ~L~ ~ `~ ' as q "'' ro u ti .. ., n ., ~, t~ ~ ` .. -...` _, ~ .. ,e .` <, is w ~Y_ .t"a~ ~ ar v .~ r+ n'~+.., ar as a. ro I °° ` ~ s -.,. r ,a ~, *z ~., v rv 'Y ^'~ ~. Sf -i~ yy ~.::. .. v .l..ie.. £ ,.. 4 1 t ~,. Mr ~ .r ti ~ xv«a'rYicwHP9'~Gktl • OS-35/Plan OS-35A • 0 ~ _ -- - ---- - ---- '~~ _ ----- __,I ---- -- - - -- I -- III ~ ~i. I_ ~ - - I 2 0 0 0 i ICI ~ i ___ - _ _ -- - ---- -- -- ~~ ~ ~~ ~ ~, ~ ~ i - --- ~-~ V - i - ------ __-_ ~, 4-000 , ~-\ ~, i ~ --- ~-- i _~- --~- 5000 ~ '~ ~~~ it ~, i ~ ~ ~ ~ ~ I ~ __ ~~ -- --__- ~ ~ I_ i-- , _r --- I 6 0 0 0 I ----' -- i ~ I III 'I _ - i I - -- I __- --- ~000 ~ t ~ ~ I, ~, ~ ~ ~~~ ~ ---- A ~ _ - ~-- _ - ~ I_ i _ ~ ~-- r 1 8000 ~ ', '~, ~ ~ ~~ ~ ,~ ,~ ,~ ,r ~ ~~ j% %~ ~I / j -- - -~ ~, ~ ~~ i ~ i __ . I ~_ -- ~~ _- ~ ~i . ~ --_ - ~-~ -- ~ ~ I I I ~ i ~ ,, , 10000 '! ~~ ~ I ~ ~ ,I i I ~~_ ~~ I ~ i ~ I _~-- ~ ~ ~~ _-~_ ~~ __ ! i~~_ I I~ -- --r- ~ ~, ,, _ _____ 1000 _~ __ i -- _ _ - .~ ~. 00 _ _ __ So ~ - ~ - ~ \ - - - ~ ~~ _~ - - -- -- -~ o - -- ~ - - -- O - _ i ~ ~ ____- O~ - - 3 - `~ - `~ -- -- / - _- - - ` _ _ - _ __ O~~ -- _ ~ ,~---` _ - - - _-- .-- _ _---- _ ~ Q ~. - - '. `~ ~--~- s __ ~ -- ~ _-- OS-35 (OS-35) Plan OS-35A O s ~ DRILL SITE 5 - ~, - ! r• >a • s ~ a n • ~,. ' ». >.~ u• I s~ d • ~ N~ n• as • b• a+ •y O O •i ~• ~• •s ~• i• 7• •M ., •• •n ~ rr •r •' l~~ •a ,-~ •~ LEGEND SEC. 31 SE 6~ SEC 32 ExtsrlNc wEUS $EC. 5___ i CONDUCTORS AS-BUILT THIS SURVEY LOCATED WITHIN PROTRACTED SEC. 32. T1iN, R15E. Ut/(AT MER]D1AN, AUSKA. t~LL A.S.P. PLANT _~`_ „ G_~-~:Ti.. CELLAR BOX LOCATION N0. COORDS. COOP,DS. PGS: 101: ELEV. IN SECTION 5,948,771.48 N 1559.76 1<4'~e't7 i38" 2604' FSL 33 697,273.69 E 2t5.t2 70't5'St.t4t' 34.1 198' FYVL 5,949,OOS.t6 N tEO~~.t3 t4°'~~'t5.t96" 2441' FNL 34 697,217.65 E 275.OJ 70't~'E3.s53' 3<.3 148' Fth'~ 5,949,121.63 N t9t9.64 t46'_s't5.9tT 2323' FNL 35 697,189.82 E 215.ic 70't5'S4605' 34.2 t2a' FWL 5.949,238.Ot N 2039.63 tob'Z<'20.6a9' 2206' FNL 36 697,161.63 E 2i 4.90 70'~5'S5757" 34.2 99' Fw DRILL SITE 5 CONDUCTOR AS-8U1LT WELLS # 33, 34, 35, 36 5-1g-91 BARNHART HITCHCOCK ~ ~ ~: ~. N.T.S. PA1011 AA 0 S/18/91 AS-BUILT E8 NGRTH SLOP"G TB H]TCH ' ,~ Nc ~ ~ ~ ; -v REV N0. DATE REY(S:C~.S DRAWN CNECK NSDP 0000 CEA-1700-037 201 ~ 1 0 t -.- E 5 SEC. 31 ~ SEC. 32 TtiN, RISE VICINITY MAP N.T.S. NOTES 1. BASIS OF LOCATION PER RECORD AS-GUILTS OF WELLS /9, /10, /tt, /t 2, /t3 k /t4 BY H.V. lOUNSBURY k ASSOC.(4/t3/77). 2. COORDINATES SHOWN ARE ALASkA STATE PLANE ZONE 4. 3. ELEVATIONS SHOWN ARE ARCO DATUM (Id.L.L.W.). 4. REFERENCE FIELD BOOK: PB 91-13 (P. 62-63,66-691 DATE OF SURVEY: 5/7&16/41 SURVEYOR'S CERTIFICATE ! HEREBY CERTIFY THAT 1 AM PRO- PERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING W THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT i SUPERVISION AND THAT ALL DIMEN- ~ SIGNS AND OTHER DETAILS ARE ~ CORRECT AS _0~~+.'