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208-203
Ima a Pro t Well History File Cove~age g J 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. ~Q ~ - ~~~ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ^ Two-sided II I II I) II II II I II III DI AL DATA Diskettes, No. ^ Other, No/Type: Re~,~~~~ iuiiiiiuiuiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: gY; Maria Date: 30 V /s/ r Pro'ect Proofin III IIIIII IIIII II III J g gY; Maria Date: ~ ~ ~© /s/ Scannin Pre aration _~ x 30 = ~~ + J"r"' =TOTAL PAGES (Count does not include cover sheet) ~p ~ g /s/ Y Y ~ BY: Maria Date: 31301 /~ Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include co sheet) Page Count Matches Number in Scanning Pre aration: YES NO BY: Maria Date:3 3 ~ I ~ /sl Stage 1 If NO in stage 1, page(s) discrepancies wer found: YES NO gY; Maria Date: /s/ nin is com lete at this Dint unless rescanning is required. II I II II II III II I I III Scan g p p ReScanned III 111111 IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III IIII I 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG A(')GCC la. Well Status: ❑Oil ❑Gas ❑SPLUG ❑Other ®Abandoned ❑Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 ❑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. 3/3/2013 V 208-203 ' 313-005 ' 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 1/21/2009 50-029-21038-02-00 • 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 1/26/2009 PBU K-06B • 2146'FNL,504'FWL, Sec.04,T11 N, R14E, UM 8. KB(ft above MSL): 53.6' 15.Field/Pool(s) Top of Productive Horizon: 85'FNL, 1376'FWL,SEC.04,T11 N, R14E, UM GL(ft above MSL): 25.77' . Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) Oil Pool 311'FNL,4970'FWL, Sec.05,T11 N, R14E, UM 8820' 8383' • 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 670778 * y- 5975058 ` Zone- ASP4 -11011' 8913' ' ADL028303&ADL028304 TPI: x- 671596 y- 5977139 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 669917 y- 5976874 Zone- ASP4 None 18.Directional Survey: 0 Yes 0 N 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 MDITVD: MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX, Memory CNL, GR ,CCL 9071' 8609' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20"x 30" Insulated Conductor Surface_ Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2673' Surface 2673' 17-1/2" 3729 cu ft Permafrost'E',and PF II 9-5/8" 47# L-80 Surface 8142' Surface 7754' 12-1/4" 1338 cu ft Class'G',575 cu ft Class'G',133 cu ft PF'C' 7" 26# L-80 7977' _ 8809' 7599' _ 8373' 8-1/2" 225 cu ft Class'G' 4-1/2" 12.6# L-80 8635' 9071' 8214' 8609' 6" 474 cu ft Class'G' 3-1/2"x3-3/16"x2-7/8" 9.2#x6.2#x6.16# L-80 8845' 11011' 8405' 8913' _ 4-1/8" 158 cu ft Class'G' 24. Open to production or injection? ❑Yes ®No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ( ) ( ) 4-1/2", 12.6#, L-80 8632' 8575'/8158' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes IN No • SCANNED AUG 0 2 2013 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED a7 8820' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested, Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 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 0 No • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS IMR 4 8 2813M Form 10-407 Revised 10/2012 CONTINUED ON REVERSE t''Lr �y�j Submit Original Only nk ill 41iq / `3 29. GEOLOGIC MARKERS(List all formations an kers encounter 30. FORMATION TESTS NAME 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. 23SB 9077' 8614' None 22TS 9128' 8662' 21TS/Zone 2A 9178' 8710' Zone 1B 9240' 8766' TDF/Zone 1A 9307' 8816' • Formation at Total Depth: 31.List of Attachment Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Johnston,564- 985 Email: David.Johnston2 @bp.com Printed Name: Jo,.L ufka Title: Drilling Technologist 2 Signature: Phone 564-4091 Date:J/2(o/13 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 la: 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 MC 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 MC 25.071. Form 10-407 Revised 10/2012 Submit Original Only • K-06B, Well History (Pre Rig Sidetrack) Date Summary 11/09/12 RAN PDS 40 ARM CALIPER FROM 8,823'SLM TO SURFACE(Good data). UNABLE TO PASS 8,387' SLM W/3.70"x 20'DUMMY WHIPSTOCK(Nothing there). CLEARED TIGHT SPOTS FROM 8,385'TO 8,565'SLM W/3.78"G-RING,4-1/2"BRUSH. DRIFT TO TOL @ 8,815'SLM/8,845'MD W/3.70"x 20' DUMMY WHIPSTOCK. SET 4-1/2"X-CATCHER SUB @ 8,583'SLM/8,599'MD. PULLED RK-OGLV FROM ST#3(5,715'MD)PULLED RK-LGLV FROM ST#4(3,245'MD). SET RK-DGLV AT ST#4 (3,245'MD). LRS CURRENTLY RIGGING UP TO IA TO LOAD W/370 BBLS OF CRUDE. T/1/0=2450/2280/9 Assist Slickline(Obj: CTD Screen)Spear in IA with 5 bbls of meth and pumped 68 bbls of crude,Stopped the job had a leak on LRS iron.SD and got the proper calls started. SRT did respond and confirmed a 1 gal leak onto WH and pad around the WH.continued WSR on next day. 11/10/12 Pumped 372 bbls of crude down IA to load.(305 bbls to SO)SSL set DGLV. Pumped 200 bbls of crude down tbg to load. Pumped 5 bbls crude down IA for MIT-IA.1 st 15 min loss of 39 •si,2nd 15 min loss of 12,,si_for total loss of 51_psi_[Passed). Pumped 5 bbls of crude down OA to reach test pressure.OA @ 15 min lost 40 psi and @ 30 min it lost 20 psi for a total of 60 psi in a 30 min test(PASSED)bled OA to 0 psi and RDMO.SSL in control of WH @ time of LRS departure. IA,OA=open called DSO when leaving, FWHP=179/535/0. (Drlg screening). LRS LOADED IA W/370 BBLS OF CRUDE.SET RK-DLGV AT ST #3(5,715'MD). LRS PUMPED 33 BBLS OF CRUDE AND TUBING PRESSURED UP. PULLED EMPTY 4-1/2"X-CATCHER SUB FROM 8,599'MD. LRS LOADED TUBING W/200 BBLS OF CRUDE. RE-SET X-CATCHER AT 8,599'MD. LRS PERFORMED SUCCESSFUL MIT-1A TO 3000 PSI (Bled pressure back to 500 psi). LRS PERFORMED SUCCESSFUL MIT-OA TO 2000 PSI Currently bleeding back to 0 psi). 11/11/12 PULLED EMPTY 4-1/2"X-CATCHER SUB FROM 8,583'SLM/8,599'MD. 11/14/12 T/1/0=SSV/400/0 Temp=SI PPPOT-T(PASS)PPPOT-IC(PASS)RWO Screen. PPPOT-T:Stung into test void(2100 psi.). Bled void to 0 psi. Functioned LDS all moved freely(2.5"). Pumped through void, good returns. Pressured test void to 5000 psi.for 30 min.test. Lost 200 psi. in 15 min. Lost 50 psi. in second 15 min.(PASS). Bled void to 0 psi. PPPOT-IC:Stung into test void(200 psi.).Bled void to 0 psi. Functioned LDS all moved freely(2.5"). Pumped through void,good returns. Pressured test void to 3500 psi.for 30 min.test. Lost 100 psi. in 15 min. Lost 0 psi. in second 15 min.(PASS). Bled void to 0 psi. 02/13/13 DRIFT TO 9,271'SLM W/2.25"CENT.&S. BAILER(recovered parrafin). RUN SBHPS,ADJUST BTM STOP DUE TO TAG DEPTH(good data,see data tab). DRIFT TO 8836'SLM(8845'MD)W/20'OF 3.70"DMY WHIPSTOCK. 02/22/13 T/I/O =2500/480/0.Temp=SI.WHPs(Pre CTD). No AL. IA FL @ surface. SV, WV, SSV=C. MV= 0. IA, OA= OTG. NOVP. 15:00 hrs. 02/23/13 T/I/O=SSV/500/5.Temp=SI. Bleed IAP&OAP to 0 psi.(Pre-RIG). IA FL @ Surface. IAP increased 20 psi since day shift. Bled IAP from 500 psi to 0 psi in 30 minutes, maintained open bleed for an additional hour.SI &monitor for 30 minutes.OAP decreased to 0 psi during IAP bleed. No change in IAP during 30 minute monitor. Final WHP's=SSV/0/0. Job Complete. SV,WV&SSV=C. MV=0. IA&OA=OTG. NOVP. Page 1 of 2 • • K-06B, Well History (Pre Rig Sidetrack) Date Summary 02/26/13 T/I/0=2460/0/0. Conduct PJSM. Barriers=Swab Valve/SSV.Start Barrier list=Swab closed and SSV valve closed. Performed LTT on SSV and Swab independently.(Passed)Rigged up lubricator and 7x4 crossover. Pressure tested to 250 psi low and 3500 psi high for 5 min each.(Passed)Set 4"CIW"H TWC#288 at 118"with 1'ext.Verified TWC holding from below.Shut in SSV and removed 4"tapped companion blind and installed solid 4"5K blind.Torqued MV x THA and companion blind flange to API spec(726 ft.lbs). Pressure tested tree to 250 psi low and 5000 psi high for 5 min each.(Passed)Rigged down lubricator and installed tree cap and pressure tested to 500 psi.(Passed)All tree tests charted and saved to TRP folder and TWC sign installed. Page 2 of 2 NNW • • • ,, t�rAre�ca=ALAS 1401$ k'''t7r:tt,fr;;34-ytiriat/f4Vihe',1 r" Operation Summary - Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor.NORDIC CALISTA UWI:/Lat:070°20'15.988"8 Long: 0148°36'51.258"W Active datum:ORIG KELLY BUSHING @62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/27/2013 04:00 - 04:30 0.50 RIGD P PRE HOLD PJSM WITH ALL CREWS BEFORE SWAPPING THE REEL.DISCUSS ROLES& RESPONSIBILITIES,HAZARD OF OVERHEAD WEIGHT AND GOOD COMMUNICATION. 04:30 - 05:45 1.25 RIGD P PRE SPOT TRAILER BENEATH REELHOUSE.OPEN BOMBAY DOOR AND LOWER DOWN REEL. CHAIN REEL TO TRAILER AND PULL AWAY FROM UNDERNEATH REELHOUSE. 05:45 - 06:00 0.25 RIGD P PRE HQLD AAR FOR LOWERING DOWN 2"REEL AjJD SPOT TRAILER WITH NEW 2-3/8"REEL 06:00 - 07:30 1.50 RIGD P PRE PERFOI CREW CHANGE. PREP REELHOUSE-FOR 2-3/8"REEL. ORDER OUT DIRTY TRUCK TO EMPTY CUTTINGS BOX. 07:30 - 08:30 1.00 RIGD P PRE HOLD PJSM ON BRINGING IN 2-3/8"COIL REEL. DISCUSS PROPER COMMUNICATION, RESTRICTING ACCESS TO THE PAD DURING SWAP AND AS SIGN PEOPLE TO POSITIONS. ATTEMPT TO SPOT 2-3/8"REEL UNDER REEL HOUSE. TRUCK UNABLE TO BACK UP DUE TO ISSUES WITH TRAILER. _ SIM OPS-DIRTY TRUCK EMPTIES CUTTINGS .`.,.BOX WHILE STAYING CLEAR OF REEL HOUSE AREA. 08:30 - 09:00 0.50 RIGD P PRE ASSESS SITUATION WITH REEL TRAILER. APPLY HEAT TO HUBS,IMPROVE TRACTION IN WORK AREA BY SPREADING NUT PLUG. 09:00 - 09:30 0.50 RIGD P PRE TRAILER IN POSITION. RAISE 2-3/8"REEL INTO REEL HOUSE AND SECURE. 09:30 - 12:30 3.00 RIGD P - PRE PREP FOR RIG MOVE. CLEAR SNOW&RD AUXILLARY EQUIPMENT. 12:30 - 13:00 0.50 RIGD R°s PRE HOLD PJSM TO DISCUSS JACK UP& BACKING RIG OFF WELL. 13:00 - 22:30 9.50 MOB P PRE MOVE RIG FROM DS 7 TO K PAD. PATH OF ROUTE:LEFT OFF DS 7 ONTO OXBOW,LEFT ONTO WEST DOCK,LEFT ON TWIN TOWERS ROAD,LEFT INTO K PAD ACCESS ROAD. SPOT RIG ON SIDE OF PAD UNTIL RIG MATS ARE LAID DOWN. 22:30 - 00:00 1.50 MOB P PRE WAIT FOR RIG MATS TO BE DELIVERED FROM DS7TOKPAD. 2/28/2013 00:00 - 00:15 0.25 RIGU P PRE HOLD PJSM. DISCUSS AWARENESS WHEN BACKING IN RIG,MAKING SURE ALL PERSONNEL ARE OUT OF THE LINE OF FIRE &TO KEEP A CLOSE EYE ON THE TREE TO AVOID BACKING INTO IT. ANYONE CAN STOP THE JOB IF ANYTHING LOOKS OUT OF THE NORM. 00:15 - 02:00 1.75 RIGU P PRE PLACE MATS AROUND WELL CELLAR. BACK IN RIG&MOVE OVER THE WELL. ACCEPT RIG AT 02:00. 02:00 - 03:30 1.50 RIGD P PRE SET UP TO LTT SWAB VALVE. PERFORM PASSING BREAKING CONTAINMENT TEST ON TREE CAP TO 3500 PSI. NO LEAKS OBSERVED. ND TREE CAP. Printed 3/18/2013 3:52:01PM • • /','r J��? ,'i Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°20'15.988"8 Long: 0148°36'51.258"W Active datum:ORIG KELLY BUSHING @62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (usft) 03:30 - 08:00 4.50 RIGD P PRE NU BOP STACK MU LUBRICATOR INSTALL HOT TUB GREASE MUD CROSS VALVES 08:00 - 09:15 1.25 RIGU P PRE FUNCTION TEST BOP FROM KOOMEY,OPS CAB&RIG FLOOR. .-FILL MGS 09:15 - 10:00 0.75 RIGU P PRE, FLUID PACK THE STACK TO SHELL TEST 10:00 - 11:15 1.25 RIGU N MISC PRE --CHART RECORDER PEN ARM IS BROKEN, CLL TOOL SERVICES TO BRING ANOTHER !� CHART RECORDER OUT 11:15 - 14:00 2.75 BOPSUR P PRE PERFORM.INITIAL BOP, TEST TO 250-PSI/3500, I. HOLD&CHART 0 EAtI4TEST FOR 5-MIN.U . ALL TESTS WITNESSP AOGCC REP CHUCK SHEAVE 14:00 - 15:00 1.00 BOPSUR N SEAL PRE CHOKE VALVE#2 FAILED,SERVICED AND FAILED 2ND TEST 15:00 - 16:45 1.75 BOPSUR P FARE CONTINUE TESTNG BOPE 16:45 - 17:30 0.75 BOPSUR P PRE , PERFORM ACCUMULATOR DRAWDOWN TEST. -STARTING ACCUMULATOR PRESSURE_ 3,000 PSI -FINAL PRESSURE AFTER FUNCTIONING �.. w -, ALL PREVENTERS AND HCR=2,000 PSI -14 SEC TO BUILD 200 PSI,94 SEC TO i l FULL PRESSURE -3 NITROGEN BACKUP BOTTLES WITH 2,000 PSI. 17:30 - 18:00 0.50 BOPSUR-. . P PRE BOP TEST COMPLETED RIG EVAC DRILL WITH DAY CREW 18:00 - 18:30 0.50 RIGU P PRE HOLD PJSM BEFORE PICKING UP INJECTOR AND PULLING COIL ACROSS THE ROOF. 18:30 - 20:20 1.83 RIGU P PRE PULLED WINCH CABLE THROUGH INJECTOR, PU INJECTOR AND MU NIGHTCAP TO LUBRICATOR. MEANHWILE REDRESS CHOKE-MANIFOLD VALVE#2. 20:20 - 20:50 0.50 RIGU P PRE MU GRAPPLE TO SECURED COIL. MEANWHILE PERFORM PRESSURE TEST ON CHOKE-MANIFOLD VALVE#2. 20:50 - 21:20 0.50 RIGU P PRE GIVE SCHLUMBERGER CREW TIME TO PERFORM CREW CHANGE AND DISCUSS WAY FORWARD. 21:20 - 22:50 1.50 RIGU P PRE BRING REEL IN POSITION AND PERFORM PULL TEST WITH PULL-BACK WINCH ON GRAPPLE. PULL COIL ACROSS ROOF,PULL THROUGH GOOSENECK AND STAB INTO INJECTOR. 22:50 - 23:30 0.67 RIGU P PRE PULL COIL THROUGH INJECTOR AND BOOT ELINE. 23:30 - 00:00 0.50 RIGU P PRE PERFORM RIG EVACUATION DRILL WITH ALL CREWS. OBSERVE THAT NO AUDIBLE ALARMS FUNCTION ON INITIAL ACTIVATION, HOWEVER ONCE THE SYSTEM IS RESET THE SIREN ON THE RIG'S BACK END WORKS AGAIN-THE ALARM ON THE REEL HOUSE APPEARS TO BE FROZEN IN. Printed 3/18/2013 3:52:01 PM NNW • • • Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°20'15.988"8 Long: 0148°36'51.258"W Active datum:ORIG KELLY BUSHING @62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations hr) (usft) 3/1/2013 00:00 - 01:30 1.50 RIGU P PRE HOLD PJSM AND FILL OUT WORKING AT HEIGHT PERMIT. STAB ON INJECTOR.AND CLOSE ALL CLAMPS ON GOOSENECK WHICH HAD BEEN OPENED WHEN RUNING COIL THROUGH GOOSENECK. 01:30 - 03:00 1.50 RIGU P PRE LINE UP METHANOL PUP AND AND PUSH 5BBLS OF NEAT METHANOL FOLLOWED BY HQT FRESHWATER INSIDE COIL.CLOSE INNER REEL VALVE AND PERFORM PRESSURE-TEST ON REEL HOUSE IRON TO 250PSI AN s 3,500PSI.ACHIEVE GOOD TEST. 03:00 - 03:30 0.50 RIGU P PRE OPEN UP IRVV AND FILL COIL WITH WARM (80degF)FRESH WATER TAKING RETURNS INTO PIT#4.. 03:30 - 04:10 0.67 RIGU PRE REARRANGE LINE-UP AND REVERSE CIRCULATE FRESH WATER BACK INTO COIL UNTIL THERE IS NO E-LINE MOVEMENT TO BE HEARD INSIDE THE COIL ANYMORE. BLOW BACK—5BBLS WATER OUT OF THE COIL TO FREEZE-PROTECT GOOSENECK. 04:10 - 04:30 0.33 RIGU `, P " PRE -"POP OFF INJECTOR AND PREPARE FOR TTING COIL. t l '-., MEANWHILE LOADING 8.5PPG MUD INTO. C.- " l PITS. 04:30 - 06:30 2.00'', 'RIGU', N ,' SFAL PRE NOTICED A PRESSURE-DEVIATION ON THE -.0 PACK-OFFS.CALL OUT SLB MECHANIC AND PERFORM MAINTENANCE&REPAIR ON POWER PACK.MECHANICS DISCOVER A FROZEN AIR LINE AND THAW UP SAME. 06:30 - 06:55 0.42 RIGU P PRE CTS AIR SUPPLY RESTORED HOLD PJSM TO CUT COIL 06:55 - 07:25 0.50 RIGU P PRE RU CUTTER CUT—300'OF COIL 07:25 - 08:10 0.75 RIGU P PRE CUT 300'NO WIRE,RD CUTTER MU CTC AND PULL TEST TO 35K 08:10 - 09:00 0.83 RIGU P -_ PRE MU 5'STINGER,STAB ON TO PUMP SLACK FORWARD 09:00 - 09:30 0.50 RIGU P -_ PRE UNSTAB COIL AND MEG TEST ELINE GOOD TEST 09:30 - 10:30 1.00 RIGU P PRE HEAD UP BHI UQC 10:30 - 10:45 0.25 RIGU P -_ PRE PT CTC AND UQC TO 3500 PSI GOOD TEST 10:45 - 11:30 0.75 BOPSUR P PRE STAB ON AND PT PACK OFF,LUBRICATOR AND INNER REEL VALVE TO COMPLETE BOP TEST GOOD LOW PT,INCREASE TO HIGH 11:30 - 12:15 0.75 RIGU P PRE GOOD PRESSURE TEST,OPEN CHOKE AND LINE UP TO CIRC COIL PU INJECTOR AND INSTALL BHI UQC CHECK VALVES AND TEST 12:15 - 12:45 0.50 BOPSUR P ■- PRE GOOD TEST THE BHI M VALVES REMOVE TEST T SUB AND MOVE OVE I NJECTOR TO THE SIDE TO CIRCULATE Printed 3/18/2013 3:52:01PM • • :'•,�, .//E,.�rf .;;r�rr , Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor.NORDIC CALISTA U M:/Let:070°20'15.988"8 Long: 0148°36'51.258"W Active datum:ORIG KELLY BUSHING i62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:45 - 14:30 1.75 MOB N WSEQ PRE PJSM TO LOAD VALVE CREW LUBRICATOR ON THE RIG 13:00 RU EXTENSION BARS TO PULL TWC 13:15 MU LUBRICATOR TO TEST THEN PULL TWC 13:25 PT LUBRICATOR —,13:55 GOOD PT,BLEED OFF AND OPEN VALVES TO PULL TWC 14:20 HAVING PROBLEMS GETTING THE SSV OPEN,SWAB CYCLED FINE 14:30 - 17:00 2.50 MOB N MISC PRE SSV STILL WON'T CYCLE,APPLY PRESSURE WITH THE TEST PUMP ABOVE THE SSV TO SEE IF THERE IS PRESSURE BELOW -PRESSURED OP TO 2,000'?SI AND NO MOVEMENT FROM THE SSV STEM PRESSURED UP TO 4,100 PSI AND STILL NO MOVEMENT VALVE CREW SUPT INSTALLED HIS 10K PRESSURE BLEED VALVE ON THE MASTER GREASE STEM AND PRESSURE SHOWED 10K,BLED THE PRESSURE OFF AND INFORMED WSL.WSL MADE PHONE CALL TO D�2ILLING SUPT AND WE DISCUSSED WHAT WE FOUND.JUST TO MAKE SURE THE VALVE ti CREW GAUGE WAS CORRECT WE CHECKED IT WITH AND ENERPAC PUMP AND IT WAS READING THE SAME AS THE GAUGE ON THE ENERPAC.CALLED DRLG SUPT AND WITH CONFORMATION THAT THE GAUGE WAS ` '~R CORRECT AND WE ARE WAITING FOR TREE &WELL HEAD TO DISCUSS WHAT TO DO 17:00 - 18:00 1.00 MOBS`° N MISC PRE PLAN FORWARD-INSPECT&RETORQUE TREE BOLTS THAT WERE EXPOSED TO THE PRESSURE AND SHELL TEST TREE TO 3500PSI AS PER MANUFACTURES (CAMERON)RECOMMENDATIONS 18:00 - 19:00 1.00 MOB N MISC PRE RETORQUE FOUND 5 OF THE 8 ADAPTER FLANGE BOLTS LOOSE,THE SSV BOLTS WERE TIGHT 19:00 - 19:30 0.50 MOB N MISC PRE HOLD PJSM. DISCUSS PLAN FORWARD WITH NIGHT CREW. ASSIGN ROLES& RESPONSIBILITIES. DISCUSS HAZARDS WHILE WORKING WITH PRESSURE AND ENSURE RIG CREW IS OUT OF THE LINE OF FIRE WHEN PRESSURING UP. KEEP SAFE DISTANCE FROM TREE WHILE MONITORING FOR LEAKS. 19:30 - 20:15 0.75 BOPSUR N MISC PRE PERFORM PRESSURE TEST ON TREE. LOW PRESSURE TEST PASSED 300 PSI/5 MIN& HIGH PRESSURE TEST PASSED 3,500 PSI/5 MIN. 20:15 - 20:30 0.25 BOPSUR N MISC PRE HOLD PJSM.DISCUSS HAZARDS OF WORKING WITH PRESSURE,REVIEW PROCEDURES FOR BLEEDING OFF GAS. MOVE TRUCKS AWAY FROM TIGERTANK TO ELIMINATE IGNITION SOURCES AND MAKE 1 NOTIFICATIONS TO PAD OP AND SECURITY BEFORE VENTING OFF GAS. Printed 3/18/2013 3:52:01PM • • . :,„ . „ . ,„ , , . , „ , . . . . ' ' Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor:NORDIC CALISTA UW1:/Lat:070°20'15.988"8 Long: 0148°36'51.258"W Active datum:ORIG KELLY BUSHING @62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 22:00 1.50 BOPSUR N MISC PRE DUMP SSV TO ENSURE IT STROKES PROPERLY.FUNCTION SSV AND NOTICE VERY SLOW TRAVEL(TAKES-2MINS TO OPEN FULLY).MEASURE STEM TO CONFIRM FULL TRAVEL:SEE 4-1/2"TRAVEL,SO VALVE FUNCTIONS PROPERLY. -PULL TWC OUT OF PROFILE&PULL UP INTO LUBRICATQ$. SEE 2,380 PSI ON 1-UBRICATOR.LINE UP CHOKE AND OPEN UP TO TAKE GAS RETURNS TO TIGERTANK, THEN BLEED OFF PRESSURE FROM LUBRICATOR. PERFORM NO FLOW CHECK WITH MASTER,SSV&SWAB CLOSED. NO PRESSURE BUILDUP IN 5 MINS. POP OFF LUBRICATOR&LD TWC&LUBRICATOR. OFFLOAD VALVE SHOP EQUIPMENT FROM RIG. 22:00 - 23:00 1.00 BOPSUR N MISC PRE POP LUBRICATOR AND RECOVER TWC.TWC IS.COMPLETE WITH ALL RUBBERS AND SEALS. LINE UP AND FREEZE-PROTECT HARDLINE TO TIGERTANK WITH METHANOL. 23:00 - 23:15 0.25 BOPSUR ht MISC PRE HOLD PJSM.DISCUSS WORKING WITH PRESSURE(2,500PSI BELOW SWAB VALVE), DEALING WITH METHANOL AND DISCUSS PUMP SCHEDULE.AGREE THAT IN ORDER TO ACHIEVE A SUFFICIENT PUMP RATE OF AT LEAST 4.5BPM,WE NEED TO FREEZE-PROTECT THE COIL AND BULLHEAD WITH BOTH PUMPS. 23:15 - 23:45 0.50 BOPSUR N MISC PRE INSTALL NIGHT CAP,RIG UP TEST PUMP AND PRESSURE-TEST TO 300PSI/5MINS AND 3,500PSI/5MINS. 23:45 - 00:00 0.25 BOPSUR N MISC PRE RE-ROUTE METHANOL TO BE ABLE TO PUMP 5BBLS METHANOL INTO COIL. 3/2/2013 00:00 - 01:00 1.00 BOPSUR N MISC PRE LOAD 5BBLS METHANOL INTO COIL AND PUMP OVER GOOSENECK. 01:00 - 03:00 2.00 BOPSUR N MISC PRE EQUALIZE PRESSURES ACROSS THE SWAB, THEN OPEN MASTERVALVE AND SWAB VALVE.OBSERVE 1,200PSI SIWHP. COMMENCE BULLHEADING OPS BY PUMPING A 1OBBLS METHANOL-SPEAR FOLLOWED BY 1%KCL WITH BOTH PUMPS.PUMP AWAY 290BBLS KCL AT 6.OBPM AND 2,161 PSI CIRC PRESSURE. LINE UP TO PITS AND PUMP 4OBBLS 8.5PPG MUD BEFORE PUMPING FURTHER 4OBBLS HI-Vf5 875PPr;M O.DISPLACE FII VIS MUD CLOSETOTOP UF PERFORATIONS AND START SLOWING DOWN PUMPS SLIGHTLY FROM 6BPM TO-5.5BPM.SEE NO CHANGE IN CIRC PRESSURE AS HI-VIS MUD HITS FORMATION.DISPLACE ALL 4OBBLS INTO FORMATION SEEING NO CHANGE IN CIRC PRESSURE.STOP PUMPING.OBSERVE -1,000PSI WHP. Printed 3/18/2013 3:52:01PM NNW • • Common Well Name:K-06 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°20'15.988"8 Long: 0148°36'51.258"W Active datum:ORIG KELLY BUSHING @62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 04:00 1.00 BOPSUR N MISC PRE ONCE PUMPS ARE STOPPED,BLEED DOWN PRESSURE.OPEN UP NEEDLE VALVE ON NIGHTCAP TO CONFIRM THAT THE WELL IS NOT ON A VACUUM.CIRCULATE ACROSS AND GET 1:1 RETURNS,THEN FLOWCHECK WELL FOR 30MINS. ACHIEVE GOOD NO-FLOWAND CONTINUE CIRCULATING ACROSS WELL AT 0.5BPM GETTING FULL RETURNS AND KEEPING HOLE FULL. 04:00 - 05:15 1.25 WHIP N MISC WEXIT HOLD PJSM,THEN LOAD BTT-TOOLS ONTO RIGFLOOR.PREP BTT WHIPSTOCK RUNNING TOOL FOR RIH. 05:15 - 05:45 0.50 WHIP N MISC WEXIT ~U WHIPSTOCK RUNNING BHA(BHA#11 WITH HYDRAULIC ORIENTER AND BOT .HYDRAULIC SETTING TOOL AND 3.70" KB-PACKER. 05:45 - 06:00 0.25 WHIP MISC WEXIT STAB ON INJETOR AND PRESSURE-TEST QTS TO 300PSI/SMISN AND 3,500PSI/5MINS. ACHIEVE GOOD TEST. 06:00 - 07:45 1.75 WHIP —N MISC WEXIT RIH W/ RUNNINGBHA(BHA#1) 7000'LOST 2 BBLS TO THE FORMATION WHILE RIH 07:45 - 08:00 0.k5 N DFAL 7,000.00 WEXIT LOST COMMS TO THE TOOL,CHECK ALL SURFACE LINES AND CTS J-BOX 08:00 - 09:15 1.25`. WHIP N DFAL 7,000.00 WEXIT ALL SURFACE LINES ARE GOOD,POOH TO CHECK UQC AND MWD P&C 09:15 - 09:40 0.42 WHIP N DFAL -. 