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205-166
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special resean activity or are viewable by direct inspection of the file. Qs - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III Illf~{ 1~ Ill II If) ^ Rescan Needed III II~I1I II II III {II RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. I ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ D o /s/ Project Proofing III II'III I I III I I {II ,, BY: Maria Date: ~ ~ ®g ls! Scanning Preparation _~ x 30 = ~~ + ~~ =TOTAL PAGES ~b I I (Count does not include cover sheet) I(ti/C BY: Maria Date: ~ r a re ~ /s/ Production Scanning Stage 7 Page Count from Scanned File: ~ ~ (Count does include cov heet) Page Count Matches Number in Scanning Preparation: _,~i' YES NO BY: Maria Date: ~' ~ V ~ /s/ ~; Stage 7 If ND in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II ~) I Ii II I ({II ReScanned II I II II11 {l III I {III. BY: Maria Date: /s! Comments about this file: Quality Checked Ill 4I'~Il III Illl III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIRND GAS CONSERVATION COMMISS N WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other: Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 IN Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 5/22/2011 205 - 166 311 - 059 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 11/16/2005 50 029 - 22635 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/21/2005 PBU 15-48B 3971' FSL, 5021' FEL, SEC. 22, T11N, R14E, UM 8. KB (ft above MSL): 66,7' 15. Field / Pool(s): Top of Productive Horizon: 3649' FSL, 984' FEL, SEC. 21, T11N, R14E, UM GL (ft above MSL): 32.9' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 1460' FSL, 1757' FEL, SEC. 21, T11N, R14E, UM 8850' 8573' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 676193 y - 5960178 Zone ASP4 11646' 8939' ADL 028306 TPI: x - 674959 y 5959828 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x 674243 Y - 5957622 Zone ASP4 N/A 18. Directional Survey: ❑ Yes 181 No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all Togs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD GR / EWR, MGR / CCL / CNL 9195' 8844' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MO SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 114' Surface 114' 30" 260 sx Arctic Set (Approx.) 9 -5/8" 40# L -80 34' 3548' 34' 3546' 12 -1/4" 995 sx CS III. 305 sx 'G'. 187 sx CS II 7" 26# / 29# L -80 32' 8554' 32' 8324' 8 -1/2" 235 sx Class 'G' 4-1/2" 12.6# L -80 8341' 9195' 8146' 8844' 6" 316 sx Class 'G' 3-1/2" x3 x 2 8.81# / 6.2# / L -80 8879' 11542' 8597' 8935' 4 -1/4" x 3-3/4, 158 sx Class 'G' �m�� a gar 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open .SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6#, L -80 8341' 8306' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED Pulled Scab Liner (From 4010' - 8877') I I F(I'i ; 8850' Set Whipstock (t.,/ /Jiec r ) L 27. iNlig ";a 5f 1 & - 1; tititi *81011 PRODUCTION TEST Date First Production: J IILhetitybl Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A 1 Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ■= No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize Iithology 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 JUN 1 '7 20 RBDMS JUN 16 2011- Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only A, 1,,"°. G � '7`6n/ 29. GEOLOGIC MARKERS (List all formations and mark countered): 30. II iATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. TDF / Zone 1A 9212' 8855' None Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0‘7/ Signed: Terrie Hubble J6na , 4464 Title: Drilling Technologist Date: PBU 15 205 - 166 311 - 059 Prepared By Name/Number Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Mark Staudinger, 564 -5733 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 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • 15 -48B, Well History (Pre Rig Sidetrack) Date Summary 3/10/2011 T /I /0= 2100/920/0 MIT -IA PASSED to 3000 psi, MIT -OA PASSED to 2000 psi. (CTD Prep) Pumped 9.7 bbls Crude down IA to reach test pressure. Loss of 50 psi 1st 15 min, Loss of 10 psi 2nd 15 min. Bled down IAP, Rigged up to OA, Pumped 2 bbls crude down OA to reach test pressure, Loss of 100 psi 1st 15 min, Loss of 20 psi 2nd 15 min. Total Toss =120 psi. Bleed OA pressure. FWHP= 2100/600/440. 4/8/2011 WELL S/I ON ARRIVAL. DRIFT TO BKR LTP @ 3996' SLM WITH 3.80" G -RING. PULL LTP FROM, 3996' SLM, ALL BUT ONE ELEMENT RECOVERED. MAKE 2 RUNS WITH WIRE GRABS, UNABLE TO FISH ELEMENT. MAKE RUN WITH 2.250" CENT AND 1.75" S- BAILER. STOP DUE TO DEVIATION @ 9268' SLM. S -BLR EMPTY. WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS. 4/27/2011 T /I /O= SSV /650NAC. Temp= SI. Install heater in wellhouse (Pre - PPPOT). No AL. Installed heater trunk on tubing head adapter. 0 psi above SSV. 4/29/2011 T /I /0= SSV /700/0 Temp =SI PPPOT-T (FAIL) (Pre CTD) PPPOT -T : RU 1 HP BT onto THA monitor port 50 psi bled to 0 psi. RU HP BT onto THA test port 700 psi unable to bled to 0 psi, Checked torque of LDS "ET style" all were at max torque for style of LDS, C & B lines both are @ 2400 PSI which indicates the leak is from primary seal. 5/2/2011 T /I /0= SSV /650Nac. Temp= SI. Bleed IA & OAP to 0 psi (pre CTD). Well house & flow line already removed. No AL. IA FL @ surface. Bled IAP from 650 psi to 520 psi in 30 minutes. Final WHPs = SSV /800Nac. Job completed. 5/2/2011 T /I /O= 2350/700/0 Conducted PJSM; Verified Barriers; Tested (charted) lubricator & SN to 400 psi -low / 3500 psi -high (passed & saved); Set 4" CIW TWC #259 @ 114" w/1 -1' ext.; Torqued tree to specification; Pulled 4" CIW TWC #259; Pre Nordic 2. 5/3/2011 T /I /O= SSV /850Nac. Temp= SI. Bleed IAP to 0 psi (CTD). Continued bleed IAP from 850 psi to 800 psi in 1.5 hours (7.8 bbls returned). Shut -in and monitored for 30 minutes, IAP increased 140 psi. Final WHPs = SSV /940Nac. Job completed. 5/6/2011 T /I /0= 2400/1260/0 Temp =SI Load & Kill TBG ( CTD Prep) Speared into TBG w/ 5 bbls of 60/40 MW followed by 200 bbls of 1% KCL. Freeze Protected TBG w/ 44 bbls of 60/40 MW. FWHP= vac/1160 /0 5/9/2011 T /I /O= SSV /1250NAC. Temp= SI. Bleed IAP & OAP to 0 psi (Pre CTD). Well house & flowline have been removed. Heater installed on wellhead. Integral flange installed on IA. IA FL near surface. OA FL near surface. Bled IAP from 1250 psi to 500 psi to bleed tank in 2 hrs (gas w/ fluid slugs, <1 bbl). SI, monitored for 30 mins. IAP unchanged. FWHPs= SSV /500NAC Job incomplete. 5/9/2011 T /I /O = SSV /640NAC. Temp = SI. Bleed IA & OA to 0 psi. (Pre CTD). No AL. IA FL 420'. IAP increased 140 psi & IA FL dropped 420' overnight. Bled IAP from 640 psi to 380 psi in 5.5 hrs (FTS, gas fluid slugs). Monitored for 30 min. IAP increased 30 psi. Final WHPs = SSV /41ONAC. 5/10/2011 T /I /O = 1830/610NAC. Temp = SI. Tbg Pressure (CTD prep). IA integral installed. IAP increased 200 psi over night, OA remained on a VAC. 5/11/2011 T /I /O = 2200/750/vac. Temp = SI. WHPs T & IA FL (Pre CTD). No AL. Tbg FL = 7850' (95 bbls). IA FL = 1100' ( 19.25 bbls). IAP increased 110 psi since 5/9/11. OAP remained the same. 5/12/2011 T /I /0= 2300 /1000 /vac Temp =Sl Injectivity test (CTD prep) Pumped 5 bbls 60/40 and 80 bbls crude down IA to establish injectivity down IA. Tags hung on WV /IA. Operator notified. FWHP's 1600 /500 /vac 5/16/2011 T /I /0= 2250/1000/0 L &K TBG and IA (CTD prep) Pumped 5 bbls neat, 170 bbls 1% inhibited kcl and 44 bbls diesel down IA. Pumped 5 bbls neat methanol, 120 bbls inhibited kcl and 38 bbls diesel down tbg. FWHP's = 0/80/0 Page 1 of 2 • • 15 -48B, Well History (Pre Rig Sidetrack) Date Summary 5/17/2011 TII /O = 0/0/0 Conduct PJSM. Verified Barriers. Rig up lubricator to set TWC. Test lubricator to 300 psi low and 3500 psi high. (passed) Set 4" CIW H TWC @ 100" w/ 1 -2' ext. Remove 4" companion valve and install blind flange with bull plug. Torque blind studs to API specs. Test and chart TWC to 300 psi low, 3500 psi, and 5000 psi high (incl. THA to MV) (passed) Night shift to install double I/A valve. 5/17/2011 T /I /O= VacNacNac. Temp= SI. WHPs. Integral flange installed on IA. Job complete. 5/18/2011 T /I /O = 0/0/0 Conduct PJSM. Test I/A valve to verify as a barrier. Remove blind flange. Install second 2 1/16" gate valve onto back side I /A. Reinstall blind flange and jewelry. Shell test and chart to 500 psi low and 5000 psi high. (passed). Job Complete. Page 2 of 2 • • . . - North America - ALASKA - BP - : Page 1 o O peration Summary Report Common Well Name: 15 -48 AFE No -- Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 5/17/2011 I End Date: IX3- 00YPQ -C: (1,967,359.00 ) Project: Prudhoe Bay Site: PB DS 15 I Rig Name /No.: NORDIC 2 I Spud Date/Time: 11/14/2005 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292263500 Active Datum: 66 : 48 5/30/1996 17:14 @66.70ft (above Mean Sea Level) Date I From - To 1 Hrs Task Code NPT NPT Depth j Phase Description of Operations (hr) (ft) 5/17/2011 20:00 - 23:00 3.00 MOB I P PRE HOLD PJSM AND MOVE RIG OFF OF WELL !I 02 -21. STAGE RIG ON PAD. I 1 RIG CREW MOVE RIG MATS AWAY FROM ;WELLHEAD AND CLEAN AREA AROUND [WELL. TOURPUSHER AND DRILLER MAKE ROUTE - I INSPECTION. SAND TRUCK BEGINS SANDING ROUTE OF TRAVEL TO DS 15. 1 1 :PAD OPERATOR SIGN OFF ON WELLWORK i TRANSFER PERMIT AND POST RIG SITE INSPECTION. 23:00 00:00 1.00 MOB P - PRE HOLD PJSM WITH RIG CREW AND SECURITY I , ION MOVING RIG TO DS 15. BEGIN MOVE FROM' AROUND DS 2 TO WEST i - - DOCK RD. MOB P 5/18/2011 00:00 - 00:30 0.50 PRE [CONTINUE TO MOVE RIG AROUND DS 2 TO WEST DOCK RD. 00:30 05:00 j 4.50 MOB P j PRE MOVE RIG DOWN WEST DOCK RD AND THEN OXBOW RD EN ROUTE TO DS 15. ,TURN ONTO OXBOW RD AT 0200 -HRS AND I ONTO DS 15 ACCESS RD AT 0330 -HRS. 0400 -HRS - MOVE SATELLITE CAMP FROM DS , 2 TO DS 15. 0500- SATELLITE CAMP AND RIG ON BACK PAD OFDS15. 05:00 06:00 1.00 MOB P j PRE j COMPLETE WELL WORK TRANSFER PERMIT I FOR 15 -48 WITH PAD OPERATOR. I j DISCUSS RIG CAMP SITING AND LOCATION , I j CONTROL. UNLOAD ALL EQUIPMENT AND RIG MATS NEEDED TO BE PLACED AROUND WELL. 06:00 - 07:30 1.50 MOB P 1 PRE PREP AREA AROUND WELLHEAD - SET RIG MATS AND PLYWOOD AROUND CELLAR 07:30 - PRE PJSM AND BACK RIG OVER WELL 09:00 09: 0.50 MOB P r PRE j SECURE CELLAR AND SPOT EQUIPMENT 09:30 - 10:00 0.50 MOB P PRE I SET STAIRWAYS AND RIG EQUIPMENT - ACCEPT RIG AT 10:00 HRS ON 5/18/11 10:00 - 12:00 1 2.00 I BOPSUR P PRE PJSM TO N/D TREE CAP AND N/U BOPE 1 t 12:00 - 15:00 3.00 BOPSUR P PRE � NU BOP EQUIPMENT - AOGCC WITNESS WAS _ _ WAIVED BY INSPECTOR: MATT HERRERA 15:00 15:30 0.50 BOPSUR P PRE PJSM TO SHELL TEST - LUBRICATOR EXTENSION TO FLOOR FAILED 15:30 - 16:30 1.00 1 BOPSUR I P 1 PRE 1RIG DOWN EXTENSIONS AND REPLACE 0-RING - RE -TEST - PASSED 1 16:30 23:30 I !, 7.00 I BOPSUR ' P I I PRE PERFORM INITIAL BOPE TEST. 150 n ALL TESTS TO 250 -PSI LOW AND 3500 -PSI I HIGH. HOLD AND CHART EACH TEST FOR 5- MINUTES. ' I I ALL TESTS WITNESSED BY NORDIC TOOLPUSHER. AOGCC REP, MATT HERRERA, WAIVED STATE'S RIGHT TO WITNESS THE BOPE TEST. Printed 5/25/2011 4:12:34PM . orth America - ALASKA - B p Page 2 A era tion Summ ary Report Common Well Name: 15 -48 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 5/17/2011 I End Date: X3- 00YPQ -C: (1,967,359.00 ) Project: Prudhoe Bay i Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA I UWI: 500292263500 Active Datum: 66 : 48 5/30/1996 17:14 @66.70ft (above Mean Sea Level) Date I From - To p Description of Operations I ( ) NPT NPT th Phase HOLD RIG EVACUATION DRILL. Hrs Task Code hr '23:30 - 00:00 0.50 ! BOPSUR P J r ! PRE I ' CREW AND CH2MHILL TRUCK DRIVER ON 'LOCATION ALL RESPONDED TO PRIMARY I MUSTER AREA AT SATELLITE CAMP. I ! AN AAR WAS HELD AND THE MAIN POINT OF I DISCUSSION WAS THE NECESSITY OF SOUNDING THE "AIR RAID" ALARM TO ALERT PERSONNEL WORKING OUTSIDE THE CONFINES OF THE RIG AND ALSO THAT ANNOUNCEMENT NEEDS TO BE MADE OVER THE RIG RADIO, HARMONY RADIO AND THE GAITRONICS, EVEN IN THE EVENT OF A DRILL. ,THE SIGN IN SHEET WAS BROUGHT FROM THE SIGN IN TRAILER TO THE MUSTER AREA IAND DISCUSSION FOLLOWED BECAUSE THERE IS NOT A PERSON ASSIGNED TO 1 I RETRIEVE THE SHEET DURING THE NIGHT SHIFT (SPOC'S RESPONSIBILITY DURING DAY TOUR)_. 5/19/2011 ! 00:00 - 01:00 1.00 I BOPSUR P PRE I CONTINUE WITH INITIAL BOPE TEST. ALL TESTS TO 250 -PSI LOW AND 3500 -PSI HIGH. ' HOLD AND CHART EACH TEST FOR I 5- MINUTES. ! ALL TESTS WITNESSED BY NORDIC I ' TOOLPUSHER AND BP WSL. AOGCC REP, MATT HERRERA, WAIVED ! STATE'S RIGHT TO WITNESS TEST. I I PERFORM ACCUMULATOR DRAWDOWN ' TEST. 01:00 - 01:30 0.50 BOPSUR P ~— B PRE RD BOP TEST EQUIPMENT. FLOW WATER THROUGH GAS BUSTER I U -TUBE TO ENSURE IT IS FREE OF _ l OBSTRUCTIONS. RIGU P PRE HOLD PRE -SPUD MEETING WITH RIG CREW. 01:30 02:00 0.50 DISCUSS WELL OBJECTIVES AND KNOWN _ _ CHALLENGES. T 02:00 02:30 0.50 RIGU P PRE I HOLD PJSM ON RU INJECTOR AND PULL COIL ' ACROSS. 02:30 - 04:30 2.00 RIGU P PRE ! MU PACKOFF TO INJECTOR HEAD. SPOOL CABLE ONTO TUGGER TO PULL COIL THROUGH INJECTOR HEAD. PULL TEST ' GRAPPLE - GOOD. REMOVE WOOD, BANDING, CLAMP AND ' ! SHIPPING BAR FROM REEL. 04:30 - 05:15 0.75 RIGU P PRE PULL COIL ACROSS ROOF AND STAB INTO INJECTOR HEAD. CUT GRAPPLE OFF AND INSTALL NEW BOOT I ON ELINE. 05:15 - 07:00 1 1.75 RIGU P PRE SET INJECTOR BACK OVER CIRCULATION I HOLE AND FILL COIL, PUMPING AT 1 -BPM. 07:00 - 07:30 I 0.50 I BOPSUR ! I P I PRE COIL FULL - PJSM FOR TESTING INNER REEL ' - VALVE , BULKHEAD, AND STRIPPER 07:30 - 08:15 0.75 I BOPSUR P PRE I TEST TO 250 LOW AND 3500 HIGH - GOOD - ' PJSM FOR PUMPING SLACK OUT OF COIL 08:15 - 08:35 I 0.33 RIGU 1 P I I PRE PUMP OUT 368' OF CABLE FROM COIL - 24% L SLACK OR 38' OF EXCESS WIRE 08:35 08:50 0.25 RIGU P PRE I PJSM FOR MU BTT CTC AND BRING UP I I BAKER FISHING TOOLS Printed 5/25/2011 4:12:34PM . . , . ' North America - ALASKA -, BP Page 3 sii0:1:* . . fi . , peration Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER- ONSHORE (RON) , Start Date: 5/17/2011 I End Date: 'X3-00YPQ-C: (1,967,359.00 ) , 1 Project: Prudhoe Bay I S 1 ite: PB DS 15 I Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:OOAM 1 Rig Release: I Rig Contractor: NORDIC CALISTA I UWI: 500292263500 Active Datum: 66 : 48 5/30/1996 17:14 @66.70ft (above Mean Sea Level) Date I From - To Hrs Task Code I NPT ' NPT Depth Phase I Description of Operations (hr) , (ft) , — 08:50 - 09:15 0.42 RIGU P I PRE I INSTALL AND TEST BAKER CTC AND TEST: PULL 34k# - PSI 4000 1 09:15 - 10:05 0.83 RIGU P ' I PRE PJSM FOR PUMPING 3/4" BALL TO DRIFT COIL , I - PUMP BALL I 1005 - 11:30 1.42 RIGU P I ' PRE I RECOVER BALL W/ 64 BBLS PUMPED - , I CONDUCT RIG EVACUATION DRILL / AAR - 1 . ALL PERSONNELL RESPONDED TO MUSTER I I , , , , 1 AREA, INCLUDING ON SITE TRUCK DRIVERS I IN 2 MINUTES - AAR DISCUSSION BROUGHT TO LIGHT THAT WE ARE STILL WAITING ON DELIVERY AND INSTALLATION OF THE I ADDITIONAL RIG EVAC SIREN FOR THE 1 , LOWER LEVEL - TP WILL CHECK ON ETA 11:30 - 12:00 0.50 WHSUR I P I DECOMP 1PJSM W/BPV CREW FOR PULLING TWC AND - 1 UP THEIR TOOLS 12:00 - 14:45 2.75 WHSUR P DECOMP I RU LUBRICATOR AND TEST TO 250 LOW AND 3500 HIGH - OK - PULL TWC AND NOTE 180 PSI BELOW - LOAD OUT BPV TEST EQUIPMENT 14:45 - 15:00 0.25 KILLW P DECOMP I PJSM FOR BULLHEAD KILL OF WELL + - ,- 15:00 - 16:00 1.00 KILLW I P I DECOMP I BULLHEAD 5 BBLS MEOH FOLLOWED BY 180 BBLS KCL @ 4.5 BPM AND AVG PSI 2600# - IA PSI'D UP © 80 BBLS PUMPED AND THEN • , TRACKED PUMPING PRESSURE THE REST , . OF JOB 16:00 - 16:30 0.50 KILLW P f DECOMP ' TP 0# - IA90# - REMOVE NIGHT CAP AND FILL 1 1 HOLE W/4.5 BBLS FLUID I-- i 16:30 - 19:00 2.50 KILLW P DECOMP I MONITOR WELL TO ESTABLISH LOSS RATE - 1 +/- 8 BPH - GAS BUBBLING UP BUT HOLE , I I STILL TAKING NORMAL FILL - IA HOLDING , : 1 1-1 1 1©90# 19:00 - 19:30 0.50 KILLW P , -I DECOMP I HOLD RIG EVAC DRILL AND AAR. I 1 , , , I WELL WAS SECURED AND ALL PERSONNEL I 1 1 ON LOCATION RESPONDED CORRECTLY TO THE SECONDARY MUSTER AREA (SPOC , I 1 , 1 1 I TRAILER) DUE TO PREVAILING WIND 1 , DIRECTION. 1 , , ALL APPROPRIATE ALARMS AND , ANNOUNCEMENTS WERE MADE. 1 I I , I IT WAS NOTED THAT THERE WERE NO WIND 1 , 1 DIRECTION INDICATORS ON THE ODS OF THE RIG, SO THE SPILL SHACK WAS MOVED TO THE ODS OF THE RIG UNTIL MORE , WINDSOCKS COULD BE INSTALLED. ALSO, NO RIG CREW ROSTER WAS . , AVAILABLE IN THE SPOC TRAILER - WILL DISCUSS AT SLT MEETING. 19:30 - 21:00 I 1.50 PULL P , , DECOMP I HOLD PJSM WITH RIG CREW ON TESTING 1 , , 1DBPV. MU DBPV TO COIL CONNECTOR AND PRESSURE TEST. , : I , TEST TO 250-PSI LOW AND 2500-PSI HIGH. , I , , I HOLD AND CHART EACH TEST FOR 5-MINUTES. -GOOD TESTS. I I I MAINTAIN CONTINUOUS HOLE FILL DURING , , 1 1 TEST WITH 12-BPH LOSS RATE. Printed 5/25/2011 4:12:34PM North America - ALASKA - BP Page 440# e ration Summary Report . Common Well Name: 15 -48 AFE No Event Type: RE- ENTER- ONSHORE (RON) ' Start Date: 5/17/2011 End Date: X3- 00YPQ -C: (1,967,359.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:OOAM 1 Rig Release: Rig Contractor: NORDIC CALISTA 1 UWI_500292263500 Active Datum: 66 : 48 5/30/1996 17:14 @66.70ft (above Mean Sea Level) Date 1 From - To Hrs Task Code ' NPT NPT Depth Phase Description of Operations (hr) 1 _ (ft) 21:00 - 21:30 0.50 I PULL P DECOMP ' PU ON INJECTOR HEAD TO SEE HOW HIGH ABOVE RIG FLOOR IT COULD BE PICKED UP. ' AT MAX HEIGHT, BOTTOM OF PACKOFF TO RIG FLOOR = 10.5'. MU 3' LUBRICATOR EXTENSION TO BOTTOM 1 _LOF PACKOFF. 21:30 1.25 PULL P 22:45 DECOMP HOLD PJSM ON MU FISHING BHA. l, MU FISHING BHA CONSISTING OF: 4" GS h SPEAR, 3/4" DISCONNECT, OIL JAR, XO, 2 -EA 3 -1/8' DCS, XO, ACCELERATOR, DBPV, XO, C; 3 -JTS OF 2 -3/8" PH6 TBG, XO , LOCKABLE SWIVEL, XO, CTC. OAL = 180.46'. t t 22:45 - 00:00 1.25 PULL fi P — -� CTC A '' DECOMP i MU BHA TO CTC AND STAB INJECTOR ON TO I WELL. TOOK 8 -BBLS TO GET RETURNS. 1 [RIH WITH FISHING BHA AT 50 -FPM TO 2900'. 1 1 ; CIRCULATE AT .8 -BPM WITH 300 -PSI. 5/20/2011 f 00:00 - 00:30 ', 0.50 PULL P 1 DECOMP HOLD KICK WHILE TRIPPING DRILL WITH RIG CREW. ALL CREW MEMBERS RESPONDED I CORRECTLY. 1 REVIEW NORDIC KICK WHILE TRIPPING ' CREW ROLES AND RESPONSIBILITIES AND COMPARE TO ADW "WELL CONTROL OPERATIONS STATION BILL ". 