«'~27~ 1991. _ PEE. ~ F A C,~ ,: •,v i y ' '.~ ~t;' ~;* 0 .. • •`~• F. liobwt 8i : ~ o %f + `••••••• ~,~pSr F. ROBERT BELL & ASSOC. ARCO Ataska Inc. ~; • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Wednesday, August 13, 2008 Jovy Roach BP Exploration (Alaska) Inc. Schlumberger Prudhoe Bay DS05-35A (P10) Nabors 7ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Program: Instrument Type Start Depth End Depth Boss Gyro 90.70' and 3890.70' and Blind 3890.70' and 4300.00' and MWD + IFR + MS 4300.00' and 12608.57' and Close Approach Analysis results: Under method (2), note. All wells pass. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 08/13/2008 • BP Alaska Anticollision Report Cumpnn~: BP Amoco Dute: 8ib12008 Time: 10:24:17 Ya; e: Field: Prudhoe Bay Relcrcnce bite: PE DS 05 Co-~,rdina re(NE) Reference Well: 05- 35, True No rth Refcrcnec N ell: 05-35 ~crtical ('l ~'U) ltcl'cre ncc: U5-35A Plan 62.7 Rcleraice ~~cllpaui: Plan 05-35A Db: Oracle GLOBAL SCAN APPLIED: All wellpa ths within 200'+ 100/1000 of reference -There are 1[L~4H{liseells in thisRl+ald~pal Plan 8~ PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 3984.00 to 12608.57 ft Scan Method: Trav Cylinder North Maximum Radius: 1 458.01 ft Erro r Surface: Ellipse + Casing Survey Program for DeSnitive Wellpath Date: 8/5/2008 Validated: No Version: 2 Panned From To Survey Toolcode Tool Name ft ft 90.70 3890.70 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 3890.70 4300.00 Planned: Plan #10 05-35A adjst BLIND Blind drilling 4300.00 7680.00 Planned: Plan #10 05-35A adjst MWD+IFR+MS MWD +IFR + M ulti Station 7680.00 12608.57 Planned: Plan #10 05-35A adjst MWD+IFR+MS MWD +IFR + M ulti Station Casing Points MD I_~"U Diameter Hole Size flame ft ft in in --- -__ 3984.00 386128 9.625 12.250 9 5/8" 9686.44 8346.70 7.000 8.500 7" 12608.57 8882.70 4.500 6.125 41/2" Summary -------- O fIsM ~~'cllparh -> Rclircncc O6sct Ctr-Ctr ~~'o-Go .Vlo~+ablc Site 16c11 ~4cllpath \1D 111D Di,tance Area Deviation ~~arnin; ft ft ft ft ft PB DS 02 02-02 02-02 V2 12532.07 10220.00 856.32 123.31 733.01 Pass: Major Risk PB DS 02 02-02 02-02A V1 12532.07 10220.00 856.32 123.31 733.01 Pass: Major Risk PB DS 02 02-02 02-02APB1 V1 12532.07 10220.00 856.32 123.31 733.01 Pass: Major Risk PB DS 02 02-29A 02-29A V3 12200.92 9760.00 767.58 161.53 606.06 Pass: Major Risk PB DS 02 02-29A 02-296 V6 12608.83 10035.00 544.04 169.26 374.77 Pass: Major Risk PB DS 02 02-29A 02-29C V3 12262.80 9460.00 827.01 157.70 669.31 Pass: Major Risk PB DS 02 02-29A 02-29CP61 V1 12606.51 9895.00 831.58 168.56 663.02 Pass: Major Risk PB DS 02 02-34A 02-34A V1 10200.00 12140.00 659.05 287.80 371.25 Pass: Major Risk PB DS 02 02-39 02-39 V2 Out of range PB DS 02 02-39 02-39L1 V3 Out of range PB DS 02 02-39 02-39L1 P61 V1 Out of range PB DS 02 02-39 02-39L1 P62 V1 Out of range PB DS 02 02-39 Plan 5, 02-39A VO Plan