7,000.00 ' WEXIT STOP POOH,OUT DENSITY DROPPED OFF THEN CAME BACK UP.RETURNS ARE 1:1 BUT SHUT DOWN PUMP TO FLOW CHECK THE WELL 0 READING ON GAS DETECTORS,CHECKED THE SHAKER AND WE HAVE SOME CROSS LINKED MUD ON THE SCREENS,LOOKS LIKE WE HAVE A LITTLE METHANOL IN OUR SYSTEM TRIP SHEET SHOWS A LOSS OF 3 BBLS 09:40 - 09:50 0.17 WHIP N DFAL 7,000.00 WEXIT GOOD NO FLOW CHECK,COME ONLINE WITH PUMP AND PUMP A BOTTOMS UP FROM HERE(-15 BBLS)TO SEE IF WE HAVE ANYMORE CLABBERED UP MUD IN THE WELL 09:50 - 10:05 0.25 WHIP N DFAL 7,000.00 WEXIT PUMPED 16 BBLS AND EVERYTHING LOOKS GOOD,RETURNS ARE 1:1 AND OUT DENSITY IS STABLE,CONTINUE POOH 10:05 - 10:15 0.17 WHIP N DFAL 7,000.00 WEXIT PJSM TO CHECK BHA FOR ELINE FAILURE, SUSPECT UQC SHORT RETURN RATE&DENSITY ARE GOOD 10:15 - 10:20 0.08 WHIP N DFAL 7,000.00 WEXIT FLOW CHECK WELL 10:20 - 10:30 0.17 WHIP N DFAL 7,000.00 WEXIT GOOD NO FLOW CHECK,TAG UP,REMOVE INJECTOR AND CHECK THE UQC. BHI WANTS TO CHANGE OUT THE UPPER PART OF THE MWD 10:30 - 11:00 0.50 WHIP N DFAL 7,000.00 WEXIT MEG TEST FAILED,LOOKS LIKE THE LINE IS SHORTED OUT IN THE UQC MOVE THE INJECTOR TO THE SIDE AND PULL THE BHA WS&KB PACKER LOOK GOOD Printed 3/18/2013 3:52:01PM • • North America-".' °° •1" ' ' Operation Summary Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor:NORDIC CALISTA WI:/Lat:070°20'15.988"8 Long: 0148°36'51.258'W Active datum:ORIG KELLY BUSHING©62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 14:00 3.00 WHIP N DFAL 7,000.00 WEXIT MWD CHECKED OUT OK,FAILURE IS IN THE UQC ELINE CHECKS OUT GOOD,CHECKING FLOW SUB WITH NEW BOOTS AND STILL GETTING A BAD TEST STRIP BACK MORE WIRE AND REHEAD 14:00 - 15:55 1.92 WHIP N DFAL 7,000.00 WEXIT- -GOOD TEST ON REHEAD,MU BHA#2,TEST SITS AND RIH 15:55 - 17:30 1.58 WHIP N MISC q WEXIT 'LQG TIE IN 17:30 - 17:50 0.33 WHIP N MISC WEXIT GETTING A LITTLE TRIP GAS, SHUT DOWN THE PUMP AND MONITOR THE WELL. GOTA LITTLE INCREASED FLOW FROM THE WELL THEN DIED RIGHT OFF.CAME BACK ONLINE WITH THE PUMP AND OUT DENSITY STARTED DROPPING AND WE ARE SEEING =1-2%METHANE AT THE SHAKER,SHUT DOWN THE PUMP AND OUT RATE AND METHANE DROPPED OFF TOO FLOW. CALLED THE DRLG SUPT WHILE LINING UP THROUGH THE MGS AND DISCUSSED OUR WELL CONDITIONS. CAME BACK ONLINE WITH THE PUMP '-.THROUGH THE MGS AND RETURNS ARE STABLE AND DENSITY IS NORMAL,ZERO OUT MM FOR BOTTOMS UP. 17:50 - 19:00 1.17 WHIP, N MISC WEXIT RETURNS ARE STABLE AND CLEAN, CONTINUE LOGGING DOWN WHILE TAKING RETURNS THROUGH THE MGS FOR THE REST OF THIS TRIP 19:00 - 19:20 0.33 WHIP ,N MISC WEXIT COMPLETE LOGGING AND RIH AT 33FT/MIN. PVT=318BBLS / MM-IN=1.00BPM / MM-OUT=1.13BPM / CIRC P=1,260PSI n- TAG DEPLOYMENT SLEEVE AT 8,838.8'.PU AND SEE BREAKOVER 8,836.4'.GEO CALLS AND ASKS TO REPEAT LOG FOR TIE-IN.PU TO 8,810'AND RELOG SECTION AT 100FT/HR. COMPLETE LOGGING TIE IN TO TOP OF SAG RIVER SAND,AND PERFORM A+4FT DEPTH CORRECTION. 19:20 - 19:30 0.17 WHIP N MISC WEXIT RIH BACK TO WHIPSTOCK SETTING DEPTH AT 10FT/MIN.PVT=319BBLS / MM-IN= 1.00BPM / MM-OUT=1.01BPM / CIRC P= 1,234PSI. TAG DEPLOYMENT SLEEVE AT 8,842.7'AND_ RE-TAG AT 8,842.0'.PU AND SEE BREAKOVER 8,840.4'.PU FURTHER 1FT TO 8,839.4'. 19:30 - 19:40 0.17 WHIP N MISC WEXIT CONFIRM WHIPSTOCK IS ORIENTED TO 0? HIGHSIDE,THEN VERIFY SETTING DEPTH WITH GEO.SHUT IN PUMPS,THEN CLOSE EDC. BRING PUMPS ONLINE AND SHEAR SETTING TOOL AT 2,100PSI CIRC PRESSURE.SIT DOWN 3,000LBS CT WEIGHT TO CONFIRM WHIPSTOCK IS PROPERLY SET.WS DOESN'T MOVE. 19:40 - 20:30 0.83 WHIP N MISC WEXIT PU TO 8,820'.OPEN EDC AND PUMP BOTTOMS UP. Printed 3/18/2013 3:52:01PM • • • • ," .!//% i//'iiJ///`,'rr/%i-'/��i , ire%ii�� Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°20'15.988"8 Long: 0148°36'51.258"W Active datum:ORIG KELLY BUSHING©62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 22:30 2.00 WHIP N MISC WEXIT POOH WITH WS SETTING TOOL(BHA#1)AT 100FT/MIN. MM-IN=3.10BPM / MM-OUT=2.72BPM / CIRC P=2,552PSI PERFORM FLOW CHECK AT 200'-NO FLOW. POOH TO SURFACE. 22:30 - 23:15 0.75 WHIP N MISC WEXIT RU'INJECTOR&LD BHA#2(WHIPSTOCK SETTING BHA) 23:15 - 23:45 0.50 STWHIP P WEXIT MU BHA#3(WINDOW MILLING BHA),2 7/8" STRAIGHT MOTOR,HCC 3.80"WHIPSTOCK MILL&STRING REAMER. GAUGE WHIPSTOCK MILL AT 3.80"GO/3.79"NO GO. PT QTS 300 PSI/5 MIN&3500 PSI/5 MIN- BOTH TESTS PASSED. 23:45 - 00:00 0.25 STWHIP P WEXIT RIH W/BHA#3(WINDOW MILLING BHA) PVT=277 BBLS 3/3/2013 00:00 - 00:45 0.75 STWHIP r P WEXIT CONTINUE RIH TO 5000'. 00:45 - 01:15 0.50 STWHIP P WEXIT `**CONDUCTED COMPLEX KICK WHILE TRIPPING DRILL********* SLB,DRILLER ANNOUNCED AN INCREASE IN RETURNS ON THE IN-MICROMOTION.WSL CALLED ON THE RADIO TO STOP RIH AND SHUT DOWN PUMPS TO FLOWCHECK WELL. WSL ASKED SLB DRILLER TO BRING ON PUMPS AT MIN PUMPRATE TO SIMULATE ONGOING FLOWTO PITS.NORDIC DRILLER ANNOUNCED THAT HE OBSERVED AN ONGOING FLOW INTO THE POSSUM BELLY AND CALLED HIS CREW ONTO THEIR POSITIONS.EACH CREW MEMBER REPORTED ON POSITION WITHIN SECONDS. WSL ASKED TO SIMULATE SHUTTING IN THE WELL WITH THE HCR AND EQUALIZING ACROSS THE HCR AT THE CHOKE MANIFOLD. THE WSL THEN ASKED'J SHUT IN THE PUMPS SO NORDIC DRILLER COULD LINE UP TO THE CLOSED CHOKE.FOLLOWING THAT THE MUDPUMPS WERE SLOWLY BROUGHT ONLINE TO APPLY 200PSI AGAINST THE CLOSED CHOKE. THE CHOKE WAS THEN SLOWLY OPENED MAINTAINING THE 200PSI WELLHEAD PRESSURE IN ORDER TO SIMULATE MAINTAINING A STEADY BOTTOMHOLE PRESSURE.CONSTANT CASING PRESSURE WAS KEPT UNTIL PUMPS WERE UP TO SPEED,THEN CONSTANT COILED TUBING PRESSURE WAS MAINTAINED UNTILA SIMULATED FIRST CIRCULATION WAS COMPLETED. HELD AAR AND DISCUSSED THE PERFORMANCE OF THE SECOND CIRCULATION WITH KILL WEIGHT FLUID. EXCELLENT PERFORMANCE BY ALL NORDIC &SLB CREWS!!! 01:15 - 01:45 0.50 STWHIP P WEXIT RIH W/BHA#3 TO 8,260'. 01:45 - 03:00 1.25 STWHIP P WEXIT COMMENCE LOGGING PASS AT 90 FPM FOR THE FOLLOWING INTERVALS:8260'-8360'. APPLY-9.5'DEPTH CORRECTION. Printed 3/18/2013 3:52:01PM • J North America-ALASKA BP P //ii/r;;����! '/ i, �'• Operation Summary Repo, Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12'00:00AM Rig Release:3/11/2013 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°20'15.988"8 Long: 0148°36'51.258"W Active datum:ORIG KELLY BUSHING©62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 04:50 1.83 STWHIP P WEXIT RIH AND LOG TIE-IN FROM 8,650'-8,815'. CIRC PRESSURE=1077 PSI/ MM IN=0.77 BPM / MM OUT=0.78 BPM (NO LOSSES)/ MW IN=8.56 PPG / PVT=319 BBLS / IA= 125 PSI / OA=565 PSI 04:50 - 06:00 1.17 STWHIP P WEXIT SHUT IN PUMPS AND CLOSE EDC.RIH AND TAG TOWS AT 8,819.8'.PU AND BRING PUMPS (Tt BACK ONLINE TO 2.52BPM SEEING 2,476PSI {- ✓-( .(t CIRC PRESSURE.RIH AT 1FT/MIN AND TAG JWv UP ON PINCH POINT AT 8,819.4' (PROVISIONAL DEPTH). SEE FIRST MOTORWORK AT 8,819.4'-START "TIME-MILLING THE WINDOWAT 1 FT/MIN. '' 8,819.40' / MM-IN-2.50 BPM / MM-OUT-2.56 -- BPM / CIRC P-2,483 PSI / DIFF P-366 PSI / FREESPIN-2,472 PSI 1ST FOOT TIME DRILLED TO 8,820.4'IN 1+ HOUR. 06:00 - 08:00 2.00 STWHIP j-p`•' WEXIT START TO LEAN ON MILL TO INCREASE WOB &MOTORWORK. ' , 8,820.6' / MM-IN-2.52 BPM / MM-OUT-2.54 BPM / CIRC P-2,677 PSI / DIFF P-586 PSI 08:00 - 09:30 1.80 SETVUHIP'` P WEXIT AS PER THE WELL PLAN,INCREASE WOB NOT TO EXCEED 4720#WOB OR 1160 PSI DIFFERENTIAL PRESSURE CONTINUE MILLING WINDOW FREE SPIN=2475 PSI AT 2.50 BPM WOB=2.5-3.0K CIRC PSI=2625 PSI MW IN=8.60 PPG MW OUT=8.53 PPG ECD =9.70 PPG IAP=350 PSI OAP=333 PSI PVT=324 BBLS BLED DOWN BOTH IA&OA FROM 800 PSI TO 200 PSI 09:30 - 09:45 0.25 STWHIP P WEXIT MILLED 7'TO MID POINT,ALLOW WOB TO DRILL OFF THEN CONTINUE MILLING THE LAST 1.5'AT 1'/HR 09:45 - 11:40 1.92 STWHIP P WEXIT START TIME MILLING LAST 1.5' 11:40 - 12:30 0.83 STWHIP P WEXIT WINDOW MILL AT THE BOTTOM OF THE TRAY 8.9'WINDOW 12:30 - 14:15 1.75 STWHIP P WEXIT STRING REAMER HAS EXITED THE BOTTOM OF THE WINDOW,START DRILLING 10'OF FORMATION 14:15 - 15:40 1.42 STWHIP P WEXIT 10'OF FORMATION MILLED,START 3 UP AND 3 DOWN REAM PASSES 15:40 - 16:00 0.33 STWHIP P WEXIT START LAST PASS UP WHILE PUMPING A20 BBL HI-VIS PILL 16:00 - 16:15 0.25 STWHIP P WEXIT LAST PASS UP WAS CLEAN AND THE PILL IS AT THE MILL,SHUT DOWN THE PUMP AND DRY DRIFT THE WINDOW IN BOTH DIRECTIONS DRY DRIFTS ARE CLEAN,COME ONLINE WITH PUMP AND RIH WHILE PUMPING PILL OUT 16:15 - 16:25 0.17 STWHIP P WEXIT FLOW CHECK WELL AND OPEN THE EDC 16:25 - 17:15 0.83 STWHIP P WEXIT GOOD NO FLOW CHECK,POOH AT MAX RATE Printed 3/18/2013 3:52:01PM • • ' , / Aso.1 7,t ;A Common Well Name:K-06 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/27/2013 End Date:3/9/2013 X3-01355-C:DRILL(2,734,199.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 1 Spud Date/Time:11/5/1983 12:00:00AM Rig Release:3/11/2013 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°2015.988"8 Long: 0148°36'51.258'W Active datum:ORIG KELLY BUSHING @62.92usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr (usft) 17:15 - 17:55 0.67 STWHIP P WEXIT PJSM TO CHANGE OUT BHA'S 17:55 - 18:05 0.17 STWHIP P WEXIT FLOW CHECK WELL 18:05 - 18:30 0.42 STWHIP P -_ WEXIT ' GOOD NO FLOW CHECK,REMOVE INJECTOR AND PULL BHA 18:30 - 19:15 0.75 STWHIP P WEXIT LD MILLING BHA(BHA#3).GAUGE MILLS= ' WINDOW MILL=3.78"NO GO/STRING MILL= .3.79".NO GO. CHECK.TREE BOLTS-NO TORQUING NECESSARY. 19:15 - 19:30 0.25 DRILL P PROD1 HOLD PJSM. DISCUSSED NEXT PLANNED OPERATIONS&ASSOCIATED HAZARDS. DISCUSSED PINCH POINTS,SLIPS,TRIPS& FALLS&WORKINGUNDEI7 SUSPENDED LOADS. KEY POINTS WERE TO ENSURE PROPER HAND&BODY PLACEMENT WHEN MAKING UP&PICKING UP BHA. 19:30 - 20:00 0.50 DRILL P PROD1 MV BHA#4(BUILD BHA)WITH 2-7/8"ULTRA LS MOTOR AND HYC"HELIOS"BIT WITH TORQUE CONTROL BOTTONS.STAB ON INJECTOR. PT QTS LOW 300 PSI/5 MIN- PASS&HIGH 3500 PSI/5 MIN-PASS. 20:00 - 22:10 2.17_ DR)LL , PROD1 - H W/BHA#4 TO 8,190'. 22:10 - 23:00 0.83 9RiLL ;- PROD1 COMMENCE LOGGING FOR TIE-IN AT 90 FPM FROM 8,190'-8,260'. CIRC PRESSURE=959 PSI/ MM IN=0.40 BPM / MM OUT=0.42 BPM (NO LOSSES)/ MW IN=8.59 PPG/MW OUT 8.54 PPG / PVT =319 BBLS / IA=236 PSI / OA=398 PSI 23:00 - 23:10 0.17 DRILL PROD1 APPLY DEPTH CORRECTION OF-9FT.CLOSE EDC AND CONTINUE RIH. 23:10 - 00:00 0.83 DRILL P 111 PROD1 FPM FROM 8U,690'TO BOTTOM. GGING AT 90 3/4/2013 00:00 - 00:45 0.75 DRILL P PROD1 CONTINUE TIE-IN LOGGING AT 90 FPM FROM 8,690'TO BOTTOM-MAKE+4'DEPTH CORRECTION. CIRC PRESSURE=945 PSI/ MM IN=0.26 BPM / MM OUT=0..26 BPM (NO LOSSES)/ MW IN=8.59 PPG/MW OUT 8.37 PPG / PVT =320 BBLS / IA=171 PSI / OA=308 PSI. 00:45 - 01:00 0.25 DRILL P PROD1 TAKE SLOW PUMP RATES AT 8,839': PUMP#1: PUMP#2: 2.89 BPM-2,740 PSI-120 SPM 2.95 BPM-2,780 PSI-121 SPM 1.52 BPM-1,600 PSI-63 SPM 1.55 BPM-1,620 PSI-64 SPM 0.54 BPM-1,070 PSI-22 SPM 0.54 BPM-1,070 PSI-22 SPM Printed 3/18/2013 3:52:01 PM TREE= 4"CAMERON • VHELLHEAD= MCEVOY O SAFETY NOTES: WELL ANGLE>70°@ 9353' w ACTUATOR= S _ A>33 _SON ***ORIG W EI I BORE NOT SHOWN BELOW 9-5/8 MIAL KB.BEV= v 62.92' CSG*** BE H-EV= 26.62' KOP= 3091' Max Angle= 91°@ 9467' 1999' —14-1/2"HES X NP,D=3.813' Datum MD= 9392' Datum TVD= 8800'SS 2590' H9-5/8"DV R(R 20"CONDUCTOR —I 110' I GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-318"CSG,72#,L-80,ID=12.347" H 2673' I—A 4 3245 3240 12 MUG DMY RK r 0 11/10/12 3 5715 5551 25 1 1G DMY RK r 0 11/10/12 TOP OF 7"LNR H 7977' I—^' 2 7402 7066 24 MMG DMY RK F 0 10/19/08 1 8493 8082 20 KBG2 DMY FIT r 0 10/19/08 Minimum ID =2.377" @ 9508' 3-3/16" x 2-7/8" XO 7977' --19-5/8"X 7"BKR ZXP LTP,D=6.313" TOP OF WHPSTOCK H 8142' 7991' —19-5/8"X 7"BKR HMC LNR HGR,13=6.250" 9-5/8"CSG,47#,L-80,ID=8.681" —I —8150 9-5/8"MLLOUT WINDOW(K 06A) 8142'-8158' 8564' —I4-1/2"HES X NP,D=3.813" ,"4 8575' —I 7"X 4-1/2"BKR S-3 PKR,D=3.958" 8599' —I4-112"HES X NP,D=3.813" I 8619' —14-1/2"HES XN NP,MLL®TO 3.80"(01/28/09) 4-1/2"TBG,12.6#,L-80 TDS,.0152 bpf,D ---I=3.958" 8632' 8632' H4-1/2"WLEG,D=3.958" I TOP OF 4-1/2"LNR H 8635' } 8635' ELMD TT LOGG®07!30/05 11 8635' —I 7"X 4-1/2"BKR ZXP LIP,13=4.312" 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" —I 8809' 8649' 7"X 4-1/2"BKR HMC HGR D=3.980" WHPSTOCK(03/02/13) —I 8820' 8845' H3.70"DEPLOY SLV,D=3.00" TOP OF 2-7/8"LNR H 8845' 8855' —13.70"X 3-1/2"XO PIN,ID=2.995" 3-1/2"LNR,9.2#,L-80 STL,.0087 bpf,D=2.992" H 8865' 8865' H 3-1/2"X 3-3/16"XO,13=2.786 4-1/2"MLLOUT WT'lDOW(K-06B) 9071'-9078' 7"MECHANICAL VVHPSTOCK w/RA TAG(01/19/09) —I 9069' 4 9384' H 3-3/16"HES CEP(03/12/11) 4-1/2"LNR,12.6#,L-80 BTRS,.0152 bpf,D •=3.958" H —9071 ,• .4 ∎� ■ 9508' H3-3/16"X 2-7/8"XO,ID=2.786" I PERFORATION SUMMARY ■• REF LOG: SLB LEE MCNUGR/CNL ON 01/28/09 ♦4��:�... ` 10300" H2-7/8"CIBP(06/15/10) I ANGLEAT TOP P :35° 9254' /� Note:Refer to Production DB for historical perf data 10810' —FISH-2.31"MLL SIZE SPF NTERVAL Opn/Sqz SHOT SQZ \ If` (01/27/09) 2" 6 9254-9290 C 03/14/11 3-3/16"LNR, —I 9508' I ` 2" 6 9290-9300 C 03/12/11 6.2#,L-80 TCI, 2" 6 9470-10250 C 01/29/09 .0076 bpf,D=2.80 PBTD H 10972' ;#:�• 2" 6 10400-10730 C 01/30/09 1 2" 6 10850-10960 C 01/31/09 2-7/8"LNR,6.16#,L-80 STL, H 11011' .0058 bpf,D=2.441 DATE REV BY COM/BIITS DATE REV BY COMETS PRIDHOE BAY UNIT 11/19/83 AUDI 3 INTIAL COMPLETION 01/09/13 JNU PJC MLLOUT/CONDUCTOR UPDATE WELL: K-06B 08/04/98 D16 SIDETRACK COMPLETION PERMT No:'2082030 01/29/09 NORDIC 1 CTD SDTRACK(K-06B) AA No: 50-029-21038-02 03/26/11 RRIY PJC CEP/ADM:TS(03/12-14/11) SEC 4,T11 N,R14E,2147'FNL&504'PM- 11/11/12 SWC/PJC RERF CORRECTION 11/12/12 BSE/PJC GLV C/O(11/10/12) BP Exploration(Alaska) • • w \� o \ � j j � s � THE STATE T Alaska Oil and Gas � °fALAS 1 Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OJ;, ¢. Anchorage, Alaska 99501 -3572 ALAS'' Main: 907.279.1 433 Fax: 907.276.7542 John McMullen a-o3 Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 SCANNED MAR 15 a°3 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K -06B Sundry Number: 313 -005 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 Sf` DATED this 3 I day of January, 2013. Encl. STATE OF ALASKA • 3 REC IV ALA. OIL AND GAS CONSERVATION COMMISSION ,�� , AN ID S 9 �01 1 3 / L3 APPLICATION FOR SUNDRY APPROVAL ;I 20 AAC 25.280 AOGC 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 -203 3. Address: ® Development- ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 21038 -02 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU K -06B- Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL028303 & ADL028304 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): • 11011' 8913' • 10972' 8912' • 9384', 10300' • 10810' Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2673' _ 13 -3/8" 2673' 2673' 4930 2670 Intermediate 8142' 9 -5/8" 8142' 7754' 6870 4760 Production Liner 832' 7" 7977' - 8809' 7599' - 8373' 7240 5410 Liner 436' 4 -1/2" 8635' - 9071' 8214' - 8609' 8430 7500 Liner 2166' 3 -1/2" x 3- 3/16" x 2 -7/8" 8845' - 11011' 8405' - 8913' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 9254' - 10960' 8778' - 8912' 4-1/2", 12.6# L -80 8632' Packers and SSSV Type: 7" x 4-1/2" Baker S -3 Packer Packers and SSSV 4 8575' / 8158' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® 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 1, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended - 17. I hereby certify that the f• regoing is true and correct to the best of my knowledge. Contact: David Johnston, 564 -5985 Printed Name: J1 ■ cliff n' / Title: Engineering Team Leader ail: David.Johnston2@bp.com Signat e: 44114 AP Phone: 564 -4711 Date / ,Z Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - 31 2 (e) e ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: 30 P fC$ i J� JL rS I RBDMS FEB 01 1 4* Spacing Exception Required? ❑ Yes L-+1 No Subsequent Form Required: / — ^ 'r v i APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: / " 3/ l3 For 1 0 TOT 0 0 2 Submit In Duplica 1. y, Approved application is valid for 12 months from the date of approval � RL. r i/3 i J) 3 �\ • • To: Alaska Oil & Gas Conservation Commission From: David Johnston bp CTD Engineer 0 Date: January 9, 2013 Re: K -06B Sundry Approval Sundry approval is requested for well K -06B. K -06A was a rig sidetrack in Aug -98, and that's when the current completion was run. CTD sidetracked the well to K -06B in Jan -09. The well was put on production at High oil rates but also, high gas rates. The oil quickly dropped, then started a typical decline while the gas built to uneconomical rates. The well started cycling in Aug -09, and saw minimal ontime form there. Plug and perfs were executed in 2010, and 2011 both resulting in all gas, and minimal oil. REASON FOR SIDETRACK After Petro Physicist review in May -11, it was determined that no further oil lenses existed, and no wellwork options remained on this well. Given the low oil rates and high gas cut K -06B is a good candidate for a coil sidetrack. The proposed side track will access 20 acres with a 37' Net LOC in Z1 B and a 25' NLOC in Z1A. The proposed plan for K -06B is to drill a through tubing sidetrack with the SLB /Nordic 2 Coiled Tubing Drilling rig on or around March 10, 2012. The existing perforations of K -06B will be isolated by a the primary liner cement job of K -06C. The sidetrack, K -06C, will exit the existing 4.5" liner and kick off in the Sag River and land in zone 1. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. Pre -Rig Work: (Already began whipstock set scheduled for February 1, 2013) r C'0�7Cv�. 'e /( 4'y G/ /�i 1. S Set DGLV's. - DONE 11/10/2012 2. F MIT -OA (Passed - 2000 psi - 11/10/2012). 'ad 4,y4 . Go _ �G /Ps 3. F MIT -IA (Passed - 3000 psi - 11/10/2012) 4. W PPPOT -T (5,000 psi) Cycle LDS. - Passed 11/14/2012 a,.T7 /1/tf qt /rd4, i O4 f 5. S Dummy WS drift to 8845' MD. - DONE 11/9/2012 P it A- 6. E Run a Static bottom hole survey p �/� y ( 13 7. F Load and kill well with 1% KCL ` 0 5 a- �. 313- OD5 8. E Set 4 -1/2 KB packer whipstock at 8,825' at 0 deg. ROHS. 9. F MIT packer whipstock to 2,500 psi for 30 min. J fed � � ✓g �,4 10. V PT MV, SV, WV. ( 0 ( "r 0 1 / 11. 0 Bleed production flow lines down to zero and blind flange. d .�� %' ! � - 12. 0 Remove wellhouse, level pad. w2 l t �� u fio- `dN Rig Work: (scheduled to begin on March 1, 2013) (f Wv/' 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 0�' l/ ° 2. Mill 3.8" window at 8,825' and 10' of rathole. Swap the well to PowerPro drilling mud. '1'`e ` / f n : uild: 4.1 5 •' • 5 eg/ • • planned) with resistivity � � 4. Drill Lateral: 4.125" OH, 1912' (12 deg /100 planned) with resistivity 5. Run 3 -1/2" x 3 -1/4" x 2 -7/8" solid L -80 liner with TOL at 8,615' 6. Pump primary cement leaving TOC at 8,615', 30 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL /GR /CCL log 8. Test liner lap to 2000 psi. V 9. Perforate liner per asset instructions ( -150') ry 10. Freeze protect well, RDMO PTO Post -Rig Work: )<- 0( 1. Re- install wellhouse and FL's. 2. Generic GLV's c )30113. Set liner top packer with Slickline if needed and MIT to 2,400 psi PTp David Johnston CC: Well File CTD Engineer Joe Lastufka 564 -5985 'TREE= 4" CAMERON • _O S NOTES: WELL ANGLE > 70° @ 9353' WEL LHEAD = MCEVOY * ACTUATOR= AXELSON ORIG W8IBORE NOT SHOWN BELOW 9 -5/8" KB. ELEV = 62.92' CSG :: BF. ELEV = 26.62' KOP= 3091' I 199W H4 -1/2" FESSSSV NP, D= 3.813" Max Angle = 91° @ 9529 Datum MD= 9392' Datum TV D = 8800' SS 2590' --I 9 - 5/8" DV PKR 120" CONDUCTOR — 7 GAS LIFT MANDRELS DATE ST ( 13-3/8° CSG, 72#, L -80, 13 = 12.347" H 267 I. 12 V 3245 3240 I D ( MMG DOME 1- LATCH kP K H 16 T 3' 02/08/09 3 5715 5551 25 MMG SO RK F 20 02/08/09 2 7402 7066 24 MMG DMY RK r 0 10/19/08 TOP OF 7" LNR I— 7977 1 8493 8082 20 KBG2 DMY INT 0 10/19/08 Minimum ID = 2.377" @ 9508' 3 -3/16" x 2 -7/8" XO ` 7977' — 9 -5/8" X 7" BKR ZXP LIP, D = 6.313" I I TOP OF WHPSTOCK IH 8142' 7991' H 9-5/8" X 7" BKR HMC LN2 HGR, D = 6.250" I 19 -5/8" CSG, 47 #, L -80, 13 = 8.681" H — 8150 9-5/8" MLLOUT WINDOW (K 06A) 8142' - 8158' MZ % F ' I 8564' —14 -1/2" HES X NP, D = 3.813" I 3 ■ I 8575' I-[" X 4 -1/2" BKR S -3 PKR, D= 3.875" I I I 8599' H4 - 1/2" I X NP, D= 3.813" I 4 -1/2" TBG, 12.6#, L -80 TDS, .0152 bpf, D = 3.958" —I 8632' 8619' 1-14 -1/2" I-ES XN NP MLL ®TO 3.80" (01/28/09) \' 8632' — - 1/2" WLEG, D = 3.958" TOP OF 4 LNR - I 8635' I 8635' H ELMD TT LOGGED 07/30/05 I 8635' H 7" X 4-1/2" BKR ZXP LTP, 13 = 4.312" 7" LNR, 26#, L -80 BTC-M, .0383 bpf, D = 6.276" H 8809' I—A , 8649' H 7" X 4-1/2" BKR HMC I-IGR, ID = 3.980" ITOP OF 2 -7/8" LNR H 8845' r— 8845' —I 3.70" DEPLOY SLV, 13 = 3.00" I I 8855' - -13.70" X 3-1/2" XO PIN, 13= 2.995" I3 -1/2" LNR, 9.2#, L -80 STL, .0087 bpf, ID = 2.992" — — I 8865' I , I 8865' — I 3 -1/2" X 3 -3/16° XO, 13 = 2.786 I 1 7" MECHANICAL WHPSTOCK w / RA TAG (01/19/09) H 9069' I 4 -1/2' MLLOUT WNDOW (K 06B) 9069' - 9078' IP PIP " - • - - 9078 • Q 9384' . —I3 -3/16" F ES CBP(03/12/11) • PERFORATION SUMMARY • t4 9508' — 3 - 3/16" X 2 - 7/8" XO, D = 2.377 • REF LOG: SLB LEE MCNUGR/CAL ON 01/28/09 ° ' `.. . ` 10300' —12 -7/8" CIBP (06/15/10) I ANGLEAT TOP PERF: 35 @ 9254' *. Nate: Refer to Production DB for historical perf data �� SIZE SFP NTERVAL I Opn /Sqz DATE 10810' — FISH - 2.31" MLL 2" 6 9254 - 9290 0 03/14/11 `I f ` (01/27/09) 2" 6 9290 - 9300 0 03/12/11 111111111111I 2" 6 9470 -10250 0 01/29/09 3 -3/16" LNR, —I 9508' 7' 6 10400 -10730 C 01/30/09 62#, L -80 ICI, I PBID H 10972' 0 2" 6 10850 -10960 C 01/31/09 .0076 bpf, D = 2.80 2 -7/8" LNR, 6.16#, L -80 STL, H 11011' .0058 bpf. D = 2.441 GATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/19/83 AUDI ORIGINAL COMPLETION 06/18/10 CJS/SV SET CBP (06/15/10) WELL: K -06B 08/04/98 D16 SIDETRACK COMPLETION 02/18/11 GR/JMD MAX ANGLE DEPTH CHANGE PEF3vTf No: " 01/29/09 NORDIC 1 CTD SDTRACK (K 06B) 03/26/11 F4 IY PJC CIBP/ ADFERFS (03/12- 14/11) API It): 50- 029 - 21038 -02 01/31/09 ?/ PJC DRLG DRAFT CORRECTIONS SEC 4, T11 N, R14E, 2147' FS/ & 504' PM 02/10/09 CJWSV GLV GO (02/08/09) 03/02/09 MCZ/PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) I )� = 4" CAMERON WELLI-EAD = MCEVOY • K- O 6 C S * NOTES: WELL ANGLE > 70° @ 9353' ACTUATOR = AXELSON ORIG W E LBORE NOT SHOWN BELOW 9 -5/8" KB. aEV = 62.92Note Mixed RKBs! Planned CTD Sidetrack CSG BE ask/ = 26.62' KOP= 3091 H4 -112" HES SSSV NIP, D = 3.813" Max Angle = 91° @ 9529' 1999' Datum MD = 939Z 0 Datum TVD = 8800' SS 2590' H9 DV PKR GAS LIFT MANDRELS 20" CONDUCTOR — ? ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 - 3/8" CSG, 72#, L -80, D = 12.347" I- 2673' 3245 3240 12 MMG DOME RK r 16 02/08/09 3 5715 5551 25 MMG SO RK " 20 02/08/09 2 7402 7066 24 MMG DMY RK r 0 10/19/08 TOP OF 7" LNR — 7977" 1 8493 8082 20 KBG2 DMY INT r 0 10/19/08 Minimum ID = 2.377" @ 9508' 3 -3/16" x 2 -7/8" XO 7977' ----19-5/8" X 7" BKR ZXP LTP, D= 6.313" I TOP OF WHIPSTOCK H 8142' 7991' — 1 9 - 5/8" X 7" BKR HMC LNR HGR, D = 6.250" 19 -5/8" CSG, 47 #, L -80, 13 = 8.681" H - 8150 9-5/8" MLLOUT WNDOW (K -06A) 8142' - 8158' Jl. i 8564' H4 -112" HES X NIP, D = 3.813" W I 8575' H7• X 4 -1/2" BKR S -3 PKR, D= 3.875" ( 8599' H4 -1/2" HES X NP, D = 3.813" . TOL 3 - 1/4" L - 80 8,615' MD ' 8619' H4 I-ES XN NP, KILLED TO 3.80 (01/28/09) 4 -1 /2" TBG, 12.6#, L -80 TDS, .0152 bpf, D = 3.958" H 8632' F 8632' — - 1/2" WLEG, D= 3.958" TOP OF 4-1/2" LNR —I 8635' 8635' — ELMD TT LOGGED 07/30/05 4 8635' — 7" X 4 -1/2" BKR ZXP LTP, D = 4.312" 8649' 1 —'7" X 4 -1/2" BKR HMC HGR, ID = 3.980" 7' LNR, 26#, L -80 BTC-M, .0383 bpf, D = 6.276" H 8809' 240 I TOP OF 2 -7/8" LNR H 8845' -- TOP of WS -8,825' MD 0° ROHS 2 -7/8" Ported Sub -11,372' MD \ 2 -7/8" X 3 -1 /4" XO 10, 900' M D 8 H3.70" DEPLOY SLV, D = 3.00" I 8855' —I X 3-1/2" XO PN, D = 2.995" ..................... 2 7/8 "x 3-1/4" L 80 Liner TD 11,412' MD 4 -1/2" MLLOUT WNDOW (K-0613) 9069' - 9078' 4 LNR, 12.6#, L - 80 BTRS, .0152 bpf, D = 3.953" — — 9078 j ♦ ■ 9384' — 13 - 3/16" HES CEP (03/12/11) ■ 4 . ' 4 9508' H 3 - 3/16" X 2 -7/8" XO, D= 2.377 RERFCRARON Slt rx • 10300' �2 7/8" CIBP(06 /15/10) I F LOG SLB LEEMal/GRCN_ ON 01!1&09 � z.