00:30 - 00:50 0.33 PULL P DECOMP CONTINUE TO RIH WITH FISHING BHA FROM 2900' TO 3900' WT CHECK AT 3900': PU WT = 25K -LBS, SO — WT = 10K -LBS. 00:50 - 01:15 0.42 t PULL P DECOMP ! HOLD PJSM ON FISHING LINER AND 1 11 I CIRCULATING WELL. DISCUSS POSITIONS OF PEOPLE, 1 POTENTIAL FOR VENTING GAS AND 1 I IMPORTANCE OF COMMUNICATION DURING FISHING/CIRCULATING OPERATIONS. RIG CREW INSPECT TIGER TANK, TAKE STRAP AND BLOW DOWN LINE TO TIGER { TANKTO ENSURE CLEAR. r 01:15 - 03:00 1.75 PULL P DECOMP I CONTINUE TO RIH SLOWLY FROM 3900' TO TAG LINER TOP AT 4036' (19' DEEP). SET DOWN 5K -LBS TO ENGAGE GS SPEAR. BEGIN WORKING PIPE, STAGING UP PULLS UNTIL JARS BEGIN HITTING WITH 20K -LB ' OVERPULLS. FOLLOW EACH JAR HIT WITH A STRAIGHT PULLS FROM 40K -LBS OVER TO 55K -LBS OVER. REPEAT SEQUENCE 15 TIMES, STAGING UP JAR HITS TO 30K -LBS 1 OVER. LINER PULLS FREE AND BEGINS TO 'MOVE UP HOLE AT 78K -LBS. I POH TO 4000'. Printed 5/25/2011 4:12:34PM ' BP Pag 5 ot"1' North America - ALASKA peration Summary Report Common Well Name: 15 -48 AFE No Event Type: RE- ENTER- ONSHORE (RON) ; Start Date: 5/17/2011 I End Date: 'X3- 00YPQ -C: (1,967,359.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292263500 Active Datum: 66 : 48 5/30/1996 17:14 @66.70ft (above Mean Sea Level) Date From - To 1 Hrs Task Code I NPT 1 NPT Depth Phase Description of Operations I (hr) DECOMP (ft) 03:00 04:45 1.75 PULL P ' ESTABLISH CIRCULATION AT 1 -BPM WITH I 1 700 -PSI. LOSS RATE = 12 -BPH. STAGE PUMP UP TO 1.5 -BPM WITH 1500 -PSI .AND CBU X 1.5. WHILE CIRCULATING, MOBILIZE EQUIPMENT ' FOR LD 3 -1/2" LINER TO RIG FLOOR. I 'WITH 37 -BBLS AWAY, DIVERT FLUID TO 1 TIGER TANK TO AVOID ANY GAS RETURNS 1 1 INSIDE RIG. TAKE 42 -BBLS OF FLUID TO 'TIGER TANK. 1 I WHEN DENSITY RETURNS TO 8.4 -PPG, TAKE I RETURNS BACK INTO PITS. LOSS RATE CONTINUES TO BE 12 -BPH. 04:45 - 05:00 0.25 PULL P DECOMP TAKE ON 8.4 -PPG 2% KCL FROM VAC TRUCK. TO BRING PIT VOLUME UP TO 300 -BBLS. 160 -BBLS REMAINS ON VAC TRUCK. CONTINUE TO CIRCULATE AT 1.5 -BPM WITH ' _ 11560 -PSI. — —1 — 05:00 - 07:00 2.00 PULL P DECOMP 1 POH FROM 4000' WITH FISHING BHA AND 1 3 -1/2" SCAB LINER AT 50 -FPM. PULLING SLIGHTLY HEAVY WHILE POH. ' CIRCULATE AT 1.3 -BPM WITH 1000 -PSI. LOSS 1 RATE = 12 -BPH. IA PRESSURE = 500 -PSI. HOLD 200 -PSI BACK PRESSURE TO LIMIT I SWABBING POTENTIAL. 1 FLOW CHECK WELL BEFORE UNSTABBING INJECTOR - NO FLUID MOVEMENT. 07:00 - 08:00 1.00 PULL P I T DECOMP HOLD PJSM ON LD FISHING BHA & LINER. STAND INJECTOR HEAD BACK ON LEGS. , RU FALSE TABLE AND EQUIPMENT FOR LD I I 3 -1/2" SCAB LINER. _ LOSS RATE — 6 TO 10 -BPH. 08:00 09:00 1.00 PULL P DECOMP 'PULL & LD FISHING BHA. — — 09 :00 10:30 1.50 PULL P DECOMP RU RIG FLOOR AND HANDLING EQUIPMENT FOR LD 3 -1/2" 13CR80 STL SCAB LINER. DISCUSS FLUID MANAGEMENT PLAN AND , DECIDE TO FILL THE WELL BY FILLING LINER , AND DOWN LNR X TBG ANNULUS EVERY I 20- MINUTES OR 5 -JTS PULLED TO MAINTAIN i 1 I 300 -PSI OVERBALANCE. 10:30 - 11:00 0.50 PULL P DECOMP I HOLD AAR ON MORNING'S ACTIVITIES AND PJSM ON LD 3 -1/2" SCAB LINER. 11:00 12:00 1 1.00 PULL I P 1 , DECOMP POH AND LD 10 -JTS OF 3 -1/2" 9.2# 13CR80 1 STL LINER. FILL LINER AND DOWN LNR X TBG ANNULUS EVERY 20- MINUTES OR 5 -JTS PULLED. SLB INSTALLS CTPID ON HORSE'S HEAD TO CONTINUOUSLY MONITOR CT INTEGRITY. 12:00 - 13:00 1.00 I PULL I P DECOMP I BRING ON MORE 8.4 -PPG 2% KCL TO PITS ' AND MONITOR WELL. 1 LOSS RATE = 8 TO 10 -BPH. 13:00 16:30 3.50 PULL I P DECOMP 1CONTINUE TO POH AND LD 40 -JTS OF 3 -1/2" , 9.2# 13CR80 STL LINER. 1 FILL LINER AND LNR X TBG ANNULUS EVERY 5 JTS OR 20- MINUTES. LOSS RATE j FLUCTUATING BETWEEN 8 AND 12 -BPH. I NO TIGHT SPOTS NOTED. NO SCALE OR _ BUILDUP ON EXTERIOR OF LINER. 16:30 - 17:00 I 0.50 PULL P I DECOMP UNLOAD PIPE SHED AND MONITOR WELL. 1 . LOSS RATE = 4 TO 10 -BPH. Printed 5/25/2011 4:12:34PM North America - ALASKA - BP Page 6 ofd Ee ratiort Summary Report Common Well Name: 15 -48 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 5/17/2011 End Date: X3- 00YPQ -C: (1,967,359.00 ) y Project: Prudhoe Bay l Site: PB DS 15 Rig Name /No.: NORDIC 2 I Spud Date/Time: 11/14/2005 12:00:OOAM I Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292263500 Active Datum: 66 : 48 5/30/1996 17:14 @66.70ft (above Mean Sea Level) Date From - To Hrs Task ' Code I NPT 1 NPT Depth Phase , Description of Operations 17:00 - 18:00 1.00 PULL P DECOMP r� � (ft) HOLD KICK WHILE TRIPPING DRILL WITH ' , WSLS, WELL CONTROL AUDITOR AND RIG CREW. HOLD AAR TO DISCUSS DRILL. SOME I I C HALLENGES WERE NOTED WITH REGARD 1 , TO CROSSOVER HANDLING AND PICKING UP I THE SAFETY JT. 18:00 19:30 1.50 PULL P DECOMP I PERFORM CREW CHANGE. DURING HOLE FILL OPERATIONS, EXCESSIVE FOAMING OF THE KCL DUE TO 1 , SAFE -LUBE WAS SEEN. ADD DEFOAMER TO PITS AND FLUID IN LINER. LOSS RATE IS 10 TO 12 -BPH. 19:30 - 20:00 0.50 PULL P DECOMP HOLD PJSM ON CONTINUE TO POH AND LD 3 -1/2" LINER. I DISCUSS PROPER HOLE FILL AND PIPE HANDLING TECHNIQUES. 20:00 21:30 1.50 PULL P DECOMP DURING INSPECTION OF 3 -1/2" HANDLING EQUIPMENT, DISCOVER THAT DOG COLLAR NEEDED TO BE RE- DRESSED AND THAT ', SLIP -TYPE ELEVATORS HAD SUSTAINED DAMAGE TO THE SETTING PLATES AND ' RETENTION WIRES (MOST LIKELY WHEN j HANDLING SAFETY JOINT). REDRESS DOG COLLAR. DISCUSS PIPE HANDLING OPTIONS WITH CTD SUPT AND TOOLPUSHER. RECIEVE APPROVAL TO PROCEED USING FLAT -TOP ELEVATORS AND BP OWNED LIFTING EYES. CHANGE OUT ELEVATORS AND VERIFY INSPECTION CERTIFICATION OF BP -OWNED LIFTING EYES. — LOSS RATE = 10 TO 12 -BPH. ' 21:30 - 00:00 2.50 PULL P DECOMP (ONTINI IF TO POH AND I D 25 - .ITS 3 - 1/2" G 2 13CR80 STL LINER (75 -JTS TOTAL LD AT I 1 0000 -H RS) FILL LINER AND LNR X TBG ANNULUS EVERY 5 -JTS OR 20- MINUTES. LOSS RATE = 10 TO I 112 -BPH. TREAT WITH DEFOAMER AS NEEDED. NO TIGHT SPOTS NOTED WHILE PULLING LINER. NO SCALE OR FILL SEEN ON EXTERIOR OF LINER. 5/21/2011 00:00 - 02:45 2.75 PULL P ' DECOMP CONTINUE TO POH AND LD 25 -JTS 3 -1/2" 9.2-# 113CR80 STL LINER (100 -JTS TOTAL LD) FILL LINER AND LNR X TBG ANNULUS EVERY 15 -JTS OR 20- MINUTES. LOSS RATE = 10 TO I 12 -BPH. TREAT WITH DEFOAMER AS NEEDED. NO TIGHT SPOTS NOTED WHILE PULLING LINER. VERY LIGHT SCALE SEEN STARTING ON JT #95 LAID DOWN. 02:45 - 03:15 0.50 PULL I P DECOMP REMOVE 50 -JTS OF 3-1/2" LINER FROM PIPE SHED. I FILL WELL - LOSS RATE = 10 -BPH. -- - - - - -- - - - - - 03:15 06:00 2.75 PULL P DECOMP CONTINUE TO POH AND LD 25 -JTS 3-1/2" 9.2-# I 1 13CR80 STL LINER (125 -JTS TOTAL LD) , !FILL LINER AND LNR X TBG ANNULUS EVERY I 15 -JTS OR 20- MINUTES. LOSS RATE = 10 TO I I 12 -BPH. Printed 5/25/2011 4:12:34PM • Page 7 0 North America - ALASKA - BP , 3 erati ©n Summary Report Common Well Name: 15 -48 I AFE No Event Type: RE- ENTER- ONSHORE (RON) ' Start Date: 5/17/2011 ' End Date: I X3- 00YPQ -C: (1,967,359.00 ) Project: Prudhoe Bay t Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date /Time: 11/14/2005 12:00:OOAM I Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292263500 Active Datum: 66 : 48 5/30/1996 17:14 @66.70ft (above Mean Sea Level) Date From - To ' Hrs Task Code 1 , NPT NPT Depth Phase I Description of Operations I— (hr) = (ft) 06:00 10:00 4.00 PULL I P 1 I DECOMP CREW CHANGE -PJSM AND CONTINUE TO . ! POOH AND LD TOTAL OF 165 JTS OF 3 ! 1/2 "9.2# 13CR80 STL LINER - PIPE IN EXCELLENT SHAPE WITH VERY LITTLE LIGHT 1 SCALE (PICTURES ATTACHED) - LOSS RATE STABLE AT 10 - 12 BPH 1 10:00 - 11:00 1.00 PULL 1 P DECOMP I PJSM- LOAD OUT LINER, TOOL SERVICE j CHECKED PIPE FOR NORM: NONE I IDETECTED - CLEAN RIG FLOOR - CHECK 1 'TORQUE OF BOLTS ON TREE: OK 11 :00 - 12:00 1.00 CLEAN P I WEXIT , PJSM- PU DUMMY WHIPSTOCK / NOZZLE 1 I i BHA W/ 3.70" DRIFT RING ON BTM - TOTAL 1 —' LENGTH OF 103.13' ' 12:00 - 15:45 3.75 CLEAN P 1 I WEXIT !PU AND STAB INJECTOR - START RIH @ 85 1 FPM - 100 PSI, IN .38, OUT .78, IA 319 #, OA 2# - 1 TAG TOL @ 8905 UNCORRECTED - — — — — _ — - CIRCULATE 130 BBLS AT 3 BPM 15:45 - 18:00 2.25 CLEAN P I WEXIT I POOH W/ DUMMY WHIPSTOCK BHA PUMPING 13 BPM - IA = 337, OA = 5 - TAG UP AT SURFACE AND FLOW CHECK WELL 18:00 - 19:45 1.75 ! CLEAN P I WEXIT HOLD PJSM ON LD DUMMY WHIPSTOCK BHA. LD DUMMY WHIPSTOCK BHA 19:45 - 20:15 0.50 CLEAN P ' j WEXIT 'CLEAR RIG FLOOR OF UNNECESSARY TOOLS. BRING ON MORE 8.4 -PPG 2% KCL. ' _ BRING WHIPSTOCK INTO PIPE SHED. 20:15 - 20:30 0.25 WHIP P WEXIT I HOLD PJSM ON SLACK MANAGEMENT OPERATIONS. I DISCUSS ORDER OF OPERATIONS, POSITIONS OF PEOPLE, HANDLING CUT COIL AND MANAGING LOSSES TO FORMATION WHILE PUMPING SLACK. 20:30 00:00 ! 3.50 WHIP P WEXIT I REBOOT COIL. STAB ON INJECTOR, CLOSE SWAB VALVE IAND REVERSE CIRCULATE E -LINE INTO COIL 'AT 3 -BPM. OPEN SWAB VALVE AND CHECK FOR PRESSURE = ON VAC. I I UNSTAB INJECTOR AND CUT OFF BTT CTC. RU CT CUTTER TO LUBRICATOR AND CUT 240' OF COIL (LEAVES 1.74% E- LINE SLACK). RD CUTTER. SET INJECTOR OVER CIRCULATION HOLE ! AND PUMP SLACK FORWARD. ' BHI PERFORM MEG TEST ON WIRE - 1 53 -OHMS = GOOD TEST. ' MAINTAIN CONTINUOUS HOLE FILL WHENEVER POSSIBLE. LOSS RATE = 8.5 -BPH. 5/22/2011 -- - -- - - - -- ' - -- 00:00 - 01:00 1.00 I WHIP ' P WEXIT INSTALL SLB DIMPLE STYLE CTC. ' PULL TEST TO 40K -LBS - G000 TEST. 01:00 - 02:00 ' 1.00 WHIP P ' WEXIT HEAD UP BHI TOOLS. TEST CONDUCTIVITY OF E -LINE - GOOD _ TEST. 02:00 - 03:30 1.50 WHIP I P ! WEXIT !PRESSURE TEST SLB CTC TO 3500 -PSI. 1 GOOD TEST. 1 PRESSURE TEST BHI DBPV TO 250 -PSI LOW / 3500 -PSI HIGH. HOLD AND CHART EACH TEST FOR 5- MINUTES. GOOD TESTS. RD TEST EQUIPMENT. Printed 5/25/2011 4:12:34PM • North America - ALASKA - BP ` Page 8 c1=# I eration Summary Report Common Well Name: 15 -48 v I AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 5/17/2011 I End Date: I X3- 00YPQ -C: (1,967,359.00 ) ( Project: Prudhoe Bay ! Site: PB DS 15 Rig Name /No.: NORDIC 2 1 Spud Date/Time: 11/14/2005 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA I UWI: 500292263500 Active Datum: 66 : 48 5/30/1996 17:14 @66.70ft (above Mean Sea Level) Date From - To Hrs Task I Code I NPT NPT Depth Phase ' Description of Operations , (hr) I (ft) 03:30 - 04:00 0.50 WHIP 1 P WEXIT HOLD PJSM ON MU WHIPSTOCK BHA. DISCUSS ORDER OF COMPONENTS, I HANDLING CONSIDERATIONS AND THE ' I ABILITY TO REMOVE THE ENTIRE BHA FROM THE WELL IN A WELL CONTROL SITUATION. MU WHIPSTOCK SETTING BHA. SCRIBE WHIPSTOCK TO HOT. BHA CONSISTS OF 3 -5/8" KB PACKER WHIPSTOCK, HYD SETTING TOOL, XO, HOT, , DGS, DPS, EXC, POWERCOMMS, WEAR SUB, LQC, UQC, XO AND SLB CTC. OAL = 79.20'. 04 :00 - 06:10 2 WHIP P IA A N R . I WEXIT i MU COIL TO BHA AND STAB ON INJECTOR. r- - - - - 1 -- - -' I [OPEN EDC. IRIH WITH WHIPSTOCK, CIRCULATING ACROSS THE TOP OF THE WELL TO L MAINTAIN RETURNS. 1 06:10 - 07:00 0.83 WHIP P WEXIT PAR @ 8615 FOR TIE -IN 07:00 - 08:00 r 1.00 WHIP r P 1 WEXIT CORRECTED DEPTH TO 8678.003 / -30' CORR I - PULL UP HOLE TO 8398 TO CCL LOG 08:00 - 08:30 0.50 WHIP P WEXIT I PARKED @ 8866 CORRECTED DEPTH = BTM OF WHIPSTOCK / 8850' =TOP OF WHIPSTOCK , / 0 DEGREE HS - SHUT EDC - PSI TO 570# I AND SLIPS SET - PSI TO 1600# AND SEE ' SHEAR - SET 7000# ON PACKER / HOLDING - STRAIGHT PULL UP TO GET BOTTOM OF ROD I ' I I 10' ABOVE TRAY - CLEAN PICK UP - CT WT WHIP 43000# 08:30 - 08:50 0.33 P 1 WEXIT RU TO TEST TBG / IA / WS PACKER - PSI TO 1000# AND HOLD FOR 10 MINUTES - SOLID ,TEST / IA UP TO 1140 AND HOLDING STEADY ALSO _ 08:50 - 10:00 1.17 WHIP P WEXIT POOH W/ WHIPSTOCK SETTING ASSEMBLY 10:00 - 10:15 0.25 WHIP P WEXIT TAG AT SURFACE -PJSM FOR HANDLING BHA 10:15 - 11:30 1.25 WHIP P WEXIT FLOW CHECK WELL AND LAY DOWN BHA 1.00 PJSM - WORK ON TOOLS AND MAKE UP - 14:15 1.75 STWHIP P WEXIT !MILLING BHA - -- 12:30 - - - - -- - -- - - - -- i STWHIP I WEXIT P ' i RIH W/ MILLING BHA CONSISTING OF: 3.8" I WINDOW MILL, 3.8" DSM, 2 -7/8" EXTREME MTR, XO, 2 -JTS 2 -3/8" PH6 TBG, XO BLIND SUB, DGS, DPS, EDC, POWER & COMMS, WEAR SUB, LQC, UQC, XO, CTC. OAL = 118.57' 14:15 - 14:40 0.42 STWHIP P WEXIT TIE IN @ 8715' / - 25.5' CORRECTION - CONTINUE TO BOTTOM 14:40 18:00 3.33 STWHIP P WEXIT TAG TOP OF WHIPSTOoK AT 8850' - BEGIN TIME MILLING WINDOW @ 1' /HR @ 3025PSI / 310# DHWOB / 2.561N / 2.6 OUT WHILE ' I DISPLACING KCL WITH USED POWER PRO / IA811 # -OA4# �f 18:00 19:45 1.75 STWHIP P � WEXIT CONTINUE TO MILL WINDOW AT 1' /HR WITH +' ' 8.8 -PPG POWERPRO TO 8852.9'. ` y RUNNING 2500 -LBS WOB AND 300 -PSI MOTOR WORK. SLIGHT GAIN NOTICED IN SURFACE MUD I VOLUME - MUD APPEARS TO BE AIRED UP AND AGITATORS MAY BE CAUSING FLUCTUATION IN TOTCO READINGS. Printed 5/25/2011 4:12:34PM WELLHEAD = FMC • 1 I R NR ** ORIGINAL W ELLBORE & * 3 ACTUATOR = BAKER C DRLG DRAFT 1 5 15 -48A NOT SHOWN BELOW XO @ 9418' ** KB. ELEV = 66.7' BF. ELEV = _; note: failed PPPOT -T - - KOP= 9495' TxIA comm thru holes in tubing Max Angle = 94 @ 11907' I 2184' H4 -1/2" HES HXO SVLN SSSV NIP, ID = 3.813" I Datum MO = 9290' Datum TVD = 8800' SS 19 -5/8" CSG, 40#, L -80, BTC-M XO NSCC H 3461' I— 1 9 -5/8" CSG, 40#, L -80, NSCC, ID = 8.835" I--I 3548' ' GAS LIFT MANDRELS ST MD TV D DEV TYPE VLV LATCH PORT DATE 1' 3677 3675 1 KGB2 -LS DMY INT 0 12/11/10 2' 6288 6284 5 KGB2 -LS DMY" INT 0 07/20/03 13.70" BOT LNR DEPOY SLV, ID = 3.000" I—I 3901' I— 1 3' 8237 8059 34 KGB2 -LS DMY" INT 0 03/10/96 =4 • MANDRELS REQUIRE MODIFIED LATCH I BKR KB LTP, ID = 2.45" H 3907' I BEHIND PIPE • hole 6660' MD Minimum ID = 2.37" @ 8774' hole 6795' MD BKR KB LTP & SEAL STINGER w/ LOC X ■ 8306' Hr X 4-1/2" BKR S -3 PKR, ID = 3.875" I I 8329' H4- 1 /2 " HESX NIP, ID = 3.813" I BEHIND 7" CSG, 26 #, L -80, BTC-M XO 29 #, L -80, BTC-M H 8139' (— PIPE 4-1/2" TBG, 12.6#, L -80. NSCT, — 8341' I"� ..m 8 341' I - 7" X 4-1/2" TM/ LNR PKR .0152 bpf, ID = 3.958" & HYDRO HGR, ID = 3.915" 17" CSG, 29#, L -80, BTC-M, ID = 6.059" H 8554' I • TSGR: 8496' MD I3 -1/2 LNR. 9.2#, 13CR -80, STL, .0087 bpf, ID= 2.992" I—I 8810' I— TCGL: 8800' MD BCGL: 8875' MD - Pull existing patch - Highside, Zone 3 Exit, 34 degs — 8774' - 3.7" deployment sleeve / 4.5" KB LTP - Rerun patch ' 8806' - TOL /TOC I ESTIMATED TOP OFCEMENT H 8884' 951 - 3 -3/16' x 2 -7/8" xo 11911' - PBTD 13-1/2" LNR, 8.81 #, L -80, STL, .0087 bpf, ID = 2.867' H 8942' I E —__ -- y (WHIPSTOCK (11/15/05) I 9195' _""" 11946' - TD IRA PIP TAG H 9204' ` - 8850' - 4-1/2'" packer whipstock .-• c 8879' I 3.7" LNR SLV & BKR HYDRO SET I RETRIEVABLE PKR, ID = 2.560" PERFORATION SUMMARY 8889' I BOT 3" SEAL STINGER & REF LOG: MWD/ GR/ ON 5/29/20011 LNR DEPLOY SLV, ID = 2.355" ANGLE AT TOP PERF: 89° 10220' 8910' I 3-1/2" HOWCO X NF, ID = 2.813" Note: Refer to Production DB for historical perf data I 8942' H3-1/2" X 3- 3/16" XO, ID = 2.786" I SIZE SPF INTERVAL Opn/Sgz DATE 2" 6 10220 -10270 0 06/01/11 MILLOUT WINDOW (15 -48B) 9195' - 9203' I 2" 6 10430 -10770 0 06/01/11 2" 6 10810 -10900 0 06/01 /11 \ 3- 3/16" LNR, 6.2 #, L -80, TC-II, --I 9390' I — 3- 3/16" X 2 -7/8" XO, 2" 6 11100 -11170 0 06/01/11 .0076 bpf, ID = 2.80" ID = 2.377" 2" 6 11210 -11400 0 06/01/11 11506' PBTD 2" 6 11490 -11560 0 06/01/11 2" 6 11650 -11790 0 06/01/11 ' NI 2-7/8" LNR, 6.16#, L -80, STL, .0058 bpf, ID= 2.441" H 11542' I 2" 6 11850 - 11900 0 06/01/11 TD — I 11646' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/28/96 ORIGINAL COMPLETION WELL: 15 - 48C 02/23/03 JLM /KK CTD SIDETRACK (15 -48A) PERMIT No: 5051660 11/26/05 NORDICI CTD SIDETRACK (15 -48B) API No: 50- 029 - 22635 -02 06/05/11 NORDIC2 CTD SIDETRA CK (15 -48C) SEC 22, T11 N, R14E, 2967.84' FEL & 1006.73' FNL BP Exploration (Alaska) • • SMITE DIF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 John McMullen b(p Engineering Team Leader !� a BP Exploration (Alaska), Inc. O� P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field , Prudhoe Bay Oil Pool, PBU 15 -48B Sund ry Number: 311 -059 MAR 32011 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. r !F K. No . Corn ' -'oner DATED this 3 day of March, 2011. Encl. STATE OF ALASKA REE Ci.rll \i lZ�� /i ' ALASKAL AND GAS CONSERVATION COMMIS41/4 FEB 2 8 2Oli - 1-//-1 / '' APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Comtntisstor 1. Type of Request: Anchorage ❑ 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. IS Development ❑ Exploratory 205 - 166 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 029 - 22635 - 02 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU I5-48B Spacing Exception Required? ❑ Yes 0 No 9. Property Designation: 10. Field / Pool(s): ADL 028306 - 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 ND (ft): Plugs (measured): Junk (measured): 11646 - 8939- 11506 8934 - None None Casing Length Size MD ND Burst Collapse Structural Conductor 114' 20" 114' 114' 1490 470 Surface 3514' 9 -5/8" 3548' 3546' 5750 3090 Intermediate 8522' 7" 8554' 8324' 7240 5410 Production Liner 854' 4 -1/2" 8341' - 9195' 8146' - 8844' 8430 7500 Liner 2663' 3 -1/2" x 3 -3/16" x 2-7/8" 8879' - 11542' 8597' - 8935' Scab Liner 4867' 3 -1/2" 4010' - 8877' 400T - 8595' 10160 10530 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10820' - 11500' 8923' - 8934' 4 - 1/2 ", 12.6# L - 80 8341' Packers and SSSV Type: 7" x 4 Baker 'S - packer; Packers and SSSV 8306' / 8117' 7" x 4 TIW Liner Packer MD (ft) and ND (ft): 8341' / 8146' 12. Attachments: 13. Well Class after proposed work: 0 Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory -1E1 Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 10, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR - Abandoned Commission Representative: ❑ WAG ❑ SPLUG - IffSuspended 4i 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Staudinger, 564 -5733 Printed Name J tidit 4 Title Engineering Team Leader /P ' ' Prepared By Name/Number Signatur: Phone 564 -4711 Date ' 25 / Terrie Hubble, 564 -4628 Commission Use Only / / -'-- 0 50( Conditions of approval: N'tify Commission so that a representative may witness Sundry Number !L-� ❑ Plug Integrity le BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance * 35m ps- £o' 7j.5 Other: A. 2S6,5 psi, /4 nn J as �"',, 1 r ' �''• - A / rbt . il / /t«.., - A. , , ,ode , fre 20 ,4,4e- z s M. C i) Subsequent Form Required: / O _ Yo 7 401 APPROVED BY Approved By: ( u MMISSIONER THE COMMISSION Date 8 -3--- /( Fol9�vi d 01 /2010 3 , . lf ! Submit In Duplicate �3 O3 Z4 ) \\ 0 � i � ORIGINAL . . To: Alaska Oil & Gas Conservation Commission From: Mark Staudinger CTD Engineer 0 b P Date: February 21 2010 Re: 15-48B Sundry Approval Sundry approval is requested to abandon existing perforations on well 15-48B in preparation for a Coiled Tubing Drilling Sidetrack. Well 15-48B is a coil sidetrack drilled in Nov 2005. The well was completed with a 620' of perforations in Zone 1A. The 3 -1/2" liner top was extended up to 4010' MD to cover known tubing holes at 6660' and 6795' MD and restore integrity. The well came on and remained fulltime until June 2006 when it hit LP MGOR. The well was then swapped to HP service and cycled near /at MGOR. In July 2009, 175' of perforations were added in Zone 1A. There was a small oil buzz, but the well was shut -in for high GOR within , weeks. After being shut -in for a year, 15-48B was POP'ed in Oct 2010 and quickly reached max GOR. The well is currently shut -in. Reason for Sidetrack: 15-48B is no longer a competitive producer, and there are no remaining wellwork options. The proposed sidetrack will access a -50 -acre target in southwest DS 15. The well is in sound mechanical condition. It passed an MIT -IA to 3000 psi (December 2010) and the MIT -OA passed to 2000 psi (December 2010). A tubing calliper was ran (December 2010) from 3,677' to surface and found the tubing to be in good to fair condition with a maximum recorded wall penetration of 39 %. A tubing patch was ran during a CTD sidetrack in November 2005 to patch holes in the 4 -1/2" tubing at 6660' and 6795'. The tubing patch consists of 3 -1/2 ", 8.81 #, 13Cr -80, STL from 8876' to 4010' MD. The sidetrack, 15 -48C, is scheduled to be drilled by Nordic 2 starting on April 15 2011 targeting Ivishak Zone 1A/1 B. The pre rig work includes pulling the LTP from the scab liner. The coiled tubing drilling rig Nordic 2 will then pull the 3 -1/2" scab liner and set a 4 -1/2" packer whipstock at 8,860' and to allow a kick off in Zone 3. The window will be milled, and the rig will then land and drill 3230 ft of Zn 1A/1 B lateral via 12 DLS. The well will be ' completed with 3- 3/16" x 2 -7/8" solid, cemented, and perforated liner. Finally, the 3 -1/2" scab liner will be re -run. The following describes the planned work. A schematic diagram of the proposed sidetrack is attached for reference. CTD Sidetrack Summary Pre -CT Rig Work: The pre CTD work is planned to begin March 10 2011. 