Out of range PB DS 05 05-09 05-09 V3 Out of range PB DS 05 05-09A 05-09A V1 Out of range PB DS 05 05-10 05-10 V3 3984.42 4340.00 893.29 71.36 821.94 Pass: Major Risk PB DS 05 05-10 05-10A V2 3984.42 4340.00 893.29 71.36 821.94 Pass: Major Risk PB DS 05 05-10 05-10B V1 3984.42 4340.00 893.29 71.36 821.94 Pass: Major Risk PB DS 05 05-10 05-106PB1 V2 3984.42 4340.00 893.29 71.36 821.94 Pass: Major Risk PB DS 05 05-10 05-10C V9 3984.42 4340.00 893.29 71.07 822.22 Pass: Major Risk PB DS 05 05-11 05-11 V13 9010.45 9140.00 259.71 153.90 105.81 Pass: Major Risk PB DS 05 05-11 05-11A V17 9006.55 9140.00 259.78 154.08 105.70 Pass: Major Risk PB DS 05 05-12 05-12 V4 3985.22 4235.00 660.83 60.43 600.40 Pass: Major Risk PB DS 05 05-12 05-12A V1 3985.22 4235.00 660.83 60.43 600.40 Pass: Major Risk PB DS 05 05-12 05-126 V5 3985.22 4235.00 660.83 60.43 600.40 Pass: Major Risk PB DS 05 05-13 05-13 V2 3984.00 4345.00 838.97 97.49 741.48 Pass: Major Risk PB DS 05 05-13 05-13A V2 3984.00 4340.00 840.24 97.52 742.72 Pass: Major Risk PB DS 05 05-13 05-136 V4 3984.00 4340.00 840.24 97.36 742.88 Pass: Major Risk PB DS 05 05-14 05-14 V1 3984.00 4270.00 811.96 69.13 742.83 Pass: Major Risk PB DS 05 05-14A 05-14A V1 3984.00 4270.00 811.96 69.13 742.83 Pass: Major Risk PB DS 05 05-15 05-15 V2 3985.61 4000.00 460.18 87.94 372.23 Pass: Major Risk PB DS 05 05-15A 05-15A V1 6983.69 3995.00 461.02 90.93 370.10 Pass: Major Risk PB DS 05 05-156 05-156 V1 6983.69 3995.00 461.02 90.93 370.10 Pass: Major Risk PB DS 05 05-156P61 05-15BP61 V1 6983.69 3995.00 461.02 90.93 370.10 Pass: Major Risk PB DS 05 05-16 05-16 V5 3984.42 3945.00 482.25 61.18 421.07 Pass: Major Risk PB DS 05 05-16 05-16A V1 3984.42 3945.00 482.25 61.30 420.94 Pass: Major Risk PB DS 05 05-16 05-166 V3 3984.07 3940.00 481.90 61.30 420.61 Pass: Major Risk PB DS 05 05-17 05-17 V2 3985.19 4020.00 496.28 57.51 438.77 Pass: Major Risk PB DS 05 05-17A 05-17A V1 3985.12 4020.00 496.27 57.56 438.71 Pass: Major Risk PB DS 05 05-17B 05-176 V5 3985.19 4020.00 496.28 57.51 438.77 Pass: Major Risk • BP Alaska Anticollision Report • Comp;rn~: BP Amoco Date 8l6i2003 'Dime: 1024:17 Page: 2 Fichl: Prudhoe bay Rclcrcncc Site: P6 DS OS Cu-~~rdina tciNl~.) Refe rence Well: OS- 35, True No rth Relcrcnce Well: 05-35 ~~ertical (' C1'D) Refere nce: 05-35A Plan b2.7 Retcrence~~'cllpath: Plan 05-35A Db: Oracle Summon <- -- - Offscl A1'cllputh ~ ~ Referenc e (Niset Cu'-Ctr Su-Gu ~lluwahle tine ~~'ull 11'cllpath i11D ~lU Dis~ancc ,1rca Dcvi:+liun Warning ft ft ft ft ft PB DS 05 05-23 05-23 V3 6983.63 3965.00 545.23 68.77 476.46 Pass: Major Risk PB DS 05 05-23 05-23A V7 6983.63 3965.00 545.23 68.77 476.46 Pass: Major Risk PB DS 05 05-23 05-236 V5 3984.86 3890.00 602.61 64.39 538.21 Pass: Major Risk PB DS 05 05-25 05-25 V3 3986.97 4300.00 803.35 67.40 735.94 Pass: Major Risk PB DS 05 05-25 05-25A V3 3986.97 4300.00 803.35 