� ANIEATTOPFEFF 35° @ 9254' , f Note: Refer to R0d"cti°' xB f« hstrcal pert data ` 10810' — FISH - 2.31" MLL SZE SFF MFR/AL OpJSqz DOTE 2" 6 9254 -9290 0 03/14/11 f` (01/27/09) 2 6 9290 - 9300 0 03/12111 1111112" 6 9470 -10250 0 012909 7 6 10103 -13730 c 01/3009 \711A " LNR, — ' - 18' \ . z 6 10650-10960 C 01131A9 6.2#, L -80 TCI, � . .0076 bpf, ID = 2.80 PBTD 10972' 2 -7/8" LNR, 6.16 #, L -80 STL, H 11011" I .0058 bpf, ID = 2.441 DATE REV BY COP U4TS DATE REV BY COP/WITS PRUDHOE BAY WIT 11/19/83 AUDI3 ORIGINAL COMPLETION 06/18/10 CJS/SV SET CEP (06/15/10) WELL: K -06B 08/04/98 D16 SIDETRACK COM PLETION 02/18/11 GR/JMD MAX ANGLE DEPTH CHANGE PERMT No: 2082030 01/29/09 NORDIC 1 CTD SDTRACK (K 03/26/11 RRLY PJC CEP/ ADPERFS (03/12- 14111) API No: 50 -029- 21038 -02 01/31/09 ?/ PJC DRLG DRAFT CORRECTIONS SEC 4, T11 N, R14E, 2147' FM: & 504' FWL 02/10 /09 CJWSV GLV GO (02/08/09) 03/02/09 MCZ/PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM Almsti Cholt Panel ; Standpipe i 2" Circulation Line l ©j MM 11 • Driller Gauge -----I' • S • ... MM 10 • • MM 9 ■ ■ Manual Choke x• � CIRCULATING MANIFOLD - M M 8 a • MM 20 MM 22 SLB Transducer • �MM 6 PVT Sensor • 7 -1/16" 5kpsi BOPS ,. Air Blow down , • • _ r MM 7 Blind Shears r 4 " "" Line 4 + , ►�'wZ ° +c: _— Baker Choke MM 15 MM 4 j., r IIIII MM 5 MM 21 GAS BUSTER • 2 -318" Combi ...•w.w.w.n►.•. • * Mk• _ „ . • ' TOT PIS e ' • • , Rev Cir Line 5 _ — e9 u d 5 ° • 41 _ la 4. ' F - 0*. � al•M t # ►.. ill CIA u u • afi•al•f�s • l. • • BOP 24 1 . . ... III ... - 111 Coiled Tubing 1 _ 2 -318' - 3 -112" .. _. ; .i... VBR ram Ba er Choke 2 -3/8" Combi r s .• MM 1 A . MP1 in • d • MM 13 I 0:4 •:, t - < Kill Line Outlet 4— Cement Line to Ground Mud • 2 in V ' Pu.. .s In Tranducers COILED TUBING Qin& Choke Lire a „ / 1 cI(J _ CIRCULATING SYSTEM Cellar Area 4' MIMI 4 ltir HP 14 I. ill int To Inner Reel Outlets Valve HP ^0 HP7 HP3 _ a HP 2 HP 1 .:. J HP 1t 4 cement line N2 ( SLB NORDIC'S 2 Circulate Manifold , CHOKE MANIFOLD in Cellar HP 11 N2 TriFlow '! f CM 85 Gauge �' - t„,„4 IV -I 11.... CHOKE LINE 1 i. • II I l Ii — Test Pump Inlet „ „ „ „ „ J HDI Gauge CM18 Flow f/ HCR Ni TO TT - . 1 ' Block CM14 - CM1 CM8 To PITS C, 2 CM C 6 0i11 wet Baker Choke Line ', °m A Baker Choke Line from wall NCR Mk I 2 I 0 MAKER CM13 CM7 .. - ' ■ , Use Baker Choke Line CM2 CM19 • ' �"' in CM 26 CM 29 Blowing Back MM CM20 s n - - CM21 M i - - CM4 — - OrMARV PAIN CM 30 CHOKE LINE CM 75 CM10 IMAM Tige Tank CM 25 Outside ' • • Page l of l Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected I 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 J 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 STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSICID REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 12 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ISI Exploratory ❑ 208 - 2030 " 3. Address: P.O. Box 196612 Stratigraphic El Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21038 -02 -00 8. Property Designation (Lease Number) : t/ , 9. Well Name and Number: a ADLO- 028304 83 03 PBU K -066 r 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11011 feet Plugs (measured) 9385, 10300 feet true vertical 8913.22 feet Junk (measured) 10810 feet Effective Depth measured 10972 feet Packer (measured) 7678 8575 8635 feet true vertical 8911.91 feet (true vertical) 7600 8158 8214 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 20" X 30" 30 - 110 30 - 110 Surface 13- 3/8 "72# L -80 29 - 2673 29 - 2673 4930 2670 Production 9 -5/8" 47# L -80 28 - 8158 28 - 7769 6870 4760 Liner 7" 26# L -80 7978 - 8809 7600 - 8373 7240 5410 Liner 4 -1/2" 12.6# L -80 8635 - 9078 8214 - 8615 8430 7500 Liner 3- 1/2 "X3- 3/16 "X2 -7/8" 8845 - 11011 8405 - 8913 Liner 9.2 #/6.2 #/6.16 #L -80 (k r � Perforation depth: Measured depth: SEE ATTACHED - _ A 4 t .. True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 23 - 8633 23 - 8211 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP LTP PKR 7978 7600 4 -1/2" BKR S -3 PKR 8575 8158 4 -1/2" BKR ZXP LTP PKR 8635 8214 12. Stimulation or cement squeeze summary: RECEIVED' Intervals treated (measured): 4� MAR 2 4 ?Or Treatment descriptions including volumes used and final pressure: nn� �` 13. Representative DailyA PTtJd Ad��r ]�Eio g Oil -Bbl Gas -Mcf Water -Bbl f:h ;,easing Pressure Tubing pressure Prior to well operation: 190 20,097 0 1,346 Subsequent to operation: 31 3,362 0 1,422 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 ~ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil i.. 151 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N. - , e LastA Title Data Manager Si gnat = Phone 564 -4091 Date 3/24/2011 Form 10-404 Revised 10/2010 RSDMS MAR 2 2011 & ' , ugmit Original Only t1t+1 MAR rG t /7 K -06B 208 -203 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base K -06B 1/29/09 PER 9,470. 10,250. 8,858.03 8,882.99 K -06B 1/30/09 PER 10,400. 10,730. 8,889.22 8,906.98 K -06B 1/30/09 PER 10,850. 10,950. 8,910.47 8,911.16 K -06B 6/15/10 BPS 10,300. 10,950. 8,885.25 8,911.16 K -06B 3/12/11 APF 9,290. 9,300. 8,804.97 8,811.78 K -06B 3/12/11 BPS 9,385. 10,400. 8,851.89 8,889.22 K -06B 3/13/11 APF 9,254. 9,290. 8,777.52 8,804.97 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . • K -06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/12/20111T/1/0=2400/440/0 Load & Kill (Pre E -Line) Loaded Tbg w/ 5 bbl meth spear, 75 bbls i 1 % KCL, 42 bbls KCL & Safe -Lube, & 85 bbls 1% KCL to spot Safe -Lube at liner top. Freeze protect tbg w/ 40 bbls crude. FWHP= 50/500/0. Swab & wing shut. SSV, master, IA, & OA open. [ � I 3/12/2011; ** *WELL SHUT -IN ON ARRIVAL * ** E -LINE PLUG SET /PERFORATING I INITAL T /I /O 0/500/0 REACHED 9400' WITH PLUG, STOPPED DUE TO DEVIATION. SET HALIBURTON CIBP AT 9385', TAGGED PLUG AFTER SET TO CONFIRM SET. PERFORATED 9290' -9300' WITH 2" HSD 6SPF 60 DEGREE PHASED PJ2006 GUN. ALL DEPTHS REFERENCED TO SLB MEMORY COIL FLAG LOG DATED 14- JUNE -2010. LAY DOWN UNIT FOR NIGHT DUE TO 16 HR RULE. RETURN IN MORNING TO FINISH PERFORATING. LEFT WELL SHUT -IN, HAND OVER W/ DSO. ** *CONTINUE JOB NEXT DAY * ** 3/13/2011, ** *JOB CONTINUED FROM 3/12/2011*** `INITAL T /I /O 200/500/0 !PERFORATED 9254' -9290' WITH 2" HSD 6SPF 60 DEGREE PHASED PJ2006 =GUNS. GOOD SURFACE INDICATION ON EACH TRIP IN THE WELL. ALL SHOTS FIRED. TAGGED PLUG AT 9385'. ALL DEPTHS CORRECTED TO SLB MEMORY COIL FLAG LOG DATED 14- JUNE -2010. HANDOVER WITH DSO ON DEPARTURE. 1WELL SHUT -IN AND READY TO POP. FINAL T /I /O 250/500/0. ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 9 METH 160 1% KCL 42 SAFE -LUBE 40 CRUDE 2 DIESEL 253 TOTAL TREE = 4" CAMERON • SAFETY WELL ANGLE > 70° @ 9353' ACTUATOR = AXELSON WELLHEAD = MCEVOY K-06 B * * *OWG WELLBORE NOT SHOWN BELOW 9 - 5/8" KB. ELEV = 62.92' CSG*** BF. ELEV = 26.62' Max Angle - 91° © 9529' 1 1999' H4 -1/2" HES SSSV NIP, ID = 3.813" I Datum MD = 9392' • Datum = 8800' SS •■■— I 2590' H9-5/8" DV PKR I 120" CONDUCTOR I I ((r Il■ GAS LIFT MANDRELS 13- 318" CSG, 72 #, L -80, ID = 12.347" H 2673' ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3245 3240 12 MMG DOME RK ' 16 02/08/09 3 5715 5551 25 MMG SO RK ' 20 02/08/09 2 7402 7066 24 MMG DMY RK r 0 10/19/08 (TOP OF 7" LNR H 7977' 1 1 8493 8082 20 KBG2 DMY INT '' 0 10/19/08 Minimum ID = 2.377" @ 9508' 3- 3/16" x 2 -7/8" XO H 7977' 9 -5/8" X 7" BKR ZXP LTP, ID = 6.313" I 7991' H 9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.250" 1 'TOP OF WHIPSTOCK H 8142' 1 A W hx (9 5/8" CSG, 47 #, L -80, ID = 8.681" H 8776' " 9 -5/8" MILLOUT WINDOW (K -06A) 8142' - 8158' I ' 11 8564' I - 14 - 1/2" HES X NP, ID = 3.813" I iii' • 8575' 1 — 1 7" X 4-1/2" BKR S -3 PKR, ID = 3.875" 1 1 r—' 8599' H4 -1/2" HES X NIP, ID = 3.813" 1 I---I 8619' 1- 14 -1/2" HES XN NIP, MILLED TO 3.80" (01/28/09) I ' 4 -1/2" TBG, 12.6#, L -80 TDS, .0152 bpf, ID = 3.958" H 8632' I `--1 8632' H4 -1/2" WLEG, ID = 3.958" 1 TOP OF 4 -1/2" LNR H 8635' Hi 1 8635' J — I ELMD TT LOGGED 07/30/05 I 8635' Hr X 4-1/2" BKR ZXP LTP, ID = 4.312" 1 7" LNR, 26#, L -80 BTC-M, .0383 bpf, ID = 6.276" I-1 8809' I-J 8649' H7" X 4 -1/2" BKR HMC HGR, D = 3.980 "I 'TOP OF 2 -7/8" LNR H 8845 1 p--L 8845' I - 13.70" DEPLOY SLV, ID = 3.00" I 8855' 1.13.70" X 3-1/2" X0 PIN, ID = 2.995" I3 -1/2" LNR, 9.2 #, L -80 STL, .0087 bpf, ID = 2.992" I-I 8865' I — I 8865' 1-13 -1/2" X 3- 3/16" XO, ID = 2.786 1 7" MECHANICAL WHIPSTOCK (01/19/09) I--1 9069' 4-1/2" MILLOUT WINDOW (K -06B) 9069' 9078' I IRA TAG I 9078' • ■ • PERFORATION SUMMARY • � . ■ 1 9508' H3-3/16" X 2 -7/8" X0, ID = 2.377 I • REF LOG: SLB LEE MCNUGR/CNL ON 01/28/09 4 I 10300' 2 -7 /8" CIBP (06/15/10) 1 ANGLE AT TOP PERF: 91° © 9470' Note: Refer to Production DB for historical pert data •*• * ; * ;* , 10810' FISH - 2.31" MILL �i * i * i * i 43e6j�� ■ f 41111111 1 (01/27/09) SIZE SPF INTERVAL Opn/Sqz DATE :• • • • �e 1 2" 6 9470 -10250 %C. 01/29/09 • • • • • • • 4 ` 2" 6 10400-10730 C 01/30/09 •�•�•�•� 3 -3/16" LNR, 9508' 2" 6 10850 -10960 C 01/31/09 •�•�•��� 6.2 #, L -80 TCII, �� z" tit* - .6( 3d 0 035119 /1► • ` NA.• • ' PBTD I-L 10972' •� • • .0076 bpf, ID = 2.80 4• 2 -7/8" LNR, 6.16#, L -80 STL, —I 11011' 1 4 ' 4 -1/2" LNR, 12.6 #, L -80 BTRS, .0152 bpf, ID = 3.953" H 12330' , e 4, e .0058 bpf, ID = 2.441 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/19/83 AUDI 3 ORIGINAL COMPLETION 06/18/10 CJS /SV SETCIBP(06 /15/10) WELL: K -06B 08/04/98 D16 SIDETRACK COMPLETION 02/18/11 GR/JMD MAX ANGLE DEPTH CHANGE PERMIT No:' 082030 01/29/09 NORDIC 1 CTD SDTRACK (K -06B) API No: 50- 029 - 21038 -02 01/31/09 ?/ PJC DRLG DRAFT CORRECTIONS SEC 4, T11N, R14E, 2147' FNL & 504' FWL 02/10/09 CJN/SV GLV C/0 (02/08/09) 03/02/09 MCZ /PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 06/30/10 • ~ciila~nb~rger Alaska Data & Consulting Services 2525 Gembell Strast, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # N0.5553 Company: State of Alaska Alaska Oi16 Gas Cons Comm Ann: Christine Mahnken 333 West 7th Ave, Suite 100 Anehorage,AK 99501 Log Description Date BL Color CD J-Y3 K-066 PWDW3-1 B14B-00109 BCUE-00027 BCRC-OOD27 USIT MEM PROD PROFILE _ a RST WFL '"~ .- ~ rf ~ 06/23/10 06/14/10 06/22/10 1 1 1 1 1 1 1-11/SN-04 3-OYM-29 8148-00107 BD88-00021 LDL ~ MEM INJ. R FILE 06/12/10 06/13/10 1 1 i 1 15-168 10AKA0047 ON MWD/LWD EDIT 04/04/10 2 1 15-166PB1 t0AKA0047 ON MWD/LWD EDIT 04/01/10 2 1 03-22 BSJN-00047 RST - 03/30/10 1 1 G-30C AZ2F-00038 MCNL 04/22/10 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. L"-- Alaska Data 8 Consulting Services 2525 Gembell Street, SuOe 400 Anchorage, AK 99503-2938 `I R .~'~ ! , ,~ h~ e~ .~ ~t11~) ~~ ~ ., 1 DATA SUBMITTAL COMPLIANCE REPORT 3/22/2010 Permit to Drill 2082030 Well Name/No. PRUDHOE BAY UNIT K-06B Operator BP EXPLORATION (ALASKIy INC API No. 50-029-21038-02-00 MD 11011 TVD 8913 Completion Date 1/29/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD / GR / ROP / RACLX / RACHX / RPCHX /MEMORY CNL, GR, Well Log Information: Log/ Electr Data Digital Dataset Log Log Run T e Med/Frmt Number Ddame Scale Media No E D ,- C Lis 17732 eN utron __ /~ ' Log Neutron 2 Blu ;i~pt LIS Verification C Lis 17837</Induction/Resistivit y Induction/Resistivity 25 Col Log Induction/Resistivity 5 Col rt_og Gamma Ray 25 Col ~o/g ~ See Notes l S D A ~ Di ti 2 Col D urvey sc rec ona Rpt Directional Survey Well Cores/Samples Information: (data taken from Logs Portion of Master WeII Data Maint Interval Start Stop OH / CH Received Comments 8501 10965 Case 3/20/2009 LIS Verim GR, CNT 8500 10971 Open 3/20/2009 MCNL, Lee, GR, CCL 28- Jan-2009 8764 10998 Open 4/10/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS !i 8764 10998 Open 4/10/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 9069 11005 Open 4/10/2009 MD MPR, GR 26-Jan-2009 9069 11005 Open 4/10/2009 TVD MPR, GR 26-Jan-2009 9069 11005 Open 4/10/2009 MD GR 26-Jan-2009 8760 10998 Open 4/10/2009 Depth Shift Monitor Plot 27 11011 Open 4!16/2009 27 11011 Open 4/16/2009 Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3122/2010 Permit to Drill 2082030 Well Name/No. PRUDHOE BAY UNIT K-066 MD 11011 TVD 8913 ADDITIONAL INFORM TION Well Cored? Y N Chips Received? ~'f71V~-' Analysis Y / N Received? Completion Date 1/29/2009 Operator BP EXPLORATION (ALASK/y INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? `nny N Formation Tops ~GN UIC N Comments: Compliance Reviewed By: Date: API No. 50-029-21038-02-00 C -/.a~ BAKER wu~HEs ,~ ~ .1 ~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: April 15, 2009 Please find enclosed directional survey data for the following wells: K-06B J-OSC E-34L1 J-OSCL1 OS-27BPB1 07-02B 05-27B 07-20B 07-29D Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one. copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~ ,State of Alaska AOGCC DATE: 2 ~ ~ Cc: State of Alaska, AOGCC ~~ ~` ~-~ IN~'E I,og Data Transmittal Eorm To: state of Alaska -A®GCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: K-06B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) 4 LAC Job#: 2415171 ~b~~3 ~~- ~ 3~ Sent by: Catrina Guidry Date: 04/09/09 Received by: `~ ' ~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING. & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 l N'T EQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ ~ ~- BAKER N~JGMES Barer Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA7IUN (ALASKA) 1NC CUUNfY NUK1H SLUYE BUKUUGH WELL NAME K-06B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 4/9/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2415171 Copies of Copies Digital Copies of Copies Digilal Each Log of Film Dala Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF O[L & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE, AK 9901 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATL4S-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: ~b~-a~3 Page I of ] 03/18/09 ~~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wou _L,h ~ a ~~~ ~./ ~~ ~~ l~~ i.)', ~~~ (~ ~a ~ fT f9,1..1A A U~ /'~~\~'~ ~~~ ~ ,,,, nee...:...:,... N0.5133 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 .,_._ e~ .._~__ J-27A AY3J-00010 CBL - j 02/21/09 1 1 S-107 AWJB-26 MEM L L U ~ 02/25/09 1 1 09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE 02/23/09 1 1 MPB-22A AXED-00005 MEM SCMT & TEMP PROFILE - (p ' 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) b -- C ( 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / - E/ 03!02/09 1 1 B-25 AVY5-00023 USIT - / t / ~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG p'~ - j'~-5 / - 03/11/09 1 1 F-18 AVY5-00022 USIT j ,- ~-%"% _ ''3- - 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL ~ - 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/1?J09 1 1 V-211 AY3J-00014 (PROF/RST WFL - ~ ~ 03/16/09 1 1 V-214 AY3J-00013 (PROF/RST WFL - L 03/15/09 1 1 K-066 AWJI-00017 MCNL ~ - 01/28/09 1 1 L5-15 12113027 RST - /O ~ 1 • • 12/09/08 1 1 07-18 12071915 RST 9 12!01/08 1 1 15-15C AWJI-00015 MCNL . ( 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT / 12!07/08 2 1 R-41 40018496 OH MWD/LWO EDIT - 5 ( 01/04/09 2 1 H-18 11999064 RST / - IO ~- 12/03/08 1 1 r~eAae A~nrvvvv~tuut FitGtlr 1 tSY ,IhININl9 ANU Fit I LIMNING UNt GUPY tAGM 1 U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 0. ~,~ ~ 3c1,G1-- ~ s c~ Cojo ~ ~e~t ~u ec~1 3 ~2~0~` Alaska Data & Consulting Services 2525 Gambell Bt.~jte 4b0 Anchorage, AK ,99~6(~~83t3 ~ 1T ATTN: Beth _ _-, :: Received by: AA~C~ r~, ;, '7~P~i ~'0' e'r'a ..< ~ a Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, March 16, 2009 11:10 AM To: 'McMullen, John C' Cc: Regg, James B (DOA); Pat Archey Subject: Stuck Pipe Response--K-066 (208-203) John, I am reviewing the completion report recently submitted for this well. The coil became stuck on 1/25/09. After attempts to mechanically get free were unsuccessful, two "crude pills" were employed. Although the 2nd pill was nearly the annular OH volume, the pipe did not free. After circulating the 2nd pill out of the hole, the decision was made to "swap the well to crude" and -125 bbl of crude is reported to have been pumped and the pipe was successfully freed. As the operations continue, it is noted that the well was flowing and it was SI. The well was circulated through the choke to "circulate of gas bubble" and drilling operations continued. While it is understood that drilling with coil is done within a closed system, it seems unusual to displace nearly the entire wellbore to crude. It is evident that underbalancing the well did succeed in freeing the coil, but it is also evident that not surprisingly a kick was induced since the well was reported to be flowing. 20 AAC 25.036 (f) requires that the Commission be notified within 24 hours when the BOPE is used to prevent the flow of fluids from a well. So far as can be determined no notice was made. Would you check your records regarding this matter? Also, we are interested how often a significant displacement of crude has been attempted in order to free stuck pipe. I look forward to your response. Tom Maunder, PE AOGCC 3/16/2009 PBU, K-06B Correction on 10-407 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Stewman, Sondra D [Sondra.Stewman@bp.com] Sent: Thursday, February 26, 2009 2:56 PM To: Maunder, Thomas E (DOA) Subject: PBU,. K-066 Correction on 10-407 Tom, The completion report (10-407) for Well K-06B, PTD 208-203, API 50-029-21038-02-00 is enroute to your office via courier as I type this email. I noticed a typo. on the 10-407 in that the cement volume shou{d read 158 cu ft Class 'G' not 185 cu ft Class 'G' for the 3-3/16" x 2-7/8" casing string. Please advise how best to handle this correction. 'Rd ~L~~~ ~.~e nk ou ~~ C Tha y , Sondra Stewman ADVV Drilling Technologist ~3 r•c~, l~~ ~~~•sca~t cxr€~Z tc~~t e~f`c~ I)e C)Sl~'Il~s"",' 2/26/2009 STATE OF ALASKA ~~o~ ALASK~IL AND GAS CONSERVATION COM SSION FEB 2 6 2009 WELL COMPLETION OR RECOMPLETION REPORT AND LO ~~'~`~' ~laska Oi! ~ Gas Cons. Catrnrrissio~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.los zoAAC zs.11o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 1 /2009 12. Permit to Drill Number 208-203 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/21/2009 13. API Number 50-029-21038-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/26/2009 14. Well Name and Number: PBU K-06B FWL, SEC. 04, T11 N, R14E, UM 2146 FNL, 504 Top of Productive Horizon: 70' FNL, 1335' FWL, SEC. 04, T11N, R14E, UM 8. KB (ft above MSL): 53.6 Ground (ft MSL): 25.77 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 312' FNL, 4970' FWL, SEC. 05, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 10972 8912 Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 670778 y- 5975058 Zone- ASP4 10. Total Depth (MD+TVD) 11011 8913 16. Property Designation: ADL028303, ADL028304 TPI: x- 671555 y- 5977153 Zone- ASP4 - 5976874 Zone- ASPs4 Total De th: x- 669917 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No mi I r i 'n in i n r 2 AA 2. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permaftost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071 MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX, Memory CNL, GR ,CCL `//.t/~40s,1 ~ O,6 9/'~D d~S.SJ'• ~TYD 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 " x 30" In I n u or S rf 11 rf 11 c ncre e 9- / " 47# L-8 rf 14 ' 7754' 1 -1/4" 1338 cu ft'G', 575 cu ft'G', 133 cu ft PF'C' 7" -8 7 77' 8 75 7 ' -1/ " 22 I s ' 4 / ,~ ~ ~ ~~ 47 1 ' 3-3~~s° X z-7is" # x 4.7# L- 11 1' 840 1 4-1 / 1 I s'' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RI=_coRD If Yes, list each i & Bottom Pe (MD+T~/D of To nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD ; p 2" Gun Diameter 6 SPF 4-1/2", 12.6#, L-80 8632' 8575' , MD TVD MD TVD 9470' -10250' 8858' - 8883' 10400' 10730' 8889' 8910' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' - - 10850' - 10960' 8910' - $912' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 2000' Freeze Protected with McOH 26. PRODUCTION TEST Date First Production: February 17, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 2/17/2009 HOUfS Tested: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 1040 GAS-MCF: 9960 WATER-BBL: 2.32 CHOKE SIZE: 96 GAS-OIL RATIO: 9585 Flow Tubing Press. 1160 Casing Press: 1320 CALCULATED 24-HOUR RATE. OIL-BBL: 3125 GAS-MCF: 29886 WATER-BBL: 7 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ^ No Sidewal l Cores Ac 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, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None 1-.1909; ,~G _~ )~. Form 10-407 Revised 022007,, ~~ 9 ~ ~ ~~ CONTINUED ON REVERSE SIDE ~ ~3 ~ l S ('" ° r 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test resuks. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. 23S6 9077' 8614' None 22TS 9128' 8662' 21TS /Top Zone 2A 9178' 8710' Top Zone 1 B 9240' 8766' TDF /Top Zone 1A 9307' 8816' Formation at Total Depth (Name): TDF /Top Zone 1A 9307' 8816' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram and Survey. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra tewman Title Drilling Technologist Date (~~, ~aC.v-(~ PBU K-06B 208-203 Prepared By NameMumber. Sondra Stewman, 564-4750 Well Number i / A r v I N Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNeRA~: 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 trajection, Water-Akernating-Gas Injection, Sak 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). IreM 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 TVD 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 (mutiple 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 25.071. Form 10-407 Revised 02/2007 Submk Original Only TREE= 4" CAMERON WELLHEAD = ...