1. W Check tubing hanger LDS. 2. W PPPOT -T to 5000 psi 3. S Dummy off GLM 4. D MIT -IA to 3000 psi, MIT -OA to 2000 psi. 5. S Drift and pull LTP. 6. V PT tree (MV,SV,WV) 7. D Bleed wellhead pressures down to zero. 8. D Bleed production flow lines and GL lines down to zero and blind flange. 9. 0 Remove wellhouse, level pad. a! P // her e� % i/ 64riex Ise tor. Tic 'veil O�� ivl' can ,$ ca�'ca ioc�fvC,� 1 J q v 4� rtie 60A i "S eat' 7?°°° scP 1 whi,1C (vov/c/ /fool r0 fits /•or,• fir► »Pe qpd r efir the 4► €11 ww/d Cbq ,, 4rlr A»/e. J`O % n creo , at,'/j+vr Arch*, /01 f pyr of rif pot, fi de t roe // ro o Cr, 4044 :' Un /vadtr drg14 A 'worn Si r(r Poo/ %odd r i ' Or' v ie Aar lrCrhve,. • • Rig Sidetrack Operations: (Scheduled to begin on April 15 2011 using Nordic Rig 2) 1. MIRU Nordic Rig 2 611/4 2. NU 7- 1/16" CT Drilling BOPE and test 3. Pull Scab Liner 4. Drift and Caliper Tubing 5. Set 4W packer whipstock. 6. Mill 3.80" single string high side window in the 4% liner at 8860'. 7. Drill 12 DLS lateral sidetrack with 4 -1/8" bi- center bit in Zone 1A/1B to a final TD of 12,090' md. 8. Run and cement 3- 3/16" x 2 -7/8" L -80 liner leaving TOL/TOC '-30' inside window. 9. Perform cleanout/log run with mill, motor, and MCNL 10. Perforate well. 11. Run Liner Top Packer. JUG 12. Re -run Scab Liner and packer. t. r ‘°1-1) 13. Freeze protect well to 2200' ND. i 14. Set BPV. ND 7- 1/16" BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. S -y 15. RDMO Nordic 2. Post -Rig Work: 1. Re- install S- riser, wellhouse and FL's 2. Pull BPV. 3. Install GLV. 4. RU PBGL. 5. RU test separator. Mark Staudinger Coiled Tubing Drilling Engineer 564 -5733 CC: Well File Sondra Stewman /Elizabeth Barker/Terrie Hubble • TREE= CM/ WELLHEAD = FMC S 15 4 8 B SAFETY ES: WELL ANGLE > 70° @ 9200' * ** 3 ACTUATOR = BAKER C 1/2" CH LNR*** ORIGINAL WELLBORE & KB. ELEV = 66.7' 15-48A NOT SHOWN BELOW XO @ 9418' * ** BF. ELEV KOP = 9495' Max Angle = 96 @ 10807' Datum MD = 9233' ® I 2184' H 4 -1/2" HES HXO SVLN SSSV NIP, ID = 3.813" Datum TVD = 8800' SS 9 -5/8" CSG, 40 #, L -80, BTC-M XO NSCC H 3461' r 19 -5/8" CSG, 40 #, L -80, NSCC, ID = 8.835" I 3548' 1J GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1* 3677 3675 1 KGB2 -LS DMY INT 0 12/11/10 I BKR KB LTP & SEAL STINGER w / LOC, ID = 2.350" H 4010' _ _ 2* 6288 6284 5 KGB2 -LS DMY ** NT 0 07/20/03 3* 8237 8059 34 KGB2 -LS DMY ** INT 0 03/10/96 13.70" BOT LNR DEPOY SLV, ID = 3.000" H 4017' * MANDRELS REQUIRE MODIFIED LATCH ** BEHIND PIPE 13.70" X 3 -1/2" XO, ID = 2.990" H 4022' Minimum ID = 2.35" @ 4010' BKR KB LTP & SEAL STINGER w/ LOC ► _ 8306' H7" X4 -1/2" BKR S-3 PKR, ID= 3.875" I 1 8 329' H 4 -1 /2" HES X NIP, ID = 3.813" I 17" CSG, 26#, L -80, BTC-M, XO 29 #, L -80, BTC-M 1-1 8139' 1- I BEHIND PIPE 4-1/2" TBG, 12.6 #, L -80, NSCT, -I 8341' ►�� 8 341' J-f 7" X 4-1/2" TM/ LNR PKR .0152 bpf, ID = 3.958" & HYDRO HGR, ID = 3.915" 17" CSG, 29 #, L -80, BTG-M, ID = 6.059" H 8554' I 8874' I-13-1/2" X 2 -7/8" XO, ID = 2.370" I I3 -1/2 LNR, 9.2 #, 13CR -80, STL, .0087 bpf, ID = 2.992" I 8874' I- 8876' I- I2 -7/8" SEAL ASSY, ID = 2.360" I 8879' I 3.7" LNR SLV & BKR HYDRO SET ►= RETRIEVABLE PKR, ID = 2.560" I ESTIMATED TOP OF CEMENT H 8884' 4 X 8889' I- BOT 3" SEAL STINGER & .., -4 LNR DEPLOY SLV, ID = 2.355" 13 -1/2" LNR, 8.81 #, L -80, STL, .0087 bpf, ID = 2.867" I 8942' 4 1 8910' I- I3 -1/2" HOWCO X NIP, ID = 2.813" •� •1 • � � A 8942' H3-1/2" X 3 -3/16" XO, ID = 2.786" I pax WHIPSTOCK (11/15/05) I 9195' .. �� in1•S MILLOUT WINDOW (15 -48B) 9195' - 9203' IRA PIP TAG H 9204' ' i; PERFORATION SUMMARY • REF LOG: MWD/ GR/ ON 11/15/05 A ANGLE AT TOP PERF: 64° @ 9250' t y ■ 1 9390' I- 3- 3/16" X 2 -7/8" XO, Note: Refer to Production DB for historical perf data • • * • ** ID = 2.377" SIZE SPF INTERVAL Opn /Sqz DATE A OA ` 2" 6 9250 - 9300 0 07/16/09 2" 6 9410 - 9485 0 07/16/09 3- 3/16" LNR, 6.2 #, L -80, TC-II, H 9390' I 2" 6 9550 - 9600 0 07/16/09 .0076 bpf, ID = 2.80" ` 2" 6 10820 - 11200 0 11/25/05 ` 11506' -I PBTD I 2" 6 11230 - 11450 0 11/25/05 2" 6 11480 - 11500 0 11/25/05 12 -7/8" LNR, 6.16 #, L -80, STL, .0058 bpf, ID = 2.441" I 11542' TD --I 11646' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/28/96 ORIGINAL COMPLETION 07/26/09 TTR/PJC PERFS (07/16/09) WELL: 15 -48B 02/23/03 JLM /KK CTD SIDETRACK (15 -48A) 09/28/09 JLJ /SV GLV C/O (08/06/09) PERMIT No: 2051660 11/26/05 NORDIC 1 CTD SIDETRACK (15 -48B) 12/11/10 AH/PJC GLV CIO API No: 50- 029- 22635 -01 11/29/05 KSBfTLH GLV C/O SEC 22, T11N, R14E, 2967.84' FEL & 1006.73' FNL 04/03/07 KSB/ PJC DRLG DRAFT CORRECTIONS 04/29/07 NS /PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) I EE= 15 48C W = SAFETY ES: WELL ANGLE > 70" @ 9200 "" 3- ACTUATOR = BAKER C _ 1/2" CHROME LNR*** ORIGINAL WELLBORE & 'KB. ELEV = 66.-77 Proposed CTD Sidetrack 15-48A NOT SHOWN BELOW XO (cD 9418' eF: a EV = ' note: failed PPPOT -T - TO OP = 949 Max Angle = 16 fp 10807' TxIA comm thru holes in tubing Datum MD = 9233' I 2184' H4 HES HXO S V LN SSSV NIP, ID = 3.813" Datum TV D = 8800' SS O 1 9 -5/8" CSG, 40#, L -80. BTC-M XO NSCC H 3461' 1 — / A 11 GAS LIFT MANDRELS 9 -5/8" CSG, 40 #, L -80, NSCC, ID = 8.835" H 3648' ST MD ND DEV TYPE VLV LATCH FORT DATE 1' 3677 3675 1 KGB2 -LS DMY INT 0 12/11/10 2* 6288 6284 5 KGB2 -LS DMY"' INT 0 07/20/03 'BKR KB LTP & SEAL STINGER w / LOC, ID = 2.250" H 4010' / 1a.41 3' 8237 8059 34 KGB2 -LS MY** INT 0 03/10/96 * 13.70" BOT LNR DEPOY SLV, ID = 3.000" 1-I 4017' B NNNDRELS REQUIRE MODIFIED LATCH D PIPE 4 -- hole 6660' MD hole 6795' MD Minimum ID = 2.35" @ 4010' BKR KB LTP & SEAL STINGER w/ LOC 0 I 8306' H 7 "X4- 1/2 " BKR S -3PKR, ID= 3.875" 1 I 8329' 1- I 4 -1/2" HES X NIP, ID = 3.813" I 1 7" CSG, 2fi #, L -80, BTC -M, XO 29 #, L -80, BTC-M H 8139' I- x BEHIND PIPE 4 -1/2" TBG, 12.6#, L -80, NSCT, -1_ 8341' _ I 8341' 17" X 4 -1/2" TW LNR PKR .0152 bpf, ID = 3.958" & HYDRO HGR, ID = 3.915" 1 ----- -29,4 '.) , -;: 11 .-__. .TC = s l_-. ' • TSGR: 8496' MD 3 -1/2 LN ' - - -- 9 88f0' TCGL: 8800' MD BCGL: 8875' MD - Pull existing patch - Highside, Zone 3 Exit, 34 degs — 8810' - 3.7" deployment sleeve / 4.5" KB LTP - Rerun patch ' ' 8830' - TOUTOC ESTIMATED TOP OF CEMENT 1 8884' 9500' 3 -3/16' x 2 -7/8" xo 12,090' - Tz 3 -1/2" LNR, 8.81 #, L -80, STL, .0087 bpf, ID = 2.867" H 8942' :,:\._____ I 'WHIPSTOCK (11/15/05) H 9196' - — ,._ _ IRA P�PTAG H 92oa' ''" `'r'' - 4 -1/2" packer whipstock 8879' 113.7" LNR SLV & BKR HYDRO SET PERFORATION SUMMARY I RETRIEVABLE PKR, ID = 2.560" REF LOG: MWD/ GR/ ON 11/15/05 8889' — BOT 3" SEAL STINGER & ANGLE AT TOP PERF: 64° @ 9250' LNR DEPLOY SLV, ID = 2.355" Note: Refer to Production DB for historical perf data 8910' — 13 -1/2" HOWCO X NIP, ID = 2.813" 1 SIZE SFF INTERVAL Opn/Sgz DATE N 8942' H3-1/2" X 3- 3/16" XO, ID= 2.786" 1 2" 6 9250 - 9300 C 07/16/09 2" 6 9410 - 9485 C 07/16/09 MILLOUT WINDOW (15 -48B) 9195' - 9203' 2" 6 9550 - 9600 C 07/16/09 2" 6 10820 - 11200 C 11/25/05 3 -3/16" LNR, 6.2#, L -80, TC-II, + 39390' X2-7/8" XO, 2" 6 11230 - 11450 C 11/25/05 .0076 bpf, ID = 2.80" ID = 2.377" 2" 6 11480 - 11500 C 11/25/05 11606' H PBTD X 12 - 7/8" LNR, 6.16 #, L - 80, STL, .0058 bpf, ID= 2.441" H 11642' 1 TD — 11646' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/28/96 ORIGINAL COMPLETION 07/26/09 I I WPJC PERFS (07/16/09) WELL: 15 -48C 02/23/03 JLM /KK CTD SIDETRACK (15 -48A) 09/28/09 JLJ /SV GLV CIO (08/06/09) PERMIT No: 1 051660 11/26/05 NORDIC 1 CTD SIDETRACK (15 -48B) 12/11/10 AH/PJC GLV GO API No: 50- 029 -22635 • '' 11/29/05 KSB/TLH GLV C/O SEC 22, T11 N, R14E, 2967.84' FEL & 1006.73' FNL 04/03/07 KSB/ PJC DRLG DRAFT CORRECTIONS 04/29/07 NS /PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) ! • BP Exploration (Alaska) Ina Attn: Wetl Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue ~~~ ~ Anchorage, Alaska 99501 , , ~ R 1~~ Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 nata• 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200- NA Sealed NA 15-02B 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-O6A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-O8C 2050050 50029211800300 NA 6.5 NA 45.9 11!28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11B 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11!7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-31 B 2050860 50029222850200 NA 1.2 NA 3.4 11 /11 /2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-36B 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-37B 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-426 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-45B 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-49B 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS F~~'~~IV~~~~~09 ~UL 2 ~ ~Q(J~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ ~~a~~~i~~ , ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension " ~~'G~ ' Change Approved Program ~ Operat. Shutdown ~ Perforate Q~ Re-enter Suspended Well ~~~~~~~~~"~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: Development ~- Exploratory I~ 205-1660 ' 3. Address: P.O. Box 196612 Stratigraphic ~~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22635-02-00 - 7. KB Elevation (ft): 9. Well Name and Number: 66.7 KB ' PBU 15-48B - 8. Property Designation: 1Q. Field/Pool(s): _ ADLO-028306 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Totai Depth measured 11646 ~ feet Plugs (measured) None true vertical 8939.12 - feet Junk (measured) None EfFective Depth measured 11506 ' feet true vertical 8934 - feet Casing Length Size MD ND Burst Collapse Conductor 114 20" 91.5# H-40 Surface - 114 Surface - 114 1490 470 Surface 3548 9-5/8" 40# L-80 34 - 3548 34 - 3546 5750 3090 Production 8554 7" 26#/29# L-80 32 - 8554 32 - 8324 7240 5410 Scab Liner 4867 3-1/2" 9.2# 13CR80 4010 - 8877 4007 - 8595 10160 10530 Liner 2663 3-1/2"x3-3/16"x2-7/8" 8879 - 11542 8597 - 8935 8.81 #, 6.2#, 6.16# PerForation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 L-80 SURFACE - 8341 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 °` 8306' 7"X4-1/2" TIW LNR PKR 8341' 3.7" LNR SLV BKR HYDRO SET PKR 8879' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ; , '~~~ uKj'~ € ~1 J~-~ _ ~E ~i~~~i ti r, '~, ~IS~ c.+~ ~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bb! Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 405 20257 13 912 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r De~lopment ~~ Sen,ice ~~ Daily Report of WeII Operations X 16. Well Status after proposed work: Oil ~~ Gas ~ WAG r GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature . Phone 564-4944 Date 7/28/2009 r Form 10-404 Revised 04/2006 ~Sr~Submit Original Only ~~~`~ ~~-, ,~i~G ~i ~ 2!~OS ~ ~ ~!~~i'.~~'a~ 15~8B 205-166 PFRF oTTArHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-48B 11/5/05 PER 10,820. 11,200. 8,923.24 8,925.89 15-486 11/5/05 PER 11,230. 11,450. 8,926.25 8,933.38 15-486 11/5/05 PER 11,480. 11,500. 8,933.9 8,934.11 15-48B 7/16/09 APF 9,250. Lx 9,300. 8,874.72 8,892.55 15-48B 7/16/09 APF 9,410. 9,485. 8,904.02 8,902.95 15-48B 7/16I09 APF 9,550. u 9,600. 8,901.9 8,900.98 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAI. ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • W~~,u:,~ .:ceReport • • WELL SERVICE REPORT Page 1 of 1 WC~t JOB SCOPE UNIT 15-48B PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 7/13/2009 RIG UP IGTANLOC COST CODE PLUS KEY PERSON NIGHT SUPV PBD15WL48-C DS-WAGONER REESE MIN ID DEPTH TTL SIZE 2.35 " 4010 FT 0 " ""*Continue on WSR ~ test. LOG ENTRIES Init Tb , IA, OA 163 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 11:06 0 Jeff Jones of AOGCC waived BOP test. 12:00 0 Travel from L4 to 15-48 13:32 0 CTU on location. Get work ermit si ned. 14:10 0 Mast in air 17:30 0 MU CTC 17:56 0 Pull Test CTC to 30k 19:15 0 PT CTC to 3500 si 22:48 0 0 Flood lines 22:56 0 4 B in BOP test. 23:59 0 Continue on WSR on 7/14/09 Final T , IA, OA XXXX pplS OT 1% 7 bbls of diesel 1:1 of containment, lines and tanks OT= http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=F3ED891269C64FFE... 7/23/2009 W~11ServiceReport ~ WELL SERVICE REPORT ~ Page 1 of 2 W~L JOB SCOPE UNIT 15~4$B PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 7/14/2009 RIG UP; JEWELRY LOG--DEPTH CONTROL IGTANLOC COST CODE PLUS KEY PERSON NIGHT SUPV PBD15WL48-C DS-WAGQNER REESE MIN ID DEPTH TTL SIZE 2.35 " 4010 FT , 0 " cTU# 9 2.00" CT Job 5cope: Extended Pertorating with WWP. «<InterAct Publishing»> ""*Continue from WSR on 7/13/09*"* Continue with BOP test. Lower set of 2" combi's failed. R&R top seal and tested fine. MU BTT MHA & PDS 2.2" Carrier with GR/CCI and RIH. Well had a small gas cap and bled off quick. Having problems with depth control with PDS and looks like an Encoder or cable issue. Encoder was bad. Log from 9800 to 8800 at 30fpm. Paint flags at 9200 and 8800. POOM. Good Loqs. (-19' Correction) "`*Continue on WSR on 7/15/09"*" LOG ENTRIES Init Tb , IA, OA 27 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 23:58 0 Read lo s. -19' Correcton 00:00 0 7d Continue from WSR on 7/13/09 Continure with BOP testin 02:00 0 Leak in e ualizin ort on u er set of BOP's 02:51 0 Leak fixed. Continue with BOP test 04:13 0 30 Have a small leak in the valves by the inner reel valve and transducer. 06:30 0 Leak fixed, continue test 07:04 0 Start testin BOPE 08:16 0 Lower 2" Combi's are leaking, open combi's and full body test tree to confirm its not one of the tree valves lus test TIW Valve 08:32 0 Good TIW & Full Bod Test 08:44 0 Lower 2" Combi's still leaking, bleed off and move pipe up a little to see if iYs 'ust out of round i e 09:05 0 PU injector to inspect pipe, mechanics bringing out new rams & seals 09:40 0 Looks like we need to get a better bite with the slips for the rams to seal. Stab on and work i e in sli s to et a better bite 09:59 0 Still leakin , bleed off and drain stack to ull doors 10:06 0 Sl.B mech on location and we are going to check the Equalizing Port before tearin into the rams 10:34 0 Still leakin , bleed off and R&R Lower 2" Combi's 12:17 0 Fluid ack stack 12:18 0 39 Full bod test LPT & HPT 12:36 0 Test lower 2" Combi's 12:52 0 Good test, continue on to testing Annular the Draw Down. Notify PDS to come to location 13:54 0 3645 PT MHA, ood PT 14:02 0 PJSM to MU Lo in tools 14:18 d MU Lo in tools 14:49 0 44 e on ine u to fluid ack stack 14:55 0 348 47 LPT 15:01 0 3950 48 HPT 15:08 0 135 17 48 Bleed off, o en swab and check for flow 15:19 0 0 23 0 48 WHP bled of in a few minutes and it was all as. RIH takin returns 15:20 0 RIH w/ CTC (2.0" x.34'), DFCV (2.13" x 1.37'), Hyd Disco (2.13" x 1.56'), PDS Carrier (2.20" x 11.44'), 2-X-Overs (2.12 x.43'), JSN 2.25" x .58' . OAL = 16.15' 15:48 2000 5 11 0 Startin to et diesel back, calibratin de ths with PDS 18:21 3660 0 0 Still having depth control issues. Try changing cables and then the encoder. 18:41 3660 5 6 RIH to check encoder 19:45 4240 0 0 53 Encoder was the roblem. Check u and down. Looks ood. 20:01 5200 0 0 Wt ck = 17k riw = 10.8k Check encoder looks ood 21:12 8800 0 0 Wt ck = 27k riw = 17k 21:14 9350 0 0 Wt ck = 28k riw = 18k 21:18 9800 0 0 Sto for sto count http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereportldefault.aspx?id=0319798893BA4E65... 7/23/2009 WellS~rvi~ceReport ~ ~ Page 2 of 2 21:24 9800 0 0 .2 48 Log up hole at 30fpm Online with diesel down backside with C- Pum 21:40 9200 3 0 52 Paint fla White fla Mechanical = 9209 Shut down um 2'1-Tb~ 9200 0 0 .1 52 Log up hole at 30fpm Online with diesel down backside with C- Pum 22:02 8800 3 0 53 Paint fla Red fla Mechanical = 8809 Shut down um 22:07 8800 4 0 53 POOH 23:28 0 74 OOH close swab valve 23-1/2 tums 23:37 0 Po off well 23:50 0 Break off PDS lo in tool. 23:59 0 74 Continue on WSR on 7/15/09 Final Tb , IA, OA xxxx bbls of 1 %KCL 74 bbls of diesel Performed daily inspection of containment, lines and tanks OT= 73C http://apps2-alaska.bpweb.bp. com/awgrs-wellservicereport/default. aspx?id=0319798 893 BA4E65 ... 