67.40 735.94 Pass: Major Risk PB DS 05 05-25 05-258 V5 3986.97 4300.00 803.35 67.40 735.94 Pass: Major Risk PB DS 05 05-31 05-31 V1 3984.07 3995.00 511.97 61.47 450.50 Pass: Major Risk PB DS 05 05-31A 05-31A V1 3984.07 3995.00 511.97 61.47 450.50 Pass: Major Risk PB DS 05 05-33 05-33 V2 4000.25 4150.00 686.17 76.04 610.13 Pass: Major Risk PB DS 05 05-33 05-33A V5 4000.25 4150.00 686.17 76.04 610.13 Pass: Major Risk PB DS 05 05-34 05-34 V3 3985.08 4295.00 747.02 62.25 684.77 Pass: Major Risk PB DS 05 05-34 05-34A V6 3984.39 4185.00 524.21 61.50 462.71 Pass: Major Risk PB DS 05 05-35 05-35 V2 3995.70 4005.00 0.14 75.26 -75.12 FAIL: Major Risk PB DS 05 05-36 05-36 V4 10689.44 10400.00 584.08 359.81 224.27 Pass: Major Risk PB DS 05 05-36 05-36A V3 10677.28 10350.00 581.24 350.82 230.42 Pass: Major Risk PB DS 05 05-36 05-36APB1 V2 10682.19 10370.00 581.53 353.64 227.89 Pass: Major Risk FieldPrudhoe Bay SitePB DS 05 We11:05-35 WellpathElan 05-35A From KOP to TD Scan interval 100 ft Scale 1:100 OS-35A Drilling Permit Maunder, Thomas E (DOA) From: Roach, Jovy [Jovy.Roach@bp.com] Sent: Tuesday, August 19, 200$ 3:40 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: 05-35A Drilling Permit Page 1 of 2 Tom, Thanks for your patience. We will downsqueeze diesel from surface after cementing. I see that's not in the ops summary, it is in the detailed well plan. Jovy From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, August 19, 2008 3:37 PM To: Roach, Jovy Cc: Hobbs, Greg S (ANC) Subject: RE: 05-35A Drilling Permit Jovy, As noted, I am reviewing the permit application. It is intended to cement the 7" above the 9-5/8" window. Mow will the 7" x 9-518" annulus be freeze protected? 1 may have other questions, but wanted to get this one off. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Tuesday, August 19, 2008 3:34 PM To: Maunder, Thomas E (DOA); Roach, Jovy Subject: RE: 05-35A Drilling Permit Thanks Tom- The D-22 well was anticipated to have more geo-steering and two bit runs for the lateral- It required no steering and one bit run. We are ribbing Eli about the savings and time being 11 days faster than expected- Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, August 19, 2008 3:24 PM To: Roach, Jovy Cc: Hobbs, Greg S (ANC) Subject: RE: 05-35A Drilling Permit I am reviewing the permit application. From: Roach, Jovy [maitto:Jovy.Roach@bp.com] Sent: Tuesday, August 19, 2008 2:09 PM To: Maunder, Thomas E (DOA) Subject: 05-35A Drilling Permit 8/19/2008 OS-35A Drilling Permit Tom, Page 2 of 2 Just wanted to make sure you got the Drilling Permit application this morning. We are still expecting to move on to the well on Friday, so if you could finish the permitting by the end of the week we would greatly appreciate it. Thanks, Jovy 8/19/2008 Alaska Department of Natura~sources Land Administration System Page 1 of~ t .~~:.