-.. . MCEVOY - ACTUATOR = AXELSON KB. ELEV = 62.92' BF ELEV - 26.62' KOP = 3091' Max Angle = 98° @ 10416' Datum MD = 9392' Datum TVD = 8800' SS JC DRAFT 20" CONDUCTOR ~~ 13-3/8" CSG, 72#, L-80, ID = 12.347" 2673' TOP OF 7" LNR ~ 7977' Minimum ID = 2.377" @ 9508' 3-3/16" x 2.7/8" XO TOPOF WHIPSTOCK 8142' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-{ 8776' 4-1/2" TBG, 12.6#, L-80 TDS, .0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" TOP OF 2-7/8" LNR 3-1/2" LNR, 9.2#, L-80 STL, :0087 bpf, ID = 2.992" 7" MECHANICAL WHIPSTOCK {01/19/09) RA TAG I 8635' I I 8809' I 8( 865' I 9069' PERFORATION SUMMARY REF LOG: SLB LEE MCNL/GR/CNL ON 01/28/09 ANGLEATTOPPERF:91° @9470' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9470-10250 O 01/29/09 2-7/8" 6 10400-10730 O 01/30/09 2-7/8" 6 10850-10960 O 01/31/09 ~ 4-1/2" LNR, 12.6#, L-80 BTRS, .0152 bpf, ID = 3.953" I K _O ~ ~ S * NOTES: WELL ANGLE > 70° @ 9353' ORIG WELLBORE NOT SHOWN BELOW 9-518" CSG *** /'~ 1999' 4-112" HES SSSV NIP, ID = 3.813" V 2590' 9-5/8" DV PKR CHAS I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3245 3240 12 MMG DOME RK 16 02/08/09 3 5715 5551 25 MMG SO RK 20 02/08/09 2 7402 7066 24 MMG DMY RK 0 10/19/08 1 8493 8082 20 KBG2 DMY INT 0 10/19/08 7977' 9-5/8" X 7" BKR ZXP LTP, ID = 6.313" 7991' 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.250" 9-5/8" MILLOUT WINDOW (K-06A) 8142' - 8158' I $564' 4-1/2" HES X NIP, ID = 3.813" 8575' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8599' 4-1 /2" HES X NIP, ID = 3.813" 8619' 4-1/2" HES XN NIP (MILLED TO 3.80" (01/19/09) 8632' 4-1/2" WLEG, ID = 3.958" 8635' - ~MD TT LOGGED 07/30/05 8635' 7" X 4-1 /2" BKR ZXP LTP, ID = 4.312" $649' 7" X 4-1 /2" BKR HMC HGR, ID = 3.980" 8845' 3.70" DEPLOY SLV, ID = 3.00" 8855' 3.70" X 3-1/2" XO PIN, ID = 2.995" 8865' 3-1/2" X 3-3/16" XO, ID = 2.786 4-1/2" MILLOUT WINDOW (K-O6B) 9069' - 9078' 9508' 3-3/16" X 2-7/8" XO, ID = 2.377 10972' FISH - 2.31" MILL PUSHED , ~ TO BTM (XX/XX/XX) 3-3116" LNR, --i 9508' 6.2#, L-80 TCII, pgTp 10972' .0076 bpf, ID = 2.80 2-7/8" LNR, 6.16#, L-80 STL, 11011' .0058 bpf, ID = 2.441 DATE REV BY COMMENTS DATE REV BY COMMENTS 11!19/83 AUDI 3 ORIGINAL COMPLETION 08/04/98 D16 SIDETRACK COMPLETION 01/29/09 NORDIC 1 CTD SDTRACK (K-06B 01/31/09 ?/ PJC DRLG DRAFTCORRECl10NS 02/10/09 CJNISV GLV C/O (02/08/09) PRUDHOE BAY UNIT WELL: K-066 PERMIT No: "2082030 API No: 50-029-21038-02 SEC 4, T11N, R14E, 2147' FNL & 504' FWL BP F~cploration (Alaska) BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: .Date From - To Hours I Task Code NPT Phase Description of Operations 1/18/2009 00:00 - 02:00 2.00 MOB P PRE Warm up tires, prep to jack up rig and move from E-36 to K-06. 02:00 - 05:00 3.00 MOB P PRE SAFETY MEETING. Review rig move hazards and mitigation 05:00 - 11:00 ~ 6.00 ~ BOPSUF~ P 11:00 - 17:00 6.00 BOPSU P 17:00 - 17:15 0.25 BOPSU P 17:15 - 19:00 1.75 BOPSU P 19:00 - 19:15 0.25 RIGU P 19:15 - 19:45 0.50 RIGU P 19:45 - 21:30 1.75 RIGU P 21:30 - 22:30 ( 1.001 CASE ~ P 22:30 - 22:45 ~ 0.25 ~ CASE ~ P 22:45 - 00:00 I 1.251 CASE I P 11/19/2009 100:00 - 01:30 I 1.501 CASE I P 01:30 - 02:00 I 0.501 BOPSUR P 02:00 - 02:55 ~ 0.92 ~ CASE ~ C 02:55 - 03:30 i 0.58 ~ CASE ~ C with Nordic, security and BP personnel. Move rig to K-06. PRE Move over well and set down. Rig accepted at 05:00, 01/18/2009 N/U and grease BOPS. Rig up cuttings tank, Tiger tank, hardline and spot Drilling control center PRE Pressure /function test BOPE. Witness waved by AOGCC inspector, Jeff Jones. Sent test report to AOGCC. PRE SAFETY MEETING. Review procedure, hazards and mitigation for pulling the BPV using the lubricator. PRE Rig up the valve crew lubricator and press test to 1000 psi. Open master valve and recover BPV. Well was on a vac. SIWHP = 0 psi. PRE SAFETY MEETING. PJSM for R/D BPV lubricator and sending it outside. Use of traction footwear and overhead loads were discussed. PRE R/D BPV lubricator and running tools, send it down the beaver slide. PRE Check whitey valve on tree cap, positive gas pressure not bleeding off. Bullhead 250 bbls KCI water to displace crude in tubing, 3.28 bpm C~ 500 psi. Load liner into pipe shed while bullheading. RUNPRD Finish bullheading, bleed off and monitor well. Well is on vac. Continue loading 2-3/8" liner into pipe shed. 22:00 -Fill well with 8 bbls. 22:30 -Fill well with 12.7 bbls RUNPRD SAFETY MEETING. PJSM for picking up injector and pulling CT across. Crew positions and overhead loads were discussed. RUNPRD Pick up injector. 23:05 -Fill well with 13.0 bbls. Well is taking about 30 bbls/hr. Pull test internal grapple on CT. Unsecure CT from shipping bar and pull across into injector. 23:45 -Fill well with 16.8 bbls. Cut off grapple and dress end of CT for CTC. RUNPRD Install CT connector and pull test to 35K, good. Install boot on end of cable. 00:25 -Fill well with 13.2 bbls. Install swizzle stick on CT, close swab. Close swab and pump 5 bbls McOH ahead, PT 1502 line inside reel. Fill reel forward. RUNPRD Break off stack. Test inner reel valve and CT connector to 250 / 3500 psi.and chart, good. RUNPRD Remove test plate from CT. 02:10 -Fill well with 22.7 bbls Run 2 jts PH6 into well to pump slack out of CT. RUNPRD M/U CT riser. Pflntetl: 2/19/20Uy 1"L:SL:4t3 F'M BP EXPLORATION Operations Summary Report Page2of14~ Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ', Task Code NPT Phase Description of Operations 1/19/2009 02:55 - 03:30 0.58 CASE C RUNPRD Pump 30 bbls fresh water ahead. Get returns after 17.9 bbls. Pump KCI water at high rate to move cable. 03:30 - 04:30 1.00 CASE C RUNPRD Break off well, total of 1.5 ft of cable pumped out. Set injector on legs. Load liner running tools to rig floor. M/U drift joint for first 5 connections. 04:30 - 12:15 7.75 CASE C RUNPRD Run liner as per program: 2-3/8" Tapered Guide Shoe, 2.65 1 jt 2-3/8", 4.43#, L-80, STL Liner, no turbo 2-3/8" perforated 4' pup jt, 20 x 3/8" holes BOT FLOAT COLLAR, 2-3/8" STL BTT FLOAT COLLAR, 2-3/8" STL 2-3/8" STL Pup jt BTT LANDING COLLAR, 2-3/8" STL 98 jts 2-3/8", 4.43#, L-80, STL Liner, no turbo 2-3/8" 4.43# STL L-80 PUP JT. BTT LINER DEPLOYMENT SLEEVE, L80, 3" GS, 2.70" OD Scoop Guide, 3-1/2" OD BOT SELBRT, 5/8" ball seat XO, 1-1/2" MT box X 6-pitch Pin BOT HYDRAULIC DISCONNECT, 3/4"BALL BOT XO, 2-3/8"REG X 1-1/2 Mt pin XO 2-3/8" PH6 x 2-3/8" REG Pin 2-3/8 PH-6 Tubing, strapped 3 jts. 5P Box x 2-3/8" PH6 P BOT Quick Connect 5P Box x Pin, 1.38" ID BOT SLIP TYPE CTC Liner to top of Scoop guide = 2931.71' BHA OAL = 3,034.10 ft. Drift first 5 connections. Fill well every 30 min, taking 20 bbl/hr. 12:15 - 14:15 2.00 CASE C RUNPRD RIH with 2-3/8" Liner and small hole SELBRT to test run / cement 2-3/8" liner with E-Coil. Circ at 1.1 bpm, 350 psi, pump kick out set at 1000 psi. RIH clean to 12,260' CTD. 32' deeper than service coil last tagged PBTD. Up wt = 39K. 14:15 - 15:00 0.75 CASE C RUNPRD Launch 5/8" steel ball. Circ 2.5 bpm for 30 bbl, slow pump to 1.0 bpm. Ball on seat at 42.6 bbl. Coil cap = 57.6 bbl. PH6 Cap = Sheared at 3300 psi. Set for 2900 psi. Pick up free at 34K. Stack wt back on liner and circ while rigging up cement unit. 12,263.4' with 5K coil wt, 10K stacked. 15:00 - 16:00 1.00 CEMT C RUNPRD Circ 2% KCL water, double slick, 1.9 bpm, 1.5 bpm returns, 620 psi. 25 bbl/hr fluid loss. Rig up SWS cement unit. 16:00 - 16:15 0.25 CEMT C RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping cement with SWS cement unit. 16:15 - 17:15 1.00 CEMT X WAIT RUNPRD Ordered 50 bbl contamination vac for 1600 hrs. Delayed at hot rrirnea: uiyieuua IL:°Y:4° YM BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To II Hours Task Code NPT 1/19/2009 16:15 - 17:15 1.00 CEMT X WAIT 17:15 - 19:00 1.75 CEMT C Spud Date: 11 /5/1983 Start: 1 /12/2009 End: 1 /30/2009 Rig Release: 1/30/2009 Rig Number: i Phase Description of Operations RUNPRD water plant, in line. Driver did not call dispatch to let us know he would be late. RUNPRD Pump 2 bbl water. Press test cement line to 6000 psi. Bleed off press. CT capacity = 57.7 bbl. Will stop Displ at 55.7 bbl. leaving 2 bbl cement in coil. Cement at weight at 17:40 hrs. Pump cement and displacement with SWS cementer to clean cement unit. Stage 35 bbl, 15.6 ppg cement, 1.9 bpm, 1100-2200 psi, 1.5 bpm returns 20 bbl cement away, 1.9 bpm, 2200 psi, 1.4 returns. 27 bbl cement away, 1.4 bpm, 1650 psi, 1.0 returns. 35 bbl cement, go to water. 1.3 bpm, 1400 psi. stg 5 bbl Water displacement, swap to Biozan. 10 bbl displ, 2.1 bpm, 1400 psi, 1.5 bpm returns. 20 bbl displ, 2.3 bpm, 1400 psi, 1.9 bpm returns 30 bbl dsipl, 2.4 bpm, 1820 psi, 1.9 bpm returns 33.8 bbl displ, zero out totalizer, cement at shoe. 40 bbl displ, 2.4 bpm, 2250 psi, 1.9 bpm returns. 50 bbl displ, 2.4 bpm, 2300 psi, 2.0 bpm returns 55.7 displ, stop pump, 2 bbl cement left in coil. Isolate SWS cementer. No pump. Pick up 11' from free up depth to 12,246'. Circ. out 5 bbl to backside, 60.7 bbl displ. 1.7 bpm, 1100 psi, 1.5 returns Stop pump at 60.7 bbl displ. Open Baker Choke. RIH and stack wt on liner. R-H to 12262.6' with 6500 coil wt. Close Baker choke. Stage Biozan displ behind LWP. 0.4 bpm, LWP sheared at 2400 psi. Liner capacity to bump LWP = 11.15 bbl. 62 bbl displ, 1.1 bpm, 1100 psi. 1.0 bpm retuns 65 bbl displ, 1.0 bpm, 980 psi, 0.9 bpm returns 70 bbl displ, 1.0 bpm, 910 psi, 0.92 bpm returns. 72.0 bbl bumped LWP, pump up to 1900 psi and hold press on LW P Bumped plug 0.3 bbl early. Calculated bump at 72.3 bbls. (included 5 bbl side exhaust.) Out totalizer has 33.1 bbl total, minus 4 bbl exhaust out = 29.1 bbls returns. 28.6 bbls calculated annular cement needed to top of liner. Press stesdy at 1800 psi on LWP. Bleed down and check floats. Floats OK. Press up to 500 psi. Pick up, press fell off at 12243' Pick clean at 33.5K. SELBRT Test went well. Printed: Z/19/2009 12:52:48 PM • • BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: Date ;From - To Hours Task I, Code ~ NPT ~ Phase Description of Operations 1/19/2009 17:15 - 19:00 1.75 CEMT C RUNPRD 19:00 - 20:15 1.25 CEMT C RUNPRD Circ 4-1/2" liner clean from top of liner to tailpipe at 8600' 20:15 - 20:30 0.25 CEMT C 20:30 - 21:00 0.50 CEMT C 21:00 - 21:20 0.33 CLEAN C 21:20 - 23:10 1.83 CLEAN C 23:10 - 23:30 0.33 CLEAN C 23:30 - 00:00 0.50 CLEAN C 1/20/2009 00:00 - 00:30 0.50 CLEAN C 00:30 - 01:00 0.50 CLEAN C 01:00 - 04:20 I 3.331 CLEAN I C 04:20 - 05:30 1.17 CLEAN C 05:30 - 06:30 1.00 CLEAN C 06:30 - 07:00 0.50 WHIP C 07:00 - 07:15 0.25 WHIP C 07:15 - 08:30 1.25 WHIP C 08:30 - 11:00 2.50 WHIP C 11:00 - 13:45 2.751 WHIP C 13:45 - 15:40 1.92 WHIP C 15:40 - 16:10 0.50 WHIP C 16:10 - 16:40 0.50 WHIP C 16:40 - 18:00 1.33 WHIP C 18:00 - 18:15 0.25 WHIP C 18:15-19:30 I 1.251WHIP IC 19:30 - 20:10 0.671 WHIP P Circ 2.5 bpm, 1700 psi. POOH. RUNPRD SAFETY MEETING. PJSM for UD PH6 and SELBRT. RUNPRD UD PH6 and SELBRT. Stinger shear pin has sheared, tool has functioned normally. WEXIT Conduct quarterly inspection of CT traction motor. SAFETY MEETING. Go through SCR lockout / tagout checklist with electrician. WEXIT Lock out SCR breakers to power pack. Perform inspection of traction motor brushes. WEXIT Unlock LO/TO from SCR breakers, close out permits. Power up pumps and try to circ, coil is frozen. WEXIT M/U check valve and nozzle, RIH 200 ft to thaw CT. Pull back to surface, close swab and jet stack up and down. WEXIT Continue jetting stack. WEXIT P/U BHA #2 - 3.79 Diamond speed mill, 2-7/8" motor, circ sub, Disconnect, BPV, 1 jt PH6 for C/O down to whipstock setting depth. WEXIT RIH BHA #2. Ream from 8700 ft to 9200 ft and back up again at 10 ft/min. Slow to 3 fUmin through whipstock setting area. WEXIT POOH. No cement to surface. WEXIT Tag stripper, UD mill and motor. WEXIT Reverse circ at 5.0 bpm to pump E-Line slack into coil. WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for cutting coil with hyd cutter. WEXIT Cut off 400' coil to get back to E-Line. WEXIT M/U SWS Kendall connector, pull/press test. M/U BHI UOC and test E-Line OK. Press test OK. WEXIT Circ at 2.5 bpm to put E-Line slack back on top of UOC. M/U BTT monobore 4-1/4" Whipstock, Hyd setting tool and CoilTrak tools. Install 2 PIP tags in whipstock. WEXIT RIH to 8850. WEXIT Log tie-in. Correction -27'. WEXIT RIH ark to of WS at 9071 03180 de rees. Close EDC 34K Up wt. Pressure to 3700 psi to set WS. WEXIT POH. WEXIT PJSM for UD BHA. Hand traps and biozah on floor were discussed. WEXIT Tag stripper and UD whipstock setting BHA. Tool has functioned normally. Install new depth encoder on injector. Assemble BHI CoilTrak on catwalk. WEXIT P/U window milling BHA #4. SLB CTC, 2-3/8" REG XO UOC LOC Sub Wear Protection Powercomms rnntea: uiai~uua ir:oe:aa rnn BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: Date ~! From - To Hours Task ~, Code ~ NPT ~ Phase 1 /20/2009 19:30 - 20:10 0.67 WHIP ~ P ~~ W EXIT 20:10-22:25 ~ 2.25~WHIP ~P ~ WEXIT 22:25 - 00:00 1.58 STWHIP P WEXIT 1/21/2009 00:00 - 14:15 14.25 STWHIP P WEXIT 14:15 - 16:10 1.92 STWHIP P WEXIT 16:10 - 18:30 2.33 STWHIP P WEXIT Description of Operations EDC DPS Sub DGS Sub Blind Sub XO Reg pin x PAC box XO 2 JTS, 2-3/8" PH6 TUBING XO 2-7/8" BOT XTREME MOTOR HCC 3.80" DIA STRING REAMER HCC 3.80" DIAMOND WINDOW MILL BHA OAL = 121.88 RIH BHA #4. Tie-in depth from 8 850 ft. Correct -4.6 ft. RIH and tag pinch point at 9071 tt. Bring pump to 2.59 bpm ~ 2400 psi FS. Ease back down to start time milling at 1 ft/hr. 22:30 - 9071.0 ft DWOB = 1.16 Klbs 23:00 - 9071.7 ft DWOB = 2.88 Klbs 00:00 - 9072..4 ft DWOB = 3.4 Klbs Continue time milling window. 00:00 - 9072.4 ft DWOB = 3.4 Klbs 01:00 - 9073.1 ft DWOB = 3.62 Klbs 02:00 - 9073.9 ft DWOB = 3.57 Klbs 03:00 - 9074.8 ft DWOB = 2.90 Klbs 04:00 - 9075.7 ft DWOB = 2.71 Klbs 05:00 - 9076.6 ft DWOB = 3.14 Klbs 06:00 - 9077.5 ft DWOB = 3.05 Klbs 07:00 - 9078.2 ft DWOB = 2.94 Klbs 08:00 - 9079.1 ft DWOB = 2.11 Klbs 09:00 - 9079.7 ft DWOB = .83 Klbs possibily out 10:00 - 9080.4 ft DWOB = .63 Klbs 10:30 - 9081.7 ft DWOB = 2.21 Klbs Start rat hole. 2.57/2.57 bpm ~ 2527 psi WOB 3.29KIbs ROP 6. Drill to 9089. Back ream to 9066. Ream down 9090 three passes. Dry tag POH LD milling BHA and PU building assembly. M/U BHA #5: SWS CTC BHI XO BHI UOC BHI LOC BHI SUB WEAR PROTECTION BHI POWER COMMS BHI EDC BHI DPS BHI DGS BHI HOT ORIENTER BHI 2-7/8 X-TREME MOTOR, 3.4 DEG HC Bicenter BIT#1 Printed: 2/19/2009 12:52:48 PM BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: Date. From - To Hours Task Code NPT Phase Description of Operations 1/21/2009 16:10 - 18:30 2.33 STWHIP P WEXIT BHA OAL = 66.16 ft. 18:30 - 19:00 0.50 DRILL P PROD1 M/U CT riser. Test BHA and open EDC. RIH, circ through open EDC. 19:00 - 19:30 0.50 DRILL P PROD1 Stop at 185 ft and replace 9 cotter pins in injector chains. 19:30 - 22:45 3.25 DRILL P PROD1 Continue RIH carefully with 3.4 deg motor. See all the nipples and a few GLVs on the way down. Log GR down from 8790 ft to 8920 ft at 120 ft/hr. Correct +2 ft. Close EDC and pass through window at 180L. Ta at 9091 ft brin um to 2.60 b m. 22:45 - 00:00 1.25 DRILL P PROD1 Drill from 9090 ft. Stall three times at 9091 ft. Slow drilling getting started. Drill to 9093 ft. 1/22/2009 00:00 - 05:00 5.00 DRILL P PROD1 Continue drilling from 9093 ft. Hold 180E TFfor now to reduce inc to 12 deg. ROP is 10-20 ft/hr with 1-2 Klbs DWOB, motor stall if pushed harder than that. 2.60 / 2.59 bpm @ 3100 - 3300 psi. Past 9125 ft ROP increases to 20-30 ft/hr. Stall and pull 50K off bottom at 9192 ft. Short wiper to window. 05:00 - 06:40 1.67 DRILL P PROD1 Continue drilling from 9192 ft, hold 90L TF for long left turn to the west. ROP 20-60 ft/hr with 0 - 2 Klbs on DWOB.Drill to 9240. Orienter failed. 06:40 - 08:45 2.08 DRILL N DFAL PROD1 POH . 08:45 - 10:20 1.58 DRILL N DFAL PROD1 BHA change out HOT, DGS and bit. Bit grade 4-2. 10:20 - 12:15 1.92 DRILL N DFAL PROD1 RIH to 9080 12:15 - 12:30 0.25 DRILL N DFAL PRODi Log tie - in. Correction +1' . 12:30 - 12:40 0.17 DRILL N DFAL PROD1 RIH tag at 9240.4 12:40 - 17:00 4.33 DRILL P PROD1 Directionally drill 2.59/2.60 bpm @ 3400 psi. FS= 3100psi, DWOB 1.78 K ,ECD 10.11 ROP 30 -50. Drill to 9450. 17:00 - 17:30 0.50 DRILL P PROD1 Wiper to window. 17:30 - 18:25 0.92 DRILL P PRODi Directionally drill 2.55/2.58 bpm C~ 3550 psi. FS= 3100psi, DWOB 1.8 K ,ECD 10.17 ROP 100+. Drill to 9530, end of build section. 18:25 - 19:45 1.33 DRILL P PROD1 Pull back to window. 8K overpull at 9520 ft. Pull through window and open EDC. 19:45 - 20:00 0.25 DRILL P PROD1 SAFETY MEETING. PJSM for LD build BHA. SIMOPs with SLB mechanic was discussed. SLB mechanic here to adjust injector chain alignment. 20:00 - 22:00 2.00 DRILL P PROD1 Tag stripper and LD build BHA. Bit is 1-2. Align injector chains, replace 9 cotter pins on the bearing pins. Assemble new BHA on catwalk and surface test. 22:00 - 23:00 1.00 DRILL P PRODi PU BHA #6 - HCC 3.75 x 4.125 bit, 1.2 deg AKO Xtreme, 3" CoilTrak with Res. BHA OAL = 79.06 ft. 23:00 - 00:00 1.00 DRILL P PROD1 Test tool at surface then RIH. 1/23/2009 00:00 - 01:30 1.50 DRILL P PROD1 Continue RIH. Log RA and correct -0.7 ft. Continue RIH to bottom. 01:30 - 02:10 0.67 DRILL P PROD1 Ta bottom at 9530 ft. MAD pass back to window. 02:10 - 02:30 0.33 DRILL P PROD1 Run back to bottom. Motor work seen at 9410 ft. Printed: 2/19/2009 12:52:48 PM BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ', Code NPT Phase 'I Description of Operations ;- 1/23/2009 02:30 - 04:00 1.50 DRILL P PROD1 Drill from 9530 ft. Several stalls getting started. 04:00 - 05:05 I 1.081 DRILL I N I SFAL I PROD1 05:05 - 10:00 4.92 DRILL P PROD1 10:00 - 11:00 1.00 DRILL P PROD1 11:00 - 15:30 4.50 DRILL P PROD1 15:30 - 16:00 0.50 DRILL P PROD1 16:00 - 16:45 0.75 DRILL P PROD1 16:45 - 20:30 3.75 DRILL P PROD1 20:30 - 21:50 I 1.331 DRILL I P I I PROD1 21:50 - 00:00 I 2.171 DRILL I P I I PROD1 1/24/2009 100:00 - 01:00 I 1.001 DRILL I P I I PROD1 01:00 - 02:00 1.00 DRILL P PROD1 02:00 - 02:10 0.17 DRILL P PROD1 02:10 - 03:45 1.58 DRILL P PRODi 03:45 - 04:00 0.25 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 05:00 0.50 BOPSU P PROD1 05:00 - 05:20 0.33 DRILL P PROD1 05:20 - 07:00 1.671 DRILL P PROD1 Drill at 2.59 / 2.57 bpm ~ 3100-3400 psi, ECD = 10.1 ppg. ROP is 20-40 ft/hr with 1-3 Klbs DWOB. Problems with Res tool, continue drilling while troubleshooting. Drill to 9,552 ft. Res tool appears to be working, MAD pass back to window to verify. Tool is working now, RIH to drill. Drill from 9552 ft at 2.58 / 2.56 bpm 3100-3400 psi. ROP is 20-40 fUhr 0-2 Klbs DWOB. Drill to 9700. Wiper to window. Drill 2.53/2.51 bpm C~ 3330 psi, 3250 psi FS, ECD 10.2 pg, ROP 30-40. 1.1K WOB. Drill to 9800. Swap mud. Drill 2.58/2.57 bpm C~ 3560 psi ,3250 psi FS, ECD10.13 ppg, ROP 50-60 New mud to Bit. Wiper to window. Drill 2.62/2.57 bpm X3400 psi. ECD 9.76 PPg, ROP 40-50 WOB 1 Klbs with new mud to surface. Stacking wt at 9925 ft. Past 9930 ft ROP increases around 100 ft/hr. Drill to 10,000 ft. Wiper trip from 10,000 ft to window. Log tie-in, correct depth +1.5 ft. Resume wiper trip to bottom. Stack wt and motor work at 9410 ft. Drill from 10,000 ft, hold 86.5-87 deg inc to match formation dip angle. 2.59 / 2.60 bpm C~3 3000 psi FS. ROP is around 100 ft/hr with some stalling. Overpull at 10027 ft, 70K to free it. , Short 100 ft wiper. Continue drilling, stacking and stalling occasionally. Past 10,030 ft drop angle to 86 deg to go down strat a few feet. Geo has found small pieces of rubber in the 10.000 ft sample. Drill to 10,100 ft. Continue drilling from 10,100 ft. Getting adequate motor work. Drill to 10,144 ft. Wiper trip from 10,144 ft to window. Clean pass up and down. Drill from 10,144 ft. 2.52 / 2.47 bpm ~ 2900 psi FS. ROP is 90-100 ft/hr with 1-3 Klbs DWOB. Getting frequent stalls now, not able to put much weight on it. POOH for motor and bit change. SAFETY MEETING. PJSM for change out BHA. Tag stripper. Stand back CoilTrack, change out bit and motor. Bit is 1-2. Function test BOPs. Run BHA #8 into well and hang it off. Replace O-ring on BHI LOC. RIH BHA #8 - 3.75 x 4.25 HYC Razor bit, 1.2 deg AKO, 3" CoilTrak with Res. RIH to 9100' Printed: 2/19/2009 12:52:48 PM BP EXPLORATION Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date 'From - To Hours Task Code'. NPT 1/24/2009 07:00 - 07:10 0.17 DRILL P 07:10 - 07:45 0.58 DRILL P 07:45 - 11:40 3.92 DRILL P 11:40 - 13:30 1.83 DRILL P PROD1 13:30 - 14:30 1.00 DRILL P PROD1 14:30 - 16:30 2.00 DRILL P PROD1 16:30 - 16:45 0.25 DRILL P PROD1 16:45 - 17:30 0.75 DRILL P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 Page 8 of 14 Spud Date: 11/5/1983 Start: 1 /12/2009 End: 1 /30/2009 Rig Release: 1/30/2009 Rig Number: Phase Description of Operations PROD1 Log tie-in .