7/23/2009 W~11Serv~ceReport ~ • WELL SERVICE REPORT Page 1 of 3 WE~l: JOB SCOPE UNIT 15-48B PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 7/16/2009 PERFORATING IGTANLOC COST CODE PLUS KEY PERSON NIGHT SUPV PBD15WL48-C DS-WAGONER REESE MIN ID DEPTH TTL SIZE 2.35 " 4010 FT 0 " ue on w5rt on 7/14/09**` End weather stand by. PJSM with crews to load & run perf guns. 30 min no flow check is good, MU Guns. RIH to Flag, correct depth to top shot. RIH to check ball drop position, PUH and 5 bbls each KCL & Flo-Pro RIH to ball drop position and launch ball. PUH to 9250' (top shot depth) ball landed at 42 bbls and sheared at 2750psi. Perforate intervals: 9250'- 9300', 9410'-9485', and 9550'-9600' with 2", 6 spf, 60 degree phasing. POOH filling down backside. Stop at 5000' hole not taking proper hole fill. Circ bottoms up and got a little gas back then POOH filling hole. At surface perForm no flow check and after 30 min the well took 0.7 bbls. Crew change and prep to LD spent guns (1/2" Ball Recovered) Lay down spent guns. RIH w/2.5" JSN to 2500' to freeze protect. ***Continue on WSR on 7/17/09*** LOG ENTRIES Init Tb , IA, OA 0 33 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 02:00 0 End weather stand by. Prepare to start perforating job. Call out all e ui ment. 04:25 0 1 Okcl Online with 1%KCL to circ coil out. 04:40 0 1 14 LPT to 500 si 05:11 0 43 Finished um in 1% KCI 05:49 0 44 PT CTC to 3500 si 06:00 0 PE & SLB Crew Chan e Out 06:41 0 PJSM to load & run erf uns 07:06 0 Line up to make sure well is fluid packed for 30 min no folw check and check wind s eed 07:27 0 BOC Weather is showing 15 mph gusting to 24 mph, IAP= 33psi OAP= 0 si 07:29 0 Drift BOT Disconnect with 1/2' ball, drifted fine 07:32 0 Wind s eed check on to of inezzanine was 16.9 m h 07:33 0 44 Fluid ack well 07:36 0 2 bbls to et returns, start no flow check 08:51 0 No flow test good, CH2 hand is still and will stay on the 40 bbl tank loookin for returns 08:53 0 Start runnin uns 09:15 0 Perform Safety Drill - PU Safety Joint and MU to guns in hole, continue runnin uns 10:02 0 Perf Guns made up, lower injector down to MU swivel to Firing Head 10:35 0 Stabbed on, ta u and zero de th, SLB Crew chan e out 10:48 0 PJSM with new crew 10:59 0 Ta u and zero de th 11:04 0 RIH, returns at OT. Shut in choke open Whitey on lubricato~ until fluid acked & shut to build ressure to see if o-rin leaks 11:13 306 65 0 0 0 No leaks 12:18 5375 0 0 0 0 WT CK 20k 12:40 7071 58 58 0 0 WHP climbing, looks like we are getting a little gas migration. Pinch in choke and continue RIH 12:54 7740 41 5 0 0 Gas ushed out 13:04 8450 8 5 0 0 WT CK 29k RIH WT 18k 13:16 9190.3 0 0 0 0 Sto at fla mech at 9201' and correct de th to to shot at 9208.3' 13:22 9266.7 0 0 0 0 Stop at ball drop position, PU to 9250' to pump 5 bbls each 1°/a KCL & Flo-Pro 13:25 9250 0 555 1.3 0 Online withb 1% KCL 13:29 9250 0 795 1.2 5.5 Swa to Flo-Pro and cau ht fluid 13:34 9267 41 1018 1.2 0 Ball launched PUH to 9250' 13:35 9250 58 1190 1.5 1.0 o s o e 13:57 9250 19 608 0.8 33 Reduce rate 14:10 9250 2 2750 0 42 Guns fired, PerForate intervals: 9250'-9300', 9410'-9485', and 9~Q'- http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?id=D03446E346004A06... 7/28/2009 W~11ServiceReport • • Page 2 of 3 9600' with 2", 6 spf, 60 degree phasing. POOH filling hole down back side 14:10 9250 17 619 0.8 42 Ball on seat 14:## 9086 0 29 0.3 0 Online with diesel down backside 14:49 7071 36 0 0 6.8 WHP is climbing like we have gas migrating up. Stop and open well to see if returns die off or continue to flow 15:06 7071 0 No as in retums, continue POOH 15:42 5021 0 Well not taking proper displacement and is pressuring up. Line up to pump bottoms up from here to make sure the hole is full and we sta over balanced 16:24 5021 8 238 0.5 52 Bottoms up got a little gas back, POOH at min rate down coil with tri s set at 600 si 17:17 12 0 44 0 77 Close to surface shut down um and start our 30 min no flow test 17:54 12 0 13 0 0 Line up to pump across top to see how many bbis it take to fill the well 17:58 0 0.7 Returns at tank, shut down and wait for chan e out 18:50 0 All chan e-outs com lete. Have PJSM 19:25 0 .7 Line up to pump across top to see how many bbls it take to fill the well 19:28 0 1 Hole full. Do final walk around. Eve one in lace 19:42 0 Po off well. 19:49 0 Move in'ector out of wa . 20:00 0 De lo ment bar and TIW valve read to o. 20:09 0 1/2" Ball recovered 20:11 0 Holes in uns 20:31 0 B in la in down erf uns 21:05 0 Swab valve close 23-1/2 turns • 22:40 0 Perf uns and all erf e ui ment off of floor. 22:41 0 MU tools. 22:53 0 Stab on Well 23:00 0 Om Flood lines w/ methanoi 23:04 0 3 LPT to 343 si 23:10 0 4 HPT to 4025 si 23:19 0 4 O en swab valve 23-1/2 turns 23:24 0 RIH w/ CTC (2.0" x.34'), DFCV (2.13" x 1.37') Hyd Disco (2.13" x 1.56'), X-Over (2.1" x.33'), JSN ( 2.5" x.58'j OAL = 4.18' to freeze rotect. 23:26 0 1 4 Online with 50/50 methanol. 23:58 2500 33 2503 1 32 Park 23:59 0 Continue on WSR on 7/17/09 Final Tb , IA OA 164 bbls of 1 %! 7 bbls of diesel 5 bbis of flo pro ~ection of containment, lines and tanks OT= 73094 TT= http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?id=D03446E346004A06... 7/28/2009 We11S~erviceReport ~ • Page 3 of 3 9,410 ~ 9,485 ~ 2.000 ~ N ~ 6.00 ~ 60 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=D03446E346004A06... 7/28/2009 WellS~ervice~teport ~ ~ WELL SERVICE REPORT Page 1 of 1 WEt~ JOB SCOPE ~ UNIT. 15-48B PERFORATING CTU #9 DATE DAILY WORK DAY SUPV 7/17/2009 FREEZE PROT; RIG DOWN IGTANLOC COST CODE PLUS KEY PERSON NIGHT SUPV PBD15WL48-C DS-WAGONER REESE MIN ID DEPTH TTL SIZE 2.35 " 4010 FT 0 " GTU# 9 2.00" CT Job 5cope: Extended Perforating with WWP. «<InterAct Publishing»> *'*"Continue on WSR on 7/16/09#""` POOH laying in 50/50 methanol from 2500' to freeze protect well. RDMO Notifv operator on departure "**Job Complete**" LOG ENTRIES Init Tb , IA, OA 33 37 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:00 0 35 Continue from WSR on 7/16/09 00:05 2500 33 2563 2 45 POOH la in in 50/50 methanol at 80% 00:27 200 0 0 0 90 Shut down um 00:31 0 OOH Close swab valve 23-1/2 turns 00:35 0 Po off well. 00:43 0 La down tools. 00:45 0 RDMO 05:00 0 End JoblTicket Finat T IA, OA 0 37 0 methanol Performed daily inspection of containment, lines and tanks OT= 73 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=4D7F0643DDD34DA... 7/23/2009 '~ C_. DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051660 Well Name/No. PRUDHOE BAY UNIT 15-488 MD 11646 TVD 8939 Completion Date 11/25/2005 REQUIRED INFORMATION Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22635-02-00 Completion Status 1-OIL Current Status 1-OIL UIC N Mud Log No Samples No Directional Surv Yes DATA INFORMATI ON Types Electric or Other Log s Run: MWD GR / EWR, MGR /CCL /CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 9188 11646 Open 1/9/2006 ~i ~ C Lis 13485 Neutron 1 8173 ' 11420 Case Mem CNL GR CCL plus Graphics ~og Neutron 25 Blu 1 8173 11420 Case Mem CNL GR CCL i~j `' ED D Lis 13797 Induction/Resistivity 8932 11618 Open 3/9/2006 GR EWR4 ROP ~tpt 13797 LIS Verification 8932 11618 Open 3/9/2006 GR EWR4 ROP .~D C Pdf 13873 Gamma Ray 2 5 8781 8872 Open 5/10/2006 DGR Dual GR 14-Nov-2005 I~D C Pdf 13873 Gamma Ray 2 5 9200 11646 Open 5/10/2006 ROP NPG Horizontal Presentation 15-Nov-2005 ~~ D C Lis 13873 Induction(Resistivity 8931 11646 Open 5/10/2006 ROP, GR Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ^ Well Cored? Y~ Daily History Received? ~ Chips Received? ~4Tht-- Formation Tops Y ( N Analysis J=-Ffd~- Received? ~t Comments: DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051660 Well Name/No. PRUDHOE BAY UNIT 15-486 MD 11646 TVD 8939 Completion Date 11/25/2005 Compliance Reviewed By: _ _- Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22635-02-00 Completion Status 1-OIL Current Status 1-OIL UIC N --___ ___ -. --- )~~~~~~j Date: ~_ (,G'1JU~1_U ------- C. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : 15-48B, !~~ -~~~ May 1, 2006 AK-MW-4054361 15-48B: Digital Log Images: 50-029-22635-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~; Date: ~- '(~~ Signed: ~ ~ ' ~ " ~ ~ WELL LOG TRANSNIITTAL To: State of Alaska February 17, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-48B, AK-MW-4054361 1 LDWG formatted Disc with verification listing. API#: 50-029-2263 5-02 ~~7 ~3 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETUKNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: ~ ~"^-~-U ~ ~ Signed: STATE OF ALASKA ~~ Y ~~~ ALASK~IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG~~ ~ +~ ~ ~~~~ ~ias~a ~~ ~ ~~ ~ ~or~lti=sioil 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well ~ ' ® Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 11/25/2005 12. Permit to Drill Number 205-166 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11116/2005 13. API Number 50-029-22635-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11121!2005 14. We11 Name and Number: PBU 15-488 3971 FSL, 5021 FEL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 3649' FSL, 984' FEL, SEC. 21, T11N, R14E, UM g. KB Elevation (ft): 66.7' 15. Field /Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 1460' FSL, 1757' FEL, SEC. 21, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11506 + 8934 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676193 y- 5960178 Zone- ASP4 10. Total Depth (MD+TVD) 11646 + 8939 Ft 16. Property Designation: ADL 028306 TPI: x- 674959 y- 5959828 Zone- ASP4 Total Depth: x- 674243 Y- 5957622 Zone- ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: -------~---~- -~----- ---~- -~----- 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD GR / EWR, MGR / CCL / CNL 2. ASING, LINER AND EMENTING ECORD CASING ING EPTH MD ; ETTIN(i H TW HOLE MOUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surtace 114' Surtace 114' 30" 60 sx Arctic Set A rox. 9-5/8" 40# L-80 34' 3548' 34' 3546' 12-114" 95 sx CS II1, 305 sx'G', 187 sx CS II 7" 26# / 29# L-80 32' 8554' 32' 8324' 8-112" 35 sx Class 'G' 4-1/2" 12.6# L-80 8341' 9195' 8146' 8844' 6" 16 sx Class 'G' a•1rz• x ~-3r1s~ z 2aia" 8.81# / 6.2# / 6.16# L-80 8879' 11542' 8597' 8935' 4-1/4' x 3-~a° 158 sx Class 'G' 3-112" 9.2# 13Cr80 4010' 8877' 4007' 8595' Scab Scab Liner - No Cement Placed 23. Perforations open to Produc tion (MD + TV D of Top and " " ~4; TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 8341' 8306' MD TVD MD TVD 10820' - 11200' 8923' - 8926' 11230' - 11450' 8926' - 8933' Q5, ACID, FRACTURE, .CEMENT SQUEEZE, ETC. 11480' - 11500' 8934' - 8934' DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 2500' Freeze Protected w/ McOH 26- PRODUCTION TEST Date First Production: December 5, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 1/23/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 157 GAS'MCF 3,243 WATER-BBL 4 CHOKE SIZE 51.77 GAS-OIL RATIO 20,621 Flow Tubing Press. 88 Casing Pressure 1,100 CALCULATED 24-HOURRATE~ OIL-BBL 944 GAS-MCF 19,458 WATER-BBL 24 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none" I ~ q~~,,~.,1.~ ~f ~s ~~~~`~~' fiv.~ None i ~- ~~~ ,iA}~ ~ ~ 2DQ6 4 V eil'i~~, / `_!'~ y~~ Form 10-407 Revised 12/2003 ~ ~ ~ ;` E ~ ; ~~I~i~Ir~D~ON REVERSE SIDE l7 r~ 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". TDF /Zone 1 A 9212' 8855' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. ~ r L Signed ~l /'~ Titl T h ic l A i t D t t e n s an a e [ (~ ec a ss Terrie Hubble PBU 15-486 205-166 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. J A royal No. Drilling Engineer: Barbara Lesley, 564-5126 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: 7PI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ireM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate °None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page.1 of 10 Operations Summary Report Legal Well Name: 1 5-486 Common W ell Name: 1 5-486 Spud Date: 1 1 /1 412005 Event Nam e: REENTE R+COM PLET E Start : 11/14/2005 End: 11/2512005 Contractor Name: NORDIC CALIST A Rig Release: 11/25/2005 Rig Name: NORDIC 1 Rig Number: 1 Date ~ From - To ~ Hours ~~ Task I Code ~~ i NPT ~~~ Phase I 1 Description of Operations 11/13!2005 00:00 - 06:30 6.50 RIGD P --- PRE ------- ----- __ RD/prep for 15-48B. S/M for move off F-44A. Move off F-44A. 06:30 - 09:00 2.50 MOB N WAIT PRE Wait on security. Wait on rig mats. 09:00 - 00:00 15.00 MOB P PRE Move ff F-44A - 15-486. (20.5 miles). Minor prep work required for back over (pad not level around well head). S/M for backover. Backover wellhead. 11/14/2005 00:00 - 02:00 2.00 RIGU P PRE Accept rig at 00:00 hrs. NU BOP. 02:00 - 07:45 5.75 BOPSU P PRE Test BOP AOGCC representative John Crisp waived witnessing BOP test. No Failures. 07:45 - 08:00 0.25 RIGU P PRE PJSM for pulling coil to injector. 08:00 - 12:00 4.00 RIGU P PRE Install grapple in coil and pull coil to injector. Stab into injector and stuffing box. Install coil connector. Pump 5bbl methanol. 12:00 - 12:30 0.50 RIGU P PRE Install dart and circulate to catcher 59.4 bbl dart volume. 12:30 - 13:30 1.00 RIGU P WEXIT Pressure test inner reel valve, & packoff. Open well No Flow. 13:30 - 14:00 0.50 WHIP P WEXIT MU Dummy WS assy 14:00 - 16:00 2.00 WHIP P WEXIT RIH with 3.7" drift to 9300' No Problem. 16:00 - 18:00 2.00 WHIP P WEXIT POH to surface. 18:00 - 19:15 1.25 WHIP P WEXIT LD WS drift BHA. PU WS BHA. 19:15 - 20:45 1.50 WHIP N SFAL WEXIT Leaking o-ring on injector drive motor. Wait on SLB mechanics to repair. 20:45 - 23:30 2.75 WHIP P WEXIT RIH, SHT test orienter/MWD: ok. RIH. 23:30 - 00:00 0.50 WHIP P WEXIT Log down f/ 8980' Correction: 1111512005 00:00 - 00:45 0.75 WHIP P WEXIT Log down f/ 8980'. Correction: -39'. 00:45 - 01:15 0.50 WHIP P WEXIT RIH. Orient TF to 44L. 01:15 - 01:30 0.25 WHIP P WEXIT Set Baker WS at TOWS C~ 9195'. Pumps up to 4K psi. Shut down pumps, bleed choke to 0 psi. Pump down CT only, shear WS at 3200 psi. PU and get survey, no click during WS set, TF still at 44L. 01:30 - 03:30 2.00 WHIP P WEXIT POOH. 03:30 - 04:15 0.75 WHIP P WEXIT LD WS setting BHA -W S. PU milling BHA #1. 04:15 - 06:30 2.25 STWHIP P WEXIT RIH. Tag WS, correct to W5 set depth.-36'. 06:30 - 19:00 12.50 STWHIP P WEXIT Mill window. TOW: 9195'. BOW : 9203'. Mill 10' of formation. Dress window 3X. 19:00 - 19:30 0.50 STWHIP P WEXIT Drift window 2x -- looks clean. Meanwhile swap the wellbore to reconditioned (100% used) 8.6 ppg Flo-Pro mud with 3% L-T & 10ppb K-G. Inspected wellhead bolts and found no loose bolts/nuts. Printed: 11/28!2005 12:58:49 PM BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: 1 5-48B Common W ell Name: 1 5-48B Spud Date: 11/14!2005 Event Nam e: REENTE R+COM PLET E Start : 11/14/2005 End: 11/25/2005 Contractor Name: NORDIC CALIST A Rig Release: 11/25/2005 Rig Name: NORDIC 1 Rig Number: 1 Date j From - To j ~ Hours II Task ~ Code j NPT i Phase ~ ! I Description of Operations T 11/15/2005 --- 19:30 - 21:30 --- 2.00 --- STWHIP P _- - WEXIT -----__---. _--- Paint EOP flag ~ 8900' & POOH window milling BHA #3, while displacing well to mud. 21:30 - 22:00 0.50 STWHIP P WEXIT PJSM. L/D BHA #3 & inspect mills. Window mill gauge 3.80" go / 3.79" no-go & string mill gauge 3.79" go / 3.78" no-go. Wear on window mill face indicates center crossed the liner wall. 22:00 - 22:45 0.75 DRILL P PRODi Behead & MIU SLB CTC. Pull test to 35k & pressure test to 3500psi _ OK. 22:45 - 23:00 0.25 DRILL P PROD1 Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. 23:00 - 00:00 1.00 DRILL P PROD1 M/U drilling BHA #4 with 3deg X-treme motor, MWD/GR, orienter & used Hycalog 3-3/4" x 4-1/4" DSX3611 bicenter bit #2. Scribe tools & M/U injector. Fix minor leak on injector. 11/16/2005 00:00 - 02:00 2.00 DRILL P PRODi RIH drilling BHA#4. Correct -38' C~3 8900' EOP. RIH to 9150'. Check TF - LOHS. RIH thru window & tag btm C~ 9214'. 02:00 - 02:40 0.67 DRILL P PRODi Orient TF to 30L. P/U wt = 40k, Run-in wt = 24k, IAP = 1000psi, OAP = Opsi, PVT = 311 bbls. 02:40 - 03:15 0.58 DRILL P PROD1 Drill to 9225' with 45L TF, 2.45/2.45bpm, 3350/3650psi, +/-5k WOB & 25fph ave BOP. 03:15 - 04:30 1.25 DRILL P PROD1 Orient & drill to 9257' with 15L TF, 2.45/2,45bpm, 3350l3650psi, +/-5k WOB & 80fph ave BOP. 04:30 - 05:20 0.83 DRILL P PROD1 Orient TF around to 30L -getting intermittent 10/20degs clicks. 05:20 - 06:00 0.67 DRILL P PROD1 Drill to 9275' with 45L TF, 2.4512.45bpm, 3350/3650psi, +/-3.5k WOB & 35fph ave BOP. 06:00 - 10:30 4.50 DRILL P PROD1 Drill f/ 9275' - 9363'. Pressure off/on btm: 3250 psi/3700 psi. O in/out: 2.6512.65 bpm. PU wt: 38K Ib, SO wt: 23K Ib, on btm: 20K Ib - 15K Ib. 10:30 - 12:00 1.50 DRILL P PROD1 Tie-in GR spike at 8962' to RA tag. Correction: 0'. TOWS: 9195' TOW: 9195' BOW: 9204' RA C~ 9204' down, 9202.5' up. WS: 44 LOHS. 12:00 - 13:15 1.25 DRILL P PROD1 POOH. 13:15 - 15:00 1.75 DRILL P PROD1 LD orienter/3.0 degree/mtr/bi-center bit PU orienter/1.2 degree mtr/rebuild HCC bicenter. 15:00 - 16:40 1.67 DRILL P PROD1 RIH. 16:40 - 17:00 0.33 DRILL P PROD1 Tie-in: +5'. 17:00 - 18:15 1.25 DRILL P PROD1 RIH to TD. Drill ahead to 9387'. Pressure off/on btm: 3000 psiJ3500 psi. O inlout: 2.412.4 bpm. PU wt: 38K Ib, SO wt: 22K Ib. TF: 24L, Pits: 308 bbl. 18:15 - 19:05 0.83 DRILL P PROD1 PUH to 9215'. Orient TF around to 90L. RBIH to btm. P/U wt = 39k, Run-in wt = 21 k, freespin = 2.65bpm/3350psi, IAP = 1070psi, OAP = Opsi, PVT = 310bb1s. 19:05 - 19:20 0.25 DRILL P PROD1 Drill to 9391' with i00L TF, 2.4512.45bpm, 3100/32350psi, 4k WOB & 20fph ave BOP. TF rolling left. 19:20 - 19:45 0.42 DRILL P PROD1 PUH to window & orient TF around to 80L. RBIH to btm. 19:45 - 21:20 1.58 DRILL P PROD1 Drill to 9413' with 90-95L TF, 2.45/2.45bpm, 3100/3450psi, 2k Printed: 11!28!2005 12:58:49 PM BP EXPLORATION Operations Summary Report Page 3 of 10 Legal Well Name: 1 5-48B Common W ell Name: 1 5-486 Spud Date: 11/14/2005 Event Nam e: REENTE R+COM PLET E Start : 1 1 11 4/2005 End: 11/25/2005 Contractor Name: NORDIC CALIST A Rig Release: 11/25/2005 Rig Name: NORDIC 1 Rig Number: 1 Date j From - To ~ Hours I Task ~ Code j NPT 'I Phase 'I Description of Operations -- __-- 11/16/2005 19:45 - 21:20 1.58 DRILL P PROD1 WOB & 15fph ave ROP. Drilling ratty ~ suspect bit balling in shales. 21:20 - 21:55 0.58 DRILL P PROD1 PUH & orient 2 clicks. RBIH to btm. 21:55 - 23:15 1.33 DRILL P PROD1 Drill to 9429' with 75-80L TF, 2.45/2.45bpm, 3250/3400psi, 2k WOB & 15fph ave ROP. Gettiing frequent motor stalls with > 200psi motor work. 23:15 - 23:35 0.33 DRILL P PROD1 Wiper trip to window. RBIH to btm. P/U wt = 38k, Run-in wt = 21 k. 23:35 - 00:00 0.42 DRILL P PRODi Drill to 9430' with 80L TF, 2.45/2.45bpm, 3200/3250psi, k WOB & 5fph ave ROP. Not gettiing much motor work & not making much progress. Decide to POOH to check motor & bit. 11/17/2005 00:00 - 01:45 1.75 DRILL P PROD1 Paint EOP flag C«? 9000' & POOH lateral BHA #5. Geo seeing some hard silica cement in samples. 