~ - . _ as ecc~~~~;~~'s Se~~ch :State Cabins ~1~tur~1 "5~U1`~5 _... ~ __ Alaska DNR base summary File Type: ADL File Number: 28326 ~ printable Case File_$ummary See Township, Range, Section and Acreage? Yes C"' No New Search !_.AS Nleni_~ I Case Abstract ~ Case Detail I Land Abstract _, F'i/e: AllL 283?6 Search for Status Plat Updates Cz~stomer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 78~ OIL & GAS LEASE COMP DNR Ur1it: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Dade: 09/14/1965. Total Acres: 2491.000 Date Initiated: 05/28/] 965 Office of Prinzany Responsibility: DOG DIV OIL AND GAS Last TNarasactiorz Date: 12/04/2006 Case Subtype: ~S NORTH SLOPE Last Transactlor~l: AA-NRB ASSIGNMENT APPROVED ME~rrc-fiar~~ U Township: O'11N Range: 011: ,S~>c~ior~: ~~~ Sectirul,lc°r~~s: 640 ' Search Plats Ilr~ri~li~nr.~ l1 Tul~~r~.i~Irip: 01 I N Rcrfl,Lre~: 013E S'eeti~ut.~ 30 .S'rc~liun .-1c~rc~~: 60~ ,lI~~ri~lrcnr. ~~' 7i~un.~~{rip: O1 IN Rarr~~c: 011; S~~cliurr.~ 31 ti'c~~~liurr ~I~~rc~~~: 60? '1'~C/7d/U/]: U ~~)1L71J'j71j>: ~) ~ ~ ~ K~1Jl~c': O ~ SE ,~c't'~liJI1: 3 ~ .~~CC'[II)il :~1C1'NS': F) }~_) Leal Descrihiion OS-2~-196 * * * SALE NOTICE LEG,4L DESCRIPTION* ~ ~` C1~-1~6 771N-RISE-UM 29,30,31,32 2-X91.00 U- 3- 7 1 a5 silll'111"'~{ Last updated on 08/19/2008. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28326&... 8/19/2008 r ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~.~CI O~'3v`'r~ PTD# ~d~J~~d Development Service Exploratory Stratigraphic Test Non Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing weft (If last two digits in permit No. ,API No. 50- - API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PII,OT HOLE In accordance with 20 AAC 25.005(f), all records, data and togs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- _, from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (game of well) until after (Comnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. S,Company Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 7/132009 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 05.35A Program DEV Well bore sag ^ PTD#:2081340 Company BP EXPLORATION (ALASKA) INC Initial Classltype D EV! PEND GeoArea 890 Unft 11650 OnlOff Shore ~ Annular Disposal ^ Administration 1 PetmitfSeattaGhed----- ------------ -- -- - -------- NA---- ------ -- -- --- - ----- ----- -- - ---- -- 2 Lease number appropriate-- - -- -- --- ------ -- -- ----- -Yes-- -- -- -- ----- --- - --- - -- -- - - - ----- --- 3 Un[quewellnameandnumber----------- - - - - -Yes -- - -- -- -- -- - - ------ ------ - -------------------------- 4 .UtreBlocaked[n-adefinedp9ol--------------- -- --- -- -- ----- -Yes-- ------- -- - ---------- - ------- - -- - -- ------ 5 WelUecated pCOper distance from drilling unit_boundary_ _ _ - _ _ _ _ _ .Yes _ - _ - - - - - - - - _ - - _ ---------------------------------------------------------- 6 Well locatedP[operdistanCefromotherwells-------------------- ---------Yes--- ------------------------------------------------------------------- 7 Suffeientaoreage_ayailablein_dri[lingunit_____________________- ---____--Yes--- ----2560 acres.