-1'. PROD1 RIH. Tag at 10150 PROD1 Drill 2.62/2.67 bpm 3300 psi FS, Extensive stalling vary pump rate RIH speeds. Slip sticking instaneously increase in WOB result in stall. Also seeing erratic reactive torques. Struggle to make hole Pump 35 bbl pill with 5 % LowTorq. No effect. POH 18:30 - 18:40 I 0.171 DRILL I P I I PROD1 18:40 - 20:05 1.42 ~ DRILL ~ P ~ ~ PROD1 20:05 - 21:30 ~ 1.421 DRILL P PROD1 21:30 - 22:45 I 1.251 DRILL I P I I PROD1 22:45 - 00:00 I 1.251 DRILL I P I I PROD1 1/25/2009 00:00 - 00:10 0.17 DRILL P PROD1 00:10 - 02:40 2.50 DRILL N STUC PROD1 02:40 - 04:00 I 1.331 DRILL I N I STUC I PROD1 for agitator. POH BHA PU ag Log tie in correction -2.5'. RIH to 10217' Drill 2.4/2.4 bpm C~ 3740 psi, 3400 psi FS. WOB .7K Ibs,ECD 9.95, ROP 80. Drill from 10,250 ft at 2.52 / 2.50 bpm ~ 3700 psi FS. ROP is 150-180 fUhr for short intervals, then stalling or stacking. Drill to 10,306 ft and stack wt. Pickup is heavy, +10K for 30 ft off bottom. No annular pressure increse or additional tension seen on DWOB during overpull. Wiper to window. Clean pass up and down. Drill from 10,306 ft. Hold 87 deg inc for now. 2.51 / 2.47 bpm @ 3500 psi FS, 4000-4400 psi while drilling. ROP is 150-180 fUhr with 2 Klbs DWOB. PVT = 228 bbls, ECD = 10 ppg. Stacking wt frequently. Drill to 10,450 ft. Wiper trip to window. Clean pass up and down. Drill from 10,450 ft. Continue holding 87 deg inc. 2.47 / 2.43 bpm C~ 3600 psi FS, 4000-4400 psi while drilling. ROP is 150-180 ft/hr with 1-2 Klbs DWOB. Drill to 10590 ft. Cycle pipe to 79 Klbs several times, no movement up or down. Able to turn orienter freely. Pump >1 bottoms up at 2.87 / 2.85 bpm, until annular pressure levels off. After bottoms up shut down pump for 10 min, then cycle pipe several times OK to 83K, no go. Pull to 60K and start agitator, pull several more times no-go. Call for crude. Shut down pump for 15 min to relax hole. DWOB slowly increasing. Cycle pipe 3 more times -5K to 83K, no go. Circ 2 bpm at neutral wt while waiting for crude. Still able to turn orientor freely. Crude arrives, get it hooked up and vapor tested. Vapor is 1.2 psi, OK to pump. Take 10 bbls crude first pill. At 5 bbls out bit shut down pump, let crude soak for 5 min. Printed: 2/19/2009 12:52:48 PM s • BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: Date 'From - To Hours I Task ~ Code NPT Phase Description of Operations 1/25/2009 102:40 - 04:00 1.33 DRILL N STUC PROD1 Cycle pipe OK to 83K with pump off 2 times, no go. 04:00 - 04:50 0.83 DRILL N STUC PROD1 04:50 - 06:00 1.17 DRILL N STUC PROD1 06:00 - 08:00 2.00 DRILL N STUC PROD1 08:00 - 08:45 0.75 DRILL N STUC PROD1 08:45 - 09:00 0.25 DRILL N STUC PROD1 09:00 - 10:15 1.25 DRILL N STUC PROD1 10:15 - 11:15 1.00 DRILL N STUC PROD1 11:15 - 12:00 0.75 DRILL N STUC PROD1 12:00 - 13:30 1.50 DRILL N STUC PROD1 13:30 - 14:00 0.50 DRILL N STUC PROD1 Pump another 2 bbls crude out, let it sit 10 min. Cycle pipe OK to 83K 3 more times, no-go. Go to neutral wt, pump remaining 3 bbls of crude out, try one pull while agitator is running. Let crude soak for 15 min. Cycle pipe 2 times OK to 83K, no go. Circulate crude out prior to starting another pill. downhole. Pump 20 bbls crude pill. Pump 18 bbls out the bit then shut down pump (17.3 bbls OH annular volume). Let it soak for 15 min. Cycle pipe 2 times OK to 83K, no movement. Pump 1 bbl to warm up CT, then soak another 20 min. Allow crude to soak. pump .5 bbl periodically to arevent , freezing CT. Pressure backside to ECD egilevent 9.6. Soak 10 min Bleed off rapidly work pipe -7 to 88K. NO Go. Circulate to activate adgitator while working pipe. Pumped 11 bbls.No Go. Pressure backside and hold for Bleed off rapidly as come on with pump. Work pipe No Go. Circulate Crude out. Prep to swap to Crude. Holding 80K on CT #2 genetator lost bearing on fan drive. Down to one motor. Swap well to crude. In total In Density Out Density ECD Rate 25 7.18 8.7 9.92 1.67/1.67 42 7.18 8.7 9.93 1.69/1.7 57 7.18 8.72 9.92 1.69/1.72 crude to bit 75 7.18 8.73 9.70 1.68/1.71 crude at window 77 bbl 85 7.17 8.72 9.37 1.67/1.70 lost 3k over pull. 100 7.17 8.72 9.04 1.66/1.68 WOB 7.6 105 7.17 8.72 8.93 1.65/1.67 7.8 110 7.15 8.72 8.73 1.65/1.67 8.13 115 7.15 8.72 8.67 1.65/1.66 8.22 120 7.15 8.72 8.49 1.65/1.67 8.47 125 7.15 8.72 8.38 1.65/1.65 8.35 126 POP free. POH to window pumpimg min rate on one motor. POH to 9040'. Log tie-in. Correction + 10'. PU above window. Complete replacement of cooling fan assembly on generator #2. RIH. Took 30 bbl to catch fluid. Circulate 2.55/1.35 bpm. Continue to circulate 2.52/2.40 bpm. 64 bbl after mud turned corner Returns 2.54/ 2/54. Well flowing. Shut in well. Circulate thru choke. _~ CIR thru choke while maintaining ECD 10.3+. Circulate out gas Printed: 2/19/2009 12:52:48 PM ~ ~ BP EXPLORATION Page 10 of 14 ~ Operations Summary Report Legal Well Name: K-06 Common W Event Nam Contractor Rig Name: Date ell Name: e: Name: From - To K-06 REENTE NORDIC NORDIC Hours R+COM CALIST 1 Task ' PLET A Code E NPT Start Rig Rig Phase Spud Date: 11/5/1983 : 1/12/2009 End: 1/30/2009 Release: 1/30/2009 Number: Description of Operations 1/25/2009 13:30 - 14:00 0.50 DRILL N STUC PROD1 bubble. 14:00 - 15:00 1.00 DRILL N STUC PROD1 Complete wiper to window. RIH tag at 10,603. 15:00 - 17:30 2.50 DRILL P PROD1 Drill at 2.5 bpm ~ 3840 PSI FS = 3700 psi, DWOB .2K,ECD 10.2ppg, ROP 80+.With new mud at bit. Drill at 2.5 bpm @ 3830 psi FS= 3700 psi, DWOB .4K, ECD 9.88 ppg. ROP 80 with new mud to surface. Drill to 10748'. 17:30 - 19:10 1.67 DRILL P PROD1 Wiper to window. 2.4 BPM at 3322 psi. ECD 9.73. 19:10 - 21:30 2.33 DRILL P PROD1 Drill from 10750 ft. Hold 87.5 deg inc to TD. 2.63 / 2.55 bpm (~ 3700 psi FS, 4000-4200 psi while drilling. ECD = 9.80 ppg. ROP is around 100 ft/hr with 1-2K DWOB. PVT = 282 bbls. Past 10800 ft hold 90 deg inc, ROP slows to 30-50 fUhr, picks back up after 10,840 ft. Drill to 10,900 ft. 21:30 - 23:30 2.00 DRILL P PROD1 Wiper trip from 10,900 ft to window. Stack wt at 10,812 ft on the way down, shales. 23:30 - 00:00 0.50 DRILL P PROD1 Drill from 10,900 ft. Hold 88 deg inc to TD. 2.63 / 2.56 bpm C~1 3800 psi FS. PVT = 262 bbls. ROP is 80-100 ft/hr with 1-2 Klbs DWOB. Drill to 10,935 ft. 1/26/2009 00:00 - 00:45 0.75 DRILL P PROD1 Continue drilling from 10,935 ft to TD of 11,000 ft. 00:45 - 03:20 2.58 DRILL P PROD1 Wiper trip back to window + tie-in log. Correct +4.5 ft. Stack wt at 10,825 ft while RIH, make 2 passes through this area. Ta bottom at 11 005 ft official TD. 03:20 - 05:15 1.92 DRILL P PROD1 POOH, la in liner ill from TD. Pull through window and POOH. 05:15 - 05:30 0.25 DRILL P PROD1 PJSM for UD BHA. Crew positions and hand placement were discussed. 05:30 - 07:30 2.00 DRILL P PROD1 LD lateral drilling BHA. 07:30 - 08:30 1.00 DRILL N RREP PROD1 Injector broken upper traction cyclinder leaking. 08:30 - 10:30 2.00 DRILL P PROD1 PU 2 joints PH-6 and injector. Circulate slack from CT 4 bpm 3430 psi. POP off well .Cut 348' of wire. 10:30 - 12:30 2.00 CASE P RUNPRD PU liner running tools. Prep floor for running liner. 12:30 - 17:40 5.17 CASE P RUNPRD PU liner. 17:40 - 18:30 0.83 CASE P RUNPRD PU injector, MU CT to liner. Circulate at surface until clean returns. 18:30 - 20:30 2.00 CASE P RUNPRD Set pump trip at 1500 psi, RIH with liner BHA. Wt check at 9,000 ft is 35K. Pass through window and RIH to bottom. Nothing seen at window. Taaaina shales past 10.800 ft. Up wt is 44K. RIH back to 11,004 ft, hard tag. Establish circulation rate, getting around 95% returns at 1.5 bpm, same as when drilling. 20:30 - 21:05 0.58 CASE P RUNPRD Move reel to good ball drop position. Drop 5/8" steel ball and launch with 800 psi. Ball is heard rolling at 2.00 / 1.93 bpm ~ 2580 psi. Slow to 1 bpm after ball goes over gooseneck. Ball on seat at 41.2 bbls, shears at 3200 si. Pick up until wt breaks over then pick up 1 ft more to confirr Printed: 2/19/2009 12:52:48 PM ~ ~ BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: Date ~', From - To Hours Task Code' NPT Phase Description of Operations 1/26/2009 20:30 - 21:05 0.58 CASE I~ 21:05 - 00:00 2.92 CEMT P 1/27/2009 100:00 - 00:30 I 0.501 CEMT I P 00:30 - 01:00 ~ 0.50 ~ CEMT ~ P 01:00 - 01:35 0.58 CEMT P 01:35 - 03:00 1.42 CEMT P RUNPRD release. New up wt is 30K. RUNPRD Set 10K back down on tool and swap well over to 2% double slick KCI. 1.85 / 1.78 bpm @ 760 psi after well is swapped to water. Finish swap to KCI and mix 80 bbls 2# biozan in Pit #3. Bring rest of KCI water onboard. RUNPRD Continue mixing 80 bbl 2# biozan and bringing rest of KCI onboard. RUNPRD SAFETY MEETING. PJSM for pumping cement. Job procedure and hazards were discussed. RUNPRD Batch up 28.3 bbls pumpable. RUNPRD Cement is up to weight. PT cement line to 6,500 psi, good. Open up cement line to CT, start cement down CT. Zero In MM on density change. Shut down cement pump at 28.2 bbls In MM. Isolate reel and pump biozan out to cement van to clean lines. Zero In/Out MM and start displacement with biozan, using rig pump. Displace cement from CT at 2.04 / 1.96 bpm. At 43.2 bbls on In MM cement is at shoe, zero the Out MM leave In MM running. In Out 43.2 0 45 1.7 50 6.4 55.9 11.9 At 55.9 bbls on In MM, 2 bbls cement left in CT + PH6. Shut down pump and pick up out of flappers, CT wt + 12 ft. Open Baker choke and stack 10K back down to same depth. Close Baker choke and pressure up to 3,200 psi to shear plug out. plug at 1.70 / 1.56 bpm ~ 2500 psi. In Out (after subtracting exhaust volume) 61.9 12.9 65 15.5 70.7 20.9 75.2 25.3 Bump plug at 75.2_bbls. (75.3 calculateol. Pressure up to 1,000 psi over circ pressure ,hold for 1 min. Open Baker choke, floats are holding. Close Baker choke, pressure up to 500 psi and pull out of seals, pump 1.0 bbl. 03:00 - 04:30 I 1.501 CEMT I P RUNPRD ~ POOH replacing coil voidage. Printed: 2/19/2009 12:52:48 PM ~ ~ BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of Operations 1/27/2009 04:30 - 04:45 0.25 CEMT P RUNPRD PJSM for LD liner running tools, and picking up cleanout BHA. 04:45 - 05:30 0.75 CEMT P RUNPRD Tag stripper and lay down PH6 and liner running tools. Tool has functioned normally, recover 5/8" ball. 05:30 - 08:00 2.50 PERFO P LOWERI PU BHA #11 -Cleanout 2.30 Carbide Mill BTT 2-1/8" Extreme Motor BTT DUAL CIRC SUB, 1/2" BALL SEAT BTT HYD DISC, 5/8" BALL SEAT XO, 1-1/4" CSH X 1-1/2" MT 36 stands 1.25 CSH ave 30.99' XO, 2-3/8 REG X 1-1/4 CSH BOT HYD DISC, 3/4" BALL DBPV XO, 2-3/8" PH6 X 2-3/8 Reg 6 JTS OF 2-3/8 PH-6 Tubing BOT X-O, 2-7/8" PAC X 2-3/8" PH6 Lockable swivel X-O, 2-3/8" PH6 X 2-7/8" PAC BOT SLIP TYPE CTC BHA OAL = 2,444.27 ft 08:00 - 10:00 2.00 EVAL P LOWERI RIH with milling Assembly with parabolic cut-rite mill. Ta ~ 8 848.5' 10:00 - 11:10 1.17 EVAL P LOWERI Mill SELRT rofile in liner to . Motor work ranged from 1,850 psi FS to 2,300 psi. Milled from 8848.5 to 8849.0 . Ten stalls during the milling operation. 11:10 - 13:00 1.83 EVAL P LOWERI RIH . Irradic run in wt from 10200 to 10,350, PU to 10100 Clean, RIH to 10500 OK. RIH irradic RI wts but no motor work. Act like junk above us over pulls 5-6K. Work in stacking 10515,10520,10527, 10558, 10566 no go 13:00 - 14:20 1.33 EVAL P LOWERI POH 36K PU to above liner to 8810. 14:20 - 15:20 1.00 EVAL P LOWERI RIH tag at 10566 push to 10586. Retag No Go past 10586. 15:20 - 16:30 1.17 EVAL P LOWERI POOH 16:30 - 16:45 0.25 EVAL P LOWERI PJSM for UD of Cleanout Assy. 16:45 - 19:30 2.75 EVAL P LOWERI U Ian t As 19:30 - 20:30 1.00 BOPSU P RUNPRD Run in and Jet stack Bring new motor and mill (Diamond parabolic) up to rig floor 20:30 - 20:45 0.25 EVAL N DFAL LOWERI PJSM for PU of new cleanout assy, discuss procedure, hazards and mitigations 20:45 - 23:00 2.25 EVAL N DFAL LOWERI PU new mill, motor and agitator, circ sub, 5/8" HYD disc, xo, 36 stands of CSH, xo, 3/4" hyd disc, DBPV, xo, 6 jts of PH6, xo, lockable swivel, xo, and CTC Total length 2450.33' 23:00 - 00:00 1.00 EVAL N DFAL LOWERI RIH 1/28/2009 00:00 - 01:00 1.00 EVAL N DFAL LOWERI Continue RIH, check up weight 30K 01:00 - 04:15 3.25 EVAL N DFAL LOW ER1 Ta the old mill fish at 10 585' Begin pushing fish to PBTD, circ press 1800 psi, 1.38 bpm, CT down weight 9K-12K Push fish until it stops moving, PU and try again, continue repeating this process, many times Printed: 2/19/2009 12:52:48 PM i • BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Event Name: REENTER+COMPLET Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code I _ __ _ __ 1/28/2009 01:00 - 04:15 3.251 EVAL N 04:15 - 06:00 1.75 EVAL N 06:00 - 08:30 2.50 EVAL N 08:30 - 09:30 1.00 EVAL P 09:30 - 10:00 0.50 EVAL P 10:00 - 11:15 1.25 EVAL P 11:15 - 11:30 0.25 EVAL P 11:30 - 14:00 2.50 EVAL P 14:00 - 15:00 1.00 EVAL P 15:00 - 16:30 1.50 EVAL P 16:30 - 17:10 0.67 EVAL P 17:10 - 18:00 0.83 EVAL P 18:00 - 18:15 0.25 EVAL P 18:15 - 18:45 0.50 EVAL P 18:45 - 19:00 0.25 EVAL P 19:00 - 21:30 2.50 EVAL P 21:30 - 22:30 1.00 CEMT P 22:30 - 00:00 I 1.501 PERFOBI P 1/29/2009 100:00 - 00:30 0.501 PERFOB~ P 00:30 - 05:30 I 5.001 PERFOBI P Spud Date: 11 /5/1983 Start: 1 /12/2009 End: 1 /30/2009 Rig Release: 1/30/2009 Rig Number: NPT ' Phase Description of Operations DFAL LOWERi __ 10,763' sat down several times w/ very little progress, Work down to 10 810' Push down to 10959' ~ 60 fUmin DFAL LOWERI POOH DFAL LOWERI LD 6 Jts PH-6 Stand back 36 stands of 1-1/4" CSH. LOW ER1 Circulate slack forward. No wire pumped. Cut 10' to expose wire. (wire trimed to use swizzel stick to flush stack. wire move above CTC.Pumping forward didn't mowe the wire. Trin CT and reboot wire.) LOWERI Assemble and test memory tools. LOWERi Install new CTC, Pressure test andpull test. LOWERi PJSM for ickin u memo to tool and source. LOW ER1 PU memory tool in carrier, 36 stands of CSH and 6 jt PH-6 tubing. LOWERI RIH to 8500'. LOWERI Log down from 8500 at 30 ft/min. LOWERI LOG up 60 fUmin. LOWERI POOH to top of BHA LOW ER1 PJSM for UD of extra liner from pipe shed LOW ER1 UD extra liner from pipe shed LOWERI PJSM for UD of logging BHA LOWERI UD logging BHA RUNPRD Pressure test liner lap to 2000 psi Start 2084 psi 15 min 2073 psi 30 min 2069 psi Lost 15 si in 30 min LOWERI RU to run guns, Download logs, interpret and send to town PBTD=10971.8' TD=11,011' LOWERI PJSM for running guns, discuss procedure, hazards and mitigations LOWERI E PU 1513' guns and blanks, 12 stands CSH and 4 jts of PH6 Total length - 2397.1' 05:30 - 07:15 1.75 PERFO P LOWERI RIH w/ perf guns tagged TD and corrected to 10972'. 07:15 - 08:05 0.83 PERFO P LOWERI Pick up to ball drop position. Ball on seat at 51.0 bbls. Pick up and shot on the fl lace bottom shot at 10961'. Sheared at 3000 psi. 08:05 - 10:00 1.92 PERFO P LOWERi POH to 8800. Flow check OK. Continnue to POH. 10:00 - 11:15 1.25 PERFO P LOWERI POOH & UD CSH to top of guns 11:15 - 11:30 0.25 PERFO P LOWERI PJSM for UD of perf guns , 11:30 - 15:00 3.50 PERFO P LOWERi 15:00 - 15:30 0.50 PERFO P LOWERI RIH with 3 stands stood back. POH lay down same. 15:30 - 16:45 1.25 WHSUR P POST PU Nozzel and RIH for FP 16:45 - 17:15 0.50 WHSUR P POST FP well to 2,000' 17:15 - 17:45 0.50 WHSUR P POST POOH 17:45 - 18:30 0.75 WHSUR P POST 18:30 - 20:30 2.00 RIGD P POST Start cooling N2 Pump 5 bbls of McOH PT N2 to 3500 psi Start on N2, the N2 units airline to the transmission must have froze, need to get a new N2 truck out. Printed: 2/19/2009 12:52:48 PM • BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: K-06 Common Well Name: K-06 Spud Date: 11/5/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: 1/30/2009 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2009 Rig Name: NORDIC 1 Rig Number: ~ Date From - To ,Hours ' Task Code I NPT Phase Description of Operations 1/29/2009 18:30 - 20:30 2.00 RIGD P POST Start cleaning pits 20:30 - 22:00 1.50 RIGD N SFAL POST Pump through coil intermittently until new N2 truck is on location 22:00 - 22:15 0.25 RIGD P POST Rig up new N2 22:15 - 22:30 0.25 RIGD P POST PJSM for reel blowdown, discuss procedure, hazards and mitigations 22:30 - 00:00 1.50 RIGD P POST Begin cooling N2 1/30/2009 00:00 - 02:00 2.00 RIGD P POST 02:00 - 02:20 0.33 RIGD P POST 02:20 - 03:30 1.17 RIGD P POST 03:30 - 07:00 3.50 RIGD P POST 07:00 - 07:30 0.50 RIGD N POST 07:30 - 08:30 1.00 RIGD N POST 08:30 - 12:30 4.00 RIGD N POST 12:30 - 13:30 1.00 RIGD P POST 13:30 - 15:30 2.00 RIGD N POST 15:30 - 16:00 0.50 RIGD N POST Pump 10 bbl McOH, PT N2 to 3500 psi Pump N2 Rig down N2, Bleed pressure down Cut off CTC, install grapple, pull test. Pull coil across and secure reel PJSM for reel swap, discuss procedure, hazards and mitigtions w/ truck drivers and crew Lower coil onto trailer and PU new reel Swap BOP to 2" coil Disconnect traction motor wiring and prep for move PJSM for traction motor swap. Open pipe shed roof. Pick traction motor form pipe shed and replace. Install traction motor and test. ND BOP. Install Tree Cap. Thaw and repair test pump. Test Tree cap to 3000 psi. Release Rig. ~ 16:00. Printed: 2/19/2009 12:52:48 PM • .~~~ BAKER 1~1~1~~ INTEQ North America -ALASKA - BP Prudhoe Bay PB K Pad K-06 K-06B Design: K-06B Survey Report -Geographic ZO February, 2009 by ~t~ ~ • Bes Survey Report -Geographic Company: North America -ALASKA - BP Project: Prudhoe Bay Site:. PB K Pad Well: - ' K-06 Wellbore: K-06B Design: K-066 by Local Co-ordinate Reference: Site PB K Pad TVD Reference: Mean Sea Level MD Reference: K-06A: @ 53.60ft (K-06A:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P project Prudhoe Bay, North Slope, UNITED STATES Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Site PB K Pad, TR-11-14 Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Slot Radius: 5,973,161.33ft Latitude: 670,342.10ft Longitude: 0" Grid Convergence: 70° 19' 57.435 N 148° 37' 5.245 W 1.30 ° Well Position +N/S 1,886.41ft Northing: 5,975,058.OOft Latitude: 70° 20' 15.988 N +E/_yy 478.89 ft Easting: 670,778.OOft Longitude: 148° 36' 51.258 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore ~ K-O6B --- -- - _ ~ Magnetics Model Name Sample Date Declination ' $ip Angte ' Field Strength b99m2007 12/5/2008 22.97 80.96 57,691 Design K-O6B---. ----- -- -- ------ - - - - .- - - - m ~ Audit Notes: Version: 2 Phase: ACTUAL Tie On Depth: 9,045.73 ~ V®rtical Section: Depth from (TVD) +N/S +FJ-W Direction -25.77 1,886.41 478.89 335.95 Survey Program Date. 2/20/2009 From`... To (ft) (ft) Survey (Wellbore) Tool Name Description 90.68 8,138.91 1 : Sperry-Sun BOSS gyro multi (K-06) BOSS-GYRO Sperry-Sun BOSS gyro multishot 8,140.23 9,045.73 K-O6A (K-06A) MWD MWD -Standard I 9,069.00 11,011.00 MWD (K-068) MWD MWD -Standard I~ 2/202009 10:59:27AM Page 2 COMPASS 2003.16 Build 70 ~t~ sees 1NTEQ Company; North America -ALASKA - BP Project: Prudhoe Bay `Site: PB K Pad Welk ' K-06 Weilbore: K-06B Design: K-06B Survey Survey Report -Geographic • tocatCo-ordinate Reference: 'Site PB K Pad ND Reference: Mean Sea Level MD Reference:...; K-06A: @ 53.60ft (K-06A:) North References True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Measured TVD Below .Depth Inclination Azimuth .System +N/S +E/-W (~} t°j (°) (~) (ftl jnj 9,045.73 28.47 66.80 8,533.68 3,900.53 1,329.89 Map Map.. Northing Easting (~) (ft) 5,977,090.79 671,582.99 by Latkude Longitude 70° 20' 35.795 N 148° 36' 26.393 W TIP 9,069.00 31.07 67.32 8,553.87 3,905.03 1,340.53 5,977,095.53 671,593.52 70° 20' 35.840 N 148° 36' 26.082 W KOP ' ', 9,091.51 26.16 59.46 8,573.63 3,909.80 1,350.18 5,977,100.52 671,603.05 70° 20' 35.887 N 148° 36' 25.800 W 9,127.49 13.43 47.54 8,607.43 3,916.68 1,360.13 5,977,107.62 671,612.85 70° 20' 35.954 N 148° 36' 25.509 W ~, 9,157.97 15.57 353.94 8,637.07 3,923.17 1,362.32 5,977,114.16 671,614.89 70° 20' 36.018 N 148° 36' 25.445 W ', 9,189.15 22.12 339.46 8,666.57 3,932.84 1,359.82 5,977,123.77 671,612.17 70° 20' 36.113 N 148° 36' 25.518 W ', 9,219.17 26.53 311.43 8,694.01 3,942.61 1,352.78 5,977,133.37 671,604.91 70° 20' 36.209 N 148° 36' 25.724 W 9,248.19 33.75 296.14 8,719.13 3,950.47 1,340.65 5,977,140.96 671,592.61 70° 20' 36.287 N 148° 36' 26.078 W 9,278.25 41.86 287.15 8,742.88 3,957.12 1,323.53 5,977,147.22 671,575.34 70° 20' 36.352 N 148° 36' 26.578 W II 9,309.50 51.63 284.67 8,764.27 3,963.31 1,301.66 5,977,152.91 671,553.34 70° 20' 36.413 N 148° 36' 27.217 W 'I 9,342.60 61.46 282.24 8,782.49 3,969.70 1,274.83 5,977,158.69 671,526.37 70° 20' 36.476 N 148° 36' 28.001 W 9,374.60 71.45 282.14 8,795.26 3,975.88 1,246.19 5,977,164.22 671,497.60 70° 20' 36.537 N 148° 36' 28.837 W ~~ 9,405.70 81.03 280.45 8,802.65 3,981.78 1,216.60 5,977,169.45 671,467.89 70° 20' 36.595 N 148° 36' 29.702 W 9,436.52 90.49 280.26 8,804.93 3,987.30 1,186.40 5,977,174.28 671,437.57 70° 20' 36.649 N 148° 36' 30.584 W 9,467.00 91.17 272.78 8,804.48 3,990.76 1,156.15 5,977,177.05 671,407.25 70° 20' 36.683 N 148° 36' 31.468 W I, 9,498.54 89.88 262.93 8,804.20 3,989.58 1,124.67 5,977,175.15 671,375.81 70° 20' 36.672 N 148° 36' 32.388 W ~I 9,529.41 91.35 253.63 8,803.86 3,983.32 1,094.48 5,977,168.21 671,345.77 70° 20' 36.610 N 148° 36' 33.270 W ~'i 9,559.75 89.66 250.88 8,803.60 3,974.07 1,065.59 5,977,158.31 671,317.09 70° 20' 36.519 N 148° 36' 34.114 W ~ 9,588.53 90.09 247.46 8,803.66 3,963.84 1,038.69 5,977,147.47 671,290.44 70° 20' 36.419 N 148° 36' 34.900 W 9,620.77 89.91 242.76 8,803.66 3,950.27 1,009.45 5,977,133.24 671,261.52 70° 20' 36.285 N 148° 36' 35.754 W I 9,652.19 88.28 240.25 8,804.15 3,935.29 981.85 5,977,117.64 671,234.26 70° 20' 36.138 N 148° 36' 36.560 W l i 9,682.91 87.70 240.84 8,805.23 3,920.19 955.12 5,977,101.94 671,207.88 70° 20' 35.989 N i 148° 36' 37.342 W II 9,713.13 88.99 246.05 8,806.11 3,906.69 928.10 5,977,087.83 671,181.19 70° 20' 35.857 N 148° 36' 38.131 W ', 9,743.73 87.51 249.84 8,807.04 3,895.21 899.76 5,977,075.71 671,153.12 70° 20' 35.744 N 148° 36' 38.959 W '~, 9,773.29 86.44 253.56 8,808.60 3,885.94 871.74 5,977,065.81 671,125.31 70° 20' 35.653 N 148° 36' 39.777 W', 9,803.43 87.30 259.10 8,810.25 3,878.83 842.51 5,977,058.03 671,096.25 70° 20' 35.583 N 148° 36' 40.631 W ', 9,833.87 87.60 264.12 8,811.60 3,874.40 812.44 5,977,052.92 671,066.29 70° 20' 35.539 N 148° 36' 41.510 W j 9,864.23 87.27 269.06 8,812.96 3,872.59 782.17 5,977,050.43 671,036.07 70° 20' 35.521 N 148° 36' 42.394 W' 9,895.23 87.63 273.76 8,814.34 3,873.36 751.22 5,977,050.49 671,005.12 70° 20' 35.529 N 148° 36' 43.298 W 9,928.06 87.70 277.10 8,815.68 3,876.46 718.57 5,977,052.85 670,972.41 70° 20' 35.560 N 148° 36' 44.252 W 9,961.29 88.00 273.32 8,816.93 3,879.47 685.50 5,977,055.11 670,939.28 70° 20' 35.589 N 148° 36' 45.218 W 10,000.53 88.18 267.75 8,818.24 3,879.84 646.30 5,977,054.59 670,900.09 70° 20' 35.593 N 148° 36' 46.363 W ', 10,030.97 85.88 265.67 8,819.81 3,878.10 615.96 5,977,052.15 670,869.79 70° 20' 35.576 N 148° 36' 47.250 W ~~ 10,061.91 ~ 85.79 261.94 8,822.06 3,874.77 585.29 5,977,048.13 670,839.20 70° 20' 35.543 N 148° 36' 48.146 W I 'I 10,095.43 86.13 257.19 8,824.42 3,868.71 552.41 5,977,041.33 670,806.48 70° 20' 35.483 N 148° 36' 49.106 W 10,130.65 87.52 250.95 8,826.38 3,859.06 518.61 5,977,030.92 670,772.91 70° 20' 35.389 N 148° 36' 50.094 W 10,160.25 88.90 247.82 8,827.30 3,848.65 490.93 5,977,019.88 670,745.47 70° 20' 35.286 N 148° 36' 50.903 W 10,194.47 89.57 248.33 8,827.76 3,835.87 459.19 5,977,006.38 670,714.03 70° 20' 35.161 N 148° 36' 51.830 W'; 10,228.61 87.89 250.88 8,828.52 3,823.98 427.20 5,976,993.77 670,682.32 70° 20' 35.044 N 148° 36' 52.765 W'.; 10,261.77 87.17 256.76 8,829.95 3,814.75 395.39 5,976,983.82 670,650.74 70° 20' 34.953 N 148° 36' 53.694 W'~, 10,289.93 87.58 261.70 8,831.24 3,809.50 367.77 5,976,977.94 670,623.24 70° 20' 34.901 N 148° 36' 54.501 W 10,328.61 88.06 267.20 8,832.71 3,805.76 329.31 5,976,973.33 670,584.88 70° 20' 34.864 N 148° 36' 55.624 W 10,356.83 88.28 272.58 8,833.61 3,805.71 301.12 5,976,972.64 670,556.70 70° 20' 34.864 N 148° 36' 56.448 W 10,386.28 87.02 275.18 8,834.82 3,807.70 271.76 5,976,973.96 670,527.31 70° 20' 34.884 N 148° 36' 57.306 W 10,419.03 85.23 271.10 8,837.03 3,809.49 239.14 5,976,975.01 670,494.66 70° 20' 34.901 N 148° 36' 58.258 W 10,447.96 84.86 266.60 8,839.53 3,808.91 210.34 5,976,973.78 670,465.87 70° 20' 34.895 N 148° 36' 59.100 W 10,479.80 86.28 261.22 8,841.99 3,805.54 178.78 5,976,969.69 670,434.41 70° 20' 34.862 N 148° 3T 0.022 W 10,511.37 89.79 257.13 8,843.08 3,799.62 147.80 5,976,963.07 670,403.57 70° 20' 34.804 N 148° 3T 0.927 W ', 10,542.34 90.00 253.50 8,843.13 3,791.77 117.85 5,976,954.54 670,373.81 70° 20' 34.727 N 148° 3T 1.802 W'; 10,572.58 90.34 257.47 8,843.04 3,784.19 88.58 5,976,946.30 670,344.72 70° 20' 34.652 N 148° 3T 2.657 W !, ~~, 10,605.14 88.28 254.26 8,843.44 3,776.24 57.02 5,976,937.64 670,313.34 70° 20' 34.574 N 148° 3T 3.579 W i ~I~ 10,674.52 84.39 268.28 8,848.33 3,768.50 -11.56 5,976,928.35 670,244.96 70° 20' 34.498 N 148° 37,5.583 W 2/20/2009 10:59:27AM Page 3 COMPASS 2003.16 Buifd 70 ~,, s • • lts Survey Report -Geographic by INTEQ company: ' , North America -ALASKA - BP Locai Co-ordinate Reference: Site PB K Pad Project: Prudhoe Bay TVD Reference: `Mean Sea Level Site:. PB K Pad MDReference: K-06A: @ 53.60ft (K-06A:) Well K-06 North Reference: True Welibore: K-066 Survey Calculation Method: Minimum Curvature t~esign: K-O6B Database: EDM .16 - Anc Prod - WH24P . Survey --- -- Measured TVD Below Map .Map Depth; ' Inclination,. Azimuth - System +N!