01:45 - 03:00 1.25 DRILL P PROD1 OOH. PJSM. L/D BHA # 5 & inspect motor & bit. Motor seemed OK & bit gauge 2/3/I with i broken & 1 chipped outer cutters & a plugged jet. 03:00 - 04:00 1.00 DRILL P PROD1 M/U drilling BHA # 6 with new 1.2deg X-treme motor, new MWD/GR probe, orienter & another rebuilt Hughes 3-3/4" x 4-1/8" RWD2ST bicenter bit #4. Scribe tools & M/U injector. 04:00 - 05:30 1.50 DRILL P PROD1 RIH drilling BHA # 6. Correct -10' C~ the flag. RIH to below the window. 05:30 - 05:45 0.25 DRILL P PRODi Log up GR & tie-into RA Pip tag -Add 4' to CTD. 05:45 - 06:00 0.25 DRILL P PROD1 RIH & tag btm ~ 9433'. 06:00 - 10:00 4.00 DRILL P PROD1 Drill f( 9433'-9528' Pressure off/on btm: 3400 psi/3750 psi. O in/out: 2.7/2.7 bpm. SO wt: 19K Ib., drill wt: 16K Ib., WOB: 7K Ib Est. ave rop: 30-45 TF: 115L, Pits: 300 bbl. 10:00 - 12:45 2.75 DRILL P PROD1 Drill f/ 9528' - 9610'. Pressure off/on btm: 3400 psi/3680 psi. O in/out: 2.712.7 bpm. drill wt: 17K Ib, WOB: 6K-5K Ib Est ave rop: 25-35 ft/hr. TF: 86L, pits: 298 bbl. 12:45 - 13:00 0.25 DRILL P PROD1 Wiper trip to window. 13:00 - 14:30 1.50 DRILL P PROD1 Drill f/ 9610' - 9630'. Pressure off/on btm: 3550 psi/3750 psi, Q in/out: 2.6/2.68 bpm drill wt: 18K Ib, WOB: 6K Ib - 5K Ib. Est ave rop: 25-30 fUhr. TF: 108L, pits: 295 bbl. 14:30 - 16:00 1.50 DRILL N RREP PRODi Pump 1 down. Pump 2 not giving good MWD readings. Pull up into casing for repairs/wiper trip. 16:00 - 16:15 0.25 DRILL P PROD1 Orient TF to 74L. 16:15 - 18:30 2.25 DRILL P PROD1 Drill f/ 9630' - 9694'. Pressure off/on btm: 3300 psi/ 3650 psi. O in/out: 2.55/2.55 bpm. PU wt: 38K Ib, SO wt: 20.5K Ib, drill wt: 17K Ib, WOB: 6K Ib. Est ave rop: 20-30 ft/hr. TF: 91 L, Pits 298 bbl. 18:30 - 18:40 0.17 DRILL P PROD1 Orient TF to 60R. P/U wt = 37k, Run-in wt = 22k, IAP = Printed: 11/28/2005 12:58:49 PM • BP EXPLORATfON Operations Summary Report Page 4 of 10 Legal Well Name: 1 5-48B Common W ell Name: 1 5-48B Spud Date: 1 1 /1 412005 Event Nam e: REENTE R+COM PLET E Start : 11!14!2005 End: 11!25/2005 Contractor Name: NORDIC CALIST A Rig Release: 11/2512005 Rig Name: NORDIC 1 Rig Number: 1 Date ~ From - To ~I, Hours ~~ Task ~I Code ~ NPT j Phase Description of Operations --__! ---1 __-_! -_ __ __ 11/17/2005 18:30 - 18:40 0.17 DRILL P PROD1 1100psi, OAP = Opsi, freespin 2.65bpm/3400psi, PVT = 295bb1s. 18:40 - 19:30 0.83 DRILL P PROD1 Drill to 9751' with 75-85R TF, 2.6/2.6bpm, 3400/3650psi, 6k WOB & 70fph ave ROP. 19:30 - 19:35 0.08 DRILL P PROD1 Short 100' wiper. 19:35 - 20:15 0.67 DRILL P PROD1 Drill to 9780' with 75R TF, 2.65/2.65bpm, 3400/3775psi, 6k WOB & 50fph ave ROP. 20:15 - 20:35 0.33 DRILL P PROD1 Drill to 9800' with 65-75R TF, 2.65/2.65bpm, 3400/3825psi, 8k WOB & 50fph ave ROP. 20:35 - 21:50 1.25 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. P/U wt = 37k, Run-in wt = 22k, IAP = 1000psi, OAP = Opsi, freespin 2.65bpm/3400psi, PVT = 289bb1s. 21:50 - 22:25 0.58 DRILL P Drill Orient 2 clicks & drill to 9818' with 75-85R TF, 2.65/2.65bpm, 340013625psi, 6k WOB & 30fph ave ROP. Stacking wt. 22:25 - 22:35 0.17 DRILL P PROD1 Short 100' wiper & orient 2 clicks. 22:35 - 23:05 0.50 DRILL P PROD1 Drill to 9841' with 100R TF, 2.65/2.65bpm, 3400/3650psi, 8k WOB & 45fph ave ROP. Stall & blow Pump #1 pop-off. 23:05 - 23:30 0.42 DRILL N RREP PROD1 Wiper trip clean to window. Meanwhile changeout Pump #1 pop-off. RBIH to btm. 23:30 - 00:00 0.50 DRILL P PRODi Orient TF to 90R. 11/18/2005 00:00 - 01:45 1.75 DRILL P PROD1 Drill to 9910' with 100R TF, 2.65/2.65bpm, 3300/3600psi, 1.5k WOB & 50fph ave ROP. Meanwhile swap the wellbore to new 8.6 ppg Flo-Pro mud with 3% L-T & 12ppb K-G. 01:45 - 02:15 0.50 DRILL P PROD1 Orient TF around to 70L. P/U wt = 36k, Run-in wt = 20k, IAP = 1000psi, OAP = Opsi, freespin 2.65bpm/3200psi. 02:15 - 02:45 0.50 DRILL P PROD1 Drill to 9950' with 60-70L TF, 2.65/2.65bpm, 3200/3600psi, 1.5k WOB & 80fph ave ROP. 02:45 - 03:15 0.50 DRILL P PROD1 Wiper trip clean to window. P/U wt = 36k. 03:15 - 03:50 0.58 DRILL P PROD1 Log up GR & tie-into RA Pip tag -Add 2' to CTD. 03:50 - 04:05 0.25 DRILL P PROD1 RBIH to btm tagged C«~ 9952'. Run-in wt = 20k, !AP = 980psi, OAP = Opsi, freespin 2.65bpm/3200psi. 04:05 - 05:15 1.17 DRILL P PROD1 Drill to 10023' with 70L TF, 2.65/2.65bpm, 3200/3600psi, 3k WOB & 100fph ave ROP. 05:15 - 06:00 0.75 DRILL P PROD1 Orient TF around to 55R. 06:00 - 08:30 2.50 DRILL P PROD1 Drill f/ 10023' - 10110'. 08:30 - 09:15 0.75 DRILL P PROD1 Wiper trip to window. 09:15 - 09:45 0.50 DRILL P PROD1 Orient TF 105R. 09:45 - 12:00 2.25 DRILL P PROD1 Drill f/ 10123' - 10250'. Pressure off/on btm: 3250 psi/3600 - 3500 psi. PU wt: 38K Ib, SO wt: 17K Ib, drilling wt: 13K - 15K Ib. Q in/out: 2.65/2.65 bpm TF: 120-100R, Pits: 293 12:00 - 13:00 1.00 DRILL P PROD1 Wiper trip to window. 13:00 - 14:00 1.00 DRILL P PROD1 Drill f! 10250' - 10301'. Pressure off/on btm: 3350 psi13850 psi. drilling wt: 18.5K - 16.5K Ib. O in/out: 2.75/2.75 bpm. TF: 70R, Pits: 288 bbl. 14:00 - 14:30 0.50 DRILL P PROD1 Orient TF to 0 14:30 - 17:45 3.25 DRILL P PROD1 Drill f/ 10301' - 10400' Pressure off/on btm: 3400 psi/3700 psi. PU wt: 39K Ib, So wt: 21 K Ib, drilling wt:17.5K Ib. O in/out: 2.7512.75 bpm Printed: 11/28/2005 12:58:49 PM C, BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 15-48B Common Well Name: 15-48B Spud Date: 11/i4/2005 Event Name: REENTER+COMPLETE Start: 11114/2005 End: 11/25/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/25/2005 Rig Name: NORDIC 1 Rig Number: 1 Date !From - To I Hours I Task II Code j NPT '~ Phase '! Description of Operations 1 1 11 8/2005 ~ 14:30 - 17:45 ~ 3.25 ~ DR1LL P 1 17:45 - 18:30 18:30 - 19:00 19:00 - 19:35 19:35 - 19:45 19:45 - 20:10 20:10 - 20:25 20:25 - 20:35 20:35 - 20:50 0.75 DRILL P 0.50 DRILL P 0.58 DRILL P 0.17 DRILL P 0.42 DRILL P 0.25 DRILL P 0.17 DRILL P 0.25 DR1LL P 20:50 - 21:15 0.42 DRILL P 21:15 - 21:45 0.50 DRILL P 21:45 - 22:05 0.33 DRILL P 22:05 - 22:25 0.33 DRILL P 22:25 - 00:00 11/19/2005 00:00 - 00:30 00:30 - Oi :15 01:15 - 01:45 01:45 - 03:00 03:00 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 07:50 07:50 - 10:00 10:00 - 12:00 PROD1 Poff btm @ 2.45 bpm = 3K psi. TF: 10R, pits: 282 bbl. Orient as needed: 15% of time. Hard to hold angle. PRODi Wiper trip clean to window. P/U wt = 38k. PROD1 Log up GR & tie-into RA Pip tag -Add 4' to CTD. PROD1 RBIH to btm tagged C«~ 10404'. Run-in wt = 22k, IAP = 1040psi, OAP = Opsi, freespin 2.65bpm/3350psi, PVT = 279bb1s. PROD1 Drill to 10420' with 65-75R TF, 2.6512.65bpm, 3350/3800psi, 4k WOB & 85fph ave ROP. PROD1 Drill to 10445' with 55-60R TF, 2.65/2.65bpm, 3350/3800psi, 4k WOB & 70fph ave ROP. PROD1 Orient TF to 30R. PROD1 Drill to 10455' with 15R TF, 2.65/2.65bpm, 3350/3800psi, 4k WOB & 85fph ave ROP. PROD1 Orient 1 click & drill to 10474' with 45R TF, 2.65/2.65bpm, 3350/3$OOpsi, 4k WOB & 65fph ave ROP. Having difficulty maintaining TF -- rolling right. PROD1 Orient TF around to HS. PROD1 Drill to 10498' with HS-15R TF, 2.65/2.65bpm, 3350/3900psi, 4k WOB & 45fph ave ROP. PROD1 Drill to 10507' with 45R TF, 2.65/2.65bpm, 3350/3700psi, 4k WOB & 25fph ave ROP. PROD1 Orient 1 click & drill to 10521' with 55-60R TF, 2.65/2.65bpm, 3350/3920psi, 4k WOB & 45fph ave ROP. Observed build/drop/turn rates not matching as-drilled TF settings. Need to check motor scribe before crossing close approach. 1.58 DRILL N DPRB PROD1 Paint EOP flag @ 8000' & POOH to check BHA scribe. 0.50 DRILL N DPRB PRODi Continue POOH drilling BHA #6. 0.75 DRILL N DPRB PROD1 OOH. PJSM. L/D BHA # 6 & inspect motor & bit. Motor is OK & bit gauge 1/1/1. Motor scribe is also OK. Grease MHA. 0.50 DRILL N DPRB PROD1 Change out bladder in Pump #2 pulsation dampner. Tighten bonnet bolts in upper SLB TOT combis to stop slight leak observed on the blind/shear BOP. 1.25 DRILL N DPRB PROD1 M!U drilling BHA # 7 with same 1.2deg X-treme motor, new MWDlGR probe, orienter & new Hughes 3-3l4" x4-1i8" RWD2ST bicenter bit #5. Scribe tools & M1U injector. 3.00 DRILL N DPRB PROD1 RIH drilling BHA # 7. SHT tools OK. Correct -10' ~ the flag. Continue RIH to btm tagged C~3 10518'. Correct CTD to 10521'. 0.50 DRILL P PROD1 Orient TF to 30R. 1.00 DRILL P PROD1 Drill f/ 10521' - 10577' P off/on btm: 3350 psi/ 3750 psi. PU wt: 39K Ib, So wt: 21 K Ib, drilling wt: 18K-15K Ib. O in/out: 2.6/2.6 bpm TF: 50R Pits: 259 bbl 0.33 DRILL P PROD1 Orient TF to 20L 2.17 DRILL P PROD1 Drill f/ 10577' - 10673' P off/on btm: 3450 psi 13850 psi PU wt: 39K Ib, SO wt: 21 K Ib ,drilling wt: 17.5K - 16K Ib O inlout: 2.6512.65 bpm TF: 20R - 20L, Pits: 253 bbl 2.00 DRILL P PROD1 Wiper trip to window. Printed: 11/28/2005 12:58:49 PM BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 1 5-48B Common W ell Name: 1 5-486 Spud Date: 11!1412005 Event Nam e: REENTE R+COM PLET E Start : 11!14/2005 End: 11/25/2005 Contractor Name: NORDIC CALIS TA Rig Release: 11!25/2005 Rig Name: NORDIC 1 Rig Number: 1 Date I From - To j Hours ~ Task j Code j NPT ~, Phase I I Description ofi Operations. 11/19/2005 12:00 - 14:45 2.75 DRILL P PROD1 Drill f/ 10673' - 10778' P off/on btm: 3450 psi/4000 psi PU wt: 39K Ib, SO wt: 21K Ib, drilling wt: 15K Ib Q in/out: 2.65/2.65 bpm TF: 0, pits Orient time: 15°1° 14:45 - 15:30 0.75 DRILL P PROD1 Orient TF. Difficulty orienting/holding TF. PU above shale to shake out trapped torque. 15:30 - 16:00 0.50 DRILL P PROD1 Drill f/ 10778' - 10818'. 16:00 - 18:40 2.67 DRILL P PROD1 Wiper trip to window. Tie-in: +4' correction RBIH to btm tagged @ 10821'. 18:40 - 18:55 0.25 DRILL P PROD1 Orient TF to 140L. Up wt = 40k, Run-in wt = 22k, IAP = 1100psi, OAP = Opsi, freespin 2.65bpm/3450psi, PVT = 235bb1s. 18:55 - 19:25 0.50 DRILL P PROD1 Drill to 10856' with 135-145L TF, 2.65/2.65bpm, 3450/3650psi, 4k WOB & 75fph ave ROP. 19:25 - 19:50 0.42 DRILL P PRODi Orient TF around to 165L. 19:50 - 20:25 0.58 DRILL P PRODi Drill to 10883' with LS TF, 2.65/2.65bpm, 3450/3875psi, 4k WOB & 50fph ave ROP. 20:25 - 20:35 0.17 DRILL P PROD1 Orient TF to 120L. 20:35 - 20:55 0.33 DRILL P PROD1 Drill to 10915' with 120E TF, 2.65/2.65bpm, 3500/3875psi, 4k WOB & 110fph ave ROP. 20:55 - 21:20 0.42 DRILL P PROD1 Orient 2 clicks & drill to 10937' with 100-135L TF, 2.65/2.65bpm, 3450/3875psi, 4k WOB & 50fph ave ROP. TF rolling right. 21:20 - 22:00 0.67 DRILL P PROD1 Short 200' wiper, 22:00 - 22:45 0.75 DRILL P PROD1 Orien 1 click & drill to 10980' with 85L TF, 2.65/2.65bpm, 3450/3950psi, 4k WOB & 55fph ave ROP. 22:45 - 23:05 0.33 DRILL P PROD1 Orient 1 click & drill to 11000' with 75L TF, 2.65/2.65bpm, 3450/3900psi, 4k WOB & 50fph ave ROP. 23:05 - 00:00 0.92 DRILL P PROD1 Wiper trip clean to window. P/U wt = 40k. 11/20/2005 00:00 - 00:50 0.83 DRILL P PROD1 RBIH to btm. 00:50 - 01:15 0.42 DRILL P PROD1 Orient TF around to 90R. 01:15 - 02:05 0.83 DRILL P PROD1 Drill to 11059' with 100-110R TF, 2.65/2.65bpm, 3600/3900psi, 4.5k WOB & 50fph ave ROP. Meanwhile swap the wellbore to new 8.6 ppg Flo-Pro mud with 3% L-T & 12ppb K-G. 02:05 - 02:30 0.42 DRILL P PROD1 Orient TF around to 40R. 02:30 - 03:20 0.83 DRILL P PROD1 Orient & drill to 11115' with 55-90R TF, 2.65l2.65bpm, 3450/3950psi, +/-5k WOB & 75fph ave ROP. 03:20 - 04:05 0.75 DRILL P PROD1 Orient & drill to 11150' with 100-110R TF, 2.65l2.65bpm, 3450/3950psi, +/-5k WOB & 85fph ave ROP. 04:05 - 05:45 1.67 DRILL P PROD1 Wiper trip clean to window. P/U wt = 40k. 05:45 - 06:00 0.25 DRILL P PROD1 Orient TF to 140L. 06:00 - 06:45 0.75 DRILL P PROD1 Continue RIH after wiper trip to window. Pits: 277 bbl. 06:45 - 09:45 3.00 DRILL P PROD1 Drill f/ 11150 - 11277 P off/on btm: 3450 psi/3650 psi. PU wt: 39K Ib, SO wt: 21 K Ib, drilling wt: 18.5K - 15K Ib. O in/out: 2.6/2.6 bpm TF: 90L, Pits: 271 bbl. ~ Orient time 10°l° Printed: 17/28/2005 12:58:49 PM • BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Wel! Name: 15-486 Common Well Name: 15-48B Spud Date: 11/14/2005 Event Name: REENTER+COMPLETE Start: 11/14/2005 End: 11/25/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/25/2005 Rig Name: NORDIC 1 Rig Number: 1 Date From - To ~ Hours I'~ Task j Code I NPT ! Phase ~~ Description of Operations __ __ ------ I 11/20/2005 09:45 - 10:00 0.25 DRILL P PRODi Orient. 10:00 - 10:30 0.50 DRILL P PRODi Drill f/ 11277' - P off/on btm: 3450 psi/ PU wt: 38.5K Ib, SO wt: 19K Ib, drilling wt: O in/out: 2.55/2.55 TF: 120E - 160L, Pits:269 bbl. Orient time: 20% LSRV too high (82K), P off btm still high, bring out 50 bbl of base mud to add to mud system and bring down LSRV. 10:30 - 12:00 1.50 DRILL P PROD1 Wiper trip. 12:00 - 12:30 0.50 DRILL P PROD1 Tie-in to RA tag. +8.5' correction. 12:30 - 13:30 1.00 DRILL P PROD1 RIH back into hole after wiper. Pits: 313 bbl. 13:30 - 14:45 1.25 DRILL P PROD1 Drill f/ 11315' - 11350'. P offion btm: psis 3615 psi. O in/out: 2.612.6 bpm. Drilling wt: -17K - 16K Ib. TF: 160L, Pits: 311 bbl. Est instant ROP: 35-55 ft/hr. 14:45 - 15:00 0.25 DRILL P PROD1 Orient. 15:00 - 18:00 3.00 DRILL P PROD1 Drill f/ 11350' - 11475' P off/on btm: 3300 psi/ 3600 psi. Drilling wt: 17K - 15K Ib. Pits:302 bbl Est instant ROP: 35-55 ft/hr. Last 20 ft ROP: 100'+ fUhr. 18:00 - 20:30 2.50 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 20:30 - 21:00 0.50 DRILL P PRODi Orient TF around to 100L. Up wt = 40k, Run-in wt = 20k, IAP = 1060psi, OAP = Opsi, freespin 2.65bpm/3400psi, PVT = 289bb1s. 21:00 - 21:45 0.75 DRILL P PROD1 Drill to 11530' with 115E TF, 2.65/2.65bpm, 3400/3850psi, +!-4k WOB & 100fph ave ROP. 21:45 - 22:25 0.67 DRILL P PROD1 Orient TF around to 160L. 22:25 - 23:15 0.83 DRILL P PROD1 Drill to 11570' with 130E TF, 2.65/2.65bpm, 3400/3850psi, +/-4k WOB & 80fph ave ROP. Drilled into shale @ 11535'. Getting sticky & pulling heavy. 23:15 - 23:25 0.17 DRILL P PROD1 Short BHA wiper. 23:25 - 23:35 0.17 DRILL P PROD1 Orient TF to 35L. 23:35 - 23:55 0.33 DRILL P PROD1 Drill shale to 11577' with 40L TF, 2.65/2.65bpm, 3400/3850psi, +/-10k WOB & 30fph ave ROP. Stacking wt. 23:55 - 00:00 0.08 DRILL P PROD1 Orient TF around to 110L. 11/21/2005 00:00 - 00:15 0.25 DRILL P PROD1 Continue orienting TF to 110L. 00:15 - 01:25 1.17 DRILL P PROD1 Drill to 11604' with 135E TF, 2.65/2.65bpm, 3400/3850psi, +/-10k WOB & 15fph ave ROP. 01:25 - 02:00 0.58 DRILL P PROD1 Orient 2 clicks & drill to 11625' with 105E TF, 2.65/2.65bpm, 3400/3850psi, +/-7k WOB & 45fph ave ROP. 02:00 - 04:15 2.25 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 04:15 - 05:20 1.08 DRILL P PROD1 Orient 2 clicks & drill to 11641' with 105E TF, 2.65/2.65bpm, 3400/3850psi, +/-7k WOB & 15fph ave ROP. Stacking & drilling ratty in shale. Geo calls TD C«~ 11641' (8872.2'ssvd). 05:20 - 06:20 1.00 DRILL P PROD1 Wiper trip clean to window. 06:20 - 06:40 0.33 DRILL P PROD1 Tie-in: +7.5' correction. Printed: 11/28/2005 12:68:49 PM BP EXPLORATfON Page 8 of 10 Operations Summary Report Legal Well Name: 1 5-48B Common W ell Name: 1 5-486 Spud Date: 11/14/2005 Event Nam e: REENTE R+COM PLET E Start : 1 1 /1 412005 End: 11/25/2005 Contractor Name: NORDIC CALIST A Rig Release: 11!25/2005 Rig Name: NORDIC 1 Rig Number: 1 Date ~ From - To ~ Hours I Task Code ~ NPT ~ i Phase ~ Description of Operations 11/21/2005 06:40 - 09:15 2.58 DRILL P PROD1 RIH after tie-in. Tag btm at 11,646'. 09:15 - 12:00 2.75 DRILL P PROD1 POOH. Lay-in liner pill. Paint flags at 8900' EOP & 6500' EOP. 12:00 - 13:00 1.00 DRILL P PROD1 LD BHA. 13:00 - 13:30 0.50 CASE P RUNPRD Put on Baker CTC Pressure test to 3500 psi. Pull test to 45K Ib. 13:30 - 14:45 1.25 CASE P RUNPRD Dart coil. 14:45 - 15:00 0.25 BOPSU P RUNPRD Conduct weekly BOP function test. 15:00 - 15:30 0.50 CASE P RUNPRD Safety meeting for running liner. Discussed overhead hazards, pinch points, and well control. 15:30 - 20:45 5.25 CASE P RUNPRD M/U 2-7/8" STL rotating guide shoe, float collar, 1 shoe jt, float collar & landing collar. M/U 66jts of 2-7/8" STL 6.16# L-80 liner & LSL sub. M/U 14jts of 3-3/16" 6.2# L-80 TCII, , 3-3/16" pup, XO, 1 jt of 3-1/2" 9.3# L80 STL, X nipple & 3-1/2" pups. M/U BKR deploy sleeve &CTLRT. OAL - 2660.84'. 20:45 - 23:00 2.25 CASE P RUNPRD RIH with liner, circ @ min rate. Correct CTD -i2.3' @ 1st flag. Wt check: Up = 43k. Run-in wt = 20k. Continue RIH smoothly C~ 40tpm thru window. Set down in shales @ 11257', 11387', 11448', 11477'. P/U & run thru. 23:00 - 00:00 1.00 CASE N RUNPRD Set down in shale @ 11541'. Work CT without success. Attempt to bounce thru shale without luck. 11!22(2005 00:00 - 00:45 0.75 CASE N RUNPRD Wash down @ 2.16/2.16bpm & 2950psi. PUH & RBIH several times @ +1-100fpm. Tag hard @ 11542' CTD. Not making any progress. Consult with ANC & decided to set Inr @ 11542'. This will place the PBTD @ 11506' -will lose +/-24' of planned pert interval. PUH Q 50k to ball drop position. 00:45 - 01:25 0.67 CASE P RUNPRD Establish circ. Load 5/8" AL ball &circ with @ 2.3/2.3bpm & 3000psi. Set down 10k down on CTLRT. Continue circ ball to seat. Slow down ~ 44bbls away. Ball on seat C 50.6bbls. Pressure up to 4600psi & release CTLRT. P/U ~ 38k & confirm release. 01:25 - 03:15 1.83 CASE P RUNPRD Circ well to 2% KCL water with double friction reducer C~3 3/3bpm & 1750 psi. Send used FloPro to MI for reconditioning. Meanwhile R/U SLB cementers. 03:15 - 03:30 0.25 CEMT P RUNPRD PJSM w/ SLB cementers. 03:30 - 04:00 0.50 CEMT P RUNPRD Batch up. 04:00 - 05:15 1.25 CEMT P RUNPRD PT hardline. Pump 10 bbl KCI spacer, 32.6 bbl cmt, 30 bbl Bio-KCI. Plug bumped at 15.2 bbl (16.1 theoritical}. Floats held. 05:15 - 07:30 2.25 CEMT P RUNPRD POOH 07:30 - 08:30 1.00 EVAL P LOWERI LD liner running BHA. 08:30 - 08:45 0.25 EVAL P LOWERI Safety meeting w/ SLB loggers. Discussed radioactivity, pinch pints, overhead loads. 08:45 - 10:00 1,25 EVAL P LOWERi Make up logging/cleanout BHA. 10:00 - 10:45 0.75 EVAL N RREP LOWERI Wait on SLB techs to troubleshoot pump trips. 10:45 - 12:30 1.75 EVAL P LOWERI RIH with logging BHA on coil. 12:30 - 14:30 2.00 EVAL P LOWERI Log f/ 8800' down to TD. 14:30 - 15:30 1.00 EVAL P LOWERI Log up at 60 fpm to 8600'. 