--._-___--.-_---_____________-------------------____-- 8 If deviated, iswelibor@Plat_included-------------------------- ---------Yes--- -----------------------------------------___--- 9 Opa[atoronlyafteotSdParlY --- ---- -- -- - - - - - Yes - ----- -- --- --------- - ----- - - --------- -------- 10 _Qperatorhas_appcoprialebandinforoe------------------------ ---------Yes--- ----Blanket@ond#6194193•--------..----------------------- 11 PetmitGaDbe[ssuedwlth2utoonseNationGrder------------- ..... .........Yes--- ------------------..---_---------------------------------------------- Appr Date 12 Petmikcanboissuedwlthoutadminist[ative.apP[oval---------------- ---------Yes--- ------.--...--------------------------.----------.---------------.___-- ACS 8!19!2008 13 CanpsrmltbeaRProvedbefore15-daY-wait---------------------- ---------Yes--- ------.------------------------------------.------------------------ 14 Well locatedwiihinareaandstrataauthor~edby-Inle~iont)rder#(ptitlQ#[n_comments).(For__NA---- ------------------------------___--_--_____--__-____-___-__--__-____ 15 -AliwelJs-wifhin114_milearea_otteviewldept[fled(Fotselvlcewellorily)------ ----------NA_-- -.--------.-------------------------------- -------------------------- 16 Pre-produced injector: duration_of pre production less than 3 months-(Ear service well only) _ _Nfl -- - - - - - - - - - - - - - - - - - - - - - - - - - ----------------- - - ------------------------- - 17 .Honconven,gas_confoRnstoAS3L05,03Qt1.1.A),Q.2.A•D)---------- -- ~---------~ -- ----- - -- - --- -- - --------- ---- -- ---- --- ---- Engineering 18 Conductorst[ing_prov[de(I-------------------------------- --------- NA---- ----ConduGtorsetinp$05.3${191.068x.--------------_------------------------------ 19 SurfeceeasiggprotectflallknownU$DWS.-----.----------- --------.NA.-- ----Noaquifers,AIO48,-ConGlusion_5------------------------------------------------ 20 CMT voladequale tQ circulate on conduoto[& suA_csg _ _ - - _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ NA_ _ _ _ _ _ _ _ SorfaGe Gasin9 satin DS 95.35_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ ------------------------- 21 CMTvo[adequaletotie•inlongstringtosladcsg- --- -- ---- -- ------ Yes - ----- -- - -------- ----- - - ------ - ----- 22 CMT-wiUcoverahknown-prods,ctivehorizons--------------------- ---------Yes--- --------------------------------------------------.-------------_----- 23 Casing desjnsadequateforC,T,B&-p~rmafrost-------.