-S +E/-W Northing Easting (ft) (°) ; (°) (~) (ft) (ft) {ft) (ft) Latitude Longitude 10,703.65 84.83 270.02 8,851.06 3,768.07 -40.56 5,976,927.26 670,215.99 70° 20' 34.494 N 148° 37' 6.430 W 10,733.13 85.13 273.47 8,853.64 3,768.97 -69.91 5,976,927.49 670,186.63 70° 20' 34.503 N 148° 37' 7.287 W 10,763.31 87.66 273.73 8,855.54 3,770.86 -99.96 5,976,928.69 670,156.54 70° 20' 34.521 N 148° 37' 8.165 W 10,793.17 88.61 269.55 8,856.51 3,771.71 -129.79 5,976,928.87 670,126.70 70° 20' 34.530 N 148° 3T 9.037 W 10,824.31 89.72 265.18 8,856.97 3,770.28 -160.89 5,976,926.73 670,095.65 70° 20' 34.516 N 148° 3T 9.945 W 10,855.23 90.93 261.23 8,856.79 3,766.62 -191.58 5,976,922.38 670,065.05 70° 20' 34.480 N 148° 37' 10.842 W ', 10,887.13 90.71 256.87 8,856.33 3,760.57 -222.89 5,976,915.61 670,033.89 70° 20' 34.420 N 148° 3T 11.756 W 10,918.83 88.38 252.90 8,856.59 3,752.30 -253.48 5,976,906.66 670,003.49 70° 20' 34.339 N 148° 3T 12.650 W 10,945.97 88.07 250.46 8,857.43 3,743.78 -279.23 5,976,897.55 669,977.94 70° 20' 34.255 N 148° 3T 13.402 W ', 11,011.00 88.07 250.46 8,859.62 3,722.04 -340.48 5,976,874.43 669,917.20 70° 20' 34.041 N 148° 3T 15.192 W ', 2.875" 2/202009 10:59:27AM Page 4 COMPASS 2003.16 Build 70 //its IsAKtR s INTEQ Company: - North America -ALASKA - BP Project: Prudhoe Bay Site:. ~ PB K Pad WeiL• K-O6 Weltbore: K-06B Design: K-06B Targets `' Target .Name Survey Report -Geographic "Local Co-ordinate Reference: 'Site PB K Pad N0 Reference:. Mean Sea Level MD Reference: K-06A: (a~ 53.60tt (K-06A:) North Reference:. True Survey Calculation Method:.. Minimum Curvature Database:. EDM .16 - Anc Prod - WH24P - hit/miss target ' Dip Angle 'Dip Dir.. ND +N/S +E/-W Northing Easting -Shape (°) (°) (n) (ft) (~) , tn) (ft) K-O6B Fault 1 0.00 0.00 0.00 3,897.81 -82.61 5,977,056.00 670,171.00 - actual wellpath misses target center by 8649.79ft at 9045.73ft MD (8533.68 ND, 3900.53 N, 1329.89 E) - Polygon Point 1 0.00 3,897.81 -82.61 5,977,056.00 670,171.00 Point 2 0.00 3,996.90 529.84 5,977,168.96 670,781.01 Point 3 0.00 4,093.65 1,069.22 5,977,277.93 671,318.01 Point4 0.00 3,996.90 529.84 5,977,168.96 670,781.01 by Latitude` Longitude , 70° 20' 35.770 N 148° 3T 7.658 W K-066 Target 2 0.00 0.00 8,830.00 3,803.77 270.37 5,976,970.00 670,526.00 70° 20' 34.845 N 148° 36' 57.346 W -actual wellpath m isses target center by 6.32ft at 10387.13ft MD (8834.86 ND, 3807.77 N, 270.92 E) - Point l K-06B Polygon 0.00 0.00 0.00 3,820.09 -712.58 5,976,964.00 669,543.00 70° 20' 35.005 N 148° 3T 26.062 W i -actual wellpath m isses target center by 8775.07ft at 9045.73ft MD (8533.68 ND, 3900.53 N, 1329.89 E) I, -Polygon Point 1 0.00 3,820.09 -712.58 5,976,964.00 669,543.00 Point 2 0.00 3,841.41 64.16 5,977,002.95 670,319.00 Point 3 0.00 4,048.08 1,355.28 5,977,238.87 671,605.02 Point4 0.00 3,867.90 1,404.20 5,977,059.86 671,658.01 Point 5 0.00 3,645.92 -707.55 5,976,790.00 669,551.99 ~I K-O66 Target 1 0.00 0.00 8,796.00 3,912.80 1,195.14 5,977,100.00 671,448.00 70° 20' 35.916 N 148° 36' 30.329 W -actual wellpath m isses target center by 72.15ft at 9413.91ft MD (8803.75 ND, 3983.25 N, 1208.61 E) - Point ~ K-066 Fault 2 0.00 0.00 0.00 3,514.95 -710.51 5,976,659.00 669,552.00 70° 20' 32.004 N 148° 3T 26.001 W -actual wellpath m isses target center by 8782.68ft at 9045.73ft MD (8533.68 ND, 3900.53 N, 1329.89 E) ~, -Polygon Point 1 0.00 3,514.95 -710.51 5,976,659.00 669,552.00 ~ Point 2 0.00 3,507.23 374.67 5,976,675.93 670,637.00 I ~~ Point 3 0.00 3,384.00 1,393.19 5,976,575.86 671,657.99 I~ Point 4 0.00 3,507.23 374.67 5,976,675.93 670,637.00 ', K-066 Target 3 0.00 0.00 8,873.00 3,770.81 -612.67 5,976,917.00 669,644.00 70° 20' 34.521 N 148° 3T 23.143 W -actual wellpath m isses target center by 276.84ft at 11011.OOft MD (8859.62 ND, 3722.04 N, -340.48 E) -Point K-06B Fault 3 0.00 0.00 0.00 3,751.15 -936.22 5,976,890.00 669,321.00 70° 20' 34.327 N 148° 3T 32.596 W ', -actual wellpath m isses target center by 8830.70ft at 9045.73ft MD (8533.68 ND, 3900.53 N, 1329.89 E) -Polygon II Point 1 0.00 3,751.15 -936.22 5,976,890.00 669,321.00 i Point 2 0.00 4,070.34 -588.84 5,977,216.98 669,661.02 2,663.68 2,609.94 13 3/8" 11,011.00 8,859.62 2.875" Design Annotations. Measured Depth lft) 9,045.73 9,069.00 ~ 11,011.00 .Vertical. LocaLCoordinates - Depth ±NlS +E/-W (ff) (ft) (ft) Comment 8,533.68 3,900.53 1,329.89 TIP 8,553.87 3,905.03 1,340.53 KOP 8,859.62 3,722.04 -340.48 TD 13-3%8 17-1/2 ~ 2-7/8 6-1/8 ~ Checked By: Approved By: Date: 2/20!2009 10:59:27AM Page 5 COMPASS 2003.16 Build 70 r : ~' /"". t ! ~ !.~ ~ ~ i8 .,d P'~ V 1 .... ~ ~.~ ~.. ~ ~.~_._.1 ~s ~..f (._.1 ALASSiA OII, ArTD GAS C01~5ERQATIOI~T COAIl-IISSIOI~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 t SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-06B BP Exploration Alaska Inc. Permit No: 208-203 Surface Location: 2146' FNL, 504' FWL, SEC. 04, T11N, R14E, UM Bottomhole Location: 263' FNL, 4699' FWL, SEC. 05, T11N, R14E, UM Dear Mr. McMullen: 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 conditiora of this permit may result in 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 December, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~,~~ ALASI~IL AND GAS CONSERVATION COMMI~N ~~ `'~' ~,,~'~ PERMI~T~ OoDRILL ~~/a°~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU K-06B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11235' TVD 8926' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL028303, ADL028304 Pool FWL, SEC. 04, T11N, R14E, UM FNL, 504 2146 Top of Productive Horizon: UM 1566' FWL SEC. 04 T11N R14E 52' FNL 8. Land Use Permit: 13. Approximate Spud Date: January 10, 2009 , , , , , Total Depth: 263' FNL, 4699' FWL, SEC. 05, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-670778 y-5975058 Zone-ASP4 10. KB Elevation (Height above GL): 53.6 feet 15. Distance to Nearest well Within Pool: 280' 16. Deviated Wells: Kickoff Depth: 9050 feet Maximum Hole An le: 89 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3350 Surface: 2470 1 in Pro ram: a 'fi i n To - in e h -Bottom u i of m n .f. r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/ " ~-~r~s~~X2-~ra~~ # 4.7# L- TC-II/STL 2 41 12 89 1 I s ' 1 g, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 12330 7 None 12444 8696 12238' Casin Len th 'ze Cement Volume MD D Conductor /Structural 11 " x 1 1 ' Surface 673' 1 318" 7 P rm fr s ' n PF II 7 ' 7 ' Intermediate Pr in 14' -/" 7 1 F' 4' ' Liner 2' 7" 2 I s' 7 7T - 80 ' 759 ' - 73' r -1/ " 74 I '-12 2 '- ' Perforation Depth MD (ft): 9500' - 12230' Perforation Depth TVD (ft): 8818' - 8696' 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 foregoing is true and correct. Contact Ron Phillips, 564-5913 Printed Name John 'Mu Title En ineerin Team Leader Prepared By Name/Number: Si nature Phone 564-4711 Date ~ z l~ d~' Sondra Stewman, 564-4750 Commission Use Onl Permit To Dr' e o?O o?O~ API Number: 50-029-21038-02-00 Permit A proval See cover letter for r 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: ~J ~J l~®FS ~ i Q ~t~~-~. ~a t-- Samples Req'd: ^ Yes G~No Mud Log Req'd: ^ Yes ~No ~~ ~ ~S , ~~ ~~ ~v ~~~ tiV~G:+C-'~`~~HZS Measures: Yes ^ No Directional Survey Req'd: e(Yes ^ No Other: APPROVED BY THE COMMISSION 1 ~ Z'~ (~ Date COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate i To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ron Phillips CTD Engineer Date: December 17, 2008 Re: K-066 Application for Permit to Drill Request CTD Drill and Complete K-06B urosram: Snud in January 26.2009 Pre-Rig Work: 1. MIT-lA, -OA. 2. PPPOT-T; Function LDS. 3. Mill XN at 8619' to 3.80" with left handed motor and mill. 4. Run 4'h" monobore dummy whipstock drift to 9200'. 5. Set a CIBP at 9122'. 6. Set Baker 4-1/2" Monobore whipstock lowside 180 ROHS at 9071'. 7. PT MV, SV, WV. 8. Blind and bleed lines, remove well house, level pad. Rig Sidetrack Operations: 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. by ~®~S-~~~ 3. Mi113.80" window at 9071' . 4. Drill build/turn section with 4.25" bicenter bit, and land well. 5. Drill lateral section to 11235' MD w/ resistivity log. 6. Run 3-1/2"x 3-3/16"x 2-7/8" solid liner w/cementralizers to TD. 7. Cement liner from TD to TOL (8850'MD) with 15.8ppg cement. 8. Clean out liner/Mill SELRT. 9. Run MCNL/GR/CCL log. 10. Test liner lap to 2000 psi. 11. Perforate per geologist. 12. Set liner top packer (if fails liner lap test) 13. Freeze protect well to 2200' . 14. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU test separator, flow test well. Place liner top at 8850' MD. -~ ~ lip ~ ~ @ ~~~~- ~~ Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/4" Casing Program: • 3-3/16", 6.2#, L-80, TC-II connection solid liner - 8850'MD - 9500' MD. • 2-7/8", 4.7# , L-80, STL connection Solid liner - 9500'MD - 11235' MD. • A minimum of 33bbls 15.8 ppg cement will be used for liner cementing. (TOC 8850'MD) Existing casina/tubina Information 13-3/8", L-80 72#, Burst 5380, collapse 2670 psi 9 5/8", L-80 47#, Burst 6870, collapse 4760 psi 7", L-80 26#, Burst 7240, collapse 5410 psi 4-1/2", L-80 12.6#, Burst 8440, collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 89 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 6500ft (North). • Distance to nearest well within pool - 280 ft (K-03B). Logging. • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole MCNVGR/CCL log will be run. Hazards • The maximum recorded H2S level on K-Pad is 25 ppm. • Lost circulation risk is medium. • Additional bit trips planned because KOP in conglomerates. Reservoir Pressure The max res. press. is estimated to be 3350 psi at 8800'ss (7.3 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2470 psi. Ron Phillips CTD Drilling Engineer cc. Well File, Sondra Stewman, Terrie Hubble ~,ac ~ ~r TREE= a" CAM820N W~LhEAD= MCEVOY ACT1d4TOR = T OTIS KB. ELEV = _ 53.80' BF. f3E1/ = 28.67 K~ _ 3091' _ Max An le = 98 10415' ~tum MD = NA DaWm TVD = 8800' SS 13-3/8' CSG. 72#, L-80. ID =12.347" 26'j$• Minimum ID = 3.725" ~ 8619' 41/2" HES XN NlPPLE TOP OF 7" LNR 797$' PERFORATION SUMMARY R~ LOG: SACS ON 09!04/98 ANGLE AT TOP PERk 85 ®9500' Note: Refer to Roduction DB for historical pert data S¢E SPF INT92VAL OpNSgz QATE 2-7/8' 4 9500 -9930 O 09117!01 2-718' 4 10350 -10500 O 09l17~1 2-314" 4 10800 -10900 C 08106/98 2-3/4' 4 11050 - 11250 C 08!08/98 2-7l8' 4 11420 - 11580 C 09H7/01 2-3l4° 4 11790 - 11900 O 08/06/98 2-3/4' 4 12000. 12230 O 08/08/98 TOP OF CBuENT ~ 8540' 9-519" CSG, 47#, L-80, ID = 8.881" 8775' 4-1/2" TBG, 12.8#, L-80, .0152 bpf, lD = 3.958" 4-112' ST MD TVD DEV TYPE v~v ~n;n rvtti uATE 4 3245 3177 13 CAMCO CA-MhAG RK 3 5715 5489 24 CAMCO CA-MMG RK 2 7402 7004 24 CAMCO CA-MMG RK 1 8493 8022 20 CAMCO KBG-2•LS BTM IiGR MILLOIlT WNDOW 8147 - 8158' h83 X Np? ~ = 3.813" i X 4-1/2" BKR S-3 PKR D = 3.875" 4-i/2" f~ X NP, b = 3.813", Y' 4.112" f~S XN tVP, ~ = 3.725" 1833' 4-i/2" WLEt'a, ID = 3.958" 8635' ELMD TT LOGGED 07130/OS ZXP PKRRfGR PBTO .0152 bpi, ~ = 3.95 DATE REV BY COfS DATE BY COM4ENT3 1883 ORKi1NAL COAIPLETKN4 05J29f08 OOIDTM TF ( 19/04 08104/98 61l]ETRACKCdilPl.tlT10N 03/12107 FDWPA MLL 1 12238' 03I10ro2 RN?P WRRFS:1'gNS KB A ION 01H7/~ JRAlPAG C28PSET(O1I10/~) 01/17/08 JRA/PAG ELMD TT LOG CORRECTION PRIJDhlOE BAY UNf Wt3L: K•08A Pt~uYt' No: 1981360 API No: 50-029-21038-01 St3C 4, T11 N, R14~ 2148' t~IL &504' FV1~L d ExPlo-Mien (Alaska) K _0 ~a ~ : 70° ~ 936r m ~ ~ 96sa• \~J • TREE= 4"CAMERON WELLHEAD = __ A CTL44TOR= T MCEVOY OTIS _ KB. ELEV = 53.60' BF. ELEV = 26.62' KO_P_=__ 3091' Max Angle = __ 98 Q 10416' Datum MD = NA Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" i 2673' Minimum ID = 2.377" @ 9500' 3-3116" x 2-7/8" XO TOP OF 7" LNR ~ 7978' MILLOIR WgVDOW 8142' - 8158' 119-5/8" CSG, 47#, L-80, ID = 8.881" i 14-1/2" HES SSSV NIP, ID = 3.813" I t;a s I IFr MA Nna~l ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3245 3177 13 CAMCO DMY RK 3 5715 5489 24 CAMCO DMY RK 2 7402 7004 24 CAMCO DMY RK 1 8493 8022 20 CAMCO DMY BTM BG, 12.6#, L-80, .0152 bpf, ID = 3.958" TOP OF 4-1/2' LNR 7" LNR, 26#, L-80, .0383 bpf, D = 8.271 PERFORATION SUMMARY REF LOG: SACS ON 08!04!98 ANGLEAT TOP PERF: 85 Q 9500' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-7/8" 4 9500 - 9930 O 09!17!01 2-7/8" 4 10350 - 10500 O 09/17/01 2-314" 4 10800 - 10900 C 08/08198 2-314" 4 11050 - 11250 C 08106/98 2-7/8" 4 11420 - 11580 C 09/17/01 2-314" 4 11790 - 11900 O 08/06/98 2-314" 4 12000 - 12230 O 08/06/98 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 12330' $$9s' 1~4-1/2" HES X NIP, ID = 3.813" 8619' 4-1/2" HES XN NIP, ID:nI!ed to = 3.80" 8633' 4-112" WLEG, ID = 3.958" 19-518" X 7" BKR ZXP PKR & HMC HGR I 7" X 4.1/2" BKR ZXP PKR/HGR TSGR 8776 of Roposed 3-3/16" Liner Window off Mechanical W C18P 1' 3-3116" X 2.718" XO 3-317 6" x 2-7i8" L-80 Liner, Cernented & Ferf'd 11235' DATE REV BY COMMENI•S GATE REV BY COMMEMS 1983 ORIGINAL COMPLETION 05/29/06 CO/DTM TREE/PERF CORRECT (6/13!04) 08/04198 SIDETRACK COM PLETION 03/12/07 HDR/PAG MILL CIBP/PUSH TO 12238' 03/10/02 RNRP CORRECTIONS 12/04/08 MSE PROPOSED CTD SDETRACK 08/04/03 CMO/TLP KB ELEVATION CORRECTION 01/17/06 JRA/PAG CIBPSET(01/10106) 01/17/06 JRA/PAG ELMD TT LOG CORRECTION PRUDHOE BAY UNTr WELL: K-08B PERMIT No: API No: 50-029-21038-02 SEC 4, T11 N, R14E, 2148' FNL & 504' FWL BP Exploration (Alaska) K ~0 6 B SAFETY NOTES: 70° C~ 9367' 8 90° @ 9654' Proposed CTD Sidetrack O 280 L Q~ ~_ ~ 18-0fi B of bag BAG 7 1 /16" 5000 psi. of pipes cross of pipe/slips Blind/Shears ~`°~~.`~ •... TOTs 2 3/8" combi ram/slips M•~..~'~,.. 7 1/16" 5000psi Mud Cross I I Mud Cross 7 1 /16" 5o0apsi variable bore pipe 3 112"-2 318" '''w..,. '`•... TOTS 2 318" combi ram/slips M,,..~r~''`~ ~ 1/16" 500opsi Swab Va! Flow Tee bP ~ BP Alaska Baker Hughes INTEQ Planning Report _,~,Y ......,~ Company: BP AmoCO Date: 12/12/2008 Time: 14:01:09 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-06, True North Site: PB K Pad Vertical (TVD) Reference: K-06A: 53.6 We11: K-06 Section (VS) Reference: Well (O.OON,O.OOE,265.OOAzi) Wellpath: Plan 4, K-06B Survey Calculation Method: Minimum Curvature Db: Sybase Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB K Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973161.33 ft Latitude: 70 19 57.435 N From: Map Easting: 670342.10 ft Longitude: 148 37 5.245 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.30 deg Well: K-06 Slot Name: K-06 Well Position: +N/-S 1886.41 ft Northing: 5975058.00 ft Latitude: 70 20 15.988 N +E/-W 478.89 ft Easting : 670778.00 ft Longitude: 148 36 51.258 W Position Uncertainty: 0.00 ft Wellpath: Plan 4, K-06B Drilled From: K-06A 500292103802 Tie-on Depth: 9045.73 ft Current Datum: K-O6A: Height 53.60 ft Above System Datum: Mean Sea Level Magnetic Data: 12/5/2008 Declination: 22.97 deg Field Strength: 57691 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 27.83 0.00 0.00 265.00 Plan: Plan 4 Date Composed: 12/5/2008 change landing depth to 8796' TVDss Version: 16 Principal: Yes Tied-to: From: Definitive Path Targets Name K-06B Polygon -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 K-066 Fault 1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 K-068 Fault 2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 K-06B Fault 3 -Polygon 1 -Polygon 2 K-06B Target 1 K-066 Target 2 K-06B Target 3 Description TVD Dip. Dir. ft .......53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 53.60 8849.60 8883.60 8926.60 Map Map +N/-S +E/-W Northing Easting ft ft ft ft __ 1933.76 -1191.35 5976964.00 669543.00 1933.76 -1191.35 5976964.00 669543.00 1955.08 -414.61 5977003.00 670319.00 2161.74 876.52 5977239.00 671605.00 1981.57 925.43 5977060.00 671658.00 1759.59 -1186.32 5976790.00 669552.00 2011.44 -561.38 5977056.00 670171.00 2011.44 -561.38 5977056.00 670171.00 2110.53 51.08 5977169.00 670781.00 2207.27 590.46 5977278.00 671318.00 2110.53 51.08 5977169.00 670781.00 1628.62 -1189.30 5976659.00 669552.00 1628.62 -1189.30 5976659.00 669552.00 1620.90 -104.12 5976676.00 670637.00 1497.66 914.40 5976576.00 671658.00 1620.90 -104.12 5976676.00 670637.00 1864.83 -1414.99 5976890.00 669321.00 1864.83 -1414.99 5976890.00 669321.00 2184.03 -1067.61 5977217.00 669661.00 2026.35 716.38 5977100.00 671448.00 1917.37 -208.40 5976970.00 670526.00 1884.47 -1091.44 5976917.00 669644.00 <---- Latitude ----> <--- Longitude ---> Deg Min Sec Deg Min Sec 70 20 35.005 N 148 37 26.062 W 70 20 35.005 N 148 37 26.062 W 70 20 35.216 N 148 37 3.371 W 70 20 37.248 N 148 36 25.650 W 70 20 35.476 N 148 36 24.222 W 70 20 33.292 N 148 37 25.915 W 70 20 35.770 N 148 37 7.658 W 70 20 35.770 N 148 37 7.658 W 70 20 36.745 N 148 36 49.766 W 70 20 37.696 N 148 36 34.008 W '. 70 20 36.745 N 148 36 49.766 W 70 20 32.004 N 148 37 26.001 W 70 20 32.004 N 148 37 26.001 W 70 20 31.929 N 148 36 54.300 W j 70 20 30.717 N 148 36 24.546 W 70 20 31.929 N 148 36 54.300 W 70 20 34.327 N 148 37 32.596 W 70 20 34.327 N 148 37 32.596 W 70 20 37.467 N 148 37 22.449 W 70 20 35.916 N 148 36 30.329 W 70 20 34.845 N 148 36 57.346 W 70 20 34.521 N 148 37 23.143 W b ~ BP Alaska P Baker Hughes INTEQ Planning Report INTEQ C Company: BP Amoco Date: 12/12/2008 Time: 14:01:09 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: W ell: K-06, True North Site: PB K Pad Vertical (TVD) Reference: K- 06A: 53.6 Well: K-06 Section (VS) Refereuce: W ell (O.OON,O.OOE,265.OOAzi) Wellpath: Plan 4, K-06B Survey Calculation Method: Mi nimum Curvature Db: Sybase ___ Targets - --- - _ -- Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +FJ-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft Annotation 14iD TVD ft ft 9045.73 8587.28 TIP 9050.00 8591.02 KOP 9070.00 8608.67 End of 9 Deg/100' DLS 9110.00 8646.22 4 9130.15 8665.98 End of 37 Deg/100' DLS ~ 9149.84 8685.33 6 ', 9170.15 8705.14 7 9208.96 8741.22 8 9237.16 8765.70 9 9274.36 8795.87 10 ~; 9403.31 8849.71 End of 38 Deg/100' DLS j 9503.00 8851.43 12 9678.00 8855.46 13 9903.00 8863.44 14 ~ 10138.00 8873.72 15 j 10328.00 8882.61 16 10478.00 8890.08 17 10678.00 8899.95 18 10828.00 8907.21 19 11003.00 8915.70 20 11235.00 0.00 TD Plan Section Information MD ___ Incl Aziro TVD +N/-S - +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9045.73 28.47 66.80 8587.28 2014.12 850.99 0.00 0.00 0.00 0.00 9050.00 28.95 66.90 8591.02 2014.92 852.87 11.30 11.24 2.34 5.76 9070.00 27.15 66.90 8608.67 2018.61 861.53 9.00 -9.00 0.00 180.00 9110.00 12.35 66.90 8646.22 2023.90 873.92 37.00 -37.00 0.00 180.00 9130.15 11.00 30.00 8665.98 2026.42 876.87 37.00 -6.70 -183.14 242.01 ~ 9149.84 11.00 350.00 8685.33 2029.90 877.48 38.00 0.00 -203.11 250.34 9170.15 15.00 320.00 8705.14 2033.82 875.46 38.00 19.70 -147.76 285.43 9208.96 28.00 300.00 8741.22 2042.27 864.27 38.00 33.49 -51.52 320.90 9237.16 32.00 280.00 8765.70 2046.90 851.15 38.00 14.18 -70.92 282.91 9274.36 40.00 260.00 8795.87 2046.53 829.56 38.00 21.51 -53.77 295.80 9403.31 89.00 260.00 8849.71 2026.93 718.40 38.00 38.00 0.00 0.00 9503.00 89.02 271.96 8851.43 2019.96 619.15 12.00 0.02 12.00 90.00 ~ 9678.00 88.37 250.97 8855.46 1994.15 447.10 12.00 -0.37 -12.00 268.00 9903.00 87.64 277.98 8863.44 1972.68 225.36 12.00 -0.32 12.00 92.00 10138.00 87.45 249.75 8873.72 1947.84 -5.72 12.00 -0.08 -12.01 269.00 10328.00 87.26 272.57 8882.61 1918.87 -192.02 12.00 -0.10 12.01 91.00 10478.00 87.08 254.55 8890.08 1902.14 -340.28 12.00 -0.12 -12.01 269.00 10678.00 87.34 278.58 8899.95 1890.27 -538.22 12.00 0.13 12.01 90.00 10828.00 87.16 260.56 8907.21 1889.15 -687.42 12.00 -0.12 -12.01 269.00 11003.00 87.35 281.58 8915.70 1892.41 -861.21 12.00 0.11 12.01 90.00 , 11235.00 87.65 253.72 8926.02 1883.00 -1090.50 12.00 0.13 -12.01 270.00 bP ~ BP Alaska ~ ~'`~ Baker Hughes INTEQ Planning Report INTEQ T ~ _~ __ - __:_ _ Company: BP Amoco Date: 12/12/2008 Time: 14:01:09 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-06, True North Site: PB K Pad Vertical (TVD) Reference: K-06A: 53.6 Well: K-06 Section (VS) Reference: Well (O.OON,O.OOE,265.OOAzi) Wellpath: Plan 4, K-O66 Survey Calculation Method: Minimum Curvature Db: Sybase Survey _ ___ 1 P P MD Incl Azim SS TVD N/S E/W Ma N Ma E DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9045.73 28.47 66.80 8533.68 2014.12 850.99 5977090.84 671582.84 0.00 -1023.29 0.00 MWDi; 9050.00 28.95 66.90 8537.42 2014.92 852.87 5977091.69 671584.71 11.30 -1025.24 5.76 MWD I 9070.00 27.15 66.90 8555.07 2018.61 861.53 5977095.57 671593.27 9.00 -1034.18 180.00 MWDj 9075.00 25.30 66.90 8559.56 2019.48 863.56 5977096.49 671595.28 37.00 -1036.28 180.00 MWD; 9100.00 16.05 66.90 8582.92 2022.94 871.67 5977100.13 671603.31 37.00 -1044.66 180.00 MWDj 9110.00 12.35 66.90 8592.62 2023.90 873.92 5977101.14 671605.55 37.00 -1046.99 180.00 MWDi ~I 9125.00 10.89 40.03 8607.32 2025.62 876.31 5977102.91 671607.90 37.00 -1049.52 242.01 MWDi 9130.15 11.00 30.00 8612.38 2026.42 876.87 5977103.72 671608.44 37.00 -1050.15 268.35 MWDj 9150.00 11.00 350.00 8631.89 2029.93 877.48 5977107.25 671608.96 37.70 -1051.06 250.34 MWDj 9170.15 15.00 320.00 8651.54 2033.82 875.46 5977111.10 671606.85 38.30 -1049.38 285.43 MWD i I II 9175.00 16.47 315.89 8656.21 2034.80 874.57 5977112.05 671605.95 38.00 -1048.59 320.90 MWDI 9200.00 24.83 302.82 8679.59 2040.20 867.68 5977117.30 671598.93 38.00 -1042.19 324.86 MWD; 9208.96 28.00 300.00 8687.62 2042.27 864.27 5977119.29 671595.48 38.00 -1038.98 337.13 MWD', 9225.00 29.91 288.02 8701.66 2045.40 857.21 5977122.25 671588.34 38.00 -1032.21 282.91 MWDj 9237.16 32.00 280.00 8712.10 2046.90 851.15 5977123.61 671582.25 38.00 -1026.30 293.40 MWDi 9250.00 34.37 272.21 