15:30 - 17:15 1.75 EVAL N FLUD LOWERI RIH and Re-log patchy spots while reloading new pert pill Printed: 11/28/2005 12:58:49 PM BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: 15-486 Common Well Name: 15-48B Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To it Hours 'I Task ~~ Code Ij NPT _- _a- -- 11/22/2005 17:15 - 19:20 2.08 EVAL P 19:20 - 22:20 3.00 EVAL P 22:20 - 22:55 0.58 BOPSU P 22:55 - 00:00 1.08 EVAL P 11/23/2005 100:00 - 01:50 I 1.831 EVAL I P 01:50 - 02:50 I 1.001 CASE I P 02:50 - 06:30 ~ 3.67 ~ CASE ~ P 06:30 - 08:30 2.00 CASE P 08:30 - 09:00 0.50 CASE P 09:00 - 10:45 1.75 CASE P 10:45 - i 1:45 I 1.001 CASE I P 11:45 - 12:15 0.50 CASE P 12:15 - 12:30 0.25 CASE P 12:30 - 13:00 0.50 CASE P 13:00 - 15:00 2.00 CASE N 15:00 - 16:00 I 1.001 CASE I P 16:00 - 17:00 1.00 CASE N 17:00 - 00:00 7.00 CASE P 11 /24/2005 100:00 - 09:00 I 9.00 I CASE I P 09:00 - 10:30 1.501 CASE P 10:30 - 12:30 I 2.001 CASE I P 12:30 - 13:30 1.00 CASE P 13:30 - 14:15 0.75 CASE P Spud Date: 11/14/2005 Start: 11/14/2005 End: 11/25/2005 Rig Release: 11!2512005 Rig Number: 1 Phase j Description of Operations LOWERI POH to BHA, stand back injector, layed in 20 bbls pert pill LOWERI POH w/ BHA, Stand back 45 stds of 1 1/4" CS Hydril tbg, LD logging tools, motor and mill LOWERI MU swivel stick, flush out BOP stack and tree, RD LOW ER1 Pressure up on Liner Lap to 2000 psi, pressure fell off to 1775 psi in 20 min, test failed, check surface lines, wellhead and tree for leaks, no leaks found, circ coil to prevent freeze up, second attempt to test liner lap to 2000 psi, pressure fell off to 1800 psi in 10 min, test failed, no visible surface leaks found LOWERI Circ through coil, loading pipe shed with 3 1/2" tubing, strap and drift same. Waiting on Baker w/ LTP RUNPRD PU Baker equipment, MU LTP assy w/ seal stringer, hyd. disconnect, 2 jts of 2 3!8" PH-6 and CTC, install injector RUNPRD RIH w/ LTP Assy, Up wt 39 k, S/O wt 23 k, stung in depolyment sleeve at 8890' w/ pumps, pressure increased to 400psi, bled off pressure slacked off w/ 10 k, PU, unstung f/ deployment sleeve, dropped 518" ball, circ ball down on seat, sting back into deployment sleeve, set packer w! 2000 psi and 10 K below S/O Wt RUNPRD Pressure up on Liner Lap to 2000 psi RUNPRD LD pkr assy, PU nozzle to PT LTP. RUNPRD Close master and swab. PT surface lines to 2100 psi. Held for 10 minutes. Open master and swab, double block IA. Repressurize as needed. After third repressurization, press. held at 2000 psi for over ha{f an hour with only 50 psi bleedoff. IA increased to 2500 and held, total of 3.6 bbls pumped into wellbore to PT. RUNPRD Conduct safety meeting for PU liner tongs. PU and load special liner tongs with crane and rig. Load onto floor. RUNPRD PU new elevators, RU and test tongs. Held. RUNPRD Conduct safety meeting for running liner RUNPRD MU seal and locator assy on bottom of liner RUNPRD Rigs slips are missing, ordered out a new set from BHI. Wrong set brought out. Wait for new set. RUNPRD RIH w/ 11 jts 3.5" liner. Slips not locking so pipe is slipping. Order out new bowl, slips, and dyes. RUNPRD Wait on supplies. RUNPRD PU, RIH w/ 83 joints of 3.5" 9.2# 13CR ST-L liner, MU Torque 1600 Ft-Lbs, box and pin ends doped with a lite coat of jet Tube seal .guard. Note - C/O 4 joints due to improper MU. RUNPRD Continued PU, RIH w! 3.5" 9.2# i3CR ST-L liner, reduced MU Torque f/ 1600 ft-Ibs to 1500 Ft-Lbs, box and pin ends doped with a lite coat of jet tube seal guard. Note, C/O a total of 8 jts since job started due to improper MU, causing box and pin to flare out w/ 1500 and i 600 ft-Ibs of torque. RUNPRD RU coil, GS spear, and deployment sleeve to RIH w! liner. Establish circulation RUNPRD RIH w/liner and coil to 8400' at 30 fpm. -Q 1230 hrs, begin displacing with new 2% KCI. RUNPRD Displace KCI with 77 bbls fresh brine. RUNPRD RIH w/ CT and liner at 30 fpm to 8800' while displacing. Tag up at 8879'. Test pkr seal to 2000 psi. Held. Sit on pkr w/ 5K hanging wt, press. up to 500 psi, slowly PU on CT. Pulled free Printed: 11/28/2005 12:58:49 PM • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 1 5-486 Common W ell Name: 1 5-48B Spud Date: 1 1 /1 412005 Event Nam e: REENTE R+COM PLET E Start : 11/14/2005 End: 11/25/2005 Contractor Name: NORDIC CALIS TA Rig Release: 11/25/2005 Rig Name: NORDIC 1 Rig Number: 1 I Date i From - To I Hours ! Task I, Code I NPT j Phase ~ I Description of Operations 11/24/2005 13:30 - 14:15 0.75 CASE P RUNPRD with 12.5K wt. POOH. 14:15 - 15:30 1.25 CASE P RUNPRD POOH w/ CT. 15:30 - 16:00 0.50 CASE P RUNPRD RD csg tongs, BHI tools. Clear floor. 16:00 - 16:15 0.25 CASE P RUNPRD Conduct safety meeting for removing tongs off of floor with crane. 16:15 - 16:45 0.50 CASE P RUNPRD Remove tongs off of floor with crane. 16:45 - 17:00 0.25 PERFO P LOW ER1 Conduct safety meeting for PU perf guns 17:00 - 17:15 0.25 PERFO P LOWERI RU to run 33 - 2" HDS 2006PJ 6 spf 60 degree phasing perf guns 17:15 - 18:50 1.58 PERFO P LOWERI RIH w133 perf guns 18:50 - 20:00 1.17 PERFO P LOWERI RIH w/ 33 stds of 1 1/4" CSH, Check all intermediate connections, Pu injector. 20:00 - 00:00 4.00 PERFO N WAIT LOWERI Unable to stab on weld on CTC, OD to big to fit inside coil, sent to machine shop to be turned down 11/25/2005 00:00 - 01:15 1.25 PERFO P LOWERI Weld on CTC, pull test w/ 35 k, P/T to 3500 psi, MU to BHA and stab onto well 01:15 - 03:15 2.00 PERFO P LOWERI RIH wJ perf gun assy to Top of liner Up at 8877', Up Wt 39.5K, Dn 23K, RIH to corrected PBTD of 11507.6' 03:15 - 03:55 0.67 PERFO P LOWERI Pump 10 bbl perf pill, Drop 1/2" ball, displace w/ 5 bbl perf pill plus 2% KCL 57 bbl (coil volume 60.6 bbl), Pressure up to 3650 psi, Fire guns on the fly w/ bottom shot at 11500' and top shot at 10820', Pits: 316 bbl. 03:55 - 06:00 2.08 PERFO P LOWERI POH to perf gun assy holding 400 psi on choke 06:00 - 06:30 0.50 PERFO P LOWERI Check for flow at surface. Static. Begin to RD 06:30 - 08:00 1.50 PERFO P LOWERI RD injector. SB 33 stds of CSH 08:00 - 08:15 0.25 PERFO P LOWERI Conduct safety meeting to LD perf guns 08:15 - 10:00 1.75 PERFO P LOWERI LD 33 perf guns 10:00 - 11:00 1.00 PERFO P LOW ER1 PU LTP and running equipment- total BHA length is 78.5 feet. 11:00 - 12:15 1.25 PERFO P LOWERI RIH w/ LTP at 75 fpm to TOL (4017'). 12:15 - 13:15 1.00 PERFO P LOWERI Tag at 4018'. Set down 7K Ibs, PU to 4010'. Drop 5/8" ball and circ. at 2.5 bpm. Ball bumped at 50.1 bbls. Bleed pressure off and RBIH to tag up. PU to string wt plus 1 foot. Press up to 2200 psi. Hold press while SO to 7K. Hold press while PU to string wt. Pump down backside to 2000 psi and test. 13:15 - 13:45 0.50 PERFO P LOW ER1 Hold 2000 psi and test for .5 hrs. held. 13:45 - 14:00 0.25 PERFO P LOWERI Bleed down backside and coil. Press up coil to 3825 and shear from LTP. Bleed press and sting off. Coil free. POOH. 14:00 - 14:45 0.75 PERFO P LOWERI POOH w/ coil and LTP setting assy. 14:45 - 15:00 0.25 PERFO P LOW ERi LD LTP setting assy, PU jet 15:00 - 15:45 0.75 PERFO P LOWERI RIH to 2500' and lay in McOH to freeze protect well 15:45 - 16:00 0.25 PERFO N LOWERI Lose the generators. SD and wait on maintanence. 16:00 - 16:30 0.50 PERFO P LOWERI Finish POOH. 16:30 - 16:45 0.25 PERFO P LOWERI Conduct safety meeting for blowing down reel 16:45 - 18:30 1.75 RIGD P LOWERI Displace coil volume with N2. Suck pits, coil, tanks dry with vac trucks. 18:30 - 19:00 0.50 RIGD P LOWERI PJSM -discussed RD operations for rig prep 19:00 - 19:30 0.50 RIGD P LOWERI Load pipeshed with excess tubulars left on location for rig move 19:30 - 20:30 1.00 BOPSU P LOWERI RD BOP Stack, Install and test tree cap, secure well and release rig at 20:30 hours on 1 1/2512005 Primed: 11/28/2005 12:58:49 PM BPXA North Slope Alaska BPXA 15-48B Job No. AKMW4054361, Surveyed: 21 November, 2005 Survey Report 1 December, 2005 Your Ref.• API 500292263502 Surface Coordinates: 5960178.18 N, 676192.85E (70° 17' 48.4446" N, 148° 34' 23.3313" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 66.70ft above Mean Sea Leve/ 1 t? I"~ 1""~ 1~- 5 C J!"1 [l~tt->~~ro~ se"~iv~c~s SurveyRef.•svy4768 A Ha9litrurten Campaay • • BPXA Survey Report for 15-488 Your Ref.• APl 500292263502 Job No. AKMW4054361, Surveyed: 21 November, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9188.44 48.270 259.800 8772,98 8839.68 318.05 S 1224.55 W 5959831.51 N 674976.09E 525.86 Tie On Point 9195.00 48.730 260.590 8777,33 8844.03 318.89 S 1229.39 W 5959830.56 N 674971.27E 11.420 527.52 Wlndow Point 9234.13 59.120 248.800 8800.39 8867.09 327.41 S 1259.71 W 5959821.33 N 674941.16E 35.960 541.18 9269.08 68.720 240.200 8815.76 8882.46 340.98 S 1287.93 W 5959807.10 N 674913.27E 35.225 559.44 9300.82 73.390 230.700 8826.09 8892,79 358.00 S 1312.59 W 5959789.51 N 674889.01E 31.892 580.49 9328.86 78.120 222.150 8833.00 8899.70 376.73 S 1332.24 W 5959770.33 N 674869.80E 34.020 602.34 9343.68 82.560 219.320 8835.48 8902.18 387.79 S 1341.77 W 5959759.04 N 674860.54E 35.380 614.90 9375.48 90.480 213.330 8837.41 8904.11 413.34 S 1360.55 W 5959733.06 N 674842.37E 31.197 643.32 9408.42 89.870 209.630 8837.31 8904.01 441.43 S 1377.74 W 5959704.58 N 674825.83E 11.384 673.96 9440.29 90.090 203.730 8837.33 8904.03 469.89 S 1392.05 W 5959675.79 N 674812.20E 18.526 704.48 9475.88 92.280 198.980 8836.59 8903.29 503.02 S 1405.00 W 5959642.36 N 674800,03E 14.693 739.35 9506.58 91.140 195.640 8835.67 8902.37 532.31 S 1414.13 W 5959612.86 N 674791.59E 11.491 769.78 9538.85 90.220 190.000 8835.29 $901.99 563.76 S 1421.29 W 5959581.26 N 674785.17E 17.707 802.00 9571.09 91.580 185.970 8834.78 8901.48 595.68 S 1425.76 W 5959549.24 N 674781.44E 13.191 834.21 9603.93 90.260 181.230 8834.25 8900.95 628.44 S 1427.82 W 5959516.44 N 674780.15E 14.981 866.83 9634.11 89.380 179.470 8834.35 8901.05 658.61 S 1428.01 W 5959486.27 N 674780.67E 6.520 896.58 9663.98 88.770 175.780 8834.83 8901.53 688.45 S 1426.77 W 5959456.47 N 674782.61E 12.520 925.75 9696.04 87.840 172.440 8835.78 8902.48 720.32 S 1423.48 W 5959424.69 N 674786.65E 10.810 956.56 9731.68 88.280 177.580 8836.99 8903.69 755.79 S 1420.39 W 5959389.29 N 674790.57E 14.466 990.96 9761.82 88.250 181.310 8837.90 8904.60 785.91 S 1420.09 W 5959359.19 N 674791.57E 12.370 1020.57 9795.00 88.980 186.040 8838.70 8905.40 819.01 S 1422.22 W 5959326.06 N 674790.22E 14.420 1053.53 9824.43 88.980 187.630 8839.23 8905.93 848.22 S 1425.72 W 5959296.77 N 674787.41E 5.402 1082.91 9856.45 88.420 191.950 8839.95 8906.65 879.76 S 1431.16 W 5959265.11 N 674782.70E 13.601 1114.91 9889.26 87.270 194.760 8841.19 8907.89 911.66 S 1438.74 W 5959233.05 N 674775.88E 9.248 1147.64 9921.86 87.020 193.330 8842.81 8909.51 943.24 S 1446.64 W 5959201.28 N 674768.72E 4.448 1180.12 9953.70 87.980 190.900 8844.20 8910.90 974.34 S 1453.31 W 5959170.04 N 674762.78E 8.199 1211.90 9990.02 88.990 185.860 8845.16 8911.86 1010.25 S 1458.60 W 5959134.02 N 674758.33E 14.148 124$.18 10024.42 86.920 183.340 8846.39 8913.09 1044.51 S 1461.36 W 5959099.70 N 674756.38E 9.476 1282.40 10055.38 87.100 184.390 8848.00 8914.70 1075.36 S 1463.44 W 5959068.81 N 674755.02E 3.436 1313.14 10088.67 87.980 189.670 8849.43 8916.13 1108.35 S 1467.51 W 5959035.73 N 674751.72E 16.065 1346.35 10116.93 90.440 189.140 8849.82 8916.52 1136.23 S 1472.13 W 5959007.75 N 674747.76E 8.905 1374.60 10150.68 86.920 192.480 8850.60 8917.30 1169.36 S 1478.46 W 5958974.48 N 674742.22E 14.375 1408.33 10184.30 87.540 197.930 8852.23 8918.93 1201.75 S 1487.26 W 5958941.89 N 674734.17E 16.296 1441.76 10227.21 88.240 201.980 8853.81 8920.51 1242.05 S 1501.89 W 5958901.26 N 674720.49E 9.572 1483.98 10259.77 $8.680 202.150 8854.68 8921.38 1272.22 S 1514.12 W 5958870.82 N 674708.97E 1.449 1515.81 • 1 December, 2005 - 11;04 Page 2 of4 DrillQuest 3.43.06.008 BPXA Survey Report for 15-486 Your Ref.' API 500292263502 Job No. AKMW4054361, Surveyed: 21 November, 2D05 North Slope Alaska Measured Depth (ft) 10291.50 10324.80 10355.33 10389.78 10430.13 Incl. 88.240 91.140 91.080 88.330 87.100 True Azim. 207.950 208.650 211.810 216.740 220.950 10464.86 10494.98 10530.76 10564.49 10600.21 10636.88 10670.72 10710.20 10746.57 10777.94 10807.28 10839.72 10858.83 10896.18 10926.22 10968.61 11007.66 11036.01 11066.69 11113.64 11148.59 11179.66 11225.28 11263.65 11300.71 85.690 89.030 89.960 89.070 89.250 89.510 89.870 89.520 91.370 94.540 95.950 94.890 92.330 89.430 88.210 88.110 89.600 88.550 88.630 89.960 221.660 220.600 224.430 221.610 224.960 221.440 214.740 215.270 213.150 212.450 209.100 204.690 201.170 199.760 196.790 192.010 195.180 196.770 199.060 205.400 88.810 209.100 88.280 205.930 89.600 202.400 92.600 198.180 90.220 194.120 11344.42 86.700 190.420 11380.09 85.990 189.720 11415.75 84.320 186.370 11461.52 89.070 180.730 11483.20 89.690 178.440 Sub-Sea Depth (ft) 8855.54 8855.72 8855.12 8855.30 8856.91 8859.10 8860.48 8860.80 8861.08 8861.61 8862.00 8862.19 8862.40 8862.12 8860.50 8857.82 8854.75 8853.55 8852.97 8853.59 8854.95 8855.73 8856.19 8856.95 8857.53 8857.90 8858.69 8859.53 8858.80 8857.88 8859.06 8861.33 8864.35 8866.99 8867.22 Vertical Depth (ft) 8922.24 8922.42 8921.82 8922.00 8923.61 8925.80 8927.18 8927.50 8927.78 8928.31 8928.70 8928.89 8929.10 8928.82 8927.20 8924.52 8921.45 8920.25 8919.67 8920.29 8921.65 8922.43 8922.89 8923.65 8924.23 8924.60 8925.39 8926.23 8925.50 8924.58 8925.76 8928.03 8931.05 8933.69 8933.92 Local Coordinates Northings Eastings (ft) (ft) 1300.94 S 1527.54 W 1330.26 S 1543.33 W 1356.63 S 1558.69 W 1385.08 S 1578.09 W 1416.48 S 1603.37 W 1442.51 S 1626.25 W 1465.17 S 1646.03 W 1491.54 S 1670.21 W 1516.20 S 1693.22 W 1542.19 S 1717.70 W 1568.92 S 1742.80 W 1595.54 S 1763.66 W 1627.87 S 1786.31 W 1657.95 S 1806.75 W 1684.28 S 1823.72 W 1709.37 S 1838.67 W 1738.17 S 1853.27 W 1755.73 S 1860.70 W 1790.71 S 1873.76 W 1819.23 S 1883.17 W 1860.25 S 1893.71 W 1898.20 S 1902.88 W 1925.45 S 1910.69 W 1954.63 S 1920.12 W 1998.06 S 1937.87 W 2029.13 S 1953.87 W 2056.67 S 1968.22 W 2098.28 S 1986.89 W 2134.25 S 2000.18 W 2169.82 S 2010.49 W 2212.51 S 2019.77 W 2247.55 S 2025.99 W 2282.73 S 2030.97 W 2328.31 S 2033.79 W 2349.98 S 2033.63 W Global Coordinates Northings Eastings (ft) (ft) 5958841.79 N 674696.23 E 5958812.11 N 674681.13 E 5958785.39 N 674666.39 E 5958756.48 N 674647.67 E 5958724.51 N 674623.13 E 5958697.94 N 674600.87 E 5958674.82 N 674581.62 E 5958647.90 N 674558.07 E 5958622.71 N 674535.64 E 5958596.14 N 674511.78 E 5958568.84 N 674487.31 E 5958541.74 N 674467.08 E 5958508.88 N 674445.20 E 5958478.33 N 674425.46 E 5958451.61 N 674409.11 E 5958426.17 N 674394.76 E 5958397.04 N 674380.83 E 5958379.31 N 674373.82 E 5958344.03 N 674361.59 E 5958315.30 N 674352.84 E 5958274. 04 N 674343.27 E 5958235. 89 N 674334.99 E 5958208. 47 N 674327.83 E 5958179. 07 N 674319.08 E 5958135. 24 N 674302.35 E 5958103. 81 N 674287.09 E 5958075. 93 N 674273.39 E 5958033. 90 N 674255.70 E 5957997. 63 N 674243.25 E 5957961. 82 N 674233.78 E 5957918.93 N 674225.50 E 5957883.75 N 674220.10 E 5957848.46 N 674215.96 E 5957802.84 N 674214.20 E 5957781.17 N 674214.87 E Dogleg Rate (°/100ft) 18.325 8.959 10.350 16.385 10.862 4.544 11.633 11.015 8.767 9.391 9.625 19.827 1.609 7.736 10.348 12.344 13.922 22.745 8.633 10.686 11.273 8.968 6.720 7.466 13.796 11.085 10.341 8.260 13.491 12.695 11.680 2.792 10.467 16.092 10.942 Vertical Section 1546.43 1578.04 1606.68 1638.07 1673.38 1702.99 1728.74 1758.91 1787.19 1817.04 1847.72 1877.55 1913.33 1946.50 1975.37 2002.69 2033.58 2052.16 2088.88 2118.60 2160.83 2199.79 2227.98 2258.36 2304.21 2337.58 2367.20 2411.42 2449.15 2485.98 2529.62 2565.22 2600.72 2646.10 2667.42 BPXA Comment • 1 December, 2005 - 11:04 Page 3 of 4 DrillQuest 3.03.06.008 BPXA Survey Report for 15-488 Your Ref.• APl 500292263502 Job No. AKMW4054361, Surveyed: 21 November, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11538.29 87.400 173.680 8868.62 8935.32 2404.90 S 2029.85 W 5957726.35 N 674219.94 E 11571.85 89.070 172.620 8869.65 8936.35 2438.21 S 2025.85 W 5957693.15 N 674224.72 E 11606.69 87.490 165.400 8870.70 8937.40 2472.37 S 2019.22 W 5957659.15 N 674232.15 E 11646.00 87.490 165.400 8872.42 8939.12 2510.37 S 2009.32 W 5957621.39 N 674242.94 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 190.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11646.OOft., The Bottom Hole Displacement is 3215.48ft., in the Direction of 218.674° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) {ft) (ft) 9188.44 8839.68 318.05 S 1224.55 W Tie On Point 9195.00 8844.03 318.89 S 1229.39 W Wlndow Point 11646.00 8939.12 2510.37 S 2009.32 W Projected Survey Survey tool program for 15-48B From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 11646.00 8939.12 MWD Magnetic (15-48) BPXA Dogleg Vertical Rate Section Comment (°/100ft) 9.585 2720.85 5.893 2752.95 21.204 2785.44 0.000 2821.15 Projected Survey • • 1 December, 2005 - 11:04 Page 4 of 4 DrillQuest 3.03.06.008 • 06-Dec-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-48B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,188.44' MD Window /Kickoff Survey: 9,195.00' MD (if applicable) Projected Survey: 11,646.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorag , AK 99518 Date ~ h-~1i,~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • ~ ~ ~ ~ ~~ a ~~ '~ ~~s~ ,~ ~ ~~ ~ ~ ~~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~~ ~«/ v0-7 ~~ 333 W. T" AVENUE, SUITE 100 COI~TSFRQA'I'IO1~T COrII~iISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Barbara Holt CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU 15-48B BP Exploration (Alaska), Inc. Permit No: 205-166 Surface Location: 3971' FSL, 5021' FEL, SEC. 22, T11N, R14E, UM Bottomhole Location: 1416' FSL, 1780' FEL, SEC. 21, T11N, R14E, UM Dear Ms. Holt: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager) . DATED this~day of November, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Chairman STATE OF ALASKA ALASKA~L AND GAS CONSERVATION CO ISSION PERMIT TO DRILL 20 AAC 25.005 ~~~~~a5 ~~' ~~ ~. ~i,~~j5 ~:~~~~ ~'ar~z= 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 15-488 ~~(¢ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11800 TVD 8880ss 12. Field /Pool(s): Prudhoe Bay Field !Prudhoe Bay 4a. Location of Well (Governmental Section): Surtace: 3971' FSL 5021' FEL SEC 22 T11 N R14E UM 7. Property Designation: ADL 028306 Pool , , , , , . Top of Productive Horizon: 3640' FSL, 1102' FEL, SEC. 21, Ti 1 N, R14E, UM 8. Land Use Permit: 13. Approximate Spu a e: Novemb 8, 005 Total Depth: 1416' FSL, 1780' FEL, SEC. 21, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Neares Property: 26,200' 4b. Location of Well (State Base Plane Coordinates); Surface: x-676193 -5960178 Zone-ASP4 10. KB Elevation (Height above GL): 66.7' feet 15. Distance to Nearest We11 within Pool 450' 16. Deviated Wells: Kickoff Depth: 9205 feet Maximum Hole Angle: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 Surtace: 2371 18. asing rogram: Size 'Specifications Setting Depth To Bottom uant~ty of ement c.f. or sacks Hote Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data a-iia• X 3.3/a• 3-3/~s• x zare• 6.2# / 6.16# L-80 STL 2800' 9000' 8626' 11800' 8880' 165 sx Class 'G' Scab Liner 3-1/2" 9.2# 13Cr80 STL 5000' 4000' 3931' 9000' 8626' cab Liner - No Cement Planned 19. PRESENT WELL CONDITION SUMM ARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 11843 Total Depth TVD (ft): 8900 Plugs (measured): None Effective Depth MD (ft): 11810 Effective Depth TVD (ft): 8899 Junk (measured): None Casin Len th Size Cement Volume MD TVD r n r 114' 20" 60 sx Arctic Set A rox. 114' 114' 3514' 9-5/8" 95 sx CS III, 305 sx 'G', 187 sx CS I I 3548' 3546' 8522' 7" 35 sx Class 'G' 8554' 8324' Pr i 1560' 4-1/2" 16 sx Class 'G' 8341' - 9901' 8146' - 8921' Liner 2464' 3-~n• x 3-3/16• x z-7ie° 108 sx Class 'G' 9379' - 11843' 8930' - 8900' Perforation Depth MD (ft): 10360' - 11800' Perforation Depth TVD (ft): 8924' - 8898' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Barbara Holt, 564-5126 Printed Name Barbara Holt Title CT Drilling Engineer Prepared ey Name/Number. Si natur Phone 564-5126 Date CJf Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: API Number: 50- 029-22635-02-00 Permit Approval Date: .. ,. ~ See cover letter for other requirements Conditions of Approval: Sam s equired J Yes ~'No Mud Log Required ^ Yes ,~'No H roge Sulfide Measures Yes ^ No Directional Survey Required ~ Yes j No Other: j~ ~ ~ ~ G - ~ ~ ~ C~ p~ S.