-------- --------Yes--- ------------------------------------------------------------------- 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ . _ _ _ _ Rig equipped w[th steel pits, No reserve pit planned._ All waste-to approved disposal well(s), _ _ - _ _ . _ - - - _ _ _ 25 Ifare-drill,has_atOr403 for abandonment been approved------------- ---------Yes--- ----308.282------------------------------,------------------------------- 26 Adequatewe[Ibote separation_propgsed _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _Yes - _ - - - _ -Proximity analysis performed, Nearest segment is plegged podion of DS 05,35 and paths-diverge._ _ _ _ _ _ _ - _ _ 27 If dlverterrequ[red,d2eaiimeafrsgulations---------------------- --------- NA---- ----BOPStackwilJal[eadY-be in place,---------------------------------------------- Appr Date 28 Drilling fluid program schemat[c bequip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - _ -Maximum expected fo[maiion pressure 9,2_ EMW in Gret. and_ 7.2 EMW_in ~one._ MW Planned up to 19.8 ppg in 8, TEM 6119!2008 29 BOPEs,-do they meet regulation-------------------__.---- -_ _-._--Yes--- -__---hole-and 8,5-ppgin zone.____________-________------_-,-----------__-- 30 BOPS-press rating appropriate; test to_(put psig in commerais)- - - - - - - - - - - - - - - - - - - -Yes _ _ - . _ _ _ MASP calcuJaled at 2400psi; 3500_psi_BOP tesiplanned, _ - - - _ - _ _ _ _ - - - - - - - - - - - - _ _ - - _ - - _ _ "' 31 Choke manifoldcoroRlieswlAPI-RP-53~May84)____-________ _ Yes--- ---------------------------------------------------------------___--- fffiii~~~ 32 -Work will occur withoutopera6onshutdown--------------------- ---------Yes--- -------------------------------------------------------.------------ 33 Is presence of H2S gas probab~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ . - _ - _ Weil H2S levels- be[ow_109 ppm._ likely present_in gas lift and MI, Mud should preclude formation N2$._ Rig _ _ - 34 _Mechanical_Condit[onofwellswBhinAORyerii'red(Forserv[cewellenlya----- -------- NA---- ------has sensorsaadaiarms,----------------------------------------------- Geology 35 Permit can be [slued wlo hYdrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - No_ _ - - - _ - - Max H2S lave[ on Pad=27ppm on well 05•Q56_(11I1190)._ _ _ _ _ - _ _ _ _ _ - - - _ - _ _ _ - - - _ _ - _ 36 Data-presented on Rolential overPressurezones - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 37 Se[sm[canalysisofshallowgas_zones---------.------------ - __--NA---- ---------------------_--- ------------------------------------------ - ACS 8!19!2008 38 5eabed_conditionsurvey_(ifgff•shore).----------------------- ---------NA__-_ -- - -____.-____--__---_-__.-_-_---__._--_--___---_--------__---- 39 Contactnamelphoneforweekiy-Rro9-~sreporls_[exp[oratoryon~]------ ----.---Yes--- ----JOvyRoach-584-43;i2------------------------------------------------------- Geologic Engineering Pu 'c Date Date: ' Date Commissioner. r C ner C issio~ ~~~ ~ ~ , ~,/ l Za~ QV