8722.85 2047.63 844.17 5977124.18 671575.26 38.00 -1019.42 295.80 MWD 9275.00 40.24 260.00 8742.76 2046.46 829.15 5977122.67 671560.27 37.69 -1004.36 303.44 MWDi 9300.00 49.74 260.00 8760.42 2043.39 811.76 5977119.21 671542.96 38.00 -986.77 0.00 MWD 9325.00 59.24 260.00 8774.92 2039.86 791.74 5977115.23 671523.03 38.00 -966.52 0.00 MWD 9350.00 68.74 260.00 8785.87 2035.96 769.64 5977110.83 671501.02 38.00 -944.16 360.00 MWD 9375.00 78.24 260.00 8792.97 2031.81 746.06 5977106.13 671477.55 38.00 -920.31 0.00 MWD 9400.00 87.74 260.00 8796.01 2027.50 721.65 5977101.28 671453.25 38.00 -895.62 360.00 MWD 9403.31 89.00 260.00 8796.11 2026.93 718.40 5977100.63 671450.01 38.00 -892.33 0.00 MWD 9425.00 89.00 262.60 8796.49 2023.65 696.96 5977096.86 671428.65 12.00 -870.68 90.00 MWD 9450.00 89.00 265.60 8796.92 2021.08 672.10 5977093.73 671403.85 12.00 -845.69 89.95 MWD ~ 9475.00 89.01 268.60 8797.35 2019.82 647.14 5977091.90 671378.93 12.00 -820.71 89.90 MWD 9500.00 89.02 271.60 8797.78 2019.86 622.15 5977091.37 671353.94 12.00 -795.82 89.85 MWD j 9503.00 89.02 271.96 8797.83 2019.96 619.15 5977091.40 671350.95 12.00 -792.85 89.80 MWD 9525.00 88.93 269.33 8798.23 2020.21 597.15 5977091.15 671328.95 12.00 -770.95 268.00 MWD 9550.00 88.83 266.33 8798.72 2019.26 572.18 5977089.63 671304.01 12.00 -745.99 268.05 MWD 9575.00 88.73 263.33 8799.25 2017.00 547.29 5977086.81 671279.18 12.00 -721.00 268.11 MWD ~ 9600.00 88.64 260.33 8799.82 2013.45 522.55 5977082.70 671254.53 12.00 -696.05 268.17 MW D ii 9625.00 88.55 257.33 8800.44 2008.61 498.04 5977077.30 671230,13 12.00 -671.20 268.24 MW D 9650.00 88.46 254.33 8801.09 2002.49 473.81 5977070.63 671206.05 12.00 -646.53 268.31 MWD 9675.00 88.38 251.33 8801.78 1995.12 449.93 5977062.71 671182.35 12.00 -622.11 268.39 MWD 9678.00 88.37 250.97 8801.86 1994.15 447.10 5977061.68 671179.54 12.00 -619.20 268.47 MWD 9700.00 88.28 253.61 8802.51 1987.46 426.15 5977054.51 671158.75 12.00 -597.75 92.00 MWD 9725.00 88.18 256.61 8803.28 1981.04 402.00 5977047.55 671134.76 12.00 -573.13 91.92 MWD 9750.00 88.09 259.61 8804.09 1975.89 377.56 5977041.84 671110.44 12.00 -548.33 91.83 MWD 9775.00 88.00 262.61 8804.95 1972.03 352.87 5977037.42 671085.85 12.00 -523.40 91.73 MWD; i 9800.00 87.92 265.61 8805.84 1969.46 328.02 5977034.29 671061.07 12.00 -498.43 91.63 MWD j 9825.00 87.84 268.61 8806.76 1968.20 303.08 5977032.46 671036.15 12.00 -473.46 91.52 MWD j 9850.00 87.77 271.61 8807.72 1968.25 278.10 5977031.94 671011.18 12.00 -448.58 91.41 MWD i 9875.00 87.70 274.61 8808.71 1969.61 253.16 5977032.73 670986.22 12.00 -423.86 91.30 MWD'; 9900.00 87.65 277.62 8809.72 1972.27 228.32 5977034.83 670961.33 12.00 -399.35 91.18 MWD; 9903.00 87.64 277.98 8809.84 1972.68 225.36 5977035.17 670958.36 12.00 -396.43 91.06 MWD; ': 9925.00 87.60 275.33 8810.76 1975.22 203.52 5977037.21 670936.47 12.00 -374.90 269.00 MWD', ~I 9950.00 87.55 272.33 8811.82 1976.89 178.60 5977038.32 670911.52 12.00 -350.22 269.11 MWD 9975.00 87.52 269.33 8812.89 1977.26 153.63 5977038.11 670886.55 12.00 -325.38 269.24 MWD 10000.00 87.49 266.33 8813.98 1976.31 128.68 5977036.59 670861.63 12.00 -300.43 269.37 MWD 10025.00 87.46 263.32 8815.08 1974.06 103.81 5977033.78 670836.81 12.00 -275.46 269.50 MWD 10050.00 87.45 260.32 8816.19 1970.50 79.09 5977029.66 670812.19 12.00 -250.53 269.63 MWD 10075.00 87.44 257.32 8817.31 1965.66 54.59 5977024.26 670787.81 12.00 -225.70 269.76 MWD by ~ BP Alaska Baker Hughes INTEQ Planning Report INTEQ Company: BP AmoCO Date: 12/12/2008 Time: 14:01:09 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-06, True North Site: PB K Pad Vertical (TVD) Reference: K-06A: 53.6 Well: K-06 Section (VS) Reference: Well (O.OON,O.OOE,265.OOAzi) Wellpath: Plan 4, K-06B Survey Calculation Method: Minimum Curvature Dh: Sybase Survey _ _ ___ T_ _ MD _ Incl _ __ Azim -_ _ _ SS TVD - - - N/S _ _ FJW _ - _ MapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg 10100.00 87.44 254.31 8818.43 1959.54 30.38 5977017.59 670763.74 12.00 -201.05 269.90 MWD 10125.00 87.44 251.31 8819.54 1952.16 6.52 5977009.67 670740.06 12.00 -176.64 270.03 MWD 10138.00 87.45 249.75 8820.12 1947.84 -5.72 5977005.07 670727.92 12.00 -1.64.07 270.17 MWD 10150.00 87.42 251.19 8820.66 1943.83 -17.02 5977000.81 670716.72 12.00 -152.46 91.00 MWD 10175.00 87.38 254.19 8821.79 1936.40 -40.86 5976992.84 670693.05 12.00 -128.06 90.94 MWD 10200.00 87.34 257.20 8822.95 1930.23 -65.06 5976986.12 670669.00 12.00 -103.42 90.80 MWD 10225.00 87.31 260.20 8824.11 1925.34 -89.54 5976980.67 670644.64 12.00 -78.60 90.66 MWD 10250.00 87.29 263.20 8825.29 1921.73 -114.25 5976976.50 670620.02 12.00 -53.67 90.52 MWD 10275.00 87.27 266.21 8826.48 1919.43 -139.11 5976973.63 670595.22 12.00 -28.70 90.38 MWD 10300.00 87.26 269.21 8827.67 1918.43 -164.06 5976972.07 670570.30 12.00 -3.76 90.24 MWD 10325.00 87.26 272.21 8828.87 1918.74 -189.03 5976971.81 670545.33 12.00 21.08 90.09 MWD 10328.00 87.26 272.57 8829.01 1918.87 -192.02 5976971.87 670542.34 12.00 24.05 89.95 MWD 10350.00 87.22 269.93 8830.07 1919.35 -213.99 5976971.85 670520.37 12.00 45.89 269.00 MWD 10375.00 87.17 266.93 8831.30 1918.66 -238.95 5976970.59 670495.43 12.00 70.82 269.13 MWD 10400.00 87.14 263.92 8832.54 1916.67 -263.84 5976968.04 670470.60 12.00 95.78 269.27 MWD 10425.00 87.11 260.92 8833.79 1913.38 -288.58 5976964.18 670445.94 12.00 120.72 269.42 MWD 10450.00 87.10 257.92 8835.05 1908.79 -313.12 5976959.04 670421.51 12.00 145.57 269.57 MWD 10475.00 87.09 254.91 8836.32 1902.93 -337.39 5976952.63 670397.38 12.00 170.26 269.73 MWD 10478.00 87.08 254.55 8836.48 1902.14 -340.28 5976951.77 670394.51 12.00 173.20 269.88 MWD 10500.00 87.09 257.20 8837.59 1896.78 -361.59 5976945.93 670373.33 12.00 194.90 90.00 MWD 10525.00 87.10 260.20 8838.86 1891.89 -386.07 5976940.48 670348.97 12.00 219.71 89.87 MWQ 10550.00 87.12 263.20 8840.12 1888.28 -410.77 5976936.31 670324.36 12.00 244.63 89.71 MWD 10575.00 87.14 266.21 8841.37 1885.98 -435.63 5976933.45 670299.56 12.00 269.60 89.56 MWD 10600.00 87.18 269.21 8842.61 1884.98 -460.58 5976931.88 670274.64 12.00 294.54 89.41 MWD 10625.00 87.22 272.21 8843.83 1885.29 -485.54 5976931.62 670249.68 12.00 319.38 89.26 MWD 10650.00 87.27 275.22 8845.03 1886.91 -510.46 5976932.67 670224.74 12.00 344.06 89.12 MWD 10675.00 87.33 278.22 8846.21 1889.83 -535.26 5976935.03 670199.88 12.00 368.51 88.97 MWD 10678.00 87.34 278.58 8846.35 1890.27 -538.22 5976935.40 670196.91 12.00 371.42 88.83 MWD 10700.00 87.29 275.94 8847.38 1893.05 -560.02 5976937.68 670175.05 12.00 392.90 269.00 MW D 10725.00 87.25 272.93 8848.57 1894.98 -584.91 5976939.04 670150.12 12.00 417.53 269.12 MW D 10750.00 87.22 269.93 8849.78 1895.60 -609.87 5976939.10 670125.16 12.00 442.34 269.27 MW D 10775.00 87.19 266.93 8851.00 1894.92 -634.83 5976937.84 670100.22 12.00 467.26 269.41 MW D 10800.00 87.17 263.92 8852.23 1892.93 -659.72 5976935.29 670075.39 12.00 492.23 269.56 MWD 10825.00 87.16 260.92 8853.47 1889.64 -684.47 5976931.43 670050.72 12.00 517.17 269.71 MWD 10828.00 87.16 260.56 8853.61 1889.15 -687.42 5976930.88 670047.78 12.00 520.15 269.85 MWD 10850.00 87.16 263.20 8854.70 1886.05 -709.17 5976927.29 670026.10 12.00 542.10 90.00 MWD 10875.00 87.17 266.21 8855.94 1883.75 -734.03 5976924.42 670001.30 12.00 567.06 89.87 MW D 10900.00 87.19 269.21 8857.17 1882.75 -758.98 5976922.85 669976.39 12.00 592.00 89.72 MWD 10925.00 87.22 272.21 8858.39 1883.06 -783.95 5976922.59 669951.42 1.2.00 616.84 89.57 MWD 10950.00 87.25 275.22 8859.60 1884.68 -808.86 5976923.64 669926.48 12.00 641.52 89.43 MWD 10975.00 87.29 278.22 8860.79 1887.60 -833.66 5976926.00 669901.62 12.00 665.97 89.28 MWD 11000.00 87.34 281.22 8861.96 1891.82 -858.27 5976929.65 669876.93 12.00 690.12 89.14 MWD 11003.00 87.35 281.58 8862.10 1892.41 -861.21 5976930.18 669873.98 12.00 692.99 89.00 MWD 11025.00 87.35 278.94 8863.11 1896.33 -882.83 5976933.60 669852.27 12.00 714.20 270.00 MWD 11050.00 87.36 275.94 8864.27 1899.56 -907.59 5976936.27 669827.44 12.00 738.58 270.12 MWD 11075.00 87.38 272.93 8865.42 1901.49 -932.49 5976937.63 669802.51 12.00 763.21 270.26 MWD 11100.00 87.40 269.93 8866.56 1902.11 -957.45 5976937.69 669777.54 12.00 788.03 270.40 MWD 11125.00 87.43 266.93 8867.68 1901.43 -982.41 5976936.44 669752.60 12.00 812.95 270.54 MWD 11150.00 87.47 263.93 8868.79 1899.44 -1007.31 5976933.88 669727.76 12.00 837.93 270.67 MWD 11175.00 87.52 260.92 8869.89 1896.15 -1032.06 5976930.02 669703.09 12.00 862.87 270.80 MWD 11200.00 87.57 257.92 8870.96 1891.56 -1056.61 5976924.88 669678.66 12.00 887.73 270.94 MWD 11225.00 87.63 254.92 8872.01 1885.70 -1080.89 5976918.47 669654.52 12.00 912.43 271.06 MWD BP Alaska by Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco ~ Date: 12/12/2008 Time: 14:01:09 Page: 5 ~ , Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL K-06, True North Site: PB K Pad Vertical (TVD) Reference: K-06A: 53.6 ~ WeIL• K-06 Section (VS) Reference: Well (O.OON,O.OOE,265.OOAzi) Wetlpath: Plan 4, K-066 Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD Incl Azim SS TVII) N/5 E/W MapN MapE DLS VS TFO Tool ft deg deg ft_ ft ft ft ft deg/100ft ft deg i 11235.00 87.65 253.72 8872.42 1883.00 -1090.50 5976915.55 669644.97 12.00 922.24 271.19 2.875 BP Alaska LEGEND ~y~l1.t K-0B,K-e~, K a61K O6A) e, +zm c' ~.° ~:,~°m~ a....v. BAKi/~R IW IIE PIan4 ~ ~ M n« Na~= wss aruvat'x ae.asu V ~ g ~ °men in+am n ,o .,.oa~M ~ ° 8~ wozax,axaox .......++~.,.: TN On aD. Bawa.tx NTEQ M ,0 ~ ,9o; F ma~~ ~~~ 1 ~01.,3~,e~~n+ee <e~, a,enae Ria: aN. lNtam: K-0W a].ept zas.oo• o 0o xzax mo i'.. I ~ REFERENCE NFORMAT ON rtl n alell NlEO' RRe erence W G MeaK Sea Lw NwN Laa 1V Ven elerenfe ~ ' 1 r } . r - ~ t - t - ~ ~ 1 - " ~ ~ ~ 1.' 1"- rT r r I- , ~ r" ~ f - L - ~ t '~ T - ~ _ r i ~ {T - { { _ - I , j 1 ' Sea on (V51 Relerence- 10 GON e00E) Meaeerea DePln ftelerence O6 5. ca cu at°n MUm.°a Mnmu Lune+ue 3fi00 _ ~. r ~'~- _ t._ ~ I ~li -tF-- - r 1 Y-- 1 , f. I ~- ,.... ~ ` ! L { 1 1. f if 'i'1 1 + + 1'~ -r ~~ ... L: ~ ._ 1 _ l }~ ~ - 1 1 I i ~ ~F' , I t I , ~ ~ F- - tt~ I '_ -~ t '-, ~F- 1 1 ~ ~ 1 1 1-E" - I 1 I. } ~ ~. _f 1 r. ~. -' r as r .. _ ,.. ~.w~ ... .. +..+ xwP - , '. .. ~ t _ - - _ +, r . } ' Y_ .: { _ t ~} ~}:}Y ~ I i r .. _ _{ ~ ^ -• ~ 1 tF" ~i u w... .... ax. n."'.:.~".. 'w~ "~~ ni aw T.,. Od' aan nr za., w..u mo FF 7 Ott} I.~_+ ~ I - ~ ~. .. . , am .u a.r rn.n r« m.a ar aa+. ~e _t - I ~..,.., a.a,. ,..~ ,~ JZ ~ ~ P.[a'r ~ii'i'j'i ~wHi ~ ) a~ ~ ... .. I I '~tom ~] -r ` - t ry~j ~ .'1'-~-~ ~ ~-}~~ ~ End of 38 Deg/100' DLS K-O6 K-06A n ~ au ww. « i .OZ..n ~ ~' JZ I L iw u r ~ / 6 , © _ ..° :o •,~~,.,. ~a a .N~o~ ow;`s ° K-O6B Fault 1 t0 + ~ End of 37 De 100' DL - 12 _ , n r.~.m wa C = K-O6B Tar et 3 1 S _. + 16 79 -- 14 _ 4 - _ _ ^ Entl of 9 De 100' DLS r Huse , e een oo iewn ,oet w Fam 20 ____ 17 18 ~ KOP + 1 . a aa.r d. a p ~ ~ Plan 4 K-O6B 1S K O6B T t 2 ' _ 1 TIP + ' ~ , - a e . _ .- ~ K-O6B Tar et 1 _. .. ~ f w zoo i ___ .. ~+ KAB K-O6A ~ .. K-O6B Fault 2 ' .... .... Tr , 1 ~~ Y 1 t ~ ... I .. 1 Pi.. I + _ Mso . C }+ _ . ~ ~ , t'' i + I ~ r 7 t . .. 1 _ I TIP asap ~ ,-r ... I ~ ~.•~.. I t I ;- ! , I ._1 .-_ I ~ ~ -.. ... + {. .,.~ t I +~ ~... ~ }r+t rt~ ~-1 I I ~ t i- I ... .. 1 ~ I i ' ~ 1 _:. I~- I I ~~ I 100'DL - T I _t- y es i End of 9 De ~ I -t~Ji. - r ~ ~ 1 - Tt T+ ' ~ , ... .. I ... -,soo „aa ,aoo soo aoo goo I . am .soo .aaa .am .zao .,oo o ~ ,O _,-. ., o zao wa aao sao so ~ I . ~I i _- o ioo wo aoo ,aaa „oo ,zao ,wo ,aaP isP~. ~ ^ _ End of 37 De /100' IbL Weat(-)/Feat,+) [100KOnJ + ~i ; B t ? ~ ~ • _ I ~r l. g1 ~ .,-. +., T... ., _... ,_. ... ,-__ _:. .. _ _., ,:. ~ _ ~ ~ : - . ~ ti-~~~ y $(I ~ + s 8 ~ 0 :_. szw , K-06B Ta et 1 I , . . { t _ _ ~a -.'Z .._._,.-.{_13 / 15 14 ~ , ~ _ t ~ m > ~ ..__-_i_ 17 -...._.____._.-.__1' ._ 1 1B Plan 4 K-068 19 eeso- . + E d 138 De 10 0' DL I 8/ ~ \ L ~ _ * _. ..x___ 1 . , 20 1 F + -.: I ~ , •.I ; I 1 i_ ~ ' _ ___ i K-06B Target 2 i i ___... -.__. __... K-06 K-06 .. ~ I T i i i .- ~ '~ L ~_. .T j + 4 - ~ { ~T ~ ~+~ ~ J . i i L-r t --~1~ } ~- .. t r -1 r -t~ ~ ~ F •- 1 t T-T ~ K-O6B Tar et a t- rl t 1 - t r I_ I _I y : '+:: ~ ~Ll - - t ?I ~ t ~~ - - T i~-r7 :~ } ~~ r - I :, ~~ ~ P I ! ' - 1~ ~~ 1-1Y:~ I;T: T I f ;~ ~:.::~ ~_~. hli+ tj+ ~!~.:ti }~# :.::~ F . . { .. 1+ T 1 _ ~J :1 I + . l t...-. ~+ r ~ it~ _ ~ 1 ,. + { ~ _ -f -r r -I ~ t - 1 I rt rt-'-i-~ ~ t t r r i rf tY t I ...r I . ~ r Ir I -t_. t ~ i- ~ 11' -r ' F 1 I f + 'r i~ ' H l! I 11 11 Y ' I r 1 ~ ~ t ~ r ~i~y $ ~ ~- - N - - t! t- _ _ j. .; _ 1 i + ,_ t I-_- r ~: r 1 f 1 t Ir ~ TT` T ~ ,.., .' C .:. r - f f i I r. 1 _ ~~ 1 r t _ i~ ! r 91 ~ _ _ _., 1 I_ : I ' i 1 ; , .. , , , . . _ : - ;~;~~-. - , - .. . • : ,Ow ,ooo oso soo sso aoo zso ,a _ew sao . , .... 4 . _:~ ~-~r,T sso .soo ww w j~,rt. r . _-. oo .oso 00o zsa .aa ~ , , ', , ' 1- .,-r}-„T-~r_, T --r . , ~~ ~~ zoo . zw ; , -, ,-rh ^ ~-t-~-r; rr'-; wo aso .ao aso soo ;T y , . , , i , , ~ ,. , sso eoa eso zoo zso coo eso oaa ow Vertical Section at 263.00' [SOfNnJ BP Alaska MIFIV~TM OET~rl6 aP010]Y2~10]1~0a v.o.enee o"rE-i :~'a"r r'A'"m"rero .nor zoo.ao• o.oo o.oo zT.ea REFERENCE INFORMATION Co-ortlinate (N/E) Reference: Well Centre: K-O6, True NoM Vertical (TMD Reference: K-O6A 53.68 Section (VS Reference: Slot - (B.BON,B.OOE) Measured Depth Reference: K-B6A: 53.60 Calculation Method: Minimum Curvature p rM rr •eL.w.ae„a.. or.. ~. nro.r LEGEND - E-09 (E-09) - E-09 (E-09A) - E-09 (E-09APB1) - E-09 (E-09B) - K-03 (K-038) - K-04 (K-04A) -~ K-04 (K-04AP81) - K-04 (K-04APB2) - K-O6 (K-O6) - K-O6 (K-O6A) -- K-07 (K-07) - K-07 (K-07A) K-07 (K-07AP81) - K-07 (K-07AP82) - K-07 (K-07B) - K-07 (K-07C) K-07 (K-07D) K-10 K-10) K-10 ~K-10A) K-10 (K-10AP81) K-10 (K-10AP82) - K-10 (K-10AP83) K-10 (K-10B) K-13 (Plan K-13A) --- Plan 4, K-06B Plan 4 T Plam Plan 4 (K-06lPlan 4, K-O6B) M Aximulns to True N0d11 Created By: BP Dale: 12/12/2888 Magnark N0M'. ]2.9)° Checketl: Dale: by Mgg; n ,~ F~a sDip Aegle~809G° Gpniael lnlwn,allen. MoDeae1'.~9mrZ~ aiu MiU~anlwn Dell. I9U>I lat.]5>e E nail. DillnilcDaeLSOn[~dln~erlcom C~ • W ELLPATH UE"I AILS Plen 4. K41fid SW?9?1038U2 Pmcm Wullpeih: K-0bA fie w MU: 9045.]3 Rig: NuMie ~ Rcl: Uawm: K-06A: 53 60ft V.Sltivw Odgiv Origin Suuting WELL DETAILS ANTI-(:ULLISION' SETTM45 COMPANY UHI'AILS SURVEY YRO(:RAM Name *N/-S +E/-W Nunhing f ling La0tude Longitude Slut Inleryola0on MethuJMD Interval: SU.11U dP Amuco U.y0r l°m Uc3rih l'o SurveylPlan TWI Depth Range Fram: 9045.]3 Tu: 11'_35181 K-W 188641 4]B.tl9 59]SdSKW 6]U]]tl.W ]U°3tl 15.9tltlN 148"3b'S1158W NIA ManimwtRwge: Illd]3 Reference: Plan: Plano Cvlculauw MUd~wl: Miuimwn Curvature 9045.]3 1133500 PWmeJ. PIm~9 VI6 MWU Lrtor System: ISC W SA Scan McihM: "I'rav Cylinder NuM Lrtor Surfuce. Elliptical-Caring Waning McISrW: RWn daseJ ~~ by ~ BP Alaska ~~ Anticollision Report . ~~~ BAKER NYGMES 1NTEQ Company: BP Amoco Date: 12/12/2008 Time: 15:04:04 Page: 1 Field: Prudhoe Bay Reference Site: PB K Pad Co-ordinate(NE) Reference: Well: K-O6, True North Reference Well: K-06 Vertical (T VD) Refere nce: K-06A: 53.6 Reference Welipath: Plan 4, K-O66 Db: Oracle LOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'Rseeils in thisBehCi pal Plan $ PLANNED PROGRAM Interpolation Method : MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9045.73 to 11235.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1 320.72 ft Error Surface: Ellipse + Casing _ r Survey Program for Definitive Welipath -- ~ Date: 12/5/2008 Validated: No Version: 0 ~ Planned From To Survey Toolcode Tool Name ~ ft ft 88.91 8138.91 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multi shot 8140.23 9045.73 K-06A (8140.23- 12328.23) (1) MWD MWD -Standard 9045.73 11235.00 Planned: Plan 4 V16 MWD MWD -Standard Casing Points MD TVD Diameter HoleSize Name ft ft in in ( 11235.00 8926.02 2.875 4.125 2_875" _ ___ _ Summary - -~ <---------- Offset Welipath ---- ._ --------> Reference Offset Ctr-Ctr No-Go - Allowable Site Well Welipath. MD MD Distance Area Deviation Warning ft ft ft ft ft PB E Pad E-09 E-09 V3 Out of range ': PB E Pad E-09 E-09A V1 10485.37 11975.00 320.43 921.02 -600.60 FAIL: Major Risk PB E Pad E-09 E-09APB1 V1 10917.50 11410.59 503.77 949.47 -445.70 FAIL: Major Risk PB E Pad E-09 E-09B V5 10957.58 11275.00 856.22 947.74 -91.52 FAIL: Major Risk PB K Pad K-03 K-03B V2 9380.70 11586.18 270.92 466.60 -195.68 FAIL: Major Risk i PB K Pad K-04 K-04A V1 9755.80 9825.00 794.29 164.01 630.28 Pass: Major Risk PB K Pad K-04 K-04APB1 V1 9425.00 9610.61 905.35 155.81 749.54 Pass: Major Risk PB K Pad K-04 K-04AP62 V1 9132.46 9485.61 1016.53 178.18 838.35 Pass: Major Risk PB K Pad K-06 K-06 V4 9424.13 9300.00 213.70 270.68 -56.99 FAIL: Major Risk ii PB K Pad K-06 K-06A V1 9050.00 9050.00 0.00 409.71 -409.71 FAIL: Major Risk ~~ PB K Pad K-07 K-07 V5 Out of range ~ PB K Pad K-07 K-07A V3 Out of range i PB K Pad K-07 K-07APB1 V3 Out of range PB K Pad K-07 K-07AP62 V5 Out of range j PB K Pad K-07 K-076 V3 Out of range PB K Pad K-07 K-07C V8 10122.80 10625.00 557.79 379.20 178.59 Pass: Major Risk PB K Pad K-07 K-07D V3 9092.28 9350.00 688.38 200.64 487.75 Pass: Major Risk PB K Pad K-10 K-10 V1 Out of range PB K Pad K-10 K-10A V7 Out of range PB K Pad K-10 K-10APB1 V1 Out of range PB K Pad K-10 K-10AP62 V1 Out of range PB K Pad K-10 K-10APB3 V2 Out of range PB K Pad K-10 K-10B V3 Out of range PB K Pad K-13 Plan K-13A V1 Pla n: K- 9055.87 10000.00 1272.86 122.52 1150.34 Pass: Major Risk Site: PB E Pad Well: E-09 Rule Assigned: Major Risk Welipath: E-09A V1 Inter-Site Error: - 0.00 ft Reference Offset Semi-Major Axis T Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10980.45 8914.64 11250.00 8883.17 30.55 272.57 191.91 273.04 5.000 594.91 944.51 -349.60 FAIL 10970.46 8914.17 11275.00 8882.01 31.15 272.49 190.84 273.16 5.000 583.60 945.57 -361.98 FAIL 10960.41 8913.69 11300.00 8880.18 31.84 272.30 189.83 273.36 5.000 572.19 946.59 -374.40 FAIL 10950.00 8913.20 11325.00 8878.57 32.55 271.97 188.77 273.55 5.000 560.62 947.29 -386.68 FAIL 10939.93 8912.71 11350.00 8876.96 33.35 271.53 187.74 273.73 5.000 549.45 947.81 -398.37 FAIL 10929.31 8912.20 11375.00 8875.16 34.20 270.94 186.68 273.94 5.000 539.04 948.10 -409.06 FAIL 10918.45 8911.67 11400.00 8873.29 35.13 270.20 185.59 274.16 5.000 529.27 948.02 -418.75 FAIL 10907.46 8911.14 11425.00 8871.41 36.10 269.31 184.50 274.39 5.000 519.63 947.77 -428.14 FAIL 10896.29 8910.59 11450.00 8869.89 37.12 268.26 183.35 274.58 5.000 510.31 947.07 -436.77 FAIL L 10884.91 8910.03 11475.00 8869.13 38.21 267.04 182.08 274.68 5.000 501.50 946.33 -444.83 FAIL a ~ BP Alaska ~ s~~s .~. ' ' p Anticollision Report 1NTEQ Company: BP Amoco Date: 12/12/2008 Time: 15:04:04 Field: Prudhoe Bay Reference Site: PB K Pad Co-ordinate(NE) Reference: Well: K-06, True North Reference Well: K-06 Vertical (TVD) Reference: K-O6A: 53.6 Reference Wellpath: PIarr4, K-066 Site: PB E Pad Well: E-09 Rule Assigned: Major Risk Wellpath: E-09A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable Page: 2 Db: Oracle MD .TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/Flsflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10873.33 8909.46 11500.00 8868.95 39.33 265.64 180.72 274.72 5.000 493.25 945.11 -451.86 fAIL ~~ 10861.57 8908.88 11525.00 8868.82 40.51 264.06 179.33 274.74 5.000 485.51 943.68 -458.17 FAIL 10850.00 8908.30 11550.00 8868.86 41.67 262.36 177.94 274.73 5.000 478.38 941.72 -463.34 FAIL 10837.54 8907.69 11575.00 8869.12 42.95 260.35 176.40 274.70 5.000 471.67 939.40 -467.73 FAIL 10677.66 8899.94 11600.00 8869.37 27.05 272.70 192.32 273.78 5.000 464.21 930.44 -466.22 FAIL 10666.87 8899.43 11625.00 8869.60 27.86 272.59 191.04 273.80 5.000 450.81 932.25 -481.44 FAIL j 10655.70 8898.91 11650.00 8869.96 28.72 272.32 189.69 273.79 5.000 438.10 933.81 -495.71 FAIL 10644.19 8898.36 11675.00 8870.32 29.69 271.90 188.30 273.78 5.000 426.04 935.06 -509.02 FAIL 10632.47 8897.80 11700.00 8870.59 30.74 271.30 186.88 273.77 5.000 414.17 936.22 -522.05 FAIL 10620.45 8897.21 11725.00 8870.63 31.86 270.52 185.46 273.79 5.000 402.81 936.87 -534.06 FAIL 'i 10608.10 8896.61 11750.00 8870.51 33.08 269.55 184.01 273.82 5.000 392.13 937.51 -545.39 FAIL 10595.46 8895.99 11775.00 8870.35 34.36 268.37 182.52 273.85 5.000 381.96 937.88 -555.92 FAIL 10582.62 8895.35 11800.00 8870.13 35.72 266.98 181.02 273.89 5.000 372.05 937.85 -565.80 FAIL 10569.52 8894.70 11825.00 8869.91 37.12 265.36 179.48 273.93 5.000 362.60. 937.30 -574.70 FAIL 10556.12 8894.03 11850.00 8869.63 38.59 263.50 177.90 273.96 5.000 353.88 936.23 -582.35 FAIL 10542.44 8893.34 11875.00 8869.30 40.11 261.39 176.29 273.99 5.000 345.83 934.56 -588.73 FAIL 10528.52 8892.64 11900.00 8868.92 41.67 259.03 174.65 274.02 5.000 338.39 932.26 -593.87 FAIL 10514.37 8891.92 11925.00 8868.50 43.27 256.40 172.98 274.06 5.000 331.60 929.28 -597.67 FAIL 10499.97 8891.19 11950.00 8867.83 44.90 253.51 171.31 274.12 5.000 325.63 925.54 -599.91 FAIL 10485.37 8890.45 11975.00 8867.07 46.54 250.33 169.63 274.19 5.000 320.43 921.02 -600.60 FAIL Ii 10480.31 8890.19 11983.59 8866.81 47.11 249.18 169.04 274.21 5.000 318.81 919.30 -600.49 FAIL Site: PB E Pad Well: E-09 Rule Assigned: Major Risk Wellpath: E-09AP61 V1 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10985.26 8914.87 11250.00 8898.61 30.29 272.60 191.08 271.62 573.98 945.29 -371.30 FAIL 10975.00 8914.39 11275.00 8897.82 30.84 272.58 189.92 271.70 561.62 946:58 -384.95 FAIL I 10965.14 8913.92 11300.00 8895.95 31.51 272.45 188.91 271.87 549.91 947.67 -397.76 FAIL ~ 10954.71 8913.42 11325.05 8893.50 32.23 272.18 187.91 272.12 538.66 948.56 -409.91 ~ FAIL ~ 10944.12 8912.91 11350.00 8890.77 33.02 271.78 186.92 272.41 527.87 949.11 -421.24 FAIL 10933.29 8912.39 11375.00 8887.87 33.88 271.23 185.93 272.72 517.55 949.54 -432.00 FAIL j 10922.24 8911.86 11400.00 8884.96 34.79 270.53 184.92 273.04 507.75 949.48 -441.73 FAIL 10917.50 8911.63 11410.59 8883.73 35.21 270.18 184.49 273.18 503.77 949.47 -445.70 FAIL Site: PB E Pad Well: E-09 Rule Assigned: Major Risk Wellpath: E-096 V5 Inter-Site Error: 0.00 ft __ Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10966.52 8913.99 11250.00 8907.95 31.42 272.42 187.61 270.40 2.875 856.78 946.81 -90.03 FAIL 10957.58 8913.56 11275.00 8907.78 32.03 272.22 186.52 270.39 2.875 856.22 947.74 -91.52 FAIL 10950.00 8913.20 11300.00 8907.56 32.55 271.97 185.58 270.36 2.875 857.27 948.12 -90.85 FAIL 10939.76 8912.70 11325.00 8907.01 33.36 271.53 184.37 270.38 2.875 859.89 948.97 -89.08 FAIL 10930.99 8912.28 11350.00 8906.22 34.06 271.05 183.34 270.40 2.875 864.19 949.36 -85.17 FAIL 10925.00 8911.99 11375.00 8905.44 34.54 270.68 182.62 270.41 2.875 870.30 949.24 -78.93 FAIL 10913.97 8911.45 11400.00 8904.70 35.52 269.87 181.33 270.44 2.875 877.93 949.50 -71.57 FAIL 10905.63 8911.05 11425.00 8903.71 36.27 269.16 180.36 270.48 2.875 885.72 949.34 -63.62 FAIL 10900.00 8910.77 11450.00 8902.53 36.77 268.65 179.72 270.50 2.875 893.04 948.87 -55.83 FAIL Alaska Department of Natural Resources Land Administration System • _-_~ ~- ~ ~;~E. , ~1.