-c ~ . APPROVED BY A rov THE COMMISSION Date Form 10-401 `Fiwis9(~4 ~ i i r'~_ ; ~ t ~~~ } _ _ ~ ~E ~ f S~bnyR In Duplicate by To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Barbara M. Holt, CTD Engineer Date: November 3, 2005 Re: Prep Prudhoe 15-48A for CTD sidetrack • The sidetrack, 15-488, is scheduled to be drilled by Nordic 1 during the second week of November. The plan calls for running a Baker 4-1/2" monobore packer retrievable whipstock for an exit into Zone lA. 15-488 /'~ will target Zone lA production. 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. CTD Sidetrack Summary Rig Work: 1. MIRU Nordic 1 and test BOPE to 250 psi low and 3500 psi high.. ~ 2. Mi113.80" window at 9205' MD (8784' ss) in Zone lA. / 3. Drill approximately 2595' of horizontal sidetrack into Zone lA target. Bit selection size from 4.25" to 3.75". 4. Run 3-3/16" x 2-7/ solid liner, TOL at 9000' MD (8626'ss). j~ 5. Cement liner wit 34 bls 15.8 ppg cement to place top of cement at TOL. 6. Cleanout liner an est to 2000 psi. 7. Log memory CNL/GR/CCL from the tubing tail to PBTD. 8. Run 3-1/2" scab liner to 4000' MD. 9. Perforate liner as per Asset instructions, approximately 1000' of perforations expected. ~ 10. Freeze protect well and RDMO. Mud Program: • Well kill: 8.5 ppg 'ne • Milling/drilling: 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. Casing Program: • 3 3/16" x 2 7/8" fully cemented liner • A minimum of 34 bbls 15.8 ppg cement will be used for liner cementing. ~ Casin finer Inform~on • OD Grade Wei ht Burst / Colla se 9-5/8" L-80 47# 6870 si 4760 si 7" L-80 26# 7240 si 5410 si 4-1/2" L-80 12.6# 8440 si 7500 si 3-3/16" L-80 6.2# 8520 si 7660 si 2-7/8" L-80 6.17# 10,570 si 11,160 si 3-1l2" 13Cr-80 9.2# 10,160 si 10,530 si 4-1/4" - 3-3/4' O en hole 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. Maximum planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 26,200 ft. • Distance to nearest well within pool - 450 ft. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. • Log memory CNL/GR/CCL from the tubing tail to PBTD. Hazards • DS 15 is not an H2S drill site. The highest concentration recorded in well 15-48A was 15 ppm, ~ recorded on 12/08/2003. • Lost circulation risk is moderate, though no fault crossings are anticipated. Reservoir Pressure • Res. press. is estimated to be 3250 psi at 8787'ss (7.1 ppg EMW • Maximum surface pressure with gas (0.10 psi/ft) to surface is 7 psi. Barbara M. Holt ~'~i~ ~~l ~~~' `''~ CTD Drilling Engineer 564-5126 CC: Well File Sondra Stewman/Terrie Hubble • • ~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~.. Company:' BP AMOCO Dates' 10/28/2005 Time: 13:17:53 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-48, True North ,Site: PB DS 15 Vertical (TYD)_Reference: 66:48 5/30/1996 17:14 66.7 Well:. 15-48 Sectioa (VS) Reference: Well (O.OON,O.OOE,218.52Azi) Weltpath: - PIanS, 15-486 Survey Calculation Method: Minimum Curvature Db: OraGe 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 Geomsgnetlc Model: bggm2005 Site: PB DS 15 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Levei: 0.00 ft Grid Convergence: 1.34 deg Well: 15-48 Slot Name: 48 15-48 We11 Position: +N/-S 1343.00 ft Northing: 5960178.22 ft Latitude: 70 17 48.445 N +E/-W -72.17 ft Eastiug : 676193.34 ft Longitude: 148 34 23.317 W Position Uncertainty: 0.00 ft Wellpath: PIanS, 15-486 Drilled From: 15-48 500292263501 Tie-on Depth: 9188.44 ft Current Datum: 66:48 5/30/1996 17:14 Height 66.70 ft Above System Datum: Mean Sea Level Magnetic Data: 10/28/2005 Declination: 24.80 deg Field Strength: 57609 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.70 0.00 0.00 218.52 Plan: Plan #5 Date Composed: 10/28/2005 Copy Lamar's PIanS Version: 2 Principal; Yes Tied-to: From: Definitive Path Targets Map Map <- Latitude -> <-- Longitude -> Name Description TVD +N/-S +El•W Northing Fasting Deg Min Sec Deg Miu Sec Dip. Dir. ft ft ft ft ft 15-486 Polygon 66.70 -593.64 -1696.83 5959545.00 674511.00 70 17 42.604 N 148 35 12.773 W -Polygon 1 66.70 -593.64 -1696.83 5959545.00 674511.00 70 17 42.604 N 148 35 12.773 W -Polygon 2 66.70 -1364.77 -1744.92 5958773.00 674481.00 70 17 35.020 N 148 35 14.170 W -Polygon 3 66.70 -1837.01 -2083.11 5958293.00 674154.00 70 17 30.375 N 148 35 24.022 W -Polygon 4 66.70 -2506.11 -2173.82 5957622.00 674079.00 70 17 23.794 N 148 35 26.660 W -Polygon 5 66.70 -2614.78 -1848.26 5957521.00 674407.00 70 17 22.726 N 148 35 17.172 W -Polygon 6 66.70 -1984.25 -1733.44 5958154.00 674507.00 70 17 28.928 N 148 35 13.831 W -Polygon 7 66.70 -1355.98 -1394.60 5958790.00 674831.00 70 17 35.107 N 148 35 3.960 W -Polygon 8 66.70 -663.79 -1350.36 5959483.00 674859.00 70 17 41.915 N 148 35 2.674 W 15-486 Fault 1 66.70 -566.61 -2252.38 5959559.00 673955.00 70 17 42.869 N 148 35 28.966 W -Polygon 1 66.70 -566.61 -2252.38 5959559.00 673955.00 70 17 42.869 N 148 35 28.966 W -Polygon 2 66.70 -2152.22 -2334.58 5957972.00 673910.00 70 17 27.274 N 148 35 31.347 W 15-488 Fault 2 66.70 -1954.38 -2538.01 5958165.00 673702.00 70 17 29.219 N 148 35 37.277 W -Polygon 1 66.70 -1954.38 -2538.01 5958165.00 673702.00 70 17 29.219 N 148 35 37.277 W -Polygon 2 66.70 -2355.96 -2263.33 5957770.00 673986.00 70 17 25.271 N 148 35 29.269 W 15-488 Fault 3 66.70 -2722.37 -2165.89 5957406.00 674092.00 70 17 21.667 N 148 35 26.427 W -Polygon 1 66.70 -2722.37 -2165.89 5957406.00 674092.00 70 17 21.667 N 148 35 26.427 W -Polygon 2 66.70 -3148.33 -1917.79 5956986.00 674350.00 70 17 17.479 N 148 35 19.194 W 15-488 Fault 4 66.70 -351.46 -1188.98 5959799.00 675013.00 70 17 44.987 N 148 34 57.972 W -Polygon 1 66.70 -351.46 -1188.98 5959799.00 675013.00 70 17 44.987 N 148 34 57.972 W -Polygon 2 66.70 -823.30 -1160.03 5959328.00 675053.00 70 17 40.347 N 148 34 57.126 W 15-486 Target 1 66.70 -776.88 -1561.08 5959365.00 674651.00 70 17 40.803 N 148 35 8.815 W • • ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco -Date: `" 10/28!2005 T'swe: 13:17:53 Page: 2 'Field:. Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-48, True North Site: PB D315 Vertical (TVD) Reference: 66:48 5/30!1996 17:14 66.7 Weil: 1 5-48 Seetion (VS) Reference: Well (O.OON,O.OOE,218.52Azi) ' Welipat6: PIanS, 15-486 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <-- Latitude -> <- Longitude --> Name Description TVI) +N/-S +E/-W" Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 15-486 Target 2 66.70 -1277.69 -1533.81 5958865.00 674690.00 70 17 35.877 N 148 35 8.018 W 15-488 Target 3 66.70 -1600.59 -1841.48 5958535.00 674390.00 70 17 32.701 N 148 35 1 6.982 W 15-486 Target 4 66.70 -2551.1 7 -2043.84 5957580.00 674210.00 70 17 23.351 N 148 35 22.871 W Annotation MD TVD ft ft 9188.44 8839.68 TIP 9205.00 8850.58 KOP 9225.00 8863.37 End of 9°/100' DLS 9347.80 8905.61 4 9422.80 8907.50 End of 35°/100' DLS 9592.80 8911.41 6 9842.80 8916.66 7 10342.80 8926.63 8 10492.80 8928.82 9 10792.80 8932.17 10 10942.80 8934.53 11 11442.80 8943.46 12 11800.00 0.00 TD Plsn Section Information MD Inc! Azim TVD +NI-S +E/-W DLS Build Tura TFO Target ft deg deg ft ft ft deg/100ft deg/100ft'deg/700ft deg 9188.44 48.27 259.80 8839.68 -318.06 -1224.55 0.00 0.00 0.00 0.00 9205.00 49.45 261.78 8850.58 -320.05 -1236.86 11.48 7.13 11.96 52.30 9225.00 51.01 260.62 8863.37 -322.41 -1252.05 9.00 7.82 -5.79 330.00 9347.80 88.50 237.60 8905.61 -365.10 -1355.87 35.00 30.53 -18.75 325.00 9422.80 88.65 211.34 8907.50 -418.14 -1407.93 35.00 0.21 -35.01 270.00 9592.80 88.74 190.93 8911.41 -575.83 -1468.89 12.00 0.05 -12.00 270.00 9842.80 88.91 160.93 8916.66 -822.30 -1451.35 12.00 0.07 -12.00 270.00 10342.80 89.02 220.94 8926.63 -1291.00 -1541.88 12.00 0.02 12.00 90.50 10492.80 89.32 238.94 8928.82 -1387.13 -1656.20 12.00 0.20 12.00 89.20 10792.80 89.45 202.93 8932.17 -1610.05 -1849.53 12.00 0.04 -12.00 270.00 10942.80 88.76 220.92 8934.53 -1736.81 -1928.52 12.00 -0.46 11.99 92.30 11442.80 89.38 160.92 8943.46 -2205.55 -2018.94 12.00 0.12 -12.00 270.00 11800.00 89.55 203.78 8946.96 -2554.17 -2033.26 12.00 0.05 12.00 90.00 Survey MD Incl. Azim SS TVD N/S E/W MapN MapE -DLS VS TFO Tool ft deg deg ft ft ,ft ft ft deg/100ft ft deg 9188.44 48.27 259.80 8772.98 -318.06 -1224.55 5959831.56 674976.66 0.00 1011.50 0.00 MWD 9200.00 49.09 261.19 8780.62 -319.49 -1233.11 5959829.92 674968.13 11.48 1017.96 52.30 MWD 9205.00 49.45 261.78 8783.88 -320.05 -1236.86 5959829.27 674964.40 11.48 1020.73 51.38 MWD 9225.00 51.01 260.62 8796.67 -322.41 -1252.05 5959826.57 674949.27 9.00 1032.03 330.00 MWD 9250.00 58.34 254.74 8811.13 -326.80 -1271.94 5959821.71 674929.49 35.00 1047.86 325.00 MWD 9275.00 65.89 249.73 8822.82 -333.57 -1292.95 5959814.45 674908.65 35.00 1066.23 328.41 MWD 9300.00 73.58 245.29 8831.47 -342.55 -1314.58 5959804.97 674887.23 35.00 1086.74 330.76 MWD 9325.00 81.37 241.19 8836.89 -353.54 -1336.35 5959793.47 674865.73 35.00 1108.89 332.30 MWD 9347.80 88.50 237.60 8838.91 -365.10 -1355.87 5959781.46 674846.48 35.00 1130.10 333.19 MWD 9350.00 88.50 236.82 8838.97 -366.29 -1357.72 5959780.22 674844.66 35.00 1132.18 270.00 MWD 9375.00 88.52 228.07 8839.62 -381.51 -1377.52 5959764.55 674825.23 35.00 1156.41 270.02 MWD 9400.00 88.58 219.32 8840.25 -399.56 -1394.77 5959746.10 674808.41 35.00 1181.28 270.25 MWD 9422.80 88.65 211.34 8840.80 -418.14 -1407.93 5959727.21 674795.68 35.00 1204.02 270.47 MWD 9425.00 88.65 211.07 8840.85 -420.02 -1409.07 5959725.31 674794.59 12.00 1206.20 270.00 MWD • • ep Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~.. ~~ IiVTEtj Company: BP Amoco Date: 10/28/2005 Time: 13:17;53 Page: 3 Field:. Prudhoe$ay Co-ordinate(NE) Reference: Welly 15-48, True North Site: PB DS 15 :Vertical (TVA)Refereoce: 66:48 5/30(1996 17:14 66.7 Well: 15-48 SeMion (VS) Reference: Well (O.OON ,I).OOE,218.52Azi) Wellpath: PIan5, 15-48B Survey Calculation Method: Minimum'Curvature Db: OraGe Survey MD Iucl Azim ... SS TVA N/S FJW MapN ' MapE DLS VS TFO Tool ft :.deg deg ft ft ft ft ft degl100ft ft deg 9450.00 88.66 208.07 8841.44 -441.76 -1421.41 5959703.29 674782.77 12.00 1230.89 270.01 MWD 9475.00 88.66 205.07 8842.03 -464.11 -1432.59 5959680.68 674772.12 12.00 1255.33 270.08 MWD 9500.00 88.67 202.07 8842.61 -487.01 -1442.58 5959657.55 674762.66 12.00 1279.48 270.15 MWD 9525.00 88.69 199.07 8843.1'..8 -510.41 -1451.36 5959633.96 674754.43 12.00 1303.25 270.22 MWD 9550.00 88.70 196.07 8843.75 -534.23 -1458.90 5959609.96 674747.45 12.00 1326.59 270.29 MWD 9575.00 88.72 193.07 8844.32 -558.42 -1465.19 5959585.64 674741.73 12.00 1349.43 270.35 MWD 9592.80 88.74 190.93 8844.71 -575.83 -1466.89 5959568.15 674738.44 12.00 1365.35 270.42 MWD 9600.00 88.74 190.07 8844.87 -582.90 -1470.20 5959561.04 674737.30 12.00 1371.71 270.00 MWD 9625.00 88.74 187.07 8845.42 -607.62 -1473.93 5959536.25 674734.16 12.00 1393.36 270.02 MWD 9650.00 88.75 184.07 8845.97 -632.49 -1476.35 5959511.33 674732.31 12.00 1414.33 270.08 MWD 9675.00 88.76 181.07 8846.51 -657.46 -1477.47 5959486.35 674731.78 12.00 1434.56 270.15 MWD 9700.00 88.77 178.07 8847.05 -682.45 -1477.28 5959461.37 674732.56 12.00 1453.99 270.22 MWD 9725.00 88.79 175.06 8847.56 -707.39 -1475.78 5959436.47 674734.64 12.00 1472.58 270.28 MWD 9750.00 88.81 172:06 8848.11 -732.23 -1472.98 5959411.71 674738.02 12.00 1490.26 270.34 MWD 9775.00 88.83 169.06 8848.62 -756.88 -1468.88 5959387.16 674742.69 12.00 1507.00 270.41 MWD 9800.00 88.86 166.06 8849.13 -781.29 -1463.50 5959362.89 674748.65 12.00 1522.74 270.47 MWD 9825.00 88.89 163.06 8849.62 -805.38 -1456.85 5959338.96 674755.86 12.00 1537.45 270.53 MWD 9842.80 88.91 760.93 8849.96 -822.30 -1451.35 5959322.17 674761.76 12.00 1547.26 270.59 MWD 9850.00 88.90 161.79 8850.10 -829.12 -1449.05 5959315.41 674764.22 12.00 1551.16 90.50 MWD 9875.00 88.88 164.79 8850.59 -853.06 -1441.86 5959291.65 674771.96 12.00 1565.42 90.48 MWD 9900.00 88.86 167.79 8851.08 -877.34 -1435.94 5959267.51 674778.45 12.00 1580.72 90.43 MWD 9925.00 88.84 170.79 8851.58 -901.90 -1431.30 5959243.07 674783.67 12.00 1597.04 90.37 MWD 9950.00 88.82 173.79 8852.09 -926.66 -1427.94 5959218.39 674787.60 12.00 1614.33 90.31 MWD 9975.00 88.81 176.79 8852.61 -951.57 -1425.89 5959193.54 674790.24 12.00 1632.54 90.24 MWD 10000.00 88.81 179.79 8853.13 -976.55 -1425.15 5959168.59 674791.57 12.00 1651.62 90.18 MWD 10025.00 88.80 182.79 8853.65 -1001.54 -1425.71 5959143.60 674791.59 12.00 1671.52 90.12 MWD 10050.00 88.80 185.80 8854.18 -1026.46 -1427.58 5959118.64 674790.30 12.00 1692.19 90.06 MWD 10075.00 88.80 188.80 8854.70 -1051.25 -1430.76 5959093.79 674787.71 12.00 1713.56 89.99 MWD '10100.00 88.81 191.80 8855.22 -1075.84 -1435.23 5959069.10 674783.82 12.00 1735.58 89.93 MWD 10125.00 88.81 194.80 8855.74 -1100.16 -1440.97 5959044.65 674778.64 12.00 1758.19 89.87 MWD 10150.00 88.83 197.60 8856.26 -1124.15 -1447.99 5959020.51 674772.19 12.00 1781.32 89.81 MWO 10175.00 88.84 200.80 8856.76 -1147.73 -1456.25 5958996.73 674764.49 12.00 1804.92 89.74 MWD 10200.00 88.86 203.80 8857.27 -1170.86 -1465.73 5958973.40 674755.55 12.00 1828.92 89.68 MWD 10225.00 88.88 206.80 8857.76 -1193.45 -1476.41 5958950.56 674745.41 12.00 1853.25 89.62 MWD 10250.00 88.91 209.50 8858.24 -1215.46 -1488.26 5958928.28 674734.08 12.00 1877.84 89.56 MWD 10275.00 88.93 212.80 8858.71 -1236.81 -1501.24 5958906.63 674721.60 12.00 1902.64 89.51 MWD 10300.00 88.96 215.80 8859.17 -1257.46 -1515.33 5958885.66 674708.00 12.00 1927.56 89.45 MWD 10325.00 89.00 218.80 8859.62 -1277.34 -1530.47 5958865.43 674693.33 12.00 1952.55 89.39 MWD 10342.80 89.02 220.94 8859.93 -1291.00 -1541.88 5958851.51 674682.24 12.00 1970.34 89.34 MWD 10350.00 89.03 221.80 8860.05 -1296.40 -1546.64 5958846.00 674677.61 12.00 1977.53 89.20 MWD 10375.00 89.08 224.80 8860.46 -1314.59 -1563.78 5958827.41 674660.91 12.00 2002.44 89.19 MWD 10400.00 89.12 227.80 8860.85 -1331.66 -1581.85 5958809.73 674643.25 12.00 2027.20 89.14 MWD 10425.00 89.17 230.80 8861.23 -1348.16 -1600.80 5958792.99 674624.68 12.00 2051.76 89.09 MWD 10450.00 89.22 233.80 8861.58 -1363.44 -1620.58 5958777.25 674605.27 12.00 2076.03 89.04 MWD 10475.00 89.28 236.80 8861.90 -1377.67 -1641.13 5958762.54 674585.06 12.00 2099.96 89.00 MWD 10492.80 89.32 238.94 8862.12. -1387,13 -1656.20 5958752.73 674570.22 12.00 2116.75 88.96 MWD 10500.00 89.32 238.07 8862.21. -1390.90 -1662.34 5958748.82 674564.17 12.00 2123.52 270.00 MWD 10525.00 89.32 235.07 8862.50'.. -1404.67 -1683.20 5958734.57 674543.64 12.00 2147.29 270.01 MWD 10550.00 89.32 232.07 8862.80' -1419.51 -1703.31 5958719.26 674523.88 12.00. 2171.42 270.05 MWD 10575.00 89.33 229.07 8863.10. -1435.38 -1722.62 5958702.94 674504.95 12.00 2195.87 270.08 MWD 10600.00 89.33 226.07 8863.39 -1452.25 -1741.07 5958685.65 674486.91 12.00 2220.55 270.12 MWD 10625.00 89.34 223.07 8863.68 -1470.05 -1758.61 5958667.44 674469.79 12.00 2245.41 270.15 MWD • • by Baker Hughes INTEQ Baker Hughes INTEQ Planning Report tNTEQ ..Company: BP Amoco - Date:> 10/28!2005 Time: 13:1T53 Page: 4~ Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-48, True North Site: PB DS 15 Vertical (TVD) Reference: 66:48 5/30/199617:14 66.7 Well: 15-48 Section (VS) Reference: Well (O.OON O:OOE,218. 52Azi) Welipat6c` PIan5,15-486 Survey Calculation Method: , Minimum Curvature Db: Oracte ~ Survey MD ' Incl. Azim SS TVD =N/S E/Vy MapN MapE DI.5 r VS TFO Tool ~ ft deg deg ft ft ft ft ft deg/1OOff ft deg 10650.00 89.35 220.07 8863.96 -1488.75 -1775.19 5958648.35 674453.65 12.00 2270.37 270.19 MWD 10675.00 89.37 217.07 8864.24 -1508.30 -1790.78 5958628.45 674438.53 12.00 2295.36 270.22 MWD 10700.00 89.38 214.07 8864.52 -1528.63 -1805.32 5958607.79 674424.47 12.00 2320.33 270.25 MWD 10725.00 89.40 211.07 8864.78 -1549.69 -1818.77 5958586.41 674411.51 12.00 2345.19 270.29 MWD 10750.00 89.41 208.07 8865.04 -1571.43 -1831.11 5958564.39 674399.69 12.00 2369.88 270.32 MWD 10775.00 89.43 205.07 8865.30 -1593.79 -1842.29 5958541.78 674389.03 12.00 2394.33 270.35 MWD 10792.80 89.45 202.93 8865.47 -1610.05 -1849.53 5958525.36 674382.18 12.00 2411.56 270.38 MWD 10800.00 89.41 203.80 8865.54 -1616.66 -1852.39 5958518.69 674379.48 12.00 2418.51 92.30 MWD 10825.00 89.29 206.80 8865.82 -1639.25 -1863.07 5958495.84 674369.33 12.00 2442.84 92.29 MWD 10850.00 89.18 209.79 8866.16 -1661.26 -1874.91 5958473.56 674358.00 12.00 2467.44 92.26 MWD 10875.00 89.06 212.79 8866.54 -1682.62 -1887.90 5958451.91 674345.53 12.00 2492.24 92.22 MWD 10900.00 88.95 215.79 8866.98 -1703.27 -1901.98 5958430.94 674331.93 12.00 2517.16 92.17 MWD 10925.00 88.84 218.79 8867.46 -1723.15 -1917.12 5958410.71 674317.26 12.00 2542.15 92.12 MWD 10942.80 88.76 220.92 8867.83 -1736.81 -1928.52 5958396.78 674306.18 12.00 2559.94 92.06 MWD 10950.00 88.76 220.06 8867.99 -1742.29 -1933.20 5958391.20 674301.64 12.00 2567.13 270.00 MWD 10975.00 88.77 217.06 8868.53 -1761.83 -1948.78 5958371.30 674286.52 12.00 2592.13 270.02 MWD 11000.00 88.77 214.06 8869.06 -1782.16 -1963.31 5958350.64 674272.47 12.00 2617.08 270.08 MWD 11025.00 88.78 211.06 8869.60 -1803.23 -1976.76 5958329.26 674259.52 12.00 2641.94 270.15 MWD 11050.00 88.79 208.06 8870.13 -1824.96 -1989.09 5958307.24 674247.71 12.00 2666.63 270.21 MWD 11075.00 88.81 205.06 8870.65 -1847.32 -2000.26 5958284.63 674237.06 12.00 2691.08 270.28 MWD 11100.00 88.83 202.06 8871.16 -1870.23 -2010.25 5958261.50 674227.61 12.00 2715.22 270.34 MWD 11125.00 88.85 199.06 8871.67 -1893.63 -2019.02 5958237.90 674219.39 12.00 2738.99 270.40 MWD 11150.00 88.88 196.05 8872.17 -1917.46 -2026.56 5958213.90 674212.41 12.00. 