~~: ~ y~=, '.. ~cr. ~-~u.~:~ i'i~ls ~ero~~er`s Searcf~ Sfate Cabins Page 1 ofxi IV~tt~e~l s+our~+es ~aS~Ca DAR ~aS#: C~'' File Type: A~~ ~ File Number: _?8303 ', ~ Printable Case F.le_Summ..a..ry See Township, Range, Section and Acreage? C New Search Yes ~° No LAS MenE~ I Case Abstract I Case Detail ~ Land Abstract File: AllL 28303 ''~~°~` Search for Status Plat Updates ~ i~f 12i~2i200S Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900E. BENSON BL ATTN: LAND MANAGER- . ALASKA ANCHORAGE AK 995196612 Case Type: 784.. OIL & GAS LEASE COMP DNR Urzit: 780 OI'L AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of~Prirnary Responsibility: DOG DIV OIL AND GAS Last Transactio~z Date: 12/04/2006 Case Satbtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED 11~er~idian: U Township: 0 I I ~ Rair,E~: OI4~ Sc>c~trofr: (1 ', ~~L'CI1~7/] ,lc~r~~s: 6=111 Search Plats ~lt~r-iJhnt: l_I %n~rrii~iaip: O1 I N R~r~a<<rc~ ~ O1 ~ f. .S'~~ctir,n: 0~ J'~~~~Iic,>> 1c~~~~~.+~: (i~O M{~t~r~/iuft: L1 7~~titi~rl.e{rij~: O] IN I~cn~~~~: Ol~I~: ,S'~c/lnn' 09 .ti~E~~~lir~rt_~lcr•c~~: 6~p 11~Ieridiun ~ I) 1 nirn~hrl,.~ 01 l N liuir~c~.~ O1 ~E_ ,~'rc°tion: I U :ti'<~c~tinn :1c r~~s: 610 Le;;al Dcscript.ioc~ OS-2<4-1965 * * * SALE NOTICE LEGAL DESCRIPTION* CI-~-12~ IIN 1=1E UM 3, ~t, 9, I D 2560.00 U- 3- 7 d t~f Case Sur~a~ Last updated on 12/2212008. http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=283... 12/22/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~^ ~~~; ,~'~-,SG ~ , ~~~ ~:: . _:., .. '...:.~.~r ±., „t 1._~ a ;ts ~ ~ ~cc~rde€"s Search State Cabins ~I~tu1"7 S~DUC€~e~ ., ~~ File T e ADL File Number: 28304 0~- Printable Case File_Summary YP _........ See Township, Range, Section and Acreage? ~ New Search ~` Yes ~° No ~~ I..AS ?~en~a I Case Abstract I Case Detail I Land Abstract _ t. File: :~DL 28304 ''!~'_~' Search for Status Piat Updates :~~ of I?%?~%'OOS Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 9951966.1.2 Case Tvpe: 784 OiL & GAS LEASE COMP DNR Unit: 780 O1L AND GAS File Location: DOG DIV OIL AND GAS Case Statzrs: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2469.000 Date Initiated: 05/28/1965 Once of Prir~~iary Responsibility: DOG DIV OIL AND GAS Last TTafISC[Ct1n/1 Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED 11~1~~ricliujt~ i! Tnx~nship: O11N Xtange: O1~[~ ~'cction: 0~ Sectior~_~lcres:640 Seared Plats ale~ri~li~rn.~ l_i Trr~n~nship: O:IIN Rar~,Lrc.~ 01.1E .ti'<rc~iorr: U6 Section_a~~r~c.~~:593 alcr~i~liun: lI Tuwtlship: D11N Ra~r,~rc.~ Ol=1I: .5'rclir,j~: 07 S~~ction_lcrc~~~: 596 Mericlrun.~ Ci Toivi~ship: 01 I N R~ur,~c: O l ~I_ .ticcliuri: 0~ .~`ec~trort.: Icre~s: tipO Legal Dcscriptiv~z 0 ~-28-1965 * _T`SALE NOTICE LEGAL DESCRIPTION'S ~` ~` CI ~-12~ 11 N 14E ~IM~, 6, 7, 8 2169.00 U- 3- 7 d e Slt~ racy Last updated on 12/22/2008. http://dnr. alaska. gov/proj ects/las/Case_Summary. cfm?FileType=ADL&FileNumber=283... 12/22/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME /~~~ ~ ~~~ PTD# o?OBc~?~3 _ /~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~.E'!/d.~/OE.~ip3~ POOL: ~,~!/~~OE~/'f!y D/L Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (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. PILOT HOLE In accordance with 20 AAC 25.005(fj, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs 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 throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Companv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/11/2008 VItELL PERMIT CHECKLIST Field 8 Pool PRUDHOE BAY, PRUDHOE OIL - ti40150 Well Name: PRUDFiOE BAY UNIT K-06B Program DEV Well bore sag ^ PTD#:2082030 Company BP EXPLORATION (ALASKA) INC Initial ClasslType D EV 1 PEND GeoArea 890 Unit 11650 On1Off Share ~_ Annular Disposal ^ Administration 1 Pemlitfeeattached ---- --- -- -- - -- -------- - NA-- - --- -- ---- - - --- ----- -- - - -- ------ 2 Lease numberapproPriate ---- ---- - -- ---- ~--- ---- Yes - ------ -- -- -- - -- -- ----- ------ -- - -- - --- -- 3 Unigaew811-name andnurober--- ---- - -- --- - --- -- Yes ------ -- -- - ------ ----- - ------- -- - --- - - 4 -WeIIfQr~tedirta-defined-po41 --- ---- ------ -- --- -- - Yes- -- -- --- -- ------- - ---- ---- ----- - -- ---- 5 WelUQCatedProperdiskancefromdrihingunii_boundary------------------------ Yes-- -------------------------------------------------------------------- 6 -Nlell located proper distance from 2iher wells- - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Suff'icientsereageayailablein_drillingenii_____-__.-_--___------------- Yes--- --------------------------------------------.--------------- 8 Ifdeviated,is-wellboreplat_incfuded-------- - --- - -- - --- - Yes-- - --- -- -- -- -------------- ---- - -- - --- -- 9 Operatofgnh~affectedParkY- --- ---- -- -- -- --- --- ---- Y~ ------ - - --- -- - ---- ---- -- -- -- ---- 10 Operatorhas_apptopriatebondinfQrce--------------------------------- Yes--- ----BlanketBond#61241$3.---------------------.---------------------------- 11 PermiteanbeissuedwithoufGOnservati~p4rder-------------------------- Yes-- -------.-------------------------------------------------- -- ----- Appr Date 12 Pe[mitEanbeissuedwjthQUfadmlhist[alive-approval------------------------- Yes--- -.-.-------------------------------------------------------- - ----- 13 Can permit beapprQVed4efgre15•daywait---- --- --- --- - -- Yes ---- - ------ ----------- --- ---- -- -- -- - ------- - ACS 1212212008 14 WeIIIQCatedwithioareaandsiratasath4rizedbylnjectionOCde[~(pptlO#in_commentsl(FCr_ NA____ .-___--_---------------------------------__------_------------_----- 15 Allwells.WithinU4_mileareaofreviewidentified(Forservicewell9nly)__-____-___-_- NA____ --__----_------------------_-_---__-_-----__------_-------.-------- 16 Pre-produced injector,durati~nofpreproductronlessthan3mgnths(ForservicewellQniy)-- -NA---- -------------------------------.--------------------------- ---- - 17 NoncAnven. gas c9oforms to AS31.05,090(1.1.A)~(L2.A-D) - - - - - - - ~- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 18 Conductor string-P-rovided_-_-_.---_._------_------------------ -NA--- ----Conductorset-inK-O$1183.1$2).---------------------------------------------- Englneering 19 Surface casingprotectsallknownUSDWs-_-_------_---_-.._--__---- -NA__- --__Allaqurfers exempted,AEO1._--________---------------------------------- --- 20 CMT_voladequafetQCirculate_oncondu~t9[8,surf_csg________________________ NA____ --__Surfa~ecasingsetinK-0$.-----__.--_-------_--_-__--------.----------------- 21 CMTvoladequatetoiie•inlQngstringtosurfcsg--------------------------_ NA____ ___Producfi4n_casingsetin-K-06._--____---__-_-____-__-_----._--------__---_-- 22 CMT-willGOyer all known-prod~Gtiveh2ri14rts------------------------------ Yes--- ------------------------------------------------------------- -- ---- 23 CasingdesynsadequateforC,T,B_&permafrosi----------------------- --- Yes--- ------------------------------------------------------------- --- -- 24 Adequate iankage_or tessnre pit - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - Yes _ - - - - _ Rig egyipped with steel pits, No-rese[ve pit planned._ Ali waste_tg approved disposalwell(s), - _ _ .. - _ - _ _ - - - 25 Ifa-re-drill,has_a10~09fQraband4nment keenaPRroved_.--------------_--- Yes-- -----308.45$--.-------------------------------------------------------- 26 Adequate wellgore separallonpropgsed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - _ - - _ Proximity analysis perfo[med: Nearest segment is P8A p9dion Qf KrO6A and paths_diverge, - - - - _ - _ _ 27 If dNerterrequired,dQesltmeetregulati9ns----------------------------- -NA--- -----BOPStaGkv~ilialready-be inplaee,---------------------------------------------- 28 program schematic & equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Drilling fluid _ Yes . - _ - - - Ma~4imam expected fo[mation pn3ssure 7,3 EMW.- MW planned $.$ ppg. - - - . - - - - _ - - _ _ - - - - - - _ - - . Appr Date TE 1212312008 29 _ BOPEs,dotheynteetregulaii9n---- ----- --- - -- - --- - -Yes - ---- -- - -- -- --- -- -- -- ----- - - -- ------- 30 BOPS-p-rasa rating appropriate; test to_(put psig in-cemments)- - - - - - - - - - - - - - - - - - -Yes - _ - - - _ MASP salculated_at 2479 psi, 3500_psi_ram lest planned.- _ . - - _ - - - _ - - . _ - - - _ - - - _ - - - - - - _ - 31 Choke-manifolds~mRiiesudAPLRP-53 (May 84) -- - -- -- -- --- Yes - - -- ----- --- - ----- ------- --- -- -- - ----- 32 Warkwi119ccurwithouioperaUonshufdown____-------------------- --- -Yes-- --------------------------------------------------------- -------- 33 is Presence of H2S gas Rrobable- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -Yes - _ - - _ _ H2$ is rep9rted.at Kpad._Mad_shQUld preclade H2$ onrig._ Rig has sensors and alarms.- _ - - - . - - - - - _ - - 34 Mechanical_c~nditionofwellswithinAQRyerified(Forse[vicewell4nly)------------- - NA--- ----------------------------------------------------------------------- 35 Permiteanbe'lssuedwlohydrogensu(fidemeasuces------------------------ -NO-- -----MaXlevelH2$Qn K-pad_is25ppm,--------------.----------.------------------ Geotogy 36 Data_presgnted on potential overpressure zenes. - - _ - - - _ . -- -- ---- --- - NA- ---- -- --- -- - --- ----- --- -- - -- -- --- App[ Date 37 Seismic-analysis°fshalloy~gas_z9nes------ .- -- - --- ---- - - NA ------ -- - --- - ----- --- - ----- - -- ------ ACS 1212212008 38 Sewed-cAnditionsurvey_(ifgffshore)--------------------------------- -NA___ _______-__--____---_---._-_---_.--_----_-.-------_----------------- 39 Contactnamelphoneforweekly_prQg_resstep9rts_[e~ploratgry9nly]--_-___------_ -Yes-- ----_RQn-Phillipsr5$4-591$.-__--__-__--------------------------_.-------_------ Geologic Date: Engineering Date tic Date ' Commissioner: one[ Commissioner C mi t~'~c7 '~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efforl has been made to chronologically organize this category of information. ~r s **** REEL HEADER **** MWD 09/03/26 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/01/26 2415171 01 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!~ !!~~!!!!!! Remark File Version 1.000 !!!!!!!!! !!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 8764.5000: Starting Depth STOP.FT 10998.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: K-06B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 20' 15.998"N 148 deg 36' 51.258"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 26 Jan 2009 API API NUMBER: 500292103802 Parameter Information Block #MNEM.UNIT Value SECT. 04 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 53.6 DMF DF EKB .F 0 EDF .F 53.6 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ~0~-~03 1~~3~- (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage (OHMM) (OHMM) (OHMM) (OHMM) surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 28 Jan 2009 per Doug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from K-06A through a milled window in a 4 1/2 inch liner. Top of window 9069 ft.MD (8554 ft.TVDSS) Bottom of window 9078 ft.MD (8561 ft.TVDSS) (9) Tied to K-06A at 9046 feet MD (8533.7 feet TVDSS). (10) The interval from 10955 feet to 11005 feet MD (8857.7 feet to 8859.4 feet TVDSS) was not logged due to sensor to bit offset. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected TVDSS -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 8766.8, 8766.38, ! -0.415039 8771.36, 8769.49, ! -1.86621 8775.09, 8773.43, ! -1.6582 8776.96, 8775.92, ! -1.03613 8778.61, 8777.99, ! -0.62207 8782.34, 8781.72, ! -0.62207 8784, 87 83.38, ! -0.621094 8786.91, 8785.87, ! -1.03613 8811.37, 8810.33, ! -1.03613 8816.76, 8815.1, ! -1.6582 8820.07, 8818.62, ! -1.45117 8824.01, 8823.6, ! -0.415039 8827.74, 8826.91, ! -0.830078 8829.61, 8828.99, ! -0.62207 8834.67, 8833.02, ! -1.6582 8836.75, 8835.09, ! -1.6582 8839.24, 8836.96, ! -2.28027 8842.34, 8841.31, ! -1.03613 8844.42, 8844, ! -0.415039 8846.08, 8845.45, ! -0.62207 8848.36, 8847.73, ! -0.62207 8849.6, 8848.98, ! -0.62207 8856.86, 8856.23, ! -0.62207 8861.21, 8859.96, ! -1.24414 8862.45, 8861.42, ! -1.03613 8864.11, 8863.49, ! -0.62207 8867.63, 8866.39, ! -1.24316 8868.67, 8867.84, ! -0.829102 8870.74, 8869.71, ! -1.03613 8873.44, 8872.2, ! -1.24414 8877.17, 8875.93, ! -1.24414 8880.28, 8880.49, ! 0.207031 8884.63, 8883.6, 8886.08, 8885.25, 8887.95, 8886.91, 8889.61, 8888.57, 8891.47, 8890.44, 8893.34, 8892.1, 9068.03, 9068.65, 9075.91, 9075.08, 9077.36, 9077.36, 9079.02, .9078.39, 9080.47, 9080.88, 9083.99, 9083.58, 9085.86, 9085.65, 9088.55, 9088.97, 9092.28, 9091.45, 9097.05, 9096.64, 9099.75, 9098.5, 9107, 9107.21, 9113.22, 911T.98, 9120.68, 9120.27, 9122.76, 9122.55, 9130.22, 9128.35, 9134.36, 9133.54, 9140.58, 9139.13, 9146.39, 9145.35, 9147.52, 9146.89, 9149.59, 9148.55, 9156.01, 9154.77, 9159.95, 9157.88, 9163.89, 9162.44, 9166.38, 9165.34, 9168.04, 9167.83, 9174.67, 9173.43, 9177.57, 9176.12, 9179.02, 9178.2, 9180.27, 9179.23, 9182.96, 9182.13, 9184.62, 9183.79, 9187.32, 9186.07, 9200.42, 9198.97, 9204.98, 9203.53, 9210.99, 9209.54, 9219.49, 9217.62, 9225.09, 9223.84, 9229.85, 9228.82, 9235.24, 9234, 9237.11, 9235.45, 9240.63, 9237.94, 9244.57, 9242.5, 9248.6, 9247.77, 9250.47, 9250.05, 9261.04, 9257.93, 9264.14, 9261.86, 9266.83, 9265.59, 9268.49, 9267.66, 9271.18, 9270.77, 9275.94, 9275.94, 9284.44, 9283.82, 9301.86, 9300.2, 9307.66, 9307.25, 9311.6, 9310.35, 9313.67, 9313.67, 9316.78, 9315.95, 9324.04, 9321.96, 9327.56, 9326.32, 9329.01, 9328.8, 9330.88, 9330.46, -1.03613 -0.829102 -1.03711 -1.03613 -1.03613 -1.24414 0.621094 -0.829102 0 -0.62207 0.414062 -0.414062 -0.207031 0.415039 -0.829102 -0.415039 -1 . ?.4414 0.207031 -1.24414 -0.414062 -0.207031 -1.86523 -0.829102 -1.45117 -1.03613 -0.62207 -1.03711 -1.24316 -2.07227 -1.45117 -1.03711 -0.207031 -1.24414 -1.4502 -0.829102 -1.03613 -0.829102 -0.829102 -1.24316 -1.45117 -1.45117 -1.45117 -1.86621 -1.24316 -1.03613 -1.24316 -1.6582 -2.69434 -2.07324 -0.829102 -0.415039 -3.10938 -2.28027 -1.24414 -0.829102 -0.414062 0 -0.621094 -1.6582 -0.415039 -1.24414 0 -0.829102 -2.07324 -1.24414 -0.208008 -0.414062 `~ L 9333.16, 9332.12, ! -1.03613 9336.06, 9335.64, ! -0.415039 9338.96, 9336.89, ! -2.07324 9342.9, 9341.24, ! -1.-6582 9355.27, 9352.78, ! -2.48828 9361.28, 9359, ! -2.28027 9399.05, 9395.32, ! -3.73145 9402.58, 9399.67, ! -2.90234 9413.35, 9410.45, ! -2.90234 9425.17, 9421.02, ! -4.14648 9447.96, 9446.3, ! -1.6582 9452.11, 9449.83, ! -2.28027 9456.25, 9451.9, ! -4.35254 9462.06, 9458.54, ! -3.52441 9496.56, 9495.73, ! -0.830078 9499.67, 9498.22, ! -1.45117 9519.57, 9519.78, ! 0.207031 9522.47, 9522.06, ! -0.414062 9541.59, 9537.86, ! -3.73145 9544.9, 9542.42, ! -2.4873 9559.41, 9555.06, ! -4.35254 9574.85, 9571.33, ! -3.52344 9582.21, 9580.96, ! -1.24414 9605.63, 9602.52, ! -3.10938 9901.74, 9899.04, ! -2.69531 9941.74, 9941.33, ! -0.414062 9973.45, 9969.51, ! -3.93848 9987.76, 9983.61, ! -4.14551 iU066.3, 10065.7, ! -0.62207 10162.4, 10159.1, ! -3.31738 10165.7, 10161.6, ! -4..14551 10204.1, 10200.3, ! -3.73145 10207.7, 10203.6, ! -4.14648 10211.9, 10207.1, ! -4.76758 10215, 1 0209.6, ! -5.38965 10247.1, 10244.6, ! -2.4873 10256.8, 10254.5, ! -2.28027 10260.1, 10258.1, ! -2.07324 10264.9, 10262, ! -2.90137 10268.8, 10264.5, ! -4.35352 10272.4, 10268, ! -4.35352 10274.6, 10272.2, ! -2.4873 10276.1, 10273.8, ! -2.28027 10287.3, 10286.7, ! -0.621094 10297.6, 10297, ! -0.62207 10307, 1 0306.4, ! -0.62207 10314, 1 0312, ! -2.07227 10319.4, 10317.8, ! -1.6582 10327.7, 10326, ! -1.6582 10332.3, 10330, ! -2.28027 10334.6, 10332.3, ! -2.28027 10341.8, 10339.1, ! -2.69434 10370.9, 10371.5, ! 0.62207 10379.2, 10379.2, ! 0 10384.6, 10384.6, ! 0 10409.3, 10408.6, ! -0.62207 10419.4, 10418.4, ! -1.03613 10429, 1 0429, ! 0 10438.1, 10437.1, ! -1.03613 10467.1, 10465, ! -2.07324 10478.5, 10477.2, ! -1.24414 10487.4, 10484.9, ! -2.48828 10499.5, 10495.1, ! -4.35352 10528.3, 10522.5, ! -5.80469 10532.6, 10528.3, ! -4.35254 10539.5, 10536.8, ! -2.69434 10554, 1 0550.7, ! -3.31641 U 10558.3, 10554.4, ! -3.93848 10601.7, 10598.2, ! -3.52344 10722.3, 10716.3, ! -6.01172 10734.7, 10730, ! -4.76758 10738.1, 10731.6, ! -6.42578 10746.8, 10741, ! -5.80469 10751.5, 10746.6, ! -4.97461 10753.4, 10747.4, ! -6.01074 10760.2, 10753.2, ! -7.04785 10762.9, 10755.9, ! -7.04785 10766.5, 10759.6, ! -6.84082 10773.3, 10764.6, ! -8.70703 10778.5, 10770, ! -8.49902 10781.2, 10773.9, ! -7.25586 10786.6, 10778.3, ! -8.29199 10791.4, 10785, ! -6.42676 10793.7, 10788.1, ! -5.59766 10796.1, 10790.6, ! -5.59668 10798.6, 10793.5, ! -5.18262 10800.1, 10795.1, ! -4.97461 10803.6, 10798, ! -5.59766 10807.5, 10802, ! -5.59668 10812.7, 10806.7, ! -6.01172 10816.9, 10811.1, ! -5.80469 10819.1, 10813.3, ! -5.80469 10825.2, 10818.5, ! -6.63379 10829.3, 10823.1, ! -6.21875 10834.3, 10827.2, ! -7.04883 10837.6, 10831.6, ! -6.01172 10841.5, 10834.5, ! -7.04785 10844.2, 10837.4, ! -6.84082 10847.5, 10840.3, ! -7.25586 10851.1, 10843.6, ! -7.46289 10853.6, 10849.6, ! -3.93848 10859.6, 10854.8, ! -4.76855 10866.2, 10861, ! -5.18164 10875.6, 10870.4, ! -5.18262 10877.9, 10872.9, ! -4.97461 10884.7, 10878.7, ! -6.01172 10887.6, 10881.8, ! -5.80469 10891.5, 10885.1, ! -6.42578 10902.5, 10896.1, ! -6.42578 10912.7, 10906, ! -6.63379 10914.5, 10908.1, ! -6.42578 10917.9, 10910.8, ! -7.04785 10919.9, 10913.3, ! -6.63281 10933, 10926.4, ! -6.63379 10936.8, 10929.5, ! -7.25586 10941.7, 10934.7, ! -7.04785 10944.9, 10938.2, ! -6.63281 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 291 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !~!~!!!!!!!!!!!!!!! Remark File Ver sion 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log pr ovided by Schlumberger GR CNL dated 28 Jan 2009 per Doug Stoner wi th BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 125 Tape File Start Depth = 8764.500000 Tape File End Depth = 10998.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 138 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes. **** FILE HEADER **** MWD .001 1024 ~ ~ *** LIS COMMENT RECORD *** !!!!!!!!!~!!!~~~!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 ° 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 249 Tape File Start Depth = 8765.000000 Tape File End Depth = 11005.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 262 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/01/26 2415171 Ol **** REEL TRAILER **** MWD 09/03/26 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8764.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8765.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8800.0000 43.9201 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8900.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 45.4997 14.7989 104.8023 64.8773 32.8367 26.6380 9200.0000 31.7395 41.8199 115.7436 113.5533 44.9290 35.7936 9300.0000 61.1448 51.4872 98.7581 64.8584 41.0762 36.1694 9400.0000 118.5705 93.1201 41.5229 39.1851 34.2468 33.0269 9500.0000 62.4203 120.3918 33.5404 35.9485 30.3050 28.9830 9600.0000 66.2715 37.1219 44.4780 40.3159 33.5210 30.9260 9700.0000 71.3727 37.1150 57.3555 49.6379 37.5047 34.2490 9800.0000 65.5117 43.2651 39.9444 39.1943 32.7670 29.9300 9900.0000 75.7371 51.9075 49.7387 38.8680 33.8051 30.9770 10000.0000 61.5576 99.7525 76.2270 57.0701 41.7781 38.2520 10100.0000 69.8059 79.1000 68.1166 54.6560 38.8840 35.5490 10200.0000 102.5443 155.6042 109.1062 53.5869 36.2120 30.4410 10300.0000 65.0609 166.2988 68.2929 40.8836 31.2660 26.8485 10400.0000 74.2899 148.4940 76.0784 59.7198 41.0510 36.8190 10500.0000 53.5467 177.0699 68.0516 71.7970 47.2250 43.7990 10600.0000 41.8705 1429.9856 104.9686 67.5947 43.9062 37.2840 10700.0000 39.7380 85.6112 34.0375 31.4688 10800.0000 166.6537 92.0904 26.9254 23.7353 10900.0000 43.2702 96.0371 38.4566 36.1540 10998.5000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8764.500000 Tape File End Depth = 10998.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 51.7803 47.2743 55.5253 -999.2500 39.2621 38.4174 42.9773 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8765.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8765.2500 73.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8800.0000 39.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8900.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 62.0000 13.5000 133.6620 61.5900 29.8270 23.8720 9200.0000 43.8000 42.5000 85.8680 82.7850 50.5560 44.9850 9300.0000 40.7000 52.4000 93.1190 64.8870 40.4320 36.0180 9400.0000 84.5000 113.4000 44.4710 43.7550 36.8240 36.1290 9500.0000 60.4000 118.6000 33.8810 35.9610 30.7720 29.4510 9600.0000 70.8000 26.9000 44.3190 40.3830 33.2990 30.9260 9700.0000 69.2000 59.2000 59.6690 52.3550 38.8290 34.8580 9800.0000 67.9000 42.9000 41.5110 40.2420 33.2990 30.4210 9900.0000 73.6000 49.9000 49.4950 38.3900 33.8890 30.4710 10000.0000 64.9000 109.6000 78.5190 56.5660 41.8710 37.5460 10100.0000 70.7000 52.6000 68.4230 54.9200 39.5960 35.5490 10200.0000 60.6000 161.6000 87.4210 54.1150 35.0050 29.4690 10300.0000 62.7000 171.0000 68.4770 41.1120 31.2660 26.8250 10400.0000 74.2000 151.1000 74.1500 58.6010 41.0510 36.8190 10500.0000 57.1000 164.7000 68.4770 71.5390 46.1550 42.9210 10600.0000 34.7000 223.2000 105.3100 68.2530 49.1340 42.0720 10700.0000 36.4000 88.6000 33.3450 31.2500 10800.0000 90.6000 90.6000 28.5600 25.6390 10900.0000 36.6000 78.3000 36.8430 32.5420 11000.0000 -999.2500 124.6000 -999.2500 -999.2500 11005.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8765.000000 Tape File End Depth = 11005.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet i 47.9460 46.1320 65.2160 -999.2500 -999.2500 37.7530 40.1160 50.9650 -999.2500 -999.2500 Tape Subfile 4 is type: LIS