2762.33 270.46 MWD 11175.00 88.91 193.05 8872.65 -1941.65 -2032.84 5958189.57 674206.70 12.00 2785.17 270.52 MWD 11200.00 88.94 190.05 8873.12 -1966.13 -2037.85 5958164.98 674202.27 12.00 2807.44 270.58 MWD 11225.00 88.97 187.05 8873.57 -1990.85 -2041.56 5958140.18 674199.14 12.00 2829.09 270.63 MWD 11250.00 89.01 184.05 8874.01 -2015.73 -2043.98 5958115.26 674197.30 12.00 2850.06 270.69 MWD 11275.00 89.05 181.05 8874.44 -2040.69 -2045.10 5958090.27 674196.77 12.00 2870.29 270.74 MWD 11300.00 89.09 178.05 8874.84 -2065.69 -2044.90 5958065.29 674197.55 12.00 2889.72 270.79 MWD 11325.00 89.14 175.05 8875.23 -2090.64 -2043.40 5958040.39 674199.64 12.00 2908.31 270.84 MWD 11350.00 89.19 172.05 8875.59 -2115.47 -2040.59 5958015.63 674203.03 12.00 2925.99 270.89 MWD 11375.00 89.24 169.05 8875.94 -2140.13 -2036.49 5957991.07 674207.71 12.00 2942.73 270.93 MWD 11400.00 89.29 166.05 8876.26 -2164.54 -2031.10 5957966.80 674213.67 12.00 2958.47 270.97 MWD 11425.00 89.34 163.05 8876.56 -2188.63 -2024.45 5957942.87 674220.88 12.00 2973.17 271.01 MWD 11442.80 89.38 160.92 8876.76 -2205.55 -2018.94 5957926.08 674226.78 12.00 2982.98 271.05 MWD 11450.00 89.38 161.78 8876.83 -2212.38 -2016.64 5957919.32 674229.25 12.00 2986.89 90.00 MWD 11475.00 89.38 164.78 8877.10 -2236.31 -2009.45 5957895.55 674236.99 12.00 3001.14 89.99 MWD 11500.00 89.39 167.78 8877.37 -2260.60 -2003.52 5957871.42 674243.49 12.00 3016.44 89.96 MWD 11525.00 89.39 170.78 8877.64 -2285.16 -1998.$7 5957846.98 674248.71 12.00 3032.76 89.93 MWD 11550.00 89.40 173.78 8877.90 -2309.93 -1995.52 5957822.29 674252.65 12.00 3050.05 89.89 MWD 11575.00 89.41 176.78 8878.17 -2334.84 -1993.46 5957797.44 674255.29 12.00 3068.26 89.86 MWD 11600.00 89.41 179.78 8878.42 -2359.82 -1992.71 5957772.48 674256.62 12.00 3087.34 89.83 MWD 11625.00 89.43 182.78 8876.68 -2384.81 -1993.27 5957747.49 674256.65 12.00 3107.24 89.80 MWD 11650.00 89.44 185.78 8878.92 -2409.74 -1995.14 5957722.53 674255.36 12.00 3127.91 89.77 MWD 11675.00 89.45 188.78 8879.17 -2434.53 -1998.31 5957697.67 674252.78 12.00 3149.28 89.74 MWD 11700.00 89.47 191.78 8879.40 -2459.13 -2002.77 5957672.97 674248.89 12.00 3171.30 89.71 MWD 11725.00 89.49 194.78 8879.63 -2483.45 -2008.52 5957648.52 674243.72 12.00 3193.91 89.68 MWD 11750.00 89.51 197.78 8879.85 -2507.45 -2015.52 5957624.37 674237.28 12.00 3217.05 89.66 MWD 11775.00 89.53 200.78 8880.06 -2531.04 -2023.78 5957600.59 674229.58 12.00 3240.65 89.63 MWD r 11800.00 89.55 203.78 8880.26 -2554.17 -2033.26 5957577.25 674220.65 12.00 3264.65 89.60 MWD BP Amoco rrnu4nr oor4ns n..s~s4as nooss eaN~ r...m sr.r~r is~o rr.«ra otN.w ww. o.eµ~r N : N vw+oN 11H4 N.mt v °.~ e.r~owr ir'«r~i ro ~N.oo' om om ae.>'o __ REFERENCE INFORMATION Co-ardna~e (WE) Reference: WeY Centre: 15-48. True North Vertical ( D) Reference: Svslem: Mean Sea Level Section (VS)Re/erence: Slot-46 (O.OON,O.OOE) Measured Depth Reference: 86:48 5/30/19% 17:14 Bfi DeICWaGOn Melhad: Minimum Curvature r ,..~ HO 1N Mrwlarl-- ~"- w Nt• 41T4.N MN.M lV aTtlJ4 °tOe.40 {Or 4M.fr °4]4.00 WM°'H00'0Y >ree°~j ~ ~ vd~vm NN.N 4N1J4 4 Y40.N Wise W MN'HO0' OlJ 4444.11 444240 YB T-p-r W iTi ~S~! m voM 1oafM vu. OCO rsf~ ~r N44.~1 ~OYIip • . 44411410444.40 4WA140MN 10 °°°~6 )410941°0 11 ;WAO 14 N.)O1 400.00 Tf yOJ °V ~a r Hv d d H 100 200 300 400 i ^~.~ BAKER HUGHES ~~ LEGEND lsee'1sr6) -- ,Sae ,SdBA> Flans,ls~s6 %~ N5 T AZIf11Dih5 l0 True North M Magnetic North: 24.80° Magnetic Field Rlan. Flan N5 (15.48rPIenS, 15-4ba) creatadeyeieMia[aelson Date: 10/262005 ---- - ----- comae[ Intormaoon '~!1 Slren9th: 57609nT Dip Angle: 80.90° Date: 10/28/2005 Br; Michaelson Direa~ (907) 267-6624 CeIP. (907)301-73670 ``ll Model: bggm2005 E-mail: bdLmichaeison@~n1eU coin -1900 t -2000 _ :~:, West(-)/East(+) [100ftlin] j iljj ilj ~~' :I: jj::I( ~~ ~1; ). _,~~~~ ;r;t- ~:::: ~;! I'~-i-~ - ~~•' ''li :~~ -~ ~.i:..-:.} 1; - I •-; ~~ T~.:.~~..~ I~ .-Ii ~I ~ i+.~ I 1 IJ -900 -800 -700 -600 -500 300 -300 PM • • Vertical Section at 190.00° [100ft/in] • ~ • TERRIE L RUBBLE BP EXPLORATION AK INC ., as-slzs2 235 PO BOX T96612 MB 7-5 Mastercard Check" ANCHORAGE, AK 99519-6612 DATE I ~~~5 PAY TO THE ORDER OF $ ~ `~ ` First ation 1 ank Alaska LABS Anchorage, AK 99501 MEMO ': i 2'S 200060:99 Ly~~~6 2 ~ 7... ,; L556~~ 0235 a • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~ ,^ s PTD# CHECK WHAT ADD-ONS "CLUE" i APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of .the origins! API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (per ~ records, data and logs acquired for the pilot ~ hole must be clearly differentiated in both ~ name (name on permit plus PH) and API number (50 - 70/80) from records, data and togs acquired for well (name on permit). SPACING The permit is approved subject to full ', EXCEPTION compliance with 20 AAC 25.055. Approval to '~~ f perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. ~ i ~ , ~ (Company Name) assumes the liability of any protest to the spacing exception that may occur. I DRY DITCH Ail dry ditch sample sets submitted to the 'I 0' ~ SAMPLE Commission must be in no greater than 3 sample intervals from below the permafrost or from where samples are first caught and ~ 10' sample intervals through target zones. ~ I Rev: oaro vos C\jody\transmitta{_checklist WELL PERMlT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL • 640150 _ i Well Name: PRUDHDE BAY UNIT 15-486 ____Program DEV _ Well bore seg ^ PTD#:2051660 Company BP EXPLORATION (ALASKA) INC Initial Classffype DEV 11-OIL GeoArea 890 Unit 11550 On/Off Share On Annular Disposal ^ Administration 1 Permit_feeattached_--_-_-__-____ -_-__ -_-_-_-__--_-_-_ Yes_ _______________________ 2 Lease numberappropriate_ _ - _ - - - _ - _ Yes _ _ _ - - _ - - . 3 Uniquewell_nameandnumbe[______________________________________ Yes_ _____-._--_.-__-___,-.- 4 Well located in a_defined-pool- -_ -____-_-_ Yes_ ___________________ 5 Well located pr_operdistance_from drilling unit_boundary_ - - Yes - - - - _ - 6 Well located properdistance-f[omotherwells---------------------- --- --- Yes_ ,_-___.__- - - 7 Sufficient acreage available in_drilling unit_ , - _ _ _ _ - Yes - _ _ 8 If deviated,is_wellboreplat_included________________.-_-___-_-_--_._-_ Yes- ----_-_ 9 Oparalot only affected park' - Yes - - - - - - - ~ - ~ - - - - - 10 Operator has.appropriate.bondinforce-----------------------_-..----- Yes_ ._._-._.--_-_._-_--_.____._____._--. 11 Permit can be issued without conservation order Yes Appr Date 12 Permitc_an be issued without administrative_approval - - - , - , Yes RPC 11!412005 13 Can permit be approved before 15-day wait No 14 Well located within area and-strata authorized by-Injection Order# (put_10# in_comments)_(For. NA- _ - _ _ _ - _ . _ - _ - _ _ - _ - _ _ _ _ - _ - , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - - . _ _ - 15 All wells within 1!4_mile area of review identified {For service well only) _ . _ - _ _ _ - . _ _ NA- - - - - - - - - - - - - - - - _ _ _ - . - - _ _ _ _ . - 1fi Pre-produced injector: duration of pre production less than 3 months-(FOr_service well only) _ - NA_ _ - _ - _ , _ _ _ 17 ACMP-Finding of Consistency_has been issuedfor-this project- - . - _ - _ - NA_ _ - - - - - Engineering 18 Conductor string_provided - - - - - - - . - - . NA_ - - _ 19 Surface casing protects all-known USDWs - - - - NA - _ 20 CMT v_ol adequafe_to circulate-on conductor & surf-csg _ _ _ _ - _ . - NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 CMT vol adequate.to tie-in long string to surfcsg- - _ NA_ 22 CMT_will cover all known-productive horizons_ - - - - - - Yes - - - - Adequate excess, - 23 Casing designs adequate f_or C,.T, B &-permafrost - Yes 24 Adequate tankage_or reserve Pit - Yes CTDU.. - _ 25 If-a_re-drill, has-a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - Yes _ - _ - _ _ 11/4/2005, 26 Adequate wellbore.ceparation-proposed- - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 27 Ifdiverterrequired,doesitmeetregulatiogs___-_-.-__--_-__-_--_-_- -__- NA_- __-___$idetrack. -_-_________________ _,-_-_---.--.-__---____--_ Appr Date 28 Drillingfluid-programschematic&e4uiplistadequate-__-_-_-___-_-_._ -_-_, Yes- -___-_MaxMW 8,6ppg.__._-__._-_-_-_-___---_______-- -_-_-_-_----_-- WGA 11/7/2005 29 BOPEs,_dotheymeetregu_lation_,----------------- ----- Yes- ---------.------- -------------------- --.-----------_-------- ,---- 30 BOPE_press rating appropriate; test to_(put prig incomments)- - - - _ _ _ . _ - _ _ - _ - _ - Yes _ - _ - _ - _ Test to 3500_ psi. -M$P 2371 psi.- _ _ _ _ - _ _ - - - - - - - - - - - - - - - - - - - - - - - _ _ - _ _ - - - - 31 Choke-manifold complieswlAPI-RP-53 {May84)___-__- __--_-__ _-_._ Yes- _-___--____,_-_ 32 Work will occur without operation shutdown_________________________ ___ _ Yes_ -___---_--_- 33 Is presence ofH2Sgasprobable--------------------------- N°-- ------Not anH2SPad.-----------------.---- ---.---.--------_-------- --.-- 34 Mechanical ~onddion of wells within AOR verified {For_s_ervice well only) - , - - - _ - NA- _ _ - - - - . - - Geology 35 Permit_can be issuedwlo hydr-ogegsulfidemeasures- - No- - - - - - 36 Data-p_resentedonpotenkialoverpressurezones ------ ---------------- --- NA__ _._-____-_-_ --. Appr Date 37 Seismic znalysis of shallow gas zones- _ _ - - _ - _ _ _ _ - _ _ _ _ - _ - - _ _ , - _ NA- _ _ _ _ - - _ - RPC 11/412005 38 Seabed condition survey-(ifoff-shore) - _ _ - - - - _ - - - - _ NA_ _ - 39 - Contact namelphone for weekly progress_reporls [exploratory onlyj- _ _ _ - - NA_ . - - - Geologic Engineering Pu Commissioner: Date: Commissioner: Date Co ' sio Date ~ f~~" • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special-effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 16 14:43:41 2006 Reel Header Service name .............LISTPE Date .....................06/02/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/02/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. r: Scientific Technical Services Scientific Technical Services Physical EOF g~ l Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: 15-48B API NUMBER: 500292263502 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 16-FEB-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0004054361 MW0004054361 MW0004054361 LOGGING ENGINEER: B. JAHN B. JAHN S. LATZ OPERATOR WITNESS: S. NOYNAERT S. NOYNAERT S. NOYNAERT MWD RUN 5 JOB NUMBER: MW0004054361 LOGGING ENGINEER: S. LATZ OPERATOR WITNESS: S. NOYNAERT SURFACE LOCATION SECTION: 22 TOWNSHIP: 11N RANGE: 14E FNL: FSL: 3971 FEL: 5021 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 66.70 DERRICK FLOOR: GROUND LEVEL: 32.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~,us-0b BIT SIZE (IN) 1ST STRING 4.125 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) 4.500 9195.0 • 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9195' MD IN THE 15-48 WELLBORE. THE WHIPSTOCK WAS POSITIONED DURING MWD RUN 1 - NO DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 2,3,5 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 4 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG), UTILIZING SCINTILLATION DETECTORS. UPHOLE SGRC TIE-IN DATA ACQUIRED WHILE POOH AFTER MWD RUN 2 WERE MERGED WITH RUN 2 MWD DATA. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 2f 13/06. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 2-5 REPRESENT WELL 15-48B WITH API#: 50-029-22635-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11646'MD/8872'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8932.5 ROP 9214.5 all bit runs merged. STOP DEPTH 11618.5 11645,0 • • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 8932.5 8931.5 8942.0 8941.0 8946.0 8946.0 8947.5 8949.0 8950.5 8950.5 8957.5 8957.0 8962.5 8961.5 9191.5 9189.5 9205.0 9204.0 9207.5 9206.0 9210.5 9210.0 9221.5 9220.5 9232.0 9232.0 9236.5 9237.0 9241.0 9240.5 9249.5 9247.5 9254.0 9252.5 9260.5 9263.0 9267.0 9270.5 9278.0 9282.0 9293.0 9297.5 9301.0 9305.0 9324.0 9328.5 9341.0 9342.5 9363.0 9361.5 9372.5 9368.5 9377.0 9373.5 9386.0 9382.0 9389.5 9389.0 9393.5 9395.0 9419.5 9418.0 9475.0 9472.0 9513.0 9513.0 9532.5 9531.5 9559.5 9558.5 9616.5 9615.0 9644.5 9640.5 9658.0 9654.5 9695.0 9693.0 9729.0 9728.0 9758.0 9757.5 9777.5 9774.5 9796.5 9791.0 9834.0 9829.5 9864.0 9861.0 9868.5 9866.0 9887.0 9884.0 9930.0 9926.5 9955.0 9951.0 10073.5 10067.5 10117.0 10116.0 10148.5 10149.5 10167.5 10167.0 10173.5 10174.5 10203.0 10203.0 10206.5 10208.0 10215.5 10214.0 10229.0 10229.0 10321.0 10322.0 10324.0 10325.5 10336.5 10337.0 10363.0 10363.5 10368.5 10367.0 10398.0 10398.0 10459.5 10458.5 10493.0 10492.5 10502.0 10498.5 10503.0 10500.0 10525.0 10521.5 10571.5 10568.0 10649.5 10650.0 10685.0 10686.0 10695.5 10696.5 10738.5 10738.5 10743.0 10743.5 10746.5 10749.0 10754.5 10754.5 10764.0 10765.0 10768.0 10770.0 10775.5 10777.0 10791.5 10792.0 10820.5 10820.0 10824.0 10824.0 10929.0 10928.0 10956.0 10952.5 10961.5 10957.5 10963.5 10960.0 10983,5 10979.5 10987.5 10984.5 10994.0 10990.5 11006.5 11004.0 11013.5 11009.0 11021.0 11018.5 11022.5 11019.5 11026.0 11023.0 11033.5 11030.0 11060.5 11058.0 11094.0 11091.5 11116.0 11112.0 11132.0 11128.0 11152.5 11147.5 11159.0 11155.0 11161.5 11156.5 11167.0 11164.0 11172.0 11171.5 11177.0 11176.5 11188.0 11187.0 11192.5 11191.5 11199.0 11197.5 11208.5 11205.5 11223.0 11222.0 11230.0 11229.0 11236.0 11235.5 11251.5 11249.5 11264.0 11262.0 11274.5 11273.5 11299.0 11298.0 11323.5 11322.0 11345.5. 11345.0 11358.0 11360.0 11366.0 11368.5 11371.5 11373.0 11375.5 11376°5 11645.0 11646.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 2 8931.5 MWD 3 9362.0 MWD 4 9433.0 MERGE BASE 9362.0 9433.0 10521.0 • • MWD 5 10521.0 11646.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8932.5 11645 10288.8 5426 8932.5 11645 ROP MWD FT/H 0.02 11 07.35 66.4075 4862 9214.5 11645 GR MWD API 17.47 203.3 71.6091 4930 8932.5 11618.5 First Reading For Entire File..........8932.5 Last Reading For Entire File...........11645 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH . GR 8931.5 9335.5 ROP 9214.0 9362.0 LOG HEADER DATA DATE LOGGED: 16-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9362.0 TOP LOG INTERVAL (FT) 9214.0 BOTTOM LOG INTERVAL (FT) 9362.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 48.7 MAXIMUM ANGLE: 82.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 72829 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 9203.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LBfG) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 131.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN}: EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .TIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8931.5 9362 9146.75 862 8931.5 9362 ROP MWD020 FT/H 1.14 140.42 35.7668 297 9214 9362 GR MWD020 API 17.47 195.67 58.9023 368 8931.5 9335.5 First Reading For Entire File..........8931.5 Last Reading For Entire File...........9362 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9336.0 9405.0 ROP 9362.5 9433.0 LOG HEADER DATA DATE LOGGED: 17-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9433.0 TOP LOG INTERVAL (FT}; 9362.0 BOTTOM LOG INTERVAL (FT): 9433.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.9 MAXIMUM ANGLE: 90.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 72829 ~i i BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 9203.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LBfG) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3) 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 134.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 ,0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY {HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9336 9433 9384.5 195 9336 9433 ROP MWD030 FT/H 0.02 45.53 25.9077 142 9362.5 9433 GR MWD030 API 77.14 1 29.66 102.617 139 9336 9405 First Reading For Entire File..........9336 Last Reading For Entire File...........9433 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02j16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER • FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9405.5 10491.5 ROP 9433.5 10521.0 LOG HEADER DATA DATE LOGGED: 18-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10521.0 TOP LOG INTERVAL (FT) 9433.0 BOTTOM LOG INTERVAL (FT) 10521.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.7 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (TN) 4.125 DRILLER'S CASING DEPTH (FT): 9203.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LBfG) 8.70 MUD VISCOSITY (S) 65.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 154.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: 0000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): ~- i EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9405.5 10521 9963.25 2232 9405.5 10521 ROP MWD040 FT/H 0.15 1107.35 64.8182 2176 9433.5 10521 GR MWD040 API 49.2 134.64 72.6165 2173 9405.5 10491.5 First Reading For Entire File..........9405.5 Last Reading For Entire File...........10521 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......5TSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10492.0 11619.5 ROP 10521.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT); BIT ROTATING SPEED {RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): i 11646.0 21-NOV-05 Insite 4.3 Memory 11646.0 10521.0 11646.0 84.3 96.0 TOOL NUMBER 72829 4.125 9203.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LO5S (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Flo Pro 8.70 65.0 8.9 26000 5.8 .000 .0 .000 162.6 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 ~ i First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10492 11646 11069 2309 10492 11646 ROP MWD050 FT/H 0.32 960.85 74.8404 2250 10521.5 11646 GR MWD050 API 23.61 203.83 70.6782 2256 10492 11619.5 First Reading For Entire File..........10492 Last Reading For Entire File...........11646 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/02f16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/02/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File
